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1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Monday, November 21, 2022 2:12 PM To:Mark Igtanloc Cc:Regg, James B (OGC) Subject:RE: CDR2 BOP Test Form for S-106 Attachments:Nabors CDR2AC 10-31-22 Revised.xlsx Mark, Attached is a revised report adding the test type Initial and changing the Misc. Inspections/Misc. “NA”. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Mark Igtanloc <Mark.Igtanloc@hilcorp.com> Sent: Wednesday, November 2, 2022 11:33 AM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Alaska NS ‐ CTD DSM <AlaskaNS‐CTD‐DSM@hilcorp.com> Subject: CDR2 BOP Test Form for S‐106 All, We had 3 Valves that Fail/Greased/Passed and 1 failure on the Blind Shears. The Blind Shears were removed and replaced with a rebuilt set Fail/replace/Pass. There was also a hydraulic fitting on B4 (HCR Valve) that got broke during the Blind Shear repair that passed the initial test. The fitting was replaced and the valve was retested with the Blind Shears and passed. Mark Igtanloc Sr. Drilling Foreman – CTD Rig (907) 670‐3097 Cell (907) 268‐9140 Positional Email AlaskaNS‐CTD‐DSM@hilcorp.com Alternate: John Perl 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. PBU S-106 PTD 2010120 2 Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:CDR2AC DATE:10/31/22 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2010120 Sundry #322-322 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250 /3500 Annular:250 /3500 Valves:250 /3500 MASP:2465 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0 NA Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 0 NA FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2-3/8"P Trip Tank P P Annular Preventer 1 7-1/16" GK P Pit Level Indicators P P #1 Rams 1 Blind / Shear FP Flow Indicator P P #2 Rams 1 2-3/8" Pipe / Slip P Meth Gas Detector P P #3 Rams 1 3.0" Pipe / Slip P H2S Gas Detector P P #4 Rams 1 2-3/8" Pipe / Slip P MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result HCR Valves 2 2-1/16"FP System Pressure (psi)2900 P Kill Line Valves 1 2-1/16"P Pressure After Closure (psi)2200 P Check Valve 0 NA 200 psi Attained (sec)19 P BOP Misc 2 2.0" Piper P Full Pressure Attained (sec)42 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):10 @ 1900 P No. Valves 12 FP ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 5 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 4 P Inside Reel valves 1 P #3 Rams 3 P #4 Rams 4 P Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:4 Test Time:18.5 HCR Choke 1 P Repair or replacement of equipment will be made within 0 days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/29/22 07:11 Waived By Test Start Date/Time:10/31/2022 3:00 (date)(time)Witness Test Finish Date/Time:10/31/2022 21:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Austin McLeod Nabors R2 - Fail/grease/Pass, Blind Shears - Fail/rebuild/Pass, B1 Fail/grease/Pass, B4 Fail/grease/Pass Bottle Pre-Charge is 1050psi R.Coyne / W. Williams Hilcorp M.Igtanloc / T. Kavanagh PBU S-106 Test Pressure (psi): Nathan.Wheeler@nabors.com alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 08/2022)2022-1031_BOP_Nabors_CDR2AC_PBU_S-106 Alaska LLC J. Regg; 11/28/2022 Wallace, Chris D (CED) From: Lopez Keith <Keith.Lopez@eni.com> Sent: Wednesday, August 26, 2020 1:23 PM To: Wallace, Chris D (CED); Regg, James B (CED) Cc: Burgess Larry; Rupert Stephanie; Lopez Keith Subject: ODSK-35A (PTD#2100120) TxIA Communication Mr. Wallace, ENI has completed the tubing leak diagnostics on ODSK-35, finding the tubing has multiple holes in the string. A tubing patch will not be adequate and the well will require a rig workover to change out the tubing string. ENI will continue to review and submit 90 day TxIAxOA pressure trends month to the AOGCC until the well is repaired. Please let me know if the AOGCC has any questions or concerns. Thank you. Keith Lopez Senior Production Engineer Eni Petroleum, Alaska 3800 Centerpoint Drive, Anchorage, AK 99503 Direct 907-865-3316 Mobile 907-903-5432 Keith. LooezO-eni. com ani From: Wallace, Chris D (CED) <chris.waIlace @alaska.gov> Sent: Monday, July 27, 2020 8:46 AM To: Lopez Keit<Keith.Lopez@eni.com>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: RE: Oo guruk Inj MIT's Keith, MITIA extension for ODSK- through September 2020 seems reasonable with the potential logistical and procurement issues noted. Regards, Chris From: Lopez Keith <Keith.Lopez@eni.com> Sent: Thursday, July 23, 2020 10:30 AM To: Regg, lames B (CED) <jim.regg@alaska.gov>; Wallace, ris D (CED) <chris.waIlace @alaska.gov> Subject: RE: Oooguruk Inj MIT's Logistics, crew scheduling, and resources have shown to be much mo difficult lately. We have them scheduled in the next couple of weeks if the schedule holds. Once we conduct the diagnos 'sand confirm that it is or is not repairable we'll know if the tubing patch we currently have will be adequate. If a differe patch is needed it will likely need to be ordered. Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Wednesday, November 13, 2019 8:28 AM To: 'Lopez Keith' Cc: Regg, lames 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 A1034.010 (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 7t" Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallacepalaska.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 MITIA'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 Wallace, Chris D (CED) From: Keith Lopez <Keith.Lopez@caelusenergy.com> Sent: Friday, June 28, 2019 2:42 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Theresa Williams; Mike Morgan; Andy Bond; Oooguruk ProdSuper; Tom Tredway; James Clark; Joel Diselrod; Hart David; Stephanie Rupert; Twogood Christina; Keith Lopez Subject: ODSK-35A (PTD#2100120). TAA Communication Attachments: ODSK-35 90 day TXIAxCA Data 06-28-19.xmi Mr. Wallace, ODSK-35A is a Kuparuk water injector. Today (6/28/18) at 11:05 am, we increased the water injection rate and pressure into the well for injection line pigging operations. Almost immediately we began observing an increase in IA pressure. At 12:20 pm, when it was clear there was communication between the tubing and IA the well was SI pending further diagnostics. Attached you will find the 90 day TxlAxOA pressure data. Please let me know any questions or concerns. • • Wallace, Chris D (DOA) From: Keith Lopez <Keith.Lopez@caelusenergy.com> Sent: Monday, February 12, 2018 8:37 AM To: Schwartz, Guy L(DOA);Wallace, Chris D (DOA) Cc: David Hart;Andy Bond; Mike Morgan;Vern Johnson;John Hellen; Oooguruk ProdSuper; Theresa Williams; Rami Jasser; Robert Tirpack; Keith Lopez Subject: ODSK-35 (PTD#2100120) OAxOOA Leak Attachments: ODSK-35 OOA Leak Diagnostics.pptx; ODSK-35 90 day TxIAxOA Data.xlsx;ODSK-35Ai Schematic Completion Final 08-08-2014.pdf Mr.Schwartz, Caelus Energy is continuing its BlueGoo campaign which includes cutting window's in the conductors of every well to cap with BlueGoo and stop any ongoing shallow surface casing corrosion. On 01/10/18,windows were cut in the conductor of ODSK-35 and diesel was discovered in the OOA. A small amount of diesel was sucked out and the well was monitored with no rise in diesel level. On 01/11/18,the OA was pressured up to 200 psi with nitrogen and the OOA was monitored with no evidence of fluid movement from the OA and a gradual decline in OA pressure. On 02/01/18,the OA was pressured up to 500 psi and a shallow leak from the OA to the OOA was confirmed. The OA pressure history shows only one anomaly on 12/16/17 where the 204 psi showed a gradual decline to 23 psi over a 7 day period. This well is an injector that is rarely taking injection fluids. Caelus plans to keep the well as an active injector with two competent barriers in 1)the tubing string and packer,and 2)the production casing. ODSK-35 last passed its 4 year MITIA on 11/20/15. There are no indications of any communication between the tubing and inner annulus or the inner annulus and outer annulus. Attached you will find TxIAxOA plots and data for the past 90 days and wellbore schematic. We will keep you informed of our diagnostics and planning as it progresses. Please contact me with any questions. Thanks. SCANNED Keith Lopez Production Engineer, Subsurface Direct 907.343.2142 I Cell 907.903.5432 Caelus Energy Alaska 3700 Centerpoint Dr I Ste 500 I Anchorage, AK 99503 Keith.Lopez@caelusenergv.com I www.CaelusEnergy.com CE CAELLS 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,November 23,2015 Jim Regg � P.I.Supervisor el' I( (56 /S SUBJECT: Mechanical Integrity Tests cc `` CAELUS NATURAL RESOURCES ALASK ODSK-35A FROM: Johnnie Hill 000GURUK KUP ODSK-35A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name 000GURUK KUP ODSK-35A API Well Number 50-703-20560-01-00 Inspector Name: Johnnie Hill Permit Number: 210-012-0 Inspection Date: 11/20/2015 Insp Num: mitJWH151122213724 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ODSK 35A (Type Inj N'TVD 5910 ' Tubing 346 347 347 347 - PTD r 2100120 (Type Test SPT Test psi, 1500 - IA 11 802 1951 - 1940 — 1935 - +- - -- Interval �4YRTST lP/F P ,/ OA 199 313 310 - 307 - Notes: 1.6 bbls of diesel used SCANNED SEP 1 6 2016 Monday,November 23,2015 Page 1 of 1 o c 0) W 9 w m m 2 W o a) W C X- p p avi O.en = w O O < < Oa Oo °) 20 Ii 42 0 a) oa) a) oa) 3 • _ C .5 m W W Zt �� Zt m U OW ) 0) W O W O w 0 �0 a i E m LL a'J ce J co E -O OQ OQ pQ J pJ Q �a) 8 � :0 O m o E o E Q{- IC 2 O O Z O Z O Z O Z m y 7 m y 7 co w 0 0 U m m L.L. 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Q M Y °° I' O I � o v) 5� a o I G N M m W = c7 p n CO to , H H ( a 1 Q C Z m o U II Ili E m I i, z a) N C 1' I CrO- O r to o ur m N 0• ;uIt E CL y O N CO o Z Q (`• .0 Z D c V .2 a> O N m '° C F U •? I E a E U �,m a� . a Q U 2 QX U U MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg j L I DATE:Thursday,January 12,2012 � i' i z� P.I.Supervisor ( I SUBJECT:Mechanical Integrity Tests PIONEER NATURAL RESOURCES ALASK ODSK-35A FROM: Matt Herrera 000GURUK KUP ODSK-35A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv; 1I 121 jz NON-CONFIDENTIAL Comm 1J111 Well Name: 000GURUK KUP ODSK-35A API Well Number: 50-703-20560-01-00 Inspector Name: Matt Herrera Insp Num: mitMFH111219085650 Permit Number: 210-012-0 Inspection Date: 12/18/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ODSK-35A Type Inj. W' TV]) 5910 IA 0 1690 1575 1555 P.T.D 2100120 TypeTest SPT Test psi 1500 ' OA 252 418 402 392 Interval INITAL P/F P - Tubing 13 13 13 13 Notes: . II Thursday,January 12,2012 Page 1 of 1 If1G'4,..49GI V GV 4 STATE OF ALASKA JAN . 2012 ALASK IL AND GAS CONSERVATION COMMISS._._ REPORT OF SUNDRY WELL OPERATIONS Alaska Oil&Gas Cons. Commission 1.Operations Abandon Li Repair Well U Plug Perforations U Stimulate U OthArl_4°Mervert to Injector Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Perforate ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Pioneer Natural Resources Alaska,Inc. Development Is Exploratory ❑ 210-012 3.Address: 700 G Street,Suite 600 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99501 _ 50-703-20560-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036 - - ODSK-35Ai 9.Field/Pool(s): Oooguruk-Kuparuk Oil Pool 10.Present Well Condition Summary: Total Depth measured 11,658 feet Plugs(measured) N/A feet true vertical 6127 feet Junk(measured) N/A feet Effective Depth measured 11,652 feet Packer(measured) See Below feet true vertical 6126 feet (true vertical) feet Casing Length Size MD ND Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3219' 9-5/8" 3257' 3049' 5750 3090 Intermediate 9464' 7" 9503' 6100' 7240 5410 Production Liner 2305' 4-1/2" 9348'-11,653' 6083'-6127' N/A N/A Perforation depth: Measured depth: 9367'-11,652' True Vertical depth: 6086'-6126' Tubing(size,grade,measured and true vertical depth): 3-1/2",9.3# L-80,TCII/TSHP 9357'MD 6084'TVD Tbg Retry UltraPak-TH Perm ScSSSV @ 768' Pkr @ 8746'MD/ Packers and SSSV(type,measured and true vertical depth): MD/768'ND 5910'ND 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: 300 523 200 821 312 Subsequent to operation: 0 0 4018 10 0 13.Attachments: 14.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service IS Daily Report of Well Operations X 15.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WAG ❑ GINJ❑ - WINJ El 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: 311-373 Contact Theresa Williams,343-2104 Prepared By:Kathy Campoamor,343-2183 Printed Name Theresa Williams '` Title Staff Operations Engineer Signatures 1 �"I't\\�( Phone.343-2104 Date 1/20/2012 Form 10-404 Revised 7/2009 C " /< Z Ali t,�7 Submit Original Only RBDAAS JAN 2 6 2012 tv PI 0 N E E R - -erations Summary Report-State Well Name: ODSK-35AI NATURAL RESOURCES Well Name: Contractor Rig Number: Job Category: Start Date: End Date: Start Depth FootRMetws Dens last Start Data End Date MKS) 1(f , Mud(lb/gal Summary 12/9/2011 12/10/2011 0.0' MIRU HES slickline unit get tools ready, shut down for the night,waiting on wireline valves to be sling loaded. Property#926524-035 12/10/2011 12/11/2011 0.0 Redeye wireline valves.Finish rig up.MU X-Lock catcher sub,stab on Lubricator on WH,PT to 1100 psi with gas.RIH and set in X nipple at 8666'MD,POOH.MURIH w/3 1/2"OM1,1 5/8" JDS and pull OV from GLM#2 at 8521'MD,POOH.MURIH w/3 1/2"OM1,1 5/8"JDS and 1.5" DMY and set in GLM#2, Bleed down IA,test OK,POOH.RIH w/31/2"GS and pull from X-lok catcher from X nipple at 8666'MD,POOH. P ..>,.. • 6524-035 12/11/2011 12/12/2011 0.0 Rig down HES slickline unit.Bleed IA down to production header pressure.Fluid pack IA •i' 169 bbls of diesel and perform MIT-IA to 1500 psi, initial 1531 psi,15 mkt 1456 psi,30 min 1431 psi,Test past.Turn well over to Ops for completion of piping and instrumentation to well for conversion to an injector. Property*926524-035 Page 111 O®card-- Regg, James B (DOA) zj®-O+l� From: Regg, James B (DOA) Sent: Wednesday, January 11, 2012 12:52 PM ��� �`It f'� To: 'Williams, Theresa' f Subject: RE: ODSK-35A MIT IAs PTD 2100120 Attachments: Industry Guidance 10-02.pdf Thanks for the updated info; please remind personnel performing test about proper test pressures; refer to "Test Pressure" paragraph on page 2 of AOGCC's Industry Guidance Bulletin 10-02 (attached). Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Williams, Theresa [mailto:Theresa.WilliamsCapxd.com] Sent: Wednesday, January 11, 2012 12:47 PM To: Regg, James B (DOA) Cc: Brooks, Phoebe L (DOA); Maunder,Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: RE: ODSK-35A MIT IAs PTD 2100120 Jim, We did test above the minimum 1500 psi, but I documented the wrong 30-minute interval. Attached are the corrected. Theresa Williams (907)343-2104 Office (907)382-3596 Cell From: Regg, James B (DOA) [mailto:jim.regg©alaska.gov] Sent: Wednesday, January 11, 2012 11:59 AM To: Williams, Theresa Cc: Brooks, Phoebe L (DOA); Maunder,Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: RE: ODSK-35A MIT IAs PTD 2100120 Your pre-injection MIT(12/11/11) is a failure based on 2 points: 1) Did not test to at least 1500psi 2) Pressure did not demonstrate a stabilizing trend (1st 15 min pressure loss was 20 psi; 2nd 15 min pressure loss was 26psi) Witnessed MIT on 12/18/11 is a passing test, allowing ODSK-35A to remain on injection. Jim Regg AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: Williams, Theresa [mailto:Theresa.Williams@ pxd.com] Sent: Wednesday, January 11, 2012 8:13 AM 1 To: Brooks, Phoebe L (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: ODSK-35A MIT IAs PTD 2100120 Phoebe, I believe the sundry has been submitted. Theresa Williams Staff Operations Engineer Pioneer Natural Resources Alaska (907)343-2104 Office (907)382-3596 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. 2 (erre C-Sr__e3__e__lrri- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaq(a4alaska.aov; doa.aogcc.prudhoe.bav(rD.alaska.00v; phoebe.brooks @alaska.gov; tom.maunder @alaska.00v OPERATOR: Pioneer Natural Resources � �� !/// FIELD/UNIT/PAD: Oooguruk / Z.— DATE: 12/11/11 OPERATOR REP: Dave Aikey AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ODSK-35A Type lnj. W TVD 5,910' Tubing 13 13 13 13 Interval 1 P.T.D. 2100120 ' Type test P Test psi '1,500' Casing 1 '1,535 `1,456 1,430' P/F P - / Notes: pre-injection V OA 3 3 3 3 (t/ Well Type Inj. TVD Tubing Interval 5�Q e P.T.D. Type test Test psi Casing P/F ` Notes: OA 0/// Well Type Inj. TVD _ Tubing Interval ' —ett'YCi P.T.D. Type test_ Test psi Casing P/F Pr - Notes: OA J � 'ice IL Well Type Inj. TVD Tubing Interval pp50,� - 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 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 ODSK-35A 12-11-11 • 00,1,3 cArGu(4_ O1--7515A 12111"VM1 1:01 19 Mk 1515 9 r., r-- 2 IC)—0( -105 5 pm(0 days.00 30 16) ODSK-35A Pre-Injection MIT IA 12-11-11 - I ■ 1 I I IAPressure(psi) -''''''...-*'s"•-•„„....s...........,...................................._....._ •)::: I 109 ____ .....— OA Pressure(psi) 1 I 00 1 1 1 I 9 3043 AM 056.33AM 101323004 103013004 10:47113444 1t03.53004 53414 12111/2011 12;112011 12112011 12/11/2011 12111)201) 121112911 :2 121'2-F2 F1_272111:'Ets'F.:-02:.'C: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa@alaska.gov; doa.aogcc.prudhoe.bay @alaska.gov; phoebe.brooks(aalaska.gov; tom.maunder @alaska.gov OPERATOR: Pioneer Natural Resources Q.,e I Ic 1 l FIELD/UNIT/PAD: Oooguruk !! {{{/ 2...-- DATE: 12/11/11 OPERATOR REP: Dave Aikey AOGCC REP: Waived Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. •%Min. Well ODSK-35A Type Inj. W - TVD ' 5,910' Tubing 13 13 13 13 Interval I P.T.D.2100120 ' Type test P Test psi • 1,500' Casing 1 - 1,476 1,456 '1,430 P/F Notes: pre-injection OA 3 3 3 3 Well Type Inj. TVD Tubing Interval I. P.T.D. Type test Test psi Casing P/F 5ee a)(-464 Notes: OA /� (xJ /1�n� Well Type Inj. TVD Tubing, Interval C / ' P.T.D. Type test Test psi Casing P/F Notes: OA I I„�tL Well Type In). _ TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD 'ubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Co•.s INTERVAL Codes D=Drilling Waste M=Annulus,onitoring I=Initial Test G=Gas P=Stand- •Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Int, al Radioactive Tracer Survey V=Required by Variance N=Not Injecting A= =mperature Anomaly Survey T=Test during Workover W=Water D Differential Temperature Test 0=Other(describe in notes) CYL \\A./ 4V- Form 10-426(Revised 06/2010) MIT ODSK-35A 12-11-11 °IC5CCrU_Jk.-- Obs -35/4- 10 . t12117::11 l',.'n.•21 AM,1K■5 ca, 2r1 210-01 -105 1 PI(Odeys.00 3002) P re-°InljD2eS}( -cti MIT 11°n--351 lArr IA IA Pressure(psi) -N , .,.„..,.......,............ ..,......_............' I 1 ' I II 1 1 ,.. - 1, t 1 , I i , I I- , , . tOA Pressure(psi) t II/21.155n 0111 1001:40.61 12111/2011 102024AM iznyzoll 1039-08 AM 12111/2011 1M52031.14 11)1613/10114 122.140.12452 P1272166 leaf(t-000000.19 240! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reao alaska.gov; doa.aoacc.prudhoe.bavCaDalaska.gov; phoebe.brooksaalaska.gov; tom.maunder(rdalaska.aov OPERATOR: Pioneer Natural Resources 'Rget4of f if i(It's FIELD/UNIT/PAD: Oooguruk DATE: 12/18/11 OPERATOR REP: Dave Aikey AOGCC REP: Matt Herrera Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ODSK-35A Type lnj. W TVD 5,910' Tubing 13 13 13 13 Interval P.T.D.2100120 Type test P - Test psi 1,500' Casing 1 -1,691 ' 1,575 -1,555 P/F P Notes: Initial test post-injection OA 252 420 402 393 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 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 ID=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 ODSK-35A 12-18-11 &Xrja 065K-7'54 • 121182011 101047441 1891 Zi Bli) -136.3 psi(0 days.DD 3014) ODSK-35A Initial MIT LA 12-18-11 LA PressLre(psi) • OA Pressure(psi) .• • 1030:40 AM 104036 Af4 10.5 r2iY4 1100.28 N4 11:1024M1 12,16 2:11 1218/2011 121&2011 18/18/2011 12/18/2011 12/189011 132.168124,52:P1_2721ES fErsfit-00 00:00-.10.191! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE:Monday,December 19,2011 P.I.Supervisor N�- i�4 ft SUBJECT:Mechanical Integrity Tests PIONEER NATURAL RESOURCES ALASK ODSK-35A FROM: Matt Herrera 000GURUK KUP ODSK-35A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name: 000GURUK KUP ODSK-35A API Well Number: 50-703-20560-01-00 Inspector Name: Matt Herrera Insp Num: mitMFH111219085650 Permit Number: 210-012-0 Inspection Date: 12/17/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ODSK-35A Type Inj. W TVD 5910 IA 0 1690 - 1575 1555 P.T.D, 2100120,TypeTest SPT Test psi 1700 OA 252 418 402 392 Interval INITAL p/F P - Tubing 13 13 13 13 Notes: Lk(iSitsICL Monday,December 19,2011 Page 1 of 1 IkTS [ /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 Sr. Staff Completions Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 1 i G - 00 Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK-35Ai Sundry Number: 311-373 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 or weekend. Sin,ere l 4/ n mis '• er DATED this 4 day of December, 2011. Encl. 4 , T RECEIVED \\\ STATE OF ALASKA �Jr l 0 1 2011 \WV ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVE Oil&Gas Cons.Commission 20 AAC 25.280 Anchorage 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well❑ Change Approved 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 Resourcs Alaska, Inc. Development p . Exploratory ❑ 210-012 . 3.Address: 700 G Street, Suite 600 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99501 50-703-20560-01-00 ' 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 0 ODSK-35Ai 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036 . Oooguruk-Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,658' 6127' . 11,652' 6126' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 3219' 9-5/8" 3257' 3049' 5750 psi 3090 psi Intermediate 9464' 7" 9503' 6100' 7240 psi 5410 psi Production Liner 2305' 4-1/2" 9348'-11,653' 6083'-6127' N/A N/A Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9367'-11,652' 6086'-6126' 3-1/2",9.3# L-80,TCII/TSHP 9357' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Tubing Retrievable ScSSSV; UltraPak-TH Hyd Perm Pkr 768'MD/768'TVD;8746'MD/5910'ND 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: 12/7/2011 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 Sr.Staff Completions Engineer Signature s"--- Phone Date 12/1/2011/2011 Prepared By:Kathy Campoamor,343-2183 _ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: C/ 1 ( ^' ---7 5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test [ Location Clearance ❑ Other: :::::::0rm Required: /D I APPROVED BY � LL "fJ MMISSION R THE COMMSION Date: -/�O► Form 10-403 Revised�201" I O Ti( l2.5 l� Submit in Duplicate iii RIGINAL 4t PM, ODSK-35Ai Oooquruk - Kuparuk Injection Well Well Conversion Slickline Work This Sundry Application serves as notice of Pioneer's intent to inject seawater into the Kuparuk formation via ODSK-35Ai. Objective: Recomplete ODSK-35Ai as an injection well in the Kuparuk formation. General Program: 1. Ensure that sundry from the state has been received for the conversion of this well to an injector. 2. MIRU Slickline unit. SI lift gas and let well de-pressure through open wing. RIH with gage ring to gage tubing and ensure there is no build up in the tubing. 3. Look for FL as POH with tool string and shoot FL in IA. An accurate pressure can then be calculated at the lowest GLV prior to pulling the SO at 8521' MD. 4. RIH and set catcher plug in X nipple at 8666' MD. 5. Pull screened orifice from GLM @ 8521' MD. 6. Set dummy in pocket. Bleed IA pressure down to ensure valve is set. 7. Fluid pack IA and pressure test to 1500 psi. Ensure there is a trend set up to record this test. This test should be held for 30 minutes. Fill out MIT-IA Form and send to Kathy Campoamor for 10-404 submission. S-��o Tvo K /4/77fls` 8. RIH and pull the catcher plug. RD Slickline. 9. Freeze protect well if not yet ready for injection. 10.If well is ready to put on injection and the necessary Sundry Notice has been approved, pump 10 bbls 50/50 MEOH and swap to water. 11.After 10 days of injection, shoot FL in IA. Notify Sate representative of intention to do initial MIT-IA 24 hours prior to test. 12.Fluid pack IA as needed with diesel based on the FL shot. 13.MIT-IA to 1500 psi. Ensure trend is set up and recording during this pressure test. 14.Fill out the appropriate form and forward both form and trend to Theresa Williams. ODSK-35Ai Page 1 • MIT-IA Prior to beginning injection a MIT-IA must be performed to a minimum of 1500psi. Please contact AOGCC representative for state witnessing of pressure test. Verify that Form 10-403 Application for Sundry Approval has been signed or that verbal authorization from state has been granted prior to injection. Area Injection Order 34 Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, and before returning a well to service following a workover affecting mechanical integrity. A Commission-witnessed mechanical integrity test must be performed after injection is commenced for the first time in a well, to be scheduled when injection conditions (temperature, pressure, rate, etc.) have stabilized. Subsequent tests must be performed at least once every four years thereafter(except at least once every two years in the case of a slurry injection well). The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressur'- of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is gre. - • shows stabilizing pressure and does not change more than 10 percent during a 30- minute period. Results of mechanical integrity tests must be readily available for Commission inspection. ODSK-35Ai Page 2 ODSK-s5Ai Injector - Final Completion Casing OWell Head: 9-5/8",5K,VetcoGray Item# Item MD(ft) TVD(ft) Tree: 3-1/2",5K,Horizontal A 16"Conductor 158 158 B 9-5/8"40#L-80 BTC, 8.835" ID 3,257 3,049 C 7"26#L-80 BTC-M 6.276" ID 9,503 6,099 D 4-1/2" 12.6#L-80 IBT-M (Slotted Liner) 11,653 6,070 A O O E 3-1/2"9.3#L-80 TC IUTSHP 9,357 6,085 *Estimated 7"TOC @ 8503'MD (ft) TVDrkb(ft) 1 VetcoGray Tubing Hanger 33 33 HES Wellstar TRSSSV w/31/2"9.2#TC-II Box x Pin 9 Chr w/ 2 2.813"X' Profile w/ 1/4"x .049 SS CL to Surface 768 768 GLM#1 HES Vanoil 3W x 1W Gas Lift Mandrel w/31/2"9.2#TO 3 II Box x Pin w/Dummy in place 2,086 2,075 O E GLM#2 HES Vanoil 31/2"x 1'/2'Gas Lift Mandrel w/TA" 9.2#TO II . II Box x Pin w/Orifice Valve installed(min. 2 jts above top X O4 nipple) 8,521 5,805 HES ROC Gauge&Carrier w/3%"9.2#TC-ll Box x Pin(min. 1 O J 2 O V- ' 5 joint above X nipple) 8,613 5,849 HES 2.813"X'Nipple 9 Chr w/3%"9.2#TC-ll Box x Pin(min 2 6 jts above packer) 8,666 5,876 Weatherford 4%13.5#x 7"23-32#Model"Ultra Pak-TH" Hydraulic Set Permanent Production Packer w/4% 13.5#New 7 Vam Pin x Pin 8,746 5,910 HES 2.813"X"Nipple 9 Chr w/3%"9.2#TC-ll Box x Pin(min 1 jt 8 above XN nipple) 8,832 5,944 HES 2.813"XN" Nipple w/2.750" No-Go 9Chr w/3W TCII Box x O $�5Z/, 9 Pin w/"RCH-M" Plug in Place(min 2 joints below packer) 8,905 5,968 J 10 WLEG w/3%"TCII Box 9,356 6,084 End of Assembly 9,357 6,085 Lower Completion Item # Item MD(ft) TVD(ft) 11 WFT PBR Tie Back Sleeve 10ft 9,348 6,083 12 WFT"NTH" Liner Top Pkr(7"23-32#X 5" 15#) 9,359 6,085 O 0 _ 13 WFT"PHR" Rotating Hyd Set Liner Hanger(7"23-32#X 5" 15#) 9,362 6,085 0- ■ ■ 5-130' 14 4-1/2" 12.6#L-80 IBT-Mod Slotted Liner 9,366 6,086 15 Liner Shoe 11,652 6,070 0 < 'TVD End of Assembly 11,653 6,070 OO NI 11 ■ ■ 10 as 0 14 O® P 10 N E E R Date: Revision By: Comments 1/10/2010 jdf Proposed Completion RESOURCES � �'` 1/21/2010 TWC Revised Format and Depths ''j lURAL A �N 1 2/26/2010 JAD Revised for Repermit ODSK-35Ai Injector Well Schematic 3/31/2010 jdf Final completion 04/08/2010 TWC Final Edits Before Submission to AOGCC Z,'o- b! - I CHA.NICAL INTEGRITY REPORT U D - 3////l O OPER & FIELD [7'on �oQ SK - 3S -•_G r 372/1 U WELL NUMBER Q(� A ',TELL DATA TD : // 65-8.1-0.. C�(27T D ; PBTD : ?ID TVD t (Sb3 Casing : 7 << Shoe : MD Co(66 TVD ; DV : 1.9) _T ZID N ,/ 9 ae= : L( S Shoe : 11653 I t (Z7 Tom ; :-OP : ?.� D S1oCT�' -= �", :.:bi g .3l Packer r7'jG 5 'a' TVD ; Set at u 5,31219 5,31219 to //653 • Hole Size �� and Pe r±s 5(a4->r Lc..at C A.N CAL INTEGRITY - PART 11 Annulus Press Test: :P 17/66k) ; 15 min -- ; 30 min - . Comments : c. J ay. • 74 V6 ' -s� - � " CHp N I CAL INTEGRITY - PART 12 7L Cement Voltmies : Amt. Liner ; Csg y0 + ; D�� C ' Cr.t vol to cover Der::s tS/' ! � �'Y7 2 11 b6/ Theoretical TOC 7f 86 c,/ Cement Bond Log ciggio or No) /( / ; In AOGCC File CBL Evaluation, zone above perfs C/ - o/< enel , ./ O . 1W Production Log : Type ; Evaluation CONCLUSIONS : _ art 11 : M ( CSQ-C�X�� STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANI:tilt035 2010 la.Well Status: Oil 1111 Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well _ 20AAC 25.105 20AAC 25.110 Developr��� - i•.,t i��$IOr GINJ ❑ WINJ❑ WAG ❑ WDSPL❑ No.of Completions: _One Service ❑ St- :�::'r"s °�e�sstt LL❑J_l 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Aband.: 3/30/2010 210-012 3.Address: 700 G Street,Suite 600 6.Date Spudded: 13.API Number: Anchorage,AK 99501 3/13/2010 50-703-20560-01-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: pry"f"-,A'") Surface: 2955'FSL, 1111'FEL,Sec. 11,T13N, R7E, UM 3/26/2010 ODSK-35Ai , Top of Productive Horizon: 8.KB(ft above MSL): 56.2' 15.Field/Pool(s): 1655'FSL,4894' FEL,Sec.2,T13N, R7E, UM GL(ft above MSL): 13.5' Total Depth: 9.Plug Back Depth(MD+TVD): Oooguruk-Kuparuk Oil Pool 3402'FSL,858'FEL,Sec.3,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- 469886.60 y- 6031070.76 Zone-AsP 4 11,658'MD/6127'TVD ADL 355036 TPI: x- 466117.09 y- 6035066.81 Zone-AsP 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 464879.37 y- 6036818.80 Zone-AsP 4 768'MD/768'TVD 417497 18.Directional Survey: Yes Q No U 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) 825'MD/823'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: Gyro, GR, DM, PWD,ABI,ADR,ALD,CTN, BAT N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING �. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109# H-40 Surface 158' Surface 158' 24" Driven 9-5/8" 40# L-80 BTC Surf ace 3257' Surface 3049' 12-1/4" 438 sx PF'L;201 sx Class'G' 7" 26# BL-80 Surface 9503' Surface 6100' 8-3/4" 189 sx Class'G' 4-1/2" 12.6# IBT M 9348' 11,653' 6083 6127 6-1/8" Uncemented 24.Open to production or injection? YesU No[] 1-,ygs,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size a'd WillkirliON SIZE DEPTH SET(MD) PACKER SET(MD/TVD) le r.!' 8 3-1/2",9.3#, UltraPak TH Hyd � �ttt�CC•ft L-80,TCII/TSHP 9357' Perm Packer 4-1/2", 12.6#, L-80 Slotted Lineri'J�L_. 8746'MD/5910'TVD MD TVD !"" 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 9367'- 11,652' 6086'-6126' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1984' Freeze Protect 9-5/8"x 7"Annulus w/56 bbls diesel 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 4/2/2010 Flowing _ Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 4/12/2010 11.2 Test Period 841 873 20.5 3" 1038 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 1259 1394 24-Hour Rate -4 1796 1864 43.8 26.0 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No 0 Sidewall Cores Acquired? Yes❑ No El 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. None RSDMS APR 3.O M Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 24 ,r Submi 4/2,4 G b 1-lv 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes U No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top 835' 835' and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1660' 1658' Top West Sak 2315' 2291' Top Tuffaceous Shale 3123' 2948' None Top Torok 6882' 5024' Base Torok 7482' 5299' Top HRZ 8549' 5821' Base HRZ 8858' 5953' Kalubik 9108' 6032' Top Kuparuk 9471' 6097' vG �.� j sw' -� k ' e, S``" 1s Formation at total depth: 11,658' 6127' 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: Alex Vaughan,343-2186 Printed Name: Ver .� ns, / Title: Drilling Superintendent Signature: �- `{(3o(io Phone: 343-2111 Date: 4/29/2010 Well Name:ODSK-35Ai Permit No.:210-012 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 1 b: 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 Operations Summary Report NATURAL RESOURCES Well Name: ODSK-35Ai Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Start Date: 3/13/2008 End Date: 3/30/2010 Depth Start Foot/Meters F Last Mud Start Date End Date (ftKE) (ft) Dens(1b/gal) Summary, 3/10/2010 3/11/2010 3,267.0 0.00 Slip and cut drill line. PU 5"drill pipe,and rack back same in derrick--30 stands racked back. Prep rig for rig move.Skid from ODSN-30,and spot substructure and pit/pipeshed complex over ODS-35Ai. Level rig substructures and pits. RU HUTZ/PUTZ, pipe skate,stairway landings and berms. ND tree and set test dart in tubing hanger. NU BOP stack with choke and kill lines. NU MPD equipment. i 3/11/2010 X3/12/2010 3,267.0 ` `` 0.00 NU bell nipple, install and tighten turn buckles. Install test dart into landing joint and attempt to MU same--unsuccessful. Pull test joint and verify test dart was made up correctly, install same without issues. RU test equipment.Attempt to test annular preventer to 250 psi,found leak on Y4; -, flange,also found leak on choke manifold flange.Tighten up both flanges.Test annular preventer to 250.psi low/2500 psi high with 5"test joint.Attempt to test top pipe rams unsuccessful.Apply 3000 psi closing pressure and function rams several times to break in new r r ram seals Test Upper and Lower 2-7/8"x 5"VBR's with 2 7/8"and 5"test joints,Kill&Choke line HCR valves, Kill&Choke Line Manual valves, 14 Choke Manifold valveloor&Dart Safety valves,Upper&Lower IBOP's to 250 psi/4500 psi.All low/high tests held 5 min and I charted.Accumulator Test System Pressure 3050 psi, Pressure After Closure 2200 psi, Initial 1200 psi Attained 12 seconds, Full Pressure attained 1 min 43 seconds.AOGCC rep Bob Noble on location to witness BOPE test. Pull BPV from tubing hanger and MU landing joint to same. Unseat hanger with 60k and pull same to rig floor. POOH with 2-7/8"tubing laying down same f/2,205'1/1,134'. .,4 „" , % .3' y IA, 3/12/2010 3/13/2010 3,267.0 0.00 POOH with 2-7/8"tubing laying down same f/1,134't/surface.TIH with 5" DP f/surface t13,040'. Circulate 250 bbls seawater.Open annular preventer and circ 85 bbls seawater. POOH(/3,040' V surface. MU Johnny whacker and TIH picking up 96 5"singles from the pipe shed f/surface 11/3,040'.Circulate 85 bbls seawater(1.5 x DP capacity). POOH f/3,040'V surface racking back ,clean DP in derrick. MU Johnny whacker and TIH picking up 96 5"singles from the pipe shed f/ surface t/3,040'. Circulate 85 bbls seawater(1.5 x DP capacity). POOH f/3,040'1/475'racking back clean DP in derrick. 3/13/2010 3/14/2010 3,267.0 516.00 9.80 POOH f/475'1/surface.TIH picking up 5"HWDP.Circulate 15 bbls seawater(1.5 x HWDP capacity). POOH f/476't/surface. PU and MU bit,mud motor,and MWD tools. Plug in and attempt to upload MWD data--No communication with upper buss.Troubleshoot same. Replace kemlon connector and MU same. Upload MWD data.Shallow pulse test MWD--Good ' test.TIH with remainder of BHA t/548'.TIH f/548'112,736'.Wash and ream f/2,736' V3,171'. Tagged plugs at 3,171'. Drilling cement,float equipment and 20'new hole f/3,171't/3,287'. Perform leak off test at 3,267'md,3,049'tvd,with 9.8 mud wt.in and out;leaked off 780 psi jfor EMW of 14.6 ppg. Drilling and sliding f/3,287'1/3,783. i 3/14/2010 3/15/2010 3,783.0 1,047.00 9.80 Drilling and sliding(/3,783'1/3,878'. Change out liner and piston on#1 mud pump#2 piston. Drilling and sliding f/3,878'113,973'. Lost electrical communication with top drive--troubleshoot same. Drilling and sliding f/3,973'V4,164'. Lost electrical communication with top drive,circulate hole clean.Change out communications wire on top drive. Drilling and sliding(/4,259'114,830'. 3/15/2010 3/16/2010 4,830.0 1,427.00 9.80 Drilling and sliding f/4,830 t/6,25T.., 1 I '3/16/2010 3/17/2010 I 6,257.0. 1,332.00 9.801Drilling and sliding f/6,257'V7,589'. Pump 40 bbls hi-vis weighted sweep and circulate hole clean with 3x bottoms up strokes. POOH f/7,589'116,637'. 3/17/2010 3/18/2010 7,589.0 246.00 10.10 POOH 1/6,637'1/surface.Download MWD data. LD of BHA. Pull wear bushing and install test „' plug, RU MPD lines to rotating head and install RCD test flange.Test MPD lines,valves,RCD body� 25 tannds.Wash and 4500 psi high--all tests V7,589'.CBU.Remove trip p nipple ple min each.and install RCD RCpipe d. y Upload MWD data files.TIH with remainder of the BHA to 548'.TIH f/548'117,113'fill every 1 Directional drilling f/7,589'V7,835'maintaining 12.48ppg EMW with MPD. I 3/18/2010 3/19/2010 7,835.0, 1,515.00 10.50 Directional drilling 8-3/4"Section f/7,835'V9,350',while maintaining 12.6 ppg EMW using MPD le ui ment,w/10.5 MW. I � � q P ppg 1 i Page 1/3 Report Printed: 4/29/2010 PIONEER )perations Summary Report 1 NATURAL RESOURCES Depth Start F Last Mud ;date (ItKB) € dens(Ib/gal) Summary 3/19/2010 3/20/2010 9,350.0 160.00 12.90 Directional drilling f19,350't/9,510'"TD".Pump 40 bbls hi-vis LCM sweep and circulate hole clean with same.Back ream out the hole f/9,510't18,445'.CBU at 8,445'. POOH f/8,445' 'C'"� t18,159'.Shut annular preventer to maintain MPD pressure and change out RCD head.TIH f/8,159'V9,301'while maintaining 12.9ppg EMW with MPD equipment.Wash and ream f/9,301' V9,510'. Pump 40 bbls hi-vis sweep and circulate hole clean with same.Weight up mud from 10.5 ppg to 12.9 ppg using 17.0 ppg spike fluid while backing off of MPD pressure to maintain minimal ECD's. Pull RCD head and install trip nipple, (flow check well-static). 3/20/2010 3/21/2010 440 l „, 0.00 12.90 TN f/9,491'V3,212'.Slip and cut drill line.TIH f/3,212'V the BHA.LD BHA.Pull weer bushing '^ 1- and install test plug.Change out lower VBR's to 7"casino rams.Test lower 7"casino rams to l 250 psi low and 4500 psi high held 5 min on chart--Good test.RU 7",casing equipment and f ' held pre job safety meeting.MU float equipment Circulate through same and continue to RIH with 7",L-80,26#,BTC-M casing f/surface c�, �. `,fs ; 3/21/2010 3/22/2010 9,510.0 0.00 8.60 RIH with 7",L-80,26#,BTC-M casing f/2,039'V9,459'w/o returns, (some partial returns).PU& MU Hgr/Ldg Jt and RIH f/9,459'V9,503'and land hanger with 75k down weight. RU cement head and lines,after problem w/Franks tool rubber failing prematurely.Staged pump up to 4 bpm=1450psi with trickle or no returns,continue to attempt est.circulation on up strokes only &then turn pump to 3-5spm for travel down stroke.Able to reciprocate casing string while attempting to est.circulation also. Pumped 1x bottoms up strokes without returns. 11.4ppg MW out/10.6ppg MW in.Transfer 450 bbls 10.Oppg dirty brine from RSC to rig pits.PJSM.Pump 10 bbls seawater.Test cement lines to 4500 psi. Drop 1st plug.Load Top Plug. Pump 55 bbls 12.5 ppg Dual Spacer.Drop 2nd Plug.• / r%Pump 39.38 bbls j189 sxl 15.8ppg "G"cement.prop Top Plug. Pump 20 bbls seawater. �'/h�4t Switch to Rig and displace with 10.0 ppg brine at 4-8 bpm.At 3,974 stks slowed pumps to 3 rY bpm.Bumped plug w/4,114 stks.CIP @ 16:34 hrs.Pressure up to 4500 psi and held 5 min, G Bled off pressure,bled back 3.6 bbls--floats holding.RD cement head and lines.Install pack off on 7"casing hanger and test same to 5000 psi on chart for 10 min--Good test. RD casing equipment. LD 5"DP from derrick to the pipe shed. 3/22/2010 3/23/2010 9,510.0 0.00 8.60 LD 5"DP from derrick to the pipe shed.Change out IBOP,saver sub,and stabbing guide on top „, ;drive to 4".Change out lower rams from 7"casing rams to 2 7/8'X 5"VBR's.MU 4"diverter tool and TIH picking up 4"singles from the pipe shed V8,448'.Circulate with seawater to insure no obstructions in pipe.POOH f/8,448'V surface racking back clean DP in derrick.MU 4"diverter tool and TIH picking up 4"HWDP,Jars, bumper sub,and DP from the pipe shed V669'. 3/23/2010 3/24/2010 9,510.0 0.00 8.70 TIH picking up 4"DP from the pipe shed f/669'V3,364'md.Circulate with seawater to insure no obstructions in pipe. POOH f/3,364'V surface.Slip and cut drill line. Remove wear bushing and install test plug.Test Annular to 250/2500psi,Test Upper and lower 2-7/8"x 5"VBR's,Blind rams,Kill&Choke line HCR valves, Kill&Choke Line Manual valves, 14 Choke Manifold valves, Floor&Dart Safety valves,Upper&Lower IBOP's to 250/4500 psi.All low/high tests held 5 min and charted. Accumulator Test,System Pressure 3100 psi, Pressure After Closure 2100 psi, Initial 200 psi Attained 25 seconds, Full Pressure attained 2 min 24 seconds.AOGCC representative Jeff Jones waived witness of BOP test at 09:00 hrs on 3/20/10. Pull test plug and install wear bushing.TIH with BHA to 409'.Shallow pulse test MWD--Good test.TIH f/409' V8,777'.Log down with BAT Sonic tool at 300'per hour f/8,777'V9,264'--tagged cement stringers.Wash and ream in the hole f/9,264'V9,410'.Pump 40 bbls hi-vis spacer and displace 10.0 ppg brine with 8.6 ppg mud.Calibrate oscillating feature on top drive and review operating procedure with Canrig rep. Page 2/3 Report Printed: 4/29/2010 PIONEER )perations Summary Report NATURAL RESOURCES Depth Start Foot/Meters Last Mud i Start Date Six!Date , {ftKt3) ', (ft) Dens(Iblgal) ', Summary', 4 � ,�‘. •; 3/24/2010 3/25/2010 9,510.0 522.00 8.70 Pressure test 7"_26#L-80 BTC;M casing to 4500 psi.Held pressure 30 min and charted same. Clean out 7"shoe track(/9,410' t/9,468'. Remove Trip Nipple and install MPD RCD element. Cleanout remaining shoe track 1/9,503'and cleanout 8-3/4"rat hole 1/9,510'.Drill new 6-1/8" hole 1/9,520'.Circulate&condition mud, MW in 8.6 ppg,MW out 8.6 ppg. Performed FIT to 12.5 ppg EMW at 6,100'TVD with 1237 psi WHP. Performed Formation Pore Pressure Test from 9.8ppg EMW=380 psi WHP,reduced in 63psi increments,(equal to.2ppg reduction in EMW), to 8.6 ppg EMW=0 psi WHP.This built back to 29psi in 3-5min's,w/Pore Pressure EMW being 8,6 -8.7PPG,w/0-32psi WHP.prepare to drill ahead,maintaining a 9.8ppg EMW w/8.8ppg MW,using 100%open Chokes from MPD. Drill f/9,520' 1/10,032'md, Lateral Section per WP #09,Well Site Geologists. e � f r; 8.75 Drill 6-1/8"hole f/10,032' t/11,093'.ECD 10.15 ppg. 3/26/2010 3/27/2010 11,093.0 565.00 8.60 Drill f/11,093' 1111,658'holding10.25 ppg ECD w/MPD.Circulate 45 bbl Hi-Vis LCM sweep S/S.POOH f/11,658' 1/9,453'. 3/27/2010 3/28/2010 11,658.0 0.00 9.00 RIH f/9,453' 1111,658'.Circulate Hi-Vis LCM S/S. Pump and spot new 8.6 ppg WBM in open hole lateral section. POOH f/11,658' 119453'. Pump 20 bbls Hi-Vis 9.4 ppg Brine spacer.POOH 119,067'.Displace 8.7 ppg mud with 9.4 ppg Brine. Remove RCD element and install Trip Nipple. POOH f/9,067' 11406'.POOH and LD BHA#4. RIH w/21 Jts 4" HWDP,flush same, POOH and stand back in derrick. RU and RIH w/4-1/2" 12.6#L-80 IBT-M Slotted Liner. 3/28/2010 3/29/2010 11,658.0 0.00 9.00 RIH w/4-1/2" 12.6#L-80 IBT-M Slotted Liner f/84' 1/2,285'. PU Hanger/Pkr, Running Tool and Bumper Sub. RIH 1/2,421'. PU Magnet Assy and 7"Csg Scraper.RIH w/4-1/2"Liner on 4"DP 1/9,436'.Circulate DP volume. RIH w/4-1/2"Liner 1/11,653'. Drop 1-3/4"Ball and set Hgr w/ 1500 psi and 45K SOW. Release from liner and set Pkr w/65K SOW.Test Pkr V 3500 psi.Held pressure 30 min and charted same.Circulate Baraclean pill and 2 ea Hi-Vis sweeps S/S. POOH w/4"DP&Liner Running Tool. Flush BOPE stack. PU 3-1/2"Test Jt and install Test Plug., tegoi 0.00 9.00 Test Annular to 250 psi low/2500 psi high.Test Upper and Lower VBR's(2-7/8"x 5")Rpms to 250 psi low/4500 psi high.All tests held 5 min each and charted.RU to RIH w/3-1/2"Tbg.PU , � � ' W/LEG and RIH w/3-1/2"9.3#L-80 TCII/TSHP Completion Tubing 118,987'; • 3/30/2010 3/31/2010 11,658.0 0.00 6.80 RIH w/3-1/2"9.3#L-80 TCII/TSHP Completion Tubing V9,323'. PU Tubing Hanger(TWC installed in Hgr)and land Tubing at 9,357'.Test Upper and Lower Hgr seals to 5000 psi.ND BOPE's.NU Production Tree.Test tree V 250/5000 psi and charted same. Remove TWC. Displace 9.0 ppg Brine with Diesel. Drop Ball and Rod.Set Pkr w/4500 psi on Tubing.Test Pkr w/4600 psi on 3-1/2"x 7"Annulus. Pkr set and test held 30 min each and charted. RD Circulating Manifold.Clean cellar and Wellbay areas. **Rig released from ODSK-35Ai at 24:00hrs on March 30th,2010" Page 3/3 Report Printed: 4/29/2010 ODSK-35Ai Injector - Final Completion _ Casing OWell Head: 9-5/8",5K,VetcoGray Item # Item MD(ft) TVD(ft) Tree: 3-1/2",5K, Horizontal A 16" Conductor 158 158 B 9-5/8"40#L-80 BTC, 8.835" ID 3,257 3,049 C 7"26#L-80 BTC-M 6.276" ID 9,503 6,099 D 4-1/2" 12.6#L-80 IBT-M (Slotted Liner) 11,653 6,070 E 3-1/2"9.3#L-80 TC-II/TSHP 9,357 6,085 O 2 CD *Estimated 7'TOC @ 8503'MD peer Completion gomdt. :,,Jfam ,..,,_, .,.,.,.„>-... ,,: MDrkb(ft) TVDrkb(ft) 1 VetcoGray Tubing Hanger 33 33 HES Wellstar TRSSSV w/3'/2'9.2#TC-ll Box x Pin 9 Chr w/ 2 2.813"X' Profile w/ 1/4"x .049 SS CL to Surface 768 768 GLM #1 HES Vanoil 3'/2"x 1'/2" Gas Lift Mandrel w/3'/2"9.2#TC;H. _ 3 II Box x Pin w/Dummy in place 2,086 2,075 O GLM #2 HES Vanoil 3'/2"x 1'/2" Gas Lift Mandrel w/3'/2" 9.2#TO B II Box x Pin w/Orifice Valve installed (min. 2 jts above top X 4 nipple) 8,521 5,805 HES ROC Gauge& Carrier w/3'/2'9.2#TC-II Box x Pin (min. 1 O J 5 joint above X nipple) 8,613 5,849 HES 2.813"X' Nipple 9 Chr w/3'/2" 9.2#TC-II Box x Pin (min 2 6 jts above packer) 8,666 5,876 Weatherford 4'/2 13.5#x 7"23-32#Model"Ultra Pak-TH" Hydraulic Set Permanent Production Packer w/4'/2 13.5#New _ 7 Vam Pin x Pin 8,746 5,910 HES 2.813"X' Nipple 9 Chr w/3'/2" 9.2#TC-II Box x Pin (min 1 jt _ 8 above XN nipple) 8,832 _ 5,944 HES 2.813"XN" Nipple w/2.750" No-Go 9Chr w/3'/2"TCII Box x _ 9 Pin w/"RCH-M" Plug in Place(min 2 joints below packer) 8,905 5,968 4 _j 10 WLEG w/3'/2"TCII Box 9,356 6,084 End of Assembly 9,357 6,085 Lower Completion Item# Item MD(ft) I TVD(ft) 11 WFT PBR Tie Back Sleeve 10ft 9,348 6,083 12 WFT"NTH" Liner Top Pkr(7"23-32#X5" 15#) 9,359 6,085 O C� 13 WFT"PHR" Rotating Hyd Set Liner Hanger(7" 23-32#X 5" 15#) 9,362 6,085 O II M/ 14 4-1/2" 12.6#L-80 IBT-Mod Slotted Liner 9,366 6,086 15 Liner Shoe 11,652 6,070 O7 End of Assembly 11,653 6,070 OO • ■ ■ 11 10 ' I��� 12 13 ,:_, 14 0• Pn Date: Revision By: Comments 1ON Il l` 1/10/2010 jdf Proposed Completion 1/21/2010 TWC Revised Format and Depths NATURAL RESOURCES ALASKA 2/26/2010 JAD Revised for Repermit ODSK-35Ai Injector Well Schematic 3/31/2010 jdf Final completion 04/08/2010 TWC Final Edits Before Submission to AOGCC Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSK-35Ai North Reference: True Wellbore: ODSK-35Ai Survey Calculation Method: Minimum Curvature Design: ODSK-35Ai KupH Surveys Database: .Pioneer Alaska Project Oooguruk Development 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 Well ODSK-35A1-Slot ODS-35 Well Position +N/-S 0.00 ft Northing: 6,031,070.76 ft Latitude: 70°29'45.448 N +E/-W 0.00 ft Easting: 469,886.60 ft Longitude: 150°14'46.452 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft Wellbore ODSK-35Ai Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 2/7/2009 22.39 80.81 57,722 Design ODSK-35Ai KupH Surveys Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,216.69 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (T) 42.70 0.00 0.00 318.45 Survey Program Date 3/31/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 100.00 722.00 ODSK-35 KupB Gyro Surveys(ODSK-3f SR-Gyro-SS Fixed:v2:surface readout gyro single shot 2/7/2008 12: 764.01 3,216.69 ODSK-35 KupB MWD Surveys(ODSK-3 MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 2/7/2008 12: 3,270.11 7,553.45 ODSK-35Ai Int 1 MWD(ODSK-35Ai) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 3/9/2010 12: 7,651.30 9,501.28 ODSK-35Ai Int 2 MWD(ODSK-35Ai) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 3/31/2010 t 9,532.31 11,609.99 ODSK-35Ai Horiz MWD(ODSK-35Ai) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 3/31/2010 t Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°lief)') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,070.76 469,886.60 0.00 0.00 UNDEFINED 100.00 0.25 237.56 100.00 43.80 -0.07 -0.11 6,031,070.69 469,886.49 0.44 0.02 SR-Gyro-SS(1) 171.00 0.16 147.79 171.00 114.80 -0.23 -0.18 6,031,070.53 469,886.42 0.42 -0.05 SRGyro-SS(1) 263.00 0.15 40.83 263.00 206.80 -0.25 -0.04 6,031,070.51 469,886.56 0.27 -0.16 SR-Gyro-SS(1) 354.00 0.25 26.25 354.00 297.80 0.02 0.13 6,031,070.78 469,886.73 0.12 -0.07 SR-Gyro-SS(1) 447.00 0.28 347.15 447.00 390.80 0.42 0.17 6,031,071.18 469,886.77 0.19 0.20 SR-Gyro-SS(1) 538.00 0.35 55.44 538.00 481.80 0.79 0.35 6,031,071.55 469,886.95 0.39 0.36 SR-Gyro-SS(1) 629.00 0.49 21.78 628.99 572.79 1.31 0.72 6,031,072.07 469,887.33 0.31 0.50 SR-Gyro-SS(1) 722.00 0.17 21.36 721.99 665.79 1.81 0.92 6,031,072.57 469,887.53 0.34 0.75 SR-Gyro-SS(1) 764.01 0.36 245.35 764.00 707.80 1.81 0.82 6,031,072.57 469,887.43 1.18 0.81 MWD+IFR2+MS+sag(2) 3/31/2010 2:58:12PM Page 2 COMPASS 2003.16 Build 428 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Project: Oooguruk Development ND Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSK-35Ai North Reference: True Wel!bore: ODSK-35Ai Survey Calculation Method: Minimum Curvature Design: ODSK-35Ai KupH Surveys Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) ; Survey Tool Name 856.15 1.49 252.62 856.13 799.93 1.34 -0.58 6,031,072.10 469,886.02 1.23 1.39 MWD+IFR2+MS+sag(2) 948.33 1.53 248.90 948.28 892.08 0.53 -2.88 6,031,071.31 469,883.73 0.11 2.31 MWD+IFR2+MS+sag(2) 1,043.51 1.88 252.59 1,043.41 987.21 -0.39 -5.55 6,031,070.39 469,881.05 0.39 3.39 MWD+IFR2+MS+sag(2) 1,139.79 1.55 242.95 1,139.65 1,083.45 -1.45 -8.22 6,031,069.34 469,878.38 0.45 4.36 MWD+IFR2+MS+sag(2) 1,235.65 1.97 243.47 1,235.47 1,179.27 -2.78 -10.85 6,031,068.02 469,875.74 0.44 5.11 MWD+IFR2+MS+sag(2) 1,333.20 1.86 267.65 1,332.96 1,276.76 -3.59 -13.93 6,031,067.22 469,872.66 0.83 6.55 MWD+IFR2+MS+sag(2) 1,429.17 4.32 294.73 1,428.79 1,372.59 -2.15 -18.77 6,031,068.69 469,867.82 2.91 10.84 MWD+IFR2+MS+sag(2) 1,525.74 5.11 296.62 1,525.03 1,468.83 1.30 -25.92 6,031,072.17 469,860.69 0.83 18.17 MWD+IFR2+MS+sag(2) 1,622.36 7.18 286.60 1,621.10 1,564.90 4.96 -35.55 6,031,075.86 469,851.07 2.41 27.29 MWD+IFR2+MS+sag(2) 1,719.74 9.44 274.58 1,717.45 1,661.25 7.33 -49.35 6,031,078.29 469,837.29 2.92 38.22 MWD+IFR2+MS+sag(2) 1,815.80 11.37 265.58 1,811.94 1,755.74 7.23 -66.64 6,031,078.26 469,819.99 2.62 49.62 MWD+IFR2+MS+sag(2) 1,912.55 13.25 260.94 1,906.46 1,850.26 4.75 -87.10 6,031,075.86 469,799.53 2.19 61.33 MWD+IFR2+MS+sag(2) 2,009.11 14.35 257.23 2,000.23 1,944.03 0.36 -109.70 6,031,071.57 469,776.91 1.46 73.03 MWD+IFR2+MS+sag(2) 2,105.41 15.91 256.13 2,093.19 2,036.99 -5.44 -134.16 6,031,065.87 469,752.44 1.65 84.91 MWD+IFR2+MS+sag(2) 2,201.97 18.24 256.76 2,185.49 2,129.29 -12.07 -161.72 6,031,059.34 469,724.85 2.42 98.23 MWD+IFR2+MS+sag(2) 2,298.82 21.92 255.23 2,276.44 2,220.24 -20.16 -193.97 6,031,051.39 469,692.57 3.84 113.57 MWD+IFR2+MS+sag(2) 2,395.13 25.99 254.76 2,364.43 2,308.23 -30.29 -231.72 6,031,041.41 469,654.78 4.23 131.03 MWD+IFR2+MS+sag(2) 2,491.86 31.03 253.95 2,449.41 2,393.21 -42.76 -276.16 6,031,029.12 469,610.30 5.23 151.17 MWD+IFR2+MS+sag(2) 2,587.63 34.73 253.05 2,529.82 2,473.62 -57.55 -326.00 6,031,014.54 469,560.41 3.90 173.16 MWD+IFR2+MS+sag(2) 2,684.28 36.76 251.65 2,608.26 2,552.06 -74.68 -379.79 6,030,997.63 469,506.55 2.26 196.02 MWD+IFR2+MS+sag(2) 2,779.94 37.29 249.80 2,684.64 2,628.44 -93.70 -434.16 6,030,978.83 469,452.11 1.29 217.84 MWD+IFR2+MS+sag(2) 2,876.70 39.47 248.30 2,760.48 2,704.28 -115.19 -490.25 6,030,957.57 469,395.94 2.45 238.96 MWD+IFR2+MS+sag(2) 2,973.29 39.90 250.03 2,834.82 2,778.62 -137.12 -547.89 6,030,935.87 469,338.22 1.23 260.78 MWD+IFR2+MS+sag(2) 3,070.47 40.97 248.05 2,908.79 2,852.59 -159.68 -606.74 6,030,913.56 469,279.28 1.72 282.93 MWD+IFR2+MS+sag(2) 3,167.15 41.02 248.08 2,981.76 2,925.56 -183.37 -665.57 6,030,890.11 469,220.36 0.06 304.22 MWD+IFR2+MS+sag(2) 3,216.69 41.28 248.82 3,019.06 2,962.86 -195.34 -695.89 6,030,878.26 469,190.00 1.11 315.37 MWD+IFR2+MS+sag(2) 3,270.11 41.42 249.14 3,059.17 3,002.97 -208.00 -728.83 6,030,865.73 469,157.01 0.47 327.75 MWD+IFR2+MS+sag(3) 3,370.62 41.54 257.71 3,134.53 3,078.33 -226.95 -792.51 6,030,847.04 469,093.26 5.65 355.81 MWD+IFR2+MS+sag(3) 3,465.44 43.09 267.98 3,204.73 3,148.53 -234.80 -855.68 6,030,839.46 469,030.06 7.47 391.83 MWD+IFR2+MS+sag(3) 3,555.76 42.33 275.09 3,271.13 3,214.93 -233.18 -916.84 6,030,841.32 468,968.92 5.40 433.61 MWD+IFR2+MS+sag(3) 3,650.52 41.94 282.22 3,341.44 3,285.24 -223.64 -979.60 6,030,851.11 468,906.20 5.06 482.37 MWD+IFR2+MS+sag(3) 3,749.80 42.79 288.85 3,414.83 3,358.63 -205.72 -1,043.98 6,030,869.29 468,841.90 4.58 538.49 MWD+IFR2+MS+sag(3) 3,844.67 43.32 293.99 3,484.18 3,427.98 -182.07 -1,104.22 6,030,893.19 468,781.76 3.74 596.15 MWD+IFR2+MS+sag(3) 3,940.45 44.47 301.39 3,553.24 3,497.04 -151.21 -1,162.92 6,030,924.27 468,723.19 5.49 658.17 MWD+IFR2+MS+sag(3) 4,035.59 46.57 307.87 3,619.94 3,563.74 -112.62 -1,218.67 6,030,963.09 468,667.60 5.34 724.03 MWD+IFR2+MS+sag(3) 4,129.42 50.23 314.34 3,682.26 3,626.06 -66.46 -1,271.41 6,031,009.45 468,615.06 6.46 793.55 MWD+IFR2+MS+sag(3) 4,225.06 53.96 318.82 3,741.02 3,684.82 -11.63 -1,323.19 6,031,064.49 468,563.51 5.37 868.93 MWD+IFR2+MS+sag(3) 4,320.03 56.76 323.31 3,795.02 3,738.82 49.14 -1,372.23 6,031,125.46 468,514.72 4.88 946.94 MWD+IFR2+MS+sag(3) 4,416.37 60.20 327.94 3,845.40 3,789.20 116.92 -1,418.52 6,031,193.42 468,468.71 5.43 1,028.37 MWD+IFR2+MS+sag(3) 4,510.78 61.16 330.56 3,891.63 3,835.43 187.66 -1,460.60 6,031,264.32 468,426.92 2.62 1,109.22 MWD+IFR2+MS+sag(3) 3/31/2010 2:58:12PM Page 3 COMPASS 2003.16 Build 428 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Project: Oooguruk Development TVD Reference: i 42.7'+13.5 @ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSK-35Ai North Reference: True Wellbore: ODSK-35Ai Survey Calculation Method: Minimum Curvature Design: ODSK-35Ai KupH Surveys Database: .Pioneer Alaska Survey Map Map Vertical MD Inc' Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) r(?) (?) (ft) (ft) (ft) {ft) (ft) (ft) {°1100') (ft) Survey Tool Name 4,607.41 61.40 330.42 3,938.07 3,881.87 261.41 -1,502.34 6,031,338.23 468,385.49 0.28 1,192.09 MWD+IFR2+MS+sag(3) 4,700.93 61.90 329.80 3,982.48 3,926.28 332.76 -1,543.35 6,031,409.74 468,344.76 0.79 1,272.70 MWD+IFR2+MS+sag(3) 4,795.28 61.56 329.83 4,027.16 3,970.96 404.59 -1,585.13 6,031,481.73 468,303.28 0.36 1,354.16 MWD+IFR2+MS+sag(3) 4,893.86 62.23 329.49 4,073.60 4,017.40 479.64 -1,629.06 6,031,556.95 468,259.66 0.74 1,439.46 MWD+IFR2+MS+sag(3) 4,987.40 62.59 329.14 4,116.93 4,060.73 550.93 -1,671.36 6,031,628.40 468,217.65 0.51 1,520.88 MWD+IFR2+MS+sag(3) 5,081.83 62.31 329.14 4,160.60 4,104.40 622.80 -1,714.31 6,031,700.44 468,175.00 0.30 1,603.15 MWD+IFR2+MS+sag(3) 5,177.92 62.54 328.17 4,205.08 4,148.88 695.55 -1,758.62 6,031,773.35 468,130.99 0.93 1,686.97 MWD+IFR2+MS+sag(3) 5,272.50 61.40 327.63 4,249.53 4,193.33 766.27 -1,802.98 6,031,844.25 468,086.92 1.31 1,769.32 MWD+IFR2+MS+sag(3) 5,367.63 61.10 326.64 4,295.29 4,239.09 836.32 -1,848.24 6,031,914.48 468,041.95 0.97 1,851.77 MWD+IFR2+MS+sag(3) 5,464.61 60.63 327.45 4,342.50 4,286.30 907.40 -1,894.32 6,031,985.73 467,996.17 0.88 1,935.53 MWD+IFR2+MS+sag(3) 5,558.18 60.52 327.68 4,388.47 4,332.27 976.18 -1,938.03 6,032,054.69 467,952.74 0.24 2,016.00 MWD+IFR2+MS+sag(3) 5,654.27 60.15 327.31 4,436.03 4,379.83 1,046.60 -1,982.90 6,032,125.28 467,908.16 0.51 2,098.45 MWD+IFR2+MS+sag(3) 5,747.76 60.26 328.49 4,482.49 4,426.29 1,115.33 -2,026.01 6,032,194.17 467,865.33 1.10 2,178.48 MWD+IFR2+MS+sag(3) 5,845.92 60.62 328.27 4,530.91 4,474.71 1,188.03 -2,070.77 6,032,267.05 467,820.87 0.42 2,262.59 MWD+IFR2+MS+sag(3) 5,937.48 60.20 329.59 4,576.13 4,519.93 1,256.23 -2,111.86 6,032,335.40 467,780.06 1.33 2,340.87 MWD+IFR2+MS+sag(3) 6,031.12 62.23 330.38 4,621.21 4,565.01 1,327.29 -2,152.91 6,032,406.62 467,739.30 2.29 2,421.28 MWD+IFR2+MS+sag(3) 6,126.05 61.99 330.50 4,665.62 4,609.42 1,400.27 -2,194.30 6,032,479.77 467,698.21 0.28 2,503.35 MWD+IFR2+MS+sag(3) 6,222.59 61.33 330.52 4,711.45 4,655.25 1,474.23 -2,236.13 6,032,553.89 467,656.69 0.68 2,586.45 MWD+IFR2+MS+sag(3) 6,318.74 60.36 330.42 4,758.29 4,702.09 1,547.29 -2,277.51 6,032,627.11 467,615.60 1.01 2,668.57 MWD+IFR2+MS+sag(3) 6,413.87 59.57 330.11 4,805.90 4,749.70 1,618.80 -2,318.36 6,032,698.78 467,575.05 0.88 2,749.18 MWD+IFR2+MS+sag(3) 6,508.55 62.30 331.34 4,851.90 4,795.70 1,690.99 -2,358.81 6,032,771.12 467,534.89 3.10 2,830.03 MWD+IFR2+MS+sag(3) 6,603.63 62.09 329.95 4,896.25 4,840.05 1,764.29 -2,400.04 6,032,844.58 467,493.97 1.31 2,912.24 MWD+IFR2+MS+sag(3) 6,698.54 62.00 330.80 4,940.74 4,884.54 1,837.16 -2,441.48 6,032,917.61 467,452.83 0.80 2,994.26 MWD+IFR2+MS+sag(3) 6,794.38 63.27 331.72 4,984.79 4,928.59 1,911.79 -2,482.40 6,032,992.40 467,412.21 1.58 3,077.25 MWD+IFR2+MS+sag(3) 6,887.42 63.13 332.49 5,026.74 4,970.54 1,985.19 -2,521.26 6,033,065.95 467,373.66 0.75 3,157.95 MWD+IFR2+MS+sag(3) 6,988.26 63.87 332.23 5,071.74 5,015.54 2,065.13 -2,563.12 6,033,146.05 467,332.12 0.77 3,245.55 MWD+IFR2+MS+sag(3) 7,079.37 63.76 331.84 5,111.94 5,055.74 2,137.35 -2,601.46 6,033,218.41 467,294.08 0.40 3,325.02 MWD+IFR2+MS+sag(3) 7,171.46 62.40 330.23 5,153.64 5,097.44 2,209.19 -2,641.22 6,033,290.40 467,254.62 2.15 3,405.15 MWD+IFR2+MS+sag(3) 7,269.52 62.19 328.49 5,199.23 5,143.03 2,283.88 -2,685.46 6,033,365.27 467,210.68 1.59 3,490.40 MWD+IFR2+MS+sag(3) 7,365.61 61.76 328.17 5,244.38 5,188.18 2,356.07 -2,729.99 6,033,437.63 467,166.45 0.54 3,573.96 MWD+IFR2+MS+sag(3) 7,460.55 62.10 327.69 5,289.05 5,232.85 2,427.06 -2,774.47 6,033,508.79 467,122.26 0.57 3,656.59 MWD+IFR2+MS+sag(3) 7,553.45 61.56 327.52 5,332.91 5,276.71 2,496.21 -2,818.35 6,033,578.11 467,078.67 0.60 3,737.44 MWD+IFR2+MS+sag(3) 7,651.30 60.45 327.42 5,380.34 5,324.14 2,568.37 -2,864.37 6,033,650.45 467,032.95 1.14 3,821.97 MWD+IFR2+MS+sag(4) 7,746.20 60.19 326.85 5,427.33 5,371.13 2,637.62 -2,909.11 6,033,719.88 466,988.49 0.59 3,903.47 MWD+IFR2+MS+sag(4) 7,841.53 61.37 326.99 5,473.87 5,417.67 2,707.33 -2,954.52 6,033,789.77 466,943.37 1.24 3,985.76 MWD+IFR2+MS+sag(4) 7,937.40 60.97 327.56 5,520.10 5,463.90 2,777.99 -2,999.93 6,033,860.60 466,898.25 0.67 4,068.75 MWD+IFR2+MS+sag(4) 8,031.96 59.82 327.94 5,566.81 5,510.61 2,847.52 -3,043.80 6,033,930.30 466,854.67 1.27 4,149.89 MWD+IFR2+MS+sag(4) 8,127.59 60.28 327.30 5,614.55 5,558.35 2,917.49 -3,088.17 6,034,000.44 466,810.58 0.75 4,231.69 MWD+IFR2+MS+sag(4) 8,222.49 59.63 326.53 5,662.07 5,605.87 2,986.32 -3,133.01 6,034,069.45 466,766.02 0.98 4,312.94 MWD+IFR2+MS+sag(4) 8,317.81 60.78 326.20 5,709.43 5,653.23 3,055.19 -3,178.83 6,034,138.49 466,720.49 1.24 4,394.87 MWD+IFR2+MS+sag(4) 3/31/2010 2:58:12PM Page 4 COMPASS 2003.16 Build 428 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSK-35Ai North Reference: True Wellbore: ODSK-35Ai Survey Calculation Method: Minimum Curvature Design: ODSK-35Ai KupH Surveys Database: .Pioneer Alaska Survey I Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,413.74 61.13 326.28 5,756.01 5,699.81 3,124.91 -3,225.44 6,034,208.40 466,674.17 0.37 4,477.96 MWD+IFR2+MS+sag(4) 8,508.32 61.41 325.91 5,801.47 5,745.27 3,193.75 -3,271.70 6,034,277.41 466,628.19 0.45 4,560.16 MWD+IFR2+MS+sag(4) 8,602.04 61.57 327.09 5,846.20 5,790.00 3,262.42 -3,317.15 6,034,346.26 466,583.02 1.12 4,641.70 MWD+IFR2+MS+sag(4) 8,696.83 63.91 327.29 5,889.62 5,833.42 3,333.24 -3,362.81 6,034,417.26 466,537.66 2.48 4,724.98 MWD+IFR2+MS+sag(4) 8,792.58 67.07 328.48 5,929.34 5,873.14 3,407.02 -3,409.11 6,034,491.22 466,491.67 3.49 4,810.91 MWD+IFR2+MS+sag(4) 8,888.00 70.37 328.51 5,963.96 5,907.76 3,482.82 -3,455.56 6,034,567.20 466,445.52 3.46 4,898.45 MWD+IFR2+MS+sag(4) 8,983.58 71.21 327.11 5,995.41 5,939.21 3,559.20 -3,503.65 6,034,643.76 466,397.75 1.64 4,987.50 MWD+IFR2+MS+sag(4) 9,077.80 73.52 327.09 6,023.95 5,967.75 3,634.59 -3,552.42 6,034,719.34 466,349.29 2.45 5,076.27 MWD+IFR2+MS+sag(4) 9,173.92 75.90 326.09 6,049.30 5,993.10 3,711.97 -3,603.47 6,034,796.92 466,298.56 2.67 5,168.04 MWD+IFR2+MS+sag(4) 9,268.90 78.87 325.58 6,070.04 6,013.84 3,788.65 -3,655.52 6,034,873.81 466,246.83 3.17 5,259.95 MWD+IFR2+MS+sag(4) 9,364.18 82.39 325.86 6,085.55 6,029.35 3,866.32 -3,708.46 6,034,951.68 466,194.21 3.71 5,353.19 MWD+IFR2+MS+sag(4) 9,459.66 84.86 326.14 6,096.15 6,039.95 3,944.98 -3,761.51 6,035,030.55 466,141.48 2.60 5,447.25 MWD+IFR2+MS+sag(4) 9,477.75 85.30 326.38 6,097.70 6,041.50 3,959.97 -3,771.52 6,035,045.58 466,131.53 2.77 5,465.10 MWD+IFR2+MS+sag(4) 9,501.28 85.42 326.09 6,099.61 6,043.41 3,979.47 -3,784.56 6,035,065.12 466,118.57 1.33 5,488.34 MWD+IFR2+MS+sag(4) 9,532.31 88.61 325.70 6,101.22 6,045.02 4,005.12 -3,801.93 6,035,090.85 466,101.31 10.36 5,519.06 MWD+IFR2+MS+sag(5) 9,564.16 92.75 326.08 6,100.84 6,044.64 4,031.49 -3,819.79 6,035,117.28 466,083.56 13.05 5,550.64 MWD+IFR2+MS+sag(5) 9,596.43 91.86 327.46 6,099.55 6,043.35 4,058.46 --3,837.46 6,035,144.32 466,066.00 5.09 5,582.54 MWD+IFR2+MS+sag(5) 9,628.70 91.30 327.92 6,098.66 6,042.46 4,085.72 -3,854.70 6,035,171.65 466,048.87 2.25 5,614.38 MWD+IFR2+MS+sag(5) 9,661.40 90.43 328.74 6,098.16 6,041.96 4,113.55 -3,871.86 6,035,199.54 466,031.82 3.66 5,646.59 MWD+IFR2+MS+sag(5) 9,693.15 90.80 327.71 6,097.82 6,041.62 4,140.54 -3,888.58 6,035,226.59 466,015.21 3.45 5,677.88 MWD+IFR2+MS+sag(5) 9,724.79 88.64 328.36 6,097.98 6,041.78 4,167.38 -3,905.33 6,035,253.50 465,998.58 7.13 5,709.07 MWD+IFR2+MS+sag(5) 9,757.84 88.58 327.91 6,098.78 6,042.58 4,195.44 -3,922.77 6,035,281.63 465,981.25 1.37 5,741.64 MWD+IFR2+MS+sag(5) 9,789.90 88.89 327.95 6,099.49 6,043.29 4,222.60 -3,939.79 6,035,308.86 465,964.34 0.97 5,773.25 MWD+IFR2+MS+sag(5) 9,828.18 88.77 328.49 6,100.27 6,044.07 4,255.13 -3,959.95 6,035,341.47 465,944.32 1.44 5,810.97 MWD+IFR2+MS+sag(5) 9,853.73 87.11 326.81 6,101.19 6,044.99 4,276.70 -3,973.61 6,035,363.09 465,930.75 9.24 5,836.17 MWD+IFR2+MS+sag(5) 9,885.92 87.46 324.63 6,102.71 6,046.51 4,303.27 -3,991.72 6,035,389.73 465,912.75 6.85 5,868.07 MWD+IFR2+MS+sag(5) 9,919.37 88.95 324.53 6,103.76 6,047.56 4,330.51 -4,011.10 6,035,417.05 465,893.48 4.46 5,901.31 MWD+IFR2+MS+sag(5) 9,950.75 89.01 325.11 6,104.32 6,048.12 4,356.16 -4,029.17 6,035,442.76 465,875.51 1.86 5,932.49 MWD+IFR2+MS+sag(5) 9,983.22 87.12 323.17 6,105.41 6,049.21 4,382.45 -4,048.18 6,035,469.13 465,856.61 8.34 5,964.78 MWD+IFR2+MS+sag(5) 10,030.67 87.04 322.78 6,107.83 6,051.63 4,420.29 -4,076.72 6,035,507.08 465,828.23 0.84 6,012.02 MWD+IFR2+MS+sag(5) 10,079.28 88.67 322.73 6,109.65 6,053.45 4,458.96 -4,106.11 6,035,545.86 465,799.00 3.35 6,060.46 MWD+IFR2+MS+sag(5) 10,112.53 88.48 322.10 6,110.48 6,054.28 4,485.30 -4,126.39 6,035,572.28 465,778.83 1.98 6,093.62 MWD+IFR2+MS+sag(5) 10,144.86 89.88 323.14 6,110.94 6,054.74 4,510.98 -4,146.01 6,035,598.05 465,759.31 5.39 6,125.86 MWD+IFR2+MS+sag(5) 10,176.34 89.75 322.62 6,111.04 6,054.84 4,536.08 -4,165.01 6,035,623.22 465,740.42 1.70 6,157.24 MWD+IFR2+MS+sag(5) 10,208.51 89.90 322.12 6,111.14 6,054.94 4,561.56 -4,184.65 6,035,648.77 465,720.88 1.62 6,189.34 MWD+IFR2+MS+sag(5) 10,240.98 90.06 323.23 6,111.15 6,054.95 4,587.38 -4,204.34 6,035,674.67 465,701.30 3.45 6,221.72 MWD+IFR2+MS+sag(5) 10,272.63 90.63 323.66 6,110.96 6,054.76 4,612.81 -4,223.19 6,035,700.17 465,682.56 2.26 6,253.25 MWD+IFR2+MS+sag(5) 10,321.06 87.77 324.85 6,111.64 6,055.44 4,652.10 -4,251.48 6,035,739.58 465,654.43 6.40 6,301.42 MWD+IFR2+MS+sag(5) 10,369.88 87.92 324.32 6,113.47 6,057.27 4,691.86 -4,279.75 6,035,779.45 465,626.33 1.13 6,349.92 MWD+IFR2+MS+sag(5) 10,419.88 88.83 324.73 6,114.89 6,058.69 4,732.56 -4,308.75 6,035,820.26 465,597.49 2.00 6,399.62 MWD+IFR2+MS+sag(5) 3/31/2010 2:58:12PM Page 5 COMPASS 2003.16 Build 428 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSK-35A1-Slot ODS-35 Project Oooguruk Development TVD Reference: 42.7+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSK-35Ai North Reference: True Wellbore: ODSK-35Ai Survey Calculation Method: Minimum Curvature Design: ODSK-35Ai KupH Surveys Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS' +N!$ +E/-W Northing Easting , DLS, Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft); (ft) (°/100')' (ft) Survey Tool Name 10,464.93 90.00 326.37 6,115.35 6,059.15 4,769.71 -4,334.23 6,035,857.51 465,572.16 4.47 6,444.32 MWD+IFR2+MS+sag(5) 10,506.06 89.88 326.58 6,115.39 6,059.19 4,804.00 -4,356.95 6,035,891.88 465,549.59 0.59 6,485.05 MWD+IFR2+MS+sag(5) 10,562.47 90.01 324.45 6,115.45 6,059.25 4,850.49 -4,388.89 6,035,938.50 465,517.84 3.78 6,541.03 MWD+IFR2+MS+sag(5) 10,612.61 90.20 319.94 6,115.36 6,059.16 4,890.10 -4,419.61 6,035,978.23 465,487.28 9.00 6,591.05 MWD+IFR2+MS+sag(5) 10,658.66 89.44 318.01 6,115.50 6,059.30 4,924.84 -4,449.84 6,036,013.08 465,457.20 4.50 6,637.09 MWD+IFR2+MS+sag(5) 10,707.78 90.37 318.10 6,115.58 6,059.38 4,961.37 -4,482.67 6,036,049.75 465,424.52 1.90 6,686.21 MWD+IFR2+MS+sag(5) 10,755.61 90.76 318.74 6,115.11 6,058.91 4,997.15 -4,514.41 6,036,085.65 465,392.92 1.57 6,734.04 MWD+IFR2+MS+sag(5) 10,801.49 90.88 319.55 6,114.45 6,058.25 5,031.85 -4,544.42 6,036,120.46 465,363.06 1.78 6,779.91 MWD+IFR2+MS+sag(5) 10,851.95 89.88 318.72 6,114.12 6,057.92 5,070.00 -4,577.43 6,036,158.75 465,330.20 2.58 6,830.37 MWD+IFR2+MS+sag(5) 10,900.83 89.63 318.46 6,114.33 6,058.13 5,106.66 -4,609.76 6,036,195.54 465,298.02 0.74 6,879.24 MWD+IFR2+MS+sag(5) 10,948.47 89.22 317.84 6,114.81 6,058.61 5,142.15 -4,641.55 6,036,231.15 465,266.39 1.56 6,926.88 MWD+IFR2+MS+sag(5) 10,995.90 90.02 316.87 6,115.12 6,058.92 5,177.03 -4,673.68 6,036,266.16 465,234.40 2.65 6,974.30 MWD+IFR2+MS+sag(5) 11,044.18 90.33 316.07 6,114.97 6,058.77 5,212.04 -4,706.93 6,036,301.30 465,201.30 1.78 7,022.55 MWD+IFR2+MS+sag(5) 11,093.27 91.73 318.90 6,114.09 6,057.89 5,248.21 -4,740.09 6,036,337.60 465,168.28 6.43 7,071.62 MWD+IFR2+MS+sag(5) 11,139.37 88.21 321.16 6,114.11 6,057.91 5,283.53 -4,769.70 6,036,373.04 465,138.82 9.07 7,117.69 MWD+IFR2+MS+sag(5) 11,189.29 89.59 321.06 6,115.07 6,058.87 5,322.38 -4,801.04 6,036,412.01 465,107.65 2.77 7,167.55 MWD+IFR2+MS+sag(5) 11,236.84 89.02 322.74 6,115.65 6,059.45 5,359.80 -4,830.37 6,036,449.54 465,078.47 3.73 7,215.01 MWD+IFR2+MS+sag(5) 11,292.35 89.51 324.26 6,116.36 6,060.16 5,404.41 -4,863.39 6,036,494.28 465,045.63 2.88 7,270.29 MWD+IFR2+MS+sag(5) 11,332,73 90.00 326.81 6,116.53 6,060.33 5,437.70 -4,886.24 6,036,527.66 465,022.92 6.43 7,310.36 MWD+IFR2+MS+sag(5) 11,384.08 89.32 329.96 6,116.84 6,060.64 5,481.42 -4,913.15 6,036,571.49 464,996.19 6.28 7,360.93 MWD+IFR2+MS+sag(5) 11,427.63 89.59 331.38 6,117.25 6,061.05 5,519.39 -4,934.48 6,036,609.53 464,975.01 3.32 7,403.50 MWD+IFR2+MS+sag(5) 11,479.74 87.72 335.45 6,118.48 6,062.28 5,565.96 -4,957.79 6,036,656.20 464,951.90 8.59 7,453.81 MWD+IFR2+MS+sag(5) 11,524.85 87.16 335.15 6,120.49 6,064.29 5,606.91 -4,976.62 6,036,697.21 464,933.23 1.41 7,496.94 MWD+IFR2+MS+sag(5) 11,575.48 86.91 335.27 6,123.11 6,066.91 5,652.81 -4,997.82 6,036,743.20 464,912.22 0.55 7,545.36 MWD+IFR2+MS+sag(5) 11,609.99 87.65 336.55 6,124.75 6,068.55 5,684.28 -5,011.89 6,036,774.72 464,898.28 4.28 7,578.24 MWD+IFR2+MS+sag(5) 11,658.00 87.65 336.55 6,126.72 6,070.52 5,728.28 -5,030.98 6,036,818.80 464,879.37 0.00 7,623.83 PROJECTED to TD 3/31/2010 2:58:12PM Page 6 COMPASS 2003.16 Build 428 A- slailE ALAEL7 SEAN PARNELL,GOVERNOR ALASKA OIL AND GA333 W.7th AVENUE,SUITE 100 II CONSERVATION COM SSIOANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 June 22, 2010 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7009 2250 0004 3911 4214 Kenneth Sheffield, Jr. President Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Shut-in Order Oooguruk ODSK -35A (PTD 210-012) Oooguruk ODSN-15 (PTD 210-032) Dear Mr. Sheffield: The Alaska Oil and Gas Conservation Commission (Commission) has determined that two wells operated by Pioneer — ODSK-35A and ODSN-15 — are not in compliance with the Commission's regulations covering good oilfield engineering practice for production equipment. Pioneer is directed to immediately shut in both ODSK-35A and ODSN-15 immediately pending replacement of the temporary pipe with an acceptable piping arrangement. The basis for this action is set forth below. Oooguruk injection well ODSK-35A has been producing (Pre-injection) through temporary chicksan pipe since early April 2010. During safety valve system inspections on May 12, 2010, a Commission Inspector observed the piping arrangement and instructed Pioneer field personnel to replace the chicksan pipe with a more permanent arrangement. A follow-up email to Pioneer on May 18, 2010 requested the timing for resolution of the temporary pipe at ODSK-35A. Pioneer did not comply. On May 27, Pioneer suggested a meeting to discuss the use of temporary pipe for pre-producing injection wells. However, no such meeting was scheduled. On June 9, the Commission again requested Pioneer provide a time frame for compliance and reiterated that the use of chicksan pipe for pre-producing an injection well was inconsistent with good oilfield practice. On June 16, 2010, the Commission again inquired about the status of Oooguruk ODSK-35A. When Mr. Pat Foley noted that the well was still producing and that Pioneer would continue pre- production of ODSK-35A for an additional 3 to 4 months, Mr. Foley was verbally instructed to A Kenneth Sheffield,PNR June 22,2010 Page 2 of 2 shut the well in immediately. Pioneer did not comply. An email from Mr. David Hart on Friday, June 18, 2010 asserted that use of chicksan pipe for temporary pre-production is believed by Pioneer to abide by good oilfield practice. Oooguruk ODSN-15 was brought to the Commission's attention as another injection well that is pre-producing through temporary chicksan pipe,having been started May 25, 2010. The Commission recognizes there have been unexpected conflicts that have prevented direct communication between appropriate personnel of the Commission and Pioneer. However, for over a month, Pioneer has clearly and repeatedly been instructed to correct the problem or shut in well ODSK-35A. Pioneer's failure to resolve this matter constitutes serious non-compliance and must be resolved immediately. In accordance with your phone conversation with Commissioner Foerster earlier today, Pioneer is instructed to shut-in both wells immediately. Within 24 hours of receipt of this letter, please confirm that Oooguruk wells ODSK-35A and ODSN-15 were shut in today, June 22, 2010. The Commission expressly reserves the right to take any further actions it deems necessary. Sincerely, Daniel T. Seamount, Jr. Chair, Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails,OR 30 days if the Commission otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes,the order or decision on reconsideration. As provided in AS 31.05.080(b),"[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. Page 1 of 1 1 'I • Regg, James B (DOA) From: Schwartz, Guy L (DOA) 4."(_ _ � 710—d(Z Sent: Friday, April 16, 2010 2:06 PM �C To: Regg, James B (DOA) Subject: FW: Sundry 310-036 (c- 1)S Attachments: 19AC -T3 BOP STACK.pdf Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Franks, James [mailto:James.Franks @pxd.com] Sent: Tuesday, March 09, 2010 3:07 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern; Crumrine, Tim Subject: Sundry 310-036 Guy, I know that you are aware that we are changing out the BOP stack on Nabors 19AC, but I wanted to be sure you had a schematic to include in the ODSN-31 RWO, Sundry 310-036, paperwork. I hope all is well. Let me know if there are any questions. james James Franks 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. 4/16/2010 0 a 7HYDRIL GX ANNULAR 11 5K w/ 11 5K BOTTOM FLANGE DLO T3 MODEL 6012 DOUBLE RAM BOP 11 5K w/ STUDDED TOP & BOTTOM ` / & NO SIDE OUTLETS w/ STD. BONNETS GIIim GI Iii Iii Iii lint / TON VERTICAL LIFT (PER LUG) - - - - -- / .II� ip IMEI O II 0 -•em 6,... ■ D iu 2:1 _4111 'IF"' LAINI: -or OP1117111111111 1 EC 11 . II 0 -„, ..,M' Mini I IIU lul III uI MI IMIMI DRILLING SPOOL O O 11 5K FLANGE TOP & BOTTOM ID 000 w/ (2) - 3.12 5K FLANGE OUTLETS 1 cv O 0 O 0 IIIICII'I iiir& I IIiIIiN 1 Eillr:..—.E4-1—"--!, o U 5 1 T3 MODEL 6012 SINGLE RAM BOP 0 O 0 11 5K w/ TOP & BOTTOM b oo 11 5K FLANGES & NO SIDE OUTLETS I N O O O O DRILLING SPOOL 11 5K FLANGE TOP & BOTTOM . w/ (1) - 3.12 5K FLANGE & (1) - 3.12 5K SWIVEL FLANGE OUTLETS THIS IS A PROPRIETARY DESIGN OF NABORS ALASKA, REPRODUCTION OR USE OF DESIGN IS PERMISSIBLE ONLY IF AUTHORIZED IN WRITING BY NABORS ALASKA. fill Nabors Alaska Nabors Alaska Drilling Inc. 2525 C Street Suite 200 ANAI.ORS ANDUSTRES Coapoor Anchorage, Alaska 99503-2639 907-263-6000 PROJECT NABORS ALASKA DRILLING .TITLE RIG 19-AC - T3 11' BOP STACK DRAWN BY CHECKED BY APPROVED BY REV. ROB C. s DATE NO. OWN.BY A BY DESCRIPTION SCALE N.T.S. DATE FEB. 2010 DWG. NO. SHT. 1 l REV. PIONEER NATURAL RESOURCES ALASKA Letter of Transmittal Date: April 5, 2010 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Christine Mahnken 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps ❑ Report X Other—logs, CD ❑ Agreement DETAIL QTY DESCRIPTION ODSK-35Ai (API: 50-703-20560-0100) 1 CD 1 CD ODSK-35Ai LWD Final Processed Data 4 Well Logs 4 Well Logs DGR EWR ADR CTN ALD (1:600, 1:240) MD logs and TVD logs We request that all data be treated as confidential information. Thank you. RECEIVED Received by:A--- _ Date: APR 0 9 2011; Please sign and return o - ..•y to Pioneer NatAlsili*Olftam atibs,Commission ATTN: Shannon Koh Anrtxxme 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2190 fax 907-343-2128 phone 9i0 —o/ a- / 9 576 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, March 30, 2010 9:02 AM To: 'Delmonico, Joe' Cc: McMains, Stephen E (DOA) Subject: RE: K-35Ai Pre-Production (PTD 210-012) Joe, As per our conversation, pre-production for a couple of months is fine. Please mark the well status as"oil" (well class will remain "service") on the 407 report. Once the pre-production period is complete submit a 403 to convert well status to injection (WINJ) . Will need the bond log data and MIT-IA done at this time to approve injection. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Delmonico, Joe [mailto:Joe.Delmonico @pxd.com] Sent: Tuesday, March 30, 2010 8:43 AM To: Schwartz, Guy L (DOA) Subject: K-35Ai Pre-Production Guy, When submitting the PTD for K-35Ai a line indicating the plan to preproduce K-35Ai for 2-3 months was mistakenly removed. Our apologies and if you have additional questions please give me a call. Regards, Joe Joe Delmonico Jr. Drilling Engineer Pioneer Natural Resources Alaska Office:907-343-2182 Mobile:907-980-7690 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. 3/30/2010 cc-L) 1 SEAN PARNELL,GOVERNOR ALAS OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMDIISSION ANCHORAGE,ALASKA 99501-3539 Mr. Vern Johnson FAX NE (907)276-7542 Sr. Staff Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Kuparuk Oil Pool, ODSK-35Ai Pioneer Natural Resources Alaska, Inc. Permit No: 210-012 (Revised) Surface Location: 2955' FSL, 1111' FEL, Sec. 11, T13N, R7E, UM Bottomhole Location: 3031' FSL, 576' FEL, Sec. 3, T13N, R7E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced development well. This approval supersedes and replaces the permit to drill for this well that was issued on January 28, 2010. 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 a re uired test, contact the Commission's petroleum field inspector at (907 .59-3617 (pager). _ y 1% e . orma Corn' is ••ner DATED this day of March, 2010 cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALI. A OIL AND GAS CONSERVATION COMM■ )N FEB 2 6 2010 PERMIT TO DRILL 20 AAC 25.005 f \L'.V is 1) OiI&Gag cons.Convaission 1a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone 0 , 1c.Specie ' roposed for: Drill 0 • Redrill ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas Gas Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG 0 • Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11.Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 ODSK-35Ai • 3.Address: 700 G Street,Suite 600 6.Proposed Depth: 12.Field/Pool(s): Anchorage,AK 99501 MD: 11,179' • TVD: 6012' 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Oooguruk- Kuparuk Oil Pool • Surface: 2955'FSL, 1111'FEL,Sec. 11,T13N, R7E, UM • ADL 355036 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1539'FSL,4811'FEL,Sec.2,T13N, R7E, UM 417497 3/5/2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3031'FSL,576'FEL,Sec.3,T13N, R7E, UM 5760 2244' ..--3 vii(..!' 410 ,.. ,•,217,,r.A ru�(s', ,14" 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: -56.2 feet 15.Distance to Nearestell Open taciAi4j Surface: x-469886.60 . y-6031070.76 . Zone-ASP 4 GL Elevation above MSL: to Same Pool:ODSK-38 is 464awIy/`' 13.5 feet D K_t3 ((S� i-.--poriat . 16.Deviated wells: Kickoff depth: 3267 feet ' 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) .4s) 3_Z Maximum Hole Angle: 92.64 degrees Downhole: 3087 • Surface: 2421 • 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) . 8-3/4" 7" 26# L-80 BTC-M 9322' Surface Surface 9365' 6055' 162 sx Class'G' • 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1966' .,.988t" -.605-r-• 11,179' 6012' Uncemented Slotted 92 iv (co35' - 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 110' 16" Driven 158' 158' • Surface 3217' 9-5/8" 438 sx PF'L';201 sx Class'G' 3257' 3049' • Intermediate)-Drlg Liner Intermediate 2 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Joe Delmonico,343-2182 Prepared By:Kathy Campoamor,343-2183 Printed Name Vern Jo nson Title Sr.Staff Drilling Engineer Z/Z‘726/a Signature C. - • Phone 343-2111 Date 2/26/2010 Commission Use Only Permit to Drill API Number: _ Permit Approval t See cover letter for other Number: ,'���[}(2�) 50-'70 ` 2..i+rjC(>'{'(-C , Date: �`� 1 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed ethane,gas hydrates,or gas contained in shales: []' Other: *'- I-15O6 p sr.: 4Q,P �S 4_ a Samples req'd: Yes❑ NoE r Mud log req'd: Yes ❑ No[�']' 2 50O �p S An"w f!�vr� 1�-4.6A42S measures: Yes❑ No 0 ' Directional svy req'd: Yes E]/No❑ *Or�� • J / r A .57�-•;p...�aJt-i eti s a , . - �� � ^/6 le� APPROVED BY THE COMMISSION DATE: ,COMMISSIONER ORIGINAL X3.2.10 Form 10-401(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate PIONEER NATURAL RESOURCES RECEIVED February 26, 2010 FEB 2 6 2010 le01&GasCans.Cornailseion State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSK-35Ai Permit To Drill #210-012 Surface Location: 2955' FSL, 1111' FEL, Sec 11, T13N, R7E, UM X = 469886.60, Y = 6031070.76, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a development well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be a injection well in the Oooguruk-Kuparuk formation. A permit for this well was originally granted under ODSK-35Ai, PTD# 210-012, but due to log results from ODSK-14, changes to the landing location of ODSK-35Ai have been made. 9-5/8" surface casing has already been set on the well, in February of 2008 as part of a batch drilling operation. 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. • Alaska Oil & Gas Conservation Commission February 26, 2010 Page 2 of 3 c. A complete proposed casing and cementing program is attached as per 20 AAC 25.030. d. A summary of the drilling operations. e. A summary of drilling hazards per 20 AAC 25.005 (c) (4). f. A wellbore schematic depicting the proposed well. 4) A copy of the Planned Directional Well Path - including travelling cylinder and development layout plots 5) 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. As with many other wells at Oooguruk, PNRA plans to implement Managed Pressure Drilling technology (MPD) while drilling the intermediate and production hole of ODSK-35Ai. PNRA plans to use this technique while drilling the intermediate interval as outlined below. • From the Surface Shoe to below the Base of the Torok Sands o Use -9.2 to 10 ppg fluid while using MPD to control pressure from the surface to -11.5-12.5 ppg EMW at the bottom of the hole. • Open formations: • Torok Sands, -8.7ppg Pore Pressure • From the base of the Torok Sands to Intermediate Hole TD o Use -9.8-10.5 ppg fluid while using MPD to control pressure from the surface to -12.5 ppg EMW at the bottom of the hole. • Open formations: • Torok Sands, -8.7 ppg Pore Pressure • Kuparuk Sands, -9.8 ppg Pore Pressure PNRA plans to use this technique while drilling the production interval as outlined below. • From the Intermediate Shoe to TD o Use -7.0 to 8.7 ppg fluid while using MPD to control pressure from the surface to -9.8 to10.2 ppg EMW at the bottom of the hole during connections and while tripping Utilizing the MPD process described above allows PNRA to reduce the materials needed for the well, increasing the overall safety of the personnel on the development by handling less material. In addition the lower solids in the production section mud system will reduce formation damage along the sandface of the well. Alaska Oil & Gas Conservation Commission February 26, 2010 Page 3 of 3 In the future, PNRA may provide information requesting the permitting of annular disposal of drilling wastes on this well. It is planned to change out the BOP stack on Nabors Rig 19AC for required maintenance and inspection. A schematic of the planned replacement stack is included with this application. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vern Johnson, Senior Staff Drilling Engineer (20 AAC 25.070) 907.343.2111 vern.iohnsonpxd.com 2) Geologic Data and Logs Paul Daggett, Senior Staff Geophysicist (20 AAC 25.071) 907.343.2134 paul.daggettapxd.com The anticipated spud date for this well is March 5, 2010. If you have any questions or require further information, please contact Joe Delmonico at 907-343-2182. Since ,'L . Vern Johnson Senior Staff Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSK-35Ai Well File • Permit to Drill Well Plan Summary ODSK-35Ai Oooguruk - Kuparuk Injection Well Surface TD @ 3,257' MD / 3,049' TVD (Previously Cased) Intermediate TD @ 9,365' MD / 6,055' TVD Production TD @ 11 ,179' MD / 6,012' TVD Surface Location: 2955' FSL, 1111' FEL, Sec 11, T13N, R7E, UM ASP 4 (NAD27) projection X =469,886.60 Y= 6,031,070.76 I Target: Oooguruk-Kuparuk 1539' FSL, 4811' FEL, Sec 2, T13N, R7E, Umiat X =466,200.00 I Y= 6,034,950.00 I 6,055' TVDrkb Bottom Hole Location: 3031' FSL, 576' FEL, Sec 3, T13N, R7E, Umiat X =465,160.00 Y=6,036,447.00 6,012' TVDrkb AFE Number: TBA Est. Start Date: March 5, 2010 I Rig: Nabors 19AC Operating days: 27 days to Drill and Complete TD:11,179' MD/6,012 TVDrkb Objective: Kuparuk I Well Type (exp, dev, etc): Development Well Design: Modified Slimhole (9-5/8"x 7" x 4-1/2" liner)— Injector—wp09 Current Mechanical Condition: Well Bay Footing/ODS Ground Level: Elevation above MSL: 13.5' RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' Conductor: 158' MDrkb Pioneer Natural Resources Last Revised: February 25,2010 ODSK-35i Permit To Drill Page 1 of 9 Well Control: Intermediate Section: • Maximum anticipated BHP: 3085 psi @ 6,055'TVDss (Based on 9.8 ppg Oooguruk-Kuparuk pore pressure) • Maximum surface pressure: 2420 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Production Lateral Section: • Maximum anticipated BHP: 3087 psi @ 6,058'TVDss (Based on 9.8 ppg Oooguruk-Kuparuk pore pressure) • Maximum surface pressure: 2421 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Maximum casing pressure: 4500 psi @ surface Planned BOP test pressure: 4500 psi (annular to 2500 psi) Due to required 4500 psi casing pressure test. Planned completion fluid: 10.2 ppg Brine/6.8 ppg Diesel 5000 psi BOP stack (see attached schematic): Pioneer Natural Resources Last Revised: February 25,2010 ODSK-35i Permit To Drill Page 2 of 9 • Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 9-5/8" Surface Shoe Rathole +20' to 50' from shoe LOT 12.5 ppg 7" Intermediate Shoe Rathole +20' from shoe FIT 12.5 ppg Drilling Fluids Program: Intermediate Hole Mud Properties: 8-3/4" hole LSND Interval Density(ppg) Viscosity(secs) YP PV MBT API FL Initial to HRZ 8.8 40-60 15-25 12-20 < 12 8 - 10 (-10.5 via MPD) HRZ to TD 9.8- 10.5 50-70 15 -25 15 -25 < 10 3-5 (8-10 HTHP) (-12.5 via MPD) Production Hole Mud Properties: 6-1/8" hole Seawater Polymer Interval Density(ppg) Viscosity(secs) YP PV MBT API FL Initial to TD 8.6-8.8 37-50 13 - 18 5 - 14 < 5 <8 (-10.2 via MPD) Formation Markers: Formation Tops MD (ft) TVDrkb(ft) Pore Press. EMW Comments (psi) (PPM • Base of Permafrost 1666 Top West Sak 2303 2281 8.65 _ Base of fluvial sands Tuffaceous Shales 3134 2957 Brook 2b 5327 4280 Top Torok Ss 6910 5037 2275 8.65 Base Torok Ss 7474 5307 Top Hrz 8469 5783 Base Hrz 8738 5904 Kalubik Mkr 8985 5987 Kup C 9354 6054 3053 9.8 TD 11179 6012 Pioneer Natural Resources Last Revised: February 25,2010 ODSK-35i Permit To Drill Page 3 of 9 Logging Program: Intermediate Section: Drilling: Dir/GR/ Res Open Hole: N/A Cased Hole: N/A Production Section: Drilling: Mud logging Dir/GR/Azm Res/Dens/Neut/PWD/BatSonic • Open Hole: N/A Cased Hole: N/A Pioneer Natural Resources Last Revised: February 25,2010 ODSK-35i Permit To Drill Page 4 of 9 Casing Program: Hole Casing/ Weight Grade Conn. Casing Csg/Tbg Top Hole Btm Size Tubing Length MDrkb MDrkb!TVDrkb 24" 16" 109# H-40 Welded 115' Surface 158'/ 158' 12-1/4" 9-5/8" 40# L-80 BTC 3,214' Surface 3,257'/3,049' 8-3/d' 7" 26# L-80 BTC-M 9,322' Surface 9,365'/6,055' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1,966' zJ 88' 'tZl 11,179'/6,012' Tubing 3-1/2" 9.3# L-80 TSHP/TCII 9,159' Surface 7tvi° 9,202'/6,035 Casing Properties Size Weight Grade ID Drift Conn. Internal Collapse Tensile Strength ID Yield (psi) (psi) Joint Body 16" 109# H-40 14.67" 14.5" Welded Conductor casing 9-5/8" 40# L-80 8.835' 8.75" Hydril 521 5750 3090 916 M 916 M 7" 26# L-80 6.276" 6.75 Hydril 511 7240 5410 604 M 604 M 4-1/2" 12.6# L-80 3.958" 3.833" IBT-M 289 M 289 M slotted 3-1/2" 9.3# L-80 2.992" 2.867" TSHP/TCII 10160 10540 207 M 207 M Cement Calculations: Casing Size: I 7" Intermediate-single stage Basis: TOC: -8,490'MD-250' MD above packer depth 875' annulus volume+30% excess, +85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 12.5 ppg Dual Spacer Primary 34 bbls/ 162 sx Premium "G" +adds. 1.17 cf/sk Displ 355 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. 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: February 25,2010 ODSK-35i Permit To Drill Page 5 of 9 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre-Rig Work 1. 16" Conductors have been set and the Well Bay modules have been placed. Rig Activity: Drill and Complete 1. MIRU Nabors 19AC over pre-installed 9-5/8" surface casing. 2. RU circulation lines and circulate out the diesel freeze protection fluid. Ensure the well is dead. ' 3. Install TWC, ND Tree, NU BOPE, Remove TWC. 4. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 5. Pull circulation tubing string from the well. 6. MU 8-3/4"directional drilling, MWD/LWD on 5" DP. RU MPD trip nipple. 7. RIH and cleanout casing to landing collar. 8. Drill through drilling liner shoe +20' of new hole and perform LOT to a minimum of 12.5 ppg.• 9. RD MPD trip nipple and RU bearing assembly. Drill 8-3/4" Intermediate to section TD. ' 10. Circulate and condition the well to run 7" intermediate casing. Displace the well over to -12.5 ppg for shale stability. RD the MPD bearing assembly and RU MPD trip nipple. POH. 11. Change one set of pipe rams to 7" and test BOPE as required. 12. Run and cement the 7" intermediate casing. 13. Bump the plug and bring the pressure up to 4500 psi-chart and hold for 30 minute pressure test. Send chart to ODE. Release pressure and ensure floats are holding. 14. LD5" DP 15. Change pipe rams to 4"and test BOPE to 250/4500 psi-Notify AOGCC 48 hours in advance of test. 16. PU 4" DP as needed to TD the Production hole section. 17. MU 6-1/8" MWD/LWD motor drilling assembly on 4" DP. RU MPD trip nipple. RIH and cleanout to landing collar. RD MPD trip nipple and RU bearing assembly. 18. Drill through Intermediate shoe, rathole+ 20' of new hole and perform FIT to 12.5 ppg. • 19. During FIT ensure Pressure vs. Volume is tracked and recorded. 20. Perform Kuparuk reservoir pressure determination. • Once FIT is complete lower the backpressure held on surface to a 9.8 EMW at the shoe. • Bleed off pressure at the surface to lower the EMW at the shoe by 0.2 ppg (-62 psi and <2 gallons of fluid). • Shut the well in and watch the casing pressure for 5 minutes or until stable. i. If the casing pressure is rising, assume that the well is underbalanced to the formation. 1. Increase the backpressure held at surface to the last over-balanced test point and circulate bottoms up to remove any wellbore fluids that may have entered. ii. If the casing pressure is static, repeat the process as needed to find the reservoir pressure. • Once the reservoir pressure has been determined, hold this pressure at the intermediate shoe while drilling ahead. 21. Displace to drill-in-fluid for production lateral. 22. Drill 6-1/8" lateral production hole to TD. Pioneer Natural Resources Last Revised: February 25,2010 ODSK-35i Permit To Drill Page 6 of 9 23. Circulate and condition the hole to run liner and POOH. 24. Change one set of pipe rams to 4-1/2"and test BOPE as required. 25. RIH w/4-1/2"slotted production liner from 150' inside the intermediate shoe to TD. 26. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine and POOH. 27. MU completion and RIH. 28. Land the tubing and RILDS. Install TWC. 29. ND BOPE, NU tree and test to 5,000 psi. . 30. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to -2000' TVD and allow to u-tube. 31. Drop ball and rod and allow to seat. Pressure test the tubing to 4,500 psi-chart and hold for 30 , minutes. Bleed off pressure and then pressure test the annulus to 4,500 psi-chart and hold for 30 minutes. Bleed off pressure. 32. RDMO to next well. . Post-Rio Work 33. RU Slickline and pull the ball and rod. Pull the RHC-m plug. 34. RD Slickline. Pioneer Natural Resources Last Revised: February 25,2010 ODSK-35i 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 (or Formation Integrity Test): • Calculate the required test pressure to reach leak off (or formation integrity test limit) 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/FIT. • 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. Note: For FIT, do not take to 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 LOT/FIT pressure at the shoe as EMW. • Submit the test results to the Pioneer drilling engineer for distribution as required. Pioneer Natural Resources Last Revised: February 25,2010 ODSK-35i Permit To Drill Page 8 of 9 ODSK-35i Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre-reservoir meeting to outline heightened . awareness for kick detection and lost circulation. 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. Hydrates and Shallow gas • No hydrates are expected in this area. Lost Circulation/Breathing/Formation Stability/Stuck Pipe Events • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the • formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN-40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling the ODSN-36 across this same interval. Review the • DOB2C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly • During the attempt to retrieve a fish from the ODSK-33 well, an un-centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold ' back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. In any event, keep the pipe moving and avoid allowing the pipe to remain stationary any longer than necessary to minimize the chances of differential sticking. • There is a small section of formation above the Top of the HRZ that is volcanic in nature . (TUFFS) and can either have "glassy" material, swelling clays or both while drilling, which produced a pack off on ODSK-33 and ODSN-45 - close attention while drilling this interval is advised. Kick Tolerance/Integrity Testing Kick Tolerance/Integrity Testing Summary Table Casing set/ Maximum Mud Weight Exp Pore Min LOT/FIT Interval Influx Volume Press 9-5/8" Surface/ 79 bbls 10.5 3085 12.5 ppg (LOT), 8-1/2" (-12.5 via MPD) 14.0 ppg Max 7" Intermediate/ Infinite 8.6 8.8 3063 12.5 ppg (FIT) 6-1/8" (-10.2 vi a MPD) 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 H2S site, however Standard Operating • Procedures for H2S precautions should be followed at all times. Faults • Sub seismic faults with throws <25' may be encountered. Losses may be associated with these faults. CONSULT THE ODS DATA SHEET FOR ADDITIONAL INFORMATION (still in development) Pioneer Natural Resources Last Revised: February 25,2010 ODSK-35i Permit To Drill Page 9 of 9 ODSK-35Ai Injector — Proposed Completion Well Head: 9-5/8",5K,VetcoGray Tree: 3-1/2",5K,Horizontal 16"Conductor 158'MDrkb/158'TVDrkb r.� 24/8"ScSSSV,2.313"ID @—750'MD/750'ND l II 9-5/8",40#L-80 BTC,8.835"ID 3257'MDrkb/3049'TVDrkb .f` ------I 3-1/2"GLM#2 @ 2100'MDrkb/2088'TVDrkb 3-1/2",9.3#L-80 TSHP H---- 3-1/2"GLM#1 @ 8580'MDrkb/5835'TVDrkb .2/I Down hole Pressure Gauge 8620'MDrkb \ 3-1/2"X Nipple,2.813"ID @ 8660'MD Estimated Top of Cement @—8490'MD/ no 7"x 3-1/2"Packer @—8740'MDrkb/5903'TVDrkb 5792'ND,—1000'above Kuparuk—into the 66 degree tangent angle so we can set the 3-1/2"X Nipple,2.813"ID w RHC-M Profile @ 8820'MD packer in section<67 degrees 3-1/2"XN Nipple,2.725"ID Nogo @ 8900'MD 7"Weatherford Liner Top Packer and Tieback A —9202'MDrkb/6035'ND 0 CI 7",26#L-80 BTC-M,6.276"ID 4-1/2"slotted liner 12.6#L-80 IBT-M 9364'MDrkb/6055'TVDrkb 11178'MDrkb/6012'TVDrkb 1 p 1O 1,\., E E R Date: Revision By: Comments 1/10/2010 Of Proposed Completion 2/12/2010 av Updated for wp08 ODSK-35Ai Injector NATURAL RESOURCES ALASKA 2/26/2010 JAD Updated for wp09 Proposed Well Schematic m 0 0 :,,,, ,,,,,, e 1 24 ' 11 5IL ANNULAR 11 5K w// 11 5K BOTTOM FLANGE �/ 1 T3 MODEL 6012 DOUBLE RAM BOP 11 5K w/ STUDDED TOP & BOTTOM 1 & NO SIDE OUTLETS w/ STD. BONNETS M / 1�11�1I�I ICI 111 ICI I1II1I 55 TON VERTICAL LIFT _ /(PER LUG) 1__ .--_ I_I = ORM ��� �e .3 c[ I mIl; M �--� C, I_.- N mil _ ...711111 0 —_ ill �� Z �_ Ii-.. 111111111!I III I!I IIIlwl!1 DRILLING SPOOL O 0 11 5K FLANGE TOP & BOTTOM 0 oOo w/ (2) — 3.12 5K FLANGE OUTLETS N O O O 0 'T111111111 Ii1 Itil ail I■III l : O Z Cr ` / may_ , ,1-4 4 ,�„� 1 T3 MODEL 6012 SINGLE RAM BOP 0 0 11 5K w/ TOP & BOTTOM 0 oOo 11 5K FLANGES & NO SIDE OUTLETS N I 0 0 O 0 DRILLING SPOOL 11 5K FLANGE TOP & BOTTOM w/ (1) — 3.12 5K FLANGE & (1) — 3.12 5K SWIVEL FLANGE OUTLETS THIS IS A PROPRIETARY DESIGN OF NABORS ALASKA,REPRODUCTION OR USE OF I DESIGN IS PERMISSIBLE ONLY IF AUTHORIZED IN WRITING BY NABORS ALASKA. ���IINabors ���� Nabors Alaska Drilling Inc. I�( 2525 C Street Suite 200 A micas mum=c,,,,. Anchorage, Alaska 99503-2639 907-263-6000 'PROJECT NABORS ALASKA DRILLING — TITLE RIG 19—AC — T3 11' BOP STACK '—"_ 'DRAWN BY CHECKED BY APPROVED BY REV. ROB C. O DATE REV. DWN. APPR. DESCRIPTION SCALE DATE DWG. NO. SHT. NO. BY BY N.T.S. FEB. 2010 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK-35Ai - Slot ODS-35 ODSK-35Ai KupH Plan: ODSK-35Ai KupH wp09 Standard Proposal Report 25 February, 2010 HALLIBURTON Aisiiimenimmsior Sperry Drilling Services 3 3 3 33 - o m m 0) I I 2 22 In oo - z N o 2' a a a a s N(NO O 100 - !00 Wit+/) I- Y Y Y YY 05 aiN4 '-g,g, - o �� —o + + o co co N-7700 N707 N I()N-CO 0) - N cv C CO NNa)NO N MLLOON N,7,7N(0 CA • 0) - (0 OOO O NN NO cON 000,7\010(0010 Q 01--N oLS OLL 1 MMO O M OODN NN ONE h E 1f) ZZ ) �+0+0 ,71010�LL0100(0000N WD za 4 - o o)fCg t i j a K 3 3 (7 -o a Z 0 1-c0 22 00o00-o0000v0000'000000000000 ? o'nn co 70. ¢��� } o 00000i000 o_oo_ Q �mCON- - n 0o q p YininU W a 3 y o>�>o, U - 0 G N1nM �6' m 2 (0 5>3 0)000000 00000000 —0 p+t 9�gg9 �ad U :o C922 0)000)000 00000000 ? .N _ -o F I (J _3 0 N mm a 0 o o 100 MO 0DOth0o)MOMO Da)N N - NO. 3F-) A. 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IIIII _ r _ rm ' e I �■■■ E A 0 °o 11111111111111 : a Ln Mill All .- N 0 'Al N CN CZ F.Z 19 E ° F—e1—a , / WA0�F■ o8o ai!Amy d ( F P_I ` Y ,I Fa • 0 >_0. 7, /0e/ y p ---• ', ce'� 0) Y % .. a ® i ■11■■ O 0 47 Y ri A— v 4.r - ....:r ....., 0 0 hi- -- �-� - °'• �, rt ■n./.�i H _ p !L � -..;I�■M V� Oro • II I 2 r" ' i W I i11./...wMIN_ �■■ _ L., . i - 0 Q o Q o 0 0 0 0 0 0? o o2 Q r� 3; i7S 25 N °n °o N °n t. d5 �1 f0 f0 ,r1 V co co N L..r (ui/ib 00g i,) (+)41ioN/(-)41noS • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC). Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True . Well: ODSK-35Ai Survey Calculation Method: Minimum Curvature • Wellbore: ODSK-35Ai KupH Design: ODSK-35Ai KupH wp09 Project Oooguruk Development 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 ODSK-35Ai-Slot ODS-35 Well Position +N/-S 0.0 ft Northing: 6,031,070.76 ft - Latitude: 70°29'45.448 N +E/-W 0.0 ft Easting: 469,886.60 ft . Longitude: 150°14'46.452 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft . Wellbore ODSK-35Ai KupH Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) I GRF200510 10/31/2007 22.95 80.81 57,670 Design ODSK-35Ai KupH wp09 Audit Notes: This well drills out of the slot 35 surface casing. The A in the name does not indicate a sidetrack. It is there due to the expiration of t Version: Phase: PLAN Tie On Depth: 3,267.0 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.7 0.0 0.0 318.45 Plan Sections I Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (?) (?) (ft) ft (ft) (ft) (?/100ft) (?/100ft) (?/100ft) (?) 3,267.0 41.28 248.82 3,056.9 3,000.7 -207.3 -726.8 0.00 0.00 0.00 0.00 3,277.0 41.28 248.82 3,064.4 3,008.2 -209.7 -733.0 0.00 0.00 0.00 0.00 4,416.5 61.42 328.92 3,844.4 3,788.2 116.1 -1,410.8 5.50 1.77 7.03 103.15 8,559.1 61.42 328.92 5,826.0 5,769.8 3,231.7 -3,289.0 0.00 0.00 0.00 0.00 9,354.7 85.00 325.00 6,054.2 5,998.0 3,864.7 -3,702.7 3.00 2.96 -0.49 -9.68 9,369.7 85.00 325.00 6,055.5 5999.3 3,876.9 -3,711.2 0.00 0.00 0.00 0.00 9,432.2 90.00 324.96 6,058.2 6,002.0 3,928.1 -3,747.1 8.00 8.00 -0.07 -0.49 I 9,810.3 90.00 324.96 6,058.2 6,002.0 4,237.6 -3,964.2 0.00 0.00 0.00 0.00 9,898.3 92.64 325.04 6,056.2 6,000.0 4,309.7 -4,014.6 3.00 3.00 0.10 1.85 I 10,255.7 92.64 325.04 6,039.7 5,983.5 4,602.3 -4,219.2 0.00 0.00 0.00 0.00 10,267.1 92.31 324.96 6,039.2 5,983.0 4,611.6 -4,225.7 3.00 -2.91 -0.71 -166.32 10,267.3 92.31 324.96 6,039.2 5,983.0 4,611.7 -4,225.8 3.00 3.00 0.00 0.00 10,683.6 92.31 324.96 6,022.4 5,966.2 4,952.4 -4,464.7 0.00 0.00 0.00 0.00 10,723.0 91.13 324.96 6,021.2 5,965.0 4,984.6 -4,487.3 3.00 -3.00 0.00 180.00 11,178.7 91.13 324.96 6,012.2 5,956.0 5,357.6 -4,748.8 0.00 0.00 0.00 0.00 2/25/2010 11:18:12AM Page 2 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-35Ai Survey Calculation Method: Minimum Curvature Wellbore: ODSK-35Ai KupH Design: ODSK-35Ai KupH wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 3,000.67 3,267.0 41.28 248.82 3,056.9 3,000.7 -207.3 -726.8 6,030,866.39 469,159.00 0.00 326.96 3,277.0 41.28 248.82 3,064.4 3,008.2 -209.7 -733.0 6,030,864.03 469,152.84 0.00 329.25 Start Dir 5.5/100'3277.00'MD,3064.40'TVD 3,300.0 41.01 250.70 3,081.7 3,025.5 -215.0 -747.2 6,030,858.85 469,138.63 5.50 334.75 3,400.0 40.19 259.06 3,157.7 3,101.5 -231.9 -809.9 6,030,842.13 469,075.88 5.50 363.63 3,500.0 39.98 267.60 3,234.3 3,178.1 -239.4 -873.7 6,030,834.91 469,012.03 5.50 400.37 3,600.0 40.41 276.10 3,310.7 3,254.5 -237.3 -938.1 6,030,837.27 468,947.66 5.50 444.64 3,700.0 41.44 284.35 3,386.3 3,330.1 -225.7 -1,002.4 6,030,849.18 468,883.38 5.50 496.04 3,800.0 43.03 292.19 3,460.4 3,404.2 -204.6 -1,066.1 6,030,870.54 468,819.77 5.50 554.08 3,900.0 45.13 299.50 3,532.3 3,476.1 -174.2 -1,128.6 6,030,901.15 468,757.42 5.50 618.24 4,000.0 47.65 306.25 3,601.3 3,545.1 -134.9 -1,189.3 6,030,940.72 468,696.91 5.50 687.93 4,100.0 50.54 312.45 3,666.8 3,610.6 -86.9 -1,247.6 6,030,988.90 468,638.78 5.50 762.50 4,200.0 53.73 318.13 3,728.2 3,672.0 -30.8 -1,303.0 6,031,045.23 468,583.58 5.50 841.26 4,300.0 57.17 323.34 3,784.9 3,728.7 33.0 -1,355.1 6,031,109.20 468,531.81 5.50 923.50 4,400.0 60.81 328.16 3,836.5 3,780.3 103.8 -1,403.2 6,031,180.23 468,483.95 5.50 1,008.45 4,416.5 61.42 328.92 3,844.4 3,788.2 116.1 -1,410.8 6,031,192.58 468,476.46 5.50 1,022.67 End Dir 4416.50'MD,3844.40'TVD 4,500.0 61.42 328.92 3,884.4 3,828.2 178.9 -1,448.6 6,031,255.53 468,438.86 0.00 1,094.78 4,600.0 61.42 328.92 3,932.2 3,876.0 254.1 -1,494.0 6,031,330.91 468,393.83 0.00 1,181.14 4,700.0 61.42 328.92 3,980.1 3,923.9 329.3 -1,539.3 6,031,406.30 468,348.80 0.00 1,267.49 4,800.0 61.42 328.92 4,027.9 3,971.7 404.5 -1,584.6 6,031,481.68 468,303.77 0.00 1,353.85 4,900.0 61.42 328.92 4,075.7 4,019.5 479.8 -1,630.0 6,031,557.06 468,258.74 0.00 1,440.21 5,000.0 61.42 328.92 4,123.5 4,067.3 555.0 -1,675.3 6,031,632.45 468,213.71 0.00 1,526.56 5,100.0 61.42 328.92 4,171.4 4,115.2 630.2 -1,720.7 6,031,707.83 468,168.68 0.00 1,612.92 5,200.0 61.42 328.92 4,219.2 4,163.0 705.4 -1,766.0 6,031,783.22 468,123.65 0.00 1,699.28 5,300.0 61.42 328.92 4,267.0 4,210.8 780.6 -1,811.3 6,031,858.60 468,078.62 0.00 1,785.63 5,327.5 61.42 328.92 4,280.2 4,224.0 801.3 -1,823.8 6,031,879.33 468,066.23 0.00 1,809.38 Brook 2b 5,400.0 61.42 328.92 4,314.9 4,258.7 855.8 -1,856.7 6,031,933.98 468,033.59 0.00 1,871.99 5,500.0 61.42 328.92 4,362.7 4,306.5 931.0 -1,902.0 6,032,009.37 467,988.56 0.00 1,958.35 5,600.0 61.42 328.92 4,410.5 4,354.3 1,006.2 -1,947.4 6,032,084.75 467,943.53 0.00 2,044.70 5,700.0 61.42 328.92 4,458.4 4,402.2 1,081.4 -1,992.7 6,032,160.14 467,898.50 0.00 2,131.06 5,800.0 61.42 328.92 4,506.2 4,450.0 1,156.6 -2,038.0 6,032,235.52 467,853.46 0.00 2,217.41 5,900.0 61.42 328.92 4,554.0 4,497.8 1,231.8 -2,083.4 6,032,310.91 467,808.43 0.00 2,303.77 6,000.0 61.42 328.92 4,601.9 4,545.7 1,307.0 -2,128.7 6,032,386.29 467,763.40 0.00 2,390.13 6,100.0 61.42 328.92 4,649.7 4,593.5 1,382.3 -2,174.1 6,032,461.67 467,718.37 0.00 2,476.48 6,200.0 61.42 328.92 4,697.5 4,641.3 1,457.5 -2,219.4 6,032,537.06 467,673.34 0.00 2,562.84 6,300.0 61.42 328.92 4,745.4 4,689.2 1,532.7 -2,264.7 6,032,612.44 467,628.31 0.00 2,649.20 6,400.0 61.42 328.92 4,793.2 4,737.0 1,607.9 -2,310.1 6,032,687.83 467,583.28 0.00 2,735.55 6,500.0 61.42 328.92 4,841.0 4,784.8 1,683.1 -2,355.4 6,032,763.21 467,538.25 0.00 2,821.91 6,600.0 61.42 328.92 4,888.9 4,832.7 1,758.3 -2,400.8 6,032,838.59 467,493.22 0.00 2,908.27 6,700.0 61.42 328.92 4,936.7 4,880.5 1,833.5 -2,446.1 6,032,913.98 467,448.19 0.00 2,994.62 6,800.0 61.42 328.92 4,984.5 4,928.3 1,908.7 -2,491.4 6,032,989.36 467,403.16 0.00 3,080.98 6,900.0 61.42 328.92 5,032.4 4,976.2 1,983.9 -2,536.8 6,033,064.75 467,358.13 0.00 3,167.34 2/25/2010 11:18:12AM Page 3 COMPASS 2003.16 Build 42B • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-35Ai Survey Calculation Method: Minimum Curvature Wellbore: ODSK-35Ai KupH Design: ODSK-35Ai KupH wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 4,981.00 6,910.1 61.42 328.92 5,037.2 4,981.0 1,991.5 -2,541.4 6,033,072.37 467,353.58 0.00 3,176.06 Top Torok Ss 7,000.0 61.42 328.92 5,080.2 5,024.0 2,059.1 -2,582.1 6,033,140.13 467,313.10 0.00 3,253.69 7,100.0 61.42 328.92 5,128.0 5,071.8 2,134.3 -2,627.5 6,033,215.52 467,268.07 0.00 3,340.05 7,200.0 61.42 328.92 5,175.9 5,119.7 2,209.6 -2,672.8 6,033,290.90 467,223.04 0.00 3,426.40 7,300.0 61.42 328.92 5,223.7 5,167.5 2,284.8 -2,718.1 6,033,366.28 467,178.01 0.00 3,512.76 7,400.0 61.42 328.92 5,271.5 5,215.3 2,360.0 -2,763.5 6,033,441.67 467,132.98 0.00 3,599.12 7,474.6 61.42 328.92 5,307.2 5,251.0 2,416.1 -2,797.3 6,033,497.89 467,099.40 0.00 3,663.52 Base Torok Ss 7,500.0 61.42 328.92 5,319.4 5,263.2 2,435.2 -2,808.8 6,033,517.05 467,087.95 0.00 3,685.47 7,600.0 61.42 328.92 5,367.2 5,311.0 2,510.4 -2,854.2 6,033,592.44 467,042.92 0.00 3,771.83 7,700.0 61.42 328.92 5,415.0 5,358.8 2,585.6 -2,899.5 6,033,667.82 466,997.89 0.00 3,858.19 7,800.0 61.42 328.92 5,462.9 5,406.7 2,660.8 -2,944.8 6,033,743.20 466,952.86 0.00 3,944.54 7,900.0 61.42 328.92 5,510.7 5,454.5 2,736.0 -2,990.2 6,033,818.59 466,907.83 0.00 4,030.90 8,000.0 61.42 328.92 5,558.5 5,502.3 2,811.2 -3,035.5 6,033,893.97 466,862.80 0.00 4,117.26 8,100.0 61.42 328.92 5,606.4 5,550.2 2,886.4 -3,080.9 6,033,969.36 466,817.77 0.00 4,203.61 8,200.0 61.42 328.92 5,654.2 5,598.0 2,961.6 -3,126.2 6,034,044.74 466,772.74 0.00 4,289.97 8,300.0 61.42 328.92 5,702.0 5,645.8 3,036.8 -3,171.5 6,034,120.12 466,727.71 0.00 4,376.33 8,400.0 61.42 328.92 5,749.9 5,693.7 3,112.1 -3,216.9 6,034,195.51 466,682.68 0.00 4,462.68 8,469.7 61.42 328.92 5,783.2 5,727.0 3,164.5 -3,248.5 6,034,248.07 466,651.28 0.00 4,522.89 Top Hrz 8,500.0 61.42 328.92 5,797.7 5,741.5 3,187.3 -3,262.2 6,034,270.89 466,637.65 0.00 4,549.04 8,559.1 61.42 328.92 5,826.0 5,769.8 3,231.7 -3,289.0 6,034,315.45 466,611.03 0.00 4,600.07 Start Dir 3.0/100'8559.10'MD,5826.00'TVD 8,600.0 62.63 328.68 5,845.1 5,788.9 3,262.6 -3,307.7 6,034,346.41 466,592.45 3.00 4,635.61 8,700.0 65.59 328.14 5,888.8 5,832.6 3,339.2 -3,354.9 6,034,423.22 466,545.64 3.00 4,724.21 8,738.1 66.72 327.93 5,904.2 5,848.0 3,368.8 -3,373.3 6,034,452.87 466,527.30 3.00 4,758.59 I Base Hrz 8,800.0 68.55 327.61 5,927.7 5,871.5 3,417.2 -3,403.8 6,034,501.40 466,496.98 3.00 4,815.06 8,900.0 71.52 327.11 5,961.9 5,905.7 3,496.4 -3,454.5 6,034,580.73 466,446.62 3.00 4,907.90 8,985.6 74.05 326.70 5,987.2 5,931.0 3,564.8 -3,499.1 6,034,649.36 466,402.28 3.00 4,988.73 Kalubik Mkr 9,000.0 74.48 326.63 5,991.1 5,934.9 3,576.4 -3,506.8 6,034,661.01 466,394.69 3.00 5,002.49 9,100.0 77.45 326.16 6,015.4 5,959.2 3,657.2 -3,560.5 6,034,742.00 466,341.33 3.00 5,098.56 9,200.0 80.41 325.70 6,034.6 5,978.4 3,738.5 -3,615.5 6,034,823.50 466,286.69 3.00 5,195.85 9,202.7 80.49 325.68 6,035.0 5,978.8 3,740.7 -3,617.0 6,034,825.74 466,285.17 3.00 5,198.53 KupH v9 GeoPoly 9,300.0 83.38 325.24 6,048.7 5,992.5 3,820.1 -3,671.6 6,034,905.27 466,230.91 3.00 5,294.10 9,354.7 85.00 325.00 6,054.2 5,998.0 3,864.7 -3,702.7 6,034,950.00 466,200.00 3.00 5,348.11 End Dir 9354.70'MD,6054.20'TVD-Kup C-KupH v9 T1 9,364.7 85.00 325.00 6,055.1 5,998.9 3,872.9 -3,708.4 6,034,958.21 466,194.30 0.00 5,358.05 7" 9,369.7 85.00 325.00 6,055.5 5,999.3 3,876.9 -3,711.3 6,034,962.30 466,191.46 0.00 5,362.99 Start Dir 8.0/100'9369.70'MD,6055.50'TVD 9,400.0 87.43 324.98 6,057.5 6,001.3 3,901.7 -3,728.6 6,034,987.13 466,174.22 8.01 5,393.03 2/25/2010 11:18:12AM Page 4 COMPASS 2003.16 Build 42B . Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-35Ai Survey Calculation Method: Minimum Curvature Wellbore: ODSK-35Ai KupH Design: ODSK-35Ai KupH wp09 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 6,002.03 9,432.2 90.00 324.96 6,058.2 6,002.0 3,928.1 -3,747.1 6,035,013.56 466,155.85 8.00 5,425.01 End Dir 9432.20'MD,6058.20'TVD 9,500.0 90.00 324.96 6,058.2 6,002.0 3,983.6 -3,786.0 6,035,069.22 466,117.15 0.00 5,492.37 9,600.0 90.00 324.96 6,058.2 6,002.0 4,065.4 -3,843.4 6,035,151.32 466,060.06 0.00 5,591.73 I 9,700.0 90.00 324.96 6,058.2 6,002.0 4,147.3 -3,900.8 6,035,233.42 466,002.98 0.00 5,691.08 9,800.0 90.00 324.96 6,058.2 6,002.0 4,229.2 -3,958.3 6,035,315.51 465,945.90 0.00 5,790.44 9,810.3 90.00 324.96 6,058.2 6,002.0 4,237.6 -3,964.2 6,035,324.00 465,940.00 0.00 5,800.71 Start Dir 3.0/100'9810.30'MD,6058.20'TVD-KupH v9 T2 9,898.3 92.64 325.04 6,056.2 6,000.0 4,309.7 -4,014.6 6,035,396.22 465,889.86 3.00 5,888.07 End Dir 9898.30'MD,6056.20'TVD 9,900.0 92.64 325.04 6,056.1 5,999.9 4,311.1 -4,015.6 6,035,397.62 465,888.90 0.00 5,889.75 10,000.0 92.64 325.04 6,051.5 5,995.3 4,392.9 -4,072.8 6,035,479.71 465,832.00 0.00 5,988.99 10,100.0 92.64 325.04 6,046.9 5,990.7 4,474.8 -4,130.1 6,035,561.81 465,775.10 0.00 6,088.22 10,200.0 92.64 325.04 6,042.3 5,986.1 4,556.7 -4,187.3 6,035,643.90 465,718.20 0.00 6,187.45 10,255.7 92.64 325.04 6,039.7 5,983.5 4,602.3 -4,219.2 6,035,689.62 465,686.51 0.00 6,242.72 Start Dir 3.0/100'10255.70'MD,6039.70'TVD 10,267.1 92.31 324.96 6,039.2 5,983.0 4,611.6 -4,225.7 6,035,699.00 465,680.00 2.99 6,254.06 KupH v9 T3 10,267.3 92.31 324.96 6,039.2 5,983.0 4,611.8 -4,225.8 6,035,699.14 465,679.90 2.20 6,254.24 End Dir 10267.30'MD,6039.20'TVD 10,300.0 92.31 324.96 6,037.9 5,981.7 4,638.5 -4,244.6 6,035,725.97 465,661.25 0.00 6,286.70 1 10,400.0 92.31 324.96 6,033.8 5,977.6 4,720.3 -4,302.0 6,035,808.00 465,604.22 0.00 6,385.97 10,500.0 92.31 324.96 6,029.8 5,973.6 4,802.1 -4,359.3 6,035,890.04 465,547.19 0.00 6,485.25 10,600.0 92.31 324.96 6,025.8 5,969.6 4,884.0 -4,416.7 6,035,972.07 465,490.17 0.00 6,584.52 10,683.6 92.31 324.96 6,022.4 5,966.2 4,952.3 -4,464.7 6,036,040.65 465,442.49 0.00 6,667.51 Start Dir 3.0/100'10683.60'MD,6022.40'TVD 10,700.0 91.82 324.96 6,021.8 5,965.6 4,965.8 -4,474.1 6,036,054.10 465,433.14 3.00 6,683.80 10,723.0 91.13 324.96 6,021.2 5,965.0 4,984.6 -4,487.3 6,036,073.00 465,420.00 3.00 6,706.66 End Dir 10723.00'MD,6021.20'TVD-KupH v9 T4 10,800.0 91.13 324.96 6,019.7 5,963.5 5,047.6 -4,531.5 6,036,136.19 465,376.07 0.00 6,783.13 10,900.0 91.13 324.96 6,017.7 5,961.5 5,129.5 -4,588.9 6,036,218.27 465,319.01 0.00 6,882.46 11,000.0 91.13 324.96 6,015.7 5,959.5 5,211.3 -4,646.3 6,036,300.35 465,261.95 0.00 6,981.80 11,100.0 91.13 324.96 6,013.8 5,957.6 5,293.2 -4,703.7 6,036,382.44 465,204.88 0.00 7,081.13 11,178.6 91.13 324.96 6,012.2 5,956.0 5,357.5 -4,748.8 6,036,446.96 465,160.03 0.00 7,159.21 Total Depth at 11178.70'MD,6012.20'TVD . 11,178.7 91.13 324.96 6,012.2 . 5,956.0 5,357.6 -4,748.8 6,036,447.00 465,160.00 0.00 7,159.26 KupH v9 T5 2/25/2010 11:18:12AM Page 5 COMPASS 2003.16 Build 428 • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-35Ai Survey Calculation Method: Minimum Curvature Wellbore: ODSK-35Ai KupH Design: ODSK-35Ai KupH wp09 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (?) (?) (ft) (ft) (ft) (ft) (ft) KupH v9 T3 0.00 0.00 6,039.2 4,611.6 -4,225.7 6,035,699.00 465,680.00 -plan hits target -Point KupH v9 T1 0.00 0.00 6,054.2 3,864.7 -3,702.7 6,034,950.00 466,200.00 -plan hits target -Point KupH v9 T4 0.00 0.00 6,021.2 4,984.6 -4,487.3 6,036,073.00 465,420.00 -plan hits target -Point KupH v9 T2 0.00 0.00 6,058.2 4,237.6 -3,964.2 6,035,324.00 465,940.00 -plan hits target -Point KupH v9 GeoPoly 0.00 0.00 6,054.0 3,629.8 -3,773.5 6,034,715.42 466,128.24 -plan misses by 192.8ft at 9202.5ft MD(6035.0 TVD,3740.5 N,-3616.8 E) -Polygon Point 1 6,054.0 3,629.8 -3,773.5 6,034,715.42 466,128.24 Point 2 6,054.0 3,869.6 -3,947.2 6,034,955.90 465,955.53 Point 3 6,054.0 4,120.4 -4,130.1 6,035,207.41 465,773.67 Point 4 6,054.0 4,354.8 -4,300.3 6,035,442.47 465,604.43 Point 5 6,054.0 4,516.1 -4,417.7 6,035,604.23 465,487.70 Point 6 6,054.0 4,839.1 -4,653.1 6,035,928.15 465,253.63 Point 7 6,054.0 5,081.6 -4,829.8 6,036,171.34 465,077.94 Point 8 6,054.0 5,306.7 -4,994.0 6,036,397.08 464,914.67 Point 9 6,054.0 5,572.2 -4,618.5 6,036,661.03 465,291.20 Point 10 6,054.0 5,341.1 -4,462.8 6,036,429.33 465,445.95 Point 11 6,054.0 5,078.9 -4,285.9 6,036,166.44 465,621.77 Point 12 6,054.0 4,761.0 -4,071.5 6,035,847.70 465,834.85 Point 13 6,054.0 4,594.9 -3,959.9 6,035,681.17 465,945.77 Point 14 6,054.0 4,346.4 -3,792.6 6,035,432.02 466,112.04 Point 15 6,054.0 4,041.4 -3,586.9 6,035,126.22 466,316.49 Point 16 6,054.0 3,847.3 -3,457.4 6,034,931.62 466,445.19 KupH v9 T5 0.00 0.00 6,012.2 5,357.6 -4,748.8 6,036,447.00 465,160.00 -plan hits target -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,257.0 3,049.4 9 5/8" 9.625 12.250 9,364.7 6,055.1 7" 7.000 8.750 11,178.7 6,012.2 4 1/2" 4.500 6.125 2/25/2010 11:18:12AM Page 6 COMPASS 2003.16 Build 428 • Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-35Ai Survey Calculation Method: Minimum Curvature Wellbore: ODSK-35Ai KupH Design: ODSK-35Ai KupH wp09 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (?) (?) 8,985.6 5,987.2 Kalubik Mkr 0.00 6,910.1 5,037.2 Top Torok Ss 0.00 7,474.6 5,307.2 Base Torok Ss 0.00 9,354.7 6,054.2 Kup C 0.00 8,738.1 5,904.2 Base Hrz 0.00 8,469.7 5,783.2 Top Hrz 0.00 5,327.5 4,280.2 Brook 2b 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 3,277.0 3,064.4 -209.7 -733.0 Start Dir 5.5/100'3277.00'MD,3064.40'TVD 4,416.5 3,844.4 116.1 -1,410.8 End Dir 4416.50'MD,3844.40'TVD 8,559.1 5,826.0 3,231.7 -3,289.0 Start Dir 3.0/100'8559.10'MD,5826.00'TVD 9,354.7 6,054.2 3,864.7 -3,702.7 End Dir 9354.70'MD,6054.20'TVD 9,369.7 6,055.5 3,876.9 -3,711.3 Start Dir 8.0/100'9369.70'MD,6055.50'TVD 9,432.2 6,058.2 3,928.1 -3,747.1 End Dir 9432.20'MD,6058.20'TVD 9,810.3 6,058.2 4,237.6 -3,964.2 Start Dir 3.0/100'9810.30'MD,6058.20'TVD 9,898.3 6,056.2 4,309.7 -4,014.6 End Dir 9898.30'MD,6056.20'TVD 10,255.7 6,039.7 4,602.3 -4,219.2 Start Dir 3.0/100'10255.70'MD,6039.70'TVD 10,267.3 6,039.2 4,611.8 -4,225.8 End Dir 10267.30'MD,6039.20'TVD 10,683.6 6,022.4 4,952.3 -4,464.7 Start Dir 3.0/100'10683.60'MD,6022.40'TVD 10,723.0 6,021.2 4,984.6 -4,487.3 End Dir 10723.00'MD,6021.20'TVD 11,178.6 6,012.2 5,357.5 -4,748.8 Total Depth at 11178.70'MD,6012.20'TVD 2/25/2010 11:18:12AM Page 7 COMPASS 2003.16 Build 428 FM CC Q1 3 C L. 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EE o z F- FQ CO U W L, 0 0 .9, 9, 0 o •95 1 <1 • 0 �c ° 6k 0 o d B'i 8 c O� ° O M `� 0 i 9„ . 11 O t ' �� ° m 7 A. 0 a g o `� 3 S a$ =N V O mg A\ ^ VJ O Z C 0 mv,c O ° ° m 0 J R z°oa 3 i ■ 1' I1 I i 1 I I • -ADiriricI boon dry [ r I SE Corner of 1 + \000cURUK SITE Protracted Sections 11 C. 1 ' m re f : ' . i ,_ r. " �1 Coordinates I / I N 6028111.04 e' 1 E 470989.01 i, I \i . i . o o� V►-2, >: 1 Ref. AK .BLM :. - - , cr j `• ''\ Harrison Bay Troct: "A" a■1 1-24\Q I J\'' ` �� F ,�► •� I'�A11,G r 'v j 9. ; 12j, I � PI-' -, • .. `, r �, Offshore Iceroce.,- 99 iJUet •, �� Near Shore ; erood.3.82'U5Ies ,' Pi-13 r Pi 20 to •... rak Site •% PI 7 tc P 20 �.. 1 v ,14' � ,� \ PY-1-14 I PI-2. i/ PI-16 , - --- 1•N, -.o►-n as i e.o.` y z, _ ♦ PI_ ? I Roads to Ldo _ J! I s, �i. do DS 3.I A C j '�:�i PI- . s Pi-is .1 3H_ s ///e Basis of Location 1`� I BBC '. 7�y%/,Cl, ,� / _ ` / 'rte Basis West Monument Coordinates id 1 -, i • N 6001016.61 • — - E 498081.23 STAKED PI INFORMATON ONLY p --', A. O J✓ r L , j =_� Ref. Lownsbury & Assoc ' ^I�CC V I �t 1 I -________ Drawing No. NSK 6.01—d672 �E OF A( lti `� , S � ce` i �� j �1 Viler :•c • • ilip G.Davis .'.10 I s.. r �.Y r % No. .J' .;;.c= ; . —<' . : , ,l9fpA ••.»r•m••PaOe',r ,•,.._ 1 -r-- 1 , rESSIONA. , + 11%91.106.10101IP Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Rance 7 East DATE: 7-12-07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location 05204 2 of 4 Alaska Statr ne ection Line Offset Well Np, -- -_...__ ei _.___ -- -__- .X-.-- Latitude (N) Longltuac (W) _ F$L — Pad Elev, FEL 1 6,031,151.32 469,920.45 70 29 46 24160 150 14 45.46468 3035 _1077 13.50 2 -6,031,146.35 469,915.52 70 29 45,19252 150 14 45,60922 3030 1032 13,50 3 ----6,0-17141,39 -.469,910,5.9 70 29 46.14354 150 14 45.75375 3025 ' 1087 13.50 4 6,031,136.46 469,905.67 70 29 46.09485 150-14 45.89799 3020 1092 13.50 5 6,031,131.40 -469;900.74 • 70 29 46,04538 150 14 46.04252 3015 1097 —1-3,60 6 6,031,126,51 - 469,895 80 70 29 45,99660 150 14 46,18735 3010 1102 13.50 7 _6,03'1,113,73 469,883.13 70 29 45.87030 -150 14 4655879 2997 1115 13,50 3'1,108.73 4697878.29 70-29 45.82102 1W-1-4 2992 1120 13750 9 6,031,103.75 469,873.26 70 29 45.77184 150 14 46.84814 2987 1125 13.50 10 6,031,098.79 - 469,868,36 70 29 45.72286 150 14 46,99179 2982 1130 13,50 11 6,031,093.84 469,863 39 70 29 45 67398 150 14 47 137 60 2977 1135 13 50 12 6,03-1-,088,87- 409,658-.47 70 29 45.62490 150 14 47.28174 2972 1140 13.50 13 8,03f,070,08- 469,845,81 70 29 45.9.9840 150 14 47.65288 2960 1152 13.50 14 6,031,071,09 469,8.40.87 70 29 4.4494— 150 1-4-47,79770 2955 1157 13-50 -- -- 15 6,031,066.15 469,835.96 70 29 45.40053--150-14 47,94105 2950 -110g-------13.50---- 6,031,061.18 469,831,04 70 29 45.35145 150 14 48,08588 . 2945 1167 13.50 17 6,031,056.25 469,826,11 70 29 45.30277 1501448.23042 2940 1172 13.50 —18 6,031,051.27 469,821:18 70 29 45.25359 150 14 48:374.95 2935 1177 13.50 19 CO3'1,0-8:62 469,808,50 70 29 45.12768 -150 14 48.74668 2922- 1189 -1-3,50 2Q 6,031,033.50 469,803.59 70 29 4507811 150 14 48.89061 2917 1194 13.50 21 6,031,028.53 469,798.62 70 29 45.02903 150 14 4-9,03632 2912 1199 13.50 2 6,031,023,58 469,793,67 70 29 44,98014 150 14 49,18144 2907 -1-2-0-47------1-3-.80— 23 6,031,018.57 469,788,76 70 29 44,93067 150 14 49.32537 2902 1209 1-3.50 24 - 5,03 .013,50 - 469,783,84 70 29 44.8819 1501$49.40900 2897 1214 - 1-3,50 s'1P�t'Of•4(•a t1� *J 9T t*ie Philip G.Davis : o% ; 4 sj ti• No.4110-5 .4;‘.7�, 0i i1 "r■F..r.s".z.w -v+ ;L :174 ` •-. ' - , ;six 4, . Notes: 1/4s .f 1, Eleyotion Qre based On BP Meon 5co Level, - ...--- 2, OQordinctes are 6Qsed on AIoskc Stote P!Qne Ned 27, ztyne 4, 3, All conductors ore within Protrgcted Section 11. Pioneer Notur-QI Re5cDuce I.QE NAME: Qoogur-uk Drill Site Conductors DRAWN 3Y BL CHECKED EY; MJD Protr-octed Section 11 SCALE: VA :Qi�ATIQN; Township 13 North RQn9e 7 East DATE; 7=12=07 L1miet Meridian NANUOQ j0E3 NO. SHEET ESCRIPTION: As-built Coordinctes 05204 3 of 4 Alaska Slat ne Section Line Offset Well No. Y X Latitude (N) Lonoituc .1) FSL FEL Pad Elev. 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 45.06895 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 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 45.87163 2975 1092 13.50 32 6,031,085.68 469,901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 33 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 37 6,031,053.00 469,869.00 70 29 45.27251 150 14 46.96749 2937 1129 13.50 38 6,031,047.99 469,864.14 70 29 45.22304 150 14 47.10995 2932 1134 13.50 39 6,031,043.03 469,859.20 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 6,031,033.05 469,849.29 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 45 6,031,005.53 469,821.86 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 SURVEYOR'S CERTIFICATE OF•4` ,i 4 ! ,+1P:' '••.'�� j! I HEREBY CERTIFY THAT I AM a h: 1 S PROPERLY REGISTERED AND * r4 ` TH * �.* /d LICENSED TO PRACTICE LAND - ' `'� _ j"'f �T.' •"° SURVEYING IN THE STATE OF � . . /. . ALASKA AND THAT THIS PLAT „ �I ' ' /•• . REPRESENTS A SURVEY DONE BY ; ' • �F ib�G.Davis •N. :4,41/4'40 ME OR UNDER MY SUPERVISION 1 '4(e.••• NO'4110-5,. o AND THAT I BELIEVE THAT ALL I O�•••'••'•• ∎Fo o DIMENSIONS AND OTHER DETAILS s � �+F � ,41 ;"• k11\oy�r,�-�'+ ARE CORRECT AS SUBMITTED TO ME BY NANUQ, INC. AS OF JULY 12TH, 2007. Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 Eost DATE: 7-12-07 Umiot Meridian NANUQ JOB NO. SHEET DESCRIPTION: As-built Coordinates 05204 4 of 4 TRANSMITTAL LETTER CHECKLIST WELL NAME C)c-r C L� L. Obc--ThkS (S S l c PTD# 2_. / 0 C Developmentervice Exploratory Stratigraphic Test Non-Conventional Well FIELD: /f POOL: or, t, 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 , Permit No. , (If last two digits in API No. . Production / injection should API number are continue to be reported as a function of the original API number between 60-69) 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. Should conventional core be acquired in this well, representative chip samples from each foot of core must be submitted to the Commission in accordance with 20 AAC 25.071. 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. 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Permit No: 210-012 Surface Location: 2955' FSL, 1111' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 3165' FSL, 265' FEL, SEC. 3, T13N, R7E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced service 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, Daniel T. . -amount V-<1 Chair DATED this day of January, 2010 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA RECEIVEY AL,+or(A OIL AND GAS CONSERVATION COML-..iION PERMIT TO DRILL i It\I 2 2 2010 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj 0 , Single Zone Q • 3, e Ong le Yamaw�i�5 Drill El • Redrill ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas tqt�lidrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ ' 2.Operator Name: 5. Bond: Blanket pi Single Well ❑ 11.Well Name and Number: n Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 ODSK ,5i!-. ITT 3.Address: 700'G"Street,Suite 600 6.Proposed Depth: '12.Field/Pool(s): Anchorage,AK 99501 MD: 11,020' ' TVD: 5976' • / z.�"c3� 4a. Location of Well(Govemmental Section): 7.Property Designation(Lease Number): Oooguruk-Kuparuk Oil Pool , Surface: 2955'FSL', 1111'FEL,Sec. 11,T13N, R7E,UM ' ADL 355036 • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2306'FSL,5065'FEL,Sec.2,T13N, R7E,UM 417497 2/18/2010 • Total Depth: 9.Acres in Property: X14.Distance to Nearest Property: 3165'FSL,265'FEL,Sec.3,T13N,R7E,UM 5760 2114' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 56.2 • feet 15.Distance to Nearest Well Open Surface: x-469886.60 . y-6031070.76 . Zone-ASP 4 ' GL Elevation above MSL: 13.5 . feet to Same Pool: ODSK-38i is 5134'away '16.Deviated wells: Kickoff depth: 3267 feet • 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 92.79 degrees Downhole: 3032 , Surface: 2367 . 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) 8-3/4" 7" 26# L-80 BTC 9988' Surface Surface 10,031' 5990' 145 sx Class'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1139' 9881' 5966' 11,020' 5976' Uncemented Slotted 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): 3267' 3057' N/A 3255' 3048' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 110' 16" Driven 158' 158' Surface 3217' 9-5/8" 438 sx PF'L';201 sx Class'G' 3257' 3049' Intermediate - Production Liner • -Perforation Depth MD(ft): N/A Perforation Depth TVD(ft): N/A 20. Attachments: Property Plat El BOP Sketch❑ Drilling Program El Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report p Drilling Fluid Program 13 20 AAC 25.050 requirements El 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Alex Vaughan,343-2186 Prepared By:Kathy Campoamor,343-2183 Printed Name m Johnson Title Sr.Staff Drilling Engineer Signature `••� Phone 343-2111 Date 1/22/2009 Commission Use Only Permit to Drill API Number: Permit Appr 'See cover letter for other Number: ,.Z_1 LAC,)/j.O 50-7e)•3- 7e_c�,Z`--('il -Cc.: Date: /s /� requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce albed ethane, s hydrates,or gas contained in shales:Er- Other Q(�D 7;7,1- Samples req'd: Yes❑ Nog Mud log req'd: Yes ❑ o D .� ySGb �°S� 1 -�' / H2S measures: Yes❑ No[ Directional svy req'd: Yes E No❑ 7fZ5QC� i0Sv A w lG$ `�+%."�) CZ - ,r,.i * 1... < Pa Dives +er toc,i.v�� rJzo AA4c 2S.6 35( ) ) 1»., - (A.1+4 rvt.t,j.4- ptrJ%e" ;01, 0014 w . Ar. 33 /ar7 9 APPROVED BY THEGOMMISSION / /�� DA ,COMMISSIONER ORIGINA /•4:'° form 10-401.(Revised 7/2009) This permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Submit in Duplicate RECEIVE D PIONEER NATURAL RESOURCES ALASKA JAN 2 2 2010 Alaska Oil&Gas Cans.Co n fission January 22, 2010 Anchorage State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 �� RE: Application for Permit to Drill ODSK f A Previous PTD # 207-181 z s Surface Location: 2955' FSL, 1111' FEL, Sec 11, T13N, R7E, UM X = 469,886.60, Y = 6,031,070.76, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a development well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be an injection well in the Oooguruk-Kuparuk formation. Pioneer Natural Resources request a change of service from originally named ODSK-35 (PTD #207-181) production well to an injection well hereby named ODSK-35i according to convention. ODSK-35 surface hole was drilled, cased, and cemented February, 2008. To clarify, the planned bottom hole location for ODSK-35i will take the place of the planned bottom hole location for ODSK-13 (PTD #209-146), which has been suspended at surface casing point. A revised permit to drill for ODSK-13 will be requested with a new bottom hole location that adheres to approved pool rules. As indicated in the attachments, the drilling and well construction program includes the following: • Surface Hole: • o Previously set 9-5/8" casing at 3257' MD/3049' TVDrkb. • Intermediate Hole: o Drill 8-3/4" to -10031' MD / 5990' TVDrkb and set 7" casing into the top of the - Oooguruk-Kuparuk formation. • Production Hole: o Drill 6-1/8" horizontally to -11020' MD / 5976' TVDrkb and set a 4-1/2" slotted . liner. • Completion: o 3-1/2"tubing and injection completion. Alaska Oil & Gas Conservation Commission January 22, 2010 Page 2 of 3 PNRA will implement Managed Pressure Drilling technology (MPD) while drilling the Intermediate and Production hole sections of ODSK-35i. PNRA plans to use this technique while drilling the Intermediate and Production intervals as outlined below. • From the Surface Shoe to Intermediate TD o Use —8.8 to 10.5 ppg fluid while using MPD to control pressure from the surface from —10.5 to12.5 ppg EMW at the bottom of the hole. • Open formations: • Kuparuk Sands, —9.8 ppg Pore Pressure • From the Intermediate Shoe to TD o Use —8.6 to 8.8 ppg fluid while using MPD to control pressure from the surface from —9.8 to10.2 ppg EMW at the bottom of the hole during connections and while tripping Utilizing the MPD process described above allows PNRA to reduce the materials needed for the well, increasing the overall safety of the personnel on the development by handling less material. In addition the lower solids in the production section mud system will reduce formation damage along the sandface of the well. 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. In the future, PNRA may provide information and permitting requesting annular disposal of drilling wastes on this well. 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 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 summary of the drilling operations. e. A summary of drilling hazards per 20 AAC 25.005 (c) (4). f. A wellbore schematic is also attached visually depicting the proposed well. 3) A copy of the Planned Directional Well Path - including traveling cylinder and development layout plots. The following items are on file with the AOGCC: Alaska Oil & Gas Conservation Commission January 22, 2010 Page 3 of 3 1) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). 2) 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). 3) A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). 4) 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. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Vern Johnson, Senior Staff Drilling Engineer (20 AAC 25.070) 907.343.2111 vern.johnson @pxd.com 2) Geologic Data and Logs Paul Daggett, Senior Staff Geophysicist (20 AAC 25.071) 907.343.2134 paul.daggett @pxd.com The anticipated spud date for this well is February 18, 2010. If you have any questions or require further information, please contact Vern Johnson at 907.343.2111. Sincer- y, /Az/Zola Vern Johnson Senior Staff Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSK-35i Well File Permit to Drill Well Plan Summary ODSK- S,4 ,fit G ,,, Oooguruk - Kuparuk Injection Well Surface TD @ 3,257' MD / 3,049' TVD (Previously Cased) Intermediate TD @ 10,031' MD / 5,990' TVD Production TD @ 11 ,020' MD / 5,976' TVD Surface Location: 2955' FSL, 1111' FEL, Sec 11, T13N, R7E, UM • ASP 4 (NAD27) projection X=469,886.60 Y=6,031,070.76 Target: Oooguruk-Kuparuk 2306' FSL, 5065' FEL, Sec2, T13N, R7E, Umiat X=465,949.70 Y= 6,035,715.40 I 5,990' TVDrkb Bottom Hole Location: 3165' FSL, 265' FEL, Sec. 3, T13N, R7E, Umiat X=465,471.76 Y=6,036,579.71 5,976' TVDrkb AFE Number: TBA Est. Start Date: February 18, 2010 Rig: Nabors 19AC Operating days: 29 days to Drill and Complete TD:11,020' MD/5,976 TVDrkb Objective: Kuparuk I Well Type (exp, dev, etc): Development Well Design: Modified Slimhole (9-5/8"x 7"x 4-1/2" liner)— Injector—wp05 Current Mechanical Condition: Well Bay Footing/ODS Ground Level: Elevation above MSL: 13.5' • RKB to Ground Level: 42.66' Rig Elevation: RKB + MSL = 56.16' • Conductor: 158' MDrkb Pioneer Natural Resources Last Revised:January 22,2010 ODSK-35i Permit To Drill Page 1 of 9 Well Control: Intermediate Section: • Maximum anticipated BHP: 3032 psi @ 5990'TVDss (Based on 9.8 ppg Oooguruk-Kuparuk pore pressure) • Maximum surface pressure: 2373 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Production Lateral Section: • Maximum anticipated BHP: 3024 psi @ 5976'TVDss (Based on 9.8 ppg Oooguruk-Kuparuk pore pressure) • • Maximum surface pressure: 2367 psi @ surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) Maximum casing pressure: 4500 psi @ surface Planned BOP test pressure: 4500 psi (annular to 2500 psi) Due to required 4500 psi casing pressure test. Planned completion fluid: 10.2 ppg Brine/6.8 ppg Diesel Diverter(see attached schematic)—Note: Requesting Diverter Exemption on a Well by Well Basis): Hydril 21-1/4"2M annular BOP 1 16"full opening knife gate valve, hydraulically actuated 1•10-e.� tia`` 16"diverter line I') -5 5000 psi BOP stack(see attached schematic): /.i4.to 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 Pioneer Natural Resources Last Revised:January 22,2010 ODSK-35i Permit To Drill Page 2 of 9 Formation Integrity Testing Requirements: Test Point Depth Test Type Minimum EMW 9-5/8"Surface Shoe Rathole + 20' to 50'from shoe LOT 12.5 ppg 7" Intermediate Shoe Rathole + 20'from shoe FIT 12.5 ppg Drilling Fluids Program: Intermediate Hole Mud Properties: 8-3/4" hole LSND Interval Density(ppg) Viscosity(secs) YP PV MBT API FL Initial to HRZ 8.8 40-60 15-25 12-20 < 12 8 - 10 (-10.5 via MPD) HRZ to TD 10.5 50-70 15-25 15-25 < 10 3-5 (8-10 HTHP) (-12.5 via MPD) Production Hole Mud Properties: 6-1/8" hole LSND Interval Density(ppg) Viscosity(secs) YP PV MBT API FL Initial to TD 8.6-8.8 37-50 13- 18 5- 14 < 5 <8 (-10.2 via MPD) Formation Markers: Pore Press. EMW Formation Tops MD (ft) TVDrkb (ft) (psi) (ppg) Comments Base of Permafrost 1666 Top West Sak 2303 2281 8.65 Base of fluvial sands Tuffaceous Shales 3134 2957 Brook 2b 5653 4322 Top Torok Ss 7500 5059 2275 8.65 Base Torok Ss 8114 5304 Top Hrz 9228 5748 Base Hrz 9509 5859 Kalubik Mkr 9792 5947 _ 1 Kup C 10040 5990 3053 9.8 TD 11020 5976 Pioneer Natural Resources Last Revised:January 22,2010 ODSK-35i Permit To Drill Page 3 of 9 Logging Program: Intermediate Section: Drilling: Dir/GR/ Res Open Hole: N/A Cased Hole: N/A Production Section: Drilling: Mud logging Dir/GR/Azm Res/Dens/Neut/PWD/BatSonic • Open Hole: N/A Cased Hole: N/A Pioneer Natural Resources Last Revised:January 22,2010 ODSK-35i Permit To Drill Page 4 of 9 Casing Program: Hole Casing/ Weight Grade Conn. Casing Csg/Tbg Top Hole Btm Size Tubing Length MDrkb MDrkb/TVDrkb 24" 16" 109# H-40 Welded 115' Surface 158'/ 158' 12-1h 9-5/8" 40# L-80 BTC 3214' Surface 3,257'/3,049' 8-%" 7" 26# L-80 BTC-M 9988' Surface 10,031'/5,990' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1,139' 9,881' 11,020'/5,976' Tubing 3-1/2" 9.3# L-80 TSHP/TCII 9,972' Surface 10,015'/6,059' Casing Properties Size Weight Grade ID Drift Conn. Internal Collapse Tensile Strength ID Yield (psi) (psi) Joint Body 16" 109# H-40 14.67" 14.5" Welded Conductor casing 9-5/8" 40# L-80 8.835' 8.75" Hydril 521 5750 3090 916 M 916 M 7" 26# L-80 6.276" 6.75 Hydril 511 7240 5410 604 M 604 M 4-1/2" 12.6# L-80 3.958" 3.833" IBT-M 289 M 289 M slotted 3-1/2" 9.3# L-80 2.992" 2.867" TSHP/TCII 10160 10540 207 M 207 M Cement Calculations: Casing Size: I 7" Intermediate-single stage Basis: TOC: -9,250'MD-250' MD above packer depth 781'annulus volume +30% excess, +85'shoe track Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 12.5 ppg Dual Spacer Primary 30.4 bbls/ 145 sx Premium "G" + adds. 1.17 cf/sk Displ 380 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. Disposal: Annular Iniection: 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:January 22,2010 ODSK-35i Permit To Drill Page 5 of 9 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre-Rig Work 1. 16" Conductors have been set and the Well Bay modules have been placed. Rig Activity: Drill and Complete 1. MIRU Nabors 19AC over pre-installed 9-5/8"surface casing. 2. RU circulation lines and circulate out the diesel freeze protection fluid. Ensure the well is dead. 3. Install TWC, ND Tree, NU BOPE, Remove TWC. 4. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 5. Pull circulation tubing string from the well. 6. MU 8-3/4"directional drilling, MWD/LWD on 5" DP. RU MPD trip nipple. 7. RIH and cleanout casing to landing collar. 8. Drill through drilling liner shoe +20'of new hole and perform LOT to a minimum of 12.5 ppg. 9. RD MPD trip nipple and RU bearing assembly. Drill 8-3/4" Intermediate to section TD. 10. Circulate and condition the well to run 7" intermediate casing. Displace the well over to -12.5 ppg for shale stability. RD the MPD bearing assembly and RU MPD trip nipple. POH. 11. Change one set of pipe rams to 7"and test BOPE as required. 12. Run and cement the 7" intermediate casing. 13. Bump the plug and bring the pressure up to 4500 psi-chart and hold for 30 minute pressure test. Send chart to ODE. Release pressure and ensure floats are holding. 14. LD5" DP 15. Change pipe rams to 4"and test BOPE to 250/4500 psi-Notify AOGCC 48 hours in advance of test. 16. PU 4" DP as needed to TD the Production hole section. 17. MU 6-1/8" MWD/LWD motor drilling assembly on 4" DP. RU MPD trip nipple. RIH and cleanout to landing collar. RD MPD trip nipple and RU bearing assembly. 18. Drill through Intermediate shoe, rathole +20'of new hole and perform FIT to 12.5 ppg. 19. Displace to drill-in-fluid for production Feral. 20. Drill 6-1/8" Intl production hole to TD. 21. Circulate and condition the hole to run liner and POOH. 22. Change one set of pipe rams to 4-1/2"and test BOPE as required. 23. RIH w/4-1/2"slotted production liner from 150' inside the intermediate shoe to TD. • 24. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine and , POOH. 25. MU completion and RIH. 26. Land the tubing and RILDS. Install TWC. 27. ND BOPE, NU tree and test to 5,000 psi. 28. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to -2000'TVD and allow to u-tube. 29. Drop ball and rod and allow to seat. Pressure test the tubing to 4,500 psi-chart and hold for 30 minutes. Bleed off pressure and then pressure test the annulus to 4,500 psi-chart and hold for 30 minutes. Bleed off pressure. 30. RDMO to next well. Post-Rig Work Pioneer Natural Resources Last Revised:January 22,2010 ODSK-35i Permit To Drill Page 6 of 9 31. RU Slickline and pull the ball and rod. Pull the RHC-m plug. 32. RD Slickline. Pioneer Natural Resources Last Revised:January 22,2010 ODSK-35i 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(or Formation Integrity Test): • Calculate the required test pressure to reach leak off (or formation integrity test limit)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/FIT. • 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. Note: For FIT, do not take to 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 LOT/FIT pressure at the shoe as EMW. • Submit the test results to the Pioneer drilling engineer for distribution as required. Pioneer Natural Resources Last Revised:January 22,2010 ODSK-35i Permit To Drill Page 8 of 9 ODSK-35i Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control • Prior to drilling into the Kuparuk, hold a pre-reservoir meeting to outline heightened awareness for kick detection and lost circulation. 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. Hydrates and Shallow gas • No hydrates are expected in this area. Lost Circulation/Breathing/Formation Stability/Stuck Pipe Events • Breathing may be seen while drilling the Hue shale. Minimizing swab and surge on the formation is critical to reducing the impact of breathing in the wellbore. Breathing was seen in the ODSN-40 well, but only after substantial time in trying to solve the lost circulation problems in the fault seen in and below the Torok Sands. • Lost Circulation was seen in drilling the ODSN-36 across this same interval. Review the DOB2C pill procedure prior to penetrating the Kuparuk. Follow the Lost Circulation Decision Tree and combat losses accordingly • During the attempt to retrieve a fish from the ODSK-33 well, an un-centralized BHA got stuck from differential sticking across the Torok due to the increase in mud weight needed to hold back the shales below. Differential sticking indications were not noted with the drilling BHA and drill pipe. In any event, keep the pipe moving and avoid allowing the pipe to remain stationary any longer than necessary to minimize the chances of differential sticking. • There is a small section of formation above the Top of the HRZ that is volcanic in nature (TUFFS)and can either have"glassy"material, swelling clays or both while drilling,which produced a pack off on ODSK-33 and ODSN-45-close attention while drilling this interval is advised. Kick Tolerance/Integrity Testing Kick Tolerance/Integrity Testing Summary Table Casing set/ Maximum Mud Weight Exp Pore Min LOT/FIT Interval Influx Volume Press 9-5/8" Surface/ 79 10.5 3032 12.5 ppg (LOT), 8-1/2" (-12.5 via MPD) 14.0 ppg Max 7" Intermediate/ Infinite 8.6—8.8 3024 12.5 ppg (FIT) 6-1/8" (-10.2 via MPD) 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 H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Faults • Sub seismic faults with throws <25' may be encountered. Losses may be associated with these faults. CONSULT THE ODS DATA SHEET FOR ADDITIONAL INFORMATION (still in development) Pioneer Natural Resources Last Revised:January 22,2010 ODSK-35i Permit To Drill Page 9 of 9 ODSK-35i Injector - Proposed Completion Casing Item # Item MD(ft) TVD(ft) A 16" Conductor 158 158 B 9-5/8"40#L-80 Hydril 521, 8.835" ID 3,257 3,049 Well Head: 9-5/8",5K,VetcoGray C 7"26#L-80 Hydril 511 6.276" ID 10,031 5,990 Tree: 3-1/2",5K, Horizontal D 4-1/2" 12.6#L-80 Hydril 521 (Slotted Liner) 11,020 5,976 E 3-1/2" 9.3#L-80 TC-I I 9,868 5,964 *Estimated 7"TOC @ 9000'MD Upper Completion MDrkb (ft) TVDrkb(ft) 1 VetcoGray Tubing Hanger 34 34 HES Wellstar TRSSSV w/3'/" 9.2#TC-II Box x Pin 9 Chr w/ 2 2.813"X' Profile w/ 1/4" x .049 SS CL to Surface 750 750 GLM #1 HES Vanoil 3'/z"x 1'/2" Gas Lift Mandrel w/3'/2" 9.2#IC- 3 II Box x Pin w/ Dummy in place 2,100 2,088 GLM #2 HES Vanoil 3'/z"x 1%" Gas Lift Mandrel w/a/2'9.2#TO- 4 II Box x Pin w/ Dummy in place (min. 2 jts above top X nipple, 8,990 5,653 HES ROC Gauge&Carrier w/3'%"9.2#TC-II Box x Pin (min. 5 joint above X nipple) 9,030 5,669 HES 2.813"X' Nipple 9 Chr w/3'h" 9.2#TC-II Box x Pin 6 Its above packer; 9,070 5,685 Weatherford 41/2 13.5#x 7" 23-32#Model "Ultra Pak-TH" Hydraulic Set Permanent Production Packer w/4% 13.5#New 7 Vam Pin x Pin 9,150 5,717 HES 2.813"X' Nipple 9 Chr w/3'/2" 9.2#TC-H Box x Pin ;,min 1 8 above XN nipple) 9,230 5,749 HES 2.813"XN" Nipple w/2.750" No-Go 9Chr w/31/2"TCII Box x 9 Pin w/"RCH-M" Plug in Place(min 2 joints below packer) 9,310 5,781 10 WLEG w/3'/2' TCII Box 9,866 5,964 End of Assembly 9,868 5,964 ■ b p etion -) Item# Item MD(ft) TVD(ft) WFT PBR Tie Back Sleeve 10ft 9,868 5,964 WET"NTH" Liner Top Pkr(7" 23-32#X5" 15#) 9,878 5,966 WFT"PHR" Rotating Hyd Set Liner Hanger(7" 23-32#X 5" 15#) 9,881 5,967 4-1/2" 12.6#L-80 IBT-Mod Slotted Liner 9,884 5,967 Liner Shoe 11,008 5,976 End of Assembly 11,010 5,976 ■ Notes: Estimated Top of Cement @ -9000'MD/5732'TVD, -1000'above Kuparuk-into the 66 degree tangent angle so ae can set the packer in section< 67 degrees PIONEE \ D 1/10/2010 Date:1 Revision By: P Comments jdf opos d Completion 1/21/2010 TWC Revised Format and Depths ODSK-35i Injector NATURAL RESOURCES ALASKA Proposed Well Schematic Well Planning - Pioneer - Oooguruk i Oooguruk Development Oooguruk Drill Site ODSK-35i - Slot ODS-35 ODSN-35i KupH Plan: ODSK-35i KupH wp05 Standard Proposal Report 12 January, 2010 I I I I 0) HALLIBURTON Sperry Drilling Services o�� o v¢¢ . 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Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35i-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-35i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-35i KupH Design: ODSK-35i KupH wp05 Project Oooguruk Development 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 ODSK-35i-Slot ODS-35 Well Position +N/-S 0.0 ft Northing: 6,031,070.76 ft Latitude: 70°29'45.448 N +E/-W 0.0 ft Easting: 469,886.60 ft Longitude: 150°14'46.452 W Position Uncertainty 0.0 ft Wellhead Elevation: ft Ground Level: 13.5ft Wellbore ODSN-35i KupH Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) I GRF200510 10/31/2007 22.95 80.81 57,670 Design ODSK-35i KupH wp05 Audit Notes: Version: Phase: PLAN Tie On Depth: 3,267.0 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.7 0.0 0.0 321.06 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +El-W Rate Rate Rate Tool Face (ft) (?) (?) (ft) ft (ft) (ft) (?/100ft) (?/100ft) (?/100ft) (?) 3,267.0 41.28 248.82 3,056.9 3,000.7 -207.3 -726.8 0.00 0.00 0.00 0.00 3,277.0 41.28 248.82 3,064.4 3,008.2 -209.7 -733.0 0.00 0.00 0.00 0.00 4,502.8 66.50 330.81 3,863.9 3,807.7 181.0 -1,471.4 5.50 2.06 6.69 100.43 9,467.8 66.50 330.81 5,844.0 5,787.8 4,156.0 -3,691.8 0.00 0.00 0.00 0.00 10,018.0 83.00 330.83 5,988.2 5,932.0 4,617.7 -3,949.7 3.00 3.00 0.00 0.05 10,033.0 83.00 330.83 5,990.0 5,933.8 4,630.7 -3,957.0 0.00 0.00 0.00 0.00 10,233.0 90.00 330.83 6,002.2 5,946.0 4,804.9 -4,054.2 3.50 3.50 0.00 0.00 10,326.1 92.79 330.83 6,000.0 5,943.8 4,886.2 -4,099.6 3.00 3.00 0.00 -0.01 10,767.2 92.79 330.83 5,978.5 5,922.3 5,270.9 -4,314.4 0.00 0.00 0.00 0.00 10,860.3 90.00 330.83 5,976.2 5,920.0 5,352.2 -4,359.8 3.00 -3.00 0.00 179.91 11,020.0 90.00 330.83 5,976.2 5,920.0 5,491.6 -4,437.6 0.00 0.00 0.00 0.00 1/12/2010 5:33:08PM Page 2 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35i-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-35i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-35i KupH Design: ODSK-35i KupH wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 43.80 100.0 0.25 237.56 100.0 43.8 -0.1 -0.1 6,031,070.69 469,886.49 0.00 0.01 200.0 0.11 122.51 200.0 143.8 -0.3 -0.1 6,031,070.48 469,886.46 0.31 -0.13 300.0 0.19 33.05 300.0 243.8 -0.2 0.0 6,031,070.60 469,886.63 0.22 -0.15 400.0 0.25 5.77 400.0 343.8 0.2 0.2 6,031,070.97 469,886.78 0.12 0.04 500.0 0.27 31.71 500.0 443.8 0.7 0.2 6,031,071.41 469,886.81 0.12 0.38 600.0 0.43 30.02 600.0 543.8 1.1 0.6 6,031,071.86 469,887.22 0.16 0.47 700.0 0.25 21.56 700.0 643.8 1.7 0.9 6,031,072.49 469,887.50 0.19 0.79 800.0 0.80 250.63 800.0 743.8 1.7 0.5 6,031,072.44 469,887.09 0.98 1.01 900.0 1.51 250.83 900.0 843.8 1.0 -1.7 6,031,071.74 469,884.93 0.71 1.81 1,000.0 1.72 251.09 999.9 943.7 0.0 -4.3 6,031,070.81 469,882.35 0.21 2.70 1,100.0 1.68 247.39 1,099.9 1,043.7 -1.0 -7.2 6,031,069.80 469,879.40 0.12 3.76 1,200.0 1.81 243.30 1,199.8 1,143.6 -2.3 -9.8 6,031,068.55 469,876.80 0.18 4.40 1,300.0 1.86 259.15 1,299.8 1,243.6 -3.5 -12.9 6,031,067.34 469,873.73 0.51 5.38 1,400.0 3.52 290.53 1,399.7 1,343.5 -2.9 -16.9 6,031,067.91 469,869.66 2.16 8.37 1,500.0 4.90 296.18 1,499.4 1,443.2 0.3 -23.9 6,031,071.16 469,862.70 1.44 15.26 1,600.0 6.69 288.37 1,598.9 1,542.7 4.1 -33.0 6,031,075.04 469,853.64 1.95 23.95 1,700.0 8.96 276.52 1,698.0 1,641.8 7.0 -46.2 6,031,077.98 469,840.43 2.77 34.51 1,800.0 11.04 266.84 1,796.4 1,740.2 7.4 -63.6 6,031,078.45 469,823.06 2.67 45.74 1,900.0 13.00 261.47 1,894.2 1,838.0 5.2 -84.3 6,031,076.29 469,802.34 2.26 57.01 2,000.0 14.24 257.56 1,991.4 1,935.2 0.9 -107.5 6,031,072.05 469,779.11 1.55 68.23 2,100.0 15.82 256.19 2,088.0 2,031.8 -5.1 -132.7 6,031,066.21 469,753.87 1.62 79.46 2,200.0 18.19 256.75 2,183.6 2,127.4 -11.9 -161.1 6,031,059.48 469,725.45 2.38 91.99 2,300.0 21.97 255.22 2,277.5 2,221.3 -20.3 -194.4 6,031,051.28 469,692.15 3.81 106.41 2,400.0 26.24 254.71 2,368.8 2,312.6 -30.9 -233.8 6,031,040.86 469,652.71 4.28 122.94 2,500.0 31.34 253.87 2,456.4 2,400.2 -43.9 -280.2 6,031,027.97 469,606.24 5.12 141.95 2,600.0 34.99 252.86 2,540.0 2,483.8 -59.6 -332.8 6,031,012.50 469,553.64 3.69 162.77 2,700.0 36.85 251.34 2,620.8 2,564.6 -77.7 -388.7 6,030,994.68 469,497.61 2.06 183.91 I 2,800.0 37.74 249.48 2,700.5 2,644.3 -97.9 -445.6 6,030,974.63 469,440.64 1.44 203.89 2,900.0 39.57 248.72 2,778.5 2,722.3 -120.6 -504.0 6,030,952.19 469,382.12 1.89 222.98 3,000.0 40.19 249.48 2,855.3 2,799.1 -143.1 -564.0 6,030,929.99 469,322.07 0.79 243.21 3,100.0 40.99 248.06 2,931.1 2,874.9 -166.9 -624.7 6,030,906.39 469,261.29 1.22 262.80 3,200.0 41.19 248.57 3,006.5 2,950.3 -191.3 -685.6 6,030,882.21 469,200.26 0.40 282.10 3,257.0 41.28 248.82 3,049.4 2,993.2 -205.0 -720.7 6,030,868.75 469,165.17 0.33 293.55 9 5/8" 3,267.0 41.28 248.82 3,056.9 3,000.7 -207.3 -726.8 6,030,866.39 469,159.00 0.01 295.56 I 3,277.0 41.28 248.82 3,064.4 3,008.2 -209.7 -733.0 6,030,864.03 469,152.84 0.00 297.57 I Start Dir 5.5/100'3277.00'MD,3064.40'TVD 3,300.0 41.07 250.71 3,081.7 3,025.5 -215.0 -747.2 6,030,858.85 469,138.62 5.50 302.43 3,400.0 40.51 259.09 3,157.5 3,101.3 -232.0 -810.1 6,030,842.10 469,075.62 5.50 328.76 3,500.0 40.56 267.56 3,233.5 3,177.3 -239.5 -874.6 6,030,834.83 469,011.17 5.50 363.39 3,600.0 41.23 275.90 3,309.2 3,253.0 -237.5 -939.9 6,030,837.10 468,945.87 5.50 406.00 3,700.0 42.48 283.94 3,383.7 3,327.5 -226.0 -1,005.5 6,030,848.89 468,880.33 5.50 456.19 3,800.0 44.26 291.52 3,456.5 3,400.3 -205.0 -1,070.8 6,030,870.10 468,815.14 5.50 513.52 3,900.0 46.50 298.57 3,526.7 3,470.5 -174.9 -1,135.1 6,030,900.53 468,750.90 5.50 577.44 4,000.0 49.15 305.08 3,593.9 3,537.7 -135.7 -1,198.0 6,030,939.89 468,688.21 5.50 647.37 1/12/2010 5:33:08PM Page 3 COMPASS 2003.16 Build 428 Halliburton Company HALL HALLIBURTOle Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35i-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-35i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-35i KupH Design: ODSK-35i KupH wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 3,601.15 4,100.0 52.14 311.06 3,657.4 3,601.2 -88.0 -1,258.7 6,030,987.84 468,627.65 5.50 722.66 4,200.0 55.40 316.55 3,716.5 3,660.3 -32.2 -1,316.8 6,031,043.92 468,569.76 5.50 802.63 4,300.0 58.89 321.61 3,770.7 3,714.5 31.3 -1,371.8 6,031,107.62 468,515.10 5.50 886.53 4,400.0 62.57 326.31 3,819.6 3,763.4 101.8 -1,423.0 6,031,178.35 468,464.14 5.50 973.60 4,500.0 66.39 330.69 3,862.7 3,806.5 178.8 -1,470.1 6,031,255.46 468,417.38 5.50 1,063.02 4,502.8 66.50 330.81 3,863.9 3,807.7 181.0 -1,471.4 6,031,257.70 468,416.14 5.50 1,065.55 End Dir 4502.80'MD,3863.90'TVD 4,600.0 66.50 330.81 3,902.6 3,846.4 258.8 -1,514.8 6,031,335.69 468,372.98 0.00 1,153.40 4,700.0 66.50 330.81 3,942.5 3,886.3 338.9 -1,559.6 6,031,415.92 468,328.59 0.00 1,243.78 4,800.0 66.50 330.81 3,982.4 3,926.2 418.9 -1,604.3 6,031,496.15 468,284.20 0.00 1,334.16 4,900.0 66.50 330.81 4,022.3 3,966.1 499.0 -1,649.0 6,031,576.38 468,239.80 0.00 1,424.54 5,000.0 66.50 330.81 4,062.2 4,006.0 579.1 -1,693.7 6,031,656.61 468,195.41 0.00 1,514.91 5,100.0 66.50 330.81 4,102.0 4,045.8 659.1 -1,738.4 6,031,736.84 468,151.02 0.00 1,605.29 5,200.0 66.50 330.81 4,141.9 4,085.7 739.2 -1,783.2 6,031,817.08 468,106.63 0.00 1,695.67 5,300.0 66.50 330.81 4,181.8 4,125.6 819.2 -1,827.9 6,031,897.31 468,062.23 0.00 1,786.05 5,400.0 66.50 330.81 4,221.7 4,165.5 899.3 -1,872.6 6,031,977.54 468,017.84 0.00 1,876.43 5,500.0 66.50 330.81 4,261.6 4,205.4 979.3 -1,917.3 6,032,057.77 467,973.45 0.00 1,966.80 I 5,600.0 66.50 330.81 4,301.4 4,245.2 1,059.4 -1,962.1 6,032,138.00 467,929.05 0.00 2,057.18 5,652.1 66.50 330.81 4,322.2 4,266.0 1,101.1 -1,985.3 6,032,179.77 467,905.94 0.00 2,104.23 Brook 2b 5,700.0 66.50 330.81 4,341.3 4,285.1 1,139.5 -2,006.8 6,032,218.23 467,884.66 0.00 2,147.56 5,800.0 66.50 330.81 4,381.2 4,325.0 1,219.5 -2,051.5 6,032,298.46 467,840.27 0.00 2,237.94 5,900.0 66.50 330.81 4,421.1 4,364.9 1,299.6 -2,096.2 6,032,378.69 467,795.87 0.00 2,328.32 6,000.0 66.50 330.81 4,461.0 4,404.8 1,379.6 -2,140.9 6,032,458.92 467,751.48 0.00 2,418.70 6,100.0 66.50 330.81 4,500.8 4,444.6 1,459.7 -2,185.7 6,032,539.16 467,707.09 0.00 2,509.07 6,200.0 66.50 330.81 4,540.7 4,484.5 1,539.8 -2,230.4 6,032,619.39 467,662.69 0.00 2,599.45 I 6,300.0 66.50 330.81 4,580.6 4,524.4 1,619.8 -2,275.1 6,032,699.62 467,618.30 0.00 2,689.83 I 6,400.0 66.50 330.81 4,620.5 4,564.3 1,699.9 -2,319.8 6,032,779.85 467,573.91 0.00 2,780.21 6,500.0 66.50 330.81 4,660.4 4,604.2 1,779.9 -2,364.6 6,032,860.08 467,529.51 0.00 2,870.59 6,600.0 66.50 330.81 4,700.3 4,644.1 1,860.0 -2,409.3 6,032,940.31 467,485.12 0.00 2,960.97 6,700.0 66.50 330.81 4,740.1 4,683.9 1,940.1 -2,454.0 6,033,020.54 467,440.73 0.00 3,051.34 6,800.0 66.50 330.81 4,780.0 4,723.8 2,020.1 -2,498.7 6,033,100.77 467,396.33 0.00 3,141.72 6,900.0 66.50 330.81 4,819.9 4,763.7 2,100.2 -2,543.4 6,033,181.00 467,351.94 0.00 3,232.10 7,000.0 66.50 330.81 4,859.8 4,803.6 2,180.2 -2,588.2 6,033,261.24 467,307.55 0.00 3,322.48 7,100.0 66.50 330.81 4,899.7 4,843.5 2,260.3 -2,632.9 6,033,341.47 467,263.15 0.00 3,412.86 7,200.0 66.50 330.81 4,939.5 4,883.3 2,340.3 -2,677.6 6,033,421.70 467,218.76 0.00 3,503.23 7,300.0 66.50 330.81 4,979.4 4,923.2 2,420.4 -2,722.3 6,033,501.93 467,174.37 0.00 3,593.61 7,400.0 66.50 330.81 5,019.3 4,963.1 2,500.5 -2,767.1 6,033,582.16 467,129.97 0.00 3,683.99 7,500.0 66.50 330.81 5,059.2 5,003.0 2,580.6 -2,811.8 6,033,662.43 467,085.56 0.00 3,774.41 Top Torok Ss 7,600.0 66.50 330.81 5,099.1 5,042.9 2,660.6 -2,856.5 6,033,742.62 467,041.19 0.00 3,864.75 1 7,700.0 66.50 330.81 5,138.9 5,082.7 2,740.6 -2,901.2 6,033,822.85 466,996.79 0.00 3,955.13 7,800.0 66.50 330.81 5,178.8 5,122.6 2,820.7 -2,945.9 6,033,903.08 466,952.40 0.00 4,045.50 7,900.0 66.50 330.81 5,218.7 5,162.5 2,900.8 -2,990.7 6,033,983.31 466,908.01 0.00 4,135.88 8,000.0 66.50 330.81 5,258.6 5,202.4 2,980.8 -3,035.4 6,034,063.55 466,863.61 0.00 4,226.26 1/12/2010 5:33:08PM Page 4 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35i-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-35i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-35i KupH Design: ODSK-35i KupH wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 5,242.27 8,100.0 66.50 330.81 5,298.5 5,242.3 3,060.9 -3,080.1 6,034,143.78 466,819.22 0.00 4,316.64 8,114.4 66.50 330.81 5,304.2 5,248.0 3,072.4 -3,086.5 6,034,155.31 466,812.84 0.00 4,329.63 Base Torok Ss 8,200.0 66.50 330.81 5,338.3 5,282.1 3,140.9 -3,124.8 6,034,224.01 466,774.83 0.00 4,407.02 8,300.0 66.50 330.81 5,378.2 5,322.0 3,221.0 -3,169.6 6,034,304.24 466,730.43 0.00 4,497.39 8,400.0 66.50 330.81 5,418.1 5,361.9 3,301.1 -3,214.3 6,034,384.47 466,686.04 0.00 4,587.77 8,500.0 66.50 330.81 5,458.0 5,401.8 3,381.1 -3,259.0 6,034,464.70 466,641.65 0.00 4,678.15 8,600.0 66.50 330.81 5,497.9 5,441.7 3,461.2 -3,303.7 6,034,544.93 466,597.25 0.00 4,768.53 8,700.0 66.50 330.81 5,537.8 5,481.6 3,541.2 -3,348.4 6,034,625.16 466,552.86 0.00 4,858.91 8,800.0 66.50 330.81 5,577.6 5,521.4 3,621.3 -3,393.2 6,034,705.39 466,508.47 0.00 4,949.29 8,900.0 66.50 330.81 5,617.5 5,561.3 3,701.3 -3,437.9 6,034,785.63 466,464.07 0.00 5,039.66 9,000.0 66.50 330.81 5,657.4 5,601.2 3,781.4 -3,482.6 6,034,865.86 466,419.68 0.00 5,130.04 9,100.0 66.50 330.81 5,697.3 5,641.1 3,861.5 -3,527.3 6,034,946.09 466,375.29 0.00 5,220.42 9,200.0 66.50 330.81 5,737.2 5,681.0 3,941.5 -3,572.1 6,035,026.32 466,330.89 0.00 5,310.80 9,227.7 66.50 330.81 5,748.2 5,692.0 3,963.7 -3,584.4 6,035,048.53 466,318.61 0.00 5,335.82 Top Hrz 9,300.0 66.50 330.81 5,777.0 5,720.8 4,021.6 -3,616.8 6,035,106.55 466,286.50 0.00 5,401.18 9,400.0 66.50 330.81 5,816.9 5,760.7 4,101.6 -3,661.5 6,035,186.78 466,242.11 0.00 5,491.55 9,467.8 66.50 330.81 5,844.0 5,787.8 4,155.9 -3,691.8 6,035,241.18 466,212.01 0.00 5,552.83 Start Dir 3.0/100'9467.80'MD,5844.00'TVD 9,500.0 67.46 330.81 5,856.6 5,800.4 4,181.8 -3,706.3 6,035,267.11 466,197.66 3.00 5,582.04 9,506.9 67.67 330.81 5,859.2 5,803.0 4,187.4 -3,709.4 6,035,272.71 466,194.56 3.00 5,588.35 Base Hrz 9,600.0 70.46 330.82 5,892.5 5,836.3 4,263.3 -3,751.8 6,035,348.76 466,152.49 3.00 5,674.01 9,700.0 73.46 330.82 5,923.4 5,867.2 4,346.3 -3,798.1 6,035,431.94 466,106.47 3.00 5,767.71 9,790.9 76.19 330.82 5,947.2 5,891.0 4,422.8 -3,840.9 6,035,508.66 466,064.03 3.00 5,854.13 Kalubik Mkr 9,800.0 76.46 330.82 5,949.4 5,893.2 4,430.6 -3,845.2 6,035,516.43 466,059.74 3.00 5,862.88 9,900.0 79.46 330.82 5,970.2 5,914.0 4,516.0 -3,892.9 6,035,601.99 466,012.41 3.00 5,959.25 10,000.0 82.46 330.83 5,985.9 5,929.7 4,602.2 -3,941.0 6,035,688.40 465,964.63 3.00 6,056.57 10,018.0 83.00 330.83 5,988.2 5,932.0 4,617.7 -3,949.7 6,035,704.00 465,956.00 3.00 6,074.14 End Dir 10018.00'MD,5988.20'TVD-KupH v5 T1 10,031.1 83.00 330.83 5,989.8 5,933.6 4,629.1 -3,956.1 6,035,715.40 465,949.70 0.01 6,086.98 7" 10,033.0 83.00 330.83 5,990.0 5,933.8 4,630.8 -3,957.0 6,035,717.05 465,948.78 0.00 6,088.84 Start Dir 3.5/100'10033.00'MD,5990.00'TVD 10,034.4 83.05 330.83 5,990.2 5,934.0 4,632.0 -3,957.7 6,035,718.26 465,948.12 3.56 6,090.20 Kup C 10,100.0 85.35 330.83 5,996.8 5,940.6 4,689.0 -3,989.5 6,035,775.37 465,916.53 3.50 6,154.52 10,200.0 88.85 330.83 6,001.9 5,945.7 4,776.1 -4,038.2 6,035,862.74 465,868.22 3.50 6,252.93 10,233.0 90.00 330.83 6,002.2 5,946.0 4,805.0 -4,054.3 6,035,891.62 465,852.25 3.50 6,285.45 Start Dir 3.0/100'10233.00'MD,6002.20'TVD 10,300.0 92.01 330.83 6,001.1 5,944.9 4,863.4 -4,086.9 6,035,950.23 465,819.84 3.00 6,351.46 10,326.1 92.79 330.83 6,000.0 5,943.8 4,886.2 -4,099.6 6,035,973.05 465,807.22 3.00 6,377.16 End Dir 10326.10'MD,6000.00'TVD 1/12/2010 5:33:08PM Page 5 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35i-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-35i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-35i KupH Design: ODSK-35i KupH wp05 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 5,940.16 10,400.0 92.79 330.83 5,996.4 5,940.2 4,950.7 -4,135.6 6,036,037.64 465,771.50 0.00 6,449.90 10,500.0 92.79 330.83 5,991.5 5,935.3 5,037.9 -4,184.3 6,036,125.04 465,723.17 0.00 6,548.34 10,600.0 92.79 330.83 5,986.6 5,930.4 5,125.1 -4,233.0 6,036,212.43 465,674.84 0.00 6,646.77 10,700.0 92.79 330.83 5,981.7 5,925.5 5,212.3 -4,281.7 6,036,299.83 465,626.51 0.00 6,745.21 10,767.2 92.79 330.83 5,978.5 5,922.3 5,270.9 -4,314.4 6,036,358.56 465,594.03 0.00 6,811.35 Start Dir 3.0/100'10767.20'MD,5978.50'TVD 10,800.0 91.81 330.83 5,977.2 5,921.0 5,299.5 -4,330.4 6,036,387.24 465,578.17 3.00 6,843.65 10,860.3 90.00 330.83 5,976.2 5,920.0 5,352.2 -4,359.8 6,036,440.00 465,549.00 3.00 6,903.07 End Dir 10860.30'MD,5976.20'TVD-KupH v5 T2 10,900.0 90.00 330.83 5,976.2 5,920.0 5,386.8 -4,379.1 6,036,474.74 465,529.79 0.00 6,942.19 11,000.0 90.00 330.83 5,976.2 5,920.0 5,474.1 -4,427.8 6,036,562.24 465,481.41 0.00 7,040.74 , 11,020.0 90.00 330.83 5,976.2 . 5,920.0 5,491.6 -4,437.6 6,036,579.71 465,471.76 0.00 7,060.41 Total Depth at 11020.00'MD,5976.20'TVD-4 1/2"-KupH v5 T3 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (?) (?) (ft) (ft) (ft) (ft) (ft) °1 v5 I', 0.00 5,988.2 4,617.7 -3,949.7 6,035,704.00 465,956.00 -plan hits target -Point KupH v5 T3 0.00 0.00 5,976.2 5,491.6 -4,437.6 6,036,579.74 465,471.74 -plan hits target -Point KupH v5 T2 0.00 0.00 5,976.2 5,352.2 -4,359.8 6,036,440.00 465,549.00 -plan hits target -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 3,257.0 3,049.4 9 5/8" 9.625 12.250 10,031.1 5,989.8 7" 7.000 8.500 11,020.0 5,976.2 4 1/2" 4.500 6.125 1/12/2010 5:33:08PM Page 6 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: .Pioneer Alaska Local Co-ordinate Reference: Well ODSK-35i-Slot ODS-35 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSK-35i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-35i KupH Design: ODSK-35i KupH wp05 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (?) (?) 8,114.4 5,304.2 Base Torok Ss 0.00 9,790.9 5,947.2 Kalubik Mkr 0.00 5,652.1 4,322.2 Brook 2b 0.00 9,506.9 5,859.2 Base Hrz 0.00 10,034.4 5,990.2 Kup C 0.00 9,227.7 5,748.2 Top Hrz 0.00 7,500.0 5,059.2 Top Torok Ss 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 3,277.0 3,064.4 -209.7 -733.0 Start Dir 5.5/100'3277.00'MD,3064.40'TVD 4,502.8 3,863.9 181.0 -1,471.4 End Dir 4502.80'MD,3863.90'TVD 9,467.8 5,844.0 4,155.9 -3,691.8 Start Dir 3.0/100'9467.80'MD,5844.00'TVD 10,018.0 5,988.2 4,617.8 -3,949.7 End Dir 10018.00'MD,5988.20'TVD 10,033.0 5,990.0 4,630.8 -3,957.0 Start Dir 3.5/100'10033.00'MD,5990.00'TVD 10,233.0 6,002.2 4,805.0 -4,054.3 Start Dir 3.0/100'10233.00'MD,6002.20'TVD 10,326.1 6,000.0 4,886.2 -4,099.6 End Dir 10326.10'MD,6000.00'TVD 10,767.2 5,978.5 5,270.9 -4,314.4 Start Dir 3.0/100'10767.20'MD,5978.50'TVD 10,860.3 5,976.2 5,352.2 -4,359.8 End Dir 10860.30'MD,5976.20'TVD 11,020.0 5,976.2 5,491.6 -4,437.6 Total Depth at 11020.00'MD,5976.20'TVD 1/12/2010 5:33:08PM Page 7 COMPASS 2003.16 Build 428 C! f9 cD B0 2 n C s —I co 0 °10000 7 7 N. a 7 7 C = C < W O CD v v v /� -o - P. v) a 3 I ° m M \V , O z ,to co \V m m o o c rn v a —■ . 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L. 7 ° o' O • 7 p t C p C 0. �B • 0 -0,~ 0 • a O o C O 0 ° a .A�F • U 5 • �� ! `�: • OA t 0 !Y Z ! • 01, W 0 • o Q 0 d 4,! 0 Z Ei A o FY CD 0 N ! Y O O w r! e • j J 0 d! • ° OA <0 0 0 9 0 <g . ! c 0 kg o • t g ° 0 02, 0 I !r ° M c 0 o : ...:::� �RY`' om'o V 0 6i N /C �' a W O8 OZ ^` c W m 0 3 —p yam � z 0< • 3' , \' 1 CC CC 1 1 i •• istrict 5cundry i i i SE Corner of t ,`oOOGURUX 9?E Protracted Section 11 $ Coordinates o1 i k N 6028111.04 I \ I E 470989.01 ( H•p o °1- . \• I Harrison. Bay Tract "A" I 1 PI-24` e - . . Prawin• I. —�, �' - , \ \\` �v. I �'. i Ado v I i m „ „� ,�j•S 1 " I X11 - ' V s' • 1•A '' �� Offshore Icerood L99 iJtles 1 .� ear shore icerood23.82 1.LI r ' p•'13 D PI 20 to Doogvrvk Site ‘■ PI 7 to PI .r • n a us �, 2 9 OC�� ■„ % PI-Z.' 1 i 1.Nis14 _ Pt 15 I ; Phl� Tundra leered DS 3N B:0.P s a 6 s •: ■ x + - Roads i.o:Cob 1 T13N 1 _ //�l 2'?'�,” ,Pt ..._- '� Basis of Location 1 111 rkij51-E13 C _.!G `.G� �'� - � DS-3H West Monument /we' ::j )L3ten♦ � Coordinates %q 3 N 6001016.61 .STAKED PI INFORMATION ONLY 1\> ! :' 4,‘, E 498081.23 (� c .+ AR 9 • � 7� - ;�' Ref. Lownsbury & Assoc. Lllai 1 Url :;:( Drawing No. crce -•---- NSK 6.01—d672 • .. - T i •• t • •7 S •21;L`‘ --'•;*i•4 1 , , S w :144; it al4 • •.• wisp-, ....,---.1,43i...1 � i4 a = y- y � s iVF • • -. 4 P,FS No 411 QS ri t,•,� : : a-„ + d .a� c i_ ` . pilOFESS ION At-L dIP Pioneer Natural Resouces JOB NAME: Ooogui-uk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 East DATE: 7-12-07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location 05204 2 of 4 STb weII No, ._ a -x Latitvde (N) Ldngitude A Pad Elev, FSL FEL 6,031,151.32 469,920,45 70 29 46.24160 150 14 45.40408 3035 1077 13,50 2 .--6,031,145 409,915,52 70 29 46,19252 150 14 45,00922 30$0 1082 13,50 6, 31i-41-,379 4699ilo:5-9---70-29-46,1-4354 -4-15-0 14 45,75.-37-5-4 3025 - 1087 TSö 4 .. 469,905,67 70 2946.09465 150 14 45,89799 3020 1092 13.50- S 6031;131,46 409,9116.7-4---70-29 40.04538 156-14 407,04252- 3015 1097 13,50 6 0,031,126,51469,895.60--70 29 45,99660 150 14 45,18735 3010 1102 13,50 7 5,031,113,73- 469,663-13-1 70 29 45.87039 ---16o 14 46-,-55.07q- 2997 1115 ‘,----'13,50 469,576.21 70-29 46.87271-0-2--160 14 46,70303---29-92 11.-270 9 6,0317071-5-4-489;873,26 70 20 45.77184 150 14 46.84814 2987 1125 13,50 --- 10 6,031,0913,79 469,1368,36 70 29 45,72286 150 14 46,99179 2902 1130--- 13,50 iF 6,031,098.64 4• 69,863.3 70 29 46,67398 160 14 47,13750 2977 113135O - 0,031,088,87- - 4• 69,858.47- 70 29 45,62490 156-14 47.25174 2972 1140 13.50 13 6,031,070,06 409,845,8*1---70 29 45,49840 150 14 47,05288 2950 1162 13,50 14 6,031,071,09— 469,540.137 70 29 45,44932 150 14 47,79770 2955 1157 6,031,060.15 -469,1335.96 7029 45.40063--- 1 5-014 47,94165-4-2900- 1102 1 ----16-- 6,031,061.18 4• 69,831,04 70 29 45.35145 150 14-48:08588 2945 1167 13,50 ---17 6,031,056.25 469,62611 70 29400277 150T446:23042 2940 1172 13,50 16 6,031,05-127 469,821,16 702045,25359 150 14 4C-37495----2935 1177 13;50-- -----19 6,031,038.52 409,806,50 702945.12768 150 T4.4V4666 2922 1189 20 6,031,033.50 469,803.59 70 29 45.07011 150 14 48,89061 2917 1194 -- 13.50 21 6,031,028,53 469,790,62 70 29 45.02903-- 1501-4 4903632 2912 1199 13,50- —22 6,031,023,58 469,793,67 70 29 44.96014 150 14 49,18144 2907 1204 13.50 25 6,031,018157 ---409,788,76 70 29 44,93067 150 14 49.32537 2902 1209 13.50 24 -0,0.3f,013,00 469,783,84 7Q2$4.,68159 1501449,46960 2897 1214 - 13,50 "4:lb OF 44 Mie h • 1.4 P•• so* • T "‘ \* • • , . . ccert/.. GT. Philip G.Davis :et° s% No 4110.$ 11'• % • . _ 4144,014.•••••••••••• " ' 7 14-,,R0FEssicrim.0" de NVit$: • 1, El@ vcttiQnS ore bored on BP Mean Sea Level, 2, Coordinotes ore bosed on Alosko State Plane No 27, Zone 4, 3. Ali eQnvctors ore within Protrocted Section 11, Pioneer Natural Reoauces - - - --------------- JOE NAME: 0Q0guruk Drill site Conductors DRAWN BY: BL CHECKED BY: MX LOCATION; Protrocted Section 11 SC_ALE; N/A Township 13 North Range 7 East DATE: 7-12-07 Umiot meridian . NANUC) JOB NO. SHEET DESCRIPTION: . - - Coordlnate5 05204 3 of 4 - - - Alaska,State i e Section Line Offset Well No. Y X Latitude (N) Longitude �_- FSL r FEL Pad Elev. 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 45.06895 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 , 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 45.87163 2975 1092 13.50 32 6,031,085.68 469,901.39 70 29 45.59523 150 14 46.01793 2970 1097 13.50 33 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 • -�-h', 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 37 6,031,053.00 469,869.00 70 29 45.27251 150 14 46.96749 2937 1129 13.50 38 6,031,047.99 469,864.14 70 29 45.22304 150 14 47.10995 2932 1134 13.50 39 6,031,043.03 469,859.20 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 6,031,033.05 469,849.29 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 45 6,031,005.53 469,821.86 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 OF A�tai SURVEYOR'S CERTIFICATE 0."4'', '•••'�•¢ii I HEREBY CERTIFY THAT I AM to•• 41.- • .V i PROPERLY REGISTERED AND • j*f 4`:T ''!. \* 'I LICENSED TO PRACTICE LAND j'•' ii • "'° SURVEYING IN THE STATE OF 4,-.",t,.L,1 : �. /. . ALASKA AND THAT THIS PLAT 1 itt e� ,1; )J;, f G.Davis REPRESENTS A SURVEY DONE BY °3 1 rJ ' • did G:Dai �o I ,� , �*: :a�� ME OR UNDER MY SUPERVISION i' ;;If'::;-1;:-771:?'",-e1:0.2 J'J,•►• No.4110•S � �- c �i� r F2- .1+CFO •.......••��o�,�� AND THAT I BELIEVE THAT ALL rt ti � I Z :, -? 40ESSIDNAI.� + DIMENSIONS AND OTHER DETAILS `$ x -:ib : , .f 11eo.,,.��.y°` ARE CORRECT AS SUBMITTED TO -` `_'> " `Z_5.; i :'• ME BY NANUQ, INC. AS OF JULY "- 3'__ 12TH, 2007. Pioneer Natural Resouces JOB NAME: Oooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MJD. LOCATION: Protracted Section 11 SCALE: N/A Township 13 North Range 7 Eost DATE: 7-12-07 Umiot Meridian NANUQ JOB NO. SHEET DESCRIPTION: As-built Coordinates 05204 4 of 4 O O O O oo M 1 XI 0 co NI OO Co o ti IN. I V' li _ re T LL °w 0 Q O CO -F v O l O (..A O co O N V T 470 L1J E 10 v I O O w - O co CD Lt3 I o co M Q • a a. 0 w o co O co O co co o co co O co co co co co co o co o 0 o 0 co co rn a) o0 Page 1 of 1 Schwartz, Guy L (DOA) From: Vaughan, Alex[AIex.Vaughan @pxd.com] Sent: Tuesday, January 26, 2010 4:03 PM To: Schwartz, Guy L(DOA) Cc: Johnson, Vern Subject: RE: ODSK-35A PTD 210-012 Attachments: Redo of Spider Plot ODSK-35i KupH wp05 Letter Size.pdf Guy, Please see attached spider plot of ODSK-35i. Please note that the intermediate casing shoe for the surrounding wells are in excess of% mile from the ODSK-35i Kuparuk penetration along a horizontal plane. Alex Vaughan Operations Drilling Engineer PIONEER NATURAL RESOURCES 907.226.2180 (Cosmo Rig) 907.343.2186 (office) 907.748.5478 (mobile) 907.343.2190 (fax) From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Tuesday, January 26, 2010 2:52 PM To: Vaughan, Alex Subject: ODSK-35A PTD 210-012 Alex, Can you give me a call to discuss the PTD for ODSK-35Ai . I have a couple of questions on the procedure. 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. 1/26/2010 TRANSMITTAL LETTER CHECKLIST WELL NAME Oooguruk ODSK-35A PTD# 2100120 Development X Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 000GURUK POOL: 000GURUK-KUPARUK OIL 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 , Permit No. (If last two digits in API No. . Production should continue to API number are be reported as a function of the original API number stated above. between 60-69) 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 (Comuanv 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 1 7 o O a)(.5 E 0 O 2 0 W 0m N o 1] a - -5 = a p o N o o C CO a >>°� c o •o 0 O v m o Q CO 0 C L a 7 L O O o Q M @ Y C( 0 N Z 0 uo a) E o c 1E w co N -O o " o ii O - 7 i m E o _ L- E? 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E a) O 0 0 = N c It u) O o o " , u_ L t/ _ o .O� �_ a* ° c = 7. Sift o v E 3 0 0 3 co O a) co N U T i° O Z L O a) E o 2 -J a. O N u) Q 0) O E N O O Z -o m ° u �i co n °� ° ci m n• Y < 7 0 >.— - = ,...= 7 N m = c V N N (6 D Q Q c n o rnu _ °. T ° E o CL u) !E !: I ? (° c > N a)g � o a -o u)• 7 O CO a O 7 N u) N Y ._ L co U 0) m 7 3 0 (n c L c m `n c Q u) u) a) m o) O 0 V 0 = -O o 0 'C_ 7 m a) 0. O O E N m o O co a) a L = a) = 0 .. a' a - a) N LO m '-> U > -O a a) N N = o o to o 0 D E E. - -co c c E (° 2 o co c c n F ..-� c O 0 cr c a) ,"-E o) �- N L n c c O O o 0 o J o @ ° c (n 3 o m = a .0 n 2 0 a °- Zi 3 2 a) u) u T ° Q o CU _ yi > a) '0 0 W _0 0 a) 0 c > o ° o CO 0 Y m —_° o o m <° 0 m m m Q m n o o) o ci) c .N 0 0 0 a) D o o a) c 2 — O _ E 'a 3 Q o a) L m 3 v a) O -I m 0 -0 CO C 00 CO m m .- w ° m m -0o E m m L E c = uu) M@ y r c 0 co o 0- 3 0 _ —° >, 3 c E o Q •a -o c Ti .8 2 -o c-° 3 3 a) .. o ° '� '-) o t 2 ° aa, o u) n .Q 2, m o 3 o r Z o w U a° D .0 o m .o 12 12 (0> 0 m a°) ) o m E o c o m o 0 c 0 ° o y -o E a) m E r °) o a°) ° 0 7 c H a) n N -0 a) 0) N ()La- 7 7 a c U OU °- O 0 0 Y -O a) ,- 0 -O m E O) 0 - :_) 7 CO m o Q L m Q7 a) q (/) N n L �- a) V) a CO CO (6 m m m O 2 O) •c U > N • co O N C L CZ N Z YO Zr, C C n n 2 N T m 0 a) a) 3 c -O 0) c CO Q Q a) c C m - 7 o L N O J O a) 0 >. y0 a)IDC u) I.L w (9 - N -0 -0 L -O L a) N 0 a) > - = is 0- O- U o 0 -p E W 4) a) m m m m a) 0C a) m E c0 >i 7 a) ° U m m 0 0 a) L a) - "00 (V') m 0 0 U y N 0. m F- z C) 2 3 0 0 0 _ o o 0 0 u) -0 > = a`) — a E . 0 a) o c CO 0 - a) 0 0 0 .m m a`� o o c • 0 0 0 o m o m o u; 3 N = ° a E m - .) a) m o ° ° E E c a) 3 a) c �t F- t- 5 'w a6) 2 aa) > c a a o Y`o o c0 E a' ._ m = m >• a _I 0 (7n . O O a a v Q a Z 0 U) 0 0 0 0 ¢ .`� Q ± 0 m m 0 n 2 a 0 0) 0) 0 ° K = W n p N M V U) CD I- 00 °) O N M V U) (0 N- M 0) O N M V U) (0 I- W 0) M N co V In (0 I- co 0) N N N N N N N N N N M M M M M M M M M cc O o_ o_ _o c N N N U W ° l° CV 0 N N -0 0 fai. O ur ',T a) E J c`) a) en O E o f a0 a) G _) o au 0 1 I- Q Q U w Q O Q I 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. HALLIBUR Sperry Drilling I i END OF WELL REPORT ' ODSK-35Ai Oooguruk Development 1 1 i 1 _n r 4. r r { • i i Surface Data Logging Services 1 I Grb-0( a 19 (06? I ' HALLIBURTON I Sperry Drilling ' TABLE OF CONTENTS 1. General Information ' 2. Daily Summary 3. Morning Reports 4. Bit Record ' 5. Mud Record ' 6. Formation Tops 7. Survey Report 8. Days vs. Depth Digital Data to include: ' Formation Evaluation Logs Halliburton Log Viewer EMF Log Viewer End of Well Report in PDF format ADI Backup 1 1 1 1 1 PIONEER . NATURAL RESOURCES I IHALLIBURTON I Sperry Drilling GENERAL WELL INFORMATION ICompany: Pioneer Natural Resources AK Rig: Nabors 19AC IWell: ODSK-35Ai Field: Oooguruk I Borough: State: North Slope Borough Alaska Country: United States I API Number: 50-703-20560-01-00 Sperry Job Number: AK-AM-0005555468 Job Start Date: 21 Mar 2010 —27 Mar 2010 ISpud Date: 10-Mar-2010 Total Depth: Production Section to 11,658.05' MD, 6,126.76' TVD INorth Reference: True Declination: 21.782° I Dip Angle: 80.903° Total Field Strength: 57654 nT Date of Magnetic Data: 11 Mar 2010 I Wellhead Coordinates N: North 70° 29' 45.45" Wellhead Coordinates W: West 150° 14' 46.45" Drill Floor Elevation 56.20' 1 Ground Elevation: 13.5 Permanent Datum: Mean Sea Level I SDL Engineers: Dan Sherwood, Mark Lindloff SDL Sample Catchers: Herman Lilgreen, Leonard Grove Company Geologist: Paul Cozma, Mindaugas Kuzminskas I Company Representatives: Joe Polya Rod Klepzig, Joey Cortez, Jim Brown SSDS Unit Number: 123 I I I I I PIONEER 1 NATURAL RESOURCES HALLIBURTON I Sperry Drilling DAILY SUMMARY ' Begin ODSK-35Ai 03/21/2010 ' Mudloggers arrive on location, rigged up gas equipment and flow out sensor that had been disconnected due to rig move. Calibrated gas equipment and surface sensors turned on computers and ensured machines were in good working order. Rig operations included running 7" casing that was set at 9,503'MD. Rigged down casing running equipment and rigged up ' Halliburton cement equipment pumped cement and displaced with 10.2 ppg brine with no recorded returns. Rigged down cement equipment and begin laying down 5" drill pipe. ' 03/22/2009 Lay down 5" drill pipe from derrick, change out IBOP, saver sub, and stabbing guide on top drive to 4". Change pipe rams RIH with 4" drill pipe and circulate cleaning same. POOH racking ' back clean drill pipe. RIH pick up 4" HWDP, jars, bumper sub, and 4" drill pipe. 03/23/2010 Continue to pick up 4" drill pipe tripping in the hole circulating every 25 stnds to ensure of no obstructions in the pipe. Slip and cut drill line and test BOP's. Pick up new BHA and shallow pulse test MWD tools. RIH to 8,777' proposed top of cement and begin logging down to 9,264' with BAT sonic tool to ensure good cementation. Tag cement stringers at 9,264' and begin ' washing and reaming to 9,410'. Pump hi vis spacer and displace 10.0 ppg brine with 8.6 ppg mud. Test casing and drill cement and float equipment to 9,468'. Remove trip nipple and install RCD bearing. Continue to drill out float equipment to 9,503' and clean out rathole to 9,510'. Circulate bottoms up for FIT and FM test. 03/24/2010 ' Pressure test casing and drill out shoe track from 9410' to 9468'. Remove trip nipple and install RCD bearing. Clean out remaining shoe track to 9503' and clean out rathole to 9520'. Circulate 8.6 ppg all around and perform FIT test to 12.5 ppg at 6100' TVD. Perform Formation Pore Pressure test to 8.7 ppg. Drilled from 9,250' to 10,032' MD. Sperry recorded 40 bbl loss over ' this interval. Losses were observed beginning at 9742' and continued throughout with an average loss rate of 5 bbls and hour. From 9500' to 9550' samples revealed primarily siltstone grading to claystone with a high amount of loose silt. 9550' to 9650' sandstone was drilled with ' max gas 2948 units, good fluorescence and cut were observed as well. 9650' - 10,032' interval revealed a sandstone with a high amount of silt contained. Low background gas accompanied this interval with no notable gas peaks. ' 03/25/2010 Drill from 10,032' to 11,100'. Continue to drill ahead to 11,000' MAD passing all slide intervals for the ALD tool. Samples revealed sandstone formation throughout the section drilled with good ' fluorescence, good visible staining and moderate to good visible staining. Background gasses remained under 1000 units until 10,212' in which a distinct rise in background gasses occurred. Losses from 10,032' to 10,226' totaled 21 bbls with an average loss rate of 5.25 bbls per hour. ' 10,226' to 11,100' interval was drilled with increased background gas levels exceeding 1000 units while rotating directional sliding gas levels decreased accordingly due to lower ROP and fluid dynamics. A 309.5 bbls loss was recorded during this interval at an average rate of 15.5 bbls/hr. Loss rate did increase dramatically from 10,676' to 11,100' with an avg of 24.8 bbls per PIONEER NATURAL RESOURCES I ' HALLIBURTON I Sperry Drilling hour. Samples through this interval possessed very good visible porosity, good visible oil ' staining and good cut characteristics. Chromatographs C1 TO C4-05 ratio readings confirm an excellent oil bearing zone. No connection gasses were recorded throughout the 24 hour period and increase in background gas levels can be contributed to formation. ' 03/26/2010 Drilled from 11,100' to a final TD of 11,658' MD, short tripped to shoe and RIH to bottom. ' 11,100' to 11,340' interval sections revealed sustained high background levels and excellent sample quality with good visible porosity and good visible staining, cut and fluorescence. This section had an average loss rate of 24 bbls an hour while drilling. 11,340' to 11,475' section an observed increase in the quantity of silt in the samples was reported and a gross reduction in background gas levels. Samples still revealed a high degree of fluorescence however much of it was contributed to mud lubricity products introduced. Mud losses slowed as well with only a 17.3 bbl average also suggesting a higher degree of silt and siltstone in the formation as well. ' 11,475' to 11,658' sample quality returned to excellent sandstone with good cut and fluorescence 23.8 bbls per hour loss was recorded to section TD. Circulated two times bottoms up and short tripped to casing, pumping out shoe with a 10 bbl loss recorded over calculated. 1 03/27/2010 Tripped back on hole to TD and pumped a 45 bbl high viscosity loss control sweep. POOH to 9067' and displaced well with 9.4 kill weight brine. Begin POOH to surface. 150 bbl loss was recorded throughout the twenty four hour period. 1 1 PIONEER NATURAL RESOURCES I Customer: Pioneer Natural Res. Report#: 1 HALLIBURTON Well: ODSK-35Ai Date: 3/22/2010 I Area: Oooguruk 04:00 Depth 9510' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Laying Down DP Job No.: AK-AM-0005555468 Report For: J Brown/J Cortez 1 Daily Charges $5,414.77 Total Charges: $45,798.84 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) 0.0 0.0 0.0 0' Flow In (gpm) 0 SPP (psi) 0 Gas(units) 0 0 0 0' Flow In (spm) 0 Gallons/stroke 3.5175 Hole Condition Dept On Bot Hrs. Ann Corr Avg Diam PWD Drilling Min Avg Max I9510' 0 0 bbls 0.00" All Circ Min Avg Max Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I % I8.80 8.80 26 8.00 23k BHA Run # I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition I . Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) Gas Breakdown L. H2S Data I Sample Line'Max: 'Avg: _ I Ambient Air Pit Room JMax: 'Avg: Gas(units) Chromatograph (ppm) Depth to I to to to I to to to to IGas Type abreviations:BG- Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG- Produced Gas; RG-Ream Gas; T---Trip...; F---Formation...; E--- Early... 24 hr Recap: Ran 7"casing and set at 9,503 ft,Reduced mud weight in pits to 11.0 ppg, Rigged down Case running equipment, Rigged up Halliburton cement equipment,Pumped cement and displaced with 10.2 brine,from pits.No returns, Rigged down cement head,Currently laying down 5 inch drill pipe.Callibrated gas equipment. I I ILogging Engineer: Mark Lindloff/Dan Sherwood * 10000 units= 100%Gas In Air I I Customer: _ _Pioneer Natural Res. Report#: 2 HALLIBURTON Well: ODSK-35Ai Date: 3/23/2010 I Area: Oooguruk 04:00 Depth 9510' Location: North Slope Progress 24 hrs: 0' Sperry Grilling Services Rig: Nabors 19AC Rig Activity: P/u 4"DP Job No.: AK-AM-0005555468 Report For: J Brown/J Cortez IDaily Charges $4,052.37 Total Charges: $48,488.81 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) 0.0 0.0 0.0 0' , Flow In (gpm) 0 SPP(psi) 0 Gas(units) 0 0 0 0' Flow In (spm) 0 Gallons/stroke 3.5175 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling Min Avg Max I -- 9510' 0 0 bbls 0.00" All Circ Min Avg Max• Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (lb/100ft2) ml/30min mg/I % I8.60 8.60 _ 28 0.00 _ 21k _ BHA Run # I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal _ Gvl Tuff I (current) _ Gas Breakdown L H2S Data I Sample Line Max: ]Avg: I Ambient Air Pit Room Max: Avg: I Gas(units) Chromatograph (ppm) Depth to I to to to _ to to to to IGas Type abreviations:BG- Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas; T---Trip...; F---Formation...; E--- Early... I 24 hr Recap: next interval. I `Note:Total Charges was corrected to reflect ADT charges halted on the 21st of Mar. I I — Logging Engineer: Mark Lindloff/Dan Sherwood * 10000 units= 100% Gas In Air 1 I I Customer: Pioneer Natural Res. Report#: 3 uALLIBURTON Well: ODSK-35Ai Date: 3/24/2010 I Area: 000guruk 04:00 Depth 9510' Location: North Slope Progress 24 hrs: 0' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: P/u 4"DP Job No.: AK-AM-0005555468 Report For: J Brown/J Cortez IDaily Charges $5,414.77 Total Charges: $53,903.58 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) 0.0 0.0 0.0 0' Flow In (gpm) Flow In (spm) 0 SPP(psi) 0 Gas(units) 0 0 0 0' 0 Gallons/stroke 3.5175 Depth On Bot Hrs Ann Corr Avg Diam Drilling Min Avg Max Hole Condition 9510' 0 0 bbls 6.13" PWD All Circ Min Avg Max• Mud Data: _ Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/gt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % I9510' 8.70 8.70 55 9 18 4.6 8.30 24k 1.7 BHA Run # I Bit Type Size TFA _ Hours Depth in/out Footage WOB RPM Condition 4 Hughes QD505HX _ 6.125 , 0.416 0.00 9510' Lithology (%): Sd Sst Silt Siltst Cht _ Clyst Sh Lst Coal Gvl Tuff I (current) Gas Breakdown H2S Data l Sample Line Max: !Avg: l Ambient Air Pit Room 'Max: 'Avg: I Depth Gas(units) Chromatograph (ppm) j to to to to Ito to to to IGas Type abreviations:BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas; T---Trip...; F---Formation...; E--- Early... I 24 hr Recap: Picked up 4 inch drill pipe,Tested BOP, Picked up BHA and tripped in hole to 9,410 ft., Displaced seawater with 8.7 ppg QuikDril-N mud system,Drill out cement,install MPD bearing. 1 Start ADT Services 3/24/2010 I I Logging Engineer: Mark Lindloff/Dan Sherwood * 10000 units= 100%Gas In Air I I Customer: Pioneer Natural Res. Report#: _ 4 1ALLIBURTOIIJ Well: ODSK-35Ai Date: 3/25/2010 I Area: Oooguruk 04:00 Depth 10226' Location: North Slope Progress 24 hrs: 715' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0005555468 Report For: J Brown/R. Klepzig / Daily Charges $5,414.77 Total Charges: $59,318.35 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) 35.0 102.0 309.0 9570' Flow In (gpm) 249 SPP (psi) 1971 Gas(units) 460 0 2948 9612' Flow In (spm) 70 Gallons/stroke 3.5175 Depth On Bot Hrs Ann Corr Avg Diam Drilling 8.60 Min 10.10 Avg 10.49 Max Hole Condition I Mud Data: 9510' 9.51 10 bbls 6.13" PWD All Circ 8.60 Min 10.09 Avg 10.75 Max Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) ml/30min mg/I % I10005' 8.70 8.70 _ 43 1.0 8 18 4.8 9.80 _ 23.5k 1.7 BHA Run # I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 Hughes QD505HX 6.125 0.416 0.00 9510' 1 Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) 85 _ 15 Gas Breakdown H2S Data I Sample Line Max: Avg: I Ambient Air Pit Room Max: Avg: I Gas(units) Chromatograph (ppm) Depth 9,563 to 9,711 2948 _ 415 261666 11471 3864 1251 371 GP 9,814 9,873 1160 260 112207 5114 1983 835 310 GP I to to to I to to to to IGas Type abreviations:BG- Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas; T---Trip...; F---Formation...; E--- Early... I 24 hr Recap: installed RCD bearing. Drilled 10'new hole from 9468',circulated BU and performed FIT to 12.5ppg. Drilled ahead to 10225'at time of report.Good qualty samples,mostly sandstone,strong fluoresence with a flash milky white cut. I I I Logging Engineer: Mark Lindloff/Dan Sherwood * 10000 units= 100%Gas In Air I I Customer: Pioneer Natural Res. Report#: 5 HALLIBURTON Well: ODSK-35Ai Date: 3/26/2010 Area: Oooguruk 04:00 Depth 11253' I Location: North Slope Progress 24 hrs: 1027' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Drilling Job No.: AK-AM-0005555468 Report For: J Brown/R. Klepzig IDaily Charges $5,414.77 Total Charges: $64,733.12 ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) 77.0 80.9 287.0 10882' Flow In (gpm) 246 SPP (psi) 2402 Gas(units) 207 1146 3100 10851' Flow In (spm) 70 Gallons/stroke 3.5175 Hole Condition Depth On Bot Hrs Ann Corr Avg Diam PWD Drilling 9.87 Min 10.12 Avg 13.40,Max 11253' 20.34 10 bbls 6.30" All Circ 9.35 Min 10.12 Avg 13.40 Max I Mud Data: Density(ppg) Viscosity MBT PV YP API Filt . pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min _ mg/I % I11047' 8.75 8.75 41 2.2 7 17 5.0 9.40 25k 1.7 BHA Run # I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 Hughes QD505HX 6.125 0.416 0.00 9510' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff (current) 85 15 Gas Breakdown H2S Data I Sample Line Max: Avg: ( Ambient Air Pit Room Max: 'Avg: IGas(units) Chromatograph (ppm) 10,321 to 10,374 2109 1137 164356 12097 6028 2901 872 FG 10,557 10,593 2348 1400 215756 11223 5389 2681 1044 FG I 10,966 to 11,002 2951 1800 242594 15097 6857 3051 1090 FG to to to to to to 1 Gas Type abreviations:BG- Background Gas; GP-Gas Peak; CG-Connection Gas; WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG -Ream Gas; T---Trip...; F---Formation...; E---Early... I 24 hr Recap: Drilled from 10,226'to 11,253'.Adding water between 20-70 bbls/hr. From 3/25 0400-12:00 Loss of 21 bbls,2.6 bbls/hr From 3/25 1200-1800 Loss of 117 bbls, 19.5 bbls/hr I From 3/25 1200-0000 Loss of 171 bbls,28.5 bbls/hr From 3/26 0000-0400 Loss of 83 bbls, 13.8 bbls/hr From 3/25 0400-3/26 0400 Loss of 393 bbls, 16.37 bbls/hr Good quality samples,strong fluoresence,strong oder and good stain. I I Logging Engineer: Mark Lindloff/Dan Sherwood * 10000 units= 100% Gas In Air I 1 Customer: Pioneer Natural Res. Report#: 6 HALLIBURTON Well: ODSK-35Ai Date: 3/27/2010 I Area: Oooguruk 04:00 Depth 11658' Location: North Slope Progress 24 hrs: 405' Sperry Drilling Services Rig: Nabors 19AC Rig Activity: Cir,Conditioning Hole Job No.: AK-AM-0005555468 Report For: J Brown/R. Klepzig I Daily Charges $5,414.77 Total Charges: $70,147.89 I ROP & Gas: Current Avg 24 hr Max Max @ ft Current Pump & Flow Data: I R.O.P. (ft/hr) Gas(units) 0.0 48.4 1012 219.0 11485' Flow In (gpm) 280 SPP(psi) 2425 49 2620 11287' Flow In (spm) 80 Gallons/stroke 3.5175 Depth On Bot Hrs Ann Corr Avg Diam Drilling 9.91 Min 10.11 Avg 10.34 Max Hole Condition I11658' 20.34 10 bbls 6.30" PWD All Circ 9.67 Min 10.15 Avg 10.50 Max• Mud Data: Density(ppg) Viscosity MBT PV YP API Filt pH Chlorides Cor Solids Depth ft in out (sec/qt) (ppb Eq) cP (Ib/100ft2) m1/30min mg/I % I11047' 8.60 8.60 44 11 18 4.4 10.10 _ 24K 0.7 BHA Run # I Bit Type Size TFA Hours Depth in/out Footage WOB RPM Condition 4 Hughes QD505HX 6.125 0.416 0.00 9510' Lithology (%): Sd Sst Silt Siltst Cht Clyst Sh Lst Coal Gvl Tuff I (current) 85 15 Gas Breakdown H2S Data I Sample Line Max: Avg. I Ambient Air Pit Room 'Max: Avg: IGas(units) Chromatograph (ppm) 11,250 to 11,310 2620 401 203749 10655 4895 2254 762 FG 11,486 to 11,575 2030 1997 179485 10951 4888 2300 827 FG I to to to to to to to Gas Type abreviations:BG-Background Gas; GP-Gas Peak; CG-Connection Gas;WTG-Wiper Trip Gas; POG-Pumps Off Gas; PG-Produced Gas; RG-Ream Gas; T---Trip...; F---Formation...; E---Early... I 24 hr Recap: Drilled from 11,253'to TD 11,658'.Adding water between 30-50 bbls/hr. From 3/26 0400-12:00 Loss of 172 bbls,21.5 bbls/hr From 3/26 1200-1800 Loss of 145 bbls,24.2 bbls/hr I From 3/25 1800-0000 Loss of 104 bbls,17.3 bbls/hr From 3/26 0000-0300 Loss of 32bbls,10.6 bbls/hr From 3/25 0400-3/26 0400 Loss of 453 bbls, 19.7 bbls/hr Good quality samples,strong fluoresence,strong oder and good stain. Logging Engineer: Mark Lindloff/Dan Sherwood * 10000 units= 100%Gas In Air I , .. 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N CO 00 — 0) CO 0) 0) 0) (Y) M W I a I- a O M n O N O M M O n N ib O UO in O in in N O O Un Un Un (O M N 0) Un 0 N O 0) 00 0 N ) V Un N 0) N CX) I: Un 2 N t v Un UO O co N 00 0 Un 0) M M Un 2 N (N .M-- V (O I� N O N 00 I J1 O O O . . .N- a- a- a- a- C • N co-- c�i V O r r r 0) a m = mit t Li w �, - J d Ts a J YL � � J L E Q L j a u/) N Q Y co Y Y cu m L n n o m o )a N I Y -t m v a .c Y Y • N U N N H m N = Y_ ` ; Y L C C ` eI� Y Y Y =0 II A m ~ (n CO FO H U H m Y U Y 0 Li _ Y CC a. li Y 0 H LI Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSK-35Ai Permit to Drill: 210-0120 API: 50-703-20560-01-00 Sperry Drilling Services Definitive Survey Report 31 March, 2010 1 ' HALLiaURTUft,, Sperry Drilling Services 1 I Halliburton Company P Y Definitive Survey Report I Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 I Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSK-35Ai North Reference: True Wellbore: ODSK-35Ai Survey Calculation Method: Minimum Curvature Design: ODSK-35Ai KupH Surveys Database: .Pioneer Alaska IProject Oooguruk Development Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level I Geo Datum: Map Zone: NAD 1927(NADCON CONUS) Using Well Reference Point Alaska Zone 04 Using geodetic scale factor Well ODSK-35Ai-Slot ODS-35 I Well Position +N/-S 0.00 ft Northing: 6,031,070.76 ft Latitude: 70°29'45.448 N +E/-W 0.00 ft Easting: 469,886.60 ft Longitude: 150°14'46.452 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50 ft 1 elWellbore ODSK-35Ai Magnetics Model Name Sample Date Declination Dip Angle Field Strength I (?) (?) (nT) IGRF200510 2/7/2009 22.39 80.81 57,722 Design ODSK-35Ai KupH Surveys IAudit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 3,216.69 Vertical Section: Depth From(ND) +N/-S +E/-W Direction I (ft) (ft) (ft) (?) 42.70 0.00 0.00 318.45 I Survey Program Date 3/31/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date I I 100.00 722.00 ODSK-35 KupB Gyro Surveys(ODSK-3E SR-Gyro-SS Fixed:v2:surface readout gyro single shot 2/7/2008 12: 764.01 3,216.69 ODSK-35 KupB MWD Surveys(ODSK-3 MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 2/7/2008 12: 3,270.11 7,553.45 ODSK-35Ai Int 1 MWD(ODSK-35Ai) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 3/9/2010 12: 7,651.30 9,501.28 ODSK-35Ai Int 2 MWD(ODSK-35A) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 3/31/2010 1: I9,532.31 11,609.99 ODSK-35Ai Horiz MWD(ODSK-35A) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 3/31/2010 t Survey I Map Map Vertical MD Inc Azi ND TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°H00) (ft) Survey Tool Name I 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,070.76 469,886.60 0.00 0.00 UNDEFINED 100.00 0.25 237.56 100.00 43.80 -0.07 -0.11 6,031,070.69 469,886.49 0.44 0.02 SR-Gyro-SS(1) 171.00 0.16 147.79 171.00 114.80 -0.23 -0.18 6,031,070.53 469,886.42 0.42 -0.05 SR-Gyro-SS(1) I 263.00 0.15 40.83 263.00 206.80 -0.04 6,031,070.51 469,886.56 0.27 -0.16 SR-Gyro-SS(1) 354.00 0.25 26.25 354.00 297.80 0.02 0.13 6,031,070.78 469,886.73 0.12 -0.07 SR-Gyro-SS(1) 447.00 0.28 347.15 447.00 390.80 0.42 0.17 6,031,071.18 469,886.77 0.19 0.20 SR-Gyro-SS(1) I 538.00 0.35 55.44 538.00 481.80 0.79 0.35 6,031,071.55 469,886.95 0.39 0.36 SR-Gyro-SS(1) 629.00 0.49 21.78 628.99 572.79 1.31 0.72 6,031,072.07 469,887.33 0.31 0.50 SR-Gyro-SS(1) 722.00 0.17 21.36 721.99 665.79 1.81 0.92 6,031,072.57 469,887.53 0.34 0.75 SR-Gyro-SS(1) I764.01 0.36 245.35 764.00 707.80 1.81 0.82 6,031,072.57 469,887.43 1.18 0.81 MWD+IFR2+MS+sag(2) 3/31/2010 2:58:12PM Page 2 COMPASS 2003.16 Build 42B I Halliburton Company P Y IDefinitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Project: Oooguruk Development ND Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSK-35Ai North Reference: True Wellbore: ODSK-35Ai Survey Calculation Method: Minimum Curvature Design: ODSK-35Ai KupH Surveys Database: .Pioneer Alaska ISurvey Map Map Vertical MD Inc Azi ND TV +14/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 856.15 1.49 252.62 856.13 799.93 1.34 -0.58 6,031,072.10 469,886.02 1.23 1.39 MWD+IFR2+MS+sag(2) 948.33 1.53 248.90 948.28 892.08 0.53 -2,88 6,031,071.31 469,883.73 0.11 2.31 MWD+IFR2+MS+sag(2) I 1,043.51 1.88 252.59 1,043.41 987.21 -5.55 6,031,070.39 469,881.05 0.39 3.39 MWD+IFR2+MS+sag(2) 1,139.79 1.55 242.95 1,139.65 1,083.45 -1.45 -8.22 6,031,069.34 469,878.38 0.45 4.36 MWD+IFR2+MS+sag(2) 1,235.65 1.97 243.47 1,235.47 1,179.27 -2.78 -10.85 6,031,068.02 469,875.74 0.44 5.11 MWD+IFR2+MS+sag(2) I 1,333.20 1.86 267.65 1,332.96 1,276.76 -3.59 -13.93 6,031,067.22 469,872.66 0.83 6.55 MWD+IFR2+MS+sag(2) 1,429.17 4.32 294.73 1,428.79 1,372.59 -2.15 -18.77 6,031,068.69 469,867.82 2.91 10.84 MWD+IFR2+MS+sag(2) 1,525.74 5.11 296.62 1,525.03 1,468.83 1.30 -25.92 6,031,072.17 469,860.69 0.83 18.17 MWD+IFR2+MS+sag(2) I 1,622.36 7.18 286.60 1,621.10 1,564.90 4.96 -35.55 6,031,075.86 469,851.07 2.41 27.29 MWD+IFR2+MS+sag(2) 1,719.74 9.44 274.58 1,717.45 1,661.25 7.33 -49.35 6,031,078.29 469,837.29 2.92 38.22 MWD+IFR2+MS+sag(2) 1,815.80 11.37 265.58 1,811.94 1,755.74 7.23 -66.64 6,031,078.26 469,819.99 2.62 49.62 MWD+IFR2+MS+sag(2) I 1,912.55 13.25 260.94 1,906.46 1,850.26 4.75 -87.10 6,031,075.86 469,799.53 2.19 61.33 MWD+IFR2+MS+sag(2) 2,009.11 14.35 257.23 2,000.23 1,944.03 0.36 -109.70 6,031,071.57 469,776.91 1.46 73.03 MWD+IFR2+MS+sag(2) 2,105.41 15.91 256.13 2,093.19 2,036.99 -5.44 -134.16 6,031,065.87 469,752.44 1.65 84.91 MWD+IFR2+MS+sag(2) I 2,201.97 18.24 256.76 2,185.49 2,129.29 -12.07 -161.72 6,031,059.34 469,724.85 2.42 98.23 MWD+IFR2+MS+sag(2) 2,298.82 21.92 255.23 2,276.44 2,220.24 -20.16 -193.97 6,031,051.39 469,692.57 3.84 113.57 MWD+IFR2+MS+sag(2) 2,395.13 25.99 254.76 2,364.43 2,308.23 -30.29 -231.72 6,031,041.41 469,654.78 4.23 131.03 MWD+IFR2+MS+sag(2) I ! 2,491.86 31.03 253.95 2,449.41 2,393.21 -42.76 -276.16 6,031,029.12 469,610.30 5.23 151.17 MWD+IFR2+MS+sag(2) 2,587.63 34.73 253.05 2,529.82 2,473.62 -57.55 -326.00 6,031,014.54 469,560.41 3.90 173.16 MWD+IFR2+MS+sag(2) 2,684.28 36.76 251.65 2,608.26 2,552.06 -74.68 -379.79 6,030,997.63 469,506.55 2.26 196.02 MWD+IFR2+MS+sag(2) I 2,779.94 37.29 249.80 2,684.64 2,628.44 -434.16 6,030,978.83 469,452.11 1.29 217.84 MWD+IFR2+MS+sag(2) 2,876.70 39.47 248.30 2,760.48 2,704.28 115.19 -490.25 6,030,957.57 469,395.94 2.45 238.96 MWD+IFR2+MS+sag(2) 2,973.29 39.90 250.03 2,834.82 2,778.62 -137.12 -547.89 6,030,935.87 469,338.22 1.23 260.78 MWD+IFR2+MS+sag(2) 3,070.47 40.97 248.05 2,908.79 2,852.59 -159.68 -606.74 6,030,913.56 469,279.28 1.72 282.93 MWD+IFR2+MS+sag(2) I3,167.15 41.02 248.08 2,981.76 2,925.56 -183.37 -665.57 6,030,890.11 469,220.36 0.06 304.22 MWD+IFR2+MS+sag(2) 3,216.69 41.28 248.82 3,019.06 2,962.86 -195.34 -695.89 6,030,878.26 469,190.00 1.11 315.37 MWD+IFR2+MS+sag(2) 3,270.11 41.42 249.14 3,059.17 3,002.97 -208.00 -728.83 6,030,865.73 469,157.01 0.47 327.75 MWD+IFR2+MS+sag(3) I 3,370.62 41.54 257.71 3,134.53 3,078.33 -792.51 6,030,847.04 469,093.26 5.65 355.81 MWD+IFR2+MS+sag(3) 3,465.44 43.09 267.98 3,204.73 3,148.53 234.80 -855.68 6,030,839.46 469,030.06 7.47 391.83 MWD+IFR2+MS+sag(3) 3,555.76 42.33 275.09 3,271.13 3,214.93 -233.18 -916.84 6,030,841.32 468,968.92 5.40 433.61 MWD+IFR2+MS+sag(3) I 3,650.52 41.94 282.22 3,341.44 3,285.24 -979.60 6,030,851.11 468,906.20 5.06 482.37 MWD+IFR2+MS+sag(3) 3,749.80 42.79 288.85 3,414.83 3,358.63 -205.72 -1,043.98 6,030,869.29 468,841.90 4.58 538.49 MWD+IFR2+MS+sag(3) 3,844.67 43.32 293.99 3,484.18 3,427.98 -182.07 -1,104.22 6,030,893.19 468,781.76 3.74 596.15 MWD+IFR2+MS+sag(3) I 3,940.45 44.47 301.39 3,553.24 3,497.04 -1,162.92 6,030,924.27 468,723.19 5.49 658.17 MWD+IFR2+MS+sag(3) 4,035.59 46.57 307.87 3,619.94 3,563.74 -112.62 -1,218.67 6,030,963.09 468,667.60 5.34 724.03 MWD+IFR2+MS+sag(3) 4,129.42 50.23 314.34 3,682.26 3,626.06 -66.46 -1,271.41 6,031,009.45 468,615,06 6.46 793.55 MWD+IFR2+MS+sag(3) I 4,225.06 53.96 318.82 3,741.02 3,684.82 4,320.03 56.76 323.31 3,795.02 3,738.82 -11.63 -1,323.19 6,031,064.49 468,563.51 5.37 868.93 MWD+IFR2+MS+sag(3) 49.14 -1,372.23 6,031,125.46 468,514.72 4.88 946.94 MWD+IFR2+MS+sag(3) 4,416.37 60.20 327.94 3,845.40 3,789.20 116.92 -1,418.52 6,031,193.42 468,468.71 5.43 1,028.37 MWD+IFR2+MS+sag(3) 4,510.78 61.16 330.56 3,891.63 3,835.43 187.66 -1,460.60 6,031,264.32 468,426.92 2.62 1,109.22 MWD+IFR2+MS+sag(3) 3/31/2010 2:58:12PM Page 3 COMPASS 2003.16 Build 428 I Halliburton Company P Y Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'©56.20ft(Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.20ft(Nabors 19AC) Well: ODSK-35Ai North Reference: True Welibore: ODSK-35Ai Survey Calculation Method: Minimum Curvature Design: ODSK-35Ai KupH Surveys Database: .Pioneer Alaska I Survey Map Map Vertical I MD (ft) Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 4,607.41 61.40 330.42 3,938.07 3,881.87 261.41 -1,502.34 6,031,338.23 468,385.49 0.28 1,192.09 MWD+IFR2+MS+sag(3) 4,700.93 61.90 329.80 3,982.48 3,926.28 332.76 -1,543.35 6,031,409.74 468,344.76 0.79 1,272.70 MWD+IFR2+MS+sag(3) I 4,795.28 61.56 329.83 4,027.16 3,970.96 404.59 -1,585.13 6,031,481.73 468,303.28 0.36 1,354.16 MWD+IFR2+MS+sag(3) 4,893.86 62.23 329.49 4,073.60 4,017.40 479.64 -1,629.06 6,031,556.95 468,259.66 0.74 1,439.46 MWD+IFR2+MS+sag(3) 4,987.40 62.59 329.14 4,116.93 4,060.73 550.93 -1,671.36 6,031,628.40 468,217.65 0.51 1,520.88 MWD+IFR2+MS+sag(3) I5,081.83 62.31 329.14 4,160.60 4,104.40 622.80 -1,714.31 6,031,700.44 468,175.00 0.30 1,603.15 MWD+IFR2+MS+sag(3) 5,177.92 62.54 328.17 4,205.08 4,148.88 695.55 -1,758.62 6,031,773.35 468,130.99 0.93 1,686.97 MWD+IFR2+MS+sag(3) 5,272.50 61.40 327.63 4,249.53 4,193.33 766.27 -1,802.98 6,031,844.25 468,086.92 1.31 1,769.32 MWD+IFR2+MS+sag(3) I 5,367.63 61.10 326.64 4,295.29 4,239.09 5,464.61 60.63 327.45 4,342.50 4,286.30 836.32 -1,848.24 6,031,914.48 468,041.95 0.97 1,851.77 MWD+IFR2+MS+sag(3) 907.40 -1,894.32 6,031,985.73 467,996.17 0.88 1,935.53 MWD+IFR2+MS+sag(3) 5,558.18 60.52 327.68 4,388.47 4,332.27 976.18 -1,938.03 6,032,054.69 467,952.74 0.24 2,016.00 MWD+IFR2+MS+sag(3) I 5,654.27 60.15 327.31 4,436.03 4,379.83 1,046.60 -1,982.90 6,032,125.28 467,908.16 0.51 2,098.45 MWD+IFR2+MS+sag(3) 5,747.76 60.26 328.49 4,482.49 4,426.29 1,115.33 -2,026.01 6,032,194.17 467,865.33 1.10 2,178.48 MWD+IFR2+MS+sag(3) 5,845.92 60.62 328.27 4,530.91 4,474.71 1,188.03 -2,070.77 6,032,267.05 467,820.87 0.42 2,262.59 MWD+IFR2+MS+sag(3) I 5,937.48 60.20 329.59 4,576.13 4,519.93 1,256.23 -2,111.86 6,032,335.40 467,780.06 1.33 2,340.87 MWD+IFR2+MS+sag(3) 6,031.12 62.23 330.38 4,621.21 4,565.01 1,327.29 -2,152.91 6,032,406.62 467,739.30 2.29 2,421.28 MWD+IFR2+MS+sag(3) 6,126.05 61.99 330.50 4,665.62 4,609.42 1,400.27 -2,194.30 6,032,479.77 467,698.21 0.28 2,503.35 MWD+IFR2+MS+sag(3) I 6,222.59 61.33 330.52 4,711.45 4,655.25 1,474.23 -2,236.13 6,032,553.89 467,656.69 0.68 2,586.45 MWD+IFR2+MS+sag(3) 6,318.74 60.36 330.42 4,758.29 4,702.09 1,547.29 -2,277.51 6,032,627.11 467,615.60 1.01 2,668.57 MWD+IFR2+MS+sag(3) 6,413.87 59.57 330.11 4,805.90 4,749.70 1,618.80 -2,318.36 6,032,698.78 467,575.05 0.88 2,749.18 MWD+IFR2+MS+sag(3) I 6,508.55 62.30 331.34 4,851.90 4,795.70 1,690.99 -2,358.81 6,032,771.12 467,534.89 3.10 2,830.03 MWD+IFR2+MS+sag(3) 6,603.63 62.09 329.95 4,896.25 4,840.05 1,764.29 -2,400.04 6,032,844.58 467,493.97 1.31 2,912.24 MWD+IFR2+MS+sag(3) 6,698.54 62.00 330.80 4,940.74 4,884.54 1,837.16 -2,441.48 6,032,917.61 467,452.83 0.80 2,994.26 MWD+IFR2+MS+sag(3) 6,794.38 63.27 331.72 4,984.79 4,928.59 1,911.79 -2,482.40 6,032,992.40 467,412.21 1.58 3,077.25 MWD+IFR2+MS+sag(3) I6,887.42 63.13 332.49 5,026.74 4,970.54 1,985.19 -2,521.26 6,033,065.95 467,373.66 0.75 3,157.95 MWD+IFR2+MS+sag(3) 6,988.26 63.87 332.23 5,071.74 5,015.54 2,065.13 -2,563.12 6,033,146.05 467,332.12 0.77 3,245.55 MWD+IFR2+MS+sag(3) 7,079.37 63.76 331.84 5,111.94 5,055.74 2,137.35 -2,601.46 6,033,218.41 467,294.08 0.40 3,325.02 MWD+IFR2+MS+sag(3) I 7,171.46 62.40 330.23 5,153.64 5,097.44 2,209.19 -2,641.22 6,033,290.40 467,254.62 2.15 3,405.15 MWD+IFR2+MS+sag(3) 7,269.52 62.19 328.49 5,199.23 5,143.03 2,283.88 -2,685.46 6,033,365.27 467,210.68 1.59 3,490.40 MWD+IFR2+MS+sag(3) 7,365.61 61.76 328.17 5,244.38 5,188.18 2,356.07 -2,729.99 6,033,437.63 467,166.45 0.54 3,573.96 MWD+IFR2+MS+sag(3) I 7,460.55 62.10 327.69 5,289.05 5,232.85 2,427.06 -2,774.47 6,033,508.79 467,122.26 0.57 3,656.59 MWD+IFR2+MS+sag(3) 7,553.45 61.56 327.52 5,332.91 5,276.71 2,496.21 -2,818.35 6,033,578.11 467,078.67 0.60 3,737.44 MWD+IFR2+MS+sag(3) 7,651.30 60.45 327.42 5,380.34 5,324.14 2,568.37 -2,864.37 6,033,650.45 467,032.95 1.14 3,821.97 MWD+IFR2+MS+sag(4) I 7,746.20 60.19 326.85 5,427.33 5,371.13 2,637.62 -2,909.11 6,033,719.88 466,988.49 0.59 3,903.47 MWD+IFR2+MS+sag(4) 7,841.53 61.37 326.99 5,473.87 5,417.67 2,707.33 -2,954.52 6,033,789.77 466,943.37 1.24 3,985.76 MWD+IFR2+MS+sag(4) 7,937.40 60.97 327.56 5,520.10 5,463.90 2,777.99 -2,999.93 6,033,860.60 466,898.25 0.67 4,068.75 MWD+IFR2+MS+sag(4) I 8,031.96 59.82 327.94 5,566.81 5,510.61 2,847.52 -3,043.80 6,033,930.30 466,854.67 1.27 4,149.89 MWD+IFR2+MS+sag(4) 8,127.59 60.28 327.30 5,614.55 5,558.35 2,917.49 -3,088.17 6,034,000.44 466,810.58 0.75 4,231.69 MWD+IFR2+MS+sag(4) 8,222.49 59.63 326.53 5,662.07 5,605.87 2,986.32 -3,133.01 6,034,069.45 466,766.02 0.98 4,312.94 MWD+IFR2+MS+sag(4) I 8,317.81 60.78 326.20 5,709.43 5,653.23 3,055.19 -3,178.83 6,034,138.49 466,720.49 1.24 4,394.87 MWD+IFR2+MS+sag(4) I 3/31/2010 2:58:12PM Page 4 COMPASS 2003.16 Build 428 I I Halliburton Company P Y IDefinitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Project: Oooguruk Development TVD Reference: 42.7+13.5'@ 56.20ft(Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSK-35Ai North Reference: True Welibore: ODSK-35Ai Survey Calculation Method: Minimum Curvature Design: ODSK-35Ai KupH Surveys Database: .Pioneer Alaska I Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,413.74 61.13 326.28 5,756.01 5,699.81 3,124.91 -3,225.44 6,034,208.40 466,674.17 0.37 4,477.96 MWD+IFR2+MS+sag(4) 8,508.32 61.41 325.91 5,801.47 5,745.27 3,193.75 -3,271.70 6,034,277.41 466,628.19 0.45 4,560.16 MWD+IFR2+MS+sag(4) I8,602.04 61.57 327.09 5,846.20 5,790.00 3,262.42 -3,317.15 6,034,346.26 466,583.02 1.12 4,641.70 MWD+IFR2+MS+sag(4) 8,696.83 63.91 327.29 5,889.62 5,833.42 3,333.24 -3,362.81 6,034,417.26 466,537.66 2.48 4,724.98 MWD+IFR2+MS+sag(4) 8,792.58 67.07 328.48 5,929.34 5,873.14 3,407.02 -3,409.11 6,034,491.22 466,491.67 3.49 4,810.91 MWD+IFR2+MS+sag(4) I8,888.00 70.37 328.51 5,963.96 5,907.76 3,482.82 -3,455.56 6,034,567.20 466,445.52 3.46 4,898.45 MWD+IFR2+MS+sag(4) 8,983.58 71.21 327.11 5,995.41 5,939.21 3,559.20 -3,503.65 6,034,643.76 466,397.75 1.64 4,987.50 MWD+IFR2+MS+sag(4) 9,077.80 73.52 327.09 6,023.95 5,967.75 3,634.59 -3,552.42 6,034,719.34 466,349.29 2.45 5,076.27 MWD+IFR2+MS+sag(4) I 9,173.92 75.90 326.09 6,049.30 5,993.10 3,711.97 -3,603.47 6,034,796.92 466,298.56 2.67 5,168.04 MWD+IFR2+MS+sag(4) 9,268.90 78.87 325.58 6,070.04 6,013.84 3,788.65 -3,655.52 6,034,873.81 466,246.83 3.17 5,259.95 MWD+IFR2+MS+sag(4) 9,364.18 82.39 325.86 6,085.55 6,029.35 3,866.32 -3,708.46 6,034,951.68 466,194.21 3.71 5,353.19 MWD+IFR2+MS+sag(4) I9,459.66 84.86 326.14 6,096.15 6,039.95 3,944.98 -3,761.51 6,035,030.55 466,141.48 2.60 5,447.25 MWD+IFR2+MS+sag(4) 9,477.75 85.30 326.38 6,097.70 6,041.50 3,959.97 -3,771.52 6,035,045.58 466,131.53 2.77 5,465.10 MWD+IFR2+MS+sag(4) 9,501.28 85.42 326.09 6,099.61 6,043.41 3,979.47 -3,784.56 6,035,065.12 466,118.57 1.33 5,488.34 MWD+IFR2+MS+sag(4) I i 9,532.31 88.61 325.70 6,101.22 6,045.02 4,005.12 -3,801.93 6,035,090.85 466,101.31 10.36 5,519.06 MWD+IFR2+MS+sag(5) 9,564.16 92.75 326.08 6,100.84 6,044.64 4,031.49 -3,819.79 6,035,117.28 466,083.56 13.05 5,550.64 MWD+IFR2+MS+sag(5) 9,596.43 91.86 327.46 6,099.55 6,043.35 4,058.46 -3,837.46 6,035,144.32 466,066.00 5.09 5,582.54 MWD+IFR2+MS+sag(5) I I 9,628.70 91.30 327.92 6,098.66 6,042.46 4,085.72 -3,854.70 6,035,171.65 466,048.87 2.25 5,614.38 MWD+IFR2+MS+sag(5) 9,661.40 90.43 328.74 6,098.16 6,041.96 4,113.55 -3,871.86 6,035,199.54 466,031.82 3.66 5,646.59 MWD+IFR2+MS+sag(5) 9,693.15 90.80 327.71 6,097.82 6,041.62 4,140.54 -3,888.58 6,035,226.59 466,015.21 3.45 5,677.88 MWD+IFR2+MS+sag(5) I 9,724.79 88.64 328.36 6,097.98 6,041.78 4,167.38 -3,905.33 6,035,253.50 465,998.58 7.13 5,709.07 MWD+IFR2+MS+sag(5) 9,757.84 88.58 327.91 6,098.78 6,042.58 4,195.44 -3,922.77 6,035,281.63 465,981.25 1.37 5,741.64 MWD+IFR2+MS+sag(5) 9,789.90 88.89 327.95 6,099.49 6,043.29 4,222.60 -3,939.79 6,035,308.86 465,964.34 0.97 5,773.25 MWD+IFR2+MS+sag(5) 9,828.18 88.77 328.49 6,100.27 6,044.07 4,255.13 -3,959.95 6,035,341.47 465,944.32 1.44 5,810.97 MWD+IFR2+MS+sag(5) I W 9,853.73 87.11 326.81 6,101.19 6,044.99 4,276.70 -3,973.61 6,035,363.09 465,930.75 9.24 5,836.17 MD+IFR2+MS+sag(5) i 9,885.92 87.46 324.63 6,102.71 6,046.51 4,303.27 -3,991.72 6,035,389.73 465,912.75 6.85 5,868.07 MWD+IFR2+MS+sag(5) 9,919.37 88.95 324.53 6,103.76 6,047.56 4,330.51 -4,011.10 6,035,417.05 465,893.48 4.46 5,901.31 MWD+IFR2+MS+sag(5) I 9,950.75 89.01 325.11 6,104.32 6,048.12 4,356.16 -4,029.17 6,035,442.76 465,875.51 1.86 5,932.49 MWD+IFR2+MS+sag(5) 9,983.22 87.12 323.17 6,105.41 6,049.21 4,382.45 -4,048.18 6,035,469.13 465,856.61 8.34 5,964.78 MWD+IFR2+MS+sag(5) 10,030.67 87.04 322.78 6,107.83 6,051.63 4,420.29 -4,076.72 6,035,507.08 465,828.23 0.84 6,012.02 MWD+IFR2+MS+sag(5) I 10,079.28 88.67 322.73 6,109.65 6,053.45 4,458.96 -4,106.11 6,035,545.86 465,799.00 3.35 6,060.46 MWD+IFR2+MS+sag(5) 10,112.53 88.48 322.10 6,110.48 6,054.28 4,485.30 -4,126.39 6,035,572.28 465,778.83 1.98 6,093.62 MWD+IFR2+MS+sag(5) 10,144.86 89.88 323.14 6,110.94 6,054.74 4,510.98 -4,146.01 6,035,598.05 465,759.31 5.39 6,125.86 MWD+IFR2+MS+sag(5) I 10,176.34 89.75 322.62 6,111.04 6,054.84 4,536.08 -4,165.01 6,035,623.22 465,740.42 1.70 6,157.24 MWD+IFR2+MS+sag(5) 10,208.51 89.90 322.12 6,111.14 6,054.94 4,561.56 -4,184.65 6,035,648.77 465,720.88 1.62 6,189.34 MWD+1FR2+MS+sag(5) 10,240.98 90.06 323.23 6,111.15 6,054.95 4,587.38 -4,204.34 6,035,674.67 465,701.30 3.45 6,221.72 MWD+IFR2+MS+sag(5) I 10,272.63 90.63 323.66 6,110.96 6,054.76 4,612.81 -4,223.19 6,035,700.17 465,682.56 2.26 6,253.25 MWD+IFR2+MS+sag(5) 10,321.06 87.77 324.85 6,111.64 6,055.44 4,652.10 -4,251.48 6,035,739.58 465,654.43 6.40 6,301.42 MWD+IFR2+MS+sag(5) 10,369.88 87.92 324.32 6,113.47 6,057.27 4,691.86 -4,279.75 6,035,779.45 465,626.33 1.13 6,349.92 MWD+IFR2+MS+sag(5) I10,419.88 88.83 324.73 6,114.89 6,058.69 4,732.56 -4,308.75 6,035,820.26 465,597.49 2.00 6,399.62 MWD+IFR2+MS+sag(5) 3/312010 2:58:12PM Page 5 COMPASS 2003.16 Build 428 I Halliburton Company P Y Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSK-35Ai-Slot ODS-35 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) I Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Well: ODSK-35Ai North Reference: True Welibore: ODSK-35Ai Survey Calculation Method: Minimum Curvature Design: ODSK-35Ai KupH Surveys Database: .Pioneer Alaska ISurvey Map Map Vertical ' MD Inc Azi TVD TVDSS +N/-S +E1-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,464.93 90.00 326.37 6,115.35 6,059.15 4,769.71 -4,334.23 6,035,857.51 465,572.16 4.47 6,444.32 MWD+IFR2+MS+sag(5) I 10,506.06 89.88 326.58 6,115.39 6,059.19 4,804.00 -4,356.95 6,035,891.88 465,549.59 0.59 6,485.05 MWD+IFR2+MS+sag(5) 10,562.47 90.01 324.45 6,115.45 6,059.25 4,850.49 -4,388.89 6,035,938.50 465,517.84 3.78 6,541.03 MWD+IFR2+MS+sag(5) 10,612.61 90.20 319.94 6,115.36 6,059.16 4,890.10 -4,419.61 6,035,978.23 465,487.28 9.00 6,591.05 MWD+IFR2+MS+sag(5) 10,658.66 89.44 318.01 6,115.50 6,059.30 4,924.84 -4,449.84 6,036,013.08 465,457.20 4.50 6,637.09 MWD+IFR2+MS+sag(5) 10,707.78 90.37 318.10 6,115.58 6,059.38 4,961.37 -4,482.67 6,036,049.75 465,424.52 1.90 6,686.21 MWD+IFR2+MS+sag(5) 10,755.61 90.76 318.74 6,115.11 6,058.91 4,997.15 -4,514.41 6,036,085.65 465,392.92 1.57 6,734.04 MWD+IFR2+MS+sag(5) 10,801.49 90.88 319.55 6,114.45 6,058.25 5,031.85 -4,544.42 6,036,120.46 465,363.06 1.78 6,779.91 MWD+IFR2+MS+sag(5) I 10,851.95 89.88 318.72 6,114.12 6,057.92 5,070.00 -4,577.43 6,036,158.75 465,330.20 2.58 6,830.37 MWD+IFR2+MS+sag(5) 10,900.83 89.63 318.46 6,114.33 6,058.13 5,106.66 -4,609.76 6,036,195.54 465,298.02 0.74 6,879.24 MWD+IFR2+MS+sag(5) 10,948.47 89.22 317.84 6,114.81 6,058.61 5,142.15 -4,641.55 6,036,231.15 465,266.39 1.56 6,926.88 MWD+IFR2+MS+sag(5) 10,995.90 90.02 316.87 6,115.12 6,058.92 5,177.03 -4,673.68 6,036,266.16 465,234.40 2.65 6,974.30 MWD+IFR2+MS+sag(5) 11,044.18 90.33 316.07 6,114.97 6,058.77 5,212.04 -4,706.93 6,036,301.30 465,201.30 1.78 7,022.55 MWD+IFR2+MS+sag(5) 11,093.27 91.73 318.90 6,114.09 6,057.89 5,248.21 -4,740.09 6,036,337.60 465,168.28 6.43 7,071.62 MWD+IFR2+MS+sag(5) I 11,139.37 88.21 321.16 6,114.11 6,057.91 5,283.53 -4,769.70 6,036,373.04 465,138.82 9.07 7,117.69 MWD+IFR2+MS+sag(5) 11,189.29 89.59 321.06 6,115.07 6,058.87 5,322.38 -4,801.04 6,036,412.01 465,107.65 2.77 7,167.55 MWD+IFR2+MS+sag(5) 11,236.84 89.02 322.74 6,115.65 6,059.45 5,359.80 -4,830.37 6,036,449.54 465,078.47 3.73 7,215.01 MWD+IFR2+MS+sag(5) I 11,292.35 89.51 324.26 6,116.36 6,060.16 5,404.41 -4,863.39 6,036,494.28 465,045.63 2.88 7,270.29 MWD+IFR2+MS+sag(5) 11,332.73 90.00 326.81 6,116.53 6,060.33 5,437.70 -4,886.24 6,036,527.66 465,022.92 6.43 7,310.36 MWD+IFR2+MS+sag(5) 11,384.08 89.32 329.96 6,116.84 6,060.64 5,481.42 -4,913.15 6,036,571.49 464,996.19 6.28 7,360.93 MWD+IFR2+MS+sag(5) I 11,427.63 89.59 331.38 6,117.25 6,061.05 5,519.39 -4,934.48 6,036,609.53 464,975.01 3.32 7,403.50 MWD+IFR2+MS+sag(5) 11,479.74 87.72 335.45 6,118.48 6,062.28 5,565.96 -4,957.79 6,036,656.20 464,951.90 8.59 7,453.81 MWD+IFR2+MS+sag(5) 11,524.85 87.16 335.15 6,120.49 6,064.29 5,606.91 -4,976.62 6,036,697.21 464,933.23 1.41 7,496.94 MWD+IFR2+MS+sag(5) 11,575.48 86.91 335.27 6,123.11 6,066.91 5,652.81 -4,997.82 6,036,743.20 464,912.22 0.55 7,545.36 MWD+IFR2+MS+sag(5) I11,609.99 87.65 336.55 6,124.75 6,068.55 5,684.28 -5,011.89 6,036,774.72 464,898.28 4.28 7,578.24 MWD+IFR2+MS+sag(5) 11,658.00 87.65 336.55 6,126.72 6,070.52 5,728.28 -5,030.98 6,036,818.80 464,879.37 0.00 7,623.83 PROJECTED to TD I I I I 3/31!2010 2:58:12PM Page 6 COMPASS 2003.16 Build 428 I HALLIBURTON OOOg u ru k O DS K-14 Sperry Drilling Days vs. Depth I Rig Days 8500 - I I P ION 1 iLrcti222oio E 9000 --5129M($2l Arivegstjo1] --- _ I 5/8"Casing se'at 9503'MD 609 ' MURAL R C TVD MR Start 6 1/8""Production I 9500 -- I I ' D 6100.29 TVD _ On Bot :52 3/24/10 __ I I \II.I 10000 ---- --- — --- ---- 10500 —I IS Q 11000 I 22 — End of ODSK-35Ai C 11500 — — TD-6-'f78'� rF oWolfion - i W a 11,658.05'MD 6126.72'TVD — ' i ' Off Bot:18:29 3/26/10 r — 12000 ---- --- --- --- 1 12500 — t ' _- _ I 13000 r , ■ , ■ — --- --- ---- Run 4 1/2"Liner 13500 -- r t ' ;_ 0 I , • , ) I I I i t 14000 ' II HALL a u D Sperry Drilling ODSK-35Ai API 50-703-20560-01-00 Digital Data EMF & PDF Logs ADI End of Well Report Halliburton Log Viewer EMF Viewer ;PIONEER'
