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Home My WebLink About211-042MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 29, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Eni US Operating Co. Inc. ODSN-23 OOOGURUK NUQ ODSN-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2024 ODSN-23 50-703-20639-00-00 211-042-0 W SPT 5690 2110420 1500 2916 2916 2916 2916 5 5 5 5 4YRTST P Adam Earl 7/20/2024 MIT IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:OOOGURUK NUQ ODSN-23 Inspection Date: Tubing OA Packer Depth 691 1651 1601 1591IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240722093413 BBL Pumped:1.7 BBL Returned:1.7 Thursday, August 29, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.30 11:44:52 -08'00' MEMORANDUM Inspector Name: Lou Laubmstein State of Alaska Permit Number: 211-042-0 Inspection Date: 7/13/2020 Iusp Num: mitLOL200716085804 Alaska Oil and Gas Conservation Commission ''� TO: Jim Re /�/ P.I. Supervisor '\!i / �(ZQ1 �AZy DATE: Tuesday, July 21, 2020 SUBJECT: Mechanical Integrity Tests / Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min DSN-23 .Type Eni US Operating Company Inc. W'TVD ODSN-23 FROM: Lou Laubenstein 2752 - OOOGURUK NUQ ODSN-23 Petroleum Inspector 2753 '110420 r Src: Inspector Test SPr Reviewed By: 1500 . IA Supry tea' 1703 NON -CONFIDENTIAL Comm Well Name OOOGURUK NUQ ODSN-23 API Well Number 50-703-20639-00-00 Inspector Name: Lou Laubmstein Permit Number: 211-042-0 Inspection Date: 7/13/2020 Iusp Num: mitLOL200716085804 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min DSN-23 .Type InJ W'TVD 5690 ' 'Tubing 2752 - 2753' 2753 - 2753 '110420 r 'Type Test SPr Test psi 1500 . IA 559 1703 1634 1620 - ed: 2.1 BBL Returned: s OA 6 7 7 s 4YRTST P/F P Notes: Good test svx dlt, 514/zaw, wvAt UM ( �un2 Zri7-C� Tuesday, July 21, 2020 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg e,/, 6/t 3I1(� DATE: Wednesday,June 08,2016 P.I.Supervisor II SUBJECT: Mechanical Integrity Tests CAELUS NATURAL RESOURCES ALASK ODSN-23 FROM: Johnnie Hill 000GURUK NUQ ODSN-23 Petroleum Inspector SIT: Inspector Reviewed Byy:pn P.I.Supry .JC✓" NON-CONFIDENTIAL Comm Well Name 000GURUK NUQ ODSN-23 API Well Number 50-703-20639-00-00 Inspector Name: Johnnie Hill Permit Number: 211-042-0 Inspection Date: 5/4/2016 Insp Num: mitJWH160508143129 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ODSN-23 Type Inj G TVD 5690 ' Tubing 4469 4470 ' 4469 = 4468 PTD 2110420 - Type Test SPT Test psi 1500 ' IA 330 1816 - 1805 1796 ' Interval4TST ' P/F P '1 OA 0 2 2 ' 2 Notes: 2.7 bbls used Sattlite DEC 2 9 2016 Wednesday,June 08,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 09,2016 Supervisor �� TO: Jim Regg �� iL4-f i SUBJECT: Mechanical Integrity Tests P.I.P CAELUS NATURAL RESOURCES ALASK ODSN-23 FROM: Johnnie Hill 000GURUK NUQ ODSN-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv3- NON-CONFIDENTIAL Comm Well Name 000GURUK NUQ ODSN-23 API Well Number 50-703-20639-00-00 Inspector Name: Johnnie Hill Permit Number: 211-042-0 Inspection Date: 5/4/2016 Insp Num: mitJWH160508143129 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ODSN-23 • Type Inj G 'TVD 5690 - Tubing 4469 - 4470 - 4469 - 4468 - PTD 2110420 Type Test SPT Test psi 1500 • IA 330 1816 1805 - 1796 Interval 41 RTST P/F P - 1 OA j 0.4 1.7 - 1.7 1.7 . i Notes: 2.7 bbls used SCANNED SEP 2 7 2016 Monday,May 09,2016 Page 1 of 1 C 'l6 > > N O O 2 Q.' 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Tr N GO e CO O y a- ;71 r N N a) .` Q' O in , c.) w O C N OS a_ a € 0 O a 0 I ' STATE OF ALASKA RECEIVED ALASK .JIL AND GAS CONSERVATION COMMISSwN REPORT OF SUNDRY WELL OPERATIONS DEC 1 7 2015 1.Operations Abandon ❑ Repair Well E Plug Perforations E Stimulate ❑✓ Other ❑ AOGGC Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown 0 Perforate ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Pioneer Natural Resources Alaska Inc Development ❑ Exploratory p 9-942—21 1-0L12 3.Address: 700 G Street, Suite 600 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99501 50-703-zo(039-00-0o 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 355037 • ODSN-23i • 9.Field/Pool(s): Oooguruk-Nuiqsut Oil Pool ' 10.Present Well Condition Summary: Total Depth measured 20,550 feet Plugs measured N/A feet true vertical 6,247 feet Junk measured N/A feet Effective Depth measured 20,099 feet Packer measured See below feet true vertical 6,223 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5738' 11-3/4" 5777' 3170' 5830 psi 3180 psi Intermediate 6293' 9-5/8" 5594'-11887' 3118'-5355' 5750 psi 3090 psi Intermediate2 2595' 7" 11,494' 5174' 7240 psi 5410 psi Liner 6188' 4-1/2" 13,912'-20,100' 6136'-6223' 8430 psi 7500 psi Perforation depth Measured depth See Attachment feet True Vertical depth feet Tubing(size,grade,measured and true vertical depth) 3-1/2", 9.3# L-80,TCII 13,907' MD 6132'TVD 13928'MD/6136' 1997'MD/1763' Packers and SSSV(type,measured and true vertical depth) 5"x7"Lnr Tp Pkr TVD Wellstar TRSSSV ND 11.Stimulation or cement squeeze summary:High Pressure Break Down Intervals treated(measured): Treatment descriptions including volumes used and final pressure: See attached operation summary report 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: - - 2193 639 2635 Subsequent to operation: - - 4687 43 2300 13.Attachments: 14.Well Class after work: Copies of Logs and Surveys Run Exploratory Development❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 15.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR 0 WINJ 0 WAG 2. GINJ p SUSP❑ SPLUG❑ 16.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-447 • Contact Jack Kralick Printed Name / Jack Kralick Title Well Work Supervisor Signature f/�t�--� Phone 343-2185 Date (•ZI/3'13 �Z-3-�`f RBC/MS DEC 2 Q 2ai3c Form 10-404 Revised 10/2010 Submit Original Only Pioneer Natural Resources Alaska Inc. ODSN-23i Page 2 Form 10-404, Report of Sundry Operations Attachment - Box #10 10. 4-W, 12.6#, L-80, Hyd 521 Uncemented Liner Sliding Sleeves fitted w/ 6ea. 1/2" Holes - open @ depths listed: MD TVD 14,257' - 14,262' 6207' - 6208' Perforated Pups w/ 6-1/2" Ports @ depths listed: MD TVD 14,687' - 14,692' 6233' - 6233' 14,850' - 14,854' 6241' - 6241' 15,051' - 15,056' 6250' - 6250' 15,256' - 15,260' 6250' - 6250' 15,459' - 15,464' 6236' - 6236' 15,659' - 15,664' 6223' - 6223' 15,864' - 15,868' 6210' - 6210' 16,064' - 16,068' 6198' - 6198' 16,266' - 16,270' 6192' - 6192' 16,468' - 16,473' 6187' - 6186' 16,673' - 16,678' 6183' - 6183' 16,874' - 16,878' 6181' - 6181' 17,079' - 17,083' 6185' - 6185' 17,279' - 17,284' 6196' - 6196' 18,285' - 18,289' 6251' - 6250' 18,479' - 18,483' 6237' - 6237' 18,678' - 18,683' 6224' - 6223' 18,875' - 18,880' 6211' - 6210' 19,076' - 19,081' 6205' - 6205' 19,279' - 19,284' 6198' - 6198' 19,488' - 19,492' 6198' - 6198' 19,692' - 19,697' 6203' - 6204' 19,896' - 19,900' 6213' - 6214' 'rations Summary Report - State Well Name: ODSN-23i .P I 0 N E E R NATURAL RESOURCES Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 4/8/2013 4/9/2013 20,550.0 Fill and heat frac tanks in anticipation of high pressure breakdown.Perform general maintenance and house keeping on frac pad.Rig down 3 pumps from missile and stage on parking lot for demob. 4/9/2013 4/10/2013 20,550.0 Continue filling and heating frac tanks for HPBD.Rig down one of the 4"frac lines--we do not need 2-4"lines to pump at 25 bpm.Rig down frac tanks 1-5 due to the ice melting underneath them.Remove melted seawater from hole,dress same and fill it with fresh water and allow same to freeze.Rig up Stinger WH protection tool. 4/10/2013 4/11/2013 20,550.0 "Finish rigging up 2—bleed lines,and connect 4—frac line to goat head.PT HP line to 9,000 psi. Pressured IA to 3,500(psi).BHP @ 4,507(psi).Start pumping 20#linear gel and increased rate to 25(bpm). Pressure increased to 7,100(psi),lowered rate to 23(bpm)and SP dropped to 6100 (psi). Pumped 100(bbl)linear gel,200(bbl)20#linear gel w/.7(ppa)Carbolite 16/20,480(bbl) linear gel,dropped 14(.875")balls,repeated process a second time. Pumped 6,077(lbs)of Carbolite 16/20 before the first ball-out and 5,703(lbs)before the second ball out. 150-200 psi ball out pressure seen.Shut down due to a chicksan leaking in the frac line(ACS estimates 2-3 gal). Repair leak and re-test lines to 9,000(psi).Repeated process above 5 more times and displaced w/64(bbls)of freeze protect for frac line and well.AVG. RATE=25(bpm),ASTP= 6,709(psi),ABHP=5,711 (psi), Propant pumped=39,910(lbs),Fluid pumped=5,580(bbl) 4/11/2013 4/12/2013 20,550.0 R/D frac line and goat head.Change wellhead valves from 10K to 5K,submit well handover form,and handover well to production group. 4/17/2013 4/18/2013 20,550.0 cost placeholder for support equipment 4/20/2013 4/21/2013 20,550.0 cost placeholder for support equipment Page 1/1 Report Printed: 12/12/2013 • • �w ��l OF%% s, THE STATE Alaska Oil and Gas �� VI— em OfALASKAConservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Judy Golding Well Work Supervisor Pioneer Natural Resources Alaska, Inc. — 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-23i Sundry Number: 312-447 Dear Ms. Golding: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ��--vim--- Cathy P oerster / Chair DATED this lttday of January, 2013. Encl. • c►O'; RE VED STATE OF ALASKA ,�b DISI(16) 1• 3 ALASKA OIL AND GAS CONSERVATION COMMISSION , NOV 2 9 2012 APPLICATION FOR SUNDRY APPROVALS 20 MC 25,280 A®GCC 1.Type of Request: Abandon a Plug for Redrill a Perforate New Pool a Repair Well a Change Approved Program ❑ Suspend a Plug Perforations a Perforate a Pull Tubing a Time Extension a Operations Shutdown a Re-enter Susp.Well a Stimulate❑✓ • Alter Casing a I Other: a 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Pioneer Natural Resources Alaska,Inc. Exploratory a Development a 211-042 3.Address: 700 G Street,Suite 600 Stratigraphic a Service 0. 6.API Number. Anchorage,AK 99501 50-703-20639-00-00, 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? WA ' ODSN 231 Will planned perforations require a spacing exception? Yes a No a 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 355037 • Oooguruk- Nuiqsut Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 20,550' • 6247' • 20,099' - 6223' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5738' 11-3/4" 5777' 3170' 5830 psi 3180 psi Intermediate 1 6293' 9-5/8" 5594'-11,887' 3118'-5355' 5750 psi 3090 psi Intermediate 2 2595' 7" 11,494'-14,089' 5174'-6178' 7240 psi 5410 psi Liner 6188' 4-1/2" 13,912'-20,100' 6136'-6223' 8430 psi 7500 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment,pg.2 See Attachment,pg.2 3-1/2",9.3# L-80,TCII 13,907' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Wellstar TRSV;7"UltrPak Hyd Prod Pkr 1997'MD/1763'TVD; 12,671'MD/5690'TVD 12.Attachments: Description Summary of Proposal Q 1 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch a Exploratory a Stratigraphic a Development❑ Service ❑✓ 14.Estimated Date for v 15.Well Status after proposed work: Commencing Operations: -1/fart;/3 ?IV Oil a Gas a WDSPL a Suspended a 16.Verbal Approval: Date: WINJ a GINJ a WAG J4 Abandoned a Commission Representative: GSTOR a SPLUG a 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact July Golding,343-2179 Email judv.golding a(.oxd.com Printed Name Judy Golding Title Well Work Supervisor Prepared By:Kathy Campoamor,343-2183 SignaturePhone Date _ 4 ' L7 343-2179 11/20/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: >1 �� Z- Plug Integrity a BOP Test a Mechanical Integrity Test a Location Clearance a Other: Ha ,Vi" JAN 2 8 L004 I Spacing Exception Required? Yes a No gi Subsequent Form Required: /v — 4.0 ¢ APPROVED BY Approved by: 4.6 Tv,�_ COMMISSIONER THE COMMISSION Date: /— /6 — /3 Submit Form and ORF 13m(R1vi d 19/2012) Approved application is valid for 12 m,nths rom the date of approval. Attachments in Duplicate ?.V Pioneer Natural Resources Alaska Inc. ODSN-23i Page 2 AOGCC Form 10-403, Application For Sundry Approvals Present Well Condition Summary- Box 11 Perforation Depth (MD/TVD) Attachment 11 . Perforation Depth 4-W, 12.6#, L-80, Hyd 521 Uncemented Liner Sliding Sleeves fitted w/ 6ea. 1/2" Holes- open @ depths listed: MD ND 14,257' - 14,262' 6207' - 6208' Perforated Pups w/ 6-1/2" Ports @ depths listed: MD ND 14,687' - 14,692' 6233' - 6233' 14,850' - 14,854' 6241' - 6241' 15,051' - 15,056' 6250' - 6250' 15,256' - 15,260' 6250' - 6250' 15,459' - 15,464' 6236' - 6236' 15,659' - 15,664' 6223' - 6223' 15,864' - 15,868' 6210' - 6210' 16,064' - 16,068' 6198' - 6198' 16,266' - 16,270' 6192' - 6192' 16,468' - 16,473' 6187' -6186' 16,673' - 16,678' 6183' - 6183' 16,874' - 16,878' 6181' - 6181' 17,079' - 17,083' 6185' - 6185' 17,279' - 17,284' 6196' - 6196' 18,285' - 18,289' 6251' - 6250' 18,479' - 18,483' 6237' - 6237' 18,678' - 18,683' 6224' - 6223' 18,875' - 18,880' 6211' - 6210' 19,076' - 19,081' 6205' -6205' 19,279' - 19,284' 6198' -6198' 19,488' - 19,492' 6198' - 6198' 19,692' - 19,697' 6203' - 6204' 19,896' - 19,900' 6213' - 6214' PIONEER NATURAL RESOURCES ALASKA ODSN-23i High Pressure Breakdown Ref: Permit To Drill# 211-042 Current Status: Well is under injecting. Perform a HPBD to increase injectivity. • Scope of work: 1. MIT-IA to 2800 psi. Ensure the test is recorded on the DCS system. 2. MIRU frac tanks. Load tanks with Conoco seawater (estimate 13 tanks). Heat as needed to keep water between 60-100 degrees. 3. MIRU Halliburton frac pumps and associated equipment. 4. Rig up second swab valve and well head isolation tool. (Diagram attached) 5. Rig up treating lines to well and pressure test treating iron. 6. Tie hot oil truck into IA and pressure up IA to 2500 psi. Maintain this pressure during all pumping operations. (Based on tube move calculations attached.) 7. Pump the following at a max rate allowable to maintain the WH treating pressure below 6000 psi. It is assumed that due to the 3.5"tubing the maximum rate will be 20-25 bpm. a. 100 bbls slick water b. 200 bbls slick water with 0.5 ppg 20/40 carbolite c. 480 bbls slick water d. 20 bbls LVT with 12- 7/8" bio balls i. Repeat steps (7a)—(7d) six times ii. On the seventh and final stage do not drop the bio-balls and instead swap to 20 bbl LVT freeze protect for the well. 8. Rig down frac equipment, WH isolation tool and secondary swab valve. 9. Return well to injection. General Well Info: MASP- 6600 psi There will be a tree saver installed across the tree and set below the pupe joint attached to the tubing hanger. The tree saver is rated to 10000 psi. Based on past frac data in the Nuiqsut formation breakdown is expected at 5800-6000 psi. Reservoir pressure/TVD - 3200 psi/6205' Wellhead Type/pressure rating Vetco Inj. System/3 1/8" 5000 psi Tree configuration Dual valve tree with isolation tool installed. MIT-IA/Mit OA- MIT-IA passed 5/5/2012 MIT-OA passed 7/5/2011 Cement- The 7" casing was cemented from 11,494-14,089' using 60.6 bbls (293 sks) of 15.8 ppg Class 'G' cement with additives. The cement was displaced with 10.2 WBM. The plug bumped with 3061 strks. Subsequently the casing was tested to 3500 psi. Good test. On 7/6/2011 a Bat sonic was run from 11,675'-14,112'. No problems with cement were noted. A copy of the log is attached. Flowback- This well is an injector so there will be no flowback. Well Type- Injector Estimated Start Date- February 15, 2013 • Completion Engineer Tim Crumrine Wells Supervisor Judy Golding Work 343-2179 Cell 231-0872 judv.golding@pxd.com W l Weatherford` Completion Systems Tubing String Analysis Force: Negative implies Tension Length:Negative implies shortef Output Data Buckling Calculations are made Top(or only) Packer Middle(or 2nd) Packer ' Bottom (or 3rd) Packer Length(inches) Force(lbs) Length(inches) Force(lbs) Length(inches) Force(lbs) Piston Effect -59.14 -30,223 Does Not Apply Does Not Apply Does Not Apply Does Not Apply Buckling Effect -9.95 0 Does Not Apply 0 Does Not Apply 0 Ballooning Effect -31.00 -15,841 Does Not Apply Does Not Apply Does Not Apply Does Not Apply Temperature Effect 26.23 13,404 Does Not Apply Does Not Apply Does Not Apply Does Not Apply Slackoff Effect 0.00 0 Does Not Apply Does Not Apply Does Not Apply Does Not Apply Total -73.86 -32,660 0.00 0 0.00 0 (Force change if anchored; Length change if free to move) Maximum Tubing Stress,psi 43,905 Does Not Apply Does Not Apply Tubing safety margin Average,% 54.88% Does Not Apply Does Not Apply Force on Top Joint(initial)lbs 111,285 Does Not Apply Does Not Apply Force on Top Joint(final)lbs 113,721 Does Not Apply Does Not Apply Tbg to Packer Force(initial)lbs 0 Does Not Apply Does Not Apply Tbg to Packer Force(final)lbs -32,660 Does Not Apply Does Not Apply Slackoff Reaching Packer lbs 0 Does Not Apply Does Not Apply Delta P Across Tubing below Packer NA NA NA Delta P Across Packer(final)psi 4,618 Does Not Apply Does Not Apply Delta P Across Tubing above Packer 4,618 Does Not Apply Does Not Apply Max Wireline Tool Length(in) 317 Does Not Apply Does Not Apply Positive pressure is from BELOW the Packer Stress on Top Joint(initial)(psi) 42,964 Does Not Apply Does Not Apply Stress on Top Joint(final)(psi) 43,905 Does Not Apply Does Not Apply Burst Tendency Packer(psi) 36,361 Does Not Apply Does Not Apply Tubing Tri-Axial Stress(final) Outside(psi) 27,841 Does Not Apply Does Not Apply Inside(psi) 33,848 Does Not Apply Does Not Apply Tubing Weight(air)(lbs) 116,573 Does Not Apply Does Not Apply Tubing Weight(initial fluid)(lbs) 104,809 Does Not Apply Does Not Apply Neutral Point Abv.Pkr.(initial;ft) 0 Does Not Apply Does Not Apply Neutral Point Abv.Pkr.(final;ft) 2,644 Does Not Apply Does Not Apply Buckle Pitch(intial;ft) 0.00 Does Not Apply Does Not Apply Buckle Pitch(final;ft) 48.96 Does Not Apply Does Not Apply Helix Angle(initial;deg) 0.00 Does Not Apply Does Not Apply Helix Angle(final;deg) 0.85 Does Not Apply Does Not Apply This Program is Copyrighted January 31,2000 by Weatherford The information and results computed by this program are based on generally accepted data and physical International and embodies the proprietary and confidential information relationships described within papers presented to the Society of Petroleum Engineers. Because of evolving of Weatherford International.The recipient agrees that this Program is well conditions and other unknown information,no warranty is given by Weatherford International,expressed loaned in confidence with the understanding that neither it nor the information in it will be reproduced,used or disclosed in whole or in part or implied,concerning the results obtained from the use of this program. for any purpose except the limited purpose for which it is loaned.This Program shall be returned to Weatherford International upon demand. Sequence No 41227.6879 ver.10102001 PI 0 N E E R Current Schematic -State Well Name: ODSN-231 SIA • : SOURCES HORIZONTAL-Sidetrack 2,8/17/2011 6:08:05 PM 'Weil Attributes A)INIM Field Name Well Status Tote/Depth(ftK8) Vertical schematic(actual) 50-703-20639-00-00 Oooguruk Unit DRILLED20,165.0 ® Casing Strings Conductor,158.0ftKB Description OD(in) ID(in) Top(ftK8) Set Depth(ft...`Set Dept.. "Grade Top Connection Witten(IWO Conductor 16 14.670 47.7 158.0 H40 Welded 109.00 j . ''E Casing Components Top _ LED Item# tem Des Top(ftK8) (ftKB)) 00(in) ID(in) Comm a 1-1 Conductor Casing Joints 47.7 47 18 14.670 1-8 .. - Surface,5,777.0ftKB bescriptlon OD(in) ID(in) Top(d<8) 'Set Depth(ft.. Set Dept.. Grade Top Connection Wt/Len(bitt) ® 4-1 Surface 11 3/4 10.772 0.0 5,777.0 3,170.6 L-80 Hyd 521 60.00 i I ' rttttt�4-2 Casing Components • %.�43 Top Rw) I item I Item Des Top(ftK8) (1tK8) OD(in) ID(in) purr 2-10 Surface Casing Shoe 5,775.0 3,170.1' 11 3/4' 10.772 HES Super Seal II 2-101 Autofili FS I _ [1-16T'T'Intermediate 2 71e-back,11,493.6ftKB Description OD(in) ID(in) Top(ftK8) Set Depth(ft.. Set Dept... Grade Top Connection ?Wt/Len(Ihlrl) [1-20 7"Intermediate 7 8.278 5.6 11,493.6 L-80 BTC-M 26.00: 2 Tie bade _ 51 9 5/8 Drilling Liner,11,887.oftKB 5-2 Description OD(in) ID(In) Top(ftK8) Set Depth(ft... Set Dept.. Grade Top Connection Wt/Len(lb/ft)I 5-4 9 5/8 Drilling 9 5/8 8.835 5,594.2 11,887.0 5,351.5 L-80 HYD 521 40.001 Liner Casing Components 4-101 Top(TVD) Item# item Des Top(IIK8) (Pot8) OD(tri) ID(in) Can 11-24 - 4-1 Liner Tie Back Sleeve 5,594.2 3118 9 5/8 8.835 6 1-28 4-2 TSP4R Liner Top Packer 5,615.8 3124 9 5/8 8.835 4-3 PHS Liner Hanger 5,618.0 3125 96/8 8.835 1-331- I4-10 9-5/8"Drilling Liner Shoe 11,884.7 5,350.4 10 8.835 Ray Oil Tool Ecentric 1116 Float Shoe 1-38 I . 7"Intermediate 2 Liner,14,089,OftKB Description OD(in) ID(in) Top(((KB) Set Depth(ft... Set Dept... Grade "Top Connection Wt/Lan pont) 11-42 7"Intermediate 7 6.276 11,493.6 14,089.0 6,173.8 L-80 Hyd 511 26.00 2 Liner lin • .- 6 1 Casing Components 1-48 Top(TVD) q / Item# Item Des Top(8K8) ((PCB) OD On) i0;in) Corn 6=3 5-1 Polish Bore Receptace11,493.6 5173 7 6.276 5-2 WFT TSP5 Liner Top Pkr 11,514.5 5182 7 6.276 5-11 5-4 PHR Liner Hanger 11,519.3 5185 7 6.276 4 6-7 5-11 7"Float Shoe 14,086.9 6,173,3 7 6.278 - 6-11 4 112"Production Liner,20,100.OftKB 6-14 Description DD(in) ID(in) Top(ftK8) Set Depth(ft..'Set Dept.. Grade Top Connection WVLen fMt) 1117 6-16 4 112" 4 1/2 3.920 13,912.3 20,100.0 6,218.5 L-80 4.5 Hyd. 12.60 6-18 Production 521 '+ 11 6-20 Liner 6-22 Casing Components rt ,, 6-24 Tap(TVD)6-26 Item# am Des Top MKS) Top OD(m) 0{Fn) Com 6-1 Weatherford 16'PBR Tie- 13,912.3 6,132.7 5.77 5.250 " 6-28 back Sleeve 6-30 " 6-32 6-2 Weatherford 5"x 7"NTH 13,927.6 6,136.2 4 1/2 3.920 e6-34 Liner Top Pkr. II 6-3 Weatherford PHR Hyd.Rot 13,930.9 6,137.0 5.93 4.000 1/ 6-36 Hanger is .6-38 III 6-40 8-7 Sliding sleeve wl 6-1/2" 14,256.6 6,202.7 5.63 3.920 6-43 ports(OPEN) 6-47 6-11 Weatherford Oil Swell Pkr. 14,508.6 6,220.7 4 1/2 3.920 6-50 ,, I6-52 r ii 6-54 if 6-56 '' 6-58 r 6-60 i* ,6-62 ,, .6-64 I. 6-66 Page 1/3 Report Printed: 8/17/2011 PIONEERCurrent Schematic -State Well Name: ODSN-231 itATURAL RESOURCES HORIZONTAL-Sidetrack 2,8/17/2011 6:08:25 PM Casing Components Vertical schematic actual rap(TVD)item if ilem hes Top(ftK8) MKS) OD(in) t0(in) Can 6-14 Perforated Pup Joint w/6- 14,688.9 6,228.5 4 1/2 3.920 ® -- 1/2"Ports 6-16 Perforated Pup Joint w/6- 14,849.8 6235.8 4 1/2 3.920 1/2"Ports J1 1 6-18 Perforated Pup Joint wl 8- 15,051.3 6,245.0 4 1/2 3.920 1/2"Ports I D. 6-20 Perforated Pup Joint w/6- 15,255.6 6,245.7 41/2 3.920 1:7-11/2"1/2"Ports I 6-22 Perforated Pup Joint w/6- 15,459.1 6,231.2 4 1/2 3.920 1-121t au 1/2"Ports 6-24 Perforated Pup Joint wt 6- t - 4 3 2-1011/2"Ports 6-26 P1/2"erforatePortds Pup Joint w/6- 15,659.5 6,218.4 4 1/2 3.920 11-16 s 6 28 Perforated Pup Joint w/6- 1615,0,863.763.8 66,,193.4205.2 44 11 22 3.9203.920 S 1/2"Ports 1-20 II 6-30 Perforated Pup Joint WI 6- 16,265.7 6,187.2 41/2 3.920 1/2"Ports II I 6-32 Perforated Pup Joint w/6- 16,468.3 6,181.8 4 1/2 3.920 ,,;_..4,9r, 1/2"Ports 6-34 Perforated Pup Joint w/6- 16,673.0 6,178.8 4 1/2 3.920 1/2"Ports i i 4-10� 6-38 Perforated Pup Joint w/6- 16,873.7 6,176.5 4 1/2 3.920 1/2"Ports 11-241 �' - 6-38 Perforated Pup Joint w/6- 17,078.7 6,180.3 4 1/2 3.920 11-28 1/2"Ports 6-40 Perforated Pup Joint w/6- 17,278.9 6,191.2 4 1/2 3.920 1/2"Ports [1-331 '- 6-43 Weatherford Oil Swell Pkr. 17,485.1 6,206.2 4 1/2 3.920 1.38 _ 6 47 Weatherford Oil Swell Pkr. 17,906.2 6,235.0 5 3/4 3.920 ' 6-50 Perforated Pup Joint w/6- 18,284.8 6,246.1 41/2 3.920 11-42 1/2"Ports lin 6-52 Perforated Pup Joint w/6- 18,478.6 6,232.4 4 1/2 3.920 1-48 r 6-1 1/2"Ports 6-2 6-54 Perforated Pup Joint w/6- 18,677.9 6,218.9 4 1/2 3.920 6-3 1/2"Ports 6-56 Perforated Pup Joint w/6- 18,875.3 6,207.6 4 1/2 3.920 5-11 1/2"Ports 6-7 6-58 Perforated Pup Joint w/6- 19,078.4 6,200.4 4 1/2 3.920 6-11 1/2"Ports 41 6-14 6-60 Perforated Pup Joint w/6- 19,279.2 6,193.0 4 1/2 3.920 6-16 1/2"Ports I. f 6-18 6-62 Perforated Pup Joint w/8- 19,487.8 6,193.4 4 1/2 3.920 " 1 6-20 1/2"Ports • 6-22 6-64 Perforated Pup Joint w/6- 19,692.3 6,198.5 41/2 3.920 . 6-24 1/2"Ports •• 6-26 6-68 Perforated Pup Joint w/6- 19,895.8 6,208.8 412 3.920 •• 6-28 1/2"Ports • 6-30 6-68 4.5"Liner Shoe 20,098.7 6,218.4 Weatherford(solid) •• 6-32 Eccentric Shoe 6-34 Tubing Strings Ili. 6-36 Tubing Oesaiption String M... 10(in) Top(f1103) Set Depth(f, 'Set Dept..W1(1b$1) Grade Top Thread 6-38 3.5"completion 31/2 2.992 0.1 13,907.3 6,131.5 9.30 L-80 TC-II •• 6-40 Tubing Components `' ,47-43 item# item Des Top(fJKB) T (two) OD(in) ID(41) Gem a 6-57 47 1-2 Vetco Gray Hgr with MAC 34.1 10 2.950 box x TC-II box 13/16 • X6-52 - •. 16.54 •• i656 •••• •58 6-60 • X662 •• 6-64 •• 6-66 Page 2/3 Report Printed: 8/17/2011 PIONEERCurrent Schematic -State Well Name: ODSN-23i NATURAL RESOURCES HORIZONTAL-Sidetrack 2,8/17/2011 6:08:45 PM Tubing r±omponents Vertical schematic(actual) Top(TVD)em# tam Das Top(hK8) NK8) 00(In) f6(n) CCM 1-8 HES Wellstar TRSV 1,997.2 1762 5.2 2.813 1-2 ---*- - w12.813"X"profile 3.5"TC- II b 1-12 Vanoil 3.5 x 1.5 MMG GLM 2,496.5 2020 5.968 2.920 w/3.5"TC-II bxp J 1-1 1-16 Vanoll 3.5 x 1.5 MMG GLM 6,602.5 3439 5.968 2.920 w/3.5"TC-II bxp El 1-20 Vanoll 3.5 x 1.5 MMG GLM 9,865.1 4545 5.968 2.920 ' r w/3.5"TC-II bxp }1-121 - t l 1-24 HES ROC gauge mandrel 12,540.3 5,632.9 5.664 2.965 t ' �� TC-Il bxp Jm 1-28 HES 2.81"X"Nipple 3.5" 12,588.5 5,652.6 3.96 2.813 TC-II bxp 9 Cr 2-101 1-33 7"WFT Ultra Pak Hyd 12,671.4 5,686.3 5.865 3.937 Perm Prod Pkr }1-16 asa I 1 1 1-38 HES 2.81"X"Nipple 3.5" 12,724.6 5,707.6 3.96 2.813 }1-20 TC-II bxp 9 Cr 1-42 HES 2.81"XN Nipple 12,802.1 5,737.8 3.94 2.750 ti I w/2.75 No-go wl RHC-m 4.41E1 plug In MI 1-47 Locator collar 13,897.5 6,129.2 5.8 3.958 1-48 5"seal stem w/o seals WI 13,898.5 6,129.5 5.2 3.958 1 Indexing mule shoe 4-101 }1-24} �.�' 1-28 }1-331 I. 1-38 1-42 I 1-47 11 I 1-48 6_1 ,6-3 • 5-11) 6-7 6-11 6-14 1 6 -16 i 116-18 ' ?6-6-2220 6-226-20 • 6-24' elm • 6-26 UM 1 • '/&3° impi ,,6-32 m 6-34 Im . ,16.36 6-38 a 6-40 6-43 6-47 6-50 a if 6-52 SIMmil �6-54 f 6-56 i /6-58 asst p 6-60 ,6-62 1111.1. -6-64 solo a -6-66 Page 3/3 Report Printed: 8/17/2011 OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) FRAC IRON CONNECTION ,L1 AA-- . i : t t ...vt, ..:- • r t I ,� • Remote Valve "" ,REMOTE OPERATED •••••• I from center 28" e'"'^• MASTER VANE ill illp. ilk iO� IMANUAL OPERATED ` NO, I E MASTER VALVE /a � �\\ ` 128"total •✓' Tool Width t�0�1 length ii �/ 32 �0 212"total length „ o `� �/ in open position Stinger ( Stinger , Bottom of remote valve to bottom of +nANDRI I II wellhead flange 59" ,.y 11 MIL= Bottom of manual • vI NT valve to bottom of _I — 6"Greyloc- - •a r� �Fti 41/16 wellhead _♦vIlli /r 8" MIL= - ,; flange C . FLOW TEE AND 4'A Setup f,"' Min Vt. VENT VALVE length 18" WELLHEAD ii IiU VALVES /me7 i. OPEN Mt WELLHEAD r VALVES CLOSED ' �r` I : . ' l1. c; ::; !e. = � QUAD PACKOFF • . ' ASSEMBLY IN r II..tt PLACE W TUBING 4T :;:z„.." I `�' TUBING 0"19.4 1 r. 1 --.] Universal Tool and Box 10,840 lbs (184"L X 49"W X 43"H) Hydraulic Power Pack 2500 lbs ( 61"L X 61"W X 53"H) PIONEER NATURAL RESOURCES ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel (907)277-2700 Fax:(907)343-2190 January 5, 2013 Mr. Guy Schwartz State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 RE: Submission of Fracture Modeling Study Data Attached please find the results of the fracture modeling studies performed by Pioneer Natural Resources Alaska, Inc. subsequent to our discussion of December 17, 2012. Fracture modeling studies were completed for both the Nuiqsut and Torok reservoirs, and all data studied has been included herein. If you have any further questions or comments, please do not hesitate to contact me. Sincerely, i'!'IryR�yy� Tim Crumrine Senior Staff Completion Engineer Attachments: Fracture Modeling Study— Nuiqsut Fracture Modeling Study-Torok Pioneer Natural Resources Inc.Alaska Asset Fracture Modeling Study-Nuiqsut Background The Alaska Oil and Gas Conservation Commission (AOGCC) has requested that fracture modeling is conducted on the Nuiqsut reservoir to determine height growth. Height growth of the induced hydraulic fracture is an important parameter to determine whether the fracture grows beyond the defined oil pool confining sedimentary rock layers violating pool rules (Oooguruk-Nuiqsut Pool) or Area Injection Order 034 in order to ensure protection of surrounding reserves. Pioneer has contracted a third party, Barree and Associates, LLC to conduct the fracture modeling study using the software program GOHFER. A meeting was held on December 17, 2012 at the AOGCC office in Anchorage, Alaska with AOGCC representatives, Chris Wallace, Guy Schwartz, Patricia Bettis, and Steve Davies, and Pioneer representatives Tim Crumrine, Andy Bond, Pat Foley, and Vern Johnson. The meeting discussion centered on conducting a fracture study that would be inclusive of all potential fracture stimulation rates and pressures, so that each individual well would not be modeled, but instead one model could be built in which the rates and pressures would exceed the capabilities of fracturing equipment hydraulic horsepower on location at the time of the fracture stimulation. This study is intended to cover all hydraulic fracture stimulations in the Nuiqsut oil pool, propped and unpropped (often referred to as high pressure breakdowns) in either producing or water injection wells. The following sections discuss the model input assumptions and the results from the induced hydraulic fracture study. Model Inputs and Assumptions Nuiqsut producing wells will be stimulated with two-million lbs of 16/20 mesh Carbolite ceramic proppant with approximately 200,000 lbs per stage for a total of 10 stages. Each producer well completion is set up to be mechanically or dynamically diverted, with some wells having a combination design. The greatest likelihood for a fracture to grow out of its confining intervals comes from a well with a vertical wellbore and a limited entry single perforation near the top or bottom of the interval being stimulated. Pioneer Alaska's wells are horizontal wells with multiple entry points that are landed in the middle of the zone. Essentially fractures in this type of wellbore are much less prone to fracturing out of zone. Each stage will contain approximately 200,000 lbs of 16/20 mesh Carbolite ramped from 0.5—10 ppa concentration with a 25 ppt cross-linked borate gel. The hydraulic horsepower on location during a fracture stimulation is approximately 12,000 HHP — based on anticipated pressures and rates. This equates to a rate limit of 60 barrels per minute based on expected pressures. Rates for the fracture modeling study were set at a limit of 80 barrels per minute: well above the available hydraulic horsepower on location. High pressure breakdown/scour treatments will be performed on injector wells with no more than 20,000 - 50,000 lbs of 20/40 mesh Carbolite proppant per stage. The injector well completions have smaller upper completions that limit the rate to 25 barrels per minute and are dynamically diverted. The fracture model geological input parameters were based on the Kalubik-1 well log data. Log data from the Kalubik-1 well were processed to derive rock mechanical properties and a stress profile for the fracture growth modeling. Based on previous MDT/RFT measurements, the pore pressure in the Nuiqsut was assumed to be on an effective 0.51 psi/ft gradient. No tectonic boundary conditions were applied to the stress profile. The Nuiqsut zone is shown in the figure below by the blue box. The two arrows indicate the upper and lower landing positions assumed for the modeling. These two fracture initiation sites are expected to represent any landing point in the zone. Kalubik 1 Processed Log Summary ....„, , , ., , MINI �1 , ' .. ' 6300 00 .. -- 6325 00 `— '` 1. — , �i ■� 6350.00 ,� ■� � �'..••' 7:ket:::::. ....,.:: - -, i-- . - -- - 6375 00 i W. �_—_._ _ __� :: _..__ ,; __,_ - __-_ _ '. 64©0.00 --- ; _ _ - Nuiqsut - •'*'.i: ---- 6425.00 -..... - - - -r1-. �• _ 6450.00 ta.y�s-'•':'•:•:.:•:-.,e.: 6500 00 • . _ _ ..... _.._ '• '� Nechelik c '3— , r 6525.00 ":7----...--. — l_ - . ' 65500 • ` - _ --'i`-��L. —= 6575.00 - - • • �--=MIMS 6660.0D -'— ==.-„.-::: • 6625 00 N ... t 2012V1/4't. --- ._ 6650.00 .14--_ �-� -- -__=-.�.:,___.._--- =---,.._ ...�, Figure 1. Kalubik-1 Processed Log Summary Modeling Results The proppant profile (side view)of the created vertical fracture in the upper part of the Nuiqsut is shown in the color-filled plot below. See Figure 2. The scale is 0-3 lb/ft2,shown at right.The fracture stays contained in the Nuiqsut at a maximum 80 bpm pump rate. A near-well concentration of 2-3 lb/ft2 is established,with a propped half-length of 300 feet.Vertical node resolution is 5 feet in the grid. .,._�•-z: g iiHi=[p[pi�e .:: [l` tae ` ix�:Co�«,e rw.�a e•� 'ems' ai • -: :i _wbc-• t xe r..aa3wver..Gir1 n. ..a ro •.ra. •w n •rear •••par. r• wr . '1 • snsseess se is sI II sa • imp _::: . Les::: iliiiscp ' :: sleasssseas - •phi! ee ape s�e linin 7 oes t in a ^_.4 it hil a...u■ ur u■ ■'� .f -' ■w ■if w .r■ p.r..a snap • g•asaa L s p , .e e , .. ;. - `_.. :Ea nui =aeasem" i■ghee 8 i t:I s ; r . .se E . .e i 4 ,- :-.1 ;::::,:.,, :r,: . .....,`. �easL:=LL:r.:s::EE III: L t-E ; BEL , *EesuLLigee s: f r "•'''" "-;:CL+.+,e:E owns p L:Li n iiil ••� EEii•q Y.`� ■a�■ar�a w� .,l.T ..::a - ` `.ate sfLe ELI. ., iiitirmie . ••— •v- a ::e '_ sin E sps::: ffiiiiii ,::ca :.• r w ■r..■••••:0'LL _4. L ea •li • aw f, : '� , .::.CELL ': .s - a :Miff 3337_.IIu. —32 J ■• dim �s•s ' 1ss E Jim r ........... e�r1 •t • ■••rr "� e•a f ::a PEW! IEEE.; It EsiiN�,r•sssibusiesi ?BR:* - Ir.. ,. 1 r i I I am t-r a E E ss. a.aatlilli Re L::aaaai 1. .. : ua .li -...-_-:--447.4v; r ' e s a a•gaa.aa is ,aaeacas,,,, •�iIlgala--- ::.tee a aspens aeaiaa saes: iu i a1•a`ae ssesaaeSisassssaaseae gi 411 MM.R HIES�iiahiffiEdiee ai E ill iaaisre■ 'iicEMilm •.- ', e:;. ,LLL. .f..;;• ' ■IeE■'ii:y l�■EEI�I r FL! a... • . Ear + - Year.. �'Ky'.� i iL•■■nha sell sLL:Cgirl�shIllLisst s�:a�i*:LLenislal seirrifiiLe . I `•NEM = _7-2 ! •hie .e an.im F, • 3Ua. ii• w.,s:aa�ru t-�.;,.it aiw,rr.pitint '..gyp .� . s:I nip ■ii a 1 I:•• gq a i essei-. -, 1!E I: 1 ..•P ! '�. s "Y in �e i 11 i � :l ill i 111 IR -•-▪ •-v-:-. '1111111111V Lirr . L9 �i LLC _" r�i ri�'i��., L. LrEi -- _ ll l lal. f �1llt. !1J!1 . ' ll! i': i LeeiiiiiiiiiiffiriLLeeL:ionH LL y{,7"" •: Minn• ..,..`.r "ii pC «'L.. C 2012 I.lt Figure 2. Proppant profile in the upper Nuiqsut Figure 3 is the proppant profile of an additional modeling run with the fracture initiated in the lower part of the Nuiqsut. As in Figure 2,the scale is 0-3 lb/ft2 with a vertical node resolution of 5 feet.The fracture stays contained in the Nuiqsut at a maximum 80 bpm pump rate. i :.i • : R ETi1=:Er::Ei: r::::~-::•r,�+,.ri■/ CC 11.21-11iiig i ■iii..:N•: .•.:• ..•r rerr. Er•.. .. •..:t r • _ ;_ t • ..r. �1.i:::::i:.:: e=tJ ....i:=ee ::eeit::ai:: e::- fat•: a F • . -1 , •..�:::aa:�•:fl u a"� - .....nIt 7111:10;135 r�I -4-11 . - e en.. — V • e1:•:::"1121 :x I i'�•a•••• 'I; ial"-. . L •rii 11 I r• • ani • N C-.•• ' Illiiiitfhth llhae inisdlhith__f iim'ii ai ;s fI� -11-„ . _ C. ;. '.. ae .:: :a:zta=Ipt:a:e:rtet 1. `ia ' .: }� .. :...i.e t i�ttE�aL tae ieeee • _ :a:i: ataaataai aaiitit alaeaa aaiaai iiia ...... 7-F •. ::::: :e::::::Iaa: ::aa till. 1a: • -a aeaaRl tae: xM :F -..:::::::: 1ee�iina ii nett :sat s:ai � ;:� '•``•:::::a- "!:aa:altgt-:::shun �. UMUl III "" -4' a a - aaa as a I R:ia ese: Wig ii = i .i. iaiui iaanit:tt `. a ..1-gr S tI a i pt iaaasa I It I i_ , , o a :C .,c,;:,,, _IIU i 1 I R 1 I? : E t i l I .:•; - Ita iIIIIII iiiaen t iii i ! .� _ ..i sal �_ ata:aa �., : a1 AI1atK I e t a I , :- d-y teatR j �:•: lig ailaanatia:Ra:L 5:111 '.'4_,..!_;44" i _ ,,aia f ii:RR 1a : •:, tj r t 11:1111 >t Illy a 1:i I- -,. .R i` v . i / a ai tR :� 11 I !:t Ra tat i�11a :+ t b» y ,,.,_"/'' a z:: `a4tit�ta :: aiiiia t ama::aat r• , :. -- :-IA it Ei _.— i Pk Willi a1 ii t RR:RtiaR ::: I _ e,}<,. ---W R i i 1 t R t1t R1 t .. :: 1.. . Y_.- ` II!! I :: : i ==#R i :1:.{: : ' i 7 a 1_ as 112 ' iiaiiip s mg Ra ii=i 1Si�,C=C�ia:US :i; i I :i :i77_`' - _ to a ' : . :ppaa:RaaaS 1 i:M:a : "•••r::.::U : ra C •Ahatill22- MLC iiii � 1 ::::r:::::1ai::: ::: ::::::: :.::n :. r=. .:a:-r ::i i:::ii:e a .. a: a •r.rre.,EE:a:=�.• .0 1 �-.a i ..a _Y. 'S 3,.a • ■.0 a r•r�_ rim r• .u!�'' �..'_� = ietc._..__ -"«>t7 ;Welk©2012 + Figure 3. Proppant profile in the lower Nuiqsut Conclusion Kalubik-1 well log data were processed to derive rock mechanical properties and a stress profile for the fracture growth modeling in the Nuiqsut reservoir. Two fracture initiation points were examined: one in the upper and one in lower sections of the Nuiqsut formation. A schedule placing 200,000 lbs of 16/20 CarboLite was run at the "worst-case" for height growth of 80 bpm. The current limitation for the maximum rate is based on the available horsepower on location. In either initiation point the fracture height is contained to the Nuiqsut at the maximum specified rate of 80 bpm. The most likely avenue for height growth is downward to the Nechelik, and this is not predicted to occur under any planned treating conditions. All treatments conducted below the maximum specified rates, pressures, and proppant concentrations are considered a subset of the models presented here in the study. Ferguson, Victoria L (DOA) From: Crumrine, Tim [Tim.Crumrine©pxd.comj Sent: Wednesday, January 02, 2013 1:05 PM To: Wallace, Chris D(DOA); Schwartz, Guy L(DOA); Ferguson, Victoria L(DOA) Subject: Pioneer Nuiqsut and Torok Frac Modeling Studies for the AOGCC Attachments: FracStudyTorok.docx; FracStudyNuiqsut.docx Dear Chris, Guy and Victoria: Attached are draft copies of the Torok and Nuiqsut fracture modeling studies discussed Dec. 17, 2012. Please review and comment. If acceptable, I will draft final copies for submission to the state. Sincerely, Tim Crumrine Office: 907-343-2184 Cell: 907-240-4295 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. 1 Ferguson, Victoria L (DOA) From: Golding, Judy[Judy.Golding©pxd.com] Sent: Thursday, December 06, 2012 3:05 PM To: Ferguson,Victoria L(DOA) Cc: Schwartz, Guy L(DOA) Subject: RE: ODSN-23i(PTD211-042, Sundry 312-447)ODSN-26i(PTD 211-121, Sundry 312-449) ODSN-32i(PTD 208-004, Sundry 312-450) Attachments: Nuigsut buffer.judy.pdf.pdf Please find the requested map attached. We put both the HPBD and frac wells on the map. If you have any other questions don't hesitate to give me a shout. TTFN me From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.govl Sent: Wednesday, December 05, 2012 1:02 PM To: Golding,Judy Cc: Schwartz, Guy L(DOA) Subject: ODSN-23i(PTD211-042, Sundry 312-447) ODSN-26i(PTD 211-121, Sundry 312-449) ODSN-32i(PTD 208-004, Sundry 312-450) Judy, For each of the three subject water injection wells to be fracture stimulated could you please provide a map showing wellbore penetrations within 1/4 mile radius. Thanx in advance, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson a(�alaska.gov This email was sent on 12/6/12 at 3:05 PM by goldingj. 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 E (13 wU O ILLIEY co cc Q (/) in a., z 0 — Oin — N O — O _/ —`--- _ ---------- i �3c _ l 0 J Z• I • Z N �• N Y , 0 0 e � N W U) W'� O. I ./ Z I I 0 0 ; , ." N N 0� O z• 4 * 1 0 o Zop 0 to N N OZ N • r (n co O N Q u) u)• 0 0 O O N 0 C N iii ++ < m � CC =N 0 Z- 9if ------•=..4- 'Z E d) A 1___ _ CC �cCJcdr��-lG ODS;:,—Z3 1 Tb ZI I o4z o Regg, James B (DOA) From: Brooks, Phoebe L (DOA) Sent: Friday, June 01, 2012 9:15 AM 4 � ( 17/ To: Williams, Theresa Cc: Regg, James B (DOA) Subject: RE: ODSN-23 MITs PTD 211420 Attachments: MIT ODSN-23 05-15-12 Revised.xls; MIT ODSN-23 05-05-12 Revised.xls Theresa, Attached are revised reports for MIT ODSN-23 05-15-12 and 05-05-12. Both reports now reflect"P" for the Type test and the 05-15-12 casing was changed to 230 based on the inspector's report; the notes were also revised to reflect post- injection. Please let me know if you disagree. Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: Williams, Theresa [mailto:Theresa.Williams(apxd.com] Sent: Thursday, May 31, 2012 2:36 PM To: Regg, James B (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay; Schwartz, Guy L(DOA) Cc: Williams, Theresa Subject: ODSN-23 MITs PTD 211420 Attached are the pre-and post-MIT lAs for conversion to injection. The pre-injection MIT was started above the minimum 1500 psi, but finished at less than 1500 psi. From a pressure loss perspective the test met the test criteria, but with a final pressure below 1500 psi it did not pass. It was communicated to me the well had passed the MIT IA at the time it was preformed, but I didn't review the data until I was putting together the forms for submittal. Had I known about the final test pressure prior to putting the well on injection I would have requested another test at a higher pressure. This isn't possible now, but I have changed our testing procedure such that 1800 psi will be our minimum test pressure. Please let me know if you have any questions. In regards to the 10-404, I was told the form has been completed and should be in your office by COB tomorrow. Regards, Theresa Williams Staff Operations Engineer Pioneer Natural Resources Alaska (907)343-2104 Office (907)382-3596 Cell (907)670-6514 OTP Office 1 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 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Jim Regg / DATE:Thursday,May 31,2012 TO: �1- 6 P.I.Supervisor '1I(I v SUBJECT:Mechanical Integrity Tests l PIONEER NATURAL RESOURCES ALASK ODSN-23 FROM: Matt Herrera 000GURUK NUQ ODSN-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name 000GURUK NUQ ODSN-23 API Well Number 50-703-20639-00-00 Inspector Name: Matt Herrera Permit Number: 211-042-0 Inspection Date: 5/15/2012 Insp Num: mitMFH120515171520 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ODSN-23 - Type Inj w TVD I 5686 , IA 230 1804 , 1761 1749 - PTD 2110420 - Type Test SPT Test psi! 1500 OA 25 I 30 30 30 - 1 Interval IINITAL ' P/F ! P v Tubin 864 866 867 868 - Notes: Thursday,May 31,2012 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test �, eC "� Submit to: jim.reoa@alaska.gov; doa.aoacc.prudhoe.bavt alaska.gov; phoebe.brookst alaska.aov; tom.maunderAalaska.gov u OPERATOR: Pioneer Natural Resources �f` FIELD/UNIT/PAD: Oooguruk `l L'/4/ DATE: 05/05/12 (((�/ OPERATOR REP: Marvin Zimmer AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ODSN-23 • Type Inj. W ' TVD ' 5,690' Tubing 949 1,008 1,017 1,014 Interval 1 P.T.D. 2110420 ' Type test P Test psi - 1,500' Casing 812 '1,515 -1,480 "1,472 P/F F - Notes: Pre-injection OA 19 18 19 19 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD TubingInterval 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 ODSN-23 05-05-12 Revised STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.rega@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov' phoebe.brooks@)alaska.00v' tom.maunderftalaska.gov OPERATOR: Pioneer Natural Resources FIELD/UNIT/PAD: Oooguruk 1f '7131 I v DATE: 05/05/12 OPERATOR REP: Marvin Zimmer AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 r in. 45 Min. 60 Min. Well ODSN-23 , Type Inj. W TVD ` 5,690' Tubing 949 1,008 1,017 1,014 Interval 1 P.T.D. 2110420 ' Type test ,.MV Test psi '1,500' Casing 812 '1,515 1, .0 1,472 ✓ P/F F Notes: Pre-injection f OA 19 18 19 19 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing _ P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casin. P/F Notes: '•A Well. Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing _ P/F Notes: OA Well Type Inj. TV', Tubing Interval - • P.T.D. Type test =st psi Casing P/F - Notes: OA TYPE INJ Codes PE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) MIT ODSN-23 05-05-12 " \k / f 2 .Q \ "' 4) &2 k ?2 Q § 2 - 8 8 S a } e 2 Q \ 2' ry kg \ 04 I 11.- C.1 a 0 I \ 0 ■ &'- & a =) [ .. ƒ \� 3 e , " a }\\\\4- s )- E L §22a»\§ 4 { L | ` 5 - E \I \ | § / mi r 71 \ \ \/ ^\§&)§\ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION CC;Ce -C9f'd Mechanical Integrity Test r"C I�f_ Submit to: jim.reaq(CDalaska.cov doa.aogcc.prudhoe.bay@alaska.gov; phoebe.brooksaalaska.aov tom.maunder(rtalaska.00v OPERATOR: Pioneer Natural Resources 6w �� FIELD/UNIT/PAD: 000guruk DATE: 05/15/12 OPERATOR REP: Bill Christopher AOGCC REP: Matt Herrera Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. Well ODSN-23 ' Type Inj. W TVD '5,690' Tubing 865 866 867 868 Interval l P.T.D. 2110420 ' Type test P ' Test psi "1,500' Casing 230 - 1,807 1,761 -1,748 _ P/F P Notes: Post-injection OA 29 30 30 30 Well Type Inj. TVD TubingInterval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi ,Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) MIT ODSN-23 05-15-12 Revised • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa alaska.aov• doa.aoocc.orudhoe.bavaralaska.00v phoebe.brooksaalaska.aov. tom.maunder(rDalaska.gov OPERATOR: Pioneer Natural Resources �"�y/It FIELD/UNIT/PAD: Oooguruk ` ( ` 4141 DATE: 05/15/12 OPERATOR REP: Bill Christopher AOGCC REP: Matt Herrera Packer Depth Pretest Initial 15 Min. 30 Mi . 45 Min. 60 Min. Well ODSN-23 Type Inj. W TVD 5,690' Tubing 865 866 867 ;68 Interval l P.T.D. 2110420 Type test Test psi 1,500' Casing 1,057_' 1,807 ' 1,761 1,748 ' P/F P Notes: P P OA 29 30 30 30 ln1olleC-4' r Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing- P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD T .ing Interval P.T.D. Type test Test psi rasing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitorin. I=Initial Test G=Gas P=Standard Pressu=Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radio- tive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature•nomaly Survey T=Test during Workover W=Water D=Differential Temperature Test 0=Other(describe in notes) Form 10-426(Revised 06/2010) MIT ODSN-23 05-15-12 ./ &� k °d 9 z §s 0 \ / S L. . . -4t.., \_ q $ _)2 I / C Q _,t� - K \ j\ / . O k of � W S Jr- ._cri A § ° ■ \ I in me § _f E. [ ms - - - §\ cri } \ -/\ - £ $#{ ))§ 777®If@ a 5»-a a7- } a f/ f/ co ct )§ , ' �)( ',\ \ k §NI } 32 • m \°S/\I 6 ' • STATE OF ALASKA RECEIVED ALA .OIL AND GAS CONSERVATION COMMI..-,ION JUN 01 2012 REPORT OF SUNDRY WELL OPERATIONS n 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other LAQ Dnjector Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Pioneer Natural Resources Alaska, Inc Development 2 Exploratory❑ '' 211-042 3.Address: 700 G Street,Suite 600 Stratigraphic Service ❑ 6.API Number:.. Anchorage,AK 99501 50-703-20639-00-00 _ 7.Property Designation(Leal?Number): • 8.Well Name and Number: ., ADL 355036/ADL 355037 ODSN-231 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Oooguruk-Nuiqsut Oil Pool 11.Present Well Condition Summary: Total Depth measured 20,550 feet Plugs measured N/A feet true vertical 6247 feet Junk measured N/A feet Effective Depth • measured 20,099 feet Packer measured see below feet true vertical 6223 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 5738' 11-3/4" 5777' 3170' 5830 psi 3180 psi Intermediate 1 6293' 9-5/8" 5594'-11,887' 3118'-5355' 5750 psi 3090 psi Tie-Back 11,450' 7" 11,494' 5174' 7240 psi 7240 psi Intermediate 2 2595' 7" 11,494'-14,089' 5174'-6178' 7240 psi 7240 psi Liner 6188' 4-1/2" 13,912'-20,100' 6136'-6223' 7500 psi 8430 psi Perforation depth Measured depth See Attachment,pg 2 feet True Vertical depth feet Tubing(size,grade,measured and true vertical depth) 3-1/2",9.3# L-80,TCII 13,907'MD 6135'TVD Wellstar TRSV @ 7"UltraPak Hyd Prod Packers and SSSV(type,measured and true vertical depth) 1997 MD/1763'TVD Pkr @ 12,671' MD/5690'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 358 117 0 687 268 Subsequent to operation: 0 0 0 563 1568 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory Development❑ Service ❑✓ Stratigraphic ❑ 1 Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG 2 GINJ ❑ SUSP❑ SPLUG❑ 17.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: 312-011 Contact Tim Crumrine Prepared By:Kathy Campoamor,343-2183 Printed Name Tim Crumrine Title Sr.Staff Completions Engineer I Signatu „ow' _ Phone 907-343-2184 Date 5/29/2012 Form 10-404 Revised 11/2011 %DMS JUN 04 m0112 C " 6/41/2- Submit Original Only 1/LP Pioneer Natural Resources Alaska Inc. ODSN-23i Page 2 AOGCC Form 10-404, Report Of Sundry Well Operations Present Well Condition Summary - Box 11 Perforation Depth (MD/TVD) Attachment 11 . Perforation Depth 4-'/2", 12.6#, L-80, Hyd 521 Uncemented Liner Sliding Sleeves fitted w/ 6ea. '/2" Holes - open @ depths listed: MD TVD 14,257' - 14,262' 6207' - 6208' Perforated Pups w/ 6-1/2" Ports @ depths listed: MD TVD 14,687' - 14,692' 6233' - 6233' 14,850' - 14,854' 6241' - 6241' 15,051' - 15,056' 6250' - 6250' 15,256' - 15,260' 6250' - 6250' 15,459' - 15,464' 6236' - 6236' 15,659' - 15,664' 6223' - 6223' 15,864' - 15,868' 6210' - 6210' 16,064' - 16,068' 6198' - 6198' 16,266' - 16,270' 6192' - 6192' 16,468' - 16,473' 6187' - 6186' 16,673' - 16,678' 6183' - 6183' 16,874' - 16,878' 6181' - 6181' 17,079' - 17,083' 6185' - 6185' 17,279' - 17,284' 6196' - 6196' 18,285' - 18,289' 6251' - 6250' 18,479' - 18,483' 6237' - 6237' 18,678' - 18,683' 6224' - 6223' 18,875' - 18,880' 6211' - 6210' 19,076' - 19,081' 6205' - 6205' 19,279' - 19,284' 6198' - 6198' 19,488' - 19,492' 6198' - 6198' 19,692' - 19,697' 6203' - 6204' 19,896' - 19,900' 6213' - 6214' PI 0 N E E R 1perations Summary Report - Sta- Well Name: ODSN-23i NATURAL RESOURCES Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Job Category WELL SERVICE Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 4/28/2012 4/29/2012 20,550.0 MORU Halliburton Slickline Equip.PT lubricator to 1000 psi.MU GS tool&Catcher. RIH t/12,746'SLM.String pulled tight.Jar&work tools free.PU hole w/150#over-weight.PUH& string weight dropped off above Sta#1 @ 9,844'.Con't OOH.Break out tolls&inspect same. Noted metal marks on GS tool&catcher.Secure well&SDFN. 4/29/2012 4/30/2012 20,550.0 RU&dress jars.MU 2.80 Gauge ring&PT lubricator to 1000 psi.RIH&tag XN Nipple @ 12,798'SLM.POOH.MU GS Tool&Catcher.RIH&set in XN Nipple @ 12,798'SLM.POOH. Shot FL on IA-7840'.RIH w/OM-1 &set down @ 9,862'SLM.Jar 1 lick came free&POOH.No Valve recovery.PU 1.73"LIB&RIH.Jar down 1 time @ 9,862'SLM.POOH.Inspect LIB.Good impression of China Cap on Latch. RIH W/OM-1 Locate&jar down 5 times on latch @ 9,862' SLM. Hit down w/OJ 1 time,came free.P00.1:1&recovered valve.Inspect same,Had 4 pcs of packing damaged.Redress valve.Secure well.SDFN. 4/30/2012 5/1/2012 20,550.0 PT lubricator.RIH w/OM-1,RK-1 Dummy Valve.Set down in Station 1 A 9,861'SLM.Set valve in pocket.Draw down IA 50 psi to 905 psi.(Tbg 750 psi).Shear off w/o pressure change.POOH, valve gone,Upper&lower arm sheared.Secure well.LD equip.W/O MITA of IA. 5/1/2012 5/2/2012 20,550.0 Fill annulus w/diesel.Pressure up to perform MITA.Pressure broke @ 3200 psi-went to 0 psi. (Tbg Press 760 psi).RD& secure well. 5/2/2012 5/3/2012 20,550.0 Rig up Lubricator,RIH XXN plug w/nuckle Jt,could not pass thu X nipple at 12,640'RKB. POOH,remove nucke jt and add 5'extra weight bar,RIH...Job in Progress. 5/3/2012 5/4/2012 20,550.0 Continue in hole XXN plug,tag up XN at 12,800'RKB.Set XXN plug in XN after trying for—45 minutes.POOH,plug gone:Purair3t7bbl diesel down tubing,shut down pumping because it appeared that plug not holding.After determining that plug was holding,33.4 bbls of diesel were pumped down tubing.The IA tracked the tubing pressure.Shut down pumping and MU&RIH 3.5"OM-1 tool&pull OV from GLM @ 9,844'SLM.POOH,retrieve OV.Bottom set of packing on OV was gone an3upper set was damaged and valve had scratches on the side of it.Rig up to pump down IA,perform CMIT to 1500 psi,it lost 34 psi in 1st 15 min and 15 psi in 2nd 15 min. MU&RIH new OV,attempt to set in GLM,could not get valve to set and latch in GLM.POOH, examine OV.It also had scratch along the side,and appeared that it was not going in far enough to latch.Shut down for the night 5/4/2012 5/5/2012 20,550.0 RU and RIH with Pocket brush with tattle tails,locate and brush pocket,POOH.RIH with OV attempt to set OV in GLM,after trying for 30+minutes POOH to inspect tools.Change the the tool orientation of the tools,RBIH.Locate and set OV @ 9 844'SLM.Before shearing off, perform drawdown of 100 psi on IA,test OK.Shear off POOH,shut down for night waiting for P6 pump to be available to pressure test IA. 5/5/2012 5/6/2012 20,550.0 Perform MITIA to 1500 psi, 15min 1479 psi,30 min 1471 psi.RIH and plug Prong from Plug, RIH with With GR pulling tool,Tool sheared POOH,RIH with GS tool sheared,POOH,MURIH 1.25 bailer,nothing recovered.Pin GR with steel pins RIH. Job in progress. 5/6/2012 5/7/2012 20,550.0 Latch on plug attempt to pull plug until sheared.POOH,Shut down for the night.Change out Slickline unit with another unit that has.125"wire.MU&RI GS and latched XXN plug @ SLM Jarred for 1/2 hr,sheared POOH,MU RIH with 2.5"hydrastatic bailer,Jarred down,No Tubing pressure change.POOH,Bailer is sheared but empty,RINGS w/X equalizing prong.Latch plug and jarring.Job in progress. 5/7/2012 5/8/2012 20,550.0 Shear of POOH,shut down for the night.start up by adding more weight bar RIH and latch on and start jarring.Sheared of POOH,redress tools,RBIH.Pressured tubing up to 1000 psi,tubing bled down to 600 psi,pressured up a 2nd time and pressure herld,started jarring,Sheared, POOH redressed tool and discussed with Halliburton some different options on pulling the plug. Made another attempt to pull plug with no success.Sheared off,POOH.Shut down for the night. Page 1/2 Report Printed: 5/24/2012 PI 0 N E E R 1perations Summary Report - Sta Well Name: ODSN-23i NATURAL RESOURCES Jobs Job Category WELL SERVICE Start Depth Foot/Meters ' Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 5/8/2012 5/9/2012 20,550.0 Rig back up and make another run with hydrostatic bailer, RIH and set down on plug at 12,768' SLM.Jarred down sevaral times,sheared tool.POOH,bailer full of thick crude,no solids.MU RIH 5.1'of 1 7/8"RLR 10.4'of 2.125"RLR,oil Jars LSSS w 3.5 GS.Set down and latch plug(")a 12,768'.Jar for half hr.Plug came free,POOH.The equalizing ports were plugged with what appears to plastic or teflon packing and small pieces of brass.RDMO job complete.Turn over to Operations to start injection Page 2/2 Report Printed: 5/24/2012 Page 1 of/I Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, May 01, 2012 11:45 AM To: 'Crumrine, Tim' Subject: RE: Pioneer Alaska Sundry 312-011 Well ODSN-23i Conversion to Injector(PTD 211-042) Tim, Is this for the witnessed MIT-IA or are you still in the process of swapping mandrels to start injection? In any case a test to 1500 psi is the minimum required to fulfill the AIO mandate. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Crumrine,Tim [mailto:Tim.Crumrine@pxd.com] Sent: Tuesday, May 01, 2012 10:08 AM To: Schwartz, Guy L(DOA) Subject: Pioneer Alaska Sundry 312-011 Well ODSN-23i Conversion to Injector Dear Guy: In Sundry#312-011 submitted by Theresa Williams for the conversion of N-23i to water injector Pioneer stated that an MIT-IA would be performed to 3500 psi for 30 minutes charted and recorded. We have tried to perform the MIT-IA twice now to 3500 psi. Each time,we have pushed the valve out of pocket by testing to this high of a pressure. This may have been a clerical error to test to 3500 psi. AIO 34 states the test pressure should be 1500 psi or 0.25 psi/ft multiplied by the ND of the packer,whichever is greater. Since the N-23i packer is set at 5690'TVD, I am requesting a change to the program that meets AIO 34 to test the IA to 1500 psi. If this is acceptable, please let me know. 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 pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical_depth of the packer, whichever is greater, that 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. Respectfully, Tim Crumrine, P.E. Senior Staff Completions Engineer Office: 907-343-2184 Cell: 907-240-4295 5/1/2012 strifgE II ALLimu SEAN PARNELL,GOVERNOR ALASKAtOIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Theresa Williams Staff Production Engineer Pioneer Natural Resources Alaska, Inc. l ' 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-23i Sundry Number: 312-011 Dear Mr. Williams: 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. ncerely, Daniel T. eamount, Jr. Chair DATED this 12-day of January, 2012. Encl. VED• • • ' �` STATE OF ALASKA Il' V A" JAN• I a ALASKA OIL AND GAS CONSERVATION COMMISSION 0v Z 2 APPLICATION FOR SUNDRY APPROVALS ; ,; ; «Fieo. Gas Gens. Commission 20 AAC 25.280 Anchoral0 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 Q • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Pioneer Natural Resourcs Alaska, Inc. Development 2 • Exploratory ❑ 211-042 • 3.Address: 700 G Street,Suite 600 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99501 50-703-20639-00-00. 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No E • ODSN-231 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 355037 Oooguruk-Nuiqsut Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 1 20,550' • 6247' 20,099' 6223' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 16" 158' 158' N/A N/A Surface 5738' 11-3/4" 5777' 3170' 5830 psi 3180 psi Intermediate 1 6293' 9-5/8" 5594'-11,887' 3118'-5355' 5750 psi 3090 psi Tie-Back 11,450' 7" 11,494' 5174' 7240 psi 7240 psi Intermediate 2 2595' 7" 11,494'-14,089' 5174'-6178' 7240 psi 7240 psi Liner 6188' 4-1/2" 13,912'-20,100' 6136'-6223' N/A N/A Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment, pg.2 See Attachment, pg.2 3-1/2",9.3# L-80,TCII 13,907' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Wellstar TRSV;7"Ultra-Pak Hyd Prod Pkr 1997'MD/1763'TVD; 12,671'MD/5690'TVD 12.Attachments: Description Summary of Proposal 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 2 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 1/6/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG Q Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certi that the foregoing is true and correct to the best of my knowledge. Contact Theresa Williams,343-2104 Printed Name heres. ill'' s Title Staff Production Engineer Signature /�� Phone 343 2104 Date 12/30/2011 Prepared By:Kathy Campoamor,343-2183 / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2_—O 11 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ILVLocation Clearance ❑ Other: . Nor �hsl' c„Ayr a-S (K aQ.G c. Subsequent Form Required: f D — le) APPROVED BY Approved by: _` ,, COMMISSIONER THE COMMISSION Date: 12 ) Form 10-403 evise�1/201' C� !/� l 2- oR1GINAL ,_. ; Submit in Duplicate Pioneer Natural Resources Alaska Inc. ODSN-23i Page 2 Form 10-403, Application For Sundry Approvals Box #11, Present Well Condition Summary Perforation Depth Attachment 24. Open to production or injection 4-Y2", 12.6#, L-80, Hyd 521 Uncemented Liner Sliding Sleeves fitted w/ 6ea. Y2" Holes - open @ depths listed: MD TVD 14,257' - 14,262' 6207' - 6208' Perforated Pups w/ 6-1/2" Ports @ depths listed: MD TVD 14,687' - 14,692' 6233' - 6233' 14,850' - 14,854' 6241' - 6241' 15,051' - 15,056' 6250' - 6250' 15,256' - 15,260' 6250' - 6250' 15,459' - 15,464' 6236' - 6236' 15,659' - 15,664' 6223' - 6223' 15,864' - 15,868' 6210' - 6210' 16,064' - 16,068' 6198' - 6198' 16,266' - 16,270' 6192' - 6192' 16,468' - 16,473' 6187' - 6186' 16,673' - 16,678' 6183' - 6183' 16,874' - 16,878' 6181' - 6181' 17,079' - 17,083' 6185' - 6185' 17,279' - 17,284' 6196' - 6196' 18,285' - 18,289' 6251' - 6250' 18,479' - 18,483' 6237' - 6237' 18,678' - 18,683' 6224' - 6223' 18,875' - 18,880' 6211' - 6210' 19,076' - 19,081' 6205' - 6205' 19,279' - 19,284' 6198' - 6198' 19,488' - 19,492' 6198' - 6198' 19,692' - 19,697' 6203' - 6204' 19,896' - 19,900' 6213' - 6214' • PIONEER NATURAL RESOURCES ALASKA ODSN-23i Conversion to Injector Slickline Work 1. Shut off lift gas and bleed down IA 2. MIRU slick line and pressure test lubricator 3. RIH and set plug catcher in X nipple above packer © 12,724' MD 4. RIH and retrieve orifice valve from GLM @ 9,865' MD. 5. RIH and retrieve dome valves from GLM's © 6,602' MD and 2,496' MD 6. RIH and set dummy valves in mandrels © 6,602' MD and 2,496' MD 7. Fluid pack IA with diesel through open GLM © 9,865' MD 8. RIH and set dummy valve in GLM © 9,865' MD 9. MITIA to 3500 psi for 30 min — chart and record — 10.Turn well over to operations for injection 11. Once stabilized injection is achieved, State witnessed MITIA must be performed o ,/elf 4/4r5 ('r''rM,f Her/ to be Q'h rh,� �G1`�t i4QIeIor /10 /QSP✓ve rev;eov ,t /leCe; ail 7P5 CDn✓e/.s,c ,, ftr 7/2 ierA Mr) 1 Ke—. / r e` PIONEERCurrent Schematic -State Well Name: ODSN-23i NATURAL RFSOURCES HORIZONTAL-Sidetrack 2,8/17/2011 6:08:05 PM Well Attributes Vertical schematic(actual) API/UWI Field Name Well Status Total Depth(ftKB) 50-703-20639-00-00 Oooguruk Unit DRILLED 20,165.0 11-21 Casing Strings Conductor,158.0ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(Ib/ft) Conductor 16 14.670 47.7 158.0 H40 Welded 109.00 J Casing Components L Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com 1-1 Conductor Casing Joints 47.7 47 16 14.670' 1- + Surface,5,777.0ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(ib/ft) 11-12 I 4-1 Surface 11 3/4 10.772 0.0 5,777.0 3,170.6 L-80 Hyd 521 60.00 p I �� Casing Components J 4-3 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com t 2-10 Surface Casing Shoe 5,775.0 3,170.1 11 3/4 10.772 HES Super Seal II 2-101 Autofill FS 1-16 ' 7"Intermediate 2 Tie-back,11,493.6ftKB Descnption OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(lb/ft) 11-20 ' 7"Intermediate 7 6.276 5.6 11,493.6 L-80 BTC-M 26.00 2 Tie-back 5-1 9 5/8 Drilling Liner,11,887.0ftKB iMi Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection Wt/Len(Ib/ft) "�5-4 9 5/8 Drilling 9 5/8 8.835 5,594.2 11,887.0 5,351.5 L-80 HYD 521 40.00 t Liner I Casing Components 14-101 — Top(TVD) -- Item#' Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn I 1-241 �-- 4-1 Liner Tie Back Sleeve 5,594.2 3118 9 5/8 8.835 1-28 - .- 4-2 TSP4R Liner Top Packer 5,615.8 3124 9 5/8 8.835 II 4-3 PHS Liner Hanger 5,618.0 3125 9 5/8 8.835 11-33 4-10 9-5/8"Drilling Liner Shoe 11,884.7 5,350.4 10 8.835 Ray Oil Tool Ecentric 1/16 Float Shoe 11-38 != 7"Intermediate 2 Liner,14,089.OftKB ' ` Description OD(in) ID(in) Top(ftKB) Set Depth(ft.. Set Dept... Grade Top Connection Wt/Len(Ib/ft) 11-42 7"Intermediate 7 6.276 11,493.6 14,089.0 6,173.8 L-80 Hyd 511 26.00 2 Liner 1-47 r 6-1 —Casing Components 1-48 Top(TVD) 1 6-2 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com i; 6-3 5-1 Polish Bore Receptacle 11,493.6 5173 7 6.276 t 5-2 WFT TSP5 Liner Top Pkr 11,514.5 5182 7 6.276 ' 5-11 5-4 PHR Liner Hanger 11,519.3 5185 7 6.276 6-7 5-11 7"Float Shoe 14,086.9 6,173.3 7 6.276 6-11III 4 1/2"Production Liner,20,100.0ftKB 6-14 Description (in) ID(in) Top(ftKB) Set Depth(ft... Set Dept.. Grade Top Connection Wt/Len(Ib/ft) 6-16 4 1/2" 4 1/2 3.920 13,912.3 20,100.0 6,218.5 L-80 4.5 Hyd. 12.60 lip6-18 Production 521 j 6-20 Liner mm 6-22 Casing Components 11. mil 6-24 Top(TVD) iu MIN 6 26 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com im mmm 6 28 6-1 Weatherford 16'PBR Tie- 13,912.3 6,132.7 5.77 5.250 mom back Sleeve Air 6-30 _ 6-2 Weatherford 5"x 7"NTH 13,927.6 6,136.2 4 1/2 3.920 "0. 6-32 6-34 Liner Top Pkr. 6immmom -36 6-3 Weatherford PHR Hyd.Rot 13,930.9 6,137.0 5.93 4.000 Is, Hanger Al, 638 Emo 6-40 6-7 Sliding sleeve w/6-1/2" 14,256.6 6,202.7 5.63 3.920 I _ 6-43 ports(OPEN) 6-47 6-11 Weatherford Oil Swell Pkr. 14,508.6 6,220.7 4 1/2 3.920 6-50 te 6-52 u 6-54 it p6-56 "' 2 6-58 il 6-60 ,�, ,6-62 •11, -6-64 f., 6-66 Page 1/3 Report Printed: 8/17/2011 I'I 0 N E E R Current Schematic - State Well Name: ODSN-23i NATURAL RESOURCES HORIZONTAL-Sidetrack 2,8/17/2011 6:08:25 PM Casing Components Vertical schematic actual Top(TVD) ( ) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 6-14 Perforated Pup Joint w/6- 14,686.9 6,228.5 4 1/2 3.920 11-21 •■ 1/2"Ports 6-16 Perforated Pup Joint w/6- 14,849.8 6,235.8 4 1/2 3.920 1/2"Ports JI [ 1-1 6-18 Perforated Pup Joint w/6- 15,051.3 6,245.0 4 1/2 3.920 1/2"Ports 6-20 Perforated Pup Joint w/6- 15,255.6 6,245.7 4 1/2 3.920 1-8 1mi-- 1/2"Ports 6-22 Perforated Pup Joint w/6- 15,459.1 6,231.2 4 1/2 3.920 11-12 4.1 1/2"Ports p' ' _A4-2 6-24 Perforated Pup Joint w/6- 15,659.5 6,218.4 4 1/2 3.920 4-3 1/2"Ports t 6-26 Perforated Pup Joint w/6- 15,863.8 6,205.2 4 1/2 3.920 2-101 1/2"Ports 1-16 6-28 Perforated Pup Joint w/6- 16,063.7 6,193.4 4 1/2 3.920 1/2"Ports 11-20 I' I 6-30 Perforated Pup Joint w/6- 16,265.7 6,187.2 4 1/2 3.920 1/2"Ports 5-1 6-32 Perforated Pup Joint w/6- 16,468.3 6,181.8 4 1/2 3.920 g® 1/2"Ports 5-4 6-34 Perforated Pup Joint w/6- 16,673.0 6,178.8 4 1/2 3.920 t 1/2"Ports 1 ii 6-36 Perforated Pup Joint w/6- 16,873.7 6,176.5 4 1/2 3.920 14-101 1/2"Ports 11-24 = 6-38 Perforated Pup Joint w/6- 17,078.7 6,180.3 4 1/2 3.920 1-28 = 1/2"Ports 6-40 Perforated Pup Joint w/6- 17,278.9 6,191.2 4 1/2 3.920 1/2"Ports I1-33 I I16-43 Weatherford Oil Swell Pkr. 17,485.1 6,206.2 4 1/2 3.920 17,906.2 6,235.0 5 3/4 3.920 1.38 _ 6-47 Weatherford Oil Swell Pkr. 6-50 Perforated Pup Joint w/6- 18,284.8 6,246.1 4 1/2 3.920 1-42 I I 1/2"Ports 1-47 6-52 Perforated Pup Joint w/6- 18,478.6 6,232.4 4 1/2 3.920 1-48 r 6-1 1/2"Ports 6-2 6-54 Perforated Pup Joint w/6- 18,677.9 6,218.9 4 1/2 3.920 _ 6-3 1/2"Ports 6-56 Perforated Pup Joint w/6- 18,875.3 6,207.6 4 1/2 3.920 5-11 1/2"Ports B_7 6-58 Perforated Pup Joint w/6- 19,076.4 6,200.4 4 1/2 3.920 6 11 1/2"Ports 6-14 6-60 Perforated Pup Joint w/6- 19,279.2 6,193.0 4 1/2 3.920 6-16 1/2"Ports 6-18 6-62 Perforated Pup Joint w/6- 19,487.8 6,193.4 4 1/2 3.920 NM 6 20 1/2"Ports iiimi 6-22 6-64 Perforated Pup Joint w/6- 19,692.3 6,198.5 4 1/2 3.920 iimi 6-24 1/2"Ports lit min 6-26 6-66 Perforated Pup Joint w/6- 19,895.8 6,208.8 4 1/2 3.920 Ems 6-28 1/2"Ports 6-30 6-68 4.5"Liner Shoe 20,098.7 6,218.4 Weatherford(solid) 6-32 Eccentric Shoe 6-34 Tubing Strings Imo 6-36 Tubing Description String M... ID(in) Top(ftKB) Set Depth(f...Set Dept...Wt(Ib/ft) Grade Top Thread :111 I M 6-38 3.5"completion 3 1/2 2.992 0.1 13,907.3 6,131.5 9.30 L-80 TC-II 6-40 Tubing Components 6-43 Top(TVD) 6-47 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 1-2 Vetco Gray Hgrwith MAC 34.1 10 2.950 6-50 box x TC-ll box 13/16 II 6-52 MN /6-54 am �6-56 II /6-58 II 6-60 6-62 ii ii min 6-64 imi 6-66 Page 2/3 Report Printed: 8/17/2011 • / P I O N E E R Current Schematic - State Well Name: ODSN-23i NATURAL RFSOURCES HORIZONTAL-Sidetrack 2,8/17/2011 6:08:45 PM Tubing Components Vertical schematic(actual) item# Item Des TopTop(TVD) (�B) (ftKB) OD(in) ID(in) Corn 1-8 HES Wellstar TRSV 1,997.2 1762 5.2 2.813 11-2I .. - - J , w/2.813"X"profile 3.5"TC- II b I I 1-12 Vanoil 3.5 x 1.5 MMG GLM 2,496.5 2020 5.968 2.920 w/3.5"TC-Il bxp 1-1 1-16 Vanoil 3.5 x 1.5 MMG GLM 6,602.5 3439 5.968 2.920 w/3.5"TC-II bxp 1 81timp.0 1-20 Vanoil 3.5 x 1.5 MMG GLM 9,865.1 4545 5.968 2.920 w/3.5"TC-II bxp 11-12 4-1 1-24 HES ROC gauge mandrel 12,540.3 5,632.9 5.664 2.965 0' I 4.2 TC-II bxp 11-16 �4-3 1-28 HES 2.81 "X"Nipple 3.5" 12,588.5 5,652.6 3.96 2.813 1 TC-II bxp 9 Cr 2-101 1-33 7"WFT Ultra Pak Hyd 12,671.4 5,686.3 5.865 3.937 Perm Prod Pkr II I 1-38 HES 2.81 "X"Nipple 3.5" 12,724.6 5,707.6 3.96 2.813 1 1-20 TC-II bxp 9 Cr 1-42 HES 2.81"XN Nipple 12,802.1 5,737.8 3.94 2.750 5-1 w/2.75 No-go w/RHC-m ® plug in 5-4 1-47 Locator collar 13,897.5 6,129.2 5.8 3.958 1-48 5"seal stem w/o seals w/ 13,898.5 6,129.5 5.2 3.958 i I indexing mule shoe 14-101 11-241 1-28 1-33 I I I1-38 I1-42 I I 1-47 1-48 V 6-1 1 6-2 r 6-3 I I 5-11 6-7 6-11 6-14 6-16 I.., 6-18 '1' 6-20 •s" 6-22 ..' I„ 6-24 /„ 6-26 imi IU 6-28 6-30 MEN IIIP MEI 6-32 6-34 n, NEE 6-36 II NM gi 6-38 1 6-40 I 6-43 6-47 6-50 i, 6-52 g 6-54 II 6-56 NM /6-58 II p 6-60 ENE 7,6-62 IU ENE 12, 6-64 NMI IU 6-66 Page 3/3 Report Printed: 8/17/2011 Page 1 of 3 4 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, August 26, 2011 3:36 PM To: 'Vaughan, Alex' Cc: Tirpack, Robert; Johnson, Vern; Campoamor, Kathy Subject: RE: ODSN-23i (PTD 211-042) Rob/Alex, Thanks for the email response to my questions. I talked to Vern yesterday too and realize that notification was probably not immediately necessary based on the actual volumes pumped vs calc. Also, we never set a standard for notification as the regulations just say "excessive" per 20 AAC 25.030 (d)(4). Of course anytime the value is negative an immediate notification before drilling ahead is required. For my benefit I would like to see an email notification after the surface cement job if it is less than 15% excess. / looked at our data base of several hundred surface casing cement jobs on the North Slope. There are only about 10 that have less than 15%excess cement left in the wellbore since we started tracking this about 10 yrs ago. Your explanation for the Liner tieback cement makes sense .( I was trying to figure why you were cementing based on the liner lap testing ok.) This should have been included in the PTD approved procedure however. Major steps should always be included in the work outline. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Vaughan, Alex [mailto:Alex.Vaughan@pxd.com] Sent: Friday, August 26, 2011 3:01 PM To: Schwartz, Guy L (DOA) Cc:Tirpack, Robert; Johnson, Vern; Campoamor, Kathy; Vaughan,Alex Subject: ODSN-23i (PTD 211-042) Sent for Rob Tirpack. Guy, As discussed on the phone yesterday, Pioneer did not contact the AOGCC concerning the N-23i surface casing cement job. As the lead cement was mixed and pumped, the flow meter on the rig showed that 662 bbls of cement was pumped downhole. This is was over the calculated volume of 593 bbls. To verify the flowmeter,the cement was displaced with the rig pumps going through the same flowmeter. Upon bumping the plug,the flowmeter matched the pump strokes for displacement volume. There was full returns during the cement job,the plugs bumped on volume,floats held and 280 bbls of cement was returned to surface. The actual volumes of cement pumped were entered into the Pioneer Surface Casing Cement Job Calc sheet along with the actual casing depths and returned cement volume. The numbers showed that while there was some channeling,the proper amount of cement was placed during the N-23i surface 8/26/2011 Page 2 of 3 casing cement job,with the actual annulus volume being 16%over of the required volume. Based on this sheet and conversations with the rig team, it was decided that notification to the AOGCC was not required. For the second question,the 7"tieback liner was cemented in place due to tieback equipment issues on previous jobs. The 7" tieback is normally run in hole with a hold-down tool located right above the tieback seal assembly. This hold-down tool is required to prevent excessive casing movement during various production loads during the life of the well. Without the hold down sub,there is a risk of the 7"tieback liner un-stinging from the 7" production liner tie-back receptacle. While running the 7' tieback jobs on N-18 and N-17 the hold- down tool became problematic, showing excessive drag and attempting to set early. Because of these tool problems, Pioneer decided to cement the bottom of the tieback liner in place. The 7" production liner had a passing liner top packer test,there was no liner lap failure. Please call with any questions. Regards, Rob Robert Tirpack Drilling Superintendent Pioneer Natural Resources 907-343-2121 office 907-903-9454 cell robert.tirpack@pxd.com From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, August 25, 2011 8:34 AM To: Vaughan, Alex;Tirpack, Robert Subject: RE: ODSN-23i (PTD 211-042) Alex/ Rob, Can you respond in a return email to our conversation yesterday regarding the topic below. Disregard the pre- production question. Also, I noticed that the 7"tieback was cemented in at the liner top... I don't see where the liner lap had failed a pressure test ... can you give me your reasoning for this added step? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L(DOA) Sent:Tuesday, August 23, 2011 3:34 PM To: 'Vaughan, Alex' Subject: ODSN-23i(PTD 211-042) Alex, I'm reviewing the 407 report on the completion of ODSN-23i. Are you going to pre-produce this well for a long time? The 407 was submitted as a Development/oil well instead of an injector.. was that your intention? The completion is also more geared to an injector(no ESP or GLM's) . I also saw the 11.75"surface cement job had some interesting results in that the gauge + excess was somewhere 8/26/2011 Page 3 of 3 between 3 and 16%. I understand the yield was off somewhat on the lead cement. Good job on capturing this with the new spreadsheet system you implemented but I would have still liked to have know that when we logged the 9 5/8"casing for TOC (to cover Torok) . In hindsight I may have insisted on running a USIT or FastCast tool with tractor so we could have gotten a better look at both of these cement jobs( ie surface and 9 5/8" drilling liner). Regards, 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. 8/26/2011 STATE OF ALASKA ALA;,..A OIL AND GAS CONSERVATION COMMIS:,..,N WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑Q Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.110 Development 2 Exploratory❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: One Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Drill Number: Pioneer Natural Resources Alaska, Inc. Aband.: 7/20/2011 211-042 3.Address: 700 G Street,Suite 600 6.Date Spudded: 13.API Number: Anchorage,AK 99501 5/14/2011 50-703-20639-00-00 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: pr',- prof/:A.4,-...( Surface: 2902'FSL, 1209'FEL, Sec. 11,T13N, R7E, UM _ 7/11/2011 ODSN-23i :1-,.,1 Top of Productive Horizon: 8.KB(ft above MSL): 56.2' 15.Field/Pool(s): 4230' FSL, 703'FEL, Sec. 16,T13N, R7E, UM GL(ft above MSL): 13.5' -4,4 Total Depth: 9.Plug Back Depth(MD+TVD): Oooguruk-Nuiqsut Oil Pool 3427 FSL, 14' FEL, Sec.8,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- 469788.76 Y-6031018.57 Zone-Asp4 20,550'MD/6247'TVD ADL 355036/ADL 355037 TPI: x- 459724.10 Y-6027114.77 Zone-AsP4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 455148.10 Y-6031617.29 Zone-AsP4 1997'MD/1763'TVD 417497 18.Directional Survey: Yes 0 No ❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 974'MD/947'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, MWD/LWD,ABI, EWR, GABI, PWD, DGR/DDS,ALD, CTN, PCDC, BAT Sonic (z.) N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH ND AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT. TOP BOTTOM TOP BOTTOM PULLED 16" 109# H-40 Surface 158' Surface 158' 24" Driven V L-80 HYD 11-3/4" 60# 521 Surface 5777' Surface 3170' 14-1/2" 800 sx PF'L';502 sx Class'G' 9-5/8" 40# L 852�YD 5594' 11,887' 3118' 5355' 10-5/8" 554 Class'G' L-80 .i 7.. 26# BTC-M Surface 11,494' Surface 5174' 8 1/2" Tie Bac • 't" 7" 26# B M 11,494' 14,089' 5174' 6178' 8-1/2" �`135g,Class'G' 4-1/2" 12.6# L-8 OHYD 13,912' 20,100' 6136' 6223' 6-1/8" Uncemented 24.Open to production or injection? Yes[ j No If Yes,list each 25. TUBING RECORD interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3-1/2",9.3#, 13,907 7"Ultra-Pak Hyd Prod Pkr S!.L 110.M L-80,TCII @ 12,671'MD/5690'ND See Attachment, pg.3 �e : , 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. • -' O, DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): 7/25/2011 Gas Lift Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: 7/25/2011 7.5 Test Period 448 377 0 3" 842 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 280 832 24-Hour Rate —. 143 121 0 26 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No❑., Sidewall Cores Acquired? Yes❑ No❑., 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 MC 25.071. RECEJVSY None AUG 2 3 2011 MOMS AUG +31011 Alaskaa Oil&Gas Cent.G,mei� is r Anchorage Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 9Submit original only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes El No If yes, list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if Permafrost-Top 857' 838' needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1831' 1668' Top West Sak 3171' 2317' Top Torok 11,043' 4980' None Top HRZ 12,871' 5768' Top Kuparuk C 13,568'✓ 6032' Top Nuiqsut 14,039' 6166' Formation at total depth: 20,550' 6247' 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: Alex1� Vaughan 1 Title: Operations Engineer Signature: YUt\ti �;jifj11"r`l � �1�"h \IC `lt�� Phone: 343-2186 Date: 8/19/2011 Well Name:ODSN-23i Permit No.:211-042 Prepared By:Kathy Campoamor, 343-2183 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Pioneer Natural Resources Alaska Inc. ODSN-23i Page 3 Form 10-407, Well Completion or Recompletion Report and Log Attachment - Box #24 24. Open to production or injection 4-1/2", 12.6#, L-80, Hyd 521 Uncemented Liner Sliding Sleeves fitted w/ 6ea. 1/2" Holes - open @ depths listed: MD TVD 14,257' - 14,262' 6207' - 6208' Perforated Pups w/ 6-1/2" Ports @ depths listed: MD TVD 14,687' - 14,692' 6233' - 6233' 14,850' - 14,854' 6241' - 6241' 15,051' - 15,056' 6250' - 6250' 15,256' - 15,260' 6250' - 6250' 15,459' - 15,464' 6236' - 6236' 15,659' - 15,664' 6223' - 6223' 15,864' - 15,868' 6210' - 6210' 16,064' - 16,068' 6198' - 6198' 16,266' - 16,270' 6192' - 6192' 16,468' - 16,473' 6187' - 6186' 16,673' - 16,678' 6183' - 6183' 16,874' - 16,878' 6181' - 6181' 17,079' - 17,083' 6185' - 6185' 17,279' - 17,284' 6196' - 6196' 18,285' - 18,289' 6251' - 6250' 18,479' - 18,483' 6237' - 6237' 18,678' - 18,683' 6224' - 6223' 18,875' - 18,880' 6211' - 6210' 19,076' - 19,081' 6205' - 6205' 19,279' - 19,284' 6198' - 6198' 19,488' - 19,492' 6198' - 6198' 19,692' - 19,697' 6203' - 6204' 19,896' - 19,900' 6213' - 6214' PIONEERi'erations Summary Report - Stat Well Name: ODSN-23i NATURAL RESOURCES Well Name: ODSN-23i Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: DEVELOPMENT DRILL Start Date: 5/13/2011 End Date: 7/21/2011 Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 5/13/2011 5/14/2011 0.0 9.00 Rig accepted on ODSN-23i on 05/13/11 at 00:00 hrs.. RD and prep to move off of ODSN-18 to ODSN-23i.Move rig f/ODSN-18 t/ODSN-23i.Spot rig over ODSN-23i.Prep rig floor for spud.Prep pits for spud.Change out saver sub to 4-1/2"IF.RU &PU 180 joints of 5"DP and stand back.PU 14 jts.5"HWT and Hyd drilling jars and stand back. 5/14/2011 5/15/2011 158.0 902.00 9.30 PU Spud BHA.Fill lines and riser.RU Gyro.Break circ.Tag ice at±60'.Clean out conductor to 158'.Directional drilling f/158't/326'while running Gym every ctanct clow POOH.PU Motor/ directional BHA#1 t/326'.Directional drilling f/326't/1,060'. 5/15/2011 5/16/2011 1,060.0 625.00 9.30 Directional drill 14-1/2"hole f/1,960't/1,117'.Inspect Kelly hose.Observed split outer cover all the way around.CBU.POOH to±79'to change out hose.Pull kelly hose&install new.Inspect BHA.LD orient sub.RIH t/1,117'.Directional drilling f/1,117't/1,685'. 5/16/2011 5/17/2011 1,685.0 952.00 9.30 Directional drill 14-1/2"hole f/1,685'V2,637'.CBU x3 while standing back 1 stand every bopttoms up.Pump out of hole f/2,352'01,114'.CBU while pulling 1 stand 01,019'.POOH on elevators to BHA at 202'.Change bit.Adjust mud motor to 1.5°.RIH t/1,399'. 5/17/2011 5/18/2011 2,637.0 1,478.00 9.45 Continue RIH on elevators V1,566.Stacked weight at 1,568'.Attempt to work through w/no success.Break circ.w/500 gpm, 1000 psi.Orient to 30°left.Attempt to slide through w/no success. PU and rotate through w/30 rpm.PU and wipe w/no rotary,no pump.OK.RIH and take weight at 1,627'.Repeat process.OK.RIH on elevators f/±1650't/2,540'.Break circulation slowly.As precaution,wash last stand to bottom.Directional drilling f/2,637'04,115'. 5/18/2011 5/19/2011 4,115.0 1,360.00 9.65 Directional drill 14-1/2"hole f/4,115'05,475'. 5/19/2011 5/20/2011 5,475.0 604.00 9.65 Directional drill 14-1/2"hole f/5,475't/6,079'.Pump 70 bbl hi-vis weighted sweep and circulate hole clean with 4x bottoms up.POOH f/5,685'01,748'.Back ream out the hole f/1,748't/1,100'. Circulate hole clean with 2x bottoms up.POOH f/1,100'U surface-inspect BHA.TIH with BHA from surface t/202'. 5/20/2011 5/21/2011 6,079.0 9.65 TIH f/202'01,395'.Ream in the hole f/1,395't/1,876'.TIH f/1,876't/5,285'.Ream in the hole f/5,285't16,079'.Pump 60 bbl hi-vis weighted sweep and circ hole clean with 5x bottoms up- rack back 1 stand every hour.POOH f/5,590't/5,494'.Back ream out the hole f/5,494'04,732'. TIH on elevators f/4,732'06,079'.Pump 60 bbl hi-vis weighted sweep and circ hole clean with 2x bottoms up.POOH f/5,875'04,732'. 5/21/2011 5/22/2011 6,079.0 9.50 Back ream out the hole f/4,732'U924'.Reciprocate f/924'U828'while circulating hole clean with 2x bottoms up-tagged up at 857'.Work past tight spot at 857'U910'and stacked out at 910'. Orient tool face and attempt to slide with no success.Clean out suspected tight hole f/910' 01,012'.Take check shot surveys and confirm open hole side track.POOH f/1,012't/738'. Attempt to orient bit into old hole,mimic drilling/sliding parameters f/738't/1,047-unable to locate original well bore.POOH f/1,047'U surface.Pick up BHA#4 f/surface t/164',and shallow test same-Good test. 5/22/2011 5/23/2011 1,048.0 1,364.00 9.45 Perform rig maintenance while waiting on RSC to repair all solids handling equipment.TIH on elevators f/164'U825'.Attempt to orient bit into old hole f/825't/1,047'-unable to locate original well bore.POOH f/1,047'0164'. 5/23/2011 5/24/2011 1,048.0 1,364.00 9.35 TIH f/164't/685'.Orient TF and trough at 25-50 fph f/685't/714'in attempt to side track.TIH f/685'01,048'. Directional drill 14-1/2"hole f/1,048't/2,412'. 5/24/2011 5/25/2011 2,412.0 1,568.00 9.40 Directional drill_14-1/2"hole.f/2,41Z't/2634'.Circulate bottoms up racking back 1 stand every 15 min f/2,634'U2,443'.Pump out the hole f/2,443'(/1,301'.POOH f/1,301'U surface. Adjust bend on motor from 1.83 to 1.5 degrees,and change out bit.TIH f/surface(12,634'.Directional drill 14- 1/2"hole f/2,634'(/3,980'. 5/25/2011 5/26/2011 3,980.0 1,618.00 9.50 Directional drill 14-1/2"hole f/3,980'V5,598'. Page 1/10 Report Printed: 8/19/2011 PI 0 N E E R aerations Summary Report - Stat Well Name: ODSN-231 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 5/26/2011 5/27/2011 5,598.0 192.00 9.60 Directional drill 14-1/2"bole(/5598't/5 790',Circulate hole clean with 4x bottoms up rack back 1 stand every 30 min 1/5,790't144,920'.POOH 1/4,920't/1,575'.TIH 1/1,575't/3,586'.Rotate and pump in the hole 1/3,586'05,250'.Trip in the hole 1/5,250't15,790'.Circulate hole clean with 3x bottoms up rack back 1 stand every hour 1/5,790't/5,491'.Attempt to POOH on elevators- unsuccessful,pump out the hole 1/5,491't15,225'.Back ream thru tight spot(/5,225't15,205'.TIH 1/5,205't15,777',pull out t/5,205'-no issues.Back ream 1/5,205't/4,920'. 5/27/2011 5/28/2011 5,790.0 0.00 10.10 CBU at 4,920'.Pump out the hole f/4,920't/4,348'.POOH 4,348'to surface.RU to run 11-3/4" surface casing with Tesco tool.Trouble shoot Tesco hydraulic unit and change out check valve. PJSM with all involved personnel,MU float equipment,circulate thru same,.f 1H Atm 60#, L-80,_H_yd 521 surface casing f/surfacg 04,464'-stacked out.Rotate and pump in the hole with casing 1/4,464't/4,748'. 5/28/2011 5/29/2011 5,790.0 0.00 9.70 Rotate and pump in the hole with casing f/4,748't/5,735'..PU casing hanger,and landing joint- land casing at 5,777'.Stage pumps up while reciprocating casing,and circulate to condition mud for cement job.RD Tesco casing running tool,RU casing bails,and elevators. RU cement head and lines.Circulate and condition mud for cement job.PJSM w/all involved personnel.Swap over to Halliburton,pump 10 bbls seawater,release 1st bottom plug and kick out w/last 2 bbls, test lines to 4000 psi.Load top plug,pump 80 bbls 10.0_2p9 spacer,pump 662 bbls(800 sx) (T E Lead cement at 10.9 ppg(type"L"Permafrost w/yield of 4.16). Drop 2nd bottom plug.Pump 100.5 bbls(502 sx)Tail cement at 15.8 ppg(Premium"G"w/yield of 1.16).Release top plug- Kick out w/20 bbls seawater.Displace w/631 bbls 9.7 ppg spud mud using rig pumps 7.5 bpm, 1,450 psi,had to slow rate to 4 bpm when cement returns got to surface.Bumped plug at at 3 bpm and pressured up to 3500 psi.280 bbls cement returned to surface.CIP at 17:30 hrs.Hold casing test at 3500 psi on chart for 30 min-Good test.Bled back 9.1 bbls-floats holding.RD cement head and lines,and LD landing joint.RD casing elevators and bails.MU diverter tool and flush riser with rig pumps.ND surface riser. **Notes: 1. The 662 bbls of L Cement measured through the flow meter was 70 bbls more than the calculated yield of 592.7 bbls. 2. The accuracy of the flow meter was confirmed by comparing the drilling fluid volume measured to bump the cement plug with both the calculated capacity of the 11-3/4"casing and the pump strokes to bump plug which were all 631 bbls. 3. Therefore 662 bbls of L Type cement plus 100.5 bbls of G cement measured through the flow meter minus the 280 bbls of cement returns to surface reflects the cement volume left in the annular space between the 11-3/4"casing and 14.5"hole was 16.8%greater than gauge hole calculations. 5/29/2011 5/30/2011 5,790.0 0.00 9.60 ND surface riser,and starting head.Install intermediate well head,and NU drilling riser.Nipple up BOP stack,choke line,kill line,and install turn buckles.Off load cement head,and casing elevators from rig floor.Install test plug,rig up testing equipment,and fill stack with water. Perform body test on BOP-kill line leaking.Change out 2"Demco valve on kill line manifold. Test BOPE w/5"test joint to 250 psi low/4500 psi high.Test annular w/5"test joint to 250psi e, low/2500 psi high. Upper IBOP on top drive not holding.Trouble shoot upper IBOP- ."-• determined it had to be rebuilt.Continue to test BOPE per AOGCC regulations.Did not test upper IBOP on top drive.Test all floor valves to 250 psi low/4500 psi high.Test choke manifold <12 to 250 psi low/4500 psi high.All tests charted and all test held for 5 min.Initial psi=3000,2000 after closure,200 psi=23 sec,full pressure 1:45.RD testing equipment.Test witness waived by AOGCC Rep.Lou Grimaldi at 06:00 hrs 05/29/11. Remove upper IBOP,rebuild same,reinstall on top drive,and test upper IBOP to 250 psi low/4500 psi high on chart 5 min each.TIH with BHA#6 f/surface t/4,089'. 5/30/2011 5/31/2011 5,810.0 20.00 9.80 TIH 1/4,089't15,325'.Fill pipe and circulate DP capacity down pipe.POOH f/5,325't/3,709'.TIH picking up singles from pipe shed f/3,709't/5,577'-tagged cement stringer.Drilling cement,and float equipment(/5,577't/5,790'.Drilling new hole f/5,790'05,810'.Pull up f/5,810't/5,777', circulate and condition mud for L.O.T.Perform L.O.T.at 5.777"and/3.180'tyd to„975 psis0112..9.7__ ppa mud for 15.6 poa EMW.Displace hole from 9.7 ppg spud mud to 9.8 ppg LSND mud.POOH f/5,777't/surface.TIH picking up directional BHA#7,and shallow pulse test same.TIH f/287' t13,038'. Fill pipe,and test MWD tools,down link GeoPilot-Good test. Page 2/10 Report Printed: 8/19/2011 PI 0 N E E R erations Summary Report - Stat Well Name: ODSN-23i NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 5/31/2011 6/1/2011 5,987.0 191.00 9.80 Fill pipe and test MWD tools,down link GeoPilot-Good test.TIH f/3,038't15,810'.Directional drilling f/5,810'115,892'.Drop 1-5/8"ball and pump ball on seat and sheer ball seat to engage under reamer cutters,pull 10k against the casing shoe to confirm cutters engaged.Saw 2k increase in torque and 250 psi decrease in pump pressure to verify blades are open.Directional drilling(/5,892't/5,987'.Trouble shoot weak MWD signal.Circulate carbide pill surface to surface -no washout detected.POOH f/5,987'U surface.Down load MWD data,change out pulser,and up load MWD data.RIH with BHA and shallow pulse test same-Good test.TIH f/260'1/5,987'. Directional drill 10-5/8"hole f/5,987'1/6,001'. 6/1/2011 6/2/2011 6,001.0 1,224.00 9.80 Directional drill 10-5/8"hole f/6,001'117,225'.Observed packoff at 7,190'during reaming down before connection.Attempt to regain circulation by rotating and reciprocating f/7,210'117,128'w/ no success.POOH f/7,210'116,558'rotating and reciprocating while attempting to establish circulation. 6/2/2011 6/3/2011 7,225.0 55.00 9.80 Working stand f/6,558't/6,488'.Work stand back down 1/6,555'.Trouble shoot Top Drive lube oil pump issues.Continue to work pipe f/6,555'1/6,654'.Establish circulation at 6,610'.Stage up to 720 gpm.Backream out of hole f/6,610'1/5,892'spotting Reamer 30'outside 11-3/4"shoe.Pump 2-30 bbls H.V.weighted sweeps to surface.RIH 1/7,225'.Directional drilling f/7,225'1/7,280'. 6/3/2011 6/4/2011 7,280.0 940.00 9.90 Directional drill 10-5/8"hole f/7,280't/8,220'. 6/4/2011 6/5/2011 8,220.0 1,830.00 9.90 Directional drill 10-5/8"hole f/8,220'1/10,050'. 6/5/2011 6/6/2011 10,050.0 1,500.00 9.90 Directional drill 10-5/8"hole f/10,050't(1.1.099'.Circulate off bottom while replacing swab&liner in MP#1.Directional drill 10-5/8"hole f/11,099'1/11,550'. **Function test BOPE per AOGCC weekly requirement.Annular,upper and lower pipe rams. 6/6/2011 6/7/2011 11,550.0 436.00 9.90 Directional drill 10-5/8"hole f/11,550't/11„986'..Open pilot hole using HES procdure w/Geo-Pilot in 1 d0%deflection in all 4 quadrants.Circulate&condition hole for wiper trip.Pump total of 3 H.V.weighted sweeps.POOH f/11,986'1/9,510'.RIH 1/11,986'.Pump sweep.Unplug flowline. Continue circulating hole clean.Change swab in#1 mud pump. 1 . 6/7/2011 6/8/2011 11,986.0 9.80 Continue to replace swab on mud pump#1.Observed 900 psi pressure loss after changing swab.Inspect mud pumps and all surface equipment.OK.Monitor pressure for loss.Pressure leveled out at 2550 psi.w/835 gpm.Pump 50 bbls H.V. 12.5 ppg sweep. Monitor well.Backream out of hole f/11,986'1/8,352'.Packed off at 8,352'.Establish circulation and stage pumps up to 800 gpm.Drop de-activation ball for Reamer and pump down w/400 gpm.No indication of of shear observed.Backream out of hole f/8,367't/6,844'. 6/8/2011 6/9/2011 6,844.0 9.80 Continue to backream f/6,844'1/5,910'bit depth(placing top stab at 11-3/4"shoe).Experiencing high torque/stalling.Pump H.V.sweep around.POOH on elevators f/5,910'U surface. LD BHA (lost 89'of BHA in hole.Service rig.Function blind rams. PU BHA#91/592'.RIH f/592'1/5,348'. 6/9/2011 6/10/2011 5,781.0 10.05 Continue to RIH w/Rhino Reamer cleanout assembly f/5,348'1/5,633'.Drop activation ball.RIH 1/5,794'(shoe at 5,777').Pump ball down.Observe ball seat and shear w/1200 psi.Increase pumps to 700 gpm,1850 psi.Pull test reamer against shoe w/10k overpull.RIH 115,781'. Reaming/hole opening f/5,781'1/10,488'. *Notified AOGCC of upcoming BOP test due on 06/12/2011. 6/10/2011 6/11/2011 11,986.0 9.80 Reaming/hole opening f/10,488'1/11,897'.Tag top of fish at 11,897'.Circulate hole clean utilizing H.V.weighted sweeps.Perform 755 bbls mud dilution using new 9.8 ppg LSND mud.POOH on elevators(/11,895'1/9,536'. Page 3/10 Report Printed: 8/19/2011 PI 0 N E E R ,erations Summary Report - Stati Well Name: ODSN-23i NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (EKB) (It) Mud(Ib/gal) Summary 6/11/2011 6/12/2011 11,986.0 9.95 Continue to POOH on elevators 09,536't16,300'.Pulled tight(60k over)at 6,300'.Work stand back down and pull up w/no issues.Pull next stand t/6,190'w/290k(50k over).Attempt to go back down-No success.Screw in T.D.break circulation&establish rotation.Ream f/6,190' t/6,283'.RIH f/6,283't16,388'w/no pump,no rotary.Backream f/6,388't15,870'placing top stab. outside shoe.Pump H.V. 12.1 ppg sweep around and CBU until)shakers clean up.Pump out of hole in casing(swabbing)f/shoe t/5,538'.Service rig.Cut drilling line.POOH f/5,538't14,529'. Pump out of hole f/4,529'to BHA at 592'due to swabbing.Stand back HWT.LD remainder of BHA. PU 9-8"DC's for upcoming liner run.Stand back same. RU to test BOPE. *AOGCC Rep.Matt Herrera waived right to witness upcoming BOP test at 08:30 hrs.on 06/11/11 6/12/2011 6/13/2011 11,986.0 9.80 Finish rigging up to test BOPE. -Test BOPE per AOGCC permit to drill: -Test BOPE w/9-5/8"test jt.to 250 psi low/4500 psi high. -Test annular w/9-5/8"test jt.to 250psi low/2500 psi high. t5` -Test lower variable rams w/5"test jt.to 250 psi low/4500 psi high. '( -Test upper and lower IBOP valves to 250 psi low/4500 psi high. r/t L� -Test annular w/5"test jt.to 250 psi low/2500 psi high. t? -Test all floor valves to 250 psi low/4500 psi high. -Test 14 choke manifold valves to 250 psi low/4500 psi high. -All tests charted and all test held for 5 min. -Initial system psi=3000; 1800 after closure;200 psi=25 sec,full pressure 1 min.55 sec. -All tests charted and all test held for 5 min. -RD test equipment.RU Tesco Casing tools.RIH w/ 9-5/8"40#L-80 Hydril 521 liner f/surface t/5,911'. "-Right to witness waived by AOGCC Rep.Matt Herrera at 08:30 hrs.on 6/11/11 6/13/2011 6/14/2011 11,986.0 9.90 Run 9-5/8"40#L-80 Hydril 521 liner f/5,911't/6.179'at±5-7 min.per joint placing first 7 centralizers outside 11-3/4"shoe.Minimal returns while RIH. Pushingfluid away.Break circ w/.5 bpm,550 psi.Monitor returns. -Achieving minimal returns(15-20%).Increase rate to 1 bpm,550 psi.w/same results.PU last jt. (#160)and wash down slowly t/6,258'with same results.RD Tesco and casing equipment.PU liner hanger assembly per Rep.PU bumper sub-RIH on 5"DP.At±6,400'(1st stand after hanger),pushing 100%fluid away.Break circ.w/1 bpm and attempt RIH while pumping 1 bpm. RIH while pumping 1 bpm f/6,497't16,687'.Break circulation and stage up to 5 bpm.Circulate until good mud surface to surface.Monitor well(breathing)until 0%flow.RIH with 9-5/8"liner on 5"DP f/6,687't/11,887'.Tag top of fish at 11,897'.PU and spot liner shoe at 11,887'.T.O.L.at 5,598'.MU cement head.Circulate&condition mud for upcoming cement job. Page 4/10 Report Printed: 8/19/2011 PIONEER ,erations Summary Report - Stab Well Name: ODSN-23i NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(ib/gal) Summary 6/14/2011 6/15/2011 11,986.0 9.85 Continue to stage up pumps f/1.5 bpm,450 psi to 6 bpm, 820 psi.At 5000 strokes away(open hole volume),shut down and drop 1-3/4"hanger setting ball.Pump ball down w/4 bpm,450 psi. Seat ball w/4760 stks.Pressure to 2500 psi&hold.Pressure up&observe ball shear w/3250 psi.Set 30k down wt. Install 5 right hand turns to release setting tool.RU cement lines to T.D. head and line up same to pump.T.O.L.at 5,597'.Liner Shoe at 11,887'.Break circ.w/1 bpm, 600 psi and stage up in 1 bpm increments to 5 bpm, 1830 psi w/full returns.Increase rate to 6 bpm and hole packed off. Pump down IA in attempt to break loose blockage w/4 bpm,950 psi.Pumped 34 bbls.Allow to bleed back-27 bbls back.Attempt to circ.long way w/1 bpm, 1030 psi-Minimal(±10%) returns.Pump 60 bbls.down IA w/8 bpm,2000 psi.-Bled back 30 bbls.Attempt to circ.long way w/1 bpm, 1030 psi-_Minmal(±j , , Pump down DP/casing to achieve rate-7 bpm,2250 psi. -Line up to Halliburton cementers: -Pump 10 bbls seawater ahead-3 bpm, 1100 psi.-Test lines to 4000 psi. -Pump 60 bbls dual spacer atn 12.5 ppg.-3 bpm,1330 psi. -Pump_113,5 bbls(554 sx)Class"G"cement at 15.8 ppg.w/yield of 1.15 and additives:0.65% HALAD 344-0.2%CFR-3&0.15°/-St;f1-100-=3:8 Tiprn,650 psi. -Drop DP wiper plug-Kick out w/20 bbls seawater w/7 bpm, 1300 psi. -Line up to rig pumps-Displace w/9.8 ppg LSND mud-8 bpm,2060 psi. -Observe DP wiper plug latch 15 bbls early(612 stks). -Slow pumps to 3 bpm,900 psi.Bump plug w/3500 psi and 5271 stks.(calculated+1/2 shoe volume).Hold 3500 psi f/5 min.Bleed off and check floats(Held).CIP at 11:50 hrs. *NQ return ,duringwhile performing cementim operations. -PU to free travel and set down 50K to set packer.Rotate on top.Repeat process.CBU x1. LD cement head and equip.POOH.LD DC's.-LD Weatherford running tool.PU Rhino Reamer and break off bullnose.Change top rams from 9-5/8"to 2-7/8"x 5"variables. 6/15/2011 6/16/2011 11,986.0 9.85 C,benge_topjanys Born 9,5L 1 2.18 c2. Fs.Test casing and liner lap to 3500 psi held and charted 30 min-Good test.Total time from cement in place to time of test=12 hrs 40 min. Cement lab test compressive strength at 12 hrs=1753 psi.Cement lab test compressive strength at 24 hrs=2791 psi.ND BOPE and drilling riser. Install Multi-bowl wellhead,and test same to 5000 psi charted for 10 min-Good test.NU drilling riser and BOPE.Test upper rams to 250 psi low/4500 psi high with 5"DP.Tested choke and kill line to 250 psi low/4500 psi high. Pull test plug and install wear bushing.TIH with BHA#10 f/surface 011,671'.Wash down f/11,671'to tag cement at 11,725'.Drill cement f/11,725'011,767'.Circulate hole clean with 2x bottoms up.POOH f/11,766'011,576'performing MADD pass for CBL. 6/16/2011 6/17/2011 11,986.0 9.85 POOH f/11,576'1110,000'performing MADD pass for CBL.POOH f/10,000'1/surface. Down load BAT Sonic data and send in to HES for interpretation.Perform rig maintenance while waiting on CBL log interpretation and acceptance from AOGCC.PU mill assembly while loading MWD tools into pipe shed.Pick up MWD tools,and shallow pulse test MWD-Good test,and scribe milling assembly.TIH picking up whip stock,and BHA f/183'U927'. 6/17/2011 6/18/2011 11,675.0 31.00 9.80 TIH with whipstock f/927'011680'.Wash down f/11,680'U11,765',while orienting at 33L to set whipstock.Set whipstock,gt cj,r with g, weight at 11,ZS5..PU 15k over PUW to confirm anchor set.Shear off of whipstock with 45k,over pull.Pump 25 bbls lube pill followed by 30 bbl lube pill and circulate raising lube concentration to 6%.Mill window in 9-5/$Sang• f/1_1,656'_ 011,706'.TOW 11,658';BOW 11,675'.Trace amounts of cement confirmed in cuttings on bottoms up.Pump 60 bbl hi-vis weighted sweep and circulate the hole clean with 4x bottoms up. ._P__erformFlT at.524Ttvd with 9 8 ppg_WBM to 1150 psi for EMW 14.0 ppg.POOH with mill assembly f/11,668'117,192'. --� 6/18/2011 6/19/2011 11,706.0 17.00 9.80 POOH with mill assembly f/7,192't/5,766'.Drop ball,pump down same,open pump out sub- circulate 2x bottoms up.POOH with mill assembly f/5,766'U surface.Remove wear bushing and install junk screen wear bushing.Make up BOP flushing tool with cross over to flush BOP stack, and while torqing up connection-flow tool fell off of cross over and went thru iunk screen in the hole.Cross over pin was HT 38 not XT 39.TIH with 2 stds DC and kelly up top drive to slip and cut drill line.Slip and cut 75'of drill line.PU fishing BHA and TIH with same f/surface 1/11,658'. to Wash&ream past whipstock at 11,658'and wash over fish at 11,723'.Washed over fish (t� f/11,697'1111,723'.Extremely soft bottom-Stack 10k while rotating,stop rotary and attempt to stack 25k with no success.Stacked up 25k at 11,723'. Page 5/10 Report Printed: 8/19/2011 PI 0 N E E R `erations Summary Report - Stat- Well Name: ODSN-23i NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 6/19/2011 6/20/2011 11,723.0 0.00 9.85 POOH_with fishing BHA f/11723'U�urface-no fish.Clean and inspect overshot and grapple- LD same.LD 6-6 1/2"DC from derrick while verifying lengths on new BHA.TIH picking up cement BHA f/surface 011,658'.Wash&ream past whip stock at 11,658'and wash down to fish at 11,719'.RU cement manifold and lines.PJSM with all personnel for pumping balanced plug. Line up to Halliburton cementers:Pump 15 bbls seawater ahead.Test lines to 4000 psi.Pump 16 bbis 1Q1 sx Class"G"cement at 17.0 ppg.w/yield of 1 00 and additives:0.06% IALAD 344 -0.75%CFR-3&0.3%SCR-100.Pumped 3 bbls seawater behind.Line up to rig pumps, Displace w/193 bbls 9.8 ppg LSND mud at 8.5 bpm with 1,600 psi.CIP @ 2230 hrs.POOH 1/11,718'011,391'.Squeeze cement at 5,247'tvd,with 9.8 ppg to 1010 psi for 13.5 ppg EWM. Install DP wiper ball in string and circulate to clear cement from DP. 6/20/2011 6/21/2011 11,723.0 21.00 9.85 Ream in the hole 1/11,486'011,665'-to clean preen cenitatirgaLcasing,Back ream 1/11,655' 011,581'.CBU at 11,581';monitor well-static,pump dry job.PU and break down cement manifold-LD same.POOH 1/11,581'U surface.PU directional BHA f/surface U467'-shallow pulse test same-Good test.TIH f/467'011,601'.Circulate&reciprocate 1/11,601'011,648'while orienting TF at 30L.TIH 1/11,648'011,675'-did not tag cement plug.Pull up 011,601'and CBU- no indication of green cement.TIH 1/11,601'011,710'-tag cement with 25k.Orient TF at 40L, and work trough 1/11,690'011,710';_slide thru cement 1/11,710'1/11,723'-did not tag fish.Slide drilling to kick off 1/11,723'011.744'. 6/21/2011 6/22/2011 11,744.0 333.00 9.80 Directional drilling 1/11,744'012077'.Circulate 5x OH volume while reciprocating 1/12,077' 011,937'.POOH 1/11,937'011,601'on elevators-max drag 25k.Circulate hole clean with 3x bottoms up. Notified AOGCC at 13:00 hrs on 06/21/11of early bi-weekly BOPE test to be perform on 06/22/11.AOGCC representative Bob Noble asked for update at 06:00 on 06/22/11.Called AOGCC again at 17:00 hrs on 06/21/11 and informed them that the test would be at 06:00 hrs on 06/22/11.Representative John Crisp notified Co-man Joey Cortez at 17:30 hrs on 06/21/11 that he would be witnessing the test on 06/22/11. 6/22/2011 6/23/2011 12,077.0 0.00 9.80 Pump dry job,and POOH 1/11,505'U surface.Service rig and top drive while changing out saver 9 sub on top drive.Remove wear bushing and install test plug.RU testing equipment and test BOPS w/5"test joint as ner AOGCC PTD.Test upper and lower variable rams to 250 psi low/ 4500 psi high.Test upper and lower IBOP valves to 250 psi low/4500 psi high.Test annular w/ di:111 5"test joint to 250 psi low/2500 psi high.Test all floor valves to 250 psi low/4500 psi high.Test 14 choke manifold valves to 250 psi low/4500 psi high.All tests charted and all test held for 5 min.Test witnessed by AOGCC Rep.John Crisp.Initial system psi=2900; 1900 after closure; 200 psi=23 sec,full pressure 1 min.40 sec.Pull trip nipple and install MPD test flange.Test MPD lines to 250 psi/3500 psi-Good test.Pull test flange and install trip nipple.TIH picking up directional BHA f/surface U531.Up load LWD data,shallow pulse test same-Good test.TIH 1/531'011,570'.Circulate while function testing MWD and GeoPilot-Good test. 6/23/2011 6/24/2011 12,077.0 888.00 10.20 Pull trip nipple and install RCD head.TIH 1/11,570'011,951'.Wash and ream 1/11,951'012,077'. Drop 1-1/4"ball and pump ball on seat with 230 gpm at 700 psi,and sheer ball seat at 1700 psi to engage under reamer cutters.Raise pump rate to 650 gpm to fully expand cutter blades. Saw 1k increase in torque and 400 psi decrease in pump pressure to verify blades are open.Under ream 1/12,046'012,064', and stack 10k at 12,064'to confirm cutters open.Directipn_I_.gfilling ,f/12 077'012,965'.._ 6/24/2011 6/25/2011 12,965.0 605.00 10.20 Directional drill 7"hole 1/12,965'013.168',Change out RCD bearing due to element failure. Directional drill 7"hole 1/13,168'U13,208'-started losing 250-300 bph at 12,178'.POOH 1/13,208'013,152'and monitor well.Spot 45 bbl 50 ppb LCM Pill at 13,178'and pull above pill 013,120'.Establish circulation using step rate method from 2 bpm to 675 gpm with unsustainable losses @ 360 bph.Monitor well while mixing LCM pill,and building volume at rig pits and RSC. Load 60 bbl fresh water and 95 bbls of 120 ppb LCM treatment into drill pipe and displace to bit. Shut choke and bullhead water into loss zone. Open choke and continue to pump LCM out of drill string @ 10 bpm.Monitor well while mixing LCM pill and building volume at rig pits and RSC. Wash and ream in the hole 1/13,175'013,208'-Initial losses 210 bph with 13.0 ppg EMW. Directional drill 7"hole 1/13,208'013,570'-Losses reduced to 0 while drilling. Total whole mud losses to hole for 24 hours is 1079 bbls. 6/25/2011 6/26/2011 13,570.0 521.00 10.20 Directional drill 7"hole 1/13,570'014.091'.CBU 5x while opening the pilot hole utilizing the Sperry GeoPilot Quadrant Technique.Pump out the hole 1/13,760'011,628'.TIH 1/11,628' 014,091'.Circulate the hole clean with 3x bottoms up at 14,091'. Page 6/10 Report Printed: 8/19/2011 erations Summary Report - Stab- Well Name: ODSN-23i PIONEER NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 6/26/2011 6/27/2011 14,091.0 0.00 12.95 Finish circulating the hole clean with 4x bottoms up at 13,951'.Stood back one stand every 45- 60 minutes t/13,760'.TIH f/13,760't/14,091'.Displace the well from 10.4 ppg WBM to 13.0 ppg WBM.Stood back one stand every 30 minutes 013,379'.Pump out the hole f/13,379'011,595'. Monitor well-static.Remove RCD bearing and install trip nipple.POOH f/11,595'011,379'-well swabbing.Pump out the hole f/11,379'U9,570'-hole taking proper displacement.Trouble shoot iron rough neck and replace hydraulic control assembly. POOH on elevators f/9,570't/5,572'. Spot 50 bbl EP Mud Lube pill at 5,572'and chase same with dry job.POOH on elevators f/5,572' U surface laying down BHA. 6/27/2011 6/28/2011 14,091.0 0.00 12.95 Finish laying down BHA f/76',and clear rig floor of same.Remove wear bushing and install test plug.Change top pipe rams from 2-7/8 x 5"VBR's to 7"casing rams.Test same with 7"test joint to 250/4500 psi.Tests held on chart for 5 min each- Good test.Remove test plug and install wear bushing-LD 7"test joint.TIH with 6 joints of 5"HWDP,pump thru same and rack back in derrick.RU 7"casing equipment and Tesco tool.Held PJSM with all personnel.MU auto-fill float equipment,RIH with 7"26#.L-80.Hvd 511 casino f/surface 02.561'.RD Tesco tool. MU liner hanger,and packer assembly f/2,561'U2,803'.TIliwith 7"IineLpn 5"QP f12.$03'010,319'. 6/28/2011 6/29/2011 14,091.0 0.00 10.30 TIH with 7"26#L80 Hyd 511 liner f/10,318'(111,658'.Attempt to est circulation f/0.5 bpm to 2 bpm @ 500 psi with partial returns.TIH with 7"26#L80 Hydril 521 Liner f/11,620' 014,082'.Fill Pipe and attempt to establish circulation.$tape pumps from 0 5 hpm to 1 5 hpm with./100 psi and .partial returns Failed attempt to reciprocate pipe to alleviate suspected pack-off slttTattorrwitfrne success.Attempt to est circ while pressuring up in 50 psi increments from 500 psi to 750 psi. Shut in annular preventor and perform Extended LOT down annulus to verify liner lap not packed off.Line up to pump down DP and attempt to establish circulaton.Bleed pressure on drill pipe. Close annular preventor and line up on kill line. Bullhead 360 bbls of 10.2 ppg drilling fluid down back side.Trap pressure on annulus while breaking out cement head,connect cementing hose, drop hanger setting ball and MU cement head.Establish Circulation down drill pipe to 4 bpm @ 650 psi while taking returns through the choke and kill lines.Pressure up to 1500 psi and set hanger,pressure up to 2500 psi to release setting tool,and shear ball seat at 3000 psi.PU and confirm running tool released.Establish circulation and use step,rate method tQ increase t0 7. pm while circulating and conditioning MW to 10.2 ppg with full returns._PJSM with all involved personnel.Line up to cementers:Pump 10 bbls seawater ahead,test lines to 4000 psi.Pump 40 bbls dual spacer at 12.5 ppg.Pump 60 6bbls i293 sx1 Premium cement at 15.8 ppg_w/yield of 1.16 and additives:0.7%HALAD 344 0.2%CFR-3&0.5%SCR-100.Drop DP wiper dart-Kick out w/20 bbls seawater.Line up to rig pumps-Displace w/10.2 ppg WBM --Full returns Did not see DP wiper dart latch liner wiper plug. Bump plug w/3,061 stks-full returns.CIP @ 2245 hrs.Pressure up to 3500 psi and hold for 5 min to test casing after bumping plug-Good test.PU to expose packer setting dogs,and set packer with 50k,and 20 rpm. 6/29/2011 6/30/2011 14,091.0 0.00 10.25 Circulate hole clean with 1.5x bottoms up with#2 pump while working on#1 mud pump.Pump dry job and POOH laying down 5"DP.LD Weatherford liner running tool.Service rig.Repair Iron Roughneck.Change top rams from 7"to 2-7/8"x 5"Variables.Function test BOPE per AOGCC weekly requirements.RIH w/5"DP from derrick 02,668'.POOH LD same.LD all 5"rotary tools and PU 4"rotary tools.Remove 5"saver sub and IBOP from Top Drive. 6/30/2011 7/1/2011 14,091.0 10.00 Install test plug. Install 4"test joint. -Test annular w/4"test joint to 250 psi low/2500 psi high. /n� -Test upper and lower variable rams w/4"test joint to 250 low/4500 psi high. �7 f -Test Upper&lower IBOP to 250 low/4500 high. �A�1 -Test 2,4"FOSV and dart valve to 250 low/4500 psi high. -All tests charted and held for 5 min.each test.RD test equipment.Mobilize polish mill BHA to rig floor.MU BHA.RIH PU 4"DP f/pipeshed f/62't/9,797'.Break circulation and circ.DP vol. Continue PU 4"DP 011,410'.Tag top of 7"liner w/No-Go at 11,488'. PU and break circ.Rotate down w/30 rpm&5 bpm,500 psi.No-go on liner top w/polish mill 2x.PU 20'above liner top. CBU 3x w/625-650 gpm.R&R DP 45'w/80 rpm.Close top rams.Pressure test 11-3/4"x 9- 4'-; 5/8"x7"casing to 3500 psi f/30 charted min.Good test. Page 7/10 Report Printed: 8/" PI 0 N E E R erations Summary Report - Stet( Well Name: ODSN-23i NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 7/1/2011 7/2/2011 14,091.0 10.00 Finish casing test and bleed pressure.Service rig.POOH standing back 4"DP f/±11405't/62'. LD polish mill assembly.Change top rams from 2-7/8"x 5"vbls to 7". Pull wear ring. Install 7" test joint.Test upper 7"rams to 250 psi low/4500 psi high for 5 charted min.each test.RD test), equipment.RU&run 7"26#L-80 BTC casing f/surface t/4.397'. /�` **AOGCC was given 48 notice of upcoming BOPE test at 20:00 hrs on 07/01/11. **AOGCC Rep.Chuck Scheve waived witness of test at 20:10 hrs on 07/01/11. 7/2/2011 7/3/2011 14,091.0 9.80 Continue RIH w/7"26#L-80 BTC casing f/4,397'U11,488'.Space out w/pup jts.RD Tesco casing tools.PU casing hanger&landing joint No-go out on liner top at 11,488'w/35k down wt. Land hanger in wellhead w/80k down wt. Pressure up on casing to 700 psi.PU and expose 4-1" ports on seal assembly and observe pressure bleed off.Circulate and condition mud for upcoming cement job. Pressure_test cement lines to 4000 cn_i.Dron 1st bottom Klug Pump 40 bbls Hi-Visc.MOBM spacer at 10.0 ppq_Pump 550 gt�,Ig 10.0 ppg M,Q.B as freeze protect;�Drgp bottom plug#2.Pump 34 bbls(176 sx)class"G"cement at 15.8 ppa.Drop top plug and kick out w/3 bbls 15.8 ppg cement and 20 bbls seawater.Displace cement using rig pumps w/413.3 bbls 9.8 ppg LSND mud.Bump plug and pressure up to 3500 psi.(CIP @ 23:15 hrs.).Sting seals into PBR.Bleed pressure to 0 psi.Slack off and no-go onto liner top w/35k down wt..Continue to slack off and land hanger in well head w/80k down wt. 7/3/2011 7/4/2011 14,091.0 10.20 PU 4"test joint and MU Packoff running tool to same.Set 7"packoff per Vetco Rep.Test packoff to 5000 psi for 10 min.LD packoff tool&test joint.Change upper rams from 7"to 2-7/8"x vbls.Change upper 8‘,lower IBOP on T.D. Install tesj lug and 4"test joint.Test upper rams w/4" test joint to 250 psi low/4500 psi high for 5 charted min.each test.Remove test plug. Install wear ring.PU"Jon Whacker"on joint.4"DP.RIH PU 4"DP from pipeshed U9,157'.Circulate DP volume x 1.5 7/4/2011 7/5/2011 14,091.0 10.20 ***From 01:00 hrs to 01:45 hrs.,Rig crew participated in the Fire Drill/Arktos Drill. The Driller remained on the rig and all other personnel responded.POOH f/9,357'U surface.MU stack washer,5 joints.4"HWT,Jars and accelerators.Pump pipe volume.POOH.Stand back BHA.Blow down all lines.Pull wear ring.Verify 0 psi on OA.Pull 7"packoff.ND BOPE and stand back.PU 7"landing joint and engage hanger at wellhead.Pull 330k on casing.Set emergency slips and cut 7"casing using Wachs cutter.Install 7"packoff.Vetco Rep.tested packoff to 4300 psi for 20 minutes.NU BOPE.Set test plug and 4"test joint.Test upper rams and all breaks to 250 psi low/4500 psi high for 5 charted min each test.Pull test plug.Install wear ring.Mobilize cleanout BHA to rig floor. 7/5/2011 7/6/2011 14,092.0 10.00 10.20 Continue to mobilize BHA to rig floor.PU cleanout BHA per DD and MWD.Download MWD tools.PU BHA U±160'-Shallow pulse test w/250 gpm,400 psi.RIH f/160'U3,235'.Perform depth calibration between rig and MWD equipment.Continue RIH f/3,235'U11,037'.Wash and ream f/11,037 U11,250'.Tag cement at 11,250'.Drill cement and tag tieback F.C.at 11,384'.Drill F.C.Drill cememnt t/1"f,403':"Tesfthe OA to-3500 psi with diesel and the P6 pump out of critical path-charted same.Wash and ream f/11,403'U13,997'.Tag landing collar at 13,997'.CBU. Test 7"casing/tieback to 3500 psi for 30 charted min.Good test -charted same.Drill L.C. cement.Tag F.C.at 14,038'. Drill F.C.and cement.Tag Shoe at 14,080'.Obtain SPR.Drill shoe and clean out 8-1/2"hole U14,092'. Drill new hole f/14,092'U14,_102'. 7/6/2011 7/7/2011 14,102.0 10.00 10.20 Continue drilling new hole f/14,102'U14,112'(total 20'new hole).CBU.Perform FIT to 12.5 ppq. EMW:7"shoe TVD=6,176'-MW=10.2 ppg.-750 psi=12.54 ppg EMW.Good FIT.Run back in hole U14,112'.POOH making MAD Pass w/BAT Sonic tool at 270-290 fph f/14,112'U11,675'. Continue POOH f/11,67b'U surface.Download BAT Sonic tool.LD N.B.stab andf bit.Pull Wear ring.PU 3-1/2"test joint.Install test plug.RU to test BOPE.Test BOPE per AOGCC PTD: Test Annular w/3-1/2"test joint to 250 psi low. gA **AOGCC was given 48 notice of upcoming BOPE test at 20:00 hrs on 07/01/11. **AOGCC Rep.Chuck Scheve waived witness of test at 20:10 hrs on 07/01/11. -AOGCC Rep.Lou Grimaldi re-confirmed waiving of witness at 20:50 hrs.on 07/05/11. Page 8/10 Report Printed: 8/19/2011 PI 0 N E E R erations Summary Report - State Well Name: ODSN-23i NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 7/7/2011 7/8/2011 14,112.0 0.00 10.20 Continue to test BOPE per AOGCC PTQ,_. -Test annular w/3-1/2"test joint to 250 psi low/3500 psi high-Annular test failed. -Continue to test BOPE: -Test upper and lower variable rams w/3-1/2"to 250 psi low/4500 psi high. -Test upper and lower IBOP valves to 250 psi low/4500 psi high. -Test all floor valves to 250 psi low/4500 psi high. .f 1 -Test 14 choke manifold valves to 250 psi low/4500 psi high(While POOH). b° -Pull 3-1/2"test joint-Install 4-1/2"test joint j t -Test upper and lower vbls rams w/4-1/2"test joint to 250 psi low/4500 high. -Initial system psi=3000, 1950 after closure,200 psi=27 sec,full pressure. 1 min.54 sec. -All tests charted and all tests held for 5 min. **Two failures: 1.Annular failed.Change element and re-test to 250 psi low/2500 high.Passed. 2.2"Demco valve to kill line on mud manifold.Rebuilt valve.Tested to 250 psi low/4500 high. Passed -Right to witness test waived by AOGCC Rep.Lou Grimaldi at 20:50 hrs.on 07/05/11. Rig down MPD equip.Change out annular element and seals.Test annular to 250 psi low/ 2500 psi high for 5 charted min each test.RU MPD equip.Test MPD equip to 250 psi low/3500 psi f/5 min each test.Pull test plug.RD RCD and test flange. Install wear ring,trip nipple and mousehole.Service rig.PU BHA 11133'.Download MWD.Continue PU BHA and RIH w/4"DP 1/1,855'. 7/8/2011 7/9/2011 14,112.0 1,140.00 7.60 Continue RIH w/BHA#18 f/1,855'114,265'.Fill pipe.Pulse test MWD.Continue RIH to 7"shoe at 14,082'.Pump 40 bbls 10.2 ppg WB mud spacert+85 bbls 7.4 ppg MOBM.Pull trip nipple. Install RCD head.Establish circulation with MPD.Displace well from 10.2 ppg LSND to 7.4 ppg MOBM.Directional drill 6-1/8"hole f/14.112'1115.252'maintaining 9.8 ppg EMW w/MPD. 7/9/2011 7/10/2011 15,252.0 2,601.00 7.70 Directional drill 6-1/8"hole f/15,252'1117,853'maintaining between 9.94 ppg-10.05 ppg EMW w/ MPD. 7/10/2011 7/11/2011 17,853.0 2,215.00 7.70 Directional drill 6-1/8"hole f/17,853'1/20,068'maintaing 10.25 ppg-10.30 ppg EMW w/MPD 7/11/2011 7/12/2011 20,068.0 482.00 7.70 Directional drill 6-1/8"hole f/20,068'1120,165'maintaining 10.34 ppg EMW w/MPD.Backream stand while onsite Geologist evaluated logs.continue drilling 6-1/8"hole f120.165'1120.550'(6- 1/8"TD)maintaining 10.25 ppg EMW w/MPD.Circulate bottoms up 2x.Backream out of hole f/20,550'(/17,371'.Change RCD head(element failure).Continue to backream out of hole f117,371'(/14,082'(7"shoe). 7/12/2011 7/13/2011 20,550.0 0.00 7.70 Pump H.V.10.1 ppg weighted sweep surface to surface+1/2 B.U. Cut&slip 97'of drilling line.Change out saver sub on Top Drive.Service Rig.RIH(/20,100'. Break circ at 20,100'.Change RCD head(element failure).Circulate hole clean by CBU lx, pump 50 bbls 10.1 ppg HV sweep,CBU lx.Spot 6.9 ppg LVT across lateral section leaving 60 bbls in DP for circulating contigency.POOH on elevators 1/15,542'.Displace LVT out of DP laying in open hole lateral section.Chase with 10.1 ppg HV spacer.Follow with 7.7 ppg MOBM placing 10.1 ppg at bit. 7/13/2011 7/14/2011 20,550.0 0.00 10.10 PQQH spotting 10.1 ppg hi-vie Dill f/15,200'1/14,08Z,Circulate and displace well from 7.7 ppg to 10.1 ppg MW.Mud wt in 10.1 ppg,mud wt out 9.6 ppg.Remove RCD head and install trip nipple. Circulate thru chokes and displace well from 9.6 ppg to 10.1 ppg.Mud wt in 10.1 ppg,mud wt out 9.2 ppg.Open annular,circulate and displace well from 9.2 ppg to 10.1 ppg.Mud wt in 10.1 ppg, mud wt out 10.1 ppg.Monitor well-static,circulate while mixing and pumping dry job.Function test BOP equipment-Good test.POOH(SLM)f/14,082'11133'.PJSM and remove nuclear sources from LWD.Down load MWD/LWD data. 7/14/2011 7/15/2011 20,550.0 0.00 10.10 Finish down loading LWD data.Lay down BHA f/133'1/surface.RU casing equipment to run 4.5" production liner.RIH with 4.5"L-80 12.6#Hyd 521 liner f/surface 116,162'.Pick up WFT"PHR' hanger,"NTH"packer,and MI razorback casing scraper--magnet assembly f/6,162'1/6,435'.TIH with 4.5"liner on 4"DP f/6,435'1/14,047'.Circulate DP volume at 14,047',and est PUW,SOW, and torque reading.TIH with 4.5"liner on 4"DP f/14,047'1/16,164'. Page 9/10 Report Printed: 8/19/2011 PI 0 N E E R erations Summary Report - StatE Well Name: ODSN-23i NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 7/15/2011 7/16/2011 20,550.0 0.00 10.10 TIH with 4.5"liner on 4"DP f/16,164'U20.098'._Establish circulation using step rate method.Drop 1.75"aluminum ball and pump down on seat to set liner hanger.Set liner hanger with 1500 psi, slack off 25k to set hanger.Rhear hall seat at 3300 psi SPt packPr with .k,TOL at 13,912'; shoe at 20,100'.Test liner top packer to 3500 psi-held 30 min on_gha):t-Good test.Displace well from 10.1 ppg OBM to 10.1 ppg brine.Pump 75 bbls spacer and displace with 645 bbls 10.1 ppg brine.Monitor well-ballooning back brine lost while displacing.TIH f/13,910't/13,410'-well flowed 1.5 bbls back.CBU with 10.1 ppg brine-monitor well for 15 min-static.POOH f/13,410' U surface-lay down WFT running tool,and magnet-scraper assembly.Remove wear bushing and install wear ring junk basket. 7/16/2011 7/17/2011 20,550.0 0.00 10.10 MU BOP flushing tool,wash out stack,and pull wear ring junk screen.RU casing equipment for Q, .prppletion run.Held PJSM with all personnel involved for running completion.RIH with 3.5" L-80 9.3#TC-II tubing f/surface 01,372'.Install ROC gauge and I-wire in gauge carrier,Test(- wire to 500 psi held 5 min-Good test.Test ROC gauge to 5000 psi,held 15 min-Good test. RIH with 3.5"L-80 9.3#TC-II tubing f/1,372'011,898'. 7/17/2011 7/18/2011 20,550.0 0.00 10.10 MU SSSV with control line-test same to 5000 psi, 10 min-Good test.BIH with 3 3# TC II tubing(/11898't/13 912'.Circulate at 2 bpm and confirm No-go on liner top at 13,912'-lay down 3 joints and space out with 9'pup.MU tubing hanger and make control line penetrations thru same.Reverse circulate 260 bbls corrosion inhibited 10.1 ppg brine into IA.Land hanger at 13,910'-run in LDS.Test upper and lower tubing hanger seals-upper seal failed.Pull hanger, found cut 0-ring-redress same.Land hanger at 13,910',run in LDS.Test upper and lower hanger seals to 5000 psi 10 min on chart-Good test.RU lines on tubing and IA-test lines to 4500 psi.Set packer with 4200 psi down tubing on chart 30 min.Attempt to test packer down IA to 3500 psi-unsuccessful.Test all surface lines-Good test.Change out landing joint and elevators to 4"DP.Back out LDS on hanger and unseat same with 150k.PU to string wt at 125k -attempt to get 50k over pull-no over pull acheived.PU 3'of free travel-packer apparently not set.Qecision made to Dull comoletion.,L.and hanger and run in LDS.RU slickline unit and lubricator to retrieve ball and rod. 7/18/2011 7/19/2011 20,550.0 0.00 10.10 RU slickline unit and lubricator to retrieve ballnaj rg._Test lubricator to 1000 psi-Good test. RIH with JDC tool and retrieve ball bar rod at 12,806'wlm.RD slickline unit and lubricator.RU tubing equipment and pull landing joint.Cut control lines,and install BPV in tubing hanger.Slip and cut 75'of drill line and send TEC wire spool off of floor.Open SSSV and fill tubing with 6 bbls 10.1 ppg brine.RU mouse hole in rotary to LD 4"DP.LD 75 stands of 4"DP from derrick using mouse hole.PJSM and RU tools to pull completion and spools for control lines.Remove BPV,install 4"landing joint,and pull hanger to rig floor.Remove control line and TEC wire from hanger,and LD hanger with landing joint. 7/19/2011 7/20/2011 20,550.0 0.00 10.10 Pressure up to 4000 psi on control line to open SSSV.POOH with 3.5"completion f/13,926' t/1,853'.Hydraulic leak on top drive-change out seal on counter balance assembly.POOH with 3.5"completion f/1,853'11 surface.Inspect mule shoe,clean rig floor,and held PJSM for TIH. RIH with 3.5"L-80 9.3#TC-Il tubing f/surface 01,355'.Change out control line and TEC wire spooling units. 7/20/2011 7/21/2011 20,550.0 0.00 10.10 Change out control line and TEC wire spooling units.Make up ROC gauge carrier,install ROC gauge and test gauge to 5000 psi for 15 min,and 500 psi for 5 min-Good test.RIH with 3.5"L- 80 9.3#TC-Il tubing f/1,356'011,897'.MU SSSV,install control line and test control line to 5000 psi for 15 min-Good test.RIH wixhal J-80 9 3#TC-Il tubing(/11_897''1/13 OW,Tag liner top at 13,909'-space out to land hanger at 13,907'.MU tubing hanger,and make control line penetrations thru same.Spot 90 bbls corrosion inhibited brine and chase with 135 bbls 10.1 ppg brine.Land hanger at 13,907'run in LDS,and test upper and lower tubing hanger seals to 5000 psi 10 min on chart-Good test.Drop ball bar rod after landing tubing.RU lines on tubing and IA -test fines to 4500 psi.Set packer,with 4200 psi down tubing on chart Qlnin..Test packer down annulus to 3500 psi for 30 min on chart-Good test.RD test lines,LD landing joint,cut control lines,and install BPV in hanger.Nipple down BOPE and drilling riser.Make all control line penetrations thru well head and test same-Good test.Test SSSV control line to 5000 psi.ROC gauge=2,982.4 psi, 145.49 degrees,with 12.81 ma current.Install and nipple up production tree and test same-Good tests.Test void to 5000 psi held 10 min on chart.Test tree to 250 psi low/ 5000 psi high on chart 5 min each. **RIG RELEASED AT 23:59 HRS 07/20/11** Page 10/10 Report Printed: 8/19/2011 Current Schematic - State Well Name: ODSN-23i PIONEER NATURAL RESOURCES HORIZONTAL-Sidetrack 2,8/17/2011 6:08:05 PM Well Attributes Vertical schematic(actual) API/UWI Field Name Well Status Total Depth(ftKB) 50-703-20639-00-00 Oooguruk Unit DRILLED 20,165.0 Casing Strings I1-2 Conductor,158.0ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft.. Set Dept... Grade Top Connection Wt/Len(11D/ft) Conductor 16 14.670 47.7 158.0 H40 Welded 109.00 J 1 LCasing Components 1-1 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com 1-1 Conductor Casing Joints 47.7 47 16 14.670' 1-8Iic s Surface,5,777.0ftKB Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept... Grade Top Connection WllLen(Ib/ft) 1-12 4-1 Surface 11 3/4 10.772 0.0 5,777.0 3,170.6 L-80 Hyd 521 60.00 6 14-2 Casing Components 4-3 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com I 2-10 Surface Casing Shoe 5,775.0 3,170.1 11 3/4 10.772 HES Super Seal II 12-10 Autofill FS 11-16 A I'ma 7"Intermediate 2 Tie-back,11,493.6ftKB # Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept_- Grade Top Connection Wt/Len(Ib/ft) 1-20 • 7"Intermediate 7 6.276 5.6 11,493.6 L-80 BTC-M 26.00 2 Tie-back 5-1 9 5/8 Drilling Liner,11,887.0ftKB `mi® Description OD(in) ID(in) Top(ftKB) Set Depth(ft...'Set Dept... Grade Top Connection Wt/Len(Ib/ft) 5-4 9 5/8 Drilling 9 5/8 8.835 5,594.2 11,887.0 5,351.5 L-80 HYD 521 40.00 t Liner i i Casing Components 14-101 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com 11-2 14-1 Liner Tie Back Sleeve 5,594.2 3118 9 5/8 8.835 1-288 I I 4-2 TSP4R Liner Top Packer 5,615.8 3124 9 5/8 8.835 II 4-3 PHS Liner Hanger 5,618.0 3125 9 5/8 8.835 11-33 4-10 9-5/8"Drilling Liner Shoe 11,884.7 5,350.4 10 8.835 Ray Oil Tool Ecentric 1/16 Float Shoe 11-38 I— 7"Intermediate 2 Liner,14,089.0ftKB IDescription OD(in) ID(in) Top(ftKB) Set Depth(ft_. Set Dept....Grade Top Connection Wt/Len(Ib/ft) 1-42 - 7"Intermediate 7 6.276 11,493.6 14,089.0 6,173.8 L-80 Hyd 511 26.00 2 Liner 1-47 Casing Components 1-48 6 1 Top(TVD) i ♦ if 6-2 Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn 76-3 5-1 Polish Bore Receptacle 11,493.6 5173 7 6.276 5-2 WFT TSP5 Liner Top Pkr 11,514.5 5182 7 6.276 5-11 5-4 PHR Liner Hanger 11,519.3 5185 7 6.276 1 6-7 5-11 7"Float Shoe 14,086.9 6,173.3 7 6.276 6-11 4 1/2"Production Liner,20,100.0ftKB 6 14 Description OD(in) ID(in) Top(ftKB) Set Depth(ft... Set Dept.. Grade Top Connection Wt/Len(Ib/ft) 6-16 4 1/2" 4 1/2 3.920 13,912.3 20,100.0 6,218.5 L-80 4.5 Hyd. 12.60 6-18 Production 521 NEN 6-20 Liner miss 6-22 Casing Components MEM 6-24 Top(TVD) vs MINN Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Corn mm 6 26 tv 6-1 Weatherford 16'PBR Tie- 13,912.3 6,132.7 5.77 5.250 II /6-28 6-30 back Sleeve Il no Li 6-32 6-2 Weatherford 5"x 7"NTH 13,927.6 6,136.2 4 1/2 3.920 mimFs 6-34 Liner Top Pkr. nomZ 6-36 6-3 Weatherford PHR Hyd. Rot 13,930.9 6,137.0 5.93 4.000 am 6-38 Hanger Ai 6-40 6-7 Sliding sleeve w/6-1/2" 14,256.6 6,202.7 5.63 3.920 6-43 ports(OPEN) 6-47 6-11 Weatherford Oil Swell Pkr. 14,508.6 6,220.7 4 1/2 3.920 6-50 la 6-52 .1710 if 6-54 imm0 if 6-56 ® if 6-58 m 6-60 ,6-62 -6-66 6-66 Page 1/3 Report Printed: 8/17/2011 PI 0 N E E R Current Schematic - State Well Name: ODSN-23i NATURAL RESOURCES HORIZONTAL-Sidetrack 2,8/17/2011 6:08:25 PM Casing Components Vertical schematic(actual) Item# Item Des TopTop(TVD) (ftKB) (ftKB) OD(in) ID(in) Corn 6-14 Perforated Pup Joint w/6- 14,686.9 6,228.5 4 1/2 3.920 1-2 - -1-- - 1/2"Ports 6-16 Perforated Pup Joint w/6- 14,849.8 6,235.8 4 1/2 3.920 J I 1/2"Ports 6-18 Perforated Pup Joint w/6 15,051.3 6,245.0 4 1/2 3.920 1-1 1/2"Ports 1 8 -- 6-20 Perforated Pup Joint w/6 15,255.6 6,245.7 4 1/2 3.920 1/2"Ports • 6-22 Perforated Pup Joint w/6- 15,459.1 6,231.2 4 1/2 3.920 11-12 4-1 1/2"Ports p' J4-2 6-24 Perforated Pup Joint w/6- 15,659.5 6,218.4 4 1/2 3.920 4-3 1/2"Ports II 6-26 Perforated Pup Joint w/6- 15,863.8 6,205.2 4 1/2 3.920 2-10 1/2"Ports 1-16 s 6-28 Perforated Pup Joint w/6- 16,063.7 6,193.4 4 1/2 3.920 1/2"Ports 1-20 ! 6-30 Perforated Pup Joint w/6- 16,265.7 6,187.2 4 1/2 3.920 1/2"Ports ill 1 5 1 6-32 Perforated Pup Joint w/6- 16,468.3 6,181.8 4 1/2 3.920 _ 1/2"Ports 5 4 6-34 Perforated Pup Joint w/6 16,673.0 6,178.8 4 1/2 3.920 I 1/2"Ports r 6-36 Perforated" Pup Joint w/6- 16,873.7 6,176.5 4 1/2 3.920 4-10 1/2Ports 1-241 -- 6-38 Perforated Pup Joint w/6- 17,078.7 6,180.3 4 1/2 3.920 1-28 — 1/2"Ports 6-40 Perforated Pup Joint w/6- 17,278.9 6,191.2 4 1/2 3.920 1/2"Ports 1-33 6-43 Weatherford Oil Swell Pkr. 17,485.1 6,206.2 4 1/2 3.920 1-38 6 47 Weatherford Oil Swell Pkr. 17,906.2 6,235.0 5 3/4 3.920 11-42 i 6-50 Perforated Pup Joint w/6- 1/2"Ports 18,284.8 6,246.1 4 1/2 3.920 1-47 I 6-52 Perforated Pup Joint w/6- 18,478.6 6,232.4 4 1/2 3.920 1-48 r = 6-1 1/2"Ports i6-2 6-54 Perforated Pup Joint w/6- 18,677.9 6,218.9 4 1/2 3.920 IJ 6-3 1/2"Ports I 6-56 Perforated Pup Joint w/6- 18,875.3 6,207.6 4 1/2 3.920 5-11 1/2"Ports di 6-7 6-58 Perforated Pup Joint w/6- 19,076.4 6,200.4 4 1/2 3.920 6-11 1/2"Ports 6-14 6-60 Perforated Pup Joint w/6- 19,279.2 6,193.0 4 1/2 3.920 6-16 1/2"Ports Ai 6-18 6-62 Perforated Pup Joint w/6- 19,487.8 6,193.4 4 1/2 3.920 diU�y, 6-20 1/2"Ports IIIA- 6-22 6-64 Perforated Pup Joint w/6- 19,692.3 6,198.5 4 1/2 3.920 6-24 1/2"Ports al al 6-26 6-66 Perforated Pup Joint w/6- 19,895.8 6,208.8 4 1/2 3.920 6-28 1/2"Ports am 6-30 6-68 4.5"Liner Shoe 20,098.7 6,218.4 Weatherford(solid) EVE6-32 Eccentric Shoe �6-34 Tubing Strings AN 6-36 Tubing Description String M_. ID(in) Top(ftKB) Set Depth(f_.Set Dept_. Wt(Ib/ft) Grade Top Thread it 11 6-38 3.5"completion 3 1/2 2.992 0.1 13,907.3 6,131.5 9.30 L-80 TC-II ill 6-40 Tubing Components 6-43 Top(TVD) Item# Item Des Top(ftKB) (ftKB) OD(in) ID(in) Com 6-47 1-2 Vetco Gray Hgr with MAC 34.1 10 2.950 6-50 box x TC-II box 13/16 li 6-52 - – 6-54 .61. 6-56 6-58 AL 6-60 6-62 st NEI at 6-64 Imo 6-66 Page 2/3 Report Printed: 8/17/2011 PIONEER Current Schematic - State Well Name: ODSN-23i NATURAL RESOURCES HORIZONTAL-Sidetrack 2, 8/17/2011 6:08:45 PM Tubing Components Vertical schematic(actual) Item# Item Des Top(ftKB) Top(TVD) (ftKB) OD(in) ID(in) Com 1-8 HES Wellstar TRSV 1,997.2 1762 5.2 2.813 1-2 - w/2.813"X"profile 3.5"TC- IIb / 1-12 Vanoil 3.5 x 1.5 MMG GLM 2,496.5 2020 5.968 2.920 il j I w/3.5"TC-II bxp 1-1 1-16 Vanoil 3.5 x 1.5 MMG GLM `/ 6,602.5 3439 5.968 2.920 w/3.5"TC-II bxp / 11-8 - ' 1-20 Vanoil 3.5 x 1.5 MMG GLM 9,865.1 4545 5.968 2.920 w/3.5"TC-II bxp 1-124-1 1-24 HES ROC gauge mandrel 12,540.3 5,632.9 5.664 2.965 6 I 4-2 TC-II bxp ' +J4-3 1-28 HES 2.81 "X"Nipple 3.5" 12,588.5 5,652.6 3.96 2.813 II TC-II bxp 9 Cr 2-10 1-33 7"WFT Ultra Pak Hyd 12,671.4 5,686.3 5.865 3.937 Perm Prod Pkr I1-16 I 1-38 HES 2.81 "X"Nipple 3.5" 12,724.6 5,707.6 3.96 2.813 1-20 TC-II bxp 9 Cr 1-42 HES 2.81"XN Nipple 12,802.1 5,737.8 3.94 2.750 5-1 w/2.75 No-go w/RHC-m a ® plug in 5-4 1-47 Locator collar 13,897.5 6,129.2 5.8 3.958 I I 1-48 5"seal stem w/o seals w/ 13,898.5 6,129.5 5.2 3.958 I I indexing mule shoe 4-10 11-241 1-28 PE iii Ile 1-33 - - 1-38 hall '1-42 1-47 1-48 !Iii, 6-7 1•--As 6-11 6-14 6-16 jai 6-18 Xi 6-20 iiii 6-22 mum 6-24 6-26 AN diiiii 6-28 dir■ 6-30 nth A 6-32 6-34 mom 6-36 atm 6-38 AN 6-40 6-43 6-47 6-50 6-52 mini oa 6-54 Num rt 6-56 NEN 'i' /6-58 Ali 6-60 u r 6-62 ri mm vi 6-64 6-66 Page 3/3 Report Printed: 8/17/2011 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 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 ODSN-23i-Slot ODS-23 Well Position +N/-S 0.00 ft Northing: 6,031,018.57 ft Latitude: 70°29'44.931 N +E/-W 0.00 ft Easting: 469,788.76 ft Longitude: 150° 14'49.325 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-23i Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-23i IN14 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 11,658.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 274.77 Survey Program Date 7/13/2011 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 83.00 454.30 ODSN-23i Gyro Run100(ODSN-23i PB1 SR-Gyro-SS Fixed:v2:surface readout gyro single shot 05/16/2011 495.48 780.68 ODSN-23i MWD Run200(ODSN-23i PB'MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 05/16/2011 875.01 2,584.38 ODSN-23i MWD Run 400(ODSN-23i PB MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 05/23/2011 2,679.92 5,727.62 ODSN-23i MWD Run500(ODSN-23i PB:MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 05/24/2011 5,827.98 5,859.47 ODSN-23i MWD Run 600(ODSN-23i PB MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 05/31/2011 5,954.20 11,658.00 ODSN-23i MWD Run 700(ODSN-23i PB MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 06/01/2011 11,747.54 14,091.00 ODST-23i MWD Run 800(ODSN-23i) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 06/23/2011 14,152.43 20,514.89 ODSN-23i MWD Run 900(ODSN-23i) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 07/11/2011 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,018.57 469,788.76 0.00 0.00 UNDEFINED 83.00 0.11 124.69 83.00 26.80 -0.02 0.03 6,031,018.55 469,788.79 0.27 -0.03 SR-Gyro-SS(1) , 173.00 1.90 254.67 172.98 116.78 -0.46 -1.34 6,031,018.11 469,787.42 2.19 1.29 SR-Gyro-SS(1) 265,00 6.05 264.54 264.74 208.54 -1.33 -7.64 6,031,017.27 469,781.12 4.56 7.50 SR-Gyro-SS(1) 359.00 7.69 283.98 358.08 301.88 -0.28 -18.67 6,031,018.37 469,770.09 3.00 18.58 SR-Gyro-SS(1) 453.00 9.09 287.10 451.07 394.87 3.42 -31.88 6,031,022.12 469,756.90 1.57 32.05 SR-Gyro-SS(1) 587.93 13.80 284.62 583.28 527.08 10.62 -57.65 6,031,029.43 469,731.16 3.51 58.33 MWD+IFR2+MS+sag(2) 685.36 16.51 286.20 677.31 621.11 17.42 -82.19 6,031,036.32 469,706.65 2.81 83.35 MWD+IFR2+MS+sag(2) 7/14/2011 8:40:33AM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 780.68 21.35 281.09 767.46 711.26 24.54 -112.25 6,031,043.56 469,676.63 5.36 113.89 MWD+IFR2+MS+sag(2) 875.01 22.30 278.86 855.03 798.83 30.60 -146.78 6,031,049.76 469,642.12 1.34 148.81 MWD+IFR2+MS+sag(3) 966.28 21.46 281.45 939.72 883.52 36.58 -180.26 6,031,055.88 469,608.67 1.40 182.67 MWD+IFR2+MS+sag(3) 1,062.82 19.33 280.25 1,030.21 974.01 42.93 -213.29 6,031,062.36 469,575.67 2.25 216.12 MWD+IFR2+MS+sag(3) 1,159.74 22.58 272.06 1,120.72 1,064.52 46.46 -247.69 6,031,066.03 469,541.29 4.51 250.69 MWD+IFR2+MS+sag(3) 1,252.62 24.68 269.02 1,205.82 1,149.62 46.77 -284.90 6,031,066.49 469,504.08 2.61 287.80 MWD+IFR2+MS+sag(3) 1,301.68 24.84 267.56 1,250.37 1,194.17 46.15 -305.44 6,031,065.96 469,483.54 1.29 308.21 MWD+IFR2+MS+sag(3) 1,350.08 26.59 265.51 1,293.97 1,237.77 44.87 -326.40 6,031,064.76 469,462.58 4.06 328.99 MWD+IFR2+MS+sag(3) 1,398.48 29.43 261.55 1,336.70 1,280.50 42.27 -348.96 6,031,062.26 469,440.01 7.01 351.27 MWD+IFR2+MS+sag(3) 1,444.53 31.47 259.13 1,376.40 1,320.20 38.34 -371.96 6,031,058.42 469,417.00 5.17 373.86 MWD+IFR2+MS+sag(3) 1,497.84 33.19 257.50 1,421.44 1,365.24 32.56 -399.87 6,031,052.75 469,389.06 3.62 401.20 MWD+IFR2+MS+sag(3) 1,540.36 34.41 257.52 1,456.78 1,400.58 27.45 -422.97 6,031,047.73 469,365.95 2.87 423.78 MWD+IFR2+MS+sag(3) 1,586.99 35.48 255.83 1,495.00 1,438.80 21.29 -448.95 6,031,041.68 469,339.94 3.09 449.17 MWD+IFR2+MS+sag(3) 1,635.09 38.39 254.87 1,533.44 1,477.24 13.97 -476.91 6,031,034.48 469,311.96 6.17 476.42 MWD+IFR2+MS+sag(3) 1,685.31 43.40 253.82 1,571.39 1,515.19 5.09 -508.56 6,031,025.72 469,280.28 10.07 507.21 MWD+IFR2+MS+sag(3) 1,730.45 46.30 253.83 1,603.39 1,547.19 -3.78 -539.13 6,031,016.98 469,249.68 6.42 536.94 MWD+IFR2+MS+sag(3) 1,758.15 48.19 252.88 1,622.20 1,566.00 -9.61 -558.61 6,031,011.23 469,230.17 7.27 555.88 MWD+IFR2+MS+sag(3) 1,792.58 51.17 251.66 1,644.47 1,588.27 -17.61 -583.61 6,031,003.34 469,205.14 9.07 580.12 MWD+IFR2+MS+sag(3) 1,824.25 53.27 251.73 1,663.87 1,607.67 -25.47 -607.37 6,030,995.57 469,181.35 6.63 603.15 MWD+IFR2+MS+sag(3) 1,869.48 54.18 251.31 1,690.63 1,634.43 -37.03 -641.96 6,030,984.15 469,146.72 2.15 636.65 MWD+IFR2+MS+sag(3) 1,918.83 54.83 249.80 1,719.29 1,663.09 -50.41 -679.84 6,030,970.93 469,108.79 2.82 673.29 MWD+IFR2+MS+sag(3) 1,967.34 56.52 247.40 1,746.65 1,690.45 -65.03 -717.13 6,030,956.46 469,071.44 5.37 709.24 MWD+IFR2+MS+sag(3) 2,013.76 56.77 246.04 1,772.17 1,715.97 -80.35 -752.75 6,030,941.29 469,035.77 2.51 743.46 MWD+IFR2+MS+sag(3) 2,062.04 57.14 245.08 1,798.50 1,742.30 -97.10 -789.59 6,030,924.69 468,998.86 1.83 778.78 MWD+IFR2+MS+sag(3) 2,110.44 57.77 244.46 1,824.53 1,768.33 -114.49 -826.50 6,030,907.45 468,961.89 1.69 814.11 MWD+IFR2+MS+sag(3) 2,156.66 57.66 243.31 1,849.22 1,793.02 -131.69 -861.58 6,030,890.40 468,926.74 2.12 847.64 MWD+IFR2+MS+sag(3) 2,204.43 58.37 242.33 1,874.53 1,818.33 -150.20 -897.62 6,030,872.04 468,890.62 2.29 882.02 MWD+IFR2+MS+sag(3) 2,250.10 58.41 241.49 1,898.46 1,842.26 -168.51 -931.94 6,030,853.87 468,856.24 1.57 914.69 MWD+IFR2+MS+sag(3) 2,300.22 58.62 240.42 1,924.64 1,868.44 -189.26 -969.30 6,030,833.27 468,818.80 1.87 950.20 MWD+IFR2+MS+sag(3) 2,347.25 59.76 238.29 1,948.73 1,892.53 -209.85 -1,004.05 6,030,812.82 468,783.97 4.58 983.12 MWD+IFR2+MS+sag(3) 2,396.72 60.81 236.29 1,973.25 1,917.05 -233.07 -1,040.19 6,030,789.75 468,747.73 4.10 1,017.21 MWD+IFR2+MS+sag(3) 2,443.41 61.71 234.93 1,995.70 1,939.50 -256.19 -1,073.97 6,030,766.77 468,713.86 3.20 1,048.95 MWD+IFR2+MS+sag(3) 2,490.14 62.42 234.78 2,017.60 1,961.40 -279.96 -1,107.73 6,030,743.14 468,680.01 1.55 1,080.61 MWD+IFR2+MS+sag(3) 2,537.76 63.92 234.91 2,039.09 1,982.89 -304.43 -1,142.47 6,030,718.82 468,645.17 3.16 1,113.20 MWD+IFR2+MS+sag(3) 2,584.38 64.07 235.24 2,059.53 2,003.33 -328.41 -1,176.83 6,030,694.97 468,610.73 0.71 1,145.44 MWD+IFR2+MS+sag(3) 2,679.92 61.17 235.63 2,103.46 2,047.26 -376.54 -1,246.68 6,030,647.13 468,540.69 3.06 1,211.05 MWD+IFR2+MS+sag(4) 2,775.45 60.34 238.49 2,150.14 2,093.94 -421.87 -1,316.62 6,030,602.10 468,470.57 2.75 1,276.97 MWD+IFR2+MS+sag(4) 2,823.60 59.67 237.60 2,174.21 2,118.01 -443.94 -1,352.00 6,030,580.18 468,435.10 2.12 1,310.40 MWD+IFR2+MS+sag(4) 2,870.81 61.77 236.77 2,197.30 2,141.10 -466.25 -1,386.60 6,030,558.00 468,400.41 4.71 1,343.03 MWD+IFR2+MS+sag(4) 2,920.58 64.12 237.31 2,219.94 2,163.74 -490.36 -1,423.79 6,030,534.05 468,363.13 4.82 1,378.08 MWD+IFR2+MS+sag(4) 7/14/2011 8:40:33AM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 2,963.49 65.98 237.85 2,238.04 2,181.84 -511.22 -1,456.63 6,030,513.33 468,330.21 4.48 1,409.07 MWD+IFR2+MS+sag(4) 3,060.12 67.95 237.77 2,275.84 2,219.64 -558.59 -1,531.88 6,030,466.27 468,254.77 2.04 1,480.13 MWD+IFR2+MS+sag(4) 3,110.19 67.93 238.41 2,294.65 2,238.45 -583.12 -1,571.28 6,030,441.90 468,215.29 1.19 1,517.34 MWD+IFR2+MS+sag(4) 3,157.11 68.56 237.36 2,312.04 2,255.84 -606.29 -1,608.18 6,030,418.89 468,178.29 2.47 1,552.20 MWD+IFR2+MS+sag(4) 3,250.45 70.06 236.47 2,345.02 2,288.82 -653.95 -1,681.34 6,030,371.52 468,104.94 1.84 1,621.14 MWD+IFR2+MS+sag(4) 3,346.32 69.32 236.47 2,378.29 2,322.09 -703.62 -1,756.29 6,030,322.17 468,029.80 0.77 1,691.69 MWD+IFR2+MS+sag(4) 3,441.21 71.31 234.96 2,410.26 2,354.06 -753.95 -1,830.10 6,030,272.14 467,955.80 2.58 1,761.06 MWD+IFR2+MS+sag(4) 3,537.18 72.49 234.97 2,440.07 2,383.87 -806.31 -1,904.79 6,030,220.08 467,880.90 1.23 1,831.14 MWD+IFR2+MS+sag(4) 3,633.78 71.56 235.52 2,469.88 2,413.68 -858.70 -1,980.28 6,030,168.02 467,805.21 1.10 1,902.01 MWD+IFR2+MS+sag(4) 3,727.51 71.08 236.81 2,499.91 2,443.71 -908.14 -2,054.03 6,030,118.88 467,731.26 1.40 1,971.40 MWD+IFR2+MS+sag(4) 3,823.02 70.92 234.68 2,531.00 2,474.80 -958.96 -2,128.67 6,030,068.36 467,656.43 2.12 2,041.55 MWD+IFR2+MS+sag(4) 3,917.46 71.29 234.99 2,561.59 2,505.39 -1,010.42 -2,201.71 6,030,017.21 467,583.18 0.50 2,110.06 MWD+IFR2+MS+sag(4) 4,013.68 72.34 235.27 2,591.62 2,535.42 -1,062.68 -2,276.71 6,029,965.25 467,507.98 1.13 2,180.46 MWD+IFR2+MS+sag(4) 4,108.26 71.32 234.13 2,621.11 2,564.91 -1,114.61 -2,350.05 6,029,913.63 467,434.43 1.57 2,249.23 MWD+IFR2+MS+sag(4) 4,203.85 69.04 233.93 2,653.52 2,597.32 -1,167.42 -2,422.83 6,029,861.12 467,361.45 2.39 2,317.36 MWD+IFR2+MS+sag(4) 4,300.09 69.69 234.26 2,687.43 2,631.23 -1,220.24 -2,495.78 6,029,808.60 467,288.29 0.75 2,385.67 MWD+IFR2+MS+sag(4) 4,394.97 70.98 234.18 2,719.36 2,663.16 -1,272.48 -2,568.26 6,029,756.67 467,215.60 1.36 2,453.55 MWD+IFR2+MS+sag(4) 4,489.73 69.75 234.55 2,751.20 2,695.00 -1,324.48 -2,640.80 6,029,704.97 467,142.87 1.35 2,521.51 MWD+IFR2+MS+sag(4) 4,584.99 70.99 235.27 2,783.21 2,727.01 -1,376.05 -2,714.22 6,029,653.70 467,069.25 1.48 2,590.39 MWD+IFR2+MS+sag(4) 4,680.34 70.58 235.23 2,814.59 2,758.39 -1,427.37 -2,788.20 6,029,602.68 466,995.07 0.43 2,659.84 MWD+IFR2+MS+sag(4) 4,775.29 70.71 234.45 2,846.06 2,789.86 -1,478.96 -2,861.43 6,029,551.40 466,921.63 0.79 2,728.54 MWD+IFR2+MS+sag(4) 4,870.87 72.27 234.19 2,876.40 2,820.20 -1,531.82 -2,935.05 6,029,498.84 466,847.80 1.65 2,797.50 MWD+IFR2+MS+sag(4) 4,965.85 70.52 234.82 2,906.70 2,850.50 -1,584.09 -3,008.34 6,029,446.88 466,774.32 1.95 2,866.19 MWD+IFR2+MS+sag(4) 5,062.17 71.56 235.12 2,938.00 2,881.80 -1,636.38 -3,082.93 6,029,394.90 466,699.52 1.12 2,936.17 MWD+IFR2+MS+sag(4) 5,158.21 70.37 234.77 2,969.32 2,913.12 -1,688.52 -3,157.25 6,029,343.06 466,625.00 1.29 3,005.90 MWD+IFR2+MS+sag(4) 5,252.24 70.84 233.85 3,000.54 2,944.34 -1,740.27 -3,229.28 6,029,291.62 466,552.76 1.05 3,073.38 MWD+IFR2+MS+sag(4) 5,346.02 68.94 234.15 3,032.79 2,976.59 -1,792.03 -3,300.52 6,029,240.15 466,481.32 2.05 3,140.07 MWD+IFR2+MS+sag(4) 5,441.55 68.96 234.00 3,067.10 3,010.90 -1,844.34 -3,372.72 6,029,188.14 466,408.92 0.15 3,207.67 MWD+IFR2+MS+sag(4) 5,535.28 70.77 234.10 3,099.36 3,043.16 -1,896.00 -3,443.95 6,029,136.78 466,337.48 1.93 3,274.36 MWD+IFR2+MS+sag(4) 5,634.19 72.77 234.65 3,130.30 3,074.10 -1,950.71 -3,520.31 6,029,082.38 466,260.90 2.09 3,345.91 MWD+IFR2+MS+sag(4) 5,727.62 73.96 234.84 3,157.05 3,100.85 -2,002.38 -3,593.41 6,029,031.01 466,187.60 1.29 3,414.46 MWD+IFR2+MS+sag(4) 5,827.98 74.63 235.65 3,184.22 3,128.02 -2,057.46 -3,672.79 6,028,976.26 466,108.01 1.02 3,488.98 MWD+IFR2+MS+sag(5) 5,859.47 74.06 235.70 3,192.71 3,136.51 -2,074.56 -3,697.83 6,028,959.27 466,082.90 1.82 3,512.51 MWD+IFR2+MS+sag(5) 5,954.20 72.71 235.60 3,219.80 3,163.60 -2,125.77 -3,772.78 6,028,908.36 466,007.76 1.43 3,582.93 MWD+IFR2+MS+sag(6) 6,049.58 71.13 235.57 3,249.40 3,193.20 -2,177.02 -3,847.57 6,028,857.43 465,932.76 1.66 3,653.21 MWD+IFR2+MS+sag(6) 6,143.90 69.31 235.69 3,281.32 3,225.12 -2,227.12 -3,920.83 6,028,807.62 465,859.31 1.93 3,722.05 MWD+IFR2+MS+sag(6) 6,239.57 69.26 235.79 3,315.16 3,258.96 -2,277.50 -3,994.79 6,028,757.56 465,785.15 0.11 3,791.56 MWD+IFR2+MS+sag(6) 6,335.17 70.31 236.02 3,348.19 3,291.99 -2,327.79 -4,069.08 6,028,707.57 465,710.67 1.12 3,861.41 MWD+IFR2+MS+sag(6) 6,430.21 69.76 236.09 3,380.64 3,324.44 -2,377.67 -4,143.18 6,028,658.00 465,636.37 0.58 3,931.11 MWD+IFR2+MS+sag(6) 6,525.92 69.79 235.78 3,413.73 3,357.53 -2,427.97 -4,217.58 6,028,608.00 465,561.77 0.31 4,001.07 MWD+IFR2+MS+sag(6) 7/14/2011 8:40:33AM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 6,620.41 70.25 235.10 3,446.02 3,389.82 -2,478.35 -4,290.71 6,028,557.93 465,488.45 0.83 4,069.76 MWD+IFR2+MS+sag(6) 6,716.41 69.86 234.27 3,478.76 3,422.56 -2,530.51 -4,364.35 6,028,506.07 465,414.61 0.91 4,138.80 MWD+IFR2+MS+sag(6) 6,811.32 70.18 232.95 3,511.19 3,454.99 -2,583.43 -4,436.15 6,028,453.45 465,342.60 1.35 4,205.95 MWD+IFR2+MS+sag(6) 6,906.79 70.38 233.33 3,543.41 3,487.21 -2,637.34 -4,508.05 6,028,399.84 465,270.48 0.43 4,273.13 MWD+IFR2+MS+sag(6) 7,000.73 70.18 232.88 3,575.11 3,518.91 -2,690.43 -4,578.77 6,028,347.04 465,199.55 0.50 4,339.19 MWD+IFR2+MS+sag(6) 7,097.05 70.43 232.73 3,607.57 3,551.37 -2,745.25 -4,651.01 6,028,292.52 465,127.10 0.30 4,406.62 MWD+IFR2+MS+sag(6) 7,192.13 70.44 232.84 3,639.41 3,583.21 -2,799.44 -4,722.36 6,028,238.63 465,055.54 0.11 4,473.21 MWD+IFR2+MS+sag(6) 7,287.67 70.12 233.52 3,671.65 3,615.45 -2,853.33 -4,794.35 6,028,185.03 464,983.33 0.75 4,540.48 MWD+IFR2+MS+sag(6) 7,382.83 70.31 232.70 3,703.86 3,647.66 -2,907.08 -4,865.97 6,028,131.58 464,911.51 0.84 4,607.37 MWD+IFR2+MS+sag(6) 7,477.61 70.70 232.56 3,735.49 3,679.29 -2,961.31 -4,936.98 6,028,077.64 464,840.29 0.43 4,673.62 MWD+IFR2+MS+sag(6) 7,572.91 69.92 232.46 3,767.60 3,711.40 -3,015.92 -5,008.17 6,028,023.33 464,768.88 0.82 4,740.03 MWD+IFR2+MS+sag(6) 7,664.65 70.64 232.47 3,798.55 3,742.35 -3,068.54 -5,076.65 6,027,971.00 464,700.19 0.78 4,803.90 MWD+IFR2+MS+sag(6) 7,760.60 70.63 233.12 3,830.37 3,774.17 -3,123.27 -5,148.75 6,027,916.56 464,627.88 0.64 4,871.20 MWD+IFR2+MS+sag(6) 7,856.07 69.85 234.09 3,862.64 3,806.44 -3,176.59 -5,221.07 6,027,863.55 464,555.35 1.26 4,938.83 MWD+IFR2+MS+sag(6) 7,953.12 69.72 234.39 3,896.18 3,839.98 -3,229.81 -5,294.97 6,027,810.63 464,481.24 0.32 5,008.05 MWD+IFR2+MS+sag(6) 8,048.34 69.91 233.63 3,929.04 3,872.84 -3,282.33 -5,367.28 6,027,758.41 464,408.72 0.78 5,075.75 MWD+IFR2+MS+sag(6) 8,143.84 69.97 233.40 3,961.79 3,905.59 -3,335.67 -5,439.41 6,027,705.37 464,336.39 0.23 5,143.19 MWD+IFR2+MS+sag(6) 8,239.93 69.84 234.12 3,994.81 3,938.61 -3,389.01 -5,512.19 6,027,652.33 464,263.40 0.72 5,211.28 MWD+IFR2+MS+sag(6) 8,334.21 69.84 234.59 4,027.30 3,971.10 -3,440.59 -5,584.11 6,027,601.05 464,191.28 0.47 5,278.66 MWD+IFR2+MS+sag(6) 8,428.63 70.30 235.71 4,059.49 4,003.29 -3,491.31 -5,656.96 6,027,550.63 464,118.23 1.22 5,347.04 MWD+IFR2+MS+sag(6) 8,525.27 70.77 235.28 4,091.69 4,035.49 -3,542.93 -5,732.04 6,027,499.32 464,042.94 0.64 5,417.57 MWD+IFR2+MS+sag(6) 8,620.64 70.17 235.61 4,123.57 4,067.37 -3,593.91 -5,806.07 6,027,448.65 463,968.72 0.71 5,487.10 MWD+IFR2+MS+sag(6) 8,715.48 70.57 235.40 4,155.43 4,099.23 -3,644.50 -5,879.69 6,027,398.36 463,894.90 0.47 5,556.26 MWD+IFR2+MS+sag(6) 8,811.36 70.83 234.56 4,187.12 4,130.92 -3,696.43 -5,953.80 6,027,346.74 463,820.59 0.87 5,625.79 MWD+IFR2+MS+sag(6) 8,906.22 70.30 233.34 4,218.69 4,162.49 -3,749.07 -6,026.12 6,027,294.40 463,748.06 1.34 5,693.49 MWD+IFR2+MS+sag(6) 9,001.02 69.84 233.07 4,251.00 4,194.80 -3,802.45 -6,097.49 6,027,241.32 463,676.48 0.55 5,760.17 MWD+IFR2+MS+sag(6) 9,092.51 70.24 233.43 4,282.23 4,226.03 -3,853.90 -6,166.39 6,027,190.15 463,607.38 0.57 5,824.56 MWD+IFR2+MS+sag(6) 9,188.01 70.05 233.76 4,314.67 4,258.47 -3,907.21 -6,238.69 6,027,137.14 463,534.88 0.38 5,892.17 MWD+IFR2+MS+sag(6) 9,282.68 70.10 234.41 4,346.93 4,290.73 -3,959.42 -6,310.77 6,027,085.23 463,462.59 0.65 5,959.66 MWD+IFR2+MS+sag(6) 9,380.15 69.85 234.32 4,380.31 4,324.11 -4,012.77 -6,385.20 6,027,032.19 463,387.95 0.27 6,029.39 MWD+IFR2+MS+sag(6) 9,472.29 69.83 235.20 4,412.06 4,355.86 -4,062.68 -6,455.84 6,026,982.57 463,317.12 0.90 6,095.64 MWD+IFR2+MS+sag(6) 9,568.74 70.11 234.28 4,445.10 4,388.90 -4,114.99 -6,529.83 6,026,930.57 463,242.92 0.94 6,165.03 MWD+IFR2+MS+sag(6) 9,666.12 70.05 233.69 4,478.28 4,422.08 -4,168.82 -6,603.88 6,026,877.04 463,168.66 0.57 6,234.35 MWD+IFR2+MS+sag(6) 9,760.80 70.31 233.31 4,510.38 4,454.18 -4,221.80 -6,675.48 6,026,824.36 463,096.85 0.47 6,301.29 MWD+IFR2+MS+sag(6) 9,858.38 70.24 233.07 4,543.32 4,487.12 -4,276.84 -6,749.03 6,026,769.62 463,023.09 0.24 6,370.00 MWD+IFR2+MS+sag(6) 9,952.01 70.12 233.37 4,575.06 4,518.86 -4,329.58 -6,819.57 6,026,717.18 462,952.34 0.33 6,435.92 MWD+IFR2+MS+sag(6) 10,048.39 70.17 233.62 4,607.80 4,551.60 -4,383.51 -6,892.44 6,026,663.55 462,879.26 0.25 6,504.05 MWD+IFR2+MS+sag(6) 10,143.67 70.31 233.81 4,640.01 4,583.81 -4,436.57 -6,964.72 6,026,610.79 462,806.77 0.24 6,571.67 MWD+IFR2+MS+sag(6) 10,237.91 70.19 233.55 4,671.86 4,615.66 -4,489.11 -7,036.19 6,026,558.55 462,735.10 0.29 6,638.52 MWD+IFR2+MS+sag(6) 10,334.15 69.58 234.87 4,704.95 4,648.75 -4,541.96 -7,109.49 6,026,506.00 462,661.59 1.44 6,707.17 MWD+IFR2+MS+sag(6) 7/14/2011 8:40:33AM Page 5 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,428.83 68.44 235.68 4,738.87 4,682.67 -4,592.31 -7,182.14 6,026,455.95 462,588.75 1.44 6,775.38 MWD+IFR2+MS+sag(6) 10,524.78 67.78 238.57 4,774.65 4,718.45 -4,640.64 -7,256.90 6,026,407.93 462,513.80 2.88 6,845.86 MWD+IFR2+MS+sag(6) 10,620.63 67.20 242.31 4,811.35 4,755.15 -4,684.32 -7,333.90 6,026,364.57 462,436.63 3.65 6,918.97 MWD+1FR2+MS+sag(6) 10,714.50 66.99 245.65 4,847.90 4,791.70 -4,722.24 -7,411.59 6,026,326.96 462,358.79 3.29 6,993.23 MWD+IFR2+MS+sag(6) 10,810.13 66.66 248.76 4,885.54 4,829.34 -4,756.30 -7,492.62 6,026,293.24 462,277.63 3.01 7,071.15 MWD+IFR2+MS+sag(6) 10,902.18 65.85 251.88 4,922.61 4,866.41 -4,784.68 -7,571.94 6,026,265.19 462,198.20 3.22 7,147.84 MWD+IFR2+MS+sag(6) 11,000.42 65.84 254.39 4,962.82 4,906.62 -4,810.68 -7,657.71 6,026,239.53 462,112.33 2.33 7,231.15 MWD+IFR2+MS+sag(6) 11,095.21 65.58 256.70 5,001.81 4,945.61 -4,832.25 -7,741.37 6,026,218.31 462,028.60 2.24 7,312.72 MWD+IFR2+MS+sag(6) 11,191.27 65.23 257.82 5,041.80 4,985.60 -4,851.51 -7,826.56 6,026,199.40 461,943.34 1.12 7,396.02 MWD+IFR2+MS+sag(6) 11,283.10 64.68 258.80 5,080.67 5,024.47 -4,868.37 -7,908.03 6,026,182.87 461,861.81 1.14 7,475.80 MWD+IFR2+MS+sag(6) 11,377.97 63.87 261.34 5,121.85 5,065.65 -4,883.11 -7,992.21 6,026,168.47 461,777.58 2.56 7,558.46 MWD+IFR2+MS+sag(6) 11,476.80 63.12 262.96 5,165.96 5,109.76 -4,895.19 -8,079.81 6,026,156.75 461,689.93 1.65 7,644.76 MWD+IFR2+MS+sag(6) 11,572.62 63.33 265.88 5,209.14 5,152.94 -4,903.51 -8,164.94 6,026,148.78 461,604.78 2.73 7,728.90 MWD+IFR2+MS+sag(6) 11,658.00 63.94 268.27 5,247.06 5,190.86 -4,907.41 -8,241.33 6,026,145.19 461,528.38 2.60 7,804.71 MWD+IFR2+MS+sag(6) 11,747.54 62.38 269.29 5,287.48 5,231.28 -4,909.12 -8,321.21 6,026,143.80 461,448.51 2.02 7,884.16 MWD+IFR2+MS+sag(7) 11,843.17 60.36 270.42 5,333.30 5,277.10 -4,909.34 -8,405.14 6,026,143.93 461,364.59 2.35 7,967.78 MWD+IFR2+MS+sag(7) 11,896.92 60.88 262.76 5,359.70 5,303.50 -4,912.13 -8,451.84 6,026,141.32 461,317.88 12.45 8,014.09 MWD+IFR2+MS+sag(7) 11,936.80 62.02 263.61 5,378.76 5,322.56 -4,916.28 -8,486.62 6,026,137.31 461,283.09 3.42 8,048.41 MWD+IFR2+MS+sag(7) 11,973.65 61.93 264.11 5,396.08 5,339.88 -4,919.76 -8,518.96 6,026,133.96 461,250.73 1.22 8,080.35 MWD+IFR2+MS+sag(7) 12,033.25 63.21 269.14 5,423.55 5,367.35 -4,922.86 -8,571.75 6,026,131.08 461,197.94 7.79 8,132.69 MWD+IFR2+MS+sag(7) 12,107.57 63.56 269.45 5,456.84 5,400.64 -4,923.68 -8,638.19 6,026,130.53 461,131.51 0.60 8,198.83 MWD+IFR2+MS+sag(7) 12,202.93 64.33 271.20 5,498.73 5,442.53 -4,923.19 -8,723.85 6,026,131.37 461,045.86 1.84 8,284.24 MWD+IFR2+MS+sag(7) 12,297.39 65.84 273.22 5,538.52 5,482.32 -4,919.88 -8,809.44 6,026,135.03 460,960.28 2.51 8,369.81 MWD+IFR2+MS+sag(7) 12,393.22 66.13 276.83 5,577.54 5,521.34 -4,912.21 -8,896.62 6,026,143.05 460,873.15 3.45 8,457.33 MWD+IFR2+MS+sag(7) 12,487.99 66.28 280.23 5,615.78 5,559.58 -4,899.35 -8,982.36 6,026,156.26 460,787.47 3.29 8,543.84 MWD+IFR2+MS+sag(7) 12,584.50 65.91 284.44 5,654.90 5,598.70 -4,880.51 -9,068.53 6,026,175.45 460,701.39 4.01 8,631.28 MWD+IFR2+MS+sag(7) 12,678.58 66.10 287.67 5,693.17 5,636.97 -4,856.74 -9,151.11 6,026,199.55 460,618.91 3.14 8,715.55 MWD+IFR2+MS+sag(7) 12,774.98 67.31 290.55 5,731.30 5,675.10 -4,827.75 -9,234.76 6,026,228.88 460,535.39 3.02 8,801.32 MWD+IFR2+MS+sag(7) 12,870.96 67.45 294.78 5,768.23 5,712.03 -4,793.62 -9,316.49 6,026,263.34 460,453.81 4.07 8,885.60 MWD+IFR2+MS+sag(7) 12,965.26 67.39 298.88 5,804.45 5,748.25 -4,754.33 -9,394.17 6,026,302.94 460,376.30 4.01 8,966.28 MWD+IFR2+MS+sag(7) 13,060.11 67.94 304.32 5,840.52 5,784.32 -4,708.37 -9,468.85 6,026,349.19 460,301.81 5.34 9,044.52 MWD+IFR2+MS+sag(7) 13,154.33 67.50 309.25 5,876.26 5,820.06 -4,656.19 -9,538.65 6,026,401.65 460,232.23 4.86 9,118.42 MWD+IFR2+MS+sag(7) 13,251.66 67.30 312.83 5,913.67 5,857.47 -4,597.21 -9,606.41 6,026,460.90 460,164.71 3.40 9,190.85 MWD+IFR2+MS+sag(7) 13,346.28 67.85 316.46 5,949.78 5,893.58 -4,535.75 -9,668.62 6,026,522.60 460,102.76 3.59 9,257.96 MWD+IFR2+MS+sag(7) 13,440.97 68.25 320.27 5,985.18 5,928.98 -4,470.13 -9,726.96 6,026,588.46 460,044.70 3.76 9,321.55 MWD+IFR2+MS+sag(7) 13,536.47 68.17 324.33 6,020.65 5,964.45 -4,399.98 -9,781.17 6,026,658.82 459,990.78 3.95 9,381.41 MWD+IFR2+MS+sag(7) 13,632.27 69.66 327.69 6,055.12 5,998.92 -4,325.88 -9,831.12 6,026,733.12 459,941.13 3.62 9,437.35 MWD+IFR2+MS+sag(7) 13,726.99 72.07 329.40 6,086.17 6,029.97 -4,249.55 -9,877.80 6,026,809.63 459,894.76 3.06 9,490.22 MWD+IFR2+MS+sag(7) 13,821.83 74.10 331.64 6,113.76 6,057.56 -4,170.56 -9,922.44 6,026,888.79 459,850.45 3.11 9,541.27 MWD+IFR2+MS+sag(7) 13,917.18 76.72 331.10 6,137.78 6,081.58 -4,089.58 -9,966.66 6,026,969.94 459,806.57 2.80 9,592.06 MWD+IFR2+MS+sag(7) 7/14/2011 8:40:33AM Page 6 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,013.05 76.22 330.41 6,160.21 6,104.01 -4,008.25 -10,012.19 6,027,051.45 459,761.37 0.87 9,644.20 MWD+IFR2+MS+sag(7) 14,058.26 76.61 330.04 6,170.83 6,114.63 -3,970.11 -10,034.02 6,027,089.67 459,739.71 1.17 9,669.12 MWD+IFR2+MS+sag(7) 14,091.00 76.61 330.04 6,178.41 6,122.21 -3,942.51 -10,049.92 6,027,117.33 459,723.92 0.00 9,687.27 MWD+IFR2+MS+sag(7) 14,152.43 79.23 329.60 6,191.27 6,135.07 -3,890.59 -10,080.12 6,027,169.37 459,693.93 4.32 9,721.68 MWD+IFR2+MS+sag(8) 14,249.50 82.68 330.95 6,206.52 6,150.32 -3,807.35 -10,127.64 6,027,252.79 459,646.76 3.81 9,775.95 MWD+IFR2+MS+sag(8) 14,344.98 84.91 331.88 6,216.84 6,160.64 -3,724.01 -10,173.05 6,027,336.31 459,601.69 2.53 9,828.14 MWD+IFR2+MS+sag(8) 14,436.69 87.76 330.54 6,222.71 6,166.51 -3,643.81 -10,217.12 6,027,416.68 459,557.95 3.43 9,878.73 MWD+IFR2+MS+sag(8) 14,538.67 87.99 327.19 6,226.49 6,170.29 -3,556.59 -10,269.81 6,027,504.10 459,505.62 3.29 9,938.48 MWD+IFR2+MS+sag(8) 14,636.20 87.00 325.12 6,230.75 6,174.55 -3,475.67 -10,324.07 6,027,585.23 459,451.69 2.35 9,999.29 MWD+IFR2+MS+sag(8) 14,732.66 87.93 322.55 6,235.02 6,178.82 -3,397.88 -10,380.93 6,027,663.25 459,395.15 2.83 10,062.42 MWD+IFR2+MS+sag(8) 14,829.17 86.87 319.59 6,239.40 6,183.20 -3,322.89 -10,441.50 6,027,738.47 459,334.89 3.25 10,129.02 MWD+IFR2+MS+sag(8) 14,925.72 87.06 315.32 6,244.51 6,188.31 -3,251.87 -10,506.68 6,027,809.75 459,270.01 4.42 10,199.88 MWD+IFR2+MS+sag(8) 15,022.68 87.99 313.50 6,248.70 6,192.50 -3,184.09 -10,575.88 6,027,877.81 459,201.10 2.11 10,274.47 MWD+IFR2+MS+sag(8) 15,119.20 88.73 312.57 6,251.46 6,195.26 -3,118.25 -10,646.40 6,027,943.93 459,130.85 1.23 10,350.22 MWD+IFR2+MS+sag(8) 15,214.79 91.15 314.19 6,251.56 6,195.36 -3,052.60 -10,715.87 6,028,009.85 459,061.66 3.05 10,424.91 MWD+IFR2+MS+sag(8) 15,311.99 93.62 316.09 6,247.52 6,191.32 -2,983.77 -10,784.36 6,028,078.95 458,993.45 3.20 10,498.89 MWD+IFR2+MS+sag(8) 15,408.31 95.11 315.97 6,240.19 6,183.99 -2,914.65 -10,851.04 6,028,148.33 458,927.06 1.55 10,571.08 MWD+IFR2+MS+sag(8) 15,504.75 94.17 313.28 6,232.38 6,176.18 -2,847.14 -10,919.45 6,028,216.12 458,858.94 2.95 10,644.87 MWD+IFR2+MS+sag(8) 15,601.51 92.93 310.76 6,226.39 6,170.19 -2,782.50 -10,991.19 6,028,281.04 458,787.47 2.90 10,721.73 MWD+IFR2+MS+sag(8) 15,697.74 94.05 309.50 6,220.53 6,164.33 -2,720.59 -11,064.62 6,028,343.24 458,714.29 1.75 10,800.06 MWD+IFR2+MS+sag(8) 15,794.87 93.67 308.07 6,213.99 6,157.79 -2,659.89 -11,140.16 6,028,404.24 458,639.01 1.52 10,880.39 MWD+IFR2+MS+sag(8) 15,890.86 93.05 306.68 6,208.37 6,152.17 -2,601.72 -11,216.31 6,028,462.71 458,563.10 1.58 10,961.11 MWD+IFR2+MS+sag(8) 15,987.05 93.80 306.84 6,202.62 6,146.42 -2,544.26 -11,293.23 6,028,520.48 458,486.42 0.80 11,042.55 MWD+IFR2+MS+sag(8) 16,083.29 92.68 307.26 6,197.18 6,140.98 -2,486.37 -11,369.92 6,028,578.68 458,409.98 1.24 11,123.78 MWD+IFR2+MS+sag(8) 16,180.10 91.26 307.71 6,193.85 6,137.65 -2,427.49 -11,446.69 6,028,637.86 458,333.45 1.54 11,205.18 MWD+IFR2+MS+sag(8) Ili 16,274.85 91.32 307.56 6,191.72 6,135.52 -2,369.65 -11,521.71 6,028,696.00 458,258.68 0.17 11,284.75 MWD+IFR2+MS+sag(8) 16,370.87 91.82 308.09 6,189.09 6,132.89 -2,310.79 -11,597.52 6,028,755.16 458,183.11 0.76 11,365.20 MWD+IFR2+MS+sag(8) 16,468.38 91.20 310.01 6,186.52 6,130.32 -2,249.38 -11,673.22 6,028,816.87 458,107.67 2.07 11,445.74 MWD+IFR2+MS+sag(8) 16,564.06 90.77 312.07 6,184.88 6,128.68 -2,186.57 -11,745.37 6,028,879.97 458,035.79 2.20 11,522.86 MWD+IFR2+MS+sag(8) 16,659.52 90.65 313.50 6,183.69 6,127.49 -2,121.74 -11,815.42 6,028,945.08 457,966.00 1.50 11,598.06 MWD+IFR2+MS+sag(8) 16,755.66 91.57 313.53 6,181.83 6,125.63 -2,055.55 -11,885.13 6,029,011.54 457,896.58 0.96 11,673.03 MWD+IFR2+MS+sag(8) 16,852.14 89.47 311.85 6,180.95 6,124.75 -1,990.15 -11,956.04 6,029,077.23 457,825.94 2.79 11,749.13 MWD+IFR2+MS+sag(8) 16,948.42 89.22 311.89 6,182.06 6,125.86 -1,925.89 -12,027.73 6,029,141.77 457,754.52 0.26 11,825.92 MWD+IFR2+MS+sag(8) 17,044.39 88.48 311.14 6,183.98 6,127.78 -1,862.29 -12,099.57 6,029,205.65 457,682.94 1.10 11,902.80 MWD+IFR2+MS+sag(8) 17,141.56 87.25 310.74 6,187.60 6,131.40 -1,798.67 -12,172.92 6,029,269.57 457,609.86 1.33 11,981.19 MWD+IFR2+MS+sag(8) 17,238.42 86.26 309.91 6,193.08 6,136.88 -1,736.09 -12,246.65 6,029,332.44 457,536.40 1.33 12,059.86 MWD+IFR2+MS+sag(8) 17,334.39 85.32 310.65 6,200.13 6,143.93 -1,674.21 -12,319.66 6,029,394.61 457,463.64 1.25 12,137.77 MWD+IFR2+MS+sag(8) 17,430.69 86.13 312.24 6,207.31 6,151.11 -1,610.65 -12,391.64 6,029,458.46 457,391.92 1.85 12,214.79 MWD+IFR2+MS+sag(8) 17,527.24 86.63 313.30 6,213.40 6,157.20 -1,545.22 -12,462.38 6,029,524.17 457,321.46 1.21 12,290.72 MWD+IFR2+MS+sag(8) 17,623.31 86.45 313.39 6,219.20 6,163.00 -1,479.39 -12,532.12 6,029,590.27 457,252.00 0.21 12,365.69 MWD+IFR2+MS+sag(8) 7/14/2011 8:40:33AM Page 7 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100) (ft) Survey Tool Name 17,720.19 86.19 313.04 6,225.42 6,169.22 -1,413.19 -12,602.57 6,029,656.75 457,181.82 0.45 12,441.41 MWD+IFR2+MS+sag(8) 17,816.77 85.27 311.36 6,232.61 6,176.41 -1,348.50 -12,673.92 6,029,721.72 457,110.75 1.98 12,517.88 MWD+IFR2+MS+sag(8) 17,911.61 85.70 311.39 6,240.08 6,183.88 -1,286.01 -12,744.87 6,029,784.49 457,040.06 0.45 12,593.78 MWD+IFR2+MS+sag(8) 18,008.71 85.82 311.82 6,247.26 6,191.06 -1,221.71 -12,817.27 6,029,849.08 456,967.92 0.46 12,671.29 MWD+IFR2+MS+sag(8) 18,104.30 86.13 310.90 6,253.97 6,197.77 -1,158.70 -12,888.84 6,029,912.37 456,896.62 1.01 12,747.85 MWD+IFR2+MS+sag(8) 18,201.41 92.57 313.34 6,255.07 6,198.87 -1,093.62 -12,960.82 6,029,977.74 456,824.91 7.09 12,824.99 MWD+IFR2+MS+sag(8) 18,298.28 93.49 314.32 6,249.95 6,193.75 -1,026.63 -13,030.61 6,030,045.01 456,755.40 1.39 12,900.10 MWD+IFR2+MS+sag(8) 18,394.58 94.73 314.77 6,243.05 6,186.85 -959.25 -13,099.06 6,030,112.66 456,687.23 1.37 12,973.92 MWD+IFR2+MS+sag(8) 18,491.00 93.24 314.35 6,236.35 6,180.15 -891.76 -13,167.59 6,030,180.42 456,618.98 1.61 13,047.83 MWD+IFR2+MS+sag(8) 18,587.18 94.17 313.40 6,230.13 6,173.93 -825.24 -13,236.78 6,030,247.21 456,550.07 1.38 13,122.31 MWD+IFR2+MS+sag(8) 18,683.57 94.17 312.81 6,223.12 6,166.92 -759.55 -13,306.97 6,030,313.18 456,480.16 0.61 13,197.72 MWD+IFR2+MS+sag(8) 18,779.84 93.61 312.99 6,216.59 6,160.39 -694.17 -13,377.33 6,030,378.84 456,410.07 0.61 13,273.27 MWD+IFR2+MS+sag(8) 18,875.80 91.51 313.62 6,212.30 6,156.10 -628.42 -13,447.08 6,030,444.86 456,340.59 2.28 13,348.25 MWD+IFR2+MS+sag(8) 18,971.61 91.88 315.22 6,209.47 6,153.27 -561.39 -13,515.48 6,030,512.16 456,272.47 1.71 13,421.99 MWD+IFR2+MS+sag(8) 19,067.62 92.87 315.79 6,205.49 6,149.29 -492.97 -13,582.71 6,030,580.85 456,205.53 1.19 13,494.67 MWD+IFR2+MS+sag(8) 19,162.81 91.69 313.56 6,201.70 6,145.50 -426.10 -13,650.34 6,030,647.99 456,138.18 2.65 13,567.63 MWD+IFR2+MS+sag(8) 19,260.28 92.31 313.05 6,198.30 6,142.10 -359.29 -13,721.23 6,030,715.08 456,067.57 0.82 13,643.83 MWD+IFR2+MS+sag(8) 19,356.97 89.35 312.74 6,196.90 6,140.70 -293.49 -13,792.05 6,030,781.16 455,997.02 3.08 13,719.87 MWD+IFR2+MS+sag(8) 19,449.64 89.53 314.14 6,197.81 6,141.61 -229.78 -13,859.33 6,030,845.14 455,930.01 1.52 13,792.22 MWD+IFR2+MS+sag(8) 19,549.96 89.59 314.98 6,198.58 6,142.38 -159.39 -13,930.81 6,030,915.81 455,858.83 0.84 13,869.30 MWD+IFR2+MS+sag(8) 19,600.71 87.93 314.47 6,199.68 6,143.48 -123.69 -13,966.86 6,030,951.66 455,822.93 3.42 13,908.19 MWD+IFR2+MS+sag(8) 19,645.46 87.86 314.80 6,201.32 6,145.12 -92.27 -13,998.68 6,030,983.20 455,791.24 0.75 13,942.52 MWD+IFR2+MS+sag(8) 19,741.64 87.12 312.27 6,205.53 6,149.33 -26.09 -14,068.33 6,031,049.66 455,721.86 2.74 14,017.43 MWD+IFR2+MS+sag(8) 19,839.08 86.94 316.07 6,210.58 6,154.38 41.71 -14,138.12 6,031,117.73 455,652.36 3.90 14,092.61 MWD+IFR2+MS+sag(8) 19,935.00 87.43 316.40 6,215.29 6,159.09 110.89 -14,204.38 6,031,187.18 455,586.38 0.62 14,164.41 MWD+IFR2+MS+sag(8) 20,031.92 87.25 314.47 6,219.79 6,163.59 179.87 -14,272,32 6,031,256.42 455,518.73 2.00 14,237.84 MWD+IFR2+MS+sag(8) 20,128.61 86.94 312.83 6,224.69 6,168.49 246.52 -14,342.19 6,031,323.35 455,449.14 1.72 14,313.01 MWD+IFR2+MS+sag(8) 20,225.31 86.81 313.46 6,229.96 6,173.76 312.55 -14,412.64 6,031,389.65 455,378.97 0.66 14,388.71 MWD+IFR2+MS+sag(8) 20,321.56 86.87 314.22 6,235.27 6,179.07 379.11 -14,481.95 6,031,456.49 455,309.93 0.79 14,463.32 MWD+IFR2+MS+sag(8) 20,418.09 87.37 314.57 6,240.12 6,183.92 446.56 -14,550.84 6,031,524.21 455,241.32 0.63 14,537.57 MWD+IFR2+MS+sag(8) 20,514.89 87.06 314.81 6,244.82 6,188.62 514.56 -14,619.58 6,031,592.48 455,172.87 0.40 14,611.73 MWD+IFR2+MS+sag(8) 20,550.00 87.06 314.81 6,246.62 6,190.42 539.27 -14,644.45 6,031,617.29 455,148.10 0.00 14,638.57 PROJECTED to TD 7/14/2011 8:40:33AM Page 8 COMPASS 2003.16 Build 42F 1 Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 PB2 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 ODSN-23i-Slot ODS-23 Well Position +N/-S 0.00 ft Northing: 6,031,018.57 ft Latitude: 70°29'44.931 N +EI-W 0.00 ft Easting: 469,788.76 ft Longitude: 150° 14'49.325 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-23i PB2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-23i IN14 PB2 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 780.68 Vertical Section: Depth From(TVD) +N/-5 +EI-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 274.77 Survey Program Date 7/13/2011 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 83.00 454.30 ODSN-23i Gyro Run100(ODSN-23i PB1 SR-Gyro-SS Fixed:v2:surface readout gyro single shot 05/16/2011 495.48 780.68 ODSN-23i MWD Run200(ODSN-23i PB'MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 05/16/2011 875.01 2,584.38 ODSN-23i MWD Run 400(ODSN-23i PB MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 05/23/2011 2,679.92 5,727.62 ODSN-23i MWD Run500(ODSN-23i PB:MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 05/24/2011 5,827.98 5,859.47 ODSN-23i MWD Run 600(ODSN-23i PB MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 05/31/2011 5,954.20 11,953.62 ODSN-23i MWD Run 700(ODSN-23i PB MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 06/01/2011 Survey 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 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,018.57 469,788.76 0.00 0.00 UNDEFINED 83.00 0.11 124.69 83.00 26.80 -0.02 0.03 6,031,018.55 469,788.79 0.27 -0.03 SR-Gyro-SS(1) 173.00 1.90 254.67 172.98 116.78 -0.46 -1.34 6,031,018.11 469,787.42 2.19 1.29 SR-Gyro-SS(1) 265.00 6.05 264.54 264.74 208.54 -1.33 -7.64 6,031,017.27 469,781.12 4.56 7.50 SR-Gyro-SS(1) 359.00 7.69 283.98 358.08 301.88 -0.28 -18.67 6,031,018.37 469,770.09 3.00 18.58 SR-Gyro-SS(1) 453.00 9.09 287.10 451.07 394.87 3.42 -31.88 6,031,022.12 469,756.90 1.57 32.05 SR-Gyro-SS(1) 587.93 13.80 284.62 583.28 527.08 10.62 -57.65 6,031,029.43 469,731.16 3.51 58.33 MWD+IFR2+MS+sag(2) • 685.36 16.51 286.20 677.31 621.11 17.42 -82.19 6,031,036.32 469,706.65 2.81 83.35 MWD+IFR2+MS+sag(2) 780.68 21.35 281.09 767.46 711.26 24.54 -112.25 6,031,043.56 469,676.63 5.36 113.89 MWD+IFR2+MS+sag(2) 875.01 22.30 278.86 855.03 798.83 30.60 -146.78 6,031,049.76 469,642.12 1.34 148.81 MWD+IFR2+MS+sag(3) 7/13/2011 3:47:03PM Page 2 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 PB2 Database: .Pioneer Alaska Survey 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 966.28 21.46 281.45 939.72 883.52 36.58 -180.26 6,031,055.88 469,608.67 1.40 182.67 MWD+IFR2+MS+sag(3) 1,062.82 19.33 280.25 1,030.21 974.01 42.93 -213.29 6,031,062.36 469,575.67 2.25 216.12 MWD+IFR2+MS+sag(3) 1,159.74 22.58 272.06 1,120.72 1,064.52 46.46 -247.69 6,031,066.03 469,541.29 4.51 250.69 MWD+IFR2+MS+sag(3) 1,252.62 24.68 269.02 1,205.82 1,149.62 46.77 -284.90 6,031,066.49 469,504.08 2.61 287.80 MWD+IFR2+MS+sag(3) 1,301.68 24.84 267.56 1,250.37 1,194.17 46.15 -305.44 6,031,065.96 469,483.54 1.29 308.21 MWD+IFR2+MS+sag(3) 1,350.08 26.59 265.51 1,293.97 1,237.77 44.87 -326.40 6,031,064.76 469,462.58 4.06 328.99 MWD+IFR2+MS+sag(3) 1,398.48 29.43 261.55 1,336.70 1,280.50 42.27 -348.96 6,031,062.26 469,440.01 7.01 351.27 MWD+IFR2+MS+sag(3) 1,444.53 31.47 259.13 1,376.40 1,320.20 38.34 -371.96 6,031,058.42 469,417.00 5.17 373.86 MWD+IFR2+MS+sag(3) 1,497.84 33.19 257.50 1,421.44 1,365.24 32.56 -399.87 6,031,052.75 469,389.06 3.62 401.20 MWD+IFR2+MS+sag(3) 1,540.36 34.41 257.52 1,456.78 1,400.58 27.45 -422.97 6,031,047.73 469,365.95 2.87 423.78 MWD+IFR2+MS+sag(3) 1,586.99 35.48 255.83 1,495.00 1,438.80 21.29 -448.95 6,031,041.68 469,339.94 3.09 449.17 MWD+IFR2+MS+sag(3) 1,635.09 38.39 254.87 1,533.44 1,477.24 13.97 -476.91 6,031,034.48 469,311.96 6.17 476.42 MWD+IFR2+MS+sag(3) 1,685.31 43.40 253.82 1,571.39 1,515.19 5.09 -508.56 6,031,025.72 469,280.28 10.07 507.21 MWD+IFR2+MS+sag(3) 1,730.45 46.30 253.83 1,603.39 1,547.19 -3.78 -539.13 6,031,016.98 469,249.68 6.42 536.94 MWD+IFR2+MS+sag(3) 1,758.15 48.19 252.88 1,622.20 1,566.00 -9.61 -558.61 6,031,011.23 469,230.17 7.27 555.88 MWD+IFR2+MS+sag(3) 1,792.58 51.17 251.66 1,644.47 1,588.27 -17.61 -583.61 6,031,003.34 469,205.14 9.07 580.12 MWD+IFR2+MS+sag(3) 1,824.25 53.27 251.73 1,663.87 1,607.67 -25.47 -607.37 6,030,995.57 469,181.35 6.63 603.15 MWD+IFR2+MS+sag(3) 1,869.48 54.18 251.31 1,690.63 1,634.43 -37.03 -641.96 6,030,984.15 469,146.72 2.15 636.65 MWD+IFR2+MS+sag(3) 1,918.83 54.83 249.80 1,719.29 1,663.09 -50.41 -679.84 6,030,970.93 469,108.79 2.82 673.29 MWD+IFR2+MS+sag(3) 1,967.34 56.52 247.40 1,746.65 1,690.45 -65.03 -717.13 6,030,956.46 469,071.44 5.37 709.24 MWD+IFR2+MS+sag(3) 2,013.76 56.77 246.04 1,772.17 1,715.97 -80.35 -752.75 6,030,941.29 469,035.77 2.51 743.46 MWD+IFR2+MS+sag(3) 2,062.04 57.14 245.08 1,798.50 1,742.30 -97.10 -789.59 6,030,924.69 468,998.86 1.83 778.78 MWD+IFR2+MS+sag(3) 2,110.44 57.77 244.46 1,824.53 1,768.33 -114.49 -826.50 6,030,907.45 468,961.89 1.69 814.11 MWD+IFR2+MS+sag(3) 2,156.66 57.66 243.31 1,849.22 1,793.02 -131.69 -861.58 6,030,890.40 468,926.74 2.12 847.64 MWD+IFR2+MS+sag(3) 2,204.43 58.37 242.33 1,874.53 1,818.33 -150.20 -897.62 6,030,872.04 468,890.62 2.29 882.02 MWD+IFR2+MS+sag(3) 2,250.10 58.41 241.49 1,898.46 1,842.26 -168.51 -931.94 6,030,853.87 468,856.24 1.57 914.69 MWD+IFR2+MS+sag(3) 2,300.22 58.62 240.42 1,924.64 1,868.44 -189.26 -969.30 6,030,833.27 468,818.80 1.87 950.20 MWD+IFR2+MS+sag(3) 2,347.25 59.76 238.29 1,948.73 1,892.53 -209.85 -1,004.05 6,030,812.82 468,783.97 4.58 983.12 MWD+IFR2+MS+sag(3) 2,396.72 60.81 236.29 1,973.25 1,917.05 -233.07 -1,040.19 6,030,789.75 468,747.73 4.10 1,017.21 MWD+IFR2+MS+sag(3) 2,443.41 61.71 234.93 1,995.70 1,939.50 -256.19 -1,073.97 6,030,766.77 468,713.86 3.20 1,048.95 MWD+IFR2+MS+sag(3) 2,490.14 62.42 234.78 2,017.60 1,961.40 -279.96 -1,107.73 6,030,743.14 468,680.01 1.55 1,080.61 MWD+IFR2+MS+sag(3) 2,537.76 63.92 234.91 2,039.09 1,982.89 -304.43 -1,142.47 6,030,718.82 468,645.17 3.16 1,113.20 MWD+IFR2+MS+sag(3) 2,584.38 64.07 235.24 2,059.53 2,003.33 -328.41 -1,176.83 6,030,694.97 468,610.73 0.71 1,145.44 MWD+IFR2+MS+sag(3) 2,679.92 61.17 235.63 2,103.46 2,047.26 -376.54 -1,246.68 6,030,647.13 468,540.69 3.06 1,211.05 MWD+IFR2+MS+sag(4) 2,775.45 60.34 238.49 2,150.14 2,093.94 -421.87 -1,316.62 6,030,602.10 468,470.57 2.75 1,276.97 MWD+IFR2+MS+sag(4) 2,823.60 59.67 237.60 2,174.21 2,118.01 -443.94 -1,352.00 6,030,580.18 468,435.10 2.12 1,310.40 MWD+IFR2+MS+sag(4) 2,870.81 61.77 236.77 2,197.30 2,141.10 -466.25 -1,386.60 6,030,558.00 468,400.41 4.71 1,343.03 MWD+IFR2+MS+sag(4) 2,920.58 64.12 237.31 2,219.94 2,163.74 -490.36 -1,423.79 6,030,534.05 468,363.13 4.82 1,378.08 MWD+IFR2+MS+sag(4) 2,963.49 65.98 237.85 2,238.04 2,181.84 -511.22 -1,456.63 6,030,513.33 468,330.21 4.48 1,409.07 MWD+IFR2+MS+sag(4) 3,060.12 67.95 237.77 2,275.84 2,219.64 -558.59 -1,531.88 6,030,466.27 468,254.77 2.04 1,480.13 MWD+IFR2+MS+sag(4) 7/13/2011 3:47:03PM Page 3 COMPASS 2003.16 Build 42F • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 PB2 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,110.19 67.93 238.41 2,294.65 2,238.45 -583.12 -1,571.28 6,030,441.90 468,215.29 1.19 1,517.34 MWD+IFR2+MS+sag(4) 3,157.11 68.56 237.36 2,312.04 2,255.84 -606.29 -1,608.18 6,030,418.89 468,178.29 2.47 1,552.20 MWD+IFR2+MS+sag(4) 3,250.45 70.06 236.47 2,345.02 2,288.82 -653.95 -1,681.34 6,030,371.52 468,104.94 1.84 1,621.14 MWD+IFR2+MS+sag(4) 3,346.32 69.32 236.47 2,378.29 2,322.09 -703.62 -1,756.29 6,030,322.17 468,029.80 0.77 1,691.69 MWD+IFR2+MS+sag(4) 3,441.21 71.31 234.96 2,410.26 2,354.06 -753.95 -1,830.10 6,030,272.14 467,955.80 2.58 1,761.06 MWD+IFR2+MS+sag(4) 3,537.18 72.49 234.97 2,440.07 2,383.87 -806.31 -1,904.79 6,030,220.08 467,880.90 1.23 1,831.14 MWD+IFR2+MS+sag(4) 3,633.78 71.56 235.52 2,469.88 2,413.68 -858.70 -1,980.28 6,030,168.02 467,805.21 1.10 1,902.01 MWD+IFR2+MS+sag(4) 3,727.51 71.08 236.81 2,499.91 2,443.71 -908.14 -2,054.03 6,030,118.88 467,731.26 1.40 1,971.40 MWD+IFR2+MS+sag(4) 3,823.02 70.92 234.68 2,531.00 2,474.80 -958.96 -2,128.67 6,030,068.36 467,656.43 2.12 2,041.55 MWD+IFR2+MS+sag(4) 3,917.46 71.29 234.99 2,561.59 2,505.39 -1,010.42 -2,201.71 6,030,017.21 467,583.18 0.50 2,110.06 MWD+IFR2+MS+sag(4) 4,013.68 72.34 235.27 2,591.62 2,535.42 -1,062.68 -2,276.71 6,029,965.25 467,507.98 1.13 2,180.46 MWD+IFR2+MS+sag(4) 4,108.26 71.32 234.13 2,621.11 2,564.91 -1,114.61 -2,350.05 6,029,913.63 467,434.43 1.57 2,249.23 MWD+IFR2+MS+sag(4) 4,203.85 69.04 233.93 2,653.52 2,597.32 -1,167.42 -2,422.83 6,029,861.12 467,361.45 2.39 2,317.36 MWD+IFR2+MS+sag(4) 4,300.09 69.69 234.26 2,687.43 2,631.23 -1,220.24 -2,495.78 6,029,808.60 467,288.29 0.75 2,385.67 MWD+IFR2+MS+sag(4) 4,394.97 70.98 234.18 2,719.36 2,663.16 -1,272.48 -2,568.26 6,029,756.67 467,215.60 1.36 2,453.55 MWD+IFR2+MS+sag(4) 4,489.73 69.75 234.55 2,751.20 2,695.00 -1,324.48 -2,640.80 6,029,704.97 467,142.87 1.35 2,521.51 MWD+IFR2+MS+sag(4) 4,584.99 70.99 235.27 2,783.21 2,727.01 -1,376.05 -2,714.22 6,029,653.70 467,069.25 1.48 2,590.39 MWD+IFR2+MS+sag(4) 4,680.34 70.58 235.23 2,814.59 2,758.39 -1,427.37 -2,788.20 6,029,602.68 466,995.07 0.43 2,659.84 MWD+IFR2+MS+sag(4) 4,775.29 70.71 234.45 2,846.06 2,789.86 -1,478.96 -2,861.43 6,029,551.40 466,921.63 0.79 2,728.54 MWD+IFR2+MS+sag(4) 4,870.87 72.27 234.19 2,876.40 2,820.20 -1,531.82 -2,935.05 6,029,498.84 466,847.80 1.65 2,797.50 MWD+IFR2+MS+sag(4) 4,965.85 70.52 234.82 2,906.70 2,850.50 -1,584.09 -3,008.34 6,029,446.88 466,774.32 1.95 2,866.19 MWD+IFR2+MS+sag(4) 5,062.17 71.56 235.12 2,938.00 2,881.80 -1,636.38 -3,082.93 6,029,394.90 466,699.52 1.12 2,936.17 MWD+IFR2+MS+sag(4) 5,158.21 70.37 234.77 2,969.32 2,913.12 -1,688.52 -3,157.25 6,029,343.06 466,625.00 1.29 3,005.90 MWD+IFR2+MS+sag(4) 5,252.24 70.84 233.85 3,000.54 2,944.34 -1,740.27 -3,229.28 6,029,291.62 466,552.76 1.05 3,073.38 MWD+IFR2+MS+sag(4) 5,346.02 68.94 234.15 3,032.79 2,976.59 -1,792.03 -3,300.52 6,029,240.15 466,481.32 2.05 3,140.07 MWD+IFR2+MS+sag(4) 5,441.55 68.96 234.00 3,067.10 3,010.90 -1,844.34 -3,372.72 6,029,188.14 466,408.92 0.15 3,207.67 MWD+IFR2+MS+sag(4) 5,535.28 70.77 234.10 3,099.36 3,043.16 -1,896.00 -3,443.95 6,029,136.78 466,337.48 1.93 3,274.36 MWD+IFR2+MS+sag(4) 5,634.19 72.77 234.65 3,130.30 3,074.10 -1,950.71 -3,520.31 6,029,082.38 466,260.90 2.09 3,345.91 MWD+IFR2+MS+sag(4) 5,727.62 73.96 234.84 3,157.05 3,100.85 -2,002.38 -3,593.41 6,029,031.01 466,187.60 1.29 3,414.46 MWD+IFR2+MS+sag(4) 5,827.98 74.63 235.65 3,184.22 3,128.02 -2,057.46 -3,672.79 6,028,976.26 466,108.01 1.02 3,488.98 MWD+IFR2+MS+sag(5) 5,859.47 74.06 235.70 3,192.71 3,136.51 -2,074.56 -3,697.83 6,028,959.27 466,082.90 1.82 3,512.51 MWD+IFR2+MS+sag(5) 5,954.20 72.71 235.60 3,219.80 3,163.60 -2,125.77 -3,772.78 6,028,908.36 466,007.76 1.43 3,582.93 MWD+IFR2+MS+sag(6) 6,049.58 71.13 235.57 3,249.40 3,193.20 -2,177.02 -3,847.57 6,028,857.43 465,932.76 1.66 3,653.21 MWD+IFR2+MS+sag(6) 6,143.90 69.31 235.69 3,281.32 3,225.12 -2,227.12 -3,920.83 6,028,807.62 465,859.31 1.93 3,722.05 MWD+IFR2+MS+sag(6) 6,239.57 69.26 235.79 3,315.16 3,258.96 -2,277.50 -3,994.79 6,028,757.56 465,785.15 0.11 3,791.56 MWD+IFR2+MS+sag(6) 6,335.17 70.31 236.02 3,348.19 3,291.99 -2,327.79 -4,069.08 6,028,707.57 465,710.67 1.12 3,861.41 MWD+IFR2+MS+sag(6) 6,430.21 69.76 236.09 3,380.64 3,324.44 -2,377.67 -4,143.18 6,028,658.00 465,636.37 0.58 3,931.11 MWD+IFR2+MS+sag(6) 6,525.92 69.79 235.78 3,413.73 3,357.53 -2,427.97 -4,217.58 6,028,608.00 465,561.77 0.31 4,001.07 MWD+IFR2+MS+sag(6) 6,620.41 70.25 235.10 3,446.02 3,389.82 -2,478.35 -4,290.71 6,028,557.93 465,488.45 0.83 4,069.76 MWD+IFR2+MS+sag(6) 6,716.41 69.86 234.27 3,478.76 3,422.56 -2,530.51 -4,364.35 6,028,506.07 465,414.61 0.91 4,138.80 MWD+IFR2+MS+sag(6) 7/13/2011 3:47:03PM Page 4 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 PB2 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 6,811.32 70.18 232.95 3,511.19 3,454.99 -2,583.43 -4,436.15 6,028,453.45 465,342.60 1.35 4,205.95 MWD+IFR2+MS+sag(6) 6,906.79 70.38 233.33 3,543.41 3,487.21 -2,637.34 -4,508.05 6,028,399.84 465,270.48 0.43 4,273.13 MWD+IFR2+MS+sag(6) 7,000.73 70.18 232.88 3,575.11 3,518.91 -2,690.43 -4,578.77 6,028,347.04 465,199.55 0.50 4,339.19 MWD+IFR2+MS+sag(6) 7,097.05 70.43 232.73 3,607.57 3,551.37 -2,745.25 -4,651.01 6,028,292.52 465,127.10 0.30 4,406.62 MWD+IFR2+MS+sag(6) 7,192.13 70.44 232.84 3,639.41 3,583.21 -2,799.44 -4,722.36 6,028,238.63 465,055.54 0.11 4,473.21 MWD+IFR2+MS+sag(6) 7,287.67 70.12 233.52 3,671.65 3,615.45 -2,853.33 -4,794.35 6,028,185.03 464,983.33 0.75 4,540.48 MWD+IFR2+MS+sag(6) 7,382.83 70.31 232.70 3,703.86 3,647.66 -2,907.08 -4,865.97 6,028,131.58 464,911.51 0.84 4,607.37 MWD+IFR2+MS+sag(6) 7,477.61 70.70 232.56 3,735.49 3,679.29 -2,961.31 -4,936.98 6,028,077.64 464,840.29 0.43 4,673.62 MWD+IFR2+MS+sag(6) 7,572.91 69.92 232.46 3,767.60 3,711.40 -3,015.92 -5,008.17 6,028,023.33 464,768.88 0.82 4,740.03 MWD+IFR2+MS+sag(6) 7,664.65 70.64 232.47 3,798.55 3,742.35 -3,068.54 -5,076.65 6,027,971.00 464,700.19 0.78 4,803.90 MWD+IFR2+MS+sag(6) 7,760.60 70.63 233.12 3,830.37 3,774.17 -3,123.27 -5,148.75 6,027,916.56 464,627.88 0.64 4,871.20 MWD+IFR2+MS+sag(6) 7,856.07 69.85 234.09 3,862.64 3,806.44 -3,176.59 -5,221.07 6,027,863.55 464,555.35 1.26 4,938.83 MWD+IFR2+MS+sag(6) 7,953.12 69.72 234.39 3,896.18 3,839.98 -3,229.81 -5,294.97 6,027,810.63 464,481.24 0.32 5,008.05 MWD+IFR2+MS+sag(6) 8,048.34 69.91 233.63 3,929.04 3,872.84 -3,282.33 -5,367.28 6,027,758.41 464,408.72 0.78 5,075.75 MWD+IFR2+MS+sag(6) 8,143.84 69.97 233.40 3,961.79 3,905.59 -3,335.67 -5,439.41 6,027,705.37 464,336.39 0.23 5,143.19 MWD+IFR2+MS+sag(6) 8,239.93 69.84 234.12 3,994.81 3,938.61 -3,389.01 -5,512.19 6,027,652.33 464,263.40 0.72 5,211.28 MWD+IFR2+MS+sag(6) 8,334.21 69.84 234.59 4,027.30 3,971.10 -3,440.59 -5,584.11 6,027,601.05 464,191.28 0.47 5,278.66 MWD+IFR2+MS+sag(6) 8,428.63 70.30 235.71 4,059.49 4,003.29 -3,491.31 -5,656.96 6,027,550.63 464,118.23 1.22 5,347.04 MWD+IFR2+MS+sag(6) 8,525.27 70.77 235.28 4,091.69 4,035.49 -3,542.93 -5,732.04 6,027,499.32 464,042.94 0.64 5,417.57 MWD+IFR2+MS+sag(6) 8,620.64 70.17 235.61 4,123.57 4,067.37 -3,593.91 -5,806.07 6,027,448.65 463,968.72 0.71 5,487.10 MWD+IFR2+MS+sag(6) 8,715.48 70.57 235.40 4,155.43 4,099.23 -3,644.50 -5,879.69 6,027,398.36 463,894.90 0.47 5,556.26 MWD+IFR2+MS+sag(6) 8,811.36 70.83 234.56 4,187.12 4,130.92 -3,696.43 -5,953.80 6,027,346.74 463,820.59 0.87 5,625.79 MWD+IFR2+MS+sag(6) 8,906.22 70.30 233.34 4,218.69 4,162.49 -3,749.07 -6,026.12 6,027,294.40 463,748.06 1.34 5,693.49 MWD+IFR2+MS+sag(6) 9,001.02 69.84 233.07 4,251.00 4,194.80 -3,802.45 -6,097.49 6,027,241.32 463,676.48 0.55 5,760.17 MWD+IFR2+MS+sag(6) 9,092.51 70.24 233.43 4,282.23 4,226.03 -3,853.90 -6,166.39 6,027,190.15 463,607.38 0.57 5,824.56 MWD+IFR2+MS+sag(6) 9,188.01 70.05 233.76 4,314.67 4,258.47 -3,907.21 -6,238.69 6,027,137.14 463,534.88 0.38 5,892.17 MWD+IFR2+MS+sag(6) 9,282.68 70.10 234.41 4,346.93 4,290.73 -3,959.42 -6,310.77 6,027,085.23 463,462.59 0.65 5,959.66 MWD+IFR2+MS+sag(6) 9,380.15 69.85 234.32 4,380.31 4,324.11 -4,012.77 -6,385.20 6,027,032.19 463,387.95 0.27 6,029.39 MWD+IFR2+MS+sag(6) 9,472.29 69.83 235.20 4,412.06 4,355.86 -4,062.68 -6,455.84 6,026,982.57 463,317.12 0.90 6,095.64 MWD+IFR2+MS+sag(6) 9,568.74 70.11 234.28 4,445.10 4,388.90 -4,114.99 -6,529.83 6,026,930.57 463,242.92 0.94 6,165.03 MWD+IFR2+MS+sag(6) 9,666.12 70.05 233.69 4,478.28 4,422.08 -4,168.82 -6,603.88 6,026,877.04 463,168.66 0.57 6,234.35 MWD+IFR2+MS+sag(6) 9,760.80 70.31 233.31 4,510.38 4,454.18 -4,221.80 -6,675.48 6,026,824.36 463,096.85 0.47 6,301.29 MWD+IFR2+MS+sag(6) 9,858.38 70.24 233.07 4,543.32 4,487.12 -4,276.84 -6,749.03 6,026,769.62 463,023.09 0.24 6,370.00 MWD+IFR2+MS+sag(6) 9,952.01 70.12 233.37 4,575.06 4,518.86 -4,329.58 -6,819.57 6,026,717.18 462,952.34 0.33 6,435.92 MWD+IFR2+MS+sag(6) 10,048.39 70.17 233.62 4,607.80 4,551.60 -4,383.51 -6,892.44 6,026,663.55 462,879.26 0.25 6,504.05 MWD+IFR2+MS+sag(6) 10,143.67 70.31 233.81 4,640.01 4,583.81 -4,436.57 -6,964.72 6,026,610.79 462,806.77 0.24 6,571.67 MWD+IFR2+MS+sag(6) 10,237.91 70.19 233.55 4,671.86 4,615.66 -4,489.11 -7,036.19 6,026,558.55 462,735.10 0.29 6,638.52 MWD+IFR2+MS+sag(6) 10,334.15 69.58 234.87 4,704.95 4,648.75 -4,541.96 -7,109.49 6,026,506.00 462,661.59 1.44 6,707.17 MWD+IFR2+MS+sag(6) 10,428.83 68.44 235.68 4,738.87 4,682.67 -4,592.31 -7,182.14 6,026,455.95 462,588.75 1.44 6,775.38 MWD+IFR2+MS+sag(6) 10,524.78 67.78 238.57 4,774.65 4,718.45 -4,640.64 -7,256.90 6,026,407.93 462,513.80 2.88 6,845.86 MWD+IFR2+MS+sag(6) 7/13/2011 3:47:03PM Page 5 COMPASS 2003.16 Build 42F • Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 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: ODSN-23i North Reference: True Wellbore: ODSN-23i PB2 Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 PB2 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,620.63 67.20 242.31 4,811.35 4,755.15 -4,684.32 -7,333.90 6,026,364.57 462,436.63 3.65 6,918.97 MWD+IFR2+MS+sag(6) 10,714.50 66.99 245.65 4,847.90 4,791.70 -4,722.24 -7,411.59 6,026,326.96 462,358.79 3.29 6,993.23 MWD+IFR2+MS+sag(6) 10,810.13 66.66 248.76 4,885.54 4,829.34 -4,756.30 -7,492.62 6,026,293.24 462,277.63 3.01 7,071.15 MWD+IFR2+MS+sag(6) 10,902.18 65.85 251.88 4,922.61 4,866.41 -4,784.68 -7,571.94 6,026,265.19 462,198.20 3.22 7,147.84 MWD+IFR2+MS+sag(6) 11,000.42 65.84 254.39 4,962.82 4,906.62 -4,810.68 -7,657.71 6,026,239.53 462,112.33 2.33 7,231.15 MWD+IFR2+MS+sag(6) 11,095.21 65.58 256.70 5,001.81 4,945.61 -4,832.25 -7,741.37 6,026,218.31 462,028.60 2.24 7,312.72 MWD+IFR2+MS+sag(6) 11,191.27 65.23 257.82 5,041.80 4,985.60 -4,851.51 -7,826.56 6,026,199.40 461,943.34 1.12 7,396.02 MWD+IFR2+MS+sag(6) 11,283.10 64.68 258.80 5,080.67 5,024.47 -4,868.37 -7,908.03 6,026,182.87 461,861.81 1.14 7,475.80 MWD+IFR2+MS+sag(6) 11,377.97 63.87 261.34 5,121.85 5,065.65 -4,883.11 -7,992.21 6,026,168.47 461,777.58 2.56 7,558.46 MWD+IFR2+MS+sag(6) 11,476.80 63.12 262.96 5,165.96 5,109.76 -4,895.19 -8,079.81 6,026,156.75 461,689.93 1.65 7,644.76 MWD+IFR2+MS+sag(6) 11,572.62 63.33 265.88 5,209.14 5,152.94 -4,903.51 -8,164.94 6,026,148.78 461,604.78 2.73 7,728.90 MWD+IFR2+MS+sag(6) 11,667.48 64.01 268.53 5,251.22 5,195.02 -4,907.65 -8,249.85 6,026,144.98 461,519.87 2.60 7,813.17 MWD+IFR2+MS+sag(6) 11,763.15 64.28 271.90 5,292.95 5,236.75 -4,907.32 -8,335.93 6,026,145.66 461,433.80 3.18 7,898.98 MWD+IFR2+MS+sag(6) 11,858.05 64.06 275.60 5,334.31 5,278.11 -4,901.74 -8,421.14 6,026,151.59 461,348.62 3.52 7,984.36 MWD+IFR2+MS+sag(6) 11,953.62 64.01 279.31 5,376.16 5,319.96 -4,890.59 -8,506.32 6,026,163.08 461,263.50 3.49 8,070.17 MWD+IFR2+MS+sag(6) 11,986.00 64.01 279.31 5,390.35 5,334.15 -4,885.89 -8,535.04 6,026,167.90 461,234.80 0.00 8,099.18 PROJECTED to TD 7/13/2011 3:47:03PM Page 6 COMPASS 2003.16 Build 42F 1. 1, Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-23i North Reference: True Wellbore: ODSN-23i PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 PB1 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 ODSN-23i-Slot ODS-23 Well Position +N/-S 0.00 ft Northing: 6,031,018.57 ft Latitude: 70°29'44.931 N +EI-W 0.00 ft Easting: 469,788.76 ft Longitude: 150° 14'49.325 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-23i PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) I GRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-23i 1N14 PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/-5 +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 274.77 Survey Program Date 7/13/2011 From To Survey (ft) (ft) Survey(Wellbore) Tool Name Description Start Date 83.00 454.30 ODSN-23i Gyro Run100(ODSN-23i PB1 SR-Gyro-SS Fixed:v2:surface readout gyro single shot 05/16/2011 495.48 2,585.21 ODSN-23i MWD Run200(ODSN-23i PB'MWD+IFR2+MS+sag Fixed:v2:lIFR dec&3-axis correction+sag 05/16/2011 2,678.19 6,012.33 ODSN-23i MWD Run300(ODSN-23i PB'MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 05/17/2011 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,018.57 469,788.76 0.00 0.00 UNDEFINED 83.00 0.11 124.69 83.00 26.80 -0.02 0.03 6,031,018.55 469,788.79 0.27 -0.03 SR-Gyro-SS(1) 173.00 1.90 254.67 172.98 116.78 -0.46 -1.34 6,031,018.11 469,787.42 2.19 1.29 SR-Gyro-SS(1) 265.00 6.05 264.54 264.74 208.54 -1.33 -7.64 6,031,017.27 469,781.12 4.56 7.50 SR-Gyro-SS(1) 359.00 7.69 283.98 358.08 301.88 -0.28 -18.67 6,031,018.37 469,770.09 3.00 18.58 SR-Gyro-SS(1) 453.00 9.09 287.10 451.07 394.87 3.42 -31.88 6,031,022.12 469,756.90 1.57 32.05 SR-Gyro-SS(1) 587.93 13.80 284.62 583.28 527.08 10.62 -57.65 6,031,029.43 469,731.16 3.51 58.33 MWD+IFR2+MS+sag(2) 685.36 16.51 286.20 677.31 621.11 17.42 -82.19 6,031,036.32 469,706.65 2.81 83.35 MWD+IFR2+MS+sag(2) 780.68 21.35 281.09 767.46 711.26 24.54 -112.25 6,031,043.56 469,676.63 5.36 113.89 MWD+IFR2+MS+sag(2) 871.01 23.44 277.27 850.97 794.77 29.98 -146.21 6,031,049.14 469,642.69 2.82 148.19 MWD+IFR2+MS+sag(2) 970.93 22.57 272.75 942.95 886.75 33.41 -185.08 6,031,052.73 469,603.84 1.97 187.21 MWD+IFR2+MS+sag(2) 1,064.78 22.63 268.75 1,029.60 973.40 33.88 -221.12 6,031,053.35 469,567.80 1.64 223.17 MWD+IFR2+MS+sag(2) 7/13/2011 4:21:35PM Page 2 COMPASS 2003.16 Build 42F . a Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-23i North Reference: True Wellbore: ODSN-23i PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 PB1 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,112.65 23.32 267.28 1,073.68 1,017.48 33.23 -239.79 6,031,052.77 469,549.13 1.87 241.72 MWD+IFR2+MS+sag(2) 1,156.84 25.14 265.47 1,113.97 1,057.77 32.08 -257.89 6,031,051.69 469,531.03 4.45 259.66 MWD+IFR2+MS+sag(2) 1,204.73 28.26 262.04 1,156.75 1,100.55 29.70 -279.27 6,031,049.40 469,509.64 7.26 280.77 MWD+IFR2+MS+sag(2) 1,253.23 29.44 259.91 1,199.23 1,143.03 26.02 -302.37 6,031,045.82 469,486.53 3.23 303.49 MWD+IFR2+MS+sag(2) 1,298.54 28.97 259.04 1,238.78 1,182.58 21.99 -324.11 6,031,041.87 469,464.78 1.40 324.81 MWD+IFR2+MS+sag(2) 1,347.34 30.19 256.53 1,281.22 1,225.02 16.88 -347.65 6,031,036.86 469,441.22 3.56 347.84 MWD+IFR2+MS+sag(2) 1,396.52 33.71 252.77 1,322.95 1,266.75 9.96 -372.72 6,031,030.04 469,416.12 8.22 372.25 MWD+IFR2+MS+sag(2) 1,441.02 35.45 252.00 1,359.59 1,303.39 2.31 -396.79 6,031,022.49 469,392.03 4.03 395.60 MWD+IFR2+MS+sag(2) 1,492.22 36.94 250.87 1,400.91 1,344.71 -7.32 -425.45 6,031,012.98 469,363.33 3.19 423.36 MWD+IFR2+MS+sag(2) 1,538.04 40.62 250.13 1,436.62 1,380.42 -16.91 -452.49 6,031,003.50 469,336.25 8.09 449.52 MWD+IFR2+MS+sag(2) 1,586.90 42.26 250.32 1,473.25 1,417.05 -27.85 -482.92 6,030,992.69 469,305.78 3.37 478.93 MWD+IFR2+MS+sag(2) 1,633.25 42.35 249.64 1,507.53 1,451.33 -38.53 -512.23 6,030,982.13 469,276.43 1.01 507.25 MWD+IFR2+MS+sag(2) 1,680.93 44.51 247.62 1,542.15 1,485.95 -50.48 -542.75 6,030,970.30 469,245.87 5.39 536.67 MWD+IFR2+MS+sag(2) 1,727.47 47.03 245.62 1,574.61 1,518.41 -63.72 -573.35 6,030,957.19 469,215.22 6.23 566.06 MWD+IFR2+MS+sag(2) 1,775.33 49.63 244.41 1,606.43 1,550.23 -78.83 -605.74 6,030,942.21 469,182.76 5.75 597.10 MWD+IFR2+MS+sag(2) 1,823.52 52.06 242.90 1,636.86 1,580.66 -95.42 -639.22 6,030,925.76 469,149.22 5.60 629.08 MWD+IFR2+MS+sag(2) 1,871.26 54.34 242.61 1,665.45 1,609.25 -112.92 -673.21 6,030,908.40 469,115.17 4.80 661.49 MWD+IFR2+MS+sag(2) 1,915.23 54.85 242.37 1,690.93 1,634.73 -129.47 -704.99 6,030,891.98 469,083.32 1.24 691.79 MWD+IFR2+MS+sag(2) 1,963.03 54.85 242.83 1,718.45 1,662.25 -147.46 -739.69 6,030,874.14 469,048.55 0.79 724.88 MWD+IFR2+MS+sag(2) 2,013.65 54.18 242.78 1,747.83 1,691.63 -166.29 -776.35 6,030,855.45 469,011.82 1.33 759.85 MWD+IFR2+MS+sag(2) 2,060.77 56.06 241.39 1,774.78 1,718.58 -184.39 -810.51 6,030,837.49 468,977.59 4.67 792.37 MWD+IFR2+MS+sag(2) 2,108.94 58.08 240.60 1,800.96 1,744.76 -204.00 -845.86 6,030,818.03 468,942.16 4.41 825.98 MWD+IFR2+MS+sag(2) 2,156.52 59.03 239.40 1,825.78 1,769.58 -224.30 -881.01 6,030,797.88 468,906.93 2.94 859.32 MWD+IFR2+MS+sag(2) 2,204.03 59.57 239.15 1,850.04 1,793.84 -245.17 -916.13 6,030,777.15 468,871.73 1.22 892.58 MWD+IFR2+MS+sag(2) 2,250.99 60.48 238.37 1,873.50 1,817.30 -266.27 -950.91 6,030,756.20 468,836.87 2.41 925.49 MWD+IFR2+MS+sag(2) 2,299.84 62.99 236.95 1,896.63 1,840.43 -289.29 -987.25 6,030,733.33 468,800.44 5.74 959.79 MWD+IFR2+MS+sag(2) 2,361.51 64.29 236.03 1,924.02 1,867.82 -319.79 -1,033.32 6,030,703.01 468,754.25 2.50 1,003.17 MWD+IFR2+MS+sag(2) 2,395.20 64.83 235.25 1,938.49 1,882.29 -336.96 -1,058.44 6,030,685.94 468,729.07 2.63 1,026.77 MWD+IFR2+MS+sag(2) 2,442.72 64.90 235.03 1,958.67 1,902.47 -361.55 -1,093.74 6,030,661.50 468,693.67 0.44 1,059.90 MWD+IFR2+MS+sag(2) 2,487.77 64.29 235.78 1,978.00 1,921.80 -384.66 -1,127.23 6,030,638.54 468,660.09 2.02 1,091.37 MWD+IFR2+MS+sag(2) 2,537.56 65.65 234.91 1,999.07 1,942.87 -410.31 -1,164.34 6,030,613.03 468,622.88 3.16 1,126.21 MWD+IFR2+MS+sag(2) 2,585.21 67.60 234.11 2,017.97 1,961.77 -435.71 -1,199.95 6,030,587.79 468,587.17 4.37 1,159.59 MWD+IFR2+MS+sag(2) 2,678.19 66.70 234.30 2,054.08 1,997.88 -485.82 -1,269.45 6,030,537.96 468,517.47 0.99 1,224.68 MWD+IFR2+MS+sag(3) 2,774.88 63.61 234.58 2,094.70 2,038.50 -536.84 -1,340.82 6,030,487.23 468,445.91 3.21 1,291.56 MWD+IFR2+MS+sag(3) 2,870.24 62.04 235.12 2,138.25 2,082.05 -585.68 -1,410.18 6,030,438.68 468,376.36 1.72 1,356.62 MWD+IFR2+MS+sag(3) 2,966.04 64.42 235.84 2,181.39 2,125.19 -634.15 -1,480.65 6,030,390.51 468,305.70 2.57 1,422.82 MWD+IFR2+MS+sag(3) 3,060.63 65.39 235.69 2,221.51 2,165.31 -682.34 -1,551.47 6,030,342.61 468,234.69 1.04 1,489.39 MWD+IFR2+MS+sag(3) 3,156.34 68.90 234.62 2,258.68 2,202.48 -732.73 -1,623.83 6,030,292.52 468,162.13 3.81 1,557.32 MWD+IFR2+MS+sag(3) 3,251.30 67.37 235.12 2,294.04 2,237.84 -783.44 -1,695.90 6,030,242.11 468,089.86 1.68 1,624.92 MWD+IFR2+MS+sag(3) 3,347.21 68.63 234.16 2,329.97 2,273.77 -834.90 -1,768.42 6,030,190.94 468,017.14 1.61 1,692.91 MWD+IFR2+MS+sag(3) 7/13/2011 4:21:35PM Page 3 COMPASS 2003.16 Build 42F Halliburton Company Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'(copy)@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'(copy)@ 56.20ft(Nabors 19AC) Well: ODSN-23i North Reference: True Wellbore: ODSN-23i PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-23i IN14 PB1 Database: .Pioneer Alaska Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (ft) (?) (?) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,442.08 67.97 234.29 2,365.05 2,308.85 -886.44 -1,839.94 6,030,139.71 467,945.42 0.71 1,759.90 MWD+IFR2+MS+sag(3) 3,534.15 70.34 234.19 2,397.81 2,341.61 -936.72 -1,909.75 6,030,089.72 467,875.41 2.58 1,825.30 MWD+IFR2+MS+sag(3) 3,632.50 69.22 234.65 2,431.80 2,375.60 -990.41 -1,984.81 6,030,036.33 467,800.14 1.22 1,895.63 MWD+IFR2+MS+sag(3) 3,727.60 69.09 233.88 2,465.64 2,409.44 -1,042.32 -2,056.95 6,029,984.72 467,727.80 0.77 1,963.21 MWD+IFR2+MS+sag(3) 3,817.38 71.04 234.01 2,496.25 2,440.05 -1,091.99 -2,125.18 6,029,935.33 467,659.37 2.18 2,027.08 MWD+IFR2+MS+sag(3) 3,916.25 69.60 235.31 2,529.55 2,473.35 -1,145.84 -2,201.12 6,029,881.80 467,583.23 1.91 2,098.27 MWD+IFR2+MS+sag(3) 4,009.19 70.27 235.70 2,561.44 2,505.24 -1,195.28 -2,273.06 6,029,832.66 467,511.09 0.82 2,165.86 MWD+IFR2+MS+sag(3) 4,109.17 71.25 235.23 2,594.38 2,538.18 -1,248.79 -2,350.82 6,029,779.47 467,433.12 1.08 2,238.91 MWD+IFR2+MS+sag(3) 4,203.92 71.96 235.40 2,624.28 2,568.08 -1,299.96 -2,424.75 6,029,728.61 467,358.99 0.77 2,308.33 MWD+IFR2+MS+sag(3) 4,299.32 71.05 233.81 2,654.55 2,598.35 -1,352.35 -2,498.50 6,029,676.52 467,285.03 1.85 2,377.47 MWD+IFR2+MS+sag(3) 4,394.71 69.94 235.64 2,686.40 2,630.20 -1,404.28 -2,571.90 6,029,624.89 467,211.43 2.15 2,446.30 MWD+IFR2+MS+sag(3) 4,489.93 70.78 234.23 2,718.40 2,662.20 -1,455.80 -2,645.30 6,029,573.68 467,137.83 1.65 2,515.16 MWD+IFR2+MS+sag(3) 4,584.01 70.07 234.05 2,749.92 2,693.72 -1,507.73 -2,717.14 6,029,522.05 467,065.79 0.78 2,582.44 MWD+IFR2+MS+sag(3) 4,680.61 71.11 234.74 2,782.03 2,725.83 -1,560.77 -2,791.22 6,029,469.31 466,991.50 1.27 2,651.85 MWD+IFR2+MS+sag(3) 4,774.32 70.02 235.62 2,813.21 2,757.01 -1,611.23 -2,863.76 6,029,419.15 466,918.76 1.46 2,719.95 MWD+IFR2+MS+sag(3) 4,870.15 70.60 234.26 2,845.50 2,789.30 -1,663.06 -2,937.61 6,029,367.63 466,844.71 1.47 2,789.24 MWD+IFR2+MS+sag(3) 4,965.64 71.18 233.97 2,876.76 2,820.56 -1,715.95 -3,010.72 6,029,315.04 466,771.40 0.67 2,857.69 MWD+IFR2+MS+sag(3) 5,060.30 70.66 233.88 2,907.70 2,851.50 -1,768.63 -3,083.02 6,029,262.67 466,698.89 0.56 2,925.37 MWD+IFR2+MS+sag(3) 5,154.96 69.55 234.34 2,939.91 2,883.71 -1,820.81 -3,155.13 6,029,210.78 466,626.57 1.26 2,992.89 MWD+IFR2+MS+sag(3) 5,252.09 70.00 234.83 2,973.49 2,917.29 -1,873.62 -3,229.41 6,029,158.28 466,552.09 0.66 3,062.52 MWD+IFR2+MS+sag(3) 5,345.78 70.53 235.36 3,005.13 2,948.93 -1,924.08 -3,301.73 6,029,108.11 466,479.57 0.78 3,130.40 MWD+IFR2+MS+sag(3) 5,441.85 70.71 233.72 3,037.01 2,980.81 -1,976.66 -3,375.54 6,029,055.85 466,405.55 1.62 3,199.59 MWD+IFR2+MS+sag(3) 5,536.91 70.79 231.62 3,068.35 3,012.15 -2,031.08 -3,446.90 6,029,001.72 466,333.98 2.09 3,266.18 MWD+IFR2+MS+sag(3) 5,632.20 71.12 231.33 3,099.45 3,043.25 -2,087.18 -3,517.37 6,028,945.91 466,263.29 0.45 3,331.74 MWD+IFR2+MS+sag(3) 5,727.30 69.35 231.83 3,131.60 3,075.40 -2,142.79 -3,587.48 6,028,890.59 466,192.96 1.93 3,396.99 MWD+IFR2+MS+sag(3) 5,822.70 67.82 232.84 3,166.44 3,110.24 -2,197.06 -3,657.78 6,028,836.61 466,122.45 1.88 3,462.54 MWD+IFR2+MS+sag(3) 5,870.17 68.49 233.51 3,184.10 3,127.90 -2,223.47 -3,693.05 6,028,810.35 466,087.08 1.93 3,495.49 MWD+IFR2+MS+sag(3) 5,917.56 69.87 234.72 3,200.94 3,144.74 -2,249.43 -3,728.94 6,028,784.54 466,051.09 3.76 3,529.09 MWD+IFR2+MS+sag(3) 6,012.33 68.42 236.05 3,234.68 3,178.48 -2,299.74 -3,801.82 6,028,734.53 465,978.01 2.02 3,597.54 MWD+IFR2+MS+sag(3) 6,079.00 68.42 236.05 3,259.21 3,203.01 -2,334.37 -3,853.24 6,028,700.12 465,926.45 0.00 3,645.91 PROJECTED to TD 7/13/2011 4:21:35PM Page 4 COMPASS 2003.16 Build 42F PIONEER NATURAL RESOURCES ALASKA )41 /6 Letter of Transmittal e. �G 20/i ag coli. 4neNirice 414441/04 Date: August 17, 2011 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Howard Okland 700 G Street, Suite 600 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps X Report X Other—Logs ❑ Agreement a DETAIL QTY DESCRIPTION ODSN-23i (API: 50-703-20639-0000) ODSN-23i PB2 (API: 50-703-20639-7100) 1 Report Surface Data Logging End of Well Report 8 Well Logs 2- 2" MD Formation Evaluation Log 2- 2" MD Drilling Engineering Log 2- 2" MD Gas Ratio Log 2- 5" MD Formation Evaluation Log We request that all data be treated as confidential information. Thank you. Received by: ' " Date: 2 11.1- ),� Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2193 fax 907-343-2128 phone PIONEER CFVE, NATURAL RESOURCES ALASKA , (; 0 2 NV Letter of Transmittait GA&c, .v141 .C9itiMiSSi011 Date: July 28, 2011 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Howard Okland 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 ODSN-23i (API:50-703-20639-0000) ODSN-23i PB1 (API:50-703-20639-7000) ODSN-23i PB2 (API:50-703-20639-7100) LWD Final Processed Data (digital graphic 1 CD 14 l ti ( 7 1 logs, digital data) 12 Well Logs Detail on following page We request that all data be treated as confidential information. Thank you. ILL Received by: O)U Date: t &d Y � 1 Please sign and return one copy to Pioneer Natural Resources, Inc., ATTN: Shannon Koh 700 G Street, Suite 600, Anchorage, AK 99501 907-343-2193 fax 907-343-2128 phone alt( — WO, July 28, 2011 QTY DESCRIPTION 1 CD LWD Final Processed Data (digital graphic logs, digital data) 12 Well Logs ODSN-23i(API:50-703-20639-0000) ROP, DGR, EWR, CTN, ALD, ABG Horizontal Presentation(1:600, 1:240) DGR, EWR, CTN, ALD, ABG (1:600, 1:240) ODSN-23i PB1 (API:50-703-20639-7000) ROP, DGR(1:600, 1:240) DGR(1:600, 1:240) ODSN-23i PB2(API:50-703-20639-7100) ROP, DGR, EWR(1:600, 1:240) DGR, EWR(1:600, 1:240) • Page 2 Page 1 of 2 • Schwartz, Guy L (DOA) 05c iA,k_ ebsK From: Schwartz, Guy L(DOA) I'r6 Z l( - 04-7_ Sent: Friday, June 17, 2011 9:23 AM To: 'Tirpack, Robert' Cc: Johnson, Vern; Vaughan, Alex Subject: RE: N-23i 9-5/8" Liner run and cement job Rob, Thanks for the summary below... I will add this to the well file. As you mention below we all agree that the Torok is isolated adequately as per the BAT sonic log. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Tirpack, Robert [mailto:Robert.Tirpack@pxd.com] Sent: Friday, June 17, 2011 8:55 AM To: Schwartz, Guy L(DOA) Cc: Johnson, Vern; Vaughan, Alex Subject: FW: N-23i 9-5/8" Liner run and cement job Guy, The N-23i intermediate hole section#1 proved to be fairly difficult to get liner run and cemented. While the interval drilled slower than normal,the trip out of the hole was very difficult. The hole packed off several times and extensive backreaming was required to clean up the interval. While backreaming right off of bottom, we experienced a 900 psi pressure loss. After pulling out of the hole, it was discovered that the BHA had parted at the reamer body and 95' of BHA was left in the hole. It was decided not to attempt a fishing operation due to the very small fishing neck on top of the BHA and the poor hole conditions. A bullnose and holeopener was run back in to clean up the hole. The fish was tagged on depth at the bottom of the hole. The clean out BHA was pulled without issues. The 9-5/8" liner run started out ok, but soon the well was taking fluid during the trip in. Circulation was established and lost several times during the trip in the hole with multiple circulating attempts. When the liner was on depth,full circulation was regained and the wellbore was circulated several times for clean up. The liner hanger was set without issue,and full circulation was once again established. Very shortly afterward, returns were lost. It is believed that drilled cuttings packed off around the liner hanger, causing the lost returns. Twice mud was bullheaded down the 11-3/4"X 9-5/8"annulus in an attempt to flush the hanger. When conventional circulation was restarted, returns were initially seen at surface, but were quickly lost. It was at this point it was decided to pump the cement job. The entire cement job was pumped without returns. The cement job was pumped without other issues,the plugs bumped, and the floats held. The liner and liner top packer all have passed subsequent pressure tests. Lift pressures from the cement job log show"71psi in lift pressure. This equates to"'529' MD of cement coverage in the annulus. The BAT sonic log was run to PBTD and MADD passed up to 10,000' MD. Good bond can be seen above and below the Torok,with some poor areas within the Torok. A good "ringing pipe"section was not found until way above the planned TOC. Based on the above information and discussions with multiple parties, it is believed that the Torok is isolated. 6/17/2011 Page 2 of 2 / • . Regards, Rob Robert Tirpack Drilling Superintendent Pioneer Natural Resources 907-343-2121 office 907-903-9454 cell robert.tirpack@pxd.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. 6/17/2011 Page 1 of 2 Schwartz, Guy L (DOA) From: Tirpack, Robert[Robert.Tirpack@pxd.com] Sent: Thursday, June 16, 2011 4:52 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern; Ryan Thompson; Davies, Stephen F (DOA) Subject: RE: N-23i Bond Log (PTD 211-042) Will proceed with the whipstock and milling operation while monitoring for cement and will report back with the FIT information. Regards, Rob From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, June 16, 2011 4:47 PM To: Tirpack, Robert Cc: Johnson, Vern; Ryan Thompson; Davies, Stephen F (DOA) Subject: RE: N-23i Bond Log (PTD 211-042) Rob, It looks like there is some cement above and below the Torok zone. (11100- 11500' md)and should provide zonal isolation as required by 20 AAC 25.030 (d)(5). (although the cement quality is poor through the Torok) . It is difficult to determine the quality of the bond but most likely there is little chance squeezing cement into the area around the Torok nonetheless. I think we can move ahead with your plan to set a whipstock and drill ahead out of the 9 5/8"casing . Please monitor the cutting during the window milling for cement and update me on the FIT once you drill out into new formation. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Tirpack, Robert [mailto:Robert.Tirpack@pxd.com] Sent: Thursday, June 16, 2011 4:11 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern; Ryan Thompson Subject: N-23i Bond Log Guy— Please take a look at the attached bond log for N-23i. It shows good bond over the MADD pass depth (10,000- 11750' MD), except for a couple of areas in the Torok. After the MADD pass depth we tripped on elevators back to surface at a much higher speed. The tool only has sporadic data from 10,000' MD up to surface. The first depth we see "free pipe" is around 7,600' MD. We can also see the top of liner at 5,598' MD. The planned TOC was 10,500' MD. I believe we have cement stringers and/or un-free pipe clouding the data from 7,600' on down which is not showing a good clear TOC. There is also appears to be more un-free above 7,600'. 6/16/2011 Page 2 of 2 We have had lengthy discussions with Halliburton in Anchorage and Houston,the data appears to be good and the tool appears to be functioning correctly. I will call you shortly so that we can discuss. Regards, Rob Robert Tirpack Drilling Superintendent Pioneer Natural Resources 907-343-2121 office 907-903-9454 cell robert.tirpack@pxd.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. 6/16/2011 Alaska Drilling project N23iPB2 r. R15P [ohmm] 0 10 r _. GR ILD_SMT[ohmm] 150 0 10 `S— 4.1Sii. . 11 ,008' and 1000 . 093 TOROK_SS Top Productive Zone--- _ _ , 11 ,100'md -too - :_-_ _ -4--- _ j _- 11200 11300isi z 11400 r. - .-,- ".." 11 ,496'mdv X500 095_TOROK_SS_BASE f". 2c 11600 I -ETRA 6/1512011 3:57:51 PM(kektoikt_type_Iop.CSP) Page 1 of 1 Schwartz, Guy L (DOA) From: Tirpack, Robert[Robert.Tirpack@pxd.com] Sent: Thursday, June 16, 2011 4:11 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern; Ryan Thompson Subject: N-23i Bond Log Attachments: AlaskaCBL3.pdf Guy— Please take a look at the attached bond log for N-23i. It shows good bond over the MADD pass depth (10,000- 11750' MD), except for a couple of areas in the Torok. After the MADD pass depth we tripped on elevators back to surface at a much higher speed. The tool only has sporadic data from 10,000' MD up to surface. The first depth we see "free pipe" is around 7,600' MD. We can also see the top of liner at 5,598' MD. The planned TOC was 10,500' MD. I believe we have cement stringers and/or un-free pipe clouding the data from 7,600' on down which is not showing a good clear TOC. There is also appears to be more un-free above 7,600'. We have had lengthy discussions with Halliburton in Anchorage and Houston,the data appears to be good and the tool appears to be functioning correctly. I will call you shortly so that we can discuss. Regards, Rob Robert Tirpack Drilling Superintendent Pioneer Natural Resources 907-343-2121 office 907-903-9454 cell robert.tirpack@pxd.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. 6/16/2011 Casing DTC Casing DTC microsec per ft microsec per ft 40 240 DTC2 Formation DTC Formation DTC Casing Energy microsec per ft microsec per ft microsec per ft 240 40 240 40 240 40 BAT DTC Depth Front Semblance Back Semblance - .,. 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'�M 3 NE=�=i7�1M�!! -7E z e a { . : simminomrmmmmi! 11650 [T`� IN= — -i 3 - M1�1•�i7IM�IMi■ 1.'-. = a t. £ e I 1 =��t�=�=Mi! — 1 - M��=C51�=�=i■ 11700 II ? =r ___ti_�___il - M�M��a==iia MMaMC.a�=�i� - -�� I ��=iNIMMEN 11750 �sii- a�it _,ii ---- - i --IN------- lra III I ��1MM=MINNOW. L�1i•i•6�Mi•i• 11800 NININI—NI NI--IIINI -------- MIIIIIIMMIONIIIIIIIIIMIIM �M��==== 11850 III=NM MMMM =---NINI =ME--- =MOM MINIIIMN ------ 11900 MINI--- MI=�� imi 11950 i BAT DTC Depth Front Semblance Back Semblance microsec per ft ft ZglaBAT Hi Freq Front R1 Wave BAT Hi Freq BackR1 Wave 240 1 1200 1 illik 200 1.2K 200 1.2K 240 microsec per ft 40 240 microsec per ft 40 - Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, June 10, 2011 1:25 PM To: 'Vaughan, Alex' Cc: Tirpack, Robert; Johnson, Vern; OoogurukDrillingSupervisor; Daggett, Paul Subject: RE: ODSN-23i (PTD 211-042 )-Open Hole Sidetrack( 9 5/8" Drilling liner) Alex, You have approval to proceed as you outline below. As the BHA doesn't have RA source a Sundry will not be required to abandon it. The 9 5/8" casing will be set about 300' higher than planned but your cement job will still isolate the Torok sand ( approx. 10800'— 11300' and as per the PTD information ) and kickoff depth of 11573' is well below the base of the Torok sand . I believe this will be PB2 for record keeping (counting the surface hole sidetrack) Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Vaughan, Alex [mailto:Alex.Vaughan@pxd.com] Sent: Friday, June 10, 2011 9:59 AM To: Schwartz, Guy L(DOA) Cc: Tirpack, Robert; Johnson, Vern; OoogurukDrillingSupervisor; Daggett, Paul Subject: ODSN-23i (PTD 211-042 )-Open Hole Sidetrack Guy, As stated via telephone conversation on 6-10-2011 we are planning to sidetrack the 8-1/2 x 9-1/2 section of ODSN-23i (PTD 211-042). After drilling to section TD of the 10-5/8"x 11-3/4" intermediate 1 section,we inadvertently twisted off above our reamer during the pre-casing run hole cleanup process. Due to the dimensional specifications of the fish we are forgoing any attempt to retrieve it. Our plan forward will be to run our 9-5/8" drilling liner to the top of fish, pump the cement job,and perform a sidetrack through our 9-5/8"casing around the fish. The fish consists of a rotary steerable BHA that does not contain radioactive logging instruments. Top of Fish: 11,897' MD Bottom of Fish: 11,991' MD Section TD: 11,991' MD Planned 9-5/8"Shoe: 11,887' MD Planned Kick-Off Point: 11,573" MD Let me know if you have any questions or require further information. Alex Vaughan Senior Drilling Engineer 6/10/2011 Page 2 of 2 PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) 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. 6/10/2011 _, Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday, May 25, 2011 4:37 PM To: Vaughan, Alex' Cc: Johnson, Vern; Tirpack, Robert; OoogurukDrillingSupervisor; Davies, Stephen F (DOA) Subject: RE: ODSN-23i (PTD 211-042 )-Open Hole Sidetrack Alex, Thanks for the update. The lost hole section will be named PB1 and will have a -70 suffix added to the API number. This notification is sufficient. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Vaughan, Alex [mailto:Alex.Vaughan@pxd.com] Sent: Wednesday, May 25, 2011 4:18 PM To: Schwartz, Guy L (DOA) Cc: Johnson, Vern; Tirpack, Robert; OoogurukDrillingSupervisor Subject: ODSN-23i (PTD 211-042 )- Open Hole Sidetrack Guy, As stated via telephone message on 5-25-2011 we sidetracked ODSN-23i (PTD 211-042). While drilling 14-1/2" hole in the surface section,we inadvertently sidetracked and were unable to re-capture the original hole. It was decided to continue sidetracking from 857' MD with the drilling BHA and drill to original planned TD. The wellbore below the sidetrack point from"'857'to 6,079' MD is expected to collapse over time and will not contribute to the production of the well as casing will cover this entire section . Deviation from permitted borehole and sidetrack is 118' at greatest point. Let me know if you have any questions or require further information. Alex Vaughan Senior Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error,please notify the sender by reply e-mail and delete the message and any attachments. 5/25/2011 v MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE:Wednesday,May 25,2011 Jim Regg --� P.I.SupervisorJ,,�- Z- SUBJECT:Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA INC 1R-06A FROM: Chuck Scheve KUPARUK RIV UNIT 1R-06A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry•JJ- NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1R-06A API Well Number: 50-029-21331-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS110522083820 Permit Number: 210-056-0 Inspection Date: 5/21/2011 , Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1R-06A •: YP Well zT a In SPT' TVD 6266 • T IA 10 zoo 2030- 2025 0560 P.T.D TypeTest Test psi L 1566 TOA 120 140 140 140 I 1 — -a-- Interval 4YRTST p/F P _ Tubings 1400 I 1400 1 1400 1 1400 Notes: 1 Wednesday,May 25,2011 Page 1 of 1 Sc[fa113 [E OF a a 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 Alex Vaughan Operations Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-23i Pioneer Natural Resources Alaska, Inc. Permit No: 211-042 Surface Location: 2902' FSL, 1209' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 3609' FSL, 190' FEL, SEC. 08, T13N, R7E, UM Dear Mr. Vaughan: 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. Sincerely, 0 ,„.. Daniel '. Seamount, Jr. Chair DATED this day of April, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) , STATE OF ALASKA RECEIVED-1, / KA OIL AND GAS CONSERVATION COh, SION PERMIT TO DRILL MAR 1 7-011 20 AAC 25.005 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil 0 Service- Winj ❑ Single Zone Qi�" e�l! jeeion Drill 0Redrill ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas Gas Hydr``at``e�stLi Re-entry ❑ Exploratory ❑ Service- WAG ❑✓ Service-Disp ❑ "qii&Mas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283 I ODSN-23. 3.Address: 700 G Street,Suite 600 6.Proposed Depth: 12.Field/Pool(s): Anchorage,AK 99501 MD: 20,578' • TVD: 6166' i 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Oooguruk-Nuiqsut Oil Pool Surface: 2902'FSL, 1209'FEL,Sec. 11,T13N, R7E, UM ADL 355036./ADL 355037 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 4285'FSL,634'FEL,Sec. 16,T13N, R7E, UM 417497 April 18,2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 3609'FSL, 190'FEL,Sec.8,T13N, R7E, UM 5760/5724 634' 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-469788.76 • y-6031018.57 • Zone-ASP 4 GL Elevation above MSL: to Same Pool: ODSN-16 is 1686'away 13.5 feet 16.Deviated wells: Kickoff depth: 164 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 94.02 degrees Downhole: 3142 • Surface: 2464 . 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 109# H-40 Welded 115' Surface Surface 158' 158' Driven 14-1/2" 11-3/4" 60# _ L-80 HYD 521 5877' Surface Surface 5920' 3214' 721 sx PF'L';518 sx Class'G' • 11-3/4" 9-5/8" 40# L-80 HYD 521 6118' 5770' 3160' 11,888' 5369' 576 sx Class'G' 8-1/2" 7" 26# L-80 BTC-M 13,837' Surface Surface 13,880' 6144' 144 sx Class'G' •6-1/8" 4-1/2" 12.6# L-80 HYD 521 6848' 13,730' 6113' 20,578' 6166' Uncemented 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 ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production - Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat Q BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 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 Alex Vaughan Title Operations Drilling Engineer Signature Phone 343-2186 Date 3/22/2011 �� Commission Use Only Permit to Drill ' d API Number: Permit Approva�r See cover letter for other Number: Z 1 50-(b3'�63?-Q>-a) Date: // >1 requirements. Conditions of approval: If box is checked, may not be used to explore for,test,or produce coalbed m hane, as hydrates,or gas contained in shales: 2' Other: ,0 L./SOO"sem 6o, -77-,;/.- Samples req'd: Yes❑ No Mud log req'd: Yes ❑ No[v]/ - , 2.5-04f., lov • A Ala w l4., 7;Z---6"14.--I‘\ H2S measures: Yes 0 No Directional svy req'd: Yes [n 'No❑ �tilon.,._ o ..•%.. 4. / /O 3`! - Di {tir Wd,ia4, -- r►` 4cc.o� — M l r Z ee.. ,.«,t-c., ox, 11AG25. o 350 ) 0// APPROVED BY THE COMMISSION WS/./ DATE: Illy, ,COMMISSIONER O R I G INAL / '/./.f( A> 7.7/,, i , 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 ALASKA Pioneer Natural Resources Alaska, Inc. 700 G Street,Suite 600 Anchorage,Alaska 99501 Tel:(907)277-2700 Fax:(907)343-2190 March 22nd, 2011 RECEIVED' State of Alaska Alaska Oil and Gas Conservation Commission Ei �',� 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 geskz Q11&Gas Cons.Commission ;tncnorege RE: Application for Permit to Drill ODSN-23i Surface Location: 2902' FSL, 1209' FEL, Sec 11, T13N, R7E, UM X = 469,788.76, Y = 6,031,018.57, 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-Nuiqsut formation. PNRA requests the Permit To Drill based on approved Pool Rules. PNRA intends to pre-produce ODSN-23i prior to • injection. As indicated in the attachments, the drilling and well construction program includes the following: • Surface Hole: o Drill 14-1/2" to —5,920' MD / 3,214' TVD and set 11-3/4" casing. , • Intermediate Hole 1: o Drill 10-5/8" and under-ream while drilling (UWD) to 11-3/4" to —11,888' MD / 5,369' TVD. Run and set a 9-5/8" drilling liner. • Intermediate Hole 2: o Drill 8-1/2" to —13,880' MD / 6,144' TVD and set 7" Intermediate casing into the top of the Oooguruk-Nuiqsut formation. • ODSN-23i Lateral Hole: o Drill 6-1/8" horizontally to —20,578' MD / 6,166' TVD and set a 4-1/2" solid liner with perforated pups. • Completion: o 3-1/2" injection completion string with Packer, Rock Gauge, GLM & SSSV. Alaska Oil & Gas Conservation Commission March 22nd, 2011 Page 2 of 3 PNRA will implement Managed Pressure Drilling technology (MPD) while drilling the Intermediate 2 and Lateral hole sections of ODSN-23i as outlined below. • From TD of Intermediate 1 until Intermediate 2 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: • Kuparuk Sands, -9.8 ppg Pore Pressure • Nuiqsut Sands, -9.8 ppg Pore Pressure • From the Intermediate 2 to TD o Use -7.2-8.2 ppg fluid while using MPD to control pressure from the surface to -9.8-10.2 ppg EMW at the bottom of the hole during connections and while tripping. • Open formations: • Nuiqsut Sands, -9.8 ppg Pore Pressure 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. Alaska Oil & Gas Conservation Commission March 22nd, 2011 Page 3 of 3 The following items are on file with the AOGCC: 1) A plat showing the surface location proposed for the well per 20 AAC 25.005 (c) (2). of the BOP and diverter equipment to be used on Nabors 2) Diagrams and descriptions Alaska Rig 19-AC as required by 20 AAC 25.035 (b) and (c). 20 3) A description of theprocedure for conductingformation integrity tests per AAC p 9 Y 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 functioningon the rigas standard operating procedure for all wells drilled by P 9 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 Robert Tirpack, Drilling Superintendent (20 AAC 25.070) 907.343.2121 robert.tirpack@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 April 18th, 2011. If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. Sincerely, Alex Vaughan Operations Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSN-23i Well File 7'4 ODSN-23i Injection Well Proposed Completion _ L..n ,,;,,_ ' Well Head: 11-3/4", 5K,VetcoGray O Casing Tree: 3-1/2", 5K, Horizontal Item# Item MD(ft) TVD(ft) A 16"Conductor 158 158 B 11-3/4"60#L-80 Hydril 521, 10.772" ID 5,920 3,214 ..1 L C 9-5/8"40#Hydril 521,8.835"ID* 11,888 5,369 D 7"26#L-80 BTC-M, 6.276" ID** 13,880 6,144 E 416#12.60#L-80 Hydril 521 20,578 6,166 -' - . 2� O F 3W 9.3#L-80 TCII 13,680 6,101 •moi' *Estimated TOC @ 10,279'MD **Estimated TOC© 13,031'MD Upper Completion Item#_•Ite ;r� IME _. _ . Uft. MDrkb. ,Nprkb(ft) 1 VetcoGray Tubing Hanger 34 34 HES Wellstar TRSSSV w/31/2"9.2#TC-II Box x Pin 9 Chr 2 2,000 1,744 w/2.813"X'Profile w/1/4"x.049 SS CL to Surface 3 GLM#1 HES Vanoil 3'W x 1'/z"Gas Lift Mandrel w/3'W TBD • TBD L(1 9.2#TC-II Box x Pin w/Dummy in place K 3 )� 4 GLM#2 HES Vanoil 3'/z'x 1W Gas Lift Mandrel w/3'/z" �D TBD II O 9.2#TC-II Box x Pin w/Dummy in place 5 GLM#3HES Vanoil 3W x 1'/z"Gas Lift Mandrel w/3W TBD TBD 9.2#TC-II Box x Pin w/Dummy in place �J« 6 HES ROC Gauge&Carrier w/TA"9.2#TSHP Box x Pin 13,120 5,891 (,, 1 joint above X nipple) • S}ti"'� 7 HES 2.813"X'Nipple 9 Chr w/3'W 9.2#TC-II Box x Pin 13,170 5,912 (min 2 its above packer) IrC ET) Weatherford 4Y 13.5#x 7"23-32#Model"Ultra Pak-T1-1" 8 Hydraulic Set Permanent Production Packer w/4''A 13.5# 13,240 5,943 4 I �� New Vam Rn x Pin 9 HES 2.813"X'Nipple 9 Chr w/3Y�"9.2#TC-II Box x Pin 13,260 5,952 (min 2 Its above XN nipple) 0 HES 2.813"XN"Nipple w/2.750"No-Go 9Chrw/3W TCII 13,330 • 5,982 Box x Pin w/"RCH-M" Plug in Place(Set-70 deg Incl.) 11 WLEG w/3'/z"TCII Box 13,880 6,144 End of Assembly 13,882 ' 6,145 Lower Completion Item# Item MD(ft) TVD(ft) 0.---------41r 12 WFT PBR Tie Back Sleeve 15ft 13,712 6,109 (51 I 13 WET"NTH"Liner Top Pkr w/Hold Down Slips 5" 184 x 7" 13,727 6,113 � 26#w/Vam Top HT Pin WFT"PHR"Rotating Liner Hanger 5" 18#x 7"26#w/5" ' O 14 Vam Top HT Pin x Pin and XO w/5"New Vam HT Box 13,730 6,114 O 4'/z'Hydril 521 Pin O 15a x 6 WFTZoneSelect Sliding Sleeve w/6 1/2 holes w/4-1/2 TBD TBD Hydril 521 Box x Pin(OPEN Position) O - - O 15b x 6 WFTZoneSelect Sliding Sleeve w/2.20 Carbide Nozzles TBD TBD w/4-1/2 Hydril 521 Box x Pin(Closed Position) O II ® 15c x 6 WFT Genesis 5.750 OD x 4-1/2 12.60 x 15 Ft Oil Base TBD TBD Swell Pkr w/4-1/2 Hydril 521 Box x Pin L-80 O 17. .J O 16 Liner Shoe(PLUGGED) 20,563 6,166 TD 20,578 6,166 . 0 0 _ 0 _ 0 _ 0 _ 00 00 0 0 0 0 0 0 O Open • 1n • Closed 16 c swL P(CA Date: Revision By: Comments PIONEER3/17/2011 Alex VTVVaughan ProposedNumber ooion vp Correction NUAlRESOSCESAIASO 3/21/2011 Alex Vaughan Updated TVD's Permit to Drill Well Plan Summary ODST-23i Oooguruk — Nuiqsut Single Lateral Injection Well Surface TD @ 5,920' MD / 3,214' TVD Drilling Liner TD @ 11 ,888' MD / 5,369' TVD Intermediate TD @ 13,880' MD / 6,144' TVD Lateral TD @ 20,578' MD / 6,166' TVD Surface Location: 2902' FSL, 1209' FEL, Sec. 11, T13N, R7E, UM ASP 4 (NAD27) projection X =469788.76 Y= 6031018.57 Target: Oooguruk-Nuiqsut 4285' FSL, 634' FEL, Sec. 16, T13N, R7E, Umiat X =459793.33 Y = 6027168.90 6,144' TVDrkb Bottom Hole Location ODST-231 3609' FSL, 190' FEL, Sec. 8, T13N, R7E, X =454972.00 Y= 6031800.00 6,166' TVDrkb AFE Number: TBA Est. Start Date: Apr 18th, 2011 Rig: Nabors 19AC Operating days: 51 days to Drill and Complete Obtective &Well Type Nuiqsut Development Well Well Design: Modified Slimhole (11-3/4"x 9-5/8" liner x 7"x 4-1/2" liner) Single-Lateral 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: March 22"d,2011 ODSN-23i Permit To Drill Page 1 of 12 Well Control: Well Section Pressure Depth Basis psi TVD 14-1/2" Surface Section Maximum anticipated BHP 1437 3214 Based on seawater gradient of 0.4472 psi/f Maximum surface pressure 1084 Surface (Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 10-5/8"x 11-3/4" Drilling Liner Hole Section Maximum anticipated BHP 2401 5369 (Based on seawater gradient of 0.4472 psi/ft) Maximum surface pressure 1810 Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 8-1/2" Intermediate Casing Hole Section Maximum anticipated BHP 3131 6144 Based on 9.8 ppg Oooguruk-Kuparuk pore pressure) Maximum surface pressure 2455 Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 6-1/8" Lateral Hole Section Maximum anticipated BHP 3142/ 6166 Based on 9.8 ppg Oooguruk-Nuiqsut pore pressure) Maximum surface pressure 2464 / Surface Based on BHP and a full column of gas • from TD @ 0.11 psi/ft) Maximum casing pressure: 3500 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): r Hydril 21-1/4"2M annular BOP 1 16"full opening knife gate valve, hydraulically actuated 16"diverter line 5000 psi BOP stack(see attached schematic): Hydril GK 11" 5M annular BOP Hydril 11" 5M single ram BOP w/studded connections Hydril 11" 5M single ram BOP w/studded connections Drilling cross 11" 5M x 11" 5M with 2 ea. 3-1/8"5M side outlets w/flanged connections 2 ea. 3-1/8"5M full opening inner manual gate valves mounted on drilling cross 2 ea. 3-1/8" 5M full opening outer remote hydraulic controlled gate valves mounted on inner gate valves. Hydril 11" 5M single ram BOP w/studded connections Pioneer Natural Resources Last Revised: March 22"d,2011 ODSN-23i Permit To Drill Page 2 of 12 Formation Integrity Testing Requirements: Test Point 11-3/4" Surface Shoe Depth Test Type Minimum EMW Rathole +20'to 50'from shoe LOT 12.5 ppg 9-5/8" Drilling Liner Shoe Rathole +20'from shoe FIT 13.5 ppg 7" Intermediate Shoe Rathole +20'from shoe FIT 12.5 ppg Drilling Fluids Program: Surface Hole Mud Properties: 14-1/2" hole Spud Mud Interval Density(ppg) Viscosity(secs) YP PV 10 sec gel API FL Initial 8.8 150-200 35-50 15-25 10- 15 unrestricted Final 9.2-9.6 70-100 25-35 15-25 10- 15 <12 Drilling Liner Mud Properties: 10-5/8"x 11-3/4" hole LSND Interval _ Density(ppg) Viscosity(secs) YP PV MBT _ API FL Initial to TD 9.8 ppg 40-60 15-25 12-20 < 12 8- 10 Intermediate Hole Mud Properties: 8-1/2" hole LSND Interval Density(ppg) Viscosity(secs) YP PV MBT API FL Initial to TD 9.8 - 10.5 ppg 50-70 15-25 15-25 < 10 3-5 (-12.5 ppg via (8-10 HTHP) MPD) Lateral Hole Mud Properties: 6-1/8" hole MOBM Interval Density(ppg) Viscosity(secs) YP PV ES HTHP 0/W Initial to TD 7.2 -8.2 ppg 55-80 12 -25 10-20 800-2000 <6 94/6 (-9.8 ppg via MPD) Pioneer Natural Resources Last Revised: March 22"d,2011 ODSN-23i Permit To Drill Page 3 of 12 Formation Markers: Formation Tops MD (ft) TVDrkb (ft) Pore Press. EMW Comments (psi) (PPM Base of Permafrost 1643 1608 Top West Sak - 3288 2281 1026 8.65 Base of fluvial sands Tuffaceous Shales 5146 2939 Hue2 tuff 5893 3204 11-3/4"casing point 5920 3213 Brook 2B 8759 4219 1898 8.65 Top Torok Sand - 10779 4938 Base Torok Sand 11294 5133 Torok Shale 1 11865 5359 9-5/8"casing point 11888 5369 Top HRZ 12757 5733 Base HRZ 13048 5860 Kalubik Mkr 13343 5987 Top Kup C 13531 6057 3087 9.8 Base Kup C (LCU) 11133 6047 BCU 13688 6104 Top Nuiqsut 13825 6135 3126 9.8 Production Zone 7"casing point 13880 6145 ODST-231 TD 20579 6168 Pioneer Natural Resources Last Revised: March 22"d,2011 ODSN-23i Permit To Drill Page 4 of 12 Logging Program: 14-1/2" Section: Drilling: Dir/GR Open Hole: N/A Cased Hole: N/A 10-5/8"x 11-3/4" Section: Drilling: Dir/GR/Res/ACAL Open Hole: N/A Cased Hole: N/A 8-1/2" Section: Drilling: Dir/GR/ Res Open Hole: N/A Cased Hole: ODST-231 6-1/8" Section: Drilling: Mud logging • Dir/GR/ Res/AzDens/ Neut / PWD/BatSonic Open Hole: N/A Cased Hole: N/A Pioneer Natural Resources Last Revised: March 22nd,2011 ODSN-23i Permit To Drill Page 5 of 12 ODST-231 Casing Program: Hole Casing/ Weight Grade Conn. Casing Csg/Tbg Hole Btm Size Tubing Length Top MDrkb/TVDrkb MDrkb 24" 16" 109# H-40 Welded _ 115 Surface 158 158 14-1/2" 11-3/4" 60# L-80 Hydril 521 5877 Surface 5920 3214 11-3/4" 9-5/8" 40# L-80 Hydril 521 _ 6118 5770 11888 5369 8-1/2" 7" 26# L-80 BTC-M 13837 Surface 13880 6144 6-1/8" 4-1/2" 12.6# L-80 Hydril 521 6848 13730 20578 6166 Tubing 3-1/2" 9.3# L-80 TCII 13637 Surface 13680 6101 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 11-3/4" 60# L-80 10.772" 10.62" Hydril 521 5830 3180 1384M 1384M 9-5/8" 40# L-80 8.835' 8.75" Hydril 521 5750 3090 916 M 916 M 7" 26# L-80 6.276" 6.151 Hydril 511 7240 5410 604 M 604 M 7" 26# L-80 6.276" 6.151 BTC-M 7240 5410 604 M 604 M 4-1/2" 12.6# L-80 3.958" 3.833" Hydril 521 na na 289 M 289 M Pioneer Natural Resources Last Revised: March 22"d,2011 ODSN-23i Permit To Drill Page 6 of 12 Cement Calculations: Casing Size: 11-3/4" Surface Casing-single stage Basis: Lead: 75% excess over gauge hole in permafrost+ 50 bbls, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 30% excess, plus 85' shoe track Tail TOC: 4,817' MD-500' MD of open hole Total Cement Volume: Preflush 10 bbl water Spacer 60 bbl 10.0 ppg Dual Spacer Lead 533 bbls/721 sx of 10.92 ppg Type "L" Permafrost Cement. 4.15 cf/sk, 20.0 gps water req. Tail 110 bbls/518 sx of 15.9 ppg Premium "G" + adds. 1.19 cf/sk, 5.23 gps water req. Displ 640 bbls Mud Temp BHST-55° F, BHCT-60° F estimated Should hole conditions indicate that we will have trouble getting cement to surface, a TAM Port Collar may be run in the casing string and a staged cement job will be performed. In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work forp ossible witness of cement to surface. Casing Size: 9-5/8" Intermediate 1 -Drilling Liner-single stage Basis: TOC: 10,279' MD-The greater of 500' MD of open hole or 500' MD above top of Torok 60% excess, plus 85'shoe track Total Cement Volume: Preflush 10 bbl water Spacer 60 bbl 10 ppg Dual Spacer Primary 120 bbls/576 sx Premium "G" +adds. 1.17 cf/sk Displ 560 bbls mud Temp BHST- 135° F, BHCT-110° F Casing Size: 7" Intermediate 2-single stage Basis: TOC: --13,031'MD-500' MD above the top of the Kuparuk 40% excess, plus 85'shoe track Total Cement Volume: Preflush 10 bbl water Spacer 40 bbl 12.5 ppg Dual Spacer Primary 30 bbls/ 144 sx Premium "G" +adds. 1.17 cf/sk Displ 528 bbls mud Temp BHST- 165° F, BHCT-135° F This well is outside the 1/2 mile radius around the disposal well at the intersection with the Torok disposal zone. Disposal: Annular Injection: Currentlynot requested, but maybe requested in the future. q � q Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 /Class 2 disposal well, ODSDW1-44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 /Class 2 disposal well, ODSDW1-44. Pioneer Natural Resources Last Revised: March 22"d,2011 ODSN-23i Permit To Drill Page 7 of 12 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 16"conductor casing. 2. Nipple up spacer spools and riser. —• "p;ver!-w 'i41('e-1 3. MU 14-1/2" Directional Drilling, MWD/LWD assembly. Drill surface hole to the casing point, making wiper trips as necessary. Circulate and condition the hole to run casing. POOH. 4. Run and cement the 11-3/4"surface casing. Bump the plug and bring the pressure up to 3500 , psi–chart and hold for 30 minute pressure test. Send chart to ODE. Note: A Port Collar may be run based on hole conditions at Company Rep discretion. 5. Ensure floats are holding. WOC if needed. • 6. ND Riser, NU Drilling Spool and BOPE and test. Test BOPE to 250/4500 psi - Notify AOGCC 48 hours in advance of test. 7. MU 10-5/8"x 11-3/4" RSS, MWD/LWD (BHA will be a 10-5/8" pilot hole opened to 11L4"while • drilling). 8. RIH and cleanout casing to landing collar. Displace well over to Intermediate 1 drilling fluid. 9. Drill through surface shoe, rathole +20'of new hole and perform LOT to a minimum of 12.5 ppg. / 10. Drill 10-5/8"x 11-3/4" Intermediate 1 to casing point., 11. Change one set of pipe rams to 9-5/8"and test BOPE as required. • 12. Run 9-5/8"drilling liner on 5" DP. Set liner hanger, release from liner and cement. 13. Bump the plug, increase pressure to 3500 psi and hold pressure for 5 minutes • This will provide a quick integrity test of the 9-5/8" liner • Note the pressure test in the morning report 14. Release pressure and ensure floats are holding • This will check the integrity of the floats to ensure there isn't a flow path through the liner shoe 15. Set liner top packer and test the liner top to 3500 psi for 5 minutes f • This will check the integrity of the liner top packer to ensure isolation between the liner and the surface casing • Note the pressure test of the liner top in the morning report 16. POOH w/5" DP. 17. ND BOPE, ND Drilling spool, NU Mulitbowl Wellhead, & NU BOPE and test to 250/4500 psi - Notify AOGCC 48 hours in advance of test. • it Ensure integrity of the liner and the liner top has been verified by a pressure test prior to performing this step 18. MU 8-1/2" RSS, MWD/LWD on 5" DP. RU MPD trip nipple. • 19. RIH and cleanout casing to landing collar. 20. Close pipe rams and combo pressure test the Drilling Liner and the Surface Casing to 3500 psi • for 30 minutes--chart and send to ODE. 21. Drill through drilling liner shoe +20' of new hole and perform FIT to 13.5 ppg, 22. RD MPD trip nipple and RU bearing assembly. Drill 8-1/2" Intermediate 2 to casing point. • 23. Circulate and condition the well to run 7" intermediate casing. Displace the well over to –12.5 ppg mud for shale stability. RD the MPD bearing assembly and RU MPD trip nipple. POOH. Pioneer Natural Resources Last Revised: March 22"d,2011 ODSN-23i Permit To Drill Page 8 of 12 24. Change one set of pipe rams to 7"and test BOPE as required, Note: Intermediate casing string may be run as a 7" long string or as a 7" liner with a 7" tieback string to surface depending on drilling conditions. Both options have been provided below: Option #1: 7" Longstring 25. Run and cement the 7"26#L-80 BTC-M intermediate casing. 26. Bump the plug and bring the pressure up to 3500 psi—hold for 5 minute pressure test. Release pressure and ensure floats are holding. 27. LD 5"DP Option#2: 7" Liner with Tie-Back Option 28. Run 7", 26#L-80 Hydril 511 intermediate liner on 5"DP. Set liner hanger, release from liner and cement. Bump the plug and bring the pressure up to 3500 psi—hold for 5 minute pressure test. • This will provide a quick integrity test of the 7"liner. • Note the pressure test in the morning report. 29. Release pressure and ensure floats are holding. • This will check the integrity of the floats to ensure there isn't a flow path through the liner shoe. 30. Set liner top packer and test the 9-5/8"liner and 7"liner top packer to 3500 psi for 30 minutes. . • This will check the integrity of the 7"liner top packer to ensure isolation between the 7"liner and the 9-5/8"drilling liner. • Note the pressure test of the liner top in the morning report • 31. Run 7", 26#L-80 BTC intermediate tie-back to 7"liner-hanger seal bore and space out. - 17e- 32. 32. Displace diesel freeze protection down 7"annulus to 2,000'tvd with annular preventer closed. 33. Strip through annular preventer and sting into 7"liner-hanger seal bore and land tie-back casing. 34. Pressure test seal assembly to 3500 psi—hold& chart for 30 minutes. • 35. Pressure test 7"tie back annulus 3500 psi—hold and chart for 30 minutes. 36. Set and test 7"pack-off. 37. RU MPD trip nipple & PU 4" DP as needed to TD the lateral hole section. 38. RIH to landing collar and w/4" DP & mill tooth cleanout bit. 39. Change pipe rams to 4"and test BOPE to 250/4500 psi—Notify AOGCC 48 hours in advance of test. 40. Pressure test casing to 3500 psi—chart and hold for 30 minute pressure test unless previously done in Option #2. Send chart to ODE. 41. Drill through Intermediate 2 shoe and POOH w/cleanout assembly. • 42. MU 6-1/8" RSS, MWD/LWD drilling assembly on 4" DP and RIH. 43. RD MPD trip nipple and RU bearing assembly. 44. Displace to drill-in-fluid for lateral hole. 45. Drill rathole +20'of new hole and perform FIT to 12.5 ppg.' 46. Drill 6-1/8" lateral lateral hole to TD. 47. Circulate and condition hole to run liner. 48. POH to intermediate shoe and set heavy weight balance brine pill. Cont POOH to surface. Pioneer Natural Resources Last Revised: March 22"d,2011 ODSN-23i Permit To Drill Page 9 of 12 49. Change one set of pipe rams to 4-1/2"and test BOPE as required. 50. RIH w/4-1/2"solid production liner w/sliding sleeves and swell packers from 150' inside the intermediate shoe to TD. 51. Release from the liner and set the liner top packer. Displace the well over to 10.2 ppg Brine and POOH. 52. MU and RIH w/3-1/2 injection completion w/ Packer, Rock Gauge, GLM, SSSV. 53. Space out, Land the tubing and RILDS. Install TWC. 54. ND BOPE, NU tree and test to 5,000 psi. 55. Pull TWC and reverse circulate corrosion inhibited brine and diesel to freeze protect the well to —2000'TVD and allow to u-tube. se)- Pack 56. Drop ball and rod and allow to seat. Pressure test the tubing to 3,500 psi—chart and hold for 30 minutes. Bleed off pressure and then pressure test the annulus to 3,500 psi—chart and hold for 30 minutes. Bleed off pressure. 57. RDMO to next well. Post-Rig Work 1. RU Slickline and pull the ball and rod. Pull the RHC-m plug. 2. RD Slickline. Pioneer Natural Resources Last Revised: March 22"d,2011 ODSN-23i Permit To Drill Page 10 of 12 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'/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: March 22nd,2011 ODSN-23i Permit To Drill Page 11 of 12 ODST-23I 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. • 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. Kick Tolerance/Integrity Testing Kick Tolerance/ Integrity Testing Summary Table Casing set/ Maximum Mud Weight Exp Pore Min LOT/FIT Interval Influx Volume Press 11-3/4" Surface/ 761 bbls 9.8 ppg 2401 12.5 ppg (LOT) 10-5/8"x 11-3/4" 9-5/8" Drilling Liner/ Infinite 9.8-10.5 ppg 3131 13.5 ppg (FIT), 8-1/2" (12.5 EMW w/MPD) ODSN-23i 7.2-8.2 ppg 7" Intermediate/ Infinite (g 8_10.2 EMW w/MPD) 3142 12.5 ppg (FIT) 6-1/8" 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 • A seismic fault with an expected throw of 20-35' may be encountered around 13,731' MD. 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Z CO W N Z Z Z Z Z Z m gSw O A a W A A A A< A A -.= 9 N < N < (<)() lD D co o 0 Halliburton Company HrALLIBURTON Standard Proposal Report Database: Pioneer Alaska Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-23i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-23i IN14 Design: ODSN-23i IN14 wp07 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: 0.00 ft Slot Radius: in Grid Convergence: -0.23 ? Well ODSN-23i-Slot ODS-23 Well Position +N/-S 0.00 ft Northing: 6,031,018.57 ft Latitude: 70°29'44.931 N +EI-W 0.00 ft Easting: 469,788.76 ft Longitude: 150° 14'49.325 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 13.50ft Wellbore ODSN-23i IN14 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (?) (?) (nT) I G RF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-23i IN14 wp07 Audit Notes: Version: Phase: PLAN Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (?) 42.70 0.00 0.00 274.77 3/16/2011 3:03:04PM Page 2 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: Pioneer Alaska Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.20ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-23i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-23i IN14 Design: ODSN-23i IN14 wp07 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +EI-W Rate Rate Rate Tool Face (ft) (?) (?) (ft) ft (ft) (ft) (?/100ft) (?/100ft) (?/100ft) (?) 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 0.00 0.00 0.00 0.00 164.00 0.00 0.00 164.00 107.80 0.00 0.00 0.00 0.00 0.00 0.00 735.43 20.00 279.77 723.90 667.70 16.75 -97.30 3.50 3.50 0.00 279.77 2,602.36 69.25 234.77 2,038.14 1,981.94 -472.25 -1,215.43 3.00 2.64 -2.41 -52.89 ' 10,302.36 69.25 234.77 4,766.18 4,709.98 -4,626.24 -7,096.93 0.00 0.00 0.00 0.00 12,802.36 64.25 309.77 5,752.73 5,696.53 -4,550.75 -9,231.44 2.76 -0.20 3.00 94.15 13,302.36 64.25 309.77 5,969.95 5,913.75 -4,262.67 -9,577.60 0.00 0.00 0.00 0.00 13,823.45 79.04 314.90 6,133.68 6,077.48 -3,929.95 -9,941.41 2.99 2.84 0.99 19.11 13,847.23 79.04 314.90 6,138.20 6,082.00 -3,913.46 -9,957.94 0.00 0.00 0.00 0.00 14,096.34 86.16 317.18 6,170.26 6,114.06 -3,735.73 -10,129.27 3.00 2.86 0.92 17.78 14,670.69 86.16 317.18 6,208.68 6,152.48 -3,315.37 -10,518.75 0.00 0.00 0.00 0.00 14,895.39 90.00 311.64 6,216.20 6,160.00 -3,158.31 -10,679.09 3.00 1.71 -2.47 -55.44 14,970.65 92.26 311.60 6,214.72 6,158.52 -3,108.34 -10,735.34 3.00 3.00 -0.05 -0.97 16,286.08 92.26 311.60 6,162.90 6,106.70 -2,235.71 -11,718.29 0.00 0.00 0.00 0.00 16,372.42 90.00 312.87 6,161.20 6,105.00 -2,177.69 -11,782.20 3.00 -2.61 1.47 150.63 16,469.65 87.08 312.84 6,163.67 6,107.47 -2,111.59 -11,853.44 3.00 -3.00 -0.02 -179.53 17,746.74 87.08 312.84 6,228.66 6,172.46 -1,244.29 -12,788.60 0.00 0.00 0.00 0.00 17,846.61 90.00 313.53 6,231.20 6,175.00 -1,175.96 -12,861.39 3.00 2.92 0.69 13.23 17,980.77 94.02 313.47 6,226.49 6,170.29 -1,083.69 -12,958.62 3.00 3.00 -0.05 -0.88 19,182.90 94.02 313.47 6,142.13 6,085.93 -258.73 -13,828.93 0.00 0.00 0.00 0.00 19,323.21 90.00 314.70 6,137.20 6,081.00 -161.20 -13,929.63 3.00 -2.87 0.88 162.93 19,368.15 88.65 314.70 6,137.73 6,081.53 -129.58 -13,961.57 3.00 -3.00 0.00 180.00 20,578.08 88.65 314.70 6,166.20 6,110.00 721.28 -14,821.31 0.00 0.00 0.00 0.00 3/16/2011 3:03:04PM Page 3 COMPASS 2003.16 Build 42B E Halliburton Company HALLIBURTOft Standard Proposal Report Database: Pioneer Alaska Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.20ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-23i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-23i 1N14 Design: ODSN-23i IN14 wp07 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section I (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) -13.50 I 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,018.57 469,788.76 0.00 0.00 100.00 0.00 0.00 100.00 43.80 0.00 0.00 6,031,018.57 469,788.76 0.00 0.00 164.00 0.00 0.00 164.00 107.80 0.00 0.00 6,031,018.57 469,788.76 0.00 0.00 Start Dir 3.5°/100':164'MD,164'TVD:279.77°RT TF 200.00 1.26 279.77 200.00 143.80 0.07 -0.39 6,031,018.64 469,788.37 3.50 0.39 300.00 4.76 279.77 299.84 243.64 0.96 -5.57 6,031,019.55 469,783.20 3.50 5.62 400.00 8.26 279.77 399.18 342.98 2.88 -16.74 6,031,021.52 469,772.04 3.50 16.92 500.00 11.76 279.77 497.65 441.45 5.83 -33.87 6,031,024.54 469,754.92 3.50 34.23 600.00 15.26 279.77 594.86 538.66 9.79 -56.88 6,031,028.59 469,731.92 3.50 57.50 700.00 18.76 279.77 690.47 634.27 14.76 -85.71 6,031,033.67 469,703.12 3.50 86.64 735.43 20.00 279.77 723.90 667.70 16.75 -97.30 6,031,035.71 469,691.54 3.50 98.35 Start Dir 3°/100':735.43'MD,723.9'TVD 800.00 21.22 275.50 784.34 728.14 19.74 -119.81 6,031,038.80 469,669.04 3.00 121.04 900.00 23.30 269.77 876.89 820.69 21.40 -157.62 6,031,040.61 469,631.25 3.00 158.85 1,000.00 25.55 264.97 967.94 911.74 19.43 -198.88 6,031,038.81 469,589.98 3.00 199.81 1,100.00 27.94 260.92 1,057.25 1,001.05 13.85 -243.51 6,031,033.40 469,545.33 3.00 243.81 1,200.00 30.42 257.47 1,144.56 1,088.36 4.66 -291.36 6,031,024.41 469,497.45 3.00 290.74 1,300.00 32.98 254.50 1,229.63 1,173.43 -8.11 -342.32 6,031,011.85 469,446.44 3.00 340.46 1,400.00 35.61 251.92 1,312.24 1,256.04 -24.42 -396.24 6,030,995.76 469,392.46 3.00 392.84 1,500.00 38.28 249.65 1,392.16 1,335.96 -44.23 -452.97 6,030,976.19 469,335.66 3.00 447.73 1,600.00 40.99 247.64 1,469.17 1,412.97 -67.48 -512.36 6,030,953.18 469,276.18 3.00 504.98 1,643.00 42.17 246.84 1,501.33 1,445.13 -78.52 -538.67 6,030,942.25 469,249.83 3.00 530.28 Base Permafrost 1,700.00 43.74 245.84 1,543.05 1,486.85 -94.11 -574.24 6,030,926.80 469,214.20 3.00 564.43 1,800.00 46.50 244.21 1,613.61 1,557.41 -124.05 -638.45 6,030,897.13 469,149.87 3.00 625.93 1,900.00 49.29 242.72 1,680.65 1,624.45 -157.21 -704.81 6,030,864.24 469,083.38 3.00 689.31 2,000.00 52.10 241.35 1,743.99 1,687.79 -193.51 -773.14 6,030,828.22 469,014.92 3.00 754.38 2,100.00 54.92 240.08 1,803.45 1,747.25 -232.84 -843.25 6,030,789.18 468,944.66 3.00 820.98 2,200.00 57.76 238.90 1,858.87 1,802.67 -275.10 -914.95 6,030,747.22 468,872.80 3.00 888.92 2,300.00 60.60 237.79 1,910.10 1,853.90 -320.17 -988.03 6,030,702.45 468,799.53 3.00 958.00 2,400.00 63.46 236.74 1,957.00 1,900.80 -367.93 -1,062.31 6,030,655.00 468,725.07 3.00 1,028.06 2,500.00 66.32 235.74 1,999.44 1,943.24 -418.24 -1,137.58 6,030,605.00 468,649.61 3.00 1,098.88 2,600.00 69.18 234.79 2,037.30 1,981.10 -470.98 -1,213.63 6,030,552.58 468,573.35 3.00 1,170.29 2,602.36 69.25 234.77 2,038.14 1,981.94 -472.25 -1,215.43 6,030,551.31 468,571.54 2.99 1,171.98 End Dir:2602.36'MD,2038.14'TVD 2,700.00 69.25 234.77 2,072.73 2,016.53 -524.92 -1,290.01 6,030,498.95 468,496.76 0.00 1,241.92 2,800.00 69.25 234.77 2,108.16 2,051.96 -578.87 -1,366.39 6,030,445.31 468,420.16 0.00 1,313.56 2,900.00 69.25 234.77 2,143.59 2,087.39 -632.82 -1,442.78 6,030,391.68 468,343.57 0.00 1,385.19 3,000.00 69.25 234.77 2,179.02 2,122.82 -686.77 -1,519.16 6,030,338.05 468,266.98 0.00 1,456.83 3,100.00 69.25 234.77 2,214.45 2,158.25 -740.72 -1,595.54 6,030,284.42 468,190.38 0.00 1,528.46 3,200.00 69.25 234.77 2,249.88 2,193.68 -794.66 -1,671.93 6,030,230.79 468,113.79 0.00 1,600.10 3,288.50 69.25 234.77 2,281.23 2,225.03 -842.41 -1,739.53 6,030,183.32 468,046.00 0.00 1,663.50 Top West Sak 3,300.00 69.25 234.77 2,285.31 2,229.11 -848.61 -1,748.31 6,030,177.16 468,037.19 0.00 1,671.73 3,400.00 69.25 234.77 2,320.74 2,264.54 -902.56 -1,824.69 6,030,123.52 467,960.60 0.00 1,743.37 3/16/2011 3:03:04PM Page 4 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTDM Standard Proposal Report Database: Pioneer Alaska Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-23i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-23i IN14 Design: ODSN-23i 1N14 wp07 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) 2,299.97 3,500.00 69.25 234.77 2,356.17 2,299.97 -956.51 -1,901.08 6,030,069.89 467,884.01 0.00 1,815.00 3,600.00 69.25 234.77 2,391.59 2,335.39 -1,010.46 -1,977.46 6,030,016.26 467,807.41 0.00 1,886.64 3,700.00 69.25 234.77 2,427.02 2,370.82 -1,064.40 -2,053.84 6,029,962.63 467,730.82 0.00 1,958.28 3,800.00 69.25 234.77 2,462.45 2,406.25 -1,118.35 -2,130.22 6,029,909.00 467,654.22 0.00 2,029.91 3,900.00 69.25 234.77 2,497.88 2,441.68 -1,172.30 -2,206.61 6,029,855.37 467,577.63 0.00 2,101.55 4,000.00 69.25 234.77 2,533.31 2,477.11 -1,226.25 -2,282.99 6,029,801.73 467,501.03 0.00 2,173.18 4,100.00 69.25 234.77 2,568.74 2,512.54 -1,280.20 -2,359.37 6,029,748.10 467,424.44 0.00 2,244.82 4,200.00 69.25 234.77 2,604.17 2,547.97 -1,334.14 -2,435.76 6,029,694.47 467,347.85 0.00 2,316.45 4,300.00 69.25 234.77 2,639.60 2,583.40 -1,388.09 -2,512.14 6,029,640.84 467,271.25 0.00 2,388.09 , 4,400.00 69.25 234.77 2,675.03 2,618.83 -1,442.04 -2,588.52 6,029,587.21 467,194.66 0.00 2,459.72 4,500.00 69.25 234.77 2,710.46 2,654.26 -1,495.99 -2,664.91 6,029,533.58 467,118.06 0.00 2,531.36 4,600.00 69.25 234.77 2,745.89 2,689.69 -1,549.94 -2,741.29 6,029,479.94 467,041.47 0.00 2,603.00 4,700.00 69.25 234.77 2,781.31 2,725.11 -1,603.88 -2,817.67 6,029,426.31 466,964.88 0.00 2,674.63 4,800.00 69.25 234.77 2,816.74 2,760.54 -1,657.83 -2,894.06 6,029,372.68 466,888.28 0.00 2,746.27 4,900.00 69.25 234.77 2,852.17 2,795.97 -1,711.78 -2,970.44 6,029,319.05 466,811.69 0.00 2,817.90 5,000.00 69.25 234.77 2,887.60 2,831.40 -1,765.73 -3,046.82 6,029,265.42 466,735.09 0.00 2,889.54 5,100.00 69.25 234.77 2,923.03 2,866.83 -1,819.68 -3,123.21 6,029,211.78 466,658.50 0.00 2,961.17 5,145.90 69.25 234.77 2,939.29 2,883.09 -1,844.44 -3,158.27 6,029,187.17 466,623.34 0.00 2,994.05 Cret Tuffs 5,200.00 69.25 234.77 2,958.46 2,902.26 -1,873.62 -3,199.59 6,029,158.15 466,581.91 0.00 3,032.81 5,300.00 69.25 234.77 2,993.89 2,937.69 -1,927.57 -3,275.97 6,029,104.52 466,505.31 0.00 3,104.44 5,400.00 69.25 234.77 3,029.32 2,973.12 -1,981.52 -3,352.36 6,029,050.89 466,428.72 0.00 3,176.08 5,500.00 69.25 234.77 3,064.75 3,008.55 -2,035.47 -3,428.74 6,028,997.26 466,352.12 0.00 3,247.71 5,600.00 69.25 234.77 3,100.18 3,043.98 -2,089.42 -3,505.12 6,028,943.63 466,275.53 0.00 3,319.35 5,700.00 69.25 234.77 3,135.61 3,079.41 -2,143.36 -3,581.51 6,028,889.99 466,198.94 0.00 3,390.99 5,800.00 69.25 234.77 3,171.03 3,114.83 -2,197.31 -3,657.89 6,028,836.36 466,122.34 0.00 3,462.62 5,892.80 69.25 234.77 3,203.91 3,147.71 -2,247.38 -3,728.77 6,028,786.59 466,051.26 0.00 3,529.10 Hue 2 Shale 5,900.00 69.25 234.77 3,206.46 3,150.26 -2,251.26 -3,734.27 6,028,782.73 466,045.75 0.00 3,534.26 5,920.00 69.25 234.77 3,213.55 3,157.35 -2,262.05 -3,749.55 6,028,772.00 466,030.43 0.00 3,548.58 11 3/4" 6,000.00 69.25 234.77 3,241.89 3,185.69 -2,305.21 -3,810.65 6,028,729.10 465,969.15 0.00 3,605.89 6,100.00 69.25 234.77 3,277.32 3,221.12 -2,359.16 -3,887.04 6,028,675.47 465,892.56 0.00 3,677.53 6,200.00 69.25 234.77 3,312.75 3,256.55 -2,413.10 -3,963.42 6,028,621.84 465,815.97 0.00 3,749.16 6,300.00 69.25 234.77 3,348.18 3,291.98 -2,467.05 -4,039.80 6,028,568.20 465,739.37 0.00 3,820.80 6,400.00 69.25 234.77 3,383.61 3,327.41 -2,521.00 -4,116.19 6,028,514.57 465,662.78 0.00 3,892.43 6,500.00 69.25 234.77 3,419.04 3,362.84 -2,574.95 -4,192.57 6,028,460.94 465,586.18 0.00 3,964.07 6,600.00 69.25 234.77 3,454.47 3,398.27 -2,628.90 -4,268.95 6,028,407.31 465,509.59 0.00 4,035.71 6,700.00 69.25 234.77 3,489.90 3,433.70 -2,682.84 -4,345.34 6,028,353.68 465,433.00 0.00 4,107.34 6,800.00 69.25 234.77 3,525.33 3,469.13 -2,736.79 -4,421.72 6,028,300.05 465,356.40 0.00 4,178.98 6,900.00 69.25 234.77 3,560.75 3,504.55 -2,790.74 -4,498.10 6,028,246.41 465,279.81 0.00 4,250.61 7,000.00 69.25 234.77 3,596.18 3,539.98 -2,844.69 -4,574.49 6,028,192.78 465,203.21 0.00 4,322.25 7,100.00 69.25 234.77 3,631.61 3,575.41 -2,898.64 -4,650.87 6,028,139.15 465,126.62 0.00 4,393.88 7,200.00 69.25 234.77 3,667.04 3,610.84 -2,952.58 -4,727.25 6,028,085.52 465,050.03 0.00 4,465.52 7,300.00 69.25 234.77 3,702.47 3,646.27 -3,006.53 -4,803.64 6,028,031.89 464,973.43 0.00 4,537.15 3/16/2011 3:03.04PM Page 5 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: Pioneer Alaska Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.20ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-23i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-23i IN14 Design: ODSN-23i IN14 wp07 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +EJ-W Northing Easting DLS Vert Section (ft) (?) (?) (ft) ft (ft) (ft) (ft) (ft) 3,681.70 7,400.00 69.25 234.77 3,737.90 3,681.70 -3,060.48 -4,880.02 6,027,978.25 464,896.84 0.00 4,608.79 7,500.00 69.25 234.77 3,773.33 3,717.13 -3,114.43 -4,956.40 6,027,924.62 464,820.24 0.00 4,680.43 7,600.00 69.25 234.77 3,808.76 3,752.56 -3,168.38 -5,032.79 6,027,870.99 464,743.65 0.00 4,752.06 7,700.00 69.25 234.77 3,844.19 3,787.99 -3,222.33 -5,109.17 6,027,817.36 464,667.05 0.00 4,823.70 7,800.00 69.25 234.77 3,879.62 3,823.42 -3,276.27 -5,185.55 6,027,763.73 464,590.46 0.00 4,895.33 7,900.00 69.25 234.77 3,915.05 3,858.85 -3,330.22 -5,261.93 6,027,710.10 464,513.87 0.00 4,966.97 8,000.00 69.25 234.77 3,950.47 3,894.27 -3,384.17 -5,338.32 6,027,656.46 464,437.27 0.00 5,038.60 8,100.00 69.25 234.77 3,985.90 3,929.70 -3,438.12 -5,414.70 6,027,602.83 464,360.68 0.00 5,110.24 8,200.00 69.25 234.77 4,021.33 3,965.13 -3,492.07 -5,491.08 6,027,549.20 464,284.08 0.00 5,181.87 8,300.00 69.25 234.77 4,056.76 4,000.56 -3,546.01 -5,567.47 6,027,495.57 464,207.49 0.00 5,253.51 8,400.00 69.25 234.77 4,092.19 4,035.99 -3,599.96 -5,643.85 6,027,441.94 464,130.90 0.00 5,325.14 8,500.00 69.25 234.77 4,127.62 4,071.42 -3,653.91 -5,720.23 6,027,388.31 464,054.30 0.00 5,396.78 8,600.00 69.25 234.77 4,163.05 4,106.85 -3,707.86 -5,796.62 6,027,334.67 463,977.71 0.00 5,468.42 8,700.00 69.25 234.77 4,198.48 4,142.28 -3,761.81 -5,873.00 6,027,281.04 463,901.11 0.00 5,540.05 8,759.30 69.25 234.77 4,219.49 4,163.29 -3,793.80 -5,918.30 6,027,249.24 463,855.69 0.00 5,582.53 Brookian 2B 8,800.00 69.25 234.77 4,233.91 4,177.71 -3,815.75 -5,949.38 6,027,227.41 463,824.52 0.00 5,611.69 8,900.00 69.25 234.77 4,269.34 4,213.14 -3,869.70 -6,025.77 6,027,173.78 463,747.93 0.00 5,683.32 9,000.00 69.25 234.77 4,304.77 4,248.57 -3,923.65 -6,102.15 6,027,120.15 463,671.33 0.00 5,754.96 9,100.00 69.25 234.77 4,340.20 4,284.00 -3,977.60 -6,178.53 6,027,066.52 463,594.74 0.00 5,826.59 9,200.00 69.25 234.77 4,375.62 4,319.42 -4,031.55 -6,254.92 6,027,012.88 463,518.14 0.00 5,898.23 9,300.00 69.25 234.77 4,411.05 4,354.85 -4,085.49 -6,331.30 6,026,959.25 463,441.55 0.00 5,969.86 9,400.00 69.25 234.77 4,446.48 4,390.28 -4,139.44 -6,407.68 6,026,905.62 463,364.96 0.00 6,041.50 9,500.00 69.25 234.77 4,481.91 4,425.71 -4,193.39 -6,484.07 6,026,851.99 463,288.36 0.00 6,113.14 9,600.00 69.25 234.77 4,517.34 4,461.14 -4,247.34 -6,560.45 6,026,798.36 463,211.77 0.00 6,184.77 9,700.00 69.25 234.77 4,552.77 4,496.57 -4,301.29 -6,636.83 6,026,744.72 463,135.17 0.00 6,256.41 9,800.00 69.25 234.77 4,588.20 4,532.00 -4,355.23 -6,713.21 6,026,691.09 463,058.58 0.00 6,328.04 9,900.00 69.25 234.77 4,623.63 4,567.43 -4,409.18 -6,789.60 6,026,637.46 462,981.99 0.00 6,399.68 10,000.00 69.25 234.77 4,659.06 4,602.86 -4,463.13 -6,865.98 6,026,583.83 462,905.39 0.00 6,471.31 10,100.00 69.25 234.77 4,694.49 4,638.29 -4,517.08 -6,942.36 6,026,530.20 462,828.80 0.00 6,542.95 10,200.00 69.25 234.77 4,729.92 4,673.72 -4,571.03 -7,018.75 6,026,476.57 462,752.20 0.00 6,614.58 10,300.00 69.25 234.77 4,765.34 4,709.14 -4,624.97 -7,095.13 6,026,422.93 462,675.61 0.00 6,686.22 10,302.36 69.25 234.77 4,766.18 4,709.98 -4,626.25 -7,096.93 6,026,421.67 462,673.80 0.00 6,687.91 Start Dir 2.76°/100': 10302.36'MD,4766.18'TVD 10,400.00 69.05 237.70 4,800.93 4,744.73 -4,676.96 -7,172.78 6,026,371.27 462,597.76 2.81 6,759.28 10,500.00 68.85 240.70 4,836.84 4,780.64 -4,724.75 -7,252.93 6,026,323.81 462,517.42 2.81 6,835.18 10,600.00 68.65 243.70 4,873.08 4,816.88 -4,768.22 -7,335.37 6,026,280.68 462,434.82 2.80 6,913.72 10,700.00 68.45 246.70 4,909.64 4,853.44 -4,807.26 -7,419.85 6,026,241.99 462,350.19 2.80 6,994.66 10,778.50 68.29 249.05 4,938.57 4,882.37 -4,834.75 -7,487.44 6,026,214.78 462,282.49 2.80 7,059.74 Top Torok Sand 10,800.00 68.25 249.70 4,946.52 4,890.32 -4,841.78 -7,506.14 6,026,207.82 462,263.77 2.80 7,077.78 10,900.00 68.05 252.70 4,983.73 4,927.53 -4,871.70 -7,593.99 6,026,178.27 462,175.80 2.79 7,162.85 11,000.00 67.85 255.70 5,021.27 4,965.07 -4,896.94 -7,683.17 6,026,153.39 462,086.53 2.79 7,249.62 11,100.00 67.65 258.70 5,059.12 5,002.92 -4,917.45 -7,773.41 6,026,133.25 461,996.21 2.78 7,337.85 11,200.00 67.45 261.70 5,097.30 5,041.10 -4,933.18 -7,864.48 6,026,117.89 461,905.10 2.78 7,427.29 3/16/2011 3:03:04PM Page 6 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTO..d Standard Proposal Report Database: Pioneer Alaska Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-23i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-23i IN14 Design: ODSN-23i IN14 wp07 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) 5,077.22 11,293.80 67.27 264.51 5,133.42 5,077.22 -4,943.58 -7,950.41 6,026,107.84 461,819.13 2.78 7,512.06 Base Torok Sand 11,300.00 67.25 264.70 5,135.81 5,079.61 -4,944.12 -7,956.11 6,026,107.33 461,813.43 2.78 7,517.69 11,400.00 67.05 267.70 5,174.63 5,118.43 -4,950.23 -8,048.05 6,026,101.59 461,721.47 2.77 7,608.81 11,500.00 66.85 270.70 5,213.78 5,157.58 -4,951.52 -8,140.05 6,026,100.67 461,629.48 2.77 7,700.38 11,600.00 66.65 273.70 5,253.24 5,197.04 -4,948.00 -8,231.85 6,026,104.56 461,537.70 2.76 7,792.16 11,700.00 66.45 276.70 5,293.03 5,236.83 -4,939.69 -8,323.21 6,026,113.24 461,446.39 2.76 7,883.89 11,800.00 66.25 279.70 5,333.14 5,276.94 -4,926.63 -8,413.87 6,026,126.67 461,355.79 2.76 7,975.32 11,865.00 66.12 281.65 5,359.38 5,303.18 -4,915.62 -8,472.30 6,026,137.91 461,297.41 2.75 8,034.47 Torok 1 Shale 11,888.00 66.08 282.34 5,368.70 5,312.50 -4,911.26 -8,492.87 6,026,142.36 461,276.86 2.75 8,055.33 9 5/8" 11,900.00 66.05 282.70 5,373.57 5,317.37 -4,908.88 -8,503.58 6,026,144.79 461,266.16 2.75 8,066.20 12,000.00 65.85 285.70 5,414.31 5,358.11 -4,886.48 -8,592.10 6,026,167.54 461,177.74 2.75 8,156.28 12,100.00 65.65 288.70 5,455.38 5,399.18 -4,859.53 -8,679.20 6,026,194.84 461,090.76 2.74 8,245.31 12,200.00 65.45 291.70 5,496.76 5,440.56 -4,828.10 -8,764.63 6,026,226.61 461,005.47 2.74 8,333.06 12,300.00 65.25 294.70 5,538.46 5,482.26 -4,792.31 -8,848.16 6,026,262.74 460,922.09 2.73 8,419.28 12,400.00 65.05 297.70 5,580.47 5,524.27 -4,752.26 -8,929.57 6,026,303.12 460,840.85 2.73 8,503.74 12,500.00 64.85 300.70 5,622.81 5,566.61 -4,708.07 -9,008.65 6,026,347.63 460,761.96 2.73 8,586.22 12,600.00 64.65 303.70 5,665.46 5,609.26 -4,659.88 -9,085.19 6,026,396.12 460,685.63 2.72 8,666.49 12,700.00 64.45 306.70 5,708.42 5,652.22 -4,607.84 -9,158.97 6,026,448.45 460,612.07 2.72 8,744.34 12,757.40 64.33 308.42 5,733.23 5,677.03 -4,576.29 -9,200.00 6,026,480.17 460,571.17 2.71 8,787.85 Top HRZ 12,800.00 64.25 309.70 5,751.71 5,695.51 -4,552.11 -9,229.81 6,026,504.47 460,541.46 2.71 8,819.57 12,802.36 64.25 309.77 5,752.73 5,696.53 -4,550.74 -9,231.44 6,026,505.84 460,539.83 2.71 8,821.31 End Dir:12802.36'MD,5752.73'TVD 12,900.00 64.25 309.77 5,795.15 5,738.95 -4,494.49 -9,299.04 6,026,562.36 460,472.47 0.00 8,893.35 13,000.00 64.25 309.77 5,838.59 5,782.39 -4,436.87 -9,368.27 6,026,620.25 460,403.48 0.00 8,967.13 13,048.00 64.25 309.77 5,859.44 5,803.24 -4,409.22 -9,401.51 6,026,648.04 460,370.36 0.00 9,002.55 Base HRZ 13,100.00 64.25 309.77 5,882.04 5,825.84 -4,379.26 -9,437.51 6,026,678.14 460,334.49 0.00 9,040.91 • 13,200.00 64.25 309.77 5,925.48 5,869.28 -4,321.64 -9,506.74 6,026,736.03 460,265.50 0.00 9,114.69 13,300.00 64.25 309.77 5,968.92 5,912.72 -4,264.03 -9,575.97 6,026,793.92 460,196.51 0.00 9,188.47 13,302.36 64.25 309.77 5,969.95 5,913.75 -4,262.67 -9,577.61 6,026,795.29 460,194.88 0.00 9,190.22 Start Dir 2.99°/100':13302.36'MD,5969.95'TVD 13,343.00 65.40 310.20 5,987.24 5,931.04 -4,239.04 -9,605.78 6,026,819.03 460,166.80 2.99 9,220.26 Kalubik Marker 13,400.00 67.01 310.80 6,010.24 5,954.04 -4,205.16 -9,645.44 6,026,853.07 460,127.29 2.99 9,262.59 13,500.00 69.84 311.82 6,047.00 5,990.80 -4,143.77 -9,715.27 6,026,914.73 460,057.71 2.99 9,337.29 13,530.90 70.72 312.13 6,057.43 6,001.23 -4,124.31 -9,736.90 6,026,934.28 460,036.17 2.99 9,360.46 Top Kuparuk C 13,536.30 70.87 312.18 6,059.20 6,003.00 -4,120.89 -9,740.68 6,026,937.71 460,032.40 2.99 9,364.51 Base Kuparuk(LCU) 13,600.00 72.68 312.81 6,079.12 6,022.92 -4,080.02 -9,785.29 6,026,978.76 459,987.96 2.99 9,412.36 3/16/2011 3:03:04PM Page 7 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: Pioneer Alaska Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-23i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-23i IN14 Design: ODSN-23i IN14 wp07 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) 6,047.22 13,687.80 75.18 313.64 6,103.42 6,047.22 -4,022.24 -9,846.76 6,027,036.79 459,926.73 2.99 9,478.42 BCU 13,700.00 75.53 313.76 6,106.51 6,050.31 -4,014.08 -9,855.29 6,027,044.97 459,918.23 2.99 9,487.60 13,800.00 78.37 314.69 6,129.09 6,072.89 -3,946.15 -9,925.09 6,027,113.19 459,848.72 2.99 9,562.80 13,823.45 79.04 314.90 6,133.68 6,077.48 -3,929.94 -9,941.41 6,027,129.46 459,832.47 2.99 9,580.41 End Dir:13823.45'MD,6133.68'TVD 13,824.80 79.04 314.90 6,133.94 6,077.74 -3,929.01 -9,942.35 6,027,130.40 459,831.53 0.00 9,581.43 Top Nuiqsut 13,847.23 79.04 314.90 6,138.20 6,082.00 -3,913.46 -9,957.94 6,027,146.00 459,816.00 0.00 9,598.26 Start Dir 3°/100':13847.23'MD,6138.2'TVD-2311N14 v5 T1 13,880.00 79.98 315.21 6,144.17 6,087.97 -3,890.66 -9,980.71 6,027,168.90 459,793.33 3.00 9,622.84 7., 13,900.00 80.55 315.39 6,147.55 6,091.35 -3,876.65 -9,994.57 6,027,182.96 459,779.52 3.00 9,637.82 14,000.00 83.41 316.31 6,161.50 6,105.30 -3,805.60 -10,063.53 6,027,254.28 459,710.86 3.00 9,712.45 14,096.34 86.16 317.18 6,170.26 6,114.06 -3,735.73 -10,129.27 6,027,324.41 459,645.42 3.00 9,783.76 End Dir:14096.34'MD,6170.26'TVD 14,100.00 86.16 317.18 6,170.50 6,114.30 -3,733.05 -10,131.75 6,027,327.10 459,642.95 0.00 9,786.46 14,200.00 86.16 317.18 6,177.19 6,120.99 -3,659.86 -10,199.56 6,027,400.56 459,575.44 0.00 9,860.12 14,300.00 86.16 317.18 6,183.88 6,127.68 -3,586.67 -10,267.38 6,027,474.01 459,507.93 0.00 9,933.78 14,400.00 86.16 317.18 6,190.57 6,134.37 -3,513.48 -10,335.19 6,027,547.47 459,440.42 0.00 10,007.44 14,500.00 86.16 317.18 6,197.26 6,141.06 -3,440.29 -10,403.00 6,027,620.93 459,372.91 0.00 10,081.10 14,600.00 86.16 317.18 6,203.95 6,147.75 -3,367.10 -10,470.81 6,027,694.38 459,305.41 0.00 10,154.76 14,670.69 86.16 317.18 6,208.68 6,152.48 -3,315.37 -10,518.75 6,027,746.31 459,257.68 0.00 10,206.83 Start Dir 3°/100': 14670.69'MD,6208.68'TVD 14,700.00 86.66 316.46 6,210.51 6,154.31 -3,294.04 -10,538.77 6,027,767.72 459,237.76 3.00 10,228.55 14,800.00 88.37 313.99 6,214.84 6,158.64 -3,223.13 -10,609.13 6,027,838.91 459,167.69 3.00 10,304.56 14,895.39 90.00 311.64 6,216.20 6,160.00 -3,158.31 -10,679.09 6,027,904.00 459,098.00 3.00 10,379.67 2311N14 v5 T2 14,900.00 90.14 311.63 6,216.19 6,159.99 -3,155.25 -10,682.54 6,027,907.08 459,094.57 3.00 10,383.36 14,970.65 92.26 311.60 6,214.72 6,158.52 -3,108.34 -10,735.34 6,027,954.19 459,041.96 3.00 10,439.88 End Dir:14970.65'MD,6214.72'TVD 15,000.00 92.26 311.60 6,213.56 6,157.36 -3,088.87 -10,757.27 6,027,973.75 459,020.11 0.00 10,463.35 15,100.00 92.26 311.60 6,209.62 6,153.42 -3,022.53 -10,832.00 6,028,040.39 458,945.66 0.00 10,543.33 15,200.00 92.26 311.60 6,205.68 6,149.48 -2,956.19 -10,906.72 6,028,107.02 458,871.22 0.00 10,623.31 15,300.00 92.26 311.60 6,201.74 6,145.54 -2,889.86 -10,981.45 6,028,173.66 458,796.77 0.00 10,703.29 15,400.00 92.26 311.60 6,197.80 6,141.60 -2,823.52 -11,056.17 6,028,240.29 458,722.32 0.00 10,783.27 15,500.00 92.26 311.60 6,193.87 6,137.67 -2,757.18 -11,130.89 6,028,306.93 458,647.88 0.00 10,863.25 15,600.00 92.26 311.60 6,189.93 6,133.73 -2,690.84 -11,205.62 6,028,373.56 458,573.43 0.00 10,943.23 15,700.00 92.26 311.60 6,185.99 6,129.79 -2,624.50 -11,280.34 6,028,440.19 458,498.98 0.00 11,023.21 15,800.00 92.26 311.60 6,182.05 6,125.85 -2,558.16 -11,355.07 6,028,506.83 458,424.54 0.00 11,103.18 15,900.00 92.26 311.60 6,178.11 6,121.91 -2,491.83 -11,429.79 6,028,573.46 458,350.09 0.00 11,183.16 16,000.00 92.26 311.60 6,174.17 6,117.97 -2,425.49 -11,504.52 6,028,640.10 458,275.64 0.00 11,263.14 16,100.00 92.26 311.60 6,170.23 6,114.03 -2,359.15 -11,579.24 6,028,706.73 458,201.20 0.00 11,343.12 16,200.00 92.26 311.60 6,166.29 6,110.09 -2,292.81 -11,653.96 6,028,773.37 458,126.75 0.00 11,423.10 3/16/2011 3.03:04PM Page 8 COMPASS 2003.16 Build 42B Halliburton Company HALLIBURTDN Standard Proposal Report Database: Pioneer Alaska Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.20ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-23i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-23i IN14 Design: ODSN-23i IN14 wp07 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) 6,106.70 16,286.08 92.26 311.60 6,162.90 6,106.70 -2,235.71 -11,718.29 6,028,830.73 458,062.67 0.00 11,491.95 Start Dir 3°/100': 16286.08'MD,6162.9'TVD 16,300.00 91.89 311.80 6,162.40 6,106.20 -2,226.45 -11,728.67 6,028,840.02 458,052.32 3.00 11,503.06 16,372.42 90.00 312.87 6,161.20 6,105.00 -2,177.69 -11,782.20 6,028,889.00 457,999.00 3.00 11,560.46 2311N14 v5 T3 16,400.00 89.17 312.86 6,161.40 6,105.20 -2,158.93 -11,802.41 6,028,907.84 457,978.87 3.00 11,582.16 16,469.65 87.08 312.84 6,163.67 6,107.47 -2,111.59 -11,853.44 6,028,955.38 457,928.03 3.00 11,636.95 End Dir:16469.65'MD,6163.67'TVD 16,500.00 87.08 312.84 6,165.22 6,109.02 -2,090.98 -11,875.66 6,028,976.08 457,905.89 0.00 11,660.81 16,600.00 87.08 312.84 6,170.31 6,114.11 -2,023.06 -11,948.89 6,029,044.29 457,832.95 0.00 11,739.42 16,700.00 87.08 312.84 6,175.40 6,119.20 -1,955.15 -12,022.12 6,029,112.49 457,760.01 0.00 11,818.04 16,800.00 87.08 312.84 6,180.48 6,124.28 -1,887.24 -12,095.34 6,029,180.69 457,687.07 0.00 11,896.66 16,900.00 87.08 312.84 6,185.57 6,129.37 -1,819.33 -12,168.57 6,029,248.89 457,614.13 0.00 11,975.27 17,000.00 87.08 312.84 6,190.66 6,134.46 -1,751.41 -12,241.79 6,029,317.10 457,541.19 0.00 12,053.89 17,100.00 87.08 312.84 6,195.75 6,139.55 -1,683.50 -12,315.02 6,029,385.30 457,468.24 0.00 12,132.51 17,200.00 87.08 312.84 6,200.84 6,144.64 -1,615.59 -12,388.25 6,029,453.50 457,395.30 0.00 12,211.12 17,300.00 87.08 312.84 6,205.93 6,149.73 -1,547.68 -12,461.47 6,029,521.70 457,322.36 0.00 12,289.74 17,400.00 87.08 312.84 6,211.01 6,154.81 -1,479.76 -12,534.70 6,029,589.91 457,249.42 0.00 12,368.36 17,500.00 87.08 312.84 6,216.10 6,159.90 -1,411.85 -12,607.92 6,029,658.11 457,176.48 0.00 12,446.97 17,600.00 87.08 312.84 6,221.19 6,164.99 -1,343.94 -12,681.15 6,029,726.31 457,103.54 0.00 12,525.59 17,700.00 87.08 312.84 6,226.28 6,170.08 -1,276.03 -12,754.37 6,029,794.51 457,030.59 0.00 12,604.20 17,746.74 87.08 312.84 6,228.66 6,172.46 -1,244.28 -12,788.60 6,029,826.39 456,996.50 0.00 12,640.95 Start Dir 3°/100': 17746.74'MD,6228.66'TVD 17,800.00 88.64 313.21 6,230.65 6,174.45 -1,207.97 -12,827.51 6,029,862.86 456,957.75 3.00 12,682.74 17,846.61 90.00 313.53 6,231.20 6,175.00 -1,175.96 -12,861.39 6,029,895.00 456,924.00 3.00 12,719.16 23i1N14v5T4 17,900.00 91.60 313.51 6,230.45 6,174.25 -1,139.21 -12,900.10 6,029,931.91 456,885.44 3.00 12,760.79 17,980.77 94.02 313.47 6,226.49 6,170.29 -1,083.69 -12,958.62 6,029,987.66 456,827.15 3.00 12,823.73 End Dir:17980.77'MD,6226:49'TVD 18,000.00 94.02 313.47 6,225.14 6,168.94 -1,070.50 -12,972.55 6,030,000.91 456,813.28 0.00 12,838.70 18,100.00 94.02 313.47 6,218.12 6,161.92 -1,001.87 -13,044.94 6,030,069.82 456,741.17 0.00 12,916.55 18,200.00 94.02 313.47 6,211.10 6,154.90 -933.25 -13,117.34 6,030,138.73 456,669.06 0.00 12,994.40 , 18,300.00 94.02 313.47 6,204.09 6,147.89 -864.62 -13,189.74 6,030,207.64 456,596.95 0.00 13,072.25 18,400.00 94.02 313.47 6,197.07 6,140.87 -796.00 -13,262.13 6,030,276.56 456,524.84 0.00 13,150.10 18,500.00 94.02 313.47 6,190.05 6,133.85 -727.37 -13,334.53 6,030,345.47 456,452.73 0.00 13,227.95 18,600.00 94.02 313.47 6,183.03 6,126.83 -658.75 -13,406.93 6,030,414.38 456,380.62 0.00 13,305.80 18,700.00 94.02 313.47 6,176.02 6,119.82 -590.12 -13,479.32 6,030,483.29 456,308.51 0.00 13,383.65 18,800.00 94.02 313.47 6,169.00 6,112.80 -521.49 -13,551.72 6,030,552.20 456,236.40 0.00 13,461.50 18,900.00 94.02 313.47 6,161.98 6,105.78 -452.87 -13,624.12 6,030,621.12 456,164.29 0.00 13,539.35 19,000.00 94.02 313.47 6,154.96 6,098.76 -384.24 -13,696.52 6,030,690.03 456,092.18 0.00 13,617.20 19,100.00 94.02 313.47 6,147.94 6,091.74 -315.62 -13,768.91 6,030,758.94 456,020.07 0.00 13,695.05 19,182.90 94.02 313.47 6,142.13 6,085.93 -258.73 -13,828.93 6,030,816.07 455,960.29 0.00 13,759.59 Start Dir 3°/100': 19182.9'MD,6142.13'TVD 19,200.00 93.53 313.62 6,141.00 6,084.80 -246.97 -13,841.30 6,030,827.87 455,947.97 3.00 13,772.89 19,300.00 90.67 314.50 6,137.33 6,081.13 -177.49 -13,913.10 6,030,897.64 455,876.45 3.00 13,850.22 3/16/2011 3:03:04PM Page 9 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTDi d Standard Proposal Report Database: Pioneer Alaska Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.20ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-23i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-23i IN14 Design: ODSN-23i IN14 wp07 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) 6,081.00 19,323.21 90.00 314.70 6,137.20 6,081.00 -161.20 -13,929.63 6,030,914.00 455,860.00 3.00 13,868.04 23iIN14v5T5 19,368.15 88.65 314.70 6,137.73 6,081.53 -129.58 -13,961.57 6,030,945.74 455,828.19 3.00 13,902.50 End Dir:19368.15'MD,6137.73'TVD 19,400.00 88.65 314.70 6,138.48 6,082.28 -107.19 -13,984.20 6,030,968.23 455,805.65 0.00 13,926.91 19,500.00 88.65 314.70 6,140.83 6,084.63 -36.86 -14,055.26 6,031,038.83 455,734.89 0.00 14,003.57 19,600.00 88.65 314.70 6,143.18 6,086.98 33.46 -14,126.31 6,031,109.43 455,664.12 0.00 14,080.23 19,700.00 88.65 314.70 6,145.54 6,089.34 103.78 -14,197.37 6,031,180.04 455,593.36 0.00 14,156.88 19,800.00 88.65 314.70 6,147.89 6,091.69 174.11 -14,268.43 6,031,250.64 455,522.60 0.00 14,233.54 19,900.00 88.65 314.70 6,150.24 6,094.04 244.43 -14,339.49 6,031,321.25 455,451.83 0.00 14,310.19 20,000.00 88.65 314.70 6,152.60 6,096.40 314.75 -14,410.54 6,031,391.85 455,381.07 0.00 14,386.85 20,100.00 88.65 314.70 6,154.95 6,098.75 385.08 -14,481.60 6,031,462.46 455,310.31 0.00 14,463.50 20,200.00 88.65 314.70 6,157.30 6,101.10 455.40 -14,552.66 6,031,533.06 455,239.54 0.00 14,540.16 20,300.00 88.65 314.70 6,159.66 6,103.46 525.72 -14,623.71 6,031,603.66 455,168.78 0.00 14,616.81 20,400.00 88.65 314.70 6,162.01 6,105.81 596.05 -14,694.77 6,031,674.27 455,098.02 0.00 14,693.47 20,500.00 88.65 314.70 6,164.36 6,108.16 666.37 -14,765.83 6,031,744.87 455,027.25 0.00 14,770.13 20,578.07 88.65 314.70 6,166.20 6,110.00 721.27 -14,821.30 6,031,799.99 454,972.01 0.00 14,829.97 Total Depth:20578.08'MD,6166.2'TVD 1 20,578.08 88.65 314.70 6,166.20 • 6,110.00 ' 721.28 -14,821.31 . 6,031,800.00 454,972.00 0.01 14,829.98 23i 1N14 v5 T6 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/-W Northing Easting -Shape (?) (?) (ft) (ft) (ft) (ft) (ft) 23i IN14 v5 T6 0.00 359.95 6,166.20 721.28 -14,821.31 6,031,800.00 454,972.00 -plan hits target -Point 23i IN14 v5 T5 0.00 359.96 6,137.20 -161.20 -13,929.63 6,030,914.00 455,860.00 -plan hits target -Point 23i IN14 v5 T3 0.00 359.97 6,161.20 -2,177.69 -11,782.20 6,028,889.00 457,999.00 -plan hits target -Point 23i IN14 v5 T2 0.00 359.98 6,216.20 -3,158.31 -10,679.09 6,027,904.00 459,098.00 -plan hits target -Point 23i IN14 v5 curve 1 0.00 0.02 4,668.70 -4,785.45 -7,028.12 6,026,262.20 462,741.96 -plan misses by 198.95ft at 10301.15ft MD(4765.75 TVD,-4625.59 N,-7096.01 E) -Point 23i IN14 v5 T4 0.00 359.96 6,231.20 -1,175.96 -12,861.39 6,029,895.00 456,924.00 -plan hits target -Point 23i IN14 v5 T1 0.00 359.99 6,138.20 -3,913.46 -9,957.94 6,027,146.00 459,816.00 -plan hits target -Point 3/16/2011 3:03:04PM Page 10 COMPASS 2003.16 Build 428 Halliburton Company HALLIBURTON Standard Proposal Report Database: Pioneer Alaska Local Co-ordinate Reference: Well ODSN-23i-Slot ODS-23 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.20ft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-23i Survey Calculation Method: Minimum Curvature Wellbore: ODSN-23i IN14 Design: ODSN-23i IN14 wp07 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 5,920.00 3,213.55 11 3/4" 11.750 14.500 11,888.00 5,368.70 9 5/8" 9.625 11.750 13,880.00 6,144.17 7" 7.000 8.500 20,578.08 6,166.20 4 1/2" 4.500 6.125 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (?) (?) 13,530.90 6,057.43 Top Kuparuk C 10,778.50 4,938.57 Top Torok Sand 13,536.30 6,059.20 Base Kuparuk(LCU) 3,288.50 2,281.23 Top West Sak 13,048.00 5,859.44 Base HRZ . 1,643.00 1,501.33 Base Permafrost 13,687.80 6,103.42 BCU 8,759.30 4,219.49 Brookian 2B 11,865.00 5,359.38 Torok 1 Shale 11,293.80 5,133.42 Base Torok Sand 12,757.40 5,733.23 Top HRZ 13,343.00 5,987.24 Kalubik Marker 5,145.90 2,939.29 Cret Tuffs 5,892.80 3,203.91 Hue 2 Shale 13,824.80 6,133.94 Top Nuiqsut Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 164.00 164.00 0.00 0.00 Start Dir 3.5°/100': 164'MD, 164'TVD:279.77°RT TF 735.43 723.90 16.75 -97.30 Start Dir 3°/100':735.43'MD,723.9'TVD 2,602.36 2,038.14 -472.25 -1,215.43 End Dir:2602.36'MD,2038.14'TVD 10,302.36 4,766.18 -4,626.25 -7,096.93 Start Dir 2.76°/100': 10302.36'MD,4766.18'TVD 12,802.36 5,752.73 -4,550.74 -9,231.44 End Dir: 12802.36'MD,5752.73'TVD 13,302.36 5,969.95 -4,262.67 -9,577.61 Start Dir 2.99°/100': 13302.36'MD,5969.95'TVD 13,823.45 6,133.68 -3,929.94 -9,941.41 End Dir: 13823.45'MD,6133.68'TVD 13,847.23 6,138.20 -3,913.46 -9,957.95 Start Dir 3°/100': 13847.23'MD,6138.2'TVD 14,096.34 6,170.26 -3,735.73 -10,129.27 End Dir: 14096.34'MD,6170.26'TVD 14,670.69 6,208.68 -3,315.37 -10,518.75 Start Dir 3°/100': 14670.69'MD,6208.68'TVD 14,970.65 6,214.72 -3,108.34 -10,735.34 End Dir: 14970.65'MD,6214.72'TVD 16,286.08 6,162.90 -2,235.71 -11,718.29 Start Dir 3°/100': 16286.08'MD,6162.9'TVD 16,469.65 6,163.67 -2,111.59 -11,853.44 End Dir: 16469.65'MD,6163.67'TVD 17,746.74 6,228.66 -1,244.28 -12,788.60 Start Dir 3°/100': 17746.74'MD,6228.66'TVD 17,980.77 6,226.49 -1,083.69 -12,958.62 End Dir: 17980.77'MD,6226.49'TVD 19,182.90 6,142.13 -258.73 -13,828.93 Start Dir 3°/100': 19182.9'MD,6142.13'TVD 19,368.15 6,137.73 -129.58 -13,961.57 End Dir: 19368.15'MD,6137.73'TVD 20,578.07 6,166.20 721.27 -14,821.30 Total Depth:20578.08'MD,6166.2'TVD 3/16/2011 3:03:04PM Page 11 COMPASS 2003.16 Build 42B Z nili 0 lm 03 M o J J L Q m = a L w M W ?_ N o Q O O . a O R i U ■i a 2 O ' _ c> • M M U N C Z v Q O O y t ® '6 0 W ca 0 i 0> Q °� X n� t r o ) M O ? 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C! ° " z 0 �Y W 0 0 Z F- o < 0 a F! 0 Z 0 Y! 0 CO U g3 S, o o AA -, —I 0 .91 o ° `94 t! o o R6 8 o CIS! 0 63c 0 0 4- S! ° a Oc. o -re o M n clc o u U 7o o 7a c W Q cc. g- E',a o x m°tl Cd Ntl ill C °O tlJ Zcia I i �U — l x 3 I j: cc s 1 I i •district Baundry i I C--' E SE Corner of -a' i OOOGURUK SITE Protracted Section 1 11 m1 itlir I . £ ii Coordinates j II _ N 6028111.04 I1� � E 470989.01 A 4 I, o Pl-zs 1\ u, Ref. AK BLM .5 E. i �• `lam Harrison; Bay Tract; "A" r 21 1 •M: \ '''>..,0',.0 s I n i P111 �`''s 9" _A (12 0 id �` Pll- 3 �s SS?, . f,: Ir `\ •?- Off ore Iceroad=3.99 lJiles 1 '. Neer Shore Iceroad=3.8.: Miles '•PI-13 . Pl 20 to Do uruk Site •` PI 7 {o PI • 4 I 1l��. % \ I. -'PI-14 Q` I • PI-23` / PI Pl-1Z •s - P1-17 Tundra iceroc m ' DS 3N B.O.P. b . , �_ x Roads to Lulu li !.3•>l-a 0: i Pi- s PI-19 �� ' ✓fj lamb {./JS1, I Ti . � �/ ' e :. TiY / S, Basis of Location BUC ( � , : -s - DS-3H West Monument 7,, t Coordinates 1 / •• ;Pi ,,- N 6001016.61 a .* I _ A . E 498081.23 STAKED PI INFORMATION ONLY p b �' Ref. Lownsbury Sc Assoc. L 4 W W l}\\ i D \ � < Drawing No. i NSK 6.01—d672 +_`��,`j .. .. OF AL A4111 / 1 e:-/:.:.* .T' ,, i h i t 'fit' 0 „woo/11r. t. I `•»«• ••• t .. t 1 c, • ilip G.Davis >°e% i::-...,.. i.,-.:,t. i,-- • sr ti• No.4110.5 •:�J``/ r } 4= -, • J r Ik c-op--..•...•.••'N,o i L ... .`. 9OFESSIONPk� air 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 East DATE: 7-12-07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: Basis of Location 05204 2 of 4 1 1 Alaska StatePlane - _.---- -6ectidn Line O sf> et_ _.-_ Well No, - -.,, - Latitude (N) Longitude (W) - FSL -Far- Pad EIEY 6,031,151.32 469,920,45 70 29 46 24160 150 T4-45,464683035 1077 13,60- 2 3,502 6,031,146,35 469,915,52 70 29 46,19252 150 14 45,00922 3030 1082 13,50 3 6,031,141,39 469,910,59- 70 29 46,14354 150 14 45,75375 3025 1087 13.50 4 6,031,13-6.46 469,905,67 70 29 46.09465 150 14 45,89799 3020 1092-_13.50--- 5 6,031,131,45409,900,74 70 29 46.04538 1-50 -4 146,04252 3015 -1097 13.50 5 6,031,1.26.51 469,895.80 70 ,99660 150-14 46,18735 3010 1102 13,50 _29 45 - 7 6,031,113,73 - •• o 0 702945, 7Q39 150 14 46,55879 2997 1115 11,5-Cf-- 6,031,W8/3 3,506,031,108/3 469,878.21 70 29 4582102 150 14 46,703 2092 1120 13.50 9 6,031 TO-3-15 -469,873-,26 70 29 45.7718.4. 150 14 46.84814 2987 1125 13.50 10 6,031,098,79 469,868,3645,72285 - 70 29 45;72286 150 i4 46_99179 --- ------ 2982 1130 `13,50 11 6,031,093,84 - •• :• • 70 29 45,67398 150 14 47,13750 2977 1135 13.50 12 6,031,088,87 469,858.477029 45,62490 150-14-0,2817-4- 2972 1140 13.50 13 6,031,076,06 4.66,-845,31- 70-29-45:491340 150 14 47.65288 2960 1152 13,50 14 6,031,071,09 469,840.87 70 29 4544932 150-14-47,79770 2955 1157 -13,50- ---15 6,031, 469,835,96066 15 70 29 45.40053 150 14 47.94165 2950 1162 13.50 16 6,031,061,18469,831,N 70 29 45.35145- 150 14 48,08588 2945 1167 13,50 17 6,031,056.25 469,826.11 70 29 45,30277 150 14 48.23042 29..40 1172 13,50 _18 6,031,051.27 469,821,18 70 29 45,25359 150 14 48.37495 2935 1177 13,50 19 6,031,038,52 469,808,-50 70 29 45.12768 150 14 48,74666 2922 1189 13,50 20 6-,03f,033,50 409,803:56- 70-270-45.0781 150 14 48,8808-f 2917 1194 -13,50 21 6,031,028.53 469,798.62 70 29 45,02903 150 14 49,03632 2912 1199 13,50 22 6,031,023,58 469,793,67 70 29 44.98014 150 14 49,18144 2907 1204 13.50 > 236,_031,018,57 469,788,76 70 29 44,93067 150 14 49,32537 2902 1209 13.50 469,783,64 70-29 44,88159 -150-1-4 49,46960 2897 1214 13,50 OF s s r; S. Philip G.Davis • • IA•• No.4110.5 .�.QJ*ae a ;�oro '11 07. Pp f hoFfSSICRA=Pl4 Htii'f � `x s' - Nstes 1, 1=levetiens Or-o bosed on BP Mean Sec Level, 2. Coordinates ore based on Alosko Mote Plane Nod 27, zone 4, 3, Alt conductors ore within Protrocted Section 11. Pioneer Neturoi ResgueeS JOB NAME: 9ooguruk Drill Site Conductors DRAWN BY: 8L CHECKED BY: Mz LOCATION; Protracted Section 11 SCALE; N/A Township 13 North _ Rouge 7 East DATE: 7-12=07 Umiat Mer-idion _. NANUQ JOB NO, SHEET DESCRIPTION: As-built Coordinates 05204 3 of 4 Alaska State Plane Section Line Offset Well No. Y X Latitude (N) Longitude (W) FSL FEL Pad Elev. 25 6,031,128.32 469,943.64 _ 70 29 46.01630 150 14 44/7930 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 ,9'�'or AL SURVEYOR'S CERTIFICATE • I HEREBY CERTIFY THAT I AM sar• D ` ••••9. V PROPERLY REGISTERED AND 47 t-, J t♦` LICENSED TO PRACTICE LAND "' �i "° � SURVEYING IN THE STATE OF :«�,3,, ��`�,} �. `• .... ` ALASKA AND THAT THIS PLAT 3L * i.. REPRESENTS A SURVEY DONE BY .� t .L+ .- � Hip,Gr Davis wo � b,,� .f< ,� 4 ��a ME OR UNDER MY SUPERVISION '�'I a -� -sr st S• No.i110�3 � E • r t�E,p�o•.�••• �•..oS � AND THAT I BELIEVE THAT ALL a4� FX „rp x iZ p. lee 10 �o�� DIMENSIONS AND OTHER DETAILS N;...�.'3 �''';, 4�>►�w•,�►�' ARE CORRECT AS SUBMITTED TO a_ • -., �..-i. °' 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 East DATE: 7-12-07 Umiat Meridian NANUQ JOB NO. SHEET DESCRIPTION: As-built Coordinates 05204 4 of 4 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME 1O V SAr—tl►k, O4bS i✓" Z 3 PTD# Development Service Exploratory Stratigraphic Test Non-Conventional Well �� FIELD: 64-4 POOL: A700 �'�/a `'-"�' • -`t • " 7' Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 w D 0 G) D 7 cn aD a -mi m a o C- 0 CO m S o p 3• 0 .< CD D) 3.o CO A W in w a) o- rn O n' N N Ni D) N D) 7 0 "y►.. 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C 0 CO : 0• 3 rn Z (<°D ( o 0 0 (o 0 o) (b -' CDD CD A a rn 7 n c - - o o n m a o O m a o 0 Cs) r *. v °o 0 0 0 0 0 m a m 3 - 0) (n - r Cn * 7 V 0. `< CO 7 5 � (O CO D N ' n N 3 n < CD (.1cn co N • O p V m Co CO p Cb O (v N N N CD V N n , n -° n - -o a o 3 n co• 7 n Q 7 ... N CD 3. n m . 0. 0 O m Q p) O of 7- X CO• a c c co 3 CO m c n (0 (0 7 7 Q a) a 0 n) c a 0 a U, n (Q o 0.) n ° o 2 0 o m V, m 3 c c 0 v O- 0 (D 7 0 CD o ' O CO co N 111_1 Vvell History t=ile AR• ENDIX 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. Technical Report Title Date Client: Pioneer Natural Resources Field: Oooguruk Development Rig: Nabors 19AC Date: July 15, 2011 Surface Data Logging End of Well Report ODSN-23i 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 GENERAL WELL INFORMATION Company: Pioneer Natural Resources AK Rig: Nabors 19AC Well: ODSN-23i ODSN-23i-PB1 ODSN-23i-PB2 Field: Oooguruk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-703-20639-00-00 50-703-20639-00-70 50-703-20639-00-71 Sperry Job Number: AK-AM-8100416 Job Start Date: 19 May 2011 Spud Date: 13 May 2011 Total Depth: ODSN-23i 20550’ MD, 6475’ TVD ODSN-23i-PB1 6079’ MD, 3259’ TVD ODSN-23i-PB2 11986’ MD, 5390’ TVD North Reference: True Declination: 20.9461 Dip Angle: 80.957 Total Field Strength: 57629 nT Date Of Magnetic Data: 9 May 2011 Wellhead Coordinates N: North 70° 29’ 44.93” Wellhead Coordinates W: West 150° 14’ 49.33“ Drill Floor Elevation 56.2’ Ground Elevation: 13.5’ Permanent Datum: Mean Sea Level SDL Engineers: Tom Mansfield, Colby Marks, Mark Lindloff, Ryan Massey David McKechnie Company Geologist: Paul Cozma, Jim Stewart Mindaugas Kuzminskas, Fletcher England Company Representatives: Rod Klepzig, Joey Cortez, Joe Polya, Jerry Haberthur SSDS Unit Number: 123 DAILY SUMMARY 5/19/2011 Mudloggers arrived on location. Rig drilled from 5475' MD to TD at 6079' MD. Pulled out of hole to 1748’ MD. Backreamed from 1748’ MD to 1100’ MD due to tight spot. Circulated 2 bottoms up at 1100’ MD and pulled out of hole. Rigged up CVE and calibrated gas gear. Checked cables for damage during rig move – Good. 5/20/2011 Prepared paperwork and computers for ODSN-23i. Began tripping in the hole for clean out run prior to running casing to 1876’ MD, reaming from 1395’ MD. Washed and reamed to 6079’ MD. Circulated 5 bottoms up. Pulled out of the hole from 5590’ MD to 5494’ MD with tight spots at 5558’ MD and 5528’ MD. Backreamed from 5494’ MD to 4732’ MD. Pumped a 60 bbl 12.7ppg sweep with no increase in cuttings. Continued pulling out of the hole to 2930’ with tight spots from 5276’ MD to 5256’ MD. 5/21/2011 Continued to backream out of tight hole from 2930' MD to approximately 896' MD at 630 gpm, 60 rpm. Circulated 2 bottoms up from 924' MD to 828' MD. Tight at 858' MD. Worked to 910' MD. Picked up and oriented. Attempted to slide down to find original wellbore. Slid from 910' MD to 1012' MD. Pulled out of the hole from 1012' MD to 738' MD. Circulated and attempted to find original wellbore from 738' MD to 975' MD with no success. Pulled out of the hole to surface and laid down BHA #3. Performed rig maintenance. Picked up and BHA #4, shallow tested tools - Good. Ran in the hole to 820' MD with no gains or losses. Oriented and attempted to locate original wellbore up to approximately 1042' MD with no success. Pull out to 822' MD and re-orient in an attempt to locate wellbore. Slid in the hole up to 1013' MD, unable to locate original wellbore. Pulled out of the hole to surface with the jars and lower BHA on slips. Continue waiting on Halliburton RSC to complete equipment maintenance. 5/22/2011 Continued to wait on Halliburton RSC to repair their Hammer Mill. Sperry SDL continued to prepare paperwork for Run 400. 5/23/2011 Continued to work on Hammer Mill. Released Mudloggers and Sample Catchers for surface hole re-drill. Shut down equipment and wait on weather to clear for helicopter. RIH to 685’ MD and trough to 714’ MD. Continued to run in hole to 1048’ MD and drilled ahead to 2412’ MD on sidetrack. Could not leave Island due to weather. 5/24/2011 Drilled from 2412’ MD to 2634’ MD and pulled out of the hole to change bent sub from 1.8° to 1.5°. Ran in hole and drilled ahead. Notified at 5am that we would not be leaving island, would stay for completion of surface hole. Drilled ahead from 2634’ MD to 3983’ MD, 5/25/2011 Continued drilling 14 1/2" Sidetrack 1 from 3983’ MD to 5396’ MD. Welded pin hole in suction manifold. Drilled ahead to 5613’ MD.' 5/26/2011 Drilled ahead from 5613’ MD to Surface Hole TD of 5790’ MD (3174’ TVD). Circulated bottoms up while pulling out of the hole at 1 stand per 30 minutes. Pumped sweep. Pulled out of the hole to 1578’ MD. Ran back to bottom and circulated out. Trip gas was 173 units at 9250 strokes (calculated 10250 strokes for gauge hole). Peak width was very wide (45 minutes). Pumped carbide tracer. Acetylene began returning after only 9025 strokes with peak at 11000 strokes (calculated at 11211 strokes for gauge hole). Continued to see acetylene after 17000 strokes. Carbide tracer indicated mud channeling and large washout area, probably in permafrost. Pumped sweep. Noted no increase in cuttings with sweep but significant increase of cuttings on bottoms up as 3x bottoms up was circulated. Pulled out of the hole to 5525' MD where hole pulled very tight, pumped out 400gpm and pulled tight with pack off. Able to work pipe free. Ran in hole with step rate to establish circulation. Circulated bottoms up with no increase in cuttings. Ran in hole to 5777' MD with no issues and pumped out of the hole until 4337' MD at which rig pulled out on elevators. No significant losses during trip or pack off event. Continued pulling out of the hole. 05/27/2011 Continued pulling out of the hole, tight at 4170’ MD. Slugged pipe at 3766’ MD. Laid down BHA 5. Rigged up Tesco equipment for running 11 ¾” casing. Displacement showed 6 bbls lost to hole during trip out. Ran in hole with 11 ¾” 60 lb/ft casing to 4464’ MD where hole became tight. Washed from 4464’ MD to 4748’ MD at 20 gpm with some packing off. Continued washing to bottom. Low trip displacement showing mud loss to hole. 5/28/2011 Continue to run in hole with 11 ¾” 60 lb/ft casing. Washed and rotated from 4748’ MD to 5447’ MD at 2 to 3 bbls/min and 5-10 RPM. Ran in hole from 5447’ MD to 5777’ MD. Displacement showed 56 bbls lost to hole while running casing. Made up hand and landed casing. Staged pumps up to 11 bbl/min with no losses. Blew pump pop-off. Changed out pop-off and staged up pumps again to 11 bbl/min. Performed cement job with 10 bbls of 10 ppg Dual Spacer, 593 bbls of 10.64 ppg lead cement, 104 bbls of 15.9 tail cement. Bumped plug. 280 bbls of 10.9 ppg returned to surface. Test casing shoe to 3500 psi. Rigged down cementing and casing equipment. Nippled up riser/spacer spools. Changed out swivel packing. Flushed out CVE hoses, lines, pump, and degasser to prevent cement from setting up in gas equipment. 5/29/2011 Nippled up and tested BOP’s. Made up 10 5/8” clean-out bottom hole assembly. Ran in hole picking up 5” drill pipe with perfect hole displacement. Cleaned pits for 9.8 ppg, 5% KCL/PHPA intermediate interval mud. 5/30/2011 Continued running in the hole with 10 5/8” Clean-out assembly picking up 5” drill pipe to 5327’ MD. Serviced Top Drive. Washed down last three stands and began drilling cement at 5673’ MD. Drilled out float equipment and shoe to 5801’ MD. Washed and reamed from 5801’ MD up to 5612’ MD. Drilled ahead to 5810’ MD. Performed FIT to 15.6 ppg equivalent MW. Swapped out Spud Mud to 9.8 ppg, 5% KCL/PHPA and POOH. Pick up MWD and under-reamer. RIH with BHA #7. 5/31/2011 Continued running in the hole with BHA #7. Shallow pulse tested MWD at 25 stands in the hole. Continued running in the hole to 5603’ MD. Slipped and cut drilling line at 5603’. Washed to bottom. Trip displacement showed no gains or losses. Drilled ahead from 5810’ MD. Trip gas was 28 units. Weak pulses from MWD tool. Drilled to 5987’ MD. Checked pumps and surface equipment for possible cause of MWD weak pulses. Pumped carbide to check for washout and lag correction. Carbide returned as single peak at 6125 strokes showing no sign of washout and gauge annular volume. Pull out of hole for MWD pulser. Trip out displacement good. Broke down BHA, replaced Pulser, made up BHA, and ran in the hole with a good displacement. Tested MWD tools - Good. Performed Reamer pull test and serviced the Top Drive. Began drilling ahead from 5987' MD to 6003’ MD. Circulated up 200 units of trip gas over a background of 30 units. ROP variable while drilling tuffaceous Shales. Torque and RPM was also variable as MWD/DD worked to mitigate vibrations to the drill string. 6/1/2011 Drilled ahead from 6003’ MD to 7224’ MD adding occasional NXS-Lube to reduce high vibration and stick slip. Background gas ran from 85 to just over 100 units. Two Hi Vis, 12.2 ppg weighted sweeps were pumped with 60% increase in cuttings noticed at shakers as sweeps returned to shakers. The hole began packing off while reaming for a connection at 7224’ blowing both pop-offs on the pumps. While attempting to regain circulation, 7 to 10 bbls were pumped away. Racked back two stands to 6558’ MD. Attempted to circulate without success. 6/2/2011 Continued to work pipe and attempt to break circulation. Worked pipe down 6488' MD to 6555' MD. Changed out lube pump on Top Drive. Continued to work tight spot from 6558' MD to 6622' MD while attempting to circulate. Worked tight spot from 6558' MD to 6654' MD. Circulated and conditioned 6610' MD to 6607' MD while stepping pump rate up to 720 gpm, 40-75 rpm. Back reamed hole from 6607' MD to 5892' MD. Circulated and conditioned from 5892' MD to 5987' MD. Circulated two 30 bbls 12 ppg Hi- Vis sweeps back to back at 700 to 720 gpm and 65 rpm. Noticed a 50% increase in cuttings at shakers with sweep returns. Tripped back into the hole to 7225' MD washing the last stand down. Staged up pumps to 850 gpm and began drilling ahead. With increased pump rate, large clay balls were seen at the shakers prior to bottoms up (from inside casing). 6/3/2011 Drilled ahead from 7280' MD to 7571' MD at 850 gpm, 110 rpm, and 2840 psi. ROP slowed from 100+ fph to 20 fph at 7466’ MD. Drilled from 7466' MD to 7650' MD with an ROP of 30-60 fph. At 7638' MD, pumped a 30 bbl anti-bit balling sweep of 30 ppb Medium Wall Nut and 3 ppb of SAPP. Spotted an 8 bbl pill out of bit and allow to soak for 10 minutes. Repeated soaking process three times allowing pill to soak around BHA. Continued drilling ahead 900 gpm, 3350 psi, 140 rpm. At 7700' ROP increased from 60 to 120 fph. Pumped additional 25 bbls SAPP, Wallnut sweep with sweep returns back to surface at 500 strokes over calculated hole volume. At 8081' MD pumped a high-vis, high weight sweep with 50% increase in cuttings at the shaker. Maximum gas for the day was 392 units from 8255’ MD. No fluid losses reported. Average hole size from annular correction of 11.8”. No fluid losses to the hole. 6/4/2011 Drill ahead to 8367' MD with 900 gpm, 3460 psi, 140 rpm. Pumped a 60 bbls 12.4 ppg high vis weighted sweep surface to surface with a 30 % increase in cuttings seen at the shakers upon return. Performed a whole mud dilution with 500 bbls of new 9.8 ppg mud from RSC while drilling ahead. At 8890' MD pumped another high vis/weighted sweep, again with 30 % increase in cuttings. Continued to drill ahead to 10062’ MD with 900 gpm, 150 rpm. Pumped third high vis/weighted sweep at 9510’ MD which brought back 70-100 % increase in cuttings. Another sweep at 10,000' MD brought back a 30% increase in cuttings. Sweeps and gas indicated average hole size of 11.9”. No connection gas noted. Average background gas for the day was 96 units. Maximum gas was 509 units from 9051’ MD. No fluid losses to the hole. 6/5/2011 Drilled ahead from 10061' MD to 10509' MD at 800-875 gpm, 3520psi and 150 rpm. Circulated and conditioned mud while working on generators. Pumped high vis, weighted (12.5 ppg) sweeps pumped at 10000' MD and 10500' MD bringing back 30% and 50%-70% increase in cuttings respectively. Drilled ahead to 11099' MD with 825 gpm, 3500 psi and 150 rpm. Encounter Torok Sand at 11043’ MD, 4980’ TVD. Lithology predominately Siltstone with minor fine grained Sandstone. Maximum gas through Torok Sand was 519 units over a background of 370 units. A high viscosity sweep was pumped at 11050' MD but pump swab failure during circulation caused blending. There was no increase in cuttings seen at the shaker from this sweep. Function tested BOP and drilled ahead to 11552' MD with 825 gpm, 3500 psi, 110 rpm. Pumped a high viscosity high weight (12.5 ppg) sweep at 11502' MD with a 30% increase in cuttings seen at the shakers. Sweeps and gas indicators show 11.8” average hole size. No fluid losses to the hole. Drilled ahead to 11552’ MD. 6/6/2011 Drilled 11552' MD to a TD of 11986' MD with 795 gpm, 3580 psi and 150 rpm. Circulated and conditioned mud while reciprocating drill pipe. Pumped a 50 bbls 12.4 ppg hi-vis sweep at 800 gpm, 3500 psi, and 140 rpm with 40-50% increase in cuttings. Sweep came back 800 strokes. Continued to circulate and reciprocate while pumping second 35 bbl 12.4 ppg hi-vis sweep with 30% increase in cuttings. Sweep also came back early. Pumped third 50 bbls 12.4 ppg hi vis sweep with 70% increase in cuttings, also returned early. Monitored well. Tripped out to 11414' MD with proper pipe displacement. Tripped back to bottom. Circulated and conditioned mud while pumping carbide pill followed by a 36 bbls 12.4 ppg hi vis sweep. Sweep returned to surface at 11950 strokes followed by Carbide, returning at 12,250 strokes, calculated strokes - 13,949. Monitored well. Tripped out to 9510' MD wiping hole with some 50-125K overpull. Tripped back into the hole without problems and circulated staging up pumps. Pumped 53 bbl 12.4 ppg hi vis sweep. At 7700 strokes the flow line packed off. Shut down pumps and cleaned out flow line. Recovered 14” long, approximately 3 lb, fragment of Shale and Tuff. Staged pumps back up, gradual pressure loss 3600-2700 psi. Work on mud pump swab. 6/7/2011 Short trip gas of 356 units. Began back reaming out. A pack-off event at 8327’ produced a mud loss of 18 bbls. Regained the 18 bbls within 10 minutes of continued circulation. Drop de-activation ball fro Rhino Reamer and pump down, no indication of shear observed. Continue back reaming out of hole to 6844’. 6/8/2011 Continue to back ream out of hole to 5910’. Experience high torque and stalling. Pump high vis sweep at 6220’ with 25% increase in cuttings, coupled with a SAPP sweep and NSX pill that both had minimal effect. Once at 5910’, circulate casing volume before pumping 50 bbl 12.4 ppg hi vis sweep, which had no effect on cuttings load. Continued out of hole to lay down BHA, 89’ of BHA left down hole. Pick up BHA number 9 and run in hole. No downhole losses for the past 24 hours, with no significant gas readings. 6/9/2011 Reaming to bottom with bull nose and reamer. Trip into hole to 5795’ MD and drop ball to open Rhino Reamer. Pumping sweeps every 1500’ MD +/-. Sweeps increase in cuttings ranging from 10%-75%. No downhole losses. Max gas for this interval while reaming was 407 units. 6/10/2011 Continued reaming and washing to 11897’ MD. Tag fish at 11897’ MD. Continue to clean hole utilizing Hi Vis weighted sweeps, with an average increase in cuttings of around 10-15%. Perform 755bbl mud dilution using new 9.8 ppg LSND mud. Begin POOH on elevators from 11985’ MD to 9536’ MD. Max gas seen while circulating was 235 units. No downhole losses. 6/11/2011 Continue to trip out of the hole 6394' MD to 5878' MD and circulate a high viscosity sweep with a 100% increase in cuttings returns.. Continue to trip out of the hole to 5638' MD and pull test reamer against casing shoe, 10K over. Pulling 90K over in casing with 100% swab. Pump out of the hole at 200 gpm, 600 psi. Cuttings return at shakers while pumping out of the hole was comparable to that seen while drilling. Trip/pump out of the hole to surface and lay down Rhino reamer BHA and inspect same. Change rams on BOP and inspect. Rig up and begin to test BOP's . No downhole losses. Max gas seen was 256 units. 6/12/2011 Finish testing BOPE. Rig up to run 9 5/8" 40# L-80 casing. Rig up Tesco equipment. Run casing to 5753'. Zero displacement. Reduce running speed from 3 to 6 minutes per stand without increase in displacement. At 5558' MD pump 1-2 bpm, 500-600psi with partial returns. At 5753' MD stage up pumps in 1/4 bbl increments to 7.5bbl/min, 500 psi and achieve 15-20% returns. Continue to run casing. Total losses to the hole as of midnight were 220 bbls. No significant gas recorded. 6/13/2011 Cont. to run casing, surging 30% returns 6497' MD to 6687' MD. Circulate and condition at 5bpm, with 100% returns. See pit gain, monitor well for 50 minutes, well breathing, 140 bbl gain. Well gain decrease from 15bbl/5 min to 5 bbls/5min. Run casing 6687' MD to 7448' MD with correct displacement. 7448' MD to 7829' MD loosing 12 bbls, decrease running speed from 10 fpm to 3 fpm. Monitor the well. Circulate at 7829' MD with 60% returns. Continue to run into the hole with casing and tag up on fish at 11897’ MD. Downhole losses for 24 hour period were 67bbsl. Total losses while running casing were 187 bbls. Max gas seen was 1000 units with and average circulating gas of 460 units. 6/14/2011 Drop 3/4" ball and seat to set hanger. While circulating at 6 bpm hole packed off. Bullhead 34 bbls down IA 4 bpm get 27 bbls of returns. Bullhead 60 bbls, get back 30 bbls. Attempt to circulate at 1 bpm with 10% returns. RSC Pump 10 bbls seawater, 60 bbl spacer, 113.5 bbls cement, 20 bbls seawater. Rig pump and latch up plug 15 bbls early. No returns to surface while pumping cement. Set liner top packer. Test liner. Rig down cement equipment. Trip out of hole and lay down. Pick up Rhino and bull nose assembly. Total downhole losses were 836 bbls for the previous 24 hours. Max gas was 418 units, with average circulating background of 115 units. 6/15/2011 Nipple up and test BOPs. Test 9 5/8” packer to 3500 psi. Pick up casing scraper and BAT sonic tool for cleanout run and cement bond log. Run in hole with 5” DP. Ream and wash from 1167’ MD to 11770’ MD. Tag float collar at 11770’ MD. Drill cement. Circulate and condition fluid. Pump to bottoms ups at 231 spm. Preparing for MADD pass. No losses to report or significant gas. 6/16/2011 Finished MADD Pass. POOH. Wait on orders from town read of BAT sonic as to how to proceed. After hearing from town, decision was made to pick up whip stock/ milling BHA. Pick up same and begin run in hole. No gas or losses to report. 6/17/2011 Run in hole to 5588’. Pump lube pill out of DP, continue running in and pump second lube pill at 8538’. Finish running in to 11770’. Orient, set, and anchor whip stock. Shear out with milling assembly. After tagging top of whip stock, condition mud with more lubes to reduce toque. Once torque was reduced, began milling window. Top of window is 11658’ and the bottom of the window is at 11675’. Pump hi vis sweeps with 50% increase in cuttings. Circulate bottoms up four times and perform FIT test to 14 ppg. Begin pulling out of hole to 5800’. Samples caught while milling were very contaminated by mud additives, and difficult to clean, although cement, sand grains, and silty clay were seen. Gas was minimal averaging around 40 units while milling/circulating. No losses observed downhole. 6/18/2011 Pump 60bbl Hi Vis weighted sweep at 5766’, circulate bottoms up twice. Pull out of hole to surface. Lay down milling assembly. Function test BOPs. Attempt to torque up Johnny Wacker, dropped in hole due to incorrect cross over sub. Slip and cut drilling line. Pick up Baker fishing assembly and run in hole with same. Run in hole to 11658’, stop to circulate and condition mud. Wash over fish to 11723’, attempt to retrieve fish. No gas for this interval or down hole losses. 6/19/2011 Pull out of hole with fishing assembly to surface, no fish. Decision was made to set bridge plug. Run in hole to 11658’. Ream and was to 11719’. Rig up cementing head and test cement lines. Pump 12.5 bbls of cement, and chase with rig pump. Pull back to 11391’ and squeeze cement with 1009 psi. 12.5 bbls of cement in and out. Drop nerf ball. Circulate bottoms up. No losses to the hole at this time. Max gas seen for the past 24 hours was 44 units. 6/20/2011 Pull out of hole. Pick up BHA motor/directional only. Run in hole to 11675’ No cement tagged. Pull to 11625’ and circulate bottoms up. No cement seen at shakers. Run back in hole to 11710’, and tag cement. Pull to 11690’. Ream, wash, and trough to 11723’. Drilling and sliding to 11742’. No losses for the past 24 hours. Max gas seen was 29 units, with average back ground gas of 15 units. 6/21/2011 Time drill at 3 feet per hour to 11760. Rotary drill to 12077’. Circulate open hole volume 5 times. Pull out of hole to 11601’. Circulate bottoms up 3 times and pump slug. Continue pulling out of hole with motor assembly. No downhole losses. Gas averaged around 35 units with a max of 62 units. Average hole size is 8.5”, in gauge. 6/22/2011 Finished pulling out of hole with motor assembly and lay down same. Test BOPs and Test MPD lines. Pick up Geo-Pilot BHA and begin to trip in hole. Shallow pulse test MWD. Continue running in hole to 11570’. Test Geo-Pilot and MWD. Circulate and condition mud. Slip and cut drill line. No downhole losses to report or significant gas peaks. Preparing to install RCD bearing. 6/23/2011 Install MPD RCD bearing. Continue running in hole to 11570’. Wash and ream down to 12077’. Drop ball to activate Rhino Reamer. Verify reamer is open. Drill to 12903’ and pump 50bbls Hi Vis Sweep, with 10% increase at shakers when sweep got to surface. Continue drilling to 13093’. No downhole losses. Max gas seen while drilling was 563 units with an average background gas of 180 units. 6/24/2011 Continue drilling to 13168’. RCD bearing failed, stop and change out same. Drill to 13208’. Started losing at 250 bph @ 13178’. Pull back to 13152’, Static losses were at 42bph. Pump 45bbl 50 ppb LCM pill. Circulate, condition, and build mud. Build 95bbl LCM pill. Spot 60 bbl freshwater pill, 10bbl 10.3 ppg mud, and 95 bbl LCM pill. Squeeze pill to 1300psi/ 5bbl mud. Hold 13 ppg EMW with MPD. Wait on squeeze. Losses 40-50 bph. Lower MPD to 12.9 ppg EMW. Observe for 1.5 hours and build mud. Begin to stage pumps and do step rate loss test. Losses ranged from 60-120bph during step rate test. Drill ahead to 13570’, with losses reduced to 5-20 bph. Drill ahead to 13665 with no losses. Pump 10bbl, 50 ppb LCM pills every connection. Total losses for the 24 hour period were 1079 bbls. Max gas seen while drilling was 263 units, with an average background gas of 155 units. 6/25/2011 Drill to TD of 2nd Intermediate section @ 14092’.Circulate 5 bottoms up. Short trip to shoe. Run back in hole with no returns for the first 15 stands, bled back pressure with MPD and started seeing returns. 40 bbls lost during trip in. Once on bottom, begin circulating 3 bottoms up. Trip gas was 1460 units. 6/26/2011 Displace 10.25ppg mud with 13ppg mud. Pump out of hole to 11595 with no issues. Remove RCD and continue to pump out of hole to 9570’, swabbing 20bbls. Trip out of hole on elevators from 9570’-5572’, hole taking correct displacement. Spot mud lube pill, slug pipe and pull out of hole to BHA. 6/27/2011 Pull out of hole to BHA. Lay down BHA and test BOPs. Rig up Tesco tool. Run 7” casing to 2561’ and rig down Tesco. Continue running 7’ casing in hole on 5” drill pipe. The last 15 stands of the trip in, noticed some surging. 30 bbl loss at 10800’ md during trip No gas to report for this interval . .6/28/2011 Stage pumps with 13ppg LSND, partial returns. Continue to trip in the hole to 11620' and rig up cement head.. Stage up pumps received partial returns. Continue tripping in hole to 14080'. Stage up pumps. receiving partial returns then returns diminished to No returns. Attempt Pick Up Liner. Wouldn't break over while circulating lost returns. Perform LOT. Attempt to circulate receive 20% returns. Bullhead 360bbls of 10.3 ppg mud weight down annulus, hold 600 psi. While pumps off install cement lines. WTF drop ball Circulate hanger ball on seat. Circulate until 10.3 ppg in / out. ( 866 units of Trip Gas seen at bottoms up). Perform job for cementing. Pump cement as per Halliburton. Bump plug with 3061 strokes. with 10.3 ppg drilling fluid. Release hanger. Circ and condition fluid to 10.25 ppg. Begin pulling out of hole and laying down 5" drill pipe, getting correct displacements. Total losses for the day 400 bbls. . 6/29/2011 Trip out of the hole laying down drill pipe, good displacement. Lay down liner setting assembly. Clean and clear the rig floor. Service the top drive. change out rams and service rig. Begin testing BOP's No losses recorded for the day. 6/30/2011 Continue to test BOPE. Pick up casing scraper and mill BHA and trip into the hole with same to 9797'. Circulate and condition drill pipe volume, 6 bpm, 950 psi to insure drillpipe is clear. Continue to trip into the hole to 11485' and dress PBR with polish tool. Pump three times bottoms up to condition mud. Pressure test casing to 3500 psi for 30 minutes. 7/01/2011 Continue to test BOPE. Pick up casing scraper and mill BHA and trip into the hole with same to 9797'. Circulate and condition drill pipe volume, 6 bpm, 950 psi to insure drillpipe is clear. Continue to trip into the hole to 11485' and dress PBR with polish tool. Pump three times bottoms up and condition mud to 10.0 ppg in and out. 5-10 units of gas seen while circulating. Pressure test casing to 3500 psi/30 minutes at time of report. No losses or gains during trip in or out,. 7/02/2011 Continue to run in hole with 7" casing to 11335'. No gains or losses during trip in. Lay down Tesco equipment. Make up and land hanger into polished bore. Rig up cementing equipment and pressure test cement lines. Circulate and condition mud from 10 ppg to 9.8 ppg in and out. Repair rig pump. Very little gas seen at bottoms up, 13 units. Pump cement according to Halliburton Cementers 7/03/2011 Rig down 7" casing equipment. Service the top drive. Run into the hole with 7" packoff and test to 5000 psi. Change rams on BOPE and test, Run into hole with 4" drill pipe to 9157'. No gains or losses seen while tripping. Circulate well 1.5 times drill pipe volume and increase mud weight to 10.2, minimal gas readings during circulation, averaging 4 units with bottoms up 236 units. Slip and cut drill line. 7/04/2011 Continue to slip and cut drilling line. Fire/Evacuation Drill. Trip out of the hole from 9157' to surface. Pick up BHA. Pump 10X pipe-volume, Remove wear bushing, suck out stack and pull wear ring. Make up pack off running tool and suck out stack and bell nipple. Nipple down BOPE. Prepare cellar and wellhead. Pick up tools and nipple up BOPE. Test BOPE and install wear ring. 07/05/2011 Pick up 6.125 BHA and trip into hole. No gains or losses during trip. Drill cement stringers 11197' to 11250'. Drill cement 11250' to 11403'. Plug/rubber seen at shakers with bottoms up strokes at 11403' . Wash and ream from 11422' to 13997'. Circulate and condition mud and pressure test casing to 3500 psi, continue to wash and ream to 14092'. Gas while washing and reaming averaged 5-10 units. 7/06/2011 Drill from 14102' to 14112’ md,. Circulate and condition mud one bottoms up and perform Formation Integrity Test to 12.5 EMW. Trip out of the hole, MAD passing to 11675' for cement bond log.. Trip out of the hole to surface and lay down BHA. Currently testing BOP. No gains or losses down hole during drilling or tripping. While drilling new formation gas fluctuated from 126 to 196 units. Sample was predominately cement and sandstone. Good show of sand in sample with good pale yellow fluorescence. and good pale yellow cut. 7/07/2011 Continue to test BOPE, troubleshoot leak. Nipple down BOP and change out annular element and seals and test. Pick up RCD head and install on BOP and test. Service top drive. Pick up bottom hole assembly and shallow pulse test MWD tools. Continue picking BHA to 409’. Trip into the hole on 4” drill pipe from 409' to 1855'. No gains or losses during trip. 7/8/2011 Trip into the hole 1855' to 4265'. Fill pipe and circulate and condition mud. Temporary loss of MWD detection due to aerated mud but was able to establish detection again. Continue to trip in the hole from 4265' to 14082', filling pipe every 25 stands. Displace well to OBW. Install Rotating head. And resume displacement. Torque dropped from 17K to 12K with Oil Base Mud in the hole. Drill ahead to 15,252’ MD. Gas averaging 300 to 850 units. Connection gas was observed between 15100 to 15300, Max connection gas seen 1860 units. Samples were 100% sandstone, angular to sub round, fine to very fine quartz grain, loose-unconsolidated, well sorted. 7/9/2011 Drill ahead 15252' to 16407'. service top drive. Continue to drill ahead 16407' to depth of 17853' while maintaining 165 FPH rate of penetration. No gains or losses down hole to report. At 16422’ a drop in ECD’s was detected when it surfaced gas peaked to 7495 units. Average for the day was 959 units. At 17930' Gas dropped from 600-1500 units to 200-350 units. Samples continue to be100% sandstone, angular to sub round, fine to very fine quartz grain, loose-unconsolidated, well sorted. 7/10/2011 Drill ahead 6.125" hole 17853' to 18912'. Service the top drive. Continue to drill ahead from 18912' to 19194', change out rotating head rubber. Drill ahead from 19194' to 20,068’md. No gains or losses to report down hole. Gas averaged 821 units for the day with a connection gas peak of 5299 units Connection Gas of 3676 units at 19863 lagged depth with background gas of 509 units. This was the result of 2 Surveys taken. Samples were 100% sandstone, angular to sub round, fine to very fine quartz grain, loose-unconsolidated, well sorted 7/11/2011 Drill ahead 20068' to 20165'. Circulate and condition while waiting on geology to determine Target Depth. Drill ahead to 20550' Target Depth. Finish drilling the well at 5:30 AM on 7-11-11. Circulate and condition well two times bottoms up . Well packed off while reciprocating at 20471'. Trip out of the hole 20550' to 19779' with intermittent pack offs from 20550' to 20100'. Back ream from19799' to 17371'. Change out RCD element and continue to back ream out of the hole to 14064' (20' inside the 7" casing).Hole was tight at 14625', wipe two times. -15 bbls loss to the hole during pack offs, connection Gas of 5298 units at 20167' with background gas of 385 units. This was the result of oscillating and rotating while waiting on further instructions then made a connection. 7/12/2011 Circulate and condition mud at 14064' md.. Pump a sweep and circulate it in and out. Small amount of cuttings prior to sweep, 50% increase with sweep return, Returns clean after sweep. Pump ½ bottoms up after sweep return. Slip and cut drilling line. Trip back into hole 14064' to 20100'. Tight at 14610', 18040', 18232'. Rotate through tight spots. Circulate and condition mud. Change out RCD element. At 20100' circulate one bottoms up,. Pumped a sweep in and out with 30% increase in cuttings with return, pump one bottoms up after sweep return. Pump spacer and base oil to fill lateral hole. Chase base oil with 139 bbls of 7.7 MOBM leaving 60 bbls of base oil in drill pipe. Pull out of the hole to 15542 md’. Pumped sweep to clear drill pipe of base oil. No losses down hole for the day. 07/13/2011 Pull out of hole to 14082' while spotting 10.1 ppg pill. Pump 10.1 ppg kill weight mud around. Monitor well for 10 minutes, received 5 bbls back. Shut chokes.100psi Well head pressure. Mud weight out 9.7ppg. Pump 60 bbls additional 10.1ppg. Mud weight out 9.5ppg. Shut chokes, well head pressure 150psi. Circulate 10.1ppg @ 2bpm. Shut chokes, well head pressure 100psi. Pull RCD bearing. Install trip nipple. Circulate 10.1ppg thru choke. Mud Weight out 9.2 ppg, well head pressure 100 psi. Circulate and condition mud while staging up circulation to 100 gpm. Mud Weight out 9.9 ppg. Circulate at 1 bpm till mud weight in and out 10.1 ppg. Shut down pumps. Monitor well. Static. Pump dry job. Function test blow out preventers. Pull out of hole to BHA. Monitor well. Static. Lay down BHA. No significant gas readings. Recorded losses down hole was 108 barrels 07/14/2011 Finish laying down bottom hole assembly. Pick up casing running tools. Trip in the hole with 4.5" Liner . Pick up magnet, scraper assembly.. Circulate and condition 20 bbls to clear heavy weight drill pipe. Trip in the hole on 4” drill pipe to 14047'. Circ Drill pipe volume from active pit 7. Trip in the hole. Total losses to hole during Liner run, last 24hrs = 21 bbls. Losses to hole approx 2.5 bbls/hr while running liner 07/15/2011 This concludes Surface Data Logging services for ODSN-23i. Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Sperry SDL arrived on location yesterday afternoon and began rigging up. The CVE was inspected and installed. -- Max: Hole Condition On Bot Hrs -- The SDL computers were updated with the new Insite versions and are ready for logging. The gas analyzer and chromatograph have been warmed up and calibrated. Sample Catchers will be on location this afternoon and will begin preparing sample ADT Engineers on SDL field ticket from 5/13/2011 to current PWD Drilling All Circ Avg Diam md. Sample Catchers arrive on location today supplies for the 1st Intermediate Section. Rig is running in the hole to bottom for cleanout run. - Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth - RIH to TD for Cleanout Run R.Klepzig/ J. Cortez -- Flow In (gpm) Current Pump & Flow Data: - 0 3.5170 $19,105.20 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % - 8.0 mg/l -AvgMin Max Max- pH Chlorides GvlCoal -Min -Avg Gas (units) ml/30min Max:Ambient Air Pit Room 72 North Slope Daily Charges Avg -- Pioneer ODSN-23i Oooguruk 1 05/20/2011-04:00 6079' Nabors 19AC $5,491.32 AK-AM-0008100416 (ppb Eq)cP PV Size MBT 6079'149.60 9.60 18.8 Silt Siltst ClystCht Chromatograph (ppm) H2S Data Sample Line Avg: C2C1 ShSd Depth Max 11.8 LstSst C4 C5 32 Tuff Gas Breakdown Avg: Average API Filt 9.00 C3 Tom Mansfield / Ryan Massey Ann Corr Cor Solids (lb/100ft2) 19,500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type TFA Hours Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield / Ryan Massey Ann Corr Cor Solids (lb/100ft2) 19,000 24 hr Max YP C3 API Filt 9.0039 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max 8.8 Lst 300 C2C1 Sh H2S Data Sample Line Avg: Chromatograph (ppm) 15.0 Silt Siltst ClystCht HTC/MXL-1 6079'189.65 9.65 32.08 Nabors 19AC $5,679.00 AK-AM-0008100416 14.5 0.700 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 2 05/21/2011-04:00 6079' North Slope Daily Charges Avg -- Gas (units) ml/30min Max:Ambient Air Pit Room 68 - pH Chlorides GvlCoal -Min -Avg % - 8.2 mg/l -AvgMin Max Max 1735 3.5170 $37,820.86 627 147 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke - POOH for Casing Run R.Klepzig/ J. Cortez -- Flow In (gpm) Current Pump & Flow Data: - - Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth md. elevators to 4681' MD. Tight hole was encountered from 5276' MD to 5256' MD as indicated with hookload. BHA pulled very very tight from 4708' MD to 4678' MD and took some time to work through. Began pumping out of the hole at 4681' MD to our current depth of 2930' MD at the time of report. Also pulled tight at approximately 4607' MD and 3658' MD to 3471' MD. No PWD Drilling All Circ Avg Diam in cuttings. Began pulling out of the hole when tight hole was encountered at 5558' MD and 5528' MD. Backreamed to 4732' MD. Ran in the hole to bottom and pumped sweep and saw no increase in cuttings. Serviced rig. Began pulling out of the hole on mud gains or losses noted during trips. Continued reaming in the hole. Circulated and conditioned just off bottom, pumped Hi-vis sweep and saw no increase -- Max: Hole Condition On Bot Hrs -- Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Continued to backream out of tight hole from 2930' MD to approximately 896' MD at 630gpm, 60rpm. Circulated -- Max: Hole Condition On Bot Hrs -- 2 bottoms up from 924' MD to 828' MD. Tight at 858' MD and worked to 910' MD. Picked up and oriented; attempt to slide down. Attempted to find original wellbore. Slide from 910' MD to 1012' MD; Pulled out of hole from 1012' MD to 738' MD. Circulated 1042' MD with no success. Pull out to 822' MD and re-orient in an attempt to locate wellbore. Slide in the hole up to 1013' MD, PWD Drilling All Circ Avg Diam md. unable to locate original wellbore. Pull out of the hole to surface with the jars and lower BHA on slips. Continue waiting on Halliburton RSC to complete equipment maintenance. and attempted to find original wellbore from 738' MD to 975' MD with no success. Pulled out of the hole to surface and laid down BHA #3. Performed rig maintenance. Picked up and BHA #4, shallow tested tools - Good. Rig on standby while RSC works on equipment. Ran in the hole to 820' MD with no gains or losses. Oriented and attempt to locate original wellbore up to approximately - Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth - Waiting on RSC R.Klepzig/ J. Cortez -- Flow In (gpm) Current Pump & Flow Data: - 0 3.5170 $43,499.86 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % - 7.0 mg/l -AvgMin Max Max- pH Chlorides GvlCoal -Min -Avg Gas (units) ml/30min Max:Ambient Air Pit Room 75 North Slope Daily Charges Avg -- Pioneer ODSN-23i Oooguruk 3 05/22/2011-04:00 6079' Nabors 19AC $5,679.00 AK-AM-0008100416 14.5 0.6995 (ppb Eq)cP PV Size MBT Hughes MXL-1V 6079'189.50 9.50 - 20.0 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: -- C2C1 ShSd Depth Max 9.2 Lst -400 Sst C4 C5 38 Tuff Gas Breakdown Avg: Average API Filt 9.40 - C3 Tom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 18,500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Continued to wait on Halliburton RSC to repair their Hammer Mill. Sperry SDL continued to prepare paperwork for -- Max: Hole Condition On Bot Hrs -- Run 400. PWD Drilling All Circ Avg Diam md. - Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth - Waiting on RSC Repairs R.Klepzig / J. Cortez -- Flow In (gpm) Current Pump & Flow Data: - 0 3.5170 $49,178.86 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % - 7.2 mg/l -AvgMin Max Max- pH Chlorides GvlCoal -Min -Avg Gas (units) ml/30min Max:Ambient Air Pit Room 69 North Slope Daily Charges Avg -- Pioneer ODSN-23i Oooguruk 4 05/23/2011-04:00 6079' Nabors 19AC $5,679.00 AK-AM-0008100416 14.5 0.6995 (ppb Eq)cP PV Size MBT Hughes MXL-1V 6079'229.45 9.45 - 20.0 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: -- C2C1 ShSd Depth Max 8.8 Lst -400 Sst C4 C5 29 Tuff Gas Breakdown Avg: Average API Filt 8.80 - C3 Tom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 19,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) - 24 hr Max YP C3 API Filt - - - Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max - Lst ---- C2C1 Sh - H2S Data Sample Line Avg: Chromatograph (ppm) - Silt Siltst ClystCht TFA Hours - ---- - Nabors 19AC $5,679.00 AK-AM-0008100416 -- (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 5 05/24/2011-04:00 - North Slope Daily Charges Avg -- Gas (units) ml/30min Max:Ambient Air Pit Room - - pH Chlorides GvlCoal -Min -Avg % - - mg/l -AvgMin Max Max - 3.5170 $54,857.00 - - Total Charges: Flow In (spm) SPP (psi) Gallons/stroke - Drilling Ahead R.Klepzig / J. Cortez -- Flow In (gpm) Current Pump & Flow Data: - - Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth md. PWD Drilling All Circ Avg Diam Sperry SDL released as of 5/23/2011 at 07:00; called back to rig 5/24/2011 09:00. No report was completed for this day. -- Max: Hole Condition On Bot Hrs -- Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Sperry SDL released as of 5/23/2011 at 07:00; called back to rig 5/24/2011 09:00 in preparation for Intermediate Hole Section 1. -- Max: Hole Condition On Bot Hrs -- No morning report # 5. Restarted computers and readied SDL supplies for drilling. The rig continued drilling 14.5" Surface Hole. Drilled from 2412' MD to 2634' MD, pumped out fo the hole to 13101' MD. Pulled out of hole on elevators to change out PWD Drilling All Circ Avg Diam md. bit and change bend in motor. Run in the to 2634' MD with tight spots at 1542' MD, 1568' MD. An increase of cuttings after circulating bottoms up. Drilling ahead at 4318' MD at the time of report. 126.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth - Drilling Ahead R.Klepzig / J. Cortez -- Flow In (gpm) Current Pump & Flow Data: - 2497 3.5170 $60,536.86 700 165 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % - 6.8 mg/l -AvgMin Max Max- pH Chlorides GvlCoal -Min -Avg Gas (units) ml/30min Max:Ambient Air Pit Room 131 North Slope Daily Charges Avg -- Pioneer ODSN-23i Oooguruk 6 05/25/2011-04:00 4318' Nabors 19AC $5,679.00 AK-AM-0008100416 14.5 0.6995 (ppb Eq)cP PV Size MBT Hughes MXL-1V 3562'239.40 9.40 - 17.5 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: -- C2C1 Sh - Sd Depth Max 8.4 Lst -400 Sst C4 C5 51 Tuff Gas Breakdown Avg: Average API Filt 9.10 - C3 Tom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP C3 API Filt 8.90 - 46 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max 9.2 Lst 2634' 500 5790' 3156' C2C1 Sh - H2S Data Sample Line Avg: Chromatograph (ppm) 20.0 Silt Siltst ClystCht TFA Hours Hughes MXL-1V 5481'209.50 9.50 26.39 Nabors 19AC $5,679.00 AK-AM-0008100416 14.5 0.6995 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 7 05/26/2011-04:00 5790' North Slope Daily Charges Avg 100.0 - Gas (units) ml/30min Max:Ambient Air Pit Room 120 - pH Chlorides GvlCoal -Min -Avg % - 7.5 mg/l -AvgMin Max Max 2417 4.2300 $66,215.86 700 162 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 1472' CBU after TD R.Klepzig / J. Cortez -- Flow In (gpm) Current Pump & Flow Data: - 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth md. PWD Drilling All Circ Avg Diam hole at 1 stnd/30 minutes. Waiting on Sweep to return to surface. Drilled ahead from 4318' MD to a Surface Hole TD of 5790' MD. Circulating bottoms up while pulling out of the -- Max: Hole Condition On Bot Hrs -- Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Continued to wait on sweep to return to surface; no definitive signs that sweep returned to surface other than -- Max: Hole Condition On Bot Hrs -- slight increase in cuttings. Pulled out of the from 4920' MD to 1575' MD and noted the BHA pulling tight at 4872' MD, 4750' MD, 4446' MD, 4168' MD, 4058' MD, 3776' MD, 3400' MD, 3200' MD. Ran in the hole from 1575' MD to 3586' MD and reamed with 11000 strokes (Calculated at 11211 strokes for a gauge hole). Channeling may be taking place with sweeps and Carbide tracers PWD Drilling All Circ Avg Diam md. based on stroke calculations. Noted no increase in cuttings with sweep but significant increase of cuttings on bottoms up as 3x bottoms up was circulated. Pulled out of the hole to 5525' MD where hole pulled very tight, pumped out 400gpm and pulled tight with pack off. Able to work pipe free. Ran in hole with step rate to establish circulation. Circulated bottoms up with no increase in cuttings. Ran in hole to 5777' MD with no issues and pumped out of the hole until 4337' MD at which rig pulled out on elevators. 3bpm, 30rpm at 3020' MD, 3208' MD, 3350' ND, 3380' MD. Washed and reamed from 3586' MD to 5790' MD, pulled tight at 5670' MD and reamed with 3bpm, 20rpm. Trip gas was 173 units max at 9250 strokes (Calculated was 10250 strokes for gauge hole). SDL dropped a Carbide tracer in the drill pipe and noted Acetylene began returning after only 9025 strokes with the gas peak at No significant losses during trip or pack off event. Pulling out of the hole, racking back HWDP at the time of report. - Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth 0' POOH J. Polya / J. Cortez -- Flow In (gpm) Current Pump & Flow Data: - 0 4.2300 $71,894.86 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % - 8.1 mg/l -AvgMin Max Max- pH Chlorides GvlCoal -Min -Avg Gas (units) ml/30min Max:Ambient Air Pit Room 64 North Slope Daily Charges Avg -- Pioneer ODSN-23i Oooguruk 8 05/27/2011-04:00 5790' Nabors 19AC $5,679.00 AK-AM-0008100416 14.5 0.6995 (ppb Eq)cP PV Size MBT Hughes MXL-1V 5790'159.60 9.60 26.39 22.5 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: 5790' 3156' C2C1 Sh - Sd Depth Max 10.0 Lst 2634' 500 Sst C4 C5 32 Tuff Gas Breakdown Avg: Average API Filt 8.80 - C3 Tom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 19,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 19,000 24 hr Max YP C3 API Filt 8.40 - 45 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max 10.0 Lst 2634' 500 5790' 3156' C2C1 Sh - H2S Data Sample Line Avg: Chromatograph (ppm) 22.5 Silt Siltst ClystCht TFA Hours Hughes MXL-1V 5790'2110.10 10.10 26.39 Nabors 19AC $5,679.00 AK-AM-0008100416 14.5 0.6995 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 9 05/28/2011-04:00 5790' North Slope Daily Charges Avg -- Gas (units) ml/30min Max:Ambient Air Pit Room 81 - pH Chlorides GvlCoal -Min -Avg % - 11.5 mg/l -AvgMin Max Max 0 4.2300 $77,573.86 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Landing Casing J. Polya / J. Cortez -- Flow In (gpm) Current Pump & Flow Data: - - Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth md. tight spots. In process of landing casing at the time of report. Noted a 56.2bbls loss during the trip in hole. PWD Drilling All Circ Avg Diam Rigged up with casing equipment; troubleshot same. Ran in the hole with 11.75" (60#) Casing to 4464' MD where hole became tight. Washed down with 20gpm, 2-10rpm to 4790' MD where hole cleared up. Continued to wash to bottom with no significant Racked back HWDP and laid down BHA. After conferring with Pit Watcher, 6bbls were lost while pulling out of the hole. -- Max: Hole Condition On Bot Hrs -- Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Made up hanger and landed casing. Rigged up cement head and began cement job. Pumped cement and saw -- Max: Hole Condition On Bot Hrs -- 280bbls of 10.9ppg cement to surface; no losses. Tested casing shoes to 3500psi. Rigged down casing and cement equipement. Sperry SDL cleaned CVE to ensure no cement set up in equipment. Rig worked on swivel packing; working on BOP at the time PWD Drilling All Circ Avg Diam md. ADT Engineer removed from Field Ticket for 5/29/2011 of report. - Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth 0' Work on BOP J. Polya / J. Cortez -- Flow In (gpm) Current Pump & Flow Data: - 0 4.2300 $81,781.64 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % - 9.2 mg/l -AvgMin Max Max- pH Chlorides GvlCoal -Min -Avg Gas (units) ml/30min Max:Ambient Air Pit Room 41 North Slope Daily Charges Avg -- Pioneer ODSN-23i Oooguruk 10 05/29/2011-04:00 5790' Nabors 19AC $4,207.78 AK-AM-0008100416 14.5 0.6995 (ppb Eq)cP PV Size MBT Hughes MXL-1V 5790'79.75 9.75 26.39 19.0 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: 5790' 3156' C2C1 Sh - Sd Depth Max 14.0 Lst 2634' 500 Sst C4 C5 14 Tuff Gas Breakdown Avg: Average API Filt 8.50 - C3 Tom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 18,000 24 hr Max YP C3 API Filt 8.20 - 12 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max 16.0 Lst 2634' 500 5790' 3156' C2C1 Sh - H2S Data Sample Line Avg: Chromatograph (ppm) 20.0 Silt Siltst ClystCht TFA Hours Hughes MXL-1V 5079'89.60 9.60 26.39 Nabors 19AC $4,207.78 AK-AM-0008100416 14.5 0.6995 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 11 05/30/2011-04:00 5790' North Slope Daily Charges Avg -- Gas (units) ml/30min Max:Ambient Air Pit Room 41 - pH Chlorides GvlCoal -Min -Avg % - 9.2 mg/l -AvgMin Max Max 0 4.2300 $85,989.42 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Singling in Hole J. Polya / J. Cortez -- Flow In (gpm) Current Pump & Flow Data: - - Max @ ft Current R.O.P. (ft/hr) Gas (units)-- - Depth md. PWD Drilling All Circ Avg Diam with 4" single joints of drill pipe. Tripping in the hole at 5306' MD at the time of report. Nipple up BOP's and tested same. Made up 10.625" Clean out BHA and ran in the hole. Picked up and ran in the hole -- Max: Hole Condition On Bot Hrs -- Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 27,000 24 hr Max YP C3 API Filt 10.50 - 21 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max 6.4 Lst 5810' 700 -- C2C1 Sh - H2S Data Sample Line Avg: Chromatograph (ppm) 1.0 Silt Siltst ClystCht TFA Hours HDBS FXG65 5810'109.80 9.80 0.00 Nabors 19AC $4,865.75 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 12 05/31/2011-04:00 5827' North Slope Daily Charges Avg -- Gas (units) ml/30min Max:Ambient Air Pit Room 47 10.04 pH Chlorides GvlCoal 9.52 Min 9.91 Avg % 10.45 5.4 mg/l 10.12 AvgMin Max Max 1892 4.2300 $90,855.17 701 165 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 17' Drilling Ahead J. Polya / J. Cortez 15 5801' Flow In (gpm) Current Pump & Flow Data: 10.71 93.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)23 - - Depth md. has returned to surface at the time of report. Pulled out of the hole to 5777' MD. Perform LOT to 15.69 EMW. Displaced 9.7ppg Spud Mud w2ith 9.8ppg 5% KCL/PHPA Mud. Pulled out of the hole to surface with Cleanout BHA and laid down same. Picked up 10.625" Intermediate Drilling BHA #7 and ran in the hole. Shallow pulse tested - Good and tested at 25 stands in the hole - Good. Continued to run in the hole to the shoe PWD Drilling All Circ Avg Diam equipment, and shoes. Drilled from 5790' MD to 5801' MD and washed/reamed from 5801' MD to 5612' MD to clean up mud. Drilled from 5801' MD to 5810' MD and circulated bottoms up. CVE was energized and a max gas of 15 units was noted. where the rig cut and slipped drill line. Washed down to bottom. Began drilling ahead 5810' MD. Neither Trip Gas nor Drillin Gas Continued to run in the hole with the 10.625" Cleanout BHA. Took weight at 5577' MD and drilled cement, float 0 bbls 10.63'' Max: Hole Condition On Bot Hrs 5827'0.48 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 27,500 24 hr Max YP C3 API Filt 10.40 - 24 Tuff Gas Breakdown Avg: 100 Average Sst C4 C5 Sd Depth Max 5.6 Lst 5810' 800 -- C2C1 Sh - H2S Data Sample Line Avg: Chromatograph (ppm) 2.0 Silt Siltst ClystCht TFA Hours HDBS FXG65 5987'109.80 9.80 0.00 Nabors 19AC $6,336.97 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 13 06/1/2011-04:00 6173' North Slope Daily Charges Avg 72.0 187 Gas (units) ml/30min Max:Ambient Air Pit Room 44 10.13 pH Chlorides GvlCoal 9.45 Min 9.72 Avg % 10.34 5.3 mg/l 10.20 AvgMin Max Max 2115 4.2300 $98,663.36 841 199 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 346' Drilling Ahead J. Polya / J. Cortez 89 6116' Flow In (gpm) Current Pump & Flow Data: 10.86 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)41 35 5896' Depth md. * ADT Engineer on Field Ticket hole. Slugged pipe and came out of the hole with good displacement. Broke down BHA, replaced Pulser, made up BHA, and ran in the hole with a good displacement. Tested MWD tools - Good. Performed Reamer pull test and serviced the Top Drive. Began drilling ahead at 5987' MD, circulated up 200 units of trip gas over a background of 30 units. ROP has been variable as PWD Drilling All Circ Avg Diam background. Continued to drill from 5827' MD to 5987' MD at which MWD had trouble getting detection. Dropped a Carbide Pill to ensure washout hasn't taken place within the drill pipe; Carbide returned to surface as calculated. Decision made to pull out of the the hard tuffaceous Shales are being drilled. Torque and RPM was also variable as MWD/DD worked to mitigate vibrations to the string. Dropped ball to activate reamer, circulated while waiting to activate. Max trip gas was 28 unit and faded back to 6 units 0 bbls 10.63'' Max: Hole Condition On Bot Hrs 6173'4.19 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Continued to drill ahead form 5987' MD to 7224' MD. There were no significant peaks in the drilling gas throughout 0 bbls 10.63'' Max: Hole Condition On Bot Hrs 6173'4.19 the interval drilled. Max gas was 215 unit at 6460' MD in a broad peak. Connection gas was noted at 6463' MD connection which read 214 units over 125 units background. No losses/gains noted while drilling. Pumped 50bbls high weight followed by high vis attempting to establish circulation. At 6944' MD, had trouble rotating stand through. BHA continued to pull tight to approximately PWD Drilling All Circ Avg Diam md. 6494' MD, having difficulty rotating. Working on top drive at the of report. sweep at 6844' MD and noted a 60% increase in returns to shakers. The hole began packing after backreaming to 7190' MD, after drilling stand down to 6844' MD. Both pop-offs on pumps blown and lost 7bbls of mud. Worked pipe with 30rpm and unable to establish circulation as SSP built up to approximately 710psi, slowly bled off. Worked back 1 stand at a time while rotating and 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 86 6566' Depth 1051' Fighting Pack Off J. Polya / J. Haberthur 215 6460' Flow In (gpm) Current Pump & Flow Data: 11.03 187 4.2300 $105,000.33 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 11.95 5.5 mg/l 10.83 AvgMin Max Max10.17 pH Chlorides GvlCoal 9.49 Min 9.90 Avg Gas (units) ml/30min Max:Ambient Air Pit Room 51 North Slope Daily Charges Avg 42.0 275 Pioneer ODSN-23i Oooguruk 14 06/2/2011-04:00 7224' Nabors 19AC $6,336.97 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT HDBS FXG65 7224'159.80 9.80 0.00 6.0 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: -- C2C1 Sh - Sd Depth Max 6.0 Lst 5810' 800 Sst C4 C5 26 Tuff Gas Breakdown Avg: 100 Average API Filt 9.20 - C3 Tom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 26,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield / Ryan Massey - Ann Corr Cor Solids (lb/100ft2) 23,000 24 hr Max YP C3 API Filt 9.00 - 31 Tuff Gas Breakdown Avg: 100 Average Sst C4 C5 Sd Depth Max 6.0 Lst 5810' 800 -- C2C1 Sh - H2S Data Sample Line Avg: Chromatograph (ppm) 12.0 Silt Siltst ClystCht TFA Hours HDBS FXG65 7243'149.80 9.80 0.00 Nabors 19AC $7,242.34 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 15 06/3/2011-04:00 7491' North Slope Daily Charges Avg 109.6 212 Gas (units) ml/30min Max:Ambient Air Pit Room 52 10.57 pH Chlorides GvlCoal 9.59 Min 9.93 Avg % 11.09 5.7 mg/l 10.77 AvgMin Max Max 2908 4.2300 $112,242.67 850 200 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 267' Drilling Ahead J. Polya / J. Haberthur 118 7317' Flow In (gpm) Current Pump & Flow Data: 10.82 33.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)55 65 7244' Depth md. a controlled rate. Drilling gas averaged 65 to 85 units with no substantial peaks. No gains or losses while drilling. Drilling ahead at the time of report. losses turned out to be mud volume replacing the cuttings volume in hole. This was confirmed by the volume received to the CCU. Circulated two 30bbls 12ppg Hi-Vis sweeps back to back at 700gpm-720gpm, 65rpm. 50% increase in cuttings were seen at the shakers when the sweep returned. Also noted an increase of gas to 177 units at bottoms up, up from 68 units background. Ran in PWD Drilling All Circ Avg Diam *Colby Marks changing out for Ryan Massey attempting to circulate. Established circulation using the step method working the flow rate up to 720pgm, 40-75rpm. Noted 111 units of gas. Hole began unloading as soon as circulation was established until the pumps were turned off. What was first noted as the hole on elevators and washed the last stand to bottom. Noted 247 units of max gas at bottoms up. Commenced drilling at Continued to work on top drive, changed out lube pump. Continued to work tight spot at 6558' MD to 6622' MD while 0 bbls 11.75'' Max: Hole Condition On Bot Hrs 7491'16.96 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.75'' Max: Hole Condition On Bot Hrs 8373'34.29 PWD Drilling All Circ Avg Diam *Colby Marks changing out for Ryan Massey and allowed it to soak in an attempt to try and relieve the balling.After doing so, when getting bacl to dilling to ROP picked back up to arounds 120' fph. Drilling ahead at time of report. No lossesw to report to the hole. Max gas observed was 365 units. With Drill ahead from 7280 to 7638 eith ROP dropping from 100 fph tp 35 fph.due to bit balling. Pumped SAPP sweep 0 bbls md no connection gases. 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)110 100 7244' Depth 971' Drilling Ahead J. Polya / J. Haberthur 365 8151' Flow In (gpm) Current Pump & Flow Data: 10.82 3158 4.2300 $118,579.64 850 200 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 11.09 6.2 mg/l 10.77 AvgMin Max Max10.57 pH Chlorides GvlCoal 9.59 Min 9.93 Avg ml/30min Max:Ambient Air Pit Room North Slope Daily Charges Avg 43.3 212 Pioneer ODSN-23i Oooguruk 16 06/4/2011-04:00 8152' Nabors 19AC $6,336.97 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT HDBS FXG65 8229'169.90 9.90 0.00 19.0 Silt Siltst ClystCht TFA Hours 52 Chromatograph (ppm) H2S Data Sample Line Avg: Gas (units) -- C2C1 Sh - Sd Depth Max 5.0 Lst 5810' 800 C4 C5 Tuff Gas Breakdown Avg: 100 Average Sst C3 API Filt 9.40 - 36 Tom Mansfield / Colby Marks - Ann Corr Cor Solids (lb/100ft2) 24,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 12.76'' Max: Hole Condition On Bot Hrs 10281'53.09 PWD Drilling All Circ Avg Diam Max gas recored during the last interval was 509 units. Calculated average hole diameter at this time is 12.76" Pump high vis/weighted sweeps every 500'.Drilling ahead at time of report. No losses for the past 24 hours. 105 bbls md 106.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)91 168 9136' Depth 2129' Drilling Ahead J. Polya / J. Haberthur 509 9055' Flow In (gpm) Current Pump & Flow Data: 3681 4.2300 $124,916.61 890 209 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 11.34 5.7 mg/l 10.78 AvgMin Max Max10.39 pH Chlorides GvlCoal Min Avg ml/30min Max:Ambient Air Pit Room North Slope Daily Charges Avg 96.0 194 Pioneer ODSN-23i Oooguruk 17 06/5/2011-04:00 10281' Nabors 19AC $6,336.97 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT HDBS FXG65 9986'159.90 9.90 0.00 14.0 Silt Siltst ClystCht TFA Hours 51 Chromatograph (ppm) 5 H2S Data Sample Line Avg: Gas (units) -- C2C1 Sh - Sd Depth Max 6.0 Lst 5810' 800 C4 C5 Tuff Gas Breakdown Avg: 95 Average Sst C3 API Filt 10.00 - 30 Tom Mansfield / Colby Marks - Ann Corr Cor Solids (lb/100ft2) 24,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield / Colby Marks - Ann Corr Cor Solids (lb/100ft2) 26,000 24 hr Max YP - C3 26 Tuff Gas Breakdown Avg: 45 Average Sst C4 C5 Sd Depth Max 5.0 Lst 5810' 800 55 -- C2C1 Sh - H2S Data Sample Line Avg: Chromatograph (ppm) 5 13.5 Silt Siltst ClystCht TFA Hours HDBS FXG65 11520'139.90 9.90 0.00 Nabors 19AC $6,336.97 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 18 06/6/2011-04:00 11775' North Slope Daily Charges Avg 67.0 155 Gas (units) ml/30min Max:Ambient Air Pit Room 50 10.39 pH Chlorides GvlCoal Min Avg 6.0 mg/l 10.78 AvgMin Max Max API Filt 10.10 3681 4.2300 $131,253.58 890 209 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 1494' Drilling Ahead J. Polya / J. Haberthur 683 11435' Flow In (gpm) Current Pump & Flow Data: 55.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)207 168 11414' Depth md increase in cuttings, confirming that our lag is accurate. No Losses at 10000' and 10500' with 30% and 50% increase in cutting respectively. A hi vis sweep was pumped at 11050' but pump swab failure during circulation caused blending, no increase was seen from this sweep. Pumped hi vis sweep at 11500' with 30% PWD Drilling All Circ Avg Diam % 11.34 Drill haead from 10281' to . Generator and MWD issues, circulate and condition. Pumped hi vis/ hi wegth sweeps 110 bbl 11.89'' Max: Hole Condition On Bot Hrs 10281'69.79 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 11.89'' Max: Hole Condition On Bot Hrs 11986'72.75 PWD Drilling All Circ Avg Diam packed off, clean out flow line. Once on bottom, pump sweeps and circulate bottoms 4x. Backreaming out of hole at report time. Drill to TD at 11986'. Circulate and condition mud. Short trip to 9510'. Run back to bottom with no issues. Flow line 110 bbl md 55.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)25 168 11414' Depth 211' Drilling Ahead J. Polya / J. Haberthur 356 Circ Flow In (gpm) Current Pump & Flow Data: 3681 4.2300 $137,590.55 890 209 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 11.34 6.2 mg/l 10.78 AvgMin Max Max10.39 pH Chlorides GvlCoal Min Avg ml/30min Max:Ambient Air Pit Room North Slope Daily Charges Avg 67.0 155 Pioneer ODSN-23i Oooguruk 19 06/7/2011-04:00 11986' Nabors 19AC $6,336.97 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT HDBS FXG65 11986'179.90 9.90 0.00 14.0 Silt Siltst ClystCht TFA Hours 49 Chromatograph (ppm) 5 H2S Data Sample Line Avg: Gas (units) -- C2C1 Sh - Sd Depth Max 6.0 Lst 5810' 800 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 API Filt 9.30 - 25 Tom Mansfield / Colby Marks - Ann Corr Cor Solids (lb/100ft2) 23,500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirTom Mansfield / Colby Marks - Ann Corr Cor Solids (lb/100ft2) 22,500 24 hr Max YP C3 API Filt 9.30 - 26 Tuff Gas Breakdown Avg: Average Sst C4 C5 Sd Depth Max 6.0 Lst 5810' 800 -- C2C1 Sh - H2S Data Sample Line Avg: Chromatograph (ppm) 14.0 Silt Siltst ClystCht TFA Hours HDBS FXG65 11986'169.80 9.80 0.00 Nabors 19AC $6,336.97 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 20 06/8/2011-04:00 11986' North Slope Daily Charges Avg Gas (units) ml/30min Max:Ambient Air Pit Room 49 10.39 pH Chlorides GvlCoal Min Avg % 11.34 6.3 mg/l 10.78 AvgMin Max Max 1631 4.2300 $143,927.52 805 191 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Back Reaming J. Polya / J. Haberthur 274 Circ Flow In (gpm) Current Pump & Flow Data: Max @ ft Current R.O.P. (ft/hr) Gas (units)39 53 Depth md. PWD Drilling All Circ Avg Diam MWD, no detection. Begin back reaming out of hole. Drop 2" deactivation ball for Rhino reamer, no indication of shear. Packoff event at 8352'. Continue back reaming out of hole at report time. No losses to the hole for the past 24 hours. Circulate and condition mud. Pump hi vis sweep, sweep brought back a 10% increase in cuttings. Trouble shoot 110 bbl 11.89'' Max: Hole Condition On Bot Hrs 11986'72.75 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Back ream to 5910' and circulate casing volume prior to pumping a hi vis sweep with no increase in cuttings upon 110 bbl 11.89'' Max: Hole Condition On Bot Hrs 11986'72.75 return. Trip out of the hole and lay down BHA, 90' of BHA left in hole. Service top drive and test BOPE. Pick up new Rhino reamer BHA for cleanout run. RIH and begin reaming, gas maintaining 50 to 90 units. Good amount of cuttings coming across the shakers. PWD Drilling All Circ Avg Diam md. Mostly shale and siltstone, <1 to 5 mm, sub angular pieces, mostly gray brown, some light gray, No losses to the hole for the past 24 hours. Max @ ft Current R.O.P. (ft/hr) Gas (units)59 60 Depth 0' Running Hole Cleaner R.Klepzig / J. Haberthur 78 Circ Flow In (gpm) Current Pump & Flow Data: 1262 4.2300 $151,537.67 496 117 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 6.3 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cleanout Run Gas (units) ml/30min Max:Ambient Air Pit Room 50 North Slope Daily Charges Avg 8.25 Pioneer ODSN-23i Oooguruk 21 06/9/2011-04:00 11986' Nabors 19AC $6,336.97 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT HDBS FXG65 11986'159.80 9.80 72.75 14.5 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: 11986' 6086' C2C1 Sh 15 Sd Depth Max 6.0 Lst 5810' 800 900 Bull Nose 40 Sst C4 C5 24 Tuff Gas Breakdown Avg: 60 Average API Filt 9.20 135 C3 Colby Marks/Mark Lindloff LIH Ann Corr Cor Solids (lb/100ft2) 22,500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks/Mark Lindloff LIH Ann Corr Cor Solids (lb/100ft2) 22,500 24 hr Max YP C3 API Filt 9.70 135 17 Tuff Gas Breakdown Avg: 55 Average Sst C4 C5 Sd Depth Max 28.0 Lst 5810' 800 900 Bull Nose 35 11986' 6086' C2C1 Sh 15 H2S Data Sample Line Avg: Chromatograph (ppm) 10 16.0 Silt Siltst ClystCht TFA Hours HDBS FXG65 11986'169.90 9.90 72.75 Nabors 19AC $4,865.75 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 22 06/10/2011-04:00 11986' North Slope Daily Charges Avg 8.25 Gas (units) ml/30min Max:Ambient Air Pit Room 55 Cleanout Run pH Chlorides GvlCoal Min Avg % 7.3 mg/l AvgMin Max Max 3645 4.2300 $155,832.20 765 180 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Running Hole Cleaner R.Klepzig / J. Haberthur 407 Circ Flow In (gpm) Current Pump & Flow Data: Max @ ft Current R.O.P. (ft/hr) Gas (units)94 118 Depth md. <1 to 5 mm, sub angular pieces, mostly gray brown, some light gray. Throughout evening large gray, sub rounded pieces of claystone >100 mm were caught coming over the shaker. No losses to the hole for the past 24 hours. PWD Drilling All Circ Avg Diam increase in cuttings (less than10%) Pumped a sweep at 10299' with a 30% increase in cuttings. Gas averaging 100 to 150 units .With Max Gas 407 units at 7900'.Cuttings coming across the shakers. Mostly shale and siltstone, scattered tuffacious material, Continue to Ream ahead at +/- 500 fph depending on hole conditions. Pumped Hi-vis sweep at 8697with minimal 110 bbl 11.89'' Max: Hole Condition On Bot Hrs 11986' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Continue reaming and washing from 10488' to 11897'. Torque up to 20K. Circulate and condition, pump 110 bbl 11.89'' Max: Hole Condition On Bot Hrs 11986' high viscosity sweep. Pump swab failure. Circulate with one pump and reciprocate 500 gpm while repairing pump. Continue circulate sweep to surface with 10% increase in cuttings. Pump another sweep as above and again blow swab on pump. PWD Drilling All Circ Avg Diam md. Repair pump and continue to circulate sweep to surface with less than 10% increase in cuttings. Pump a third as above Circulate 1.7 times 1.7 times bottoms up. Circulate and condition mud over 6X BU. Torque dropped from 25K to 12K. Pull out of hole on elevators to 6481'. Tight Spot. Begin circulating and back reaming through, Continue to back ream at report time. Max @ ft Current R.O.P. (ft/hr) Gas (units)52 56 Depth 0' POOH R.Klepzig / J. Haberthur 235 Circ Flow In (gpm) Current Pump & Flow Data: 2335 4.2300 $160,697.95 748 177 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 7.8 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cleanout Run Gas (units) ml/30min Max:Ambient Air Pit Room 48 North Slope Daily Charges Avg 8.25 Pioneer ODSN-23i Oooguruk 23 06/11/2011-04:00 11986' Nabors 19AC $4,865.75 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT HDBS FXG65 11986'99.80 9.80 72.75 11.5 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) 10 H2S Data Sample Line Avg: 11986' 6086' C2C1 Sh 15 Sd Depth Max 6.0 Lst 5810' 800 900 Bull Nose 35 Sst C4 C5 24 Tuff Gas Breakdown Avg: 55 Average API Filt 9.70 135 C3 Colby Marks/Mark Lindloff LIH Ann Corr Cor Solids (lb/100ft2) 22,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks/Mark Lindloff LIH Ann Corr Cor Solids (lb/100ft2) 25,000 24 hr Max YP C3 API Filt 9.70 55 135 26 Tuff Gas Breakdown Avg: 55 Average Sst C4 C5 Sd Depth Max 6.5 Lst 5810' 800 900 Bull Nose 35 11986' 6086' C2C1 Sh 15 H2S Data Sample Line Avg: Chromatograph (ppm) 10 13.5 Silt Siltst ClystCht TFA Hours HDBS FXG65 11986' 11986' 11986' 129.95 9.95 43.19 0' 72.75 Nabors 19AC $4,865.75 AK-AM-0008100416 10.63 1.2701 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 24 06/12/2011-04:00 11986' North Slope Daily Charges Avg 8.25 Gas (units) ml/30min Max:Ambient Air Pit Room 72 Cleanout Run pH Chlorides GvlCoal Min Avg % 6.1 mg/l AvgMin Max Max 0 4.2300 $165,563.70 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Test BOP's R.Klepzig / J. Haberthur 246 Circ Flow In (gpm) Current Pump & Flow Data: Max @ ft Current R.O.P. (ft/hr) Gas (units)0 56 Depth md. comparable to that seen while drilling. Trip/pump out of the hole to surface and lay down Rhino reamer BHA and inspect same. Clear and clean rig floor and pick up drill collars. Change rams on BOP and inspect. Rig up and begin to test BOP's PWD Drilling All Circ Avg Diam return. Continue to trip out of the hole to 5638' and pull test reamer against casing shoe, 10K over. Pulling 90K over in casing with 100% swab. Pump out of the hole at 200 gpm, 600 psi. Cuttings return at shakers while pumping out of the hole were Continue to trip out of the hole 6394' to 5878' and circulate a high viscosity sweep with a 100% increase in cuttings . 110 bbl 11.89'' Max: Hole Condition On Bot Hrs 11986' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks/Mark Lindloff Liner run Ann Corr Cor Solids (lb/100ft2) 23,500 24 hr Max YP C3 API Filt 10.20 55 0 20 Tuff Gas Breakdown Avg: 55 Average Sst C4 C5 Sd Depth Max 6.2 Lst 0' 940 900 Bull Nose 35 0' 0' C2C1 Sh 0 H2S Data Sample Line Avg: Chromatograph (ppm) 10 14.5 Silt Siltst ClystCht TFA Hours 9 5/8" Liner 11986' 11986' 11986' 119.80 9.80 43.19 0' 0.00 Nabors 19AC $4,865.75 AK-AM-0008100416 9.625 0.0000 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 25 06/13/2011-04:00 11986' North Slope Daily Charges Avg 8.25 Gas (units) ml/30min Max:Ambient Air Pit Room 54 Cleanout Run pH Chlorides GvlCoal Min Avg % 5.7 mg/l AvgMin Max Max 620 4.2300 $170,429.45 42 10 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Running 9 %/* Liner R.Klepzig / J. Haberthur 0 Circ Flow In (gpm) Current Pump & Flow Data: Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 Depth md. Total losses down hole from Midnight to 4:00 AM -72 bbls. returns. Continue to run casing to . Total losses to the hole for Midnight -220 bbls. Finish running 9 5/8" Liner, -9 bbl displacement. Circulate 40 gpm, 48 bbl/hr loss. Total -53 bbl ( 1+ hours) Rig up hanger and begin RIH on 5" drill pipe to 6578'. 28 bbl return while rigging 9 5/8" hanger (1.5 hrs) Circulate at 42 GPM with 42 bbl/hr losses Total -47 bbls at report time. PWD Drilling All Circ Avg Diam Zero displacement. Reduce running speed from 3 to 6 minutes per stand without increase in displacement. At 5558' pump 1-2 bpm, 500-600psi with partial returns. At 5753' stage up pumps in 1/4 bbl increments to 7.5bbl/min, 500 psi and achieve 15-20% Total losses down hole for Midnight- Midnight -220 bbls Finish testing BOPE. Rig up to run 9 5/8" 40# L-80 casing. Rig up Tesco equipment. Run casing to 5753'. 110 bbl 11.89'' Max: Hole Condition On Bot Hrs 11986' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks/Mark Lindloff Liner run Ann Corr Cor Solids (lb/100ft2) 24,500 24 hr Max YP C3 API Filt 9.80 55 0 15 Tuff Gas Breakdown Avg: 55 Average Sst C4 C5 Sd Depth Max 6.4 Lst 0' 940 900 Bull Nose 35 0' 0' C2C1 Sh 0 H2S Data Sample Line Avg: Chromatograph (ppm) 10 14.0 Silt Siltst ClystCht TFA Hours 9 5/8" Liner 11986' 11986' 11986' 89.90 9.90 43.19 0' 0.00 Nabors 19AC $6,336.97 AK-AM-0008100416 9.625 0.0000 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 26 06/14/2011-04:00 11986' North Slope Daily Charges Avg 8.25 Gas (units) ml/30min Max:Ambient Air Pit Room 44 Cleanout Run pH Chlorides GvlCoal Min Avg % 7.7 mg/l AvgMin Max Max 453 4.2300 $176,766.42 173 41 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Dropping Ball R.Klepzig / J. Haberthur 1000 Circ Flow In (gpm) Current Pump & Flow Data: Max @ ft Current R.O.P. (ft/hr) Gas (units)189 460 Depth md. 12 midnight to 12 midnight -37 bbls No losses from AM to 6 AM the well. Circulate at 7829' with 60% returns. Continue to run into the hole with casing and tag up on fish at 11897'. Circulate with 100% returns at time of report. Total gains for this report - 33 bbls. Total losses while running casing = 187 bbls. Drop ball and currently it circulating to bottom at 4 bbls/hr. No gains or losses during circulation. PWD Drilling All Circ Avg Diam gain, monitor well for 50 minutes, well breathing, 140 bbl gain. Well gain decrease from 15bbl/5 min to 5 bbls/5min. Run casing 6687' to 7448' with correct displacement. 7448' to 7829' loosing 12 bbls, decrease running speed from 10 fpm to 3 fpm. Monitor Cont. to run casing, surging 30% returns 6497' to 6687'. Circulate and condition at 5bpm, with 100% returns. See pit 16 bbl 9.63'' Max: Hole Condition On Bot Hrs 11986' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Drop 3/4" ball and seat to set hanger. While circulating at 6 bpm hole packed off. Bullhead 34 bbls down IA 4 bpm, get 16 bbl 9.63'' Max: Hole Condition On Bot Hrs 11986' 27 bbls of returns. Bullhead 60 bbls, get back 30 bbls. Attempt to circulate at 1 bpm with 10% returns. RSC Pump. 10 bbls seawater, 60 bbl spacer, 113.5 bbls cement, 20 bbls seawater. Rig pump and latch up plug 15 bbls early. No returns to PWD Drilling All Circ Avg Diam md. 12 midnight to 12 midnight -836 bbls No losses from AM to 6 AM surface while pumping cement. Set liner top packer. Test liner. Rig down cement equipment. Trip out of hole and lay down. Pick up Rhino and bullnose assembly. Rig up to change rams at time of report Max @ ft Current R.O.P. (ft/hr) Gas (units)0 115 Depth 0' Picking up BHA R.Klepzig / J. Haberthur 418 Circ Flow In (gpm) Current Pump & Flow Data: 0 4.2300 $181,632.17 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 7.2 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Gas (units) ml/30min Max:Ambient Air Pit Room 45 North Slope Daily Charges Avg Pioneer ODSN-23i Oooguruk 27 06/15/2011-04:00 11986' Nabors 19AC $4,865.75 AK-AM-0008100416 9.625 0.0000 (ppb Eq)cP PV Size MBT 9 5/8" Liner 11986'109.85 9.85 0.00 8.0 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) 10 H2S Data Sample Line Avg: 11986' 0' C2C1 Sh 0 Sd Depth Max 6.5 Lst 11986' 940 35 Sst C4 C5 17 Tuff Gas Breakdown Avg: 55 Average API Filt 10.30 0 C3 Colby Marks/Mark Lindloff Liner run Ann Corr Cor Solids (lb/100ft2) 16,500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Nipple Up and Test BOPs. Psi Test 9 5/8" Packer to 3500psi. Pump 14bbls/ get back 13bbls. TIH / P/Up 5" DP. Ream 16 bbl 9.63'' Max: Hole Condition On Bot Hrs 11986' and Wash from 11671' to 11770'. Tag Float Collar @ 11770' md. WOB =20k. Drill Cmt. Circ and Cond fluid 2xB/Up @ 231spm At report time, Begin MADD Pass @ 300fph.Currently Mad Passing at report time, PWD Drilling All Circ Avg Diam md. 12 midnight to 12 midnight 0 bbls No losses from AM to 6 AM Max @ ft Current R.O.P. (ft/hr) Gas (units)0 6 Depth 0' Mad Passing R.Klepzig / J. Cortez 16 Circ Flow In (gpm) Current Pump & Flow Data: 0 4.2300 $186,497.92 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 6.3 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Mad Pass Gas (units) ml/30min Max:Ambient Air Pit Room 43 North Slope Daily Charges Avg 8.5 Pioneer ODSN-23i Oooguruk 27 06/16/2011-04:00 11986' Nabors 19AC $4,865.75 AK-AM-0008100416 9.625 0.0000 (ppb Eq)cP PV Size MBT 9 5/8" Liner 11986' 11986' 11986' 69.85 9.85 0' 0.00 10.0 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) 10 H2S Data Sample Line Avg: 11986' 0' C2C1 Sh 0.00 0 Sd Depth Max 6.4 Lst 11986' 940 1000 Tricone Bit 35 Sst C4 C5 18 Tuff Gas Breakdown Avg: 55 Average API Filt 11.10 0 0 C3 Colby Marks/Mark Lindloff Liner run Ann Corr Cor Solids (lb/100ft2) 15,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Finish MADD Pass. POOH. Wait on orders from town re:BAT Sonic results.Pick up whipstock / milling BHA. 16 bbl 9.63'' Max: Hole Condition On Bot Hrs 11986' RIH to 3018' @ report time. PWD Drilling All Circ Avg Diam md. 12 midnight to 12 midnight 0 bbls No losses from AM to 6 AM Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 Depth 0' RIH R.Klepzig / J. Cortez 0 Circ Flow In (gpm) Current Pump & Flow Data: 0 4.2300 $191,363.67 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 6.7 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Gas (units) ml/30min Max:Ambient Air Pit Room 43 North Slope Daily Charges Avg 8.5 Pioneer ODSN-23i Oooguruk 29 06/17/2011-04:00 11986' Nabors 19AC $4,865.75 AK-AM-0008100416 8.5 (ppb Eq)cP PV Size MBT Tricone Bit 11986' 11986' 89.85 9.85 0' 11.3 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) 10 H2S Data Sample Line Avg: 11986' 0' C2C1 Sh 0.00 0.00 Sd Depth Max 5.2 Lst 11986' 1000 1100 MillTooth 35 Sst C4 C5 19 Tuff Gas Breakdown Avg: 55 Average API Filt 10.90 0 0 C3 Colby Marks/Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 13,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air TIH to 5588'. Pump Lube pill out of DP. TIH to 8538'. Pump another Lube pill out of DP. TIH to 11770'. Orient , 16 bbl 9.63'' Max: Hole Condition On Bot Hrs 11706'0.22 set, and anchor whip stock. Shear out w/ milling assembly. Tag top of WS. Circ and Cond mud pump a lube pill. Drilling / Milling window. Pump hi vis sweep. 50% cuttings increase at shakers. Circ 4x B/Up. Perform FIT to 14ppg EMW. Pump 16bbls/ Rec 15bbls.'. PWD Drilling All Circ Avg Diam md. 12 midnight to 12 midnight 0 bbls No losses from AM to 6 AM POOH to 5800' @ report time. TOW 11658' BOW 11675. Samples very contaminated with mud lube products very thick and gooey. Observed very fine sand to silty clay. Gas remained minimal 10-40 units while milling window and drilling 30 ft of formation. 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 15 11691' Depth 31' POOH R.Klepzig / J. Cortez 40 Circ Flow In (gpm) Current Pump & Flow Data: 2107 4.2300 $197,700.64 885 250 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 6.4 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Gas (units) ml/30min Max:Ambient Air Pit Room 40 North Slope Daily Charges Avg 8.5 283.0 551 Pioneer ODSN-23i Oooguruk 30 06/18/2011-04:00 11706' Nabors 19AC $6,336.97 AK-AM-0008100416 8.5 (ppb Eq)cP PV Size MBT Tricone Bit 11986' 11675' 11706' 119.80 9.80 31' 8.0 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: 11986' 0' C2C1 Sh 1.90 0.00 Sd Depth Max 6.8 Lst 11986' 1000 1100 MillTooth 50 Sst C4 C5 20 Tuff Gas Breakdown Avg: 50 Average API Filt 10.10 27 0 C3 Colby Marks/Mark Lindloff Start ADT Charges today Ann Corr Cor Solids (lb/100ft2) 14,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks/Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 13,000 24 hr Max YP C3 API Filt 10.20 27 0 19 Tuff Gas Breakdown Avg: 50 Average Sst C4 C5 Sd Depth Max 5.8 Lst 11986' 1000 1100 MillTooth 50 11986' 0' C2C1 Sh 1.90 0.00 H2S Data Sample Line Avg: Chromatograph (ppm) 10.0 Silt Siltst ClystCht TFA Hours Tricone Bit 11986' 11675' 11706' 99.80 9.80 31' Nabors 19AC $6,336.97 AK-AM-0008100416 8.5 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 31 06/19/2011-04:00 11706' North Slope Daily Charges Avg 8.5 Gas (units) ml/30min Max:Ambient Air Pit Room 43 pH Chlorides GvlCoal Min Avg % 6.5 mg/l AvgMin Max Max 4.2300 $204,037.61Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' POOH R.Klepzig / J. Cortez Circ Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 Depth md. 12 midnight to 12 midnight 0 bbls No losses from AM to 6 AM PWD Drilling All Circ Avg Diam incorrect X/O. Service Rig. Slip & Cut drill line. TIH w/ Baker fishing assembly per Baker Rep. TIH to 11658'. Circ and Cond. Wash over Fish to 11723'. Slack off / Rotate. Repeat, in attempt to catch Fish. Currently POOH, 4147' at report time. Continue to POOH to surface. Function test BOPs. Attempt to torque up Johnny Whacker. Dropped in hole due to 16 bbl 9.63'' Max: Hole Condition On Bot Hrs 11706'0.22 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air TIH to 11658'. Ream and wash to 11723'. R/Up Cmt head. Circ and cond fluid. Hold pre job safety mtg for cement 16 bbl 9.63'' Max: Hole Condition On Bot Hrs 11723'0.1 squeeze. Test cmt lines. Perform cement job/squeeze as per Well Plan. Currently POOH at report time. PWD Drilling All Circ Avg Diam md. 12 midnight to 12 midnight 0 bbls No losses from AM to 6 AM 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)6 8 11719' Depth 17' POOH R.Klepzig / J. Cortez 44 Circ Flow In (gpm) Current Pump & Flow Data: 0 4.2300 $210,374.58 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 6.7 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Gas (units) ml/30min Max:Ambient Air Pit Room 40 North Slope Daily Charges Avg 8.5 264.0 487 Pioneer ODSN-23i Oooguruk 32 06/20/2011-04:00 11706' Nabors 19AC $6,336.97 AK-AM-0008100416 8.5 (ppb Eq)cP PV Size MBT Tricone Bit 11986' 11675' 11706' 89.85 9.85 31' 13.5 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: 11986' 0' C2C1 Sh 1.90 0.00 Sd Depth Max 5.0 Lst 11986' 1000 1100 MillTooth 50 Sst C4 C5 19 Tuff Gas Breakdown Avg: 50 Average API Filt 8.90 27 0 C3 Colby Marks/Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 12,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks/Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 13,000 24 hr Max YP C3 API Filt 9.90 27 19 Tuff Gas Breakdown Avg: 85 Average Sst C4 C5 Sd Depth Max 3.3 Lst 11706' 1300 1100 MillTooth C2C1 Sh 1.90 H2S Data Sample Line Avg: 15 Chromatograph (ppm) 8.0 Silt Siltst ClystCht TFA Hours FDB/FDB4914 11986' 11675' 11706' 119.85 9.85 31' Nabors 19AC $6,336.97 AK-AM-0008100416 8.5 0.8650 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 33 06/21/2011-04:00 11757' North Slope Daily Charges Avg 8.5 40.0 343 Gas (units) ml/30min Max:Ambient Air Pit Room 43 Cmnt pH Chlorides GvlCoal Min Avg % 6.7 mg/l AvgMin Max Max 2440 4.2300 $216,711.55 565 158 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 51' Time Drilling R.Klepzig / J. Cortez 29 11712' Flow In (gpm) Current Pump & Flow Data: 3.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)10 16 11707' Depth md. 12 midnight to 12 midnight 0 bbls No losses from AM to 6 AM PWD Drilling All Circ Avg Diam 11710'. Tag cement. Pull to 11690'. Ream / wash/ trough to 11723'. Time drilling to 11757' @ report time. Gas remains low Averaging 10-15 units, Samples 11753' remain 80-90% cement with trace of formation. POOH. P/Up BHA. TIH to 11675'. No cement tagged. Pull to 11625'. Circ B/Up. No cement seen @ shakers. TIH to 16 bbl 8.50'' Max: Hole Condition On Bot Hrs 11757'6.85 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Time drill 3' per hr to 11760'. Rotary drill to 11786'. Service Top Drive. Rotary drill to 12077' . Circ 5x OH volume. TOH to. 16 bbl 8.50'' Max: Hole Condition On Bot Hrs 12077'18.79 11601'. Circ 3 x B/Up. POOH to 1260' @ report time Gas remains minimal during slow drill rates. Samples predominately siltstone grading to shale. Lt gray to gray. Sub blocky to blocky. PWD Drilling All Circ Avg Diam md. 12 midnight to 12 midnight 0 bbls No losses from AM to 6 AM Very Calcareous. Sandstone seen in the form of loose quartz in samples, Cement slowly diminishing as we drill further. 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 30 11984' Depth 320' POOH R.Klepzig / J. Cortez 62 12073' Flow In (gpm) Current Pump & Flow Data: 0 4.2300 $223,048.52 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 6.5 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmnt Gas (units) ml/30min Max:Ambient Air Pit Room 45 North Slope Daily Charges Avg 8.5 58.0 245 Pioneer ODSN-23i Oooguruk 34 06/22/2011-04:00 12077' Nabors 19AC $6,336.97 AK-AM-0008100416 8.5 0.8650 (ppb Eq)cP PV Size MBT FDB/FDB4914 12077' 11675' 11706' 179.80 9.80 31' 18.79 8.0 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: 15 C2C1 Sh 1.90 Sd Depth Max 4.6 Lst 11706' 1300 1100 MillTooth Sst C4 C5 25 Tuff Gas Breakdown Avg: 85 Average API Filt 9.50 27 C3 Colby Marks/Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 13,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks/Mark Lindloff 1-1-NO-A-E-I-NO-BHA Ann Corr Cor Solids (lb/100ft2) 13,000 24 hr Max YP C3 API Filt 10.40 99 27 Tuff Gas Breakdown Avg: 30 10 Average Sst C4 C5 Sd Depth Max 4.5 Lst 11706' 1300 1400 HDBS/FXG46Ds 40 12077' 371' C2C1 Sh 13.00 H2S Data Sample Line Avg: 10 Chromatograph (ppm) 8.0 Silt Siltst ClystCht TFA Hours FDB/FDB4914 12077' 12077' 189.80 9.80 18.79 Nabors 19AC $6,336.97 AK-AM-0008100416 8.5 0.8650 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 35 06/23/2011-04:00 12089' North Slope Daily Charges Avg 8.5 0.9687 60.7 78 Gas (units) ml/30min Max:Ambient Air Pit Room 47 Cmnt 12.98 pH Chlorides GvlCoal 12.98 Min 11.39 Avg % 13.07 6.6 mg/l 13.01 AvgMin Max Max 3388 4.2300 $229,385.49 650 180 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 12' Drilling J. Polya / J. Cortez 55 Cir Flow In (gpm) Current Pump & Flow Data: 13.07 46.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)55 12 12092' Depth md. 12 midnight to 12 midnight 0 bbls No losses from AM to 6 AM PWD Drilling All Circ Avg Diam w/ BHA. Shallow test MWD. TIH to 11570. Test Geo Pilot/ MWD. Circ and Cond w/ LCM 6sks / hr during circ. Service Top Drive. Slip & cut drill line install RCD Bearing, Drop ball to open Reamer. TOH to surface. Service Top drive. Test BOPs. TIH. P/Up MPD trip nipple. Install RCD test flange. Test MPD lines. TIH 19 bbl 8.50'' Max: Hole Condition On Bot Hrs 12089'0.28 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 563 Verify reamer open by P/Up and shut rotary off. Take 5k at 12064'. Drill to 12903'. Pump Sweep. (10% inc at shakers). 30 bbl 9.61'' Max: Hole Condition On Bot Hrs 13168'0.28 Service Top Drive. At 13102', Pump Sweep began to see good returns when RCD Bearing Failled, Change out Bearing at report. time Drill to 13169', PWD Drilling All Circ Avg Diam md. 12 midnight to 12 midnight No losses No losses from AM to 6 AM Gas increased throughout the day, Reached highest levels for the day when in the HRZ (563 Units) Samples in the HRZ 90% Shale gray to dark gray, gray/brown in places, Predominately flakey, fissile, angular to sub angular. 36.2 Max @ ft Current R.O.P. (ft/hr) Gas (units)226 181 12718' Depth 1079' Change out bearing J. Polya / J. Cortez 563 13094' Flow In (gpm) Current Pump & Flow Data: 13.33 4014 4.2300 $235,722.46 677 191 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 13.33 8.3 mg/l 13.01 AvgMin Max Max12.78 pH Chlorides GvlCoal 12.36 Min 13.00 Avg Cmnt Gas (units) ml/30min Max:Ambient Air Pit Room 49 North Slope 13126 Daily Charges Avg 8.5 0.9687 61.6 198 Pioneer ODSN-23i Oooguruk 36 06/24/2011-04:00 13168' Nabors 19AC $6,336.97 AK-AM-0008100416 8.5 0.8650 (ppb Eq)cP PV Size MBT FDB/FDB4914 12874' 12077' 1710.20 10.20 18.79 10.0 Silt Siltst ClystCht TFA Hours 55297 Chromatograph (ppm) H2S Data Sample Line Avg: 5 3237 1369 12077' 371' C2C1 Sh 13.00 Sd Depth Max 4.6 Lst 11706' 1300 1400 HDBS/FXG46Ds 10 Sst 190 C4 C5 F 690 28 Tuff Gas Breakdown 12676 Avg: 85 325 0 Average API Filt 9.90 99 C3 Colby Marks/Mark Lindloff 1-1-NO-A-E-I-NO-BHA Ann Corr Cor Solids (lb/100ft2) 14,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks/Mark Lindloff 1-1-NO-A-E-I-NO-BHA Ann Corr Cor Solids (lb/100ft2) 6,000 24 hr Max YP C3 API Filt 9.50 99 24 Tuff Gas Breakdown Avg: 85 Average Sst C4 C5 Sd Depth Max 4.6 Lst 11706' 1300 1400 HDBS/FXG46Ds 12077' 371' 15 C2C1 Sh 13.00 H2S Data Sample Line Avg: Chromatograph (ppm) 6.5 Silt Siltst ClystCht TFA Hours FDB/FDB4914 12874' 12077' 1110.20 10.20 18.79 Nabors 19AC $6,336.97 AK-AM-0008100416 8.5 0.8650 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 37 06/25/2011-04:00 13760' North Slope Daily Charges Avg 8.5 0.9687 77.0 193 Gas (units) ml/30min Max:Ambient Air Pit Room 49 Cmnt 12.43 pH Chlorides GvlCoal 12.43 Min 12.98 Avg % 13.26 8.4 mg/l 13.00 AvgMin Max Max 0 4.2300 $242,059.43 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 592' Change Saver Sup J. Polya / J. Cortez 263 13094' Flow In (gpm) Current Pump & Flow Data: 13.31 Max @ ft Current R.O.P. (ft/hr) Gas (units)29 157 12718' Depth md. Samples remain 85-90% shale. Mostly gray/brown, some gray, angular, fissile, 10-15% claystone: white, light green, light gray to gray, earthy, some waxy, platy, some blocky. 12 midnight to 12 midnight -1079 bbls downhole, No losses from 12 midnight to 6 AM Observe 1.5hr. Stage pumps /step rt loss test. Losses 120 to 60 bph. Drill to 13570'. Losses reduce 20bph to 5 bph. Drill to 13760' working on saver sub.at report time. No losses.as of 04:00 AM. Gas averaged 140 units for the day. No peaks of high gas. PWD Drilling All Circ Avg Diam Pump LCM pill. Stage pumps Circ / Cond/ Build mud. Spot 60bbl FW pill/ 10bbl LCM pill. Squeeze pill 1k psi to 1300psi /5bbl mud. Hold 13.0ppg EMW w/ MPD. Wait on squeeze. Losses 40/50bph. Lower MPD to 12.9ppg EMW. Continue to change RCD bearing. Drill to 13208'. Start losing 250bph @ 13178'. TOH to 13152'. Static loss at 42bph. 34 bbl 9.80'' Max: Hole Condition On Bot Hrs 13168'28.79 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Finish repairing Saver sub. Continue drilling ahead till TD (14091' md, 6178.26' TVD), Circulate. Short trip to. 34 bbl 9.80'' Max: Hole Condition On Bot Hrs 14091'33.46 No losses from 12 midnight to 6 AM shoe. No losses. Run back in hole, first 15 stnds no returns. Eased off on MPD and started seeing displacement. 40 bbl loss during trip in. Run to bottom and start circulating. 1460 units of Trip Gas. Currently displacing to 13.00 ppg MW PWD Drilling All Circ Avg Diam md. Samples Transitioned from 85-90% Shale to 80% Sandstone when drilling into the Nuiqsut Sandstone clear to frosty in places, very fine -fine grain, round to well rounded, sub angular in places. Moderately sorted, loosely consolidated, trace of fluoresence Average Gas while drilling 196 units, Max Gas 574 units Average gas while circulating 116 units, Max Gas 1460 units 12 midnight to 12 midnight -39 bbls downhole, Max @ ft Current R.O.P. (ft/hr) Gas (units)91 118 13997' Depth 331' Swapping Mud to 13 ppg J. Polya / J. Cortez 1460 Cir Flow In (gpm) Current Pump & Flow Data: 13.28 1646 4.2300 $248,396.40 363 111 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 13.20 8.4 mg/l 13.00 AvgMin Max Max12.77 pH Chlorides GvlCoal 12.76 Min 13.01 Avg Cmnt Gas (units) ml/30min Max:Ambient Air Pit Room 49 North Slope Daily Charges Avg 8.5 0.9687 77.0 168 Pioneer ODSN-23i Oooguruk 38 06/26/2011-04:00 13760' Nabors 19AC $6,336.97 AK-AM-0008100416 8.5 0.8650 (ppb Eq)cP PV Size MBT FDB/FDB4914 14092' 12077' 1113.10 13.10 18.79 6.5 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: 90 12077' 371' C2C1 Sh 13.00 Sd Depth Max 4.6 Lst 11706' 1300 1400 HDBS/FXG46Ds 5 Sst C4 C5 24 Tuff Gas Breakdown Avg: 5 Average API Filt 9.50 99 C3 Colby Marks/Mark Lindloff 1-1-NO-A-E-I-NO-BHA Ann Corr Cor Solids (lb/100ft2) 6,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks/Mark Lindloff 1-1-NO-A-E-I-NO-BHA Ann Corr Cor Solids (lb/100ft2) 7,300 24 hr Max YP C3 API Filt 9.80 99 99 25 Tuff Gas Breakdown Avg: 5 Average Sst C4 C5 Sd Depth Max 4.6 Lst 11706' 1300 1400 HDBS/FXG46Ds 5 12077' 371' C2C1 Sh 31.00 13.00 H2S Data Sample Line Avg: 90 Chromatograph (ppm) 2.5 Silt Siltst ClystCht TFA Hours FDB/FDB4914 14092' 12077' 14092' 1412.95 12.95 33.46 2015' 18.79 Nabors 19AC $6,336.97 AK-AM-0008100416 8.5 0.8650 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 39 06/27/2011-04:00 13760' North Slope Daily Charges Avg 8.5 0.9687 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 44 1-1-ER-C-X-I-NO-TD Cmnt pH Chlorides GvlCoal Min Avg % 19.3 mg/l AvgMin Max Max 0 4.2300 $256,100.29 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Running Liner J. Polya / J. Cortez 244 Cir Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 19 0' Depth md. 12 midnight to 12 midnight -20 bbls downhole, PWD Drilling All Circ Avg Diam No losses from 12 midnight to 6 AM Service TDrv. TOH / PmpOOH to 9570', loss of 20 bbls Repair Iron Rneck. TOH from 9570' to 5572' on elevators. Hole taking correct fill. Spot pill @ 5572'. Pump slug. POOH to BHA, lay down BHA, Start rigging up tp Run 7" Liner. Continue to displace to 13.0ppg. TOH / Pump OOH to 11595'. Remove RCD. Cont to pump OOH to 10046'. 34 bbl 9.80'' Max: Hole Condition On Bot Hrs 14091'33.46 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air Run 7" liner and 5" Drill Pipe to bottom. 34 bbl 9.80'' Max: Hole Condition On Bot Hrs 14091'33.46 12 midnight to 6 AM 53.27 bbls. PWD Drilling All Circ Avg Diam md. 12 midnight to 12 midnight -30 bbls. 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth 0' Running Liner J. Polya / J. Cortez 0 Cir Flow In (gpm) Current Pump & Flow Data: 730 4.2300 $261,701.64 19 6 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 18.2 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg 1-1-ER-C-X-I-NO-TD Cmnt Gas (units) ml/30min Max:Ambient Air Pit Room 43 North Slope Daily Charges Avg 8.5 0.9687 0.0 0 Pioneer ODSN-23i Oooguruk 40 06/28/2011-04:00 14092' Nabors 19AC $5,601.35 AK-AM-0008100416 7 (ppb Eq)cP PV Size MBT Liner 14092' 12077' 14092' 1512.20 12.20 33.46 2015' 3.0 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: 90 14091' 0' C2C1 Sh 31.00 0.00 Sd Depth Max 5.0 Lst 14091' 1440 1400 HDBS/FXG46Ds 5 Sst C4 C5 28 Tuff Gas Breakdown Avg: 5 Average API Filt 8.80 99 0 C3 Colby Marks/Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 6,500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks/Mark Lindloff Ann Corr Cor Solids (lb/100ft2) 4,000 24 hr Max YP C3 API Filt 10.00 99 0 12 Tuff Gas Breakdown Avg: 5 Average Sst C4 C5 Sd Depth Max 6.0 Lst 14091' 1440 1400 HDBS/FXG46Ds 5 14091' 0' C2C1 Sh 31.00 0.00 H2S Data Sample Line Avg: 90 Chromatograph (ppm) 1.0 Silt Siltst ClystCht TFA Hours Liner 14092' 12077' 14092' 4310.30 10.30 33.46 2015' Nabors 19AC $5,601.35 AK-AM-0008100416 7 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 41 06/29/2011-04:00 14092' North Slope Daily Charges Avg 8.5 0.9687 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 43 1-1-ER-C-X-I-NO-TD Cmnt pH Chlorides GvlCoal Min Avg % 8.9 mg/l AvgMin Max Max 0 4.2300 $267,302.99 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' POH & L/D 5" DP J. Polya / J. Cortez 866 TG Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 42 0' Depth md. Circ hanger ball on seat. Cir till. 10.3 ppg in / out. 866 units of Trip Gas seen at bottoms up. Pre job for cmt. Line. Pump cmt per Halliburton. BMP plug w/ 3061 stks. / 10.3 ppg. Release hgr. Circ and condition fluid to 10.25 ppg. Begin POOH and laying down 5" Drillpipe. Getting correct displacements. 12 midnight to 12 midnight -400 bbls. PWD Drilling All Circ Avg Diam 12 midnight to 6 AM 0 bbls. Stage pmps. Partial returns, then returns diminished. No returns. Attempt P/Up Liner. Wouldn't break over. Circ /lost returns. Perform LOT. Attempt circ. 20% returns. Bullhead 360bbls 10.3 ppg down annulus. Hold 600 psi. Pmps off. Install Cmt lines. WTF drop ball. Stage Pumps w/ 13ppg LSND. Partial returns. TIH to 11620'. R/U Cmt head. Stg pumps. Partial returns. TIH to 14080'. 34 bbl 9.80'' Max: Hole Condition On Bot Hrs 14091'33.46 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air trip out of the hole laying down drill pipe. Lay down liner setting assembly. Clean and clear the rig floor. 20 bbls 6.28'' Max: Hole Condition On Bot Hrs 14091' 12 midnight to 6 AM 0 bbls. Service the top drive. Change out rams.Service rig, Currently testing BOP's PWD Drilling All Circ Avg Diam md. 12 midnight to 12 midnight -7 bbls. 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 71 0' Depth 0' Testing BOP's J. Polya / J. Haberthur 262 Cir Flow In (gpm) Current Pump & Flow Data: 0 4.2300 $268,490.68 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 8.1 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmnt Gas (units) ml/30min Max:Ambient Air Pit Room 44 North Slope Daily Charges Avg 0.0 0 Pioneer ODSN-23i Oooguruk 42 06/30/2011-04:00 14092' Nabors 19AC $4,130.13 AK-AM-0008100416 8.5 0.9687 (ppb Eq)cP PV Size MBT HDBS/FXG46Ds 14092'4410.25 10.25 33.46 1.0 Silt Siltst ClystCht TFA Hours Chromatograph (ppm) H2S Data Sample Line Avg: 90 14092' 2015' C2C1 Sh 31.00 Sd Depth Max 6.5 Lst 12077' 1400 5 Sst C4 C5 13 Tuff Gas Breakdown Avg: 5 Average API Filt 9.30 99 C3 Colby Marks/Mark Lindloff 1-1-ER-C-X-I-NO-TD Ann Corr Cor Solids (lb/100ft2) 4,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirColby Marks/Mark Lindloff 1-1-ER-C-X-I-NO-TD Ann Corr Cor Solids (lb/100ft2) 4,000 24 hr Max YP 78 99 C3 10 Tuff Gas Breakdown Avg: 5 Average Sst C4 C5 Sd Depth Max 6.5 Lst 12077' 1400 1460 Mill & Casing Scraper BHA 5 14092' 2015' C2C1 Sh 31.00 H2S Data Sample Line Avg: 90 Chromatograph (ppm) 1.0 Silt Siltst ClystCht TFA Hours HDBS/FXG46Ds 14092' 14092' 14092' 4410.00 10.00 33.46 Nabors 19AC $4,130.13 AK-AM-0008100416 8.5 0.9687 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 43 07/01/2011-04:00 14092' North Slope Daily Charges Avg 8.375 9.0000 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 44 Cmnt pH Chlorides GvlCoal Min Avg 7.1 mg/l AvgMin Max Max API Filt 10.90 0 4.2300 $272,620.81 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' POOH J. Polya / J. Haberthur 15 Cir Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 5 0' Depth md 12 midnight to 12 midnight 0 bbls. 12 midnight to 6 AM 0 bbls. 6 bpm, 950 psi to insure drillpipe is clear. Continue to trip into the hole to 11485' and dress PBR with polish tool. Pump three times bottoms up and condition mud to 10.0 ppg in and out. Pressure test casing to 3500 psi/30 minutes. Pump dry job and POOH. PWD Drilling All Circ Avg Diam % Continue to trip into the hole with casing scraper BHA to 9797'. Circulate and condition drill pipe volume, 20 bbls 6.28'' Max: Hole Condition On Bot Hrs 14091' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.28'' Max: Hole Condition On Bot Hrs 14091'PWD Drilling All Circ Avg Diam 12 midnight to 6 AM 0 bbls. run 7" casing with Tesco at 7067', filling every 10 joints at time of report. Continue POOH. Displacement good. Lay down Mill/scraper BHA. Change rams and test BOPE. Rig up and 20 bbls md 12 midnight to 12 midnight 0 bbls. 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth 0' RIH 7" Casing J. Polya / J. Haberthur 0 Cir Flow In (gpm) Current Pump & Flow Data: 0 4.2300 $276,750.94 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 7.1 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmnt ml/30min Max:Ambient Air Pit Room North Slope Daily Charges Avg 8.375 9.0000 0.0 0 Pioneer ODSN-23i Oooguruk 44 07/02/2011-04:00 14092' Nabors 19AC $4,130.13 AK-AM-0008100416 8.5 0.9687 (ppb Eq)cP PV Size MBT HDBS/FXG46Ds 14092' 14092' 14092' 4510.00 10.00 33.46 1.0 Silt Siltst ClystCht TFA Hours 45 90 Chromatograph (ppm) H2S Data Sample Line Avg: Gas (units) 14092' 2015' C2C1 Sh 31.00 Sd Depth Max 9.8 Lst 12077' 1400 1460 Mill & Casing Scraper BHA 5 C4 C5 Tuff Gas Breakdown Avg: 5 Average Sst C3 API Filt 10.90 78 99 11 Colby Marks/Mark Lindloff 1-1-ER-C-X-I-NO-TD Ann Corr Cor Solids (lb/100ft2) 4,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirMark Lindloff/ David Mckechnie 1-1-ER-C-X-I-NO-TD Ann Corr Cor Solids (lb/100ft2) 4,000 24 hr Max YP 99 C3 25 Tuff Gas Breakdown Avg: 5 Average Sst C4 C5 Sd Depth Max 5.8 Lst 12077' 1400 1470 Running 7" Casing 5 14092' 2015' C2C1 Sh 31.00 H2S Data Sample Line Avg: 90 Chromatograph (ppm) 1.0 Silt Siltst ClystCht TFA Hours HDBS/FXG46Ds 14092'109,8 9.80 33.46 Nabors 19AC $4,130.13 AK-AM-0008100416 8.5 0.9687 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 45 07/03/2011-04:00 14092' North Slope Daily Charges Avg 7 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 46 Cmnt pH Chlorides GvlCoal Min Avg 7.1 mg/l AvgMin Max Max API Filt 4500.00 0 4.2300 $280,881.07 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Testing 7" Rams J. Polya / J. Haberthur 13 Cir Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 1 0' Depth md Halliburton Cementers. Rigging down cement equipment. Drained BOP stack. Install and test 7" pack off. Change out IBOP and saver sub. Currently getting ready to test 7" Rams. 12 midnight to 12 midnight 0 bbls. 12 midnight to 6 AM 0 bbls. and land hanger into polished bore. Rig up cementing equipment and pressure test cement lines. Circulate and condition mud from 10 ppg to 9.8 ppg in and out. Repair rig pump. Very little gas seen at bottoms up, 13 units. Pump cement according to PWD Drilling All Circ Avg Diam % Continue to run in hole with 7" casing to 11335'. No gains or losses during trip in .Lay down Tesco equipment. Make up 20 bbls 6.28'' Max: Hole Condition On Bot Hrs 14091' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.28'' Max: Hole Condition On Bot Hrs 14091'PWD Drilling All Circ Avg Diam 12 midnight to 6 AM 0 bbls. Circulate well 1.5 times drill pipe volume and increase mud weight to 10.2. Gas minimal during circulation, averaging 4 units with. bottoms up 236 units.Slip and cut drilling line. Currently racking back 4" DP Change rams on BOPE and test. Run into hole with 4" drill pipe to 9157' with no gains or losses during displacement. 20 bbls md 12 midnight to 12 midnight 0 bbls. 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 4 0' Depth 0' Testing Blocks and Top Drive J. Polya / J. Haberthur 236 Cir Flow In (gpm) Current Pump & Flow Data: 0 4.2300 $285,011.20 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 8.6 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmnt ml/30min Max:Ambient Air Pit Room North Slope Daily Charges Avg 0.0 0 Pioneer ODSN-23i Oooguruk 46 07/04/2011-04:00 14092' Nabors 19AC $4,130.13 AK-AM-0008100416 8.5 0.9687 (ppb Eq)cP PV Size MBT HDBS/FXG46Ds 14092'1210.20 10.20 33.46 1.0 Silt Siltst ClystCht TFA Hours 46 90 Chromatograph (ppm) H2S Data Sample Line Avg: Gas (units) 14092' 2015' C2C1 Sh 31.00 Sd Depth Max 6.5 Lst 12077' 1400 5 C4 C5 Tuff Gas Breakdown Avg: 5 Average Sst C3 API Filt 9.00 99 18 Mark Lindloff/ David Mckechnie 1-1-ER-C-X-I-NO-TD Ann Corr Cor Solids (lb/100ft2) 4,500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirMark Lindloff/ David Mckechnie ADT Engineer charges start today. 1-1-ER-C-X-I-NO-TD Ann Corr Cor Solids (lb/100ft2) 4,000 24 hr Max YP 99 C3 25 Tuff Gas Breakdown Avg: 5 Average Sst C4 C5 Sd Depth Max 6.5 Lst 12077' 1400 1500 Mill tooth 5 14091' 2015' C2C1 Sh 31.00 H2S Data Sample Line Avg: 90 Chromatograph (ppm) 1.0 Silt Siltst ClystCht TFA Hours HDBS/FXG46Ds 14092' 14091' 1010.00 10.00 33.46 Nabors 19AC $5,601.35 AK-AM-0008100416 8.5 0.9687 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 47 07/05/2011-04:00 14092' North Slope Daily Charges Avg 6.125 0.9204 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 45 Cmnt pH Chlorides GvlCoal Min Avg 7.6 mg/l AvgMin Max Max API Filt 9.40 0 4.2300 $290,612.55 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' RIH J. Polya / J. Haberthur 0 Cir Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 0' Depth md wear ring. Pick up 61/4" BHA and RIH to 3415, Filling pipe every 30 stands. 12 midnight to 12 midnight 0 bbls. 12 midnight to 6 AM 0 bbls. Remove wear bushing, suck out stack and pull wear ring. Make up packoff running tool and suck out stack and bell nipple to insure no WBM gets into annulus. Nipple down BOPE. Prepare cellar and wellhead. Pick up tools and nipple up BOPE. Test BOPE. Install PWD Drilling All Circ Avg Diam % Slip and cut drilling line. Fire/Evacuation Drill.Trip out of the hole 9157' to surface. Pick up BHA. Pump 10X pipe-volume, 20 bbls 6.28'' Max: Hole Condition On Bot Hrs 14091' Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 196 6.13'' Max: Hole Condition On Bot Hrs 14091'0.7 PWD Drilling All Circ Avg Diam 12 midnight to 6 AM 0 bbls. seen at shakers with bottoms up strokes at 11403' . Wash and ream 11422' to 13997'. Circulate and condition mud. Pressure test casing to 3500 psi. Wash and ream to 14092'. Drill to 14112'. Perform FIT test to 12,5 ppg EMW, Drill cement stringers 11197' to 11250'. Drill cement 11250' to 11403'. 275 gpm, 100 rpm, torque 13-15K. Plug/rubber 30 bbls md Before drilling 5-10 units was seen on average, while drilling new formation gas fluctuated from 126 to 196 units Sample was predominately cement and sandstone. Good show of sand in sample with good pale yellow fluorescence and good pale yellow cut. 12 midnight to 12 midnight 0 bbls. 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)13 127 1498' Depth 0' Mad Pass J. Polya / J. Haberthur 196 14112' Flow In (gpm) Current Pump & Flow Data: 720 4.2300 $296,213.90 33 39 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 8.1 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmnt ml/30min Max:Ambient Air Pit Room North Slope 14112 Daily Charges Avg 6.125 0.9204 58.0 269 Pioneer ODSN-23i Oooguruk 48 07/06/2011-04:00 14092' Nabors 19AC $5,601.35 AK-AM-0008100416 8.5 0.9687 (ppb Eq)cP PV Size MBT HDBS/FXG46Ds 14102' 14091' 14112' 1210.20 10.20 0.70 21' 33.46 1.0 Silt Siltst ClystCht TFA Hours 45 50 17820 Chromatograph (ppm) H2S Data Sample Line Avg: Gas (units) 558 14091' 2015' C2C1 Sh 16.00 31.00 Sd Depth Max 7.0 Lst 12077' 1400 1500 Mill tooth 125 C4 C5 GP302 Tuff Gas Breakdown 14092 Avg: 127 50 Average Sst C3 API Filt 10.50 71 99 32 1148 Mark Lindloff/ David Mckechnie 1-1-ER-C-X-I-NO-TD Ann Corr Cor Solids (lb/100ft2) 4,000 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirMark Lindloff/ David Mckechnie 1-1-ER-C-X-I-NO-TD Ann Corr Cor Solids (lb/100ft2) 8 24 hr Max YP 70 99 C3 35 Tuff Gas Breakdown Avg: 50 Average Sst C4 C5 Sd Depth Max 14.0 Lst 12077' 1400 1500 Mill tooth 14091' 2015' C2C1 Sh 20.00 31.00 H2S Data Sample Line Avg: 50 Chromatograph (ppm) 1.0 Silt Siltst ClystCht TFA Hours HDBS/FXG46Ds 14112' 14091' 14112' 1010.20 10.20 0.82 21' 33.46 Nabors 19AC $5,601.35 AK-AM-0008100416 8.5 0.9687 (ppb Eq)cP PV Size MBT Pioneer ODSN-23i Oooguruk 49 07/07/2011-04:00 14112' North Slope Daily Charges Avg 6.125 0.9204 0.0 0 Gas (units) ml/30min Max:Ambient Air Pit Room 45 2-2-WT-A-E-I-ER-BHA Cmnt pH Chlorides GvlCoal Min Avg 8.1 mg/l AvgMin Max Max API Filt 10.20 4.2300 $301,815.25Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' Test BOP's R. Klepzig/ / J. Haberthur 16 Cir Flow In (gpm) Current Pump & Flow Data: 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 9 0' Depth md 12 midnight to 12 midnight 0 bbls. 12 midnight to 6 AM 0 bbls. at time of report. No losses or gains down hole while POOH PWD Drilling All Circ Avg Diam % Continue to Trip out of the hole MAD passing to 11675'. Trip out of the hole to surface and lay down BHA. Testing BOPE 30 bbls 6.13'' Max: Hole Condition On Bot Hrs 14091'8.2 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.13'' Max: Hole Condition On Bot Hrs 14091'8.2 PWD Drilling All Circ Avg Diam 12 midnight to 6 AM 0 bbls. test. Service top drive. Pick up BHA and shallow pulse test MWD 190 gpm, 550 psi at 133'. Continue to pick up BHA to 409'. Trip into the hole 409' to 6518'. No gains or losses during trip in. Nipple down BOP and change out annular element and seals and test. Pick up RCD head and install on BOP and 30 bbls md 12 midnight to 12 midnight 0 bbls. 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 9 0' Depth 0' Test BOP's R. Klepzig/ / J. Haberthur 16 Cir Flow In (gpm) Current Pump & Flow Data: 4.2300 $305,945.38Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 8.6 mg/l AvgMin Max Max pH Chlorides GvlCoal Min Avg Cmnt ml/30min Max:Ambient Air Pit Room North Slope Daily Charges Avg 6.125 0.3889 0.0 0 Pioneer ODSN-23i Oooguruk 50 07/08/2011-04:00 14112' Nabors 19AC $5,601.35 AK-AM-0008100416 6.125 0.9204 (ppb Eq)cP PV Size MBT Mill tooth 14112' 14112' 1110.20 10.20 0.82 1.0 Silt Siltst ClystCht TFA Hours 46 50 Chromatograph (ppm) H2S Data Sample Line Avg: Gas (units) 14112' 21' C2C1 Sh 20.00 Sd Depth Max 14.0 Lst 14091' 1500 1600 FXG64 C4 C5 Tuff Gas Breakdown Avg: 50 Average Sst C3 API Filt 10.30 70 33 Mark Lindloff/ David Mckechnie 2-2-WT-A-E-I-ER-BHA Ann Corr Cor Solids (lb/100ft2) 4,500 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirMark Lindloff/ David Mckechnie 2-2-WT-A-E-I-ER-BHA Ann Corr Cor Solids (lb/100ft2) 4.00 24 hr Max 109 YP 70 589 448 C3 691 8 Tuff Gas Breakdown 14285 Avg: 504 0 Average Sst F 51 C4 C5 GP229 109 F Sd Depth Max 1920.0 Lst 14091' 1500 1600 FXG64 2894 781 14112' 21' C2C1 Sh 20.00 1974 14626 15100 15400 1869 689 2360 H2S Data Sample Line Avg: 100 104029 Chromatograph (ppm) 6.0 Silt Siltst ClystCht TFA Hours Mill tooth 15229' 14112' 107.60 7.60 0.82 Nabors 19AC $5,601.35 AK-AM-0008100416 6.125 0.9204 (ml/30 min)cP PV Size HTHP Pioneer ODSN-23i Oooguruk 51 07/09/2011-04:00 15559' North Slope 14556 15011 Daily Charges Avg 6.125 0.3889 152.9 311 Gas (units) (volt) 233 Max:Ambient Air Pit Room 47 Cmnt 9.40 Lime Alkai GvlCoal 9.40 Min 10.05 Avg 1.7 (lbs/bbl)(Pom) 9.86 AvgMin Max Max Elec Stab 5.18 2770 4.2300 $311,546.73 240 68 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 1447' Drilling R. Klepzig/ / J. Haberthur 1869 15157' Flow In (gpm) Current Pump & Flow Data: 12.87 170.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)670 598 14973' Depth md with Background 800-900 units. Samples 100% sandstone. 12 midnight to 12 midnight 0 bbls. 12 midnight to 6 AM 0 bbls. displacement, Torque dropped from 17K to 12K with OBM in the hole. Drill ahead to report depth. Gas averaging 300 to 850 units, some connection gas observed between 15100 to 15300, Max connection gas seen1860 units PWD Drilling All Circ Avg Diam % 10.21 Continue to trip into the hole 4265' to 14082' filling pipe every 25 stands. Displace well to OBW. Install RCD, Resume 40 bbls 6.73'' Max: Hole Condition On Bot Hrs 15559'12.17 1828 794 92276 7966 877 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 924 1699 385 41346 530049 1579 1770017000 Drill ahead 15252. Service top drive. Drill ahead with no issues to 18247'. 40 bbls 6.34'' Max: Hole Condition On Bot Hrs 18247'29.82 12 midnight to 6 AM 0 bbls. At 17930' Gas dropped from 600-1500 units to 200-350 units PWD Drilling All Circ Avg Diam md. Samples 100% sandstone. 12 midnight to 12 midnight 0 bbls. 152.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)203 959 17960' Depth 2688' Drilling R. Klepzig/ / J. Haberthur 7495 16422' Flow In (gpm) Current Pump & Flow Data: 10.39 3044 4.2300 $317,148.08 212 68 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 10.31 2.6 (lbs/bbl)(Pom) 10.05 AvgMin Max Max9.63 118 Lime Alkai GvlCoal 9.57 Min 10.05 Avg Cmnt F Gas (units) (volt) 352 868 616 Max:Ambient Air Pit Room 51 North Slope 16000 16700 Daily Charges Avg 6.125 0.3889 157.7 316 Pioneer ODSN-23i Oooguruk 52 07/10/2011-04:00 18247' Nabors 19AC $5,601.35 AK-AM-0008100416 6.125 0.9204 (ml/30 min)cP PV Size HTHP Mill tooth 16600' 14112' 137.70 7.70 0.82 4.0 Silt Siltst ClystCht TFA Hours 89551 Chromatograph (ppm) 2714 H2S Data Sample Line Avg: 100 33505 16300 16705 16950 7495 1799 101053 2180 1899 2895 899 14112' 21' C2C1 Sh 20.00 Sd Depth Max 1800.0 Lst 14091' 1500 1600 FXG64 Sst F 136 C4 C5 F488 873 GP 9 Tuff Gas Breakdown 15600 Avg: 815 0 Average Elec Stab 3058.00 70 11819 3841 C3 791 Mark Lindloff/ David Mckechnie 2-2-WT-A-E-I-ER-BHA Ann Corr Cor Solids (lb/100ft2) 2.75 24 hr Max 110 YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 924 1639 1000 11283 75699 1649 6.50'' Max: Hole Condition On Bot Hrs 20396'46.02 20186 PWD Drilling All Circ Avg Diam 12 midnight to 6 AM 0 bbls. RCD. Drill ahead 19194' to report dept Gas averaged 821 units for today. Samples 100% sandstone. Drill ahead 6.125" hole 18247' to 18912' Service the top drive. Continue to drill ahead 18912' to 19194'. Change out 60 bbls md CG 3676 units at 19863' BKG 509 units. (2 Surveys were taken at this point.) CG 5298 units at 20167'' BKG 385 units. (Rig Circulated while waiting on Geologist, then made a connection.) 12 midnight to 12 midnight 0 bbls. 50.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)275 821 19015' Depth 154' Circulating R. Klepzig/ / J. Haberthur 5299 20171' Flow In (gpm) Current Pump & Flow Data: 10.68 2153 4.2300 $322,749.43 180 50 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 10.68 2.7 (lbs/bbl)(Pom) 10.26 AvgMin Max Max9.87 282 Lime Alkai GvlCoal 9.83 Min 10.25 Avg Cmnt CG (volt) 934 2907 332 Max:Ambient Air Pit Room North Slope 19010 19650 Daily Charges Avg 6.125 0.3889 149.0 323 Pioneer ODSN-23i Oooguruk 53 07/11/2011-04:00 20550' Nabors 19AC $5,601.35 AK-AM-0008100416 6.125 0.9204 (ml/30 min)cP PV Size HTHP Mill tooth 20088' 14112' 157.70 7.70 0.82 4.8 Silt Siltst ClystCht TFA Hours 51 100 108477 Chromatograph (ppm) 459991 2180 2953 H2S Data Sample Line Avg: 11743 Gas (units) 20162 19050 19750 20050 1550 742 1451 909 14112' 21' C2C1 Sh 20.00 Sd Depth Max 1920.0 Lst 14091' 1500 1600 FXG64 F 120 C4 C5 F258 49 F Tuff Gas Breakdown 18650 Avg: 989 0 Average Sst 413 221 C3 876 Elec Stab 5.18 70 8 3074 Mark Lindloff/ David Mckechnie 2-2-WT-A-E-I-ER-BHA Ann Corr Cor Solids (lb/100ft2) 4.00 24 hr Max 95 YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.50'' Max: Hole Condition On Bot Hrs 20550'47.21 PWD Drilling All Circ Avg Diam 12 midnight to 6 AM 0 bbls. hole 20550' to 19779' with intermittent pack off 20550' to 20100'. Back ream 19799' to 17371'. Change out rotating rubber RCD element. Continue to back ream out of the hole to 14064' (20' inside the 7" casing).Hole was tight at 14625', wipe two times. Samples 100% sandstone. Drill to TD, 20550' MD. Circulate and condition well two times bottoms up. Pack off while recip. at 20471'. Trip out of the 60 bbls md Pull back to 13987', pumped sweep saw 50% increase in returns and gas increased to 1490 units at bottoms up.Currently Slip and cutting drill line. 12 midnight to 12 midnight -15 bbls.(This includes the Short Trip) 0.0 Max @ ft Current R.O.P. (ft/hr) Gas (units)0 187 19015' Depth 0' Cut & Slip R. Klepzig/ / J. Haberthur 2523 Cir Flow In (gpm) Current Pump & Flow Data: 11.41 0 4.2300 $330,357.04 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 2.6 (lbs/bbl)(Pom) AvgMin Max Max Lime Alkai GvlCoal 8.63 Min 10.13 Avg Cmnt (volt) Max:Ambient Air Pit Room North Slope Daily Charges Avg 6.125 0.3889 0.0 0 Pioneer ODSN-23i Oooguruk 54 07/12/2011-04:00 20550' Nabors 19AC $5,601.35 AK-AM-0008100416 6.125 0.9204 (ml/30 min)cP PV Size HTHP Mill tooth 20550' 14112' 20552' 127.70 7.70 47.21 6440' 0.82 4.8 Silt Siltst ClystCht TFA Hours 48 100 Chromatograph (ppm) H2S Data Sample Line Avg: Gas (units) 14112' 21' C2C1 Sh 25.00 20.00 Sd Depth Max 2000.0 Lst 14091' 1500 1600 FXG64 C4 C5 Tuff Gas Breakdown Avg: 0 Average Sst C3 Elec Stab 3.24 140 70 7 Mark Lindloff/ David Mckechnie Charges for sample supplies have been applied 2-2-WT-A-E-I-ER-BHA Ann Corr Cor Solids (lb/100ft2) 2.50 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.50'' Max: Hole Condition On Bot Hrs 20550'47.21 PWD Drilling All Circ Avg Diam 12 midnight to 6 AM 0 bbls. through tight spots. Repair RCD element. At 20100' circulate one bottoms up, max gas 6394 units. Pump sweep with 30% increase in cuttings and 900 unitsof gas with returns, pump one bottoms up after sweep return. Pump spacer Continue to Slip/cut drilling line. Trip back into hole 14064' to 20100'. Tight at 14610', 18040', 18232'. Rotate 60 bbls md POOH to 15542'. Continue to pull back to 14075'. Prepare to swap 7.7 MW for 10.1. Currently circulating 10.1 Mud in and Out. Max gas 1090 units. 12 midnight to 12 midnight NA Max @ ft Current R.O.P. (ft/hr) Gas (units)17 187 NA Depth 0' Cir Kill Weight Mud R. Klepzig/ / J. Haberthur 2523 Cir Flow In (gpm) Current Pump & Flow Data: 10.34 699 4.2300 $335,958.39 108 31 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 2.5 (lbs/bbl)(Pom) AvgMin Max Max Lime Alkai GvlCoal 8.63 Min 10.04 Avg Cmnt (volt) Max:Ambient Air Pit Room North Slope Daily Charges Avg 6.125 0.3889 NA NA Pioneer ODSN-23i Oooguruk 55 07/13/2011-04:00 20550' Nabors 19AC $5,601.35 AK-AM-0008100416 6.125 0.9204 (ml/30 min)cP PV Size HTHP Mill tooth 20550' 14112' 20552' 157.70 7.70 47.21 6440' 0.82 4.8 Silt Siltst ClystCht TFA Hours 50 100 Chromatograph (ppm) H2S Data Sample Line Avg: Gas (units) 14112' 21' C2C1 Sh 25.00 20.00 Sd Depth Max 1950.0 Lst 14091' 1500 1600 FXG64 C4 C5 Tuff Gas Breakdown Avg: 0 Average Sst C3 Elec Stab 3.50 140 70 7 Mark Lindloff/ David Mckechnie 2-2-WT-A-E-I-ER-BHA Ann Corr Cor Solids (lb/100ft2) 2.70 24 hr Max YP Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In AirMark Lindloff/ David Mckechnie 2-2-WT-A-E-I-ER-BHA Ann Corr Cor Solids (lb/100ft2) 4.70 24 hr Max YP 140 70 C3 8 Tuff Gas Breakdown Avg: 0 Average Sst C4 C5 Sd Depth Max 1250.0 Lst 14091' 1500 1600 FXG64 14112' 21' C2C1 Sh 25.00 20.00 H2S Data Sample Line Avg: 100 Chromatograph (ppm) 5.8 Silt Siltst ClystCht TFA Hours Mill tooth 20550' 14112' 20552' 2310.10 10.10 47.21 6440' 0.82 Nabors 19AC $5,601.35 AK-AM-0008100416 6.125 0.9204 (ml/30 min)cP PV Size HTHP Pioneer ODSN-23i Oooguruk 56 07/14/2011-04:00 20550' North Slope Daily Charges Avg 6.125 0.3889 NA NA Gas (units) (volt) Max:Ambient Air Pit Room 48 Cmnt Lime Alkai GvlCoal Min Avg 10.9 (lbs/bbl)(Pom) AvgMin Max Max Elec Stab 6.00 0 4.2300 $341,634.74 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke 0' R/U to Run 4.5" Liner R. Klepzig/ / J. Cortez 21 Cir Flow In (gpm) Current Pump & Flow Data: NA Max @ ft Current R.O.P. (ft/hr) Gas (units)0 6 NA Depth md 10.1ppg to 100 gpm. MW out 9.9 ppg. Circ @ 1bpm till MW in and out 10.1 ppg. Shut down pumps. Monitor well. Static. Pump dry job. Function test BOPs. TOH to BHA. Monitor well.Static. Lay down BHA. Remove nukes. Pick up liner running equipment. Begin running 4 1/2" in the hole 12 midnight to 12 midnight -108 bbls 12 midnight to 4 AM -4 bbls. 9.7ppg. Pump 60 bbls additional 10.1ppg. MW out 9.5ppg. Shut chks.WHP 150psi. Circ 10.1ppg @ 2bpm. Shut chks. WHP 100psi. Pull RCD bearing. Install trip nipple. Circ 10.1ppg thru choke. MW out 9.2ppg. WHP 100 psi. Circ and cond / stage rate PWD Drilling All Circ Avg Diam % p ppg p ppg Pump 60 bbls additional 10.1ppg. MW out 9.5ppg. Shut chks. 60 bbls 6.50'' Max: Hole Condition On Bot Hrs 20550'47.21 Customer:Report #: Well:Date: Area:04:00 Depth Location:Progress 24 hrs: Rig:Rig Activity: Job No.:Report For: ROP & Gas: Mud Data:Density (ppg)Viscosity Depth ft in out (sec/qt) BHA Run #Bit Type Depth in / out Footage WOB RPM Condition Lithology (%): (current) to to 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… 24 hr Recap: Logging Engineer:*10000 units = 100% Gas In Air 6.50'' Max: Hole Condition On Bot Hrs 20550'47.21 PWD Drilling All Circ Avg Diam Run in the hole on DP to 14047'. Circ DP volume from active pit 7 (No gas) Run in the hole to 17140'. TIH w/ 4.5" Liner . P/U magnet, scraper assy, etc. Circulate and condition 20 bbls to clear heavy weight drill pipe. 60 bbls md Total losses to hole during Liner run, last 24hrs= 21 bbls. Losses to hole approx 2.5 bbls NA Max @ ft Current R.O.P. (ft/hr) Gas (units)0 0 NA Depth 0' Running 4.5" Liner R. Klepzig/ / J. Cortez 0 Cir Flow In (gpm) Current Pump & Flow Data: 0 4.2300 $345,764.87 0 0 Total Charges: Flow In (spm) SPP (psi) Gallons/stroke % 11.1 (lbs/bbl)(Pom) AvgMin Max Max Lime Alkai GvlCoal Min Avg 1-1-NO-A-X-I-ER-TD Cmnt (volt) Max:Ambient Air Pit Room North Slope Daily Charges Avg 6.125 0.3889 NA NA Pioneer ODSN-23i Oooguruk 57 07/15/2011-04:00 20550' Nabors 19AC $4,130.13 AK-AM-0008100416 6.125 0.9204 (ml/30 min)cP PV Size HTHP Mill tooth 20550' 14112' 20552' 2110.10 10.10 47.21 6440' 0.82 5.4 Silt Siltst ClystCht TFA Hours 45 100 Chromatograph (ppm) H2S Data Sample Line Avg: Gas (units) 14112' 21' C2C1 Sh 25.00 20.00 Sd Depth Max 1290.0 Lst 14091' 1500 1600 FXG64 C4 C5 Tuff Gas Breakdown Avg: Average Sst C3 Elec Stab 5.44 140 70 8 Mark Lindloff/ David Mckechnie End of SDL Services for ODSN-23i 2-2-WT-A-E-I-ER-BHA Ann Corr Cor Solids (lb/100ft2) 4.20 24 hr Max YP W E L L N A M E : OD S N - 2 3 i , - P B 1 , - P B 2 LO C A T I O N : Oooguruk OP E R A T O R : Pi o n e e r N a t u r a l R e s o u r c e s AR E A : North Slope MU D C O : Ba r o i d ST A T E : Alaska RI G : Na b o r s 1 9 A C SP U D : 13-May-11 SP E R R Y J O B : AK - A M - 8 1 0 0 4 1 6 TD : 11-Jul-11 BI T RE C O R D BH A # B i t # B i t T y p e B i t Si z e De p t h In De p t h Ou t Fo o t a g e B i t Ho u r s TF A A V G RO P WO B (m a x ) RP M (m a x ) SP P (m a x ) FL O W G P M (m a x ) Bi t G r a d e R e m a r k s 1 1 M X L - 1 V 1 4 . 5 0 1 5 8 1 1 1 7 9 5 9 1 2 . 2 2 0 . 6 9 9 5 78 . 4 30 60 1 1 5 0 6 0 0 1 - 1 - W T - A - E - I - N O - R I G R i g R e p a i r 2 1 r r 1 M X L - 1 V 1 4 . 5 0 1 1 1 7 2 6 3 6 1 5 1 9 1 3 . 5 8 0 . 6 9 9 5 11 1 . 9 30 60 1 6 8 0 6 5 0 1- 1 - W T - A - E - I - N O - B H A BHA Chg 3 2 M X L - 1 V 1 4 . 5 0 2 6 3 6 6 0 7 9 3 4 4 3 3 8 . 9 6 0 . 6 9 9 5 88 . 4 35 10 0 2 7 2 5 7 0 0 3 - 1 - F C - M - E - I - E - T D T D h o l e s e c t i o n 4 1 r r 2 M X L - 1 V 1 4 . 5 0 8 5 7 2 6 3 4 1 7 7 7 1 0 . 8 8 0 . 6 9 9 5 1 6 3 . 3 3 5 6 0 1 5 0 0 5 5 0 3 - 4 - W T - A - E - I - F C - B H A B H A C h g 5 3 M X L - 1 V 1 4 . 5 0 2 6 3 4 5 7 9 0 3 1 5 6 2 9 . 8 3 0 . 6 9 9 5 1 1 1 . 8 1 0 8 1 0 0 2 5 8 0 7 0 0 2 - 1 - W T - M - E - I - H C - T D T D h o l e s e c t i o n 6 4 G T - C I 1 0 . 6 3 5 7 9 0 5 8 1 0 2 0 0 . 6 0 0 . 9 4 1 9 3 3 . 3 2 4 8 0 9 0 0 5 5 0 2- 3 - C D - A - E - 1 - W T - B H A Drill Cement, BHA Chg En d o f O D S N - 2 3 i - P B 1 7 5 F X G 6 5 1 0 . 6 3 5 8 1 0 5 9 8 7 1 7 7 2 . 0 0 1 . 2 7 0 1 8 8 . 5 8 8 0 1 8 5 0 7 5 0 0- 0 - N O - A - X - I - N O - D T G POOH due to Tool Failure 8 5 r r 1 F X G 6 5 1 0 . 6 3 5 9 8 7 1 1 9 8 6 5 9 9 9 7 2 . 7 0 1 . 2 7 0 1 8 2 . 5 3 7 1 6 3 3 7 8 0 9 5 3 L e f t i n H o l e T D h o l e s e c t i o n 11 6 W i n d o w M i l l 8 . 50 1 1 6 7 5 1 1 7 0 6 3 1 0 . 2 2 - 2 8 3 . 0 1 . 9 5 2 1 5 4 3 4 5 3 - M i l l e d w i n d o w and drilled 30 feet. 13 7 X R + 8 . 5 0 1 1 7 0 6 1 2 0 7 7 3 7 1 1 8 . 8 0 0 . 9 6 8 7 1 9 . 7 3 2 1 0 0 3 8 0 0 7 0 0 1 - 1 - N O - A - E - I - N O - B H A C h a n g e o u t B H A 14 8 F X G 4 6 s 8 . 5 0 1 2 0 7 7 1 4 0 9 1 2 0 1 4 3 3 . 4 6 0 . 8 5 6 0 6 0 . 2 4 9 1 4 2 4 1 9 8 7 0 5 1 - 1 - E R - C X - I - N O - T D T D h o l e s e c t i o n 15 9 Q H 1 R 6 . 1 3 1 4 0 9 1 1 4 1 1 2 2 1 0 . 8 2 0 . 9 2 0 4 25 . 6 2 0 7 0 2 3 5 0 2 7 2 2 - 2 - W T - A - E - I - E R - B H A D r i l l C e m e n t , B H A C h g 16 1 0 F X G 6 4 6 . 1 3 1 4 1 1 2 2 0 5 5 0 6 4 3 8 4 7 . 2 1 0 . 3 8 8 9 1 3 6 . 4 2 5 1 4 0 3 2 0 0 2 4 0 1 - 1 - N O - A - X - I - E R - T D T D W e l l En d o f O D S N - 2 3 i - P B 2 En d o f O D S N - 2 3 i WE L L N A M E : OD S N - 2 3 i , - P B 1 , - P B 2 LO C A T I O N : Oo o g u r u k OP E R A T O R : Pi o n e e r N a t u r a l R e s o u r c e s AR E A : No r t h S l o p e MU D C O : Ba r o i d ST A T E : Al a s k a RI G : Na b o r s 1 9 A C SP U D : 13 - M a y - 1 1 SP E R R Y J O B : AK - A M - 8 1 0 0 4 1 6 TD : 11 - J u l - 1 1 W a t e r - a n d O i l - B a s e d M u d R e c o r d Da t e D e p t h W t V i s P V Y P G e l s F i l t R6 0 0 / R 3 0 0 / R 2 0 0 / R 1 0 0 / R6 / R 3 Ca k e S o l i d s Oi l / W a t e r Sd P m p H M B T P f / M f C h l o r H a r d R e m a r k s ft - M D p p g s e c c P l b / 1 0 0 l b / 1 0 0 f t 2 m / 3 0 m R h e o m e t e r 3 2 n d s % % % p p b E q v m g / l C a + + 19 - M a y 6 0 7 9 9 . 6 5 6 1 1 4 2 8 2 2 / 3 6 / 4 5 1 1 . 8 5 6 / 4 2 / 3 3 / 2 6 / 1 8 / 1 7 3 / - 8 . 2 1 . 0 / 8 9 . 8 0 . 1 5 0 . 8 0 9 . 0 2 0 . 0 0 . 1 2 / 0 . 5 0 1 9 , 0 0 0 8 0 0 S h o r t T r i p a t T D 20 - M a y 6 0 7 9 9 . 6 5 6 8 1 8 3 9 2 1 / 3 2 / 3 4 8 . 8 7 5 / 5 7 / 5 0 / 4 0 / 2 3 / 2 2 3 / - 8 . 2 2 . 0 / 8 8 . 8 0 . 5 0 0 . 8 0 9 . 0 1 5 . 0 0 . 1 2 / 0 . 6 0 1 9 , 0 0 0 6 0 0 P O O H w / 1 4 . 5 " B H A 21 - M a y 6 0 7 9 9 . 5 0 7 5 1 8 3 8 1 9 / 4 1 / 4 3 9 . 2 7 5 / 5 6 / 4 7 / 3 7 / 2 1 / 1 9 3 / - 7 . 0 2 . 0 / 9 0 . 0 0 . 2 0 1 . 2 0 9 . 4 2 0 . 0 0 . 1 5 / 0 . 5 0 1 8 , 5 0 0 6 0 0 R i g o n S t a n d b y 22 - M a y 6 0 7 9 9 . 4 5 6 9 2 2 2 9 1 9 / 3 2 / 3 4 8 . 8 7 5 / 5 1 / 4 2 / 3 2 / 1 6 / 1 4 3 / - 7 . 2 2 . 0 / 8 9 . 8 0 . 1 0 0 . 8 0 8 . 8 2 0 . 0 0 . 1 0 / 0 . 5 5 1 9 , 0 0 0 6 0 0 R i g o n S t a n d b y 23 - M a y 2 1 9 9 9 . 3 5 1 2 1 2 3 5 1 2 7 / 3 5 / 3 8 8 . 4 9 7 / 7 4 / 6 4 / 5 2 / 2 8 / 2 6 3 / - 6 . 5 1 . 5 / 9 1 . 0 1 . 0 0 1 . 2 0 9 . 5 1 7 . 5 0 . 1 8 / 0 . 6 0 1 8 , 0 0 0 4 0 0 D r il l i n g 1 4 . 5 " S i d e t r a c k 1 24 - M a y 3 5 6 2 9 . 4 0 1 3 1 2 3 5 1 2 7 / 3 3 / 3 5 8 . 4 9 7 / 7 4 / 6 5 / 5 3 / 2 9 / 2 7 3 / - 6 . 8 1 . 0 / 9 1 . 2 1 . 0 0 1 . 0 0 9 . 1 1 7 . 5 0 . 1 5 / 0 . 5 0 1 8 , 0 0 0 6 0 0 D r il l i n g 1 4 . 5 " S i d e t r a c k 1 25 - M a y 5 4 8 1 9 . 5 0 1 2 0 2 0 4 6 3 2 / 4 2 / 4 4 9 . 2 8 6 / 6 6 / 6 0 / 4 9 / 3 1 / 2 9 2 / - 7 . 5 1 . 5 / 9 0 . 0 1 . 0 0 0 . 5 0 8 . 9 2 0 . 0 0 . 1 0 / 0 . 5 0 1 8 , 0 0 0 6 0 0 D r il l i n g 1 4 . 5 " S i d e t r a c k 1 26 - M a y 5 7 9 0 9 . 6 0 5 4 1 5 3 2 1 9 / 3 2 / 3 6 1 0 . 0 6 2 / 4 7 / 4 1 / 3 2 / 1 9 / 1 7 2 / - 8 . 1 1 . 5 / 8 9 . 4 0 . 3 0 0 . 5 0 8 . 8 2 2 . 5 0 . 1 2 / 0 . 5 5 1 9 , 0 0 0 8 0 0 B a c k r e a m i n g o u t of Hole 27 - M a y 5 7 9 0 1 0 . 1 0 8 1 2 1 4 5 2 5 / 3 9 / 4 8 1 0 . 0 8 7 / 6 6 / 5 6 / 4 4 / 2 6 / 2 4 2 / - 1 1 . 5 1 . 5 / 8 6 . 0 0 . 7 5 - 8 . 4 2 2 . 5 0 . 0 2 / 0 . 6 0 1 9 , 0 0 0 6 0 0 R u n n i n g 1 1 . 7 4 " C a sing (60#) 28 - M a y 5 7 9 0 9 . 7 5 4 1 7 1 4 8 / 1 5 / 1 8 1 4 . 0 2 8 / 2 1 / 1 6 / 1 2 / 8 / 7 3 / - 9 . 2 1 . 0 / 8 8 . 8 0 . 3 0 - 8 . 5 1 9 . 0 0 . 0 2 / 1 . 1 0 1 8 , 0 0 0 6 0 0 C h a n g e o u t S w i v e l P a c k i ng 29 - M a y 5 0 7 9 9 . 6 0 4 1 8 1 2 8 / 1 5 / 2 1 1 6 . 0 2 8 / 2 0 / 1 5 / 1 1 / 8 / 7 2 / - 8 . 1 1 . 0 / 8 9 . 9 0 . 5 0 - 8 . 2 2 0 . 0 - / 1 . 1 0 1 8 , 0 0 0 6 0 0 R I H w / 1 0 . 6 2 5 " C l e a n o u t B H A 30 - M a y 5 8 1 0 9 . 8 0 4 7 1 0 2 1 8 / 1 1 / 1 2 6 . 4 4 1 / 3 1 / 2 5 / 2 0 / 9 / 7 2 / - 5 . 4 1 . 5 / 9 1 . 0 - 0 . 8 0 1 0 . 5 1 . 0 0 . 3 0 / 0 . 7 0 2 7 , 0 0 0 3 0 0 R I H w / 1 0 . 6 2 5 " D r illing BHA 31 - M a y 5 9 8 7 9 . 8 0 4 4 1 0 2 4 8 / 1 3 / 1 5 5 . 6 4 4 / 3 4 / 2 9 / 2 2 / 1 0 / 8 2 / - 5 . 3 2 . 5 / 9 0 . 0 0 . 8 0 0 . 4 0 1 0 . 4 2 . 0 0 . 1 8 / 0 . 7 0 2 7 , 0 0 0 1 0 0 D r il l i n g 1 0 . 62 5 " I n t e r m e d i a t e 1- J u n 7 2 2 4 9 . 8 0 5 1 1 5 2 6 1 2 / 1 7 / 1 9 6 . 0 5 6 / 4 1 / 3 6 / 2 8 / 1 2 / 1 0 2 / - 5 . 5 5 . 0 / 8 7 . 5 0 . 3 5 - 9 . 2 6 . 0 0 . 0 7 / 0 . 8 0 2 6 , 0 0 0 2 0 0 T r i p p i n g o u t o f H o l e , Packed Off 2- J u n 7 2 4 3 9 . 8 0 5 2 1 4 3 1 1 3 / 1 7 / 2 6 6 . 0 5 9 / 4 5 / 3 8 / 3 0 / 1 4 / 1 2 2 / - 5 . 7 5 . 0 / 8 7 . 5 0 . 2 5 - 9 . 0 1 2 . 0 0 . 0 3 / 0 . 8 0 2 3 , 0 0 0 2 4 0 D r il l i n g 1 0 . 62 5 " I n t e r m e d i a t e 3- J u n 8 2 2 0 9 . 9 0 5 2 1 6 3 6 1 2 / 2 3 / 3 4 6 . 2 6 8 / 5 2 / 4 4 / 3 2 / 1 3 / 1 0 2 / - 6 . 2 5 . 0 / 8 7 . 0 0 . 1 0 0 . 0 0 9 . 4 1 9 . 0 . 0 5 / 1 . 0 0 2 4 , 0 0 0 1 6 0 D r il l i n g 1 0 . 62 5 " I n t e r m e d i a t e 4- J u n 9 9 8 6 9 . 9 0 5 1 1 5 3 0 1 3 / 1 9 / 2 5 6 . 0 6 0 / 4 5 / 3 8 / 3 0 / 1 2 / 1 0 2 / - 5 . 7 5 . 0 / 8 7 . 5 0 . 1 0 0 . 0 0 1 0 . 0 1 4 . 0 . 1 0 / 1 . 1 0 2 4 , 0 0 0 1 6 0 D r il l i n g 1 0 . 62 5 " I n t e r m e d i a t e 5- J u n 1 1 5 2 0 9 . 9 0 5 0 1 3 2 6 1 1 / 1 6 / 2 0 5 . 0 5 2 / 3 9 / 3 5 / 2 7 / 1 1 / 9 2 / - 6 . 0 5 . 0 / 8 7 . 0 0 . 1 0 0 . 0 0 1 0 . 1 1 3 . 5 . 1 0 / 1 . 1 0 2 6 , 0 0 0 1 6 0 D r il l i n g 1 0 . 62 5 " I n t e r m e d i a t e 6- J u n 1 1 9 8 6 9 . 9 0 4 9 1 7 2 5 1 4 / 2 1 / 2 7 6 . 0 5 9 / 4 2 / 3 5 / 2 7 / 1 5 / 1 1 2 / - 6 . 2 5 . 0 / 8 7 . 0 0 . 2 0 0 . 0 0 9 . 3 1 4 . 0 . 0 5 / . 8 5 2 3 , 5 0 0 1 6 0 T D 1 0 . 6 2 5 " I n t e r m e d iate Sec 7- J u n 1 1 9 8 6 9 . 8 0 4 9 1 6 2 6 1 3 / 1 9 / 2 5 6 . 0 5 8 / 4 2 / 3 6 / 2 8 / 1 1 / 9 2 / - 6 . 3 5 . 0 / 8 7 . 0 0 . 1 0 0 . 0 0 9 . 3 1 4 . 0 0 . 1 0 / 0 . 8 5 2 2 , 5 0 0 1 6 0 B a c k R e a m i n g 8- J u n 1 1 9 8 6 9 . 8 0 5 0 1 5 2 4 1 1 / 2 0 / 2 5 6 . 0 5 4 / 3 9 / 3 2 / 2 4 / 1 1 / 9 2 / - 6 . 3 4 . 5 / 8 7 . 5 0 . 0 5 0 . 0 0 9 . 2 1 4 . 5 0 . 0 5 / 0 . 8 0 2 2 , 5 0 0 1 6 0 T r i p p i n g 9- J u n 1 1 9 8 6 9 . 9 0 5 5 1 9 2 8 1 8 / 3 0 / 3 6 6 . 0 1 8 / 2 0 / 3 0 / 3 9 / 4 5 / 6 2 2 / - 7 . 3 3 . 0 / 8 8 . 5 0 . 1 0 0 . 0 0 9 . 7 1 6 . 0 0 . 1 0 / 1 . 2 0 2 2 , 5 0 0 8 4 R e a m i n g i n t h e h o l e 10 - J u n 1 1 9 8 6 1 0 . 1 5 7 5 9 2 4 2 6 / 5 3 / 5 4 7 . 6 7 4 / 5 8 / 5 3 / 4 5 / 3 2 / 3 0 2 / - 7 . 8 1 . 0 / 8 9 . 5 0 . 1 2 0 . 3 0 1 0 . 0 1 7 . 5 0 . 1 2 / 0 . 9 8 2 1 , 0 0 0 6 8 T r i p p i n g o u t o f Hole 11 - J u n 1 1 9 8 6 9 . 9 5 7 2 1 2 2 6 1 9 / 3 2 / 3 5 6 . 5 5 0 / 3 8 / 3 3 / 2 8 / 1 6 / 1 5 2 / - 6 4 . 0 / 8 8 . 0 0 . 1 0 . 2 9 . 7 1 3 . 5 0 . 1 0 / 1 . 0 2 5 0 0 0 1 2 0 T e s t B O P 12 J u n 11 9 8 6 99 5 55 10 21 10 / 1 5 / 1 6 62 41 / 3 1 / 2 7 / 2 0 / 1 4 / 1 2 2/ 57 40 / 8 7 5 01 12 5 10 8 15 0 7 0 / 1 4 5 24 0 0 0 48 Ru n n i n g 9 6 2 5 " Casing (54#) En d o f O D S N - 2 3 i - P B 2 En d o f O D S N - 2 3 i - P B 1 12 -Ju n 11 9 8 6 9 .95 55 10 21 10 / 1 5 / 1 6 6 .2 41 / 3 1 / 2 7 / 2 0 / 1 4 / 1 2 2/ - 5 .7 4 .0/ 8 7 .5 0 .1 1 .25 10 .8 15 0 .70 / 1 .45 24 0 0 0 48 Ru n n i n g 9 .62 5 Casing (54#) 13 - J u n 1 1 9 8 6 9 . 9 4 4 9 1 5 4 / 1 1 / 1 4 6 . 4 3 3 / 2 4 / 2 0 / 1 3 / 5 / 4 2 / - 7 . 7 5 . 0 / 8 5 . 5 0 . 1 0 . 1 9 . 8 1 4 0 . 1 0 / 0 . 9 0 2 4 5 0 0 6 0 c i r c u l t a t e p r i o r t o c e m e n t i n g 14 - J u n 1 1 9 8 6 9 . 9 4 5 1 0 1 7 7 / 1 0 / 1 3 6 . 5 3 7 / 2 7 / 2 3 / 1 7 / 8 / 6 2 / - 7 . 2 2 . 5 / 8 9 . 0 0 . 1 0 . 7 1 0 . 3 8 0 . 4 5 / 1 . 2 5 1 6 5 0 0 4 0 C h a n g e R a m s 15 - J u n 1 1 9 8 6 9 . 8 5 4 3 6 1 8 5 / 7 / 1 2 6 . 4 3 0 / 2 4 / 1 9 / 1 5 / 6 / 5 2 / - 6 . 3 2 . 3 / 9 0 . 2 0 . 1 0 . 4 1 1 . 1 1 0 0 . 4 0 / 1 . 3 0 1 5 0 0 0 4 0 T r i p p i n g 16 - J u n 1 1 9 8 6 9 . 8 5 4 3 8 1 9 7 / 9 / 1 2 5 . 2 3 5 / 2 7 / 2 3 / 1 8 / 8 / 6 2 / - 6 . 7 5 . 0 / 8 7 . 0 0 . 1 0 . 2 5 1 0 . 9 1 1 . 3 0 . 2 5 / 1 . 4 0 1 3 0 0 0 8 0 T r i p p i n g 17 - J u n 1 1 9 8 6 9 . 8 4 0 1 1 2 0 6 / 8 / 9 6 . 8 4 2 / 3 1 / 2 5 / 1 9 / 7 / 5 2 / - 6 . 4 6 . 0 / 8 6 . 5 0 . 1 0 . 3 1 0 . 1 8 0 . 1 5 / 0 . 9 0 1 4 0 0 0 8 4 P O O H 18 - J u n 1 1 6 7 5 9 . 8 4 3 9 1 9 6 / 8 / 9 5 . 8 3 7 / 2 8 / 2 3 / 1 8 / 7 / 5 2 / - 6 . 5 6 . 0 / 8 6 . 5 0 . 0 1 0 . 4 1 0 . 2 1 0 0 . 6 0 / 2 . 2 0 1 3 0 0 0 1 2 4 F i s h i n g 19 - J u n 1 1 6 7 5 9 . 8 5 4 0 8 1 9 4 / 6 / 7 5 3 5 / 2 7 / 2 2 / 1 6 / 4 / 3 2 / - 6 . 7 6 . 0 / 8 6 . 3 0 . 1 0 . 2 8 . 9 1 3 . 5 0 . 1 0 / 0 . 7 0 1 2 0 0 0 2 8 0 C o n d i t i o n M u d 20 - J u n 1 1 7 4 9 9 . 8 5 4 3 1 1 1 9 4 / 6 / 8 3 . 3 4 1 / 3 0 / 2 5 / 1 9 / 8 / 5 2 / - 6 . 7 5 . 0 / 8 7 . 3 0 . 1 0 . 9 9 . 9 8 0 . 3 2 / 4 . 0 1 3 0 0 0 5 2 0 D r il l i n g 21 - J u n 1 2 0 7 7 9 . 8 4 5 1 7 2 5 4 / 6 / 1 0 4 . 6 5 9 / 4 2 / 3 6 / 2 8 / 1 0 / 8 2 / - 6 . 5 6 . 0 / 8 6 . 5 0 . 1 1 9 . 5 8 0 . 7 0 / - 1 3 0 0 0 3 2 0 T r i p p i n g 22 - J u n 1 2 0 7 7 9 . 8 4 7 1 8 2 7 8 / 1 0 / 1 3 4 . 5 6 3 / 4 5 / 4 0 / 3 0 / 1 1 / 8 2 / - 6 . 6 5 . 5 / 8 7 . 2 0 . 1 0 . 7 1 0 . 4 8 0 . 6 0 / 2 . 8 0 1 3 0 0 0 3 8 0 T r i p p i n g 23 - J u n 1 3 0 6 3 1 0 . 2 4 9 1 7 2 8 9 / 1 1 / 1 3 4 . 6 6 2 / 4 5 / 4 0 / 3 1 / 1 3 / 8 2 / - 8 . 3 6 . 0 / 8 5 . 0 0 . 1 0 . 7 9 . 9 1 0 0 . 4 0 / 3 . 7 0 1 4 0 0 0 3 8 0 D r il l i n g 24 - J u n 1 3 6 2 8 1 0 . 2 4 9 1 1 2 4 8 / 1 2 / 1 4 4 . 6 4 6 / 3 5 / 2 9 / 2 2 / 9 / 7 2 / - 8 . 4 4 . 0 / 8 7 . 2 0 . 1 0 . 4 9 . 5 6 . 5 0 . 3 0 / 3 . 2 0 6 0 0 0 1 6 0 D r il l i n g 25 - J u n 1 4 0 9 1 1 0 . 3 4 3 1 4 3 2 1 3 / 1 9 / 2 3 4 6 0 / 4 6 / 4 0 / 3 1 / 1 4 / 1 2 2 / - 8 . 5 4 . 5 / 8 6 . 5 0 . 1 0 . 4 1 0 . 3 1 2 0 . 3 0 / 2 . 6 0 9 0 0 0 1 4 0 T r i p p i n g 26 - J u n 1 4 0 9 1 1 2 . 9 5 4 4 1 4 2 5 - / 1 2 / 1 4 4 . 6 5 3 / 3 9 / 3 0 / 2 3 / 1 1 / 8 2 / - 1 9 . 3 4 . 5 / 7 5 . 8 0 . 0 5 0 . 2 9 . 8 2 . 5 0 . 1 0 / 2 . 1 0 7 3 0 0 1 0 0 R u n C a s i n g 27 - J u n 1 4 0 9 1 1 2 . 2 4 3 1 5 2 8 1 0 / 1 3 / 1 + 5 5 8 / 4 3 / 3 7 / 2 5 / 1 2 / 9 2 / - 1 8 . 2 3 . 0 / 8 7 . 5 0 . 0 5 - 8 . 8 3 0 . 0 5 / 2 . 2 0 6 5 0 0 1 0 0 R u n C a s i n g 28 - J u n 1 4 0 9 1 1 0 . 3 4 3 1 2 1 7 1 0 / 1 2 / 1 4 6 4 1 / 2 9 / 2 4 / 2 0 / 1 1 / 8 2 / - 8 . 9 2 . 0 / 8 8 . 7 0 . 0 5 0 . 3 1 0 1 0 . 2 0 / 2 . 7 0 4 , 0 0 0 1 2 0 R u n c a s i n g a n d c e m e n t 29 - J u n 1 4 0 9 1 1 0 . 2 5 4 4 1 3 1 5 1 1 / 1 3 / 1 5 6 . 5 4 1 / 2 8 / 2 4 / 2 0 / 1 1 / 9 2 / - 8 . 1 2 . 0 / 8 9 . 5 0 . 0 5 - 9 . 3 1 0 . 0 5 / 2 . 6 5 4 0 0 0 S e r v i c e R i g 30 - J u n 1 4 0 9 1 1 0 4 4 1 0 2 5 1 0 / 1 3 / 1 5 6 . 5 4 5 / 3 5 / 3 1 / 2 4 / 1 2 / 9 2 / - 7 . 1 2 . 0 / 9 0 . 5 - - 1 0 . 9 1 0 . 3 5 / 2 . 7 5 4 0 0 0 1 6 0 P r e s s u r e T e s t C a s i n g 1- J u l 1 4 0 9 1 1 0 4 5 1 1 2 2 1 0 / 1 2 / 1 4 6 . 5 4 4 / 3 3 / 2 9 / 2 2 / 1 0 / 8 2 / - 7 . 1 2 . 0 / 9 0 . 5 - - 9 . 8 1 0 . 2 0 / 2 . 4 5 4 0 0 0 1 6 0 R u n c a s i n g a n d c e m e n t 2- J u l 1 4 0 9 1 9 . 8 4 6 1 0 2 5 1 3 / 1 5 / 1 6 5 . 8 4 5 / 3 5 / 3 1 / 2 4 / 1 3 / 1 1 2 / - 7 . 1 2 . 0 / 9 0 . 5 0 . 1 - 9 . 5 1 0 . 1 0 / 1 . 1 0 4 5 0 0 1 6 0 P u m p i n g C e m e n t 3- J u l 1 4 0 9 1 1 0 . 2 4 6 1 2 1 8 1 1 / 1 3 / 1 5 6 . 5 4 2 / 3 0 / 2 5 / 2 2 / 1 2 / 1 0 2 / - 8 . 6 2 . 0 / 8 9 . 0 0 . 0 5 - 9 1 0 . 1 0 / 1 . 4 0 4 5 0 0 1 6 0 S l i p a n d c u t d r il l l i n e 4- J u l 1 4 0 9 1 1 0 . 2 4 5 1 0 2 5 1 2 / 1 4 / 1 6 6 . 5 4 5 / 3 5 / 2 9 / 2 5 / 1 2 / 1 0 2 / - 7 . 6 2 . 0 / 9 0 . 0 0 . 0 5 - 9 . 4 1 0 . 1 0 / 1 . 6 5 4 0 0 0 1 6 0 P i c k u p B H A 5- J u l 1 4 1 0 2 1 0 . 2 4 5 1 2 3 2 1 3 / 2 0 / 2 5 7 5 6 / 4 4 / 3 9 / 3 1 / 1 4 / 1 1 2 / - 8 . 1 1 . 5 / 9 0 . 0 0 . 0 5 - 1 0 . 5 1 0 . 1 0 / 2 . 2 0 4 0 0 0 4 0 0 D r il l i n g 6- J u l 1 4 1 1 2 1 0 . 2 4 5 1 0 3 5 1 3 / 1 9 / 2 3 1 4 5 5 / 4 5 / 3 9 / 3 2 / 1 5 / 1 3 2 / - 7 . 6 1 . 0 / 9 1 . 0 0 . 0 5 - 1 0 . 2 1 0 . 1 5 / 2 . 1 0 5 0 0 0 6 0 0 T e s t B O P E 7- J u l 1 4 1 1 2 1 0 . 2 4 6 1 1 3 3 1 4 / 1 9 / 2 4 1 4 5 5 / 4 4 / 3 7 / 3 2 / 1 5 / 1 3 2 / - 8 . 6 1 . 0 / 9 0 . 0 0 . 0 5 - 1 0 . 3 1 0 . 1 0 / 1 . 8 5 4 5 0 0 4 8 0 R u n I n H o l e 6 . 1 2 5 " B H A 8- J u l 1 5 2 5 2 7 . 6 0 4 7 1 0 8 4 / 5 / 8 6 . 0 2 8 / 1 8 / 1 4 / 1 0 / 4 / 3 2 1 . 2 9 0 . 8 / 7 . 0 4 . 8 0 5 . 1 8 1 9 2 0 5 . 3 2 7 6 5 2 3 1 1 . 0 / 0 . 6 1 3 . 2 3 6 D r il l i n g 9- J u l 1 7 8 5 3 7 . 7 0 5 1 1 3 9 4 / 5 / 7 4 . 0 3 5 / 2 2 / 1 7 / 1 1 / 4 / 3 2 1 . 9 8 9 . 2 / 8 . 0 2 . 7 5 3 . 5 6 1 8 0 0 4 . 3 2 6 8 7 9 5 2 2 . 7 4 / 1 . 9 7 2 . 6 8 1 D r il l i n g 10 - J u l 2 0 0 6 8 7 . 7 0 5 1 1 5 8 4 / 7 / 8 4 . 8 3 6 / 2 3 / 1 8 / 1 3 / 5 / 4 2 2 . 7 9 2 . 7 / 7 . 3 4 . 0 0 5 . 1 8 1 8 2 0 8 . 2 2 8 2 8 4 5 2 3 . 0 3 / 2 . 3 8 2 . 6 9 5 D r il l i n g 11 - J u l 2 0 5 5 0 7 . 7 0 4 8 1 2 7 5 / 9 / 1 2 4 . 8 3 1 / 1 9 / 1 4 / 1 0 / 6 / 4 2 2 . 6 9 2 . 2 / 7 . 5 2 . 5 0 3 . 2 4 2 0 0 0 8 . 2 2 9 5 1 7 6 2 2 . 2 2 / 1 . 7 7 2 . 6 7 5 P O O H 12 - J u l 2 0 5 5 0 7 . 7 0 5 0 1 5 7 6 / 1 1 / 1 5 4 . 8 3 7 / 2 2 / 1 7 / 1 2 / 5 / 4 2 2 . 5 9 2 . 2 / 7 . 8 2 . 7 0 3 . 5 0 1 9 5 0 1 0 . 2 3 1 3 8 1 2 2 2 . 3 9 / 0 . 5 8 2 . 6 2 5 P u m p K il l W e i g h t 13 - J u l 2 0 5 5 0 1 0 . 1 0 4 8 2 3 8 7 / 1 0 / 1 3 5 . 8 5 4 / 3 1 / 2 2 / 1 3 / 4 / 3 2 1 0 . 9 9 2 . 1 / 7 . 9 4 . 7 0 6 . 0 9 1 2 5 0 9 . 4 3 1 0 7 0 5 1 7 . 4 5 / 1 3 1 . 9 9 3 . 9 1 8 P O O H 14 - J u l 2 0 5 5 0 1 0 . 1 0 4 5 2 1 8 7 / 1 0 / 1 4 5 . 4 5 0 / 2 9 / 2 1 / 1 2 / 4 / 3 2 1 1 . 1 9 2 . 0 / 8 . 0 4 . 2 0 5 . 4 4 1 2 9 0 8 . 2 3 0 0 4 5 8 2 1 . 0 6 / 1 2 9 . 4 8 3 . 8 6 7 R u n n i n g 4 . 5 " l i n e r and cement Ca s i n g R e c o r d 16 " C o n d u c t o r @ 1 5 8 11 . 7 5 " I n t e r m e d i a t e @ 5 , 7 7 7 ' 9. 6 2 5 " I n t e r m e d i a t e @ 1 1 , 6 5 8 7 ' 7" I n t e r m e d i a t e @ 1 4 , 0 8 2 ' En d o f O D S N - 2 3 i Marker MD INC AZ TVD TVDSS Top Permafrost 857.0 23.10 277.80 838.20 782.00 Base Permafrost 1831.0 53.40 251.70 1667.70 1611.50 Top West Sak 3171.0 68.80 237.20 2316.90 2260.70 Tuffaceous Shale 4982.0 70.70 234.90 2911.80 2855.60 SCP 5777.0 74.30 235.20 3170.30 3114.10 Brook 2B 9005.0 69.90 233.10 4252.20 4196.00 Torok Top 11043.0 65.70 255.40 4980.10 4923.90 Torok Base 11495.0 63.20 263.50 5147.00 5117.80 ICP1 11887.0 64.00 276.70 5347.10 5290.90 Torok SH_1 11930.0 64.02 278.39 5365.59 5309.39 TD ICP1 11986.0 64.01 279.31 5390.13 5333.93 ODSN-23i PB2 Interpolated Tops Marker MD INC AZ TVD TVDSS Top Permafrost 857.0 23.10 277.80 838.20 782.00 Base Permafrost 1831.0 53.40 251.70 1667.70 1611.50 Top West Sak 3171.0 68.80 237.20 2316.90 2260.70 Tuffaceous Shale 4982.0 70.70 234.90 2911.80 2855.60 SCP 5777.0 74.30 235.20 3170.30 3114.10 Brook 2B 9005.0 69.90 233.10 4252.20 4196.00 Torok Top 11043.0 65.70 255.40 4980.10 4923.90 Torok Base 11495.0 63.20 263.50 5147.00 5117.80 ICP1 11887.0 64.00 276.70 5347.10 5290.90 Top HRZ 12871.0 67.50 294.80 5768.00 5711.80 Base HRZ 13214.0 67.40 311.40 5898.90 5842.70 Kalubik Marker 13411.0 68.10 319.10 5973.80 5917.60 Kup C 13568.0 68.70 325.40 6032.00 5975.80 LCU 13585.0 68.90 326.00 6038.20 5982.00 BCU 13865.0 75.30 331.40 6124.90 6068.70 BCU::Top Nuiqsut_D1 14039.0 76.44 330.20 6166.13 6109.93 Top Nuiqsut::Nuiq_1_D1 14048.0 76.50 330.10 6168.20 6112.00 ICP2 14082.0 76.60 330.00 6176.10 6119.90 Nuiq_1::Nuiq_2_D1 14301.0 83.88 331.45 6211.60 6155.40 Nuiq_2::Nuiq_3_D1 14380.0 86.00 331.37 6218.57 6162.47 Nuiq_3::Nuiq_4_D1 14589.0 87.48 326.12 6227.53 6171.33 Nuiq_4::Nuiq_5_D1 14675.0 87.37 324.09 6231.71 6175.51 Invert #1 15170.0 90.02 313.43 6251.07 6194.87 ODSN-23i Interpolated Tops Nuiq_5::Nuiq_4_U2 15557.0 93.50 311.92 6227.94 6171.74 Nuiq_4::Nuiq_3_U2 15611.0 93.04 310.64 6224.95 6168.75 Nuiq_3::Nuiq_2_U2 15770.0 93.77 308.44 6214.56 6158.46 Nuiq_2::Nuiq_1_U2 15804.0 93.61 307.94 6212.47 6156.27 Revert #1 16828.0 90.00 312.27 6179.89 6123.69 Nuiq_1::Nuiq_2_D3 17585.0 86.52 313.35 6215.91 6159.71 Fault 10' DTNW Nuiq _2::Nuiq_1 17638.0 86.41 313.34 6219.17 6162.97 Nuiq_1::Nuiq_2_D3 17750.0 85.91 312.52 6226.53 6170.33 Nuiq_2::Nuiq_3_D3 17833.0 85.34 311.37 6232.99 6176.79 Nuiq_3::Nuiq_4_D3 17996.0 85.80 311.76 6245.38 6189.18 Nuiq_4::Nuiq_5_D3 18066.0 86.01 311.27 6250.39 6195.12 Invert #2 18163.0 90.02 312.38 6254.99 6198.79 Nuiq_5::Nuiq_4_U4 18258.0 93.11 313.92 6251.32 6195.12 Nuiq_4::Nuiq_3_U4 18376.0 94.49 314.68 6243.59 6187.39 Nuiq_3::Nuiq_2_U4 18508.0 93.40 314.18 6234.41 6178.21 Nuiq_2::Nuiq_1_U4 18630.0 94.17 313.14 6226.14 6169.87 Revert #2 19335.0 90.02 312.81 6195.81 9139.63 Nuiq_1::Nuiq_2_D5 20062.0 87.15 313.96 6220.31 6164.11 Nuiq_2::Nuiq_3_D5 20142.0 86.92 312.92 6224.46 6168.26 Nuiq_3::Nuiq_4_D5 20295.0 86.85 314.01 6232.87 6176.67 Nuiq_4::Nuiq_5_D5 20468.0 87.21 314.69 6241.53 6185.33 TD 20550.0 87.06 314.81 6245.68 6189.48 13 July, 2011 Oooguruk Development Oooguruk Drill Site ODSN-23i PB1 Permit to Drill: 211-042 API: 50-703-20639-00-70 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' (copy) @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 PB1 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' (copy) @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Development Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSN-23i - Slot ODS-23 ft ft 0.00 0.00 6,031,018.57 469,788.76 13.50Wellhead Elevation:ft0.00 70° 29' 44.931 N 150° 14' 49.325 W Wellbore Declination (?) Field Strength (nT) Sample Date Dip Angle (?) ODSN-23i PB1 Model NameMagnetics IGRF200510 12/31/2009 21.99 80.81 57,759 Phase:Version: Audit Notes: Design ODSN-23i IN14 PB1 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (?) +E/-W (ft) Tie On Depth:42.70 274.770.000.0042.70 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 7/13/2011 Survey Start Date SR-Gyro-SS Fixed:v2:surface readout gyro single shot83.00 454.30 ODSN-23i Gyro Run100 (ODSN-23i PB1 05/16/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag495.48 2,585.21 ODSN-23i MWD Run200 (ODSN-23i PB1 05/16/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag2,678.19 6,012.33 ODSN-23i MWD Run300 (ODSN-23i PB1 05/17/2011 MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.70 0.00 0.00 42.70 0.00 0.00-13.50 6,031,018.57 469,788.76 0.00 0.00 UNDEFINED 83.00 0.11 124.69 83.00 -0.02 0.0326.80 6,031,018.55 469,788.79 0.27 -0.03 SR-Gyro-SS (1) 173.00 1.90 254.67 172.98 -0.46 -1.34116.78 6,031,018.11 469,787.42 2.19 1.29 SR-Gyro-SS (1) 265.00 6.05 264.54 264.74 -1.33 -7.64208.54 6,031,017.27 469,781.12 4.56 7.50 SR-Gyro-SS (1) 359.00 7.69 283.98 358.08 -0.28 -18.67301.88 6,031,018.37 469,770.09 3.00 18.58 SR-Gyro-SS (1) 453.00 9.09 287.10 451.07 3.42 -31.88394.87 6,031,022.12 469,756.90 1.57 32.05 SR-Gyro-SS (1) 587.93 13.80 284.62 583.28 10.62 -57.65527.08 6,031,029.43 469,731.16 3.51 58.33 MWD+IFR2+MS+sag (2) 685.36 16.51 286.20 677.31 17.42 -82.19621.11 6,031,036.32 469,706.65 2.81 83.35 MWD+IFR2+MS+sag (2) 780.68 21.35 281.09 767.46 24.54 -112.25711.26 6,031,043.56 469,676.63 5.36 113.89 MWD+IFR2+MS+sag (2) 871.01 23.44 277.27 850.97 29.98 -146.21794.77 6,031,049.14 469,642.69 2.82 148.19 MWD+IFR2+MS+sag (2) 970.93 22.57 272.75 942.95 33.41 -185.08886.75 6,031,052.73 469,603.84 1.97 187.21 MWD+IFR2+MS+sag (2) 1,064.78 22.63 268.75 1,029.60 33.88 -221.12973.40 6,031,053.35 469,567.80 1.64 223.17 MWD+IFR2+MS+sag (2) 7/13/2011 4:21:35PM COMPASS 2003.16 Build 42F Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' (copy) @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 PB1 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' (copy) @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 1,112.65 23.32 267.28 1,073.68 33.23 -239.791,017.48 6,031,052.77 469,549.13 1.87 241.72 MWD+IFR2+MS+sag (2) 1,156.84 25.14 265.47 1,113.97 32.08 -257.891,057.77 6,031,051.69 469,531.03 4.45 259.66 MWD+IFR2+MS+sag (2) 1,204.73 28.26 262.04 1,156.75 29.70 -279.271,100.55 6,031,049.40 469,509.64 7.26 280.77 MWD+IFR2+MS+sag (2) 1,253.23 29.44 259.91 1,199.23 26.02 -302.371,143.03 6,031,045.82 469,486.53 3.23 303.49 MWD+IFR2+MS+sag (2) 1,298.54 28.97 259.04 1,238.78 21.99 -324.111,182.58 6,031,041.87 469,464.78 1.40 324.81 MWD+IFR2+MS+sag (2) 1,347.34 30.19 256.53 1,281.22 16.88 -347.651,225.02 6,031,036.86 469,441.22 3.56 347.84 MWD+IFR2+MS+sag (2) 1,396.52 33.71 252.77 1,322.95 9.96 -372.721,266.75 6,031,030.04 469,416.12 8.22 372.25 MWD+IFR2+MS+sag (2) 1,441.02 35.45 252.00 1,359.59 2.31 -396.791,303.39 6,031,022.49 469,392.03 4.03 395.60 MWD+IFR2+MS+sag (2) 1,492.22 36.94 250.87 1,400.91 -7.32 -425.451,344.71 6,031,012.98 469,363.33 3.19 423.36 MWD+IFR2+MS+sag (2) 1,538.04 40.62 250.13 1,436.62 -16.91 -452.491,380.42 6,031,003.50 469,336.25 8.09 449.52 MWD+IFR2+MS+sag (2) 1,586.90 42.26 250.32 1,473.25 -27.85 -482.921,417.05 6,030,992.69 469,305.78 3.37 478.93 MWD+IFR2+MS+sag (2) 1,633.25 42.35 249.64 1,507.53 -38.53 -512.231,451.33 6,030,982.13 469,276.43 1.01 507.25 MWD+IFR2+MS+sag (2) 1,680.93 44.51 247.62 1,542.15 -50.48 -542.751,485.95 6,030,970.30 469,245.87 5.39 536.67 MWD+IFR2+MS+sag (2) 1,727.47 47.03 245.62 1,574.61 -63.72 -573.351,518.41 6,030,957.19 469,215.22 6.23 566.06 MWD+IFR2+MS+sag (2) 1,775.33 49.63 244.41 1,606.43 -78.83 -605.741,550.23 6,030,942.21 469,182.76 5.75 597.10 MWD+IFR2+MS+sag (2) 1,823.52 52.06 242.90 1,636.86 -95.42 -639.221,580.66 6,030,925.76 469,149.22 5.60 629.08 MWD+IFR2+MS+sag (2) 1,871.26 54.34 242.61 1,665.45 -112.92 -673.211,609.25 6,030,908.40 469,115.17 4.80 661.49 MWD+IFR2+MS+sag (2) 1,915.23 54.85 242.37 1,690.93 -129.47 -704.991,634.73 6,030,891.98 469,083.32 1.24 691.79 MWD+IFR2+MS+sag (2) 1,963.03 54.85 242.83 1,718.45 -147.46 -739.691,662.25 6,030,874.14 469,048.55 0.79 724.88 MWD+IFR2+MS+sag (2) 2,013.65 54.18 242.78 1,747.83 -166.29 -776.351,691.63 6,030,855.45 469,011.82 1.33 759.85 MWD+IFR2+MS+sag (2) 2,060.77 56.06 241.39 1,774.78 -184.39 -810.511,718.58 6,030,837.49 468,977.59 4.67 792.37 MWD+IFR2+MS+sag (2) 2,108.94 58.08 240.60 1,800.96 -204.00 -845.861,744.76 6,030,818.03 468,942.16 4.41 825.98 MWD+IFR2+MS+sag (2) 2,156.52 59.03 239.40 1,825.78 -224.30 -881.011,769.58 6,030,797.88 468,906.93 2.94 859.32 MWD+IFR2+MS+sag (2) 2,204.03 59.57 239.15 1,850.04 -245.17 -916.131,793.84 6,030,777.15 468,871.73 1.22 892.58 MWD+IFR2+MS+sag (2) 2,250.99 60.48 238.37 1,873.50 -266.27 -950.911,817.30 6,030,756.20 468,836.87 2.41 925.49 MWD+IFR2+MS+sag (2) 2,299.84 62.99 236.95 1,896.63 -289.29 -987.251,840.43 6,030,733.33 468,800.44 5.74 959.79 MWD+IFR2+MS+sag (2) 2,361.51 64.29 236.03 1,924.02 -319.79 -1,033.321,867.82 6,030,703.01 468,754.25 2.50 1,003.17 MWD+IFR2+MS+sag (2) 2,395.20 64.83 235.25 1,938.49 -336.96 -1,058.441,882.29 6,030,685.94 468,729.07 2.63 1,026.77 MWD+IFR2+MS+sag (2) 2,442.72 64.90 235.03 1,958.67 -361.55 -1,093.741,902.47 6,030,661.50 468,693.67 0.44 1,059.90 MWD+IFR2+MS+sag (2) 2,487.77 64.29 235.78 1,978.00 -384.66 -1,127.231,921.80 6,030,638.54 468,660.09 2.02 1,091.37 MWD+IFR2+MS+sag (2) 2,537.56 65.65 234.91 1,999.07 -410.31 -1,164.341,942.87 6,030,613.03 468,622.88 3.16 1,126.21 MWD+IFR2+MS+sag (2) 2,585.21 67.60 234.11 2,017.97 -435.71 -1,199.951,961.77 6,030,587.79 468,587.17 4.37 1,159.59 MWD+IFR2+MS+sag (2) 2,678.19 66.70 234.30 2,054.08 -485.82 -1,269.451,997.88 6,030,537.96 468,517.47 0.99 1,224.68 MWD+IFR2+MS+sag (3) 2,774.88 63.61 234.58 2,094.70 -536.84 -1,340.822,038.50 6,030,487.23 468,445.91 3.21 1,291.56 MWD+IFR2+MS+sag (3) 2,870.24 62.04 235.12 2,138.25 -585.68 -1,410.182,082.05 6,030,438.68 468,376.36 1.72 1,356.62 MWD+IFR2+MS+sag (3) 2,966.04 64.42 235.84 2,181.39 -634.15 -1,480.652,125.19 6,030,390.51 468,305.70 2.57 1,422.82 MWD+IFR2+MS+sag (3) 3,060.63 65.39 235.69 2,221.51 -682.34 -1,551.472,165.31 6,030,342.61 468,234.69 1.04 1,489.39 MWD+IFR2+MS+sag (3) 3,156.34 68.90 234.62 2,258.68 -732.73 -1,623.832,202.48 6,030,292.52 468,162.13 3.81 1,557.32 MWD+IFR2+MS+sag (3) 3,251.30 67.37 235.12 2,294.04 -783.44 -1,695.902,237.84 6,030,242.11 468,089.86 1.68 1,624.92 MWD+IFR2+MS+sag (3) 3,347.21 68.63 234.16 2,329.97 -834.90 -1,768.422,273.77 6,030,190.94 468,017.14 1.61 1,692.91 MWD+IFR2+MS+sag (3) 7/13/2011 4:21:35PM COMPASS 2003.16 Build 42F Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i PB1 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' (copy) @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 PB1 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' (copy) @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,442.08 67.97 234.29 2,365.05 -886.44 -1,839.942,308.85 6,030,139.71 467,945.42 0.71 1,759.90 MWD+IFR2+MS+sag (3) 3,534.15 70.34 234.19 2,397.81 -936.72 -1,909.752,341.61 6,030,089.72 467,875.41 2.58 1,825.30 MWD+IFR2+MS+sag (3) 3,632.50 69.22 234.65 2,431.80 -990.41 -1,984.812,375.60 6,030,036.33 467,800.14 1.22 1,895.63 MWD+IFR2+MS+sag (3) 3,727.60 69.09 233.88 2,465.64 -1,042.32 -2,056.952,409.44 6,029,984.72 467,727.80 0.77 1,963.21 MWD+IFR2+MS+sag (3) 3,817.38 71.04 234.01 2,496.25 -1,091.99 -2,125.182,440.05 6,029,935.33 467,659.37 2.18 2,027.08 MWD+IFR2+MS+sag (3) 3,916.25 69.60 235.31 2,529.55 -1,145.84 -2,201.122,473.35 6,029,881.80 467,583.23 1.91 2,098.27 MWD+IFR2+MS+sag (3) 4,009.19 70.27 235.70 2,561.44 -1,195.28 -2,273.062,505.24 6,029,832.66 467,511.09 0.82 2,165.86 MWD+IFR2+MS+sag (3) 4,109.17 71.25 235.23 2,594.38 -1,248.79 -2,350.822,538.18 6,029,779.47 467,433.12 1.08 2,238.91 MWD+IFR2+MS+sag (3) 4,203.92 71.96 235.40 2,624.28 -1,299.96 -2,424.752,568.08 6,029,728.61 467,358.99 0.77 2,308.33 MWD+IFR2+MS+sag (3) 4,299.32 71.05 233.81 2,654.55 -1,352.35 -2,498.502,598.35 6,029,676.52 467,285.03 1.85 2,377.47 MWD+IFR2+MS+sag (3) 4,394.71 69.94 235.64 2,686.40 -1,404.28 -2,571.902,630.20 6,029,624.89 467,211.43 2.15 2,446.30 MWD+IFR2+MS+sag (3) 4,489.93 70.78 234.23 2,718.40 -1,455.80 -2,645.302,662.20 6,029,573.68 467,137.83 1.65 2,515.16 MWD+IFR2+MS+sag (3) 4,584.01 70.07 234.05 2,749.92 -1,507.73 -2,717.142,693.72 6,029,522.05 467,065.79 0.78 2,582.44 MWD+IFR2+MS+sag (3) 4,680.61 71.11 234.74 2,782.03 -1,560.77 -2,791.222,725.83 6,029,469.31 466,991.50 1.27 2,651.85 MWD+IFR2+MS+sag (3) 4,774.32 70.02 235.62 2,813.21 -1,611.23 -2,863.762,757.01 6,029,419.15 466,918.76 1.46 2,719.95 MWD+IFR2+MS+sag (3) 4,870.15 70.60 234.26 2,845.50 -1,663.06 -2,937.612,789.30 6,029,367.63 466,844.71 1.47 2,789.24 MWD+IFR2+MS+sag (3) 4,965.64 71.18 233.97 2,876.76 -1,715.95 -3,010.722,820.56 6,029,315.04 466,771.40 0.67 2,857.69 MWD+IFR2+MS+sag (3) 5,060.30 70.66 233.88 2,907.70 -1,768.63 -3,083.022,851.50 6,029,262.67 466,698.89 0.56 2,925.37 MWD+IFR2+MS+sag (3) 5,154.96 69.55 234.34 2,939.91 -1,820.81 -3,155.132,883.71 6,029,210.78 466,626.57 1.26 2,992.89 MWD+IFR2+MS+sag (3) 5,252.09 70.00 234.83 2,973.49 -1,873.62 -3,229.412,917.29 6,029,158.28 466,552.09 0.66 3,062.52 MWD+IFR2+MS+sag (3) 5,345.78 70.53 235.36 3,005.13 -1,924.08 -3,301.732,948.93 6,029,108.11 466,479.57 0.78 3,130.40 MWD+IFR2+MS+sag (3) 5,441.85 70.71 233.72 3,037.01 -1,976.66 -3,375.542,980.81 6,029,055.85 466,405.55 1.62 3,199.59 MWD+IFR2+MS+sag (3) 5,536.91 70.79 231.62 3,068.35 -2,031.08 -3,446.903,012.15 6,029,001.72 466,333.98 2.09 3,266.18 MWD+IFR2+MS+sag (3) 5,632.20 71.12 231.33 3,099.45 -2,087.18 -3,517.373,043.25 6,028,945.91 466,263.29 0.45 3,331.74 MWD+IFR2+MS+sag (3) 5,727.30 69.35 231.83 3,131.60 -2,142.79 -3,587.483,075.40 6,028,890.59 466,192.96 1.93 3,396.99 MWD+IFR2+MS+sag (3) 5,822.70 67.82 232.84 3,166.44 -2,197.06 -3,657.783,110.24 6,028,836.61 466,122.45 1.88 3,462.54 MWD+IFR2+MS+sag (3) 5,870.17 68.49 233.51 3,184.10 -2,223.47 -3,693.053,127.90 6,028,810.35 466,087.08 1.93 3,495.49 MWD+IFR2+MS+sag (3) 5,917.56 69.87 234.72 3,200.94 -2,249.43 -3,728.943,144.74 6,028,784.54 466,051.09 3.76 3,529.09 MWD+IFR2+MS+sag (3) 6,012.33 68.42 236.05 3,234.68 -2,299.74 -3,801.823,178.48 6,028,734.53 465,978.01 2.02 3,597.54 MWD+IFR2+MS+sag (3) 6,079.00 68.42 236.05 3,259.21 -2,334.37 -3,853.243,203.01 6,028,700.12 465,926.45 0.00 3,645.91 PROJECTED to TD 7/13/2011 4:21:35PM COMPASS 2003.16 Build 42F Page 4 13 July, 2011 Oooguruk Development Oooguruk Drill Site ODSN-23i PB2 Permit to Drill: 211-042 API: 50-703-20639-00-71 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 PB2 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Development Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSN-23i - Slot ODS-23 ft ft 0.00 0.00 6,031,018.57 469,788.76 13.50Wellhead Elevation:ft0.00 70° 29' 44.931 N 150° 14' 49.325 W Wellbore Declination (?) Field Strength (nT) Sample Date Dip Angle (?) ODSN-23i PB2 Model NameMagnetics IGRF200510 12/31/2009 21.99 80.81 57,759 Phase:Version: Audit Notes: Design ODSN-23i IN14 PB2 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (?) +E/-W (ft) Tie On Depth:780.68 274.770.000.0042.70 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 7/13/2011 Survey Start Date SR-Gyro-SS Fixed:v2:surface readout gyro single shot83.00 454.30 ODSN-23i Gyro Run100 (ODSN-23i PB1 05/16/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag495.48 780.68 ODSN-23i MWD Run200 (ODSN-23i PB1 05/16/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag875.01 2,584.38 ODSN-23i MWD Run 400 (ODSN-23i PB 05/23/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag2,679.92 5,727.62 ODSN-23i MWD Run500 (ODSN-23i PB2 05/24/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag5,827.98 5,859.47 ODSN-23i MWD Run 600 (ODSN-23i PB 05/31/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag5,954.20 11,953.62 ODSN-23i MWD Run 700 (ODSN-23i PB 06/01/2011 MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.70 0.00 0.00 42.70 0.00 0.00-13.50 6,031,018.57 469,788.76 0.00 0.00 UNDEFINED 83.00 0.11 124.69 83.00 -0.02 0.0326.80 6,031,018.55 469,788.79 0.27 -0.03 SR-Gyro-SS (1) 173.00 1.90 254.67 172.98 -0.46 -1.34116.78 6,031,018.11 469,787.42 2.19 1.29 SR-Gyro-SS (1) 265.00 6.05 264.54 264.74 -1.33 -7.64208.54 6,031,017.27 469,781.12 4.56 7.50 SR-Gyro-SS (1) 359.00 7.69 283.98 358.08 -0.28 -18.67301.88 6,031,018.37 469,770.09 3.00 18.58 SR-Gyro-SS (1) 453.00 9.09 287.10 451.07 3.42 -31.88394.87 6,031,022.12 469,756.90 1.57 32.05 SR-Gyro-SS (1) 587.93 13.80 284.62 583.28 10.62 -57.65527.08 6,031,029.43 469,731.16 3.51 58.33 MWD+IFR2+MS+sag (2) 685.36 16.51 286.20 677.31 17.42 -82.19621.11 6,031,036.32 469,706.65 2.81 83.35 MWD+IFR2+MS+sag (2) 780.68 21.35 281.09 767.46 24.54 -112.25711.26 6,031,043.56 469,676.63 5.36 113.89 MWD+IFR2+MS+sag (2) 875.01 22.30 278.86 855.03 30.60 -146.78798.83 6,031,049.76 469,642.12 1.34 148.81 MWD+IFR2+MS+sag (3) 7/13/2011 3:47:03PM COMPASS 2003.16 Build 42F Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 PB2 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 966.28 21.46 281.45 939.72 36.58 -180.26883.52 6,031,055.88 469,608.67 1.40 182.67 MWD+IFR2+MS+sag (3) 1,062.82 19.33 280.25 1,030.21 42.93 -213.29974.01 6,031,062.36 469,575.67 2.25 216.12 MWD+IFR2+MS+sag (3) 1,159.74 22.58 272.06 1,120.72 46.46 -247.691,064.52 6,031,066.03 469,541.29 4.51 250.69 MWD+IFR2+MS+sag (3) 1,252.62 24.68 269.02 1,205.82 46.77 -284.901,149.62 6,031,066.49 469,504.08 2.61 287.80 MWD+IFR2+MS+sag (3) 1,301.68 24.84 267.56 1,250.37 46.15 -305.441,194.17 6,031,065.96 469,483.54 1.29 308.21 MWD+IFR2+MS+sag (3) 1,350.08 26.59 265.51 1,293.97 44.87 -326.401,237.77 6,031,064.76 469,462.58 4.06 328.99 MWD+IFR2+MS+sag (3) 1,398.48 29.43 261.55 1,336.70 42.27 -348.961,280.50 6,031,062.26 469,440.01 7.01 351.27 MWD+IFR2+MS+sag (3) 1,444.53 31.47 259.13 1,376.40 38.34 -371.961,320.20 6,031,058.42 469,417.00 5.17 373.86 MWD+IFR2+MS+sag (3) 1,497.84 33.19 257.50 1,421.44 32.56 -399.871,365.24 6,031,052.75 469,389.06 3.62 401.20 MWD+IFR2+MS+sag (3) 1,540.36 34.41 257.52 1,456.78 27.45 -422.971,400.58 6,031,047.73 469,365.95 2.87 423.78 MWD+IFR2+MS+sag (3) 1,586.99 35.48 255.83 1,495.00 21.29 -448.951,438.80 6,031,041.68 469,339.94 3.09 449.17 MWD+IFR2+MS+sag (3) 1,635.09 38.39 254.87 1,533.44 13.97 -476.911,477.24 6,031,034.48 469,311.96 6.17 476.42 MWD+IFR2+MS+sag (3) 1,685.31 43.40 253.82 1,571.39 5.09 -508.561,515.19 6,031,025.72 469,280.28 10.07 507.21 MWD+IFR2+MS+sag (3) 1,730.45 46.30 253.83 1,603.39 -3.78 -539.131,547.19 6,031,016.98 469,249.68 6.42 536.94 MWD+IFR2+MS+sag (3) 1,758.15 48.19 252.88 1,622.20 -9.61 -558.611,566.00 6,031,011.23 469,230.17 7.27 555.88 MWD+IFR2+MS+sag (3) 1,792.58 51.17 251.66 1,644.47 -17.61 -583.611,588.27 6,031,003.34 469,205.14 9.07 580.12 MWD+IFR2+MS+sag (3) 1,824.25 53.27 251.73 1,663.87 -25.47 -607.371,607.67 6,030,995.57 469,181.35 6.63 603.15 MWD+IFR2+MS+sag (3) 1,869.48 54.18 251.31 1,690.63 -37.03 -641.961,634.43 6,030,984.15 469,146.72 2.15 636.65 MWD+IFR2+MS+sag (3) 1,918.83 54.83 249.80 1,719.29 -50.41 -679.841,663.09 6,030,970.93 469,108.79 2.82 673.29 MWD+IFR2+MS+sag (3) 1,967.34 56.52 247.40 1,746.65 -65.03 -717.131,690.45 6,030,956.46 469,071.44 5.37 709.24 MWD+IFR2+MS+sag (3) 2,013.76 56.77 246.04 1,772.17 -80.35 -752.751,715.97 6,030,941.29 469,035.77 2.51 743.46 MWD+IFR2+MS+sag (3) 2,062.04 57.14 245.08 1,798.50 -97.10 -789.591,742.30 6,030,924.69 468,998.86 1.83 778.78 MWD+IFR2+MS+sag (3) 2,110.44 57.77 244.46 1,824.53 -114.49 -826.501,768.33 6,030,907.45 468,961.89 1.69 814.11 MWD+IFR2+MS+sag (3) 2,156.66 57.66 243.31 1,849.22 -131.69 -861.581,793.02 6,030,890.40 468,926.74 2.12 847.64 MWD+IFR2+MS+sag (3) 2,204.43 58.37 242.33 1,874.53 -150.20 -897.621,818.33 6,030,872.04 468,890.62 2.29 882.02 MWD+IFR2+MS+sag (3) 2,250.10 58.41 241.49 1,898.46 -168.51 -931.941,842.26 6,030,853.87 468,856.24 1.57 914.69 MWD+IFR2+MS+sag (3) 2,300.22 58.62 240.42 1,924.64 -189.26 -969.301,868.44 6,030,833.27 468,818.80 1.87 950.20 MWD+IFR2+MS+sag (3) 2,347.25 59.76 238.29 1,948.73 -209.85 -1,004.051,892.53 6,030,812.82 468,783.97 4.58 983.12 MWD+IFR2+MS+sag (3) 2,396.72 60.81 236.29 1,973.25 -233.07 -1,040.191,917.05 6,030,789.75 468,747.73 4.10 1,017.21 MWD+IFR2+MS+sag (3) 2,443.41 61.71 234.93 1,995.70 -256.19 -1,073.971,939.50 6,030,766.77 468,713.86 3.20 1,048.95 MWD+IFR2+MS+sag (3) 2,490.14 62.42 234.78 2,017.60 -279.96 -1,107.731,961.40 6,030,743.14 468,680.01 1.55 1,080.61 MWD+IFR2+MS+sag (3) 2,537.76 63.92 234.91 2,039.09 -304.43 -1,142.471,982.89 6,030,718.82 468,645.17 3.16 1,113.20 MWD+IFR2+MS+sag (3) 2,584.38 64.07 235.24 2,059.53 -328.41 -1,176.832,003.33 6,030,694.97 468,610.73 0.71 1,145.44 MWD+IFR2+MS+sag (3) 2,679.92 61.17 235.63 2,103.46 -376.54 -1,246.682,047.26 6,030,647.13 468,540.69 3.06 1,211.05 MWD+IFR2+MS+sag (4) 2,775.45 60.34 238.49 2,150.14 -421.87 -1,316.622,093.94 6,030,602.10 468,470.57 2.75 1,276.97 MWD+IFR2+MS+sag (4) 2,823.60 59.67 237.60 2,174.21 -443.94 -1,352.002,118.01 6,030,580.18 468,435.10 2.12 1,310.40 MWD+IFR2+MS+sag (4) 2,870.81 61.77 236.77 2,197.30 -466.25 -1,386.602,141.10 6,030,558.00 468,400.41 4.71 1,343.03 MWD+IFR2+MS+sag (4) 2,920.58 64.12 237.31 2,219.94 -490.36 -1,423.792,163.74 6,030,534.05 468,363.13 4.82 1,378.08 MWD+IFR2+MS+sag (4) 2,963.49 65.98 237.85 2,238.04 -511.22 -1,456.632,181.84 6,030,513.33 468,330.21 4.48 1,409.07 MWD+IFR2+MS+sag (4) 3,060.12 67.95 237.77 2,275.84 -558.59 -1,531.882,219.64 6,030,466.27 468,254.77 2.04 1,480.13 MWD+IFR2+MS+sag (4) 7/13/2011 3:47:03PM COMPASS 2003.16 Build 42F Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 PB2 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 3,110.19 67.93 238.41 2,294.65 -583.12 -1,571.282,238.45 6,030,441.90 468,215.29 1.19 1,517.34 MWD+IFR2+MS+sag (4) 3,157.11 68.56 237.36 2,312.04 -606.29 -1,608.182,255.84 6,030,418.89 468,178.29 2.47 1,552.20 MWD+IFR2+MS+sag (4) 3,250.45 70.06 236.47 2,345.02 -653.95 -1,681.342,288.82 6,030,371.52 468,104.94 1.84 1,621.14 MWD+IFR2+MS+sag (4) 3,346.32 69.32 236.47 2,378.29 -703.62 -1,756.292,322.09 6,030,322.17 468,029.80 0.77 1,691.69 MWD+IFR2+MS+sag (4) 3,441.21 71.31 234.96 2,410.26 -753.95 -1,830.102,354.06 6,030,272.14 467,955.80 2.58 1,761.06 MWD+IFR2+MS+sag (4) 3,537.18 72.49 234.97 2,440.07 -806.31 -1,904.792,383.87 6,030,220.08 467,880.90 1.23 1,831.14 MWD+IFR2+MS+sag (4) 3,633.78 71.56 235.52 2,469.88 -858.70 -1,980.282,413.68 6,030,168.02 467,805.21 1.10 1,902.01 MWD+IFR2+MS+sag (4) 3,727.51 71.08 236.81 2,499.91 -908.14 -2,054.032,443.71 6,030,118.88 467,731.26 1.40 1,971.40 MWD+IFR2+MS+sag (4) 3,823.02 70.92 234.68 2,531.00 -958.96 -2,128.672,474.80 6,030,068.36 467,656.43 2.12 2,041.55 MWD+IFR2+MS+sag (4) 3,917.46 71.29 234.99 2,561.59 -1,010.42 -2,201.712,505.39 6,030,017.21 467,583.18 0.50 2,110.06 MWD+IFR2+MS+sag (4) 4,013.68 72.34 235.27 2,591.62 -1,062.68 -2,276.712,535.42 6,029,965.25 467,507.98 1.13 2,180.46 MWD+IFR2+MS+sag (4) 4,108.26 71.32 234.13 2,621.11 -1,114.61 -2,350.052,564.91 6,029,913.63 467,434.43 1.57 2,249.23 MWD+IFR2+MS+sag (4) 4,203.85 69.04 233.93 2,653.52 -1,167.42 -2,422.832,597.32 6,029,861.12 467,361.45 2.39 2,317.36 MWD+IFR2+MS+sag (4) 4,300.09 69.69 234.26 2,687.43 -1,220.24 -2,495.782,631.23 6,029,808.60 467,288.29 0.75 2,385.67 MWD+IFR2+MS+sag (4) 4,394.97 70.98 234.18 2,719.36 -1,272.48 -2,568.262,663.16 6,029,756.67 467,215.60 1.36 2,453.55 MWD+IFR2+MS+sag (4) 4,489.73 69.75 234.55 2,751.20 -1,324.48 -2,640.802,695.00 6,029,704.97 467,142.87 1.35 2,521.51 MWD+IFR2+MS+sag (4) 4,584.99 70.99 235.27 2,783.21 -1,376.05 -2,714.222,727.01 6,029,653.70 467,069.25 1.48 2,590.39 MWD+IFR2+MS+sag (4) 4,680.34 70.58 235.23 2,814.59 -1,427.37 -2,788.202,758.39 6,029,602.68 466,995.07 0.43 2,659.84 MWD+IFR2+MS+sag (4) 4,775.29 70.71 234.45 2,846.06 -1,478.96 -2,861.432,789.86 6,029,551.40 466,921.63 0.79 2,728.54 MWD+IFR2+MS+sag (4) 4,870.87 72.27 234.19 2,876.40 -1,531.82 -2,935.052,820.20 6,029,498.84 466,847.80 1.65 2,797.50 MWD+IFR2+MS+sag (4) 4,965.85 70.52 234.82 2,906.70 -1,584.09 -3,008.342,850.50 6,029,446.88 466,774.32 1.95 2,866.19 MWD+IFR2+MS+sag (4) 5,062.17 71.56 235.12 2,938.00 -1,636.38 -3,082.932,881.80 6,029,394.90 466,699.52 1.12 2,936.17 MWD+IFR2+MS+sag (4) 5,158.21 70.37 234.77 2,969.32 -1,688.52 -3,157.252,913.12 6,029,343.06 466,625.00 1.29 3,005.90 MWD+IFR2+MS+sag (4) 5,252.24 70.84 233.85 3,000.54 -1,740.27 -3,229.282,944.34 6,029,291.62 466,552.76 1.05 3,073.38 MWD+IFR2+MS+sag (4) 5,346.02 68.94 234.15 3,032.79 -1,792.03 -3,300.522,976.59 6,029,240.15 466,481.32 2.05 3,140.07 MWD+IFR2+MS+sag (4) 5,441.55 68.96 234.00 3,067.10 -1,844.34 -3,372.723,010.90 6,029,188.14 466,408.92 0.15 3,207.67 MWD+IFR2+MS+sag (4) 5,535.28 70.77 234.10 3,099.36 -1,896.00 -3,443.953,043.16 6,029,136.78 466,337.48 1.93 3,274.36 MWD+IFR2+MS+sag (4) 5,634.19 72.77 234.65 3,130.30 -1,950.71 -3,520.313,074.10 6,029,082.38 466,260.90 2.09 3,345.91 MWD+IFR2+MS+sag (4) 5,727.62 73.96 234.84 3,157.05 -2,002.38 -3,593.413,100.85 6,029,031.01 466,187.60 1.29 3,414.46 MWD+IFR2+MS+sag (4) 5,827.98 74.63 235.65 3,184.22 -2,057.46 -3,672.793,128.02 6,028,976.26 466,108.01 1.02 3,488.98 MWD+IFR2+MS+sag (5) 5,859.47 74.06 235.70 3,192.71 -2,074.56 -3,697.833,136.51 6,028,959.27 466,082.90 1.82 3,512.51 MWD+IFR2+MS+sag (5) 5,954.20 72.71 235.60 3,219.80 -2,125.77 -3,772.783,163.60 6,028,908.36 466,007.76 1.43 3,582.93 MWD+IFR2+MS+sag (6) 6,049.58 71.13 235.57 3,249.40 -2,177.02 -3,847.573,193.20 6,028,857.43 465,932.76 1.66 3,653.21 MWD+IFR2+MS+sag (6) 6,143.90 69.31 235.69 3,281.32 -2,227.12 -3,920.833,225.12 6,028,807.62 465,859.31 1.93 3,722.05 MWD+IFR2+MS+sag (6) 6,239.57 69.26 235.79 3,315.16 -2,277.50 -3,994.793,258.96 6,028,757.56 465,785.15 0.11 3,791.56 MWD+IFR2+MS+sag (6) 6,335.17 70.31 236.02 3,348.19 -2,327.79 -4,069.083,291.99 6,028,707.57 465,710.67 1.12 3,861.41 MWD+IFR2+MS+sag (6) 6,430.21 69.76 236.09 3,380.64 -2,377.67 -4,143.183,324.44 6,028,658.00 465,636.37 0.58 3,931.11 MWD+IFR2+MS+sag (6) 6,525.92 69.79 235.78 3,413.73 -2,427.97 -4,217.583,357.53 6,028,608.00 465,561.77 0.31 4,001.07 MWD+IFR2+MS+sag (6) 6,620.41 70.25 235.10 3,446.02 -2,478.35 -4,290.713,389.82 6,028,557.93 465,488.45 0.83 4,069.76 MWD+IFR2+MS+sag (6) 6,716.41 69.86 234.27 3,478.76 -2,530.51 -4,364.353,422.56 6,028,506.07 465,414.61 0.91 4,138.80 MWD+IFR2+MS+sag (6) 7/13/2011 3:47:03PM COMPASS 2003.16 Build 42F Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 PB2 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 6,811.32 70.18 232.95 3,511.19 -2,583.43 -4,436.153,454.99 6,028,453.45 465,342.60 1.35 4,205.95 MWD+IFR2+MS+sag (6) 6,906.79 70.38 233.33 3,543.41 -2,637.34 -4,508.053,487.21 6,028,399.84 465,270.48 0.43 4,273.13 MWD+IFR2+MS+sag (6) 7,000.73 70.18 232.88 3,575.11 -2,690.43 -4,578.773,518.91 6,028,347.04 465,199.55 0.50 4,339.19 MWD+IFR2+MS+sag (6) 7,097.05 70.43 232.73 3,607.57 -2,745.25 -4,651.013,551.37 6,028,292.52 465,127.10 0.30 4,406.62 MWD+IFR2+MS+sag (6) 7,192.13 70.44 232.84 3,639.41 -2,799.44 -4,722.363,583.21 6,028,238.63 465,055.54 0.11 4,473.21 MWD+IFR2+MS+sag (6) 7,287.67 70.12 233.52 3,671.65 -2,853.33 -4,794.353,615.45 6,028,185.03 464,983.33 0.75 4,540.48 MWD+IFR2+MS+sag (6) 7,382.83 70.31 232.70 3,703.86 -2,907.08 -4,865.973,647.66 6,028,131.58 464,911.51 0.84 4,607.37 MWD+IFR2+MS+sag (6) 7,477.61 70.70 232.56 3,735.49 -2,961.31 -4,936.983,679.29 6,028,077.64 464,840.29 0.43 4,673.62 MWD+IFR2+MS+sag (6) 7,572.91 69.92 232.46 3,767.60 -3,015.92 -5,008.173,711.40 6,028,023.33 464,768.88 0.82 4,740.03 MWD+IFR2+MS+sag (6) 7,664.65 70.64 232.47 3,798.55 -3,068.54 -5,076.653,742.35 6,027,971.00 464,700.19 0.78 4,803.90 MWD+IFR2+MS+sag (6) 7,760.60 70.63 233.12 3,830.37 -3,123.27 -5,148.753,774.17 6,027,916.56 464,627.88 0.64 4,871.20 MWD+IFR2+MS+sag (6) 7,856.07 69.85 234.09 3,862.64 -3,176.59 -5,221.073,806.44 6,027,863.55 464,555.35 1.26 4,938.83 MWD+IFR2+MS+sag (6) 7,953.12 69.72 234.39 3,896.18 -3,229.81 -5,294.973,839.98 6,027,810.63 464,481.24 0.32 5,008.05 MWD+IFR2+MS+sag (6) 8,048.34 69.91 233.63 3,929.04 -3,282.33 -5,367.283,872.84 6,027,758.41 464,408.72 0.78 5,075.75 MWD+IFR2+MS+sag (6) 8,143.84 69.97 233.40 3,961.79 -3,335.67 -5,439.413,905.59 6,027,705.37 464,336.39 0.23 5,143.19 MWD+IFR2+MS+sag (6) 8,239.93 69.84 234.12 3,994.81 -3,389.01 -5,512.193,938.61 6,027,652.33 464,263.40 0.72 5,211.28 MWD+IFR2+MS+sag (6) 8,334.21 69.84 234.59 4,027.30 -3,440.59 -5,584.113,971.10 6,027,601.05 464,191.28 0.47 5,278.66 MWD+IFR2+MS+sag (6) 8,428.63 70.30 235.71 4,059.49 -3,491.31 -5,656.964,003.29 6,027,550.63 464,118.23 1.22 5,347.04 MWD+IFR2+MS+sag (6) 8,525.27 70.77 235.28 4,091.69 -3,542.93 -5,732.044,035.49 6,027,499.32 464,042.94 0.64 5,417.57 MWD+IFR2+MS+sag (6) 8,620.64 70.17 235.61 4,123.57 -3,593.91 -5,806.074,067.37 6,027,448.65 463,968.72 0.71 5,487.10 MWD+IFR2+MS+sag (6) 8,715.48 70.57 235.40 4,155.43 -3,644.50 -5,879.694,099.23 6,027,398.36 463,894.90 0.47 5,556.26 MWD+IFR2+MS+sag (6) 8,811.36 70.83 234.56 4,187.12 -3,696.43 -5,953.804,130.92 6,027,346.74 463,820.59 0.87 5,625.79 MWD+IFR2+MS+sag (6) 8,906.22 70.30 233.34 4,218.69 -3,749.07 -6,026.124,162.49 6,027,294.40 463,748.06 1.34 5,693.49 MWD+IFR2+MS+sag (6) 9,001.02 69.84 233.07 4,251.00 -3,802.45 -6,097.494,194.80 6,027,241.32 463,676.48 0.55 5,760.17 MWD+IFR2+MS+sag (6) 9,092.51 70.24 233.43 4,282.23 -3,853.90 -6,166.394,226.03 6,027,190.15 463,607.38 0.57 5,824.56 MWD+IFR2+MS+sag (6) 9,188.01 70.05 233.76 4,314.67 -3,907.21 -6,238.694,258.47 6,027,137.14 463,534.88 0.38 5,892.17 MWD+IFR2+MS+sag (6) 9,282.68 70.10 234.41 4,346.93 -3,959.42 -6,310.774,290.73 6,027,085.23 463,462.59 0.65 5,959.66 MWD+IFR2+MS+sag (6) 9,380.15 69.85 234.32 4,380.31 -4,012.77 -6,385.204,324.11 6,027,032.19 463,387.95 0.27 6,029.39 MWD+IFR2+MS+sag (6) 9,472.29 69.83 235.20 4,412.06 -4,062.68 -6,455.844,355.86 6,026,982.57 463,317.12 0.90 6,095.64 MWD+IFR2+MS+sag (6) 9,568.74 70.11 234.28 4,445.10 -4,114.99 -6,529.834,388.90 6,026,930.57 463,242.92 0.94 6,165.03 MWD+IFR2+MS+sag (6) 9,666.12 70.05 233.69 4,478.28 -4,168.82 -6,603.884,422.08 6,026,877.04 463,168.66 0.57 6,234.35 MWD+IFR2+MS+sag (6) 9,760.80 70.31 233.31 4,510.38 -4,221.80 -6,675.484,454.18 6,026,824.36 463,096.85 0.47 6,301.29 MWD+IFR2+MS+sag (6) 9,858.38 70.24 233.07 4,543.32 -4,276.84 -6,749.034,487.12 6,026,769.62 463,023.09 0.24 6,370.00 MWD+IFR2+MS+sag (6) 9,952.01 70.12 233.37 4,575.06 -4,329.58 -6,819.574,518.86 6,026,717.18 462,952.34 0.33 6,435.92 MWD+IFR2+MS+sag (6) 10,048.39 70.17 233.62 4,607.80 -4,383.51 -6,892.444,551.60 6,026,663.55 462,879.26 0.25 6,504.05 MWD+IFR2+MS+sag (6) 10,143.67 70.31 233.81 4,640.01 -4,436.57 -6,964.724,583.81 6,026,610.79 462,806.77 0.24 6,571.67 MWD+IFR2+MS+sag (6) 10,237.91 70.19 233.55 4,671.86 -4,489.11 -7,036.194,615.66 6,026,558.55 462,735.10 0.29 6,638.52 MWD+IFR2+MS+sag (6) 10,334.15 69.58 234.87 4,704.95 -4,541.96 -7,109.494,648.75 6,026,506.00 462,661.59 1.44 6,707.17 MWD+IFR2+MS+sag (6) 10,428.83 68.44 235.68 4,738.87 -4,592.31 -7,182.144,682.67 6,026,455.95 462,588.75 1.44 6,775.38 MWD+IFR2+MS+sag (6) 10,524.78 67.78 238.57 4,774.65 -4,640.64 -7,256.904,718.45 6,026,407.93 462,513.80 2.88 6,845.86 MWD+IFR2+MS+sag (6) 7/13/2011 3:47:03PM COMPASS 2003.16 Build 42F Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i PB2 Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 PB2 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 10,620.63 67.20 242.31 4,811.35 -4,684.32 -7,333.904,755.15 6,026,364.57 462,436.63 3.65 6,918.97 MWD+IFR2+MS+sag (6) 10,714.50 66.99 245.65 4,847.90 -4,722.24 -7,411.594,791.70 6,026,326.96 462,358.79 3.29 6,993.23 MWD+IFR2+MS+sag (6) 10,810.13 66.66 248.76 4,885.54 -4,756.30 -7,492.624,829.34 6,026,293.24 462,277.63 3.01 7,071.15 MWD+IFR2+MS+sag (6) 10,902.18 65.85 251.88 4,922.61 -4,784.68 -7,571.944,866.41 6,026,265.19 462,198.20 3.22 7,147.84 MWD+IFR2+MS+sag (6) 11,000.42 65.84 254.39 4,962.82 -4,810.68 -7,657.714,906.62 6,026,239.53 462,112.33 2.33 7,231.15 MWD+IFR2+MS+sag (6) 11,095.21 65.58 256.70 5,001.81 -4,832.25 -7,741.374,945.61 6,026,218.31 462,028.60 2.24 7,312.72 MWD+IFR2+MS+sag (6) 11,191.27 65.23 257.82 5,041.80 -4,851.51 -7,826.564,985.60 6,026,199.40 461,943.34 1.12 7,396.02 MWD+IFR2+MS+sag (6) 11,283.10 64.68 258.80 5,080.67 -4,868.37 -7,908.035,024.47 6,026,182.87 461,861.81 1.14 7,475.80 MWD+IFR2+MS+sag (6) 11,377.97 63.87 261.34 5,121.85 -4,883.11 -7,992.215,065.65 6,026,168.47 461,777.58 2.56 7,558.46 MWD+IFR2+MS+sag (6) 11,476.80 63.12 262.96 5,165.96 -4,895.19 -8,079.815,109.76 6,026,156.75 461,689.93 1.65 7,644.76 MWD+IFR2+MS+sag (6) 11,572.62 63.33 265.88 5,209.14 -4,903.51 -8,164.945,152.94 6,026,148.78 461,604.78 2.73 7,728.90 MWD+IFR2+MS+sag (6) 11,667.48 64.01 268.53 5,251.22 -4,907.65 -8,249.855,195.02 6,026,144.98 461,519.87 2.60 7,813.17 MWD+IFR2+MS+sag (6) 11,763.15 64.28 271.90 5,292.95 -4,907.32 -8,335.935,236.75 6,026,145.66 461,433.80 3.18 7,898.98 MWD+IFR2+MS+sag (6) 11,858.05 64.06 275.60 5,334.31 -4,901.74 -8,421.145,278.11 6,026,151.59 461,348.62 3.52 7,984.36 MWD+IFR2+MS+sag (6) 11,953.62 64.01 279.31 5,376.16 -4,890.59 -8,506.325,319.96 6,026,163.08 461,263.50 3.49 8,070.17 MWD+IFR2+MS+sag (6) 11,986.00 64.01 279.31 5,390.35 -4,885.89 -8,535.045,334.15 6,026,167.90 461,234.80 0.00 8,099.18 PROJECTED to TD 7/13/2011 3:47:03PM COMPASS 2003.16 Build 42F Page 6 14 July, 2011 Oooguruk Development Oooguruk Drill Site ODSN-23i Permit to Drill: 211-042 API: 50-703-20639-00-00 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Oooguruk Development Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: ft +E/-W +N/-S Position Uncertainty ft ft ftGround Level: ODSN-23i - Slot ODS-23 ft ft 0.00 0.00 6,031,018.57 469,788.76 13.50Wellhead Elevation:ft0.00 70° 29' 44.931 N 150° 14' 49.325 W Wellbore Declination (?) Field Strength (nT) Sample Date Dip Angle (?) ODSN-23i Model NameMagnetics IGRF200510 12/31/2009 21.99 80.81 57,759 Phase:Version: Audit Notes: Design ODSN-23i IN14 1.0 ACTUAL Vertical Section: Depth From (TVD) (ft) +N/-S (ft) Direction (?) +E/-W (ft) Tie On Depth:11,658.00 274.770.000.0042.70 From (ft) Survey Program DescriptionTool NameSurvey (Wellbore) To (ft) Date 7/13/2011 Survey Start Date SR-Gyro-SS Fixed:v2:surface readout gyro single shot83.00 454.30 ODSN-23i Gyro Run100 (ODSN-23i PB1 05/16/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag495.48 780.68 ODSN-23i MWD Run200 (ODSN-23i PB1 05/16/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag875.01 2,584.38 ODSN-23i MWD Run 400 (ODSN-23i PB 05/23/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag2,679.92 5,727.62 ODSN-23i MWD Run500 (ODSN-23i PB2 05/24/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag5,827.98 5,859.47 ODSN-23i MWD Run 600 (ODSN-23i PB 05/31/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag5,954.20 11,658.00 ODSN-23i MWD Run 700 (ODSN-23i PB 06/01/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag11,747.54 14,091.00 ODST-23i MWD Run 800 (ODSN-23i)06/23/2011 MWD+IFR2+MS+sag Fixed:v2:IIFR dec & 3-axis correction + sag14,152.43 20,514.89 ODSN-23i MWD Run 900 (ODSN-23i)07/11/2011 MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 42.70 0.00 0.00 42.70 0.00 0.00-13.50 6,031,018.57 469,788.76 0.00 0.00 UNDEFINED 83.00 0.11 124.69 83.00 -0.02 0.0326.80 6,031,018.55 469,788.79 0.27 -0.03 SR-Gyro-SS (1) 173.00 1.90 254.67 172.98 -0.46 -1.34116.78 6,031,018.11 469,787.42 2.19 1.29 SR-Gyro-SS (1) 265.00 6.05 264.54 264.74 -1.33 -7.64208.54 6,031,017.27 469,781.12 4.56 7.50 SR-Gyro-SS (1) 359.00 7.69 283.98 358.08 -0.28 -18.67301.88 6,031,018.37 469,770.09 3.00 18.58 SR-Gyro-SS (1) 453.00 9.09 287.10 451.07 3.42 -31.88394.87 6,031,022.12 469,756.90 1.57 32.05 SR-Gyro-SS (1) 587.93 13.80 284.62 583.28 10.62 -57.65527.08 6,031,029.43 469,731.16 3.51 58.33 MWD+IFR2+MS+sag (2) 685.36 16.51 286.20 677.31 17.42 -82.19621.11 6,031,036.32 469,706.65 2.81 83.35 MWD+IFR2+MS+sag (2) 7/14/2011 8:40:33AM COMPASS 2003.16 Build 42F Page 2 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 780.68 21.35 281.09 767.46 24.54 -112.25711.26 6,031,043.56 469,676.63 5.36 113.89 MWD+IFR2+MS+sag (2) 875.01 22.30 278.86 855.03 30.60 -146.78798.83 6,031,049.76 469,642.12 1.34 148.81 MWD+IFR2+MS+sag (3) 966.28 21.46 281.45 939.72 36.58 -180.26883.52 6,031,055.88 469,608.67 1.40 182.67 MWD+IFR2+MS+sag (3) 1,062.82 19.33 280.25 1,030.21 42.93 -213.29974.01 6,031,062.36 469,575.67 2.25 216.12 MWD+IFR2+MS+sag (3) 1,159.74 22.58 272.06 1,120.72 46.46 -247.691,064.52 6,031,066.03 469,541.29 4.51 250.69 MWD+IFR2+MS+sag (3) 1,252.62 24.68 269.02 1,205.82 46.77 -284.901,149.62 6,031,066.49 469,504.08 2.61 287.80 MWD+IFR2+MS+sag (3) 1,301.68 24.84 267.56 1,250.37 46.15 -305.441,194.17 6,031,065.96 469,483.54 1.29 308.21 MWD+IFR2+MS+sag (3) 1,350.08 26.59 265.51 1,293.97 44.87 -326.401,237.77 6,031,064.76 469,462.58 4.06 328.99 MWD+IFR2+MS+sag (3) 1,398.48 29.43 261.55 1,336.70 42.27 -348.961,280.50 6,031,062.26 469,440.01 7.01 351.27 MWD+IFR2+MS+sag (3) 1,444.53 31.47 259.13 1,376.40 38.34 -371.961,320.20 6,031,058.42 469,417.00 5.17 373.86 MWD+IFR2+MS+sag (3) 1,497.84 33.19 257.50 1,421.44 32.56 -399.871,365.24 6,031,052.75 469,389.06 3.62 401.20 MWD+IFR2+MS+sag (3) 1,540.36 34.41 257.52 1,456.78 27.45 -422.971,400.58 6,031,047.73 469,365.95 2.87 423.78 MWD+IFR2+MS+sag (3) 1,586.99 35.48 255.83 1,495.00 21.29 -448.951,438.80 6,031,041.68 469,339.94 3.09 449.17 MWD+IFR2+MS+sag (3) 1,635.09 38.39 254.87 1,533.44 13.97 -476.911,477.24 6,031,034.48 469,311.96 6.17 476.42 MWD+IFR2+MS+sag (3) 1,685.31 43.40 253.82 1,571.39 5.09 -508.561,515.19 6,031,025.72 469,280.28 10.07 507.21 MWD+IFR2+MS+sag (3) 1,730.45 46.30 253.83 1,603.39 -3.78 -539.131,547.19 6,031,016.98 469,249.68 6.42 536.94 MWD+IFR2+MS+sag (3) 1,758.15 48.19 252.88 1,622.20 -9.61 -558.611,566.00 6,031,011.23 469,230.17 7.27 555.88 MWD+IFR2+MS+sag (3) 1,792.58 51.17 251.66 1,644.47 -17.61 -583.611,588.27 6,031,003.34 469,205.14 9.07 580.12 MWD+IFR2+MS+sag (3) 1,824.25 53.27 251.73 1,663.87 -25.47 -607.371,607.67 6,030,995.57 469,181.35 6.63 603.15 MWD+IFR2+MS+sag (3) 1,869.48 54.18 251.31 1,690.63 -37.03 -641.961,634.43 6,030,984.15 469,146.72 2.15 636.65 MWD+IFR2+MS+sag (3) 1,918.83 54.83 249.80 1,719.29 -50.41 -679.841,663.09 6,030,970.93 469,108.79 2.82 673.29 MWD+IFR2+MS+sag (3) 1,967.34 56.52 247.40 1,746.65 -65.03 -717.131,690.45 6,030,956.46 469,071.44 5.37 709.24 MWD+IFR2+MS+sag (3) 2,013.76 56.77 246.04 1,772.17 -80.35 -752.751,715.97 6,030,941.29 469,035.77 2.51 743.46 MWD+IFR2+MS+sag (3) 2,062.04 57.14 245.08 1,798.50 -97.10 -789.591,742.30 6,030,924.69 468,998.86 1.83 778.78 MWD+IFR2+MS+sag (3) 2,110.44 57.77 244.46 1,824.53 -114.49 -826.501,768.33 6,030,907.45 468,961.89 1.69 814.11 MWD+IFR2+MS+sag (3) 2,156.66 57.66 243.31 1,849.22 -131.69 -861.581,793.02 6,030,890.40 468,926.74 2.12 847.64 MWD+IFR2+MS+sag (3) 2,204.43 58.37 242.33 1,874.53 -150.20 -897.621,818.33 6,030,872.04 468,890.62 2.29 882.02 MWD+IFR2+MS+sag (3) 2,250.10 58.41 241.49 1,898.46 -168.51 -931.941,842.26 6,030,853.87 468,856.24 1.57 914.69 MWD+IFR2+MS+sag (3) 2,300.22 58.62 240.42 1,924.64 -189.26 -969.301,868.44 6,030,833.27 468,818.80 1.87 950.20 MWD+IFR2+MS+sag (3) 2,347.25 59.76 238.29 1,948.73 -209.85 -1,004.051,892.53 6,030,812.82 468,783.97 4.58 983.12 MWD+IFR2+MS+sag (3) 2,396.72 60.81 236.29 1,973.25 -233.07 -1,040.191,917.05 6,030,789.75 468,747.73 4.10 1,017.21 MWD+IFR2+MS+sag (3) 2,443.41 61.71 234.93 1,995.70 -256.19 -1,073.971,939.50 6,030,766.77 468,713.86 3.20 1,048.95 MWD+IFR2+MS+sag (3) 2,490.14 62.42 234.78 2,017.60 -279.96 -1,107.731,961.40 6,030,743.14 468,680.01 1.55 1,080.61 MWD+IFR2+MS+sag (3) 2,537.76 63.92 234.91 2,039.09 -304.43 -1,142.471,982.89 6,030,718.82 468,645.17 3.16 1,113.20 MWD+IFR2+MS+sag (3) 2,584.38 64.07 235.24 2,059.53 -328.41 -1,176.832,003.33 6,030,694.97 468,610.73 0.71 1,145.44 MWD+IFR2+MS+sag (3) 2,679.92 61.17 235.63 2,103.46 -376.54 -1,246.682,047.26 6,030,647.13 468,540.69 3.06 1,211.05 MWD+IFR2+MS+sag (4) 2,775.45 60.34 238.49 2,150.14 -421.87 -1,316.622,093.94 6,030,602.10 468,470.57 2.75 1,276.97 MWD+IFR2+MS+sag (4) 2,823.60 59.67 237.60 2,174.21 -443.94 -1,352.002,118.01 6,030,580.18 468,435.10 2.12 1,310.40 MWD+IFR2+MS+sag (4) 2,870.81 61.77 236.77 2,197.30 -466.25 -1,386.602,141.10 6,030,558.00 468,400.41 4.71 1,343.03 MWD+IFR2+MS+sag (4) 2,920.58 64.12 237.31 2,219.94 -490.36 -1,423.792,163.74 6,030,534.05 468,363.13 4.82 1,378.08 MWD+IFR2+MS+sag (4) 7/14/2011 8:40:33AM COMPASS 2003.16 Build 42F Page 3 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 2,963.49 65.98 237.85 2,238.04 -511.22 -1,456.632,181.84 6,030,513.33 468,330.21 4.48 1,409.07 MWD+IFR2+MS+sag (4) 3,060.12 67.95 237.77 2,275.84 -558.59 -1,531.882,219.64 6,030,466.27 468,254.77 2.04 1,480.13 MWD+IFR2+MS+sag (4) 3,110.19 67.93 238.41 2,294.65 -583.12 -1,571.282,238.45 6,030,441.90 468,215.29 1.19 1,517.34 MWD+IFR2+MS+sag (4) 3,157.11 68.56 237.36 2,312.04 -606.29 -1,608.182,255.84 6,030,418.89 468,178.29 2.47 1,552.20 MWD+IFR2+MS+sag (4) 3,250.45 70.06 236.47 2,345.02 -653.95 -1,681.342,288.82 6,030,371.52 468,104.94 1.84 1,621.14 MWD+IFR2+MS+sag (4) 3,346.32 69.32 236.47 2,378.29 -703.62 -1,756.292,322.09 6,030,322.17 468,029.80 0.77 1,691.69 MWD+IFR2+MS+sag (4) 3,441.21 71.31 234.96 2,410.26 -753.95 -1,830.102,354.06 6,030,272.14 467,955.80 2.58 1,761.06 MWD+IFR2+MS+sag (4) 3,537.18 72.49 234.97 2,440.07 -806.31 -1,904.792,383.87 6,030,220.08 467,880.90 1.23 1,831.14 MWD+IFR2+MS+sag (4) 3,633.78 71.56 235.52 2,469.88 -858.70 -1,980.282,413.68 6,030,168.02 467,805.21 1.10 1,902.01 MWD+IFR2+MS+sag (4) 3,727.51 71.08 236.81 2,499.91 -908.14 -2,054.032,443.71 6,030,118.88 467,731.26 1.40 1,971.40 MWD+IFR2+MS+sag (4) 3,823.02 70.92 234.68 2,531.00 -958.96 -2,128.672,474.80 6,030,068.36 467,656.43 2.12 2,041.55 MWD+IFR2+MS+sag (4) 3,917.46 71.29 234.99 2,561.59 -1,010.42 -2,201.712,505.39 6,030,017.21 467,583.18 0.50 2,110.06 MWD+IFR2+MS+sag (4) 4,013.68 72.34 235.27 2,591.62 -1,062.68 -2,276.712,535.42 6,029,965.25 467,507.98 1.13 2,180.46 MWD+IFR2+MS+sag (4) 4,108.26 71.32 234.13 2,621.11 -1,114.61 -2,350.052,564.91 6,029,913.63 467,434.43 1.57 2,249.23 MWD+IFR2+MS+sag (4) 4,203.85 69.04 233.93 2,653.52 -1,167.42 -2,422.832,597.32 6,029,861.12 467,361.45 2.39 2,317.36 MWD+IFR2+MS+sag (4) 4,300.09 69.69 234.26 2,687.43 -1,220.24 -2,495.782,631.23 6,029,808.60 467,288.29 0.75 2,385.67 MWD+IFR2+MS+sag (4) 4,394.97 70.98 234.18 2,719.36 -1,272.48 -2,568.262,663.16 6,029,756.67 467,215.60 1.36 2,453.55 MWD+IFR2+MS+sag (4) 4,489.73 69.75 234.55 2,751.20 -1,324.48 -2,640.802,695.00 6,029,704.97 467,142.87 1.35 2,521.51 MWD+IFR2+MS+sag (4) 4,584.99 70.99 235.27 2,783.21 -1,376.05 -2,714.222,727.01 6,029,653.70 467,069.25 1.48 2,590.39 MWD+IFR2+MS+sag (4) 4,680.34 70.58 235.23 2,814.59 -1,427.37 -2,788.202,758.39 6,029,602.68 466,995.07 0.43 2,659.84 MWD+IFR2+MS+sag (4) 4,775.29 70.71 234.45 2,846.06 -1,478.96 -2,861.432,789.86 6,029,551.40 466,921.63 0.79 2,728.54 MWD+IFR2+MS+sag (4) 4,870.87 72.27 234.19 2,876.40 -1,531.82 -2,935.052,820.20 6,029,498.84 466,847.80 1.65 2,797.50 MWD+IFR2+MS+sag (4) 4,965.85 70.52 234.82 2,906.70 -1,584.09 -3,008.342,850.50 6,029,446.88 466,774.32 1.95 2,866.19 MWD+IFR2+MS+sag (4) 5,062.17 71.56 235.12 2,938.00 -1,636.38 -3,082.932,881.80 6,029,394.90 466,699.52 1.12 2,936.17 MWD+IFR2+MS+sag (4) 5,158.21 70.37 234.77 2,969.32 -1,688.52 -3,157.252,913.12 6,029,343.06 466,625.00 1.29 3,005.90 MWD+IFR2+MS+sag (4) 5,252.24 70.84 233.85 3,000.54 -1,740.27 -3,229.282,944.34 6,029,291.62 466,552.76 1.05 3,073.38 MWD+IFR2+MS+sag (4) 5,346.02 68.94 234.15 3,032.79 -1,792.03 -3,300.522,976.59 6,029,240.15 466,481.32 2.05 3,140.07 MWD+IFR2+MS+sag (4) 5,441.55 68.96 234.00 3,067.10 -1,844.34 -3,372.723,010.90 6,029,188.14 466,408.92 0.15 3,207.67 MWD+IFR2+MS+sag (4) 5,535.28 70.77 234.10 3,099.36 -1,896.00 -3,443.953,043.16 6,029,136.78 466,337.48 1.93 3,274.36 MWD+IFR2+MS+sag (4) 5,634.19 72.77 234.65 3,130.30 -1,950.71 -3,520.313,074.10 6,029,082.38 466,260.90 2.09 3,345.91 MWD+IFR2+MS+sag (4) 5,727.62 73.96 234.84 3,157.05 -2,002.38 -3,593.413,100.85 6,029,031.01 466,187.60 1.29 3,414.46 MWD+IFR2+MS+sag (4) 5,827.98 74.63 235.65 3,184.22 -2,057.46 -3,672.793,128.02 6,028,976.26 466,108.01 1.02 3,488.98 MWD+IFR2+MS+sag (5) 5,859.47 74.06 235.70 3,192.71 -2,074.56 -3,697.833,136.51 6,028,959.27 466,082.90 1.82 3,512.51 MWD+IFR2+MS+sag (5) 5,954.20 72.71 235.60 3,219.80 -2,125.77 -3,772.783,163.60 6,028,908.36 466,007.76 1.43 3,582.93 MWD+IFR2+MS+sag (6) 6,049.58 71.13 235.57 3,249.40 -2,177.02 -3,847.573,193.20 6,028,857.43 465,932.76 1.66 3,653.21 MWD+IFR2+MS+sag (6) 6,143.90 69.31 235.69 3,281.32 -2,227.12 -3,920.833,225.12 6,028,807.62 465,859.31 1.93 3,722.05 MWD+IFR2+MS+sag (6) 6,239.57 69.26 235.79 3,315.16 -2,277.50 -3,994.793,258.96 6,028,757.56 465,785.15 0.11 3,791.56 MWD+IFR2+MS+sag (6) 6,335.17 70.31 236.02 3,348.19 -2,327.79 -4,069.083,291.99 6,028,707.57 465,710.67 1.12 3,861.41 MWD+IFR2+MS+sag (6) 6,430.21 69.76 236.09 3,380.64 -2,377.67 -4,143.183,324.44 6,028,658.00 465,636.37 0.58 3,931.11 MWD+IFR2+MS+sag (6) 6,525.92 69.79 235.78 3,413.73 -2,427.97 -4,217.583,357.53 6,028,608.00 465,561.77 0.31 4,001.07 MWD+IFR2+MS+sag (6) 7/14/2011 8:40:33AM COMPASS 2003.16 Build 42F Page 4 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 6,620.41 70.25 235.10 3,446.02 -2,478.35 -4,290.713,389.82 6,028,557.93 465,488.45 0.83 4,069.76 MWD+IFR2+MS+sag (6) 6,716.41 69.86 234.27 3,478.76 -2,530.51 -4,364.353,422.56 6,028,506.07 465,414.61 0.91 4,138.80 MWD+IFR2+MS+sag (6) 6,811.32 70.18 232.95 3,511.19 -2,583.43 -4,436.153,454.99 6,028,453.45 465,342.60 1.35 4,205.95 MWD+IFR2+MS+sag (6) 6,906.79 70.38 233.33 3,543.41 -2,637.34 -4,508.053,487.21 6,028,399.84 465,270.48 0.43 4,273.13 MWD+IFR2+MS+sag (6) 7,000.73 70.18 232.88 3,575.11 -2,690.43 -4,578.773,518.91 6,028,347.04 465,199.55 0.50 4,339.19 MWD+IFR2+MS+sag (6) 7,097.05 70.43 232.73 3,607.57 -2,745.25 -4,651.013,551.37 6,028,292.52 465,127.10 0.30 4,406.62 MWD+IFR2+MS+sag (6) 7,192.13 70.44 232.84 3,639.41 -2,799.44 -4,722.363,583.21 6,028,238.63 465,055.54 0.11 4,473.21 MWD+IFR2+MS+sag (6) 7,287.67 70.12 233.52 3,671.65 -2,853.33 -4,794.353,615.45 6,028,185.03 464,983.33 0.75 4,540.48 MWD+IFR2+MS+sag (6) 7,382.83 70.31 232.70 3,703.86 -2,907.08 -4,865.973,647.66 6,028,131.58 464,911.51 0.84 4,607.37 MWD+IFR2+MS+sag (6) 7,477.61 70.70 232.56 3,735.49 -2,961.31 -4,936.983,679.29 6,028,077.64 464,840.29 0.43 4,673.62 MWD+IFR2+MS+sag (6) 7,572.91 69.92 232.46 3,767.60 -3,015.92 -5,008.173,711.40 6,028,023.33 464,768.88 0.82 4,740.03 MWD+IFR2+MS+sag (6) 7,664.65 70.64 232.47 3,798.55 -3,068.54 -5,076.653,742.35 6,027,971.00 464,700.19 0.78 4,803.90 MWD+IFR2+MS+sag (6) 7,760.60 70.63 233.12 3,830.37 -3,123.27 -5,148.753,774.17 6,027,916.56 464,627.88 0.64 4,871.20 MWD+IFR2+MS+sag (6) 7,856.07 69.85 234.09 3,862.64 -3,176.59 -5,221.073,806.44 6,027,863.55 464,555.35 1.26 4,938.83 MWD+IFR2+MS+sag (6) 7,953.12 69.72 234.39 3,896.18 -3,229.81 -5,294.973,839.98 6,027,810.63 464,481.24 0.32 5,008.05 MWD+IFR2+MS+sag (6) 8,048.34 69.91 233.63 3,929.04 -3,282.33 -5,367.283,872.84 6,027,758.41 464,408.72 0.78 5,075.75 MWD+IFR2+MS+sag (6) 8,143.84 69.97 233.40 3,961.79 -3,335.67 -5,439.413,905.59 6,027,705.37 464,336.39 0.23 5,143.19 MWD+IFR2+MS+sag (6) 8,239.93 69.84 234.12 3,994.81 -3,389.01 -5,512.193,938.61 6,027,652.33 464,263.40 0.72 5,211.28 MWD+IFR2+MS+sag (6) 8,334.21 69.84 234.59 4,027.30 -3,440.59 -5,584.113,971.10 6,027,601.05 464,191.28 0.47 5,278.66 MWD+IFR2+MS+sag (6) 8,428.63 70.30 235.71 4,059.49 -3,491.31 -5,656.964,003.29 6,027,550.63 464,118.23 1.22 5,347.04 MWD+IFR2+MS+sag (6) 8,525.27 70.77 235.28 4,091.69 -3,542.93 -5,732.044,035.49 6,027,499.32 464,042.94 0.64 5,417.57 MWD+IFR2+MS+sag (6) 8,620.64 70.17 235.61 4,123.57 -3,593.91 -5,806.074,067.37 6,027,448.65 463,968.72 0.71 5,487.10 MWD+IFR2+MS+sag (6) 8,715.48 70.57 235.40 4,155.43 -3,644.50 -5,879.694,099.23 6,027,398.36 463,894.90 0.47 5,556.26 MWD+IFR2+MS+sag (6) 8,811.36 70.83 234.56 4,187.12 -3,696.43 -5,953.804,130.92 6,027,346.74 463,820.59 0.87 5,625.79 MWD+IFR2+MS+sag (6) 8,906.22 70.30 233.34 4,218.69 -3,749.07 -6,026.124,162.49 6,027,294.40 463,748.06 1.34 5,693.49 MWD+IFR2+MS+sag (6) 9,001.02 69.84 233.07 4,251.00 -3,802.45 -6,097.494,194.80 6,027,241.32 463,676.48 0.55 5,760.17 MWD+IFR2+MS+sag (6) 9,092.51 70.24 233.43 4,282.23 -3,853.90 -6,166.394,226.03 6,027,190.15 463,607.38 0.57 5,824.56 MWD+IFR2+MS+sag (6) 9,188.01 70.05 233.76 4,314.67 -3,907.21 -6,238.694,258.47 6,027,137.14 463,534.88 0.38 5,892.17 MWD+IFR2+MS+sag (6) 9,282.68 70.10 234.41 4,346.93 -3,959.42 -6,310.774,290.73 6,027,085.23 463,462.59 0.65 5,959.66 MWD+IFR2+MS+sag (6) 9,380.15 69.85 234.32 4,380.31 -4,012.77 -6,385.204,324.11 6,027,032.19 463,387.95 0.27 6,029.39 MWD+IFR2+MS+sag (6) 9,472.29 69.83 235.20 4,412.06 -4,062.68 -6,455.844,355.86 6,026,982.57 463,317.12 0.90 6,095.64 MWD+IFR2+MS+sag (6) 9,568.74 70.11 234.28 4,445.10 -4,114.99 -6,529.834,388.90 6,026,930.57 463,242.92 0.94 6,165.03 MWD+IFR2+MS+sag (6) 9,666.12 70.05 233.69 4,478.28 -4,168.82 -6,603.884,422.08 6,026,877.04 463,168.66 0.57 6,234.35 MWD+IFR2+MS+sag (6) 9,760.80 70.31 233.31 4,510.38 -4,221.80 -6,675.484,454.18 6,026,824.36 463,096.85 0.47 6,301.29 MWD+IFR2+MS+sag (6) 9,858.38 70.24 233.07 4,543.32 -4,276.84 -6,749.034,487.12 6,026,769.62 463,023.09 0.24 6,370.00 MWD+IFR2+MS+sag (6) 9,952.01 70.12 233.37 4,575.06 -4,329.58 -6,819.574,518.86 6,026,717.18 462,952.34 0.33 6,435.92 MWD+IFR2+MS+sag (6) 10,048.39 70.17 233.62 4,607.80 -4,383.51 -6,892.444,551.60 6,026,663.55 462,879.26 0.25 6,504.05 MWD+IFR2+MS+sag (6) 10,143.67 70.31 233.81 4,640.01 -4,436.57 -6,964.724,583.81 6,026,610.79 462,806.77 0.24 6,571.67 MWD+IFR2+MS+sag (6) 10,237.91 70.19 233.55 4,671.86 -4,489.11 -7,036.194,615.66 6,026,558.55 462,735.10 0.29 6,638.52 MWD+IFR2+MS+sag (6) 10,334.15 69.58 234.87 4,704.95 -4,541.96 -7,109.494,648.75 6,026,506.00 462,661.59 1.44 6,707.17 MWD+IFR2+MS+sag (6) 7/14/2011 8:40:33AM COMPASS 2003.16 Build 42F Page 5 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 10,428.83 68.44 235.68 4,738.87 -4,592.31 -7,182.144,682.67 6,026,455.95 462,588.75 1.44 6,775.38 MWD+IFR2+MS+sag (6) 10,524.78 67.78 238.57 4,774.65 -4,640.64 -7,256.904,718.45 6,026,407.93 462,513.80 2.88 6,845.86 MWD+IFR2+MS+sag (6) 10,620.63 67.20 242.31 4,811.35 -4,684.32 -7,333.904,755.15 6,026,364.57 462,436.63 3.65 6,918.97 MWD+IFR2+MS+sag (6) 10,714.50 66.99 245.65 4,847.90 -4,722.24 -7,411.594,791.70 6,026,326.96 462,358.79 3.29 6,993.23 MWD+IFR2+MS+sag (6) 10,810.13 66.66 248.76 4,885.54 -4,756.30 -7,492.624,829.34 6,026,293.24 462,277.63 3.01 7,071.15 MWD+IFR2+MS+sag (6) 10,902.18 65.85 251.88 4,922.61 -4,784.68 -7,571.944,866.41 6,026,265.19 462,198.20 3.22 7,147.84 MWD+IFR2+MS+sag (6) 11,000.42 65.84 254.39 4,962.82 -4,810.68 -7,657.714,906.62 6,026,239.53 462,112.33 2.33 7,231.15 MWD+IFR2+MS+sag (6) 11,095.21 65.58 256.70 5,001.81 -4,832.25 -7,741.374,945.61 6,026,218.31 462,028.60 2.24 7,312.72 MWD+IFR2+MS+sag (6) 11,191.27 65.23 257.82 5,041.80 -4,851.51 -7,826.564,985.60 6,026,199.40 461,943.34 1.12 7,396.02 MWD+IFR2+MS+sag (6) 11,283.10 64.68 258.80 5,080.67 -4,868.37 -7,908.035,024.47 6,026,182.87 461,861.81 1.14 7,475.80 MWD+IFR2+MS+sag (6) 11,377.97 63.87 261.34 5,121.85 -4,883.11 -7,992.215,065.65 6,026,168.47 461,777.58 2.56 7,558.46 MWD+IFR2+MS+sag (6) 11,476.80 63.12 262.96 5,165.96 -4,895.19 -8,079.815,109.76 6,026,156.75 461,689.93 1.65 7,644.76 MWD+IFR2+MS+sag (6) 11,572.62 63.33 265.88 5,209.14 -4,903.51 -8,164.945,152.94 6,026,148.78 461,604.78 2.73 7,728.90 MWD+IFR2+MS+sag (6) 11,658.00 63.94 268.27 5,247.06 -4,907.41 -8,241.335,190.86 6,026,145.19 461,528.38 2.60 7,804.71 MWD+IFR2+MS+sag (6) 11,747.54 62.38 269.29 5,287.48 -4,909.12 -8,321.215,231.28 6,026,143.80 461,448.51 2.02 7,884.16 MWD+IFR2+MS+sag (7) 11,843.17 60.36 270.42 5,333.30 -4,909.34 -8,405.145,277.10 6,026,143.93 461,364.59 2.35 7,967.78 MWD+IFR2+MS+sag (7) 11,896.92 60.88 262.76 5,359.70 -4,912.13 -8,451.845,303.50 6,026,141.32 461,317.88 12.45 8,014.09 MWD+IFR2+MS+sag (7) 11,936.80 62.02 263.61 5,378.76 -4,916.28 -8,486.625,322.56 6,026,137.31 461,283.09 3.42 8,048.41 MWD+IFR2+MS+sag (7) 11,973.65 61.93 264.11 5,396.08 -4,919.76 -8,518.965,339.88 6,026,133.96 461,250.73 1.22 8,080.35 MWD+IFR2+MS+sag (7) 12,033.25 63.21 269.14 5,423.55 -4,922.86 -8,571.755,367.35 6,026,131.08 461,197.94 7.79 8,132.69 MWD+IFR2+MS+sag (7) 12,107.57 63.56 269.45 5,456.84 -4,923.68 -8,638.195,400.64 6,026,130.53 461,131.51 0.60 8,198.83 MWD+IFR2+MS+sag (7) 12,202.93 64.33 271.20 5,498.73 -4,923.19 -8,723.855,442.53 6,026,131.37 461,045.86 1.84 8,284.24 MWD+IFR2+MS+sag (7) 12,297.39 65.84 273.22 5,538.52 -4,919.88 -8,809.445,482.32 6,026,135.03 460,960.28 2.51 8,369.81 MWD+IFR2+MS+sag (7) 12,393.22 66.13 276.83 5,577.54 -4,912.21 -8,896.625,521.34 6,026,143.05 460,873.15 3.45 8,457.33 MWD+IFR2+MS+sag (7) 12,487.99 66.28 280.23 5,615.78 -4,899.35 -8,982.365,559.58 6,026,156.26 460,787.47 3.29 8,543.84 MWD+IFR2+MS+sag (7) 12,584.50 65.91 284.44 5,654.90 -4,880.51 -9,068.535,598.70 6,026,175.45 460,701.39 4.01 8,631.28 MWD+IFR2+MS+sag (7) 12,678.58 66.10 287.67 5,693.17 -4,856.74 -9,151.115,636.97 6,026,199.55 460,618.91 3.14 8,715.55 MWD+IFR2+MS+sag (7) 12,774.98 67.31 290.55 5,731.30 -4,827.75 -9,234.765,675.10 6,026,228.88 460,535.39 3.02 8,801.32 MWD+IFR2+MS+sag (7) 12,870.96 67.45 294.78 5,768.23 -4,793.62 -9,316.495,712.03 6,026,263.34 460,453.81 4.07 8,885.60 MWD+IFR2+MS+sag (7) 12,965.26 67.39 298.88 5,804.45 -4,754.33 -9,394.175,748.25 6,026,302.94 460,376.30 4.01 8,966.28 MWD+IFR2+MS+sag (7) 13,060.11 67.94 304.32 5,840.52 -4,708.37 -9,468.855,784.32 6,026,349.19 460,301.81 5.34 9,044.52 MWD+IFR2+MS+sag (7) 13,154.33 67.50 309.25 5,876.26 -4,656.19 -9,538.655,820.06 6,026,401.65 460,232.23 4.86 9,118.42 MWD+IFR2+MS+sag (7) 13,251.66 67.30 312.83 5,913.67 -4,597.21 -9,606.415,857.47 6,026,460.90 460,164.71 3.40 9,190.85 MWD+IFR2+MS+sag (7) 13,346.28 67.85 316.46 5,949.78 -4,535.75 -9,668.625,893.58 6,026,522.60 460,102.76 3.59 9,257.96 MWD+IFR2+MS+sag (7) 13,440.97 68.25 320.27 5,985.18 -4,470.13 -9,726.965,928.98 6,026,588.46 460,044.70 3.76 9,321.55 MWD+IFR2+MS+sag (7) 13,536.47 68.17 324.33 6,020.65 -4,399.98 -9,781.175,964.45 6,026,658.82 459,990.78 3.95 9,381.41 MWD+IFR2+MS+sag (7) 13,632.27 69.66 327.69 6,055.12 -4,325.88 -9,831.125,998.92 6,026,733.12 459,941.13 3.62 9,437.35 MWD+IFR2+MS+sag (7) 13,726.99 72.07 329.40 6,086.17 -4,249.55 -9,877.806,029.97 6,026,809.63 459,894.76 3.06 9,490.22 MWD+IFR2+MS+sag (7) 13,821.83 74.10 331.64 6,113.76 -4,170.56 -9,922.446,057.56 6,026,888.79 459,850.45 3.11 9,541.27 MWD+IFR2+MS+sag (7) 13,917.18 76.72 331.10 6,137.78 -4,089.58 -9,966.666,081.58 6,026,969.94 459,806.57 2.80 9,592.06 MWD+IFR2+MS+sag (7) 7/14/2011 8:40:33AM COMPASS 2003.16 Build 42F Page 6 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 14,013.05 76.22 330.41 6,160.21 -4,008.25 -10,012.196,104.01 6,027,051.45 459,761.37 0.87 9,644.20 MWD+IFR2+MS+sag (7) 14,058.26 76.61 330.04 6,170.83 -3,970.11 -10,034.026,114.63 6,027,089.67 459,739.71 1.17 9,669.12 MWD+IFR2+MS+sag (7) 14,091.00 76.61 330.04 6,178.41 -3,942.51 -10,049.926,122.21 6,027,117.33 459,723.92 0.00 9,687.27 MWD+IFR2+MS+sag (7) 14,152.43 79.23 329.60 6,191.27 -3,890.59 -10,080.126,135.07 6,027,169.37 459,693.93 4.32 9,721.68 MWD+IFR2+MS+sag (8) 14,249.50 82.68 330.95 6,206.52 -3,807.35 -10,127.646,150.32 6,027,252.79 459,646.76 3.81 9,775.95 MWD+IFR2+MS+sag (8) 14,344.98 84.91 331.88 6,216.84 -3,724.01 -10,173.056,160.64 6,027,336.31 459,601.69 2.53 9,828.14 MWD+IFR2+MS+sag (8) 14,436.69 87.76 330.54 6,222.71 -3,643.81 -10,217.126,166.51 6,027,416.68 459,557.95 3.43 9,878.73 MWD+IFR2+MS+sag (8) 14,538.67 87.99 327.19 6,226.49 -3,556.59 -10,269.816,170.29 6,027,504.10 459,505.62 3.29 9,938.48 MWD+IFR2+MS+sag (8) 14,636.20 87.00 325.12 6,230.75 -3,475.67 -10,324.076,174.55 6,027,585.23 459,451.69 2.35 9,999.29 MWD+IFR2+MS+sag (8) 14,732.66 87.93 322.55 6,235.02 -3,397.88 -10,380.936,178.82 6,027,663.25 459,395.15 2.83 10,062.42 MWD+IFR2+MS+sag (8) 14,829.17 86.87 319.59 6,239.40 -3,322.89 -10,441.506,183.20 6,027,738.47 459,334.89 3.25 10,129.02 MWD+IFR2+MS+sag (8) 14,925.72 87.06 315.32 6,244.51 -3,251.87 -10,506.686,188.31 6,027,809.75 459,270.01 4.42 10,199.88 MWD+IFR2+MS+sag (8) 15,022.68 87.99 313.50 6,248.70 -3,184.09 -10,575.886,192.50 6,027,877.81 459,201.10 2.11 10,274.47 MWD+IFR2+MS+sag (8) 15,119.20 88.73 312.57 6,251.46 -3,118.25 -10,646.406,195.26 6,027,943.93 459,130.85 1.23 10,350.22 MWD+IFR2+MS+sag (8) 15,214.79 91.15 314.19 6,251.56 -3,052.60 -10,715.876,195.36 6,028,009.85 459,061.66 3.05 10,424.91 MWD+IFR2+MS+sag (8) 15,311.99 93.62 316.09 6,247.52 -2,983.77 -10,784.366,191.32 6,028,078.95 458,993.45 3.20 10,498.89 MWD+IFR2+MS+sag (8) 15,408.31 95.11 315.97 6,240.19 -2,914.65 -10,851.046,183.99 6,028,148.33 458,927.06 1.55 10,571.08 MWD+IFR2+MS+sag (8) 15,504.75 94.17 313.28 6,232.38 -2,847.14 -10,919.456,176.18 6,028,216.12 458,858.94 2.95 10,644.87 MWD+IFR2+MS+sag (8) 15,601.51 92.93 310.76 6,226.39 -2,782.50 -10,991.196,170.19 6,028,281.04 458,787.47 2.90 10,721.73 MWD+IFR2+MS+sag (8) 15,697.74 94.05 309.50 6,220.53 -2,720.59 -11,064.626,164.33 6,028,343.24 458,714.29 1.75 10,800.06 MWD+IFR2+MS+sag (8) 15,794.87 93.67 308.07 6,213.99 -2,659.89 -11,140.166,157.79 6,028,404.24 458,639.01 1.52 10,880.39 MWD+IFR2+MS+sag (8) 15,890.86 93.05 306.68 6,208.37 -2,601.72 -11,216.316,152.17 6,028,462.71 458,563.10 1.58 10,961.11 MWD+IFR2+MS+sag (8) 15,987.05 93.80 306.84 6,202.62 -2,544.26 -11,293.236,146.42 6,028,520.48 458,486.42 0.80 11,042.55 MWD+IFR2+MS+sag (8) 16,083.29 92.68 307.26 6,197.18 -2,486.37 -11,369.926,140.98 6,028,578.68 458,409.98 1.24 11,123.78 MWD+IFR2+MS+sag (8) 16,180.10 91.26 307.71 6,193.85 -2,427.49 -11,446.696,137.65 6,028,637.86 458,333.45 1.54 11,205.18 MWD+IFR2+MS+sag (8) 16,274.85 91.32 307.56 6,191.72 -2,369.65 -11,521.716,135.52 6,028,696.00 458,258.68 0.17 11,284.75 MWD+IFR2+MS+sag (8) 16,370.87 91.82 308.09 6,189.09 -2,310.79 -11,597.526,132.89 6,028,755.16 458,183.11 0.76 11,365.20 MWD+IFR2+MS+sag (8) 16,468.38 91.20 310.01 6,186.52 -2,249.38 -11,673.226,130.32 6,028,816.87 458,107.67 2.07 11,445.74 MWD+IFR2+MS+sag (8) 16,564.06 90.77 312.07 6,184.88 -2,186.57 -11,745.376,128.68 6,028,879.97 458,035.79 2.20 11,522.86 MWD+IFR2+MS+sag (8) 16,659.52 90.65 313.50 6,183.69 -2,121.74 -11,815.426,127.49 6,028,945.08 457,966.00 1.50 11,598.06 MWD+IFR2+MS+sag (8) 16,755.66 91.57 313.53 6,181.83 -2,055.55 -11,885.136,125.63 6,029,011.54 457,896.58 0.96 11,673.03 MWD+IFR2+MS+sag (8) 16,852.14 89.47 311.85 6,180.95 -1,990.15 -11,956.046,124.75 6,029,077.23 457,825.94 2.79 11,749.13 MWD+IFR2+MS+sag (8) 16,948.42 89.22 311.89 6,182.06 -1,925.89 -12,027.736,125.86 6,029,141.77 457,754.52 0.26 11,825.92 MWD+IFR2+MS+sag (8) 17,044.39 88.48 311.14 6,183.98 -1,862.29 -12,099.576,127.78 6,029,205.65 457,682.94 1.10 11,902.80 MWD+IFR2+MS+sag (8) 17,141.56 87.25 310.74 6,187.60 -1,798.67 -12,172.926,131.40 6,029,269.57 457,609.86 1.33 11,981.19 MWD+IFR2+MS+sag (8) 17,238.42 86.26 309.91 6,193.08 -1,736.09 -12,246.656,136.88 6,029,332.44 457,536.40 1.33 12,059.86 MWD+IFR2+MS+sag (8) 17,334.39 85.32 310.65 6,200.13 -1,674.21 -12,319.666,143.93 6,029,394.61 457,463.64 1.25 12,137.77 MWD+IFR2+MS+sag (8) 17,430.69 86.13 312.24 6,207.31 -1,610.65 -12,391.646,151.11 6,029,458.46 457,391.92 1.85 12,214.79 MWD+IFR2+MS+sag (8) 17,527.24 86.63 313.30 6,213.40 -1,545.22 -12,462.386,157.20 6,029,524.17 457,321.46 1.21 12,290.72 MWD+IFR2+MS+sag (8) 17,623.31 86.45 313.39 6,219.20 -1,479.39 -12,532.126,163.00 6,029,590.27 457,252.00 0.21 12,365.69 MWD+IFR2+MS+sag (8) 7/14/2011 8:40:33AM COMPASS 2003.16 Build 42F Page 7 Project: Company: Local Co-ordinate Reference: TVD Reference: Site: Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site Halliburton Company Definitive Survey Report Well: Wellbore: ODSN-23i ODSN-23i Survey Calculation Method:Minimum Curvature 42.7' + 13.5' @ 56.20ft (Nabors 19AC) Design:ODSN-23i IN14 Database:.Pioneer Alaska MD Reference:42.7' + 13.5' @ 56.20ft (Nabors 19AC) North Reference: Well ODSN-23i - Slot ODS-23 True MD (ft) Inc (?) Azi (?) +E/-W (ft) +N/-S (ft) Survey TVD (ft) TVDSS (ft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 17,720.19 86.19 313.04 6,225.42 -1,413.19 -12,602.576,169.22 6,029,656.75 457,181.82 0.45 12,441.41 MWD+IFR2+MS+sag (8) 17,816.77 85.27 311.36 6,232.61 -1,348.50 -12,673.926,176.41 6,029,721.72 457,110.75 1.98 12,517.88 MWD+IFR2+MS+sag (8) 17,911.61 85.70 311.39 6,240.08 -1,286.01 -12,744.876,183.88 6,029,784.49 457,040.06 0.45 12,593.78 MWD+IFR2+MS+sag (8) 18,008.71 85.82 311.82 6,247.26 -1,221.71 -12,817.276,191.06 6,029,849.08 456,967.92 0.46 12,671.29 MWD+IFR2+MS+sag (8) 18,104.30 86.13 310.90 6,253.97 -1,158.70 -12,888.846,197.77 6,029,912.37 456,896.62 1.01 12,747.85 MWD+IFR2+MS+sag (8) 18,201.41 92.57 313.34 6,255.07 -1,093.62 -12,960.826,198.87 6,029,977.74 456,824.91 7.09 12,824.99 MWD+IFR2+MS+sag (8) 18,298.28 93.49 314.32 6,249.95 -1,026.63 -13,030.616,193.75 6,030,045.01 456,755.40 1.39 12,900.10 MWD+IFR2+MS+sag (8) 18,394.58 94.73 314.77 6,243.05 -959.25 -13,099.066,186.85 6,030,112.66 456,687.23 1.37 12,973.92 MWD+IFR2+MS+sag (8) 18,491.00 93.24 314.35 6,236.35 -891.76 -13,167.596,180.15 6,030,180.42 456,618.98 1.61 13,047.83 MWD+IFR2+MS+sag (8) 18,587.18 94.17 313.40 6,230.13 -825.24 -13,236.786,173.93 6,030,247.21 456,550.07 1.38 13,122.31 MWD+IFR2+MS+sag (8) 18,683.57 94.17 312.81 6,223.12 -759.55 -13,306.976,166.92 6,030,313.18 456,480.16 0.61 13,197.72 MWD+IFR2+MS+sag (8) 18,779.84 93.61 312.99 6,216.59 -694.17 -13,377.336,160.39 6,030,378.84 456,410.07 0.61 13,273.27 MWD+IFR2+MS+sag (8) 18,875.80 91.51 313.62 6,212.30 -628.42 -13,447.086,156.10 6,030,444.86 456,340.59 2.28 13,348.25 MWD+IFR2+MS+sag (8) 18,971.61 91.88 315.22 6,209.47 -561.39 -13,515.486,153.27 6,030,512.16 456,272.47 1.71 13,421.99 MWD+IFR2+MS+sag (8) 19,067.62 92.87 315.79 6,205.49 -492.97 -13,582.716,149.29 6,030,580.85 456,205.53 1.19 13,494.67 MWD+IFR2+MS+sag (8) 19,162.81 91.69 313.56 6,201.70 -426.10 -13,650.346,145.50 6,030,647.99 456,138.18 2.65 13,567.63 MWD+IFR2+MS+sag (8) 19,260.28 92.31 313.05 6,198.30 -359.29 -13,721.236,142.10 6,030,715.08 456,067.57 0.82 13,643.83 MWD+IFR2+MS+sag (8) 19,356.97 89.35 312.74 6,196.90 -293.49 -13,792.056,140.70 6,030,781.16 455,997.02 3.08 13,719.87 MWD+IFR2+MS+sag (8) 19,449.64 89.53 314.14 6,197.81 -229.78 -13,859.336,141.61 6,030,845.14 455,930.01 1.52 13,792.22 MWD+IFR2+MS+sag (8) 19,549.96 89.59 314.98 6,198.58 -159.39 -13,930.816,142.38 6,030,915.81 455,858.83 0.84 13,869.30 MWD+IFR2+MS+sag (8) 19,600.71 87.93 314.47 6,199.68 -123.69 -13,966.866,143.48 6,030,951.66 455,822.93 3.42 13,908.19 MWD+IFR2+MS+sag (8) 19,645.46 87.86 314.80 6,201.32 -92.27 -13,998.686,145.12 6,030,983.20 455,791.24 0.75 13,942.52 MWD+IFR2+MS+sag (8) 19,741.64 87.12 312.27 6,205.53 -26.09 -14,068.336,149.33 6,031,049.66 455,721.86 2.74 14,017.43 MWD+IFR2+MS+sag (8) 19,839.08 86.94 316.07 6,210.58 41.71 -14,138.126,154.38 6,031,117.73 455,652.36 3.90 14,092.61 MWD+IFR2+MS+sag (8) 19,935.00 87.43 316.40 6,215.29 110.89 -14,204.386,159.09 6,031,187.18 455,586.38 0.62 14,164.41 MWD+IFR2+MS+sag (8) 20,031.92 87.25 314.47 6,219.79 179.87 -14,272.326,163.59 6,031,256.42 455,518.73 2.00 14,237.84 MWD+IFR2+MS+sag (8) 20,128.61 86.94 312.83 6,224.69 246.52 -14,342.196,168.49 6,031,323.35 455,449.14 1.72 14,313.01 MWD+IFR2+MS+sag (8) 20,225.31 86.81 313.46 6,229.96 312.55 -14,412.646,173.76 6,031,389.65 455,378.97 0.66 14,388.71 MWD+IFR2+MS+sag (8) 20,321.56 86.87 314.22 6,235.27 379.11 -14,481.956,179.07 6,031,456.49 455,309.93 0.79 14,463.32 MWD+IFR2+MS+sag (8) 20,418.09 87.37 314.57 6,240.12 446.56 -14,550.846,183.92 6,031,524.21 455,241.32 0.63 14,537.57 MWD+IFR2+MS+sag (8) 20,514.89 87.06 314.81 6,244.82 514.56 -14,619.586,188.62 6,031,592.48 455,172.87 0.40 14,611.73 MWD+IFR2+MS+sag (8) 20,550.00 87.06 314.81 6,246.62 539.27 -14,644.456,190.42 6,031,617.29 455,148.10 0.00 14,638.57 PROJECTED to TD 7/14/2011 8:40:33AM COMPASS 2003.16 Build 42F Page 8 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 D ep t h Oooguruk ODSN-23i Lost Surface Hole Begin 14 1/2" Surface Hole Redrill at 857' MD, 838' TVD On Bot: 07:08 05/23/2011 TD 1st Intermediate at Hole Packed Off SDL Crew Arrived 05/19/2011 TD 14.5" Surface Hole Redrill 11045' MD, 4698' TVD Off Bot: 04:42 03-Feb-2011 Ran 11.75" Casing and Cemented Begin 10.625" Intemediate w/ 11.75" Under-Reamer at 5810' MD, 3179' TVD On Bot: 07:08 05/23/2011 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 0 1 02 03 04 05 06 0 Me a s u r e d D Rig Days TD 1st Intermediate at 11986' MD, 5390' TVD, 07:35 06/06/2011 BHA Broken, LIH Abandon ODSN-23i-PB2 Run Cleanout Run TD Well 20550' MD, 6245.68' TVD Ont: 05:30 ,7-Jul-2011 Drill out of window with Mud Motor Pick up GeoPilot/Rhino Reamer to finish 2nd Intermediate TD 2nd Intermediate at 14091' MD, 6178' TVD, @ 10:00 6/25/2011 Set 9 5/8" Liner TOL 5,597', 3119' TVD BOL 11887' MD, 5346' TVD Set Whipstock and kick off @ 11675' MD. Dropped fish in hole. Attempt to retrieve fish. Set 7" Liner TOL 11488' MD, 5171' TVD BOL 14089' MD, 6178' TVD Begin 6 1/8" Production On Bot: 22:23 07/06/2011 Surface Data Logging After Action Review Employee Name: Mark Lindloff Date: 15-July-2011 Well: ODSN-23i Hole Section: Intermed/Production What went as, or better than, planned: Working with a newly promoted Mudlogger went better than been expected. Others in the unit chipped in to assist when they could and most issues were resolved to the customers satisfaction. Difficulties experienced: None Recommendations: None Innovations and/or cost savings: Introduced a calculator for calculating hole size to provide quicker and more accurate hole size numbers for the customer.