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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lopez Keith To:Wallace, Chris D (OGC); Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay Cc:Lyden Dan; Dexheimer Stephen; Darsie Francesco; Lopez Keith Subject:Eni MIT"s for July 2024 Date:Wednesday, July 31, 2024 2:32:14 PM Attachments:image001.png MIT ODSN-23 07-20-24.xlsx MIT ODSN-40 07-20-24.xlsx MIT conducted in July 2024 by Eni. N23 – 4 year MIT N40 – 4 year MIT Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith.Lopez@eni.com 2RRJXUXN2'61 37' N40 – 4 year MIT Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2080390 Type Inj W Tubing 100 100 100 100 Type Test P Packer TVD 5929 BBL Pump 1.5 IA 840 1650 1600 1591 Interval 4 Test psi 1500 BBL Return 1.5 OA 224 224 287 284 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Eni US Operating Co Inc Oooguruk/ODS Brannon Starkweather 07/20/24 Notes:AOGCC Inspector did not stay to witness this test. Notes: Notes: Notes: ODSN-40 Form 10-426 (Revised 01/2017)2024-0720_MIT_Oooguruk_ODSN-40 9 9 9 9 999 9 9 -5HJJ Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Wednesday, November 13, 2019 8:29 AM To: Lopez Keith Cc: Regg, James B (CED); Rupert Stephanie Subject: RE: ODSK-35A (PTD#2100120) TxIA Communication Keith, Extension as requested below for shut in wells ODSK-35A and ODSN-40 is granted. Please add ODSK-35A (PTD 2100120), ODSN-40 (PTD 2080390), and ODSN-15 (PTD 2100320) to the monthly TIO report list that includes AIO 34.009 (ODSN-03) and AI034.010 (ODSN-07) until we get these wells compliant with their MIT's. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7`h Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace(@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska aov. From: Lopez Keith <Keith.Lopez@eni.com> Sent: Tuesday, November 12, 2019 3:07 PM To: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Rupert Stephanie <Stephanie.Rupert@eni.com> Subject: RE: ODSK-35A (PTD#2100120) TxIA Communication The path forward is to perform diagnostics and hopefully repair the leak on ODSK-35A before the end of the year. We currently have an extension on ODSN-15's 4 year MITIA until we have injection water supply back to the island and the well is back online (-January 2020). ENI would propose the same extension for ODSK-35A so we can conduct the MITIA's when the wells are on stable injection. Also please consider: ODSN-40 is a long-term shut in injector that is due for its 4 year MITIA this month as well. Having injection water back is not an issue since the well is a LTSI and the MITIA will be conducted cold. However, being shoulder season it may make logistical sense to have the inspector flown out once in January to witness all three M ITIA's. Please let us know if the AOGCC will grant an extension for ODSK-35A and/or ODSN-40 until we have seawater injection back to Oooguruk. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,November 23,2015 P.I.Supervisor i b� SUBJECT: Mechanical Integrity Tests CAELUS NATURAL RESOURCES ALASK ODSN-40 FROM: Johnnie Hill 000GURUK NUQ ODSN-40 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name 000GURUK NUQ ODSN-40 API Well Number 50-703-20571-00-00 Inspector Name: Johnnie Hill Permit Number: 208-039-0 Inspection Date: 11/20/2015 Insp Num: mitJWH151122213013 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well j ODSN-40 - Type Inj N'TVD 5930 - Tubing 369 380 - 375 • 371 " -------------------------- -------- PTD 2080390 Type Test SPT Test psi 1500 IA 1151 1966 1955 • 1950 , Interval kYRTST PAF P OA 237 302 299 297 Notes: 1.4 bbls of diesel used SCANNED SEP 1 6 2016, Monday,November 23,2015 Page 1 of 1 n • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 8 2012 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alaska Oil & Gas Cons. Commission 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Chrffitepappved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate 0l Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current WelhCdass — 5. Permit to Drill Number: Pioneer Natural Resources Alaska Inc. Development ❑ Exploratory ❑ 208 -039 - 3. Address: 700 G Street Suite 600 Stratigraphic ❑ Service 12 6. API Numbe Anchorage, Alaska 99510 tI\, : 71 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: n property line where ownership or landownership changes: V Ol■ Spacing Exception Required? Yes ❑ No IS 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 355036 / ADL 355037 Oooguruk - Kuparuk Oil Pool N '• Oil Pool 11. PRESENT WELL CONDITION SUMMARY Vy Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): PIS , .' asured): Junk (measured): 18,364' , 6160' ' 18,364' 6160' a l i 10,3,5' N/A Casing Length Size MD ��T� _ 2 Collapse Structural W Conductor 110' 16" 153' 1 . ' N/A N/A 0 ,, Surface 3370' 9 -5/8" 3409' •9' 5750 psi 3090 psi Intermediate 11,029' 7" 11,066' 6 ' V 7240 psi 5410 psi Production Liner 1465' 4 - 1/2" 10,951' - 1 :190' - 6209' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: v bing Grade: Tubing MD (ft): See attachment, pg. 2 See attachment, pg. 2 t T, 9. • L - 80, TCII 10,944' Packers and SSSV Type: • ` ers d SSSV (ft) and TVD (ft): TRSSSV; Hyd Retry Packer / 'O.'' , 02005' TVD; 10,003' MD/5926' TVD 12. Attachments: Description Summary of Proposal ., II Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Development 0 - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/1/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and cor -ct to the best of my knowledge. Contact Tim Crumrine, 343 -2184 Printed Name Tim Crumrine 343 - 218A Title Staff Completions Engineer Signature., ).. Phone 2/27/2012 Date Prepared by:Kathy Campoamor 343 - 2183 .:rte::.., ;,b.. ... r COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '1 Z CP1C0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 5t.ANNED AUG ( 1 Z01 Subsequent Form Required: / O — Lioli APPROVED BY Approved by: A! COMMISSIONER THE COMMISSION Date: // Form 10 403 Revised T20 T9'V`s AUG 0 - ' ! K I I W A L i ���t� li mit in Duplicate ii � *. A 1 1i i 5 R • • Pioneer Natural Resources Alaska Inc. ODSN -40i HPBD Page 2 AOGCC Form 10-403 Application For Sundry Approvals Present Well Condition Summary, Box #11 Perforation Depth attachment 10. Perforation Depth MD/TVD Kuparuk Perforations 3 -' /2" Sliding Sleeve w/ 2.813" X Profile MD TVD 10,185' — 10,234' 5983' — 5997' Nuiqsut Perforations — Below Plug 4 -W, 12.6 #, L -80 BTC -M Uncemented Slotted /Solid Liner Slotted Liner Intervals: MD TVD 10,996' — 11,578' 6201' — 6289' 12,290' — 12,415' 6223' — 6209' Open Hole Interval: MD TVD 12,416' — 18,364' 6209' — 6160' • • PIONEER NATURAL RESOURCES ALASKA eiv" f ODSN -40 HPBD /Step Rate Test / '1 1J • Objectives: a. Well is under injecting. b. Perform HPBD. Procedure: 1. MIRU Schlumberger tanks. Load tanks with Conoco seawater. (Estimate 2 tanks for fluids) 70 deg. Fluid will be used. 2. MIRU Schlumberger frac pumps and associated equipment. 3. Shut -In well and freeze protect. 4. Install Stinger Frac WH Isolation Tool. 5. RU Pollard to the IA (3 -1/2" tubing by 7 -5/8" casing annulus). Pressure up to 3000 psi and then bleed off to 2500 psi and continue to maintain & monitor pressure. a. During HPBD, ensure onsite personnel monitor ScSSSV control line pressure. 6. Pump the following at max rate allowable to maintain the WH treating pressure below 6000 psi. It is assumed that due to the 3 -1/2" tubing, a maximum of 20 bpm will be the treating rate. a. 100 bbls slick water b. 200 bbls slick water with 0.5 ppa 16/20 carbolite c. 500 bbls slick water d. 20 bbls diesel for freeze protect and clear lines. 7. Shut down pumping and monitor WHP fall -off for 15 minutes. 8. Record WHP, BHP, and BHT. 9. RD Schlumberger frac head and hard line and bleed down IA to 200 psi. 10. RD Stinger Wellhead Isolation Tool per singer representative. 11. Function Test ScSSSV. 12. Return well to injection. ODSN -40 HPBD Page 1 III 411 Schwartz, Guy L (DOA) From: Crumrine, Tim [Tim.Crumrine @pxd.com] Sent: Sunday, July 29, 2012 8:35 PM To: Schwartz, Guy L (DOA) Subject: Re: ODSN -40 Hydraulic Frac Sundry ( PTD 208 -039) Yes, Pioneer would line to withdraw the application at this time. Tim Crumrine (907) 240 -4295 On Jul 27, 2012, at 10:10 AM, "Schwartz, Guy L (DOA)" < guy. schwartz@ alaska. gov>< mailto:guy.schwartz @alaska.gov» wrote: Tim. I know this sundry is on hold. It might be better to withdraw it and start over when you decide you want to stimulate this well. Can you send me an email request. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission !") DATE: Wednesday, December 14, 2011 TO: Jim Regg zZ I/ SUB JECT: Mech anical Integrity Tests P.I. Supervisor � Z g .ty PIONEER NATURAL RESOURCES ALASK ODSN -40 FROM: Jeff Jones 000GURUK NUQ ODSN -40 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON CONFIDENTIAL Comm Well Name: OOOGURUK NUQ ODSN -40 API Well Number: 50- 703 - 20571 -00 -00 Inspector Name: JeffJones Insp Num: mitJJ111128113734 Permit Number: 208 -039 -0 Inspection Date: 11/20/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ODSN -40 ' Type Inj. W ' TVD 5930 IA 388 1738 1657 1646 P.T.D 2080390 TypeTest SPT Test psi 1500 ` OA 314 420 410 402 Interval OTHER p/F P - Tubing 2733 2733 2733 2733 Notes: Post injection MITIA. 3.3 BBLS diesel pumped. One well inspected; no exceptions noted. ; FE& 1 (.-� a � ' i 7L Wednesday, December 14, 2011 Page 1 of 1 • • Page l of l Regg, James B (DOA) From: Williams, Theresa [Theresa.Williams @pxd.com] Sent: Sunday, November 20, 2011 4:08 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Cc: Hart, David; OoogurukProdSuper 4 l 1((2110 Subject: ODSN40 MIT IA PTD 2080390 Attachments: MIT ODSN -40 11 -11 -11 MTIA.xls; MIT ODSN -40 11 -20 -11 MTIA.xls; ODSN40 MIT IA Trend 11-11 - 11.pdf; ODSN40 MIT IA Trend 11- 20- 11.pdf Attached you'll find the results of pre- and post- injection MIT lAs for ODSN40. Regards, Theresa Williams Stuff Operations Engineer Pioneer Natural Resources Alaska (907) 343 -2104 Office (907) 382.35596 Cell Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 11/21/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg(8 alaska.aov; doa. aogcc.prudhoe.bavCrilalaska.gov; phoebe.brooks(caalaska.aov: tom.maunder(ctalaska.gov OPERATOR: Pioneer Natural Resources ' l //l / Zt /t FIELD / UNIT / PAD: Oooguruk DATE: 11/11/11 / OPERATOR REP: Joe Delmonico AOGCC REP: Waived ' Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ODSN40 ' Type Inj. W ' TVD " 5,929' Tubing 577 - 3,481 3,406 " 3,384 Interval l P.T.D. 2080390 ' Type test P _ Test psi - 1500 Casing 474 2,553 2,441 2,436 P/F P Notes: Pre - Injection MIT IA as required by AOGCC OA 235 405 389 379 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA _ Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) MIT ODSN -40 11 -11 -11 MTIA.xls Pit Zo &cc 39 (11 2011 10 17:13AM) i Initial IA Pressure f11/1t20111047:19AM)2436 Final (30 mini IA Pressure 117 psifQ y 00: 62 IA Pressure if ODSN-40 Pre- Injection MIT IA 11 -11 -11 • -100 420 F---"---- -- OA Pressure 1 • 10:08:11 AM 10:23: AM 10:38: AM 10:53: AM 11:08: AM 11:2338 AM 11/11/2011 11111/2011 11/112011 11/11/2011 11/11,2011 11/11,2011 192.168.124.52:P1_27203G [BestFit - 00 00:00:19.8353 • s STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test al Submit to: 1 'im.regq(cDalaska.gov; doa. aogcc.prudhoe.bav(c�alaska.gov; phoebe.brooksCrDalaska.gov; tom.maunde r (rD a ska. q ov 1/ ( /l OPERATOR: Pioneer Natural Resources l FIELD / UNIT / PAD: Oooguruk DATE: 11/20/11 - OPERATOR REP: Dave Aikey AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ODSN40 ' Type Inj. W - TVD ' 5,929' Tubing 2,733 2,733 2,733 2,733 Interval 0 P.T.D. 2080390 ' Type test P Test psi '1500 Casing 388 - 1,738 1,657 ' 1,646 P/F P - Notes: Post - Injection MIT IA as required by AOGCC OA 314 420 410 402 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 - 426 (Revised 06/2010) MIT ODSN -40 11 -20 -11 MTIA.xls I I P 26 6 — C (11:202201112:57:43 PM) 1738psi Initial IA Pressure (11.20,20111 27:45PM) 1646psi Final (30 min[ IA Pressure -92 psi (D•'ys00:30:02) OD SN-40 Post- Injection MIT IA 11 -20 -11 • 12.43.50 PM 1:07:56 PM 1:32:03 PM 1:56:10 PM 2.20:16 PM 2:44:23 PM 112202011 11/2012011 11/20/2011 11120/2011 11,/2022011 11120 192.168.124.52:P1_27203G [BestFit - 00 00 00 31 6951 • • • s liatf[E o[F A[LAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tim Crumrine Staff Completions Engineer Pioneer Natural Resources Alaska, Inc. o $ -- o el 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut /Kuparuk Oil Pool, ODSN -40i Sundry Number: 311 -326 Dear Mr. Crumrine: akt. 3; # Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 40 Dani . Seamount., Jr. Chair 57 DATED this / day of October, 2011. Encl. , A- ,,( I 1 .11 '� RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION nut 2 4 2011 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 p% ka Oil & Gas Cols- Commission 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Aneoftwp proved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other:Nuiqsut injector to Kuparuk injector El . 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Development ❑ Exploratory ❑ 208 - 039 • 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service 6. API Number: Anchorage, AK 99501 50 703 - 20571 - 00 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El ODSN-40i 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 355036/ ADL 355037 Oooguruk - Nuiqsut Oil Pool / Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18,364' • 6160' • 18,364' 6160' 10,365' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 153' 153' N/A N/A Surface 3370' 9 -5/8" 3409' 2998' 5750 psi 3090 psi Intermediate 11,029' 7" 11,066' 6219' 7240 psi 5410 psi Production Liner 1465' 4 10,951' - 12,416' 6190' - 6209' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment, pg 2 See Attachment, pg 2 3 - 1/2 ", 9.3# L - 80, TCII 10,944' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): TRSSSV; Hyd Retry Prod Packer 2069' MD / 2005' TVD; 10,003' MD / 5926' TVD 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/25/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tim Crumrine, 343 - 2184 Printed Name Tim Crumrine 343 -2184 Title Staff Completions Engineer Signature ------ Phone Date 10/21 /2011 Prepared By: Kathy Campoamor, 343-2183 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 I 1 .... 2,2- T Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other. _ `'� yv � r 4S L )i c JJ /v � ,D Subsequent Form Required: /0-- 4/6 € j / j> APPROVED BY � � �� �� Approved b op COMMISSIONER THE COMMISSION Date: RBD = NOV 0 1 2011 ) /o. 2-6 - << ynk I ' Form 10 -403 Revised 1/2010 ORIGINAL Submit in Duplicate l (6/4ir • Pioneer Natural Resolces Alaska Inc. ODSN -40i Page 2 AOGCC Form 10 -403 Application for Sundry Approvals Present Well Condition Summary, Box #11 Perforation Depth attachment 11. Perforation Depth MD /TVD Kuparuk Perforations - 3-Y2" Sliding Sleeve w/ 2.813" X Profile MD TVD 10,185' — 10,234' 5983' — 5997' 6 X ,4‘,Ae ° Nuiqsut Perforations — Below Plug 4- qt W, 12.6 #, L -80 BTC -M Uncemented Slotted /Solid Liner • Slotted Liner Intervals: 0 A MD TVD rur 10,996' — 11,578' 6201' — 6289' 12,290' — 12,415' 6223' — 6209' Open Hole Interval: 16'2" MD TVD 12,416' — 18,364' 6209' — 6160' • • Operation Summary for Conversion of ODSN -40 from Nuigsut infector to Kuparuk iniector 1. Close and function test ScSSSV 2. Set BPV 3. Install second swab valve • 151 4. MIRU Slickline Unit P°" O r- 5. Set XX plug to isolate Nuiqsut. Positive and Negative PT XX Plug 6. Open Sliding Sleeve across Kuparuk • 7. MIT -IA to 2500 psi or .25 psi /ft x TVD and record test 8. Notify State prior to injecting seawater . 9. Establish injection 10. Schedule State witnessed MIT -IA for 5 -7 days after establishing injection Page 1 of 1 Schwartz, Guy L (DOA) From: Crumrine, Tim [Tim.Crumrine @pxd.com] Sent: Wednesday, October 26, 2011 11:16 AM To: Schwartz, Guy L (DOA) Subject: RE: ODSN -40i (PTD 208 -039) Between, lack of ability to inject and CPAI lack of water, we have never had continuous or steady injection into the Nuiqsut. I think the 404 should be in your hands very soon. Tim Crumrine Office: 907 - 343 -2184 Cell: 907 -240 -4295 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, October 26, 2011 11:13 AM To: Crumrine, Tim Subject: FW: ODSN -40i (PTD 208 -039) Tim... should have copied you. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Wednesday, October 26, 2011 10:58 AM To: 'Campoamor, Kathy' Subject: ODSN -40i (PTD 208 -039) Cathy, Can you update me on ODSN -40i status and injection history . I have a sundry for a switch to Kuparuk Injection. Did you ever inject into the Nuiqsut ? Haven't seen a 404 report yet on anything. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 10/26/2011 ATE OF ALASKA ALASKA OIL AN S CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS QnVegliPector 1. Operations Abandon ❑ Repair Well El Plug Perforations III Stimulate El RE Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver ❑ Time Exte, i 4i 4 /PPP Change Approved Program ❑ Operat. Shutdown Perforate ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: Maki 13P11 atS. Commission Name: Pioneer Natural Resources Alaska In c Development Q Exploratory p p ry ❑ 208 -039 3. Address: 700 G Street, Suite 600 Stratigraphic Service ❑ 6. API Number: Artc.irur Anchorage, AK 99501 50 703 - 20571 - 00 - 00 7. Property Designation (Lease Number): - 8. Well Name and Number: ADL 355036 / ADL 355037 ° ODSN 9. Field /Pool(s): Oooguruk - Nuiqsut Oil Pool / Kuparuk Oil Pool 10. Present Well Condition Summary: i Total Depth measured 18,364 feet Plugs measured N/A feet true vertical 6160 feet Junk measured feet Effective Depth measured 18,364 feet Packer measured See Below feet true vertical 6160 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 153' 153' N/A N/A Surface 3370' 9 -5/8" 3409' 2998' 5750 psi 3090 psi Intermediate 11,029' 7" 11,066' 6219' 7240 psi 5410 psi Production Liner 1465' 4 -1/2" 10,951' - 12,416' 6190' - 6209' N/A N/A Perforation depth Measured depth See Attachment, pg 2 feet True Vertical depth See Attachmen, pg 2 feet ;. 4 /kiN ,,,! :., - Tubing (size, grade, measured and true vertical depth) 3 -1/2 ", 9.3# L -80, TCII 10,944' MD 6188' TVD TRSSSV @ 2069' Hyd Retry Prod Pkr Packers and SSSV (type, measured and true vertical depth) MD / 2005' TVD @ 10,003' MD/ 5926' TVD 11. Stimulation or cement squeeze summary: - Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 74 200 0 645 306 Subsequent to operation: 0 0 717 468 2676 13. Attachments: 14. Well Class after work: a Copies of Logs and Surveys Run Exploratory Development ❑ Service EI Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: . Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -219 Contact Tim Crumrine, 343 - 2184 Prepared By: Kathy Campoamor, 343 -2183 Printed Name Tim Crumrine Title Staff Completions Engineer Signature I`� -� Phone 343 -2184 Date 10/20/2011 / RBDMS OCT 25 3)11e4‘7-- -. /6-3i. m Form 10 -404 Revised 10/2010 Submit Original Only // • Pioneer Natural Resoces Alaska Inc. ODSN -40i Page 2 AOGCC Form 10 -404 Report of Sundry Well Operations Present Well Condition Summary, Box #10 Perforation Depth attachment 10. Perforation Depth MD /TVD Kuparuk Perforations 3- Sliding Sleeve w/ 2.813" X Profile MD TVD 10,185' — 10,234' 5983' — 5997' Nuiqsut Perforations — Below Plug 4-W, 12.6 #, L -80 BTC -M Uncemented Slotted /Solid Liner Slotted Liner Intervals: MD TVD 10,996' — 11,578' 6201' — 6289' 12,290' — 12,415' 6223' — 6209' Open Hole Interval: MD TVD 12,416' — 18,364' 6209' — 6160' P I 0 N E E R Operatio,Summary Report - State • Well Name: ODSN -40 NATURAL RESOURCES Well Name: ODSN -40 Contractor: NABORS DRILLING Rig Number: 19AC Job Category: RECOMPLETION Start Date: 4/16/2011 End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (lb/gal) Summary 7/30/2011 7/31/2011 0.0 10.15 MIRU slickline. RIH with 2.75" LIB on 5' stem. Tag up at 527'. Attempt to work through with no luck. POOH. RIH with 2.75 gage ring and brush on 3" stem . Tag at 580' and work t/597'. Not making headway. What appear to be metal marks on bottom of gage ring. RIH with 2.80 LIB and tag up at 597'. Jar down twice and POOH. Results inconclusive. Rerun same and tag again at 597'. Tag up 7 times. POOH. Faint metal marks on face of LIB. Run 2.70 centralizer and brush. Tag at 597' and work t/607'. Again not making headway. POOH. Brush is heavily coated with heavy crude /tar. RIH with pump bailer. Tag up at 607' and work t/612'. POOH. Bailer is full of hydrates and heavy tarry crude. Lay down for night. (AFE- 927054 -001) 7/31/2011 8/1/2011 0.0 10.15 MIRU LRS. Mix and Toad 8 bbls 60/40 MEOH. Tie into tubing and pump 4.6 bbls MEOHat .5 b/m and pressure up tubing to 3000 psi. Monitor 15 minutes. No bleed back. Bleed down to 1100 psi and pressure up again with same results. Bleed WHP to 1200 psi. On line with 180 degree diesel down IA at 0.75 b /m. Hold WHP between 2000 psi and 1100 psi. After third bleed down WHP holding at 1100 psi for 20 minutes. Swap back to pump down tubing. With 1.2 bbl hot diesel away WHP back up to 3000 psi. Swap back to pump down IA and bleed WHP to 455. WHP slowly climbing as pumping down IA continues. With 230 bbls away WHP jumps from 900 psi to 1300 psi. Pump 20 additional BBLs and swap back to pump down tubing. Pump 2 bbls and tubing pressures up to 3000 psi. Bleed back to1100 psi. Attempt to pump down tubing again with same results. SD for night and let heat work on plug. (AFE - 927054 -001) 8/1/2011 8/2/2011 0.0 10.15 Rerig return line to production. On line with hot diesel down IA at .75 b /m. After 60 bbls cut rate to .6 b /m. First stringer broke with 123 bbls away. Continue pumping. With 157 bbls away plug broke. Bleed gas to production while continuing to pump hot diesel. 170 bbls diesel in total pumped down IA. SI bleed and swap to tubing. Pump 20 bbls hot diesel, 20 bbls cold diesel, 16 bbls xysol to clear asphaltines from tubing and displace to ss with 80 bbls cold diesel. All tubing pumping done at 1.25 b /m. SI and RD hot oil. (AFE- 927054 -001) 8/2/2011 8/3/2011 0.0 10.15 RU slickline. RIH with 13' 1 7/8" RLR stem, OJ, KJ, LSS, 2.7" cent, 3' stem brush and 2.75" gage ring. RIH t/10,117' and had to work past. Continue in hole t/10,200' WLMD. POOH. Again had to work through 10,117'. RIH with 2.70 cent, 5' stem and 3.5" 42B0. Engage and beat up to close sleeve. POOH. Pin not sheared and 90 deg angle looks good. RIH with 3.5" OM -1, 7" ext. 1 5/8" JDS, latch and pull SO f/9,172' WLMD. Rerun same configuration and latch and pull dome valve f/3,930'. RIH with dummy t/3,930'. Tag up in mandrel. Attempt to set valve. POOH with valve. Redress and rerun. Set dummy valve at 3,930' WLMD. RIH and set dummy at 9,172' WLMD. Line up and fluid pack IA using 61 bbls diesel. Large gas bubble in IA. Bump up 3 times. Bleeding off 150 to 200 psi in 10 minutes. LD for night due to P-6 needed to inject slurry and liquid waste. Will bleed excess gas from annulus. Total diesel used 64 bbls. (AFE- 927054 -001) 8/3/2011 8/4/2011 0.0 10.15 Bleed gas off of IA. Line up P -6 and pressure IA up to 1875 psi using 3 bbls diesel., Monitor 30 minutes. Lost 75 psi in 30 minutes. Pass. SD and wait for P -6 to finish injection. (AFE- 927054- 001) 8/4/2011 8/5/2011 0.0 10.15 RIH with 2.7" cent.,5' stem, BLB, 2.3" LIB. Tag up at 10,004' WLMD,(X nipple) unable to work past. POOH. Impression of wire or shear stock. RIH with 2.3" LIB on same tools string t/10,339 WLMD. POOH. Impression of prong. RIH with 2.5" RS. Latch and pull prong f/10,339' WLMD. POOH. RIH with 3.5" GR 1110,342' WLMD. Latch and pull plug. RDMO. (AFE- 927054 -001) Page 1/1 Report Printed: 10/21/2011 • • Campoamor, Kathy From: Oooguruk Wellwork Supervisor Sent: Friday, September 16, 2011 4:31 PM To: Williams, Theresa; Crumrine, Tim; OoogurukProdSuper Cc: Campoamor, Kathy; Oooguruk Wellwork Supervisor Subject: RE: N -40 MIT conversation Attachments: Daily Drilling Report 4.26.11.pdf; img- 110917002621.pdf Theresa, Here is the annulus test that the rig did. 2500 psi for 30 min. Report and chart attached. Joe From: Williams, Theresa Sent: Tuesday, September 13, 2011 5:10 PM To: Crumrine, Tim; OoogurukProdSuper Cc: Campoamor, Kathy; Oooguruk Wellwork Supervisor Subject: FW: N -40 MIT conversation Here's Jim's note below to Rock. Pre - Inject MIT shows no issues prior to starting injection. Theresa Williams - Staff Ops Engr 0: (907) 343 - 2104 C: (907) 382 - 3596 From: Rauchenstein, Rock Sent: Tuesday, September 13, 2011 1:56 PM To: Williams, Theresa Subject: FW: N -40 MIT conversation From: OoogurukProdSuper Sent: Tuesday, September 13, 2011 9:36 AM To: Rauchenstein, Rock Subject: FW: N -40 MIT conversation From: Regg, James B (DOA) Sent: Tuesday, September 13, 2011 12:35:56 PM (UTC- 06:00) Central Time (US & Canada) To: OoogurukProdSuper; Clark, James Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: N -40 MIT conversation Clarification; AOGCC witness of the initial post- injection MIT may be delayed as described but you still must have a passing MIT before the well can commence injection; refer to AIO 34, Rule 6. I do not find a copy of the pre- injection MIT report in our records. Please provide. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 1 Anchorage, AK 99501 • • 907 - 793 -1236 From: OoogurukProdSuper [ mailto: Oooguruk .ProdSupervisor @pxd.com] Sent: Monday, September 12, 2011 5:49 PM To: DOA AOGCC Prudhoe Bay Cc: Clark, James Subject: N -40 MIT conversation Good afternoon gentlemen, This is just a note with regards to our earlier conversation as to status of N -40i initial MIT witness. It is a mutual understanding that N -40i will await for an initial MIT until such time as Pioneer has multiple drilling or production task which require witnessing by AOGCC. Pioneer has N -40i under human and electronic monitoring and will notify AOGCC if any anomalies occur which appear out of normal scope of service. At this time N -40i is injecting at 424 BWPD @ 2,653 PSIG surface pressure. 73.5 DEG injection temperature. 501.5 PSIG inner annulus pressure. Regards, William Rauchenstein Oooguruk Production Supervisor Pioneer Natural Resources Office: 907 - 670 -6530 Office 2 : 907 - 670 -6602 MBL: 907 - 223 -1143 Fax : 907-670-6610 rock.rauchensteina.pxd.com Oooguruk.ProdSupervisora.pxd.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. This email was sent on 9/12/11 at 5:48 PM by Rauchenr. This email was sent on 9/13/11 at 1:55 PM by Rauchenr. This email was sent on 9/16/11 at 4:30 PM by delmonij. 2 _ - - _- (U- + s , if } /// r / / ; :- -::-.7l1"--=/...:4-17-2-:- _ \ \ \ ` ., ` ill, I r I l - `\ \ i t \ ttt p r { j I 1 / ' / x l k 4 + x,, v \ \ \ f r I t / � � t �t •0 t ... r f 1 Jr ri j. 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T t' t i - 1 " t -- i ! i t F } ` P i ��,£ 3 1 NI t £' �W ', D► . ` t s C>l x �Q v, t £ ' i. £ t ip} } C7 +►i t {."?, ` i k X {A & 1 � , v 1 : ' t � < vv (}, / r / 1 f' 1 { , l it' ) t t 1 t t i c } \ \-,1\,, k 5 . .. . -y.,. y . _ ,,,� f f F 1 f 1 I{ ` r r ' ill! 1 1 J Si j � � � ' � � i �' � `� :, i ``. -•,-\ ( \ \ , \- � 7 .... � / ' I r { f ff /11 1 / t , ; 4Ip i i Y \ , \ t_ -,.., r' ,•, t . ;'"`„. . \ \ \ \ , \\., \,"•, \ . `•-,',:'--.' - --... - '---,,4 , . \ f y x / • 6 \ \ '\ .` "--2 1 _ k 7, _ --- IM"' i ` 4 / ' 7, V / / / / , � n. ,.I y � t "PIONEER Opelions Report Review • NATURAL RESOURCES Well Name: ODSN -40 Permit #: 208 -039 Report End Date: 4/26/2011 Depth End: 0.0 ftKB Operations Summary Bull head tubing volume down tubing with 10.2 ppg brine. Packer set due to high bullhead pressure. Test packer down IA to 2500 psi while holding 500 psi on tubing, on chart for 30 min - Good test. RU slickline lubricator and unit. Test lubricator to 1000 psi. RIH with 2.5" JDC tool and retrieve PX prong f/10,365' wlm. RIH with 3.5" GS tool to pull plug body - parted slickline - 2,100' of slickline plus tool string left in hole. RIH with 3.5" wire grab and tag up at 3,957' wlm at GLM #1. RIH with 3.5" wire grab and work to grab fish at 8,478' wlm. Gained 280 Ibs on pick up weigth - POOH with fish. LD approximately 200' of balled up slickline. RD slick line unit and lubricator. PJSM, ND BOP stack, lift stack and riser. 2 mechanical barriers in place - Closed SSSV, and BPV. Make SSSV control line and ROC gauge Tec wire penetrations thru well head. Test control line to 5000 psi - Good test. NU BOP stack and RU testing equipment. Test annular to 250 psi low, 2500 psi high. Right to witness test waived by AOGCC Rep Jeff Jones at 18:00 hrs on 4/25/2011. Vance Hazzard Date Drilling Superintendent Pioneer Natural Resources, Alaska, Inc. Page 1/1 Report Printed: 10/23/2011 • • Campoamor, Kathy From: Schwartz, Guy L (DOA) [guy.schwartz @alaska.gov] Sent: Friday, September 02, 2011 1:04 PM To: Campoamor, Kathy Cc: Johnson, Vern; Crumrine, Tim; Williams, Theresa; McMains, Stephen E (DOA) Subject: RE: ODSN -40, PTD #208 -039 Cathy, Thanks for the update on the well. Since you have done the mechanical work but haven't yet put the well on injection (due to water constraints) please wait to submit the 10 -404 until the well is on injection and has been MIT -IA'd. This will put the report past 30 days for the mechanical work but in this case the delay in reporting until actual conversion to water injection is acceptable. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Campoamor, Kathy [ mailto:Kathy.Campoamor @pxd.com] Sent: Friday, September 02, 2011 12:01 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern; Crumrine, Tim; Williams, Theresa Subject: ODSN -40, PTD #208 -039 Hi Guy, The conversion well work was done in early August 2011 to change ODSN -40 from a producer to an injector (Ref: Sundry# 311 -219). Currently, due to the lack of water supply, the MIT has not been done. Pioneer will submit the Report of Sundry after the MIT takes place, which is expected in the next few days. A confirmation email from you to follow up our telephone conversation today regarding our status on the AOGCC Report of Sundry (Form 10 -404) for ODSN -40 would be appreciated to use as written documentation for our files. Thanks and have a nice weekend, Kathy .xatFiy Campoamor Engineering Tech II Pioneer Natural Resources Alaska Inc. phone 907 - 343 -2183 fax 907 - 343 -2192 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 1 DATA SUBMITTAL COMPLIANCE REPORT 9/28/2011 Permit to Drill 2080390 Well Name /No. 000GURUK NUQ ODSN -40 Operator PIONEER NATURAL RESOURCES AL API No. 50- 703 - 20571 -00 -00 MD 18364 TVD 6160 Completion Date 8/1/2008 Completion Status 1 -OIL Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, Gyro SS, MWD, ABG, PCDC, EWR, PWD, ALD, CTN, ACA (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr • Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Logue Induction /Resistivity 5 Col 153 6160 Open 8/21/2008 TVD ROP, DGR, EWR, CTN, ALD Invert Log✓ Induction /Resistivity 2 Col 153 6160 Open 8/21/2008 TVD ROP, DGR, EWR, CTN, ALD Invert Log-" Induction /Resistivity 5 Col 153 18364 Open 8/21/2008 Horizontal Log I /Resistivity 2 Col 153 18364 Open 8/21/2008 Horizontal C Las 16781'�Induction /Resistivity 182 18364 Open 8/21/2008 MD and TVD for EWR logs in PDS, EMF and CGM graphics Log 1-V Induction /Resistivity 5 Col 153 5348 Open 8/21/2008 PB1 TVD ROP, DGR, EWR, CTN, ALD I Log Induction /Resistivity 2 Col 153 5348 Open 8/21/2008 PB1 TVD ROP, DGR, EWR, CTN, ALD Log Induction /Resistivity 5 Col 153 8764 Open 8/21/2008 PB1 MD ROP, DGR, • EWR, CTN, ALD Log Induction /Resistivity 2 Col 153 8764 Open 8/21/2008 PB1 MD ROP, DGR, `` EWR, CTN, ALD ,4b C Las 16782 r41 duction /Resistivity 182 8765 Open 8/21/2008 PB1 MD and TVD for EWR 1 logs in PDS, EMF and CGM graphics Log " Induction /Resistivity 5 Col 153 5348 Open 8/21/2008 PB2 TVD ROP, DGR, EWR, CTN, ALD Invert Log Induction /Resistivity 2 Col 153 5348 Open 8/21/2008 PB2 TVD ROP, DGR, EWR, CTN, ALD Invert Log Induction /Resistivity 2 Col 153 13359 Open 8/21/2008 PB2 MD ROP, DGR, EWR, CTN, ALD Horizontal Log Induction /Resistivity 5 Col 153 13359 Open 8/21/2008 PB2 MD ROP, DGR, EWR, CTN, ALD Horizontal DATA SUBMITTAL COMPLIANCE REPORT 9/2812011 Permit to Drill 2080390 Well Name /No. 000GURUK NUQ ODSN -40 Operator PIONEER NATURAL RESOURCES AL API No. 50- 703 - 20571 -00 -00 MD 18364 TVD 6160 Completion Date 8/1/2008 Completion Status 1 -OIL Current Status 1WINJ UIC Y �Rpt Report: Final Well R 0 0 Open 8/21/2008 End of Well Report, Includes PB1 & PB2 Gen Info, Daily Summ, Daily Ops, Morn Report, Bit Rec, Mud Report, Show Reports, Form Tops, Survey Reports, Days vrs Depth v`D C 16784 eport: Final Well R 0 18364 Open 8/21/2008 End of Well Reports, PDF . and EMF of Mud Logs, Survey etc. ADI Backups... in PB1 and PB2 as well Log Mud Log 2 Col 153 18364 Open 8/21/2008 MD Combo Mud Log Log Mud Log 5 Col 153 6160 Open 8/21/2008 TVD Combo Mud Log Log Mud Log 5 Col 153 18364 Open 8/21/2008 MD Engineering Log Log Mud Log 2 Col 153 18364 Open 8/21/2008 MD Gas Ratio Log Log % Mud Log 2 Col 153 8764 Open 8/21/2008 PB1 MD Combo Mud Log Log Mud Log 5 CoI 153 5374 Open 8/21/2008 PB1 TVD Combo Mud Log Lo q1 Mud Log 5 Col 153 8764 Open 8/21/2008 PB1 MD Engineering Log Log / Mud Log 5 CoI 153 8764 Open 8/21/2008 PB1 MD Gas Ratio Log Log / Mud Log 2 Col 153 13359 Open 8/21/2008 PB2 MD Combo Mud Log Log Mud Log 2 Col 153 13359 Open 8/21/2008 PB2 MD Gas Ratio Log Log/ Mud Log 2 Col 153 13359 Open 8/21/2008 PB2 MD Engineering Log D C Las 16783 ✓Induction /Resistivity 182 13359 Open 8/21/2008 PB2 MD and TVD for EWR • logs in PDS, EMF and CGM graphics Log Cent Bond 5 Col one 9500 10925 Case MD RCBL D C Las 14678 -*Cement Bond 9465 10947 Case RCBL + Graphics TIFF PDF Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 9/28/2011 Permit to Drill 2080390 Well Name /No. OOOGURUK NUQ ODSN -40 Operator PIONEER NATURAL RESOURCES AL API No. 50- 703 - 20571 -00 -00 MD 18364 TVD 6160 Completion Date 8/1/2008 Completion Status 1 -OIL Current Status 1WINJ UIC Y ADDITIONAL INFORM ION Well Cored? Y N Daily History Received? N Chips Received? "14.111—. Formation Tops / N Analysis Received? Comments: Compliance Reviewed By: Date: QN, V 1 1 • Page 1 of l Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, September 02, 2011 1:04 PM To: 'Campoamor, Kathy' Cc: Johnson, Vern; Crumrine, Tim; Williams, Theresa; McMains, Stephen E (DOA) Subject: RE: ODSN -40, PTD #208 -039 Cathy, Thanks for the update on the well. Since you have done the mechanical work but haven't yet put the well on injection (due to water constraints) please wait to submit the 10 -404 until the well is on injection and has been MIT -IA'd. This will put the report past 30 days for the mechanical work but in this case the delay in reporting until actual conversion to water injection is acceptable. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Campoamor, Kathy [ mailto:Kathy.Campoamor @pxd.com] Sent: Friday, September 02, 2011 12:01 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern; Crumrine, Tim; Williams, Theresa Subject: ODSN -40, PTD #208 -039 Hi Guy, The conversion well work was done in early August 2011 to change ODSN -40 from a producer to an injector (Ref: Sundry# 311 -219). Currently, due to the lack of water supply, the MIT has not been done. Pioneer will submit the Report of Sundry after the MIT takes place, which is expected in the next few days. A confirmation email from you to follow up our telephone conversation today regarding our status on the AOGCC Report of Sundry (Form 10 -404) for ODSN -40 would be appreciated to use as written documentation for our files. Thanks and have a nice weekend, Kathy AWhy Campoamor Engineering Tech II Pioneer Natural Resources Alaska Inc. phone 907 - 343 -2183 fax 907- 343 -2192 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 9/2/2011 ` t • • s ALAs SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CO1 IM1SSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tim Crumrine Staff Completions Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 d Re: Oooguruk Field, Nuiqsut /Kuparuk Oil Pool, ODSN -40 L Sundry Number: 311 -219 Dear Mr. Crumrine: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday ► - ekend. rI oh �'. orm. - ,, �j o issio • er DATED this !" day of July, 2011. Encl. . P.,I f, • /iii ,t■ STATE OF ALASKA P#� ! /E ALASKA OIL AND GAS CONSERVATION COMMISSION a � l it l . - :j I - APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Ai4 , ( Jli & Gel Car . ii. ti lli tfflf $,41 or 1. Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool Repair Well ❑ Chapgg■pproved Program Suspend❑ Plug Perforations❑ Perforate ❑ Pull Tubing ❑ Time Extension❑ Operations Shutdown❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Convert to Injector El - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Development p Exploratory ❑ ` 208 -039 • 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99501 50- 703 - 20571 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes El No ili ODSN - • 7 ZYIt 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 355036/ ADL 355037 ' Oooguruk - Nuiqsut Oil Pool / /tZ r j a • _ d :r P011 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18,364' • 6160' • 18,364' 6160' 10,365' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 153' 153' N/A N/A Surface 3370' 9 -5/8" 3409' 2998' 5750 psi 3090 psi Intermediate 11,029' 7" 11,066' 6219' 7240 psi 5410 psi Production Liner 1465' 4 -1/2" 10,951' - 12,416' 6190' - 6209' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment, pg 2 See Attachment, pg 2 3 -1/2 ", 9.3# L -80, TCII 10,944' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): TRSSSV; Hyd Retry Prod Packer 2069' MD / 2005' TVD 10,003' MD / 5926' TVD 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El - 14. Estimated Date for 15. Well Status after proposed work: 7/15/2011 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ID • Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tim Crumrine, 343 -2184 Printed Name Tim Crumrine 343 -2184 Title Staff Completions Engineer Signature. Phone Date 7/12/2011 Prepared By: Kathy Campoamor, 343 -2183 -- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 1 -a 1 9 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test /°k-' Location Clearance El ' f---- Act �LKdl6 v ice a . Other: j�No • • � 4 hS, e.� ,(�, r /� /� 1 CL U (4- i... c d�0 2rc. ; 8r. ; h ‘CC-c kJ( AGO . 33 L 3 1. 1 " Ni- t _ . /4... .l ft \ (461.41( ci ry V k COvrl " i ,SSi O h Subsequent Form Required: /b -C/0 APPROVED BY ' // Approved by: C THE COMMISSION Date: Ille iRG71 JUL 2 9.4... 1 R 1 G 1 z z8• �r Form 10 -403 Revised 1 2 ' Submit in Duplicate • ter +1 ' • Pioneer Naturaesources Alaska Inc. ODSN -40 Page 2 AOGCC Form 10 -403 Application for Sundry Approvals Present Well Condition, Box #11 Perforation Interval attachment 11. Perforation Depth MD /TVD Added Perforations 3- Sliding Sleeve w/ 2.813" X Profile MD TVD K (t .. 10,185' — 10,234' 5983' — 5997' R.1 Existing — Below Plug 4-W, 12.6 #, L -80 BTC -M Uncemented Slotted /Solid Liner Slotted Liner Intervals: MD TVD 10,996' — 11,578' 6201' — 6289' ��( 12,290' — 12,415' 6223' — 6209' N `'`"` Open Hole Interval: MD TVD 12,416' — 18,364' 6209' — 6160' • Operation Summary for Conversion of ODSN -40 from Kuparuk Producer to Nuipsut Injector. 1. Close and function test ScSSSV. ✓ 2. Set BPV. 3. Install second swab valve. 4. MIRU Slickline Unit. 5. MU toolstring with kick over tool. 6. Make up lubricator to Otis lubricator adaptor and PT to 2500 psi 7. Pull lowest GLV. Circulate CI seawater. Diesel freeze protect.' 8. Dummy remaining GLMs.. 9. Close sliding sleeve across Kuparuk • 10. PT tubing to 3500 psi. Bleed pressure to 500 psi • �, �" - 6arw 11. PT annulus to 3500 psi. Bleed annulus to 500 psi. • 4 • 12. Bleed tubing to 0 psi. Negative pressure test sliding sleeve to ensure no leakage from Kuparuk. 13. Bleed annulus. 14. Pull XX plug isolating Kuparuk. • 15. Establish injection. . 16. Notify state prior to injecting seawater. • 17. Schedule state witnessed MIT -IA for 5 -7 days after establishing injection. II Page 1 of/ • Schwartz, Guy L (DOA) ID Z°8 - 031 From: Crumrine, Tim [Tim.Crumrine @pxd.com] Sent: Thursday, July 28, 2011 11:32 AM To: Schwartz, Guy L (DOA) Subject: Pioneer Alaska ODSN -40 Conversion to Injector Area of Review Information Attachments: Area of Review for Pioneer ODSN- 40.docx; ODSN -15i Tbg & IA Press Test Chart 051910.pdf; Daily Operations Report 5.4.11.pdf Guy, Please see attached documentation for the Area of Review. None of our wells cross the % -mile radius of the Kuparuk. The ODSN -15i is the only well that crosses the N -40 Nuiqsut % -mile radius. The original map showed the N -18 skirting the 1 4-mile radius of the Nuiqsut. I had our well planner show different views of the' -mile radius in more detail and the N -18 does not cross the boundary. Attachment 1— % mile radii surrounding the N -40 Kuparuk and Nuiqsut. Attachment 2 — ODSN -15i Tubing and IA Pressure Tests Attachment 3 — Daily Operations Report from N -15i I believe you already have a copy of the N -15i Cement Bond Log. The file is about 5 MB and I didn't want to send if it may clog your email. Please let me know if you would like an electronic copy and I will send it. An analysis of the bond surrounding the Kuparuk is below: The top of the Kuparuk came in at 10,856' MD. Pioneer stated in the permit that we would pump a cement volume that is sufficient to cover 500' MD above this depth at 10,356' MD plus 40% excess and 85' of shoe track. The 7" shoe on ODSN -15i was set at 11,348' MD. We pumped a total of 62 bbls (lead + tail cement). We had 90- 100% returns during the job. With 62 bbls pumped that puts TOC at 8,747' MD. That is 2,109' MD above the Kuparuk. We logged from TD to 10,250' MD and the results show sufficient cement bond to isolate both the Nuiqsut from the Kuparuk and the Kuparuk from any shallower formations. The annotation on the log showing top of good cement was a field interpretation showing the top of the so called "best" cement on the log. It is not meant to suggest that there is no cement bond above this depth. With the excess pumped and the clear bond shown in numerous depths on the log (both cement to casing and casing to formation) Pioneer is confident that the Kuparuk is isolated from above and below. ro e) Tim Crumrine, P.E. a � c 6"`� yU a'rl Senior Staff Completions Engineer #.) Pioneer Natural Resources Alaska, Inc. tim.crumrine @pxd.com Office: 907 - 343 -2184 �► ~ J G� Cell: 907- 240 -4295 /� 7� 7/28/2011 • • Area of Review for Pioneer ODSN -40 Below is a map detailing the area % -mile from the Nuiqsut N -40 horizontal wellbore and the area 1/4-mile from the N -40 Kuparuk penetration (slanted wellbore through the Kuparuk). _.. d_ _ -ioi� '.. ® 103 !6H a Ib ❑ t'.3 ii SJ l E i. . G 1f , a 41 9 _ 6 0DSN -41 PN12 Surveys ODSN- 40 /ODSN -40 PN12 *0alunik a2, Kaiuca 02, Kewen 332 VO X ODSDW144, OD3PW1 -14 Disposal, 0050W1.44 Di.po.al V0 0030 -13, 005,13 PIC1P74 0D9413, KUpH VO I $ OD9( -14, ODSK -14 PBy 005% -14 P61 KupB VO 10009( - 14 ODSK- 14082, ODSK -14 P82 KupB VO ,,..--- 009( -14 009( -14 00SK -14 KupB V3 8009( -33, ODSN -33 Kupq ODSK -33 Kup4V0 - �� $OD9( -33, ODSK -33 P81 KUpq 005% -33 PBS KUpAVO .. - . 4444. -34 ODSK351 4 009735 Kup/1009,35 KupB Surveys VO .1 004% 3442, 009(-3542, ODSP 3442 KupH Survey, VC ----'---!--- A. OD3(-30; ODSK 301 KupO, ODSK 311 KupO Surveys VO # 41, ODS I1 K ODS% /1 -41 81 Kup VO 49(11, ODSK- 41001Ku0 y Sever F VO 400SK Ili, 0059( 42/k, 0097-114i VO -34005% -42t, 01)97-42i KupG, OD9( -421 KUpG `O -5- - ' 0044157 000615i, 0094-1911412 00 \ �, 440DSN140DSN16, ODSN16 PN13 Surveys VO '\ / �� ODSN 16, 00911611, ODSN 1611 PN33 W ' i= �► OD9417, ODSN11 k; OD541211PN13V0 \\ � ��_� _� � -. $0096 -11, 009111, 0092 -I1 pN13 Mid S+rvrrsW - \ .10094 1/, ODSN -N PBS, ODSN -18 PN31 P85 VO `1 .100SN 11, OD92 -18 PBI ODSN -10 PN11 PB1 VB `. .. \ ' 800 0042 - -]4 Y, O ODSN- D91- 11 11 0 08 82 2, 00,OOSN -142 -10 8 P 2W / 43 W \ _ $0042 -ll, OD91 -ll 083, OD91 -18 PNll 083 V0 \�__� -`� _� 4- 0091 -11, ODSN- 11 PIA 0179410 MO. PBI VO _ �i` - x4009 -231, ODSN -231 OD SN N -1 W11 PB2 W 8e 0042 -231, 00 N , 00 DD OOSN -3111 W 8 0052 -31 OD42 -31 -311 PBI, ODSN -31083 PN6 Surveys VO --- --____ 1(1pC Target 4 96 0DSN- 31 005N-31 ODSN -31 PPM Surveys VO - - 4,4c, 4 00-321, 0092-32i1N2, OD91 -32,00 SurveysW - _.. _ _. - .. -" .100516 32i, 0092 - 321001321, 0151- 33iPO1INI VO 114 mile raus \ - NO welts I�S di 0034 347 0092.34 P32, ODSN 3P821 Vl VO � \ - - . -.`. ❑ 0091 -34, 0054 -341 P60 0096- 34PB3029 410 . ODSN -34, OD92- 342010042 - 340010200 0004 -3f PB1 ODSN -36 001 PN1 9 0 VO 0091 -36, ODSN -30 P132, 00334 -36 PB2 PN10 VO 43 ODSN -36, 0199 -36 PN10, 0094 -36 P810 Surveys ll 440091 -37, 0091 -33, 0094 -31 P346 VD 80092 -10, 0091 -60051 PN32, 00381-4001310N12 00 440044 -49, OD96 -40P82 P3332. 0001 0P32 PN12 00 40017- 39,0092- 391 116110052- 39311100 ODSr -45, 0006- 451 Ka 1 3113, 0094 -453 P8112413 00 - - ODSr -I5, ODSr -454 ODSr -434 Sarver VO - - - _ 30DST- 46i, 00Sr -161 PB10DSr -461 TorokC MVO ODST -661, ODST -461 PB2, ODST -46, Torok C PB2 W - -- $DUST -467 ODSr- 461 Torok CPB3, ODSr- 46,PB3V0 - - _ 4 O0Sr- 44,0DSr -461, ODST- 161 TorokC VO Only one well, the ODSN -15i penetrates the 1/4 -mile radius of the N -40 horizontal wellbore. No wells • penetrate the Kuparuk within a 1/4 -mile radius. The N -18 well was previously thought to penetrate the • • %-mile radius; however, after further investigation in 3 dimensions, the well does not cross the boundary. The following map shows the ODSN -15i penetration into the % -mile radius of N -40. e - ou ® ]9 •1D.' rl ❑ C3 it 0 8'R .. 4 • : 0 S1 Q 110074 O PN12 w rvrys ODSN 40 /ODSN - 40 PN12 , $ K.s,biL 42, K.wo .2, Kdvni4 S2 o +40091W1 -41, ODSDW1 -44 Dopax{ ODSDW1 -44 D13pos41 VO � ' . 009( -13, OOSK -13 PK1 PH, ODSK -13, KupH VB 90095 K ODSI( 16 PM, ODK -11 PB1 KupB VB ODSK I4, ODSK 16 PB2, OOK-11 PB upAVO 009(SI,ODSK 11 OOKI4KuB1T 0090 -33, 009( -33 Kupq ODK -33 KupAVe 90057 33, ODSK -33881 KupA, ODSK -33 PB1 KupA W +4 009( 35lµ ODK -35 KupB, ODSK -35 KupB Saner VO AODK -3542, 009-35X, ODK -35Ai KupH Surveys V8 d K OD-374 90 , 00-38i KupD, 009( -38 ury i KupO Surveys W '� _ 81009(g005NJ1KUpi 005K-61KUpF VO 0090; ODK- 418817 pF ODK -Il PBl KupFW bODK 121 0 0 57 -4 241 ODSK 424+40 / +47 00 �, ODK-0 KupG ODKJ21 Ku. G VD _ +40094- 16.ODS11- 16,0044- 16PN13S y,VO ' l / _ 2009 SN 4 -16, 0043- 1411, 00- 16L1PN13 VO O 051 -11, OD43 -111,1, ODSH- 1111PN13w - $0051 -11, 0043-11, Nkd Sur ye w d OD91 -N, WSN -1B 885, PBS, ODSN-18 ODSN -U PNll PBS W . __ - -j dOD41- 18,0091 -18 P83, on.-3.8 8 mu 081 V8 e0D5N -18, 009.418 PB2, OOSN -10 PNll 882 VO 00042-18, 0051/-11 pB2, OD42 -18_ PB2 VO .1 $ 0043 -18, 0091 -]B PB3, OD42 -18 PNll PB3 VO 1 I �s _ ^ ! Y�-.. 0043- 18.0051 -16 DB1. /I Y, 002148 0111 DB1VO I -{ .- ' +40043 - ODSH -l8, 005N- 18011140 • 1 \ :_, ' \ / 200442310051 - 231881, ODSN- 2318414 MVO �•IfS \ • �/ - + 4009423 +,00511 -23 PB2, 234011 PB2N i `� ' � 43 OD9423i, 0047-231 0047-231 0041- iii MIVO " 00-31, OD43 -31 DB1, ODSN -31881 ON6 Surveys VO �. 9 0092 -31, 0041- 31, 005N-31PN6 Surveys VD ODSN- 32..0051- 32i3N1, ^, 41,0D 24087 Su I00 O 044 -321 ODSN- 32+88111!, OD443HPB11N1 VD 00093 - 3410092- 341749, OD41 -38829 Survrys V0 00043 -34, 0042 -341 0228-3411 OD41- 3 4 882 8!9 VO (! /\ 00051434,0251 -34 PB3, ODSN- 34083819 VO e 0041 -34, 0044 - 341P11, 0DSN•34pB11N9 V0 4004436, 005%36 P81, 00SN -36 P010N1A V0 0 0094 -36, O0SN -36 P12, ODSN -36 P132 0741000 0 009434, 0043 -36 PN30, 000836 PN10 Survey, VO 44 0043 -31, ODSN -31, 0094-37 PN806 ----- __..-___ 00041 -W, 0051 -1PB1 PN12, 0094- 40PB1PN12 VO _ _ . __. _.. __.._ __ ..._ 46 OOg1- 60.Opg1 -10882 8112.0091 -10082 811240 - - -_ - - -. Q 0051 -39,0051 - 39+1111,0051- 39i ODSr -45, OOSN -455, 0318413, DDSP3 -45. P8111413 VI ODSr -45, ODS1 -ISA, ODSr -45A Sury ys Vl ODST- 4610051 -44 881, 0050 -46, Torok C P81V0 COST -46,, 0DST -44 042, ODST -46, Torok C PB21O $O0ST -443 0DSr.461 Tarok C PB3, ODS1-46i P4300 4 00ST- 4610051 -4G. ODSr -16, Torok C VO • • The next series of maps show wells near the Y4 - mile radius, but not within the boundaries. Below is ODSN -16 shown just outside of the radius. t. k' ❑ a it a - y :: s s K +� s ? 00094 -40 PM , ODSN - All /ODSN-40 PNIZ 43Kelubik 02, Kelukik 02,104.0 0200 44 OD4YW1 -4l 00 3181 - 4 4 040444 00508U 1- U VO 4. OD 3 -13, ODSK -13 P PH, OD5l -13i KWH Ve 0009( -14, 0051 -14 P01, 009( -14001 Kup0 W ' 100.614,009: -14 POI,00A -14082 Kup4 VO 1--; .----- Cx }Y001K- 14,009: - 14,003% -14 Kup0 VII 0088 -33, 0081 -33 Kup]S 0098 -33 Kup4 VB 0009( -33, ODSK- 330011 04,00SK-33PB1KupAVI - / � OD-3581, 0051 3581 S0 -35 KupOODSK- 351upO 5 sVO 35k OM - KupH L A ODSK -38i, ODSK-38i KupD, ODSK -001 KupO Survey, VO 4. ODSK- 11 0 0 81-11 KW, ODSK -I1 Ku,. 5urvep VO 46 ODSK -41, 0096 -IS PB1 Kup6, 009:-11001 NA VT 4009( -Qi, 0051 -1211, 0031 1120; W _ 44008% -40, 009: -40 K..ODSK -42i KupG W // _.!'� �ODSN -15 ODBN -15 DD41 -15i 011200 / /� / ODSN -16, OOA1- UL1009J -1461 PNU W OD9N -1 I, 002,17 L1, ODSN -3) Ll 00823 �._ - / a ODA -11, OD41- 17,0041 -11 PNU Mid SxrtysVO �ODSN -U, OD4J -U 085, 00A-18 04330858 ��- _ - 11 0034 -U, OO48UN1 OOSN -U PNll MVO ( - - ■ 44 ODSN -U, ODSN 19 P02, ODA -U 41411 PK VP '1 �► 0ODSN -U, OOSN -U era 0034-14_ 092 VO 60011 -U, ODSN -U PB3, 0024-10 0431 PB3 W � i ��i 004J -U, 0041 -U PO4 00A-10 PNll PBI W _I 440034 -U, ODSN -U, OD4!- U 00817`1 '�� : _��lS 11' 440014 -23i, 0041-23; P01, OD41 -231 Pill PO 00 31 00.1-20, OM- 231081, OD4l- 2011411 P02 VO 800308- 23i,°°SN-33i ODSN -31 0041 -31081 ODSN 3. 101 PN6 Burleys VO / 0 00 808 -31 00 0108 -3 00 41 -31 PN6 Surveys VO 0084 -32i ODSM301N1 Survey VO / 001 -32i D1I a OD41 -321, ODSN- 32;001083, 0041- 32RB11N7 W / 011117 -34, 0094. 31149, OD48 -34019 Survrys W 4, 00808 - 182, 0041- 3401419 VD 00508 ❑ 0000 -34, 00808 -34 003, 00$41.00013 A1910 2 ODSN -34, ODBN-34PB10010/.40411040 N -36 VO 00.-16, 0048-36 081 0041 -36 PBI 0N10 W b 0091 -36, 0057- 36092, 00008 -36 P02 PN10 W 6 0084 -36, 0041 -36 PN10, 0048-36 PN33 Surveys VO 4400108-15, 004V- 31,0084 -31 PNBVO 40034 -44, 0041 -40001 PNll, OD4440pe1PN12 W 440041 -41, 0041 -40004 P0812, 0004 -40P82 01412 VI I OOSN -393 Pill, 0041 -33, Pill W 0 00511 -451 PB101U, 0004 -45i 0811541300 0D1T -4513, 0OST- 4548wey3 0015 -161 PBI ODST -/6i Tprok C P01 VO 0111 -161 PB2, ODST -tli Torok C 082 VO 6 0011 -8i, 0011 Torok C PB3, 001T -163 0011 4 ODST -461, ODST -4i, ODST -461 Torok 300 Below is ODSN -18 shown just outside of the radius. VI • • - 4-3 ? ? .,,t, ' ' - 1 D J x 3 $00440 PPM Surveys ODSN- 40/ODSN -40 PN12 $Kweik B2, 31.IPNO3E, K.wbkik216 / N 0090W1 -M, ODSDWI- N0isposel, OD1DW1 -M Disposal VO /� J 4 O09K -13, 009( -13 PK1 PH, OD9K-131 Kup0 w 40091-18, ODSK -11 PIN. 0-191- lIPB1KUpBw • 1'4009( -1A ODSK -U PR, OD9: -14 PIN KupBw 4 0091-11, ODSK -111, 012SN- 1.11CUp6w ODSK -33, ODSK -33 KupeK ODS1C-13 KupAw $0091( -33, 009% -33 PBI Kup8, 009: -33081 KupP V0 4(-009% -354, 0021-35 Ks.%ODSK -3S KupB Surveys w A ODSK -354, 009%-354, ODSK -354 K.N Surveys w $ 009C -3N, 009( -3Bi KupD, 009( -381 Kupll Surveys w - - 00 9( -11, OD51( -Il PO1K 005% -11 SUrveysw % : O D9: - q OD5K- I1P -11 PB1 KUDiw 0 09( -121 009( -42 Ar, 009(-42.410 0D9C - ODSK -Iti KupG. 009( -121 KupG w / 0094-151, ODW-15i -151 04]210 � ' ODSN -16, OD91 -16, ODSN-16 PN33 Surveysw 0044 -]6, 0092 -16L; ODSN -10.1 PN33 N \ �� i� �, � ODSN- 13.0641 -14- L1,0D41 -l4- L1911310 4 0041 -11, ODSN -11, 003N -11 PN13 Mid Surveys Surveys ll, 00094 - 113, 0011 -38 PBS, ODSN -18 PNll PBS V0 ilthlp. : \ 000381 -18, OOSN- 109131,0041 -18 PN11 P131110 � \\ QOD9Y18, ODSN -10 PB2, ODSN -U MU 96210 + � � 800.1 -1B, OM -18 9132, ODSN -U_ P132 2 w \ $0041 -U, ODSN -18 PBX ODSN- 180111063 V0 \ 0O41-1B .0091 -38 pB4 U ,O09N-pNll PBI VO \_ �2� �- te aiiegt i1.OD9 1U.ODSN- 1&0041 -18 PNllw .:. ► 400- 231, 0051 -23i PIN, 0041 -231 1 w 14 PB1 l ��' X 0091 -231, 0044 -231 PIN, 0044 - 231111 POE w • 0o0044 -231, 0091-231, 0041- 23i1N11w 0094- 31, 00-31060 91 00- 31001916 Surveys w ' 42 4 - 003; 0092-31, ODSN- 31 PN6 Surveys w l 0 0 44- 0044-321 0024-3N 041, 00561 -321 NI Surveys w 41.321, 00 O01N- 321P1211N1, 0 091 - 3 20121041 10 4009434, 0051 -3419, 0041 -38 1N9 Surveys VD • 40091 -381 13 0 51 -3 4112n 0094 -3PPB2 399w • 130091 -38, 00.1-341P03, 0094- 31,P63N900 0091 -314 00944 - 34.001, 0041-34PB1IN9 w 0091 -36, 0094.16 PBX 0011 -36 P61PN3013 0094 -36, 0044 -36 862, 0091 -36 P62 05416 30 $009436.0091 -36 PN10, 0094-34 PN10 Surveys w • 44000 -31, ODSN -31, 0094 -31 P148143 40091 -10, 0054 -40961 PN13, 0094 -40001 PN12 w • 44.005440, 0009 - 409619112.00944 - 44862 P111130 4000r -39, 009439,1N1; 0094 - 38111100 OOS141, 00153-451 MIND, 0091 -151 P310413 w -- _. _- � ODSr -45, ODST -458, ry OOSr- 4SASueys w - - " - - 0097 -M4-, 0051 - 46196; 00ST- 161TOrck 01.100 _ - -- • 4005- 164 001FJ61 POE, - iODrokCPBiw 4 0005*1 - , 0000- M4-Torok Torok CP pB3w -- 4o6n -M., 0007-46i, o69r - M1 rarok c w Below is a plan view spider map of the surrounding wells for your review. El 0 -1O u ® 1® 0 L2 Fe m O it 9S i' at 21 8 r a mtt 8 $ODSN -46P5412 surveys r _ _ _ ODSN401ODSN -40 PN12 $K3lubik ON, Kalubik 112, Kalub,66003 X ODSDW1 -44. ODSDW1 44Disposal, 00SDW1 -44 Disposal w 4 DDox -13, ODSK -13 PK1 PH, OD9K -131 KupH VO 0009% -14, 009%-14 PBX ODSK -14 PB1KupB w ODSK -14 0DSK -1I PB2, ODSK -14 PB2 KupB w ODSK -14, 009( -13,, 009(-14 KupB VO 8000 0DSK- 33,009( -33 KupA, OD9( -33 KupA VO $ODSK -33, 009( -33 Ill Kup8, 0090 -33 PBLKupA V6 4+ 009% -3541, ODS( -35 KuS, ODSK -35 KupB Surveys W A 009: -354, 009( -354, ODSK-354 KupH Surveys w £009( -38 0093 -38, KupD, ODSK -381 KupD Surveys VO 6000 1009(- 41,009( -41 KupF, 009( -41 KupF Surveys w 005%41, OOSK -41081 KupF, 001K -41 PB1 KupF VO 41009%- 421.0D9K -4201, OD1K -42,N w *009%42i, 0090 KupG, OD5i KupG •.• 4 000 - - -_. -. , 0051 -15i, 0094 15,, K-2 w 15,, 005N- 15iO412V0 :..� \ • \ - 440094 -16, ODS14 16, ODSN -I6 Surveys Sueys VO W �'. '\ � 40D15416, OD94 -16L1, OD91- 161,1 �\ 1 '\ 4OD94 -11, OD9N- 13 11, 00 594- 13 11PN13 V0 -.... ...` . \ `, 214 4 i'`- .. 3 4 0091 -1E, OD41 -11, 0058 -11 PN13 Mrd Surveys 10 - - , __ -- - -l` d 0094 -10, 0094 -18 905, 00PM]. 4 -18 PM]. P05 � � $0D94 -1.8,0021-18P131, ODSN -U PN11 PB1 VO �, � •004316, 00164 -18 P02, ODSN -14 PNll PB2 VII 009418,009618 P82, 009118 P82 00 0 v r \ ; '= $ 003110, ODSN- 18P03,00SN10PN11P83w /' \ / # 009418, ODSN18 PB4, ODSN -18 pN11 PBIw Z -16000-14000121 21 1 a3 4- 0 e 'r -440 'N+'t • rl 2000 40 000 6000 80( 46 ODSN 112 SN , OD 18, 009118 PNll w t 5 1 40D5N 23,, 0091 -231 PBX 94 OD 23i IN1 w PB2 �� � \ -20�'t "� 4 « 34 0023 DOSN 1 PBE, ODSN 23 W11 4 PB2w .' - •Q0094 94-231, 0094 23251, 0091 -231 Nw 44 1 / \\ 90094 31, 00 31 P81,00S94 31P81 PM Surveys VO 0 \ $ OD4 31, 0044- 31, 009431PN6 Surveysw OD94 -321 ODSN 321 542, OD9N -32i N y w I Surveys - � • 4000 - '« 1+ 004432, 009133 PBl Wi, OD91- 3219811110 , 4. 00SN 3k, ODSN -341N3, ODSN 341NO guys 10 OD4434i, ODSN 34PB2, ODSN34<PB2 NO VD \ 00051 -34, ODS1 -3k PB3, ODSN- 349331N910 -6000 0094 -341, ODSN- 34.P61,0D94- 34.PB1049 w 005N -30, OD94 -36 PBX ODSN -36 831 PN10 00 0094-36, 0051 -36 882, 0094 -36 002 PN1000 • O , $0094- 36,00$1 -36 PN10,009-36 PNU Surveysw - 0000 - - - - 1 3 40094 -33, OD44 -34-, O0SN -33 PN810 400SN -40, OD41 -40P01 PN12, ODSN -40PB1 PN12 w 340644 -48, 0096-40883 P912, 0009-408132 PN12 w 0 005( - 39, 0091-39■1111, 0094 - 39i11110 ODSe -45, ODSN -451 P01N13, ODSN -45, PB1113 w ODSr •45, ODST -45A, ODST -45A Surveys 10 ODSr -463 0011-43,803. 0091 -M1 Torok C PBlw ,,,.,{ Q 0009! -Mi, ODSr -M< P82, ODSr -M1 Torok C 882 w West(_) /j 7 � ast(}) [ft] *0000 -46,, ODST -464- ODSr -43, Torok C146 • • 78 21 26 25 I 32 33 34 35 36 T14NR7E N31 N32 N34 N37 5 { 3 2 1 NUIQSUT PA N18 N1•L1 N15i N36 N16 40 ODS 8 9 10 11 2 1/4 Mile suffer ....1414 5i 17 16 14 13 1 • 7L1 PIONEER NATURAL RESOURCES ALASKA 2C 21 22 ODSN -40 NUIQSUT INJECTOR SCALE 0 S r: es Page 1 of 4 • Schwartz, Guy L (DOA) From: Crumrine, Tim [Tim.Crumrine @pxd.com] Sent: Friday, July 22, 2011 9:05 AM To: Schwartz, Guy L (DOA) Cc: Roby, David S (DOA) Subject: RE: Pioneer Oooguruk Application for Sundry Approval for ODSN -40 Conversion to Injector Attachments: ODSN-40 Nuiq_Inj.jpg Guy, Prior to submission of the requested information for the area of review, I would like to ensure we are submitting the correct information to you. Attached is a map of the ODSN -40 well. Only two wells, ODSN -18 and ODSN -15i cross within the quarter -mile radius of the N -40 wellbore. The N -15i was permitted as an injector and therefore has a cement integrity log. The ODSN -18 (only a very small portion of the well crosses the quarter -mile boundary) was permitted as a producer; therefore, it does not have a cement integrity log. Would cement reports for the 7" production casing be acceptable for the AOR? Tim Crumrine Senior Staff Completions Engineer Office: 907- 343 -2184 Cell: 907 - 240 -4295 From: Schwartz, Guy L (DOA) [ mailto :guy.schwartz @alaska.gov] Sent: Wednesday, July 20, 2011 8:43 AM To: Crumrine, Tim Cc: Roby, David S (DOA) Subject: RE: Pioneer Oooguruk Application for Sundry Approval for ODSN -40 Conversion to Injector Tim, A review of the cement integrity is what is mostly needed. The idea is to be sure that any fluids injected will not be able migrate out of zone after reaching the wellbore in question. This would mostly apply to the Kuparuk zone in this case. A spider map is needed showing all wellbores ( including PB and P &A wellbores) A schematic is marginally helpful.. but you could include it. Attached is a help file. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Crumrine, Tim [mailto :Tim.Crumrine @pxd.com] Sent: Tuesday, July 19, 2011 3:38 PM To: Schwartz, Guy L (DOA); Roby, David S (DOA) Subject: RE: Pioneer Oooguruk Application for Sundry Approval for ODSN -40 Conversion to Injector Guy, 7/27/2011 • Page 2 of 4 • • 20 AAC 25.402 (c)(15) requires reporting on the mechanical condition of each well that has penetrated the injection zone within a one - quarter mile radius of a proposed injection well. Would -a schematic of each well suffice? Tim Crumrine Senior Staff Completions Engineer Office: 907 - 343 -2184 Cell: 907 - 240 -4295 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Thursday, July 14, 2011 8:59 AM To: Roby, David S (DOA); Crumrine, Tim Subject: RE: Pioneer Oooguruk Application for Sundry Approval for ODSN -40 Conversion to Injector Tim, Just a reminder that the well can't start injection until we get a %4 mile AOR (Area of Review) from PNR. See 20 AAC 25.402 (c)(1) and (15). I can then finish up the 403 sundry request. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Roby, David S (DOA) Sent: Thursday, July 14, 2011 8:33 AM To: Crumrine, Tim; Schwartz, Guy L (DOA) Subject: RE: Pioneer Oooguruk Application for Sundry Approval for ODSN -40 Conversion to Injector Tim, Thanks for the info. If you have any questions regarding the application for commingled injection please let me know. As per the "new" regulations pertaining to commingled injection after receiving the application we will need to provide public notice and opportunity for comment and /or hearing. Typically no one requests a hearing on commingling applications, but we still must provide the opportunity for one and tentatively schedule one. If a hearing is not requested we will more than likely cancel the one we tentatively schedule. If we do end up having the hearing we will let you know and also let you know what we expect of PNR at the hearing. Regards, Dave Roby (907)793 -1232 From: Crumrine, Tim [mailto:Tim.Crumrine @pxd.com] Sent: Thursday, July 14, 2011 8:02 AM To: Schwartz, Guy L (DOA) Cc: Roby, David S (DOA) Subject: RE: Pioneer Oooguruk Application for Sundry Approval for ODSN -40 Conversion to Injector Guy, Our initial intent was to temporarily shut off the Nuiqsut and produce the Kuparuk. The Kuparuk in N -40 has 7127/2011 Page 3 of 4 • • produced less than expected. Our ultimate goal is to convert the well into a commingled injector into both the Kuparuk and Nuiqsut. The Kuparuk in this area is not currently in our PA, and we are working to add it. In the meantime, we would like to inject into the Nuiqsut to help support our N -15 and 16 wells before adding the Kuparuk to our participating area and designing a plan (with state approval) to make the well a commingled injector. It will also help to establish injection into the Nuiqsut, prior to the Kuparuk, as the Nuiqsut tends to be tighter. I hope this clarifies and if you would like more detail, please advise. Tim Crumrine Senior Staff Completions Engineer Office: 907- 343 -2184 Cell: 907 - 240 -4295 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Wednesday, July 13, 2011 9 :02 AM To: Crumrine, Tim Cc: Roby, David S (DOA) Subject: RE: Pioneer Oooguruk Application for Sundry Approval for ODSN -40 Conversion to Injector Tim, I thought your intention was to convert the Kuparuk zone to injection after pre- production and leave the lower Nuiqsut for later? Can you explain what is going on with ODSN -40? I agree with your assessment of the cement bond through the intermediate casing. There is plenty of isolation at the shoe as well as above and below the Kuparuk zone. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Crumrine, Tim [mailto:Tim.Crumrine @pxd.com] Sent: Tuesday, July 12, 2011 4:32 PM To: Schwartz, Guy L (DOA) Subject: Pioneer Oooguruk Application for Sundry Approval for ODSN -40 Conversion to Injector Guy, I will be submitting an Application for Sundry Approval to convert the ODSN -40 to an injector. This sundry will have us close the sliding sleeve across the Kuparuk, pull the plug above the Nuiqsut to begin injection. The reason I am writing is to confirm with you the adequacy of the cement bond in the well. The cement bond log was submitted with the 10 -407 by Kathy Campoamor. Lo$ results indicate agood cement bond from 9750' — 10918'. The top of the Nuiqsut is at 11020' in the ODSN -40. Top and base of the Kuparuk are 10196' MD and 10,229' respectively. Please let me know if you agree with my assessment of the CBL, and 1 will continue preparing for the upcoming conversion. Sincerely, 7/27/2011 Page 4 of 4 • • Tim Crumrine, P.E. Senior Staff Completions Engineer Pioneer Natural Resources Alaska, Inc. tim.crumrine @pxd.com Office: 907 - 343 -2184 Cell: 907- 240 -4295 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 7/27/2011 ! rrent Schematic -State PIONEER Well Name: ODSN -40 NATIIRAL RESOURCES HORIZONTAL - Sidetrack 1, 6/27/2011 4:31:47 PM Well Attributes Vertical schematic (actual) API /UWI Field Name Well Status Total Depth (ftKB) 50- 703 - 20571 -0000 000GURUK UNIT DRILLED 18,364.0 Casing Strings ® mi Conductor, 153.0ftKB Description OD (in) ID (in) Top (ftKB) Set Depth (ft.. Set Dept... Grade Top Connection Wt/Len (lb/ft) T I 1 Conductor 16 14.670 44.0 153.0 153.0 X -56 Welded 109.00 Casing Components J I Top (TVD) Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 1 -1 1 -1 Conductor Shoe 44.0 16 14.670 ■ Surface, 3,408.8ftKB 11-61 I Description OD (in) ID (in) Top (ftKB) Set Depth (ft... Set Dept... Grade Top Connection Wt/Len (Ib /ft) Surface 9 5/8 8.835 39.0 3,408.8 2,997.9 L -80 BTC 40.00 Casing Components Top (TVD) ® Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 2 -7 9 5/8" Surface Shoe 3,407.1 2,996.9 9 5/8 8.835 HES Float Shoe I1 -101 £ Intermediate, 11,066.5ftKB I i Description OD (in) ID (in) Top (ftKB) Set Depth (ft... Set Dept... Grade Top Connection Wt/Len (lb/ft) 3 -2 Intermediate 7 6.276 37.6 11,066.5 6,219.4 L -80 IBT -M 26.00 ii 1 -14 am Casing Components Top(TVD) 11 Item # Item Des T op (ftKB) (ftKB) OD (in) ID (in) Com 3 -1 Vetco Gray Landing Jt 37.6 7 6.276 1 -18 a 3 -2 Casing Joint 37.6 7 6.276 ■ 3 -3 HES Super Float II 10,981.6 6,197.8 7 3/4 a 3 -4 Casing Joints 10,982.6 6,198.1 7 6.276 I1 -231 a 3 -5 Reamer Shoe 11,064.4 6,218.9 7 3/4 a 4 1/2" Liner, 12,416.0ftKB 1 -26 Description OD (in) ID (in) Top (ftKB) Set Depth (ft... Set Dept... Grade Top Connection Wt/Len (lb/ft) a 4 1/2" Liner 4 1/2 3.958 10,937.6 12,416.0 6,209.1 L -80 IBT -M 12.60 al Casing Components Top (TVD) 11 -311 a Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com ■ 4 -1 WFT PBR Tie Back Sleeve 10,937.6 6,186.7 5.77 5.250 1 1 4 -2 WFT 5 "X7" NTH Packer 10,947.9 6,189.3 5.96 4.290 1 -36 1 4 -3 WFT 5'X7" PHR Hangar 10,951.2 6,190.2 6.1 4.375 • 4 -4 XO 10,954.9 6,191.1 5.57 3.958 a 4 -5 4 1/2" solid liner 10,956.4 6,191.5 4 1/2 3.958 a 4 -6 4 1/2" slotted liner 10,995.9 6,201.5 4 1/2 3.958 1 -43 II 4 -7 4 1/2" solid liner 11,578.4 6,289.6 4 1/2 3.958 1 • 4 -8 4 1/2" slotted liner 12,290.0 6,222.4 4 1/2 3.958 1 -47 1 4 -9 4 1/2" slotted liner 12,373.3 6,213.8 4 1/2 3.958 1 -48 4 -10 Full opening shoe 12,415.0 6,209.2 5 3.958 ® al Tubing Strings r Tubing Description String M... ID (in) Top (ftKB) Set Depth (f... Set Dept... Wt (lb/ft) Grade Top Thread Tubing - Secondary 3 1/2 2.992 0.0 10,309.9 6,019.7 9.30 L -80 TCII 2- 4 'M Production Tubing Components Top (TVD) Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 2-9 E L: 1 -2 Vetco Grey tubing hanger 34.3 10 7/8 2.950 I I 1 -6 HES Wellstar TRSSSV w/ 2,068.7 5.2 2.813 2.813 "X" profile ® It 1 -10 Vanoil 3.5 x 1.5" 9Cr GLM 3,950.3 5.968 2.920 a w/ Dummy ® 4 -1 1 -14 Vanoil 3.5 x 1.5" 9Cr GLM 9,186.9 5,680.3 5.968 2.920 I ` 4 -2 w/ Dummy 1 2. 2 -18 F 1 -18 HES "ROC-L" Gauge 9,948.0 5,912.7 4.8 2.920 -1M , i 4 -3 4 -4 Mandrel 4 -5 4� 3 -3 3 -4 3 -5 i 4 -6 I 4 -7 f 4 -8 4 -9 I 1 4 -10 Page 1/2 Report Printed: 6/27/2011 9. IP • PIONEER Current Schematic - State Well Name: ODSN -40 NATURAL RESOURCES HORIZONTAL - Sidetrack 1, 6/27/2011 4:31:53 PM Tubing Components Vertical schematic (actual) Item # Item Des Top (ftKB) Top (ND) (ftKB) OD (in) ID (in) Com 1 -23 WFT 3 1/2 x 7" "WH -6" Hyd 10,002.6 5,929.1 6 2.930 ® an Retry pkr 1 -26 HES 2.813 "X" Nipple 10,025.9 5,936.1 3.94 2.813 1 -31 SLB MMG 3.5 x 1.5 w/ 10,074.0 5,950.5 5.968 2.920 Dummy & RK latch J I 1 -36 HES "XD" Sliding Sleeve 10,129.4 5,966.8 4.55 2.992 1 -1 w/2.813 "X" profile 1 -43 SLB MMG 3.5 x 1.5 w/ 10,276.8 6,009.9 5.968 2.920 11 -61 ! Dummy & RK latch • 1 -47 Locator sub EUE 8rd 10,301.0 6,017.1 5 2.937 1 -48 WFT Seal Assembly w/7 10,301.4 6,017.2 3.94 2.937 ® bonded seals Tubing Description String M... ID (in) Top (ftKB) Set Depth (f... Set Dept... Wt (lb/ft) Grade Top Thread 1 Tubing- Isolation String 3 1/2 2.992 10,306.5 10,944.0 6,188.3 9.30 L -80 TCII 11 -101 a Tubing Components I ■ I3 -2I Top (TVD) Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 1 -14 11 2 -2 WFT 7" x 4" ID "ArrowPak" 10,306.5 6,018.7 5 4.000 I II Retrievable 15/16 I ! 2 -3 Seal Bore Extension 10,311.5 6,020.2 4 4.000 1 -18 ■ 11/16 ■ 2 -4 Seal Bore Extension w/ 10,315.7 6,021.5 5 7/8 2.992 I ® ACME box 2 -9 HES 2.813" X Nipple w/ PX 10,365.4 6,036.3 3.94 2.813 I1 -231 it plug in place 1 2 -13 HES 2.813" XN Nipple w/ 10,442.9 6,059.1 3.94 2.750 1 -26 $ 2.750" no -go 2 -17 Locator Sub w/ 4 1/2" Hyd. 10,934.5 6,185.9 5.8 3.958 S 521 box 1 -31 1 t 2 -18 Spacer tube w/ indexing 10,935.5 6,186.2 5.2 3.958 II ■ muleshoe 1 1 -36 a ■ ■ i ■ S • 1 -43 ill 1 -47 pi 1 -48 s RS �r 2 -3 ► 2-4 ! ' a 2 -9 ® i s ® 4 -1 =. � 4 -2 2 -18 4 -3 — 4 -4 4 -5 1.12 1 3 -44 3 -5 i if 4 -6 i i } / 48 . 4 -9 J E 4 -101 Page 2/2 Report Printed: 6/27/2011 i 1 STATE OF ALASKA b ALASKOL AND GAS CONSERVATION COMMISSICIIP WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil 0 • Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: 1 One ; 6'ht 7/r Service ❑ Stratigraphic Test 111 2. Operator Name: 5. Date Comp., Susp 12. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Aband.: 5/c/2011 208 - 039 / 311 - 113 3. Address: 700 G Street, Suite 600 6. Date Spudded: 13. API Number: Anchorage, AK 99501 5/7/2008 50 703 - 20571 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2922' FSL, 1144' FEL, Sec. 11, T13N, R7E, UM 7/16/2008 ODSN - • Top of Productive Horizon: 8. KB (ft above MSL): 56.2' 15. Field /Pool(s): 3230' FSL, 5271' FEL, Sec. 14, T13N, R7E, UM GL (ft above MSL): 13.5' Total Depth: 9. Plug Back Depth(MD +TVD): Oooguruk - Kuparuk Oil Pool 3415' FSL, 633' FEL, Sec. 9, T13N, R7E, UM N/A 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x - 469854.21 y 6031038.10 Zone - Asp4 , 18,364' MD / 6160' TVD. ADL 355036 / ADL 355037 TPI: x 465711.29 y - 6026084.31 Zone - Asp 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x - 459807.58 y - 6031578.12 Zone - Asp4 2069' MD / 2005' TVD 417497 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 727' MD /709' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re- drill /Lateral Top Window MD/TVD: BAT Sonic, GR, CCL, CBL N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109# X -56 Surface 153' Surface 153' 24" Driven 9 -5/8" 40# L -80 BTC Surface 3409' Surface 2998' 12 -1/4" 410 sx PF 'L'; 190 sx Class 'G' 7" 26# L- 80IBT- Surface 11,066' Surface 6219' 8 -3/4" 371 sx Class 'G' 4 -1/2" 12.6# BTC -M 10,951' 12,416' 6190' 6209' 6 -1/8" Uncemented Slotted /Solid Liner 24. Open to production or injection? Yes U No U If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3-1/2", 9.3#, Hyd Retry Prod Pkr L-80 TCII 10,944' @ 10,003' MD / See Attachment, page 2 n J / 5926' TVD pe tom+ ( Ai 2,...., pet, 1 IC ,-,.. c ,,J(-) 2 6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. j' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED r" 7-1-11 10,365' 2.813" X Nipple w/ PX Plug 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 5/23/2011 Gas Lift Date of Test: Hours Tested: Production for Oil - Bbl: Gas - MCF: Water - Bbl: Choke Size: Gas - Oil Ratio: 5/23/2011 17.2 Test Period - 275 420 64.5 3" 1526 Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 584 1277 24 -Hour Rate - 384 586 90 25 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored ( - 4D +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit c:Aeiled descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. w, None „x °. 1, .� RBDMS JUL .#f 1 101'1 Sl b) li GA & tim COW CAlitmiSSion Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Submit original only }_, Et 1 77 rl i l `1 • 1 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top 821' 820' needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 1548' 1529' Top West Sak 2384' 2282' Top Torok 7480' 5062' None Top HRZ 9317' 5720' Top Kuparuk C 10,196' 5986' LCU 10,229' 5996' Top Nuiqsut 11,020' 6208' Formation at Total Depth 18,364' 6160' 31. List of Attachments: Summary of Daily Drilling Operations, Well Schematic Diagram, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Crumrine, 343 - 2184 Printed Name: Tim Crumrine Title: Staff Completions Engineer Signatur � Phone: 343 -2184 Date: 6/29/2011 SN Well Name: OD-40 Permit No.: 208 - 039 / 311 -113 Prepared By: Kathy Campoamor, 343 -2183 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 • • Pioneer Natural Ressrces Alaska Inc. ODSN -40 Page 2 AOGCC Form 10 -404, Report of Sundry Well Operations Present Well Condition — Box #10 Perforation Depth attachment 10. Perforation Depth — New Pool U„petrJ) 3-W Sliding Sleeve w/ 2.813" X Profile MD TVD 10,185' — 10,234' 5983' — 5997' Existing — Below Plug 4-W, 12.6 #, L -80 BTC -M Uncemented Slotted /Solid Liner ( , Slotted Liner Intervals: MD TVD 10,996' — 11,578' 6201' — 6289' 12,290' — 12,415' 6223' — 6209' • Open Hole Interval: MD TVD 12,416' — 18,364' 6209' — 6160' P I N E E R Oations Summary Report - State Well Name: ODSN -40 ATURAL RESOURCES Well Name: ODSN -40 Contractor: NABORS DRILLING Rig Number: 19AC Job Category: RECOMPLETION Start Date: 4/16/2011 End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (lb/gal) Summary 4/16/2011 4/17/2011 0.0 10.20 RIG ACCEPTED ODSN -40 at 00:00 hrs on 4/16/11. Finish up on well ODST -45A. PU "GS" retrieving tool and 2.30" centralizer. RIH and latch RHC- M at 9,376'. POOH. Work through tight spot at 9,166'. Continue POOH. Recovered RHC -M - RD slickline unit / lubricator. Monitor ESP conductivity. OK - Secure well. Tubing pressure = 0 psi - IA pressure = 0 psi. ** *Close ScSSSV * * *RD and prep rig to move f/ ODST -45A to ODSN -40. Move rig f/ ODST -45A t/ ODSN -40. Pressure SSSV line 5000 psi. Hold pressure to keep open. RU circ manifold to Tubing and IA. Tubing pressure = 0 psi - IA = 700 psi. Lubricate & bleed to fluid pack IA. Pressure up to 3500 psi. Observe very little pressure drop. Pump total of 14 bbls. Bled off 13 bbls back to flowback tank. RU E -line, WL BOP's, lubricator. PU 12' guns w/ 10' of 4 spf (40 total shots). Test Lubricator /BOP's to 1000 psi. w/ Ops gas. Pressure up to 750 psi to equalize w/ tubing. RIH w/ E - line to max depth of 8,374' (could not get down because of 72° inc). PU and spot guns to fire f/8,345' (top shot) t/8,357' (btm shot). Fire guns. Good indication on WL weight indicator. No pressure change. POOH w/ E -line. All shots fired. 800 psi on tubing. Line up to bullhead down tubing (850 psi on tubing). Bullhead 10.2 ppg 3% KCL filtered brine down tubing. At 25 bbls away, pump 15 bbls viscosified pill. Increase rate to 2 bpm, 1600 psi. Increase rate to 3 bpm, 2000 psi. Continue to bullhead w/ 3 bpm, 2000 -2100 psi. Pumped total of 196 bbls. Shut down & bleed back to trip tank. 8 bbls back. Total of 188 bbls pumped away. Shut in well and monitor pressure while prepping #2 pert guns. Pressure stablized at 450 psi. ** *AOGCC Rep. Bob Noble was given 48 hr notice of upcoming BOP test on 4/16/2011. Asked to be updated for 24 hr notice. *** 4/17/2011 4/18/2011 0.0 10.20 Monitor tubing pressure while prepping Gun run #2. PU guns (12' w/ 40 shots, 4 spf). RIH t/4,620'. Log up to correlate. Spot guns at 4,565' (top shot) 1/4,577' (btm shot).Tubing pressure before firing at 500 psi - After 550 psi. POOH w/ E -line. Spot in lubricator. Secure well. Break lubricator and inspect guns. All shots fired. RD E -line. Bullhead down tubing w/ 10.2 ppg 3% KCL brine w/ 1/2 bpm. At 25 bbls away, pump 15 bbls viscosified pill 2.5 bpm, 1900 psi. Continue bullheading w/ 3 bpm, 2050 psi. Lubricate and bleed to remove residual gas from well. Secure well. Close SSSV. Bleed tubing and IA to 0 psi. Monitor well. Verify 0 psi. Set BPV. ND tree. Terminate SSSV and GW control lines at wellhead. Install test dart. Install riser and flowline. ND riser and spacer spools. Terminate SSSV line through wellhead. Test same to 5000 psi f/ 10 min. NU tree. test upper and lower seals + voids to 5000 psi f/ 10 min. RU slickline and RIH w/ plug. Set plug in profile in top of SSSV at 751'. POOH. RD slickline and equip. Open SSSV. Test plug to 1000 psi f/ 5 charted min. Install BPV. ND tree. 4/18/2011 4/19/2011 0.0 10.20 Continue ND tree - Open SSSV - Hold 5000 psi - Terminate control line. Install test dart - NU riser and flowline - NU BOPE. RU test equip - PU 4" test joint. Test BOPE per AOGCC Sundry Approval: - Test BOPE w/ 4" test joint to 250 psi low and 3500 psi high. -Test all floor valves to 250 psi low and 3500 psi high. -Test upper and lower IBOP valves to 250 psi low, 3500 psi high. -Test 14 choke man. valves to 250 psi low, 3500 high. -Test annular w/ 2 7/8" test jt to 250 psi low, 2500 psi high. -Test upper & lower variable rams w/ 2 7/8" test jt. to 250 low, 3500 high. - Initial sys. pressure = 3000 psi. After closure = 2100. 200 psi obtained in 24 seconds. Full pressure in 94 sec. -All tests charted and all tests held for 5 min. -Right to witness test waived by AOGCC Rep. Bob Noble at 12:30 hrs on 4/17/2011. RD test equip. Pull test dart. RU slick line. RIH to 754'. Equalize pressure on plug set in top of SSSV profile. POH. Bleed pressure f/ 480 psi to 100 psi. RIH w/ slickline. Pull plug f/ top of SSSV. POH. RU to bleed through gas buster. Bleed tubing from 125 psi to 0 psi. 18 bbls back. Lubricate and bleed to fill well w/ 10.2 ppg KW brine. Pumped 18.5 bbls. Bled 4.8 bbls back. LD landing jt. and lubricator. Close blinds and monitor f/ pressure. Bled off 165 psi. Lubricate & bleed. Pumped 70 bbls. Bled back 56 bbls.Bleed IA to 20 psi. Bleed Tubing to 0 psi. MU landing jt. Open blinds. Monitor well. Screw in Landing jt. Close annular. BOLDS. Pull hanger off seat. Verify 0 psi. Open annular.Pull up to 160k and work pipe down to 40k. Pull up to 170k and work pipe down. Packer sheared on down stroke. Work pipe 15' strokes to wear packer elements. Page 1/5 Report Printed: 6/28/2011 , P I 0 N E E R Omations Summary Report - State • Well Name: ODSN -40 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (lb/gal) Summary 4/19/2011 4/20/2011 0.0 10.20 Continue to work pipe 15 strokes to wear packer element. Break circ w/ 1 bpm, 0 psi. Close annular. Line up and circ through choke and gas buster w/ 1 bpm, 0 psi. Pressure up under packer w/ 1.5 bpm or more. Continue to circ - full circulation f/4,565' (perfs below packer). Verify 0 psi. Open annular. Monitor well. Static. Pull hanger to floor w/ 120k up wt. Continue to circ while rigging up to pull completion. Terminate Control line /ESP cable. LD hanger. POOH LD 2- 7/8" tubing f/10,759' t/10,455' slowly watching for swab. RU ESP cable spooling unit. POOH LD completion f/10,455' t/6,249'. LD Weatherford packer and jewelry. Continue LD completion t16,005'. Change out spool on ESP spooling unit. Continue to LD completion f/6,005' t/2,987'. 4/20/2011 4/21/2011 0.0 10.20 POOH w/ 2 -7/8" completion f12,987' U surface. Pull ESP cable over sheave, RD control line spools, and prep rig floor to TIH with 4" DP. Install wear bushing. PU casing scraper, and magnet BHA f/ surface t/256', and TIH 1/10,937'. Pump 25 bbl hi -vis sweep and circulate hole clean with 2x bottoms up strokes. POOH f/10,937' 1/ surface. 4/21/2011 4/22/2011 0.0 10.20 Pick up BAT /Sonic BHA f/ surface t/250', and download same. TIH f/250' 1/10,946'. Memory log out the hole with BAT /Sonic tool f/10,946' 1/9,696'. POOH f/9,696' 1/35'. Download BAT /Sonic log data and send in to ROC to configure log - lay down BAT /Sonic tool. PJSM, rig up E -line unit with Welltec tractor unit. PU Gamma, CCL, and CBL tool string with Welltec tractors. 4/22/2011 4/23/2011 0.0 10.20 RIH f/ surface 1/10,946' with CCL, Gamma, RCBL tool string and loq f/10,946' 1/9,500' wlm. I-OC/Hi/9,500' wim, and rig down E -line unit. RU 3 -1/2" tubing equipment. RIH with lower packer completion f/ surface 1/649'. TIH with lower packer completion on 4" DP f/649' 1/10,946'. Drop 1- 3/4" aluminum ball and pump down same on seat. Pressure up to 3500 psi to set packer. POOH f/10,308' 1/10,233'. Test packer to 3500 psi on chart 30 min - Good test. Slip and cut 170' of drill line. POOH f/10,233' 1/ surface with running tool. 4/23/2011 4/24/2011 0.0 9.45 LD Weatherford packer running tool. TIH with TCP puns on 4" DP f/ surface 1/10.308' Tag packer at 10,308' and PU to place guns f /10 185' t /10 734' Pump 50 bbl hi -vis spacer and displace well from 10.2 ppg to 9.1 ppg brine. Shut pipe rams and pressure up to 2500 psi to fire perf guns. Bleed off pressure and monitor well 30 min - static. Circulate bottoms up, shut down pumps - well flowing 2.5 bbls in 10 min. CBU, shut down pumps - well flowing 2.5 bbls in 10 min. SICP and SIDPP= 16 psi. Raise brine wt. from 9.1 ppg to 9.4 ppg. CBU thru choke while raising brine weight from 9.1 ppg to 9.4 ppg. Open rams and monitor well 15 min - static. POOH f/10,235' 1/ surface with spent perf guns and LD same. Remove wear bushing. RU tubing equipment, control line spool, I -wire spool, and hang sheaves for same. PU WFT seal assembly and jewelry f/ surface 1/186'. 4/24/2011 4/25/2011 0.0 9.45 RIH with 3.5" L -80 9.3# TC II tubing and jewelry f/186' 1/10,308'. PU tubing hanger and landing joint. Make Tec wire and control line penetrations thru hanger and test same. Spot 30 bbl 9.4 ppg corrosion inhibited brine on IA f/10,009' 1/9,194'. Land hanger f/10,283' 1/10,308' with 16k compression on seal assembly, and lock down same. Test upper and lower hanger seals to 5000 psi held 10 min on chart - Good test. Pump down tubing in attempt to set packer - unable to achieve 3500 psi. Troubleshoot leak and test all surface lines - good test. Monitor well on ROC gauge while waiting on slick line crew to mob from Dead Horse. Well built 60 psi below TIW valve. Bull head tubing volume down tubing with 10.2 ppg brine. Packer was set while bull heading down tubing. 4/25/2011 4/26/2011 0.0 10.15 Bull head tubing volume down tubing with 10.2 ppg brine. Packer set due to high bullhead pressure. Test packer down IA to 2500 psi while holding 500 nsi nn tithing nn chart fnr 30 min - Good test. RU slickline lubricator and unit. Test lubricator to 1000 psi. RIH with 2.5" JDC tool and retrieve PX prong f/10,365' wim. RIH with 3.5" GS tool to •ull .lu• bod - sarted slickline - 2,100' of slickline plus tool string left in hole. RIH with 3.5" wire grab and tag up at 3,957' wim at GLM #1. RIH with 3.5" wire grab and work to grab fish at 8,478' wim. Gained 280 Ibs on pick up weigth - POOH with fish. LD approximately 200' of balled up slickline. RD slick line unit and lubricator. PJSM, ND BOP stack, lift stack and riser. 2 mechanical barriers in place - Closed SSSV, and BPV. Make SSSV control line and ROC gauge Tec wire penetrations thru well head. Test control line to 5000 psi - Good test. NU BOP stack and RU testing equipment. Test annular to 250 psi low, 2500 psi high. Right to witness test waived by AOGCC Rep Jeff Jones at 18:00 hrs on 4/25/2011. Page 2/5 Report Printed: 6/28/2011 P I O N E E R O,ations Summary Report - State • Well Name: ODSN -40 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (lb/gal) Summary 4/26/2011 4/27/2011 0.0 10.15 Test BOPE w/ 3.5" test joint to 250 psi low and 3500 psi high. Test all floor valves to 250 psi low and 3500 psi high. Test upper and lower IBOP valves to 250 psi low, 3500 psi high. Test 14 choke manifold valves to 250 psi low, 3500 high. Initial system pressure = 3000 psi. After closure = 2100. 200 psi obtained in 22 seconds. Full pressure in 89 sec. All tests charted and all tests held for 5 min. Blind rams failed to test. Right to witness test waived by AOGCC Rep Jeff Jones at 18:00 hrs on 4/25/2011. Change out blind ram seals. Test blind rams to 250 psi low and 3500 - psi high - on chart for 5 min. Pull test dart from tubing hanger and RD test equipment. Pull BPV, open SSSV, and install 3.5" landing joint. RU slickline unit and lubricator - to same to 500 . si. Run 1 - RIH w/ wire grab t/8,470' - tagged up, POOH - no fish. Run 2 - RIH w/ wire grab t/8,466' - tagged up, POOH - no fish. Run 3 - RIH w/ wire finder /spear t/8,467' - tagged up, POOH - no fish. Run 4 - RIH w/ spear t/10,050' - tagged up, POOH - latch fish at 9,400'. Unable to pull fish - max PUW 1,700#. Slickline parted at lubricator while attempting to free fish - 15' of slicklinp still. in lubricator. Wait on Kinley slickline cutting tool to mob from Dead Horse. 4/27/2011 4/28/2011 0.0 10.15 RU slickline sheaves to drop Kinley cutting tool. Drop Kinley cutting tool, POOH with +/ -8,500 of slickline. Close SSSV, and RD slickline equipment. Remove landing joint and install BPV in tubing hanger. ND BOP stack and drilling riser. Install and NU production tree. Test tree void to 5000 psi held 10 min on chart - Good test. Remove BPV and install TWC valve. Test tree to 250 psi low and 5000 psi high - Good test Move Nabors 19AC down towards the end of the well row in order to clear ODSDW1 -44. LD DP from derrick using mouse hole. NOTE: RIG RELEASED AT 24:00 HRS 4/27/11 YA14 4/30/2011 5/1/2011 0.0 10.15 RIH with BLB, wire finder, and 2.5" RS. SD at 8,431' wlm. POOH. Recover Kinley cutter. RIH with 3.5" slip stop. Unable to get through GLM at 3,922' wlm. POOH. Add 2.7" centralizer and 5' stem above slip stop in tool string. RIH and set slip stop at 4,039' slm. POOH, RIH with 3.5" OM- 1. Locate and pull GL dummy from station 1 at 3,930' wlm. RIH and pull slip stop f/4,039' wlm. Line up and freeze protect both IA and tubing with 140 bbls diesel. Final SIWHP -0 IAP -0 OAP - 400. 5/5/2011 5/6/2011 0.0 10.15 NU additional swab valve on tree for upcoming slickline operations. 5/6/2011 5/7/2011 0.0 10.15 MIRU HES braided line unit. Inspect pad, wellbay and equipment with HSE prior to rigging up. NU two sets of slickline BOP's. Lay herculite onwellbay and pad in front of N-40. RU scaffolding around BOP's. MIRU crane and stab 86' lubricator. 5/7/2011 5/8/2011 0.0 10.15 Line up P6 to IA and pump 175 bbls 10.2 ppg brine and 25 bbls diesel holding backpressure with the production choke. Initial Tubing pressure 460 psi, Final Tubing pressure 0 psi. RIH w/ LIB t/8,422' MD, hard tag. POOH. LIB shows wire at 8,422' MD. MU wire grab, wire scratcher, centralizer, wire finder and GR, RIH (/3,957' MD. Holding up in GLM #1. POOH to reconfigure tool string. Remove wire finder from tool string. PU 3 prong wire grab, wire brush, 2.3" centralizer, wire scratcher and GR. RIH t/8,430' MD and latch fish. PU to 1900 Ibs and lost fish. Make multiple attempts to relatch - unsuccessful. POOH for new tool string - PU two prong wire grab and 2.7" centralizer, keep all others tools on string the same. RIH and tag fish at 8,420' MD. Work f/8,420' (/8430' MD. POOH - no fish. PU spear and new oil jars. RIH (/8,440' MD and tag fish. Work spear f/8,440' (/8,449' MD. POOH - no fish. Reconfigure string add wire finder and replace spear with 3 prong wire grab. RIH (/8,432' MD - latch fish. POOH w/ extra weight and jar through ScSSSV. Recovered 3' piece of slickline. 5/8/2011 5/9/2011 0.0 10.15 RBIH (/8,449' MD. Latch fish and jar. Shear GR - POOH. Repin GR and add wt bar, RBIH. Latch bait sub and work to 1900 lbs - sheared GR - POOH. PU 1/2 pin GS and RIH. Latch fish at 8,418' MD and work to free. GS sheared - POOH. RIH with full pin GSCheck PU, 575 Ibs 8,300' MD. Latch fish © 8,418' MD. Jar fish free and POOH w/ 525 lbs excessive weight. Hole sticky at 6,491' MD. Free at 6,440' - lost 150 Ibs. POOH (/1,053' MD. Second tool string seems to be hung up in ScSSSV. Jar and lose fish. POOH. RIH w/ GR, wirefinder, and 3 prong wire grab and grab fish at 4,815' MD. Inadvertantly shear GR. POOH and PU GS, RBIH and tag fish at 4,804' MD. Work to free. Could not get a good bite. POOH to repin for GR. RIH and latch. Jar and shear GR. RIH w/ GS and latch baited fish at 4,824' MD. POOH and lost weight. Set down in attempt to grab fish and shear GS. Page 3/5 Report Printed: 6/28/2011 'PIONEER O,ations Summary Report - State • Well Name: ODSN -40 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud (lb /gal) Summary 5/9/2011 5/10/2011 0.0 10.15 05:00 - POOH. Repin GS with steel. RIH and tag at 4,822' MD. Jar up and free fish POOH with 600 Ibs of excessive weight. Sticky at 2,004' MD(ScSSSV), jar free and POOH t/347' MD. Sticky at 347', jar and parted wire below fish. POOH and recover 15 of wire wrapped on wire grab. RIH w/ GR and tag fish at 375' MD. Attempt to pull out but GR sheared. POOH. LD lubricator to change packoff. RIH w/ GS, tag at 361' MD, beat down t/425' MD. Fish moving freely down hole. POOH to check GS. Wire grab had 1 ft of wire caught. RIH w/ GR and latch fish at 1,085' MD. Shear GR and POOH for GS. RIH w/ GS and latch baited sub at 1,082' MD. Jar while pulling 1100 lbs and move fish 1/1,077' MD. Work up to 1400 Ibs for 3 hrs - no movement. Attempt to shear GS - unsuccessful. Work line and jar to 2500 Ibs - no movement. Work at 2600 lbs - pull free. POOH f/1,077' MD w/ 1300 Ibs excess weight 1/552' MD. Pull tight and jar at 1900 lbs. Broke loose - POOH. 3' of wire on grab. Line up P6 to IA taking returns off tubing to flow back tanks and pump 25 bbls diesel to move cold KCL out of tubing. Repin to GR and RIH w/ wire grab and latch fish at 588' MD. POOH for accelerators and GS. Change rig up - move braided line BOP's 20 ft up lubricator. Stand by for 1 hr waiting for GS parts from KOC. RIH and latch baited fish at 571' MD. 5/10/2011 5/11/2011 0.0 10.15 Jar fish f/571' 1/503' MD. Shear off POOH and check tools. RBIH and continue jarring fish up hole 1/315' MD. Shear off and POOH to check tool string. RBIH and latch baited sub and continue jarring. Broke free at 229' MD and POOH 1/75' MD with 2300 Ibs tension. Line up lift gas to IA, shut ScSSSV. Pressure up IA to 500 psi and monitor tubing pressure - ScSSSV appears to be leaking. Bleed gas from IA and remaining tubing pressure. Shut down and discuss pulling fish through the tree with town. Open tubing to bleed tank and monitor for 30 min - well static. Have PJSM with crew to discuss bringing fish to surface. POOH to surface and unable to pull through tree. Jar with 2500 Ibs tension for 1.5 hrs and pull fish into lubricator. Close wireline valves and break lubricator - —600' of wire recovered. RIH w/ GR and tag at 1,093' MD. Plant wire grab, shear GR and POOH. RBIH w/ GS and latch baited sub @ 1,084' MD. 5/11/2011 5/12/2011 0.0 10.15 Jar @ 1,084' MD for 1.5 hrs - came loose. POOH and recover 1' piece of wire. RBIH w/ GR and attempt to latch fish - moving downhole. POOH f/1,104' MD and recover 5' of wire. RIH w/ GR and get a solid bite. Jar for 1 hr break free and POOH - recover 2' of wire. RIH w/ GR and get a good bite, POOH. RIH 1/1,102' MD with GS and jar for 1 hr at 1200 lbs. Work up to 2000 lbs jarring, break free, POOH - recovered 8' of wire. Determined that 1 stand of wire is looking up. PU 2.25" LIB and 2.3" centralizer and RIH 1/1,200' MD- POOH 1/1,000' MD. RIH 1/1,400' -POOH to 1200' MD. RIH 1/ 1600' - POOH to 1400' MD. RIH to 2014' MD and tag. POOH 1/ 1134' MD and pull tight. Work braided line up to 3600 Ibs - appear to part braided line. POOH and line stuck in flow tubes. Close wireline valves and break lubricator. Manually recover —450' of braided line. Braided line parted above tool string. Place tree cap on well, LD lubricator and shut down while crew performs GLV work on ODSN -18. 5/12/2011 5/13/2011 0.0 10.15 Line up to IA and pump 25 bbls diesel taking retums to the test meter. Measure braided line recovered from well —562'. Waiting on slickline operations on ODSN -18. 5/13/2011 5/14/2011 0.0 10.15 RIH 2.75" LIB to 1099', tagged only wire. RIH with 3 prong wire and make several runs and recover 3' to 6' of wire each time. Make another LIB run to tag tool string top, no tag, RIH with spear and recovered —900' of .125" wire, Make LIB run to tag top of tool string, no tag, Make another run with a spear and recovered 3' wire. Make another run with spear and recovered 150' of .125 wire. Run LIB to tag tool top, no tag. RIH 3 prong wire grab and recovered — 60' .125 wire ball wrapped around the wire grab 5/14/2011 5/15/2011 0.0 10.15 Make multiple runs to retrieve wire, getting 4' to 20' of wire recoved on each run. Made another run and retrieved —433' of wire. Ran in LIB and got impression of rope socket of braided line tools. Made three attempts to pull tools, 1st attempt was to plant a pulling tool on the rope socket and could not latch the rope socket. 2nd attempt was go in with 3 prong wire grab, was able to pull tools up hole but dropped off, made third attempt with wire grab and retrieved tools from well. Ran LIB to tag tool top, and came back with rope socket impression. Ran in with weight bars and blind box to attempt to knock fish loose. total wire retrieved to date —2144' of .125" wire Left in hole — 500' of .125" slickline, 2 tool strings and no braided line. Page 4/5 Report Printed: 6/28/2011 • P I� o N E E R O,ations Summary Report - State • Well Name: ODSN -40 ATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ttKB) (ft) Mud (lb/gal) Summary 5/15/2011 5/16/2011 0.0 10.15 RIH LIB and tag top of rope socket. MURIH SB pulling tool could not latch up. Make two runs with 3 prong wire grab and recover a total — 8' of .125" wire. RIH with SB pulling tool and latch up on to the first set of wireline tools stuck in the SCSSSV, Jar for 1 1/2 hr until the fish pulled free, POOH, recover tool string down to the GR. RIH with 3 prong wire grab to tag up at 8440', appeared to be pushing something down. tried to grab wire but were unable, appeared to possibly be the bait sub, pushed to to 8588', POOH with wire grab and RBIH with baited GS. 5/16/2011 5/17/2011 0.0 10.15 RIH with baited GS and retrieve bait sub and wireline grab. RIH with 3 prong wireline grab and GR and bait fish at 8664', RIH with GS and and pull fish free. Fish got stuck in SSSV, jarred to free but wireline grab pulled free from fish, Made three runs to catch fish with wire grab and each time brought out chunks of wire totaling —100 ft. Make up spear, scractcher, bib, wire stop and RIH, did not see anything at the SSSV continued RIH to 8389' tagged, made multiple attempts catch wire, but coould go past 8389'. POOH, MURIH JD pulling tool , tagged fish, made 2 attempts to catch fish, caought on second try, POOH, and lay down fish. MURIH 3 prong wire grab, scratcher, BLB to dean up any wire left in the well. 5/17/2011 5/18/2011 0.0 10.15 Make two runs with Wire grab to retrieve any pieces of wire left from fishing. MURIH hole GS and retrieve PX plug body at 10321' SLM. RDMO braided wire slickline unit and MIRU HES combo slickline unit, RIH with brush and trip to bottom and rattle the mandrels, Pump 20 bbls of diesel at 1/2 and 1 bpm while brushing the SSSV. POOH, perform negativie test on SSSV by bleeding pressuer from 1000 psi to 280 psi and monitoring the pressure above and below the valve, Test on ScSSSV OK. RIH with PX plug body , appear to be pushing something downhole, cannot get deeper than 9854' SLMD, POH pickup brush and scratcher to do a brush and flush, RIH to 6200'. POOH,cannot pump, P6 pump not available to pump. Set catcher 5/18/2011 5/19/2011 0.0 10.15 RIH and set DMY valve in @ 3924' SLM. Perform drawdown IA to 0, TBG holding 350 psi. Pull catcher. RIH with X -Line PX plug body, Sit down in X- nipple at 9991' SLM, tap thru. Sit down at sliding sieve at 10,096' SLM, tap down for one hour. Able to pick up with no overpulls. Pump diesel with P-6 at .5 bpm increse to 1.5 bpm, unable to pass 10096' SLM Plug picks up with no overpulls. POOH, marks around No Go. MURIH, wire scratcher , braided line brush, 2.75" guage ring . Brush area 10048' to 10326' while pumping at 2 bpm. POOH with tools. RIH with X -Line PX plug body and attempt to set in X - nipple at 10360 rkbMD. could set POOH and check tools. RBIH with X -Line PX plug body and set in X Nipple @ 10328' SLM. 5/19/2011 5/20/2011 0.0 10.15 RIH with P- Prong, set at 10321' SLM. POOH, rig up little Red and pressure test tubing to 3500 psis, Isost 150 psi in 30 minutes. RIH KJ, 3 1/2" 1 -42 BO shifting tool, set down on XD sliding sleeve at 10098' SLM tap down until pressure on tubing starts dropping from 1125 psi to 425 psi and tool pass thru sliding sleeve.. POOH. RIH with 3 1/2" OM -1 and JDS. Locate and set down at 9158' SLM, Pull DMY. Repeat same tool set up and set down on valve in Station # 1 at 3925' SLM, POOH. RIH W/ 3 1/2" OM -1 RK -1, 1.5" 16/64" (1300 psi opening, closing 1245psi) TRO Live gas lift valve, locate and set down at 3925' SLM, shear off and POOH, valve gone. RIH W/ 3 1/2" OM -1 RK -1, 1.5" 1/4" orifice valve . Locate and set down at 9158' SLM, set valve, POOH, Draw down IA to 0 psi, tubing did not change. RDMO. turn wet over to Operationss, Expro on location began rigging up. Page 5/5 Report Printed: 6/28/2011 r , • Current Schematic -State • PIONEER Well Name: ODSN -40 NATURAL RESOURCES HORIZONTAL - Sidetrack 1, 6/27/2011 4:31:47 PM Well Attributes Vertical schematic (actual) API /UWI Field Name Well Status Total Depth (ftKB) 50- 703 - 20571 -0000 000GURUK UNIT DRILLED 18,364.0 I- Casing Strings 1 -2 Conductor, 153.0ftKB Description OD (in) ID (in) Top (ftKB) Set Depth (ft._ Set Dept... Grade Top Connection Wt/Len (lb/ft) d ' Conductor 16 14.670 44.0 153.0 153.0 X -56 Welded 109.00 I I Casing Components Top (TVD) J 1 -1 Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 1 -1 Conductor Shoe 44.0 16 14.670 Surface, 3,408.8ftKB 1-6 Description OD (in) ID (in) Top (ftKB) Set Depth (ft .. Set Dept Grade Top Connection Wt/Len (lb/ft) Surface 9 5/8 8.835 39.0 3,408.8 2,997.9 L -80 BTC 40.00 Casing Components Top (TVD) I2 -7I Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 2 -7 9 5/8" Surface Shoe 3,407.1 2,996.9 9 5/8 8.835 HES Float Shoe 1 -10 Intermediate, 11,066.5ftKB ' ' Description OD (n) ID (in) Top (ftKB) Set Depth (ft_- Set Dept... Grade Top Connection Wt/Len (lb/ft) I3 -2I Intermediate 7 6.276 37.6 11,066.5 6,219.4 L -80 IBT -M 26.00 1 - 14 'V Casing Components Top (TVD) I Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com I 3 -1 Vetco Gray Landing Jt 37.6 7 6.276 1 -18 3 -2 Casing Joint 37.6 7 6.276 ■ 3 -3 HES Super Float II 10,981.6 6,197.8 7 3/4 3 -4 Casing Joints 10,982.6 6,198.1 7 6.276 1 -231 • 3 -5 Reamer Shoe 11,064.4 6,218.9 7 3/4 4 1 Liner, 12,416.0ftKB 1 -26 Description OD (in) ID (in) Top (ftKB) Set Depth (ft... Set Dept... Grade Top Connection Wt/Len (lb/ft) 4 1/2" Liner 4 1/2 3.958 10,937.6 12,416.0 6,209.1 L -80 IBT -M 12.60 I Casing Components Top (TVD) 11-311 Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 4 -1 WFT PBR Tie Back Sleeve 10,937.6 6,186.7 5.77 5.250 4 -2 WFT 5 "X7" NTH Packer 10,947.9 6,189.3 5.96 4.290 1 -36 I 4 -3 WFT 5 "X7" PHR Hangar 10,951.2 6,190.2 6.1 4.375 4 -4 XO 10,954.9 6,191.1 5.57 3.958 4 -5 4 1/2" solid liner 10,956.4 6,191.5 4 1/2 3.958 4 -6 4 1/2" slotted liner 10,995.9 6,201.5 4 1/2 3.958 1 -43 4 -7 4 1/2" solid liner 11,578.4 6,289.6 4 1/2 3.958 4 -8 4 1/2" slotted liner 12,290.0 6,222.4 4 1/2 3.958 4 -9 4 1/2" slotted liner 12,373.3 6,213.8 4 1/2 3.958 1 -47 w 1 -48 I 4 -10 Full opening shoe 12,415.0 6,209.2 5 3.958 BE Tubing Strings 2 3 Tubing Description String M ID (in) Top (ftKB) Set Depth (f.. Set Dept.. Wt (lb/ft) Grade Top Thread Tubing - Secondary 3 1/2 2.992 0.0 10,309.9 6,019.7 9.30 L -80 TCII 22 = 4 — Production Tubing Components ik Top (TVD) Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 2-9 it 1 -2 Vetco Grey tubing hanger 34.3 10 7/8 2.950 1 -6 HES Wellstar TRSSSV w/ 2,068.7 5.2 2.813 2.813 "X" profile 2 -13 1 -10 Vanoil 3.5 x 1.5" 9Cr GLM 3,950.3 5.968 2.920 w/ Dummy 12-171 4 -1 1 -14 Vanoil 3.5 x 1.5" 9Cr GLM 9,186.9 5,680.3 5.968 2.920 w/ Dummy ` 4 -2 2 -18 r IN, 3 1 -18 HES "ROC -L" Gauge 9,948.0 5,912.7 4.8 2.920 4 -4 Mandrel ' 4 -5 3_3 1 ,/ 3 -4 (3 -5 i / 4 -6 i 4 -7 4 -8 .4 -9 I L 4 -10 1 Page 1/2 Report Printed: 6/27/2011 PIONEER Current Schematic - State Well Name: ODSN -40 NATURAL RESOURCES HORIZONTAL - Sidetrack 1, 6/27/2011 4:31:53 PM Tubing Components Vertical schematic (actual) Top (ND) I tem # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Com 1 -23 WFT 3 1/2 x 7" "WH -6" Hyd 10,002.6 5,929.1 6 2.930 ® Retry pkr 1 -26 HES 2.813 "X" Nipple 10,025.9 5,936.1 3.94 2.813 E 1 -31 SLB MMG 3.5 x 1.5 w/ 10,074.0 5,950.5 5.968 2.920 Dummy & RK latch 1 I 1 -36 HES "XD" Sliding Sleeve 10,129.4 5,966.8 4.55 2.992 1 -1 w/2.813 "X" profile 1-43 SLB MMG 3.5 x 1.5 w/ 10,276.8 6,009.9 5.968 2.920 1 1-6 I & RK latch 1 -47 Locator sub EUE 8rd 10,301.0 6,017.1 5 2.937 1 -48 WFT Seal Assembly w/7 10,301.4 6,017.2 3.94 2.937 bonded seals ® Tubing Description String M... ID (in) Top (ftKB) Set Depth (f... Set Dept... Wt (Ib /ft) Grade Top Thread Tubing - Isolation String 3 1/2 2.992 10,306.5 10,944.0 6,188.3 9.30 L -80 TCII 1 -10� Tubing Components I I I 13-2 Top (ND) Item # Item Des Top (ftKB) (ftKB) OD (in) ID (in) Corn 2-2 WFT 7" x 4" ID "ArrowPak" 10,306.5 6,018.7 5 4.000 Retrievable 15/16 II 1 2 -3 Seal Bore Extension 10,311.5 6,020.2 4 4.000 1-18 a 11/16 ■ 2 -4 Seal Bore Extension w/ 10,315.7 6,021.5 5 7/8 2.992 i ACME box 2 -9 HES 2.813" X Nipple w/ PX 10,365.4 6,036.3 3.94 2.813 1 - 23� plug in place 2 -13 HES 2.813" XN Nipple w/ 10,442.9 6,059.1 3.94 2.750 1 -26 2.750" no -go 2 -17 Locator Sub w/ 4 1/2" Hyd. 10,934.5 6,185.9 5.8 3.958 521 box 1-311 2 -18 Spacer tube w/ indexing 10,935.5 6,186.2 5.2 3.958 muleshoe 1 -36 ■ ■ ■ a 1 -43 I 1-47 1 -48`k 1551 2-4 la 2 -9 iE IIII if c. 2 -17 4 -1 _4 a 4 -2 2 -18 Q /14 -3 f 1 i 4 -4 li : 4 -5 3 -3 I • 3 -4 3 -5 i 4 -6 1 4 -7 1 1 4 -8 I • 4 -9 J E 4 -10 Page 2/2 Report Printed: 6/27/2011 • Campoamor, Kathy From: Schwartz, Guy L (DOA) [guy.schwartz @alaska.gov] Sent: Wednesday, June 29, 2011 8:25 AM To: Delmonico, Joe Cc: Campoamor, Kathy; McMains, Stephen E (DOA) Subject: ODSN -40 RWO (PTD 208 -039) Joe, Can you have Cathy resubmit the 404 as a 407 form as this was a new pool completion? Also , I need the results of the CBL that was run. Thnks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) '� 'E; - � ma y _` JSi"Fl i 4 , 5�itt�. ;xtEr:attissio /t , ii irra jo 1 • • SITAITE ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Joe Delmonico Drilling Engineer 3� Pioneer Natural Resources Alaska, Inc. 'o � j ' - 700 G Street, Suite 600 au s - ' 31 AK 99501 Re: Oooguruk Field, Kuparuk River Oil Pool, ODSN -40 Sundry Number: 311 -113 Dear Mr. Delmonico: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. f� Chair DATED this day of April, 2011. Encl. • PIONEER NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, Alaska 99501 Tel: (907) 277 -2700 Fax: (907) 343 -2190 April 04, 2011 RECEIVED APR 4 2011 State of Alaska Alaska Oil and Gas Conservation Commission Abska col a Gas Cans. Carmasaan 333 West 7 Ave, Suite #100 I nctor$ge Anchorage, AK 99501 RE: Application for Sundry to Perforate Kuparuk and Modify Completion, ODSN- 40 �--T Per f Ark-c) Rpot Pioneer Natural Resources Alaska is requesting Sundry approval for the workover of the ODSN -40 production well. Please see the attached Form 10 -403 and proposed rig workover plan. The well's upper completion is currently a 2 -7/8" ESP. The proposed workover includes perforating the Kuparuk interval, and replacing the 2 -7/8" string with a 3 -1/2" upper completion. Pioneer plans on pre producing the Kuparuk zone prior to " swapping the Kuparuk over to injection. The Nuiqsut formation will be isolated when producing /injecting the Kuparuk. Depending on the Kuparuk results the Nuiqsut zone ✓" may be entered at a later date. Pleas the attached proposed completion diagram and operations summary for further detail. broker b- - �Y RO►t..Gt S Sincerel, ;, N 1 /, Y7sr Joe De onico Jr. Drilling Engineer • Attachments: Form 10 -403 Supporting Sundry information cc: ODSN -40 Well File • • - %1► RECEIVED STATE OF ALASKA P APR 0 4 ?WO ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Alum cm & fias Cons. Commission 20 AAC 25.280 Aa COOrAgt; 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ei ' Repair Well ❑ Change Approved Program ❑ Suspend 0 Plug Perforations ❑ Perforate ❑ Pull Tubing El • Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Change Upper Completion 19 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Development ig . Exploratory ❑ 208 -039 • 3. Address: 700 G Street, Suite 600 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99501 50- 703 - 20571 -00 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: • Spacing Exception Required? Yes ❑ No El ODSN - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 355036 / ADL 355037 • Oooguruk - Kuparuk Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18,364' t 6160' ' 18,364' 6160' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 153' 153' N/A N/A Surface 3370' 9 -5/8" 3409' 2998' 5750 psi 3090 psi Intermediate 11,029' 7" 11,066' 6219' 7240 psi 5410 psi 1 Production Liner 1465' 4 -1/2" 10,951' - 12,416' 6190' - 6209' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,996' - 11,578'; 12,290' - 12,415' 6201' - 6289; 6223' - 6209' 2 -7/8 ", 6.5# L -80, IBT -M 10,806' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): ScSSSV; 7" x 2 -7/8" Dual ESP Packer 748' MD / 748' TVD; 4501' MD / 3639' TVD 12. Attachments: Description Summary of Proposal Ei 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development El • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 4/11/2011 Commencing Operations: Oil El ' Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Delmonico, 343 -2182 Printed Name �; B - r • •. - • �, 4.218 =07- 980-7690 Title Drilling Engineer Signature f ".1 Phone Date 4/4/2011 Prepared By: Kathy Campoamor, 343 -2183 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 , ^ k `3 Plug Integrity ❑ BOP Test X , Mechanical Integrity Test ❑ Location Clearance ❑ 7t / Other: ?SOD s /J p O 1 G(s -- f C , 4e 5 4 CBL Subsequent Form Required: / U — go APPROVED BY Approved by: 0 RL / COMMISSIONER THE COMMISSION Date: 4 OMS APR -- ($ : ,..4d. G • l/ M R I GI NAL Form 10 -403 Revised 1/2010 4• -7 .1( Submit in pl� tQ,� • ODSN -40 Proposed Rig Workover Summary Pre Rig: 1. MASP = 2756 psi 2. Open ScSSSV and PVV. Bleed any residual gas from IA and tubing. Monitor tubing and IA pressure until MIRU. MIRU Nabors 19AC: 1. Line up rig pumps and lubricate and bleed IA to fluid pack above the packer with the PVV ✓ closed. • 2. Bleed any residual gas off of the IA. 3. Bullhead 1.5x tubing volume of kill weight fluid from surface to the formation. 4. RU E -line and RIH with 12' of 4 SPF tubing punch. Locate and shoot in first full joint below -� packer. 5. Bullhead 1.5x tubing and casing volume of kill weight fluid. ✓ 6. Close ScSSSV. Monitor ScSSSV and PVV for any pressure build up prior to ND tree. 7. Set BPV in tubing hanger. 7 8. ND Tree / NU BOP. Test BOP 250 low 3500 psi high. Pull BPV. 9. Install 4" landing joint. a. Bullhead 1.5x tubing and annulus volume of kill weight fluid down tubing. b. Ensure fluid level on IA is at surface. BOLDS and pull the tubing hanger and the packer free with elevators. c. Packer will shear release straight pull. - d. Bullhead 1.5x annulus volume of kill weight fluid down IA once the packer elements relax. 10. Pull the 2 -7/8" completion string out of the hole filling hole as needed. 11. PU bit and scraper and RIH to the top of the 4.5" liner top. POOH. - 12. RU E -line and run a cement bond loafrom the top of the 4.5" liner to the estimated TOC @ 9,991' MD. CQL 13. PU mule shoe, 3.5" tubing tail, XN nipple, X nipple, 7" x 3.5" packer and seal bore. RHC -M and plug should be installed in the X nipple below the packer. Page 1 of 2 1 14. RIH on DP and sting tubing tail into 4.5" liner top @ 10,951' MD. Set packer. Test 7" x 4" DP annulus to 2500 psi for 30 min. Test plug to 2500 psi for 5 min via DP. Release and POOH w/ DP. 15. RIH w/ perforating guns on DP. Circulate well over to under balanced brine. Close BOPE 's on DP. Perforate Kuparuk interval. Monitor pressure increase on DP and annulus. Circulate the well over to kill weight fluid. Flow check well. Open BOP's and POOH w/ perf gun V assembly. (cF 64r-, k`41'4-``"AL 16. PU and RIH w/ 3 -1/2" 12.6# L -80 TC -II injection string consisting of: a. Mule shoe, seals, water injection mandrels, sliding sleeve (closed position), X nipple with RHC -M plug installed, 7" x 3.5" packer, ROC gauge, GLM's, and ScSSSV. See schematic for further detail. 17. Spot corrosion inhibitor from top packer to lowest GLM. 18. Sting seals into seal bore, space out and land tubing hanger. Test upper and lower hanger seals to 5000 psi each. 19. Pressure up against bottom plug to set packer. Test tubing and IA to 2500 psi for 30 min each. Set BPV. 20. ND BOPE. 21. NU 3 -1/2' injection tree. -/ 22. Replace BPV w/ TWC. Test tree void to 5,000 psi and bleed off pressure. Test tree internals through the 3" wing assy. Test the 2" gas lift wing assembly against shop tested closed inner valve to 5,000 psi. 23. Move Drilling rig off and turn well over to Well Work Supervisor. Post Rig: 1. MIRU HES slickline. 2. RIH with kick over tools and pull dummy from lower and upper GLM. RIH and set LGLV's in upper and lower GLM's. 3. RIH and shift sliding sleeve to the open position. 4. Rig down slickline. 5. Function Test ScSSSV. Page 2 of 2 • curre .k` ODSN -40 Well Status Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 2 -7/8 ", 5K, Horizontal Vent Valves Control Line 16" Conductor ' 153' MDrkb / 153' TVDrkb 2 -7/8" HES ScSSSV, 2.313" ID @ 748' MDrkb / 748' TVDrkb 9 -5/8 ", 40# L -80 BTC, 8.835" ID 3409' MDrkb / 2998' TVDrkb X Nipple, 2.313" ID 4641' MD PP " @ ' 2 -7/8" GLM @ 3972' MDrkb / 3320' TVDrkb 7" x 2 -7/8" Dual ESP Packer @ X Nipple, 2.313" ID w RHC M 4501' MDrkb / 3639' TVDrkb Profile @ 4701' MD 2 -7/8" GLM @ 9193' MDrkb / 5682' TVDrkb 2 -7/8 ", 6.5# L -80 IBT -M ESP Cable 00 2 -7/8" Durasleeve Sliding Sleeve, 2.313" ID @ 10649' MDrkb / 6115' TVDrkb ■ Estimated Top of Cement @ 9991' XN Nipple, 2.205" ID Nogo MD / -5835' TVDrkb @ 10693' MDrkb / 6126' TVDrkb 81 degrees ESP @ 10806' MDrkb / 6154' TVDrkb 11066' MDrkb / 6219' TVDrkb 6 -1/8" Open Hole 7 ", 26# L -80 BTC -M, 6.276" ID 4-W, 12.6# L80 BTC Liner Top @ 10951' MD - — — — — — Slotted Liner 10996-11578' MD and 12290' - 12415' MD; Solid Liner 10956'- 10996' and' 11576- 12290' 18364' MDrkb / 6160' TVDrkb Date: Revision By: Comments 5/2/2008 JDF Proposed Completion 7/25/2008 JDP Proposed 4'W Line ODSN -40 Producer ` '- 9/2/2008 KLC Actual Completion Well Schematic PIONEER NATURAL RESOURCES ODSN -40 Kuparuk Producer Proposed tcompletion Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 3 -1/2 ", 5K, Horizontal Ok ar 16" Conductor 153' MDrkb / 153' TVDrkb ScSSSV Control Line 3-1/2" HES ScSSSV, 2.813 "ID@ 2,075' MDrkb / 2011' TVDrkb 9 -5/8 ", 40# L -80 BTC, 8.835" ID 3409' MDrkb / 2998' TVDrkb 3 -1/2" GLM © 3972' MDrkb / 3320' TVDrkb 3 -1/2 ", 12.6# L -80 TCII 3 -1/2" GLM © 9193' MDrkb / 5682' TVDrkb I -wire 7" x 3 -1/2" Packer @ 10,025' MDrkb / 5,935' TVDrkb Gauge carrier @ 9,961' MDrkb / 5916' TVDrkb Estimated Top of Cement @ 9991' MD / -5835 TVDrkb =� = X Nipple w/ RHC -M plug, 2.813" ID Nogo @ 10,057' MDrkb / 5,945' TVDrkb K - J �"^^ 3 -1/2" Durasleeve Sliding Sleeve, 2.813" ID @ 10,200' MDrkb / 5,987' TVDrkb 3 -'% WFM's w/ 1 -'V2" valves X Nipple (plug set), 2.813" ID Nogo Seal bore and Seal Assy @ 1 © 10,360' MDrkb / 6,034' TVDrkb 10,308' MDrkb / 6,019' TVDrkb XN Nipple, 2.75" ID Nogo 7" x 3 -1/2" Packer @ 10,328' � @ 10,392' MDrkb / 6044' TVDrkb MDrkb / 6,025 TVDrkb 11066' MDrkb / 6219' TVDrkb 3 -1/2", 12.6# L -80 TCII @ 11,015' MDrkb / 6,206 TVDrkb 1 6 -1/8" Open Hole 7 ", 26# L -80 BTC -M, 6.276" ID 4 -'W, 12.6# L80 BTC Liner Top @ 10951' MD f _ Slotted Liner 10996'- 11578' MD and 12290'- 12415' MD; Solid Liner 10956-10996' and' 11576- 12290' 18364' MDrkb / 6160' TVDrkb Date: Revision By: Comments 1/20/11 JDF Proposed Completion r 4/04/2011 JAD Proposed Completion ODSN -40 Kuparuk Producer Well Schematic PIONEER NA'UHAL.H 30JHCES • Page 1 of f Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, November 04, 2008 9:48 AM To: 'Vaughan, Alex' Cc: Polya, Joe; Franks, James; Campoamor, Kathy; Hazzard, Vance Subject: RE: ODSN -40 (208 -039) Thanks Alex. I will make a hand correction on the 407. Tom Maunder, PE AOGCC From: Vaughan, Alex [mailto:Alex.Vaughan @pxd.com] Sent: Monday, November 03, 2008 4 :20 PM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Franks, James; Campoamor, Kathy; Hazzard, Vance Subject: RE: ODSN -40 (208 -039) Toni, You are correct. My calculations for verification are as follows: Total bbls pumped = 56.11bb1 @ 15.8ppg @ 1.18 ft /sack (56.11bbl) * (5.6146 ft /bbl) / (1.18 ft /sack) = 266.98bbls My guess is that when the calculation was initially carried out the following mistake occurred resulting in a unit error of ft /sack (66.11 bbl) * (6.6116 f /hack) - 371.7 ft /sock Please see sticky note on ODSN -40 Inter Cement Summary.pdf (Weilview Cement Summary Report) and time entry 06:51:50 on ODSN -40 7in intermediate.xis (Halliburton cement job schedule) for reference. Regards, Alex Vaughan Operations Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) 907.343.2190 (fax) Fro . - der, Thomas E (DOA) [mailto :tom.maunder @alaska.gov] Sent: Monday, l• - . -r 03, 2008 10:01 AM To: Vaughan, Alex Cc: Polya, Joe Subject: ODSN -40 (208 -039) Alex, I am reviewing the completion r - . ubmitted for this well. 1. I need some clarific- on the 7" cementing volume. 371 sx is listed on the 401, but in the oper- . .ns 11/4/2908 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, November 03, 2008 10:01 AM To: 'Vaughan, Alex' Cc: Polya, Joe Subject: ODSN -40 (208 -039) Alex, I am reviewing the completion report submitted for this well. 1. I need some clarification on the 7" cementing volume. 371 sx is listed on the 401, but in the operations summary the cement detail is given as 56 bbls, 314 ft^3 of slurry at 1.18 ft^3 /sx. Using this information I calculate 266 sx pumped. Thanks in advance. Tom Maunder, PE AOGCC 11/3/2008 W 0 STATE OF ALASKA 1 SEP 0 4 2008 ALASKA OIL AND GAS CONSERVATION COMMIS 1 N WELL COMPLETION OR RECOMPLETION R &�cission la. Well Status: Oil 0 .Gas El Plugged ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 1 0U 9€ 20AAC 25.105 20AAC 25.110 Development El • Exploratory ❑ . GINJ❑ WINJE WDSPL WAG ❑ Other❑ No. of Completions: 1 Service ❑ Stratigraphic Test 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Pioneer Natural Resources Alaska Inc Aband.: 8/1/2008 ' 208 -039 / 308 -264 3. Address: 6. Date Spudded: 13. API Number: 700 G Street, Suite 600, Anchorage, AK 99501 5/7/2008 • 50- 703 - 20571 -00 • 4a. Location of Well (Governmental Section): 7. Date TD Reached: r14. Well Name and Number: Surface: 2922' FSL, 1144' FEL, Sec. 11, T13N, R7E, UM • 7/16/2008. 5?.c f.6 ODSN - . Top of Productive Horizon: 8. KB (ft above MSL): 15. Field /Pool(s): 3615' FSL, 776' FEL, Sec. 15, T13N, R7E, UM Ground (ft MSL): 13.50' Total Depth: 9. Plug Back Depth(MD +TVD): Oooguruk Nuiqsut Oil Pool • 3415' FSL, 633' FEL, Sec. 9, T13N, R7E, UM N/A 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 469854.21 • y- 6031038.1 • Zone -AsP4 • 18364' MD / 6160' TVD • ADL 355036 / ADL 355037 TPI: x- 464928.08 y- 6026473.34 Zone -AsPa 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x- 459807.58. y- 6031578.12 ' Zone- ASP4 748' MD / 748' TVD 417497 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 709' . 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR, GR, Gyro SS, MWD, ABG, PCDC, EWR, PWD, ALD, CTN, ACAL, DDS 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109# X -56 Surface 153' Surface 153' 24" Welded 9 -5/8" 40# L -80 BTC Surface 3409' Surface 2998' 12 -1/4" 410 sx PF'L; 190 sx Class 'G' 7" 26# L -80 Surface 11066' Surface 6219' 8 -3/4" A Wsx Class 'G' � IBT -M 36'1 ct' QMf,>`1� l 4 -12" 12.6# L -80 10951' 12416' 6190' 6209' 6 -1/8" Uncemented Slotted / Solid Liner RTC -M 23. Open to production or injection? Yes el No If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) Slotted Liner Intervals 2 -7/8 ", 6.5 #, L -80 IBT -M 10806' 4501' MD TVD 10996' - 11578' 6201' - 6289' ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12290' - 12415' 6223' - 6209' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Open Hole Interval 1900' Freeze Protect w/70 bbls Diesel MD TVD 12416' - 18364' 6209' - 6160' P6 PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate - 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 - Sidewall Cores Acquired? Yes ❑ No 0 • If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ' i-57/17LETIOid 1 DA E None ` genre ` l e a - .)MS BR SEP 0 9 ?DQg /ro %trot Form 10 -407 Revised 2/200 R 161h A L CONTINUED ON REVERSE t- `V- G. 1 1 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes [' No . If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top Permafrost 821' 821' Base Permafrost 1548' 1529' Top West Sak 2384' 2283' Top Torok 7917' 5054' Top HRZ 9317' 5720' Top Kuparuk C 10198' 5987' LCU 10229' 5996' Top Nuiqsut 11020' 6208' None 30. List of Attachments: Summary of Daily Drilling Operations, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Joe Polya, 343 -2111 Printed Name: Vance Hazzard Title: Drilling Superintendent �i Signature: 1' ! Phone: 343 -2116 Date: 9/3/2008 Well No. ODSN -40 t� ermit No. 208 -039 / 308 -264 Prepared By: Kathy Campoamor, 343 -2183 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 z Operations Summary Report l e Well Name Contractor Rig Number Rig Release Date ODSN -40 Nabors Alaska Drilling 19 AC Job Category Spud Date Start Date End Date DEVELOPMENT DRILL 5/7/2008 5/7/2008 Operations Report Report Start Date Report End Date 5/7/2008 5/8/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 03:30 3.50 RIGSER PP R/D Freeze Protect, Putz and Cuttings Lines 03:30 05:00 1.50 MOB PP Prepare rig to move 05:00 06:00 1.00 MOB PP Skid Rig to ODSN -40 06:00 07:30 1.50 MOB PP R/U Lines in Hutz and Putz, R/U Skate and Beaver Slide, Rig accepted at 07:30 07:30 10:00 2.50 BOPS PP Nipple up Starting Head, Drill Riser and test Starting head to 500 psi for 10 min. 10:00 12:00 2.00 RIGSER PP Change out TD Lube Filter and prepare Rig Floor for P/U BHA 12:00 14:30 2.50 BHA PP M/U Bit, Motor, Float sub and Stabilizer. 14:30 15:00 0.50 CIRC PP Fill up lines an pump thru motor and check rig for leaks 15:00 16:00 1.00 RMWASH PP Clean out Conductor F/71' to 153' using 450 gpm @ 150 psi, 40 rpm w/ 1 -2K / Torque 16:00 17:30 1.50 DRLG PP Drilling F/ 153' to 225' using 480 GPM @ 200 PSI, 40 RPM, 3K WOB 17:30 18:00 0.50 BHA PP Stand back 2 stands of HWDP in order to build BHA 18:00 19:30 1.50 DEVSUR PP Rig up Gyro Survey equipment on Floor and over ODSN 39i 19:30 20:00 0.50 RIGSER PP Service Rig 20:00 22:30 2.50 BHA PP P/U BHA #1 and Load EM Probe and Orient 22:30 23:00 0.50 RMWASH PP Wash and Ream F/ 193' to 226' 23:00 00:00 1.00 DRLG PP Drilling F/ 226' to 266' taking Gyro Survey, Drill using 490 GPM @ 250 PSI, 60 RPM w/ 2K torque Report Start Date Report End Date 5/8/2008 5/9/2008 Start Time End Time - Our (hrs) Op Step _ Phase - P/N Comment 00:00 05:30 5.50 DRLG PP Drilling and Sliding F/ 266' to 568'. Using 490 GPM @ 430 PSI, 60 RPM, WOB 3K. Torque 3.5. P /U -75K, S/O -75K, R/W -73K. Gyro surveys at connectiol MWD Problems F/ 500' to 530'. 05:30 07:30 2.00 CIRC PP Clean Gumbo out of Riser and Flow Line. 07:30 10:30 3.00 DRLG PP Drilling and Sliding F/ 568' to 667'. Using 500 GPM @ 450 PSI, 60 RPM, WOB 10K. Torque 3.5. P /U -85K, S/O -85K, R/W -85K. Gyro surveys at connection, 10:30 12:30 2.00 U_OTR PN Trouble Time: Circulate amd Condition hole when we Lost High Line Power.wAl f FOR HES -RSC to regain power. Clear cuttings line. 12 hrs. ADT -3.3 hrs AST -1.3 hrs ART -2.0 hrs 12:30 17:30 5.00 DRLG PP Drilling and Sliding F/ 667' to 976'. Using 500 GPM @ 800 PSI, 70 RPM, WOB 10K. Torque 3.5. P /U -89K, S/O -89K, R/W -89K. 17:30 18:00 0.50 U_SEQ PN Trouble Time: CCU down, Circulate and Condition 18:00 00:00 6.00 DRLG PP Drilling and Sliding F/ 976' to 1390'. Using 450 -500 GPM @ 800 -850 PSI, 80 RPM, WOB 20K. Torque 3.5. P /U -92K, S/O -92K, RNV -92K. Pump a Sweep at 1000' 12 Hrs ADT -6.18 AST -4.18 ART- 2.0 Report Start Date Report End Date 5/9/2008 5/10/2008 Start Time End Time - Our (hrs) Op Step Phase P/N Comment 00:00 01:30 1.50 DRLG PP Drilling and Sliding F/ 1,390' to 1,484'. Using 450 GPM W/ 814 PSI. Torq On -5K Torq off -2K, WOB- 20K, RPM -60. P/U -100. S /O -100K, R/T- 95K. Gyro survey at connections 01:30 02:30 1.00 CIRC PP Circulate while trying to recieve IFR Surveys. BP cut Power to field due to. Fire at GC1, IFR power was interupted due to this incident. After talking td Sperry and determining that we were out of critical close approach decision made to drill ahead using uncorrected MWD surveys. 02:30 12:00 9.50 DRLG PP Drilling and Sliding F/ 1,484' to 2,243'. Using 520 GPM W/ 1,120 PSI. Torq On -6K Torq off -3K, WOB- 17K, RPM -80. P /U -125K. S /O -105K, R/T- 110K. Gyro survey taken at 1,486', R/D Gyro. Pump 60 bbl sweep at 2,000' 12 Hrs ADT -6.37 hrs ART -3.20 hrs AST -3.17 hrs www.peloton.com Page 1/45 Report Printed: 8/29 /2008 • Operations Summary Report Start Time End Time Dur (hrs) Op Step Phase P/N Comment 12:00 00:00 12.00 DRLG PP Drilling and Sliding F/ 2,243 to 3,003'. Using 600 GPM W/ 1,550 PSI. Torq On -6K Torq off-3K, WOB- 20K, RPM -80. P /U -125K. S/O -110K, R/T- 118K. Gyro survey taken at 1,486', Pump 60 bbl sweep at 3,038' 12 Hrs ADT -8.10 hrs ART -3.33 hrs AST -4.47 hrs Operations Report Report Start Date Report End Date 5/10/2008 5/11/2008 Start Time End Time [ Our (hrs) Op Step Phase j P/N Comment 00:00 07:30 7.50 DRLG PP Drill 12 -1/4" Surface Hole, 3,003- 3,420', (Slide /Rotate), per HES DD & Well plan. Parameters Inca 650gpm flow rate= 1,650psi off71,860psi on, 25 -30K WOB (S /R), 80 -90 TDS rpm= 4K off /6K on Bottom torque, PuWt= 135K/SoWt= 117K/RotWt= 120K. Pump 60bbI Hi- Vis/Wt. sweep @ 3,042' & 3,412' w/15% increase cuttings w /returns. ADT= 5.83hr, AST= 1.59hrs, ART= 4.24hrs, TADT= 30.68hrs, Jar Hrs= 59.80hrs, Ftg.= 3,259' Rop Avg.= 106.23fph 07:30 10:00 2.50 CIRC PP CBU 3.5x @ 750gpm flow rate= 1,950psi, TDS rpm= 90, w /4 -5K off Bottom torque, rack back 1 x std. per 1 hr to avoid washing bottom of hole, f/3,412' to 3,098', (lots of Clays returns seen across shakers & cleaned up). 10:00 11:00 1.00 STRIP PP POOH w /BHA #1, 3,095- 2,425', (3,050= 50K over, 2,660'= 50K over). Some 50K over & swabbing seen @ 2,390', & decision made to back ream up, (SLM out of hole). 11:00 12:00 1.00 RMCLN PN Screw into Std. & back ream w /90 rpm TDS= 4 -5K torque, 750gpm= 1,925psi, 120K RotWt, 110K SoWt, & 135K PuWt. Work 2,390'- 2,243', w /no circ. or rot. on final wipes, (no swabbing /10K over, hole appears to be good). Had CBU @ final std., (3,500 strokes @ 2,243' w /lots of Clay material seen). 12:00 17:30 5.50 STRIP PP Continue to POOH to bit w /BHA #1, f/2,243' to bit w /10 -30K over 2,220'- 1,855' & no swabbing, (@ 1,855= 40K over), & usual 10 -15K over rest of way out. Rack back HWDP & DrIg. Jar, lx Std. Flex Monels. Bit & Mtr. stab.= 90% pack off w /Clay Material & String IBS= 30 %, (clean off same). SLM= +.68' diff, no corr. 17:30 18:00 0.50 RIGSER PP Clean rig floor 18:00 20:00 2.00 TRIP PP RIH to 220', work thru tight spot just out of casing 30K Dn Wt., Resume RIH F/ 220' to 1,528' Hole getting sticky 30 K Dn Wt. 20:00 20:30 0.50 RMWASH PP Wash and Ream F/ 1,434' to 1,528' With 450 gpm, Hole unloaded a large amount of cuttings blinding the shakers, reduce pumps to 400 gpm and let hole clean up. 20:30 21:30 1.00 TRIP PP RIH on Elevators F/ 1,528' to 2,215'. Hit tight spot 35K Dn Wt 21:30 22:00 0.50 RMWASH PP Wash and Ream F/ 2,215' to 2,287' using 400 GPM w/ 850 psi and 30 rpm. 22:00 22:30 0.50 TRIP PP RIH on Elevators F/ 2,287 to 2,381. Hit tight spot 30K Dn Wt. Wash and Ream using 400 gpm w/ 850 psi 22:30 23:30 1.00 TRIP PP RIH on Elevators f/ 2,381 to 3,288' 23:30 00:00 0.50 RMWASH PP Wash and Ream F/ 3,288' to 3,383' using 500 gpm w/ 1000 psi, rotating at 100 rpm Report Start Date Report End Date 5/11/2008 5/12/2008 Start Time End Time Our (hrs) Op Step Phase P/N Comment 00:00 00:30 0.50 RMWASH PP Continue to wash & clean 3,383- 3,420' w /500gpm= 1,120psi, 90rpm on TDS= 5K Torque, & 1 -5K WOB, (no problems encountered getting to bottom). 00:30 02:00 1.50 CIRC PP CBU 3.0x @ 750gpm flow rate= 1,770psi & 100rpm on TDS= 3.5K Torque off bottom, rack back a stand every hr. Hole appeared clean & decision made to POOH for 9 -5/8" casing. 02:00 06:00 4.00 TRIP PP Hoist BHA #1 for 9 -5/8" Surface casing, 3,305-630', w /no swabbing experiened, (3,290'= 40K over, 2,050'= 35K over). 06:00 10:00 4.00 BHA PP Rack back HWDP in derrick, & LD NM Flex, (3x). Read MWD probe & LD same, along w /Bit & motor, after milking same, (good shape). Bit was 60 -80% pack -off w /Clays, as was motor stab. Graded bit: 2- 3- FC- A- E- 1- NO -TD. 10:00 10:30 0.50 BHA PP Clean & clear floor of all uneccessary tools & equipment. 10:30 14:00 3.50 CSG PP RU floor for runnin 9 -5/8" casing C -O bails to long type on TDS & MU Franks Fill up tool. ontinue to U all required tools for same. PJSM for same, w /all related involved services. www.peloton.com Page 2/45 Report Printed: 8/29/2008 mow CEA• Operations Summary Report ii0 i Start Time End Time j Dur (hrs) [ Op Step Phase P/N _ 14:00 22:30 8.50 CSG PP PU 9 -5/8" Shoe track jt. & RIH w /same. Bakerloc all required connection for Shoe track assembly, per program. Test Float equipment, per SOP, (held OK). Witness loading of Cement head w /plug #1. Continue to RIH w/9 -5/8" Casing per program, 165'- 3,364', ensure proper fill ups every 5 joints, & proper returns. Had to Circulate at 3,037- 3,079' and 3,228'- 3,268' due to tight conditions. P/U Wt. 195K, S/O Wt 125K. M/U Hanger and RIH F/3,364' to 3,410' where we landed out. 22:30 00:00 1.50 CSG PP Drain Stack and insure Land out of Hanger. PJSM, Rig Down Casing Equipment Operations Report Report Start Date Report End Date 5/12/2008 5/13/2008 Start Time End Time Our (his) Op Step Phase P/N Comment 00:00 00:30 0.50 CSG PP Continue to drain out Riser to confirm Landing depth of Casing hanger, (set in Load shoulder properly). 00:30 01:00 0.50 CSG PP Finish LD Franks Tool & MU HES 9 -5/8" Cement head. 01:00 05:00 4.00 CIRC PP Stage up circulation f /.5BPM to 10.0BPM, per circulating schedule, (10BPM= 2,170psi), w /full returns, (hole clean & not much seen across shakers). Attempt to reciprocate casing, but taking 40 -50K w/o breaking over, (leave landed in the Load Shoulder), w /Casing Shoe depth of 3,408.75. 05:00 07:30 2.50 CMTPRI PP PJSM w/ all related services. Pump 10 BBL's Sea Waer spacer, (3 BBL's to fill lines from RSC to Rig). Pressure test cement lines to 3,500psi, (ok). Drop plug #1 w/ 1BBL of 10.0ppg spacer, (confirmed). Bleed off pressure, & load plug #2 & 3. Pump 39 BBL's of 10.0ppg Dual @ average 2.5 BPM @ 470psi. Mix & pump 303 BBL's of 10.7ppg "Type L" Lead Cmt. w /average 4.5 BPM displacement rate @ 500psi. Drop Plug #2, & mix/pump 43 BBL's 15.6ppg "Type G" Tail Cmt. @ 4.5 BPM rate = 300psi. Drop Plug #3 @ Displace w /10 BBL's Sea Water. Shut down & line up on Rig pump, coritinue to displace w /Rig pumps @ 7.61 BPM rate for 2,000 Strokes, (ICP= 1,230psi @ 20% flow & FCP= 1,520psi @ 32% flow), w /Cmt. seen @ surface @ 1,760 Strokes. Continue to pump @ 6 BPM @ 2,700 strokes= 1,300psi @ 26% Flow rate, and slow to 4 BPM rate= 960psi @ 16% Flow rate, (Bump plugs @ 2,905 strokes /18 strokes over calc., & hold 1,400psi for 2 min's- OK). Release pressure & check floats, (ok). CIP @ 07:31am, w /100 BBL's cment returns @ surface, (had to divert 50 BBL's to pit & treat w /Citric Acid as CCU unable to handle same). 07:30 10:00 2.50 CSG PP RD 9 -5/8" casing running equipment & LD Vetco Gray Landiing tools, (Clear floor of same). 10:00 12:00 2.00 CSG PP P/U Riser Washing Tool and Wash out Riser 12:00 17:00 5.00 BOPS PP Nipple Down Drilling Riser, N/U Wellhead and test to 5000 psi for 15 min, OK 17:00 00:00 7.00 BOPS PP Nipple Up BOP's, Change out Top and Lower Rams to 5" Report Start Date Report End Date 5/13/2008 5/14/2008 Stan Time End Time Our (hrs) Op Step Phase PIN Comment 00:00 01:00 1.00 BOPS PP Continue to NU BOP stack & C -O Pipe Rams to 5" size. 01:00 03:00 2.00 BOPS PP PU & MU Vetco Gray Testing joint, w/required x -o's. Install test plug for testing BOPE. 03:00 09:30 6.50 BOPS PP Test BOPE per AOGCC requirements, (Mr. Jeff Jones waived witness). Test Annular Preventer, (250psi Low /2,500psi High). Continue to test all BOP stack components, choke manifold valves, TDS I -BOP valve /manual valve, & all floor valves per NAD test procedure to 250psi Low /3,500psi High, & chart same, (problem w /rental TIW valve - leak around Hex wrench seal). LD TIW valve and get replacement from NAD sent out, (had backup on location - tested OK). Function test Accumulator system, per AOGCC requirements, (OK). Function test Gas detection alarms & LEL, (OK). Pull Vetco Gray test plug & install wear bushings, LD testing equipment. 09:30 10:30 1.00 CSG PP Pump 3 BBL's water through kill line to ensure lines /stack free of air. Close Blind rams & test 9 -5/8" casing to 3,600psi for 1 /2hr, (chart same). ISIP= 3,600psi, & FSIP= 3,480psi, 6.33% drop - good Test). Bleed off same, RD test equipment, & Blow down lines. Line up valves for Drilling Operations. 10:30 11:00 0.50 RIGSER PP Seal up Cracks in Rotary Table, Prior to taking on OBM. 11:00 13:30 2.50 BHA PP P/U Bit, Geo- Pilot, NM Flex Joint, A/C Sub, EWR, Smart Stab, HCIM /PWD /DGR and Density Neutron. www.peloton.com Page 3/45 Report Printed: 8/29 /2008 1 Operations Summary Report Steri Time End Time Our (hrs) Op Step Phase P /tJ Comment 13:30 16:00 2.50 LWD PP Load MWD Tool, and check all connections 16:00 17:30 1.50 LWD PP Shallow Hole Test MWD at 530 gpm w/ 575 PSI. Tools Tested OK 17:30 18:30 1.00 LWD PP Conduct PJSM on Loading Radioactive Sources. Load Sources 18:30 19:30 1.00 BHA PP Finish P/U Rest of BHA #2 19:30 22:30 3.00 TRIP PP RIH F/ 664' to 3,315' where we started taking weight, set 10 K weight down and P/U to 3,224' Float at 3,323' 22:30 00:00 1.50 RIGSER PP Service Crown, Top Drive, Check Bolts in Derrick and Drawworks. Operations Report Report Start Date Report End Date 5/14/2008 5/15/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 01:30 1.50 CUTDL PP Finish Slipping & cutting drilling line per NAD Tool push requirements. 01:30 04:30 3.00 CIRC PP Transfer MOBM from RSC to Rig pits, (Sim Op's: C -O Top Drum cutter on Hammer Mill). Once ready, displace Sea Water from well bore to fresh 9.6ppg MOBM @ 425gpm Flow rate= 1,320psi, (had 40 BBL'S interface), & transfer Well bore fluid to RSC. 04:30 09:30 5.00 DRLCMT PP Commence drill out of Plug rubbers @ 3,321', F/C at 3,323', cement, 3,323- 3,407', and 9 -5/8" Casing shoe @ 3,408.75' MD, (2,998.01' TVD). Ream /Dress shoe 3x, to ensure full gauge. Clean out 12 -1/4" Rat Hole, 3,408.8'- 3,420', w/o problems. Drill out parameters included Various WOB, 2 -15K, 40 -60rpm on TDS= 2K off /5 -7K on Bottom Torque, 480gpm Flow rate= 1,425psi, PuWt= 135K, SoWt= 120K, RotWt= 125K. 09:30 10:00 0.50 DRLG PP Drill 8 -3/4" Hole section, 3,420- 3,440', w /540gpm Flow rate= 1,750psi, 100rpm on TDS= 3K off /5K on bottom Torques, 8 -10K WOB, (20' new hole in preparations for LOT). 10:00 11:00 1.00 CIRC PP CBU for LOT @ 540gpm Flow rate= 1,650psi, 100rpm on TDS, w /125K RotWt. Pull back into casing, 3,440'- 3,406'. Get slow pump rates prior to suspending circulation. 11:00 12:00 1.00 LKOFF PP Open Kill line & pump 5 BBL's both ways to clear air from lines. Shut in Top Pipe rams, and perform LOT, w /9.6ppg MW= 705psi, (14.1 ppq EMW). Pumped 1.78BBL's, recover 1.5 BBL's, when bleed off pressure. Call in results to Town ODE, while RD test equipment & prepare to drill ahead. 12:00 17:00 5.00 DRLG PP Drill 8 -3/4" hole F/ 3440' to 3833' w/550 gpm flow rate = 2000 psi, 120 rpm w/TD = 5K on / 3K off for torques, 12 -14 K wob. 17:00 18:00 1.00 CIRC PN Ciro & Condition hole while waiting on Halliburton GI plant to get equipment running, w /400gpm= 1,500psi, 100rpm on TDS= 5K off Bottom Torque, Pu Wt= 135K, SoWt= 115K, RotWt =125K. Decision made to Wiper Trip back into casing, as Halliburton will be unable to fix plugging problem in short amount of time. 18:00' 19:00 1.00 STRIP PN Short Trip 3,833'- 3,386' w/o problems, & wait on Halliburton to clear CCU Hopper, Cuttings return line, & C -O lower blades on Hammer mill. CCU hopper has approx. 40 BBL's of cuttings packed off on top of pump suction. 19:00 21:00 2.00 U_SEQ PN Halliburton continue to work on getting CCU Hopper unplug, (rocked Cuttings line from backside w /air & unplug), & pulled covers off Hammer Mill & unplug Upper & Lower sections. Halliburton reported that had CCU cutting line cleared up, & Hammer Mill unplugged. CCU Hopper had cuttings Tote rigged up to blow cuttings into, in event plugged off again. 21:00 21:30 0.50 STRIP PN Rig prepared to & RIH back to bottom w /BHA #2, to 3,833' w/o incidents from Well Bore. 21:30 22:30 1.00 CIRC PN Halliburton not quite ready, a few more issues but working hard to resolve issues. 22:30 23:00 0.50 DRLG PP Drill ahead F/3,833' to 3,890' w /same parameters. Discovered that CCU pump having issues again, as Blockage of Hopper suction was not cleaned out properly, and building up cuttings in hopper. Unable to clear cuttings buildup inside Hopper. 23:00 00:00 1.00 CIRC PN Circulate & condition hole while deciding how to best address Halliburton's issues. Found that the hopper above the pump was totaly packed off, w /50 BBL's worth of clays and cuttings. Made preparations to Short trip to the shoe again, so Halliburton could get cuttings hopper discharge unplugged. Report Start Date Report End Date 5/15/2008 5/16/2008 www.peloton.com Page 4/45 Report Printed: 8/29/2008 , Operations Summary Report Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 00:30 0.50 STRIP PN Hoist 3,890'- 3,320' w/o incidents, due to problems encountered w /HES CCU unit, & Cuttings return line. 00:30 06:30 6.00 U_SEQ PN Work on clearing CCU Hopper, (approx. 50 -60 BBL's of packed cuttings). Attempt to pump10 tares, put unable to get dry cuttings out, (packed off in chute). Rig up line from RSC to inject slurry inside Hopper discharge to pump, (1" manifold). Attempt to free Primary cutting return line, but unable, switch over to secondary line, until able to spend time on same. Establish circulation to RSC shaker and pump out out cuttings in slugs, and trying a couple different fluid mediums, (Sim -Op's: Service rig & TDS, & misc. Rig maintenance issues). 06:30 07:00 0.50 STRIP PN HES gave clearance that able to proceed, once Hopper had been cleared & pumped over to RSC. RIH w /BHA #2, 3,320'- 3,890', w/o incidents or problems, PuWt= 135K, SoWt= 110K 07:00 11:15 4.25 DRLG PP Continue to drill ahead 8 -3/4" Hole section, 3,890'- 4,270', using 540gpm flow rates= 2,040psi, 10 -18K, w /12Orpm's on TDS= 4K off /5K on Bottom Torque. PuWt= 140K, SoWt= 115K, RotWt= 125K ADT= 2.70hrs, TADT= 5.61 hrs, Jars= 5.61 hrs, Drilled 850'= 151.52fph average 11:15 12:00 0.75 U_SEQ PN Total time spent off bottom circulating at reduced rate & Clearing out Plugged possum belly chute @ RSC shaker. Take off inlet on secondary cutting line & flush out same, (completely packed off). Once cleaned out, transfer over 60 BBI's of cuttings in CCU hopper, & limit discharge over shaker, to prevent plugging Hammer mill off also. 12:00 12:30 0.50 DRLG PP Drill ahead F/ 4270' to 4366' 12:30 14:00 1.50 U_SEQ PN Circulate & Conditon hole @ 300 gpm/ 100 rpm while reciprocating. Waiting on Halliburton to get repairs done at CCU, (Weld up connection on Hydraulic line hard & unplug RSC shaker chute). 14:00 20:30 6.50 DRLG PP Drill ahead 8 -3/4" hole section f/4,366' to 4,935' using 580gpm flow rate = 2150 psi, WOB= 10 -18K, w/130 rpm, 5K off /6K on bottom torque. PUW= 150K, RTW =135K, DWT =130K. Average ROP= 150' hr. 20:30 21:30 1.00 CIRC PP Circulate and Condition hole for Short Trip. Took survey a 4,094'. Hole cleaned up good at shakers, monitor well, before starting short trip, (Static). Talked with Geologist about the cuttings and there was no fracturing or splintering observed, they are perfectly cut cuttings. 21:30 22:30 1.00 STRIP PP Short trip 11 stands 4,935'- 3,890' w/o incidents or any hole problems. Hole took proper amount of fluid, observed well and prepared to service Rig. Sim -Op's: Halliburton worked on unplugging Primary cuttings line during this operation, & cleared the line of its obstruction, (also serviced their equipment). 22:30 23:00 0.50 RIGSER PP PJSM on overhead work for TDS. Serviced TDS /Rig and looked over for loose fittings. 23:00 23:30 0.50 STRIP PP Trip back in the hole, 3,890'- 4,935', w/o incidents or problems, (Hole appears in excellent shape). 23:30 00:00 0.50 DRLG PP Drill ahead 8 -3/4" hole section f/4,935' to 4,979' using 590 gpm @ 2,150 psi, WOB= 10 -18K, TDS rpm= 120 w /6K on /5K off for torques. ART= 5.93hrs, ADT= 5.93hrs, Bit= 11.54hrs, Jars= 11.54hrs. Operations Report Report Start Date Report End Date 5/16/2008 5/17/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 04:30 4.50 DRLG PP Drill 8 -3/4" Hole Section, 4,965' - 5,470', w /12 -20K WOB, 120- 13Orpm on TDS, w /5 -6K off & 6 -7K on Bottom, PuWt= 164K, SoWt= 125K, RotWt= 130K, (have to stop DrIg. @ 5,470' & repair Leaky Hydraulic line on Geho pump). 04:30 05:00 0.50 U_SEQ PN Circulate off bottom@ 300gpm= 980psi & rotate @ 12Orpm, while HES CCU make repair to Leaky Hydraulic line on Geho pump, (same one as repaired yesterday). Once welded & back on, clearance given to rig to proceed w /Drilling operations. 05:00 13:00 8.00 DRLG PP Drill 8 -3/4" Hole section per Well Plan & HES DD requirements, 5,470'- 6,168', (planned short trip station). Parameters included, 15 -20K WOB, 12Orpm's on TDS, w /5K off /6.5K on Bottom Torque, 590gpm= 2,900psi, PuWt= 175K, SoWt= 125K, RotWt= 135K. ADT= 7.73hrs, TADT= 18.52hrs, Jar= 18.52hrs, Ftg.= 2,748' w /average of 133.8 fph, MW= 11.4ppg www.peloton.com Page 5/45 Report Printed: 8/29/2008 • Operations Summary Report Ilk Start Time End Time Our (hrs) Op Step Phase P/N Comment 13:00 13:30 0.50 CIRC PP CBU w /590gpm= 2,850psi, & 12Orpm's on TDS while reciprocating drill string, prior to short trip, (planned station). 13:30 15:30 2.00 STMILL PP Shut off Rotary & pumps. Break off TDS, & vac off elevators. Flow check well bore for 10 min's, (static). Hoist BHA #2, 6,168'- 4,935', w/o any swabbing, or hole problems, (max. 5 -10K over while hoisting). The Trip volumes were Calc.= 9.1 BBL's & Actual= 12.7 BBL's, (diff.= 3.6 BBL's more). The assembly was suspended while flow checking the Well Bore for 5 min's, (static), and assembly ran back to bottom w/o incidents, (5 -8K max. over down wt.). Washed last std. down to avoid surging hole, and min. Bottoms up gas. Prepare for continuing Drilling operations, & Short trip went extremely well. 15:30 00:00 8.50 DRLG PP Drill 8 -3/4" Hole section per well plan F/6,168' to 7,000'. Parameters used were 600 gpm @ 3100 psi with 130 rpm on TDS, WOB= 15 -20K, 7K on & 5K off BTM torques. ART =6.45, ADT =6.46, BT= 24.25, Jars = 24.25. PU/WT =180, SO/WT =120, RT/WT =140. Had a issue with RSC and power for shakers but was able to remedy with Nabors electrician's help and not shut operation down. CCU & Mill operations working well., Operations Report Report Start Date Report End Date 5/17/2008 5/18/2008 Start Time End Time Our (hrs) Op Step Phase P/14 Comment 00:00 01:00 1.00 DRLG PP Drill 8 -3/4" Hole Section, 7,000'- 7,117', w /600gpm= 3,000psi, w /20K WOB, 15Orpm's on TDS. PuWt= 175K, SoWt= 122K, RotWt= 140K, ECD's= 13.09, @ 11.9ppg MW, (have to suspend Drilling, due to Top Drive Issues). 01:00 02:00 1.00 U_RIG PN PU off bottom & continue to circulate @ 400gpm= 1025psi, while Changing oil /filter on the Top Drive System, due to contamination & over filling. 02:00 06:00 4.00 DRLG PP Drilling 8-3/4" Hole Section, 7,117'- 7,402', w/130 rpm's on TDS= 5K off /8K on Bottom Torque, 20K WOB, PuWt= 180K, SoWt= 122K, RotWt= 135K, w /600gpm= 3, 250psi. ECD's= 12.43ppg @ 12.0ppg MW, w /ADT= 4.31 hrs, TADT= 28.56hrs, Jar= 28.56hrs, ftg.= 3,982' ROP average= 139.43 fph. 06:00 07:00 1.00 CIRC PP CBU 1.5x to ensure Well Bore clean of cuttings, and even 12.0ppg MW in /out of hole. Check shakers & cleaned up, so decision made to perform upcoming Open Hole LOT. 07:00 08:00 1.00 LKOFF CP Position 2nd TJ above floor & shut down pump /rotation. Open lines to Cement unit in RSC, and pump over 25 BBL's of 12.0ppg MW. Open Kill line & have HES pump 3 BBL's to clear air in line. Shut in Top pipe rams & perform LOT, w /.1 BPM rate, (chart & record same). Recieved a 601psi ISIP @ 7,402'md/ 4,873 i VD, pea aown tb 5T1 psi i - iI @ 10min's. Bleed back 2.01 BBL's from 3.1 BBL's pumped. Open Pipe rams and pump through Kill line 12 BBL's from RSC while comin down to Break out TDS. Blow down Cement line while preparing to Short trip, (well static). 08:00 10:00 2.00 STRIP PP Short trip BHA #2, 7,402'- 6,168' w/o incidents or problems, (max. 5 -10K out/in while tripping). Ensure no swabbing seen, and hole took proper fill ups, (Calc.= 9.1 BBL's /Actual= 10.7 BBL's= 1.6 BBL's Diff.). The Short trip went Extremely well, & hole appears to be in good shape. 10:00 12:00 2.00 DRLG PP Drilling 8 -3/4" Hole Section, 7,402'- 7,592', w/130 rpm's on TDS= 5K off /8K on Bottom Torque, 20K WOB, PuWt= 190K, SoWt= 122K, RotWt= 135K, w /600gpm= 3, 500psi. ECD's= 13.66ppg @ 12.2ppg MW, w /ADT= 1.35hrs, TADT= 29.91 hrs, Jar= 29.91 hrs, ftg.= 4,172' ROP average= 139.48 fph. 12:00 15:30 3.50 DRLG PP Drilling 8 -3/4" Hole Section, 7,592'- 7,858', w/130 rpm's on TDS= 5K off /8K on Bottom Torque, 20K WOB, PuWt= 193K, SoWt= 124K, RotWt= 137K, w /600gpm= 3, 600psi. ECD's= 13.08ppg @ 12.3ppg MW, w /ADT= 4.32hrs, ftg drilled 570' ROP average= 131.94 fph. Geologist confirmed top of Torok @ 7,935' MD = 5,060' TVD. 15:30 16:00 0.50 U_SEQ PN Downtime due to leaking hammer union on standpipe goose neck to kelly hose. Hammer up tighter. 16:00 19:00 3.00 DRLG PP Drill ahead F/ 7,858' to 8,162' using same parameters as prior section drilled. No hole problems. 19:00 20:30 1.50 CIRC PN Circulate bottoms up to prepare for Rig Repair. Circulated @ 600 gpm initally to get cuttings up hole then reduced to 450 gpm to lessen the wash out possibility on standpipe goose neck union. 20:30 22:30 2.00 U_RIG PN Stand back 2 stands DP in derrick. Blow mud line down to prepare for replacement of union gasket. Run 2 stds back in hole and break circulation and prepare to drill. www.peloton.com Page 6/45 Report Printed: 8/29/2008 Operations Summary Report Start Time End Time Dur (hrs) Op Step Phase P/N 1 Comment 22:30 23:30 1.00 DRLG PP Drilling 8 -3/4" Hole Section,8,162'- 8,257', w/130 rpm's on TDS= 5K off /6 -12K on Bottom Torque, 22K WOB, PuWt= 200K, SoWt= 120K, RotWt= 140K, w /575gpm= 3, 650psi. ECD's= 13.9ppg @ 12.5ppg MW, w /ADT= 5.15hrs, hrs, Jar= 35.06 hrs, ftg.= 664' ROP average= 139.48 fph. 23:30 00:00 0.50 U_LC PN Circulating hole to clean cuttings while preparing pits for mixing LCM pill. Observing well and recording losses. Hole is static with pumps off. Operations Report Report Start Date Report End Date 5/18/2008 5/19/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 01:30 1.50 U_LC PN Spot 25 BBL's of 10.0# /BBL of each Baracarb 5 & 25, + 5.0# /BBL of Steel Seal. Displace out of string w /150 BBL's 12.5ppg MW + 20 BBL'S extra to clear BHA. Pump @ 300gpm= 980psi, w /78BPH loss rate= 26% Loss Ratio. 01:30 02:00 0.50 U_LC PN Close Annular Preventer & Bullhead LCM pill #1 w/15 BBL's of 12.5ppg MW, @ 3spm= 50psi, stopping to let pressure bleed off, and work up to 7spm= 150- 200psi, (13.3 EMW w /12.5ppg MW), while holding 100psi & let bleed into fm. Total of 15 BBL's & 180 strokes. Let pressure bleed off to zero & open Annular up, w/Well Bore static. 02:00 04:00 2.00 DRLG PP Drill ahead to determine losses & build cuttings to help seal thief zone in 8 -3/4" Hole Section, 8,257' - 8,351', w /130rpm's on TDS= 5K off & 8K on Bottom Torques. WOB= 20K, PuWt= 175k, SoWt= 135K, RotWt= 150K w /450gpm= 2,400psi, & losses @ 240 BPH rate= 53% Loss ratio. ADT= .71 hrs, TADT= 35.77hrs, Jar= 35.77hrs Ftg.= 4,878' @ 136.37 fp}i average ROP. Had stopped @ 8,286', to monitor well, (3 -5 BPH loss rate), while also taking on 150 BBL's of 12.5ppg MW from RSC to Rig pits. 04:00 07:00 3.00 U_LC PN Mix & pump 40 BBL's of LCM Pill #2, @ 15# /BBL each of Baracarb 5 & 25, + 10# /BBL Steel Seal. Displace w/150 BBL's into open hole w /425gpm= 2,220psi. Shut in Annular Preventer & squeeze @ 9spm= 150psi & allow to bleed off to 100 -Opsi, staging up to 200psi, (13.3 EMW w /12.5ppg MW). Hold 1 o0psi while allowing Pill to bleed off into Thief zone. Bleed off pressure after a total of 30 BBL's squeezed away, & open Annular Preventer (Well Bore static to slight loss @ 1 -3 BPH loss). Loss rate while spotting pill was 125 BPH rate = % Loss Ratio. 07:00 07:30 0.50 DRLG PP Drill ahead to determine losses & build cuttings to help seal thief zone in 8 -3/4" Hole Section, 8,351' - 8,435', w /130rpm's on TDS= 5K off & 8K on • Bottom Torques. WOB= 20K, PuWt= 175k, SoWt= 135K, RotWt= 150K w /460gpm= 2,500psi, & losses @ 240 BPH rate= 52% Loss ratio. ADT= .5hrs, TADT= 36.27hrs, Jar= 36.27hrs Ftg.= 5,027' @ 138.6 tph average ROP. 07:30 08:00 0.50 U_LC PN Circulate @ 300gpm= 920psi, w /40 RPM's on TDS= 5K off Bottom Torque. Experience 240 BPH Loss rate= 36 BPH= 12% Loss Ratio. Pull back to 8,351'. RSC building 200 BBL's of 12.Oppg MOBM, & Rig Pits have Total of 283 BBL's. 08:00 08:30 0.50 U_LC PN Shut down pump to save Volume, & rotate slowly, while monitoring Well Bore, (3 -5 BPH loss rate). Build 60 BBL's of 12.Oppg MW LCM Pill #3, w/65# /BBL Steel Seal, 10 # /BBL each of Baracarb 50/150, & 5 # /BBL Barafiber. Cut MW of Rig Pits to 12.Oppg MW. Consult Town ODE & decision made to hoist back into casing to Build volume & stage back in hole w /12.OPPG MW. 08:30 13:00 4.50 STRIP PN Hoist BHA #2, 8,351- 6,548', Wet), while mixing Dry Job. Ensure not swabbing out of well bore, and fill every 3 std's to ensure hole full, (3 -15 BPH losses). Max. over pull seen was 5 -20K while POOH to Casing shoe. dry Job Job & continue to Hoist, 6,548- 3,384', w /losses slowing down to 3 -7 BPH rate. Total Losses @ 12:0ohrs= 594 BBL's Trip Out schedule has Calculated 42.3 BBL's, & Actual= 81.1 BBL's, (diff.= 38.8 BBL's). 13:00 14:00 1.00 RIGSER PN Service Rig & TDS. C -O Grabber dies on Top Drive. HES continued to bring 200 BBL's of MOBM up to 12.0ppg MW, as directed by Baroid Rep. Losses @ 2.4 BPH rate while static, & continue to Top fill hole continuously. www.peloton.com Page 7/45 Report Printed: 8/29/2008 Operations Summary Report 1 Start Time - End Time Der (hrs) Op Step Phase P/N Comment 14:00 16:00 2.00 U_LC PN Wait on HES RSC unit to finish preparing 200 BBL's of 12.0ppg MW, as directed by Baroid Rep. Transfer over to Rig Pits once completed. Loss rate= 2.4 BPH static. Sim -Op's: HES Hammer mill having Carrier Bearings & Cutters C -O on lower drum while Supervised by Harris Welding Rep. Rig Had Spill & BOP drill. Installed Safety Valve, and simulated shut in, w/Well secured in 1:15 sec's. Leave Safety Valve on, (open), while waiting on RSC. 16:00 17:00 1.00 U_LC PN Take off Safety Valve, & screw into string w/TDS. Rotate @ 40rpm's= 3K off Bottom Torque & Est. circ. @ 300gpm, w /110 BPH loss rate= 37% loss ratio. Cut pump back to 250gpm= 670psi @ 79 BPH loss rate= 32% Loss ratio, until 12.0ppg MW @ bit. Losses dropped to 26 BPH rate= 10.4% loss ratio, & once heavy mud out, losses decreased to 18 BPH rate= 7.2% w/28-30% now returns. PuWt= 130K, SoWt= 112K, & RotWt= 115K. 17:00 17:30 0.50 STRIP PN Break out of string w/TDS & RIH w /BHA #2 @ 50 -60 fpm rate to reduce & avoid surge pressures while tripping in 11std's, 3,416- 4,448'. 17:30 18:15 0.75 U_LC PN Est. circulation @ 275gpm= 800psi @ 40 BPH loss rate= 13.3% Loss ratio. As heavy mud moved up w /BU, decreased to 25 BPH rate= 8.3% Loss ratio. Used 40 rpm's= 4K off Bottom Torque, PuWt= 130K, SoWt= 125K, RotWt= 127K. 18:15 19:00 0.75 STRIP PN Break out of string w/TDS & RIH w /BHA #2 @ 50 -60 fpm rate to reduce & avoid surge pressures while tripping in 11std's, 4,448' - 5,487'. 19:00 19:45 0.75 U_LC PN Est. circulation a 300gpm= 900psi @ 21 BPH loss rate= 7.1% Loss ratio. Used 40 rpm's= 4K off Bottom Torque, PuWt= 140K, SoWt= 130K, RotWt= 133K. 19:45 20:30 0.75 STRIP PN Break out of string w/TDS & RIH w /BHA #2 @ 50 -60 fpm rate to reduce & avoid surge pressures while tripping in 11std's, 5,487'- 6,531'. 20:30 21:30 1.00 U_LC PN Est. circulation @ 300gpm= 980psi @ 54 BPH loss rate= 18.2% Loss ratio. Used 40 rpm's= 4K off Bottom Torque, PuWt= 140K, SoWt= 135K, RotWt= 138K. 21:30 22:15 0.75 STRIP PN Break out of string w/TDS & RIH w /BHA #2 @ 50 -60 fpm rate to reduce & avoid surge pressures while tripping in 11std's, 6,531'- 7,583. 22:15 23:15 1.00 U_LC PN Est. circulation @ 250gpm= 800psi @ 22 BPH loss rate= 8.8% Loss ratio. Used 40 rpm's= 4K off Bottom Torque, PuWt= 153K, SoWt= 140K, RotWt= 150K. 23:15 00:00 0.75 STRIP PN Break out of string w/TDS & RIH w /BHA #2 @ 50 -60 fpm rate to reduce & avoid surge pressures while tripping in 11std's, 7,583' - 8,435'. Total Losses for 24hrs= 864 BBL's Operations Report Report Start Date Report End Date 5/19/2008 5/20/2008 Start Time End Time . Dur (hrs) Op Step Phase P/N Comment 00:00 01:30 1.50 U_LC PN Stage in to bottom @ 250gpm flow rate= 800psi w/24 BPH loss rate= 9.6% loss ratio. Use 40 rpm's on TDS= 5K off Bottom Torque. Wash down 8,351 - 8,435'. 01:30 03:00 1.50 U_LC PN Attempt to drill ahead, to monitor loss rate, and use cuttings to help seal losses. Drill 8 -3/4" Hole section, 8,435' - 8,441', w /450gpm= 2,300psi= 120 rpm's on TDS= 5K off /8 -10K on Bottom Torques. WOB= 20K, PuWt =175K, SoWt= 135K, RotWt= 150K. Loss rate @ 110 BPH= 24.4% loss ratio. Decision made to suspend drilling & spot LCM pill #3. Pull up off bottom, & stop pumping, and slow rpm's to 40 rpm. Pull suction screen on pump to help spot pill. Pump 67.7 BBL's of 12.0ppg MW w/65# /BBL Steel Seal, & 10.0 # /BBL of Baracarb 50/150 & Barafiber, w/a total of 1,825 strokes, (displ. out bit + 5 BBL's). Spot w /pump @ 250gpm= 800psi, & chase out of MWD tools /bit @ 360gpm= 1,500psi, (prevent plugging off tools). Total loss of pill while exiting bit & being spotted @ 6 -7 BBL's, or 1.9 %. 03:00 03:30 0.50 U_LC PN Hoist BHA #2 from 8,441'- 7,972', slowly, while monitoring for swabbing & hole filling, (none experienced). Pulled 175K, w /no excess over pull. www.peloton.com Page 8/45 Report Printed: 8/29/2008 • Operations Summary Report Start Time End Time - Our (Ills) Op Step Phase P /N comment 03:30 09:30 6.00 U_LC PN Shut in Annular Preventer & turn pressure down to 400- 450psi, in preparations for working drill pipe tube between element. Open up through Kill line & zero in all gauges. Initiate Hesitation squeezes@ 5spm rate, until break over seen, (much like LOT), & then record pressure & allow to bleed off to holding pressure over 1 /2hr. Work pipe each time to ensure no differential sticking, & ensure to stop & allow element to relax, before going down. The rate initiated started w /50- 100psi before break over & bled to zero. During course of squeezes, pressure increased to a max. of 285psi, (trying to achieve 400psi - the diff. between 12.0ppg MW & expected 13.4 ECD value @ depth). The bleed back increased relative to break over value from zero- 150psi. Initial volumes pumped also increased from 1 -2 BBL's pumped, to final 3 -5 BBL's on squeezes. Total of 45.6 BBL'S pumped, which, calculated @ final squeeze that possibly mud being squeezed @ 8,220' de th. Bleed 011 slowly w/1.65 BBC's recovered. Open Annular & well bore sta ic. 09:30 11:00 1.50 U_LC PN To allow Well Bore time to relax after squeeze at depth, initialized circulation @ 7,972', & work string slowly, while rotating @ 40rpm on TDS= 4K off Bottom Torque. Pump @ 200gpm= 590psi, & CBU to allow mud to get moving & warm up slightly, (experienced some 17 BPH losses= 8.5% loss ratio. Adding 6 bag's per hour of Steel Seal & Barafiber to aid in sealing Torok fm. Losses. PuWt= 175K/SoWt= 135K/RotWt =148K. 11:00 11:30 0.50 U_LC PN RIH @ 50 fpm rate to avoid surging Well bore while going, 7,972' - 8,441'. 11:30 '16:30 5.00 DRLG PP Drill ahead in 8 -3/4" Hole Section, 8,441' - 8,730', w /Base of the Torok Fm. called @ est. 8,500'md/5,626.1' I VD, (higher than expected), w /rtOI' rates restricted to 80 -90 fph max., due to ECD & hole cleaning restraints. Parameters used incl. 6 -8K WOB, (except at couple hard streaks, (18 -20K), w /120- 13Orpm's on TDS= 5K off /8 -10K rotary Torque. Pumped @ 375gpm= 1,635psi, w /PuWt= 175K, SoWt =135K, RotWt= 150K & 32 -35% flow returns. ECD's were 12.84, (max. @ 12.9EMW -saw a 13.1EMW w /BU). TDT= 4.05hrs, TADT= 40.32hrs, Jar= 40.32hrs, Ftg.= 5,322', ROP Avg.= 131.99 fph. Experienced various losses @ 8,491' - 8,541'= 8 -24 BPH= 2.1 -6.4% loss ratio,8,551'- 8,604'= 115 -2 BPH= 31 -1.0% loss ratio, 8,636' - 8,700'= 14 -90 -24 BPH= 3.5- 24 -6.4% loss ratio's. Continued w /Steel Seal, & Barafiber until 8,670', where switched to BaraCarb 50/150 mix, & slowed additions to 3 Bags /hr each. Drilled to 8,730' where pull off bottom for connection & 100% losses occurred. Total Losses @ 12:OOhr= 232 BBL's / Total Losses for Well= 926 BBL's 16:30 19:00 2.50 U_LC PN Pull off bottom & shut down pump down the hole. Fill back side w /hole fill, (took 29 BBL's to fill hole), & experiencing 70 BPH losses, which increased to osses, ini is inn , : s owe. o .1 - - osses. Consult w/Town ODE & plan 90 -95 BBL Salt Water LCM Pill #4 w /same concentrations as Pill #3, w/60 -65# /BBL Steel Seal, 10 # /BBL BaraCarb 50/150, BaraVis to bring viscosity to 60 -65, & 12.0ppg w /Barite. Switched to Base Mineral oil to fill backside, w /losses @ 38 BBL's + initial 142 BBL's of MOBM. Well bore went static to 1 -2 BPH loss rate. Working pipe, but soon as rotating @ 40rpm, loss increase 24 BPH rate. Continue to mix LCM pill #4, while monitoring loss rate filling backside. 19:00 21:00 2.00 U_LC PN Pull up 13 std's, (in preparations for spotting LCM Pill #4), 8,730'- 7,522', having to rotate 8 Std's out, (25K over pull), & no rotation other 5 Std's, (5 -10K over). Total of 41 BBL's to keep back side full while Pulling up to 7,522'. 21:00 22:00 1.00 U_LC PN Est. circulation w /253gpm= 703psi= 1 8 BPH= 46.5% loss Ratio. Shut down pump & continue to prepare for LCM Pill #4. Well bore static, until resumed Rotation @ 40rpm= 70 BPH loss rate, shut down rotation & just reciprocate string slowly. PuWt= 160K, SoWt= 145K, RotWt= 150K. 22:00 23:30 1.50 U_LC PN Line up to & pump LCM Pill #4, 95 BBL's Total pumped, @ 300gpm= 1,482psi= 140 BPH loss rate= 33% loss ratio, while displacing Pill to Bit, (1,663 Strokes). Shut down pump & closed Annular Preventer, Bull Head 82gpm= 318psi, & 102gpm= 348psi, & pump Pill + 5 BBL's to displace from Drill string. Shut pumping operations down & monitor Well Bore, (100psi recorded), & let LCM Pill #4 set up. www.peloton.com Page 9/45 Report Printed: 8/29/2008 1 Operations Summary Report 40 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 23:30 00:00 0.50 U_LC PN Intiate Hesitation squeeze's & turn Annular Pressure down to 400- 450psi, in preparations for working drill pipe tube between element. Zero in all gauges. Initiate Hesitation squeezes@ 5spm rate, until break over seen, & record pressure's. Allow to bleed off to holding pressure over 1 /2hr. Work pipe each time to ensure no differential sticking, & ensure to stop & allow element to relax, before going down. The rate initiated started w /180 -250 psi before break over & bled to 115 psi and held constant. During course of squeezes, pressure increased to a max. of 250psi, (trying to achieve 400psi - the dill. between 12.0ppg MW & expected 13.4 ECD value @ depth). The bleed back increased relative to break over value from 105- 118psi. Initial volumes pumped were 3 -5 BBL's on squeezes. Operations Report Report Start Date Report End Date 5/20/2008 5/21/2008 Start Time End Time Our (hrs) Op Step Phase P/N Comment 00:00 03:30 3.50 U_LC PN Continue w /Hesitation squeeze's & allow to bleed off to holding pressure over 1 /2hr. Work pipe each time to ensure no differential sticking, & ensure to stop & allow element to relax, before going down. The rate initiated started w/180 -250 psi before break over & bled to 115 psi and held constant. During course of squeezes, pressure increased to a max. of 250psi, (trying to achieve 400psi - the diff. between 12.0ppg MW & expected 13.4 ECD value I) depth). The bleed back increased relative to break over value from 105- 118psi. Initial volumes pumped were 3 -5 BBL's on squeezes. 03:30 05:00 1.50 U_LC PN Est. circulation staging up 50gpm per schedule, 50gpm= 65psi, 100gpm= 120psi, w/25 BPH loss rate= 25% loss ratio. PuWt= 165K, SoWt= 140K, RotWt =145K, w /40 rpm's= 4 -5K off Bottom torque. Shut down due to losses. 05:00 06:00 1.00 U_LC PN RIH @ 50 fpm rate to avoid surging Well bore while going, 7,500'- 7,905'. 06:00 06:30 0.50 U_LC PN Try to Est. circulation w /50gpm flow rate= 200psi @ 36 BPH= 50.4% loss ratio, (lost 10 BBL's & shut to avoid pumping excess mud away). 06:30 09:30 3.00 U_LC PN Continue to reciprocate Drill String while finish building 95 BBL's of HES 12.0ppg Hydro Plu LC per Baroid Mud Rep. Well was static w /no pumping. Held PJ w a re a ed parties, & ensure all gauges /straps zero. Clean off element area of DP were setting and Doped same. Sim -Op's: Take on 250 BBL's of 12.0ppg MOBM from RSC to Rig Pits. 09:30 10:30 1.00 U_LC PN Mix in Hydrating Polymer to LCM Pill #5, (Hydro Plug), & plug @ 09:45, (1.5hr pump time available). Pump @ 250gpm, (screen out of pump), @ 230psi, & built to 760psi while pumping a total of 88 BBL's recovered from pit, (loss 27.6 BBL'S while pumping). Switch to active system pit #5, while taking returns to other pits, to ensure accurate strap of volume pumped, & returns. Pump per procedure, (adj. for 88 BBL's)= 619 strokes, w /104.1 BBL's loss while displacing @ 250gpm= 1,150psi, (temporary staged to 350gpm= 1,500psi to achieve MWD signal - still working). Once @ bit, shut down & close Annular Preventer w /400psi closing pressure. Bull Head plug into fm. w /staged pump rate, 100gpm= 340psi, 150gpm= 600psi, & 170gpm= 670psi, which built up to 875psi & broke over to 740psi. Increase to 200gpm= 890psi, w /rate @ 750psi for final pressure. Once in place w/1,158 strokes, (98 BBL'S total= 88 BBL's pill & 10 BBL excess), shut down w /87psi ISIP. Plug in place @ 10:40am. 10:30 17:00 6.50 U_LC PN .1„/\_Ilij on Pill #5 to set ue,,per Baroid schedule, (MWD recorded 118 degree BHT= 5 -7hr set time). Rotate drill string every .5- .75hrs, w /total of 15 wraps per try, (pipe had previously been rotated prior to pumping pill= 6 wraps to break over). Each time rotated, pressure bled off, 87- 47 -36 -3 -Opsi, & break over went down, 4 -3 -2 wraps, & continued to take 2x wraps to break over. This continued until 17:15hrs, which was 6.5hrs total set up time. www.peloton.com Page 10/45 Report Printed: 8/29/2008 Operations Summary Report • Start Time ( End Time Dur (hrs) Op Step Phase P/N Comment - 17:00 19:00 2.00 U_LC PN Bleed off any trapped pressure, (gauged @ zero psi). Recover to trip tank, but very slight flow. Open Annular Preventer & see very little flow. Est. slow rotation @ 40 rpm's= 6K, work string up= 180K break over. Start pumping w /50gpm increment, (50gpm= 380psi, 100gpm= 211 psi, 150gpm= 380psi, 200gpm= 556psi), all w/o any losses recorded. Increased to 250gpm= 801psi w/48 BPH loss rate= 13.4% loss ratio,& 300gpm= 1,137psi= 60 BPH loss rate= 14.0 loss ratio, & 350gpm= 1,424psi= 120 BPH loss rate= 24% loss ratio. Cut pump back 200gpm & finish CBU, w /tota[52BisEs total w/o any LCM material seen across shaker's. Shut down & monitor Well bore for 1 /2hr, (static). 19:00 00:00 5.00 U_CMT PN Lay down single & POOH F/ 7922' to 7,416 (wet pipe). Hole not taking proper fluid7 slightly swabbing. Pump 20 bbl dry job and pull up to 6,941' (5 std's) monitoring hole. Make up TDS and rotate @ 130 rpm while moving up, hole took 2 bbls, (diff of 1.5 bbls), Blow down TDS. POOH to 6,466' and rotate @ 130 rpm 5th std while pulling, hole took 3.0 bbls (diff of .6 bbls). POOH to 5,991' and rotated up on 5th std again. Hole took 3.6 bbls, OK. Did same procedure for next 10 stds with proper hole fill of 3.5 bbls per 5 stds. Hole then started accepting fluid with out rotating. We probably have a ball on the end and knocked off some of it through some hard formations per dicussion with geologist. POOH to 3,087' @ midnight. Operations Report Report Start Date Report End Date 5/21/2008 5/22/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 02:00 2.00 U_LC PN Tripped out of hole F/3701' To/ 377'. 02:00 05:00 3.00 U_LC PN Lay down BHA #2, stand back drill collars, unload Nukes, down load recorded data. 05:00 06:30 1.50 U_LC PN Layed down BHA #2 and cleared rig floor of exess tools. 06:30 07:00 0.50 U_LC PN M/U WBRT and pull wear bushing. 07:00 11:00 4.00 U_LC PN Set test plug, fill stack stack with water. TestTest BOPEper AOGCC requirements, Test Annular Preventer, (250psi Low /2,500psi High). Continue to test all BOP stack components, choke manifold valves, TDS 1 -BOP valve /manual valve, & all floor valves per NAD test procedure to 250psi Low /3,500psi High, & chart same, Function test Accumulator system, per AOGCC requirements, (OK). Function test Gas detection alarms & LEL, (OK). Pull Vetco Gray test plug & install wear bushings, LD testing equipment. (Tests witnessed by Lou Grimaldi AOGCC) 11:00 12:00 1.00 U_LC PN Service Top drive, travelling block and crown block. Changed gearbox oil and filter. 12:00 16:00 4.00 U_LC PN PU & MU BHA w/ Bit #3 on 5" Drill pipe and TIH to 3,400'. 16:00 17:00 1.00 U_LC PN Circulate Mud to condition to new MW of 11.5 all around. Started pumping @ 100 gpm =95 psi/ increased to 200 gpm= 150 psi, RPM= 40, UP WT =110K, DN WT =102K, RW =107K. Total losses were 2 bbls. 17:00 19:00 2.00 U_LC PN TIH to 4,460' and circulate BU conditioning MOBM to 11.5 MW. No losses to hole. 19:00 21:00 2.00 U_LC PN TIH to 5,503' and circulate BU and condition MOBM to 11.5 MW. Total losses were 9 bbls. 21:00 23:30 2.50 U_LC PN TIH to 6,551' and circulate BU and condition MOBM to 11.5 MW. Total losses were 1 bbls. RPM= 40, 200 gpm =170 psi. UW =138K, DW =138, TQ= 4K. 23:30 00:00 0.50 U_LC PN TIH to 6,745'. Hole in good shape. Report Start Date Report End Date 5/22/2008 5/23/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 01:00 1.00 U_LC PN Continue to RIH w /BHA #3 to spot Turbo -Chem LCM Pill #6, 6,745'- 7,900', @ 50 -60fpm rate, to avoid surging hole. Actual & Calculated Hole fill volumes w /in .3 BBL's (ok), & SLM to ensure accuracy of pipe tally. 01:00 02:30 1.50 U_LC PN Stage up circulation @ 100gpm= 250psi, 150gpm= 320psi, 200gpm= 360psi, & CBU, (lost total of 17 BBL's when BU hit shakers & unloaded cuttings & Hydro Plug materials). No losses recorded while staging to 200gpm, & had 40rpm's on TDS w /5K off bottom Torque, PuWt= 165K, SoWt= 1351K, & RotWt= 150K. www.peloton.com Page 11/45 Report Printed: 8/29/2008 ro Operations Summary Report • Start Time End Tine Our (hrs) Op Step Phase PfN Comment 02:30 07:30 5.00 U_LC PN Continue to circulation @ 200gpm= 360psi, due to CCU -RSC loaded up w /cuttings & Hydro Plug materials). No losses recorded while circ.@ 200gpm, & had 40rpm's on TDS w /5K off bottom Torque, PuWt= 165K, SoWt= 135K, & RotWt= 150K. Once ready, prepare to Wash /Ream to bottom. 07:30 11:00 3.50 U_LC PN Wash /Ream @ 15fpm, to ensure not to load up CCU -RSC w /Hydro Plug cuttings, but not alot seen, (saw a medium load of sand come across w /BU). Continue w/o having to use 0 -2K WOB & 60rpm's on TDS= 5k off Bottom Torque, until 8,700' where tagged up on bridge, (4 -6K WOB, and thru in @ 8,703'). Losses also started to increase to 20 -42 -78 BPH Loss rates= 9.3 % -19..' 0- •. • - o, " • e . e - ... " . .. e = • 5psi. Slowed flow rate to 100gpm= 385psi, w/36 -60 BPH Loss rate= 25.2 % -42 %. Continue to wash down to 8,730' w/o further incidents, but loss rates continued. Ensure any cuttings, circulated well up the Annulas, & shut down pumping, due to losses. Rotate slowly, w /40 rpm's @ 4 -5K off bottom Torque, PuWt= 165K, SoWt= 135K, RotWt= 150K. 11:00 12:00 1.00 U_LC PN Monitor well bore due to Breathing conditions. Initial shut down rate @ 20 BPH, & continue to monitor well bore w /tlow slowing to 2 BPH in 45 min's. Consult w/Town ODE over change of actions. 12:00 12:45 0.75 U_LC PN Attempt to Drill 10', to ensure that across any fault @ bottom of hole, w /80 -140 rpm's on TDS= 5K of /7K on Bottom Torques, 8 -20K WOB, 170gpm= 434psi, @ 120 BPH loss rate= 49.4% loss ratio, but unable to make progress despite various parameters, lost Total of 50 BBL's in attempt. Suspend attempt w/o making any ftg., as losing at unacceptable rate. 12:45 13:15 0.50 U_LC PN Open Kill line & pump 2 BBL's to ensure air out line. Close Annular Preventer & 4" Demco on Stand pipe. Perform Open Hole LOT w /125psi achieved, before break over & Total of .761 BBL's pumped. ISIP pressure was 50 psi, which bled off to zero w /in a minute. Used 11.5ppg MW @ 8,694'md/5,324'Tvd= 11.95ppg EMW. Shut down & prepare for Injectivity test. 13:15 14:30 1.25 U_LC PN Perform Infectivity ste test, per outlined schedule, of .5 BPM @ 6spm= n4psi, 1.0 BPM 1 spm= 161 psi, 1.5 BPM @ 18spm= 227psi, 2.0 BPM @ 24spm= 287psi. All steps were w /max. 2 BBL's pumped away, for 8 BBL Total loss. All ISIP were 52- 58psi, which bled off to Opsi < 1 min. Bleed off through bleeder, (zero pressure), & open Annular Preventer, (slight 9 BPH Breathing rate, & died down to 0 BPH rate in 20 min's). 14:30 16:30 2.00 U_LC PN Circulate and condition hole and build volume. Observing well for breathing or losses. Finish the mixing of 65 bbl SweILCM pill and prepare to pump. 16:30 17:00 0.50 U_LC PN Line up and pump SweILCM pill. Total volume of pill pumped was 63 bbls. Chased with 3 bbl MOBM spacer per procedure. Stop any more pumping. Prepare to clean pit for pill #2. 17:00 00:00 7.00 U_LC PN Rotating DP @ 40 rpms w/ 6K torque. Observing well for losses or gains. No losses or gains observed. Continue to mix pill #2 EZ squeeze. Having some difficulty with pill getting thick and to mix EZ Squeeze slowly to keep hopper from over flowing. Called Turbo Chem rep for advice. Advised mixing 1/2 barite required before adding final pallet of EZ Squeeze sack material. Mixing rate improved. Operations Report Report Start Date Report End Date 5/23/2008 5/24/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 05:30 5.50 U_LC PN Observing well by just rotating at 40 rpm and working pipe with SweILCM pill and spacer in pipe. Working on cleaning of mix pit and the preparation and mixing of second EZ squeeze pill. 05:30 06:30 1.00 U_LC PN PumD EZ Squeeze pill @ 3 bpm 500- 950 psi. Note: Had difficulty both mixing & pumping this pill as it was very thick. We did get 71 bbls pumped and chased with 14 bbls MOBM to have the pill below the first stand we set back. 06:30 09:30 3.00 U_LC PN We then continued to POOH pumping 84 stks per std to 6,530'. Parameters were 40 rpm with 5K torque and 1000 psi. Circulated 800 strokes and pumped dry job in combined strokes. POOH to shoe. 09:30 12:00 2.50 U_LC PN POOH F/ 6,530' to 3,406' and monitor well. 12:00 13:30 1.50 U_LC PN Waiting on orders for squeeze job. Change oil in TDS. Observe well, Static. www.peloton.com Page 12/45 Report Printed: 8/29/2008 1 Operations Summary Report 1 - Start Time End Time Dur (hrs) Op r Step Phase P/N 1 Comment 13:30 16:00 2.50 U_LC PN Pumping squeeze cycle #1. Squeeze 37 bbls @ 6 spm and observe pressure build up to 203 psi and fell back to 170 psi at end. 16:00 00:00 8.00 U_LC PN Continue to perform squeeze cycles every hr. until 19:00 with psi climbing results. During this time frame the psi increased f/196 to 190 on cycle 3, f/227 to 221 psi on cycle 4, f/ 212 to 195 on cycle 5. From 19:00 to 23:30 performed 2 squeezes with 2 hr wait time per consulting of Thermo Chem rep & Joe Polya. Cycle 6 psi went from 190 initial to 187. Cycle 7 went from 194 inital to 189 for 2 bbls, we were advised to pump the other 4 bbls if we did not see a increase in the first 2. We did so with a slight increase of 193 psi after 2 bbls to 194 psi after 4 bbls. We then consulted Joe and he agreed with a plan to prepare for another pill of EZ squeeze to be laid out f/8,250'. We are also going to try and mix pill in 20 bbls batches w/ Halliburton cement pump. We also have a contingency plan and will clean and have Nabors mix pit ready if Halliburton plan to difficult. Operations Report Report Start Date Report End Date 5/24/2008 5/25/2008 Start Time End Time Our (hrs) Op Step, Phase - P/N Comment 00:00 01:30 1.50 U_LC PN Pumping last cycle of sqeeze and close in w/ 200 psi, monitor well for 20 min. Bleed off pressure and open annular and observe well for breathing, slight flow. Prepare for TIH. 01:30 07:00 5.50 U_LC PN TIH F/ 3,407' to 7,026'. Hit tight spot, MU TDS attemt to circulate, unable. POOH to 6,736' and regained circulation. Shut down pumps and check for flow. OK. Washed and reamed back down maintaing circulation until reaching 7,560' with partial returns. RIH F/ 7,320' to 7,560' on elevators. Unable to circulate at 7,560'. Parameters were 40 spm = 400 psi, 40 rpm = 4K torque. 07:00 07:30 0.50 U_LC PN POOH F/ 7,560' to 7,320' and establish circulation. 07:30 10:00 2.50 U_LC PN Wash & Ream F/7,320' to 8,731' @ 2 bpm = 360 psi, 50 rpm = 4K torque. 10:00 11:00 1.00 U_LC PN Circulate hole at 2 bpm = 360 psi, 40 rpm, monitoring losses. Shut down pumps and observe well breathing for 30 min, confirmed well is breathing. 11:00 13:30 2.50 U_LC PN POOH F 8,731' to 8,100', PU wt =175K, SO WT =130 K. TIH F 8,100' to 8,392'. Monitor well 5 min. Continue TIH F/ 8,392' to 8,720'. POOH F/ 8,720' to 8,000' and monitor well. PU WT = 175K, SO WT = 130K. 13:30 23:30 10.00 U_LC PN Circulate hole @ 8,000' with 2 bpm= 200 to 280 psi for 30 min. Stop circulating and pump 1st 20 bbls of EZ squeeze pill F/ Halliburton of the 100 bbls we are mixing and pumping into the drill string c 5- 20 bbls batches. Monitor well breathing @ 1 bbl hr. Drill String cap.@ 8,000 ' = 138 bbls. Chase and spot the 100 bbl EZ pill w/ 40 bbls of MOBM. Prepare to TIH. Blow down cement line & wash up. 23:30 00:00 0.50 U_LC PN TIH F/ 8,068' to 8,542' @ 40 fpm. 125K DN WT & 175K UP WT. Report Start Date Report End Date 5/25/2008 5/26/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 01:30 1.50 U_LC PN TIH to 8,730', MU TDS and start pumping LCM EZ pill and POOH @ 84 stks per stand to 8,740' lay a total of 66 bbls in open hole. Parameters were 40 rpm= 5K torque, 3bpm = 1200psi. PUWT =175K, SOWT =125K. 01:30 18:00 16.50 U_LC PN Close annular and start squeeze cycle #1 of 37 bbls/ 418 stks @ 6spm. Final psi was 343 psi and bleed down to 240 psi. A waiting period of 50 minutes between all cycles.Closed top pipe rams and lined up on kill line also for remaining cycles. Performed cycle #2 of 7 bbls/ 83 stks @ 6spm= initial 275psi, final 369psi. Cycle #3 of 5 bbls /60stks @ 6spm= initial 300psi- 10stks in 425 psi broke back to 395psi, final 288psi. Cycle #4A of 2 bbls /22 stks @ 6spm= initial 124psi, final 425psi. Let stabilize and performed cycle #4B of 1.2 bbls /15stks @ 6spm= inital 142psi, final 390psi, broke back to 375 psi. Cycle #5 of 1.2 bbls /15stks @ 6spm= inital 142psi, final 390 psi, broke back to 375- 380psi. Cycle #6 of 2 bbls /24 stks @ 6spm= initial 0 psi (bleed pressure off and rotated string) 6 stks 166 psi, final 330psi, broke back to 320- 325psi. Cycle #7 of 1.7 bbls /20stks @ 6spm= initial 84psi, final 425 psi. Cycle #8 of 2 bbls /25stks @ 6spm= initial 80psi, final 425psi. Monitor pressure for 4 hrs= 42psi. www.peloton.com Page 13/45 Report Printed: 8/29/2008 1 Operations Summary Report S Start Time End Time Dur (hrs) Op Step Phase _ PIN Comment 18:00 00:00 6.00 U_LC PN Break circulation and condition mud @ 2bbls min/ 24 stks, rotating @ 20 increasing to 50 rpm, 600 psi, increased rate to 3bbl /min. Experienced losses over shaker after 15 minutes. Heavy amounts of LCM coming back, cut back rate to 2 bbl min while washing screens. 1200 stks into 1st BU of 4643 stks shut down pumping to clean and change shaker screens to minimize losses. Increase flow rate 3 bbl /min 1/2 way into BU and still showing losses over shaker, reduced back to 30 spm, 475 psi @ 4400 stks. Shut down, wash & change shaker screens. Parameters were 50 rpm= 4 -5K torque, 24 spm= 250psi, UPWT =155K, DNWT =125K, RTWT =135K. Total bbls squeezed away was 60. Operations Repo Report Start Date Report End Date 5/26/2008 5/27/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 04:00 4.00 U_LC PN Circulate & Condition @ 4 to 7 bbl /min rates, with 450 to 600 psi, 50 rpm = 4K Torque. Slow rate due to heavy concentration of LCM coming over shakers to control fluid losses. Change out a few shaker screens. Continue circulating staging rates up every 15 min 5 -10 spm to what shakers can handle. 04:00 06:00 2.00 U_LC PN Continue to circulate 2 bottoms up @ 350 to 450 gpm= 850 to 1,350 psi, 50 rpm= 4K torque. Working pipe F/ 7,840' to 7,750'. 06:00 12:00 6.00 U_LC PN Start washing & reaming F/7,840' to 8,375' @ 215gpm= 500psi, 10 -20 rpm= 5K torque. Changed some shaker screen to help with shaker fluid losses. 12:00 14:00 2.00 U_LC PN Continue to wah & ream F/ 8,375' to 8,492' @ 10 -20 rpm = 3 -4K torque, 50 -60 spm = 350 to 450 psi, 5 -8K WOB. UPWT =165K, DNWT =125K, RTWT =140K. 14:00 16:00 2.00 U_LC PN Circulate & condition hole & MOBM @ 8,492' w/40 -90 spm= 178 to 335 gpm, 20 to 50 rpm= 3 -4K torque. Stage up flow rate as allowable for shakers. 16:00 19:30 3.50 U_LC PN Wash & ream F/ 8,492' to 8,700' @ 48 to 90 spm= 178 to 335 gpm= 575 to 800 psi, 50 rpm = 4 -5K torque. UPWT =180K, DNWT =120K, RTWT =143K. 19:30 21:30 2.00 U_LC PN Circulate & condition hole & MOBM @ 8,700' w /80 spm =281 gpm =675 psi, 50 rpm= 4 -5 torque. 21:30 22:30 1.00 U_LC PN Wash & ream F/8,700' to 8,731' @ 1ft/min ROP w/ 3bpm= 36 spm= 300psi, 10 rpm= 3 -5 torque. No losses to hole, slight losses over shakers. 22:30 00:00 1.50 U_LC PN Circulate & condition hole & MOBM @ 8,731 w /60spm increasing in 10 min intervals to 120 spm= 211 to 422 gpm= 650 to 1250 psi, 15 rpm= 3 -4K torque. Performed SPR on both pumps @ 8,700' @ 20 & 40 spm rates. Report Start Date Report End Date 5/27/2008 5/28/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 03:00 3.00 U_LC PN Circulate @ 8,731' w/375 -450 gpm= 1000 -1450 psi w/ 5 rpm= 4K torque. Transfer 650 bbls of new MOBM f/ RSC to rig, send 524 bbls to RSC f/ rig to have cleaned up. Monitor well for 15 minutes, confirm well is breathing slightly. 03:00 11:30 8.50 U_LC PN POOH F/ 8,731' to 8,535', monitor well 45 min for breathing. UPWT =175K, DNWT =125K. Continue to POOH f/8,535' to 7,860' pumping out metal displacement only. Monitor well 20 minutes. 50K overpull @ 8,325, 25K overpull @ 8,036'. POOH f/ 7,860' to 7,490' swabbing slightly, pumped 190 stks= 16bbls. POOH f/ 7,490' to Bit. No overpull or swabbing. Break off bit/bit sub and clear rig floor. Tested choke manifold while POOH. 11:30 13:30 2.00 U_LC PN PU/ MU single and prepare rig to cut drilling line. Slip & cut 54' of drilling line. 13:30 14:30 1.00 U_LC PN Service rig &TDS. 14:30 20:30 6.00 U_RIG PN Downtime, change out TDS torque booster, change oil, adjust link tilt and grabber. 20:30 00:00 3.50 U_LC PN PU BOPE testing tools and test to 250 psi / 2500 psi on annular for 5 minutes. Test 250 psi / 3500 psi on Upper /lower pipe rams, blind rams, dart valve, set6171751WIFFTTIMFFICR & manual valves for 5 min each. Perform koomey draw down test. Report Start Date Report End Date 5/28/2008 5/29/2008 Start Time End lime Our (hrs) Op Step Phase P/N Comment 00:00 07:00 7.00 U_RIG PN Change out Upper IBOP valve on Canrig Top Drive and adjust Gripper. 07:00 07:30 0.50 U_LC PN Test IBOP valve 250/3500 per AOGCC, Nabors & Pioneer policies. 07:30 08:00 0.50 U_LC PN Pull BOP test plug and install Wear Bushing. www.peloton.com Page 14/45 Report Printed: 8/29/2008 ti Operations Summary Report IP . Start Time End Time Our (hrs) Op Step Phase P/N Comment 08:00 11:30 3.50 U_LC PN Make up SSDD BHA #4 per HES Directional Personnel, down load MWD and shallow test tools 350 GPM, 700 PSI. 11:30 13:00 1.50 U_LC PN M/U float sub and stabilizer, P/U source adn install same. Pick up collars. 13:00 16:00 3.00 U_LC PN TIH F/ 662' To/ 3408'. 16:00 17:00 1.00 U_LC PN Circ. and Condition, stage pumps up to 400 GPM, 112 SPM, 1350 PSI and circulate bottoms up. 17:00 18:00 1.00 U_LC PN TIH F/ 3408' To/ 5500'. P /U -150K, S/O -125K, Rot -140K. 18:00 19:30 1.50 U_LC PN Circ. and Condition, stage pumps up and circulate B /U. 19:30 21:00 1.50 U_LC PN TIH F/ 5500' To/ 6690', tagged obstruction with 25K WOB. 21:00 22:30 1.50 U_LC PN B/C and stage pumps up to 340 GPM with good detection by MWD /Sperry. 12.03 ECD. Wash thru obstruction and circulate bottoms up. Had significant increase in LCM (EZ Squeeze product). Initial PVT 535 BBL, Final PVT 511 BBL, Observed well for flow back to 519 BBL PVT with each barrel back slowing. 22:30 23:30 1.00 U_LC PN TIH F/ 6690' To/ 7590'. Tagged obstruction 25K exess WOB. 23:30 00:00 0.50 U_LC PN B/C stage pumps up to 127 GPM w/ 400 psi, ROT Wt -145K. Operations Report Report Start Date Report End Date 5/29/2008 5/30/2008 Start Time End Time 1 Our (hrs) Op Step Phase P/N Comment 00:00 02:30 2.50 U_LC PN Circulate and condition at 7590'. Staged pump rate from 168 GPM to 294 GPM with 1200 PSI, 40 RPM with 6K TQ. Well packed off while circulating at 7586'. 15K over pull , set down 20 K with no pipe movement and low returns. Racked back 1 stand and attempted to pull on elevators, 75 K over pull and fired jars at 7530'. M/U TDS, B/C and work up to 210 GPM, 700 PSI, 40 RPM, 6K TQ and work through tight spot up to 7495'. Pumped 10 BBLs LCM Pill. - '-' 02:30 05:00 2.50 U_LC PN Back ream F/ 7495' to 6690' with 210 GPM, 700 PSI, 40 RPM, 6K TQ. 05:00 08:00 3.00 U_LC PN Circulate and condition at 6690', 350 -425 GPM, 1550 -1950 PSI, 40 -100 RPM, 5K TQ. 08:00 12:00 4.00 U_LC PN Wash and ream F/ 6690' to/ 7150', 350 -375 GPM, 1500 -1630 PSI, 120 RPM, 6K TQ. 12:00 17:00 5.00 U_LC PN Wash and ream F/7150' To 7550', well packed off. Staged pumps up to 375 GPM, 1630 PSI, 120 -130 RPM, 5 -7K TQ, 150k ROT WT, 177k P /U, 120k S /O, wash at 3 -5 Ft/min. Monitor well each connection till flow back slows. Before pack off getting back 90 -95 %. 17:00 17:30 0.50 U_LC PN Well packed off at 7550', lost 30 BBLs, observe well for flow back, had slower flow back of ballooned fluid and only got back + or - 70% of lost fluid. 17:30 22:30 5.00 U_LC PN Wash and ream F/7550' To/ 7970'. Staged pumps up to 300 GPM, 1180 PSI, 120 RPM, 5 -7K TQ, 150k ROT WT, 177k P /U, 120k S /O, wash at 3 -5 Ft/min. Monitor well each connection till flow back slows. Before pack off getting back 90 -95 %, after pack off at 7550' getting back 70 -40% decreasing each connection. 22:30 00:00 1.50 U_LC PN Per discussion with PNR ODE, Circ. B /U, to POOH and lay down BHA. At 108 GPM losing 10% during bottoms up circulation. Report Start Date Report End Date 5/30/2008 5/31/2008 Start Time End Time Our (hrs) Op Step Phase P/N Comment 00:00 02:00 2.00 U_LC PN Circulate Bottoms up at slow rate to minimize losses. 100 GPM, 350 PSI, 126 RPM, 6K TQ. Losing 10% at this rate. Observed well with pumps off 15 min. to verify well ballooning fluid back and not flowing. Each barrel flowed back slowed. 02:00 03:00 1.00 U_LC PN Pump out of hole F/ 7970' To/ 7400'. 84 GPM, 40 RPM. 03:00 05:00 2.00 U_LC PN Pull on elevators F/7400' To/ 6065'. P/U 180k, S/O 120K. 05:00 05:30 0.50 U_LC PN Pumped Slug and monitor well to verify ballooning. Flow back slowed after initial slug fall. 05:30 08:30 3.00 U_LC PN POOH on elevators F/ 6065' To/ 660'. 08:30 10:00 1.50 U_LC PN Lay down BHA, Rack back jars and HWDP and flex collars. Remove RA source. 10:00 13:30 3.50 U_LC PN Lay down BHA and down load MWD. 13:30 15:00 1.50 U_LC PN P/U spare LWD and break and lay down same for helicopter transfer. 15:00 16:00 1.00 U_LC PN Service Top Drive, blocks and crown. 16:00 18:00 2.00 U_LC PN Wait on ghost reamer & SPS circulating sub. www.peloton.com Page 15/45 Report Printed: 8/29/2008 1 Operations Summary Report le Start Time End Time Dur (hrs) Op Step Phase P/N 1 Comment 18:00 19:30 1.50 U_LC PN Make up 6 1/8 bit, subs and stabilizers. 19:30 20:00 0.50 U_LC PN TIH with 5 stands HWDP and Jars. 20:00 23:00 3.00 U_LC PN TIH on 5" drill pipe F/ 584' To/ 3408'. P/U 115K, S/O 105K. 23:00 00:00 1.00 U_LC PN Circ. and condition mud at 3408'. Stage pumps to 128 GPM, 160 PSI, 40 RPM, 1 K TQ. Cut mud to 11.3 PPG from 11.5 PPG with arctic grade diesel per ODE Pioneer. Operations Report Report Start Date Report End Date 5/31/2008 6/1/2008 Start Time End Time DUI (hrs) Op Siep Phase P/N Comment 00:00 01:30 1.50 U_LC PN Circulate and condiiton at 3408'. 120 GPM, 160 PSI, 10 RPM, TQ 2K, ROT WT -115K, S /0 -107K, P /U -117K, monitor well for 15 min on trip tank. Flowed back less than .25 BBLs in 15 min. 01:30 03:30 2.00 U_LC PN TIH F/ 3408' To/ 5000', P /U140K, S /O -120K. 03:30 06:00 2.50 U_LC PN Circulate and condition OBM, stage pumps up to 230 GPM, 440 PSI. Lost 17 BBLs while circulating and cutting mud to 11.3 PPG in and out. 06:00 08:00 2.00 U_LC PN TIH F/ 5000' To/ 6600'. P/U 155K, S /O -120K. 08:00 10:00 2.00 U_LC PN Circulate and condition at 6600'. 200 GPM, 420 PSI, 55 RPM, TQ -5K. 10:00 11:30 1.50 U_LC PN TIH F/ 6600' To/ 7414'. P /U -165K, S /O -125K. 11:30 12:00 0.50 U_LC PN Ream and wash F/ 7414' To/ 7513'. 120 GPM, 293 PSI, 120 RPM, TQ -6K, Rot WT -145K. 12:00 15:00 3.00 U_LC PN Ream and wash F/ 7513' To/ 7900'. 34 SPM, 120 GPM, 300 PSI, 120 RPM, 5 -6K TQ., 140K ROT. 15:00 15:30 0.50 U_LC PN Circulate and condition 34 SPM, 120 GPM, 300 PSI, 40 RPM, 4K TQ. 15:30 16:00 0.50 U_LC PN Drop ball to open ports in Centurion Circ. sub with bit at 7893'. 28 SPM, 100 GPM, 200 PSI. CCV shifted with 1700 PSI. 16:00 17:00 1.00 U_LC PN Spot 30 BBLs MOBM, LCM pill and drop ball for CCV closure. 34 SPM, 120 GPM, 250 -500 PSI to shift valve. 120 RPM, 5 -6K TQ, Spotted 33 BBLs LCM at 7893'. 17:00 18:00 1.00 U_LC PN POOH F/ 7893' to/ 7323'. P /U -175K, S/0 -122k. 18:00 22:00 4.00 U_LC PN Circulate and condition with 70 SPM, 250 GPM, 475 PSI, ROT- 140K. While cleaning residual LCM out of suction manifolds and seats on #1 mud pump. 22:00 00:00 2.00 U_LC PN Circulate and condition with 70 SPM on #1 pump while cleaning suction manifold and valves on #2 pump. 70 SPM, 250 GPM, 600 PSI (125 PSI INCREASE WITH STEADY PRESSURE.) 120 RPM, 140K ROT. 5K TQ. 112 SPM, 400 GPM, 1100 PSI FOR 15 MIN NO LOSSES AFTER INITIAL PUMP START UP. Slowed pumps to 70 SPM. 550 BBLs WMB mixed at RSC at midnight. Report Start Date Report End Date 6/1/2008 6/2/2008 Start Time ` End lime Our (hrs) Op Step Phase P/N Comment 00:00 08:30 8.50 U_LC PN Circ. & condition while wait on mud from RSC. Reciprocate F/ 7038' To/ 7228'. 245 GPM, 560 PSI, ROT WT- 142K, RPM -120, TQ -7K. Cleaning rig pits, mixed spacer pill. 08:30 11:00 2.50 U_LC PN Wash and ream F/ 7228' To/ 7892'. 150 GPM, 325 PSI, 120 RPM, 7K TQ, ROT WT -145K. 11:00 13:30 2.50 U_LC PN Circulate and condition, 170 BBLs, 150 GPM, 350 PSI, 120 RPM, TQ -7K, staged pumps to 400 GPM, 1300 PSI, '0' LOSSES. 13:30 19:30 6.00 U_LC PN Circulate and condition @ 7892'. 15 RPM, TQ -5K, 42 SPM, 150 GPM, 300 PSI. 19:30 20:00 0.50 U_LC PN Service Top Drive. 20:00 21:00 1.00 U_LC PN Circulate and condition @ 7892', 15 RPM, TQ -5K, 42 SPM, 150 GPM, 300 PSI. 21:00 22:30 1.50 U_LC PN Held PJSM with all personnel, Displaced well with 11.5 PPG KCUPolymer Mud, pumped 20 BBLS LVT, 40 BBLS spacer, 98 BBLs WBM, @ 284 GPM, 750 PSI, 160 BBLs WBM @ 400 GPM, 900 PSI, 120 RPM TQ -6K, Rot WT- 145K. 22:30 00:00 1.50 U_LC r PN P001-I F/ 7892' To/ 6373'. 160K P /U, 125K 5/0. Well taking correct hole fill. Report Start Date Report End Date 6/2/2008 6/3/2008 Start Time End Time Our (ttrs) Op Step Phase P/N Comment 00:00 01:00 1.00 U_LC PN POOH F/ 6373' to/ 5994'. P /U -150k, S/0 -125k. 01:00 01:30 0.50 U_LC PN Displace with 123 BBLs water base KCU Polymer mud. 11.5 PPG, 400 GPM, 820 PSI< 120 RPM, TQ -6K, Rot. Wt -130 K. www.peloton.com Page 16/45 Report Printed: 8/29/2008 • Operations Summary Report • Start Time End Time Dur (hrs) Op Step Phase P/N Comment 01:30 03:30 2.00 U_LC PN POOH F/ 5994' To/ 4191'. 03:30 04:30 1.00 U_LC PN Displace well with 123 BBLs water base KCU Polymer mud at 11.5 PPG, 300 GPM, 300 PSI, 100 RPM, TO-4K, Rot Wt -115K. 04:30 05:30 1.00 U_LC PN POOH F/ 4191' To/3405'. 05:30 06:00 0.50 U_LC PN Displace well with 60 BBLs water base KCU Polymer at 11.5 PPG. Water base back to surface. 230 GPM, 270 PSI, 100 RPM, TO-4K, Rot Wt. -107K, 06:00 10:00 4.00 U_LC PN Clean pits and send OBM from rig pit system to RSC for storage. M/U WBM volume in and rig pits. 10:00 13:30 3.50 U_LC PN Build volume, weight up 70 BBLs SWBM F/ RSC, weight up to 11.5 PPG, M/U 85 BBLs SWBM in pits. 13:30 16:00 2.50 U_LC PN TIH F/ 3432' To/ 7900'. P /U -175K, S/O -125K. 16:00 17:00 1.00 U_LC PN Circulate and condition. Stage pumps up to 300 GPM, 675 PSI. 120 RPM, TQ -8 -9K. 17:00 00:00 7.00 U_LC PN Wash and ream F/ 7900' To/ 8461' 85 SPM, 700 PSI, 300 GPM, 120 RPM, TQ- 7 -10K, Rot Wt -155K, P /U -175K. Operations Report Report Start Date Report End Date 6/3/2008 6/4/2008 Start Time End Time Our {hrs) Op Step Phase P/N Comment 00:00 01:30 1.50 U_LC PN Wash and ream F/ 8461' To/ 8651'. 300 GPM, 660 PSI, RPM 120, TO-8-10K, 3 FPM, ROT WT -150K, 01:30 04:00 2.50 U_LC PN Circ. and condition mud. Cut mud weight from 11.7 PPG to 11.5 PPG and circulate until balanced in and out. pumped 20 BBLs LCM pill at 0230 hrs. to stop any seepage well might be experiencing. 04:00 05:00 1.00 U_LC PN Wash and ream F/ 8651' To/ 8731'. 305 GPM, RPM 120, TO- 11.5K -15k. 05:00 06:00 1.00 U_LC PN Circulate and condition mud, at 8731', 300 GPM, 750 PSI, RPM -120, TQ -12K, ROT WT -155K. 06:00 08:00 2.00 U_LC PN Circulate and condtion, stage pumps to 400 GPM, 950 PSI, with no losses. Spot 25 BBLs 100 # /BBL LCM pill at 8730'. 08:00 09:00 1.00 U_LC PN POOH F/ 8731' To/ 7790'. No drag, tight spots, or swabbing. Pump slug. P /U -195K, S/O -125K. 09:00 12:00 3.00 U_LC PN POOH F/ 7790' To/ 3800' with no drag, tight spots or swabbing. Well took proper hole fill. 12:00 14:00 2.00 U_LC PN POOH F/ 3800' To/ 584'. 14:00 16:30 2.50 U_LC PN Lay down BHA. 16:30 17:00 0.50 U_LC PN Service Top Drive and change out saver sub. 17:00 18:30 1.50 U_LC PN M/U WBRT and pull wear bushing. M/U test plug and equipment, fill BOP with water. 18:30 22:00 3.50 U_LC PN DART, Rams, Kill and choke lines, choke manifold 250/3500 PSI 5 min each test. Pulled pipe out and tested blind rams Zbu /3500 each for 5 min. Performed Koomey draw down test. John Crisp W/ AOGCC waived witnessing BOP test. 22:00 22:30 0.50 U_LC PN Install wear bushing. 22:30 23:00 0.50 U_LC PN Service Top Drive, & traveling blocks. 23:00 00:00 1.00 U_LC PN P/U stand with CCV ball catcher, recover 3 balls located in catcher. Made stand back up and racked back. Report Start Date Report End Date 6/4/2008 6/5/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 02:00 2.00 U_LC PN P/U and M/U MWD Tool 02:00 06:00 4.00 U_LC PN Load MWD and ADL, Programming Malfunction. 06:00 07:00 1.00 ULC PN Lay Down MWD and Trouble shoot Same 07:00 08:00 1.00 U_LC PN M/U MWD and Down Load Same. 08:00 09:00 1.00 U_LC PN Orient Tool and Load Radioactive Source. 09:00 10:00 1.00 U_LC PN M/U Rest of BHA and RIH to 618' 10:00 12:00 2.00 U_LC PN RIH F/ 618' to 3,380'. Fill pipe and break circulation 12:00 12:30 0.50 U_LC PN Stage pumps up to 400 GPM @ 1500 psi. 12:30 14:00 1.50 U_LC PN RIH F/ 3,380' to 5,850'. Tight spots at 4,784', 4,838', 5,400' 14:00 14:30 0.50 U_LC PN Circulate and Condition mud, staging pumps F/ 125 gpm to 400 gpm, 600 -1600 PSI. Rot Wt = 135K, RPM = 135, Torque = 7K. 14:30 16:00 1.50 U_LC PN RIH F/ 5,850' to 7,721' Tight spot @ 7,640', 30 K Dn Weight. P/U Wt = 155K, S/O Wt = 130K www.peloton.com Page 17/45 Report Printed: 8/29/2008 mss. 1 Operations Summary Report 1 - Start Time f End Time Dur (hrs) _ Op Step Phase P/N Comment 16:00 23:30 7.50 U_LC PN Wash and Ream F/ 7,721' to 8,730'. 125 -250 GPM, 400 -900 PSI, 120 -140 RPM, 8 -10K Torque P/U Wt = 203, S/O Wt = 120K, Rot Wt = 155K. Well was Balloning from 7,721' to 8,250' giving back 20 to 30 BBL on each stand. From 8,300' to 8,730' well started taking mud at a rate of 145 BPH., 23:30 00:00 0.50 U_LC PN Monitor well on trip tank Static Losses are F/ 45 - 80 BPH. Building 75 BBL 100 PPB LCM Pill and Build Volume at RSC and Pits. Operations Report Report Start Date Report End Date 6/5/2008 6/6/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 04:30 4.50 U_LC PN Monitor well on trip tank. Static losses @ 24 -42 BPH. Build mud at RSC and Build 75 bbl, 100 PPB LCM pill. 04:30 05:00 0.50 U_LC PN Drop Chrome shifting ball for CCV and pump down @ 100 GPM w/ 250 PSI. Land ball and shift sleeve with 1900 psi. 05:00 06:00 1.00 U_LC PN Drop Bronze BHA shut off ball and displace down, pump 75 bbls of 100 PPB LCM pill @ 120 gpm w/ 170 psi. Displace LCM Pill with 153 bbls of mud at a rate of 250 gpm w/ 400 psi. 06:00 06:30 0.50 U_LC PN Close Annular and attempt to pressure up to 400 psi on Hesitation squeeze. Pump 8 bbls at 213 gpm w/ 235 psi. Shut pumps down, open annular work pipe and monitor well, Static loss of 6 bbls in 10 min. 06:30 09:30 3.00 U_LC PN Close annular and squeeze LCM pill. Pump 5 bbls @ 1 - 2 BPM, 60 - 70 PSI hold pressure for 10 min. Total LCM squeezed away = 40 bbls. Open annular and work pipe. 09:30 10:30 1.00 U_LC PN Drop Chrome operating Ball to close CCV Valve. Pump down at 100 gpm, shift tool closed with 2000 psi. 10:30 12:00 1.50 U_LC PN Stage pumps up to 350 gpm w/ 1350 psi. Losses estimated at 260 BPH. Shut pump down and put well on trip tank and monitor. Static losses at 14 BPH. Total losses per tour at 155 bbls. 12:00 16:00 4.00 U_LC PN Monitor well on Trip Tank, Working pipe, Cut MW F/ 11.5 to 11.0, and mix LCM to active pits. Static Losses at 25 - 35 BPH 16:00 18:00 2.00 DRLG PP Drilling F/ 8,731' to 8,746'. Hit hard spot at 8,745'. Drilling w/ 300 - 400 gpm, 1300 - 1900 psi, 80 - 135 rpm, 14K Torque. P/U Wt 205, S/O Wt 120K, Rot Wt 155K. At 18:00 mud running out,losing at a rate of 140 - 160 BPH. Stop Drilling and build Volume 18:00 00:00 6.00 U_LC PN Monitor well on trip tank, building volume at RSC and Pits. Stand one stand back and work pipe. Static losses 10 - 25 BPH. Total losses for 24 hrs 836 BBLs Report Start Date Report End Date 6/6/2008 6/7/2008 - Start Time] End Time Dur Ohre) Op Step Phase P/N Comment 00:00 07:30 7.50 U_LC PN Build new mud in the RSC & Rig pits, in preparations for drilling ahead. Transfer over 200 BBL's from RSC to Rig Pits, and continue to build another 400 BBL's in RSC, (had total of 675 BBL's, prior to attempting to drill, & wt. up same to 11.0ppg. 07:30 09:30 2.00 DRLG PP Drill 8 -3/4" Hole section, 8,746 - 8,764' w /total of 510 BBL's loss while drilling ahead. Staged flow rate @ 200gpm= 950psi, 450gpm= 2,345psi, 500gpm= 2,650psi, w/205 -240 BPH loss rate= 33.6% loss ratio. PuWt= 210K, SoWt= 130K, RotWt= 155K. WOB= 20 -25K @ 130 rpm's on TDS, w/14 -17K Torque on Bottom, ADT= 1.60hrs, TADT= 2.69hrs, Jar= 43.01 hrs. Suspend drilling, due to severe losses & pull back to 8,746' & spot 30 BBL's Walnut sweep + 10 BBL's LCM pill. 09:30 11:00 • 1.50 U_LC PN Monitor well for flow back after pump shut down, (15 BBL's return after 40 min's). Well bore went to 9 -10 BPH static losses, & mix dry job to have ready. 11:00 21:00 10.00 U_LC PN POOH w /BHA #6, F/ 8,764' to 618'. Take ACAL readings at 7,100' to 7,080', 6,100' to 6,080', 5,100' to 5,080' and 4,100' to 4,080'. 21:00 00:00 3.00 U_LC PN Rack back HWDP and Jars, Remove Sources and down Toad MWD. LtD CCV Sub and Ball Catcher. (3 balls in ball catcher sub.) Report Start Date Report End Date 6/7/2008 6/8/2008 • www.peloton.com Page 18/45 Report Printed: 8/29/2008 • Operations Summary Report 1 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 03:30 3.50 U_LC PN Continue to down load MWD & prepare to LD same, due to batteries needing to be changed out on next run. Once down loaded, & laid down, stand back what was possible of the Geo -Pilot assembly w /Bit having 3 flow passages plugged off on one side. Clean up same once broken off. Clear floor of unnecessary tools. 03:30 05:30 2.00 U_LC PN Pull wear ring w /Vetco Gray Rep. & set test plug. Open bottom Pipe Ram doors & 0 -0 to 4" Dp type rams. Close up & ensure ready to test same. 05:30 06:00 0.50 U_LC PN Pressure test Bottom Pipe rams to 250psi (low) /3,500psi (high), per AOGCC requirements 5min's each test, (chart same). Rig down test equipment. 06:00 09:00 3.00 U_LC PN MU cement Mule Shoe on 4" Dp, & RIH 12 Std's 4" DP from derrick. Cross over to 5" Dp, & continue to RIH to 3,409', w /PuWt= 105K & SoWt= 95K. 09:00 12:00 3.00 U_LC PN Est. circulation @ 100gpm, & stage to 250gpm= 340psi @ 50 rpm's on TDS= 1K off Bottom Torque. CBU @ 250gpm & cut MW f /11.0ppg, 1/10.Oppg in /out of hole, w /very slight losses, (1 -2 BPH). Depth @ 3,409' 12:00 13:30 1.50 U_LC PN Trip in hole F/ 3,409 to 5,135' 13:30 14:30 1.00 U_LC PN Est. circulation @ 100gpm, & stage to 250gpm= 420psi @ 50 rpm's on TDS= 1K off Bottom Torque. CBU @ 250gpm & cut MW f /11.0ppg, t/10.Oppg in /out of hole, w /very slight losses, Depth @ 5,135' 14:30 15:30 1.00 U_LC PN Trip in Hole F/ 5,135' to 6,857' 15:30 17:30 2.00 U_LC PN Est. circulation @ 100gpm, & stage to 250gpm= 420psi @ 120 rpm's on TDS= 1K off Bottom Torque. CBU @ 250gpm & cut MW f /11.0ppg, t/10.Oppg in /out of hole, W/ losses = 25 BPH, Depth @ 6,857' 17:30 19:00 1.50 U_LC PN Trip in Hole F/ 6,857' to 8,755' 19:00 21:00 2.00 U_LC PN Est. circulation @ 100gpm, & stage to 250gpm= 510 psi @ 120 rpm's on TDS= 8 - 10K off Bottom Torque. CBU @ 250gpm & cut MW f /11.0ppg, t/10.0ppg in /out of hole, W/ losses = 30 BPH, Depth @ 8,755'. P/U Wt = 175K, S/0 Wt = 147K 21:00 23:30 2.50 U_LC PN R/U to Cement, Conduct JSA. Pump 3 BBIs water ahead, Test lines to 1500 psi. Pump 7 bbls of water, Followed by 20 bbls of 12.5 ppg spacer. Mix and pump 410 sacks or 86 bbls of 15.8 ppg of Preimium Cement, mixed at 5.06 gal /Sk, 1.17 yield, additives included .55 % Halad -344, .20 % CFR -3, .30 % SCR -100 and .125 % Super CBL. Chase with 3 bbls of 12.5 ppg spacer and 3 bbls of water. Displace with 125 bbls of 10.0 ppg mud, pumping with rig pump. 23:30 00:00 0.50 U_LC PN POOH slowly F/ 8,755' to 7,795'. (10 stands) Had 30K overpull leaving bottom. Operations Report Report Start Date Report End Date 6/8/2008 6/9/2008 Stan Time End Time Dur (hrs) Op Step Phase — P/N Comment 00:00 00:30 0.50 U_LC PN Continue to finish Hoistina Cement string, 7,795- 7,550' w /180K PuWt & 130K SoWt & no swabbing seen. 00:30 03:00 2.50 U_LC PN Install wiper ball in drill string & CBU @ 300gpm= 450psi, w /30 rpm on TDS= 6K off Bottom torque, 145K RotWt, 135K SoWt, & 152K PuWt. Circulated Surface to Surface w /approx. 200 BBL's contaminated mud, (3 -5 BBL's cement - checked w /11.4 pH), & no return of wiper ball seen. 03:00 09:30 6.50 U_LC PN WOC for 500psi compressive strength results, (approx. 6:02hrs @ 130 deg. F test result). Consulted w /HES & Town ODE, due to 94 deg. F recorded BHT, and decision made to WOC for extra 2hrs. Cement string was rotated @ 20 rpm on TDS w /6K off Bottom torque, & 145K RotWt., (no Losses experienced). Sim -Op: Worked on TDS gripper dies & C-0 same while WOC 09:30 10:00 0.50 U_LC PN Est. circulation w /100gpm= 200psi, & staged to 200gpm= 350psi. Wash down, 7,522- 7,636' w /30 rpm's on TDS= 7 -8K off Bottom Torque. PuWt= 152K, SoWt= 135K, & RotWt= 145K (all taken w /rot.). At 7,636', (approx. 30' low from calculated Cement top), tagged cement stringer, (torqued jumped to 14k, pressure increased to 450psi, & 5 -6K weight on Mule shoe seen). Picked up to re -tag & confirm, but fell off, & continued to Wash, 7,636- 7,647', where tagged up again w /similar parameters seen, (8K weight on Mule shoe). Work up twice & tagged up at same depth to confirm cement top. Consulted w/Town ODE w /results. 10:00 11:30 1.50 U_LC PN CBU 5,700 strokes @ 250gpm= 395psi e 7,612' (racked back stand), w /no losses seen. Used 50 rpm's on TDS= 8K off Bottom Torque. Held PJSM w /all related services on next Cement plug, ( #2). Blow down TDS as pre- caution. www.peloton.com Page 19/45 Report Printed: 8/29 /2008 „ F • Operations Summary Report Start Time End Time Dur (hrs) Op Step Phase P/N Comment 11:30 13:30 2.00 U_LC PN MU TIW valve & cement head @ 7,612' & RU to Cement & Pump 3 BBL's water ahead, Test lines to 1,500 psi. Pump 7 bbls of water, Followed by 20 bbls of 12.5 ppg spacer. Mix and pump 206 sacks or 43 bbls of 15.8 ppg of "G” Cement, mixed at 5.06 gal /Sk, 1.17 yield, additives included .55 % Halad -344, .20 % CFR -3, .25 % SCR -100 and no Super CBL. Chase with 3 BBL's of 12.5 ppg spacer and 3 BBL's of water. Shut down HES HT pump unit & ensure pressures bled off. Break off TIW valve & cement head & LD same. Screw into Dp w/TDS & Displace with 116 BBL's of 10.0 ppg mud= 1386 strokes, pumping with rig pump @ 250gpm= 432psi final pressure, while rotating @ 50 rpm's on TDS. CIP @ 13:24hrs. Average flow rate pumping cement was 3.5 BPM, w /500psi, (550psi FCP). 13:30 14:00 0.50 U_LC PN Hoist Cement string, 7,612- 6,970' w/55 -60K over pull 7,612- 7,560', 35K over pull 7,560 - 7300', & 1 T5Kover Oull 7,300- 6,970' w /no swabbing seen while hoisting. 14:00 16:00 2.00 U_LC PN Install wiper ball, & CBU 6,600 strokes @ 200gpm= 300psi w /80 rpm's on TDS= 7 -8K off Bottom Torque, w /140K PuWt, 130K SoWt, & 135K RotWt. Had 100 BBL's contaminated mud w/1 BBL cement returns seen @ surface, (11.6 pH recorded). 16:00 21:00 5.00 U_LC PN POOH and rack back 5" and 4" Drill Pipe F/ 6,967' to Surface 21:00 21:30 0.50 U_LC PN Clear Rig Floor and P/U 5" Test joint 21:30 23:00 1.50 U_LC PN Pull wear ring and install test plug. Change out 4" rams and replace them wiith 5" Rams. Tested Choke Manifold on trip out of hole. 23:00 00:00 1.00 U_LC PN Fill the stack and test joint. Test annular and floor valves to 250 low and 3500 High. ,Operations Report Report Start Date Report End Date 6/9/2008 6/10/2008 Start Time End Time Out (hr8) op Step T Phase P/N Comment 00:00 02:30 2.50 U_LC PN Test BOPE per AOGCC requirements, (Chuck Sheeve waived witness). Had tested Choke manifold on way out of hole, (250psi Low /3,500psi High -all good 5min's each). Test all rams, floor/TDS valves tested 250psi Low /3,500psi High for 5 min's each. Function test Accumulator w /system pressure @ 3,000psi, & 1,800psi after closure. 200psi obtained in 17sec's, w /full pressure @ 1:53sec's. %x N2 Bottles @ 1,800psi. Test LEL, alarms, floor lights & log in Nabors book. Testing took 3.5hrs w/o failures. 02:30 03:30 1.00 U_LC PN RD test plug & install wear ring wNetco Gray Rep. present. RD test equipment, BD lines & line up Choke manifold for drilling operations. 03:30 06:30 3.00 U_LC PN PU & MU BHA #7, (RTSS Type), w /Fresh Geo -Pilot bit, (FSF 2565 Z - w /5x15's). MU rest of components accordingly & Initialise MWD probe w/o problems. RIH & shallow pulse test MWD w /400gpm= 500psi (OK). Pull back to MWD section of tools. 06:30 08:30 2.00 U_LC PN PJSM /clear floor of un- neccessary personnel & load Nuke sources in carriers. Lower assembly and give all clear announcement & continue to add components as required, (Flex Monels, Drlg. Jar, & HWDP) & RIH to 681'. 08:30 10:00 1.50 U_LC PN Continue to RIH w /BHA #7, 681 - 3,400', w /PuWt= 140K & SoWt= 105K. 10:00 10:30 0.50 U_LC PN Fill pipe as required & test MWD, after breaking in Geo -Pilot seals w /5rpm's on TDS, and increase 5 rpm's every minute to 60 rpm's max. Flow rate @ 400gpm= 915psi, & 450gpm= 1,180psi, w /no reported losses experienced. Shakers screened up w /2x @ 170's (210 old API #'s), & 1x .@ 140's (170's old API #). Rotate w /10Orpm's on TDS= 5K off Bottom Torque, 125K RotWt. Shut down & flow check well as precaution (static) for 10 min's. Sim -Op's: Service TDS while observing well bore. 10:30 12:00 1.50 U_LC PN Continue to RIH w /BHA #7, 3,400' 5,047', w /no problems, (Hole fill as calculations correct & checked every 5std's). Break circulation w /9.8ppg MW & est. slow pump rates, Pump #1= 20spm @ 250psi, & 40spm= 450psi. Pump #2= 20spm @ 250psi & 40spm= 470psi. 12:00 13:30 1.50 U_LC PN CBU w /9.8ppg MW in /out & recieved a large amount w /Bottoms up, (primary clays & siltstone), & slowed pump's, (350gpm), until cleaned up. PuWt= 185K & SoWt= 100K (no- rotation). RotWt= 136K w /100rpm's on TDS= 6 -7K off Bottom Torque. Flow rate @ 450gpm= 1,270psi @ 24% flow returns, & 500gpm= 1,450psi @ 25 -26% returns. Ensure even MW for upcoming FIT. www.peloton.com Page 20/45 Report Printed: 8/29/2008 • Operations Summary Report S LL. Stan Time _ End Time Dur (hrs) Op Step Phase P/N Comment 13:30 14:00 0.50 U_LC CN Open Kill line & Est. circ. to ensure no air in lines. Shut down pump & close Top Rams, & pump @ 10spm down both sides for FIT w /9.8ppg MW. Est. pre - calculated 711psi to ensure 13.2ppg EMW @ 5,100'md /3,990'TVD, w /14.4ppq EMW @ 2,998'TVD 9 -5/8" Casing shoe depth. Report results to town ODE's & RD test equipment &`blow down Kill line. Prepare for Side tracking operations. 14:00 00:00 10.00 DRLG PN Est. Drilling parameters for Time drilling 8 -3/4" Hole, 5,100' Side Track point, w/136K RotWt, 143K PuWt, & 130K SoWt, @ 60 To 100rpm's on TDS= 6 -7K of Bottom Torque. Flow rate @ 450gpm= 1,270psi & 1,450psi @ 500gpm. Time drill @ 1" per 2.5 minutes Presently @ 5120'. Operations Report Report Start Date Report End Date 6/10/2008 6/11/2008 Start Time End Time Our (hrs) Op Step Phase P/N Comment 00:00 16:30 16.50 DRLG PN Time drilling 8 -3/4" Hole Side Track, 5,119' - 5,123', w/83% deflection @ 150R TF, & 53.84 deg. ABI showing. Attempt to increase ROP rate, w /6 -7K WOB, but popped out of Trough. Pull back to 5,123' & continue w/1 min per inch rate, 5,123 - 5,129', but ABI indicated not decreasing Inclination as should be, (ABI 4.7' back of bit). Decrease to 3min per inch, 5,129' - 5,136', w /ABI indicating 53.6 -53.75 inc. Parameters included 0 -2K WOB, 80- 100rpm on TDS= 6 -9K off Botom Torque, (tryed various rates to increase, but harmonics unable to substain higher rpm's). PuWt= 143K, SoWt= 130K, RotWt. Flow rate @ 550gpm= 1,700psi. ART= 11.12hrs & Jar= 65.71hr 16:30 23:00 6.50 DRLG PN Cont. to time drill Side Track to 5,146, @ 3min per inch, where ABI indicating not getting advancing, (still 53.75 -53.8 deg.). Consult Town ODE & decision made to attempt to push assembly w /4 -6K WOB. Start slowly w /2K increments, & limit drum speed to reduce producing loading on assembly. Attempt various rpm's on TDS & achieve 120 -130 w /4K WOB. Drill 5,145' - 5,170' @ reduced rate, where ABI showed 53.13 deg. Inc. This indicated assembly Side Tracking off w/o further problems. Drill 8 -3/4" Hole, 5,170' to 5,427', w /10 -15K WOB, 120rpm on TDS= 6K off /8K on Bottom torque, 550gpm flow rate= 1,700psi w /9.7ppg MW. PuWt= 190K, SoWt= 105K, RotWt= 140K. ADT= 10.75hr, TADT= 30.15hr, Jar= 73.16hr 23:00 00:00 1.00 DRLG PN Swab on # 1 mud pump went out, Repair same and Circulate B /U, prepare for short trip. Report Start Date Report End Date 6/11/2008 6/12/2008 Start Time End Time Dur (hrs) Op Step Phase PIN Comment 00:00 00:30 0.50 STRIP PN Continue w /Short trip, 5,427' - 5,190', w/o more than 10 -15K over. Check well, (static), & RIH to 5,427' w /issues. Hole took proper fill up on way out, (no swabbing experienced), & proper displacement on way in. 00:30 12:00 11.50 DRLG PN Drill 8 -3/4" Hole section per HES DD & WP #14, 5,427' - 5,996 w /600gpm flow rate= 2,230psi. Used various TDS rpm's, (average= 120), = 9K off & 10-11K on Bottom Torques, WOB= 12 -15K. PuWt= 195K, SoWt= 120K, RotWt= 140K. ADT= 8.59hrs, TADT= 38.74hrs, (incl. time drlg.), Jar= 81.75hrs. Slow pump rates taken @ 5,521'md/4,232'TVD, w /9.8ppg MW. 12:00 20:00 8.00 DRLG PN Drill 8 -3/4" Hole section per HES DD & WP #14, 5,996- 6,470', (planned Short trip point), w /600gpm flow rate= 2,320psi. Used various TDS rpm's, (average= 120), = 9K off & 10-11K on Bottom Torques, WOB= 16 -18K. PuWt= 205K, SoWt= 115K, RotWt= 147K. ADT= 6.43 hrs, TADT= 45.13 hrs, (incl. time drlg.), Jar= 88.09hrs. Slow pump rates taken @ 5,521'md/4,232'TVD, w /9.8ppg MW. 20:00 20:30 0.50 CIRC PN Ciruculate and condition hole for short trip. 20:30 00:00 3.50 STRIP PN Short trip F/ 6,470' to 4,900'. Pulled 3 stands on elevators with 5 -10 K overpull. Then had excess overpull of 35K and had wash and back ream rest of way out to 4,900'. Had large amount of cuttings over shakers during this operation. Report Start Date Report End Date 6/12/2008 6/13/2008 Start Time End Time Our (hrs) Op 1 Step Phase P/N Comment 00:00 01:30 1.50 CIRC PN CBU @ 600gpm= 2,130psi, while reciprocating std., 5,047'- 4,950' @ 120rpm= 8K Torque off Bottom. Hole unloaded a large amount of mostly Clay materials w /Bottom Up, & continue to Circ. until clean. Switch to A -Cal "B" mode for pumping up data while CBU. www.peloton.com Page 21/45 Report Printed: 8/29 /2008 • Operations Summary Report ID Stan Time End Time Our (his) Op Step Phase P/N CornrneM 01:30 04:30 3.00 STRIP PN RIH w /BHA #7, 4,950'- 6,470'. Take A -Cal data point @ 5,128' - 5,131' (average= 9.57 "), & attempt @ 5,801' - 5,803', (Bad data). Some tight spots were recorded @ 5,590' & 5,755', (25K WOB, 500gpm= 2,250psi, 12Orpm's= 12 -14K off Bottom Torque), to get through & wiped spots. Continue to 5,890', where attempted to get a A -Cal data point, but tight spot encountered, and slight pack -off experienced, (no losses occurred). Pull above same & increase flow rate back to 500gpm= 2,300psi, & ream down, 5,800' - 5,900', w /10 -25K WOB, 13Orpm on TDS= 12K Torque off Bottom. Appeared to be clear, & RIH on elevators to 6,375' & Washed to bottom, @ 6,470', as precaution. A -Cal tool had quit during pack -off, and unable to regain, dispite all surface attempts. 04:30 12:00 7.50 DRLG PN Drill 8 -3/4" Hole, 6,470'- 6,875' w /600gpm flow rate= 2,690psi, 125- 15Orpm's on TDS= 8K Torque off/9-11K Torque on bottom. PuWt= 210K, SoWt= 120K, RotWt= 140K, WOB= 25 -30K. Pumped 10 BBL's Nut Plug sweep, (low vis), @ 6,850' w/o any increase in cuttings seen. A -Cal tool came back @ 6,657'. Slow pump rates were taken @ 6,844'md/4,791'TVD, w /9.7ppg MW. ADT= 5.12hrs, TADT= 50.2hrs, (incl. Time drilling), Jar= 93.21 hrs Used various WOB/TDS rpm's to optimise ROP rates at 125 -150 fph. Added .5% EP Mud Lube which help reduced the Dp rattle at higher rpm's & now able to sustain 150 rpm's. Encountered a couple of hard streaks which involved slowing rpm's down, (60 -80), & increasing WOB30 -35K, to get bit to engage, & then drill off. 12:00 21:30 9.50 DRLG PN Drill 8 -3/4" Hole, 6,876- 7,419' w /600gpm flow rate= 2,825psi, 130- 15Orpm's on TDS= 12.5K Torque off /9 -10K Torque on bottom. PuWt= 210K, SoWt= 120K, RotWt= 147K, WOB =25 -35K. Pumped 10 BBL's Nut Plug sweep, (low vis), @ 7,419' w/o any increase in cuttings seen. Slow pump rates were taken @ 7,419'md/5,036'TVD, w /9.7ppg MW. ADT= 2.85hrs, TADT= 58.17hrs, (incl. Time drilling), Jar= 101.18hrs Used various WOB/TDS rpm's to optimise ROP rates at 125 -150 fph. Added .5% EP Mud Lube which help reduced the Dp rattle at higher rpm's & now able to sustain 150 rpm's. Encountered a hard streak @ 7,071'- 7,074's which involved slowing rpm's down, (60 -80), & increasing WOB30 -35K, to get bit to engage, & then drill off. 21:30 23:30 2.00 CIRC PN Circulate bottoms up 3.5x, pump low vis nut plug sweep. Took survey w /MWD @ 7,387' and change over to ACAL reading. Work pipe @ 150 rpm and 600 gpm for BU's. Saw alot of clays on shakers till end of 17,000 stks, which reduced significantly. 23:30 00:00 0.50 STRIP PN Get SPR on both pumps @ 7,419' & monitor well, (well bore static). POOH, short tripping to 6,470'. Operations Report Report Start Date Report End Date 6/13/2008 6/14/2008 Start Time End Time Our (hrs) Op Step Phase P/N Comment 00:00 01:30 1.50 STRIP PN Short trip, 7,224'- 6,940', pulling on elevators, w /PuWt= 225K, SoWt= 120K, pulling 30K & slight swabbing. MU TDS & pump out, 6,940'- 6,375', w /400gpm= 1,405psi. Attempt to pull on elevator @ 6,455', w /35K over & swabbing seen again. No further problems seen while pumping out only to 6,375'. 01:30 02:00 0.50 CIRC PN Circulate Bottoms up @ 600gpm= 230 BBL's, @ 2,640psi. Reciprocate Dp @ 80rpm on TDS= 10K Torque off Bottom, (6,375'- 6,470'), & 140K RotWt. Received a large amount of Clay based material across shakes. 02:00 04:00 2.00 STRIP PN RIH w /BHA #7, 6,376- 7,419' w/o problems. Take A -Cal reading while going back to bottom @ 6,277'- 6,286= 9.49" average, 6,644- 6,657'= 8.76" average, & 7,024'- 7,040'= 9.95" average. PuWt= 225K & SoWt= 120K www.peloton.com Page 22/45 Report Printed: 8/29/2008 Operations Summary Report.) Start Time End Time j Our (Mrs) Op Step Phase P/N Comment 04:00 12:00 8.00 DRLG PN Drill 8 -3/4" Hole, 7,419'- 7,894' w /600gpm flow rate= 2,640psi, 130- 15orpm's on TDS= 11K Torque off /12.5K Torque on bottom. PuWt= 230K, SoWt= 125K, RotWt= 150K, WOB= 25 -35K. Performed a 400 BBL mud dilution once back on bottom, w /MBT's reduced from 13, down to 8.5, (approx. 40% volume C -O). The To of the Torok was seen @ 7,105'/5,072.9', & started the scheduled 10 BBL's LCM pil every s an , consisting f 20# /BBL each Steel Seal & Barafiber, w /10# /BBL BaraCarb 5 -50 -150. Slow pump rates were taken @ 7,700'md/5,156'TVD, w /9.7ppg MW. ADT= 6.11hrs, TADT= 64.28hrs, (incl. Time drilling), Jar= 107.29hrs Used various WOB/TDS rpm's to optimize ROP rates at 125 -150 fph. Continue to hold .5% EP Mud Lube which help reduced the Dp rattle at higher rpm's. Shaker that was down was repaired & back operational before noon. 12:00 19:30 7.50 DRLG PN Drill 8 -3/4" Hole, 7,894' - 8,464' w /600gpm flow rate= 2,940psi, 15Orpm's on TDS= 15K Torque off /18K Torque on bottom. PuWt= 250K, SoWt= 140K, RotWt= 150K, WOB =25K. The Bottom of the Torok was seen @ 7,97975,279.1', & continued the scheduled 10 BBL's LCM pill every stand, consisting of [tl# /BBL each Steel Seal & Barafiber, w /10# /BBL BaraCarb 5 -50 -150. ADT= 5.60hrs, TADT= 69.88hrs, (incl. Time drilling), Jar= 112.89hrs Used various WOB/TDS rpm's to optimise ROP rates at 125 -150 fph. Continue to hold .5% EP Mud Lube level. Well bore started to take fluid @ 8,085' @ initial rate of 2 -3 BPH rate. This was stead until +/- 8 where increase. o 1 : • ra e. au was predicted for 8,335' & #2 @ 8,780' on this leq. Continue to monitor fluid levels after connections. 19:30 21:30 2.00 CIRC PN Circulate hole bottoms up 3.5x. Shakers were looking clean with encapsulated Clays @ end of circulating. Monitor well 10 min, hole static. 21:30 00:00 2.50 STRIP PN Short trip F/8,464' to 7,419'. Had over pull of 40K +, & swabbing hole when starting off bottom. MU TDS @ 8,368' and Back ream 8,368'- 7,419', w/o further issues, (Decided to pump out & Back ream total trip). Had a issue with both mud pump pressure relief discharging at same time. Lower IBOP valve showed it opened, but apparently did not. Using more caution when bring pumps on, even when you visually see actuator move. Continue to short trip out. Capable of using one pump c 90 spm rate while repairing each pumps pulsation dampners. Operations Report Report Start Date Report End Date 6/14/2008 6/15/2008 Start Time End Time Dor (Mrs) Op Step Phase P/N Comment 00:00 02:00 2.00 STRIP PN Continue Short trip, & Back ream f/7,419'- 6,755', w /285gpm= 900psi, (can't use both pumps), 12Orpm's on TDS= 12 -15K off Bottom Torque, PuWt= 200K, SoWt= 120K, RotWt= 150K. 02:00 04:00 2.00 STRIP PN RIH w /BHA #7, 6,755' - 8,464', w/o problems. Take A -Cal data points @ 7,486- 7,499'= 9.30" average, 7,977'- 7,989'= 9.50" average, & 8,318' - 8,329'= 9.86" average Hole sizes, using 3fpm lowering speed, w /560gpm= 2,400psi, (both pumps up & running OK), 60rpm's on TDS= 10K Torque off Bottom. RIH on elevators, 8,329' - 8,464' w/o problems. 04:00 09:00 5.00 DRLG PN Drill 8 -3/4" Hole, 8,464' - 8,585', w /600gpm= 3,000psi, 24 -26K WOB, 150rpm's on TDS= 12K off Bottom, /12 -15K on Bottom Torques. PuWt= 245K, SoWt= 130K, RotWt= 150K. At 8,585', losses were experienced, w /300 BPH rate seen. Flow rates fell from 34 %, to 7-1P/0 returns, w/Loss ratio @ 38.2 %. - 'Uo`nssult w/Town ODE, (PU off bottom & shut down pumps - well bore static). Decision made to a ttempt to drill ahead to uncover all of Dossible fault area. Cut flow to 450gpm= 1,850psi, but unable to drill ahead, 8,585' - 8,589', using 35 -40K WOB, 60- 8orpm's on TDS= 12 -20K on Bottom Torque, (bit appeared to be possibly balled, later found not the case). Experinced 437 BBL's loss, w /flow returns fluctuating from 34%-17%-29%-1%. This was a 24- 450 -785 BPH loss rate. Suction pit was sucked down below usable pit level & pumps started to jack. PU off bottom to mix 40 BBL viscos flush, prior to pumping 60 BBL's of 100 # /BBL LCM pile of Steel Seal /Barafiber, w /BaraCarb 5 -50 -150 mix. Well Bore was static, but while pulling 8,589' - 8,555' saw 30 -40K over pull & swabbing. www.peloton.com Page 23/45 Report Printed: 8/29 /2008 III Operations Summary Report • [Start Time End Time Dur (hrs) [ Op Step - Phase P/N Comment 09:00 10:00 1.00 U_LC PN Transfer 180 BBL's of 9.7ppg Good mud, & 200 BBL's of 9.7ppg from previous day dilution program. Take on 40 BBL's H2O from rig water tank, & mix caustic, w /2x sack of Nut plug & N -vis to raise viscosity. Continue to mix finishing products for LCM pill per mud Man recommendations, & once H2O pill ready, line up to pump same. 10:00 12:00 2.00 DRLG PN Drill 8 -3/4" 8,589' - 8,597', w /530gpm= 2,050psi, WOB= 20 -40K, w /40- 15Orpm's on TDS= 9 -12K off /12 -20K on Bottom Torque. PuWt= 245K, SoWt= 130K, RotWt= 150K. Had pumped the H2O pill to aid possible bit balling, (tried mech. aggravation also). The H2O was also for flushing into formation, prior to LCM pill. While attempting to get drilling, 8,589' - 8,591', used various parameters, & took approx. 1.5 hrs to achieve, but once through, drilling took off w /26K WOB, & 15Orpm's, (had seen same hard streak before on last leg. Losses were experienced @ 151 -0 BPH rates= 20 % -0% loss ratio. Also unit gas come up, prior to A2pil[Town, (H20 also took extra 6,100strokes to return). Hole appeared to reach saturation point & losses ceased, w/Total losses @ 560 BBL`srilling time @ 12:00hrs for Tour were AV r= 3..sinr8, T cn= /3.z5r1rs, im I. Time Drilling), Jar= 116.26hrs. 12:00 17:30 5.50 DRLG PN Drill 8 -3/4" 8,597' to 8,764', w /530gpm= 2,050psi, WOB= 20 -40K, w /40- 15Orpm's on TDS= 9 -12K off /12 -20K on Bottom Torque. Pumping 10 bbls @ 100 # bbls LCM sweep every stand drilled.PuWt= 250K, SoWt= 135K, RotWt= 155K. Drilling time @ 15:30hrs for Tour was ADT= 4.9hrs, TADT= 78.1 hrs, (incl. Time Drilling), Jar= 121.15hrs. 17:30 00:00 6.50 DRLG PP Drill 8 -3/4" 8,764' to 9,105', w /530gpm= 2,050psi, WOB= 20 -30K, w /40- 15Orpm's on TDS= 9 -12K off /12 -20K on Bottom Torque. Pumping 10 bbls @ 100 # bbls LCM sweep every stand drilled. PuWt= 253K, SoWt= 137K, RotWt= 157K. Performed Kick while Drilling Drill = 1:20 minutes. Drilling time @ 24:00hrs for Tour were ADT= 4.63hrs, TADT= 82.78hrs, (incl. Time Drilling), Jar= 125.79hrs. (Hole losses for 12 hrs= 120bbIs) Operations Report Report Start Date Report End Date 6/15/2008 6/16/2008 Start Time [ End Time 1 Dur (hrs) 1 Op - Step Phase P/N Comment 00:00 03:00 3.00 DRLG PP Drill 8 -3/4" 9,105'- 9,316', (T. of HRZ predicted @ 9,327'), w /550gpm= 2,580psi, WOB= 20 -24K, w /15Orpm's on TDS= 12K off/15 -18K on Bottom Torque. Pumping 10 bbls @ 100 # bbls LCM sweep every stand drilled. PuWt= 255K, SoWt= 135K, RotWt= 157K, & ECD's= 11.31ppg EMW. Drilling time for Tour was ADT= 2.45hrs, TADT= 85.23hrs, (incl. Time Drilling), Jar= 128.24hrs. (Hole losses= 12bbls) 03:00 05:00 2.00 CIRC PP CBU 3.5x @ 610gpm= 2,850psi, w /15Orpm's on TDS= 12K off Bottom Torque, RotWt= 155k, & reciprocate string. Hole appeared to be clean @" shakers. 05:00 06:00 1.00 TRIP PP Attempt to pull on elevators, but experience 35 -40K over pull.•& swabbing. Decision made to MU TDS & back ream out of hole. Back ream 9,316- 8,835', w /550gpm= 2,250psi, 12Orpm's on TDS= 10 -15K off Bottom Torque, PuWt= 225K, SoWt= 135K, RotWt= 150K. 06:00 06:45 0.75 U_RIG PN C -O gripper dies on TDS. Monitor well bore, (static). 06:45 13:00 6.25 TRIP PP Continue to Back ream out of the hole, 8,836- 4,804', using 500- 550gpm= 2,150- 2,400psi, 12Orpm's on TDS= 10 -12K off Bottom Torque, (did not rotate past fault area, just pump, as rotation caused 30 -35BPH loss rates, 8,730' - 8,450'). Attempt to continue Back reaming out of hole @ 4,804', but experienced some packing off, and tight hole conditions. Slack off and get rotation w /12Orpm's, (28K to break over), and bring pumps up to 400gpm. 13:00 14:30 1.50 U_TH PN Continue to reciprocate stand slowly @ 12Orpm's on TDS= 10 -12K off Bottom Torque, & 400gpm= 1,520psi. CBU 2x, and receive a lot of Clay cuttings material @ 1st bottoms up, & have to cut back to 150gpm, to handle @ shakers. Continue to stage back up slowly during 2nd BU, as mud containing a lot of Clays & continue to blind shaker screens. Able to achieve 550- 600gpm, but ECD's @ 12.6ppg EMW. Cut back to 450gpm & begin to continue POOH to casing shoe @ www.peloton.com Page 24/45 Report Printed: 8/29/2008 • Operations Summary Report Start Time End Ttme j Dur (hrs) f Op Step Phase P/N Comment 14:30 19:30 5.00 TRIP PP Back reaming slowly @ 400 -450 gpm, 120 rpm maintain 11.8 -12.0 ECD's. Started increasing hoisting rate 3,900' to 25 -30 ft/min seeing hole was looking better. At 3,700' the pump pressure came up 200 psi, but no torque on TDS or over pull, & saw ECD's had went to a 16.2ppg EMW, Immediately slacked off and cut pumps off, but pressure held @ 1200 psi, (packed off). Continued to work pipe and rotate, until pressure fell off. Started pumping again slowly increasing rate while working pipe to get flow & ECD's back down. Got flow and ECD's under control, & pumped a 20 BBL, 11.5ppg, Hi -vis, 50# bbl nut plug sweep, w /BU and saw some increase in cuttings. Continue to pump & back ream out to 3,528', stopped rotating and just pumped with top stabilizer entering shoe, pulled to 3,408' very slow watching ECD's and having to slack off and work pipe. 19:30 21:00 1.50 U_TH PN From 3,405' to 3,334', pumped @ 300 -550 gpm & 60 -120 rpm, getting large cuttings back. Mixed & pumped 50 bbl/70# bbl -nut plug/120 Vis with a drum of EP, Drill N slide, EZ glide sweep. On bottoms up, encountered a large pack -off from inside the casing of very large clay balls and rocks. 21:00 23:00 2.00 TRIP PP Continue to pump out & back ream @ 500 -550 gpm /120 rpm to 3,054', where cuttings cleaned out. Pump Dry job, monitor well 10 min. (Static) 23:00 00:00 1.00 TRIP PP POOH on elevators to 2,010'. Monitored well, w /swabbing slightly for first couple stands. MU TDS and rotated pipe and hole dropped to normal. Continued monitoring 10 stands for correct hole fill. (took right amount). Operations Report Report Start Date Report End Date 6/16/2008 6/17/2008 Start Time End Time Our (hrs) Op Step Phase P/N Comment 00:00 01:00 1.00 TRIP PP Continue to POOH w /BHA #7, 2,010' -681', pulling on elevators only, w/o further problems or incidents, (hole taking proper fill up), PuWt= 125K, & SoWt= 105K. Performed kick while tripping drill =lmin 45 sec. 01:00 03:00 2.00 BHA PP POOH w /BHA #7, racking back HWDP & Drilling Jar, 3x NM Flex monels, LD CCV sub, PJSM & recover Nuke Sources. 03:00 06:00 3.00 BHA PP Plug into MWD & down load same, recovering recorded MWD data & shut down same. LD same and Geo- Pilot, after breaking off bit, Graded: 1- 1- WT- A- X -I -ER -BHA. The floor was then cleared & cleaned. 06:00 07:00 1.00 BOPS PP BO LDS & PU /pull wear ring w /Vetco Gray Representative. Install test plug & RI LDS per Vetco Gray. Prepare to test anular preventer w/Test joint. Hole was static, prior to setting test plug. 07:00 09:00 2.00 BOPS PP Test BOPE per AOGCC requirements (Bob Noble waived witness), Had tested Choke manifold on way out of hole, (250psi Low /3,500psi High -all good 5min's each). Test Annular Preventer to 250psi Low /2,500psi High for 5 min.'s each. Test all rams, floor/TDS valves tested 250psi Low /3,500psi High for 5 min's each. Function test Accumulator w /system pressure @ 3,000psi, & 1,900psi after closure. 200psi obtained in 25sec's, w /full pressure @ 1:30sec's. 5x N2 Bottles @ 1,800psi. Test LEL, alarms, floor lights & log in Nabors book. Testing took 2.0hrs w/o failures. 09:00 09:30 0.50 BOPS PP RD test plug & install wear ring w /Vetco Gray Rep. present. RD test equipment, BD lines & line up Choke manifold for drilling operations. 09:30 10:00 0.50 RIGSER PP Service rig & TDS. Check TDS gripper dies, (OK). 10:00 11:00 1.00 U_OTR CN Open Kill line valve & est. circualtion through same, to clear lines of air. Shut Blind ram & perform FIT to 780psi, which was a 14.8ppg EMW @ Casing shoe depth of 3,409'md/2,998'TVD, using 9.8ppg MW. This equated to 12.53ppg EMW @ 8,585'md/5,494'TVD Fault area. BH @ 9,316'md/5,719'TVD= 12.42ppg EMW. A total of 17.51 BBL's were used for test, & bled slowly, w /14.0 BBL's returned. Results sent to Town ODE, and per discussion, decision made to continue w /PU & MU BHA #8. 11:00 14:00 3.00 BHA PP PU & MU BHA #8, (RTSS Type), w /Fresh Geo - Pilot, & re -run bit, (FSF 2565 Z w /5x15's). MU rest of components accordingly & Initialize MWD probe w/o problems. RIH & shallow pulse test MWD w /400gpm= 500psi (OK). Pull back to MWD section of tools. 14:00 15:00 1.00 BHA PP PJSM /clear floor of un- neccessary personnel & load Nuke sources in carriers. Lower assembly and give all clear announcement & continue to add components as required, (Drlg. Jar, & HWDP) & RIH to 681'. 15:00 18:00 3.00 TRIP PP Continue to RIH w /BHA #8, 681' to +/- 3,345', w /PuWt= 125K & SoWt= 105K. www.peloton.com Page 25/45 Report Printed: 8/29 /2008 Operations Summary Report • Stan Time End Tirol Our (hrs) . Op Step Phase P/N Comment 18:00 18:30 0.50 CIRC PP Fill pipe as required & test MWD, after breaking in Geo -Pilot seals w /5rpm's on TDS, and increase 5 rpm's every minute to 60 rpm's max. Flow rate @ 400gpm= 1000psi, Shut down & flow check well as precaution (static) for 10 min's. 18:30 20:30 2.00 CUTDL PP PJSM /Slip & Cut Drilling line per Tool Pusher's requirements. Ensure all tools PU, and prepare to RIH w /BHA #8. 20:30 00:00 3.50 TRIP PP Pump @ 450gpm= 1,200psi, Rotate w /80 -120 rpm's and set up MWD on B mode. TDS= 4.4K off Bottom Torque @ 120 rpm, 115K RotWt. Continue RIH f/ 3,345' to 5,228' (side track @ 5,100'), break circulation and pump @ 450 • gpm to get survey for confirmation in sidetrack. Monitor well for losses while pumping for 15 minutes. (static). RIH f/ 5,228' to 5,899'. UW =185K, DN WT =115K, RT WT =130K. Had Kick while tripping drill= 1 min 15 sec., (No tight hole or bridging, & taking proper hole displacement) Operations Report Report Start Date Report End Date 6/17/2008 6/18/2008 Stan Time End Time Our (hrs) Op Step Phase P/N Comment 00:00 02:30 2.50 TRIP PP Continue to RIH w /BHA #8, 5,899' - 8,560', where taged bridge. Set down 20K WOB, while attempting to go through. PuWt= 225K & SoWt= 115K, RotWt= 115K. 02:30 06:30 4.00 TRIP PN Ream bridge w /60- 80rpm's on TDS= 12 -15K off Bottom Torque, 200- 250gpm= 900psi, & 15 -20K WOB, PuWt= 225K & SoWt= 115K, RotWt= 115K. Ream, 8,560' - 8,580', (went through quickly, & used these parameters to minimize any aggravation to Fault), & pump 50 BBL's, of Hi -vis 100 # /BBL LCM pill around, (lots of Clays returned @ surface), to aid w /any possible losses that might occur in Fault area, (no losses recorded). Continue to Wash, 8,580'- 9,250', seeing other slight bridge @ 9,075' & 9,120', (both easily reamed through w /10 -15K WOB & 10Orpm's on TDS, w/16 -20K off Bottom Torque, 400- 450gpm flow rate= 1,600- 1,800psi. A -Cal Data points were take @ 8,727 - 8,739'= 10.26" average, 8,944'- 8,954'= 9.42" average, & 9,114'- 9,124'= 10.34" average sizes. Had 4,144 unit of gas come @ 8,826', (believe from Fault area BU). No losses appeared to occur during reaming /washing operations. 06:30 07:30 1.00 CIRC PP Circulate Well Bore w /530gpm= 2,150psi, w /9.7ppg MW after Flow Check prior to starting was static. Some tight hole was seen @ 9,270', & reciprocated w /12Orpm's on TDS= 15 -20K off Bottom Torque, (PuWt= 250K & SoWt= 125K w /no rotation), RotWt= 155K. CBU, & pumped 50 BBL's of 100 # /BBL, (20 # /BBL each of Steel Seal, BaraFiber, BaraCarb 5 -25 -150). Spotted LCM w /base located @ +/- 8,600', (coverage 8,600'- 7,675'). 07:30 08:30 1.00 CIRC PP Let LCM pill soak @ 8,600'- 7,675' for 1 hr, while transferring 9.7ppg from displacement to RSC, & transfer 50 BBL's of 100 # /BBL LCM pill to pit #7, and take 300 BBL's of fresh 10.0ppg MW to pit #5. Check well bore, (static). Held spill drill= 1 min 15 sec. 08:30 13:00 4.50 CIRC PP Circulate & displace to 10.0ppg MW after Flow Check prior to starting was static. Some tight hole was seen @ 9,270', & reciprocated w /12Orpm's on TDS= 12 -15K off Bottom Torque, (PuWt= 175K & SoWt= 150K w /rotation), RotWt= 162K, w /550gpm= 2,150psi. Circulate fresh 10.0ppg MW in Well Bore, in & out. Flow check well bore (static). Continue to bring MW up to 10.3ppg MW, w /2,250psi, & once spaced out to ensure 10.3ppg MW same time LCM spotted, pumped 50 BBL's of 100# /BBL, (20 # /BBL each of Steel Seal, BaraFiber, BaraCarb 5 -25 -150). Spotted LCM w /base located @ +/- 8,600', (coverage 8,600'- 7,675'). Let soak 15 min's & flow check (static). Had some issues of getting to 9,316', as @ 9,280', appeared to stack WOB, (15 -26K), but erratic torque seen. Top IBS back @ 9,168', & appeared to hanging up. Back reamed slowly to avoid stalling, (saw 15 -25K torque), 9,280'- 9,220'= 9,108' for Top IBS. Once back reamed up & through same, went to bottom w/o incidents, further problems, or fill. Continued to work stand full length w/o issues. www.peloton.com Page 26/45 Report Printed: 8/29/2008 • Operations Summary Report • Stara Time End Time Dur (hrs) [ Op Step Phase P/N Comment 13:00 15:00 2.00 CIRC PP Circulate & continue Wt. up to 10.7ppg MW after Flow Check prior to starting was static. Reciprocated w /12Orpm's on TDS= 12 -15K off Bottom Torque, (PuWt= 175K & SoWt= 150K w /rotation), RotWt= 162K, w /550gpm= 2,250psi. Once spaced out to ensure 10.7ppg MW @ same time LCM spotted, pumped 50 BBL's of 100 # /BBL, (20 # /BBL each of Steel Seal, BaraFiber, BaraCarb 5 -25 -150). Spotted LCM w /base located @ +/- 8,600', (coverage 8,600'- 7,675'). 15:00 16:30 1.50 CIRC PP Let LCM pill soak @ 8,600'- 7,675' & transfer 50 BBL's of 100 # /BBL LCM pill to pit #7, and take 300 BBL's of fresh 10.9ppg MW to pit #1 -4= 650+ BBL's PVT. Check well bore, (static). 16:30 18:30 2.00 CIRC PP Circulate & continue Wt. up to 11.0ppg MW after Flow Check prior to starting was static. Reciprocated w /12Orpm's on TDS= 12 -15K off Bottom Torque, (PuWt= 175K & SoWt= 150K w /rotation), RotWt= 162K, w /550gpm= 2,250psi. Once received 11.0 ppg MW in /out, flow checked Well Bore, (static), & made TDS connection, to prepare for drilling ahead. Mud lubricants were brought up to Rig pits to be added, to bring Mud into proper condition while drilling ahead. 18:30 00:00 5.50 DRLG PP Drill 8 -3/4" 9,316' to 9,585', w /550gpm= 2,250psi, WOB= 12 -15K, w /130- 15Orpm's on TDS= 11 -12K off/12 -13K on Bottom Torque. PuWt= 250K,SoWt= 135K, RotWt= 162K. Performed slow pump rate @ 9,500'md/5,775'TVD, w /11.0 ppg MW. Drilling time @ 24:00hrs for Tour were ADT= 4.22hrs, TADT= 4.22hrs, Jar= 132.46hrs. Had 2253 units of connection •as w /BU, @ 9,409'. The Top of HRZ fm. came in @ 9,311', per Well Site eo ogis pic . ' e . spi .11 = min • sec. Operations Report Report Start Date Report End Date 6/18/2008 6/19/2008 Start Time End Time Dur (Ms) ' Op Step Phase P/N - Comment 00:00 05:00 5.00 DRLG PP Drill 8 -3/4" Hole, 9,598'- 9,883', w /550gpm= 2,400psi, WOB= 15K, w /130- 15Orpm's on TDS= 13K off /15 -24K on Bottom Torque. PuWt= 250K,SoWt= 125K, RotWt= 160K. 05:00 07:00 2.00 CIRC PP Pumped 30 BBL's High Vis sweep & CBU 3.5x, (not much seen w /sweep return), while reciprocating string w /PuWt= 250K, SoWt= 125K, RotWt= 160K. Flow rate @ 550gpm= 2,400psi, 13Orpm's w/TDS= 12K off Bottom Torque. Hole appeared clean @ 21 K strokes, & decision made to Short trip same. 07:00 08:00 1.00 STRIP PP Flow check Well Bore, (static). Attempt to POOH on elevators, but 85 -90K over and static well bore, (not dropping/or flowing). Decision made to pump out only & POOH, 9,880'- 9,220' w/o further difficulties, w /550gpm, no rotation, PuWt= 225 -230K & SoWt= 125K. 08:00 08:30 0.50 STRIP PP RIH on elevator only, 9,220'- 9,403', (no problems). Attempt to Wash /Ream, 9,403'- 9,440', (A -Cal data point, but tool not reading, (plugged off same). Attempt various parameters, 130- 16Orpm's on TDS= 15 -18K off Bottom Torque, 550gpm= 2,500psi= 12.18ppg ECD, 600gpm= 2,820psi= 12.26ppg ECD, & 630gpm= 3,050psi= 12.36ppg ECD. Not able to regain detection & decision made to RIH. 08:30 09:00 0.50 STRIP PP RIH on elevators only, 9,403'- 9,883' w/o incidents, SoWt= 125K. 09:00 12:00 3.00 DRLG PP Drill 8 -3/4" 9,883' to 10,073', w /550gpm= 2,500psi, WOB= 15K, w /130- 15Orpm's on TDS= 15K off /15 -24K on Bottom Torque. PuWt= 250K,SoWt= 130K, RotWt= 162K. Drilling time @ 12:00hrs for Tour were ADT= 5.38hrs, TADT= 9.60hrs, Jar= 137.84hrs, ECD= 12.24 w /11.0ppg MW. 12:00 20:30 8.50 DRLG PP Drill 8 -3/4" (/10,073' to 10,453', w /550gpm= 2,750psi, WOB= 15K, w /130- 15Orpm's on TDS= 15K off /16K on Bottom Torque. PuWt= 250K,SoWt= 130K, RotWt= 162K. Drilling time @ 20:30hrs for Tour were ADT= 5.81 hrs, TADT= 11.19hrs, Jar= 143.65hrs, ECD= 12.40 w /11.0ppg MW. No losses occurred while drilling section, & 1,60units of gas @ 9,983', & 1,044 units @ 10,206'. Had some problems w /rig air to draw works @ 10,166', & unable to proceed until diagnosed, (15min's). 20:30 23:30 3.00 CIRC PP Circulate bottoms up 3.5x @ 10,453', with cuttings subsiding completely at the end of circulating. Monitor well for 10 min prior to short trip, (static). 23:30 00:00 0.50 STRIP PP Short trip f/10,453' to 10,258', w /over pull of 40K on second stand, begin pumping out @ 320 gpm and no rotation. www.peloton.com Page 27/45 Report Printed: 8/29 /2008 Operations Summary Report Operations Report Report Start Date Report End Date 6/19/2008 6/20/2008 Start Time End lime Dur (hrS) Op Step Phase P/N Comment 00:00 02:30 2.50 U_TH PN Back ream out of hole, 10,258'- 10,175', w /300gpm= 1,500psi, PuWt= 265K, SoWt= 135K, RotWt= 165K, & 15Orpm's on TDS= 17 -24K off Bottom Torque. Seeing 50K over pull & hole attempting to pack -off. Back ream 10,176- 10,089', where hole packed -off, stalled string. Pulled 90K w/o firing jar, and work free. Re- establish circulation & rotation, back ream to 10,073'- 02:30 03:30 1.00 U_TH PN Mix & pump 30 BBI pill of lube pill, (Ep Mud lube, N -vis). Pump, & stage pumps up 550gpm= 2,700psi, 15Orpm's on TDS= 15 -18K off Bottom Torque. Circ. until shaker's clean. 03:30 05:30 2.00 U_TH PN Continue to Back ream 10,073'- 9,883', seeing well bore attempting to pack -off, & unable to stage up to 550gpm. Once able to achieve, back reaming w /15Orpm's on TDS= 15 -19K off Bottom Torque, 2,700psi. 05:30 09:00 3.50 U_TH PN Total Losses suffered during pack- off /tight hole events= 150 BBL's. Continue to reciprocate stand, 9,962'- 9,866, & raise MW to 11.5ppg, t control fm., (seeing coffee ground shales form LCU fm. steady over shaker's). Stand back a std., after 1.25hrs, & continue to reciprocate std., 9,866- 9,772', w /150rpm's on TDS= 15 -20K off Bottom Torque, 550gpm= 2,800psi (12.66 ECD) & 38% flow returns. PuWt= 265K, SoWt= 135K, RotWt= 165K. Once achieved 11.5ppg MW, in /out, and Shale stabilizer mixed, shut down & monitor well, (static). 09:00 18:00 9.00 U_TH PN Wash in hole, 9,772'- 10,226' where encountered first tight spot. Ream 10,226- 10,390', seeing well trying to pack -off numerous times, if too big of bite taken. WOB= 4 -8K when wanting to pack -off, & 12 -18K when wouldn't drill off very well. On pack -off's, Hole would try to pressure up w /200- 400psi, & if didn't work up & slow pumps, then would try stalling TDS. TDS= 15Orpm's, w/15 -25K off Bottom Torque, & 525- 550gpm's= 2,650- 2,750psi. A -Cal data was taken @ 9,930'- 9,940'= 9.83" average, 10,130'- 10,140'= 9.80" average, & 10,340'- 10,350'= 10.42 ". Had to stop reaming operations @ 10,300' & 10,415' to unload cutting out of hole across shaker's, (Kupurak Sands unloaded both times, cut back to 350- 400gpm, & stage up as unloaded). Stopped also @ 10,250' to spot 50 BBL's of 100 # /BBL LCM & let soak 1 /2hr, & 10,363' for another 25 BBL for 15 min's. Both times well bore was static. Losses of 30 BPH started @ 10,234', & increased to 80 -90 BPH @ 10,259'. This stayed constant 80 -100 BPH until second LCM pill @ ''3 where slowed to 70 BPH, & 10,388' @ 25 -33 BPH to bottom. On last std., worked single after reaming, w/o rotation, & mode switched MWD. Saw PuWt= 260K, SoWt= 100K, RotWt= 165K. 18:00 00:00 6.00 DRLG PP Drill 8 -3/4" 10,453' to 10,690', w /550gpm= 2,750psi, WOB= 12 -15K, w /15Orpm's on TDS= 18K off /19K on Bottom Torque. PuWt= 265K,SoWt= 110K, RotWt= 168K. Performed slow pump rate @ 10,547 "md /6,008.7'TVD, w/11.5 ppg MW. Drilling time @ 24:00hrs for Tour were ADT=4.29hrs, TADT= 19.70hrs, Jar= 147.94hrs. Had 1045units of connection gas w /BU, @ 10,206'. Report Start Date Report End Date 6/20/2008 6/21/2008 Start Time End Time Our (hrs) ' Op Step Phase P/N Comment 00:00 06:00 6.00 DRLG PP Drill f/10,690' to 10,927' @ 150 rpm= 18 -22K on bottom/ 18K off botttom torques, 550 gpm =2850 psi. Pumped 20 bbl Icm pill and spot and let soak for 15 min. for hole losses of 150 bbl /hr rate, Pumped second 30 bbl Icm pill in attempt to stop losses but circ it slowly across loss zones. 06:00 09:00 3.00 CIRC PN POOH 1 stand and circulate and build volume. Circulate @ 100 gpm = 450 psi, 60 rpm = 15 -18K torque. 09:00 12:00 3.00 CIRC PN Pump 100 bbl Icm pill and spot @ 10,797', shut bag in and squeeze pill @ .5 BPM /2 BBLS @130-250 psi every 10 min for a total of 34 bbls squeezed. Mixing more volume in pits and another pill. 12:00 13:30 1.50 CIRC PN Pump and spot second pill and perform hesitation squeeze @ 2 BBLS every 10 minutes @ 6 SPM = 224 psi for a total of 40 BBLS squeezed. 13:30 14:30 1.00 CIRC PN Monitor flow back from sqeeze of 20 bbl total. 14:30 15:00 0.50 RMWASH PP Wash & ream f/ 10,790' to 10,927' @ 140 spm = 500 gpm/ 30 rpm = 15 K torque. www.peloton.com Page 28/45 Report Printed: 8/29/2008 Operations Summary Report Stan Time End Time Our (hrs) Op Step Phase P/N Comment 15:00 16:00 1.00 DRLG PP Drill ahead f/ 10,927' to 11,016' C 155 SPM = 2750 PSI = 547 GPM, 150 RPM = 18 -25K torque, 15 -25K WOB, 265K UP, 125K DN, 165K ROT. Still having hole losses of 160 /180 BBLS hr. 16:00 17:30 1.50 CIRC PP Circulate bottoms up @ 11,016 for geologist sample @ 547 GPM = 2650 PSI, 150 RPM = 18K torque. 17:30 18:30 1.00 DRLG PP Drill f/11,016' to 11,100' for TD. Nuiqsit came in @11,085'. Used same drilling parameters. 18:30 20:00 1.50 CIRC PP Circulate bottoms up 1.5x as mud allowed @ 11,100' for short trip. Observed well for 10 minutes, well flowing back 10 BBLS. 20:00 22:30 2.50 STRIP PP Short tripping w/o pumping or back reaming f/ 11,100' to 10,698' @ 30 -40 K over pull. Hole gave back(breathing 86 bbls in 1 hr and decreasing. Pump metal displacement of each stand. P WT =265K, DN W I =12Uts. Hit tight spot @ 10,825'/ 70K over pull. 10,747 to 10,714' 35 -49K over pull. Hit next tight spots f/ 10,698' to 10,642' w/ 90K over pull. had to pump on it & rotate, had pack off issues but got 550 gpm and 150 rpm rates and worked through it. 22:30 00:00 1.50 CIRC PN Circulate hole @ 550 gpm/ rotating 150 rpm for bottoms up. Operations Report Report Start Date Report End Date 6/21/2008 6/22/2008 Start Time End Time Dm (Ma) Op Step J Phase [ P/N Comment 00:00 06:30 6.50 STRIP PP Short trip f/ 10,737' to 9,883', had to pump/ back ream f/ 10,548' to 10,037' where we came out of tangent, over pull of 90 K. Hole is still flowing back @ 85 BBL's /hr. Pulled pumping metal displacement + volume swabbed only f/10,548' to 10,175' w /50K over pull CO 10,398'- 10,306', 75K over pull @ 10,248'- 10,175'. Pumped & back reamed f/10,175' to 10,073', @ 10,168' both stalling & packing off, had to be easy and patient with pumps until able to get full pump rate of 550 GPM/ 150 RPM /18 -29K Torques. Pulled pumping metal displacement only f/ 10,073' to 9,883' with 30 -40K over pull. PU =270K, SO =125K. Noticed while pulling on elevators @ 10,245' or stand #9 it was dry. 06:30 11:30 5.00 STRIP PP RIH f/ 9,883' to 10,130' on elevators. PU =275K, SO =125K. Taking weight, MU TDS and wash & ream to 10,168' @ 550 GPM, 150 RPM. RIH on elevators to 10,235', take MAD survey @ 1ft/min f/10,235' to 10,275'. RIH on elevators f/ 10,275' to 11,100'. Had tight spot @ 10,743' set 50K on rotate through, (a ledge on log correlating to a stabilizer). 11:30 12:00 0.50 DRLG PP Drill f/11,100' to 11,103' @ 500 GPM =2500 PSI, 150 RPM =20K torque, WOB =10K. Monitor well for 15 minutes. ADT =.21 /hrs, TDT= 24.83/hrs, JARS= 153.07/hrs. 12:00 13:00 1.00 STRIP PP Monitor well flowing for 1 /hr and record time and volumes. A total of 85 BBL's /1hr. Positive well is breathing. 13:00 16:00 3.00 STRIP PP Short trip pumping metal displacement only + volume swabbed f/ 11,103' to 9,985' @ 340 -275K UP, 75 -120K DN. Made another MAD pass (/10,275' to10,235' @ 1FPM rate. 16:00 23:00 7.00 U_OTR PN Move string up & down 10' every 15 min while building volume up in rig pits and RSC per Co. Man /mud engineer's specifications to circulate bottoms up of 4x @9,985' before wiper trip to 9 -5/8" casing shoe. Total returns back f/ well= 8.4BBL's. 23:00 00:00 1.00 U_LC PN Finished weighting up mud to 11.5 PPG. Started to circulate BU 4x @ 550 GPM rate. Monitored losses for 15 minutes = 350 BBL's /hr loss = 45% loss rate. Backed off pumps to 200 GPM rate for 15 minutes= 10 BBL's/hr loss = 1.5 % loss rate. Picked up pump rate to 300 GPM for 15 minutes =115 BBL's /hr loss = 14% loss rate. Report Start Date Report End Date 6/22/2008 6/23/2008 Start Time] End Time Our (hrs) Op Step Phase P/N Comment 00:00 02:30 2.50 CIRC PN Circulate hole @ 200 GPM= 700 PSI/ 60 RPM= 15K torque. Mixing 100# per BBL/ 60 BBI's LCM pill. Pump pill @ 250 GPM =800 PSI to within 400' f /bit, then pump @ 560 GPM= 2800 PSI the Volume of pill + 5 BBIs out the bit. Monitor well 10 min, flowing a 54 -34 GPM. Got back 24 BBL's. 02:30 05:00 2.50 STRIP PP POOH f/10,073' to 8,790' pumping metal displacement + swab volume. Had tight spots @ 9,711', 9,659', 9,580', 9,422' pulling 50K over string weight only. Stop and monitor well and flowing subsided to 2BBU hr. www.peloton.com Page 29/45 Report Printed: 8/29 /2008 Operations Summary Report S Start Time End Time Dur (hrs) Op Step Phase P/N Comment . 05:00 09:30 4.50 CIRC PP Circulate hole BU 4x slowly increasing pump rate to 500 GPM =2200 PSI, 100 -150 RPM = 15 -22K torque. Monitor well 30 minutes to confirm breathing @ 80 to 35 GPM. Total losses were 270 BBL's @ 50 BBL'S /hr average. Final losses f /circulating 50 BPH. 09:30 00:00 14.50 STRIP PP . POOH f /8,70' to 8,462' pumping metal displacement + swab volume only. Hit tight spots @ 8,558' - 8,550', 8,636', 8,176, 7,629', 7,603', 7,585', 7,471', 7,256', 7,007' to 6,930', 6,686', 6,083',pulling 70K over. Continue to POOH pumping metal displacement + swab volume and only pumping & rotating when totally necessary f/6,083' to 5,992' w/o problems. Continue to P001-I f/ 5,992' to 4,640' with a few problem ledges, pulling great. Operations Report Report Start Date Report End Date 6/23/2008 6/24/2008 Start Time End Time Dur (hrs) : Op Step Phase. P/N Comment 00:00 02:30 2.50 STRIP PP Wiper trip f/4,665' to 3,337'. PU /155K, DN /110K. Work tight spots @ 4,640', 4,532', 3,963' & 3,850' pull 50K over pull and pumping @ 100 GPM. a 50 CIRC PN Circulate hole while s e rv icing TDS d this operation and prepare for RIH 02:30 04:00 1.50 CIRC i �� Circulate .�v�� ....�.v t .ia.�..v. � ..... during ..... operation ..a.. prepare r ..... .. .... .... .. 04:00 09:30 5.50 TRIP PP RIH 1/3,337' to 5,426' work tight spots @ 5,160', 5,226- 5,266. Take a survey and confirm in wrong hole. 09:30 12:00 2.50 TRIP PN POOH f/5,426 to 5,045', PU =165K, DN =115K. RIH to 5,045', orient tool to line up w /kickoff @ 5,100', wash & ream @ 500 GPM =1900 PSI, 60 RPM= 5K torque. Continue to RIH to 5,430' and takin�w Confirm in wrong hole. POOH to 5,045', wash & ream kickoff point i - 500 GPM =1900 PSI, 60 = RPTA= 5K torque. 12:00 16:30 4.50 RMCLN PN Washing & reaming @ kickoff point f/5,100' to 5,235' using time drilling and, MWD data to successfully get into new hole. Work section a couple times and continue onin the hole. 16:30 00:00 7.50 TRIP PP Continue to RIH f/ 5,235' to 10,358' filling DP every 2000'. Had to pump f/ 9,900' @ 140 GPM and continue to RIH. Made MAD pass f/ 10,230' to 10,275' @ 1 FPM rate. UP /260K, DN /105K. Report Start Date Report End Date 6/24/2008 6/25/2008 Start Time End Time Our (hrs) Op Step Phase P/N Comment 00:00 02:00 2.00 TRIP PP TIH f/10,358' to 11,103' working tight spot @ 10,535', 10,672', 10,740', 10,878', pumped @ 150 GPM through area's. PU =275K, DN =115K. Ream f/11,098' to 11,103' @ 125 RPM =15K torque, 150GPM= 700 PSI. ROT WT= 165K. 02:00 07:30 5.50 CIRC PP Circulate & condition mud & clean hole. Did a step rate increase on GPM f/150 to 500 in 50 GPM increments over 10 minutes each to check loss rate. Notified Lead Co. man of rates and established 300 GPM rate for 3 hrs. Mixing 100 BBL's /100# per BBL LCM pill. Mix & pump 100 BBL lube pill and spot on bottom. Monitor well to confirm breathing, flow rate f/ 74 to 26 GPM, 41 BBL's back f/ monitoring. 07:30 09:00 1.50 TRIP PP POOH f/ 11,103' to9,788' with no difficulties. PU =290K, DN= 100K.. 09:00 10:00 1.00 CIRC PN Circulate hole and spot 100 BBL LCM pill outside the bit @ 9,788'. 10:00 11:00 1.00 TRIP PP POOH f/9,788' to 8,746' with no difficulties. PU =240K, DN =120K. Hole in good shape. 11:00 14:00 3.00 CIRC PP Circulate and conditon mud & hole @ 150 to 500 GPM =1400 PSI, 150 RPM =15K torque. 140 BBUhr losses. 14:00 00:00 10.00 TRIP PP POOH f/8,746' to 3,340' pumping metal displacement + swab volume = 80 STKS= 7BBL's. Worked top stabilizer & bottom stabilizer /bit extensively through window area of 5,160' to 5,140', assuring 3 x that we could go out 5', 10' & 15' and back in with out pumping this entire process. Take survey @ 5,235'/MWD- bit/5,203', survey confirmed in correct hole. POOH to 4,760'. UP =160K, DN =115K. Report Start Date Report End Date 6/25/2008 6/26/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 01:00 1.00 TRIP PP POOH F/ 4760' To/ 3337'. P /U =130k, S/0 =100k. 01:00 01:30 0.50 CIRC PP Circ. and condition at 500 GPM, 150 RPM, 1500 PSI, 4K TQ. 01:30 03:00 1.50 TRIP PP POOH F/ 3337' To/ 1059'. 03:00 03:30 0.50 U_RIG PN Repair pin on elevators. 03:30 04:00 0.50 TRIP PP POOH F/ 1059' To/ 680'. 04:00 05:00 1.00 BHA PP Rack back HWDP, DC & UD subs. www.peloton.com Page 30/45 Report Printed: 8/29/2008 Operations Summary Report Start Time End Ttme Dur (hrs) Op Step Phase PIN Comment 05:00 07:00 2.00 LWD PP UD BHA, remove Nukes, & down load MWD. 07:00 08:30 1.50 BHA PP UD BHA, pull pulser, stand back MWD, B/0 Bit and UD Geo Pilot. 08:30 09:00 0.50 BHA PP Clear rig floor of exess equipment. 09:00 10:30 1.50 BOPS PP Nipple down BOPs, change upper ram to 7" csq ram_ Change saver sub on TDS to XT -39 and install stab guide. 10:30 12:00 1.50 BOPS PP Pull wear ring, set test plug and make up cross overs & valves. 12:00 13:00 1.00 BOPS PP Finish make up test equipment. 13:00 16:00 3.00 BOPS PP Test BOPE per AOGCC, Nabors & Pioneer Policies. Held each test 5 min. and charted same. Annular 250/2500 psi, 7" rams, dart, HCR Kill and choke, safety valve, manual choke and kill valves, IBOP, #5 choke manifold valve, lower !BOP, blind rams, 250/3500 psi. Performed accumulator draw down. Jeff Jones with AOGCC waived witnessing test. 16:00 17:00 1.00 BOPS PP Test BOPE, UD test equipment pull and lay down test plug. 17:00 19:00 2.00 CSG PN Break out collar on joint of 7" casing and while attempting to torque with Baker Lock applied to thread; tube on joint was egg shaped. 19:00 21:00 2.00 CSG PP Lay out damaged joint, pick up spare, back off collar, pick up second joint, clean threads and Baker locked same, installed Reamer Float Shoe and centralizers. 21:00 00:00 3.00 CSG PP Rigged up casing spiders, elevators, tongs, Franks fill up tool and changed Bales. Operations Report Report Start Date Report End Date 6/26/2008 6/27/2008 Start Time End Time Our (hrs) Op Step Phase P/N Comment 00:00 01:00 1.00 CSG PP Make up float equipment and verify floats open with circulation. 01:00 07:00 6.00 CSG PP Run 7 ", 26 #, N -80 casing F/ 120' To/ 3376' filling every joint with Franks fill up tool. Install centraiizers and stop rings on first 90 joints. P /U =145k, S /0 =105K. 07:00 07:30 0.50 CIRC PP Circulate and condition casing volume at 3376', 135 BBLs, 1600 stks, 300 GPM with 700 PSI. 07:30 12:00 4.50 CSG PP Run Casing F/ 3376' To/ 6619'. Fill every joint with Franks fill up tool. P /U =200K, S /0 =120K. 12:00 20:30 8.50 CSG PP Run Casing F/ 6619' To/ 11045'. S /0 =125K. 20:30 21:30 1.00 CSG PP M/U Vetco Hanger and landing joint. 21:30 23:00 1.50 CSG PN Slack off to 11068', tagged obstruction, attempted to break circulation. 5 SPM, 750 PSI, no returns,warR cd ation. Picked up to 400K to break casing tree. Nnelums. 23:00 00:00 1.00 U_OTR PN UD casing landing joint and Franks Fill Up tool. Report Start Date Report End Date 6/27/2008 6/28/2008 Start Time End Time Cur (hrs) Op Step Phase PIN Comment _ 00:00 01:30 1.50 CMTPRI PP Install cement lines and R/U cement head. 01:30 04:30 3.00 CMTPRI PP Circulate casing volume increasing circulation rate .25 BPM each 5 minutes up to 6 BPM. Losses approximately 70% with 460 BBLs pumped. 6 BPM with 1530 PSI. 04:30 05:30 1.00 CMTPRI PP Take on 300 BBLS of 10.4 PPG OBM from RSC into Pit #5. Held PJSM for cement job, flush lines and pumps with OBM. 05:30 07:00 1.50 CMTPRI PP Pump 10 BBLS Pre Flush, Test lines to 4000 PSI. Drop 1st plug, load 2nd plug, pump 40 BBLs 12 PPG spacer, Drop 2nd plug, mix and pump 56 BBLs premium cement at 15.8 PPG, yield 1.18 cu ft/sk, 314 cu /ft slurry. Mixed with sea water +.55% Halad -344 + .2% CFR -3 + 0.25 LB /SK Super CBL + 0.25 % SCR -100. Drop top plug with good indicator shift of plug launch. Chase with 3 BBLs water. 07:00 09:00 2.00 CMTPRI PP Displace cement with 421.5 BBLs 10.4 PPG OBM at 6 BPM, 1480 -1800 PSI. Bumped plug with 5119 Strokes (433 BBLS at 96 %). Pressure up to 3500 PSI and chart same for 30 min. casing test. Cement in place at 08:20 HRS. 09:00 11:30 2.50 U_WT PN Close annular and WOC due to not landing 7" on hanger. Clean pits and rig floor. 11:30 14:30 3.00 U_OTR PN UD cement head and suck out landing joint. 14:30 15:30 1.00 U_OTR PN PJSM, Nipple down BOP, raise stack for emergency slips. 15:30 16:00 0.50 U_OTR PN Set 7" emergency csg slips with 200k weight indicator reading for 150K tension on slips. 16:00 17:30 1.50 U_OTR PN R/U and cut 7" casing, 20.80' cut off placing shoe at 11066.5'. www.peloton.com Page 31/45 Report Printed: 8/29 /2008 Operations Summary Report - Start Time End Time Dui (hrs) Op Step Phase PIP} _ Comment 17:30 18:30 1.00 U_OTR PN Set pack off. 18:30 20:00 1.50 U_OTR PN Test pack off to 4300 PSI F /10 min. Witness by Vetco Service Rep and PNR Drlg Rep. 20:00 21:00 1.00 CSG PP L/D hanger and landing joint. 21:00 21:30 0.50 RURDRT PP M/U test plug and install in well head. 21:30 00:00 2.50 CSG PP Rigged down casing elevators and change out bales. ,Operations Report Report Start Date Report End Date 6/28/2008 6/29/2008 Start Time End Time Dur (hrs) Op Step Phase PIN Comment 00:00 00:30 0.50 CSG PP Change Elevators F/ 7" To/ 5" DP. 00:30 03:30 3.00 BHA PP Lay down 8 3/4" BHA. 03:30 10:00 6.50 DPIPE PP Install mouse hole in Rotary table and Lay down 15 Jts HWDP, Jars and 93 joints 5" Drill Pipe. 10:00 11:00 1.00 RIGSER PP Clean rig floor, pull & lay down mouse hole, pull test plug, install wear ring. 11:00 13:30 2.50 DPIPE PP Change elevators, M/U x -o and mule shoe, TIH picking up 20, 4" dirll pipe Ringies_ 13:30 14:30 1.00 U_RIG PN Repair Iron Roughneck Spinners. 14:30 17:30 3.00 DPIPE PP Continue Pick up 4" DP for total of 96 jts to 3168'. 17:30 18:30 1.00 DPIPE PP Re- position 4" drill pipe in derrick before Trip out of hole. 18:30 21:00 2.50 DPIPE PP POOH with 32 stands of 4" DP and rack on drillers side of derrick. 21:00 21:30 0.50 BOPS PP Remove wear bushing, install test plug in well head. 21:30 00:00 2.50 BOPS PP Change Upper and Lower Rams from 7" & 5" fixed rams to 4" fixed. Report Start Date Report End Date 6/29/2008 6/30/2008 Start Time' End Time Dun (hrs) Op Step Phase P/N Comment 00:00 00:30 0.50 BOPS PP Change Upper and Lower Drill Pipe Rams F /7' & 5" to 4" Fixed. 00:30 01:00 0.50 BOPS PP Make up Test equipment. 01:00 04:00 3.00 BOPS PP Tested BOPE Der AOGCC,.Nabors and Pioneer guide lines. Annular, Upper and lower 4" fixed rams, Blind Rams, 14 Choke manifold valves, Upper & Lower TDS IBOP, Safety Valve, Inside BOP, Manual Choke, Hydraulic Choke, 2 HCR Valves, Kill Line valve & choke line valve. 250/3500 for total of 28 components. Performed accumulator test, 3000 System pressure, 2000 After closure, 200 psi attained in 16 sec, full pressure attained 1 min 19 sec. No failures. Choke manifold was tested while picking up and racking back 4" drill pipe in derrick. AOGCC Rep Lou Grimaldi Waived witnessing the test 6/28/2008 07:00 hrs. 04:00 05:00 1.00 BOPS PP Blow down lines, Install wear bushing, and R/D test tools. 05:00 09:00 4.00 BHA PP M/U 6 1/8" Steerable BHA. 09:00 10:00 1.00 LWD PP Down Load MWD. 10:00 11:00 1.00 LWD PP Shallow test MWD, 243 GPM= 1390 PSI, All test OK, Load Nukes. 11:00 12:00 1.00 BHA PP M/U 6 1/8" Steerable BHA, install flex collars, circ. sub and ball catcher to 226'. 12:00 13:00 1.00 BHA PP M/U BHA, pick up HWDP and Jars. Clear floor . 13:00 13:30 0.50 CIRC PP B /C, test Geo Pilot, 70 SPM, 247 GPM, 2150 PSI, 70 RPM, 2k TQ, Blow down TDS. 13:30 17:00 3.50 DPIPE PP Pick up 4" DP singles to 3146'. (Freeze Protect 9 5/8" x 7" annulus with 86 BBLs WBM, 10 BBL OBM, @ 3 BPM, 1000 PSI, W/ 60 BBLs Diesel 2 BPM, 1150 PSI, 1000 PSI shut 14:30 -15:30 Hrs) 17:00 00:00 7.00 DPIPE PP P/U 4" DP singles F/ 3146' To/ 8612'. At 6000' filled pipe, P/U Wt =175K, S/O Wt =105K. Report Start Date Report End Date 6/30/2008 7/1/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 04:30 4.50 DPIPE PP Picked up 4" DP singles F/ 8312' To/ 10833'. P/U Wt. =195K, S/O Wt. =115K. 04:30 05:00 0.50 RMWASH PP Wash and Ream F/ 10833' To/ 10930'. 200 GPM, 3430 PSI, RPM 40, TQ =8K, Rot WT =125K. 05:00 06:00 1.00 CIRC PP Circulate and Condition 1 Bottoms up. 06:00 07:30 1.50 CUTDL PP Slip and cut drill line, service TDS. Record SPR's: 10930 MD, 6184 TVD, #1 Pump, 20 SPM =760 Psi, 40 SPM= 1500 Psi, #2 Pump 20 SPM =800 Psi, 40 SPM =1550 Psi MW =10.4 PPG 07:30 08:30 1.00 RMWASH PP Wash and Ream F/ 10930' To/ 10978', Tag plugs, 250 GPM, 3760 PSI. 08:30 09:30 1.00 U_MWD PN Trouble shoot detection on M no pu se. lrculate. www.peloton.com Page 32/45 Report Printed: 8/29/2008 Operations Summary Report Start Time End Time ' Dur (hrs) Op Step 7 Phase '/N Comment • 09:30 12:00 2.50 DRLCMT PP Drilled Plugs, cement and float equipment. F/10978' To/ 11045'. 230 GPM, 3080 PSI, 75 RPM, 7 -10K WOB, P/U =195, S /0 =112K, ROT WT =125K. 12:00 12:30 0.50 DRLCMT PP Drill Cement and float shoe F/ 11045 To 11067'. 12:30 15:00 2.50 DRLCMT PP .0lean out rat hole F/11045' to 11103' and drill new formation F/ 11103' to/ 11122'. 200 GPM, 60 -90 RPM, 5 -f0K TQ, 3100 -390U VSI. 15:00 16:30 1.50 CIRC PP Circ & condition for FIT at 11122', 229 GPM, 3500 PSI, 127 K ROT WT. 16:30 17:00 0.50 LKOFF PP Perform FIT Test @11067' MD, 6224 TVD, 1/2 BPM with 10.4 PPG, 760 PSI, ¶2.75 EMW. 1.5 BBLS used, 1 BBLS bled back. 17:00 20:00 3.00 U_MWD PN Trouble shoot` detection. Attempt different flow rates, and pressures on discharge dampners. 200 GPM gave best detection. 20:00 00:00 4.00 DRLG PP Drill F/ 11122' To/ 11253'. 57 SPM, 200 GPM, 2900 PSI, 60 -150 RPM, 8 -10K TQ, 190K P /U, 105K S /O, 127K ROT. TVD 6258', ADT =2.19, ART =2.19. Operations Report Report Start Date Report End Date 7/1/2008 7/2/2008 Start Time 0 o:OC 6.00 DRLG Tool Our (hrs) f Op Step I Phase P/N Comment 00:00 � 0 DR L G I 11253' To/ 11508' 200 GPM, 3030 PSI ON , 2790 PSI OFF, �a r � PP Drill � i F/ G_ RPM =120 PSI, TQ ON =10 -12K, TQ OFF =8K, P /U =225K, S /0 =100K, ROT =130K, WOB =7K. 06:00 07:00 1.00 U_MWD PN Trouble shoot detection problem with MWD and directional equipment. 07:00 08:00 1.00 DRLG PP Drill F/ 11508' To/ 11551'. 243 GPM, 3580 PSI ON, 3450 PSI OFF, RPM =140, TQ ON = 12 -14K, TQ OFF = 9 -10K, P/U 225K, S/O 100K, ROT WT 128K, WOB= 12 -15K. 08:00 09:00 1.00 U_MWD PN Trouble shoot detection problem with MWD. 09:00 10:30 1.50 DRLG PP Drill F/ 11551' To/ 11605'. 243 GPM, 3580 PSI ON, 3450 PSI OFF, RPM =140, TQ ON = 12 -14K, TQ OFF = 9 -10K, P/U 225K, S/O 100K, ROT WT 128K, WOB= 12 -15K. 10:30 14:00 3.50 U_MWD PN Trouble shoot detection problem with MWD. Change pump dampner pressure, change out transducer. 14:00 23:00 9.00 DRLG PP Drill F/ 11605' To/ 11991'.70 SPM, 248 GPM, 3750 PSI, 130 RPM, 10 -12K TQ ON, S /O =98K, P /U =250K, ROT =125K. 23:00 00:00 1.00 CIRC PP Circulate & condition, ECD's staying higher than usual, circulate to verify hole cleaning at higher pump rate. 79 SPM, 278 GPM, 4450 PSI, 150 RPM, 9 -10 K, ROT =125K. 11991 MD, 6253 TVD, ART 5.13, SPR@ 11991: #1 -20 =790, 40 =1550, #2- 20 =790, 40 =1510. Report Start Date Report End Date 7/2/2008 7/3/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 09:00 9.00 DRLG PP Drilling F/ 11,991 to 12,474. Using 250 GPM @ 4.050 psi ,140 RPM, Torque 14K, P/U 250K, S/O 82K, R/T 123K. 09:00 09:30 0.50 CIRC PP Circulate and work pipe F/ 12,474' to 12,377' due to ECD reaching 13.5 ppg. Circulate @ 250 gpm W/ 3880 psi and 140 rpm. 09:30 10:30 1.00 CIRC PP Circulate and work pipe F/ 12,474' to 12,377' due to ECD reaching 13.5 ppg. Circulate @ 200 gpm W/ 2,990 psi and 140 rpm. Rack Back 1 stand 10:30 11:30 1.00 CIRC PP Circulate and work pipe F/ 12,377' to 12,281' due to ECD reaching 13.5 ppg. Circulate @ 250 gpm W/ 2,990 psi and 140 rpm. 11:30 12:00 0.50 RMWASH PP Wash and Ream F/ 12,377' to 12,474' Using 250 GPM @ 3900 psi, Torque 12K @ 140 RPM, ECD at 13.26 ppg. DATA POINT= ( With no pumps P/U 245K, S/O 80K, R/T 125K Torque 11 -12K) 12:00 12:30 0.50 CIRC PP Circulate and Condition Hole @ 12,474'. Circulate @ 250 gpm W/ 3,700 psi and 120 rpm. 12:30 13:30 1.00 RMWASH PP Backream F/ 12,474' to 11,750' using 200 GPM @ 2500 psi and 50 RPM 13:30 16:30 3.00 RMWASH PN Backream (Mad Pass) F/ 11,750' to 11,610' using 200 GPM @ 2500 psi and 50 RPM Reaming @ 50FPH 16:30 18:00 1.50 RMWASH PN Working thru Tight spot, hole packing off @ 11,610'. Pulled 30K over 18:00 00:00 6.00 RMWASH PN Backream (Mad Pass) F/ 11,610' to 11,315' using 225 GPM @ 3000 psi and 50 RPM Reaming @ 60 -70 FPH. P/U 230K, S/O 105K, R/T 135K. 11K Torque. ECD Reading 11.85 ppg Report Start Date Report End Date 7/3/2008 7/4/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 04:00 4.00 RMWASH PN Backream (Mad Pass) F/ 11,315' to 11,102' using 225 GPM @ 2800 psi and 50 RPM Reaming @ 60 -70 FPH. P/U 220K, S/O 110K, R/T 130K. 11K Torque. ECD Reading 11.85 ppg www.peloton.com Page 33/45 Report Printed: 8/29/2008 Operations Summary Report Stsrl Time End Time Dur (hrs) Op Step Phase P/N Comment 04:00 04:30 0.50 TRIP PP RIH F/ 11,102' to 11,300'. Collecting Torque and Drag Data Points 11,300' No Pumps (P /U =220K, S /0 =107K, R/T =145K, Torque 11 -13K). 04:30 06:30 2.00 CIRC PP Circulate and Condition Hole 2x B /U. 250 gpm W/ 3430 psi. After Circulating collect Torque and Drag readings at 11,300'. No Pump (P /U 220K, S/O 105K, R/T 145K, Torque 10 -12 ) 06:30 07:00 0.50 RIGSER PP Service Rig and Top Drive 07:00 07:30 0.50 TRIP PP POOH into casing shoe F/ 11,300' to 11,025 No Problems 07:30 08:30 1.00 CIRC PP Circulate with no rotary and 120 gpm @ 1300 psi. Analyze Mad Pass Data, 08:30 10:30 2.00 TRIP PP RIH F/ 11,025' to 12,474' Hit tight spot @ 12,068'. M/U TD and wash F/ 12,050' to 12,177'. Wash to bottom F/ 12,369' to 12,474'. using 140gpm @ 1430 psi, 65 rpm 10:30 12:00 1.50 DRLG PP Drilling F/ 12,474' to 12,530' using 200 gpm @ 2,788 psi, 90 rpm, Torque 10-11K WOB 15K ADT =1.05 Hrs. 12:00 00:00 12.00 DRLG PP Drilling F/ 12,350' to 13,053' using 235 gpm @ 3,350 psi, 105 rpm, Torque 10 -14K WOB 15K P/U 250K, S/O 84K, A/T 128K ADT= 6.80 Hrs. Total ADT 7.85 Hrs. ECD 12.45 ppg Operations Report Report Start Date Report End Date 7/4/2008 7/5/2008 Start Time End 'time Dar (hrs) Op Step Phase P/N Comment 00:00 03:30 3.50 DRLG PP Drilling F/ 13,053' to 13,211' using 235 gpm @ 3,400 psi, 100 Rpm, Torque 10 -14K WOB 15K P/U 258K, S/O 78K, R/T 125K 03:30 05:30 2.00 CIRC PP Stop Drilling @ 13,211' and Circulate. Geologist needed to confer about hole direction and the formation we were in. Circulate at 225 Gpm w/ 3200 psi and 100 Rpm. 05:30 09:00 3.50 DRLG PP Drilling F/ 13,211' to 13,359'. Decision made to start dropping angle when Geo Pilot would not recieve commands, attempt to trouble shoot same, No Luck. using 225 gpm @ 3,490 psi, 110 Rpm,Torque 13 -16K WOB 10K P/U 258K, S/O 78K, A/T 125K 09:00 14:00 5.00 CIRC PN Circulate and work pipe F/ 13,359' to 13,248' while consulting with town about Geo - Pilot. using 240 gpm @ 3,570 psi, 130 Rpm,Torque 10 -12K 14:00 17:30 3.50 TRIP PN POOH F/ 13,359' to 11,060'. Had tight hole from 12,670' and 11,780' pulled 20 -35K over. 17:30 21:00 3.50 TRIP PN Pump dry job and continue POOH F/ 11,060' to 7,553' 21:00 00:00 3.00 DPIPE PN Start UD 54 Joints of 5" DP from the Derrick in the mouse hole. 74 stands of 4" plus BHA still in the hole, Depth 7,553' Report Start Date Report End Date 7/5/2008 7/6/2008 Start Time End Time Our (hrs) Op Step Phase P/14 Comment 00:00 06:30 6.50 DPIPE PN Continue to LD 198 Joints of 5" DP from the Derrick in the mouse hole. 74 stands of 4" plus BHA still in the hole, Depth 7,553' 06:30 07:00 0.50 RIGSER PN Service Rig & TDS /Clear floor & C -O elevators. 07:00 11:00 4.00 TRIP PN Flow check well bore 10 min.'s, (static). POOH w /BHA #10, 7,553' -411', w/o incidents, (hole taking proper amount fill). PuWt= 55K, SoWt= 55K 11:00 12:00 1.00 BHA PN R/B HWDP, UD Circulating Sub /Ball Catcher 12:00 13:00 1.00 BHA PN Remove Radioactive Sources and R/B Flex collars 13:00 14:30 1.50 BHA PN Down Load Smart Tools 14:30 17:00 2.50 BHA PN UD remaining BHA and Geo - Pilot. 17:00 17:30 0.50 BOPS PP Pull wear Bushing 17:30 20:00 2.50 BOPS PP Set Test plug and test BOP's to 3500 hi h and 250 Low as per AOGCC. Bob Nobles of AOGCC waived witness ss of test. hoke ani old was tested while pulling out of hole. 20:00 21:00 1.00 BOPS PP R/D test equipment and blow down all lines, pull test plug and install wear bushing 21:00 21:30 0.50 RIGSER PP Service Crown and Drawworks 21:30 00:00 2.50 BHA PN P/U BHA out of pipe shed, plug in and load Smart Tools, 155' of BHA in hole. Report Start Date Report End Date 7/6/2008 7/7/2008 www.peloton.com Page 34/45 Report Printed: 8/29/2008 • Operations Summary Report Start Time End Time Der (hrs) [ Op Step Phase P/N Comment 00:00 02:30 2:50 BHA PN Continue to PU /MU BHA #11 components, (Geo -Pilot Type), & initialize MWD system. Assembly RIH & shallow pulse tested, (OK), w /150gpm= 620psi. PJSM was held, and pulled back up & loaded MWD Nuke sources. Once all clear sign given, continued to PU /MU rest of components, 155' -411', w /PuWt= 55K & SoWt= 50K 02:30 11:00 8.50 TRIP PN RIH w /BHA #11, (8 -3/4" Geo -Pilot Type), 411'- 11,060', filling pipe as required, (break circulation short to warm MOBM mud also), circulating 60 BBL's every 30 std's RIH. PuWt= 215K, SoWt= 100K 11:00 11:30 0.50 CIRC PN Break circulation @ 11,060', and establish parameters, w /200gpm= 2,475psi @ 24% flow rate, 40rpm's on TDS= 8 -9K TDS off Bottom Torque, PuWt= 218K, SoWt= 100K, RotWt= 125K 11:30 12:00 0.50 TRIP PN RIH w /BHA #11, 11,060'- 11,415' w/o incidents, PuWt= 215K, SoWt= 95K 12:00 16:00 4.00 TRIP CN Madd Pass per Geology request over Shale sections @ 180 -225 fph, 11,415'- 11,485', (Zone 2) /RIH 11,485'- 11,720', (saw slight tight spot @ 11,600'= 20 -25K Down, screwed into std. & rotate 30rpm w/o pumping & went through w/o further problems). Continue Madd Pass 11,720'- 11,790', (Nechelik), RIH 11,790'- 11,870', Madd Pass 11,870'- 11,980', (Nechelik), RIH 11,980'- 12,110', & Madd Pass 12,110'- 12,202', (Shale between Nechelik & Nuiqsut), where experienced some packing off & tight hole condition, (tryed to stick string & stalled TDS). Bled off pressure & pulled back to 12,180'. During Madd pass sections had screwed into std. as rotated @ 40- 60rpm's • on TDS for accurate data points, & pumped @ 195gpm average= 2,500psi, (no time wasted est. MWD signal, just for circulation and roll mud @ same time). 16:00 17:30 1.50 U_TH PN Establish circulation @ 12,180', but as working Dp down, only able to get 3 -5', w/o packing off seen and bleed off immediately, (max. pulled was 50K over to work up). Attempted 3 -4 times, & decision made to rack back stand, & work up 12,180'- 12,088' w/o pumping. Established full circulation w /54spm= 195gpm @ 2,600psi (23 -25% flow returns), 125rpm's on TDS, w/10-11K off Bottom Torque, PuWt= 225K, SoWt= 85K, & RotWt= 138K. Worked stand while circulating 3,500 strokes, (1x BU), & medium amount of Sand fines across shakers. • 17:30 19:30 2.00 U_TH PN Continue with Mad Pass F/ 12,180' to 12,227 Pump @ 200 GPM w/ 2550 psi and 80 RPM. Started packing off at 12,227' and experienced 13.5 ECD spike. Continue working thru tight spot and resume Mad Pass F/ 12,227' to 12,340' 19:30 21:00 1.50 U_TH PN Wash and Ream F/ 12,340 to 12,380' using 200GPM w/ 2550 Psi and 100 RPM. Started Packing Off @ 12,380'. Work thru tight spot F/ 12,380' to 12,387'. Resume washing and Reaming F/ 12,387' to 12,547'. Started Packing Off @ 12,547'. Work thru tight spot F/ 12,547' to 12,558'. Resume washing and Reaming F/ 12,558' to 12,560' 21:00 23:30 2.50 U_TH PN Conduct last Mad Pass F/ 12,560' to 12,680' Using 200 GPM w/ 2550 psi and 80 RPM Torque 12 -14K P/U 230K, S/0 85K R/T 135K 23:30 00:00 0.50 U_TH PN Wash and Ream F/ 12,680' to 12,732'. Using 200 GPM w/ 2600 PSI and 80 RPM. Operations Report Report Start Date Report End Date 7/7/2008 7/8/2008 Start Time End Time Our (tars) Op Step Phase P/N Comment 00:00 01:30 1.50 U_TH PN Continue to Wash /Ream 12,732'- 12,930', w /200gpm= 2,460psi, 110rpm's on TDS= 1 -13K off Bottom torque, PuWt= 245K, SoWt= 90K, RotWt= 130K 01:30 05:00 3.50 STMILL PN Begin Side Track troughing procedure, w /stroking assembly 3x, 12,930'- 12,953', @ 20fph rate, w /110rpm on TDS= 11 -13K off Bottom torque, 225gpm= 3,460psi. ABI showed an -/ +.25 degree drop. 05:00 15:00 10.00 STMILL PN Time Drill @ 5 Min / 1" F/ 12,953' to 12,957' Time Drill @ 4 Min/ 1" F/ 12,957' to 12,961' Time Drill @ 3 Min /1" F/ 12,961 to 12,963' Time Drill @ 2 Min /1" F/ 12,963 to 12,966' Time Drill @ 11'/ Hr IF 12,966 to 12,978' www.peloton.com Page 35/45 Report Printed: 8/29/2008 Operations Summary Report • hibaL • Start Time End Time Dur (Mt) Op Step Phase P/N Comment 15:00 00:00 9.00 DRLG PP Drilling F 12,978' to 13,021'. Control drill at 31' /hr, Taking Surveys at 45' intervals due to 9 degree DLS .Drill F/ 13,021' to 13,119' and monitor and Mitigate Shock and Vibrations, Drill F/ 13,119' to 13,210' Geo Pilot tool face is changing on it's own, Trouble shoot while drilling. Pumping at 235 GPM w/ 3458 PSI, RPM =115, Torque= 10 -12K ART =8.64 ADT =8.64 P/U 245K, S/O 84K, R/T 135K Operations Report Report Start Date Report End Date 7/8/2008 7/9/2008 Start Time End Time Dur (hrs) Op Step Phase PIN Comment 00:00 12:00 12.00 DRLG PP Drill 6 -1/8" Lateral Hole Section, 13,210'- 13,658', w /230gpm= 3,225psi, 135rpm's= 11 -12K off Bottom /12 -15K on Bottom Torque. PuWt= 270K, SoWt= 77K, RotWt= 128K. WOB= 11 -15K, ADT= 8.18hrs, TADT= 23.26hr, Jar= 72.32hrs, (no losses experiences). 12:00 00:00 12.00 DRLG PP Drill 6 -1/8" Lateral Hole Section, 13,658'- 14,197', w /230gpm= 3,225psi, 135rpm's= 11 -12K off Bottom /12 -15K on Bottom Torque. PuWt= 280K, SoWt= 75K, RotWt= 130K. WOB= 11 -15K, ADT= 8.64hrs, TADT= 31.90hr, Jar= 80.24 hrs, (no losses experiences). Report Start Date Report End Date 7/9/2008 7/10/2008 Start Time End Time 1 Ow (Mrs) Op Step Phase PIN Comment 00:00 12:00 12.00 DRLG PP Drill 6 -1/8" Lateral Hole Section, 14,197- 14,596, w /230gpm= 3,230psi, 135rpm's= 12 -13K off Bottom /12 -15K on Bottom Torque. PuWt= 285K, SoWt= 60K, RotWt= 125K. WOB= 11 -15K, ADT= 8.2hrs, TADT= 40.57hr, Jar= 89.63 hrs, (no losses experiences). 12:00 12:30 0.50 RIGSER PP Service Top Drive System and associated rig equipment. 12:30 00:00 11.50 DRLG PP Drill 6 -1/8" Lateral Hole Section, 14,596' to 15,161', w /230gpm= 3,500psi, 135rpm's= 12 -13K off Bottom /16 -17K on Bottom Torque. PuWt= 285K, SoWt= 60K, RotWt= 125K. WOB= 10-11K, ADT= 8.09hrs, TADT= 48.66hr, Jar= 97.72 hrs, (no losses experiences). Report Start Date Report End Date 7/10/2008 7/11/2008 Start Time L End Time Dur (hrs) Op Step Phase P/N Comment 00:00 12:00 12.00 DRLG PP Drill 6 -1/8" Lateral Hole Section, 15,161' to 15,658', w /230gpm= 3,450psi, 135rpm's= 14K off Bottom /16 -18K on Bottom Torque. PuWt= 305K, SoWt= 40K, RotWt= 128K. WOB= 8 -13K, ADT= 8.45hrs, TADT= 57.11 hrs, Jar= 106.17hrs, (no losses experiences). 12:00 19:30 7.50 DRLG PP Drill 6 -1/8" Lateral Hole Section, 15,658' to 15,942', w /230gpm= 3,520psi, 135rpm's= 15K off Bottom /16 -18K on Bottom Torque. PuWt= 305K, SoWt= 40K, RotWt= 130K. WOB= 8 -13K, ADT= 5.29hrs, TADT= 62.40hrs, Jar= 111.46hrs, (no losses experiences). Had hard sections f/15,722' -725' & 15,768' -773'. 19:30 22:30 3.00 U_DIR PN Had communication error with down linking from geo pilot. Work on getting geo pilot communication back. Changed out choke on geo span, then pulled up hole 190' and re- established communication, increased down link thresh hold limit. Ran back to bottom with successful communication, go back to drilling. 22:30 00:00 1.50 DRLG PP Drill 6 -1/8" Lateral Hole Section, 15,942' to 16,000' w /230gpm= 3,550psi, 135rpm's= 14K off Bottom /16 -18K on Bottom Torque. PuWt= 310K, SoWt= 40K, RotWt= 130K. WOB= 8 -13K, ADT= 1.00hrs, TADT= 63.40hrs, Jar= 112.46hrs, (no losses experiences). Report Start Date Report End Date 7/11/2008 7/12/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 00:30 0.50 DRLG PP Drill 6 -1/8" Lateral Hole Section, 16,000' to 16,044' w /230gpm= 3,480psi, 135rpm's= 16K off Bottom /18K on Bottom Torque. PuWt= 315K, SoWt= 40K, RotWt= 128K. WOB= 8 -13K, (no losses experiences). 00:30 01:00 0.50 U_MWD PN Had to PU off bottom & reciprocate string while Mode switching MWD to set Theshold value in upper limits, (took on first attempt). 01:00 12:00 11.00 DRLG PP Drill 6 -1/8" Lateral Hole Section, 16,044' to 16,440' w /230gpm= 3,485psi, 135rpm's= 15K off Bottom /18 -19K on Bottom Torque. PuWt= 320K, SoWt= 40K, RotWt= 125K. WOB= 8 -13K, ADT= 7.81 hrs, TADT= 71.21 hrs, Jar= 120.27hrs, (no losses experiences). www.peloton.com Page 36/45 Report Printed: 8/29/2008 Operations Summary Report Start Time End Time Our (hrs) ' Op Step Phase P/N Comment 12:00 15:30 3.50 U_MWD PN Experience MWD signal detection problems @ 16,440', & unable to • communicate w /same. Pull off bottom & attempt several different senario's, including 260 - 265gpm= 4,500- 4,580psi, 65- 13Orpm's on TDS= 17 -19K off Bottom torque, & racked back a stand every 1 hr. While shutting down to rack stand back, attempt to bleed off pump quickly @ + /- 1,000psi, flow back string. When bringing up pump, again brought quickly up to attempt shock to system, but although gotten small pulse, could also be same frequency noise. After circualting 3.5x BU, decision was made to back ream Lateral section & POOH for MWD tool failure. During attempts w /higher flow rate, at the 265gpm, well bore taking fluid & 9 BBL's total were lost to fm. The well bore was able to substain the 250gpm max., and a couple small attempts again saw slight losses & pump backed down. 15:30 00:00 8.50 U_MWD PN POOH back reaming through lateral section to 12,458'. 130 RPM =18.5K torque, 230 GPM = 2,500 -3,000 PSI, UpWT /Rot= 150 -175K. Hole good, no problems. (No losses experienced). Operations Report Report Start Date Report End Date 7/12/2008 7/13/2008 Start Time End Time Our (hrs) Op Step Phase l P/N Comment 00:00 04:30 4.50 U_MWD PN POOH back reaming f/12,571' to 11,088' @ 226 GPM= 3200 PSI, 140 RPM= 13K torque. Tight at 11,550' to 11,527', over pull of 30K & 19K torque. POOH f/11,088' to 11,026'. Had to work BHA several times to get top stabilizer to • enter 7" casing shoe. 04:30 06:30 2.00 CUTDL PN Circulate @ 250 GPM =3400 PSI, 125 RPM= 8K torque for 1000 stks. Continue to circulate, set slips, Slip & cut drilling line while completing BUx 2 and pumping a 30 bbl /12.0 ppg dry job. Observe well, static. Blow down TDS and Geo Span. 06:30 16:00 9.50 U_MWD PN POOH f/ 11,026' to 2,824'. Hole swabbing first 1000'. Noticed excessive wear on box/pin ends of 4" DP f /4000' to 2824', flag joints, LD joint # 72, PU replacement. Continue to lay down 11 more joints out of string + 2 good joints to get on even stand. Stand back HWDP & flex collars. 16:00 20:00 4.00 U_MWD PN Held PJSM for BHA & Nukes. Remove Nuke sources, Download tools. Lay down all BHA /break off bit. (Removed Geo Span unit and replaced w /new and also put Sperry gang box on top motor shed using crane simultaneously) Note: No excessive or large debris found in MWD tool. 20:00 00:00 4.00 BOPS PP RU & pull wear ring, set test plug, fill hole w /water and testing BOPE's & choke to 250/2500 psi on Annular, 250/3500 psi on BOP & choke. John Crisp w /AOGCC witnessing. Report Start Date Report End Date 7/13/2008 7/14/2008 Start Time End Time Our (hrs) Op Step Phase P/N Comment 00:00 03:00 3.00 BOPS PN Continue to test BOPE per AOGCC requirements, (John Crisp present to witness for State). All test were 250psi low /3,500psi High & held for 5min's, (charted same). Accumulator system was function tested w /3,000psi operating & 25sec's for 200psi charge, & 1 min /33sec recharge, (5x N2 bottles= 1,750psi), RD test equipment & chart. 03:00 04:00 1.00 BOPS PN Pull test plug & set wear ring, (RILDS), wNetco Gray Representative, (LD all test joints & plugs). 04:00 08:30 4.50 BHA PN PU & MU BHA #12, (6 -1/8" Geo Pilot type), & re -run bit #7, (FMF 3641). Run fresh 5200series Geo Pilot & MU MWD components accordingly. Initialize MWD probe & set time limit, (10hrs). PJSM held & loaded Nuke sources into carriers. All clear given & continued to MU BHA #12, while RIH to +/ -319'. Shallow pulse test w /200gpm= 1,000psi (ok), & break in Geo Pilot seals w /5- 60rpm's, brought up @ 5rpm's per min. Continue to RIH w /BHA #12 to 412' w /std from Derrick. NOTE: Drill pipe screen installed in top of Non Mag flex collar & Ball catcher. 08:30 12:00 3.50 TRIP PN PU & RIH w/39 jt's of replacement DP, to C -O flat sided damaged DP on previous run. Pipe was drifted & rattled, prior to adding to string. TIH f/1,666' to 3,307' and fill pipe. LD 6 bad joints. 12:00 19:00 7.00 TRIP PN TIH f/3,307' to 9,083' filling pipe every 3,000', (circulated 60 BBL's @ each fill up station to ensure MWD working & to roll mud in hole). www.peioton.com Page 37/45 Report Printed: 8/29/2008 • Operations Summary Report Start Time End Time Dur (hrs) Op Step Phase P/N 7 Comment 19:00 22:30 3.50 U_RIG PN Swivel packing started leaking when filling DP. Greased and tightened, still leaking. Decision made to change out swivel packing and tested same, (OK). 22:30 00:00 1.50 TRIP PN Continue to TIH f/9,083' to 10,350'. UPwt= 150K, SOwt =115K. Operations Report Report Start Date Report End Date 7/14/2008 7/15/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 02:00 2.00 TRIP PN Continue to TIH f/10,350' to 12,070', before running out usable push Wt. w /the assembly. PuWt= 225K, SoWt =100K. Assembly took 50K down @ 12,070', & becoming neccessary to rotate to get down. 02:00 09:00 7.00 RMCLN PN Wash & ream in the hole (/12,070' to 16,433' @ 60 spm/ 200 gpm= 2500 psi, 60 rpm = 8 -10K torque. Rot Wt= 140K. 09:00 10:30 1.50 CIRC PN Circulate bottoms up @ 230 gpm =3600 psi, 120 rpm = 14 -17K torque while reciprocating pipe. 10:30 00:00 13.50 DRLG PP Drilling 6 1/8" Lateral hole section, f/16,440' to 17,108' @ 230gpm = 3550psi, 120 rpm's on TDS= 16K off /17 -19K on Bottom Torque. PuWt= 320K, SoWt= 40K, RotWt= 125K. ADT= 9.45hrs, TADT= 9.45hrs, Jar Hrs= 129.72hrs. Serviced TDS & greased wash pipe packing on connection. Losses experienced @ 3 -4 BPH= 1.1% Flow ratio. Total Losses for Lateral section= 24 BBL's. Report Start Date Report End Date 7/15/2008 7/16/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 12:00 12.00 DRLG PP Drilling 6 1 /8" Lateral hole section, (/17,108' to 17,619' @ 215- 230gpm = 3,200- 3,550psi, 120 rpm's on TDS= 17K off /19 -20K on Bottom Torque. PuWt= 325K, SoWt= 40K, RotWt= 130K & WOB= 8K. ADT= 9.41hrs, TADT= 18.86hrs, Jar Hrs= 139.13hrs, ECD's= 12.7- 13.1ppg EMW max. Having to steer Geo Pilot down @ 50 -90% deflection rate to keep from bouncing up, & maintain 6,160'- 6,161' TVD, until 17,622', where hard streak pinched off & assembly dropped below, (losses increased to 12 BPH rate & cut flow to 200- 215gpm rate to reduce ECD & loss rate to 8 BPH). Losses experienced @ 4 -12 BPH= 1.3-4.1% Flow ratio. Losses for Tour= 74 BBL's, & Total Losses for Lateral section= 98 BBL's. 12:00 00:00 12.00 DRLG PP Drilling 6 1/8" Lateral hole section, f/17,619' to 17,978' @ 215gpm = • 3,200psi, 120 rpm's on TDS= 17K off/19 -20K on Bottom Torque. PuWt= 325K, SoWt= 40K, RotWt= 135K & WOB= 8K. ADT= 9.86hrs, TADT= 28.72hrs, Jar Hrs= 149.19hrs., ECD's= 12.7ppg EMW max. Losses experienced @ 4 -12 BPH= 1.3 -4.1% Flow ratio. Losses for Tour= 66 BBL's, & Total Losses for Lateral section= 164 BBL's. Report Start Date Report End Date 7/16/2008 7/17/2008 Start Time End Time Dur (Ms) Op Step Phase L P/N Comment 00:00 09:00 9.00 DRLG PP Drillin 6 1/8" Lateral hole section, f/17,978' to 18,364' @ 215gpm = 3,300psi, 120 rpm's on TDS= 18 0 on o om Torque. PuWt= 330K, SoWt= 40K, RotWt= 130K & WOB= 8 -10K. ADT= 6.68hrs, TADT= 35.4hrs, Jar Hrs= 155.67hrs., ECD's= 12.76ppg EMW max. Losses experienced @ 2 -8 BPH= .65 -2.6% Flow ratio. Well Bore called "TD" CO 18,364' by Geology in Town. 09:00 16:00 7.00 CIRC PP Circulate & reciprocate string for 22,000 strokes= 4.5 Bottoms up. Shakers appeared clean & decision made to Back Ream out lateral section made, (per procedure). While circulating, approx. 90 min's per Bottoms up & rack back 1 std. for every bottoms up. PuWt= 325K, SoWt= 40K, RotWt= 130K, w /12Orpm's on TDS= 18K off Bottom torque. Flow rate was 215- 230gpm= 3,250- 3,340psi, w/1 -2 BPH= .65% Loss Ratio. 16:00 00:00 8.00 TRIP PP Back Ream out of Lateral section f/18,267' to 14,298' pumping @ 200 gpm= 3,000psi & 12Orpm's on TDS= 19K off Bottom torque. PuWt= 280K, SoWt= 40K, RotWt= 120K. Jar Hrs= 155.7, TADT= 35.4. No problems were encountered Report Start Date Report End Date 7/17/2008 7/18/2008 www.peloton.com Page 38/45 Report Printed: 8/29 /2008 • Operations Summary Report 40 Stan Time . End Time Our (his) 1 OP Step Phase P/N Comment 00:00 06:00 6.00 TRIP PP Back Ream out of Lateral section f/14,298' to 11,026' pumping @ 140gpm= 1,560psi & 12Orpm's on TDS= 14 -6K off Bottom torque. PuWt= 115K, SoWt= 110K, RotWt= 110K. Jar Hrs= 155.7, TADT= 35.4. Problems were encountered € 11,709' where Top stabilizer was across Fault @ 11,600', and spike in TDS torque saw T9:5 +FKtorque. This causediailure in top of Std. #23, (Found failed once out of Hole). Continue to Pump & rotate to expected bit depth of 11,026', (actually +/- 8,429' Failed Dp depth). 06:00 08:00 2.00 CIRC PP CBU lx @ 230gpm= 1,270psi, increase pump & CBU @ 375gpm= 2,600psi 2x w /steady cuttings stream decreasing on second bottoms up. Reciprocate & rotate @ 12Orpm's on TDS= 6K off Bottom torque, PuWt= 115K, SoWt =110K, RotWt =110K. 08:00 16:00 8.00 TRIP PN Pump Dry job & flow check well bore 5 min's, (static). POOH on elevators w/o issues & correct hole fill. Pulled to Top of std #32 & had to LD 7jts (std. #32 -31 -Top single #30), racked back double of std #30 +29 +double of std. #28, (PU single to rack back std.). LD Bottom single of std #28 +2x jts of std. #27, (wash /cracked), +Top single of std. #26= 4 jts. Rack back Bottom 2x jts OT sta. #2b -F25+ i op single std. #24, LD B. 2x singles of std #24= 2 jts, for total of 13jts. Box of Top single on std. #23 missing 3.5 ", that failed & on pin on bottom of std. #24. Of 3.5 ", (Total average box length= 16 "), so approx. 12.5" is left to shallow of worn, (4 -3/8" OD), top single of std. #23. This figured on the,11,780'- 11,709' incident event= Fish top @ approx. 9,148- 9,077', (inside casing) w /approx. 72 degree inclination. 16:00 18:30 2.50 U_WT PN Waiting on fishing tools to arrive f/ Deadhorse. PU & MU 9 joints of 4 3/4" spiral DC's and stand back in derrick. 18:30 00:00 5.50 TRIP PN Load over shot w/ 4 3/8" grapple & PU & MU Fishing assembly w/ 3 stds DC's. TIH to 884' strapping DP and also culling and laying down questionable joints w/ excessive wear. (33 jts). UpWt =60K, Dn Wt =60K. Operations Repo Report Start Date Report End Date 7/18/2008 7/19/2008 Start Time End Time Our (hrs) Op Step Phase P>N Comment 00:00 05:00 5.00 TRIP PN TIH f/ 884' to 8,990' SLM each stand. (LD 3 bad Jts DP). 05:00 06:00 1.00 U_FSH PN Washing in the hole f/8,990' to 9,028' @ 123 gpm= 800psi. Pu Wt= 170K, So Wt =100K. Tagged top of fish @ 9,028'. Egage top of fish setting 25 K DN, w/ psi increase of 400 psi. Circulate ensuring full flow and start pulling on fish in slow increments up to 230K over pull. Slack off increasing pump rate to 200 gpm= 2,000 psi and start pulling slowly again to 240K over pull and fish coming free. 06:00 07:30 1.50 U_FSH PN POOH w/ Fish f/ 11,628' to 10,940' @ 200 gpm =2,000 psi. Pu Wt =210K. Hole taking proper amout of fluid. 07:30 09:00 1.50 U_FSH PN Drop Dart and circulate @ 150 gpm = 1,600 psi, shear and open circulating sub @ 1,700 psi. CBU @ 350 gpm= 2,900 psi. POOH f/10,940' to10,743', Monitor well 5 minutes and pump dry job. 09:00 12:00 3.00 U_FSH PN POOH f/ 10,743' to 5,414'. PuWt =150K. Hole taking proper fill. 12:00 22:00 10.00 U_FSH PN POOH f/5,414' to 3,034' w /100K UpWt. LD 3 Jts DP & BHA DC's /fishing assembly /top fish. LD bad DP for a total of 32 jts f/2,610' to 1,570'. 1 Jt had open crack 3/4 of the circumference of the TJ. (Total bad jts LD today =35) 22:00 00:00 2.00 U_FSH PN POOH f/1,570' to 570' racking back 13 good stands DP. UpWt =70K. LD BHA HWDP, Jars. 1 jt HWDP cracked on pin end. Report Start Date Report End Date 7/19/2008 7/20/2008 Start Time j End Time Our (hrs) Op - Step Phase P/N Comment 00:00 04:30 4.50 U_FSH PN LD fished BHA #11. Hold PJSM, LD circulating sub /ball catcher & flex collars. Pull nuke sources. CD stabilizer /float sub. Down load MWD /LWD. LD BHA, PWD and pull up & beak off bit and LD rest of BHA smart tools and examine for erosion damage. 04:30 05:30 1.00 U_FSH PN PU oil jars f/ pipe shed w/ lifter MU on it and break out lifter and LD. PU overshot w/ fish and break out and LD fish and overshot. 05:30 07:00 1.50 CSG PP Clean up rig floor and PU 4 1/2" liner tools and prepare to run liner. www.peloton.com Page 39/45 Report Printed: 8/29 /2008 :: Operations Summary Report Start Time] End Time Dar (hrs) - Op Step Phase P/N Comment 07:00 10:30 3.50 CSG PP MU wire line entry guide(shoe) to first jt of slotted 4 1/2" liner w/ stop ring in middle and a turbolizer on both sides. MU and run rest of liner per plan,shoe =1.00, 3 slotted= 125.01', 18 solid= 713.57', 14 slotted= 582.52', 1 solid =39.52 for a total of 1462.06' w/1 turbolizer on each jt. MU Packer w/ tie back sleeve & hanger and XO w /7" razorback scraper assembly per plan. 10:30 14:00 3.50 TRIP PP RIH f/1,595' to 3,644' w/ 4" DP drifting & SLM each stand. UpWt =90K, DnWt =80K. 14:00 17:30 3.50 CUTDL PP Slip & cut 157' of drilling line. 17:30 18:00 0.50 RIGSER PP Service TDS and rest of rig components. 18:00 00:00 6.00 TRIP PP TIH f/3,644' to 8,737' w/ 4" DP rabbitting & SLM each stand. UpWt =165K, DnWt =100K. Operations Report Report Start Date Report End Date 7/20/2008 7/21/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 04:30 4.50 TRIP PP RIH 4 1/2" liner on 4" DP f/8,737' to 12,416' drifting & SLM each stand. PuWt =220K, SoWt =100K. 04:30 06:00 1.50 TIEBCK PP Drop Ball and PU single and MU TDS and stage in 10' on single. Pump ball down @ 20 stks /min =72 gpm =650 psi. Ball seated @ 972 stks when psi increased to 1200 psi, continue to pressure up to 2000 psi and set hanger. Then pressured up to 2700 psi to shear collett on running tool. Attempt to pull out of tie back, unsuccessful. Packer moved up hole 5' f/ 10,936' to 10,931'. Work string multiple times to pull running tool out of tie back. Apply two left hand rotation on DP. Work torque down to release. Picked up out of tie back 6', then slack off and tag up at 10,931'. Worked pipe multiple times to verify liner top @ 10,931. Apply 60K down to set packer. Purr up comltiCnCe [Aria displacement. 06:00 09:30 3.50 DPLACE PP Prepare to displace well by mixing spacers/ clear rig floor of running equipment. Pump 23 bbls Barakleen spacer, 40 bbls Barascrub spacer, 23 bbls of Barakleen spacer then chase with 367 bbls of 10.2 brine @ 210 -450 gpm= 1600- 3250 psi. 09:30 14:00 4.50 TRIP PP POOH laying down DP f/10,931' to 7,161', UpWt =210K, DnWt =95K. 14:00 15:00 1.00 U_RIG PN Repair hydraulic hose on pipe skate. No spill, all contained & cleaned up. 15:00 00:00 9.00 TRIP PP POOH laying down DP f/7,161' to running tools. Lay down razor back scraper and pull up and discovered liner was still connected. Got well site leader up and called town engineer and discussed the situation. Agreed to proceed LD liner to test BOPE's and get another Hanger /Packer assembly f /Prudhoe coming. Report Start Date Report End Date 7/21/2008 7/22/2008 Stara Time End Time j Dar (hrs) j Op .. Step Phase P /Ar Comment 00:00 05:30 5.50 U_OTR PN Had discussion w/ town engineer & well site leader about liner, agreed to LD liner. PU casing tools to LD 4 1/2" liner & hanger /packer assembly. BO & LD liner inspecting & saving each centralizer. Had tong hang up on 1 solid jt and egged, LD and exchanged. Swapped out tongs and finished LD rest of liner. All centralizers accounted for and in good shape. LD tools and clean up floor for BOPE test. 05:30 09:00 3.50 U_OTR PN PU test jt, pull wear ring, set test plug w/ Vetco Grey represenative.Test BOPE's to 250/2,500 psi on annular, 250/3,500 psi on both 4" pipe rams, blind rams, Manual and HCR valves on mud cross. Pull test plug/ set wear ring RILDS. LD testing equipment clean rig floor. 09:00 10:00 1.00 RIGSER PN Service TDS, change out gear oil. Service rest of rig. 10:00 13:30 3.50 U_OTR PN PU /RU casing tools and run 36 jts of 4 1/2" liner w/ centralizers on each jt and two on shoe jt w/ stop ring in middle of jt. Liner weight =15K, UpWt =55K, DnWt =50K. 13:30 00:00 10.50 U_OTR PN MU XO in top of liner to XT -39. PU/ MU/ RIH w/31 jts DP f/ pipe shed drifting each joint. POOH and stand back 10 stds leaving single DP to work from for next set of 30 jts. Continue process until PU and stood back 54 stds for a total of 105 stds in derrick. PuWt =75K, SoWt =70K w/ 31 jts DP & Liner. Report Start Date Report End Date 7/22/2008 7/23/2008 Start Time End Time Our (hrs) Op ' Step Phase PM Comment 00:00 00:30 0.50 U_OTR PN Finish racking back remaining stands of DP in derrick for a total of 105 stands in derrick. Clear Floor. www.peloton.com Page 40/45 Report Printed: 8/29 /2008 40 C e Operations Summary Report 0 Start Time 1 End Time Our (hrs) - Op Step 1 Phase 1 P/N Comment 00:30 02:00 1.50 U_OTR PN Start assembly of hanger /packer in pipe shed, while rigging up rig floor w /casing tongs. PU hanger /packer assembly on elevators and MU ball catcher, stab into liner & MU and torque connections. RIH and fill top of tie back sleeve w/ water /polymer mixture while LD casing tongs. PU bumper jars, MU. SLM DP stands & RIH. UpWt= 55K, SoWt =50K, Liner Wt =15K. 02:00 11:00 9.00 U_OTR PN Continue to RIH SLM each stand to 12,366'. PU 2 singles, drop ball & MU TDS. • 11:00 12:00 1.00 U_OTR PN Drop setting ball & circulate down. Set Hgr. w/ 1,000 psi., Shear Pkr. release w/ 2,500 psi., Open circulating sleeve w/ 3,500 psi., P/U 6' & set down on liner top to set Pkr. w/ 30k Dn Wt. (observed Pkr. setting pins shear @ 15K Dn Wt). Liner top @ 10,937'. P/U 6' & reset Wt Dn 30K to confirm liner set. • P/U 90' (observed 15K P/U Wt. loss, 255k original P/U Wt., 240K after liner release) & clear running tool f/ tie -back. S/O and tag liner top @ 10.937'. 12:00 14:00 2.00 U_OTR PN LD 3 jts DP and circulate & condition brine 2x BU @ 85 spm= 302 gpm= 1200 psi. UpWt =240K, DnWt =110K. 14:00 00:00 10.00 U_OTR PN POOH LD DP & HWDP f/10,841 to 2,431'. UpWt =90K, DnWt =80K. Hole fill OK. . Operations RepOrt • Report Start Date Report End Date 7/23/2008 7/24/2008 Start.Time End Time Dur (hrs) [ Op Step - Phase P/N Comment 00:00 03:30 3.50 DPIPE PP Lay down Drill pipe remaining 2,431' of Drill Pipe. 03:30 04:30 1.00 DPIPE PP UD Bumper Jars and running tool, Clear Rig Floor. 04:30 05:00 0.50 BOPS PP R/U and Remove Wear Bushing 05:00 05:30 0.50 BOPS PP M/U Test Tools and set test plug. 05:30 07:00 1.50 BOPS PP _ Change out upper rams F/ 4" to 2 7/8" 07:00 09:00 2.00 BOPS PP Test upper rams to 250 low and 3500 high. Attempt to test Annular, Test failed. Pull Test joint and found that is was bent, Pull test plug and P/U Riser washing tool. 09:00 09:30 0.50 U_RIG PN Circulate riser clean using 425 gpm at 100 psi 09:30 10:30 1.00 U_RIG PN UD Riser washing tool, M/U new test joint and set test plug, attempt to test Annular again, Test Failed 10:30 11:00 0.50 U_RIG PN UD Test tool, Drain Stack and inspect Annular and found it was bad, Install test plug. 11:00 12:00 1.00 U_RIG PN Hold PJSM on Annular removal, Pull Riser, Clean Out Drip pans, Remove Turnbuckels, Remove Koomey hoses and fittings. 12:00 18:30 6.50 U_RIG PN Change out Annular Perventors 18:30 19:30 1.00 BOPS PP Test Annular Perventor against 2 7/8" Tubing 250 low 2500 high, Retest 2 7/8" rams to 250 low and 3500 high, Held both tests for 5 min. 19:30 20:30 1.00 BOPS PP UD Test tool and Test Plug. 20:30 00:00 3.50 TUBING PP R/U Tubing handling equipment, ESP control lines and Sheaves, SCSSV control lines and Sheaves. P/U ESP pump and start servicing same. Report Start Date Report End Date 7/24/2008 7/25/2008 Start Time End Time Our (hrs) ' Op Step Phase P/N Comment 00:00 06:30 6.50 TUBING PP Service ESP Downhole Pump, Finish hanging Control Line Sheaves, Install control line and clamps. I est tSP and Control Lines. Install XN Nipple and Install Sliding sleeve and run in the closed position. 06:30 19:30 13.00 TUBING PP Run ESP completion on 2 7/8" tubing,Test cable every 1000' and install Cannon clamps on every Joint. RIH F/ 63' to 6,300'. Installed GLM w/ dummy @ 1609' 19:30 22:30 3.00 TUBING PP Install WFT Hydro II Dual Packer F/ ESP along with X Nipple and RHC Plug below Packer and X. Nipple Above Packer. Splice control cable and test same to 5000 psi, Cycle Test ESP Vent Valve. RIH w/ 4000 PSI on Control Line 22:30 00:00 1.50 TUBING PP Resume RIH w/ 2 7/8" ESP Completion F/ 6,300' to 6,825', Testing Cable every 1000' and install Cannon Clamps on every other Joint. Report Start Date Report End Date 7/25/2008 7/26/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 02:00 2.00 TUBING PP RIH w/ 2 7/8" Tubing F/ 6,816' to 7,814' 02:00 03:30 1.50 TUBING PP Change out ESP Spool and RIH F/ 7,814' to 8,061' 03:30 07:00 3.50 TUBING PP Stop at 8,061' and Splice ESP cable and test. www.peloton.com Page 41/45 Report Printed: 8/29/2008 Operations Summary Report • Stan Time End Time Dur (hrs) Op Step Phase P/N Comment 07:00 10:30 3.50 TUBING PP RIH W/ ESP Completion F/ 8,061' to 10,045', Testing cable every 1,000 feet. 10:30 11:00 0.50 TUBING PP P/U and install SCSSV Valve, Test to 5000 psi for 10 min. RIH with 5000 psi on Line. 11:00 12:00 1.00 TUBING PP RIH W/ ESP Completion F/ 10,060' to 10,484 ", Testing ESP cable every 1,000 feet. installing Cannon Clamps Every other Joint. 12:00 12:30 0.50 TUBING PP RIH W/ ESP Completion F/ 10,484' to 10,757', Testing ESP cable every 1,000 feet. installing Cannon Clamps vE ether Joint. 12:30 13:00 0.50 TUBING PP P/U Hanger and Landing Joint 13:00 15:00 2.00 TUBING PP Cut ESP Cable and attach same to the wellhead, R/D ESP Cable 15:00 16:00 1.00 TUBING PP Land Han er, Run in Lock down Screws, Test seals to 5000 psi for 10 min. ota c amps run 18 , with tree an s 16:00 18:30 2.50 RURD PP L/D Running tool, Secure floor, remove Sheaves from Derrick 18:30 20:30 2.00 RURD PP Change out Upper and Lower Rams to 5" 20:30 00:00 3.50 RURD PP Nipple Down BOP's, Well Head and Riser. Operations Report Report Start Date Report End Date 7/26/2008 7/27/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 01:00 1.00 RURD PP Test SCSSV Line to 5000 psi for 10 Min, OK. Test Packer Vent to 5000 psi for 10 Min, OK 01:00 06:30 5.50 RURD PP N/U Tree and Test to 5000 PSI, OK 06:30 07:30 1.00 RURD PP R/U U -Tube Manifold and test to 4000 PSI, OK 07:30 08:30 1.00 DPLACE PP Reverse Circulate 85 BBL of 10.2 Brine w/ Corrosion Inhibator at 2.5 BPM w/ 1375 PSI, Taking Returns to the Pits. Lost 60 BBLs while pumping Brine 08:30 09:30 1.00 DPLACE PP Reverse Circulate 70 BBL of Diesel for Freeze Protection at 2.0 BPM w/ 1475 PSI. Shut down pump and line up to U -Tube. Lost 50 BBLs while pumping Diesel 09:30 10:00 0.50 DPLACE PP Attempt to U -Tube, U -Tubed very slowly if at all, operation not succeful. 10:00 11:00 1.00 DPLACE PP Pump 10 BBLs of Deisel down 2 7/8" tubing @ 1/2 BPM w/ 2175 PSI. Shut in well with 1,500 psi on both the Annulus and Tubing. 11:00 12:00 1.00 SLCK PP R/U Lubricator for 1 3/8" ball and Rod and drop same. 12:00 12:30 0.50 SLCK PP ^ Pressure up Tubing to 3500 psi and set packer, Frg7i for 30 Min. Bleed down pressure to 1,500 psi 12:30 20:30 8.00 U_OTR PN Pump down backside & test Pkr. w/ 3,500 psi. Slowly bleed off to 2,900 psi. _Pressure •ac up o , • • psi. 1 • ee•ing o' a 11 psi per menu e.: eed annulus pressure down to 1,400 psi. Pressure back up on tbg t/ 3,900 psi to reset Pkr. Bleed Down. Pressure up on annulus t/ 3,500 psi. Still bleeding down. Bleed Annulus pressure down to 0 psi. Pressure up on Ann to/ 3,900 psi. Tubing still bleeding down. R/U single line to annulus to pressure up. Bleed pressure down to 0 on Annulus and pressure up to 4,000 psi. Still lossing 100 psi a minute. Swap hoses to verify no surface leaks. Bleed pressure down to 0 on Annulus and pressure up to 4,500 psi. Still tossing 100 psi a minute. A total of 8 attempts were made in order to get a test. 2 20:30 00:00 3.50 U_OTR PN R/U Slick Line and hang sheaves in the Derrick, Contacted Halliburton Slick line to ship out tools needed in order to POOH. Report Start Date Report End Date 7/27/2008 7/28/2008 Stan Time End lime Dur (hrs) Op Step Phase P/N Comment 00:00 01:00 1.00 U_OTR PN Held PJSM w/ HES on Slick Line Lubricator installation. Prep Floor 01:00 04:00 3.00 U_OTR PN R/U Lubricator and Tools. Needed parts coming F/ Pruhdoe Bay. 04:00 04:30 0.50 U_OTR PN Test Lubricator to 2000 PSI, OK 04:30 06:30 2.00 U_OTR PN RIH W/ 2.313" PX Body to 4,483' and set same. 06:30 07:00 0.50 U_OTR PN POOH w/ Slick Line. 07:00 08:00 1.00 U_OTR PN Drain Lubricator and M/U P- Prong. IA Pressure =1,375 Tbn Pressure =1,170 08:00 09:00 1.00 U_OTR PN RIH with P -Prong to 4,438' and set same, POOH. 09:00 09:30 0.50 U_OTR PN Bleed Tbn pressure off to 0 psi and M/U GLM Dummy retrieving tool. Bleed IA to 0 psi, wait 5 min. close back pressure increased to 500 psi and stabilized. 09:30 11:00 1.50 U_OTR PN RIH w/ GLM Dummy Retrieving tool to 3,973'. IA Pressure= 500, Tbn Pressure= 0. Eauilize IA and Tbn Pressure, Retrieve GLM Dummy and POOH. IA Pressure= 475, Tbn Pressure= 575 www.peloton.com Page 42/45 Report Printed: 8/29/2008 • • Operations Summary Report Start Time End Time ' Our (hrs) Op t Step Phase ] P/N Comment 11:00 12:00 1.00 U_OTR PN Circulate 141 BBL's of 10.2 Brine down Tbn Displacing Diesel out of hole and take returns up the Annulus and to Pits. Pump at 3 BPM @ 400 psi. Shut down pumps IA Pressure= 0. Tbn Pressure= 0. 12:00 12:30 0.50 U_OTR PN Shut Well in and Monitor Pressure. 12:30 13:00 0.50 U_OTR PN Circulate 20 BBLs down Tbn, taking returns from IA to pits. 127 gpm 525 psi, swap lines 13:00 13:30 0.50 U_OTR PN Reverse Circulate Down IA and up the Tbn, Pump 22 BBL at 127gpm w/ 525 psi 13:30 14:30 1.00 U_OTR PN Shut well in and Monitor Pressure. IA= 100 .si, Tbn= 100 Psi. 14:30 17:30 3.00 U_OTR PN M/U GLM Dummy Running Tool and RIH to 748' , having trouble going in the hole. Pull up into Lubricator. 17:30 18:30 1.00 U_OTR PN Circulate 60 BBLs down Tbn, taking returns from IA to pits. 127 gpm 525 psi, Monitor Pressures 18:30 19:30 1.00 U_OTR PN Open Master valve and RIH w/ GLM Dummy Running Tool and blank to 3,973' and set Blank. 19:30 21:30 2.00 U_OTR PN RIH w/ Slick Line to 4,483' and Pull P -Prong and PX Plug. 21:30 22:30 1.00 U_OTR PN RIH w/ Slick Line to 4,517' and pull Rod and Ball. 22:30 23:30 1.00 U_OTR PN RIH w/ Slick Line to 4,517 and pull RSC Valve 23:30 00:00 0.50 U_OTR PN R/U Lines to test IA another Time. Operations Report Report Start Date Report End Date 7/28/2008 7/29/2008 Start Time End Time Our (hra tap Step Phase P/N Comment 00:00 00:30 0.50 U_OTR PN Pressure up IA to 1500 psi and observe, Leaking at 100 psi /min.. 00:30 05:30 5.00 U_OTR PN M/U HES Sliding sleeve Shifting tool and RIH to 10.648' and attempt to shift sleeve. Not Succesful, 05:30 06:30 1.00 U_OTR PN POOH with HES Sliding sleeve Shifting tool F/ 10,648' to surface. Add one additional weight bar to tool. 06:30 08:30 2.00 U_OTR PN M/U HES Sliding sleeve Shifting tool with additional weight bar and RIH to 10,648' and attempt to shift sleeve. Not Succesful. 08:30 09:00 0.50 U_OTR PN POOH with HES Sliding sleeve Shifting tool F/ 10,648' to surface. 09:00 10:30 1.50 U_OTR PN Annulus and Tbn Pressure reading 0. Monitor Centralift down hole pressure at pump = 3,230 PSI Open Vent valve and monitor Annulus for pressure and Flow, None. 10:30 12:00 1.50 U_OTR PN Pressure up IA with vent valve opened to 100 psi to establish communictions w/ ESP pump, 68 psi was observed at ESP pump. Bleed off pressures and monitor well. 12:00 12:30 0.50 U_OTR PN Shut ESP Vent Valve. Pressure on IA and Tbn 50 PSI. 12:30 14:00 1.50 U_OTR PN R/D Wireline, blow down lines and R/D Same. 14:00 14:30 0.50 U_OTR PN _ N/D Tree and install Back Pressure Valve. 14:30 15:00 0.50 U_OTR PN Install TST Dart in Hanger 15:00 16:00 1.00 U_OTR PN Nipple Up BOP's 16:00 16:30 0.50 U_OTR PN Change out BPV -TWC, Remove Dart 16:30 17:00 0.50 U_OTR PN Conduct Landing Joint Dummy Run. 17:00 19:30 2.50 U_OTR PN Finish Nippling up BOP's, Change out Vetco 0-Ring. 19:30 21:30 2.00 U_OTR PN Change upper and lower rams to 2 7/8" 21:30 22:00 0.50 U_OTR PN P/U Test Tools and 2 7/8" Landing Joint. 22:00 23:30 1.50 U_OTR PN M/U Test tools and TIW, cross over and Dart 23:30 00:00 0.50 U_OTR PN Test BOP's to 250 Low and 3500 High. Wittness vaived by Lou Gimaldi of AOGCC. Report Start Date Report End Date 7/29/2008 7/30/2008 Start Time End Time Dur (hrs) Op Step Phase P/N Comment 00:00 07:30 7.50 U_OTR PN Test BOP's to 250 Low and 3,500 High holding each test for 5 min. Witness vaived by Lou Gimaldi w/ AOGCC. 07:30 08:00 0.50 U_OTR PN L/D Test Tool 08:00 10:00 2.00 U_OTR PN P/U 48 Joints of 5" Drill Pipe and Rack back as a back stop for 2 7/8" Tbn. 10:00 12:00 2.00 U_OTR PN Finish R/U Spools, Sheeves and handling equipment for 2 7/8" Tbn. 12:00 12:30 0.50 U_OTR PN Pull TWC out of Hanger 12:30 13:00 0.50 U_OTR PN M/U Landing Joint 13:00 13:30 0.50 U_OTR PN Back out Lock Down Screws on Wellhead 13:30 14:00 0.50 U_OTR PN P/U and Release Packer using 30K over pull, 108K string weight, 148K with Blocks. Monitor We1f www.peloton.com Page 43/45 Report Printed: 8/29/2008 • Operations Summary Report Stan Time End Time . Dur (hrs) Op Step Phase P/N Comment 14:00 14:30 0.50 U_OTR PN Disconnect ESP Cables and Control Lines from Hanger 14:30 17:00 2.50 U_OTR PN L/D Landing Joint and Hanger. 17:00 00:00 7.00 U_OTR PN POOH w/ 2 7/8" ESP Productin String F/ 10,802' to 6,830', UO SCSSV Valve and GLIB Spooling ESP cable and Control Line, 3 Bands and 64 Clamps. Operations Report Report Start Date Report End Date 7/30/2008 7/31/2008 Start Time End Time Dor (hrs) Op Step Phase P/N Comment 00:00 02:30 2.50 U_OTR PN POOH w/ 2 7/8" Tbn F/ 6816' to 6,300', UD Single 02:30 04:00 1.50 U_OTR PN Pull Packer above Rig Floor and inspect Packer, Disconnect ESP Line, R/D Control Line and UD Packer. 04:00 04:30 0.50 U_OTR PN POOH F/ 6,300 to 6,005' P/U Wt =75K, S/O Wt =68K 04:30 05:30 1.00 U_OTR PN Change out spool on ESP Unit. 05:30 09:00 3.50 U_OTR PN Identified worn seal on Packer Vent Valve, Contact office and develop new Plan forward. Conduct Rtg"MaIr1taTTERce 09:00 11:00 2.00 U_OTR PN R/U HES Slick Line and Lubricator. Plan to Shift Slidding sleeve. Build new 10.2 Filtered Brine 11:00 11:30 0.50 U_OTR PN RIH w/ Shifting tool, hit refusal at 90', unable to work past. 11:30 12:00 0.50 U_OTR PN POOH and P/U Sample Bailer w/ Centrilizer. and RIH to Sliding Sleeve 500', pathway is clear. POOH 12:00 14:30 2.50 U_OTR PN P/U HES Shifting and RIH and Shift Sliding Sleeve open_ , POOH. 14:30 15:00 0.50 U_OTR PN R/U to Circulate 15:00 17:00 2.00 U_OTR PN Circulate and Condition Hole w/ 10.2 Brine.. Circulate at 317 GPM w/ 3150 psi. Filter brine Circulate two hole volumes and transfer 240 bbls from RSC to pits. 17:00 19:30 2.50 U_OTR PN R/U HES Slick Line and RIH and Close Sliding sleeve @ 5,940' 19:30 20:00 0.50 U_OTR PN R/D Slick Line 20:00 20:30 0.50 U_OTR PN Change out ESP Spool. 20:30 21:00 0.50 U_OTR PN R/U ESP to RIH 21:00 22:00 1.00 U_OTR PN RIH F/ 6,005' to 6,249', attaching clamps to secure ESP Cable. 22:00 23:00 1.00 U_OTR PN P/U X- Nipple w/ RHC Dressed and install same, P/U Packer assembly and test low side of vent to 5,000 psi -OK 23:00 00:00 1.00 U_OTR PN Splice ESP Cable thru packer Report Start Date Report End Date 7/31/2008 8/1/2008 Start Time End Time ' Our (hrs) Op Step Phase P/N Comment 00:00 00:30 0.50 U_OTR PN Finish splice ESP to packer penetrator and test. Test good. 00:30 01:00 0.50 U_OTR PN M/U control line to packer vent. Test packer vent valve and control line to 5000 psi for 10 min. each. Closed in 500 psi on control line to keep packer vent valve closed during running. 01:00 02:00 1.00 U_OTR PN RIH with 2 7/8" 6.5 #, L -80 tubing, ESP per Pioneer running procedure F/ 6273' To/ 6450'. Install new seal rings/ clamps every other joint. P/U Wt =72k, S /O =65k. 02:00 04:00 2.00 U_RIG PN Repair broken service loop wire on rig Top drive. Controls link tilt. 04:00 12:00 8.00 U_RIG PN TIH with 2 7/8" Tbg F/ 6450' To/ 8670'. Test ESP every 1000', LID 12 joints with damaged threads and replace with new joints off rack. P/U WT =75k, S /O =70k. 12:00 17:30 5.50 U_RIG PN Continue TIH with 2 7/8" Tbg F/ 8670' To/ 10049'. C/O seal rings, install clamps every other joint, C/O joints with bad pin threads. Test ESP every 1000', S/O 65k. 17:30 18:30 1.00 U_RIG PN M/U SCSSSV, Test 5000 psi for 10 min. 18:30 21:00 2.50 U_RIG PN TIH with 2 7/8" Tbg F/ 10093' To/ 10761', with 500 on vent line and 5000 psi on SCSSV. Change out seal rings and joints with bad pin threads. Install clamps every other joint. 68k S /O, 115 P /U. 21:00 21:30 0.50 U_RIG PN P/U Vetco Hanger and landing joint. Install 2.20 pup below hanger for clamp placement. 21:30 00:00 2.50 U_RIG PN Terminate ESP cable, allow sealant to cure and connect to hanger and test. Report Start Date Report End Date 8/1/2008 8/2/2008 Start Time End Time Dur (hrs) ' Op Step Phase P/N Comment 00:00 01:30 1.50 U_RIG PN M/U SS control lines to hanger and test same to 5000 psi. Held 5000 psi on SCSSSV line and bled vent line to 500 psi. www.peloton.com Page 44/45 Report Printed: 8/29 /2008 • Operations Summary Report Start Time End Time Dor (hrs) Op Step Phase P/N 1 Comment 01:30 02:30 1.00 U_RIG PN RIH with Hanger and land with EOT at 10806'. 344 jts 2 7/8" IBT -M, L -80, 6.5 #. Run in lock down dogs per Vetco Service Rep. Test upper and lower hanger seals to 5000 psi for 10 min each. 02:30 03:30 1.00 U_RIG PN Drop ball &rod to set packer. R/U lines and test to 3500 psi. 03:30 05:00 1.50 U_RIG PN . I Pressure u. to 3500 .si down tubin. observed •acker shift at 1200 •si. Continued to pressure up to 3500 psi and chart same for 30 min. Good test, bled off pressure. Line up and pressure up down annulus to 3500 psi and chart same for 30 min. Good test. 05:00 06:00 1.00 U_RIG PN Back out landing joint, set TWC, pull riser. 06:00 08:30 2.50 BOPS PP Nipple down drill riser and rig down 2 7/8" handling equipment, ESP sheaves. 08:30 09:00 0.50 BOPS PP Nipple down BOP, R/U & test control lines 5000 psi. 09:00 09:30 0.50 TUBING PP Run down hole pump and test ESP, OK. 09:30 10:30 1.00 BOPS PP Nipple up tree per Vetco Rep. 10:30 11:00 0.50 BOPS PP Test Tree, 5000 psi. Good test, Pull TWC. 11:00 12:00 1.00 SLCK PP R/U slick line lubricator and equipment. 12:00 17:00 5.00 CIRC PP Rig up and reverse 60 Bbls brine with inhibitor and 70 Bbls diesel. Held PJSM. Initial circ. pressure 350 psi, final circ. pressure 350 psi. @3 BPM. Tripped breaker on aggitators, stopped and reset. Pumped diesel at 2 BPM initial pressure 70 psi, final pressure 650 psi. U -tube well for 50 min. to freeze protect. 17:00 18:00 1.00 RURDRT PP Rigged up lines and blew down manifolds. 18:00 19:30 1.50 SLCK PP PJSM, Rig up slick line equipment, bleed off pressure and change out tools. 19:30 20:30 1.00 SLCK PP M/U and run Dummy, and in GLM. Ret. wire and bled lubricator down. 20:30 21:30 1.00 SLCK PP M/U retrieval tool, GIH #2 Run and retrieve ball and rod. Bled down lubricator. 21:30 22:30 1.00 SLCK PP Run #3, retrieve "RHC" plug. Bled down and remove tools. 22:30 00:00 1.50 DEMOB PP Secure well, bled down pressure and R/D slick line equipment. Secure tree for move. Rig Released at 23:49 hrs. to move to 45i. www.peloton.com Page 45/45 Report Printed: 8/29/2008 • ODSN -40 Well Status Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 2 -7/8 ", 5K, Horizontal Vent Valves Control Line 16" Conductor 153' MDrkb / 153' TVDrkb 2 -7/8" HES ScSSSV, 2.313" ID @ 748' MDrkb / 748' TVDrkb 9 -5/8 ", 40# L -80 BTC, 8.835" ID 3409' MDrkb / 2998' TVDrkb X Nipple, 2.313" ID @ 4641' MD $ II 2 -7/8" GLM @ 3972' MDrkb / 3320' TVDrkb ■ 7" x 2 -7/8" Dual ESP Packer @ X Nipple, 2.313" ID w RHC -M Profile @ 4701' MD 4501' MDrkb / 3639' TVDrkb 2 -7/8" GLM @ 9193' MDrkb / 5682' TVDrkb 2 -7/8 ", 6.5# L -80 IBT -M ESP Cable O 0 2 -7/8" Durasleeve Sliding Sleeve, 2.313" ID @ 10649' MDrkb / 6115' TVDrkb ■ Estimated Top of Cement @ 9991' XN Nipple, 2.205" ID Nogo MD / -5835' TVDrkb @ 10693' MDrkb / 6126' TVDrkb 81 degrees ESP @ 10806' MDrkb / 6154' TVDrkb 11066' MDrkb / 6219' TVDrkb 6 -1/8" Open Hole 7 ", 26# L -80 BTC -M, 6.276" ID 4-W, 12.6# L80 BTC Liner Top @ 10951' MD — — — — — Slotted Liner 10996- 11578' MD and 12290'- 12415' MD; f - Solid Liner 10956'- 10996' and' 11576- 12290' 18364' MDrkb / 6160' TVDrkb Date: Revision By: Comments 5/2/2008 JDF Proposed Completion 7/25/2008 JDP Proposed 4 -'/2" Lin 9/2/2008 KLC Actual Completion 4 ODSN -40 Producer Well Schematic PIONEER NATURAL RESOURCES llalliburton Company Survey Report Company: Pioneer Date: 8/8/2008 Time: 11:32:26 Page: 1 Field; Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well; ODSN -40, True North Site: Oooguruk ODS Vertical (TVD) Reference: RKB 57.5: 57.5 .- Weil: ODSN -40 Section (VS) Reference: Well (0.00N,0.00E,272.84Azi) Wellpath: ODSN -40 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Pioneer ASP Zone 4 Map System:US State Plane Coordinate System 1927 / Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: ODSN -40 Slot Name: 507032057100 Well Position: +N / -S - 112.21 ft Northing: 6031038.10 ft • Latitude: 70 29 45.125 N +E / -W -66.24 ft Easting : 469854.21 ft • Longitude: 150 14 47.401 W Position Uncertainty: 0.00 ft Wellpath: ODSN -40 Drilled From: OSDN -40PB2 507032057100 Tie -on Depth: 12824.11 ft Current Datum: RKB 57.5: Height 57.50 ft Above System Datum: Mean Sea Level Magnetic Data: 5/7/2007 Declination: 23.09 deg Field Strength: 57597 nT Mag Dip Angle: 80.87 deg Vertical Section: Depth From (TVD) +N / -S +E / -W Direction ft ft ft deg 44.00 0.00 0.00 272.84 1 Survey Program for Definitive Wellpath Date: 8/8/2008 Validated: Yes Version: 4 Actual From To Survey Toolcode Tool Name ft ft 100.00 821.00 ODSN -40PB1 Gyro 1 (100.00 -821. SRG- Gyro -SS Conventional SRG single shots 861.67 1050.07 ODSN -40PB1 MWD 1 (861.67 -1050. MWD +Sag +CA +IIFR +MIIIWD + Sag + CA + IIFR + MS 1105.00 1105.00 ODSN -40PB1 Gyro 2 (1105.00 -110 SRG- Gyro -SS Conventional SRG single shots 1144.97 1241.07 ODSN -40PB1 MWD 2 (1144.97 -1241 MWD +Sag +CA +IIFR +MIERND + Sag + CA + IIFR + MS 1316.00 1486.00 ODSN -40PB1 Gyro 3 (1316.00 -148 SRG- Gyro -SS Conventional SRG single shots 1530.82 5092.89 ODSN -40PB1 MWD 3 (1530.82 -8714 MWD +Sag +CA +IIFR +MIilWD + Sag + CA + IIFR + MS 5100.00 12824.11 OSDN -40PB2 MWD (5100.00- 13306. MWD +Sag +CA +IIFR +MMWD + Sag + CA + IIFR + MS 12920.87 18327.37 OSDN -40 MWD (12920.87 - 18327.37 MWD +Sag +CA +IIFR +MEWD + Sag + CA + IIFR + MS Survey _ MD 1ncl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 44.00 0.00 0.00 44.00 -13.50 0.00 0.00 6031038.10 469854.21 TIE LINE 100.00 0.39 240.43 100.00 42.50 -0.09 -0.17 6031038.01 469854.04 SRG- Gyro -SS 170.00 0.34 176.53 170.00 112.50 -0.42 -0.36 6031037.68 469853.85 SRG- Gyro -SS 259.00 0.51 244.17 259.00 201.50 -0.86 -0.70 6031037.25 469853.51 SRG- Gyro -SS 352.00 1.22 176.03 351.99 294.49 -2.02 -1.00 6031036.08 469853.20 SRG- Gyro -SS 444.00 3.18 150.68 443.92 386.42 -5.23 0.31 6031032.87 469854.50 SRG- Gyro -SS 534.00 4.23 145.82 533.73 476.23 -10.15 3.40 6031027.94 469857.57 SRG- Gyro -SS 630.00 4.11 151.15 629.47 571.97 -16.09 7.05 6031021.98 469861.19 SRG- Gyro -SS 725.00 5.18 150.70 724.16 666.66 -22.81 10.79 6031015.25 469864.91 SRG- Gyro -SS 821.00 6.17 155.13 819.69 762.19 -31.27 15.08 6031006.77 469869.16 SRG- Gyro -SS 861.67 6.00 151.94 860.13 802.63 -35.13 17.00 6031002.90 469871.07 MWD +Sag +CA +IIFR +MS 956.76 5.58 152.47 954.73 897.23 -43.62 21.47 6030994.40 469875.51 MWD +Sag +CA +IIFR +MS 1050.07 7.30 154.40 1047.45 989.95 -52.99 26.13 6030985.01 469880.13 MWD +Sag +CA +IIFR +MS 1105.00 8.81 155.76 1101.84 1044.34 -59.97 29.37 6030978.02 469883.33 SRG- Gyro -SS 1144.97 9.24 155.31 1141.31 1083.81 -65.68 31.97 6030972.30 469885.91 MWD +Sag +CA +IIFR +MS 1241.07 11.48 154.47 1235.84 1178.34 -81.32 39.31 6030956.63 469893.19 MWD +Sag +CA +IIFR +MS 1316.00 13.83 155.06 1308.95 1251.45 -96.17 46.30 6030941.75 469900.12 SRG- Gyro -SS 1391.00 16.14 154.08 1381.39 1323.89 - 113.67 54.64 6030924.22 469908.38 SRG- Gyro -SS 1486.00 21.72 149.84 1471.22 1413.72 - 140.77 69.26 6030897.06 469922.89 SRG- Gyro -SS 1530.82 21.90 149.99 1512.83 1455.33 - 155.18 77.60 6030882.62 469931.17 MWD +Sag +CA +IIFR +MS 1620.97 20.72 150.30 1596.82 1539.32 - 183.59 93.91 6030854.15 469947.37 MWD +Sag +CA +IIFR +MS 1716.07 22.89 151.41 1685.11 1627.61 - 214.45 111.10 6030823.22 469964.43 MWD +Sag +CA +IIFR +MS 1808.67 24.86 158.02 1769.80 1712.30 - 248.32 127.01 6030789.29 469980.20 MWD +Sag +CA +IIFR +MS 1904.52 25.17 159.62 1856.66 1799.16 - 286.11 141.65 6030751.44 469994.68 MWD +Sag +CA +IIFR +MS ■ • Halliburton Company Survey Report Company: Pioneer Date: 8/8/2008 Time: 11:32 :26 Page: 2 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well: ODSN -40, True North Site: Oooguruk ODS Vertical (TVD) Reference: RKB 57.5: 57.5 Well: ODSN -40 Section (VS) Reference: Well (O.00N,0.00E,272.84Azi) Wel!path: ODSN -40 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 1999.17 25.27 160.64 1942.28 1884.78 - 324.04 155.35 6030713.46 470008.23 MWD +Sag +CA +IIFR +MS 2094.61 25.61 164.07 2028.47 1970.97 - 363.10 167.77 6030674.36 470020.49 MWD +Sag +CA +IIFR +MS 2187.75 26.22 168.42 2112.26 2054.76 - 402.61 177.43 6030634.81 470029.98 MWD +Sag +CA +IIFR +MS 2283.65 29.33 173.22 2197.11 2139.61 - 446.71 184.45 6030590.69 470036.83 MWD +Sag +CA +IIFR +MS 2377.66 34.42 171.98 2276.92 2219.42 - 495.91 190.88 6030541.46 470043.06 MWD +Sag +CA +IIFR +MS 2472.90 36.80 176.68 2354.35 2296.85 - 551.07 196.29 6030486.30 470048.25 MWD +Sag +CA +IIFR +MS 2571.09 37.87 175.57 2432.43 2374.93 - 610.48 200.32 6030426.88 470052.04 MWD +Sag +CA +IIFR +MS 2667.32 39.92 176.18 2507.32 2449.82 - 670.74 204.66 6030366.60 470056.13 MWD +Sag +CA +IIFR +MS 2761.38 43.05 179.91 2577.78 2520.28 - 732.98 206.72 6030304.36 470057.94 MWD +Sag +CA +IIFR +MS 2853.73 45.19 182.07 2644.08 2586.58 - 797.25 205.59 6030240.10 470056.55 MWD +Sag +CA +I1FR +MS 2949.25 46.47 185.50 2710.65 2653.15 - 865.59 201.05 6030171.79 470051.73 MWD +Sag +CA +IIFR +MS 3043.84 47.92 186.37 2774.92 2717.42 - 934.61 193.87 6030102.80 470044.27 MWD +Sag +CA +IIFR +MS 3138.67 49.67 186.88 2837.39 2779.89 - 1005.48 185.63 6030031.98 470035.74 MWD +Sag +CA +IIFR +MS 3233.92 53.09 188.05 2896.83 2839.33 - 1079.25 175.95 6029958.25 470025.76 MWD +Sag +CA +IIFR +MS 3327.71 55.19 190.36 2951.77 2894.27 - 1154.27 163.77 6029883.29 470013.28 MWD +Sag +CA +IIFR +MS 3356.70 55.37 191.09 2968.29 2910.79 - 1177.68 159.33 6029859.90 470008.75 MWD +Sag +CA +IIFR +MS 3477.63 55.07 192.26 3037.27 2979.77 - 1274.95 139.24 6029762.72 469988.26 MWD+Sag+CA+ I IFR+MS 3573.90 55.83 195.59 3091.88 3034.38 - 1351.89 120.15 6029685.87 469968.86 MWD +Sag +CA +IIFR +MS 3668.37 55.39 197.84 3145.24 3087.74 - 1426.55 97.73 6029611.31 469946.15 MWD +Sag +CA +IIFR +MS 3763.81 54.83 197.86 3199.83 3142.33 - 1501.06 73.74 6029536.90 469921.85 MWD +Sag +CA +IIFR +MS 3858.11 54.50 197.68 3254.37 3196.87 - 1574.32 50.26 6029463.75 469898.08 MWD +Sag +CA +IIFR +MS 3952.26 53.46 199.06 3309.74 3252.24 - 1646.59 26.27 6029391.58 469873.80 MWD +Sag +CA +IIFR +MS 4048.71 53.19 200.20 3367.35 3309.85 - 1719.45 0.28 6029318.84 469847.52 MWD +Sag +CA +IIFR +MS 4144.92 53.07 201.93 3425.08 3367.58 - 1791.27 -27.38 6029247.14 469819.57 MWD +Sag +CA +IIFR +MS 4241.65 53.26 204.61 3483.07 3425.57 - 1862.38 -57.96 6029176.16 469788.70 MWD +Sag +CA +IIFR +MS 4333.84 53.24 206.01 3538.23 3480.73 - 1929.15 -89.54 6029109.52 469756.86 MWD +Sag +CA +IIFR +MS 4428.58 53.10 207.72 3595.03 3537.53 - 1996.79 - 123.80 6029042.02 469722.32 MWD +Sag +CA +IIFR +MS 4523.74 53.12 210.75 3652.16 3594.66 - 2063.19 - 160.97 6028975.78 469684.89 MWD +Sag +CA +IIFR +MS 4619.01 52.95 214.03 3709.46 3651.96 - 2127.46 - 201.73 6028911.69 469643.87 MWD +Sag +CA +IIFR +MS 4715.41 53.40 217.59 3767.25 3709.75 - 2190.01 - 246.87 6028849.32 469598.48 MWD +Sag +CA +IIFR +MS 4802.82 54.93 220.15 3818.43 3760.93 - 2245.17 - 291.35 6028794.35 469553.79 MWD +Sag +CA +IIFR +MS 4904.22 55.00 221.23 3876.64 3819.14 - 2308.12 - 345.48 6028731.63 469499.41 MWD +Sag +CA +IIFR +MS 4998.95 54.17 221.40 3931.54 3874.04 - 2366.11 - 396.45 6028673.85 469448.21 MWD +Sag +CA +IIFR +MS 5092.89 54.48 223.38 3986.32 3928.82 - 2422.46 - 447.89 6028617.71 469396.54 MWD +Sag +CA +IIFR +MS 5100.00 54.55 223.58 3990.45 3932.95 - 2426.66 - 451.88 6028613.53 469392.54 MWD +Sag +CA +IIFR +MS 5163.35 52.83 224.51 4027.96 3970.46 - 2463.36 - 487.36 6028576.98 469356.91 MWD +Sag +CA +IIFR +MS 5203.29 51.88 225.43 4052.36 3994.86 - 2485.73 - 509.71 6028554.70 469334.48 MWD +Sag +CA +IIFR +MS 5299.51 53.71 226.74 4110.54 4053.04 - 2538.87 - 564.92 6028501.79 469279.06 MWD +Sag +CA +IIFR +MS 5393.25 56.29 226.90 4164.30 4106.80 - 2591.41 - 620.91 6028449.48 469222.86 MWD +Sag +CA +IIFR +MS 5488.93 58.62 225.39 4215.77 4158.27 - 2647.30 - 679.05 6028393.84 469164.49 MWD +Sag +CA +IIFR +MS 5585.01 62.27 223.27 4263.16 4205.66 - 2707.09 - 737.42 6028334.29 469105.89 MWD +Sag +CA +IIFR +MS 5679.43 65.78 223.43 4304.51 4247.01 - 2768.80 - 795.68 6028272.82 469047.39 MWD +Sag +CA +IIFR +MS 5773.54 65.50 224.99 4343.33 4285.83 - 2830.25 - 855.46 6028211.62 468987.37 MWD +Sag +CA +IIFR +MS 5870.65 65.31 228.51 4383.75 4326.25 - 2890.74 - 919.76 6028151.40 468922.83 MWD +Sag +CA +IIFR +MS 5964.24 65.57 229.92 4422.66 4365.16 - 2946.34 - 984.21 6028096.06 468858.16 MWD +Sag +CA +IIFR +MS 6059.66 65.37 229.12 4462.27 4404.77 - 3002.70 - 1050.24 6028039.99 468791.91 MWD +Sag +CA +IIFR +MS 6154.40 65.43 227.47 4501.71 4444.21 - 3060.00 - 1114.55 6027982.95 468727.38 MWD +Sag +CA +IIFR +MS 6248.80 65.78 225.87 4540.70 4483.20 - 3118.99 - 1177.08 6027924.21 468664.61 MWD +Sag +CA +IIFR +MS 6343.84 65.86 224.37 4579.63 4522.13 - 3180.17 - 1238.51 6027863.29 468602.94 MWD +Sag +CA +IIFR +MS 6438.33 64.75 224.30 4619.11 4561.61 - 3241.57 - 1298.51 6027802.14 468542.70 MWD +Sag +CA +IIFR +MS 6532.70 65.09 225.48 4659.11 4601.61 - 3302.13 - 1358.83 6027741.84 468482.14 MWD +Sag +CA +IIFR +MS 6627.93 65.77 225.43 4698.71 4641.21 - 3362.88 - 1420.55 6027681.34 468420.17 MWD +Sag +CA +IIFR +MS H alliburton Company Survey Report Company: Pioneer Date: 8/8/2008 Time: 11:32 :26 Page: 3 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well: ODSN-40, True North Site: Oooguruk ODS Vertical (TVD) Reference: RKB 57.5: 57.5 Wen: ODSN -40 Section (VS) Reference: Well (O.O0N,0.00E,272.84Azi) Wellpath: ODSN -40 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD lncl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 6724.54 66.04 225.65 4738.15 4680.65 - 3424.65 - 1483.50 6027619.83 468356.98 MWD +Sag +CA +IIFR +MS 6813.99 66.04 225.48 4774.48 4716.98 - 3481.88 - 1541.87 6027562.85 468298.39 MWD +Sag +CA +IIFR +MS 6912.81 65.38 225.48 4815.13 4757.63 - 3545.03 - 1606.09 6027499.96 468233.92 MWD +Sag +CA +IIFR +MS 7007.83 63.59 226.31 4856.06 4798.56 - 3604.71 - 1667.66 6027440.54 468172.11 MWD +Sag +CA +IIFR +MS 7102.62 64.76 226.86 4897.35 4839.85 - 3663.35 - 1729.64 6027382.16 468109.91 MWD +Sag +CA +IIFR +MS 7198.31 64.41 226.38 4938.42 4880.92 - 3722.71 - 1792.45 6027323.05 468046.85 MWD +Sag +CA +IIFR +MS 7292.15 63.88 226.12 4979.34 4921.84 - 3781.11 - 1853.45 6027264.91 467985.62 MWD +Sag +CA +IIFR +MS 7387.84 63.66 225.92 5021.63 4964.13 - 3840.71 - 1915.22 6027205.56 467923.62 MWD +Sag +CA +IIFR +MS 7482.18 64.69 226.10 5062.73 5005.23 - 3899.69 - 1976.32 6027146.84 467862.29 MWD +Sag +CA +IIFR +MS 7580.58 64.63 226.02 5104.84 5047.34 - 3961.40 - 2040.35 6027085.40 467798.01 MWD +Sag +CA +IIFR +MS 7672.01 64.00 226.05 5144.47 5086.97 - 4018.60 - 2099.66 6027028.44 467738.48 MWD +Sag +CA +IIFR +MS 7765.81 64.21 225.38 5185.43 5127.93 - 4077.52 - 2160.06 6026969.78 467677.84 MWD +Sag +CA +IIFR +MS 7862.09 63.73 225.28 5227.69 5170.19 - 4138.34 - 2221.59 6026909.21 467616.08 MWD +Sag +CA +IIFR +MS 7965.15 64.00 225.99 5273.08 5215.58 - 4203.03 - 2287.73 6026844.79 467549.68 MWD +Sag +CA +IIFR +MS 8053.82 64.54 226.14 5311.58 5254.08 - 4258.46 - 2345.26 6026789.61 467491.94 MWD +Sag +CA +IIFR +MS 8146.79 66.18 227.02 5350.34 5292.84 - 4316.53 - 2406.64 6026731.79 467430.33 MWD +Sag +CA +IIFR +MS 8241.30 69.12 227.69 5386.27 5328.77 - 4375.74 - 2470.93 6026672.85 467365.80 MWD +Sag +CA +IIFR +MS 8336.45 71.03 227.63 5418.70 5361.20 - 4435.99 - 2537.05 6026612.88 467299.45 MWD +Sag +CA +IIFR +MS 8430.34 72.72 226.84 5447.90 5390.40 - 4496.57 - 2602.55 6026552.56 467233.71 MWD +Sag +CA +IIFR +MS 8526.96 72.40 226.26 5476.86 5419.36 - 4559.97 - 2669.47 6026489.45 467166.54 MWD +Sag +CA +IIFR +MS 8621.74 72.84 227.91 5505.18 5447.68 - 4621.55 - 2735.71 6026428.14 467100.05 MWD +Sag +CA +IIFR +MS 8717.05 72.46 231.65 5533.61 5476.11 - 4680.29 - 2805.16 6026369.69 467030.37 MWD +Sag +CA +IIFR +MS 8809.61 71.73 235.44 5562.07 5504.57 - 4732.61 - 2875.98 6026317.66 466959.34 MWD +Sag +CA +IIFR +MS 8903.84 71.86 237.99 5591.52 5534.02 - 4781.73 - 2950.80 6026268.84 466884.33 MWD +Sag +CA +IIFR +MS 8999.29 71.48 241.23 5621.54 5564.04 - 4827.57 - 3028.95 6026223.33 466806.01 MWD +Sag +CA +IIFR +MS 9094.69 71.75 244.87 5651.64 5594.14 - 4868.59 - 3109.63 6026182.65 466725.17 MWD +Sag +CA +IIFR +MS 9189.30 71.99 247.24 5681.08 5623.58 - 4905.07 - 3191.80 6026146.50 466642.86 MWD +Sag +CA +IIFR +MS 9284.80 72.27 251.06 5710.40 5652.90 - 4937.41 - 3276.72 6026114.50 466557.82 MWD +Sag +CA +IIFR +MS 9378.07 72.62 254.81 5738.54 5681.04 - 4963.50 - 3361.72 6026088.76 466472.73 MWD +Sag +CA +IIFR +MS 9472.51 72.18 258.24 5767.10 5709.60 - 4984.48 - 3449.24 6026068.14 466385.13 MWD +Sag +CA +IIFR +MS 9567.23 71.93 262.62 5796.30 5738.80 - 4999.46 - 3538.07 6026053.53 466296.24 MWD +Sag +CA +IIFR +MS 9657.71 71.94 265.85 5824.36 5766.86 - 5008.10 - 3623.64 6026045.23 466210.65 MWD +Sag +CA +IIFR +MS 9757.04 72.19 268.35 5854.96 5797.46 - 5012.88 - 3718.02 6026040.84 466116.26 MWD +Sag +CA +IIFR +MS 9851.95 72.44 272.03 5883.80 5826.30 - 5012.57 - 3808.42 6026041.51 466025.87 MWD +Sag +CA +IIFR +MS 9946.04 72.51 275.15 5912.14 5854.64 - 5006.96 - 3897.96 6026047.49 465936.37 MWD +Sag +CA +IIFR +MS 10040.89 72.56 278.49 5940.61 5883.11 - 4996.21 - 3987.78 6026058.59 465846.60 MWD +Sag +CA +IIFR +MS 10135.40 73.02 281.01 5968.58 5911.08 - 4980.92 - 4076.74 6026074.24 465757.70 MWD +Sag +CA +IIFR +MS 10231.78 73.09 284.66 5996.68 5939.18 - 4960.45 - 4166.62 6026095.08 465667.92 MWD +Sag +CA +IIFR +MS 10326.54 72.50 288.60 6024.71 5967.21 - 4934.55 - 4253.33 6026121.32 465581.32 MWD +Sag +CA +IIFR +MS 10422.32 73.03 291.70 6053.10 5995.60 - 4903.04 - 4339.20 6026153.18 465495.59 MWD +Sag +CA +IIFR +MS 10516.02 74.38 296.06 6079.40 6021.90 - 4866.63 - 4421.41 6026189.92 465413.54 MWD +Sag +CA +IIFR +MS 10611.11 75.08 299.36 6104.45 6046.95 - 4823.98 - 4502.60 6026232.90 465332.53 MWD +Sag +CA +IIFR +MS 10704.72 75.46 299.54 6128.25 6070.75 - 4779.47 - 4581.44 6026277.72 465253.88 MWD +Sag +CA +IIFR +MS 10801.66 75.47 299.55 6152.58 6095.08 - 4733.20 - 4663.07 6026324.32 465172.44 MWD +Sag +CA +IIFR +MS 10896.15 75.46 299.47 6176.30 6118.80 - 4688.14 - 4742.67 6026369.69 465093.03 MWD +Sag +CA +IIFR +MS 10989.94 75.32 301.94 6199.96 6142.46 - 4641.80 - 4820.70 6026416.34 465015.20 MWD +Sag +CA +IIFR +MS 11075.39 75.26 305.69 6221.66 6164.16 - 4595.82 - 4889.36 6026462.60 464946.74 MWD +Sag +CA +IIFR +MS 11105.07 75.28 303.47 6229.21 6171.71 - 4579.53 - 4912.99 6026478.98 464923.18 MWD +Sag +CA +IIFR +MS 11184.67 79.05 303.10 6246.89 6189.39 - 4536.94 - 4977.86 6026521.83 464858.49 MWD +Sag +CA +IIFR +MS 11278.65 80.10 303.29 6263.90 6206.40 - 4486.34 - 5055.20 6026572.74 464781.36 MWD +Sag +CA +IIFR +MS 11377.02 82.80 304.84 6278.52 6221.02 - 4431.86 - 5135.77 6026627.54 464701.02 MWD +Sag +CA +IIFR +MS 11473.50 87.93 307.57 6286.31 6228.81 - 4375.07 - 5213.33 6026684.64 464623.70 MWD +Sag +CA +1IFR +MS 11520.45 87.21 309.39 6288.31 6230.81 - 4345.89 - 5250.05 6026713.97 464587.10 MWD +Sag +CA +IIFR +MS Halliburton Company Survey Report Company: Pioneer Date: 8/8/2008 Time: 11:32:26 Page: 4 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well: ODSN -40, True North Site: Oooguruk ODS Vertical (TVD) Reference: RKB 57 :5: 57.5 Well: ODSN -40 Section (VS) Reference: Well (0.00N,0.00E,272.84Azi) Welkpath: ODSN -40 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD lnci Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft , ft ft ft ft 11570.00 89.82 311.60 6289.59 6232.09 - 4313.72 - 5287.71 6026746.28 464549.57 MWD +Sag +CA +IIFR +MS 11602.91 92.23 312.46 6289.00 6231.50 - 4291.70 - 5312.15 6026768.41 464525.23 MWD +Sag +CA +IIFR +MS 11634.50 93.01 312.92 6287.56 6230.06 - 4270.30 - 5335.35 6026789.89 464502.12 MWD +Sag +CA +IIFR +MS 11665.02 93.37 313.03 6285.86 6228.36 - 4249.53 - 5357.64 6026810.75 464479.91 MWD +Sag +CA +IIFR +MS 11712.47 95.12 313.50 6282.35 6224.85 - 4217.10 - 5392.10 6026843.32 464445.59 MWD +Sag +CA +IIFR +MS 11762.66 96.79 314.61 6277.14 6219.64 - 4182.39 - 5427.97 6026878.17 464409.86 MWD +Sag +CA +IIFR +MS 11858.89 95.77 314.64 6266.61 6209.11 - 4115.20 - 5496.05 6026945.63 464342.06 MWD +Sag +CA +1IFR +MS 11954.54 94.97 314.42 6257.66 6200.16 - 4048.41 - 5563.94 6027012.68 464274.45 MWD +Sag +CA +IIFR +MS 12051.41 96.41 314.26 6248.06 6190.56 - 3981.04 - 5632.87 6027080.32 464205.80 MWD +Sag +CA +IIFR +MS 12148.35 95.72 313.37 6237.82 6180.32 - 3914.31 - 5702.43 6027147.34 464136.52 MWD +Sag +CA +IIFR +MS 12245.05 96.60 312.31 6227.44 6169.94 - 3848.94 - 5772.93 6027212.99 464066.29 MWD +Sag +CA +IIFR +MS 12341.81 95.71 312.22 6217.06 6159.56 - 3784.23 - 5844.12 6027277.97 463995.37 MWD +Sag +CA +IIFR +MS 12438.09 96.90 312.76 6206.49 6148.99 - 3719.60 - 5914.69 6027342.89 463925.08 MWD +Sag +CA +IIFR +MS 12532.87 95.90 311.67 6195.93 6138.43 - 3656.31 - 5984.44 6027406.45 463855.58 MWD+Sag+CA+I IFR+MS 12630.73 97.53 312.59 6184.48 6126.98 - 3591.12 - 6056.52 6027471.92 463783.78 MWD +Sag +CA +IIFR +MS 12726.81 96.84 313.16 6172.47 6114.97 - 3526.26 - 6126.38 6027537.06 463714.19 MWD +Sag +CA +IIFR +MS 12824.11 92.97 312.83 6164.15 6106.65 - 3460.16 - 6197.27 6027603.44 463643.57 MWD +Sag +CA +IIFR +MS 12920.87 93.99 313.18 6158.27 6100.77 - 3394.29 - 6267.90 6027669.59 463573.22 MWD +Sag +CA +IIFR +MS 12953.00 95.36 313.80 6155.66 6098.16 - 3372.25 - 6291.13 6027691.72 463550.08 MWD +Sag +CA +IIFR +MS 12999.69 91.53 313.90 6152.85 6095.35 - 3339.97 - 6324.73 6027724.13 463516.61 MWD +Sag +CA +IIFR +MS 13017.31 91.74 313.87 6152.35 6094.85 - 3327.76 - 6337.43 6027736.39 463503.97 MWD +Sag +CA +IIFR +MS 13067.01 91.61 313.90 6150.90 6093.40 - 3293.32 - 6373.23 6027770.97 463468.31 MWD +Sag +CA +IIFR +MS 13113.34 90.97 314.46 6149.85 6092.35 - 3261.04 - 6406.45 6027803.38 463435.22 MWD +Sag +CA +IIFR +MS 13210.15 87.80 313.83 6150.89 6093.39 - 3193.63 - 6475.90 6027871.07 463366.05 MWD +Sag +CA +IIFR +MS 13306.80 84.57 313.81 6157.32 6099.82 - 3126.87 - 6545.48 6027938.11 463296.76 MWD +Sag +CA +IIFR +MS 13403.13 84.86 314.70 6166.19 6108.69 - 3059.93 - 6614.18 6028005.32 463228.33 MWD +Sag +CA +IIFR +MS 13500.10 86.17 316.70 6173.78 6116.28 - 2990.75 - 6681.69 6028074.77 463161.11 MWD +Sag +CA +IIFR +MS 13596.42 85.68 317.37 6180.62 6123.12 - 2920.44 - 6747.17 6028145.33 463095.92 MWD +Sag +CA +IIFR +MS 13694.79 87.71 317.22 6186.29 6128.79 - 2848.28 - 6813.77 6028217.76 463029.62 MWD +Sag +CA +IIFR +MS 13790.29 86.34 316.39 6191.25 6133.75 - 2778.75 - 6879.05 6028287.54 462964.63 MWD +Sag +CA +IIFR +MS 13886.32 85.66 318.17 6197.95 6140.45 - 2708.38 - 6944.04 6028358.17 462899.93 MWD +Sag +CA +IIFR +MS 13981.71 87.52 320.85 6203.62 6146.12 - 2635.97 - 7005.86 6028430.82 462838.42 MWD +Sag +CA +IIFR +MS 14078.63 90.28 322.80 6205.48 6147.98 - 2559.80 - 7065.74 6028507.23 462778.85 MWD +Sag +CA +IIFR +MS 14175.17 92.71 322.87 6202.97 6145.47 - 2482.90 - 7124.03 6028584.35 462720.87 MWD +Sag +CA +IIFR +MS 14269.72 93.37 322.09 6197.95 6140.45 - 2408.01 - 7181.54 6028659.47 462663.68 MWD +Sag +CA +IIFR +MS 14365.30 95.92 320.04 6190.21 6132.71 - 2333.92 - 7241.40 6028733.80 462604.13 MWD +Sag +CA +IIFR +MS 14462.31 96.53 317.33 6179.69 6122.19 - 2261.49 - 7305.06 6028806.47 462540.77 MWD +Sag +CA +IIFR +MS 14559.72 96.13 317.20 6168.95 6111.45 - 2190.38 - 7370.76 6028877.84 462475.36 MWD +Sag +CA +IIFR +MS 14656.50 97.54 315.08 6157.43 6099.93 - 2121.10 - 7437.33 6028947.39 462409.07 MWD +Sag +CA +IIFR +MS 14752.82 96.17 313.68 6145.93 6088.43 - 2054.22 - 7505.68 6029014.54 462341.01 MWD +Sag +CA +IIFR +MS 14849.34 95.17 313.48 6136.40 6078.90 - 1988.01 - 7575.26 6029081.03 462271.70 MWD +Sag +CA +IIFR +MS 14945.76 92.50 312.98 6129.95 6072.45 - 1922.12 - 7645.35 6029147.19 462201.89 MWD +Sag +CA +IIFR +MS 15041.04 91.53 312.45 6126.60 6069.10 - 1857.53 - 7715.31 6029212.06 462132.20 MWD +Sag +CA +IIFR +MS 15139.55 90.23 313.48 6125.09 6067.59 - 1790.40 - 7787.38 6029279.47 462060.40 MWD +Sag +CA +IIFR +MS 15234.57 91.02 315.44 6124.05 6066.55 - 1723.85 - 7855.19 6029346.29 461992.87 MWD +Sag +CA +IIFR +MS 15331.83 89.31 315.19 6123.77 6066.27 - 1654.71 - 7923.59 6029415.70 461924.76 MWD +Sag +CA +IIFR +MS 15429.07 90.39 315.02 6124.02 6066.52 - 1585.82 - 7992.22 6029484.86 461856.42 MWD +Sag +CA +IIFR +MS 15525.56 90.84 314.49 6122.99 6065.49 - 1517.89 - 8060.73 6029553.06 461788.19 MWD +Sag +CA +IIFR +MS 15621.90 89.43 313.35 6122.76 6065.26 - 1451.07 - 8130.12 6029620.16 461719.07 MWD +Sag +CA +1IFR +MS 15717.76 90.16 313.61 6123.11 6065.61 - 1385.11 - 8199.68 6029686.39 461649.79 MWD +Sag +CA +IIFR +MS 15811.70 88.56 313.04 6124.15 6066.65 - 1320.66 - 8268.01 6029751.11 461581.73 MWD +Sag +CA +IIFR +MS 15909.32 88.82 312.32 6126.39 6068.89 - 1254.50 - 8339.76 6029817.56 461510.26 MWD +Sag +CA +IIFR +MS Halliburton Company 41 0 Survey Report Company: Pioneer Date: 8/8/2008 Time: 11 :32:26 Page: 5 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well: ODSN -40, True North Site: Oooguruk ODS Vertical (TVD) Reference: RKB 57.5: 57.5 Well: ODSN -40 Section (VS) Reference: Well (0.00N,0.00E,272.84Azi) Welipath: ODSN -40 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 16007.51 86.90 314.31 6130.05 6072.55 - 1187.19 - 8411.14 6029885.14 461439.15 MWD +Sag +CA +IIFR +MS 16104.81 86.09 315.81 6136.00 6078.50 - 1118.45 - 8479.74 6029954.16 461370.84 MWD +Sag +CA +IIFR +MS 16200.05 86.58 316.86 6142.09 6084.59 - 1049.70 - 8545.37 6030023.17 461305.50 MWD +Sag +CA +I1FR +MS 16297.30 87.55 317.19 6147.07 6089.57 - 978.64 - 8611.57 6030094.49 461239.59 MWD +Sag +CA +I1FR +MS 16392.46 86.65 317.04 6151.88 6094.38 - 909.00 - 8676.25 6030164.38 461175.21 MWD +Sag +CA +IIFR +MS 16491.42 85.38 317.52 6158.76 6101.26 - 836.48 - 8743.22 6030237.17 461108.54 MWD +Sag +CA +IIFR +MS 16588.46 86.66 316.83 6165.50 6108.00 - 765.48 - 8809.02 6030308.43 461043.03 MWD +Sag +CA +IIFR +MS 16685.31 89.41 317.24 6168.82 6111.32 - 694.65 - 8874.98 6030379.51 460977.36 MWD +Sag +CA +IIFR +MS 16781.89 90.15 317.65 6169.19 6111.69 - 623.51 - 8940.30 6030450.91 460912.34 MWD +Sag +CA +IIFR +MS 16876.96 90.47 316.12 6168.67 6111.17 - 554.12 - 9005.27 6030520.56 460847.65 MWD +Sag +CA +IIFR +MS 16973.71 91.07 314.01 6167.37 6109.87 - 485.64 - 9073.60 6030589.31 460779.61 MWD +Sag +CA +IIFR +MS 17071.76 90.98 312.20 6165.62 6108.12 - 418.65 - 9145.17 6030656.58 460708.32 MWD +Sag +CA +IIFR +MS 17168.04 90.14 310.87 6164.68 6107.18 - 354.81 - 9217.24 6030720.70 460636.52 MWD +Sag +CA +IIFR +MS 17265.73 90.65 310.20 6164.00 6106.50 - 291.32 - 9291.48 6030784.48 460562.55 MWD +Sag +CA +IIFR +MS 17362.42 90.78 309.12 6162.80 6105.30 - 229.62 - 9365.91 6030846.48 460488.37 MWD +Sag +CA +IIFR +MS 17458.90 90.02 309.91 6162.12 6104.62 - 168.23 - 9440.34 6030908.17 460414.20 MWD +Sag +CA +IIFR +MS 17554.78 89.45 312.73 6162.57 6105.07 - 104.93 - 9512.34 6030971.75 460342.47 MWD +Sag +CA +IIFR +MS 17651.56 88.07 316.19 6164.66 6107.16 -37.18 - 9581.38 6031039.78 460273.70 MWD +Sag +CA +IIFR +MS 17746.64 90.17 317.44 6166.12 6108.62 32.14 - 9646.44 6031109.35 460208.93 MWD +Sag +CA +IIFR +MS 17842.84 90.12 318.02 6165.88 6108.38 103.32 - 9711.15 6031180.79 460144.52 MWD +Sag +CA +IIFR +MS 17940.50 90.29 318.62 6165.53 6108.03 176.26 - 9776.09 6031253.98 460079.89 MWD +Sag +CA +IIFR +MS 18036.14 90.83 319.29 6164.60 6107.10 248.39 - 9838.88 6031326.36 460017.39 MWD +Sag +CA +IIFR +MS 18134.78 90.38 320.57 6163.55 6106.05 323.87 - 9902.38 6031402.09 459954.21 MWD +Sag +CA +IIFR +MS 18229.91 90.42 319.98 6162.89 6105.39 397.03 - 9963.17 6031475.49 459893.72 MWD +Sag +CA +IIFR +MS 18327.37 91.43 319.68 6161.32 6103.82 471.49 - 10026.03 6031550.20 459831.17 MWD +Sag +CA +IIFR +MS 18364.00 91.43 319.68 6160.40 . 6102.90 499.41 - 10049.73 6031578.21. 459807.59. MWD +Sag +CA +IIFR +MS i alliburton Company III Survey Report Company: Pioneer Date: 8/812008 Time: 11 :24 :58 Page: 1 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well; ODSN -40, True North Site: Oooguruk 008 Vertical (TVD) Reference: RKB 57.5: 57.5 Well: ODSN -40 Section (VS) Reference: Well (0.00N,0.00E,210.17Azi) Wel 1path: ODSN -40PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Pioneer ASP Zone 4 Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: ODSN -40 Slot Name: 507032057100 Well Position: +N / -S - 112.21 ft Northing: 6031038.10 ft Latitude: 70 29 45.125 N +E / -W -66.24 ft Easting : 469854.21 ft Longitude: 150 14 47.401 W Position Uncertainty: 0.00 ft Wellpath: ODSN -40PB1 Drilled From: Well Ref. Point 507032057170 Tie -on Depth: 44.00 ft Current Datum: RKB 57.5: Height 57.50 ft Above System Datum: Mean Sea Level , Magnetic Data: 5/7/2008 Declination: 22.55 deg Field Strength: 57624 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From (TVD) +N / - +E / - Direction ft ft ft deg 44.00 0.00 0.00 210.17 Survey Program for Definitive Wellpath Date: 8/8/2008 Validated: Yes Version: 12 Actual From To Survey Toolcode Tool Name ft ft 100.00 821.00 ODSN -40PB1 Gyro 1 (100.00 -821. SRG- Gyro -SS Conventional SRG single shots 861.67 1050.07 ODSN -40PB1 MWD 1 (861.67 -1050. MWD +Sag +CA +IIFR +MMWD + Sag + CA + IIFR + MS 1105.00 1105.00 ODSN -40PB1 Gyro 2 (1105.00 -110 SRG- Gyro -SS Conventional SRG single shots 1144.97 1241.07 ODSN -40PB1 MWD 2 (1144.97 -1241 MWD +Sag +CA +IIFR +MMWD + Sag + CA + IIFR + MS 1316.00 1486.00 ODSN -40PB1 Gyro 3 (1316.00 -148 SRG- Gyro -SS Conventional SRG single shots 1530.82 8714.90 ODSN -40PB1 MWD 3 (1530.82 -8714 MWD +Sag +CA +IIFR +MWD + Sag + CA + IIFR + MS Survey MD lncl Azim TVA Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 44.00 0.00 0.00 44.00 -13.50 0.00 0.00 6031038.10 469854.21 TIE LINE 100.00 0.39 240.43 100.00 42.50 -0.09 -0.17 6031038.01 469854.04 SRG- Gyro -SS 170.00 0.34 176.53 170.00 112.50 -0.42 -0.36 6031037.68 469853.85 SRG- Gyro -SS 259.00 0.51 244.17 259.00 201.50 -0.86 -0.70 6031037.25 469853.51 SRG- Gyro -SS 352.00 1.22 176.03 351.99 294.49 -2.02 -1.00 6031036.08 469853.20 SRG- Gyro -SS 444.00 3.18 150.68 443.92 386.42 -5.23 0.31 6031032.87 469854.50 SRG- Gyro -SS 534.00 4.23 145.82 533.73 476.23 -10.15 3.40 6031027.94 469857.57 SRG- Gyro -SS 630.00 4.11 151.15 629.47 571.97 -16.09 7.05 6031021.98 469861.19 SRG- Gyro -SS 725.00 5.18 150.70 724.16 666.66 -22.81 10.79 6031015.25 469864.91 SRG- Gyro -SS 821.00 6.17 155.13 819.69 762.19 -31.27 15.08 6031006.77 469869.16 SRG- Gyro -SS 861.67 6.00 151.94 860.13 802.63 -35.13 17.00 6031002.90 469871.07 MWD +Sag +CA +IIFR +MS 956.76 5.58 152.47 954.73 897.23 -43.62 21.47 6030994.40 469875.51 MWD +Sag +CA +IIFR +MS 1050.07 7.30 154.40 1047.45 989.95 -52.99 26.13 6030985.01 469880.13 MWD +Sag +CA +IIFR +MS 1105.00 8.81 155.76 1101.84 1044.34 -59.97 29.37 6030978.02 469883.33 SRG- Gyro -SS 1144.97 9.24 155.31 1141.31 1083.81 -65.68 31.97 6030972.30 469885.91 MWD +Sag +CA +IIFR +MS 1241.07 11.48 154.47 1235.84 1178.34 -81.32 39.31 6030956.63 469893.19 MWD +Sag +CA +IIFR +MS 1316.00 13.83 155.06 1308.95 1251.45 -96.17 46.30 6030941.75 469900.12 SRG- Gyro -SS 1391.00 16.14 154.08 1381.39 1323.89 - 113.67 54.64 6030924.22 469908.38 SRG- Gyro -SS 1486.00 21.72 149.84 1471.22 1413.72 - 140.77 69.26 6030897.06 469922.89 SRG- Gyro -SS 1530.82 21.90 149.99 1512.83 1455.33 - 155.18 77.60 6030882.62 469931.17 MWD +Sag +CA +IIFR +MS 1620.97 20.72 150.30 1596.82 1539.32 - 183.59 93.91 6030854.15 469947.37 MWD +Sag +CA +IIFR +MS 1 1716.07 22.89 151.41 1685.11 1627.61 - 214.45 111.10 6030823.22 469964.43 MWD +Sag +CA +IIFR +MS 1808.67 24.86 158.02 1769.80 1712.30 - 248.32 127.01 6030789.29 469980.20 MWD +Sag +CA +IIFR +MS 1904.52 25.17 159.62 1856.66 1799.16 - 286.11 141.65 6030751.44 469994.68 MWD +Sag +CA +IIFR +MS 1999.17 25.27 160.64 1942.28 1884.78 - 324.04 155.35 6030713.46 470008.23 MWD +Sag +CA +IIFR +MS 1 •Halliburton Company 0 Survey Report Company: Pioneer Date: 8/8/2008 Time: 11 :24:58 Page: 2 Field: Pioneer ASP Zone 4 Co-ordinate(NE) Reference; WeII: ODSN -40, True North Site: Oooguruk ODS Vertical (TVD) Reference: RKB 57.5: 57.5 Well: ODSN -40 Section (VS) Reference: Well (0.00N,0.00E,210.17AzI) Wellpatb: ODSN -40PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2094.61 25.61 164.07 2028.47 1970.97 - 363.10 167.77 6030674.36 470020.49 MWD +Sag +CA +IIFR +MS 2187.75 26.22 168.42 2112.26 2054.76 - 402.61 177.43 6030634.81 470029.98 MWD +Sag +CA +IIFR +MS 2283.65 29.33 173.22 2197.11 2139.61 - 446.71 184.45 6030590.69 470036.83 MWD +Sag +CA +IIFR +MS 2377.66 34.42 171.98 2276.92 2219.42 - 495.91 190.88 6030541.46 470043.06 MWD +Sag +CA +IIFR +MS 2472.90 36.80 176.68 2354.35 2296.85 - 551.07 196.29 6030486.30 470048.25 MWD +Sag +CA +IIFR +MS 2571.09 37.87 175.57 2432.43 2374.93 - 610.48 200.32 6030426.88 470052.04 MWD +Sag +CA +IIFR +MS 2667.32 39.92 176.18 2507.32 2449.82 - 670.74 204.66 6030366.60 470056.13 MWD +Sag +CA +IIFR +MS 2761.38 43.05 179.91 2577.78 2520.28 - 732.98 206.72 6030304.36 470057.94 MWD +Sag +CA +IIFR +MS 2853.73 45.19 182.07 2644.08 2586.58 - 797.25 205.59 6030240.10 470056.55 MWD +Sag +CA +IIFR +MS 2949.25 46.47 185.50 2710.65 2653.15 - 865.59 201.05 6030171.79 470051.73 MWD +Sag +CA +IIFR +MS 3043.84 47.92 186.37 2774.92 2717.42 - 934.61 193.87 6030102.80 470044.27 MWD +Sag +CA +IIFR +MS 3138.67 49.67 186.88 2837.39 2779.89 - 1005.48 185.63 6030031.98 470035.74 MWD +Sag +CA +IIFR +MS 3233.92 53.09 188.05 2896.83 2839.33 - 1079.25 175.95 6029958.25 470025.76 MWD +Sag +CA +IIFR +MS 3327.71 55.19 190.36 2951.77 2894.27 - 1154.27 163.77 6029883.29 470013.28 MWD +Sag +CA +IIFR +MS 3356.70 55.37 191.09 2968.29 2910.79 - 1177.68 159.33 6029859.90 470008.75 MWD +Sag +CA +IIFR +MS 3477.63 55.07 192.26 3037.27 2979.77 - 1274.95 139.24 6029762.72 469988.26 MWD +Sag +CA +IIFR +MS 3573.90 55.83 195.59 3091.88 3034.38 - 1351.89 120.15 6029685.87 469968.86 MWD +Sag +CA +IIFR +MS 3668.37 55.39 197.84 3145.24 3087.74 - 1426.55 97.73 6029611.31 469946.15 MWD +Sag +CA +IIFR +MS 3763.81 54.83 197.86 3199.83 3142.33 - 1501.06 73.74 6029536.90 469921.85 MWD +Sag +CA +IIFR +MS 3858.11 54.50 197.68 3254.37 3196.87 - 1574.32 50.26 6029463.75 469898.08 MWD +Sag +CA +IIFR +MS 3952.26 53.46 199.06 3309.74 3252.24 - 1646.59 26.27 6029391.58 469873.80 MWD +Sag +CA +IIFR +MS 4048.71 53.19 200.20 3367.35 3309.85 - 1719.45 0.28 6029318.84 469847.52 MWD +Sag +CA +IIFR +MS 4144.92 53.07 201.93 3425.08 3367.58 - 1791.27 -27.38 6029247.14 469819.57 MWD +Sag +CA +IIFR +MS 4241.65 53.26 204.61 3483.07 3425.57 - 1862.38 -57.96 6029176.16 469788.70 MWD +Sag +CA +IIFR +MS 4333.84 53.24 206.01 3538.23 3480.73 - 1929.15 -89.54 6029109.52 469756.86 MWD +Sag +CA +IIFR +MS 4428.58 53.10 207.72 3595.03 3537.53 - 1996.79 - 123.80 6029042.02 469722.32 MWD +Sag +CA +IIFR +MS 4523.74 53.12 210.75 3652.16 3594.66 - 2063.19 - 160.97 6028975.78 469684.89 MWD +Sag +CA +IIFR +MS 4619.01 52.95 214.03 3709.46 3651.96 - 2127.46 - 201.73 6028911.69 469643.87 MWD +Sag +CA +IIFR +MS 4715.41 53.40 217.59 3767.25 3709.75 - 2190.01 - 246.87 6028849.32 469598.48 MWD +Sag +CA +IIFR +MS 4802.82 54.93 220.15 3818.43 3760.93 - 2245.17 - 291.35 6028794.35 469553.79 MWD +Sag +CA +IIFR +MS 4904.22 55.00 221.23 3876.64 3819.14 - 2308.12 - 345.48 6028731.63 469499.41 MWD +Sag +CA +1IFR +MS 4998.95 54.17 221.40 3931.54 3874.04 - 2366.11 - 396.45 6028673.85 469448.21 MWD +Sag +CA +IIFR +MS 5092.89 54.48 223.38 3986.32 3928.82 - 2422.46 - 447.89 6028617.71 469396.54 MWD +Sag +CA +IIFR +MS 5189.96 55.45 226.12 4042.06 3984.56 - 2478.89 - 503.85 6028561.52 469340.37 MWD +Sag +CA +IIFR +MS 5283.41 57.57 225.20 4093.62 4036.12 - 2533.36 - 559.58 6028507.28 469284.42 MWD +Sag +CA +IIFR +MS 5378.96 59.29 224.20 4143.64 4086.14 - 2591.23 - 616.83 6028449.65 469226.94 MWD +Sag +CA +IIFR +MS 5473.02 61.08 222.03 4190.41 4132.91 - 2650.80 - 672.59 6028390.31 469170.94 MWD +Sag +CA +IIFR +MS 5568.75 63.58 220.77 4234.86 4177.36 - 2714.40 - 728.64 6028326.95 469114.64 MWD +Sag +CA +IIFR +MS 5662.04 66.38 221.63 4274.32 4216.82 - 2777.99 - 784.33 6028263.58 469058.70 MWD +Sag +CA +IIFR +MS 5760.64 69.42 220.19 4311.41 4253.91 - 2847.03 - 844.13 6028194.80 468998.62 MWD +Sag +CA +IIFR +MS 5855.29 70.09 220.04 4344.16 4286.66 - 2914.94 - 901.35 6028127.12 468941.13 MWD +Sag +CA +IIFR +MS 5947.13 69.63 220.69 4375.78 4318.28 - 2980.64 - 957.19 6028061.66 468885.03 MWD +Sag +CA +IIFR +MS 6040.82 69.52 219.70 4408.48 4350.98 - 3047.71 - 1013.86 6027994.83 468828.10 MWD +Sag +CA +IIFR +MS 6140.00 70.43 218.27 4442.44 4384.94 - 3120.14 - 1072.48 6027922.64 468769.20 MWD +Sag +CA +IIFR +MS 6231.39 69.58 219.50 4473.69 4416.19 - 3186.99 - 1126.39 6027856.02 468715.02 MWD +Sag +CA +IIFR +MS 6326.10 69.50 221.68 4506.80 4449.30 - 3254.37 - 1184.12 6027788.88 468657.02 MWD +Sag +CA +IIFR +MS 6419.52 70.30 224.94 4538.92 4481.42 - 3318.19 - 1244.29 6027725.31 468596.60 MWD +Sag +CA +IIFR +MS 6515.15 70.68 226.74 4570.86 4513.36 - 3380.98 - 1308.95 6027662.79 468531.69 MWD +Sag +CA +IIFR +MS 6608.75 70.28 226.46 4602.13 4544.63 - 3441.60 - 1373.05 6027602.44 468467.35 MWD +Sag +CA +IIFR +MS 6705.30 70.49 227.06 4634.54 4577.04 - 3503.90 - 1439.30 6027540.41 468400.85 MWD +Sag +CA +IIFR +MS 6800.11 70.02 228.19 4666.57 4609.07 - 3564.04 - 1505.23 6027480.54 468334.69 MWD +Sag +CA +IIFR +MS 6895.03 70.04 227.64 4698.99 4641.49 - 3623.84 - 1571.43 6027421.03 468268.25 MWD +Sag +CA +IIFR +MS 6990.84 70.16 227.37 4731.60 4674.10 - 3684.69 - 1637.86 6027360.44 468201.58 MWD +Sag +CA +IIFR +MS wH alliburton Company Survey Report Company: Pioneer Date: 8/812008 Time: 11 :24:58 Page: 3 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well; ODSN -40, True North Site: Oooguruk ODS Vertical (TVD) Reference: RKB 57.5: 57.5 Well: ODSN -40 Section (VS) Referenee: Well (0.00N,0.00E,210.17Azi) Welipath: ODSN -44PB1 Survey Calculation Method: Minimum Curvature Rh: Oracle Survey MD Inc] Azim TVD Sys TVD NIS E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 7085,84 69.98 227.10 4763.99 4706.49 - 3745.33 - 1703.43 6027300.07 468135.78 MWD +Sag +CA +IIFR +MS 7180.95 70.22 225.63 4796.36 4738.86 - 3807.05 - 1768.15 6027238.63 468070.81 MWD +Sag +CA +IIFR +MS 7276.34 69.64 224.82 4829.10 4771.60 - 3870.15 - 1831.75 6027175.79 468006.96 MWD +Sag +CA +IIFR +MS 7371.31 69.56 223.74 4862.20 4804.70 - 3933.88 - 1893.90 6027112.33 467944.56 MWD +Sag +CA +IIFR +MS 7466.07 69.44 225.99 4895.39 4837.89 - 3996.78 - 1956.51 6027049.68 467881.71 MWD +Sag +CA +IIFR +MS 7559.27 69.10 224.14 4928.38 4870.88 - 4058.34 - 2018.21 6026988.38 467819.76 MWD +Sag +CA +IIFR +MS 7653.71 69.51 224.50 4961.76 4904.26 - 4121.55 - 2079.93 6026925.43 467757.79 MWD +Sag +CA +IIFR +MS 7750.54 69.58 225.55 4995.60 4938.10 - 4185.67 - 2144.11 6026861.57 467693.35 MWD +Sag +CA +IIFR +MS 7844.64 69.57 226.16 5028.44 4970.94 - 4247.09 - 2207.39 6026800.42 467629.83 MWD +Sag +CA +IIFR +MS 7939.55 69.69 226.88 5061.47 5003.97 - 4308.31 - 2271.95 6026739.46 467565.03 MWD +Sag +CA +IIFR +MS 8033.31 69.84 226.89 5093.90 5036.40 - 4368.44 - 2336.17 6026679.60 467500.57 MWD +Sag +CA +IIFR +MS 8130.04 69.56 225.14 5127.46 5069.96 - 4431.44 - 2401.45 6026616.87 467435.05 MWD +Sag +CA +IIFR +MS 8224.38 70.23 223.60 5159.89 5102.39 - 4494.77 - 2463.39 6026553.80 467372.86 MWD +Sag +CA +IIFR +MS 8321.00 69.25 222.85 5193.35 5135.85 - 4560.81 - 2525.47 6026488.02 467310.52 MWD +Sag +CA +IIFR +MS 8414.62 69.44 222.46 5226.37 5168.87 - 4625.24 - 2584.83 6026423.84 467250.90 MWD +Sag +CA +IIFR +MS 8505.68 69.83 223.27 5258.06 5200.56 - 4687.81 - 2642.90 6026361.51 467192.58 MWD +Sag +CA +IIFR +MS 8602.89 69.37 226.27 5291.96 5234.46 - 4752.49 - 2707.06 6026297.10 467128.17 MWD +Sag +CA +IIFR +MS 8659.57 69.13 227.75 5312.04 5254.54 - 4788.63 - 2745.83 6026261.12 467089.26 MWD +Sag +CA +IIFR +MS 8714.90 69.33 230.42 5331.66 5274.16 - 4822.51 - 2784.92 6026227.40 467050.04 MWD +Sag +CA +IIFR +MS 8764.00 69.33 230.42 5348.99 5291.49 - 4851.78 - 2820.32 6026198.28 467014.51 MWD +Sag +CA +IIFR +MS 0 Halliburton Company , • Survey Report Company: Pioneer Date: 8/11/2008 Time: 10:45 :28 Page: I Field: Pioneer ASP Zone 4 Ca- ordinate(NE) Reference: Well: ODSN -40, True North Site: Oooguruk ODS Vertical (TVD) Reference: RKB 57.5: 57.5 Well: ODSN -40 Section (VS) Reference: Well (0.00N,0.00E,244.85Azi) Wellpath: OSDN -40PB2 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Pioneer ASP Zone 4 Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: ODSN -40 Slot Name: 507032057100 Well Position: +N / -S - 112.21 ft Northing: 6031038.10 ft Latitude: 70 29 45.125 N +E / -W -66.24 ft Easting : 469854.21 ft Longitude: 150 14 47.401 W Position Uncertainty: 0.00 ft Wellpath: OSDN -40PB2 Drilled From: ODSN -40PB1 507032057171 Tie -on Depth: 5092.89 ft Current Datum: RKB 57.5: Height 57.50 ft Above System Datum: Mean Sea Level Magnetic Data: 5/7/2008 Declination: 22.55 deg Field Strength: 57624 nT Mag Dip Angle: 80.88 deg Vertical Section: Depth From (TVD) +N / -S +E / -W Direction ft ft ft deg 44.00 0.00 0.00 244.85 Survey Program for Definitive Wellpath Date: 8/8/2008 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 100.00 821.00 ODSN -40PB1 Gyro 1 (100.00 -821. SRG- Gyro -SS Conventional SRG single shots 861.67 1050.07 ODSN -40PB1 MWD 1 (861.67 -1050. MWD +Sag +CA +IIFR +MIOWD + Sag + CA + IIFR + MS 1105.00 1105.00 ODSN -40PB1 Gyro 2 (1105.00 -110 SRG- Gyro -SS Conventional SRG single shots 1144.97 1241.07 ODSN -40PB1 MWD 2 (1144.97 -1241 MWD +Sag +CA +IIFR +MIIi1WD + Sag + CA + IIFR + MS 1316.00 1486.00 ODSN -40PB1 Gyro 3 (1316.00 -148 SRG- Gyro -SS Conventional SRG single shots 1530.82 5092.89 ODSN -40PB1 MWD 3 (1530.82 -8714 MWD +Sag +CA +IIFR +MMWD + Sag + CA + IIFR + MS 5100.00 13306.02 OSDN -40PB2 MWD (5100.00- 13306. MWD +Sag +CA +IIFR +MMWD + Sag + CA + IIFR + MS Survey MD Inca Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 44.00 0.00 0.00 44.00 -13.50 0.00 0.00 6031038.10 469854.21 TIE LINE 100.00 0.39 240.43 100.00 42.50 -0.09 -0.17 6031038.01 469854.04 SRG- Gyro -SS 170.00 0.34 176.53 170.00 112.50 -0.42 -0.36 6031037.68 469853.85 SRG- Gyro -SS 259.00 0.51 244.17 259.00 201.50 -0.86 -0.70 6031037.25 469853.51 SRG- Gyro -SS 352.00 1.22 176.03 351.99 294.49 -2.02 -1.00 6031036.08 469853.20 SRG- Gyro -SS 444.00 3.18 150.68 443.92 386.42 -5.23 0.31 6031032.87 469854.50 SRG- Gyro -SS 534.00 4.23 145.82 533.73 476.23 -10.15 3.40 6031027.94 469857.57 SRG- Gyro -SS 630.00 4.11 151.15 629.47 571.97 -16.09 7.05 6031021.98 469861.19 SRG- Gyro -SS 725.00 5.18 150.70 724.16 666.66 -22.81 10.79 6031015.25 469864.91 SRG- Gyro -SS 821.00 6.17 155.13 819.69 762.19 -31.27 15.08 6031006.77 469869.16 SRG- Gyro -SS 861.67 6.00 151.94 860.13 802.63 -35.13 17.00 6031002.90 469871.07 MWD +Sag +CA +IIFR +MS 956.76 5.58 152.47 954.73 897.23 -43.62 21.47 6030994.40 469875.51 MWD +Sag +CA +IIFR +MS 1050.07 7.30 154.40 1047.45 989.95 -52.99 26.13 6030985.01 469880.13 MWD +Sag +CA +IIFR +MS 1105.00 8.81 155.76 1101.84 1044.34 -59.97 29.37 6030978.02 469883.33 SRG- Gyro -SS 1144.97 9.24 155.31 1141.31 1083.81 -65.68 31.97 6030972.30 469885.91 MWD +Sag +CA +IIFR +MS 1241.07 11.48 154.47 1235.84 1178.34 -81.32 39.31 6030956.63 469893.19 MWD +Sag +CA +IIFR +MS 1316.00 13.83 155.06 1308.95 1251.45 -96.17 46.30 6030941.75 469900.12 SRG- Gyro -SS 1391.00 16.14 154.08 1381.39 1323.89 - 113.67 54.64 6030924.22 469908.38 SRG- Gyro -SS 1486.00 21.72 149.84 1471.22 1413.72 - 140.77 69.26 6030897.06 469922.89 SRG- Gyro -SS 1530.82 21.90 149.99 1512.83 1455.33 - 155.18 77.60 6030882.62 469931.17 MWD +Sag +CA +IIFR +MS 1620.97 20.72 150.30 1596.82 1539.32 - 183.59 93.91 6030854.15 469947.37 MWD +Sag +CA +IIFR +MS 1716.07 22.89 151.41 1685.11 1627.61 - 214.45 111.10 6030823.22 469964.43 MWD +Sag +CA +IIFR +MS 1808.67 24.86 158.02 1769.80 1712.30 - 248.32 127.01 6030789.29 469980.20 MWD +Sag +CA +IIFR +MS 1904.52 25.17 159.62 1856.66 1799.16 - 286.11 141.65 6030751.44 469994.68 MWD +Sag +CA +I1FR +MS 1999.17 25.27 160.64 1942.28 1884.78 - 324.04 155.35 6030713.46 470008.23 MWD +Sag +CA +IIFR +MS 1 Halliburton Company Survey Report Company: Pioneer Date: 8/11/2008 Time: 10 :45;28 Page: 2 Field; Pioneer ASP Zone 4 Co- ordinate(NE) Reference; Well: ODSN -40, True North Site: Oooguruk ODS Vertical (TVD) Reference: RI<B 57.5: 57.5 Well: ODSN -40 Section (VS) Reference: Well (0.00N,0.00E,244.85AzI) Wellpatb: OSDN -40P82 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 2094.61 25.61 164.07 2028.47 1970.97 - 363.10 167.77 6030674.36 470020.49 MWD +Sag +CA +IIFR +MS 2187.75 26.22 168.42 2112.26 2054.76 - 402.61 177.43 6030634.81 470029.98 MWD +Sag +CA +IIFR +MS 2283.65 29.33 173.22 2197.11 2139.61 - 446.71 184.45 6030590.69 470036.83 MWD +Sag +CA +IIFR +MS 2377.66 34.42 171.98 2276.92 2219.42 - 495.91 190.88 6030541.46 470043.06 MWD +Sag +CA +IIFR +MS 2472.90 36.80 176.68 2354.35 2296.85 - 551.07 196.29 6030486.30 470048.25 MWD +Sag +CA +IIFR +MS 2571.09 37.87 175.57 2432.43 2374.93 - 610.48 200.32 6030426.88 470052.04 MWD +Sag +CA +IIFR +MS 2667.32 39.92 176.18 2507.32 2449.82 - 670.74 204.66 6030366.60 470056.13 MWD +Sag +CA +IIFR +MS 2761.38 43.05 179.91 2577.78 2520.28 - 732.98 206.72 6030304.36 470057.94 MWD +Sag +CA +IIFR +MS 2853.73 45.19 182.07 2644.08 2586.58 - 797.25 205.59 6030240.10 470056.55 MWD +Sag +CA +IIFR +MS 2949.25 46.47 185.50 2710.65 2653.15 - 865.59 201.05 6030171.79 470051.73 MWD +Sag +CA +IIFR +MS 3043.84 47.92 186.37 2774.92 2717.42 - 934.61 193.87 6030102.80 470044.27 MWD +Sag +CA +IIFR +MS 3138.67 49.67 186.88 2837.39 2779.89 - 1005.48 185.63 6030031.98 470035.74 MWD +Sag +CA +IIFR +MS 3233.92 53.09 188.05 2896.83 2839.33 - 1079.25 175.95 6029958.25 470025.76 MWD +Sag +CA +IIFR +MS 3327.71 55.19 190.36 2951.77 2894.27 - 1154.27 163.77 6029883.29 470013.28 MWD +Sag +CA +IIFR +MS 3356.70 55.37 191.09 2968.29 2910.79 - 1177.68 159.33 6029859.90 470008.75 MWD +Sag +CA +IIFR +MS 3477.63 55.07 192.26 3037.27 2979.77 - 1274.95 139.24 6029762.72 469988.26 MWD +Sag +CA +IIFR +MS 3573.90 55.83 195.59 3091.88 3034.38 - 1351.89 120.15 6029685.87 469968.86 MWD +Sag +CA +IIFR +MS 3668.37 55.39 197.84 3145.24 3087.74 - 1426.55 97.73 6029611.31 469946.15 MWD +Sag +CA +IIFR +MS 3763.81 54.83 197.86 3199.83 3142.33 - 1501.06 73.74 6029536.90 469921.85 MWD +Sag +CA +IIFR +MS 3858.11 54.50 197.68 3254.37 3196.87 - 1574.32 50.26 6029463.75 469898.08 MWD +Sag +CA +IIFR +MS 3952.26 53.46 199.06 3309.74 3252.24 - 1646.59 26.27 6029391.58 469873.80 MWD +Sag +CA +IIFR +MS 4048.71 53.19 200.20 3367.35 3309.85 - 1719.45 0.28 6029318.84 469847.52 MWD +Sag +CA +IIFR +MS 4144.92 53.07 201.93 3425.08 3367.58 - 1791.27 -27.38 6029247.14 469819.57 MWD +Sag +CA +IIFR +MS 4241.65 53.26 204.61 3483.07 3425.57 - 1862.38 -57.96 6029176.16 469788.70 MWD +Sag +CA +IIFR +MS 4333.84 53.24 206.01 3538.23 3480.73 - 1929.15 -89.54 6029109.52 469756.86 MWD +Sag +CA +IIFR +MS 4428.58 53.10 207.72 3595.03 3537.53 - 1996.79 - 123.80 6029042.02 469722.32 MWD +Sag +CA +IIFR +MS 4523.74 53.12 210.75 3652.16 3594.66 - 2063.19 - 160.97 6028975.78 469684.89 MWD +Sag +CA +IIFR +MS 4619.01 52.95 214.03 3709.46 3651.96 - 2127.46 - 201.73 6028911.69 469643.87 MWD +Sag +CA +IIFR +MS 4715.41 53.40 217.59 3767.25 3709.75 - 2190.01 - 246.87 6028849.32 469598.48 MWD +Sag +CA +IIFR +MS 4802.82 54.93 220.15 3818.43 3760.93 - 2245.17 - 291.35 6028794.35 469553.79 MWD +Sag +CA +IIFR +MS 4904.22 55.00 221.23 3876.64 3819.14 - 2308.12 - 345.48 6028731.63 469499.41 MWD +Sag +CA +IIFR +MS 4998.95 54.17 221.40 3931.54 3874.04 - 2366.11 - 396.45 6028673.85 469448.21 MWD +Sag +CA +IIFR +MS 5092.89 54.48 223.38 3986.32 3928.82 - 2422.46 - 447.89 6028617.71 469396.54 MWD +Sag +CA +IIFR +MS 5100.00 54.55 223.58 3990.45 3932.95 - 2426.66 - 451.88 6028613.53 469392.54 MWD +Sag +CA +IIFR +MS 5163.35 52.83 224.51 4027.96 3970.46 - 2463.36 - 487.36 6028576.98 469356.91 MWD +Sag +CA +IIFR +MS 5203.29 51.88 225.43 4052.36 3994.86 - 2485.73 - 509.71 6028554.70 469334.48 MWD +Sag +CA +IIFR +MS 5299.51 53.71 226.74 4110.54 4053.04 - 2538.87 - 564.92 6028501.79 469279.06 MWD +Sag +CA +IIFR +MS 5393.25 56.29 226.90 4164.30 4106.80 - 2591.41 - 620.91 6028449.48 469222.86 MWD +Sag +CA +IIFR +MS 5488.93 58.62 225.39 4215.77 4158.27 - 2647.30 - 679.05 6028393.84 469164.49 MWD +Sag +CA +IIFR +MS 5585.01 62.27 223.27 4263.16 4205.66 - 2707.09 - 737.42 6028334.29 469105.89 MWD +Sag +CA +IIFR +MS 5679.43 65.78 223.43 4304.51 4247.01 - 2768.80 - 795.68 6028272.82 469047.39 MWD +Sag +CA +IIFR +MS , 5773.54 65.50 224.99 4343.33 4285.83 - 2830.25 - 855.46 6028211.62 468987.37 MWD +Sag +CA +IIFR +MS 5870.65 65.31 228.51 4383.75 4326.25 - 2890.74 - 919.76 6028151.40 468922.83 MWD +Sag +CA +IIFR +MS 5964.24 65.57 229.92 4422.66 4365.16 - 2946.34 - 984.21 6028096.06 468858.16 MWD +Sag +CA +IIFR +MS 6059.66 65.37 229.12 4462.27 4404.77 - 3002.70 - 1050.24 6028039.99 468791.91 MWD +Sag +CA +IIFR +MS 6154.40 65.43 227.47 4501.71 4444.21 - 3060.00 - 1114.55 6027982.95 468727.38 MWD +Sag +CA +IIFR +MS 6248.80 65.78 225.87 4540.70 4483.20 - 3118.99 - 1177.08 6027924.21 468664.61 MWD +Sag +CA +IIFR +MS 6343.84 65.86 224.37 4579.63 4522.13 - 3180.17 - 1238.51 6027863.29 468602.94 MWD +Sag +CA +IIFR +MS 6438.33 64.75 224.30 4619.11 4561.61 - 3241.57 - 1298.51 6027802.14 468542.70 MWD +Sag +CA +IIFR +MS 6532.70 65.09 225.48 4659.11 4601.61 - 3302.13 - 1358.83 6027741.84 468482.14 MWD +Sag +CA +IIFR +MS 6627.93 65.77 225.43 4698.71 4641.21 - 3362.88 - 1420.55 6027681.34 468420.17 MWD +Sag +CA +IIFR +MS 6724.54 66.04 225.65 4738.15 4680.65 - 3424.65 - 1483.50 6027619.83 468356.98 MWD +Sag +CA +IIFR +MS Halliburton Company • Survey Report Company: Pioneer Date: 8/11/2008 Time: 10 :45:28 Page: 3 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well: ODSN -40, True North Site: Oooguruk ODS Vertical (TVD) Reference: RKB 57.5: 57.5 Well: ODSN -40 Section (VS) Reference: Well (0,00N,0.00E,244.85Az1) Wellpath: OSDN -40PB2 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Intl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 6813.99 66.04 225.48 4774.48 4716.98 - 3481.88 - 1541.87 6027562.85 468298.39 MWD +Sag +CA +IIFR +MS 6912.81 65.38 225.48 4815.13 4757.63 - 3545.03 - 1606.09 6027499.96 468233.92 MWD +Sag +CA +IIFR +MS 7007.83 63.59 226.31 4856.06 4798.56 - 3604.71 - 1667.66 6027440.54 468172.11 MWD +Sag +CA +IIFR +MS 7102.62 64.76 226.86 4897.35 4839.85 - 3663.35 - 1729.64 6027382.16 468109.91 MWD +Sag +CA +IIFR +MS 7198.31 64.41 226.38 4938.42 4880.92 - 3722.71 - 1792.45 6027323.05 468046.85 MWD +Sag +CA +IIFR +MS 7292.15 63.88 226.12 4979.34 4921.84 - 3781.11 - 1853.45 6027264.91 467985.62 MWD +Sag +CA +IIFR +MS 7387.84 63.66 225.92 5021.63 4964.13 - 3840.71 - 1915.22 6027205.56 467923.62 MWD +Sag +CA +IIFR +MS 7482.18 64.69 226.10 5062.73 5005.23 - 3899.69 - 1976.32 6027146.84 467862.29 MWD +Sag +CA +IIFR +MS 7580.58 64.63 226.02 5104.84 5047.34 - 3961.40 - 2040.35 6027085.40 467798.01 MWD +Sag +CA +IIFR +MS 7672.01 64.00 226.05 5144.47 5086.97 - 4018.60 - 2099.66 6027028.44 467738.48 MWD +Sag +CA +IIFR +MS 7765.81 64.21 225.38 5185.43 5127.93 - 4077.52 - 2160.06 6026969.78 467677.84 MWD +Sag +CA +IIFR +MS 7862.09 63.73 225.28 5227.69 5170.19 - 4138.34 - 2221.59 6026909.21 467616.08 MWD +Sag +CA +IIFR +MS 7965.15 64.00 225.99 5273.08 5215.58 - 4203.03 - 2287.73 6026844.79 467549.68 MWD +Sag +CA +IIFR +MS 8053.82 64.54 226.14 5311.58 5254.08 - 4258.46 - 2345.26 6026789.61 467491.94 MWD +Sag +CA +IIFR +MS 8146.79 66.18 227.02 5350.34 5292.84 - 4316.53 - 2406.64 6026731.79 467430.33 MWD +Sag +CA +IIFR +MS 8241.30 69.12 227.69 5386.27 5328.77 - 4375.74 - 2470.93 6026672.85 467365.80 MWD +Sag +CA +IIFR +MS 8336.45 71.03 227.63 5418.70 5361.20 - 4435.99 - 2537.05 6026612.88 467299.45 MWD +Sag +CA +IIFR +MS 8430.34 72.72 226.84 5447.90 5390.40 - 4496.57 - 2602.55 6026552.56 467233.71 MWD +Sag +CA +IIFR +MS 8526.96 72.40 226.26 5476.86 5419.36 - 4559.97 - 2669.47 6026489.45 467166.54 MWD +Sag +CA +IIFR +MS 8621.74 72.84 227.91 5505.18 5447.68 - 4621.55 - 2735.71 6026428.14 467100.05 MWD +Sag +CA +IIFR +MS 8717.05 72.46 231.65 5533.61 5476.11 - 4680.29 - 2805.16 6026369.69 467030.37 MWD +Sag +CA +IIFR +MS 8809.61 71.73 235.44 5562.07 5504.57 - 4732.61 - 2875.98 6026317.66 466959.34 MWD +Sag +CA +IIFR +MS 8903.84 71.86 237.99 5591.52 5534.02 - 4781.73 - 2950.80 6026268.84 466884.33 MWD +Sag +CA +IIFR +MS 8999.29 71.48 241.23 5621.54 5564.04 - 4827.57 - 3028.95 6026223.33 466806.01 MWD +Sag +CA +IIFR +MS 9094.69 71.75 244.87 5651.64 5594.14 - 4868.59 - 3109.63 6026182.65 466725.17 MWD +Sag +CA +IIFR +MS 9189.30 71.99 247.24 5681.08 5623.58 - 4905.07 - 3191.80 6026146.50 466642.86 MWD +Sag +CA +IIFR +MS 9284.80 72.27 251.06 5710.40 5652.90 - 4937.41 - 3276.72 6026114.50 466557.82 MWD +Sag +CA +IIFR +MS 9378.07 72.62 254.81 5738.54 5681.04 - 4963.50 - 3361.72 6026088.76 466472.73 MWD +Sag +CA +IIFR +MS 9472.51 72.18 258.24 5767.10 5709.60 - 4984.48 - 3449.24 6026068.14 466385.13 MWD +Sag +CA +IIFR +MS 9567.23 71.93 262.62 5796.30 5738.80 - 4999.46 - 3538.07 6026053.53 466296.24 MWD +Sag +CA +IIFR +MS 9657.71 71.94 265.85 5824.36 5766.86 - 5008.10 - 3623.64 6026045.23 466210.65 MWD +Sag +CA +IIFR +MS 9757.04 72.19 268.35 5854.96 5797.46 - 5012.88 - 3718.02 6026040.84 466116.26 MWD +Sag +CA +IIFR +MS 9851.95 72.44 272.03 5883.80 5826.30 - 5012.57 - 3808.42 6026041.51 466025.87 MWD +Sag +CA +IIFR +MS 9946.04 72.51 275.15 5912.14 5854.64 - 5006.96 - 3897.96 6026047.49 465936.37 MWD +Sag +CA +IIFR +MS 10040.89 72.56 278.49 5940.61 5883.11 - 4996.21 - 3987.78 6026058.59 465846.60 MWD +Sag +CA +IIFR +MS 10135.40 73.02 281.01 5968.58 5911.08 - 4980.92 - 4076.74 6026074.24 465757.70 MWD +Sag +CA +IIFR +MS 10231.78 73.09 284.66 5996.68 5939.18 - 4960.45 - 4166.62 6026095.08 465667.92 MWD +Sag +CA +IIFR +MS 10326.54 72.50 288.60 6024.71 5967.21 - 4934.55 - 4253.33 6026121.32 465581.32 MWD +Sag +CA +IIFR +MS 10422.32 73.03 291.70 6053.10 5995.60 - 4903.04 - 4339.20 6026153.18 465495.59 MWD +Sag +CA +IIFR +MS 10516.02 74.38 296.06 6079.40 6021.90 - 4866.63 - 4421.41 6026189.92 465413.54 MWD +Sag +CA +IIFR +MS 10611.11 75.08 299.36 6104.45 6046.95 - 4823.98 - 4502.60 6026232.90 465332.53 MWD +Sag +CA +IIFR +MS 10704.72 75.46 299.54 6128.25 6070.75 - 4779.47 - 4581.44 6026277.72 465253.88 MWD +Sag +CA +1IFR +MS ' 10801.66 75.47 299.55 6152.58 6095.08 - 4733.20 - 4663.07 6026324.32 465172.44 MWD +Sag +CA +IIFR +MS 10896.15 75.46 299.47 6176.30 6118.80 - 4688.14 - 4742.67 6026369.69 465093.03 MWD +Sag +CA +IIFR +MS 10989.94 75.32 301.94 6199.96 6142.46 - 4641.80 - 4820.70 6026416.34 465015.20 MWD +Sag +CA +IIFR +MS 11075.39 75.26 305.69 6221.66 6164.16 - 4595.82 - 4889.36 6026462.60 464946.74 MWD+Sag+CA+I IFR+MS 11105.07 75.28 303.47 6229.21 6171.71 - 4579.53 - 4912.99 6026478.98 464923.18 MWD +Sag +CA +IIFR +MS 11184.67 79.05 303.10 6246.89 6189.39 - 4536.94 - 4977.86 6026521.83 464858.49 MWD +Sag +CA +IIFR +MS 11278.65 80.10 303.29 6263.90 6206.40 - 4486.34 - 5055.20 6026572.74 464781.36 MWD +Sag +CA +IIFR +MS 11377.02 82.80 304.84 6278.52 6221.02 - 4431.86 - 5135.77 6026627.54 464701.02 MWD +Sag +CA +IIFR +MS 11473.50 87.93 307.57 6286.31 6228.81 - 4375.07 - 5213.33 6026684.64 464623.70 MWD +Sag +CA +IIFR +MS 11520.45 87.21 309.39 6288.31 6230.81 - 4345.89 - 5250.05 6026713.97 464587.10 MWD +Sag +CA +IIFR +MS 11570.00 89.82 311.60 6289.59 6232.09 - 4313.72 - 5287.71 6026746.28 464549.57 MWD +Sag +CA +IIFR +MS Halliburton Company Survey Report Company: Pioneer Date: 811//2008 Time: 10 :45:28 Page: 4 Field: Pioneer ASP Zone 4 Co- ordinate(NE) Reference: Well: ODSN -40, True North Site: Oooguruk ODS Vertical (TVD) Reference: RKB 57.5: 57.5 Well: ODSN -40 Section (VS) Reference: Well (0.00N,0.00E,244.85Az1) Wellpath: OSDN -40PB2 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 11602.91 92.23 312.46 6289.00 6231.50 - 4291.70 - 5312.15 6026768.41 464525.23 MWD +Sag +CA +IIFR +MS 11634.50 93.01 312.92 6287.56 6230.06 - 4270.30 - 5335.35 6026789.89 464502.12 MWD +Sag +CA +IIFR +MS 11665.02 93.37 313.03 6285.86 6228.36 - 4249.53 - 5357.64 6026810.75 464479.91 MWD +Sag +CA +IIFR +MS 11712.47 95.12 313.50 6282.35 6224.85 - 4217.10 - 5392.10 6026843.32 464445.59 MWD +Sag +CA +IIFR +MS 11762.66 96.79 314.61 6277.14 6219.64 - 4182.39 - 5427.97 6026878.17 464409.86 MWD +Sag +CA +IIFR +MS 11858.89 95.77 314.64 6266.61 6209.11 - 4115.20 - 5496.05 6026945.63 464342.06 MWD +Sag +CA +IIFR +MS 11954.54 94.97 314.42 6257.66 6200.16 - 4048.41 - 5563.94 6027012.68 464274.45 MWD +Sag +CA +IIFR +MS 12051.41 96.41 314.26 6248.06 6190.56 - 3981.04 - 5632.87 6027080.32 464205.80 MWD +Sag +CA +IIFR +MS 12148.35 95.72 313.37 6237.82 6180.32 - 3914.31 - 5702.43 6027147.34 464136.52 MWD +Sag +CA +IIFR +MS 12245.05 96.60 312.31 6227.44 6169.94 - 3848.94 - 5772.93 6027212.99 464066.29 MWD +Sag +CA +IIFR +MS 12341.81 95.71 312.22 6217.06 6159.56 - 3784.23 - 5844.12 6027277.97 463995.37 MWD +Sag +CA +IIFR +MS 12438.09 96.90 312.76 6206.49 6148.99 - 3719.60 - 5914.69 6027342.89 463925.08 MWD +Sag +CA +IIFR +MS 12532.87 95.90 311.67 6195.93 6138.43 - 3656.31 - 5984.44 6027406.45 463855.58 MWD +Sag +CA +IIFR +MS 12630.73 97.53 312.59 6184.48 6126.98 - 3591.12 - 6056.52 6027471.92 463783.78 MWD +Sag +CA +IIFR +MS 12726.81 96.84 313.16 6172.47 6114.97 - 3526.26 - 6126.38 6027537.06 463714.19 MWD +Sag +CA +IIFR +MS 12824.11 92.97 312.83 6164.15 6106.65 - 3460.16 - 6197.27 6027603.44 463643.57 MWD +Sag +CA +IIFR +MS 12920.87 93.99 313.18 6158.27 6100.77 - 3394.29 - 6267.90 6027669.59 463573.22 MWD +Sag +CA +IIFR +MS 13017.35 98.11 315.06 6148.11 6090.61 - 3327.52 - 6336.76 6027736.63 463504.64 MWD +Sag +CA +IIFR +MS 13113.51 97.39 314.78 6135.14 6077.64 - 3260.24 - 6404.23 6027804.18 463437.45 MWD +Sag +CA +IIFR +MS 13210.30 96.83 315.37 6123.16 6065.66 - 3192.24 - 6472.05 6027872.45 463369.91 MWD +Sag +CA +IIFR +MS 13306.02 95.40 314.15 6112.96 6055.46 - 3125.23 - 6539.63 6027939.73 463302.61 MWD +Sag +CA +IIFR +MS 13359.00 95.40 314.15 6107.98 6050.48 - 3088.49 - 6577.48 6027976.62 463264.92 PROJECTED to TD • Page 1 of 3 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, October 16, 2008 3:04 PM To: Vaughan, Alex' Cc: Hazzard, Vance; Polya, Joe; Franks, James; Campoamor, Kathy Subject: RE: Current Oooguruk Well Status as of 10/16/2008 Alex, et al, Thanks much for the updated information. Looking at the information and cross checking our files, I only found one well that may need some paperwork filed; ODSN -39. If no activity is likely on this well until springtime, it is appropriate for Pioneer to file a 404 with attachments for the operational SD as was done with K -35, K -36 and N- 34. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: Vaughan, Alex [mailto:Alex.Vaughan @pxd.com] Sent: Thursday, October 16, 2008 2:09 PM To: Maunder, Thomas E (DOA) Cc: Hazzard, Vance; Polya, Joe; Franks, James; Campoamor, Kathy Subject: Current Oooguruk Well Status as of 10/16/2008 Tom, Well Name PTD Completion Date- Comment Status ODSDW 01 -44 207 -140 1/27/2008 Active Disposal Well ODSK -35 207 -181 2/12/2008 Surface Casing Set ODSK -36i 207 -182 2/4/2008 Surface Casing Set ODSK -33 207 -183 4/29/2008 Active Kuparuk Producer ODSN -34i 207 -184 2/17/2008 Surface Casing Set ODSN -31 208 -003 n/a Not Spudded ODSN -32 208 -004 n/a Not Spudded ODSN -40 208 -039 8/1/2008 Active Nuiqsut Producer ODSN -39i 208 -040 5/7/2008 Surface Casing Set ODSN -45i 208 -100 10/15/2008 Intermediate Casing Set, temporarily abandoned, likely to be side tracked ODSN -43 208 -139 n/a Not Spudded ODSK -41 208 -147 n/a Not Spudded, Spud 10/16/2008 ODSK -38 208 -148 n/a Not Spudded ODSN -37 n/a n/a Not Spudded The following is the current schedule as of 10/16/2008. We will be submitting the ODSN -37 Surface Casing Depth Change Sundry middle of next week, Drill Start Da y s Drill End Date Date 10/20/2008 Paoe2of3 • �N�� �� — �� �� � � �JDSN~45i-|N13-S,|-/\CJ��{�{�approved , ::;:' , 8/2/2048: � 74'0 10/15/2008. ODSK-41 ' Kup F (Horiz) - S . 10/15/2008:. 64 �1:4/21/200 � � �- «JQS>�-38i - Kup D (Slant) -S 5�O . 1 | ��OSN-37-PN8-S '' 5.7 11/2/2008 ODSK-38i -Kup O (Slant) - P,C 11/2/2008 15.1 11/17/2808 ODSN'37-PN8 '| 11/17/2008 13.0 11/30/2008 {JOSN-41 'KupF(Hmriz) -| 11/30/2008 32.9 1/2/2008 Alex Vaughan Operations Drillin Engineer PIONEER NATURAL RESOURCES 9O7.34321O6(nffice) 907.748.5478 (mobile) QO7.34321Q0(fax) From: Polya, Joe Sent: Wednesday, October 15, 2008 4:38 PM To: Vaughan, Alex Subject: FW: Current Oooguruk Well Status - Again Alex, Please review the attached and lets make ourselves a duplicate spreadsheet whereby we can track and ensure that we have all the applicable permits submitted and approved for our various wells in their array of stages toward completion. ".~_~._--, Pge Pdiet Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer jVc.pol'n(c Main Office: (907) 277-2700 Direct: (907) 343-2111 Fax: (907) 343-2192 Mobile: (907) 244-0668 From: Maunder, Thomas E (DOA) [mailto:tnnn.maunder©alaskn.00v] Sent: Tuesday October 14, 2008 10:01 AM To: Maunder, Thomas E (DOA); Polya, Joe Subject: RE: Current Oooguruk Well Status - Again Joe, I know you have been busy with ODSN-45, but I would appreciate if you or one of your staff could fill out the table below. Thanks in advance. Tom Maunder, PE AOGCC Page 3 of 3 From: Maunder, Thomas E (DOA) Sent: Friday, October 03, 2008 12:00 PM To: Polya, Joe Subject: Current Oooguruk Well Status Joe, As you know, I am reviewing the permit applications for ODSK -41 and -38. In the course of that review, I have prepared a list of the permits issued to date for the Oooguruk project. I realize that Pioneer has encountered drilling difficulties that have resulted in halting operations on some of the wells. Also, halting operations was planned due to the seasonal drilling restriction for some of the Kuparuk wells. Would you or one of the engineers complete the following table for the ODS wells? I have included the information I have available. It is possible that I have not seen all the paperwork that has been filed. I am particularly interested in wells that have been spudded and then operations halted. I expect that we will exchange a few messages to get things all filled out. Call or message with any questions. Tom Maunder, PE AOGCC Well Name PTD Completion Date- Comment Status ODSDW 01 -44 207 -140 1/27/08 WDSP1 _ ODSK -35 207 -181 ODSK -36 207 -182 ODSK -33 207 -183 4/29/08 1 -oil Initial production well. ODSN -34 207 -184 ODSN -31 208 -003 ODSN -32 208 -004 ODSN -40 208 -039 8/1/08 1-oil ODSN -39 208 -040 ODSN -45 208 -100 ODSN -43 208 -139 ODSK -41 208 -147 Permit under review ODSK -38 208 -148 Permit under review Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 10/20/2008 1 1 :11:7; Pri PIONEER NATURAL RESOURCES, INC. Letter of Transmittal Date: August 25, 2008 From: Doug Waters To: Christine Mahnken Pioneer Natural Resources AOGCC 700 G Street, Suite 600 333 W. 7 Avenue, Suite 100 Anchorage AK 99501 Anchorage, AK 99501 Information Transmitted: ODSN-40, ODSN-40PB2 and ODSN-40PB1 Mudloq Data Two (2) additional End of the Well Reports Or )46° 3c1 4R E C E C AUG 2 6 2006 Received by: E Please sign and return one copy to: Pioneer Natural Resources, Inc. Attn: Doug Waters/Shannon Kim 700 G Street, Suite 600, Anchorage AK 99501 907-343-2190 fax 0 • cv •J PIONEER NATURAL RESOURCES INC. „,...,,„ ‘, ,, t Letter of Transmittal Part2of2 Date: August 4, 2008 From: Doug Waters To: Steve Davies Pioneer Natural Resources AOGCC 700 G Street, Suite 600 333 W. 7 Avenue, Suite 100 Anchorage AK 99501 Anchorage, AK 99501 Information Transmitted: ODSN -40, ODSN -40PB2 and ODSN -40PB1 Mudloq Data (Logs, Reports, CDs) End of the Well Report Data on CD (Reports /Logs /ascii)- lncluded ODSN - 40 1 Print - 2" MD Mudlog (153'- 18364') 1 Print - 5" MD Mudlog (153'- 18364') 1 Print - 5" TVD Mudlog (153- 6287') 1 Print - 2" MD Engineering log (153- 18364') 1 Print - 2" MD, Gas Ratio Log (153'- 18364') ODSN -40PB2 1 Print - 2" MD Mudlog (153' - 13359') 1 Print - 5" MD Mudlog (153'- 13359' 1 Print - 2" MD Engineering log (153 - 13359') 1 Print - 2" MD, Gas Ratio Log (153'- 13359') ODSN -40PB1 1 Print - 2" MD Mudlog (153'- 8764') 1 Print - 5" MD Mudlog (153'- 8764') 1 Print - 5" TVD Mudlog (153- 5349') 1 Print - 2" MD Engineering log (153- 8764') 1 Print - 2" MD, Gas Ratio Log (153'- 8764') . -t L i . Received by: /_ Date: t', >, �,r Please sign and return one copy to: Pioneer Natural Resources, Inc. Attn: Doug Waters /Shannon Kim 700 G Street, Suite 600, Anchorage AK 99501 907 - 343 -2190 fax avly-034 ,,, /cj -( II • Q, RESOURCES 'CES r C Letter of Transmittal Part 1 of 2 Date: August 4, 2008 From: Doug Waters To: Steve Davies Pioneer Natural Resources AOGCC 700 G Street, Suite 600 333 W. 7 Avenue, Suite 100 Anchorage AK 99501 Anchorage, AK 99501 Information Transmitted: ODSN -40, ODSN -40PB2 and ODSN -40PB1 LWD DATA (Logs, Reports, CDs) ODSN -40 1 Print — MD 1:240 LWD Triple Combo 1 Print — MD 1:600 LWD Triple Combo 1 Print — TVD 1:240 LWD Triple Combo 1 Print — TVD 1:600 LWD Triple Combo 1 CD — LWD Data LAS, DLIS & Graphic logs (PDF, EMF & CGM) ODSN -40PB2 1 Print — MD 1:240 LWD Triple Combo 1 Print — MD 1:600 LWD Triple Combo 1 Print — TVD 1:240 LWD Triple Combo 1 Print — TVD 1:600 LWD Triple Combo 1 CD — LWD Data LAS, DLIS & Graphic logs (PDF, EMF & CGM) ODSN -40PB1 1 Print — MD 1:240 LWD Triple Combo 1 Print — MD 1:600 LWD Triple Combo 1 Print — TVD 1:240 LWD Triple Combo 1 Print — TVD 1:600 LWD Triple Combo 1 CD — LWD Data LAS, DLIS & Graphic logs (PDF, EMF & CGM) Received by: ,, Date: Please sign and return one copy to: Pioneer Natural Resources, Inc. Attn: Doug Waters /Shannon Kim 700 G Street, Suite 600, Anchorage AK 99501 907 - 343 -2190 fax 6 39 / / to / to 3 • 4110 cc?, TT 4\1T cycl y a � j n SARAH PAL1N, GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COM IISSIOIQ ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Joe Polya Senior Staff Drilling Engineer Pioneer Natural Resources Alaska Inc, 700 G. Street Ste 600 Anchorage, AK 99501 Re: Oooguruk Field, Oooguruk - Nuiqsut Oil Pool, ODSN -40 Sundry Number: 308 -264 Dear Mr. Polya: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, 4 Daniel T. Seamount, Jr. ,/ Chair DATED this day of July, 2008 Encl. R PIONEER. - : rfi NATURAL RESOURCES ALASKA, INC. July 25, 2008 ;, State of Alaska : Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Sundry Notice to run short 4 -1/2" Liner, ODSN -40 Surface Location: 2,922' FSL, 1144' FEL, T13N, R7E, UM X = 469,854.21; Y = 6,031,038.1, ASP 4 NAD27 As previously discussed, Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for Sundry Approval to run a short 4 -1/2" Liner in ODSN -40. While geo- steering the 6 -1/8" lateral hole section a fault was encountered at 11600' md. This fault was upthrown -120 feet which resulted in the lateral penetrating the Nechelik formation on the other side of the fault. The well was turned up and the Jurassic shale underlying the base of the Nuiqsut formation was encountered enroute to drilling back into Zone 5 of the Nuiqsut formation. In an effort to ensure borehole stabilibilty and preserve access to the 6034' and of lateral on the other side of the Jurassic Shale, a short liner was installed which is a combination slotted pipe across Zone 1 Nuiqsut from the 7" Casing Shoe at 11066' and to the fault at 11600' md; blank pipe across the Fault, Nelchelik and Jurassic Shale to 12270' md; and slotted pipe to 12416' and across Zone 5 Nuiqsut. The remainder of the completion will be in accordance to the approved Permit to Drill (208 -039). Please find attached information for your review: 1) Form 10 -403 Application for Sundry. 2) Documentation on the current well conditions and justification for running a Liner. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vance Hazzard, Drilling Superintendent (20 AAC 25.070) (907) 343 -2116 vance.hazzard@pxd.com 2) Geologic Data and Logs Doug Waters, Operations Geologist (20 AAC 25.071) (907) 343 -2133 doug.waters @pxd.com Sincerely, e Polya Senior Staff Drilling Engineer Attachments: Form 10 -403 Supporting information cc: ODSN -40 Well File 700 G STREET, STE 600 • ANCHORAGE, ALASKA 99501 MAIN (907) 277 -2700 STATE OF ALASKA , \ ' O ALASKA OIL AND GAS CONSERVATION COMMISSION 1 J ", r 2O, *► APPLICATION FOR SUNDRY APPROVALS, . . ^ 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational shutdown ❑ Perforate ❑ Waiver ❑':. , _ y a Other ❑ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ Change approved program 0 . Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Pioneer Natural Resources Alaska Inc. Development 0 Exploratory ❑ 208 -039 ' 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 700 G Street, Suite 600 Anchorage, AK 99501 50- 703 - 20571 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: • ODSN -40 Spacing Exception Required? Yes ❑ No 0 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 355037 / ADL 355036 56' MSL • Ooogurk - Nuiqsut Oil Pool ' 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18364' 6160' 18364' 6160' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 16" 153' 153' N/A N/A Surface 3370' 9 -5/8" 3409' 2998' 5750 3090 Intermediate 11029' 7" 11066' 6219' 7240 5410 Production 10739' 2 -7/8" 10805' 6153' 13450 13890 Liner (Slotted /Blank) 1479' 4 -1/2" 12416' 6209' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Open Hole N/A 2 -7/8" L -80 10739' Packers and SSSV Type: Packers and SSSV MD (ft): HES ScSSSV; ESP Packer 748'; 4685' 13. Attachments: Description Summary of Proposal II 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Development la Service ❑ 15. Estimated Date for 16. Well Status after proposed work: 7/19/2008 Commencing Operations: Oil El Gas ❑ Plugged ❑ Abandoned ❑ 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Polya, 343 -2111 Printed Name Joe Polya Title Senior Staff Drilling Engineer Signature Phone 343-2111 Date 7/25/2008 COMMISSION USE ONLY /, Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,S ..4 pb.L/ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: 'CGtizct' \c..s‘tc;,,`Nr, J '-0-. it �v� ( Gk C-\ APPROVED BY J 7 2,"( 7 Approved by: . COMMISSIONER THE COMMISSION Date: / / Form 10 -403 Revised 06/2006U R 1G1NAL R' • S BFL„1UL 3 0 2008 °% "" t i up irate 7.2tds ODSN -40 All Status with Propos 4 -1/2" Liner Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 2 -7/8 ", 5K, Horizontal Vent Valves Control Line 16" Conductor 153' MDrkb / 153' TVDrkb 2 -7/8" HES ScSSSV, 2.313" ID @ 748' MDrkb / 748' TVDrkb 9 -5/8 ", 40# L -80 BTC, 8.835" ID 1 3409' MDrkb / 2998' TVDrkb X Nipple, 2.313" ID @ 4641' MD $ 2 -7/8" GLM @ 3972' MDrkb / 3320' TVDrkb 7" x 2 -7/8" Dual ESP Packer © X Nipple, 2.313" ID w RHC -M 4685' MDrkb / 3730' TVDrkb Profile @ 4701' MD 2 -7/8 ", 6.5# L -80 IBT-M 2 -7/8" GLM © 9193' MDrkb / 5682' TVDrkb ESP Cable O O O 2 -7/8" Durasleeve Sliding Sleeve, 2.313" ID @ 10649' MDrkb / 6115' TVDrkb ■ Estimated Top of Cement @ 9991' XN Nipple, 2.205" ID Nogo MD / —5835' TVDrkb © 10693' MDrkb / 6126' TVDrkb 81 degrees ESP @ 10739' MDrkb / 6151' TVDrkb 11066' MDrkb / 6219' TVDrkb 6 -1/8" Open Hole 7 ", 26# L -80 BTC -M, 6.276" ID 4-W, 12.6# L80 BTC Liner Top © 10937' and Slotted Liner from 7" Casing Shoe to Fault at 11600' and J Blank Liner f/ Fault @ 11600' to Bottom Zone 5 Nuiqsut @ 12270' and and Slotted Liner to 12416' in Zone 5 Nuiqsut 18364' MDrkb / 6160' TVDrkb = Date: Revision By: Comments of 5/2/2008 JDF Proposed Completion 7/25/2008 JDP Proposed 4 1 A" Liner ODSN -40 Producer • Well Schematic PIONEER NATURAL RESOURCES • • Page 1 of 3 Maunder, Thomas E (DOA) From: Polya, Joe [Joe.Polya©pxd.com] Sent: Wednesday, June 25, 2008 11:45 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: Upcoming BOPE Test for Nabors 19AC for ODSN -40 Mr. Maunder, The dates the BOPE Tests have been conducted on ODSN -40 are as follows: • 5/13/08 • 5/21/08 • 5/28/08 • 6/03/08 • 6/9/08 • 6/16/08 • 6/25/08 — Testing Today for 7" casing run as per our email request The Drill Site Leader discussed the BOP test due on 6/23/08 with the field inspectors and they informed him that they had the authority and did grant the extension to test the BOPE when we pulled out of the hole to run 7" casing. However, they did inform Rod that we would have to request permission to not test the 5" in the lower pipe body rams from AOGCC Representatives in Anchorage, hence my request. I hope this addresses your questions. On another note, I am preparing to send the formal request for increasing the BOPE Test cycle from 7 days to 14 days for the Nabors 19AC Rig at Oooguruk. 7 4mk 9oe Po4a Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya @pxd.com Main Office: (907) 277 -2700 Direct: (907) 343 -2111 Fax: (907) 343 -2192 Mobile: (907) 244 -0668 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, June 25, 2008 8:01 AM To: Polya, Joe Subject: RE: Upcoming BOPE Test for Nabors 19AC for ODSN -40 Joe, Further to this message on not testing the 5" rams, could you please provide me with the dates BOP tests have been conducted on this well? 7/22/2008 Page 2 of 3 I believe you and I had discussed an extension earlier in this hole section. Lately, I seem to remember that when the well reached TD that a request for extension was requested from the rig to the Inspectors and that the request was going to come to either Jim or I. Did that occur? Thanks in advance. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, June 24, 2008 6:28 PM To: Polya, Joe Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Franks, James; Campoamor, Kathy Subject: RE: Upcoming BOPE Test for Nabors 19AC for ODSN -40 Joe, It is acceptable to test everything but the 5" rams prior to running the 7" casing. Call or message with any questions. Tom Maunder, PE AOGCC From: Polya, Joe [mailto:Joe.Polya @pxd.com] Sent: Tue 6/24/2008 5:16 PM To: Maunder, Thomas E (DOA) Cc: OoogurukDrillingSupervisor; Hazzard, Vance; Franks, James; Campoamor, Kathy Subject: Upcoming BOPE Test for Nabors 19AC for ODSN -40 Mr. Maunder, As per our discussion this afternoon the Nabors 19AC rig crew is currently POOH with the 8 -3/4" drilling assembly after reaching TD of the intermediate hole section. • Prior to running the 7" casing, the top set of pipe rams will be changed to 7" and 5" dp rams will be left in the bottom set. • The annular and the top set of pipe rams will be tested against the 7" casing test joint as per the BOPE Test Pressures specified in the ODSN -40 Drilling Permit. • All floor valves and safety valves will be tested. • The bottom pipe rams will receive a full body test during the blind /shear ram test; however, the rig will not be testing the bottom rams around 5" drill pipe since the next operations is to run the 7" long string. • The choke manifold will be tested out of the critical path while POOH with the drilling assembly — the Drill Site Leader has already cleared this with the AOGCC North Slope Inspector. • After the 7" casing is run, both pipe rams will be fitted for 4" drill pipe and a complete BOPE test will be performed. 'Nada, Poe Po €ya Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya @pxd.com Main Office: (907) 277 -2700 Direct: (907) 343 -2111 7/22/2008 Page 1 of 2 • Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Friday, July 11, 2008 12:29 PM To: Maunder, Thomas E (DOA) Subject: FW: Request for BOPE Test Extension for Nabors 19AC on the ODSN -40 well I have no problem with the request; next well should be moved to testing interval not to exceed 14 days Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 _ s -CYS From: Polya, Joe [mailto:Joe.Polya ©pxd.com] Sent: Friday, July 11, 2008 11:45 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Hazzard, Vance; Franks, James; OoogurukDrillingSupervisor Subject: Request for BOPE Test Extension for Nabors 19AC on the ODSN -40 well Mr. Regg and Mr. Maunder, Pioneer is requesting extension for the BOPE Test currently scheduled for Saturday July 12, 2008 for the Nabors 19AC Rig while drilling the ODSN -40 well. Current Drilling Conditions and Pertinent Information: • Nabors 19AC is currently operating with the 7 Day BOPE Test Cycle. • The Nabors 19AC Crew is currently drilling ahead at 16,421' and in the 6 -1/8" production lateral. • The 7" casing shoe is landed into the Nuiqsut formation at 11066' and - Projected TD is approximately 19000' and and we are averaging -1000 feet per day. • The last BOPE Tests were performed as follows: o 7/05/08 - Pulled BHA due to Rotary Steerable BHA - tested BOPE while on bank. o 6/29/08 - Tested BOPE for 4" dp after running 7" Intermediate Casing String. o 6/25/08 - Tested ram and annular and associated BOPE for 7" casing run. • We have the following time limitations with the current Rotary Steerable /Geo Steering BHA which is really driving this extension request. o Rotary Steerable Battery Life (functions the push pad) has -50 hours remaining - this battery dies and we are done steering. o MWD /LWD Battery Life also has -50 hours left; however, we can get real time data and calculate directional without this. o Azimuthal Density will run out any time. o and EWResistivity will run out in -80 hours. Forward Plan is to TD the lateral @ - 19,000, Wiper Trip to 7" casing shoe, POOH, Test BOPS and RIH with 4- 1/2" slotted /blank liner to cover approximately 1200' of the intermediate hole right out of the shoe. If we need to trip for any tool failures, we will test BOPE with bit at surface. Thank you in advance for your time and consideration of this matter. 7/11/2008 Page 2 of 2 P Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya @pxd.com Main Office: (907) 277 -2700 Direct: (907) 343 -2111 Fax: (907) 343 -2192 Mobile: (907) 244 -0668 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 7/11/2008 Maunder, Thomas E (DOA) From: Polya, Joe [Joe.Polya ©pxd.com] Sent: Sunday, June 08, 2008 1:54 PM To: OoogurukDrillingSupervisor Cc: Maunder, Thomas E (DOA); Hazzard, Vance; Franks, James; Cody, Rick; Regg, James B (DOA) Subject: Granted permission to NOT tag 2nd Plug. RE: Update and Request for ODSN -40 Plug Back of Intermediate Hole Section. Jim, I just received a call from Mr. Regg with AOGCC regarding the requirement to tag the 2nd cement plug and the BOPE Test. Two things: 1. He granted us permission to proceed without requiring the tagging of the 2nd cement plug based on the confirmation of the first cement plug with adequate coverage (288' md) above the Top of the Torok Zone. 2. He wanted to ensure we called the North Slope Inspector and gave him the opportunity if possible (weather and chopper flights permitting) to witness the BOPE test. I assured him you would do so. thanks, joe polya 907 - 244 -0668 From: Polya, Joe Sent: Sun 6/8/2008 1:35 PM To: Polya, Joe; jim.regg @alaska.gov Cc: Maunder, Thomas E (DOA); Hazzard, Vance; Franks, James; OoogurukDrillingSupervisor; Cody, Rick Subject: Update and Request for ODSN -40 Plug Back of Intermediate Hole Section. Mr. Regg, I am requesting permission from the AOGCC to waive the necessity to tag the second cement plug based on the following: 1. The first cement plug was tagged with 6K -lbs weight with a 3 -1/2" half mule shoe -- all indications are the rig team executed the plug with excellent placement results. 2. The tag was performed with 20 rpm, 200 gpm and 6K -lbs @ 7647' and which is 288' above the Top of the Torok Disposal Zone @ 7935' md. The first plug was calculated for 1000' length plus 15% excess -- as a result it covered 1147' from 8764' and (total depth of 8 -3/4" intermediate hole section) to 7647' md. * The rig lost a total of 10 bbls during placement which mostly occured while displacing cement and the well was static with no losses after pulling 13 stands and circulating bottoms up. * 1 The spotting procedure calls for a weighted spacer after the water ahead and the same with the water behind -- I am confident that practices greatly improves the cemetn placement process with the 4" drill pipe stinger in the 70 degree hole interval. There was about 20 bbls of contamiated mud with no sign of cement back to surface. 3. The rig team is in the process of pumping a second 500 feet length cement plug which should leave the top of cement at approximately 7150' md. 4. As you recall in the original notification, we are planning to perform an openhole sidetrack by lowsiding with the rotary steerable assembly at -5100' md. I have contacted the North Slope Inspector and also talked to Mr. Tom Maunder -- since I informed you via email on Friday of the intent to tag the first and last plugs, the North Slope Inspector does not feel comfortable granting my request. Given the losses Pioneer experienced before spotting the cement plugs, I did not feel we would cover the entire Torok Zone plus 100 feet with one plug; however, we did -- therefore, I am making this request. The reason Pioneer is pumping the second plug is we did induce losses associated with a packoff while RIH with Rotary Steerable assembly at 7500' and and our original intent is to bring cement up to 7300' and minimum. If I have not heard back from you after spotting the second cement plug, my plan it to have the rig POOH perform the weekly BOPE test, MU the Rotary Steerable Assembly for sidetracking the well. Should AOGCC require that Pioneer tag the second plug, this would be perfromed prior to sidetracking the well; however, Pioneer would prefer not spend the rig time and avoid any unnecessary risk related to RIH with the expensive Rotary Steerable BHA into the -2000' and of hole between the 5100' and kickoff point and the calculated top of cement plug #2 at -7150' md. I will look forward to your call either today or Monday morning when you return to the office. thanks for you assitance in this matter. Joe Polya Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya @pxd.com Main Office: (907) 277 -2700 Direct: (907) 343 -2111 Fax: (907) 343 -2192 Mobile: (907) 244 -0668 From: Polya, Joe Sent: Fri 6/6/2008 5:02 PM To: jim.regg @alaska.gov Cc: Maunder, Thomas E (DOA); Hazzard, Vance; Franks, James Subject: Notificatoin of Plans to Plug back and open hole sidetrack the ODSN -40. 2 . • Mr. Regg, As per out telephone conversation, Pioneer is planning to set an cement plug from our current total depth of 8764' and to -7300' in the 8 -3/4" intermediate hole section of the ODSN -40 wellbore. The following criteria apply for the cement plug: 1. The Top and Base of the Torok Disposal Zone is 7935' and and 8500' md, respectively. 2. We plan to tag the first plug and final plug to confirm 500 psi compressive strength. 3. The estimated cement volume will be 125 bbls with 15% excess. 4. The rig is currently drilling with 5" drill pipe and plans are to use a 1000 feet of 4" drill pipe for a stinger to set the balanced cement plugs (2 @ approximately 750 feet each). a. Currently BOPE has 5" rams in both the top and bottom rams and Pioneer is requesting that we treat the 1000' of 4" dp as a bha and not change out rams for this stinger? The following criteria apply to the sidetrack: 1. Pioneer will sidetrack up the hole at 5100' without the aid of a cement sidetrack plug by simply low siding the well in a dogleg that has been identified. 2. Pioneer will drill to the Nuiqsut objective already identified in the approved drilling permit. Thanks, Joe Polya Pioneer Natural Resources Alaska, Inc. Sr. Staff Drilling Engineer joe.polya @pxd.com Main Office: (907) 277 -2700 Direct: (907) 343 -2111 Fax: (907) 343 -2192 Mobile: (907) 244 -0668 *************************************** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 3 • • Page 1 of I,. Regg, James B (DOA) ► ► ') z .) From: Regg, James B (DOA) Sent: Friday, June 06, 2008 5:46 PM 06 To: 'Polya, Joe' `''tt Cc: Maunder, Thomas E (DOA); Hazzard, Vance; Franks, James Subject: RE: Notificatoin of Plans to Plug back and open hole sidetrack the ODSN -40. Joe - Thank you for providing the information about plug for OSDN -40 (PTD 208 -039) and plans to sidetrack. As noted, Pioneer has not yet penetrated the objective Nuiqsut in this well and has been experiencing ongoing problems with the Torok. The planned plug (volume and placement) is sufficient to isolate the Torok disposal zone and meets the intent of AOGCC regulation. There is no additional paperwork needed for this sidetrack since you are pursuing the same bottomhole objective. You will need to install and test 4" pipe rams to cover the 1000 feet of 4" drillpipe to be used as a cement stinger. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: Polya, Joe [mailto:Joe.Polya @pxd.com] Sent: Friday, June 06, 2008 5:02 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); Hazzard, Vance; Franks, James Subject: Notificatoin of Plans to Plug back and open hole sidetrack the ODSN -40. Mr. Regg, As per out telephone conversation, Pioneer is planning to set an cement plug from our current total depth of 8764' and to —7300' in the 8 -3/4" intermediate hole section of the ODSN -40 wellbore. The following criteria apply for the cement plug: 1. The Top and Base of the Torok Disposal Zone is 7935' and and 8500' md, respectively. 2. We plan to tag the first plug and final plug to confirm 500 psi compressive strength. 3. The estimated cement volume will be 125 bbls with 15% excess. 4. The rig is currently drilling with 5" drill pipe and plans are to use a 1000 feet of 4" drill pipe for a stinger to set the balanced cement plugs (2 @ approximately 750 feet each). a. Currently BOPE has 5" rams in both the top and bottom rams and Pioneer is requesting that we treat the 1000' of 4" dp as a bha and not change out rams for this stinger? The following criteria apply to the sidetrack: 1. Pioneer will sidetrack up the hole at -5100' without the aid of a cement sidetrack plug by simply low siding the well in a dogleg that has been identified. 2. Pioneer will drill to the Nuiqsut objective already identified in the approved drilling permit. 6/6/2008 Page 1 of 2 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, May 20, 2008 4 :13 PM To: Polya, Joe; AOGCC North Slope Office Cc: 'Franks, James'; 'Robert Jackson' Subject: RE: Re: After noon report 5 -19 -08 O US Q \ Joe, � With the 7 -day test interval still applying, it is acceptable to delay the test due today. You have indicated that if this squeeze pill is successful that you should TD the 8 -3/4" section in 3 days and with the BOP test being done when you change your casing rams. If you the squeeze pill does not prove successful, then further discussion needs to be held. This extension is not open- ended. As mentioned, this extension is possible since a 7 -day test interval applies. That test interval should apply for the duration of this well. Call or message with any questions. Tom Maunder, PE AOGCC From: OoogurukDrillingSupervisor [mailto:OoogurukDrlgCm @pxd.com] Sent: Monday, May 19, 2008 4:16 PM To: DOA AOGCC Prudhoe Bay Cc: Polya, Joe; Franks, James; Jackson Jr., Robert Subject: FW: Re: After noon report 5 -19 -08 Chuck, I believe you are still up here, but sending a copy of Forecaster & afternoon report. This is due to having problems w /losses inside the Torok fm., but have an upcoming BOP test tomorrow, (May 20th), and I'm requesting an extension, until coming out for casing, @ which point will perform test prior to running 7 ". I'll keep you in the loop w /daily updates, if required. Please inform me @ below numbers of granting request of variance from the weekly test schedule JB Subject: Re: After noon report 5 -19 -08 FYI, back on bottom drilling ahead, dispite some various losses. Suspended Barafiber additions & just Steel Seal & Baracarb 50/150 for stringing in to control Iosses.....JB Jim Brown Rig Supervisor: Gravel, Snow, & Shallow Water Pioneer Natural Resources (Alaska), Inc. Anchorage Office # 1- 907 - 277 -2700 Home # 1-403- 547 -0825 E mail: jim.brown(c@pxd.com Pioneer Camp On Ooogurak Island, AK Office # 1- 907 -670- 6606/6609 Fax # 1- 907 -670 -6673 Pioneer /Cruz Camp © Hansen - Anchor Pt., AK Office # 1- 907 -226 -2180 *New Contact Numbers* 5/21/2008 • . SARAH PALIN, GOVERNOR ALASKA L SKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 May 6, 2008 James Franks Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G. Street, Ste 600 Anchorage, AK 99501 Re: Oooguruk Field, Oooguruk- Nuiqsut Oil Pool, ODSN -40 Pioneer Natural Resources Alaska, Inc. t-- Permit No: 208 -039 ‘ 40 t -- Surface Location: 2922' FSL, 1144' FEL, SEC. 11, T13N, R7E, UM Dear Mr. Franks: Enclosed for your records is the duplicate copy of Pioneer Natural Resources Alaska, Inc.'s (Pioneer) application to re -issue Permit to Drill No. 208 -039 that was submitted to the Commission on April 28, 2008 and subsequently withdrawn by Pioneer on May 5, 2008. The original copy of this withdrawn application, and all correspondence relating to it, will be placed in the Commission's well history file for well ODSN- 40. All terms and conditions of Permit to Drill No. 208 -039, issued on April 17, 2008, remain in effect for well ODSN -40. Please let us know if you have any questions. Sincerely, Steve Davies Sr. Petroleum Geologist • • RECEIVED l j MAY 0 5 2008 Alaska 011 & Gas Cons, Commission PIONEER Anchorage NATURAL RESOURCES ALASKA, INC. May 1, 2008 Re: Pioneer Request to Withdraw the Recently Submitted ODSN -40 Permit to Drill Application Mr. Maunder, Pioneer would like to withdraw the recent Application to Drill application submitted for the ODSN -40 well. Pioneer's Subsurface Well Planning Team reconsidered the Nuiqsut reservoir intercept location change which prompted this 2nd application and decided to proceed with the original Nuiqsut reservoir intercept reflected in the already approved ODSN -40 Permit to Drill. I sincerely apologize for any confusion or added work scope this 2nd Permit to Drill application may have caused AOGCC. This 2 Permit to Drill Application was necessary due to the Nuiqsut reservoir intercept being moved. This intercept was moved to avoid intercepting a mapped fault while drilling the production lateral -- this was prompted by massive losses associated with drilling through a fault in the Kuparuk production lateral on the recent ODSK -33 well. However, after further consideration the team determined it would be better to intercept this fault in the production lateral rather than higher in the HRZ interval as would be the case with the 2 application. Furthermore Pioneer realizes that the five Nuiqsut wells approved for drilling during the 2008 restricted drilling season were selected based on stringent criteria regarding the Kuparuk intercept — and as a result Pioneer recognizes that changes in this intercept location would require more detailed review by AOGCC, North Slope Borough and Alaska Department of Environmental Conservation. Thank you for your patience and understanding regarding this matter. James Franks 700 G STREET STE 600 ANCHORAGE ALASKA 99501 • MAIN: (907) 277 -2700 . . Maunder, Thomas E (DOA) From: Polya, Joe [Joe.Polya @pxd.com] Sent: Thursday, May 01, 2008 4:28 PM To: Maunder, Thomas E (DOA) Cc: Franks, James; Davies, Stephen F (DOA) Subject: RE: Notification to Withdraw the recently submitted 2nd Application to Drill for the ODSN -40 well (208 -039) Mr. Maunder, --0 3 Thank you for your prompt response and acknowledgement of this matter. James will be delivering a formal letter to follow up this email as per our original dicussion. thanks, joe polya 907 - 244 -0668 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thu 5/1/2008 3:58 PM To: Polya, Joe Cc: Franks, James; Davies, Stephen F (DOA) Subject: RE: Notification to Withdraw the recently submitted 2nd Application to Drill for the ODSN -40 well (208 -039) Joe and James, Your message is acknowledged. A formal letter may be necessary. I will have to check with Steve Davies and he is out until Monday. Call or message with any questions. Tom Maunder, PE AOGCC Original Message From: Polya, Joe [mailto:Joe.Polya @pxd.com] Sent: Thursday, May 01, 2008 3:56 PM To: Maunder, Thomas E (DOA); thomas.maunder @alaska.gov Cc: Franks, James Subject: Notification to Withdraw the recently submitted 2nd Application to Drill for the ODSN -40 well Mr, Maunder, As per our earlier telephone conversation, Pioneer requests that AOGCC disregard the recent Application to Drill submitted for the ODSN -40 well. Pioneer's Subsurface Well Planning Team reconsidered the Nuigsut reservoir intercept location change which prompted this 2nd application and decided to proceed with the original Nuigsut reservoir intercept reflected in the already approved ODSN -40 Permit to Drill. I sincerely apologize for any confusion or added work scope this 2nd Permit to Drill application may have caused AOGCC. The Nuiqsut reservoir intercept was moved to avoid intercepting a mapped fault while drilling the production lateral -- this was prompted by massive losses associate with drilling through a fault in the Kuparuk production lateral on the recent ODSK -33 well. However, after further consideration the team determined it would be better to intecept this fault in the production lateral than higher in the HRZ interval which would be the case in the 2nd application. Furthermore Pioneer realized that the five Nuigsut wells approved for drilling during the 2008 restricted drilling season were selected based on stringent criteria regarding the Kuparuk intercept -- changes in this intercept lcoation 1 • would require more detailed review by AOGCC, North Slope Burourgh and Alaska Department of Environmental Conservation. Thank you for your patience and understanding regarding this matter. Joseph D. Polya Sr. Staff Drilling Engineer Oooguruk Drilling Coordinator Pioneer Natural Resources Alaska 907 - 343 -2111 office 907 - 244 -0668 cell 907 - 343 -2192 fax *************************************** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. *************************************** * * * * * * * * * * * * * * * * * * * * * * * * * * * * * ** Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. • 2 Page 1 of 1 • . Maunder, Thomas E (DOA) From: Franks, James [James.Franks @pxd.com] Sent: Monday, April 28, 2008 10:48 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Campoamor, Kathy Subject: Emailing: ODSN -40 Permit to Drill Request - PTD 208 -039 repermit.PDF Attachments: ODSN -40 Permit to Drill Request - PTD 208 -039 repermit.PDF Tom, Attached is a request for a "repermit" for the ODSN -40 well, originally permitted as 208 -039. The reason for the new permit is to avoid a fault at the heel of the originally permitted well due to the losses we have seen while drilling the ODSK -33 well. As such, the changes to the wellplan from the original are: • Surface casing is set a bit deeper in MD • The heel of the well has moved -2600' down the original lateral, so the intermediate casing is a bit deeper in MD • The formation intersections deeper in the well have changed. Really everything is the same except the well path :). I know this is very short notice, but we are optimistic that we could be ready to drill this well by the beginning of next week. What is the addage... "poor planning on our part does not constitute a crisis on yours "... If it would be possible to get the permit approved in this short of time, that would be great. If not, would we be able to get a verbal on the surface hole portion - that could buy a bit more time for you to eval the rest of the well? I am really sorry for this. I am going to hand carry the hard copies to you as soon as I send this e-mail. Thanks for your time. james Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 5/6/2008 RECEIVED STATE OF ALASKA ALAOOIL AND GAS CONSERVATION COM °ION APR 2 8 2008 PERMIT TO DRILL 20 AAC 25.005 Alaska Oil & Gas C. s. Commission 1a. Type of Work: 1b. Current Well Class: Exploratory ❑ Development Oil ISI 1c. Specify if well is proposed forAnC • rage Drill si Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ s Hydrates ❑ Re -entry ❑ Multiple Zone SI Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket isi Single Well ❑ 11. ell Name and Number: Pioneer Natural Resources Alaska Inc Bond No. 103655283 ODSN -40 ' 3. Address: 6. Proposed Depth: 2. Field/Pool(s): 700 G Street, Suite 600 Anchorage, AK 99501 MD: 16,867' . TVD: 6,247' 4a. Location of Well (Governmental Section): 7. Property Designation: Oooguruk - Nuiqsut • Surface: 2922' FSL, 1144' FEL, Sec. 11, T13N, R7E, UM ADL 355037./ ADL 355036 ' Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 5227.7' FSL, 2778' FEL, Sec 15, T13N, R7E, UM 417497 5/4/2008 • Total Depth: 9. Acres in Property: 14. Distance to Nearest 3651.7' FSL, 742.9' FEL, Sec 9, T13N, R7E, UM 5760 + 5724 = 1 ,484 Property: 19,500' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation ' 7.4 / / 7 4 V , , 15. Distance to Nearest Well Surface: x- 469854.21 . y- 6031038.1 . Zone- ASP 4 (Height above GL): 44 feet ithin Pool: N/A oi. 404 16. Deviated wells: N/A Kickoff depth: 300' • feet 17. Maximum Anticip. ed Pressures in psig (see 2 AAC 25.035) Maximum Hole Angle: 92.15 degrees Downhole: 3088 • .ig ' Surface: 2422 psig . 18. Casing Program: Specifications Top - ' etting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 109# H -40 Welded 109' Surface Surface 153' 153' Driven 12 -1/4" 9 -5/8" 40# L -80 BTC 3550' Surfac Surface 3594' 2995' 431 sx Permafrost 'L'; 203 sx Class 'G' 8 -3/4" 7" 26# L -80 BTC -M 11870' Surf , e Surface 11914' 6117' 187 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To b completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs iz gs Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length „ S Cement Volume MD TVD Conductor /Structural A � Y/ 0� Surface \ ,�, Intermediate Production .t h p \ � � � ^ Liner Perforation Depth MD (ft): \ Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ c • P S ketch IS Drilling Program IS Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat IS Di erter Sketch 0 Seabed Report ❑ Drilling Fluid Program IS 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Represent. ive: Date 4/25/2008 22. I hereby certify that the foregoing is true . d correct. Contact Joe Polya, 343 -2111 Prepared By: Kathy Campoamor, 343 - 2183 Printed Name Jame Franks Title Drilling Engineer 4.-- Signature i�1' Phone 343 -2179 Date 4/25/2008 Commission Use Only Permit to Drill .� 3 O ,, API Number: 0 ,„3 2pJ 71 Permit Approval See cover letter for other Number: ,L!✓� l Date: requirements. Conditions of approval : If box '- checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: IC Other: Samples req'd: Yes❑ No[." Mud log req'd: Yes❑ " Nog H measures: Yes❑ No[" Directional svy req'd: Yes[ No❑ • APPROVED BY THE COMMISSION DATE: , COMMISSIONER Form 10 -401 Revised 12/2005 Submit in Duplicate i.sexze nR‘G\N AL ,,,,../A(A-5 • RECEIVED A tri, 7-74 APR 2 8 2008 Alaska Oil & Gas Cons. Commission Anchorage PIONEER NATURAL RESOURCES ALASKA, INC. April 25, 2008 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSN -40 Surface Location: 2922FSL, 1144FEL, Sec 11, T13N, R7E, UM X = 469854.21, Y = 6031038.10, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a production • well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be a production well in the Oooguruk - Nuiqsut formation. PNRA requests the permit to drill based on Pool Rules - Conservation Order 597. A permit for this well was originally granted as ODSN -40, PTD 208 -039, but due to what we have seen on the ODSK -33, PTD 207 -183, and the losses due to a fault at the heel of that well, we have re- evaluated the risk associated with crossing a fault at the heel of the ODSN -40 well currently permitted. This new Permit to Drill request has the ODSN -40 well heel location -2600' down the lateral, on the other side of a fault originally planned to be crossed. As indicated in the attachments, the drilling program will entail drilling a directional 12'/4' surface hole to approximately 3594' MD / 2995' TVDrkb, where surface casing will be set. An 8 -3/4" directional wellbore will be drilled into and set at the top of the Oooguruk - Nuiqsut interval at approximately 11914' MD / 6117' TVDrkb. The horizontal production interval will be drilled to - 16687' MD / 6267 TVDrkb, the final TD of the well. The proposed casing program will utilize 9%" surface casing, 7" intermediate casing and an open hole completion of the 6 -1/8" hole section. The completion will utilize 2 7/8" tubing and an ESP. Prior to commencement of drilling operations on the ODSN -40 well, the surface hole on ODSN- 39i will have been drilled, cased and suspended. This is to mitigate the risk of wellbore collision and to allow PNRA to run Magnetic Ranging tools into the surface hole of ODSN -39i to further 700 G STREET, STE. 600 ANCHORAGE, ALASKA 99501 • MAIN. (907) 277 -2700 • • Alaska Oil & Gas Conservation Commission April 25, 2008 Page2of3 Virfr PIONEER NATURAL RESOURCES ALASKA, INC aid in reducing the wellbore placement uncertainty while drilling the surface hole of ODSN -40. It is planned to drill and complete ODSN -40 in its entirety. Based on information previously submitted to the AOGCC and included in the AOGCC Oooguruk Field File, PNRA requests an exemption from 20 AAC 25.035 (c) which requires a diverter system be installed on the well while drilling the surface interval. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10 -401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 3) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). e. A summary of the drilling operations. f. A summary of drilling hazards per 20 AAC 25.005 (c) (4). g. A wellbore schematic is also attached visually depicting the proposed well. 4) A copy of the Planned Directional Well Path — including travelling cylinder and development layout plots 5) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19 -AC as required by 20 AAC 25.035 (b) and (c). 6) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 AAC 25.065(1) will be functioning on the rig as standard operating procedure for all 700 G STREET, STE. 600 ANCHORAGE, ALASKA 99501 MAIN: (907) 277 -2700 • • Alaska Oil & Gas Conservation Commission April 25, 2008 Page 3 of 3� PIONEER NATURAL RESOURCES ALASKA, INC. wells drilled by that rig. Products for treating H2s contamination in the drilling mud system will be maintained on the ODS. In the future, PNRA may provide information requesting the permitting of annular disposal of drilling wastes on this well. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Joe Polya, Senior Drilling Engineer (20 AAC 25.070) 907/343 -2111 ioe.polya a(�,pxd.com 2) Geologic Data and Logs Tavia Jackson, Senior Operations Geologist (20 AAC 25.071) 907/343 -2133 tavia. iackson(cr� pxd . com The anticipated spud date for this well is May 4, 2008. If you have any questions or require further information, please contact James Franks at 907.343.2179 or Joe Polya at 907.343.2111. Sincerely, James Franks Drilling Engineer Attachments: Form 10 -401 Supporting permit information cc: ODSN -40 Well File (Re- permit) 700 G STREET, STE. 600 ANCHORAGE, ALASKA 99501 MAIN: (907) 277 -2700 • Oooguruk Well Plan Summary: Permit to Drill ODSN -40 - Nuiqsut Production Well Surface Location: 2922' FSL, 1144' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X = 469854.21 1 Y = 6031038.1 1 Target: 5227.7' FSL, 2778' FEL, Sec 15, T13N, R7E, UM X = 462932.00 1 Y = 6028095.00 1 6,117' TVDrkb Bottom Hole Location: 3651.7' FSL, 742.9' FEL, Sec 9, T13N, R7E, UM X = 459698.90 1 Y = 6031815.10 ( 6,267' TVDrkb AFE Number: 14865 Est. Start Date: May 4, 2008 1 Rig: Nabors 19AC Operating days: 32.4 days Drill and Complete TD: 16,867 MD / 6,267 TVDrkb Objective: Nuiqsut 1 Well Type (exp, dev, etc): Development Well Design (conventional, slimhole, etc): Ultra -slim hole - Producer Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' RKB to Ground Level: 44' Rig Elevation: RKB + MSL = 57.5' Conductor: 153' MDrkb Well Control: Based on calculations below, BOP equipment will be tested to 3,500 psi. Surface Section: • Maximum anticipated BHP: 1314 psi @ 2938' TVDss (Based on seawater gradient of 0.4472 psi /ft) • Maximum surface pressure: 991 psi @ surface (Based on BHP and a full column of gas from TD CO) 0.11 psi /ft) Intermediate Section: • Maximum anticipated BHP: 3088 psi @ 6059' TVDss • Maximum surface pressure: 2422 psi @ surface • (Based on BHP and a full column of gas from TD OP 0.11 psi /ft) Production Hole Section: • Maximum anticipated BHP: 3088 psi CP 6059' TVDss • Maximum surface pressure: 2422 psi @ surface (Based on BHP and a full column of gas from TD 0.11 psi /ft) Planned BOP test pressure: 3500 psi (annular to 2500 psi) Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Pioneer Natural Resources Last Revised: April 25, 2008 ODSN -40 Permit To Drill — adjusted heel location Page 1 of 8 1 • Diverter (see attached schematic): Hydril 21 -1/4" 2M annular BOP 1 16" full opening knife gate valve, hydraulically actuated 16" diverter line 5000 psi BOP stack (see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11" 5M single ram BOP w/ studded connections Hydril 11" 5M single ram BOP w/ studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3 -1/8" 5M side outlets w /flanged connections 2 ea. 3 -1/8" 5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3 -1/8" 5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/ studded connections Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 9 -5/8" Surface Shoe Rathole + 20' to 50' from 9 -5/8" shoe LOT 12.0 ppg 7" Intermediate Shoe Rathole + 20' to 50' from 7" shoe FIT 13.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 12 -1/4" hole S ud Mud Interval Density (ppg) Viscosity (secs) YP PV 10 sec gel API FL Initial 8.8 150 -200 35 - 50 15 -25 10 - 15 unrestricted Final 9.2 -9.6 70 -100 25 - 35 15 - 25 10 - 15 <12 Intermediate Hole Mud Properties: 8 -3/4" hole MOBM Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial 11.0 -11.5 40 -60 15 -25 15 -20 <12 6 -8 HRZ to TD 12.5 40 - 60 15 - 25 20 - 30 < 15 3 - 5 (8 -10 HTHP) Production Hole Mud Properties: 6 -1/8" hole MOBM Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial 10.4 40 - 60 15 - 25 15 - 20 0 <4 Disposal: Annular Infection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Pioneer Natural Resources Last Revised: April 25, 2008 ODSN -40 Permit To Drill — adjusted heel location Page 2 of 8 • • Hydraulics: Surface Hole: 12 -1/4" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Surf to BPRF 550 4" 15.7# 90 1800 10.0 N/A 18,18,18,16 .942 BPRF to TD 650 4" 15.7# 110 2400 10.2 N/A 18,18,18,16 .942 Intermediate Hole: 8 - Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ("/32) Surf Shoe to TD 550 4" 15.7# 215 4500 13.8 N/A 5x16 0.982 Production Hole: 6 -1/8" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ("/32) Int Shoe to TD 275 4" 15.7# 275 2800 11.57 N/A 3x14 0.451 Formation Markers: TVD Pore Press. EMW Formation Tops MD (rkb) (psi) (ppg) Comments Base Permafrost 1645 1607 Top West Sak 2530 2354 1039 8.7 Base of fluvial sands Hue Shale 3387 2905 Tuffaceous Shales 3558 2981 Top Torok Sand 8612 4923 2201 8.7 Top of Disposal Zone Base Torok Sand 9264 5172 Base of Disposal Zone Top HRZ 10574 5696 Base HRZ 10940 5832 Top Kuparuk C 11378 5974 3015 9.8 Non - producible Base Kuparuk C 11393 5978 Top Nuiqsut 11894 6112 3085 9.8 Oil Base Nuiqsut Not penetrated Pioneer Natural Resources Last Revised: April 25, 2008 ODSN -40 Permit To Drill — adjusted heel location Page 3 of 8 • Logging Program: 12 -1/4" Section: Drilling: Mud logging Dir/GR Open Hole: N/A Cased Hole: N/A 8 -3/4" Section: Drilling: Mud logging Dir /GR /Res /Dens /Neut Open Hole: N/A Cased Hole: N/A 6 -1/8" Section: Drilling: Mud logging Dir / GR / Res / Dens (Azm) / Neut Open Hole: N/A Cased Hole: N/A Casing Program: Hole Casing / Weight Grade Conn. Casing Csg/Tbg Top Hole Btm Size Tubing Length MDrkbITVDrkb MDrkb/TVDrkb 24" 16" 109# H -40 Welded 109' Surface 153' / 153' 12 - 9 -5/8" 40# L -80 BTC 3550' Surface 3594' / 2995' 8 -3/4' 7" 26# L -80 BTC -M 11870' Surface 11914' / 6117' Tubing 2 -7/8" 6.5# L -80 IBT -M 11870' Surface 16867' / 6267' Casing Properties Size Weight Grade ID Drift ID Conn. Internal Collapse Tensile Yield (psi) Strength (psi) Joint 1 Body 16" 109# H -40 14.67" 14.5" Welded Conductor casing 9 -5/8" 40# L -80 8.835" 8.679" BTC 5750 3090 916 M 916 M 7" 26# L -80 6.276" 6.151" BTC -M 7240 5410 604 M 604 M Pioneer Natural Resources Last Revised: April 25, 2008 ODSN -40 Permit To Drill — adjusted heel location Page 4 of 8 • • Cement Calculations: Casing Size: 1 9-5/8" Surface Casing - single stage Basis: Lead: 75% excess over gauge hole in permafrost + 50 bbls, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 500' of open hole with 30% excess, plus 85' shoe track Tail TOC: 3094' MD (500' MD above shoe) Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 10.0 ppg Dual Spacer Lead 319 bbls / 431 sx of 10.9 ppg Type "L" Permafrost Cement. 4.15 cf /sk, 20.0 gps water req. Tail 43 bbls / 203 sx of 15.9 ppg Premium "G" + adds. 1.18 cf /sk, 5.23 gps water req. Displ 267 bbls mud Temp BHST -55° F, BHCT -60° F estimated During drilling operations, should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar may be run in the casing string and a staged cement job will be performed, if needed. In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casing Size: 1 7" Intermediate Casing - single stage Basis: Tail: 1036' of open hole with 30% excess, plus 85' shoe track Tail TOC: - 10878' MD - 500' above the top of the Kuparuk Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 11.5 ppg Dual Spacer Tail 39.3 bbls / 187 sx of 15.8 ppg Premium "G" + adds. 1.18 cf /sk, 5.18 gps water req. Displ 453 bbls mud Temp BHST - 165° F at 6100' TVDrkb, -135° F BHCT This well is outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone Pioneer Natural Resources Last Revised: April 25, 2008 ODSN -40 Permit To Drill - adjusted heel location Page 5 of 8 • • Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Riq Work 1. 16" Conductors have been set and the Well Bay modules have been placed. 2. The Oooguruk Drill Site Class 1 / Class 2 Disposal Well, ODSDW1 -44, has been drilled and commissioned for disposal. Riq Activity: Drill Surface Hole through Case Intermediate Hole and Suspend 1. MIRU Nabors 19AC over pre - installed 16" conductor casing. 2. Nipple up and function test the 21 -1/4" diverter system prior to spud. (Notify the AOGCC Field Inspectors 48 hours prior to diverter function test). Note: A diverter waiver has been requested for this well. 3. MU 12 -1/4" Directional Drilling, MWD /LWD assembly. Drill surface hole to the casing point at -3594' MD / 2995' TVDrkb, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 9 -5/8 ", 40# surface casing - a Port Collar may be run based on hole conditions at Company Rep discretion. 5. Ensure floats are holding. WOC if needed. 6. ND Diverter, NU BOPE and test. Test BOPE to 250/3500 psi 7. MU 8 -3/4" directional drilling, MWD /LWD assembly. RIH and cleanout the casing to landing collar. 8. Test the 9 -5/8" casing to 3,500 psi for 30 min. 9. Drill out shoe tract, cement, rat hole and 20' of new formation below 9 -5/8" shoe. Pull the bit back into the 9 -5/8" casing and perform LOT. 10. Displace the well over to intermediate hole drilling fluid. 11. Drill 8 -3/4" intermediate hole to casing point at -11914' MD/ 6117' TVDrkb. Circulate and condition the drilling fluid to run casing. 12. Run and cement the 7 ", 26# intermediate casing. Ensure floats are holding. 13. MU 6 -1/8" directional drilling, MWD /LWD assembly. RIH and cleanout to landing collar. 14. Pressure test the 7" casing to 3,500 psi. 15. Drill out shoe tract, cement, rat hole and 20' of new formation below 7" shoe. Pull the bit back into the 7" casing and perform an FIT. 16. Displace the well over to production hole drilling fluid. 17. Drill the 6 -1/8" production hole to TD at -16867' MD/ 6267' TVDrkb. POH. 18. MU 6 -1/8" Cieanout BHA and cleanout to the 7" casing shoe. 19. Displace the well over to 10.2 ppg Brine. POH. 20. MU completion with ESP and RIH. 21. Land the tubing and RILDS. Install TWC. 22. ND BOPE, NU tree and test to 5,000 psi. 23. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to -2000' TVD and allow to u -tube. 24. Drop ball and rod and allow to seat. Pressure up to set the packer and test the tubing to 3,500 psi - chart and hold for 30 minutes. Bleed off pressure and then pressure test the annulus to 3,500 psi - chart and hold for 30 minutes. Bleed off pressure. 25. RU Slickline and pull the ball and rod. Pull the RHC -m plug. 26. RD Slickline. RDMO to next well. Pioneer Natural Resources Last Revised: April 25, 2008 ODSN -40 Permit To Drill - adjusted heel location Page 6 of 8 • • Casing Shoe Leak Off Test Procedure: 1. After testing BOPE, pick up the drilling assembly and RIH to the float collar. Circulate to consistent mud weight and rheology. 2. Shut in with the pipe rams and test the casing to the required test pressure. Record the volume of mud required and the corresponding pressures in 1 /4 bbl increments. When the design pressure is reached shut in the well and record the shut in pressure for 30 minutes. 3. Bleed off pressure while taking returns to a calibrated tank and record volume recovered. 4. Drill out the shoe track. Drill 20 ft of new hole and circulate the hole clean with consistent mud weight in /out. Pull up into the casing shoe. 5. Perform a Leak Off Test: • Calculate the required test pressure to reach leak off with the actual mud weight and the estimated fracture EMW. • Plot the casing test data and the calculated leak off on appropriate scale coordinate paper. As a guide, use the data from the casing test to determine the approximate volume of mud required to reach the calculated LOT. • Shut the well in. R/U the test pump. • Bring the pump on line at 0.25 - 0.50 bpm. Maintain a constant rate. • Record the pressure for every 1 /4 of a bbl pumped. • Continue pumping until the pressure vs. volume curve breaks over indicating leak off. • Discontinue pumping and shut in the well. Record the shut in pressure in 1 minute increments for 10 minutes or until pressure shows stabilization. • Bleed off the pressure and record the volume of mud recovered. • Plot the data to determine the Leak Off Test pressure at the shoe as EMW. • Submit the test results to the Pioneer drilling engineer for distribution as required. Pioneer Natural Resources Last Revised: April 25, 2008 ODSN -40 Permit To Drill — adjusted heel location Page 7 of 8 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • A ConocoPhillips well drilled to the south of the Oooguruk development showed communication with the main body of the Kuparuk field. In that well, they took an -2 ppg kick over planned mud weight - to -12.5 ppg. Prior to drilling into the Kuparuk, hold a pre - reservoir meeting to outlined heightened awareness and kick detection o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. o During the drilling of ODSDW01 -44 and ODSK -33, no increase in pressure was seen. o This is a new fault block Lost Circulation/Breathing /Formation Stability • The Torok Shales just above the HRZ showed that they are problematic on the ODSK -33 well - causing "temporarily restricted" pipe. These shales are bentonitic (clay) and /or vitrious (volcanic) in nature and may have some coal stringers. Any Toss of flow across this interval could allow the drilled solids to expand or dislodge and grab onto the BHA. While drilling this interval, o Take small bites and circulate them up and away from the BHA prior to taking another bite. • Lost circulation is a concern and if encountered, consult the Lost Circulation Decision Tree in the Halliburton Mud Program. o This well plan was adjusted to miss a fault at the heel. o The ODSK -33 well drilled into an unmapped fault and had total losses. • Breathing may be seen while drilling the Hue and Torok shales. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. • A formation study was conducted by GMI which indicated mud weights >12.5 ppg to maintain hole stability across the HRZ above the Kuparuk. Should shale instability be observed, pay close attention to the cuttings returned to surface and attempt to make small changes to mud weight to regain stability. o Splintered shales - indicates the mud weight may be too low o Tabular shales - indicates the mud weight may be too high Kick Tolerance/Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Interval Maximum Influx Mud Exp Pore Min LOT / FIT Volume Weight Press 9 -5/8" Surface / 8 -3/4" hole 45.6 bbls 10.2 3129 12.0 ppg (LOT) 7" Intermediate / 6-1/8" hole Infinite 10.2 3129 13.5 ppg (FIT) NOTE: All LOT / FIT will be taken with a minimum of 20 -ft and a maximum of 50 -ft of new hole drilled outside of the previous casing string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H site, however Standard Operating Procedures for H precautions should be followed at all times. Faults • No seismically visible faults are expected to be crossed and sub seismic faults may also be encountered. Losses may be associated with these faults. Fault Location MD TVDss Throw Direction Uncertainty CONSULT THE ODS DATA SHEET AND WELL PLAN FOR ADDITIONAL INFORMATION Pioneer Natural Resources Last Revised: April 25, 2008 ODSN -40 Permit To Drill - adjusted heel location Page 8 of 8 ODSN -40 Pruction Well Proposecompletion Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 2 -7/8 ", 5K, Horizontal Vent Valves Control Line 16" Conductor 153' MDrkb / 153' TVDrkb 2 -7/8" ScSSSV, 2.313" ID @ –750' 9 -5/8 ", 40# L -80 BTC, 8.835" ID 3594' MDrkb / 2995' TVDrkb X Nipple, 2.313" ID @ 5500' MD g ■ 2 -7/8" GLM @ 4444' MDrkb / 3330' TVDrkb ■ X Nipple, 2.313" ID w RHC -M 7" x 2 -7/8" Packer @ 5530' MDrkb / –3750' TVDrkb Profile @ 5560' MD 2 -7/8" GLM @ 10106' MDrkb / 5510' TVDrkb 2 -7/8 ", 6.5# L -80 ►BT -M —r ESP Cable O O 2 -7/8" Durasleeve Sliding Sleeve, 2.313" ID @ 11744' MDrkb t Estimated Top of Cement XN Nipple, 2.205" ID Nogo @ 10878' MD @ 11774' MDrkb 81 degrees ESP @ 11814' MDrkb 11914' MDrkb / 6117' TVDrkb 6 -1/8" Open Hole 7 ", 26# L -80 BTC -M, 6.276" ID 16867' MDrkb / 6267' TVDrkb Date: Revision By: Comments 4/28/2008 JDF Proposed Completion t# - ODSN -40 Producer Well Schematic PIONEER NATURAL RESOURCES li S . ; t fL Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site 4 i ' ODSN-40 - Slot ODS-40 ODSN-40 PN12 4: t 4it 1 i A 1 - I Plan: ODSN-40 PN12 wp10 -, • L Standard Proposal Report 0 , -•,' ,.i 25 April, 2008 4, P -. 1 a 7 ' t 1 4. ,, y , * y , 4 4 4 w x ,... . HALLIBURTON ! 1 Sperry Drilling Services 1 ,..i.. WELL DETAILS: ODSN -40 REFERENCE INFORMATION Co-ordinate (N /E) Reference: Well ODSN -40 - Slot ODS -40, True North H AL L! B tJ R TO f11 Ground Level 13.5 Vertical (TVD) Reference: 44.0' + 13 5' @ 57.5ft (Nabors 19AC) +N / - +F/ - Northing Easting Latittude Longitude Slot Measured Depth Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) um Sperry Drilling Services 0.0 0.0 6031038 469854.21 70 °29'45.125N 150° 14'47 W ODS -40 Calculation Method: Minimum Curvature PIONEER SURVEY PROGRAM SECTION DETAILS Date: 200804- 25700:00:00 Validated: Yes Version: Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target Depth From Depth To Survey /Plan Tool 1 44.0 0.00 0.00 44.0 0.0 0.0 0.00 0.00 0.0 44.0 1400.0 ODSNao PN12 wp10 CB GYRO - SS Project: Oooguruk Developement 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 1400.0 16867.0 ODSN-40 PN12 wp10 MWD +SAG +CA +IIFR +MS Site: Oooguruk Drill Site 3 800.0 5.00 150.00 799.4 -18.9 10.9 1.00 150.00 -12.2 g 4 1050.0 10.00 150.00 1047.1 -47.1 27.2 2.00 0.00 -30.5 Well: ODSN -40 5 1693.2 29.29 150.00 1650.0 -233.5 134.8 3.00 0.00 -151.3 Wellbore: ODSN-40 PN12 6 1807.8 29.29 150.00 1750.0 -282.1 162.9 0.00 0.00 -182.8 COMPANY DETAILS: Well Planning - Pioneer - Oooguruk 7 3593.8 67.00 220.00 2995.0 - 1395.1 -179.3 3.38 84.49 78.0 Plan: ODSN -40 PN12 wp10 8 3613.8 67.00 220.00 3002.8 - 1409.2 -191.1 0.00 0.00 88.8 Calculation Method: Minimum Curvature 9 5243.9 67.63 246.53 3641.2 - 2297.6 - 1382.8 1.50 93.76 1213.2 Error System: ISCWSA 10 9214.7 67.63 246.53 5152.7 - 3760.1 - 4750.8 0.00 0.00 4466.7 Scan Method: Tray. Cylinder North 11 11614.2 75.00 322.88 6039.9 - 3202.5 - 6736.0 3.00 99.23 6487.1 Error Surface: Elliptical Conic 12 11914.2 75.00 322.88 6117.5 - 2971.4 - 6910.9 0.00 0.00 6678.2 PN12 v10 T1 Warning Method: Rules Based 13 12343.8 87.88 323.35 6181.3 - 2632.4 - 7165.3 3.00 2.11 6956.4 14 13075.1 87.88 323.35 6208.4 - 2046.0 - 7601.5 0.00 0.00 7433.9 15 13271.5 90.00 317.86 6212.0 - 1894.3 - 7726.1 3.00 -68.96 7569.0 PN12 v10 Ts CASING DETAILS 2400- 16 13343.2 92.15 317.90 6210.7 - 18 - 7774.2 3.00 1.12 7620.8 17 14568.1 92.15 317.90 6164.7 -932.9 - 8594.8 0.00 0.00 8505.0 ize S Na M VD MD Name 18 14652.5 90.00 316.56 6163.1 -871.0 - 8652.1 3.00 - 148.16 8566.6 PN12 v10 T2 2995.0 TVD 3593 N me S izes - 19 14997.4 79.65 316.44 6194.2 -622.2 - 8888.2 3.00 - 179.33 8820.0 6117.5 11914.2 7" 9.625 - 20 15425.2 79.65 316.44 6271.0 -317.2 - 9178.2 0.00 0.00 9131.3 1800- 21 15770.7 90.00 317.10 6302.1 -66.8 - 9413.6 3.00 3.67 9384.2 PN12v10 22 15832.9 91.87 317.10 6301.1 -21.2 - 9455.9 3.00 0.00 9429.7 - ODSN -40 PN12 wp10 23 16867.0 91.87 317.10 6267.4 735.9 - 10159.4 0.00 0.00 10186.0 PN12 v10 TF 1200 _ , ' Total Depth at 16867.00' MD, 6267.40' TVD - _ ' ' - - Start Dir 1.00 /100' 300.00' MD, 300.00' TVD c - PN12 Fault � � � - � # End Dir 15832.90' MD, 6301.10' TVD 600- ` � Start Dir 260/100' 800.00' MD, 799.40' TVD 1 // \• Start Dir 3.00 /100' 15425.20' MD, 6327.00' TVD - .Start Dir 3.00 /100' 1050.00' MD, 1047.10' TVD • C 0- \ \ - - - End Dir 14997.40' MD, 6194.20' TVD -`506 - End Dir 1693.20' MD, 1650.00' TVD • - c o - i \ \ - - Start Dir 3.00/100' 14568.10' MD, 6164.70' TVD 211 , -600- IPN12 v10 T �1 •` / ... Start Dir 3.38/100'1807.80' MD, 1750.00' TVD + _ •� • - - - End Dir 13343.20' MD, 621030' TVD 2500 • ' 9 5/8" End Dir 3593.80' MD, 2995.00' TVD I -1200- [ N12•10113 •\ \ _ \ \ ' \ , 1 -1800- \ . \ Start Dir 3.00/100' 13075.10' MD, 6208.40 TVD ' - , , • r p _ _ _ _ - - Start Dir 1.5/100' 3613.80' MD, 3002.80' TVD _ DDf = 6 PN12 •v10 T� •� End Dir 12343.80' MD, 6181.30' TVD -2400- . End ` _ - Start Dir 3.00/100' 11914.20' MD, 6117.50' TVD •� • \ k End Dir 5243.90' MD, 3641.20' TVD - 3000 - LPN12 00 TI - ♦ _ - - End Dir 11614.20' MD, 6039.90' TVD N - / 1 °o WELLBORE TARGET DETAILS (MAP CO- ORDINATES) _ / -3600- IPN12 Geo Poly F, .0., TVD +N / -S +E / -W Northing Easting Shape '^ ` $ PN12 Fault #1 6117.5 - 4459.2 - 5576.2 6026602.00 464260.52 Polygon PN12 Fault #2 6117.5 581.3 - 10640.2 6031662.50 459217.56 Polygon PN12 Geo Poly 6117.5 - 3231.2 - 6884.9 6027835.21 462956.93 Polygon 4200- Start Dir 3.00/100' 9214.70' MD, 5152.80' TVD PN12 v10 T1 6117.5 - 2971.4 - 6910.9 6028095.00 462932.00 Point PN12 v10 T3 6163.1 -871.0 - 8652.1 6030202.30 461199.50 Point - - - _ PN12 v10 T2 6212.0 - 1894.3 - 7726.1 6029175.30 462121.30 Point l LN1 Fa1 lt # PN12 v10 T5 6267.4 735.9 - 10159.4 6031815.10 459698.90 Point 4800 - PN12 v10 T4 6302.1 -66.8 - 9413.6 6031009.51 460441.39 Point - 1 1 1 1 1 I 1 1 1 1 I I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 F 1 1 ] 1 1 I 1 1 1 1 1 1 1 x 1 1 1 1 1 1 1 r 1 1 1 I 1 Fr 1 1 H 1 1 1 r t 1 1 1 1 1 1 1 1 I 1 I 1 i I 1 1 1 1 I 1 I 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -12000 -11400 -10800 -10200 -9600 -9000 -8400 -7800 -7200 -6600 -6000 -5400 -4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 1200 1800 2400 West( - )/East( +) (1500 ft/in) • WELL DETAIIS: ODSN -40 REFERENCE INFORMATION HALI Co-ordinate (N/E) Reference: Well ODSN-40 - Slot ODS -40, True North Ground Level: 13.5 Vertical (TVD) Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) +N / -S +E/-W Northing Easting Latittude Longitude Slot I Measured Depth Reference: 44.0' + 13.5' @ 57.50 (Nabors 19AC) Sperry Drilling Services 0.0 0.0 6031038.10 469854.21 70° 29' 45.125 N 150° 14' 47.401 W ODS -40 Calculation Method: Minimum Curvature PIONEER WELLBORE TARGET DETAILS (MAP CO- ORDINATES) CASING DETAILS SURVEY PROGRAM Date: 2006- 04- 25T00:00:00 Validated: Yes Version: Name TVD +N / - +E / -W Northing Easting Shape TVD MD Name Size PN12 Fault #1 6117.5 - 4459.2 - 5576.2 6026602.00 464260.52 Polygon 2995.0 3593.8 9 5/8" 9.625 Depth From Depth To Survey/Plan Tool Project: Oooguruk Developement PN12 Fault #2 6117.5 581.3 - 10640.2 6031662.50 459217.56 Polygon 6117.5 11914.2 7" 7.000 14000 1686 ODSN- 40 PN12 w MWD +SAG +CA +IIFR +MS Site: Oooguruk Drill Site PN12 Geo Poly 6117.5 - 3231.2 - 6884.9 6027835.21 462956.93 Polygon Well: ODSN -40 PN12 v10 Tt 6117.5 - 2971.4 - 6910.9 6028095.00 462932.00 Point PN12 v10 T3 6163.1 -871.0 - 8652.1 6030202.30 461199.50 Point SECTION DETAILS Wellbore: ODSN -40 PN12 PN12 v10 T2 6212.0 - 1894.3 - 7726.1 6029175.30 462121.30 Point PN12 v10 T5 6267.4 735.9 - 10159.4 6031815.10 459698.90 Point Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target Plan: ODSN -40 PN12 wp10 PN12 v10 T4 6302.1 -66.8 - 9413.6 6031009.51 460441.39 Point 1 44.0 0.00 0.00 44.0 0.0 0.0 0.00 0.00 0.0 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 3 800.0 5.00 150.00 799.4 -18.9 10.9 1.00 150.00 -12.2 -1200- 4 1050.0 10.00 150.00 1047.1 -47.1 27.2 2.00 0.00 -30.5 - DDI = 6.95 FORMATION TOP DETAILS 5 1693.2 29.29 150.00 1650.0 -233.5 134.8 3.00 0.00 -151.3 _ 6 1807.8 29.29 150.00 1750.0 -282.1 162.9 0.00 0.00 -182.8 - 7 3593.8 67.00 220.00 2995.0 - 1395.1 -179.3 3.38 84.49 78.0 - Start Dir 1.00/100' 300.00' MD, 300.00' TVD TVDPathTVDssPath MDPath Formation 8 3613.8 67.00 220.00 3002.8 - 1409.2 -191.1 0.00 0.00 88.8 - 1607.5 1550.0 1644.8 Base of Permafrost 9 5243.9 67.63 246.53 3641.2 - 2297.6 - 1382.8 1.50 93.76 1213.2 • 2354.2 2296.7 2530.5 Top West Sak 10 9214.7 67.63 246.53 5152.7 - 3760.1 - 4750.8 0.00 0.00 4466.7 _ W 2904.7 2847.2 3387.3 Hue Shale 11 11614.2 75.00 322.88 6039.9 - 3202.5 - 6736.0 3.00 99.23 6487.1 0- Start Dir 2.00/100' 800.00' MD, 799.40' TVD 2980.7 2923.2 3558.0 Tuffaceous Shales 12 11914.2 75.00 322.88 6117.5 - 2971.4 - 6910.9 0.00 0.00 6678.2 PN12 v10 T1 4179.9 4 122.4 6659.0 Brook 26 13 12343.8 87.88 323.35 6181.3 - 2632.4 - 7165.3 3.00 2.11 6956.4 ' 4923.4 4865.9 8612.1 Top Torok Sand 14 13075.1 87.88 323.35 6208.4 - 2046.0 - 7601.5 0.00 0.00 7433.9 P 15 13271.5 90.00 317.86 6212.0 - 1894.3 - 7726.1 3.00 -68.96 7569.0 PN12 v10 T2 5171.8 5114.3 9264.5 Base Torok Sand 16 13343.2 92.15 317.90 6210.7 - 1841.2 - 7774.2 3.00 1.12 7620.8 600- Start Dir 3.00/100' 1050.00' MD, 1047.10' TVE 5696.5 5639.0 10574.3 Top HRZ 17 14568.1 92.15 317.90 6164.7 -932.9 - 8594.8 0.00 0.00 8505.0 5831.7 5774.2 10939.9 Base HRZ 18 14652.5 90.00 316.56 6163.1 -871.0 - 8652.1 3.00 - 148.16 8566.6 PN12 v10 T3 - Base of Permafrost _ " " 5903.7 5846.2 11151.7 Kalubik Marker 19 14997.4 79.65 316.44 6194.2 -622.2 - 8888.2 3.00 - 179.33 8820.0 - ' 20 15425.2 79.65 316.44 6271.0 -317.2 - 9178.2 0.00 0.00 9131.3 1200 ` End Dir 1693.20' MD, 1650.00' TVD 5974.2 5916.7 11377.8 Top Kuparuk C 21 15770.7 90.00 317.10 6302.1 -66.8 - 9413.6 3.00 3.67 9384.2 PN12 v10 T4 _ - " 5978.7 5921.2 11393.0 Base Kuparuk ( 22 15832.9 91.87 317.10 6301.1 -21.2 - 9455.9 3.00 0.00 9429.7 20 " "' " " 6112.4 6054.9 11894.5 Top Nuiqsut 23 16867.0 91.87 317.10 6267.4 735.9 - 10159.4 0.00 0.00 10186.0 PN12 v10 T5 • 1800 Start Dir 3.38/100' 1807.80' MD, 1750.00' TVD o _ Top West Sak COMPANY DETAILS: Well Planning - Pioneer - Ooogunsk • End Dir 3593.80' MD, 2995.00' TVD Calculation Method: Minimum Curvature Lo - 2400 40 Error System: ISCWSA _ Start Dir 1 3613 MD , 3002 TVD Scan Method: Tray. Cylinder North - Hue Shale Error Surface: Elliptical Conic a _ _ 6 � _ _ _ - - - - - Warning Method: Rules Based � 3000 _ , End Dir 5243.90' MD, 3641.20' TVD End Dir 13343.20' MD, 6210.70' TVD r f z 9 5/8" _ - " Start Dir 3.00/100' 13075.10' MD, 6208.40' TVD > 3600- Tuffaceous Shales ' - 3.00/100' 9214.70' 5152.80' Start Dir 3.00/100 9214.70 MD, 5152.80 TVD 1 a) - ; Start Dir 3.00/100' 14568.10' MD, 6164.70' TVD III H 1 E Dir 12343.80' MD, 6181.30' TVD; ■ End Dir 14997.40' MD, 6194.20' TVD 4200 Brook 2B - & ■ Start Dir 3.00/100' 11914.20' MD, 6117.50' TVD Start Dir 3.00/100' 15425.20' MD, 6327.00' TVD 4800 Top Torok Sand_ ■ 1 1 1 - ■ End Dir 11614.20 MD, 6939.90' TVD 1 End Dir 15832.90' MD, 6301.10' TVD Base Torok Sand - \ 1 1 5400 Top HRZ _ _ Base HRZ �� , - Total Depth at 16867.00' MD, 6267.40' TVD 6000 - - -- _ 0 q ` S Ka lubik Marker - - _ - - 1 , 1 Top Kuparuk C - - - Top Nuiqsut I 1 ,,I ODSN - 40 PN12 wp10 6600 PN12 v10 - r ' 1 - Base Kuparuk (LCU) 11'1412 v10 T1 I PN12 v10 T21 rPN12 v10 T PN12 v10 T� . - 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 n 1 1 1 1 r 1 1 1 1 1[ 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1] 1 I 1 1 1 1 1 1 1 1 1 1 1 I 1 I I I - 1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 Vertical Section at 274.14bearing (1500 ft/in) ■ OJS 'IN1 wf + v v v HALLIBURTON ti t - \, OOSN- 2711N2 wp°u\\ Sperry Drilling Services - OOSN -28 w506. ST \ • - ,m PIONEER ODSK -18 KUpN wp01 \ Project: Oooguruk Developement .. \ Site: Oooguruk Drill Site O DSN- 2911N4 wpOS - T \ ODSN -30PN5 wp05 • ST \ o „ 00SK -101 KupE wp03 \ ODSN-31 PN6 TEST \ p \ _.,. •,•- OOSN -321 IN] wp14 \ z ; 7 - /1, 41111 •.. :r PW wy10 . "° ODSN - 341 IN9 .0.. �� • • ^..- ODSK-3S KWS .06. ODSK- .■ 565 wp05 \ \ \ OO SN -391 IN, w. 2 - / 7. ODS4-2 PS1 wp06 . „,. ��. -w, r ODBIIJO PN12 wp' i/ /���\ ODSN -3i IS2 wpm -I �= \ ODSDW2 -20 Di>mea5wp01 4 ' OD,N .i 1'00 466 6 ODSN-0511513 wp0T *pig /: ® \\ ODSN -51134 wp06 •.J AS KupA PSl surveys,,/ -.. P \ r \ SUrve OD9N -T I 13T w50T \ Olt4' r ■ \ N 01:014-8 PS8 wPO) . a 005N -9139 wp10 \ \ODSN- 1111 wpOP. ..� \ \DDSK 41 KupG w002 \ 003N-10101 p06 _ ""` \\ OOSN -15 PS14 x506 \ ODSK -42 KupF wp02 \O006- PS16 w.06 _ - .A. ..'m .,T.. .6 .6, 4.. .4. '4: ,.'., .6 4. ,L :.;,. ..6. ..s .w «. .o a 16 J. ,.. ...f.1' .6 .I. 4 .. 4 A. I. . ...I lnan . w ., .. ,.. ,,. .o a. .6 . .o , ". .. .. .6 .. .. S .6 . .6 ..% J. 4. 4. .,» „I. . ,17, ;,I.. 4.. . ,". . ,.e ,... . . Z. .. ,u. J : 4.. „. 4. ... ... J. J. ,... ,.o SURVEY PROGRAM ANTI- COLLISION SETTINGS Date: 2008 -04- 25700:00:00 Validated: Yes Version: FROMr Interpolation Method: MD, interval: 25.0 S URFACE Depth Range From: 0.0 To 3590.0 Depth From Depth To Survey/Plan Tool Results Limited By: Centre Distance: 1884.1 44.0 1400.0 ODSN -40 PN12 wp10 CB- GYRO -SS 240 re10 (O 4/ 42) 1400.0 16867.0 ODSN-40 PN12 wp10 MWD+SAG+CA+HFR+MS Sca Ref Type: nce: NO Plan: GLOBAL ODSN -40 FILTER: PN12 wp Using user DSN defined ODSN selection 0 PN1 8 filtering criteria ODSN -11i IS1j ODSK -33 KupA ODSN -39i IN1i1 F SN -7i 13 ODSN -13 PS12 ODSN -12 PS1¢ . KupA ODSK-35 Ku OD SN-9i 1S ODSN - 37 PNt� ODSK - 33 Ku A PB1 p ODSN39i !Nil ODSK -42 Ku . , 4 ODSN -32 IN# RANGE 0 -150 ' \ ODSN -8 PS , From Color To MD ODSK-41i KupP( s • ODSN -14i 1311' ' ` ,' ,vDSK toI KupE - - - _ - - - - _ ODSN -37 PN8 ODSN 6 PS SK-41i Kup ' 0 RANG 100( ODSN -15 PS1 � ��` " � . \ - , „ e' i � ' - - -- ODSN34iIN� 44 250 0-1 - • Iii , E 0 \ � i t9 •. p � � , 250 5 �� i ODSN -16i IS1 330 q ► ODSN-30 P 500 750 �� _ 11 30 33 0 �. ` ' , � / - - - - - - N$ 750 100( `� - ODSN -17 PS1 ¢ \ ! % #� ODSN -38 PN10 , - 1a� T a . r' - ��!e, /i ce ... ! ' - - - 29i -29i INS 1 000 1250 // +� �I i . ,iii . . " , , � .. 2 \\� RANGE 0 -150(' ODSDW2 -20 Disposal ,. T , \ ,�� j ; y , 1250 7500 3 00 1 ° ' � �' � \ �l o 60 � �1 ► - _ � O D S N3 1 PN 15 1750 %' (pa ": . _ ,',1 illi; ODSDW1-04Dispos ' ! �� � 1 �, 80 175 2000 � e: ��� • • a � ",,,,,,',4,,f t � 1 OD SK36 i Kup n 2000 2250 nu' �� �a �� • ODSK -18 KupN G • - 4! f � . • . 2250 2500 ',: /// / 4.14' . ` - 0 . , -i 1 ,. ' ' 2500 - 2750 r• 11 I 1 a �I , \ �'Tr1: // ' " ?. '•,, _ 4 `� i , i 4r � � a ' " '2Ate' i - Y � ` ODSN - "sf 2750 3000 270 �� i �i � �, i > ' �i >, � • ��- 3000 3250 ' i 1/,/ s / �/ ` \ 3250 3500 i • / ,�� ' � � Ls.. -.. `t : " '' 3500 3750 1 % ' • 270 � 1� _ \� g0 3750 4000 r , . :' N 4000 5000 ,, i 7 ) si ` , � ' 5000 6000 240 _ ` 120 ,, � � � � , ;; 1 6000 7000 :::- i�i� • I �/�, 7000 -- s000 , , ODSN 45i PN13 (I ( 8000 9000 i uii'' • 9000 - 10000 ' ,• /j�. ›�i 10000 11000 210 T � l hij �� "� 150 240 + \ 120 11000 12000 ODSN 43 PN14 30 : +� 12000 13000 Range 0 -1000' 180 4 ' '..--, ' . I . T _!�� i i -. ' 13000 14000 \ - - ' ' , '' 14000 15000 ;� ; ' 15000 16000 Travelling Cylinder Azimuth (TFO +AZn [bearing] vs Centre to Centre Separation [20 ft/in] ��� - '� 16000 - 17000 210 150 17000 18000 • .410 18000 19000 19000 20000 180 I 20000 21000 ODSN - 43 PN14 21000 22000 22000 0 Travelling Cylinder Azimuth (TFO+AZI) [bearing] vs Centre to Centre Separation 150 ft /in] SECTION DETAILS Sec MD Inc Az TVD +111-5 +E1 - W DLeg TFace VSec Target 1 440 0.00 000 440 0.0 0.0 000 000 0.0 2 3000 0.00 0.00 300 0 0,0 00 0.00 000 00 3 800.0 5.00 15000 7994 -18,9 109 100 15000 -122 REFERENCE INFORMATION Well Planning - Pioneer - OOOguruk 5 i69ai 2929 150 550.0 16509 - 33 13 3.00 000 -lsia 6 1807.8 2929 15000 17500 -282.1 162.9 0.00 0 00 -1828 Co- ordinate (N /E) Reference: Well ODSN -40 - Slot ODS -40, True North Calculation Method: Minimum Curvature 7 3593.8 6700 220.00 29050 - 1395.1 -179.3 338 8449 78.0 8 35138 67.00 22000 30028 -14992 -1911 099 000 886 Vertical TVD Reference: 44.0' + 13.5' 57.5ft Nabors 19AC 9 52439 67.63 246.53 3641.2 -22976 -13828 150 9378 1213.2 ( ) @ �% ( ) Error System: ISCWSA 10 9214.7 8783 24653 51527 37601 -47508 000 000 44657 Section (VS) Reference: Slot - ODS -40(0.ON, O.OE) Scan Method: Tray. C tinder North Depth Reference: 44.0 + 13.5 @ 57.5ft 11 11614.2 7600 32288 60399 -32025 87369 300 9923 64871 Measured De ' ' (Nabors 19AC) y 12 11914,2 7500 32288 61175 -29714 -8910.9 000 000 6678.2 PN12 v10 T1 Calculation Method: Minimum Curvature Error Su p ( 1 13 123435 87.88 32335 8181 3 -26324 -71653 300 211 69564 Surface: Elliptical Conic 14 13075,1 87.88 32335 6208 4 -20480 -78015 000 000 74339 Warning Method: Rules Based 15 13271,5 9090 317.86 6212 0 - 1894.3 - 7726.1 3,00 .8.96 75699 P1412 v10 T2 16 13343 2 9215 317.90 6210.7 -1841 2 - 7774.2 3.00 1.12 7620.8 17 145861 9215 31790 61647 -9329 -8594.8 0.00 000 85050 1814652.5 9000 31656 6183.1 - 8710 -86521 300- 148.18 85866 PN12 v10 T3 19 14997.4 7965 316.44 6194.2 - 6222 -68882 3.00 - 17933 88200 NAD 27 ASP Zone 4 : WELL DETAILS: ODSN -40 21 15 9000 317.10 6302.7 -317.2 -68.8 -94138 300 387 93842 PN12 v10 T4 22 158329 91.87 31710 6301,1 -212 - 94559 300 000 94297 23 16867.0 91.87 31710 8287.4 735.9 - 10159.4 000 0,00 101860 P912410 T5 Ground Level: 13.5 +N / -S +E/ -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031038.10 469854.21 70° 29' 45.125 N 150° 14' 47.401 W ODS-40 • SURVEY PROGRAM ANTI - COLLISION SETTINGS Date: 2008- 04- 25T00:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.0 Depth Range From: 2400.0 To 16867.0 Depth From Depth To Survey/Plan Tool Results Limited By: Centre Distance: 1884.1 44.0 1400.0 ODSN -40 PN12 wp10 CB- GYRO -SS Reference: Plan: ODSN -40 PN12 wp10 (ODSN- 40 /ODSN -40 PN12) 1400.0 16867.0 ODSN -40 PN12 wp10 MWD+SAG+CA+IIPR +MS Scan Type: NO GLOBAL FILTER: Using user defined selection & filtering criteria FOR USE FROM 2400' TO TD i ODSN -39i IN1) 7 ] o ...� 0 '` � ' f1 r .o 330,x' ` �. % %. 30 From Color To MD �� 3; � ' , .- as 2so � . �.- - . 250 - ` \ � ;\`;_ ``��= � � 500 - 750 \ `� s �` 750 1000 ������� j 000 2so 300 � ��``�_- �� i 1250 1500 ` -- 300 ,, 60 ��'� � 1590 1750 , , + ]50 2000 It 411111111/111111 ` 00 t , :2 ., 25 25 500 2]50 ` ]50 3 000 000 3250 Itirti#1111 '�' 325 - 3500 , ��� A . i \ / 3500 3] 50 270 4000 - 5000 270 \�,t.. I �� ��� � � 5000 6900 '', ; ��` ` I • - tii ]000900 8008 0 10000 ]M 12000 13000 - 17000 2, ` ' t ' ', 240 11 ! 1 ( L ' ,A,• 17000 1 1 17000 19000 \ \ ,I\ 111`, ,0\\. 18000 ' 19009 ,9000 - 20090 180 � 1 � 1 � 1 1 k1 1 % 0 ' ' . - - 20009 21900 1 \ 1 \ ,t 21000 22000 ODSN -161 IS16 Ij 1 1%1�., '' 22000 - o ,t ∎• %• d - � � a Travelling Cylinder Azimuth (TFO +AZI) [bearing] vs Centre to Centre Separation 120 ft/in) . 210 '•ii 150 180 SECTION DETAILS Sec MD Inc AN 1503 .51-6 +VS. r -W OLeg TFace VS Target Travelling Cylinder Azimuth (TFO+AZI) [bearing( vs Centre to Centre Separation (50 ft /ink 1 440 0.00 0.00 44.0 00 9.9 0.00 coo 00 2 3000 0.00 000 3000 00 0.0 000 0.00 00 3 8000 500 15000 7994 -189 10.9 100 15000 -122 4 1050.0 1000 150.00 1047.1 -47.1 27.2 200 000 -305 5 16932 29.29 15000 1650.0 -233.5 134.8 3.00 0.00 -151.3 REFERENCE INFORMATION Well Planning Pioneer - Oooguruk 6 1807.8 2929 150.00 1750 -282, 1829 0.00 000 -1828 g - g 7 3593.8 6700 220.00 29950 - 1395.1 -1]93 338 8449 780 8 3613.8 6] 00 220.00 30028 - 14092 -191.1 000 000 88.8 Co- ordinate (N /E) Reference: Well ODSN -40 - Slot ODS- 40, True North 9 52419 6763 24853 36412 - 22972 - 1382.8 1.50 93 76 1213.2 Calculation Method: Minimum Curvature 10 9214.7 67.63 24653 5152 - 3760.1 4750.8 000 000 4466.7 Vertical (TV Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) 11 118142 7500 322.88 8039.9 - 3202.5 -6736.0 300 9923 6487.1 Section (VS) ) Reference: Slot - ODS- 40(0.0N, 0.0E) Error System: ISCWSA 12 11914.2 7500 32288 61175 - 2971.4 -69109 0.00 0.00 68782 PN12 v10 T1 Measured Depth Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Scan Method: Tray. Cylinder North 13 123438 87.88 323.35 61813 -26324 -71653 300 2.11 6956.4 y 14 13075 87.88 32335 6208.4 -20480 - 7601.5 0.00 000 74339 Calculation Method: Minimum Curvature Error Surface: Elliptical Conic 15 13271 5 90.00 317.88 62120 - 1896.3 - 7726.1 300 -8896 75690 PN12 v1072 p 16 13343.2 9215 317.90 62107 - 18412 -]7742 3.00 112 7620.0 Warning Method: Rules Based 17 14568.1 92.15 317.90 6164.7 - 9329 - 8596.8 0.00 000 8505.0 g 18 148525 9000 31658 6163.1 - 871 0 -86521 300 - 148.16 85666 P111241073 19 14997.4 7965 316.44 61942 -622 2 -88882 300 - 17933 8820 0 20 154252 7985 316.44 62710 -317.2 -91782 090 0.00 9131.3 21 15770 90.00 317.10 6302.1 -668 -94136 300 367 93042 PN12 v10 14 NAD 27 ASP Zone 4: WELL DETAILS: ODSN -40 22 158329 9187 317.10 6301.1 -21.2 -94559 3.00 000 9429.7 23 18867.0 9187 317.10 62674 735.9 - 101;9.4 000 0.00 101860 PN12 v10 T5 Ground Level: 13.5 +N / -S +E / -W Northing Easting Latittude Longitude Slot 0.0 0.0 6031038.10 469854.21 70° 29' 45.125 N 150° 14' 47.401 W ODS-40 • • Sperry Drilling Services • H.A,LL1BURTON Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN -40 - Slot ODS -40 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) - Project: Oooguruk Developement MD Reference: 44.0' + 13.5 @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -40 Survey Calculation Method: Minimum Curvature Welibore: ODSN -40 PN12 Design: ODSN -40 PN12 wp10 Project Oooguruk Developement Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70° 29' 46.242 N From: Map Easting: 469,920.45ft Longitude: 150° 14' 45.465 W Position Uncertainty: 0.0 ft Slot Radius: in Grid Convergence: -0.23 ? Well ODSN -40 - Slot ODS -40 Well Position +N/-S 0.0 ft Northing: 6,031,038.10ft Latitude: , 70 29' 45.125 N +E / -W 0.0 ft Easting: 469,854.21 ft Longitude: 150° 14' 47.401 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft . Wellbore ODSN -40 PN12 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ( ?) ( ?) (nT) IGRF200510 3/8/2007 23.23 80.81 57,644 Design ODSN -40 PN12 wp10 Audit Notes: Version: Phase: PLAN Tie On Depth: 44.0 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (bearing) 44.0 0.0 0.0 274.14 I 4/25/2008 9:27 :16AM Page 2 COMPASS 2003.16 Build 428 • • Sperry Drilling Services HALLIBURTC:IN Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN -40 - Slot ODS -40 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44.0' + 13.5 @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -40 Survey Calculation Method: Minimum Curvature Welibore: ODSN -40 PN12 Design: ODSN -40 PN12 wp10 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth inclination Azimuth Depth System +NI-S +g/ -W Rate Rate Rate Tool Face (ft) ( ?) ( (ft) ft (ft) (ft) ( ?/100ft) ( ?/100ft) ( ?/100ft) ( ?) 44.0 0.00 0.00 44.0 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 300.0 ' 0.00 0.00 300.0 242.5 0.0 0.0 0.00 0.00 0.00 0.00 800.0 5.00 150.00 799.4 741.9 -18.9 10.9 1.00 1.00 0.00 150.00 1,050.0 10.00 150.00 1,047.1 989 -47.1 27.2 2.00 2.00 0.00 0.00 1,693.2 29.29 150.00 1,650.0 1,592.5 -233.5 134.8 3.00 3.00 0.00 0.00 1,807.8 29.29 150.00 1,750.0 1,692.5 -282.1 162.9 0.00 0.00 0.00 0.00 3,593.8 67.00 220.00 2,995.0 2,937.5 - 1,395.1 -179.3 3.38 2.11 3.92 84.49 3,613.8 67.00 220.00 3,002.8 2,945.3 - 1,409.2 -191.1 0.00 0.00 0.00 0.00 5,243.9 67.63 246.53 3,641.2 3,583.7 - 2,297.6 - 1,382.8 1.50 0.04 1.63 93.76 9,214.7 67.63 246.53 5,152.7 5,095.2 - 3,760.1 - 4,750.8 0.00 0.00 0.00 0.00 11,614.2 75.00 322.88 6,039.9 5,982.4 - 3,202.5 - 6,736.0 3.00 0.31 3.18 99.23 11,914.2 75.00 322.88 6,117.5 6,060.0 - 2,971.4 - 6,910.9 0.00 0.00 0.00 0.00 12,343.8 87.88 323.35 6,181.3 6,123.8 - 2,632.4 - 7,165.3 3.00 3.00 0.11 2.11 13,075.1 87.88 323.35 6,208.4 6,150.9 - 2,046.0 - 7,601.5 0.00 0.00 0.00 0.00 13,271.5 90.00 317.86 6,212.0 6,154.5 - 1,894.3 - 7,726.1 3.00 1.08 -2.80 -68.96 13,343.2 92.15 317.90 6,210.7 6,153.2 - 1,841.2 - 7,774.2 3.00 3.00 0.06 1.12 14,568.1 92.15 317.90 6,164.7 6,107.2 -932.9 - 8,594.8 0.00 0.00 0.00 0.00 14,652.5 90.00 316.56 6,163.1 6,105.6 - 871.0 - 8,652.1 3.00 -2.55 -1.58 - 148.16 14,997.4 79.65 316.44 6,194.2 6,136.7 -622.2 - 8,888.2 3.00 -3.00 -0.04 - 179.33 15,425.2 79.65 316.44 6,271.0 6,213.5 -317.2 - 9,178.2 0.00 0.00 0.00 0.00 15,770.7 90.00 317.10 6,302.1 6,244.6 -66.8 - 9,413.6 3.00 2.99 0.19 3.67 15,832.9 91.87 317.10 6,301.1 6,243.6 -21.2 - 9,455.9 3.00 3.00 0.00 0.00 16,867.0 91.87 317.10 6,267.4 6,209.9 735.9 - 10,159.4 0.00 0.00 0.00 0.00 • 4/25/2008 9 :27 :16AM Page 3 COMPASS 2003.16 Build 428 • • Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM _Alaska Local Co- ordinate Reference: Well ODSN -40 - Slot ODS -40 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44.0' + 13.5 @ 57.5ft (Nabors 19AC) Project Oooguruk Developement MD Reference: 44.0' + 13.5 @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -40 Survey Calculation Method: Minimum Curvature Welibore: ODSN -40 PN12 Design: ODSN -40 PN12 wp10 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth TVDss +N/-$ +E/-W Northing Easing DLS Vert Section (ft) ( ?) (bearing) (ft) ft (ft) (ft) (ft) (ft) -13.50 .44.0 0.00 0.00 44.0 -13.5 0.0 0.0 6,031,038.10 ' 469,854.21 • 0.00 0.00 100.0 0.00 0.00 100.0 42.5 0.0 0.0 6,031,038.10 469,854.21 0.00 0.00 200.0 0.00 0.00 200.0 142.5 0.0 0.0 6,031,038.10 469,854.21 0.00 0.00 300.0 0.00 0.00 300.0 242.5 0.0 0.0 6,031,038.10 469,854.21 0.00 0.00 Start Dir 1.00/100' 300.00' MD, 300.00' TVD 400.0 1.00 150.00 400.0 342.5 -0.8 0.4 6,031,037.34 469,854.64 1.00 -0.49 500.0 2.00 150.00 500.0 442.5 -3.0 1.7 6,031,035.07 469,855.94 1.00 -1.96 600.0 3.00 150.00 599.9 542.4 -6.8 3.9 6,031,031.29 469,858.11 1.00 -4.41 700.0 4.00 150.00 699.7 642.2 -12.1 7.0 6,031,025.99 469,861.14 1.00 -7.83 800.0 5.00 150.00 799.4 741.9 -18.9 10.9 6,031,019.18 469,865.03 1.00 -12.24 Start Dir 2.00/100' 800.00' MD, 799.40' TVD 900.0 7.00 150.00 898.8 841.3 -27.9 16.1 6,031,010.10 469,870.22 2.00 -18.10 1,000.0 9.00 150.00 997.8 940.3 -40.0 23.1 6,030,998.03 469,877.13 2.00 -25.91 1,050.0 10.00 150.00 1,047.1 989.6 -47.1 27.2 6,030,990.86 469,881.23 2.00 -30.55 Start Dir 3.00/100' 1050.00' MD, 1047.10' TVD 1,100.0 11.50 150.00 1,096.3 1,038.8 -55.2 31.9 6,030,982.77 469,885.86 3.00 -35.78 1,200.0 14.50 150.00 1,193.7 1,136.2 -74.7 43.1 6,030,963.25 469,897.02 3.00 -48.40 1,300.0 17.50 150.00 1,289.8 1,232.3 -98.6 56.9 6,030,939.32 469,910.70 3.00 -63.87 1,400.0 20.50 150.00 1,384.4 1,326.9 -126.7 73.2 6,030,911.07 469,926.86 3.00 -82.14 1,500.0 23.50 150.00 1,477.1 1,419.6 -159.2 91.9 6,030,878.56 469,945.46 3.00 - 103.17 1,600.0 26.50 150.00 1,567.7 1,510.2 -195.8 113.0 6,030,841.88 469,966.44 3.00 - 126.88 1,644.8 27.84 150.00 1,607.5 1,550.0 -213.5 123.3 6,030,824.14 469,976.58 3.00 - 138.36 Base of Permafrost 1,693.2 29.29 150.00 1,650.0 1,592.5 -233.5 134.8 6,030,804.05 469,988.07 3.00 - 151.34 End Dir 1693.20' MD, 1650.00' TVD 1,700.0 29.29 150.00 1,656.0 1,598.5 -236.4 136.5 6,030,801.15 469,989.74 0.00 - 153.22 1,800.0 29.29 150.00 1,743.2 1,685.7 -278.8 161.0 6,030,758.68 470,014.03 0.00 - 180.69 1,807.8 29.29 150.00 1,750.0 1,692.5 -282.1 162.9 6,030,755.36 470,015.92 0.00 - 182.83 Start Dir 3.38/100' 1807.80' MD, 1750.00' TVD 1,900.0 29.74 156.26 1,830.2 1,772.7 -322.6 183.4 6,030,714.81 470,036.25 3.38 - 206.19 2,000.0 30.55 162.80 1,916.7 1,859.2 -369.6 200.9 6,030,667.75 470,053.56 3.38 - 227.05 I 2,100.0 31.66 168.97 2,002.4 1,944.9 -419.6 213.4 6,030,617.65 470,065.90 3.38 - 243.17 2,200.0 33.06 174.73 2,086.9 2,029.4 -472.6 220.9 6,030,564.69 470,073.21 3.38 - 254.51 2,300.0 34.69 180.03 2,169.9 2,112.4 -528.2 223.4 6,030,509.06 470,075.48 3.38 - 261.01 2,400.0 36.54 184.89 2,251.2 2,193.7 -586.3 220.9 6,030,450.93 470,072.69 3.38 - 262.67 2,500.0 38.57 189.32 2,330.5 2,273.0 -646.8 213.3 6,030,390.53 470,064.86 3.38 - 259.46 2,530.5 39.22 190.59 2,354.2 2,296.7 -665.6 210.0 6,030,371.71 470,061.47 3.38 - 257.52 Top West Sak 2,600.0 40.75 193.37 2,407.5 2,350.0 -709.3 200.7 6,030,328.05 470,052.01 3.38 - 251.42 2,700.0 43.06 197.06 2,481.9 2,424.4 -773.7 183.1 6,030,263.72 470,034.18 3.38 - 238.55 2,800.0 45.48 200.44 2,553.5 2,496.0 -839.8 160.7 6,030,197.75 470,011.44 3.38 - 220.91 2,900.0 47.99 203.54 2,622.1 2,564.6 -907.3 133.4 6,030,130.38 469,983.87 3.38 - 198.56 3,000.0 50.58 206.41 2,687.3 2,629.8 -976.0 101.3 6,030,061.85 469,951.57 3.38 . - 171.57 3,100.0 53.23 209.07 2,749.0 2,691.5 - 1,045.6 64.7 6,029,992.38 469,914.64 3.38 - 140.04 3,200.0 55.94 211.55 2,806.9 2,749.4 - 1,115.9 23.5 6,029,922.22 469,873.21 3.38 - 104.09 , 4/25/2008 9 :27 :16AM Page 4 COMPASS 2003.16 Build 428 ID 411 Sperry Drilling Services HA LLIBURTOIIV Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN -40 - Slot ODS -40 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Project :_ Oooguruk Developement MD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -40 Survey Calculation Method: Minimum Curvature Wellbore: ODSN -40 PN12 Design: ODSN -40 PN12 wp10 Planned Survey Measured Vertical Map Map Depth Inclination. Azimuth Depth TVDss +N/-S +E.1 -W Northing Easting DLS Vert Section (ft) (7) (bearing) (ft) ft (ft) (ft) (ft) (ft) 2,803.43 3,300.0 58.70 213.87 2,860.9 2,803.4 - 1,186.7 -22.0 6,029,851.62 469,827.43 3.38 -63.82 3,387.3 61.14 215.79 2,904.7 2,847.2 - 1,248.7 -65.1 6,029,789.79 469,784.02 3.38 -25.25 Hue Shale 3,400.0 61.49 216.06 2,910.8 2,853.3 - 1,257.7 -71.7 6,029,780.82 469,777.46 3.38 -19.39 3,500.0 64.32 218.14 2,956.3 2,898.8 - 1,328.7 -125.4 6,029,710.06 469,723.47 3.38 29.05 3,558.0 65.97 219.30 2,980.7 2,923.2 - 1,369.7 -158.3 6,029,669.14 469,690.39 3.38 58.91 Tuffaceous Shales 3,593.8 67.00 220.00 2,995.0 2,937.5 - 1,395.1 -179.3 6,029,643.93 469,669.31 3.38 78.00 End Dir 3593.80' MD, 2995.00' TVD - 9 5/8" 3,600.0 67.00 220.00 2,997.4 2,939.9 - 1,399.4 -182.9 6,029,639.60 469,665.65 0.00 81.32 3,613.8 67.00 220.00 3,002.8 2,945.3 - 1,409.1 -191.1 6,029,629.90 469,657.45 0.00 88.77 Start Dir 1.5/100' 3613.80' MD, 3002.80' TVD 3,700.0 66.92 221.40 3,036.5 2,979.0 - 1,469.3 -242.8 6,029,569.98 469,605.49 1.50 136.01 3,800.0 66.85 223.03 3,075.8 3,018.3 - 1,537.4 -304.6 6,029,502.13 469,543.42 1.50 192.72 3,900.0 66.79 224.66 3,115.2 3,057.7' - 1,603.7 -368.3 6,029,436.10 469,479.48 1.50 251.44 4,000.0 66.74 226.29 3,154.6 3,097.1 - 1,668.1 -433.8 6,029,371.94 469,413.72 1.50 312.13 4,100.0 66.72 227.93 3,194.1 3,136.6 - 1,730.6 -501.1 6,029,309.70 469,346.17 1.50 374.74 4,200.0 66.71 229.56 3,233.7 3,176.2 - 1,791.2 -570.1 6,029,249.41 469,276.88 1.50 439.23 4,300.0 66.72 231.19 3,273.2 3,215.7 - 1,849.8 -640.9 6,029,191.13 469,205.90 1.50 505.56 4,400.0 66.75 232.82 3,312.7 3,255.2 - 1,906.3 -713.3 6,029,134.88 469,133.29 1.50 573.69 4,500.0 66.79 234.46 3,352.1 3,294.6 - 1,960.8 -787.3 6,029,080.71 469,059.08 1.50 643.55 4,600.0 66.85 236.09 3,391.5 3,334.0 - 2,013.2 -862.8 6,029,028.66 468,983.32 1.50 715.12 4,700.0 66.92 237.72 3,430.8 3,373.3 - 2,063.4 -939.9 6,028,978.75 468,906.09 1.50 788.34 4,800.0 67.02 239.34 3,469.9 3,412.4 - 2,111.4 - 1,018.3 6,028,931.03 468,827.41 1.50 863.15 4,900.0 67.13 240.97 3,508.9 3,451.4 - 2,157.3 - 1,098.2 6,028,885.53 468,747.35 1.50 939.51 5,000.0 67.25 242.59 3,547.6 3,490.1 - 2,200.8 - 1,179.4 6,028,842.27 468,665.97 1.50 1,017.36 5,100.0 67.39 244.21 3,586.2 3,528.7 - 2,242.2 - 1,261.9 6,028,801.30 468,583.31 1.50 1,096.66 5,200.0 67.55 245.82 3,624.5 3,567.0 - 2,281.2 - 1,345.7 6,028,762.63 468,499.44 1.50 1,177.34 5,243.9 67.63 246.53 3,641.2 3,583.7 - 2,297.6 - 1,382.8 6,028,746.38 468,462.26 1.50 1,213.19 End Dir 5243.90' MD, 3641.20' TVD 5,300.0 67.63 246.53 3,662.6 3,605.1 - 2,318.2 - 1,430.4 6,028,725.92 468,414.59 0.00 1,259.15 5,400.0 67.63 246.53 3,700.7 3,643.2 - 2,355.1 - 1,515.2 6,028,689.43 468,329.63 0.00 1,341.09 5,500.0 67.63 246.53 3,738.7 3,681.2 - 2,391.9 - 1,600.0 6,028,652.95 468,244.67 0.00 1,423.03 5,600.0 67.63 246.53 3,776.8 3,719.3 - 2,428.7 - 1,684.8 6,028,616.47 468,159.71 0.00 1,504.97 5,700.0 67.63 246.53 3,814.9 3,757.4 - 2,465.6 - 1,769.7 6,028,579.98 468,074.75 0.00 1,586.90 5,800.0 67.63 246.53 3,852.9 3,795.4 - 2,502.4 - 1,854.5 6,028,543.50 467,989.79 0.00 1,668.84 5,900.0 67.63 246.53 3,891.0 3,833.5 - 2,539.2 - 1,939.3 6,028,507.02 467,904.83 0.00 1,750.78 6,000.0 67.63 246.53 3,929.1 3,871.6 - 2,576.1 - 2,024.1 6,028,470.53 467,819.87 0.00 1,832.72 6,100.0 67.63 246.53 3,967.1 3,909.6 - 2,612.9 - 2,108.9 6,028,434.05 467,734.91 0.00 1,914.65 6,200.0 67.63 246.53 4,005.2 3,947.7 - 2,649.7 - 2,193.8 6,028,397.57 467,649.95 0.00 1,996.59 6,300.0 67.63 246.53 4,043.3 3,985.8 - 2,686.5 - 2,278.6 6,028,361.08 467,564.99 0.00 2,078.53 6,400.0 67.63 246.53 4,081.3 4,023.8 - 2,723.4 - 2,363.4 6,028,324.60 467,480.03 0.00 2,160.47 6,500.0 67.63 246.53 4,119.4 4,061.9 - 2,760.2 - 2,448.2 6,028,288.12 467,395.07 0.00 2,242.40 6,600.0 67.63 246.53 4,157.5 4,100.0 - 2,797.0 - 2,533.0 6,028,251.64 467,310.11 0.00 2,324.34 4/25/2008 9 :27 :16AM Page 5 COMPASS 2003.16 Build 42B • • • Sperry Drilling Services HALL1BURTON Standard Proposal Report Database: ..EDM _Alaska Local Co- ordinate Reference: Well ODSN -40 - Slot ODS -40 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44.0' + 13.5 @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -40 Survey Calculation Method: Minimum Curvature Welibore: ODSN -40 PN12 Design :. ODSN -40 PN12 wp10 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth TVDss +NI-S . +E/ -W Northing Easting DLS Vert Section (ft) (7) (bearing) (ft) ft (ft) (ft) (ft) (ft) 4,122.40 6,659.0 67.63 246.53 4,179.9 4,122.4 - 2,818.8 - 2,583.0 6,028,230.12 467,260.01 0.00 2,372.66 Brook 2B 6,700.0 67.63 246.53 4,195.5 4,138.0 - 2,833.9 - 2,617.9 6,028,215.15 467,225.15 0.00 2,406.28 6,800.0 67.63 246.53 4,233.6 4,176.1 - 2,870.7 - 2,702.7 6,028,178.67 467,140.19 0.00 2,488.22 6,900.0 67.63 246.53 4,271.7 4,214.2 - 2,907.5 - 2,787.5 6,028,142.19 467,055.23 0.00 2,570.15 7,000.0 67.63 246.53 4,309.7 4,252.2 - 2,944.4 - 2,872.3 6,028,105.70 466,970.27 0.00 2,652.09 7,100.0 67.63 246.53 4,347.8 4,290.3 - 2,981.2 - 2,957.1 6,028,069.22 466,885.31 0.00 2,734.03 7,200.0 67.63 246.53 4,385.8 4,328.3 - 3,018.0 - 3,042.0 6,028,032.74 466,800.35 0.00 2,815.97 7,300.0 67.63 246.53 4,423.9 4,366.4 - 3,054.9 - 3,126.8 6,027,996.25 466,715.39 0.00 2,897.90 7,400.0 67.63 246.53 4,462.0 4,404.5 - 3,091.7 - 3,211.6 6,027,959.77 466,630.43 0.00 2,979.84 7,500.0 67.63 246.53 4,500.0 4,442.5 - 3,128.5 - 3,296.4 6,027,923.29 466,545.47 0.00 3,061.78 7,600.0 67.63 246.53 4,538.1 4,480.6 - 3,165.4 - 3,381.2 6,027,886.80 466,460.51 0.00 3,143.72 7,700.0 67.63 246.53 4,576.2 4,518.7 - 3,202.2 - 3,466.1 6,027,850.32 466,375.55 0.00 3,225.65 7,800.0 67.63 246.53 4,614.2 4,556.7 - 3,239.0 - 3,550.9 6,027,813.84 466,290.59 0.00 3,307.59 7,900.0 67.63 246.53 4,652.3 4,594.8 - 3,275.8 - 3,635.7 6,027,777.35 466,205.63 0.00 3,389.53 8,000.0 67.63 246.53 4,690.4 4,632.9 - 3,312.7 - 3,720.5 6,027,740.87 466,120.67 0.00 3,471.47 8,100.0 67.63 246.53 4,728.4 4,670.9 - 3,349.5 - 3,805.3 6,027,704.39 466,035.71 0.00 3,553.40 8,200.0 67.63 246.53 4,766.5 4,709.0 - 3,386.3 - 3,890.2 6,027,667.90 465,950.75 0.00 3,635.34 8,300.0 67.63 246.53 4,804.6 4,747.1 - 3,423.2 - 3,975.0 6,027,631.42 465,865.79 0.00 3,717.28 8,400.0 67.63 246.53 4,842.6 4,785.1 - 3,460.0 - 4,059.8 6,027,594.94 465,780.83 0.00 3,799.22 8,500.0 67.63 246.53 4,880.7 4,823.2 - 3,496.8 - 4,144.6 6,027,558.45 465,695.87 0.00 3,881.15 8,600.0 67.63 246.53 4,918.8 4,861.3 - 3,533.7 - 4,229.4 6,027,521.97 465,610.91 0.00 3,963.09 8,612.1 67.63 246.53 4,923.4 4,865.9 - 3,538.1 - 4,239.7 6,027,517.54 465,600.59 0.00 3,973.05 Top Torok Sand 8,700.0 67.63 246.53 4,956.8 4,899.3 - 3,570.5 - 4,314.3 6,027,485.49 465,525.95 0.00 4,045.03 8,800.0 67.63 246.53 4,994.9 4,937.4 - 3,607.3 - 4,399.1 6,027,449.00 465,440.99 0.00 4,126.97 8,900.0 67.63 246.53 5,033.0 4,975.5 - 3,644.2 - 4,483.9 6,027,412.52 465,356.03 0.00 4,208.90 9,000.0 67.63 246.53 5,071.0 5,013.5 - 3,681.0 - 4,568.7 6,027,376.04 465,271.07 0.00 4,290.84 9,100.0 67.63 246.53 5,109.1 5,051.6 - 3,717.8 - 4,653.5 6,027,339.55 465,186.11 0.00 4,372.78 9,200.0 67.63 246.53 5,147.2 5,089.7 - 3,754.7 - 4,738.4 6,027,303.07 465,101.15 0.00 4,454.72 9,214.7 67.63 246.53 5,152.8 5,095.3 - 3,760.1 - 4,750.8 6,027,297.71 465,088.66 0.00 ' 4,466.76 Start Dir 3.00/100' 9214.70' MD, 5152.80' TVD 9,264.5 67.39 248.13 5,171.8 5,114.3 - 3,777.8 - 4,793.2 6,027,280.16 465,046.18 3.00 4,507.78 Base Torok Sand 9,300.0 67.24 249.27 5,185.5 5,128.0 - 3,789.7 - 4,823.8 6,027,268.37 465,015.58 3.00 4,537.40 9,400.0 66.84 252.50 5,224.5 5,167.0 - 3,819.9 - 4,910.8 6,027,238.58 464,928.48 3.00 4,621.98 9,500.0 66.52 255.75 5,264.1 5,206.6 - 3,845.0 - 4,999.1 6,027,213.81 464,840.08 3.00 4,708.24 9,600.0 66.25 259.01 5,304.2 5,246.7 - 3,865.0 - 5,088.5 6,027,194.16 464,750.61 3.00 4,795.96 9,700.0 66.06 262.28 5,344.6 5,287.1 - 3,879.9 - 5,178.7 6,027,179.66 464,660.33 3.00 4,884.88 9,800.0 65.94 265.56 5,385.3 5,327.8 - 3,889.5 - 5,269.5 6,027,170.35 464,569.47 3.00 4,974.77 9,900.0 65.89 268.85 5,426.1 5,368.6 - 3,894.0 - 5,360.7 6,027,166.27 464,478.30 3.00 5,065.38 10,000.0 65.91 272.13 5,467.0 5,409.5 - 3,893.2 - 5,452.0 6,027,167.43 464,387.05 3.00 5,156.46 10,100.0 65.99 275.42 5,507.7 5,450.2 - 3,887.2 - 5,543.1 6,027,173.81 464,295.98 3.00 5,247.76 10,200.0 66.15 278.70 5,548.3 5,490.8 - 3,876.0 - 5,633.8 6,027,185.41 464,205.34 3.00 5,339.03 10,300.0 66.38 281.96 5,588.6 5,531.1 - 3,859.5 - 5,723.8 6,027,202.18 464,115.37 3.00 5,430.02 4/25/2008 9:27 :16AM Page 6 COMPASS 2003.16 Build 42B • • Sperry Drilling Services HALL1BURTON Standard Proposal Report Database: ..EDM_Alaska Local Co-ordinate Reference: Well ODSN -40 - Slot ODS -40 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44.0' + 13.5 @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -40 Survey Calculation Method: Minimum Curvature Wellborn: ODSN -40 PN12 Design: ODSN -40 PN12 wp10 Planned Survey Measured Vertical Map Map Depth Inclination .Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) ( ?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 5,570.90 10,400.0 66.67 285.22 5,628.4 5,570.9 - 3,838.0 - 5,813.0 6,027,224.10 464,026.33 3.00 5,520.49 10,500.0 67.04 288.46 5,667.7 5,610.2 - 3,811.4 - 5,900.9 6,027,251.09 463,938.46 3.00 5,610.17 10,574.3 67.35 290.85 5,696.5 5,639.0 - 3,788.3 - 5,965.4 6,027,274.37 463,874.10 3.00 5,676.13 Top HRZ 10,600.0 67.46 291.68 5,706.4 5,648.9 - 3,779.7 - 5,987.5 6,027,283.07 463,851.99 3.00 5,698.84 10,700.0 67.96 294.88 5,744.3 5,686.8 - 3,743.2 - 6,072.5 6,027,319.98 463,767.17 3.00 5,786.24 10,800.0 68.51 298.05 5,781.4 5,723.9 - 3,701.8 - 6,155.7 6,027,361.69 463,684.22 3.00 5,872.13 10,900.0 69.12 301.20 5,817.6 5,760.1 - 3,655.7 - 6,236.7 6,027,408.11 463,603.38 3.00 5,956.29 10,939.9 69.38 302.45 5,831.7 5,774.2 - 3,636.0 - 6,268.4 6,027,427.90 463,571.77 3.00 5,989.31 Base HRZ 11,000.0 69.79 304.32 5,852.7 5,795.2 - 3,605.0 - 6,315.4 6,027,459.09 463,524.87 3.00 6,038.47 11,100.0 70.51 307.42 5,886.6 5,829.1 - 3,549.9 - 6,391.6 6,027,514.51 463,448.89 3.00 6,118.46 11,151.7 70.91 309.01 5,903.7 5,846.2 - 3,519.7 - 6,429.9 6,027,544.83 463,410.70 3.00 6,158.85 Kalubik Marker 11,200.0 71.29 310.49 5,919.4 5,861.9 - 3,490.5 - 6,465.1 6,027,574.20 463,375.67 3.00 6,196.03 11,300.0 72.12 313.52 5,950.8 5,893.3 - 3,427.0 - 6,535.6 6,027,638.01 463,305.40 3.00 6,270.97 11,377.8 72.79 315.87 5,974.2 5,916.7 - 3,374.8 - 6,588.3 6,027,690.36 463,252.92 3.00 6,327.29 Top Kuparuk C 11,393.0 72.93 316.32 5,978.7 5,921.2 - 3,364.3 - 6,598.4 6,027,700.91 463,242.85 3.00 6,338.14 Base Kuparuk (LCU) 11,400.0 72.99 316.53 5,980.7 5,923.2 - 3,359.5 - 6,603.0 6,027,705.76 463,238.27 3.00 6,343.08 11,500.0 73.90 319.51 6,009.2 5,951.7 - 3,288.2 - 6,667.1 6,027,777.27 463,174.47 3.00 6,412.16 11,600.0 74.86 322.47 6,036.2 5,978.7 - 3,213.4 - 6,727.7 6,027,852.33 463,114.17 3.00 6,478.01 11,614.2 75.00 322.88 6,039.9 5,982.4 ' - 3,202.5 - 6,736.1 6,027,863.27 463,105.90 2.99 6,487.09 End Dir 11614.20' MD, 6039.90' TVD 11,700.0 75.00 322.88 6,062.1 6,004.6 - 3,136.4 - 6,786.1 6,027,929.55 463,056.16 0.00 6,541.75 11,800.0 75.00 322.88 6,087.9 6,030.4 - 3,059.4 - 6,844.4 6,028,006.80 462,998.19 0.00 6,605.45 11,894.5 75.00 322.88 6,112.4 6,054.9 - 2,986.6 - 6,899.4 6,028,079.78 462,943.42 0.00 6,665.63 Top Nuiqsut 11,900.0 75.00 322.88 6,113.8 6,056.3 - 2,982.4 - 6,902.7 6,028,084.05 462,940.22 0.00 6,669.15 11,9142 75.00 322.88 6,117.5 6,060.0 - 2,971.4 - 6,910.9 6,028,095.00 462,932.00 0.00 6,678.19 Start Dir 3.00 /100' 11914.20' MD, 6117.50' TVD - 7" - PN12 v10 T1 12,000.0 77.57 322.98 6,137.8 6,080.3 - 2,904.9 - 6,961.2 6,028,161.72 462,882.02 3.00 6,733.11 12,100.0 80.57 323.09 6,156.8 6,099.3 - 2,826.5 - 7,020.2 6,028,240.39 462,823.31 3.00 6,797.66 12,200.0 83.57 323.20 6,170.6 6,113.1 - 2,747.2 - 7,079.6 6,028,319.86 462,764.24 3.00 6,862.63 12,300.0 86.57 323.31 6,179.2 6,121.7 - 2,667.4 - 7,139.2 6,028,399.92 462,704.97 3.00 6,927.84 12,343.8 87.88 323.35 6,181.3 6,123.8 - 2,632.3 - 7,165.3 6,028,435.11 462,678.99 3.00 6,956.44 End Dir 12343.80' MD, 6181.30' TVD 12,400.0 87.88 323.35 6,183.4 6,125.9 - 2,587.3 - 7,198.9 6,028,480.30 462,645.65 0.00 6,993.13 12,500.0 87.88 323.35 6,187.1 6,129.6 - 2,507.1 - 7,258.5 6,028,560.71 462,586.34 0.00 7,058.41 12,600.0 87.88 323.35 6,190.8 6,133.3 - 2,426.9 - 7,318.1 6,028,641.13 462,527.02 0.00 7,123.69 12,700.0 87.88 323.35 6,194.5 6,137.0 - 2,346.7 - 7,377.8 6,028,721.54 462,467.71 0.00 7,188.97 12,800.0 87.88 323.35 6,198.2 6,140.7 - 2,266.6 - 7,437.4 6,028,801.95 462,408.39 0.00 7,254.26 12,900.0 87.88 323.35 6,201.9 6,144.4 - 2,186.4 - 7,497.1 6,028,882.36 462,349.08 0.00 7,319.54 13,000.0 87.88 323.35 6,205.6 6,148.1 - 2,106.2 - 7,556.7 6,028,962.77 462,289.76 0.00 7,384.82 4/25/2008 9:27:16AM Page 7 COMPASS 2003.16 Build 428 • • Sperry Drilling Services HALLI B U RTD N Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN -40 - Slot ODS -40 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -40 Survey Calculation Method: Minimum Curvature Wellbore: ODSN -40 PN12 Design: ODSN -40 PN12 wp10 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth TVDss +N/-S +E/AN Northing Easting DLS Vert Section (ft) ( ?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,150.87 13,075.1 87.88 323.35 6,208.4 6,150.9 - 2,046.0 - 7,601.5 6,029,023.16 462,245.22 0.00 7,433.85 Start Dir 3.00/100' 13075.10' MD, 6208.40' TVD 13,100.0 88.15 322.66 6,209.2 6,151.7 - 2,026.1 - 7,616.5 6,029,043.10 462,230.32 3.00 7,450.22 13,200.0 89.23 319.86 6,211.5 6,154.0 - 1,948.1 - 7,679.1 6,029,121.31 462,168.09 3.00 7,518.25 13,271.5 90.00 317.86 6,212.0 6,154.5 - 1,894.3 - 7,726.1 6,029,175.30 462,121.30 3.00 7,569.03 PN12 v10 T2 13,300.0 90.86 317.87 6,211.8 6,154.3 - 1,873.2 - 7,745.2 6,029,196.54 462,102.24 3.00 7,589.65 13,343.2 92.15 317.90 6,210.7 6,153.2 - 1,841.1 - 7,774.2 6,029,228.69 462,073.41 3.00 7,620.85 End Dir 13343.20' MD, 6210.70' TVD 13,400.0 92.15 317.90 6,208.5 6,151.0 - 1,799.0 - 7,812.2 6,029,270.95 462,035.54 0.00 7,661.85 13,500.0 92.15 317.90 6,204.8 6,147.3 - 1,724.9 - 7,879.2 6,029,345.36 461,968.85 0.00 7,734.03 13,600.0 92.15 317.90 6,201.0 6,143.5 - 1,650.7 - 7,946.2 6,029,419.77 461,902.16 0.00 7,806.20 13,700.0 92.15 317.90 6,197.3 6,139.8 - 1,576.6 - 8,013.2 6,029,494.18 461,835.47 0.00 7,878.38 13,800.0 92.15 317.90 6,193.5 6,136.0 - 1,502.4 - 8,080.2 6,029,568.59 461,768.78 0.00 7,950.56 13,900.0 92.15 317.90 6,189.8 6,132.3 - 1,428.3 - 8,147.2 6,029,643.00 461,702.10 0.00 8,022.74 14,000.0 92.15 317.90 6,186.0 6,128.5 - 1,354.2 - 8,214.2 6,029,717.40 461,635.41 0.00 8,094.91 14,100.0 92.15 317.90 6,182.3 6,124.8 - 1,280.0 - 8,281.2 6,029,791.81 461,568.72 0.00 8,167.09 14,200.0 92.15 317.90 6,178.5 6,121.0 - 1,205.9 - 8,348.2 6,029,866.22 461,502.03 0.00 8,239.27 14,300.0 92.15 317.90 6,174.7 6,117.2 - 1,131.7 - 8,415.2 6,029,940.63 461,435.34 0.00 8,311.45 14,400.0 92.15 317.90 6,171.0 6,113.5 - 1,057.6 - 8,482.2 6,030,015.04 461,368.65 0.00 8,383.62 14,500.0 92.15 317.90 6,167.2 6,109.7 -983.4 - 8,549.2 6,030,089.44 461,301.97 0.00 8,455.80 14,568.1 92.15 317.90 6,164.7 6,107.2 -932.9 - 8,594.8 6,030,140.12 461,256.55 0.00 8,504.95 Start Dir 3.00/100' 14568.10' MD, 6164.70' TVD 14,600.0 91.34 317.39 6,163.7 6,106.2 -909.4 - 8,616.3 6,030,163.76 461,235.17 3.00 8,528.08 14,652.5 90.00 316.56 6,163.1 6,105.6 -871.0 - 8,652.1 6,030,202.30 461,199.50 3.00 8,566.59 PN12 v10 T3 14,700.0 88.58 316.55 6,163.7 6,106.2 -836.5 - 8,684.8 6,030,236.90 461,167.00 3.00 8,601.64 14,800.0 85.58 316.51 6,168.8 6,111.3 -764.0 - 8,753.5 6,030,309.64 461,098.60 3.00 8,675.40 14,900.0 82.58 316.48 6,179.1 6,121.6 -691.9 - 8,821.9 6,030,382.04 461,030.43 3.00 8,748.90 14,997.4 79.65 316.44 6,194.2 6,136.7 -622.2 - 8,888.2 6,030,452.05 460,964.44 3.00 8,820.05 • End Dir 14997.40' MD, 6194.20' TVD 15,000.0 79.65 316.44 6,194.6 6,137.1 -620.3 - 8,890.0 6,030,453.91 460,962.68 0.00 8,821.94 15,100.0 79.65 316.44 6,212.6 6,155.1 -549.0 - 8,957.8 6,030,525.47 460,895.19 0.00 8,894.70 15,200.0 79.65 316.44 6,230.5 6,173.0 -477.7 - 9,025.6 6,030,597.03 460,827.70 0.00 8,967.46 15,300.0 79.65 316.44 6,248.5 6,191.0 -406.4 - 9,093.3 6,030,668.58 460,760.21 0.00 9,040.22 15,400.0 79.65 316.44 6,266.5 6,209.0 -335.1 - 9,161.1 6,030,740.14 460,692.71 0.00 9,112.99 15,425.2 79.65 316.44 6,271.0 6,213.5 -317.2 - 9,178.2 6,030,758.17 460,675.71 0.00 9,131.32 Start Dir 3.00/100' 15425.20' MD, 6327.00' TVD 15,500.0 81.89 316.59 6,283.0 6,225.5 -263.6 - 9,229.0 6,030,811.94 460,625.12 3.00 9,185.86 15,600.0 84.89 316.78 6,294.5 6,237.0 -191.3 - 9,297.2 6,030,884.47 460,557.28 3.00 9,259.05 15,700.0 87.88 316.97 6,300.8 6,243.3 -118.5 - 9,365.4 6,030,957.57 460,489.37 3.00 9,332.35 15,770.7 90.00 317.10 6,302.1 6,244.6 -66.8 - 9,413.6 6,031,009.51 460,441.39 3.00 9,384.16 PN12 v10 T4 15,800.0 90.88 317.10 6,301.9 6,244.4 -45.3 - 9,433.5 6,031,031.03 460,421.55 3.00 9,405.58 4/25/2008 9 :27 :16AM Page 8 COMPASS 2003.16 Build 42B • • Sperry Drilling Services HALLIBURTO11111 Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN -40 - Slot ODS -40 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -40 Survey Calculation Method: Minimum Curvature We!lbore: ODSN -40 PN12 Design: ODSN -40 PN12 wp10 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (ft) ( ?) (bearing) (ft) ft (ft) (ft) (ft) (ft) 6,243.58 15,832.9 91.87 317.10 6,301.1 6,243.6 -21.2 - 9,455.9 6,031,055.21 460,399.27 3.00 9,429.65 End Dir 15832.90' MD, 6301.10' TVD 15,900.0 91.87 317.10 6,298.9 6,241.4 27.9 - 9,501.5 6,031,104.52 460,353.82 0.00 9,478.73 16,000.0 91.87 317.10 6,295.6 6,238.1 101.1 - 9,569.6 6,031,178.00 460,286.09 0.00 9,551.87 16,100.0 91.87 317.10 6,292.4 6,234.9 174.3 - 9,637.6 6,031,251.49 460,218.36 0.00 9,625.02 16,200.0 91.87 317.10 6,289.1 6,231.6 247.5 - 9,705.6 6,031,324.98 460,150.63 0.00 9,698.16 16,300.0 91.87 317.10 6,285.9 6,228.4 320.8 - 9,773.7 6,031,398.46 460,082.90 0.00 9,771.31 16,400.0 91.87 317.10 6,282.6 6,225.1 394.0 - 9,841.7 6,031,471.95 460,015.17 0.00 9,844.45 16,500.0 91.87 317.10 6,279.4 6,221.9 467.2 - 9,909.7 6,031,545.43 459,947.44 0.00 9,917.60 16,600.0 91.87 317.10 6,276.1 6,218.6 540.4 - 9,977.8 6,031,618.92 459,879.72 0.00 9,990.74 16,700.0 91.87 317.10 6,272.8 6,215.3 613.6 - 10,045.8 6,031,692.40 459,811.99 0.00 10,063.89 16,800.0 91.87 317.10 6,269.6 6,212.1 686.9 - 10,113.8 6,031,765.89 459,744.26 0.00 10,137.04 • 16,867.0 91.87 317.10 6,267.4 - 6,209.9 735.9 - 10,159.4 6,031,815.10 459,698.90 0.00 10,186.02 PN12 v10 T5 4/25/2008 9 :27 :16AM Page 9 COMPASS 2003.16 Build 428 • • Sperry Drilling Services HALL1BURTON Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN - 40 - Slot ODS - 40 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Weil: ODSN -40 Survey Calculation Method: Minimum Curvature Weilbore: ODSN -40 PN12 . Design: ODSN -40 PN12 wp10 Targets Target WO t Name +E/-W Northing Easting hit/miss target Dip Angle Dip DirWO +N!-S g g - Shape ( ?) (bearing (ft) (ft) (ft) (ft) (ft) PN12 Geo Poly 0.00 0.00 6,117.5 - 3,231.2 - 6,884.9 6,027,835.21 462,956.93 - plan misses by 147.7ft at 11699.0ft MD (6061.8 TVD, - 3137.2 N, - 6785.5 E) - Polygon Point 1 6,117.5 - 3,231.2 - 6,884.9 6,027,835.21 462,956.93 Point 2 6,117.5 - 2,132.0 - 7,729.9 6,028,937.72 462,116.48 Point 3 6,117.5 - 1,043.6 - 8,738.7 6,030,030.09 461,112.20 Point4 6,117.5 661.7 - 10,384.7 6,031,741.88 459,473.30 Point 5 6,117.5 956.4 - 10,070.1 6,032,035.27 459,789.06 Point6 6,117.5 -811.3 - 8,460.9 6,030,261.24 461,390.91 Point 7 6,117.5 - 1,953.4 - 7,478.1 6,029,115.28 462,368.98 Point 8 6,117.5 - 3,066.2 - 6,668.7 6,027,999.32 463,173.78 PN12 v10 T3 0.00 0.00 6,163.1 -871.0 - 8,652.1 6,030,202.30 461,199.50 - plan hits target - Point PN12 v10 T1 0.00 0.00 6,117.5 - 2,971.4 - 6,910.9 6,028,095.00 462,932.00 - plan hits target - Point PN12 Fault #1 0.00 0.00 6,117.5 - 4,459.2 - 5,576.2 6,026,602.00 464,260.52 - plan misses by 812.6ft at 10281.6ft MD (5581.2 TVD, - 3863.0 N, - 5707.3 E) - Polygon Point 1 6,117.5 - 5,118.4 - 5,372.0 6,025,942.04 464,462.02 Point2 6,117.5 - 2,481.5 - 6,188.7 6,028,581.97 463,656.10 Point 3 6,117.5 - 1,822.8 - 6,543.8 6,029,242.04 463,303.71 Point4 6,117.5 - 1,163.8 - 6,804.1 6,029,902.02 463,046.11 Point5 6,117.5 - 1,822.6 - 6,491.6 6,029,242.02 463,355.91 Point6 6,117.5 - 2,481.4 - 6,172.6 6,028,582.00 463,672.20 Point 7 6,117.5 - 2,920.6 - 5,974.3 6,028,142.05 463,868.70 Point 8 6,117.5 - 3,799.9 - 5,756.4 6,027,261.96 464,083.01 Point 9 6,117.5 - 4,678.9 - 5,486.5 6,026,381.96 464,349.31 PN12 v10 T4 0.00 0.00 6,302.1 -66.8 - 9,413.6 6,031,009.51 460,441.39 - plan hits target - Point PN12 v10 T2 0.00 0.00 6,212.0 - 1,894.3 - 7,726.1 6,029,175.30 462,121.30 - plan hits target - Point . PN12v10T5 0.00 0.00 6,267.4 735.9 - 10,159.4 6,031,815.10 459,698.90 - plan hits target - Point PN12 Fault #2 0.00 0.00 6,117.5 581.3 - 10,640.2 6,031,662.50 459,217.56 - plan misses by 526.8ft at 16867.0ft MD (6267.4 TVD, 735.9 N, - 10159.4 E) - Polygon Point 1 6,117.5 581.3 - 10,640.2 6,031,662.50 459,217.56 Point2 6,117.5 1,020.8 - 10,769.5 6,032,102.48 459,090.06 Point 3 6,117.5 2,339.9 - 11,034.4 6,033,422.51 458,830.54 Point4 6,117.5 2,998.4 - 11,430.2 6,034,082.54 458,437.45 Point 5 6,117.5 3,656.8 - 11,825.2 6,034,742.47 458,045.16 Point 6 6,117.5 4,096.1 - 12,006.5 6,035,182.46 457,865.66 Point 7 6,117.5 3,437.4 - 11,684.9 6,034,522.52 458,184.56 Point 8 6,117.5 2,559.5 - 11,136.6 6,033,642.50 458,729.24 Point 9 6,117.5 2,120.3 - 10,917.4 6,033,202.46 458,946.63 Point 10 6,117.5 1,900.5 - 10,876.5 6,032,982.51 458,986.64 Point 11 6,117.5 1,020.8 - 10,763.8 6,032,102.45 459,095.76 Point 12 6,117.5 581.3 - 10,640.2 6,031,662.50 459,217.56 4/25/2008 9 :27 :16AM Page 10 COMPASS 2003.16 Build 428 • • Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM_Alaska Local Co- ordinate Reference: Well ODSN -40 - Slot ODS -40 Company: Well Planning - Pioneer - Oooguruk TVD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Project: Oooguruk Developement MD Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN -40 Survey Calculation Method: Minimum Curvature Wellbore: ODSN -40 PN12 Design: ODSN -40 PN12 wp10 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,593.8 2,995.0 9 5/8" 9.625 12.250 11,914.2 6,117.5 7" 7.000 8.750 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology ( ?) (bearing) 3,558.0 2,980.7 Tuffaceous Shales 0.00 11,393.0 5,978.7 Base Kuparuk (LCU) 0.00 8,612.1 4,923.4 Top Torok Sand 0.00 9,264.5 5,171.8 Base Torok Sand 0.00 11,377.8 5,974.2 Top Kuparuk C 0.00 11,894.5 6,112.4 Top Nuiqsut 0.00 6,659.0 4,179.9 Brook 2B 0.00 1,644.8 1,607.5 Base of Permafrost 0.00 10,574.3 5,696.5 Top HRZ 0.00 3,387.3 2,904.7 Hue Shale 0.00 11,151.7 5,903.7 Kalubik Marker 0.00 2,530.5 2,354.2 Top West Sak 0.00 10,939.9 5,831.7 Base HRZ 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E! W (ft) (ft) (ft) (ft) Comment 300.0 300.0 0.0 0.0 Start Dir 1.00/100' 300.00' MD, 300.00' TVD 800.0 799.4 -18.9 10.9 Start Dir 2.00/100' 800.00' MD, 799.40' TVD 1,050.0 1,047.1 -47.1 27.2 Start Dir 3.00/100' 1050.00' MD, 1047.10' TVD 1,693.2 1,650.0 -233.5 134.8 End Dir 1693.20' MD, 1650.00' TVD 1,807.8 1,750.0 -282.1 162.9 Start Dir 3.38/100' 1807.80' MD, 1750.00' TVD 3,593.8 2,995.0 - 1,395.0 -179.2 End Dir 3593.80' MD, 2995.00' TVD 3,613.8 3,002.8 - 1,409.1 -191.1 Start Dir 1.5/100' 3613.80' MD, 3002.80' TVD 5,243.9 3,641.2 - 2,297.6 - 1,382.8 End Dir 5243.90' MD, 3641.20' TVD 9,214.7 5,152.8 - 3,760.1 - 4,750.8 Start Dir 3.00/100' 9214.70' MD, 5152.80' TVD 11,614.2 6,039.9 - 3,202.5 - 6,736.1 End Dir 11614.20' MD, 6039.90' TVD 11,914.2 6,117.5 - 2,971.4 - 6,910.9 Start Dir 3.00/100' 11914.20' MD, 6117.50' TVD 12,343.8 6,181.3 - 2,632.3 - 7,165.3 End Dir 12343.80' MD, 6181.30' TVD 13,075.1 6,208.4 - 2,046.0 - 7,601.5 Start Dir 3.00/100' 13075.10' MD, 6208.40' TVD 13,343.2 6,210.7 - 1,841.1 - 7,774.2 End Dir 13343.20' MD, 6210.70' TVD 14,568.1 6,164.7 -932.9 - 8,594.8 Start Dir 3.00/100' 14568.10' MD, 6164.70' TVD 14,997.4 6,194.2 -622.2 - 8,888.2 End Dir 14997.40' MD, 6194.20' TVD 15,425.2 6,271.0 -317.2 - 9,178.2 Start Dir 3.00/100' 15425.20' MD, 6327.00' TVD 15,832.9 6,301.1 -21.2 - 9,455.9 End Dir 15832.90' MD, 6301.10' TVD 16,867.0 6,267.4 735.9 - 10,159.4 Total Depth at 16867.00' MD, 6267.40' TVD 4/25/2008 9 :27 :16AM Page 11 COMPASS 2003.16 Build 428 • • 1. Mck•Y WPC C 3 1 /e -2000 PSI NE sm.* 2. *WV IYPE C 2 9/16'-5000 PSI CARMINE E • . 3. /OIE DIME CHOKE MANIFOLD SC EMATIC %CO 2 1/16 -10030 PSI 9EI nlowSS L-cwAKR 3 1 /8 -5000 PSI swam QOM • NABORS ALASKA RIG 19AC s. &MID IEE 2 I /16 x 2 I /1a• X 2 I /l6 -2000 PSI • 6. a Mg at* BIACX 3 I /e' x 3 1 /e X 2 1 /le• X 2 1/12• x 2 I /Ie' -s0110 P!1 • 7. 5 MY FLO0 9.0C 3 1 /e x 3 1 /e• x 3 1 /e• x 3 1 /e' x 2 1 /If -5000 PSI • 4 4 IN BLOC 2 1 le X 2 1 le' X 2 1 1' 6 X • • • 3 / / / s 1/16 -5000 PSI T ' 9. 2 1/W-5000 PSI Soma 8=8 S� ' • 10. 2 1/16 - l0.000P91 2.2 1 /le' -5000 P51 SPOOL - V/ 11. 3 1 /e• X 2 1 /Ie P9 wax TK - .12. a or 2 1 /u -2000 . PSI SP00. 13. 3 1 /e• - 5000 PSI 2 2 1/16 -5000 PSI SPU(L . . 1 N. 2 1/W PSI X 2 1 /1e' - 2000 P9 caulk( SND amok 2 12. 2 1/16• - s000 PSI us a PlM1cE • • 14 3 I /6' -51100 PSI IM4C J FUICE • 3' 17. S 1 /n' -SOW PSI x 2 1/16' -2000 PSI IXXII9E SBA) IIOMI ® 1 A& �I 0 j 14 3 1 x 3 1/8 5 000 PSI seat 19. 3 .#1 PLOD BLOCK 3 1 /e' 8 3 1 /e' X 3 1 /e•-5000 PSI I 1NE W \ I 1 20. 5 uAY Mr BLOCK 2 9/16' X 2 9/16' x 2 9/16 X 2 9/W 2 2 9/16 -5000 psi I • • ®Z m o 3• Tp 1 is � \ . . • © 0 j 2�g ; m ��► t t /� 6 014E 0 O �� i . G�o,cE 2 t 3 . d • • • • ilrael fUI.IPOLD Scn 1 --------'-'4: 11C 1 aLll MEE mom as Imo 8. a ' 1.S ...... o' • • • -. EMU n`�.+ .. O �r- as . • • • • • t ' • • • • : . . • . • . . i HYORLL 11" 5k P9 ... • ; CK AMOUR _OOP • 3 '— I 1 " 1 FLANGED B0 QM CONNECTION • • I 47.3/4 LENGTH . 1 _� ----- - - - -- — i - 11" 50001 . I ...... FLANGED HYORIL 10- • DO 4 —7 UBLE GATE PREVENTOR • 0 . • 13' -10" 3 1/8" 50001 HC VALV£ _� - - -- —� - - - - -- 55" LENGTH 1 � � . i 3 1/8" 50001 HCR VALVE I.-91' 3' CHOKE L £ 1271 4 11 4 11 11'1- 4t1 - 11 2 " KILL UNE 1 =Z r- -- - - - - • I 3 1/8" 50001 TE VALVE :. 3 " 50001 CATE VALVE HYDRIL 1l" 5k PSf -. HYORAUUC RAM SINGLE CATE j�_ - -- - - - -- — —. — _ FLANGED ONNECTtON I 41 3/4 LENGTH • • . NABORS ALASKA RIG 19AC . BOP STACK CONFIGURATION • • • :a _II . _ i► � �� �� • ` 111111 ' ,MM6 "AVM la: 1arC MA iAmit-MAnimo • • • • A L w ` 4 w�*.Mwu ' 11 a " ..a alt w • low 1111111111111 ir memo ag III i i: :Li MOM SPOLL III im -!zi Oki 0 11llL'::Iiil _a u_i lei r 1111111 t SO -:—.=.4:4 I Ai ,._.i@ 1 i i l ii �� law Eli iillll„ll,ll IN , to Nown legifOr?r �� ww F+-y FI -iWrW , OMM .' .$M ILL' 1 � C 11■ /, I wEX1tii • Legend �� • 1 M • a 1 As -Dolt C onductor y� • • • O O • • Mp.t ••••••••, . �L:1�,. j . • •• • .i s •4 • „„...\*.),.. • qo • • 4 . • L• 1 k{ • 1� 0 I ,o i `� • Location 'Map • • sA. • 4 • GRAPHIC SCALZ 4' •• • • • 30 119 a sa �,� OF �1 • • . ,� • •9 . Ar ' °� ••... ..... .:q' t, % tM• -r.e. 1h • ‘O'') • r J• l .• . � ▪ 4 J l ' • • u : G. oa.1. t f.f se • . 'Jn 1 0,, Ni Ma. 41l0S • :' • Y ° �' I jTs t � f • • • tt .' . . • as '. s Plan..r Sutural Roewuw• IP . J OB NAME: Oooqur Drill Stt! DRAWN BY: at. ILA CHECKED BY: A • • LOCATION: Protroated 6wtl.n ,11 SCALE: 1'.30" • n. • ia.hip 13 No" Rang* 7 Ea.i • ' DATE: 7 -12 -07 - Wnlat Meridian 1: • No 4 NAM { JOB NO. SHEET • Coordinates or. 0•11/4 an shoots 3 and 41 DESCRIPTION: I Ma•ka Nod 27, Zan. 4 Cooduatar As-1;160i Pion ! 03204 1 014 0 0 - ---7- . • ! L .., , , • ... . "i iiul Fo mdr) I T 1 corner of • 1 , oomoRUx s7E Protracted Section 11 • >< n e s = V • m t1 Coordinates �• . N 60281 -� r. 6028111.04 • �l • r l E 4i0S83.01 1 . • a 1 \ • . e . t� ?Sx • R ef_ AK , BLM ■ s � • • �A ♦ ♦ ■ ` � H arrison: Boy .Troc A Pi- < <:� Rf ► r c W i is ...-- 1 ''s% e §k.. . r-17,4 • 4 i s ic •,.,.. 1 14. 4 +� J • Q' Ci�!,en 1r/rms.-LP e ) V • `.-� • roar Same Ierool' =3.67=+' 4 • - P: 20 ie Cwoc_•r .,4 :As ♦ ♦ PI 7 io Pi, . 3t � � a e � . * \ i " }. sl. , • CI-2t I . / ? ♦ . lunar= Ite•e •1 i .4% . .,...„...1.4, . D5 3M 1 O.F • a ♦ e r p Fods am. O or 1. a. . 0 ir • , 3 PI- sf- = • • 11 - t'"' Ft " Basis of Location I'' ElfC`' /A 4Ca:El�r / DS -3H West Monument • A V ' Coordinates l :•R,>s_ N 6001016.61 411416 I . .. E 596081.23 .S1AKCD P1 INFCRMR71oN ONLY r iv ?•: ._ _.. ......- ._...... oW _ R � __ � `�.� of i nsbury & Assoc • ..._.^ ..... rowing No. �in •� NSK 6.01-d672 Lt ,,�f �. ...1.• .4, SJi 1 �� y ` _ ma c Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Frotrocied Section 11 SCALE: N/A Township 13 North - ' Range 7 East - DATE: 7 -12 -07 Urniot Meridian NANUQ JOB NO. SHEET DESCRIPTION: . • Basis of Location 05204 2 of 4 . . • 0 . __________ , , , ------, - - - - - - A 1 a s ii Sizte P$ne — 7 S (i Line Oft - ---- ' - -- .--------- • si 6,01,161,4 4 702145,24150 150 14 46.4646 IBM - 6, al: rig., 6 49;916,52 -- 7 . 29 - 45,19252 - .- 50 -7 14 45,60922 5050 102 . 14,50 7 4 505141,9 --- :49910:59 -- -- 7025 --- 4:5 - , - 1Ta4 50'171 475 - 5026 . .10 - 7 -7- -- 6,0$4:1:446 49x.:0 - 'itig 5.055 .- 15V14 4 5020 1092 ---- --- 6 - ,4i,I1,45 --- - 459,900,74 - 70 29 46,0455 .- 1501 - 5.2 - - 50 7 15 • 1 f$: 6 - - "6,0?1,12 . 6,$1 - 4 0060 25•4,V,q660 -- 10 -- f446.i7:5 - 1 - 3.010 1102 16:60 • . RIM 6,0 469,M1$ i i0a9 - - 150 - 14 6 2997 1115 --- 6:0 - e0 -- :$7821 70 45 15 45.70505 294 1120 •15 9 5,0 Z69, - 70 29 477104 '101 297 Nem ly, 1v 5,01,096,79 469,555,56 ?�2945728 160 14 29'62 -7 i1$ - 0 -- 1540 Mit 5,051,09,54 469,555,5 - 70 29 45,57n5 - 150 1 -- 2977 MEM - 15,50 . KIISM11111 4.. # .. _8E i 4.!=?, ..---- -- rid ... - 445.6gii ----- i6IFIAA7. - 6174 2972 1140 NM e,0f,076, 06 ---- 46, - 7P295547D - 14 2960 1152 - 14:50 ---- 6 007 09 - - 459,840 ,$1 - - 7 - 0 - 29 - 46 - ,42 -- - 160 1 - 29 6 11 — - 16 -' ' 6:051,006,15 - 459,85,96 - - 70 29 150 14 41,94155 2950 1162 --- 15:50 - — 601, Q61,ie 4 69,831,04 74 29 45,55145 150 2945 1167 - 15,50 NM 6,051,05525 459,525,11 70 2:9 45,50277 - 5Q14420 2940 _ 1'172 . 1F, - 50 • 15 -- 6:0 -- f;06 - 21 ---- 40 - , - 6c,if TO 6,a4tY 160 --- 25 • 11 • 1 1V ---- - 5,05 . 1,0 - 55, - 52 - 4 - 5 - 9 - ,505.,50 10 2.9 465 1 2922 — War -- --- --- 2P - -- 5 - ,07i3O3', • 60' -- '4we02:69 --- 10 -- 29 - 46.07 - 61TM601 - 4 . 4 -- 50061 - 2917 - 21 5,051,025,55 . 459,795,52 70 25,a_05 - 150171 - 4V, - 05652 2912 114 15,50 22 6, 01 ,02. . 4 60,‘m:67 - 70 29 44; aolir -- 10 14 49,10144 2907 1204 15,50 25 COWM -7 46C - 7 - 66 - .76 --- 7029 471, '',.27 2902 ,' 1209 .14 • 24 57,05i;0 459,755 - 70 29 15014 4A00 2 . IMI:11 15,50 _._ • . .„ „ .. .....::-.".t . -..Z oF 44 ,11, • . . .....-0 . ....,........ 7 _ 0 . is -._ .. * -t p.°e.c#2\_,;..t.--gla_... ........ ...... ........ . . . . . . e * I V 4 .4. f : 911d a* 0 „ a* - ,/,_);.)-- •-• — -• • • . _ . _ _ „-..-J _• -:-.• - . • Philip G. Dovb :101 . ..'i' 4 : 4 %'..M . :' i 1 V6. 4 No. 41104 ., Ase •••• $..: .; ; 4. C;--AegT41:-': 1 0 p .......• • v Ala 4 ., t,fortmcw. t .... -,,,N,.............""' ":„.k. . ... IT' : • a• - : • 1 . rltYriivn; pro b2oecd on 8P moon $co Level, 0 - . - 2. Coordinotec ore t_DoecO on Alceko Stoic Plonc Nod 27, Zone 4, 3. M conductors ore within Protrocted Section 11, Pioneer Nclurol Recpuccv JOE NAME: Ocosyvruk Drill rite Cgndwctipr4 PRAwN EY: in CHECKED BY: MJD . :OCATION; Protrocice. :section 11 SCALE: N/A Town 13 North R ()Int 7 Eciri DA ---- ATE 7-12-07 Urniot Meridion --- NAN SHEET ESCRIPTION: Ak- bwilt Ccorefinotcv 0:5204 3 of 4 ---- 0 • 1 . • . - Al2s Elsie PlEne . • Section Line Offset ............ W'e1r - N.. Y X -i=ct ti4e C E' - • -ligt . ... 25 6,031,128.32 469 ,943.64 70 29 46.01630 150 14 44.77930 3013 1055 13.50 26 . 6,031,123.35 469,938.69 70 29 45:96722 150 14 44.92442 3008 ,1060•• 13.50 27 6,031,118.33 469,933.76 70 29 45.91765 150 14 45.06695 • 300 • 1065 .13.50 . 28 6,031,113.39 469,928.66• 70 29 45.86667 150 14 45.21260 2997 . 1070 13.50 29. • 6,031, 108.44 469 70 29 45.81999 150 14 45.35655 - 2992 1075 13.50 30 6,031,103.45 469,919.01 70 29 45.77071 150 14 45.50137 2988 1079 13.50. 31 6,031,090.65 469,906.38 70 29 45.64431 150 14 45.57163 2975 1092. 13.50 Ell 6,031,0E5.68 469,901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 6,031,080.67 469,896.50 70 29 45.54576 150 14 46.16128• 2965 1102 13.50 NM 6,031,075.73 469,891.57 70 29 45.49698 15014 46.30581 2960. • 1106 13.50 • . ® 6,031,070.76 469,886.60* 70 29 45.44789 150 14 46.45152 2955 ® 13.50 36 6,031,065.83• 469,881.69 70 29 45.29921 150 14 46.59547 2950 1116 13.50 ' J , 3170,, • i 89, CCS.:: - -G-29-45. -- - -50--1A-45.9-674 • ' linTIMIIIIIMEll • 38 6,031;047.99 4 69,864.14 70 29 45.22304 150 14 47.10995 2932 1134• • 13.50 39 6,031,04.03 469,659.20 70 29 45.17406 150 14 47.25478 2927 • 1139 13.50 • P 40 6,031,055.10 489,854.21 70 29 45.12537 150 14 47.40108 2922 _ .•1144 . 13.50 • 41 6,031,055.05 469,649.29 70 29 45.07551 150 14 47.54530 2917 1149 13.50 . 42 6,031,028.13 469,644.38 70 29 45.02692 150 14 47.66925 2912 1154. 13.50 • 43 6,031,015.46 469,831.70 70 29 44.90180 150 14 48.06099 2699 1166 13.50 44 6,031,010.49 469,826.79 70 29 44.65272 150 14 48.20493. 2E94. 1171 • 13.50 • MEM 6,031,005.53 459,621.86 *70 29 44.80373 150 14 48.34946 2E89 ' 1176 13.50 ER 6,031,000.54 469,616.94 70 29 44.75446 150 14 48.49369 • 2884 • 1181 . 13.50 6,050,995.50 469,811.98 70 29 150 14 48.63910 2879 1186 13.50 48 6,030,990.58 469,807.07 70 29 44.65610 150 14 48.76304 '2874 • 1101. 13.50 _7:3. ~~ ~cF,A.4 SURVEYOR'S CERTIFICATE' • • '•+ h_.2 41 ! t __ I HEREBY CERTIFY THAT I AM . '21 __�_ 1 _i _ -- -• ,�" r F FcGFERLY R EGI�TE�EIS�.IJC� - r"•' - � - � � 4_,91)4,;,4 • 4 it LICENSED TO PRACTICE LAND •F 4` = • • " d SURVEYING IN 'THE STATE OF '"' . ° ALASKA AND THAT Ti-Ii5 PLAT r; r , ::� t / / REPRESENTS A SURVEY DONE BY "" �� ' '°•;� . ME OR UNDER MY SUFERVISION .. ���- .',` „�;, X%,•ti N`' 41104 •4J i AND THAT I BELIEVE THAT ALL ` * ill " . . <� DIMENSIONS AND OTHER DETAILS ,�- .< ; a. _. _ .. ,� � ° ARE CORRECT AS SUEMITTED TO =- • ME BY NANUO. INC. AS OF JULY. __ 12TH. 2007. Pioneer Noturol Resouces . JOB NAME: Oocouruk Drill Site Conductors DRAWN BY: BL 'CHECKED BY: N.I.D. OCATION: • Protrocied Section 11 SCALE: N/A . • Town_hip 13 North Ronne 7 Eost DATE: 7 -12 =07 Urniot Meridion • • NANUO JOB NO. SHEET • IESCRlPTION: As -built C oor din otes 05204 4 of 4 • • Page 1 of • • Maunder, Thomas E (DOA) From: Franks, James [James.Franks @pxd.com] Sent: Thursday, April 24, 2008 2:00 PM To: Davies, Stephen F (DOA); Maunder, Thomas E (DOA) Subject: RE: ODSN -40 (PTD 208 -39) Steve, Thanks again for the input and the help. james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2179 From: Davies, Stephen F (DOA) [mailto:steve.davies©alaska.gov] Sent: Thursday, April 24, 2008 1:36 PM To: Franks, James; Maunder, Thomas E (DOA) Subject: RE: ODSN -40 (PTD 208 -39) James, Likely not. If you remind us to move it along quickly, we will do so. Steve Davies AOGCC From: Franks, James [mailto:James.Franks @pxd.com] Sent: Thursday, April 24, 2008 1:20 PM To: Davies, Stephen F (DOA); Maunder, Thomas E (DOA) Subject: RE: ODSN -40 (PTD 208 -39) Steve, Tom, Thanks for confirming. Would we still have the 10 working days to get the permit back? I only ask because they are still working it up and by the time I could get it over to you for review, I will definitely be pressing that timeline. Thanks for your time. james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2179 From: Davies, Stephen F (DOA) [ mailto:steve.davies @alaska.gov] Sent: Thursday, April 24, 2008 11:40 AM To: Franks, James Cc: Maunder, Thomas E (DOA) 5/6/2008 Page 2 of • Subject: RE: ODSN -40 (PTD 208 -39) James, A significant change to the well trajectory such as this will ripple through the rest of the program, causing significant changes to the directional surveying, casing and cementing plans. So, it would be best to submit a replacement permit to drill application with all supporting documentation to the Commission. If approved, the Commission will re -issue the permit to drill. This re- issued permit will retain the permit and API numbers originally assigned to the well. Please let me know if you have any questions. Steve Davies AOGCC From: Maunder, Thomas E (DOA) Sent: Thursday, April 24, 2008 11:05 AM To: Franks, James Cc: Davies, Stephen F (DOA) Subject: RE: ODSN -40 (PTD 208 -39) James, I am not sure on the need for a new permit. You aren't changing the BHL. I will defer to my colleague Mr. Davies. Steve, what is your assessment? I think they can just provide the new directional path And any changes in casing. The actual changes can be "caught" with the 407. Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks @pxd.com] Sent: Thursday, April 24, 2008 10:57 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: ODSN -40 (PTD 208 -39) Tom, I wanted to let you know that our geosciences department has gone back to look at the seismic data a bit more and they would potentially like to move the heel location for the ODSN -40 well - 2600' down the planned lateral and leave the TD location the same. When we turned the permit in, there was not a fear of losses in crossing a fault in the well path, but with the losses seen on our current well, ODSK -33, when crossing an unmapped fault, the fear for losses has increased in the ODSN -40 well even though the wells are in different formations. In any case, in my looking at the regs, my assumption is that I would need to re- permit. Is this accurate? Thanks for your time. james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2179 Statement of Confidentiality: 5/6/2008 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 23, 2008 11:24 AM To: Franks, James Cc: Polya, Joe; Hazzard, Vance Subject: RE: ODSN -39i (PTD 208 -040) & ODSN -40 (PTD 208 -039) 1 believe you had indicated that to me previously. Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks @pxd.com] Sent: Wednesday, April 23, 2008 11:22 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: ODSN -39i (PTD 208 -040) & ODSN -40 (PTD 208 -039) Tom, Sorry for the barrage of e-mails to you this morning. When I sent the permit to drill requests over for the ODSN -39i and ODSN -40 wells, we had not received a favorable notification of our planned wells to drill during the summer months. As such, 1 indicated in my cover letters that we would be batch drilling through the intermediate casing strings. This was based on the thought that we might not get a favorable notification and that we would have to drill as many penetrations through the Oooguruk - Kuparuk formation to ensure we had some work to do over the summer months as well as the possibility of not receiving a diverter waiver. As we have now received a favorable ruling on the drilling schedule to allow drilling during the summer months, it would be more efficient for PNRA to drill the surface hole on the ODSN -39i well and then drill and complete the ODSN -40 well in its entirety. Following the completion of the ODSN -40 well, we would move back to ODSN -39i and drill that well to ultimate completion. Please let me know if you find this agreeable. Thanks! james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 -343 -2179 Statement of Confidentiality : . Thiglinessage may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. •• • • 5/6/2008 Page 1 of 2 i Maunder, Thomas E (DOA) From: Franks, James [James.Franks @pxd.com] Sent: Wednesday, April 23, 2008 11:18 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: RE: ODSN -40, PTD 208 -039 ODSN- 39i... James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2179 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, April 23, 2008 10:48 AM To: Franks, James Cc: Polya, Joe; Hazzard, Vance Subject: RE: ODSN -40, PTD 208 -039 James, I believe so. Which well will you go on first? Tom From: Franks, James [mailto:James.Franks @ pxd.com] Sent: Wednesday, April 23, 2008 10:39 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: ODSN -40, PTD 208 -039 Tom, On the approved 10-401 for the ODSN -40 well, PTD 208 -039, I notice that it does not have language indicating approval of our request for a diverter waiver. As the ODSN -39i well, PTD 208 -040, has a diverter waiver granted, was this just an omission on the ODSN -40 well? Thanks for your time. james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 - 343 -2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. Statement of Confidentiality: 5/6/2008 Page 1 of 1 1 110 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 23, 2008 11:24 AM To: Franks, James Cc: Polya, Joe; Hazzard, Vance Subject: RE: ODSN -39i (PTD 208 -040) & ODSN -40 (PTD 208 -039) I believe you had indicated that to me previously. Tom Maunder, PE AOGCC From: Franks, James [mailto:James.Franks @pxd.com] Sent: Wednesday, April 23, 2008 11:22 AM To: Maunder, Thomas E (DOA) Cc: Polya, Joe; Hazzard, Vance Subject: ODSN -39i (PTD 208 -040) & ODSN -40 (PTD 208 -039) Tom, Sorry for the barrage of e-mails to you this morning. When I sent the permit to drill requests over for the ODSN -39i and ODSN -40 wells, we had not received a favorable notification of our planned wells to drill during the summer months. As such, I indicated in my cover letters that we would be batch drilling through the intermediate casing strings. This was based on the thought that we might not get a favorable notification and that we would have to drill as many penetrations through the Oooguruk - Kuparuk formation to ensure we had some work to do over the summer months as well as the possibility of not receiving a diverter waiver. As we have now received a favorable ruling on the drilling schedule to allow drilling during the summer months, it would be more efficient for PNRA to drill the surface hole on the ODSN -391 well and then drill and complete the ODSN -40 well in its entirety. Following the completion of the ODSN -40 well, we would move back to ODSN -39i and drill that well to ultimate completion. Please let me know if you find this agreeable. Thanks! james James Franks Drilling Engineer Pioneer Natural Resources Alaska 907 -343 -2179 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e -mail and delete the message and any attachments. 5/6/2008 Page 1 of 1 Maunder, Thomas E (DOA) From: Greg Griffin [Greg.Griffin ©HALLIBURTON.com] Sent: Tuesday, April 15, 2008 5:03 PM To: Maunder, Thomas E (DOA) Subject: ODSN -40 PN12 TC plots Attachments: AC Plot ODSN -40 PN12 wp08 MGT.pdf; AC Plot ODSN -40 PN12 wp08 Intermediate.pdf; AC Plot ODSN -40 PN12 wp08 MGT to Surface Csng.pdf Tom, Here are the Traveling cylinder plots for ODSN -40. N),) ) 7 - 1 AK 005-i)1 1 I . I V f _ >l; iC•. This e-mail, including any attached files, may contain confidential and privileged information for the sole use of the intended recipient. Any review, use, distribution, or disclosure by others is strictly prohibited. If you are not the intended recipient (or authorized to receive information for the intended recipient), please contact the sender by reply e -mail and delete all copies of this message. 4/15/2008 1 SURVEY PROGRAM ( ANTI- COLLISION SETTINGS Date: 2008- 04 -08T00 :00:00 Validated: Yes Version: I FOR MGT USE I Interpolation Method: MD, interval: 25.0 Depth From Depth To Survey/Plan Tool ONLY Depth Range From: 0.0 To 1300.0 44.0 1300.0 ODSN -40 PN12 wp08 CR- GYRO -SS Results Limited By: Centre Distance: 1970.0 1300.0 19224.6 ODSN -40 PN12 wpO MWD+SAG +CA +IIFR +MS Reference: Plan: ODSN -40 PN12 wpO8 (ODSN- 40IODSN -40 PN12) Scan Type: NO GLOBAL FILTER: Using user defined selection 8, filtering criteria ODSN•12 PS1 OD$N 141 IS1 ODSN •111181 ` iODSK•35 Kup1 ODSN -91 IS4 ..I. ODSN -e P ODSN•321 IN ODIIIM 69 .7$11 - 0011114.$3 KupA ri' OQBK•101)112 - ' Ring _ __ . [0.569.15 PS1�1 OODSN 13 PSI � t8 From C olor To MD 12000 ODSN -43i IN13 l0000 11000 210 ,\ fK•4h -T T5 (10569 -161 .751(4 _ 44 250 ODSN -6 PS' � OD 0• � 4 16 �O � K•411 a OD$N•>IO 330. y . !t �I� /l Itl 30 30 .01/1 - 250 500 i l 1 1 f Ran O 7.4 'r LoDSN -1T PS14 - - , r ';,1: "',ii r 1000 _ 1aK . � e 1 l iI /v4;40., ., , KP �C1DSK 42 u 1 OD$0W2 20 D1spw�Ii 1 r • - OOSN•7!i 1N4 1000 1250 Range 0.12- •: 1 C d r / / k ;3 ,, �' �• 1)� 1250 1500 � %�' fit �, � 60 ODSDW1 -44 Disposal . 1 ))4),11 � ODSN -31 PN# 1500 1750 300 �� r � - 1 J� s9 � g .� � r �,„ t ; 1i 1 � ' • +� . „, ,,,,,„„ - - . - r ` 80 _ 1750 2000 : ib� III OD$K -18 Kupl� ,�i [008 1(.361 Kupl0 2000 2250 01 t r � "� K. --- - - - - - � ��\� � 2250 - 2500 #.10,..4!' ; z f t ` ` . . ODSK 41 KtIp . - ; lis { � 2500 2750 ` I . 4s VI,,, .� Vat . S At i .. e� " � % 27 3000 R t 0.. g ,aye 1 ��'' _ ' -, IOW t". " 1 4ll r. . 3000 3250 270 * f ; ` ®� 9 90 \11111 ir,orinf-,, S� !� 3250 - 3500 : 1 � C r � - y 1 9 I �F - 1; r `.�1����'��, 3500 3760 .. %' _ 0.i 11 , / J 270 90 3750 4000 a"". �'` I 4000 _-- 5000 10110.7/ / C, .,, 2,i 005N -38PNI 5000 6000 '� 's%' / ' 6000 7000 240 iiil 120 ... 4 ' ,� � ki\-: � � O W11•!$IiN1 7000 8000 i ,, , r -.1'.i iN1 y �� � r �� s 000 9000 4 ►i► 1 1 11 `�- •i s000 10000 ) ��� %� - /_ '�" 150 240 -f �' 120 3G • . a A J• f l' - 12 13000 180 "� riJf ■ . ; ' � 11000 O 13000 - Range 0 - 1000' ` ,:S� `4 i� � la000 a;�r�) '� 15000 15000 15000 16000 ravelling Cylinder Azimuth (TFO+AZI) Ibearing) vs Centre to Centre Separation 120 ftAn) • .a -- i � ' 16000 17000 41 210 L � 150 17000 18000 SECTION DEtv�s ODSN•48 p 1 '' 18000 19000 5.° MD Ins P8 TVD •1420 •EJ -W R.9 TF. 4 VS. Tap. .... _ 1 44.0 000 0.00 44.0 0.0 0.0 0.00 090 0.0 180 19000 20000 2 300.0 0.00 0.00 300.0 0.0 a0 0.00 000 0.0 3 800.0 5.00 150.00 7984 -18.9 10.9 1.00 150.00 -12.8 20000 21000 4 1050.0 10.00 150.00 1047.1 -41.1 27.2 2.00 Q00 -320 5 1693.2 20.29 150.00 1650.0 -2315 134.8 500 500 -158.7 21000 22000 6 1807.8 29.29 150.00 1750.0 -2621 162.9 0.00 000 491.7 7 34726 55.00 180.00 29980 1341.8 251.1 2.17 63.15 -391.2 22000 0 8 3482.6 5600 190.00 30045 1357.9 2402 0.00 0.00 080.1 9 5124.6 55.00 220.00 3957.1 2546.4 -306.0 1.50 9174 35.7 10 54500 60.00 220.00 4136.1 2781.7 -466.6 1.50 0.00 192.8 11 57724 65.86 230.47 4279.5 29670 4854 150 60.32 369.6 Travelling Cylinder Azimuth (TF)+AZI) bearing+ vs Centre to Centre Separation 150 ft /inl 12 6740.3 6588 230.47 5405 -6 460.5.1 2778.7 0.00 0.00 2260.0 13 10885.7 63.00 307.00 6160.8 4664.4 4854.4 150 90.90 41345 14 11185.7 8100 307.00 6197.5 4445.2 4092.2 Q00 000 4391.8 PN12 v6 T1 15 11001.2 89.22 305.23 8212.1 058.8 5055.8 3.00 -1587 4577.8 REFERENCE INFORMATION Well Planning - Pioneer - Oooguruk i1 1s 4 8 3 X1.1 X12 5668 am 43:72 5 PN12 v872 18 12314.3 9197 311.83 62145 38029 57928 300 575 53588 Co-ordinate (NIE) Reference: Well ODSN -40 - Slot ODS -40, True North Calculation Method: Minimum Curvature 20 12993.6 90.00 31 61695 3217.4 -6441.2 100 0.00 6006.2 20 13 80.00 31830 6162.5 3217.1 4446.2 3.00 130.50 80680 PN12 45 TJ Vertical (TVD) Reference: 44.0' + 13.5' 57.5ft (Nabors 19AC) 22 14208268 .5 67.11 31530 621 25612 - 70167. 0m ,80.00 6157.5 Section (VS) Reference: Slot- ODS- 40(0,0N, 0.0E) 9100 Error System: ISCWSA 22 ,4,0.55 310.30 62x5,05, 2582.2 70672 0.00 0.00 6757.5 Scan Method: Tray. Cylinder North 23 14185.3 80.00 316.29 6207.5 2493.7 71326 100 -002 68248 P1412 v5 74 Measured Depth Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Y 7.4 14391.4 55.49 316.25 6157.4 2351.9 726111 100 0.00 4979.5 Calculation Method: Minimum Curvature i Error Surface: Elliptical Conic 25 150014 9588 31629 6134.5 1912.1 7688.5 0.00 7444.0 P 26 151909 90.00 31429 6124.5 1770.3 7624.0 300 100 16010 75917 P1412 v5 75 ■ Warning Method: Rules Based 28 15 80.76 2.7626 6iu< 13 0.1 83302.2 am 1 0.0 0 81 29 16208.4 8000 316.29 6237.5 1046.9 8515.4 100 000 8357.5 P8112 v516 30 16269.3 91.83 316.30 6238.5 10029 8557.6 300 001 8404.0 31 77148.6 91.83 31030 6201.5 -367.6 9184.7 000 0.00 9074.8 NAD 27 ASP Zone 4 : WELL DETAILS: ODSN -40 32 17208.5 90.00 318.28 6207.5 - 323.5 82068 3.00 -17099 9121.4 0,112 v5 77 33 17580.3 7858 316.30 62453 - 50.1 9468.2 100 18000 94101 34 17839.3 76.56 316.30 6284.7 126.4 9836.9 0.00 0.00 9586.4 Ground Level: 13.5 35 18220.2 90.00 316.29 6332.5 3098 9898.2 100 0.00 980.2 P81225 T8 36 163072 95.33 316.29 6324.3 5250 - 10020.7 3.00 000 10020.5 +NI -S +E/ -W Northing Easting Latittude Longitude Slot 37 192246 95.33 31629 6247.5 11212 - 10589.7 000 000 10640.1 0832v579 0.0 0.0 6031038.10 469854.21 70° 29' 45.125 N 150°14' 47.401 W ODS-40 ■mma SURVEY PROGRAM ANTI- COLLISION SETTINGS Date: 2008 04 08T00:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.0 Depth From Depth To Survey/Plan Tool Depth Range From: 2200.0 To 19224.6 44.0 1300.0 ODSN - 40 PN12 wp08 CB GYRO - SS Results Limited By: Centre Distance: 2118.1 1300.0 19224.6 ODSN -40 PN wp08 MWD+SAG +CA +IIPR +MS Reference: Plan: ODSN -40 PN12 wp08 (ODSN- 40 /ODSN -40 PN12) Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference OD3N•391 INi 0 From Color To MD n�� 100 390 c riatirim ■ 9 0 44 250 0 • d � 250 500 ;30 � �'����� 500 _. 750 - .... 30 750 1000 -- 1000 1250 ♦ - __.._.._ �, / 3 •- 1250 1500 300 � \rai l ,,� 60 1500 1750 300 /� � ` ' 0 1750 2000 60 I i 200 0 - 2250 - 1 2250 - 2500 74phris 4 / - \ l 2500 2750 % tt 2750 - " " "' "'-" 3000 1 f 3000 3250 � ( : 1 1 � 3250 3500 270 � I 90 270 i Is 3600 3750 / go i ( i 3750 _ 4000 / / , 8008 5000 f f 0 Air 1 ‘ , f f 5000 soon ;, �, / 9000 7000 ,i 7000 " 8000 240 / // 120 8000 9000 2 8000 10000 240 ` 120 10000 -- -- -- 11000 11000 12000 210 150 / 12000 1300 13000 14000 180 V 14000 - 15000 r 15000 16000 Travelling Cylinder Azimuth (TFO+AZI) 'bearing' vs Centre to Centre Separation 120 ftlinl 210 150 16000 " 17000 17000 18000 SECTON DETAILS I 18000 19000 6.4 910 Inc w 710 00-6 +6nw 01,9 TP•o• 06.2 r& 180 19000 20000 30o.0 0.00 0.00 30000.0 0.0 0.0 0.00 0.00 ao 8000 5.00 1 799.4 -18.9 10.9 1,00 150.00 -12.8 20000 21000 7050.0 10 150.00 1047,1 -471 272 200 0.00 32.0 1893.2 2939 150.00 1650,0 -2315 131.8 300 0.00 -1567 21000 22000 18078 29.29 150.00 1750,0 -282.1 162.9 0.00 0.00 -191.7 3472.6 55.00 190.00 2995,0 - 1341.8 251.1 2.17 8315 -391.2 22000 0 3492.9 55.00 190.00 3006,5 -1357.8 248.2 0.00 0.00 -390.1 51246 55.00 220.00 3857,1 - 2549.4 -306.0 1.50 8674 357 Travelling Cylinder Azimuth (TFO+AZI) [bearings vs Centre to Centre Separation 150 f /ink 1 0 54550 8586 220.00 47 427 : -685A 0� o: 2 ;30.8 2 87463 65.86 230.47 505.6 4885.1 - 2778.7 0.00 0.00 2269.0 3 10885,7 83.00 30700 6160,9 - 4881.4 4654.4 350 90.96 41365 REFERENCE INFORMATION Well Planning ioneer -Oo uruk 4 11165. 8300 30700 6197,5 -4485,2 - 4892.2 0,00 0.00 4391,9 PN12.T1 0 - 5 11401,2 89.22 30523 6212.1 41506 -some 300 -1697 4577.8 6 119136 89.22 305.23 6219,5 4045,7 - 5500.8 0.00 000 5051.5 Co-ordinate (NIE) Reference: Well ODSN -40 - Slot ODS-40, True North Calculation Method: Minimum Curvature 7 1 29 6 1 '0 . 90.00 31 0 u;es - - 80 4 -67929 iw as 5 sere P6112 15 T2 Vertical (TVD) Reference: 44.0' + 13.6' @ 57.5ft (Nabors 19AC) E rror System: ISCWSA 0 13193.6 9197 ' 318. 30 016 3355. x.5 - 4 - °88.3 60 684 0. 00 131 5609.2 59 9 P1121573 Section (VS) Reference: Slot - ODS40(0.0N, 0.0E) Y Depth Reference: 44.0' + 13.5' @ 57.5ft (Nabors 19AC) Scan Method: Tray. Cylinder North 1 142005 87.16 31030 6204.8 3148.6 - 7057 3.00 180.00 6138.3 Measured De P ( ) Y 2 14100.5 87.16 31630 6205.1 - 2562.2 6506.7 0.00 0.00 6757.5 Calculation Method: Minimum Curvature Error Surface: Elliptical Conic 3 14195,3 90,00 316.29 6207.5 -2493.7 -7132,8 300 -0.02 6629.8 P1412 v514 4 14391,9 95.89 31629 61974 4351,9 - 72661 300 000 seas Warning Method: Rules Based 5 15003.4 95.89 31629 6131.6 - 1912.1 - 7688.5 0,00 0,00 7444.0 8 151999 80.00 31629 6124.5 - 1770.3 - 78248 3.00 180.00 7583.7 P1412 v5 T5 7 15509.9 80.70 31030 8149.6 - 1547.2 - 8037.3 100 18000 76293 8 15898.3 80.70 31630 6212.4 - 1270.1 - 8302.2 000 0.00 8121.9 9 18208.4 90.00 31629 6237.5 - 1048.9 -8515.4 100 000 8357.5 P1412 v5 T6 NAD 27 ASP Zone 4 : WELL DETAILS: ODSN -40 I 30 162653 91.83 31530 8236.5 - 1002.9 - 8557.6 3.00 401 6401.0 31 17141.6 91.83 316.30 6206.5 -367.6 - 9164.7 400 0.00 9074.6 32 17208.8 90.00 31629 6207.5 323.5 - 9206.8 100 -178.99 9121.4 %412 4 77 Ground Level: 13.5 33 17590.3 7656 316.30 6245.3 -90.1 - 9469.2 3.00 16.00 9410.1 34 178363 7658 31630 6294.7 1264 - 96309 0.00 000 9596.4 +WS +E/-W Northing Easting Latittude Longitude Slot 35 182202 90.00 316.29 6332.5 398.8 -98983 100 0.00 9685.2 P412.16 0.0 0.0 6031038.10 469854.21 70° 29' 45.125 N 150° 14' 47.401 W ODS-40 36 18397.7 95.33 316.29 6324,3 526.0 - 10020.7 300 0.00 10020,5 37 192203 9533 31529 62475 1123.2 - 10569.7 0,00 000 106451 P312 v5 78 SURVEY PROGRAM ANTI- COLLISION SETTINGS Date: 2008 -04- 08700:00:00 Validated: Yes Version: Interpolation Method: MD, interval: 25.0 Depth From Depth To Survey/Plan Toot Depth Range From: 1300.0 To 19224.6 44.0 1300.0 ODSN -40 PN12 wp08 CB-GYRO-SS Results Limited By: Centre Distance: 2118.1 1300.0 19224.6 ODSN -40 PN12 wp08 MWD+SAG+CA +11FR +MS Reference: Plan; ODSN -40 PN12 wp08 (ODSN- 40 /ODSN•40 PN121 Scan Type: NO GLOBAL FILTER: Using user defined selection & filtering criteria FOR USE FROM OD$N 3581 IN1 ODSN•37 PNb 1300' TO 3492' 0 ''''l,' ' i OD9N•34) I ODSN•3911N11 r 1381631 PN10 Range 1300' • 1600 Q 3 a.v4 p r 1 30 From Color To MD Range 1300' • 1100' ODIK•411KYp� ,0 ti* 3 / ` ' r$ 0, 330 3g 3 �,,J -.7 �b1,, 4014- 509 -_- 756 � . ' i �' it �, � 0001(.301 /Woo ,: • ; 4 a f ' , fi w�a ' / 1 1500 300 �; R� i � , fi 7 , .60 1750 -"'-° 1675 300 60 �'� Z ,� t �►' �/ g ' �+ ��``� jj � . � . i � " a 1650 2000 N. . 4� _ 4 5 i li - 3 1 , �{ I 7.000 ", use - #,--41,irt, ! - i 1 W 2: - 2500 �i IP� IP 1 '4'%-' G� � k � 'i, 2759 -- woo / /' 1 S � . ; 1 <_ . . . , , Z�J (,..... t t � j \ \ \ � 3000 .. .�.� 3250 ' j ! 84 ♦� N'' \ r .: 3280 3800 ! 1 , .. , -• ` _ __ 1 5 75 0 1675 270 90 r 3750 4000 Willi , 270 fil��ll�l 911 5006 6000 , 1 l +, 6009 7900 , � � / ; i M , �1��� � ' % 11 1 ' o 9000 � / 4/ p 9009 10000 Ic10601 IN1# � 4 40 A � �, ‘ ! i / i 1090 - ,1000 / 240 ' 120 • 4 . � ! J /// / 13000 94000 11)))))r t 041.* f / 11000 -- 15000 �� •✓ \ ' 15000 16000 MI 01104° 240 ������� /' 120 16900 - 16000 210 -- 150 ` 19000 -- 20000 180 20000 21000 ` 21000 -'-_ 22000 / '- - 22000 - 0 ` "j - -_' . - --- Travelling Cylinder Azimuth (TFO+AZ1) [bearing) vs Centre to Centre Separation 120 Win) =, 210 -1111 1 50 SEC110N DETAILS Sec MD Inc Am NO 04/4 ..E)-W Trip 3P.. VS. 7419.1 180 1 44.0 0.00 000 41.0 0.0 0.0 0.00 0.00 0.0 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 3 800.0 5.00 150.00 799.1 -199 10.9 1.00 150.00 -12.8 4 1050.0 10.00 150.00 1047.1 -41,1 27.2 2.00 0.00 -32.0 5 1693.2 29.29 150.00 1860.0 -2315 1368 3.00 0.00 -158.7 6 1807.8 29.29 150.00 1750.0 -282.1 182.9 0.00 0.00 -191.7 7 3472. 5500 190.00 2905,0 -1341.8 251.1 2.17 63.15 491.2 /� 8 3492.6 6 55.00 19000 30065 - 1357.9 2482 000 0.00 -390.1 T ravelling Cylinder Azimuth (TFO+AZI) Ibearingl vs Centre to Centre Separation 150 ft /inl 9 51246 5500 220.00 38571 - 2548.4 -306.0 1.59 96.74 35.7 10 5458.0 60.00 22000 4136.1 - 2781.7 486.6 1.50 0.90 1926 11 5772.4 65.86 230.47 4279.5 - 2957.9 -685.4 3.50 60.32 369.6 12 8746.3 65.86 230.47 5495.6 - 4685.1 - 2778.7 0.90 0.00 2268.0 13 10886.7 83.00 307.00 6160.9 4664.4 4654.4 3.50 90.69 4136.5 REFERENCE INFORMATION 14 00857 83,00 307.00 61975 - 4465.2 4892.2 0.00 0.69 4391.9 PN12 0671 Well Planning • Pioneer - Oooguruk 15 11401.2 8922 305.23 6212.1 43566 - 5065.8 100 - 16.97 4577.8 16 11413.8 89.22 305.23 6219.5 4045.7 - 5508.9 0.00 0.00 5051.5 Co-ordinate (N /E) Reference: Well ODSN -40 - Slot ODS -40, True North 17 12181.0 9000 31230 6221.1 4697.2 5693.8 3.00 8772 5251.0 9/4/20672 C alculation Method: Minimum Curvature 18 12314.3 93.97 311.83 62165 - 3807.9 - 5792.6 3.00 -6.75 5358.8 Vertical (ND) Reference: 44.0' + 13.b' 57. bit (Nabors 19AC) 19 12991.1 9397 311.63 6180.4 - 3355.4 -6296.3 000 0.00 59092 Section (VS) Reference: Slot- ODS-40(0.ON, 0.0E) Error System: ISCWSA 20 13193.8 90.00 316.30 6162.5 4217.1 4441.2 3.00 131.59 6068.0 P3112 05 73 21 132881 87,18 316.30 6164.9 4140.6 -65067 3.00 160.00 6138.3 Measured Depth Reference: 44.0' + 13.5' @ 57.6ft (Nabors 19AC) Scan Method: Tray. Cylinder North 22 14100.5 87.16 316.30 6205.1 -2562,2 -7067.2 0.00 0.00 6757.5 Calculation Method: Minimum Curvature Error Surface: Elliptical Conic 23 14195.3 90.00 316.29 6207.5 -24917 - 7132.8 3.00 -0.02 8829.8 76120574 P 24 14391.8 9589 316.26 61971 - 2351.9 - 7366.1 3.00 OW 9790 Warning Method: Rules Based 25 15903.4 9649 316.29 6134.6 -19121 -76895 000 0.00 7444.0 26 151999 9000 31929 6124.5 - 1779.3 -79 0 4.0 100 18090 7593.7 76112 45 75 27 15509.9 9.70 316.30 6149.6 - 1547.2 4037.3 100 180.00 7829.3 26 15695.3 6070 31930 6212.4 - 1270.1 4302.2 0.00 0.00 8121.9 29 182061 90.00 31929 6237.5 - 1046.9 45194 3.00 0.00 8357.5 76120576 NAD 27 ASP Zone 4 : WELL. DETAILS: ODSN -40 30 1629.3 91.91 31630 6236.5 - 1002.9 4557.6 3.00 0.01 8404.0 31 17100,8 91,83 316.30 6206.5 -361.6 4164.7 0.00 0.90 90788 32 1729.5 90.00 316.39 6207.5 -323.5 4206.6 3.00 -1799 9121.4 1 Ground Level. 13.5 33 17590.3 7986 31930 62453 -50,1 -94692 3.13 180.00 9410.1 34 17539.3 7658 31930 6294.7 1264 - 98369 0.00 0.00 96994 +N / -S +E/ -W Northing Easting Latittude Longitude Slot 35 1920.2 90.03 316.29 6332.5 39.8 - 98982 3.00 0.00 9886.2 76120576 0.0 0.0 6031038.10 469854.21 70° 29' 45.125 N 150° 14' 47.401 W ODS-40 36 16397.7 95.33 31829 6324.3 5269 - 100207 100 0.00 19020.5 3719224.6 95.33 318.29 6247.5 11212 - 105867 000 000 108451 7612 05 19 NIL RE: ODSN -39 Page 1 of 3 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, April 15, 2008 2:03 PM To: 'Greg Griffin' Cc: Franks, James Subject: RE: ODSN -40 Greg, I hate to bother you, but do you have the small plots for ODSN -40? Thanks, Tom Maunder, PE AOGCC From: Greg Griffin [ mailto :Greg.Griffin @HALLIBURTON.com] Sent: Monday, April 14, 2008 9:29 AM To: Maunder, Thomas E (DOA) Subject: RE: ODSN -39 Tom, I have included a Spider Plot of the Oooguruk Project and several Traveling Cylinder Plots. The Spider Plot and a couple of the Traveling Cylinder Plots are large Wall Plots. If you need something else let me know. :!', i 1, t �,r tt. ti:7i (AA: From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Saturday, April 12, 2008 3:55 PM To: Franks, James; Polya, Joe; Griffin, Greg Cc: Greg Griffin Subject: RE: ODSN - 39 James, Thanks for the response. Yes, I'd appreciate if the layout in the reservoir could be provided. A plan view would be fine. I understand that the other wells are still to be drilled. Tom Maunder, PE AOGCC Original Message From: Franks, James [mailto :James.Franks@pxd.com] Sent: Sat 4/12/2008 12 :55 PM To: Maunder, Thomas E (DOA); Polya, Joe; Griffin, Greg Cc: greg.griffm @halliburton.com Subject: RE: ODSN -39 4/15/2008 °"M5 "' "' HALLIBURTON .,- ; . �. Sperry Drilling Services IMO- :e m] 99.04 �, 544 191 i'17M.? 1125. -MN 44 49x1«6 ,x ]4o- P roject: Oooguruk Developement ..o- Site: Oooguruk Drill Site _ 15]]5 54 4eepx]Iye 0586 1x5 ea+ .so- `�' \ / 9x5 x 44 141111 7/ _9x5 aorwwer6en6 \ / ,, \ -449 „so- � � ; ^ -,.. ]w- 8%58x4 owe rxL6 tV I1 i /� � 1, 4 \ 454 . \ > � ti V 4054.141 jam. /fir \ nw 1x5- V V ` f� . 9 a e r. MI 5.05111 ,> t * f 99 91... p 105- / �*, 54 555 e , Ww.ifun055. .591 .e *Npe— .,\ t \�r OGSM4lHn 4544 I 4311- _ „x 45.8 ` 4454 w. x /5 eMM1M'YMre Me'M '•. ,taw1 OM • X x .] ` ,'/ ` \r r \ 11.006990.59., ,.w • y ti N ..4» 9.559.- '. \ 4\ \ \\ 1,* \0 6x1 Pet MlV -y55 \ l \ \ \ r \\ \ 0.r / \ \r \rl \\ \\ \tl485454pN nP4 \ •9ff \ \ \ �0.@.PJ99•.,r ,900 x s t \r 1 \ t,, .` 5054 r\ ` \ t CCMteMI40. 14454 .M- \\ \\ F -,0WM.n0MM \ 40614,5 5w01. +5454 .,.41- 00499611.9. ti5554 • 004E 6Mx5066 9.4005 • • 9.125119 5 002.11111515 995 1]H0. OWxd10555,M1 n W4 '. 0440.4 P6+i vn TM +454 - 14 00 4 5 41014x1400 ,140.1H.14001400x1x140014l 0.140514x1] 500154x4505 ,x501110011]x1.05051x.x54.054-5425 M4.,x.lW.l]x+ 155.5]x. 505- f1ae+. x.x55.Mf5.]x..Nx.]1x. . 042 . 4 x 5 409 9 1x5 4. .4. 4 354 Y 2 N 91 M 4555 9.50 2.x 2.x 2.x 150 1]r )w *9 545 140 545 454 lxx xn .1.55 0 lxW � 0e - 1110 r i'''' V [1\ n ,A ( .3- 2 _,,,i1\ -,,,,, u +�. s L _.I t -..1 i ! 1_--.A SARAH PALIN, GOVERNOR ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Joe Polya Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G. Street, Ste 600 Anchorage, AK 99501 Re: Oooguruk Field, Oooguruk- Nuiqsut Oil Pool, ODSN -40 Pioneer Natural Resources Alaska, Inc. Permit No: 208 -039 Surface Location: 2922' FSL, 1144' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 4038' FSL, 1173' FEL, SEC. 9, T13N, R7E, UM Dear Mr. Polya: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued, In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, , I , / P4 1 Cathy 4 . Foerster Commissioner DATED this f 7 day of April, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALAS OIL AND G STATE OF ALASKA AS CONSERVATION COMM13,J N � C I PERMIT TO DRILL C � �- MAR 1 1 2008 20 AAC 25.005 tL G [* 1a. Type of Work: 1b. Current Well Class: Exploratory ❑ Development Oil - 0 1c. Specify if well aif 1k Ctlb. Cv1111 1155iC: Drill 0 . Redrill ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Coalbed Methane ❑ Anotteragifrates ❑ Re -entry ❑ Multiple Zone 0 Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 1511 Single Well ❑ 11. Well Name and Number: Pioneer Natural Resources Alaska Inc Bond No. 103655283 • ODSN -40 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 700 G Street, Suite 600 Anchorage, AK 99501 MD: 18,906' ` TVD: 6,246' ' 4a. Location of Well (Governmental Section): 7. Property Designation: Oooguruk Unit Surface: 2922' FSL, 1144' FEL, Sec. 11, T13N, R7E, UM • ADL 355037 / ADL 355036 a ' 6/846% a ( 4� Top of Productive Horizon: 8. Land Use Permit: 13. approximate Spud Date: 3716' FSL, 760' FEL, Sec. 15, T13N, R7E, UM • 417497 4/14/2008 '7 � Total Depth: 9. Acres in Property: 14. Distance to Nearest 4038' FSL, 1173' FEL, Sec. 9, T13N, R7E, UM • 5760 + 5724 = 11,484 Property: 19,500' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation -- "4. ' I1S4-. 15. Distance to Nearest Well Surface: x- 469854.21 • y- 6031038.1 • Zone- ASP 4 (Height above GL): 42.66 feet Within Pool: N/A Ab ;.Z •, 16. Deviated wells: N/A Kickoff depth: Befjr 0 feet , ' , 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 95.89 degrees Downhole: 3129 psig • Surface: 2454 psig • 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 109# H -40 Welded 109' Surface Surface 153' 153' . Driven 12 -1/4" 9 -5/8" 40# L -80 BTC 3247' Surface Surface 3291' . 2995' • 393 sx Permafrost's'; 203 sx Class 'G' 8 -3/4" 7" 26# L -80 BTC -M 10823' Surface Surface 10867' . 6196' • 336 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch 0 Drilling Program El Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat El Diverter Sketch IN Seabed Report ❑ Drilling Fluid Program IN 20 AAC 25.050 requirements ❑ 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Joe Polya, 343 -2111 I Prepared By: Kathy Campoamor, 343 - 2183 Printed Name Joe Polya Title Sr. Staff Drilling Engineer Signature >-----_ Phone 343 -2111 Date 3/11/2008 Commission Use Only Permit to Drill , - API Number: Permit App oval See cover letter for other Number: �- 50- 703 - 2e.)5 ^ 5 / f 60 Date: q .10 . Q3 requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:Q Other: z�� Samples req'd: Yes❑ No� Mud log req'd: Yes❑ No� ✓v'�o y .--- 7 \'�� 5 r°�`' Y`�'n-`� e H measures: Yes❑ No 161" Directional svy req'd: Yes[✓] No❑ 11/6/F �i APPROVED BY THE COMMISSION DATE: , COMMISSIONER Form 10-401 Revised 12/2005 ORIGNAL ‘ 0 / it in Duplicate -u+6n • • '� �' M A R G as 1 1 00 :8 Alaska Oil & C ans. Co m mi ssion PIONEER =- Anchorage NATURAL RESOURCES ALASKA, INC March 10, 2008 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSN -40 Surface Location: 2922FSL, 1144FEL, Sec 11, T13N, R7E, UM X = 469854.21, Y = 6031038.10, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a production well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be a production well in the Oooguruk - Nuiqsut formation. PNRA requests the permit to drill based on Pool Rules turned in, but yet to be approved. As indicated in the attachments, the drilling program will entail drilling a directional 12 surface hole to approximately 3291' MD / 2995' TVDrkb, where surface casing will be set. An 8 -3/4" directional wellbore will be drilled into and set at the top of the Oooguruk - Nuiqsut interval at ' approximately 10867' MD / 6196' TVDrkb. The horizontal production interval will be drilled to 18906' MD / 6246 TVDrkb, the final TD of the well. The proposed casing program will utilize 9%" surface casing, 7" intermediate casing and an open hole completion of the 6 -1/8" hole section. The completion will utilize 2 7/8" tubing and an ESP. It is planned to drill and case this well through the intermediate casing, suspend the well and move to do the same thing on the well next to it, ODSN -39i. This is to mitigate the risk of wellbore collision and to allow PNRA to run Magnetic Ranging tools to further aid in reducing the wellbore placement uncertainty while drilling the surface hole of ODSN -39i. Once ODSN -39i is drilled and suspended, the plan would be to return to ODSN -40 to drill the productive interval and complete. Based on information previously submitted to the AOGCC and included in the AOGCC Oooguruk Field File, PNRA requests an exemption from 20 AAC 25.035 (c) which requires a diverter system be installed on the well while drilling the surface interval. 700 G STREET, STE 600 ANCHORAGE, ALASKA 99501 MAIN (907) 277 - 2700 ORIGINAL Alaska Oil & Gas Conse ion Commission, ._- March 10, 2008 Page2of3 PIONEER NATURAL RESOURCES ALASKA, INC. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10 -401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 3) A copy of the proposed drilling program per 20 AAC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 AAC 25.033 b. Complete logging and mud logging operations are planned and descriptions are attached. c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). e. A summary of the drilling operations. f. A summary of drilling hazards per 20 AAC 25.005 (c) (4). g. A wellbore schematic is also attached visually depicting the proposed well. 4) A copy of the Planned Directional Well Path. 5) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19 -AC as required by 20 AAC 25.035 (b) and (c). 6) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 AAC 25.065(1) will be functioning on the rig as standard operating procedure for all wells drilled by that rig. Products for treating H2s contamination in the drilling mud system will be maintained on the ODS. In the future, PNRA may provide information requesting the permitting of annular disposal of drilling wastes on this well. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 700 G STREET, STE 600 ANCHORAGE, ALASKA 99501 MAIN: (907) 277 -2700 Alaska Oil & Gas Conseil/Pion Commission • March 10, 2008 Page3of3 PIONEER NATURAL RESOURCES ALASKA, INC 1) Completion Report Joe Polya, Senior Drilling Engineer (20 AAC 25.070) 907/343 -2111 ioe.polyaepxd.com 2) Geologic Data and Logs Tavia Jackson, Senior Operations Geologist (20 AAC 25.071) 907/343 -2133 tavia. iackson(a�pxd.com Doug Waters, Operations Geologist 907/343 -2133 doug.waters @pxd.com The anticipated spud date for this well is April 14, 2008. If you have any questions or require further information, please contact Joe Polya at 907/343 -2111. Sincerely, Joe Polya Senior Drilling Engineer Attachments: Form 10 -401 Supporting permit information cc: ODSN -40 Well File 700 G STREET, STE. 600 • ANCHORAGE, ALASKA 99501 MAIN (907) 277 -2700 • Oooguruk Well Plan Summary: Permit to Drill ODSN -40 — Nuiqsut Production Well Surface Location: 2922' FSL, 1144' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X = 469854.21 Y = 6031038.1 Target: 3715.94' FSL, 760.27' FEL, Sec 15, T13N, R7E, UM • X = 464944.33 Y = 6026573.23 1 6,196' TVDrkb Bottom Hole Location: 4038.3' FSL, 1172.8' FEL, Sec 9, T13N, R7E, UM X = 459270.27 Y = 6032204.15 1 6,246' TVDrkb AFE Number: TBD Est. Start Date: April 14, 2008 • Rig: Nabors 19AC Operating days: 17.2 days Drill Intermediate, Case and Suspend 16 days Drill Production and Complete TD: 18,906 MD / 6,246 TVDrkb Objective: Nuiqsut 1 Well Type (exp, dev, etc): Development Well Design (conventional, slimhole, etc): Ultra -slim hole — Producer • Current Mechanical Condition: Well Bay Footing / ODS Ground Level: Elevation above MSL: 13.5' - RKB to Ground Level: 44' Rig Elevation: RKB + MSL = 56.16' Conductor: 153' MDrkb Well Control: Based on calculations below, BOP equipment will be tested to 3,500 psi. Surface Section: • Maximum anticipated BHP: 1314 psi @ 2939' TVDss (Based on seawater gradient of 0.4472 psi /ft) • Maximum surface pressure: 991 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Intermediate Section: • Maximum anticipated BHP: 3129 psi @ 6140' TVDss • Maximum surface pressure: 2454 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Production Hole Section: • Maximum anticipated BHP: 3129 psi © 6140' TVDss • • Maximum surface pressure: 2454 psi @ surface • (Based on BHP and a full column of gas from TD @ 0.11 psi /ft) Planned BOP test pressure: 3500 psi (annular to 2500 psi) Planned completion fluid: 10.2 ppg Brine /6.8 ppg Diesel Pioneer Natural Resources Last Revised: March 5, 2008 ODSN -40 Permit To Drill Page 1 of 9 • • Diverter (see attached schematic): Hydril 21 -1/4" 2M annular BOP 1 16" full opening knife gate valve, hydraulically actuated 16" diverter line 5000 psi BOP stack (see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11" 5M single ram BOP w/ studded connections Hydril 11" 5M single ram BOP w/ studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3 -1/8" 5M side outlets w /flanged connections 2 ea. 3 -1/8" 5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3 -1/8" 5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/ studded connections Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 9 -5/8" Surface Shoe Rathole + 20' to 50' from 9 -5/8" shoe LOT 12.0 ppg 7" Intermediate Shoe Rathole + 20' to 50' from 7" shoe FIT 13.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 12 -1/4" hole Spud Mud Interval Density (ppg) Viscosity (secs) YP PV 10 sec gel API FL Initial 8.8 150 -200 35 - 50 15 -25 10 — 15 unrestricted Final 9.2 -9.6 70 -100 25 — 35 15 — 25 10 —15 <12 Intermediate Hole Mud Properties: 8 -3/4" hole LSND Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial 8.8 -9.3 40 - 60 15 - 25 15 — 20 < 12 6 - 8 HRZ to TD 11.0 40 — 60 15 - 25 20 - 30 < 15 3 — 5 (8 -10 HTHP) Production Hole Mud Pro erties: 6 -1/8" hole Baradril -N Interval Density (ppg) Viscosity (secs) YP PV MBT API FL Initial 10.4 - 40 - 60 15 - 25 15 — 20 0 <4 Disposal: Annular Injection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 / Class 2 disposal well, ODSDW1 -44. Pioneer Natural Resources Last Revised: March 5, 2008 ODSN -40 Permit To Drill Page 2 of 9 • • Hydraulics: Surface Hole: 12 -1/4" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Surf to BPRF 550 4" 15.7# 90 1800 10.0 N/A 18,18,18,16 .942 BPRF to TD 650 4" 15.7# 110 2400 10.2 N/A 18,18,18,16 .942 Intermediate Hole: 8 - /a" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Surf Shoe to TD 550 4" 15.7# 215 3500 11.0 N/A 5x16 0.982 Production Hole: 6 -1/8" Interval Pump Drill Pipe AV Pump ECD ppg- Motor Jet Nozzles TFA (in GPM (fpm) PSI emw ( "/32) Int Shoe to TD 275 4" 15.7# 275 2800 11.57 N/A 3x14 0.451 Formation Markers: TVD Pore Press. EMW Formation Tops MD (rkb) (psi) (ppg) Comments Base Permafrost 1643 1606 - Top West Sak 2469 2326 1027 8.7 Base of fluvial sands Hue Shale 3019 2786 Tuffaceous Shales 3044 2806 Top Torok Sand 7442 4981 2228 8.7 Top of Disposal Zone Base Torok Sand 7949 5206 Base of Disposal Zone Top HRZ 9133 5726 Base HRZ 9446 5851 Top Kuparuk C 9892 6004 3031 9.8 Base Kuparuk C 9915 6011 Top Nuiqsut 10867. 6196 • 3129 9.8 Base Nuiqsut _ Not penetrated • Pioneer Natural Resources Last Revised: March 5, 2008 ODSN -40 Permit To Drill Page 3 of 9 • Logging Program: 12 -1/4" Section: Drilling: Mud logging - Dir / GR Open Hole: N/A Cased Hole: N/A 8 -3/4" Section: Drilling: Mud logging Dir /GR /Res /Dens /Neut f Open Hole: N/A Cased Hole: N/A 6 -1/8" Section: Drilling: Mud logging Dir / GR / Res / Dens (Azm) / Neut Open Hole: N/A Cased Hole: N/A Casing Program: Hole Casing / Weight Grade Conn. Casing CsglTbg Top Hole Btm Size Tubing Length MDrkb/TVDrkb MDrkb/TVDrkb 24" 16" 109# H -40 Welded 109' Surface 153' / 153' 12 -1/4" 9 -5/8" 40# L -80 BTC 3247' Surface 3291' / 2995' • 8 -3/4' 7" 26# L -80 BTC -M 10823' Surface 10867' / 6196' - Tubing 2 -7/8" 6.5# L -80 IBT -M 10823' Surface 10867' / 6196' Casing Properties Size Weight Grade ID Drift ID Conn. Internal Collapse Tensile Yield (psi) Strength (psi) Joint 1 Body 16" 109# H -40 14.67" 14.5" Welded Conductor casing 9 -5/8" 40# L -80 8.835" 8.679" BTC 5750 3090 916 M 916 M 7" 26# L -80 6.276" 6.151" BTC -M 7240 5410 604 M 604 M Pioneer Natural Resources Last Revised: March 5, 2008 ODSN -40 Permit To Drill Page 4 of 9 • • Cement Calculations: Casing Size: 1 9 -5/8" Surface Casing - single stage Basis: Lead: 75% excess over gauge hole in permafrost + 50 bbls, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 500' of open hole with 30% excess, plus 85' shoe track Tail TOC: 2791' MD (500' MD above shoe) Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 10.0 ppg Dual Spacer Lead 291 bbls / 393 sx of 10.9 ppg Type "L" Permafrost Cement. 4.15 cf /sk, 20.0 gps water req. Tail 43 bbls / 203 sx of 15.9 ppg Premium "G" + adds. 1.18 cf /sk, 5.23 gps water req. Displ 231 bbls Mud Temp BHST -55° F, BHCT -60° F estimated During drilling operations, should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar may be run in the casing string and a staged cement job will be performed, if needed. In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casing Size: 1 7" Intermediate Casing - single stage Basis: Tail: 1934' of open hole with 30% excess, plus 85' shoe track Tail TOC: -8933' MD (1934' above the shoe) - 200' above the top of the HRZ Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 11.5 ppg Dual Spacer Tail 71 bbls / 336 sx of 15.8 ppg Premium "G" + adds. 1.18 cf /sk, 5.18 gps water req. Displ 411 bbls seawater Temp BHST - 165° F at 6100' TVDrkb, -135° F BHCT This well is outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone Pioneer Natural Resources Last Revised: March 5, 2008 ODSN -40 Permit To Drill Page 5 of 9 1 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre -Riq Work 1. 16" Conductors have been set and the Well Bay modules have been placed. 2. The Oooguruk Drill Site Class 1 / Class 2 Disposal Well, ODSDW1 -44, has been drilled and commissioned for disposal. Riq Activity: Drill Surface Hole through Case Intermediate Hole and Suspend 1. MIRU Nabors 19AC over pre - installed 16" conductor casing. 2. Nipple up and function test the 21 -1/4" diverter system prior to spud. (Notify the AOGCC Field Inspectors 48 hours prior to diverter function test). 3. MU 12 -1/4" Directional Drilling, MWD /LWDassembly. Drill surface hole to the casing point at -3291' MD / 2995' TVDrkb, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 9 -5/8 ", 40# surface casing - a Port Collar may be run based on hole conditions at Company Rep discretion. 5. Ensure floats are holding. WOC if needed. 6. ND Diverter, NU BOPE and test. Test BOPE to 250/3500 psi 7. MU 8 -3/4" directional drilling, MWD /LWD RIH and cleanout the casing to landing collar. Displace the well over to intermediate hole drilling fluid. 8. Test the 9 -5/8" casing to 3,500 psi for 30 min. 9. Drill out shoe tract, cement, rat hole and 20' of new formation below 9 -5/8" shoe. Pull the bit back into the 9 -5/8" casing and perform LOT. 10. Drill 8 -3/4" intermediate hole to casing point at - 10867' MD/ 6196' TVDrkb: Circulate and condition the drilling fluid to run casing. 11. Run and cement the 7 ", 26# intermediate casing. Displace the cement with seawater. Ensure floats are holding. 12. RIH with enough 2 -7/8" tubing to allow for the circulation of diesel freeze protection fluid to -2000' TVDrkb. 13. Land the tubing and RILDS. Install TWC. 14. NU Tree and test. 15. Pull TWC. Test the 7" casing to 3,500 psi for 30 minutes. 16. Circulate diesel freeze protection fluid to freeze protect the well to -2000' TVDrkb. Also, freeze protect the 7" x 9 -5/8" annulus with diesel to -2000' TVDrkb. 17. Temporarily suspend the well.' RDMO to slot 39 to drill the surface and intermediate hole for that ✓ well. Note: By temporarily suspending the well at this point we can minimize the risk of collision by allowing MGT tools to be run in the upper part of the hole while drilling the next well Riq Activity: Drill and Complete Remaining Well 1. MIRU to ODSN -40. RU circulation lines and circulate out the diesel freeze protection fluid and ensure the well is dead. 2. Install TWC. ND Tree and NU BOPE. Test BOPE to 250/3500 psi. 3. Pull circulation tubing string from the well. 4. MU 6 -1/8" directional drilling, MWD /LWD assembly. RIH and cleanout to landing collar. 5. Re- verify the pressure test the 7" casing to 3,500 psi. Pioneer Natural Resources Last Revised: March 5, 2008 ODSN -40 Permit To Drill Page 6 of 9 6. Displace the well over to production hole drilling fluid. 7. Drill out shoe tract, cement, rat hole and 20' of new formation below 7" shoe. Pull the bit back into the 7" casing and perform an FIT. 8. Drill the 6 -1/8" production hole to TD at -18906' MD/ 6246' TVDrkb. POH. 9. MU 6 -1/8" Cleanout BHA and cleanout to the 7" casing shoe. 10. Displace the well over to 10.2 ppg Brine. POH. 11. MU completion with ESP and RIH. 12. Land the tubing and RILDS. Install TWC. 13. ND BOPE, NU tree and test to 5,000 psi. 14. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to -2000' TVD and allow to u -tube. 15. Drop ball and rod and allow to seat. Pressure test the tubing to 3,500 psi - chart and hold for 30 minutes. Bleed off pressure and then pressure test the annulus to 3,500 psi - chart and hold for 30 minutes. Bleed off pressure. 16. RU Slickline and pull the ball and rod. Pull the RHC -m plug. 17. RD Slickline. RDMO to next well. Pioneer Natural Resources Last Revised: March 5, 2008 ODSN -40 Permit To Drill Page 7 of 9 • Casing Shoe Leak Off Test Procedure: 1. After testing BOPE, pick up the drilling assembly and RIH to the float collar. Circulate to consistent mud weight and rheology. 2. Shut in with the pipe rams and test the casing to the required test pressure. Record the volume of mud required and the corresponding pressures in 1 /4 bbl increments. When the design pressure is reached shut in the well and record the shut in pressure for 30 minutes. 3. Bleed off pressure while taking returns to a calibrated tank and record volume recovered. 4. Drill out the shoe track. Drill 20 ft of new hole and circulate the hole clean with consistent mud weight in /out. Pull up into the casing shoe. 5. Perform a Leak Off Test: • Calculate the required test pressure to reach leak off with the actual mud weight and the estimated fracture EMW. • Plot the casing test data and the calculated leak off on appropriate scale coordinate paper. As a guide, use the data from the casing test to determine the approximate volume of mud required to reach the calculated LOT. • Shut the well in. R/U the test pump. • Bring the pump on line at 0.25 — 0.50 bpm. Maintain a constant rate. • Record the pressure for every 1 /4 of a bbl pumped. • Continue pumping until the pressure vs. volume curve breaks over indicating leak off. • Discontinue pumping and shut in the well. Record the shut in pressure in 1 minute increments for 10 minutes or until pressure shows stabilization. • Bleed off the pressure and record the volume of mud recovered. • Plot the data to determine the Leak Off Test pressure at the shoe as EMW. • Submit the test results to the Pioneer drilling engineer for distribution as required. Pioneer Natural Resources Last Revised: March 5, 2008 ODSN -40 Permit To Drill Page 8 of 9 • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • A ConocoPhillips well drilled to the south of the Oooguruk development showed communication with the main body of the Kuparuk field. In that well, they took an -2 ppg kick t, over planned mud weight - to -12.5 ppg. Prior to drilling into the Kuparuk, hold a pre - reservoir meeting to outlined heightened awareness and kick detection o Following the Kuparuk penetration, pick up off bottom, shut off the pumps and perform a flow check to verify there isn't any overpressure. o During the drilling of ODSDW01 -44 and ODSK -33, no increase in pressure was seen. o During the drilling of ODSK -33, no increase in pressure was seen. o This is a new fault block r/ Lost Circulation /Breathing /Formation Stability • The Torok Shales just above the HRZ showed that they are problematic on the ODSK -33 well - causing "temporarily restricted" pipe. These shales are bentonitic (clay) and /or vitrious (volcanic) in nature and may have some coal stringers. Any loss of flow across this interval could allow the drilled solids to expand or dislodge and grab onto the BHA. While drilling this interval, o take small bites and circulate them up and away from the BHA prior to taking another bite. • Lost circulation is not expected, but if encountered, consult the Lost Circulation Decision Tree in the Halliburton Mud Program. • Breathing may be seen while drilling the Hue and Torok shales. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. • A formation study was conducted by GMI which indicated mud weights >12.5 ppg to maintain hole stability across the HRZ above the Kuparuk. Should shale instability be observed, pay close attention to the cuttings returned to surface and attempt to make small changes to mud weight to regain stability. o Splintered shales - indicates the mud weight may be too low o Tabular shales - indicates the mud weight may be too high Kick Tolerance /Integrity Testing Kick Tolerance / Integrity Testing Summary Table Casing set / Interval Maximum Influx Mud Exp Pore Min LOT / FIT Volume Weight Press 9 -5/8" Surface / 8 -3/4" hole 45.6 bbls 10.2 3129 12.0 ppg (LOT) 7" Intermediate / 6 -1/8" hole Infinite 10.2 3129 13.5 ppg (FIT) NOTE: All LOT / FIT will be taken with a minimum of 20 -ft and a maximum of 50 -ft of new hole drilled outside of the previous casing string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H site, however Standard Operating Procedures for H precautions should be followed at all times. Faults • One seismically visible fault is expected to be crossed and sub seismic faults•with throws may also be encountered. Losses may be associated with these faults. I Fault Location MD TVDss Throw Direction Uncertainty Lateral section 12600 6173 20' East 150' CONSULT THE ODS DATA SHEET AND WELL PLAN FOR ADDITIONAL INFORMATION Pioneer Natural Resources Last Revised: March 5, 2008 ODSN -40 Permit To Drill Page 9 of 9 ODSN -40 Producth Well Proposed Sussion Completion Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 2 -7/8 ", 5K, Horizontal �j 16" Conductor 153' MDrkb / 153' TVDrkb 2 -7/8 ", 6 5# L -80 IBT -M @2300' MD lf� 9 -5/8 ", 40# L -80 BTC, 8.835" ID 3291' MDrkb / 2995' TVDrkb • Estimated Top of Cement @ 8933' MD / —5640' TVDrkb 7 ", 26# L -80 BTC -M, 6.276" ID 10867' MDrkb / 6196' TVDrkb ... Date: Revision By: Comments 3/6/2008 JDF Proposed Completion ODSN -40 Producer =ti Suspension Well Schematic PIONEER NATURAL RESOURCES ODSN -40 Piluction Well Proposecompletion Well Head: 9 -5/8 ", 5K, VetcoGray Tree: 2 -7/8 ", 5K, Horizontal Vent Valves Control Line 16" Conductor 153' MDrkb / 153' TVDrkb Ase 2 -7/8" ScSSSV, 2.313" ID @ -750' 2 -7/8" GLM @ 4700' MDrkb / 3764' TVDrkb 9 -5/8 ", 40# L -80 BTC, 8.835" ID 3291' MDrkb / 2995' TVDrkb X Nipple, 2.313" ID @ 4750' MD ~ 7" x 2 -7/8" Packer @ -4800' MDrkb / -3750' TVDrkb X Nipple, 2.313" ID w RHC -M Profile @ 4850' MD 2 -7/8" GLM @ 10450' MDrkb / 6139' TVDrkb 2 -7/8 ", 6.5# L -80 IBT-M Estimated Top of Cement @ 8933' ESP Cable MD / -5640' TVDrkb O O 0'4 2 -7/8" Durasleeve Sliding Sleeve, 2.313" ID @ 10500' MDrkb ■ XN Nipple, 2.205" ID Nogo @ 10550' MDrkb 81 degrees ESP @ 10600' MDrkb 10867' MDrkb / 6196' TVDrkb 6 -1/8" Open Hole 7 ", 26# L -80 BTC -M, 6.276" ID 18906' MDrkb / 6246' TVDrkb Date: Revision By: Comments 3/6/2008 JDF Proposed Completion ,l rfc. ODSN -40 Producer Well Schematic PIONEER. NATURAL RESOURCES • • I .. : Well Planning - Pioneer - Oooguruk Oooguruk Developement Oooguruk Drill Site ODSN-40 - Slot ODS-40 . 4 ODSN-40 PN12 1 1 i Plan: ODSN-40 PN12 wp06 4 1 ,‘ , i 'it '. Standard Proposal Report ' * 06 March, 2008 4 : 1 a 1 • HALLIBURTON Sperry Drilling Services WELL DETAILS: ODSN -40 REFERENCE INFORMATION H A L L I B U R TO N Ground Level: 13.5 Co-ordinate (N/E) Reference: Well ODSN -40 - Slot ODS -40, True North Lon Vertical (TVD) Reference: 42.5 * 13.5' @ 56.0ft - . + N / - S + P / - W Northin 8 Eason 8 IatitWde 8t lode Slot Measured Depth Reference: 42 5' + 13.5' @ 56.0ft Sperry Drilling Services 0.0 0.0 6031038.10 469854.21 70° 29' 45.125 N 150° 14' 47.401 W ODS-40 Calculation Method: Minimum Curvature PIONEER SURVEY PROGRAM WELLBORE TARGET DETAILS (MAP CO- ORDINATES) Date: 2008 -02- 20100:00:00 Validated: Yes Version: Name TVD +N / -S +E / -W Northing Easting Shape Depth From Depth To Survey/Plan Tool Project: Oooguruk Developement PN12 v5 T5 6123.0 - 1770.3 - 7824.0 6029299.70 462023.85 Point 600.0 ODSN-40 PN12 wp06 CB- GYRO -SS PN12 v5 T3 6161.0 - 3217.1 - 6441.2 6027847.47 463400.64 Point 16000 18906.4 ODSN -40 PN12 wp06 MWD +SAG +CA +IiFR +MS Site: Oooguruk Drill Site PN12 v6 T1 6196.0 - 4485.2 - 4892.2 6026573.23 464944.33 Point Well: ODSN -40 PN12v5T4 6206.0 - 2493.7 - 7132.6 6028573.59 462712.25 Point PN12 v5 T7 6206.0 -323.5 - 9206.8 6030751.93 460647.06 Point ilc CASING DETAILS COMPANY DETAILS: WellPlanning - Pioneer - Ooogun Wellbore: ODSN -40 PN12 PN12 v6 T2 6219.6 - 3897.2 - 5693.8 6027164.39 464145.19 Point Plan: ODSN -40 PN12 wp06 PN12 v5 T6 6236.0 - 1046.9 - 8515.4 6030025.82 461335.45 Point TVD MD Name Size Calculation Method: Minimum Curvature PN12 v5 T9 6246.0 1123.2 - 10589.7 6032204.15 459270.27 Point 2995.0 3291.0 9 5/8" 9.625 Error System: ISCWSA PN12 v5 T8 6331.0 399.8 - 9898.2 6031478.04 459958.67 Point 6196.0 10866.8 7" 7.000 Scan Method: Tray. Cylinder North Error Surface: Elliptical Conic - 1200 - Warning Method: Rules Based - - DDI = 7.10 FORMATION TOP DETAILS -600- Start Dir 1.00/100' 300.00' MD, 300.00' TVD TVDPathTVDssPath MDPath Formation SECTION DETAILS III _ 1606.0 1550.0 1643.1 Base of Permafrost Sec MD Inc Azi TVD +N / -S +E / -W DLeg TFace VSec Target 2326.0 2270.0 2469.0 Top West Sak 1 42.5 0.00 0.00 42.5 0.0 0.0 0.00 0.00 0.0 2786.0 2730.0 3019.1 Hue Shale 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 0 - Start Dir 2.00/100' 800.00' MD, 799.40' TVD 2806.0 2750.0 3044.3 Tuffaceous Shales 3 800.0 5.00 150.00 799.4 - 18.9 10.9 1.00 150.00 - 12.8 - 4981.0 4925.0 7442.2 To Torok Sand 4 1050.0 10.00 150.00 1047.1 -47.1 27.2 2.00 0.00 -32.0 P 5 1693.2 29.29 150.00 1650.0 -233.5 134.8 3.00 0.00 -158.7 5206.0 5150.0 7949.1 Base Torok Sand 6 2209.1 29.29 150.00 2100.0 -452.2 261.1 0.00 0.00 -307.3 600 Start Dir 3.00/100' 1050.00' MD, 1047.10' TVD 5726.0 5670.0 9133.0 Top HRZ 7 4197.7 63.65 224.37 3541.0 - 1617.6 - 157.2 3.00 90.44 - 14.3 - - 5851.0 5795.0 9446.4 Base HRZ 8 8551.2 63.65 224.37 5473.2 - 4406.3 - 2885.4 0.00 0.00 2404.5 - - - 5944.0 5888.0 9705.3 Kalubik Marker 9 10666.8 83.00 300.00 6171.6 - 4584.5 - 4720.3 3.50 89.99 4210.4 _ - - 6004.0 5948.0 9892.4 Top Kuparuk C 10 10866.8 83.00 300.00 6196.0 - 4485.2 - 4892.2 0.00 0.00 4391.9 PN12 v6 T1 1200 End Dir 1693.20' MD, 1650.00' TVD 6011.0 5955.0 9915.7 Base Kuparuk (LCU) 11 11185.2 89.68 306.85 6216.3 - 4310.3 - 5157.1 3.00 45.94 4673.7 12 11680.7 89.68 306.85 6219.1 - 4013.2 - 5553.6 0.00 0.00 5099.3 Base of Permafrost 15° - - - 6196.0 6140.0 10866.8 Top Nuiqsut 13 11862.7 90.00 312.30 6219.6 - 3897.2 - 5693.8 3.00 86.62 5251.0 PN12 v6 T2 - - 14 11996.1 93.97 311.83 6215.0 - 3807.9 - 5792.8 3.00 -6.75 5358.8 ' 15 12676.2 93.97 311.83 6167.9 - 3355.4 - 6298.3 0.00 0.00 5909.2 - 1800 Start Dir 3.0/100' 2209.14' MD, 2100.00' TVD 16 12875.3 90.00 316.30 6161.0 - 3217.1 - 6441.2 3.00 131.59 6066.0 PN12 v5 T3 - - - - - - - 17 12970.1 87.16 316.30 6163.4 - 3148.6 - 6506.7 3.00 180.00 6138.3 Top West Sak - 18 13782.3 87.16 316.30 6203.6 - 2562.2 - 7067.2 0.00 0.00 6757.5 o End Dir 11996.10' MD, 6215.03' TVD 19 13877.1 90.00 316.29 6206.0 - 2493.7 - 7132.6 3.00 -0.02 6829.8 PN12 v5 T4 '0 2400 30° End Dir 4197.66' MD, 3540.98' TVD \ 20 14073.5 95.89 316.29 6195.9 - 2351.9 - 7268.1 3.00 0.00 6979.5 Start Dir 3.00/100' 12676.21' MD, 6167.90' TVD 21 14685.2 95.89 316.29 6133.1 - 1912.1 - 7688.5 0.00 0.00 7444.0 r - Hue Shale 22 14881.7 90.00 316.29 6123.0 - 1770.3 - 7824.0 3.00 180.00 7593.7 PN12 v5 T5 Q. - - 9 5/8" \ , 23 15191.7 80.70 316.30 6148.1 - 1547.2 - 8037.3 3.00 180.00 7829.3 - i p \ \ 24 15580.1 80.70 316.30 6210.9 - 1270.1 - 8302.2 0.00 0.00 8121.9 3000- p5 Start Dir 3.50/100' 8551.15' MD, 5473.19' TVD End Dir 12970.13' MD, 6163.35' TVD 25 15890.2 90.00 316.29 6236.0 - 1046.9 - 8515.4 3.00 0.00 8357.5 PN12 v5 T6 8' 1 \ 1 \ 26 15951.1 91.83 316.30 6235.0 - 1002.9 - 8557.6 3.00 0.01 8404.0 c.1 / 6 0, ' ■ 5 \ 5 27 16830.3 91.83 316.30 6207.0 -367.6 - 9164.7 0.00 0.00 9074.8 N - End Dir 10666.79' MD, 6171.63' TVD Start Dir 3.00/100' 13782.27' MD, 6203.65' TVD 28 16891.3 90.00 316.29 6206.0 - 323.5 - 9206.8 3.00 - 179.99 9121.4 PN12 v5 T7 ` ` ` ` 30 17521.1 78.58 316.30 6293.2 126.4 - 9636.9 0.00 0.00 9596.4 Start Dir 3.00/100' 10866.790' MD, 6196.00' TVD t s /V \ \ 5 . 31 17901.9 90.00 316.29 6331.0 399.8 - 9898.2 3.00 0.00 9885.2 PN12 v5 T8 \ End Dir 14073.53' MD, 6195.90' TVD 32 18079.4 95.33 316.29 6322.8 528.0 - 10020.7 3.00 0.00 10020.5 - - 33 18906.4 95.33 316.29 6246.0 1123.2 - 10589.7 0.00 0.00 10649.1 PN12 v5 T9 4 200- gy p, End Dir 11185 MD, 6216.35' TVD ` ` ` 5 Top Torok Sand , \ Start Dir 3.00/100' 14685.21' MD, 6133.10' TVD Start Dir 3.00/100' 16830.34' MD, 6206.97' TVD 4800- Base Torok Sand . End Dir 15191.72' MD, 6148.11' TVD ` - End Dir 17272.10 MD, 6243.84' TVD - - - - t Start Dir 3.00/100' 11680.69' MD, 6219.14' TVD \ 5 5 ` -- Top HRZ_ 5 ` Start Dir 3.00/100' 15580.12' MD, 6210.89' Ty D 54 .\ , `, \ 5 \ Start Dir 3.00/100' 17521.12' MD, 6293.16' TVD Base HRZ_ _ _ _ - - _ _ o . • • `. • . 5 5 ` 5 End Dir 15951.12' MD, 6235.03' TVD - - - i` ^ • . `\ a • . 1 ` `\ ` , - End Dir 18079.44' MD, 6322.76' TVD So S 6000- Kalubik Marker = to ` °' , . Top Kuparuk C /' . / / / c . i i 6600- Base Kuparuk (LCU) Top Nuiqsut ,' PN12 v6 T2 / PN1 v5 T4 ,' / PN12 v5 / PN12 v5 T8 � i Total Depth at 18906.41' MD, 6246.00' TVD / / / _ [N12 v6 T1 PN12 v5 T3 PN12 v5 T5 PN12 v517 PN12 v5 T91 ODSN -40 PN12 wp06 I I I i i i 1 l l l l l i i i i l l l l l l l l l i i i i i i I i l I l l l i l l l r I I I I I I I I I I I i I I I I I I I I I I I I I I I I I i i I I l i i I i i i i I l I l ' I l I I HI I I l i i I I l I l l l i I i i t' I I I -1200 -600 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 Vertical Section at 276.05bearing (1500 ft/in) WELL DETAILS: ODSN-40 REFERENCE INFORMATION ii t o, Co-ordinate (N/E) Reference: Well ODSN-40 - Slot ODS -40, True North G round Level: 13.5 H A LLI B lJ RT ©N Vertical (TVD) Reference: 42.5' + 13.5 (§ 56.00 +N/ -S +E/-W Northing Fasting Latittude Longitude Slot Measured Depth Reference: 42.5 + 13.5 @ 56.00 Sperry Grilling Service* 0.0 0.0 6031038.10 469854.21 70 °29'45.5.125 25N 150 °14'47.401 W ODS-40 Calculation Method: Minimum Curvature PIONEER SURVEY PROGRAM WELLBORE TARGET DETAILS (MAP CO- ORDINATES) Date: 2008-02-20T00:00:00 Validated: Yes Version: Name TVD +N / -S +E/ -W Northing Easting Shape Depth From Depth To Survey /Plan Tod Project: Oooguruk Developement P N12 v5 T5 6123.0 - 1770.3 - 7824.0 6029299.70 462023.85 Point 42.5 1600.0 ODSN -40 PN12 wp06 (01:1504110446132) 1600.0 18906.4 ODSN-40PN12wp06(Gt3at048,Rt8/40 *11FR +MS PN12 v5 T3 6161.0 - 3217.1 - 6441.2 6027847.47 463400.64 Point Site: Oooguruk Drill Site PN12 v6 T1 6196.0 - 4485.2 - 4892.2 6026573.23 464944.33 Point Well: ODSN -40 PN12 v5 T4 6206.0 - 2493.7 - 7132.6 6028573.59 462712.25 Point PN12 v5 T7 6206.0 -323.5 - 9206.8 6030751.93 460647.06 Point COMPANY DETAILS: Well Planning - Pioneer - Oooguruk Wellbore: ODSN -40 PN12 PN12 v6 T2 6219.6 - 3897.2 - 5693.8 6027164.39 464145.19 Point Plan: ODSN-40 PN12 w p O6 PN12v5T6 6236.0 - 1046.9 - 8515.4 6030025.82 461335.45 Point Calculation Method: Minimum Curvature PN12 v5 T9 6246.0 1123.2 - 10589.7 6032204.15 459270.27 Point Error System: ISCWSA 1200- I PN12 v5 T8 6331.0 399.8 - 9898.2 6031478.04 459958.67 Point Scan Tray.Cyl der North Elliptical - ' - I Total Depth at 18906.41' MD, 6246.00' TVD Warning Method: Rules Based ODSN -40 PNI2 wp06 I I End Dit 18079.44' MD, 6322.76' TVD 600- I _ Start Dir 1.00 /100' 300.00' MD, 300.00' TVD = '11) PN12vs- F_ - = Start Dir 3.00/100' 17521.12' MD, 6293.16' TVD i I Start Dir 2.00 /100' 800.00' MD, 799.40' TVD p- IPN12 v5 T End Dir 17272.10 MD, 6243.84' TVD \ _ - DDI -7.10 Start Dir3.00 /100' 1050.00' MD, 1047.10'TVD - -- 1 Start Dir 3.00 /100' 16830.34' MD, 6206.97' TVD 1P p0 1 End Dir 15951.12' MD, 6235.03' TVD End Dir 1693.20' MD, 1650.00' TVD -600- PN12 v5 T7 - - - - ' - Start Dir 3.00 /100' 15580.12' MD, 6210.89' TVD - - CASING DETAILS Start Dir 3.0/100' 2209.14' MD, 2100 - - 9 5/8" ,( 2500 - 3 PN12 v5 T�r - ' - - - End Dir 15191.72' MD, 6148.11' TVD .00' TVD -1200- 1 - - - TVD MD Name Size - - 2995.0 3291.0 9 5/8" 9.625 - - - - Start Dir 3.00 /100' 14685.21' MD, 6133.10' TVD 6196.0 10866.8 7" 7.000 I PN12 vs T _ 1 - , - - End Dir 4197.66' MD, 3540.98' TVD- _ &sib -1800 - - - _ - - End Dir 14073.53' MD, 6195.90' TVD 1 - SECTION DETAILS - - - - - - Start Dir 3.00/100' 13782.27' MD, 6203.65' TVD 0 - - Sec MD Inc Azi TVD +N / -S +E/ -W DLeg TFace VSec Target r _ - - - v -2400 1 42.5 0.00 0.00 42.5 0.0 0.0 0.00 0.00 0.0 - -- - - - - End Dir 12970.13' MD, 6163.35' TVD q70 + _ 2 300.0 0.00 0.00 300.0 0.0 0.0 0.00 0.00 0.0 t - - - - 3 800.0 5.00 150.00 799.4 -18.9 10.9 1.00 150.00 -12.8 I Start Dir 3.00/100' 12676.21' MD, 6167.90' TVD - t - 4 1 050.0 10.00 150.00 1047.1 -47.1 27.2 2.00 0.00 -32.0 I - - y -3000- 5 1693.2 29.29 150.00 1650.0 -233.5 134.8 3.00 0.00 -158.7 - - _ _ - p 6 2209.1 29.29 150.00 2100.0 -452.2 261.1 0.00 0.00 -307.3 I PN12 v5 T{I I ' s� _ 7 4197.7 63.65 224.37 3541.0 - 1617.6 -157.2 3.00 90.44 -14.3 I - - End Dir 1 1996.10' MD, 6215.03' TVD 8 8551.2 63.65 224.37 5473.2 -4406.3 - 2885.4 0.00 0.00 2404.5 - - 7 -3600 - 9 10666.8 83.00 300.00 6171.6 -4584.5 -4720.3 3.50 89.99 4210.4 PNI2 v5 T$ - - - 0 - 10 10866.8 83.00 300.00 6196.0 -4485.2 -4892.2 0.00 0.00 4391.9 PN12 v6 T1 1- , - - Start Dir 3.00/100' 11680.69' MD, 6219.14' TVD s 4) r4 - 11 11185.2 89.68 306.85 6216.3 -4310.3 -5157.1 3.00 45.94 4673.7 _ - 12 11680.7 89.68 306.85 6219.1 -4013.2 - 5553.6 0.00 0.00 5099.3 - 4200- 13 11862.7 90.00 312.30 6219.6 - 3897.2 - 5693.8 3.00 86.62 5251.0 PN12 v6 T2 [PN12 v6 T- End Dir 11185.24' MD, 6216.35' TVD 14 11996.1 93.97 311.83 6215.0 - 3807.9 - 5792.8 3.00 -6.75 5358.8 - 1 -7: - 15 12676.2 93.97 311.83 6167.9 - 3355.4 - 6298.3 0.00 0.00 5909.2 - - - - 16 12875.3 90.00 316.30 6161.0 - 3217.1 - 6441.2 3.00 131.59 6066.0 PN12 v5 T3 , _ $ ,r Start Dir 3.50/100' 8551.15' MD, 5473.19' TVD - 17 12970.1 87.16 316.30 6163.4 - 3148.6 - 6506.7 3.00 180.00 6138.3 �N12v6 TI -4800- 18 13782.3 87.16 316.30 6203.6 - 2562.2 - 7067.2 0.00 0.00 6757.5 - 19 13877.1 90.00 316.29 6206.0 - 2493.7 - 7132.6 3.00 -0.02 6829.8 PN12 v5 T4 1 - 20 14073.5 95.89 316.29 6195.9 - 2351.9 - 7268.1 3.00 0.00 6979.5 21 14685.2 95.89 316.29 6133.1 - 1912.1 - 7688.5 0.00 0.00 7444.0 / End Dir 10666.79' MD, 6171.63' TVD -5400- 22 14881.7 90.00 316.29 6123.0 - 1770.3 - 7824.0 3.00 180.00 7593.7 PN12 v5 T5 - 23 15191.7 80.70 316.30 6148.1 - 1547.2 - 8037.3 3.00 180.00 7829.3 Start Dir 3.00/100' 10866.790' MD, 6196.00' TVD - 24 15580.1 80.70 316.30 6210.9 - 1270.1 - 8302.2 0.00 0.00 8121.9 - 25 15890.2 90.00 316.29 6236.0 - 1046.9 - 8515.4 3.00 0.00 8357.5 PN12 v5 T6 • - 6000- 26 15951.1 91.83 316.30 6235.0 - 1002.9 - 8557.6 3.00 0.01 8404.0 27 16830.3 91.83 316.30 6207.0 -367.6 - 9164.7 0.00 0.00 9074.8 _ 28 16891.3 90.00 316.29 6206.0 -323.5 - 9206.8 3.00 - 179.99 9121.4 PN12 v5 T7 - 29 17272.1 78.58 316.30 6243.8 -50.1 - 9468.2 3.00 180.00 9410.1 - 30 17521.1 78.58 316.30 6293.2 126.4 - 9636.9 0.00 0.00 9596.4 -6600- 31 17901.9 90.00 316.29 6331.0 399.8 - 9898.2 3.00 0.00 9885.2 PN12 v5 T8 - 32 18079.4 95.33 316.29 6322.8 528.0 - 10020.7 3.00 0.00 10020.5 - 33 18906.4 95.33 316.29 6246.0 1123.2 - 10589.7 0.00 0.00 10649.1 PN12 v5 T9 I l I I I I i I I I I i I I I I i I I I I I I I i l I i I i i l i i l l l l i I r l i i l i i r i l l l i r l i l l l r i l i l i l i l i i l i i l i l l i l i l l I l i l i l i i 1 l i I i l l l l i l i i l i i l l l i l l l l i -13800 -13200 -12600 -12000 -11400 -10800 -10200 -9600 -9000 -8400 -7800 -7200 -6600 -6000 -5400 -4800 -4200 -3600 -3000 -2400 -1800 -1200 -600 0 600 West(- )/East( +) (1500 ft/in) • 0 Sperry Drilling Services HALLIBURTON Standard Proposal Report DMA Dane: ..EDM _Alaska LocaiCC?-ordlnater_, ncei . Well ODSN -40 - Slot ODS -40 , " C' y' , Well Planning - Pioneer - Oooguruk T't@ .. ence: • 42.5' + 13.5' @ 56.0ft • ct: Oooguruk Developement MMMD .. rence:; 42.5' + 13.5' @ 56.0ft Slte: <.:', Oooguruk Drill Site Maiiti Ref _ True We*" ` ODSN -40 Survey Calcua#ton Method: Minimum Curvature W e ODSN -40 PN12 Design: ' ODSN -40 PN12 wp06 Project Oooguruk Developement . Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site, Oooguruk Drill Site Site Position: Northing: 6,031,151.32ft Latitude: 70° 29' 46.242 N From: Map Easting: 469,920.45ft Longitude: 150° 14' 45.465 W Position Uncertainty: 0.0 ft Slot Radius: in Grid Convergence: -0.23 ? Well ODSN -40 - Slot ODS -40 Well Position +N /-S 0.0 ft Northing: 6,031,038.10 ft Latitude: 70° 29' 45.125 N +E / -W 0.0 ft Easting: 469,854.21 ft Longitude: 150° 14' 47.401 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft • pe ODSN -40 PN12 Magnet= liliernet Name Sample Date DedinatiOn Dip Angle Field Strength ' (?). (nT) IGRF200510 3/8/2007 23.23 80.81 57,644 Design ODSN -40 PN12 wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 42.5 VeNical Section:. Depth From MD), +N($ +EFW Direction {#t} (ft} (bearing) 42.5 0.0 0.0 276.05 I 3/6/2008 11 :15 :43AM Page 2 COMPASS 2003.16 Build 42B • Sperry Drilling Services HALLIBURTON Standard Proposal Report Database: ..EDM_Alaska Local Co to nce; Well ODSN -40 - Slot ODS -40 Company , Well Planning - Pioneer - Oooguruk TVD Rim ` 42.5' + 13.5 @ 56.Oft PiroJoct• : Oooguruk Developement MD R eAt: 42.5' + 13.5 @ 56.0ft $ Oooguruk Drill Site NOM) - Reference: True Wit, ., ODSN-40 reitycalculatron Minimum Curvature W� ODSN -40 PN12 ODSN -40 PN12 wp06 , ure+d VertiCal WD , Dogleg Build Turn Depth inclination Azimuth Depth System +P1/ -s +E!-W Rate Rate Tool Face (ft) ( ?) ( (ft) ft (ft) (ft) ( ?(1OOft) 0H00ft) ( ?/lOOft) ( ?) 42.5 0.00 0.00 42.5 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 300.0 0.00 0.00 300.0 244.0 0.0 0.0 0.00 0.00 0.00 0.00 800.0 5.00 150.00 799.4 743.4 -18.9 10.9 1.00 1.00 0.00 150.00 1,050.0 10.00 150.00 1,047.1 9 -47.1 27.2 2.00 2.00 0.00 0.00 1,693.2 29.29 150.00 1,650.0 1,594.0 -233.5 134.8 3.00 3.00 0.00 0.00 2,209.1 29.29 150.00 2,100.0 2,044.0 -452.2 261.1 0.00 0.00 0.00 0.00 4,197.7 63.65 224.37 3,541.0 3,485.0 - 1,617.6 -157.2 3.00 1.73 3.74 90.44 8,551.2 63.65 224.37 ' 5,473.2 5,417.2 - 4,406.3 - 2,885.4 0.00 0.00 0.00 0.00 10,666.8 83.00 300.00 6,171.6 6,115.6 - 4,584.5 - 4,720.3 3.50 0.91 3.57 89.99 10,866.8 83.00 300.00 6,196.0 6,140.0 - 4,485.2 - 4,892.2 0.00 0.00 0.00 0.00 11,185.2 89.68 306.85 6,216.3 6,160.3 - 4,310.3 - 5,157.1 3.00 2.10 2.15 45.94 11,680.7 89.68 306.85 6,219.1 6,163.1 - 4,013.2 - 5,553.6 0.00 0.00 0.00 0.00 11,862.7 90.00 312.30 6,219.7 6,163.7 - 3,897.2 - 5,693.8 3.00 0.18 2.99 86.62 11,996.1 93.97 311.83 6,215.0 6,159.0 - 3,807.9 - 5,792.8 3.00 2.98 -0.35 -6.75 12,676.2 93.97 311.83 6,167.9 6,111.9 - 3,355.4 - 6,298.3 0.00 0.00 0.00 0.00 12,875.3 90.00 316.30 6,161.0 6,105.0 - 3,217.1 - 6,441.2 3.00 -2.00 2.24 131.59 12,970.1 87.16 316.30 6,163.4 6,107.4 - 3,148.6 - 6,506.7 3.00 -3.00 0.00 180.00 13,782.3 87.16 316.30 6,203.6 6,147.6 - 2,562.2 - 7,067.2 0.00 0.00 0.00 0.00 13,877.1 90.00 316.29 6,206.0 6,150.0 - 2,493.7 - 7,132.6 3.00 3.00 0.00 -0.02 14,073.5 95.89 316.29 6,195.9 6,139.9 - 2,351.9 - 7,268.1 3.00 3.00 0.00 0.00 14,685.2 95.89 316.29 6,133.1 6,077.1 - 1,912.1 - 7,688.5 0.00 0.00 0.00 0.00 14,881.7 90.00 316.29 6,123.0 6,067.0 - 1,770.3 - 7,824.0 3.00 -3.00 0.00 180.00 15,191.7 80.70 316.30 6,148.1 6,092.1 - 1,547.2 - 8,037.3 3.00 -3.00 0.00 180.00 15,580.1 80.70 316.30 6,210.9 6,154.9 - 1,270.1 - 8,302.2 0.00 0.00 0.00 0.00 15,890.2 90.00 316.29 6,236.0 6,180.0 - 1,046.9 - 8,515.4 3.00 3.00 0.00 0.00 15,951.1 91.83 316.30 6,235.0 6,179.0 - 1,002.9 - 8,557.6 3.00 3.00 0.00 0.01 16,830.3 91.83 316.30 6,207.0 6,151.0 -367.6 - 9,164.7 0.00 0.00 0.00 0.00 16,891.3 90.00 316.29 6,206.0 6,150.0 -323.5 - 9,206.8 3.00 -3.00 0.00 - 179.99 17,272.1 78.58 316.30 6,243.8 6,187.8 -50.1 - 9,468.2 3.00 -3.00 0.00 180.00 1 17,521.1 78.58 316.30 6,293.2 6,237.2 126.4 - 9,636.9 0.00 0.00 0.00 0.00 17,901.9 90.00 316.29 6,331.0 6,275.0 399.8 - 9,898.2 3.00 3.00 0.00 0.00 18,079.4 95.33 316.29 6,322.8 6,266.8 528.0 - 10,020.7 3.00 3.00 0.00 0.00 18,906.4 95.33 316.29 6,246.0 6,190.0 1,123.2 - 10,589.7 0.00 0.00 0.00 0.00 3/6/2008 11:15:43AM Page 3 COMPASS 2003.16 Build 428 • Sperry Drilling Services HALLIBURT0N Standard Proposal Report se: ..EDM_Alaska Weal C,odinate , ce: Well ODSN -40 - Slot ODS -40 any: Well Planning - Pioneer - Oooguruk TVD n ee: 42.5' + 13.5 @ 56.0ft Oooguruk Developement MD nee: 42.5 + 13.5 @ 56.0ft Site: Oooguruk Drill Site elerth i2efereriGea:. True Well: ODSN -40 veycalc d: Minimum Curvature Wetiec . ODSN -40 PN12 Desige ODSN -40 PN12 wp06 Planned SurVe t . . Measured Vertical Map Map Depth Inclination Azimuth Depth WD +N!-S +EI llt Northing Easting DLS Vert Section (ft} ( ?} - („ ng) (ft) ft (ft} (ft) (ft) (ft} 43,50 42.5 0.00 0.00 42.5 -13.5 0.0 0.0 6,031,038.10 • 469,854.21 • 0.00 0.00 100.0 0.00 0.00 100.0 44.0 0.0 0.0 6,031,038.10 469,854.21 0.00 0.00 200.0 0.00 0.00 200.0 144.0 0.0 0.0 6,031,038.10 469,854.21 0.00 0.00 300.0 0.00 0.00 300.0 244.0 0.0 0.0 6,031,038.10 469,854.21 0.00 0.00 . Start Dir 1.00/100' 300.00' MD, 300.00' TVD 400.0 1.00 150.00 400.0 344.0 -0.8 0.4 6,031,037.34 469,854.64 1.00 -0.51 500.0 2.00 150.00 500.0 444.0 -3.0 1.7 6,031,035.07 469,855.94 1.00 -2.05 600.0 3.00 150.00 599.9 543.9 -6.8 3.9 6,031,031.29 469,858.11 1.00 -4.62 700.0 4.00 150.00 699.7 643.7 -12.1 7.0 6,031,025.99 469,861.14 1.00 -8.21 800.0 5.00 150.00 799.4 743.4 -18.9 10.9 6,031,019.18 469,865.03 1.00 -12.83 Start Dir 2.00/100' 800.00' MD, 799.40' TVD 900.0 7.00 150.00 898.8 842.8 -27.9 16.1 6,031,010.10 469,870.22 2.00 -18.98 1,000.0 9.00 150.00 997.8 941.8 -40.0 23.1 6,030,998.03 469,877.13 2.00 -27.17 1,050.0 10.00 150.00 1,047.1 991.1 -47.1 27.2 6,030,990.86 469,881.23 2.00 -32.03 Start Dir 3.00/100' 1050.00' MD, 1047.10' TVD . 1,100.0 11.50 150.00 1,096.3 1,040.3 -55.2 31.9 6,030,982.77 469,885.86 3.00 -37.52 1,200.0 14.50 150.00 1,193.7 1,137.7 -74.7 43.1 6,030,963.25 469,897.02 3.00 -50.76 1,300.0 17.50 150.00 1,289.8 1,233.8 -98.6 56.9 6,030,939.32 469,910.70 3.00 -66.98 1,400.0 20.50 150.00 1,384.4 1,328.4 -126.7 73.2 6,030,911.07 469,926.86 3.00 -86.14 1,500.0 23.50 150.00 1,477.1 1,421.1 -159.2 91.9 6,030,878.56 469,945.46 3.00 - 108.18 1,600.0 26.50 150.00 1,567.7 1,511.7 -195.8 113.0 6,030,841.88 469,966.44 3.00 - 133.05 1,643.1 27.79 150.00 1,606.0 1,550.0 -212.8 122.9 6,030,824.83 469,976.19 3.00 - 144.62 Base of Permafrost • 1,693.2 29.29 150.00 1,650.0 1,594.0 -233.5 134.8 6,030,804.05 469,988.07 3.00 - 158.71 End Dir 1693.20' MD, 1650.00' TVD , 1,700.0 29.29 150.00 1,656.0 1,600.0 -236.4 136.5 6,030,801.15 469,989.74 0.00 - 160.68 1,800.0 29.29 150.00 1,743.2 1,687.2 -278.8 161.0 6,030,758.68 470,014.03 0.00 - 189.47 1,900.0 29.29 150.00 1,830.4 1,774.4 -321.2 185.4 6,030,716.21 470,038.32 0.00 - 218.27 2,000.0 29.29 150.00 1,917.6 1,861.6 -363.5 209.9 6,030,673.74 470,062.61 0.00 - 247.07 2,100.0 29.29 150.00 2,004.8 1,948.8 -405.9 234.4 6,030,631.27 470,086.90 0.00 - 275.87 2,200.0 29.29 150.00 2,092.0 2,036.0 -448.3 258.8 6,030,588.80 470,111.19 0.00 - 304.67 2,209.1 29.29 150.00 2,100.0 2,044.0 -452.2 261.1 6,030,584.92 470,113.41 0.00 - 307.30 Start Dir 3.0/100' 2209.14' MD, 2100.00' TVD • 2,300.0 29.39 155.56 2,179.2 2,123.2 -491.7 281.4 6,030,545.29 470,133.59 3.00 - 331.70 2,400.0 29.76 161.60 2,266.2 2,210.2 -537.6 299.4 6,030,499.32 470,151.39 3.00 - 354.43 2,469.0 30.17 165.66 2,326.0 2,270.0 -570.7 309.1 6,030,466.24 470,160.96 3.00 - 367.56 Top West Sak 2,500.0 30.39 167.45 2,352.8 2,296.8 -585.9 312.7 6,030,451.03 470,164.53 3.00 - 372.78 2,600.0 31.28 173.04 2,438.6 2,382.6 -636.3 321.4 6,030,400.53 470,172.96 3.00 - 386.70 2,700.0 32.39 178.33 2,523.6 2,467.6 -688.9 325.3 6,030,347.97 470,176.68 3.00 - 396.14 2,800.0 33.71 183.27 2,607.5 2,551.5 -743.4 324.5 6,030,293.49 470,175.66 3.00 - 401.10 2,900.0 35.21 187.86 2,689.9 2,633.9 -799.7 319.0 6,030,237.24 470,169.90 3.00 - 401.54 3,000.0 36.88 192.10 2,770.8 2,714.8 -857.6 308.7 6,030,179.37 470,159.43 3.00 - 397.47 3,019.1 37.21 192.87 2,786.0 2,730.0 - 868.8, 306.3 6,030,168.17 470,156.90 3.00 - 396.18 Hue Shale 3/6/2008 11 :15 :43AM Page 4 COMPASS 2003.16 Build 42B Sperry Drilling Services P r'Y 9 HA►LLIBURTON Standard Proposal Report Database; _ ..EDM_Alaska !ordinate Reference: Well ODSN -40 - Slot ODS-40 Company: Well Planning - Pioneer - Oooguruk WO , e: 42.5' + 13.5' @ 56.0ft ftiltet Oooguruk Developement WO Ref.0044Ke: 42.5' + 13.5' @ 56.011 Me: . Oooguruk Drill Site North nce' True Well ODSN -40 Sur y Calculation Method: Minimum Curvature ore:: ODSN -40 PN12 gitaign: ODSN -40 PN12 wp06 PlaWtOd Survey . ured Vertical Map Map pooh Incifeadm Azimuth Depth TVDa4 +N/-S +E14f Northing Easting D4S Vert Secton ftft f?} , thawing) (ft) ft (ft) ffft th) (ft) 2,750.00 3,044.3 37.66 193.87 2,806.0 2,750.0 -883.7 302.7 6,030,153.29 470,153.30 3.00 - 394.23 Tuffaceous Shales 3,100.0 38.68 196.02 2,849.8 2,793.8 -917.0 293.8 6,030,120.05 470,144.28 3.00 - 388.90 3,200.0 40.61 199.63 2,926.8 2,870.8 -977.7 274.3 6,030,059.43 470,124.48 3.00 - 375.85 3,291.0 42.45 202.67 2,995.0 2,939.0 - 1,033.9 252.5 6,030,003.26 470,102.46 3.00 - 360.11 9 5/8" 3,300.0 42.63 202.96 3,001.6 2,945.6 - 1,039.5 250.1 6,029,997.69 470,100.08 3.00 - 358.37 3,400.0 44.75 206.04 3,073.9 3,017.9 - 1,102.3 221.5 6,029,934.99 470,071.17 3.00 - 336.49 3,500.0 46.94 208.89 3,143.6 3,087.6 - 1,166.0 188.3 6,029,871.50 470,037.81 3.00 - 310.28 3,600.0 49.20 211.54 3,210.4 3,154.4 - 1,230.2 150.9 6,029,807.40 470,000.09 3.00 - 279.81 3,700.0 51.52 214.02 3,274.2 3,218.2 - 1,294.9 109.2 6,029,742.86 469,958.12 3.00 - 245.16 3,800.0 53.88 216.34 3,334.8 3,278.8 - 1,359.9 63.3 6,029,678.06 469,912.02 3.00 - 206.43 3,900.0 56.29 218.52 3,392.0 3,336.0 - 1,425.0 13.5 6,029,613.18 469,861.91 3.00 - 163.72 4,000.0 58.73 220.59 3,445.7 3,389.7 - 1,490.0 -40.2 6,029,548.39 469,807.93 3.00 - 117.15 4,100.0 61.21 222.55 3,495.8 3,439.8 - 1,554.8 -97.7 6,029,483.88 469,750.23 3.00 -66.85 4,197.7 63.65 224.37 3,541.0 3,485.0 - 1,617.6 -157.2 6,029,421.30 469,690.43 3.00 -14.26 End Dir 4197.66' MD, 3540.98' TVD 4,200.0 63.65 224.37 3,542.0 3,486.0 - 1,619.1 -158.7 6,029,419.81 469,688.96 0.01 -12.96 4,300.0 63.65 224.37 3,586.4 3,530.4 - 1,683.2 -221.4 6,029,356.02 469,626.04 0.00 42.60 4,400.0 63.65 224.37 3,630.8 3,574.8 - 1,747.2 -284.0 6,029,292.22 469,563.12 0.00 98.15 4,500.0 63.65 224.37 3,675.2 3,619.2 - 1,811.3 -346.7 6,029,228.42 469,500.21 0.00 153.71 4,600.0 63.65 224.37 3,719.6 3,663.6 - 1,875.3 -409.4 6,029,164.63 469,437.29 0.00 209.27 4,700.0 63.65 224.37 3,763.9 3,707.9 - 1,939.4 -472.0 6,029,100.83 469,374.37 0.00 264.83 4,800.0 63.65 224.37 3,808.3 3,752.3 - 2,003.4 -534.7 6,029,037.04 469,311.45 0.00 320.39 4,900.0 63.65 224.37 3,852.7 3,796.7 - 2,067.5 -597.4 6,028,973.24 469,248.53 0.00 375.95 5,000.0 63.65 224.37 3,897.1 3,841.1 - 2,131.6 -660.0 6,028,909.45 469,185.62 0.00 431.51 5,100.0 63.65 224.37 3,941.5 3,885.5 - 2,195.6 -722.7 6,028,845.65 469,122.70 0.00 487.07 5,200.0 63.65 224.37 3,985.9 3,929.9 - 2,259.7 -785.4 6,028,781.86 469,059.78 0.00 542.63 5,300.0 63.65 224.37 4,030.2 3,974.2 - 2,323.7 -848.0 6,028,718.06 468,996.86 0.00 598.19 5,400.0 63.65 224.37 4,074.6 4,018.6 - 2,387.8 -910.7 6,028,654.27 468,933.94 0.00 653.75 5,500.0 63.65 224.37 4,119.0 4,063.0 - 2,451.8 -973.3 6,028,590.47 468,871.02 0.00 709.31 5,600.0 63.65 224.37 4,163.4 4,107.4 - 2,515.9 - 1,036.0 6,028,526.68 468,808.11 0.00 764.86 5,700.0 63.65 224.37 4,207.8 4,151.8 - 2,580.0 - 1,098.7 6,028,462.88 468,745.19 0.00 820.42 5,800.0 63.65 224.37 4,252.1 4,196.1 - 2,644.0 - 1,161.3 6,028,399.08 468,682.27 0.00 875.98 5,900.0 63.65 224.37 4,296.5 4,240.5 - 2,708.1 - 1,224.0 6,028,335.29 468,619.35 0.00 931.54 6,000.0 63.65 224.37 4,340.9 4,284.9 - 2,772.1 - 1,286.7 6,028,271.49 468,556.43 0.00 987.10 6,100.0 63.65 224.37 4,385.3 4,329.3 - 2,836.2 - 1,349.3 6,028,207.70 468,493.52 0.00 1,042.66 6,200.0 63.65 224.37 4,429.7 4,373.7 - 2,900.2 - 1,412.0 6,028,143.90 468,430.60 0.00 1,098.22 6,300.0 63.65 224.37 4,474.1 4,418.1 - 2,964.3 - 1,474.7 6,028,080.11 468,367.68 0.00 1,153.78 6,400.0 63.65 224.37 4,518.4 4,462.4 - 3,028.4 - 1,537.3 6,028,016.31 468,304.76 0.00 1,209.34 6,500.0 63.65 224.37 4,562.8 4,506.8 - 3,092.4 - 1,600.0 6,027,952.52 468,241.84 0.00 1,264.90 6,600.0 63.65 224.37 4,607.2 4,551.2 - 3,156.5 - 1,662.7 6,027,888.72 468,178.93 0.00 1,320.46 6,700.0 63.65 224.37 4,651.6 4,595.6 - 3,220.5 - 1,725.3 6,027,824.93 468,116.01 0.00 1,376.01 6,800.0 63.65 224.37 4,696.0 4,640.0 - 3,284.6 - 1,788.0 6,027,761.13 468,053.09 0.00 1,431.57 6,900.0 63.65 224.37 4,740.4 4,684.4 - 3,348.6 - 1,850.7 6,027,697.34 467,990.17 0.00 1,487.13 3/6/2008 11:15:43AM Page 5 COMPASS 2003.16 Build 42B • • Sperry Drilling Services HALL1BURTDN Standard Proposal Report as ; ; •. ..EDM_Alaska Local Cp Viinate Referent: Well ODSN -40 - Slot ODS -40 company: Well Planning - Pioneer - Oooguruk We ROWOCCO: 42.5' + 13.5' @ 56.0ft oJect: • Oooguruk Developement r,nce; . • 42.5' + 13.5' @ 56.0ft *bat L:sr Oooguruk Drill Site NO0 Retafinae: True Welt:`,; ODSN -40 SoyC tt od: Minimum Curvature We ODSN -40 PN12 ODSN -40 PN12 wp06 Planned Survey Measured Vertical Map Map Depth inclination Azimuth Depth TVDss +N1-S +E/ -W Noting Easting DLS Vert Section (ft) ( ?} (being) (ft ) (ft) (ft) ) (ft) 4,728.74 7,000.0 63.65 224.37 4,784.7 4,728.7 - 3,412.7 - 1,913.3 6,027,633.54 467,927.25 0.00 1,542.69 7,100.0 63.65 224.37 4,829.1 4,773.1 - 3,476.7 - 1,976.0 6,027,569.74 467,864.34 0.00 1,598.25 7,200.0 63.65 224.37 4,873.5 4,817.5 - 3,540.8 - 2,038.7 6,027,505.95 467,801.42 0.00 1,653.81 7,300.0 63.65 224.37 4,917.9 4,861.9 - 3,604.9 - 2,101.3 6,027,442.15 467,738.50 0.00 1,709.37 7,400.0 63.65 224.37 4,962.3 4,906.3 - 3,668.9 - 2,164.0 6,027,378.36 467,675.58 0.00 1,764.93 7,442.2 63.65 224.37 4,981.0 4,925.0 - 3,695.9 - 2,190.4 6,027,351.44 467,649.04 0.00 1,788.37 Top Torok Sand 7,500.0 63.65 224.37 5,006.7 4,950.7 - 3,733.0 - 2,226.7 6,027,314.56 467,612.66 0.00 1,820.49 7,600.0 63.65 224.37 5,051.0 4,995.0 - 3,797.0 - 2,289.3 6,027,250.77 467,549.75 0.00 1,876.05 7,700.0 63.65 224.37 5,095.4 5,039.4 - 3,861.1 - 2,352.0 6,027,186.97 467,486.83 0.00 1,931.61 7,800.0 63.65 224.37 5,139.8 5,083.8 - 3,925.1 - 2,414.6 6,027,123.18 467,423.91 0.00 1,987.16 7,900.0 63.65 224.37 5,184.2 5,128.2 - 3,989.2 - 2,477.3 6,027,059.38 467,360.99 0.00 2,042.72 7,949.1 63.65 224.37 5,206.0 5,150.0 - 4,020.7 - 2,508.1 6,027,028.03 467,330.07 0.00 2,070.03 Base Torok Sand 8,000.0 63.65 224.37 5,228.6 5,172.6 - 4,053.3 - 2,540.0 6,026,995.59 467,298.07 0.00 2,098.28 8,100.0 63.65 224.37 5,273.0 5,217.0 - 4,117.3 - 2,602.6 6,026,931.79 467,235.15 0.00 2,153.84 8,200.0 63.65 224.37 5,317.3 5,261.3 - 4,181.4 - 2,665.3 6,026,868.00 467,172.24 0.00 2,209.40 8,300.0 63.65 224.37 5,361.7 5,305.7 - 4,245.4 - 2,728.0 6,026,804.20 467,109.32 0.00 2,264.96 8,400.0 63.65 224.37 5,406.1 5,350.1 - 4,309.5 - 2,790.6 6,026,740.40 467,046.40 0.00 2,320.52 8,500.0 63.65 224.37 5,450.5 5,394.5 - 4,373.5 - 2,853.3 6,026,676.61' 466,983.48 0.00 2,376.08 8,551.1 63.65 224.37 5,473.2 5,417.2 - 4,406.3 - 2,885.4 6,026,643.98 466,951.30 0.00 2,404.50 Start Dir 3.501100' 8551.15 MD, 5473.19' TVD 8,600.0 63.66 226.28 5,494.9 5,438.9 - 4,437.1 - 2,916.5 6,026,613.33 466,920.05 3.50 2,432.21 8,700.0 63.77 230.18 5,539.2 5,483.2 - 4,496.8 - 2,983.3 6,026,553.90 466,852.96 3.50 2,492.39 8,800.0 63.98 234.07 5,583.2 5,527.2 - 4,551.9 - 3,054.2 6,026,499.09 466,781.89 3.50 2,557.04 8,900.0 64.29 237.95 5,626.8 5,570.8 - 4,602.2 - 3,128.8 6,026,449.11 466,707.10 3.50 2,625.91 9,000.0 64.71 241.80 5,669.9 5,613.9 - 4,647.5 - 3,206.8 6,026,404.14 466,628.88 3.50 2,698.74 9,100.0 65.22 245.62 5,712.2 5,656.2 - 4,687.6 - 3,288.0 6,026,364.35 466,547.51 3.50 2,775.27 9,133.0 65.41 246.87 5,726.0 5,670.0 - 4,699.7 - 3,315.5 6,026,352.40 466,520.05 3.50 2,801.26 Top HRZ 9,200.0 65.83 249.40 5,753.7 5,697.7 - 4,722.4 - 3,372.1 6,026,329.90 466,463.31 3.50 2,855.21 9,300.0 66.54 253.15 5,794.1 5,738.1 - 4,751.7 - 3,458.8 6,026,300.90 466,376.57 3.50 2,938.26 9,400.0 67.33 256.86 5,833.2 5,777.2 - 4,775.5 - 3,547.6 6,026,277.47 466,287.63 3.50 3,024.10 9,446.4 67.73 258.56 5,851.0 5,795.0 - 4,784.7 - 3,589.5 6,026,268.51 466,245.67 3.50 3,064.83 Base HRZ 9,500.0 68.21 260.52 5,871.1 5,815.1 - 4,793.7 - 3,638.4 6,026,259.70 466,196.82 3.50 3,112.43 9,600.0 69.16 264.13 5,907.5 5,851.5 - 4,806.1 - 3,730.7 6,026,247.65 466,104.47 3.50 3,202.91 9,700.0 70.19 267.70 5,942.2 5,886.2 - 4,812.8 - 3,824.2 6,026,241.36 466,010.94 3.50 3,295.20 9,705.3 70.25 267.89 5,944.0 5,888.0 - 4,813.0 - 3,829.2 6,026,241.19 466,005.93 3.50 3,300.16 Kalubik Marker 9,800.0 71.29 271.22 5,975.2 5,919.2 - 4,813.7 - 3,918.6 6,026,240.86 465,916.56 3.50 3,388.97 9,892.4 72.37 274.43 6,004.0 5,948.0 - 4,809.3 - 4,006.2 6,026,245.55 465,828.95 3.50 3,476.57 Top Kuparuk C 9,900.0 72.46 274.69 6,006.3 5,950.3 - 4,808.7 - 4,013.4 6,026,246.16 465,821.70 3.50 3,483.85 3/6/2008 11:15:43AM Page 6 COMPASS 2003.18 Build 428 Sperry Drilling Services HALLI BU RTO N Standard Proposal Report Database: ..EDM_Alaska t.ocai CO -ordI .Refer oo; Well ODSN -40 - Slot ODS -40 ny; . • Well Planning - Pioneer - Oooguruk 7 0 0 Referenie 42.5 + 13.5 @ 56.0ft Oooguruk Developement! tit;1; 42.5 + 13.5 @ 56.0ft Sthiti Oooguruk Drill Site Mirth True ODSN -40 SurveyCalriuulation Method: Minimum Curvature thelibore: ODSN -40 PN12 .. ODSN -40 PN12 wp06 thinned Sway ' Me Vertical Map Map Depth Inclination Azimuth ` Depth TVDss +N!-S +E.t -N Northing Easting DLS Vert Section t Gering (ft) ft ('h) (ft) (ft) (ft) 5,955.00 9,915.7 72.65 275.23 6,011.0 5,955.0 - 4,807.5 - 4,028.3 6,026,247.51 465,806.83 3.50 3,498.77 Base Kuparuk (LCU) 10,000.0 73.68 278.12 6,035.4 5,979.4 - 4,798.1 - 4,108.5 6,026,257.22 465,726.70 3.50 3,579.49 10,100.0 74.96 281.50 6,062.5 6,006.5 - 4,781.7 - 4,203.3 6,026,274.02 465,631.93 3.50 3,675.55 10,200.0 76.29 284.85 6,087.3 6,031.3 - 4,759.6 - 4,297.7 6,026,296.48 465,537.73 3.50 3,771.65 10,300.0 77.66 288.15 6,109.8 6,053.8 - 4,731.9 - 4,391.0 6,026,324.52 465,444.45 3.50 3,867.45 10,400.0 79.08 291.42 6,130.0 6,074.0 - 4,698.7 - 4,483.2 6,026,358.05 465,352.45 3.50 3,962.58 10,500.0 80.52 294.66 6,147.7 6,091.7 - 4,660.2 - 4,573.7 6,026,396.93 465,262.06 3.50 4,056.69 10,600.0 82.00 297.87 6,162.9 6,106.9 - 4,616.5 - 4,662.4 6,026,441.02 465,173.63 3.50 4,149.42 10,666.8 83.00 300.00 6,171.6 6,115.6 - 4,584.5 - 4,720.3 6,026,473.29 465,115.82 3.50 4,210.43 End Dir 10666.79' MD, 6171.63' TVD 10,700.0 83.00 300.00 6,175.7 6,119.7 - 4,568.0 - 4,748.9 6,026,489.88 465,087.34 0.00 4,240.55 10,800.0 83.00 300.00 6,187.9 6,131.9 - 4,518.3 - 4,834.8 6,026,539.85 465,001.60 0.00 4,331.26 10,866.8 83.00 300.00 6,196.0 6,140.0 - 4,485.2 - 4,892.2 6,026,573.23 464,944.33 0.00 4,391.85 Start Dir 3.00/100' 10866.790' MD, 6196.00' TVD - Top Nuiqsut - 7" - PN12 v6 T1 10,900.0 83.69 300.72 6,199.8 6,143.8 - 4,468.5 - 4,920.7 6,026,590.01 464,915.94 3.00 4,421.91 11,000.0 85.79 302.88 6,209.0 6,153.0 - 4,416.1 - 5,005.3 6,026,642.82 464,831.54 3.00 4,511.60 1 11,100.0 87.89 305.03 6,214.5 6,158.5 - 4,360.3 - 5,088.1 6,026,698.91 464,748.96 3.00 4,599.83 11,185.2 89.68 306.85 6,216.3 6,160.3 - 4,310.3 - 5,157.1 6,026,749.20 464,680.18 3.00 4,673.71 End Dir 11185.24' MD, 6216.35' TVD 11,200.0 89.68 306.85 6,216.4 6,160.4 - 4,301.4 - 5,168.9 6,026,758.09 464,668.40 0.00 4,686.39 11,300.0 89.68 306.85 6,217.0 6,161.0 -4,241.5 - 5,248.9 6,026,818.38 464,588.64 0.00 4,772.29 11,400.0 89.68 306.85 6,217.6 6,161.6 - 4,181.5 - 5,329.0 6,026,878.67 464,508.87 0.00 4,858.19 11,500.0 89.68 306.85 6;218.1 6,162.1 - 4,121.5 - 5,409.0 6,026,938.96 464,429.10 0.00 4,944.09 11,600.0 89.68 306.85 6,218.7 6,162.7 - 4,061.5 - 5,489.0 6,026,999.25 464,349.33 0.00 5,029.99 11,680.7 89.68 306.85 6,219.1 6,163.1 - 4,013.2 - 5,553.6 6,027,047.90 464,284.97 0.00 5,099.30 Start Dir 3.00/100' 11680.69' MD, 6219.14' TVD 11,700.0 89.71 307.43 6,219.2 6,163.2 - 4,001.5 - 5,569.0 6,027,059.62 464,269.62 3.00 5,115.84 11,800.0 89.89 310.42 6,219.6 6,163.6 - 3,938.7 - 5,646.8 6,027,122.75 464,192.10 3.00 5,199.81 11,862.7 90.00 312.30 6,219.7 6,163.7 - 3,897.2 - 5,693.8 6,027,164.39 464,145.19 3.00 5,251.01 PN12 vii T2 11,900.0 91.11 312.17 6,219.3 6,163.3 - 3,872.2 - 5,721.4 6,027,189.55 464,117.71 3.00 5,281.08 11,996.1 93.97 311.83 6,215.0 6,159.0 - 3,807.9 - 5,792.8 6,027,254.07 464,046.64 3.00 5,358.80 End Dir 11996.10' MD, 6215.03' TVD 12,000.0 93.97 311.83 6,214.8 6,158.8 - 3,805.3 - 5,795.7 6,027,256.67 464,043.75 0.00 5,361.95 12,100.0 93.97 311.83 6,207.8 6,151.8 - 3,738.8 - 5,870.0 6,027,323.50 463,969.70 0.00 5,442.89 12,200.0 93.97 311.83 6,200.9 6,144.9 - 3,672.3 - 5,944.3 6,027,390.33 463,895.64 0.00 5,523.83 12,300.0 93.97 311.83 6,194.0 6,138.0 - 3,605.7 - 6,018.7 6,027,457.16 463,821.59 0.00 5,604.76 12,400.0 93.97 311.83 6,187.0 6,131.0 - 3,539.2 - 6,093.0 6,027,523.98 463,747.53 0.00 5,685.70 12,500.0 93.97 311.83 6,180.1 6,124.1 - 3,472.7 - 6,167.3 6,027,590.81 463,673.48 0.00 5,766.63 12,600.0 93.97 311.83 6,173.2 6,117.2 - 3,406.1 - 6,241.7 6,027,657.64 463,599.42 0.00 5,847.57 12,676.2 93.97 311.83 6,167.9 6,111.9 - 3,355.4 - 6,298.3 6,027,708.57 463,542.99 0.00 5,909.25 Start Dir 3.00/100' 12676.21' MD, 6167.90' TVD 12,700.0 93.50 312.37 6,166.4 6,110.4 - 3,339.5 - 6,315.9 6,027,724.55 463,525.44 3.00 5,928.44 12,800.0 91.50 314.61 6,162.0 6,106.0 - 3,270.8 - 6,388.4 6,027,793.59 463,453.25 3.00 6,007.76 3/6/2008 11:15:43AM Page 7 COMPASS 2003.16 Build 42B • 0 Sperry Drilling Services H,ALLIBURTON Standard Proposal Report f} se: ..EDM_Alaska `p a Co- ordinate R eference: Well ODSN -40 - Slot ODS -40 ny: Well Planning - Pioneer - Oooguruk ' rend ' ` 42.5' + 13.5' @ 56.0ft Pa Oooguruk Developement PP R4ferene e: 42.5' + 13.5' @ 56.0ft Spec ' Oooguruk Drill Site North Refeteneel True Weil: I , ODSN -40 Survey c*uiition Methpd; Minimum Curvature Weiner e;'. ODSN -40 PN12 'Design ODSN -40 PN12 wp06 Piann d.Survey Meztered.. Vertical Map Map PePttl incHnatiop AZ ,. ' DeP� `EVDss +W$ +E/AWW Northing East 'ig DLS Vert Section { , en f . (ft) ft (f ) (ft) (ft), ff) 6,105.00 12,875.3 90.00 316.30 6,161.0 6,105.0 - 3,217.1 - 6,441.2 6,027,847.47 463,400.64 3.00 6,065.97 PN12v5T3 12,900.0 89.26 316.30 6,161.2 6,105.2 - 3,199.3 - 6,458.3 6,027,865.37 463,383.67 3.00 6,084.80 12,970.1 87.16 316.30 6,163.4 6,107.4 - 3,148.6 - 6,506.7 6,027,916.23 463,335.45 3.00 6,138.30 End Dir 12970.13' MD, 6163.35' ND 13,000.0 87.16 316.30 6,164.8 6,108.8 - 3,127.0 - 6,527.3 6,027,937.88 463,314.93 0.00 6,161.07 13,100.0 87.16 316.30 6,169.8 6,113.8 - 3,054.8 - 6,596.3 6,028,010.36 463,246.22 0.00 6,237.31 13,200.0 87.16 316.30 6,174.8 6,118.8 - 2,982.6 - 6,665.3 6,028,082.83 463,177.51 0.00 6,313.55 13,300.0 87.16 316.30 6,179.7 6,123.7 - 2,910.4 - 6,734.3 6,028,155.30 463,108.80 0.00 6,389.79 13,400.0 87.16 316.30 6,184.7 6,128.7 - 2,838.2 - 6,803.4 6,028,227.78 463,040.09 0.00 6,466.03 13,500.0 87.16 316.30 6,189.6 6,133.6 - 2,766.0 - 6,872.4 6,028,300.25 462,971.38 0.00 6,542.27 13,600.0 87.16 316.30 6,194.6 6,138.6 - 2,693.8 - 6,941.4 6,028,372.73 462,902.68 0.00 6,618.51 13,700.0 87.16 316.30 6,199.6 6,143.6 - 2,621.6 - 7,010.4 6,028,445.20 462,833.97 0.00 6,694.75 13,782.3 87.16 316.30 6,203.6 6,147.6 - 2,562.2 - 7,067.2 6,028,504.83 462,777.44 0.00 6,757.47 Start Dir 3.00/100' 13782.27' MD, 6203.65' TVD 13,800.0 87.69 316.30 6,204.4 6,148.4 - 2,549.4 - 7,079.4 6,028,517.68 462,765.26 3.00 6,770.99 13,877.1 90.00 316.29 6,206.0 6,150.0 - 2,493.7 - 7,132.6 6,028,573.59 462,712.25 3.00 6,829.81 PN12v5T4 13,900.0 90.69 316.29 6,205.9 6,149.9 - 2,477.1 - 7,148.5 6,028,590.23 462,696.48 3.00 6,847.31 14,000.0 93.69 316.29 6,202.0 6,146.0 - 2,404.9 - 7,217.5 6,028,662.73 462,627.74 3.00 6,923.58 14,073.5 95.89 316.29 6,195.9 6,139.9 - 2,351.9 - 7,268.1 6,028,715.89 462,577.34 3.00 6,979.51 End Dir 14073.53' MD, 6195.90' TVD 14,100.0 95.89 316.29 6,193.2 6,137.2 - 2,332.9 - 7,286.3 6,028,735.00 462,559.22 0.00 6,999.61 14,200.0 95.89 316.29 6,182.9 6,126.9 - 2,261.0 - 7,355.1 6,028,807.18 462,490.79 0.00 7,075.54 14,300.0 95.89 316.29 6,172.6 6,116.6 - 2,189.1 - 7,423.8 6,028,879.36 462,422.36 0.00 7,151.47 14,400.0 95.89 316.29 6,162.4 6,106.4 - 2,117.2 - 7,492.5 6,028,951.54 462,353.93 0.00 7,227.40 14,500.0 95.89 316.29 6,152.1 6,096.1 - 2,045.3 - 7,561.2 6,029,023.72 462,285.50 0.00 7,303.33 14,600.0 95.89 316.29 6,141.8 6,085.8 - 1,973.4 - 7,630.0 6,029,095.89 462,217.07 0.00 7,379.26 14,685.2 95.89 316.29 6,133.1 6,077.1 - 1,912.1 - 7,688.5 6,029,157.40 462,158.76 0.00 7,443.96 Start Dir 3.00/100' 14685.21' MD, 6133.10' TVD 14,700.0 95.45 316.29 6,131.6 6,075.6 - 1,901.4 - 7,698.7 6,029,168.08 462,148.64 3.00 7,455.20 14,800.0 92.45 316.29 6,124.7 6,068.7 - 1,829.3 - 7,767.6 6,029,240.46 462,080.01 3.00 7,531.34 14,881.7 90.00 316.29 6,123.0 6,067.0 - 1,770.3 - 7,824.0 6,029,299.70 462,023.85 3.00 7,593.66 PN12 v5 T5 14,900.0 89.45 316.29 6,123.1 6,067.1 - 1,757.1 - 7,836.7 6,029,313.00 462,011.24 3.00 7,607.66 15,000.0 86.45 316.30 6,126.7 6,070.7 - 1,684.8 - 7,905.7 6,029,385.51 461,942.49 3.00 7,683.93 15,100.0 83.45 316.30 6,135.5 6,079.5 - 1,612.8 - 7,974.6 6,029,457.79 461,873.98 3.00 7,759.96 15,191.7 80.70 316.30 6,148.1 6,092.1 - 1,547.2 - 8,037.3 6,029,523.69 461,811.49 3.00 7,829.29 End Dir 15191.72' MD, 6148.11' ND 15,200.0 80.70 316.30 6,149.5 6,093.5 - 1,541.3 - 8,043.0 6,029,529.63 461,805.87 0.00 7,835.54 15,300.0 80.70 316.30 6,165.6 6,109.6 - 1,469.9 - 8,111.2 6,029,601.24 461,737.98 0.00 7,910.87 15,400.0 80.70 316.30 6,181.8 6,125.8 - 1,398.6 - 8,179.3 6,029,672.85 461,670.09 0.00 7,986.20 15,500.0 80.70 316.30 6,197.9 6,141.9 - 1,327.2 - 8,247.5 6,029,744.46 461,602.20 0.00 8,061.53 15,580.1 80.70 316.30 6,210.9 6,154.9 - 1,270.1 - 8,302.2 6,029,801.83 461,547.81 0.00 8,121.88 I I Start Dir 3.00/100' 15580.12' MD, 6210.89' TVD 3/6/2008 11 :15 :43AM Page 8 COMPASS 2003.16 Build 42B • • Sperry Drilling Services HA►LLIBURTON Standard Proposal Report Datab ..EDM_Alaska i Co- ordifate Reference: Well ODSN -40 - Slot ODS -40 Corn Well Planning - Pioneer - Oooguruk .' tame: 42.5 + 13.5 @ 56.0ft P Oooguruk Developement Reference ;..:, ' 42.5 + 13.5 @ 56.0ft .. ,..... '. t Oooguruk Drill Site NfOrdtR tie: True . ODSN -40 Survey4 : tion Method: Minimum Curvature re. ODSN -40 PN12 in, ODSN -40 PN12 wp06 Manned Surly • • Measured V . Map Map Dew InanatiOn A4*Inith TVDss +NJ-S : •E!-W Northing Easting DLS Vert Section (ft) (?) Owing) (it) ft (ft) (ft) (1 (ft) 6,158.00 15,600.0 81.30 316.30 6,214.0 6,158.0 - 1,255.9 - 8,315.7 6,029,816.08 461,534.30 3.00 8,136.87 15,700.0 84.30 316.30 6,226.5 6,170.5 - 1,184.2 - 8,384.3 6,029,888.06 461,466.06 3.00 8,212.59 15,800.0 87.30 316.30 6,233.9 6,177.9 - 1,112.1 - 8,453.2 6,029,960.42 461,397.46 3.00 8,288.71 15,890.2 90.00 316.29 6,236.0 6,180.0 - 1,046.9 - 8,515.4 6,030,025.82 461,335.45 3.00 8,357.52 PN12v5T6 15,900.0 90.30 316.30 6,236.0 6,180.0 - 1,039.8 - 8,522.2 6,030,032.96 461,328.68 3.00 8,365.02 15,951.1 91.83 316.30 6,235.0 6,179.0 - 1,002.9 - 8,557.6 6,030,070.04 461,293.52 3.00 8,404.04 End Dir 15951.12' MD, 6235.03' TVD 16,000.0 91.83 316.30 6,233.5 6,177.5 -967.5 - 8,591.3 6,030,105.49 461,259.91 0.00 8,441.33 16,100.0 91.83 316.30 6,230.3 6,174.3 -895.3 - 8,660.4 6,030,178.02 461,191.16 0.00 8,517.62 16,200.0 91.83 316.30 6,227.1 6,171.1 -823.0 - 8,729.4 6,030,250.55 461,122.40 0.00 8,593.92 16,300.0 91.83 316.30 6,223.9 6,167.9 -750.8 - 8,798.5 6,030,323.07 461,053.64 0.00 8,670.21 16,400.0 91.83 316.30 6,220.7 6,164.7 -678.5 - 8,867.5 6,030,395.60 460,984.88 0.00 8,746.51 16,500.0 91.83 316.30 6,217.5 6,161.5 -606.3 - 8,936.6 6,030,468.13 460,916.12 0.00 8,822.81 16,600.0 91.83 316.30 6,214.3 6,158.3 -534.0 - 9,005.7 6,030,540.65 460,847.36 0.00 8,899.10 16,700.0 91.83 316.30 6,211.1 6,155.1 -461.8 - 9,074.7 . 6,030,613.18 460,778.60 0.00 8,975.40 16,800.0 91.83 316.30 6,207.9 6,151.9 -389.5 - 9,143.8 6,030,685.70 460,709.85 0.00 9,051.69 . 16,830.3 91.83 316.30 6,207.0 6,151.0 -367.6 - 9,164.7 6,030,707.71 460,688.98 0.00 9,074.84 Start Dir 3.00/100' 16830.34' MD, 6206.97' TVD 16,891.3 90.00 316.29 6,206.0 6,150.0 -323.5 - 9,206.8 6,030,751.93 460,647.06 3.00 9,121.36 PN12 v5 T7 16,900.0 89.74 316.30 6,206.0 6,150.0 -317.2 - 9,212.9 6,030,758.25 460,641.07 3.00 9,128.00 17,000.0 86.74 316.30 6,209.1 6,153.1 -245.0 - 9,281.9 6,030,830.77 460,572.32 3.00 9,204.29 17,100.0 83.74 316.30 6,217.4 6,161.4 -173.0 - 9,350.8 6,030,903.07 460,503.77 3.00 9,280.36 17,200.0 80.74 316.30 6,230.9 6,174.9 -101.3 - 9,419.2 6,030,974.96 460,435.61 3.00 9,355.98 17,272.1 78.58 316.30 6,243.8 6,187.8 -50.1 - 9,468.2 6,031,026.43 460,386.82 3.00 9,410.12 End Dir 17272.10 MD, 6243.84' TVD 17,300.0 78.58 316.30 6,249.4 6,193.4 -30.3 - 9,487.1 6,031,046.27 460,368.01 0.00 9,431.00 17,400.0 78.58 316.30 6,269.2 6,213.2 40.6 - 9,554.8 6,031,117.40 460,300.58 0.00 9,505.82 17,500.0 78.58 316.30 6,289.0 6,233.0 111.4 - 9,622.6 6,031,188.52 460,233.15 0.00 9,580.64 17,521.1 78.58 316.30 6,293.2 6,237.2 126.4 - 9,636.9 6,031,203.55 460,218.91 0.00 9,596.44 Start Dir 3.00 /100' 17521.12' MD; 6293.16' TVD 17,600.0 80.94 316.30 6,307.2 6,251.2 182.5 - 9,690.5 6,031,259.87 460,165.51 3.00 9,655.69 17,700.0 83.94 316.30 6,320.3 6,264.3 254.1 - 9,759.0 6,031,331.79 460,097.32 3.00 9,731.35 17,800.0 86.94 316.29 6,328.3 6,272.3 326.2 - 9,827.9 6,031,404.12 460,028.75 3.00 9,807.44 17,900.0 89.94 316.29 6,331.0 6,275.0 398.5 - 9,896.9 6,031,476.65 459,959.99 3.00 9,883.73 17,901.9 90.00 316.29 6,331.0 6,275.0 399.8 - 9,898.2 6,031,478.04 459,958.67 3.00 9,885.20 PN12 v5 T8 18,000.0 92.94 316.29 6,328.5 6,272.5 470.7 - 9,966.0 6,031,549.18 459,891.23 3.00 9,960.04 18,079.4 95.33 316.29 6,322.8 6,266.8 528.0 - 10,020.7 6,031,606.67 459,836.72 3.00 10,020.51 End Dir 18079.44' MD, 6322.76' TVD 18,100.0 95.33 316.29 6,320.8 6,264.8 542.8 - 10,034.9 6,031,621.52 459,822.64 0.00 10,036.14 18,200.0 95.33 316.29 6,311.6 6,255.6 614.8 - 10,103.7 6,031,693.77 459,754.14 0.00 10,112.14 18,300.0 95.33 316.29 6,302.3 6,246.3 686.7 - 10,172.5 6,031,766.02 459,685.65 0.00 10,188.15 1 18,400.0 95.33 316.29 6,293.0 6,237.0 758.7 - 10,241.3 6,031,838.27 459,617.15 0.00 10,264.15 3/6/2008 11:15:43AM Page 9 COMPASS 2003.16 Build 42B • • Sperry Drilling Services HALLIBURTON Standard Proposal Report se; r` ..EDM_Alaska Locai C stet . ; ,..tea: Well ODSN -40 - Slot ODS -40 t pany; : Well Planning - Pioneer - Oooguruk T 42.5' + 13.5' @ 56.0ft Oooguruk Developement �' ;' g p Rt# " -. �;,. • .. 42.5' + 13.5' @ 56.Oft Stkt: Oooguruk Drill Site 74ciith Reference: True We11; ODSN -40 Sucrey Calculation. o Minimum Curvature 'We ODSN -40 PN12 Design: ODSN -40 PN12 wp06 Plan... dSutvey ..., Measured Map on Azimuth Depth TVDss +AIMS +EI-W Nc'thing Earning DLS . Vert Section ( I. ( ?) (bearing) (ft) . ft (ft) (ft) (ft) (ft) 6,227.72 18,500.0 95.33 316.29 6,283.7 6,227.7 830.7 - 10,310.1 6,031,910.52 459,548.65 0.00 10,340.16 18,600.0 95.33 316.29 6,274.4 6,218.4 902.7 - 10,378.8 6,031,982.77 459,480.15 0.00 10,416.16 18,700.0 95.33 316.29 6,265.2 6,209.2 974.7 - 10,447.6 6,032,055.02 459,411.66 0.00 10,492.17 18,800.0 95.33 316.29 6,255.9 6,199.9 1,046.6 - 10,516.4 6,032,127.27 459,343.16 0.00 10,568.17 18,900.0 95.33 316.29 6,246.6 6,190.6 1,118.6 - 10,585.2 6,032,199.52 459,274.66 0.00 10,644.18 . 18,906.4 95.33 316.29 6,246.0 . 6,190.0 1,123.2 - 10,589.6 6,032,204.15 459,270.27 0.00 10,649.05 Total Depth at 18906.41' MD, 6246.00' TVD - PN12 v5 T9 T is IMiget Nays a .. is9 ,.. f NI% TVD #N/$ +E/ It Northing Fasting ? (f0 (st) ( (ft) (ft) PN12 v5 T8 0.00 0.00 6,331.0 399.8 - 9,898.2 6,031,478.04 459,958.67 - plan hits target - Point PN12 v5 T3 0.00 0.00 6,161.0 - 3,217.1 - 6,441.2 6,027,847.47 463,400.64 - plan hits target - Point PN12 v5 T9 0.00 0.00 6,246.0 1,123.2 - 10,589.7 6,032,204.15 459,270.27 - plan hits target - Point PN12 v5 T6 0.00 0.00 6,236.0 - 1,046.9 - 8,515.4 6,030,025.82 461,335.45 - plan hits target - Point PN12 v5 T4 0.00 0.00 6,206.0 - 2,493.7 - 7,132.6 6,028,573.59 462,712.25 - plan hits target - Point PN12 v6 T2 0.00 0.00 6,219.7 - 3,897.2 - 5,693.8 6,027,164.39 464,145.19 - plan hits target - Point PN12 v5 T7 0.00 0.00 6,206.0 -323.5 - 9,206.8 6,030,751.93 460,647.06 - plan hits target - Point PN12 v6 T1 0.00 0.00 6,196.0 - 4,485.2 - 4,892.2 6,026,573.23 464,944.33 - plan hits target - Point PN12 v5 T5 0.00 0.00 6,123.0 - 1,770.3 - 7,824.0 6,029,299.70 462,023.85 - plan hits target - Point Casing Poi Measu Vertical Hole D ;, ` Diameter Namxi (in} (in} 3,291.0 2,995.0 9 5/8" 9.625 12.250 10,866.8 6,196.0 7" 7.000 8.750 3/6/2008 11:15:43AM Page 10 COMPASS 2003.16 Build 42B Sperry Drilling Services HALLIBURTON Standard Proposal Report Data ..EDM_Alaska LO tad Re erence: Well ODSN -40 - Slot ODS -40 Cori , . Well Planning - Pioneer - Oooguruk . „ FCC*: : • 42.5' + 13.5' @ 56.0ft Oooguruk Developement MD nce 42.5' + 13.5' @ 56.0ft S Oooguruk Drill Site NFth ftetermay, .: - True ODSN -40 StuVeY Calculeftoo Method: Minimum Curvature cqe: ODSN -40 PN12 Dialith: ODSN -40 PN12 wp06 Formations Measured Vertieal. Vertical Dip - Depth' Depth Depth SS Dip Direction (ft) trt0 f Name Uthology (?) (nearing) 9,446.4 5,851.0 Base HRZ 0.00 3,019.1 2,786.0 Hue Shale 0.00 3,044.3 2,806.0 Tuffaceous Shales 0.00 1,643.1 1,606.0 Base of Permafrost 0.00 9,705.3 5,944.0 Kalubik Marker 0.00 10,866.8 6,196.0 Top Nuiqsut 0.00 9,915.7 6,011.0 Base Kuparuk (LCU) 0.00 7,949.1 5,206.0 Base Torok Sand 0.00 9,892.4 6,004.0 Top Kuparuk C 0.00 7,442.2 4,981.0 Top Torok Sand 0.00 2,469.0 2,326.0 Top West Sak 0.00 9,133.0 5,726.0 Top HRZ 0.00 Plait Annota . red Venal .Local Coordinates +Nt-S +Sf w { {ft) {€t) not 300.0 300.0 0.0 0.0 Start Dir 1.00/100' 300.00' MD, 300.00' TVD 800.0 799.4 -18.9 10.9 Start Dir 2.00/100' 800.00' MD, 799.40' TVD 1,050.0 1,047.1 -47.1 27.2 Start Dir 3.00/100' 1050.00' MD, 1047.10' TVD 1,693.2 1,650.0 -233.5 134.8 End Dir 1693.20' MD, 1650.00' TVD 2,209.1 2,100.0 -452.2 261.1 Start Dir 3.0/100' 2209.14' MD, 2100.00' TVD 4,197.7 3,541.0 - 1,617.6 -157.2 End Dir4197.66' MD, 3540.98' TVD 8,551.1 5,473.2 - 4,406.3 - 2,885.4 Start Dir 3.50/100' 8551.15' MD, 5473.19' TVD 10,666.8 6,171.6 - 4,584.5 - 4,720.3 End Dir 10666.79' MD, 6171.63' TVD 10,866.8 6,196.0 - 4,485.2 - 4,892.2 Start Dir 3.00/100' 10866.790' MD, 6196.00' TVD 11,185.2 6,216.3 - 4,310.3 - 5,157.1 End Dir 11185.24' MD, 6216.35' TVD 11,680.7 6,219.1 - 4,013.2 - 5,553.6 Start Dir 3.00/100' 11680.69' MD, 6219.14' TVD 11,996.1 6,215.0 - 3,807.9 - 5,792.8 End Dir 11996.10' MD, 6215.03' TVD 12,676.2 6,167.9 - 3,355.4 - 6,298.3 Start Dir 3.00/100' 12676.21' MD, 6167.90' TVD 12,970.1 6,163.4 - 3,148.6 - 6,506.7 End Dir 12970.13' MD, 6163.35' TVD 13,782.3 6,203.6 - 2,562.2 - 7,067.2 Start Dir 3.00/100' 13782.27' MD, 6203.65' TVD 14,073.5 6,195.9 - 2,351.9 - 7,268.1 End Dir 14073.53' MD, 6195.90' TVD 14,685.2 6,133.1 - 1,912.1 - 7,688.5 Start Dir 3.00/100' 14685.21' MD, 6133.10' TVD 15,191.7 6,148.1 - 1,547.2 - 8,037.3 End Dir 15191.72' MD, 6148.11' TVD 15,580.1 6,210.9 - 1,270.1 • - 8,302.2 Start Dir 3.00/100' 15580.12' MD, 6210.89' TVD 15,951.1 6,235.0 - 1,002.9 - 8,557.6 End Dir 15951.12' MD, 6235.03' TVD 16,830.3 6,207.0 -367.6 - 9,164.7 Start Dir 3.00/100' 16830.34' MD, 6206.97' TVD 17,272.1 6,243.8 -50.1 - 9,468.2 End Dir 17272.10 MD, 6243.84' TVD 17,521.1 6,293.2 126.4 - 9,636.9 Start Dir 3.00/100' 17521.12' MD, 6293.16' TVD 18,079.4 6,322.8 528.0 - 10,020.7 End Dir 18079.44' MD, 6322.76' TVD 18,906.4 6,246.0 1,123.2 - 10,589.6 Total Depth at 18906.41' MD, 6246.00' TVD j 3/6/2008 11:15:43AM Page 11 COMPASS 2003.16 Build 428 • 1.' moor rat c 3 1/9' -5000 PS GAZE WLW . 2. NcESOY ME C 2 9/18 -5000 PSI GAR VINE 3 CHOKE MANIFOLD SC EMATIC 4 . 5 21/16 -IO000 Ps1 so orE r3KXCE 4. I110R►ilrl- CNAVErt 1/8'-5000 P9 YAWN. CHOKE NABORS ALASKA RIG 19AC 5. RANGED 1EE 21/19' X 2 I /16' X 21/16' -5000 PSI 6. 5 NAY FUN BOCK 3 I /6' X 3 1/8' X 2 1 /I6' x 2 1/16' x 2 1 /I6' -5000 Psi • 7. 5 NAY FLAN B001• 3 1/8' X 3 1/8' x 3 1/8 x 3 I /8' x 2 1/16" -5000 PSI 3, 8. 4 NAY FLOW BOCK 2 1/16' X 2 I/16' X 2 I/16 X 2 1/16' -5000 PSI • T 9. 2 1/18' -5000 PSI sE1soR BLOCK 1, . 10. 2 1 /16'- w.000PSI X 2 1/16' -5000 PSI SPOOL • • $� Ups 11. 3 1/8 X 2 I/16 -5009 PSI SPOOL . • TQp .12. 2 1/16 X 2 1/16 -5000 PSI sPO0l • 13. 3 1/8' -5000 PSI X 2 I/16' -5000 P51 SPOOL • 15 14. 2 1/16' -10,000 PS 2 I/16 -5000 P51 00UBLE S111O ADAPTOR 2 Tp 15 2 1/16 -5aoo P51 tNKXT FtANt1E 16 3 I/8' -5000 PSI uRGEf FI/NCE 3" 0 /8' : 17. 3 1/8' -5000 P51 X 2 1/16 -5000 PSI 00081E S1U0 MVP= 18 1/8' 3 X 3 1/8 5000 PSI SPOOL P� 1C N e gel �I 19. 3 NAY 11.011 BLOCK 3 1 X 3 1 /6' X 3 1/8' -5000 PSI 2 { I 20. 5 wAY FLOW BOCK 2 9/16' X 2 9/16' X 2 9/16' X 2 9/16' X 2 9/16' -5000 PSI . Z' m ; z r ' • FR ©� / OE m • • `�- �' ; a -00 0 • 0 X'''...''.°.%)""Hp '......71111)<'>,... :,.<11 1 ‘ ..".....""......./. i . . .. CH () 1 C 16 • t Ns0srsA1vls1 m c"»'..'""'. m ...........• ...-= .w.-as NI -1 • NA90HS MASKA 14C 19nC . lat OlOAE I MIPOLO SCsEwfC • 11.' 1O! ISOM No IFWm 4 L'r9lliLy .+q' - .. $ °X` IP OMAN -- NIS . 24 nw 99 I9AC SIM 1 a I • • l IL 1 J " 1 1 CK ANNUbAR BO P 3' -1 � FLANGED HYDR 8OTTQM C ONNECTION i r 47 LENGTH . _ - -- - - - -- - -- - - -- 11 " 5000 4._7 y I . - -• FLANGED HYDRIL 13' -10 " - --- - -- -- -- DOUBLE TENPREEVENTOR 3 1/8 5000/ HCR VALVE _4 — — • � , 111111 I ; _ 3 1/8" 50001 HCR VALVE 1 , -91 3 _CHOKE L ET._ mw `"i �.. - -.- iii �„. ,��' . --- -- ?_KILL LINE .. • i i \3x2 y 3 1/8" 5000/ LATE VALVE ' 1 + t : 3" 50001 GATE VALVE I HYDRIL 11" 5k PSI 9 3' - " ___.7......._______7 1 -- - - - -.- -- -., HYDRAULIC RAM GATE FLANGED 1 F I 'I 41 3/4 LENGTH . NABORS ALASKA RIG 19AC . BOP STACK CONFIGURATION . • • x::"a- .rasti -ama -� • • nVAtS AlA9rA a: ,inC .a At,.-WI litItAIDC 1017 A /a MEW MD ww _ .Al • pQ ' µ.ms -- . -- -� p� war A "L �' '�' mamma 1 IVA M ON. f"1G/Mo K 1,, • • • • • 1 v�, zY ; • t5 _ �— . . �I - 4 : "- - . , L. . , . w a......., • ,: 1 . 1E1M ' le 0 I 1 a I i R II i S l ail . 11111111111 Y MINIX ma a r[..1. .13=== ico „mai =LI PS iiii,IXIMIll ' Mirrign POOL 1 �:.."I I:.J till ill) ' E • . II t 1II _ � _ � � i�M ! 1'E Ri: i I kill 1 .1 M iuItiraIu►I, --; -- - -- - -- ) `; -, - n os =o ---- T .. .: . iTill . , 0 Nabors Akashi :In= = 2.7* 1,_.x. -; X 11 .-1/� MOM . ",! MV Q� ar...... • M i r c RID i.C. KW Ala" f.0 IIIIII Aa A • • • Legend % • 1 1 �, I �' ' C As --a,rt Conductor • 0 . " • h • ° Mep.t wail& , • It a . MO , 71' Al - ,1.02.1.=.... • ^,� �� ' 0 • Location •Map : 4 11 • GRAPHIC BCAL 4*. • • . • • .,o a ..• • k_a.i• • � UPG.Doris o / • 4 I t d� No. 4110-$ � ,`` j ° "p ' • 1 Pep "` o r S J r h • 1 �; AOffSSf04P..� . • M1` • .• . . • • M , �A► \111' • w ry . ry t , • • 0. • !t "t�' i 1 $,.1: .. .. '' } 41 . t p Pioneer Natural Manaus)** JOB NAME: Dooguruk D Slto DRAWN BY BL !CHECKED BY: MJD • LOCATION: Ptotrooted Swoon .II SCALE: 1' -30' • Township 13 North • . Rungs 7 East DATE: 7 -12 -07 • • Umlat M•rlolan 1. • Notes NANUQ JOB NO. SHEET Coordinates ore listed on sheets 3 and 41 DESCRIPTION: Alaska Nod 27. Zone 4 Conductor M —bullt Plan • 05204 1 el 4 ' • • • • L ! '" . 1— I 7 � 1 • a . I 1 I i •.L^irtrict fan I ' SE orner o • _ i 000.01) o0oc1RuX sTE Protrocted Section 11 ac a, ill a s • a • +j" 11 Coordinates , § I!. N 6028111.04 . I 0 . 1 I \ _ E 4/� ••.• i o v1 - n • • , a Ref. AK ,BLM x . a �I �• \ \. Harrison: Boy . Trot h 'A' _ R -2a\ L t : �ti ~. ` Re rd • bk 1 prewirjg 1 1 z e 1 a -' `S-�c •? f pi -V i' Ce Ictroci =�P9 1 bE6 1, 4, , ' X eor Share itarooi.3.S7= ' 4 r t3 Ys? or a R 20 to Daor_•r,ik Ma Pt 7 4o P. ■ : t • t• s.„,14-2;....,7 , - " " :11-1 . 1tmGra icm'00 Spada to`Cd• 4 -- I 1 BUG t -/ , _ Bosis of Location P r 7 • r p , A DS -3H West Monument /lIr' 1 ' Coordinates 444 Mi# a a.+ 1 N 600107 6.61 STM[D PI INFORMfJ)ON ONLY P ; . 4...„...7-‘ 4 • . E 498081.23 • a a j , ; `et. L Ref. Lownsbury & Assoc. ^' s Drawing No. cc ' in 1 -- - I NSK 6.01—d672 • 011 1 ' .ryetr0�#y a' � • r• /!'4 % No. 4110.S . a y. i o i; , rr 3 t oras ionxi' Pioneer Natural Resouces JOB NAME: Ooogu'ruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protrocted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7 - 12 - 07 Umiat Meridian NANUQ JOB NO. I SHEET DESCRIPTION: Bosis of Locution 05204 2 of 4 • • Alaska $tate Plane t , .,,,..,_ - SeetiQn Line Of _ - I 1 (N) V X 1 6,031,151,32 469,Q0, 70 2 40,241 15 3035 10 7 --- 6,03 469,916;62 70 29 150 14 45,50922 3030 14 % 50 - -- .03 - 1141, - 9 ---- 46900,59 X 2940, 476376 3 fo -- i - s;so --- 4 6,031,136-46 469905,67 7 70 29 4 .6 - 7 -0 - 945 - 5 - . - 16014 46,69799 3020 1092 5 6,031;1 31145 - 409,900,74 7029 4,04536 150 1446,04252 3015 1097 ---- I3,50 0 ----- 6,031,126,51 46900,60 70 29 46,99000 150144 - $010 - 1102 - 13.50 ---- 6,031,113,73 469,6all 70 945709 :160 14 40 111 1$:50 ------- - 631, 1 0 & $ 469 7029 .- 021 Q2 15 46,70603 2992 112 . 13,50 9 6,03 70 29 4i M -7 1014f) 4.614 - w37 1125 is,w -- 6,031,0,98,79 - 69,868,66 - 70294572286 160 1446,99179 - 2,962 7 1140 -- 13,50 --- - 6,061,093,84 469 80, 39 70 29 46,67c-,98 150 14 47.13750 297t - Mal 13,50 7 - . • 1 0_13B R7 4E. F584 - 71)29 150 an 1140 13,50 . . 2 6 ,031,070,06 469,846,81 70 29 46,49640 160 14 47.65206 2900 1152 13:50 --r 14 - 0,031,071,09 70 29 45:44932 15014 47,79.770 2955 . h57 15 0,031,006-15 - 469,636,96 70 29 46,40066 150 '1447,94165 295 1 13, 50 - ' --- 16 --- 0,031,061,16 409,831,04 7Q 29 46,66146 150 14 2945 1167 - 13,50 17 0,031,056,26 - 409,026,11 70 2945,30277 15014 4.023042 2940 1172 - 13 - , - $0 16 0031,051-27 409,021,16 70 29 46,26669 160 14 46,67495 - 2965 1177 13,50 --- 19 6, g 469067,60 70 29 46,12766 'IN 14 46,74666 2922 1169 11, 409,003,59 70 29 40,0761 1 4006i 2917 2F6031 0,031,020-5S 4 69,7U,62 70 294:62706 160 1449,06.662 2912 1199 22 6,061,02,60 460;70,61 70 29 4C96914 1604 49, 2907 1204 - - 4,60 25 6,06f;016,67 7 40 , 7 .68 7 6 70 2.9 - 160 14 ;49,62667 2902 . 1209 1 • 24 6, 06 469,76.6 70 29 44,66169 16014 419:46960 2697. 1214 16,50 • - ....Tr: T. •....:Ird., 9 . 0 As, e - m - 7 , - 4- --Pstrti----- - - .... . . ... It 1 ? 7 N • * A...: . ..:. 7 .-.)...• • • .Philip: se d : i1 - . - ., -,•%.; Cl No 41104 :-.1 f - 4 4 ' % • 0 Nit" or 1 ' ."' :',:INt...`.: ...C-f 4. *, t 4 9 A, • 0 * .. GM. • 1 ,0) 4 ,„ : '', 1 ''' . ,', f s ' . L . 1 normiciiim.v 4. , ,, , ,t2 :,,,,p_•, -=,,:t.....: IV 4Fi ... 114‘1,1110,006:111P ".**4 : ZAI : :; ' &7t .1 >;•.: +. i:.; ,-..;• • 1, rivet, 4 or bgc.d cm VP Mg n $cc Le*, I ._ .. 2, Coordinotee ore toed on Alceko flote Plone Nod 27, Zohe 4, 3, All conductorg gre within Protrected Section 11, Pioneer Noturol Reecucee JOB NAME: OPc'gurvic Drill it C (DrichActor PRAWN BY: K. CHECKED BY: MX LOCATION; Prctrccted sectign 11 SCALE: N/A Towns.hip 1 North _._. Rouge 7 Eort DATE: 7-12.-Q7 Urniot Meridion - - - - NJ -- 4.1■10 ---- j166 - fti. SHEET bESCRIPTION; . . lk-bwIt Co(Prthriots 05204 3 of • • _W�1I-N. Alaske State Plane - - L�t�t ve �- ox�c33 d - Section Line Offset d-Elek Y X -FSL F t`t - 25 6,031,128.32 469,993.64 70 29 46.01630 150 14 44.77930 3013 1055 13.50 26 6,031,123.35 469,938.69 70 29 45:96722 150 14 44.92442 3008 1060: 13.50 27 6,031,118.33 469,933.76 70 29 45.91765 150 14 45.06895 300 1065 .13.50 28 6,031,113.39 469,928.86. 70 29 45.86887 ' 150 14 45.21260 2997 1070 13.50 29.' 6,031, 108.44 469,923.95 1 , 70 29 45.81999 150 14 45.35655 - 2992 1075 13.50 30 6,031,103.45 469,919.01 70 29 45.17071 150 14 45.50137 2988 1079 13.50. 31 6,031,090.65 469,906.38 70 29 45.64431 150 14 45.87163 2975 I 1092. 13.50 6,031,0E5.68 469,901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 6,031,080.67 469,896.50 70 29 45,54576 150 14 46.16128 2965 1102 13.50 34 . 6,031,075.73 469,891.57 70 29 45.49698 . 150 14 46.30581 2960 1106 13.50 35 6,031,070.76 469,886.60 70 29 45.44789 150 14 46.45152 2955 . 1111 13.50 36 6,031,065.83 469,881.69 70 29 45.39921 150 14 46.59547 2950 1116 13.50 ,I31 - r . • 9917 1 29 13.50 38 6,031,047.99 469,864.14 • • 2932 1134• 13.50 39 6,031,043.03 469,659.20 70 29 45.17406 150 14 47.25478 2927 1139 13.50 40 6,031,038.10 469,854.21 70 29 45.12537 150 14 47.40108 2922 .1144 13.50 '' 41 6,031,033.05 469,649.29 70 29 45.07551 150 14 47.54530 2917 1149 13.50 . 42 6,031,028.13 469,844.38 ` 70 29 45.02692 150 14 47.68925 2912 1154. 13.50 43 6,031,015.46 469,831.70 70 29 44.90180 150 14 48.06099 2899 1166 13.50 44 6,031,010.49 ' 469,826.79 70 29 44.85272 150 14 48.20493 2894 1171 " 13.50 ' l 45 .. 6,031,005.53 ' 459,821.86 '70 29 44.80373 150 14 48.34946 2889 1176 13.50 46 6,031,000.54 469,816.94 70 29 44.75446 150 14 48.49369 _ - 2884 . 1181 13.50 -47 6,030,995.50: 469,811.98 70 29'44.70469 150 14 48.63910 2879 1186 13.50 48 6,030,990.58 469,807.07 70 29 44.65610 150 14 48.78304 2874 • 1191 • 13.50 •. :N. . �, >> ` SURVEYOR'S CERTIFICATE' • ""''S .O..... ( � • --- rg_..•..'_' ' !..e4, 11 _ _ I _HEREBY CERTIFY THAT I AM l ` ' • \1 r. - -� PROPERLY REGISTER ETANEY -'- --`� ----' - -- or '� : 1k .•. d LICENS TO PRA CTICE LAND SURVEYING IN THE STATE OF "= 'j'b. • • . .... ALASKA AND THAT T PLAT :':' Nom = ply G; Davis % REPRESENTS A SURVEY DONE BY 3 %. No, A110.S •4�u / 40 ME OR UNDER MY SUPERVISION 1 ;'lfe 1•• «... ••. �o �J,,;+ AND THAT I BELIEVE THAT ALL 41 � orr,s�nNa'` ■ , DIMENSIONS AND OTHER DETAILS t �V'`:�tac •: . - %...,.,, � ...� ARE CORRECT AS SUBMITTED TO YY ME BY NANUO. INC. AS OF JULY 12TH, 2007. Pioneer Natural Resouces JOB NAME:' Oooguruk Drill Site Conductors DRAWN BY: 8L CHECKED BY: MJD. LOCATION: Protrocted Section 11 ' SCALE: N/A Township 13 North Ronge 7 rost DATE: 7 -12 -07 Umiot Meridian NANUQ JOB NO. SHEET DESCRIPTION: As -built Cocrdinotes 05204 4 of 4 • • TRANSMITTAL LETTER CHECKLIST WELL NAME rp.sA(" 5;I PTD# Development Service Exploratory Stratigraphic Test Non - Conventional Well 0;1 oo/ FIELD: _ C> © I� (AA -/A POOL. - Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool 000GURUK, NUIQSUT UNDEF OIL - 576150 Well Name: 000GURUK NUQ ODSN -40 Program DEV Well bore seg ❑ PTD#: 2080390 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type DEV / PEND GeoArea 973 Unit 11550 _ On /Off Shore Annular Disposal ❑ Administration 1 Permit fee attached NA 2 _Lease number appropriate Yes Surf Loc &Top Prod Int in ADL0355036; TO in ADL0355037. roA 3 Unique well name and number Yes 4 Well located in_a_defined pool No 000GURUK,_NUIQSUT UNDEF OIL - 576150; Conservation Order is progress. 15 Welllocated paper distance from drilling unit boundary Yes 1 6 Welliocated proper distance from ot her wells Yes 17 Sufficientacreage_available in_driiling u nit Yes 18 If_deviated, is wellbore plat_included Yes 19 _Operator only affected party Yes 110 Operator has_appropriate bond in force Yes 11 Permitcan be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative_approval Yes SFD 3/21/2008 '13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by_ Injection Order_ # (put_ 10# in_comments)_ (For NA • 1 115 All weliswithi_n 1 /4_mile_area_of review identified ( For service well only) NA 118 Pre- produced injector duration of pre - production less than 3 months (For service well only) _ _ _NA_ 117 _Nonconven, gas_COnforms to AS31.05:030(j_.1.A),(1.2.A -D) NA Engineering 118 Conductorstring_p_rovided Yes 1 19 Surface casingprotects all known USDWs NA Surface location is offshore, No known USDWs. ■ 20 CMT_vol adequate to circutate_on_conductor& surf csg Yes 21 CMT_ vol. adequate to tie -in long string to surf csg No 1 22 CMT will coverall known_ productive horizons No Open hole completion planned, 123 Casing designs adequate for C, 1, B & permafrost Yes 124 Adequate tankage_or reserve pit Yes Rig equipped with steel pits, No reserve pit planned. Alt waste to approved disposal well. 125 its re- drill, has_ a 10403 for abandonment been approved NA 126 Adequate wellbore separation_proposed Yes Proximity_ anelysis performed, Traveling cylinder paths calculated. Magnetic ranging likely in surface hole. 127 If divetter required, does it meet regulations NA PXD filed surf ace_ hole_information_& seeks a diverter waiver. No issues identified_dritling prior wells. Appr Date 128 Drilling fluid program schematic_& equip list adequate Yes Maximum expected formation pressure 906 EMW. Planned MW_up to 10.4 ppg. TEM 4/15/2008 1 29 BOPEs,_do _they _meet regulation Yes • 4_9,7y( 130 BOPE_press rating appropriate; test to_(put prig in comments) Yes MASP calculated at 2454 psi. 3500psiBOP test_plan 131 Choke manifold compliesw /API_ RP -53 (May 8 4) Yes 132 Work will occur without operation shutdown Yes This well should be drilled to TD in a continuous operation, 1 is presence of H2S gas probable No H2S has not been reported in offset wells. Rig equipped with sensors and alarms. 134 _Mechanical_condkion of wets within AOR verified (For service well only NA Geology 1 35 Permit can be issued wIo hydrogen sulfide measures Yes None encountered in previous wefts but operator will take standard H2S precautions. 36 Data_preaented on potential overpressure. zones Yes Expected reservoirpressure is 9.8_ppg;will be drilled_ with 10.4 ppg mud. Appr Date 37 Sei analysis of shallow gas_zo NA SFD 3/21/2008 38 Seabed condition survey_(if off - s hore) NA 139 Contact name /phone for weekly_progress reports [exploratory only] NA Geologic Date: Engineering Date Public Date Commissioner: Commissioner Commissioner -; ;- p , C*(,47-•-41,-/7-0 g� ' , • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1 HALLIBURTON I Sperry Drilling Services I I END OF WELL REPORT PIONEER NATURAL RESOURCES I ODSN- 40PB1, 40PB2, AND 40 I I I :..:;:. • • • yp •wR'Y“„ -' f x.H kaav� F. y' j y 1M1l r wK. . tt ' fi I 1. i .,,.....„...........idu 1 1 I Surface Data Logging Services I I 3b �A 1 1 TABLE OF CONTENTS 1 1. General Information 1 2. Daily Summary 1 3. Daily Operations (I.A.D.C.) 4. Morning Reports 1 5. Bit Record ' 6. Mud Reports 7. Show Reports 1 8. Formation Tops 1 9. Survey Report 10. Days vs Depth ' 11. Data CD ' 12. Formation Evaluation Logs 13. Engineering Log 1 HALLIBURTON 1 Sperry Drilling Services 1 1 1 1 1 GENERAL WELL INFORMATION I Company: Rig: Pioneer Natural Resources AK Nabors 19AC Well: ODSN- 40PB1, ODSN -40PB2 & ODSN -40 I Field: Oooguruk Borough: North Slope Borough State: Alaska I Country: United States API Number: 50- 703 - 20571 -70; 50- 703 - 20571 -71 & 50- 703 - 20571 -00 Sperry -Sun Job Number: AK -AM- 0005710855 I Job Start Date: 7 May 2008 Spud Date: 7 May 2008 Total Depth: PB1 06 Jun 2008 at MD 8764.0, TVD 5348.0, 09:30 hrs I Total Depth: PB2 04 Jul 2008 at MD 13359.0, TVD 6108.0, 10:10 hrs Total Depth: ODSN -40 16 Jul 2008 at MD 18364.0, TVD 6160.4, 09:10 hrs North Reference: True I Declination: 22.549° Dip Angle: 80.882° Total Field Strength: 57624 nT I Date Of Magnetic Data: 07 May 2008 Wellhead Coordinates N: North 70° 29' 45.13" Wellhead Coordinates W: West 150° 14' 47.40" 1 Drill Floor Elevation 57.5' Ground Elevation: 13.5' Permanent Datum: Mean Sea Level 1 SDL Engineers: Boyd Piercey, Tom Mansfield, Eugene Payne, Wayne Hermanson, Mark Lindloff and Doug Wilson Company Geologist: Jaque Ledbetter, Paul Cozma, Jim Stewart and John Pruit I Company Representatives: Rod Klepzig, Jeff Clarke, Jim Brown, Herb Hupperich and Sylvester Guszregan SSDS Unit Number: 123 I This report covers ODSN -40PB1 PB2 and ODSN -40. Loss ratios forced well planners to sidetrack from the original intermediate path drilled to 8,764', renaming it ODSN- 40PB1. A I cement plug was set and a sidetrack was made at 5100'. After continuing drilling operations on the production zone, it was determined the well path had climbed too high and it was feared that it had broken through the top of the production zone. A second side track was 1 performed at 12,950', leaving the former section from 12,950' to 13,359' renamed PB2. Drilling continued on the production zone to a final TD of 18,364', where completion work 1 commenced. HALLIBURTON 1 i Sperry Drilling Services 1 1 DAILY SUMMARY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 1 2_ DAILY SZJMMARY 1 Oooguruk ODSN -40PB 1 05/07/08 1 Prepare rig for rig move and move to ODSN -40. Prepare for drilling operations to commence while waiting on Gyro and other hands to get to the island. High winds and low visibility have hampered rig operations for the previous three days and a weather watch continues for today. Start picking up tool to start drilling rat I hole to allow room to pick up and test MWD tools. Start drilling rat hole to 226'. Rig up Gyro and logging equipment, pick up remaining BHA and prepare to resume drilling 12 -1/4" surface hole. 1 05/08/08 Directional drill 12 -1/4" hole from 226' to 568' when a ball of clay plugged the flow line. Rig shut down pumps and pulled back one stand. They continued to work at plugged section from rig floor with intermittent I attempts to flow the flow line. With clay percentages high in the returns, the possum belly and gas trap began flooding resulting in the loss of early gas data. Several other clay balls migrated to surface and had to be worked over and broken down, to prevent plugging the flow line again. Directional drill 12 -1/4" hole I from 568' to 979' and pump a high viscosity sweep to aid in hole cleaning. Problems with pumps and line blockages between CCU and RSC caused slow downs and shutdowns in drilling. Directional drill 12 -1/4" hole from 976' to 1,390'. Gas values remained low, ranging from 35 to 70 units with a maximum value of I 136 units observed. 05/09/08 I Directional drill 12 -1/4" surface hole section from 1,391' to 3,002'. Cuttings continued to build up in the possum belly flooding the gas trap causing fluctuations in actual numbers. Pump high viscosity sweep at 2,210' as per drilling program. Problems with RSC and CCU continue to slow drilling slightly. 1 05/10/08 Directional drill 12 -1/4" surface hole section from 3002' to 3090'. Pump another high viscosity sweep according to the drilling plan to help clean the hole of excess cuttings. Directional drill 12 -1/4" hole from 1 3,090' to 3,420' for TD of the surface section allowing approximately 89' for rat hole. Another high viscosity sweep was pumped at this stage and three bottoms up to clean the hole before tripping out for clean out run. Started tripping out of the hole and encountered tight sections around 2400'. Pumped while pulling one stand l and decided to pull without pumping. Pulling hard so pumps were turned on again to pull out of the tight area, for another stand. Pull next stands, slowly, without pumping, no issues or over pull. Continue pulling slowly monitoring for gains and or losses during the trip. Slight losses were observed but could be attributed I to spilling on the rig floor when breaking connections. Pull out of hole remainder of drill string, remove excess clay from tools and prepare to trip in for clean out run. Run in hole with clean out run experiencing tight sections and pumping in. Hole loaded up with cuttings blinding the shakers and pump rate was reduced. I Continue to wash and ream to bottom. 05/11/08 1 Continue with clean out run pumping three bottoms up and pulling out of the hole backreaming through tight spots. Some slight overpulls encountered. Pull out of hole to surface and lay down BHA. Read MWD tools and lay down. Prepare and rig up to run 9 -5/8" casing and perform rig maintenance. Start running 9 -5/8" I casing some tight sections required washing down. The start of the trip in gave very little to no displacement until stands 15 to 20 when the displacement started taking off. Continue running in hole to casing setting point at 3,412'. 1 05/12/08 1 1 DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 Transfer mud to RSC in preparation for cement job. Start pumping cement taking returns into pits 1 to 4 and transferring from there to CCU and onto RSC for processing. The cement job started with pumping 10 bbls of seawater and a pressure test to 3,500 psi was conducted. Cementing continued after a good line test, with ' mixing and pumping 40 bbls of spacer chased with 303 bbls of lead cement. After dropping the second plug, 43 bbls of tail cement was mixed and pumped down hole. The Cementers pumped an additional 10 bbls of seawater before the rig took over displacement, pumping 231.9 bbls of mud before slowing down to bump the plug with 10 additional bbls of mud. The plug was bumped, pressure was held and the floats checked. Floats held and cementing equipment rigged down. CCU starting to fill up too fast and asked the rig to slow down to avoid overflowing it. Displacement pumped out of pits 5, 6 and 7. Nipple down diverter and nipple up BOP's. 05/13/08 Continue with rig maintenance and start testing BOP's. With testing complete, cleaning pits ongoing in preparation for taking on oil -based mud. Start running in hole, pick up bit, geo pilot and MWD tools. Confidence testing MWD tools. Experinced technical difficulties and trouble shoot problem. Continue to ' run in hole and perform shallow hole test. Run in hole to 3,315', tag up. Place 10 klbs weight down. Slip and cut drilling line. Do a complete service on rig and continue running in hole. Tag cement to prepare for drilling. 05/14/08 Drill out cement and shoe then continue for 20' outside casing. Pull back into casing and perform FIT to 14.1 ppg EMW as per Company Man's directions. Monitor and plot the FIT. With good test, continue drilling ' intermediate section performing wiper trips every 1,000' or 12 hours. At 3,834' the CCU started filling up fast with the abundance of cuttings coming over the shakers and drilling operations ceased. A trip to the shoe was made in order to allow the backed up cuttings to be transferred to the RSC. ' 05/15/08 Drilling continued to 3890' where the CCU again became backed up with cuttings. Once again, a trip was ' made to the shoe while the backed up cuttings in the CCU were cleaned out and sent to the RSC. Drill to 4,081' before CCU requested the rig to stop drilling to allow them to catch up with the sending of cuttings to the RSC. Mud weight continues to climb as per weighting up plan to 10.1 ppg at 4,100', 10.4 ppg at 4,400' and so on. Cuttings amounts continue to play havic on the CCU, slowing drilling several times. Cuttings also played a role in gas numbers as the trap flooded and or was continuosly clogged with them. This result saw gas numbers fluctuating up and down as the trap was cleaned and plugged again, during the day. ' 05/16/08 Drill 8 -3/4" hole section from 4,965' to 5,470'. Circulate at 5,470' while repairing Geho pump hydraulic line. Drill from 5,470' to 6,168' and short trip back to 4,935'. Run in hole back to bottom and continue to drill 8- ' 3/4" hole section from 6,168' to 7,000'. Continue with weight up schedule per mud program for intermediate section. ' 05/17/08 Directional drill 8 -3/4" hole from 7,000' to 7,402'. Bottoms up was circulated and an open hole leak off test performed, which produced a leak off equivalent to 14.4 ppg EMW. Short trip from 7,402' to 6,198' and back to bottom, (went Extremely well). Continue to directional drill 8 -3/4" hole from 7,402' to 8,257'. Had lost circulation, with inital loss rate of 90 bbls in 15 minutes, decision made to mix and pump LCM Pill. ' 05/18/08 Spot 40 bbl LCM pill #1 and squeeze with 15 bbls over an interval. Directional drill 8 -3/4" hole from 8,257' to 8,351'. Mix and pump LCM pill #2 and intermittent squeeze with 30 bbls mud. Drill 8 -3/4" hole from 2 DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 8,351' to 8,435' with 240 bbls/hr losses. Pull out of hole to 3,384' and build 200 bbls MOBM and transfer to rig. Stage in hole with 12.0 ppg mud every +/- 1,000' to 8,351'. ' 05/19/08 Wash down from 8,351' to 8,434'. Attempt to drill ahead, to monitor loss rate and use cuttings to help seal losses. Directional drill 8 -3/4" hole from 8,434' to 8,441'. Decision made to suspend drilling and spot LCM pill #3. Pump 67.7 bbls of 12.0 ppg LCM pill and displace out bit plus 5 bbls. Total loss of pill while exiting bit and being spotted. Pull out of hole from 8,441' to 7,972', slowly, while monitoring for swabbing and hole filling - none experienced. Initiate Hesitation squeezes at 5 spm until break over seen and allow to bleed off ' to holding pressure over 'h hour. Work pipe each time to ensure no differential sticking and allow element to relax, before going down. The initial pressure was 50 -100 psi before break over and bled to zero. During course of squeezes, pressure increased to a max of 285 psi. The bleed back increased relative to break over value from zero -150 psi. Initial volumes pumped also increased from 1 -2 bbls pumped, to final 3 -5 bbls on squeezes. A total of 45.6 bbls of mud was pumped. Bleed off slowly with 1.65 bbls recovered. Open Annular and well bore static. Initialized circulation at 7,972' and worked string slowly. Experienced mud ' losses of approximately 17 bbls/hr. Adding 6 bag's per hour of Steel Seal and Barafiber to aid in sealing Torok fm. Losses. ' 05/20/08 Continued with the hesitation squeezing with no real success. Establish circulation at +1- 7,500' and run in hole from 7,500' to 7,905' and fifth loss circulation plug was prepared and pumped. The drillstring was positioned to allow for proper placement of the pill and displacement was so that the entire drillstring was ' displaced. Fluid was then bullheaded down the backside with the bag closed. Total losses for the pill amounted to 134.6 bbls, with 156.4 bbls displacement, 82 bbls of pill and returns of 101.8 bbls. With the bag closed the well was monitored for approximately 7 hours holding pressure while waiting for the pill to cure. ' Start circulating and staging pump rates while monitoring losses. Losses were low to non - existent at the lower rates but staged up as pump rates increased to 140 bbls per hour. Pump rates were lowered but losses continued at high rates ( -120 bbls/hr), so the decision was made to pull out of the hole from 7,905' to 3,087'. 05/21/08 Continue tripping out of the hole to surface. Lay down, rack back, and download BHA and MWD tools. Pressure test BOPs. Prepare to go back in the hole to pump cement to cure all losses. Run back in hole monitoring gains and or losses. Stop at 3400' and pump bottoms up at approximately 2000 strokes. Gas numbers of 30 units were observed at this time. Continue to trip in circulating bottoms up at 4,460', 5,503' , 6,551' and 6,745' with maximum trip gas of 40 units observed. Note: Condition MOBM to 11.5 ppg at each circulation. Total losses were 9 bbls. Hole in good shape. RSC started experiencing problems when the lost circulation material from pill 5 returned to surface. ' 05/22/08 Run in hole with BHA #3 from 6,745' to 7,900'to spot Turbo -Chem LCM Pill #6. Continue to circulate bottoms up every + / -1000' checking and reducing mud weight to 11.5 ppg. Stop at 7,900' and installed IBOP (Dart) valve on top of stand 67. Had large ball of cuttings from Form a Plug come back and plugged off Hammer mill. Circulate and observe well while cleaning pit for pill #1 and mix. Wash and ream to 8,730'. Circulate and condition mud, monitor losses. Try to drill with assembly. Drilled 1 foot and stopped. Performed LOT per schedule. Circulated hole, then pumped first pill plus 3 bbl spacer. Rotate and observe well while cleaning pit for the mixing pill #2. At TD circulate at 200 gpm noticed losses increasing so the decision was made to lower pump rate and observe losses, which increased to 10 plus bbls per hour. Pumping ceased and the well was monitored and gains were observed, pumping started again followed by monitoring again. At this point the well was observed to be flowing again and was shut in. Loss circulation pill number 6 was prepared during this time. 3 DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 ' 05/23/08 Work pipe with Swel LCM pill and spacer in pipe. Work on cleaning mix pit, preparation and mixing second EZ squeeze pill. Pump EZ Squeeze pill at 3 bbls /min and 500 -950 psi. Note: Had difficulty both ' mixing and pumping this pill as it was very thick. Pumped 71 bbls mud and chased with 14 bbls MOBM to have the pill below the first stand set back. Continued to pull out of hole pumping 84 strokes per stand to 6,530'. Pull out of hole from 6,530' to 3,406' and monitor well. Wait on orders for squeeze job. Pump i squeeze cycle #1. Squeeze 37 bbls at 6 spm and observe pressure build up to 203 psi and fall back to 170 psi at end. Continue to perform squeeze cycles every hour. During this time frame the psi increased from 196 to 190 on cycle 3, from 227 to 221 psi on cycle 4, from 212 to 195 on cycle 5. From 19:00 to 23:30 performed 2 squeezes with 2 hr wait time per consultation with Thermo Chem rep and Joe Polya. Cycle 6 went from 190 psi initial to 187 psi. Cycle 7 went from 194 psi inital to 189 psi for 2 bbls. Advised to pump the other 4 bbls if no increase in the first 2. Pumped lat 4 bbls with a slight increase of 193 psi after 2 bbls to ' 194 psi after 4 bbls. 05/24/08 Finish pumping last of squeeze jobs. Trip in hole from 3,407' to 7,026'. Hit tight spot and unable to circulate. Pull out of hole to 6,736' and regained circulation. Washed and reamed back down maintaining circulation until reaching 7,560' with partial returns. Run in hole from 7,320' to 7,560' on elevators. Unable to circulate at 7,560'. Pull out of hole from 7,560' to 7,320' and establish circulation. Wash and ream from 7,320' to 8,731'. Circulate hole at 2 bpm and 360 psi, monitoring losses. Shut down pumps and observe well breathing for 30 min, confirmed well is breathing. Pull out of hole from 8,731' to 8,100'. Stop circulating and pump 1st 20 bbls of 100 bbls mixed EZ squeeze pill from Halliburton and pumped into the drill string at 5- 20 bbls batches. Monitor well breathing at 1 bbl hr. Chase and spot the 100 bbl EZ pill with 40 bbls of MOBM. Trip in hole from 8,068' to 8,542'. 05/25/08 Trip in hole from 8,542' to 8,730', start pumping LCM EZ pill and pull out of hole to 8,740', while laying a total of 66 bbls in open hole. Close annular and start squeeze cycle 1 of 8, with a waiting period of 50 minutes between all cycles. Break circulation and condition mud at 2 bbls per min. Experienced losses over shaker after 15 minutes. Heavy amounts of LCM coming back, cut back rate to 2 bbl min while washing screens. Shut down pumping to clean and change shaker screens to minimize losses. 05/26/08 Circulate and condition mud at 4 to 7 bbl /min rates. Slow rate due to heavy concentration of LCM coming over shakers to control fluid losses. Changed shaker screens through process several times to minimize shaker losses. Work pipe from 7,840' to 7,750'. Start washing and reaming from 7,840' to 8,592'. Stage up flow rate as allowable for shakers. Wash and ream from 8,592' to 8,700' at 48 to 90 spm, 178 to 335 gpm, 575 to 800 psi, 50 rpm and 4 -5 k ft -lbs torque. No losses to hole, but slight losses over shakers. 05/27/08 Circulate at 8,731' with 375 -450 gpm, 1000 -1450 psi, 5 rpm and 4 k ft -lbs torque. Transfer 650 bbls of new MOBM from RSC to rig, send 524 bbls to RSC from rig to have cleaned up. Monitor well for 15 minutes, confirm well is breathing slightly. Pull out of hole from 8,731' to 8,535', monitor well 45 min for breathing. Continue to pull out of hole from 8,535' to 7,860' pumping out metal displacement only. Monitor well 20 minutes. Pull out of hole from 7,860' to 7,490' swabbing slightly. Pull out of hole from 7,490' to bit. No overpull or swabbing. Slip and cut 54' of drilling line. Service rig and top drive. Change out top drive torque booster, change oil, adjust link tilt and grabber. Test BOPE's per testing procedure. 05/28/08 Finish testing BOP's and related equipment. Pull BOP test plug and install wear bushing. Make up BHA #4, down load MWD and shallow test tools. Trip in hole from 662' to 3408'. Stage pumps up to 400 gpm and 4 ' DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 circulate bottoms up. Trip in the hole from 3408' to 5500'. Stage pumps up and circulate bottoms up. Trip in hole from 5500' to 6690', tag obstruction with 25 klbs WOB. Break circulation and stage pumps up to 340 gpm with good detection by MWD, with 12.03 ppg ECD. Wash through obstruction and circulate bottoms up. Had significant increase in LCM (EZ Squeeze product). Initial pit volume 535 bbls, final pit volume 511 bbls. Observed well for flow back to 519 bbls, with each barrel back slowing. Trip in hole from 6690' to 7590'. Tagged obstruction with 25 klbs excess WOB. 05/29/08 Circulate at 7590' and staged pump rate from 168 gpm to 294 gpm with 1200 psi, 40 rpm and 6 k ft -lbs ' torque. Well packed off while circulating at 7586' with 15 klbs over pull. Set down 20 klbs with no pipe movement and low returns. Racked back 1 stand and attempted to pull on elevators with 75 klbs over pull and fired jars at 7530'. Make up top drive, break circulate and work up to 210 gpm, 700 psi, 40 rpm, 6 k ft- ' lbs torque and work through tight spot up to 7495'. Pumped 10 bbls LCM pill. Back ream from 7495' to 6690' with 210 gpm, 700 psi, 40 rpm and 6 k ft -lbs torque. Wash and ream from 6690' to 7550', well packed off. Staged pumps up to 375 gpm and wash through at 3 -5 ft/min. Well packed off at 7550' and lost 30 bbls. ' Observe well for flow back, had slower flow back of ballooned fluid and got back +/- 70% of lost fluid. Wash and ream from 7550' to 7970'. Staged pumps up to 300 gpm, 1,180 psi, 120 rpm and 5 -7 k ft -lbs torque. Wash at 3 -5 ft/min. 05/30/08 Circulate bottoms up at slow rate to minimize losses. Losing 10% at this rate. Observed well with pumps off 15 minutes to verify well ballooning fluid back and not flowing. Each barrel flow back slowed. Pump out of hole from 7,970' to 7,400' at 84 gpm and 40 rpm. Pull on elevators from 7,400' to 6,065'. Pump slug and monitor well to verify ballooning. Flow back slowed after initial slug fall. Pull out of hole on elevators from 6065' to 660'. Pull out of hole with BHA #4 and MWD/LWD equipment. Service top drive, blocks and crown. Wait on ghost reamer and SPS circulating sub. Make up 6 -1/8 bit, subs and stabilizers. Run in hole with bottom hole assembly #5 and 5" drill pipe from 584' to 3408'. Circulate and condition mud at 3408'. Stage pumps to 128 gpm, 160 psi, 40 rpm and 1 k ft -lbs torque. Cut mud to 11.3 ppg from 11.5 ppg with Arctic grade diesel. 05/31/08 Circulate and condition mud at 3408'. Monitor well for 15 minutes with a flow back less than 0.25 bbls. Run in hole from 3408' to 5000'. Circulate and condition oil base mud stage pumps up to 230 gpm and 440 psi. Lost 17 bbls while circulating and cutting mud weight to 11.3 ppg in and out. Run in holefrom 5000' to 7414'. Ream and wash from 7414' to 7900'. Drop ball to open ports in Centurion circulating sub. Spot 30 bbls MOBM, LCM pill and drop ball for CCV closure. Pull out of hole from 7900' to 7323'. Circulate at 400 gpm with no losses after initial 24 bbls. Slowed pumps to 70 spm and continued to pump while RSC mixed water based mud. Racked back 1 stand each 3 hours to keep from low siding hole per Directional Driller. 06/01/08 Circulate and condition mud while waiting on mud from RSC. Reciprocate pipe from 7038' to 7228'. Clean ' rig pits, mixed spacer pill. Wash and ream from 7228' to 7892' at 150 gpm, 325 psi, 120 rpm and 7 k ft-lbs torque - no losses. Displace well with 11.5 ppg KCL/Polymer mud. Pumped 20 bbls LVT, 40 bbls spacer, 498 bbls water based mud. Pull out of hole from 7892' to 6373' - well taking correct hole fill. 06/02/08 Trip out from 6373' to 5994' and displace mud with 123 bbls 11.5 ppg water base KCL/Polymer mud. Pull out of hole from 5994' to 4191' and displace well with 123 bbls water base mud. Pull out of hole from 4191' ' 11.5 water base mud. Clean pits and send oil base mud from rig 3405' and displace hole with 60 bbls 1 .5 ppg e p g pit to RSC for storage. Build mud volume in pits. Run in hole from 3432' to 7900'. Stage pumps up to 300 gpm and wash/ream from 7900' to 8461'. 5 1 DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 06/03/08 Wash from 8461' to 8651'. Circulate and cut mud weight from 11.7 to 11.5 ppg, wash and ream from 8651' to 8731'. Circulate and condition mud. Stage pumps to 400 gpm with no mud losses. Pull out of hole from ' 8731' to 7790'. Pump slug, pull out of hole and lay down BHA. Note: no drag, tight spots or swabbing and well took proper fill on trip out. Rig up and test BOP's. 06/04/08 Pick up new BHA. Trip in hole to 3,380'. Break circulation and fill pipe. Run in hole from 3,380' to 5,850' and encounter tight spots at 4,784', 4,838' and 5,400'. Stage pumps to 400 gpm and circulate. Run in hole ' from 5,850' to 7,721' and hit tight spot at 7,721'. Wash and ream from 7,721' to 8,730'. Well balloning from 7,721' to 8,300'. Well losing 140 bbls/hr from 8,300' to 8,730', pumping at 250 gpm. Note: Static losses 80 bbls/hr. Building 100 ppb LCM pill and building mud volume at RSC and pits. ' 06/05/08 Monitor well on trip tank. Static losses at 24 -42 bbls/hr. Build mud at RSC and build 75 bbl, 100 PPB LCM pill. Displace LCM Pill with 153 bbls of mud at a rate of 250 gpm with 400 psi. Close annular and attempt to pressure up to 400 psi on hesitation squeeze. Pump 8 bbls at 213 gpm with 235 psi. Shut pumps down, open annular work pipe and monitor well, static loss of 6 bbls in 10 min. Close annular and squeeze LCM pill. Pump 5 bbls at 1 - 2 bbls /min, 60 - 70 psi and hold pressure for 10 min. Total LCM squeezed away = 40 bbls. Stage pumps up to 350 gpm with 1350 psi. Losses estimated at 260 bbls/hr. Shut pump down and put well on trip tank and monitor. Static losses at 14 bbls/hr. Monitor well on trip tank, working pipe, cut mud weight from 11.5 to 11.0 ppg and mix LCM to active pits. Static Losses at 25 -35 bbls/hr. Directional drill 8 -3/4" hole from 8,731' to 8,746'. Hit hard spot at 8,745'. Stop drilling and build volume. Monitor well on trip tank, building volume at RSC and rig pits. Stand one stand back and work pipe. Static losses 10 - 25 bbls/hr. Total losses for 24 hrs 836 bbls. 06/06/08 Build new mud in the RSC and rig pits, in preparations for drilling ahead. Transfer 200 bbls from RSC to rig pits and continue to build another 400 bbls in RSC. Directional drill 8-3/4" hole section from 8,746' to 8,764' with a total of 510 bbls of mud lost while drilling ahead. Staged flow rate at 200 gpm= 950 psi, 450 gpm= 2,345 psi, 500 gpm= 2,650 psi, with 205 -240 bbls/hr loss rate. Suspend drilling, due to severe losses and pull back to 8,746' and spot 30 bbls Walnut sweep + 10 bbls LCM pill. Monitor well for flow back after pump shut down - 15 bbls return after 40 minutes. Well bore went to 9 -10 bbls/hr static losses. Pull out of hole with BHA #6 from 8,764' to 618'. Take ACAL readings between 7,100' to 7,080', 6,100' to 6,080', 5,100' to 5,080' and 4,100' to 4,080'. Lay down BHA #6. Oooguruk ODSN -40PB2 r 06/07/08 Finish laying down BHA. Open bottom pipe ram doors and change out to 4" drill pipe type rams. Close up ' and ensure ready to test same. Test BOP's and related equipment. Make up cementing assembly and run in hole to 3,409'. Establish circulation at 100 gpm and stage to 250 gpm. Circulate bottoms up at 250 gpm and cut mud weight from 11.0 ppg to 10.0 ppg in/out of hole, with very slight losses of 1 -2 bbls/hr. Trip in hole from 3,409' to 8,755'. Establish circulation at 100 gpm and stage to 250 gpm. Circulate bottoms up at 250 gpm and cut mud weight from 11.0 ppg to 10.0 ppg in/out of hole, with losses of 30 bbls/hr. Rig up to cement. Pump cement plug #1. Pull out of hole slowly from 8,755' to 7,795' - had 30 klbs overpull leaving bottom. 1 6 DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 06/08/08 Pull out of hole with cement string from 7,795' to 7,550' — no swabbing. Wait on cement for 500 psi compressive strength results, (approx. 6:00 hrs at 130° F test result). Consulted with HES and Town ODE, ' due to 94° F recorded BHT and decision made to wait on cement for an extra 2 hours. Establish circulation with 100 gpm =200 psi and staged to 200 gpm =350 psi. Wash down from 7,522 to 7,636'. At 7,636' (approximately 30' low from calculated cement top), tagged cement stringer, torque jumped to 14 k ft -lbs, pressure increased to 450 psi and 5 -6 klbs weight on Mule shoe. Picked up to re -tag and confirm, but fell off and continued to wash from 7,636 to 7,647', where tagged up again with similar parameters seen. Work up twice and tagged up at same depth to confirm cement top. Consulted with Town ODE with results. Circulate bottoms up at 250gpm, 395 psi and at 7,612' racked back one stand, with no mud losses observed. Pump cement plug #2 at 7,612'. Average flow rate pumping cement was 3.5 bbls /min, with 500 psi. Pull out of hole and lay down cementing assembly. Test BOP's. 06/09/08 Finish testing BOP's and related equipment. Pick up BHA #7 with Fresh Geo -Pilot bit, (FSF 2565 Z with 5x15's). Make up remainder of components accordingly and initialize MWD probe with out problems. Run in hole and shallow pulse test MWD. Finish making up BHA #7 and continue to run in hole to 3,400'. Fill pipe as required and test MWD. Shut down and flow check well as precaution for 10 minutes - static. Continue to run in hole from 3,400' to 5,047' with no problems. Break circulation and circulate bottoms up with 9.8 ppg mud weight in/out and received a large amount of cuttings with bottoms up (primary clays and siltstone), slowed pumps to 350 gpm until cleaned up. Ensure even mud weight for upcoming FIT. Open kill line and establish circulation to ensure no air in lines. Shut down pump and close top rams and pump at 10 spm down both sides for FIT with 9.8 ppg mud weight. Establish pre - calculated 711 psi to ensure 13.2 ppg EMW at 5,100' MD/3,990' TVD, with 14.4 ppg EMW at 2,998' TVD 9 -5/8" casing shoe depth. Prepare for side tracking operations. Establish drilling parameters for time drilling 8 -3/4" hole at 5,100' - Side Track point. Time drill at 1" per 2.5 minutes. 06/10/08 Time drill 8 -3/4" hole and side track from 5,119' to 5,123'. Attempt to increase ROP, with 6 -7 klbs WOB, but popped out of trough. Pull back to 5,123' and continue with 1 minute per inch rate from 5,123 to 5,129', but "at bit inclination" (ABI) indicated inclination was not decreasing as required. Decrease to 3 min per inch from 5,129' to 5,136', with ABI indicating 53.6 ° - 53.75 °. Continue to time drill Side Track to 5,145' at 3 min/in, where ABI indicating not advancing, (still 53.75 ° - 53.8 °). Consult Town ODE and decision made to attempt to push assembly with 4 -6 klbs WOB. Start slowly with 2 klbs increments and limit drum speed to reduce loading on assembly. Drill from 5,145' to 5,170' at reduced rate, where ABI showed 53.13 °. This indicated assembly side tracking off with out further problems. Directional drill 8 -3/4" hole from 5,170' to 5,427'. Swab on # 1 mud pump went out. Repair swab, circulate bottoms up and prepare for short trip. 06/11/08 Continue with short trip from 5,427' to 5,190' with out more than 10 -15 klbs over pull. Check flow — well static and run in hole to 5,427' with no issues. Hole took proper fill on way out, (no swabbing experienced), and proper displacement on way in. Directional drill 8 -3/4" hole section from 5,427' to 6470' (planned short trip point). Circulate and condition hole for short trip. Short trip from 6,470' to 4,900'. Pulled three stands on elevators with 5 -10 klbs overpull. Then had excess overpull of 35 klbs and had to wash and back ream the rest of way out to 4,900'. Had large amount of cuttings over shakers during this operation. 06/12/08 Circulate bottoms up while reciprocating pipe from 5,047' to 4,950'. Hole unloaded a large amount of mostly clay materials with bottom up and continue to circulate until clean. Run in hole and take A -Cal data points on way in at designated intervals. Note: at 5,890' when attempting to get a A -Cal data points, tight spot ' encountered and slight pack -off experienced, no losses occurred. Circulate above tight zone and clear up 7 DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 problem. Run in hole and directional drill 8 -3/4" hole from 6,470' to 7,419'. Circulate three and a half bottoms up. Observed a lot of clays on shakers on bottoms up, which reduced significantly. Wiper trip from 7,419' to 7,224'. ' 06/13/08 Wiper trip from 7,224' to 6,940', pulling on elevators with 30 klbs and slight swabbing. Make up top drive and pump out from 6,940' to 6,375' with 400 gpm and 1,405 psi. Attempt to pull on elevator at 6,455' with 35 klbs over pull and slight swabbing. No further problems seen while pumping out to 6,375'. Circulate bottoms up and observed a large amount of clay based material across shakes on bottoms up. Run in hole from 6,375' to 7,419' without problems. Note: Take A -Cal reading while going back to bottom at 6,277'- 6,286'= 9.49" average, 6,644- 6,657' = 8.76" average and 7,024'- 7,040'= 9.95" average. Directional drill 8 -3/4" hole from 7,419' to 8,464'. The bottom of the Torok was intersected at 7,979'/5,279.1' . Well bore started to take fluid at 8,085' at an initial rate of 2 -3 bbls/hr. This was steady until +/- 8,300' where it increased to 10 bbls/hr. Circulate three and a half bottoms up and cleaned up hole. Wiper trip from 8,464' to 7,419'. Had over pull of 40 klbs and swabbing hole when starting off bottom. Back ream from 8,368' to 7,419' without further issues. Had an issue with both mud pump pressure relief discharging at same time. Lower IBOP rive showed it opened, but apparently did not. Continue to short trip out. Capable of using one pump at 90 spm while repairing each pumps pulsation dampners. 06/14/08 Wiper trip and back ream from 7,419' to 6,755' and run in hole from 6,755' to 8,464' without problems. Take A -Cal data points at 7,486'- 7,499'= 9.30" average, 7,977'- 7,989'= 9.50" average and 8,318' - 8,329'= 9.86" average hole size. Directional drill 8 -3/4" hole from 8,464' to 8,585'. Start losing mud at 300 bbls/hr. Check for flow - well bore static. Decision made to attempt to drill ahead to uncover all of possible fault area. Cut flow to 450 gpm and 1,850 psi, but unable to drill ahead from 8,585' to 8,589'. Experinced 437 bbls loss. Suction pit was sucked down below usable pit level and pumps started to jack. Stop drilling. Mix and pump LCM pill. Mix a water caustic and second LCM pilll. Pump pill and and directional drill 8 -3/4" hole from 8,589' to 8,597'. Note: Water pill was pumped to aid possible bit balling, flushing into formation and tried mechanical aggravation also. Drilling hard spot from 8,589' to 8,591', used various parameters and took approximately 1.5 hrs to achieve, but once through, drilling took off. Losses were experienced ranging from 151 -0 bbls/hr. Also had 6,416 unit gas peak from 8590', prior to water pill down. Hole appeared to reach saturation point and losses inceased, with total losses at 560 bbls. Directional drill 8 -3/4" hole from 8,597' to 9,105'. Note: pump 10 bbls at 100 ppb LCM sweep every stand drilled. 06/15/08 Drilled 8 -3/4" hole from 9,105' to 9,316', just above HRZ. Attempt to pull on elevators, but experience 35 -40 klbs over pull and swabbing. Decision made to back ream out of hole. Back ream from 9,316' to 8,835'. Circulate three and a half bottoms up and back ream from 9,316' to 8,835' after attempting to pull on elevators with 30 -40 klbs over pull and swabbing. Change out gripper dies and continue to back ream from 8,835' to 4,804', where slight pack -offs seen. Circulate two bottoms up with abundant clay material across shaker. Continue to back ream out from 4,804' to 3,700' and observed high ECD's and packing off. Worked 1 pipe and pumps to get flow back. Continued into casing where a large cuttings bed was encountered. Pumped sweeps and circulated bottoms up. Pumped and back reamed out to 3,054'. Pull out of hole on elevators from 3,054' to 2,010'. 06/16/08 Finish trip out with BHA #7. Recover Nuke sources and down load MWD. Lay down tools as required and pulled wear ring. Set test plug and test BOP's per AOGCC requirements. Once BOP test completed, pull test plug and set wear ring. Service top drive and rig. Perform FIT to 14.8 ppg EMW at casing shoe= 2,998' TVD= 780 psi. Run in hole with BHA #8 to 3,345'. Slip and cut drilling line. Run in hole with BHA #8, ' from 3,345' to 5,899'. 8 1 DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 06/17/08 Run in hole with BHA #8 from 5,899' to 8,560' where a bridge was tagged with 20 klbs. Ream through bridge from 8,560' to 8,580' without difficulties. Pump 50 bbls Hi -Vis LCM pill and continue to wash down from 8,560' to 9,250' obtaining A -Cal data points at 8,727 - 8,739'= 10.26" average, 8,944' - 8,954'= 9.42" average and 9,114'- 9,124'= 10.34" average sizes 4'. Circulate and reciprocate pipe from 9,250' to 9,316' while performing mud weight -up schedule from 9.7 ppg to 11.0 ppg. Directional drill 8 -3/4" hole from 9,316' to 9,585'. Note: The Top of HRZ formation came in at 9,317'. 06/18/08 Drill 8 -3/4" Hole, 9,598' to 9,883'. Pump 30 bbls HiVis sweep and circulate three bottoms up. Pump out, from 9,883' to 9,220'. Run in hole to 9,314' and attempt to get A -Cal data points - tool plugged off. Run in hole to 9,883' without issues and mode switch MWD. Directional drill 8 -3/4" hole from 9,883' to 10,453'. Circulate three bottoms up for short trip. Monitor well - static. Short trip from 10,453' to 10,258'. Note: over pull of 40 klbs on second stand, therefore pump out at 320 gpm and no rotation. 06/19/08 Continue to Back ream out of hole from 10,258' to 9,883'. Experienced pack off /tight hole events between 10,258' to 10,073'. Circulate bottoms up and weight mud up to 11.5 ppg. Ream/wash from 9,772' to 10,453', with some slight pack off events from 10,263' to 10,453'. Directional drill 8 -3/4" hole from 10,453' to 10,690'. Note: Had 1045 units of connection gas with bottoms up at 10,206'. 06/20/08 Directional drill 8 -3/4" hole from 10,690' to 10,927' combating hole losses. Pulled one stand and circulated and mixed volume. Pumped 100 bbls LCM pill at 100 ppb, spotted and sqeezed pill at 2 bbl increments for a total of 40 bbls squeezed. Run in hole washing to bottom and directional drill 8 -3/4" hole from 10,927' to 11,016' and circulate up sample. Directional drill 8 -3/4" hole from 11,016' to 11,100' for TD of intemediate hole. Nuiqsit top picked at 10,918'. Circulate hole for short trip. Monitor well and start short trip, pulled first 4 -3/4 stands on elevator with 35 -40 klbs over pull. Hit tight spot at 10,698' to 10,648' and had to pump and back ream to 10,553'. Circulate bottoms up. 06/21/08 Pumped and back reamed from 10,737' to 10,548'. Pulled on elevators from 10,548' to 10,175' - tight hole, circulate and back ream, having pack -off issues, able to get free and work pipe to 10,073'. Pull on elevators to 9,883'. Run in hole to 11,100'. Perform A -Cal MAD pass through Kuparuk zone. Drilled 3' for casing rat hole. Monitor well for flow back issues and trip out to 9,985'. Build volume in preparation for circulating bottoms up. Hole flowing at 1.2 bbls/hr (breathing). Attempt to circulate bottoms up but hole losses were very high at 350 bbls/hr. Called town and advised them of situation. 06/22/08 Circulated at 200 gpm while preparing 100 ppb LCM pill at 10,073'. Spot pill, monitor well and pull out of hole to 8,790'. Circulated four bottoms up slowly increasing flow from 250 to 500 gpm. Monitored well 0.50 hours to confirm hole breathing. Continue to pull out of hole from 8,790' to 4,640'. Encountered tight spots or ledges and able to get past them using some pump and rotation, while never exceeding 75 klbs of over pull. 06/23/08 Pull out of hole from 4,665' to 3,337'. Circulate bottoms up at shoe while servicing top drive and rig. Run in hole from 3,337' to 5,426' and determined that pipe went back into old plug back hole. Pull up to 5,045' and wash/ream and finally get back into sidetrack hole. Trip in hole on elevators until MAD pass from 10,230' to 10,275' and pump at 150 gpm running at 1 foot/min. 1 9 1 DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 06/24/08 Run in hole from 10,358' to 11,103', reaming last 5' and stage up circulation to determine loss rates. Circulate at 300 gpm until bottom section of hole clean. Mix and spot lubricant pill on bottom. Mix 100 bbls of 100 ' ppb LCM pill. Monitor and confirm well breathing. Pull out of hole to 9,788'. Pump and spot 100 bbl LCM pill out bit. Pull out of hole to 8,746'. Circulate and condition mud and hole. Pull out of hole to 5,280'. Work top stabilizer and lower stabilizer/bit through window section. Pull out of hole to 4,094', then trip in hole to 5,232' and confirm re -entry into correct hole by pumping a survey. Pull out of hole to 4,760'. Hole and window area in great shape. Pull and pump metal displacement/volume swabbed only —6 bbls /std. Pulling on elevators at 4,851' with out swabbing and taking proper fill. 06/25/08 Pull out of hole from 4,760' to 3,337'. Circulate and condition mud. Trip out from 3,337' to 680'. Rack back HWDP, DC and lay down subs. Lay down BHA, remove Nukes and down load MWD. Lay down BHA, pull pulser, stand back MWD, break off bit and lay down Geo Pilot. Test BOP's and related equipment. Make up shoe track. Prepare to run 7" casing. ' 06/26/08 Make up and test float equipment. Run in hole with 7" 26 #, N -80 casing to shoe at 3,376'. Circulate casing volume and run in hole to 11045'. Make up hanger, tag obstruction at 11068', attempt to break circulation - ' no success. Lay down landing jont. 06/27/08 Install cement head and cement lines. Circulate casing volume, mix and pump cement, displace with rig pumps, test casing for 30 minutes with 3,500 psi. Close annular, wait on cement. Nipple down well head, set slips and pack off. Cut casing and test pack off to 4,300 psi for 10 minutes. Lay down landing joint and hanger. Change bales and install test plug. 06/28/08 Lay down 8 -3/4" BHA. Lay down 5" drill pipe from derrick. Pick up 96 joints 4" drill pipe. Repair Iron Rough Neck. Pull out of hole standing 32 stands of 4" drill pipe in derrick. Change upper and lower rams from 7" and 5" to 4" fixed. i 06/29/08 Finish change upper and lower rams to 4" fixed. Test BOPE, Make up 6 -1/8" steerable BHA. Shallow test MWD and Geo -Pilo. Pivk up 4" drill pipe singles from BHA to 8612'. 06/30/08 Finish picking up 4" drill pipe to 10833'. Wash to 10930'. Slip and cut drill line. Drill plugs, float equipment and cement. Clean out rat hole and drill 20' new formation. Perform FIT to 12.75 ppg MWE. Trouble shoot MWD detection and directional drill 6 -1/8" hole from 11,122' to 11,253'. 07/01/08 Directional drill 6 -1/8" hole from 11,253' to 11,508'. Continue troubleshooting MWD tools while drilling to 11,605'. Drill ahead to 11,991' and circulate and condition hole to lower ECDs and check hole cleaning. 07/02/08 Directional drill 6 -1/8" hole from 11,991' to 12,474' experiencing ECD's up to 13.5ppg. Circulate hole to lower ECD's. The decision was made to backream from 12,474' to 11,750'. Conduct Mad Pass and log section from 11,750' to 11,315' using 200 gpm flow, with 2500 psi observed at 50 rpm logging up at a rate of 50 ft/hr. 1 10 I DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 I 07/03/08 Finish with Mad Pass from 11,315' to 11,102'. Position pipe to clear top stabilizer out of shoe. Collecting torque and drag data points at 11,300', no pumps. Start circulating 2 bottoms up collecting torque and drag I data points at 11,300'. Pull up to the shoe and circulate while analyzing Mad Pass data. Run in hole from 11,025' to 12,474'. Drill from 12,474' to 13,053'. I 07/04/08 Directional drill 6 -1/8" hole from 13,053' to 13,211'. Stop drilling as per Geologists at 03:45. Circulate and work pipe while Geologist calls town with decision made to turn tool 180 degrees down and continue I drilling. Directional drill 6 -1/8" hole from 13,211' to 13,359'. Geo -Pilot not responding. Decision was made to pull out of hole. Circulate hole clean and continue to troubleshoot Geo - Pilot. Pull out of hole to 7,546' filling up driller's side of derrick with 4" DP. Rig up and start laying out 5" drill pipe to make room for 4" 1 and bottom hole assembly. 07/05/08 I Lay down 252 joints of 5" drill pipe. Pull out of hole from 7,553' with 4" drill pipe and rack back. Download MWD tools and lay out BHA # 9. Test BOP' s. Pick up bottom hole assembly #10 and load MWD tools. 1 Oooguruk ODSN -40 I 07/06/08 Continued to run in hole with bottom hole assembly #11, (8 -3/4" Geo Pilot Type), filling drill pipe and break circulation as required to 11,060'. Exit 7" casing and run in hole to 11,415' and begin Madd Pass of required I shale sections per Geologist request, (11,415' - 11,485'; 11,720' - 11,790; 11,870' - 11,980' and 12,110'- 12,202'). Experienced some pack -off and tight hole conditions at 12,202' and established circulation at 12,180- 12,088' and circulate bottoms up. Continue with Madd Pass from 12,180'- 12,340' and 12,560'- 12,680'. Wash and I ream from 12,680' to 12,732'. Experienced packoff problems at 12,380'- 12,387' and 12,547'- 12,558'. These sections were worked several times to achieve the desired goal. I 07/07/08 Continued to wash and ream bottom hole assembly #11 from 12,732'- 12,930'. Trough assembly from 12,930' - 12953', (01:00- 05:00), and start side track 12,953' - 12,966' At 5 -4 -3 min per inch rates. Control drill 12,966'- 12,978' at 5 -10 fph, and drill 6 -1/8" hole per Geo Steer request, and well plan #14 from 12,978' to 1 13,210'. 07/08/08 1 Drill from 14,197' to 14,340'. There was a change in formation at 14210' to 14230' indicated by higher torque which ranged from 12 -14 k ft -lbs. I 07/09/08 Directional drill 6 -1/8" lateral section from 14,197' to 15,161' per Geo Steer requests and well plan #14. No losses gains or abnormalities of any sort. Samples continue to consist mostly of very fine to fine grained I sandstone with gas values topping out around 3 to 500 units. Some connection gas has been observed at or near 200 units above background gas for the interval. I 07/10/08 Directional drill 6 -1/8" lateral section from 15,161' to 16,000'. 1 1 DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 07/11/08 Directional drill 6 -1/8" lateral section from 16,000' to 16,440' per Geo Steer requests and well plan #14. MWD experienced failure at 16,440' and unable to regain detection. The decision was made to pull out of hole back reaming out of the lateral section to 12,458'. 07/12/08 Pull out of hole, back reaming lateral section from 12,458' to +/- 11,023' and circulate 2 bottoms up. Slip and cut drilling line. Pump dry job and flow check well - static. Pull out of hole from 11,023' to 411'. Lay down MWD and Geo Pilot tools. Test BOP' s. 07/13/08 Continue to test blow out preventers. Pick up and make up bottom hole assembly #12, (6 -1/8" Geo Pilot Type), per MWD and DD, and run in hole picking up 39 joints new drill pipe from pipe shed. Run in hole with stands from derrick and lay down a total of 27 joints from various stands that had flat - sided wear. Continue to run in hole, filling pipe every +1- 3,000' and circulate 60 bbls to ensure MWD working and roll mud to warm same. Stop and replace wash pipe packing on top drive system at 9,083'. Continue to run in hole with assembly to 10,350' without further problems. 07/14/08 Run in hole with bottom hole assembly #12 to 12,070', where it became necessary to begin rotating assembly, due to negative weight conditions. Continue to wash and ream bottom hole assembly #12 into well bore from 12,070' - 16,430'. Finish circulating bottoms up to check samples for shale cuttings, (ok). Directional drill 6- 1/8" lateral section from 16,440' to 17,108' per Geo Steer requests and well plan #14. 07/15/08 Directional drill 6 -1/8" lateral section from 17,108' to 17,978' per Geo Steer requests and well plan #14. Experiencing losses of 4 -12 bbls per hour. Total losses for the day 140 bbls and total losses for lateral section 164 bbls. 1 07/16/08 Directional drill 6 -1/8" lateral section from 17,978' to 18,364' per Geo Steer requests and well plan #14, (TD called at 18,364" by Town Geology group). Experienced losses at 2 -8 bbls per hour. Total losses for the day 64 bbls and total losses for lateral section 228 bbls. 07/17/08 Continue to back ream bottom hole assembly #11 out of lateral section, 14,406' - 11,026'. Parameters indicated loss of part of bottom hole assembly at approx. 11,710' bit depth. Circulate 2 bottoms up at 375 gpm and pull out of hole to inspect loss area. Lay down 13 joints between stands #33 -23, where a failed box was found on XT -39 drill pipe. Pick up and run in hole 9, 4 -3/4" drill collars and rack back. Pick up and make up bottom hole assembly #12, (Fishing Type), and run in hole, strapping in with same to 884'. Lay down questionable bad drill pipe. 07/18/08 Trip in hole fishing for bottom hole assembly #12. Tag fish at 9,028', latch onto fish circulating at 100 gpm, saw 400 psi increase when engaging fish. Pull on fish slowly up to 230 klbs over pull then slacking off, increase pump rate to 200 gpm and 2,000 psi. Pull on fish slowly to 240 klbs over pull, fish relinquished it's hold and coming up. Pull out of hole with fish. Lay down drill collars, fishing tools, fish with overshot attached and 35 joints of bad drill pipe. 1 12 i DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 07/19/08 Finish laying down top of bottom hole assembly, pull nuclear sources and down load MWD. F inish laying down rest of bottom hole assembly. Lay down fish and Jars. Pick up liner running tools. Pick and make up shoe, run 36 joints of solid and slotted liner and packer/hanger per plan. Make up scraper running assembly on top of hanger and run in hole on 4" drill pipe rabbitting / SLM each stand. Slip and cut drilling line and service rig. Continue running in hole with liner on 4" drill pipe to 8,737'. 07/20/08 Run in hole with 4 1/2" liner on 4" drill pipe to 12,416'. Drop ball and pick up single. Make up top drive system and measure in 10' (12,416 TDS / 10,936' TOL) on single pumping ball down at 20 spm, 650 psi for 972 strokes. Pressure up to 1200 psi and ball seated. Pressure up to 2000 psi, set hanger, pressure up to 2700 psi to shear dogs on packer. Attempt to pull out of tie back, unsuccessful. Set 30 klbs down to set packer and put left hand torque in drill pipe to un-jay and release setting tool. Worked a couple times to confirm. Displace well with 10.2 ppg brine. Pump 3 scrubbing spacers prior to displacing well with 367 bbis of brine. Pull out of hole and lay down drill pipe. Tested choke manifold on the way out. Losses to hole for 24 hrs 9.0 bbls. Total lateral hole losses 264 bbls. 07/21/08 Lay down hanger and packer assembly, lay down 4 1/2" liner, had tong failure, change out tongs, finish laying down liner. Test BOP' s. Pick up, make up and run 4 1/2" liner. Make up crossover to XT39. Pick up drill pipe 30 joints at a time then stand back in derrick. Drift each joint. Losses to hole for 24 hrs 7.0 bbis, total lateral hole losses 271 bbls. 07/22/08 Finish racking back stands drill pipe in derrick. pick up and make up crossover, hanger, packer, and bumper jars on to liner. Run in hole with liner on 4" drill pipe, SLM each stand to 12,416'. Check string weight, and drop ball. Pump ball to packer at 20spm, pressure up and set hanger, then shear circulating sleeve. Pick up 6', see free travel, set packer with 50klbs and repeat. EOL = 12,416', TOL = 10,937'. Circ and condition brine 2 bottoms up and pull out of hole laying down 4" drill pipe. Losses to hole for 24 hrs 7.0 bbis. Total lateral hole losses 278 bbis. 07/23/08 Finish laying down 4" drill pipe. Pull the wear bushing and pick up the test plug and rig up test equipment. Change upper rams to 2 7/8 ". Attempt to test Annular with no success. Pick up Johnny Whacker and circulate stack clean. Pick up new test joint due to old joint being bent and attempt to re -test annular, test failed. Lay down test joint, drain stack and inspect annular and found to be bad. Rig up to remove annular rubber and remove same. Replace annular rubber and test annular and upper pipe rams, tested ok. Rig up to run 2 7/8" tubing, service ESP downhole Pump. 07/24/08 Service ESP Downhole Pump. Finish hanging control line sheaves. Install control line and clamps. Test ESP and control lines. Install XN nipple and install sliding sleeve and run in the closed position. Run ESP completion on 2 -7/8" tubing. RIH from 63' to 6,300'. Installed GLM dummy at 1,09' and X Nipple above packer. Splice control cable and test the same to 5000 psi. Cycle test ESP vent valve. RIH with 4,000 psi on control line. Resume RIH with 2 -7/8" ESP completion from 6,300' to 6,825' 07/25/08 RIH with 2 -7/8" ESP Completion from 6,825' to 8,061'. Test cable every 1000' and install Cannon Clamps on every other joint. Install GLM with Dummy Valve at 6,830'. Stop at 8,061' and splice together new control cable for ESP Pump. Resume RIH from 8,061' to 10,757'. Stop at 10,045' and install the SCSSV valve and test lines. Pick up tubing hanger and attach ESP cable. Land tubing hanger. Run in lock down screws and 13 DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 test seal to 5000 psi for 10 min. Change rams from 2 -7/8" to 5 ". Lay down running tool and rig down tubing running tools along with sheaves in the derrick. Nipple down BOP's. Spot Slick Line unit. 07/26/08 Test SCSSV and vent line to 5000 psi. Test tee to 5,000 psi. Remove TWC. Rig up test circulating manifold and lines to 4,000 psi. Reverse circulate 85 bbls 10.2 ppg brine with corrosion inhibitor followed by 70 bbls diesel (freeze protect) at 2.5 bbls /min and 1,475 psi. Lost 60 bbls while pumping brine and 50 bbls while while pumping diesel. U -tube freeze protect from inner annulus to tubing. Note: u- tubing very slowly if at all. Bullhead 10 bbls diesel down tubing at 1/2 bbl /min at 2,175 psi. Shut in well with 1,500 psi on both sides. Drop 1 -3/8" ball and rod. Pump down tubing and set packer with 3,500 psi. Chart and held 30 min. Bleed pressure down to 1,500 psi. Pump down backside and test packer with 3,500 psi. Slowly bleed off to 2,900 psi. Pressure back up to 3,500 psi. Still bleeding off. Bleed annulus pressure down to 1,400 psi. Pressure back up on annulus to 3,900 psi to reset packer. Bleed down. Pressure up on annulus to 3,500 psi. Still bleeding down. Bleed Annulus pressure down to 0 psi. Pressure up on annulus to 3,900 psi. Tubing still bleeding down. Rig up single line to annulus to pressure up. Bleed annulus pressure down to 0 psi. Pressure up on annulus to 4,000 psi. Annulus still bleeding down. Bleed annulus pressure down to 0 psi. Pressure up on annulus to 4,500 psi. Annulus still bleeding down. Note: 8 attempts were made to get a test and surface equipment was double checked. Shut well in with 1325 psi on annulus and holding and 1200 psi on tubing. Rig up slick line and hang sheaves. Prepare floor in preperation for pulling production string. 07/27/08 Finish rigging up Slick Line Unit - tools arrived at 00:30 hrs. Test lubricator to 2,000 psi. RIH with 2.313" PX plug body and set at 4,483'. Annulus holding at 1,325 psi and tubing 1,200 psi. Set P Prong on top of PX body. Retrieve dummy from GLM at 3,973'. Circulate down tubing taking return up inner annulus and displace diesel from annulus. Reverse circulate 1 tubing vol. Shut in well both sides pressured up to 100 psi in 30 min. Rig up dummy setting tool and reset blank in GLM. Pull P- Prong, PX body, retrieve rod and ball and pull RSC Plug. ' 07/28/08 Attempt to pressure up inner annulus. Started to bring pressure up 1450 psi and lost 150 psi. Bring pressure back up to 1500 psi. Close in and observe pressures. Losing 100 psi/min. Bleed pressure off. Rig up Sliding sleeve shifting tool and RIH to 748'. Tool hitting hard. POOH and pick up Gauge tool to check on passage thru SCSSV valve. Gauge run was succesful. Found keys on shifting tool were not passing lock out sleave in SCSSV valve. Re -run shifting tool and able to pass on second run. RIH to 10,648' to the XD sliding sleeve and work on shifting sleeve. POOH to add additional weight bars. At 04:30 inner annulus pressure= 0 and tubing pressure= 0. Add additonal weight bar and RIH with same. Attempt to open sliding sleeve - unsuccesful. POOH with slickline. ESP pressure = 3,250 psi. Inner annulus = 0 psi. Open packer vent valve. ESP = 3,245 psi. Pressure up inner annulus to 100 psi. ESP = 3,313 psi. Shut in. Bleed down rate 5 psi/min both sides. Bleed down all pressures. Close packer vent line. Rig down slickline lubricator and equipment. Close SSSV and set BPV. Nipple down tree. 07/29/08 Test BOP's to 250 low / 3500 high. Witness waived by Lou Gimaldi of AOGCC. Move Slick line unit out of way and place ESP unit. Rig up floor with tongs, spooling units and sheaves for pulling ESP production string. Finished testing BOPE. Pick up 5" DP (18 stands) and stand back in derrick (to be used for backstop for the 2 -7/8" tubing which will be racked back in the derrick 011 the trip out of the hole). Rig up Centrilift, Halliburton's and Nabor's tubing handling equipment. Pick up and make up landing joint and pull packer free with 108,000 lbs string weight, 33,000 lbs overpull. Let packer element relax and monitor well. Well static. Pull hanger to rig floor. Check connection to ESP - good. Connect SS control lines to spooling unit. POOH with 2 -7/8" tubing and connect ESP cable to spooler. POOH, lay out SCSSV Valve and GLM. 14 1 DAILY SUMMAY Oooguruk ODSN- 40PB1, ODSN -40PB2 and Oooguruk ODSN -40 1 1 1 a il 1 1 1 1 1 1 1 1 1 1 1 1 1 1 15 1 DAILY ACTIVITY Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 3_ DAILY ACTIVITY Time Elapsed Operations Breakdown ' (hrs) Time Oooguruk ODSN -40PB 1 ' 05/07/2008 00:00-03:30 3.50 Rig down freeze protect, putz & cuttings lines. 03:30-05:00 1.50 Prepare rig to move. 05:00 -06:00 1.00 Skid Rig to ODSN -40. 06:00 -07:30 1.50 Rig up lines in hutz & Putz, rig up skate & beaver slide, rig accepted at 07:30. 07:30 -10:00 2.50 Nipple up starting head, drill riser & test starting head to 500 psi for 10 min. 10:00 -12:00 2.00 Change out top drive lube filter & prepare rig floor for pick up BHA. 12:00 -14:30 2.50 Make up bit, motor, float sub & stabilizer. ' 14:30 -15:00 0.50 Fill up lines an pump thru motor & check rig for leaks. 15:00 -16:00 1.00 Clean out conductor from 71' to 153' using 450 gpm at 150 psi, 40 rpm with 1 -2k ft -Ibs torque. 16:00 -17:30 1.50 Drilling 12 -1/4" hole from 153' to 225'. 17:30 -18:00 0.50 Stand back 2 stands of HWDP in order to build BHA. 18:00 -19:30 1.50 Rig up Gyro Survey equipment on floor & over ODSN 391. 19:30 -20:00 0.50 Service rig. 20:00 -22:30 2.50 Pick up BHA #1 & load EM probe & orient. 22:30 -23:00 0.50 Wash & ream from 193' to 226'. 23:00 -24:00 1.00 Directional drill 12 -1/4" hole from 226' to 266' taking Gyro Surveys. ' 05/08/2008 00:00 -05:30 5.50 Directional drill 12 -1/4" hole from 266' to 568'. Run Gyro surveys at connection. MWD problems from 500' to 530'. 05:30-07:30 2.00 Clean gumbo out of riser & flow line. 07:30 -10:30 3.00 Directional drill 12 -1/4" hole from 568' to 667'. Gyro survey at connections. 10:30 -12:30 2.00 Circ & cond hole when high line power lost. Wait for HES -RSC to regain power. Clear cuttings line 12 hrs. 12:30 -17:30 5.00 Directional drill 12 -1/4" hole from 667' to 976'. ' 17:30 -18:00 0.50 CCU down, clrc & cond mud. 18:00 -24:00 6.00 Directional drill 12 -1/4" hole from 976' to 1390'. Pump sweep at 1000'. 05/09/2008 00:00 -01:30 1.50 Directional drill 12 -1/4" hole from 1,390' to 1,484'. Gyro survey at connections. 01:30 -02:30 1.00 Circ while trying to receive IFR surveys. BP cut power to field due to fire at GC1. IFR power was interrupted due to this incident. After talking to Sperry & determining that we were out of critical close approach, decision was made to drill ahead using uncorrected MWD surveys. 02:30 -12:00 9.50 Directional drill 12 -1/4" hole from 1,484' to 2,243'. Gyro survey taken at 1,486'. Rig down Gyro. Pump 60 bbl sweep at 2,000'. 12:00 -24:00 12.00 Directional drill 12 -1/4" hole from 2,243' to 3,003'. Gyro survey taken at 1,486'. 05/10/2008 00:00 -07:30 7.50 Directional drill 12 -1/4" hole from 3,003' to 3,420'. Pump 60 bbls sweep at 3,038'. 07:30 -10:00 2.50 Circ 3.5 bottoms up at 750gpm & 1,950psi. Rack back 1 stand per hour to avoid washing bottom of hole, from 412' to 3,098', (large amount of clay returns seen across shakers & cleaned up). 10:00 -11:00 1.00 POOH with BHA #1 from 3,098'to 2,425'. Some 50 klbs over pull & swabbing seen at 2,390' & decision made to back ream out of hole. ' 11:00 -12:00 1.00 Back ream with 90 rpm, 750 gpm & 1,925 psi. Work pipe from 2,390' to 2,243', with no circ or rotating on final wipes. Circ bottoms up at final stand with abundant clay material observed. 12:00 -17:30 5.50 Continue to POOH from 2,243' to bit with 10-30K over 2,220'- 1,855' & no swabbing. POOH. Note: Stab = 90% packed off with clay material & string IBS =30% (clean off same). 17:30 -18:00 0.50 Clean rig floor. ' 18:00 -20:00 2.00 RIH to 220' - work through tight spot just out of casing (30klbs down wt). RIH from 220' to 1,528'. Hole becoming sticky with 30 klbs down wt. 20:00 -20:30 0.50 Wash & ream from 1,434' to 1,528' with 450 gpm. Hole unloaded a large amount of cuttings blinding the shakers, reduced pumps to 400 gpm & let hole clean up. 20:30 -21:30 1.00 RIH on elevators from 1,528' to 2,215'. Hit tight spot with 35 klbs down wt. 21:30 -22:00 0.50 Wash & ream from 2,215' to 2,287' using 400 gpm, 850 psi & 30 rpm. 22:00 -22:30 0.50 RIH on elevators from 2,287' to 2,381'. Hit tight spot 30 klbs down wt. Wash & ream using 400 gpm with 850 psi. 22:30 -23:30 1.00 RIH on elevators from 2,381' to 3,288'. 23:30 -24:00 0.50 Wash & ream from 3,288' to 3,383' using 500 gpm with 1000 psi & rotating at 100 rpm. 1 1 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time (hrs) Elapsed Operations Breakdown Time 05/11/2008 00:00 -00:30 0.50 Wash & clean from 3,383' to 3,420' with 500 gpm, 1,120 psi, 90 rpm, 5 k ft-Ibs torque & 1 -5 klbs WOB, (no problems encountered getting to bottom). 00:30 -02:00 1.50 Circ bottoms up 3.0x at 750 gpm, 1,770psi & 100 rpm & 3.5 k ft -Ibs torque off bottom. Rack back a stand every hr. Hole appeared clean & decision made to POOH for 9 -5/8" casing. 02:00-06:00 4.00 Hoist BHA #1 for 9 -5/8" surface casing from 3,305' to 630', with no swabbing experienced, (3,290'= 40 klbs over & 2,050'= 35 klbs over). 06:00 -10:00 4.00 Rack back HWDP in derrick & lay down 3 non -mag flex collars. Read MWD probe & lay down same, along with bit & motor. Note: Bit was 60 -80% packed -off with clays, as was motor stab. Graded bit: 2- 3- FC- A- E- 1- NO -TD. 10:00 -10:30 0.50 Clean & clear floor of all unnecessary tools & equipment. 10:30 -14:00 3.50 Rig up floor for running 9 -5/8" casing. Cross over bails to long type on top drive & make up Franks fill up tool. Continue to rig up all required tools for same. PJSM for same, with all related services. 14:00 -22:30 8.50 Pick up 9 -5/8" shoe track joint & RIH with same. Baker loc all required connection for shoe track assembly, per program. Test float equipment, per SOP, (held OK). Witness loading of cement head with plug #1. Continue to RIH with 9 -5/8" casing per program, 165' - 3,364'. Ensure proper fill ups every 5 joints & proper returns. Had to Circ at 3,037 - 3,079' & 3,228'- 3,268' due to tight conditions. Pick up wt 195 klbs, slack off wt 125 klbs. Make up hanger & RIH from 3,364' to 3,410' where we landed out. 22:30 -24:00 1.50 Drain stack & ensure land out of hanger. PJSM, rig down casing equipment. 05/12/2008 00:00 -00:30 0.50 Drain out riser to confirm landing depth of casing hanger. 00:30 -01:00 0.50 Finish laying down Franks tool & make up HES 9 -5/8" cement head. 01:00 -05:00 4.00 Stage up circ from 5 to 10 bbls/min, per circ schedule, (10bbls/min= 2,170psi), with full returns. Note: hole clean & not much seen across shakers. Attempt to reciprocate casing, but taking 40-50 klbs without breaking over, (leave landed in the Load Shoulder), with casing shoe depth of 3,408.75'. 05:00 -07:30 2.50 PJSM with all related services. Pump 10 bbls sea water spacer, (3 bbls to fill lines from RSC to rig). Pressure test cement lines to 3,500psi - ok. Drop plug #1 with 1 bbl of 10.0 ppg spacer. Bleed off pres & load plug #2 & #3. Pump 39 bbls of 10.0 ppg dual at average 2.5 bbls/min & 470 psi. Mix & pump 303 bbls of 10.7 ppg "Type L" lead cement with average 4.5 bbis/min displacement rate at 500 psi. Drop plug #2 & mix/pump 43 bbls 15.6 ppg "Type G" tail cement at 4.5 bbls/min 7 900 psi. Drop plug #3 & displace with 10 bbls sea water. Shut down & line up on rig pump & continue to displace with rig pumps at 7.61 bbls/min for 2,000 strokes. ICP= 1,230psi at 20% flow & FCP =1,520 psi at 32% flow), with cement seen at surface after 1,760 strokes. Continue to pump at 6 bbls/min for 2,700 strokes & 1,300 psi at 26% flow rate, & slow to 4 bbls/min =960 psi at 16% flow rate, (Bump plugs at 2,905 strokes = 18 strokes over calc & hold 1,400 psi for 2 min's - OK). Release pres & check floats - ok. Cement in place at 07:31 hrs, with 100 bbls cement returns at surface. Note: had to divert 50 bbls to pit & treat with citric acid as CCU unable to handle same. 07:30 -10:00 2.50 Rig down 9 -5/8" casing running equipment & lay down Vetco Gray landing tools. 10:00 -12:00 2.00 Pick up riser washing tool & wash out riser. 12:00 -17:00 5.00 Nipple down drilling riser. Nipple up well head & test to 5000 psi for 15 min - OK. 17:00 -24:00 7.00 Nipple Up BOP's, Change out top & lower rams to 5 ". 05/13/2008 00:00 01:00 1.00 Nipple up BOP stack & change out pipe rams to 5" size. 01:00 03:00 2.00 Pick up & make up Vetco Gray testing joint, with required crossovers. Install test plug for testing BOPE. 03:00 09:30 6.50 Test BOPE per AOGCC requirements, (Mr. Jeff Jones waived witness). Test annular preventer, (250psi h Low with 2 500 psi High). Continue to test all BOP stack components, choke manifold valves top � P 9) P drive I -BOP valve/manual valve & all floor valves per NAD test procedure to 250 psi low with 3,500 psi high. Had problem with rental TIW valve - leak around Hex wrench seal. Lay down TIW valve & get replacement from NAD sent out, (had backup on location - tested OK). Function test accumulator system, per AOGCC requirements - OK. Function test gas detection alarms & LEL - OK. Pull Vetco Gray test plug & Install wear bushings. Lay down testing equipment. 09:30 10:30 1.00 Pump 3 bbls water through kill line to ensure lines/stack free of air. Close blind rams & test 9 -5/8" casing to 3,600 psi for 0.5 hr - chart same. ISIP =3,600 psi & FSIP= 3,480psi, (3.33% drop - good test). Bleed off same, rig down test equipment & blow down lines. Line up valves for drilling operations. 10:3011:00 0.50 Seal up cracks in rotary table prior to taking on OBM. 11:00 13:30 2.50 Pick up bit, Geo- Pilot, NM flex joint, A/C sub, EWR, smart stab, HCIM /PWD /DGR & density neutron. 13:30 16:00 2.50 Load MWD tool & check all connections. 16:00 17:30 1.50 Shallow hole test MWD at 530 gpm with 575 psi. Tools tested OK. 17:30 18:30 1.00 Conduct PJSM on loading radioactive sources. Load sources. 18:30 19:30 1.00 Finish picking up rest of BHA #2. 19:30 22:30 3.00 RIH from 664' to 3,315' where pipe started taking weight. Set 10 klbs weight down & pick up to 3,224'. 22:30 00:00 1.50 Service crown, top Drive, check bolts in derrick & draw works. 05/14/2008 00:00 -01:30 1.50 Slip & cut drilling line per NAD tool push requirements. 01:30-04:30 3.00 Transfer MOBM from RSC to rig pits, (Sim Op's: change out top drum cutter on hammer mill). Once ready, displace sea water from well bore to fresh 9.6 ppg MOBM at 425 gpm flow rate & 1,320 psi, (had 40 bbls interface), & transfer well bore fluid to RSC. 2 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 I Time (hrs) Elapsed Operations Breakdown Time 04:30 -09:30 5.00 Commence drill out of plug rubbers at 3,321', flow check at 3,323', cement at 3,323- 3,407' & 9 -5/8" I casing shoe at 3,408.75' MD, (2,998.01' TVD). Ream/Dress shoe 3x, to ensure full gauge. Clean out 12- 1/4" rat hole from 3,408.8' to 3,420'. 09:30 -10:00 0.50 Directional drill 8 -3/4" hole from 3,420 to 3,440' for 20' new hole in preparations for LOT. 10:00 -11:00 1.00 Circ bottoms up for LOT. Pull back into casing from 3,440' to 3,406'. 11:00 -12:00 1.00 Open kill line & pump 5 bbls both ways to clear air from lines. Shut in top pipe rams & perform LOT I with 9.6 ppg MW, 705 psi for an EMW =14.1 ppg. Pumped 1.78 bbls & recovered 1.5 bbls, when bleed off pres. Call in results to town ODE while rigging down test equipment & prepare to drill ahead. 12:00 -17:00 5.00 Directional drill 8 -3/4" hole from 3440' to 3833'. 17:00 -18:00 1.00 Circ & cond hole while waiting on RSC to get equipment running. Decision made to wiper trip back I into casing, as RSC unable to fix plugging problem in short amount of time. 18:00 -19:00 1.00 Short trip from 3,833' to 3,386' with out problems. Wait on RSC to clear CCU hopper, cuttings return line & change out lower blades on hammer mill. Note: CCU hopper had approx 40 bbls of cuttings packed off on top of pump suction. 19:00 -21:00 2.00 RSC continue to work on getting CCU hopper unplug, (rocked cuttings line from backside with air & 1 unplug) & pulled covers off hammer mill & unplug upper & lower sections. RSC reported that they had CCU cutting line cleared up & hammer mill unplugged. CCU hopper had cuttings tote rigged up to blow cuttings into, in event of plugging off again. 21:00 -21:30 0.50 Rig prepared to & RIH back to bottom with BHA #2 to 3,833' with out incidents from well bore. I 21:30 -22:30 1.00 RSC not quite ready, a few more issues but working hard to resolve issues. 22:30 -23:00 0.50 Directional drill 8-3/4" hole from 3,833' to 3,890'. Discovered that CCU pump having issues again, as blockage of hopper suction was not cleaned out properly & building up cuttings in hopper. Unable to clear cuttings buildup inside hopper. 23:00 -24:00 1.00 Circ & cond hole while deciding how to best address RSC issues. Found that the hopper above the I pump was totally packed off with 50 bbls worth of clays & cuttings. Made preparations to short trip to the shoe again, so RSC could get cuttings hopper discharge unplugged. 05/15/2008 I 00:00-00:30 0.50 POOH from 3,890' to 3,320' with out incidents, due to problems encountered with RSC's CCU unit & cuttings return line. 00:30 -06:30 6.00 Work on clearing CCU hopper, (50 -60 bbls of packed cuttings). Attempt to pump to totes, but unable to get dry cuttings out - packed off in chute. Rig up line from RSC to inject slurry inside hopper discharge to pump with a 1" manifold. Attempt to free primary cutting return line, but unable. Switch I over to secondary line, until able to spend time on same. Establish circ to RSC shaker & pump out cuttings in slugs & trying a couple of different fluid mediums, (Sim -Op's: service rig, top drive & misc rig maintenance Issues). 06:30 -07:00 0.50 RSC gave clearance that able to proceed, once hopper had been cleared & pumped over to RSC. RIH I with BHA #2 from 3,320' to 3,890' without incidents or problems. 07:00 -11:15 4.25 Directional drill 8-3/4" hole from 3,890' to 4,270'. 11:15 -12:00 0.75 Total time spent off bottom circulating at reduced rate & clearing out plugged possum belly chute at RSC shaker. Take off inlet on secondary cutting line & flush out same - completely packed off. Once cleaned out, transfer over 60 bbls of cuttings in CCU hopper & limit discharge over shaker to prevent I plugging hammer mill off. 12:00 -12:30 0.50 Directional drill 8 -3/4" hole from 4270' to 4366'. 12:30 -14:00 1.50 Circ & cond hole at 300 gpm & 100 rpm while reciprocating pipe. Wait on RSC to get repairs done at CCU. Weld up connection on hydraulic line hard & unplug RSC shaker chute. 14:00 -20:30 6.50 Directional drill 8-3/4" hole from 4,366' to 4,935' 20:30 -21:30 1.00 Circ & cond hole for short trip. Took survey at 4,094'. Hole cleaned up good at shakers, monitor well before starting short trip - static. 21:30 -22:30 1.00 Short trip 11 stands from 4,935' to 3,890' with out incidents or any hole problems. Hole took proper amount of fluid, observed well & prepared to service rig. Sim -Op's: RSC worked on unplugging I primary cuttings line during this operation & cleared the line of obstructions & serviced equipment. 22:30 -23:00 0.50 PJSM on overhead work for TDS. Serviced top drive/Rig & looked over derrick for loose fittings. 23:00 -23:30 0.50 Trip back in the hole, 3,890' to 4,935', with out incidents or problems - hole in excellent shape. 23:30 -24:00 0.50 Directional drill 8-3/4" hole from 4,935' to 4,979'. 1 05/16/2008 00:00 -04:30 4.50 Directional drill 8-3/4" hole from 4,965' to 5,470'. 04:30 -05:00 0.50 Circ off bottom while RSC & CCU make repair to leaky hydraulic line on Geho pump. 05:00 -13:00 8.00 Directional drill 8-3/4" hole from 5,470' to 6,168' - planned short trip station. 13:00 -13:30 0.50 Circ & cond mud while reciprocating drill string. 13:30 -15:30 2.00 Break off top drive & vac off elevators. Flow check well bore for 10 min - static. POOH with BHA #2 from 6,168' to 4,935' without any swabbing or hole problems. Check flow for 5 min - static. RIH & wash last stand down to avoid surging hole & min bottoms up gas. 15:30 -24:00 8.50 Directional drill 8-3/4" hole from 6,168' to 7,000'. Had an issue with RSC & power for shakers but able to remedy with Nabors electrician's help & did not shut operation down. CCU & RSC operations working well. 1 3 I I DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown I (hrs) Time 05/17/2008 00:00-01:00 1.00 Directional drill 8-3/4" hole from 7,000' to 7,117'. I 01:00-02:00 1.00 Circ while changing oil/filter on the top drive system, due to contamination & over filling. 02:00 -06:00 4.00 Directional drill 8-3/4" hole from 7,117' to 7,402'. 06:00 -07:00 1.00 Circ bottoms up 1.5x to ensure well bore clean of cuttings & an even 12.0 ppg MW in /out of hole. Check shakers & cleaned up so decision made to perform upcoming open hole LOT. I 07:00 -08:00 1.00 Position 2nd TJ above floor & shut down pump /rotation. Open lines to cement unit in RSC & pump over 25 bbls of 12.0 ppg mud. Open kill line & have HES pump 3 bbls to clear air in line. Shut in top pipe rams & perform LOT at 0.1 bbls/min - chart & record same. Recieved a 601 psi ISIP at 7,402'md/4,873'TVD, (bled down to 511 psi FSIP at 10min. Bleed back 2.01 bbls from 3.1 bbls pumped. Open pipe rams & pump through kill line 12 bbis from RSC while coming down to break out TDS. I Blow down cement line while preparing to short trip - well static. 08:00 -10:00 2.00 Short trip BHA #2 from 7,402' to 6,168' with out incidents or problems (max 5 -10 klbs out/in while tripping). Ensure no swabbing seen & hole took proper fill ups. The short trip went extremely well & hole appeared to be in good shape. I 10:00 -12:00 2.00 Directional drill 8 -3/4" hole from 7,402' to 7,592'. 12:00 -15:30 3.50 Directional drill 8-3/4" hole from 7,592' to 7,858'. Geologist confirmed top of Torok at 7,935' MD = 5,060' TVD. 15:30 -16:00 0.50 Repair leaking hammer union on standpipe goose neck to kelly hose - hammer up tighter. 16:00 -19:00 3.00 Directional drill 8-3/4" hole from 7,858' to 8,162'. I 19:00 -20:30 1.50 Circ bottoms up to prepare for rig repair. Circ at 600 gpm initally to get cuttings up hole then reduced to 450 gpm to lessen the wash out possibility on standpipe goose neck union. 20:30 -22:30 2.00 Stand back 2 stands DP. Blow mud line to prepare for replacement of union gasket. RIH 2 stands. Break circ & prepare to drill. I 22:30 -23:30 1.00 Directional drill 8-3/4" hole from 8,162' to 8,257'. 23:30 -24:00 0.50 arc hole to clean cuttings while preparing pits for mixing LCM pill. Observe well & recording losses. Note: Hole static for losses with pumps off. 08/18/2008 00:00-01:30 1.50 Spot 25 bbis of 10.0 ppb of each Baracarb 5 & 25 plus 5.0 ppb of Steel Seal. Displace out of string with 150 bbls 12.5 ppg mud, plus 20 bbls extra to clear BHA. Pump at 300 gpm & 980 psi, with 78 bbls/hr loss rate. 01:30 -02:00 0.50 Close annular preventer & bullhead LCM pill #1 with 15 bbls of 12.5 ppg mud at 3 spm & 50psl, I stopping to let pres bleed off. Work up to 7 spm & 150 -200 psi, (13.3 EMW with12.5 ppg MW), while holding 100 psi & let bleed Into formation. Total of 15 bbls & 180 strokes. Let pres bleed off to zero & open annular, with well bore static. 02:00 -04:00 2.00 Directional drill 8-3/4" hole from 8,257' to 8,351' to determine losses & build cuttings to help seal thief zone. Losses at 240 bbls/hr=53% loss ratio. Had stopped at 8,286' to monitor well with 3 -5 bbls/hr loss rate. Take on 150 bbls of 12.5 ppg mud from RSC to rig pits. 04:00-07:00 3.00 Mix & pump 40 bbls LCM Pill #2 at 15 ppb each of Baracarb 5 & 25, plus 10 ppb Steel Seal. Displace with 150 bbls Into open hole with 425 gpm & 2,220 psi. Shut in annular preventer & squeeze at 9 spm =150 psi & allow to bleed off from 100 to 0 psi, staging up to 200 psi, (13.3 EMW with 12.5 ppg I MW). Hold 100 psi while allowing pill to bleed off into thief zone. Bleed off pres after a total of 30 bbls squeezed away, & open annular preventer, (well bore static to slight loss at 1 -3 bbls/hr loss). Loss rate while spotting pill was 125 bbls/hr =29% loss ratio. 07:00-07:30 0.50 Drill ahead to determine losses & build cuttings to help seal thief zone in 8 -3/4" hole section from 8,351' to 8,435'. Losses at 240 bbls/hr=52% loss ratio. I 07:30 -08:00 0.50 Circ at 300 gpm & 920 psi with 240 bbls/hr losses =12% Toss ratio. Pull back to 8,351'. RSC building 200 bbls of 12.0 ppg MOBM & rig pits have total of 283 bbls. 08:00-08:30 0.50 Shut down pump to save volume & rotate slowly while monitoring well bore (3 -5 bbls/hr loss rate). Build 60 bbls of 12.0 ppg LCM pill #3, with 65 ppb Steel Seal, 10 ppb each of Baracarb 50/150 & 5 ppb I Barafiber. Cut mud wt of rig pits to 12.0 ppg. Consult town ODE & decision made to POOH into casing to build volume & stage back in hole with12.0 ppg mud. 08:30 -13:00 4.50 POOH with BHA #2 from 8,351 to 6,548' wet, while mixing Dry Job. Ensure not swabbing out of well bore & fill every 3 stands to ensure hole full - 3 -15 bbls/hr losses. Max over pull observed 5 -20 klbs while POOH to casing shoe. Pump Dry Job & continue to POOH from 6,548' to 3,384', with losses 1 slowing down to 3 -7 bbls/hr. Total losses at 12:00 hrs =594 bbls trip out schedule calculated 42.3 bbls & actual =81.1 bbls (diff=38.8 bbls). 13:00 -14:00 1.00 Service rig & top drive. Cross over grabber malfunctioned on top drive. RSC continued to bring 200 bbls of MOBM up to 12.0 ppg as directed by Baroid Rep. Losses at 2.4 bbls/hr while not circulationg & continue to top fill hole continuously. 14:00 -16:00 2.00 Wait on RSC unit to finish preparing 200 bbls of 12.0 ppg mud, as directed by Baroid Rep. Transfer over to rig pits once completed. Loss rate =2.4 bbls/hr static. Sim -Op's: RSC hammer mill having carrier bearings & cutters changed out on lower drum while supervised by Harris Welding Rep. Rig had spill & BOP drill. Installed safety valve & simulated shut in, with well secured in 1 min & 15 sec. I Leave safety valve on, (open), while waiting on RSC. 16:00 -17:00 1.00 Take off safety valve & screw into string with top drive. Rotate at 40 rpm & establish circ at 300 gpm, with 110 bbis/hr loss rate =37% loss ratio. Cut pump back to 250 gpm =670 psi at 79 bbls/hr loss rate =32% Toss ratio, until 12.0 ppg mud at bit. Losses dropped to 26 bbls/hr rate =10.4% loss ratio, & 1 once heavy mud out, losses decreased to 18 bbls/hr rate =7.2% with 28 -30% flow returns. 4 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time (hrs) Elapsed Operations Breakdown Time 17:00 -17:30 0.50 Break out of string with top drive & RIH with BHA #2 at 50 -60 fpm to reduce & avoid surge pres while tripping in 11 stands from 3,416' to 4,448'. 17:30 -18:15 0.75 Establish circ at 275 gpm =800psi at 40 bbls/hr loss rate= 13.3% loss ratio. As heavy mud moved up with bottoms up, decreased to 25 bbls/hr rate =8.3% loss ratio. 18:15 -19:00 0.75 RIH with BHA #2 at 50 -60 fpm rate to reduce & avoid surge pres while tripping in 11 stands, 4,448' to 5,487'. 19:00 -19:45 0.75 Establish circ at 300 gpm =900 psi at 21 bbls/hr loss rate =7.1% loss ratio. 19:45 -20:30 0.75 RIH with BHA #2 at 50 -60 fpm rate to reduce & avoid surge pres while tripping in 11 stands from 5,487' to 6,531'. 20:30 -21:30 1.00 Establish circ at 300gpm= 980psi at 54 bbls/hr loss rate = 18.2% loss ratio. 21:30 -22:15 0.75 RIH with BHA #2 at 50 -60 fpm rate to reduce & avoid surge pres while tripping in 11 stands from 6,531' to 7,583. 22:15 -23:15 1.00 Establish circ at 250 gpm =800 psi at 22 bbls/hr loss rate =8.8% loss ratio. 23:15 -24:00 0.75 RIH with BHA #2 at 50 -60 fpm rate to reduce & avoid surge pres while tripping In 11 stands from 7,583' to 8,438'. Total losses for 24hrs =864 bbls. 05/19/2008 00:00 -01:30 1.50 Stage in to bottom at 250 gpm flow rate =800 psi with 24 bbls/hr loss rate =9.6% loss ratio. Use 40 rpms & 5 k ft-lbs off bottom torque. Wash down 8,351 to 8,434'. 01:30 -03:00 1.50 Attempt to drill ahead, to monitor loss rate & use cuttings to help seal losses. Directional drill 8-3/4" hole from 8,434' to 8,441'. Loss rate at 110 bbls/hr =24.4% loss ratio. Decision made to suspend drilling & spot LCM pill #3. Pull off bottom & stop pumping & slow rotary to 40 rpm. Pull suction screen on pump to help spot pill. Pump 67.7 bbls of 12.0 ppg mud with 65 ppb Steel Seal & 10.0 ppb of Baracarb 50/150 & Barafiber, with a total of 1,825 strokes to displace out of bit plus 5 bbls. Spot with pump at 250 gpm =800 psi & chase out of MWD tools/bit at 360 gpm =1,500 psi to prevent plugging off tools. Total loss of pill while exiting bit & being spotted at 6 -7 bbls or 1.9 %. 03:00 -03:30 0.50 POOH with BHA #2 from 8,441' to 7,972' slowly while monitoring for swabbing & hole filling - none experienced. Pulled 175 klbs with no excess over pull. 03:30 -09:30 6.00 Shut In annular preventer & turn pres down to 400 -450 psi in preparations for working DP tube between element. Open up through kill line & zero in all gauges. Initiate hesitation squeezes at 5 spm rate, until break over seen. Record pres & allow to bleed off to holding pres over '1/2 hr. Work pipe each time to ensure no differential sticking & allow element to relax before going down. The rate initiated started with 50-100 psi before break over & bled to zero. During course of squeezes pres increased to a max of 285 psi, (trying to achieve 400psl - the diff between 12.0 ppg mud & expected 13.4 ECD value at depth). The bleed back increased relative to break over value from zero -150 psi. Initial volumes pumped also increased from 1 -2 bbls pumped, to final 3 -5 bbls on squeezes. Total of 45.6 bbls pumped, which calculated at final squeeze that possibly mud being squeezed at 8,220' depth. Bleed off slowly with 1.65 bbls recovered. Open annular & well bore static. 09:30 -11:00 1.50 To allow well bore time to relax after squeeze at depth, initialized circ at 7,972' & work string slowly while rotating at 40 rpm. Pump at 200 gpm =590 psi & circ bottoms up to allow mud to get moving & warm up slightly. Experienced some 17 bbls/hr losses =8.5% loss ratio. Adding 6 bags per hour of Steel Seal & Barafiber at 50 fpm rate to aid in sealing Torok formation. 11:00 -11:30 0.50 Running in hole from 7,972' to 8,441'. 11:30 -16:30 5.00 Directional drill 8-3/4" hole from 8,442' to 8,730' with base of the Torok formation called at 8,500' and / 5,626.1' TVD, (higher than expected). ROP rates restricted to 80-90 fph max due to ECD & hole cleaning restraints. Experienced various losses from 8,491' to 8,541' = 8-24 bbls/hr=2.1-6.4% loss ratio; 8,551' to 8,604'= 115 -2 bbls/hr= 31 -1.0% loss ratio; 8,636' to 8,700'= 14 -90-24 bbls/hr= 3.5- 24 -6.4% loss ratio's. Continued with Steel Seal & Barafiber until 8,670' where switched to BaraCarb 50/150 mix & slowed additions to 3 bags/hr each. Drilled to 8,730' where pull off bottom for connection & 100% losses occurred. Total losses at 12:00 hr= 232 bbls / total losses for well= 926 bbls. 16:30 -19:00 2.50 Pull off bottom & shut down. Pump down the hole & fill back side with hole fill, (took 29 bbls to fill hole). Experienced 70 bbls/hr losses, which increased to 140 bbls/hr losses, (initial drink), & slowed to 60 bbls/hr losses. Consult with town ODE & plan 90-95 bbl salt water LCM Pill #4 with same concentrations as pill #3, with 60-65 ppb Steel Seal, 10 ppb BaraCarb 50/150, BaraVis to bring viscosity to 60 -65 & 12.0 ppg with Barite. Switched to base mineral oil to fill backside, with losses at 38 bbls, plus initial 142 bbls of MOBM. Well bore went static to 1 -2 bbls/hr loss rate. Working pipe, but as soon as rotating at 40 rpm, loss increase to 24 bbls/hr rate. Continue to mix LCM pill #4 while monitoring loss rate & filling backside. 19:00 -21:00 2.00 Pull up 13 stds from 8,730' to 7,522' in preparations for spotting LCM pill #4. Note: Rotate 8 stands out with 25 klbs over pull & no rotation other 5 stands. Total of 41 bbls to keep back side full while pulling up to 7,522'. 21:00 -22:00 1.00 Establish circ with 253 gpm =703 psi. Losing at 168 bbls/hr =46.5% loss ratio. Shut down pump & continue to prepare for LCM Pill #4. Well bore static until resumed rotation at 40 rpm =70 bbls/hr loss rate. Shut down rotation & reciprocate string slowly. 22:00 -23:30 1.50 Line up to & pump LCM Pill #4, 95 bbls total pumped at 300 gpm & 1,482 psi, with 140 bbls/hr loss rate =33% loss ratio, while displacing pill to bit. Shut down pump & closed annular preventer, bull head 82 gpm =318 psi & 102 gpm= 348 psi & pump pill plus 5 bbls to displace from drill string. Shut pumping operations down & monitor well bore (100 psi recorded) & let LCM Pill #4 set up. 23:30 -24:00 0.50 Inflate hesitation squeeze & turn annular pres down to 400 -450 psi, in preparations for working DP tube between element. Zero in all gauges. Initiate hesitation squeezes at 5 spm until break over seen & record pres. Allow to bleed off to holding pres over 'h hr. Work pipe each time to ensure no 5 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time differential sticking & ensure to stop & allow element to relax, before going down. The rate initiated started with 180 -250 psi before break over & bled to 115 psi & held constant. During course of squeezes, pres increased to a max of 250 psi, (trying to achieve 400psi - the dill between 12.0 ppg MW & expected 13.4 ECD value at depth). The bleed back increased relative to break over value from 105- 118 psi. Initial volumes pumped were 3 -5 bbls on squeezes. 05/20/2008 00:00-03:30 3.50 Continue with hesitation squeeze as above. 03:30-05:00 1.50 Establish circ staging up 50 gpm per schedule, 50 gpm= 65 psi, 100 gpm= 120psi, with 25 bbls/hr loss rate =25% loss ratio. Shut down due to losses. 05:00 -06:00 1.00 RIH from 7,500' to 7,905' at 50 fpm to avoid surging well bore while going. 06:00 -06:30 0.50 Try to establish circ with 50 gpm flow rate =200 psi at 36 bbls/hr= 50.4% loss ratio. Lost 10 bbls & shut down to avoid pumping excess mud away. 06:30 -09:30 3.00 Continue to reciprocate drill string while finish building 95 bbls of HES 12.0 ppg Hydro Plug LCM pill #5, per Baroid Mud Rep. Well was static with no pumping. Held PJSM with all related parties & ensure all gauges/straps zero. Clean off element area of DP were setting & doped same. Sim -Op's: Take on 250 bbls of 12.0 ppg MOBM from RSC to rig pits. 09:30 -10:30 1.00 Mix In hydrating polymer to LCM Pill #5, (hydro plug), & plug at 09:45 (1.5 hr pump time available). Pump at 250 gpm, (screen out of pump), at 230 psi & built to 760 psi while pumping a total of 88 bbls recovered from pit - loose 27.6 bbis while pumping. Switch to active system pit #5 while taking returns to other pits. Pump per procedure, with 104.1 bbis loss while displacing at 250 gpm= 1,150psi, (temporary staged to 350gpm =1,500 psi to achieve MWD signal - still working). Once at bit, shut down & close annular preventer with 400 psi closing pres. Bull head plug into formation with staged pump rate, 100gpm =340 psi, 150gpm =600 psi & 170 gpm= 670 psi, which built up to 875psi & broke over to 740 psi. Increase to 200 gpm =890 psi, with rate at 750 psi for final pres. Once in place with 1,158 strokes, (98 bbls total =88 bbis pill & 10 bbls excess), shut down with 87 psi ISIP. Plug in place at 10:40 hrs. 10:30 -17:00 6.50 Wait on Pill #5 to set up, per Baroid schedule. Note: MWD recorded 118° BHT= 5 -7hr set time). Rotate drill string every 0.5 - 0.75 hrs, with total of 15 wraps per try. Pipe had previously been rotated 6 wrapsto break over prior to pumping pill. Each time pipe rotated, pres bled off, 87- 47 -36 -3 -Opsi & break over went down, 4 -3 -2 wraps & continued to take 2x wraps to break over. This continued until 17:15 hrs, which was 6.5 hrs total set up time. 17:00 -19:00 2.00 Bleed off any trapped pres, (gauged at zero psi). Recover to trip tank, but very slight flow. Open annular preventer & see very little flow. Establish slow rotation at 40 rpm =6 klbs, work string up =180 klbs break over. Start pumping with 50 gpm Increment, (50 gpm =380 psi, 100 gpm =211 psi, 150 gpm =380 psi, 200 gpm =556 psi), all with out any losses recorded. Increased to 250 gpm = 801 psi, with 48 bbls/hr loss rate =13.4% loss ratio & 300 gpm =1,137 psi =60 bbls/hr loss rate =14.0% loss ratio & 350 gpm= 1,424, psi =120 bbls/hr loss rate =24% loss ratio. Cut pump back 200 gpm & finish circulating bottoms up, with total 52 bbls with out any LCM material seen across shakers. Shut down & monitor well bore for 1 h hr - static. 19:00 -24:00 5.00 Lay down single & POOH from 7922' to 7,416 (wet pipe). Hole not taking proper fluid - slight swabbing. Pump 20 bbl Dry Job & pull up 5 stds to 6,941' monitoring hole. Make up top drive & rotate at 130 rpm while moving up, hole took 2 bbls. Blow down top drive. POOH to 6,466' & rotate at 130 rpm - 5th stand while pulling, hole took 3.0 bbls (difference of .6 bbls). POOH to 5,991' & rotate up on 5th stand again. Hole took 3.6 bbls - OK. Did same procedure for next 10 stands with proper hole fill of 3.5 bbls per 5 stands. Hole then started accepting fluid with out rotating. We probably have a ball on the end & knocked off some of it through some hard formations per discussion with Geologist. POOH to 3,087' at midnight. 05/21/2008 00:00 -02:00 2.00 POOH from 3701' to 377'. 02:00 -05:00 3.00 Lay down BHA #2, stand back DC's, unload nukes & down load recorded data. 05:00 -06:30 1.50 Lay down BHA #2 & clear rig floor of excess tools. 06:30 -07:00 0.50 Make up WBRT & pull wear bushing. 07:00 -11:00 4.00 Set test plug, fill stack with water. Test BOPE per AOGCC requirements, test annular preventer, (250 psi low / 2,500 psi high). Test BOP stack components, choke manifold valves, top drive 1 -BOP valve / manual valve & all floor valves per NAD test procedure to 250 psi low / 3,500 psi high. Function test accumulator system - OK. Function test gas detection alarms & LEL - OK. Pull Vetco Gray test plug & install wear bushings, lay down testing equipment. (Tests witnessed by Lou Grimaldi AOGCC) 11:00 -12:00 1.00 Service top drive, traveling block & crown block. Changed gearbox oil & filter. 12:00 -16:00 4.00 Pick up & make up BHA with Bit #3 on 5" DP & RIH to 3,400'. 16:00 -17:00 1.00 Circ mud to new mud weight of 11.5 ppg all around. Started pumping at 100 gpm = 95 psi / increased to 200 gpm =150 psi, rpm =40. Total losses were 2 bbls. 17:00 -19:00 2.00 RIH to 4,460' & circ bottoms up & cond MOBM to 11.5 ppg. No losses to hole. 19:00 -21:00 2.00 RIH to 5,503' & circ bottoms up & cond MOBM to 11.5 ppg. Total losses were 9 bbls. 21:00 -23:30 2.50 RIH to 6,551' & circ bottoms up & cond MOBM to 11.5 ppg. Total losses were 1 bbls. Rotate at 40 rpm & circ at 200 gpm =170 psi. 23:30 -24:00 0.50 RIH to 6,745'. Hole in good shape. 6 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 05/22/2008 00:00 -01:00 1.00 Continue to RIH with BHA #3 to spot Turbo -Chem LCM Pill #6 from 6,745' to 7,900', at 50-60 fpm, to avoid surging hole. Actual & calculated hole fill volumes within 0.3 bbls & SLM to ensure accuracy of pipe tally. 01:00-02:30 1.50 Stage up circ at 100 gpm =250 psi, 150 gpm =320 psi, 200 gpm =360 psi & circ bottoms up, (lost total of 17 bbls when bottoms up hit shakers & unloaded cuttings & Hydro Plug materials). No losses recorded while staging to 200 gpm & had 40 rpm. 02:30 -07:30 5.00 Continue to circ at 200 gpm & 360 psi, due to CCU -RSC loaded up with cuttings & Hydro Plug materials. No losses recorded while circ at 200 gpm & 40 rpm. 07:30 -11:00 3.50 Wash / ream at 15 fpm, to ensure not to load up CCU -RSC with Hydro Plug cuttings, but not a lot seen. Note: saw a medium load of sand come across shakers with bottoms up. Tag bridge at 8,700'. Losses also started to increase to 20 -42 -78 bbls/hr Loss rates =9.3 %- 19.6 % - 36.4 %, with pump turned down to 150 gpm =435 psi. Slowed flow rate to 100 gpm =385 psi, with 36 -60 bbls/hr loss rate= 25.2 % - 42 %. Continue to wash down to 8,730' with out further incidents, but loss rates continued. Ensure any cuttings, circulated well up the annulus & shut down pumping, due to losses. Rotate slowly at 40 rpm. 11:00 -12:00 1.00 Monitor well bore due to breathing conditions. Initial shut down rate at 20 bbls/hr & continue to monitor well bore with flow slowing to 2 bbls/hr in 45 min's. Consult with Town ODE over change of actions. 12:00 -12:45 0.75 Attempt to drill 10' to ensure fault crossed at bottom of hole, with 80 -140 rpm with 120 bbls/hr loss rate =49.4% loss ratio, but unable to make progress despite various parameters. Lost a total of 50 bbis in attempt. Suspend attempt with out making any footage due to losing mud at unacceptable rate. 12:45 -13:15 0.50 Open kill line & pump 2 bbls to ensure air out of line. Close annular preventer & 4" Demco on stand pipe. Perform open hole LOT with 125 psi achieved, before break over & total of 0.76 bbls pumped. ISIP pres was 50 psi, which bled off to zero within a min. Used 11.5 ppg mud at 8,694'md/5,324' TVD =11.95 ppg EMW. Shut down & prepare for injectivity test. 13:15 -14:30 1.25 Perform injectivity step test, per outlined schedule, of 0.5 bbls/min at 6 spm =104 psi, 1.0 bbis/min at 12 spm= 161 psi, 1.5 bbis/min at 18 spm =227 psi, 2.0 bbls/min at 24 spm =287 psi. All steps were with max 2 bbis pumped away, for 8 bbls total loss. All ISIP were 52 -58 psi, which bled off to 0 psi < 1 min. Bleed off through bleeder, (zero pres), & open annular preventer, (slight 9 bbls/hr breathing rate & died down to 0 bbls/hr rate in 20 min). 14:30 -16:30 2.00 Circ & cond hole & build volume. Observing well for breathing or losses. Finish the mixing of 65 bbl Swell LCM pill & prepare to pump. 16:30 -17:00 0.50 Line up & pump Swel LCM pill. Total volume of pill pumped was 63 bbis. Chased with 3 bbl MOBM spacer per procedure. Stop any more pumping. Prepare to clean pit for pill #2. 17:00 -24:00 7.00 Rotate DP at 40 rpm with 6 k ft-lbs torque. No losses or gains observed. Continue to mix pill #2 EZ squeeze. Having some difficulty with pill getting thick & to mix EZ Squeeze slowly to keep hopper from over flowing. Called Turbo Chem rep for advice. Advised mixing 1/2 barite required before adding final pallet of EZ Squeeze sack material. Mixing rate improved. 05/23/2008 00:00 -05:30 5.50 Observe well by just rotating at 40 rpm & working pipe with Swel LCM pill & spacer in pipe. Work on cleaning mix pit, preparation & mixing of second EZ squeeze pill. 05:30 -06:30 1.00 Pump EZ Squeeze pill at 3 bpm 500 -950 psi. Note: Had difficulty both mixing & pumping this pill as it was very thick. Pumped 71 bbls mud & chased with 14 bbls MOBM to have the pill below the first stand set back. 06:30 -09:30 3.00 Continued to POOH pumping 84 strokes per stand to 6,530'. Parameters were 40 rpm with 5 k ft-Ibs torque & 1000 psi. Circ 800 strokes & pumped dry job in combined strokes. POOH to shoe. 09:30 -12:00 2.50 POOH from 6,530' to 3,406' & monitor well. 12:00 -13:30 1.50 Wait on orders for squeeze job. Change oil in top drive. Observe well, Static. 13:30 -16:00 2.50 Pump squeeze cycle #1. Squeeze 37 bbls at 6 spm & observe pres build up to 203 psi & fell back to 170 psi at end. 16:00 -00:00 8.00 Continue to perform squeeze cycles every hr until 19:00 with psi climbing results. During this time frame the psi increased from 196 to 190 on cycle 3, from 227 to 221 psi on cycle 4, from 212 to 195 on cycle 5. From 19:00 to 23:30 performed 2 squeezes with 2 hr wait time per consultation with Thermo Chem rep & Joe Polya. Cycle 6 went from 190 psi initial to 187 psi. Cycle 7 went from 194 psi instal to 189 psi for 2 bbls. Advised to pump the other 4 bbls if no increase in the first 2. We did so with a slight increase of 193 psi after 2 bbls to 194 psi after 4 bbls. Consulted Joe Polya & he agreed with plan to prepare for another pill of EZ squeeze to be laid out from 8,250'. 05/24/2008 00:00 -01:30 1.50 Pump last cycle of squeeze & close in with 200 psi. Monitor well for 20 min. Bleed off pres & open annular & observe well for breathing - slight flow. Prepare for RIH. 01:30 -07:00 5.50 RIH from 3,407' to 7,026'. Hit tight spot & attempt to circ - unable. POOH to 6,736' & regained circ. Shut down pumps & check for flow - OK. Wash & ream back down maintaining circ until reaching 7,560' with partial returns. RIH from 7,320' to 7,560' on elevators. Unable to circ at 7,560'. Parameters were 40 spm = 400 psi, 40 rpm = 4 k ft -Ibs torque. 07:00 -07:30 0.50 POOH from 7,560' to 7,320' & establish circ. 07:30 -10:00 2.50 Wash & ream from 7,320' to 8,731' at 2 bpm = 360 psi, 50 rpm = 4 k ft -Ibs torque. 10:00 -11:00 1.00 Circ hole at 2 bbls/min = 360 psi, 40 rpm, monitoring losses. Shut down pumps & observe well breathing for 30 min - confirmed well breathing. 7 I DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 I Time (hrs) Elapsed Operations Breakdown Time 11:00 -13:30 2.50 POOH from 8,731' to 8,100', pick up wt =175K, SO WT =130 K. RIH from 8,100' to 8,392'. Monitor well 5 I min. Continue RIH from 8,392' to 8,720'. POOH from 8,720' to 8,000' & monitor well. Pick up WT = 175K, SO WT = 130K. 13:30 -23:30 10.00 Circ hole at 8,000' with 2 bpm= 200 to 280 psi for 30 min. Stop circulating & pump 1st 20 bbls of EZ squeeze pill from Halliburton of the 100 bbls we are mixing & pumping into the drill string at 5- 20 bbls batches. Monitor well breathing at 1 bbl hr. Drill String capacity at 8,000' = 138 bbls. Chase & spot the I 100 bbl EZ pill with 40 bbls of MOBM. Prepare to RIH. Blow down cement line & wash up. 23:30 -24:00 0.50 RIH from 8,068' to 8,542' at 40 fpm. 125K DN WT & 175K UP WT. 05 /25 /2008 I 00:00 -01:30 1.50 RIH to 8,730', make up top drive & start pumping LCM EZ pill & POOH at 84 strokes per stand to 8,740'. Lay a total of 66 bbls In open hole. 01:30 -18:00 16.50 Close annular & start squeeze cycle #1 pump for 37 bbls/418 strokes at 6 spm. Final pres 343 psi & bleed down to 240 psi. Note: wait period of 50 min between all cycles. Closed top pipe rams & lined up on kill line for remaining cycles. Performed cycle #2 of 7 bbls/ 83 stks at 6spm= initial 275 psi, final I 369 psi. Cycle #3 of 5 bbls/60 stks at 6 spm= initial 300 psi- 10stks in 425 psi broke back to 395 psi, final 288 psi. Cycle #4A of 2 bbls/22 strokes at 6 spm = initial 124 psi, final 425 psi. Let stabilize & performed cycle #4B of 1.2 bbls/15 stks at 6 spm= initial 142 psi, final 390 psi, broke back to 375 psi. Cycle #5 of 1.2 bbls/15stks at 6 spm = initial 142 psi, final 390 psi, broke back to 375 -380 psi. Cycle #6 I of 2 bbls/24 stks at 6spm = initial 0 psi (bleed pres off & rotate string) 6 strokes 166 psi, final 330 psi, broke back to 320 -325 psi. Cycle #7 of 1.7 bbls/20stks at 6 spm = initial 84 psi, final 425 psi. Cycle #8 of 2 bbls/25 stks at 6 spm = initial 80 psi, final 425 psi. Monitor pres for 4 hrs =42 psi. 18:00 -24:00 6.00 Break circ & cond mud at 2 bbls min /24 stks, rotating at 20 increasing to 50 rpm, 600 psi, increased rate to 3 bbl /min. Experienced losses over shaker after 15 min. Heavy amounts of LCM coming back, I cut back rate to 2 bbl min while washing screens. 1200 strokes into 1st BU of 4643 strokes. Shut down pumping to clean & change shaker screens to minimize losses. Increase flow rate 3 bbl/min 1/2 way into BU & still showing losses over shaker, reduced back to 30 spm, 475 psi at 4400 strokes. Shut down, wash & change shaker screens. Total bbls squeezed away was 60. I 05/28/2008 00:00 -04:00 4.00 Circ & cond at 4 to 7 bbl /min rates, with 450 to 600 psi & 50 rpm. Slow rate due to heavy concentration of LCM coming over shakers to control fluid losses. Change out a few shaker screens. Continue circulating staging rates up every 15 min 5 -10 spm to what shakers can handle. I 04:00 -06:00 2.00 Continue to circ 2 bottoms up at 350 to 450 gpm =850 to 1,350 psi, 50 rpm =4 k ft -Ibs torque. 06:00 -12:00 6.00 Start washing & reaming from 7,840' to 8,375' at 215 gpm =500 psi, 10-20 rpm & 5k ft -Ibs torque. Change shaker screens to help with shaker fluid losses. 12:00 -14:00 2.00 Continue to wash & ream from 8,375' to 8,592' at 10-20 rpm = 3 -4 k ft -Ibs torque, 50-60 spm = 350 to 450 psi, 5-8 klbs WOB. 14:00 -16:00 2.00 Circ & cond hole & MOBM at 8,492' with 40-90 spm, 178 to 335 gpm, 20 to 50 rpm & 3 -4 k ft-Ibs torque. Stage up flow rate as allowable for shakers. 16:00 -19:30 3.50 Wash & ream from 8,492' to 8,700' at 48 to 90 spm, 178 to 335 gpm, 575 to 800 psi, 50 rpm & 4-5 k ft-Ibs torque. 19:30 -21:30 2.00 Circ & cond hole & MOBM at 8,700' with 80 spm, 281 gpm, 675 psi, 50 rpm & 4 -5 k ft-Ibs torque. 21:30 -22:30 1.00 Wash & ream from 8,700' to 8,731' at 1 ft/min ROP with 3 bbls/min, 36 spm, 300 psi, 10 rpm & 3 -5 k ft- Ibs torque. No losses to hole. Slight losses over shakers. 22:30 -24:00 1.50 Circ & cond hole & MOBM at 8,731 with 60 spm increasing in 10 min intervals to 120 spm, 211 to 422 I gpm, 650 to 1250 psi, 15 rpm & 3-4 k ft-Ibs torque. Performed slow pump rates. 05/27/2008 00:00 -03:00 3.00 Circ at 8,731' with 375 -450 gpm, 1000 -1450 psi,5 rpm & 4 k ft-Ibs torque. Transfer 650 bbls of new MOBM from RSC to rig, send 524 bbls to RSC from rig to have cleaned up. Monitor well for 15 min & I confirm well breathing slightly. 03:00 -11:30 8.50 POOH from 8,731' to 8,535', monitor well 45 min for breathing. Continue to POOH from 8,535' to 7,860' pumping out metal displacement only. Monitor well 20 min. POOH from 7,860' to 7,490' swabbing slightly, pumped 190 stks =16 bbls. POOH from 7,490' to bit. No overpull or swabbing. Break off bit, bit sub & clear rig floor. Tested choke manifold while P0011. I 11:30 -13:30 2.00 Pick up & make up single & prepare rig to cut drilling line. Slip & cut 54' of drilling line. 13:30 -14:30 1.00 Service rig & top drive. 14:30 -20:30 6.00 Change out top drive torque booster, change oil, adjust link tilt & grabber. 20:30 -24:00 3.50 Pick up BOPE testing tools & test to 250 psi / 2500 psi on annular for 5 minutes. Test 250 psi / 3500 I psi on upper /lower pipe rams, blind rams, dart valve, safety vavle, kill & choke HCR & manual valves for 5 min each. Perform koomey draw down test. 05/28/2008 00:00-07:00 7.00 Change out upper IBOP valve on Canrig top drive & adjust gripper. 07:00-07:30 0.50 Test IBOP valve 250/3500 psi per AOGCC, Nabors & Pioneer policies. 07:30 -08:00 0.50 Pull BOP test plug & install wear bushing. 08:00 -11:30 3.50 Make up BHA #4 per HES directional personnel, down load MWD & shallow test tools at 350 gpm & 700 psi. I 11:30 -13:00 1.50 Make up float sub & stabilizer, pick up source & install same. Pick up collars. 13:00 -16:00 3.00 RIH from 662' to 3408'. 8 1 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 16:00 -17:00 1.00 Circ & cond mud , stage pumps up to 400 gpm, 112 spm, 1350 psi & circ bottoms up. 17:00 -18:00 1.00 RIH from 3408' to 5500'. 18:00 -19:30 1.50 Circ & cond mud. Stage pumps up & circ bottoms up. 19:30 -21:00 1.50 RIH from 5500' to 6690' - tag obstruction with 25 klbs WOB. 21:00 -22:30 1.50 Break circ & stage pumps up to 340 gpm with good detection by MWD /Sperry -12.03 ECD. Wash thru obstruction & circ bottoms up. Had significant increase in LCM (EZ Squeeze product). Initial PVT 535 bbis & final PVT 511 bbls. Observed well for flow back to 519 bbis PVT with each barrel back slowing. 22:30 -23:30 1.00 RIH from 6690' to 7590'. Tag obstruction with 25 klbs excess WOB. 23:30 -24:00 0.50 Break circ & stage pumps up to 127 gpm with 400 psi, 05/29/2008 00:00 -02:30 2.50 Circ & cond mud at 7590'. Staged pump rate from 168 gpm to 294 gpm with 1200 psi, 40 rpm & 6 k ft- Ibs torque. Well packed off while circ at 7586' with 15 klbs over pull. Set down 20 k ft-Ibs with no pipe movement & low returns. Racked back 1 stand & attempted to pull on elevators, 75 klbs over pull & fired jars at 7530'. Make up top drive, break circ & work up to 210 gpm, 700 psi, 40 rpm, 6 k ft-Ibs torque & work through tight spot up to 7495'. Pumped 10 bbls LCM pill. 02:30-05:00 2.50 Back ream from 7495' to 6690' with 210 gpm, 700 psi, 40 rpm & 6 k ft-Ibs torque. 05:00-08:00 3.00 Circ & cond at 6690', 350 -425 gpm, 1550 -1950 psi, 40-100 rpm & 5 k ft-Ibs torque. 08:00 -12:00 4.00 Wash & ream from 6690' to 7150', 350 -375 gpm, 1500 -1630 psi, 120 rpm & 6 k ft -Ibs torque. 12:00 -17:00 5.00 Wash & ream from 7150' to 7550', well packed off. Staged pumps up to 375 gpm, 1630 psi, 120 -130 rpm, 5 -7 k ft-lbs torque. Wash at 3 -5 ft/min. Monitor well each connection till flow back slows. Before pack off getting back 90 -95 %. 17:00 -17:30 0.50 Well packed off at 7550' & lost 30 bbls. Observe well for flow back, had slower flow back of ballooned fluid & only got back +/- 70% of lost fluid. 17:30 -22:30 5.00 Wash & ream from 7550' to 7970'. Staged pumps up to 300 gpm, 1,180 psi, 120 rpm, 5 -7 k ft-lbs torque. Wash at 3 -5 ft/min. Monitor well each connection till flow back slows. Before pack off getting back 90 -95 %, after pack off at 7550' getting back 70 -40% decreasing each connection. 22:30 -24:00 1.50 Per discussion with PNR ODE, circ bottoms up to POOH & lay down BHA. At 108 gpm losing 10% during bottoms up circ. 05/30/2008 00:00-02:00 2.00 Circ bottoms up at slow rate to minimize losses. 100 gpm, 350 psi, 126 rpm, 6 k ft -Ibs torque. Losing 10% at this rate. Observed well with pumps off 15 min to verify well ballooning fluid back & not flowing. Each barrel flow back slowed. 02:00 -03:00 1.00 Pump out of hole from 7,970' to 7,400' at 84 gpm & 40 rpm. 03:00 -05:00 2.00 Pull on elevators from 7,400' to 6,065'. 05:00-05:30 0.50 Pump slug & monitor well to verify ballooning. Flow back slowed after initial slug fall. 05:30-08:30 3.00 POOH on elevators from 6065' to 660'. 08:30 -10:00 1.50 Lay down BHA, rack back jars & HWDP & flex collars. Remove radioactive source. 10:00 -13:30 3.50 Lay down BHA & down load MWD. 13:30 -15:00 1.50 Pick up spare LWD & break & lay down same for helicopter transfer. 15:00 -16:00 1.00 Service top drive, blocks & crown. 16:00 -18:00 2.00 Wait on ghost reamer & SPS circulating sub. 18:00 -19:30 1.50 Make up 6 -1/8 bit, subs & stabilizers. 19:30 -20:00 0.50 RIH with 5 stands HWDP & Jars. 20:00 -23:00 3.00 RIH on 5" DP from 584' to 3408'. 23:00 -24:00 1.00 Circ & cond mud at 3408'. Stage pumps to 128 gpm, 160 psi, 40 rpm & 1 k ft-lbs torque. Cut mud to 11.3 ppg from 11.5 ppg with Arctic grade diesel per ODE Pioneer. 05/31/2008 00:00 -01:30 1.50 Circ & cond at 3408'. 120 gpm, 160 psi, 10 rpm, 2 k ft -Ibs torque. Monitor well for 15 min on trip tank. 111 Flow back less than 0.25 bbis in 15 minutes. 01:30-03:30 2.00 RIH from 3408' to 5000'. 03:30 -06:00 2.50 Circ & cond OBM, stage pumps up to 230 gpm & 440 psi. Lost 17 bbls while circ & cutting mud to 11.3 ppg in & out. 06:00-08:00 2.00 RIH from 5000' to 6600'. 08:00 -10:00 2.00 Circ & cond mud at 6600'. 10:00 -11:30 1.50 RIH from 6600' to 7414'. 11:30 -12:00 0.50 Ream & wash from 7414' to 7513' at 120 gpm, 293 psi, 120 rpm & 6 k ft-Ibs. 12:00 -15:00 3.00 Ream & wash from 7513' to 7900' at 34 spm, 120 gpm, 300 psi, 120 rpm, 5-6 k ft -Ibs torque. 15:00 -15:30 0.50 Circ & cond 34 spm, 120 gpm, 300 psi, 40 rpm & 4 k ft -Ibs torque. 15:30 -16:00 0.50 Drop ball to open ports in Centurion circ sub with bit at 7893'. Note: CCV shifted with 1700 psi. 16:00 -17:00 1.00 Spot 30 bbis MOBM, LCM pill & drop ball for CCV closure. 34 SPM, 120 gpm, 250 -500 psi to shift valve. Spot 33 bbis LCM at 7893'. 17:00 -18:00 1.00 POOH from 7893' to 7323'. 18:00 -22:00 4.00 Circ & cond mud with 250 gpm & 475 psi, while cleaning residual LCM out of suction manifolds & seats on #1 mud pump. 22:00 -24:00 2.00 Circ & cond with 70 spm on #1 pump while cleaning suction manifold & valves on #2 pump. Increase pump rate to 112 spm=400 gpm, 1100 psi for 15 min - no losses after initial start up. Slowed pumps to 70 spm. Note: 550 bbls water based mud mixed at RSC at midnight. 9 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 06/01/2008 00:00 -08:30 8.50 Circ & cond while wait on mud from RSC. Reciprocate from 7038' to 7228'. Clean rig pits, mixed spacer pill. 08:30 -11:00 2.50 Wash & ream from 7228' to 7892' at 150 gpm, 325 psi, 120 rpm & 7 k ft -Ibs torque. 11:00 -19:30 8.50 Circ & cond mud at 150 gpm - no losses. 19:30 -20:00 0.50 Service top drive. 20:00 -21:00 1.00 Circ & cond mud at 150 gpm - no losses. 21:00 -22:30 1.50 Held PJSM with all personnel, displaced well with 11.5 ppg KCUPolymer mud. Pumped 20 bbls LVT, 40 bbls spacer, 98 bbls WBM at 284 gpm, 750 psi, 160 bbis WBM at 400 gpm, 900 psi, 120 rpm & 6 k ft- Ibs torque. 22:30 -24:00 1.50 POOH from 7892' to 6373' - well taking correct hole fill. 06/02/2008 00:00-01:00 1.00 POOH from 6373' to 5994'. 01:00 -01:30 0.50 Displace with 123 bbls water base KCUPolymer mud 11.5 ppg, 400 gpm, 820 psi, <120 rpm & 6 k ft-Ibs torque. 01:30 -03:30 2.00 POOH from 5994' to 4191'. 03:30 -04:30 1.00 Displace well with 123 bbls water base KCUPolymer mud at 11.5 ppg, 300 gpm, 300 psi, 100 rpm & 4 k ft -Ibs torque. 04:30 -05:30 1.00 POOH from 4191' to 3405'. 05:30 -06:00 0.50 Displace well with 60 bbls water base KCUPolymer at 11.5 ppg. Water base back to surface. 06:00 -10:00 4.00 Clean pits & send OBM from rig pit system to RSC for storage. Make up WBM volume in RSC & rig pits. 10:00 -13:30 3.50 Build volume, weight up 70 bbls SWBM from RSC, weight up to 11.5 ppg. Make up 85 bbls SWBM in pits. 13:30 -16:00 2.50 RIH from 3432' to 7900'. 16:00 -17:00 1.00 Circ & cond mud. Stage pumps up to 300 gpm, 675 psi, 120 rpm & 8-9 k ftlbs torque. 17:00 -24:00 7.00 Wash & ream from 7900' to 8461' at 85 spm, 700 psi, 300 gpm, 120 rpm & 7 -10 k ft-Ibs torque. 06/03/2008 00:00-01:30 1.50 Wash & ream from 8461' to 8651' at 3 ft/min, 300 gpm, 660 psi, 120 rpm & 8-10 k ft-Ibs torque. 01:30-04:00 2.50 Circ & cond mud. Cut mud weight from 11.7 ppg to 11.5 ppg & circ until mud balanced in & out. Pump 20 bbls LCM pill at 02:30 hrs, to stop any seepage well might be experiencing. 04:00 -05:00 1.00 Wash & ream from 8651' to 8731' at 305 gpm, 120 rpm & 11 k ft-Ibs torque. 05:00 -06:00 1.00 Circ & cond mud at 8731' with 300 gpm, 750 psi, 120 rpm & 12 k ft -Ibs torque. 06:00 -08:00 2.00 Circ & cond mud. Stage pumps to 400 gpm, 950 psi, with no losses. Spot 25 bbls 100 ppb LCM pill at 8730'. 08:00 -09:00 1.00 POOH from 8731' to 7790'. No drag, tight spots, or swabbing. Pump slug. 09:00 -12:00 3.00 POOH from 7790' to 3800' with no drag, tight spots or swabbing. Well took proper hole fill. 12:00 -14:00 2.00 POOH from 3800' to 584'. 14:00 -16:30 2.50 Lay down BHA. 16:30 -17:00 0.50 Service top drive & change out saver sub. 17:00 -18:30 1.50 Make up WBRT & pull wear bushing. Make up test plug & equipment, fill BOP with water. 18:30 -22:00 3.50 BOP test rams, kill & choke lines, choke manifold 250/3500 psi 5 min each test. Pulled pipe out & tested blind rams 250/3500 each for 5 min. Performed Koomey draw down test. John Crisp with AOGCC waived witnessing BOP test. 22:00 -22:30 0.50 Install wear bushing. 22:30 -23:00 0.50 Service top drive & traveling blocks. 23:00 -24:00 1.00 Pick up stand with CCV ball catcher. Recover 3 balls located in catcher. Made stand back up & racked back. 06/04/2008 00:00-02:00 2.00 Pick up & make up MWD Tool. 02:00 -06:00 4.00 Load MWD & ADL - programming malfunction. 06:00 -07:00 1.00 Lay down MWD & trouble shoot same. 07:00 -08:00 1.00 Make up MWD & down load same. 08:00 -09:00 1.00 Orient tool & load radioactive source. 09:00 -10:00 1.00 Make up rest of BHA & RIH to 618'. 10:00 -12:00 2.00 RIH from 618' to 3,380'. Fill pipe & break circ. 12:00 -12:30 0.50 Stage pumps up to 400 gpm at 1500 psi. 12:30 -14:00 1.50 RIH from 3,380' to 5,850'. Tight spots at 4,784', 4,838' & 5,400'. 14:00 -14:30 0.50 Circ & cond mud, staging pumps from 125 gpm to 400 gpm, 600 -1600 psl, 135 rpm, 7 k ft -Ibs torque. 14:30 -16:00 1.50 RIH from 5,850' to 7,721' - tight spot at 7,640', 30 Kibs Dn wt, P/U Wt = 155 klbs, S/O Wt = 130 klbs. 16:00 -23:30 7.50 Wash & ream from 7,721' to 8,730' at 125 -250 gpm, 400 -900 psi, 120 -140 rpm, 8 -10 k ft -Ibs torque. P/U Wt = 203 klbs, 5/0 Wt = 120 klbs, Rot Wt = 155 klbs. Well balloning from 7,721' to 8,250' giving back 20 to 30 bbls on each stand. From 8,300' to 8,730' well started taking mud at a rate of 145 bbls/hr. 23:30 -24:00 0.50 Monitor well on trip tank static losses are from 45 - 80 bbls/hr. Build 75 bbls 100 ppb LCM pill & build volume at RSC & pits. e I 10 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 06/05/2008 00:00 -04:30 4.50 Monitor well on trip tank. Static losses at 24-42 bbls/hr. Build mud at RSC & build 75 bbl, 100 ppb LCM pill. 04:30 -05:00 0.50 Drop chrome shifting ball for CCV & pump down at 100 gpm with 250 psi. Land ball & shift sleeve with 1900 psi. 05:00 -06:00 1.00 Drop bronze BHA shut off ball & displace down, pump 75 bbis of 100 ppb LCM pill at 120 gpm with 170 psi. Displace LCM pill with 153 bbls of mud at a rate of 250 gpm with 400 psi. 06:00 -06:30 0.50 Close annular & attempt to pres up to 400 psi on hesitation squeeze. Pump 8 bbls at 213 gpm with 235 psi. Shut pumps down, open annular work pipe & monitor well, Static loss of 6 bbls in 10 min. 06:30 -09:30 3.00 Close annular & squeeze LCM pill. Pump 5 bbis at 1 - 2 bbls/min, 60 - 70 psi hold pres for 10 min. Total LCM squeezed away = 40 bbis. Open annular & work pipe. 09:30 -10:30 1.00 Drop chrome operating ball to close CCV valve. Pump down at 100 gpm, shift tool closed with 2000 psi. 10:30 -12:00 1.50 Stage pumps up to 350 gpm with 1350 psi. Losses estimated at 260 bbls/hr. Shut pump down & put well on trip tank & monitor. Static losses at 14 bbls/hr. Total losses per tour at 155 bbls. 12:00 -16:00 4.00 Monitor well on trip tank, working pipe, cut MW from 11.5 ppg to 11.0 ppg & mix LCM to active pits. Static Losses at 25 - 35 bbls/hr. 16:00 -18:00 2.00 Directional drill 8 -3/4" hole from 8,731' to 8,746'. Hit hard spot at 8,745'. Drilling with 300 - 400 gpm, 1300 -1900 psi, 80 -135 rpm, 14 k ft -Ibs torque. P/U Wt 205 klbs, S/O Wt 120 klbs, Rot Wt 155 klbs. At 18:00 mud running out while losing at a rate of 140 -160 bbls/hr. Stop drilling & build volume. 18:00 -24:00 6.00 Monitor well on trip tank, building volume at RSC & pits. Stand one stand back & work pipe. Static losses 10 - 25 bbls/hr. Total losses for 24 hrs 836 bbis. 06/06/2008 00:00 -07:30 7.50 Build new mud in the RSC & rig pits, in preparations for drilling ahead. Transfer 200 bbis from RSC to rig pits & continue to build another 400 bbis in RSC. Note: had total of 675 bbls, prior to attempting to drill & wt up same to 11.0 ppg. 07:30 -09:30 2.00 Directional drill 8-3/4" hole from 8,746' to 8,764' with a total of 510 bbls lost while drilling ahead. Staged flow rate at 200 gpm, 950 psi; 450 gpm, 2,345 psi & 500 gpm, 2,650 psi, with 205 -240 bbls/hr loss rate =33.6% loss ratio. Suspend drilling, due to severe losses & pull back to 8,746' & spot 30 bbis Walnut sweep, plus 10 bbis LCM pill. 09:30 -11:00 1.50 Monitor well for flow back after pump shut down, (15 bbis return after 40 min's). Well bore went to 9- 10 bbls/hr static losses & mix dry job to have ready. 11:00 -21:00 10.00 POOH with BHA #6 from 8,764' to 618'. Take ACAL readings at 7,100' to 7,080'; 6,100' to 6,080'; 5,100' to 5,080' & 4,100' to 4,080'. 21:00 -24:00 3.00 Rack back HWDP & jars, remove sources & down load MWD. Lay down CCV sub & ball catcher. (3 balls in ball catcher sub). Oooguruk ODSN -40PB2 06/07/2008 00:00-03:30 3.50 Continue to down load MWD & prepare to lay down same, due to batteries needing to be changed out on next run. Once down loaded & laid down, stand back what was possible of the Geo -Pilot assembly. Note: bit had 3 flow passages plugged off on one side, therefore clean up same. Clear floor of unnecessary tools. 03:30-05:30 2.00 Pull wear ring with Vetco Gray Rep & set test plug. Open bottom pipe ram doors & change out to 4" DP type rams. Close up & ensure ready to test same. 05:30 -06:00 0.50 Pressure test bottom pipe rams to 250 psi (low)/3,500psl (high), per AOGCC requirements for 5 min each test - chart same. Rig down test equipment. 06:00-09:00 3.00 Make up cement Mule Shoe on 4" DP & RIH 12 stands 4" DP from derrick. Cross over to 5" DP & continue to RIH to 3,409'. 09:00 -12:00 3.00 Establish circ at 100 gpm & stage to 250 gpm, 340 psi, 50 rpm. Circ bottoms up & cut MW from 11.0 ppg to 10.0 ppg in /out of hole, with very slight losses of 1 -2 bbis/hr. 12:00 -13:30 1.50 RIH from 3,409 to 5,135'. 13:30 -14:30 1.00 Establish circ at 100 gpm & stage to 250 gpm 340 psi, 50 rpm. Circ bottoms up & cut MW from 11.0 ppg to 10.0 ppg in /out of hole, with very slight losses. 14:30 -15:30 1.00 Trip in tole from 5,135' to 6,857'. 15:30 -17:30 2.00 Establish circ at 100 gpm & stage to 250 gpm 420 psi, 120 rpm. Circ bottoms up & cut MW from 11.0 ppg to 10.0 ppg in/out of hole, with losses of 25 bbls/hr. 17:30 -19:00 1.50 RIH from 6,857' to 8,755'. 19:00 -21:00 2.00 Establish circ at 100 gpm & stage to 250 gpm 510 psi, 120 rpm. Circ bottoms up & cut MW from 11.0 ppg to 10.0 ppg in /out of hole, with losses of 30 bbls/hr. 21:00 -23:30 2.50 Rig up to cement, conduct JSA. Pump 3 bbis water ahead, test lines to 1500 psi. Pump 7 bbls of water, followed by 20 bbis of 12.5 ppg spacer. Mix & pump 410 sacks or 86 bbis of 15.8 ppg of Premium Cement, mixed at 5.06 gai/sk, 1.17 yield, additives included 0.55 % Halad -344, 0.20% CFR -3, 0.30 % SCR -100 & 0.125 % Super CBL. Chase with 3 bbis of 12.5 ppg spacer & 3 bbis of water. Displace with 125 bbls of 10.0 ppg mud with rig pump. 23:30 -24:00 0.50 POOH slowly from 8,755' to 7,795'. (10 stands). Note: 30 klbs overpull leaving bottom. 11 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 08/08/2008 00:00 -00:30 0.50 POOH with cement string from 7,795 to 7,550' with 180 klbs PuWt & 130 klbs SoWt & no swabbing. 111 00:30-03:00 2.50 Install wiper ball in drill string & circ bottoms up at 300 gpm, 450 psi, 30 rpm & 6 k ft-lbs off bottom torque. Circ surface to surface with approximately 200 bbls contaminated mud, (3 -5 bbls cement - checked with 11.4 pH). Note: wiper ball seen at return line. 03:00 -09:30 6.50 Wait on cement for 500 psi compressive strength results, (approx 6:02 hrs at 130° F test result). Consulted with HES & Town ODE, due to 94° F recorded BHT & decision made to WOC for extra 2 hrs. Cement string was rotated at 20 rpm with 6 k ft-lbs off bottom torque. No losses experienced. Sim - Op: Work on top drive gripper dies & change out same while waiting on cement. 09:30 -10:00 0.50 Establish circ with 100 gpm, 200 psi & staged to 200 gpm & 350 psi. Wash down from 7,522 to 7,636' with 30 rpm, 7 -8 k ft-lbs off bottom torque. At 7,636' (approx 30' low from calculated cement top, tagged cement stringer, torque jumped to 14 k ft-Ibs, pres increased to 450 psi & 5-6 klbs weight on Mule shoe observed. Pick up to re-tag & confirm, but fell off & continued to wash from 7,636 to 7,647', where tagged up again with similar parameters seen, (8 klbs weight on Mule shoe). Work up twice & tagged up at same depth to confirm cement top. Consulted with Town ODE with results. 10:00 -11:30 1.50 Circ bottoms up at 250 gpm & 395 psi at 7,612', racked back stand with no losses seen. Used 50 rpm & 8 k ft-lbs off bottom torque. Held PJSM with all related services on next cement plug, ( #2). Blow down top drive as precaution. 11:30 -13:30 2.00 Make up TIW valve & cement head at 7,612' & rig up to Cement & pump 3 bbls water ahead, test lines to 1,500 psi. Pump 7 bbls of water, followed by 20 bbls of 12.5 ppg spacer. Mix & pump 206 sacks or 43 bbls of 15.8 ppg "G" Cement, mixed at 5.06 gal /sk, 1.17 yield, additives included 0.55 % Halad -344, 0.20 % CFR -3, 0.25 % SCR -100 & no Super CBL. Chase with 3 bbls of 12.5 ppg spacer & 3 bbls of water. Shut down HES HT pump unit & ensure pressures bled off. Break off TIW valve & cement head & lay down same. Screw into DP with TDS & displace with 116 bbls of 10.0 ppg mud. Displace with rig pumps at 250 gpm & 432 psi final pres, while rotating at 50 rpm. CIP at 13:24hrs. 13:30 -14:00 0.50 POOH with cement string from 7,612 to 6,970' with 55-60 klbs over pull; 7,612 to 7,560' with 35 klbs over pull; 7,560 to 7,300' & 7,300 to 6,970' 10-15 klbs over pull with no swabbing seen while POOH. 14:00 -16:00 2.00 Install wiper ball, & circ bottoms up 6,600 strokes at 200 gpm, 300 psi, 80 rpm & 7 -8 k ft-lbs torque off bottom, with 140 klbs PuWt, 130 klbs SoWt, & 135 klbs RotWt. Had 100 bbls contaminated mud with 1 bbls cement returns seen at surface, (11.6 pH recorded). 16:00 -21:00 5.00 POOH & rack back 5" & 4" DP from 6,967' to surface. 21:00 -21:30 0.50 Clear rig floor & pick up 5" test joint. 21:30 -23:00 1.50 Pull wear ring & install test plug. Change out 4" rams & replace them with 5" rams. Test choke manifold on trip out of hole. 23:00 -24:00 1.00 Fill the stack & test joint. Test annular & floor valves to 250 low & 3500 psi high. 06/09/2008 00:00 -02:30 2.50 Test BOPE per AOGCC requirements, (Chuck Sheeve waived witness). Test all rams, floor/top drive valves tested 250 psi low / 3,500 psi high for 5 min each. Function test accumulator with system pres at 3,000 psi & 1,800 psi after closure. Test LEL, alarms, floor lights & log in Nabors book. 02:30 -03:30 1.00 Rig down test plug & install wear ring with Vetco Gray Rep present. Rig down test equipment, break down lines & line up choke manifold for drilling operations. 03:30-06:30 3.00 Pick up & make up BHA #7, (RTSS Type), with Fresh Geo -Pilot bit, (FSF 2565 Z with 5x15's). Make up rest of components accordingly & Initialize MWD probe with out problems. RIH & shallow pulse test MWD with 400 gpm & 500 psi - OK. Pull back to MWD section of tools. 06:30 -08:30 2.00 PJSM / clear floor of un- necessary personnel & load Nuke sources in carriers. Lower assembly & give all clear announcement & continue to add components as required, (Flex Monels, Drlg Jar & HWDP) & run in hole to 681'. 08:30 -10:00 1.50 Continue to RIH with BHA #7 from 681 to 3,400'. 10:00 -10:30 0.50 Fill pipe as required & test MWD, after breaking In Geo -Pilot seals with 5 rpm & increase 5 rpm every minute to 60 rpm max. Flow rate at 400 gpm, 915 psi & 450 gpm, 180 psi, with no reported losses experienced. Shakers screened up with 2x at 170's (210 old API #'s) & 1x at 140's (170's old API #). Rotate with 100 rpm's. Shut down & flow check well as precaution (static) for 10 min's. Sim -Op's: Service top drive while observing well bore. 10:30 -12:00 1.50 Continue to RIH with BHA #7 from 3,400' to 5,047', with no problems. Break circ with 9.8 ppg mud & establish slow pump rates. 12:00 -13:30 1.50 Circ bottoms up with 9.8 ppg mud in /out & received a large amount of cuttings with bottoms up, primary clays & siltstone. Slowed pumps to 350 gpm until cleaned up. Flow rate at 450 gpm, 1,270 psi at 24% flow returns & 500 gpm, 1,450 psi at 25 -26% returns. Ensure even MW for upcoming FIT. 13:30 -14:00 0.50 Open Kill line & establish circ to ensure no air in lines. Shut down pump & close top rams & pump at 10 spm down both sides for FIT with 9.8 ppg MW. Establish pre - calculated 711 psi to ensure 13.2 ppg EMW at 5,100' and / 3,990' TVD, with 14.4 ppg EMW at 2,998' TVD 9-5/8" casing shoe depth. Report results to Town ODE's & rig down test equipment & blow down kill line. Prepare for side tracking operations. 14:00 -24:00 10.00 Establish drilling parameters for time drilling 8 -3/4" hole from 5,100' - side track point with 136 klbs RotWt, 143 klbs PuWt & 130 klbs SoWt at 60 to 100 rpm on top drive & 6-7 k ft-Ibs off bottom torque. Flow rate at 450 gpm, 1,270 psi & 500 gpm, 1,450 psi. Time drill at 1" per 2.5 minutes presently at 5120'. 1 12 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 06/10/2008 00:00 -16:30 16.50 Time drilling 8-3/4" hole side track from 5,119' to 5,123', with 83% deflection at 150 R TF & 53.84 °. ABI showing. Attempt to increase ROP, with 6 -7 klbs WOB, but popped out of trough. Pull back to 5,123' & continue with 1 min per inch from 5,123' to 5,129', but ABI indicated Inclination not decreasing as should be, (ABI 4.7' back of bit). Decrease to 3 min per inch from 5,129' to 5,136', with ABI indicating 53.6 -53.75 Inc. Parameters included 0 -2 klbs WOB, 80 -100 rpm & 6 -9 k ft-Ibs off bottom torque. Note: tried various rpm to increase ROP, but harmonics unable to substain higher rpm. PuWt =43 klbs & SoWt =130 klbs. Flow rate at 550 gpm & 1,700 psi, 16:30 -23:00 6.50 Continue to time drill side track from 5136' to 5,145' at 3 min per inch, where ABI indicated inclination still 53.75 ° - 53.8 °. Consult Town ODE & decision made to attempt to push assembly with 4-6 klbs WOB. Start slowly with 2 klbs increments & limit drum speed to reduce loading on assembly. Attempt various rpm & achieve 120 -130 rpm with 4 klbs WOB. Directional drill 8-3/4" hole from 5,145'- 5,170' at reduced rate, where ABI showed 53.13° inc. This indicated assembly side tracking off with out further problems. Directional drill 8 -3/4" hole from 5,170' to 5,427' with 10-15 klbs WOB, 120 rpm, 550 gpm & 1,700 psi. 23:00 -24:00 1.00 Swab on # 1 mud pump went out, repair same & circ bottoms up, prepare for short trip. 08/11/2008 00:00 -00:30 0.50 Continue with short trip from 5,427' to 5,190', with out more than 10-15 klbs over pull. Check well - static & RIH to 5,427' without issues. Hole took proper fill up on way out & proper displacement on way in. 00:30 -12:00 11.50 Directional drill 8-3/4" hole from 5,427' to 5,996'. 12:00 -20:00 8.00 Directional drill 8-3/4" hole from 5,996' to 6,470'. 20:00 -20:30 0.50 Circ & cond hole for short trip. 20:30 -24:00 3.50 Short trip from 6,470' to 4,900'. Pulled 3 stands on elevators with 5 -10 klbs overpull. Had excess overpull of 35 klbs & had to wash & back ream rest of way out to 4,900'. Note: large amount of cuttings over shakers during this operation. 06/12/2008 00:00 -01:30 1.50 Circ bottoms up at 600 gpm & 2,130 psi while reciprocating std from 5,047' to 4,950' at 120 rpm & 8 k ft -Ibs torque off bottom. Hole unloaded a large amount of mostly clay materials with bottom up & continue to circ until clean. Switch to A -Cal "B" mode for pumping up data while circ bottoms up. 01:30 -04:30 3.00 RIH with BHA #7 from 4,950' to 6,470'. Take A -Cal data point at 5,128' to 5,131' (average= 9.57 ") & attempt at 5,801' to 5,803' - bad data. Some tight spots were recorded at 5,590' & 5,755' with 25 klbs WOB, 500 gpm, 2,250 psi, 120 rpm & 12 -14 k ft-Ibs off bottom torque, to get through & wiped spots. Continue to 5,890', where attempted to get a A -Cal data point, but tight spot encountered & slight pack -off experienced, (no losses occurred). Pull above same & Increase flow rate back to 500 gpm, 2,300 psi & ream down from 5,800' to 5,900', with 10-25 klbs WOB, 130 rpm & 12 k ft -Ibs torque off bottom. Appeared to be clear & RIH on elevators to 6,375' & washed to bottom at 6,470', as precaution. A -Cal tool had quit during pack -off & unable to regain, dispite all surface attempts. 04:30 -12:00 7.50 Directional drill 8-3/4" hole from 6,470' to 6,875'. Pumped 10 bbls Nut Plug sweep, (low vis) at 6,850' without any increase in cuttings seen. A -Cal tool came back at 6,657'. Used various WOB & rpm to optimise ROP. Added 0.5% EP Mud Lube which help reduced the DP rattle at higher rpm & now able to sustain 150 rpm. Encountered a couple of hard streaks which involved slowing rpm down to 60 -80 & increasing WOB from 30 -35 klbs, to get bit to engage & then drill off. 12:00 -21:30 9.50 Directional drill 8-3/4" hole from 6,875' to 7,419'. Pumped 10 bbls Nut Plug sweep, (low vis) at 7,419' without any increase in cuttings seen. Added 0.5% EP Mud Lube which help reduced the DP rattle at higher rpm's & now able to sustain 150 rpm. Encountered a hard streak at 7,071'- 7,074' which involved slowing rpm down to 60-80 & increased WOB to 30 -35 klbs, to get bit to engage & then drill off. 21:30 -23:30 2.00 Circ bottoms up 3.5x, pump low vis nut plug sweep. Took survey with MWD at 7,387' & change over to ACAL reading. Work pipe at 150 rpm & 600 gpm for bottoms up. Observed a lot of clays on shakers till end of 17,000 stks when cuttings were reduced significantly. 23:30 -24:00 0.50 Wiper trip from 7,419' to 7,224'. 06/13/2008 00:00-01:30 1.50 Wiper trip from 7,224'- 6,940', pulling on elevators, with PuWt =225 klbs, SoWt =120 klbs, pulling 30 klbs & slight swabbing. Make up top drive & pump out from 6,940' to 6,375' with 400 gpm & 1,405 psi. Attempt to pull on elevator at 6,455', with 35 klbs over & swabbing seen again. No further problems seen while pumping out to 6,375'. 01:30 -02:00 0.50 Circ bottoms up at 600 gpm & 2,640 psi. Reciprocate DP at 80 rpm & 10 k ft -Ibs torque off bottom, (6,375' - 6,470'). Received a large amount of clay based material across shakes. 02:00 -04:00 2.00 RIH with BHA #7 from 6,375' to 7,419' without problems. Take A -Cal reading while going back to bottom at 6,277'- 6,286' = 9.49" average, 6,644-6,657=8.76" average & 7,024' - 7,040'= 9.95" average. 04:00 -12:00 8.00 Directional drill 8-3/4" hole from 7,419' to 7,894'. Performed a 400 bbls mud dilution once back on bottom, with MBT's reduced from 13 down to 8.5 (approx 40% volume changed out). Top of the Torok was seen at 7,105'/5,072.9', & started the scheduled 10 bbls LCM pill every stand, consisting of 20 ppb each Steel Seal & Barafiber, withl0 ppb BaraCarb 5 -50 -150. Used various WOB/rpm to optimize ROP rates at 125 -150 fph. Continue to hold 0.5% EP Mud Lube which help reduced the DP rattle at higher rpm. Shaker that was down was repaired & back operational before noon. 13 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 12:00 -19:30 7.50 Directional drill 8 -3/4" hole from 7,894' to 8,464'. The bottom of the Torok was intersected at 7,979'/5,279.1' & continued the scheduled 10 bbls LCM pill every stand. Well bore started to take fluid at 8,085' at an initial rate of 2 -3 bbls/hr. This was steady until +/- 8,300' where it increased to 10 bbls/hr. Fault # 1 was predicted for 8,335' & #2 at 8,780' on this leg. Continue to monitor fluid levels after connections. 19:30 -21:30 2.00 Circ bottoms up 3.5x. Shakers were looking clean with encapsulated clays at end of circulating. Monitor well 10 min - hole static. 21:30 -24:00 2.50 Short trip from 8,464' to 7,419'. Had over pull of 40 klbs+ & swabbing hole when starting off bottom. Back ream from 8,368' to 7,419' without further issues, (Decided to pump out & back ream total trip). Had an issue with both mud pump pres relief discharging at same time. Lower !BOP valve showed it opened, but apparently did not. Continue to short trip out. Capable of using one pump at 90 spm while repairing each pumps pulsation dampners. 06/14/2008 00:00 -02:00 2.00 Wiper trip & back ream from 7,419' to 6,755' with 285 gpm & 900psi. 02:00 -04:00 2.00 RIH with BHA #7 from 6,755' to 8,464' without problems. Take A -Cal data points at 7,486'- 7,499'= 9.30" average, 7,977'- 7,989'= 9.50" average & 8,318' - 8,329'= 9.86" average hole size using 3 fpm lowering speed 560 gpm & 2,400 psi. RIH on elevators from 8,329' to 8,464' without problems. 04:00 -09:00 5.00 Directional drill 8 -3/4" hole from 8,464' to 8,585'. Start losing mud at 300 bbls/hr. Loss ratio 38.2 %. Consult with Town ODE. Check for flow - well bore static. Decision made to attempt to drill ahead to uncover all of possible fault area. Cut flow to 450 gpm & 1,850 psi, but unable to drill ahead from 8,585' to 8,589'. Appeared bit was balled, later found not the case. Experinced 437 bbl loss, with flow returns fluctuating from 34 %- 17 %- 29 % -1 %. This was a 24- 450 -785 bbls/hr loss rate. Suction pit was sucked down below usable pit level & pumps started to jack. Pick up off bottom to mix 40 bbls viscos flush, prior to pumping 60 bbls of 100 ppb LCM pill of Steel Seal/Barafiber, with BaraCarb 5- 50-150 mix. Well Bore was static, but while pulling from 8,589' to 8,555' saw 30-40 klbs over pull & swabbing. 09:00 -10:00 1.00 Transfer 180 bbls of 9.7 ppg good mud & 200 bbls of 9.7 ppg mud from previous day dilution program. Take on 40 bbls H2O from rig water tank & mix caustic with 2 sacks of Nut plug & N -vis to raise viscosity. Continue to mix finishing products for LCM pill per mud Man recommendations & once H2O pill ready, line up to pump same. 10:00 -12:00 2.00 Directional drill 8-3/4" hole from 8,589' to 8,597'. Pumped water pill to aid possible bit balling & tried mech aggravation also. The water was also for flushing into formation, prior to LCM pill. While attempting to get drilling at 8,589' to 8,591', used various parameters & took approx 1.5 hrs to achieve, but once through, drilling took off with 26 klbs WOB & 150 rpm - had seen same hard streak before on last leg. Losses were experienced at 151-0 bbls/hr= 20 % -0% loss ratio. Also had 6,416 unit gas come up, prior to water pill down, (water also took extra 6,100strokes to return). Hole appeared to reach saturation point & losses inceased, with total losses at 560 bbls. 12:00 -17:30 5.50 Directional drill 8-3/4" hole from 8,597' to 8,764'. Note: pump 10 bbls at 100 ppb LCM sweep every stand drilled. 17:30-24:00 6.50 Directional drill 8 -3/4" hole from 8,764' to 9,105'. 06/15/2008 00:00 -03:00 3.00 Directional drill 8-3/4" hole from 9,105' to 9,316'. Hole losses = 12 bbls. 03:00 -05:00 2.00 Circ bottoms up 3.5 times. 05:00 -06:00 1.00 Attempt to pull on elevators, but experience 35 -40 klbs over pull & swabbing. Decision made to back ream out of hole. Back ream from 9,316' to 8,835'. 06:45 -13:00 6.25 Continue to Back ream out of the hole from 8,835' to 4,804'. Note: did not rotate past fault area, just pump, as rotation caused 30-35 bbls/hr loss rates from 8,730' to 8,450'. Attempt to continue back reaming out of hole at 4,804', but experienced some packing off & tight hole conditions. Slack off & get rotation with 120 rpm & bring pumps up to 400 gpm. 13:00 -14:30 1.50 Continue to reciprocate stand slowly at 120 rpm, 400 gpm, 1520 psi & 10-12 k ft -Ibs off bottom torque. Circ 2 bottoms up & observe a lot of clay cuttings material at 1st bottoms up & had to cut back to 150 gpm to handle at shakers. Continue to stage back up slowly during 2nd bottoms up as mud containing a lot of clays & continue to blind shaker screens. Able to achieve 550 -600 gpm, but ECD's at 12.6 ppg EMW. Cut back to 450 gpm & POOH to casing shoe at 3,409'. 14:30 -19:30 5.00 Back ream slowly at 400 -450 gpm, 120 rpm maintain 11.8 -12.0 ECD's. Started increasing hoisting rate at 3,900' to 25 -30 ft/min. At 3,700' the pump pres came up 200 psi, but no torque or over pull. Observed ECD's went to a 16.2 ppg EMW. Immediately slacked off & cut pumps off, but pres held at 1200 psi, (packed off). Continued to work pipe & rotate, until pres fell off. Started pumping again slowly increasing rate while working pipe to get flow & ECD's back down. Got flow & ECD's under control & pumped a 20 bbl, 11.5 ppg, Hi -Vis, 50 ppb nut plug sweep. Observed some increase in cuttings at bottoms up. Continue to pump & back ream out to 3,528', stopped rotating & just pumped with top stabilizer entering shoe. Pulled to 3,408' very slow watching ECD's & having to slack off & work pipe. 19:30 -21:00 1.50 From 3,405' to 3,334', pumped at 300 -550 gpm, 60-120 rpm & getting large cuttings back. Mixed & pumped 50 bbl of 70 ppb Nut Plug / 120 vis with a drum of EP, Drill N slide, EZ glide sweep. On bottoms up, encountered a large pack -off from inside the casing of very large clay balls & rocks. 21:00 -23:00 2.00 Continue to pump out & back ream at 500 -550 gpm / 120 rpm to 3,054', where cuttings cleaned out. Pump Dry job, monitor well 10 min. (Static) 14 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 23:00 -24:00 1.00 POOH on elevators to 2,000'. Monitor well, with slight swabbing for first couple stands. Make up top drive & rotate pipe & hole volume dropped to normal. Continue monitoring 10 stands for correct hole fill - took right amount. 06/16/2008 00:00 -01:00 1.00 POOH with BHA #7 from 2,010' to 681' on elevators only without further problems or incidents. Performed kick while tripping drill in 1 min 45 sec. 01:00-03:00 2.00 POOH with BHA #7, racking back HWDP & Drilling Jar, 3x NM Flex monels, LD CCV sub, PJSM & recover Nuke Sources. 03:00-06:00 3.00 Plug into MWD & down load, recovering recorded MWD data & shut down same. Lay down MWD/LWD equipmnt & Geo- Pilot, after breaking off bit, Graded: 1- 1- WT- A- X -I -ER -BHA. 06:00 -07:00 1.00 Pull wear ring. Install test plug. Prepare to test anular preventer with test joint. Note: Hole was static prior to setting test plug. 07:00 -09:00 2.00 Test BOPE per AOGCC requirements, (Bob Noble waived witness). Had tested Choke manifold on way out of hole, (250 psi Low / 3,500 psi High -all good 5 min each). Test annular to 250 psi Low / 2,500 psi High for 5 min each. Test all rams, floor / top drive valves tested 250 psi Low / 3,500 psi High for 5 min each. Function test Accumulator with system pres at 3,000 psi & 1,900 psi after closure. 200 psi obtained in 25sec, with full pres at 1:30sec. 5x N2 Bottles at 1,800psi. Test LEL, alarms, floor lights & log in Nabors book. Test took 2.0 hrs without failures. 09:00-09:30 0.50 Rig down test plug & Install wear ring. Rig down test equipment, blow down lines & line up choke manifold for drilling operations. 09:30 -10:00 0.50 Service rig & top drive. Check top drive gripper dies - OK. 10:00 -11:00 1.00 Open kill line valve & establish circ through same, to clear lines of air. Shut blind ram & perform FIT to 780 psi, which was a 14.8 ppg EMW at casing shoe depth of 3,409' md/2,998' TVD, using 9.8 ppg MW. This equated to 12.53 ppg EMW at 8,585' md/5,494' TVD Fault area. Bottom hole at 9,316' md/5,719' TVD =12.42 ppg EMW. A total of 17.51 bbis were used for test & bled slowly, with 14.0 bbls returned. Results sent to Town ODE & per discussion decision made to continue with pick up of BHA #8. 11:00 -14:00 3.00 Pick up BHA #8, (RTSS Type), with fresh Geo -Pilot & re-run bit, (FSF2565 Z w /5x15's). Make up rest of components accordingly & Initialize MWD probe without problems. RIH & shallow pulse test MWD with 400 gpm & 500 psi - OK. Pull back to MWD section of tools. 14:00 -15:00 1.00 PJSM / clear floor of un- neccessary personnel & load Nuke sources in carriers. Lower assembly & continue to add components as required, (Drag jar & HWDP) & RIH to 681'. 15:00 -18:00 3.00 Continue to RIH with BHA #8 from 681' to +/- 3,345'. 18:00 -18:30 0.50 Fill pipe as required & test MWD, after breaking in Geo -Pilot seals with 5 rpm on top drive & increase 5 rpm every min to 60 rpm max. Flow rate at 400 gpm =1000 psi, shut down & flow check well for 10 min as precaution (static). 18:30 -20:30 2.00 PJSM/ slip & cut drilling line per Tool Pusher's requirements. Prepare to RIH with BHA. 20:30 -24:00 3.50 Pump at 450 gpm =1,200 psi, rotate with 80-120 rpm & set up MWD on B mode. Continue RIH from 3,345' to 5,228'. Break circ & pump at 450 gpm to get survey for confirmation in sidetrack. Monitor well for losses while pumping for 15 min - static. RIH from 5,228' to 5,899'. Had kick while tripping drill = 1 min 15 sec, (No tight hole or bridging, & taking proper hole displacement). 06/17/2008 00:00-02:30 2.50 RIH with BHA #8 from 5,899' to 8,560', where tagged bridge. Set down 20 klbs WOB, while attempting to go through. 02:30 -06:30 4.00 Ream bridge from 8,560' to 8,580'. Note: went through quickly. Pump 50 bbls Hi -Vis 100 ppb LCM pill around. Abundant clay observed on bottoms up. Continue to wash from 8,580' to 9,250' slight bridge at 9,075' & 9,120' - both easily reamed through. A -Cal Data points were taken at 8,727 - 8,739'= 10.26" average, 8,944' - 8,954'= 9.42" average & 9,114'- 9,124' = 10.34" average sizes. Had 4,144 unit of gas come at 8,826', (believe from Fault area bottoms up). No losses appeared to occur during reaming/washing operations. 06:30 -07:30 1.00 Circ well bore with 530 gpm & 2,150 psi. Flow check prior to starting was static. Some tight hole was seen at 9,270' & reciprocated with 120 rpm. Circ bottoms up & pumped 50 bbls of 100 ppb (20 ppb each of Steel Seal, BaraFiber, BaraCarb 5 -25 -150). Spotted LCM with base located at +/- 8,600', (coverage 8,600' - 7,675'). 07:30 -08:30 1.00 Let LCM pill soak at 8,600' - 7,675' for 1hr, while transferring 9.7 ppg from displacement to RSC & transfer 50 bbis of 100 ppb LCM pill to pit #7 & take 300 bbis of fresh 10.0 ppg mud to pit #5. Check well bore - static. Held spill drill =1 min 15 sec. 08:30 -13:00 4.50 Circ & displace to 10.0 ppg mud. Note: Flow check prior to starting displacement was static. Some tight hole was seen at 9,270' & reciprocated pipe with 120 rpm, 12 -15 k ft-Ibs off bottom torque. Circ fresh 10.0 ppg mud in well bore in & out. Flow check well bore - static. Continue to bring MW up to 10.3 ppg mud, with 2,250 psi & once spaced out to ensure 10.3 ppg mud at same time LCM spotted, pumped 50 bbls of 100 ppb, (20 ppb each of Steel Seal, BaraFiber, BaraCarb 5 -25 -150). Spotted LCM with base located at 4- 8,600', (coverage 8,600' - 7,675'). Let soak 15 min & flow check - static. Had some issues of getting to 9,316' as at 9,280' appeared to stack WOB 15 -26 klbs, but erratic torque seen. Top IBS back at 9,168' & appeared to hang up. Back reamed slowly to avoid stalling, (saw 15 -25 k ft -Ibs torque), 9,280-9,220=9,108 ' for top IBS. Once back reamed up & through same, went to bottom without incidents, further problems or fill. 1 15 t DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 13:00 -15:00 2.00 Circ & continue weight up to 10.7 ppg mud. Once spaced out to ensure 10.7 ppg mud same time LCM spotted, pumped 50 bbls of 100 ppb, (20 ppb each of Steel Seal, BaraFiber, BaraCarb 5 -25 -150). Spotted LCM with base located at +/- 8,600', (coverage 8,600'- 7,6751. 15:00 -16:30 1.50 Let LCM pill soak at 8,600' to 7,675' & transfer 50 bbls of 100 ppb LCM pill to pit #7 & take 300 bbls of fresh 10.9 ppg mud to pit #1-4 =650+ bbls PVT. Check well bore, (static). 16:30 -18:30 2.00 Circ & continue weight up to 11.0 ppg mud after static flow check. Reciprocated with 120, 550 gpm & 2,250 psi. Once received 11.0 ppg mud In/out, flow check - static. 18:30 -24:00 5.50 Directional drill 8-3/4" from 9,316' to 9,585'. Note: Had 2253 units of formation gas from the Top of HRZ fm at 9,317'. Held spill drill =1 min 10 sec. 06/18/2008 00:00 -05:00 5.00 Directional drill 8 -3/4" from 9,598' to 9,883'. 05:00-07:00 2.00 Pump 30 bbls HiVis sweep & circ bottoms up 3.5x, (not much seen with sweep return), while reciprocating string & circ at 550 gpm, 2,400 psi, 130 rpm & 12 k ft -Ibs off bottom torque. Hole appeared be clean at 21 k strokes & decision made to short trip. 1 07:00 -08:00 1.00 Flow check - static. Attempt to POOH on elevators, but 85 -90 klbs over pull experienced. Decision made to pump out only & POOH from 9,880' to 9,220' without further difficulties at 550 gpm & no rotation. 08:00 -08:30 0.50 RIH on elevator from 9,220' to 9,403' - no problems. Attempt to wash /ream from 9,403' to 9,440', (A -Cal I data point, but tool not reading - A -Cal tool plugged. Attempt various parameters, but not able to regain detection & decision made to RIH. 08:30 -09:00 0.50 RIH on elevators from 9,403' to 9,883' without inidents. 09:00 -12:00 3.00 Directional drill 8-3/4" from 9,883' to 10,073'. 12:00 -20:30 8.50 Directional drill 8-3/4" from 10,073' to 10,453'. I 20:30 -23:30 3.00 Circ bottoms up 3.5x at 10,453 with cuttings subsiding completely at the end of circulating. Monitor well for 10 min prior to short trip. 23:30 -24:00 0.50 Short trip from 10,453' to 10,258', over pull of 40 klbs on 2nd stand, pumping out at 320 gpm & no rotation. I 06/19/2008 00:00 -02:30 2.50 Back ream out of hole from 10,258' to 10,175' with 300 gpm, 1,500 psi, 150 rpm & 17 -24 k ft -Ibs off bottom torque. Experienced 50 klbs over pull & hole attempting to pack -off. Back ream 10,175' to 10,089', where hole packed -off & stalled string. Pulled 90 klbs without firing jar 7& work free. Re- 1 establish circulation & rotation, back ream to 10,073'. 02:30 -03:30 1.00 Mix & pump 30 bbl lube pill, (Ep Mud lube, N -vis). Stage pumps up to 550 gpm, 2,700psl, 150 rpm & 15 -18 k ft -Ibs off bottom torque. Circ until shaker's clean. 03:30-05:30 2.00 Continue to back ream 10,073' to 9,883' - well bore attempting to pack -off & unable to stage up to 550 gpm. Once able to achieve 550 gpm, continue to back ream. 05:30 -09:00 3.50 Total losses suffered during pack - off/tight hole events= 150 bbls. Continue to reciprocate stand, 9,962' from 9,866' & raise mud weight to 11.5 ppg, to help control fm. Note: observe coffee ground shales form LCU fm steady over shaker's. Stand back 1 stand after 1.25 hrs & continue to reciprocate stand from 9,866' to 9,772'. When 11.5 ppg mud weight achieved, in/out & shale stabilizer mixed, shut I down & monitor well - static. 09:00 -18:00 9.00 Wash in hole from 9,772' to 10,226' where first tight spot encountered. Ream from 10,226' to 10,390', seeing well trying to pack -off numerous times if too big a bite taken. Note: hole packing off at 4-8 klbs WOB & 12 -18 klbs WOB bit would not drill off very well. On pack-offs hole would try to pres up with 200 -400 psi above normal & if pipe was not worked up & slow pumps, rotary would try stalling. A -Cal data was taken at 9,930'- 9,940'= 9.83" average, 10,130'- 10,140'= 9.80" average & 10,340' - 10,350'= 10.42 ". Had to stop reaming operations at 10,300' & 10,415' to unload cutting out of hole across shaker's, (Kupurak Sands unloaded both times, cut back to 350 -400 gpm & stage up pumps as hole unloaded). Stopped at 10,250' to spot 50 bbls of 100 ppb LCM & let soak 'A hr & 10,363' for another 25 1 bbls for 15 mins - both times well bore was static. Losses of 30 bbls/hr started at 10,234' & increased to 80-90 bbls/hr at 10,259'. This stayed constant at 80-100 bbls/hr until second LCM pill at 10,363' where slowed to 70 bbls/hr & 10,388' at 25 -33 bbls/hr to bottom. On last stand worked single after reaming without rotation & mode switched MWD. 18:00 -24:00 6.00 Directional drill 8-3/4" hole from 10,453' to 10,690'. Note: Had 1045 units of connection gas with I bottoms up at 10,206'. 06/20/2008 00:00 -06:00 6.00 Directional drill 8-3/4" hole from 10,690' to 10,927'. Pumped 20 bbl LCM pill, spot & let soak for 15 min I for hole losses of 150 bbl/hr. Pump 2 30 bbl LCM pill in attempt to stop losses, but circ it slowly across loss zones. 06:00-09:00 3.00 POOH 1 stand. Circ & build volume. 09:00 -12:00 3.00 Pump 100 bbl LCM pill & spot at 10,797'. Shut bag in & squeeze pill at 0.5 bbls/2 bbls at 130 -250 psi every 10 min for a total of 34 bbls squeezed. Mix more volume in pits & mix another pill. I 12:00 -13:30 1.50 Pump & spot 2 pill & perform hesitation squeeze at 2 bbls every 10 minutes & 6 spm = 224 psi for a total of 40 bbls squeezed. 13:30 -14:30 1.00 Monitor flow back from sqeeze of 20 bbl total. 14:30 -15:00 0.50 Wash & ream from 10,790' to 10,927' at 140 spm, 500 gpm, 30 rpm & 15 k ft-Ibs torque. I 15:00 -16:00 1.00 Directional drill 8-3/4" hole from 10,927 to 11,016' . Note: Still having hole losses of 160/180 bbls/hr. 16:00 -17:30 1.50 Circ bottoms up at 11,016 for Geologist sample at 547 gpm, 2650 psi, 150 rpm & 18 k ft -Ibs torque. 16 I DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 17:30 -18:30 1.00 Directional drill 8-3/4" hole from 11,016' to 11,100' for TD. Nuiqsit top picked at 10,918'. 18:30 -20:00 1.50 Circ 1.5x bottoms up as mud allowed at 11,100' for short trip. Observed well for 10 minutes, well flowing back 10 bbls. 20:00 -22:30 2.50 Short trip without pumping or back reaming from 11,100' to 10,698' at 30-40 klbs over pull. Hole gave back (breathing) 86 bbls in 1 hr & decreasing. Pump metal displacement of each stand. Hit tight spot at 10,825' with 70 klbs over pull & 10,747' to 10,714' 35 -49 klbs over pull. Hit next tight spots from 10,698' to 10,642' with 90 klbs over pull. Note: had to pump & rotate, had pack off issues but got 550 gpm, 150 rpm & worked through it. 22:30 -24:00 1.50 Circulate hole at 550 gpm /rotating at 150 rpm for bottoms up. 06/21/2008 00:00-06:30 6.50 Short trip from 10,737' to 9,883'. Note: had to pump / back ream from 10,548' to 10,037' drill string came out of tangent section with an over pull of 90 klbs. Hole was still flowing back at 85 bbls/hr. Pulled out od hole pumping metal displacement plus volume swabbed only from 10,548' to 10,175' with 50 klbs over pull at 10,398' to 10,306' - 75 klbs over pull at 10,248' to 10,175'. Pumped & back reamed from 10,175' to 10,073'. Note: at 10,168' pipe was both stalling & packing off, had to be easy & patient with pumps until able to get full pump rate of 550 gpm, 150 rpm & 18 -29 k ft-lbs torque. Pulled pumping metal displacement only from 10,073' to 9,883' with 30-40 klbs over pull. 06:30 -11:30 5.00 RIH from 9,883' to 10,130' on elevators. Taking weight, therefore wash & reamfrom 10,130' to 10,168' at 550 gpm & 150 rpm. RIH on elevators to 10,235'. Run A -Cal mad pass at 1 ft/min from 10,235' to 10,275'. RIH on elevators from 10,275' to 11,100'. Had tight spot at 10,743' & set 50 klbs to rotate through, (a ledge on log correlating to a stabilizer). 11:30 -12:00 0.50 Drill 8-1/2" hole from 11,100' to 11,103'. Monitor well for 15 minutes. 12:00 -13:00 1.00 Monitor well flowing for 1/hr - total of 85 bbls gained in 1 hr. Positive well Is breathing. 13:00 -16:00 3.00 Short trip pumping metal displacement only plus volume swabbed from 11,103' to 9,985'. Made another MAD pass from 10,275' to10,235' at 1 ft/hr. 16:00 -23:00 7.00 Move string up & down 10' every 15 min while building volume up in rig pits & RSC per Co Man/mud Engineer's specifications to circulate bottoms up of 4x at 9,985' before wiper trip to 9 -5/8" casing shoe. 23:00 - 240:00 1.00 Finished weighting up mud to 11.5 ppg. Circ 4 bottoms up at 550 gpm. Monitored losses for 15 min =350 bbls/hr. Backed off pumps to 200 gpm for 15 min =10 bbls/hr. Picked up pump rate to 300 gpm for 15 min =115 bbls/hr. 06/22/2008 00:00-02:30 2.50 Circulate hole at 200 gpm, 700 psi, 60 rpm & 15 k ft -Ibs torque. Mixing 100 ppb/ 60 bbls LCM pill. Pump pill at 250 gpm & 800 psi to within 400' of bit, then pump at 560 gpm & 2800 psi the Volume of pill plus 5 bbls out the bit. Monitor well 10 min, flowing at 54 -34 gpm. Got back 24 bbls mud. 02:30-05:00 2.50 POOH from 10,073' to 8,790' pumping metal displacement plus swab volume. Had tight spots at 9,711', 9,659', 9,580' & 9,422' pulling 50 klbs over string weight only. Stop & monitor well flowing. Note: flow back subsided to 2 bbls/ hr. 05:00 -09:30 4.50 Circ 4 bottoms up slowly increasing pump rate to 500 gpm, 2200 psi, 100 -150 rpm & 15 -22 k ft -Ibs torque. Monitor well 30 min to confirm breathing at 80 to 35 gpm. Total losses were 270 bbls at 50 bbls/hr average. Final losses from circ were 50 bbls/hr. 09:30 -24:00 14.50 POOH from 8,790' to 8,462' pumping metal displacement plus swab volume only. Hit tight spots at 8,558' - 8,550', 8,636', 8,176', 7,629', 7,603', 7,585', 7,471', 7,256', 7,007' - 6,930', 6,686' & 6,083',pulling 70 klbs over. Continue to POOH pumping metal displacement plus swab volume & only pumping & rotating when totally necessary from 6,083' to 5,992' without problems. Continue to POOH from 5,992' to 4,640' with a few problems - ledges pulling great. 06/23/2008 00:00 -02:30 2.50 Wiper trip from 4,665' to 3,337'. Work tight spots at 4,640', 4,532', 3,963' & 3,850' pull 50 klbs over pull & pumping at 100 gpm. 02:30 -04:00 1.50 Circ hole while servicing top drive during this operation & prepare for RIH. 04:00-09:30 5.50 RIH from 3,337' to 5,426' work tight spots at 5,160', 5,226' - 5,266'. Take survey & confirm in wrong hole. 09:30 -12:00 2.50 POOH from 5,426 to 5,045'. RIH to 5,045', orient tool to line up with kick -off at 5,100', wash & ream at 500 gpm, 1900 psi, 60 rpm & 5 k ft -Ibs torque. Continue to RIH to 5,430' & taking weight. Confirm in wrong hole. POOH to 5,045', wash & ream kick -off point at 500 gpm, 1900 psi, 60 rpm & 5 k ft-Ibs torque. 12:00 -16:30 4.50 Wash & ream at kick -off point from 5,100' to 5,235' using time drilling & MWD data to successfully get into new hole. Work section a couple times & continue in the hole. 16:30 -24:00 7.50 RIH from 5,235' to 10,358' filling DP every 2000'. Had to pump from 9,900' at 140 gpm & continue to RIH. Made MAD pass from 10,230' to 10,275' at 1 ft/min. 06/24/2008 00:00 -02:00 2.00 TIH from 10,358' to 11,103' working tight spot at 10,535', 10,672', 10,740', 10,878', pumped at 150 gpm through tight area's. Ream from 11,098' to 11,103' at 125 rpm, 15 k ft-Ibs torque, 150 gpm & 700 psi. 02:00 -07:30 5.50 Circ & cond mud & clean hole. Did a step rate increase on gpm from 150 to 500 in 50 gpm increments over 10 min each to check loss rate. Notified Lead Co Man of rates & established 300 gpm rate for 3 hrs. Mix 100 bbls of 100 ppb LCM pill. Mix & pump 100 bbls lube pill & spot on bottom. Monitor well to confirm breathing - flow back rates of 74 to 26 gpm. Gained a total of 41 bbls back. 07:30- 09:00 1.50 POOH from 11,103' to 9,788' with no difficulties.. 17 1 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 09:00 -10:00 1.00 Circ hole & spot 100 bbls LCM pill outside the bit at 9,788'. ' 10:00 -11:00 1.00 POOH from 9,788' to 8,746' with no difficulties. Hole in good shape. 11:00 -14:00 3.00 Circ & cond mud & hole at 150 to 500 gpm, 1400 psi, 150 rpm & 15 k ft -Ibs torque - loss rate 140 bbls/hr. 14:00 -24:00 10.00 POOH from 8,746 to 3,340' pumping metal displacement plus swab volume = 80 stks= 7 bbis. Worked top stabilizer & bottom stabilizer/bit extensively through window area from 5,160' to 5,140', assuring 3 ' x that we could go out 5', 10' & 15' & back in with out pumping this entire process. Take survey at 5,235' / MWD- bit / 5,203', survey confirmed in correct hole. POOH to 4,760'. 06/25/2008 ' 00:00 -01:00 1.00 POOH from 4760' to 3337'. 01:00 -01:30 0.50 Circ & cond mud at 500 gpm, 150 rpm, 1500 psi & 4 k ft -klbs torque. 01:30-03:00 1.50 POOH from 3337' to 1059'. 03:00-03:30 0.50 Repair pin on elevators. 03:30-04:00 0.50 POOH from 1059' to 680'. ' 04:00-05:00 1.00 Rack back HWDP, DC & lay down subs. 05:00 -07:00 2.00 Lay down BHA, remove Nukes & down load MWD. 07:00 -08:30 1.50 Lay down BHA, pull pulser, stand back MWD, break off bit & lay down Geo Pilot. 08:30 -09:00 0.50 Clear rig floor of exess equipment. ' 09:00 -10:30 1.50 Nipple down BOPS, change upper ram to 7" csg ram. Change saver sub on top drive to XT -39 & install stab guide. 10:30 -12:00 1.50 Pull wear ring, set test plug & make up cross overs & valves. 12:00 -13:00 1.00 Finish making up test equipment. 13:00 -16:00 3.00 Test BOPE per AOGCC, Nabors & Pioneer Policies. Held each test 5 min & charted same. Annular 250/2500 psi, 7" rams, dart, HCR Kill & choke, safety valve, manual choke & kill valves, IBOP, #5 choke manifold valve, lower IBOP, blind rams, 250/3500 psi. Performed accumulator draw down. Jeff Jones with AOGCC waived witnessing test. 16:00 -17:00 1.00 Lay down test equipment, pull & lay down test plug. ' 17:00 -19:00 2.00 Break out collar on joint of 7" casing & while attempting to torque with Baker Lock applied to thread; tube on joint was egg shaped. 19:00 -21:00 2.00 Lay out damaged joint, pick up spare, back off collar, pick up second joint, clean threads & Baker locked same, installed reamer rloat shoe & centralizers. 21:00 -24:00 3.00 Rig up casing spiders, elevators, tongs, Franks fill up tool & changed bales. 1 06/26/2008 00:00-01:00 1.00 Make up float equipment & verify floats open with circ. 01:00 -07:00 6.00 Run 7 ", 26 #, N -80 casing from 120' to 3,376' filling every joint with Franks fill up tool. Install ' centralizers & stop rings on first 90 joints. 07:00-07:30 0.50 Circ & cond casing volume at 3,376', 1600 stks, 300 gpm & 700 psi. 07:30-12:00 4.50 Run 7" casing from 3,376' to 6,619'. Fill every joint with Franks fill up tool. 12:00-20:30 8.50 Run Casing from 6,619' to 1,1045'. 20:30 -21:30 1.00 Make up Vetco Hanger & landing joint. ' 21:30-23:00 1.50 Slack off to 11068', tagged obstruction, attempted to break circ at 5 spm, 750 psi with no returns. Work casing 10' attempting to break circ. Picked up to 400 klbs to break casing free. No returns. 23:00-24:00 1.00 Lay down casing landing joint & Franks fill up tool. ' 06/27/2008 00:00-01:30 1.50 Install cement lines & rig up cement head. 01:30-04:30 3.00 Circ casing volume increasing circ rate 0.25 bbls/min each 5 minutes up to 6 bbls/min. Losses approximately 70% with 460 bbls pumped. 04:30 -05:30 1.00 Take on 300 bbls of 10.4 ppg OBM from RSC into Pit #5. Held PJSM for cement job. Flush lines & pumps with OBM. 05:30-07:00 1.50 Pump 10 bbls pre flush. Test lines to 4000 psi. Drop 1 plug, load 2 plug, pump 40 bbls of 12.0 ppg spacer. Drop 2 " plug, mix & pump 56 bbls premium cement at 15.8 ppg, yield 1.18 cu ft/sk, 314 cu/ft slurry. Mixed with sea water + 0.55% Halad -344 + 0.2% CFR -3 + 0.25 Ibs/sk Super CBL + 0.25 % SCR - 100. Drop top plug with good Indicator shift of plug launch. Chase with 3 bbls water. ' 07:00 -09:00 2.00 Displace cement with 421.5 bbls 10.4 ppg OBM at 6 bbls/min, 1480-1800 psi. Bumped plug with 5119 strokes (433 bbls at 96 %). Pressure up to 3500 psi & chart same for 30 min for casing test. Cement in place at 08:20 hrs. 09:00-11:30 2.50 Close annular & WOC due to not landing 7" on hanger. Clean pits & rig floor. 11:30 -14:30 3.00 Lay down cement head & suck out landing joint. 14:30-15:30 1.00 PJSM, Nipple down BOP, raise stack for emergency slips. 15:30-16:00 0.50 Set 7" emergency csg slips with 200 klbs on weight indicator for a net 150 klbs tension on slips. 16:00-17:30 1.50 Rig up & cut 7" casing, 20.80' cut off placing shoe at 11066.5'. 17:30-18:30 1.00 Set pack off. ' 18:30-20:00 1.50 Test pack off to 4300 psi for 10 min. Witness by Vetco Service Rep & PNR Drlg Rep. 20:00 -21:00 1.00 Lay down hanger & landing joint. 21:00 -21:30 0.50 Make up test plug & install in well head. 21:30 -24:00 2.50 Rig down casing elevators & change out bales. 1 18 1 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 06/28/2008 00:00 -00:30 0.50 Change Elevators from 7" to 5" DP. 00:30-03:30 3.00 Lay down 8 3/4" BHA. 03:30 -10:00 6.50 Install mouse hole in rotary table & lay down 15 joints HWDP, jars & 93 joints 5" DP. 10:00 -11:00 1.00 Clean rig floor. Pull & lay down mouse hole. Pull test plug & install wear ring. 11:00 -13:30 2.50 Change elevators. Make up XO & mule shoe. RIH picking up 20 singles of 4" DP. 13:30 -14:30 1.00 Repair iron roughneck spinners. 14:30 -17:30 3.00 Pick up 4" DP for total of 96 joints to 3168'. 17:30 -18:30 1.00 Re- position 4" DP in derrick before POOH. 18:30 -21:00 2.50 POOH with 32 stands of 4" DP & rack on Drillers side of derrick. 21:00 -21:30 0.50 Remove wear bushing & install test plug in well head. 21:30 -24:00 2.50 Change upper & lower rams from 7" & 5" fixed rams to 4" fixed. 06/29/2008 00:00 -00:30 0.50 Change upper & lower rams from 7" & 5" to 4" fixed. 00:30 -01:00 0.50 Make up test equipment. 01:00 -04:00 3.00 Test BOPE per AOGCC, Nabors & Pioneer guide lines. Test annular, upper & lower 4" fixed rams, blind rams, 14 choke manifold valves, upper & lower top drive !BOP, safety valve, inside BOP, manual choke, hydraulic choke, 2 HCR valves, kill line valve & choke line valve to 250/3500 psi for total of 28 components. Performed accumulator test, 3000 psi system pres, 2000 psi after closure, 200 psi attained in 16 sec, full pres attained 1 min 19 sec. No failures. Choke manifold was tested while picking up & racking back 4" DP in derrick. AOGCC Rep Lou Grimaldi waived witness of test. 04:00-05:00 1.00 Blow down lines, Install wear bushing & rig down test tools. 05:00-09:00 4.00 Make up 6 1/8" steerable BHA. 09:00 -10:00 1.00 Down Load MWD. 10:00 -11:00 1.00 Shallow test MWD at 243 gpm & 1390 psi - all test OK. Load Nukes. 11:00 -12:00 1.00 Make up 6 1 /8" steerable BHA. Install flex collars, circ sub & ball catcher to 226'. 12:00 -13:00 1.00 Make up BHA, pick up HWDP & Jars. Clear floor . 13:00 -13:30 0.50 Break circ & test Geo Pilot. Blow down top drive. 13:30 -17:00 3.50 Pick up 4" DP singles to 3146'. (Freeze Protect 9 -5/8" x 7" annulus with 86 bbls water base mud, 10 bbls OBM, at 3 bbls/min, 1000 psi, with 60 bbls diesel at 2 bbls/min, 1150 psi, 1000 psi shut press 14:30 -15:30 Hrs) 17:00 -24:00 7.00 Pick up 4" DP singles from 3146' to 8612'. Fill pipe at 6000'. 06/30/2008 00:00 -04:30 4.50 Picked up 4" DP singles from 8,312' to 10,833'. 04:30 -05:00 0.50 Wash & ream from 10,833' to10,930'. 05:00-06:00 1.00 Circ & cond mud. Circ bottoms up. 06:00-07:30 1.50 Slip & cut drill line. Service top drive. 07:30 -08:30 1.00 Wash & ream from 10,930' to10,978'. Tag cement. 08:30 -09:30 1.00 Trouble shoot detection on MWD, no pulse. Circ. 09:30 -12:00 2.50 Drill plugs, cement & float equipment from 10,978' to11,045'. 12:00 -12:30 0.50 Drill cement & float shoe from 11,045 to 11,067'. 12:30 -15:00 2.50 Clean out rat hole from 11,045' to 11,103' & drill new formation from 11,103' to 11,122'. 15:00 -16:30 1.50 Circ & cond mud for FIT at 11122'. 16:30 -17:00 0.50 Perform FIT test at 11,067' MD / 6224 TVD at 0.5 bbls/min with 10.4 ppg, 760 psi for an EMW of 12.75 Tp9 17:00 -20:00 3.00 Trouble shoot MWD detection. Attempt different flow rates & pressures on discharge dampners. 200 gpm gave best detection. 20:00 -24:00 4.00 Directional drill 6 -1/8" hole from 11,122' to 11,253'. 07/01/2008 00:00 -06:00 6.00 Directionally drill from 11,253' to 11,508'. 200 gpm, 3,030 psi on , 2,790 psi off, rpm =120 psi, torque on = 10- 12klbs, torque off =8k ft -lbs, pick up weight = 225k1bs, slack off weight = 100klbs,rot = 130klbs, wob= 7klbs. 06:00 -07:00 1.00 Trouble shoot detection problem with MWD & directional equipment. 07:00 -08:00 1.00 Directionally drill from11,508' to 11,551'. 243 gpm, 3,580 psi on, 3,450 psi off, rpm =140, torque on =12- 14k ft-Ibs, torque off = 9 -10k ft -lbs. 08:00 -09:00 1.00 Trouble shoot detection problem with MWD. 09:00 -10:30 1.50 Directional drill 6 -1/8" hole from 11,551' to 11,605'. 10:30 -14:00 3.50 Trouble shoot detection problem with MWD. Change pump dampner pres, change out transducer. 14:00 -23:00 9.00 Directional drill 6 -1/8" hole from 11,605' to 11,991'. 23:00 -24:00 1.00 Circ & cond mud - ECD's staying higher than usual. Circ to verify hole cleaning at higher pump rate & 79 spm, 278 gpm, 4,450 psi & 150 rpm. 07/02/2008 00:00 -09:00 9.00 Directional drill 6 -1/8" hole from 11,991' to 12,474'. 09:00 -09:30 0.50 Circ hole & work pipe from 12,474' to 12,377' due to ECD's reaching 13.5 ppg. Circ at 250 gpm with 3880 psi & 140 rpm. 09:30 -10:30 1.00 Circ hole & work pipe from 12,474' to 12,377' due to ECD's reaching 13.5 ppg. Circ at 200 gpm with 2,990 psi & 140 rpm. Rack back 1 stand. 19 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 10:30 -11:30 1.00 Circ hole & work pipe from 12,377' to 12,281' due to ECD's reaching 13.5 ppg. Circ at 250 gpm with 2,990 psi & 140 rpm. 11:30 -12:00 0.50 Wash & ream from12,377' to 12,474' using 250 gpm at 3900 psi, torque 12 k ft -Ibs at 140 rpm, ECD at 13.26 ppg. 12:00 -12:30 0.50 Circ & cond hole at 12,474' with 250 gpm, 3,700 psi & 120 rpm. 12:30 -13:30 1.00 Backream from12,474' to 11,750' using 200 gpm, 2500 psi & 50 rpm. 13:30 -16:30 3.00 Backream (Mad Pass) from11,750' to 11,610' using 200 gpm, 2500 psi & 50 rpm, reaming at 50 fph. 16:30 -18:00 1.50 Working through tight spot, hole packing off at 11,610' - pulled 30 klbs over. 18:00 -24:00 6.00 Backream (Mad Pass) from11,610' to 11,315' using 225 gpm at 3000 psi & 50 rpm reaming at 60-70 fph. Pick up weight 230 klbs, slack off weight 105 klbs, 11 k ft -Ibs torque & ECD of 11.85 ppg. 07/03/2008 00:00 -04:00 4.00 Backream (Mad Pass) from 11,315' to 11,102' using 225 gpm, 2,800 psi & 50 rpm. Ream at 60-70 fph. Pick up weight 220 klbs, slack off weight 110 klbs, rotary torque 11 k ft -Ibs & ECD 11.85 ppg. 04:00 -04:30 0.50 RIH from 11,102' to 11,300'. Collecting torque & drag data points at 11,300' no pumps running. Pick up ' weight = 220k1bs, slack off weights = 107kIbs, rotary torque =145k ft-Ibs, torque 11 -13k ft -Ibs. 04:30-06:30 2.00 Circ & cond hole with 2 bottoms up at 250 gpm with 3430 psi. After circ collect torque & drag readings at 11,300'. 06:30-07:00 0.50 Service rig & top drive. 07:00 -07:30 0.50 POOH into casing shoe from 11,300' to 11,025' -no problems. 07:30 -08:30 1.00 Circ with no rotary & 120 gpm at 1,300 psi. Analyze Mad Pass data. 08:30 -10:30 2.00 RIH from 11,025' to 12,474' & hit tight spot at 12,068'. Make up top drive & wash from 12,050' to 12,177'. Wash to bottom from 12,369' to 12,474' using 140 gpm at 1430 psi & 65 rpm. 10:30 -12:00 1.50 Directional drill 6 -1/8" lateral from 12,474' to 12,530'. 12:00 -24:00 12.00 Directional drill 6 -1/8" lateral from 12,350' to 13,053'. 07/04/2008 00:00-03:30 3.50 Directional drill 6 -1/8" lateral from 13,053' to 13,211'. 03:30 -05:30 2.00 Stop drilling at 13,211' & circ. Geologist needed to confer about hole direction & the formation being drilled. Circ at 225 gpm with 3200 psi & 100 rpm. 05:30 -09:00 3.50 Directional drill 6 -1/8" lateral from 13,211' to 13,359'. Decision made to start dropping angle when Geo Pilot would not receive commands. Attempt to trouble shoot Geo Pilot - no luck. 09:00 -14:00 5.00 Circ & work pipe from 13,359' to 13,248' while consulting with town about Geo- Pilot. 14:00 -17:30 3.50 POOH from 13,539' to 11,060'. Had tight hole from 12,670' & 11,780' pulled 20-35 klbs over. 17:30 -21:00 3.50 Pump dry job & continue to POOH from 11,060' to 7,553'. 21:00 -24:00 3.00 Lay down 54 joints of 5" DP from the derrick in the mouse hole. Note: 74 stands of 4" plus BHA still in the hole, depth 7,553'. 07/05/2008 00:00 -06:30 6.50 Lay down 198 joints of 5" DP from the derrick. 06:30-07:00 0.50 Service rig & top drive, clear floor & change out elevators. 07:00 -11:00 4.00 Flow check well bore 10 min - static. POOH with BHA#10 from 7,553' -411', without incidents. 11:00 -12:00 1.00 Rack back HWDP, lay down circ sub/ball catcher. 12:00 -13:00 1.00 Remove radioactive sources & rack back flex collars. 13:00 -14:30 1.50 Down load smart tools. 14:30 -17:00 2.50 Lay down remaining BHA& Geo- Pilot. 17:00 -17:30 0.50 Pull wear bushing. 17:30 -20:00 2.50 Set test plug & test BOP's to 3,500 psi high & 250 psi low as per AOGCC. Bob Nobles of AOGCC waived witness of test. Choke manifold was tested while POOH. 20:00 -21:00 1.00 Rig down test equipment & blow down all lines, pull test plug & install wear bushing. 21:00 -21:30 0.50 Service crown & draworks. 21:30 -24:00 2.50 Pick up BHA out of pipe shed, plug in & load smart tools, 155' of BHAin hole. 07/06/2008 00:00-02:30 2.50 Continue to pick up & make up BHA #11 components (Geo -Pilot Type) & initialize MWD system. Assemble RIH & shallow pulse test with 150 gpm = 620 psi — OK. PJSM & POOH & load nuclear sources. Once all clear sign given, continued to pick up & make up remainder of components, 155'- 411'. 02:30 -11:00 8.50 RIH with BHA #11, (8 -3/4" Geo -Pilot Type), 411' - 11,060', filling pipe as required, break circ to warm MOBM mud also. Note: circ 60 bbl's every 30 stands run in. 11:00 -11:30 0.50 Break circ at 11,060' & establish parameters with 200 gpm, 2,475 psi & 40 rpm. 11:30 -12:00 0.50 RIH with BHA #11 from 11,060' to 11,415' without incidents. 12:00 -16:00 4.00 Madd Pass per Geology request over shale sections at 180 -225 fph from 11,415' to 11,485', (Zone2) RIH from 11,485' to 11,720'. Note: saw slight tight spot at 11,600' with 20-25 klbs down, screwed into stand & rotate 30 rpm without pumping & went through without further problems. Continue Madd Pass from 11,720' to 11,790', (Nechelik). RIH from 11,790' to 11,870'. Madd pass from 11,870' to 11,980', (Nechelik). RIH from 11,980' to 12,110' & Madd Pass from 12,110' to 12,202' (Shale between Nechelik & Nuiqsut) - experienced some packing off & tight hole. Note: tried to stick string & stalled top drive. Bled off pres & pulled back to 12,180'. During Madd pass sections had screwed into stand, rotated at 40-60 rpm for accurate data points & pumped at 195 gpm. 20 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time (hrs) Elapsed Operations Breakdown Time 16:00 -17:30 1.50 Establish circ at 12,180', but while working DP down, only able to get 3 -5', without packing off, bleed off immediately, (max pull was 50 klbs over to work up). Attempted 3 -4 times & decision made to rack back a stand & work up from 12,180' to 12,088' without pumping. Established full circ with 54 spm, 195 gpm, 2,600 psi, 125 rpm, 10-11 k ft-lbs off bottom torque, pick up weights = 225 klbs, slack off weight = 85 klbs & rotary weight 138 klbs. Work stand while circ bottoms up. Observed medium amount of sand & fines across shakers. 17:30 -19:30 2.00 Continue with Mad Pass from 12,180' to 12,227' & pump at 200 gpm with 2550 psi & 80 rpm. Started packing off at 12,227' & experienced 13.5 ppg ECD spike. Continue working through tight spot & resume Mad Pass from 12,227' to 12,340'. 19:30 -21:00 1.50 Wash & ream from 12,340 to 12,380' using 200 gpm with 2550 psi & 100 rpm. Started packing off at 12,380'. Work thru tight spot from 12,380' to 12,387'. Resume washing & reaming from 12,387' to 12,547'. Started packing off at 12,547'. Work thru tight spot from 12,547' to 12,558'. Resume washing & reaming from 12,558' to 12,560'. 21:00 -23:30 2.50 Conduct last Mad Pass from 12,560' to 12,680' using 200 gpm with 2,550 psi & 80 rpm, torque 12 -14 k ft-lbs pick up weights 230 klbs, slack off weights 85 klbs. 23:30 -24:00 0.50 Wash & ream from 12,680' to 12,732'. Using 200 gpm with 2,600 psi & 80 rpm. Oooguruk ODSN -40 07/07/2008 00:00 -01:30 1.50 Wash & ream from 12,732' to 12,930' with 200 gpm, 2,460 psi, 110 rpm 13 k ft -Ibs off bottom torque, pick up weight 245 klbs, slack off weight 90 klbs & rotary weight 130 klbs. 01:30 -05:00 3.50 Begin side track troughing procedure, with stroking assembly three times from 12,930' to 12,953' at 20 fph, with110 rpm 11 k ft-lbs off bottom torque, 225 gpm, 3,460 psi. At bit inclination) showed a /+ 0.25 degree drop. 05:00 -15:00 10.00 Time drill at 5 min/in from 12,953' to 12,957'. Time drill at 4 min /in from 12,957' to 12,961'. Time drill at 3 min/in from 12,961 to 12,963'. Time drill at 2 min /in from 12,963 to 12,966'. Time drill at 11'/hr from 12,966 to 12,978'. 15:00 24:00 9.00 Directional drill 6 -1 /8 lateral from 12,978' to 13,021'. Control drill at 31 ft/hr, taking surveys at 45' intervals due to 9 degree dog leg severity. Drill from 13,021' to 13,119'. Monitor & mitigate shock & vibrations. Drill from 13,119' to 13,210' - Geo Pilot tool face changing on its own, therefore trouble shoot while drilling. Pump at 235 gpm, 3,458 psi, 115 rpm & 10-12 k ft-lbs torque. 07/08/2008 00:00 -12:00 12.00 Directional drill 6 -1/8 lateral from 13,210' to 13,658'. 12:00 -24:00 12.00 Directional drill 6 -1/8 lateral from 13,658' to 14,197'. 07/09/2008 00:00 -12:00 12.00 Directional drill 6 -1/8 lateral from 14,197' to 14,596'. 12:00 -12:30 0.50 Service top drive & associated rig equipment. 12:30 -24:00 11.50 Directional drill 6 -1/8 lateral from 14,596' to 15,161'. 07/10/2008 00:00 -12:00 12.00 Directional drill 6 -1/8 lateral from 15,161' to 15,658'. 12:00 -19:30 7.50 Directional drill 6 -1/8 lateral from 15,658' to 15,942'. Note: Had hard sections from 15,722' to 15,725' & 15,768'- 15,773'. 19:30 -22:30 3.00 Had communication error with down linking from Geo Pilot. Work on getting Geo Pilot communication back. Changed out choke on Geo Span, then pulled up hole 190' & re- established communication. Increased down link threshhold limit. Ran back to bottom with successful communication & go back to drilling. 22:30 -24:00 1.50 Directional drill 6-1/8 lateral from 15,942' to 16,000'. 07/11/2008 00:00 -00:30 0.50 Directional drill 6-1/8 lateral from 16,000' to 16,044'. 00:30 -01:00 0.50 Had to pick up off bottom & reciprocate string while mode switching MWD to set threshold value in upper limits. 01:00 -12:00 11.00 Directional drill 6-1/8 lateral from 16,044' to 16,440'. 12:00 -15:30 3.50 Experienced MWD signal detection problems at 16,440', & unable to communicate with same. Pull off bottom & attempt several different scenario's, including 260 -265 gpm, 4,500 -4,580 psi, 65 -130 rpm 7 17 -19 k ft -Ibs off bottom torque. Racked back a stand every 1 hour. While shutting down to rack a stand back, attempt to bleed off pump quickly at + /- 1,000psi, flow back string. When bringing up pump, again brought it quickly up to attempt shock to system. A small pulse was observed, could also be same frequency noise. After circ 3.5 bottoms up, decision was made to back ream lateral section & POOH for MWD tool failure. During attempts with higher flow rate, at the 265 gpm, well bore taking fluid & 9 bbls mud was lost to the formation. The well bore was able to sustain the250 gpm max. 15:30 -24:00 8.50 POOH back reaming through lateral section to 12,458' with 130 rpm, 18.5 k ft -Ibs torque, 230 gpm & 2,500 -3,000 psi. Hole good, no problems & no losses experienced. 21 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 07/12/2008 00:00 -04:30 4.50 POOH back reaming from12,571' to 11,088' at 226 gpm, 3200 psi, 14Orpm & 13 k ft -Ibs torque. Tight hole conditions at 11,550' to 11,527', over pull of 30 klbs & 19 k ft-lbs torque. POOH from11,088' to 11,026'. Had to work BHAseveral times to get top stabilizer to enter 7" casing shoe. 04:30 -06:30 2.00 Circ at 250 gpm, 3400 psi, 125 rpm & 8 k ft-Ibs torque for 1000 strokes. Continue to circ, set slips, slip & cut drilling line while completing 2 bottums up & pumping a 30 bbl, 12.0 ppg dry job. Observe well - static. Blow down top drive & Geo Span. 06:30 -16:00 9.50 POOH from 11,026' to 2,824'. Hole swabbing first 1000'. Noticed excessive wear on box/pin ends of 4" DP from 4000' to 2824'. Flag joints & lay down joint # 72 & pick up replacement. Continue to lay down 11 more joints out of string plus 2 good joints to get on even stands & stand back HWDP & flex collars. 16:00 -20:00 4.00 Held PJSM for BHA & nuclear sources handling. Remove nuclear sources & download MWD tools. Lay down all BHA & break off bit. Removed Geo Span unit & replaced with new unit & also put Sperry gang box on top motor shed using crane simultaneously. Note: No excessive or large debris found in MWD tool. 20:00 -24:00 4.00 Rig up & pull wear ring, set test plug, fill hole with water & testing BOPs & choke to 250/2500 psi on annular, 250/3500 psi on BOP & choke. John Crisp with AOGCC witness tests. 07/13/2008 00:00 -03:00 3.00 Continue to test BOPE per AOGCC requirements. All tests were 250 psi low & 3,500 psi high & held for 5 min. Accumulator system was function tested with 3,000 psi operating & 25 sec for 200 psi charge & 1 min /33 sec recharge, (5 nitrogen bottles = 1,750 psi), rig down test equipment & chart. 03:00-04:00 1.00 Pull test plug & set wear ring, (RILDS), with Vetco Gray representative, (lay down all test joints & plugs). 04:00 -08:30 4.50 Pick up & make up BHA #12, (6 -1/8" Geo Pilot type) & re -run bit #7, (FMF 3641). Run fresh 5200series Geo Pilot & make up MWD components accordingly. Initialize MWD probe & set time limit, (10hrs). PJSM held & loaded nuclear sources into carriers. All clear given & continued to make up BHA #12, while running in hole to +/ -319'. Shallow pulse test with 200 gpm, 1,000psi & break in Geo Pilot seals with 5-60 rpm, brought up at 5 rpm per min. Continue to run in hole with BHA #12 to 412' with stands from the derrick. Note: Drill pipe screen installed in top of non magnetic flex collar & ball catcher. 08:30 -12:00 3.50 Pick up & RIH with 39 joints of replacement DP, to change out flat -sided damaged DP on previous run. Pipe was drifted & rattled, prior to adding to string. RIH from 1,666' to 3,307' & fill pipe. Lay down 6 bad joints. 12:00 -19:00 7.00 RIH from 3,307' to 9,083' filling pipe every 3,000'. Note: circulated 60 bbls at each fill up station to ensure MWD working & to roll mud In hole. 19:00 -22:30 3.50 Swivel packing started leaking when filling DP. It was greased & tightened, but still leaked. Decision made to change out swivel packing & tested same. 22:30 -24:00 1.50 Continue to trip in hole from 9,083' to 10,350'. 07/14/2008 00:00 -02:00 2.00 Continue to RIH from 10,350' to 12,070', before running out usable push weight with the assembly. Pick up weight = 225 klbs, slack off weight = 100 klbs. Assembly took 50 klbs down at 12,070' & I became necessary to rotate to go down. 02:00 -09:00 7.00 Wash & ream in the hole from 12,070' to 16,433' at 200 gpm, 2500 psi, 60 rpm & 8-10 k ft -Ibs torque. Rotary weight = 140 klbs. 09:00 -10:30 1.50 Circ bottoms up at 230 gpm, 3600 psi, 120 rpm & 14 -17 k ft -Ibs torque while reciprocating pipe. 10:30 -24:00 13.50 Directional drill 6 -1/8 lateral from 16,440' to 17,108'. 07/15/2008 00:00 -12:00 12.00 Directional drill 6 -1/8 lateral from 17,108' to 17,619'. Note: having to steer Geo Pilot down at 50-90% deflection rate to keep from bouncing up & maintain 6,160' to 6,161' TVD until 17,622', where hard streak pinched off & assembly dropped below. Losses increased to 12 bbls/hr & cut flow to 200 -215 gpm rate to reduce ECD & loss rate to 8 bbls/hr. 12:00 -24:00 12.00 Directional drill 6 -1/8 lateral from 17,619' to 17,978'.. 07/18/2008 00:00-09:00 00:00 -09:00 9.00 Directional drill 6 -1/8 lateral from 17,978' to 18,364'. Experienced mud losses of 2-8 bbls/hr "TD" called at 18,364' by Geology in Town. 09:00 -16:00 7.00 Circ & reciprocate string for 22,000 strokes for 4.5 bottoms up. Shakers appeared clean & decision made to back ream out of lateral section. While circ, approx 90 min's per bottoms up & rack back 1 stand for every bottoms up. Pick up weight = 325 klbs, slack off weights = 40 klbs, rotary weight = 130 klbs, with120 rpm & 18 k ft-Ibs off bottom torque. Flow rate was 215 -230 gpm & 3,250 -3,340 psi with 1- 2 bbls/hr mud losses. 16:00 -24:00 8.00 Back ream out of lateral section from 18,267' to 14,298' pumping at 200 gpm, 3,000 psi & 120 rpm & 19 k ft-Ibs off bottom torque. Pick up weight = 280 klbs, slack off weight = 40 klbs & rotary weight = 120 klbs. No problems were encountered. 07/17/2008 00:00 -06:00 6.00 Back ream out of lateral section from14,298' to 11,026' pumping at 140 gpm, 1,560 psi, 120 rpm & 14-6 k ft-Ibs off bottom torque. Pick up weight 115 klbs, slack off weight 110 klbs & rotary weight 110 klbs. Problems were encountered at 11,709' where top stabilizer was across fault at 11,600' & spike in top 22 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time drive system torque saw +/ -19.5 k ft-lbs torque. This caused a failure in top of stand. #23, (Found failed once out of hole). Continue to pump & rotate to expected bit depth of 11,026', (actually +1- 8,429' failed DP depth). 06:00 -08:00 2.00 Circ bottoms up at 230 gpm & 1,270 psi. Increase pump & circ 2 bottoms up at 375 gpm & 2,600 psi, with steady cuttings stream decreasing on second bottoms up. Reciprocate & rotate at 120 rpm, 6 k ft-Ibs off bottom torque, pick up weight 115 klbs, slack off weight 110 klbs & rotary weight 110 klbs. 08:00 -16:00 8.00 Pump dry job & flow check well bore 5 min - static. POOH on elevators without issues & with correct hole fill. Pull to top of stand #32 & had to lay down 7 jts. 16:00 -18:30 2.50 Waiting on fishing tools to arrive from Deadhorse. Pick up & make up 9 joints of 4 3/4" spiral DC's & stand back in derrick. 18:30 -24:00 5.50 Load over shot with 4 3/8" grapple & pick up & make up fishing assembly with 3 stands DC's. RIH to 884' strapping DP & also culling & laying down questionable joints with excessive wear. (33 joints). 07/18/2008 00:00 -05:00 5.00 Trip in hole from 884' to 8,990'. SLM each stand. (lay down 3 bad Joints DP). 05:00 -06:00 1.00 Wash in the hole from 8,990' to 9,028' at 123 gpm & 800 psi. Pick up weight 170 klbs, slack off weight 100 klbs. Tagged top of fish at 9,028'. Engage top of fish setting 25 klbs down weight, with stand pipe pres increase of 400 psi. Circ ensuring full flow & start pulling on fish in slow increments up to 230 klbs over pull. Slack off increasing pump rate to 200 gpm, 2,000 psi & start pulling slowly again to 240 klbs over pull with fish coming free. 06:00-07:30 1.50 POOH with fish from 11,628' to 10,940' at 200 gpm & 2,000 psi. Pick up weight 210 kibs. Hole taking proper amount of fluid. 07:30 -09:00 1.50 Drop dart & circ at 150 gpm & 1,600 psi. Shear & open circ sub at 1,700 psi. Circ bottoms up at 350 gpm & 2,900 psi. POOH from 10,940' to10,743'. Monitor well for 5 min & pump dry job. 09:00 -12:00 3.00 POOH from 10,743' to 5,414'. Pick up weight 150 klbs. Hole taking proper fill amounts. 12:00 -22:00 10.00 POOH from 5,414' to 3,034' with 100 klbs up weight. Lay down 3 joints of DP & BHA. DC's & fishing assembly with top of fish. Lay down bad DP for a total of 32 joints from 2,610' to 1,570'. One joint had open crack 3/4 of the circumference of the tool joint. (Total bad joints laid down today = 35). 22:00 -24:00 2.00 POOH from1,570' to 570' racking back 13 good stands of DP. Up weight 70 klbs, lay down BHA, HWDP, jars, 1 joint HWDP cracked on pin end. 07/19/2008 00:00 -04:30 4.50 Lay down fished BHA #12. Hold PJSM. Lay down circ sub/ball catcher & flex collars. Pull nuke sources. Lay down stabilizer/float sub. Down load MWD tools. Lay down BHA, PWD, pull up & break off bit & lay down rest of BHA, smart tools & examine for erosion damage. 04:30 -05:30 1.00 Pick up oil jars from pipe shed with lifter, make up on it & break out lifter & lay down. Pick up overshot with fish, break out & lay down fish & overshot. 05:30 -07:00 1.50 Clean up rig floor & pick up 4 1/2" liner tools & prepare to run liner. 07:00 -10:30 3.50 Make up wire line entry guide (shoe) to first joint of slotted 4 1/2" liner with stop ring in middle & a turbolizer on both sides. Make up & run rest of liner per plan, shoe = 1.00', 3 slotted = 125.01', 18 solid = 713.57', 14 slotted = 582.52', 1 solid = 39.52' for a total of 1462.06' with 1 turbolizer on each joint. Make up packer with tie back sleeve & hanger & crossover with 7" razorback scraper assembly per plan. 10:30 -14:00 3.50 RIH from 1,595' to 3,644' with 4" DP drifting & SLM each stand. Up weight = 90 klbs, down weight = 80 klbs. 14:00 -17:30 3.50 Slip & cut 157' of drilling line. 17:30 -18:00 0.50 Service top drive system & rest of rig components. 18:00 -24:00 6.00 Trip in hole from 3,644' to 8,737' with 4" DP rabbiting & SLM each stand. Up weight 165 klbs, down weight 100 klbs. 07/20/2008 00:00-04:30 4.50 RIH 4 1/2" liner on 4" DP from 8,737' to 12,416' drifting & SLM each stand. Pick up weight 220 klbs & slack off weight 100 klbs. 04:30 -06:00 1.50 Drop ball & pick up single & make up top drive system & stage in 10' on single. Pump ball down at 20 spm, 72 gpm & 650 psi. Ball seated at 972 strokes when pres increased to 1,200 psi. Continue to pres up to 2,000 psi & set hanger. Then pressured up to 2700 psi to shear collect on running tool. Attempt to pull out of tie back - unsuccessful. Packer moved up hole 5' from 10,936' to 10,931'. Work string multiple times to pull running tool out of tie back. Apply two left hand rotations on DP. Work torque down to release. Picked up out of tie back 6', then slack off & tag up at 10,931'. Work pipe multiple times to verify liner top at 10,931. Apply 60 klbs down to set packer. Pull up & commence brine displacement. 06:00 -09:30 3.50 Prepare to displace well by mixing spacers, clear rig floor of running equipment. Pump 23 bbls Barakleen spacer, 40 bbls Barascrub spacer, 23 bbls of Barakleen spacer then chase with 367 bbls of 10.2 brine at 210 -450 gpm & 1,600 -3,250 psi. 09:30 -14:00 4.50 POOH laying down DP from10,931' to 7,161', up weight 210 klbs 7 down weight 95 klbs. 14:00 -15:00 1.00 Repair hydraulic hose on pipe skate - no spill, all contained & cleaned up. 15:00 -24:00 9.00 POOH laying down DP from 7,161' to running tools. Lay down razor back scraper & pull up & discovered liner was still connected. Got well site leader up & called town engineer & discussed the situation. Agreed to proceed to lay down liner to test BOPE & get another hanger /packer assembly from Prudhoe coming. 23 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 07/21/2008 00:00 -05:30 5.50 Had discussion with town engineer & well site leader about liner, agreed to lay down liner. Pick up casing tools to lay down 4 1/2" liner & hanger /packer assembly. Break out & lay down liner inspecting & saving each centralizer. Had tong hang up on 1 solid joint & egged, lay down & exchanged. Swapped out tongs & finished laying down rest of liner. All centralizers accounted for & in good shape. Lay down tools & clean up floor for BOPE test. 05:30 -09:00 3.50 Pick up test joint, pull wear ring, set test plug with Vetco Grey representative. Test BOPE to 250/2,500psi on annular, 250/3,500psi on both 4" pipe rams, blind rams, manual & HCR valves on mud cross. Pull test plug, set wear ring RILDS. Lay down testing equipment clean rig floor. 09:00 -10:00 1.00 Service top drive system, change out gear oil & service rest of rig. 10:00 -13:30 3.50 Pick up rig up casing tools & run 36 joints of 4 1/2" liner with centralizers on each joint & two on shoe joint with stop ring in middle of joint. Liner weight 15 klbs, up weight 55 klbs & down weight 50 klbs. 13:30 -24:00 10.50 Make up crossover in top of liner to XT -39. Pick up, make up & run in hole with 31 joints of DP from pipe shed, drifting each joint. POOH & stand back 10 stands leaving single DP to work from for next set of 30 joints. Continue process until pick up & stood back 54 stands for a total of 105 stands in the derrick. Pick up weight 75 klbs, slack off weight 70 klbs with 31 Joints DP & Liner. 07/22/2008 00:00 -00:30 0.50 Finish racking back remaining stands of DP in derrick for a total of 105 stands in derrick. Clear floor. 00:30 -02:00 1.50 Start assembly of hanger /packer in pipe shed, while rigging up rig floor with casing tongs. Pick up hanger /packer assembly on elevators & make up ball catcher, stab into liner & make up & torque connections. RIH & fill top of tie back sleeve with water /polymer mixture while laying down casing tongs. Pick up bumper jars & make up. SLM DP stands & RIH. Up weight 55 klbs, slack off weight 50 klbs & liner weight 15 klbs. 02:00 -11:00 9.00 Continue to RIH, SLM each stand to 12,366'. Pick up 2 singles, drop ball & make up top drive system. 11:00 -12:00 1.00 Drop setting ball & circ down. Set hanger with 1,000 psi & shear packer. Release with 2,500 psi. Open circ sleeve with 3,500 psi, pick up 6' & set down on liner top to set packer, with 30 klbs down weight. Note: observed packer setting pins shear at 15 klbs down weight. Liner top at 10,937'. Pick up 6' & reset weight down 30 kibs to confirm liner set. Pick up 90' (observed 15 klbs pick up weight loss, 255 kibs original pick weight, 240 kibs after liner release) & clear running tool from tie -back. Slack off & tag liner top at 10.937'. 12:00 -14:00 2.00 Lay down 3 joints of DP & circ to condition brine 2x bottoms up at 85 spm, 302 gpm & 1200 psi. Up weight 240 klbs & down weight 110 kibs. 14:00 -24:00 10.00 POOH laying down DP & HWDP from 10,841' to 2,431'. Up weight 90 kibs & down weight 80 klbs. Hole fill ok. 07/23/2008 00:00 -03:30 3.50 Lay down remaining 2,431' of DP. 03:30 -04:30 1.00 Lay down bumper jars & running tool, clear rig floor. 04:30 -05:00 0.50 Rig up & remove wear bushing. 05:00 -05:30 0.50 Make up test tools & set test plug. 05:30-07:00 1.50 Change out upper rams from 4" to 2 -7/8 ". 07:00 -09:00 2.00 Test upper rams to 250 low & 3500 high. Attempt to test annular, test failed. Pull test joint & found that is was bent, pull test plug & pick up riser washing tool. 09:00 -09:30 0.50 Circ riser clean using 425 gpm at 100 psi. 09:30 -10:30 1.00 Lay down riser washing tool, make up new test joint & set test plug. Attempt to test annular again - test failed 10:30 -11:00 0.50 Lay down test tool, drain stack & inspect annular & found it was bad. Install test plug. 11:00 -12:00 1.00 Hold PJSM on annular removal, pull riser, clean out drip pans, remove turnbuckels, remove koomey hoses & fittings. 12:00 -18:30 6.50 Change out annular preventers. 18:30 -19:30 1.00 Test annular preventers against 2 -7/8" tubing 250 low, 2500 high, retest 2 -7/8" rams to 250 psi low & 3500 psi high - held both tests for 5 min. 19:30 -20:30 1.00 Lay down test tool & test plug. 20:30 -24:00 3.50 Rig up tubing handling equipment, ESP control lines & sheaves, SCSSV control lines & sheaves. Pick up ESP pump & start servicing same. 07/24/2008 07/24/2008 00:00-06:30 6.5 Service ESP downhole pump. Finish hanging control line sheaves. Install control line & clamps. Test ESP & control lines. Install XN nipple & install sliding sleeve & run in the closed position. 06:30 -19:30 13.00 Run ESP completion on 2 -7/8" tubing. Test cable every 1000' & install Cannon clamps on every Joint. RIH from 63' to 6,300'. Install GLM with dummy at 1,609'. 19:30 -22:30 3.00 Install WFT Hydro II Dual Packer from ESP along with X nipple & RHC plug below packer & X Nipple above packer. Splice control cable & test same to 5,000 psi. Cycle test ESP vent valve. RIH with 4000 psi on control line 22:30 -00:00 1.50 Resume RIH with 2 -7/8" ESP completion from 6,300' to 6,825'. Test cable every 1000' & install Cannon Clamps on every other Joint. 24 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time Elapsed Operations Breakdown (hrs) Time 07/25/2008 00:00 -02:00 2.00 RIH with 2 7/8" tubing from 6,816' to 7,814'. 02:00 -03:30 1.50 Change out ESP spool & RIH from 7,814' to 8,061'. 03:30 -07:00 3.50 Stop at 8,061' & splice ESP cable & test. 07:00 -10:30 3.50 RIH with ESP completion from 8,061' to 10,045'. 10:30 -11:00 0.50 Pick up & install SCSSV valve. Test to 5000 psi for 10 min. RIH with 5000 psi on line. 11:00 -12:00 1.00 RIH with ESP completion from 10,060' to 10,484 ", Test ESP cable every 1,000 feet. Install Cannon clamps every other Joint. 12:00 -12:30 0.50 RIH with ESP Completion from 10,484' to 10,757'. 12:30 -13:00 0.50 Pick up Hanger & Landing joint. 13:00 -15:00 2.00 Cut ESP cable & attach same to the wellhead. Rig down ESP cable. 15:00 -16:00 1.00 Land hanger. Run in lock down screws. Test seals to 5000 psi for 10 min. Total clamps run 180, with three Bands 16:00 -18:30 2.50 Lay down running tool. Secure floor & remove sheaves from derrick. 18:30 -20:30 2.00 Change out upper & lower rams to 5 ". 20:30 -24:00 3.50 Nipple down BOP's, well head & riser. 07/26/2008 00:00-01:00 1.00 Test SCSSV line to 5000 psi for 10 min - OK. Test packer vent to 5000 psi for 10 min - OK. 01:00 -06:30 5.50 Nipple up tree & test to 5000 psi - OK. 06:30 -07:30 1.00 Rig up U -tube manifold & test to 4000 psi - OK. 07:30 -08:30 1.00 Reverse circ 85 bbis of 10.2 ppg brine with Corrosion Inhibator at 2.5 bbis/min with 1375 psi, taking returns to the pits. Lost 60 bbls while pumping brine. 08:30 -09:30 1.00 Reverse circ 70 bbis of diesel for freeze protection at 2.0 bbis/min with 1475 psi. Shut down pump & line up to U -tube. Lost 50 bbls while pumping Diesel. 09:30 -10:00 0.50 Attempt to U -tube. Note: U -tubed very slowly if at all - operation not succeful. 10:00 -11:00 1.00 Pump 10 bbls of deisel down 2 -7/8" tubing at 1/2 bbis/min with 2175 psi. Shut in well with 1,500 psi on both the annulus & tubing. 11:00 -12:00 1.00 Rig up lubricator for 1 -3/8" ball & rod & drop same. 12:00 -12:30 0.50 Pres up tubing to 3500 psi & set packer - held for 30 min. Bleed down pres to 1,500 psi. 12:30 -20:30 8.00 Pump down backside & test packer with 3,500 psi. Slowly bleed off to 2,900 psi. Pres back up to 3,500 psi - still bleeding off at 100 psi per min. Bleed annulus pres down to 1,400 psi. Pres back up on tubing to 3,900 psi to reset packer. Bleed down. Pres up on annulus to 3,500 psi. Still bleeding down. Bleed annulus pres down to 0 psi. Pres up on annulus to 3,900 psi. Tubing still bleeding down. Rig up single line to annulus to pres up. Bleed pres down to 0 on annulus & pres up to 4,000 psi. Still tossing 100 psi a min. Swap hoses to verify no surface leaks. Bleed pres down to 0 on annulus & pres up to 4,500 psi. Still tossing 100 psi a min. A total of 8 attempts were made in order to Set k test. 20:30 -00:00 3.50 Slick line & hang sheaves in the Derrick. Contacted Halliburton Slick line to ship out tools needed in order to POOH. 07/27/2008 00:00- 01:00 1.00 Held PJSM with HES on Slick Line lubricator installation. Prepare floor. 01:00-04:00 3.00 Rig up lubricator & tools. eeded parts coming from Pruhdoe Bay. 04:00-04:30 0.50 Test Ibricator to 2000 psi - OK. 04:30-06:30 2.00 RIH with 2.313" PX Body to 4,483' & set same. 06:30 -07:00 0.50 POOH with slick line. 07:00 -08:00 1.00 Drain lubricator & make up P- Prong. Inner annulus pres 1,375 psi & tubing pres 1,170 psi 08:00 -09:00 1.00 RIH with P -Prong to 4,438' & set same, POOH. 09:00 -09:30 0.50 Bleed tubing pres off to 0 psi & make up GLM dummy retrieving tool. Bleed inner annulus to 0 psi, wait 5 min. Close back in, pres increased to 500 psi & stabilized. 09:30 -11:00 1.50 RIH with GLM Dummy Retrieving tool to 3,973'. Inner annulus pres 500 psi, tubing pres 0. Equilize inner annulus & tubing pres. Retrieve GLM Dummy & POOH. Inner annulus pres 475 psi & tubing pres 575 psi. 11:00 -12:00 1.00 Circ 141 bbls of 10.2 ppg brine down tubing displacing diesel out of hole & take returns up the annulus & to pits. Pump at 3 bbls/min & 400 psi. Shut down pumps with inner annulus pres of 0 psi & tubing pres of 0 psi. 12:00 -12:30 0.50 Shut well In & monitor pres. 12:30 -13:00 0.50 Circ 20 bbis down tubing, taking returns from inner annulus to pits at 127 gpm & 525 psi, swap lines. 13:00 -13:30 0.50 Reverse circ down inner annulus & up the tubing. Pump 22 bbis at 127 gpm with 525 psi. 13:30 -14:30 1.00 Shut well in & monitor pres - inner annulus= 100 psi & tubing= 100 psi. 14:30 -17:30 3.00 Make up GLM Dummy Running tool & RIH to 748' - having trouble going in the hole. Pull up into lubricator. 17:30 -18:30 1.00 Circ 60 bbis down tubing, taking returns from inner annulus to pits at 127 gpm & 525 psi. Monitor pres. 18:30 -19:30 1.00 Open Master valve & RIH with GLM Dummy Running tool & blank to 3,973' & set blank. 19:30 -21:30 2.00 RIH with Slick Line to 4,483' & pull P -Prong & PX Plug. 21:30 -22:30 1.00 RIH with Slick Line to 4,517' & pull rod & ball. 22:30 -23:30 1.00 RIH with Slick Line to 4,517' & pull RSC valve. 23:30 -24:00 0.50 Rig up Lines to test inner annulus another time. 1 25 1 1 DAILY ACTIVITY (I.A.D.C.) Pioneer Oooguruk ODSN- 40PB1, ODSN -40PB2 & ODSN -40 Time (hrs) Elapsed Operations Breakdown Time 07/28/2008 ' 00:00-00:30 0.50 Pres up inner annulus to 1500 psi & observe - leaking at 100 psi /min. 00:30-05:30 5.00 Make up HES Sliding sleeve Shifting tool & RIH to 10,648' & attempt to shift sleeve - not succesful. 05:30 -06:30 1.00 POOH with HES Sliding sleeve Shifting tool from 10,648' to surface. Add one additional weight bar to tool. 06:30 -08:30 2.00 Make up HES Sliding sleeve Shifting tool with additional weight bar & RIH to 10,648' & attempt to shift ' sleeve - not succesful. 08:30 -09:00 0.50 POOH with HES Sliding sleeve Shifting tool from 10,648' to surface. 09:00 -10:30 1.50 Annulus & tubing pres reading 0 psi. Monitor centralift down hole pres at pump = 3,230 psi. Open vent valve & monitor annulus for pres & flow - none observed. ' 10:30 -12:00 1.50 Pres up inner annulus with vent valve opened to 100 psi to establish communictions with ESP pump. Note: 68 psi was observed at ESP pump. Bleed off press & monitor well. 12:00 -12:30 0.50 Shut ESP vent valve. Pres on Inner annulus & tubing 50 psi. 12:30 -14:00 1.50 Wireline, blow down lines & rig down same. 14:00 -14:30 0.50 Nipple down tree & install back pres valve. 14:30 -15:00 0.50 Install TST dart in hanger. 15:00 -16:00 1.00 Nipple up BOP's. 16:00 -16:30 0.50 Change out BPV -TWC. Remove dart. 16:30 -17:00 0.50 Conduct landing joint Dummy Run. ' 17:00 -19:30 2.50 Finish nippling up BOP's. Change out Vetco 0-Ring. 19:30 -21:30 2.00 Change upper & lower rams to 2 -7/8" 21:30 -22:00 0.50 Pick up test tools & 2 -7/8" landing joint. 22:00 -23:30 1.50 Make up test tools & TIW, cross over & dart. 23:30 -00:00 0.50 Test BOP's to 250 psi low & 3500 psi high. Wittness waived by Lou Gimaidi of AOGCC. ' 07/29/2008 00:00 -07:30 7.50 Test BOP's to 250 psi low & 3500 psi high holding each test for 5 min. 07:30 -08:00 0.50 Lay down test tool. ' 08:00 -10:00 2.00 Pick up 48 joints of 5" DP & rack back as a back stop for 2 -7/8" tubing. 10:00 -12:00 2.00 Finish rigging up spools, sheeves & handling equipment for 2 -7/8" tubing. 12:00 -12:30 0.50 Pull TWC out of hanger. 12:30 -13:00 0.50 Make up landing joint. 13:00 -13:30 0.50 Back out lock down screws on wellhead. ' 13:30 -14:00 0.50 Pick up & release packer using 30 klbs over pull, 108 klbs string weight, 148 klbs with blocks. Monitor Well. 14:00 -14:30 0.50 Disconnect ESP cables & control lines from hanger. 14:30 -17:00 2.50 Lay down landing joint & hanger. ' 17:00 -00:00 7.00 POOH with 2 -7/8" ESP productin string from 10,802' to 6,830'. Lay out SCSSV valve & GLM. Spool ESP cable & control Line, 3 bands & 64 clamps. 1 1 1 1 1 1 1 26 1 r cay 3 9�x � r /' + jr/ k; ;NW / i ce . s ' ,l// Customer: Pioneer Natural Res. Report #: 1 1 A HALL1BURTON Well: ODSN -40 Date: 05/08/2008 -5:00 Area: Oooguruk 05:00 Depth 566 Location: North Slope Progress 24 hrs: 566 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drill Surface Job No.: AK -AM- 0005710855 Report For: Rod / Herb ft Daily Charges $3,500.00 Total Charges $3,500.00 y f r . 1 � � . i,.� ., x /,. =; ,it ,,.::ii: „/1 3 '° �� ROP &Gas: Current Avg 24 hr Max Max 0 ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr 91.0 185.0 434.0 336 Flow in • •m 499 SPP •si 275 31 22 61 540 Flow Rate s • m 142 Gallons/stroke 3.6 x ,^ -.a /' £x % %jj 'r 9 ;� �� f�r� %;* ;.;%' ` i / /r' rr' %��' / ✓�. �' � � r f /�. �v r'`1... y�/<a` � .f<;1 .. .... ,.y /ri'� x� ,,,. /a. � //� /ra . .,;, .,, � � '. s / �/G .� ;cz.��� r , r. , /rr i /.�,, .i% - ,,, ✓,,,,,:, ... , L � : ,'', Mud Data: Density (ppg) Viscosity FILTRATE PV VP Chlorides Hard Alkal Md Cor Solids I Death in out sec /•t cc /30 min cP Ib /100ft m. /I Ibs/bbl Pm 8.9 8.9 80 9.5 15 45 34,000 800 0.10 1.6 ,v / ✓ p k : ' w. </r;' ' . :: ✓ i r r/ * g. ro r % - I I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1 MXL -1 12.25 .699 4.3 153 2 to 5 62 r /ir /{ : /m rr //i rj:Of ,' : ' § /r ,oir I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current ---- _� - - -� -- /� / i r�< /r� /// ,P.: fr; ,, e � rn ; ', ;f r f :'; �r.�6xr, �/..4.144. x7�// s,,,, �i?r� x :;✓ � �r�.. ^,"�"r �...`.'. .:b � . ../�'/ ice..... , >'. ;. ? � / %,..,,��, „a. � ,r,r /,.`�;- i /� >,5../,,�.:ikk ,. . �i<ry,,; 1 r Gas Breakdown '' Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I 228 to 568 61 22 5055 0 0 0 0 to to to I to to fi to ' to to to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; , BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas - ,. :.. i / /t �' y r /,/"T " ,.e :: L se,� .r r/r/'"` / 4 1 y y ":r:".. /./�,�� :: .ld� /ll" y r o , z . cz//�rr�/'�,�� .< / �. saYm� /�/ .�;��,� /,, �� � /%�r/,'�" .,.,L.�� .,. !s ,,.. �o� r;r / / /�t�f��:, t a ' f 24 hr Recap: Moved rig over ODSN -40. Nipple up riser. P/U directional BHA. Transfer 600 bbls 8.9 ppg hi vis spud mud to r pits. Drill to 266' and P/U MWD. Drill ahead. 1 I Sample Catchers : Andrew Chilton / Steve Mircovich (off location) Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air • ' .,. �r%"�_;% „ar /,,, ✓. »;u.rr� ...1... r ...�. � r,,,...k I: ., t'A. ., .a:i. ,,;r. � . 1 1 ' rr ✓ ✓fir . �" -,.%S� .% / ; /ter/ � - "` &.✓ R , ,,`,', r , � , , „. /, ��1, �'`. ',�.��`�.s,- "��A71Y!'/f,!�3�f,, .� %// /���� F 'Alf ���"���/ %� ,. � „ �, ����, z i .,. , ,, ,,. ,r��,..`��,a.'�//'!�i /��M !.9 , ,� s /... ";1'L' Customer: Pioneer Natural Res. Report #: 2 I Well: ODSN -40 Date: 05/09/2008 -5:00 ' Area: Oooguruk 05:00 Depth 1645 Sperry Location: North Slope Progress 24 hrs: 1079 1 j. Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drill Surface Job No.: AK -AM- 0005710855 Report For: Rod / Herb Daily Charges $3,500.00 Total Charges $7,000.00 1 r ., � / . � j / ,. i� ,,, y . : ;/ i% i - ,% � .... . / % . . %a Js r r )� .,. �✓ � 'i � a� „� -... ���/ ..... ,. , .F ✓, / / ,. � >. ,c,. ! , .” �� a ... , r � 9 , x +� /;�, 'f�1 ._.,�. ✓. ..,. ROP &Gas: Current Avg 24 hr Max Max 0 ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr 176.0 136.0 275.0 623 Flow in • •m 500 SPP •si 995 26 57 136 1175 Flow Rate s • m 141 Gallons/stroke 3.6 ✓ y o,, % !�!� ✓J /' f � r b h / ✓ '�. `` ���` ✓ �. l : - 3✓ �/s/✓/'"F ;.. % r '�' "' ' .. �' i ✓ /i r x' '.. fi /.G.�.,./ �� ������N s ..v_ : ���,.�r talk .�.��'� ":. �r ,',,,',;. , s;,7r .. 'v� ,����r „!i �✓�.ia .. .�l%%r.,::- s�X/�� /�r � '�,. . , ��,.r. ,3 .�ij,F ilrh .'. Mud Data: Density (ppg) Viscosity FILTRATE PV YP Chlorides Hard Alkal Md Cor Solids I Death in out sec /at cc /30 min cP Ib /100ft m• /I Ibs /bbl Pm % 9.5 9.5 70 10 19 44 34,000 600 0.10 5.2 ,, ."11 `:,,:' G r,,,,;'.j ;-.,” ,,` A .t.'. , , �j/ ,, ,' ,;:a ,lG �, .�. 1 ".* BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1 MXL -1 12.25 .699 13.2 153 1492 5 to 10 68 .41g: y ✓% j a x 'yam r 1' r 3 . / . .-i i " f • .. / 1i I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current ----- -� - -�- 4 .: . ...' ? ..,;' /„/%:.'�. s,� ;,. s n, t „ ,II .....,aFb.., ,., ,li ,'„ ...... • 1 Gas Breakdown ` Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I 568 to 1585 136 57 13491 0 0 0 0 y to to t0 t0 to to to 1 to to to I if Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 2 hr Recap: Drilling ahead building angle. 1 I j' Sample Catchers : Andrew Chilton / Steve Mircovich (off location) Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air in ' %iii I : '11111P /���� /. i/.,'.� / ,,,;. <� ,,,,., �' �S J, : Iii ..k.::. . if !.,.v � . /;,M ra'.. 1 1 1 ,±c /`,%°,g..,. *. , a .,,,,;,.. ".. ..9'�7i IX i . '. _ . : F�'�..✓�.���, „2. . , ,.,:% dr;:, Customer: Pioneer Natural Res. Report #: 3 I T Well: ODSN -40 Date: 05/10/2008 -5:00 Area: Oooguruk 05:00 Depth 3335 4. Location: North Slope Progress 24 hrs: 1690 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drill Surface Job No.: AK -AM- 0005710855 Report For: Rod / Herb Daily Charges $3,500.00 Total Charges $10,500.00 u ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING � ; R.O.P. ft/hr 176.0 136.0 275.0 623 Flow in • •m 649 SPP •si 1750 I 3/ s KEEMEMII 26 29 57 2487 Flow Rate s • m 183 Gallons/stroke 3 6 17i ��/ / � / �/ .. _ ,. rr, s // , & p/ /r' r ;W� ij / �r�, /� . %�S �f Fi / �; ,a / - ,..1:;;,;��%, ��r,: �, r� 4. . �;.a�� f.41.. .4X rr ' ,.,aarv� ... _. �i /// o ,,..,. w��c, > �„r� � ,,,'.�...�� r v; , s , �.�`"✓' ./�. 1 '. Mud Data: Density (ppg) Viscosity FILTRATE PV YP Chlorides Hard Alkal Md Cor Solids I De in out sec /•t cc /30 min cP Ib /100ft m• I Ibs /bbl Pm % 9.3 9.3 90 10 22 46 34,000 600 0.19 4.7 'f' ilitoW a,,,mr, a, ,. ., ..- .11 ,✓/�i„°.. :`�..F.'r .. Taff- + ��;� .., ; n- st ✓'. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 1 MXL -1 12.25 .699 13.2 153 3182 25 94 � . a l% ;yi � '” , � // /r s t,'i / f /// : %� / /„r,? yr /r /yr . r,. , � : / , ..asp r j // /,,,,,,, , �' ?���lF ,,, ,;,, r,�,fi/..., >��j /� ,, 3 ,�F, :.� � ��:.� / %,r.,,..��,. Vii , , „ ,., , , , -,'i� SO '� „��i,,,��� /r ,... ,! /, i , ;w I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current -- _--- - - - - -- "� Z '' .>3:,!,trr,, Q�a . ,,,i„ y.. . .. . *c . s �. �. / ✓/ �;.s , /,.,,. I Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 1645 to 3335 57 29 5617 0 0 0 0 to to to I ii t . : + to to to to I to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas TG - Trip Gas � r , � /4 r ,'e /r s Y l.~f rr / / ' r r'�,'/ r r ; .w,��.yrr rr� / /r / ' ; i i i r y ,, c t � %� /� : j /r /y:: �/ ti� /ir / . / r / ki ii `� <% � " „�� � r,� „ , .,,,� .` r ..,,��' IOW: ��„> T -° � � r� r�::r i /� / s�i,'..�r,� . �// .. /!:e.. /�;�vl�ll.�..�.�,������� 24 hr Recap: Drilling ahead building angle. - r I Sample Catchers : Nick Douck / Steve Mircovich Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air r q 3' v ;. r r as;� r r / r rp / % //7/ � Ji 1 . � r i y / �� : �i // r / %' iU, l �/"/ • ', r� t -.., �/ /.., y ,. i ../ r /fir . r / ; /�',. j ;;r r G /� r; �,;,: F r: f� r % ,,,.,� /,.�,.,�Nc��wr „ : �� /./ /..���,�y!�.f /. ,,, !;�; ,.3.,,��,r�" /i //.ri`i %� b�:, ..,H,.�;£/ /. �a�c„ .ul,��,...v�. / /,U„ // _._,,.,,� .,, .,, ,.�„ ��,��/r //r� ✓ /,l.r.; /r,, ., r / „ < I 1 1 -' r rax .4. ''. / ;"s •r; a Alta ''.* , ilii 1 , - Customer: Pioneer Natural Res. Report #: 4 1 Well: ODSN -40 Date: 05/11/2008 -5 :00 '< Area: Oooguruk 05:00 Depth 3420 Location: North Slope Progress 24 hrs: 85 1 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Trip Out Job No.: AK -AM- 0005710855 Report For: Rod / Herb Daily Charges $3,500.00 Total Charges $14,000.00 e. 1 / i // %''' , .74: A y'i 'r�i . r a"�// 6rii /lri /r = 1a/ /i . ...,. i's' :Mb ,•?� . , i / „r`''i. ..r�".� �i,. 1 r ROP &Gas: Current Avg 24 hr Max Max CO ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr NA 69.0 125.0 3348 Flow in • •m 649 SPP ssi 1750 I F NA 37 60 3384 Flow Rate s•m 183 Gallons /stroke 3.6 y „f y %% r %ma y ;' /rr / fi /� s r y . i3 ANN. ✓ .: x / 310: roc ., / F . %i � 2 r r,;:<:� �. /ri;;yaD.' ' �� /li,��i ..,.��/6�s,, .� �",y�i���ir., .,.,._,,,,,y�"�lr�••, „ .,, :..,a�,�%.NLor ,•,z��'/,''^�... . :/i r,��,,, ' �,,,.,,.. .,, Mud Data: Density (ppg) Viscosity FILTRATE PV YP Chlorides Hard Alkal Md Cor Solids I De•th in out sec /•t cc /30 min cP Ib /100ft m I Ibs /bbl Pm % 9.4 9.4 50 10 14 28 34,000 600 0.10 5.2 *:. �; , „y r , ; . . i ✓ j ,. r/ / r / ; E /7cs / /f,. ' ' ,,,,� /.r / j.. /r,�/ // .� `� /':;- r � '% Y,,, cy. ` %'.... �'� r „ „.r,,�F„xs,: „i�';,.. %, ,%z / <, fir, ✓,; %j�f`"� /r„ ,�� /,,, y; - c., ,::- ,x /� „�,> ,,q�- �s /�, /�, ..,.? BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 1 MXL - 12.25 .699 30.8 153 3420 3267 25 94 / rii4 ” r rcir,rF✓y�i c r 'r Y �� % y i / g r fi, %r ,'' r r1' ✓iy' %r , r , ' '.. .' ari..t.� . -' �r ��.���'�i, ���, sit . � � i � .. •r c, �� ,+, . / ,; �� /„ ��„ ::' 'ay,.�; /fir„ , /c��, ';>;,,,,4 =`�'sr,. , ^�.� '�.r', ,,,,�, ,,, ,y,,�.%� , ,,>. ,�E., �/,�/r„rfr.' I r Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current ------ - - -� -- r� , /' ,I ' te ,./, •g ' , r ✓ / rri � i � ,/ r � . ✓i ',� ?si�, ,r��' o,.u: rr „aJy/ /a� �/�,s /.:F_: r. %�� ��sy ak� i. � �jt',�, � ,.,... ;��,; x% ,,..,. ,,.,µ,'es «_. ,✓ /,, �".o:,,.�c' ,.,�Ns / /.,�. .. .. Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I 3382 to 3412 60 37 4456 0 0 0 0 BG 3412 to 3420 28 27 3322 35 0 0 0 BG 3412 to 3412 132 16749 95 8 WTG f • to to I to to I to I to ., to to 1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG Trip Gas P. I � r 7 % //j � / , ; .p r ;� r /�..,, ✓` a ,,i / �rjr/ s /f _:* /� �r r / ... s � .;? yy� ;,. �rr,l 1%r rz;,' r` �r,r/!rr'�i? /,,, r�i��F/ /r. /fir /lei ! %� r - a� g: � 24 hr Recap: Drilled to 3412'. Pumped Hi Vis sweep and circulatec hole clean. POOH working tight spots at 3050', 2660', 2415', and 2406'. Reamed and washed due to swabbing from 2425' to 2243'. Pulled tight at 1865'. RIH reaming and washing from 1434' to 1528' and 2215' to 2287'. Tag bottom and drill 8' to 3420'. Circulate hole clean w/ Trip gas of 132 units. POOH to I p 1583' at report time. I Sample Catchers : Nick Douck / Steve Mircovich gging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air ✓' /'iii':; r , ;,: r i L rf t ' ?!. rr 'fie L ' . a ti':' ,r 1 1 r / p� ?�` � em ` ✓ �i i�' , 9 �",'f, / � ; r ✓ :. F /, , Y,, /h`, -;xr' / l r G 1 r; ��,/lr,�i/lnY /�, �, / / / /E /.'?3�,., ,., _. .Fr ,���,/, :,,,// Y...' "��' ` „� tir/'s T'r Customer: Pioneer Natural Res. Report #: 5 I . � ALU l RTQN Well: ODSN -40 Date: 05/12/2008 -5 :00 3' Area: Oooguruk 05:00 Depth 3420 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Run 9 5/8 / CMT Job No.: AK -AM- 0005710855 Report For: Jim / Herb Daily Charges $3,500.00 Total Charges $17,500.00 1 f „ <.� _.. , , /f� i ,, sir % / r"i'/i9 / / 3�,f?�?'r/� /i , , 1 ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING / R.O.P. ft/hr NA Flow in • •m SPP •si I NA 29 37 3416 Flow Rate s • m Gallons /stroke 3.6 „ F' %,r ✓¢� 1 / / , r , /r �, . P / r ,s . ''f ; ' fx yr i ri /rF/ / r k �i� r // r, �i�'x.! �;.�% �,- " „/ /' �e. „ , v,.� // � . ,...; � %',"r'' /;fir, .', rc„ s,,,,,/9 w ''//�/i ,:. Mud Data: Density (ppg) Viscosity FILTRATE PV YP Chlorides Hard Alkal Md Cor Solids 1 Death in out sec /•t cc /30 min cP Ib /100ft m• I Ibs/bbl Pm 9 5 9 5 50 12.2 14 27 34,000 640 0.10 6.2 ir: r / / / // r %” r/N r r /u r j // i % , /f ar... r� ✓ a / � r %/ /i �e ' ? �' i Vi % ,., r /�€"� - ., ��ir „,. ,i .', �,- Z.Y. „...�, ,����� /,,., „u,,, ,,., ,.v,�� ,.,�.�ir, �iyi ,r ✓,�, s;.,,.. ,,,,,,,. ,.,. G�Fi, r, ...,Q_» .. .,,,.�>,.z,., „�.ri fi ,� /e r l h< <.. - BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1 MXL -1 12.25 .699 30.8 153 3420 3267 25 94 / sue' c aw' , / /y - / r -s . I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current ,, q / rs / H . . , : / / / / r ,r y r i �' i g '�' / y f 1` �' �. ?j�' r ` r r %: z -�- � :. �/�s:/ :;: 6.. ii .. .>�;vrr%'%r�i,,�..�sTZ, -� 1� /� %�� /.�;�,,,.!/�,€ /;- 6'.����/ ����'' �? r.,,,,. �� .�: I Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I 3416 to 3416 29 28 2768 4 0 0 0 BG to 3416 37 4686 34 0 0 0 BUG to to I to to to r to to ';- to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas TG Trip Gas ••• • // y i rib r: y s� � r � �� ;��i�;� y� r / %�� � �/ Asti / , sr � � f; I �� �,�/ K�„ ' �� r �� ,r �irr�' %�,r.. � ,,.< � >//'�%;, �: �,/, % ;. ,, / ,rte r „iy . ,% �� �:���/ r�//rirr�! ,������� _ ;����,.., .� � fs,��� ', , 3 c k 24 hr Recap: Finish POOH. R/U and run 9 5/8” CSG. Washed CSG to bottom through tight spots at 3035' and 3241'. R/D CSG tools and Circulate hole with bottoms up gas of 37 units. Prepare to CMT at report time. 1 I �. Sample Catchers : Nick Douck / Steve Mircovich Logging Engineer: Boyd Piercey / Tom Mansfield 10000 units = 100% Gas In Air le rr '�` r% / ,. % fi/ rfiz < % / ,,� r ar / ii /x r ✓ s//' /. /, / i'r ? y / . %ii - . ,,, : z , ; oir / .�so' // /':r ap��� �/�// /// f/ i✓ r ✓. r i r .,,. �;,, % % F,s ,.�,= /�����u.' ✓,�� � 1�/� /��i,n „cis w. 5���j�% / /<. /> � ,,,., .. ..y/. , %/�/.:; /, z,,, �> . .....a , � ,.;. /.�„a�k' ' �'', �' as ,�. 1 r 1 . * 1 4114 *; . fl . �.. , P,'✓, , r Natural l Res. Report # : 6 1 HALLIBURTDN Well: ODSN -40 Date: 05/13/2008 -5:00 Area: Oooguruk 05:00 Depth 3420 Location: North Slope Progress 24 hrs: 0 1 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Nipple up BOPs Job No.: AK -AM- 0005710855 Report For: Jim / Herb Daily Charges $3,500.00 Total Charges $21,000.00 .% r -r i r '2 m r =? �� ./r, 'sir W ;I f FF t %/.; „/,,�y `. . :£� „��, '�' f /�'/� :;r e �; 1,r �r : 22 ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr NA - -- Flow in •.m - SPP •si 1EMEED1 NA 33 units Flow Rate s • m - Gallons/stroke 3.6 r 6 f'r''� p�. / �%i , ;' r rr ',%.r /iii r,ii',/ r% f / rr r ..,. %� //, . -`� �. �f ,'�.�'// ,„ ..., „v' �,! ,,fix%. ,,. j�� ,,, . r Mud Data: Density (ppg) Viscosity FILTRATE PV YP Chlorides Hard Alkal Md Cor Solids I De in out sec /.t cc /30 min cP Ib /100ft m. /I Ibs /bbl Pm % 8.6 8.6 28 34,000 .0 - ' /till r. ,., ' /,r�' /� /i , .�/�” /�.� _.:;' �� r�� ��s',!y rr €r ,.: " i', „,�� /< .., ,,, ,,; ,� ' i��"y /��, � a, „.:�..,5�„ � .':: �,> ..:si$ Z',`r,,,,:,. r '-':'� f,. // /Ly;,, _ /,�rrr�"',� �.:;?�,F.�r i� .c,;. � r; .v „ -. ...:1; �f,£; I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1 MXL -1 12.25 .699 30.8 153 3420 3267 25 94 �i @@ / ri /r i °' .i.MF i . , !.. ! 1..i., :° ?'It tC ;r, , ..4 47 . 1 ir �- I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current ------ - - - - -- ' / % x ^ ' r„ r�%ie�i / �,,,�c�,�r �;�� / // �` - 9 . - %J / � r /„ :. ... % /% , /, �, ,, �k �X�,xrozr..'vr /4/, 2 /�� „�+&aw'„ir� „<, r. ;U'': i.?it:�3';; . .r. u*. .. rr ; Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to 3420 24 2421 16 0 0 0 BG 1 111 to 3420 33 3241 29 0 0 0 BUG to to I to to to to 1 Gas Type abreviations: BG - Background Gas; GP Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; / / BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas „ c. ri. �� 4 � i, ti� ' `r r r .i2j' % % r � ✓/ .� �� /i � ,: !/ / /,_, /i /� /aly�.i rfi'/ / r,'.,y�C ' :::= ,' r v ,. r ,ri . a , � : ;;.. ;, ' / ,//// � a:.:%r. � � �;Ci'r"� , %th / �%%r? // . ��s'yrr /_/ %'. r te. / ; 1 24 hr Recap: Cement 9 5/8” casing. N/D riser and N /U Clean pits. Change rams. 1 ' Sample Catchers : Nick Douck / Steve Mircovich Logging Engineer: Boyd Piercey / Tom Mansfield 10000 units = 100% Gas In Air r i u , >. r %r' / r ' f / 'my 1 . / ,�, .?+'; ;'.' r / /i / ; ''.KII��/� /i r , - /i ! /,.�: :. .;s- ;,, �r yr, li ,�r ??' �, / } y r r f” ✓ rr. ",,,r� ;.'I :g 3Y � /i��i'W" rr ��� /� / ; �.i�.,:v ��y>%��.��»% / �i %,� �r�'/ e „:2 /,�Ni�� /�,: /� /��f,'i �33'���2,m %f- ..,- ri,..i..i�,,, k N 1 1 e. 1 ✓/ r i - / r/i ,r, „zr : � ,?,' , ,, -sr ,,g �,l i ii r . �r // ii r 3 r> �,� c " //s;+- ;,;- :- ;� i at. . .89� . .J3 ,�„f�„/:- 3.;,`Srd . r.,. . , /�. .. '�,,,.:.i,.,,, I Customer: Pioneer Natural Res. Report #: 7 Well: ODSN -40 Date: 05/14/2008 -5:00 Area: Oooguruk 05:00 Depth 3420 Location: North Slope Progress 24 hrs: 0 • ;, Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drill Cement Job No.: AK -AM- 0005710855 Report For: Jim / Herb Daily Charges $3,500.00 Total Charges $24,500.00 .i..*.. � rata: . � 4g I: . 7? ,., JZ., , ._.� .,, .M. . : ,.� sF, ,iii .,�/r�/ /, Z y��,.. a., 4,hi, 4 ..,. , N C.�,..i ROP &Gas: Current Avg 24 hr Max Max @ ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr NA - -- Flow in • .m - SPP •si *. NEEMEM11111 I NA - -- Flow Rate s•m Gallons /stroke 3.6 r ,,, '.1111 ; te r' i s y � M'. 7 r ,f .iy✓�/' r / .. '.rr" r r % * ; / z � yf'� __,��� �,' /:3`. r � � � , ' i...�/ /�Yyi/ ,, :: ,��,. ,�,,,� . .�' iii it R. 5��r. „ . > ., . , , - :<.,:F��„ ,,_,,.,.Z%ju, yu, r � �,�'i/,w��. -.I ....,:. ✓ „ ' , ' :,,tia ,..: ? . zrr, . ..,�..�/.rr. , i,,,,., ,.,, „�� Mud Data: Density (ppg) Viscosity FILTRATE PV YP Chlorides Hard Alkal Md Cor Solids I Death in out sec /•t cc /30 min cP Ib /100ft m• I Ibs /bbl Pm % � ri ,< -s / ir<'�� �'i,. d /r',`r���..:, / /r r' «w' r y rr / /j i . ri '. i % /ii /i�, „ y Vi i, :c *.. ,< .,.� �ir'',�., /,; , /J� /� ,rte /,ri,.,,,:...��� / /�i,..:;� ,,,, /,,/ ,v „,,,,;., ,.,,z,,, !ir,�,.�i „r., i ,,,,,� „r' r. «,.r ���r/„�!./%,r,:�,,. ,, „ �, ,,,fi,�,�:. .' �r.�/::,.,ii„ ,,,+� ,.�s s BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 2 FMF -2643 8.75 1.178 0 3420 0 -- Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current ----- - -�� -� , ;r /3%,i jes ..i. t1P: .. r ri r ' % ,ri r r / i / 1 .. Gas Breakdown Gas (units) Chromatograph (ppm) y - Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I to to to ' to to to 1 to to .� to to 1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; r BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas < : /7. 8 r' /s - - ?r r � / y;r ry"r%/ 1 �✓ rr, , ✓/ / ,,:, ,.. -F %ice � r ✓ s/r r i ... /, / / � ,✓ ��a ,'. / r - ,r rri ri / r 1 qf I , � , y"��� �� „«� ,3i.; /��j �/e .'S�Z.:i�t�,.�,��... ,� � ,...,,.:�::_ , ., . r. �,�'`� /fir :%�,;;z %�a „/i., � y �.r. c� /��.:;.r :�!��,o /� ,6 ,,, ,�'�,, .;':� F ., 24 hr Recap: Nipple up and test BOPE. Make up BHA and test tools. Clean pits and lines. Cut and slip p: P p� drill line. Service rig. Displace to OBM. Drill cement. I I j Sample Catchers : Nick Douck / Steve Mircovich Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air z i / r tjd / r ' / %' / .: r i; /�% r��,r/ ' , i� /ii _, % :lam +r ' r,° � , / / /iv ,r..M�.. � /j / * ... :,�;��, � A... «:cis:'« , ��,!v�' / /��- ;:�.E, %%G . /,r•,� /:+;,�.0 r/�r���r /.. .,: �s� „�„ .,.!,Mei �',��C,:>F,"`� %�fi, 1 1 '4'. if l'it �' � F;..,_. ,... ,.. ik ''���f�/ � „I , l.,Y�4. . If tl �F. ''..g. ,/ „ ..N. . .4. Customer: Pioneer Natural Res. Report #: 8 Well: ODSN -40 Date: 05/15/2008 -5:00 Area: Oooguruk 05:00 Depth 3890 Location: North Slope Progress 24 hrs: 470 II . Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Service CCU r, Job No.: AK -AM- 0005710855 Report For: Jim / Herb Daily Charges $3,500.00 Total Charges $24,500.00 ROP &Gas: Current Avg 24 hr Max Max @ ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr NA 162.0 376.0 3647 Flow in • •m 536 SPP •si 1945 NA 35 70 3788 Flow Rate s • m 154 Gallons /stroke 3.6 0 . � % r / r / . . „� . ,, ti , 4 / � //.i 1 i /.. ,� % ' ✓ `r /�i . .rI �% '' ' ,hrr✓ -� %' `, %,,.:: %„%/ / � i,. ' ... i; ;.. . x., rx /�� / � ,,. i� z.a 1.,. /� ..r.,, , >,.. „.. ds... Mud Data: Density (ppg) Viscosity FILTRATE PV YP Chlorides Hard Alkal Md Cor Solids Death in out sec/•t cc /30 min cP Ib /100ft m•/I Ibs/bbl Pm To . 9.9 9.9 60 23 13 - -- 10.5 � /� ';i '% . * ' '.r / r ' .v "s I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition � . 2 FMF-2643 8.75 1.178 2.9 3420 470 15 120 .I. / £ ill ` i :r..Z'/ ;€ .i-.: ' y r / ✓ ' / .,�'4. ✓, r� /u .: K„<,;;,,,, /F ,'s. .,, .:7i ,r ,. // ' r.I.i v ”. Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current 100 ,A .,,.,,.,,.,r.. IfIA:' , 2 i s ,;' '/,/ his„ /.r F ,au �..�T ��,.,. i.����,f ' 1 t.; Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type • 3420 to 3890 70 35 6920 52 14 BG to to to to to to I to to to to II Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; . BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas r a; y% , ` , r i, r.,, att.- . .. : r13 ',, 'rf n / . /y r� �/ a” 24 hr Recap: Drilled plugs and shoe track to 3409'. Drilled rathole to 3440'. CBU and pull back to 3400'. FIT to 14.1 ppg EMW.. Drill to 3834'. Pull to shoe for repairs in CCU. Drill ahead to 3890'. Pull to shoe for further repairs in CCU. • Sample Catchers : Nick Douck / Steve Mircovich j Logging Engineer: Boyd Piercey / Tom Mansfield 10000 units = 100% Gas In Air . '31`. fr // „,,. , %�. - % /�i //, r rrs : r /''.2, ,. � %ji / / / % /�i / _ : ra , z ,, ; „. ."s'. � - 1 1 141'. ,,,�r �„ � � . � a�.�. �.; , �, >,,.�� /, �i�� i;./ � �. . ,,,< �� i,,. � 1 1 A ?. �� Wk. � _. s,�,',.,,:47 "- `.ria <.,,!'.,' . ,.. . .YS / •;xm , . ,...r�.E Customer: Pioneer Natural Res. Report #: 9 1 / I ... Well: ODSN -40 Date: 05/16/2008 -5:00 Area: Oooguruk 05:00 Depth 5480 Location: North Slope Progress 24 hrs: 1590 I : Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0005710855 Report For: Jim/Herb Daily Charges $3,500.00 Total Charges $28,000.00 S i, %�",.yi;,, ; �r „ 4 � a / /...0 r t" :- 7' ` vii .' / >.., %,` .. / ,,f aw, ,.,,,,t „ se .., 1. ROP &Gas: Current Avg 24 hr Max Max CO ft Pump & Flow Data: R = ROTATING I R.O.P. ft/hr 162.0 177.0 442.0 5326 Flow in • •m 591 SPP •si 2640 IIEMIEUME 98 88 249 4510 Flow Rate se 166 Gallons/stroke 3.6 ,,..,, /; -xx, r aJ.., ,,,<, sg. .,, 14 .�. ,�. „ ., , , m " .,:, // , i;'?. z i, /„ c,,, , ., Mud Data: Density (ppg) Viscosity FILTRATE PV YP Chlorides Hard Alkal Md Cor Solids I k Death in out sec /•t cc /30 min cP Ib /100ft m• I Ibs /bbl Pm j 10.7 10.7 60 27 12 - -- 9.8 > ti i „L ,� / ` .../ /✓ rri ,; i �' /� /� _ Yt // / y Y �,,,, :,'"r,//,.',°./ %.:::� , ✓''•`� !,.. , /L..ri %�J „� E / , r / aCr y /./�ii� / /s,$ ,, 'Ys?'. 'i . .. / / / / , . , %i� ✓., , /i .. .., , 'h` a's.; ,, ;. ;'T BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 2 FMF -2643 8.75 1.178 13.5 3420 2060 15 120 1 4. Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff t Itt current - - - - -- 85 - -- 15 . � q /r , y ; /✓ //� M �/ / / / /i / / / F �//!//' / / �ti ..4.4,' �� / !. , �' Y'"ys'„�. , �;.H,;:,''w' ,//�..!"�' .,.. % .� _, ,,z ,i „l�fl!, „ <.Y.l:.x”„ ,,,x� r y , ,.., ✓.r �J✓ , , l 5 �. �i., ,, %• �. .,,,, ' r „ �. 1 Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I 3890 to 4476 116 60 6596 72 22 3 0 BG 4476 to 4615 249 142 15353 178 40 6 0 BG i 4615 to 5330 183 91 10031 178 44 7 0 BG 5330 to 5410 213 160 17793 484 131 27 0 BG 1 to to I to to to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; F BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas a '' / 4.` /..rte /O/ _OM" f 5Z7 . . , /,,./ � ?��/yl�i, „'`"� �,.�.i . ?. 1.,�%Lr,�, ' .� ' w . r ` !:wI� .» 1 / .. 24 hr Recap: Repaired RSC and CCU. Drilled ahead to 4935'. Short tripped to shoe. RIH. Max Short Trip Gas of 40 units. Drilling ahead at report time. 1 / I Sample Catchers : Nick Douck / Steve Mircovich Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air 1 1 1 o-r �. � _a r�r"�^ : ' //�' ✓� "`�% �",,s ",:. � �'."/' � ��' ' , / , f `" / // / s' / ,. �rxr,�,,,, �� / ly��..r. �.,.����v�A����� � � /`��,,, " ��„?�Y�i.,�.,,���i��v'rr�� ✓.,, ,��,,,.�,,, r�,,, �� /r�i�'`�.,,s��<l%,.��r>../� Customer: Pioneer Natural Res. Report #: 1 0 T Well: ODSN -40 Date: 05/17/2008 -5:00 Area: Oooguruk 05:00 Depth 7300 Location: North Slope Progress 24 hrs: 1820 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0005710855 Report For: Jim/Het Daily Charges $3,500.00 Total Charges $31,500.00 : r x + ,� i .o . / 1 ' /rr' / .� % . .:( r r ,s`l rr '� s .rfir r y ��r /r� ,. ✓::.�., s� �c <r �.�r . .;. "i, ..,'`';,�, '�, s ,,.,• ,�'%, ,.. �F r�r� �,, ,., , „, >i „ / �i _M.z.;` f!, .. .°��,. �� �%;r '- -.. ROP &Gas: Current Avg 24 hr Max Max @ ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr 118.0 150.0 316.0 5515 Flow in •.m 587 SPP •si 3036 39 72 265 5515 Flow Rate s • m 169 Gallons /stroke 3 6 v r t�+v� : , r .)1M-.4'. "rG r %e r /. ;. r � �.r ,rr r � - ;� ry ✓ /7' ¢� , %i^�%r" , ?� / i,:.:. .7 .r /'`tii ( / . �/'r E %"s/�,. i r,� / i'� / y ” �� ,.(.:, rP, -,z, 3 „` . . ��.. `/ l.,ar..,,, ��Z��/,iL`„"''sirc i,,,,i,. . .. i����� ...,,,. ��� :w,,. ��3 � ..G�r%xisz,r=!G�,,..:'��r, /r,,,,�r��`,� r ,3� 7 � ': Mud Data: Density (ppg) Viscosity FILTRATE PV YP Chlorides Hard Alkal Md Cor Solids I De•th in out sec /•t cc /30 min cP Ib /100ft m I lbs/bbl Pm % 12.0 81 27 12 9 � 12.0 20 9.8 /' �� ��� r x. r r r r a rm, /r /i! , a �/ /y //� / ter; • r/ BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I i 3 FMF -2643 8.75 1.178 13.5 3420 3880 20 126 %r / r v y r te/ .. i d r y / /// - /r ' r t� . ✓ S ri .�i� ✓�, %. . / .: /! / , r ,r % 's / /. .. _ rti,r% a 2�2,� „.. �.�i, � ,.� fr, .;� ' i, iii I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current - - - -- 5 95 - - - -- } Agar. .:iii :I, `i: .,. . � 4 >., „,, ,� /� ,... ,., %��t /y ,,;. .', . , a.. ..l ..... : ....... Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I 4 5500 to 5550 265 173 15604 466 152 45 0 BG 5800 # 5850 156 138 14493 488 201 75 0 BG 6000 to 6050 130 111 11590 389 150 54 0 BG 6900 to 6950 66 50 4455 135 45 21 0 BG I to to to to I to to 1 . Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG Trip Gas „ , G z Y✓ , . NF. /i ✓oL /�? / /, ,, «� ;� � F r // r;,' '% �'/ ,, ' F a / S ri %� � r //`Ii s' r <:: /r /•. ,;� �✓ ✓ r • // . , ri: /.,� %,.. ,41;4 / � /'Z;%i � /. .� ,,, „ayr„ h :,,. u,� � r r �,. x � .,y ,.:,, /% F,,, `s . ,,, 9 � �,rh. >„�, II .ri. 24 hr Recap: Drilling ahead, Short Trip to shoe, STG 60 units, Continue to drill ahead at report time. Weighting up mud to 12 ppg. ROP's slowing down from 200 fph to 100 fph. r y I 1 Sample Catchers : Nick Douck / Josh Gagnebin Logging Engineer: Boyd Piercey / Mark Lindloff * 10000 units = 100% Gas In Air , r . ., / s % %F %./„ -;ay; �r /,'� / 1/ 4:' / ,,y r/'rr /�//, ✓r �/9'�'.?2&. �', i,, v � �u,.t ,�t,�7 •�..�%%��F;'�.� �� /�ai',;,,L�i l /fir ,,, ,, ,,,,.'.s,f �, /r /r�3 /� �,i� "sl��r,;;%��., /sri /,,. �/r/�.///,�iG �:;,,�:ti> � � ., w �/ /i I 1 1 1 **Ike:::;.. �;, ���/� /�,%,r ��N,L. ��z /G6 /r .„, .,,,�������,�.ys�<i,�,��*'s,�r, , /<, , � �.'<`l 'w it. / /��',, ,....,,,... III Customer: Pioneer Natural Res. Report #: 11 111 HALLIBURTON Well: ODSN -40 Date: 05/18/2008 -5:00 Area: Oooguruk 05:00 Depth 8351 Location: North Slope Progress 24 hrs: 1051 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0005710855 Report For: Jim / Herb Daily Charges $3,500.00 Total Charges $34,000.00 1 ii F. � ;'r i � .:.i. �ir '�i', /i>i�'r�>'�, ROP&Gas: Current Avg 24 hr Max Max @ ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr 118.0 147.0 326.0 7785 Flow in • •m 587 SPP •si 3036 39 90 602 8096 Flow Rate s • m 169 Gallons /stroke 3.6 4 ''6/ � � :.._ /3' 3�'i....,,,,,:: /`'fp l./�.,a�i,'',. , '' 9�i %���.'. X ;.* .: `:: Mud Data: Density (ppg) Viscosity FILTRATE PV YP Chlorides Hard AIkaI Md Cor Solids I II Death in out sec /•t cc /30 min cP Ib/100ft m• I Ibs /bbl Pm % 12.5 12.5 81 27 12 - -- 9.8 // ,,,, /% ;:ti„ /� / % :�"i,, , s Z 9 /%% %r „r.�� P.. .e... t BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 FMF - 2643 8.75 1.178 13.5 3420 4931 20 130 f tl /y',�,'r�"`.��/�""�"'.ri., i. „h„ ,.,,�a�.� i/ F' • ..�.z;'�� . Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff ��� current 10 0 95 /y . „,,;.y'�`% /%t, ..�.:.v.� „le,�: w.'z✓<„ ' Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 7750 to 7800 150 99 10663 249 62 18 0 BG ; , 7975 to 8075 322 231 27735 855 247 89 3 BG 8160 to 8174 364 199 14997 674 231 92 8 BG to to to to to to to to rs. Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas ,,_ , � . i1 ii::i ���:. ;.. ��� /,�'r,�i'a�.^ �c; /::.; u`.,,. ��.. �,,,,,. sfxL�..,. �' /.� / / /J /�'lr'_'s...,,�r����... �r`df�� /�� %��/„�, ,� >. ,44f.. sue:, 24 hr Recap: Drilling ahead, Short Trip to shoe, STG 60 units, Continue to drill ahead at report time. Weighting up mud to 12 ppg. ROP's slowing down from 200 fph to 100 fph. I Sample Catchers : Nick Douck / Josh Gagnebin Logging Engineer: Boyd Piercey / Mark Lindloff 10000 units = 100 % Gas In Air . ,` ". j ;•: /'t� ;�i/ 1, , ;�`� ✓'r : s r�,. ,v � �' S 3 ',. 1 1 ir* iti. .',��.)WP/ �n� ,,,.�<, .<: ?���_ ✓. ..ri���,% <.�a �.��. ,, p;,:r,,,A i' %Gil;��s , ,,,,.�,.,,�,�';.,., �,.�i,,.:, /�. �r, Customer: Pioneer Natural Res. Report #: 12 • ▪ HALLIBURTON Well: ODSN -40 Date: 05/19/2008 -5 :00 Area: Oooguruk 05:00 Depth 8442 Location: North Slope Progress 24 hrs: 90 ■ Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK -AM- 0005710855 Report For: Jim / Herb Daily Charges $3,500.00 Total Charges $37,500.00 y .� // � 3 z:- - ' �i'/%i ' i r lTe/ 4 a.. / '/�i: %%: 'zr r � € - -/ rJ i '/ mom .: N ' �y,,', : 7if ; 1 � j � ' /�ix'�; „�i� .,, c��a � ., . �.��<" . P ..� .. .. ,' % , ,a � i ,h/ , r . , <,�w. // �s „� „ i ,�'<. , »” ., ,�2� ' �/�,,.,y>�r„ yi „� � ' , .. % , �i�r. r ; ROP &Gas: Current Avg 24 hr Max Max @ ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr 0.0 159.0 291.0 8356 Flow in • •m 250 -300 SPP •si 800 0 5 97 8352 Flow Rate s • m 70-120 Gallons/stroke 3.6 �x 46*, ,Y;' � i /�'j� r r � % r � r / „� ��a, 3,� ar..;�i ���:�t <,���;:,.,i,.,�i „y+�i, ,, .ri,,,, �� „'�°,�!Sr..i'.. ,r`i� <' , /i.�,�..;�,a�, ✓,�, rr.5>,%r,.,,.s, ., r.n i%, a, .c. f Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids Death in out sec /•t m1/30 min cP Ib /100ft • • Volt • •b r 12.0 12.0 55 3.8 22 13 290K 780 3.11 17.2 y s ' ' / / %r /ii i' r I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 FMF -2643 8.75 1.178 13.5 3420 5021 0 40 efr ' ///' //�j/ y '/ . / /,� r /' / 'i/ * f err /yr r i . <asiL ' -.« , . .., J..� . /,,. . ,.�. : ,,,; - .,,,,Ir - a i �; .., i , „i< , , � /,. ;: ,�. 1' „'. � , r, /, /�',,,,. . ,_;;; ���,fi � ,�, I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current 10 45 0 45 - - - -- / /;s i r 1.', ✓* % /ir 1 r ” / ��rrr l��' r &” F �. � ��. /' F ,1 j .n "s</ ,Z < ar H� ..< ,,.., / .� ✓ T„ -< ,.,.. ,. ' rs✓r' � ,..,,,;,i .' Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to to to to . r e to to to to I to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 1 24 hr Recap: Drill from 8351 to 8434, POOH to 3410' (shoe), circulate till mud weight is 12.0 in and out. RIH and every 10 stands circulate 12.0 mud weight, monitoring losses, 55 bbls lost in trip, with a 159 bbls loss total during circulations. On bottom drilled rest of stand to 8441 ft. with a 40 bbl loss. Pumped a LCM Pill according to forward plan with a 1 I 4�: 23 bbls Toss. Currently letting LCM pill soak. 1 I I Sample Catchers : Nick Douck / Josh Gagnebin Logging Engineer: Boyd Piercey / Mark Lindloff * 10000 units = 100% Gas In Air te i / / a /ti / ✓f/ „< u.,..1.; 4/101,31 rj6 „F „/ ad.x:tii ,..:. ✓c a 1 1 .r� .v r / . y r r % / r F'r �! ,%/ /�' ✓ , Ls *y � 3 p s r ' 7 a �" 1 ' ID i,�i /r.! ������ . �i!��.,�'�.. , . �i/ /i��i„ „r,! . b�".� ,":��a ,,, >� 'n. -,���! ..r /;;i„= ^.:.,.�,,/, .. ..<,, , .s. Customer: Pioneer Natural Res. Report #: 13 HALUBURTON Well: ODSN -40 Date: 05/20/2008 -5:00 Area: Oooguruk 05:00 Depth 8731 Location: North Slope Progress 24 hrs: 289 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating fr Job No.: AK -AM- 0005710855 Report For: Jim / Herb Daily Charges $3,500.00 Total Charges $41,000.00 i ' r ry 9,;Y;,',5x y , , ,sr ;. ::,. % r ".'/ y :y . / r,z / z !i ' / `�::' /r r / �' ,' f� i J /r / 3 ,, .:r c ';. -,. , r �.y , j��� .. `,.,..'�a�,�/;l/ .,,�� � . /�,. ,.,�� /�/;�.., /'�"`',�.. „�3r °:, f / /:%...,: ._,�r� „� „;,,, ,,. '�� �� .,..: j'y�r. �✓ . , . ROP &Gas: Current Avg 24 hr Max Max @ ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr 0.0 78.0 118.0 8639 Flow in • •m 371 SPP •si 1570 0 35 197 8463 Flow Rate s•m 70-120 Gallons/stroke 3.6 pi: s... i r .. . r r - / r y r/ z” 'ir i ri r j/ r / `" ✓1'i ! -. r �Fycf,,,,:: _ ' j ' rr'.,,, ,,.'�� ,r „� 6 ,"ti$.�;z �.,�rr�y'r' ,.!` t. 1 � i,'.ryyys, ' Mud Data: Density (ppg) Viscosity HTHP PV YP MI Elec Stab Lime Cor Solids 14 De•th in out sec /•t ml /30 min cP Ib /100ft Volt • •b % 12.0 12.0 59 3.6 27 12 268k 611 3.24 15.9 r iil., .y „,� is i= ,ntii ,, r, ,,.";',% Li.. /.: y % 1. 7 ,,,.it r, , / /,r"C e,. ' ,' BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 FMF -2643 8.75 1.178 40.29 3420 5310 0 -5 130 / r j " G / r, �,y rri / /i l// ��xr y ” r riy�' % ' .z j �a i L l t � h IO ���w w Sd �� Sst /'�� . Silt � Siltst Cht ��`� _ � , �� � �� �� * �,.,..,.. „�'�� Lithology y( ) Clyst Sh Lst Coal Gvl Tuff current - -- 25 15 60 - - - -- y / r / y , /y s �. � ' ' � ,- r r / r'/ / / � r r /. ti c f! ' � yz� fz °- s,��,. . ” r �� , /���,.,� ���r%y r / ; y G 4:.;,.. ,. �c ..ai„�� /�/?_.. /�,.r��i « i/ ! /.. ;i 111 i Gas Breakdown II i Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to to I to to I to to to to Ir to r- to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; -' BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 24 hr Recap: Run back to bottom and drill from 8442 to 8730' md, Total losses CO 8730' 140 bbls, pull back to 7521' and pump 95 bbl LCM pill to the bit. Then bullheaded it in with a Toss of 106 bbls. Perform rig and top drive maitenance. From 23:10 -03:10 loss of 32 bbls while rotating. At 04:00 start staging up pumps from 15 -43 SPMS with 10 bbl mil i „ loss in 15 min at 43 SPM.From 12 AM to 12 PM total of 596 bbl loss. 11 1 I Sample Catchers : Nick Douck / gging Engineer: Boyd Piercey / Mark Lindloff * 10000 units = 100% Gas In Air rev:: r '�'/iii° %' Yf - % // � < .: � � r y / i`/ ,/ � & j ” , ',, . ''/�, z i / G „o ,;�; � ev :: . t'�«..:i�''..,; .iii rx'-, .�:`'l!�,,.�- /%:: a'% r / %!a j !%i.�';, rT/ '.f�..5,x ,.,:7: 6��i/ rrr / /�,...: (r',",..,�,�.::r'//..� sa'�„3� °. I 1 1 N. II ��` 'INC: j ? /' / ,. p , : , i i /.: .,.,; ' . s / � ' Vii y �. y / . �!���v�a' ��r � r �r`���// >/r ,� vt� i' �''�s' '' sr `l//i � ��, � r ; ���� �� i ��'/i !�� r �^�� . / / .,. �'! . , ✓'i...: Customer: Pioneer Natural Res. Report #: 14 HALLIBURTON Well: ODSN -40 Date: 05/21/2008 -5:00 Y Area: Oooguruk 05:00 Depth 8731 Location: North Slope Progress 24 hrs: 0 I Sperry Drilling Services Rig: Nabors 19AC Rig Activity: LD /BHA Job No.: AK -AM- 0005710855 Report For: Jim / Herb Daily Charges $3,500.00 Total Charges $44,500.00 II Virkw - X4 s, lg .f / /,, i :,?;',.> /;":`..! / w x . k %yir,.,., r t , ��i,.r ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING ���� in • •m SPP •si - - -- Flow Rate s • m Gallons /stroke 3.6 1 R.O.P. ft/hr Flow / %, , ////`/''" /x'e �,. `��� ' ' „' %'Y"''!/ `: ii.: / '' s � %y 4 /a; /y,` . ✓ "a_. : iii X , ! ' /" " ' / ' � i � ...rt.:: i a ' i -, , :�',�'r irk - ��, fin 4 , � / f'.. i �r ..< "� X: r , , / , / : " = E., / i „ ��� a A � ,. : / � / , ic y ; ,,.. . ,, !' fir^ „ z � i"/'//x��% . :, Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids I ' De•th in out sec /•t m1/30 min cP Ib /100ft • • Volt • •b 12.0 12.0 66 3.6 41 15 294.5k 586 4.92 17.4 I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 FMF -2643 8.75 1.178 40.29 3420 8731 5310 1 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current - -- 25 15 60 - - - -- n� i t: % , j's / i y i 3” .,.; * / ter i/ �,' �i..i sy - 7 / i ' /:i,��i,'. :; .� /✓' `ii/ /�",yw',GV.,,`XiXr�'z'/,h' ....;ix� '.,,,,� - , < s / /✓.�,'.' /. /` , , _.�'iwy„F , .., /U;� � 1 Gas Breakdown Gas (un Chromatograph (ppm) , Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to I to to to I to W 111 to to to .' to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas 1 i,?, / , +'i � . 'IMF' i i i . 7... i ,a i 7� , / . /, i r._. % ✓ /;'i',:� 'i / /x 24 hr Recap: Continue to wait on LCM pill to set up. Tried to establish circulation but continued to take losses, losing at a rate of 5 bbls /minute. POOH and laydown BHA, Trip data, Actual Displacement 45.1 bbls, calculated Displacement 58.5 bbls - 13.4 bbl differnece. Total losses from 12 am to 12 pm 340 bbls. I f I Sample Catchers : Nick Douck / Josh Gagnebin Logging Engineer: Boyd Piercey / Mark Lindloff * 10000 units = 100% Gas In Air . .�'.'%���z � /��i���.i ' /.,( : . Li, ,,,,,,.:- vhfr �' �%. s„%';`''�� / /.: �:; -"au... _,,. ,..,.•=:9�s , �1,,,.� /. /i,.r,, .� / ✓�,, 1 1 ma 1 • J S%/;:: . `, �i"r/,, z3�^.` zr��/,'.% E:fw: r ,,,, .,,'15i *.i/,f°"riflfs firYr.. r,� .: ;%`!7 % „ Y �F , ,....,`� +'.j.' „o,. -. .r ,, Customer: Pioneer Natural Res. Report #: 15 Well: ODSN -40 Date: 05/22/2008 -5:00 Area: Oooguruk 05:00 Depth 8731 I Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK -AM- 0005710855 Report For: Jim /Gus Daily Charges $3,500.00 Total Charges $48,000.00 1 '11,. y .. a ✓ �/ �' / % Y� / /� r ,i '� / .� i ;Mitt ' � ,.. ..: .�,,.a °�� S �.:<„iG �,,.,..,xx;�.x; ,.w.��, . /./v„,., is�` -�� .. . , �F�� 7iii, :�. , : ,,i r�+'�,, � ROP &Gas: Current Avg 24 hr Max Max CO ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr - - -- Flow in • • m 200 SPP •si 350 I 2 30 3400 Flow Rate s • m 57 Gallons /stroke 3.6 Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids De•th in out sec /•t m1/30 min cP Ib /100ft Nil Volt • •b 12.0 12.0 62 3.2 31 11 281k 508 2.85 14.7 ! ''' it • % /?mss' -``r,v / i,, / % %/i /. ' i , / I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 FMF -2643 8.75 1.178 40.29 3420 8731 5310 4 Smith /MZ7514 8.75 3.142 0 8731 0 00 -Jan 40 J' '.' .41 / .: , � / %</ / /i// rri r� . - / /y / / / /r / / �. / / _ / / - r/ , r :'riJ r, , � / r „_!r','„/s i� ,.. /F s;.i ;:��a . �i✓,.,,, st..:;t «, h,,,,, -,ii,« �„ .: � , i, «;.�'',: -a rim`,,.i;,,, „.. v «> ' ",,,..,./ G li II % Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff current 25 15 60 ,qc Sit .._. �`�. 9 . ” . A'. r; �. a, . ,. �� .4 , ;. his,,, .,,v.gi ; , /y..,,.r'r,�,;, /G! Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type ' to to to I to to to to to to to % "', , Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas ? »., / y. /% .. �,; `w r s /,, ,.. �; ,�,i• / / / /;:,- rrte',v -, /% r oi, / /// %J�% /ar r %' �,,,.,. ' rr/ /�':,%, // ... _..x:.:�lu „3, .. „,' .. .;> ' % ` „ 24 hr Recap: Tested BOP's, Serviced rig, picked up BHA and RIH to shoe. TIH to 6745' circulating and conditioning Bottoms Up every 1000'. Currently circulating at 7872' Pit levels holding steady. P 1! I f . * Sample Catchers : Nick Douck / Josh Gagnebin ° Logging Engineer: Boyd Piercey / Mark Lindloff * 10000 units = 100% Gas In Air x / !i / r� � .s.� /f% /,p /. r / :r //! r� r ,.,�, / /�����>E ,�/ %,,,;;i j�/*,.,`w, / /,�. �,.c ` �: ���% bz� %ak � �, i� i.� z°„s��F�.�i �i,"r��t%.' x'�s ��i. % /�,,,.�, .u„ ✓£,. ,i „i�i.;�: 1 1 n. 1 1 1.P. /%/ r F ,!,," /r,"�n''s -i r` Customer: Pioneer Natural Res. Report #: 16 HALLIBURTON Well: ODSN -40 Date: 05/23/2008 -5:00 Area: Oooguruk 05:00 Depth 8731 Location: North Slope Progress 24 hrs: 0 f <: Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK -AM- 0005710855 Report For: Jim /Gus Daily Charges $3,500.00 Total Charges $51,500.00 . *;! � �m"'�,"///. r;: SV! : • ROP &Gas: Current Avg 24 hr Max Max ( ft Pump & Flow Data: R = ROTATING ���� R.O.P. ft/hr Flow in • •m 0 SPP •si 0 - I 0 0 0 Flow Rate s•m 0 Gallons/stroke 3.6 ��i %l%% 5!/��/✓ ," i , s r' r '41r: .s,,._ r x /'z'",L��� ✓ % r�,," „ r ,;:.. *- �t '�. : �j / %/- '�� �cy,y /,%y //,�.„r,.,..s` /,5 % ,. i.. c���i. .,r��,"//y� ��i': .s. :'= / %,. >o- „,>>a'�^'�/... !s, • Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids Death in out sec /•t m1/30 min cP lb /100ft • • Volt • •b % 11.5 11.5 62 3.2 31 11 281k 508 2.85 14.7 ✓'_ - ,. ✓ems , �'?:-... /�, y ✓ ✓ .� % //F�i. r � D/; - /// . 'ry% /c ** id +fi fi � / i/,! i/, G�/ k.; dGiili/.,✓ y!.. �n^' z?% r/ �i,,,.% //'E.��.!a % /,.,.y / ": i. ,�,, ,,<. ,.z', ., gift- BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition h 3 FMF -2643 8.75 1.178 40.29 3420 8731 5310 4 Smith /MZ7514 8.75 3.142 0.44 8731 0 0.00 40 I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current - -- 25 15 60 - - - -_ rq r x ✓ / l / :✓ r r � r - " /may / r �.,< /"f r � ✓ /� // r i / s �l / /.,,.; ,, 1 /�' - , / . � ✓ ., „ i..?s? , r/ iii,,, ..” `:.. e�:, ,, ,.1 . , .1.1 Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to to to to to to s. to to to to to e. e. Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas P P P 9 P • " r 9�r'3' g G J i ✓/r r rr .�:,+, /, % i ✓. rr� r;rr r � , F x, � 'i " y`� �i ✓ r' ,., r�;��,lyi,.... /�� Ei,��i /is./�,ia° . /': "'. ;, �/ . , �? „ i:. ,�i, ;2e „',�i� .. ... �i� // . _� 1 ;% 24 hr Recap: Reamed down from 7900 to 8730, circulate and condition mud while monitoring well. Circulating from 105 -150 gpm. Losing 108 bbl /hr to 30 bbl /hr. Total losses 74 bbls. When pumps shut down well flowed and received 42 bbls back before flow tapered off. Total lost 32 bbls. Pumped 65 bbl 11.5 ppg Swell LCM pill and chased with 3 bbl of OBM from active system. Currently mixing 95 bbl EZ Sqeeze slurry as per Turbo -Chem program. Today Eugene Payne will replace Boyd Piercey and Andrew Chilton Will be replacing Nick Douck I Sample Catchers : Nick Douck / Josh Gagnebin y` Logging Engineer: Boyd Piercey / Mark Lindloff * 10000 units = 100% Gas In Air 7r ✓ �✓�J /!" ,; ✓y', rre sr / / „� „�;✓ /',: / y,” % r� ! , y � °, ,r,< e / /ii' yr t ^ - % z .�i,/rF/” � .�A,x ✓ ; ` you ✓ / +M N ✓ / ' ei / ✓ j yr / r ' .,,,�.E�.f� ,..��1, �...� /�,:�i..<xa�.si...,,� „2r �,.� ", /.,..i".��.z;, ";�; �ci,,,�, ,,,;:.. , ✓i /��Fii 1 1 1 .. > ,. - ,`; r/ r , '' 4 4" k" ; ,. �.;, r..%`r ui . �. r,,, ' . .,: / ,/ ;w'iic /l r''1 ✓,' . . „ ,,,, '. �.,:,. ,. ��� ,: . �, z.,� rt'� ,zP%% �, it ii ,� ,,. „,. ,, , , / _. �;� r /% ���� / /, �` / �:. Customer: Pioneer Natural Res. Report #: 17 1 HALLIBURTN Well: ODSN -40 Date: 05/24/2008 -5:00 Area: Oooguruk 05:00 Depth 8731 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK -AM- 0005710855 Report For: Jeff /GUS Daily Charges $3,500.00 Total Charges $55,000.00 1 i v ✓ /,,, '�. �,/���/�r'/'i'''!�' .� ,�i� i r . ,.. ! y. ,.'.y� /ly, , r „ /,,' ,. , „%' ,� � . "':f ,,, / .. -. � -i , ,,. zi. r s,,, ,,,vi, ROP &Gas: Current Avg 24 hr Max Max 0 ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr Flow in • •m 128 SPP •si 355 I 0 0 0 Flow Rate s• m 34 Gallons /stroke 3.6 / /./� / % Ali ; r p ✓ G �x �v �'' H / '� !i �'' 'r�1�i. ��/'�''��i'' .. - . ». � ,'. ,., ,.�����''.%v.��,��� / �''''� %v 1 �. **"!= �',Nr.,a �.rV �.. . '' Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids :: 1 Death in out sec /•t m1/30 min cP Ib /100ft • • Volt • •b % 11.5 11.5 85 3 73 19 266k 445 3.24 14 1 tii: yr r ,i �,, p f "� y r jj4114* / ' . �l r l / , ' r. x . �% %% i i /ii ri / / F / ,. �// , �,'���� / /.;�"���%� -�� ///i; f� „,,.. ' '� ' ��� /, � ::',��` u„ '� �.,. ..r '/.`. r i / %,y;;, ;pro „ %' ,,,,,,,,��� ,., ., 5� ,,' ,,. �,,,, ..,. �, , ,.,o,r,.,, , ., rte/. , „ BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 FMF -2643 8.75 1.178 40.29 3420 8731 5310 . 4 Smith /MZ7514 8.75 3.142 0.44 8731 0 0.00 20 fil*If '% %a, rr '�'�, v.. :. / , . .. ,,, , I= -:; ,1,,, '.... is :.7 , %// Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current - -- 25 15 60 - -_ -- F .. Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type t to to to to 1.'i to to I to � to to 1 IS Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 3 / ` ���/i,%'r�y ,i z. /: ,,r h // rf,, s i ,/N / 3 ;s a ",; / / /'% z/ r / r r"r in ✓: ....W,.'�;!/� '..w. . ����.- rv�„ , / //c ,�i,,,rs�tWa..- .G�ik";gr„ r „3` .. �' � „`r1�i / ; !//r.% ,,r/r !ice, ;:rr 111 c 24 hr Recap: Continue to mix 95 bbl EZ Slurry, Loaded DP, Pumped 94 strokes per stand while POOH 22 stands. To 3400'. Displacement before dry job pumped -12 bbls diffence, after dry job displacement within 2 bbls of calculate vol. 4. .Circulated 6 SPM F/13:40 T/ 14:56 ( -32 bbls), 5 spm F/16:01 T/16:17 ( -8 bbls), 5 spm F/17:05 T/17:18 ( -5 BBLS), 7 spm F/18:10 T/18:20 ( -4 BBLS), 7 spm F/19:07 T/19:13 ( -4 BBLS), 6 spm F/21:14 T/21:20 (0 BBLS), t. 7 spm F/23:24 T/23:37 ( -3 BBLS), for a total of - 68 bbls. Currently RIH and circulating periodically et I Sample Catchers : Andrew Chilton / Josh Gagnebin ,. Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air �i����,''R' /,,;�': . .� �r �/ . ` .k„ �7' � .1.:��."lY/G,' %� / / /,���,.J/ %'. ! . �/ , f/ i � . % N, CsJrYf r :'sa�������; /�,k,� /�� /,,, /, / /z �i. /,�.�. ���h`:, �%j �//// htir'. ����, C//,% �� /.,�x3„�,x,,,./.�3�,,;f� 1 1 1 1 , %err. .If '�l/,` Y. /.a '` - Sri P.. L./i/�/„.X i .Y ar „�. � is . n i./r,�' % .1 ` � �Yo"� x� %. >, Customer: Pioneer Natural Res. Report #: 18 Well: ODSN -40 Date: 05/25/2008 -5:00 Area: Oooguruk 05:00 Depth 8731 v. Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Squeezing Job No.: AK -AM- 0005710855 Report For: Jeff /GUS Daily Charges $3,500.00 Total Charges $58,500.00 r ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr - - -- Flow in • •m 0 SPP •si 0 II larEEMIll 0 0 0 Flow Rate s•m 0 Gallons /stroke 3.6 ' - . ter j ;/ y % r/ f ✓,,. // //a %”. �/h i �✓ �� .,. er, w,,.,# ' r:j / /,tfy .� r� „� �..s..;/ii ,,, , „ s.;. s ✓.,, . ,. F,. ,., .� w „a rcs,,, ,, ,: r,.n.� r. -s �; ,,, ,, ,. + F Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids I � ' Death in out sec /•t m1/30 min cP Ib/100ft Fill Volt • • b % 8730 11.5 11.5 68 3.4 72 19 271.7K 412 3.24 14.0 ; � /9i , , % . ,///9�//% . -, , /' r, % / /ir r � � r /i / /�/ �/ r ///%�/ r :. ✓% r �"✓ I l^% / / rrrr, �� / %/r r Vii.. �„s``rlT,.... „J� 4 , /i_,9 ,�%�„va,:zli:�!a �n �. /���yiJ�/, -� ,i /F ,i „..!k, sF�✓ ,s ��, F- „ry,,.,, -- asr,,,,.., ��''z ,'s. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 FMF -2643 8.75 1.178 40.29 3420 8731 531 5 4 Smith /MZ7514 8.75 3.142 0.48 8731 0 0.00 0 y /Li rs � T _ , ,i / // ,. ,,,, ,,, r_r,.., ._ rr ,, .1; y Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff ER t current - - - 25 15 60 - - - -_ ✓ r y � �r /' // o /, r - r / f r / , . /��� / r„ . / „-s' a, ,,... ///s ., „nom„ ,f.:; .43ts�as „l/ , / ,.� /. ,,.' ,,,,/,,.,: „ '� a€ w,.... /! %��:� a I Gas Breakdown r ., Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I to to to I; to I to to to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; F ” BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas P P P 9 P y, 'rr sr c ork , ,., v,,. rr , / T: rr - ,y y - r / /�� / �/ / ,.,/ C.°,.' / /fir' f/ f / I s 9 24 hr Recap: Wash and ream F/6736'- T/8731', Losses between 9 -15 bbls per stand, Total losses 98 bbls. Mix up F Next batch of EZ Squeeze pill, POOH to 8000'. Pump EZ Squeeze pill from RSC into drillpipe through cement lines #. in 20 bbls increments. RIH to 8730', POOH to 7840, pumping out of hole ( -11 bbls for the ten stands)leaving EZ Squeeze pill in open I 4. hole below bit. .Circulated 5 -7 SPM F/01:36 T/ 02:50 (33.5 bbls), 5 -8 spm F/03:52 T/04:05 (- 7bbls), 5 spm F/17:05 T/17:18 ( -5 BBLS), I Sample Catchers : Andrew Chilton / Josh Gagnebin Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air � !k / ,�1/r„nf�,.�.7��i:;.,.9' 6 /�i!/�i / /..,,'; %.;. -: � a �.:�.. �i- �a a;� /i �a� s...v»...,:,rH �- . /m ,..,.,� i .. 1 1 r 1 I y. Customer: Pioneer Natural Res. Report #: 19 HALLIBURTON Well: ODSN -40 Date: 05/26/2008 -5:00 Area: Oooguruk 05:00 Depth 8731 Location: North Slope Progress 24 hrs: 0 I Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK -AM- 0005710855 Report For: Jeff /Gus Daily Charges $3,500.00 Total Charges $62,000.00 f ROP &Gas: / Current Avg 24 hr Max Max © ft Pump & Flow Data: R = ROTATING � R O P ft/hr - - -- Flow in • • m 426 SPP •si 1173 I — 23 73 7746 Flow Rate s • m 124 Gallons/stroke 3.6 � -, at . ' �r,.' „,I ii� / . '”. ITS. V. � ��i /. % '�:, 'r ;�li .�/!�Gi/��/,,,; Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids De•th in out sec /•t mV30 min cP Ib/100ft • • Volt • • b 8730 11 5 11 5 38 3.4 38 15 262K 426 3.37 14.0 ,'�� ! �/ h i'% ri/ ;... �, .r te f ��i /,;; # /� r �// / r` y r� , j i . F' "i _L�,/r%i/r /;,�� - am i �., z.. fir' r�„ x z z„ o, , , /r.,, /� /, / /i / „/, ����i / %L/�„ . ,,.,, u, ,< 5. Y6; ::?�r. ` N y �. ;. s,,,,,,�Fi% /✓%, „,,, ' BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 FMF -2643 8.75 1.178 40.29 3420 8731 5310 4 Smith /MZ7514 8.75 3.142 0.48 8731 0 0.00 48 / , -, r t:i: Ali fi r' - �, „'4 1: tr �Z. I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current 25 15 60 OE : /i., >r//s , ": .:, ,it; .#40*.'' * , i . , -** ,,,, ��, "/,rte ✓,,. /�, a,;,'V r,?G . ,��<os �,,:.r „' ti,. , It 1 Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I to to to to 1 to to t0 t0 to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; , BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas .itri , ,; :�� —. r . AiiiiF ' . A ;, w �. o : / �r /; ”. `` l , , �:* , 24 hr Recap: Continue conditioning and circulating for 8 hestitation squeezes to 18:00 hrs. Currently circulating out !< LCM material. Currently about 60% of sample is LCM. Currently showing 195 bbl loss from 0500 -0500. ,, I I Sample Catchers : Andrew Chilton / Josh Gagnebin Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air < l: /�il'/'i.%Y/ ,���j /: �fS/i9/„ "� ,. "CT,,.'! ^�. �,�. /�j /.n?h`..3,r,'.�' /�, .. ,. x�/. ... ? %r',.:lw�� /e�7� %:i,///.//3 m ��,✓/i�;�.�� ..,.. /„✓,/ , ^��,J,'h/m�;..� 1 • 1 vliftrb. r / r y� r rrs r / r 1 y ' ' �,✓ ' rl' C %; /�ir/ ',.:: � i /l /.11". �' 'r`,.i' /,r",," ' .r,. /,r , ,. rr ,/ ., ;,.,! /. Customer: Pioneer Natural Res. Report #: 20 i Well: ODSN -40 Date: 05/27/2008 -5:00 Area: Oooguruk 05:00 Depth 8731 Location: North Slope Progress 24 hrs: 0 I Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK -AM- 0005710855 Report For: Jeff /Gus Daily Charges $3,500.00 Total Charges $65,500.00 F s , ms s ,;,: % /'%/'�'�._a �u,.' "i, " . r j �'r .^ %'.,s�� / ✓ � ",r v r/ j z ` ^ s �; 1 17 ' :'��,, r kT= „,`'y;,;, �'/�,. ! /,r r'::�'.,,7'.* s �/' .%:. ;', , %.! ,,,,..ud rri „r,. ,,,, r. P x, . ., %,,,,, �"� /., .."��/.1* : ROP &Gas: Current Avg 24 hr Max Max C© ump & OW Data: R = ROTATING R.O.P. ft/hr - - -- Flow in • •m 375 SPP •si 986 11 71 7836 Flow Rate s • m 106 Gallons /stroke 3.6 l!r rk % ” � s�.,✓/ � r ,� /r/r," '� ° % m r��r „� / �,r � s r' � / yo s � c � .,...,'�, . � ..:. L.�,r��. /�l,%: /!�'�u�..... g i6 w .z�is F/% � §?���2�i�.�,,,,fl. /c = °,. /— ,,, �.,iz� , �'�.,� .,.,,r� �,+ ,. Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids I De•th in out sec /•t m1/30 min cP Ib/100ft •• Volt ••b % r 8730 11.5 11.5 90 3.6 41 19 244K 364 3.89 15.0 / r�r � : / � °Fi ri '. ::. ' / � %� ! /: . ✓•J /r / ,, r /r o `' i %, r yy ., r � r :ir �. - % �..r '''.. i ✓% �� % , if ,,.,, /r :!, V / r %// , � , L ��, ,, ,/ /ii yi,, ,f,, s.: � / %manic /// ;;,,���,,, ; ;% „ %,2,?�"'/r�� /„ �I% „ /,,,,, pia / ter„ :'4 ri,X., ,, ,.. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 FMF -2643 8.75 1.178 40.29 3420 8731 5310 4 Smith /MZ7514 8.75 3.142 0.48 8731 0 0.00 15 �'i % . sM .., , „ ,,, _ ,;;. ,3 ' V , r, 4 <n,..: j r,.;J ',. , t `,�.�''�„ Y..:.. I ' Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current - -- 25 15 60 - - - -- r r E s 1'� x y yam/ fJ i ' r r / / . r / ' Y/ 6r� ** ,,.� ,s, ?",.,n, .�iiii ",.,,. ,.,,,<. �i';,.. h� /;ti ✓,,,v.., ,-.t`�+ ,,r, :��r � r��s%�.r•,,, ,r ;: , :..a'., ���' . �r' 7 y '/� z. / f Gas Breakdown l Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type • to F ,. to to to to to t I to to to to II Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas kfil _ '/'� /rc'r �N7, r ✓ >,..,,,,,., r �� °li!r�.` r i/ _ '” �� // r !r "�' i . 4 q mod // /y✓' //; /: f%� Jj�i% r ,,,,'.xxLtf'�''.j�/ at- l �.. 1 , ri /,�r/i✓! / /'/'„/'�', „ u�;,ri ar, : f ! c,. 1111 � 24 hr Recap: Continue to circulate 5 -10 bbls /hr completeing the 2 bottoms up circulations. Reamed and washed from 7840' %: to 8375', changed out screens to 80 api and then continued to ream to 8735' md. Continue circulating and start swapping out. 600 bbls of mud. Start POOH at report time. From 5 AM -5 AM -76 bbls 1 I Sample Catchers : Andrew Chilton / Josh Gagnebin Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air /. ✓ r ,F % y' r i , /.. c % �, r /, r,. ` ,✓ ' ,, % /i rr� h!� r i::� , r Z,'' °'�'� n'i�j���i/'u�'��1',z''w o. ,,/r,�; /�rf�s'� rcr�s, ,..:�1.':3'/ „x.,:!.,�;� „ -/ ,,,,,, /i..�3.u.!�.o�l,�.// ,.. as „�,f ��i'��',. ,,,.�, �. �r'/.,,,� /.,�� ��.v.,._ // 1 1 1 Customer: Pioneer Natural Res. Report #: 22 k HALLIBURTON Well: ODSN -40 Date: 05/29/2008 -5:00 Area: Oooguruk 05:00 Depth 8731 Location: North Slope Progress 24 hrs: 0 , Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK -AM- 0005710855 Report For: Rodney /Jeff 4 Daily Charges $3,500.00 Total Charges $72,500.00 I , ROP &Gas: Current Avg 24 hr Max Max © ft Pump & Flow Data: R = ROTATING ' R.O.P. ft/hr ���� Flow in • .m 250 SPP •si 940 IREIMOMM 0 0 0 Flow Rate s li m 71 Gallons /stroke 3.6 � : ' ✓ / %'%' =: ;. " c/ O �%� -fr'.! A7rNS!/. / :F - .. r %r;. / �„`. F/ // / ,:Oi // //9 ", ..wi / , / r/� • , ��� i, � F,sit; � / ' ., y r . fi / / i, .,r,.. /.. �. - ' -� / -i� , ..,. ��.�����5�..� .;.nyi /r�y / /i //�/���� / ✓� /.. �::/ ;��, .,,�!�§ -:. ,.yix Mud Data: Density (ppg) Viscosity HTHP PV YP pi Elec Stab Lime Cor Solids I Death in out sec /•t ml /30 min cP Ib/100ft Volt • •b % 8730 11.5 11.5 88 3.8 33 12 282K 517 3.63 14.0 -; /i /�/ :.: //` j i /� / / f t'.***':, /r ,�: iy : � w ��/ /X°sb / / / -v ./" ✓s� - „?':. �S% .':���i.% /. %... /'�,. sue. / / / % %.,'� .. �r k. ,,., .� .; ,. > ,, ,r '"".�Ca , /,� /�:�� :��,c „� >. l <, ., %; /T l ". I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 3 FMF -2643 8.75 1.178 40.29 3420 8731 5310 . f. 4 Smith /MZ7514 8.75 3.142 0.53 8731 8731 0 0.00 0 II Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current - -- 25 15 60 - - - -- / /./✓ ` � t . 6, !f ./ /�,., r / /N�i /� ate../ %y /� �,��y/ him /,! ' ,, T " / /. %. :+.: ”; ��,; o � r., y, . /,,.��.�`?;:,'/ / �/./ �1 /y i ;,L/" l / iii <u," .. /� /��y�,.": /7�i/',/ors', ,.,i %,�1� � � i// � 'ice 1 '1 *,e. Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I to to to to I to to to I to to '- to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas � 24 hr Recap: Test BOPs, Make up BHA #4 and run in the hole with the same. At 3400' and Circulated Bottoms Up j then pooh dry. Slipped and cut drill line, serviced rig and top drive, currently testing BOP's. . From 5 AM -5 AM -6 bbls 1 I Sample Catchers : Andrew Chilton / Josh Gagnebin Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air ki; �- �'I�G�.�y� / /%i ,n: .: JiL �.�.. ,.:,�����,.,...:�//i, /�/ �<, .i.rw„ , %� .,.,.�.�y / „� /.sY3 1 1 r 1 Custo mer: Pioneer Natural Res. Report #: 22 1 HALLIBURTON Well: ODSN -40 Date: 05/29/2008 -5:00 Area: Oooguruk 05:00 Depth 8731 Location: North Slope Progress 24 hrs: 0 # Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating Job No.: AK -AM- 0005710855 Report For: Rodney /Jeff Daily Charges $3,500.00 Total Charges $72,500.00 I -, iC;;,. /- :,,"?l'?' ,9,." r . , ✓/ G., 41 / ✓ _ ... �/ / _ �" w iz :?' y x et ROP &Gas: Current Avg 24 hr Max Max 0 ft Pump & Flow Data: R = ROTATING • R.O.P. ft/hr Flow in • •m 250 SPP •si 940 i 1 0 0 0 Flow Rate s• m 71 Gallons /stroke 3.6 %% t ' ®r;<'/>j��,,�'���J /, //'`✓';>,✓ / it. // r y� // , :: ' y "-: ,,.w � :!_" s^ i f rj <� -. L LL/%,J,Y,�y .'4'.5 , /fry.! ,, ;�`"Y"'/��, ,., b �/G '�'�6 / %i, ,:,ir ;; "�' ".5'/�. / ,�.,,. ,, , , '/,, ,. ' ,:• �i,, :.4,., v�`, " .,,G ,,,,, oz, a, Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids De•th in out sec /•t m1/30 min cP Ib /100ft • • Volt • •b % 8730 11.5 11.5 88 3.8 33 12 282K 517 3.63 14.0 ✓,' -,�i. �: „ /G /,v : • '.!' ,!. l E �.:;:va,. ,.,;M %,..;'t�i�� / „�,,,, ,, ✓, ,.i i /r .;.,., «/� .., „, ,ry,`„ ,>' y >✓i y BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 4 FMF -2643 8.75 1.178 0 8731 0 0 40 301 Smith /MZ7514 8.75 3.142 0.53 8731 8731 0 0.00 0 in ` Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current -_- 25 15 60 - - - -- , �. x � s'✓ rr c �f� .� v h ., ✓ ,1 /r.-..tits ' , sir a.. /. /'shy /i.,,F =:va, ,�i ,, . Gas Breakdown y Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I to to to to to t0 to to I 1 to to to 1 y` Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas • 24 hr Recap: Test BOPs, Make up BHA #4 and run in the hole with the same. At 3400' and circulate bottoms up no losses 1... recorded. RIH to 5350' ( -9 bbls), circulate bottoms up. -10 bbls displacement, Hole breathing lost 20 bbls got 10 bbls back. Continue to RIH to 6650 -15 bbl displacement. Circulating bottoms up, hole continues to breath, 33 bbl lost, got 21 bbls back. Reamed and washed to 7590', sticky, jars went off once, circulating from 23:30 - 03:10 - 77 bbl loss. Backed off flow rate from 300 I gpm to 100 the gradually increasing rates. Taking spot samples every half hour, mostly fn pcs of claystone with decreasing amounts . of LCM material. I • Sample Catchers : Andrew Chilton / Josh Gagnebin Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air . S �i . ' ��. ��/ _ .r < L/� „ <,. /: p✓ y!% //� i/i is ( / ?A , s�.,.,.. ,. /.�: %� �'.� zFi., i�� ,,,;.,�ax...���/F./�i />c,'i %/ ,,,,. �,Mw"z�,� /,,...:�� /tif�s ,.z� `����,..aeµ,3���y �r�._i.� / / / / „i /�' ,,.� >��y�i� „ >�' 1 1 1 1 ii ,` „ ,,.r„ r,,�, /,� $4 a / , k %,_, ::( ii,. m s , v. %l, "ey� "Ail � 1.' Fr;? Ito , � :, I • , Customer: Pioneer Natural Res. Report #: 23 HALUBURTON Well: ODSN -40 Date: 05/30/2008 -5:00 Area: Oooguruk 05:00 Depth 8731/6033 Location: North Slope Progress 24 hrs: 0 IN Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH ■ Job No.: AK -AM- 0005710855 Report For: Rodney /Jeff Daily Charges $3,500.00 Total Charges Y es $76,000.00 I ii 9 9 ., / r ^ , ; / / / / , � ,r r. 5 % ` � / / � y ; Y : V. ROP &Gas: Current Avg 24 hr Max Max @ ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr - - -- Flow in • •m 0 SPP •si 0 0 0 0 Flow Rate s•m 0 Gallons/stroke 3.6 Mud Data: Density (ppg) Viscosity HTHP PV YP El Elec Stab Lime Cor Solids is I Death in out sec /•t m1/30 min cP Ib /100ft Volt • • b To 8730 11 5 11.5 82 3.7 42 14 259K 574 3.89 15.2 u P . � i /i / /. i . - <ui . larn, ,,,, , : r xr¢�iV �I�,!! ,.' a,,, . !. /% /. . i, BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 4 FMF -2643 8.75 1.178 0 8731 8731 0 0 301 Smith /MZ7514 8.75 3.142 0.53 8731 8731 0 0.00 0 s/ %', //i. i � , / / // / ,1 .*" ' �� - x „ ,, ,., , ✓: r ✓ .,o,ce,,;; ., ac,,,,,rn /,,,,�, ,.., /,�;,;,, ,� ,.�; , xs,��_,.r..x ,,,, , ,. ,, x� //, �f%i '' /�, i „ice, .���.��'.,•;. �s�. ,� , ,,u� ”. -.'.4. sue I - Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current - -- 25 15 60 - - - -- . . ,. ,,,, %, < ✓ %o. / / .. h /F,.' /,,.,i,,... rail r',k'1.,, I .,,,,'1 "17, I Gas Breakdown Gas (units) Chromatograph (ppm) ' Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type I to to / to to 1 to to to to 1 to to to 1 - Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas �, .. ,. -. �; ii / / / /%? h ". < �, /fi /� F / s z�.a.. i /� /,/ /,/ /, >'� / €:; �j.. . '. /. � � �/ �:. a a te :/ . P :. y p /i / %k, / ..' r .% 9T �. ����1/ice ,�.i..: / %�i�"' -; "� ��%i;� � ;,. ”- f���; /`� / / / /s/� � /_ �� :� /�., ..� 'i'i,,,./ ,� '�`'r. � ., -;'. I 24 hr Recap: From 0500 to 1800, reamed from 6690' to 7650' well was breathing, bbls going in same as bbls going out. it From 18:24 to 19:47 reamed from 7679 to 7775', 108 bbl loss. From 2010 -2050 Reamed From 7774' to 7870', 48 bbl loss From 21:14 to 21:57 Reamed from 7869 to 7961, 68 bbl loss. From 22:50 to 02:10 circulated 125 bbl loss. I Start rotating and pumping out of hole to 6825 ft, continue to POOH without pumps. j Kevin Mullen comes out & Josh Gagnebin goes in. I Sample Catchers : Andrew Chilton / Josh gging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air ,; ,,,; .,��.r� ,:c/fr.��% .:Iiili ✓ / /,.,,,,:1,. . , ,,,. £ „„ M :� , . * � ' v° ,. r,:a:�:.�,, ,. !� //, ..._ i � /,� /ii;2 F C. � y 1 1 1 . . a% >. ". : ,,,' \,v..,.:, If li..... .�",✓�/Ht�u' i, . ". ..:> �, . ; x,"; .,r. _. . .< :. ,,, »% :. ,,.,> i, s V. e,: iftAt 4 HALLIBURTON Customer: Pioneer Natural Res. Report #: 24 Well: ODSN -40 Date: 06/1/2008 -5:00 Area: Oooguruk 05:00 Depth 8731/7052 %. Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating 1 Job No.: AK -AM- 0005710855 Report For: Rodney/Jeff Charges $3,500.00 Total Charges $83,000.00 �� ` � /r"I / r., / /� 9i�: y r �,� _ " , ! �i / ..%'v,r'r.n"' ; a' r F a r f ' y� ,! / ! ` ✓ '� , � . ` ,; � : ' ,.' e /� .. „. /5�� , /.i2/ , %'�.,,,/�,r'. °f a ROP &Gas: Current Avg 24 hr Max Max @ ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr Flow in • •m 247 SPP •si 578 I v ` IREFEBBIE 15 22 180 7796 Flow Rate s • m 70 Gallons /stroke 3.6 . ” :'*ifl "4— r, ,� .:1, , ., . : 4 . ,�� I me Mud Data: Density (ppg) Viscosity HTHP PV YP IN Elec Sta. Lime Cor Solids Death in out sec /•t ml /30 min cP Ib /100ft Volt • •b 8730 11.3 11.3 . 91 3.8 34 12 247K 739 3.63 14.4 titt h- j /93 �r r / r.fh:, / /' //,.,.. /.i,y �, ins, �,,,/ ./ %���i _ s:� y..,. , iii',,,,, ;: �, oi.. <;y�yir, >L. , .r;�% �., „ .a ,,,,, ,.: , f. , e ,,, s,.,�; s.. , „2,�i.,., „ ,/,,.� � �, r � ".,. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 4 FMF -2643 8.75 1.178 0 8731 8731 0 0 410 Baker/XR20D2T 8.75 2.356 0 8731 0 0 0.00 120 ; /. �; , ,. y�* .�/r..,,,�r:. 4 .ii ,1,;� i.,',,, „i ,,.x, -_..,� ,'�'��',�� „ ...1 .:. # �. , ,�L s �i� a,,, ,,,: <;.r�s_, . /:,, ,,v. ms,..... ... c,.,....;.� ,.,.;,,,,, „ .. /. �,�, .,�., �,,.� "...4'.::t. (� I Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff — current - -- 25 15 60 - - - - - . � 1 ;' .* • - / / /// ,E fir / x,', / /., x r �r,�, r l i .'. . :,tea: � ., " . ?` , �.,,. s.,.� /.,,, ''.,,.' �r�,,, �.�.,. .,,��,.,,,, � ;a �i,,.,., i' ,,,. ...... y I Gas (units) Gas Breakdown Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to to to to to to /,', to to y to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas + ' ✓ g ✓ �� r/ // y / F "3 ate„ ' .. // Sty 5,1 ..i:lritE .. ,,,,1 ... d 7� ,.f / ..,:a I / 24 hr Recap: Circulated and conditioned mud, dropped ball to open ports and close BHA, spotted 33 bbl LCM pill C© 7893' f POOH from 7900' to 7323', dropped ball to close ports and open BHA, Continue to circulate while waiting on WBM to be made up for displacement.y / "- +F Sample Catchers : Andrew Chilton / Kevin Mullen Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air ry ' s,r x/ /., .. �/� r r r: pa sY � �� � �s� a� ., ��� � <✓r i, r / /r,,,,., _m" .. ,: n." / /yii rs.�9..�;25zv.. . /��i/.�i ✓//�/i//� //.,�1 s 1 1 1 /i r r y r / / y rir s =�/ / ✓ a a ��'/, rx����% �. ��� � �,,, ,� ! , rs, . Y , . „�,.� ,> ..'5 +,6�/ % r. ��.: z,i. ��%% ?��� t�s�r v�, ..� l: l�. : Customer: Pioneer Natural Res. Report #: 25 I it HALLIBURTDN Well: ODSN -40 Date: 06/1 /2008 -5:00 Area: Oooguruk 05:00 Depth 8731/7052 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circulating 1 yS Job No.: AK -AM- 0005710855 Report For: Rodney /Jeff . Daily Charges $3,500.00 Total Charges $83,000.00 II ,.✓ r a d ' H , rs, , , � '.0 :: h is / ,„ ,i;, E ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING ^'�� R.O.P. ft/hr - - -- Flow in s •m 247 SPP •si 578 15 22 180 7796 Flow Rate s • m 70 Gallons/stroke 3.6 Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids De•th in out sec /•t mV30 min cP Ib /100ft IFil Volt • •b % I N 11 8730 11.3 11.3 91 3.8 34 12 247K 739 3.63 14.4 / � :. / � r r //i r ✓ ri l - .( /„ / %S / r�/ �� � / ✓/`�% !/ � / ✓ rs r"'�� /r � � g; � ✓. � �''�' s. -: ,. , .,� . ,.., � " '„ ,, ., � /'. _ ,, „ -,, , ��a .. � . ,,, ,,, � /!. r � ���`i,.r.,L�/,,, s �., l��s. �. , �.. _ . �d r ,� • BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 4 FMF-2643 8.75 1.178 0 8731 8731 0 0 � � 410 Baker/XR2002T 8.75 2.356 0 8731 0 0 0.00 120 '" r // ✓ y/ / ✓ , a - . „ .4:;:':.. ys yi/ y ✓!/ ✓ h ✓ / Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff I current 25 ... 15 60 / ✓F/ �✓ - *yy is tii j 3 .......1M. /// s/i : rx . i . r Gas Breakdown I Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to I to to to ' to to to .. to I to to to 1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG Trip Gas 5. / �r� r' // �/ / r'/ '7" i4117— / F / /, / '<Y /� //' r/r 40,7' .r.,. 2 4 hr Recap: Circulated and conditioned mud, dropped ball to open ports and close BHA, spotted 33 bbl LCM pill @ 7893' I f POOH from 7900' to 7323', dropped ball to close ports and open BHA, Continue to circulate while waiting on WBM to be made up for displacement. Sample Catchers : Andrew Chilton / Kevin Mullen I % Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air ,✓i ..,d ti er , T r // -r , . a i /// i/F �r ,. �r /ir,,,;'„ , #.'�., %. �ri /. /jif ! „ a�!i /r /%r mss. // '.i 3* ��9 �,� %�f„��,..w ,, ✓'� <,'�'(� '����C,:',. Viz,,, ✓, ���', ���/ il/ i/,- o�,,,,',: ��, 6��i,/,,, c, ii,,, �.,:: T, 9b�jio/ GC, i�%/. ���, ����������%.,,/'/r y yr' ���,,,,,z��� /r,,: ",u,' / ✓,�' „_., f,� -:, 1 1 � rq . ") �'/ t/r / y - / “. x : o/,�✓'� s ,/r ?t isx;,/ ',� y / /' � . ��' „���!”. ', r�a/��a`r„ :r.,,,,, ... _. ,.. , , i;„ . , . ,., �;, yr;,y'i ;'. ,,,.,,;,� ..e �� //; r�.c�. „� - '�. �<, / �F� � � Rl��.,^�', v, , , .._, .,��, -. ,... � ..� . Customer: Pioneer Natural Res. Report #: 26 I u Well: ODSN -40 Date: 06/2/2008 -5:00 Area: Oooguruk 05:00 Depth 8731/3424 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Displacing Mud Sys I Job No.: AK -AM- 0005710855 Report For: Rodney /Jeff 1: Daily Charges $3,500.00 Total Charges $8,650.00 i s / ' / � /i ,/ _ i C� r. r yx , "Y . " : x r r,,. r/ +` a. I ROP &Gas. Current Avg 24 hr Max Max CO ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr Flow in • .m 247 SPP •si 578 0 9 63 7836 Flow Rate s•m 70 Gallons/stroke 3.6 I _ c IV "// / % ','�,�'`y / �,1 %i /%, S.. / // 4 r q ?y /F r ., ✓ /� � i r j'. / /;',^ "� / r/ x ri fir 'r ��', � "'�,�%� ���'. ;cx`�,.� r��, < .fir. /�i ��., 4,;,,, , %' �i/�. ,. . ,�/„ f , �/. . a„ �r!::�/',.,, y : � /> „i�, ,,, .,.y..�>�r.,. - ,,, _;:� . �Gi;�,L /. ��x/ � ..r.. �% � . Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids Death in out sec /•t Ibs /100ft 2 cP Ib /1008 m• 1 m1/30 min % 8730 11.5 11.5 75 9/12/- 19 24 247K 739 5.60 11.5 r7 / , ° /' . r r r b ra y ri /r , . i r _ Zti /// . 'iti %/ ,. // r - BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I j 4 FMF-2643 8.75 1.178 0 8731 8731 0 0 410 Baker/XR20D2T 8.75 2.356 0 8731 0 0 0.00 119 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I current 25 15 60 .;;r��. /1.,, 14 ' ic % C, H /,.; 114 i .._.....�� I'. ,....% /, zs.9i /sa 6 0 .z,,,., ,,. >; I y'. Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to I to to t. to to to to 111 to to to ' Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; ' BUG Bottoms Up Gas: POG pumps off gas TG Trip Gas ' %/ /..$ /i r s -f r � /L�,�a >. ,: 1, .,,rr , /r,t / / /.: t.”. �- ; / „t .,,,% �� ,. I 24 hr Recap: Circulate and mix KCL Polymer. Cleaned pits, RIH to 7888', circulate © 400 gpm with mininmal losses, Displace OBM for the first stage, pumped 159 bbls displaced 160 bbls. POOH 20 stds 5950' md, Pumped 105 bbls displaced • 100 bbls. POOH another 20 stnds, 4090'. Pumped 123 bbls and displaced 125 bbls. Pull back to shoe, I Sample Catchers : Andrew Chilton / Kevin Mullen I Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air � is �57` r ' r/ y r: / yr r r /rr / /r c./ „�f�� .o.:. C / / /..��/ // �ioi,/ri /, a .,�„ f ,.��i. i .,.. �. ,"u.� x��,i ,,. /ri�i,r.�:.;..,,. i , _ i u��XF /��� /iiv.� <ii�.z,�"F /�,/iu „__, ��, .. i ✓ „r,,, , /�,. , 1 1 / " S' //^ ' y r y :_i � i/r r�'� /T /' �T * '/„'� a .. �i'^'" /,� i" -° a^ r �. 1 /., , !fie ,.. % /?,.,. h > / / ���',j� ! ,. m, ,. ..yam /i, ��N, .„ Res. {' , _.. /r,,,,,,F ..r � .s„ Y ' / S � ' Customer: Pioneer Natural R , �` . Report #: 27 1 1 HALLIBURTON Well: ODSN -40 Date: 06/2/2008 -5:00 Area: Oooguruk 05:00 Depth 8731/8653 Location: North Slope Progress 24 hrs: 0 Sp @t'1'y �I'I���l1g @t'VICBS Rig: Nabors 19AC Rig Activity: Displacing Mud Sys 1 Job No.: AK -AM- 0005710855 Report For: Rodney /Jeff Daily Charges $3,500.00 Total Charges $90,000.00 II *err s ' !i. . r'%� g , /,., s. �F. /� , .. %r >,.,�., ?.� , �d , �' ' � 1w ` . „ / . i• lrl ' s,. -- * f % j � , ROP &Gas: Current Avg 24 hr Max Max 0 ft Pump & Flow Data: R = ROTATING n R.O.P. ft/hr - - -- Flow in • 306 SPP •si 680 4 5 3 I 2 581 7964 Flow Rate s • m *. , , � , * , r 83 Gallons/stroke 3 6 r , . , , �..,, ; �/ �,'. ��✓.��, � / >'i. , lam. .. ,, :. �� /..,, s /,zs.. , i .,.: s '`s 4 . ` ,..4 Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De.th in out sec /•t Ibs /100ft 2 cP Ib /100ft m• 1 m1/30 min % 5 8/ 13 15 8 24K 7.40 ' 8730 11 5 11.5 45 / / / / /// %� / ' ' % � „: a Vii/ `` / 3 . ; card ;� 8 a '`3..� /,/ i��iyi 1�� f...,'� /,. '&. � c� � /� - :� .�"�'l i ,. , �., L a"�'� j��i% � � % i�. j / "� 13.3 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 4 FMF-2643 8.75 1.178 0 8731 8731 0 0 410 Baker/XR20D2T 8.75 2.356 0 8731 0 0 0.00 120 ... r _ .. ,y / , Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl vI Tuff I - - 25 15 60 — — — current � «: I Gas Breakdown Gas (units) Chromatograph (ppm) 4 . Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type . , 7916 to 7986 581 34 TG to to to to ' to to t ' o to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas /// <iT aa'Fi'! .. i �i , i , /i/ ,,. �'�„�j/ij //i ,,,..,rs �,.,,.. �r ,, ,., /2;! °4k.' rll / /,r—"d , � t&%' /., , , I 24 hr Recap: Completed WBM displacement. Clean pits and building volume. Volumes holding steady during cleaning. RIH to 7964' Circulated B/U received 581 Units.Trip Gas. RIH while pumping to 8760'. Adding 20 bbl /hr to the active but was not seeing any increase in volume. 1 Pumped 25 bbl LCM pill, seemed to stop losses and started gaining back, reduced water to 5 bbls/hr at report time I ' Currently circulating at bottom. Sample Catchers : Andrew Chilton / Kevin Mullen ' % Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air a d ip / / . ' ii / % i /ji r i i a '// . / ;: i.. v.... �. �(i c .,�� /..�...o�,. %,,,, ;i, .. ,�i /,; /..., /ii //i of/✓. /c;: v /r.: �ia % sc �G ... ,,., � � lJ, ;! 1 1 'rp � y� / ,� y %� r. r ii %/��� er / ,rte /'� .? /.�/� /� S 1 . . /lo „' f, r, 't, /, ,., 14 ' „ . >.las „ . / /rte , `. 4414 / „i�;!/ , ,,,, ...31t1 , , ,,.:.,�,, �"�/',rr„ „ ., A� - •�%, ti,,' ' Customer: Pioneer Natural Res. Report #: 28 I �� y Well: ODSN -40 Date: 06/3/2008 -5:00 Area: Oooguruk 05:00 Depth 8731/8653 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH I Job No.: AK -AM- 0005710855 Report For: Rodney/Jeff Dally Charges $3,500.00 Total Charges $93,500.00 z 3 r 14S i _ ' , / k . / `/ r / ry .. s r / y /, ROP &Gas: Current Avg 24 hr Max Max @ ft Punt • & Flow Data: R = ROTATING R.O.P. ft/hr - - -- Flow in • •m 0 SPP •si 0 0 42 174 8614 Flow Rate s• m 0 Gallons /stroke 3.6 / / ,r • f. 141' � // Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids s..; De•th in out sec /•t Ibs /100ft 2 cP Ib /100ft m• 1 m1/30 min % I 8730 11.5 11.5 48 5/6/- 20 17 8 25k 7.40 12.3 / J a C// - fi° // 3 / r/ : / r E': /,l' ! ! ,' i/ / a /,s5 g ... /; BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition ' 500 FMF-2643 8.75 1.178 0 8731 - -- 0 I i 410 Baker/XR20D2T 8.75 2.356 0 8731 0 0 0.00 120 aa /ii/ * vH � i s � '4'4.. . / �i fi '� ��,'�, //���j �3�X% .� x, ,, , „�.�5 �,,, .,�k � �� ,.,., •x��.�, �/„ .�..� :., !, - i , , -„ „?emu "s � �.�� � ,,, Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current - -- 25 15 60 - - - -- / // r :it.- / ,.: < / /r/ li : % i / / / ` ter I Gas Breakdown Gas (units) Chromatograph (ppm) D epth Max Average C1 C2 C3 C4 Tot C5 Tot Type to to to to to I to to to to ' to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas TG Trip Gas / z . .(, : .r ,._ , �,:. f Vii, � o ,L . " a , k .. ,:'. % ; // / /r 24 hr Recap: Continue to circulate, staging up pumps to 400 gpm.No losses. POOH to test BOP's and pickup BHA #5 I Currently waiting on MWD I Sample Catchers : Andrew Chilton / Kevin Mullan Logging Engineer Eugene Payne / Mark Lindloff 10000 units 100% Gas In Air ; j i ri ✓ r //� /i / ;a� /i/ _s / / /�j / % y r / i k / / a$ ,� 6; ,, � Yi , a,,,,,, r�,yI,. .;&�a ✓�,/ / :i: N6',fJ �, „'�' /�,�c.. l .,�':'. ,,,.�c /, / /,,. „ /o�.,.., ,.1 .':,, / � /, ,,,,,:..�s ,,, //i„�,� /„ ✓// /r /t , �/ i /,,,,�, ,,,,,,r,,,,,; c�,,,,. / /f5 1 1 1 r r : / ` , Cy' / � i > y " fi ,.. " % /y ' ✓' . / i 3 ' i " yr ' xi / ?� � .✓�ry . f !c':'. /,ice >.,,r.w,.,. ,,. r i. /�„ ,,,,, , , ,:",. a,;,a /,.,.,F;Nrw�,� /,� „rf� ,,....ti . ,•"�;x Customer: Pioneer Natural Res. Report #: 29 LLI Well: ODSN -40 Date: 06/4/2008 -5:00 Area: Oooguruk 05:00 Depth 8731/8649 Location: North Slope Progress 24 hrs: 0 i. Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Losing Circulation Job No.: AK -AM- 0005710855 Report For: Rodney /Herb Daily Charges $3,500.00 Total Charges $97,000.00 I Pl., r ' //a r / // *./.. /ai r ,f /� .¢ ay R & Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr - - -- Flow in • •m 100 SPP •si 260 IMESEEMI 0 70 509 8081 Flow Rate s • m 29 Gallons /stroke 3.6 ' x z y . ! i ,r rs/ , r / a.. • / i l ' /r,/ r�r y �.'i s ,�:;; %/ ,. i�'r ,f r %.s r 'tea , I .i. a}7, /, , �, ���,.... , <L /y /e ,.,, . hF �� . ,���'iL /// i:. r , „ ,,,i; u, ,a3,.;;: //'�?i .§&, ,: �.'� ; ,., ,�.i���J �u / /,., /„ �t, i,.. / v, t , ,r„�£ -s, '. Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids Death in out sec /•t Ibs/100ft 2 cP Ib/100ft me/1 m1/30 min % 8730 11.5 11.5 57 6/7/- 18 23 9 25K 5.80 12.3 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 500 FMF-2643 8 75 1 178 0 01 8731 2 6 0 5 10 I 410 Baker/XR20D2T 8.75 2.356 0 8731 0 0 0.00 0 ; ' r A.. a i r 4 ' ei / , / j� r. . ,�i-<N " " � , ��... _ ,r' � ,,, ,r,,, .. ...'eu.r „A,r.�6ii •� 7; ,, ,fi r, ,. 5njz"z� Y „ic .. s , ,/,,,�,,,5 ,., ,s.. 'rm,,,, .. :r .. ��S . ; :r�,.e Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current - -- 25 15 60 - - - -- r y •' / - ^ y fro � i_ !i r % r,., 4 - . f �, �, ;,..,;! /,,, � �� " „!,��r��t�z:rl�� •� r ��/ i , � / /;� / /ru„ � „!ri_ „a „',.,, o-r, ?�1 . ,.r /�, /,,, , -r , c..,,; ,,Y �:.. ,��, ��v /,. � /... .x� Gas Breakdown I : . Gas (units) Chromatograph (ppm) s. Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to ' to to to to I to to to to to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas TG Trip Gas ., , r irr r / � ,. % >i; s . ,�� „w, �sary ,/ /!�, .�i ,,, o % ..�i'i%ti „rr �/, �����/'. ,;.�i»� %�r,�..�,,,,�,,, �/r�. ** (...1 „ ,,, ,...ft „.'Ox y` 24 hr Recap: RIH to 3380' md, circulated and conditioned mud. No Losses, RIH to 5850' md, Work through 4784', 4838', 5400' I tight spots. Continue to RIH 7721' md, Tight through 7640' md, started taking losses at 7900' and @ 05:20 pm. averaging 90 -150 bbl /hr. Stopped pumps at midnight to minimize losses. Averaging 5 -7 bbl losses while pumps off. r Currently getting ready to pump an 85 bbl LCM pill and sqeeze. Sample Catchers : Andrew Chilton / Kevin Mullan - Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air 1 1 . by /j ii/ ri r rK .y ✓ / / ✓%"s/ / rq ✓r / ' s i` ✓ !//r'r . 71.'"' " r m f'x�" r g , /' , r % / r � � '� ���������"l "��`/iy/ �r5 > ,� ��,z < �,: -�- ��� "� .�r ":.�,�°+d�l��l, �/ / / ,,,rrr , �y/ ���„ ��%"" r% ��j "�xi`C .,,,.� , x� . �� % /:`r�/� Customer: Pioneer Natural Res. Report #: 30 LLI Well: ODSN -40 Date: 06/6/2008 -5:00 Area: Oooguruk 05:00 Depth 8746/8668 Location: North Slope Progress 24 hrs: 15.3 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Building mud volume Job No.: AK -AM- 0005710855 Report For: Rodney /Herb D aily Charges $3,500.00 Total Charges $103,500.00 . , .,rr, fir.., z . r ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING • R.O.P. ft/hr Flow in . •m 0 SPP •si 0 a 0 2 48 8741 Flow Rate s • m 0 Gallons/stroke 3.6 • Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids " De•th in out sec /•t I /100ft 2 cP Ib /100ft m. 1 ml /30 min % s. s. 8730 11.0 11.0 65 6/7/- 18 16 9 24k 4.80 10.2 � ) r / " ' ` ,/✓ // r /r y r yi C, � a / qr BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 500 FMF-2643 8 75 0 90 0 01 8731 17 9 0 5 10 I 410 Baker/XR20D2T 8.75 2.356 0 8731 0 0 0.00 0 / a s:*r., .+si .;.,.i{ ", ,.i� r., E ../✓ .,,/ i; +;.,.k,, ...i, ='i' . .i;rf / /.' , .'i'r ,..'i'�," , /, „, s; ,cr`, „�" / Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff I current - -- 25 15 60 - - - -- II Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to I to to 1 to to to to to t0 I to t0 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I 4. BUG Bottoms Up Gas: POG - pumps off gas; TG Trip Gas , �'"ir,,, / /i, , ,F. /�li a „i% a "., ,.. •lzi .. Vii, / /,!v . ,.r", 4 >"� % r /. � h /r!�f/ /� 24 hr Recap: Pumped 75 bbl Icm, at 120 gpm. Monitored well for ten minutes, with 6 bbl loss, Squeezed LCM, monitored I well for ten minutes 40 bbl loss, Dropped ball to close off port pumping at 100 gpm. Staged pumps to 350 gpm drilled from 8732' to 8746' and (losses 100 bbls/hr), Pull off bottom and circulated losses jumped to 200 -250 bbls/hr. From 15:50 -18:00 ( -439 bbl total bbis lossed). At 1800 stopped pumps, monitored well 14 bbl /hr loss while staic. I Drop Mud Weight to 11 ppg, and build up volume. At report time losing 4 -6 bbl /hr while staic. Tom Mansfield out/Mark Lindloff in Nick Douk out/Andrew Chilton in • Sample Catchers : Andrew Chilton / Kevin Mullen I Logging Engineer: Eugene Payne / Mark Lindloff * 10000 units = 100% Gas In Air . r // /r! r ✓ i 's • z�, �� / /�,,,,` „n ��i. /rco�h, ,,,;r / a,,,,v,,'u� ���� /r /';. ��� %��i� : � /�'�,,,a; ��i�.; ,,, Ai ' 1 ' z% k,, ,!0 i„�.r N;.i,.. .. a.;;< „ %,,,.. ; ,,,ar; .,` l ''t . ' , . .. i .., '� ^ . . ' .. ,..,,.,. 1 / ✓' r'� .,,.., s e';i f Customer: Pioneer Natural Res. Report #: 31 HALL1BURTON Well: ODSN -40 Date: 06/7/2008 -5:00 Area: Oooguruk 05:00 Depth 8764 Location: North Slope Progress 24 hrs: 18 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Trip Out ' Job No.: AK -AM- 0005710855 Report For: Rodney /Herb D aily Charges $3,500.00 Total Charges $107,000.00 ll / - -it S ri r s ir 4 / r� - ' rr t / ' �i/ y r 111 e r ROP&Gas: Current Avg 24 hr Max Max CO ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr 0.0 38.0 69.0 8754 Flow in s.m 0 SPP •si 0 IIETIEMII 0 38 311 8751 Flow Rate s s m 0 Gallons/stroke 3.6 I rr -z v G t . .y /: /•r // r' / , / / % �r r r� S 7 / '. i/ r ,� � r/ r,,:. ' � u <i ��.?� �. //r c. � ..r � � •. ' ,.a ' 'A?,. .. �` ..,,, �i : F.��' >..` Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De.th in out sec /•t Ibs/100ft 2 cP Ib /100ft me/1 ml /30 min % 8730 10.0 10.0 56 7/9/- 11 23 8 22K 4.50 6.3 ,; BHA R un # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 500 FMF-2643 8.75 0.90 2.7 8731 8764 33 0-5 130 410 Baker/XR20D2T 8.75 2.356 0 8731 0 0 0.00 0 r / '.'�:e ,,, 4. ` <: �, ,. .1.4::' a/„ .o. � „-:, „ fin , Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff ' current - -- 25 15 60 , r . - - - -- a� /'i /,,, ,,.. , , ,��/r /� ...� fig. � y, � •�.�- /ir;,;r;;;�i,�r ,rii;'yx., . s ✓ � :,. �- � r,,:� .� � /� ,...,,, ✓..,�� : ' Gas Breakdown Gas (units) Chromatograph (ppm) D epth Max Average C1 C2 C3 C4 Tot C5 Tot Type 8731 to 8732 48 37 4174 292 190 130 32 BG I 8749 to 8751 311 199 20631 688 276 135 33 GP to to I to to I to to to 7 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; 1 BUG Bottoms Up Gas: POG pumps off gas TG Trip Gas ' i i',.c of /r, ;;..: , s,.. .. n , ii .* y% :g..,... r ., r ,,,, . , ,,,.,, 24 hr Recap: Built volume to 750 bbls at surface. Losses to hole at 200 to 250 bbls/hr. Drilled ahead to 8764'. Stop drilling when surface volume dropped to 200 bbls. POOH. Build volume at rig and RSC. Hole taking approx 5 bbls / hr at midnight. Trip showed loss of 54 bbls over calculated displacement. Lost 555 bbls last 24 hrs. Reduce MW to 10.0 ppg in preparation for cementing back for new sidetrack. 1 r j Sample Catchers : Nick Douk / Kevin Mullen 1 Logging Engineer: Eugene Payne / Tom Mansfield * 10000 units = 100% Gas In Air x 1 1 x r /yy" /ir .. . * ''''T �� y ' y ' 4 -` G f . , � 1 ''�� y '. /� ' .: � f a d'' �� ,,,, � r Ai, z5i, ,. 's/ ,� r:�s �.- s�. / >,,,�i�,.,� a..� /,ii � �;. i,,J� „ .. . '; �i ti, „, sz�/.�i �r�.ti.. .N r �u� '��'flir,r,,,,,�u,��� i .,� ,� 7^ ,r..� Customer: Pioneer Natural Res. Report #: 32 T Well: ODSN -40 Date: 06/8/2008 -5:00 I Aea: Oooguruk 05:00 Depth 8764 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Plug Back I s Job No.: AK -AM- 0005710855 Report For: Jim /Herb y Charges $3,500.00 Total Charges $110,500.00 111 P "f4 yam., . ROP &Gas: Current Avg 24 hr Max Max CO ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr - - -- Flow in • •m 0 SPP •si 0 MIMEOMMI 0 136 1655 8764 Flow Rate s•m 0 Gallons /stroke 3.6 I / r r /i i/ /y a ri s ',It: / rx- 1:31.4. �. '!."14!. r`s . r / / / Ca r/ / r Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids ' De•th in out sec /•t Ibs/100ft 2 cP Ib /100ft m• 1 m1 /30 min % I / 8764 10.0 10.0 52 7/9/- 11 19 9.7 22K 4.30 6.2 t r _ / , y / r %f L ' :; .. j ' s/ ;. 41- , i :/ ..flit'” � /, /ii fl.' ' "; 'JMW' W. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 500 FMF -2643 8.75 0.90 2.7 8731 8764 33 0 -5 130 I 410 Baker/XR20D2T 8.75 2.356 0 8731 0 0 0.00 0 L ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current ------ - - - - -- ,. may,.. ,1 ,...,: ..,. w .., ,r. ,.. Y . -: F . : ",.,..... iri ,.,..r i.. Gas Breakdown I Gas (units) Chromatograph (ppm) 4. Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 8764 to 8764 1655 136 166242 5238 1408 408 67 TG to to to 1 to to to ' to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; 9 BUG Bottoms Up Gas: POG - pumps off gas; TG Trip Gas y i,.L aw , , , yc �:: /i/ /,�,,,, , s�. , . � /. � �''�'�j/ /.��,:w.�� /�i,. �.��� � , /�r/5s.,�/' ' � _.<, 4 '!' , � i ��.,,, :.. ,�t�j //�r, ;ia / � f /iii;, /, , „ / f. : � ! r 24 hr Recap: RIH to 3400' and displace heavy mud with 10 ppg mud. RIH to 5135' and displace with 10 ppg mud again. RIH to 6857' and displace with 10 ppg mud again. Displace with 10 ppg mud again at 8755'. Hole was taking 15 -20 bbls /hr circ. off bottom, 35 -40 circulating on bottom. Pump 15.8 ppg cement plug with 1655 units gas at bottoms up. Pull up to 7530' and circulate. Prepare for second plug. I Sample Catchers : Nick Douk / Kevin Mullan I 5 Logging Engineer: Eugene Payne / Tom Mansfield * 10000 units = 100% Gas In Air '� % /%i r� .c ,ri r ��r,ri/ ss . / /'ri ��''i / r c;r.,H- /,/ � ��� '�� � � �'% ����'/ //✓ , .� y !� / � ' ,y , rr ;,, � �' i t � � � ���� � / ' „ /' > , ,,,, �, ��� _,.. , ,i iii/ , /i r,'. ,, , ,,, �. ,,,, „_.. , z,,,,x ,.., a.'�i.�r<��� /,ii�z, ,,. „ /i / /rr /, ,... /r ...�z /.. � r i,., ✓.,, . ,, ���,.� III.. r 1 1 1 �.�.L /.., „.' ,i,:.�o�,u,,.,.�"Y; �. ,.. .,,�.r,., /,% s,�r;�<,..:. /, .,. „ .r� , r.:..� „ :%'./ii ;,i,;,. �.3,.... �., L .: .,.�� .. r.b,, ,.... h,, ,_,... Customer: Pioneer Natural Res. Report #: 33 LL1 TD ' , Well: ODSN -40 Date: 06/9/2008 -5:00 Area: Oooguruk 05:00 Depth Location: North Slope Progress 24 hrs: 0 Sperry Drilling services Rig: Nabors 19AC Rig Activity: M/U BHA yam; Job No.: AK -AM- 0005710855 Report For: Jim /Herb Daily Charges $3,500.00 Total Charges $114,000.00 ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr - - -_ Flow in • •m 0 SPP •si 0 1=111[5' 0 75 157 a • • rox 7300 Flow Rate s • m 0 Gallons /stroke 3.6 /„ � i` y �.� r /l%y i / a .. F ' y % 1i / r lF. " -- '.✓�.r,” , � ti �.:''.�H' �. „ <� ✓� �� ! - �,. ,�. � .. ';: � , a- : -�,�! / �, /, , . v . ✓. / / „�,: �'.�✓, ., /�//i,.�y ��'lf��r� r� '. �.y. ,� � % /�� _,,, � , �= „a�:"�i ,. -� , ,'` „ i r,' , . Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De•th in out sec /.t Ibs /100ft 2 cP Ib /100ft m• 1 m1/30 min % 8764 9.8 9.8 60 7/8/- 14 24 11 21K 7.00 5.3 I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 500 FMF -2643 8.75 0.90 2.7 8731 8764 33 0 -5 130 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff i current ----- - -� -�- /' / // K ,Gil - { * '. ' 1. , - r Gas Breakdown I Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type to 158 75 15346 736 387 205 71 BG I to to to I to to to to to � Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG Wiper Trip Gas; i f BUG Bottoms Up Gas: POG - pumps off gas; TG Trip Gas I 24 hr Recap: RIH and tag top of first cement plug at 7647'. Set second cement plug. POOH. Change rams. Test BOPs. M/U BHA. 1 �.' Sample Catchers : Nick Douk / Kevin Mullen Logging Engineer: Eugene Payne / Tom Mansfield * 10000 units = 100% Gas In Air , / / /i/ r /r, i i� / / /%/ /i % S� ' i i ' j/„ , . .. 1f(c�/ i „e ,i.. <,e://_ �.:. %/. i..,,,,: H,>* '�� � �� / / /:/ // /,....i „ii% , �j /� �/, �' F /,.,,,,. ,.,� �C�'i,� ,� /,F �� � i,�i, , .rte %//r8 vr/., _,,.1, /,,,� >...,; ,,, .,i..ai, j 1 1 Customer: Pioneer Natural Res. Report #: 34 Well: ODSN -40 Date: 06/10/2008 -5:00 xti Area: Oooguruk 05:00 Depth 5135 Location: North Slope Progress 24 hrs: 35 . Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK -AM- 0005710855 Report For: Jim /Herb D aily Charges $3,500.00 Total Charges $117,500.00 , 1 , .,,... 4 rr':� c ?.,,,,' /i„`t , .4,..':r,.:r .',,., ,F, .,r,.:,, �ti, „_...irc'„r/3„%i�A;ti' <. /'r^ "..M ,< . :, ROP &Gas: Current Avg 24 hr Max Max @ ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr 38.0 2.5 38.0 5135 Flow in • •m 553 SPP •si 1700 y� MEEMMIIII 7 7 38 5100 Fl 1 ow Rate s•m 155 Gallons /stroke 3.6 I " 1111,t _ � ::.. %r,` c� i %ajj � �, �.. , ,. E. i %'"`i /r., , , ✓,J �< . „rti Sri r f�� %' ,. : i... '. Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De•th in out sec /•t Ibs/100ft 2 cP Ib/100ft m• 1 m1/30 min % 5117 9.7 9.7 52 6/7/- 14 18 10.2 27K 7.10 4.8 I r � / % �y � v , � ,,,, y / /n/ ,�.,x,, .. �a,: .F „. ,. , ., , �i,y „<.c ',/9 , � � i/! ;; r �„ f " BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 600 FMF -2565z 8.75 0.648 13.7 5100 35 10 -Ma 59 1 s Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I current 100 4 t, ` � �i / � i / � /i� �,r ,�5,�, s�ri � %ir,.,F.._ <v /�,._,.__.:�,.,._' �_�;,6.< �� ��v� ���„� e;,s� , /i /r,,,/ �,. /,:,.,%c^x r_.,��//t;`... i / /,, Gas Breakdown Gas ( units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 5100 to 5135 16 7 1042 72 56 53 4 BG 1 to to to to 1 to t0 t0 t0 t0 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas r .. / , r/ ,, i � � F3 y u /'. F `. v r - y `�`�� l� l ! i r - /,” �,;::'�.sa . * . �� /�/rr, i,%i�� /r/i / / /.,,a�.:�.�.r�r,; .. ,, ✓ , k'�ll� ,'.� , ,,;,,. 0/7111511 , - .' . t ?' � . :; r ..x., .. !/ , u� . / ., / /�c/r/' y i % ... 24 hr Recap: M/U BHA and RIH to shoe. Shallow test MWD tools at shoe. RIH to 5100' and circ. B/U with 38 units trip gas. I ; Perform FIT to 13.2ppg EMW. Time drill to kick off. Sample Catchers : Nick Douk / Kevin Mullan I Logging Engineer: Eugene Payne / Tom Mansfield • 10000 units = 100% Gas In Air , i . . rc .. ! fir- " :AZ'S ` ` '. :e % %Li% h , 1 1 1 ill " k i ?.� ; i z�.. <., '' 4., .i N, " . %r / S Wit. " �.� ii; /, /„ :<,'i.�.Z�a / s.� s'�¢,a,,, ' 44‘ % ,44.t — „,,,, _ti,.r Customer: Pioneer Natural Res. Report #: 35 I i LI Well: ODSN -40 Date: 06/11/2008-5:00 ' Area: Oooguruk 05:00 Depth 5640 Location: North Slope Progress 24 hrs: 505 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling ' Job No.: AK -AM- 0005710855 Report For: Jim /Herb ii D Charges $3,500.00 Total Charges $121,000.00 I : .s, !... .C. � y44 's /,rte . 4;4; , �r ,ter. i;'r �. :Y.+X: Wu: #3,1v "ilk :4 , ROP &Gas: Current Avg 24 hr Max Max 0 ft Pum • & Flow Data: R = ROTATING ,y.. R .O.P. ft/hr 114.0 38.0 234.6 5434 Flow in • •m 548 SPP •si 1855 I w 11E77111111 _ 159 65 . 176 5580 Flow Rate s•m 154 Gallons/stroke 3 +: 6 ,4 Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De •th in out sec /•t Ibs /100ft 2 cP Ib/100ft m• I mV30 min To 5117 9.7 9.7 46 6/8/- 16 26 10.1 18K 5 80 5.8 y r a r s" y r rrr ?* //�i s r�" i 7 i . , "r � /v <�� r//�,,, „ i� /r /��i ✓i /�� ��/ �./ / „ ^� % �*� ,,,fir, r i/, �I,,,.k., �E , ��, � „� `,: 4 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 600 FMF -2565z 8.75 0.648 33.1 5100 540 10 -Ma 59 -- ' r Y Y,%'r ry / / Ji � :*+- /• ' ✓ mi l/ //' c , Y.,�,r • , .,,., ;.,,, ,, . .e, �� ^ r „ ...r ; , �:,�t�i „�„ ... /, ,,,�����. �rc _:� ,,.,., / // ,, .. „� ,� , ,, . " .:,! // ,�, „ ✓,r , �4„ / .vs„ , , Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvi Tuff ; current - -- 10 -- 80 - -- 10 - /” . �ak,,�r �;, ar,. � „y' ", %rc,�� r..� + 10,.. „, /r�'r- ,;.,., �( /zr� /�” �/`%� ? , .,w'� � . ✓.� I Gas Breakdown Gas (units) Chromatograph (ppm) Depth Max Average C1 C2 C3 C4 Tot C5 Tot Type 5600 to 5610 120 113 10156 722 436 235 39 BG 1 5575 to 5585 176 150 14810 1098 669 361 62 GP s to to to to to I to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I + ' BUG Bottoms Up Gas: POG pumps off gas TG Trip Gas . . f / ✓F. ; - �- ; ''r i . /,i� ,% ? ? /�Y/f /r r � / /�/ /% �” ; � �i r >; �/i,,. > ��r��� /�y.,�,>x, ��*a� �r , ������ ,�,,. ���/������, ���a�C � r/ �. �� �i/ /���, �,,,:, ���!, F 7 �,. ��E � ��/� / /l °, 24 hr Recap: Time drill while trenching low side to kick off old hole. Drilling ahead. l i Sample Catchers : Nick Douk / Kevin Mullen I • Logging Engineer: Eugene Payne / Tom Mansfield * 10000 units = 100% Gas In Air y r l� '�r , Y' // i ` �f/� r% %r ,, / ✓ /%` / �/' it %/ �i��x „�l/c� .z..��, Vii;. %a ��v.�r . �, � / /._: r � %i.,�,�h3��i .t�.f�.....� /y�,, ,., �', µ��//„/i� /� / � �% /r'r/ ir'y � <c.� -- M, `i''/r,�%o„'� /�i. �µ� /��!r.% Vi i,.:. �,:? /rs� 1 1 1 t i t 11" „o ,,, <i i ff:,,,,.%'.;.. !,,., 34 e,,�i ter, .. , ,; tau fir, . ,/ ?fin .44* *X* � ., "ItV . , ,,r* — ..i „ 4:.. , /�,,,. Customer: Pioneer Natural Res. Report #: 36 Well: ODSN -40 Date: 06/12/2008 -5:00 Area: Oooguruk 05:00 Depth 6523 Location: North Slope Progress 24 hrs: 883 4 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling s Job No.: AK -AM- 0005710855 Report For: Jim /Gus Daily Charges $3,500.00 Total Charges $124,500.00 f y , Y 'k , /� F, --' /. /"' ' i r q /,, r 0 . �/ i ce / s �'/ �; , - Y . � � %��� N ��//�'� . ._. . . �> rr, ,,. � �� �,� • i., , _ .21� ,. 'k?�� � ., � 3�� � ��'� // �i?/ r.. �� .. �� �t .���i. ,, l ✓.,. 3�� i ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr 61.0 80.0 167.0 6395 Flow in • •m 606 SPP •si 2475 50 97 238 6470 Flow Rate s • m 170 Gallons /stroke 3.6 I „ *" -s ! . /r ' ,, �'t , ;,,r ' %i �i, /r' r,' + . rf_r %� �z �%��yi�i�'�� '� Y',�� ,,�.. �Jr%� /.� ri", �,,,, �"/,. �� /s�s>, /,�'�/ /rj�'�s��/,'/ �''�.�, r, �;, � .i% F'H, �''�r.,�1:.,/„,,,, „�.., yid l �,x��i�!r,/,,rr���', k�C T, ,�,ritl sr;, Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids Death in out sec /at Ibs /100ft 2 cP Ib /100ft m• I mV30 min % 6470 9.7 9.7 49 7/8/- 20 21 10.1 19K 5.40 5.5 / - Illf / / ,/' .. : ,✓ /. / a Ar . //: - r_, ,. , r II': z* ri/ 1;' .'' ,.r,,,; BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 600 FMF -2565z 8.75 0.648 45.7 5100 1423 10 -Ma 59 • f „ .. .,.x 404 or./// Yr / . / / e,,',, , :s '�i�.r . r . . �.i y '; ' :' /.Y /rU '4 , / e . ;.., Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current - -- 10 -- 80 - -- 10 , ". . .1 IP ! ' - . »r, o „/✓,✓ 4.4 it %., ,., rc P m., ,w a , ' Gas Breakdown 1 '' Gas (units) Chromatograph (ppm) D epth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type '; 6400 to 6500 7662 418 251 177 3 9 BG I �� 5575 to 5585 176 150 24368 959 451 310 59 WTG to to to I to to to to to 1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas; TG - Trip Gas , 3.3 ,... / :; �r z„ /i F ri r /L „ / // . „ ' r . . ,.?Y�/ , . r ,. a? r rii �”' /3`' zw �/ ri„'� /�� /z ®�i / % /�X/� � 'i ;:, / / „� ,l % /?� r /,,,Fair /sl ; / w ' /i�/1�',,;, 24 hr Recap: Drill ahead to 6470'. Short trip 15 stnds to kick off point. Ream tight hole 6182'- 6235', 5992'- 5911', 5815'- 5866', I ' 5624'- 5684'. Circulate bottoms up with 192 units gas. RIH to 5128' and Pump up ACAL data. RIH to bottom. Tag bottom and resume drilling with 237 units of short trip gas. Drilling ahead at report time. I Sample Catchers : Nick Douk / Kevin Mullan Logging Engineer: Eugene Payne / Tom Mansfield * 10000 units = 100% Gas In Air 14 .rt: ///s, T /sip icsa� r. .t ',,, titit ir.. ' / /,,. ,. �. 1 1 I mo ' . 5 %�/rt" "e, .. ry x' ' yl / ° / s / ,} /.'.x 6 r �.�r s��. ' ,,rr ��. �r✓ /,�� ..' %.<v. � � �...��� ' ,i_,. � , '�' . ti . r >lr,.,,✓ e, ,, ii.: 1- :'. Customer: Pioneer Natural Res. Report #: 37 I . HALLIBURTON Well: ODSN -40 Date: 06/13/2008 -5:00 Area: Oooguruk 05:00 Depth 7525 Location: North Slope Progress 24 hrs: 1002 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling 1 Job No.: AK -AM- 0005710855 Report For: Jim /GUS D aily Charges $3,500.00 Total Charges $128,000.00 ,r /y x % ✓ ' :Fri lt, 4 .'. ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr 79.5 104.0 286.0 7043 Flow in • •m 603 SPP •si 2825 75 70 110 7403 Flow Rate s • m 170 Gallons /stroke 3.6 I � . '.s^ / ✓ / �; r i /�� � rr i � f '�5 ��s �.,'_ %/' € �;/ �/ / //. rvi'� � : ✓� /r�.;�Y r / a /i - 1/ _ / ° / � r ,� ,�° / :� Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De in out sec /•t Ibs/100ft 2 cP Ib/100ft m•/I m1/30 min To 7362 9.7 9.7 54 12/4/- 23 30 10 20k 5.20 6.4 > � ;x ,. r i,i% 2/- i %,,,, ;.ro: si/'. "::*1111 ..t r, > '�.,. > >c, „ >,t BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition • ' ; 600 FMF -2565z 8.75 0.648 59.1 5100 2425 15 148 r r , s r a �i ri r i r A.% r / �� sa " ri; - ✓ ,✓ €� �� %...). / r / y � '�� �. rry // r�� / / /,� ' �5� . �. >a��,?�S � L'ItholO /o ' � d Ss �� Silt Siltst . " ,,, Cl Sh Lst ° ` Coal � /� Lithology ( ). GvI Tuff I current - 10 -- 90 - - - -- r � x ari ' SR! ' f"'�rf' / r r ^ �, r F „ � r' , it , ,,; _ % �/ � �? ` *4. �< G/„�%6 %'.�, „ . ,, �;s����/: � /ia�` � .�,,,, �/,'� � ' b. F ��!��.r�r,<� _ U. ,,; �, , , . �' e ... ,.,, yi / -.. �f r ... , .,, :': Gas Breakdown I r Gas (units) Chromatograph (ppm) D epth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 6523 to 7520 110 70 10270 423 162 118 50 BG I ; to to to to II to to tc tc to t0 to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG Wiper Trip Gas; I rr % BUG Bottoms Up Gas: POG pumps off gas TG - Trip Gas ' i. r� /- /r"�xr. !r ✓�iG ; r, ' r r l / %�;' r/ �" ir r ' "! . � i � . r r ' %ri y .. . �1�':� *z y /... % „. i�L /i% ss; rim* r r, ..° r'���,x.` Sri, � ,r, ���� z .,//r/��� �% /mss. ;, a� r >.�r. „ , ,,,; x,.., ,. L , -. ,;:. ,,,r r �� � 24 hr Recap: Drill ahead to 7419'. Circulate 3 1/2 bottoms up to clean hole for short trip. Pull 5 stands. Began pulling tight. I ; Pull 5 stands and circulate hole clean. RIH and resume drilling. Short trip gas of 230 units. Drilling ahead at report time. IS 1. Sample Catchers : Nick Douk / Kevin Mullan 1 Logging Engineer: Eugene Payne / Tom Mansfield * 10000 units = 100% Gas In Air ��;�% � . r,...- F- ni,a, /i:a.:ckrMsr:- -' �✓�/i /i y::.,,: /, % / / /i /o� /i % //%ii... ,r,,,.2 •:. ...i: - `,���� /��:.. cr /i i�y ,.�%%yc.,o, - >�. 1 1 1 �� /f ,�,< ✓a.; ,o% ,�� ��:,/"'`,",��;;' %?. i,'� M '� �,ti.�r��. �� „�, s z�..r�:�Y��,. .�Y� Customer: Pioneer Natural s. Report #: 38 I HALLIBURTON Well: ODSN -40 Date: 06/14/2008 -5:00 Area: Oooguruk 05:00 Depth 8491 I . Location: North Slope Progress 24 hrs: 966 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling 1 Job No.: AK -AM- 0005710855 Report For: Jim /GUS ' Daily Charges $3,500.00 Total Charges $131,500.00 ll r'" r`✓! i0 Y”: �i , / r / c r,� S ;' // i f * .+.,rrt n/// , v rr , r � �,�� /r ���, - r� m � � �' ����f r /��', , ;, s��, � 1, % Vii/ 3 ' %ti ,/,h„isr ,.. �z „�r�'. . �r�' „ „ �"� � . . � �lo r� °%1� �i � ,,, ,.,,. >. ., �. �.�i /l y�%t1';,,, _ _ � S ,�s;. ' x carry.,.. ROP &Gas: Current Avg 24 hr Max Max 0 ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr 41.0 85.5 298.0 7932 Flow in • • m 603 SPP •si 2825 68 226 610 7812 Flow Rate s • m 170 Gallons /stroke 3.6 I „r te r s� // r/ %, %'.'..r'' o ';/ /x rye` y,«/s /,r/ ,` /� �"^ � SU l.. �r ��l���'// /i�% � � .miF/ /a��r „,5e�, �l� �,, /j %„ „y .�v.,, ,: u:;.i „< �. „r.;;c,% aE ,,.�G ,.,. x „��/f ,/%,�. �`'�.. ,, .,:�,�'�, ,, ,�,,, „S^c!` . ,,14. Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De•th in out sec /•t Ibs /100ft 2 cP Ib /100ft m. /I mV30 min % 8463 9.7 9.7 57 13/25/- 14 32 9.2 20k 4.30 6.4 y % r i rr/ ,r ,,. /F/ // ” ”. / /✓/ I . `; ' -: / St' BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 600 FMF-2565z 8.75 0.648 70.4 5100 3391 25 148 x � , ` / !!� r r.p l y/ , � �� N y lw'r .� s^i/FC . / . � ., �i x 5 5 � / / Y r � / {/ r - x3 � , �� 4 `3. . ,,�, r m, , ^ a� err rr 3 " � . ,' / �4;,..4' � f� , � =r , f �� w„ c: Lithology % : Sd Sst Silt Siltst Cht gy ( )• ht Clyst Sh Lst Coal Gvl Tuff I -� - - - -- current 10 20 70 :1 .,^• .., vrd. 1. t; ✓ ... �';': . . .., ra ., ' i. ���"' / 'r , r ` Gas Breakdown 1 4 Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type t ; 8400 to 8420 157 152 10090 761 512 381 240 BG I f 8463 to 8463 161 13432 738 401 296 144 STG 8465 to 8470 69 67 6190 439 295 257 136 BG to to 1 to to • to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas 'f ' //j , r/ .ar i s ;Vitt - .4f,: // - e :. ! , i I 24 hr Recap: Drilled to 8085'. Began losing 3 to 5 bbls /hr. Drilled to 8300'. Losses increased to 5 -10 bbls /hr. Drilled to � 8463'. Circulated X 3.5 bottoms up. Short tripped out to 6443' while working on pump 1. Repair pump 1 and RIH. Short '' trip went well. Drill ahead. Short trip gas of 161 units. I Sample Catchers : Nick Douk / Kevin Mullan I ' Logging Engineer: Eugene Payne / Tom Mansfield * 10000 units 100% Gas In Air ��r.:v..:„R T /i„iM . , F�,<�„ „. . /��4.rc. ur . . ,., f...,.. . � I 1 1 1 i ' T. "4' .''' .i4gt . — 0 : 1 M I F''' . ifil -i ' Ir l r6 7 it; ti44.: " * iiiii 1: . ..... * A. , . ...:. I 1,4 AZ Customer: Pioneer Natural Res. Report #: 39 • HALLIBURTON Well: ODSN -40 Date: 06/15/2008 -5:00 Area: Oooguruk 05:00 Depth 9316 Location: North Slope Progress 24 hrs: 825 p` Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling 1 rr Job No.: AK -AM- 0005710855 Report For: Jim /Gus t #' Daily Charges $3,500.00 Total Charges $135,000.00 Il i i z /rx i y / i /i 4 �/ z „.r �< � �'�% , , /.c , r,,,., � �1� �.?y< x"�� ..:: , / .5 �14.�,.��.x ` .`��' . , � r�� „ z* ` ,o„ �.� „” �! �� „a; >. .„ �. � ? ^': r 3�,�,../ ▪ ROP &Gas: Current Avg 24 hr Max Max @ ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr 93.0 79.0 239.0 8498 Flow in • •m 566 SPP •si 2590 il 580 223 6416 8590 Flow Rate s • m 159 Gallons /stroke 3.6 : ! ✓ / / r ; i . / � ; ` / % / ...c , /" % ; ; l $ � / r h i _ ' -- i , r . , 3 _ //r.�j/ � '�/.� / 'd // r L x/'rr'�s/�'6ir/ S ' ',,J w.. >�/nr'�r✓% r,.,,:ir� / �� i; li �.., r„ v,��. z���1/ -�3 /rJ'„ ,r;., /�",/�N,,,, >r, rr, , � 1,;;.,�r /, �Xr�1 /i, /.aY r ��.. � / ✓./r'v/��,rr , r /,.I �F�'� y. �/ � %� /F ii ,,,, ��u�xz :�.a Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids it De•th in out sec /•t Ibs/100ft 2 cP Ib/100ft ml/1 m1/30 min % 8463 9.7 9 7 55 10/17/- 15 28 9 3 20k 4 80 5.9 r . c ' / r f 3 /,% / /� /r'' c an r �i - �q' r /< . ' , @� , ��'% /, r„ (. ,6� ,:,. .. r, ��:',r ;,» �yF / /.. %..? -„ ;�� %,.. , ,. ��'�' ,. / %,. /r ,f , h, ., r �/,, .r /rrr, rr/rr .t / i. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 600 FMF-2565z 8.75 0.648 85.2 5100 4216 25 148 y / y /1'� / /� / , r / yii r/ / / � /l/r°,ri o,✓ e« y / v x Hr / /lam z ;i / / / //s j Lithology ( %): Sd Sst r Silt Siltst Cht Clyst Sh Lst _ Coal Gvl Tuff ill current 10 20 �� 70 i /� / / v x y .! r r� `/ r � -:fir r ' . / . /. r� //,� �. �� r r : i/// //// /' // r.; rr a "'r r ?���LxY / ///,.ra ,� .r'r'� / /�,r//rr /// iG ��F -,- ��e. �,.,�„ /' „t�..:. 7,rrrr,� t, /�� /�,slx%�„w :K.. ...., rrr. � f��.s� , / //� „/ ; �,l /! . �.. 9�X��i/ �% �, f /� /...- �.r,r. <,�,.:.:,�.t�., �� ., Gas Breakdown 1 Gas (units) Chromatograph (ppm) " Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 8491 to 8590 102 60 5372 359 225 193 126 BG 8590 to 8590 6416 peak 438842 35842 14875 6137 2381 GP 9221 to 9221 780 365 65348 2832 999 504 267 CG 9221 to 9316 587 450 58355 2727 1019 505 274 BG to to to to I to to ;,, Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; . BUG Bottoms Up Gas: POG - pumps off gas TG Trip Gas ,:? ,// & r , r' , ;�,%yis r't - /` r ,r / / i�'.": / r ;thy /� r / / /rr . /"/ /r /r ,ar H .� , fi r ...rx.sr / /r Y r HI r / / /r� r r , ,,.., =���j, ,r /. r „a J ,... . ' y /'. z . /� y j v ' ,r: %r r r✓/ > ri � r �,,, r.., ri. < <.- _.r,.zr � i�a, / /x!v ' / / //�i „r,,:.;,dG / «r.."' „r, o, / G.,, yu/� „ v, .�..� r�Gc.../�.,:�,.i'' /l r, ��� ,'r�.. r '. I 24 hr Recap: Drilled ahead to 8585' MD, 5494' TVD, lost all returns. Pumped 100 bbl LCM pill. Lost 560 bbls to hole. Regained returns with a max gas of 6416 units and MW gas cut from 9.6+ to 8.3 ppg. Continue drilling with approx 15 bph losses to 9316'. Circulate 3 1/2 bottoms up. Prepare for short trip. i i Sample Catchers : Nick Douk / Kevin Mulian I Logging Engineer: Tom Mansfield / Wayne Hermanson * 10000 units = 100% Gas In Air / , / ,. r r r, i x .! r i /. :x , / / /// / rr'w,� / � rS, / '� % r % , /ii / �,, r, /� � /// ���/ n //rte „ �, l / ... // � �i �. /. j y .. ,.. ��i „�. .Fi:1,��r. �.���i� „c,/ ���rcc 7 /��� /�d /,r �..r ice..,,,,, ,_�,ti,^ %ui 9"� /iii,/��rr..:r, ,,.. /,. ..%,.' ..r, /_., _ /'��O ;// -2 �,r �,., r � 1 1 1 I 7.1N''°���/ ji l i yr r i r z/� jy: "�.�?,n,•k '/' . : j * "V y lir ,'�, %. ����; �',a;,a����f�,` .>,.;��i,oy3,�:E i : :.,,. Zr���� -'� / / ✓ .� ,. �,'.?5�1� 1 Y �;�' .��41•14 �., f4��!c ,,,,�„�/, �.,� * ,SM �'„�, a , � ,. »,ti,,. Customer: Pioneer Natural Res. Report #: 40 HALLIBURTON Well: ODSN -40 Date: 06/16/2008 -5:00 Area: Oooguruk 05:00 Depth 9316 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping I ** Job No.: AK -AM- 0005710855 Report For: Jim /GUS Daily Charges $3,500.00 Total Charges $138,500.00 ; r''� / ; s r /r� „% r l„� / t n' /j/ 3 / /` . ✓ E; .� /,rr/'/ /' r /y! e /', 3 � /, fir: % ' . ` �!, ,�,,,r /',� � /, ,.;�::,..,,,,,,,,, /- ,,, S�S - ": . A�if,.�",' , ,,.-�fs�, xi F; r'/ , ✓irv ,: „"`il�� /�;' r. ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING '' R.O.P. ft/hr 79.0 239.0 8498 Flow in • .m - SPP •si ' 223 6416 8590 Flow Rate s•m Gallons/stroke 3.6 r/ rti , r % , . _ %.. r r r'r/�"' ' ? r � 5 s`<'/'�' '' / ' "`w vt Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De•th in out sec /•t Ibs/100ft 2 cP Ib/100ft m• 1 m1/30 min 8463 9.7 9.7 55 17/23/- 13 23 9 15K 6.40 6.8 r, S / i r // / ,' // ny%'r;^ ri / /,'' / y yam BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 600 FMF -2565z 8.75 0.648 85.2 5100 4216 25 148 x . £�v, w� ,,., ,, ',, ,., ,,, ✓�w', iki aij4,i .. ,,,se<3,X��W' ewn ,;, wS�Ji...,, ,,, ,,, ...' „r'„ ,,.a.,'. , >ttu Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current 10 20 -- 70 - - - -- K ^ 6r fir% r, r z 1 /U/' / / i. .. . ? . �� �,� a. .� //. ,l„ a„l; c�d,T , s a,,,, : , ,G?sz- ;.Liz,.F �+ w..f 1 ,z ��, yirr 1,.,,,.� ,,;� � �! /i.�'.,o ,.� h�, .�,� r/. Gas Breakdown I Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to I to to to to jv to to to I to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I . BUG Bottoms Up Gas: POG pumps off gas TG Trip Gas ji ff Witi if: : ; mss r r r 24 hr Recap: Pumped out of hole to 4960'. Circulate hole clean. Pumped out to shoe, slowly, circulating hole clean. 418 bbl I 24 hr mud loss to hole. Continue pulling out of hole. UD BHA and MWD. Sample Catchers : Nick Douk / Steve Mircovich 1 Logging Engineer: Tom Mansfield / Wayne Hermanson * 10000 units = 100% Gas In Air y % /r/ l x ice, y.i ", /'���� ,.i '% �. � /'i',,, y;' / . "q1...4: 3 , /;: ;i �. yy y.�/ / / „�5' r✓/'i/:'� /jG%fr.� s ��. ,�Gd/Y�r /i`' /� , ✓�% '. ,,>., .,;ra>' % . %',y'� h � '/' Z�i /rid y r ,, ,,,,,,G,,,..'.M ,,,,,, ����� / /, //. / /,G,!;%i// /i,% /i r�, �/i �,. . .,va, " //G.,. 1 1 1 III %o'N , r�`r%�a�e� �'�' s"��`���' %�l 'ry!�O�<`�� �, r!� � %� . � �� „ , �,�r "�I�*�r�ll/I� „��i��i��, 1���� "���C��������,�� �' �i,�; Customer: Pioneer Natural Res. Report #: 41 x. Customer: HAL.IURTON Well: ODSN -40 Date: 06/17/2008 -5:00 Area: Oooguruk 05:00 Depth 9316 Location: North Slope Progress 24 hrs: 0 • Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping Job No.: AK -AM- 0005710855 Report For: Jim /Gus ` Daily Charges $3,500.00 Total Charges $142,000.00 I ,. . A : ;, � , . -: . ��� .:, 'V , .,./ f'' � . = �i i�, .: , . �F /i., ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R ROTATING • R.O.P. ft/hr - - -- Flow in • •m - SPP •si 180 223 4144 TG Flow Rate s•m Gallons /stroke 3.6 .,' /,,< - ;.'G��, /'..'. '%//,,!',.,. ti3 s �.; -..r .� i ✓ r c „rs „ t,1 ''' ,?u' / '.. " .'. s.. ! iu ' w,r, , . �,.. , . �_ r ru f ;; rae.� , �'�Z: ,f/ , / /,�,✓ , , ;.s.'i....,. ;� ... z.,✓. ... r -- %/i i n.� , ,., Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids Death in out sec /•t Ibs/100ft 2 cP Ib /100ft m• 1 mI /30 min % 8463 9.7 9.7 63 18/25/- 16 23 11 20k 6.60 6.9 I • O P . .,,�� / r,,.,'��j' y „ �',....,..,,.a,`Z3,� �'..,,, ., ..'7 ..... .. i -f,; BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 700 . 9316 0 9316 4216 15 150 1 1 -ER A X I NO BHA - - - -� 600 FMF -2565z FMF -2565z 8 8 75 75 0 0.863 648 85 0 2 59101 , e G// i ” y r . .... / .� �v , : : , / ' / / ' a/” ,,;' N � / a/ �/�ir i h '' • '',. �!'� w..�. „r i✓'/,,�„% s / t ` /id �.,.a _...` F..., ... ..,...vi r'"' - "x % i, //,`"t. ✓,,� s .�i,... „,::!,, ,r � �,ka..3 Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff 1 current 10 20 �� 70 ,?'' % ,, ys T f /' % . /, /' /r • _:?v , �rjr'� , �:- ” 7 ,r?/y'�i r / ' yz% y ?';' f ;,�'.,ni %� t t: a '' ', r ,/ y :..�.'Dr;^' x. � u- z.�x.. �.M4a�'i,� , � � �i' .'w �.r//'i�a' /s %< y// �f` '..:,:: /.Sl %r'.:"��,:..� /'1/% ,! Gas Breakdown I Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to to to 1 to to I to to to .; to 1 to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; "" BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas ::"�� . a ar:' �/ f 7 �� , /,,, ,,,1 ry'� ' Z a / y / / y" /r.._.� �,,,,, / /,�. ,,,�„ta /. /,,,, /. / /i. . limey,,,, ,,:r:� .i i,.,,,, . ",//,:,.. 24 hr Recap: Complete POOH. Test BOPE. Cut and slip drill line. RIH to shoe. Circulate out. RIH to 8545'. Pump in hole. I Bottoms up gas of 4144 units. Continue pumping in hole with negligible to no mud losses to hole. Sample Catchers : Nick Douk / Steve Mircovich 1 Logging Engineer: Tom Mansfield / Wayne Hermanson * 10000 units = 100% Gas In Air �" ' f // '% // � / a /' / ,,,� .' % r ,. r/, y '.,, r /i � " � r Ff ii / � r / .,���^„��'J/�,�ua//.",/'i ...,, ,':u y, Cz.�s ✓ik �FCr,'Gd����r,;�;,' ��� ° .' j�.�w ,�a�y%� .�✓; ��.%/f '-� %r� � � r��� � .. ,,._ L'' rr' %��41 , ii /' �''rr,;;'',;...,., 1 1 1 tii, rs . .,fitii irakb. "�&�i ' z � 491, . ii*3 i as :. : 44 � 'li ?yi,.fti , . Pk Fi „ ", '. Customer: Pioneer Natural Res. Report #: 42 a HALL1BURTON Well: ODSN -40 Date: 06/18/2008 -5:00 f .4 Area: Oooguruk 05:00 Depth 9883 Location: North Slope Progress 24 hrs: 567 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circ for short trip 1 Job No.: AK -AM- 0005710855 Report For: Jim /Gus D aily Charges $3,500.00 Total Charges $142,000.00 7. ROP &Gas: Current Avg 24 hr Max Max 6 ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr 90.0 77.5 124.5 9729 Flow in • •m 555 SPP •si 2475 360 386 2253 9375 Flow Rate s • m 156 Gallons /stroke 3.6 < „ � , . Mfr �, %O f '' �' J6',,; f/ ,,''. zlif %'; ° 1 /', i /rte j?y /i' %;.. I Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids e De•th in out sec /•t Ibs /100ft 2 cP Ib /100ft m•/I m1/30 min % 8463 11.0 11.0 49 9/11/- 22 27 9.1 19K 6.20 11.6 / Vii._/ ' " r / r% .4' :/ / 4147!” rr% - . ; ; %i/ 's' s ".i / /; ' j ,' .. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 700 FMF -2565z 8.75 0.863 7.31 9316 567 Irt -- 600 FMF-2565z 8.75 0 648 85.2 5100 9316 4216 15 35 150 1 1 ER A X 1 NO BHA / %� lk 'i" /I �'6 ,✓ �q /i� r te'- //��S �V y - . * s- �/ r %r� � / r// %" %'' r.� , %` r sr � S ��" � ����x.�3 �'� -�� �r� c,����`���� �' , ,; ..¢�'�; ...':>, ", /r.. <.,. ...�J��r� /r �.��, y ;,r. ��f, ,,,, r5�.. �'�e,„r; ,i�� , /v. � .Y - : Lithology (h.): Sd Sst _ Silt Siltst Cht Clyst ° Sh Lst Coal Gvl Tuff j current - -- 20 -- 80 - - - -- II ..1 .Se` %�'�:��2,, �'r' . v ,,:f �.�.v� :;. � , � ""'.'. :z'� ,. * ..,..,., ,.;%9vAlf e 0 ,., . i /. 2 .4... y�. Gas Breakdown I i' Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 9316 to 9400 2253 550 213454 8604 2654 879 261 GP I 9400 to 9800 1018 386 36663 1688 698 342 138 BG � to to . to I to to to to to 1 i f to I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas ilf r/ C �%/ ,5 � ,..,S;;* ii / / /fir , rj /, // y s /d ' R y�� /i / /.,� Vii/ / /; „ r %r, ,<! . ,�, � ✓sr�fiti „ a,r�� /2, l��i„ n, /r ./X t / „r, ; .. ...,.... ,,, ,./ %�:r „�,✓ , it / /��. � .,<n,� /����„ r� :.;, r,;-; /,�?,,,,,,xo riT,l i" j 24 hr Recap: Displaced 9.6 ppg mud w/ 10.0 ppg mud from RSC. Weight up mud to 11.0 ppg. Drill ahead. 1 I Sample Catchers : Nick Douk / Steve Mircovich Logging Engineer: Tom Mansfield / Wayne Hermanson * 10000 units = 100% Gas In Air :.. /ri %// //i 'r r /� %,/'. ,,!fi, % �/i iJ %/ ,E -f z: g 's . y , /£- / /// %.: Uc.,.; 4 '.,, r."y /x-Oi ..,.,,,.,,. x.r. °ic,.,,,,; % /r," r/� /iy.. i�ii�/ ,,, r.,./ - ,;v:afAl✓/ //i�`✓r,.- y i„ a,,,l .,�s,�./.. ��*2 1 1 1 1 u * .. �' - .. r u r / i ' / r'rrp / i ;�i r •'„ " - % / r"4 '?�/ r�'i s". r5 �* :� + , � -w J ✓ r � -' ,y r 3 � / yr ," t / 11 %4: �; „./ % s„ , <a r /� r , �% c �i rr . f . ��� a�'/ ///''� �� z � , L . Customer: Pioneer Natural Res. Report #: 43 N Well: ODSN -40 Date: 06/19/2008 -5:00 Area: Oooguruk 05:00 Depth 10453 . Location: North Slope Progress 24 hrs: 570 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Circ for short trip 1 . v Job No.: AK -AM- 0005710855 Report For: Jim /Gus D aily Charges $3,500.00 Total Charges $142,000.00 / , r r✓ , � r /r r, rr r,Arc:, rr ui r/ /` % / r ��� �/ ��i�(E� 'r � �� � / fi / /ir7�i r % �% ��.,;.� ��°rl �//i : f �s ��� / // /� s?`� ,✓ _ r % /. a ��,>/' ,r. , ,zap . z . .., , , .. , �i„�,��„�,r /'�L,.� ' , „� . f,. „ r�� • /,. /„ �i /: /% a Ill ROP &Gas: Current Avg 24 hr Max Max @ ft Pum • & Flow Data: R = ROTATING F R.O.P. ft/hr 79.5 74.0 143.0 10361 Flow in • •m 555 SPP •si 2475 185 295 1715 9984 Flow Rate s•m 156 Gallons/stroke 3.6 %J ✓ : ✓ / %! ,i , z sr ,G bid/ "",,guy'✓ . �� / � r '�%%� /r/ ,: " / /�,;; /,, 7 r5 �rs« : ,�,./r/, %r�'%r� /f ,, 4��' .. ..,rrmFn ,r �. -,a.�. s;: �,, ,, .. _� rr,,,,;.::w � �r /l`%,;,,,'���. .,.u...,, r....rci / ,i rac „,.,,✓ti Lr ��' I ii 5r Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De•th in out sec /•t Ibs/100ft 2 cP Ib /100ft m• 1 m1/30 min % 8463 11.1 11.1 50 12/16/- 28 30 9 20K 5.20 13.1 S . ✓ �. - �j / u c i/�i„ . � s` , ✓ ✓ it fir/ / �” l'... P 'j % x '� "/ f'. s .< '// r .� �...,.:w,,,. a;�/,� � # � „ 3'k r. a r” / � r� .. � rs ��� ��' r �� � i„r.<. . ,,,, rr / L � _5:. . . � � „r��k �� /,. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 700 FMF-2565z 8.75 0.863 15.36 9316 1137 �' 600 FMF-2565z 8.75 0.648 85.2 5100 9316 4216 15-35 150 1 1 ER A X I NO BHA ,� . ✓ ' , � /� / r ' .. ' 4 r; / � / % r� ; �y ` ,� r % �` n � / / � r rte �� � „� :!.! '�/ir/y.i: �� /i %� �,� % ;`x ,,.�L ,,,�„ ,r.'� �i.'":.�'�:;,,,� . .� � „s� € ` ,.. ,�,� , r, x �i % / �. %! ,. , .,. jiri /” „ra ,.r £� /�i:,rr. r.�. ,.... �.� Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current 5 10 -- 85 - - - -- � r ���, � , �,m,.:- ' ab . i A� �r���"si/`/..a , ;.� : :- ..'.`:ti. /.%?;;��11 .s. u „u „ � . �,;1/;” /S. . :,;.X .,,,. Gas Breakdown I Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 9900 to 9975 284 266 29843 1606 785 371 144 BG 9975 to 10000 1691 975 167271 6663 2178 827 306 GP 10000 to 10197 325 250 26245 1512 681 357 150 BG 10197 to 10230 1041 900 96553 5583 2304 1044 400 GP 10230 to 10453 266 225 23483 1322 678 396 187 BG to to to I to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas �,,..�f%✓ /' „ -r ,r , /l / ✓ r rli /� / ✓i !'r i /% !j yf i�; £ �� // .. „ r� % // s : r „ ?s.. ; Mi. �.<.r„ ��, !. ., //, P, ; :, ,,, „ ,. ;,,,✓ ..�f %a, r ;,,,/�tesl, . -. , ,, c / „,�,i /L /o ,,,,,,�. /i.,;,` ,, / ✓�ii„ „, .�7/rr/ _. ,,.urn ,iii,. I 24 hr Recap: Drill to 9883' MD , 5893' TVD and CBU 3.5 times. Make 7 stnd short trip. Trip went well. 450 units trip gas. Drill ahead to 10453' MD, 6062' TVD. CBU 3.5 times for short trip. Pump out to 10100'. Packed off. Lost rotation and 150 bbls mud. Pumped Lube pill. Regained circulation and rotation. Continue pumping out of hole w/ out mud losses. iI Sample Catchers : Nick Douk / Steve Mircovich 1 Logging Engineer: Tom Mansfield / Wayne Hermanson * 10000 units = 100% Gas In Air ��� <.. ,i:': �j�v' r✓ ✓ u err % / / ✓ / / / /,'.:. j 3 �,e% ,�e: /� / /���.sc, / /,� „�,;��� / /i.,,,,� : /���� �:�� %,+:; .f�,'��r. � G:. � %'//i„ di,.r ,. 3..� -. „ ���.e, or.� „���.��j��,,, ii .. , ,/ llt.Y 1 1 1 M1...«/'z ,���/�,, ', .r . :x��" . �� E_ ,,,���'.::�. ,,1 � ,`,. w` :. ✓ .40: . ii, / - �/ ,'�'' j. 4 ,,..,d:,< ..f i4. ., <. Customer: Pioneer Natural Res. Report #: 44 LLI Well: ODSN -40 Date: 06/20/2008 -5:00 Area: Oooguruk 05:00 Depth 10880 Location: North Slope Progress 24 hrs: 427 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling / Pump pill 1 Job No.: AK -AM- 0005710855 Report For: Jim /Gus 1 Daily Charges $3,500.00 Total Charges $145,500.00 III / , v. . ,7,' ,r - os.a.� I , .. %✓�„^,� � 7 /,"' ' - 'AN ' "'! .:, *. ROP &Gas: Current Avg 24 hr Max Max 0 ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr 83.5 69.5 116.0 10614 Flow in • • m 555 SPP •si 2475 1 NEMOMMIll 273 128 273 10832 Flow Rate s • m 156 Gallons /stroke 3.6 -a.:. / -�': 1 yvl;,'. r,' „� % / r .. ; ti ' .`�' ,.; ' %' "" s i� / ' 'iii . . ”. , J '�jr's.� ri�. �,r" ��'..:...e. . lj��.F ! ,.,. ,... , ,.,�' �.�,�y,�r� „.,r, %�����. ✓.;. /;� / / „yiN.u� . Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De•th in out sec /•t Ibs/100ft 2 cP Ib /100ft m• /I m1/30 min % 8463 11.5 11.5 60 13/17/- 38 31 9.9 19k 4.60 15.7 �,✓!j�/r / / /// r�, /, / i �Zi�,,';""i% �,,� y / 1 ' /J' .. �� „ "r/9 /'' '''' i” r i �. .c„ .,:. /Lra / ya� .,,�y�n � /,.. /,!,v �/' �� , , � / %, f ' ,, . ' /�� Q /,,.i...,, ... o / / /� „���' r, r ri. ✓.; � .:: r BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition ;, 700 FMF -2565z 8.75 0.863 22.5 9316 1564 - -_- 600 FMF 2565z 8.75 0.648 85.2 5100 9316 4216 15-35 150 1 t ER A X I -NO BHA r L /�i / j 3 , �l ' y� /y�i 44...,....4- F, /. /!Cfj � ' / / `.. �� � ' /H / � i � xFxC �X. ,' , .6 ., ; .i /% /%✓o � ` ;, Fw '`''1,.�, ''`. „ - - ;�7`, '. ?�, : ;% .i� „ s:<,.,.;?;,' ','"',.. ` %rri., :,.,.` ,; r„`„a ithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current 10 10 -- 80 - - - -- I Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 10453 to 10700 202 150 10078 530 284 232 163 BG 10700 to 10740 136 131 10784 474 247 207 129 BG 10740 to 10755 228 215 21557 888 360 231 120 GP "x 10755 to 10825 148 132 12804 539 267 208 137 BG 10825 to 10832 268 220 24752 1013 457 308 182 GP I to to to to I to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I BUG Bottoms Up Gas: POG pumps off gas TG Trip Gas r, r. r ;IS' i �� „',1�,,,,,�/r�x 7 ,�,?�r /m1,r „,,,� /�.....� hc F,. // 1. r��r ..�t� x r,..:j�,�� /�,i.,,.�,._. 24 hr Recap: RIH to 10230 while losing 90 bbls /hr. Pump 60 bbl LCM pill. Spot and soak 30 minutes across zone. Wash and ream while losing 60 bbls /hr. Drill ahead losing 60 bbls /hr. to 10829' MD. Began losing 150 bbls/hr. Spot LCM pill and let soak 30 min at report time. III Sample Catchers : Nick Douk / Steve Mircovich I Logging Engineer: Tom Mansfield / Wayne Hermanson * 10000 units = 100% Gas In Air _ .. � /,'/ ,�f'/ ' • :.; �/ a .✓ ri�ir�” i, � //'/'i 'i, % / / / / /,Li/', ,: � �i�u e r , �//,,.�z�r c/'6�f.� ��C',v,. ���� v Y�% �_ „!�� /,. .r.�- :,.�,rr _. -: ;% „z'k� / „���/ � M. %:''rte /,i G/i,� % ,.: ,c 1 1 Customer: Pioneer Natural Res. Report #: 45 HALLI URT N Well: ODSN -40 Date: 06/21/2008 -5:00 Area: Oooguruk 05:00 Depth 11100 Location: North Slope Progress 24 hrs: 220 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping 1 Job No.: AK -AM- 0005710855 Report For: Rod/GUS Tot D aily Charges $3,500.00 Total Charges $156,000.00 p ' r %/�i``✓��' ,, �% te ; f ir s / r r i% r 4 fi t' Z / / /�% !, at.��?��/ i row!'; %�r,'/�F ,, >,, / ,f/ /rl����� /� c , .0 ter. . . :.,. ,.. /,,, . m, 3�6'.���i'„ .,s,,,,,�iF,�„ �, r ROP &Gas: Current Avg 24 hr Max Max @ ft Punt • & Flow Data: R = ROTATING R.O.P. ft/hr 0.0 45.9 275.6 11023 in • •m - SPP •si 0 107 1432 10832 Fl Flow ow Rate s • m Gallons /stroke 3.6 f � r f / r r : / r / �f ; 7',:. *JIM i r � - s „ ✓ji Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids " De•th ft in out sec /•t Ibs /100ft 2 cP Ib/100ft m• I mV30 min % 11100 11 5 11.5 51 8/14/- 35 30 9.2 21k 5.80 14.8 om . i , ., / ., . / ,`' ras" /' ,' ' r , .`M': BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 700 FMF -2565z 8.75 0.863 22.5 9316 11100 1784 I 600 FMF-2565z 8.75 0.648 85.2 5100 9316 4216 15-35 150 1 1 -ER A X -I -NO BHA rp €l / . i 4 9rr ,. , . d . � / i ,. � -✓ / %, ,. ' s /7 % ,✓!. /`y /,,, %:. ' �� f j � r J %Jr /� 44"., /�;, r r/ � //� / �� %i ..a,. �. „> � �: �� ,, ."�.. ,,.r.i.��''7��,',�� �� � �Y�,,. � � Lithology C%): sd .,,, ,�� �_ ,. „�; , .,, ;� , , r ..�� � a ,,,� Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I current t 30 50 � � 20 � �� la w e a y" ✓ r ;n risrj r/ /: r , ,' f. / s 6 -e �,���� > ' r :�� . ,�,. � ;� ,Y. its � � €r , 1 a . � � Gas Breakdown I Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type " 10880 to 10927 187 140 12620 595 306 212 125 BG I 109271 11021 to to 11100 305 177 16291 686 335 219 100 BG 391 24209 1115 507 312 150 GP 11100 to 1432 72552 3717 1775 924 410 BUG 10654 to 10539 1210 292 27413 1236 568 337 164 TG I 10170 to 242 17502 852 415 267 138 TG to - to I to to �. Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I BUG Bottoms Up Gas: POG pumps off gas; TG - Trip Gas 3J, r%i �5 . . . ,;.. rl er ' - /ri r / / /,€r;r,r ., , „_ �i �r ,' r �.ur ,:. %._ y � ,,. i✓ ti/ r "y ��' / rte � l, '- �// P % � //< Jr. fj� / / . �; �/ / /, / / /,ir.;” .;� ��w,., �s��r,�;?�/ ��9,� r /i,.', �zx � ,�','.,! ., ✓i,,.. �s rt �r/ /,. !/ ,.. , ,,: �: . �a�„r . F��,r „'.., �ii 24 hr Recap: Drilled to 11100' with continued losses of 100 to 200 bbls/hr. Pumped 100 bbl pill which was squeezed in. I Short trip to shoe encountering tight spots from 10865'. Well continuing to breathe. j II 1 Logging Engineer: Boyd Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air ✓ � O /y/�, ,a x -,li ga r " / ' ;a ` , r % % %%/ i, ..�, ii "'��% ri„ i � /// r % r � / s / sr � �, „u:,l�:vv /, r '. ��!,. �i`./r % ��� /� ,�� / /do 'ACV; ;i,%/H;:✓ i �/ �.. z ��;/ �,�e«�,�,�.:rtii,.�i „z�� / / „�.$�, ,1 /i.,.a is / 1 1 1 Ulmij a F ! �i /� p 9i�i! / Customer: Pioneer Natural Res. Report #: I HA UBURTDN Well: ODSN -40 Date: 06/22/2008 -5:00 Area: Oooguruk 05:00 Depth 11103 Location: North Slope Progress 24 hrs: 3 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping Job No.: AK -AM- 0005710855 Report For Rofi/Gus ' Daily Charges $3,500.00 Total Charges $159,500.00 ROP &Gas Current Avg 24 hr Max Max @ ft Pum • & Flow Data R ROTATING ;; R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • •m - SPP •si - 0 103 1091 10135 Flow Rate s • m Gallons/stroke 3 6 //�!' /'%/ r '�/ `� ! / / "iii' //� a F/ v '�'//'// ,'/t",ix ✓/ ,,,,,: > �. !%, r r .:. , .�.��a. �!�i.aw.,.- r ��M.>?, , . _ ,>�, /„ , , , „!� � , zSsx ..�fl //i �z ,�' %r, ii. �j�a,✓ i. !. >, ....,,r,:, ., . , F. / / /ii ., ,. i... �''�` >: »s <; , <. Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De•th ft in out sec /•t Ibs/100ft 2 cP Ib /100ft m• /I m130 min % 11103 11 � 5 11 5 55 8/11 / 21 26 8.5 15k 3 20 16 9 ' %�'"`n -.. ,;�,,,,.✓ i v ��'� r � .�i ,'�� !G/i^.r,,, ,.:..�i7,,,,,,%; � /„��,.;�,� -y� r / „/, � ,o� /. .:../�>,,:�'".,./, /,,. ...,1: -'. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 700 FMF 2565z 8 75 0 863 22.5 9316 11103 1787 15 35 150 600 FMF 2565z 8 75 0 648 85.2 5100 9316 4216 15 35 150 1 1 ER A X I -NO BHA I r' ; /o/ „'"'"! ± /� � '/ '"^` �i �`.: � 1.4 -% /' y z*y.;'.. ''yfr'.i'/ r /xi,'��!p, t •. uSl% /i ... /! c ,:;;�''� % �� � za;,fr ,�!�'��:.�.- r,�,,;�, ,� � �, , � °! , ;;, �,,,">,��,y % "�: '- �.".z� "Hi„ ,,,,,.>,'a�ii,.,9,,, ,.i< �-� . �3��z��� /.", �! i�,� „c,ksz�i Ltthology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff - �� ����- current 30 50 20 �! "ti; /,/ ,„rH , r °,z k .,..- % ' r' // ' �w"h '! .: 7r �€n. v/. y .2 ,�>� s ei� /%i rca r o ,.._� ,,.,a��E�.;- .,.�.. .._ �� „�!a ,., /, .� >_,,,,.. ✓, i s,_ .>;. i„ cam,:: "', Gas Breakdown 1 Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 10092 to 10095 684 175 17108 810 353 201 96 POG I 10134 to 10236 1038 365 369226 1693 657 340 154 POG 10718 to 11071 1091 490 49271 2130 819 415 188 POG 10042 to 10061 548 220 21677 990 414 228 98 POG to '' to to to to Gas Type abreviations: BG - Background Gas GP Gas Peak CG Connection Gas, WTG Wiper Trip Gas, BUG Bottoms Up Gas POG pumps off gas, TG Trip Gas "� ,`�,�,z � %�i - '3�' - ,,,. //, %�Y, „ %�� � � i'/ ti�s, , ,�f��� G''/�e���'/', h�� ,� f�'%.�! '. /��./., �„ %.�1, z. . f i „ -,- /�ir., s. ���,,,, .�J'.', , ,.:T'�, i” I ' 24 hr Recap: Tripped out of hole encountering tight sections, tripped back in and drilled extra 3 ft as per casing program 1 ; tripped out of hole to 10055' prepared mud volume to pump 2 bottoms up, encountered losses up to 348 bbls per hour, cut rate down to 200gpm losses decreased to 15 to 20 bbls per hour. Pumped 55 bbl LCM pill and began squeezing same Continue pulling out of hole encountering tight sections at approximately 10081', continue to pull out to 8777' 1' I ` Logging Engineer: Boyd Piercey / Wayne Hermanson * 10000 units 100% Gas In Air d��j ' %i� %s���� ,,.:��r��.,zas..�� /,w, �,�:�y ✓z,.r; ��i!��� ��f �1 ,..:k,%;,�u�5���.�� ".�✓�L / 3, ,�� „ /��,::.,,,,:�3,"s. %>�:. Ll,....y,,,.,,,,, ',�,� /,i6iu �',.w�, ... 1 1 Customer: Pioneer Natural Res. Report #: 47 Well: ODSN -40 Date: 06/23/2008 -5:00 Area: Oooguruk 05:00 Depth 11103 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping I Job No.: AK -AM- 0005710855 Report For: ROCl/Gus Total Daily Charges $3,500.00 Charges $163,000.00 r: x . f r/ ` 4F '� Sc F #�! , v i a :. ,�. r 5 , %` ' , ,� C`�/' ! r .,.. 2 �z`, a�; � C� ��� ;,s�rG /�� / /� /> „��� ����s., 1 ��'. ' /�, .., „,s�/'.�. : . xa�� , �1 l �/ � ., a� / /i .. /�a'sy �� '✓ r , �� n i . . ROP&Gas: Current Avg 24 hr Max Max © ft Pump & Flow Data: R = ROTATING ' R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • .m - SPP •si 0 69 1416 8761 Flow Rate se Gallons/stroke 3.6 I ; / zy ,;%✓', �� /i/ / .�N y ?*Y „, s , : f.N / "A ; g ' ,/ Mud Data: 4 ��� Density (ppg) // o si� � n � Gels �� a �/ � PV ���� K PH Chlor API � � Cor Sol ds De•th ft in out sec /•t Ibs/100ft 2 cP Ib /100ft m• 1 m1/30 min % 11103 11.5 11.5 50 6/14/- 16 23 8 16 5.80 14.8 ff. ss /r /r i✓/ r a - • ' . .r'a:J _ /'�yr�i' / i /j`rr0�' ” , ... r , / ✓ /.: 'Ji `Y £�k� �s"9r/si r ' r',. :,� � ..F.,� %� >„ �/ y , , s � .a Y � , %rii ,r,;., ✓ir ;.. < r . . � t. . / i, � nc „ � BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 700 FMF -2565z 8.75 0.863 22.5 9316 11103 1787 15 -35 150 600 FMF-2565z 8.75 0.648 85.2 5100 9316 4216 15-35 150 1 1 ER A X I NO BHA / , z, "r ysu„ ry a ; .,; /_� rte„ , . ..: � -.. , - , Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff -- current 30 50 20 - -- � ' - . % �% � a'�,. .` /.3�, ,. , �;:�i, �,/i'rr�..,'F.. - �,/C �.....� .. ;N.M..;:�<,"%x,;» � %u.��r�... ,Il' � � ; ,��� /F.,� ��� i''. r Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 8795 to 8785 1416 223 20896 1073 492 293 135 POG 8670 to 8459 302 78 6788 430 225 138 49 POG I 7313 to 6900 816 103 10411 464 180 94 41 POG ' 4930 to 3330 698 56 5014 288 148 84 22 POG to I to to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas ✓ /f,9 �/ ;/ /' �„ ,% ,!, o �. ; .. /i!„ ;i �% . '�',:. . � ✓, ;,. ✓ r �, 'D. �/ r i , Sri„ 2 . P. , h Recap: / Tri pped out of hole encountering tight sections throughout. Tripp out ,, . . ,, Tripped out of hole to the shoe and started to I / pump 2 bottoms up. H2S values observed were seen to be minimal with numbers of 5.5 ppm observed in the pits. Trip back in hole to perform clean out run. 1 Logging Engineer: Boyd Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air 'fli w` %%%su /c %�.„`'' , 'F /,�. /M�,.;%'.;�i2. � ' � . 2��� /�,�: �. . ..;*i..1...: l.c. t 1 1 1 I ry ar /i g . " � i�� �����- ��r �„ ,rF�,,,;��� /Iir..,,��;.,,z, &� /Cc'. %s ✓ � /,,, ,,. „�"u.�l .-. �` �% r' � i � ' , � �� a .� /: ,y��/ /ir / .a ,,,, ;`.IL %r „,. Customer: Pioneer Natural Res. Report #: 48 1 „ HALLIBURTON Well: ODSN -40 Date: 06/24/2008 -5:00 Area: Oooguruk 05:00 Depth 11103 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping Job No.: AK -AM- 0005710855 Report For: Rod/Gus D aily Charges $3,500.00 Total Charges $166,500.00 1. I z .,. ;02.,,,,i•iP., !/ ,. / / % <.�. 410 . . , . li. ,. <,,,..,.., . ���� s,. .. ,. c //!.r i.:ie ��:: F, ., , fti „5, x+A.�./, /..r.r,,,.,, .. Wt. r r „ ROP &Gas: Current Avg 24 hr Max Max © ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • .m SPP •si 0 37 740 5137 Flow Rate s m � Gallons/stroke 36 s. , r / //r ti!r r�i % ;�rr rr.%',% /�', ! / / rx,,;, ., Srr3� „-. Fa r r / O F ..., „ z.z1/ /��/'.�1� ., / %L.,.. ; „ra -. / ,,. !/!,v�'�,® %� s , ,,. uu i , , , ✓,?iz,, v , r/ .... ',.r, Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De.th ft in out sec /•t Ibs/100ft 2 cP Ib /100ft ms/1 mL30 min % 11103 11.5 11.5 51 6/22/- 17 18 8.6 16 5.20 14.8 lir rsrr fir/ ,r / rr -' .. ' n .F, „ � ;; s .' //% i ' �/ f/� �/ �, r ./ ,:.. , , rl !. �ti� „a S�.1/ , .,,��3� //, , sir r„ �r . -�._, iiida ii ,,,:,err. , �� _.. � iG� , �_ r�, � /, �� °. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 700 FMF -2565z 8.75 0.863 22.5 9316 11103 1787 15 -35 150 -� G 600 FMF-2565z 8.75 0.648 85.2 5100 9316 4216 15-35 150 1 1 ER A X I NO BHA I s 'i. /r /, r �:s ' c try %/ y r/� r” 7” / ,,.,�:_ / / /r c ;lsl r // r y �ir'... °^� '/ �� �l:l,ri .. fi'�i; .��1 %% /,'� /, a, � ..�� / /, / Y ,, ,'1 , ,i /I'n`o�.., _ .,,f"�F„ 'SCf ,., /,,,:;rA�i� Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I current 30 50 20 / // // a z r 'i r C ^' 4 �.��, ��`��1,���1� ' � %r /��z., �” , � ! l .�����'. ,a ��� �'i�� a „�i ��✓�, ,s...��,r. '� .._ ,t � �?.�R�r,r ,� �� i �✓s si�a ., ,,,;„s ,,,, i !. ... ).. Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 5164 to 5232 740 80 6968 398 239 135 38 POG U S to to to to t to r to to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; 1 r BUG Bottoms Up Gas: POG pumps off gas TG - Trip Gas . /�, h, ; / zf� % , „ r'J . 44' . !r�� .;e s r / $ 'r err . * ,' ,%�,. rL. a�'' /:. ,;” /s�r,!:;: /,. �, ;;:,,�.1f�% � / �.�lG .,.;. «�, �., /,,, r,f /�,,,, +9 /;r //. %i ✓„ ' �/ 'la'i i..,,, /i`'... 24 hr Recap: Pulled out of hole to shoe. Sensors indicated H2S in mud to surface from 3802', Tess than 6ppm over shakers. I Pumped 50 bbl sweep at shoe. TIH from 3402' to KOP, went into old hole, POOH 4 stands, TIH to 10358', mad pass from 10230' to 10275'. Trip in hole to TD and circulate bottoms up staging 50 gpm every 10 min, losses increased with gpm incre lowered gpm to 300 losses up to 250bb1 /hr slowed to 190 bbl /hr 1 1 Logging Engineer: Boyd Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air r z /rr , : : ; % / : 2 , „ � , . � � ! / . j � , l l ' i ‘ ° � x � ' ' 3 � 1 e � , S 3 � d . r.��,�i,. zw - /;' /''„/'i . �� , e,: ✓. 1 1 1 x / O 6" 5 ""/ ' 4 / f N P / , % : " ✓G YOz/r",",'' .'''11‘ i , " °l- ; � f „ilk �rrr/” a. „�i� %/r" /%% ° , . , ^ , ' � ", /�i� ff � ����%/�s�ro.�� -ry ..�, iR��� , � ,. ,., ,:`�'Y'' , ., „,. . , , r, " , F„ .__ x , Wiz„ ��v Customer: Pioneer Natural Res. Report #: 49 HALUBURTDN Well: ODSN -40 Date: 06/25/2008 -5:00 3 Area: Oooguruk 05:00 Depth 11103 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping 1 Job No.: AK -AM- 0005710855 Report For: Rod/Gus Daily Charges $3,500.00 Total Charges $170,000.00 • ,;. k r E.M: I ✓�rh .1 i ,. II ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in ..m SPP .si 0 63 1485 8710 Flow Rate s• m Gallons /stroke 3.6 ' r ' �/ "; ✓ _ , /ifi ,r // / x yrp.. ,..; : r / � %/; j 1 'i r l A e9 4. . ps '' . / %� /�lr„ ii, L,.< ,....i .; 3"'z: ,.;..., s ,.z �,, 4� / /,,:,,.,:ai /, %,r ! ,.,,.,.. I/ % s, `�i 'r,y y,ar;•.,.y � r ` , , f i,'. Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De.th ft in out sec /.t Ibs/100ft 2 cP Ib /100ft m•/I mV30 min % 11103 11.5 11.5 52 7/25/- 18 19 9.2 19 5.10 14.7 / . ii% *: o' % « �"' r r' " r r yi /y✓/ l r / � �r // . r a ,�.� �"<�.:,� i,% /z� �.r�,Gi�"% .. , > „�: F2�i,��;�,�!� %r' �///,":<:i, r -: / „r „ > „ / /fL ...., ��i/ /i��,z,i.: ,'/i .�. ,, -.Y , , <r.... /�� , ... �,.. , may,,. ,. /r „ „ BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 700 FMF -2565z 8.75 0.863 22.5 9316 11103 1787 15 -35 150 I 600 FMF-2565z 8.75 0.648 85.2 5100 9316 4216 15-35 150 1 1 ER A X I - NO BHA sr= �� , r *' '..I .; ,e /.;`' 1' / _z 5 /�/r%yyi`. �r /i�/`✓/? /' ,xr'r- /y.' '� x �% �i95r 4 ...���r;. ���,f „ .. +,.. �",�^�'��'.G�. �:�:�"aE „,.,;� ' AWE' �, , s . r,.� r ..�.r"Cf, ��� -. 5,'z�„ sy Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current 30 50 -- 20 - - - -- , ✓a: , ✓ h, I /j /,r / .,; / /G' ,' ,. r> / t.' '''' ";z'"`z� .4.41 /r F"wi %i y" Gas Breakdown r' Gas (units) Chromatograph (ppm) 4=' Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 11055 to 11062 863 106 9556 530 259 158 69 TG I 9721 to 9768 323 199 18954 1026 478 258 107 POG 8739 to 8649 1485 416 40731 1870 791 392 147 POG • 5232 to 3325 284 30 2435 147 105 82 26 POG 2 to I to ' to to to to to y Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG pumps off gas TG Trip Gas , ' ii. ��iF, ,,, /s,'i��i%i � /!,� ,lril�.,:g.1.1 •4;1'. /// r��,,: rri9ix, . 't % / � li * �/r„- • 24 hr Recap: TOOH from TD 11103'. Circulated and conditioned BU prior to conditioning for casing run, losses c 66 to 240bbI /hr. POOH to 9880', spotted 100bbI LCM pill, POOH to 8680', circulated hole clean. Directional work @ 5280' to 5130'. Simulate casing run to 5232'. Service rig while circulating for H2S monitoring. I • Logging Engineer: Boyd Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air f , i' ,LC / ... ii /r/i/ r . r hr', % ri,! //% �F , r/ /' / / /i. : -:. r %,! F ,//r`", ,.. - r z l � / -/ 1�z ' �x��,.a''f'' /��j /i ' ' � %f�s.�, , ,, i i �/% �� /�� /j //i < .r.;,, „ „r /��rr,'%/ % / / %r +:k ” z,',�`r &���� /�� /� /.r ' , ,.si�� - ��i',3:. 6� / i ,. 1 1 I �r' IMO ;:it .* � „�.,.�,.. i�^.','. ''., r' � %,/'%k�''„�/ %��71'l��n�tii„* lid �. .s.,,. /.H5! £,;i rr /, e, ,....?F, Customer: Pioneer Natural Res. Report #: 50 1 _ HALLIBURTDN Well: ODSN-40 06/26/2008 -5:00 Area: Oooguruk 05:00 Depth Dat 11103 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Running Casing Job No.: AK -AM- 0005710855 Report For: Rod/Jeff Daily Charges $3,500.00 Total Charges $173,500.00 ROP&Gas: Current Avg 24 hr Max Max CO ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • •m SPP •si IMEMIBM 0 0 0 0 Flow Rate s• m Gallons/stroke / :,r' ' % :< � ' / /i,. � !� i ' , „ a ; /i' i i /'/ ��% ' � ' / „'iF /� „!j��..�, , G�,: a.'. ..'�.�.�:��i!'r.,iv'.c�� /�fi, � , ,,,�a.��i8rr'�1�1�z1.�.'�� /� ,�,sx, >c��r,,., �;i� . F /��i�'!�;a /„ , :,:«/.'�u':,?,' "' �� /��` /./z�rc«/.''' ` �;' ^r';� /, ., ,za��r Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De•th ft in out sec /•t Ibs/100ft 2 cP Ib /100ft m• /I m1/30 min 11103 11 5 11.5 51 6/20/- 19 18 10 18k 5.20 13.7 1 ''^ " y am / /� � / /r�i- �•,,. %/, «: %: �', '%"'" / % ;s , , ;i / ry.. � % � ' � % Y ;'� ri �7,r d ' // � ' , BHA Run # ��/ Bit Type � Size TFA / �� / Hours Depth in / out / Footage �� WOB � �� RPM � / r, r, Condition 701 -- 1 - - - - -- Casin. Run 700 FMF-2565z 8 75 0.863 22.5 9316 11103 1787 15-35 150 1 2 BT N X 1 ER TD - ; ih yam' .,....„ - < ✓««,,,� c �`7v dii. �a� �✓ c rHO ., a.,� /7G,rr�j,*��,�, �' i���. _ ,__- ... �r�if « „ ✓ // Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff / current • � - /r«''"x 6i% ��.i�..�A..,ti> 6: ,X c <c / .,,,r. �;r..:�''i. , .i �:: ,,.�.... . s „y %;r,'�, Gas Breakdown I Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to r to 1 t0 t0 to I to to to to 1 to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I BUG Bottoms Up Gas: POG - pumps off gas; TG Trip Gas 4 z, f � zi7 - .. . " £�s'y,,. ., � �`F'�'/, , «iiv , «, /.. .x z .. . .... h «,;,.. u: /.' __.. <�!�ki, ,....... r, 24 hr Recap: Finished pulling out of the hole, read MWD tools, lay down BHA, test BOPs, rigwand run 7” casing. I There was no significant amount of circulating during report period, therefore there are no gas values to speak of. I �;. 9 9 9 p P 9 1 . Logging Engineer: Boyd Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air � � .?ii, s' ',, .. <, , � /.,, � y /; ! !G r ✓: / / /....air/ r y// z i. r�� r /fi � „� .. , /'/r /: -/ / � � /% ,17y., �/ � /ice -.r j /// /�l-z �i, i::;�� L %/�,' _.. i,�:',..��,�'1,.; �'//,.< o� �- �: �.. � „�����zH,�e „ /,,.il/, //Yv,.�;w� �.,,,��.r- �,u / ✓ ✓i,__....,,... ,« io�<.< � �ue//.,..,» „ �> ��' fi�l ,....,✓'',rf. ✓.r��,.,,,:;:;� c,..� ✓c .l, 1 1 1 I '— x ��i /., ar z 2 ; ..J n ,. // �� Z/,. � I >, %i� . ,. �rcz� „,- ,r�., �G, �,�, >iz u, ;. �� "�„ ! ��I� /,��: ., �0 .,,, />/%„/"' �S� %% ,x �> /,, '. / z y,�,rraa Customer: Pioneer Natural Res. Report #: 51 I L T Well: ODSN -40 Date: 06/27/2008 -5 :00 Area: Oooguruk 05:00 Depth 11103 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Running Casing • Job No.: AK -AM- 0005710855 Report For: Rod/Jeff Tot D aily Charges $3,500.00 Total Charges $177,000.00 l / � / .rr`/ % � x / / h �„�; i / // a,+`" �'' >r, r °- r,i. .. / .,,.,.., 1. � .,, ,,,.,,� „�ixi //%s.� wz��� �i�'i,./k.„s� „�r,�. , /�'.,i✓J,�i�i,., /d /�r��,�% /,.. ,..2.. ;.,,� ROP &Gas: Current Avg 24 hr Max Max CO ft Pum • & Flow Data: R = ROTATING a R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • • m SPP •si illEMOMM 0 0 0 0 Flow Rate s•m Gallons /stroke 3.6 ,r ; /s ''✓ i>,ry.: /i r r / „// r - yr9i,i iiy� /' /ria r r 1.4 rr � / `� x, C -lr� / l 33 r ��f r�� /%�/ y r/ v r �- ,�// : / ��� /�r »`. / � 9 • I "> s// ii�szr / / 4��/� �. ;,... %� , .. ,ter „r �'' // jrz /. ! / � �,..,,. .� a,. : .,. Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids De•th ft in out sec /•t Ibs /100ft 2 cP Ib /100ft m • /I m1/30 min 11103 11.5 11.5 52 6/19/- 20 18 8.7 18k 5.20 13.7 J % / <i/ ; ,r, , > ? :1674:::* ",y/'/ � ✓, �� // ? ;;i!..4' /ice/ ., /// /r,� ....I. i, I �. >�'i�.� /�;;� /� /' /�. ' .,,,�.:,Y , st„ y r / z /i „ %��i�G „ii „,,,, ✓:, l r,-,/ �/,//ir/,.G . ���,;:%,r ,,,�;�. >,. � /P BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 701 -------- Casin• Run 700 FMF 2565z 8.75 0.863 22.5 9316 11103 1787 15 150 1 2 BT N X 1 ER TD a v r ;, / � ; / /ry . 1 1 . '� /� /� /,� r , ' r /r,�/ i, F , * 4 , /h"'`l%�.z %%/..4 ',` z � • �'/' . =,' / / '�i � / ����40441 a '.�. , 11: 4 ;.:. ��� Afar .;,,,,i;.% , � lu �' .c.,. ., �� ' -„� / / �,,,,,' / hi ��i� ,,. rc .x Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff current - - — . — . ..44i rIt.:: ,,, S : .. .! tr';* * .. airktV :4:4 ita7§ .4 Gas Breakdown I Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 3367 to 114 27 2447 114 61 35 8 POG I to to to II to to to to 1 .' to to r Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas r, /' /%; x.,. / / /s %; „,_ /,/e i G,r,,, ,,, / „poi /r,.1P �', r, '' 24 hr Recap: Trip in 7” casing to near projected hang -off point. Tight hole conditions prevented casing from going to TD. I Several attempts were made to get the casing to the setting point. Problems occurred while trying to pump downhole to wash the casing down. Pumped 5400 stks at bottom to clean and condition hole while taking losses up to 300bbIs per hour at 70 stks /min and 240 gpm. There was no gas observed at this time. Rig up to pump cement job. 1 y 1 Logging Engineer: Boyd Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air / f ; /// ” „,i /r, r // '/ h r,`..1 %r r. '�y� // r %% / /��%., /�'� Z Fiay iti / %� / , r .., �s ., / s / „:i, 1 "%/'/ %/. '': 1 1 1 '"° /� "C' y r / j r� y - y rr 1 ✓;-* / / r ,/ `..i//' f , % - r io t � „� x, '� ! <i//� �� „� J /� x;��:5,��^� ,. �f�li„��� {��, � � ,.. ., s � . ',� ry �s , „a s, , n ��� /a/„ t . Customer: Pioneer Natural Res. Report #: 52 N Well: ODSN -40 Date: 06/28/2008 -5:00 €° Area: Oooguruk 05:00 Depth 11103 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Rig maintenance Job No.: AK -AM- 0005710855 Report For: Rod/Jeff Daily Charges $3,540.00 Total Charges $181,580.00 1E ;4:6 Vitriff; . ROP &Gas: Current Avg 24 hr Max Max © ft Pump & Flow Data: R = ROTATING ti R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • . m - SPP • si / 0 0 1019 11066 Flow Rate s•m Gallons /stroke 3.6 ,%; x Mud Data: Density (ppg) Viscosity Gels PV YP PH Chlor API Cor Solids Death ft in out sec /•t Ibs/100ft 2 cP Ib /100ft me/1 m1/30 min % 11103 10.4 10.4 65 8/11/- 28 19 - -- 16.5 / � , :, /, ;. / %, , /;ii . , ': 1� , q' / .%%� � y ' Y /i „.� , f�.;;;'�e���/r/r /f�,.:�;� � ,�i/ / ,_.. a�<. .� '> �,l /, k���/%Gij�x;�:i�/�,:ir�'�F, . � L46, B HA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 701 -__- 11103 - - -- Casin. Run 700 FMF 2565z 8.75 0.863 22.5 9316 11103 1787 15 35 150 1 2 BT N X 1 ER TD /; ",'r, E��/��',�y��� � �1.�' i „�/r'' ,, x,i ,: s?�.`s��s�w; /�' /i,?., r.,✓ �/Gir / / /r /.ri!'/i/9L -.. ✓ ��, .:, c�,i,7, ..,?�,.� 3` Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current a y/ .- 2sY i % /yi/rfr/ t;� .� .'i. / /'�/, it • a ,,rr i . ; «.. ,./ / r, �., ✓- /, /;�r/ 's?"i: • "k`;✓7 /r/r`.' , /,��'iF , ,.'. "''• " ,.� „�./' h'' s h f�// �i//`" 'r�°.„�ir�w� „..a� i�i�x 1 Gas Breakdown Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 11066 to 1019 679 67837 2623 980 426 143 TG I to to v to to to to to to ; to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas r s J/r • / / Aiew i r /Ya F ' i i � a'::: mi l //i% „� ;%//,rs e%i;',,,,, s� �.,r `�/ /% /�,.,,,,,, pas,'f i /,,,,1 1 �"/�l 9 .. � /,l�/,, ,,, .,;,�' ,�'/i/ i,..�;,,.Y „ 24 hr Recap: Finish Circulating hole to prepare for cement job. Rig up and perform cement job. Change well over to OBM I While displacing cement gas numbers of 1019 units were observed. Perform rig maintenance finish casing job prepare to lay down 5” pipe to replace with 4 ". Finish laying down and reading MWD tools. I Logging Engineer: Boyd Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air ;/ % .r ,..ice /r%!�� ✓,�' �� / �j / - %� �i �rrt/ r y5 /z� f / :; Y i; y y`, r ,% r F a j ' ✓ �Ett i��.&,,��;,,,�;- � -:,:, .r:;�.a;���f'rri������.Ki., ✓i y, /' .;Oi „��l �,rc: i,o,,,rt: "�,. ✓�:i CZ. 1 1 1 • Customer: Pioneer Natural Res. Report #: 53 Well: ODSN -40 Date: 06/29/2008 -5:00 II it Area: Oooquruk 05:00 Depth 11103 Location: North Slope Progress 24 hrs: 0 ft Sperry Drilling Services Rig: Nabors 19AC Rig Activity: trip in Job No.: AK -AM- 0005710855 Report For: Rod/Jeff D ally Charges $3,540.00 Total Charges $185,120.00 : %r . iiy% * I „ * M /.., te i�� a1"��, ,i.. ,� „ � " .,r.�, .. < /,� :;'i,�,2,...61 "t1.-. '.,, r'� E ROP &Gas: Current Avg 24 hr Max Max 0 ft Pum • & Flow Data: R = ROTATING R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • .m - SPP •si 0 0 0 0 Flow Rate s•m Gallons/stroke 3.6 y,'F i,s- ",,Ac', ��. /r✓ f% /ry ^4. i s /��yi!'d"/ ,tz... ` :. y, v �i ' ) r' . ^s . ..:4g: ; r * .V. , Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids De•th ft in out sec /•t m1/30 min cP Ib /100ft volt wiii • •b % 11103 10.4 10.4 65 2 22 14 390 291214 3.89 17.1 111 y,���` .1rt. ,.;;.v : i.,, <, r�� /�� '-'� .1::;? X ,' 7' x,, BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 800 FMF- 3543zz 6.125 0.464 11103 700 FMF -2565z 8.75 0.863 22.5 9316 11103 1787 15-35 150 t 2 - BT N X 1 ER TD �/ r r✓ N Y.*".* r ,. ' /. .4011. . s' / r „/ / ,, r ^,.�' ..a;>��.;. E/" /�f�.,,:�1 � �� >rs ;; �, . i.. ,�,�, /vii ^„ �� ,. ���.:, n C:' ,. ,. Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff � current I u,, c/ c . '' .- iiair • .,.,Z i, ..,..<SrM:,i itz:;*" >x' 41 * ... ,,,;':' /z"aliir ..k if `.;,: i',,.. `' Gas Breakdown 1 Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to to I to to 1 i to to to to to 1 to to y Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I c BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas „ / � r ' -'� rl r r. �, u /� r �/� /' 1, ' - �` : � � �,, - // %,_%// 44 , ,`"am r ;,,i . // / ' �% ri iic `. i d....,,.',i , ,,, y� .4f Me ,;:' ,. ✓..,• / /s�,,� /. ^� �. i�y� /� ., rr sn d ` � r �i�/ ,.>a� /,✓Wl�r4�.fu.�w .xr .h ,,,, h.,, ��r r?r,., /' � , /�� /r, ,.,: ,, „. 24 hr Recap: Lay down 5” drill pipe, pick up 4" drill pipe, change out pipe rams, perform rig maintenance, test BOPs I prepare to run in hole with BHA # 10 to drill production zone. 1 I Logging Engineer: Boyd Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air t ^; . � ro.w /x„ ,,/ r ,,,' s% /!� r / /// � �i /r �y r "- ,;..,^� / , �i ,, , � „ . „c,s,,; , ' q , / 44 /,,,,,/i/ /fi , /,:- r �/ �' %9 / ,� / / „/ ;, /�r/ ,�F�/y ./ ;, r :^ ✓. :. —✓ /�y v� / %ir l%r,, ..� /i „_^ /�.,,i ,,: �r,% ii/ /�/ri' .�,Fr/i /r..,.%” /.;'x/i/., , �rx����i .,;�,...� „y!/stF/,.,,�H:: ..:I. 1 1 1 1 yn '. . t . 3 *a « p r r s` i /x`;. ` .'�. >ix ' �j� x '. /.,, zx�'I�G�1r�, , s% 3 ..�w.'r /!��':�", ;�1� ..7�� �. �� /i% /�iy „:,,,, y�?xirr;, 44, r c' Customer: Pioneer Natural Res. Report #: 54 ' L Well: ODSN -40 Date: 06/30/2008 -5:00 Area: Oooguruk 05:00 Depth 11103 Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: trip in Job No.: AK -AM- 0005710855 Report For: Rod/Jeff iy�F< Daily Charges $3,540.00 Total Charges $188,660.00 II ROP &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • • m - SPP •si ' :111EMIZE' 0 0 0 0 Flow Rate s•m - Gallons /stroke 3.6 I ii ' .! /r ✓ r ry ve' ' : ” tare!' ., hr //t � / /, '.. , j r// '- , . fi Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids De•th ft in out sec /•t m1/30 min cP lb/100f volt • • • . b % I 11103 10.4 10.4 83 2 25 15 375 283935 3.76 17.3 y ,f' f 1x/ F / %fir rr ,'/ e ', r/w"'� /y �r Fr � // i'»�`'� r/ y s� / / .;1 , r"" . , � � ,- .. ,.l %,/', , :%� r if�xi �� , -, is / / %d, -: at .. , .�'��,..�;�,�. : �r ✓l %, <% _... ,.,, zrf : BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 800 FMF- 3543zz 6.125 0.464 11103 ' 700 FMF -2565z 8 75 0.863 22.5 9316 11103 1787 15-35 150 t 2 BT N X 1 ER TD ;✓e K^' r�''' /'%� z s All. i . , „ y mxG / /rr /p / '/ ;, c h � d;: , „: ��s;.,��"� ..f /., ..:. r. . ., '.� �?ir ✓/ ✓a'„ra�O,S%;.,��:> ,_.,,.. �/ /v. x. ,/ �� ,, ,�. - ; �+� .,, : . Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff : current ----- _ - - - - -- „? �i...Mt ,;1 ,It." X : : ., i,%f/ = � ,.;1 ' ._ ,! .../f,J' .x'°s ?.,,. v.rif%;., x,x s Gas Breakdown I Gas (units) Chromatograph (ppm) Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to I to to to to to to to to I to to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; %r BUG Bottoms Up Gas: POG pumps off gas; TG Trip Gas s ;, �r. rr .0 / r / r / / ir y , . / / % / / .. : r . r / ! r ���r� - - � �` - '� -� - r;,, �'�r/ /,r it „r, .,. /..L�,!ti�r'i %i ` .'.,; ✓. ,,i,. «, � /r %,✓,./ ,. ,r.,, :: .v,� . i,., �, iii. ;:, ri ,,.,.... 24 hr Recap: Pick up and make up BHA to prepare to run in hole. Start running in hole singling in hole with 4” drill pipe filling I as necessary. Pump freeze protect down the backside of the 7" casing. 86 bbls water based mud, 10 OBM, 60bbls diesel Continue running in hole with 4" singles to 10827' rotate and pump. Finish running in hole to tag cement. 1 Logging Engineer: Boyd Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air / ' / ' /i % �s; / .rr�.. , , r s :, /i r , <,./ r' � %��.<„ /�,o��,���`�,r���✓/ryi. %� 1��2��'�.,, >� 'V AL ..te 1 1 1 I Customer: Pioneer N atural Res. Report #: 55 ''''" HALLIBURTON Well: ODSN-40 Date: 07/01/2008-5:00 Area: Oooguruk 05:00 Depth 11455 ' II ../ • Location: North Slope Progress 24 hrs: 352 111 Sperry Drilling Services oi Rig: Nabors 19AC Rig Activity: Drilling •..., Job No.: AK-AM-0005710855 Report For: Rod/Jeff 1 I Daily Charges $3,540.00 Total Charges $199,867.60 . 1 irstt . - , • , All' Ir ' ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING I 14 ,3 R.O.P. ft/hr 110.0 82.0 178.0 11306 Flow in • ern 205 SPP a si 2900 1 1 IZETELEMIE 285 49 492 11299 Flow Rate s 4 m 58 Gallons/stroke 3.6 1 ''‘ NIIMIt* „amik.f.' Illiate ' '''` .11 S , 1444 ' mai., AIL . I ' Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids Depth ft in out (sec/qt) m1/30 min cP (1b/100ft volt .pm (6 • b) % 11253 10.4 10.4 93 2.5 ,.. 40 16 268 307872 10.36 15.3 1 ,* . 1Aitilitt Milk, WAhi. .1 .*:'41111/P' - Mr , ". iiiiik-, ''"''' lit Illiti. lila ,11111fft,"„ At i 111 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 800 FMF-3543zz 6.125 0.464 4.26 11103 WI 700 FMF-2565z 8.75 0.863 22.5 9316 11103 1787 15-35 150 1-2-BT-N-X-1-ER-TD I -..., 11 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff .• R (current 90 5 5 I , :agar 41: , Iiiitr' - .1.77 . ja , ser ws diar Aiiiir ,ivir„, '•• --- - .,_ . RIF 1,11 4 Gas (units) Gas Breakdown Chromatograph (ppm) 41 Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 1 "; I 11103 to 11409 490 224 23148 750 243 80 3 BG to 1 to I 1 :t1 to 4 to 1 to to to — M.... to ! I ; to __ _ Il Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; P • BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas III , 11 17' 41111 I Aia Ifiltif .... ' MI6 9.4 „.„, III . 24 hr Recap: Slip and cut drill line, circulate and clean hole of cement before drilling float equipment. Drill out to 11122 and circulate bottoms up. Pull bit to into shoe and perform FIT to 12.75 ppg EMW. Worked on MWD tools for better detection I , Continue drilling ahead changing and trying different parameter set ups to clean and strengthen detection. Drill ahead to I approximately 11455. Gas numbers hovering around 2 to 300 units with a maximum value of 491 observed. I i i Logging Engineer: Boyd Piercey / Wayne Hermanson * 10000 units = 100% Gas In Air ..1 111 1 1 1 1 Report co:ett7: 07 HALLIBURTON Well: ODSN-40 08:5:0: Customer: Pioneer Natural Res. 111 ; .:: Area: Oooguruk 05:00 Depth 12473 I Location: North Slope Progress 24 hrs: 233 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH f/ shoe Job No.: AK-AM-0005710855 Report For: Rod/Herb ,.. I Daily Charges $3,540.00 Total Charges $206,947.60 .. , f I @ ROP&Gas: Current Avg 24 hr Max Max ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr 75.0 84.0 214.0 12394 Flow in o om 226 SPP esi 2830 ,. IllErlanta= 12 276 465 12417 Flow Rate s • m 64 Gallons/stroke 3.6 !-'s to 114 i' I IIINK 41111L =F0 41111L.. 4IILL . * ,..,, Mud Data. . Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids 0 De oth ft in out (sec/. t m1/30 min cP (Ib/100ft volt 11 ..b) % ' 12473 10.3 10.3 78 1.5 38 13 624 299,044 5.44 15.1 ..,.... 1- . a: . sl f Mr MOP . .41111ii Ant ,;,...,41t . r.r7.— ' il $4111111,. I rak 1 r BH ,.... A R 00 o n # FF mm B i i t 58 8 S 1. 1 z 27 e 58 T 00 F .. 45 43 H 21 0 28 u .. 1 p i n / 1 F o o 37 t 87 a 07 g e 1 5 W - 31 R C 3500M 1 on dition , 1 1 ID, Alf .at "Mr.s. . IXF ..,11.- W.."..., S '''' -SIP ,... 1 1111101 0 att- 14 11it alit .11k. • Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff 0 (current ..,. 80 20 , ..... . t . . ' alw I ' ..,. Gas Breakdown Gas (units) Chromatograph (ppm) I Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type k ' l liti ai x, 12200 to 12248 153 120 17270 547 183 67 2 BG I ,1 12248 to 12400 387 245 39573 1331 420 156 16 BG • 12400 to 12433 462 395 47646 1474 448 152 19 GP to to to to ■ : I to to . to 1 i ii I 11 to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas - Trip Gas 1 ' 24 hr Recap: Drill ahead from 12238' MD, 6228' TVD to 12473' MD, 6202' TVD. Hole began taking 3-5 bbls/hr at 12300' MD. M. Total loss for 24 hrs of approx 20 bbls. Mad Pass up to shoe at 11067. Reduced MW from 10.5 to 10.2 ppg. Connection 1 gas while mad passing out of 85 units over background of 12 units. , i 1 :40, 4" Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air 4 .1' ' 1 1 1 1 I , : ' , :.:,1 - ''' *41* '' *.- Culi;m:r: Pioneer Natural Res. Repori#: 6....:4 58 4'.' f HALLIBURTON Well: ODSN-40 Date: 07/04/2008-5:00 ;., Area: Oooguruk 05:00 Depth 13222 I Sperry Drilling Services Location: North Slope Rig: Nabors 19AC Progress 24 hrs: 749 Rig Activity: Drilling Ahead Job No.: AK-AM-0005710855 Report For: Rod/Herb I Daily Charges $3,540.00 Total Charges $210,487.60 :- .V. ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R= ROTATING I , R.O.P. ft/hr 66.3 68.0 186.0 12748 Flow in • .m 241 SPP is' 3380 11 NEEEEMEME 60 253 500 12794 Flow Rate s • m 68 Gallons/stroke 3.6 _ ititt:... 4111i iNa. 4 1111k,—,..1113K.. W! itS... AMIE I Data Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids Mud 04 Depth ft in out (sec/qt) m1/30 min cP (Ib/100ft volt IR (•pb % — 7. I 13053 10.2 10.2 78 1.5 44 16 592 314,804 6.09 14.8 wo k. B HA ;ir- 44&, 411111F ',..Alit .,..: '"..- ,....,. , ITV I : BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 11 y ... 800 FMF 6.125 0.464 29.4 11103 2119 10 110 700 FMF-2565z 8.75 0.863 22.5 9316 11103 1787 15-35 150 1-2-BT-N-X-1-ER-TD . ,.. 111 I. Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff , 4- (current 80 10 10 ,.. I r akr",:iir ' Mililbe .4lier * ....m'Ide --latte - riiir '1111 Ja. ' -mak. - -.4., ' III ',,..' Gas Breakdown Gas (units) Chromatograph (ppm) I Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 12590 to 12700 430 302 44142 1499 455 138 7 BG 12700 to 13000 431 375 44064 1593 504 178 27 BG 13000 to 13052 362 33 35639 1286 425 161 17 CG l i 13052 to 13052 425 425 40740 1292 407 145 22 BG , 13052 to 13149 371 230 25324 922 334 133 12 BG ., 1 13149 to 13149 225 225 14367 528 203 88 5 CG I to to PI to 41 to . -,,, 111 '''''' '.I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas ‘;;;...k WW "'M , sl.! , ...,,... VA 1 : 4 wlilto Silk, iiillife. `11., 1,7!:... ' 41/, 24 hr Recap: RIH 11101' to 11300' and circulate 2X BU. RIH with tight spot at 12068'. Drill ahead from 12473' to 13300 111 Connection gas of 225 units over 138 units background gas from connection at 13149'. 111 1 , Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air ' . . - - * . , .. ...... . , .41.' .... :...,',.. ., ? . • : , '.. Aim: , , IF1' - -4 - E ---. 44N siiir atier ' it lor .4ra` te 9 4 "'" at le 1 1 1 • .v.. . ,,,,,, . A - 1. 41 le 24 ' 4 addla n 1. . -:' • - ' Aft' Vg ' Customer: Pioneer Natural Res. Report #: 59 HALLIBURTON Well: ODSN-40 Date: 07/05/2008-5:00 1 il i Area: Oooguruk 05:00 Depth 13359 I t.. Location: North Slope Progress 24 hrs: 137 atf, 1 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping Job No.: AK-AM-0005710855 Report For: Rod/Herb I Daily Charges $3,540.00 Total Charges $214,027.60 4. :r; ‘.',..• ,14• W , ' At Agr .'41116*. ... .Vr ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING IIIr4 R.O.P. ft/hr 61.9 60.9 90.7 13354 Flow in • • m 236 SPP • si 3325 I IHEICE51= 91 90 154 13343 Flow Rate s•m 67 Gallons/stroke 3.6 ... 411 L, AIL_ 411111._ 4 118 .111. I ...4 Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids A 71 De •th ft in out (sec/. t ml/30 min cP (Ib/100ft volt ppm (p • b) % !rf „,..A 13053 10.2 10.2 80 1.5 39 15 690 298,141 6.48 15.2 .....m. ifff.., fr"7 .„,... zilit. I ,. BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition I 800 FMF-3543zz 6.125 0.464 31.9 11103 2256 12 110 700 FMF-2565z 8.75 0.863 22.5 9316 11103 1787 15-35 150 1 1 Alirt. 1VIP„ ..., '"'. .40, ,..,Miii, .. 1111111e. 1 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current 50 20 30 ' J 1 Gas Breakdown I Gas (units) Chromatograph (ppm) I -., Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 13149 to 13149 225 225 14367 528 203 88 5 CG 8 13149 to 13250 163 135 9786 304 116 46 5 BG iii A 13250 to 13359 203 109 6905 207 77 38 2 BG Il * to to i i to to to :I/1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; '.;. I in ". BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas ?.., 24 hr Recap: Drilled to 13359' MD, 6108.3 TVD. CBU 3X and POOH to change out GeoPilot. Backreamed f/ 12679' to , F 12564'. Pumped slug and POOH to 7553'. UD 5" DP from derrick. I� Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air 1 nig' - - tr '' ' ;" Air ' tan * Stir leir d .4e 1 1 ., 1 • - 1111 Customer: P Natural Res. Report #: 60 r '... HALLIBURTON Well: ODSN-40 Date: 07/06/2008-5:00 .i: Area: Oooguruk 05:00 Depth 13359 ;„...,.,.4 I ''...." . . . Location: North Slope Progress 24 hrs: 0 - 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH Job No.: AK-AM-0005710855 Report For: Jim/Herb I Daily Charges $3,540.00 Total Charges $214,027.60 . :1 t,41.: Mnirnf _ . . . - -7': ,MIIIINY „. 21, ''''' s Atilii, "r..., . ' ' . , illitiV Nillrgfk3,. I ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr Flow in • •m SPP •si IMMEZ23= Flow Rate stm Gallons/stroke 3.6 4 .6s, ..... 1 Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids TIN Depth ft in out (sec/qt) m1/30 min cP Ib/100ft volt ppm (4 .b % 13053 10.2 10.2 98 1.5 39 15 653 298,141 6.48 15.2 VIr Ali iilliff Ar,,,. ' — 'r 4111111 --11'. f .Skit;1/4 . I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 900 FMF-3641 6.125 0.589 13359 ....„ 800 FMF-3543zz 6.125 0.464 31.9 11103 13359 2256 12 110 0-1-6T-C-X-I-NO-DIT I . Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff . ..., (current) 50 20 30 . .fifir , Zg ita ' -ilnwrs • Gas Breakdown Gas (units) Chromatograph (ppm) I Depth Maximum Average Cl C2 C3 C4 Tot C5 Tot Type 4 to 4 ' : -v. to _ I, ii , to _ 111 to to to 1 . : to to — .,„ to 1 ; -- Gas Type a BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; ' I : BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas in it -2.. 7131111V ilia ., ,.. - 1..f.fr ;411W 4 ;f:' MI& Iliallt , . 24 hr Recap: UD 5" DP in derrick and POOH. UD BHA and test BOPE. Make up and surface test MWD. RIH to 3295' and I I : shallow pulse test MWD. 1 , . i 4 4 l' 1 .1 Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air 1 _ i i 10 AU - 417 . MOW 1 1 1 . ,, Inatr " ..7 ,,„. -..„?' ' , ; . 1.A . ' • "'A'' ''' ' ' , _ - Customer: - Pioneer Natural Res. ' — Report #: 6 9 HALLIBURTON Well: ODSN-40 Date: 07/07/2 Area: Oooguruk 05:00 Depth • .. Location: North Slope Progress 24 hrs: 0 II s ,„ s Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Sidetrack ki, Job No.: AK-AM-0005710855 Report For: Jim/Herb I :/.... Daily Charges $3,540.00 Total Charges $217,567.60 „fmrlikAiir 1.46-- Mir! - :, 'MOM W - :., Mirtr - TvAPP',• ;z4ViiNL. Immtlf 1 F., ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING I f: .,-. 1 R.O.P. ft/hr Flow in • am 240 SPP •si 31 ilEMIIIIMIIM 17 30 640 Flow Rate s•m 67 Gallons/stroke 3 it 41 11 /Mt I i tg Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids ‘4„, De•th . ft in out (sec/et) m1/30 min cP lb/100ft volt • pm • • b % 12950 10.2 10.2 105 1.5 44 16 693 298,743 6.48 15.1 ''':.-i WIMP Arai: ,:okstaisti_ Aar III BHA R # Fm 6.125 TFA Hours 1 D 2 e 9 p 5 t 0 h in / out Footage WOB RPM Condition !i 800 FMF-3543zz 6.125 0.464 31.9 11103 13359 2256 12 110 0 AN 1 .. 461 411iiir f,,, '... Allr . 4111111111e ne‘..mrP -.., ' Atifigie ' ABM*. 1 Villa. -..ftg,..outa likiiiit -ill 1 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current 50 20 30 , a ., . Gas Breakdown _.... Gas (units) Chromatograph (ppm) I .: II Depth to Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to ' - to I 1 to to to I ' to to to to I to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; ■ I BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas I.,' n ' MNII Ilk -alsr, mr tk. AMIllit 'XV aic. ':illillte 4111 '41 24 hr Recap: Shallow pulse test MWD at 3295'. RIH to 11412'. Began reaming from 11412' and mad passing at 180-200' ft/hr with a max gas of 391 units. Reamed from 12141', tight and packed off, picked up to 12090' and circulated bottoms up 1 I at 200 gpm with 210 units gas. Continue reaming with max gas of 640 units and tight spot at 12227'. Worked pipe and • . , circulated hole clean at 12385'. Packed off at 12550'. Worked pipe. Wash and ream to trough sidetrack from 12950'. i .'.' . Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air "* - , . i ;..L___ i lili: Mg 41: .MIE 'JIM'' i .----- 'Mir; *:::Mir 4177 -.4411115.7'sigt : --Ar: tf '-v iv& 1 1 1 1 Customer: Pioneer Natural Res. Report #: 62 11 HALLIBURTON Well: ODSN-40 Date: 07/08/2008-5:00 Area: Oooguruk 05:00 Depth 13440 , ...., I Location: North Slope Progress 24 hrs: 490 4 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling 4,1 Job No.: AK-AM-0005710855 Report For: Jim/Herb 1 Daily Charges $3,540.00 Total Charges irt, $224,647.60 fl I ir irr . ROP&Gas: Current I . i 64.0 A 18 v . g 5 IRIMEME, ft/hr M111 340 350 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING 113.0 13291 Flow in • •m 240 SPP •si 3175 535 13281 Flow Rate ssm 67 Gallons/stroke 3.6 ..4 ...L.-2:- 'VSELLL-27 . ,,iii...411 ‘:, I , Mud Data: Density (ppg) Viscosity HTHP . PV YP Elec Stab WPS Lime Cor Solids De •th ft in out (sec/qt) m1/30 min cP (Ib/100ft volt ppm (ppb) % :;. 12950 10.2 10.2 86 1.5 43 15 693 299,644 4.14 15.1 1 1 .Atie .: .411111P 4tt * ..ii, ,i11111111F- 1111.:',. I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition •.: 900 FMF-3641 6.125 0.589 18.6 12950 490 10 95 800 FMF-3543zz 6.125 0.464 31.9 11103 13359 2256 12 110 0 I .1.' ' LithOlOgY (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff .,.. (current 80 10 10 i II al 11 Gas Breakdown If Gas (units) Chromatograph (ppm) ii :t• ni Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type - z. I 12950 to 13000 309 195 25497 780 236 77 5 BG 13000 to 13200 436 310 35223 1228 404 145 6 BG 13200 to 13370 529 425 52196 1681 534 181 33 BG II 1 to to _ to • ;` I to to - I to to 1 to _ ••11 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; ii BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas I 1 . AWE 4t:lain if - 11111116-,.. 11111111tX. MOM . Ali ,, 1111111i; 24 hr Recap: Worked sidetrack #2 at 12950'. Time drilled from 12953' to 13440. I 1 it Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air ii I 1 1 NO 1 • I Customer: Pioneer Natural Res. Report #: 63 HALLI BURTDN Well: ODSN-40 Date: 07/09/2008-5:00 Area: 000guruk 05:00 Depth 14337 1 Location: North Slope Progress 24 hrs: 897 Sperry Drilling Services Rig: Nabors I9AC Rig Activity: Drilling :1 Job No.: AK-AM-0005710855 Report For: Jim/Herb I Daily Charges $3,540.00 Total Charges . r I ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING R.O.P. ft/hr 75.0 53.6 130.5 13291 Flow in ..m 228 SPP •si 3300 ECID 212 320 725 14050 Flow Rate s.m 64 Gallons/stroke 3.6 . w I Mud Data: Density (ppg) Viscosity HTHP PV YP EIec Stab Lime Cor Solids Death ft in out sec/•t) ml /30 min cP (lb/100ft volt • • (ppb) % 12950 10.2 10.2 87 1.5 44 17 731 337,315 5.96 15.1 — BHA Run # Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 900 FMF-3641 6.125 0.589 35.3 12950 1387 10 134 800 FMF-3543zz 6.125 0.464 31.9 11103 13359 2256 12 110 0 1 1 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff (current 90 10 Gas Breakdown Gas (units) Chromatograph (ppm) I Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 13440 to 13700 555 299 59921 1790 576 212 23 BG 13700 to 14060 725 385 73908 2190 701 255 41 BG 14060 to 14305 365 260 37445 1175 400 162 20 BG I to ____ to _ 1 1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas �� 24 hr Recap: Drilled ahead from 13440 MD, 6169' TVD to 14337 1! 11 Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air 1 1 1 - .1.,,...,.f...1 ] 1 Customer: Pioneer Natural Res. Report #: 64 .. HALLIBURTON Well: ODSN-40 Date: 07/10/2008-5:00 '1 ,., Area: Oooguruk 05:00 Depth 15368 -- i Location: North Slope Progress 24 hrs: 1031 i I Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling ., ..., Job No.: AK-AM-0005710855 Report For: Jim/Gus I Daily Charges $3,540.00 Total Charges $231,727.60 - ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING I R.O.P. ft/hr 75.0 74.3 147.8 15005 Flow in • • m 228 SPP •si 3300 IEMEIMII 283 360 1087 14594 Flow Rate s•m 64 Gallons/stroke 3.6 MR „ a , 14:001Mit: ,U h' 6 it ••,. . , 411111W. ... I A i Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids Death ft in out (sec/ft m1/30 min cP (Ib/100ft volt ppm (ppb % 15101 10.2 10.2 75 1.4 29 15 787 376,241 6.22 16.2 s :. INF a 1 1 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition i 1 ? ' 900 FMF-3641 6.125 0.589 52.2 12950 2418 12 134 800 FMF-3543zz 6.125 0.464 31.9 11103 13359 110 o- • II l i r iii Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff : (current) 85 10 5 i i - Iiiir"'' 1N ''' . .z IsLP .,:t,'''' s.ataig . .gia . -vIrmw......:1•Arr --- II j Gas Breakdown Gas (units) Chromatograph (ppm) I Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 14305 to 14490 486 312 44200 1360 444 161 27 BG - - 14490 to 14500 665 605 67408 1759 533 186 24 CG 14500 to 14590 463 330 42698 1340 446 170 23 BG I IA,. 14590 to 14600 IF 1053 350 100828 2325 650 213 46 CG ':51 14600 to 14880 931 480 65785 2071 665 227 50 BG 14880 to 14885 976 620 98142 2846 888 317 57 CG .1F1 I 14885 to 15100 661 400 66038 2120 690 251 62 BG 15100 to 15300 425 325 31491 1430 527 207 38 BG v...„ to to , I to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas i' - Illti Alt : 6..;:litt -*-.' it MEM ' 24 hr Recap: Drilled ahead from 14337 MD, 6192.9 TVD to 15368' MD, 6120.4' TVD t: 11 1 - 4 Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air 1 1 1 JIM_ 1 I 1 Customer: Pioneer Natural Res. Report #: 65 HALLIBURTON Well: ODSN-40 Date: 07/11/2008-5:00 Area: Oooguruk 05:00 Depth 16140 I ,, 774 If Sperry Drilling Services Drilling Job No.: AK-AM-0005710855 Location: N N a o b rt o h rs Sl i o 9 p A e c *.i Prog Report For: Jim/Gus $235,267.60 I/ Daily Charges $3,540.00 Total Charges : ANNg 41%Rtrr!TW .1*111M0 4. AINNWaz ;.. ,'. i ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING I R.O.P. ft/hr 54.7 55.1 138.0 15948 Flow in • sm 228 SPP •si 3300 . ECTTID 310 372 548 15481 Flow Rate sem 64 Gallons/stroke ..., _ 3.6 illtt,..,1111111111COM 7 14114W ' , . 1 1/1111iiiii' - ‘ - . 1111=1. `-ri*:*_,. . ;:f,4411041W - Ai lik ,-„.: I Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids Depth ft in out sec/.t m1/30 min cP (Ib/100ft volt ppm (spb 1 % 15101 10.2 10.2 75 1.4 30 13 860 343,066 4.79 15.3 I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 900 FMF-3641 6.125 0.589 66.5 12950 3192 10 134 0 800 FMF-3543zz 6.125 0.464 31.9 11103 13359 2256 12 110 0-1-BT-C-X-I-No-DTF i • Lithology (Y0): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff current) 85 e.. 10 5 I 38 Bi G 15300 to 15500 556 485 53861 1762 '. , Gas Breakdown Gas (units) Chromatograph (ppm) ..., I 4: Depth Maximum Average i 15100 I r -‘ 15500 to 15650 425 604 604 1870 C1 31491 53837 C2 1430 C3 C4 Tot C5 Tot Type to 15300 527 582 621 207 226 222 68 BG 45 CG 51 BG 1 15650 to 15850 477 405 40727 1450 494 206 15850 to 15850 886 886 87165 2285 677 241 47 CG i -71 15850 to 16070 465 320 37541 1417 447 164 26 BG - 4..i I 1 tO tO 1 ' tO _ tO I Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; VVTG - Wiper Trip Gas; I I3u G7i13ottoms Up Gas: POG - pumps off ga TG - 741 Tr it ip 4l as , lagyaki I ..3fe v:ii. op,i , .. , 1 , , n 24 R ecap: n e c ti o n gases: D r i I l e d 1 a 5 h 6 e 5 a 8 d .. from 650 1 5 368 i t s1 7_3 6 P u u n ll it 2 s. stnds to re threshold on PWD tool. Drill ahead to 16137 : . III 'xi Logging Engineer: 1 Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air , 1 1 1 alwa 1 *_ 66 1 Customer: Pioneer Natural Res. R eport #: .:., HALLIBURTON Well: ODSN-40 teh: 16440 I 07/12/2008-5:00 Area: Oooguruk 05:00 .., i Location: North Slope DDeapt Progress 24 hrs: 300 . Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping Job No.: AK-AM-0005710855 Report For: Jim/Gus 1 ll • Daily Charges $3,540.00 Total Charges $238,807.60 tt .., i' - aspgrt -%igsw ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Da ta: 22 R ,s = ROTATING TATING F•t. 22 8 SPP 3350 22 Millii 17 456 16216 Flow Rate s e m 64 Gallons/stroke 3.6 ',e'''',.•111257v., lw, 2 ! i?oisitw,,, -itglirr.:!, ....;141m ,. in, :i1K. 1L..... i'illc I Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids 0 De eth ft in out (sec/qt) m1/30 min cP (Ib/100ft volt p em (p a b % 1 , 15101 10.2 10.2 75 1.5 37 17 809 345,308 2.98 16.6 %Air mw- ' k' asfilL. -*ski "rjvit„ . I ' BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 900 FMF-3641 6.125 0.589 71.2 12950 3490 10 134 800 FMF-3543zz 6.125 0.464 31.9 11103 13359 2256 12 110 ‘list o-1-B RI T-C-X it6 I-NO-DTF litt4c... H . 1 ' - V illir 1 0 Lithology Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff k (current) 85 10 5 ,..„,. .....ar 1 Gas Breakdown Gas (units) Chromatograph (ppm) I : Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type . 16150 to 16250 448 362 37893 1428 465 175 41 BG 16290 to 16400 325 187 29260 1103 376 149 42 BG • to .., I to to - itl to to ..,. ...! :t to ..,.., I ' Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; ii . BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas I at - s- Me ik lit it 'IN& "''''',F , ' — ''--- ---- *-". ' ' 4 '''' ' . POOH 24 hr Recap: Drilled ahead from 16140' to 16440'. Trip out for MWD tools, back reamed from 16440 to shoe. POOH. I i ..1.4 i Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air i ' , 1 1 1 ir 1 ' * 5 Air tpfir' :,,,e4tr'n.- ..g.t.k .. .- za vp I Customer: Pioneer Natural Res. Report #: 67 HALLIBURTON Well: ODSN-40 Date: 07/13/2008-5:00 Area: Oooguruk 05:00 Depth 16440 I Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: PU BHA . I Job No.: AK-AM-0005710855 Report For: Jim/Gus J I Daily Charges $3,540.00 Total Charges $242,347.60 1 I 1:: :•*- AI . -"Aifilir - 4110! .160 "AVIV MK ''''' AM- "Makt*.< ' iiiika. 111F i '9 ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING I 1 R.O.P. ft/hr NA NA NA NA Flow in • .m 228 SPP •si 3350 11Erlatra= 0 18 11022 Flow Rate sim 64 Gallons/stroke 3.6 I Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids i De •th ft in out (sec/. t) m1/30 min cP (Ib/100ft volt ppm (ppb) % F1 16440 10.2 10.2 78 1.4 40 18 883 333,759 4.79 14.4 WA 11, .1.. VIM 4 411 ''.diii6/4 116 4filt. ' Ail I i BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1000 FMF-3641 6.125 0.589 16440 0 900 FMF-3641 6.125 0.589 71.2 12950 16440 3490 10 134 1 -1-ER -A-X-1-NO-DTF 111,,i1 • • Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff 1 (current 85 10 5 • ' - - 1 k'I Gas Breakdown 1, ..r I . 1 Gas (units) Chromatograph (ppm) I Depth to Maximum Average C1 C2 C3 C4 Tot C5 Tot Type .‘ to I to to 'Tt 0..., to 4; 1 to to ' - to to • III to - , Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I .. BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas *.. ..::,a;.: .ior Alit Stria 17 ' 11 IMF ;oat III . ,,. 24 hr Recap: POOH, lay down BHA and test BOPs. PU BHA. I 1 1 : • Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air A" I 7 4111 igg si: 1WP ,A7 Aar iiiir* t: sir: stir • - ` - 141111t - 41.1,17 1 1 1 I , Customer: Pioneer Natural Res. Report #: 68 -1 HALLIBURTON Well: ODSN-40 Date: 07/14/2008-5:00 Area: Oooguruk 05:00 Depth 16440 I Location: North Slope Progress 24 hrs: 0 Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH Job No.: AK-AM-0005710855 Report For: Jim/Gus Daily Charges $3,540.00 Total Charges $245,887.60 I ..t A • . , V.. a . ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING I R.O.P. ft/hr NA NA NA NA Flow in • •m 228 SPP •si 3350 4 1 IENMESIM 0 0 NA Flow Rate slim 64 Gallons/stroke 3.6 I i Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids .j De•th ft in out sec/qt) m1/30 min cP lb/100ft volt p.m (ppb % 1, 16440 10.2 10.2 78 1.5 40 18 847 349,903 4.53 16.6 AMMO; AV , I:4ig lif 'C ...4i s. „ Alit_ , 41,7", liti I TI Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition ' 1000 FMF-3641 III 6.125 0.589 16440 0 : 900 FMF-3641 6.125 0.589 71.2 12950 16440 3490 10 134 (-1-ER-A-X-I-NO-D 41 • Ti4iff „ziaws -, „A Ill _-,-,...-44, . Lithology (70): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff (current) 85 10 5 1 1111 1 , Gas Breakdown Gas (units) Chromatograph (ppm) I Depth to Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to to I to to to 3z1 _ I to to _ to to i II .‘ to I . G a p t a t o b m r e i j a p t i o B - B a gGaass;;TGGP_-TGriapsGPaes to ak; CG - Connection Gas; WTG - Wiper Trip Gas; I : al..,., issrft 7'7* .4111111:: 1St.. .„,4',.-.4 _Allt Iiii '7' let: Ant AIR& t ' ..., :;.- 24 hr Recap: Picked up BHA #12 and RIH. Serviced top drive at 8930'. ki " I 1 ''fv: P. . , ..; r I . Logging Engineer: Boyd Piercey / Tom Mansfield is 1 - * 10000 units = 100% Gas In Air 1 , I ' - 4 "; -: - - - JIM *.-- ' MIK:: 7.,33t:2; La ail ' siltir .:41kr — ' .?...7.7 --- 1 1 1 I Customer: Pioneer Natural Res. Report #: 69 "1 ,A) HALLIBURTON Well: ODSN-40 Date: 07/15/2008-5:00 Area: Oooguruk 05:00 Depth 17301 .. ,—, Location: North Slope Progress 24 hrs: 861 I Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling .!, Job No.: AK-AM-0005710855 Report For: Jim/Gus I Daily Charges $3,540.00 Total Charges $249,427.60 .i_. ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING .fl I R.O.P. ft/hr 39.0 63.3 151.0 16819 Flow in . *m 230 SPP •si 3450 i ,.. lEIMMMIIII 150 270 453 17003 Flow Rate s • m 64 Gallons/stroke 3.6 41 1 il Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Ell Lime Cor Solids . p ,,,, Depth ft in out (sec/.t m1/30 min cP (Ib/100ft volt • • (ppb) % : 16440 10.2 10.2 75 1.5 35 17 821 364,722 4.66 16.5 i BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1000 FMF-3641 rr 6.125 0.589 13.6 16440 861 10 130 900 FMF-3641 6.125 0.589 71.2 12950 16440 3490 10 134 1-1-ER-A-X-1-NO-DTF ! -W Art ' Aar 'At, - ;,,:' jkaA. VINViikk.- '''"Williiiiki - 4111111i, ' . • ,, Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff " 5 . current) 90 5 i '''' • n Gas Breakdown -. Gas (units) Chromatograph (ppm) ifei .:, ; 16440 to 16440 290 32323 1099 322 84 3 TG 16440 to 16480 315 302 32240 1100 314 88 3 BG 1 16480 to 16540 191 120 9103 503 178 63 1 BG I ' 16540 to 16800 373 261 31937 1272 400 134 4 BG 16800 to 17000 445 338 34936 1474 489 177 34 BG 17000 to 17250 453 265 26345 1228 442 161 31 BG I 4 to 0 Ali to Vi ii r i ii to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; v , im BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas . ..i: I ''''' MBE lir Sk: '11111r: Nfi Milk .. . 24 hr Recap: RIH to 16440' Circulated bottoms up with a Trip Gas of 290 units. Drilling ahead from 16440' to 17301'. .. . • i 111 t. I Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air 1 iW ---- 1 1 1 ii .wr... . Customer: Pioneer Natural Res. Report #: 70 . III HALLIBURTON Well: ODSN-40 Date: 07/16/2008-5:00 Area: Oooguruk 05:00 Depth 18210 .. I Location: North Slope Progress 24 hrs: 909 It ) Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0005710855 Report For: Jim/Gus I Daily Charges $3,540.00 Total Charges $252,967.60 ' kUUNIMIEW . iirAA4n n ' '!' . I -. ' jar n ''Ilk.. 41tka , Oln , . ' ' AS • 'c'.... ,,, .,., ' * ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING ,... I R.O.P. ft/hr IIECIEDMIIII 8 54.6 195 117.0 283 17977 Flow in • • m 230 SPP •si 3450 17574 Flow Rate s am 64 Gallons/stroke 3.6 .t , . I ' Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids Depth ft in out sec/•t m1/30 min cP 113/100ft volt ppm • • 13) % 17977 10.2 10.2 75 1.7 31 16 783 370,003 4.14 16.6 I ....., BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition '-' 1000 FMF rr 6.125 0.589 32.4 16440 900 FMF-3641 1770 10 3490 6.125 0.589 71.2 12950 16440 10 130 134 1-1-ER-A-X-I-NO-DTF ,.. 14". - W monfr „iffir--. 0...:.,,,,,..., -- --w ,,,. .-litititt Awl !:., ..,.. 23 _BG l • .,.., w Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff ,.. (current) 90 5 5 ill Gas Breakdown Gas (units) Chromatograph (ppm) C3 C4 Tot C5 Tot Type 17300 Depth Maximum Average C1 C2 .. to 17600 305 230 27059 1218 430 163 17600 to 17900 280 150 9610 513 198 89 8 BG 17900 to 18100 242 165 13259 621 223 88 3 BG I ::t to to .., to . ....„ a I I I t 0 t 0 t 0 t 0 to tr Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I , BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas ; ... 1g: - 4, M. VW iiiii f :„.c.6.i..A.::. Agit Asiiiir At 24 hr Recap: Drilled ahead from 17301 to 18210'. 5 am - 5 am mud loss = 164 bbls. Midnight to Sam = 34 bbls. 6 bbl loss . i last hour. 1 1 Logging Engineer: Boyd Piercey / Tom Mansfield * 10000 units = 100% Gas In Air ttada .:ca 1 1 _....._ 1 I — 4111"8fr:' '''' tltonier Pi oneer N;tur:Res. --*'" 4111°. Report #: 71 li HALLIBURTON Well: ODSN-40 Date: 07/17/2008-5:00 4 . Area: Oooguruk 05:00 Depth 18364' ..,, I Location: North Slope Progress 24 hrs: 154' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Tripping Out il , ... Job No.: AK-AM-0005710855 Report For: Jim/Gus II Daily Charges $3,540.00 Total Charges $256,507.60 ' 7. ,,1111P 4 ' 1 4.1r.iet . slfirmr ' .9116.. lir natit,16„.. go R 0 P &Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING I , .. ; ) R.O.P. ft/hr 0.0 6.4 88.0 18269 Flow in • em 140 SPP •si 670 11:3(121TaW 295 56 236 18320 Flow Rate s • m 40 Gallons/stroke 3.6 t .ar.A.'Y I Mud Data: . i F Density (ppg) Viscosity HTHP in out (sec/.t YP Elec Stab WPS Lime Cor Solids Depth ft m1/30 min cP (Ib/100ft volt ppm (ppb % 18364 10.2 10.2 75 1.7 40 18 927 326,386 4.66 15.7 li iit Wjjk. IIIIPV '.' .Alik 7.,,,,iiii W. iiir Allilli ' Ailli -tit.. 110 - 17,iiiik 11 /7 Aiiii ' . e Ilk , /.1,. $...4 1000 FMF-3641 rr 6.125 0.589 32.4 16440 1770 10 130 , 900 FMF-3641 6.125 0.589 71.2 12950 16440 3490 10 134 1-1-ER-A-X-I-NO-DTF 4.1CP4..- * it' - Tr r .: +. ' ....,„ '.. W.,,., - .,„, file, ..„ . At ,— - da. - Ali . ,:.- Adi -vw Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff • 11 , (current) 90 5 5 NI i . I I 4 Gas Breakdown 31 Gas (units) Chromatograph (ppm) ... I Depth Maximum Average Cl C2 C3 C4 Tot C5 Tot Type 18100 to 18364 305 230 18945 867 294 115 10 BG to to I to to I to to to to to to I .1 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; 'I ' in BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas : I ' Mit' `7 .10 ' ,iii AtE4 likit; '11211i W Alt Vail mlik t • i 24 hr Recap: Drilled ahead from 18210' MD to well TD of 18364' MD [6160' TVD]. POOH from 18364' MD to 11493' MD while backreaming. Hole appears to be taking proper fill. I Oi • , 1 er, • : Logging Engineer: Boyd Piercey / Danny Kane * 10000 units = 100% Gas In Air 1 NI, -1 Tifit .-:/- v -.; '''''T ali" .11iii Vt" .47 Air' ifilr'''. . ,:$2.'-'4, ' .... aiiiig -114: - ki '' ' 1 1 1 . I Par N'fi"h , Aldailar - - , i::::11sc --„,,,,a , rowl-. . I 7 /1 1 ' ....;.,„ 4 Customer: Pioneer Natural Res. Report #: 72 - ', 1 . HALLIBURTON Well: ODSN-40 Date: 07/18/2008-5:00 ... Area: Oooguruk 05:00 Depth 18364' Location: North Slope Progress 24 hrs: 0' I Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Fishing RIH IA Job No.: AK-AM-0005710855 Report For: Jim/Gus Daily Charges $3,540.00 Total Charges $260,047.60 n„ ,.„ . .... ...4 . . 4': * ' 211/ ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING I R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • sm 0 SPP ssi 0 ,IgErian= 0 72 0 0 Flow Rate ssm 0 Gallons/stroke lii 6 1 43 ' ARUM ' f4T: ' l it' , 4 Willinige. ..... —IMO -;*:;**** hx—: :Jr Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids I Depth ft in out (sec/qt) m1/30 min cP (Ib/100ft volt ppm (ppb) % 18364 10.2 10.2 75 1.8 39 18 911 326,386 4.53 15.7 4 4 , I s ' BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1000 FMF rr 6.125 0.589 32.4 16440 1770 10 130 900 FMF-3641 6.125 0.589 71.2 12950 16440 3490 10 134 1-1-ER-A-X-I-NO-DTF . 7 ' , ''' , 'Var ainift1 - MEV n 4-4, . ' 4106., artiSV 411111r* 1111K-, Alle44.. -. • • Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 90 5 5 . ,.. .1,r ortlaw I Gas Breakdown Gas (units) Chromatograph (ppm) I Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to L... ,;. ,,,, _ to i to I to to to t4 _ I to to to to 11111 __ t'- ti Gas Type a BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas 1 i '5' ..isignki. '.., :IV ad& Mt :Ili Mit MEM III "F•AsPel- .A. ISM. leg i 1 24 hr Recap: Twisted off at 11709' while POOH with —2000' of drill pipe & BHA in hole. POOH to casing shoe and circulate 5 BU. Dry job pumped and continue POOH. Rack back stands and then RIH with fishing assembly to 8992'. I ' Losses for previous 24 hours 16.4 bbls. 1 1 1, i I Logging Engineer: Boyd Piercey / Danny Kane * 10000 units = 100% Gas In Air im I - — 1 1 1 • l ic Lar .-......., - ..,...:Arii:ir''''' e . Customer Pioneer Natural Res. Report # 73 ill 1 HALLIBURTON Well: ODSN -40 Date 07/19/2008 5:00 Area: Oooguruk 05:00 Depth 18364' I Location: North Slope Rig: Nabors 19AC Progress 24 hrs: 0' Sperry Drilling Services Rig Activity: Prep for Casing Pme Job No.: AK -AM- 0005710855 Report For: JR11/Gus Daily Charges $3,540.00 Total Charges $263,587.60 ' : k t+„ ' ° .h $ " 11111 , „It . § Y . fi =, ROP &Gas: Cu Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING 1 - R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in •.m 0 SPP •si 0 0 1 73 0 Flow Rate s• m 0 Gallons /stroke # 3.6 o # . , 4 ,,.; c.:21. F , ..uc tau ; t • f *5' .^ Ytr.l . dh ' �� .- I Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab Lime Cor Solids ry De•th ft in out (sec./•t mI /30 min cP (Ib /100ft volt Ng (ppb) % 18364 10.2 10.2 7.7 1.8 38 17 905 326,778 4.27 15.6 ,_. .:, I tit w BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1000 FMF -3641 rr 6.125 0.589 32.4 16440 1770 10 130 900 FMF -3641 6.125 0.589 71.2 12950 16440 3490 10 3 I t ' 1295 134 1- 1- ER- A- X- I- NO -DTF leak �_ 5 1jelftt., 1101C Lithology ( %): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff _ ; ' current 90 5 5 Viz,: � �” ��ti 1 Gas Breakdown Gas (units) Chromatograph (ppm) I Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 11159' to 73 44 3987 135 38 11 0 TG 10939' to 21 14 1291 29 9 0 0 TG to � 3 I to to to w{ to to to 1 .: to ` as ype abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip Gas ; ",.. . Sy t 1 24 hr Recap: RIH with fishing assembly and tag fish at 9089' with 20 klb downweight and 400 psi SPP increase. Pull 250 klb over & jar at 9089'. POOH to surface w/ partial dry job pumped. Laid down damaged joints. BHA laid down & MWD 1 download from tools. Preparing for casing. Total losses past 24 hours 10 bbls. 1 Logging Engineer: Boyd Piercey / Danny Kane * 10000 units = 100% Gas In Air ' ma x ': . { W F 1 1 1 I ...iere '4 Customer: Pioneer Natural Res. Report #: 74 ie' HALLIBURTON ,:;. Well: ODSN-40 Date: 07/20/2008-5:00 Area: Oooguruk 05:00 Depth 18364' I Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: RIH Liner ..i. Job No.: AK-AM-0005710855 Report For: Rod/Gus I Daily Charges $3,540.00 Total Charges $267,127.60 ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING I R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • • m 0 SPP •si 0 ErriattEMII 0 0 0 0 Flow Rate sem 0 Gallons/stroke _ 3.6 4 1 1 I d i Mud Data: Depth ft Density (ppg) Viscosity HTHP PV YP Elec Stab la Lime Cor Solids 011 in out (sec/et) m1/30 min cP (Ib/100ft volt • • (p.b % r 18364 10.2 10.2 78 1.8 35 19 882 317,220 4.14 15.7 A O ''' w ' Mr Ai"! **11 I 4 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB ' RPM Condition '1 - ,..., 1000 FMF-3641 rr 6.125 0.589 32.4 16440 18364 1924 10 130 900 FMF-3641 6.125 0.589 71.2 12950 16440 3490 10 134 1 ill -•!7,voiow ,, is * Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 90 5 5 ... il l 1 *4 . Gas Breakdown ..*1 Gas (units) Chromatograph (ppm) I 4` Depth to Maximum Average C1 C2 C3 C4 Tot C5 Tot Type to 1. ... to . — 4 1' to to A , to I ii to to .,. ' to to _ A. i I to fa ,. _ Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; VVTG - Wiper Trip Gas; ' BUG Bottoms Up Gas: POG - pumps off gas; TG - Trip I . .,-; hr Recap: RIH w/ 4 1/2" 36 joints completion liner and 23 stands of 4" DP to 3642. Slip & cut drill line and perform rig mainte rig maintenance. RIH w/ 4" DP for a total of 113 stands to 12415'. Start pumping at 72 gpm. f 24 Total losses from 0500-2359 07/19/08 5 bbls. Total losses 0000-0500 07/20/08 4 bbls. 1 "I * Logging Engineer: Boyd Piercey / Danny Kane * 10000 units = 100% Gas In Air ../' 1 1 1 _ _...._ 1 I 1 ,. ,. ' ''''''''" , - ''' - ' . " . ' ` '.1:44" ' s liv • ite! i ' iW ''''' - A ane.: , k - .4"7. 4'. ` r, *111 ' ' ' ''' ' ; . ''' Customer: Pioneer Natural Res. Report #: 75 .0 x HALLIBURTON Well: ODSN-40 Date: 07/21/2008-5:00 Area: Oooguruk 05:00 Depth 18364' I Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: POOH for Tubing Job No.: AK-AM-0005710855 Report For: Rod/Gus Daily Charges $3,540.00 Total Charges $270,667.60 11 ) I * ':'31" Jig lttale; ..faiglikfi-* .‘ jallir'. :: 3 7 1 W ..itir MIMI& 4 Aft/f 144 4-' " , ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING • • R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • • m 0 SPP isi 0 0 0 103 12366 Flow Rate s • m 0 Gallons/stroke 3.6 l i I i Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids in out (sec/qt es Depth ft ml/30 min cP (Ib/100ft volt ppm (ppb) % 18364 18.2 10.2 28 - ; ,... - - - .. - ,,.. 4 : 7 ; 111 1 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1000 FMF-3641 rr 6.125 0.589 32.4 16440 18364 1924 10 130 1-2-ER-A-X-0-NO-TD il 900 FMF-3641 6.125 0.589 71.2 12950 16440 3490 10 134 1-1-ER-A-X-I-NO-DTF I II 4- Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal GvI Tuff : (current) 90 5 ... 5 . r . I Gas Breakdown Gas (units) Chromatograph (ppm) 4 1 1 ., Depth to Maximum Average C1 C2 C3 C4 Tot C5 Tot Type s . _ to s' . to 1 to - 1 to 1 to to to to - I 41 to . t . 94 Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; . .i. 4 . BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas I anti 14211frt iliiihip Mitgr".. A* - ;try! '..11rIt' z, ' ,..t4 : 24 hr Recap: Thought to have set liner and circulate OBM. Ran 3 spacers and displaced OBM with brine. POOH & laid - ' down 4" DP in preparation for RIH production tubing. While POOH realized liner wasn't set. POOH 4 1/2" liner and lay I down for new packer and hanger. After BOP test, prepare to RIH w/ 4 1/2" liner and 4" DP to set. .', Total losses from 0500-2359 07/20/08 5 bbls. Total losses 0000-0500 07/21/08 2 bbls. ... . .... °4 Logging Engineer: Boyd Piercey / Danny Kane * 10000 units = 100% Gas In Air 1 '''' ,.. 1 1 1 I P ' - ' Customer: Pioneer Natural Res. Report #: 76 1 Area: Oooguruk 05:00 Depth 18364' ■ . Location: North Slope Progress 24 hrs: 0' , I , Sperry Drilling Services Rig: Nabors 19AC Rig Activity: ', I ....iio.; Job No.: AK-AM-0005710855 Report For: Rod/Gus Daily Charges $3,540.00 Total Charges $274,207.60 .,, i ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING I A R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • .m 0 SPP •si 0 tq,,k, Mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab 111 Lime Cor Solids I BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition .... s 1000 FMF-3641 rr 6 125 0 589 32.4 16440 18364 1924 10 130 1 F.:' current) 90 5 5 11 Gas Breakdown „, Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type " to 1111 ' to 1 to I to to '411 to • iv - Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; VVTG - Wiper Trip Gas; in .: BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas ', . : 24 hr Recap: Complete BOP Test. RIH w/ 4 1/2" liner. Pick up & make stands DP & stack in derrick. Place packer I , , •• • Total losses from 0500-2359 07/21/08 5 bbls. Total losses 0000-0500 07/22/08 0 bbls. , . Logging Engineer: Boyd Piercey / Danny Kane * 10000 units = 100% Gas In Air :.` 1 .-__-�_____ __ ___ ____-___ '______ _' _ -_ , - Te 1 ~~ 1 • Customer: Pioneer Natural Res. Report #: 77 II HALLIBURTON Well: ODSN-40 Date: 07/23/2008-5:00 ,* Area: Oooguruk 05:00 Depth 18364' I , / Sperry Drilling Services :,,, Location: North Slope Rig: Nabors 19AC Progress 24 hrs: 0' Rig Activity: Prep to RIH Tubing ; Job No.: AK-AM-0005710855 Report For: Rod/Gus I Daily Charges $3,540.00 Total Charges $277,747.60 ' IT " AM' tilir f . al ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING I lik R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • sm 0 SPP •si 0 KETIMMII 0 0 260 12327' Flow Rate s • m 0 Gallons/stroke 3.6 ' Iginii Trlatal" 'MLA. ,....—.. ..' ..AA,...,,.: :4k§a&k'':. _. . ::, - Alia/M, W A I mud Data: Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids , ' Depth ft in out (sec/qt m1/30 min cP lb/100ft volt ppm • .b ok 18364 10.2 10.2 28 - - - - 4.5 I ' BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition 1000 FMF-3641 rr 6.125 0.589 32.4 16440 18364 1924 10 900 FMF-3641 6.125 0.589 71.2 12950 16440 3490 10 130 1-2-ER-A-X-O-NO-TD 134 1-1-ER-A-X-I-NO-DTF 1 1 . Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current 90 5 5 • I ' 4.41 Gas Breakdown Gas (units) Chromatograph (ppm) ...i I Depth Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 12327' to 12327' 260 43 28504 700 321 134 22 TG to to I ' to to _. to LA 1 I I to to to 2,1 to I 1 to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; I BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas III ' ' - Vrfillt -Mit' lillift 'A" Allii* Mliki: ' :) TA Ifit-7. - 717f * '7A... 24 hr Recap: RIH to 12416' w/ 4" DP to set 4 1/2" production liner. Set & release liner. Circulate BU with Trip Gas peak of 260 units. POOH to surface & lay down HWDP & DP. Prepare to RIH 2 7/8" production tubing. I Total losses from 0500-2359 07/22/08 7 bbls. Total losses 0000-0500 07/23/08 2 bbls. s. ..,1 ii I f) Logging Engineer: Boyd Piercey / Danny Kane * 10000 units = 100% Gas In Air 1 1 1 1 I Customer: Pioneer Natural Res. Report #: 78 --A HALLIBURTON Well: ODSN-40 Date: 07/24/2008-5:00 .-.1 Area: Oooguruk 05:00 Depth 18364' 1 Location: North Slope Progress 24 hrs: 0' I il Sperry Chilling Services Rig: Nabors 19AC Rig Activity: Prep for Tubing ' 1 Job No.: AK-AM-0005710855 Report For: Rod/Herb I Daily Charges $3,540.00 Total Charges $281,277.60 ...., LI 4kar 111 lifiii. 'NNW' 41111111r ' aiitilikiwiiit , m,gfr .dmilik,, , agstaidak',.•.,. .- ROP&Gas: Current Avg 24 hr Max Max @ ft Pump & Flow Data: R = ROTATING • R.O.P. ft/hr 0.0 0.0 0.0 0 Flow in • .m 0 SPP •si 0 , IIZEITEEMI 0 0 0 0 Flow Rate s•m 0 Gallons/stroke 3 I Mud Data: De •th ft in out (sec/qt Density (ppg) Viscosity HTHP PV YP Elec Stab WPS Lime Cor Solids m1/30 min cP (Ib/100ft % 2 , volt ppm • eb 18364 10.2 10.2 28 - - - 4.5 791 BHA Run # Bit Type Size TFA Hours Depth in / out Footage WOB RPM Condition . I .:-. 1 000 FMF-3641 rr 6.125 0.589 32.4 16440 18364 1924 10 130 1-2-ER-A-X-O-NO-TD i'l 900 FMF-3641 .,... 6.125 0.589 71.2 12950 16440 3490 10 134 1 - - ER - A - X - I - NO - DTF III Sitk viia 44.4,14 ' '711 ‘ 11 ' . MOW jaft,* n .31iii44 , - .AKt • Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff . current . i .tar; 1 r : Gas Breakdown Gas (units) Chromatograph (ppm) ': I , o Depth to Maximum Average C1 C2 C3 C4 Tot C5 Tot Type 11, to to 1 A to to - 1411 to 11 to - I 1 to :ffl '.." to ..., 3 to ',. to Gas Type abreviations: BG - Background Gas; GP - Gas Peak; CG - Connection Gas; WTG - Wiper Trip Gas; BUG Bottoms Up Gas: POG - Pumps Off Gas; TG - Trip Gas 1 1 I 1 24 hr Recap: Test BOP's. Replaced Annular Preventor & retest BOP. Rig up for Completion Tubing & Downhole Pump. ; I ' Total losses from 0500-2359 07/23/08 0 bbls. Total losses 0000-0500 07/24/08 0 bbls. I IIII Logging Engineer: Boyd Piercey / Danny Kane * 10000 units = 100% Gas In Air 1 A ',1r, Itt slat& -Cr' ' 3IwEv v '''" . islatFare.: 41. 1 1 1 - - - - - I am EN - mu ........ N. - - ow ow HALL I BU RTON WELL NAME: ODSN -40 & 2 Plug Backs LOCATION: Oooguruk OPERATOR: Pioneer Natural Resources AREA: Noth Slope CONTRACTOR: Nabors 19AC STATE: Alaska Sperry Drilling Services BIT RECORD PIONEER % BHA Bit Bit Bit Depth Depth Footage Bit TFA AVG WOB RPM PUMP PUMP Bit Grade Remarks # # Type Size IN OUT Hours ROP Total Press GPM ODSN -40 PB1 1 1 Hughes MXL -1 12.25 153 3420 3267 30.77 0.699 106.2 17 -35 60 -76 1800 650 2- 3- FC- A- E- 1 -NO -TD Clean out 16" Conductor and Drill 121/4" Hole 2 2 Security DBS (FMF -2643) 8.75 3420 8730 5310 40.30 1.178 131.8 5 -25 126 2745 565 1- 1- N- ER- X- I -NO -HP Drill 8 3/4" Section, POOH for loss circulation 3 3 Smith XR-*C 8.75 8730 8730 0 0.00 3.142 0.0 12 40 202 66 0- 1- WT- 0- E -I -NO -BHA Seal loss circulation zone, clean up wellbore. 4 2rr1 Security DBS (FMF -2643) 8.75 8730 8730 0 0.00 1.178 0.0 2 38 448 113 1- 1- ER- N- X- I -NO -HP Wellbore packed off, Loss Circulation, POOH 5 4 Hughes XR20D2TD2G 6.13 8730 8730 0 0.00 2.356 0.0 0 0 0 0 2- 2- WT- A- E -I -NO -BHA Clean hole, swap mud, heal losses, POOH 6 2rr2 Security DBS (FMF -2643) 8.75 8730 8764 34 2.70 0.902 12.6 27 -34 131 2650 500 1- 1- ER- A- X- I -BU -HP Drilling with losses, POOH for plug back 7 5 Security DBS (FMF - 2565z) 8.75 8764 8764 0 0.00 0.000 0.0 0 0 0 0 Run cement stinger & set plugs in loss zone ODSN -40 PB2 8 5rr2 Security DBS (FMF - 2565z) 8.75 5100 9316 4216 85.20 0.863 49.5 20 -35 150 2800 615 1- 1- ER- A- X -I -NO -BHA Sidetrack from ODSN -40PB1 at 5100' 9 5rr1 Security DBS (FMF - 2565z) 8.75 9316 11103 1787 24.86 0.863 72.1 10 -20 150 2800 550 1- 2- BT- N- X- 1 -ER -TD TD intermediate section 10 6 Security DBS (FMF - 3543zz) 6.13 11103 13359 2256 31.90 0.464 70.7 10 -15 115 3325 236 0- 1- BT- C- X -I -NO -DTF TD PB2 for Sidetrack ODSN -40 11 7 Security DBS (FMF -3641) 6.13 12950 16440 3490 71.20 0.589 49.0 10 130 3350 236 0- 1- ER- A- X -I -NO -DTF MWD Failure 12 7rr1 Security DBS (FMF -3641) 6.13 16440 18364 1924 35.35 0.5890 54.5 10 120 3000 200 1- 2- ER- A- X- I -NO -TD TD Production Section M E I IIIII NM I I • IIIIII I IIIIII 111111 • • NM • MO M I IALLIBURTON Casing Record Company: Pioneer Natural Res. Area North Slope, Alaska Sperry Drilling Services Well ODSN -40 ODSN -40 PB1 Job No: AK -AM- 0005710855 16" Conductor Csg @ 153' Water & Oil-based Rig Nabors 19AC ODSN -40 PB2 Spud Date 07 May 2008 9 5/8" Surface Csg @ 3408' Mud Recor•' Mud Co Baroid ODSN -40 TD Date: 16 July 2008 7" Intermediate Csg @ 11066' Water Based Mud 1 Oil Based Mud 4" Production Liner @ 12305' Date Depth Wt Vis PV YP Gels Filt R600 /R300R200 Cake Solids Water Sd Pm pH MBT Pf /Mf Chlor Hard Remarks ft - MD ppg sec lb/100 Ib /100ft2 m /30m R100 /R6 /R3 32nds % % % ppm(k) Ca ++ 07 -May 266 8.90 80 15 45 21/31/- 9.5 75/60/50/41/19/18 2 1.6 96.5 0.10 8.5 0.05/1.00 34.0 800 Drilling 08 -May 1339 9.50 70 19 44 28/32/- 10.0 82/63/54/42/19/17 2 5.2 93.0 2.00 0.10 8.6 8.0 0.05/1.50 34.0 600 Drilling 09 -May 2900 9.30 90 22 46 29/37/- 10.0 90/68/59/47/24/22 2 4.7 _ 93.5 1.00 0.10 8.6 10.0 0.05/1.80 34.0 600 Drilling 10 -May 3412 9.40 50 14 28 19/37/- 10.0 56/42/37/27/14/11 _ 2 5.2 93.0 0.25 0.10 9.0 11.0 0.05/2.20 34.0 600 Tripping 11 -May 3420 9.50 50 14 27 17/34/39 12.2 55/41/36/29/13/11 2 6.2 92.0 0.25 0.10 8.8 10.0 0.05/2.00 34.0 640 Run 9 5/8" casing 12 -May 3420 Switch to OBM, no mud in pits Date Depth Wt Vis PV YP Gels HTHP R600/R300R200 HT Solids NAP Sd Alk Lime WPS ES LGS LGS Remarks ft - MD ppg sec lb/100 lb /100ft` m /30m R100 /R6 /R3 Cake % % % Pom -ml ppb ppm Volts % Vol ppb 13 -May 3420 Switch to OBM no mud in pits 14 -May 3833 9.90 60 23 13 8/11/- 59/36/26/18/6/5 2 10.5 23.5 0.10 OBM mud, Drilling 15 -May 4700 10.50 60 27 12 7/12/- 66/39/30/20/6/5 / 2 9.8 20 0.10 Drilling 16 -May 6926 11.60 66 44 27 12/16/- 3.3 115/71/54/35/12 /10 2 15.3 65 0.10 Drilling 17 -May 8256 12.50 63 37 19 11/16/- 3.0 93/56/46/31/10/09 2 19.3 63.5 0.10 3.80 4.9 287,395 908 5.0 46 Drilling 18 -May 8434 12.00 54 21 14 6/10/- 4.0 56/35/26/16/7/6 2 17.2 70 0.10 2.40 3.1 287,395 780 2.3 21 Drilling 19 -May 8441 12.00 26 26 13 7/9/- 3.0 65/39/29/10/7/5 2 17.3 66 0.10 2.50 3.2 268,458 611 3.5 32 Circulating 20 -May 8730 12.00 66 41 15 9/11/- 3.6 97/56/46/32/9/8 2 17.0 17.3 0.10 3.80 4.9 294,551 600 3.5 32 L/D BHA 21 -May 8730 11.50 62 31 11 6/10/- 3.2 73/42/31/19/5/4 2 14.7 64 0.10 2.20 2.9 254,430 508 2.6 23 Circulating 22 -May 8730 11.50 44 40 11 8/12/- 3.2 91/51/38/23/6/5 _ 2 14.6 64.5 0.10 _ 2.30 3.1 270,895 524 2.3 21 Circulating 23 -May 8730 11.50 85 73 19 10/15/- 3.0 165/92/67/39/8/7 2 14.1 64.5 0.10 2.50 3.2 266,201 445 1.3 11 Waiting LCM Pill 24 -May 8730 11.50 68 72 19 11/16/- 3.4 163/91/68/40/9/7.5 2 14.0 65 _ 0.10 2.50 3.2 271,715 412 1.1 10 Mixing EZ Squeeze LCM Pill 25 -May 8730 11.50 120 38 15 10/15/- 3.4 91/53/40/26/8/7 2 14.0 _ 64 0.10 2.60 3.4 262,085 426 1.1 10 Sqeezing EZ Squeeze Pill 26 -May 8730 11.50 90 41 19 11/14/- 3.6 101/60/45/29/9/8 2 15.0 61 0.10 3.00 3.9 244,455 364 3.4 31 Circulating and conditioning mud 27 -May 8730 11.50 65 43 11 7/12/- 3.4 98/55/39/24/5/4 2 15.0 63 0.10 3.80 4.9 262,085 514 3.2 30 Testing BOPS 28 -May 8730 11.50 88 33 12 7/12/- 3.8 78/45/33/20/6/5 2 14.0 66 _ 0.10 2.80 3.6 282,126 517 1.1 10 Reaming 29 -May 8730 11.50 88 42 14 8/13/- 3.7 98/56/41/26/7/6 2 15.2 65 _ 0.25 3.00 3.9 259,964 574 3.1 28 Lost Circulation 30 -May 8730 11.50 85 41 13 7/11/- 3.5 95/54/38/24/6/5 2 15.4 65 0.25 2.80 3.6 247,209 530 3.3 30 Lost Circulation 31 -May 8730 11.50 Switch to WBM, no mud in pits Date Depth Wt Vis PV YP Gels Filt R600/R300R200 Cake Solids Water Sd Pm pH MBT Pf /Mf Chlor Hard Remarks ft - MD ppg sec lb/100 Ib /100ft` m /30m R100/R6/R3 32nds % % % ppm(k) Ca ++ 02 -Jun 8730 11.50 45 13 15 5/8/- ` 7.4 41/28/22/14/5/4 1 13.3 80 8.0 0.0 0.05/0.80 24.0 1400 Reaming 03 -Jun 8730 11.50 48 20 17 5/6/- 7.4 57/37/29/19/5/4 1 12.3 79 8.0 2.0 -/0.90 25.0 2400 Picking up BHA 04 -Jun 8730 11.50 57 18 23 6/7/- 5.8 59/41/32/22/5/4 1 12.3 79 0.15 8.7 2.0 0.05/2.20 25.0 800 Loss Circulation 05 -Jun 8746 11.00 65 18 16 6/7/- 4.8 52/34/27/17/5/4 1 10.2 84.0 0.20 9.0 0.1/- 24.0 1200 Lost Circulation 06 -Jun 8764 10.00 56 11 23 7/9/- 4.5 45/34/29/22/8/6 1 6.3 90.0 0.05 8.4 2.0 0.01/1.30 22.0 480 Tripping 07 -Jun 8764 10.00 52 11 19 7/9/- 4.3 41/30/25/19/7/6 1 6.2 91.0 0.25 9.7 1.0 0.15/2.00 22.0 840 Plug Back 08 -Jun 8764 9.80 60 14 24 7/8/- 7.0 52/38/31/23/8/6 1 5.3 92.0 _ 4.80 11.0 2.0 0.15/2.85 21.0 1160 Test BOPs 09 -Jun 5117 9.70 52 14 18 6/7/- 7.1 46/32/26/16/7/6 1 4.8 92.0 0.25 1.40 10.2 3.0 0.30/3.90 27.0 420 Kick off drilling sidetrack 10 -Jun 5193 9.70 46 16 26 6/8/- 5.8 58/42/35/26/8/7 1 5.8 93.0 0.25 0.75 10.1 5.0 0.35/2.65 18.0 26 Drilling 11 -Jun 6470 9.70 49 20 21 7/8/- 5.4 61/41/34/25/8/6 1 5.5 92.0 0.25 0.40 10.1 8.0 0.25/3.40 19.0 360 Drilling 12 -Jun 7362 9.70 54 23 30 12/4/- 5.2 76/53/43/32/13/11 2 6.4 90.0 0.25 0.20 10.0 11.0 0.15/2.00 20.0 220 circ and cond mud 13 -Jun 8463 9.70 57 14 32 13/25/- 4.3 60/46/40/31/14/13 1 6.4 90.0 0.25 0.02 9.2 9.5 0.10/2.60 20.0 320 Short trip I • • • • • • • • • • • i - • • • • • • 1ALLIBURTDN Company: Pioneer Natural Res. Area North Slope, Alaska Casing Record Sperry Drilling Services Well ODSN -40 ODSN -40 PB1 Job No: AK -AM- 0005710855 16" Conductor Csg @ 153' Water & Oil-based Rig Nabors 19AC ODSN -40 PB2 Spud Date 07 May 2008 9 5/8" Surface Csg @ 3408' Mud Record Mud Co Baroid ODSN -40 TD Date: 16 July 2008 7" Intermediate Csg @ 11066' Water Based Mud Oil Based Mud 4" Production Liner @ 12305' Date Depth Wt Vis PV YP Gels Filt R600/R300R200 Cake Solids Water Sd Pm pH MBT Pf /Mf Chlor Hard Remarks ft - MD ppg sec lb/100 Ib /100ft2 m /30m R100/R6/R3 32nds % % % ppm(k) Ca ++ 14 -Jun 8990 9.60 58 15 28 10/17/- 4.8 58/43/36/27/9/8 1 5.9 90.0 _ 0.25 0.10 9.3 8.5 2.40/- 20.0 240 Drilling 15 -Jun 9316 9.70 55 13 23 17/23/- 6.4 49/36/31/23/13/12 2 6.8 90.0 0.15 9.0 10.0 0.15/1.65 15.0 320 POOH 16 -Jun 9316 9.70 63 16 23 18/25/- 6.6 55/39/31/22/13/12 2 6.9 89.5 0.25 11.0 9.0 0.30/3.30 20.0 160 Tripping In 17 -Jun 9594 11.00 49 22 27 9/11/- 6.2 71/49/39/28/7/6 2 11.6 85.0 0.30 9.1 6.0 0.10/0.90 19.0 680 Drilling 18 -Jun 10453 11.10 50 28 30 12/16/- 5.2 86/58/47/33/10/8 1 13.1 81.5 0.40 9.0 8.0 0.10/1.50 20.0 320 Tripping 19 -Jun 10607 11.50 60 38 31 13/17/- 4.6 107/69/54/37/11 /9 2 15.7 79.0 0.50 9.9 8.0 0.30/1.90 19.0 180 Drilling 20 -Jun 11100 11.50 51 20 27 8/14/- 5.8 67/47/39/28/8/6 2 14.8 81 0.20 _ 9.2 8.0 -/0.5 16.0 320 Tripping 21 -Jun 11103 11.50 55 21 26 8/11/- 3.2 75/51/42/30/9/7 2 16.9 79 0.40 8.5 8.0 0.05/0.70 15.0 240 tripping 22 -Jun 11103 11.50 50 16 23 6/14/- 5.8 55/39/31/22/6/5 1 14.8 81 0.05 8.8 6.0 -/.90 16.0 560 Tripping 23 -Jun 11103 11.5 51 17 18 6/22/- 5.2 52/35/28/19/5/4 2 14.8 81 _ 0.2 8.6 6.0 .05/.9 16 520 Tripping 24 -Jun 11103 11.5 52 18 19 7/22/- 5.1 55/37/30/20/6/5 2 14.7 79 0.1 9.2 6.0 .05/.9 19 520 Tripping 25 -Jun 11103 11.5 51 19 18 6/20/- 5.2 56/37/30/20/6/5 1 13.7 80 0.1 10 6.0 .10/.90 18 320 Run 7" Casing 26 -Jun 11103 11.5 52 20 18 6/19/- 5.2 59/38/30/21/5/4 2/- 13.7 80 0.05 8.7 6.0 /0.90 18 320 Run & Cmt 7" Csg 27 -Jun 11103 Switch to OBM, no mud in pits Date Depth Wt Vis PV YP Gels HTHP R600 /R300R200 HT Solids NAP Sd AIk Lime WPS ES LGS LGS Remarks ft - MD ppg sec lb/100 Ib /100ft2 m /30m R100 /R6 /R3 Cake % % % Pom -mi ppb ppm Volts % Vol ppb 29 -Jun 11103 10.40 83 25 15 8/12/- 2.0 65/40/32/22/8/7 - /1 17.3 57/23 2.90 3.8 283,935 375 17.5/ -.2 159.4/ -3.1 RIH 30 -Jun 11253 10.40 93 40 16 8/11/- 2.5 96/56/42/36/8/6 -/1 15.3 60/22 8.00 10.4 307,872 268 13.7/1.6 125/23.6 Drilling 01 -Jul 11991 10.40 86 38 14 9/12/- 1.3 90/52/39/25/8/7 _ 41 16.0 57/24 0.40 5.00 6.5 306,793 428 15.6/.4 142.4/5.2 Drilling 02 -Jul 12474 10.30 78 38 13 6/9/- 1.5 89/51/37/21/5/4 -/1 15.1 58/24 0.25 4.20 5.4 299,044 624 14.3/0.8 130.3/11.43 Mad Pass 03 -Jul 13053 10.20 78 44 16 7/11/- 1.5 104/60/44/26/6/5 -/1 14.8 58/24 0.25 4.70 6.1 314,804 592 14.9/0.0 135.4/ -0.64 Drilling 04 -J ` 13359 10.20 80 39 15 8/12/- 1.5 93/54/39/23/7/6 -/1 15.2 58/24 0.20 5.00 6.5 298,141 690 15.3/ -0.1 139.6/ -1.90 Tripping 05 -J 13359 10.20 98 39 15 8/12/- 1.5 93/54/39/23/7/6 -/1 15.2 58/24 5.00 6.5 298,141 653 15.3/ -0.1 139.6/ -1.90 Test BOPE -J' 12950 10.20 105 44 16 8/12/- 1.5 104/60/45/27/8/6 -/1 15.1 58/24 I 8 5.00 6.5 298,743 693 15.1/0.0 137.9/ - 0.36 Sidetrack -J 13100 10.20 86 43 15 8/11/- 1.5 101/58/43/27/8/7 -/1 15.0 58/24 3.20 4.1 299,644 693 14.9/0.1 135.5/1.92 Drilling -J 14100 10.20 87 44 17 9/13/- 2.0 105/61/46/30/9/8 -/1 15.1 62/20 4.60 6.0 337,315 731 14.8/0.4 134.73/5.25 Drilling -J 15101 10.20 75 29 15 8/12/- 1.4 73/44/33/22/8/7 -/1 16.2 65/16 4.80 6.2 376,241 787 16.3/ -0.1 148.32 -1.31 Drilling -J 15942 10.20 75 30 13 8/12/- 1.4 73/43/33/21/7/6 -/1 15.3 64/18 0.10 3.70 4.8 343,066 860 14.6/0.7 133.27/10.56 Drilling 1 -J 16440 10.20 75 37 17 8/13/- 1.5 91/54/42/27/9/8 -/1 16.6 65/16 0.10 2.30 3.0 345,308 809 16.5/0 150.36/91 Tripping -J 16440 10.20 78 40 18 10/14/- 1.4 98/58/44/29/9/8 -/1 14.4 65/18 0.10 3.70 4.8 333,759 883 12.6/1.9 114.51/27.72 Tripping, Test BOP -J 16440 10.20 78 40 18 10/14/- 1.5 98/58/43/27/9/7 -/1 16.6 65/16 0.10 3.50 4.5 349,903 847 16.6/ -.1 151.45/-79 RIH -J 17054 10.20 75 35 17 11/16/- 1.6 87/52/40/27/10.5 /9 -/1 16.5 66/15 0.10 3.60 4.7 364,722 821 16.4/0.1 149.85/1.37 Drilling -J 17900 10.20 75 31 16 10/15/- 1.7 78/47/37/26/10/8.5 -/1 16.6 67/14 0.10 3.20 4.1 370,003 783 16. 3/0.3 14898/417 Drilling -J 18364 10.20 75 40 18 10/15/- 1.7 98/58/43/27/9/7 -/1 15.7 65/17 0.10 _ 3.60 4.7 326,386 927 14.7/1.0 13367/1479 TD, POOH 7 -J 18364 10.20 75 39 18 10/15/- 1.8 96/57/44/29/10/8 -/1 15.7 65/17 0.10 3.50 4.5 326,386 911 14.7/1.0 13367/14.79 POOH, Fishing J 18364 10.20 77 38 17 10/15/- 1.8 93/44/43/28/9/8 /1 15.6 65/17 0.10 3.30 4.3 326,778 905 14.6/1. 13287/15.55 Fishing 19 -J 18364 10.20 78 35 19 11/15/- 1.8 89/54/42/29/10/9 -/1 _ 15.7 65/17 0.10 3.20 4.1 317,220 882 14.5/1.2 13231/1735 Running Completion Liner 20 -J 18364 10.20 28 - - - - - - 4.7 -/87 - - - - - 4.6/0.0 41.6/0.72 POOH 21 -J 18364 10.20 28 - - - - - - 4.5 -/87 - - - - - 4.6/0.1 41.6/0.73 Running Completion Liner 22 -J 18364 10.20 28 - - - - - - 4.5 -/87 - - - - - 4.6/0.0 41.6/0.72 POOH 23 -J 18364 10.20 28 - - - - - - 4.5 -/87 - - - - - 4.6/0.0 41.6/0.72 Rigging Up Completion Equi • 24 -J . 18364 I 1 1111011 sperry-sun Well Name: ODSN 40 Depth (MD) 9362 to 11100 ft Location: North Slope, Alaska (TVD) 5734 to 6203 ft I DRILLING SERVICES Operator: Pioneer Natural Resources Show Report No Date/Time Report Prepared By: B. Piercey / S. Mircovich Show Report 1 : 21-Jun-08 111 Report Delivered To John Pruitt I MIN Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. 11111111 Sandstone: It brn, gy, wh, clr, f - m - c gr, prly srtd, ang - sb ang, rd - sb rd, pred lose grs, v fri, pred qtz, dll yel for inst pale yel cut. gal Pixler plot indicates a gas zone but since the analysis was from possum belly rather than steam still. This ratio plot can be interpreted I as a good oil zone. I.e. steam still analysis would move ratios lower indicationg oil. . .„,,,,,:.:::,:::::::::::::::::::::::::::::::::::::::.,-„,::::::::::::::::::::::::::::::::.:::::.:.:.:::::::::::„:,::::::::::::::::::::::::.:::::.:,:.„ „::::::::::::::::::::::,,..:0.:::.:.:.:::-..:::::::::::::::::::::.:::::::-.,,,,,,, "."""""". - ...... ....• - 11111111 1 % Hydrocarbon Ratios Depth 9362 ft Gas Units 2228 Mud Chlorides (1000's) , Cl Cl Cl Cl Plowiine Background thow C2 C3 C4 C5 PPm ppm ppm Hydrocarbon Ratios 1000 Cl 213454 - = 213454 C1/C2 = 25 I MIN C2 8604 - = 8604 c1iC3 = 80 1:11111: C3 2654 - = 2654 C1/C4 = 243 IIIIIIII C4 879 - = 879 C1/C5 = 818 NPH 11111111 C5 261 - = 261 - - • - I 11111111 Producnon 100 - _.... -- - - IIIIIII Analysis nGas rxiOil nWater n Non-Producible Hydrocarbons .... - - ...- .... 2 I loll Depth 9983 ft Gas ['Units 1650 Mud Chlorides (1000's) , G Flowline Background t how - - PPm ppm ppm -------- - Hydrocarbon Ratios 10 - Nil C1 167271 - = 167271 C1/C2 = 25 I Milli C2 6663 - = 6663 C1/C3 = 77 .. lilliiii C3 2178 - = 2178 C1/C4 = 202 ON pp! C4 827 - = 827 C1/C5 = 547 - - • • 1 11111111 C5 306 - = 306 NP -I 1 11111111 Production 11111111 Analysis fl Gas I51( Oil nWater nNonProducible Hydrocarbons 3 4 Hydrocarbon Ratios I NE 1 Depth 10212 ft Gas H 1042 Mud Chlorides (1000's) , Cl Cl Cl Cl Flowline Background t how C2 C3 C4 C5 PPm PPm PPm il Hydrocarbon Ratios ii 1000.0 II 11111111 Cl 96553 - = 96553 C1/C2 = 17 :1 II 11111111 C2 5583 - = 5583 C1/C3 = 42 11111111 C3 2304 - = 2304 C1/C4 = 92 NPH NO C4 1044 - = 1044 C1/C5 = 241 I 11111111 CS 400 - = 400 — , 11111111 Production 100.0 -- .... ,..._,..e ••• '... ii, • Analysis II Gas 51 Oil I Water U .... - .... - - CI 1% I sio Depth 11100 ft Gas 1 Units 1432 Mud Chlorides (1000's) , Gas Flowline Background t how ,-.----- ..... - ..., -------- PPm PPm PPm Hydrocarbon Ratios 10.0 I 11111111 Cl 72552 - = 72552 C1/C2 = 20 1 C2 3717 - = 3717 C1/C3 = 41 Oil 111 C3 1775 - = 1775 C1/C4 = 79 11111111 C4 924 - = 924 C1/C5 = 177 I 111111 C5 410 - = 410 NPH 1 1.0 1 Rill! Production llnil Analysis n Gas [Oil Water riNon-Producible Hydrocarbons I "1"1"1"11111"11"111111"""1.11"MIIIII•11"'":"1"1111"1""1111111111"11""M"1"1"°"11""M""""""""ii"111"1"1"1"111"1""""""11"1"11""n""""1"111"1".. I ■ I sperry -sun Well Name: ODSN -40 Depth (MD) 11414 to 12200 ft Location: North Slope, Alaska (TVD) 6283 to 6232 ft iiii DRILLING SERVICES Operator Pioneer Natural Resources Show Report No 2 ' Show Report Report Prepared By B. Piercey / D. Kane Date/Time: 02- Jul -08 Report Delivered To John Pruitt 1 Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Sandstone: clr -trsp, bf -It gry, of -f gr, occ m gr, sb rd -rd, m -w srt, v fri pred Ise grs, occ mud additive, occ cmt cvgs. Show & flourescence masked by oil -based mud. 3 II I % Hydrocarbon Ratios Depth 11414 ft Gas © Units 438 Mud Chlorides (1000's) C1 C1 C1 C1 RI I Flowline Background Show C2 C3 C4 C5 PPm ppm ppm Hydrocarbon Ratios 1000 C1 23624 - = 23624 C1 /C2 = 27 I C 2 869 - = 869 C1 /C3 = 75 316 - = 316 C1 /C4 = 200 C4 118 - = 118 C1 /C5 = 2953 NPH r C5 8 - = 8 .. • ' i Production 100 — ��-' Analysis I Gas © Oil I Water 'Non-Producible Hydrocarbons _ © I% Depth 11585 ft Gas © Units 290 Mud Chlorides (1000's) : G _ I __ - - - - Fl owline Background how '' ppm PPm PPm _ ____" -- i Hydrocarbon Ratios 10 `I C1 17250 # = 17250 C1 /C2 = 27 I f C2 648 - = 648 C1 /C3 = 69 1 , , ,,, C3 249 - 249 C1 /C4 = 171 Oil — . C4 101 - = 101 C1 /C5 = 2464 — — — — C5 7 - = 7 NP -I I . 1 L Production h. Analysis I Gas © Oil I Water I Non - Producible Hydrocarbons eK, © 1% Hydrocarbon Ratios I 11111111 Depth 11615 ft Gas I Units 303 Mud Chlorides (1000's) : C1 C1 C1 Cl Flowline Background $how C2 C3 C4 C5 ppm PPm PPm Hydrocarbon Ratios 1000.0 I !` c1 11114 - = 11114 C1 /C2 = 30 C2 369 - = 369 C1 /C3 = 77 `:. C3 145 - = 145 C1 /C4 = 176 NPH III C4 63 - = 63 C1 /C5 = 3705 C5 3 - = 3 Mil Production 100.0 — Hi Analysis II Gas © Oil II Water II Non - Producible Hydrocarbons _ + _ /� mill 1% / I Depth 11997 ft Gas © Units 395 Mud Chlorides (1000 s) Gas — — Flowline Background $how PPm ppm PPm -------- Hydrocarbon Ratios 10.0 I 11111111 C1 43048 - = 43048 C1 /C2 = 32 C2 1334 - 1334 C1 /C3 = 100 Oil NE C3 431 - = 431 C1 /C4 = 283 — — — — I ii C4 152 - = 152 C1 /C5 = 1304 NPH ME C5 33 33 NH Production 1.0 Ili Analysis U Gas © Oil . Water . Non - Producible Hydrocarbons I i,. I sperry-sun Well Name: ODSN-40 Depth (MD) 14305 to 15300 ft Location: North Slope, Alaska (TVD) 6169 to 6124 ft 1 1 DRILLING SERVICES Operator Pioneer Natural Resources Show Report No. 3 MIMI Show Report Report Prepared By B. Piercey / D. Kane Date/Time: 10-Jul-08 Report Delivered To John Pruitt I Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Sandstone: clr-trnsl, sme It brn, vf-f gr, occ m gr, IMIM sb ang-sb rnd, m-w sad, v fri, pred Ise qtz gr, tr cht, tr calc cmt, occ brn o stn. Show & flourescence masked by oil-based mud. M!Mi Pixler plot indicates a gas zone but since the analysis was from possum belly rather than steam still. This ratio plot can be interpreted I as a good oil zone. I.e. steam still analysis would move ratio's lower indicationg oil. 1011 _ % Hydrocarbon Ratios milib Depth 14305 ft Gas x Units 486 Mud Chlorides (1000's) Cl Cl Cl Cl I iiiiiiii Flowline Background Show P C2 C3 C4 C5 Pm ppm ppm Hydrocarbon Ratios 1000 MO Cl 44200 - = 44200 C1/C2 = 33 I IN C2 1360 - = 1360 C1/C3 = 100 AIN C3 444 - = 444 C1/C4 = 275 ppg C4 161 - = 161 C1/C5 = 1637 NPH IM C5 27 - = 27 ..- ■• -" --' I 11111111 Production 100 - .... ... .... --- ''''' NH Analysis nGas Fl: Oil nWater nNon-Producible Hydrocarbons -- -- IMIM 21 % i 111 Depth 14590 ft Gas HUnits 1053 Mud Chlorides (1000's) . Ga Flowline Background Show . - PPm ppm PPm - - - - - - - - - - - Hydrocarbon Ratios 10 :::11111 Cl 100828 # = 100828 C1/C2 = 43 I NM C2 2325 - = 2325 C1/C3 = 155 11111::: C3 650 - = 650 C1/C4 = 444 Oil 1111:1:1 C4 227 - = 227 C1/C5 = 2192 - • _.._ I MI C5 46 - = 46 NPH 11111111 Production 1 HE Analysis nGas MOH nWater {Non -Producible Hydrocarbons IMM 21 - °/0 Hydrocarbon Ratios I in Depth 14600 ft Gas _ Units 931 Mud Chlorides (1000's) Cl Cl Cl Cl Flowline Background Show C2 C3 C4 C5 PPm ppm ppm Hydrocarbon Ratios 1000.0 II ci 65785 - = 65785 C1/C2 = 32 gli C2 2071 - = 2071 C1/C3 = 99 111.:11!! C3 665 - = 665 C1/C4 = 290 NPH 111,1 C4 227 - = 227 C1/C5 = 1316 I Hp C5 50 - = 50 ... ...- -- Production 100.0 NH Analysis nGas MOO nWater 171 _. ..- -- II 11111111 4 Depth 14880 ft Gas Units 976 Mud Chlorides (1000's) Gas Flowline Background Show _ _. - - ----- - — PPm PPm PPm -- Hydrocarbon Ratios 10.0 C1/C2 = 34 II 1110 Cl 98142 - = 98142 III C2 2846 - = 2846 C1/C3 = 111 Oil I 1111 C3 888 - = 888 C1/C4 = 310 ..li I 11!!!!!! C4 317 - = 317 C1/C5 = 1722 NPH 1!111111 C5 57 - = 57 u ..,. HIM Production 1.0 1M1M Analysis nGas Moil nWater ri Non-Producible Hydrocarbons I ' I =II I p (MD) _ .< >...... to _ _ <.. 16400 ft ogil sperry-sun Well Name: ODSN -40 Depth INI Location: North Slope, Alaska (TVD) 6139 to 6152 ft DRILLING SERVICES Operator: Pioneer Natural Resources Show Report No. 4 I Show Report Report Prepared By B. Piercey / D. Kane Date/Time: 12- Jul -08 Report Delivered To John Pruitt I d Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Sandstone: clr- trnsl, It -m brn, vf-f gr, occ m gr, ig! sb ang -sb rnd, m-w srtd, v fri, pred Ise qtz gr, occ carb specks, tr calc cmt, brn o stn ip. Show & floursences masked by oil-based mud. Pixler plot indicates a gas zone but since the analysis was from possum belly rather than steam still. This ratio plot can be interpreted as a good oil zone. I.e steam still analysis would move ratios lower indicationg oil. 11 % Hydrocarbon Ratios i.: Depth 16150 ft Gas Units 448 Mud Chlorides (1000's) C1 C1 C1 C1 I Flowline Background Show ppm ppm ppm C2 C3 C4 C5 Hydrocarbon Ratios 1000 Cl 1 37893 - = 37893 C1 /C2 = 27 C2 1428 = 1428 C1 /C3 = 81 C3 465 465 C1 /C4 = 217 C4 175 - = 175 C1 /C5 = 924 NPH C5 41 - = 41 Production 100 — — — — _ �" -- Analysis nGas Oil nWater nNOn- Producible Hydrocarbons i 2 Hunits Depth 16290 ft Gas 325 Mud Chlorides (1000's) G l Flowline Background Show !ii ppm ppm ppm -------------- l Hydrocarbon Ratios 10 E C1 29260 # = 29260 C1 /C2 = 27 I Il C2 1103 - = 1103 C1 /C3 = 78 C3 376 376 C1 /C4 = 196 ON i C4 149 - = 149 C1 /C5 = 697 I C5 42 = 42 NP -I I Production 1 Analysis nGas [Oil nWater [Non- Producible Hydrocarbons 3 % Hydrocarbon Ratios Depth 16440 ft Gas Units 290 Mud Chlorides (1000's) Cl C1 C1 C1 Flowline Background Show C2 C3 C4 C5 ppm PPm PPm Hydrocarbon Ratios 1000.0 III '. C1 32323 - = 32323 C1 /C2 = 29 C2 1099 1099 C1 /C3 = 100 C3 322 - = 322 C1 /C4 = 385 NPH : C4 84 - = 84 C1 /C5 = 10774 I I C5 3 - = 3 — -- Production 100.0 li th Analysis nGas Fla_ nWater [ — — — — ill' El R _ Gas -- _ —_— Depth 16480 ft Gas x Units 315 Mud Chlorides (1000's) H Flowline Background Show PPm PPm PPm — — — — — Hydrocarbon Ratios 10.0 I 1111 1 C1 32240 - = 32240 C1 /C2 = 29 C2 1100 1100 C1 /C3 = 103 Oil Illil C3 314 - = 314 C1 /C4 = 366 — C4 88 - = 88 C1 /C5 = 10747 — — — ( I C5 3 - = 3 NPH Production 1.0 Ii :liii Analysis nGas [Oil Water n Non - Producible Hydrocarbons , " ,E E E r i N� e:% r I I ........ 7 , sperry -sun Well Name: ODSN -40 Depth (MD) 16540 to 17250 ft Location: North Slope, Alaska (TVD) 6162 to 6164 ft DRILLING SERVICES Operator: Pioneer Natural Resources Show Report No. 5 II li I Show Report Report Prepared By: B. Piercey / D. Kane Date/Time: 15- Jul -08 li Report Delivered To: John Pruitt ' . e - ... I Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Sandstone: clr- trnsl, It -m brn, pred of -f gr, sb ang -w md, m -w srtd, v fri, pred Ise qtz gr, tr carb specks, tr calc cmt, brn o stn ip. Show & flourescence masked by oil -based mud. Pixler plot indicates a gas zone but since the analysis was from possum belly rather than steam still. This ratio plot can be interpreted d I as a good oil zone. I.e. steam still analysis would move ratio's lower indicationg oil. 11 1 % Hydrocarbon Ratios Depth 16540 ft Gas © Units 191 Mud Chlorides (1000's) C1 C1 C1 Cl ii I Flowline Background Show C2 C3 C4 C5 PPm ppm PPm Hydrocarbon Ratios 1000 — ''a; C1 9103 - = 91 C1 /C2 = 18 I C2 503 503 C1 /C3 = 51 C3 178 178 C1 /C4 = 144 . C4 63 - = 63 C1 /C5 = 9103 NPH C5 1 - = 1 -.- - - I Production 100 — — _ Analysis I Gas © Oil I Water I Non - Producible Hydrocarbons _ _ © 1% Depth 16800 ft Gas © Units 373 Mud Chlorides (1000's) G Flowline Background Show PPm ppm ppm Hydrocarbon Ratios 10 — C1 31973 # = 31973 C1 /C2 = 25 I C2 1272 = 1272 C1 /C3 = 80 C3 400 400 C1 /C4 = 239 ON C4 134 - = 134 C1 /C5 = 7993 — — • C5 4 - = 4 NP 1 Production Analysis I Gas ©Oil I Water II Non-Producible Hydrocarbons © • % Hydrocarbon Ratios I Depth 17000 ft Gas ' Units 445 Mud Chlorides (1000's) C1 C1 C1 Cl Flowline Background Show C2 C3 C4 C5 ppm ppm ppm Hydrocarbon Ratios 1000.0 I Cl 34936 = 34936 C1 /C2 = 24 j C2 1474 1474 C1 /C3 = 71 C3 489 - = 489 C1 /C4 = 197 NPH C4 177 - = 177 C1 /C5 = 1028 I . C5 34 - = 34 -. — — Production 100.0 — — Analysis I Gas © Oil . Water © — — — 0 - ,% I Depth 17250 ft Gas © ` Units 453 Mud Chlorides (1000's) Gas — — — - — — Flowline Background Show PPm ppm ppm — — — — — — — Hydrocarbon Ratios 10.0 I [ C1 26345 - = 26345 C1 /C2 = 21 C2 1228 1228 C1 /C3 = 60 Oil C3 442 - = 442 C1 /C4 = 164 I C4 161 = 161 C1 /C5 = 850 — C5 31 31 NPH Production 1.0 I Analysis U Gas © Oil I Water I Non - Producible Hydrocarbons I NE am ! err En i mu ow Er = = ow ►# on gni I I NO MN PIONEER NATURAL RESOURCES ODSN -40 FORMATION NOMENCLATURE /TOPS - FINAL ANCHORAGE PICKS Tops Prog from WOPR MD 1 INC 1 AZ 1 TVD TVDSS TVD 1 TVDSS +/- to PROG TVD I Comment Base of Permafrost 1548.0 21.7 150.0 1528.8 1471.3 NA Top West Sak 2384.5 34.6 172.3 2282.6 2225.1 1607.5 1,550.0 675 Hue Shale 3108.0 49.1 186.7 2817.4 2759.9 2345.5 2,288.0 472 Tuffaceous Shale 3258.5 53.6 188.7 2911.5 2854.0 2891.4 2,833.9 20 SCP 3409.8 55.2 191.6 2998.5 2941.0 2944.1 2,886.6 54 Sidetrack ODSN -40 ST -1 5100.0 54.6 223.6 3990.5 3933.0 Brook 2B 5591.0 64.2 221.0 4244.6 4187.1 4178.6 4,121.1 66 Tagged TOC plug #2 7647.0 69.5 224.5 4959.4 4901.9 Torok Top 7917.0 69.7 226.7 5053.6 4996.1 5048.5 4,991.0 5 Fault #1 -10' DTNE 8100.0 69.6 225.7 5117.0 5059.5 Fault #2 -15 DTNE 8188.0 70.0 224.2 5147.5 5090.0 Fault #3 -10 DTNE 8271.0 69.8 223.2 5175.8 5118.3 Torok Base 8504.0 69.8 223.3 5257.5 5200.0 5287.7 5,230.2 -30 Fault #4 -3.5 DTNE 8640.0 69.2 227.2 5305.1 5247.6 Fault #5 -20 DTNE 8674.0 69.2 228.4 5317.2 5259.7 TD 8764.0 69.3 230.4 5349.0 5291.5 KOP ODSN -40 PB -1 KOP #1 5100.0 1 54.6 1 223.6 1 3990.5 1 3933.0 Prog from wp14 Brook 2B 5552.0 61.0 224.0 4247.5 4190.0 4178.5 4,121.0 69 Torok Top 7480.0 64.7 226.1 5061.8 5004.3 5048.5 4,991.0 13 Torok Base 7985.0 64.1 226.0 5281.8 5224.3 5287.5 5,230.0 -6 Fault/Fracture #1 8585.0 72.7 227.3 5494.3 5436.8 probably no offset Top HRZ 9317.0 72.4 252.4 5720.2 5662.7 5719.5 5,662.0 0.7 Base HRZ 9722.0 72.1 267.5 5844.2 5786.7 5846.5 5,789.0 -2.3 Kalubik Marker 9980.0 72.5 276.3 5922.3 5864.8 5947.5 5,890.0 -25.2 Top Kup C 10196.0 73.1 283.3 5986.3 5928.8 6015.5 5,958.0 -29.2 LCU 10229.0 73.1 284.6 5995.9 5938.4 6021.5 5,964.0 -25.6 BCU 10828.0 75.5 299.5 6159.2 6101.7 NA NA NA 4 1 /2- inchLiner Hanger (slotted) 10937.6 75.4 300.6 6186.7 6129.2 Top Nuiqsut 11020.0 75.3 303.3 6207.6 6150.1 6209.5 6,152.0 -1.9 ICP 11066.5 75.3 305.3 6219.4 6161.9 6210.5 6,153.0 8.9 Nuiq_2 11350.0 82.1 304.4 6275.0 6217.5 App Dip 2.5° DTNW Fault #2 in Zone 2 (1' DTSE) 11350.0 82.1 304.4 6275.0 6217.5 in Zone 2 (1' DTSE) D1 to U1 Symmetry Plane 11425.0 85.4 306.2 6283.5 6226.0 ,Nuiq_2_U1_Upthrown 11517.0 87.3 309.3 6288.1 6230.6 Invert D1 to U1 11572.5 , 90.0 311.7 6289.6 6232.1 Top of solid liner 11578.4 90.4 311.8 6289.6 6232.1 Fault #3 Lower Zone 1 to Nechelik 11603.0 92.2 312.5 6289.0 6231.5 110' DTSE Nechelik_U1 12042.0 96.3 314.3 6249.1 6191.6 App Dip 1.4° DTNW Nuiq_Base_U1 12151.0 95.7 313.3 6237.6 6180.1 App Dip 0.9° DTNE Bottom of solid liner 12290.0 96.2 312.3 6222.4 6164.9 Bottom of slotted liner 12416.0 96.6 312.6 6209.1 6151.6 Nuiq_5_U1 12501.0 96.2 312.0 6199.3 6141.8 App Dip 1.7° DTNW Nuiq_4_U1 12563.0 96.4 312.0 6192.7 6135.2 Nuiq_3_U1 12651.0 97.4 312.7 6181.9 6124.4 App Dip 1.2° DTSE Nuiq_2_U1 12698.0 97.0 313.0 6175.9 6118.4 ODSN -40 PB -2 KOP #2 1 12950.0 95.2 1 313.7 1 6155.9 1 6098.4 1 I U1 to D2 Symmetry Plane 13100.0 91.2 314.3 6150.1 6092.6 Revert U1 to D2 13143.0 90.0 314.3 6149.6 6092.1 Nuiq_2_D2 13418.0 85.1 315.0 6167.5 6110.0 Nuiq_3_D2 13481.0 85.9 316.3 6172.5 6115.0 App Dip 0.7° DTSE Nuiq_4_D2 13596.0 85.7 317.4 6180.6 6123.1 Nuiq_5_D2 13691.0 87.6 317.2 6186.1 6128.6 Invert D2 to U2 14069.0 90.0 322.6 6205.5 6148.0 D2 to U2 Symmetry Plane 14150.0 92.1 322.9 6204.0 6146.5 Nuiq_5_U2 14501.0 96.4 317.3 6175.3 6117.8 App Dip 0.8° DTSE Nuiq_4_U2 14559.0 96.1 317.2 6169.0 6111.5 Nuiq_3_U2 14654.0 97.5 315.1 6157.8 6100.3 App Dip 0.7° DTSE Nuiq_2_U2 14699.0 96.9 314.5 6152.1 6094.6 U2 to D3 Symmetry Plane 15425.0 90.3 315.0 6124.1 6066.6 Revert U2 to D3 15697.0 90.0 313.6 6123.1 6065.6 Nuiq_2_D3 16294.0 87.5 317.2 6146.9 6089.4 App Dip 0.2° DTSE Nuiq_3_D3 16361.0 86.9 317.1 6150.1 6092.6 Nuiq_4_D3 16508.0 85.6 317.4 6160.1 6102.6 App Dip 0.3° DTSE Nuiq_5_D3 16566.0 86.4 317.0 6164.1 6106.6 D3 to U3 Symmetry Plane 16760.0 90.0 317.6 6169.2 6111.7 Invert D3 to U3 17739.0 90.0 317.3 6166.1 6108.6 TD 18364.0 91.4 319.7 6160.4 6102.9 6306.1 6,248.6 -145.7 Proj. Bottom Zone4 /Top Zone 5 -5 18493.0 91.4 319.7 6157.2 6099.7 ' HALLIBURTON End of Well Report for Pioneer Natural Resources, AK Rig : Nabors 19AC Well : ODSN -40PB1 Field : Oooguruk Country : U.S.A. ' Job Number : AK -MW- 0005710855 Date : 07- May -08 API Number : 50- 703 - 20571 -70 I r I I 1 Sperry Drilling Services 1 I HALLIBURTON Sperry Drilling Services 1 Directional Survey Data 0.00 0.00 0.00 0.00 0.00 N 0.00 E "" I Measured Inclination Direction Vertical Latitude Departure Vertical Dogleg Depth Depth Section I (ft) (deg) (deg) (ft) (ft) (ft) (ft) (° /100') 100.00 0.39 240.43 100.00 0.17 S 0.30 W 0.28 0.39 170.00 0.34 176.53 170.00 0.49 S 0.49 W 0.44 0.56 I 259.00 0.51 244.17 259.00 0.93 S 0.83 W 0.75 0.55 352.00 1.22 176.03 351.99 2.10 S 1.14 W 0.94 1.22 444.00 3.18 150.68 443.92 5.30 S 0.18 E -0.65 2.33 534.00 4.23 145.82 533.73 10.22 S 3.27 E -4.17 1.22 I 630.00 4.11 151.15 629.47 16.16 S 6.92 E -8.33 0.42 725.00 5.18 150.70 724.16 22.89 S 10.66 E -12.65 1.13 821.00 6.17 155.13 819.69 31.35 S 14.95 E -17.68 1.13 I 861.67 6.00 151.94 860.13 35.20 S 16.87 E -19.93 0.93 956.76 5.58 152.47 954.73 43.69 S 21.34 E -25.14 0.45 1050.07 7.30 154.40 1047.45 53.06 S 26.00 E -30.62 1.86 I 1105.00 8.81 155.76 1101.84 60.04 S 29.24 E -34.46 2.77 1144.97 9.24 155.31 1141.31 65.75 S 31.84E -37.55 1.09 1241.07 11.48 154.47 1235.84 81.39 S 39.18 E -46.26 2.34 I 1316.00 13.83 155.06 1308.95 96.24 S 46.17 E -54.54 3.14 1391.00 16.14 154.08 1381.39 113.75 S 54.51E -64.41 3.10 1486.00 21.72 149.84 1471.22 140.85 S 69.12 E -81.37 6.05 I 1530.82 21.90 149.99 1512.83 155.26 S 77.47 E -90.97 0.42 1620.97 20.72 150.30 1596.82 183.67 S 93.78 E - 109.74 1.31 1716.07 22.89 151.41 1685.11 214.52 S 110.97 E - 129.60 2.32 I 1808.67 24.86 158.02 1769.80 248.40 S 126.88 E - 148.46 3.58 1904.52 25.17 159.62 1856.66 286.19 S 141.52 E - 166.40 0.78 1999.17 25.27 160.64 1942.28 324.12 S 155.22 E - 183.42 0.47 I 2094.61 25.61 164.07 2028.47 363.17 S 167.64 E - 199.26 1.58 2187.75 26.22 168.42 2112.26 402.69 S 177.30 E -212.39 2.14 2283.65 29.33 173.22 2197.11 446.78 S 184.32 E - 223.31 3.99 I 2377.66 34.42 171.98 2276.92 495.99 S 190.75 E - 234.09 5.46 2472.90 36.80 176.68 2354.35 551.14 S 196.16 E -244.38 3.81 2571.09 37.87 175.57 2432.43 610.55 S 200.19 E - 253.68 1.29 I 2667.32 39.92 176.18 2507.32 670.81 S 204.53 E -263.36 2.17 2761.38 43.05 179.91 2577.78 733.05 S 206.59 E -270.94 4.24 2853.73 45.19 182.07 2644.08 797.32 S 205.46 E - 275.53 2.83 2949.25 46.47 185.50 2710.65 865.67 S 200.92 E - 277.08 2.90 I 3043.84 47.92 186.37 2774.92 934.69 S 193.73 E -276.06 1.67 3138.67 49.67 186.88 2837.39 1005.55 S 185.50 E - 274.16 1.89 3233.92 53.09 188.05 2896.83 1079.33 S 175.81 E - 271.07 3.72 3327.71 55.19 190.36 2951.77 1154.34 S 163.64 E -265.61 3.00 3356.70 55.37 191.09 2968.29 1177.76 S 159.20 E -263.27 2.16 3477.63 55.07 192.26 3037.27 1275.02 S 139.11 E - 251.90 0.83 I 3573.90 55.83 195.59 3091.88 1351.96 S 120.02 E -239.73 2.96 3668.37 55.39 197.84 3145.24 1426.62 S 97.60 E -224.04 2.02 3763.81 54.83 197.86 3199.83 1501.14 S 73.61 E - 206.76 0.59 I 3858.11 54.50 197.68 3254.37 1574.39 S 50.13 E - 189.89 0.38 3952.26 53.46 199.06 3309.74 1646.66 S 26.14 E -172.41 1.62 Job No.: AK -MW- 0005710855 Well No.: ODSN -40PB1 End of Well Report Page 2 I HALLIBURTON Sperry Drilling Services I Measured Directional Survey Data Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg I (ft) (deg) (deg) (ft) (ft) (ft) (ft) (° /100') 4048.71 53.19 200.20 3367.35 1719.52 S 0.15 E -153.01 0.99 4144.92 53.07 201.93 3425.07 1791.34 S 27.51 W - 131.84 1.44 I 4241.65 53.26 204.61 3483.07 1862.45 S 58.09 W - 107.70 2.23 4333.84 53.24 206.01 3538.23 1929.22 S 89.67 W -82.18 1.22 4428.58 53.10 207.72 3595.03 1996.87 S 123.94 W -54.07 1.45 I 4523.74 53.12 210.75 3652.16 2063.27 S 161.10 W -22.95 2.55 4619.01 52.95 214.03 3709.46 2127.53 S 201.87 W 11.94 2.76 4715.41 53.40 217.59 3767.25 2190.09 S 247.01 W 51.34 2.99 I 4802.82 54.93 220.15 3818.43 2245.24 S 291.48 W 90.74 2.95 4904.22 55.00 221.23 3876.64 2308.19 S 345.61 W 139.05 0.87 4998.95 54.17 221.40 3931.53 2366.18 S 396.58 W 184.67 0.89 5092.89 54.48 223.38 3986.32 2422.54 S 448.03 W 230.90 1.74 I 5189.96 55.45 226.12 4042.05 2478.96 S 503.98 W 281.61 2.52 5283.41 57.57 225.20 4093.62 2533.44 S 559.71 W 332.28 2.41 5378.96 59.29 224.20 4143.64 2591.30 S 616.97 W 384.17 2.01 1 5473.02 61.08 222.03 4190.41 2650.88 S 672.73 W 434.41 2.76 5568.75 63.58 220.77 4234.86 2714.47 S 728.78 W 484.59 2.86 5662.04 66.38 221.63 4274.31 2778.07 S 784.46 W 534.40 3.12 I 5760.64 69.42 220.19 4311.41 2847.11 S 844.27 W 587.83 3.37 5855.29 70.09 220.04 4344.16 2915.02 S 901.49 W 638.78 0.72 5947.13 69.63 220.69 4375.78 2980.72 S 957.33 W 688.56 0.83 I 6040.82 69.52 219.70 4408.48 3047.78 S 1013.99 W 739.04 1.00 6140.00 70.43 218.27 4442.44 3120.21 S 1072.61 W 790.99 1.64 6231.39 69.58 219.50 4473.69 3187.06 S 1126.52 W 838.74 1.57 I 6326.10 69.50 221.68 4506.80 3254.44 S 1184.25 W 890.26 2.16 6419.52 70.30 224.94 4538.91 3318.26 S 1244.42 W 944.52 3.39 6515.15 70.68 226.74 4570.85 3381.05 S 1309.09 W 1003.34 1.82 I 6608.75 70.28 226.46 4602.13 3441.67 S 1373.19 W 1061.80 0.51 6705.30 70.49 227.06 4634.54 3503.97 S 1439.44 W 1122.25 0.62 6800.11 70.02 228.19 4666.57 3564.11 S 1505.36 W 1182.56 1.23 I 6895.03 70.04 227.64 4698.99 3623.91 S 1571.57 W 1243.20 0.55 6990.84 70.16 227.37 4731.60 3684.77 S 1638.00 W 1303.95 0.29 7085.84 69.98 227.10 4763.98 3745.41 S 1703.56 W 1363.87 0.33 I 7180.95 70.22 225.63 4796.36 3807.12 S 1768.29 W 1422.85 1.48 7276.34 69.64 224.82 4829.09 3870.22 S 1831.89 W 1480.59 1.00 7371.31 69.56 223.74 4862.20 3933.95 S 1894.03 W 1536.82 1.07 7466.07 69.44 225.99 4895.39 3996.85 S 1956.64 W 1593.59 2.23 I 7559.27 69.10 224.14 4928.38 4058.41 S 2018.35 W 1649.58 1.89 7653.71 69.51 224.50 4961.75 4121.62 S 2080.07 W 1705.44 0.56 7750.54 69.58 225.55 4995.59 4185.74 S 2144.25 W 1763.66 1.02 7844.64 69.57 226.16 5028.43 4247.16 S 2207.53 W 1821.23 0.61 7939.55 69.69 226.88 5061.47 4308.38 S 2272.09 W 1880.09 0.72 8033.31 69.84 226.89 5093.90 4368.51 S 2336.31 W 1938.71 0.16 I 8130.04 69.56 225.14 5127.46 4431.51 S 2401.58 W 1998.13 1.72 8224.38 70.23 223.60 5159.89 4494.84 S 2463.53 W 2054.20 1.69 8321.00 69.25 222.85 5193.35 4560.88 S 2525.61 W 2110.16 1.25 I 8414.62 69.44 222.46 5226.37 4625.31 S 2584.97 W 2163.56 0.44 8505.68 69.83 223.27 5258.06 4687.88 S 2643.04 W 2215.84 0.94 Job No.: AK -MW- 0005710855 Well No.: ODSN -40PB1 End of Well Report Page 3 1 a - - - -- - HALLIBURTON Sperry Drilling Services I Directional Survey Data Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg I (ft) (deg) (deg) (ft) (ft) (ft) (ft) ( /100') 8602.89 69.37 226.27 5291.95 4752.56 S 2707.20 W 2273.99 2.93 8659.57 69.13 227.75 5312.03 4788.70 S 2745.96 W 2309.39 2.48 I 8714.90 69.33 230.42 5331.66 4822.58 S 2785.05 W 2345.32 4.53 8764.00 69.33 230.42 5348.99 4851.85 S 2820.46 W 2377.98 0.00 I CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT I TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 275.10 DEGREES(TRUE) I A TOTAL CORRECTION OF 22.55 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD 1 HORIZONTAL DISPLACEMENT(CLOSURE) AT 8764.00 FEET IS 5612.08 FEET ALONG 210.17 DEGREES (TRUE) I I 1 I I I I I I 1 Job No.: AK -MW- 0005710855 Well No.: ODSN -40PB1 End of Well Report Page 4 ' HALLIBURTON End of Well Report for Pioneer Natural Resources, AK Rig : Nabors 19AC Well : ODSN -40 PB2 Field : Oooguruk Country : U.S.A. ' Job Number : AK -MW- 0005710855 Date : 07- May -08 API Number : 50- 703 - 20571 -71 I 1 1 I Drilling Sperry g Services 1 I HALLIBURTON Sperry Drilling Services 1 Directional Survey Data 0.00 0.00 0.00 0.00 0.00 N 0.00 E """ I Measured Inclination Direction Vertical Latitude Departure Vertical Dogleg Depth Depth Section I (ft) (deg) (deg) (ft) (ft) (ft) (ft) ( /100') 44.00 0.00 0.00 44.00 0.00 N 0.00E 0.00 0.00 100.00 0.39 240.43 100.00 0.09 S 0.17 W 0.16 0.70 I 170.00 0.34 176.53 170.00 0.42 S 0.36 W 0.32 0.56 259.00 0.51 244.17 259.00 0.86 S 0.70 W 0.62 0.55 352.00 1.22 176.03 351.99 2.02 S 1.00 W 0.82 1.22 I 444.00 3.18 150.68 443.92 5.23 S 0.31 E -0.78 2.33 534.00 4.23 145.82 533.73 10.15 S 3.40 E -4.29 1.22 630.00 4.11 151.15 629.47 16.09 S 7.05 E -8.45 0.42 725.00 5.18 150.70 724.16 22.81 S 10.79 E -12.78 1.13 I 821.00 6.17 155.13 819.69 31.27 S 15.08 E -17.80 1.13 861.67 6.00 151.94 860.13 35.13 S 17.00 E -20.06 0.93 956.76 5.58 152.47 954.73 43.62 S 21.47 E -25.27 0.45 1 1050.07 7.30 154.40 1047.45 52.99 S 26.13 E -30.74 1.86 1105.00 8.81 155.76 1101.84 59.97 S 29.37 E -34.58 2.77 1144.97 9.24 155.31 1141.31 65.68 S 31.97 E -37.68 1.09 I 1241.07 11.48 154.47 1235.84 81.32 S 39.31 E -46.38 2.34 1316.00 13.83 155.06 1308.95 96.17 S 46.30 E -54.67 3.14 1391.00 16.14 154.08 1381.39 113.68 S 54.64 E -64.53 3.10 I 1486.00 21.72 149.84 1471.22 140.77 S 69.26E -81.50 6.05 1530.82 21.90 149.99 1512.83 155.18 S 77.60E -91.09 0.42 1620.97 20.72 150.30 1596.82 183.59 S 93.91 E - 109.86 1.31 I 1716.07 22.89 151.41 1685.11 214.45 S 111.10 E - 129.73 2.32 1808.67 24.86 158.02 1769.80 248.32 S 127.01 E -148.58 3.58 1904.52 25.17 159.62 1856.66 286.11 S 141.65 E - 166.52 0.78 I 1999.17 25.27 160.64 1942.28 324.04 S 155.35 E - 183.55 0.47 2094.61 25.61 164.07 2028.47 363.10 S 167.77 E -199.38 1.58 2187.75 26.22 168.42 2112.26 402.61 S 177.43 E - 212.51 2.14 I 2283.65 29.33 173.22 2197.11 446.71 S 184.45 E - 223.43 3.99 2377.66 34.42 171.98 2276.92 495.92 S 190.88 E -234.21 5.46 2472.90 36.80 176.68 2354.35 551.07 S 196.29 E - 244.50 3.81 I 2571.09 37.87 175.57 2432.43 610.48 S 200.32 E -253.80 1.29 2667.32 39.92 176.18 2507.32 670.74 S 204.66 E -263.48 2.17 2761.38 43.05 179.91 2577.78 732.98 S 206.72 E - 271.07 4.24 2853.73 45.19 182.07 2644.08 797.25 S 205.59 E - 275.65 2.83 I 2949.25 46.47 185.50 2710.65 865.59 S 201.05 E - 277.20 2.90 3043.84 47.92 186.37 2774.92 934.61 S 193.86 E - 276.18 1.67 3138.67 49.67 186.88 2837.39 1005.48 S 185.63 E - 274.28 1.89 1 3233.92 53.09 188.05 2896.83 1079.25 S 175.94 E -271.19 3.72 3327.71 55.19 190.36 2951.77 1154.27 S 163.77 E -265.73 3.00 3356.70 55.37 191.09 2968.29 1177.68 S 159.33 E - 263.39 2.16 I 3477.63 55.07 192.26 3037.27 1274.95 S 139.24 E -252.02 0.83 3573.90 55.83 195.59 3091.88 1351.89 S 120.15 E -239.85 2.96 3668.37 55.39 197.84 3145.24 1426.55 S 97.73 E - 224.16 2.02 I 3763.81 54.83 197.86 3199.83 1501.06 S 73.74 E - 206.88 0.59 3858.11 54.50 197.68 3254.37 1574.32 S 50.26 E -190.01 0.38 Job No.: AK -MW- 0005710855 Well No.: ODSN -40 PB2 End of Well Report Page 2 I JIM I HALLIBURTON Sperry Drilling Services I Directional Survey Data Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (° /100') 3 952.26 53.46 199.06 3309.74 1646.59 S 26.27E -172.54 1.62 4048.71 53.19 200.20 3367.35 1719.45 S 0.28 E - 153.13 0.99 I 4144.92 53.07 201.93 3425.07 1791.27 S 27.38 W - 131.96 1.44 4241.65 53.26 204.61 3483.07 1862.38 S 57.96 W -107.82 2.23 4333.84 53.24 206.01 3538.23 1929.15 S 89.54 W -82.31 1.22 I 4428.58 53.10 207.72 3595.03 1996.79 S 123.81 W -54.19 1.45 4523.74 53.12 210.75 3652.16 2063.19 S 160.97 W -23.08 2.55 4619.01 52.95 214.03 3709.46 2127.46 S 201.74 W 11.81 2.76 I 4715.41 53.40 217.59 3767.25 2190.01 S 246.88 W 51.22 2.99 4802.82 54.93 220.15 3818.43 2245.17 S 291.35 W 90.61 2.95 4904.22 55.00 221.23 3876.64 2308.12 S 345.48 W 138.93 0.87 I 4998.95 54.17 221.40 3931.53 2366.11 S 396.45 W 184.54 0.89 5092.89 54.48 223.38 3986.32 2422.46 S 447.90 W 230.77 1.74 5100.00 54.55 223.58 3990.45 2426.66 S 451.88 W 234.37 2.49 5163.35 52.83 224.51 4027.96 2463.36 S 487.36 W 266.45 2.96 1 5203.29 51.88 225.43 4052.36 2485.73 S 509.71 W 286.72 3.00 5299.51 53.71 226.74 4110.54 2538.87 S 564.92 W 336.99 2.19 5393.25 56.29 226.90 4164.30 2591.41 S 620.91 W 388.09 2.76 I 5488.93 58.62 225.39 4215.77 2647.30 S 679.06 W 441.03 2.77 5585.01 62.27 223.27 4263.16 2707.09 S 737.43 W 493.86 4.26 5679.43 65.78 223.43 4304.51 2768.80 S 795.69 W 546.40 3.72 1 5773.54 65.50 224.99 4343.32 2830.25 S 855.46 W 600.48 1.54 5870.65 65.31 228.51 4383.75 2890.74 S 919.76 W 659.14 3.30 5964.24 65.57 229.92 4422.65 2946.34 S 984.21 W 718.40 1.40 I 6059.66 65.37 229.12 4462.27 3002.69 S 1050.24 W 779.16 0.79 6154.40 65.43 227.47 4501.71 3060.00 S 1114.55 W 838.11 1.58 6248.80 65.78 225.87 4540.70 3118.99 S 1177.08 W 895.16 1.59 I 6343.84 65.86 224.37 4579.63 3180.17 S 1238.52 W 950.91 1.44 6438.33 64.75 224.30 4619.11 3241.57 S 1298.51 W 1005.21 1.18 6532.70 65.09 225.48 4659.11 3302.13 S 1358.83 W 1059.91 1.19 I 6627.93 65.77 225.43 4698.71 3362.88 S 1420.56 W 1115.99 0.72 6724.54 66.04 225.65 4738.15 3424.65 S 1483.50 W 1173.19 0.35 6813.99 66.04 225.48 4774.48 3481.88 S 1541.87 W 1226.24 0.17 I 6912.81 65.38 225.48 4815.13 3545.03 S 1606.09 W 1284.59 0.67 7007.83 63.59 226.31 4856.05 3604.71 S 1667.66 W 1340.61 2.04 7102.62 64.76 226.86 4897.35 3663.35 S 1729.64 W 1397.13 1.34 I 7198.31 64.41 226.38 4938.41 3722.71 S 1792.46 W 1454.43 0.58 7292.15 63.88 226.12 4979.34 3781.11 S 1853.46 W 1510.00 0.62 7387.84 63.66 225.92 5021.63 3840.71 S 1915.23 W 1566.22 0.30 7482.18 64.69 226.10 5062.73 3899.69 S 1976.32 W 1621.83 1.11 I 7580.58 64.63 226.02 5104.84 3961.40 S 2040.36 W 1680.13 0.10 7672.01 64.00 226.05 5144.47 4018.60 S 2099.67 W 1734.11 0.69 7765.81 64.21 225.38 5185.43 4077.52 S 2160.07 W 1789.04 0.68 7862.09 63.73 225.28 5227.68 4138.34 S 2221.60 W 1844.92 0.51 7965.15 64.00 225.99 5273.08 4203.03 S 2287.74 W 1905.05 0.67 8053.82 64.54 226.14 5311.57 4258.45 S 2345.26 W 1957.42 0.63 I 8146.79 66.18 227.02 5350.33 4316.53 S 2406.64 W 2013.39 1.96 8241.30 69.12 227.69 5386.27 4375.74 S 2470.94 W 2072.17 3.18 Job No.: AK -MW- 0005710855 Well No.: ODSN -40 PB2 End of Well Report Page 3 I Am -- 1 HALLIBURTON Sperry Drilling Services I Directional Survey Data Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg I (ft) (deg) (deg) (ft) (ft) (ft) (ft) (° /100') 8 336.45 71.03 227.63 5418.69 4435.98 S 2537.05 W 2132.67 2.01 8430.34 72.72 226.84 5447.90 4496.57 S 2602.56 W 2192.52 1.97 I 8526.96 72.40 226.26 5476.86 4559.96 S 2669.48 W 2253.54 0.66 8621.74 72.84 227.91 5505.17 4621.55 S 2735.72 W 2314.05 1.73 8717.05 72.46 231.65 5533.60 4680.28 S 2805.17 W 2378.00 3.77 I 8809.61 71.73 235.44 5562.07 4732.61 S 2875.99 W 2443.89 3.98 8903.84 71.86 237.99 5591.51 4781.73 S 2950.81 W 2514.05 2.57 8999.29 71.48 241.23 5621.54 4827.56 S 3028.96 W 2587.81 3.25 I 9094.69 71.75 244.87 5651.64 4868.58 S 3109.64 W 2664.53 3.63 9189.30 71.99 247.24 5681.08 4905.07 S 3191.81 W 2743.13 2.39 9284.80 72.27 251.06 5710.40 4937.41 S 3276.73 W 2824.84 3.82 I 9378.07 72.62 254.81 5738.54 4963.50 S 3361.72 W 2907.18 3.85 9472.51 72.18 258.24 5767.10 4984.47 S 3449.25 W 2992.49 3.49 9567.23 71.93 262.62 5796.30 4999.45 S 3538.08 W 3079.64 4.41 I 9657.71 71.94 265.85 5824.36 5008.09 S 3623.65 W 3164.10 3.39 9757.04 72.19 268.35 5854.95 5012.87 S 3718.03 W 3257.68 2.41 9851.95 72.44 272.03 5883.79 5012.57 S 3808.43 W 3347.75 3.70 9946.04 72.51 275.15 5912.13 5006.95 S 3897.97 W 3437.43 3.16 I 10040.89 72.56 278.49 5940.61 4996.21 S 3987.79 W 3527.85 3.36 10135.40 73.02 281.01 5968.57 4980.92 S 4076.75 W 3617.83 2.59 10231.78 73.09 284.66 5996.67 4960.44 S 4166.63 W 3709.17 3.62 10326.54 72.50 288.60 6024.71 4934.54 S 4253.34 W 3797.84 4.02 10422.32 73.03 291.70 6053.10 4903.03 S 4339.21 W 3886.17 3.14 10516.02 74.38 296.06 6079.40 4866.63 S 4421.42 W 3971.28 4.69 I 10611.11 75.08 299.36 6104.45 4823.97 S 4502.61 W 4055.95 3.43 10704.72 75.46 299.54 6128.25 4779.46 S 4581.45 W 4138.43 0.45 10801.66 75.47 299.55 6152.58 4733.19 S 4663.08 W 4223.86 0.01 I 10896.15 75.46 299.47 6176.29 4688.13 S 4742.68 W 4307.15 0.08 10989.94 75.32 301.94 6199.95 4641.80 S 4820.71 W 4388.98 2.55 11075.39 75.26 305.69 6221.66 4595.81 S 4889.36 W 4461.46 4.25 I 11105.07 75.28 303.47 6229.21 4579.52 S 4913.00 W 4486.44 7.23 11184.67 79.05 303.10 6246.89 4536.94 S 4977.86 W 4554.84 4.76 11278.65 80.10 303.29 6263.89 4486.33 S 5055.21 W 4636.38 1.13 I 11377.02 82.80 304.84 6278.52 4431.85 S 5135.78 W 4721.47 3.16 11473.50 87.93 307.57 6286.31 4375.06 S 5213.34 W 4803.77 6,02 11520.45 87.21 309.39 6288.30 4345.88 S 5250.06 W 4842.94 4.16 I 11570.00 89.82 311.60 6289.59 4313.71 S 5287.72 W 4883.31 6.90 11602.91 92.23 312.46 6289.00 4291.69 S 5312.16 W 4909.61 7.78 11634.50 93.01 312.92 6287.56 4270.29 S 5335.35 W 4934.62 2.87 11665.02 93.37 313.03 6285.86 4249.52 S 5357.65 W 4958.67 1.23 11712.47 95.12 313.50 6282.34 4217.09 S 5392.10 W 4995.87 3.82 11762.66 96.79 314.61 6277.14 4182.38 S 5427.98 W 5034.69 3.99 11858.89 95.77 314.64 6266.61 4115.19 S 5496.06 W 5108.47 1.06 I 11954.54 94.97 314.42 6257.66 4048.40 S 5563.94 W 5182.03 0.87 12051.41 96.41 314.26 6248.06 3981.03 S 5632.88 W 5256.68 1.50 12148.35 95.72 313.37 6237.81 3914.30 S 5702.44 W 5331.90 1.16 I 12245.05 96.60 312.31 6227.44 3848.93 S 5772.93 W 5407.92 1.42 12341.81 95.71 312.22 6217.06 3784.22 S 5844.13 W 5484.58 0.92 Job No.: AK -MW- 0005710855 Well No.: ODSN -40 PB2 End of Well Report Page 4 ' 1 HALLIBURTON Sperry Drilling Services I Directional Survey Data Measured Inclination Direction Vertical Latitude Departure Vertical Dogleg Depth Depth Section l (ft) (deg) (deg) (ft) (ft) (ft) (ft) ( /100') 1 2438.09 96.90 312.76 6206.49 3719.59 S 5914.69 W 5560.62 1.36 12532.87 95.90 311.67 6195.92 3656.30 S 5984.45 W 5635.72 1.56 I 12630.73 97.53 312.59 6184.48 3591.11 S 6056.52 W 5713.31 1.91 12726.81 96.84 313.16 6172.46 3526.25 S 6126.38 W 5788.65 0.93 12824.11 92.97 312.83 6164.15 3460.15 S 6197.27 W 5865.14 3.99 I 12920.87 93.99 313.18 6158.27 3394.28 S 6267.90 W 5941.35 1.11 13017.35 98.11 315.06 6148.10 3327.51 S 6336.76 W 6015.87 4.69 13113.51 97.39 314.78 6135.14 3260.23 S 6404.23 W 6089.05 0.80 I 13210.30 96.83 315.37 6123.16 3192.23 S 6472.06 W 6162.66 0.84 13306.02 95.40 314.15 6112.96 3125.21 S 6539.63 W 6235.92 1.96 13359.00 95.40 314.15 6107.97 3088.48 S 6577.48 W 6276.88 0.00 I CALCULATION BASED ON MINIMUM CURVATURE METHOD SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT I TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD I VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 275.10 DEGREES(TRUE) A TOTAL CORRECTION OF 22.55 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD 1 HORIZONTAL DISPLACEMENT(CLOSURE) AT 13359.00 FEET IS 7266.49 FEET ALONG 244.85 DEGREES (TRUE) I I I I I I I I Job No.: AK -MW- 0005710855 Well No.: ODSN -40 PB2 End of Well Report Page 5 I I HALLIBURTON End of Well Report for Pioneer Natural Resources, AK I Rig : Nabors 19AC Well Field : Oooguruk Country : U.S.A. Job Number : AK- MW- 0005710855 Date : 07- May -08 API Number : 50- 703 - 20571 -00 1 I r I i 1 i 1 Sperry Drilling Services 1 I HALLIBURTON Sperry Drilling Services I Directional Survey Data I 0.00 0.00 0.00 0.00 0.00 N 0.00 E Measured Inclination Direction Vertical Latitude Departure Vertical Dogleg Depth Depth Section I (ft) (deg) (deg) (ft) (ft) (ft) (ft) (° /100') 44.00 0.00 0.00 44.00 0.00 N 0.00E 0.00 0.00 100.00 0.39 240.43 100.00 0.09 S 0.17 W 0.16 0.70 I 170.00 0.34 176.53 170.00 0.42 S 0.36 W 0.32 0.56 259.00 0.51 244.17 259.00 0.86 S 0.70 W 0.62 0.55 352.00 1.22 176.03 351.99 2.02 S 1.00 W 0.82 1.22 I 444.00 3.18 150.68 443.92 5.23 S 0.31 E -0.78 2.33 534.00 4.23 145.82 533.73 10.15 S 3.40 E -4.29 1.22 630.00 4.11 151.15 629.47 16.09 S 7.05 E -8.45 0.42 725.00 5.18 150.70 724.16 22.81 S 10.79 E -12.78 1.13 I 821.00 6.17 155.13 819.69 31.27 S 15.08 E -17.80 1.13 861.67 6.00 151.94 860.13 35.13 S 17.00 E -20.06 0.93 956.76 5.58 152.47 954.73 43.62 S 21.47 E -25.27 0.45 I 1050.07 7.30 154.40 1047.45 52.99 S 26.13 E -30.74 1.86 1105.00 8.81 155.76 1101.84 59.97 S 29.37 E -34.58 2.77 1144.97 9.24 155.31 1141.31 65.68 S 31.97 E -37.68 1.09 I 1241.07 11.48 154.47 1235.84 81.32 S 39.31 E -46.38 2.34 1316.00 13.83 155.06 1308.95 96.17 S 46.30 E -54.67 3.14 1391.00 16.14 154.08 1381.39 113.68 S 54.64 E -64.53 3.10 I 1486.00 21.72 149.84 1471.22 140.77 S 69.26 E -81.50 6.05 1530.82 21.90 149.99 1512.83 155.18 S 77.60 E -91.09 0.42 1620.97 20.72 150.30 1596.82 183.59 S 93.91 E - 109.86 1.31 I 1716.07 22.89 151.41 1685.11 214.45 S 111.10 E - 129.73 2.32 1808.67 24.86 158.02 1769.80 248.32 S 127.01 E -148.58 3.58 1904.52 25.17 159.62 1856.66 286.11 S 141.65 E - 166.52 0.78 I 1999.17 25.27 160.64 1942.28 324.04 S 155.35 E - 183.55 0.47 2094.61 25.61 164.07 2028.47 363.10 S 167.77 E -199.38 1.58 2187.75 26.22 168.42 2112.26 402.61 S 177.43 E - 212.51 2.14 I 2283.65 29.33 173.22 2197.11 446.71 S 184.45 E - 223.43 3.99 2377.66 34.42 171.98 2276.92 495.92 S 190.88 E -234.21 5.46 2472.90 36.80 176.68 2354.35 551.07 S 196.29 E - 244.50 3.81 I 2571.09 37.87 175.57 2432.43 610.48 S 200.32 E - 253.80 1.29 2667.32 39.92 176.18 2507.32 670.74 S 204.66 E -263.48 2.17 2761.38 43.05 179.91 2577.78 732.98 S 206.72 E - 271.07 4.24 2853.73 45.19 182.07 2644.08 797.25 S 205.59 E - 275.65 2.83 I 2949.25 46.47 185.50 2710.65 865.59 S 201.05 E - 277.20 2.90 3043.84 47.92 186.37 2774.92 934.61 S 193.86 E - 276.18 1.67 3138.67 49.67 186.88 2837.39 1005.48 S 185.63 E - 274.28 1.89 I 3233.92 53.09 188.05 2896.83 1079.25 S 175.94 E -271.19 3.72 3327.71 55.19 190.36 2951.77 1154.27 S 163.77 E - 265.73 3.00 3356.70 55.37 191.09 2968.29 1177.68 S 159.33 E - 263.39 2.16 I 3477.63 55.07 192.26 3037.27 1274.95 S 139.24 E -252.02 0.83 3573.90 55.83 195.59 3091.88 1351.89 S 120.15 E -239.85 2.96 3668.37 55.39 197.84 3145.24 1426.55 S 97.73 E - 224.16 2.02 I 3763.81 54.83 197.86 3199.83 1501.06 S 73.74 E - 206.88 0.59 3858.11 54.50 197.68 3254.37 1574.32 S 50.26 E - 190.01 0.38 Job No.: AK -MW- 0005710855 Well No.: ODSN -40 End of Well Report Page 2 I r 1 HALLIBURTON Sperry Drilling Services 1 111 I Directional Survey Data Measured Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg I (ft) (deg) (deg) (ft) (ft) (ft) (ft) (° /100') 3952.26 53.46 199.06 3309.74 1646.59 S 26.27 E -172.54 1.62 4048.71 53.19 200.20 3367.35 1719.45 S 0.28 E - 153.13 0.99 I 4144.92 53.07 201.93 3425.07 1791.27 S 27.38 W - 131.96 1.44 4241.65 53.26 204.61 3483.07 1862.38 S 57.96 W -107.82 2.23 4333.84 53.24 206.01 3538.23 1929.15 S 89.54 W -82.31 1.22 I 4428.58 53.10 207.72 3595.03 1996.79 S 123.81 W -54.19 1.45 4523.74 53.12 210.75 3652.16 2063.19 S 160.97 W -23.08 2.55 4619.01 52.95 214.03 3709.46 2127.46 S 201.74 W 11.81 2.76 I 4715.41 53.40 217.59 3767.25 2190.01 S 246.88 W 51.22 2.99 4802.82 54.93 220.15 3818.43 2245.17 S 291.35 W 90.61 2.95 4904.22 55.00 221.23 3876.64 2308.12 S 345.48 W 138.93 0.87 I 4998.95 54.17 221.40 3931.53 2366.11 S 396.45 W 184.54 0.89 5092.89 54.48 223.38 3986.32 2422.46 S 447.90 W 230.77 1.74 5100.00 54.55 223.58 3990.45 2426.66 S 451.88 W 234.37 2.49 5163.35 52.83 224.51 4027.96 2463.36 S 487.36 W 266.45 2.96 1 5203.29 51.88 225.43 4052.36 2485.73 S 509.71 W 286.72 3.00 5299.51 53.71 226.74 4110.54 2538.87 S 564.92 W 336.99 2.19 5393.25 56.29 226.90 4164.30 2591.41 S 620.91 W 388.09 2.76 I 5488.93 58.62 225.39 4215.77 2647.30 S 679.06 W 441.03 2.77 5585.01 62.27 223.27 4263.16 2707.09 S 737.43 W 493.86 4.26 5679.43 65.78 223.43 4304.51 2768.80 S 795.69 W 546.40 3.72 I 5773.54 65.50 224.99 4343.32 2830.25 S 855.46 W 600.48 1.54 5870.65 65.31 228.51 4383.75 2890.74 S 919.76 W 659.14 3.30 5964.24 65.57 229.92 4422.65 2946.34 S 984.21 W 718.40 1.40 I 6059.66 65.37 229.12 4462.27 3002.69 S 1050.24 W 779.16 0.79 6154.40 65.43 227.47 4501.71 3060.00 S 1114.55 W 838.11 1.58 6248.80 65.78 225.87 4540.70 3118.99 S 1177.08 W 895.16 1.59 I 6343.84 65.86 224.37 4579.63 3180.17 S 1238.52 W 950.91 1.44 6438.33 64.75 224.30 4619.11 3241.57 S 1298.51 W 1005.21 1.18 6532.70 65.09 225.48 4659.11 3302.13 S 1358.83 W 1059.91 1.19 I 6627.93 65.77 225.43 4698.71 3362.88 S 1420.56 W 1115.99 0.72 6724.54 66.04 225.65 4738.15 3424.65 S 1483.50 W 1173.19 0.35 6813.99 66.04 225.48 4774.48 3481.88 S 1541.87 W 1226.24 0.17 I 6912.81 65.38 225.48 4815.13 3545.03 S 1606.09 W 1284.59 0.67 7007.83 63.59 226.31 4856.05 3604.71 S 1667.66 W 1340.61 2.04 7102.62 64.76 226.86 4897.35 3663.35 S 1729.64 W 1397.13 1.34 7198.31 64.41 226.38 4938.41 3722.71 S 1792.46 W 1454.43 0.58 I 7292.15 63.88 226.12 4979.34 3781.11 S 1853.46 W 1510.00 0.62 7387.84 63.66 225.92 5021.63 3840.71 S 1915.23 W 1566.22 0.30 7482.18 64.69 226.10 5062.73 3899.69 S 1976.32 W 1621.83 1.11 7580.58 64.63 226.02 5104.84 3961.40 S 2040.36 W 1680.13 0.10 7672.01 64.00 226.05 5144.47 4018.60 S 2099.67 W 1734.11 0.69 7765.81 64.21 225.38 5185.43 4077.52 S 2160.07 W 1789.04 0.68 I 7862.09 63.73 225.28 5227.68 4138.34 S 2221.60 W 1844.92 0.51 7965.15 64.00 225.99 5273.08 4203.03 S 2287.74 W 1905.05 0.67 8053.82 64.54 226.14 5311.57 4258.45 S 2345.26 W 1957.42 0.63 I 8146.79 66.18 227.02 5350.33 4316.53 S 2406.64 W 2013.39 1.96 8241.30 69.12 227.69 5386.27 4375.74 S 2470.94 W 2072.17 3.18 Job No.: AK -MW- 0005710855 Well No.: ODSN -40 End of Well Report Page 3 w. I HALLIBURTON Sperry Drilling Services I Measured Directional Survey Data Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg I (ft) (deg) (deg) (ft) (ft) (ft) (ft) (° /100') 8336.45 71.03 227.63 5418.69 4435.98 S 2537.05 W 2132.67 2.01 8430.34 72.72 226.84 5447.90 4496.57 S 2602.56 W 2192.52 1.97 I 8526.96 72.40 226.26 5476.86 4559.96 S 2669.48 W 2253.54 0.66 8621.74 72.84 227.91 5505.17 4621.55 S 2735.72 W 2314.05 1.73 8717.05 72.46 231.65 5533.60 4680.28 S 2805.17 W 2378.00 3.77 I 8809.61 71.73 235.44 5562.07 4732.61 S 2875.99 W 2443.89 3.98 8903.84 71.86 237.99 5591.51 4781.73 S 2950.81 W 2514.05 2.57 8999.29 71.48 241.23 5621.54 4827.56 S 3028.96 W 2587.81 3.25 I 9094.69 71.75 244.87 5651.64 4868.58 S 3109.64 W 2664.53 3.63 9189.30 71.99 247.24 5681.08 4905.07 S 3191.81 W 2743.13 2.39 9284.80 72.27 251.06 5710.40 4937.41 S 3276.73 W 2824.84 3.82 9378.07 72.62 254.81 5738.54 4963.50 S 3361.72 W 2907.18 3.85 I 9472.51 72.18 258.24 5767.10 4984.47 S 3449.25 W 2992.49 3.49 9567.23 71.93 262.62 5796.30 4999.45 S 3538.08 W 3079.64 4.41 9657.71 71.94 265.85 5824.36 5008.09 S 3623.65 W 3164.10 3.39 9757.04 72.19 268.35 5854.95 5012.87 S 3718.03 W 3257.68 2.41 9851.95 72.44 272.03 5883.79 5012.57 S 3808.43 W 3347.75 3.70 9946.04 72.51 275.15 5912.13 5006.95 S 3897.97 W 3437.43 3.16 I 10040.89 72.56 278.49 5940.61 4996.21 S 3987.79 W 3527.85 3.36 10135.40 73.02 281.01 5968.57 4980.92 S 4076.75 W 3617.83 2.59 10231.78 73.09 284.66 5996.67 4960.44 S 4166.63 W 3709.17 3.62 I 10326.54 72.50 288.60 6024.71 4934.54 S 4253.34 W 3797.84 4.02 10422.32 73.03 291.70 6053.10 4903.03 S 4339.21 W 3886.17 3.14 10516.02 74.38 296.06 6079.40 4866.63 S 4421.42 W 3971.28 4.69 I 10611.11 75.08 299.36 6104.45 4823.97 S 4502.61 W 4055.95 3.43 10704.72 75.46 299.54 6128.25 4779.46 S 4581.45 W 4138.43 0.45 10801.66 75.47 299.55 6152.58 4733.19 S 4663.08 W 4223.86 0.01 I 10896.15 75.46 299.47 6176.29 4688.13 S 4742.68 W 4307.15 0.08 10989.94 75.32 301.94 6199.95 4641.80 S 4820.71 W 4388.98 2.55 11075.39 75.26 305.69 6221.66 4595.81 S 4889.36 W 4461.46 4.25 I 11105.07 75.28 303.47 6229.21 4579.52 S 4913.00 W 4486.44 7.23 11184.67 79.05 303.10 6246.89 4536.94 S 4977.86 W 4554.84 4.76 11278.65 80.10 303.29 6263.89 4486.33 S 5055.21 W 4636.38 1.13 I 11377.02 82.80 304.84 6278.52 4431.85 S 5135.78 W 4721.47 3.16 11473.50 87.93 307.57 6286.31 4375.06 S 5213.34 W 4803.77 6.02 11520.45 87.21 309.39 6288.30 4345.88 S 5250.06 W 4842.94 4.16 11570.00 89.82 311.60 6289.59 4313.71 S 5287.72 W 4883.31 6.90 I 11602.91 92.23 312.46 6289.00 4291.69 S 5312.16 W 4909.61 7.78 11634.50 93.01 312.92 6287.56 4270.29 S 5335.35 W 4934.62 2.87 11665.02 93.37 313.03 6285.86 4249.52 S 5357.65 W 4958.67 1.23 11712.47 95.12 313.50 6282.34 4217.09 S 5392.10 W 4995.87 3.82 11762.66 96.79 314.61 6277.14 4182.38 S 5427.98 W 5034.69 3.99 11858.89 95.77 314.64 6266.61 4115.19 S 5496.06 W 5108.47 1.06 I 11954.54 94.97 314.42 6257.66 4048.40 S 5563.94 W 5182.03 0.87 12051.41 96.41 314.26 6248.06 3981.03 S 5632.88 W 5256.68 1.50 12148.35 95.72 313.37 6237.81 3914.30 S 5702.44 W 5331.90 1.16 I 12245.05 96.60 312.31 6227.44 3848.93 S 5772.93 W 5407.92 1.42 ..- 12341.81 95.71 312.22 6217.06 3784.22 S 5844.13 W 5484.58 0.92 Job No.: AK -MW- 0005710855 Well No.: ODSN -40 End of Well Report Page 4 1 II HALLIBURTON Sperry Drilling Services 1 ill I Directional Survey Data Measured Inclination Direction Vertical Latitude Departure Vertical Dogleg Depth Depth Section I (ft) (deg) (deg) (ft) (ft) (ft) (ft) ( /100') 12438.09 96.90 312.76 6206.49 3719.59 S 5914.69 W 5560.62 1.36 12532.87 95.90 311.67 6195.92 3656.30 S 5984.45 W 5635.72 1.56 I 12630.73 97.53 312.59 6184.48 3591.11 S 6056.52 W 5713.31 1.91 12726.81 96.84 313.16 6172.46 3526.25 S 6126.38 W 5788.65 0.93 12824.11 92.97 312.83 6164.15 3460.15 S 6197.27 W 5865.14 3.99 I 12920.87 93.99 313.18 6158.27 3394.28 S 6267.90 W 5941.35 1.11 12953.00 95.36 313.80 6155.65 3372.24 S 6291.13 W 5966.45 4.68 12999.69 91.53 313.90 6152.85 3339.96 S 6324.74 W 6002.79 8.21 I 13017.31 91.74 313.87 6152.35 3327.75 S 6337.43 W 6016.52 1.20 13067.01 91.61 313.90 6150.89 3293.31 S 6373.24 W 6055.24 0.27 13113.34 90.97 314.46 6149.85 3261.03 S 6406.45 W 6091.20 1.84 13210.15 87.80 313.83 6150.89 3193.62 S 6475.91 W 6166.37 3.34 I 13306.80 84.57 313.81 6157.32 3126.86 S 6545.48 W 6241.60 3.34 13403.13 84.86 314.70 6166.19 3059.92 S 6614.18 W 6315.98 0.97 13500.10 86.17 316.70 6173.77 2990.73 S 6681.69 W 6389.37 2.46 13596.42 85.68 317.37 6180.62 2920.43 S 6747.17 W 6460.84 0.86 13694.79 87.71 317.22 6186.29 2848.27 S 6813.78 W 6533.60 2.07 13790.29 86.34 316.39 6191.25 2778.74 S 6879.05 W 6604.80 1.68 I 13886.32 85.66 318.17 6197.95 2708.36 S 6944.04 W 6675.78 1.98 13981.71 87.52 320.85 6203.62 2635.95 S 7005.86 W 6743.79 3.42 14078.63 90.28 322.80 6205.48 2559.79 S 7065.74 W 6810.21 3.49 I 14175.17 92.71 322.87 6202.96 2482.89 S 7124.04 W 6875.11 2.52 14269.72 93.37 322.09 6197.95 2408.00 S 7181.54 W 6939.04 1.08 14365.30 95.92 320.04 6190.21 2333.91 S 7241.40 W 7005.25 3.42 I 14462.31 96.53 317.33 6179.69 2261.48 S 7305.06 W 7075.10 2.85 14559.72 96.13 317.20 6168.95 2190.37 S 7370.76 W 7146.86 0.43 14656.50 97.54 315.08 6157.42 2121.08 S 7437.33 W 7219.33 2.62 I 14752.82 96.17 313.68 6145.92 2054.20 S 7505.68 W 7293.35 2.03 14849.34 95.17 313.48 6136.39 1987.99 S 7575.26 W 7368.54 1.06 14945.76 92.50 312.98 6129.94 1922.11 S 7645.35 W 7444.21 2.82 I 15041.04 91.53 312.45 6126.59 1857.51 S 7715.31 W 7519.63 1.16 15139.55 90.23 313.48 6125.08 1790.38 S 7787.38 W 7597.39 1.68 15234.57 91.02 315.44 6124.04 1723.84 S 7855.19 W 7670.85 2.22 I 15331.83 89.31 315.19 6123.76 1654.69 S 7923.58 W 7745.12 1.78 15429.07 90.39 315.02 6124.01 1585.81 S 7992.22 W 7819.60 1.12 15525.56 90.84 314.49 6122.98 1517.87 S 8060.73 W 7893.88 0.72 15621.90 89.43 313.35 6122.75 1451.05 S 8130.12 W 7968.94 1.88 I 15717.76 90.16 313.61 6123.09 1385.09 S 8199.68 W 8044.09 0.81 15811.70 88.56 313.04 6124.14 1320.64 S 8268.01 W 8117.88 1.81 15909.32 88.82 312.32 6126.38 1254.48 S 8339.76 W 8195.22 0.78 16007.51 86.90 314.31 6130.04 1187.18 S 8411.14 W 8272.31 2.82 16104.81 86.09 315.81 6135.99 1118.43 S 8479.74 W 8346.75 1.75 16200.05 86.58 316.86 6142.08 1049.68 S 8545.36 W 8418.22 1.21 I 16297.30 87.55 317.19 6147.06 978.62 S 8611.57 W 8490.48 1.05 16392.46 86.65 317.04 6151.87 908.99 S 8676.24 W 8561.09 0.96 16491.42 85.38 317.52 6158.75 836.46 S 8743.22 W 8634.24 1.37 I 16588.46 86.66 316.83 6165.48 765.46 S 8809.02 W 8706.10 1.50 16685.31 89.41 317.24 6168.81 694.64 S 8874.98 W 8778.09 2.87 Job No.: AK -MW- 0005710855 Well No.: ODSN -40 End of Well Report Page 5 1 I HALLIBURTON Sperry Drilling Services I Measured Directional Survey Data Vertical Vertical Depth Inclination Direction Depth Latitude Departure Section Dogleg (ft) (deg) (deg) (ft) (ft) (ft) (ft) (° /100') 1 6781.89 90.15 317.65 6169.18 623.49 S 8940.30 W 8849.48 0.88 16876.96 90.47 316.12 6168.66 554.10 S 9005.27 W 8920.36 1.64 I 16973.71 91.07 314.01 6167.36 485.62 S 9073.60 W 8994.50 2.27 17071.76 90.98 312.20 6165.61 418.63 S 9145.17 W 9071.75 1.85 17168.04 90.14 310.87 6164.67 354.79 S 9217.23 W 9149.20 1.63 17265.73 90.65 310.20 6163.99 291.31 S 9291.48 W 9228.79 0.86 17362.42 90.78 309.12 6162.79 229.60 S 9365.91 W 9308.41 1.12 17458.90 90.02 309.91 6162.11 168.22 S 9440.33 W 9388.00 1.14 I 17554.78 89.45 312.73 6162.56 104.92 S 9512.33 W 9465.35 3.00 17651.56 88.07 316.19 6164.65 37.16 S 9581.38 W 9540.14 3.85 17746.64 90.17 317.44 6166.11 32.16 N 9646.44 W 9611.10 2.57 17842.84 90.12 318.02 6165.87 103.34 N 9711.14 W 9681.88 0.61 I 17940.50 90.29 318.62 6165.52 176.28 N 9776.08 W 9753.05 0.64 18036.14 90.83 319.29 6164.58 248.41 N 9838.88 W 9822.01 0.90 18134.78 90.38 320.57 6163.54 323.89 N 9902.37 W 9891.96 1.38 18229.91 90.42 319.98 6162.88 397.05 N 9963.17 W 9959.02 0.62 18327.37 91.43 319.68 6161.30 471.51 N 10026.03 W 10028.25 1.08 18364.00 91.43 319.68 6160.39 499.43 N 10049.72 W 10054.33 0.00 I CALCULATION BASED ON MINIMUM CURVATURE METHOD I SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT VERTICAL SECTION RELATIVE TO WELL HEAD I VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 275.10 DEGREES(TRUE) A TOTAL CORRECTION OF 22.55 DEG FROM MAGNETIC NORTH TO TRUE NORTH HAS BEEN APPLIED I HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD HORIZONTAL DISPLACEMENT(CLOSURE) AT 18364.00 FEET IS 10062.12 FEET ALONG 272.85 DEGREES (TRUE) I I I I I I Job No.: AK -MW- 0005710855 Well No.: ODSN -40 End of Well Report Page 6 I 1 1 Oooguruk ODSN -40 PB1, ODSN -40 PB2 & ODSN- 40 1 Days -vs- Depth 0 Gun &uulu Ce Set I I - ` Start drilling 04/29/08 1000 9 - -- - -- - -- - -- - - 1.6 - - -- —} -- - -- Of0 4 Dr II 12 1/4" Hole f 1 2000 — to 3420.0' MD /1'004.3' ND' Set & cement 9 5/8" casin. PIONEER 3000 — - -/ at-3408-0:1W.2-90.7- 11 - -- - -- - -- - --- --- 1� 4000 - -- - -- _ Plu•• d Back to 51C0' M_D. _ ___ ____L--- _ I Drill 8 3/4" Hole to 8764.0' This chart covers ODSN- 40PB1, PB2 and ODSN 40. Loss MD / 5349.0 TVD ratios forced well planners to sidetrack from the original 5000 - - -- z ------ -- - intermediate path drilled to 8,764', renaming it ODSN- 40PB1. '__ I -A cement plug was set and a sidetrack was made at 5100'. After continuing drilling operations on the production zone, it 6000 --------- - -- - -- — — — was determined the well path had climbed too high and it was - - feared that it had broken through the top of the production I _zone. A second side track was performed at 12,950', leaving 7000 - - -- - -- - -- I -- zone. former section from 12,950' to 13,359' renamed PB2. - • Drilling continued on the production zone to a final TD of Fracture @ 8175' 18,364', where completion work commenced a 8000 - - -- -- — - CD Ar/71777)Clic-7 breath ng problems 0 9000 -13tle- te- treeeetf-er le-1: - • - . - -- , - -- - -- - -- - -- - - -- Fault @ ' i decision was made to pl . back @ . name hanged TD Interme• late 8730' MD 8764' M� Well h g ed Section @1 103' = 10000 - - -- - e° -- - -- -- a; - i s - -- - -- - - -- N A I CU D II 6 118" hole - - - 11000 - - -- - -- - -- - -- — 13359 - -- - - -- 1 12000 - - -- - -- - -- - - •• •• _ Sidetrack ODSN -40 Casing at 11,66' MD �a 12950' 13000 -------- - -- - -- 1 14000 ------------ - -- - -- - -- I Due to dri ling out of pro uction zo e pull up to sif etrack 15000 - - -- - -- - -- - -- - -- ��� r- - .001 failure MOM= _ Ill 16000 - - -- - -- - -- - -- - -- i L TD Production I 17000 — - -- -- Section 18334'MD 09:30 07/16'08 18000 ------------ - -- - -- - -- Run & pLll production tubing 19000 ' , . , . , ' ' ' , . ' ,__ — , ' ' ' ' ' ' , 0 10 20 30 40 50 60 70 80 90 1 Rig Days ■
