Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
213-037
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' Eni US Operating Co, Inc WELL LOG/DATA TRANSMITTAL To:333 W. 7th Ave, Anchorage, AK 99501 March 22, 2023 Well:ODSN-04 LWD/MWD Logs PDF LAS DLIS Excel Mudlogs E-line logs 3.5"Multifinger Caliper Log x x PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Edgar Pinzon Mail: edgar.pinzon@eni.com Received By: ___________________________________Date:____________ Eni US Operating Co, Inc. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________OOOGURUK ODSN-04 JBR 04/20/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:1 Tested with 2 7/8" and 4" test joints, Annular Failed to hold pressure on high test. 0100 Long wait on annular. Moved on to next job and did not witness the passing test. Seth sent me a charted passing test chart @0730 Test Results TEST DATA Rig Rep:Seth BeardOperator:Eni US Operating Co. Inc.Operator Rep:Takahiro Kosaka Rig Owner/Rig No.:Nabors 19AC PTD#:2130370 DATE:3/1/2023 Type Operation:WRKOV Annular: 250/2500Type Test:WKLY Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopSTS230227101253 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 14 MASP: 1265 Sundry No: 322-707 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 15 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11"F #1 Rams 1 2 7/8"x5"P #2 Rams 1 blind/shear P #3 Rams 1 2 7/8"x5"P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 3 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 4 3 1/8" & 2"P Check Valve 0 NA BOP Misc 0 NA System Pressure P2950 Pressure After Closure P1650 200 PSI Attained P12 Full Pressure Attained P60 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P6@2306 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P26 #1 Rams P7 #2 Rams P7 #3 Rams P7 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P3 HCR Kill P3 9 9 9 9 9999 9 9 9 F Annular Failed to hold pressure on high test. did not witness the passing test STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:19AC DATE:2/21/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2130370 Sundry #322-707 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/3500 Annular:250/2500 Valves:250/3500 MASP:1265 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 1 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2 7/8" X 5"P Flow Indicator P P #2 Rams 1 Blind/Shear P Meth Gas Detector P P #3 Rams 1 2 7/8" X 5"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 3 3 1/8"P Time/Pressure Test Result HCR Valves 2 3 1/8"P System Pressure (psi)3000 P Kill Line Valves 4 3 1/8" & 2" P Pressure After Closure (psi)1550 P Check Valve 0 NA 200 psi Attained (sec)11 P BOP Misc 0 NA Full Pressure Attained (sec)67 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):6@2140 P No. Valves 15 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 25 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 10 P Inside Reel valves 0 NA #3 Rams 10 P #4 Rams NA Test Results #5 Rams NA #6 Rams NA Number of Failures:0 Test Time:5.5 HCR Choke 4 P Repair or replacement of equipment will be made within days. HCR Kill 4 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/13/23 10:00am Waived By Test Start Date/Time:2/21/2023 11:30 (date)(time)Witness Test Finish Date/Time:2/21/2023 17:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Nabors Tested with 2-7/8" & 4" test jt, XT-39 floor valve equipment. Matt Turcotte/Seth Beard ENI Justin Hays/Paul Dillon Oooguruk ODSN-04 Test Pressure (psi): matthew.turcotte@nabors.com odsdrilling@eni.com Form 10-424 (Revised 08/2022)2023-0221_BOP_Nabors19AC_Oooguruk_ODSN-04 J. Regg; 6/12/2023 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Run ESP Completion_ 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?A ODSN-04 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: Oooguruk Nuiqsut Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 19,868'6,364' 19,858' 6,363' 1265 N/A N/A Casing Collapse Structural Conductor N/A Surface 3,180 psi Intermediate 1 3,090 psi Intermediate 2 5,410 psi Liner 9,200 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Stefano Pierfelici Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Amjad Chaudhry amjad.chaudhry@eni.com 907-865-3379 12/16/2022 Well Operations Project Manager 11,590 psi Tubing Grade:Tubing MD (ft): See attachment pg. 3 Perforation Depth TVD (ft):Tubing Size: 9.2 #, L-80 IBT-M 11,800 December 25th, 2022 See attachment pg. 3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 355036 / ADL 389958 / ADL 389959 213-037 3700 Centerpoint Drive, Suite 500, Anchorage, AK 99503 50-703-20670-00-00 Eni US Operating CO. Inc. Length Size Proposed Pools: TVD Burst Nuiqsut Oil Pool PRESENT WELL CONDITION SUMMARY 7,240 psi MD 5,750 psi N/A 5,830 psi 158' 3,339' 5,561' 158' 5,284' 6,412'12,965' 16" 11-3/4" 115' 5,241' Perforation Depth MD (ft): 10,365' See attachment pg. 2 12,923' 4-1/2" See attachment pg. 2 19,858'7,092' 3-1/2" 6,363' 7" 9-5/8"5,258' m n P s t _ 2 6 5 6 Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Anne Prysunka at 1:46 pm, Dec 16, 2022 322-707 X BJM 12/22/22 BOP test to 3500 psi, Annular test to 2500 psi. 10-404 DLB 12/19/2022 X GCW 12/22/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.22 16:48:57 -09'00' RBDMS JSB 122922 Top (MD)Top (TVD) 13,270 6,419 13,967 6,419 14,613 6,415 15,185 6,397 15,833 6,395 16,544 6,388 17,156 6,387 17,727 6,390 18,255 6,395 18,955 6,389 19,512 6,378 19,811 6,366 4-1/2" SLHT Ball Actuated Sleeve w/Seat #08 4-1/2" SLHT Ball Actuated Sleeve w/Seat #07 4-1/2" SLHT Ball Actuated Sleeve w/Seat #06 4-1/2" SLHT Ball Actuated Sleeve w/Seat #05 4-1/2" SLHT Ball Actuated Sleeve w/Seat #04 4-1/2" SLHT Ball Actuated Sleeve w/Seat #03 4-1/2" SLHT Ball Actuated Sleeve w/Seat #02 4-1/2" SLHT Ball Actuated Sleeve w/Seat #01 Pre-Perforated Pup Attachment 2 Sundry Application Box 11 - Perforation Locations Well: ODSN-04 4-1/2" SLHT Ball Actuated Sleeve w/Seat #09 4-1/2" SLHT Ball Actuated Sleeve w/Seat #11 4-1/2" SLHT Ball Actuated Sleeve w/Seat #10 AOGCC Form 10-403 SSSV MD TVD 3-1/2" 'NE' TRSV 2345' 2024' PACKERS 11710' 6,132' 12,766' 6,395' 13,095' 6,420' 13,456' 6,417' 13,621' 6,421' 14,271' 6,421' 14,920' 6,399' 15,452' 6,395' 16,179' 6,397' 16,850' 6,388' 17,463' 6,388' 17,993' 6,393' 18,561' 6,394' 19,262' 6,384' 19,779' 6,367'HES Swell Packer #1 HES Swell Packer #7 HES Swell Packer #6 HES Swell Packer #5 HES Swell Packer #4 HES Swell Packer #3 HES Swell Packer #2 HES Swell Packer #11 HES Swell Packer #10 HES Swell Packer #9 Attachment 3 HES Swell Packer #8 5" x 7" Baker ZXP Liner Top Packer HES Swell Packer #13 HES Swell Packer #12 AOGCC Form 10-403 Application for Sundry Box 11 - Packers & SSSV Well: ODSN-04 3-1/2" x 7" Baker Premier Retrievable Pac 3700 Centerpoint Drive Suite 500 Anchorage, Alaska 99503 Stefano Pierfelici Phone (907) 865-3320 E-mail: Stefano.perfelici@eni.com December 16, 2022 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for ODSN-04 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well ODSN-04. ODSN-04 was drilled and completed in August 2013 and well was put on production in March 2014. In 2017 Rig workover was performed to repair 7” casing and run ESP completion. In September 2018 rig workover was performed to pull ESP and run gas lift completion. Well was on Production until June 28 th, 2022, when well is shut down because of low gas lift pressure. Plan is to re-complete the well with an ESP completion to increase the production. Estimated date for beginning this work is December 25th, 2022. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907-865-3379. Sincerely, Stefano Pierfelici Well Operations Project Manager ODSN-04 Workover – Proposal Summary and Wellbore Schematic PTD#: 213-046 Current Status Well, ODSN-04 is currently shut down. Scope of Work Scope of this workover is to pull existing 3-1/2” completion, perform a clean out of the heel area, and run a new ESP completion including a chemical injection line and back-up gas lift. General Well Info Reservoir Pressure/TVD: The estimated maximum reservoir pressure for the ODSN-04 Nuiqsut area is 1,900 psi at -6,350’ TVDss (table and chart below), yielding a maximum anticipated surface pressure (MASP) of 1,265 psi ODSN-04 MASP Shut-in BHP 1,900 psi 5.8 ppge Depth 6,350 ft (TVDss) Gradient 0.1 psi/ft MASP 1,265 psi Wellhead type/pressure rating: Vault PC, MB-233/5000 psi BOP configuration: Annular/Pipe/Blind/Pipe Well type: Producer TIFL/MIT-IA/MIT-OA: Intermediate (7”) casing was tested to 2500 psi in October 2018. Estimated start date: December 25th, 2022 Drilling Rig: Nabors 19AC Sr. Drilling Engineer: Amjad Chaudhry Amjad.chaudhry@eni.com Work: 907-865-3379 Well Operations Project Manager: Stefano Pierfelici Stefano.pierfelici@eni.com Work: 907-865-3320 Procedure Summary x MIRU Nabors 19AC x Slickline Program: Option to perform pre-rig x Set Cat Standing valve in XN nipple x Pull OV from GLM#1 x Fluid pack tubing and IA with treated/filtered seawater x Combo Test Tubing x IA to 1000psi x SL - Install DV in GLM#1 x SL - Pull Cat Standing valve x Install test dart x ND Tree/ NU BOPE x Test BOPE 250psi low/3500psi high, Annular to 2500psi o Test joints: 2-7/8”, 3-1/2”, 4” x Install 3-1/2” landing joint in the tubing hanger w/ FOSV made up. x Bullhead 10 bbl vis pill down tubing followed by 125% tubing volume of filtered seawater x BOLDS and pull the tubing hanger in tension RU E-line, RIH and cut, cut-to-release Baker Premier packer at 11,710’ MD x Release packer and pull hanger to rig floor x Bullhead a 20 bbls vis pill followed by 125% annular volume of 8.6 ppg filtered seawater. x Pull the 3 ½” completion string out of the hole x RIH with 7” 26# casing conditioning assembly to 12500’ MD x RIH with 7” 26# test packer assembly to 12500’ MD and pressure test casing to 2500 psi. x PU & RIH 2-7/8” x 3-1/2” ESP completion o Note: RHC installed in X-nipple o Note: 2500 psi DCK-2 installed in GLM #3 x Land hanger and test both the upper and lower tubing hanger body seals to 5000 psi x Release packer setting ball and rod o If fluid is within 500’ MD via ecometer drop ball and rod from surface o If fluid is greater than 500’ MD from surface run on slickline x Fill tubing with seawater and set ESP packer x Perform tubing and annulus pressure test o Reduce tubing pressure from ESP packer setting pressure to 2500psi o Pressure test 2-7/8” x 7” annulus to 2500psi o Bleed tubing pressure down to zero to shear DCK-2 in GLM#3 Reduce pressure per Centrilift Annulus Pressure Control schedule to mitigate risk of ESP cable damage x Close TRSSV x Confirm PVV is closed x Set TWC x ND BOPE / NU Tree x Perform Passport test x Pull TWC x Circulate LVT freeze protection to ESP packer down annulus to tubing x ROMO Nabors19AC Post Rig (Slick-line): x Set catcher below GLM#2 x Pull SOV from GLM#2 x Set DV in GLM#2 x Pull catcher Current Completion: Planned Completion STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMMISSION ..1,2,;,' REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other:Repair 7"Casing/Run ESP 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Caelus Natural Resources Alaska,LLC Development 0 Exploratory ❑ 213-037 3.Address: 3700 Centerpoint Drive,Suite 500 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-703-20670-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 389958/ADL 389959 ODSN-04 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 19,868 feet Plugs measured N/A feet true vertical 6,364 feet Junk measured N/A feet Effective Depth measured 19,858 feet Packer measured See attachment,pg.3 feet true vertical 6,363 feet true vertical See attachment,pg.3 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5,245' 11-3/4" 5,284' 3,339' 5,830 psi 3,180 psi Intermediate 5,260' 9-5/8" 10,365' 5,561' 5,750 psi 3,090 psi Int 2 Tie Back 2,307' 7" 2,344' 2,023' 7,240 psi 5,410 psi Intermediate 2 10,422 7" 12,965' 6,412' 7,240 psi 5,410 psi Liner 7,092' 4-1/2" 19,858' 6,363' 11,590 psi 9,200 psi Perforation depth Measured depth See attachment,pg.2 feet 1 2 2G 18 True Vertical depth See attachment,pg.2 feet SCANNED 0AN Tubing(size,grade,measured and true vertical depth) 2-7/8",6.4# L-80,IBT-M 11,484'MD 6,038'TVD Packers and SSSV(type,measured and true vertical depth) See attachment,pg.3 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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: 1,170 256 538 1,384 362 Subsequent to operation: 316 100 828 365 402 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Develo ment p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas 0 WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ 3USP❑ 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: 317-244 Authorized Name:Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Staff • pletion Engineer Contact Email: rami.iasser(a�caeluseneray.com Authorized Signature: i ii ., Date: 10/13/a_ Contact Phone: 907-343-2182 Form 10-404 Revised 4/2017 74- ///577 , /�,/� Submit Original Only Re D '�I Ui;1 1 7 Ll i, • • Attachment 2 . ,i;;.:v-i4.Xs/vU/"!/C1rNxH���Nv9yr�'�' .'MNWrMb a.rrenro'uMu mv4a+vi� av'�tin rH4nFniM'a.H�reNS. wvMwarvroM4m a iNa.Mawv w7v✓w;Hv.,N<H.mva AOGCC Form 10-404 Sundry Report Box 11 - Perforation Locations y, .,,.,p,P v n..,.a a./,. ,..L v^P ry..,.,/,s9,:,L..,,.„✓,SZ.AAyH,':r,�.r rvx/>rar.nrssw+,mra'.:.a,/, �' Well: ODSN-04 Top (MD) Top(TVD) 4-1/2" SLHT Ball Actuated Sleeve w/Seat#11 13,270 6,419 4-1/2" SLHT Ball Actuated Sleeve w/Seat#10 13,967 6,419 4-1/2" SLHT Ball Actuated Sleeve w/Seat#09 14,613 6,415 4-1/2" SLHT Ball Actuated Sleeve w/Seat#08 15,185 6,397 4-1/2" SLHT Ball Actuated Sleeve w/Seat#07 15,833 6,395 4-1/2" SLHT Ball Actuated Sleeve w/Seat#06 16,544 6,388 4-1/2" SLHT Ball Actuated Sleeve w/Seat#05 17,156 6,387 4-1/2" SLHT Ball Actuated Sleeve w/Seat#04 17,727 6,390 4-1/2" SLHT Ball Actuated Sleeve w/Seat#03 18,255 6,395 4-1/2" SLHT Ball Actuated Sleeve w/Seat#02 18,955 6,389 4-1/2" SLHT Ball Actuated Sleeve w/Seat#01 19,512 6,378 Pre-Perforated Pup 19,811 6,366 • Attachment 3 AOGCC Form 10-404 Sundry Report Box 11 - Packers & SSSV Well: ODSN-04 SSSV MD TVD 2-7/8" 'NE' TRSV w/2.313 "X" Profile 2,289 1,989 PACKERS 2-7/8" x 7" EFT Hydrow II ESP Packer 3,354' 2,495' 5" x 7" Baker ZXP Liner Top Packer 12,766' 6,395' HES Swell Packer#13 13,095' 6,420' HES Swell Packer#12 13,456' 6,417' HES Swell Packer#11 13,621' 6,421' HES Swell Packer#10 14,271' 6,421' HES Swell Packer#9 14,920' 6,399' HES Swell Packer#8 15,452' 6,395' HES Swell Packer#7 16,179' 6,397' HES Swell Packer#6 16,850' 6,388' HES Swell Packer#5 17,463' 6,388' HES Swell Packer#4 17,993' 6,393' HES Swell Packer#3 18,561' 6,394' HES Swell Packer#2 19,262' 6,384' HES Swell Packer#1 19,779' 6,367' • . • LL S Operations Summary Report- State Well Name: ODSN-04 �;c r' Alaska Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Start Deplh FootMeters Dens Last Start Date End Date (ftKB) (ft) Mud(Iblgal) Summary 9/2/2017 9/3/2017 0.0 00:00 9/2/17-00:00 9/3/17(Pre RWO S/L) *Take possession of the well OPS-Wells,Shut in and freeze protect. *Pump 60 bbl of LVT/Diesel mix for freeze protect on TBG. *MIRU Expro S/L w/.125"wire. *Drifted w/3.83"gauge ring to SVLN @ 2,283'slm. *Pulled 4.5"FXE SSSV from SVLN @ 2,283'slm. *Drifted w/3.80 Swage to 11,785'slm w/no issues. *Set 4.5"Evo Trieve in the TBG at 11,755 slm. *Set catcher sub on top of the 4.5"Evo Trieve at 11,741'slm. *Pull the 1"OV from GLM#1 at 11,674'slm. 9/3/2017 9/4/2017 0.0 00:00 9/3/17-00:00 9/4/17(Pre RWO S/L) *Pull to surface after pulling the 1"BTTM latch valve from GLM#1 at 11,674'slm. *RDMO Expro S/L. *MIRU LRS to begin fluid packing the TBG&IA w/treated seawater and Diesel as freeze protect. *Pump 360 bbls of treated seawater down the IA while taking returns up the TBG to flowback tanks. *Pump 120 bbls of diesel down the IA while taking returns up the TBG to flowback tanks. *Complete a passing MIT-Combo on the TBG&IA to 3500 psi. *U tube the TBG x IA to ensure the freeze protect is distributed evenly. **Catcher sub left on top of Evo Trieve at 11,755'slm.Will need a 4"GS to pull,This is on ODS in Expro Trailer** ***Nabors 19 AC Well Status:Evo-Trieve RBP set @ 11,755'slm,T x IA freeze protected w/diesel to 2500',treated seawater 2,500'-11,688',GLM#1 has empty pocket,GLM#2-3 Dummy GLVS*** 9/4/2017 9/5/2017 0.0 00:00 9/4/17-00:00 9/5/17 *Continue to let ODSN-04 u-tube from IA to TBG to ensure the freeze protect is dispersed evenly. *After 18 hours of U-tubing it is decided to seta BPV in preparation for the RWO. *MIRU GE Vetco Gray and set a BPV in the TBG hanger. *Handover ODSN-04 from Wells-OPS. **Catcher sub left on top of Evo Trieve at 11,755'slm.Will need a 4"GS to pull,This is on ODS in Expro Trailer** ***Nabors 19 AC Well Status:Evo-Trieve RBP set @ 11,755'slm,T x IA freeze protected w/diesel to 2500',treated seawater 2,500'-11,688',GLM#1 has empty pocket,GLM#2-3 Dummy GLVS,BPV set in TBG hanger*** 9/19/2017 9/20/2017 0.0 8.50 Rig accepted on ODSN-04 RWO 00:00.Finish freeze protect well.Allow diesel to U-tube.Vetco Gray install TWC.R/D lubricator. Secure well&prepare rig for rig move.Swap from Hi Line to Rig electrical power.Hold PJSM for rig move.RDMO ODSN-28 RWO&MIRU on ODSN-04 RWO. ***Provided 48 hour notice to AOGCC for BOPE test on 09-21-2017 1:00 PM.*** 9/20/2017 9/21/2017 0.0 8.50 Cont to move Rig over ODSN-04 and RU Pull BPV on lubricator Circ out diesel freeze protect with 40bbls BaraKlean followed by 575bbls seawater to OPS flowback tank Bleed off trapped pressure in 4-1/2"tubing to bleed trailer Pull BPV on lubricator&ND Tree Bleed trapped pressure in WLRSSSV control line to bleed trailer RU Riser&BOPE Page 1/4 Report Printed: 10/13/2017 ce •CAELIJS • Ataska Operations Summary Report- State Well Name: ODSN-04 ww Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 9/21/2017 9/22/2017 0.0 8.50 Test BOPE per sundry#317-244 -Rams,Annular,&Valves pressure tested to:250psi low,3500psi high -Test Joints:4"&4-1/2" -Result:Passed -AOGCC:Witness waived by AOGCC rep Matt Herrera @ 18:56 9/20/2017 via email Pull test dart Pull BPV on dry rod RU HAL Slickline and Pressure test lubricator to 500psi -POOH with junk basket -POOH with Evo-Treive Bullhead 150bbls down 4-1/2"tubing 30min flowcheck Pull 4-1/2"12.6#C-110 Hydril 521 hanger&seal assembly free 30min Flow check 9/22/2017 9/23/2017 0.0 8.50 POOH with 4-1/2"12.6#C-110 Hydril 521 completion from 12,750'to surface Flush and function stack with junk basket installed Install 6-3/8"wear ring PU and RIH with RPB running BHA on 4"DP from surface to 170' Fill hole w/5bbl/30min+150%displacement volume 9/23/2017 9/24/2017 0.0 8.50 RIH with RBP assembly from 170'to 3,869'and set -Top:3859,Element:3862',Bottom:3869' Fill hole with seawater and test RBP to 2500psi -Increase pressure in 500psi/5min while monitoring OA,Test sequence charted -RBP held 2500psi for 5min -No change in pressure observed on OA. Spot 20bbl BaraCarb pill as per Bariod procedure -Tagged top of BaraCarb pill at 3,847'3 POOH with RBP running assembly from 3,847'to surface. MU and RIH with scrapper/magnet BHA from surface to 3,365',POOH MU and RIH with 7"casing cutter assembly from surface to 2,300' Cut 7"26#L-80 Hydril 563 casing at 2,326' Circ out OA diesel freeze protection to OPS flowback tank POOH with 7"casing cutter assembly from 2,326'to surface and LD BHA Swap BOPE upper rams from 2-7/8"x 5"VBR to 7"ram 9/24/2017 9/25/2017 0.0 8.50 Test BOPE 7"upper ram with 7"test joint to 250psi low,3500psi high -Passed Pull 7"pack-off,&hanger POOH w/7"26#L-80 Hydril 563 casing from surface to 2,326' PU Baker casing back-off assembly and RIH from surface to 2,825'on 4"DP Back-off 7"26#L-80 Hydril 563 dutchman at 2,327' POOH with Baker casing back-off assembly from 2,825'to surface and LD BHA 9/25/2017 9/26/2017 0.0 8.50 POOH with Baker casing back-off assembly from 462'and LD BHA RIH with Baker spear BHA from surface to 2300' Engaged dutchman with spear. Backed off dutchman with 6 rotations POOH with Baker spear assembly from 2,320'to surface and LD BHA Remove 9"wear bushing RIH with 7"26#L-80 Hydril 563 from surface to 2,340. Circ 150 bbls diesel freeze protection down 11-3/4"x 7"OA through 7"gap at 2343.73'and up 7" casing through top drive and back to pits. Screw triple connect into 7"casing and work 12.200ft-lbs down to triple connect Test 7"casing ID to 2500 psi/30min,charted,Passed RU to lift stack and set 7"casing slips -Pump out 7"casing and stack Page 2/4 Report Printed: 10/13/2017 • • Operations Summary Report- State Well Name: ODSN-04 CIECAEUJS rm. Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gaI) Summary 9/26/2017 9/27/2017 0.0 8.50 Cont to RU to lift stack and set 7"casing slips Lift stack to perform 7"slip setting and cut Set 7"casing slips with 115klbs at slip body WACHS cut 7"casing and set pack-off Test 7"casing pack-off as per Vetco -4300psi/10min,Passed Swap 7"rams in upper ram body with 2-7/8"x 5"VBR's -Test 2-7/8"x 5"VBR's in upper and lower ram bodies to 250 psi low,3500psi highl0 min low/high,charted -Test annular to 250 psi low,2500psi high forlOmin,charted -Annular,upper ram,&lower ram tested with 2-7/8"test joints -Upper VBR ram tested with 4"test joint -All tests passed Install 6-3/8"wear bushing PU and RIH with RBP retrievable BHA on 4"DP from surface to 3,815' -Tag BaraCarb pill 40'above RBP Wash down to 2'above RBP at 3859'and latch onto RBP Slip and cut drill line Fill hole w/5bbls every 30min 9/27/2017 9/28/2017 0.0 8.50 Remove 6-3/8"wear bushing MU ESP assembly to 91' RIH with 2-7/8"6.4#L-80 IBT-M tubing ESP completion from 91'to 2024' Fill tubing 5bb1/30min 9/28/2017 9/29/2017 0.0 8.50 POOH from 2,024'to surface with 2-7/8"6.4#L-80 IBT-M ESP Completion due to ESP cable failure Inform Drilling Manager of damage Decision to suspend ESP install and Test BOPE. Notified AOGCC Rep Brian Bixby of immediate BOPE test. AOGCC Rep Adam Earl en route to witness BOPE test. Install test dart and PU BOPE test tools Test BOPE per sundry#317-244 -Rams,Annular,&Valves pressure tested to:250psi low,3500psi high -Test Joints:2-7/8" -Result:Passed -AOGCC:Witnessed by AOGCC rep Adam Earl LD test tools and pull test dart RIH 2-7/8"6.4#L-80 IBT-M ESP completion from surface to 1,529' 9/29/2017 9/30/2017 0.0 8.50 RIH with 2-7/8"6.44 L-80 IBT-M ESP Completion from 1,526'to 8,678' -Bullhead 75bbls seawater at 8,088'down tubing -Cont to fill annulus 5bb1/30min 9/30/2017 10/1/2017 0.0 8.50 RIH with 2-7/8"6.4#L-80 IBT-M ESP Completion from 8,678'to 11,449' Land 3-1/2"tubing hanger -SO:75klbs Pressure test tubing hanger seals -5000psi,good RU HAL slickline w/lubricator and RIH with ball and rod RD HAL slickline Set Weatherford ESP packer -Pressure test tubing to 3500psi for 30min/charted -Pressure test IA to 2500psi for 30min/charted Shear DCK and confirm SET TWC on dry rod Pressure test TWC from below via IA -1500psi for 10min Page 3/4 Report Printed: 10/13/2017 • • 411126, Operations Summary Report- State Well Name: ODSN-04 kg LL Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 10/1/2017 10/2/2017 0.0 8.50 ND BOPE&riser Perform wellhead control line feed through NU Tree Test tree void to 5000psi/10min Pull TWC with lubricator Freeze protection 2-7/8"tubing and IA with diesel -132bb1 diesel @ 2bbl/min Install TWC via lubricator RDMO ODSN-04 to ODSN-17 Release rig from ODSN-04 Accept rig on ODSN-17 as of 10/2/2017 @ 00:00 10/5/2017 10/6/2017 0.0 8.50 00:00 10/5/17-00:00 10/6/17(Post RWO S/L) *MIRU HES Slickline. *Take control of well from OPS-Wells. *MIRU GE Vetco Gray and pull the TWC from the TBG hanger. *Pull the Ball and Rod from the RHC-M at 3,509'slm. *Pull 1"DCK SOV from GLM#2 at 3,231'slm.Valve on surface. *Set 1"DGLV in GLM#2 at 3,231'slm.Good set. *Run the Ball and Rod on a 2"RS to land in the RHC-M set in the X nipple at 3,509'slm.Stay on ball and rod.Pressure test the TBG to 3500 psi. IA does no track.Monitor for 15 min.DGLV are holding. *Unseat the ball and rod after bleeding pressure to 1000 psi.pressure falls to 0 psi.POOH to surface. *Pull the RHC-M set in the X nipple at 3,515'slm. *Lay down HES Slickline for the night. *Hand well over to OPS from Wells. Page 4/4 Report Printed: 10/13/2017 • • ODSN-04 Nuiqsut Production Well Completion FINAL 10-9-17 I No. Upper Completion Equipment MD(ft) TVD(ft) I Upper A GE Tubing Hanger 34 34 -����'�I Completion 3-112"9.2 i 7 3.112"9 7)TC-II Pin L-80 Cro. ,, . Landed with C 3-1/2"L-80 9 2#tubing joint TC-II Box x Pin(2 Joints) 40,000 lbs �_" ' 3-1,12"9.2#L-80 1"L x 2-7;8"6.4#IST-M Pin GLM= d Slack Off DGL', O J K E 2-7/8"6.4#L-80 IBT-M Tubing '6.4#L-80 IBT-M 15ft Pup Joint Box x Pin -1/8"'NE'TRSV w/2.313"X"Profile-IBT-M Box x Pin-Control line to surface 26J lasa A © ,16"Conductor 2-7/8"6.48 L-80 IBT-M 15ft Pup Joint Box x Pin GLM# RHC-M I 2-7/8"6.4#L-80 IBT-M Tubing x DGLV © stalled in 2-7/8"6.4#L-80 IBT-M 15ft Pup Joint Box x Pin X Nipple K 2-7/8"x 1"GLM#3 KBMG IBT-M Box x Pin 3256 2451 Casing Repair: L 2-7/8"6.4#L-80 IBT-M 15ft Pup Joint Box x Pin New 7"Casing M 2-7/8"6.4#L-80 IBT-M Tubing um 2,344'MD to ` • N 2-7/8"6.48 L-80 IBT-M 15ft Pup Joint Box x Pin Surface Ea ,'7/8"x 7"WET Hydrow II ESP Packer with Packer Vent Valve IBT-M Box x Pin /354 2495 A 5111h.. P 2-7/8"6.48 L-80 IBT-M 5ft Pup Joint Box x Pin Q 2-7/8"6.4#L-80 IBT-M Tubing 2-7/8"6.5# 11-3/4"60#L-80 1 2-7/8"6.4#L-80 IBT-M 15ft Pup Joint Box x Pin L-80 IBT-M BTC Surface s 2-7/8"x 1"GLM#2 KBMG IBT-M Box x Pin 3441 2533 Tubing Casing T 2-7/8"6.4#L-80 IBT-M 15ft Pup Joint Box x Pin (Upper @ 5,284'MD/ U 2-7/8"6.4#L-80 IBT-M Tubing Completion)_ 3,339'TVD v 15 ft.2-7/8"6.4#IBT-M Box x 2-7/8"6.4#EUE Pin L-80 Crossover Pup Joint Box x Pin cemented to 1N 2-7/8""X"Nipple(2.313"ID)EUE Box x Pin 3540 2576 surface X 15 ft.2-7/8"6.48 EUE Box x 2-7/8"6.48 IBT-M Pin L-80 Crossover Pup Joint Box x Pin Y 2-7/8"6.4#L-80 IBT-M Tubing AA J Z 2-7/8"6.4#L-80 IBT-M 15ft Pup Joint Box x Pin AA 2-7/8"x 1"GLM#1 KBMG IBT-M Box x Pin 11186 5912 k 9-5/8"40#L-80 BB 2-7/8"6.4#L-80 IBT-M 15ft Pup Joint Box x Pin GLM#1 Hydril 521 CC 2-7/8"6.4#L-80 IBT-M Tubing 5/16"OV Intermediate 1 DL) 15 ft.2-7/8"6.4#IBT-M Box x 2-7/8"6.48 EUE Pin L-80 Crossover Pup Joint Box x Pin Pre-Installed EE "XN"2.313"2.205"No-Go IBT-M Box x Pin 11285 5954 Casing @ 10,365'MD/ FF 15 ft.2-7/8"6.4#EUE Box x 2-7/8"6.48 IBT-M Pin L-80 Crossover Pup Joint Box x Pin 5,561'TVD GG 2-7/8"6.4#L-80 IBT-M Tubing Cemented 500' HH Auto Diverter Valve 11372 5991 II ESP Pump Assembly 11375 5992 above shoe End of Assembly 11484 6038 EE Chemical Injection Valve (Annular Injection)@ 11,362'MD ® 3/8"Control Line to Surface 1/4"Control Line to top of 1't ii Seal 0 - TOC Estimated 500'above top of Kuparuk 0 1_ ;;;;: 6-1/8"Hole TD :it;'--- @19,868'MD/ . ® ;: 34 6,364'TVD + .� 39 44 49 54 59 64 69 74 79 82 , El _ __id Et Et El E 7"26# L-80 ® - - - _ _ _ _ BTC-M &Hydril 563 - - - Intermediate 2 Casing 29 '� El Elr 14 ® i N ao @ 12,965'MD/6,412'TVD 4-'/z"Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve 4111 • • ODSN-04 Nuiqsut Production Well Completion FINAL 10-9-17 '� No. Lower Completion MD(ft) 7VD(ft) I Mi Upper 18 Baker 5"X7"2XP Liner Top Packer with 15ft Tie Back extension and Flex Lock Hanger 12766 6395 , , di Completion 19 4-A"12.6#/ft C-110 Hydril 521 Liner iiiiii Landed with 20 4-'/:"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers G 40,000 lbsHalliburton Swell Packer(4-':"Hydril 521)00 5.85'-9 meter long oil activated element with 71 13095 6.120 Slack Off slide on Volant centralizers pin end GLM#3 c� J K 22 4-A"12.6#/ft C-110Hydri 1521 Liner DGLV Oo E. iiii 23 HLB4-1/2"SLHT Ball Actuated Sleeve(3.009 ball/2.95 Seat) 13270 6419 IO =4 24 4-%"12.6#/ft C-110 Hydri 1521 Liner cL I ,16"Conductor � 25 4-'/."12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers © Halliburton Swell Packer(4-A"Hydril 521)OD 5.85'-9 meter long oil activated element with GLM#2 O I RHC-M 26 slide on Volant centralizers pin end 13456 6417 DGLV © Installed in 27 4-A"12.6#/ft C-110 Hydri 1521 Liner X Nipple 28 i.4-A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-A"Hydril 521)OD 5.85'-9 meter long oil activated element with 7"Casing Repair: 29 13621 6421 slide on Volant centralizers pin end New 7"Casing 30 4-A"12.6#/ft C-110Hydril 521 Liner from 2,344'MD to ` 31 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.925 ball/2.867 Seat) 13967 6419 Surface 32 4-A"12.6#/ft C-110 Hydril 521 Liner ® ® 33 4-A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-'A"Hydril 521)0D 5.85'-9 meter long oil activated element with dial kik 34 slide on Volant centralizers pin end 14271 6421 2-7/8"6.5# 11-3/4"60#L-80 35 4-'A"12.6#/ftC-110 Hydril 521 Liner L-80 IBT-M BTC Surface 36 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.842 ball/2.786 Seat) 14613 6415 Tubing Casing 37 4-A"12.6#/ft C-110 Hydril 521 Liner 38 4-''i:"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers (Upper @ 5,284'MD/ Halliburton Swell Packer(4-''/."Hydril 521)OD 5.85'-9 meter long oil activated element with Completion)_ _ 3,339'TVD 39 slide on Volant centralizers pin end 14920 6399 cemented to 40 4-A"12.6#/ft C-110 Hydri1521 Liner surface 41 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.761 ball/2.706 Seat) 15185 6397 42 4-'/:"12.6#/ft C-110Hydri 1521 Liner 43 4-A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers p 1 44 Halliburton Swell Packer(4-'A"Hydril 521)00 5.85'-9 meter long oil activated element with 15452 6395 ilih. slide on Volant centralizers pin end 9-5/8"40#L-80 45 4-A"12.6#/ft C-110Hydri 1521 Liner GLM#1 46 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.681 ball/2.628 Seat) 15833 6395 Hydril 521 47 4-A"12.6#/ftC-110Hydril521 Liner 5/16"OV Intermediate 1 48 4-A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Pre-Installed Halliburton Swell Packer(4-'''A"Hydril 521)OD 5.85'-9 meter long oil activated element with Casing 49 16179 6397 @ 10,365'MD/ slide on Volant centralizers pin end 50 4-'/."12.6#/ft C-110 Hydril 521 Liner 5,561'TVD 51 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.603 ball/2.552 Seat) 16544 6388 Cemented 500' 52 4-'/."12.6#/ft C-110 Hydril 521 Liner above shoe 53 4-A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-'/."Hydril 521)OD 5.85'-9 meter long oil activated element with (2) 54 slide on Volant centralizers pin end 16850 6388 Chemical Injection Valve 55 4-'A"12.6#/ft C-110 Hydril 521 Liner (Annular Injection)@ 11,362'MD 56 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.527 ball/2.477 Seat) 17156 6387 ® 3/8"Control Line to Surfacer 57 4'/:"12.6#/ft C-110 Hydril 521 Liner iiii 1/4"Control Line to top of 1' 58 4-A:"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Seal Halliburton Swell Packer(4-A"Hydril 521)OD 5.85'-9 meter long oil activated element with 0 59 slide on Volant centralizers pin end 17463 6388 iiiii TOC Estimated 60 4-%"12.6#/ft C-110 Hydri 1521 Liner 500'above top of 61 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.452 ball/2.404 Seat) 17727 6390 iii Kuparuk 62 4A"12.6#/ft C-110 Hydri 1521 Liner ii. iii.i. 63 4-'/."12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-A"Hydril 521)0D 5.85'-9 meter long oil activated element with64 17993 6393 slide on Volant centralizers pin end 0 65 4-'/."12.6#/ft C-110 Hydril 521 Liner iP 66 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.379 ball/2.332 Seat) 18255 6395 is e 21 6-1/8"Hole TD @19,868'MD/ ® 6,364'TVD 11 S9 = ® 11 79 82 7"26# L-80 zs of $ it = 49_ _ _ _ _ _ _ _ o BTC-M &Hydril 563 - _ - - I I Intermediate 2 Casing 29 l g ® I 1 IIIc ■■_ BO @ 12,965'MD/6,412'TVD 4-'/2"Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve • 0► ODSN-04 Nuiqsut Production Well Completion FINAL 10-9-17 1 I Upper _No. Lower Completion MD(ft) TVD(ft) Completion 67 4-14"12.6#/ft C-110 Hydril 521 Liner Landed with 68 4-'X"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers O 40,000 lbs 69 Halliburton Swell Packer(4-34"Hydril 521)OD 5.85'-9 meter long oil activated eler Slack Off slide on Volant centralizers pin end GLM#3 • J O 70 4-X"12.6#/ft C-110 Hydril 521 Liner DGLV _ u) 71 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.307 ball/2.261 Seat) 18955 6389 �4a1 72 444"12.6#/ft C-110 Hydril 521 Liner A J s ,16"Conductor 73 4-14"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers — RHC-M Halliburton Swell Packer(4-14"Hydril 521)OD 5.85'-9 meter long oil activated element with GLM#2 ®x w Installed in 74 slide on Volant centralizers pin end DGLV X Nipple 75 4-4"12.6#/ft C-110 Hydril 521 Liner 76 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.236 ball/2.192 Seat) 19512 6378 Casing Repair: 77 4-'/,"12.6#/ft C-110 Hydril 521 Liner ew 7"Casing 78 444"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers in 2,344'MD to Surface 79 Halliburton Swell Packer(4-34•'Hydril 521)0D 5.85'-9 meter long oil activated element with 19779 2Ilh: slide on Volant centralizers pin end 80 Pre-Perforated Pup with 4-X"12.6#/ft C-110 Hydril 521 Pup above and below J81 4-14"12.6#/ft C-110 Hydril 521 Liner 2-7/8"6.5# 11-3/4"60#L-80 82 Eccentric Shoe with Float Sub 19855 6363 L-80 IBT-M BTC Surface Bottom of Shoe 19858 6363 Tubing Casing (Upper © 5,284'MD/ Completion)_ 3,339'TVD cemented to surface J.IAAA li 111. 9-5/8"40#L-80 GLM#1 Hydril 521 5/16OV Intermediate 1 Pre-Installed Casing @ 10,365'MD/ 5,561'TVD Cemented 500' above shoe EE Chemical Injection Valve Annular Injection)@ 11,362'MD HH 3/8•'Control Line to Surface 1/4"Control Line to top of 1'' Seal - TOO Estimated __ 500'above top of Kuparuk UP .0".•,i;,. . "'; -• Z' 6-1/8" Hole TD @ 19,868'MD/ if* . O O O O 0 0 0 0 6,364'TVD 34 39 44 49 54 59 64 69 74 79 7"26# L-80 - - _ _ _ _ - _ - _ fiz BTC-M&Hydril 563 z6 ® - - - o12 9 ® as ill X 1 l i Intermediate 2 Casing ao © 12,965'MD/6,412'TVD 4-'/2"Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve vOr Tit, THE STATE Alaska Oil and Gas 0.,,;.—sem it, o Conservation Commission ___'°- fALAs��`11 s - }�:Z:::;:74-:'. 333 West Seventh Avenue " `� l. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wM Main: 907.279.1433 A S�� Fax: 907.276.7542 www.aogcc.alaska.gov Rami Jasser �� `'Ll i o 6 2017 Seior Staff Completion Engineer Caelus Natural Resources Alaska, LLC 3700 Centerpoint Drive, Suite 500 Anchorage, AK 99503 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-04 Permit to Drill Number: 213-037 Sundry Number: 317-244 Dear Mr. Jasser: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC 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, Cathy P. Foerster ,,,, _ Chair DATED this �/' day of June, 2017. RBDMS 1,U'JUN t 6 2017 '14ECEIVED STATE OF ALASKA JUN 1 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION 07S C/20/I APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 , Operations shutdown El Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 . Change Approved Program❑ Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other. Repair 7"Casing/Run ESP El- 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Caelus Natural Resources Alaska,LLC Exploratory ❑ Development 0 , 213-037 3.Address: Stratigraphic ❑ Service [] 6.API Number. 3700 Centerpoint Drive,Suite 500,Anchorage,AK 99503 50-703-20670-00-00 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ODSN-04 ' Will planned perforations require a spacing exception? Yes El No 0 ✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 389958/ADL 389959 • Oooguruk-Nuiqsut Oil Pool i 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 19,868' 6,364' • 19,858' • 6,363' , 1,155 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5,241' 11-3/4" 5,284' 3,339' 5,830 psi 3,180 psi Intermediate 5,258' 9-5/8" 5,105'-10,365' 3,260'-5,561' 5,750 psi 3,090 psi Production 12,923' 7" 12,965' 6,412' 7,240 psi 5,410 psi Liner 7,092' 4-1/2" 12,766'-19,858' 6,395'-6,363' 11,590 psi 9.200 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attachment pg.2 ' See attachment pg.2 4-1/2" 12.6#,C-110,Hyd 521 12,782' Packers and SSSV Type: See attachment pg.3 Packers and SSSV MD(ft)and TVD(ft): See attachment pg.3 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development 0 r Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/22/2017 OIL 0 , WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ El Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Staff C,u.I: ion En•ineerContact Email: rami.IaSSertU7ca61US2n@rov.com Authorized Signature: / Date: Contact Phone: 907-343-2182 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 (7- z `{`( Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance El OSC (p 1 Zo Other: )( 3SO0 pSv BD() `/rs-.F--- Post Initial Injection MIT Req'd? Yes ❑ No ❑ � JLJN t't!�I� 2 6 20�ti/7 Spacing Exception Required? Yes ❑ No Ei Subsequent Form Required: ) y 0`'� RDDIl11S j" APPROVED BY Approved by: , .....‘4414,-.—. COMMISSIONER THE COMMISSION Date: G -La _ /7 ?� b /11 i�- ,1 &67 2/_ 4.--.26-1 O Submit Form and Attachments 10-403 Revised 4/2017 RP Rr1af I a nes valid for 12 months from the date of approval. in Duplicate • I CAEL1JS June 8, 2017 RECEIVED JUN State of Alaska Alaska Oil and Gas Conservation Commission AOG CC 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: ODSN-04 Sundry Application to repair 7" casing and replace 4-1/2" Frac/Gas Lift Upper Completion with a 2-7/8" ESP Upper Completion REF: Approved Permit to Drill #213-037 Caelus Natural Resources Alaska, LLC. (CNRA) submits an Application for Sundry to fix 7" Casing due to a shallow casing IA x OA leak and Replace 4-1/2" Frac/ Gas Lift Upper Completion string with a 2-7/8" ESP Upper Completion on ODSN-04. See the proposed plan attachments and supporting documentation. Sincerely, Rami :sser Senior Staff Completion Engineer Attachments: Form 10-403 Supporting Information cc: ODSN-04 Well File • 2 ODSN-04 Procedure Summary: Pre-Rig: 1. Set EVO-trieve above deep XN nipple or PXN plug in XN nipple 2. Confirm DV's in GLM#2 and GLM#3 3. Pull OV from GLM#1 4. Fluid pack tubing and IA with treated/filtered seawater 5. Freeze protect tubing and IA to 2,500' TVD with diesel 6. Combo Test Tubing x IA to 3500 psi c -r 7. Set BPV 8. Test Pack-offs to 5000psi 9. Lube and bleed Tubing and IA to ensure fluid packed Rig Work: 1, MIRU N19AC 2. Install test dart 3. ND Tree/ NU BOPE 4. Test BOPE to 250psi low/3500psi high; Annular to 2500psi 5. Circulate out diesel freeze protect with treated/filtered seawater 6. Circulate IA to tubing at high rate with surfactants to clean IA 7. SL - Install DV in GLM#1 8. SL - Pull EVO-trieve or PXN plug 9, Monitor fluid level in tubing, establish loss rate 10. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 11. BOLDS 12. Pull seals from SBR 13. Monitor fluid level in tubing and IA, establish loss rate 14. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 15. POOH with 4-1/2" Frac / GL string and LDtA- G yam' 16. PU and RIH with 7" RBP, set at 0'rlAD 10) 17. Fluid pack 7" casing with treated seawater, Pressure test RBP to 3500psi 18. Dump sand on top of RBP 19. POOH with RBP setting tool 20. RIH with bit, scraper and magnets to 3,950' MD, tag top of sand 21. Circulate clean 22. POOH Cleanout BHA 23. PU and RIH with 7" mechanical casing cutter 24. Locate 7" collars at depth and cut casing mid joint, -3,380' MD (2500' TVD) 25. Circulate casing and IA (7"x11-3/4") to seawater, ensure IA is dead 26. POOH with casing cutter 27. BOLDS on 7" casing hanger 28. Break hanger free, POOH and LD 7" casing - identify leak point 29. PU and RIH with Back-off tool 30. Engage 7" stub, back off 7" dutchman, POOH and LD 31. Contingency fishing run for dutchman if needed 32. PU Triple Connect Screw-in sub and RIH on new 7" casing 33. Place diesel FP in IA, close Annular protector 34. Screw into 7" casing at depth, work appropriate torque into string 35. Ensure IA dead 36. Break BOPE and lift 37. Pull tension in 7" casing and set casing slips, RILDS • ss (di'41-3 „.3 e6, 11 38. Rough cut 7” casing, LD stub (08 39. Set back BOPE on stump 5.1? 40. WACHS cut 7" s r 1`` C`�.�`� 41. Install 7" PO's and test 42. NU BOPE and test breaks 43. RIH with RBP retrieving tool, circulate sand from RBP 44. Release RBP, establish loss rate 45. Follow Caelus Well Control SOP with no fluid level at surface - minimizing losses to formation 46, POOH and LD RBP and tools 47. PU and RIH with 2-7/8" ESP upper completion as per attached schematic, with OV installed in GLM#1 48. Drop Ball-Rod 49. Set packer 50. Pressure test tubing to 3500psi, Pressure test IA to 3500psi 51. Shear SOV in GLM#3 52. Freeze protect tubing and IA with diesel to 2,500' TVD 53. Close ScSSSV 54. Set BPV, test from below 55. ND BOPE/NU Tree 56. RDMO N19AC Post Rig (Slick-line): 1. Pull Ball-Rod 2. Pull SOV from GLM#3 3. Set DV in GLM#3 4. Pull RHC • • 4 Reservoir Pressures: Nuiqsut Pressure: 1,790 psi at 6,350' TVDss after 30 days of shut-in = 0.28 psi/ft = 5.4 ppge Maximum surface pressure: 1,790 psi at 6,350' TVDss reservoir pressure with 0.1 psi/ft gas gradient = 1,155 psi MASP ODSN-04 Nuiqsut Bottomhole Pressure Build Up 3,500 —2014 Initial Pressure 3,000 Seawater(8.55 ppge) 2,500 -LVT/Diesel(6.8 ppge) co co M 10/15/16 PBU •�–° 2,000 a X03/23/17 PBU 3 y1,500 •• • Expected Pressure Build Up T. a oa ra m u 1,000 0 500 0 0 5 10 15 20 25 30 Shut-in Time,Days 0 • 5 Original Well Schematic: ODSN-04 Nuiqsut Production Well Completion FINAL 12-13-201b No. Upper Compact on d4i'equipment n !e ue be no ss then 10,000ps�nted( MD(ft) TW[ft) Upper - 1 -atoll-a-;e• 34 34 Completion z 14.1z6e ft:- -,_- 5::--t Landed with 3 a >8r.msrgeu, L'.'- 40,000 '.-40,000 lbs ' 4 14.1260)ft G1.2 ,z _-- __ a Slack Off 5 1'5'x1"GOA= 2478 6 14'1260:ft.'-110-,_- 521-.t.-y 7 115"w•lippl a 5813' . 3421 2526 I , 3 14'1260/ft C-110nyd,+.521-_t-e 16"Conductor . 3.'.1 GIM e2 KrMG r,: 659 10 s-."us ftc-itc.id 5217-b.n; 11 1: .: G0.1 e1 Er,3G-,- .,. Packer Fluid MIX: 12 -14•1260,ftC-11G-yo- 521-,.trn; Inhibited Kill weight 13 Mr5AN 4S(1725'NoGo(•(11a i ndertion 68dep'ees} 11871 6168 Brine 14 44 125a-ftC-110n4a 521--t•.; 4.5" FXE I C. with 2000'TVD 15 a; button ROC Ge..• e:a met a!e•• ?:new Surface WRSSSV at ell / diesel cap 16 1• .s+,ftc-im^,d- 521-utint 2,304' MD tttq��'t .. 6. 17 641 et Seal Ayemuy with HS Set f-Nig nmg Mw)e Shoe 12766 6335 1 Bottom of Shoe '._a.. _ 66. No. Lower Comp etion MD(ft) TYD(MI 11-3/4"60#L-80 18 Baker 5'XT DIP Liner Top Packer with 15ftTia Deet estensio,and Flea ea toMenge' GLM#3 DV 5 GI- 111:11BTC Surface Casing 19 14 1260/ftc-lm-,�- 521Lne• @ cemented MD/ surface TVD 20 4.4.126/ft ryd= 5z1-5 1Une• s de Venom cent,'>zez 7 tial5b:erton Swe0 Swim(4-Y'Hydril 521(013516-9meter long ail ectisated el erne to vet' to 21 s-S de onVodent centralizers pun end 22 4- t2.58,ftc-110'•yd.- 521Lne• 25 -34-312•5L)176a Actuated See.e)3 CO3 ba 'L955eat1 .::. 611> GLM#2 i. 24 14.1260/ftc-110.tyd-':521Lne- OL 9-5/8"40#L-80 25 14'1260/ft hyo- 521.6 pup w th s 4e on Vo ant cent,se-s DV 0 I Hydril 521 26 Mali Merton Swel dr (44V Hyd61524 00 185-9meter km'ail ace rat ed el ement+rra• iii Intermediate 1 si de onVolent centralizers pin end A k Casing 27 44"1260ifte-110nyd- 5211ne- 23 14'1260/ft nye!, 521.6 Sup with side on Vo ant cent,ze•s @ 10,365'MD/ >1.i button Swel Packer(4-%•Hydril 521;x13585--9meter tong ail activated dement wet, 5,561'TVD de onVoiant centred biers pin end Cemented 500' 3, 1'='1268/tC-lbnyd :521Lne- above shoe it: --54.1/2-SL!-,6a'.. Actuated s ee,e;2325b /2867Seat) .5%- 54:= _: 14•1261,11C-110nydr521Lne- 35 1•:'1260/ft nyd-. 521-6 Sup wih s:41e on Vo'ant cent-a':.ze-4 _ t a Marton Swell Packet(4X'H.061524 OD Ste-9 meter long oil acv,.... . ..., ie onVodent centre end 35 14'12 'ftC-130 nys- 5:1.ne- GLM#1 4-1/2" 12.6#C-110 36 n311/2'S..n'6s Ad-ated ice.(26Q Mt-/1716Seat) 1.1513 6115 5/16"OV — GL Hydril 521 3' 4.4'1260/ftc-11C-,-s- 521 Lew .i..'' Tubing 38 14'1260/ftnyd-,521-6 Sup wthaftleonVol ant cenaades Bottom Latch HatSMrton SwelPecker(4-14•Hydtil 5211 OD 56'-9 met er dory)ail scv..,. -. 41) CZ I 111 . (Upper Completion) 39 side onVaiett central tiers pin end ' ' I 40 4 1261/ftC-110+ayd= 521 Linc- I-17 41 -34-YT SLn'5e Actuated lee.e'2.'el so '2'06Seat) 513< 6S- 0 °C 42 14'126s;ftc-110nyd- 521Lare- TOC Estimated 43 14.12611ft ryd-'521-6 sup wt•s _e a-t:e-t-a' e-4 500'above top of Kuparuk .(41,- 04 21 6-1/8" Hole TD 4' @ 19,868' MD / ii 6,364'TVD ,, , AIP' i+ 4! `O 39 o 49 e 59 O 69 74 79 or ® _ _ _ W = Y31 = _ _ _ �I 7"26# L-80 26 0 BTC-M& Hydril 563 Intermediate2Casing 29 \ —g--IC -fft -- -- �-' @ 12,965'MD/6,412'TVD 4-1/2"Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve • 1 6 Proposed Well Schematic: ODSN-04 Nuigsut Production Well Completion DRAFT 5-4-17 1 1 k 01.11 No Upp C +rvpie t?san Lqu merat M (ftD __ _ tvrct§_ If1 Upper A GETubngHanger 34 34 I 8 278-6aL-80BT-Ar Tubing Completion C 22.8"1F TR 311 e-15 Pup Top 8 Bottom-Cont i line to surface ;;, 0 Landed with D 2a.s-6aL-80ET-UT-r-, krc: ,,, --- 40,000 lbs E 2248-x r GL1,1 a,En., .-•_ ,131.14 vii If Pup Top&Elocom -._ 2481 Slack Off F 22:2 o da=3O ET.l T,bng © G 2-71 x 7 OFT Hydro..II ESP Packer ^..365 2.5� ® ®0 H 2-7:8-6 4*L-80 BTU Tubing I 2-7:8-z f GLIA*2 BK-5 latch,KBl' „ 11.Pup Top&Bottom ,415 2.535 0 , 16"Conductor J 2-7.8-6 4*L-80 ET-U Tubing 0 K Ili ppix rt 1.5_'5 X L '8"6aL-s IET-UT btry Packer Flnid mil Inhibited Kill weight x r GLM*1 BK-5 tan-.. If Pup Top&Bolton; 1,11, 5,891 Brinek 2-78"64*L-80BT-A1Tubrid 0 2-718-Chemical Haled -mt4us injection)wi tt'Puz 11224 5.927 with 2000'pin P 2-7.8-84*L-813ET-1fT..c- Cliefiels Q '71-1 2.313-22175 - • .. cup Top&Bcttom - 5.98< , _: R 2.7 8-6.4+r L-8018 T-#/Tuta tg S Aub L1.erter Vale 6.'306 11-3/4"60#L-80 T ESP Pang)Assert," 4 '_ 5_A70 BTC Surface End of Assembly 5 345 Casing @ 5,284'MD/ "`_ ' lea.et cz ,15 0 MOlt, . Fy'otftj 1 3,339'TVD 15 baker 5'X7'APliner"Op Packet with 15ftTie 6ackexteraionand flax Lock Hane 6395 cemented to 19 4X'12.6efft C-110 Hydni MI liner surface 20 4.6'12.5A/ft Hydra 521.6'Pup with slide on Vo lent centralizers Halliburton swell Packer(41S"Hydric 521)0D 585'-9 meter longoli activated element wit; 9-5/8"40#L80 21 slkieonvdantcentrallzerspinend 647n GLM#1 —r�� J Hydril521 22 4X'12.6e/ftC-170rydnl321uner DGLV M Intermediate 1 23 HUS 41/2'SL KT Bali Actuated Sleeve(3_709ban/295 Seats 13_7 6411 4 Casing 24 4-'s"12.64/ftC-110Hydnl 521uerr @ 10,365 MD/ 25 4%. 12.6e/ft Hydr1521-6'Pup with slide On V O'ant central izers 5,561'TVD z6 Hal lburton Swell Packer(4X'Hydr11521)OD 585'-greeter longoil activated element watt 6417Ode on V olantcentrallzers pin end Cemented 500' 27 4-X'1268/ft C-170 Hydra 1 S21 liner Chemical above shoe 28 4-14'126e/ft Hyd1521-6'Pup with slide on Volant centralizers Injection �O Hdi allburton swell Paer(4X"Hyddl Sri)W 585'-9meter long oll ac:.a' --1 Valve slide on vdant centralizers On end 6421 (Annular 2-7/8"6.5#L-80 30 4X'1.2.5e/ft C-110Hydnl 521 Injection) 11 0 31 et84-1/2'SLHT Ball Actuated Sleeve(2925 ball/2.867 Seat) 13 5112 IBT-M s Tubing 32 4-X'12.61r/ft C-110 Hydnl S21 liner 33 4h"12.6e/ft Hydra 521-6'Pup with slide On VolantceMrailters (Upper Halliburton Swell Packer(4x'Hydrii Sri)00 18S'-9 meter Iongotiactieated element wit/ O Completion) m slide onvolantcentralizers pin end 35 4X'12.6iri ft 4170 Hy d n l 521 uner 36 HL841/25LKT Ball Actuated Serve(2242 bail 12.786 Se at, 145:3 5315 37 4-•1'12.66/ft C-170 Ie dnl 321 uner TOC Estimated 38 £-1S L26e/ftegdr1521-6'Pup with slide onvolantcentral izers 500'aboimat of HallburtonSwellPacker(4X'Hydr11521)OD585'-9meterlongoilactivatedelementwin p slide on vdarrtcerrtrallzers pin end 1492, E399 Kuparuk 40 4-V126e/ftC-1m Hyde'S23.liner 41 r:E 4-1:C SLIT BaII Actuated Sleeve(2.781 ball/2.705 Seat; 151E 53 42 4-,.'12..6n/ft C-170 Hydn1 521 liner ...0 43 4-V12.6RMHydra521-6•PupwithsldeOn`:o!art_e•tra':..:e*: z, 6-1/8"Hole TD '_ @ 19,868'MD 1 ,r> �0 ® ® ®_ 0 ® CD CD 6,364'TVD \ ®,\ 34 39 44 49 54 59 64 69 74 79 7"26# L-80 _ _ - _ _I BTC M& Hydril 563 lel ED- —X_- - EL__ __ .r __El__ 7__IN__X_ B,Y 80 Intermediate 2 Casing @ 12,965'MD/6,412'TVD 4-'/2" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve • Attachment 2 ,. „4�Na%/�✓gW6H4%SHUT'.wTai//h%4'lH.✓�/5iL/,�iGL ®NN/ia'a.- warm<mva,.nm� nroaorve..muli nada raumram>rnz i.x mmwF. AOGCC Form 10-403 Sundry Application Box 11 - Perforation Locations Well: ODSN-04 Top (MD) Top (TVD) 4-1/2" SLHT Ball Actuated Sleeve w/Seat#11 13,270 6,419 4-1/2" SLHT Ball Actuated Sleeve w/Seat#10 13,967 6,419 4-1/2" SLHT Ball Actuated Sleeve w/Seat#09 14,613 6,415 4-1/2" SLHT Ball Actuated Sleeve w/Seat#08 15,185 6,397 4-1/2" SLHT Ball Actuated Sleeve w/Seat#07 15,833 6,395 4-1/2" SLHT Ball Actuated Sleeve w/Seat#06 16,544 6,388 4-1/2" SLHT Ball Actuated Sleeve w/Seat#05 17,156 6,387 4-1/2" SLHT Ball Actuated Sleeve w/Seat#04 17,727 6,390 4-1/2" SLHT Ball Actuated Sleeve w/Seat#03 18,255 6,395 4-1/2" SLHT Ball Actuated Sleeve w/Seat#02 18,955 6,389 4-1/2" SLHT Ball Actuated Sleeve w/Seat#01 19,512 6,378 Pre-Perforated Pup 19,811 6,366 • Attachment 3 AOGCC Form 10-403 Application for Sundry Box 11 - Packers & SSSV Well: ODSN-04 SSSV MD TVD 4-1/2" Halliburton 'XXO' SVLN 2,304' 1,998' PACKERS 5" x 7" Baker ZXP Liner Top Packer 12,766' 6,395' HES Swell Packer#13 13,095' 6,420' HES Swell Packer#12 13,456' 6,417' HES Swell Packer#11 13,621' 6,421' HES Swell Packer#10 14,271' 6,421' HES Swell Packer#9 14,920' 6,399' HES Swell Packer#8 15,452' 6,395' HES Swell Packer#7 16,179' 6,397' HES Swell Packer#6 16,850' 6,388' HES Swell Packer#5 17,463' 6,388' HES Swell Packer#4 17,993' 6,393' HES Swell Packer#3 18,561' 6,394' HES Swell Packer#2 19,262' 6,384' HES Swell Packer#1 19,779' 6,367' • • P Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-04 PN5 ext 50703206700000 Sperry Drilling Services Definitive Survey Report 26 December, 2013 /I 0 HALLIBURTON 11 tt Sperry Drilling Services • • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD 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-4 Well Position +N/-S 0.00 usft Northing: 6,031,136.46 usfl Latitude: 70°29'46.095 N +EI-W 0.00 usft Easting: 469,905.67 usfl Longitude: 150° 14'45.898 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 13.50 usft Wellbore ODSN-04 PN5 ext Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) IGRF2010 10/11/2013 20.10 80.99 57,680 Design ODSN-04 PN5 ext Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,541.94 Vertical Section: Depth From(ND) +N/-S +EI-W Direction (usft) (usft) (usft) (0) 42.70 0.00 0.00 338.57 Survey Program Date 11/5/2013 From To Survey (usft) (usft) Survey(Wellbore) Tool Name Description Start Date 112.00 732.00 ODSN-4 Gyro Survey(ODSN-4 PN5 ext SRG-SS Surface readout gyro single shot 03/24/2013 774.62 12,714.27 ODSN-4 MWD(ODSN-4 PN5 ext PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 03/25/2013 12,722.03 12,944.74 ODSN-4 MWD SC(no checkshots)(ODE MWD+IFR2+SC+sag Fixed:v2:IIFR dec&axial correction+sag 08/21/2013 13,013.79 13,541.94 ODSN-4 MWD#2(ODSN-4 PN5 ext PB1 MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/07/2013 13,555.00 19,783.79 ODSN-04 MWD#3(ODSN-04 PN5 ext) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/11/2013 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,136.46 469,905.67 0.00 0.00 UNDEFINED 112.00 0.48 26.30 112.00 55.80 0.26 0.13 6,031,136.72 469,905.80 0.69 0.20 SRG-SS(1) 174.00 1.19 320.91 173.99 117.79 0.99 -0.16 6,031,137.45 469,905.51 1.75 0.98 SRG-SS(1) 201.00 1.94 309.55 200.98 144.78 1.50 -0.69 6,031,137.96 469,904.98 2.99 1.65 SRG-SS(1) 263.00 2.42 301.95 262.94 206.74 2.86 -2.61 6,031,139.33 469,903.07 0.90 3.62 SRG-SS(1) 356.00 4.89 284.85 355.74 299.54 4.92 -8.11 6,031,141.41 469,897.58 2.87 7.54 SRG-SS(1) 448.00 7.48 301.23 447.21 391.01 9.03 -17.02 6,031,145.56 469,888.69 3.38 14.62 SRG-SS(1) 541.00 11.08 306.95 538.98 482.78 17.54 -29.34 6,031,154.12 469,876.40 3.99 27.05 SRG-SS(1) 637.00 16.68 305.79 632.14 575.94 31.15 -47.91 6,031,167.81 469,857.89 5.84 46.51 SRG-SS(1) 732.00 20.18 307.43 722.25 666.05 49.09 -71.99 6,031,185.84 469,833.89 3.72 72.00 SRG-SS(1) 12/26/2013 3:38:45PM Page 2 COMPASS 5000.1 Build 61 • 0 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5 @ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +Et-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 774.62 22.52 311.69 761.94 705.74 58.99 -83.92 6,031,195.78 469,822.00 6.58 85.58 MWD+IFR2+MS+sag(2) 870.41 25.53 307.68 849.43 793.23 83.82 -113.97 6,031,220.73 469,792.06 3.57 119.66 MWD+IFR2+MS+sag(2) 965.82 25.86 306.69 935.41 879.21 108.82 -146.92 6,031,245.86 469,759.20 0.57 154.98 MWD+IFR2+MS+sag(2) 1,060.78 27.64 303.55 1,020.21 964.01 133.37 -181.89 6,031,270.55 469,724.34 2.39 190.61 MWD+IFR2+MS+sag(2) 1,158.91 31.45 307.91 1,105.57 1,049.37 161.69 -221.08 6,031,299.03 469,685.27 4.46 231.29 MWD+IFR2+MS+sag(2) 1,253.31 31.34 310.24 1,186.15 1,129.95 192.68 -259.25 6,031,330.17 469,647.23 1.29 274.08 MWD+IFR2+MS+sag(2) 1,346.25 31.25 316.29 1,265.59 1,209.39 225.73 -294.37 6,031,363.36 469,612.25 3.38 317.68 MWD+IFR2+MS+sag(2) 1,441.64 33.89 322.68 1,346.00 1,289.80 264.78 -327.60 6,031,402.54 469,579.17 4.54 366.18 MWD+IFR2+MS+sag(2) 1,539.14 34.36 327.67 1,426.72 1,370.53 309.66 -358.80 6,031,447.54 469,548.16 2.91 419.35 MWD+IFR2+MS+sag(2) 1,629.82 33.18 331.63 1,502.11 1,445.91 353.12 -384.28 6,031,491.10 469,522.86 2.75 469.12 MWD+IFR2+MS+sag(2) 1,726.75 36.11 338.96 1,581.88 1,525.68 403.15 -407.16 6,031,541.21 469,500.19 5.25 524.04 MWD+IFR2+MS+sag(2) 1,818.84 36.88 343.11 1,655.93 1,599.73 454.93 -424.93 6,031,593.06 469,482.63 2.81 578.73 MWD+IFR2+MS+sag(2) 1,917.03 41.42 348.78 1,732.08 1,675.88 515.03 -439.82 6,031,653.21 469,467.98 5.88 640.12 MWD+IFR2+MS+sag(2) 2,010.33 43.80 350.53 1,800.74 1,744.54 577.16 -451.14 6,031,715.39 469,456.91 2.85 702.10 MWD+IFR2+MS+sag(2) 2,104.90 46.99 351.69 1,867.14 1,810.94 643.68 -461.53 6,031,781.93 469,446.80 3.48 767.81 MWD+IFR2+MS+sag(2) 2,201.72 48.91 352.43 1,931.99 1,875.79 714.88 -471.45 6,031,853.17 469,437.16 2.06 837.71 MWD+IFR2+MS+sag(2) 2,297.04 50.46 352.48 1,993.66 1,937.46 786.93 -480.99 6,031,925.25 469,427.91 1.63 908.26 MWD+IFR2+MS+sag(2) 2,389.45 54.12 353.13 2,050.17 1,993.97 859.45 -490.14 6,031,997.80 469,419.06 4.00 979.11 MWD+IFR2+MS+sag(2) 2,486.35 56.99 354.61 2,104.98 2,048.78 938.89 -498.65 6,032,077.27 469,410.87 3.22 1,056.17 MWD+IFR2+MS+sag(2) 2,579.35 60.23 355.02 2,153.41 2,097.21 1,017.94 -505.82 6,032,156.34 469,404.02 3.50 1,132.38 MWD+IFR2+MS+sag(2) 2,675.53 59.59 354.48 2,201.63 2,145.43 1,100.81 -513.43 6,032,239.23 469,396.75 0.82 1,212.30 MWD+IFR2+MS+sag(2) 2,770.12 64.22 353.33 2,246.16 2,189.96 1,183.76 -522.31 6,032,322.21 469,388.21 5.01 1,292.75 MWD+IFR2+MS+sag(2) 2,861.85 66.78 356.02 2,284.21 2,228.01 1,266.85 -530.03 6,032,405.32 469,380.82 3.86 1,372.93 MWD+IFR2+MS+sag(2) 2,957.20 66.70 354.94 2,321.86 2,265.66 1,354.18 -536.94 6,032,492.67 469,374.27 1.04 1,456.74 MWD+IFR2+MS+sag(2) 3,053.86 64.00 352.89 2,362.18 2,305.98 1,441.52 -546.23 6,032,580.04 469,365.33 3.39 1,541.44 MWD+IFR2+MS+sag(2) 3,147.12 63.78 351.99 2,403.22 2,347.02 1,524.54 -557.25 6,032,663.09 469,354.65 0.90 1,622.74 MWD+IFR2+MS+sag(2) 3,241.30 63.71 353.29 2,444.88 2,388.68 1,608.30 -568.07 6,032,746.89 469,344.17 1.24 1,704.66 MWD+IFR2+MS+sag(2) 3,337.04 63.45 353.54 2,487.48 2,431.28 1,693.48 -577.90 6,032,832.10 469,334.69 0.36 1,787.54 MWD+IFR2+MS+sag(2) 3,431.96 64.04 354.11 2,529.47 2,473.27 1,778.11 -587.06 6,032,916.76 469,325.87 0.82 1,869.67 MWD+IFR2+MS+sag(2) 3,526.22 64.68 354.57 2,570.26 2,514.06 1,862.67 -595.44 6,033,001.35 469,317.84 0.81 1,951.45 MWD+IFR2+MS+sag(2) 3,620.86 65.21 353.55 2,610.34 2,554.14 1,947.95 -604.31 6,033,086.64 469,309.31 1.13 2,034.06 MWD+IFR2+MS+sag(2) 3,716.97 64.70 353.40 2,651.03 2,594.83 2,034.46 -614.21 6,033,173.18 469,299.77 0.55 2,118.21 MWD+IFR2+MS+sag(2) 3,812.31 63.59 351.70 2,692.61 2,636.41 2,119.52 -625.32 6,033,258.29 469,288.99 1.98 2,201.46 MWD+IFR2+MS+sag(2) 3,907.31 64.94 352.84 2,733.86 2,677.66 2,204.32 -636.83 6,033,343.12 469,277.83 1.79 2,284.59 MWD+IFR2+MS+sag(2) 4,002.73 66.49 353.60 2,773.10 2,716.90 2,290.68 -647.09 6,033,429.52 469,267.92 1.78 2,368.74 MWD+IFR2+MS+sag(2) 4,097.78 65.80 352.86 2,811.54 2,755.34 2,377.01 -657.34 6,033,515.87 469,258.02 1.02 2,452.83 MWD+IFR2+MS+sag(2) 4,192.46 64.58 353.57 2,851.27 2,795.07 2,462.34 -667.49 6,033,601.24 469,248.22 1.46 2,535.98 MWD+IFR2+MS+sag(2) 4,286.51 64.15 353.45 2,891.96 2,835.76 2,546.59 -677.08 6,033,685.52 469,238.97 0.47 2,617.91 MWD+IFR2+MS+sag(2) 4,382.61 61.86 353.42 2,935.58 2,879.38 2,631.66 -686.87 6,033,770.61 469,229.53 2.38 2,700.66 MWD+IFR2+MS+sag(2) 4,478.55 62.40 353.32 2,980.42 2,924.22 2,715.90 -696.66 6,033,854.89 469,220.08 0.57 2,782.66 MWD+IFR2+MS+sag(2) 12/26/2013 3:38:45PM Page 3 COMPASS 5000.1 Build 61 ! i Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E-/-W Northing Easting DLS Section (usft) (°) (') (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 4,572.77 62.63 355.68 3,023.91 2,967.71 2,799.09 -704.67 6,033,938.11 469,212.41 2.24 2,863.03 MWD+IFR2+MS+sag(2) 4,668.11 63.59 356.26 3,067.03 3,010.83 2,883.91 -710.64 6,034,022.94 469,206.78 1.14 2,944.17 MWD+IFR2+MS+sag(2) 4,763.20 63.42 354.83 3,109.46 3,053.26 2,968.76 -717.25 6,034,107.80 469,200.51 1.36 3,025.56 MWD+IFR2+MS+sag(2) 4,857.09 63.74 353.78 3,151.23 3,095.03 3,052.42 -725.60 6,034,191.49 469,192.51 1.06 3,106.49 MWD+IFR2+MS+sag(2) 4,952.65 64.20 353.35 3,193.17 3,136.97 3,137.75 -735.22 6,034,276.85 469,183.23 0.63 3,189.43 MWD+IFR2+MS+sag(2) 5,048.13 64.16 352.56 3,234.76 3,178.56 3,223.05 -745.76 6,034,362.18 469,173.04 0.75 3,272.68 MWD+IFR2+MS+sag(2) 5,143.34 63.18 351.98 3,276.98 3,220.78 3,307.60 -757.24 6,034,446.77 469,161.90 1.17 3,355.58 MWD+IFR2+MS+sag(2) 5,238.40 64.12 352.00 3,319.18 3,262.98 3,391.95 -769.11 6,034,531.16 469,150.38 0.99 3,438.44 MWD+IFR2+MS+sag(2) 5,320.00 64.14 353.52 3,354.78 3,298.58 3,464.79 -778.36 6,034,604.03 469,141.42 1.68 3,509.62 MWD+IFR2+MS+sag(2) 5,371.78 63.74 353.06 3,377.53 3,321.33 3,510.98 -783.79 6,034,650.24 469,136.17 1.11 3,554.61 MWD+IFR2+MS+sag(2) 5,467.39 64.21 354.99 3,419.48 3,363.28 3,596.43 -792.73 6,034,735.71 469,127.58 1.88 3,637.41 MWD+IFR2+MS+sag(2) 5,562.63 64.48 354.64 3,460.72 3,404.52 3,681.93 -800.49 6,034,821.23 469,120.17 0.44 3,719.83 MWD+IFR2+MS+sag(2) 5,657.38 64.74 354.41 3,501.35 3,445.15 3,767.13 -808.66 6,034,906.46 469,112.35 0.35 3,802.13 MWD+IFR2+MS+sag(2) 5,752.70 64.40 354.49 3,542.28 3,486.08 3,852.81 -816.99 6,034,992.17 469,104.37 0.36 3,884.93 MWD+IFR2+MS+sag(2) 5,847.78 64.21 354.38 3,583.50 3,527.30 3,938.09 -825.29 6,035,077.47 469,096.41 0.23 3,967.34 MWD+IFR2+MS+sag(2) 5,942.61 64.08 355.16 3,624.86 3,568.66 4,023.07 -833.07 6,035,162.47 469,088.97 0.75 4,049.29 MWD+IFR2+MS+sag(2) 6,036.56 63.79 354.83 3,666.14 3,609.94 4,107.14 -840.44 6,035,246.56 469,081.95 0.44 4,130.24 MWD+IFR2+MS+sag(2) 6,132.10 63.67 354.78 3,708.42 3,652.22 4,192.46 -848.19 6,035,331.91 469,074.54 0.13 4,212.50 MWD+IFR2+MS+sag(2) 6,224.71 63.87 355.21 3,749.35 3,693.15 4,275.22 -855.44 6,035,414.68 469,067.63 0.47 4,292.18 MWD+IFR2+MS+sag(2) 6,322.72 64.41 354.73 3,792.10 3,735.90 4,363.07 -863.17 6,035,502.56 469,060.25 0.71 4,376.79 MWD+IFR2+MS+sag(2) 6,417.83 64.55 355.10 3,833.08 3,776.88 4,448.57 -870.78 6,035,588.08 469,052.99 0.38 4,459.15 MWD+IFR2+MS+sag(2) 6,512.73 64.47 355.28 3,873.92 3,817.72 4,533.93 -877.96 6,035,673.46 469,046.15 0.19 4,541.23 MWD+IFR2+MS+sag(2) 6,607.37 63.79 354.03 3,915.22 3,859.02 4,618.71 -885.89 6,035,758.26 469,038.57 1.39 4,623.05 MWD+IFR2+MS+sag(2) 6,702.87 63.65 355.08 3,957.50 3,901.30 4,703.95 -894.02 6,035,843.53 469,030.79 1.00 4,705.36 MWD+IFR2+MS+sag(2) 6,798.37 63.09 354.25 4,000.31 3,944.11 4,788.95 -901.96 6,035,928.55 469,023.20 0.97 4,787.38 MWD+IFR2+MS+sag(2) 6,891.40 63.14 354.45 4,042.38 3,986.18 4,871.52 -910.13 6,036,011.14 469,015.36 0.20 4,867.23 MWD+IFR2+MS+sag(2) 6,987.87 63.30 355.19 4,085.84 4,029.64 4,957.29 -917.90 6,036,096.94 469,007.94 0.70 4,949.91 MWD+IFR2+MS+sag(2) 7,083.12 63.54 355.18 4,128.46 4,072.26 5,042.18 -925.05 6,036,181.84 469,001.13 0.25 5,031.54 MWD+IFR2+MS+sag(2) 7,177.84 64.08 355.96 4,170.27 4,114.07 5,126.92 -931.61 6,036,266.60 468,994.91 0.93 5,112.82 MWD+IFR2+MS+sag(2) 7,270.68 64.35 356.37 4,210.65 4,154.45 5,210.32 -937.20 6,036,350.02 468,989.66 0.49 5,192.50 MWD+IFR2+MS+sag(2) 7,366.93 64.21 356.49 4,252.42 4,196.22 5,296.87 -942.60 6,036,436.58 468,984.61 0.18 5,275.04 MWD+IFR2+MS+sag(2) 7,461.72 64.42 356.15 4,293.51 4,237.31 5,382.12 -948.09 6,036,521.84 468,979.47 0.39 5,356.39 MWD+IFR2+MS+sag(2) 7,556.46 64.01 354.30 4,334.72 4,278.52 5,467.12 -955.19 6,036,606.86 468,972.72 1.81 5,438.12 MWD+IFR2+MS+sag(2) 7,651.42 63.80 356.32 4,376.49 4,320.29 5,552.11 -962.16 6,036,691.87 468,966.09 1.92 5,519.78 MWD+IFR2+MS+sag(2) 7,747.28 64.07 355.71 4,418.61 4,362.41 5,638.01 -968.14 6,036,777.79 468,960.45 0.64 5,601.92 MWD+IFR2+MS+sag(2) 7,840.95 64.37 355.62 4,459.35 4,403.15 5,722.12 -974.52 6,036,861.91 468,954.42 0.33 5,682.54 MWD+IFR2+MS+sag(2) 7,934.71 64.27 354.35 4,499.98 4,443.78 5,806.29 -981.91 6,036,946.11 468,947.37 1.23 5,763.60 MWD+IFR2+MS+sag(2) 8,028.65 64.00 353.91 4,540.96 4,484.76 5,890.38 -990.55 6,037,030.22 468,939.07 0.51 5,845.03 MWD+IFR2+MS+sag(2) 8,124.90 64.34 353.97 4,582.90 4,526.70 5,976.53 -999.70 6,037,116.39 468,930.27 0.36 5,928.56 MWD+IFR2+MS+sag(2) 8,221.76 64.22 354.44 4,624.94 4,568.74 6,063.35 -1,008.51 6,037,203.24 468,921.82 0.45 6,012.59 MWD+IFR2+MS+sag(2) 12/26/2013 3:38:45PM Page 4 COMPASS 5000.1 Build 61 • • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,316.01 64.42 354.12 4,665.78 4,609.58 6,147.86 -1,016.97 6,037,287.78 468,913.69 0.37 6,094.36 MWD+IFR2+MS+sag(2) 8,408.97 64.22 354.57 4,706.06 4,649.86 6,231.23 -1,025.23 6,037,371.18 468,905.78 0.49 6,174.98 MWD+IFR2+MS+sag(2) 8,504.62 64.20 353.81 4,747.68 4,691.48 6,316.91 -1,033.95 6,037,456.88 468,897.41 0.72 6,257.92 MWD+IFR2+MS+sag(2) 8,601.35 63.93 354.45 4,789.98 4,733.78 6,403.44 -1,042.84 6,037,543.44 468,888.86 0.66 6,341.72 MWD+IFR2+MS+sag(2) 8,696.80 63.68 354.20 4,832.12 4,775.92 6,488.67 -1,051.31 6,037,628.69 468,880.74 0.35 6,424.15 MWD+IFR2+MS+sag(2) 8,791.47 64.07 354.30 4,873.80 4,817.60 6,573.24 -1,059.83 6,037,713.29 468,872.56 0.42 6,505.99 MWD+IFR2+MS+sag(2) 8,885.77 64.00 354.12 4,915.09 4,858.89 6,657.59 -1,068.38 6,037,797.66 468,864.35 0.19 6,587.63 MWD+IFR2+MS+sag(2) 8,980.14 63.85 354.26 4,956.57 4,900.37 6,741.92 -1,076.96 6,037,882.02 468,856.12 0.21 6,669.26 MWD+IFR2+MS+sag(2) 9,075.61 64.07 354.80 4,998.48 4,942.28 6,827.31 -1,085.14 6,037,967.43 468,848.29 0.56 6,751.73 MWD+IFR2+MS+sag(2) 9,169.87 63.87 354.70 5,039.85 4,983.65 6,911.65 -1,092.89 6,038,051.79 468,840.88 0.23 6,833.08 MWD+IFR2+MS+sag(2) 9,265.51 63.85 355.19 5,081.98 5,025.78 6,997.17 -1,100.45 6,038,137.34 468,833.66 0.46 6,915.45 MWD+IFR2+MS+sag(2) 9,360.79 64.09 355.19 5,123.80 5,067.60 7,082.49 -1,107.63 6,038,222.67 468,826.83 0.25 6,997.49 MWD+IFR2+MS+sag(2) 9,455.74 64.36 355.55 5,165.08 5,108.88 7,167.71 -1,114.53 6,038,307.92 468,820.27 0.44 7,079.34 MWD+IFR2+MS+sag(2) 9,549.72 64.22 355.79 5,205.85 5,149.65 7,252.15 -1,120.93 6,038,392.37 468,814.22 0.27 7,160.27 MWD+IFR2+MS+sag(2) 9,647.28 63.95 355.49 5,248.49 5,192.29 7,339.64 -1,127.60 6,038,479.88 468,807.90 0.39 7,244.16 MWD+IFR2+MS+sag(2) 9,742.22 64.02 355.76 5,290.13 5,233.93 7,424.71 -1,134.11 6,038,564.97 468,801.74 0.27 7,325.72 MWD+IFR2+MS+sag(2) 9,837.04 64.41 355.17 5,331.38 5,275.18 7,509.82 -1,140.86 6,038,650.10 468,795.33 0.70 7,407.42 MWD+IFR2+MS+sag(2) 9,930.55 64.61 354.84 5,371.62 5,315.42 7,593.91 -1,148.21 6,038,734.21 468,788.33 0.38 7,488.38 MWD+IFR2+MS+sag(2) 10,026.77 64.14 355.21 5,413.23 5,357.03 7,680.34 -1,155.73 6,038,820.66 468,781.15 0.60 7,571.58 MWD+IFR2+MS+sag(2) 10,122.59 63.86 354.12 5,455.24 5,399.04 7,766.09 -1,163.74 6,038,906.43 468,773.49 1.06 7,654.32 MWD+IFR2+MS+sag(2) 10,215.44 64.07 353.96 5,495.99 5,439.79 7,849.07 -1,172.40 6,038,989.43 468,765.17 0.27 7,734.73 MWD+IFR2+MS+sag(2) 10,311.87 64.21 354.01 5,538.05 5,481.85 7,935.36 -1,181.49 6,039,075.75 468,756.43 0.15 7,818.38 MWD+IFR2+MS+sag(2) 10,342.37 64.22 354.05 5,551.32 5,495.12 7,962.68 -1,184.35 6,039,103.08 468,753.68 0.12 7,844.85 MWD+IFR2+MS+sag(2) 10,445.79 64.14 354.03 5,596.37 5,540.17 8,055.27 -1,194.02 6,039,195.70 468,744.39 0.08 7,934.57 MWD+IFR2+MS+sag(2) 10,538.73 64.13 354.41 5,636.91 5,580.71 8,138.47 -1,202.44 6,039,278.93 468,736.31 0.37 8,015.10 MWD+IFR2+MS+sag(2) 10,634.01 64.26 353.84 5,678.39 5,622.19 8,223.80 -1,211.22 6,039,364.28 468,727.87 0.56 8,097.73 MWD+IFR2+MS+sag(2) 10,729.76 64.56 353.43 5,719.74 5,663.54 8,309.62 -1,220.79 6,039,450.14 468,718.65 0.50 8,181.12 MWD+IFR2+MS+sag(2) 10,826.05 65.03 352.69 5,760.75 5,704.55 8,396.11 -1,231.32 6,039,536.65 468,708.47 0.85 8,265.47 MWD+1FR2+MS+sag(2) 10,920.84 65.38 353.91 5,800.50 5,744.30 8,481.57 -1,241.36 6,039,622.15 468,698.78 1.23 8,348.69 MWD+IFR2+MS+sag(2) 11,017.61 64.89 353.99 5,841.19 5,784.99 8,568.88 -1,250.61 6,039,709.48 468,689.88 0.51 8,433.35 MWD+IFR2+MS+sag(2) 11,112.57 65.10 352.26 5,881.34 5,825.14 8,654.32 -1,260.92 6,039,794.95 468,679.92 1.67 8,516.64 MWD+IFR2+MS+sag(2) 11,207.52 64.90 351.35 5,921.46 5,865.26 8,739.49 -1,273.18 6,039,880.17 468,668.00 0.89 8,600.41 MWD+IFR2+MS+sag(2) 11,302.45 65.05 351.28 5,961.62 5,905.42 8,824.52 -1,286.17 6,039,965.24 468,655.36 0.17 8,684.31 MWD+IFR2+MS+sag(2) 11,397.89 65.03 351.69 6,001.90 5,945.70 8,910.09 -1,298.98 6,040,050.86 468,642.90 0.39 8,768.64 MWD+IFR2+MS+sag(2) 11,492.65 64.96 351.62 6,041.95 5,985.75 8,995.06 -1,311.45 6,040,135.87 468,630.78 0.10 8,852.29 MWD+IFR2+MS+sag(2) 11,588.46 65.31 346.93 6,082.25 6,026.05 9,080.44 -1,327.62 6,040,221.30 468,614.95 4.46 8,937.67 MWD+IFR2+MS+sag(2) 11,683.69 65.92 343.81 6,121.58 6,065.38 9,164.35 -1,349.53 6,040,305.29 468,593.38 3.05 9,023.78 MWD+IFR2+MS+sag(2) 11,778.82 67.22 342.65 6,159.41 6,103.21 9,247.91 -1,374.72 6,040,388.95 468,568.54 1.77 9,110.78 MWD+IFR2+MS+sag(2) 11,873.85 69.30 342.06 6,194.60 6,138.40 9,332.03 -1,401.48 6,040,473.16 468,542.12 2.26 9,198.85 MWD+IFR2+MS+sag(2) 11,968.41 71.04 341.11 6,226.68 6,170.48 9,416.42 -1,429.58 6,040,557.66 468,514.36 2.07 9,287.68 MWD+IFR2+MS+sag(2) 12/26/2013 3:38:45PM Page 5 COMPASS 5000.1 Build 61 . S Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development ND Reference: 42.T+13.5 @ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.T+13.5 @ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°M00) (ft) Survey Tool Name 12,057.59 73.05 339.73 6,254.17 6,197.97 9,496.34 -1,458.01 6,040,637.69 468,486.26 2.69 9,372.46 MWD+IFR2+MS+sag(2) 12,155.55 73.49 336.61 6,282.38 6,226.18 9,583.41 -1,492.90 6,040,724.89 468,451.73 3.08 9,466.26 MWD+IFR2+MS+sag(2) 12,254.12 75.42 335.60 6,308.79 6,252.59 9,670.23 -1,531.36 6,040,811.86 468,413.62 2.19 9,561.13 MWD+IFR2+MS+sag(2) 12,347.92 77.33 333.11 6,330.89 6,274.69 9,752.40 -1,570.82 6,040,894.17 468,374.50 3.29 9,652.03 MWD+IFR2+MS+sag(2) 12,443.74 79.46 331.19 6,350.17 6,293.97 9,835.38 -1,614.67 6,040,977.32 468,330.99 2.97 9,745.29 MWD+IFR2+MS+sag(2) 12,538.91 80.33 330.11 6,366.87 6,310.67 9,917.04 -1,660.59 6,041,059.16 468,285.40 1.44 9,838.09 MWD+IFR2+MS+sag(2) 12,634.53 82.15 328.07 6,381.43 6,325.23 9,998.11 -1,709.14 6,041,140.42 468,237.19 2.84 9,931.30 MWD+IFR2+MS+sag(2) 12,714.27 84.51 325.58 6,390.69 6,334.49 10,064.39 -1,752.47 6,041,206.87 468,194.13 4.29 10,008.83 MWD+IFR2+MS+sag(2) 12,722.03 84.47 325.84 6,391.44 6,335.24 10,070.77 -1,756.82 6,041,213.27 468,189.80 3.37 10,016.36 MWD+IFR2+SC+sag(3) 12,818.82 85.96 322.11 6,399.51 6,343.31 10,148.76 -1,813.54 6,041,291.48 468,133.41 4.14 10,109.68 MWD+IFR2+SC+sag(3) 12,914.81 84.78 322.05 6,407.26 6,351.06 10,224.24 -1,872.34 6,041,367.18 468,074.92 1.23 10,201.42 MWD+IFR2+SC+sag(3) 12,944.74 84.28 321.89 6,410.11 6,353.91 10,247.71 -1,890.69 6,041,390.72 468,056.66 1.75 10,229.97 MWD+IFR2+SC+sag(3) 13,013.79 84.94 322.54 6,416.60 6,360.40 10,302.04 -1,932.81 6,041,445.22 468,014.77 1.34 10,295.93 MWD+IFR2+MS+sag(4) 13,060.60 88.15 323.52 6,419.42 6,363.22 10,339.36 -1,960.91 6,041,482.65 467,986.83 7.17 10,340.94 MWD+IFR2+MS+sag(4) 13,112.77 90.07 324.18 6,420.23 6,364.03 10,381.48 -1,991.68 6,041,524.89 467,956.23 3.89 10,391.39 MWD+IFR2+MS+sag(4) 13,156.91 90.38 323.67 6,420.06 6,363.86 10,417.16 -2,017.67 6,041,560.67 467,930.39 1.35 10,434.10 MWD+IFR2+MS+sag(4) 13,253.77 90.26 322.62 6,419.52 6,363.32 10,494.66 -2,075.76 6,041,638.39 467,872.61 1.09 10,527.47 MWD+IFR2+MS+sag(4) 13,349.68 91.37 323.45 6,418.15 6,361.95 10,571.28 -2,133.43 6,041,715.24 467,815.26 1.45 10,619.86 MWD+IFR2+MS+sag(4) 13,445.77 89.68 319.44 6,417.27 6,361.07 10,646.40 -2,193.30 6,041,790.60 467,755.70 4.53 10,711.67 MWD+IFR2+MS+sag(4) 13,541.94 88.96 319.85 6,418.41 6,362.21 10,719.68 -2,255.57 6,041,864.12 467,693.74 0.86 10,802.63 MWD+IFR2+MS+sag(4) 13,555.00 89.19 319.97 6,418.62 6,362.42 10,729.67 -2,263.98 6,041,874.15 467,685.37 1.99 10,815.00 MWD+IFR2+MS+sag(5) 13,604.76 87.40 319.62 6,420.11 6,363.91 10,767.66 -2,296.09 6,041,912.26 467,653.42 3.67 10,862.09 MWD+IFR2+MS+sag(5) 13,636.81 87.15 320.45 6,421.63 6,365.43 10,792.19 -2,316.65 6,041,936.87 467,632.96 2.70 10,892.45 MWD+IFR2+MS+sag(5) 13,732.18 89.18 319.25 6,424.68 6,368.48 10,865.05 -2,378.11 6,042,009.97 467,571.80 2.47 10,982.72 MWD+IFR2+MS+sag(5) 13,828.96 91.46 319.45 6,424.14 6,367.94 10,938.47 -2,441.15 6,042,083.64 467,509.07 2.36 11,074.10 MWD+IFR2+MS+sag(5) 13,925.43 92.83 319.77 6,420.53 6,364.33 11,011.89 -2,503.61 6,042,157.31 467,446.90 1.46 11,165.27 MWD+IFR2+MS+sag(5) 14,021.98 91.43 321.94 6,416.94 6,360.74 11,086.71 -2,564.52 6,042,232.37 467,386.31 2.67 11,257.17 MWD+IFR2+MS+sag(5) 14,119.29 90.01 328.18 6,415.72 6,359.52 11,166.44 -2,620.21 6,042,312.31 467,330.94 6.58 11,351.73 MWD+IFR2+MS+sag(5) 14,180.50 88.17 329.59 6,416.69 6,360.49 11,218.83 -2,651.84 6,042,364.82 467,299.53 3.79 11,412.06 MWD+IFR2+MS+sag(5) 14,213.24 87.61 329.49 6,417.90 6,361.70 11,247.03 -2,668.42 6,042,393.09 467,283.06 1.74 11,444.37 MWD+IFR2+MS+sag(5) 14,301.61 86.45 331.22 6,422.48 6,366.28 11,323.73 -2,712.07 6,042,469.95 467,239.73 2.35 11,531.71 MWD+IFR2+MS+sag(5) 14,399.02 91.14 329.63 6,424.52 6,368.32 11,408.40 -2,760.13 6,042,554.81 467,192.02 5.08 11,628.09 MWD+IFR2+MS+sag(5) 14,495.45 91.64 324.82 6,422.18 6,365.98 11,489.43 -2,812.30 6,042,636.04 467,140.19 5.01 11,722.58 MWD+IFR2+MS+sag(5) 14,592.24 94.67 324.24 6,416.86 6,360.66 11,568.13 -2,868.37 6,042,714.96 467,084.44 3.19 11,816.32 MWD+IFR2+MS+sag(5) 14,689.77 94.67 324.32 6,408.92 6,352.72 11,647.05 -2,925.12 6,042,794.10 467,028.01 0.08 11,910.52 MWD+IFR2+MS+sag(5) 14,784.86 93.25 321.93 6,402.35 6,346.15 11,722.93 -2,982.04 6,042,870.20 466,971.40 2.92 12,001.95 MWD+IFR2+MS+sag(5) 14,880.97 90.78 318.54 6,398.97 6,342.77 11,796.74 -3,043.47 6,042,944.26 466,910.28 4.36 12,093.11 MWD+IFR2+MS+sag(5) 14,977.73 89.60 318.91 6,398.65 6,342.45 11,869.46 -3,107.30 6,043,017.22 466,846.76 1.28 12,184.12 MWD+IFR2+MS+sag(5) 15,074.30 90.53 317.71 6,398.54 6,342.34 11,941.57 -3,171.52 6,043,089.59 466,782.83 1.57 12,274.71 MWD+IFR2+MS+sag(5) 15,170.57 90.96 318.18 6,397.29 6,341.09 12,013.04 -3,236.00 6,043,161.32 466,718.65 0.66 12,364.80 MWD+IFR2+MS+sag(5) 12/26/2013 3:38:45PM Page 6 COMPASS 5000.1 Build 61 s I Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N!-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,266.02 90.10 316.38 6,396.40 6,340.20 12,083.16 -3,300.75 6,043,231.69 466,654.19 2.09 12,453.73 MWD+IFR2+MS+sag(5) 15,363.56 90.90 315.95 6,395.55 6,339.35 12,153.52 -3,368.30 6,043,302.31 466,586.93 0.93 12,543.91 MWD+IFR2+MS+sag(5) 15,460.86 90.41 315.83 6,394.44 6,338.24 12,223.38 -3,436.02 6,043,372.44 466,519.50 0.52 12,633.68 MWD+IFR2+MS+sag(5) 15,555.68 89.78 316.34 6,394.28 6,338.08 12,291.68 -3,501.79 6,043,441.00 466,454.02 0.85 12,721.29 MWD+IFR2+MS+sag(5) 15,652.36 90.34 313.33 6,394.18 6,337.98 12,359.84 -3,570.34 6,043,509.43 466,385.75 3.17 12,809.78 MWD+IFR2+MS+sag(5) 15,749.13 89.48 311.27 6,394.33 6,338.13 12,424.96 -3,641.91 6,043,574.83 466,314.45 2.31 12,896.55 MWD+IFR2+MS+sag(5) 15,798.79 89.79 312.74 6,394.65 6,338.45 12,458.19 -3,678.81 6,043,608.21 466,277.69 3.03 12,940.97 MWD+IFR2+MS+sag(5) 15,843.60 89.72 317.58 6,394.84 6,338.64 12,489.96 -3,710.40 6,043,640.10 466,246.23 10.80 12,982.08 MWD+IFR2+MS+sag(5) 15,939.80 88.18 318.24 6,396.60 6,340.40 12,561.33 -3,774.87 6,043,711.73 466,182.06 1.74 13,072.07 MWD+IFR2+MS+sag(5) 16,037.01 90.22 321.15 6,397.96 6,341.76 12,635.45 -3,837.73 6,043,786.09 466,119.50 3.66 13,164.03 MWD+IFR2+MS+sag(5) 16,132.28 90.16 323.08 6,397.65 6,341.45 12,710.63 -3,896.23 6,043,861.50 466,061.31 2.03 13,255.40 MWD+IFR2+MS+sag(5) 16,228.53 91.39 324.09 6,396.34 6,340.14 12,788.08 -3,953.36 6,043,939.17 466,004.50 1.65 13,348.36 MWD+IFR2+MS+sag(5) 16,324.95 91.70 323.71 6,393.74 6,337.54 12,865.96 -4,010.15 6,044,017.27 465,948.03 0.51 13,441.61 MWD+IFR2+MS+sag(5) 16,421.38 92.20 323.77 6,390.46 6,334.26 12,943.67 -4,067.15 6,044,095.20 465,891.35 0.52 13,534.77 MWD+IFR2+MS+sag(5) 16,518.89 90.59 322.02 6,388.09 6,331.89 13,021.41 -4,125.95 6,044,173.17 465,832.87 2.44 13,628.62 MWD+IFR2+MS+sag(5) 16,612.64 90.53 322.40 6,387.17 6,330.97 13,095.49 -4,183.40 6,044,247.48 465,775.73 0.41 13,718.57 MWD+IFR2+MS+sag(5) 16,710.35 89.91 325.75 6,386.80 6,330.60 13,174.60 -4,240.72 6,044,326.82 465,718.74 3.49 13,813.16 MWD+IFR2+MS+sag(5) 16,806.28 89.36 327.08 6,387.41 6,331.21 13,254.51 -4,293.78 6,044,406.93 465,666.01 1.50 13,906.93 MWD+IFR2+MS+sag(5) 16,903.61 89.60 323.48 6,388.29 6,332.09 13,334.50 -4,349.21 6,044,487.13 465,610.91 3.71 14,001.64 MWD+IFR2+MS+sag(5) 16,998.75 90.16 325.71 6,388.49 6,332.29 13,412.04 -4,404.32 6,044,564.89 465,556.11 2.42 14,093.95 MWD+IFR2+MS+sag(5) 17,095.28 90.78 324.13 6,387.70 6,331.50 13,491.03 -4,459.80 6,044,644.10 465,500.97 1.76 14,187.75 MWD+IFR2+MS+sag(5) 17,192.02 91.21 324.49 6,386.02 6,329.82 13,569.59 -4,516.22 6,044,722.87 465,444.86 0.58 14,281.50 MWD+IFR2+MS+sag(5) 17,287.76 90.03 323.14 6,384.98 6,328.78 13,646.85 -4,572.74 6,044,800.36 465,388.66 1.87 14,374.07 MWD+IFR2+MS+sag(5) 17,383.93 88.05 320.83 6,386.59 6,330.39 13,722.60 -4,631.96 6,044,876.34 465,329.76 3.16 14,466.22 MWD+IFR2+MS+sag(5) 17,480.52 89.73 321.63 6,388.47 6,332.27 13,797.89 -4,692.43 6,044,951.87 465,269.60 1.93 14,558.40 MWD+IFR2+MS+sag(5) 17,530.83 89.85 321.55 6,388.65 6,332.45 13,837.31 -4,723.68 6,044,991.41 465,238.51 0.29 14,606.51 MWD+IFR2+MS+sag(5) 17,576.97 88.80 322.30 6,389.19 6,332.99 13,873.63 -4,752.13 6,045,027.84 465,210.21 2.80 14,650.72 MWD+IFR2+MS+sag(5) 17,627.20 90.03 323.90 6,389.71 6,333.51 13,913.79 -4,782.29 6,045,068.12 465,180.22 4.02 14,699.12 MWD+IFR2+MS+sag(5) 17,672.60 89.36 326.18 6,389.95 6,333.75 13,951.00 -4,808.30 6,045,105.43 465,154.36 5.23 14,743.26 MWD+IFR2+MS+sag(5) 17,724.08 90.22 326.38 6,390.14 6,333.94 13,993.82 -4,836.88 6,045,148.36 465,125.96 1.72 14,793.56 MWD+IFR2+MS+sag(5) 17,769.48 89.23 327.27 6,390.35 6,334.15 14,031.82 -4,861.72 6,045,186.45 465,101.27 2.93 14,838.01 MWD+IFR2+MS+sag(5) 17,865.73 89.05 326.88 6,391.80 6,335.60 14,112.60 -4,914.03 6,045,267.44 465,049.29 0.45 14,932.32 MWD+IFR2+MS+sag(5) 17,961.80 89.42 325.73 6,393.08 6,336.88 14,192.52 -4,967.32 6,045,347.57 464,996.33 1.26 15,026.18 MWD+IFR2+MS+sag(5) 18,057.46 89.42 325.09 6,394.05 6,337.85 14,271.27 -5,021.63 6,045,426.52 464,942.35 0.67 15,119.33 MWD+IFR2+MS+sag(5) 18,153.64 89.54 324.02 6,394.92 6,338.72 14,349.62 -5,077.40 6,045,505.09 464,886.90 1.12 15,212.64 MWD+IFR2+MS+sag(5) 18,248.97 90.34 322.67 6,395.02 6,338.82 14,426.09 -5,134.31 6,045,581.79 464,830.31 1.65 15,304.62 MWD+IFR2+MS+sag(5) 18,345.48 90.28 321.61 6,394.50 6,338.30 14,502.29 -5,193.54 6,045,658.22 464,771.39 1.10 15,397.19 MWD+IFR2+MS+sag(5) 18,441.43 89.73 321.42 6,394.49 6,338.29 14,577.39 -5,253.25 6,045,733.56 464,711.99 0.61 15,488.92 MWD+IFR2+MS+sag(5) 18,539.04 90.41 321.48 6,394.37 6,338.17 14,653.73 -5,314.08 6,045,810.13 464,651.48 0.70 15,582.20 MWD+IFR2+MS+sag(5) 18,634.39 90.41 321.97 6,393.69 6,337.49 14,728.58 -5,373.14 6,045,885.21 464,592.73 0.51 15,673.46 MWD+IFR2+MS+sag(5) 12/26/2013 3:38:45PM Page 7 COMPASS 5000.1 Build 61 • • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5 @ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5 @ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Noting Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 18,727.00 91.27 321.89 6,392.33 6,336.13 14,801.48 -5,430.24 6,045,958.34 464,535.93 0.93 15,762.18 MWD+IFR2+MS+sag(5) 18,827.60 90.65 321.98 6,390.65 6,334.45 14,880.67 -5,492.26 6,046,037.77 464,474.24 0.62 15,858.56 MWD+IFR2+MS+sag(5) 18,924.04 90.65 321.62 6,389.55 6,333.35 14,956.46 -5,551.89 6,046,113.79 464,414.92 0.37 15,950.89 MWD+IFR2+MS+sag(5) 19,019.72 91.02 323.51 6,388.16 6,331.96 15,032.42 -5,610.04 6,046,189.98 464,357.08 2.01 16,042.85 MWD+IFR2+MS+sag(5) 19,115.71 90.90 322.57 6,386.55 6,330.35 15,109.11 -5,667.75 6,046,266.89 464,299.69 0.99 16,135.32 MWD+IFR2+MS+sag(5) 19,211.89 90.90 319.40 6,385.04 6,328.84 15,183.82 -5,728.28 6,046,341.84 464,239.47 3.30 16,226.98 MWD+IFR2+MS+sag(5) 19,308.52 91.39 319.05 6,383.11 6,326.91 15,256.98 -5,791.38 6,046,415.25 464,176.68 0.62 16,318.14 MWD+IFR2+MS+sag(5) 19,403.12 91.40 318.83 6,380.81 6,324.61 15,328.29 -5,853.50 6,046,486.80 464,114.85 0.23 16,407.22 MWD+IFR2+MS+sag(5) 19,500.25 91.21 319.05 6,378.59 6,322.39 15,401.51 -5,917.28 6,046,560.27 464,051.37 0.30 16,498.68 MWD+IFR2+MS+sag(5) 19,596.01 92.38 319.94 6,375.59 6,319.39 15,474.28 -5,979.44 6,046,633.29 463,989.51 1.53 16,589.13 MWD+IFR2+MS+sag(5) 19,692.19 92.63 319.86 6,371.39 6,315.19 15,547.78 -6,041.34 6,046,707.03 463,927.92 0.27 16,680.17 MWD+IFR2+MS+sag(5) 19,783.79 92.94 319.38 6,366.94 6,310.74 15,617.48 -6,100.61 6,046,776.96 463,868.94 0.62 16,766.70 MWD+IFR2+MS+sag(5) 19,868.00 92.94 319.38 6,362.62 6,306.42 15,681.31 -6,155.36 6,046,841.01 463,814.45 0.00 16,846.13 PROJECTED to TD 12/26/2013 3:38:45PM Page 8 COMPASS 5000.1 Build 61 • • Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-4 PN5 ext PB1 50703626717000 Sperry .. . riiiin Services Definitive Survey Report 26 December, 2013 Sperry Drilling Services • 0 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-4 PN5 ext PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-4 PN5 ext PB1 Database: EDMAKPRD 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-4 Well Position +NI-S 0.00 usft Northing: 6,031,136.46 usft Latitude: 70°29'46.095 N +E/-W 0.00 usft Easting: 469,905.67 usft Longitude: 150° 14'45.898 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 13.50 usft Wellbore ODSN-4 PN5 ext PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-4 PN5 ext PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 42.70 0.00 0.00 338.46 Survey Program Date 11/5/2013 From To Survey (usft) (usft) Survey(Wellbore) Tool Name Description Start Date 112.00 732.00 ODSN-4 Gyro Survey(ODSN-4 PN5 ext SRG-SS Surface readout gyro single shot 03/24/2013 774.62 5,284.00 ODSN-4 MWD(ODSN-4 PN5 ext PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 03/25/2013 5,284.00 10,365.00 ODSN-4 MWD(ODSN-4 PN5 ext PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 03/25/2013 10,365.00 12,714.30 ODSN-4 MWD(ODSN-4 PN5 ext PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 03/25/2013 12,714.30 12,986.00 ODSN-4 MWD SC(no checkshots)(ODE MWD+IFR2+SC+sag Fixed:v2:IIFR dec&axial correction+sag 08/21/2013 13,013.79 14,751.21 ODSN-4 MWD#2(ODSN-4 PN5 ext PB1 MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/07/2013 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 42.70 0.00 0.00 42.70 -13.50 0.00 0.00 6,031,136.46 469,905.67 0.00 0.00 UNDEFINED 112.00 0.48 26.30 112.00 55.80 0.26 0.13 6,031,136.72 469,905.80 0.69 0.19 SRG-SS(1) 174.00 1.19 320.91 173.99 117.79 0.99 -0.16 6,031,137.45 469,905.51 1.75 0.98 SRG-SS(1) 201.00 1.94 309.55 200.98 144.78 1.50 -0.69 6,031,137.96 469,904.98 2.99 1.65 SRG-SS(1) 263.00 2.42 301.95 262.94 206.74 2.86 -2.61 6,031,139.33 469,903.07 0.90 3.62 SRG-SS(1) 356.00 4.89 284.85 355.74 299.54 4.92 -8.11 6,031,141.41 469,897.58 2.87 7.55 SRG-SS(1) 448.00 7.48 301.23 447.21 391.01 9.03 -17.02 6,031,145.56 469,888.69 3.38 14.65 SRG-SS(1) 541.00 11.08 306.95 538.98 482.78 17.54 -29.34 6,031,154.12 469,876.40 3.99 27.09 SRG-SS(1) 637.00 16.68 305.79 632.14 575.94 31.15 -47.91 6,031,167.81 469,857.89 5.84 46.57 SRG-SS(1) 732.00 20.18 307.43 722.25 666.05 49.09 -71.99 6,031,185.84 469,833.89 3.72 72.09 SRG-SS(1) 12/26/2013 3:35:09PM Page 2 COMPASS 5000.1 Build 61 • ! Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-4 PN5 ext PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-4 PN5 ext PB1 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100'} (ft) Survey Tool Name 774.62 22.52 311.69 761.94 705.74 58.99 -83.92 6,031,195.78 469,822.00 6.58 85.68 MWD+IFR2+MS+sag(2) 870.41 25.53 307.68 849.43 793.23 83.82 -113.97 6,031,220.73 469,792.06 3.57 119.81 MWD+IFR2+MS+sag(2) 965.82 25.86 306.69 935.41 879.21 108.82 -146.92 6,031,245.86 469,759.20 0.57 155.16 MWD+IFR2+MS+sag(2) 1,060.78 27.64 303.55 1,020.21 964.01 133.37 -181.89 6,031,270.55 469,724.34 2.39 190.83 MWD+IFR2+MS+sag(2) 1,158.91 31.45 307.91 1,105.57 1,049.37 161.69 -221.08 6,031,299.03 469,685.27 4.46 231.57 MWD+IFR2+MS+sag(2) 1,253.31 31.34 310.24 1,186.15 1,129.95 192.68 -259.25 6,031,330.17 469,647.23 1.29 274.41 MWD+IFR2+MS+sag(2) 1,346.25 31.25 316.29 1,265.59 1,209.39 225.73 -294.37 6,031,363.36 469,612.25 3.38 318.04 MWD+IFR2+MS+sag(2) 1,441.64 33.89 322.68 1,346.00 1,289.80 264.78 -327.60 6,031,402.54 469,579.17 4.54 366.57 MWD+IFR2+MS+sag(2) 1,539.14 34.36 327.67 1,426.72 1,370.53 309.66 -358.80 6,031,447.54 469,548.16 2.91 419.77 MWD+IFR2+MS+sag(2) 1,629.82 33.18 331.63 1,502.11 1,445.91 353.12 -384.28 6,031,491.10 469,522.86 2.75 469.55 MWD+IFR2+MS+sag(2) 1,726.75 36.11 338.96 1,581.88 1,525.68 403.15 -407.16 6,031,541.21 469,500.19 5.25 524.48 MWD+IFR2+MS+sag(2) 1,818.84 36.88 343.11 1,655.93 1,599.73 454.93 -424.93 6,031,593.06 469,482.63 2.81 579.17 MWD+IFR2+MS+sag(2) 1,917.03 41.42 348.78 1,732.08 1,675.88 515.03 -439.82 6,031,653.21 469,467.98 5.88 640.54 MWD+IFR2+MS+sag(2) 2,010.33 43.80 350.53 1,800.74 1,744.54 577.16 -451.14 6,031,715.39 469,456.91 2.85 702.49 MWD+IFR2+MS+sag(2) 2,104.90 46.99 351.69 1,867.14 1,810.94 643.68 -461.53 6,031,781.93 469,446.80 3.48 768.17 MWD+IFR2+MS+sag(2) 2,201.72 48.91 352.43 1,931.99 1,875.79 714.88 -471.45 6,031,853.17 469,437.16 2.06 838.05 MWD+IFR2+MS+sag(2) 2,297.04 50.46 352.48 1,993.66 1,937.46 786.93 -480.99 6,031,925.25 469,427.91 1.63 908.57 MWD+IFR2+MS+sag(2) 2,389.45 54.12 353.13 2,050.17 1,993.97 859.45 -490.14 6,031,997.80 469,419.06 4.00 979.38 MWD+IFR2+MS+sag(2) 2,486.35 56.99 354.61 2,104.98 2,048.78 938.89 -498.65 6,032,077.27 469,410.87 3.22 1,056.40 MWD+IFR2+MS+sag(2) 2,579.35 60.23 355.02 2,153.41 2,097.21 1,017.94 -505.82 6,032,156.34 469,404.02 3.50 1,132.57 MWD+IFR2+MS+sag(2) 2,675.53 59.59 354.48 2,201.63 2,145.43 1,100.81 -513.43 6,032,239.23 469,396.75 0.82 1,212.44 MWD+IFR2+MS+sag(2) 2,770.12 64.22 353.33 2,246.16 2,189.96 1,183.76 -522.31 6,032,322.21 469,388.21 5.01 1,292.85 MWD+IFR2+MS+sag(2) 2,861.85 66.78 356.02 2,284.21 2,228.01 1,266.85 -530.03 6,032,405.32 469,380.82 3.86 1,372.98 MWD+IFR2+MS+sag(2) 2,957.20 66.70 354.94 2,321.86 2,265.66 1,354.18 -536.94 6,032,492.67 469,374.27 1.04 1,456.74 MWD+IFR2+MS+sag(2) 3,053.86 64.00 352.89 2,362.18 2,305.98 1,441.52 -546.23 6,032,580.04 469,365.33 3.39 1,541.40 MWD+IFR2+MS+sag(2) 3,147.12 63.78 351.99 2,403.22 2,347.02 1,524.54 -557.25 6,032,663.09 469,354.65 0.90 1,622.66 MWD+IFR2+MS+sag(2) 3,241.30 63.71 353.29 2,444.88 2,388.68 1,608.30 -568.07 6,032,746.89 469,344.17 1.24 1,704.55 MWD+IFR2+MS+sag(2) 3,337.04 63.45 353.54 2,487.48 2,431.28 1,693.48 -577.90 6,032,832.10 469,334.69 0.36 1,787.39 MWD+IFR2+MS+sag(2) 3,431.96 64.04 354.11 2,529.47 2,473.27 1,778.11 -587.06 6,032,916.76 469,325.87 0.82 1,869.47 MWD+IFR2+MS+sag(2) 3,526.22 64.68 354.57 2,570.26 2,514.06 1,862.67 -595.44 6,033,001.35 469,317.84 0.81 1,951.20 MWD+IFR2+MS+sag(2) 3,620.86 65.21 353.55 2,610.34 2,554.14 1,947.95 -604.31 6,033,086.64 469,309.31 1.13 2,033.78 MWD+IFR2+MS+sag(2) 3,716.97 64.70 353.40 2,651.03 2,594.83 2,034.46 -614.21 6,033,173.18 469,299.77 0.55 2,117.88 MWD+IFR2+MS+sag(2) 3,812.31 63.59 351.70 2,692.61 2,636.41 2,119.52 -625.32 6,033,258.29 469,288.99 1.98 2,201.09 MWD+IFR2+MS+sag(2) 3,907.31 64.94 352.84 2,733.86 2,677.66 2,204.32 -636.83 6,033,343.12 469,277.83 1.79 2,284.19 MWD+IFR2+MS+sag(2) 4,002.73 66.49 353.60 2,773.10 2,716.90 2,290.68 -647.09 6,033,429.52 469,267.92 1.78 2,368.29 MWD+IFR2+MS+sag(2) 4,097.78 65.80 352.86 2,811.54 2,755.34 2,377.01 -657.34 6,033,515.87 469,258.02 1.02 2,452.34 MWD+IFR2+MS+sag(2) 4,192.46 64.58 353.57 2,851.27 2,795.07 2,462.34 -667.49 6,033,601.24 469,248.22 1.46 2,535.45 MWD+IFR2+MS+sag(2) 4,286.51 64.15 353.45 2,891.96 2,835.76 2,546.59 -677.08 6,033,685.52 469,238.97 0.47 2,617.33 MWD+IFR2+MS+sag(2) 4,382.61 61.86 353.42 2,935.58 2,879.38 2,631.66 -686.87 6,033,770.61 469,229.53 2.38 2,700.05 MWD+IFR2+MS+sag(2) 4,478.55 62.40 353.32 2,980.42 2,924.22 2,715.90 -696.66 6,033,854.89 469,220.08 0.57 2,782.00 MWD+IFR2+MS+sag(2) 12/26/2013 3:35:09PM Page 3 COMPASS 5000.1 Build 61 • • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-4 PN5 ext PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-4 PN5 ext PB1 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) () (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,572.77 62.63 355.68 3,023.91 2,967.71 2,799.09 -704.67 6,033,938.11 469,212.41 2.24 2,862.33 MWD+IFR2+MS+sag(2) 4,668.11 63.59 356.26 3,067.03 3,010.83 2,883.91 -710.64 6,034,022.94 469,206.78 1.14 2,943.42 MWD+IFR2+MS+sag(2) 4,763.20 63.42 354.83 3,109.46 3,053.26 2,968.76 -717.25 6,034,107.80 469,200.51 1.36 3,024.76 MWD+IFR2+MS+sag(2) 4,857.09 63.74 353.78 3,151.23 3,095.03 3,052.42 -725.60 6,034,191.49 469,192.51 1.06 3,105.65 MWD+IFR2+MS+sag(2) 4,952.65 64.20 353.35 3,193.17 3,136.97 3,137.75 -735.22 6,034,276.85 469,183.23 0.63 3,188.55 MWD+IFR2+MS+sag(2) 5,048.13 64.16 352.56 3,234.76 3,178.56 3,223.05 -745.76 6,034,362.18 469,173.04 0.75 3,271.76 MWD+IFR2+MS+sag(2) 5,143.34 63.18 351.98 3,276.98 3,220.78 3,307.60 -757.24 6,034,446.77 469,161.90 1.17 3,354.62 MWD+IFR2+MS+sag(2) 5,238.40 64.12 352.00 3,319.18 3,262.98 3,391.95 -769.11 6,034,531.16 469,150.38 0.99 3,437.44 MWD+IFR2+MS+sag(2) 5,320.00 64.14 353.52 3,354.78 3,298.58 3,464.79 -778.36 6,034,604.03 469,141.42 1.68 3,508.59 MWD+IFR2+MS+sag(3) 5,371.78 63.74 353.06 3,377.53 3,321.33 3,510.98 -783.79 6,034,650.24 469,136.17 1.11 3,553.55 MWD+IFR2+MS+sag(3) 5,467.39 64.21 354.99 3,419.48 3,363.28 3,596.43 -792.73 6,034,735.71 469,127.58 1.88 3,636.31 MWD+IFR2+MS+sag(3) 5,562.63 64.48 354.64 3,460.72 3,404.52 3,681.93 -800.49 6,034,821.23 469,120.17 0.44 3,718.69 MWD+IFR2+MS+sag(3) 5,657.38 64.74 354.41 3,501.35 3,445.15 3,767.13 -808.66 6,034,906.46 469,112.35 0.35 3,800.94 MWD+IFR2+MS+sag(3) 5,752.70 64.40 354.49 3,542.28 3,486.08 3,852.81 -816.99 6,034,992.17 469,104.37 0.36 3,883.70 MWD+IFR2+MS+sag(3) 5,847.78 64.21 354.38 3,583.50 3,527.30 3,938.09 -825.29 6,035,077.47 469,096.41 0.23 3,966.07 MWD+IFR2+MS+sag(3) 5,942.61 64.08 355.16 3,624.86 3,568.66 4,023.07 -833.07 6,035,162.47 469,088.97 0.75 4,047.97 MWD+IFR2+MS+sag(3) 6,036.56 63.79 354.83 3,666.14 3,609.94 4,107.14 -840.44 6,035,246.56 469,081.95 0.44 4,128.87 MWD+IFR2+MS+sag(3) 6,132.10 63.67 354.78 3,708.42 3,652.22 4,192.46 -848.19 6,035,331.91 469,074.54 0.13 4,211.08 MWD+IFR2+MS+sag(3) 6,224.71 63.87 355.21 3,749.35 3,693.15 4,275.22 -855.44 6,035,414.68 469,067.63 0.47 4,290.72 MWD+IFR2+MS+sag(3) 6,322.72 64.41 354.73 3,792.10 3,735.90 4,363.07 -863.17 6,035,502.56 469,060.25 0.71 4,375.28 MWD+IFR2+MS+sag(3) 6,417.83 64.55 355.10 3,833.08 3,776.88 4,448.57 -870.78 6,035,588.08 469,052.99 0.38 4,457.59 MWD+IFR2+MS+sag(3) 6,512.73 64.47 355.28 3,873.92 3,817.72 4,533.93 -877.96 6,035,673.46 469,046.15 0.19 4,539.63 MWD+IFR2+MS+sag(3) 6,607.37 63.79 354.03 3,915.22 3,859.02 4,618.71 -885.89 6,035,758.26 469,038.57 1.39 4,621.40 MWD+IFR2+MS+sag(3) 6,702.87 63.65 355.08 3,957.50 3,901.30 4,703.95 -894.02 6,035,843.53 469,030.79 1.00 4,703.68 MWD+IFR2+MS+sag(3) 6,798.37 63.09 354.25 4,000.31 3,944.11 4,788.95 -901.96 6,035,928.55 469,023.20 0.97 4,785.65 MWD+IFR2+MS+sag(3) 6,891.40 63.14 354.45 4,042.38 3,986.18 4,871.52 -910.13 6,036,011.14 469,015.36 0.20 4,865.46 MWD+IFR2+MS+sag(3) 6,987.87 63.30 355.19 4,085.84 4,029.64 4,957.29 -917.90 6,036,096.94 469,007.94 0.70 4,948.09 MWD+IFR2+MS+sag(3) 7,083.12 63.54 355.18 4,128.46 4,072.26 5,042.18 -925.05 6,036,181.84 469,001.13 0.25 5,029.67 MWD+IFR2+MS+sag(3) 7,177.84 64.08 355.96 4,170.27 4,114.07 5,126.92 -931.61 6,036,266.60 468,994.91 0.93 5,110.90 MWD+IFR2+MS+sag(3) 7,270.68 64.35 356.37 4,210.65 4,154.45 5,210.32 -937.20 6,036,350.02 468,989.66 0.49 5,190.54 MWD+IFR2+MS+sag(3) 7,366.93 64.21 356.49 4,252.42 4,196.22 5,296.87 -942.60 6,036,436.58 468,984.61 0.18 5,273.02 MWD+IFR2+MS+sag(3) 7,461.72 64.42 356.15 4,293.51 4,237.31 5,382.12 -948.09 6,036,521.84 468,979.47 0.39 5,354.33 MWD+IFR2+MS+sag(3) 7,556.46 64.01 354.30 4,334.72 4,278.52 5,467.12 -955.19 6,036,606.86 468,972.72 1.81 5,436.00 MWD+IFR2+MS+sag(3) 7,651.42 63.80 356.32 4,376.49 4,320.29 5,552.11 -962.16 6,036,691.87 468,966.09 1.92 5,517.62 MWD+IFR2+MS+sag(3) 7,747.28 64.07 355.71 4,418.61 4,362.41 5,638.01 -968.14 6,036,777.79 468,960.45 0.64 5,599.72 MWD+IFR2+MS+sag(3) 7,840.95 64.37 355.62 4,459.35 4,403.15 5,722.12 -974.52 6,036,861.91 468,954.42 0.33 5,680.29 MWD+IFR2+MS+sag(3) 7,934.71 64.27 354.35 4,499.98 4,443.78 5,806.29 -981.91 6,036,946.11 468,947.37 1.23 5,761.30 MWD+IFR2+MS+sag(3) 8,028.65 64.00 353.91 4,540.96 4,484.76 5,890.38 -990.55 6,037,030.22 468,939.07 0.51 5,842.68 MWD+IFR2+MS+sag(3) 8,124.90 64.34 353.97 4,582.90 4,526.70 5,976.53 -999.70 6,037,116.39 468,930.27 0.36 5,926.18 MWD+IFR2+MS+sag(3) 8,221.76 64.22 354.44 4,624.94 4,568.74 6,063.35 -1,008.51 6,037,203.24 468,921.82 0.45 6,010.16 MWD+IFR2+MS+sag(3) 12/26/2013 3:35:09PM Page 4 COMPASS 5000.1 Build 61 • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development ND Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-4 PN5 ext PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-4 PN5 ext PB1 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi ND NDSS +NI-S +E/-W Northing Easting DLS Section (usft) () () (usft) (usft) (usft) (usft) (ft) (ft) (°Hoo') (ft) Survey Tool Name 8,316.01 64.42 354.12 4,665.78 4,609.58 6,147.86 -1,016.97 6,037,287.78 468,913.69 0.37 6,091.89 MWD+IFR2+MS+sag(3) 8,408.97 64.22 354.57 4,706.06 4,649.86 6,231.23 -1,025.23 6,037,371.18 468,905.78 0.49 6,172.47 MWD+IFR2+MS+sag(3) 8,504.62 64.20 353.81 4,747.68 4,691.48 6,316.91 -1,033.95 6,037,456.88 468,897.41 0.72 6,255.36 MWD+IFR2+MS+sag(3) 8,601.35 63.93 354.45 4,789.98 4,733.78 6,403.44 -1,042.84 6,037,543.44 468,888.86 0.66 6,339.12 MWD+IFR2+MS+sag(3) 8,696.80 63.68 354.20 4,832.12 4,775.92 6,488.67 -1,051.31 6,037,628.69 468,880.74 0.35 6,421.50 MWD+IFR2+MS+sag(3) 8,791.47 64.07 354.30 4,873.80 4,817.60 6,573.24 -1,059.83 6,037,713.29 468,872.56 0.42 6,503.29 MWD+IFR2+MS+sag(3) 8,885.77 64.00 354.12 4,915.09 4,858.89 6,657.59 -1,068.38 6,037,797.66 468,864.35 0.19 6,584.89 MWD+IFR2+MS+sag(3) 8,980.14 63.85 354.26 4,956.57 4,900.37 6,741.92 -1,076.96 6,037,882.02 468,856.12 0.21 6,666.48 MWD+IFR2+MS+sag(3) 9,075.61 64.07 354.80 4,998.48 4,942.28 6,827.31 -1,085.14 6,037,967.43 468,848.29 0.56 6,748.91 MWD+IFR2+MS+sag(3) 9,169.87 63.87 354.70 5,039.85 4,983.65 6,911.65 -1,092.89 6,038,051.79 468,840.88 0.23 6,830.21 MWD+IFR2+MS+sag(3) 9,265.51 63.85 355.19 5,081.98 5,025.78 6,997.17 -1,100.45 6,038,137.34 468,833.66 0.46 6,912.53 MWD+IFR2+MS+sag(3) 9,360.79 64.09 355.19 5,123.80 5,067.60 7,082.49 -1,107.63 6,038,222.67 468,826.83 0.25 6,994.53 MWD+IFR2+MS+sag(3) 9,455.74 64.36 355.55 5,165.08 5,108.88 7,167.71 -1,114.53 6,038,307.92 468,820.27 0.44 7,076.33 MWD+IFR2+MS+sag(3) 9,549.72 64.22 355.79 5,205.85 5,149.65 7,252.15 -1,120.93 6,038,392.37 468,814.22 0.27 7,157.22 MWD+IFR2+MS+sag(3) 9,647.28 63.95 355.49 5,248.49 5,192.29 7,339.64 -1,127.60 6,038,479.88 468,807.90 0.39 7,241.05 MWD+IFR2+MS+sag(3) 9,742.22 64.02 355.76 5,290.13 5,233.93 7,424.71 -1,134.11 6,038,564.97 468,801.74 0.27 7,322.57 MWD+IFR2+MS+sag(3) 9,837.04 64.41 355.17 5,331.38 5,275.18 7,509.82 -1,140.86 6,038,650.10 468,795.33 0.70 7,404.22 MWD+IFR2+MS+sag(3) 9,930.55 64.61 354.84 5,371.62 5,315.42 7,593.91 -1,148.21 6,038,734.21 468,788.33 0.38 7,485.13 MWD+IFR2+MS+sag(3) 10,026.77 64.14 355.21 5,413.23 5,357.03 7,680.34 -1,155.73 6,038,820.66 468,781.15 0.60 7,568.28 MWD+IFR2+MS+sag(3) 10,122.59 63.86 354.12 5,455.24 5,399.04 7,766.09 -1,163.74 6,038,906.43 468,773.49 1.06 7,650.98 MWD+IFR2+MS+sag(3) 10,215.44 64.07 353.96 5,495.99 5,439.79 7,849.07 -1,172.40 6,038,989.43 468,765.17 0.27 7,731.35 MWD+IFR2+MS+sag(3) 10,311.87 64.21 354.01 5,538.05 5,481.85 7,935.36 -1,181.49 6,039,075.75 468,756.43 0.15 7,814.95 MWD+IFR2+MS+sag(3) 10,342.37 64.22 354.05 5,551.32 5,495.12 7,962.68 -1,184.35 6,039,103.08 468,753.68 0.12 7,841.41 MWD+IFR2+MS+sag(3) 10,445.79 64.14 354.03 5,596.37 5,540.17 8,055.27 -1,194.02 6,039,195.70 468,744.39 0.08 7,931.08 MWD+IFR2+MS+sag(4) 10,538.73 64.13 354.41 5,636.91 5,580.71 8,138.47 -1,202.44 6,039,278.93 468,736.31 0.37 8,011.57 MWD+IFR2+MS+sag(4) 10,634.01 64.26 353.84 5,678.39 5,622.19 8,223.80 -1,211.22 6,039,364.28 468,727.87 0.56 8,094.16 MWD+IFR2+MS+sag(4) 10,729.76 64.56 353.43 5,719.74 5,663.54 8,309.62 -1,220.79 6,039,450.14 468,718.65 0.50 8,177.51 MWD+IFR2+MS+sag(4) 10,826.05 65.03 352.69 5,760.75 5,704.55 8,396.11 -1,231.32 6,039,536.65 468,708.47 0.85 8,261.82 MWD+IFR2+MS+sag(4) 10,920.84 65.38 353.91 5,800.50 5,744.30 8,481.57 -1,241.36 6,039,622.15 468,698.78 1.23 8,345.00 MWD+IFR2+MS+sag(4) 11,017.61 64.89 353.99 5,841.19 5,784.99 8,568.88 -1,250.61 6,039,709.48 468,689.88 0.51 8,429.61 MWD+IFR2+MS+sag(4) 11,112.57 65.10 352.26 5,881.34 5,825.14 8,654.32 -1,260.92 6,039,794.95 468,679.92 1.67 8,512.86 MWD+IFR2+MS+sag(4) 11,207.52 64.90 351.35 5,921.46 5,865.26 8,739.49 -1,273.18 6,039,880.17 468,668.00 0.89 8,596.59 MWD+IFR2+MS+sag(4) 11,302.45 65.05 351.28 5,961.62 5,905.42 8,824.52 -1,286.17 6,039,965.24 468,655.36 0.17 8,680.45 MWD+IFR2+MS+sag(4) 11,397.89 65.03 351.69 6,001.90 5,945.70 8,910.09 -1,298.98 6,040,050.86 468,642.90 0.39 8,764.75 MWD+IFR2+MS+sag(4) 11,492.65 64.96 351.62 6,041.95 5,985.75 8,995.06 -1,311.45 6,040,135.87 468,630.78 0.10 8,848.36 MWD+IFR2+MS+sag(4) 11,588.46 65.31 346.93 6,082.25 6,026.05 9,080.44 -1,327.62 6,040,221.30 468,614.95 4.46 8,933.71 MWD+IFR2+MS+sag(4) 11,683.69 65.92 343.81 6,121.58 6,065.38 9,164.35 -1,349.53 6,040,305.29 468,593.38 3.05 9,019.80 MWD+IFR2+MS+sag(4) 11,778.82 67.22 342.65 6,159.41 6,103.21 9,247.91 -1,374.72 6,040,388.95 468,568.54 1.77 9,106.78 MWD+IFR2+MS+sag(4) 11,873.85 69.30 342.06 6,194.60 6,138.40 9,332.03 -1,401.48 6,040,473.16 468,542.12 2.26 9,194.85 MWD+IFR2+MS+sag(4) 11,968.41 71.04 341.11 6,226.68 6,170.48 9,416.42 -1,429.58 6,040,557.66 468,514.36 2.07 9,283.66 MWD+IFR2+MS+sag(4) 12/26/2013 3:35:09PM Page 5 COMPASS 5000.1 Build 61 I • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5 @ 56.20usft(Nabors 19AC) Site: Oooguruk Drill Site MD Reference: 42.7'+13.5 @ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-4 PN5 ext PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-4 PN5 ext PB1 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +Et-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1007 (ft) Survey Tool Name 12,057.59 73.05 339.73 6,254.17 6,197.97 9,496.34 -1,458.01 6,040,637.69 468,486.26 2.69 9,368.44 MWD+IFR2+MS+sag(4) 12,155.55 73.49 336.61 6,282.38 6,226.18 9,583.41 -1,492.90 6,040,724.89 468,451.73 3.08 9,462.24 MWD+IFR2+MS+sag(4) 12,254.12 75.42 335.60 6,308.79 6,252.59 9,670.23 -1,531.36 6,040,811.86 468,413.62 2.19 9,557.12 MWD+IFR2+MS+sag(4) 12,347.92 77.33 333.11 6,330.89 6,274.69 9,752.40 -1,570.82 6,040,894.17 468,374.50 3.29 9,648.03 MWD+IFR2+MS+sag(4) 12,443.74 79.46 331.19 6,350.17 6,293.97 9,835.38 -1,614.67 6,040,977.32 468,330.99 2.97 9,741.31 MWD+IFR2+MS+sag(4) 12,538.91 80.33 330.11 6,366.87 6,310.67 9,917.04 -1,660.59 6,041,059.16 468,285.40 1.44 9,834.14 MWD+IFR2+MS+sag(4) 12,634.53 82.15 328.07 6,381.43 6,325.23 9,998.11 -1,709.14 6,041,140.42 468,237.19 2.84 9,927.37 MWD+IFR2+MS+sag(4) 12,714.27 84.51 325.58 6,390.69 6,334.49 10,064.39 -1,752.47 6,041,206.87 468,194.13 4.29 10,004.93 MWD+IFR2+MS+sag(4) 12,722.03 84.47 325.84 6,391.44 6,335.24 10,070.77 -1,756.82 6,041,213.27 468,189.80 3.37 10,012.46 MWD+IFR2+SC+sag(5) 12,818.82 85.96 322.11 6,399.51 6,343.31 10,148.76 -1,813.54 6,041,291.48 468,133.41 4.14 10,105.83 MWD+IFR2+SC+sag(5) 12,914.81 84.78 322.05 6,407,26 6,351.06 10,224.24 -1,872.34 6,041,367.18 468,074.92 1.23 10,197.62 MWD+IFR2+SC+sag(5) 12,944.74 84.28 321.89 6,410.11 6,353.91 10,247.71 -1,890.69 6,041,390.72 468,056.66 1.75 10,226.19 MWD+IFR2+SC+sag(5) 13,013.79 84.94 322.54 6,416.60 6,360.40 10,302.04 -1,932.81 6,041,445.22 468,014.77 1.34 10,292.19 MWD+IFR2+MS+sag(6) 13,060.60 88.15 323.52 6,419.42 6,363.22 10,339.36 -1,960.91 6,041,482.65 467,986.83 7.17 10,337.22 MWD+IFR2+MS+sag(6) 13,112.77 90.07 324.18 6,420.23 6,364.03 10,381.48 -1,991.68 6,041,524.89 467,956.23 3.89 10,387.70 MWD+IFR2+MS+sag(6) 13,156.91 90.38 323.67 6,420.06 6,363.86 10,417.16 -2,017.67 6,041,560.67 467,930.39 1.35 10,430.43 MWD+IFR2+MS+sag(6) 13,253.77 90.26 322.62 6,419.52 6,363.32 10,494.66 -2,075.76 6,041,638.39 467,872.61 1.09 10,523.84 MWD+IFR2+MS+sag(6) 13,349.68 91.37 323.45 6,418.15 6,361.95 10,571.28 -2,133.43 6,041,715.24 467,815.26 1.45 10,616.29 MWD+IFR2+MS+sag(6) 13,445.77 89.68 319.44 6,417.27 6,361.07 10,646.40 -2,193.30 6,041,790.60 467,755.70 4.53 10,708.14 MWD+IFR2+MS+sag(6) 13,541.94 88.96 319.85 6,418.41 6,362.21 10,719.68 -2,255.57 6,041,864.12 467,693.74 0.86 10,799.17 MWD+IFR2+MS+sag(6) 13,635.88 90.62 320.51 6,418.76 6,362.56 10,791.83 -2,315.72 6,041,936.51 467,633.88 1.90 10,888.36 MWD+IFR2+MS+sag(6) 13,732.24 91.00 322.12 6,417.40 6,361.20 10,867.04 -2,375.95 6,042,011.95 467,573.97 1.72 10,980.43 MWD+IFR2+MS+sag(6) 13,828.85 91.31 320.06 6,415.45 6,359.25 10,942.19 -2,436.61 6,042,087.34 467,513.62 2.16 11,072.61 MWD+IFR2+MS+sag(6) 13,925.26 90.06 318.87 6,414.30 6,358.10 11,015.46 -2,499.26 6,042,160.85 467,451.27 1.79 11,163.76 MWD+IFR2+MS+sag(6) 14,023.18 88.26 317.63 6,415.73 6,359.53 11,088.50 -2,564.45 6,042,234.15 467,386.38 2.23 11,255.64 MWD+IFR2+MS+sag(6) 14,070.26 86.32 318.82 6,417.96 6,361.76 11,123.57 -2,595.78 6,042,269.34 467,355.20 4.83 11,299.76 MWD+IFR2+MS+sag(6) 14,118.30 87.29 319.64 6,420.63 6,364.43 11,159.89 -2,627.10 6,042,305.79 467,324.03 2.64 11,345.05 MWD+IFR2+MS+sag(6) 14,212.80 91.79 323.74 6,421.39 6,365.19 11,234.01 -2,685.66 6,042,380.14 467,265.78 6.44 11,435.48 MWD+IFR2+MS+sag(6) 14,264.39 90.67 322.64 6,420.29 6,364.09 11,275.30 -2,716.56 6,042,421.55 467,235.05 3.04 11,485.24 MWD+IFR2+MS+sag(6) 14,308.96 90.81 321.78 6,419.71 6,363.51 11,310.52 -2,743.87 6,042,456.88 467,207.88 1.95 11,528.02 MWD+IFR2+MS+sag(6) 14,405.58 91.55 322.42 6,417.72 6,361.52 11,386.74 -2,803.21 6,042,533.33 467,148.86 1.01 11,620.71 MWD+IFR2+MS+sag(6) 14,501.94 91.12 321.82 6,415.48 6,359.28 11,462.78 -2,862.35 6,042,609.60 467,090.03 0.77 11,713.15 MWD+IFR2+MS+sag(6) 14,599.02 91.12 320.07 6,413.58 6,357.38 11,538.15 -2,923.51 6,042,685.21 467,029.18 1.80 11,805.71 MWD+IFR2+MS+sag(6) 14,695.67 92.42 320.40 6,410.59 6,354.39 11,612.40 -2,985.30 6,042,759.71 466,967.70 1.39 11,897.47 MWD+IFR2+MS+sag(6) 14,751.21 93.04 321.27 6,407.95 6,351.75 11,655.42 -3,020.33 6,042,802.85 466,932.84 1.92 11,950.34 MWD+IFR2+MS+sag(6) 14,810.00 93.04 321.27 6,404.83 6,348.63 11,701.21 -3,057.06 6,042,848.80 466,896.30 0.00 12,006.42 PROJECTED to TD 12/26/2013 3:35:09PM Page 6 COMPASS 5000.1 Build 61 21 3037 • • 28 164 ® CAELL S LETTER OF TRANSMITTAL Energy Alaska DATALOGGED RECEIVED 20,7 N1. K. BENDER MAY 052017 AOGCC DATE: May 3, 2017 FROM: TO: Shannon Koh AOGCC Caelus Energy Alaska Attn: Makana Bender 3700 Centerpoint Dr., Suite 500 333 W. 7th Avenue, Suite 100 Anchorage, AK 99503 Anchorage, AK 99501 INFORMATION TRANSMITTED ❑ Letter ❑ Maps CD-R M Other— Log ❑ Agreement DETAIL QTY DESCRIPTION ODSN-04 (50-703-20670-0000) 1 CD Memory Press-Temp Survey log 1 Log Memory Press-Temp—digital data contains DLIS, LAS, PDF SCANNED JUN 1 92017 Received by:p 4Ll ,5 ca Date: Please sign and return one copy to: Caelus Energy Alaska ATTN: Shannon Koh 3700 Centerpoint Dr., Suite 500, Anchorage, AK 99503 907-343-2193 fax 907-343-2128 phone shannon.koh(a�caelusenergy.com STATE OF ALASKA AIL OIL AND GAS CONSERVATION COM ION 1 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Scale Squeeze[] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: / r Name: Caelus Natural Resources Alaska,LLC Development i I Exploratory ❑ 213-037 w 3.Address: 3700 Centerpoint Drive,Suite 500 Stratigraphic ❑ Service Q 6.API Number: Anchorage,AK 99503 50-703-20670-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 389959/ADL 389958 ODSN-04 RECEIVED ECE1VED 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Oooguruk- Nuiqsut Oil Pool MAY 0.1 11.Present Well Condition Summary: ZU17 Total Depth measured 19,868 feet Plugs measured N/A feAOGCC true vertical 6,364 feet Junk measured N/A feet Effective Depth measured 19,858 feet Packer measured See attachment, feet Da.3 true vertical 6,363 feet true vertical See attachment, feet aa.3 Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5,241' 11-3/4" 5,284' 3,339' 5,830 psi 3,180 psi Intermediate 5,258' 9-5/8" 5,105'-10,365' 3,260'-5,561' 5,750 psi 3,090 psi Production 12,923' 7" 12,965' 6,412' 7,240 psi 5,410 psi Liner 7,092' 4-1/2" 12,766'-19,858' 6,395'-6,363' 11,590 psi 9,200 psi Perforation depth Measured depth See attachment,pg.2 feet True Vertical depth See attachment,pg.2 feet SCANNED MAY 2 2 a 1r Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6",C-110,Hyd 521 12,782'MD 6,397'TVD Packers and SSSV(type,measured and true vertical depth) See attachment,pg.3 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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: 1,246 861 438 1,302 419 Subsequent to operation: 1,254 628 441 1,426 438 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations [] Exploratory Q Develo ment p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil [] Gas ❑ WDSPLD Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ Q 3USP❑ 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: 317-102 - Authorized Name: Rami Jasser Contact Name: Rami Jasser Authorized Title: Senior Staff Ct rrtpletion Engineer Contact Email: rami.IasserCa� omcaelusenergy.0 Authorized Signature: ' (4 4 Date: 12.&O\1.7- Contact Phone: 907-343-2182 Form IU-4U4 Revisea 120i i7/‘ >---/(- RBDMb �s.4 AY - 3 2017 9 y ,e.iK, 1 auom¢On mai only • • Attachment 2 AOGCC Form 10-404 ,gaLt0M01.00.1V0802MOVe. AMMO Report of Sundry Box 11 - Perforation Locations Well: ODSN-04 Top (MD) Top (TVD) 4-1/2" SLHT Ball Actuated Sleeve w/Seat#11 13,270 6,419 4-1/2" SLHT Ball Actuated Sleeve w/Seat#10 13,967 6,419 4-1/2" SLHT Ball Actuated Sleeve w/Seat#09 14,613 6,415 4-1/2" SLHT Ball Actuated Sleeve w/Seat#08 15,185 6,397 4-1/2" SLHT Ball Actuated Sleeve w/Seat#07 15,833 6,395 4-1/2" SLHT Ball Actuated Sleeve w/Seat#06 16,544 6,388 4-1/2" SLHT Ball Actuated Sleeve w/Seat#05 17,156 6,387 4-1/2" SLHT Ball Actuated Sleeve w/Seat#04 17,727 6,390 4-1/2" SLHT Ball Actuated Sleeve w/Seat#03 18,255 6,395 4-1/2" SLHT Ball Actuated Sleeve w/Seat#02 18,955 6,389 4-1/2" SLHT Ball Actuated Sleeve w/Seat#01 19,512 6,378 Pre-Perforated Pup 19,811 6,366 • • Attachment 3 AOGCC Form 10-404 Report of Sundry Box 11 - Packers & SSSV Well: ODSN-04 SSSV MD TVD 4-1/2" Halliburton 'XXO' SVLN 2,304' 1,998' PACKERS 5" x 7" Baker ZXP Liner Top Packer 12,766' 6,395' HES Swell Packer#13 13,095' 6,420' HES Swell Packer#12 13,456' 6,417' HES Swell Packer#11 13,621' 6,421' HES Swell Packer#10 14,271' 6,421' HES Swell Packer#9 14,920' 6,399' HES Swell Packer#8 15,452' 6,395' HES Swell Packer#7 16,179' 6,397' HES Swell Packer#6 16,850' 6,388' HES Swell Packer#5 17,463' 6,388' HES Swell Packer#4 17,993' 6,393' HES Swell Packer#3 18,561' 6,394' HES Swell Packer#2 19,262' 6,384' HES Swell Packer#1 19,779' 6,367' • • LU S Operations Summary Report - State Well Name: ODSN-04 CG AE ;., Alaska Well Name: ODSN-04 Contractor: Rig Number: Job Category: WELL SERVICE Start Date: 3/23/2017 End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 3/23/2017 3/24/2017 0.0 00:00 3/23/17-00:00 3/24/17 (coil prep) *Complete well handover from Ops to Wells Group. *Ops shut in well.LRS freeze protected tubing w/48 bbls of diesel. *MIRU HES Slickline w/.125 wire. *Drifted w/3.84"gauge ring to SVLN @ 2,282'slm. *Pulled 4.5"FXE SSSV from SVLN @ 2,282'slm. *Drifted w/3.80"gauge ring to XN nipple @ 11,795'slm. *Set 4.5"Frac Isolation Sleeve(3.12"ID)in SVLN @ 2,282'slm. Establish control line integrity to 4500 psi. *RDMO HES Slickline. *Vetco installed second 10k gate valve on wellhead. Iv *SLB coiled tubing support equipment arrived @ ODS via Lynden transport. *Unload power stand,BOPs,2"1502 hardline rack,risers,and tool box. 3/24/2017 3/25/2017 0.0 00:00 3/24/17-00:00 3/25/17 *MIRU SLB Coiled tubing to execute the Scale Squeeze job scope. *Make up all hydraulic lines incorporated in the Coiled Tubing Injector head. *Rig up the flow cross Ton the wing of ODSN-04 to enable SLB coiled tubing to bleed off fluid to the flowback tanks.- *At 13:00 the wind speed increased to 35-46 mph making the 275 ton crane inoperable. *Continue rigging up all ground lines until the crane is operable to set the coiled tubing spool into the reel cradle. *Rig up 3"206 hoses from RSC down to coil pump. *At 22:00 the wind speed is still 40-45 mph.Continue monitoring winds. 3/25/2017 3/26/2017 0.0 00:00 3/25/17-00:00 3/26/17 *Stand by for winds to subside under the crane operating maximum wind speed. *Winds layed down at 06:45 to begin crane operations and continue on with the rig up. *Install the 1.75"coil spool in the spooling cradle. *Make up BOPs&P-sub to the wellhead.Rig up 2"1502 hardline from P-sub to ground lines. *Stab pipe through the injector head. *Rig up high pressure hose from flowline to SLB 2"1502 hardline for returns. *Pick up injector head&risers.Install 2-1/8"Cold Roll Connector. 3/26/2017 3/27/2017 0.0 00:00 3/26/17-00:00 3/27/17 *Continue SLB Coiled Tubing rig up operations. *Complete the weekly BOP test as per SLB policy and procedure.(Next BOP Test Due 4/2/17) *Make up Slick BHA=1.75"CTC,1.69"DBPV,1.69"Disconnect(5/8"ball), 1.69 Dual Circ Sub, 1.69"XO to 3/"SR,and 1.69"SLB PBMS Gamma/CCL. *RIH to 4,500'CTM and pump 16 bbls of hot diesel down the coiled tubing. *At 4,500'CTM,pump 50 bbls of slick seawater down the coiled tubing to get friction reducer out in front of BHA. *Continue RIH w/Slick BHA at 75 fpm while pumping slick seawater @ 0.8 bpm.Pumped total of 250 bbls of slick seawater then freeze protected 1.75"coiled tubing w/45 bbls of diesel.Max depth achieved=18,213'CTM. *Log CCL/Gamma from 18,213'CTM up hole to 11,600'CTM @ 45 fpm.Pull out of hole w/BHA. 3/27/2017 3/28/2017 0.0 00:00 3/27/17-00:00 3/28/17 *Complete the Gamma Ray log as per program. *On surface w/BHA.SIBD.Blow down PCE to Ops flowback tanks via test header. *SLB memory tech verified good data.Send logging data to Anchorage team for review. *Make up Slick BHA=1.75"CTC,1.75"DBPV, 1.75"Stingers,&1.75"JSN. *RIH w/1.75"JSN to perform the Scale Squeeze Program. *Reach 18,075'CTM and pump Scale Squeeze#1. *Pull up to 17,000'CTM and pump Scale Squeeze#2 *Pull up to 14,800'CTM and pump Scale Squeeze#3 *Pull up to 13,100'CTM and pump Scale Squeeze#4 *Freeze protect the Coiled Tubing with 44 bbls of diesel. *Begin pulling out of hole w/BHA. Page 1/2 Report Printed: 4/7/2017 • i • Operations Summary Report- State Well Name: ODSN-04 CAELL rc;,, Alaska Start Depth Foot'Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 3/28/2017 3/29/2017 0.0 00:00 3/28/17-00:00 3/29/17 *Stand by for the wind to subside below 35 mph to complete the RDMO of SLB Coiled Tubing. *Break down all ground iron and hoses in preparation of a complete CTU move. *Wind subsided at 11:00 am and allowed SLB coiled tubing to RDMO off of the ODSN-04 wellhead. *Break down the BHA,Lubricator and rack back the injector head. *Begin moving all SLB coiled tubing to the ODSN-02 location to execute the Scale Squeeze program. *MIRU HES Slickline to complete the Post Scale Squeeze Slickline Program. *RIH and pull the 4.5"Frac sleeve from 2,282'SLM. *RIH and set the 4.5"FXE in the XXO SVLN at 2,282'SLM. *Complete a closure test as per program. *Rig down the 4 1/16"10K second swab valve off of the wellhead via Vetco Gray. *Rig down 2"1502 drop off of flowline&install 5k blind flange via Vetco Gray. *Pick 1.75"coiled tubing reel w/275 ton crane and secure reel on ground. *Pick SLB power stand w/275 ton crane and re-spot on ODSN-02. *Pick 1.75"coiled tubing reel&secure in power stand. *Complete well handover over from Wells Group to Operations. Page 2/2 Report Printed: 4/7/2017 • i ODSN-04 Nuiqsut Production Well Completion FINAL 12-13-2016 I I I IUer No. Upper Completion 1AIl equipment must be no less than 10,000 psi rated) MD(ft) TVD(ft) pp 1 Tubing Hanger 34 34 Completion 2 4-''/:"12.6#/ft C-110 Hydril 521 Tubing I Landed with 3 4/"Halliburton'XXO'SVLN w/3.813""X"profile RTS-8with singlel/4"x0.049" 2304 1998 I I 40,000 lbs s/s control line.Cannon Cross-coupling clamps on every joint 4 4-/"12.6#/ft C-110 Hydril 521 Tubing I Slack Off 5 4-'/:"x 1"GLM#3,KBMG Hydril 521 3315 2478 I 6 4-/"12.6#/ftC-110 Hydril 521 Tubing iiiI I 7 HES"X"Nipple 3.813" 3428 2528 I I ',., 8 4-''/:"12.6#/ftC-110 Hydril 521 Tubing 16"Conductor 9 4/"x 1"GLM#2,KBMG Hydril 521 6591 3908 is I 10 4-''/:"12.6#/ftC-110Hydril 521Tubing I I 11 4-34"x 1"GLM#1,KBMG Hydril 521 11688 6123 I Packer Fluid mix; 12 4'/:"12.6#/ftC-110Hydril 521 Tubing ilii; I I €' Inhibited Kill weight 13 HES XN 4.5"(3.725"NoGo)-(Max inclination 68 degrees) 11801 6168 I E? Brine 14 4/"12.6#/ft C-110 Hydril 521 Tubing 4.5" FXE with 2000'TVD 15 4-1/2"Halliburton'ROC'Gauge Carrier w/Encapsulated e-line to Surface 12655 6384 WRSSSVat II© . 16 4-/"12.6#/ftC-110 Hydril 521 u I diesel cap Tubing 2,304' MD ` 17 Bullet Seal Assembly with HLB self-Aligning Mule Shoe 12766 6395 VII: 1Bottom of Shoe 12782 6397 I No. Lower Completion MD(ft) TVD(ft) I - I 11-3/4"60#L-80 18 Baker 5"X 7"ZXP Liner Top Packer with 15ft Tie Back extension and flex Lock Hanger 12766 6395 GLM#3 DV 19 4/"12.6#/ftC-110Hydril 521 Liner I @ 5,2$4' MD/3,339'TVD 20 4-/"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 7 © BTC Surface Casing 21 Halliburton Swell Packer(4-X"Hydril 521)OD 5.85'-9 meter long oil activated element with 13095 6420 I cemented to surface slide on Volant centralizers pin end 22 4-''/:"12.6#/ft C-110 Hydri 1521 Liner 23 HLB 4-1/2"SLHT Ball Actuated Sleeve(3.009 ball/2.95 Seat) 13270 6419 GLM#2 I ` 24 4-/"12.6#/ft C-110 Hydril521 Liner ;,'�" 9-5/8"40#L-80 25 4-%"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers DV LJ I Hydril 521 Halliburton Swell Packer(4'/:"Hydril 521)OD5.85'-9meter long oil activated element with • Intermediate 1 26 slide on Volant centralizers pin end 13456 6417 . 27 4-''/:"12.6#/ft C-110 Hydril521 Liner Casing 28 4-/"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers © 10,365' MD/ 29 Halliburton Swell Packer(4-75"Hydril 521)0D 5.85'-9 meter long oil activated element with 5,561'TVD slide on Volant centralizers pin end 13621 6421 Cemented 500' 30 4-/"12.6#/ftC-lb Hydril 521 Liner I above shoe 31 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.925 ball/2.867 Seat) 13967 6419 32 4-V:"12.6#/ft C-110 Hydril 521 Liner 33 4/"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(434"Hydril 521)OD 5.85'-9 meter long oil activated element with 34 14271 6421 slide on Volant centralizers pin end 35 444"12.6#/ft C-110 Hydril 521 Liner GLM#1 4-1/2" 12.6#C-110 36 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.842 ball/2.786 Seat) 14613 6415 alum 5/16"OV I Hydril 521 37 4-'/:"12.6#/ft C-110 Hydril 521 Liner 0 m iiii 1 Tubing 38 4-'/:"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Bottom Latch Halliburton Swell Packer(4'/:"Hydril 521)OD 5.85'-9 meter long oil activated element with I (Upper Completion) 39 14920 6399 slide on Volant centralizers pin end I iiii 40 4-/"12.6#/ft C-110 Hydri 1521 Liner 41 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.761 ball/2.706 Seat) 15185 6397 0 ROC 42 4-7."12.6#/ft C-110 Hydril 521 Liner TOC Estimated 43 4-'/:"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 500'above top of Kuparuk ' VIP .,„„: 4,.,,,,,, „ .:;„„, \, 21 6-16,3/864'"HoleTVD TD ... .,,„,..,, „,„„:. `� @ 19,868' MD/ \ J ` 7"26# L-80 _ o BTCM& Hydril 563 26 29 •-` _- __®_-®__1_- __®__1__®__® I I Intermediate 2 Casing - @ 12,965' MD/6,412'TVD 4-'%" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve ODSN-04 Nuiqsut Production Well Completion FINAL 12-13-2016 I I I Upper Halliburton Swell Packer(4-'A"Hydril521)OD5.85'-9 meter long oil activated element with 15452 6395 I Comletion slide on Volant centralizers pin end p 45 4-x"12.6#/ft C-110 Hydril 521 Liner I Landed with 46 HLB 4-1/Y'SLHT Ball Actuated Sleeve(2.681 ball/2.628 Seat) 15833 6395 I 40,000 lbs 47 4-'/"12.6#/ft C-110 Hydril521 Liner Slack Off 48 4-x"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 49 Halliburton Swell Packer(4-'/:"Hydril 521)OD 5.85'-9 meter long oil activated element with 16179 6397 I I slide on Volant centralizers pin end 50 4-Y,"12.6#/ft C-110 Hydril 521 Liner . I I , 51 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.603 ball/2.552 Seat) 16544 6388 16"Conductor 52 4-x"12.6#/ft C-110 Hydril 521 Liner 53 4-'/,"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton SwellPacker(4X"Hydril521)OD5.85'-9meterlongoilactivatedelementwith Packer Fluid mix: 16850 6388 I slide on Volant centralizers pct end I I : inhibited Kill weight 55 4-x"12.6#/ft C-110 Hydril 521 Liner I I ;((i liking 56 HLB 4-1/2 SLHT Ball Actuated Sleeve(2.527 ball/2.477 Seat) 17156 6387 4.5" FXE I I 3 with 2000'TVD 57 4-A:"126#/ft C-110 Hydril 521 Liner WRSSSV at �'I'I diesel cao 58 4-x"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 2,304' MD I / Halliburton Swell Packer(444"Hydril 521)OD 5.85'-9 meter long oil activated element with • 59 slide on Volant centralizers pin end 17463 6388 '-:ii 60 4-%"12.61f/ft C-130 Hydril 521 Liner IMI61 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.452 ball/2.404 Seat) 17727 6390 I 62 4-x"12.6#/ft C-110 Hydril 521 Liner 11-3/4"60#L-80 63 4-x"12.64/ft Hydril 521-6'Pup with slide on Volant centralizers GLM#3 D V 5 GL Halliburton Swell Packer(445"Hydril 521)OD 5.85'-9 meter long oil activated element with 17993 6393 BTC Surface Casing slide on Volant centralizers pin end I @ 5,284' MD/3,339'TVD 65 4-x"12.6#/ft C-110Hydril 521 Liner © cemented to surface 66 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.379 ball/2.332 Seat) 18255 6395 67 4-V,"12.60/ft C-110 Hydril 521 Liner 68 4-x"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(44S"Hydril 521)OD 5.85'-9 meter long oil activated element with GLM#2 ' GL i 9-5/8"40#L-80 69 slide on Volant centralizers pin end 18561 6394 DV 'QJ i Hydril 521 70 4'/,"12.6#/ft C-110 Hydril 521 Liner 71 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.307 ball/2.261 Seat) 18955 6389 ''i Intermediate 1 72 4-%"12.6#/ft C-110 Hydril 521 Liner 4hii. Casing 73 4-x"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers @ 10,365' M D/ 74 Halliburton Swell Packer(4x"Hydril 521)0D 5.85'-9 meter long oil activated element with 19262 6384 slide on Volant centralizers pin end 5,561'TVD 75 4-x"12.6#/ft C-110 Hydril 521 Liner Cemented 500' 76 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.236 bat/2.192 Seat) 19512 6378 above shoe 77 4-V:"12.6#/ft C-110 Hydril 521 Liner 78 4-%"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-14"Hydril 521)OD 5.85'-9 meter long oil activated element with 79 slide on Volant centralizers pin end 19779 6367 80 Pm-Perforated Pup with 4-V:"12.6#/ft C-110 Hydril 521 Pup above and below 81 4-V:"12.6#/ft C-110 Hydril 521 Liner GLM#1 4-1/2" 12.6#C-110 I 82 Eccentric Shoe with Float Sub 19855 6363 iiii moo 5/16" OV - :� i Hydriliiri 521gBottom of Shoe 19858 6363 Bottom Latch ® I (Upper Completion) ® I !E 40 Roc TOC Estimated 500'above top of Kuparuk �♦ , , 21 6-1/8"Hole TD @ 19,868'MD/ 6,364'TVD •` \ 39 _ __l 54)- 59 _ 69 _ 74 _ —— `\ CD # BTCM & Hydril 56329 `.`_IL--IL__0__II___E.__ __®__l__®__® D Intermediate 2 Casing @ 12,965' MD/6,412'TVD 444" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Seal Tite 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Caelus Natural Resources Alaska,LLC ,��� � Development 0 Exploratory❑ 213-037 3.Address: 3700 Centerpoint Drive,Suite 500 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-703-20670-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: RECEI ADL 355036/ADL 389959/ADL 389958 ODSN-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MAP 0 9 :1017 N/A Oooguruk- Nuiqsut Oil Pool 11.Present Well Condition Summary: Total Depth measured 19,868 feet Plugs measured N/A feet true vertical 6,364 feet Junk measured N/A feet Effective Depth measured 19,858 feet Packer measured See attachment 3 feet true vertical 6,363 feet true vertical See attachment 3 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5,241' 11-3/4" 5,284' 3,339' 5,830 psi 3,180 psi Intermediate 5,258' 9-5/8" 5,105'-10,365' 3,260'-5,561' 5,750 psi 3,090 psi Production 12,923' 7" 12,965' 6,412' 7,240 psi 5,410 psi Liner 7,092' 4-1/2" 12,766'-19,858' 6,395'-6,363' 11,590 psi 9,200 psi Perforation depth Measured depth See attachment feet aPR3 r+SCANNEDl .. 130.2 True Vertical depth See attachment feet po.2 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#,C-110,Hyd 521 12,782'MD 6,397'TVD Packers and SSSV(type,measured and true vertical depth) See attachment pg.3 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A 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: 1,720 1,478 445 1,059 358 Subsequent to operation: 1,373 850 372 1,266 406 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUGE] 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: N/A Contact Rami Jasser,343-2182 Email rami.jasser@caelusenergy.com Printed Name Rami Ja Title Senior Staff Completion Engineer Signature z1 Phone 343-2182 Date3/q/FF Form 10-404 Revised 5/2015 Submit Original Only /,,,,,i /7 `' ' 3---.2-`(—/ BDMS 'U J MAR 2 7 2017 Attachment 2 AOGCC Form 10-404 Sundry Report Box 11 - Perforation Locations Well: ODSN-04 Top (MD) Top (TVD) 4-1/2" SLHT Ball Actuated Sleeve w/Seat#11 13,270 6,419 4-1/2" SLHT Ball Actuated Sleeve w/Seat#10 13,967 6,419 4-1/2" SLHT Ball Actuated Sleeve w/Seat#09 14,613 6,415 4-1/2" SLHT Ball Actuated Sleeve w/Seat#08 15,185 6,397 4-1/2" SLHT Ball Actuated Sleeve w/Seat#07 15,833 6,395 4-1/2" SLHT Ball Actuated Sleeve w/Seat#06 16,544 6,388 4-1/2" SLHT Ball Actuated Sleeve w/Seat#05 17,156 6,387 4-1/2" SLHT Ball Actuated Sleeve w/Seat#04 17,727 6,390 4-1/2" SLHT Ball Actuated Sleeve w/Seat#03 18,255 6,395 4-1/2" SLHT Ball Actuated Sleeve w/Seat#02 18,955 6,389 4-1/2" SLHT Ball Actuated Sleeve w/Seat#01 19,512 6,378 Pre-Perforated Pup 19,811 6,366 • • Attachment 3 AOGCC Form 10-404 Sundry Report Box 11 - Packers & SSSV Well: ODSN-04 SSSV MD TVD 4-1/2" Halliburton 'XXO' SVLN 2,304' 1,998' PACKERS 5" x 7" Baker ZXP Liner Top Packer 12,766' 6,395' HES Swell Packer#13 13,095' 6,420' HES Swell Packer#12 13,456' 6,417' HES Swell Packer#11 13,621' 6,421' HES Swell Packer#10 14,271' 6,421' HES Swell Packer#9 14,920' 6,399' HES Swell Packer#8 15,452' 6,395' HES Swell Packer#7 16,179' 6,397' HES Swell Packer#6 16,850' 6,388' HES Swell Packer#5 17,463' 6,388' HES Swell Packer#4 17,993' 6,393' HES Swell Packer#3 18,561' 6,394' HES Swell Packer#2 19,262' 6,384' HES Swell Packer#1 19,779' 6,367' • Operations Summary Report- State• Well Name: ODSN-04 Ca AE F Alaska Well Name: Contractor: Rig Number: Job Category: Start Date: End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 11/30/2016 12/1/2016 19,868.0 00:00 11/30/16-00:00 12/01/16 *MIRU Seal Tite equipment to execute the Gly Flow misting. *Shoot a fluid level on the IA=250'. *P/T to 4400 psi with gas on surface with the IA gate valve shut in. *Pressure up the IA to 2500 psi in 500 psi increments while monitoring leak rate from the IA. *Inject/mist a total of 16.3 liters of Gly Flow into the IA.in 3 seperate treatments. *IA x OA communication still evident. *Shut down for the night and monitor all pressures. 12/1/2016 12/2/2016 19,868.0 00:00 12/01/16-00:00 12/02/16 *MIRU Seal Tite equipment to execute the Gly Flow misting. *Shoot a fluid level on the IA=250'. *Inject/mist a total of 12.5 liters of Gly Flow into the IA in 1 treatment. _-, *IA x OA communication still evident. *Consult with Seal Tite management on best practice for plan forward. *Pump 4 bbls of diesel down the TBG to bring fluid level up in the IA to 50-100'. *Cycle pressure on the IA from 2500 to 250 psi 3 times in attempt to fracture the sealant for better penetration. *Shut down for the night to let fluid relax. *Notify the OPS team to monitor all pressures. 12/2/2016 12/3/2016 19,868.0 00:00 12/02/16-00:00 12/03/16 *MIRU Seal Tite equipment to execute the Gly Flow misting. *Shoot a fluid level on the IA=100'. *Inject/mist a total of 7 liters of Gly Flow into the IA in 1 treatment. *IA x OA communication still evident but slowing down by a noticeable amount. *Let Seal Tite Gly Flow cure for 6 hours while monitoring the OA pressure build. *See a sudden increase in the OA pressure build and leak flow rate. *Mist another 1.5 liters in the IA and the up-trend stops immediately. *Leak is substantially better. *Monitor fro the night with the OA shut in. *Consult with Seal Tite management on best practice for plan forward. 12/3/2016 12/4/2016 19,868.0 00:00 12/03/16-00:00 12/04/16 *Monitor the IA and OA pressures closely. *Ensure the IA pressure does not fall below 2500 psi. *Monitor a shut in pressure build of the OA.Ensure the pressure does not exceed 500 psi. *Begin the 48 hour cure time on the Seal Tite Gly Flow misting solution. *OA pressure build is averaging 7.5 psi per hour.This build rate is improving. *The IA pressure fall rate from 2500 psi is averaging 3 psi per hour. 12/4/2016 12/5/2016 19,868.0 00:00 12/04/16-00:00 12/05/16 *Monitor the IA and OA pressures closely. *Ensure the IA pressure does not fall below 2500 psi. *Monitor a shut in pressure build of the OA.Ensure the pressure does not exceed 500 psi. *Complete the 48 hour cure time on the Seal Tite Gly Flow misting solution. *OA pressure build is averaging 8 psi per hour. *The IA pressure fall rate from 2500 psi is averaging 3 psi per hour. 12/5/2016 12/6/2016 19,868.0 00:00 12/05/16-00:00 12/06/16 *48 hour cure time is complete on the Gly Flow Seal Tite. *Re-rig the gas lift spool to the wellhead to return the well to flowing parameters. *MIRU HES Slickline to ready ODSN-04 for flowing parameters. *Displace the 215 bbls of diesel out of the IA by taking fluid off of the TBG while keeping 2500 psi on the IA. *Pump a total of 6 liters of Gly Flow in the IA while displacing the IA with lift gas. *Set 5/16"(BTTM LTCH)OV in GLM#1 at 11,688'MD.P/T the OV to 1500 psi on the TBG. Good test. *OA Build rate is at 15 psi per hour average.This has doubled from what was observed on the 48 cure process. *Lay down HES Slickline for the night. Page 1/4 Report Printed: 3/9/2017 • • CAELLS Operations Summary Report - State Well Name: ODSN-04 F Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 12/6/2016 12/7/2016 19,868.0 00:00 12/06/16-00:00 12/07/16 *Pick up HES Slickline and continue to prep for flowing parameters. *Attempt to retrieve the 4.5"bait sub.Unable to latch.sit down at 11,655'slm.Frac sand evident. *Make 3 bailer runs with a 3.00"pump bailer(mule shoe flapper bottom.retrieve a total of 3.0 gallons of proppant.see metal marks on the bailer once 11,765'slm is reached from 11,655'slm. *Pull the 4.5"bait sub(valve catcher)from 11,765'slm to surface. *Lay down the HES Lubricator for the night. 12/7/2016 12/8/2016 19,868.0 00:00 12/07/16-00:00 12/08/16 *Pick up HES Slickline and continue to prep for flowing parameters. *Equalize and pull the 4.5"Evo Trieve from 11,774'slm.Evo-Trieve on surface. *Set a FXE SSSV in the XXO SVLN,perform a closure test on the FXE.Good test. *Contact the OPS group and line up ODSN-04 to the flowback tanks. *Begin flowing ODSN-04 to flowback tanks while monitoring all pressures. *Well Flows for 1 hour and wellhead pressure begins to fall off.Bring IA pressure up to 2350 psi to lift the well. *IA and TBG not communicating,5/16"OV most likely not opening. *Talk to the OPS team and begin bleeding the IA pressure to 1000 psi to"Rock"the OV differential pressure. *TBG begins to track the IA some at 2070 psi on the IA.Choke was closed and IA fell below BHP so the well was never brought online. 12/8/2016 12/9/2016 19,868.0 00:00 12/08/16-00:00 12/09/16 *Consult with the Anchorage team on a plan forward to get ODSN-04 flowing into production. *Bring IA pressure up to 2300 psi. *Pump 10 bbls of diesel down the IA to"flush"the 5/16"OV at 11,688'MD. *IA begin communicating with the TBG at 2297 psi. *Well flowing into the production line. *OA leak rate increased to 300 scfph. *Pump a total of 33.1 liters of Gly Flow Seal Tite in 12 different sessions.OA leak rate falls to 125 scfph. *Continue To flow into the production line at OPS teams direction. 12/9/2016 12/10/2016 19,868.0 00:00 12/09/16-00:00 12/10/16 *Monitor OA pressure build and leak flow rate. *ODSN-04 flowing to the production line. *OA building to 500 psi every 3 hours through the night.Leak has gotten significantly worse. *Consult with the Anchorage team on recorded OA pressure builds. *Consult with the Seal Tite management team. *Reconfigure the Seal Tite misting rig up to the IA. *Bring well back online and begin misting crew. *Mist in a total of 8.1 liters in 3 stages.Leak flow rate is unreadable at 0 psi.Leak has improved. 12/10/2016 12/11/2016 19,868.0 00:00 12/10/16-00:00 12/11/16 *Monitor OA pressure build and leak flow rate. *ODSN-04 flowing to the production line. *OA built to 480 psi in 8 hours and had to bleed off the OA at 02:50 am. *Consult with the Seal Tite management team. *Turn off the Methanol trickle in lift gas. *Mist in a total of 8 liters in 7 stages *Monitor the OA pressure through the night.Ensure the pressure does not exceed 500 psi. Page 2/4 Report Printed: 3/9/2017 • Operations Summary Report - State a CAELLWell Name: ODSN-04 Ln le y Alaska Start Depth Foot/Meters Dens Last Start Date End Date (ttKB) (ft) Mud(Ib/gal) Summary 12/11/2016 12/12/2016 19,868.0 00:00 12/11/16-00:00 12/13/16 *Monitor OA pressure build and leak flow rate. *ODSN-04 flowing to the production line. *Consult with the Seal Tite management team. *Mist in 12 liters of Seal Tite Gly Flow in 3 stages.OA leak rate does not improve. *Inspet fluid returns coming from the OA.Confirmed Gly Flow in the OA returns. *Seal Tite is flowing through the leak at 14'and flowing out of the OA. *Consult with the Seal Tite management team. *Decision is made to mix the"Neat"Gly Flow and the formulated fgly flow at 60/40 blend. *Pump 3.3 gallons of the Gly Flow blend into the IA.No improvement on the leak rate and pressure builds. *OA pressure build is averaging 30 psi per hour. *Ensure the OA pressure does not exceed 500 psi 12/12/2016 12/13/2016 19,868.0 00:0012/12/16-00:00 12/13/16 *Monitor OA pressure build and leak flow rate. *ODSN-04 flowing to the production line. *IA built to 425 psi at 04:09 am.Bleed pressure to 0 psi. *Consult with the OPS supervisor and create a plan forward to shut the well in and RDMO Seal Tite equipment. *Shut in ODSN-04 to RDMO all seal tite equipment. *Return the IA wellhead configuration to normal operating status. *Hand well over to OPS from the Wells Group. ***A total of 31.5 gallons of seal tite was pumped in 39 separate stages*** 2/3/2017 2/4/2017 19,868.0 00:00 2/3/17-00:00 2/4/17 *MIRU Seal Tite equipment to execute the Gly Flow misting. *Well Flowing to the production header. *Rig up a jumper line from the gas lift header to the instrumentation manifold. *P/T to 2500 psi with diesel with the IA gate valve shut in.Good Test *Inject/mist a total of 12 liters of Gly Flow into the IA.in 4 separate treatments. *IA x OA communication still evident. *After the last treatment it was noticed that the pack off on the misting rod.Rig down all Seal Tite equipment and monitor the well. *Seal Tite equipment inoperable.New misting rod and pack off in route from Houston expected to arrive 2/5/17-2/6/17. *Shut down for the night and monitor all pressures. *OA is on a consistent pressure build of 7 psi per hour.this is consistent to the trends prior to the current days treatments. 2/4/2017 2/5/2017 19,868.0 00:00 2/4/17-00:00 2/5/17 *Monitor the OA pressure build trends. *Well is on lift gas with a consistent lift rate of 1.0 MMSCFPD. *Well is being produced to the production header. *The OA build rate is at an average of 3 psi per hour. *This build rate is half of what the"pre retreat"build was. *A total of 12 liters of Gly Flow has been misted into the IA during the re treat. *Standing by for the new misting rod and pack off to arrive on ODS. 2/5/2017 2/6/2017 19,868.0 00:00 2/5/17-00:00 2/6/17 *Monitor the OA pressure build trends. *Well is on lift gas with a consistent lift rate of 1.0 MMSCFPD. *Well is being produced to the production header. *The OA build rate is at an average of 1.25 psi per hour. *This build rate is 1/5 of what the build was pre re-treat. *A total of 12 liters of Gly Flow has been misted into the IA during the re treat. *Standing by for the new misting rod and pack off to arrive on ODS. Page 3/4 Report Printed: 3/9/2017 •Operations Summary Report- State a Well Name: ODSN-04 CAELL Alaska Start Depth Foot/Meters Dens Last Start Date End Date MKS) (k) Mud(Iblgal) Summary 2/6/2017 2/7/2017 19,868.0 00:00 2/6/17-00:00 2/7/17 *Monitor the OA pressure build trends. *Well is on lift gas with a consistent lift rate of 1.0 MMSCFPD. *Well is being produced to the production header. *The OA build rate is at an average of 1.75 psi per hour. *This build rate is 1/5 of what the build was pre re-treat. *A total of 12 liters of Gly Flow has been misted into the IA during the re treat. *Standing by for the new misting rod and pack off to arrive on ODS. *OA pressure stabilized at 30-32 psi at 14:13 and began to fluctuate in that pressure range. 2/7/2017 2/8/2017 19,868.0 00:00 2/7/17-00:00 2/8/17 *SealTite replacement rod&pack off arrived @ ODS. *Well Flowing to production w/lift gas©1 MMSCFD. *24 Hr OA leak rate=30 psi in last 24 hrs or 1.25 psi/hr. *Shut in lift gas to IA.MIRU SealTite misting assembly to IA and attempt pressure test.Misting assembly leaking @ 500 psi where misting rod goes into pack off.Attempt multiple tests with same results. *Rig down misting assembly from IA and inspect.Found damaged internal teflon seal rings inside pack off assembly. *SealTite contacted vendor&they do not have any of the damaged teflon rings in stock. *Contact Anchorage team. Decision made to release SealTite Rep&execute job at a later date. *Install SSV on IA and pressure test with gas. *Complete well handover from Wells Group to Operations. Page 4/4 Report Printed: 3/9/2017 • • ODSN-04 Nuiqsut Production Well Completion FINAL 12-13-2016 II I Upper No. Upper Completion(All equipment must be no less than 10,000 psi rated) MD(ft) ND(ft) 1 Tubing Hanger 34 34 Completion 2 4-t4"12.6#/ft C-110 Hydril 521 Tubing I Landed with 3 4-%"Halliburton'XXO'SVLN w/3.813""X"profile RTS-8 with single1/4"x 0.049" 2304 1998 I 40 000 lbs s/s control line.Cannon Cross-coupling clamps on every joint I 4 4-34"12.6#/ft C-110 Hydril 521 Tubing Slack Off 5 4-'/,"x 1"GLM#3,KBMG Hydril 521 3315 2478 I I 6 4-1A"12.6#/ft C-110 Hydril 521 Tubing I 7 HES"X"Nipple 3.813" 3428 2528 8 4-A"12.6#/ft C-110 Hydril 521 Tubing 16"Conductor 9 4-'/:"x 1"GLM#2,KBMG Hydril 521 6591 3908 I 10 4-'/,"12.6#/ft C-110 Hydril 521 Tubing I 11 444"x 1"GLM#1,KBMG Hydril 521 11688 6123 Packer Fluid mix; 12 4-%"12.6#/ftC-110HydriI521Tubing I Inhibited Kill weight . 13 HESXN4.5"(3.725"NoGo)-(Max inclination 68 degrees) 11801 6168 4.5" FXE I I • Brine, 14 4-'/"12.6#/ft C-110 Hydril 521 Tubing I *areal 0 with 2000'TVD 15 .4-1/2"Halliburton'ROC'Gauge Carrier w/Encapsulated a-line to Surface 12655 6384 WRSSSVatdiesel cap 16 4-'/,"12.6#/ftC-110 Hydril 521 Tubing 2,304' MD I 17 Bullet Seal Assembly with HLB Self-Aligning Mule Shoe 12766 6395 I =d ' Bottom of Shoe 12782 6397 ii: I No. Lower Completion MD(ft) TVD(ft) 11-3/4" 60#L-80 18 Baker 5"X 7"ZXP Liner Top Packer with 15ft Tie Back extension and Flex Lock Hanger 12766 6395 GLM#3 DV 5 GL BTC Surface Casing 19 4-'A"12.6#/ft C-110 Hydril 521 Liner I @ 5284' MD/3339'TVD 20 4-'/"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 7 f X , , Halliburton Swell Packer(4-'A"Hydril 521)OD5.85'-9 meter long oil activated element with cemented to surface 21 slide on Volant centralizers pin end 13095 6420 22 4-''A"12.6#/ft C-110 Hydril 521 Liner iiii 23 HLB 4-1/2"SLHT Ball Actuated Sleeve(3.009 ball/2.95 Seat) 13270 6419 GLM#2 ;;:i24 4-'A"12.6#/ft C-110 Hydril 521 Liner GL € 9-5/8"40#L-80 25 4-A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers DV 521 Halliburton Swell Packer(4'/:"Hydril 521)0D 5.85'-9 meter long oil activated element with I Intermediate 1 26 slide on Volant centralizers pin end 13456 6417 A I Casing 27 4-'A"12.6#/ftC-110Hydril521 Liner 28 4-'A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers @ 10,365' MD/ Halliburton Swell Packer(4%"Hydril 521)OD 5.85'-9 meter long oil activated element with 29 13621 6421 5,561'TVD slide on Volant centralizers pin end Cemented 500' 30 4-%"12.6#/ft C-110 Hydril 521 Liner 31 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.925 ball/2.867 Seat) 13967 6419 above shoe 32 4-'A"12.6#/ft C-110 Hydril 521 Liner 33 4-%"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-'/,"Hydril 521)OD 5.85'-9 meter long oil activated element with 34 slide on Volant centralizers pin end 14271 6421 35 4-'/="12.6#/ft C-110 Hydril 521 Liner GLM#1 4-1/2" 12.6#C-110 36 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.842 ball/2.786 Seat) 14613 6415 5/16"OV m 1 Hydril 521 37 4-A"12.6#/ft C-110 Hydril 521 Liner I Tubing 38 4-A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Bottom Latch Halliburton Swell Packer(4-''h"Hydril 521)ODS.8S'-9 meter long oil activated element with I (Upper Completion) 39 14920 6399 ® ,1:11I .1 slide on Volant centralizers pin end 40 4-'A"12.6#/ft C-110 Hydril 521 Liner 41 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.761 ball/2.706 Seat) 15185 6397 0 ROCii42 4-'''A"12.6#/ft C-110 Hydril 521 Liner TOC Estimated 43 4-'''A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 500'above top of Kuparuk :%• q_0 # ,...,•",,i;,. k ..,:/ 21 6-1/8" Hole TD ` �. @ 19,868' MD/ 6,364'TVD �� ``O - 39 - O - 49 - O- 59 - 61 - 1)9- 69 -4-9-- Q . „ # BTC-M & Hydril 563 ® ® 2 9 -` -__N___N__N__ __N__®__ill__N__® 8 0 _J Intermediate 2 Casing @ 12,965' MD/6,412'TVD 4-'%" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve • • . , ODSN-04 Nuiqsut Production Well Completion FINAL 12-13-2016 I Upper 44 Halliburton Swell Packer(4-%"Hydril 521)OD 5.8V-9 meter long oil activated element with :;, 15452 6395 I Completion slide on Volant centralizers pin end I 45 4-3512.69/ft C-110 Hydril 521 Liner Landed with 46 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.681 ball/2.628 Seat) 15833 6395 .,., I 40,000 lbs 47 4,A"12.6#/ft C 110 Hydril 521 Liner I Slack Off 48 4-X"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers I ...:, Halliburton Swell Packer(4,A"Hydril 521)OD 5.8V-9 meter long oil activated element with 49 16179 6397 •1• I slide on Volant centralizers pin end 1'11 I I :,, 50 4-35"12.6#/ft C-110 Hydril 521 Liner . 51 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.603 ball/2.552 Seat) 16544 6388 . k: ,,,,a 16"Conductor 52 4,A"12.6#/ft C-110 Hydril 521 Liner I 53 4,A"12.6#/ft Hydril 521-6Pup with slide on Volant centralizers - - Halliburton Swell Packer(4-%"Hydril 521)OD 5.8V-9 meter long oil activated element with Packer Fluid mix: 54 . 16850 6388 Islide on Volant centralizers pin end I :, Inhibited Kill weight ss 4-35"12.6#/ft C-110 Hydril S21 Liner I I Brine 56 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.527 ball/2.477 Seat) 17156 6387 4.5 FXE i22 I (V with 2000'TVD 57 4-3512.69/ft C-110 Hydril 521 Liner WRSSSV at ii ::: 58 4-1A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers ‘ ... . I diesel cao 2,304' MD 59 Halliburton Swell Packer(4-%"Hydril 521)OD 5.85'-9 meter long oil activated element with 17463 6388 i;I:. : slide on Volant centralizers pin end .. ,: .. 60 4,A"12.6#/ft C-110 Hydril 521 Liner :,:: 61 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.452 ball/2.404 Seat) 17727 6390 62 4-35"12.6P/ft C-110 Hydril 521 Liner 11-3/4"60#L-80 63 4-351269/ft Hydril 521-6'Pup with slide on Vol ant centralizers Halliburton Swell Packer(4-35"Hydril 521)0D 5.85'-9 meter long oil activated element with GLM#3 DV GL BTC Surface Casing 64 slide on Volant centralizers pin end 17993 6393 I © 5,284' MD/3,339'TVD 65 4-M"12.6#/ft C-110 Hydril 521 Liner • 7 X 1, cemented to surface 66 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.379 ball/2.332 Seat) 18255 6395 67 4,A"12.6#/ft C-110 Hydril 521 Liner •P, 68 4,35"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers ii .. Halliburton Swell Packer(4-%"Hydril 521)0D 5.85'-9 meter long oil activated element with 69 18561 6394 GLM#2 . ./.7..1' GL :: 9-5/8"40#L-80 slide on Volant centralizers pin end DV :Q..../ Hydril 521 70 4,35"12.6#/ft C-110 Hydril 521 Liner 71 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.307 ball/2.261 Seat) 18955 6389 11. Intermediate 1 72 4-3512.69/ft C-110 Hydril 521 Liner 4 Casing 73 4-3512.69/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(44S"Hydril 521)00 5.85'-9 meter long oil activated element with @ 10,365' MD/ 19262 6384 74 slide on Volant centralizers pin end 5,561'TVD 75 4-35"12.6#/ft C-110 Hydril S21 Liner Cemented 500' 76 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.236 ball/2.192 Seat) 19512 6378 77 4-3512.69/ft C-110 Hydril 521 Liner above shoe 78 4,A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-35"Hydril 521)OD 5.85'-9 meter long oil activated element with 79 19779 6367 slide on Volant centralizers pin end 80 Pre-Perforated Pup with 4,35"12.6#/ft C-110 Hydril 521 Pup above and below 81 4-35"12.6#/ft C-110 Hydril 521 Liner 4-1/2" 12.6#C-110 GLM#1 82 Eccentric Shoe with Float Sub 19855 6363 5/16" OV GL Hydril 521 Bottom of Shoe 19858 6363 An•:.- 1:;: Bottom Latch I71m -I;: Tubing -i (Upper Completion) 41) Ea .:il li:il — :ili 4111 R" :.:. TOC Estimated -• 500'above top of .. ' : Kuparuk ..., .... ... !fii .• *Lk. ... e ..0 6-1/8"Hole TD '1 4,` ,.... @ 19,868'MD/ • ,,, _ 7"26# L-80 , # _ BTC-M & Hydril 563 1 Intermediate 2 Casing @ 12,965' MD/6,412'TVD 4-1/2" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve •OA • VOFTji "I//7, .sA THE STATE Alaska Oil and Gas 64 114 o f® ®® SKA Conservation Commission 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Rami Jasser 149 Senior Staff Completion Engineer SCO- Caelus Natural Resources Alaska, LLC 3700 Centerpoint Drive, Suite 500 Anchorage,AK 99503 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-04 Permit to Drill Number: 213-037 Sundry Number: 317-102 Dear Mr. Jasser: 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 AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration is considered timelyif it is for reconsideration. Arequest 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, Cathy(r11611Foerster Chair DATED this gl&a day of March, 2017. RBDEAS 2 3 23';7 • ! RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 06 ;! l ar /� APPLICATION FOR SUNDRY APPROVALS ny r3 j d 20 AAC 25.280 , f, C, 1.Type of Request: Abandon ❑ Plug Perforations El Fracture Stimulate ❑ Repair Well El Operations shutdown El Suspend ❑ Perforate ❑ Other Stimulate El Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Scale Squeeze. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Caelus Natural Resources Alaska,LLC Exploratory ❑ Development , 213-037 3.Address: Stratigraphic LiService ❑ 6.API Number: 3700 Centerpoint Drive Suite 500 Anchorage,AK 99503 50-703-20670-00-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A / ODSN-04 • Will planned perforations require a spacing exception? Yes CI No Cl 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 389959/ADL 389958 - Oooguruk- Nuiqsut Oil Pool' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 19,868' 6,364' 19,858' 6,363' 1,316 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5,241' 11-3/4" 5,284' 3,339' 5,830 psi 3,180 psi Intermediate 5,258' 9-5/8" 5,105'-10,363' 3,260'-5,560' 5,750 psi 3,090 psi Production 12,923' 7" 12,966' 5,412' 7,240 psi 5,410 psi Liner 7,092' 4-1/2" 12,766'-19,858' 6,395'-6,363' 11,590 psi 9,200 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See attachment pg.2 / See attachment pg.2 4-1/2" 12.6#,C-110,Hyd 521 12,802' Packers and SSSV Type: See attachment pg.3 Packers and SSSV MD(ft)and TVD(ft): See attachment pg.3 / 12.Attachments: Proposal Summary ❑ Wellbore schematic E] 13.Well Class after proposed work: Detailed Operations Program l] BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development El • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/22/2017 OIL D. WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Rami Jasser,343-2182 Contact Email ramijasser0/caelusenergy.com Printed Name Rami asser Title Senior Staff Completion Engineer Signature /17,A, Phone Date ��17,A,1 230-1390 3/Cl/ " COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -3 \"7— ‘v2 Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test El Location Clearance ❑ c-;- ? ill- Other: 1 Post Initial Injection MIT Req'd? Yes ❑ No El Re Fa 3 Cty I"'7 2 2 2:1;7 Spacing Exception Required? Yes ❑ No (( Subsequent Form Required: /p„tf Oci p APPROVED BY Approved by: n COMMISSIONER THE COMMISSION Date: 3 _ g — 17 A 710- 9674r7 RiaeicitNsAibr h3-7.-17 Submn Farm ane Form 10-403 Revised 11/2015 12 months from a date of approval. Attachments in Duplicate 0 RECEIVED GmAR16X017 Energy Alaska Caelus Natural Resources Alaska,LLC 3700 Centerpoint Drive,Anchorage,AK 99503 Tel:(907)277-2700 Fax:(907)343-2190 March 6, 2017 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite #100 Anchorage, AK 99501 RE: ODSN-04 Sundry Application for Scale Squeeze Treatment REF: Approved Permit to Drill #213-037 Caelus Natural Resources Alaska, LLC. (CNRA) hereby submits an Application for Sundry to perform a Scale Squeeze Treatment across the production lateral. The treatment is requested as a preventative measure due to the recent 20% water cut recorded while on production. Please see the proposed plan attachment and supporting documentation. Sincerely, I. ir Rami Jasser Senior Staff Completion Engineer Attachments: Form 10-403 Supporting information cc: ODSN-04 Well File • Attachment 2 AOGCC Form 10-403 Sundry Application � Box 11 - Perforation Locations Well: ODSN-04 Top(MD) Top(TVD) 4-1/2" SLHT Ball Actuated Sleeve w/Seat#11 13,270 6,419 4-1/2" SLHT Ball Actuated Sleeve w/Seat#10 13,967 6,419 4-1/2" SLHT Ball Actuated Sleeve w/Seat#09 14,613 6,415 4-1/2" SLHT Ball Actuated Sleeve w/Seat#08 15,185 6,397 4-1/2" SLHT Ball Actuated Sleeve w/Seat#07 15,833 6,395 4-1/2" SLHT Ball Actuated Sleeve w/Seat#06 16,544 6,388 4-1/2" SLHT Ball Actuated Sleeve w/Seat#05 17,156 6,387 4-1/2" SLHT Ball Actuated Sleeve w/Seat#04 17,727 6,390 4-1/2" SLHT Ball Actuated Sleeve w/Seat#03 18,255 6,395 4-1/2" SLHT Ball Actuated Sleeve w/Seat#02 18,955 6,389 4-1/2" SLHT Ball Actuated Sleeve w/Seat#01 19,512 6,378 Pre-Perforated Pup 19,811 6,366 • • Attachment 3 MAMMA AOGCC Form 10-403 xelMar 'COMMApplication for Sundry Box 11 - Packers & SSSV Well: ODSN-04 SSSV MD TVD 4-1/2" Halliburton 'XXO' SVLN 2,304' 1,998' PACKERS 5"x 7" Baker ZXP Liner Top Packer 12,766' 6,395' HES Swell Packer#13 13,095' 6,420' HES Swell Packer#12 13,456' 6,417' HES Swell Packer#11 13,621' 6,421' HES Swell Packer#10 14,271' 6,421' HES Swell Packer#9 14,920' 6,399' HES Swell Packer#8 15,452' 6,395' HES Swell Packer#7 16,179' 6,397' HES Swell Packer#6 16,850' 6,388' HES Swell Packer#5 17,463' 6,388' HES Swell Packer#4 17,993' 6,393' HES Swell Packer#3 18,561' 6,394' HES Swell Packer#2 19,262' 6,384' HES Swell Packer#1 19,779' 6,367' • Oooguruk Wells Group CE CAELLS Alaska ODSN-04 Coil Tubing — Scale Squeeze Treatment 3-6-2017 Version 2 Prepared: Date: Chad Gueco Wells Group Supervisor Prepared: Date: Eli Wilson Wells Group Supervisor Reviewed: Date: Rami Jasser Completions Engineer ODSN-04 Coil Tubing Scale Squeeze Treatment—version 2(3/6/2017) • Oooguruk Wells Group • Objective: ODSN-04 had been on production for close to 3 years. Due to the current 20% water cut recorded while on production, decision has been made to utilize Coil Tubing during the ice road season to lay scale treatment evenly across the production lateral as a preventative measure. Scale Squeeze Design: Baker Petrolite recommends the following scale squeeze design and operational procedure to protect ODSN-04 from barium sulfate and calcium carbonate precipitation: • 32 barrel pre-flush containing 50% WAW5206 o 660 gallons WAW5206 & 16 barrels seawater • 242 barrel main treatment containing 13% SCW4004 o 1320 gallons SCW4004 & 210 barrels seawater • 442 est. barrel seawater formation over-displacement (0.5 ft. OD). • 12 hour shut in • Use recommended maximum injection pressures and rates. • Please be aware that SCW4004 is not compatible with methanol. • Obtain QA/QC concentration samples during job. Slickline: 1. Coordinate with Operations to shut in well. 2. Record WH, IA, and OA pressures. Shoot and record fluid levels on Tubing, IA, and OA. If the OA is bled, measure and record H2S level. Send results to Anchorage team. 3. Complete handover from Operations to Wells. 4. Conduct pre-job safety meeting with Wells Group Supervisor, Operations, and all service companies involved in the job scope. 5. MIRU HES Slick-line. Pick up lubricator, tool string, and 3.83" gauge ring. 6. Pressure test PCE as per HES policy and procedure. 7. RIH w/ 3.83" gauge ring to XXO SVLN @ 2,304' MD. 8. RIH w/4.5" GS & prong to FXE SSSV in SVLN @ 2,304' MD. 9. Drift w/ 2' of weight bar, and 3.79" gauge ring to XN nipple @ 11,801' MD. 10.RIH w/ 4.5" GS w/ 4.5" Frac sleeve and set in the XXO SVLN @ 2,304' MD. 11.P/T the Frac sleeve to 4500 p i ens sure control line integrity. Shear off and POOH. 12.RDMO HES Slickline. 13.Prepare to rig up coil tubing unit. ODSN-04 Coil Tubing Scale Squeeze Treatment—version 2 (3/6/2017) Oooguruk Wells Group Coiled Tubing Gamma Ray / CCL Loq: • The objective of running the Gamma Ray/ CCL Log to identify the source of water. • CoiICADE modeling showing lockup around 18,400 ft. MD with 0.23 friction factor. 1. MIRU 1 3/4" coil tubing unit and associated equipment. Nipple up 4-1/16" 10k Quad BOP's and required cross-over spools. 2. A crane is needed for lifting operations, verify with crane operator, weight of every component to be lifted during rigging up/rigging down procedures. 3. Conduct Pre Job Safety Meeting (PJSM) in rigging up Coiled Tubing Unit (CTU) along with associated surface equipment. Mitigate all hazards discussed. 4. The Well Site Supervisor and the Coiled Tubing Unit Supervisor should agree to contingencies to follow in the event of a tubing failure during operations. 5. High pressure areas should be recognized and posted. Make an all call prior to testing lines alerting personnel to stay away from high pressure. Consider site control measures during the cleanout operations 6. Ensure that the IA is shut-in and both IA & OA pressures are monitored throughout the job. NOTE: Ensure that IA is always higher pressure than the OA (maintain a 500 psi differential). 7. Ensure that all tanks and lines are clean and all fluids filtered before entering the CT pump. 8. Rig up Schlumberger (SLB) 2" 1502 hardline from the manifold on the swivel joint side of the coiled tubing reel. NOTE: Ensure the Micro Motion (MM) is calibrated with water and will record in both direction of flow. 9. Conduct HSE walk through with Schlumberger's CTU supervisor and CEA Well Site Supervisor. 10.Conduct BOP pressure test using Diesel. Re: Schlumberger's Seven Day BOP Test Guidelines and Procedure for CTS Operations date 10/31/11. Also pressure test all associated equipment Release pressure and un-stab. 11.Verify OD, ID, length of all tools and that any fishing equipment is available if needed. Ensure that the CTU operator is aware of all restrictions in the well and has a plan to slow down prior to running BHA thru the restrictions. 12.Make-up (MU) BHA.Install roll-on Coiled Tubing Connector (CTC) (refer to SLB SOP's on CTC installation) and pull test to 10k. Both the CTU and Well Site Supervisor must pre-approve the BHA. 13.Make-up (MU) BHA, Install the 1 11/16" Gamma Ray Logging BHA. ODSN-04 Coil Tubing Scale Squeeze Treatment—version 2 (3/6/2017) • Oooguruk Wells Group 14.AII BHA items run in the hole dimensions will be measured and posted by Well Site Supervisor and CTU Supervisor in the Op's Cab. 15.Pick up the required lubricator and stab on well. Line up and pressure test the BOP body to 250/4000 psi. Line up to diesel out of SLB pumps truck. Pressure up on the lubricator to equal the Well Head Pressure (WHP) and open the lower FV, count and record turns. Open the upper FV slowly and count and record turns. NOTE: Open bottom valve first and with low pressure differential between wellbore and lubricator, open top FV slowly to reduce any possible erosion of bottom FV gate. 16.RIH not pumping (dry) to 3,500ft MD. 17.Pump-friction reducer at 1 BPM running at coil speed of 50 fpm until reach coil lockup depth. 18.RIH at the SLB Coiled Tubing Memory Gamma Ray Tool and follow Schlumberger`' running procedure per tool specialist. NOTE: If unable to reach a desired deepest depth consult with the Anchorage team and discuss plan forward. 19.POOH while logging at recommended logging parameters as per SLB Memory. 20.Once on surface download and notify the Caelus Energy LLC team on logging results for a plan forward. Scale Squeeze Treatment: 1. Make-up (MU) BHA, Install a Jet Swirl BHA. 2. All BHA items run in the hole dimensions will be measured and posted by Well Site Supervisor and CTU Supervisor in the Op's Cab. 3. Pick up the required lubricator and stab on well. Line up and pressure test the BOP body to 250/4000 psi. Line up to diesel out of SLB pumps truck. Pressure up on the lubricator to equal the Well Head Pressure (WHP) and open the lower FV, count and record turns. Open the upper FV slowly and count and record turns. NOTE: Open bottom valve first and with low pressure differential between wellbore and lubricator, open top FV slowly to reduce any possible erosion of bottom FV gate. 4. RIH not pumping (dry) as deep as possible. ODSN-04 Coil Tubing Scale Squeeze Treatment—version 2 (3/6/2017) • • Oooguruk Wells Group 5. Begin laying in the treatment as per the table below: Down Coil Back Side Coil Zone (MD)ft. Fluid Type Volume (bbl.) Pump Rate Pump Rate (BPM) Max Depth Pre-Flush 16 Scale Squeeze 60 Over Flush 110 17000 — 18400 Pre-Flush 16 Max Rate 0.25 BPM Scale Squeeze 60 While pumping Over Flush 110 not to exceed 2,000 psi down coil 14800 — 17000 Pre-Flush 16 tubing 60 coil x tubing Scale Squeeze annulus WHP simultaneously Over Flush 110 13100 — 14800 Pre-Flush 16 Scale Squeeze 60 Over Flush 110 6. POOH to surface. 7. RDMO SLB Coiled Tubing. 8. Allow a minimum of 12 hours shut-in time for treatment. ODSN-04 Coil Tubing Scale Squeeze Treatment—version 2 (3/6/2017) • • Oooguruk Wells Group Fluff and Stuff Contingency: 1. Make-up (MU) BHA.Install roll-on Coiled Tubing Connector (CTC) (refer to SLB SOP's on CTC installation) and pull test to 10k. Both the CTU and Well Site Supervisor must pre-approve the nozzle selection. 2. All BHA items run in the hole dimensions will be measured and posted by Well Site Supervisor and CTU Supervisor in the Op's Cab. 3. Pick up the required lubricator and stab on well. Line up and pressure test the BOP body to 250/4000 psi. Line up to diesel out of SLB pumps truck. Pressure up on the lubricator to equal the Well Head Pressure (WHP) and open the lower FV, count and record turns. Open the upper FV slowly and count and record turns. NOTE: OPEN BOTTOM VALVE FIRST AND WITH LOW PRESSURE DIFFERENTIAL BETWEEN WELLBORE AND LUBRICATOR, OPEN TOP FV SLOWLY TO REDUCE ANY POSSIBLE EROSION OF BOTTOM FV GATE. 4. Clear all reel depth counters. 5. If injectivity will allow, proceed to RIH with choke closed pumping at minimum rate. Control well pressure by opening choke while RIH if unable to inject. 6. Perform regular weight checks at 2000' intervals. 7. Once reaching 10,000', increase pump rate to between 1.5 and 2.0 BPM and perform weight checks. 8. Begin running in hole at 15' to 20' per minute. Open coil tubing by production tubing annulus valve and pump down coil with seawater. 9. Rig-up LRS to pump down coil x tubing annulus with diesel. 10.Once 11,200' (200' bites) is reached. Pull up hole 50' to disperse sand and ensure sand is strung out and not collecting around the bottom hole assembly. 11.Continue taking 200' bites and pulling up hole 50' while watching run in hole (RIH) weights and pull up hole (PUH) weights. Repeat these steps until desired depth is accomplished or signs that the well is starting to flow. If a break through event happens the well may see a sudden increase in pressure. 12.Be mindful of sudden increases or decreases over time in Coiled Tubing Pressure (CTP) and Well Head Pressure (WHP) which may indicate sand bridging off the flow path to formation and we also need to maintain a close eye on the Coiled Tubing (CT) pull out of hole (POOH) and run in hole (RIH) weights if a significant change is noted pull up hole (PUH) to above the uppermost frac sleeve to ensure sand is dispersed behind the coiled tubing (CT). 13.POOH to surface and notify the Anchorage team on results for a plan forward. ODSN-04 Coil Tubing Scale Squeeze Treatment—version 2(3/6/2017) • Oooguruk Wells Group Post Scale Squeeze Slickline: 1. Record tubing, IA, and OA pressures. Record BHP and Temp. Note on Daily Well Work Report. 2. Receive handover form from Operations to Wells. 3. MIRU slickline. Conduct a pre-job safety meeting with Op,s, well work supervisor, and all associated service companies. 4. Spot slickline unit, hang load cell, and necessary sheaves. 5. Pick up lubricator, toolstring, and -3.84" gauge ring. 6. Make up lubricator. 7. RIH with 3.84 gauge ring to tag Frac isolation sleeve in SVLN at 2304' MDrkb. 8. RIH with 4.5 "GS" pulling tool to pull Frac isolation sleeve in SVLN at 2304' MDrkb. 9. RIH with 4.5 X-Line running tool with prong with 4.5" "FXE" WRSSSV (Record SN#) to set in SVLN at 2304' MDrkb. 10. Purge '/ control line prior to setting with 3 gallons of Hydraulic oil. 11. Set "FXE" in the XXO SVLN @ 2,304' MD. 12. PT control line to 5000 psi. 13. Shear off, POOH. 14. Perform a Closure test and monitor for 15 min. 15. RDMO HES Slickline ODSN-04 Coil Tubing Scale Squeeze Treatment—version 2(3/6/2017) • • ODSN-04 Nuiqsut Production Well Completion FINAL 12-13-2016 I IUpper No. Upper Completion(All equipment must be no less than 10,000 psi rated) MD(ft) ND(ft) 1 Tubing Hanger 34 34 Completion 2 4-%"12.6#/ft C-110 Hydril 521 Tubing I i,' 3 4-%' Halliburton profileTS-8withsin le1/4"x0.049" 2304 1998 Landed with a II 40,000 lbs s/s control line.Cannon Cross-coupling clamps on every joint 1 4 4-%"12.6#/ft C-110 Hydril 521 Tubing Slack Off 5 4-'/:"x 1"GLM#3,KBMG Hydril 521 3315 2478 I 6 4-''/,"12.6#/ft C-110 Hydril 521 Tubing I 7 HES"X"Nipple 3.813" 3428 2528 A8 4%"12.6#/ft C-110 Hydril 521 Tubing 16"Conductor 9 4%"x 1"GLM#2,KBMG Hydril 521 6591 3908 I10 4%"12.6#/ft C-110 Hydril 521 Tubing I Packer Fluid mix: 11 4h"x 1"GLM#1,KBMG Hydril 521 11688 6123 I I12 4-"A"12.6#/ft0-110 Hydril 521 Tubing iiii Inhibited Kill weight 13 HESXN4.5"(3.725"NoGo)-(Max inclination 68 degrees) 11801 6168 I Brine 14 4'/:"12.6#/ftC-110Hydril 521Tubing 4.5" FXE I_�,..�i©:` with 2000'TVD 15 4-1/2"Halliburton'ROC'Gauge Carrier w/Encapsulated n-line to Surface 12655 6384 WRSSSV at I diesel cao 16 4-'/:"12.6#/ftC-110 Hydril 521 Tubing 2,304' MD 17 Bullet Seal Assembly with HLB Self-Aligning Mule Shoe 12766 6395 •'•'.4 I `-'iii Bottom of Shoe 12782 6397 I No. Lower Completion MD(ft) TVD(ft) I 18 Baker 5"X 7"ZXP Liner Top Packer with 15ft Tie Back extension and Flex Lock Hanger 12766 6395 1 11-3/4" 60#L-80 GLM#3 DV 0 GL +i BTC Surface Casing 19 4r"12.6#/ftC-110Hydril 521Liner I 1 @ 5,284' MD/3,339'TVD 20 4-''/,"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers OX Halliburton Swell Packer(4''/"Hydril 521)OD 5.85'-9 meter long oil activated element with I cemented to surface 21 slide on Volant centralizers pin end 13095 6420 22 4-'/="12.6#/ft C-110 Hydril 521 Liner 23 HLB 4-1/2"SLHT BaII Actuated Sleeve(3.009 ball/2.95 Seat) 13270 6419 GLM#2 I 24 4%"12.6#/ft C-110 Hydril 521 Liner GL 9-5/8"40#L-80 25 4-'/:"12.64t/ft Hydril 521-6'Pup with slide on Volant centralizers DV 0 I Hydril 521 Halliburton Swell Packer(4-%"Hydril 521)OD 5.85'-9 meter long oil activated element with 13456 6417 Intermediate 1 26 slide on Volant centralizers pin end 27 4-'/:"12.6#/ft C-110 Hydril 521 Liner I Casing 28 4-'/,"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers @ 10,365' MD/ 29 HailiburtonSwellPacker(4%"Hydril521)OD5.85'-9meterlongoilactivatedelementwith 13621 6421 5,561'TVD slide on Volant centralizers pin end Cemented 500' 30 4r"12.6#/ftC-110 Hydril 521 Liner I above shoe 31 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.925 ball/2.867 Seat) 13967 6419 32 4-'4"12.6#/ft C-110 Hydril 521 Liner 33 4-4"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 1 Halliburton Swell Packer(4Y"Hydril 521)OD 5.85'-9 meter long oil activated element with 34 14271 6421 I slide on Volant centralizers pin end 35 4-%"12.6#/ft C-110 Hydril 521 Liner GLM#1 I 4-1/2" 12.6#C-110 36 HLB 4-1/2"SLHT BaII Actuated Sleeve(2.842 ball/2.786 Seat) 14613 6415 5/16" OV - `' GL J 's Hydril 521 37 4-%"12.6#/ft C-110 Hydri1521 Liner 0 I Tubing 38 4-'/"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Bottom Latch Halliburton Swell Packer(4-%"Hydril 521)0D 5.85'-9 meter long oil activated element with I (U, iipper Completion) 39 slide on Volantcentrallzerspinend 14920 6399 CD Amor'' I il 40 4-'Y"12.6#/ft C-110 Hydril 521 Liner ti 41 HLB4-1/2"SLHT BaII Actuated Sleeve(2.761 ball/2.706 Seat) 15185 6397 ® Rovii42 4-Y="12.6#/ft C-110 Hydril521 Liner TOC Estimated 43 4-'/"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 500'above top of Kuparuk 0 ,,,.;„ .„.4 ,,,,,,,„, #21 6-1/8"Hole TD @19,868' MD/ ® ``` ((//���^6644\���)) 6,364'TVD N� ,- , -O-- -E� - O _ GED _-O_ 59so_ _-69 _ 74 _ 79 -- 7"26# L-80 _ _ _ _ _ _ BTC-M & Hydril 563 26 - - - - - Id>I Intermediate 2 Casing 29 �� -- -- -- -- -- --®-- -- � @ 12,965' MD/6,412'TVD 4-%" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve • 0 ODSN-04 Nuiqsut Production Well Completion FINAL 12-13-2016 I 1 I I Upper Halliburton Swell Packer(4X"Hydril 521)OD 5.85'-9 meter long oil activated element with I Completion slide on Volant centralizers pin end 15452 6395 ( , 45 4,A"12.6#/ft C-110Hydril 521 Liner Landed with 46 HLB 4-1/2"SLHT BaII Actuated Sleeve(2.681 ball/2.628 Seat) 15833 6395 1 40,000 lbs, 47 4-%"12.6#/ft C-110 Hydril 521 Liner 1 I Slack Off 48 4,A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 49 Halliburton Swell Packer(4X"Hydril 521)OD 5.85'-9 meter long oil activated element with 1slide on Volant centralizers pin end 16179 6397 1 50 4X"12.6#/ft C-110 Hydril 521 Liner 1 , 51 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.603 ball/2.552 Seat) 16544 6388 16"Conductor 52 4,A"12.6#/ft C-110 Hydril 521 Liner 1 53 4-'/:"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers I Halliburton Swell Packer(4X"Hydril 521)OD 5.85'-9 meter long oil activated element with Packer Fluid mix• 54 slide on Volant centralizers pin end 16850 6388 ( I Inhibited Kill weight ss 4-X"12.6#/ft C-110 Hydri 1521 Liner Boils 56 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.527 ball/2.477 Seat) 17156 6387 4.5" FXE Iwith 2000'TVD 57 4-X"12.6#/ft C-110 Hydril 521 Liner WRSSSV at I �'-' diesel cap 58 4'/,"12.6#/ftHydril 521-6'Pup with slide onVolant centralizers 2,304' MD I 59 Halliburton Swell Packer(4-X"Hydril 521)OD5.85'-9meter long oil activated element with . s4 I ,.' slide on Volant centralizers pin end 17463 6388 I 60 4X"12.6#/ft C-110 Hydril 521 Uner 61 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.452 ball/2.404 Seat) 17727 6390 I 1111662 4-h"12.6#/ft C-110 Hydril 521 Liner 1 11-3/4"60#L-80 63 4,A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers GLM#3 DV © GL Halliburton Swell Packer(444"Hydril 521)OD5.85'-9 meter long oil activated element with ' BTC Surface Casing slide on Volant centralizers pin end 17993 6393 0 © I @ 5,284' MD/3,339'TVD 65 4,A"12.6#/ft C-110 Hydril 521 Liner I cemented to surface 66 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.379 ball/2.332 Seat) 18255 6395 67 4-X"12.6#/ft C-110 Hydril 521 Liner 1 68 4-X"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(414"Hydril 521)OD5.85'-9 meter long oil activated element with 18561 6394 GLM#2 GL ' 9-5/8"40#L-80 69 -X slide on Volant centralizers pin end DV :O 70 4,A"12.6#/ft C-110 Hydril 521 Liner 1 , Hydril 521 71 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.307 ball/2.261 Seat) 18955 6389 1 .. Intermediate 1 72 4-%"12.6#/ft C-110 Hydril521 Liner h Casing 73 4-'/,"12.6#/ftHydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(444"Hydril 521)OD 5.85'-9 meter long oil activated element with I @ 10,365' MD/ 74 slideonvolantcentralizerspinend 19262 6384 5,561'TVD 75 ftC-1104-''/:"12.6#/ Hydril 521 Liner Cemented 500' 76 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.236 ball/2.192 Seat) 19512 6378 I above shoe 77 4,A"12.6#/ft C-110 Hydril 521 Liner 1 78 4-'/="12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4X"Hydril 521)OD 5.85'-9 meter long oil activated element with 1 79 slide on Volant centralizers pin end 19779 6367 1 80 Pre-Perforated Pup with 4-'/,"12.6P/ft C-110 Hydril 521 Pup above and below 81 4-A:"12.6#/ft C-110 Hydril 521 Liner GLM#1 4-1/2" 12.6#C-110 82 Eccentric Shoe with Float Sub 19855 6363 5/16" OV ''i` OL I fi Hydril 521 Bottom of Shoe 19858 6363 Bottom Latch 0 Tubing o 1 : (Upper Completion) Roc TOC Estimated 500'above top of Kuparuk r0 0 /,,q `...fir 21 6-1/8"Hole TD 4' `. @19,868'MD/ ® `%` 6,364'TVD `. 4 y �O C_ O _ as _ O Ss _cl- ss 7�a _ 7s _ , BTC-M & Hydril 563 26 ® - - - id>, Intermediate2Casing zs •` __ __ __ __ __®__ `$--�__N__N �1--' @ 12,965' MD/6,412'TVD 4-'/z" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve L°J Wallace, Chris D (DOA) From: Keith Lopez <Keith.Lopez@caelusenergy.com> Sent: Wednesday, April 22, 2015 4:20 PM To: Wallace, Chris D (DOA) Cc: •-•• .ii- : DO A • Davi. Hart; Keith Lopez Subject: FW: ODSN-04 (PTD 2130370) &28 (PTD 2131480)IAxOA Comm Diagnostics Attachments: image001.png We have conducted the bleed diagnostics on the ODSN-04 and ODSN-28 IAxOA communication. Results below. ODSN-28 OA was bled and built back the^'650 psi in 6 days. The IA pressure did drop slightly as the OA's pressure was coming back up. The IA was then bled and the OA pressure fell to equalize with it in 2-1/2 days. The OA gas did not test positive for H2S. Over the past couple of weeks we have observed the IA and OA re-pressurizing at a very slow but consistent rate of 10 psi/day. We then conducted diagnostics and monitored the surface lift gas piping and confirmed those closed valves were not leaking by. Our next plan is to get into the well with slickline and remove the orifice valve at 11,287' and replace with a dummy. The most likely case is that we have a leaking check valve in this orifice. This should be completed in the next couple of days. ODSN-04 OA was bled and built back the —650 psi in 28 hours. The IA pressure did drop slightly as the OA's pressure was coming back up. The IA was then bled and the OA pressure fell to equalize with it in 14 hours. Both annuli have remained stable and have not shown any significant pressure increases since bleeding. We do not expect we will need to manage the OA pressure by bleeding until the point that the well requires lift gas. The OA gas did not test positive for H2S. Let me know if you would like any additional information. Keith Lopez SCANNED APP r ii Production Engineer, Subsurface Direct 907.343.2142 I Cell 907.903.5432 Caelus Energy Alaska 3700 Centerpoint Dr I Ste 500 I Anchorage, AK 99503 Keith.Lopez@caelusenergy.com I www.CaelusEnergy.com CECAFUS Fro • Wallace, Chris D (DOA) Sent: -:•esday, April 01, 2015 3:17 PM To: 'keith.lope aelusenergy.com' Cc: Regg, James B ••A) Subject: RE: ODSN-04 & : IAxOA Comm Diagnostics 1 • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday, April 01, 2015 3:22 PM To: 'keith.lopez@caelusenergy.com' Cc: Regg, James B (DOA) Subject: RE: ODSN-04 (PTD 2130370) & 28 (PTD 2131480)IAxOA Comm Diagnostics Attachments: image001.png Keith, Also please include the Permit to Drill (PTD numbers for each well in the subject line—it makes it easier for our crosschecking and filing. rODSN-04 (PTD 2130370)) DSN-28 (PTD 2131480) Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Wallace, Chris D (DOA) Sent: Wednesday, April 01, 2015 3:17 PM To: 'keith.lopez©caelusenergy.com' Cc: Regg, James B (DOA) Subject: RE: ODSN-04 & 28 IAxOA Comm Diagnostics 1 Keith, Your plans including pressure limits for ODSN-04 and ODSN-28 are approved. Thanks and Regards, Chris Wallace 1 Sr. Petroleum Engineer 1 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@alaska.gov 1 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: Keith Lopez [mailto:Keith.Lopez@caelusenergy.com] Sent: Wednesday, April 01, 2015 10:40 AM To: Regg, James B (DOA) Cc: David Hart; Gary Ross Subject: ODSN-04 & 28 IAxOA Comm Diagnostics Mr. Regg, We have two free-flowing producers that we have been watching the IA and OA pressure tracking and would like to conduct some further diagnostics. ODSN-04 We have recognized the IA and OA pressure tracking and conducted bleed diagnostics in November 2014 on the OA. The IA was displaced with lift gas during frac flowback operations in March 2014,though the well is currently free flowing without lift gas. We did not test the OA gas for H2S which would have confirmed that the gas came from the IA. We have not had to bleed the OA or IA to remain under 1,000 psi or 2,000 psi pressure limits respectively. The annuli are currently sitting together at 914 psi with a tubing pressure of 703 psi. ODSN-28 The IA and OA pressures began tracking around November 1st 2014. This is also a free flowing producer without lift gas. We have not conducted any diagnostics at this point and have not had to bleed the OA or IA to remain under 1,000 psi or 2,000 psi pressure limits respectively. The annuli are currently sitting together at 963 psi with a tubing pressure of 632 psi. We would like to do further diagnostics as follows: 1) Bleed the OA down to^'300 psi and test the gas for H2S. Monitor the buildup. 2) Bleed the IA down to^300 psi and monitor. 3) Review data for future remediation planning. Keith Lopez Production Engineer, Subsurface Direct 907.343.2142 I Cell 907.903.5432 Caelus Energy Alaska 3700 Centerpoint Dr I Ste 500 I Anchorage, AK 99503 Keith.Lopez@caelusenergy.com I www.CaelusEnergy.com e CAELJS 2 Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 3 LCI , PIONEER JAN 282014 NATURAL RESOURCES ALASKA AOGCC Letter of Transmittal D` ri- E4D M K BENDER Date: January 27, 2014 FROM TO Shannon Koh AOGCC Pioneer Natural Resources Attn: Makana Bender 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 o Agreement DETAIL QTY DESCRIPTION Well Name: ODSN-04 (50-703-20670-0000) ODSN-04 PB1 (50-703-20670-7000) 2 CD-Roms ODSN-28 (50-703-20676-0000) 14 Well Logs See Details Below We request that all data be treated as confidential information. Thank you. Received by: /? Date: " (2.76/k14 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 Ib- January 27, 2014 QTY DESCRIPTION ODSN-04 (50-703-20670-0000) 1 CD Digital Graphic Logs—Digital Data 6 Well Logs DGR, EWR-Phase 4, ABG, ALD, CTN, Horizontal Presentation(1:240, 1:600) MD; ROP, DGR, ABG, ALD, XBAT(1:240, 1:600) MD; ROP, DGR, EWR-Phase 4, ABG, ALD, CTN Horizontal Presentation(1:240, 1:600) ODSN-04 PB1 (50-703-20670-7000) 4 Well Logs DGR, EWR-Phase 4, ABG, ALD, CTN, Repeat Presentation (1:240, 1:600)TVD; ROP, DGR, EWR-Phase 4, ABG, ALD, CTN Horizontal Presentation Repeat Presentation (1:240, 1:600) MD ODSN-28 (50-703-20676-0000) 1 CD Digital Graphic Logs—Digital Data 4 Well Logs ROP, DGR, EWR-Phase 4, ABG, ALD, CTN Horizontal Presentation(1:240, 1:600) MD DGR, EWR-Phase 4, ABG, ALD, CTN, Reverted Section (1:240, 1:600)TVD • Page 2 RECEIVED • STATE OF ALASKA NOV 2 7 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AI5 la.Well Status: Oil Q . Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 2OAAt 25.105 20AAC 25.110 Development 0 . 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.: 11/4/2013 '• 213-037/313-450. 3.Address: 700 G Street,Suite 600 6.Date Spudded: 13.API Number. Anchorage,AK 99501 3/24/2013 . • 50-703-20670-00-00' 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number. Surface: 3020'FSL, 1092'FEL,Sec. 11,T13N, R7E,Umiat 10/26/2013 ODSN-04 ' Top of Productive Horizon: 8.KB(ft above MSL): 56.2' 15.Field/Pool(s): 2726'FSL,2988'FEL,Sec. 35,T14N, R7E,Umiat GL(ft above MSL): 13.5" Total Depth: 9.Plug Back Depth(MD+TVD): Oooguruk-Nuiqsut Oil Pool 2857'FSL, 1958'FEL,Sec.27,T14N, R7E,Umiat 14,810 MD/6,349 ND' 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 469905.67 Y- 6031136.46 Zone Asp 4 19,868 MD/6,306 TVD' ADL 355036/ADL 389958/ADL 389959 TPI: x- 468043.8 Y- 6041407.7 Zone-Asp 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 463814.45 Y- 6046841.01 Zone-Asp 4 2,304 MD/1,998 TVD 417497 18. Directional Survey: Yes Q 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) 960 MD/815 ND 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,DIR,DDSr,DDS,DDS-HCIM,DGR,EWR,PWD,GABI,X-BAT,ALD,CTN,Geo-Tap N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 109# H-40 Surface 158' _ Surface 158' 24" Driven 11-3/4" 60# L-80Surface 5284' Surface 3339' 14-1/2^ 672 sx,10.7 ppg PF'L'; BTC-M 629 sx,15.8 ppg Class'G' ✓ L 9-5/8" 40# H 1 5105' 10365' 3260' 5561' 11-3/4" 178 sx, 15.8 ppg,Class'G' 7" 26# tivHYD Surface 12965' '� Surface 6412' 9-1/2" 336 sx, 15.8 ppg Class'G' V 4-1/2" 12.6# HYD521 12766' 19858' 6,395' 6364' 6-1/8" Uncemented 24.Open to production or Injection? Yes ❑ No ❑ 25. TUBING RECORD If Yes,list each interval open(MD+TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MID/TVD) Size and Number): 4-1/2", 12.6#, 12,802' See Attachment,pg.3 C-110,Hyd 521 1 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. X114 /I L( See Attachment, pg.2 Was hydrauUc fracturing used during completion? Yes❑ No n a , , DEPTH INTERVAL ND) 'AMOUNT AND KIND OF Nl7ii tKIHL'USED ick . Freeze Protect w/150 bbls diesel 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(torr): Press. 24-Hour Rate 01. 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No Q if Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. None RBDMMS MAR 2 0 HI& Form 10-407 Revised 10/2012 ?K Lilt('I/1 CONTINUED ON REVERSE 74 Li,(S/Submit original only G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD _Well tested? Yes [ Ngo If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed, Permafrost-Top 874' 853' and submit detailed test information per 20 AAC 25.071. Permafrost-Base 1834' 1668' Top West Sak 2915' 2305' Cretaceous Tuffs 4336' 2914' Brookian 2B 7552' 4333' None Top Torok 9354' 5121' Top HRZ 11,316' 5967' Kalubik 11,840' 6182' Top Kuparuk C 12,055' 6253' BCU 12,577' 6373' Top Nuiqsut 12,870' 6403' Formation at total depth: I I 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 Email: alex.vaughan(a)pxd.com Printed Name: Alex Vaughan Title: Sr. Drilling Engineer Signature Phone: 343-2186 Date: /1/Z7// Well Name/Number:OI-O4 ' Pe it To Drill:213-037/313-450 Prepared By:Kimberly Pape,343-2130 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-Altemating-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 10/2012 ODSN-04 Nuiqsut Prc iction Well Completion FINAL 11-4-2013 - WP06 i i jYo. Upper Completion(All equipment must be no less than 1.0 000 osi rated) MD(ft) TVD(ft) 1 Tubing Hanger 43 43 I • 2 4-34"12.6#/ft C-110 Hydril 521 Tubing "`" ""' 3 4-34"Halliburton'XXO'SVLN w/3.813""X"profile RTS-8 with singlel/4"x 0.049" 2304 1998 I s/s control line.Cannon Cross-coupling clamps on every Joint 4 4-Y"12.6#/ft C-110Hydri1521Tubing _ I 5 4-34"x 1"GLM#3,KBMG Hydril 521 w/SOV 331; 2478 i 6 4-Y="12.6#/ft C-110Hydril521Tubing 7 HES“r Nipple 3.813" 3428 2528 °i ' 16" Conductor 8 4-Y"12.6#/ft C-110 Hydril 521 Tubing I 9 434"x 1"GLM#2,KBMG Hydril 521 w/DV 6591 3908 i 10 434:"12.6#/ft C-110 Hydril 521 Tubing igiii Packer Fluid mix: 11 4-/"x 1"GLM#1,KBMG Hydril 521w/DV 11688 6123 I €i Inhibited Kill weight 12 4-Y"12.6#/ft C-110 Hydril 521 Tubing I Brine 1.3 HES XN4.5"(3.725"NoGo)-with RHC Plug(Max inclination 68degrees) 11801 6168 with 2000'TVD 14 4-'/:"12.6#/ftC-110 Hydril 521 Tubing "'"""I ©i iiiiS 15 4-1/2"Halliburton'ROC'Gauge Carrier w/Encapsulated a-line to Surface 12655 6384 \ � diesel cap 16 A"12 C-110 Hydril 521 Tubing E I17 Bullet Seal Assembly with HLB Self-Aligning Mule Shoe 12766 6395 Bottom of Shoe 12782 6397 I NG. Lower Completion MD(ft) TVD(ft) 18 Baker 5-34"X 7"ZXP Liner Top Packer with 15ft Tie Back extension and Flex Lock Hanger 11-3/4" 60# L-80 s GLI BTC Surface Casing 19 4-34"12.6#/ft C-110 Hydril 521 Liner • @ 5,284' M D /3,339' TVD 20 4-34"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 7 ' x i 21 Halliburton Swell Packer(4-34"Hydril 521)OD 5.85'-9 meter long oil activated element with 13095 6420 cemented to surface slide on Volant centralizers pin end _77 22 434"12.6#/ft C-110 Hydril 521 Liner liiii- 23 HLB 4-1/2"SLHT Ball Actuated Sleeve(3.009 ball/2.95 Seat) 13270 6419 24 4-A"12.6#/ft C-110 Hydril 521 Liner GL 9-5/8"40# L-80 25 434"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Hydril 521 26 Halliburton Swell Packer(434"Hydril 521)OD 5.85'-9 meter long oil activated element with 6417 slide on Volant centralizers pin end iii'I Intermediate 1 27 444"12.6#/ft C-110 Hydril 521 Liner A I1111 Casing 28 4-34"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers @ 10,365' MD / 29 Halliburton Swell Packer(434"Hydril 521)OD 5.85'-9 meter long oil activated element with 13621 6421 slide on Volant centralizers pin end 5,561' TVD 30 4-34"12.6#/ftC-110 Hydril 521 Liner i Cemented 500' 31 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.925 ball/2.867 Seat) 13967 6419 I above shoe 32 4-Y"12.64/ft C-110 Hydril 521 Liner 33 4-34"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(434"Hydril 521)OD 5.85'-9 meter long oil activated element with34 14271 6421 slide on Volant centralizers pin end 35 4-'/="12.6#/ftC-110 Hydril 521 Liner 36 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.842 ball/2.786 Seat) 14613 _ 6415 4-1/2" 12.6# C-110 37 4-i"12.6#/ft C-110 Hydril 521 Liner _ NIHydril 521 38 +4-! 12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-34"Hydril 521)OD 5.85'-9 meter long oil activated element with 0 ( Tubing 39 slide on Volant centralizers pin end 14920 6399 ( (Upper Completion) is ® .R°0. TOC Estimated 500'above top of Kuparuk :.01\/` ..: e • z, 6-1/8" Hole TD @ 19,868' MD/ 33iell PaA 111 ck •er9 6'.364' TVD 82 11 - o 2 BTC-M & Hydril 563 i j i 1 I 1 Intermediate 2 Casing 29 • aD @ 12,965' MD /6,412' TVD 4-W Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve FINAL 11-4-2013 . ODSN-04 Nuiqsut Prc ction Well Completion WP06 I P14., Lower Completion MD(ft) TVD(ft) i40 4-1"12.6#/ft C-110 Hydril 521 Liner 41 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.761 ball/2.706 Seat) 15185 6397 I 42 4-1"12.6#/ft C-110 Hydril 521 Liner 43 41"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(41"Hydril 521)OD 5.85'-9 meter long oil activated element with '•I":'k 16" Conductor slide on Volant centralizers pin end 15452 6395 45 4-'/,"12.6#/ft C-110 Hydril 521 Liner 46 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.681 ball/2.628 Seat) 15833 6395 Packer Fluid mix: 47 VA"1z.6#/ftC-110 Hydril 521 Liner iiiiiii Inhibited Kill weight 48 4-%"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers I Brine 49 Halliburton Swell Packer(41"Hydril 521)OD 5.85'-9 meter long oil activated element with 16179 6397 ;;;;; I 3 with 2000'TVD slide on Volant centralizers pin end C;;; ` 50 4-'/::"12.6#/ft C-110 Hydril 521 Liner ) Mt I diesel cap 51 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.603 ball/2.552 Seat) 16544 6388 "• I 52 4- 12.6#/ft C-110 Hydril 521 Liner '"""" "53 4-1"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Halliburton Swell Packer(4-1"Hydril 521)0D 5.85'-9 meter long oil activated element with Mit 54 slide on Volant centralizers pin end 16850 6388 i 55 4-1"12.6#/ft C-110 Hydril 521 Liner 11-3/4" 60# L-80 56 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.527 ball/2.477 Seat) 17156 6387 0 GL I BTC Surface Casing 57 4-'A"12.6#/ft C-110Hydril 521 Liner I @ 5,284' MD / 3,339' TVD 58 4-A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers O x 59 Halliburton Swell Packer(4-14"Hydril 521)OD 5.85'-9 meter long oil activated element with 17463 6388 cemented to surface slide on Volant centralizers pin end I 60 4-'/="12.6#/ftc-noHydril 521 Liner lITEr 61 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.452 ball/2.404 Seat) 17727 6390 62 4-A"12.6#/ft C-110 Hydril 521 Liner GL 4- 9-5/8"40# L-80 63 A"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers OHydril 521 Halliburton Swell Packer(41"Hydril 521)OD 5.85'-9 meter long oil activated element with 17993 6393 slide on Volant centralizers pin end _ Intermediate 1 65 VA"12.6#/ftC-110 Hydril 521 Liner I Casing 66 HLB4-1/2"SLHT Ball Actuated Sleeve(2.379 ball/2.332Seat) ^ 18255 6395 I @ 10,365' MD/ 67 4-1"12.6#/ftC-110 Hydril 521 Liner 68 4-1"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 5,561' TVD Halliburton Swell Packer(4-1"Hydril 521)OD 5.85'-9 meter long oil activated element with Cemented 500' 69 slide on Volant centralizers pin end 18561 6394 above shoe 70 4-1"12.6#/ftC-110 Hydril 521 Liner 71 HLB 4-1/2"SLHT Ball Actuated Sleeve(2.307 ball/2.261 Seat) - 18955 6389 I 72 4-1"12.6#/ft C-110 Hydril 521 Liner 73 4-34"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers 74 Halliburton Swell Packer(4-1"Hydril 521)OD 5.85'-9 meter long oil activated element with 19262 6384 slide on Volant centralizers pin end 4-1/2" 12.6#C-110 75 4-A'12.6#/ftC-110 Hydril 521 Liner Hydril 521 76_HLB 4-1/2"SLHT Ball Actuated Sleeve(2.236 ball/2.192 Seat) 19512 6378 '"": GL iEiEii 77 4-1"12.6#/ft C-110 Hydril 521 Liner CI i€ Tubing 78 VA"12.6#/ft Hydril 521-6'Pup with slide on Volant centralizers Oil Ihi.il i (Upper Completion) 79 Halliburton Swell Packer(4-1"Hydril 521)OD 5.85'-9 meter long oil activated element with 19779 6367 slide on Volant centralizers pin end 80 Pre-Perforated Pup with 41"12.6#/ft C-110 Hydril 521 Pup above and below _.R 81 41"12.6#/ft C-110 Hydril 521 Liner ® OC ii!N r:=:=:_: 82 Eccentric Shoe with Float Sub 19855 6363 TOC Estimated Bottom of Shoe 19858 6363 500'above top of , ] Iiiiii Kuparuk :.0��, „. 'II `1 21 6-118” Hole TD @ 19,868' MD/ ® 34 ease 59 T 79 CDO 6974 6,364' TVD T ■T 1 1 1- 1 t 7" 26# L-80 , _ _ _ _ — _ — — — BTC-M & Hydril 563 26 - - - - _ _ _ _ o Intermediate 2 Casing 29 ■ ■ ■ -' 1 1 1 1 ■ 1 Bo @ 12,965' MD/6,412' TVD 4-'/z" Hydril 521C-110 Liner with Halliburton Ball Actuated Sleeve Pioneer Natural Resources Alaska Inc. ODSN-04 Page 2 Form 10-407, Well Completion or Recompletion Report and Log Box #24 - Attachment Open to production or injection 4-W, 12.6#, C-110, Hyd 521 Uncemented Liner 4-1/2" SLHT Ball Actuated Sleeves w/seats: MD ND 13,270' — 13,273' 6419' — 6419' 13,967' — 13,970' 6419' — 6419' 14,613' — 14,616' 6415' — 6415' 15,185' — 15,187' 6397' — 6397' • 15,833' — 15,836' 6395' — 6395' 16,544' — 16,547' 6388' — 6388' 17,156' — 17,158' 6387' —6387' 17,727' — 17,729' 6390' —6390' 18,255' — 18,257' 6395' —6395' 18,955' — 18,957' 6389' —6389' 19,512' — 19,515' 6378' —6378' Perforated Pup joint w/6, 1/2" holes: MD ND 19,811' — 19,816' 6366' — 6365' Pioneer Na«,ral Resources Alaska Inc. ODSN-04 Page 3 AOGCC Form 10-407, Well Completion or Recompletion Report and Log Box# 25 - Attachment Packers ZXP Packer w/ 15' Tie-back Extension MD ND 12,766' 6,395' HES OM Swell Packers MD ND 13,095' - 13,124' 6,420' - 6,420' 13,456' - 13,485' 6,417' - 6,418' 13,621' - 13,650' 6,421' - 6,422' 14,271' - 14,300' 6,421' - 6,422' 14,920' - 14,950' 6,399' - 6,399' 15,452' - 15,481' 6,395' - 6,394' 16,179' - 16,209' 6,397' - 6,397' 16,850' - 16,879' 6,388' - 6,388' 17,463' - 17,493' 6,388' - 6,389' 17,993' - 18,022' 6,393' - 6,394' 18,561' - 18,590' 6,394' - 6,394' 19,262' - 19,291' 6,384' - 6,384' 19,779' - 19,808' 6,367' - 6,366' Pioneer Natural Recourses CASING&CEMENTING REPORT Lease&Well No. 50-703-20670-00-00 ODSN-04 Date 30-Mar-13 County USA State Alaska Supv. CASING RECORD urface casin•. TD 5294'MD/3345'TVD Shoe Depth: 5284'MD PBTD: Casing(Or Liner)Detail Setting Depths No.of Jts. Size Wt. Grade THD Make Length Bottom Top Shoe/jt F.Collar/jt L Hanger landing jt Totals Csg Wt.On Hook: Type Float Collar: Halliburton No.Hrs to Run: Csg 1M.On Slips: Type of Shoe: Halliburton Casing Crew: Fluid Description: Liner hanger Info(Make/Model): Liner top Packer?: _Yes X No Liner hanger test pressure: Centralizer Placement: one per joint from TD to 1834'(base of Permafrost) CEMENTING REPORT Preflush(Spacer) Type: Tuned Spacer Ill Density(ppg) 10 Volume pumped(BBLs) 100 Lead Slurry Type: Permafrost L Blend Yield Ft3/sack): 4.36 ft3/sk Density(ppg) 11.1 ppg Volume (BBLs/sacks): 548 bbl 672 sacks Mixing/Pumping Rate(bpm): 5bpm Tail Slurry Type: Premium G Blend Yield(Ft3/sack): 1.18 ft3/sk Density(ppg) 15.8 ppg Volume (BBLs/sacks): 132 bbls/629 sacks Mixing/Pumping Rate(bpm): 4 bpm w Post Flush(Spacer) y Type: Seawater Density(ppg) 8.5 ppg Rate(bpm): 8 bpm Volume: 20 bbl.' LL Displacement: 05 v Type: Mud Density(ppg) 9.5 ppg Rate(bpm): 10 bpm Volume(actual/calculated): 572/566 ( r FCP(psi): 1070 Pump used for disp: Rig pumps Plug Bumped? X Yes No Bump press • Casing Rotated? Yes X No Reciprocated? Yes X No %Returns during job 100 Cement returns to surface? X Yes No Spacer returns? X Yes_No Vol to Surf: 238 bbl cmt V Cement In Place At: 19:00 Date: 3/30/2013 Estimated TOC: —Surface Method Used To Determine TOC: Cement sample taken&weighed @ surface Preflush(Spacer) Type: Density(ppg) Volume pumped(BBLs) Lead Slurry Type: Yield(Ft3/sack): Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): Tail Slurry Type: Yield(Ft3/sack): a Density(ppg) Volume (BBLs/sacks): Mixing/Pumping Rate(bpm): N Post Flush(Spacer) ' o o Type: Density(ppg) Rate(bpm): Volume: ti Displacement: Type: Density(ppg) Rate(bpm): Volume(actual/calculated): FCP(psi): Pump used for disp: Plug Bumped? _Yes No Bump press Casing Rotated? Yes _No Reciprocated? _Yes_No %Returns during job Cement returns to surface? Yes_No Spacer returns? Yes_No Vol to Surf: Cement In Place At: Date: Estimated TOC: Method Used To Determine TOC: Remarks: C C .. C O ❑ ❑ ❑ M o O 0 O p m m m m C) > N O N m m d U d U d U dri, ii Cs1N E N a3 M n (n N 2 n 'C r t ca 13 - C O 7 m m CG -0 3 3v) C. m m Enmo d N m v, m ' N m ti m N m N N N N 0 o CO N a m (a t0 ca O C N Q C o U 0—U CO o 0 n 2 O n o x x v0 0 Q H H H H a a a a C Y C Y C y c C = .K C O 0 O 0 CO F- O - V CO CO N CO CO O O 0 O) cW c O M N M4 D) C) 6 COO N Ni c co m a0 co al V V co co N- O O) CO O CO CO m N m Y Cn Y 1- 0) Y U) U) U) 1- .- •- .-- N N N m Y l- ( c c = U) .. U) U) U) U) L. c U) N E w E E. E w E m co m - m c m M U) O) C- Q r O) f- O N V CO CO N CO CO O c N N- O O M N C`') V CT M U) CO O N U) ❑ m ❑ m V 0 m co V V CO CO r O CO CO O CO 0 m 0 o Y o Y O Y U) U) U) '- a- r a- N N 0 Y a n c n U) US Ui Ui L L ' n U) o H E H E 0 E H z z z z m m m o, c cc . O c CD UN U ) ) CD O V N V N- O (D c CO N M N ,- co N I� (D N O CO CO O VCT V) CO tO N CO r 0 U) . r E. x CO V CO CO E N 0. J ) J W a a a a M Na- N N N CO o yw - CO E HH H H E n N n n 0) O O O 0. ,^ V) 0V U) U) CO CO N Nm -0 -0 -0 -0 'O "O "O "O M m = E E � d ca m ca m m ca ca ca o m L Q) • 0. L N `) `) `) `) N 4)(� H H H L L L L L L L L H RS H H H ~ ~ ~ ~ ~ ~ ~ N N ~ N N H N U fn co N N N co co N N N N N N (n N N U) = N U) U) L N N 2 N 2 2 N - , d _ mi. m 7 7 7 7 7 7 7 >,17 �. 7 > >. Si'17 > L L L m m m m m m m S S m S = I 0. a a a o o a, N ❑ E a -E ❑ S ❑ t m m - d c c c 0 0 0 m v v v v O cc 0 pCo (j C 0 0 C 0 0 0 0 0 0 0 0 CO OE O O CO CO CO CO CO CO CO 00 N CO CO CO ,- CO CV OS N J J J J J J J J J J J J N J CO O O 000000000000 CO O N 0 CO O O O O O O O O O O O O O 'k- ,- Z m M Z O6 6 6 6 6 6 6 6 6 6 6 k O a O a CO CO (O O CO CO CO CO CO CO CD CO a V d m m g m g m m S Er ce O cc N N N N N N N N N N N N CC' O N- r r r 0 r N- 0 N- N- 0 0 0 U) c c(0 h r r 0- - n N- 0- 0 0- 0 E N o V Q 0 0 0 0 0 0 0 0 0 0 0 0 O O U) - _ - C') .. co V V V V V V V V V V •V 'r 00 O c c c M CO CO CO CO CO CO CO CO CO M CO U) U) C 0 07 0 Y O O O O O OO w ..UZO O O O N - m O vo ea —M ZS M c•-)sO p w A N to • N eI N �J W +t' C 4' N NtS N N /�1 �a a u o Q1 LL W .0 d N M 2 M d •la - M y d 0 a 5. O e. O .. ❑ « O .00 = O X OJ E C y E E C a E c S c c C m 3 0 E Q co 41 m .� m C U a •- N U . U 'o o N 0 d 50 DCC ? U C9 A n m = a ats .E.' rn V a ata ro P. _ an d c 0.) +.- 0.) U > c N a°� rn �� C F— E C ° E •y Q_' E o. .N E .N •) > 'H N N 9 CC E r1 Q ? c E •o co E co > ca E O = m m m co Q m o Q m c0 E m 0 p M O O p LI ca N 2 2 n M N a- O a- CN CD T1) v d E CV 0 0 or z rC Ct. d U) e. P.' N EaI a a H F n n x co O Lo Co Lf) co N LO 0 V N N- O 0 00 V O CO O V O N 6) N N- M N- r "Li LC) O O O V Ln CO O O N L() c co N M LO I- O N CC) Ln V co 6 C`) m co co co N co N- N- N- LO Co CO m co O O O O N O N CO N N .1- X- r r N N N N N CO CO M CO CO oL Y N M M M M M M M M M V V V V t() LC) LC) O O 0 0 0 0 0 0 0 0c N N N N N N co- M cococoM M M E m E m C m co N 6) CO O LC) co U) O N L() O V N I� • m 00 V CO 00 0 V O N O N r CO r (O V LC) N O O V N- CO 6) 6) N a0 N M Ln N: O N LC) LC) V co O m N co co co co N-N N- N U) CO 0 m 7 N O O O O N O N M N N Y N N N N N M CO M M 0 Y N CO M M M M CO CO CO CO V V V C L) L) f) C) O 0 0 0 0 0 0 0 0 m z N N N N N N co- co- M co- M M M n E 8- 1- H 0 1- z Z m c O N O 0) N- CO N M LC) N V N V CO V LO N 6) N O CO N LI) 0 0 6) 6) N Ln O CO M V CO V V W V CO N r CO N N V LO N N 00 4 CO V V Z"4 N r a O O M r OV C) M C'') N 6 M r N r C) C`) CO M 61 c') r M E a)O O c N r r C) r r r Q. a) Ln 2 N- CI) Ce a r r r CO rcsJ . 6) r r r r r in r r r N r r r `"" o U) N W E - N F N E to O) = (00_ co w of r, C E d L L Y/ n_ n U lo- N N N N N N N N N N N N N F LO LC) LC) LC) LC) LC) LC) LC) LC) LC) LC) LC) LC) 'O "O 'O 'O "0 'O '6 'O 'O "O ' "0 "O m O > >' >, >, >' >, >, >+ T >, T >+ >' r I I I 2 2 11111111 n m cc U = O b O a) a) m CO 2 0 0 0 0 0 0 0 0000 000 CO O O O O O 0 0 0 0 0 0 0 0rC� Cb W CO W W W CO C17 W W C6 co W 0 . . . . . . r r r r r r .l- -I J J J J J J J J J J J J J N U U U U U U U U U U U U U U O O O O O 0 0 0 0 0 0 0 0 M O 0 0 0 0 0 0 O O O O O O O O O O O O O O O O O O O O O Co CO CO CO CO CO CO CO Co Co CO 0 Co Co --O6 O O O 0 0 0 0 0 0 0 0 r "N Ni N N N N N N N N N N N N qn V V V 4 V V 4- 4 V V V .0 r r r r r r r r r r r r r r S m g o D •L() L() LC) LC) LC) LC) LI) L() L() L() LC) L() LO CC CO CO CO M CO CO CO CO LC) CO CO CO CO CO CO M CO CO M C') CO C') C') 01 CO CO CO LI) LC) Ln U) LC) LI) U) CO U) U) Ln LO E 00 CO 00 CO CO O CO CO CO CO CO CO CO E 6) 61 6) CO 6) 6) 6) 61 CO 61 61 Q7 00 6) of Co co W W N W CO oD 00 W W W M M M M M M CO M M M M M M M oo co • oo . O co O 00 ooO O 0O O CO - 6) 6) C 6) O) O1 co O) O) o m Coo co M M M M M M M M M M M M M c 0▪0 c I- 4 4 4 r 4 r 4 r 4 r 4 4 4 CO W Q O O CO O) CO D) 01 O O Q) Q) Q) Cr) N O O V V V V V V V V V V V 7 7 r U O O 0 F�r , CC ZO Z O M Laj 0 CI co 2 co LA vZ. N Cr) Q d 0. O J CU 'Cr) N N £ 1� w _ O X CO N N •N O N O O O 43) m F- X J CL fL0 fL0 L V Mcu _ d _ J a`� c a N 11 o w e w e y c e` 0 U U U O Q RI °) O) 007 J m •p O p C� l0 p U p U N v- U _ N Z N 8 co _ _ _ '. _ cc Z x m m e -, y '' CT -6 -, CT "" 0) m v _ cNi - O > O G. g c g D _ 2 cc t 0• 0) 2 0) c U 0) g. 0) 0,5 c 0) 0 0 0) 0 o m o n o �� _se cO n c ct c c c o e c -3 u1 Co c -3 -1 c -) n -) �— M N d U .O .N C4 .y f0 f0 •y i0 •y N N d' E N rn N 4-= N ^ Q r mLO > m S o m 0 0 m o m o a s 0 '-> > o X o 7 > > Co 7 '-> > Z 7 • 1 I I c O O M • O 0 r O m 0 N M N r a- 0 N N m m D v mN D S M N c m a r 0a -. ) 0. m a) 0 w m N 16 E N m N C c O n n (r Cr I- I- n n S C 2 v ✓ oo (o N N O 1� CO r CO (O rT LU N 1` Q) V co N CO ❑ V N- V CO O) 1— O r M V W V CU I- N co N (n O M O (o CO O .,-- i O) N (o O a)N- O) C)) O N- co O) O (U O O V (O (O I,- (o (fl c0 r co Ci M V O V co co co co co O co Co 1` 1` CO CO CO CO (O CO CO I� r r N. N- rn Y O O c0 CO C. (o C. N N N N N N N N N c (o (o N E r r r r r r r r r r r r r r r r r E mN m CO (o N N O I- CO CO Ln O N r CO V (1) N C O) V h- V CO M 1� O N- M 4 c0 V CU 1- N O N O O M O (o Co O co O N O O m V N. CO CO 0 N- CO O 0 O 0 0 V (O CO N- (o CO CO I,- ❑ aj M M V O 4- 4 V (o Ln (o CO CO CO CO I� N. CO CO CO (O (O CO CO 1- r r N. 0 Y O O M (O (D (D (D N N N N N N N CV- LO CO 0 a r r r r r r r r r r r r r r ,- r o. H E F- 0 Z m c_ N O N W (f) O N aD W (o N M O O V O M 11-- CO N V N CO 1- CO O 1` - CO CO (o CV (o O V CO (O r LU O CO V (O N I- N N tO C U) M O (o O M O M O M M co M V M n v N N x O M co 0 U) Qd M r r r r r r r r r J ‘r- co CD re n r r r r r r r r r r r r r r r r r r r O O N N a O V co N o r co d M a) E N m n m = Co a C ) co a DO D a C N N L F H _ Vi o oa M c') CM U F- 1-- CO CO N (o (O V) 07 .1- t- L... L... ... ..... -, "O "O CO r I- 2 2 2 c0 a cc v (n = c .. a o d m 0 O 0 O O 0 0 0 0 O O O 0 0 0 0 0 O O O O m Cj M (j O O O O O r r r r r r r r r r r r r r r r r V- r' r CO CO CO CO CO U U U U U U U U U U U U U U U U U U U U U o J J J J J O O O O O O O 0 0 0 0 0 0 CD O 0 0 0 0 0 0 N- O O O O O CO CO CO CO CO (O CO CO CO CO CO CO CO CO CO CO O (O (O CO (O N O O O O O N N N N N N N N N N N N N N N N N N N N N CO "co O co O O .0 r r r r r ,— r r r r r r r r r r r r r r r a_N N N N (V S a? a a S .- c0 co co CU 00 co (O Cd 00 c0 (o CU 00 CU 0 0 0 0 0 0 0 CC CO Co CO CO CO CO 10 CO (O (O CO CO (o (o Co N Co (O (O CO CO CO CO CO CO CO N- N N. CO O CO O CO O CO 0) O O I. O CO O CO CO CO O 00 CO CO C(N N N (N N (N N N co' M M M M M M M M M M CO M M M M M M M M M CO CO CO M CO ❑ O O) O O) O O O O O O CO v O o) O O O O O CO V r n r N r N-- CO M CO CO CO CO CO C/ 0101 M N- M M M M M M M N r N TE I� n r N- N h r t` V N- r N- N. r r r V O C W o Y o 1.x..1 cc Z m . 1+j O o caca CDC COCD (n O 4) < 'X N '0 Z w O O 0 O E O a, N 2 CO m c N c c Rg ( cu ( m ( ( ° 12 m o � d 2 c •o c Ta_ 'oO cl Z ( c c • c c c c • c m c • c d � n 'N co a)- rn oo a) o o m o n o • co o CD o • a3 o o c M = c M -I c Z c M -) c ' N o o C c 0. N N N N i `" o S s m N 2 2 N M N T". O .- N N Tt m U m a NI rg IL' 7c3 a Mcn C CD a CU CI 0. rt Q a, N a, (I) my @ a` ) o N m.N "O c O_)N 8''OCU a n LT LS H H a. a > > c 2 . -2 C W 'I- O 0 st O NI- CO N LO N I- N CO LO st r CO N N- sr o) sr CO CO M CO M LO c N O LO s N- 4 st W W LO O N N- N CO LO LO C) N- C) O C)Cb Co Co m 6) D) O O O co co a) N N CO LO N- N- CO V V LO CO Cp 0 N Y CO Cr) Q) co Y N- N- CO co co O O 0 r r r N N N N st st V st st CD CD CO -N N N c 5 N N N N N M M M M M M M M M co- co- co- M coM M M M E r r r N .g r r r r r r r r r . . . . . . . . . . .- r r rm N CO R (TCO st " sr sr. 6) sr CO N LO N C` N CO LO 'I' r CO N r` sr Cr) -4- co CO co . M . O M CO N O <ri0 r co V st CO W L0 O N CO N Cb LO LO O 0 M m Co co CD 0 m CO O N O O O 0 0 0 N N M CO (N.N N- CO st st LO W CO O Y CO CO M 0 Y � � N- M CO CO 0 0 0 r .-- r N N N N Sr V sr si st (D M E N N N m s N N N CsN N C`') M 05M M coM M M M M M M M coco- M a r r r c 2 r r r r . . . . . H .E H r r r r r . . . . . r r r r 0 z LT c LO O N r a> r Cn N- N CO 0 N Cr) r CD CD CO CP LO 0 N N- CO sr O O CO r O) .- sf L r CO M co Ln LO LO CO O) CO LO CO st CO LO LO CO CO CO Ln t 0 N st N- M CO Ln r CT st CT M 4 N st O Ln r O 4 N- LO r x CO N h N r r LU N Q. c c N r r W IY NO_ r N r E r r r r r C` r r r r r co r r r r r r r C`) r r E sr E N N = O 1 C Cn Ln 00 C m m °� L N H CU 0 N N N N N N N N (71 N N N N N N N N N N N N N N U C 2 2 Ln Ln Ln Lo Lo LD Ln Ln to Ln LL7 Ln Lo Lc) Ln Ln Ln Ln Ln Ln Lo Lo Lo U U U ca `o o `a o a o o o o o � o a a -o -o -o H H H z= >' >' >' > >, >, >, > >, >. >. >' >. >. >, >' >. >. >. >, >. >. >. CO CO CO .. 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 a, 0 c c = co = c aL o m C,.) m 0 O O O O O O 0 O O O O O O O O O O O CD 0 0 0 C.0 0 0 b W CO 0 0 r r r . . . . . r r r r r . . . . . r r r r J J J N U U U U U U U U U U U U U U U U U 6 U U U U U 0 0 0 co 0 0 0 0 0 O 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 O O O0 CD CO CO CO CO CO CO CO CO CO CO CD CO CO CD CO CO CO CO CO CO CO CO CO O (D r N N N N N N N N N N N N N N N N N N N N N N N N N N .0 r r r r . . . . . r r r r r r r r r r r r r r Ta0 0 CD CO CO LO O O 0 CO CO CO CO CO CO CO CO CO CO CO CO CO CO Cr) CO CO CO M (N CV (N C) CO Ln N Lc)CD Cr) LO Lf) Lf) Ln Ln Ln Ln Cr)Lr) LC) LO LO Ln O Ln LE-) Ln Ln N N N c 0 sr N Cr) m 0 0 0 O Cr) O) Cr) (P Cr) Cr) Cr) Cr) 0 Cr) O) Cr) Cr) O CO• •CO CO• S C') <4 <4 CO M M M M M M M M M M (.6 M M M M M M M M N- r N- N V N V N N N N N N N N N LC) N N N N CD N N N N O co n ■ _ Cr)(f) 0 m O O N LO LU LO Cr st st st st sr st st st L st st st st NI- st s. sr U0 o 0 I-0 cc Z2O M o0 r N Zr)iti 'a5 Y O O J r O N N 7 O N N LL m N ] Y d 0_ d N d .tiZ d c co d Cr JcX c a 'Cr. > r:it ❑ y ` J ❑ _ rn ' c CcN N a Yo N ; N o 'O m O 1 N 34 •O NOQJ ? E C mo92 W CU O 0 E > 15 oc = (n Nx S> z ' n alco to cU C rn n a NQ ' N c -, ti N a m if_1.1 iO ifpm � m O o°6 m Y O_ 0_ aYOc 0_ Y1, .1 cm mNtQLNm c c c co m % cmcYcWme 17, c .i5W W a E N c m O0 m 0 c o m o N C m^ Q ? o = 15 • " I i co o 0 O N m N M N r 1- 0 O N ! N Nii MC 'L w 0. a t 0 0 rt aCO fo I 0 0- n s co •a) co C .M co f� co Co coV co (o C co O LO O CO O) M U) O r V (O l'-- 6 O V V N N- O) V h M 0 0 U) V CO M U) O) N- M O O V M O V r Co V a- U) Ed'U) U) N- U) CO I CO CO LU CO r C) C) N C) N O N LU LO t` f` CO Co O M V LO CO CO Y (0 '(O CO Q) m O) O N N N M M CO LO CO CO (0 CP Cr) Cr) Cr) O O) - N V V V V V C) M M M C`') C`') M V V V V V V V V V V V V V V V V U) U) co- U) co- LO LO LO LO E m co co co co V (D M r M Co CO V W CO O CO O U) O CO O CO U) O h V M O O V V N f� (A V M O O U) V W M U) O n M O O V M O V W V CO N LO LO r LO CD CO CO LO CO f- O O N CP N O N LO LO N- N- 00 CO O M V U) CO Y M CO M CO Cr) D) O O) N N N M M CO U) CO CO CO O) 0) O) 0) Cr) C) x- A- N V V 'Cr V S C') C) co M M C) co- co- V V V V V V V V V V V V V V V V U) U) U) U) U) U) U) U) 0 a- 0 f- N N (O M CO O M N (DON f- N O) O O (0 CO V O N CD O M N O CO CO U) O N O U) CO M x- CO U) f. CO CO U) LU f� M M M U) N V (0 U) U) LO N V N U) CO f'• CO U) 0 O t O V O) W V N V M LO f- O) V OV V N V r U) f- T V O) O V N V CO U) r P V O N x- lx... � N N a- 1- CV a- N N rCD) r .- N N O J w,. W Ce a- a- N r ,- ,- r ,- r e- N r a- '- ,- ,- N LO x- 1- x- (fl a-- e- c- r- RS 4 co E N d O) = a u) of C N n_ U H N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N U) U) U) U) LU U) U) U) U) U) U) U) U) U) U) U) U) LC) LO U) LU LO LO U) U) U) U) U) U) U) LU U) ` ` 0 ` 0 `ao ` aaao ` ` -o -o -o - -o -o -o a -o -o o - -o -o -o 0 0 -o 0 0 a a 0 - -o -o >. T >. T T T >+ T >+ >' T T >. >. >. >. T T >. >. >. >. >. >. T T >+ T >+ T >. >+ I 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 11111 2 2 2 2 2 2 •c v Uc O 0 Fa 0 O O O O O O O O O O 0 0 0 0 0 O O O O O O O O O O O O O O O O 6 •6 6 6 6 6 U U U U U U U U U U U U U U U U U U U U U U U U U U O OOOOO 00000 0 0 0 0 0 00000 0 0 0 0 0 O O O O O O CD (OCD CO CO CO CO CO CO CO CO CO CO M (O CD (D CO CO CD CD CO CD CO CO CO CO CO CO CO (D CO . _, NN N N ,..; N N N N N N N N N N N N N N N N N N N N N N N N N N N a Co co Co Co Co f- Co co co co co Co Co Co co co co Co co Co co co co co co Co co co co co co Co co U) U) U) U) CO U) U) U) U) U) U) U) U) U) CO LO LO LO LO U) LO LO L0 LC) O LO U) U) U) U) U) O) O O) O O) CO 6) O) O) Cr) O) O) O) C) 6) f'` O O Q) CA Cr) Cn O) D) O n Cr O) O) 0) O) CO O M M M M M N M M M M M M M M M N M M M M M M M M M N M M M M M M U) N N N N (D N N N N U) N N N N (D N N N N U) N N N N CD N N N N U) N o n V V V V V V V V Ln V V V V V V V V U) V V V V VV' V V4- v LLI 0 Y Y YO 0 Y CI) U U U U w n. a a) a s a a) a d a d a d a d d N d d no 0. N 0 cc a 0 dC d 0 a N d 0 d — p Yac ma dYp Yd aca apc 'tmYYa ma d Oa % p Zr)•, 0 (n U N •'u) N m 0 N z N U (n U N z N m 0 N 'rn N U (/> U N y N m0 N ' d U UQ W (d c 03 C J U c co c (p W uC 0 C J U c m C 0 W a c m c J U C 0 C 0 W 0 e I I 0 M 0 O m N 2 F- CO N e- 0 N Tr d ii o i) g C .` y a a o a o. Y N fa .' a) fHd0- 1- 0_ J O M N I-- O O r N I,- co o r co Co r V C) V O) N LU CO CO CO CO O) V C) LO I,- CO Q) Lf) WLn t CO M ) O CO O6 M (N Q M O CO N CA O M M LM N O LO M N C) N6 CO O r co M LC) r h 0 r N LO 10 CO CO 00 V CO 0 V LnO CO N- CC) Ni• CO O CA r N N Y Lf) W W W W r r r N N LO Ll) LO CO CO CO COO CO O r r r r � er .4- vt Ln � I-- S 6 Ln LO Cl) Ln CO CO CO CO (O M (6 M CO CO CO CO CO CO CO h I- N- h h r h r r I` r I� E ‘- ‘- ,- ‘- rrrrr r r r r . . . . . rrrrrrrrrr r r r r m N- 0 CO N I,- O O N- N N CO V r CO CO h VO) sO) N LO CO CO (O CO O) V O) LO I,- CO L . W M CO O M A V- (O O CO N O N M M n O N O LCO N CCN. CO 0 r CO CO CO CO N- N- 0 r N LO LO CO CO 00 00 N- 00 0 V LO •- LO CO CO O O) r Y V Ln CO O W W r r r N N L) L) L] CO CO CO CO CO CO CO r .- r r � � V. s}' V CO r S Ln Ln Cn Ln Ln Ln CO co (oM (O (O (O CD (D (o (o CO CO co co h r h h r r r r I- I- N- o r r r r . . . r r r r r . . . . . r r r r r r r r r r r r r r 12 N CO 6 0 (O (P O N O) CO 0 I- 10 CO 0 N CO 0 V 0 CO LO V O N N 0 0 C) CO LO CO LC) N O) I,- Lf) LO CO O CO L() N CO CO LO L() CC) CO CO N LL) CO CO CO LO LO CO N O) N t x 0 v N vr CO CO h N v M vr N v Ll) r N V O CO v N v N 7 NM O c C r Mr c COr r rr r CI) •- •- O. rQ. d Et N 00 r r r CO r r r e- CO r r r I� r r r r N CO r r r r r N CO r MI ' CO E `° E a) a) 3 a CO C) C •N a_ _ _ _ . . . . . _ _ _ _ . . . . . . . . . . _ _ _ _ _ _ _ _ _ U N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N CO CO Lc) CO CO CO LO CO CO LO CO CO CO LO CC) CO CO U) LO U) CO U) U) CO CO CO CO CO CO Lf) L() LO oooaao ` ` a ` ` 10-o -o a v -o -o a -o -o - -o - a - -o -o -o -o -o -o -o -o -o -o -0 -o T T T T T T T T T T T T T T T T T T T T T T T T T T T T T T T T 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 c a) C d E 0000O O O O O 0000 00000 00000 00000 0000 C) U U 6 U U 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 000, 0 00000 .0 .0 .00 OOOO O 0 0 0 0 0 O O O O O O O O O CO CO CO CO CO c0 CO CO CO CO CO CD CO CO CO M CO (O (D (O CO CO (O CO CO CO CO CO CO CO CO (O . . N N N N N N N N NN N N N N N N N N N N N N N N N N N N N N N N a r r r . . . . . r r r r . . . . . . . . . . r r r r r r r r r co co CO CO co co CO co co co co CO N CO 00 00 00 CO CO CO 00 00 N- 00 00 00 00 00 00 CO 00 00 CC) CC) CC) N CO LC) LC) CC) CC) CC) CC) CC) CC) CC) LC) LO LO CC) LO LO LO CC) N- Ln CC) CC) CC) CC) CC) CC) L() CC) O) O) O CO O) C) O) O) O) O) O) O) LC) O) CT O) O) C) O O) O) O) O) O) O) O) O) O) C) O) C)) ' M M M N M M CO M M M M M N CO M M M M CO M M M N M CO M M M M CO CO CO N N N CO N N N N 10 N N N CO N N N N CC) N N N N CO N N N N CO N N N N (n V V V V V V . LO . . . vt . vt . LU . . . . . TY . a 6 4444 ■ 1 o U 4 0 � +� Z ILO Cl) .0 a _ U 0U W n a a)a d N coa d Nad 9aa- aa d o o_ _ 0) _ _ 0) d _cry _ "a' 0) • a _ _ my _ _ d d_ _ _ J E oO Qpm o 'o CLaY 'o anp d o o am o omao o m m o 0 Q c oc (o n .c ' ') c a n mOa N a 0 a o (A C ( C 0 o a p a N apa (a (n C mapaO _ a p n n n N cc 2 ca a C a � a d Y p� a �m a Y p; c Y a o mpmaaaY '- a ma p � F— NfNm = aaNUN UmammCUuN () m ( NfNmmaiNo0 oN '(nNQy ^ C co C J U C co C o W co Co C J t C o C Co W 0 C Co C J U C N C co W co C Co C • c I ( M • O O m N M N r O N D ii N °o 0 M M C a) a CtS r 0 a W a CO 3 s I- a ✓ r n V M V O (D 0 CO LO CD N N N W CO CAV (O V O LO CO CO LO 6) Mai LO N N f� O V r N- M O O M N6 V t` CO 4- r to LO N- N V O L() m N V N- CO M N N N LO L() r V LO CO O O N V LO Ln h LO CO M 6) O O) N (O Y I- r 6) 6) 6) O O N N N N LO LO LO LI) LC) (O (T (3) O 6) N N N N N M V LO LO LO N- E r r (` N- r CO c Cb CO CO CO CO co' co co- co CO CO co co- Co 6) O) O) M 6) 6> 6) M. O) 0) 0) . . . . . r = .- r r r r r r r r r r r r r r r r r r r r r m O V N- r V CD V O CO O CO LO CO N N N CO M 61 COV O LO CO M (O 6) C'') 6) LO N N N- O V N- r M O O C) N6 4 I- CO V r LO L6 r- N V 6) m N (V V N CO 6) N N N LO LO N V Lf) (D O CT) N V LO LO N V LO CO 6) O O O N Y 1- N- N- O) 6) 6) O O N N N N LO LO LO LO LO CO 6) CO 6) 6) N N N N N CO V LO LO LO a r r N r (` co CO CO CO coco- CO Cd Cb CO CO CO CO CO Co CO O 6) Cn 6) 6) 6) 6) 6) d) O) o r .- r r r r—,—r r r r r r r r r r r r r r r r r . . . . . r r co V' co LO O N CD CO O CA CO O O N sT CO N- 0 6) 0 LO 0 N V CO N CO 0 CO ,- ,n N O CO LO LO CO CO O LO (D (D CO LO LO O 6) C)) (O LO CO LO CO LO LO N (O V CO LO CO N t N V co LO N- D) .t- co N V M M N TM LO LO O M CO N- N r N NM .- V O LO r cri r N V ON N T r V CO rNO N N a^` m W J re r r co r r r r LO CO r r I� r r r r CO CO ,- r r I. r r r r a- LO r r r CO E E 01 = a Cl) 0) 13 Cd en H oso- r r r r r r r .- r r r r r r r r r o N N N N N N N N N N NNNNN NNNNN NNNNN NNNNN NN 0 LO LO LO In LO LO CO LO LO LO LO LO LO LO LO LO LO LO LO LO LO LO LO LO LO LO LO LO to to to to 1710a -0 -0 -0 -0a -010 ,0 -0 -0 -0 ,0 -0 -0a a -01717 -0 -0 -0 -0 ,0 -0 1010 >. > >. >. > >, >, >, >, >, >, >. >, >, >, >, >. >. >. >, >, >, T >, >. >, >, >, >, T >. >, I 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 I I 0 N w 0 00000 0 0 0 0 00000 00000 00000 0 0 0 0 0 00 .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. 6 66666 6666 66666 66666 66666 66666 66 O 00000 0 0 0 0 0 0 0 0 0 00000 0 0 0 0 0 0 0 0 0 0 00 r. (O Cfl CO CO D CO ( CO (D (D (D CO CO CO CD CO CO CO CD CO CD CD (O CO (D (D CO CO CO (O (O (D (D .. NN N N N N N N N N N N N N N N N N N NNN N N N N N N N N N N n r .-- r r r r r r r r . . . . . r r r r . . . . . rrrr r r ✓ 0) 0) 0) 0) 0) CO CO CO N CO CO CO CO 00 CO CO CO CO r CO CO CO CO CO CO CO CO CO N CO CO 0 LO LO LO LO In LO LO LO CO LO LO LO LO LO U) LO LO LO CO LO LO LO LO Lf) LO LO LO LO 6) CO LO -V O 6) O O 6) CO O CO CO Cn (T CO 6) 6) O O M Cn N CO 6) 6) 6) 6) O Cn O CO r 6) 6) O N M M M M M M M M N M M M M M M M M M N M M M M M M M M M N M M CD N N N N LO N N N CO N N N N LO N N N N CO N N N N LO N N N N (O NN LO r r r r co ,.... ,- ,-. 6 rr rrM ,—,- ,- ,-. 6 r r ,- ,- ,- ,... ,r) (O ,r . 4 4- 4- 6 444 4- 4- 4 4- 6 4444 V V V to V V V V V NI- C..)i Y U Q o cc Z • W 2 — > •a• "a. n_ d a _ _ _ °_� 03 � _ _ a CL m Tii Tozzl 'oc ,- o — c5 m mO ¢ m n n a a n N CU a • ma n N n O n a O _ .4 a co a y pv c y c a to t a 60 a a a a o) CL - p C m c Ca rn a 1-4° a 0) iqr � mj � CY) U) YnNmON .,7NYCA YNiNm = NNNYn mNmNmmN ^ ¢ C m W m m C J U C m C 0 W m C m C J U C m C m W O C m G J U G m • C p M • O 0 O 2 M N � O N m � M � � CD ° a re '0^. U) Y n F o_ N N N N O) V O oO W L- LC) ¢� I� r` O LP Y f� r CO CO CO CO CO O O M O O O O E r r r r r r m r LC) N h N N O W W ¢1 Co r r O LOO N• r N• CO CO CO CO O O O O O O 'O 0 r r r r r r r 0 LO O N O O CO LO O O r LC) ICO Cn N N M 4 M N a 1.6 r r r r r r E a C) C m U 0 N N N N N N N lA LO L() LC) LO LO LC) a 73 0 • d m 0 0 0 O O O O C7 ,� U U U U U U 0 0 0 0 0 0 0 CO O Co O (D CO CO N N N N N N 5a r r r r r r CO CO CO CO CO CO CO LC) LC) LC) L() LO LC) LL) O O O O O O O M M M M M M M O N N LC) N N N V co M (I) V V "Zr V V V U 4 0 cc Z • Z O cu d a 8 o o m a O Q E m 0 OIL CD OW Pt0 N E E R Operations Summary Report - Stag Well Name: ODSN-04 • NATURAL RESOURCES Well Name: ODSN-04 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: ORIG DRILL&COMPLETE Start Date: 3/22/2013 End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftK8) (ft) Mud(lb/gal) Summary 3/21/2013 3/22/2013 0.0 Pull TWC,Install BPV as per Vetco rep.RD equipment and prep for Rig Move.Remove MPD Pump house.Move rig from ODSN-24 and position to dissemble stack.Disassemble the new stack and prepare to lift and set on BOP Stump. *Rig accepted 03/21/13 @ 00:01 hrs* 3/22/2013 3/23/2013 0.0 MU replacement Hydril BOPE.Move onto ODSN-04.Install Beaver Slide.Connect utility lines. Spot Sperry Gyro unit.Connect to HiLine Power.Receive Spud Mud from RSC to Mud Pits while adding cold lake water. 3/23/2013 3/24/2013 0.0 8.80 Remove completion running equipment from pipeshed and rig floor.NU riser,spacer spool and surface stack.Test seals and connections to 500 psi.RU 5"drillpipe equipment.Recieve 252 bbls of Spud mud from RSC to Rig pits.Load pipe shed with 5"drillpipe and MWD tools.LD 4" drillpipe from derrick.PU 5"drillpipe and rack back in derrick. 3/24/2013 3/25/2013 158.0 564.00 9.10 PU 5"drillpipe and HWDP singles from pipe shed and rack back in derrick.Slip and Cut Drill Line.RU ESP spool,Gyro unit and equipment.MU Conductor clean out assembly. Clean out Conductor f/39't/158'.Spud in with 14 1/2"Conductor Clean out assembly f/158't/226'.TOOH f/226'U Surface.Finish MU BHA#1 and directional drill f/226't/722'.Gyro survey on each connection. 3/25/2013 3/26/2013 722.0 1,805.00 9.30 Directional drill new 14-1/2"surface hole with BHA#1 f/722't/1,388'.Gyro survey each connection t/817' (Gyro on standby and released @1,600'MD).Rig Service.Directional drill w/ BHA#1 f/1,388'1/2,337'. Circulate 25 BBL SAPP pill and performed soak sequence to address high overpull with pumps off--suspected balled up BHA with 150-175K overpull when pumps off PU restored to 125K.Rig Service.Directional drill surface hole w/BHA#1 f/2,337't/2,527'. 3/26/2013 3/27/2013 2,527.0 574.00 9.40 Directional drill 14 1/2"surface hole f/2,527'U2,816. Circulate for BHA change.TOOH to adjust motor from 1.84 to 1.15. Change out MWD and upsize 1.75 orifice to 1.80. Minor Swabbing incremental and overpull as high as 80K over through UGNU Sands and at base of permafrost —1,825'through to 1,600'. Pull BHA and Change out MWD—down load same. Check bit—ok to finish surface hole. Adjust motor to 1.15°. TIH U2,816'MD and resume drilling. Stacked up at 225'MD and unable to fall through,pump 1 bpm and rotate 15 rpm and work pipe through. Continue TIH with intermittent and repeat stacking up with all the string weight which required rotation 15 rpm and pumps at 1bpm. Stubbom hole at 1,675'MD. Unable to progress with low rpm and flow rate,increased flow rate to 200 gpm,rpm to 40 and wash and ream to bottom. Took check shots to confirm new Directional Survey Tool at 2,196'and 2,669'. Directional drill f/2,816'03,101'. 3/27/2013 3/28/2013 3,101.0 1,439.00 9.50 Directional drill 14 1/2"surface hole f/3,101'04,540'. Encountered Cretaceous Tuffs @ 4,336' MD. 3/28/2013 3/29/2013 4,540.0 754.00 9.50 Directional drill 14 1/2"surface hole f/4,540'1/5,294'. TD called by on-site geologist 43'TVD into the Hue 2 shale. Pump 50 bbl Hi-Visc weighted sweep—Significant increase in cuttings. CBU 2X while racking back 1 stand every 30-40 minutes. TOOH on elevators,tight @ 2,379'—70K over,wipe through with no pump or rotary.Tight©1,100'-unable to wipe through. Rotate 20 rpm and ream through with no pumps. Continue to trip to jars©162', hole taking proper displacement—not swabbing,no signs of excess clay on tool joints. TIH f/162'U5,294'-tight @ 1,234'. Wipe through with no pump or rotary. PU single to reach TD. 3/29/2013 3/30/2013 5,294.0 0.00 9.55 Establish circulation using step rate method to 850 gpm at TD. Pump 50 bbl Hi-Visc weighted sweep. CBU 3X,racking back stand each BU. Spot 300 bbls of new mud. TOOH on elevators f/5,294'1/3,829'. Circulate and condition mud to YP-28. TOOH on elevators 0632'. LD BHA download same. RU TESCO equipment and RU floor to run casing. Run 59 joints of 11 3/4" 60#L-80 Hyd-521/BTC surface casing f/surface 1/2,403'as per tally. Baker lock shoe track and check floats. Torque turn every joint. No losses while running casing. Page 1/10 Report Printed: 11/27/2013 • PIONEER 1perations Summary Report - Stal Well Name: ODSN-04 : SOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 3/30/2013 3/31/2013 5,294.0 0.00 9.70 RIH with a total of 1291oints of 11 3/4"L-80 Hid-521/BTC 60#Surface casing,torque turn every joint. MU hanger and landing joint. Land surface casing @ 5,284'as per VG Rep. Break circulation using step rate method to 12 bpm. RD Tesco equipment and RU HES cement head. Hold PJSM while circulating @ 10 bpm. Perform Surface cement job: Line up cement head and pump 10 bbls sea water.Kick out bottom plug last 2 bbls.Pressure test pump and lines to 4000 psi. Bleed off and load top plug. Pump 100 bbls of 10.0 ppg Tuned spacer III with 0.2 gal/bbl Dual Spacer Surfactant B at 2.5 bpm, 145 psi. Drop second plug. Mix and pump 548 bbls(672 sx)of 11.1 ppg Type"L"Permafrost Lead Cement with 0.15%D-Air 5000P--Yield 4.36 ft/3. Mix and pump 132 bbls(629 sx)of 15.8 ppg Premium Class'G'Tail Cement with 1%CaCl2&0.2%CFR-3--Yield 1.18 ft/3. Drop top plug--Visual of plug away with tattle tail. Pump 17 bbls with cement pump at 6.7 bpm,234 psi. Turn over to rig for displacement:Rig displace 572 bbls at 10 bpm,ICP-433 psi,FCP-1,070 psi @ 3 bpm. Bump plug at calculated strokes and,pressure to 3500 psi,hold for 5 minutes--Chart same. Bleed off pressure and check floats--Floats holding. Monitor well—Static. 238 bbls of cement to surface. **CIP @ 19:00 hrs.** RD cement head,clean under rotary,flush flow line. Flush and begin to ND surface drilling riser. *AOGCC Rep Bob Noble waive witness of BOP test on 03/30/2013 @ 6:30 hrs* 3/31/2013 4/1/2013 5,294.0 0.00 10.30 ND surface drilling riser and spool. NU drilling adaptor and riser. VG Rep pressure test void to 5000 psi. NU New BOP stack,HCR valves,and hydraulic fittings and lines. Install 2 7/8"X 5" VBR in upper and lower rams. Install blind rams. Adjust turnbuckles and test gas alarms. RU to test BOPE. Test BOPE per AOGCC PTD: Test upper and lower VBR w/5"test joint to 250 psi I low/4500 psi high. Test upper and lower IBOP valves to 250 psi low/4500 psi high. Test rV/ 'f annular w/5" test joint ton 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 tests held for 5 min. Initial system psi:3000—1950 after closure;200 psi=23 sec,full pressure 1 min.52 sec. Blow down top drive and kill line. Hydraulic leak found on blind ram door hinge while closing to test blinds. Trouble shoot and repair hydraulic leak on blind ram door hinge. Function test blind rams 3X with no hydraulic leaks. Pressure test blind rams to 250 psi low/4500 psi high—test good. RD test equipment. MU BHA#3 bit and motor. *AOGCC Rep.Bob Noble waived witness at 06:30 hrs on 03/30/2013* 4/1/2013 4/2/2013 5,294.0 0.00 10.30 MU and RIH with 11 3/4"surface clean out BHA#3. Tag stringer @ 4,872'. Circulate BU for casing test. Pressure test 11 3/4"Hyd-521/BTC 60#L-80 surface casing to 3500 psi for 30 minutes--chart same. Wash stringers to FC @ 5,187'. Drill cement float equipment,shoe track and clean rat hole 1/5,294'. CBU. TOOH with BHA#3 f/5,294'1/597'. LD BHA#3. Clear rig floor. MU 10 5/8"RSS MWD/LWD with XBat 1/116'. Unable to download MWD tools. HES MWD Reps troubleshoot issues and contact office. 4/2/2013 4/3/2013 5,294.0 715.00 10.30 Troubleshoot MWD tools. POH and remove PCDC and replace with DM Collar. RIH with BHA #41/116'. Download MWD tools. Shallow test MWD—OK. Break in Geo-Pilot bearings. Load MWD nuclear sources. MU BHA#4 1/561'. TIH with BHA#4 1/5,215'. Fill pipe and check MWD tools©2,935'. Slip and cut 68'of drill line. TIH 1/5,294'. Break circulation and displace 9.7 ppg LSND with 10.3 ppg MOBM. Drill new 10 5/8"Intermediate#1 hole f/5,294'1/5,314'. CBU. Perform FIT to 12.5 ppg EMW,hold for 10 minutes—Chart same. Directional drill 10 5/8" Intermediate#1 hole f/5,314'1/6,009'@ 120'/hr ROP. CCU Geo-Pump motor shut down,Super Vac and cutting transfer line plug up. RSC/CCU and electrician trouble shoot Geo-Pump motor issues. 4/3/2013 4/4/2013 6,009.0 45.00 10.30 CCU/RSC troubleshoot electrical breaker on Geo-Pump motor, Un-plug Super Vac,and clear cutting transfer line. Resume drilling @ 60'/hr,drill 10 5/8"hole 1/6,054'. At 03:00 hrs,shut down cuttings transfer line plugged. CCU/RSC work on clearing line. Remove section of cuttings transfer line out side of RSC building that was plugged. Work on clearing/thawing line. Rig Crew: General housekeeping and maintenance. TOOH f/6,054'1/5,210'--inside of surface casing.Hang SRL for man rider on crown. Load,drift, and strap 9 5/8"Intermediate#1 liner. Page 2/10 Report Printed: 11/2712013 . P I 0 N E E R Operations Summary Report - Sta' Well Name: ODSN-04 ATURAL RESOURCES Start Depth FooVMeters Dens Last Start Date End Date (19(B) (ft) Mud(lb/gal) Summary 4/4/2013 4/5/2013 6,054.0 1,157.00 10.25 RSC/CCU Clear cuttings transfer line with2"pipe. Apply suction from CCU Super Vac. Install sections of CTL that were removed. Circulate"Hot Purple Pill"through CTL. Able to move fluid through CTL,approx 25%of normal flow,line pressure still high 40 psi—normal pressure is 15- 30 psi. Circulate Purple Pill/Slurry through Slurry line to CCU back to RSC until line pressure back to normal 15-30 psi. TIH f/5,215'06,054'. CBU. Directional drill 10 5/8"Intermediate#1 hole f/6,054't/7,211';750 gpm, 160 rpm, 110'/hr average ROP. Empty CCU hopper and circulate purple pill through slurry and cuttings transfer line every 500'. 4/5/2013 4/6/2013 7,211.0 1,929.00 10.25 Directional drill 10 5/8"Intermediate#1 hole f17,211'09,125',750 gpm, 160 rpm,125'/hr average ROP,with no losses. 4/6/2013 4/7/2013 9,140.0 1,235.00 10.35 Directional drill 10 5/8"Intermediate#1 f/9,125'09,848'. Pack off©9,848'. Stage pumps and rotary to full rate. Circulate and condition hole to drilling parameters. Directional drill f/9,848' t/10,375'--TD called by onsite geologist. CBU 3X while working pipe f/10,375't/10,147'. 4/7/2013 4/8/2013 10,375.0 0.00 10.30 TIH UI0,375'. CBU 3X while working pipe f/10,375'010,147'. CBU 6X total. Monitor well— Static. TOOH on elevators f/10,147'09,675". Low energy back ream 117,823'.MADD PASS log f/7,823'115,533'@ 250'/hr,2 bpm,30 rpm. TOOH t/5,215'. CBU while staging pumps to full rate, to reduce losing mud over shakers. 4/8/2013 4/9/2013 10,375.0 0.00 10.25 CBU at 725 gpm, 120-150 rpm in 11 3/4"casing 4-6 minutes a stand. Back ream out of hole f/5,215'113,500',Service rig.Continue to backream f13,500'111,000'. POOH 1/561'(BHA).LD BHA 11116'. Download MWD and continue LD BHA to surface.PU back up WFD reamer and bullnose.Drop opening RFID tags and verify reamer opened. Drop closing tags and verify reamer closed. Pull blank nozzles.Install 8/32"(3)nozzles in reamer.Continue to PU BHA#5 1/534'.RIH w/BHA#5 U3,953'. 4/9/2013 4/10/2013 10,375.0 0.00 10.25 Continue to RIH w/BHA#5 f/3,953'1/5,278'(4'inside shoe). Fill pipe and break circulation slowly(thick mud)and stage up to 780 gpm,4100 psi.Drop RFID opening tags(4).Make connection and pump tags down-Obtain parameters.Slow rate to 300 gpm.Slackoff to 15,300' bullnose depth.Increase rate to 780 gpm,3700 psi(400 psi pressure drop).Pull test reamer against 11 3/4"shoe w/10k over pull.Obtain SPR.Begin reaming/hole opening f/5,285'w/750 gpm,3250 psi-180-200 fph.Stage pumps up to 805 gpm,3700 psi 150 rpm, 180-200 fph. f/5,350'116,328'.Lost circulation/packed off after connection.PU 116,208'.Establish circulation and continue to hole opening f/6,328'1/6,735'.Observed 500 psi pressure loss.Check surface equipment.OK.Determined that probably lost a jet nozzle from bullnose.Obtain new parameters and continue reaming/hole opening f/6,735'1/7,125'w/800 gpm,3250 psi,165 rpm. 4/10/2013 4/11/2013 10,375.0 0.00 10.20 Reaming/Hole opening f/7,125'09,368'. 4/11/2013 4/12/2013 10,375.0 0.00 10.20 Reaming/hole opening f/9,368'to TD at 10,375'.Drop reamer closing tags.CBU hole clean 7X while standing back 1 stand every 30 minutes f/10,375'119,463'.POOH on elevators f/9,463' 1/5,473'. NOTE:At 11:30 hrs,AOGCC was given notice of upcoming BOP test due on 04/14/13. 4/12/2013 4/13/2013 10,375.0 0.00 10.20 Attempt to pump out(no rotary)f/5,473'w/470 gpm.Observing losses of 42 bbls(no overpull). Backream w/470 gpm,2300 psi,40 rpm f/5,473'U5,300'w/no losses observed.Stop rotary and pull into shoe while pumping 470 gpm to verify reamer blades closed.Well bled back±6 bbls after entering shoe. Backream in casing f/5,284'111,199'w/800 gpm,3500 psi-165 rpm.CBU 2x.POOH f/1,199'11534'(BHA).LD BHA to surface. PU 4 jts of HWDP and stand back in derrick. Drain stack. Install test plug.Change lower rams from 2 7/8"x 5"vbls to 9 5/8". Test BOPE per AOGCC PTD: Test lower rams w/9 5/8"test joint to 250 psi low/4500 psi high. Test upper VBR w/5"test joint to 250 psi low/4500 psi high. Test upper and lower IBOP valves to 250 psi low/4500 psi high. Test annular w/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 tests held for 5 min. Initial system psi:3000--1950 after closure;200 psi= 24 sec,full pressure 2 min. Blow down top drive and kill line. Upper 2 7/8"x 5"VBL's failed- Change out rams(2 7/8"x 5").Retest-Passed. *AOGCC Rep.Chuck Scheve waived witness on 04/12/2013 at 06:00 hrs` Page 3/10 Report Printed: 11/27/2013 PIONEER 'perations Summary Report - Stag Well Name: ODSN-04 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ft)(B) (ft) Mud(Ib/gal) Summary 4/13/2013 4/14/2013 10,375.0 0.00 10.20 Mobilize casing equipment to rig floor.PU 9-8"DC's(drift w/2 3/4").Stand back same in derrick.RU Tesco and Nabors casing tools.RU to run 9 5/8"liner.PU shoe track.Check floats. RIH w/9 5/8"40#L-80 Hyd 521 liner t/3,288'.Circulate w/1 bpm.Continue to run 9 5/8"liner f/3,288't15,229'.Break circulation and CBU.RD Tesco and casing equipment.PU WTF liner hanger/packer assembly.RIH with 9 5/8"liner on 5"DP f15,265' U6,189'. Break circulation& circulate open hole volume. 4/14/2013 4/15/2013 10,375.0 0.00 10.20 Continue to RIH w/9 5/8"liner on 5"DP f/6,189't/±7550'(top,of Brookian 2B).Break circulation. Pumped open hole volume.RIH f/7,550'U10,365'. MU Weatherford cement head. Break circulation&stage up to 4 bpm,1085 psi.Drop hanger setting ball and pump on seat w/6-7 bpm.Observe ball seat.Pressure up and set liner hanger.Pressure up and shear ball seat w/ 3500 psi.PU to string wt.Install 3 RH turns in string.Release torque and repeat process to release from hanger.PU and verify.Line up Halliburton cementers: Pump 10 bbls seawater. Pressure test lines to 4000 psi. Pump 60 bbls tuned spacer at 11.0 ppg. Pump 52 bbls(120 sx) r\)( Class'G'Lead Cement at 12.5 ppg(yield 2.42 CuFUSk)w/additives:15 Ibm/sk Microlite-P,.75% ,NHALAD(R)-344,.2%CFR-3,.15 lbm/sk EZ-FLO&.25%SCR-100. Pump 40 bbls(178 sx) ke,1 Class'G'Tail Cement at 15.8 ppg(yield 1.17 CuFt/Sk)w/additives:.5%HALAD(R)-344,.2% SCR-100&.2%CFR-3. Drop wiper plug and kick out w/20 bbls seawater. Displace cement w/ 450 bbls of 9.8 ppg brine using rig pumps.Bump plug and pressure up to 3500 psi.Hold pressure for 5 charted min.Bleed pressure and check floats-OK.CIP at 23:55 hrs.Top of liner at 5,105'. Liner shoe at 10,365'. Observed full returns during cement job&displacement. 4/15/2013 4/16/2013 10,375.0 0.00 9.80 LD cement head and pups.PU 14'to expose setting dogs.Tag top of liner-Rotate w/10 rpm and apply 50K down weight-Observe packer set.PU and repeat process 2X.Close top variable rams-Line up and test 11 3/4"x 9 5/8"liner lap to 3500 psi f/5 charted min-Good test. Displace well from liner top to surface w/9.8 ppg brine. LD 5"DP f/5,105'U surface.LD liner running tools. RIH w/3 stands of 8"DC's.LD same.RIH w/5"DP t15,706'.Circulate pipe clean. POOH LDDP. close blind rams and test 11 3/4"x 9 5/8"casing to 3500 psi for 30 charted min. Good test.Change bottom rams from 9 5/8"to 2 7/8"x 5"variables.Remove choke&kill line. 4/16/2013 4/17/2013 10,375.0 0.00 9.80 ND BOPE.Install VG Multi-Bowl.Test seals to 5000 psi.NU BOPE.Test upper&lower variable rams to 250 psi low/4500 psi high.Test annular to 250 psi low/2500 psi high for 5 charted minutes each test using 2 7/8"test jt.PU 204 jts of 5"DP from pipeshed.Flush same w/1 1/2 x DP volume.POOH standing back 5"DP.Service rig.Pull wear ring.RU and run 2 7/8"6.5#L-80 kill string to±160'. AOGCC was notified of upcoming Diverter test at 06:00 hrs on 04/17/13. 4/17/2013 4/18/2013 10,375.0 0.00 9.80 RIH w/2 7/8"6.5#L-80 BTC-M kill string f/160'to 2288'(75 jts).MU 3 1/2"x 2 7/8"XO.MU hanger.Drain stack.Land hanger in wellhead w/muleshoe at 2332'-RILDS.Vetco Rep tested hanger seals to 5000 psi-Good test.LD landing jt.RD tubing tongs&handling equip.ND BOPE and risers.NU Vetco Gray tree.Test void and tree to 5000 psi f/10 charted minutes.Secure well.Clean/clear wellbay.Slip new drilling line on blocks and draw-works. "Rig released from ODSN-04 at 23:59 hrs on 04/17/13* � 3 `� 4/18/2013 8/10/2013 10,375.0 0.00 9.80 Temporary Operation Shutdown j 3' 8/10/2013 8/11/2013 10,375.0 0.00 9.80 Prepare&move Nabors 19AC from ODSDW01-44 to ODSN-04. Note:Noitify AOGCC with 48 Notice for BOPE Test 08/10/13. Rig Accepted on ODSN-04 at 00:00 hrs on 08/10/13. 8/11/2013 8/12/2013 10,375.0 0.00 9.80 MIRU Nabors 19AC from ODSDW01-44 to ODSN-04. Note:Notify AOGCC(3rd Notification)with notice for BOPE Test 08/11/13 via email at 14:02 hrs. Page 4110 Report Printed: 11/27/2013 PI 0 N E E R Operations Summary Report - Stae Well Name: ODSN-04 ATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 8/12/2013 8/13/2013 10,375.0 0.00 10.20 Prepare Rig for operations.Displace diesel from well with Seawater. Install check valve in hanger,ND Tree. Install test dart in hanger.NU 5K BOP Stack. Test BOPE as per AOGCC PTD: Test Upper& Lower VBR against 2-7/8"&5"DP at 250 psi low/4500 psi high. Test Upper&Lower IBOP Valves at 250 psi low/4500 psi high. Test Annular Preventer against 2-7/8"DP at 250 psi low/2500 psi high. Test all Floor Valves at 250 psi low/4500 psi high. Test 14 Choke Manifold Valves at 250 psi low/4500 psi high.All Tests done with seawater&held for 5 minutes on chart. -AOGCC Jeff Jones witness Tests f/11:30 hrs U 17:30 hrs on 08/08/13. -Perform Accumulator Draw Down,initial system Psi:3000-2000 after closure;200 psi=20 seconds,full pressure at 90 seconds. Remove test dart&BPV from hanger.Verify zero pressure on Tubing&inner annulus.Pull&LD Hanger.Pull&LD 2-7/8"Tubing. Install Wear Bushing. 8/13/2013 8/14/2013 10,237.0 0.00 10.20 PU&TIH w/5"DP t/3,520'.Circulate(Flush)Drill Pipe.POOH,PU clean out assy,TIH t/10,191'(Tag Up).Wash&Ream to 10,237'(Landing Collar).Pressure Test 9-5/8"Liner x 11- 3/4"Casing to 3500 psi(Good Test).Establish drilling parameters to Drill 9-5/8"Landing Collar. 8/14/2013 8/15/2013 10,375.0 20.00 10.30 Drill cement,float equipment&rathole f/10,237' (/10,375'.Drill 20'of new formation f/10,375' 010,395'.CBU 1.5x.Perform FIT to 13.5 ppg EMW.Good FIT.Pump dry job.POOH f/10,358' (/504'(BHA).LD BHA#6.PU BHA#7 0181'. 8/15/2013 8/16/2013 10,395.0 153.00 10.25 Continue to PU 8-1/2"x 9-1/2"BHA#7 to Rhino Reamer.Cycle pumps to test Rhino reamer per Smith Rep-OK.Pulse test MWD w/600 gpm, 1050 psi.Begin loading sources in MWD-Load sources for density tool.Discovered that sources for Neutron tool were for 4 3/4"tools.Service rig.Cut&slip drilling line.Wait on sources from Deadhorse.Load sources.Continue to PU BHA #7 (/688'.RIH f/688' 03,538'.Break in Geo-Pilot per D.D.and pulse test MWD.Continue to RIH f/3,538' (/10,224'.Pull trip nipple.Install RCD element.Test MPD system.Cycle Rhino Reamer.Wash&ream f/10,224' 010,395'(TD).Drill f/10,395' 010,548'. 8/16/2013 8/17/2013 10,548.0 893.00 10.20 Drill 8-1/2"x 9-1/2" (/10,573'.Cycle pumps to activate Rhino Reamer. Initial pressure 700 gpm, 4200 psi-Pressure after pump cycle 700 gpm,3870 psi. Pull reamer against 9 5/8"shoe w/10k over at 10,546'bit depth(10,365'reamer depth).Drill new hole f/10,573' (/11,441'. 8/17/2013 8/18/2013 11,441.0 369.00 10.20 Drill 8-1/2"x 9-1/2" f/11,441' (/11,447'.Repair leak on standpipe(gasket in upper hammer union).Drill f/11,447' 011,487'.CBU in attempt to reduce torque. Drill f/11,487' 011,620'. Service rig.Repair Top Drive Decoder.Drill f/11,620' 1/11,810'. 10.2 ppg w 13.0 ECD via MPD 8/18/2013 8/19/2013 11,810.0 475.00 10.20 Drill 8 1/2"x 9 1/2"new hole f/11,810' (/11,965'placing reamer 40'above Kalubik Marker.Cycle pumps to close Rhino Reamer per Smith Rep.Continue to drill 8 1/2"new hole f/11,965' U12,121'.Repair leak on standpipe union.Drill f/12,121' U12,285'.CBU.Perform Mad Pass in preparation for Geo-Tap.Set tool face and postion string for first Geo-Tap at 12,221'bit depth. 10.2 ppg w 13.0 ECD via MPD 8/19/2013 8/20/2013 12,285.0 0.00 10.20 Continue to perform Geo-Tap samples f/12,221' 012,199'bit depth.POOH (/12,212' 1/11,950'. Cyde pumps in attempt to open Rhino Reamer WI no success.Establish circulation using step rate method after packoff event.Function test BOPE per AOGCC weekly requirement.Wash& ream f/12,000' 1/12,260' with high torque&intermittent packoffs.Backream f/12,260' 012,190' with no issues.Wash&ream f/12,190' (/12,285(TD).Cycle pumps to troubleshoot MWD detection issues.Service rig. 10.2 ppg w 13.0 ECD via MPD 8/20/2013 8/21/2013 12,285.0 462.00 10.20 Drill 8 1/2"hole(Reamer closed) f/12,285' 012,607'. Lost shore power.Trap 400 psi on well w/ annular.Start rig engines and swap to rig power.Drill f/12,607' U12,710'.Change swab in MP# 2. Drill f/12,710' (/12,747'. 10.2 ppg w 13.0 ECD via MPD Page 5/10 Report Printed: 11/27/2013 . PIONEER ')perations Summary Report - Sta' Well Name: ODSN-04 ATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date MKS) (ft) Mud(lb/gal) Summary 8/21/2013 8/22/2013 - 12,747.0 0.00 10.30 Backream f/12747'to 12468'.Observing flow back in DP indicating possible washout or float failure.RIH f/12468'to 12747'-No pump, 15 rpm-No issues.Drop Carbide Pill-Break circulation and stage up to 680 gpm,4000 psi(250-300 psi loss from yesterdays pressures). Attempt to drill f/12747'w/no success while monitoring pump pressure for signs of washout. Pump 72 bbls 17.0 ppg slug. POI-If/12747'to 3918'. 10.2 ppg w 13.0 ECD via MPD 8/22/2013 8/23/2013 12,747.0 0.00 11.00 Continue to POH f/3918'to 1900'.Calculate average MW in hole(11.2 ppg).RIH&spot 50 bbls 17.0 ppg HV KW pill!at 2500'.POH to 2019'.Displace well to surface w/17.0 ppg KWM. Remoce RCD head,install Trip Nipple.POH f/2019'to 688'(BHA).Observed jars washed out/ parted at outer mandrel.LD jars.PU new jars&stand back.LD remainder of BHA to surface. Service rig.Pull wear ring.RU test tools. Test BOPE As Per AOGCC PTD: -Test Upper& Lower VBR w/5"DP at 250/4500 psi. -Test Upper&Lower IBOP Valves at 250/4500 psi. -Test Annular Preventer w/5"DP at 250/2500 psi. -Test All Floor Valves at 250/4500 psi. -Test 14 Choke Manifold Valves at 250/4500 psi.(while LD BHA). -All Tests held For 5 minutes on chart. -AOGCC Rep.Lou Grimaldi waived witness of test at 09:00 hrs on 8-22-13. 8/23/2013 8/24/2013 12,747.0 0.00 11.00 -Continue to test BOPE: -Test blind rams to 250 psi low,4500 psi high f/5 charted min.each test. -Perform Accumulator test: Initial System Psi:3000-2200 after closure;200 psi=20 Sec., Full Pressure at 97 Sec. -RD test equipment.Blow down lines.Install wear ring.Mobilize BHA to rig floor&verify.PU BHA to 130'.Download MWD.Pulse test same.RIH f/130'to 2974'.Cut drilling line. Pull Trip Nipple.Install RCD head.Displace KWM out of hole w/11.0 ppg LSND.RIH to 6490'. Displace KWM out of hole w/11.0 ppg LSND.RIH to 9 5/8"shoe at 10365'.Displace KWM out of hole w/ 11.0 ppg LSND. 8/24/2013 8/25/2013 12,747.0 239.00 10.20 Circulate at 10365'(9 5/8"shoe)w/500 gpm to get PWD reading-13.26 ECD-Obtain SPR. RIH f/10365'to 12745'(TD).Circulate to achieve 11.0 ppg MW in/out-250 gpm,1450 psi. Increase flow rate to 410 gpm,2300 psi-Obtain PWD reading(12.88 ppg ECD).Increase rate to 500 gpm,3150 psi while holding 13.0 ppg ECD w/MPD.Drilling f/12747'to 12986'(8 1/2"TD). Circulate hole clean w/5+bottoms up while standing back 1 stand every half hr.to 12475'.Packed off&stalled out.RIH 1 stand.Establish circulation.Lubricate out of hole f/12575' to 9 5/8"shoe at 10365'. 8/25/2013 8/26/2013 12,986.0 0.00 12.00 Break circ.at 10290'(9 5/8"shoe)w/3 bpm, 1150 psi.Stage up to 550 gpm,3050 psi-80 rpm- No losses observed.Pump 50 bbls 12.5 ppg HV sweep surface to surface.Pump sweep w/400 gpm-Increase rate to 660 gpm,3900 psi after sweep entered annulus.Continue to circulate total of 3 x bottoms up.RIH f/10290'to 12986'(TD).Break circulation and stage up pumps to 625 gpm.Pump 50 bbls HV sweep surface to surface and continue to CBU total 3 x.Displace well from 10.2 ppg to 12.0 ppg LSND.Lubricate out of hole w/1-2 bpm f/12986'to 10290'(Inside 9 5/8"casing).Monitor well.Continue to POH on elevators f/10290'to 7631'. 8/26/2013 8/27/2013 12,986.0 0.00 10.20 Continue to POH on elevators f/7631'to 5064'(41'above 9 5/8"liner top).Pump 35 bbls 13.9 ppg HV pill and spot in annulus.POH 5 stands to 4589'.Displace well to surface w/530 bbls 13.9 ppg KWM.Monitor well.Pull RCD.Install Trip Nipple.POH to 598'(BHA).LD BHA.Service rig.Pull wear ring.Install test plug.Change upper rams f/2 7/8"X 5"vbls to 7".Test 7"rams to 250 psi low,4500 psi high f/5 charted min.each test.RD test equipment.RU Tesco to run 7" casing.PU shoe track.Check floats-OK.RIH w/7"26#L-80 BTC-M casing to 771'. 8/27/2013 8/28/2013 12,986.0 0.00 10.20 Continue to RIH w/7"26#L-80 BTC-M casing w/torque rings installed in 196 BTC-M joints f/ 771' t/12,920'and 119 Hydril 563 joints(315 total joints).PU VG hanger&landing jt.Land 7" casing in wellhead w/shoe at 12,963'.RD Tesco and other casing equipment. RU HES cement head.Break circulation w/4 spm, 1080 psi.Observed retums w/6.75 bbls away.Stage pumps up to 1 bpm @ 1/3 bpm increments with 1350 psi w/full returns. Page 6/10 Report Printed: 11/27/2013 . PIONEER Operations Summary Report - Ste" Well Name: ODSN-04 ATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(th/gal) Summary 8/28/2013 8/29/2013 12,986.0 0.00 10.20 Continue to stage pumps up in 1/2 bpm increments.At 2 bpm,full returns observed w/total of 83 bbls pumped.At 2.5 bpm,retums fell off to 0%.Slow pumps to 2 bpm.No returns observed. Stop pumps&bleed pressure.Attempt to break circulation w/3 spm(1/4 bpm)w/no success, Stop pumps&bleed pressure.Allow well to sit for 15 min.Fluid dropped approximately 18 inches.Attempt to break circulation w/3 spm.Pumping all fluid away(0%returns). Discuss options w/Drilling Supt.Decision made to proceed with cement job. Prep for cement job-Add 1/2 ppb Baraseal Fine to the 50 bbls 12.5 ppg Dual Spacer. -Pump 8 bbls seawater-Kick out 1st bottom plug w/2 bbls seawater. -Pressure test lines to 4000 psi-Load Top plug. -Pump 55 bbls 12.5 ppg Dual Spacer w/1/2 lb/bbl of Baraseal Fine at 4 bpm, 1870 psi.Mix& pump 70 bbls(330 sx)Class G Tail Cement,15.8 ppg w/1.17 yield and additives: .15%HALAD- 344&.3%SCR-100. v -Drop bottom plug&kick out w/20 bbls seawater. /l -Line up to rig pumps-Displace cement w/474.6 bbls 10.1 ppg brine. CA' -At 380 bbls away,observed lift f/1220 psi to 1850 psi at 473 bbls away. tt -Pumped 1/2 shoe track volume&did not bump plug-CIP @ 08:00 hrs. -Minimal returns observed during cement&displacement-Pumped 616 bbls-Retums=24.5 bbls. -Checked Floats-Held.RD Cement head.LD landing jt. Install 7"packoff per VG Rep.Test same to 5000 psi f/10 min-good test. Install test plug.Change top rams f/7" to 2 7/8" x 5" vbls.Use 2 7/8"test jt,test annular to 250 psi low/2500 psi high.Test upper&lower vbls to 250 psi low/4500 psi high.All tests charted and all tests held for 5 minutes each.RD test equipment. RU&run 75 jts of 2 7/8"6.5#L-80 IBT-M tubing.PU VG hanger and tubing in wellhead w/ muleshoe depth at 2,295'.Test hanger seals to 5000 psi f/10 charted min.Good test.Hydril Rep changing seals in operator shaft on BOP's.Released rig f/ODSN-04 at 24:00 hrs. Temporary Ops Shutdown 10/2/2013 10/3/2013 12,986.0 0.00 10.00 *"Accepted rig onto ODSN-04 at 00:00 hrs on 10/2/2013.Continue to NU Otis flange connection on tree.RU to P-6 pump.Pump 91 bbls diesel down 4-1/2"x 7"annulus taking returns out tubing to flowback tank.RU and allow to"U"tube while rigging down.Pump additional 86 bbls down annulus taking returns to flowback tank.Blow down and RD lines.Install gauges on tree.PU lubricator.Install BPV.RD lubricator&secure tree.RD&move rig from ODSN-02 to ODSN-04. RU all lines berms stairs,etc.RU on tree to pump down tubing.Pressure test lines.Displace diesel out of well using seawater.Pump 100 bbls seawater down tubing taking returns out IA to flowback tank.Shut down and allow diesel to migrate.Pump additional 20 bbls to flowback tank. Install TWC.Test from below to 3500 psi f/5 min.ND tree and install test dart.NU drilling riser. 10/3/2013 10/4/2013 12,901.0 0.00 10.00 Continue to NU BOPE.RU test equipment. -Test BOPE per AOGCC PTD: Test Upper& Lower VBR Against 2-7/8"&4-1/2"DP at 250 psi low/4500 psi high. Test Upper&Lower IBOP Valves at 250 psi low/4500 psi high. Test Annular Preventer Against 2-7/8"DP at 250 psi low/2500 psi high. Test All Floor Valves at 250 psi low/4500 psi high. Test 14 Choke Manifold Valves at 250 psi low/4500 psi high. Ail Tests Charted&held for 5 min each test. -AOGCC was notified of upcoming test via website at 18:00 hrs on 10/01/2013. -AOGCC Rep Lou Grimaldi waived witness of test at 17:21 hrs on 10/02/2013. Perform Accumulator Draw Down,Initial System Psi:3100-2100 After Closure;200 psi=24 Seconds,Full Pressure at 95 Seconds. RD test equipment.Pull test dart.Verify 0 psi on tubing &IA.Pull TWC.Pressure tesL.7_"rasing to-3500.gsi f/30 chartedmin.Good test. PU 4"landing jt engage hanger&pull to rig floor.LD 75 jts of 2-7/8"IBT-M kill string.RD tubing equipment. MU MPD lines to BOP stack.Install test plug&MPD test cap.Test MPD equipment to 250 psi low/2500 psi high.Pull test cap. Install Trip Nipple.Pull test plug. Install wear ring.PU Cleanout BHA t/370'. PU 4"DP f/370' t/1,266'. 10/4/2013 10/5/2013 12,901.0 0.00 10.00 Continue to RIH w/BHA#9 while PU 4"DP f/1,266' t/7,517'. Repair Iron Roughneck spinners. Continue to RIH w/cleanout BHA f/7,51 T t/8,448'. Cut&slip drilling line.RIH w/4"DP from derrick f/8,448' 1112,359'.Take weight at 12,359'.Drilling cement f/12,359' 1112,591'.Displace well from 10.2 ppg brine to 10.2 ppg MOBM.Continue drilling cement f/12,591' 1112,660'. Page 7/10 Report Printed: 11/27/2013 PIONEER1perations Summary Report - Ste' Well Name: ODSN-04 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 10/5/2013 10/6/2013 12,986.0 4.00 10.00 Continue to drill hard cement f/12,952' 1/12,956'.Fell through w/no resistance at 12,956'. Work down w/no rotary,no pump f/12,956'.Tag 7"shoe at 12,984'. PU t/12,956'. Wash&ream f/12,956' t/12,984'.Drill 7"shoe at 12,984'-Clean out rathole t/12,986'. Drill t/12,990'to verify out of shoe.CBU 2x.POOH performing Bat Sonic Log f/12,984' t/11,339'. POOH 1/10,954'.Log f/10,954' t/10,857'.POOH f/10,854' t/368'(BHA).LD BHA#9. PU BHA#10 to 210'. 10/6/2013 10/7/2013 12,990.0 343.00 7.65 RIH w/HWDP,jars 1/396'.RIH w/6-1/8"BHA#10 on 4"DP f/396' 1/12,904'.Cut&slip drilling line.Pull trip nipple.Install RCD.Displace well from 10.2 ppg MOBM to 7.6 ppg MOBM.Drilling 20'of new formation f/12,990' 1/13,010'. CBU.Perform FIT to 12.5 ppg EMW.Pressure stabilized at 12.0 ppg EMW.Drilling f113,010' 1/13,097'.Circulate Surface to surface. Perform Static Pore Pressure Test:8.8 ppg EMW.Drilling f/13,097' 1/13,289'.Service rig.Drilling r t/13,333'. 10/7/2013 10/8/2013 13,333.0 736.00 7.70 Drill f/13,333' t/±13,962'.Service rig.Drilling f/13,962' 1/14,069'.Wash&ream f/14,035' t/14,058' with 100%deflection in attempt to knock down angle/dogleg.Cut trough (/14,005' 1/14,035' to initiate sidetrack.Cut trough f/13,990' t114,035' to bury stabilizer.Time drill f/14,035' 1/14,037'. 10/8/2013 10/9/2013 14,069.0 276.00 7.65 Time drill at 1 fph f/14,037' 1114,055'.Drill f/14,055' 1/14,155'.Service rig.Change RCD bearing.Drill f/14,155' 1/14,205'.Ream through excessive angle/dogleg f/14,205' 1/14,185'.Drill f/14,205' 1/14,249'.Stand back 1 stand and change saver sub on Top Drive.Drill f/14,249' 1/14,345'. 10/9/2013 10/10/2013 14,345.0 465.00 7.70 Drill f/14,345' t/14,635'.Service rig.Drill f/14,635' 1/14,786'.Wash&ream f/14,786' 1/14,731. Continue to drill (/14,786' 1/14,810'.Trough f/14,810' 1/14,765' to minimize dogleg at 14,806'. POOH f/14,810' t/13,555'.Service rig.Begin cutting trough to initiate sidetrack f/13,555' 1/13,585'. 10/10/2013 10/11/2013 13,585.0 36.00 7.70 Continue troughing to initiate sidetrack f/13,540' 1/13,585'.Time drill f/13,585' 1/13,610'.Control drill f/13,610' 1/13,621 w/3-8 fph. "Function test BOPE per AOGCC weekly requirement."" 10/11/2013 10/12/2013 13,621.0 52.00 10.20 Continue to control drill at 8-10 fph f/13,621' 1/13,673'-190 gpm, 1900 psi-80-95 rpm, 10k tq. Experiencing 100% housing roll with Geo-Pilot. Hold discussion with Drig Supervisors,DD's, Geologists and Anch Drilling Supt.POOH existing sidetrack to attempt rotation in hole where Geo-Pilot was last working.POOH f/13,569' 1/13,546'stopping in 2' increments while pumping and rotating to observe indications of Geo-Pilot working properly.Displace well f/7.7 ppg MOBM to 10.2 ppg KW MOBM.Pull RCD.Install trip nipple.POOH 1/396'(BHA).Stand back HWDP& jars 1/172'. ""AOGCC was notified of upcoming BOP test via email at 06:00 hrs on 10/11/2013.AOGCC Rep John Crisp requested to witness test. 10/12/2013 10/13/2013 13,673.0 0.00 10.20 Continue to remove sources-Download MWD.LD BHA#10.Mobilize tools for BHA#11.Pull wear ring.Install test plug.Fill stack.RU to test BOPE. Test BOPE per AOGCC PTD: Test Upper& Lower VBR Against 4"&4-1/2"DP at 250 psi low/ 4500 psi high.Test Upper&Lower IBOP Valves at 250 psi low/4500 psi high. Test Annular Preventer Against 4"DP at 250 psi low/2500 psi high. Test All Floor Valves at 250 psi low/ 4500 psi high. Test 14 Choke Manifold Valves at 250 psi low/4500 psi high. All tests charted &held For 5 min-each test. -AOGCC was notified of upcoming test via website at 06:00 hrs on 10/11/2013. -AOGCC Rep John Crisp witnessed test. -Perform Accumulator Draw Down, Initial System Psi:3050-2200 After Closure;200 psi=25 Seconds,Full Pressure at 100 Seconds. -The accumulator pre charge record had not been marked as checked in the last month- checked&updated. RD test equipment.Pull test plug.Install wear ring.PU BHA 1/395'.RIH f/395' 1/3,763'.Fill pipe &break in Geo-Pilot.Continue to RIH 1/10,497'. 10/13/2013 10/14/2013 13,673.0 475.00 7.80 Continue to RIH f/10,497' 1/13,455'.Pull Trip Nipple. Install RCD Head.Displace well at 13,486' f/10.2 ppg KW MOBM to 7.7 ppg MOBM.Orient Geo-Pilot.Wash&ream (/13,482' 1/TD at 13,673'.Drill f/13,673' 1/14,138'.Time drill through siderite stringers (/14,138' 1/14,148'. Page 8/10 Report Printed: 11/27/2013 • Pt 0 N E E R iperations Summary Report - Sta' Well Name: ODSN-04 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (1KB) (ft) Mud(Ib/gal) Summary 10/14/2013 10/15/2013 14,148.0 29.00 7.70 Continue time drilling at 1.5 fph f/14,148' 1/14,161'.Drill f/14,161' U14,177'. Wash&ream to reduce dog leg severity f/14,160' U14,174'.Automated fire alarms were activated in Well Bay #1.Secure well and evacuate rig to ODS camp.All clear given by Well Site Leader.Open well. Resume wash&ream f/14,141' U14,164'. 10/15/2013 10/16/2013 14,177.0 56.00 7.70 Time drill to reduce dog leg severity at 1 fph f/14,160' U14,178'.Drill f/14,178' U14,217'. Service rig.Continue drilling f/14,217' U14,230'.Time drill at 1 fph f/14,230' 1/14,232'. 10/16/2013 10/17/2013 14,233.0 102.00 10.20 Time drill f/14,232' 1114,245'.Begin drilling with 10 fph f/14,245' 1/14,335'.Displace well from 7.7 ppg MOBM to 10.2 ppg KW MOBM.Monitor well.Static.Pull RCD head.Install Trip Nipple. POOH (/14,345' 1/12,231'. 10/17/2013 10/18/2013 14,335.0 0.00 10.20 TOOH w/Geo-Pilot Geo-Steering BHA.LD Geo-Pilot Geo-Steering BHA.Hang SRL&perform Rig Maintenance while waiting on orders.PU 4-3/4"Motor+Agitator Geo-Steering BHA.Perform Shallow Pulse Test.TIH w/same 1/1,533' &install 4-3/4"Agitator with shock sub assembly. Continue TIH 1/7,166' filling pipe every 35 stds.Attempt to obtain signal from MWD tool with no success-POOH. 10/18/2013 10/19/2013 14,335.0 0.00 10.20 POOH f/7,166' 1/1,533'. MU Top Drive&establish communication w/MWD tool. Download new parameters to MWD tool.MU Agitator tool,filter out noise from same to enable constant communication with MWD tool.POOH,pull wear ring& install test plug. Unable to make intemet BOP Notification on AOGCC website due to no intemet service on Rig. -Left detailed message of intent to test BOPE on message machine with AOGCC Field Inspector Office on North Slope&Mr.Jim Regg in AOGCC Office at 0700 Hrs. -Called back to AOGCC Field Inspector Office on Slope at 1700 hrs&discussed with Inspector Jeff Turkington. Pressure Test BOPE As Per AOGCC PTD: Test Upper& Lower VBR Against 4"&4-1/2"DP at 250 psi low/4500 psi high. Test Upper&Lower IBOP Valves at 250 psi low/4500 psi high. Test Annular Preventer Against 4"DP at 250 psi low/2500 psi high. Test All Floor Valves at 250 psi low/4500 psi high.Test 14 Choke Manifold Valves at 250 psi low/4500 psi high. All tests charted&held for 5 min-each test. -Perform Accumulator Draw Down,Initial System Psi:3000-1950 After Closure;200 psi=24 Seconds,Full Pressure at 126 Seconds. PU 4-3/4"Motor+Agitator Geo-Steering BHA.Download to MWD/LWD Tools,load nukes& perform Shallow Pulse Test.TIH with Motor BHA f/436' U6,204'(Install Agitator Tool at 1,533'). 10/19/2013 10/20/2013 14,335.0 245.00 7.80 TIN with Motor BHA f/6,204' U12,945'.Slip&Cut Drill line.CBU 1.5x.TIH U14,334'.Remove trip nipple and install RCD.Displace 10.2 ppg KW MOBM With 7.7+ppg MOBM.Geo-Steering in 6-1/8"lateral with 1.5°bh 4-3/4"mud motor w/Agitator f/14,335' U14,580'. 10/20/2013 10/21/2013 14,580.0 1,032.00 7.85 Geo-Steer in 6-1/8"lateral f/14,580' 1/15,612'with 1.5°BH 4-3/4"mud motor&Agitator. 10/21/2013 10/22/2013 15,612.0 411.00 7.90 Geo-Steer in 6-1/8"lateral (/15,612' 1/16,023'with 1.5°BH 4-3/4"mud motor&Agitator. 10/22/2013 10/23/2013 16,023.0 1,002.00 7.90 Geo-Steer in 6-1/8"lateral (/16,023' 1117,025'with 1.5°BH 4-3/4"mud motor&Agitator. 10/23/2013 10/24/2013 17,025.0 910.00 8.00 Geo-Steer in 6-1/8"lateral f/17,025' U17,935'with 1.5°BH 4-3/4"mud motor&Agitator. 10/24/2013 10/25/2013 17,935.0 981.00 8.10 Geo-Steer in 6-1/8"lateral f/17,935' U18,916'with 1.5°BH 4-3/4"mud motor&Agitator. 10/25/2013 10/26/2013 18,916.0 952.00 8.30 Geo-Steer in Nuiqsut Zone1 with 6-1/8"mud motor&Agitator in Production Lateral f/18,916' 1/19,868'MD/6362.6'TVD(Total Depth).Backream Out of Hole to augment and smooth ledges for up coming liner run f/19,868' U18,998'. 10/26/2013 10/27/2013 19,868.0 0.00 8.30 Backream Out of Hole to augment and smooth ledges for up coming Liner run f/18,998' U14,365'.Mad Pass f/14,365' 1/13,060'(Bit Depth). Obtaining real time HSI data at 275 FPH- circulate casing clean at 7"shoe. Page 9/10 Report Printed: 11/27/2013 • PIONEER 7perations Summary Report - Sta' Well Name: ODSN-04 ATURAL RESOURCES _ Start Depth Foot/Meters Dens Lest Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 10/27/2013 '10/28/2013 19,868.0 0.00 10.20 TIH on elevators to TD at 19,868'. Displace 8.3 ppg MOBM with 10.2 ppg KW MOBM.Shut down pump&monitor Well for 15 minutes(static).Remove RCD&install Trip Nipple.Lubricate Out of Hole f/19,868' 1/12,945'(inside 7"casing).Slip&cut Drill line while monitoring Well at trip tank(well static). 10/28/2013 10/29/2013 19,868.0 0.00 10.20 Lubricate Out of Hole f/12,945' 1/1,560'.Pump slug&continue POOH,laying down remaining 4" drillpipe and BHA components. 10/29/2013 10/30/2013 19,868.0 0.00 10.20 Finish LD BHA.PU&TIH with 48 Joints of 4"HWDP.Circulate 1.5x capacity,Pull&rack back same in derrick.Pull wear ring and install wear ring junk screen.Function Rams from top to bottom&flush same.Pull wear ring junk screen and install wear ring.RU Liner running equipment.PU and RIH with 4-1/2"12.6#C110 Hyd 521 Production Liner 1/3,644'with proper pipe displacement. 10/30/2013 10/31/2013 19,868.0 0.00 10.10 Continue TIH while MU Lower Completion Assembly with One WFT Eccentric Mule Shoe, 150 Joints of 4-1/2"12.6#C-110 Hyd 521 Casing,HES 11 Rapid Stage Frac Sleeves and HES 13 Swell Packer Assemblies 1/7,052'.PU&MU ZXP Flex Lock Hanger Assembly.Trip Liner In Hole on 4"Drill Pipe to 7"shoe.Circulate&Condition Mud. 10/31/2013 11/1/2013 19,868.0 0.00 10.20 TIH with 4-1/2"Lower Completion Liner on 4"Drill Pipe f/12,925' U Total Depth at 19,868'. PU 10'&set hanger/packer(shoe at 19,858'/TOL at 12,766').Test 4"x 7"Annulus above Packer to 3500 psi for 15 Minutes(Good Test).PU above Liner Top.CBU 2x,displace 7"casing volume with 10.1 NaCI/Br Brine.POOH&LD 4"Drill Pipe 1/7,961'. Submit online BOPE Test notification to AOGCC on 10/31/2013 at 5:31 PM.Receive reply email from John Crisp waiving State Witness on BOPE Test on 10/31/2013 at 6:16 PM. 11/1/2013 11/2/2013 19,868.0 0.00 10.10 Finish LD 4"Drillpipe. Submit online BOPE Test notification to AOGCC on 10/31/2013 at 5:31 PM.Receive reply email from John Crisp waiving State witness on BOPE Test on 10/31/2013 at 6:16 PM. Pressure Test BOPE as per AOGCC PTD: Test Upper& Lower VBR against 4 1/2"DP at 250 psi low/4500 psi high. Test Upper&Lower IBOP valves at 250 psi low/4500 psi high. Test Annular Preventer against 4 1/2"DP at 250 psi low/2500 psi high. Test all floor valves at 250 psi low/4500 psi high. Test 14 Choke Manifold valves at 250 psi low/4500 psi high. All tests charted&held for 5 min each test. -Perform Accumulator Draw Down,initial system psi:3100-2000 after closure:200 psi=19 seconds,full pressure at 96 seconds. Remove test plug&install wear ring. RU Tesco and HES equipment in preparation RIH with upper completion. 11/2/2013 11/3/2013 19,868.0 0.00 10.10 TIH with 4-1/2"12.6#C-110 Hyd 521 Tubing and upper completion 1/12,426'. 11/3/2013 11/4/2013 19,868.0 0.00 10.10 TIH with 4-1/2"12.6#C110 Hyd 521 Tubing and upper completion f/12,426' 1/12,781'(into Tie- Back extension).Slack off 40,000 lbs on seals.Close Annular Preventer,pump down backside& test seals to 200 psi. Space out,MU Tubing hanger&orient same. MU feed through for SVLN control line and downhole gauge I-wire.Land hanger in Wellhead,run in lock down screws,Test Tubing hanger seals to 10,000 psi.Pressure test Annulus to 500 psi(confirm seal stabbed in)- bleed down annulus.Drop ball&rod to RHC profile,pressure test upper completion string to 3500 psi for 30 minutes&chart.Bleed same down to 2200 psi.Pressure test 4-1/2"x 7" annulus to 3500 psi for 30 minutes&chart.Bleed down Tubing to shear DCK-2 valve.Pump 2 . t Bbls from each direction to confirm DCK-2 is fully sheared.Install 2-way check into Tubing Hanger.Pressure up inner annulus to 2500 psi to test two way check from below and Tubing Hanger from below(direction of flow).RD circulating lines. Pull land joint&install TWC&test same to 2500 psi.Flush stack to clean brine and ND BOPE. NU 10K frac tree with one swab valve and 10K test flange.Test Tubing Hanger void to 5000 psi. Install solid VR plug in production outlet of Wellhead.Test tree to 10,000 psi against 2-way check&solid VR plug. Remove solid VR plug from production outlet.Secure Well-prep to mobilize Nabors 19AC to ODSN-28.Rig released from ODSN-04 on 11/03/13 @ 2400 hrs. ,. Page 1 0/1 0 Report Printed: 11/27/2013 Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-04 PN5 ext 50703206700000 Sperry Drilling Services Definitive Survey Report 05 November, 2013 mom HALLIBURTON NEN Sperry Grilling Services • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD 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-4 Well Position +N/-S 0.00 usft Northing: 6,031,136.46 usfl Latitude: 70°29'46.09 N +E/-W 0.00 usft Easting: 469,905.67 usfl Longitude: 150° 14'45.90 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 13.50 usft Wellbore ODSN-04 PN5 ext Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) IGRF2010 10/11/2013 20.10 80.99 57,680 Design ODSN-04 PN5 ext Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 13,541.94 Vertical Section: Depth From(TVD) +N/-S +E/-W . Direction (usft) (usft) (usft) (°) -13.50 0.00 0.00 338.57 Survey Program Date 11/5/2013 From To Survey (usft) (usft) Survey(Wellbore) Tool Name Description Start Date 112.00 732.00 ODSN-4 Gyro Survey(ODSN-4 PN5 ext SRG-SS Surface readout gyro single shot 03/24/2013 774.62 12,714.27 ODSN-4 MWD(ODSN-4 PN5 ext PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 03/25/2013 12,722.03 12,944.74 ODSN-4 MWD SC(no checkshots)(OD:MWD+IFR2+SC+sag Fixed:v2:IIFR dec&axial correction+sag 08/21/2013 13,013.79 13,541.94 ODSN-4 MWD#2(ODSN-4 PN5 ext PB'MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/07/2013 13,555.00 19,783.79 ODSN-04 MWD#3(ODSN-04 PN5 ext) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/11/2013 Survey Map Map Vertical MD Inc Azi TVDSS TVD +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 42.70 0.00 0.00 -13.50 -13.50 0.00 0.00 6,031,136.46 469,905.67 0.00 0.00 UNDEFINED 112.00 0.48 26.30 55.80 55.80 0.26 0.13 6,031,136.72 469,905.80 0.69 0.20 SRG-SS(1) 174.00 1.19 320.91 117.79 117.79 0.99 -0.16 6,031,137.45 469,905.51 1.75 0.98 SRG-SS(1) 201.00 1.94 309.55 144.78 144.78 1.50 -0.69 6,031,137.96 469,904.98 2.99 1.65 SRG-SS(1) 263.00 2.42 301.95 206.74 206.74 2.86 -2.61 6,031,139.33 469,903.07 0.90 3.62 SRG-SS(1) 356.00 4.89 284.85 299.54 299.54 4.92 -8.11 6,031,141.41 469,897.58 2.87 7.54 SRG-SS(1) 448.00 7.48 301.23 391.01 391.01 9.03 -17.02 6,031,145.56 469,888.69 3.38 14.62 SRG-SS(1) 541.00 11.08 306.95 482.78 482.78 17.54 -29.34 6,031,154.12 469,876.40 3.99 27.05 SRG-SS(1) 637.00 16.68 305.79 575.94 575.94 31.15 -47.91 6,031,167.81 469,857.89 5.84 46.51 SRG-SS(1) 732.00 20.18 307.43 666.05 666.05 49.09 -71.99 6,031,185.84 469,833.89 3.72 72.00 SRG-SS(1) 11/5/2013 2:43:01PM Page 2 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVDSS TVD +NI-S +EI-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 774.62 22.52 311.69 705.74 705.74 58.99 -83.92 6,031,195.78 469,822.00 6.58 85.58 MWD+IFR2+MS+sag(2) 870.41 25.53 307.68 793.23 793.23 83.82 -113.97 6,031,220.73 469,792.06 3.57 119.66 MWD+IFR2+MS+sag(2) 965.82 25.86 306.69 879.21 879.21 108.82 -146.92 6,031,245.86 469,759.20 0.57 154.98 MWD+IFR2+MS+sag(2) 1,060.78 27.64 303.55 964.01 964.01 133.37 -181.89 6,031,270.55 469,724.34 2.39 190.61 MWD+IFR2+MS+sag(2) 1,158.91 31.45 307.91 1,049.37 1,049.37 161.69 -221.08 6,031,299.03 469,685.27 4.46 231.29 MWD+IFR2+MS+sag(2) 1,253.31 31.34 310.24 1,129.95 1,129.95 192.68 -259.25 6,031,330.17 469,647.23 1.29 274.08 MWD+IFR2+MS+sag(2) 1,346.25 31.25 316.29 1,209.39 1,209.39 225.73 -294.37 6,031,363.36 469,612.25 3.38 317.68 MWD+IFR2+MS+sag(2) 1,441.64 33.89 322.68 1,289.80 1,289.80 264.78 -327.60 6,031,402.54 469,579.17 4.54 366.18 MWD+IFR2+MS+sag(2) 1,539.14 34.36 327.67 1,370.53 1,370.53 309.66 -358.80 6,031,447.54 469,548.16 2.91 419.35 MWD+IFR2+MS+sag(2) 1,629.82 33.18 331.63 1,445.91 1,445.91 353.12 -384.28 6,031,491.10 469,522.86 2.75 469.12 MWD+IFR2+MS+sag(2) 1,726.75 36.11 338.96 1,525.68 1,525.68 403.15 -407.16 6,031,541.21 469,500.19 5.25 524.04 MWD+1FR2+MS+sag(2) 1,818.84 36.88 343.11 1,599.73 1,599.73 454.93 -424.93 6,031,593.06 469,482.63 2.81 578.73 MWD+IFR2+MS+sag(2) 1,917.03 41.42 348.78 1,675.88 1,675.88 515.03 -439.82 6,031,653.21 469,467.98 5.88 640.12 MWD+IFR2+MS+sag(2) 2,010.33 43.80 350.53 1,744.54 1,744.54 577.16 -451.14 6,031,715.39 469,456.91 2.85 702.10 MWD+IFR2+MS+sag(2) 2,104.90 46.99 351.69 1,810.94 1,810.94 643.68 -461.53 6,031,781.93 469,446.80 3.48 767.81 MWD+IFR2+MS+sag(2) 2,201.72 48.91 352.43 1,875.79 1,875.79 714.88 -471.45 6,031,853.17 469,437.16 2.06 837.71 MWD+IFR2+MS+sag(2) 2,297.04 50.46 352.48 1,937.46 1,937.46 786.93 -480.99 6,031,925.25 469,427.91 1.63 908.26 MWD+IFR2+MS+sag(2) 2,389.45 54.12 353.13 1,993.97 1,993.97 859.45 -490.14 6,031,997.80 469,419.06 4.00 979.11 MWD+IFR2+MS+sag(2) 2,486.35 56.99 354.61 2,048.78 2,048.78 938.89 -498.65 6,032,077.27 469,410.87 3.22 1,056.17 MWD+IFR2+MS+sag(2) 2,579.35 60.23 355.02 2,097.21 2,097.21 1,017.94 -505.82 6,032,156.34 469,404.02 3.50 1,132.38 MWD+IFR2+MS+sag(2) 2,675.53 59.59 354.48 2,145.43 2,145.43 1,100.81 -513.43 6,032,239.23 469,396.75 0.82 1,212.30 MWD+IFR2+MS+sag(2) 2,770.12 64.22 353.33 2,189.96 2,189.96 1,183.76 -522.31 6,032,322.21 469,388.21 5.01 1,292.75 MWD+IFR2+MS+sag(2) 2,861.85 66.78 356.02 2,228.01 2,228.01 1,266.85 -530.03 6,032,405.32 469,380.82 3.86 1,372.93 MWD+IFR2+MS+sag(2) 2,957.20 66.70 354.94 2,265.66 2,265.66 1,354.18 -536.94 6,032,492.67 469,374.27 1.04 1,456.74 MWD+IFR2+MS+sag(2) 3,053.86 64.00 352.89 2,305.98 2,305.98 1,441.52 -546.23 6,032,580.04 469,365.33 3.39 1,541.44 MWD+IFR2+MS+sag(2) 3,147.12 63.78 351.99 2,347.02 2,347.02 1,524.54 -557.25 6,032,663.09 469,354.65 0.90 1,622.74 MWD+IFR2+MS+sag(2) 3,241.30 63.71 353.29 2,388.68 2,388.68 1,608.30 -568.07 6,032,746.89 469,344.17 1.24 1,704.66 MWD+IFR2+MS+sag(2) 3,337.04 63.45 353.54 2,431.28 2,431.28 1,693.48 -577.90 6,032,832.10 469,334.69 0.36 1,787.54 MWD+IFR2+MS+sag(2) 3,431.96 64.04 354.11 2,473.27 2,473.27 1,778.11 -587.06 6,032,916.76 469,325.87 0.82 1,869.67 MWD+IFR2+MS+sag(2) 3,526.22 64.68 354.57 2,514.06 2,514.06 1,862.67 -595.44 6,033,001.35 469,317.84 0.81 1,951.45 MWD+IFR2+MS+sag(2) 3,620.86 65.21 353.55 2,554.14 2,554.14 1,947.95 -604.31 6,033,086.64 469,309.31 1.13 2,034.06 MWD+IFR2+MS+sag(2) 3,716.97 64.70 353.40 2,594.83 2,594.83 2,034.46 -614.21 6,033,173.18 469,299.77 0.55 2,118.21 MWD+IFR2+MS+sag(2) 3,812.31 63.59 351.70 2,636.41 2,636.41 2,119.52 -625.32 6,033,258.29 469,288.99 1.98 2,201.46 MWD+IFR2+MS+sag(2) 3,907.31 64.94 352.84 2,677.66 2,677.66 2,204.32 -636.83 6,033,343.12 469,277.83 1.79 2,284.59 MWD+IFR2+MS+sag(2) 4,002.73 66.49 353.60 2,716.90 2,716.90 2,290.68 -647.09 6,033,429.52 469,267.92 1.78 2,368.74 MWD+IFR2+MS+sag(2) 4,097.78 65.80 352.86 2,755.34 2,755.34 2,377.01 -657.34 6,033,515.87 469,258.02 1.02 2,452.83 MWD+IFR2+MS+sag(2) 4,192.46 64.58 353.57 2,795.07 2,795.07 2,462.34 -667.49 6,033,601.24 469,248.22 1.46 2,535.98 MWD+IFR2+MS+sag(2) 4,286.51 64.15 353.45 2,835.76 2,835.76 2,546.59 -677.08 6,033,685.52 469,238.97 0.47 2,617.91 MWD+IFR2+MS+sag(2) 4,382.61 61.86 353.42 2,879.38 2,879.38 2,631.66 -686.87 6,033,770.61 469,229.53 2.38 2,700.66 MWD+IFR2+MS+sag(2) 4,478.55 62.40 353.32 2,924.22 2,924.22 2,715.90 -696.66 6,033,854.89 469,220.08 0.57 2,782.66 MWD+IFR2+MS+sag(2) 11/52013 2:43:01PM Page 3 COMPASS 5000.1 Build d 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVDSS TVD +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,572.77 62.63 355.68 2,967.71 2,967.71 2,799.09 -704.67 6,033,938.11 469,212.41 2.24 2,863.03 MWD+IFR2+MS+sag(2) 4,668.11 63.59 356.26 3,010.83 3,010.83 2,883.91 -710.64 6,034,022.94 469,206.78 1.14 2,944.17 MWD+IFR2+MS+sag(2) 4,763.20 63.42 354.83 3,053.26 3,053.26 2,968.76 -717.25 6,034,107.80 469,200.51 1.36 3,025.56 MWD+IFR2+MS+sag(2) 4,857.09 63.74 353.78 3,095.03 3,095.03 3,052.42 -725.60 6,034,191.49 469,192.51 1.06 3,106.49 MWD+IFR2+MS+sag(2) 4,952.65 64.20 353.35 3,136.97 3,136.97 3,137.75 -735.22 6,034,276.85 469,183.23 0.63 3,189.43 MWD+IFR2+MS+sag(2) 5,048.13 64.16 352.56 3,178.56 3,178.56 3,223.05 -745.76 6,034,362.18 469,173.04 0.75 3,272.68 MWD+IFR2+MS+sag(2) 5,143.34 63.18 351.98 3,220.78 3,220.78 3,307.60 -757.24 6,034,446.77 469,161.90 1.17 3,355.58 MWD+IFR2+MS+sag(2) 5,238.40 64.12 352.00 3,262.98 3,262.98 3,391.95 -769.11 6,034,531.16 469,150.38 0.99 3,438.44 MWD+IFR2+MS+sag(2) 5,320.00 64.14 353.52 3,298.58 3,298.58 3,464.79 -778.36 6,034,604.03 469,141.42 1.68 3,509.62 MWD+IFR2+MS+sag(2) 5,371.78 63.74 353.06 3,321.33 3,321.33 3,510.98 -783.79 6,034,650.24 469,136.17 1.11 3,554.61 MWD+IFR2+MS+sag(2) 5,467.39 64.21 354.99 3,363.28 3,363.28 3,596.43 -792.73 6,034,735.71 469,127.58 1.88 3,637.41 MWD+IFR2+MS+sag(2) 5,562.63 64.48 354.64 3,404.52 3,404.52 3,681.93 -800.49 6,034,821.23 469,120.17 0.44 3,719.83 MWD+IFR2+MS+sag(2) 5,657.38 64.74 354.41 3,445.15 3,445.15 3,767.13 -808.66 6,034,906.46 469,112.35 0.35 3,802.13 MWD+IFR2+MS+sag(2) 5,752.70 64.40 354.49 3,486.08 3,486.08 3,852.81 -816.99 6,034,992.17 469,104.37 0.36 3,884.93 MWD+IFR2+MS+sag(2) 5,847.78 64.21 354.38 3,527.30 3,527.30 3,938.09 -825.29 6,035,077.47 469,096.41 0.23 3,967.34 MWD+IFR2+MS+sag(2) 5,942.61 64.08 355.16 3,568.66 3,568.66 4,023.07 -833.07 6,035,162.47 469,088.97 0.75 4,049.29 MWD+IFR2+MS+sag(2) 6,036.56 63.79 354.83 3,609.94 3,609.94 4,107.14 -840.44 6,035,246.56 469,081.95 0.44 4,130.24 MWD+IFR2+MS+sag(2) 6,132.10 63.67 354.78 3,652.22 3,652.22 4,192.46 -848.19 6,035,331.91 469,074.54 0.13 4,212.50 MWD+IFR2+MS+sag(2) 6,224.71 63.87 355.21 3,693.15 3,693.15 4,275.22 -855.44 6,035,414.68 469,067.63 0.47 4,292.18 MWD+IFR2+MS+sag(2) 6,322.72 64.41 354.73 3,735.90 3,735.90 4,363.07 -863.17 6,035,502.56 469,060.25 0.71 4,376.79 MWD+IFR2+MS+sag(2) 6,417.83 64.55 355.10 3,776.88 3,776.88 4,448.57 -870.78 6,035,588.08 469,052.99 0.38 4,459.15 MWD+IFR2+MS+sag(2) 6,512.73 64.47 355.28 3,817.72 3,817.72 4,533.93 -877.96 6,035,673.46 469,046.15 0.19 4,541.23 MWD+IFR2+MS+sag(2) 6,607.37 63.79 354.03 3,859.02 3,859.02 4,618.71 -885.89 6,035,758.26 469,038.57 1.39 4,623.05 MWD+IFR2+MS+sag(2) 6,702.87 63.65 355.08 3,901.30 3,901.30 4,703.95 -894.02 6,035,843.53 469,030.79 1.00 4,705.36 MWD+IFR2+MS+sag(2) 6,798.37 63.09 354.25 3,944.11 3,944.11 4,788.95 -901.96 6,035,928.55 469,023.20 0.97 4,787.38 MWD+IFR2+MS+sag(2) 6,891.40 63.14 354.45 3,986.18 3,986.18 4,871.52 -910.13 6,036,011.14 469,015.36 0.20 4,867.23 MWD+IFR2+MS+sag(2) 6,987.87 63.30 355.19 4,029.64 4,029.64 4,957.29 -917.90 6,036,096.94 469,007.94 0.70 4,949.91 MWD+IFR2+MS+sag(2) 7,083.12 63.54 355.18 4,072.26 4,072.26 5,042.18 -925.05 6,036,181.84 469,001.13 0.25 5,031.54 MWD+IFR2+MS+sag(2) 7,177.84 64.08 355.96 4,114.07 4,114.07 5,126.92 -931.61 6,036,266.60 468,994.91 0.93 5,112.82 MWD+IFR2+MS+sag(2) 7,270.68 64.35 356.37 4,154.45 4,154.45 5,210.32 -937.20 6,036,350.02 468,989.66 0.49 5,192.50 MWD+IFR2+MS+sag(2) 7,366.93 64.21 356.49 4,196.22 4,196.22 5,296.87 -942.60 6,036,436.58 468,984.61 0.18 5,275.04 MWD+IFR2+MS+sag(2) 7,461.72 64.42 356.15 4,237.31 4,237.31 5,382.12 -948.09 6,036,521.84 468,979.47 0.39 5,356.39 MWD+IFR2+MS+sag(2) 7,556.46 64.01 354.30 4,278.52 4,278.52 5,467.12 -955.19 6,036,606.86 468,972.72 1.81 5,438.12 MWD+IFR2+MS+sag(2) 7,651.42 63.80 356.32 4,320.29 4,320.29 5,552.11 -962.16 6,036,691.87 468,966.09 1.92 5,519.78 MWD+IFR2+MS+sag(2) 7,747.28 64.07 355.71 4,362.41 4,362.41 5,638.01 -968.14 6,036,777.79 468,960.45 0.64 5,601.92 MWD+IFR2+MS+sag(2) 7,840.95 64.37 355.62 4,403.15 4,403.15 5,722.12 -974.52 6,036,861.91 468,954.42 0.33 5,682.54 MWD+IFR2+MS+sag(2) 7,934.71 64.27 354.35 4,443.78 4,443.78 5,806.29 -981.91 6,036,946.11 468,947.37 1.23 5,763.60 MWD+IFR2+MS+sag(2) 8,028.65 64.00 353.91 4,484.76 4,484.76 5,890.38 -990.55 6,037,030.22 468,939.07 0.51 5,845.03 MWD+IFR2+MS+sag(2) 8,124.90 64.34 353.97 4,526.70 4,526.70 5,976.53 -999.70 6,037,116.39 468,930.27 0.36 5,928.56 MWD+IFR2+MS+sag(2) 8,221.76 64.22 354.44 4,568.74 4,568.74 6,063.35 -1,008.51 6,037,203.24 468,921.82 0.45 6,012.59 MWD+IFR2+MS+sag(2) 11/5/2013 2:43:01PM Page 4 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVDSS TVD +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,316.01 64.42 354.12 4,609.58 4,609.58 6,147.86 -1,016.97 6,037,287.78 468,913.69 0.37 6,094.36 MWD+IFR2+MS+sag(2) 8,408.97 64.22 354.57 4,649.86 4,649.86 6,231.23 -1,025.23 6,037,371.18 468,905.78 0.49 6,174.98 MWD+IFR2+MS+sag(2) 8,504.62 64.20 353.81 4,691.48 4,691.48 6,316.91 -1,033.95 6,037,456.88 468,897.41 0.72 6,257.92 MWD+IFR2+MS+sag(2) 8,601.35 63.93 354.45 4,733.78 4,733.78 6,403.44 -1,042.84 6,037,543.44 468,888.86 0.66 6,341.72 MWD+IFR2+MS+sag(2) 8,696.80 63.68 354.20 4,775.92 4,775.92 6,488.67 -1,051.31 6,037,628.69 468,880.74 0.35 6,424.15 MWD+IFR2+MS+sag(2) 8,791.47 64.07 354.30 4,817.60 4,817.60 6,573.24 -1,059.83 6,037,713.29 468,872.56 0.42 6,505.99 MWD+IFR2+MS+sag(2) 8,885.77 64.00 354.12 4,858.89 4,858.89 6,657.59 -1,068.38 6,037,797.66 468,864.35 0.19 6,587.63 MWD+IFR2+MS+sag(2) 8,980.14 63.85 354.26 4,900.37 4,900.37 6,741.92 -1,076.96 6,037,882.02 468,856.12 0.21 6,669.26 MWD+IFR2+MS+sag(2) 9,075.61 64.07 354.80 4,942.28 4,942.28 6,827.31 -1,085.14 6,037,967.43 468,848.29 0.56 6,751.73 MWD+IFR2+MS+sag(2) 9,169.87 63.87 354.70 4,983.65 4,983.65 6,911.65 -1,092.89 6,038,051.79 468,840.88 0.23 6,833.08 MWD+IFR2+MS+sag(2) 9,265.51 63.85 355.19 5,025.78 5,025.78 6,997.17 -1,100.45 6,038,137.34 468,833.66 0.46 6,915.45 MWD+IFR2+MS+sag(2) 9,360.79 64.09 355.19 5,067.60 5,067.60 7,082.49 -1,107.63 6,038,222.67 468,826.83 0.25 6,997.49 MWD+IFR2+MS+sag(2) 9,455.74 64.36 355.55 5,108.88 5,108.88 7,167.71 -1,114.53 6,038,307.92 468,820.27 0.44 7,079.34 MWD+IFR2+MS+sag(2) 9,549.72 64.22 355.79 5,149.65 5,149.65 7,252.15 -1,120.93 6,038,392.37 468,814.22 0.27 7,160.27 MWD+IFR2+MS+sag(2) 9,647.28 63.95 355.49 5,192.29 5,192.29 7,339.64 -1,127.60 6,038,479.88 468,807.90 0.39 7,244.16 MWD+IFR2+MS+sag(2) 9,742.22 64.02 355.76 5,233.93 5,233.93 7,424.71 -1,134.11 6,038,564.97 468,801.74 0.27 7,325.72 MWD+IFR2+MS+sag(2) 9,837.04 64.41 355.17 5,275.18 5,275.18 7,509.82 -1,140.86 6,038,650.10 468,795.33 0.70 7,407.42 MWD+IFR2+MS+sag(2) 9,930.55 64.61 354.84 5,315.42 5,315.42 7,593.91 -1,148.21 6,038,734.21 468,788.33 0.38 7,488.38 MWD+IFR2+MS+sag(2) 10,026.77 64.14 355.21 5,357.03 5,357.03 7,680.34 -1,155.73 6,038,820.66 468,781.15 0.60 7,571.58 MWD+IFR2+MS+sag(2) 10,122.59 63.86 354.12 5,399.04 5,399.04 7,766.09 -1,163.74 6,038,906.43 468,773.49 1.06 7,654.32 MWD+IFR2+MS+sag(2) 10,215.44 64.07 353.96 5,439.79 5,439.79 7,849.07 -1,172.40 6,038,989.43 468,765.17 0.27 7,734.73 MWD+IFR2+MS+sag(2) 10,311.87 64.21 354.01 5,481.85 5,481.85 7,935.36 -1,181.49 6,039,075.75 468,756.43 0.15 7,818.38 MWD+IFR2+MS+sag(2) 10,342.37 64.22 354.05 5,495.12 5,495.12 7,962.68 -1,184.35 6,039,103.08 468,753.68 0.12 7,844.85 MWD+IFR2+MS+sag(2) 10,445.79 64.14 354.03 5,540.17 5,540.17 8,055.27 -1,194.02 6,039,195.70 468,744.39 0.08 7,934.57 MWD+IFR2+MS+sag(2) 10,538.73 64.13 354.41 5,580.71 5,580.71 8,138.47 -1,202.44 6,039,278.93 468,736.31 0.37 8,015.10 MWD+IFR2+MS+sag(2) 10,634.01 64.26 353.84 5,622.19 5,622.19 8,223.80 -1,211.22 6,039,364.28 468,727.87 0.56 8,097.73 MWD+IFR2+MS+sag(2) 10,729.76 64.56 353.43 5,663.54 5,663.54 8,309.62 -1,220.79 6,039,450.14 468,718.65 0.50 8,181.12 MWD+IFR2+MS+sag(2) 10,826.05 65.03 352.69 5,704.55 5,704.55 8,396.11 -1,231.32 6,039,536.65 468,708.47 0.85 8,265.47 MWD+IFR2+MS+sag(2) 10,920.84 65.38 353.91 5,744.30 5,744.30 8,481.57 -1,241.36 6,039,622.15 468,698.78 1.23 8,348.69 MWD+IFR2+MS+sag(2) 11,017.61 64.89 353.99 5,784.99 5,784.99 8,568.88 -1,250.61 6,039,709.48 468,689.88 0.51 8,433.35 MWD+IFR2+MS+sag(2) 11,112.57 65.10 352.26 5,825.14 5,825.14 8,654.32 -1,260.92 6,039,794.95 468,679.92 1.67 8,516.64 MWD+IFR2+MS+sag(2) 11,207.52 64.90 351.35 5,865.26 5,865.26 8,739.49 -1,273.18 6,039,880.17 468,668.00 0.89 8,600.41 MWD+IFR2+MS+sag(2) 11,302.45 65.05 351.28 5,905.42 5,905.42 8,824.52 -1,286.17 6,039,965.24 468,655.36 0.17 8,684.31 MWD+IFR2+MS+sag(2) 11,397.89 65.03 351.69 5,945.70 5,945.70 8,910.09 -1,298.98 6,040,050.86 468,642.90 0.39 8,768.64 MWD+IFR2+MS+sag(2) 11,492.65 64.96 351.62 5,985.75 5,985.75 8,995.06 -1,311.45 6,040,135.87 468,630.78 0.10 8,852.29 MWD+IFR2+MS+sag(2) 11,588.46 65.31 346.93 6,026.05 6,026.05 9,080.44 -1,327.62 6,040,221.30 468,614.95 4.46 8,937.67 MWD+IFR2+MS+sag(2) 11,683.69 65.92 343.81 6,065.38 6,065.38 9,164.35 -1,349.53 6,040,305.29 468,593.38 3.05 9,023.78 MWD+IFR2+MS+sag(2) 11,778.82 67.22 342.65 6,103.21 6,103.21 9,247.91 -1,374.72 6,040,388.95 468,568.54 1.77 9,110.78 MWD+IFR2+MS+sag(2) 11,873.85 69.30 342.06 6,138.40 6,138.40 9,332.03 -1,401.48 6,040,473.16 468,542.12 2.26 9,198.85 MWD+IFR2+MS+sag(2) 11,968.41 71.04 341.11 6,170.48 6,170.48 9,416.42 -1,429.58 6,040,557.66 468,514.36 2.07 9,287.68 MWD+IFR2+MS+sag(2) 11/52013 2:43:01PM Page 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVDSS ND +NI-S +E/-W Northing Easting DLS Section (usft) (°) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°11001 (ft) Survey Tool Name 12,057.59 73.05 339.73 6,197.97 6,197.97 9,496.34 -1,458.01 6,040,637.69 468,486.26 2.69 9,372.46 MWD+IFR2+MS+sag(2) 12,155.55 73.49 336.61 6,226.18 6,226.18 9,583.41 -1,492.90 6,040,724.89 468,451.73 3.08 9,466.26 MWD+IFR2+MS+sag(2) 12,254.12 75.42 335.60 6,252.59 6,252.59 9,670.23 -1,531.36 6,040,811.86 468,413.62 2.19 9,561.13 MWD+IFR2+MS+sag(2) 12,347.92 77.33 333.11 6,274.69 6,274.69 9,752.40 -1,570.82 6,040,894.17 468,374.50 3.29 9,652.03 MWD+IFR2+MS+sag(2) 12,443.74 79.46 331.19 6,293.97 6,293.97 9,835.38 -1,614.67 6,040,977.32 468,330.99 2.97 9,745.29 MWD+IFR2+MS+sag(2) 12,538.91 80.33 330.11 6,310.67 6,310.67 9,917.04 -1,660.59 6,041,059.16 468,285.40 1.44 9,838.09 MWD+IFR2+MS+sag(2) 12,634.53 82.15 328.07 6,325.23 6,325.23 9,998.11 -1,709.14 6,041,140.42 468,237.19 2.84 9,931.30 MWD+IFR2+MS+sag(2) 12,714.27 84.51 325.58 6,334.49 6,334.49 10,064.39 -1,752.47 6,041,206.87 468,194.13 4.29 10,008.83 MWD+IFR2+MS+sag(2) 12,722.03 84.47 325.84 6,335.24 6,335.24 10,070.77 -1,756.82 6,041,213.27 468,189.80 3.37 10,016.36 MWD+IFR2+SC+sag(3) 12,818.82 85.96 322.11 6,343.31 6,343.31 10,148.76 -1,813.54 6,041,291.48 468,133.41 4.14 10,109.68 MWD+IFR2+SC+sag(3) 12,914.81 84.78 322.05 6,351.06 6,351.06 10,224.24 -1,872.34 6,041,367.18 468,074.92 1.23 10,201.42 MWD+IFR2+SC+sag(3) 12,944.74 84.28 321.89 6,353.91 6,353.91 10,247.71 -1,890.69 6,041,390.72 468,056.66 1.75 10,229.97 MWD+IFR2+SC+sag(3) 13,013.79 84.94 322.54 6,360.40 6,360.40 10,302.04 -1,932.81 6,041,445.22 468,014.77 1.34 10,295.93 MWD+IFR2+MS+sag(4) 13,060.60 88.15 323.52 6,363.22 6,363.22 10,339.36 -1,960.91 6,041,482.65 467,986.83 7.17 10,340.94 MWD+IFR2+MS+sag(4) 13,112.77 90.07 324.18 6,364.03 6,364.03 10,381.48 -1,991.68 6,041,524.89 467,956.23 3.89 10,391.39 MWD+IFR2+MS+sag(4) 13,156.91 90.38 323.67 6,363.86 6,363.86 10,417.16 -2,017.67 6,041,560.67 467,930.39 1.35 10,434.10 MWD+IFR2+MS+sag(4) 13,253.77 90.26 322.62 6,363.32 6,363.32 10,494.66 -2,075.76 6,041,638.39 467,872.61 1.09 10,527.47 MWD+IFR2+MS+sag(4) 13,349.68 91.37 323.45 6,361.95 6,361.95 10,571.28 -2,133.43 6,041,715.24 467,815.26 1.45 10,619.86 MWD+IFR2+MS+sag(4) 13,445.77 89.68 319.44 6,361.07 6,361.07 10,646.40 -2,193.30 6,041,790.60 467,755.70 4.53 10,711.67 MWD+IFR2+MS+sag(4) 13,541.94 88.96 319.85 6,362.21 6,362.21 10,719.68 -2,255.57 6,041,864.12 467,693.74 0.86 10,802.63 MWD+IFR2+MS+sag(4) 13,555.00 89.19 319.97 6,362.42 6,362.42 10,729.67 -2,263.98 6,041,874.15 467,685.37 1.99 10,815.00 MWD+IFR2+MS+sag(5) 13,604.76 87.40 319.62 6,363.91 6,363.91 10,767.66 -2,296.09 6,041,912.26 467,653.42 3.67 10,862.09 MWD+IFR2+MS+sag(5) 13,636.81 87.15 320.45 6,365.43 6,365.43 10,792.19 -2,316.65 6,041,936.87 467,632.96 2.70 10,892.45 MWD+IFR2+MS+sag(5) 13,732.18 89.18 319.25 6,368.48 6,368.48 10,865.05 -2,378.11 6,042,009.97 467,571.80 2.47 10,982.72 MWD+IFR2+MS+sag(5) 13,828.96 91.46 319.45 6,367.94 6,367.94 10,938,47 -2,441.15 6,042,083.64 467,509.07 2.36 11,074.10 MWD+IFR2+MS+sag(5) 13,925.43 92.83 319.77 6,364.33 6,364.33 11,011.89 -2,503.61 6,042,157.31 467,446.90 1.46 11,165.27 MWD+IFR2+MS+sag(5) 14,021.98 91.43 321.94 6,360.74 6,360.74 11,086.71 -2,564.52 6,042,232.37 467,386.31 2.67 11,257.17 MWD+IFR2+MS+sag(5) 14,119.29 90.01 328.18 6,359.52 6,359.52 11,166.44 -2,620.21 6,042,312.31 467,330.94 6.58 11,351.73 MWD+IFR2+MS+sag(5) 14,180.50 88.17 329.59 6,360.49 6,360.49 11,218.83 -2,651.84 6,042,364.82 467,299.53 3.79 11,412.06 MWD+IFR2+MS+sag(5) 14,213.24 87.61 329.49 6,361.70 6,361.70 11,247.03 -2,668.42 6,042,393.09 467,283.06 1.74 11,444.37 MWD+IFR2+MS+sag(5) 14,301.61 86.45 331.22 6,366.28 6,366.28 11,323.73 -2,712.07 6,042,469.95 467,239.73 2.35 11,531.71 MWD+IFR2+MS+sag(5) 14,399.02 91.14 329.63 6,368.32 6,368.32 11,408.40 -2,760.13 6,042,554.81 467,192.02 5.08 11,628.09 MWD+IFR2+MS+sag(5) 14,495.45 91.64 324.82 6,365.98 6,365.98 11,489.43 -2,812.30 6,042,636.04 467,140.19 5.01 11,722.58 MWD+IFR2+MS+sag(5) 14,592.24 94.67 324.24 6,360.66 6,360.66 11,568.13 -2,868.37 6,042,714.96 467,084.44 3.19 11,816.32 MWD+IFR2+MS+sag(5) 14,689.77 94.67 324.32 6,352.72 6,352.72 11,647.05 -2,925.12 6,042,794.10 467,028.01 0.08 11,910.52 MWD+IFR2+MS+sag(5) 14,784.86 93.25 321.93 6,346.15 6,346.15 11,722.93 -2,982.04 6,042,870.20 466,971.40 2.92 12,001.95 MWD+IFR2+MS+sag(5) 14,880.97 90.78 318.54 6,342.77 6,342.77 11,796.74 -3,043.47 6,042,944.26 466,910.28 4.36 12,093.11 MWD+IFR2+MS+sag(5) 14,977.73 89.60 318.91 6,342.45 6,342.45 11,869.46 -3,107.30 6,043,017.22 466,846.76 1.28 12,184.12 MWD+IFR2+MS+sag(5) 15,074.30 90.53 317.71 6,342.34 6,342.34 11,941.57 -3,171.52 6,043,089.59 466,782.83 1.57 12,274.71 MWD+IFR2+MS+sag(5) 15,170.57 90.96 318.18 6,341.09 6,341.09 12,013.04 -3,236.00 6,043,161.32 466,718.65 0.66 12,364.80 MWD+IFR2+MS+sag(5) 11/52013 2:43:01PM Page 6 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVDSS TVD +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 15,266.02 90.10 316.38 6,340.20 6,340.20 12,083.16 -3,300.75 6,043,231.69 466,654.19 2.09 12,453.73 MWD+IFR2+MS+sag(5) 15,363.56 90.90 315.95 6,339.35 6,339.35 12,153.52 -3,368.30 6,043,302.31 466,586.93 0.93 12,543.91 MWD+IFR2+MS+sag(5) 15,460.86 90.41 315.83 6,338.24 6,338.24 12,223.38 -3,436.02 6,043,372.44 466,519.50 0.52 12,633.68 MWD+IFR2+MS+sag(5) 15,555.68 89.78 316.34 6,338.08 6,338.08 12,291.68 -3,501.79 6,043,441.00 466,454.02 0.85 12,721.29 MWD+IFR2+MS+sag(5) 15,652.36 90.34 313.33 6,337.98 6,337.98 12,359.84 -3,570.34 6,043,509.43 466,385.75 3.17 12,809.78 MWD+IFR2+MS+sag(5) 15,749.13 89.48 311.27 6,338.13 6,338.13 12,424.96 -3,641.91 6,043,574.83 466,314.45 2.31 12,896.55 MWD+IFR2+MS+sag(5) 15,798.79 89.79 312.74 6,338.45 6,338.45 12,458.19 -3,678.81 6,043,608.21 466,277.69 3.03 12,940.97 MWD+IFR2+MS+sag(5) 15,843.60 89.72 317.58 6,338.64 6,338.64 12,489.96 -3,710.40 6,043,640.10 466,246.23 10.80 12,982.08 MWD+IFR2+MS+sag(5) 15,939.80 88.18 318.24 6,340.40 6,340.40 12,561.33 -3,774.87 6,043,711.73 466,182.06 1.74 13,072.07 MWD+IFR2+MS+sag(5) 16,037.01 90.22 321.15 6,341.76 6,341.76 12,635.45 -3,837.73 6,043,786.09 466,119.50 3.66 13,164.03 MWD+IFR2+MS+sag(5) 16,132.28 90.16 323.08 6,341.45 6,341.45 12,710.63 -3,896.23 6,043,861.50 466,061.31 2.03 13,255.40 MWD+IFR2+MS+sag(5) 16,228.53 91.39 324.09 6,340.14 6,340.14 12,788.08 -3,953.36 6,043,939.17 466,004.50 1.65 13,348.36 MWD+IFR2+MS+sag(5) 16,324.95 91.70 323.71 6,337.54 6,337.54 12,865.96 -4,010.15 6,044,017.27 465,948.03 0.51 13,441.61 MWD+IFR2+MS+sag(5) 16,421.38 92.20 323.77 6,334.26 6,334.26 12,943.67 -4,067.15 6,044,095.20 465,891.35 0.52 13,534.77 MWD+IFR2+MS+sag(5) 16,518.89 90.59 322.02 6,331.89 6,331.89 13,021.41 -4,125.95 6,044,173.17 465,832.87 2.44 13,628.62 MWD+IFR2+MS+sag(5) 16,612.64 90.53 322.40 6,330.97 6,330.97 13,095.49 -4,183.40 6,044,247.48 465,775.73 0.41 13,718.57 MWD+IFR2+MS+sag(5) 16,710.35 89.91 325.75 6,330.60 6,330.60 13,174.60 -4,240.72 6,044,326.82 465,718.74 3.49 13,813.16 MWD+IFR2+MS+sag(5) 16,806.28 89.36 327.08 6,331.21 6,331.21 13,254.51 -4,293.78 6,044,406.93 465,666.01 1.50 13,906.93 MWD+IFR2+MS+sag(5) 16,903.61 89.60 323.48 6,332.09 6,332.09 13,334.50 -4,349.21 6,044,487.13 465,610.91 3.71 14,001.64 MWD+IFR2+MS+sag(5) 16,998.75 90.16 325.71 6,332.29 6,332.29 13,412.04 -4,404.32 6,044,564.89 465,556.11 2.42 14,093.95 MWD+IFR2+MS+sag(5) 17,095.28 90.78 324.13 6,331.50 6,331.50 13,491.03 -4,459.80 6,044,644.10 465,500.97 1.76 14,187.75 MWD+IFR2+MS+sag(5) 17,192.02 91.21 324.49 6,329.82 6,329.82 13,569.59 -4,516.22 6,044,722.87 465,444.86 0.58 14,281.50 MWD+IFR2+MS+sag(5) 17,287.76 90.03 323.14 6,328.78 6,328.78 13,646.85 -4,572.74 6,044,800.36 465,388.66 1.87 14,374.07 MWD+IFR2+MS+sag(5) 17,383.93 88.05 320.83 6,330.39 6,330.39 13,722.60 -4,631.96 6,044,876.34 465,329.76 3.16 14,466.22 MWD+IFR2+MS+sag(5) 17,480.52 89.73 321.63 6,332.27 6,332.27 13,797.89 -4,692.43 6,044,951.87 465,269.60 1.93 14,558.40 MWD+IFR2+MS+sag(5) 17,530.83 89.85 321.55 6,332.45 6,332.45 13,837.31 -4,723.68 6,044,991.41 465,238.51 0.29 14,606.51 MWD+IFR2+MS+sag(5) 17,576.97 88.80 322.30 6,332.99 6,332.99 13,873.63 -4,752.13 6,045,027.84 465,210.21 2.80 14,650.72 MWD+IFR2+MS+sag(5) 17,627.20 90.03 323.90 6,333.51 6,333.51 13,913.79 -4,782.29 6,045,068.12 465,180.22 4.02 14,699.12 MWD+IFR2+MS+sag(5) 17,672.60 89.36 326.18 6,333.75 6,333.75 13,951.00 -4,808.30 6,045,105.43 465,154.36 5.23 14,743.26 MWD+IFR2+MS+sag(5) 17,724.08 90.22 326.38 6,333.94 6,333.94 13,993.82 -4,836.88 6,045,148.36 465,125.96 1.72 14,793.56 MWD+IFR2+MS+sag(5) 17,769.48 89.23 327.27 6,334.15 6,334.15 14,031.82 -4,861.72 6,045,186.45 465,101.27 2.93 14,838.01 MWD+IFR2+MS+sag(5) 17,865.73 89.05 326.88 6,335.60 6,335.60 14,112.60 -4,914.03 6,045,267.44 465,049.29 0.45 14,932.32 MWD+IFR2+MS+sag(5) 17,961.80 89.42 325.73 6,336.88 6,336.88 14,192.52 -4,967.32 6,045,347.57 464,996.33 1.26 15,026.18 MWD+IFR2+MS+sag(5) 18,057.46 89.42 325.09 6,337.85 6,337.85 14,271.27 -5,021.63 6,045,426.52 464,942.35 0.67 15,119.33 MWD+IFR2+MS+sag(5) 18,153.64 89.54 324.02 6,338.72 6,338.72 14,349.62 -5,077.40 6,045,505.09 464,886.90 1.12 15,212.64 MWD+IFR2+MS+sag(5) 18,248.97 90.34 322.67 6,338.82 6,338.82 14,426.09 -5,134.31 6,045,581.79 464,830.31 1.65 15,304.62 MWD+IFR2+MS+sag(5) 18,345.48 90.28 321.61 6,338.30 6,338.30 14,502.29 -5,193.54 6,045,658.22 464,771.39 1.10 15,397.19 MWD+IFR2+MS+sag(5) 18,441.43 89.73 321.42 6,338.29 6,338.29 14,577.39 -5,253.25 6,045,733.56 464,711.99 0.61 15,488.92 MWD+IFR2+MS+sag(5) 18,539.04 90.41 321.48 6,338.17 6,338.17 14,653.73 -5,314.08 6,045,810.13 464,651.48 0.70 15,582.20 MWD+IFR2+MS+sag(5) 18,634.39 90.41 321.97 6,337.49 6,337.49 14,728.58 -5,373.14 6,045,885.21 464,592.73 0.51 15,673.46 MWD+IFR2+MS+sag(5) 11/5/2013 2:43:01PM Page 7 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-04 PN5 ext Survey Calculation Method: Minimum Curvature Design: ODSN-04 PN5 ext Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVDSS TVD +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 18,727.00 91.27 321.89 6,336.13 6,336.13 14,801.48 -5,430.24 6,045,958.34 464,535.93 0.93 15,762.18 MWD+IFR2+MS+sag(5) 18,827.60 90.65 321.98 6,334.45 6,334.45 14,880.67 -5,492.26 6,046,037.77 464,474.24 0.62 15,858.56 MWD+IFR2+MS+sag(5) 18,924.04 90.65 321.62 6,333.35 6,333.35 14,956.46 -5,551.89 6,046,113.79 464,414.92 0.37 15,950.89 MWD+IFR2+MS+sag(5) 19,019.72 91.02 323.51 6,331.96 6,331.96 15,032.42 -5,610.04 6,046,189.98 464,357.08 2.01 16,042.85 MWD+IFR2+MS+sag(5) 19,115.71 90.90 322.57 6,330.35 6,330.35 15,109.11 -5,667.75 6,046,266.89 464,299.69 0.99 16,135.32 MWD+IFR2+MS+sag(5) 19,211.89 90.90 319.40 6,328.84 6,328.84 15,183.82 -5,728.28 6,046,341.84 464,239.47 3.30 16,226.98 MWD+IFR2+MS+sag(5) 19,308.52 91.39 319.05 6,326.91 6,326.91 15,256.98 -5,791.38 6,046,415.25 464,176.68 0.62 16,318.14 MWD+IFR2+MS+sag(5) 19,403.12 91.40 318.83 6,324.61 6,324.61 15,328.29 -5,853.50 6,046,486.80 464,114.85 0.23 16,407.22 MWD+IFR2+MS+sag(5) 19,500.25 91.21 319.05 6,322.39 6,322.39 15,401.51 -5,917.28 6,046,560.27 464,051.37 0.30 16,498.68 MWD+IFR2+MS+sag(5) 19,596.01 92.38 319.94 6,319.39 6,319.39 15,474.28 -5,979.44 6,046,633.29 463,989.51 1.53 16,589.13 MWD+IFR2+MS+sag(5) 19,692.19 92.63 319.86 6,315.19 6,315.19 15,547.78 -6,041.34 6,046,707.03 463,927.92 0.27 16,680.17 MWD+IFR2+MS+sag(5) 19,783.79 92.94 319.38 6,310.74 6,310.74 15,617.48 -6,100.61 6,046,776.96 463,868.94 0.62 16,766.70 MWD+IFR2+MS+sag(5) 19,868.00 92.94 319.38 6,306.42 6,306.42 15,681.31 -6,155.36 6,046,841.01 463,814.45 0.00 16,846.13 PROJECTED to TD 11/52013 2:43:01PM Page 8 COMPASS 5000.1 Build 61 • III Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-4 PN5 ext PB1 50703626717000 Sperry Drilling Services Definitive Survey Report 00 t 05 November, 2013 HALLIBURTON • ■ f`'• Sperry Drilling Services Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-4 PN5 ext PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-4 PN5 ext PB1 Database: EDMAKPRD 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-4 Well Position +N/-S 0.00 usft Northing: 6,031,136.46 usfl Latitude: 70°29'46.09 N +E/-W 0.00 usft Easting: 469,905.67 usfl Longitude: 150° 14'45.90 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 13.50 usft Wellbore ODSN-4 PN5 ext 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-4 PN5 ext PB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 42.70 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) -13.50 0.00 0.00 338.46 Survey Program Date 11/5/2013 From To Survey (usft) (usft) Survey(Wellbore) Tool Name Description Start Date 112.00 732.00 ODSN-4 Gyro Survey(ODSN-4 PN5 ext SRG-SS Surface readout gyro single shot 03/24/2013 774.62 5,284.00 ODSN-4 MWD(ODSN-4 PN5 ext PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 03/25/2013 5,284.00 10,365.00 ODSN-4 MWD(ODSN-4 PN5 ext PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 03/25/2013 10,365.00 12,714.30 ODSN-4 MWD(ODSN-4 PN5 ext PB1) MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 03/25/2013 12,714.30 12,986.00 ODSN-4 MWD SC(no checkshots)(ODE MWD+IFR2+SC+sag Fixed:v2:IIFR dec&axial correction+sag 08/21/2013 13,013.79 14,751.21 ODSN-4 MWD#2(ODSN-4 PN5 ext PB1 MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10/07/2013 Survey Map Map Vertical MD Inc Azi TVDSS ND +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 42.70 0.00 0.00 -13.50 -13.50 0.00 0.00 6,031,136.46 469,905.67 0.00 0.00 UNDEFINED 112.00 0.48 26.30 55.80 55.80 0.26 0.13 6,031,136.72 469,905.80 0.69 0.19 SRG-SS(1) 174.00 1.19 320.91 117.79 117.79 0.99 -0.16 6,031,137.45 469,905.51 1.75 0.98 SRG-SS(1) 201.00 1.94 309.55 144.78 144.78 1.50 -0.69 6,031,137.96 469,904.98 2.99 1.65 SRG-SS(1) 263.00 2.42 301.95 206.74 206.74 2.86 -2.61 6,031,139.33 469,903.07 0.90 3.62 SRG-SS(1) 356.00 4.89 284.85 299.54 299.54 4.92 -8.11 6,031,141.41 469,897.58 2.87 7.55 SRG-SS(1) 448.00 7.48 301.23 391.01 391.01 9.03 -17.02 6,031,145.56 469,888.69 3.38 14.65 SRG-SS(1) 541.00 11.08 306.95 482.78 482.78 17.54 -29.34 6,031,154.12 469,876.40 3.99 27.09 SRG-SS(1) 637.00 16.68 305.79 575.94 575.94 31.15 -47.91 6,031,167.81 469,857.89 5.84 46.57 SRG-SS(1) 732.00 20.18 307.43 666.05 666.05 49.09 -71.99 6,031,185.84 469,833.89 3.72 72.09 SRG-SS(1) 11/5/2013 2:34:04PM Page 2 COMPASS 5000.1 Build 61 • Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-4 PN5 ext PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-4 PN5 ext PB1 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVDSS TVD +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (11001 (ft) Survey Tool Name 774.62 22.52 311.69 705.74 705.74 58.99 -83.92 6,031,195.78 469,822.00 6.58 85.68 MWD+IFR2+MS+sag(2) 870.41 25.53 307.68 793.23 793.23 83.82 -113.97 6,031,220.73 469,792.06 3.57 119.81 MWD+IFR2+MS+sag(2) 965.82 25.86 306.69 879.21 879.21 108.82 -146.92 6,031,245.86 469,759.20 0.57 155.16 MWD+IFR2+MS+sag(2) 1,060.78 27.64 303.55 964.01 964.01 133.37 -181.89 6,031,270.55 469,724.34 2.39 190.83 MWD+IFR2+MS+sag(2) 1,158.91 31.45 307.91 1,049.37 1,049.37 161.69 -221.08 6,031,299.03 469,685.27 4.46 231.57 MWD+IFR2+MS+sag(2) 1,253.31 31.34 310.24 1,129.95 1,129.95 192.68 -259.25 6,031,330.17 469,647.23 1.29 274.41 MWD+IFR2+MS+sag(2) 1,346.25 31.25 316.29 1,209.39 1,209.39 225.73 -294.37 6,031,363.36 469,612.25 3.38 318.04 MWD+IFR2+MS+sag(2) 1,441.64 33.89 322.68 1,289.80 1,289.80 264.78 -327.60 6,031,402.54 469,579.17 4.54 366.57 MWD+IFR2+MS+sag(2) 1,539.14 34.36 327.67 1,370.53 1,370.53 309.66 -358.80 6,031,447.54 469,548.16 2.91 419.77 MWD+IFR2+MS+sag(2) 1,629.82 33.18 331.63 1,445.91 1,445.91 353.12 -384.28 6,031,491.10 469,522.86 2.75 469.55 MWD+IFR2+MS+sag(2) 1,726.75 36.11 338.96 1,525.68 1,525.68 403.15 -407.16 6,031,541.21 469,500.19 5.25 524.48 MWD+IFR2+MS+sag(2) 1,818.84 36.88 343.11 1,599.73 1,599.73 454.93 -424.93 6,031,593.06 469,482.63 2.81 579.17 MWD+IFR2+MS+sag(2) 1,917.03 41.42 348.78 1,675.88 1,675.88 515.03 -439.82 6,031,653.21 469,467.98 5.88 640.54 MWD+IFR2+MS+sag(2) 2,010.33 43.80 350.53 1,744.54 1,744.54 577.16 -451.14 6,031,715.39 469,456.91 2.85 702.49 MWD+IFR2+MS+sag(2) 2,104.90 46.99 351.69 1,810.94 1,810.94 643.68 -461.53 6,031,781.93 469,446.80 3.48 768.17 MWD+IFR2+MS+sag(2) 2,201.72 48.91 352.43 1,875.79 1,875.79 714.88 -471.45 6,031,853.17 469,437.16 2.06 838.05 MWD+IFR2+MS+sag(2) 2,297.04 50.46 352.48 1,937.46 1,937.46 786.93 -480.99 6,031,925.25 469,427.91 1.63 908.57 MWD+IFR2+MS+sag(2) 2,389.45 54.12 353.13 1,993.97 1,993.97 859.45 -490.14 6,031,997.80 469,419.06 4.00 979.38 MWD+IFR2+MS+sag(2) 2,486.35 56.99 354.61 2,048.78 2,048.78 938.89 -498.65 6,032,077.27 469,410.87 3.22 1,056.40 MWD+IFR2+MS+sag(2) 2,579.35 60.23 355.02 2,097.21 2,097.21 1,017.94 -505.82 6,032,156.34 469,404.02 3.50 1,132.57 MWD+IFR2+MS+sag(2) 2,675.53 59.59 354.48 2,145.43 2,145.43 1,100.81 -513.43 6,032,239.23 469,396.75 0.82 1,212.44 MWD+IFR2+MS+sag(2) 2,770.12 64.22 353.33 2,189.96 2,189.96 1,183.76 -522.31 6,032,322.21 469,388.21 5.01 1,292.85 MWD+IFR2+MS+sag(2) 2,861.85 66.78 356.02 2,228.01 2,228.01 1,266.85 -530.03 6,032,405.32 469,380.82 3.86 1,372.98 MWD+IFR2+MS+sag(2) 2,957.20 66.70 354.94 2,265.66 2,265.66 1,354.18 -536.94 6,032,492.67 469,374.27 1.04 1,456.74 MWD+IFR2+MS+sag(2) 3,053.86 64.00 352.89 2,305.98 2,305.98 1,441.52 -546.23 6,032,580.04 469,365.33 3.39 1,541.40 MWD+IFR2+MS+sag(2) 3,147.12 63.78 351.99 2,347.02 2,347.02 1,524.54 -557.25 6,032,663.09 469,354.65 0.90 1,622.66 MWD+IFR2+MS+sag(2) 3,241.30 63.71 353.29 2,388.68 2,388.68 1,608.30 -568.07 6,032,746.89 469,344.17 1.24 1,704.55 MWD+IFR2+MS+sag(2) 3,337.04 63.45 353.54 2,431.28 2,431.28 1,693.48 -577.90 6,032,832.10 469,334.69 0.36 1,787.39 MWD+IFR2+MS+sag(2) 3,431.96 64.04 354.11 2,473.27 2,473.27 1,778.11 -587.06 6,032,916.76 469,325.87 0.82 1,869.47 MWD+IFR2+MS+sag(2) 3,526.22 64.68 354.57 2,514.06 2,514.06 1,862.67 -595.44 6,033,001.35 469,317.84 0.81 1,951.20 MWD+IFR2+MS+sag(2) 3,620.86 65.21 353.55 2,554.14 2,554.14 1,947.95 -604.31 6,033,086.64 469,309.31 1.13 2,033.78 MWD+IFR2+MS+sag(2) 3,716.97 64.70 353.40 2,594.83 2,594.83 2,034.46 -614.21 6,033,173.18 469,299.77 0.55 2,117.88 MWD+IFR2+MS+sag(2) 3,812.31 63.59 351.70 2,636.41 2,636.41 2,119.52 -625.32 6,033,258.29 469,288.99 1.98 2,201.09 MWD+IFR2+MS+sag(2) 3,907.31 64.94 352.84 2,677.66 2,677.66 2,204.32 -636.83 6,033,343.12 469,277.83 1.79 2,284.19 MWD+IFR2+MS+sag(2) 4,002.73 66.49 353.60 2,716.90 2,716.90 2,290.68 -647.09 6,033,429.52 469,267.92 1.78 2,368.29 MWD+IFR2+MS+sag(2) 4,097.78 65.80 352.86 2,755.34 2,755.34 2,377.01 -657.34 6,033,515.87 469,258.02 1.02 2,452.34 MWD+IFR2+MS+sag(2) 4,192.46 64.58 353.57 2,795.07 2,795.07 2,462.34 -667.49 6,033,601.24 469,248.22 1.46 2,535.45 MWD+IFR2+MS+sag(2) 4,286.51 64.15 353.45 2,835.76 2,835.76 2,546.59 -677.08 6,033,685.52 469,238.97 0.47 2,617.33 MWD+IFR2+MS+sag(2) 4,382.61 61.86 353.42 2,879.38 2,879.38 2,631.66 -686.87 6,033,770.61 469,229.53 2.38 2,700.05 MWD+IFR2+MS+sag(2) 4,478.55 62.40 353.32 2,924.22 2,924.22 2,715.90 -696.66 6,033,854.89 469,220.08 0.57 2,782.00 MWD+IFR2+MS+sag(2) 11/512013 2:34:04PM Page 3 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-4 PN5 ext PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-4 PN5 ext PB1 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVDSS TVD +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 4,572.77 62.63 355.68 2,967.71 2,967.71 2,799.09 -704.67 6,033,938.11 469,212.41 2.24 2,862.33 MWD+IFR2+MS+sag(2) 4,668.11 63.59 356.26 3,010.83 3,010.83 2,883.91 -710.64 6,034,022.94 469,206.78 1.14 2,943.42 MWD+IFR2+MS+sag(2) 4,763.20 63.42 354.83 3,053.26 3,053.26 2,968.76 -717.25 6,034,107.80 469,200.51 1.36 3,024.76 MWD+IFR2+MS+sag(2) 4,857.09 63.74 353.78 3,095.03 3,095.03 3,052.42 -725.60 6,034,191.49 469,192.51 1.06 3,105.65 MWD+IFR2+MS+sag(2) 4,952.65 64.20 353.35 3,136.97 3,136.97 3,137.75 -735.22 6,034,276.85 469,183.23 0.63 3,188.55 MWD+IFR2+MS+sag(2) 5,048.13 64.16 352.56 3,178.56 3,178.56 3,223.05 -745.76 6,034,362.18 469,173.04 0.75 3,271.76 MWD+IFR2+MS+sag(2) 5,143.34 63.18 351.98 3,220.78 3,220.78 3,307.60 -757.24 6,034,446.77 469,161.90 1.17 3,354.62 MWD+IFR2+MS+sag(2) 5,238.40 64.12 352.00 3,262.98 3,262.98 3,391.95 -769.11 6,034,531.16 469,150.38 0.99 3,437.44 MWD+IFR2+MS+sag(2) 5,320.00 64.14 353.52 3,298.58 3,298.58 3,464.79 -778.36 6,034,604.03 469,141.42 1.68 3,508.59 MWD+IFR2+MS+sag(3) 5,371.78 63.74 353.06 3,321.33 3,321.33 3,510.98 -783.79 6,034,650.24 469,136.17 1.11 3,553.55 MWD+IFR2+MS+sag(3) 5,467.39 64.21 354.99 3,363.28 3,363.28 3,596.43 -792.73 6,034,735.71 469,127.58 1.88 3,636.31 MWD+IFR2+MS+sag(3) 5,562.63 64.48 354.64 3,404.52 3,404.52 3,681.93 -800.49 6,034,821.23 469,120.17 0.44 3,718.69 MWD+IFR2+MS+sag(3) 5,657.38 64.74 354.41 3,445.15 3,445.15 3,767.13 -808.66 6,034,906.46 469,112.35 0.35 3,800.94 MWD+IFR2+MS+sag(3) 5,752.70 64.40 354.49 3,486.08 3,486.08 3,852.81 -816.99 6,034,992.17 469,104.37 0.36 3,883.70 MWD+IFR2+MS+sag(3) 5,847.78 64.21 354.38 3,527.30 3,527.30 3,938.09 -825.29 6,035,077.47 469,096.41 0.23 3,966.07 MWD+IFR2+MS+sag(3) 5,942.61 64.08 355.16 3,568.66 3,568.66 4,023.07 -833.07 6,035,162.47 469,088.97 0.75 4,047.97 MWD+IFR2+MS+sag(3) 6,036.56 63.79 354.83 3,609.94 3,609.94 4,107.14 -840.44 6,035,246.56 469,081.95 0.44 4,128.87 MWD+IFR2+MS+sag(3) 6,132.10 63.67 354.78 3,652.22 3,652.22 4,192.46 -848.19 6,035,331.91 469,074.54 0.13 4,211.08 MWD+IFR2+MS+sag(3) 6,224.71 63.87 355.21 3,693.15 3,693.15 4,275.22 -855.44 6,035,414.68 469,067.63 0.47 4,290.72 MWD+IFR2+MS+sag(3) 6,322.72 64.41 354.73 3,735.90 3,735.90 4,363.07 -863.17 6,035,502.56 469,060.25 0.71 4,375.28 MWD+IFR2+MS+sag(3) 6,417.83 64.55 355.10 3,776.88 3,776.88 4,448.57 -870.78 6,035,588.08 469,052.99 0.38 4,457.59 MWD+IFR2+MS+sag(3) 6,512.73 64.47 355.28 3,817.72 3,817.72 4,533.93 -877.96 6,035,673.46 469,046.15 0.19 4,539.63 MWD+IFR2+MS+sag(3) 6,607.37 63.79 354.03 3,859.02 3,859.02 4,618.71 -885.89 6,035,758.26 469,038.57 1.39 4,621.40 MWD+IFR2+MS+sag(3) 6,702.87 63.65 355.08 3,901.30 3,901.30 4,703.95 -894.02 6,035,843.53 469,030.79 1.00 4,703.68 MWD+IFR2+MS+sag(3) 6,798.37 63.09 354.25 3,944.11 3,944.11 4,788.95 -901.96 6,035,928.55 469,023.20 0.97 4,785.65 MWD+IFR2+MS+sag(3) 6,891.40 63.14 354.45 3,986.18 3,986.18 4,871.52 -910.13 6,036,011.14 469,015.36 0.20 4,865.46 MWD+IFR2+MS+sag(3) 6,987.87 63.30 355.19 4,029.64 4,029.64 4,957.29 -917.90 6,036,096.94 469,007.94 0.70 4,948.09 MWD+IFR2+MS+sag(3) 7,083.12 63.54 355.18 4,072.26 4,072.26 5,042.18 -925.05 6,036,181.84 469,001.13 0.25 5,029.67 MWD+IFR2+MS+sag(3) 7,177.84 64.08 355.96 4,114.07 4,114.07 5,126.92 -931.61 6,036,266.60 468,994.91 0.93 5,110.90 MWD+IFR2+MS+sag(3) 7,270.68 64.35 356.37 4,154.45 4,154.45 5,210.32 -937.20 6,036,350.02 468,989.66 0.49 5,190.54 MWD+IFR2+MS+sag(3) 7,366.93 64.21 356.49 4,196.22 4,196.22 5,296.87 -942.60 6,036,436.58 468,984.61 0.18 5,273.02 MWD+IFR2+MS+sag(3) 7,461.72 64.42 356.15 4,237.31 4,237.31 5,382.12 -948.09 6,036,521.84 468,979.47 0.39 5,354.33 MWD+IFR2+MS+sag(3) 7,556.46 64.01 354.30 4,278.52 4,278.52 5,467.12 -955.19 6,036,606.86 468,972.72 1.81 5,436.00 MWD+IFR2+MS+sag(3) 7,651.42 63.80 356.32 4,320.29 4,320.29 5,552.11 -962.16 6,036,691.87 468,966.09 1.92 5,517.62 MWD+IFR2+MS+sag(3) 7,747.28 64.07 355.71 4,362.41 4,362.41 5,638.01 -968.14 6,036,777.79 468,960.45 0.64 5,599.72 MWD+IFR2+MS+sag(3) 7,840.95 64.37 355.62 4,403.15 4,403.15 5,722.12 -974.52 6,036,861.91 468,954.42 0.33 5,680.29 MWD+IFR2+MS+sag(3) 7,934.71 64.27 354.35 4,443.78 4,443.78 5,806.29 -961.91 6,036,946.11 468,947.37 1.23 5,761.30 MWD+IFR2+MS+sag(3) 8,028.65 64.00 353.91 4,484.76 4,484.76 5,890.38 -990.55 6,037,030.22 468,939.07 0.51 5,842.68 MWD+IFR2+MS+sag(3) 8,124.90 64.34 353.97 4,526.70 4,526.70 5,976.53 -999.70 6,037,116.39 468,930.27 0.36 5,926.18 MWD+IFR2+MS+sag(3) 8,221.76 64.22 354.44 4,568.74 4,568.74 6,063.35 -1,008.51 6,037,203.24 468,921.82 0.45 6,010.16 MWD+IFR2+MS+sag(3) 11/52013 2:34:04PM Page 4 COMPASS 5000.1 Build 61 Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-4 PN5 ext PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-4 PN5 ext PB1 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVDSS TVD +N/-S +E/-W Northing Easting DLS Section (usft) (°) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,316.01 64.42 354.12 4,609.58 4,609.58 6,147.86 -1,016.97 6,037,287.78 468,913.69 0.37 6,091.89 MWD+IFR2+MS+sag(3) 8,408.97 64.22 354.57 4,649.86 4,649.86 6,231.23 -1,025.23 6,037,371.18 468,905.78 0.49 6,172.47 MWD+IFR2+MS+sag(3) 8,504.62 64.20 353.81 4,691.48 4,691.48 6,316.91 -1,033.95 6,037,456.88 468,897.41 0.72 6,255.36 MWD+IFR2+MS+sag(3) 8,601.35 63.93 354.45 4,733.78 4,733.78 6,403.44 -1,042.84 6,037,543.44 468,888.86 0.66 6,339.12 MWD+IFR2+MS+sag(3) 8,696.80 63.68 354.20 4,775.92 4,775.92 6,488.67 -1,051.31 6,037,628.69 468,880.74 0.35 6,421.50 MWD+IFR2+MS+sag(3) 8,791.47 64.07 354.30 4,817.60 4,817.60 6,573.24 -1,059.83 6,037,713.29 468,872.56 0.42 6,503.29 MWD+IFR2+MS+sag(3) 8,885.77 64.00 354.12 4,858.89 4,858.89 6,657.59 -1,068.38 6,037,797.66 468,864.35 0.19 6,584.89 MWD+IFR2+MS+sag(3) 8,980.14 63.85 354.26 4,900.37 4,900.37 6,741.92 -1,076.96 6,037,882.02 468,856.12 0.21 6,666.48 MWD+IFR2+MS+sag(3) 9,075.61 64.07 354.80 4,942.28 4,942.28 6,827.31 -1,085.14 6,037,967.43 468,848.29 0.56 6,748.91 MWD+IFR2+MS+sag(3) 9,169.87 63.87 354.70 4,983.65 4,983.65 6,911.65 -1,092.89 6,038,051.79 468,840.88 0.23 6,830.21 MWD+IFR2+MS+sag(3) 9,265.51 63.85 355.19 5,025.78 5,025.78 6,997.17 -1,100.45 6,038,137.34 468,833.66 0.46 6,912.53 MWD+IFR2+MS+sag(3) 9,360.79 64.09 355.19 5,067.60 5,067.60 7,082.49 -1,107.63 6,038,222.67 468,826.83 0.25 6,994.53 MWD+IFR2+MS+sag(3) 9,455.74 64.36 355.55 5,108.88 5,108.88 7,167.71 -1,114.53 6,038,307.92 468,820.27 0.44 7,076.33 MWD+IFR2+MS+sag(3) 9,549.72 64.22 355.79 5,149.65 5,149.65 7,252.15 -1,120.93 6,038,392.37 468,814.22 0.27 7,157.22 MWD+IFR2+MS+sag(3) 9,647.28 63.95 355.49 5,192.29 5,192.29 7,339.64 -1,127.60 6,038,479.88 468,807.90 0.39 7,241.05 MWD+IFR2+MS+sag(3) 9,742.22 64.02 355.76 5,233.93 5,233.93 7,424.71 -1,134.11 6,038,564.97 468,801.74 0.27 7,322.57 MWD+IFR2+MS+sag(3) 9,837.04 64.41 355.17 5,275.18 5,275.18 7,509.82 -1,140.86 6,038,650.10 468,795.33 0.70 7,404.22 MWD+IFR2+MS+sag(3) 9,930.55 64.61 354.84 5,315.42 5,315.42 7,593.91 -1,148.21 6,038,734.21 468,788.33 0.38 7,485.13 MWD+IFR2+MS+sag(3) 10,026.77 64.14 355.21 5,357.03 5,357.03 7,680.34 -1,155.73 6,038,820.66 468,781.15 0.60 7,568.28 MWD+IFR2+MS+sag(3) 10,122.59 63.86 354.12 5,399.04 5,399.04 7,766.09 -1,163.74 6,038,906.43 468,773.49 1.06 7,650.98 MWD+IFR2+MS+sag(3) 10,215.44 64.07 353.96 5,439.79 5,439.79 7,849.07 -1,172.40 6,038,989.43 468,765.17 0.27 7,731.35 MWD+IFR2+MS+sag(3) 10,311.87 64.21 354.01 5,481.85 5,481.85 7,935.36 -1,181.49 6,039,075.75 468,756.43 0.15 7,814.95 MWD+IFR2+MS+sag(3) 10,342.37 64.22 354.05 5,495.12 5,495.12 7,962.68 -1,184.35 6,039,103.08 468,753.68 0.12 7,841.41 MWD+IFR2+MS+sag(3) 10,445.79 64.14 354.03 5,540.17 5,540.17 8,055.27 -1,194.02 6,039,195.70 468,744.39 0.08 7,931.08 MWD+IFR2+MS+sag(4) 10,538.73 64.13 354.41 5,580.71 5,580.71 8,138.47 -1,202.44 6,039,278.93 468,736.31 0.37 8,011.57 MWD+IFR2+MS+sag(4) 10,634.01 64.26 353.84 5,622.19 5,622.19 8,223.80 -1,211.22 6,039,364.28 468,727.87 0.56 8,094.16 MWD+IFR2+MS+sag(4) 10,729.76 64.56 353.43 5,663.54 5,663.54 8,309.62 -1,220.79 6,039,450.14 468,718.65 0.50 8,177.51 MWD+IFR2+MS+sag(4) 10,826.05 65.03 352.69 5,704.55 5,704.55 8,396.11 -1,231.32 6,039,536.65 468,708.47 0.85 8,261.82 MWD+IFR2+MS+sag(4) 10,920.84 65.38 353.91 5,744.30 5,744.30 8,481.57 -1,241.36 6,039,622.15 468,698.78 1.23 8,345.00 MWD+IFR2+MS+sag(4) 11,017.61 64.89 353.99 5,784.99 5,784.99 8,568.88 -1,250.61 6,039,709.48 468,689.88 0.51 8,429.61 MWD+IFR2+MS+sag(4) 11,112.57 65.10 352.26 5,825.14 5,825.14 8,654.32 -1,260.92 6,039,794.95 468,679.92 1.67 8,512.86 MWD+IFR2+MS+sag(4) 11,207.52 64.90 351.35 5,865.26 5,865.26 8,739.49 -1,273.18 6,039,880.17 468,668.00 0.89 8,596.59 MWD+IFR2+MS+sag(4) 11,302.45 65.05 351.28 5,905.42 5,905.42 8,824.52 -1,286.17 6,039,965.24 468,655.36 0.17 8,680.45 MWD+IFR2+MS+sag(4) 11,397.89 65.03 351.69 5,945.70 5,945.70 8,910.09 -1,298.98 6,040,050.86 468,642.90 0.39 8,764.75 MWD+IFR2+MS+sag(4) 11,492.65 64.96 351.62 5,985.75 5,985.75 8,995.06 -1,311.45 6,040,135.87 468,630.78 0.10 8,848.36 MWD+IFR2+MS+sag(4) 11,588.46 65.31 346.93 6,026.05 6,026.05 9,080.44 -1,327.62 6,040,221.30 468,614.95 4.46 8,933.71 MWD+IFR2+MS+sag(4) 11,683.69 65.92 343.81 6,065.38 6,065.38 9,164.35 -1,349.53 6,040,305.29 468,593.38 3.05 9,019.80 MWD+IFR2+MS+sag(4) 11,778.82 67.22 342.65 6,103.21 6,103.21 9,247.91 -1,374.72 6,040,388.95 468,568.54 1.77 9,106.78 MWD+IFR2+MS+sag(4) 11,873.85 69.30 342.06 6,138.40 6,138.40 9,332.03 -1,401.48 6,040,473.16 468,542.12 2.26 9,194.85 MWD+IFR2+MS+sag(4) 11,968.41 71.04 341.11 6,170.48 6,170.48 9,416.42 -1,429.58 6,040,557.66 468,514.36 2.07 9,283.66 MWD+IFR2+MS+sag(4) 11/5/2013 2:34:04PM Page 5 COMPASS 5000.1 Build 61 r Pioneer Natural Resources Definitive Survey Report Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: Mean Sea Level Site: Oooguruk Drill Site MD Reference: 42.7+13.5'@ 56.20usft(Nabors 19AC) Well: ODSN-4 North Reference: True Wellbore: ODSN-4 PN5 ext PB1 Survey Calculation Method: Minimum Curvature Design: ODSN-4 PN5 ext PB1 Database: EDMAKPRD Survey Map Map Vertical MD Inc Azi TVDSS TVD +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 12,057.59 73.05 339.73 6,197.97 6,197.97 9,496.34 -1,458.01 6,040,637.69 468,486.26 2.69 9,368.44 MWD+IFR2+MS+sag(4) 12,155.55 73.49 336.61 6,226.18 6,226.18 9,583.41 -1,492.90 6,040,724.89 468,451.73 3.08 9,462.24 MWD+IFR2+MS+sag(4) 12,254.12 75.42 335.60 6,252.59 6,252.59 9,670.23 -1,531.36 6,040,811.86 468,413.62 2.19 9,557.12 MWD+IFR2+MS+sag(4) 12,347.92 77.33 333.11 6,274.69 6,274.69 9,752.40 -1,570.82 6,040,894.17 468,374.50 3.29 9,648.03 MWD+IFR2+MS+sag(4) 12,443.74 79.46 331.19 6,293.97 6,293.97 9,835.38 -1,614.67 6,040,977.32 468,330.99 2.97 9,741.31 MWD+IFR2+MS+sag(4) 12,538.91 80.33 330.11 6,310.67 6,310.67 9,917.04 -1,660.59 6,041,059.16 468,285.40 1.44 9,834.14 MWD+IFR2+MS+sag(4) 12,634.53 82.15 328.07 6,325.23 6,325.23 9,998.11 -1,709.14 6,041,140.42 468,237.19 2.84 9,927.37 MWD+IFR2+MS+sag(4) 12,714.27 84.51 325.58 6,334.49 6,334.49 10,064.39 -1,752.47 6,041,206.87 468,194.13 4.29 10,004.93 MWD+IFR2+MS+sag(4) 12,722.03 84.47 325.84 6,335.24 6,335.24 10,070.77 -1,756.82 6,041,213.27 468,189.80 3.37 10,012.46 MWD+IFR2+SC+sag(5) 12,818.82 85.96 322.11 6,343.31 6,343.31 10,148.76 -1,813.54 6,041,291.48 468,133.41 4.14 10,105.83 MWD+IFR2+SC+sag(5) 12,914.81 84.78 322.05 6,351.06 6,351.06 10,224.24 -1,872.34 6,041,367.18 468,074.92 1.23 10,197.62 MWD+IFR2+SC+sag(5) 12,944.74 84.28 321.89 6,353.91 6,353.91 10,247.71 -1,890.69 6,041,390.72 468,056.66 1.75 10,226.19 MWD+IFR2+SC+sag(5) 13,013.79 84.94 322.54 6,360.40 6,360.40 10,302.04 -1,932.81 6,041,445.22 468,014.77 1.34 10,292.19 MWD+IFR2+MS+sag(6) 13,060.60 88.15 323.52 6,363.22 6,363.22 10,339.36 -1,960.91 6,041,482.65 467,986.83 7.17 10,337.22 MWD+IFR2+MS+sag(6) 13,112.77 90.07 324.18 6,364.03 6,364.03 10,381.48 -1,991.68 6,041,524.89 467,956.23 3.89 10,387.70 MWD+IFR2+MS+sag(6) 13,156.91 90.38 323.67 6,363.86 6,363.86 10,417.16 -2,017.67 6,041,560.67 467,930.39 1.35 10,430.43 MWD+IFR2+MS+sag(6) 13,253.77 90.26 322.62 6,363.32 6,363.32 10,494.66 -2,075.76 6,041,638.39 467,872.61 1.09 10,523.84 MWD+IFR2+MS+sag(6) 13,349.68 91.37 323.45 6,361.95 6,361.95 10,571.28 -2,133.43 6,041,715.24 467,815.26 1.45 10,616.29 MWD+IFR2+MS+sag(6) 13,445.77 89.68 319.44 6,361.07 6,361.07 10,646.40 -2,193.30 6,041,790.60 467,755.70 4.53 10,708.14 MWD+IFR2+MS+sag(6) 13,541.94 88.96 319.85 6,362.21 6,362.21 10,719.68 -2,255.57 6,041,864.12 467,693.74 0.86 10,799.17 MWD+IFR2+MS+sag(6) 13,635.88 90.62 320.51 6,362.56 6,362.56 10,791.83 -2,315.72 6,041,936.51 467,633.88 1.90 10,888.36 MWD+IFR2+MS+sag(6) 13,732.24 91.00 322.12 6,361.20 6,361.20 10,867.04 -2,375.95 6,042,011.95 467,573.97 1.72 10,980.43 MWD+IFR2+MS+sag(6) 13,828.85 91.31 320.06 6,359.25 6,359.25 10,942.19 -2,436.61 6,042,087.34 467,513.62 2.16 11,072.61 MWD+IFR2+MS+sag(6) 13,925.26 90.06 318.87 6,358.10 6,358.10 11,015.46 -2,499.26 6,042,160.85 467,451.27 1.79 11,163.76 MWD+IFR2+MS+sag(6) 14,023.18 88.26 317.63 6,359.53 6,359.53 11,088.50 -2,564.45 6,042,234.15 467,386.38 2.23 11,255.64 MWD+IFR2+MS+sag(6) 14,070.26 86.32 318.82 6,361.76 6,361.76 11,123.57 -2,595.78 6,042,269.34 467,355.20 4.83 11,299.76 MWD+IFR2+MS+sag(6) 14,118.30 87.29 319.64 6,364.43 6,364.43 11,159.89 -2,627.10 6,042,305.79 467,324.03 2.64 11,345.05 MWD+IFR2+MS+sag(6) 14,212.80 91.79 323.74 6,365.19 6,365.19 11,234.01 -2,685.66 6,042,380.14 467,265.78 6.44 11,435.48 MWD+IFR2+MS+sag(6) 14,264.39 90.67 322.64 6,364.09 6,364.09 11,275.30 -2,716.56 6,042,421.55 467,235.05 3.04 11,485.24 MWD+IFR2+MS+sag(6) 14,308.96 90.81 321.78 6,363.51 6,363.51 11,310.52 -2,743.87 6,042,456.88 467,207.88 1.95 11,528.02 MWD+IFR2+MS+sag(6) 14,405.58 91.55 322.42 6,361.52 6,361.52 11,386.74 -2,803.21 6,042,533.33 467,148.86 1.01 11,620.71 MWD+IFR2+MS+sag(6) 14,501.94 91.12 321.82 6,359.28 6,359.28 11,462.78 -2,862.35 6,042,609.60 467,090.03 0.77 11,713.15 MWD+IFR2+MS+sag(6) 14,599.02 91.12 320.07 6,357.38 6,357.38 11,538.15 -2,923.51 6,042,685.21 467,029.18 1.80 11,805.71 MWD+IFR2+MS+sag(6) 14,695.67 92.42 320.40 6,354.39 6,354.39 11,612.40 -2,985.30 6,042,759.71 466,967.70 1.39 11,897.47 MWD+IFR2+MS+sag(6) 14,751.21 93.04 321.27 6,351.75 6,351.75 11,655.42 -3,020.33 6,042,802.85 466,932.84 1.92 11,950.34 MWD+IFR2+MS+sag(6) 14,810.00 93.04 321.27 6,348.63 6,348.63 11,701.21 -3,057.06 6,042,848.80 466,896.30 0.00 12,006.42 PROJECTED to TD 11/52013 2:34:04PM Page 6 COMPASS 5000.1 Build 61 ' V OF T4, %s, THE STATE Alaska Oil and Gas 1 °fALAS]��A Coiiservatio Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Alex Vaughan Sr. Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field,Nuiqsut Oil Pool, ODSN-04 Sundry Number: 313-450 Dear Mr. Vaughan: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, Cb-gi Cathy P. Foerster Chair • DATED this day of August, 2013. Encl. , aiy. r\7 , ti „.:.,. .. STATE OF ALASKA it) t i .;: ., ,, , ALASKA OIL AND GAS CONSERVATION COMMISSION D� 8'!231!3 APPLICATION FOR SUNDRY APPROVALS 14,4 r f; f T? 20 MC 25.280 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❑ I Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Pioneer Natural Resources Alaska,Inc. Exploratory ❑ Development [] + 213-037 3.Address: 700 G Street,Suite 600 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99501 50-703-20670-00-00. 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A ODSN-04• Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 389958/ADL 389959 . 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): 12,285' 6316' 12,285' 6316' N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5244' 11-3/4" 5284' 3339' 5830 psi 3180 psi Intermediate 1 5260' 9-5/8" 5105'-10,365' 3260'-5561' 5750 psi 3090 psi Intermediate 2 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Liner Top Packer 5132'MD/3272'TVD 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q . Service ❑ 14.Estimated Date for 15.Well Status ya�r proposed work: Commencing Operations: 8/23/2013 Oil [1 I Gas•Lz❑rl WDSPL ❑ OpsSthutdown iv 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan,343-2186 Email alex.vaughan@pxd.com Printed NameAlex Vaughan Title Sr.Drilling Engineer Prepared By:Kathy Campoamor,343-2183 Signature - Phone Date 343-2186 8/20/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 515- 14 , Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: \\ e 4... t� , D,rrCc n o er.- -5 s a►171-241—c-‘10 . RBr 5 t. OCT 1 0 201 Spacing Exception Required? Yes ❑ Nor/ Subsequent Form Required: /D - 4/Q7Cn:„. tt , e v APPROVED BY Approved by: ;� COMMISSIONER THE COMMISSION Date: g-?_ _13 / Submit Form and '$ Form 10-403( evised 1 2012) Approver pmsriciAmEhs from the date of approval. Attachments in Duplicate -1, 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 August 20, 2013 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 RE: Application for Operation Shutdown, ODSN-04 Permit to Drill #213-037 Surface Location: 3020' FSL, 1092' FEL, Sec 11, T13N, R7E, UM X = 469783.84, Y = 6031013.60, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Sundry Approval for an Operation Shutdown for ODSN-04 after setting the Intermediate2 casing. This request is intended to optimize PNRA's Drilling Schedule. PNRA will drill the 9-1/2" Intermediate2 hole of ODSN-04. Once the Intermediate2 casing is set on ODSN-04, PNRA will secure the well and perform an Operation Shutdown. The rig will move off of ODSN-04 for approximately 38 days. It is anticipated that the rig will move back on to ODSN-04 and resume operations as outlined in the approved Permit To Drill. 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 10-403 Application for Sundry Approval 20 AAC 25.280. 2) A revised summary of the drilling and completions operations. 3) A proposed schematic of the well condition at the time of the Operation Shutdown. Alaska Oil & Gas Conservation Commission - August 20, 2013 Page 2 of 2 The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Alex Vaughan, Operations Drilling Engineer (20 AAC 25.070) 907.343.2186 alex.vaughan@pxd.com 2) Geologic Data and Logs Paul Daggett, Operations Geologist (20 AAC 25.071) 907.343.2134 paul.daggettCa pxd.com The anticipated date to resume drilling is August 23, 2013. If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. Sincerely, Alex Vaughan Sr. Drilling Engineer Attachments: Form 10-403 Supporting sundry information cc: ODSN-04 Well File Pioneer Natural Resources Well Plan Operations Shutdown Summary, ODSN-04 A temporary operation shutdown is planned after drilling the 8-1/2" x 9-1/2" Intermediate 2 Hole section and running and cementing the 7" Iongstring Intermediate 2 casing. Rig Activity: Temporary Operations Shutdown: 1. RIH with 2300' of 2-7/8" tubing and land hanger with TWC installed. • Base of Permafrost —1834' MD 2. Pressure test 7" Intermediate casing to 3500 psi for 30 minutes. Chart and send same to the Operations Drilling Engineer. 3. ND BOPE, NU Tree, Remove TWC. 4. RDMO to ODSN-02. Post Rig: 1. Install surface circulation manifold. Circulate freeze protection fluid surface to surface to 2000' TVD (-2300' MD). Pioneer Natural Resources ODSN-04 Operations Shutdown Page 1 of 1 . ODSN-04 — Proposed Operation Shutdown after Int2 Updated 8/07/2013 1111111 ``& 16"Conductor • Packer Fluid mix. 11111111 Inhibited Kill weight Brine with 2000'TVD diesel can 7 11-3/4"60 ppf L-80 BTC-M Surface Casing @ 5284' MD/3339'TVD cemented to surface ■ �--� 9-5/8"40 ppf L-80 Hydril 521 Intermediate 1 Casing @ 10,365' MD/5561'TVD L.„-a (71 TOC Estimated 500'above top of Kuparuk 7"26 ppf L-80 BTC-Mod + Hydril 563 Intermediate 2 Casing @—13,105' MD/ 6425'TVD tbo J Z' 3 D -jv August 26, 2013 To: AOGCC From: Nabors 19AC Tool Pusher Subject: Updated Information Regarding Nabors 19AC BOPE Test on 8/12/2013 The initial BOPE Test for the N19AC Rig while on the ODSN-04Well was conducted on 8/12/2013 with Inspector Jeff Jones present to witness the test. During this test, the VBR's were tested for 2 7/8" & 5" test joints and the Annular Preventer was tested for 2 7/8" test joint. During the test it was discovered the off driller side lower and upper pipe ram tattletale holes were damp with hydraulic oil. It was also discovered the off driller side lower pipe rams cylinder to rod lock seal had hydraulic oil weeping. Complete bonnet seal kits were ordered with the intent to replace at the first opportunity. Subsequently, the BOPE was retested on August 23 for 5" drill pipe. The complete replacement seal kits were not yet received; however, during this testing there was no sign of hydraulic oil leaking at the lower or upper pipe ram tattletale holes nor was there any hydraulic oil weeping at the lower pipe ram cylinder lock seals. The complete bonnet seal kits were promptly ordered; however, these parts were not - received into the rig's inventory until the day following the August 231.9-3-0-PE test. The Nabors Tool Pusher talked to the Hydril Representative in Anchorage regarding this issue. The representative stated these leaks even if they were still present would have no affect on the proper functioning of the rams and their ability to control the well. Consequently, the Nabors Tool Pusher has scheduled the Hydril Representative to arrive at the rig site on Wednesday, August 28 to oversee and perform the repairs on the rod lock seal. The mud wiper seals will also be replaced at his time. The rig is currently running 7" casing on the ODSN-04 Well after which time the well will be suspended. The BOPE seal repair work scope described above will be performed prior to moving the rig and resuming well work operations on the ODSN-02 Well. Mark Ashley, Tool Pusher, Nabors 19AC STATE OF ALASKA Af (A OIL AND GAS CONSERVATION CON SION ` • REPORT OF SUNDRY WELL OPERATIONS 1.GperationsAbandon Li Repair Well U Plug Perforations Ll Perforate L] Other LI Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown• Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: I Name: Pioneer Natural Resources Alaska, Inc Development ❑✓ . Exploratory❑ 213-037 ' 3.Address: 700 G Street,Suite 600 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99501 50-703-20670-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 355036/ADL 389958/ADL 389959 _ ODSN-04 • 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 10,375 feet Plugs measured N/A feet true vertical 5566' feet Junk measured N/A feet Effective Depth measured 10,363' feet Packer measured feet true vertical 5560' feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface 5244' 11-3/4" 5284' 3339' 5830 psi 3180 psi Intermediate) 5260' 9-5/8" 5105'-10,365' 3260'-5566' 5750 psi 3090 psi Intermediate2 Liner 1°:; 'z Perforation depth Measured depth N/A feet a - True Vertical depth feet A.O(3�^.l�C Tubing(size,grade,measured and true vertical depth) 2-7/8",6.5# L-80, BTC-M 2333'MD 2016'TVD Packers and SSSV(type,measured and true vertical depth) Liner Top (cit 5132'MD/327272''NO 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: Subsequent to operation: 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Q • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil L1 Gas L j WDSPL U GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 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: 313-158 Prepared By:Kathy Campoamor,343-2183 Contact Alex Vaughan,343-2184 Email alex.vauahan( Dxd.com Printed Name Alex Vaughan Title Sr.Drilling Engineer T/'` Signature �� - " Phone 343-2184 Date 5/20/2013 VX 1/vr N Form 10-404 Revised 10/2012 "/5li3 RBDMS MAY 2 3 2015 Submit Original Only . 7 PI 0 N E E R Operations Summary Report - St?", Well Name: ODSN-04 NATURAL RESOURCES Well Name:,ODSN-04 Contractor: NABORS DRILLING Rig Number: 19 AC Job Category: ORIG DRILL&COMPLETE Start Date: 3/22/2013 End Date: Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(lb/gal) Summary 3/21/2013 3/22/2013 0.0 Pull TWC, Install BPV as per Vetco rep. RD equipment and prep for Rig Move.Remove MPD Pump house.Move rig from ODSN-24 and position to dissemble stack. Disassemble the new stack and prepare to lift and set on BOP Stump. `Rig accepted 03/21/13 @ 00:01 hrs° 3/22/2013 3/23/2013 0.0 MU replacement Hydril BOPE.Move onto ODSN-04. Install Beaver Slide.Connect utility lines. Spot Sperry Gyro unit.Connect to HiLine Power.Receive Spud Mud from RSC to Mud Pits while adding cold lake water. 3/23/2013 3/24/2013 0.0 8.80 Remove completion running equipment from pipeshed and rig floor. NU riser,spacer spool and surface stack.Test seals and connections to 500 psi.RU 5"drillpipe equipment.Recieve 252 bbls of Spud mud from RSC to Rig pits.Load pipe shed with 5"drillpipe and MWD tools.LD 4" drillpipe from derrick. PU 5"drillpipe and rack back in derrick. 3/24/2013 3/25/2013 158.0 564.00 9.10 PU 5"drillpipe and HWDP singles from pipe shed and rack back in derrick.Slip and Cut Drill Line.RU ESP spool,Gyro unit and equipment.MU Conductor clean out assembly. Clean out Conductor f/39't/158'.Spud in with 14 1/2"Conductor Clean out assembly f/158't/226'.TOOH f/226't/Surface.Finish MU BHA#1 and directional drill f/226't/722'.Gyro survey on each connection. 3/25/2013 3/26/2013 722.0 1,805.00 9.30 Directional drill new 14-1/2"surface hole with BHA#1 f/722't/1,388'.Gyro survey each connection t/817' (Gyro on standby and released @1,600'MD).Rig Service.Directional drill w/ BHA#1 f/1,388't/2,337'. Circulate 25 BBL SAPP pill and performed soak sequence to address high overpull with pumps off--suspected balled up BHA with 150-175K overpull when pumps off PU restored to 125K. Rig Service.Directional drill surface hole w/BHA#1 f/2,337't12,527'. 3/26/2013 3/27/2013 2,527.0 574.00 9.40 Directional drill 14 1/2"surface hole f12,527't/2,816. Circulate for BHA change.TOOH to adjust motor from 1.84 to 1.15. Change out MWD and upsize 1.75 orifice to 1.80. Minor Swabbing incremental and overpull as high as 80K over through UGNU Sands and at base of permafrost -1,825'through to 1,600'. Pull BHA and Change out MWD-down load same. Check bit--ok to finish surface hole. Adjust motor to 1.15°. TIH t/2,816'MD and resume drilling. Stacked up at 225'MD and unable to fall through,pump 1 bpm and rotate 15 rpm and work pipe through. Continue TIH with intermittent and repeat stacking up with all the string weight which required rotation 15 rpm and pumps at 1bpm. Stubborn hole at 1,675'MD. Unable to progress with low rpm and flow rate,increased flow rate to 200 gpm,rpm to 40 and wash and ream to bottom. Took check shots to confirm new Directional Survey Tool at 2,196'and 2,669'. Directional drill f/2,816't/3,101'. 3/27/2013 3/28/2013 3,101.0 1,439.00 9.50 Directional drill 14 1/2"surface hole f/3,101'04,540'. Encountered Cretaceous Tuffs @ 4,336' MD. 3/28/2013 3/29/2013 4,540.0 754.00 9.50 Directional drill 14 1/2"surface hole f14,540't/5,294'. TD called by on-site geologist 43'TVD into the Hue 2 shale. Pump 50 bbl Hi-Visc weighted sweep--Significant increase in cuttings. CBU 2X while racking back 1 stand every 30-40 minutes. TOOH on elevators,tight @ 2,379'--70K over,wipe through with no pump or rotary.Tight @ 1,100'-unable to wipe through. Rotate 20 rpm and ream through with no pumps. Continue to trip to jars @ 162', hole taking proper displacement--not swabbing,no signs of excess clay on tool joints. TIH f/162'05,294'-tight @ 1,234'. Wipe through with no pump or rotary. PU single to reach TD. 3/29/2013 3/30/2013 5,294.0 0.00 9.55 Establish circulation using step rate method to 850 gpm at TD. Pump 50 bbl Hi-Visc weighted sweep. CBU 3X,racking back stand each BU. Spot 300 bbls of new mud. TOOH on elevators (/5,294't13,829'. Circulate and condition mud to YP-28. TOOH on elevators t/632'. LD BHA download same. RU TESCO equipment and RU floor to run casing. Run 59 joints of 11 3/4" 60#L-80 Hyd-521/BTC surface casing f/surface t12,403'as per tally. Baker lock shoe track and check floats. Torque turn every joint. No losses while running casing. Page 1/4 Report Printed: 5/21/2013 PI 0 N E E R Operations Summary Report - St".. Well Name: ODSN-04 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 3/30/2013 3/31/2013 5,294.0 0.00 9.70 RIH with a total of 129 joints of 11 3/4"L-80 Hyd-521/BTC 60#Surface casing,torque turn every joint. MU hanger and landing joint. Land surface casing @ 5,284'as per VG Rep. Break circulation using step rate method to 12 bpm. RD Tesco equipment and RU HES cement head. Hold PJSM while circulating @ 10 bpm. Perform Surface cement job: Line up cement head and pump 10 bbls sea water.Kick out bottom plug last 2 bbls. Pressure test pump and lines to 4000 psi. Bleed off and load top plug. Pump 100 bbls of 10.0 ppg Tuned spacer III with 0.2 gal/bbl Dual Spacer Surfactant B at 2.5 bpm, 145 psi. Drop second plug. Mix and pump 548 bbls(672 sx)of 11.1 ppg Type"L"Permafrost Lead Cement with 0.15%D-Air 5000P--Yield 4.36 ft/3. Mix and pump 132 bbls(629 sx)of 15.8 ppg Premium Class'G'Tail Cement with 1%CaCl2&0.2%CFR-3--Yield 1.18 ft/3. Drop top plug--Visual of plug away with tattle tail. Pump 17 bbls with cement pump at 6.7 bpm,234 psi. Turn over to rig for displacement: Rig displace 572 bbls at 10 bpm,ICP-433 psi, FCP-1,070 psi @ 3 bpm. Bump plug at calculated strokes and pressure to 3500 psi,hold for 5 minutes--Chart same. Bleed off pressure and check floats--Floats holding. Monitor well--Static. 238 bbls of cement to surface. **CIP @ 19:00 hrs.** RD cement head,clean under rotary,flush flow line. Flush and begin to ND surface drilling riser. *AOGCC Rep Bob Noble waive witness of BOP test on 03/30/2013 @ 6:30 hrs* 3/31/2013 4/1/2013 5,294.0 0.00 10.30 ND surface drilling riser and spool. NU drilling adaptor and riser. VG Rep pressure test void to 5000 psi. NU New BOP stack,HCR valves,and hydraulic fittings and lines. Install 2 7/8"X 5" VBR in upper and lower rams. Install blind rams. Adjust turnbuckles and test gas alarms. RU to test BOPE. Test BOPE per AOGCC PTD: Test upper and lower VBR w/5"test joint to 250 psi low/4500 psi high. Test upper and lower IBOP valves to 250 psi low/4500 psi high. Test annular w/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 tests held for 5 min. Initial system psi:3000—1950 after closure;200 psi=23 sec,full pressure 1 min.52 sec. Blow down top drive and kill line. Hydraulic leak found on blind ram door hinge while closing to test blinds. Trouble shoot and repair hydraulic leak on blind ram door hinge. Function test blind rams 3X with no hydraulic leaks. Pressure test blind rams to 250 psi low/4500 psi high—test good. RD test equipment. MU BHA#3 bit and motor. *AOGCC Rep.Bob Noble waived witness at 06:30 hrs on 03/30/2013* 4/1/2013 4/2/2013 5,294.0 0.00 10.30 MU and RIH with 11 3/4"surface clean out BHA#3. Tag stringer @ 4,872'. Circulate BU for casing test. Pressure test 11 3/4"Hyd-521/BTC 60#L-80 surface casing to 3500 psi for 30 minutes--chart same. Wash stringers to FC @ 5,187'. Drill cement float equipment,shoe track and clean rat hole t/5,294'. CBU. TOOH with BHA#3 f/5,294't/597'. LD BHA#3. Clear rig floor. MU 10 5/8"RSS MWD/LWD with XBat t/116'. Unable to download MWD tools. HES MWD Reps troubleshoot issues and contact office. 4/2/2013 4/3/2013 5,294.0 715.00 10.30 Troubleshoot MWD tools. POH and remove PCDC and replace with DM Collar. RIH with BHA #4 t/116'. Download MWD tools. Shallow test MWD--OK. Break in Geo-Pilot bearings. Load MWD nuclear sources. MU BHA#4 t/561'. TIH with BHA#4 t/5,215'. Fill pipe and check MWD tools @ 2,935'. Slip and cut 68'of drill line. TIH t15,294'. Break circulation and displace 9.7 ppg LSND with 10.3 ppg MOBM. Drill new 10 5/8"Intermediate#1 hole f/5,294't/5,314'. CBU. Perform FIT to 12.5 ppg EMW,hold for 10 minutes--Chart same. Directional drill 10 5/8" Intermediate#1 hole f/5,314't/6,009'@ 120'/hr ROP. CCU Geo-Pump motor shut down,Super Vac and cutting transfer line plug up. RSC/CCU and electrician trouble shoot Geo-Pump motor issues. 4/3/2013 4/4/2013 6,009.0 45.00 10.30 CCU/RSC troubleshoot electrical breaker on Geo-Pump motor, Un-plug Super Vac,and clear cutting transfer line. Resume drilling @ 60'/hr,drill 10 5/8"hole t16,054'. At 03:00 hrs,shut down cuttings transfer line plugged. CCU/RSC work on clearing line. Remove section of cuttings transfer line out side of RSC building that was plugged. Work on clearing/thawing line. Rig Crew: General housekeeping and maintenance. TOOH f/6,054't/5,210'--inside of surface casing. Hang SRL for man rider on crown. Load,drift,and strap 9 5/8"Intermediate#1 liner. Page 2/4 Report Printed: 5/21/2013 Operations Summary Report - Sty n Well Name: ODSN-04 PIONEER NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 4/4/2013 4/5/2013 6,054.0 1,157.00 10.25 RSC/CCU Clear cuttings transfer line with2"pipe. Apply suction from CCU Super Vac. Install sections of CTL that were removed. Circulate"Hot Purple Pill"through CTL. Able to move fluid through CTL,approx 25%of normal flow,line pressure still high 40 psi--normal pressure is 15- 30 psi. Circulate Purple Pill/Slurry through Slurry line to CCU back to RSC until line pressure back to normal 15-30 psi. TIH f/5,215'1/6,054'. CBU. Directional drill 10 5/8"Intermediate#1 hole f/6,054't17,211';750 gpm, 160 rpm, 110'/hr average ROP. Empty CCU hopper and circulate purple pill through slurry and cuttings transfer line every 500'. 4/5/2013 4/6/2013 7,211.0 1,929.00 10.25 Directional drill 10 5/8"Intermediate#1 hole f/7,211'1/9,125',750 gpm, 160 rpm, 125'/hr average ROP,with no losses. 4/6/2013 4/7/2013 9,140.0 1,235.00 10.35 Directional drill 10 5/8"Intermediate#1 f/9,125't/9,848'. Pack off @ 9,848'. Stage pumps and rotary to full rate. Circulate and condition hole to drilling parameters. Directional drill(/9,848' 1110,375'--TD called by onsite geologist. CBU 3X while working pipe f/10,375'1/10,147'. 4/7/2013 4/8/2013 10,375.0 0.00 10.30 TIH 1/10,375'. CBU 3X while working pipe f/10,375'1/10,147'. CBU 6X total. Monitor well-- Static. TOOH on elevators f/10,147'1/9,675". Low energy back ream 1/7,823'.MADD PASS log 1/7,823'1/5,533'@ 250'/hr,2 bpm,30 rpm. TOOH 1/5,215'. CBU while staging pumps to full rate, to reduce losing mud over shakers. 4/8/2013 4/9/2013 10,375.0 0.00 10.25 CBU at 725 gpm, 120-150 rpm in 11 3/4"casing 4-6 minutes a stand. Back ream out of hole 1/5,215'1/3,500',Service rig.Continue to backream f/3,500'1/1,000'. POOH 1/561'(BHA). LD BHA t/116'.Download MWD and continue LD BHA to surface.PU back up WFD reamer and bullnose.Drop opening RFID tags and verify reamer opened. Drop closing tags and verify reamer closed.Pull blank nozzles. Install 8/32"(3)nozzles in reamer.Continue to PU BHA#5 1/534'.RIH w/BHA#5 t/3,953'. 4/9/2013 4/10/2013 10,375.0 0.00 10.25 Continue to RIH w/BHA#5 f/3,953'1/5,278'(4'inside shoe). Fill pipe and break circulation slowly(thick mud)and stage up to 780 gpm,4100 psi.Drop RFID opening tags(4).Make connection and pump tags down-Obtain parameters.Slow rate to 300 gpm.Slackoff to±5,300' bullnose depth. Increase rate to 780 gpm,3700 psi(400 psi pressure drop).Pull test reamer against 11 3/4"shoe w/10k over pull.Obtain SPR.Begin reaming/hole opening(/5,285'w/750 gpm,3250 psi-180-200 fph.Stage pumps up to 805 gpm,3700 psi 150 rpm, 180-200 fph. f/5,350'U6,328'.Lost circulation/packed off after connection.PU U6,208'.Establish circulation and continue to hole opening 1/6,328'U6,735'.Observed 500 psi pressure loss.Check surface equipment.OK.Determined that probably lost a jet nozzle from bullnose.Obtain new parameters and continue reaming/hole opening f/6,735'1/7,125'w/800 gpm,3250 psi, 165 rpm. 4/10/2013 4/11/2013 10,375.0 0.00 10.20 Reaming/Hole opening f/7,125'119,368'. 4/11/2013 4/12/2013 10,375.0 0.00 10.20 Reaming/hole opening f/9,368'to TD at 10,375'.Drop reamer closing tags.CBU hole clean 7X while standing back 1 stand every 30 minutes f/10,375'1/9,463'. POOH on elevators f/9,463' 1/5,473'. NOTE:At 11:30 hrs,AOGCC was given notice of upcoming BOP test due on 04/14/13. 4/12/2013 4/13/2013 10,375.0 0.00 10.20 Attempt to pump out(no rotary)f/5,473'w/470 gpm.Observing losses of 42 bbls(no overpull). Backream w/470 gpm,2300 psi,40 rpm f/5,473'1/5,300'w/no losses observed.Stop rotary and pull into shoe while pumping 470 gpm to verify reamer blades closed.Well bled back±6 bbls after entering shoe. Backream in casing f/5,284'1/1,199'w/800 gpm,3500 psi-165 rpm.CBU 2x.POOH f/1,199'11534'(BHA).LD BHA to surface.PU 4 jts of HWDP and stand back in derrick. Drain stack. Install test plug.Change lower rams from 2 7/8"x 5"vbls to 9 5/8". Test BOPE per AOGCC PTD: Test lower rams w/9 5/8"test joint to 250 psi low/4500 psi high. Test upper VBR w/5"test joint to 250 psi low/4500 psi high. Test upper and lower IBOP valves to 250 psi low/4500 psi high. Test annular w/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 tests held for 5 min. Initial system psi:3000--1950 after closure;200 psi= 24 sec,full pressure 2 min. Blow down top drive and kill line. Upper 2 7/8"x 5"VBL's failed- Change out rams(2 7/8"x 5").Retest-Passed. *AOGCC Rep.Chuck Scheve waived witness on 04/12/2013 at 06:00 hrs* Page 3/4 Report Printed: 5/21/2013 PI 0 N E E R Operations Summary Report - Sta+Q Well Name: ODSN-04 NATURAL RESOURCES Start Depth Foot/Meters Dens Last Start Date End Date (ftKB) (ft) Mud(Ib/gal) Summary 4/13/2013 4/14/2013 10,375.0 0.00 10.20 Mobilize casing equipment to rig floor.PU 9-8"DC's(drift w/2 3/4").Stand back same in derrick. RU Tesco and Nabors casing tools. RU to run 9 5/8"liner.PU shoe track.Check floats. RIH w/9 5/8"40#L-80 Hyd.521 liner t13,288'.Circulate w/1 bpm.Continue to run 9 5/8"liner (/3,288't15,229'.Break circulation and CBU.RD Tesco and casing equipment. PU Weatherford liner hanger/packer assembly.RIH w/9 5/8"liner on 5"DP f/5,265't16,189'. Break circulation& circulate open hole volume. 4/14/2013 4/15/2013 10,375.0 0.00 10.20 Continue to RIH w/9 5/8"liner on 5"DP f/6,189'U±7550'(top of Brookian 2B).Break circulation. Pumped open hole volume.RIH f17,550'U10,365'. MU Weatherford cement head. Break circulation&stage up to 4 bpm, 1085 psi.Drop hanger setting ball and pump on seat w/6-7 bpm.Observe ball seat.Pressure up and set liner hanger.Pressure up and shear ball seat w/ 3500 psi.PU to string wt.Install 3 RH turns in string.Release torque and repeat process to release from hanger.PU and verify.Line up Halliburton cementers: Pump 10 bbls seawater. Pressure test lines to 4000 psi. Pump 60 bbls tuned spacer at 11.0 ppg. Pump 52 bbls(120 sx) Class'G'Lead Cement at 12.5 ppg(yield 2.42 CuFUSk)w/additives: 15 Ibm/sk Microlite-P, .75% HALAD(R)-344,.2%CFR-3, .15 Ibm/sk EZ-FLO&.25%SCR-100. Pump 41 bbls(178 sx) Class'G'Tail Cement at 15.8 ppg(yield 1.15 CuFUSk)w/additives: .5%HALAD(R)-344, .2% SCR-100&.2%CFR-3. Drop wiper plug and kick out w/20 bbls seawater. Displace cement w/ 450 bbls of 9.8 ppg brine using rig pumps.Bump plug and pressure up to 3500 psi.Hold pressure for 5 charted min.Bleed pressure and check floats-OK.CIP at 23:55 hrs.Top of liner at 5,105'. Liner shoe at 10,365'. Observed full returns during cement job&displacement. 4/15/2013 4/16/2013 10,375.0 0.00 9.80 LD cement head and pups.PU 14'to expose setting dogs.Tag top of liner-Rotate w/10 rpm and apply 50K down weight-Observe packer set. PU and repeat process 2X.Close top variable rams-Line up and test 11 3/4"x 9 5/8"liner lap to 3500 psi f/5 charted min-Good test. Displace well from liner top to surface w/9.8 ppg brine.LD 5"DP f/5,105'U surface. LD liner running tools. RIH w/3 stands of 8"DC's.LD same. RIH w/5"DP[/5,706'.Circulate pipe clean. POOH LDDP. Close blind rams and test 11 3/4"x 9 5/8"casing to 3500 psi for 30 charted min. Good test.Change bottom rams from 9 5/8"to 2 7/8"x 5"variables. Remove choke&kill line. 4/16/2013 4/17/2013 10,375.0 0.00 9.80 ND BOPE.Install VG Multi-Bowl.Test seals to 5000 psi.NU BOPE.Test upper&lower variable rams to 250 psi low/4500 psi high.Test annular to 250 psi low/2500 psi high for 5 charted minutes each test using 2 7/8"test jt.PU 204 jts of 5"DP from pipeshed.Flush same w/1 1/2 x DP volume.POOH standing back 5"DP.Service rig.Pull wear ring.RU and run 2 7/8"6.5#L-80 kill string to±160'. AOGCC was notified of upcoming Diverter test at 06:00 hrs on 04/17/13. 4/17/2013 4/18/2013 10,375.0 0.00 9.80 RIH w/2 7/8"6.5#L-80 BTC-M kill string f/160'to 2288'(75 jts).MU 3 1/2"x 2 7/8"XO.MU hanger.Drain stack.Land hanger in wellhead w/muleshoe at 2332'-RILDS.Vetco Rep tested hanger seals to 5000 psi-Good test.LD landing jt.RD tubing tongs&handling equip.ND BOPE and risers.NU Vetco Gray tree.Test void and tree to 5000 psi f/10 charted minutes.Secure well.Clean/clear wellbay.Slip new drilling line on blocks and draw-works. *Rig released from ODSN-04 at 23:59 hrs on 04/17/13* 4/18/2013 4/19/2013 10,375.0 0.00 9.80 Temporary Operation Shutdown Page 4/4 Report Printed: 5/21/2013 'ODSN-04 Proposed Operations Shutdown Updated 4/20/2013 AI ::::::::: 16"Conductor @ 158' MD Base Permafrost @ 1834' MD/1668'TVD € @ 2142' MD/2000'TVD w/Diesel 2-7/8", 6.5#, L-80 Killstring @ 2333' MD/2016'TVD / • f "" . "' 11-3/4" 60 ppf L-80 BTC-M >::.. Surface Casing @ 5284' MD / 3339' TVD Cemented to surface • Tested to 3500 psi /30 min. .•.:• f Seawater 9-5/8"40 ppf L-80 Hydril 521 Intermediate 1 Casing @ 10,365' MD/5566'TVD Tested to 3500 psi/30 min oF zit �w��\ I%%sv THE STATE A hska l and Gas .sty ~��'�� °fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue 04y, Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Alex Vaughan ���1 Sr. Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-04 Sundry Number: 313-158 Dear Mr. Vaughan: 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, Cathy . Foerster Chair DATED this'day of April, 2013. Encl. cb,k1' REr'- FR/ED STATE OF ALASKA t4A 1-7:57/3 0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug for Redrill 0 Perforate Nov Pod 0 Repair Well 0 Change Approved Program 0 Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension 0 Operations Shutdown in' Re-enter Susp.Well 0 Stimulate❑ Alter Casing 0 I Other. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Pioneer Natural Resources Alaska, Inc. Exploratory 0 Development p • 213-037• 3.Address: 700 G Street, Suite 600 Stratigraphic 0 Service ❑ 6.API Number. Anchorage,AK 99501 50-703-20670-00-00• 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? WA ODSN-04' Will planned perforations require a spacing exception? Yes 0 No Q 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 355036/ADL 389958 I ADL 389959• Oooguruk-Nuiqsut Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 4540' 3014' 4540' 3014' N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 158' 158' N/A N/A Surface Intermediate 1 Intermediate 2 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development Q• Service 0 14.Estimated Date for 15.Well Status after proposed work: 3/12/2013 Commencing Operations: Oil 0 Gas 0 WDSPL 0 Ops Shutdown Els 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Vaughan,343-2186 Email alex.vauahanaDxd.com Printed Name Alex Vaughan Title Sr. Drilling Engineer Prepared By:Kathy Campoamor,343-2183 Signature Phone Date 343-2186 3/28/2013 G------ COMMISSION USE ONLY Conditions of approval: Notify Com fission so that a representative may witness Sundry Number: 31 ( 5 Ux fy Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test 0 Location Clearance 0 Other: / r tiBDMS APR 0 8 2 P,IC -4" /V6- 1,. "-%n-/ Ce� t..SS i(r.-%.(r.-%. !�..--4,ry (G,Sf`4.✓A. 6rerc. dtiS. Spacing Exception Required? Yes 0 No © Subsequent Form Required: /Q —4/0(-/ pAPPROVED BY I---Approved by: 0 01 w COMMISSIONER THE COMMISSION Date: ' — �a—(3 Submit Form and v, d� (J:CF .l 1Approved application is valid for 12 months from the date of approval./6—,./.3./.? Attachments in Du licate �\ti\t- Pioneer Natural Resources Well Plan Operations Shutdown Summary Rig Activity: Operations Shutdown 1. RIH with enough 3-1/2" or 2-7/8" tubing to allow for the circulation of diesel freeze protection fluid to -2000' TVDrkb. c_c_S; / 2. Land the tubing and RILDS. Install TWC. 3. NU Tree and test. 4. Pull TWC. Circulate diesel freeze protection fluid surface to surface to freeze protect the well to -2000' TVDrkb 4417 5. Temporarily suspend the well. RDMO. Note: The well will be temporarily suspended due well scheduling issues concerningseasonal drillingrestrictions. Pioneer Natural Resources ODSN-04 Operations Shutdown Page 1 of 1 ODSN-04 Proposed Operations Shutdown Updated 3/27/2013 16"Conductor @ 158'MD • Base Permafrost @ 1834'MD/1668'TVD @ 2142' MD/2000'TVD w/Diesel • 1111.1.0 11-3/4" 60 ppf L-80 BTC-M Surface Casing @ —5225' MD/3315' TVD iiiLCemented to surface Tested to 3500 psi /30 min. f Seawater 9-5/8"40 ppf L-80 Hydril 521 j Intermediate 1 Casing @ —10,252' MD/ 5510' TVD Tested to 3500 psi/30 min itit O �j, sv THE STATE Alaska Oil and Gas �� 0fALAS� Commission Conservation commi GOVERNOR SEAN PARNELL 333 West Seventh Avenue Omm^ Q• Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Alex Vaughan Sr. Drilling Engineer Pioneer Natural Resources Alaska, Inc. 700 G Street, Suite 600 Anchorage, AK 99501 Re: Oooguruk Field, Nuiqsut Oil Pool, ODSN-04 Pioneer Natural Resources Alaska, Inc. Permit No: 213-037 Surface Location: 3020' FSL, 1092' FEL, SEC. 11, T13N, R7E, UM Bottomhole Location: 2907' FSL, 2012' FEL, SEC. 27, T14N, R7E, UM Dear Mr. Vaughan: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster ,, � Chair DATED this /8 day of March, 2013. .EILJ STATE OF ALASKA F CA OIL AND GAS CONSERVATION COMM. )N MAR 1. 2013 PERMIT TO DRILL AOC 20 MC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil Q• Service- Winj ❑ Single Zone Q. 1 c.Specify if well is proposed for: Drill ❑✓ . Lateral 0 Stratigraphic Test ❑ Development-Gas 0 Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates 0 Redrill❑ Reentry 0 Exploratory ❑ Service- WAG 0 Service-Disp 0 Geothermal ❑ Shale Gas 0 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: Pioneer Natural Resources Alaska, Inc. Bond No. 103655283• ODSN-04: 3.Address: 700 G Street, Suite#600 6.Proposed Depth: 12.Field/Pool(s): Anchorage,AK 99501 MD: 19,953'i TVD: 6386'- 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Oooguruk-Nuiqsut Oil Pool. Surface: 3020' FSL, 1092' FEL, Sec. 11,T13N, R7E, UM • ADL 355036/ADL 389958/ADL 389959 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2815' FSL, 3052' FEL, Sec. 35,T14N, R7E, UM • 417497 3/28/2013 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2907' FSL, 2012' FEL, Sec.27,T14N, R7E, UM• 5760+2560+2560 2376' 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-469783.84 y-6031013.60 Zone-ASP 4 u GL Elevation above MSL: . 13.5 feet to Same Pool: ODSN-20 is 1446' away 16.Deviated wells: Kickoff depth: .200 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: • 90.36 degrees Downhole: 3274• Surface: 2567• 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 BTC-M 5182' Surface Surface 5225' 3315' 600 sx PF'L'; 576 sx Class'G' 11-3/4" 9-5/8" 40# L-80 Hyd 521 5177' 5075' 3250' 10,252' 5510' 153 sx Class'G' 8-1/2" 7" 26# L-80 BTC-M/ 13,062' Surface Surface 13,105' 6425' 439 sx Class'G' Hyd 563 6-1/8" 4-1/2" 13.5# C-110 Hyd 521 6998' 12,955' 6413' 19,953' 6386' ,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 TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate - Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch ❑ Drilling Program ❑✓ Time v.Depth Plot 0 Shallow Hazard Analysis Diverter Sketch 0 Seabed Report 0 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 Email alex.vaughan( xd.com Printed Name Alex Vaughan Title Sr. Drilling Engineer ,.. .....7Signature Phone 343-2186 Date 3/11/2013 Commission Use Only Permit to Drill API Number: Permit ApprovaII\ `Q/ See cover letter for other Number: a13 O3? 50-?O -„.O�o ' 7.D- 00 -00 Date: �-l1 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: Other: *11500 /S L (foe --i--.:s-f-- Samples req'd: Yes 0 No[I Mud log req'd:Yes❑ No0 y�� HZS measures: Yes 0 No[ Directional svy req'd:Yes[ No $C Divi+'kr (,(-14-4:41‘t..-) Spacing exception req'd: Yes 0 No 121 Inclination-only svy req'd:Yes 0 No Er .p"-.---fr pa,1-:-c: 4.14-41- i cJ r - Sic,n W,O v e--(2- PROVED BY Approved by. , /� ' i' -' /-` -- COMMISSIONER THE COMMISSION Date: 3 �'/8 - /3 Submit Form andLI, �0' OJ z-�1 vved 1q(20 2) I This permit is valid fo24 months from the date of approval(20 AAC 25.005(g)) Attachments in Du licate 1\, \ N uA 3•/3 . - _ l'As RECEIED V PIONEER MAR 1 2013 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 11th, 2013 State of Alaska Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite#100 Anchorage, AK 99501 RE: Application for Permit to Drill ODSN-04 Surface Location: 3020' FSL, 1092' FEL, Sec. 11, T13N, R7E, UM X = 469905.67, Y = 6031136.46, ASP4 Pioneer Natural Resources Alaska, Inc. (PNRA) hereby applies for a Permit to Drill a development well from the Oooguruk Drill Site (ODS) located within the Oooguruk Unit. The well is designed to be a production well in the Oooguruk-Nuiqsut formation. PNRA requests the Permit To Drill based on approved Pool Rules. As indicated in the attachments, the drilling and well construction program includes the following: • Surface Hole: o Drill 14-1/2" to —5,225' MD /3,315' 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 —10,252' MD / 5,510' TVD. Run and set a 9-5/8" drilling liner. • Intermediate Hole 2: o Drill 8-1/2" and under-ream while drilling (UWD) to 9-1/2" to —13,105' MD /6,425' TVD and set 7" Intermediate casing into the top of the Oooguruk-Nuiqsut formation. • Lateral Hole: o Drill 6-1/8" horizontally to —19,953' MD / 6,386' TVD and set a 4-1/2" liner with a Baker MultiPoint mechanical diversion frac system. • Fracture Stimulation Completion: o 4-1/2" fracture stimulation string with SSSV& Sliding Sleeves. • Fracture Stimulation: o 2,000,000 lbs of Carboceramics Carbolite proppant pumped in 600,000 gallons of Schlumberger's YF125ST. • ESP Completion: o ESP completion string with SSSV& GLM. Alaska Oil & Gas Conserv,_ Jn Commission March 11th, 2013 Page 2 of 3 PNRA will implement Managed Pressure Drilling technology (MPD) while drilling the Intermediate 2 section and the Lateral hole section as outlined below. • Intermediate 2 shoe to TD o Use -7.2-8.2 ppg fluid while using MPD to control pressure from the surface to j -9.8-10.5 ppg EMW at the bottom of the hole during connections and while tripping. �� • Open formations: vJ� • Nuiqsut Sands, -9.8 ppg Pore Pressure • Kuparuk Sands, -9.8 ppg Pore Pressure • Lateral shoe 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. L & xr NW c.i�kJ vies, r."' z Based on information previously submitted to the AOGCC and includ@d in t e 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. A map showing location of the ODSN-04 surface casing point relative to surrounding wells has been included. _' c.o..c_c..r . ,, S[.,a Sf -CIro....- S.C. In the future, PNRA may provide information and permitting requesting annular disposal of ) drilling wastes on this well. 2(c- 3-11--:q 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 MC 25.005 (c) (13) including: a. The drilling fluid program as required by 20 MC 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 MC 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 Consen, in Commission March 11th, 2013 Page 3of3 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). 2) Diagrams and descriptions of the BOP and diverter equipment to be used on Nabors Alaska Rig 19-ek$ as required by 20 AAC 25.035 (b) and (c). 3) A description of the procedure for conducting formation integrity tests per 20 AAC 25.035 (c) (5). 4) PNRA does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment as specified in 20 MC 25.065(1) will be functioning on the rig as standard operating procedure for all wells drilled by that rig. Products for treating H2S contamination in the drilling mud system will be maintained on the ODS. The following are PNRA's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Alex Vaughan, Senior Drilling Engineer (20 AAC 25.070) 907.343.2186 alex.vaughan@pxd.com 2) Geologic Data and Logs Greg Griffin, Operations Geologist (20 MC 25.071) 907.343.2141 greg.griffin@pxd.com The anticipated spud date for this well is March 28th, 2013. If you have any questions or require further information, please contact Alex Vaughan at 907.343.2186. Sincerely, Alex Vaughan Senior Drilling Engineer Attachments: Form 10-401 Supporting permit information cc: ODSN-04 Well File P .pit to Drill Well Plan Sun*ary ODSN-04 Oooguruk — Nuiqsut Single Lateral Production Well Surface TD @ 5,225' MD / 3,315' TVD Drilling Liner TD @ 10,252' MD / 5,510' TVD Intermediate TD @ 13,105' MD / 6,425' TVD Lateral TD @ 19,953' MD / 6,386' TVD Surface Location: 3020' FSL, 1092' FEL, Sec. 11, T13N, R7E, UM ASP 4(NAD27) projection X=469905.67 Y=6031136.46 (ADL355036) Target: Oooguruk-Nuiqsut 2815' FSL, 3052' FEL, Sec. 35, T14N, R7E, Umiat, (ADL389958) X=468033.53 Y=6041428.19 6,425' TVDrkb Bottom Hole Location 2907' FSL, 2012' FEL, Sec. 27, T14N, R7E, UM (ADL389959) X=463761.01 Y=6046890.98 6,386' TVDrkb AFE Number: TBA Est. Start Date: March 25th, 2013 Rig: Nabors 19AC Operating days: 60 days to Drill and Complete Objective&Well Type Nuiqsut Development Well:WPO2a 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 11th,2013 ODSN-04 Permit To Drill Page 1 of 13 Well Control: Well Section Pressure Depth psi TVD Basis 14-1/2" Surface Section Maximum anticipated BHP 1482 3315 Based on seawater gradient of 0.4472 psi/f Maximum surface pressure (Based on BHP and a full column of gas 1118 Surface from TD @ 0.11 psi/ft) 10-5/8" x 11-3/4" Drilling Liner Hole Section Maximum anticipated BHP (Based on seawater gradient of 0.4472 2464 5510 psi/ft) Maximum surface pressure 1858 Surface Based on BHP and a full column of gas from TD @ 0.11 psi/ft) 8-1/2"x 9-1/2" Intermediate Casing Hole Section Maximum anticipated BHP 3274 6425 Based on 9.8 ppg Oooguruk-Kuparuk pore pressure) Maximum surface pressure 2567. 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 3254 6386 Based on 9.8 ppg Oooguruk-Nuiqsut pore pressure) Maximum surface pressure 2552 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): 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 11th,2013 ODSN-04 Permit To Drill Page 2 of 13 Formation Integrity Testis eguirements: Test Point Depth Test Type Minimum EMW 11-3/4" Surface Shoe 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 MOBM Interval Density(ppg) Viscosity(secs) YP PV HTHP 0/W • Initial to TD 10.0- 10.6 ppg 55-80 12-25 15-30 800-2000 <4 Intermediate Hole Mud Properties: 8-1/2"x 9-1/2" 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 (-13.0 ppg via (8-10 MPD) HTHP) Lateral Hole Mud Properties: 6-1/8" hole MOBM Interval Density(ppg) Viscosity(secs) YP PV HTHP _ 0/W • Initial to TD 7.2-8.2ppg 55-80 12-25 10-20 <6 94/6 (-9.8-10.2 ppg via MPD) Pioneer Natural Resources Last Revised: March 11th,2013 ODSN-04 Permit To Drill Page 3 of 13 • Formation Markers: Formation Tops MD(ft) TVDrkb(ft) Pore Press. EMW Comments (psi) (PP9) Base of Permafrost 1838 1668 Top West Sak 2875 2289 1029 8.65 Base of fluvial sands Tuffaceous Shales 4290 2907 � Hue2 tuff 5156 3285 11-3/4"casing point 5225 3315 Brook 2B 7616 4359 Top Torok Sand 9384 5131 2308 8.65 Base Torok Sand 9941 5374 Torok Shale 1 10241 5505 9-5/8" casing point 10252 5510 Top HRZ 11219 5932 Base HRZ(Top Kalubik Sh) 11526 6066 Kalubik Mkr 11836 6188 Top Kuparuk C 12033- 6253 3186 9.8 LCU (Top Miluveach Sh) 12074 6265 BCU (Top Kingak Sh) 12710 6281 Top Nuiqsut 13017 6418 3271 9.8 Production Zone Nuiqsut 1 13051 6421 7"casing point 13105 6425 3274 • 9.8 ODSN-29 TD 19953 6386 3254 9.8 Pioneer Natural Resources Last Revised: March 11th,2013 ODSN-04 Permit To Drill Page 4 of 13 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: Mud Logging Dir/GR/Res/XBat Open Hole: N/A Cased Hole: N/A 8-1/2" Section: Drilling: Mud Logging Dir/GR/Res/AzDens/ Neut Open Hole: N/A Cased Hole: 6-1/8"Section: Drilling: Mud logging Dir/GR/ Res/AzDens/Neut /ABI Open Hole: N/A Cased Hole: N/A Pioneer Natural Resources Last Revised: March 11th,2013 ODSN-04 Permit To Drill Page 5 of 13 ' 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 BTC-M 5182 Surface 5225 3315 11-3/4" 9-5/8" 40# L-80 Hydril 521 5177 5075 10252 5510 BTC-M & 8-1/2" 7" 26# L-80 13062 Surface 13105 6425 Hydril 563 6-1/8" 4-1/2" 13.5# C-110 Hydril 521 6998 12955 19953 6386 Tubing 4-1/2" 13.5# C-110 Hydril 521 12957 Surface 13000 6417 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" BTC-M 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 563 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" 13.5# C-110 3.920" 3.795" Hydril 521 12410 10690 422 M 422 M _ Pioneer Natural Resources Last Revised: March 11th,2013 ODSN-04 Permit To Drill Page 6 of 13 • Cement Calculations: Casing Size: 11-3/4" St...ace 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: 4,000' MD-500' MD above 3000'TVD Total Cement Volume: Preflush 10 bbl water Spacer 100 bbl 10.0 ppg Tuned Spacer Lead 466 bbls/600 sx of 11.1 ppg Type"L" Permafrost Cement. 4.36 cf/sk, 22.80 gps water req. Tail 121 bbls/576 sx of 15.8 ppg Premium "G"+adds. 1.18 cf/sk, 5.24 gps water req. Displ 564 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 for possible witness of cement to surface. Casing Size: 9-5/8" Intermediate 1 -Drilling Liner-single stage Basis: TOC: 9,752' MD-500' MD above casing point 15% excess, plus 85' shoe track Total Cement Volume: Preflush 10 bbl water Spacer 60 bbl 10 ppg Dual Spacer Primary 32 bbls/ 153 sx 15.8 ppg Premium °G"+adds. 1.17 cf/sk Displ 476 bbls mud Temp BHST-- 135° F, BHCT--110° F Casing Size: 7" Intermediate 2-single stage Basis: TOC: -11,533' MD-500' MD above the top of the Kuparuk 40%excess, plus 85'shoe track Total Cement Volume: Preflush 10 bbl water Spacer 50 bbl 12.5 ppg Dual Spacer Primary 91 bbls/439 sx Premium "G" +adds. 1.17 cf/sk Displ 498 bbls mud Temp BHST- 165° F, BHCT-135° F This well is outside the 1/2 mile radius around ODSN-DW1 at the intersection with the Torok disposal zone. Disposal: Annular Infection: Currently not requested, but may be requested in the future. Cuttings Handling: All Class 2 solids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 /Class 2 disposal well, ODSDW1-44. Fluid Handling: All Class 1 and Class 2 fluids will be processed on the Oooguruk Drill Site by the Grind and Inject facility in the Rig Support Complex and injected down the approved Class 1 /Class 2 disposal well, ODSDW1-44. Pioneer Natural Resources Last Revised: March 11th,2013 ODSN-04 Permit To Drill Page 7 of 13 Pioneer Natural Resources Well Plan Summary Drilling Operations Pre-Rip Work 1. 16"Conductors have been set and the Well Bay modules have been placed. Rise Activity: Drill and Complete 1. MIRU Nabors 19AC over pre-installed 16"conductor casing. —� L--)1":" 2. Nipple up spacer spools and riser. 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 250/45Q0 psi -Notify AOGCC 48 hours in advance of test. 7. MU 10-5/8"x 11-3/4" RSS, MWD/LWD. 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 ppq/. 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 with kill weight brine, increase pressure to 3500 psi and hold pressure for 30 minutes • This will provide an 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 30 minutes • 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. t�]Activity: Operations Shutdown �P S P - Sct,�N�t i SccN��� 1. RIH with enough 3-1/2"or 2-7/8"tubing to allow for the circulation of iesel freeze protection fluid to-2000'TVDrkb. 2. Land the tubing and RILDS. Install TWC. 3. NU Tree and test. \' 4. Pull TWC. Circulate diesel freeze protection fluid surface to surface to freeze protect the well to -2000'TVDrkb 5. Temporarily suspend the well. RDMO. Note: The well will be temporarily suspended due well scheduling issues concerning seasonal drilling restrictions. Pioneer Natural Resources Last Revised: March 11`h,2013 ODSN-04 Permit To Drill Page 8 of 13 Ria Activity: Drill Lateral and Complete Well Note: ODSN-04 was temporary shutdown with 9-5/8"casing pressure tested to 3500 psi and charted. The 9-5/8"cement plug was bumped with kill weight brine. 1. MIRU. RU circulation lines and circulate out the diesel freeze protection fluid and ensure the well is dead. 2. Install TWC. ND Tree, NU Mulitbowl Wellhead, &NU BOPE and test to 250/4500 psi- Notify AOGCC 48 hours in advance of test. 3. Pull circulation tubing string from the well. 4. RU MPD trip nipple&PU 5" DP as needed to TD the Intermediate 2 hole section. 5. MU 8-1/2"x 9-1/2" RSS, MWD/LWD on 5" DP. RU MPD trip nipple. 6. RIH and cleanout casing to landing collar. 7. Close pipe rams and combo pressure test the Drilling Liner and the Surface Casing to 3500 psi for 5 minutes--chart and send to ODE. 8. Drill through drilling liner shoe +20'of new hole and perform FIT to 13.5 ppg. 9. RD MPD trip nipple and RU bearing assembly. 10. Drill 8-1/2" Intermediate 2 to casing point. 11. Circulate and condition the well to run 7" intermediate casing. 12. Displace the well over to-12.0 ppg mud for shale stability. RD the MPD bearing assembly and RU MPD trip nipple. POOH. 13. 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" Lonustring a) Run and cement the 7"26#L-80 BTC-M intermediate casing. b) Bump the plug and bring the pressure up to 3500 psi-hold for 5 minute pressure test. Release pressure and ensure floats are holding. c) LD 5"DP ' Option #2: 7" Liner with Tie-Back Option a) 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. b) 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. c) 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 d) Run 7", 26#L-80 BTC intermediate tie-back to 7"liner-hanger seal bore and space out. Pioneer Natural Resources Last Revised: March 11th,2013 ODSN-04 Permit To Drill Page 9 of 13 e) Displace diesel fres rotection down 7"annulus to 2,000'tvd 1 nnular preventer closed. f) Strip through annular preventer and sting into 7"liner-hanger seal bore and land tie-back casing. g) Pressure test seal assembly to 3500 psi-hold&chart for 30 minutes. h) Pressure test 7"tie back annulus 3500 psi-hold and chart for 30 minutes. i) Set and test 7"pack-off. 14. RU MPD trip nipple & PU 4" DP as needed to TD the lateral hole section. 15. RIH to landing collar and w/4" DP&mill tooth cleanout bit. 16. Change pipe rams to 4"and test BOPE to 250/4500 psi-Notify AOGCC 48 hours in advance of test. 17. Pressure test casing to 3500 psi-chart and hold for 30 minute pressure test unless previously done in Option#2. Send chart to ODE. 18. Drill through Intermediate 2 shoe and POOH w/cleanout assembly. 19. MU 6-1/8" RSS, MWD/LWD drilling assembly on 4" DP and RIH. 20. RD MPD trip nipple and RU bearing assembly. 21. Displace to drill-in-fluid for lateral hole. 22. Drill rathole +20' of new hole and perform FIT to 12.5 ppg. 23. Drill 6-1/8" lateral lateral hole to TD. 24. Circulate and condition hole to run liner. 25. POH to intermediate shoe and set heavy weight balance brine pill. 26. RD MPD bearing assembly and RU MPD trip nipple. Cont POH to surface. 27. Change one set of pipe rams to 4-1/2"and test BOPE as required. 28. RIH w/4-1/2" production liner w/Baker MultiPoint frac system from 150' inside the intermediate shoe to TD. 29. Release from the liner and set the liner top packer. Displace the well over to completion brine and POOH. 30. Run 4-1/2"fracture stimulation string to top of 4-1/2" liner seal bore. 31. Reverse circulate corrosion inhibited brine or diesel to freeze protect the well to -2000'TVD. 32. Sting 4-1/2"fracture stimulation string into the 4-1/2" liner seal bore. 33. Pressure test 7"x 4-1/2"annulus to 3500 psi-chart and hold for 30 minute pressure. Send chart to ODE. r° Pioneer Natural Resources Last Revised: March 11th,2013 ODSN-04 Permit To Drill Page 10 of 13 PNRA rbmit a sundry prior to executing the folic program Post Rio Operation: Fracture Stimulation 1. Fracture stimulate well 2,000,000 lbs of 20/40 Carboceramics Carbolite proppant pumped in 600,000 gallons of Schlumberger's YF125ST. The fluid volume includes a pad stage yet to be determined. The stimulation will target the Torok reservoir in a 9 stage treatment using the Baker MultiPoint mechanical diversion system. The expected surface treating pressure at a planned pump rate of 50 barrels per minute is 7000 psi. Maximum proppant concentration is 10 ppa per gallon. The Schlumberger YF125ST is a water based guar gel system with borate crosslinker. The chemical make-up of the YF125ST includes: i`-)9 -)t Seawater base-983.75 gpt Clay Stabilizer-2 gpt f) l/ Polymer-6.25 gpt ` U 4z.13 Surfactant-2 gpt V 3 Crosslinker-6 gpt Oxidative Breaker-0.05 ppt 2. Remove SSSV sleeve and install wireline retrievable SSSV 3. Install live gaslift valves 4. Flowback well with gaslift. 5. RDMO well. Rig Activity: ESP Completion 1. Rig up over well. 2. Install BPV and nipple down tree. 3. Pull 41/2"fracture stimulation string. 4. RIH w/ ESP completion w/Packer&Tubing Retrievable ScSSSV. 5. Space out and land tubing hanger. 6. RILDS and test both the upper and lower tubing hanger body seals to 5000psi. 7. Set BPV, ND BOPE, NU Production Tree 8. Replace BPV w/TWC& Test Production Tree void to 5000psi &recover TWC 9. Reverse circulate corrosion inhibited brine or diesel to freeze protect the well to -2000'TVD 10. Set packer and test annulus to 3500 psi for 30 min. Post Rig Operations: 1. Rig up slickline 2. Retrieve ball/rod assembly from the RHC-M plug body 3. Pull dummy valve from lower GLM, set'/." OV in same. 4. Retrieve RHCM plug body 5. Rig down slickline Pioneer Natural Resources Last Revised: March 11th,2013 ODSN-04 Permit To Drill Page 11 of 13 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% 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 11`h,2013 ODSN-04 Permit To Drill Page 12 of 13 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/ 549 bbls 10.0- 10.5 ppg 2464 12.5 ppg (LOT) 10-5/8"x 11-3/4" 9-5/8" Drilling Liner/ Infinite 9.8-10.5 ppg 3274 13.5 ppg (FIT), 8-1/2"x 9-1/2" (13.0 EMW w/MPD) 7" Intermediate/ Infinite 7.2-8.2 ppg 3254 12.5 ppg (FIT) 6-1/8" (9.8-10.2 EMW w/MPD) NOTE: All LOT/ FIT will be taken with a minimum of 20-ft and a maximum of 50-ft of new hole drilled outside of the previous casing string Hydrogen Sulfide • The Oooguruk Drill Site is not designated as an H25 site, however Standard Operating Procedures for H2S precautions should be followed at all times. Faults • A seismic faults with expected throws of 15-40' may be encountered. Losses may be associated with these faults. • Consult the ODS data sheet for additional information (still in development). Pioneer Natural Resources Last Revised: March 11`h, 2013 ODSN-04 Permit To Drill Page 13 of 13 Nuiqsut Production Well Completion Updated 3/11/2013 I 16" Conductor I I IN Packer Fluid mix: Inhibited Kill weight Brine with 2000'TVD diesel cap I I Surface Casing Ilk 1 11-3/4" 60 ppf L-80 BTC-M I 5,225' MD / 3,315' TVD GL 11 Cemented to surface IxII I iiiiii I Inil ,r -- Intermediate 1 Casing 1 9-5/8" 40 ppf L-80 Hydril 521 I 10,252' MD / 5,510' TVD GL 11 Cemented 500' above Top of Torok 1 1 1 I GL jl I I Intermediate 2 Casing 7" 26 ppf L-80 BTC-M & Hydril 563 0 i. 13,105' MD /6,425' TVD lik ''ii!• Cemented 500' above Top of Kuparuk :iii Production Casing 4_1P/2r 1/2" C 110 Hydril 521 ,illibl::: 19,953' MD/6,386' TVD 0o No cement �000 M ■ M M Z IL ■ -IL IL O O O O O O O O p O O O O O O O O O 0 4-W Hydril 521 Liner with High Torque Frac Sleeves spaced 500 ft apart and isolated with Hydraulic Set Open Hole Packers (12 total) -'''''',4, _ f _ _ _ _ ` z _ _= C}) °0 7 _ • _ •r _ -....7,- . • • r::.......... �,-•" • moo .'. o o n ell .. . . .. . • .. _ . . .. .. .. ... '.'jr _ ,.o ....... „. .:...._.. ,-.7, ..... crs . • fa) _ .• v 4. S � � au 1 • Q n = rD N n N Q LQ Q >4 t I>x++D00 041+<.`a>" x❑1>D❑141)44$4>* ID+F+0m x 4>1.+}+$ Ip+j+4>t++$ t P Ib+'+ID$+}+©? 01> $ 0000000000000000000000000000 . 0 . 0 . 00000000000000000 0 0 . 0 0 . 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N N N V, N NV. `r 0 N N N N N N N N N N N N zzzzzzz ` zzzz zzzr- N N N zzzzzzzN N zzzzzzN ` N zzzzzzzzzzzz " " "c7[ `AAAAA3c3"c �cr� � �c � W W N, Ny NN N NN N N NN N N NN NN N N N N NN NN F+ r'-• F+ F+ F+ F+ N F+ F+ h+ F+ F+ N F+ A A O J W W W W W r r F' F-` IL F+ �� 4. I-+ F+ ID O V Q. O. O,In 1n In U U A A A W W W CO CO CO CO CO CO CO V V O, Q, N N N f+ 1--` 00 N N W W A A A lu W W F+ O Oa 0000000000000000000000000000000 0 0 000000, 0 00000000* ' 0 0 0 g O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 q O 0 0 O N Nm 0 0 O O O O O OC O 0 0 0 N N N N N 2 N N N 2 N N N N N N N N N N N N N 2 N N N N N N N N Z 2 7c coCF F F 7 O W N N N N N ' !0 F+ F+ H F+ F, , H H F, - A . N W WW N ' H WN NNNA, NN NN A AA W 00 CO CO CO CO W NJ +1 OI ON R N -' I-' W NJ WW AAAaW s V O, 7SvvOmwmmG 11 COrav= crc °°W � "` bo v,Z ,Z ,„Zq00Eo w ,.,Wm nm mO W 0 A. w _co' OO 00 o00 a o,No aL NO 000y • 0a 7 .0 00000 20oWWOOmm lV' Z 0v `-•C' - c000 ,1_, 0000 ,2_, 0 WOOO 0000WOO00000OZ20013OO v-, O A77Cw , N N , N N N N NONOO NNNN , Z , thrOD •Tor aZ ZOOZZOOZZZOOwZZaZ2Z2ZZa - 5 a N - 0 N 0ANW00F ,; r ,'' ,'' 6 3 rn � eZZ , 00mwcom � ' Fziz7cA � y �c0WWAvv� 00 .r. Y . 1, GwoocoG ., z . 4i, m m m m�• Z L � 7 7S 7z N a `I' r' a a' a s w awrnt, a is Ee � 7 - NN. RM13mGAPO zzKZ mr ~ Zacw , Wv7S ` 0v Ln M 0, -0 a a C t 7 a ,, '-. � rc v � o C. a as a t a a Y c c 6N Qoas CO CO CO o 0 MCO A A WOZZ A W N N a s COCOCOCOW c c '. nCoc„ Wp ,6 WW MN 4N mOO O < 0o adm ° co W00G O d N � 2 A o T I 0 .o ❑ SoAI(-yNorth(+l[u1Q a a ai 'r? ' s: F r —11 WI f I • 41 Xi • � : g p : . . Q I i" iiimio. ag. aw V I I I Pr .. tC •R � 2 , Z d 1 p . . L >O* Ib x++p0 0 0+#<I>*❑a>D o 4-+®*m$ * It>+1+01)x 4>IaH+$ Ia+}+m*H$* D* t++IP$+}+m*O® $ O 0000000000000000000000000000000000000000000000000 0 00000000000000000000000000000000000000000040000000 y yI y y�I y yI y�I yI yI 5n �yI y yI yI y�I yI y 50�I ✓t v, 2 N N N N 2 N N u, N N Vt Vt N vI 7C 7C 7C 7C 7C 7C 7C 7C 7p 7C 7C 7C 7C 7C 7C O Z zzzNzzz 'zszzzZZzzzzzzzzzzz �zZzzzZzzzNz Yzz N H 1D v a,, a, a .41 In In lin A A A W W W co W W co corrW Co +r! L Or1 Ori L.~~ N N N H 00 Vwi lwn W W A A a W W W A O 00000000000000000000000000000000000 ° .., 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 p 0 0 0 0 0 0 0 0 0 0•••> 00000000i 0 0 0 0 00 00 0 0 N vI vI LA vI O O O O N vt vI N kn vI VI v. O O O vI VI In N VI vt vt v' vI ut In O, Z Z O O k 7, O� O OI 7C , , 7C 7S O a ll z z ZIy Z1�, N zN z z z z z I Z NNz z N z z z z z z z z z z z z z z z z z z Z �c 7C yyI yy y4y1 Fw+ Fw+ la 1p tO N N N N n In U U In ? > A N I" Oo 00 Oro W W Oro +rl V Ori Ori aril 7C 7c N N 1' .I.- 7C 7C W W A A A W W W p a a a a 7C 7C JC W W a a, O, ON. w w �i. y a 7c Ln In a 7C a a v a s o O co Z z Z z 7C 7cAO '' '' ' ''com m iI in M O v a 0 ... " -= -.:. -00 W w w . F.P0 .-.0-0 -0 c m-0 c- 7C °r°-c O .., m no m 00 I, 0, LO -!'' G vI �n A,�i �i O w �' a a p N m O w N N r �n p O Ov O m o c?I 0 .� 7C.Yc O O 0 0 7�C Z80mpo OOpapmZ 00000 ,,,,,, 2 OOZ 000000ZOn "IZZZOOvviloO VOvI J. OrOO � � rO fW,, v, N r O O 0 N �+ vt Z Z Z vI N O O vI vI vI ut ut � rd Z Z a �:. p O A' ut p 7c O. O A 7C 7S W a Z Z O O 2 2 0 0 , z Z z z z 00 00 w Z Z v z Z Z Z z z v .• a v Lo vI Ly/1� N O 7c In 6,, 0 0 7Nc c r r �' IL o 0 Z W O O N N p 0 N N N ,, z •- 1- 1-• " 1"' f',, Z '^I Z 7C Z 7C O A 7C In 7C O W a A A a a u. N 7 Z� Z Z — rn Z Z 7, 7c 7c 'a 7C Z Z a Ci w Ir-• a s I� a a v w G v w " �'i', i+ N 01 7C w D 7c w m a 0, m m _ 2 Ca v G c W rn a �+' �' W �n o o 8 Z Z 0 r r r r r — Z Z . 6 �, 7S r v L" a 7S w v 7C 7C o o O • gaZra s a v a C C� 7C a R A r r r r CL r W a s a "a 2 a a 1. C a v' z8 < I7n m AmNo G+ prp as "° ""' 81' 13 -0 '^ u" 64 mcg mv+ 4 CO - as 0 In In M o f CO CO E W W W W c r r _ r cc In I._. 0 m pp ~6 j W W W W r0 o ONO o 0 C Ko a O `�-�v C] 0 V N � z a 6 G A v _ o M <iiD 0 0 o o ❑ �, L I I. L 0 A 0 0 0 A 9 „0 .I�- Norm+,i A... 0....A....8....A....0,...8....I....0.,.,A L1 ai 41 I!�/ w L�' ... ... ®i = — Ali': xo 1r LT�J 3 0. • 04 k.,- Ihhil kikA p fit )1.1 )4* t 4+»+>00 0+#J x o 1 o++1D*1>$1>x Ib+FOI x 4 1 1>t+-+$ t ©* Ia+#+>$+fK x(1> $ • 00000000000000000000000000000000000000000000000000 0 00000000000000000000000000000000000000000000000000 0 N N N z N N N N N N N N N N N N N N N N N N z 2 N N N N N N N N N N N N N N zz NzN NNz Nzz NzN lzN� NzN Nz Nz Nz Nz NzzzzNz Nz NzNzz `rzzzzzz �z � 22 �zZy�' �c �"c �c {{?,,yyc c `�c �c ?c `3'c ?c ?c ?c ?c `�7 z SiO�O v T O, O, In ' In In>A jr: W W W,0~0,0~D O~0 O~0 0~O 0~0 O'J v a a U~~ N N N IA. OD lwi, fl W W A A A W W W L O 0000000000000000000000000000000'0 v v v 0 v O O O o O D D o o O O o o O Q F, v o 0 o 0 0 O 0 0 Eg 0 O Eg v v v 0 0 0 0 0 0 0 0 0 0 0 v 2 2 v 0 0 0 0 o 0 0 0 0 Z Z Z Z z z z z z z Z Z Z Z Z Z z z z z Z Z Z Z Z Z Z `rz rz Z 2 z 0 0 W FF+ i r, H 0 g. ill Lit fit 64 'ie N N W N0 FW N NW NW FW H NV N N H, f'' A 4' HA NA ly77W W A+ AH WH ;.'1 W vAp .NWWDvc �' v. vvv -e '0� zzG9 � Ovvv° v � aao0 o v v .o oVp , l � 7c cOoNcni l'i NNW0 oooOO °° „ v � ' "co88ZOOaOOvZOOOOyN Z000000200 ,r� 00vO03Or O o N . 0N., 0 0'N m 0 0 p iv 0 O 0 0 o NP ? Ov 0F• V. 52 1� Z zo0oT O 0°OoANN77W : 1+ ZN002 N00N22 Z Z ZOoGCNN � N N V ,Ls O 610 0 0 Np70 77 �a oozz -o . . v0vv2AZD , " D, wc I• ILW � , ,, Z - -. 6 „ „ xvaZZ4 '' v' VW . � 1 ynggw , mvv m; , - o 15 7, Z6igE6 MMM � P acgd 4ZFaZ4cs6Ec1-'vc6266 O N R w L ` w 7C 7G 'O S� v D c c §6 g NWWN . O v 9 .QW -2,' mOommm m Ka CCCcg pNm0 1N 6 6O SSS 068 gs 8 S S 6 .'S ❑❑ L I 1► L” g P. 8ou11(-YNortl(*)[lett] 1CC .i L x 1 8 R v X L r R R R i 4 G ISI °-1171 illl s 1 Nii xo JL IV if I L9 3 R p r - q 8: A s 7i1 7,1 8 i 4 O .1 R 1p I 1 is 6-sJ 3 / Y • R >4. - I LiX ? 2°13 3/iz� Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-4 ODSN-4 PN5 ext Plan: ODSN-4 PN5 ext wp02.a Standard Proposal Report 27 February, 2013 HALLIBURTON Sperry Drilling Services IO N E E R HALLIsURTON REFERENCE INFORMATION Co-ordinate(N/E1 Reference:Well ODSN-4,True North Sperry h'ertical(TVel Reference:42.7'+13.5'@ 56.2usft(Nabors 19AC) !Measured Depth Reference:42.7+13.5'@ 56.2usft(Nabors 19AC) Calculation Method:Minimum Curratere COMPANY DETAILS: Well Planning-Pioneer-Oooguruk Calculation Method:Minimum Curvature SECTION DETAILS Error System:ISCWSA Scan Method: Tray.Cylinder North Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Error Surface: Elliptical Conic 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 Warning Method: Rules Based 2 200.0 0.00 0.00 200.0 0.0 0.0 0.00 0.00 0.0 3 342.9 5.00 315.00 342.7 4.4 -4.4 3.50 315.00 5.7 4 1062.9 30.00 300.00 1024.1 118.4 -185.4 3.50 -17.69 178.2 Project: Oooguruk Development 5 2203.5 48.00 354.00 1931.5 703.1 -487.3 3.25 85.84 832.9 Site: Oooguruk Drill Site 6 2740.8 64.11 354.45 2230.5 1145.1 -531.8 3.00 1.46 1260.4 g 7 11499.4 64.11 354.45 6054.4 8988.0 -1293.8 0.00 0.00 8835.3 Well: ODSN-4 8 12753.2 85.00 321.74 6395.1 10079.1 -1751.6 3.00 -61.8910018.4 Wellbore:ODSN-4 PN5 ext 9 13053.2 85.00 321.74 6421.2 10313.8 -1936.6 0.00 0.0010304.6 PN5 ext V3 Ti heel 10 13231.8 90.36 321.74 6428.4 10453.9 -2047.1 3.00 -0.0110475.5 Plan: ODSN-4 PN5 ext wp02.a 11 19952.8 90.36 321.74 6386.2 15731.1 -6209.0 0.00 0.0016912.1 PN5 ext V3 T2 toe 17100- _ WELLBORE TARGET DETAILS(MAP CO-ORDINATES) ODSN-4/ODSN-4 PNS ext wp02.a Name TVD +N/-S +E/-W Northing Easting Shape 16200- PN5 ext v2 t1 6301.2 9824.3 -1564.96040966.00 468380.70 Point - 4b'- PN5 ext v1 t2 6307.2 14994,6 -5582.0 6046152.00 464385.00 Point -I k�'_---4-1/2 PN5 ext v1 t1 6346.2 10213.1 -1858.26041356.00 468089.00 Point PN5 ext v2 t2 6376.2 14994.6 -5582.0 6046152.00 464385.00 Point 15300- PN5 ext V3 T2 toe 6386.2 15731.1 -6209.0 6046891.00 463761.00 Point I PN5 ext V3 T1 heel 6421.2 10313.8 -1936.6 6041457.00 468011.00 Point _ - 14400- - IPN5 ext A'.'+12 I - WELL DETAILS: ODSN-4 13500- Ground Level: 13.5 +N/-S +E/-W Northing Fasting Latittude Longitude Slot 0.0 0.0 6031136.46 469905.67 70°29'46.095 N 150°14'45.898 W 12600- - SURVEY PROGRAM Date:2013-02-27T00:00:00 Validated:Yes Version: 11700- Depth From Depth To Survey/Plan Tool 42.7 600.0 ODSN-4 PN5 ext wp02.a SRG-SS 600.0 5225.0 ODSN-4 PN5 ext wp02.a MWD+IFR2+MS+sag 5225.0 10252.0 ODSN-4 PN5 ext wp02.a MWD+IFR2+MS+sag 10800- 10252.0 13105.0 ODSN-4 PN5 ext wp02.a MWD+IFR2+MS+sag - 1 13105.0 19952.8 ODSN-4 PNS ext wp02.a MWD+IFR2+MS+sag o - ,n N • 9900- + IPN5 ext V3'I I;...� - - O• 9000- 0 6000 CASING DETAILS r 9 SSS' TVD MD Name Size O 8100- 3315.2 5225.2 11-3/4 11-3/4 5510.0 10252.4 9 5/8" 9-5/8 r5500 6425.0 13104.7 7" 7 6386.2 19952.8 4-1/2 5-1/2 7200- 5000 6300- = DDI=6.85 4500 5400- 4000 4500- 3600- 3500 11-3/4 2700- 3000 1800- 2500 900- 2000 0- 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 ( 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 I 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -7200 -6300 -5400 -4500 -3600 -2700 -1800 -900 0 900 1800 2700 3600 4500 5400 6300 7200 8100 West(-)/East(+)(2250 usft/in) a% o ] a cr2ooa 3 - N d G o N oo n0 > > C C C C C C N �- = 55550 3 z v1 zz d d (naaaaaa a - m ` rn m Z N c `d Z Z 4' \ 3 I- a a .rru a Z ,.1 _ 0 I-t"vdi i C 00000 O 0 —� O z qC _ roa'doroN $ 0 N - F- Ztn inU OON NOVM V 0N7 W OV C00 VM W - V 0 N �000WNOt00VON 6 0 a N I�MfOM.-0,A- 0 0.0O0 Z WVO > N O+nE > A-WN00MVW \ F- - Z - OC) a,' �� zO 1- > L 3aV� Q 0000000 z C000000 0pN / to— L — 00000.1.000n-0000000'000000 ❑ L0NB. W / T / Z LLOOlN�N�O 000 K O M WV . ' 0 . i�L ~ r`7 OZq4:4:424.'47- 0�000� N o M O Z CL Co 0 00000O ;,1. p —N _ to at @p 0000010000000 a Q _ ,- ,SEE. 00010tON000000 ¢ .. Q 866666666666 2 Olo N00. 0 _ 0 '17,• 0 WO >OOCOM000t010 -O Cl) W C00OttOCNDOM y . Cq\? 0) > J + 0.0NN0 Fj 7 y M 11-4. i5` z + `TmroMNr..moN ¢ 47 ¢ ,- 777,11V - 0 ,� 7vtn NNONN w CI p a _ J - r 1 1 W ❑ N A a L _ 0 U .00OV�-0. 00_ I- Z Mt0'-tOA-W ,r.]] o Q p. 0 00.17WW nW0MM.- W + V Vri7.-ri g 5 0 0 40° M 00,001 Z 0.4.W 1OM 0 NMA-MM,- lJ dtOdto + .-N,-00000 a. CO WNvtM - A- a0000� ¢ O'0�1n0 ;4. o ++++ _ O 066(0 0,0,A- 0VA—NVN W C m 0 i- —o 222 t N NNNN V NMoOMiNOM V V M O > Nr(NO(NO(NO- LO 0 - N C MMMM „,N0000c0 00 > 0 _ 01 wu_u_ J ~ MMMMMV z '00 ❑ d _ (0++++ O O O O O t0 N V V V V W 000606 L 0 • .0000 -,C00000,4-11,.. N N N N > 003333 oouioovo. 3 o uo F -o ow 01010100000 C N M - .- >-°) y 0(02222 MMMMMMMMM (0 N > d d N + CO } 0000000.-0000 COSL 0 y ddl0dd =00000,-.-00MM _ d 0 ¢ E NNNNN 001n0044,666d 7- ..W.-F '9 �_ l0 ~ O W n 00p.0p00p. MV000001pm N�� MM O fV ❑ Z —N 0 m 55 5a3 >>>>>> Z 6 M .O _ a _ 0 > ON-.00O 0VNN00 Sc T(T1;T<xT< to c CVO NN M O0 M M.-N ddd dd dd 0-- CjJ N _ a CN N00N 40460401010M10 0 0 _ _ O } 00 410 010 610 N M O N K V N O N M N Z Z Z Z Z Z > __- _ 0 C W -ajFCZLaaaa NN�NMMO1 zaaaaaa o 09•-.• - 0 rn > 0 0 IV W - 7 O jZ ZZZZ m,-NMV100N0MF� N ` \\ - 3 N I- N tn00000 V 0 t` o$ i \\\\ —0 O 00000 v \ Cp r O v v O 000000 CO O 0 � � \ \\ - O M- ~O1n i.NfV Y (0 S II 1 \ \ _ CO N "6-(°M-Ig 0 N N 0 y\ J 0 N (n 0 .9 j 11 \ \ \ - 0 c' 100'0 too O t0 U 21 CO _ 1 \ \ \ _O • N L] N 2. Y C d d a 0>01 N - 11I 1 \ \ - '0 0 EN0000 _t d d (0(02 O'0 J C... V N _ it I " - M o 1 of o Q C E. N '0 0.0 ~N 2 3 y� 00 N_ j 1 I 1 I I VON100 F oda d OCO CJv d aC_T �_ 1 1 1 \ - N LL L > CONN.., W . a.-0.j.C 20,-WN MO0 J" ❑ X 11 \ \ \ - 0 C 2 d00J> NY10-~YSS'z Yt- o O 11 \ \ _O O O O OdIAOCjJLOOWOOyN OD OJ O y 1 ` _ U Zla_FQ1DF SOON OOF~mYh-�pOp�2 O W /r II I \ \\ \\ _ (n 0 0M'-(ONN.--M000 N0,-tO0100 !0 I 1 I \ O dMm N F m,-0064000'00.-0)010MM000 t. I ' 1 \ J N ¢ aNM0NOt0�0CV-NMMN'-�10 I I y - n U N1n 6 2 00000N.-(MONNt00NNNM0 ❑ 1 i 1 \ C 6 _ (0.-O>N1n c 2 „.-NVt0N000. . 't I 1 1 1 J _ N 0 N 1 I 1 \ J Z - °'2\6�nN LL c000000000000000000 (n I 1 1 1 1 \ Z > J N .- 6ri01�Oi N�6Oi.-4to Nt(pp6ri 10 11p.- I 1 1 \ a a tOffpp 00000 M NO Co t00tCO.�N I 1 1 1 1 o - E Q Z_06 p0(ONNOINM.-Mt00)GO NNMppss}} F > A-NNW,TO.0t00000... I I 11 1 \ ~ WH 1 1 ❑ I I 1 -- O ? ON V NO I- I 11 11 1 1 - W ¢ 2 N.O.000 N 0 b9 1 I 11 \ to - U N04,70 \ 100,-r6 LL >in 0 1 I 11 1(L Y - 0 NOON ~ 0 N I I 1 L d W 7.-O CV W a M 0 i ' 1 I W 0 _ HCO(OV M 2 I 1 > - Co t0 0 O V: o v I ' J U � m .o M CO1 o2 02 o _ Q. ❑ y az Z HO0 J I L Q h 0 O O ON inNa I Y ;p Y 0 ON F ❑ co O o Ui Y Y M a o I I O 1 I 1 1 N N Z 1p • CN O_ O \ 1 1 V (0 0. Y o 00 N i.. \ I t 0 O` - g M m J Co1 o2 ' = N _ 1 W v I v , m N 2 F- O y d O L G t. 1 41 19 I - a m m 0. 4) w I N 2 a. o to j k L. dz \ ISI ? m ,c \ � \ W N 0 Za E Tv CO � a s Q -a OI -C le WcE3U4 c iLd'a � V' e .E Z z wj L .M..FWa II O E ❑ Z $ uo a 00 0Q 0{iO 3a � s 0 €s T$ 0 000 00 Z WC nc a 0 `o R V= OaJ n'v' Iii IIIIIIIIIIIIIIIIIIIIIIIQjm rTTIIIIIIIIIIIIIIIIIIIIIIIIIlTI OK w 0 0 0 0 0 0 0 H 0 0 0 0 0 0 0 o '0 to 3 0 m 0 0 3 o o o 0 0 o 0 0 0 o 0 0 0 0 i n y, U co N 4' t0 co CO W V N O W O V N V M N N M V V In CO N a d Or Z (ui1j}sn 0002)4]dea leogaan anal S 0 U Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a 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: 6,031,151.32 usft Latitude: 70`29'46.242 N From: Map Easting: 469.920.45usft Longitude: 150' 14'45.465 W Position Uncertainty: 0.0 usft Slot Radius: 13-3/16" Grid Convergence: -0.23 ' Well ODSN-4 Well Position +N/-S 0.0 usft Northing: 6,031,136.46 usfl Latitude: 70`29'46.095 N +E/-W 0.0 usft Easting: 469,905.67 usfl Longitude: 150` 14'45.898 W Position Uncertainty 0.0 usft Wellhead Elevation: usfl Ground Level: 13.5 usfl 1 Wellbore ODSN-4 PN5 ext Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) IGR F200510 12/31/2009 21.99 80.81 57,759 Design ODSN-4 PN5 ext wp02.a Audit Notes: Version: Phase: PLAN Tie On Depth: 42.7 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 42.7 0.0 0.0 338.46 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°1100usft) (°100usft) (0) • 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 200.0 0.00 0.00 200.0 143.8 0.0 0.0 0.00 0.00 0.00 0.00 342.9 5.00 315.00 342.7 286.5 4.4 -4.4 3.50 3.50 0.00 315.00 1,062.9 30.00 300.00 1,024.1 967.9 118.4 -185.4 3.50 3.47 -2.08 -17.69 2,203.5 48.00 354.00 1,931.5 1,875.3 703.1 -487.3 3.25 1.58 4.73 85.84 2,740.8 64.11 354.45 2,230.5 2,174.3 1,145.1 -531.8 3.00 3.00 0.08 1.46 11,499.4 64.11 354.45 6,054.4 5,998.2 8,988.0 -1,293.8 0.00 0.00 0.00 0.00 12,753.2 85.00 321.74 6,395.1 6,338.9 10,079.1 -1,751.6 3.00 1.67 -2.61 -61.89 13,053.2 85.00 321.74 6,421.2 6,365.0 10,313.8 -1,936.6 0.00 0.00 0.00 0.00 13,231.8 90.36 321.74 6,428.4 6,372.2 10,453.9 -2,047.1 3.00 3.00 0.00 -0.01 19,952.8 90.36 321.74 6,386.2 6,330.0 15,731.1 -6,209.0 0.00 0.00 0.00 0.00 2/27/2013 9:55:44AM Page 2 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -13.50 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031,136.46 469,905.67 0.00 0.00 100.0 0.00 0.00 100.0 43.8 0.0 0.0 6,031,136.46 469,905.67 0.00 0.00 200.0 0.00 0.00 200.0 143.8 0.0 0.0 6,031,136.46 469,905.67 0.00 0.00 Start Dir 3.5°1100':200'MD,200'TVD:315°RT TF 300.0 3.50 315.00 299.9 243.7 2.2 -2.2 6,031,138.63 469,903.52 3.50 2.80 342.9 5.00 315.00 342.7 286.5 4.4 -4.4 6,031,140.88 469,901.28 3.50 5.71 400.0 6.93 309.96 399.5 343.3 8.4 -8.8 6,031,144.88 469,896.90 3.50 11.03 500.0 10.38 305.69 498.4 442.2 17.5 -20.8 6,031,154.05 469,884.99 3.50 23.91 600.0 13.85 303.54 596.1 539.9 29.4 -38.0 6,031,165.99 469,867.75 3.50 41.30 700.0 17.33 302.24 692.4 636.2 43.9 -60.6 6,031,180.64 469,845.23 3.50 63.13 800.0 20.82 301.37 786.9 730.7 61.1 -88.4 6,031,197.95 469,817.53 3.50 89.33 871.3 23.31 300.90 853.0 796.8 75.0 -111.3 6,031,211.89 469,794.66 3.50 110.62 Top of Permafrost 900.0 24.31 300.73 879.2 823.0 80.9 -121.3 6,031,217.86 469,784.74 3.50 119.79 1,000.0 27.80 300.25 969.1 912.9 103.2 -159.1 6,031,240.28 469,746.98 3.50 154.40 1,062.9 30.00 300.00 1,024.1 967.9 118.4 -185.4 6,031,255.64 469,720.75 3.50 178.25 Start Dir 3.25°/100':1062.9'MD,1024.1'TVD 1,100.0 30.11 302.40 1,056.2 1,000.0 128.1 -201.3 6,031,265.33 469,704.90 3.25 193.03 1,200.0 30.62 308.75 1,142.6 1,086.4 157.5 -242.4 6,031,294.88 469,663.98 3.25 235.44 1,300.0 31.42 314.86 1,228.3 1,172.1 191.8 -280.7 6,031,329.37 469,625.77 3.25 281.46 1,400.0 32.50 320.66 1,313.1 1,256.9 231.0 -316.2 6,031,368.69 469,590.42 3.25 330.94 1,500.0 33.84 326.08 1,396.9 1,340.7 274.9 -348.8 6,031,412.71 469,558.02 3.25 383.73 1,600.0 35.39 331.11 1,479.2 1,423.0 323.3 -378.3 6,031,461.29 469,528.68 3.25 439.65 1,700.0 37.13 335.75 1,559.8 1,503.6 376.2 -404.7 6,031,514.27 469,502.51 3.25 498.53 1,800.0 39.04 340.01 1,638.5 1,582.3 433.3 -427.9 6,031,571.49 469,479.57 3.25 560.18 1,838.1 39.81 341.54 1,668.0 1,611.8 456.2 -435.9 6,031,594.39 469,471.69 3.25 584.38 Base of Permafrost 1,889.3 40.87 343.52 1,707.0 1,650.8 487.8 -445.8 6,031,626.02 469,461.89 3.25 617.41 Ugnu D 1,900.0 41.09 343.93 1,715.1 1,658.9 494.5 -447.8 6,031,632.76 469,459.95 3.25 624.40 2,000.0 43.27 347.52 1,789.2 1,733.0 559.6 -464.3 6,031,697.88 469,443.71 3.25 690.97 2,100.0 45.55 350.84 1,860.6 1,804.4 628.3 -477.4 6,031,766.64 469,430.90 3.25 759.70 2,200.0 47.92 353.90 1,929.2 1,873.0 700.5 -487.0 6,031,838.83 469,421.56 3.25 830.35 2,203.5 48.00 354.00 1,931.5 1,875.3 703.1 -487.3 6,031,841.41 469,421.30 3.25 832.85 Start Dir 3°/100':2203.5'MD,1931.5'TVD 2,300.0 50.89 354.10 1,994.2 1,938.0 776.0 -494.9 6,031,914.35 469,413.99 3.00 903.47 2,400.0 53.89 354.19 2,055.3 1,999.1 854.8 -503.0 6,031,993.17 469,406.23 3.00 979.73 2,500.0 56.89 354.27 2,112.1 2,055.9 936.6 -511.2 6,032,075.08 469,398.28 3.00 1,058.93 2,600.0 59.89 354.35 2,164.5 2,108.3 1,021.4 -519.7 6,032,159.84 469,390.18 3.00 1,140.85 2,700.0 62.89 354.42 2,212.3 2,156.1 1,108.7 -528.3 6,032,247.22 469,381.95 3.00 1,225.26 2,740.8 64.11 354.45 2,230.5 2,174.3 1,145.1 -531.8 6,032,283.58 469,378.56 3.00 1,260.37 End Dir:2740.8'MD,2230.5'TVD 2,800.0 64.11 354.45 2,256.4 2,200.2 1,198.1 -537.0 6,032,336.60 469,373.62 0.00 1,311.57 2,874.7 64.11 354.45 2,289.0 2,232.8 1,265.0 -543.5 6,032,403.52 469,367.40 0.00 1,376.18 Top West Sak 2/27/2013 9:55:44AM Page 3 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 2,243.84 2,900.0 64.11 354.45 2,300.0 2,243.8 1,287.6 -545.7 6.032,426.17 469,365.29 0.00 1,398.05 3,000.0 64.11 354.45 2,343.7 2,287.5 1,377.2 -554.4 6,032,515.74 469,356.95 0.00 1,484.54 3.100.0 64.11 354.45 2,387.4 2,331.2 1,466.7 -563.1 6,032,605.31 469,348.61 0.00 1,571.02 3,200.0 64.11 354.45 2,431.0 2,374.8 1,556.3 -571.8 6,032,694.88 469,340.28 0.00 1,657.51 3,300.0 64.11 354.45 2,474.7 2,418.5 1,645.8 -580.5 6,032,784.45 469,331.94 0.00 1,743.99 3,400.0 64.11 354.45 2,518.3 2,462.1 1,735.4 -589.2 6,032,874.02 469,323.61 0.00 1,830.48 3,500.0 64.11 354.45 2,562.0 2,505.8 1,824.9 -597.9 6,032,963.59 469,315.27 0.00 1,916.96 3,600.0 64.11 354.45 2,605.7 2,549.5 1,914.5 -606.6 6,033,053.17 469,306.93 0.00 2,003.45 3,700.0 64.11 354.45 2,649.3 2,593.1 2,004.0 -615.3 6,033,142.74 469,298.60 0.00 2,089.94 3,800.0 64.11 354.45 2,693.0 2,636.8 2,093.5 -624.0 6,033,232.31 469,290.26 0.00 2,176.42 3,900.0 64.11 354.45 2,736.6 2,680.4 2,183.1 -632.6 6,033,321.88 469,281.93 0.00 2,262.91 4,000.0 64.11 354.45 2,780.3 2,724.1 2,272.6 -641.3 6,033,411.45 469,273.59 0.00 2,349.39 4,100.0 64.11 354.45 2,823.9 2,767.7 2,362.2 -650.0 6,033,501.02 469,265.25 0.00 2,435.88 4,200.0 64.11 354.45 2,867.6 2,811.4 2,451.7 -658.7 6,033,590.59 469,256.92 0.00 2,522.36 4,290.2 64.11 354.45 2,907.0 2,850.8 2,532.5 -666.6 6,033,671.42 469,249.39 0.00 2,600.41 Cret tuffs 4,300.0 64.11 354.45 2,911.3 2,855.1 2,541.3 -667.4 6,033,680.16 469,248.58 0.00 2,608.85 4,400.0 64.11 354.45 2,954.9 2,898.7 2,630.8 -676.1 6,033,769.73 469,240.25 0.00 2,695.33 4,500.0 64.11 354.45 2,998.6 2,942.4 2,720.4 -684.8 6,033,859.30 469,231.91 0.00 2,781.82 4,600.0 64.11 354.45 3,042.2 2,986.0 2,809.9 -693.5 6,033,948.87 469,223.57 0.00 2,868.31 4,700.0 64.11 354.45 3,085.9 3,029.7 2,899.4 -702.2 6,034,038.44 469,215,24 0.00 2,954.79 4,800.0 64.11 354.45 3,129.6 3,073.4 2,989.0 -710.9 6,034,128.01 469,206.90 0.00 3,041.28 4,900.0 64.11 354.45 3,173.2 3,117.0 3,078.5 -719.6 6,034,217.58 469,198.56 0.00 3,127.76 5,000.0 64.11 354.45 3,216.9 3,160.7 3,168.1 -728.3 6,034,307.15 469,190.23 0.00 3,214.25 5,100.0 64.11 354.45 3,260.5 3,204.3 3,257.6 -737.0 6,034,396.72 469,181.89 0.00 3,300.73 5,156.1 64.11 354.45 3,285.0 3,228.8 3,307.8 -741.9 6,034,446.93 469,177.22 0.00 3,349.22 Hue 2 shale 5,200.0 64.11 354.45 3,304.2 3,248.0 3,347.2 -745.7 6,034,486.29 469,173.56 0.00 3,387.22 5,225.2 64.11 354.45 3,315.2 3,259.0 3,369.8 -747.9 6,034,508.89 469,171.45 0.00 3,409.04 11-3/4 5,300.0 64.11 354.45 3,347.8 3,291.6 3,436.7 -754.4 6,034,575.86 469,165.22 0.00 3,473.70 5,400.0 64.11 354.45 3,391.5 3,335.3 3,526.3 -763.1 6,034,665.43 469,156.88 0.00 3,560.19 5,500.0 64.11 354.45 3,435.2 3,379.0 3,615.8 -771.8 6,034,755.00 469,148.55 0.00 3,646.68 5,600.0 64.11 354.45 3,478.8 3,422.6 3,705.3 -780.5 6,034,844.57 469,140.21 0.00 3,733.16 5,700.0 64.11 354.45 3,522.5 3,466.3 3,794.9 -789.2 6,034,934.14 469,131.88 0.00 3,819.65 , 5,800.0 64.11 354.45 3,566.1 3,509.9 3,884.4 -797.9 6,035,023.71 469,123.54 0.00 3,906.13 5,900.0 64.11 354.45 3,609.8 3,553.6 3,974.0 -806.6 6,035,113.28 469,115.20 0.00 3,992.62 6,000.0 64.11 354.45 3,653.5 3,597.3 4,063.5 -815.3 6,035,202.85 469,106.87 0.00 4,079.10 6,100.0 64.11 354.45 3,697.1 3,640.9 4,153.1 -824.0 6,035,292.42 469,098.53 0.00 4,165.59 6,200.0 64.11 354.45 3,740.8 3,684.6 4,242.6 -832.7 6,035,381.99 469,090.19 0.00 4,252.07 6,300.0 64.11 354.45 3,784.4 3,728.2 4,332.2 -841.4 6,035,471.57 469,081.86 0.00 4,338.56 6,400.0 64.11 354.45 3,828.1 3,771.9 4,421.7 -850.1 6,035,561.14 469,073.52 0.00 4,425.05 6,500.0 64.11 354.45 3,871.7 3,815.5 4,511.3 -858.8 6,035,650.71 469,065.19 0.00 4,511.53 6,600.0 64.11 354.45 3,915.4 3,859.2 4,600.8 -867.5 6,035,740.28 469,056.85 0.00 4,598.02 6,700.0 64.11 354.45 3,959.1 3,902.9 4,690.3 -876.2 6,035,829.85 469,048.51 0.00 4,684.50 2/27/2013 9:55:44AM Page 4 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,946.52 6,800.0 64.11 354.45 4,002.7 3,946.5 4,779.9 -884.9 6,035,919.42 469,040.18 0.00 4,770.99 6,900.0 64.11 354.45 4,046.4 3,990.2 4,869.4 -893.6 6,036,008.99 469,031.84 0.00 4,857.47 7,000.0 64.11 354.45 4,090.0 4,033.8 4,959.0 -902.3 6,036,098.56 469,023.51 0.00 4,943.96 7.100.0 64.11 354.45 4.133.7 4,077.5 5,048.5 -911.0 6,036,188.13 469,015.17 0.00 5,030.44 7,200.0 64.11 354.45 4,177.4 4,121.2 5,138.1 -919.7 6,036,277.70 469.006.83 0.00 5.116.93 7,300.0 64.11 354.45 4,221.0 4,164.8 5,227.6 -928.4 6,036,367.27 468.998.50 0.00 5,203.42 7,400.0 64.11 354.45 4,264.7 4,208.5 5,317.2 -937.1 6,036,456.84 468,990.16 0.00 5,289.90 7,500.0 64.11 354.45 4,308.3 4,252.1 5,406.7 -945.8 6,036,546.41 468,981.82 0.00 5,376.39 7,600.0 64.11 354.45 4,352.0 4,295.8 5,496.2 -954.5 6,036,635.98 468,973.49 0.00 5,462.87 7,616.1 64.11 354.45 4,359.0 4,302.8 5,510.6 -955.9 6,036,650.37 468,972.15 0.00 5,476.77 Brookian 2B 7,700.0 64.11 354.45 4,395.6 4,339.4 5,585.8 -963.2 6,036,725.55 468,965.15 0.00 5,549.36 7,800.0 64.11 354.45 4,439.3 4,383.1 5,675.3 -971.9 6,036,815.12 468,956.82 0.00 5,635.84 7,900.0 64.11 354.45 4,483.0 4,426.8 5,764.9 -980.6 6,036,904.69 468,948.48 0.00 5,722.33 8,000.0 64.11 354.45 4,526.6 4,470.4 5,854.4 -989.3 6,036,994.26 468,940.14 0.00 5,808.81 8,100.0 64.11 354.45 4,570.3 4,514.1 5,944.0 -998.0 6,037,083.83 468,931.81 0.00 5,895.30 8,200.0 64.11 354.45 4,613.9 4,557.7 6,033.5 -1,006.7 6,037,173.40 468,923.47 0.00 5,981.79 8,300.0 64.11 354.45 4,657.6 4,601.4 6,123.1 -1,015.4 6,037,262.97 468,915.14 0.00 6,068.27 8,400.0 64.11 354.45 4,701.3 4,645.1 6,212.6 -1,024.1 6,037,352.54 468,906.80 0.00 6,154.76 8,500.0 64.11 354.45 4,744.9 4,688.7 6,302.1 -1,032.8 6,037,442.11 468,898.46 0.00 6,241.24 8,600.0 64.11 354.45 4,788.6 4,732.4 6,391.7 -1,041.5 6,037,531.68 468,890.13 0.00 6,327.73 8,700.0 64.11 354.45 4,832.2 4,776.0 6,481.2 -1,050.2 6,037,621.25 468,881.79 0.00 6,414.21 8,800.0 64.11 354.45 4,875.9 4,819.7 6,570.8 -1,058.9 6,037,710.82 468,873.45 0.00 6,500.70 8,900.0 64.11 354.45 4,919.5 4,863.3 6,660.3 -1,067.6 6,037,800.40 468,865.12 0.00 6,587.18 9,000.0 64.11 354.45 4,963.2 4,907.0 6,749.9 -1,076.3 6,037,889.97 468,856.78 0.00 6,673.67 9,100.0 64.11 354.45 5,006.9 4,950.7 6,839.4 -1,085.0 6,037,979.54 468,848.45 0.00 6,760.16 9,200.0 64.11 354.45 5,050.5 4,994.3 6,929.0 -1,093.7 6,038,069.11 468,840.11 0.00 6,846.64 9,300.0 64.11 354.45 5,094.2 5,038.0 7,018.5 -1,102.4 6,038,158.68 468,831.77 0.00 6,933.13 9,384.3 64.11 354.45 5,131.0 5,074.8 7,094.0 -1,109.8 6,038,234.22 468,824.74 0.00 7,006.07 Top Torok Sand 9,400.0 64.11 354.45 5,137.8 5,081.6 7,108.1 -1,111.1 6,038,248.25 468,823.44 0.00 7,019.61 9,500.0 64.11 354.45 5,181.5 5,125.3 7,197.6 -1,119.8 6,038,337.82 468,815.10 0.00 7,106.10 9,600.0 64.11 354.45 5,225.2 5,169.0 7,287.1 -1,128.5 6,038,427.39 468,806.77 0.00 7,192.58 9,700.0 64.11 354.45 5,268.8 5,212.6 7,376.7 -1,137.2 6,038,516.96 468,798.43 0.00 7,279.07 9,800.0 64.11 354.45 5,312.5 5,256.3 7,466.2 -1,145.9 6,038,606.53 468,790.09 0.00 7,365.56 9,900.0 64.11 354.45 5,356.1 5,299.9 7,555.8 -1,154.6 6,038,696.10 468,781.76 0.00 7,452.04 9,940.9 64.11 354.45 5,374.0 5,317.8 7,592.4 -1,158.2 6,038,732.77 468,778.34 0.00 7,487.44 Base Torok Sand 10,000.0 64.11 354.45 5,399.8 5,343.6 7,645.3 -1,163.3 6,038,785.67 468,773.42 0.00 7,538.53 10,100.0 64.11 354.45 5,443.4 5,387.2 7,734.9 -1,172.0 6,038,875.24 468,765.09 0.00 7,625.01 10,200.0 64.11 354.45 5,487.1 5,430.9 7,824.4 -1,180.7 6,038,964.81 468,756.75 0.00 7,711.50 10,241.0 64.11 354.45 5,505.0 5,448.8 7,861.1 -1,184.3 6,039,001.53 468,753.33 0.00 7,746.95 Torok 1 Shale 10,252.4 64.11 354.45 5,510.0 5,453.8 7,871.4 -1,185.3 6,039,011.79 468,752.38 0.00 7,756.86 9 5/8" 2/27/2013 9:55:44AM Page 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Veil Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 5,474.56 10,300.0 64.11 354.45 5,530.8 5,474.6 7,914.0 -1,189.4 6,039,054.38 468,748.41 0.00 7,797.98 10,400.0 64.11 354.45 5,574.4 5,518.2 8,003.5 -1,198.1 6,039,143.95 468,740.08 0.00 7,884.47 10,500.0 64.11 354.45 5,618.1 5,561.9 8,093.0 -1.206.8 6,039,233.52 468,731.74 0.00 7,970.95 10,600.0 64.11 354.45 5,661.7 5,605.5 8,182.6 -1.215.5 6,039,323.09 468,723.40 0.00 8,057.44 10,700.0 64.11 354.45 5,705.4 5,649.2 8,272.1 -1.224.2 6,039.412.66 468.715.07 0.00 8,143.93 10,800.0 64.11 354.45 5,749.1 5,692.9 8.361.7 -1,232.9 6,039.502.23 468,706.73 0.00 8.230.41 10,900.0 64.11 354.45 5,792.7 5,736.5 8,451.2 -1,241.6 6,039,591.80 468,698.40 0.00 8,316.90 11,000.0 64.11 354.45 5,836.4 5,780.2 8,540.8 -1,250.3 6,039,681.37 468,690.06 0.00 8,403.38 11,100.0 64.11 354.45 5,880.0 5,823.8 8,630.3 -1,259.0 6,039,770.94 468,681.72 0.00 8,489.87 11,200.0 64.11 354.45 5,923.7 5,867.5 8,719.9 -1,267.7 6,039,860.51 468,673.39 0.00 8,576.35 11,219.0 64.11 354.45 5,932.0 5,875.8 8,736.9 -1,269.4 6,039,877.57 468,671.80 0.00 8,592.82 Top HRZ 11,300.0 64.11 354.45 5,967.3 5,911.1 8,809.4 -1,276.4 6,039,950.08 468,665.05 0.00 8,662.84 11,400.0 64.11 354.45 6,011.0 5,954.8 8,898.9 -1,285.1 6,040,039.65 468,656.72 0.00 8,749.32 11,499.4 64.11 354.45 6,054.4 5,998.2 8,988.0 -1,293.8 6,040,128.69 468,648.43 0.00 8,835.29 Start Dir 3°/100':11499.4'MD,6054.4'TVD 11,500.0 64.12 354.43 6,054.7 5,998.5 8,988.5 -1,293.8 6,040,129.23 468,648.38 2.89 8,835.81 11,526.2 64.49 353.67 6,066.0 6,009.8 9,011.9 -1,296.3 6,040,152.67 468,646.03 3.00 8,858.51 Base HRZ(Top Kalubik Sh) 11,600.0 65.56 351.53 6,097.2 6,041.0 9,078.3 -1,304.9 6,040,219.08 468,637.67 3.00 8,923.42 11,700.0 67.06 348.69 6,137.4 6,081.2 9,168.5 -1,320.6 6,040,309.33 468,622.30 3.00 9,013.10 11,800.0 68.61 345.91 6,175.1 6,118.9 9,258.8 -1,341.0 6,040,399.73 468,602.30 3.00 9,104.60 11,835.8 69.17 344.93 6,188.0 6,131.8 9,291.2 -1,349.4 6,040,432.12 468,594.01 3.00 9,137.79 Kalubik Marker 11,900.0 70.20 343.19 6,210.3 6,154.1 9,349.0 -1,365.9 6,040,490.03 468,577.72 3.00 9,197.66 12,000.0 71.83 340.53 6,242.8 6,186.6 9,438.9 -1,395.4 6,040,579.99 468,548.65 3.00 9,292.04 12,033.1 72.38 339.66 6,253.0 6,196.8 9,468.5 -1,406.1 6,040,609.69 468,538.03 3.00 9,323.57 Top Kuparuk C 12,073.5 73.05 338.61 6,265.0 6,208.8 9,504.6 -1,419.9 6,040,645.77 468,524.44 3.00 9,362.13 LCU(Top Miluveach Sh) 12,100.0 73.50 337.92 6,272.6 6,216.4 9,528.1 -1,429.2 6,040,669.35 468,515.15 3.00 9,387.48 12,200.0 75.20 335.35 6,299.6 6,243.4 9,616.5 -1,467.4 6,040,757.87 468,477.32 3.00 9,483.71 12,300.0 76.92 332.82 6,323.7 6,267.5 9,703.8 -1,509.8 6,040,845.32 468,435.27 3.00 9,580.47 12,400.0 78.67 330.33 6,344.8 6,288.6 9,789.7 -1,556.4 6,040,931.44 468,389.10 3.00 9,677.49 12,500.0 80.45 327.87 6,363.0 6,306.8 9,874.1 -1,606.9 6,041,016.01 468,338.94 3.00 9,774.51 12,600.0 82.23 325.43 6,378.0 6,321.8 9,956.7 -1,661.2 6,041,098.79 468,284.94 3.00 9,871.27 12,700.0 84.04 323.02 6,390.0 6,333.8 10,037.2 -1,719.3 6,041,179.56 468,227.23 3.00 9,967.49 12,710.0 84.22 322.78 6,391.0 6,334.8 10,045.2 -1,725.3 6,041,187.54 468,221.24 3.00 9,977.11 BCU(Top Kingak Sh) 12,753.2 85.00 321.74 6,395.1 6,338.9 10,079.2 -1,751.6 6,041,221.63 468,195.08 3.00 10,018.37 End Dir:12753.2'MD,6395.1'TVD 12,800.0 85.00 321.74 6,399.1 6,342.9 10,115.8 -1,780.4 6,041,258.35 468,166.36 0.00 10,063.02 12,900.0 85.00 321.74 6,407.8 6,351.6 10,194.0 -1,842.1 6,041,336.81 468,105.00 0.00 10,158.43 13,000.0 85.00 321.74 6,416.6 6,360.4 10,272.2 -1,903.8 6,041,415.27 468,043.63 0.00 10,253.84 2/27/2013 9:55:44AM Page 6 COMPASS 5000.1 Build 61 0 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +E/-W Northing Easting DLS Vert Section (usft) (0) (°) (usft) usft (usft) (usft) (usft) (usft) 6,361.80 13,016.5 85.00 321.74 6,418.0 6,361.8 10,285.1 -1,914.0 6,041,428.19 468,033.53 0.00 10,269.55 Top Nuiqsut 13,050.9 85.00 321.74 6,421.0 6,364.8 10.312.0 -1,935.2 6,041,455.20 468,012.41 0.00 10,302.39 Nuiqsut 1 13,053.2 85.00 321.74 6,421.2 6,365.0 10,313.8 -1,936.6 6,041,457.02 468,010.99 0.00 10,304.59 Start Dir 3°/100':13053.2'MD,6421.2'TVD 13,100.0 86.40 321.74 6,424.7 6,368.5 10,350.5 -1,965.5 6,041,493.77 467,982.24 3.00 10,349.29 13,104.7 86.55 321.74 6,425.0 6,368.8 10.354.1 -1,968.4 6,041,497.47 467,979.35 3.00 10,353.78 7" 13,200.0 89.40 321.74 6,428.4 6,372.2 10,428.9 -2,027.4 6,041,572.47 467,920.69 3.00 10,444.98 13,231.8 90.36 321.74 6,428.4 6,372.2 10,453.9 -2,047.1 6,041,597.52 467,901.10 3.00 10,475.44 End Dir:13231.8'MD,6428.4'TVD 13,300.0 90.36 321.74 6,428.0 6,371.8 10,507.4 -2,089.3 6,041,651.23 467,859.09 0.00 10,540.75 13,400.0 90.36 321.74 6,427.4 6,371.2 10,586.0 -2,151.3 6,041,729.99 467,797.49 0.00 10,636.52 13,500.0 90.36 321.74 6,426.7 6,370.5 10,664.5 -2,213.2 6,041,808.75 467,735.89 0.00 10,732.29 13,600.0 90.36 321.74 6,426.1 6,369.9 10,743.0 -2,275.1 6,041,887.51 467,674.29 0.00 10,828.06 13,700.0 90.36 321.74 6,425.5 6,369.3 10,821.5 -2,337.0 6,041,966.27 467,612.69 0.00 10,923.83 13,800.0 90.36 321.74 6,424.9 6,368.7 10,900.0 -2,399.0 6,042,045.03 467,551.09 0.00 11,019.60 13,900.0 90.36 321.74 6,424.2 6,368.0 10,978.5 -2,460.9 6,042,123.79 467,489.49 0.00 11,115.37 14,000.0 90.36 321.74 6,423.6 6,367.4 11,057.1 -2,522.8 6,042,202.55 467,427.90 0.00 11,211.14 14,100.0 90.36 321.74 6,423.0 6,366.8 11,135.6 -2,584.7 6,042,281.31 467,366.30 0.00 11,306.91 14,200.0 90.36 321.74 6,422.3 6,366.1 11,214.1 -2,646.7 6,042,360.07 467,304.70 0.00 11,402.67 14,300.0 90.36 321.74 6,421.7 6,365.5 11,292.6 -2,708.6 6,042,438.83 467,243.10 0.00 11,498.44 14,400.0 90.36 321.74 6,421.1 6,364.9 11,371.1 -2,770.5 6,042,517.59 467,181.50 0.00 11,594.21 14,500.0 90.36 321.74 6,420.5 6,364.3 11,449.7 -2,832.4 6,042,596.35 467,119.90 0.00 11,689.98 14,600.0 90.36 321.74 6,419.8 6,363.6 11,528.2 -2,894.3 6,042,675.11 467,058.30 0.00 11,785.75 14,700.0 90.36 321.74 6,419.2 6,363.0 11,606.7 -2,956.3 6,042,753.87 466,996.70 0.00 11,881.52 14,800.0 90.36 321.74 6,418.6 6,362.4 11,685.2 -3,018.2 6,042,832.63 466,935.10 0.00 11,977.29 14,900.0 90.36 321.74 6,417.9 6,361.7 11,763.7 -3,080.1 6,042,911.39 466,873.50 0.00 12,073.06 15,000.0 90.36 321.74 6,417.3 6,361.1 11,842.2 -3,142.0 6,042,990.15 466,811.90 0.00 12,168.83 15,100.0 90.36 321.74 6,416.7 6,360.5 11,920.8 -3,204.0 6,043,068.91 466,750.30 0.00 12,264.60 15,200.0 90.36 321.74 6,416.1 6,359.9 11,999.3 -3,265.9 6,043,147.67 466,688.70 0.00 12,360.37 15,300.0 90.36 321.74 6,415.4 6,359.2 12,077.8 -3,327.8 6,043,226.43 466,627.10 0.00 12,456.13 15,400.0 90.36 321.74 6,414.8 6,358.6 12,156.3 -3,389.7 6,043,305.19 466,565.51 0.00 12,551.90 15,500.0 90.36 321.74 6,414.2 6,358.0 12,234.8 -3,451.7 6,043,383.96 466,503.91 0.00 12,647.67 15,600.0 90.36 321.74 6,413.5 6,357.4 12,313.4 -3,513.6 6,043,462.72 466,442.31 0.00 12,743.44 15,700.0 90.36 321.74 6,412.9 6,356.7 12,391.9 -3,575.5 6,043,541.48 466,380.71 0.00 12,839.21 15,800.0 90.36 321.74 6,412.3 6,356.1 12,470.4 -3,637.4 6,043,620.24 466,319.11 0.00 12,934.98 15,900.0 90.36 321.74 6,411.7 6,355.5 12,548.9 -3,699.4 6,043,699.00 466,257.51 0.00 13,030.75 16,000.0 90.36 321.74 6,411.0 6,354.8 12,627.4 -3,761.3 6,043,777.76 466,195.91 0.00 13,126.52 16,100.0 90.36 321.74 6,410.4 6,354.2 12,705.9 -3,823.2 6,043,856.52 466,134.31 0.00 13,222.29 16,200.0 90.36 321.74 6,409.8 6,353.6 12,784.5 -3,885.1 6,043,935.28 466,072.71 0.00 13,318.06 16,300.0 90.36 321.74 6,409.2 6,353.0 12,863.0 -3,947.1 6,044,014.04 466,011.11 0.00 13,413.83 16,400.0 90.36 321.74 6,408.5 6,352.3 12,941.5 -4,009.0 6,044,092.80 465,949.51 0.00 13,509.60 16,500.0 90.36 321.74 6,407.9 6,351.7 13,020.0 -4,070.9 6,044,171.56 465,887.91 0.00 13,605.36 2/27/2013 9:55:44AM Page 7 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (0) (usft) usft (usft) (usft) (usft) (usft) 6,351.07 16,600.0 90.36 321.74 6,407.3 6,351.1 13,098.5 -4,132.8 6,044,250.32 465,826.31 0.00 13,701.13 16,700.0 90.36 321.74 6,406.6 6,350.4 13,177.0 -4,194.7 6,044,329.08 465,764.71 0.00 13,796.90 16,800.0 90.36 321.74 6,406.0 6,349.8 13,255.6 -4.256.7 6,044,407.84 465,703.11 0.00 13,892.67 16,900.0 90.36 321.74 6,405.4 6,349.2 13,334.1 -4.318.6 6.044,486.60 465,641.52 0.00 13,988.44 17,000.0 90.36 321.74 6,404.8 6,348.6 13,412.6 -4.380.5 6,044,565.36 465,579.92 0.00 14,084.21 17,100.0 90.36 321.74 6,404.1 6,347.9 13,491.1 -4,442.4 6,044,644.12 465,518.32 0.00 14,179.98 17,200.0 90.36 321.74 6,403.5 6,347.3 13,569.6 -4,504.4 6,044.722.88 465,456.72 0.00 14,275.75 17,300.0 90.36 321.74 6,402.9 6,346.7 13,648.2 -4,566.3 6,044,801.64 465,395.12 0.00 14,371.52 17,400.0 90.36 321.74 6,402.2 6,346.0 13,726.7 -4,628.2 6,044,880.40 465,333.52 0.00 14,467.29 17,500.0 90.36 321.74 6,401.6 6,345.4 13,805.2 -4,690.1 6,044,959.16 465,271.92 0.00 14,563.06 17,600.0 90.36 321.74 6,401.0 6,344.8 13,883.7 -4,752.1 6,045,037.92 465,210.32 0.00 14,658.82 17,700.0 90.36 321.74 6,400.4 6,344.2 13,962.2 -4,814.0 6,045,116.68 465,148.72 0.00 14,754.59 17,800.0 90.36 321.74 6,399.7 6,343.5 14,040.7 -4,875.9 6,045,195.44 465,087.12 0.00 14,850.36 17,900.0 90.36 321.74 6,399.1 6,342.9 14,119.3 -4,937.8 6,045,274.20 465,025.52 0.00 14,946.13 18,000.0 90.36 321.74 6,398.5 6,342.3 14,197.8 -4,999.8 6,045,352.96 464,963.92 0.00 15,041.90 18,100.0 90.36 321.74 6,397.8 6,341.6 14,276.3 -5,061.7 6,045,431.72 464,902.32 0.00 15,137.67 18,200.0 90.36 321.74 6,397.2 6,341.0 14,354.8 -5,123.6 6,045,510.48 464,840.72 0.00 15,233.44 18,300.0 90.36 321.74 6,396.6 6,340.4 14,433.3 -5,185.5 6,045,589.24 464,779.13 0.00 15,329.21 18,400.0 90.36 321.74 6,396.0 6,339.8 14,511.9 -5,247.5 6,045,668.00 464,717.53 0.00 15,424.98 18,500.0 90.36 321.74 6,395.3 6,339.1 14,590.4 -5,309.4 6,045,746.76 464,655.93 0.00 15,520.75 18,600.0 90.36 321.74 6,394.7 6,338.5 14,668.9 -5,371.3 6,045,825.52 464,594.33 0.00 15,616.52 18,700.0 90.36 321.74 6,394.1 6,337.9 14,747.4 -5,433.2 6,045,904.28 464,532.73 0.00 15,712.29 18,800.0 90.36 321.74 6,393.4 6,337.2 14,825.9 -5,495.1 6,045,983.04 464,471.13 0.00 15,808.05 18,900.0 90.36 321.74 6,392.8 6,336.6 14,904.4 -5,557.1 6,046,061.80 464,409.53 0.00 15,903.82 19,000.0 90.36 321.74 6,392.2 6,336.0 14,983.0 -5,619.0 6,046,140.56 464,347.93 0.00 15,999.59 19,100.0 90.36 321.74 6,391.6 6,335.4 15,061.5 -5,680.9 6,046,219.32 464,286.33 0.00 16,095.36 19,200.0 90.36 321.74 6,390.9 6,334.7 15,140.0 -5,742.8 6,046,298.08 464,224.73 0.00 16,191.13 • 19,300.0 90.36 321.74 6,390.3 6,334.1 15,218.5 -5,804.8 6,046,376.84 464,163.13 0.00 16,286.90 19,400.0 90.36 321.74 6,389.7 6,333.5 15,297.0 -5,866.7 6,046,455.60 464,101.53 0.00 16,382.67 19,500.0 90.36 321.74 6,389.0 6,332.8 15,375.5 -5,928.6 6,046,534.36 464,039.93 0.00 16,478.44 19,600.0 90.36 321.74 6,388.4 6,332.2 15,454.1 -5,990.5 6,046,613.12 463,978.33 0.00 16,574.21 19,700.0 90.36 321.74 6,387.8 6,331.6 15,532.6 -6,052.5 6,046,691.88 463,916.74 0.00 16,669.98 19,800.0 90.36 321.74 6,387.2 6,331.0 15,611.1 -6,114.4 6,046,770.64 463,855.14 0.00 16,765.75 19,900.0 90.36 321.74 6,386.5 6,330.3 15,689.6 -6,176.3 6,046,849.40 463,793.54 0.00 16,861.51 19,952.8 90.36 321.74 6,386.2 6,330.0 15,731.1 -6,209.0 6,046,890.98 463,761.01 0.00 16,912.08 , Total Depth:19952.8'MD,6386.2'TVD-4-112 2/27/2013 9:55:44AM Page 8 COMPASS 5000.1 Build 61 rlioneer Natural Resources HALLI BURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) PN5 ext v2 11 0.00 0.00 6,301.2 9,824.3 -1,564.9 6,040,966.00 468,380.70 -plan misses target center by 50.4usft at 12425.5usft MD(6349.8 TVD,9811.4 N,-1568.9 E) -Point PN5 ext v2 t2 0.00 0.00 6,376.2 14,994.6 -5,582.0 6,046,152.00 464,385.00 -plan misses target center by 39.7usft at 18986.3usft MD(6392.3 TVD, 14972.2 N,-5610.5 E) -Point PN5 ext V3 T1 heel 0.00 0.00 6,421.2 10,313.8 -1,936.6 6,041,457.00 468,011.00 -plan hits target center -Point PN5 ext v1 t1 0.00 0.00 6,346.2 10,213.1 -1,858.2 6,041,356.00 468,089.00 -plan misses target center by 63.6usft at 12919.5usft MD(6409.5 TVD, 10209.2 N,-1854.2 E) -Point PN5 ext V3 T2 toe 0.00 0.00 6,386.2 15,731.1 -6,209.0 6,046,891.00 463,761.00 -plan hits target center -Point PN5 ext v1 t2 0.00 0.00 6,307.2 14,994.6 -5,582.0 6,046,152.00 464,385.00 -plan misses target center by 92.5usft at 18986.7usft MD(6392.3 TVD, 14972.5 N,-5610.8 E) Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') C) 13,104.7 6,425.0 7" 7 8-1/2 19,952.8 6,386.2 4-1/2 5-1/2 6-1/8 10,252.4 5,510.0 9 5/8" 9-5/8 11-3/4 5,225.2 3,315.2 11-3/4 11-3/4 14-1/2 2/27/2013 9:55:44AM Page 9 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology (°) (0) 12,710.0 6,391.0 BCU(Top Kingak Sh) 871.3 853.0 Top of Permafrost 9,384.3 5,131.0 Top Torok Sand I 12,033.1 6,253.0 Top Kuparuk C 9,940.9 5,374.0 Base Torok Sand 10,241.0 5,505.0 Torok 1 Shale 7,616.1 4,359.0 Brookian 2B 1,889.3 1,707.0 Ugnu D 1,838.1 1,668.0 Base of Permafrost 13,050.9 6,421.0 Nuiqsut 1 4,290.2 2,907.0 Crettuffs 5,156.1 3,285.0 Hue 2 shale 11,526.2 6,066.0 Base HRZ(Top Kalubik Sh) 11,835.8 6,188.0 Kalubik Marker 12,073.5 6,265.0 LCU(Top Miluveach Sh) 13,016.5 6,418.0 Top Nuiqsut 2,874.7 2,289.0 Top West Sak 11,219.0 5,932.0 Top HRZ Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 200.0 200.0 0.0 0.0 Start Dir 3.5°/100':200'MD,200'TVD:315°RT TF 1,062.9 1,024.1 118.4 -185.4 Start Dir 3.25°/100': 1062.9'MD, 1024.1'TVD 2,203.5 1,931.5 703.1 -487.3 Start Dir 3°/100':2203.5'MD, 1931.5'TVD 2,740.8 2,230.5 1,145.1 -531.8 End Dir:2740.8'MD,2230.5'TVD 11,499.4 6,054.4 8,988.0 -1,293.8 Start Dir 3°/100': 11499.4'MD,6054.4'TVD 12,753.2 6,395.1 10,079.2 -1,751.6 End Dir: 12753.2'MD,6395.1'TVD 13,053.2 6,421.2 10,313.8 -1,936.6 Start Dir 3°/100': 13053.2'MD,6421.2'TVD 13,231.8 6,428.4 10,453.9 -2,047.1 End Dir: 13231.8'MD,6428.4'TVD 19,952.8 6,386.2 15,731.1 -6,209.0 Total Depth: 19952.8'MD,6386.2'TVD 2/27/2013 9:55:44AM Page 10 COMPASS 5000.1 Build 61 PIONEER NATURAL RESOURCES Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-4 ODSN-4 PN5 ext ODSN-4 PN5 ext wp02.a Anticollision Summary Report 27 February, 2013 HALLIBURTON Sperry Drilling • N o. s s H Y m m \'�� ��i� O4 ...z :04 `' # �1esr%i, c) 2 u' N " a o-�$.111?-4444-1110110. �'a�/�r�� 8 Z A N Z N H!' . ' 111x0,i�rs♦ �;8, = zoo7ra.�.mh7 0 0 •la1 .pp. - .. 4 D♦ ►_�-.a1 o o �8B3o Z NNd I I . S� A kdK \ ��lk i-l'IO��� Z O , f E888ea:848o8 -. ',•.,;'•p, - ` '��• 98888„888888 z `o_ z ••••‘\.�`®;;IIA• e --'0,/ 1,4►.:�4.k•uMIA!0 0,111114.04160,"qv:� . e ' w , ,v Q N 1 c� e\'i��latt,`�`� A � Si':'A/• ,r. 0 U E o PmW .ii. gq8"4ggIL6-.S .p\ V)I/11,1",� ,i y 'L 8888M \ 1-�' f 18o888 ;. 8.A8 40(5' A i 0 7_ a.,ommnm.rnmm 11'II i Y E f Oo R Z O N J ,, ❑ rn 3 m 0 0 0 0 0 0 0 0 0 0 0 0 0 00 3 a 0 a o 0 82828282828888888888888888888 p ar N 0 N o Lo 0 0 .- U c U F eV le, r 0 N 1- r ry N ry n n ") N v voi to r m m . . . . . . . . . .Mr co m N N 0 co �0o om aoi E 3 i s ami ❑ I I +I E 0 0 000000000000000 00000000 0 0 0 0 0 0 0 0 a, O y 0 u o E a N N o . ow N o M N n o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 r o N ' o N .n N o N M o N o 0 0 0 o o N o o N o 0 00 0 0 0 0 L L R L Q N N Q tC r co O V co r O ,- N C N.-' « lt LL a ootcooc Tu AWu1W U 2g 3' co Z — Y m Z n ,9. 0 O. Z •Z a 0i 0ZO O.' N d N h gi / 1 ')i fall C o M , c � �k I�gr410.4�:q�n uu)iz m - ii p • o_c U I Q0 i 0 O .a m0'm zz 0a c 0 ++ + + y► �_ � 8 . e, F ` , r ina y I@ , r to wwww NNNN / d.r�"I3I • a N =t0 attf., CCCCI:LX C.'d AI ' (oLLLLLLLL N.*.H74 �® � t'!if • • •1 MIIZ GOG 0000 � llj�r� i, �/� / u pI o !:!; j .. J O.- C .tro j g w mmmmm t i'A'. .A► • • • o_ o o.__ z ccL Q N NNNNN /•:Mi. —• = a N N w N l d v 00000 11,1''',4.4•41411111.1/11,�� �� �, N w' W o o a,a,u. c o .nn.n.n.n ,t� 4►P� ► r%, E ¢ rn to p.> Le o ♦-4.3.1...---,.....-411.411041,4.•!,. Y < .-,:,,..7/1.0 0 I o a d oo dzzzzz op�. • d, <`,..ao . N p zo o>2o � TiNd►� � � n ,. ..)00� r ��'ae (7,00000 .., 6,'®�� 0 000co i 4: ,-o N N to N i1��Aa R r{1 'M Z, fn co❑ LONN0O. `������'r I4�Y!� N U) ZO o`.no-o) 00 �y�♦s l` !•. a 00 +o ❑ M �` N o O O E r 00 00 N oN O0(V u) LL q.o 0 n o (oNN,- o O M d . 0 i I O N E E R Pioneer Natural Resources HALLIBURTON Anticollision Report NATURAL RESOURCES ---;parry Drilling Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site Error: 0.0usft North Reference: True Reference Well: ODSN-4 Survey Calculation Method: Minimum Curvature Well Error: 0.0usft Output errors are at 2.00 sigma Reference Wellbore ODSN-4 PN5 ext Database: EDMAKPRD Reference Design: ODSN-4 PN5 ext wp02.a Offset TVD Reference: Offset Datum Reference ODSN-4 PN5 ext wp02.a Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of refer Interpolation Method: MD Interval 25.0usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 2,191.0usft Error Surface: Elliptical Conic Survey Tool Program Date 2/27/2013 From To (usft) (usft) Survey(Wellbore) Tool Name Description 42.7 600.0 ODSN-4 PN5 ext wp02.a(ODSN-4 PN5 e: SRG-SS Surface readout gyro single shot 600.0 5,225.0 ODSN-4 PN5 ext wp02.a(ODSN-4 PN5 e. MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 5,225.0 10,252.0 ODSN-4 PN5 ext wp02.a(ODSN-4 PN5 e: MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10,252.0 13,105.0 ODSN-4 PN5 ext wp02.a(ODSN-4 PN5 e: MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 13,105.0 19,952.8 ODSN-4 PN5 ext wp02.a(ODSN-4 PN5 e: MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 2/27/2013 10:21:50AM Page 2 of 5 COMPASS 5000.1 Build 61 PION EER Pioneer Natural Resources HALLIBURTON Anticollision Report NATURAL RESOURCES Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site Error: 0.0usft North Reference: True Reference Well: ODSN-4 Survey Calculation Method: Minimum Curvature Well Error: 0.0usft Output errors are at 2.00 sigma Reference Wellbore ODSN-4 PN5 ext Database: EDMAKPRD Reference Design: ODSN-4 PN5 ext wp02.a Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSDW1-44-ODSDW1-44 Disposal-ODSDW1 322.4 325.0 150.3 6.42 144.0 Pass-Major Risk ODSDW2-19-ODSDW2-19 Disposal-ODSDW2 1,020.5 1,025.0 85.4 25.38 62.0 Pass-Major Risk ODSK-13-ODSK-13-ODSK-13 548.6 550.0 89.3 12.74 76.6 Pass-Major Risk ODSK-13-ODSK-13PB1 -ODSK-13PB1 548.6 550.0 89.3 12.74 76.6 Pass-Major Risk ODSK-13-ODSK-13PB2-ODSK-13PB2 548.6 550.0 89.3 12.74 76.6 Pass-Major Risk ODSK-14-ODSK-14-ODSK-14 KupB 599.7 600.0 93.3 14.45 78.8 Pass-Major Risk ODSK-14-ODSK-14 PB1 -ODSK-14 PB1 KupB 599.7 600.0 93.3 14.45 78.8 Pass-Major Risk ODSK-14-ODSK-14 PB2-ODSK-14 PB2 KupB 599.7 600.0 93.3 14.45 78.8 Pass-Major Risk ODSK-33-ODSK-33 KupA-ODSK-33 KupA 272.2 275.0 57.9 6.11 51.8 Pass-Major Risk ODSK-33-ODSK-33 PB1 KupA-ODSK-33 PB1 I 272.2 275.0 57.9 6.11 51.8 Pass-Major Risk ODSK-35Ai-ODSK-35 KupB-ODSK-35 KupB St 273.5 275.0 69.5 6.10 63.4 Pass-Major Risk ODSK-35Ai-ODSK-35Ai-ODSK-35Ai KupH Sun/ 273.5 275.0 69.5 6.10 63.4 Pass-Major Risk ODSK-38i-ODSK-38i KupD-ODSK-38i KupD St 247.7 250.0 98.8 5.54 93.3 Pass-Major Risk ODSK-41 -ODSK-41 KupF-ODSK-41 KupF Sur, 296.6 300.0 120.9 6.68 114.3 Pass-Major Risk ODSK-41 -ODSK-41 PB1 KupF-ODSK-41 PB1 l' 296.6 300.0 120.9 6.77 114.2 Pass-Major Risk ODSK-42i-ODSK-42Ai-ODSK-42Ai 273.5 275.0 126.0 6.28 119.8 Pass-Major Risk ODSK-42i-ODSK-42i KupG-ODSK-42i KupG 273.5 275.0 126.0 6.28 119.8 Pass-Major Risk ODSK-7i-ODSN-7i Ivik Kup-ODSN-7i Ivik Kup vt 473.8 475.0 33.2 10.85 22.3 Pass-Major Risk ODSN-1 -ODSN-1 KE3-ODSN-1 KE3 374.4 375.0 22.0 8.43 13.6 Pass-Major Risk ODSN-1 -ODSN-1 KE3 PB1 -ODSN-1 KE3 PB1 374.4 375.0 22.0 8.43 13.6 Pass-Major Risk ODSN-10-ODSN-10 PS12-ODSN-10 PS12 wp1 424.4 425.0 54.7 9.87 44.9 Pass-Major Risk ODSN-11i-ODSN-11i IS11 -ODSN-11i IS11 wp1 1,078.6 1,075.0 52.9 29.45 24.1 Pass-Major Risk ODSN-12-ODSN-12 PS10-ODSN-12 PS10 wp1 449.4 450.0 68.8 10.49 58.3 Pass-Major Risk ODSN-15i-ODSN-15i-ODSN-15i IN12 652.6 650.0 99.7 15.89 83.8 Pass-Major Risk ODSN-16-ODSN-16-ODSN-16 PN13 Surveys 651.4 650.0 101.0 15.57 85.4 Pass-Major Risk ODSN-16-ODSN-16L1 -ODSN-16L1 PN13 651.4 650.0 101.0 15.57 85.4 Pass-Major Risk ODSN-17-ODSN-17-ODSN-17 PN13 Mid Survc 523.8 525.0 110.9 12.27 98.6 Pass-Major Risk ODSN-17-ODSN-17 L1 -ODSN-17 L1 PN13 523.8 525.0 110.9 12.27 98.6 Pass-Major Risk ODSN-18-ODSN-18-ODSN-18 PN11 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk ODSN-18-ODSN-18 PB5-ODSN-18 PN11 PB5 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk ODSN-18-ODSN-18 PB1 -ODSN-18 PN11 PB1 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk ODSN-18-ODSN-18 PB2-ODSN-18 PN11 PB2 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk ODSN-18-ODSN-18 PB2-ODSN-18_PB2 526.1 525.0 122.3 11.15 111.2 Pass-Major Risk ODSN-18-ODSN-18 PB3-ODSN-18 PN11 PB3 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk ODSN-18-ODSN-18 PB4-ODSN-18 PN11 PB4 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk ODSN-2-ODSN-2 PN3 ext-ODSN-2 PN3 ext wp 325.0 325.0 15.6 7.44 8.2 Pass-Major Risk ODSN-20-ODSN-20i KE4-ODSN-20i KE4 wp08 1,097.4 1,100.0 130.3 26.15 104.8 Pass-Major Risk ODSN-21 -ODSN-21 PS13-ODSN-21 PS13 wp0 1,116.4 1,100.0 158.7 28.22 130.5 Pass-Major Risk ODSN-22i-ODSN-22i IS14-ODSN-22i IS14 wp0 400.6 400.0 160.6 9.16 151.4 Pass-Major Risk ODSN-23i-ODSN-23i-ODSN-23i IN14 150.0 150.0 166.7 3.28 163.5 Pass-Major Risk ODSN-23i-ODSN-23i PB1 -ODSN-23i IN14 PB1 150.0 150.0 166.7 3.28 163.5 Pass-Major Risk ODSN-23i-ODSN-23i PB2-ODSN-23i IN14 PB2 150.0 150.0 166.7 3.28 163.5 Pass-Major Risk ODSN-24-ODSN-24 KE5-ODSN-24 KE5 175.0 175.0 173.5 3.81 169.6 Pass-Major Risk ODSN-24-ODSN-24 KE5-ODSN-24 KE5 wp18. 175.0 175.0 173.5 3.81 169.6 Pass-Major Risk ODSN-24-ODSN-24 KE5 PB1 -ODSN-24 PB1 175.0 175.0 173.5 3.81 169.6 Pass-Major Risk ODSN-24-ODSN-24 KE5 PB2-ODSN-24 KE5 P 175.0 175.0 173.5 3.81 169.6 Pass-Major Risk ODSN-25-ODSN-25-ODSN-25 KE1 273.5 275.0 39.2 6.11 33.0 Pass-Major Risk ODSN-25-ODSN-25 PB1 -ODSN-25 PB1 273.5 275.0 39.2 6.11 33.0 Pass-Major Risk ODSN-25-ODSN-25 PB2-ODSN-25 KE1 PB2 273.5 275.0 39.2 6.11 33.0 Pass-Major Risk ODSN-25-ODSN-25 PB3-ODSN-25 KE1 PB3 273.5 275.0 39.2 6.11 33.0 Pass-Major Risk ODSN-25-ODSN-25 PB4-ODSN-25 KE1 PB4 273.5 275.0 39.2 6.11 33.0 Pass-Major Risk ODSN-26i-ODSN-26 KE2 PB2-ODSN-26 KE2 P 224.5 225.0 36.9 5.03 31.9 Pass-Major Risk ODSN-26i-ODSN-26i KE2-ODSN-26i KE2 224.5 225.0 36.9 5.03 31.9 Pass-Major Risk 2/27/2013 10:21:50AM Page 3 of 5 COMPASS 5000.1 Build 61 P I NIE E R Pioneer Natural Resources HALLIBURTON Anticollision Report NATURAL RESOURCES Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site Error: 0.0usft North Reference: True Reference Well: ODSN-4 Survey Calculation Method: Minimum Curvature Well Error: 0.0usft Output errors are at 2.00 sigma Reference Wellbore ODSN-4 PN5 ext Database: EDMAKPRD Reference Design: ODSN-4 PN5 ext wp02.a Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSN-26i-ODSN-26i KE2 PB1 -ODSN-26i KE2 224.5 225.0 36.9 5.03 31.9 Pass-Major Risk ODSN-27i-ODSN-27i IN4-ODSN-27i IN4 224.5 225.0 33.6 5.02 28.6 Pass-Major Risk ODSN-28-ODSN-28 PN3-ODSN-28 PN3 wp09 249.0 250.0 33.5 5.63 27.8 Pass-Major Risk ODSN-29-ODSN-29 PN5-ODSN-29 PN5 224.5 225.0 34.0 4.95 29.1 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB1 -ODSN-29 PN5 F 224.5 225.0 34.0 4.95 29.1 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB2-ODSN-29 PN5 F 224.5 225.0 34.0 4.95 29.1 Pass-Major Risk ODSN-30-ODSN-30 PS5-ODSN-30 PS5 wp02 249.0 250.0 36.3 5.37 30.9 Pass-Major Risk ODSN-31 -ODSN-31 -ODSN-31 PN6 Surveys 249.0 250.0 45.7 5.75 40.0 Pass-Major Risk ODSN-31 -ODSN-31 PB1 -ODSN-31 PB1 PN6 Si 249.0 250.0 45.7 5.75 40.0 Pass-Major Risk ODSN-32i-ODSN-32i IN7-ODSN-32i IN7 Surve, 249.0 250.0 51.7 5.67 46.1 Pass-Major Risk ODSN-32i-ODSN-32iPB1 IN7-ODSN-32iPB1 IN 249.0 250.0 51.7 5.67 46.1 Pass-Major Risk ODSN-34i-ODSN-34 IN9-ODSN-34i IN9 Survey 273.5 275.0 62.6 6.21 56.4 Pass-Major Risk ODSN-34i-ODSN-34i PB2-ODSN-34iPB2 IN9 273.5 275.0 62.6 6.21 56.4 Pass-Major Risk ODSN-34i-ODSN-34i PB3-ODSN-34iPB3 IN9 273.5 275.0 62.6 6.21 56.4 Pass-Major Risk ODSN-34i-ODSN-34iPB1 -ODSN-34iPB1 IN9 273.5 275.0 62.6 6.21 56.4 Pass-Major Risk ODSN-36-ODSN-36 L1 -ODSN-36 L1 wp05 273.5 275.0 74.5 6.03 68.5 Pass-Major Risk ODSN-36-ODSN-36 PB1 -ODSN-36 PB1 PN10 273.5 275.0 74.5 6.12 68.4 Pass-Major Risk ODSN-36-ODSN-36 PB2-ODSN-36 PB2 PN10 273.5 275.0 74.5 6.12 68.4 Pass-Major Risk ODSN-36-ODSN-36 PN10-ODSN-36 PN10 Sur 273.5 275.0 74.5 6.12 68.4 Pass-Major Risk ODSN-37-ODSN-37-ODSN-37 PN8 297.9 300.0 92.9 6.88 86.0 Pass-Major Risk ODSN-37-ODSN-37 L1 -ODSN-37 L1 wp01 297.9 300.0 92.9 6.79 86.1 Pass-Major Risk ODSN-3i-ODSN-3i IN4 ext-ODSN-3i IN4 wp07 400.1 400.0 9.9 9.31 0.6 Pass-Major Risk ODSN-40-ODSN-40 PN12-ODSN-40 PN12 Sur 272.2 275.0 112.7 6.15 106.6 Pass-Major Risk ODSN-40-ODSN-40PB1 PN12-ODSN-40PB1 P 272.2 275.0 112.7 6.15 106.6 Pass-Major Risk ODSN-40-ODSN-40PB2 PN12-ODSN-40PB2 P 272.2 275.0 112.7 6.15 106.6 Pass-Major Risk ODSN-43-ODSN-43 PS15-ODSN-43 PS15 wp0 297.8 300.0 142.9 6.73 136.2 Pass-Major Risk ODSN-48-ODSN-48i IS16-ODSN-48i IS16 wp0'; 224.5 225.0 176.3 5.02 171.3 Pass-Major Risk ODSN-5i-ODSN-5i IS3-ODSN-5i IS3 wp09 324.8 325.0 8.0 7.43 0.6 Pass-Major Risk ODSN-6-ODSN-6 PS4-ODSN-6 PS4 wp01 324.7 325.0 14.9 7.15 7.7 Pass-Major Risk • ODSN-8-ODSN-8 PS8-ODSN-8 PS8 wp08-8K 399.4 400.0 40.7 9.15 31.5 Pass-Major Risk ODSN-9i-ODSN-9i IS9-ODSN-91 wp12-8k horz 523.8 525.0 48.9 12.29 36.6 Pass-Major Risk ODST-39-ODSN-39i IN11 -ODSN-39i IN11 273.4 275.0 106.3 6.19 100.2 Pass-Major Risk ODST-39-ODST-39 Torok D-ODST-39 Torok D 273.4 275.0 106.3 6.19 100.2 Pass-Major Risk ODST-39-ODST-39 Torok D PB1 -ODST-39 Tor 273.4 275.0 106.3 6.19 100.2 Pass-Major Risk ODST-45-ODSN-45i PB1 IN13-ODSN-45i PB1 297.8 300.0 157.7 6.96 150.7 Pass-Major Risk ODST-45-ODST-45A-ODST-45A Surveys 297.8 300.0 157.7 6.96 150.7 Pass-Major Risk ODST-46i-ODST-46i-ODST-46i Torok C 175.0 175.0 163.5 3.82 159.7 Pass-Major Risk ODST-46i-ODST-46i PB1 -ODST-46i Torok C P 175.0 175.0 163.5 3.82 159.7 Pass-Major Risk ODST-46i-ODST-46i PB2-ODST-46i Torok C P 175.0 175.0 163.5 3.82 159.7 Pass-Major Risk ODST-46i-ODST-46i Torok C PB3-ODST-46i P 175.0 175.0 163.5 3.82 159.7 Pass-Major Risk ODST-47-ODST-47-ODST-47 273.5 275.0 169.7 6.11 163.6 Pass-Major Risk 2/27/2013 10.21:50AM Page 4 of 5 COMPASS 5000.1 Build 61 VP-led3 Well Planning - Pioneer - Oo guruk Oooguruk Development Oooguruk Drill Site ODSN-4 ODSN-4 PN5 ext Plan: ODSN-4 PN5 ext wp02.a Standard Proposal - eport 27 February, 2013 1f� HALLIBURTON Sperry Drilling Services PIONEERIiALLIBURTON REFERENCE INFORMATION Coordiaate(NE)Reference:Well ODSN-4,Tnie North NATURAL RESOURCES Sperry Drilling Vertical(TVD)Reference:42.7 a 13.5'(§56.2usfl(Nabors 19AC) - -- --- Measured Depth Reference:42.7'+13.5't$56.2usfl(Nabors 19AC) Cakuledoo Method:Minimum Curvature COMPANY DETAILS: Well Planning-Pioneer-Oooguruk Calculation Method:Minimum Curvature SECTION DETAILS Error Systent ISCWSA Scan Method Tray.Cylinder North Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Error Surface: Elliptical Conic 1 42.7 0.00 0.00 42.7 0.0 0.0 0.00 0.00 0.0 Warning Method:Rules Based 2 200.0 0.00 0.00 200.0 0.0 0.0 0.00 0.00 0.0 1 3 342.9 5.00 315.00 342.7 4.4 -4.4 3.50 315.00 5.7 4 1062.9 30.00 300.00 1024.1 118.4 -185.4 3.50 -17.69 178.2 Project: Oooguruk Development 5 2203.5 48.00 354.00 1931.5 703.1 -487.3 3.25 85.84 832.9 Site: Oooguruk Drill Site 6 2740.8 64.11 354.45 2230.5 1145.1 -531.8 3.00 1.48 1260.4 g7 11499.4 64.11 354.45 6054.4 8988.0 -1293.8 0.00 0.00 8835.3 Well: ODSN-4 8 12753.2 85.00 321.74 6395.1 10079.1 -1751.6 3.00 51.8910018.4 Wellbore:ODSN-4 PN5 ext 9 13053.2 85.00 321.74 6421.2 10313.8 -1936.6 COO 0.0010304.6 PN5 ext V3 T1 heel 10 13231.8 90.36 321.74 6428.4 10453.9 -2047.1 3.00 -0.0110475.5 Plan:ODSN-4 PN5 ext wp02.a 11 19952.8 90.36 321.74 6386.2 15731.1 -6209.0 0.00 0.0016912.1 PN5 ext V3 T2 toe 17100- WELLBORE TARGET DETAILS(MAP CO-ORDINATES) ODSN-4/ODSN-4 PN5 ext wp02.a Name TVD +N/-S +E/-W Northing Easting Shape 16200- PN5 ext v2 11 6301.2 9824.3 -1564.96040966.00 468380.70 Point Ob.' PN5 ext v1 12 8307.2 14994.6 -5582.0 6046152.00 484385.00 Point I --4-1/2 PN5 ext v1 t1 6346.2 10213.1 -1858.26041356.00 468089.00 Point PN5 ext v2 t2 8376.2 14994.8 5582.0 6046152.00 464385.00 Point 15300- PN5 ext V3 T2 toe 8388.2 15731.1 5209.0 6046891.00 463761.00 Point I PN5 ext V3 T1 heel 8421.2 10313.8 -1936.6 6041457.00 468011.00 Point 14400- - I PN5 ext V3 T2 toel WELL DETAILS: ODSN-4 13500- Ground Level: 13.5 +NI-S +E/-W Northing Easting Latittude Longitude Slot - 0.0 0.0 6031136.46 469905.67 70°29'46.095 N 150°14'45.898 W 12600- - - SURVEY PROGRAM - Date:2013-02-27T00:00:00 Validated:Yes Version: 11700- Depth From Depth To Survey/Plan Tool 42.7 600.0 ODSN-4 PN5 ext wp02.a SRG-SS 800.0 5225.0 ODSN-4 PN5 ext wp02.a MWD+IFR2+MS+sag 7" 5225.0 10252.0 ODSN-4 PN5 ext wp02.a MVVD+IFR2+MS+sag 10800- 10252.0 13105.0 ODSN-4 PN5 ext wp02.a MWD+IFR2+MS+sag 13105.0 19952.8 ODSN-4 PN5 ext wp02.a MVVD+IFR2+MS+sag - N 9900- _ + _ IPN5 ext V3 T1 heel) - - T= 9000- 0 - 6000 CASING DETAILS 5 _ 9 5/8" T1 DMD Name Size 0 8100- 52 5225.2 11-3/4 11-3/4 ' _ - 5510.0 10252.4 9 5/8" 9-5/8 _ <"5500 6425.0 13104.7 7" 7 - 6386.2 19952.8 4-1/2 5-1/2 7200- 5000 6300- DDI=6.85 4500 5400- 4000 4500 3600- 3500 11-3/4 2700- 3000 1800-- 2500 900- 2000 0- I I I I I I 1 1 1 1 1 1 1 I I I I I I I I I I I 1 I 1 1 1 1 I I I I I I I I I I I 1 1 1 I 1 1 1 1 I I I I I I I I I I I I I I 1 I 1 1 1 I I I I I I I I 1 I I I I I I -7200 -6300 -5400 -4500 -3600 -2700 -1800 -900 0 900 1800 2700 3600 4500 5400 6300 7200 8100 West(-)/East(+)(2250 usWin) . n 0 True Vertical Depth(2000 urn) yx z m 13 N A ON) COA0 co A 0) 00 OD O) A co' O n K C ~~ 1 O O O O O O O O O O O O O O y�( 0 n 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I I f T i 1 1 1 1 1 1 1 1 1 1 1 1 1 1 I 1 I 1 I 1 1 1 1 1 1 1 1 1 1 1 ', p m — g m v 4,r 54 W M O poo m m \ 5 8 8 8. t O rn mo 0 c 2 2 zc c * N II E...,;n. g Crn-I 2 (i O0 N g 1 01ol n m [ m s y S° \\ m 2 R ID RR 0fD ID \ 1 1 1 D 'O m 3 �o o 3 N4 7 s0L , O 4'3 2 < r W 1, 1 \\ -:-*; 0 r N z A O co I \1 m \I N 1 v, v II 0 N l4 C •� .Z1 m 7 1 1 1 1W 8 O N a I I- O a m N ' W - r v c o. , , O O N O O N 0 x Q // a N t0 NO oa C " to O / p 0 m m --- .. w O 2 I I N tr O A - v >< iD 1 i 1 r A 0 - 0 E , A 0? A 0 c- c I - mt�mW - 1 W 1 11 1 1 C W wNjj �m00 A m , , N 0 Al O O IJ O O.NNG < - O 11 o NpNOi c Dj m� O Z0 0, iI o- v \ I 1 0 0 O 1 O _ m 0) - C \ I 1 TTmmm mmfnNL N(NpNJ�m p< D 1 �-tO Nm ON1 m% WOVW4(T)m O m O° DI A O�Z r A F.)-. WOo NfTA-•PP:-IP-40W m co o Z c \I 1 Q 00o0oo0boob0000000= 0 nr�JNAm el Oj N_ c •' \ \ Q WOWWN1m1��mw Apt0�p 2pEtplra Ti9 D -J ro i.1 \ 1 O m oAm OAmo_.m _1 N Wm O r\ \ 1 o 00)Ot- OiobboWrriJVWr4)5 O A \ - m m - ` \\ 1 It m 0 Z V 0 C9 Ol m,o m c ,m dt,0 8 O' O_ \ \ \ ' a r 17CQ x� ffi$Zc nmi_$c��g rr 7 o - \\ \ \ toll O A _j�9m'NEAJrO Qj� m C$'mp m NNN� 5 m - \ \ \ m ' 'E 5)=4N ga)t'Nr-ci, pSp 3 D o0,r,iTONC� W - \ \ 1 N C x o m W mN m m O °°°°- 0) 3 O CO 03 - \ \ \ _ J A m n m m x N m 0) ocn fp ca �p v O \`0) - \\\\\\1 1„ ss° N iJ �a x m00NO5 O ` \ \ _0) 3 m ro= x NONmo, - \ O N 0)0 0 0 0 0 kl 0o o— `\\\\ , 5° 0) A — 00000 N O - \\ 1 a W E)O O O E7 O GUI fn v�f/)l/)(/)VIw Co r -, \\ s N +ww Jm01AWNrm ZZZZZc 0 C 0 0 r O �0 0 bbbL1z p A, m O - .fl 'S° q w���V� 8 A _ / r ZZZZZZ0 WWWN,NN, ZZZZZS) m { 0 NN�mnmm3 ppNIOJJAJN OW N- 0 0 0 0 0m 0 v0 W CWCCOAOOA8A / \ V m - O rWW�pOWNNN; mm mAmm0NAocoOo0 N O� aW O + 6WNrrk 44€ G O N 000 l A N_ ZoW FSCfSC 880A480,00 ,,,,!...m mD 0 t1 / 3 �N WWO8 -+000005 ymNNN am 0 m / r v_ n, W = 000 »000000 \ GI o) R+1 m N - W A o ` c.c.. y N N N N N m m m 0 o 3 N 0_ 02 e0 cG A00 0000�O Co N G "-.14466600?A.0 0. ppOOO Co 0 3 m(.1 m m m m r A A A A N m 0 0 0 0 0 i±±± 0 0 $ z N0D V A 0 0 r m m m m w O 0 O mmA00 0 w moo mor..)-.-`- mmm g N- - to O WAAw ONt00WN Al iJrV + ) O_ N q iJNJiJO m mNNOmWWNAOAmmmrmAO-'ANON + ++ MMKK o iomOVO omo/O A Co - -- P D mNNm OCA0 o om jJONOC Z JAW00-`Jr + °04 ^ WO ONG WrAWAA + m •Wr•J•mOrZ n __OmmWm oc- m. A )- lOQ00 �_ O . • 000 0 - q�7 11i++ r A _ _. 0 m No.,,.. � + O f1 z fz8 to yp .t .... + 0-0 000Caubo0T¢ 0) 2. A— N it o° N �p m((��mp� N 6-.60)6ODWAAOo< m s. 0 _ N J g82gNA -1 A 1 O - 0p 0) 0 OoiCo0 a owowowwwwooO D R f7 D OCC)OOC)IJ/ .00m r J N m 0 0 0 0 0 o m 0 0 0 0Q O Z5 cn 0, mmmmmm 00 z 0 _ z ; m N S 5R888g S b, 0,2.2! Tei O m / '0 y��W�Otpp p o Orm Jmoom 10 n - m a OW000 .Z O 000a)oa�m8000 $R R ?t / o Jr NMNOl 0,0000 m 000 o- — < / N O �� 888888 rrrr NNS / 0 y a m 9'V 0) 0 0 - N \ / O Z z g&pn •y -'vO-sWTWJ (0/) ++00 - AT 0D N0AmCONmm00 0/',)/',)y O .. OO) 00p Co m rmmAWAtO 1VVO0$ ni.linZ 8 m co •; f7 0° r Q°l mo(T O 7 aa- 0 _ 0 as 888888 ro v -I i RSm z ` m m N v0i A/M v R m m- — i' Z F 000000g )S cc 33 O _ r to m »»».0)0 < W II O = N O m N -i 4 g i ng N ID • Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a 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 lysing geodetic scale factor Site Oooguruk Drill Site Site Position: Northing: 6,031,151.32 usft Latitude: 70°29'46.242 N From: Map Easting: 469,920.45us# Longitude: 150°14'45.465 W Position Uncertainty: 0.0 usft Slot Radius: 13-3/16" Grid Convergence: -0.23 ° Well ODSN-4 Well Position +N/-S 0.0 usft Northing: 6,031,136.46 usfl Latitude: 70°29'46.095 N +El-W 0.0 usft Easting: 469,905.67 usft Longitude: 150° 14'45.898 W Position Uncertainty 0.0 usft Wellhead Elevation: usft Sround Level: 13.5 usft Wellbore ODSN-4 PN5 ext 1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) IGRF200510 12/31/2009 21.99 80.81 57,759 Design ODSN-4 PN5 ext wp02.a Audit Notes: Version: Phase: PLAN Tie On Depth: 42.7 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (usft) (usft) (usft) (°) 42.7 0.0 0.0 338.46 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 0.00 0.00 0.00 0.00 200.0 0.00 0.00 200.0 143.8 0.0 0.0 0.00 0.00 0.00 0.00 342.9 5.00 315.00 342.7 286.5 4.4 -4.4 3.50 3.50 0.00 315.00 1,062.9 30.00 300.00 1,024.1 967.9 118.4 -185.4 3.50 3.47 -2.08 -17.69 2,1'03.5 48.00 354.00 1,931.5 1,875.3 703.1 -487.3 3.25 1.58 4.73 85.84 2,740.8 64.11 354.45 2,230.5 2,174.3 1,145.1 -531.8 3.00 3.00 0.08 1.46 11,499.4 64.11 354.45 6,054.4 5,998.2 8,988.0 -1,293.8 0.00 0.00 0.00 0.00 12,753.2 85.00 321.74 6,395.1 6,338.9 10,079.1 -1,751.6 3.00 1.67 -2.61 -61.89 13,053.2 85.00 321.74 6,421.2 6,365.0 10,313.8 -1,936.6 0.00 0.00 0.00 0.00 13,231.8 90.36 321.74 6,428.4 6,372.2 10,453.9 -2,047.1 3.00 3.00 0.00 -0.01 19,952.8 90.36 321.74 6,386.2 6,330.0 15,731.1 -6,209.0 0.00 0.00 0.00 0.00 2272013 9:55:44AM Page 2 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) -13.50 42.7 0.00 0.00 42.7 -13.5 0.0 0.0 6,031,136.46 469,905.67 0.00 0.00 100.0 0.00 0.00 100.0 43.8 0.0 0.0 6,031,136.46 469,905.67 0.00 0.00 200.0 0.00 0.00 200.0 143.8 0.0 0.0 6,031,136.46 469,905.67 0.06 0.00 Start Dir 3.5°/100':200'MD,200'TVD:315°RT TF 300.0 3.50 315.00 299.9 243.7 2.2 -2.2 6,031,138.63 469,903.52 3.50 2.80 342.9 5.00 315.00 342.7 286.5 4.4 -4.4 6,031,140.88 469,901.28 3.50 5.71 400.0 6.93 309.96 399.5 343.3 8.4 -8.8 6,031,144.88 469,896.90 3.50 11.03 500.0 10.38 305.69 498.4 442.2 17.5 -20.8 6,031,154.05 469,884.99 3.50 23.91 ' 600.0 13.85 303.54 596.1 539.9 29.4 -38.0 6,031,165.99 469,867.75 3.50 41.30 ' 700.0 17.33 302.24 692.4 636.2 43.9 -60.6 6,031,180.64 469,845.23 3.50 63.13 800.0 20.82 301.37 786.9 730.7 61.1 -88.4 6,031,197.95 469,817.53 3.50 89.33 871.3 23.31 300.90 853.0 796.8 75.0 -111.3 6,031,211.89 469,794.66 3.50 110.62 Top of Permafrost 900.0 24.31 300.73 879.2 523.0 80.9 -121.3 6,031,217.86 469,784.74 3.50 119.79 1,000.0 27.80 300.25 969.1 912.9 103.2 -159.1 6,031,240.28 469,746.98 3.50 154.40 1,062.9 30.00 300.00 1,024.1 967.9 118.4 -185.4 6,031,255.64 469,720.75 3.50 178.25 Start Dir 3.25°/100':1062.9'MD,1024.11:UR 1,100.0 30.11 302.40 1,056.2 1,000.0 128.1 -201.3 6,031,265.33 469,704.90 3.25 193.03 1,200.0 30.62 308.75 1,142.6 1,086.4 157.5 -242.4 6,031,294.88 469,663.98 3.25 235.44 1,300.0 31.42 314.85 1,228.3 1,172.1 191.8 -280.7 6,031,329.37 469,625.77 3.25 281.46 1,400.0 32.50 320.66 1,313.1 1,1'56.9 231.0 -316.2 6,031,368.69 469,590.42 3.25 330.94 1,500.0 33.84 326.08 1,396.9 1,340.7 274.9 -348.8 6,031,412.71 469,558.02 3.25 383.73 1,600.0 35.39 331.11 1,479.2 1,423.0 323.3 -378.3 6,031,461.29 469,528.68 3.25 439.65 1,700.0 37.13 335.75 1,559.R 1,503.6 376.2 -404.7 6,031,514.27 469,502.51 3.25 498.53 1,800.0 39.04 340.61 1,638.5 1,582.3 433.3 -427.9 6,031,571.49 469,479.57 3.25 560.18 1,838.1 39.81 341.54 1,668.0 1,611.8 456.2 -435.9 6,031,594.39 469,471.69 3.25 584.38 Base of Permafrost 1,889.3 40.87 343.52 1,767.0 1,650.8 487.8 -445.8 6,031,626.02 469,461.89 3.25 617.41 Ugnu D 1,900.0 41.09 343.93 1,715.1 1,658.9 494.5 -447.8 6,031,632.76 469,459.95 3.25 624.40 2,000.0 43.27 347.52 1,789.2 1,733.0 559.6 -464.3 6,031,697.88 469,443.71 3.25 690.97 2,100.0 45.55 350.84 1,860.6 1,804.4 628.3 -477.4 6,031,766.64 469,430.90 3.25 759.70 2,200.0 47.92 353.90 1,929.2 1,873.0 700.5 -487.0 6,031,838.83 469,421.56 3.25 830.35 2,203.5 48.00 354.00 1,931.5 1,875.3 703.1 -487.3 6,031,841.41 469,421.30 3.25 832.85 Start DIr 3°/100':2203.5'MD,1931.5'TVD 2,300.0 50.89 354.10 1,994.2 1,938.0 776.0 -494.9 6,031,914.35 469,413.99 3.00 903.47 2,400.0 53.89 354.19 2,055.3 1,999.1 854.8 -503.0 6,031,993.17 469,406.23 3.00 979.73 2,500.0 56.89 354.27 2,112.1 2,055.9 936.6 -511.2 6,032,075.08 469,398.28 3.00 1,058.93 r 2,600.0 59.89 354.35 2,164.5 2,108.3 1,021.4 -519.7 6,032,159.84 469,390.18 3.00 1,140.85 2,700.0 62.89 354.42 2,212.3 2,156.1 1,108.7 -528.3 6,032,247.22 469,381.95 3.00 1,225.26 2,740.8 64.11 354.45 2,230.5 2,174.3 1,145.1 -531.8 6,032,283.58 469,378.56 3.00 1,260.37 k End Dir:2740.8'MD,2230.5'TVD 2,800.0 64.11 354.45 2,256.4 2,200.2 1,198.1 -537.0 6,032,336.60 469,373.62 0.00 1,311.57 2,874.7 64.11 354.45 2,289.0 2,232.8 1,265.0 -543.5 6,032,403.52 469,367.40 0.00 1,376.18 Top West Sak 2/272013 9:55:44AM Page 3 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLII URTO111 Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map , Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 2,243.84 2,900.0 64.11 354.45 2,300.0 2,243.8 1,287.6 -545.7 6,032,426.17 469,365.29 0.00 1,398.05 3,000.0 64.11 354.45 2,343.7 2,287.5 1,377.2 -554.4 6,032,515.74 469,356.95 0.00 1,484.54 3,100.0 64.11 354.45 2,387.4 2,331.2 1,466.7 -563.1 8,032,605.31 469,348.61 0.06 1,571.02 3,200.0 64.11 354.45 2,431.0 2,374.8 1,556.3 -571.8 6,032,694.88 469,340.28 0.00 1,657.51 3,300.0 64.11 354.45 2,474.7 2,418.5 1,645.8 -580.5 6,032,784.45 469,331.94 0.00 1,743.99 3,400.0 64.11 354.45 2,518.3 2,462.1 1,735.4 -589.2 6,032,874.02 469,323.61 0.00 1,830.48 3,500.0 64.11 354.45 2,562.0 2,505.8 1,824.9 -597.9 6,032,963.59 469,315.27 0.00 1,916.96 3,600.0 64.11 354.45 2,605.7 2,549.5 1,914.5 -606.6 6,033,053.17 469,306.93 0.00 2,003.45 3,700.0 64.11 354.45 2,649.3 2,593.1 2,004.0 -615.3 6,033,142.74 469,298.60 0.00 2,089.94 3,800.0 64.11 354.45 2,693.0 2,636.8 2,093.5 -624.0 6,033,232.31 469,290.26 0.00 2,176.42 3,900.0 64.11 354.45 2,736.6 2,680.4 2,183.1 -632.6 6,033,321.88 469,281.93 0.00 2,262.91 4,000.0 64.11 354.45 2,780.3 2,724.1 2,272.6 -641.3 6,033,411.45 469,273.59 0.00 2,349.39 4,100.0 64.11 354.45 2,823.9 2,767.7 2,362.2 -650.0 6,033,501.02 469,265.25 0.00 2,435.88 4,200.0 64.11 354.45 2,867.6 2,811.4 2,451.7 -658.7 6,033,590.59 469,256.92 0.00 2,522.36 4,290.2 64.11 354.45 2,907.0 2,850.8 2,532.5 -666.6 6,033,671.42 469,249.39 0.00 2,600.41 Cret tuffs 4,300.0 64.11 354.45 2,911.3 2,855.1 2,541.3 -667.4 6,033,680.16 469,248.58 0.00 2,608.85 4,400.0 64.11 354.45 2,954.9 2,898.7 2,630.8 -676.1 6,033,769.73 469,240.25 0.00 2,695.33 4,500.0 64.11 354.45 2,998.6 2,942.4 2,720.4 -684.8 6,033,859.30 469,231.91 0.00 2,781.82 4,600.0 64.11 354.45 3,042.2 2,986.0 2,809.9 -693.5 6,033,948.87 469,223.57 0.00 2,868.31 4,700.0 64.11 354.45 3,085.9 3,029.7 2,899.4 -702.2 6,034,038.44 469,215.24 0.00 2,954.79 4,800.0 64.11 354.45 3,129.6 3,073.4 2,989.0 -710.9 6,034,128.01 469,206.90 0.00 3,041.28 4,900.0 64.11 354.45 3,173.2 3,117.0 3,078.5 -719.6 6,034,217.58 469,198.56 0.00 3,127.76 5,000.0 64.11 354.45 3,216.9 3,160.7 3,168.1 -728.3 6,034,307.15 469,190.23 0.00 3,214.25 5,100.0 64.11 354.45 3,260.5 3,204.3 3,257.6 -737.0 6,034,396.72 469,181.89 0.00 3,300.73 5,156.1 61.11 354.45 3,285.0 3,228.8 3,307.8 -741.9 6,034,446.93 469,177.22 0.00 3,349.22 1 Hue Z shale 5,200.0 64.11 354.45 3,304.2 3,248.0 3,347.2 -745.7 6,034,486.29 469,173.56 0.00 3,387.22 5,225.2 64.11 354.45 3,315.2 3,259.0 3,369.8 -747.9 6,034,508.89 469,171.45 0.00 3,409.04 , 11-3/4 5,300.0 64.11 354.45 3,347.8 3,291.6 3,436.7 -754.4 6,034,575.86 469,165.22 0.00 3,473.70 5,400.0 64.11 354.45 3,391.5 3,335.3 3,526.3 -763.1 6,034,665.43 469,156.88 0.00 3,560.19 5,500.0 64.11 354.45 3,435.2 3,379.0 3,615.8 -771.8 6,034,755.00 469,148.55 0.00 3,646.68 5,800.0 64.11 354.45 3,478.8 3,422.6 3,705.3 -780.5 6,034,844.57 469,140.21 0.00 3,733.16 5,700.0 64.11 354.45 3,522.5 3,466.3 3,794.9 -789.2 6,034,934.14 469,131.88 0.00 3,819.65 5,800.0 64.11 354.45 3,566.1 3,509.9 3,884.4 -797.9 6,035,023.71 469,123.54 0.00 3,906.13 5,900.0 64.11 354.45 3,609.8 3,553.6 3,974.0 -806.6 6,035,113.28 469,115.20 0.00 3,992.62 6,000.0 64.11 354.45 3,653.5 3,597.3 4,063.5 -815.3 6,035,202.85 469,106.87 0.00 4,079.10 6,100.0 64.11 354.45 3,697.1 3,640.9 4,153.1 -824.0 6,035,292.42 469,098.53 0.00 4,165.59 6,200.0 64.11 354.45 3,740.8 3,684.6 4,242.6 -832.7 6,035,381.99 469,090.19 0.00 4,252.07 6,300.0 64.11 354.45 3,784.4 3,728.2 4,332.2 -841.4 6,035,471.57 469,081.86 0.00 4,338.56 6,400.0 64.11 354.45 3,828.1 3,771.9 4,421.7 -850.1 6,035,561.14 469,073.52 0.00 4,425.05 6,500.0 64.11 354.45 3,871.7 3,815.5 4,511.3 -858.8 6,035,650.71 469,065.19 0.00 4,511.53 6,600.0 64.11 354.45 3,915.4 3,859.2 4,600.8 -867.5 6,035,740.28 469,056.85 0.00 4,598.02 6,700.0 64.11 354.45 3,959.1 3,902.9 4,690.3 -876.2 6,035,829.85 469,048.51 0.00 4,684.50 2/27/2013 9:55:44AM Page 4 COMPASS 5000.1 Build 61 • Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting OLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 3,946.52 6,800.0 64.11 354.45 4,002.7 3,946.5 4,779.9 -884.9 6,035,919.42 469,040.18 0.00 4,770.99 6,900.0 64.11 354.45 4,046.4 3,990.2 4,869.4 -893.6 6,036,008.99 469,031.84 0.00 4,857.47 7,000.0 64.11 354.45 4,090.0 4,033.8 4,959.0 -902.3 6,036,098.56 469,023.51 0.0G 4,943.96 7,100.0 64.11 354.45 4,133.7 4,077.5 5,048.5 -911.0 6,036,188.13 469,015.17 0.00 5,030.44 7,200.0 64.11 354.45 4,177.4 4,121.2 5,138.1 -919.2 6,036,277.70 469,006.83 0.00 5,116.93 7,300.0 64.11 354.45 4,221.0 4,164.8 5,227.6 -928.4 6,036,367.27 468,998.50 0.00 5,203.42 7,400.0 64.11 354.45 4,264.7 4,208.5 5,317.2 -937.1 6,036,456.84 468,990.16 0.00 5,289.90 7,500.0 64.11 354.45 4,308.3 4,252.1 5,406.7 -945.8 6,036,546.41 468,981.82 0.00 5,376.39 7,600.0 64.11 354.45 4,352.0 4,295.8 5,496.2 -954.5 6,036,635.98 468,973.49 0.00 5,462.87 7,616.1 64.11 354.45 4,359.0 4,302.8 5,910.6 -955.9 6,036,650.37 468,972.15 0.00 5,476.77 Brookian 2B 7,700.0 64.11 354.45 4,395.6 4,339.4 5,585.8 -963.2 6,036,725.55 468,965.15 0.00 5,549.36 7,800.0 64.11 354.45 4,439.3 4,383.1 5,675.3 -971.9 6,036,815.12 468,956.82 0.00 5,635.84 7,900.0 64.11 354.45 4,483.0 4,426.8 5,764.9 -980.6 6,036,904.69 468,948.48 0.00 5,722.33 8,000.0 64.11 354.45 4,526.6 4,470.4 5,554.4 -989.3 6,036,994.26 468,940.14 0.00 5,808.81 8,100.0 64.11 354.45 4,570.3 4,514.1 5,944.0 -998.0 6,037,083.83 468,931.81 0.00 5,895.30 8,200.0 64.11 354.45 4,613.9 4,557.7 6,033.5 -1,006.7 6,037,173.40 468,923.47 0.00 5,981.79 8,300.0 64.11 354.45 4,657.6 4,601.4 6,123.1 -1,015.4 6,037,262.97 468,915.14 0.00 6,068.27 8,400.0 64.11 354.45 4,701.3 4,645.1 6,212.6 -1,024.1 6,037,352.54 468,906.80 0.00 6,154.76 8,500.0 64.11 354.45 4,744.9 4,688.7 6,302.1 -1,032.8 6,037,442.11 468,898.46 0.00 6,241.24 8,600.0 64.11 354.45 4,788.6 4,732.4 6,391.7 -1,041.5 6,037,531.68 468,890.13 0.00 6,327.73 8,700.0 64.11 354.45 4,832.2 4,776.0 6,481.2 -1,050.2 6,037,621.25 468,881.79 0.00 6,414.21 8,800.0 64.11 354.45 4,875.9 4,819.7 6,570.8 -1,058.9 6,037,710.82 468,873.45 0.00 6,500.70 8,900.0 64.11 354.45 4,919.5 4,863.3 6,660.3 -1,067.6 6,037,800.40 468,865.12 0.00 6,587.18 9,000.0 64.11 354.45 4,963.2 4,907.0 6,749.9 -1,076.3 6,037,889.97 468,856.78 0.00 6,673.67 9,100.0 44.11 354.45 5,006.9 4,950.7 6,839.4 -1,085.0 6,037,979.54 468,848.45 0.00 6,760.16 9,200.0 64.11 354.45 9,050.5 4,994.3 6,929.0 -1,093.7 6,038,069.11 468,840.11 0.00 6,846.64 9,300.0 64.11 354.45 5,094.2 4,038.0 7,018.5 -1,102.4 6,038,158.68 468,831.77 0.00 6,933.13 9,384.3 64.11 354.45 5,131.0 5,074.8 7,094.0 -1,109.8 6,038,234.22 468,824.74 0.00 7,006.07 1 Top Torok Sand 9,400.0 64.11 354.45 5,137.8 5,081.6 7,108.1 -1,111.1 6,038,248.25 468,823.44 0.00 7,019.61 9,500.0 64.11 354.45 5,181.5 5,125.3 7,197.6 -1,119.8 6,038,337.82 468,815.10 0.00 7,106.10 9,600.0 64.11 354.45 5,225.2 5,169.0 7,287.1 -1,128.5 6,038,427.39 468,806.77 0.00 7,192.58 9,700.0 64.11 354.45 5,268.8 5,212.6 7,376.7 -1,137.2 6,038,516.96 468,798.43 0.00 7,279.07 9,800.0 64.11 354.45 5,312.5 5,256.3 7,466.2 -1,145.9 6,038,606.53 468,790.09 0.00 7,365.56 1 9,900.0 64.11 354.45 5,356.1 5,299.9 7,555.8 -1,154.6 6,038,696.10 468,781.76 0.00 7,452.04 9,940.9 64.11 354.45 5,374.0 5,317.8 7,592.4 -1,158.2 6,038,732.77 468,778.34 0.00 7,487.44 Base Torok Sand 10,000.0 64.11 354.45 5,399.8 5,343.6 7,645.3 -1,163.3 6,038,785.67 468,773.42 0.00 7,538.53 ' 10,100.0 64.11 354.45 5,443.4 5,387.2 7,734.9 -1,172.0 6,038,875.24 468,765.09 0.00 7,625.01 10,200.0 64.11 354.45 5,487.1 5,430.9 7,824.4 -1,180.7 6,038,964.81 468,756.75 0.00 7,711.50 10,241.0 64.11 354.45 5,505.0 5,448.8 7,861.1 -1,184.3 6,039,001.53 468,753.33 0.00 7,746.95 Torok 1 Shale 10,252.4 64.11 354.45 5,510.0 5,453.8 7,871.4 -1,185.3 6,039,011.79 468,752.38 0.00 7,756.86 9 5/8" 2/27/2013 9:55:44AM Page 5 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTDN Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +NI-S +EJ-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 5,474.56 10,300.0 64.11 354.45 5,530.8 5,474.6 7,914.0 -1,189.4 6,039,054.38 468,748.41 0.00 7,797.98 10,400.0 64.11 354.45 5,574.4 5,518.2 8,003.5 -1,198.1 6,039,143.95 468,740.08 0.00 7,884.47 10,500.0 64.11 354.45 5,618.1 5,561.9 8,093.0 -1,206.8 6,039,233.52 468,731.74 0.0G 7,970.95 10,600.0 64.11 354.45 5,661.7 5,605.5 8,182.6 -1,215.5 6,039,323.09 468,723.40 0.00 8,057.44 10,700.0 64.11 354.45 5,705.4 5,649.2 8,272.1 -1,224.2 6,039,412.66 468,715.07 0.00 8,143.93 j 10,800.0 64.11 354.45 5,749.1 5,692.9 8,361.7 -1,232.9 6,039,502.23 468,706.73 0.00 8,230.41 10,900.0 64.11 354.45 5,792.7 5,736.5 8,451.2 -1,241.6 6,039,591.80 468,698.40 0.00 8,316.90 11,000.0 64.11 354.45 5,836.4 5,780.2 8,540.8 -1,250.3 6,039,681.37 468,690.06 0.00 8,403.38 1 11,100.0 64.11 354.45 5,880.0 5,823.8 8,630.3 -1,259.0 6,039,770.94 468,681.72 0.00 8,489.87 11,200.0 64.11 354.45 5,923.7 5,867.5 8,719.9 -1,267.7 6,059,860.51 468,673.39 0.00 8,576.35 11,219.0 64.11 354.45 5,932.0 5,875.8 8,736.9 -1,269.4 6,039,877.57 468,671.80 0.00 8,592.82 Top HRZ 11,300.0 64.11 354.45 5,967.3 5,911.1 8,809.4 -1,276.4 6,039,950.08 468,665.05 0.00 8,662.84 11,400.0 64.11 354.45 6,011.0 5,954.8 8,898.9 -1,285.1 6,040,039.65 468,656.72 0.00 8,749.32 11,499.4 64.11 354.45 6,054.4 5,998.2 8,588.0 -1,293.8 6,040,128.69 468,648.43 0.00 8,835.29 Start Dir 3°/100':11499.4'MD,6054.4'TVD 11,500.0 64.12 354.43 6,054.7 5,998.5 8,988.5 -1,293.8 6,040,129.23 468,648.38 2.89 8,835.81 11,526.2 64.49 353.67 8,066.0 6,009.8 9,011.5 -1,296.3 6,040,152.67 468,646.03 3.00 8,858.51 Base HRZ(Top Kalubik Sh) 11,600.0 65.56 351.53 6,097.2 6,041.0 9,078.3 -1,304.9 6,040,219.08 468,637.67 3.00 8,923.42 11,700.0 67.06 348.69 6,137.4 6,(81.2 9,168.5 -1,320.6 6,040,309.33 468,622.30 3.00 9,013.10 11,800.0 68.61 345.91 6,175.1 6,118.9 9,258.8 -1,341.0 6,040,399.73 468,602.30 3.00 9,104.60 11,835.8 69.17 344.93 6,188.0 6,131.8 9,291.2 -1,349.4 6,040,432.12 468,594.01 3.00 9,137.79 Kalubik Marker 11,900.0 70.20 343.19 6,210.3 6,154.1 9,349.0 -1,365.9 6,040,490.03 468,577.72 3.00 9,197.66 12,000.0 71.83 340.53 6,242.8 6,186.6 9,438.9 -1,395.4 6,040,579.99 468,548.65 3.00 9,292.04 12,033.1 72.38 489.66 6,253.0 6,196.8 9,468.5 -1,406.1 6,040,609.69 468,538.03 3.00 9,323.57 Top Kuparuk C 12,073.5 73.05 338.61 6,265.6 6,208.8 9,504.6 -1,419.9 6,040,645.77 468,524.44 3.00 9,362.13 LCU(Top Miluveach Sh) 12,100.0 73.50 337.92 6,272.6 6,216.4 9,528.1 -1,429.2 6,040,669.35 468,515.15 3.00 9,387.48 12,200.0 75.20 335.35 6,299.6 6,243.4 9,616.5 -1,467.4 6,040,757.87 468,477.32 3.00 9,483.71 12,300.0 76.92 332.82 6,323.7 6,267.5 9,703.8 -1,509.8 6,040,845.32 468,435.27 3.00 9,580.47 12,400.0 78.67 330.33 6,344.8 6,288.6 9,789.7 -1,556.4 6,040,931.44 468,389.10 3.00 9,677.49 12,500.0 80.45 327.87 6,363.0 6,306.8 9,874.1 -1,606.9 6,041,016.01 468,338.94 3.00 9,774.51 12,600.0 82.23 325.43 6,378.0 6,321.8 9,956.7 -1,661.2 6,041,098.79 468,284.94 3.00 9,871.27 12,700.0 84.04 323.02 6,390.0 6,333.8 10,037.2 -1,719.3 6,041,179.56 468,227.23 3.00 9,967.49 12,710.0 84.22 322.78 6,391.0 6,334.8 10,045.2 -1,725.3 6,041,187.54 468,221.24 3.00 9,977.11 BCU(Top Kingak Sh) 12,753.2 85.00 321.74 6,395.1 6,338.9 10,079.2 -1,751.6 6,041,221.63 468,195.08 3.00 10,018.37 End Dir:12753.2'MD,6395.1'TVD 12,800.0 85.00 321.74 6,399.1 6,342.9 10,115.8 -1,780.4 6,041,258.35 468,166.36 0.00 10,063.02 12,900.0 85.00 321.74 6,407.8 6,351.6 10,194.0 -1,842.1 6,041,336.81 468,105.00 0.00 10,158.43 13,000.0 85.00 321.74 6,416.6 6,360.4 10,272.2 -1,903.8 6,041,415.27 468,043.63 0.00 10,253.84 2/272013 9:55:44AM Page 6 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (°) (°) (usft) usft (usft) (usft) (usft) (usft) 6,361.80 13,016.5 85.00 321.74 6,418.0 6,361.8 10,285.1 -1,914.0 6,041,428.19 468,033.53 0.00 10,269.55 Top Nuiqsut 13,050.9 85.00 321.74 6,421.0 6,364.8 10,312.0 -1,935.2 6,041,455.20 468,012.41 0.00 10,302.39 Nuiqsut 1 13,053.2 85.00 321.74 6,421.2 6,365.0 10,313.8 -1,936.6 6,041,457.02 488,010.99 0.00 10,304.59 Start Dir 3°/100':13053.2'MD,6421.2'TVD 13,100.0 86.40 321.74 6,424.7 6,368.5 10,350.5 -1,965.5 6,041,493.77 467,982.24 3.00 10,349.29 13,104.7 86.55 321.74 6,425.0 6,368.8 10,354.1 -1,968.4 6,041,497.47 467,979.35 3.00 10,353.78 7" 13,200.0 89.40 321.74 6,428.4 6,372.2 10,428.9 -2,027.4 6,041,572.47 467,920.69 3.00 10,444.98 13,231.8 90.36 321.74 6,428.4 6,372.2 10,450.9 -2,047.1 6,041,597.52 467,901.10 3.00 10,475.44 End Dir:13231.8'MD,6428.4'TVD 13,300.0 90.36 321.74 6,428.0 6,371.8 10,507.4 -2,089.3 6,041,651.23 467,859.09 0.00 10,540.75 13,400.0 90.36 321.74 6,427.4 6,371.2 1((,586.0 -2,151.3 6,041,729.99 467,797.49 0.00 10,636.52 13,500.0 90.36 321.74 6,426.7 6,370.5 10,664.5 -2,213.2 6,041,808.75 467,735.89 0.00 10,732.29 13,600.0 90.36 321.74 6,426.1 6,369.9 10,743.0 -2,275.1 6,041,887.51 467,674.29 0.00 10,828.06 13,700.0 90.36 321.74 6,425.5 6,369.3 10,821.5 -2,337.0 6,041,966.27 467,612.69 0.00 10,923.83 13,800.0 90.36 321.74 6,424.9 6,368.7 10,900.0 -2,399.0 6,042,045.03 467,551.09 0.00 11,019.60 13,900.0 90.36 321.74 6,424.2 6,368.0 10,978.5 -2,460.9 6,042,123.79 467,489.49 0.00 11,115.37 14,000.0 90.36 321.74 6,423.6 6,367.4 11,057.1 -2,522.8 6,042,202.55 467,427.90 0.00 11,211.14 14,100.0 90.36 321.74 6,423.0 6, 66.8 11,135.6 -2,584.7 6,042,281.31 467,366.30 0.00 11,306.91 14,200.0 90.36 321.74 6,422.3 6,366.1 11,214.1 -2,646.7 6,042,360.07 467,304.70 0.00 11,402.67 14,300.0 90.36 321.74 6,421.7 6,365.5 11,292.6 -2,708.6 6,042,438.83 467,243.10 0.00 11,498.44 14,400.0 90.36 321.74 6,421.1 6,364.9 11,371.1 -2,770.5 6,042,517.59 467,181.50 0.00 11,594.21 14,500.0 90.36 321.74 6,420.5 6,364.3 11,449.7 -2,832.4 6,042,596.35 467,119.90 0.00 11,689.98 14,600.0 90.36 321.74 6,419.8 6,363.6 11,528.2 -2,894.3 6,042,675.11 467,058.30 0.00 11,785.75 14,700.9 90.36 321.74 6,419.2 6,363.0 11,606.7 -2,956.3 6,042,753.87 466,996.70 0.00 11,881.52 14,800.0 90.36 321.74 6,418.6 6,362.4 11,685.2 -3,018.2 6,042,832.63 466,935.10 0.00 11,977.29 14,900.0 90.36 321.74 6,417.5 6,361.7 11,763.7 -3,080.1 6,042,911.39 466,873.50 0.00 12,073.06 15,000.0 90.36 321.74 6,417.3 6,361.1 11,842.2 -3,142.0 6,042,990.15 466,811.90 0.00 12,168.83 15,100.0 90.36 321.74 6,416.7 6,360.5 11,920.8 -3,204.0 6,043,068.91 466,750.30 0.00 12,264.60 15,200.0 90.36 321.74 6,416.1 6,359.9 11,999.3 -3,265.9 6,043,147.67 466,688.70 0.00 12,360.37 15,300.0 90.36 321.74 6,415.4 6,359.2 12,077.8 -3,327.8 6,043,226.43 466,627.10 0.00 12,456.13 15,400.0 90.36 321.74 6,414.8 6,358.6 12,156.3 -3,389.7 6,043,305.19 466,565.51 0.00 12,551.90 15,500.0 90.36 321.74 6,414.2 6,358.0 12,234.8 -3,451.7 6,043,383.96 466,503.91 0.00 12,647.67 15,600.0 90.36 321.74 6,413.5 6,357.4 12,313.4 -3,513.6 6,043,462.72 466,442.31 0.00 12,743.44 15,700.0 90.36 321.74 6,412.9 6,356.7 12,391.9 -3,575.5 6,043,541.48 466,380.71 0.00 12,839.21 15,800.0 90.36 321.74 6,412.3 6,356.1 12,470.4 -3,637.4 6,043,620.24 466,319.11 0.00 12,934.98 15,900.0 90.36 321.74 6,411.7 6,355.5 12,548.9 -3,699.4 6,043,699.00 466,257.51 0.00 13,030.75 16,000.0 90.36 321.74 6,411.0 6,354.8 12,627.4 -3,761.3 6,043,777.76 466,195.91 0.00 13,126.52 I 16,100.0 90.36 321.74 6,410.4 6,354.2 12,705.9 -3,823.2 6,043,856.52 466,134.31 0.00 13,222.29 16,200.0 90.36 321.74 6,409.8 6,353.6 12,784.5 -3,885.1 6,043,935.28 466,072.71 0.00 13,318.06 16,300.0 90.36 321.74 6,409.2 6,353.0 12,863.0 -3,947.1 6,044,014.04 466,011.11 0.00 13,413.83 16,400.0 90.36 321.74 6,408.5 6,352.3 12,941.5 -4,009.0 6,044,092.80 465,949.51 0.00 13,509.60 16,500.0 90.36 321.74 6,407.9 6,351.7 13,020.0 -4,070.9 6,044,171.56 465,887.91 0.00 13,605.36 2/272013 9:55:44AM Page 7 COMPASS 5000.1 Build 61 Pioneer Natural Resources '1ALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (usft) (0) (0) (usft) usft (usft) (usft) (usft) (usft) 6,351.07 16,600.0 90.36 321.74 6,407.3 6,351.1 13,098.5 -4,132.8 6,044,250.32 465,826.31 0.00 13,701.13 16,700.0 90.36 321.74 6,406.6 6,350.4 13,177.0 -4,194.7 6,044,329.08 465,764.71 0.00 13,796.90 16,800.0 90.36 321.74 6,406.0 6,349.8 13,255.6 -4,256.7 6,044,407.84 465,703.11 0.0t 13,892.67 16,900.0 90.36 321.74 6,405.4 6,349.2 13,334.1 -4,318.6 6,044,486.60 465,641.52 0.00 13,988.44 17,000.0 90.36 321.74 6,404.8 6,348.6 13,412.6 -4,380.5 6,044,565.36 465,579.92 0.00 14,084.21 17,100.0 90.36 321.74 6,404.1 6,347.9 13,491.1 -4,442.4 6,044,644.12 465,518.32 0.00 14,179.98 17,200.0 90.36 321.74 6,403.5 6,347.3 13,569.6 -4,504.4 6,044,722.88 465,456.72 0.00 14,275.75 17,300.0 90.36 321.74 6,402.9 6,346.7 13,648.2 -4,566.3 6,044,801.64 465,395.12 0.00 14,371.52 17,400.0 90.36 321.74 6,402.2 6,346.0 13,726.7 -4,628.2 6,044,880.40 465,333.52 0.00 14,467.29 17,500.0 90.36 321.74 6,401.6 6,345.4 13,605.2 -4,690.1 6,044,959.16 465,271.92 0.00 14,563.06 17,600.0 90.36 321.74 6,401.0 6,344.8 13,883.7 -4,752.1 6,045,037.92 465,210.32 0.00 14,658.82 17,700.0 90.36 321.74 6,400.4 6,344.2 13,962.2 -4,814.0 6,045,116.68 465,148.72 0.00 14,754.59 17,800.0 90.36 321.74 6,399.7 6,343.5 14,040.7 -4,875.9 6,045,195.44 465,087.12 0.00 14,850.36 17,900.0 90.36 321.74 6,399.1 6,342.9 14,119.3 -4,937.8 6,045,274.20 465,025.52 0.00 14,946.13 18,000.0 90.36 321.74 6,398.5 6,342.3 14,197.8 -4,999.8 6,045,352.96 464,963.92 0.00 15,041.90 18,100.0 90.36 321.74 6,397.8 6,341.6 14,276.3 -5,061.7 6,045,431.72 464,902.32 0.00 15,137.67 18,200.0 90.36 321.74 6,357.2 6,341.0 14,354.8 -5,123.6 6,045,510.48 464,840.72 0.00 15,233.44 18,300.0 90.36 321.74 E,396.6 6,340.4 14,433.3 -5,185.5 6,045,589.24 464,779.13 0.00 15,329.21 18,400.0 90.36 321.74 6,396.0 6,339.8 14,511.9 -5,247.5 6,045,668.00 464,717.53 0.00 15,424.98 18,500.0 90.36 321.714 6,395.3 6,339.1 14,590.4 -5,309.4 6.045,746.76 464,655.93 0.00 15,520.75 18,600.0 90.36 321.74 6,394.7 6,338.5 14,668.9 -5,371.3 6,045,825.52 464,594.33 0.00 15,616.52 18,700.0 90.36 321.74 6,394.1 6,337.9 14,747.4 ,433.2 6,045,904.28 464,532.73 0.00 15,712.29 18,800.0 90.36 321.74 6,393.4 6,337.2 14,825.9 -5,495.1 6,045,983.04 464,471.13 0.00 15,808.05 18,900.0 90.36 321.74 6,392.8 6,336.6 14,904.4 -5,557.1 6,046,061.80 464,409.53 0.00 15,903.82 19,000.0 90.36 321.74 6,392.2 6,336.0 14,983.0 -5,619.0 6,046,140.56 464,347.93 0.00 15,999.59 19,100.0 RR.38 321.74 6,391.6 6,335.4 15,061.5 -5,680.9 6,046,219.32 464,286.33 0.00 16,095.36 19,200.0 90.36 321.74 6,390.9 6,334.7 15,140.0 -5,742.8 6,046,298.08 464,224.73 0.00 16,191.13 19,300.0 90.36 321.74 6,390.3 6,334.1 15,218.5 -5,804.8 6,046,376.84 464,163.13 0.00 16,286.90 19,400.0 90.36 321.74 6,389.7 6,333.5 15,297.0 -5,866.7 6,046,455.60 464,101.53 0.00 16,382.67 19,500.0 90.36 321.74 6,389.0 6,332.8 15,375.5 -5,928.6 6,046,534.36 464,039.93 0.00 16,478.44 19,600.0 90.36 321.74 6,388.4 6,332.2 15,454.1 -5,990.5 6,046,613.12 463,978.33 0.00 16,574.21 19,700.0 90.36 321.74 6,387.8 6,331.6 15,532.6 -6,052.5 6,046,691.88 463,916.74 0.00 16,669.98 19,800.0 90.36 321.74 6,387.2 6,331.0 15,611.1 -6,114.4 6,046,770.64 463,855.14 0.00 16,765.75 19,960.0 90.36 321.74 6,386.5 6,330.3 15,689.6 -6,176.3 6,046,849.40 463,793.54 0.00 16,861.51 19,952.8 90.36 321.74 6,386.2 6,330.0 15,731.1 -6,209.0 6,046,890.98 463,761.01 0.00 16,912.08 Total Depth:19952.8'MD,6386.2'TVD-4-1/2 2/27/2013 9:55:44AM Page 8 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+ 13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W, Northing Easting -Shape (°) (°) (usft) (usft) (usft) (usft) (usft) PN5 ext v2 t1 0.00 0.00 6,301.2 9,824.3 -1,564.9 6,040,966.00 468,380.70 -plan misses target center by 50.4usft at 12425.5usft MD(6349.8 TVD,9811.4 N,-1568.9 EZ -Point PN5 ext v2 t2 0.00 0.00 6,376.2 14,994.6 -5,582.0 6,046,152.00 464,385.00 -plan misses target center by 39.7usft at 18986.3usft MD(6392.3 TVD,14972.2 N,-5610.5 E) I -Point PN5 ext V3- 0.00 0.00 6,421.2 10,313.8 -1,936.6 6,041,457.00 468,011.00 -plan hits target center -Point PN5 Pxt v1 +' 0.00 0.00 6,346.2 10,213.1 -1,858.2 6,041,356.00 468,089.00 -plan misses target center by 63.6usft at 12919.5usft MD(6409.3 TVD,10209.2 N,-1854.22 E) -Point PN5 ext V3 T2 toe 0.00 0.00 6,386.2 15,731.1 -6,209.0 6,046,891.00 463,761.00 c -plan hits target center -Point i PN5 ext v1 t2 0.00 0.00 6,307.2 14,994.6 -5,582.0 6,046,152.00 464,385.00 -plan misses target center by 92.5usft at 18986.7usft MD(6392.3 TVD,14972.5 N,-5610.8 E) -Point Casing Points r Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name C') (") I 13,1043 6,425.0 7" 7 8-1/2 19,952.8 6,386.2 4-1/2 5-1/2 6-1/8 10,252.4 5,510.0 9 5/8" 9-5/8 11-3/4 h 5,225.2 3,315.2 11-3/4 11-3/4 14-1/2 t 2/27!2013 9:55:44AM Page 9 COMPASS 5000.1 Build 61 Pioneer Natural Resources HALLIBURTON Standard Proposal Report Database: EDMAKPRD Local Co-ordinate Reference: Well ODSN-4 Company: Well Planning-Pioneer-Oooguruk TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Project: Oooguruk Development MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site: Oooguruk Drill Site North Reference: True Well: ODSN-4 Survey Calculation Method: Minimum Curvature Wellbore: ODSN-4 PN5 ext Design: ODSN-4 PN5 ext wp02.a Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name tlthology (°) (0) 12,710.0 6,391.0 BCU(Top Kingak Sh) 871.3 853.0 Top of Permafrost 9,384.3 5,131.0 Top Torok Sand 12,033.1 6,253.0 Top Kuparuk C 9,940.9 5,374.0 Base Torok Sand 10,241.0 5,505.0 Torok 1 Shale 7,616.1 4,359.0 Brookian 2B 1,889.3 1,707.0 Ugnu D 1,838.1 1,668.0 Base of Permafrost 13,050.9 6,421.0 Nuiqsut 1 4,290.2 2,907.0 Cret tuffs 5,156.1 3,285.0 Hue 2 shale 11,526.2 6,066.0 Base HRZ(Top Kalubik Sh) 11,835.8 6,188.0 Kalubik Marker 12,073.5 6,265.0 LCU(Top Miluveach Sh) 13,016.5 6,418.0 Top Nuiqsut 2,874.7 2,289.0 Top West Sak 11,219.0 5,932.0 Top HRZ Plan Annotations Measured Vertical Local Coordinates Depth Deptb +N/-S +E/-W (usft) (usft) (usft) (usft) Coorment 200.0 200.0 0.0 0.0 Start Dir 3.5°/100':200'MD,200'TVD:315°RT TF 1,062.9 1,024.1 118.4 -185.4 Start Dir 3.25°/100':1062.9'MD,1024.1'TVD 2,203.9 1,931.5 703.1 -487.3 Start Dir 3°/100':2203.5'MD,1931.5'TVD 2,740.8 2,230.5 1,145.1 -531.8 End Dir:2740.8'MD,2230.5'TVD 11,499.4 6,054.4 8,988.0 -1,293.8 Start Dir 3°/100': 11499.4'MD,6054.4'TVD 12,753.2 6,395.1 10,079.2 -1,751.6 End Dir: 12753.2'MD,6395.1'TVD 13,053.2 6,421.2 10,313.8 -1,936.6 Start Dir 3°/100':13053.2'MD,6421.2'TVD 13,231.8 6,428.4 10,453.9 -2,047.1 End Dir: 13231.8'MD,6428.4'TVD 19,952.8 6,386.2 15,731.1 -6,209.0 Total Depth: 19952.8'MD,6386.2'TVD 2/27/2013 9:55:44AM Page 10 COMPASS 5000.1 Build 61 Pj3 5 „ L-i kd 3 142-� PIONEER NATURAL RESOURCES Well Planning - Pioneer - Oooguruk Oooguruk Development Oooguruk Drill Site ODSN-4 ODSN-4 PN5 ext ODSN-4 PN5 ext wp02.a Anticollision Summary Report 27 February, 2013 HALLIBURTON Sperry Drilling 0 m v ONNp8p AT J, NNNQ Na N Z COOOva O '• —o ,„, o ca pZ g Z .174011110P...-- =' ,'��.��1.� . 8�/' tO�NNO-g 0 6 Z N 4. \ �==i1,;;,'��1►=�1► 0)00000 N W 1 • 1p 0 ':::.♦� �ma I� w HrJI W z C ,.♦ ♦ ���► �♦ w cma3 o S N o,� �, �_ ;.•►♦♦�����..��/����o�i �0 ZZ> ter.: ,�•�..;;,r:,'' ;'�O,,,t� 0 < -13 » m OM(i1 ? , '':�'e4.��_1.���•A.�� NNN N d D Z a±� 440.�/ m m m m or 0 0 0 0 0 n m o i n ►♦ ���.�� �'Al art 0 m n m .o < 4 0 4•'damtA���AA•4' 3ANA* T o r - t - a7,21-Ti 'S AAS Aa4z.z - 0 • ..4 y0♦♦4% f•/�.OV **** .38 *f* n.-1,0,3 00000 g' • 0 Z - i � I� ��24pm§ ZmwD RiTTmto u te.N 2 , ,'A `�_ ��( 004441 NNNA' • m m? a o Z eb= : . - =• •Tw"Y,.,'• �� . .�1p4W�A%I�I 2 2 2 2 D D *'' O D j G Z= .. iI� .� 04: -_sera/ 0-0 izw b o .�i1,501' m e'er to •.' ,�; '- �_ • -h ,a I?b z 'O i 1��a:m-�0. o O zy,.. 63 .z3 O Q cn �'a co m! o z CD p z• z -o rr •w•' br Z d = CD y c c U) Iv w 3 mtnmm 7 0 Di 0 O = 10 3 ;tn3tn; N + O CO W V N N A W N O f0 W V 0) N 40. 434 . 431. NNW + + + + O g y g^ 0000000000000000000 V N N V N O V N N O V N3 O n O 0 O s. 88888888888888888888888882888888888 a m a 3 0 unIHHIIIHIiWIIHHY1II o o T. NIL< *3 ,g pG ��pp pp�� 00�� pp pp pp pp pp pG (� to d.�D 3 O O O O O O O O O O O O O S O O O S 8 tVi, O f�'i, 0 vVi O N O {Vrl 0 '8 0 0 0 0 O N C) 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a 0 a = o 0 0 0 0 0 0 0 0 0 0 0 0 0 3 z 0 Z d c N O ce V 0 .1 W F N to ONO.111111411 -n ',,,11�''--' , mi. ffii.58mia8vo 0 0,31)'I,/' �,,��,fto ,, co O 888 =:t8g800_ \ `, , MK88--$$888 s 414,7 �� W ` ,, n ni. $8$8 8& w '� �./11,414,7'--- 11 ��S 1\��,-� Sride0,00.7/d.:,:'.';(;":„\A) _ Alk14111100111 o 5 P + � H per. ♦wANc\ Y o O 888 88 . 4.4‘,;,10‘,14,1 `�`� �► ..t . /l i m 8 ,8588 w A 0givrS a o r � �'�8-$gBSffggg$. a OW''�,` � ti ,.. q� I' , le to © o 0! , =� jj o ' C.,�.,. jlt�.4101.: �� 1W -v co N cn g g z ` -411=\1��•�1 -stn z • N • 3 z G p '1t,-N•4V► ---a"- m 5 6., y o f, m f z w a i O N d PIONEER Pioneer Natural Resources HALLIBURTON Anticollision Report Sperry DrillingNATURAL RESOURCES Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site Error: 0.0usft North Reference: True Reference Well: ODSN-4 Survey Calculation Method: Minimum Curvature Well Error: 0.0usft Output errors are at 2.00 sigma Reference Wellbore ODSN-4 PN5 ext Database: EDMAKPRD Reference Design: ODSN-4 PN5 ext wp02.a Offset TVD Reference: Offset Datum Reference ODSN-4 PN5 ext wp02.a Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.0usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 2,191.0usft Error Surface: Elliptical Conic Survey Tool Program Date 2/27/2013 From To (usft) (usft) Survey(Wellbore) Tool Fame Description 42.7 600.0 ODSN-4 PN5 ext wp02.a(ODSN-4 PN5 e: SRG-SS Surface readout gyro single shot 600.0 5,225.0 ODSN-4 PN5 ext wp02.a(ODSN-4 PN5 e: MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 5,225.0 10,252.0 ODSN-4 PN5 ext wp02.a(ODSN-4 PN5 e: MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 10,252.0 13,105.0 ODSN-4 PN5 ext wp02.a(ODSN-4 PN5 e: MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 13,105.0 19,952.8 ODSN-4 PN5 ext wp02.a(ODSN-4 BN5 e: MWD+IFR2+MS+sag Fixed:v2:IIFR dec&3-axis correction+sag 2/27/2013 10:21:50AM Page 2 of 5 COMPASS 5000.1 Build 61 PIONEER Pioneer Natural Resources HALLIBURTON Anticollision Report Sperry Drilling RESOURCES Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site Error: 0.0usft North Reference: True Reference Well: ODSN-4 Survey Calculation Method: Minimum Curvature Well Error: 0.0usft Output errors are at 2.00 sigma Reference Wellbore ODSN-4 PN5 ext Database: EDMAKPRD Reference Design: ODSN-4 PN5 ext wp02.a Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-(o Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSDW1-44-ODSDW1-44 Disposal-ODSDW1 322.4 325.0 150.3 6.42 144.0 Pass-Ilajor Risk ODSDW2-19-ODSDW2-19 Disposal-ODSDW2 1,020.5 1,025.0 85.4 25.38 62.0 Pass-Major Risk ODSK-13-ODSK-13-ODSK-13 548.6 550.0 89.3 12.74 76.6 Pass-Major Risk ODSK-13-ODSK-13PB1 -ODSK-13PB1 548.6 550.0 89.3 12.74 76.6 Pass-Major Risk ODSK-13-ODSK-13PB2-ODSK-13PB2 548.6 550.0 89.3 12.74 76.6 Pass-Major Risk ODSK-14-ODSK-14-ODSK-14 KupB 599.7 600.0 93.3 14.45 78.8 Pass-Major Risk ODSK-14-ODSK-14 PB1 -ODSK-14 PB1 KupB 599.7 600.0 93.3 14.45 78.8 Pass-Major Risk ODSK-14-ODSK-14 PB2-ODSK-14 PB2 KupB 599.7 600.0 93.3 14.45 78.8 Pass-Major Risk ODSK-33-ODSK-33 KupA-ODSK-33 KupA 272.2 275.0 57.9 6.11 51.8 Pass-Major Risk ODSK-33-ODSK-33 PB1 KupA-ODSK-33 PB1 F 272.9 275.0 57.9 6.11 51.8 Pass-Major Risk ODSK-35Ai-ODSK-35 KupB-ODSK-35 KupB Si 273.5 275.0 69.5 6.10 63.4 Pass-Major Risk ODSK-35Ai-ODSK-35Ai-ODSK-35Ai KupH Sun, 273.5 275.0 69.5 6.10 63.4 Pass-Major Risk ODSK-38i-ODSK-38i KupD-ODSK-38i KupD Si 247.7 250.0 98.8 5.54 93.3 Pass-Major Risk ODSK-41 -ODSK-41 KupF-ODSK-41 KupF Sun, 296.6 300.0 120.9 6.68 114.3 Pass-Major Risk ODSK-41 -ODSK-41 PB1 KupF-ODSK-41 PB1 F 296.E 300.0 120.9 6.77 114.2 Pass-Major Risk ODSK-42i-ODSK-42Ai-ODSK-42Ai 273.5 275.0 126.0 6.28 119.8 Pass-Major Risk ODSK-42i-ODSK-42i KupG-ODSK-42i KupG 273.5 275.0 126.0 6.28 119.8 Pass-Major Risk ODSK-7i-ODSN-7i Ivik Kup-ODSN-7i Ivik Ifi ip u 473.8 475.0 33.2 10.85 22.3 Pass-Major Risk ODSN-1 -ODSN-1 KE3-ODSN-1 KE3 374.4 375.0 22.0 8.43 13.6 Pass-Major Risk ODSN-1 -ODSN-1 KE3 PB1 -ODSN-1 KE3 PBI 374.4 375.0 22.0 8.43 13.6 Pass-Major Risk ODSN-10-ODSN-10 PS12-ODSN-10 PS12 wp1 424.4 425.0 54.7 9.87 44.9 Pass-Major Risk ODSN-11 i-ODSN-11 i IS11 -ODSN-11i IS11 wp1 1,078.6 1,075.0 52.9 29.45 24.1 Pass-Major Risk ODSN-12-ODSN-12 PS10-ODSN-12 PS10 wp1 449.4 450.0 68.8 10.49 58.3 Pass-Major Risk ODSN-15i-ODSN-15i-ODSN-15i IN12 652.6 6Y0.0 99.7 15.89 83.8 Pass-Major Risk ODSN-16-ODSN-16-ODSN-16 PN13 Surveys 651.4 650.0 101.0 15.57 85.4 Pass-Major Risk ODSN-16-ODSN-18L1-ODSN-16L1 PN13 651.4 650.0 101.0 15.57 85.4 Pass-Major Risk ODSN-17-ODSN-17-ODSN-17 PN13 Mid Surve 523.8 525.0 110.9 12.27 98.6 Pass-Major Risk ODSN-17-OD5N-17 L1 -ODSN-17 L1 PN13 523.8 525.0 110.9 12.27 98.6 Pass-Major Risk ODSN-18-ODSN-18-ODSN-18 PN11 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk ODSN-18-ODSN-18 PBS-ODSN-18 PN11 PB5 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk ODSN-18-ODSN-18 PBI-ODSN-18 PN11 PBI 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk ODS1N-18-ODSN-18 PB2-ODSN-18 PN11 PB2 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk 012SN-18-ODSN-18 PB2-ODSN-18_PB2 526.1 525.0 122.3 11.15 111.2 Pass-Major Risk ODSN-18-ODSN-18 PB3-ODSN-18 PN11 PB3 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk ODSN-18-ODSN-18 PB4-ODSN-18 PN11 PB4 550.9 550.0 123.0 12.96 110.0 Pass-Major Risk ODSN-2-ODSN-2 PN3 ext-ODSN-2 PN3 ext wp 325.0 325.0 15.6 7.44 8.2 Pass-Major Risk ODSN-20-ODSN-20i KE4-ODSN-20i KE4 wp08 1,097.4 1,100.0 130.3 26.15 104.8 Pass-Major Risk O11SN-21 -ODSN-21 PS13-ODSN-21 PS13 wp0 1,116.4 1,100.0 158.7 28.22 130.5 Pass-Major Risk ODSN-22i-ODSN-22i IS14-ODSN-22i IS14 wp0 400.6 400.0 160.6 9.16 151.4 Pass-Major Risk ODSN-23i-ODSN-23i-ODSN-23i 1N14 150.0 150.0 166.7 3.28 163.5 Pass-Major Risk ODSN-23i-ODSN-23i PB1 -ODSN-23i IN14 PB1 150.0 150.0 166.7 3.28 163.5 Pass-Major Risk ODSN-23i-CIDSN-23i PB2-ODSN-23i IN14 PB2 150.0 150.0 166.7 3.28 163.5 Pass-Major Risk ODSN-24-OD5N-24 KE5-ODSN-24 KE5 175.0 175.0 173.5 3.81 169.6 Pass-Major Risk ODSN-24-ODSN-24 KE5-ODSN-24 KE5 wp18. 175.0 175.0 173.5 3.81 169.6 Pass-Major Risk ODSN-24-ODSN-24 KE5 PB1 -ODSN-24 PB1 175.0 175.0 173.5 3.81 169.6 Pass-Major Risk ODSN-24-ODSN-24 KE5 PB2-ODSN-24 KE5 P 175.0 175.0 173.5 3.81 169.6 Pass-Major Risk ODSN-25-ODSN-25-ODSN-25 KE1 273.5 275.0 39.2 6.11 33.0 Pass-Major Risk ODSN-25-ODSN-25 PB1 -ODSN-25 PB1 273.5 275.0 39.2 6.11 33.0 Pass-Major Risk ODSN-25-ODSN-25 PB2-ODSN-25 KE1 PB2 273.5 275.0 39.2 6.11 33.0 Pass-Major Risk ODSN-25-ODSN-25 PB3-ODSN-25 KE1 PB3 273.5 275.0 39.2 6.11 33.0 Pass-Major Risk ODSN-25-ODSN-25 PB4-ODSN-25 KE1 PB4 273.5 275.0 39.2 6.11 33.0 Pass-Major Risk ODSN-26i-ODSN-26 KE2 PB2-ODSN-26 KE2 P 224.5 225.0 36.9 5.03 31.9 Pass-Major Risk ODSN-26i-ODSN-26i KE2-ODSN-26i KE2 224.5 225.0 36.9 5.03 31.9 Pass-Major Risk 2/27/2013 10:21:50AM Page 3 of 5 COMPASS 5000.1 Build 61 • PIONEER Pioneer Natural Resources HALLIBURTON Anticollision Report Sperry Drilling NATURAL.RESOURCES Company: Well Planning-Pioneer-Oooguruk Local Co-ordinate Reference: Well ODSN-4 Project: Oooguruk Development TVD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Reference Site: Oooguruk Drill Site MD Reference: 42.7'+13.5'@ 56.2usft(Nabors 19AC) Site Error: 0.0usft North Reference: True Reference Well: ODSN-4 Survey Calculation Method: Minimum Curvature Well Error: 0.0usft Output errors are at 2.00 sigma Reference Wellbore ODSN-4 PN5 ext Database: EDMAKPRD Reference Design: ODSN-4 PN5 ext wp02.a Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-mo Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well-Wellbore-Design (usft) (usft) (usft) (usft) Oooguruk Drill Site ODSN-26i-ODSN-26i KE2 PB1 -ODSN-26i KE2 224.5 225.0 36.9 5.03 31.9 Pass-Major Risk ODSN-27i-ODSN-27i IN4-ODSN-27i IN4 224.5 225.0 33.6 5.02 28.6 Pass-Major Risk ODSN-28-ODSN-28 PN3-ODSN-28 PN3 wp09 249.0 250.0 33.5 5.63 27.8 Pass-Major Risk ODSN-29-ODSN-29 PN5-ODSN-29 PN5 224.5 225.0 34.0 4.95 29.1 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB1 -ODSN-29 PN5 F 224.5 225.0 34.0 4.95 29.1 Pass-Major Risk ODSN-29-ODSN-29 PN5 PB2-ODSN-29 PN5 F 224.5 225.0 34.0 4.95 29.1 Pass-Major Risk ODSN-30-ODSN-30 PS5-ODSN-30 PS5 wp02 249.0 250.0 36.3 5.37 30.9 Pass-Major Risk ODSN-31 -ODSN-31 -ODSN-31 PN6 Surveys 249.0 250.0 45.7 5.75 40.0 Pass-Major Risk ODSN-31 -ODSN-31 PB1 -ODSN-31 PB1 PN6 St 249.0 250.0 45.7 5.75 40.0 Pass-Major Risk ODSN-32i-ODSN-32i IN7-ODSN-32i IN7 Surve, 249M 250.0 51.7 5.67 46.1 Pass-Major Risk ODSN-32i-ODSN-32iPB1 IN7-ODSN-32iPB1 IN 249.0 250.0 51.7 5.67 46.1 Pass-Major Risk ODSN-34i-ODSN-34 1N9-ODSN-34i IN9 Survey 273.5 275.0 62.6 6.21 56.4 Pass-Major Risk ODSN-34i-ODSN-34i PB2-ODSN-34iPB2 IN9 273.5 275.0 62.6 6.21 56.4 Pass-Major Risk ODSN-34i-ODSN-34i PB3-ODSN-34iPB3 IN9 273.5 275.0 62.6 6.21 56.4 Pass-Major Risk ODSN-34i-ODSN-34iPB1 -ODSN-34iPB1 IN9 273.5 275.0 62.6 6.21 56.4 Pass-Major Risk ODSN-36-ODSN-36 L1 -ODSN-36 L1 wp05 273.5 275.0 74.5 6.03 68.5 Pass-Major Risk ODSN-36-ODSN-36 PB1 -ODSN-36 PB1 RN10 273.5 275.0 74.5 6.12 68.4 Pass-Major Risk ODSN-36-ODSN-36 PB2-ODSN-36 PB2 BRIG 8 273.5 275.0 74.5 6.12 68.4 Pass-Major Risk ODSN-36-ODSN-36 PN10-ODSN-36 PN10 Sur 273.5 275.0 74.5 6.12 68.4 Pass-Major Risk ODSN-37-ODSN-37-ODSN-37 PNA 297.9 300.0 92.9 6.88 86.0 Pass-Major Risk ODSN-37-ODSN-37 L1 -ODSN-37 L1 wp01 297.9 300.0 92.9 6.79 86.1 Pass-Major Risk ODSN-3i-ODSN-3i IN4 ext-ODSN-3i IN4 wp07 400.1 400.0 9.9 9.31 0.6 Pass-Major Risk ODSN-40-ODSN-40 PN12-ODSN-40 PN12 Sur 272.2 '75.0 112.7 6.15 106.6 Pass-Major Risk ODSN-40-ODSN-40PB1 PN12-ODSN-40PB1 P 272.2 27/5.0 112.7 6.15 106.6 Pass-Major Risk ODSN-40-ODSN-40P6'PN12-ODSN-40PB2 P 272.2 275.0 112.7 6.15 106.6 Pass-Major Risk ODSN-43-ODSN-43 PS15-ODSN-43 PS15 wp0 297.8 300.0 142.9 6.73 136.2 Pass-Major Risk ODSN-48-ODSN-48i IS16-CfeDSN-48i IS16 wp01. 224.5 225.0 176.3 5.02 171.3 Pass-Major Risk ODSN-5i-ODSN-5i 1S3-ODSN-5i IS3 wp09 324.8 325.0 8.0 7.43 0.6 Pass-Major Risk ODSN-6-OIDSN-6 PS4-ODSN-6 PS4 wp01 324.7 325.0 14.9 7.15 7.7 Pass-Major Risk ODSN-8-ODSN-8 PS8-ODSN-8 PS8 wp08-8K 399.4 400.0 40.7 9.15 31.5 Pass-Major Risk ODSN-9i-ODSN-9i IS9-ODSN-91 wp12-8k horz 523.8 525.0 48.9 12.29 36.6 Pass-Major Risk ODS1T-39-ODSN-39i IN11-ODSN-39i IN11 273.4 275.0 106.3 6.19 100.2 Pass-Major Risk OAST-39-ODST-39 Torok D-ODST-39 Torok D 273.4 275.0 106.3 6.19 100.2 Pass-Major Risk ODST-39-ODST-39 Torok D PB1 -ODST-39 Tor 273.4 275.0 106.3 6.19 100.2 Pass-Major Risk ODST-45-ODSN-45i PB1 IN13-ODSN-45i PB1 297.8 300.0 157.7 6.96 150.7 Pass-Major Risk ODST-45-ODST-45A-ODST-45A Surveys 297.8 300.0 157.7 6.96 150.7 Pass-Major Risk ODST-46i-ODST-46i-ODST-46i Torok C 175.0 175.0 163.5 3.82 159.7 Pass-Major Risk OL ST-46i-ODST-46i PB1 -ODST-46i Torok C P 175.0 175.0 163.5 3.82 159.7 Pass-Major Risk ODS11-46i-ODST-46i PB2-ODST-46i Torok C P 175.0 175.0 163.5 3.82 159.7 Pass-Major Risk ODST-46i-ODST-46i Torok C PB3-ODST-46i P 175.0 175.0 163.5 3.82 159.7 Pass-Major Risk ODST-47-ODST-47-ODST-47 273.5 275.0 169.7 6.11 163.6 Pass-Major Risk 2/27/2013 10:21:50AM Page 4 of 5 COMPASS 5000.1 Build 61 i 1 1-- >g)E —g IV 0- , rn ip n p CD =fid T NE g • , u Weil3 o: T' 8 s3 k g i • a 4 e I • .Po • 1, --11 �' o 0 '6 e r.... • 10 't7, • • 4 a • 1J 0 0 0 • 0 m x? •1 • 1? • .0 • .\ • 11 '41, • 1� e ° 1O 9 pp `{� • � ` a -$11 Jj • e C i yiii •_ 414rp fir • • e c "if t-^ 4 • • Jli T . • • 1< 3 Jr •• • .1 7 J1 0 ? e 1 0 e 47 1 • I A 4. ........ •.,,,,, „4,,,,„,..„,,,, , ,, „•,„„ • •,,, • z i R 9 9 k $3 1 i P • *r%$ T—....-'- ' g tr;:k g 4, I ::.• - le .•-•• 1 _ rn S • a — t i w� s . 12 , 1 -1015uFt lsounary N E SE Corner of ` U ) Protracted Section 11 a c F ,. r . s e n Lit 11 Coordinates i 1 N 6028111.04 3 J 'i` E 470989.01 -1 • e , i PI-254 Ref. AK BLM s� P12\2'4\11\ � Harrison: Bay Trace"A" — I Ru9C�J?rawing 1S 9. !ly''"i2 �� • Iwo&:✓S99 Was ''•.... ' ' *or Shore le•rood=3. = e 13 n Ii •,. • OC•• u _ tom.. , PI7t0P120 .00\ ,4,• PI-22. I / ,'. v 1,14 o i\ a - 1,F-17 Tuncra loam DS al B D.P. �r, a n Root to Lob /4-0 1! PI-• g PC-151411-., 111 i I 1. il — BU4 , , ., • r , `."! Basis of Location I I ADS-3H West Monument AI ` i ' Coordinates ;,per, N 6001016.61 •�� �•t•• n 21-?!. 3r E 498081.23 •STAKED PI INFORMAUION ONLY ' a i d Q . D I < Ref. Drawing LownsburyNo & Assoc. . ''` --•--- NSK 6.01—d672 .44' 'IS ..•••..S.4.0 h _ _ • rot/14• lk °I...i.,A , . ..-:- .:., „...• .,. .IM .040007/ ,- , , _lo• • ilip G.leis I.,*"l t�fF••'• No.4110.5 '• tea``'j I9 .•' J r 6�o 'w••.»•,r• o: - - ---- 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 { l Alaska State " ane Seofion Lir18 f- ----- Well No, Y X Latitude (N) Longitude (W) FSL FEL Pad Elev, • 1 6,031,151,32 469,920,45 70 29 46.24160 150 14 45,46463 3035 1077 _ 3,5 9 2 9,031,146.35 469,915.52 70 29 46,19252 150 14 45,60922 3030 1082 13750 3 6,031,141.39 489,910,59 70 29 46,14354150 14 •. •75375 3025 108 13,50 1=Z-7 6,031,136.46 469,905,6/ X70 29 4 _6.09485 150-1-4-45,8979-9-m- 3020 1092 13.50 5 6,031,131,45 469,900,74 ' 70 29 46,04538 15014 46,04252 3015 109- 13,5, 6 `6,031,126,51 469,895,80 70 29 45,99660 15014 46.18735 3010 1102 13.50 7 6,031,113,73 469,683,13 70 29 45,87039 15 46.55f378 299.7r -1115 13.50 8 6,031,108.73 469,878.21 70 29 45,82102 15014 46,70303 2992 1120 13,50 9 6,031,103.75 469,873,26 70 29 45.77184 15014 46,84814 2987 1125 13.50 ' 10 6,031,098.79 469,868,36 70 29 45,72286 150 14 46,99179 2982 1130 13,50 11 6,031,093.84 469,863,39 70 29 45,67398 15014 47,13750 2977 1135 13.50 12 6,031,088,87 469,858.47 70 29 45,62490 150 14 47,28174 2972 1140 13.50 136,031,076,06 469,845 81 70 29 45,49' , r 15014 47.65288 2960 1152 1 ,51 1-4 _-60i,1571,o9 -469,6415,97 70 29 45,44932 15014 47,79770 2953 1157 --'13.50-4- 15 3,50 15 6,031,066.15 469,835,96 70 29 45.40053 150 14 47,9416 29 r 1162 13.50 16 6,031,061.113 469,831,04 70 29 45.35145 15014 48,08588 2945 1167 13.50 17 6,031,056,25 r 29 45.30277r 14 48,230422940 117 13,50 8,031,051.27 1 29 45,25359 15014 48,37495 2935 1177 13,50 1 6,031,038.52 469,808, 70 29 0.12768 15014 48,74668 29 1189 13, 20 6,031,033,50 469,803.59 70 29 45.07811 150 14 48.59051 2917 - 1194 13.50 21 6,031,028.53 469,798.62 7' 2* 45,02903 15014 49,03632 2912 1199 13,50 22 6,031,023,58 469,793.67 70 29 44.98014 1 r 14 49,1:144 2'y 12 r- 13,51 23 6,031,018, 46-,788,76 70 29 44,93067 15014 49,32537 2902 1209 13.50 r 24 6,031,013,60 469,783,84 70 29 44,88159 150 1 . •.=,46`,r 28' 114 13,5' 4f4cf. of •e %.414.11411 '..0'''..... (o f:9 :tp I,/ i !S•N •• •.N• -MM ••• a,•� Philip G.Dove el �y j. c ; ii, ,t ', ; .t V. No,4110.5 P� �� �;i� . tu/104-ssicirkv VP' Ar Notes; : '.. 1. Elevations ore based on 8P Mean Sea Level- 2, ,: 2, Coordinates are based on Alaska State Plane Nad 27, Zone 4. 3, Alt conductors are within Protracted Section 11. Pioneer Natural Resouces JOB NAME: 0ooguruk Drill Site Conductors DRAWN BY: BL CHECKED BY: MX LOCATION: Protracted Section 11 - - . SCAL€; N/A Township 13 North . Ronge 7 East DATE: 7-12-07 Umiot Meridian -_ NANUQ JOB NO, SHEET DESCRIPTION: As-built Coordinates 452154 3 of 4 ........ .. ,.... ! i f= Alaska State r'lane Section Line Offset Well No. X Latitude (N) Longitude (W) FSL FEL Pad Elev. 25 6,031,128.32 469,943.64 70 29 46.01630 150 14 44.77930 3013 1055 13.50 26 6,031,123.35 469,938.69 70 29 45.96722 150 14 44.92442 3008 1060 13.50 27 6,031,118.33 469,933.76 70 29 45.91765 150 14 45.06895 30031065 13.50 28 6,031,113.39 469,928.86 70 29 45.86887 150 14 45.21260 2997 7 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 Of SURVEYOR'S CERTIFICATE -( .... A 4gil! '•,°rj• I HEREBY CERTIFY THAT I AM ArcO `p- '• 9 PROPERLY REGISTERED AND 'r`f ' t. a LICENSED TO PRACTICE LAND • .:�� SURVEYING IN THE STATE OF 0. /. 4# ALASKA AND THAT THIS PLAT If • • ilipG.Davis 1o REPRESENTS A SURVEY DONE BY e€�A s % No.4110-3 Ja'r ME OR UNDER MY SUPERVISION fF�". SJc r AND THAT I BELIEVE THAT ALL ' ' e0._PROFESSION 0��~++ DIMENSIONS AND OTHER DETAILS �. 1 f 11/4*1s.t"N11+"` ARE CORRECT AS SUBMITTED TO ME BY NANUQ, INC. AS OF JULY " v 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 Bettis, Patricia K (DOA) From: Vaughan, Alex [AIex.Vaughan@pxd.com] Sent: Tuesday, March 12, 2013 1:35 PM To: Bettis, Patricia K(DOA) Cc: Campoamor, Kathy Subject: RE: Permit to Drill Application: ODSN-04 Attachments: ODSN-4 PN5ext wp02a planning report.pdf Please see attached. Alex Vaughan Senior Drilling Engineer PIONEER NATURAL RESOURCES 907.343.2186 (office) 907.748.5478 (mobile) From: Bettis, Patricia K (DOA) [mailto:Datricia.bettis@alaska.gov] Sent: Tuesday, March 12, 2013 11:15 AM To: Vaughan, Alex Subject: Permit to Drill Application: ODSN-04 Good morning Alex, I started the review of the application for a Permit to Drill for the proposed ODSN-04 well. The well plan survey and anti-collision summary report are both in draft forms. Please provide copies of the final survey and report. These can be emailed to me. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907)793-1238 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 I ( / \ 4.4 \, / 1 \-\\ / / 11:1, \N-\\\\ Kifj 1 r ' ,\\\\ \ \\\\\\. 11 f \\\ \\\ ...1////' /I) (Z$431 \1 ^t \ / .0, • - ov" \A• tot tle • toos : r $$$$$$ o llll on,, / I , aj 010410 a.4 00, zee. • „ \\v/ pp' “0,0' ,v1 •••a-1 . • rl r • a." al , • a Z. ria - $4'• " r-411' . , TRANSMITTAL LETTER CHECKLIST WELL NAME aoc/u,l`Wk O1\ J-O�f PTD# c 13o 37- Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: Oo wr-Lc POOL: COO A &J< 1 N ski" 04 Check Box for 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 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:9/09/2011 To N3 m 0 0 o c a) CD-N LL co N 0 a OU N _0 as O _• 7 a N a) C >@ C 7 O co 'C N @ o o O L CO Il n a U a) @ L a. (_> CO CO0 a`) ai a) a a co g c o co VS CT) 2 -p 0 3o N c c S c a 0 c @ 2 EL) c 0 c a)• ca a) co co v co a. >Lu -c A O c v U o E a mci • o :S -o RS a a`)o o1-0 'o �°• N TOo 2 of oo a r 3 O i o m v N U.1 V) o o N o c co T a) a) N E i CD o @ 0 N a. 00 co 0 3 3 p W N c L @ O Jo .- c -c) 3 a`) x r N o 3 o c O 0 O C a) Y a) 0 0 03 a Q O ani m c 2 o •§ -a a) c _ 2 C U X O T d !// - 7 '=O. o. 'o a) 30 a) T a) n c -`o E - Co -o L @ N C = w U .D d • 0 3 dN nE3 N � NN n > N p O aoN 0E Y ch W co V Ho co a) X L ( cci v W O co a W per• N D o q c Z oo- Lo 0 3 E c a) aa) 0 N - n m v m y CO to rn co m m 2 > c m = o co co = o • o a 0 co OJ — = N `n p U N N •0 O_ o °� a) N o a) O 3 J tx Q 0 .c o cco = E 0 N '5 E E o a) o C7 U N a w co �O-. = 3 p O N = a) f0 U) N N aCO CO @ °) o 3 E Q N M op >— E o _ a 0 0 CO O O C o @ L Y N Q II a) > a). C ` N. N 0 ' D c w oo • 0 ca) _ o O a co Z aa) N p 3 Le ca - > a N o a o N o > _c ac6 '6 co a) Z 0 N o M Y :� 00 =_co 0 co O Y N 3 ru C d = C O. co p .N C p"O E o o n o 3co co a N@ .3 n '3 N `o m axi °) o ° o co 0 10 o D n o 2 -o .. a) Eh- c N o E o u o y o aa) m n N °) z C� co o o Q 0 0 Y @ E °) o a a 0) @ c i) 3 E o m :) o o cn O 'n t T @ 't ,- o L co .X ate) x 2 U) c L co n u) c > 0)m I z 0 0 0 0 . p 00 co o @ COm N m o N @ > Q X@ @ LU < 0 0 0 3 Z co 9 t- E co a` 0 2 1 2 a E2 I w a 2 0 -4- N z2 0 o a°) w O Q < CO) a) a) a) a) a) a) Cl)) CO) CO) a) a) < < < a) < CO) o a) Cl)) a) < a) < a) a) Cl)) a) 0 0 < a) a) < < < No a z z >- r >- >- >• >- >- >- r > > r z z z >- z r z r r r z >- z >- r r r z z z r } z z z 1 T I- -in O N 0 VO N LL co U --c-ti o E• E 3 — E a) O U U 'j E a) m N LLT d C L O a. �\ It 0 c a) > U - o 0 3 E _ a3i o co N U > 0 0 _U C (0 C @ a o Z O In > E N J 0 . @ N o N co u) a) O O co n X 0 Z N j C o o U a @ U .LL.. N a) 1:.(„.\. F- p o - C 0 N @ O C 0 • Y Q a) Q _0 a o u3) m o c aa) co v a) co ai r p lv Ckp u) u) N -2 m a ? i) off 0 m a) _am '7 op .- a) c o O Q C o o w N - C E N o@ C a) E N - 'J O 3 O C > C N O O O C N > a) D Q M 0 3 .. o @ o a) 0 U N N a`) c o = a 3 Cr a N Y wco r 3 CO N a o us E aai m .a o a O c u) N 2 JJ D 0 �_ °c Z _ a@ a3) n cn o c COc o ' Cl- s N co c o°' r1 a o _ a o oC. a) o o) a) . 7 M E E = a C c E r @ N o C C V) > ♦- _ C O N «$ a) N L_' a) �: N 5")°' Q C 0 C a) O) • Z p co o 0 0 0 a o m a) in o o c m m U n m C aoi aS n ° @ 3 0 > m Y a`>w O co 0 4 o a) a) • 0 O 7 ° a @ Y O O a) p (0 m Q (6 L N 'O O OJ p N. O co O o 0 p m -c _a o 0 o c o .- — ° Z o E 3 a`) o L m 3 w a) E O I2C E 0 c a@ CO co Q Q L L -0 as @ -co CD COE 6 N co m 'N L co o a o n 3 0 > 3 c o o Q o a s c -' iii 'm o a m 3 3 m o a) .. a '� - o co 0 0 0 of a .a co 3 CD o w U d C o a =o > 0 a s a o@ E o p o 0 o c Q o N a a) @ o 0) c a n N o a) p a 0,,= N @ L U p a) a) U Y a) O E a) E p @ N c xs t- p m n o a o. 0 o o Q u') CO a E v o a o a) 0 — a a) `- 2 -o m E C o csi N' .- c' c 0 0 < N U @ E @ O O O) D n N N @ L 'C 0) n@ @ o @ 0) @ p Nco va T C U 3 2 a, N 0 N. O n a) @ a) C Q n N N > @ a) a) a) 3 C a 6 6 a) C Y @ 7 a O 7 O a) N >. " N 0) CLi) a) Q 0 O U a E W L — a a a U N L L L a w a) (n a) a) > L N L 5 TO LL w a>) a�0i 3 m m m@ aai o L m E is 3 c o v m m a o = o Oo aNi @ 0 c CO C N o 0 c N O C . c 0 0 U o m o o -.3. .0. o U o 0 a) o o m -o m c °- E 3 a) .0 0 9 U a U J a. o E V) Q a) a) '- o a`) a) E E n a) 3 d0 a .2 t- t-• F •5 a 0 a > •.0 d d o o, n C E coo •w 0 c m Y• z0 a _I D 5 -..,T) 5 cn o o a.. a o co s Q a 0 U) 0 0 0 0 co < ) < ) 0 m m 0 5 2 a 0 u (0 0 o bo. IEO N. <- N CO ,t Cr) O I . 00 0) O " M in "znON N N CN N LN N N N OM M (7 N C) M M M M M M (1f) V U 1— co co co6. (OC •' r N • V O N pay � p p M 0a) O aR M M _ E - 1 N a) a) 0 E f%N • E o- O Q m _ Q 0. m 8 41 W a o JiQ Q C7 Q a50 Q t 0 Technical Report Title Date Client: Pioneer Natural Resources Field: Oooguruk Development Rig: Nabors 19AC Date: November 3, 2013 Surface Data Logging End of Well Report ODSN-04 ODSN-04 PB1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Formation Tops 6. Mud Record 7. Bit Record 8. Morning Reports 9. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: Pioneer Natural Resources Rig: Nabors 19AC Well: ODSN-04 & ODSN-04 PB1 Field: Oooguruk Borough: North Slope Borough State: Alaska Country: United States API Number: 50-703-20670-00-00 (ODSN-04) 50-703-20670-70-00 (ODSN-04 PB1) Sperry Job Number: AK-AM-0900261430 Job Start Date: 21 March 2013 Spud Date: 24 March 2013 Total Depth: 19868’ MD, 6363’ TVD (ODSN-04) 14810’ MD, 6404’ TVD (ODSN-04 PB1) North Reference: True Declination: 19.855° Dip Angle: 80.998° Total Field Strength: 57601 nT Date Of Magnetic Data: 25 March 2013 Wellhead Coordinates N: North 70° 29’ 46.095” Wellhead Coordinates W: West 150° 14’ 45.898“ Drill Floor Elevation 56.2’ Ground Elevation: 13.5’ Permanent Datum: Mean Sea Level SDL Engineers: Todd Wilson, Kerry Garner, Makenzie Jorgensen, Martin Nnaji, Charles Sinn, Christina Medlyn SDL Sample Catchers: England Fletcher, Paul Cozma, Mindaugas Kuzminskas, John Hill Company Geologist: Greg Griffin Company Representatives: Rod Klepzig, Jerry Haberthur, Joe Polya, Tony Deranger SSDS Unit Number: 123 DAILY SUMMARY 03-21-2013 Rig down on ODSN-24, moving rig to ODSN-04. Change out blow out preventer stack during move. 03-22-2013 Finish changing out stack and moving rig to ODSN-04. Rig up ODSN-04. 03-23-2013 Continued rigging up ODSN-04. Nipple up riser and spacer spools. Laid down 207 joints of 4 " drill pipe in mouse hole. Serviced top drive pickup 5" drill pipe and replace link tilt float valve. Precede picking up 5" drill pipe. 03-24-2013 Finish picking up 5" drill pipe. Slip and cut drill line and serviced top drive. Change out solenoid valve. Made up 14.5" surface bottom hole assembly and cleaned out conductor. Drill from 158' MD to 226' MD. Pull out of hole to adjust bottom hole assembly. Drill ahead from 226' MD to 722' MD, running Gyro at every connection. No samples collected for the surface hole section. Gas: There was a max gas of 19 units with an average gas of 4 units. Fluids: No losses seen. 03-25-2013 Drill ahead from 722' MD to 2,527' MD. Pump 25 barrel sweep at 1,995' MD. Minimal clay returns at shakers. Continue to drill ahead. Gas: No significant gas data. Fluids: No losses seen. 03-26-2013 Drill ahead from 2,547' MD to 2,811' MD. Pump 50 barrels of 10.5 ppg high viscosity sweep which returned at 5,571 strokes. Drill from 2,811' MD to 2,816' MD. Pull out of hole for bottom hole assembly #2. Wash and ream from 345' MD to 2,816' MD. Continue to drill ahead to 3,100' MD. Gas: No significant gas data. Fluids: No losses seen. 03-27-2013 Continue drilling ahead from 3,100' MD to 4,545' MD. Gas: No significant gas data. Fluids: No losses seen. 03-28-2013 Drill from 4,545' MD to total depth 5,294' MD . Pumped carbide pill at 5288' MD, returned 1500 strokes early. Pump 50 barrel 10.9 ppg high viscosity sweep at 5,002' MD, returned at 9,400 strokes. Moderate increase in cuttings. Circulate two bottoms up. Trip out from 5,002' MD to 165' MD, trip in hole from 165' MD to 5,294' MD, work through tight spots at 1,234' MD, 1,700' MD and 4,630' MD. Gas: There was a max gas of 74 units with an average gas of 10 units. Fluids: No losses seen. 03-29-2013 Circulate stage pumps up to 850 gpm, pumped 50 barrel 10.5 ppg high viscosity sweep. Noted 100% increase in cuttings at 12,000 strokes. Begin circulating three bottoms up, spotted 300 barrels of fresh new mud on bottom and trip out of hole from 5,294' MD to surface. Gas: No significant gas data. Fluids: No losses seen. 03-30-2013 Completed 11.75" casing run from 2403' MD to 5284' MD while filling pipe every 10 joints. Landed casing at 5284’ MD. Break circulation and stage up pumps to 12 bpm, Rigged up cement tools and held safety meeting. Cementers pumped 10 barrels of water, 100 barrels of 10.0 ppg spacer, and 522 barrels lead cement, 132 barrels tail cement, and 20 barrels of water. Return spacer at 2,415 strokes, 10.8 ppg cement at 2,780 strokes and there was eight samples taken during cement job. Flush lines and riser. Clean surface equipment. Gas: There was a max gas of 54 units with an average gas of 10 units. Fluids: There was 54 barrels lost down hole. 03-31-2013 Nipple up and down blow out preventer stack, clean pits. Service mud pumps and test blow out preventer stack. Troubleshoot issue with hinge seal on Rams. Test blow out preventer stack to 4,500 psi. Begin picking bottom hole assembly #3. Gas: No gas data Fluids: No losses seen. 04-01-2013 Pick up bottom hole assembly #3 (clean-out assembly), trip into 5,187' MD and tag stringers. Run casing pressure test to 3,500 psi for 30 minutes. Ream and wash from 5,187' MD to 5,195' MD. Drill cement from 5,195' MD to 5,294' MD and circulate at 700 gpm. Trip out to surface and laid down BOTTOM HOLE ASSEMBLY #3. Pick up BOTTOM HOLE ASSEMBLY #4, troubleshoot MWD. Gas: No significant gas data. Fluids: No losses seen. 04-02-2013 Pick up/make up bottom hole assembly #4, shallow pulse test, load nukes, trip in hole to 2,935' MD. Slip and cut drill line. Trip in hole to 5,294’ MD and displace to 10.3 ppg MOBM, pump high viscosity spacer followed by MOBM. Drill ahead to 5314' MD. Run Formation Integrity Test to 12.5 ppg EMW at shoe. Drill from 5,314' MD to 6,009' MD. Gas: There was a max gas of 150 units with an average gas of 85 units. Fluids: No losses seen. Geology: 100% Shale 04-03-2013 Troubleshoot GEO pump. Drill from 6,009' MD to 6,054' MD. Troubleshoot pack off between CCU and RSC. Miscellaneous rig service conducted. Active system treated with RM 63 & LIME while drilling/circulating. Gas: There was a max gas of 146 units with an average gas of 68 units. Fluids: No losses seen. Geology: 100% Shale 04-04-2013 Continue to clear cutting line, trip in hole to 5,215’ MD to 5,064’M MD. Begin reaming and staging up pumps to 700 gpm. Drill from 6,054’ MD to 6,736’ MD. Service top drive and flushed cutting line with purple pill. Continue drilling to 7,220’ MD. Gas: There was a max gas of 304 units with an average gas of 139 units. Fluids: No losses seen. Geology: 100% Shale 04-05-2013 Drill from 7,211' MD to 8,160' MD. Slow pump rate at 7,780' MD. Drill from 8,160' MD to 8,729' MD. Service top drive then drill from 8,729' MD to 8,825' MD. Mud pump #2 pop off troubleshoot issue and repair. Drill from 8,825' to 9,140' 745. Slow pump rate at 8,729' MD. Gas: There was a max gas of 416 units with an average gas of 185 units. Fluids: No losses seen. Geology: 100% Shale 04-06-2013 Drill from 9,140' MD to 9,848' MD. Pack off while back reaming at 9,848' MD. Increased LCM additions, work pipe, and circulate bottoms up 600 gpm. Drill from 9,848' MD to 10,346' MD. Service top drive, and then drill from 10,346' MD to 10,375' MD TD. Circulate and rack back one stand every 45 minutes. Gas: There was a max gas of 590 units with an average gas of 194 units. Fluids: There was 110 barrels lost down hole. Geology: 100% Shale 04-07-2013 Circulate six bottoms up from 10,375' MD to 10,147' MD. Trip out from 10,147' MD to 9600' MD. Log open hole from 7,823' MD to 5,533' MD. Trip out from 5,533' MD to 5,215' MD. Circulate at 5,215' MD, stage up pumps to 325 gpm. Began losing over shakers. Gas: There was a max gas of 178 units with an average gas of 40 units. Fluids: There was 33 barrels lost down hole. Geology: 100% Shale 04-08-2013 Back ream from 5,215' MD to 3,505' MD, staging pumps up to 725 gpm. Service top drive and mud pump #2. Continue to back ream from 3,505' MD to 1,000' MD. Trip out of hole from 1,000' MD to 561' MD then lay down BOTTOM HOLE ASSEMBLY to surface. Make up BOTTOM HOLE ASSEMBLY #5, pick up and trip in the hole. Gas: There was a max gas of 21 units with an average gas of 2 units. Fluids: No losses seen. 04-09-2013 Trip in hole from 3,953' MD to 5,283' MD then slowed pump rates at 5,300' MD. Pump down radio frequency identifier device to open 11.75" reamer. Ream from 5,300' MD to 6,328' MD pumping at 820 gpm. Packed off at 6,328' MD, worked pipe then picked up to 6,208' MD and staged pumps up to 800 gpm. Reamed from 6,208' MD to 6,735' MD where a sudden 500 psi pressure drop was noticed. Verified reamer was open. Ream from 6,735' to 6,804' at 800 gpm. Ream from 6,804' MD to 7,125' MD pumping at 800 gpm. Gas: There was a max gas of 278 units with an average gas of 52 units. Fluids: There was 178 barrels lost down hole. 04-10-2013 Continue opening hole with 11.75" reamer from 7,125' MD to 9,083' MD pumping at 800 gpm. Ream from 9,083' MD to 9,368' MD pumping at 800 gpm. Steel seal additions started at 9,200' MD. Gas: There was a max gas of 277 units with an average gas of 52 units. Fluids: There was 100 barrels lost down hole. 04-11-2013 Continue opening hole with 11.75" reamer from 9,368' MD to 10,375' MD pumping at 800 gpm. Deactivate reamer with chip. Circulate seven bottoms up at 84,000 strokes while pulling up from 10,375' MD to 9,463' MD pumping at 775 gpm then trip out of hole from 9,463' MD to 5,473' MD. Gas: There was a max gas of 124 units with an average gas of 46 units. Fluids: There was 77 bbls lost down hole. 04-12-2013 Ream up from 5,473' MD to 5,284' MD, lost approximately 40 barrels in returns at shore. Reamed and washed in casing from 5,284' MD to 1,199' MD pumping at 800 gpm. Trip out from 1,199' MD to surface. Lay down BOTTOM HOLE ASSEMBLY # 5. Nipple up then down blow out preventer also changed RAMS. Tested blow out preventer then troubleshoot top RAMS with a good test then rig down testing equipment. Gas: There was a max gas of 62 units with an average gas of 9 units. Fluids: There was 65 barrels lost down hole. 04-13-2013 Finished testing blow out preventer then rigged down equipment. Rigged up TESCO equipment then ran in hole with 9 5/8" 40# L-80 liner to 5,229' MD. Staged up pumps to 1 bpm then circulated one bottom up. Rigged down TESCO then ran in hole with 5" DP to 6,189' MD, staged up pumps to 1.5 bpm. Run in hole to 6,224' MD. Gas: No significant gas data. Fluids: There was 130 barrels lost down hole. 04-14-2013 Continue running in hole with 9 5/8" liner from 6,224' MD to 7,552' MD. Circulated and stepped rate up to 1.5 bpm after 100 barrels pumped, 24 barrels were lost. Run in hole from 7,552' MD to 10,365' MD. Rig up cement equipment. Circulated one bottoms up then pressure tested cement lines up to 4000 psi. Pump 10 barrel of seawater, 60 barrel spacer, 52 barrel 12.5 ppg cement, 36 barrel 15.8 ppg cement, and 20 barrels of seawater. Chase with 9.8 ppg brine. Bumped plug at 4530 strokes. Gas: There was a max gas of 266 units with an average gas of 18 units. Fluids: There was 472 barrels lost down hole. 04-15-2013 Rigged down cement equipment then displaced MOBM in casing with 9.8 ppg brine at 6 bpm, brine returned at 4600 strokes. Tripped out from 5,105' MD to surface and laid down tools. Trip in hole with Johnny W hacker to 5,706' MD and pump CONDET sweeps and fresh brine. Trip out from 5,706' MD to surface. Tested casing to 3500 psi for 30 minutes. Nipple up then down blow out preventer and change out RAMs. Gas: No significant gas data. Fluids: No losses seen. 04-16-2013 Nipple up then down blow out preventer and test to 4500 psi. Ran in hole with Johnny whacker on 2 7/8" to 6,463' MD, flushed pipe and circulated at 350 gpm. Trip out to surface. Rig up to run 2 7/8" 6.5# L-80 tubing. Run in hole to 160' MD with tubing. Gas: No significant gas data. Fluids: No losses seen. 04-17-2013 Cut and slip drill line. Currently preparing rig for move to ODSN-02. Gas: No significant gas data. Fluids: No losses seen. 08-13-2013 Pick up 5" drill pipe to 3520’ MD. Pump 9.3 ppg dry job and trip out of the hole from 3500’ MD to surface. Pick up new Bottom hole assembly to 504’ MD. Pick up 5" drill pipe from 504’ MD to 10237’ MD at 300 gpm. Pressure tested casing shoe to 3500 psi for 5 minutes. Begin drilling cement on landing collar at 10237’ MD and begin displacement of 9.8 ppg brine with 10.2 ppg LSND mud. Gas: No significant gas data. Fluids: No losses seen. 08-14-2013 Drill out the cement shoe track and rathole from 10,237’ MD to 10,375’ MD. Displace 9.8 brine with 10.2 ppg LSND mud while drilling. Drill from 10,375’ MD to 10,395’ MD, circulated 1.5 bottoms up at 700 gpm. Perform formation integrity test to a 13.5 ppg equivalent mud weight. Pumped 35 bbls 13.3 ppg dry job and tripped out of hole from 10,358’ MD to 504’ MD. Laid down bottom hole assembly and began picking up new bottom hole assembly. Prepared Geo tap tool, and began pre job for loading nukes. While drilling average gas was 14 units and max gas was 26 units at 10,376’ MD. Gas: There was a max gas of 26 units with an average gas of 14 units. Fluids: No losses seen. 08-15-2013 Picked up bottom hole assembly number 7 to 220’ MD and tested. Cut drilling line, loaded nukes and continued to pick up bottom hole assembly to 688’ MD and Trip in the hole to 3538’ MD. Fill pipe break in Geo-pilot per directional driller and trip in the hole from 3538’ MD to 10,224’ MD. Wash reamer down from 10,224’ MD to 10,395’ MD. Rotary drilled from 10,395’ MD to 10,548’ MD at 700 gallons per min. Gas: There was a max gas of 32 units at 10494’ MD with an average gas of 19 units. Fluids: No losses seen. Geology: Shale: grey to dark grey, hard, blocky, sub angular, non-calcareous. Trace sandstone and siltstone. 08-16-2013 Rotary drilled from 10,548’ MD to 10,573’ MD. Cycled pumps to activate reamer and cut reamer ledge from 10,557’ MD to 10,562’ MD. Pick up 230K against shoe at 10,546’ MD. Rotary drilled from 10,573’ MD to 11,441’ MD. Gas: There was a max gas of 55 units at 10615’ MD with an average gas of 21 units. Fluids: No losses seen. Geology: Shale: dark grey, blocky, flaky, laminations, sub rounded to sub angular, dull texture, non- calcareous. Trace sandstone and siltstone. 08-17-2013 Rotary drilled to 11,447’ MD, developed leak on stand pipe union. Replaced gasket on standpipe and tested to 4500 psi. Drilled ahead from11 447’ MD to 11,487’ MD and experienced high torque. Treated mud with lubes, rotary drilled from 11,487’ MD to 11,620’ MD. Serviced top drive, and changed out decoder. Gas: There was a max gas of 170 units at 11484’ MD with an average gas of 16 units. Fluids: No losses seen. Geology: Shale: light grey to grey, blocky, flaky, sub rounded to sub angular, laminated, non-calcareous, trace glauconitic, sandstone and siltstone. 08-18-2013 Rotary drilled from 11,810’ MD to 11,965’ MD, closed reamer and drilled 8.5" hole from 11,695’ MD to 12,121’ MD. Replaced gasket on standpipe union, serviced top drive. Drill ahead from 12,121’ MD to 12,285’ MD. Circulated one bottoms up while pulling up to 12,190’ MD. Perform MAD pass from 12,190’ MD to 12,168’ MD at 600 gallons per minute. MWD reset depth, and repeated MAD pass from 12,177’ MD to 12,169’ MD. Stop rotation of drill string from 12,222 to 12,190’ MD. Set tool face position per GEO- TAP at 12,221. Gas: There was a max gas of 80 units at 12099’ MD with an average gas of 16 units. Fluids: No losses seen. Geology: Shale: light grey to grey, blocky, flaky, sub rounded to sub angular, laminated, non-calcareous, trace well sorted sandstone. 08-19-2013 Perform GEO-TAP work from 12,222 to 12,098’ MD. Replace gasket on mud pump number 1. Oriented GEO-TAP tool and performed work from 12,205’ MD to 12,106’ MD. Open hole GEO-TAP at 12,212’ MD. Tripped out of the hole from 12,212’ MD to 11,950’ MD, attempted to open reamer but unable. Circulated from 11,950’ MD to 11,910’ MD, began packing off and observed 23 bbls mud loss. Circulate with some pack off from 11,910’ MD to 12,000. Ream/wash down from 12,000 to 12,285’ MD. Pack off at 12,260’ MD, 35 bbl losses. Circulate and started MWD/LWD tools, serviced top drive. Gas: There was a max gas of 123 units at 11953’ MD with an average gas of 8 units. Fluids: 115 bbls lost downhole. Geology: Shale: light grey to grey, blocky, flaky, sub rounded to angular, laminated, non-calcareous, trace well sorted sandstone. 08-20-2013 Drill ahead from 12,285’ MD to 12,607’ MD, power failure on rig. Started generators and drilled swab on number 2 mud pump. Drill ahead from 12,710’ MD to 12,746’ MD, GEO-PILOT not working properly. Drill from 12,746’ MD to 12,749’ MD encounter hard spot. Gas: There was a max gas of 35 units at 12369’ MD with an average gas of 9 units. Fluids: There were no losses observed. Geology: Shale: light grey to grey, blocky, flaky, sub rounded to angular, laminated, non-calcareous, trace well sorted sandstone. 08-21-2013 Back reamed from 12747’ MD to 12468’ MD at 680 gallons per minute. Drill from 12747’ MD to 12749’ MD at 650 gallons per minute, pumped 2nd Carbide pill. Trip out from 12749’ MD to 3918’ MD. Pump 72 barrels 17.0 pounds per gallon kill weight mud at 12749’ MD; pump 20 barrels 17.0 pounds per gallon kill weight mud at 12095’ MD. Gas: No significant gas data. Fluids: There were no losses observed. 08-22-2013 Trip out of the hole from 4013’ MD to 2493’ MD. Pump 50 barrels 17.0 pounds per gallon spacer, and chase with 35 barrels 17.0 pounds per gallon kill weight mud. Trip out to 2019’ MD, pumped 178 barrels 17.0 pounds per gallon kill weight mud at 6 barrels per minute. Highest returns were 15.7 - 16.0 pounds per gallon. Tripped out of hole to surface, and laid down bottom hole assembly. Serviced rig, and rigged up to test blow out preventers. Gas: No significant gas data. Fluids: There were no losses observed. 08-23-2013 Test blow out preventer s to 4500 pounds per square inch, and rig down test equipment. Pick up bottom hole assembly #8, and shallow pulse test at 450 gallons per minute. Trip into the hole from surface to 2974’ MD. Cut 45’ MD of drill line. Trip in hole from 2974’ MD to 3025’ MD, and displace hole with 11.0 pounds per gallon LSND mud at 250 gallons per minute. Trip in hole from 3025’ MD to 6490’ MD, and displace hole with 11.0 pounds per gallon LSND mud at 250 gallons per minute. Trip in hole from 6490’ MD to 10365’ MD, and displace hole to 11.0 ppg LSND mud at 250 gallons per minute. Gas: No significant gas data. Fluids: There were no losses observed. 08-24-2013 Circulate three bottoms up at the shoe. Trip in hole to 12749’ MD, and begin reducing active system mud weight to 10.2 pounds per gallon. Drill ahead from 12749’ MD to 12986’ MD, target depth. Circulate at target depth; begin taking losses 0.5 - 1.0 barrels per minute. Add lost circulation material as pulling to shoe. Pump high viscosity weighted sweep at the shoe. Gas: While drilling average gas was 8 units, max gas was trip gas of 98 units. Fluids: 150 bbls lost downhole. Geology: Sandstone: clear, milky, unconsolidated, very fine to medium grained, sub angular to rounded, sorted to well sorted, non-calcareous, trace glauconitic, trace dark grey shale, trace brown siltstone. 08-25-2013 Pump high viscosity sweep at 10293’ MD, no significant increase in cuttings. Trip in hole from 10293’ MD to 12986’ MD and circulate. Pump a 50 barrel high viscosity weighted sweep, two bottoms up, and it was 1200 strokes late. Pump a 50 barrel spacer and displaced hole to 12.0 pounds per gallon LSND mud. Trip out of hole from 12986’ MD to 10293’ MD, and monitored well 15 minutes for static losses. Gas: While circulating average gas was 77 units, max gas was trip gas of 1142 units. Fluids: There were no losses observed. 08-26-2013 Trip out of the hole from 7631’ MD to 5064’ MD, and pump 35 barrel high viscosity spacer. Trip out to 4589’ MD and displace to 13.9 pounds per gallon kill weight mud and monitor well. Trip out to surface and lay down bottom hole assembly. Change out RAMs to 7” and test blow out preventer. Rig up to run 7" 26# L-80 casing Gas: While circulating average gas was 5 units and max gas was 52 units. Fluids: There were no losses observed. 08-27-2013 Run in hole with 7" casing from 771’ MD to 12962’ MD. TESCO rigged down casing equipment. Rig up cement equipment. Circulate and pressure test cement lines at 4000 psi. Gas: No significant gas data. Fluids: There were no losses observed. 08-28-2013 Attempt to circulate through casing, at 1-2 barrels per minute at 1350 pounds per square inch and lost circulation at 2.5 barrels per minute continues circulation with no returns. Rig up for cement job; and pumped 10 barrels water, 50 barrels spacer with 0.5 pounds per barrel BAROSEAL FINE, 70 barrels 15.8 pounds per gallon cement, 20 barrels water, and 487 barrels 10.1 pounds per gallon brine. Rig down cement lines, and changed RAMs to 2 7/8", and injected 1 barrel every 30 min for 6 hours. Test blow out preventers at 2500 pounds per square inch. Run in hole with 2 7/8" kill string from surface to 2295’ MD. Serve rig and rig down to prepare for rig move. Gas: No significant gas data. Fluids: There was 134 barrels lost down hole. 10-2-2013 Moved rig over to ODSN-04 well and rigged up. Displace diesel freeze protect out of hole with seawater and 10 ppg brine. Rig up to test TWC, set TWC and test to 3500 psi for 5 min. Rig down and circulate lines. Nipple down tree and set test dart, and nipple up blow out preventer with drilling risers. Gas: No significant gas data. Fluids: There were no losses observed. 10-3-2013 Start with nipple up the blow out preventers. Pressure tested 7" casing shoe to 3500 pounds per square inch for 30 minutes. Pull tubing hanger and trip out of the hole from 2325' MD to surface. Pick up test tools and test MPD to 2500 pounds per square inch. Pull MPD and install trip nipple. Install 6 3/8" wear bushing and pick up cleanout bottom hole assembly. Begin trip in the hole. Calibrated and tested gas detection equipment. Gas: No significant gas data. Fluids: There were no losses observed. 10-4-2013 Pick up drill pipe from 1,266’ MD to 7,517' MD. Repair broken gear shaft on iron rough neck. Pick up drill pipe from 7,517’ MD to 8,255’ MD. Continue trip in the hole from 8,255’ MD to 8,448’ MD. Cut and slip drilling line; trip in the hole from 8,448’ MD to 12,359’ MD, tagged cement at 12,395’ MD. Drill cement from 12,395’ MD to 12,591’ MD; begin displacement of brine to 10.2 pounds per gallon mineral oil based mud. Displace from 12,591’ MD to 12,660’ MD. Drill cement from 12.660’ MD to 12,952’ MD. Gas: While circulating max gas was 39 units with an average of 5 units. Fluids: There were no losses observed. 10-5-2013 Drill cement from 12,952’ MD to 12,990’ MD. Circulate two bottoms up and monitor well. Pump dry job. Perform Bat Sonic logs from 12,984’ MD to 11,339’ MD and from 10,854’ MD to 10,857’ MD. Continue tripping out of the hole from 10,857’ MD to 368’ MD. Pump 15 barrel dry job at 5750’ MD. Lay down bottom hole assemble and download Bat Sonic logs. Pick up bottom hole assembly #10, break in Geo- Pilot, and load nukes. Gas: While circulating max gas was 81 units with an average of 7 units. Fluids: There was 14 barrels lost during trip. 10-6-2013 Pick up bottom hole assembly from 150’ MD to 395’ MD. Begin tripping in the hole from 395’ MD to 3282’ MD. Fill drill pipe, test MWD, and break in Geo-Pilot. Continue tripping in the hole from 3282’ MD to 11,076’ MD. Monitor the well for 10 minutes. Continue tripping in the hole to 12,904’ MD. Cut and slip drilling line and installed rotary control device. Displace well from a 10.2 pounds per gallon mineral oil based mud to a 7.6 pounds per gallon mineral oil based mud at 12,990’ MD. Drill ahead from 12,990’ MD to 13,010’ MD and circulate bottoms up. Perform formation integrity test to 12.5 pounds per gallon, and bleed down to 12 pounds per gallon. Drill ahead from 13,010’ MD to 13.097’ MD and conduct pore pressure test. Test formation pressure is equal to 8.8 pounds per gallon equivalent mud weight. Drill ahead from 13,097’ MD to 13,289’ MD. Service the top drive and blocks. Gas: 1709 units (after pore pressure test). While drilling max gas was 373 units from 13099’ MD. Fluids: 10 bbls lost during trip Geology: Sandstone: clear, milky, unconsolidated, very fine to fine grained, sub round to rounded, sorted to well sorted, non-calcareous, quartz, trace oil show, trace dark grey shale, trace light brown siltstone. 10-7-2013 Drill ahead from 13,333’ MD to 13,962’ MD, service top drive. Drill ahead from 13,962’ MD to 14,069’ MD. Pick up to 14,035’ MD and trough to 14,050’ MD. Ream/wash down from 14,035’ MD to 14,058’ MD, ream dogleg. Ream/wash down from 14,035’ MD to 14,005’ MD in an attempt to trough. Ream/wash down from 14,035’ MD to 13,990’ MD. Continue to time drill from 14,035’ MD to 14,037’ MD. Gas: There was a maximum gas of 736 units from 13327’ MD with an average of 158 units. Fluids: There were no losses observed. Geology: Sandstone: clear, translucent, unconsolidated, very fine to fine grained, sub rounded, sorted to well sorted, non-calcareous, quartz, trace light brown siltstone. 10-8-2013 Continue to time drill 14,037’ MD to 14,040’ MD at 1 foot per hour. Continue time drill 14,040’ MD to 14,045’ MD at 1.25 feet per hour. Continue time drill 14,045’ MD to 14,050’ MD at 1.5 feet per hour. Continue time drill 14,050’ MD to 14,053’ MD at 2.5 feet per hour. Continue time drill 14,053’ MD to 14,055’ MD at 2 feet per hour. Drill ahead 14,055’ MD to 14,155’ MD. Service top drive, change out bad bearing on RCD element. Drill ahead 14,155’ MD to 14,205’ MD, wash and ream through dog leg 14,205’ MD to 14,185’ MD. Drill ahead 14,205’ MD to 14,249’ MD. Service top drive, rack back one stand and change out SVR sub. Advance to 14,249’ MD. Drill ahead 14,249’ MD to 14,345’ MD. Gas: There was a maximum gas reading of 117 units from 14285' MD with an average of 50 units. Fluids: There were no losses observed. Geology: Sandstone: clear, translucent, unconsolidated, very fine to fine grained, sub rounded, sorted to well sorted, non-calcareous, quartz, trace light brown siltstone. 10-9-2013 Drill ahead 14,345’ MD to 14,635’ MD. Conduct service on top drive and blocks. Drill ahead from 14,635’ MD to 14,715’ MD. Conduct directional surveys at 14,715’ MD and 14,710’ MD. Drill ahead 14,715’ MD to 14,786’ MD. Conduct directional survey at 14,784’ MD. Wash and ream down 14,786’ MD to 14,371’ MD. Drill ahead beginning at 14,786’ MD to 14,810’ MD. Wash/ream down 14,810’ MD to 14,765’ MD. Wash/ream down 14,760’ MD to 14,810’ MD to smooth the hole. Trip out of the hole 14,810’ MD to 14,770’ MD. MPD computer failure. Close bags and held to 720 pounds per square inch of pressure on well. Fix computer and trip out of the hole 14,770 to 13,555’ MD. Lay down one joint off the top of a stand. Conduct Service to top drive and blocks. Ream/wash down 13,555 to 13,585’ MD. Start trough drilling. Gas: There was a maximum gas reading of 334 units from 14417’ MD with an average of 137 units. Fluids: There were no losses observed. Geology: Sandstone: clear, translucent, unconsolidated, very fine to fine grained, sub rounded, sorted to well sorted, non-calcareous, quartz, trace light brown siltstone. 10-10-2013 Drill trough from 13,555’ MD to 13,585’ MD. Continue time drill from 13,585’ MD to 13,588’ MD at one foot per hour. Time drill and worked pipe from 13,588’ MD to 13,545’ MD as per Directional Driller. Drill ahead from 13,588’ MD to 13,590’ MD at one foot per hour. Time drill the first stand at one foot per hour from 13,594’ MD to 13,610’ MD. Continue time drill 1.25 foot per hour from 13,594’ MD to 13,595’ MD. Drill 1.5 foot per hour from 13,595’ MD to 13,600’ MD and two foot per hour from 13,600’ MD to 13,610’ MD. Conduct a function test of the blow out preventers. Continue to time drill from 13,610 to 13,621’ MD with 4,000 pounds weight on bit. Gas: While circulating max gas was 28 units with an average of 16 units. Fluids: There were no losses observed. 10-11-2013 Start time drill at a rate of 8 feet per hour from 13,621’ MD to 13,641’ MD. Service top drive and grease blocks. Continue time drill at a rate ranging between 12 and 40 feet per hour from 13,641’ MD to 13,674’ MD. Circulate while trouble shooting the Geo-Pilot. Displace well from 7.7 pounds per gallon of mineral oil based mud to a 10.2 pounds per gallon of mineral oil based mud. Change rotating head rubber, monitor well, and remove rotary control device element and installed trip nipple. Rig Crew tripped out of the hole from 13,578’ MD to 2,030’ MD. Cut and slip 74’ of drill line and service top drive. Continue to trip out of hole from 2,030’ MD to 395’ MD. Lay down bottom hole assembly from 395’ MD to 115’ MD and unload nukes. Gas: There was a maximum gas reading of 128 units from 13670’ MD with an average of 92 units. Fluids: There were 5 bbls lost during trip out of hole. 10-12-2013 Lay down bottom hole assembly #10 from 115' MD to surface. Prepare tools and bottom hole assembly #11 for trip into hole. Remove wear bushings, pick up test tools, and fill stack. Make up test tools and test blow out preventer at 250 and 4000 pounds per square inch. La y down test tools, rig down, and blow down lines. Set wear bushings, blow down choke and kill lines. Pick up bottom hole assembly #11 and download MWD tools. Circulate, shallow pulse test tools, and load nukes. Begin trip into the hole from a depth of 395' MD to 3,763' MD. Fill pipe and break in Geo-Pilot. Continue trip into hole from a depth of 3,763' MD to 10,497' MD. Fill pipe at 7,125' MD and 10,497' MD. Gas: No significant gas data. Fluids: There were 7 bbls lost during the trip into the hole. 10-13-2013 Continue to trip in the hole from 10,497' MD to 13,482' MD. Pull trip nipple and install Rotating control device bearing. Fill MPD lines with pre-charge pump. Displace mineral oil based mud from 10.2 pounds per gallon to 7.7 pounds per gallon. Ream and wash down well from 13,482' MD to 13,673' MD. Orient Geo-Pilot through sidetrack at 13,585' MD. Begin to drill ahead from 13,673’ MD to 14,138' MD. Begin time drilling at 14,138’ MD to 14,143' MD at one foot per hour. Continue time drill at 14,143' to 14,148' at 1.2 feet per hour. Gas: There was a maximum gas reading of 430 units at a depth of 14139’ MD while drilling with an average of 198 units. Fluids: There were no losses observed. Geology: Sandstone: clear and milky quartz, un-consolidated, very fine to fine grained, Sub-rounded to rounded grains, sorted to well sorted, non-calcareous, trace of brown to reddish-orange siderite, trace of dark gray shale, trace of light brown siltstone. 10-14-2013 Continue to time drill from 14,148' to 14,161'. Drill ahead from 14,161' to 14,177'. Ream/wash down to smooth out the hole from 14,160' to 14,174'. Shut in the well and evacuate rig because of fire in well bay number 1. All persons present in primary muster area and return to work after fire was extinguished. Ream/wash down from 14,155' to 14,161'. Pull out of the hole to 14,155' and ream/wash down to 14,173'. Pull out of the hole and ream/wash down from 14,141' to 14,164'. Gas: The maximum gas reading of 141 units from a depth of 14,174’ MD with an average of 56 units. Fluids: There were no losses observed. 10-15-2013 Continue to time drill from 14,160’ MD to 14,170’ MD. Work pipe as necessary to stop Geo-Pilot housing roll. Continue time drill from 14,170’ MD to 14,178’ MD. Start to rotary drill from 14,178’ MD to 14,217’ MD. Service top drive and cleaned suction screens. Drill ahead from 14,217’ MD to 14,230’ MD. Return to time drill from 14,230’ MD to 14,232’ MD. Gas: The maximum gas reading of 90 units from a depth of 14,206’ MD with an average of 61 units. Fluids: There were no losses observed. Geology: Sandstone: clear and milky quartz, un-consolidated, very fine to fine grained, Sub-rounded to rounded grains, sorted to well sorted, non-calcareous, common to abundant brown to reddish-orange siderite, trace of light brown siltstone. 10-16-2013 Continue time drill from 14,232’ MD to 14,262' MD. Ream/wash down from 14,180' MD to 14,240' MD. Drill ahead from 14,262' MD to 14,334' MD. Circulate and take survey. Displace mineral oil based mud within well from 7.7 pounds per gallon to 10.2 pounds per gallon kill weight mud. Change out the rotating head and rubber. Remove rotating control device bearing and install trip nipple. Begin tripping out of hole from 14,334' MD to 12,231' MD. Gas: While drilling max gas was the recorded connection gas of 120 units from 14250’ MD with an average of 54 units. Fluids: There were no losses observed. Geology: Sandstone: milky, clear, unconsolidated, very fine to fine grained, sub rounded to sub angular, sorted to well sorted, non-calcareous cement, quartz, trace siderite, trace light brown siltstone. 10-17-2013 Trip out from 12,231’ MD to surface. Lay down bottom hole assembly #11. Pick up bottom hole assembly #12. Start trip into hole from surface to 7,166’ MD. Gas: No significant gas data observed. Fluids: There were 5 barrels lost during trip out of hole. 10-18-2013 Trip out of hole from 7166' MD to 1527' MD and troubleshoot with MWD. Continue to trip out to surface and lay down bottom hole assembly # 12. Test blow out preventers. Pick up bottom hole assembly # 13 and begin to trip into hole from surface to 6204' MD. Gas: No significant gas data observed. Fluids: There were no losses observed. 10-19-2013 Continue trip into hole from 6204' MD to 12945' MD. Test MWD equipment and cut and slip drill line. Complete trip to 14334' MD and install rotating control device. Circulate and stage pumps. Displace well to 7.7 pounds per gallon mineral oil based mud from 10.4 pounds per gallon mineral oil based mud. Take returns to active at 6340 strokes. Drill ahead from 14334’ MD to 14580’ MD at 190 gallons per minute. Gas: The max gas was trip gas of 1622 units. While drilling the max gas was 398 units from 14557’ MD with an average of 156 units. Fluids: There were 3 barrels lost during trip into the hole. Geology: Sandstone: Black, clear, milky, unconsolidated, very fine to fine grained, sub rounded to sub angular, sorted to well sorted, non-calcareous cement, Quartz, trace siderite, trace light brown siltstone, and trace black glauconite. 10-20-2013 Continue to drill from 14580' to 15612' at 240 gallons per minute. Begin to pump seawater for the wells group. The pop-off valve blew causing less than 5 bbls seawater to infiltrate the active system. Minimal effects of discharge are viewed to the mud system. Gas: While drilling the max gas was 947 units from 15026’ MD with an average of 470 units. Fluids: There were no losses observed. Geology: Sandstone: clear, unconsolidated, very fine to fine grained, sub rounded to sub angular, sorted to well sorted, non-calcareous cement, Quartz, trace siderite, trace light brown siltstone, and trace black glauconite. 10-21-2013 Continue to drill from 15612' to 15885' at 240 gallons per minute. MWD tool troubleshooting begins, as no detection over 20 revolutions per minute observed. Continue to drill from 15885' to 16023' at 230 gpm. Gas: While drilling the max gas was 1110 units from 15026’ MD with an average of 432 units. Fluids: There were no losses observed. Geology: Sandstone: clear, unconsolidated, very fine to fine grained, sub rounded to sub angular, sorted to well sorted, non-calcareous cement, Quartz, black lithic inclusion, trace siderite, trace light brown siltstone, and trace black glauconite. 10-22-2013 Continue to drill from 16023' to 17025' at 240 gallons per minute. Service top drive and check shaker screens. Gas: While drilling the max gas was connection gas of 915 units from 16603’ MD with an average of 453 units. Fluids: There were no losses observed. Geology: Sandstone: yellowish to clear, unconsolidated, very fine to fine grained, sub rounded to sub angular, sorted to well sorted, non-calcareous cement, Quartz, trace of pyrite, trace siderite, and trace black glauconite. 10-23-2013 Continue to drill from 17025' MD to 17935' MD at 240 gallons per minute. Change rotating head rubber and rotating control device bearing at 17083' MD. Conduct service to the top drive at 17850' MD. Gas: While drilling the max gas was connection gas of 1141 units from 17563’ MD with an average of 456 units. Fluids: There were no losses observed. Geology: Sandstone: Quartz, translucent, clear, unconsolidated, very fine to fine grained, sub rounded to sub angular, sorted to well sorted, non-calcareous cement, trace of pyrite, and trace black glauconite. 10-24-2013 Continue to drill from 17935' MD to 18916' MD at 240 gallons per minute. Service the top drive. Gas: While drilling the max gas was 770 units from 18238’ MD with an average of 319 units. Fluids: There were no losses observed. Geology: Sandstone: Quartz, brown –tan, black, gray, white, translucent - transparent, unconsolidated, very fine to fine grained, sub rounded to sub angular, sorted to well sorted, non-calcareous cement, trace of pyrite , and trace black glauconite. 10-25-2013 Continue to drill from 18916' MD to total depth at 19868' MD. Back ream from 19868' MD to 19105' MD at 190 gallons per minute and 700-800 foot pounds per minute. Replace rotating control device. Gas: While drilling the max gas was 1120 units from 19475’ MD with an average of 355 units. Fluids: There were no losses observed. Geology: Sandstone: Quartz, brown –tan, black, gray, white, translucent - transparent, unconsolidated, very fine to fine grained, sub rounded to sub angular, sorted to well sorted, non-calcareous cement with trace of siderite. 10-26-2013 Back reamed from 19105' MD to 12942' MD, 190 gpm. Mad passed from 14460' MD to 13060' MD, 250- 275 fpm. Circulate at shoe at report time. Gas: Max gas was 284 units and Average gas was 40 units while circulating Fluids: There were 2 barrels lost down hole. 10-27-2013 Trip into hole to TD and establish circulation. Displace well to 10.2 ppg KW MOBM, 10.2 ppg returns at 8650 strokes, 210 gpm. Install trip nipple and trip out from TD to 12945' MD. Slip and cut drill line. Gas: Max gas was 302 units and Average gas was 17 units while circulating. Fluids: There were 9 barrels lost down hole. 10-28-2013 Trip out of hole from 12945' MD to 4734' MD, lubricate while laying down drill pipe from 4734' MD to 1560' MD. Pump dry job and lay down from 1560' MD to 133' MD, remove nukes and lay down MWD. Gas: No significant gas data observed. Fluids: There were 14 barrels lost down hole 10-29-2013 Lay down of BHA #13 completed. Rig up and ran 4.5" 12.6# C-110 tubing from surface to 3644' MD. Gas: No significant gas data observed. Fluids: There were no losses observed 10-30-2013 Run 4.5" liner into hole from 3644' MD to 7052' MD. Rig down Tesco. Ran from 7052' MD to 7214' MD with 4.5" liner, circulate and condition mud at 1.5 BPM. Continue tripping into hole with 4.5" liner from 7214' MD to 12925' MD. Break circulation and stage up to 1.5 BPM. Gas: No significant gas data observed. Fluids: There were no losses observed 10-31-2013 Circulate bottoms up at 1.5 to 2 barrel per minute at 12925' MD and condition mud. Continue to run into hole with liner on 4" drill pipe from 12925' MD to 19858' MD and set liner. Circulate, drop ball and set liner hanger on seat. Lay down drill pipe, pump dry job and trip out of hole from 12754' MD to 7961' MD. Gas: No significant gas data observed. Fluids: There were no losses observed 11-01-2013 Lay down 4" drill pipe from 7961' MD to 66' MD. Test BOP and rig down test equipment. Rig up Tesco and Halliburton equipment to run into hole with 4.5” tubing. Gas: No significant gas data observed. Fluids: There were no losses observed 11-02-2013 Hang control line sheave and trip into hole with 4.5" tubing to 139' MD. Make up ROC gauge and test control line to 500 psi for 10min. Trip into hole with 4.5" tubing from 139' MD to 12426' MD, cannon clamp every connection. Continue tripping into hole. Routine maintenance of mudloggers gas equipment performed. Gas: No significant gas data observed. Fluids: There were no losses observed 11-03-2013 Completed ODSN-04. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 0 10 20 30 40 50 60 70 80 90 100 Me a s u r e d D e p t h Rig Days Days vs. Depth 29 March 2013 Sperry SDL Arrived on Location WELL NAME: ODSN-04 OPERATOR: Pioneer Natural Resources MUD CO: Baroid RIG: Nabors 19AC SPERRY JOB: AK-AM-0900261430 LOCATION: Oooguruk AREA: North Slope STATE: Alaska SPUD: 21 March 2013 TD: 25 October 2013 Landed 11.75" Casing 5284' MD, 3333' TVD 30 March 2013 Commenced 10.625" Intermediate 1 Hole Section On Bot: 14:50 02 April 2013 TD Intermediate 1 Hole Section 10375' MD, 5565' TVD Off Bot: 20:45 06 April 2013 Troubleshoot pack off between CCU and RSC 03 April 2013 Landed 11.75" Casing 10365' MD, 5561' TVD 13 April 2013 17 April 2013 Rig down ODSN-04 07 August 2013 Rig up to complete ODSN-04 Landed 7" Liner 12984' MD, 6414' TVD 27 Aug 2013 Commenced 14.5" Surface Hole Section On Bot: 09:40 24 March 2013 TD Surface Hole Section 5294' MD, 3343' TVD Off Bot: 13:35 28 March 2013 Commenced 9.5" Intermediate 2 Hole Section On Bot: 17:40 15 Aug 2013 Perform Geo-Tape from 12098' MD to 12222' MD Issue noted with reamer POOH 19 Aug 2019 TD Intermediate 2 Hole Section 12986' MD, 6414' TVD Off Bot: 12:51 24 Aug 2013 TD ODSN-04 PB1 14811' MD, 6406 TVD Off Bot: 09:22 09 Oct 2013 Commenced 6.125" Production Hole Section On Bot: 15:25 06 Oct 2013 Commenced ODSN-04 Production Hole Section On Bot: 02:28 11 Oct 2013 TD Production Hole Section 19868' MD, 6362' TVD Off Bot: 20:00 25 Oct 2013 WELL NAME:LOCATION:Oooguruk OPERATOR:AREA:North Slope SPERRY JOB:STATE:Alaska RIG:Nabors 19AC HOLE SECTION Intermediate 1 EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 What went as, or better than, planned: INSITE stopped calculating pump strokes. When this has happened before the fix was to delete the config files and when that did not fix the problem, we uninstalled and reinstalled INSITE. This still did not fix the issue. The fix found was to delete the pump config file out of well based on the MADI machine. Recommendations: Innovations and/or cost savings: We had the opportunity to run real time hydraulics. One issue noted, the system would go into Standby mode when the rig was blowing down the top drive. Also with the hole being so large in diameter, there was a low number for surg/swab pressures. Difficulties experienced: We need to make sure that we always have clean configuration files on hand to avoid major downtime and lost data. While running real time hydraulics, we were able to collect data which will help us develop a process to run this valuable tool. Pioneer Natural Resources AK-AM-0900231430 Charles Sinn 8-Apr-2013 ODSN-04 Surface Data Logging After Action Review WELL NAME:LOCATION:Oooguruk OPERATOR:AREA:North Slope SPERRY JOB:STATE:Alaska RIG:Nabors 19AC HOLE SECTION Production EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 What went as, or better than, planned: There was a short amount of time to rig up the CVE system once back on the rig after workovers. In the rush the suction tube assembly was not tightened down properly, which resulted in lower than normal gas readings. Recommendations: Innovations and/or cost savings: Communications between the pit watcher and mudlogger went smoothly and monitoring of volumes were accurate. Difficulties experienced: When rigging up the CVE be sure to read the manual and ask questions. Be sure that all parts are tightened correctly and the correct seals are used. N/A Pioneer Natural Resources AK-AM-0900231430 Kerry Garner 1-Nov-2013 ODSN-04 Surface Data Logging After Action Review WELL NAME:LOCATION:Oooguruk OPERATOR:AREA:North Slope SPERRY JOB:STATE:Alaska RIG:Nabors 19AC HOLE SECTION Production EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 What went as, or better than, planned: There was a short amount of time to rig up the CVE system once back on the rig after workovers. In the rush the suction tube assembly was not tightened down properly, which resulted in lower than normal gas readings. Recommendations: Innovations and/or cost savings: Communications between the pit watcher and mudlogger went smoothly and monitoring of volumes were accurate. Difficulties experienced: When rigging up the CVE be sure to read the manual and ask questions. Be sure that all parts are tightened correctly and the correct seals are used. N/A Pioneer Natural Resources AK-AM-0900231430 Kerry Garner 1-Nov-2013 ODSN-04 Surface Data Logging After Action Review WELL NAME:ODSN-04 & ODSN-04 PB1 LOCATION:Oooguruk OPERATOR:Pioneer Natural Resources AREA:North Slope MUD CO:Baroid STATE:Alaska RIG:Nabors 19AC SPUD:21-Mar-2013 SPERRY JOB:AK-AM-0900231430 TD:25-Oct-2013 Marker MD INC AZ TVD TVDSS 14 1/2" Surface Hole Section Top Permafrost 874.0 25.54 307.64 852.7 796.5 Base Permafrost 1,834.0 37.58 343.26 1,668.0 1,611.8 Ugnu D 1,920.0 41.50 348.73 1,734.3 1,678.1 Top West Sak 2,915.0 66.74 355.42 2,305.2 2,249.0 Cretaceous Tuffs 4,336.0 62.97 353.43 2,914.0 2,857.8 Hue 2 Shale 5,186.0 63.60 351.99 3,296.1 3,239.9 11 3/4" SCP TD 5,284.0 64.13 352.85 3,339.1 3,282.9 10 5/8" Intermediate 1 Hole Section Brookian 2B 7,552.0 64.03 354.39 4,332.8 4,276.6 Top Torok Sand 9,354.0 64.07 355.19 5,120.8 5,064.6 Base Torok Sand 9,975.0 64.39 355.01 5,390.8 5,334.6 Torok 1 Shale 10,349.0 64.22 354.05 5,554.2 5,498.0 9 5/8" ICP1 10,365.0 64.22 354.05 5,561.2 5,505.0 8 1/2" Intermediate 1 Hole Section Top HRZ 11,316.0 65.05 351.34 5,967.3 5,911.1 Base HRZ (Top Kalubik Sh)11,633.0 65.60 345.47 6,100.8 6,044.6 Kalubik Marker 11,840.0 68.56 342.27 6,182.4 6,126.2 Top Kuparuk C 12,055.0 72.99 339.77 6,253.4 6,197.2 LCU (Top Miluveach Sh)12,136.0 73.40 337.23 6,276.8 6,220.6 BCU(Top Kingak Sh)12,577.0 81.05 329.30 6,373.0 6,316.8 Top Nuiqsut 12,870.0 85.33 322.08 6,403.4 6,347.2 Top Nuiqsut::Nuiq_1 12,904.0 84.91 322.06 6,406.3 6,350.1 7" ICP2 12,965.0 84.47 322.08 6,412.2 6,355.9 Invert 1 13,111.0 90.00 324.16 6,420.2 6,364.0 Revert 1 13,427.5 90.00 320.20 6,417.2 6,361.0 Invert 2 13,601.0 90.00 320.41 6,418.9 6,362.7 Revert 2 13,928.7 90.00 319.06 6,414.3 6,358.1 Nuiq_1::Nuiq_2 D5 13,993.0 88.81 318.24 6,415.0 6,358.8 Nuiq_2::Nuiq_3 D5 14,110.0 87.12 319.50 6,420.2 6,364.0 Invert 3 14,175.3 90.00 322.11 6,422.0 6,365.8 Nuiq_3::Nuiq_2 U6 14,634.0 91.59 320.19 6,412.8 6,356.6 Nuiq_2::Nuiq_1 U6 14,678.0 92.18 320.34 6,411.3 6,355.1 ODSN-04 PB1 TD 14,810.0 93.04 321.27 6,404.8 6,348.6 6 1/8" Production Hole Section KOP from ODSN-04 PB1 13,585.0 88.11 319.76 6,419.3 6,363.1 Nuiq_1::Nuiq_2 D3 13,710.0 88.71 319.53 6,424.3 6,368.1 Nuiq_2::Nuiq_3 D3 13,722.0 88.96 319.38 6,424.5 6,368.3 Invert 2 13,767.0 90.00 319.32 6,424.9 6,368.7 Nuiq_3::Nuiq_2 U4 13,895.0 92.40 319.67 6,421.9 6,365.7 Nuiq_2::Nuiq_1 U4 13,927.0 92.81 319.81 6,420.5 6,364.3 Revert 2 14,119.5 90.00 328.18 6,415.7 6,356.5 Nuiq_1::Nuiq_2 D5 14,190.0 88.01 329.56 6,417.0 6,360.8 Nuiq_2::Nuiq_3 D5 14,201.0 87.82 329.53 6,417.4 6,361.2 Nuiq_3::Nuiq_4 D5 14,278.0 86.76 330.76 6,421.1 6,364.9 Nuiq_4::Nuiq_5 D5 14,355.0 89.02 330.35 6,424.6 6,368.4 Invert 3 14,375.3 90.00 330.02 6,424.8 6,368.6 Nuiq_5::Nuiq_4 U6 14,502.0 91.85 324.78 6,422.0 6,365.8 Nuiq_4::Nuiq_3 U6 14,592.0 94.66 324.24 6,416.9 6,360.7 Nuiq_3::Nuiq_2 U6 14,632.0 94.67 324.27 6,413.6 6,357.4 Nuiq_2::Nuiq_1 U6 14,650.0 94.67 324.29 6,412.2 6,356.0 TD Lateral 19,868.0 92.94 319.38 6,362.6 6,306.4 Formation Tops ODSN-04 PB1 6 1/8" Production Hole Section WELL NAME:ODSN-04 & ODSN-04 PB1 LOCATION:Oooguruk OPERATOR:Pioneer Natural Resources AREA:North Slope MUD CO:Baroid STATE:Alaska RIG:Nabors 19AC SPUD: SPERRY JOB:AK-AM-0900231430 TD: Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 23-Mar 0 8.00 123 22 55 17/19/21 7.6 99/77/66/49/19/17 2/0 2.3 2.0/94.6 0.01 1.10 9.6 5.0 0.20/0.35 19500 520 P/U 5" DP 24-Mar 450 9.10 115 22 51 19/25/28 7.2 95/73/62/48/21/19 2/0 4.6 2.0/92.3 0.15 1.20 9.7 6.5 0.20/0.40 19500 600 Drilling 14 1/2" Surface Interval 25-Mar 2280 9.30 105 22 41 22/48/64 7.8 85/63/55/44/22/20 2/0 6.2 2.0/90.8 0.15 0.90 9.5 10.0 0.18/0.35 17500 480 Drilling 14 1/2" Surface Interval 26-Mar 2935 9.40 120 22 43 28/68/80 6.4 87/65/58/46/30/28 2/0 6.8 2.0/90.1 0.15 1.00 10.1 10.5 0.30/0.60 20000 240 Drilling 14 1/2" Surface Interval 27-Mar 4501 9.50 96 12 48 34/45/58 10.0 72/60/55/48/35/33 2/0 7.4 2.0/89.5 0.30 1.00 10.2 12.0 0.30/0.80 20000 220 Drilling 14 1/2" Surface Interval 28-Mar 5294 9.50 83 9 40 27/39/46 10.8 58/49/45/40/28/26 2/0 7.3 2.0/89.6 0.10 1.00 9.9 13.0 0.28/0.95 20000 140 Tripping 29-Mar 5294 9.55 45 10 26 17/24/31 12.3 46/36/32/26/16/15 2/0 7.4 1.5/90.0 0.05 1.00 9.0 15.0 0.10/0.50 20000 220 Running 11.75" Casing 30-Mar 5294 9.70 67 9 41 35/40/47 14.2 59/50/45/41/35/34 2/0 8.6 1.0/89.4 0.05 1.00 10.0 15.0 0.25/1.00 19000 480 Rig Down Cement Equip 31-Mar 5294 10.30 92 23 12 8/12/14 14.0 58/35/25/16/7/6 2/0 13.8 1.0/89.0 0.05 1.00 9.5 15.0 0.25/1.00 19000 480 Picking up BHA #3 1-Apr 5294 10.30 90 23 12 7/12/15 16.6 58/35/25/16/7/6 2/0 13.6 1.0/91.0 0.05 0.00 11.2 12.5 0.35/0.70 20000 800 Picking up BHA #4 Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Alka POM Excess Lime Elec Stab CaCl2 WPS LGS/HGS ASG Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%ml ppb volts ppb ppm ppb ASG 2-Apr 5808 10.3 92 26 15 12/16/18 2.6 67/41/32/22/11/10 0/2 16.3 70/13 2.72 702 3.84 145,223 108.72/65.05 3 Displaced to MOBM 3-Apr 6054 10.3 120 31 19 14/22/26 2.1 81/50/39/27/12/11 0/2 16.4 70/13 4.47 754 4.81 132,634 110.46/63.41 3.02 Drilling 10.625" Intermediate 1 4-Apr 6891 10.25 80 27 20 16/24/28 2.2 74/47/37/25/12/11 0/2 16.4 70/13 4.66 765 3.84 133483 112.99/58.73 2.989 Drilling 5-Apr 9015 10.25 80 37 21 16/28/34 2.2 95/58/45/30/13/12 0/2 16.3 70/13 4.4 728 2.87 134330 112.13/59.54 2.996 Drilling 6-Apr 10215 10.35 86 25 23 16/28/33 2.4 73/48/38/28/13/12 0/2 16.4 70 / 13 4.73 708 4.3 133059 106.60/69.34 3.059 Circulating 7-Apr 10375 10.30 132 20 20 15/22/28 2.4 60/40/31/23/12/11 0/2 16.4 72 / 11 4.40 674 4.8 132634 113.87/57.90 2.983 TOOH 8-Apr 10375 10.25 100 14 22 13/22/28 2.5 50/36/26/19/11/10 0/2 15.8 70/13 4.92 701 2.9 130001 103.01/66.91 3.059 TIH 9-Apr 10375 10.20 96 21 18 15/20/0 2.6 60/39/32/24/13/11 0/2 16.9 71 / 12 4.40 691 3.8 138085 122.11/51.36 2.931 Reaming 10-Apr 10375 10.20 74 36 23 14/20/29 2.2 95.0/59/46/32/12/11 0/2 16.8 70/12.5 4.66 691 2.9 138956 124.66/46.66 2.901 Reaming 11-Apr 10375 10.20 84 38 22 14/22/29 2.2 98/60/46/31/12/11 0/2 16.2 72.5/10.5 2.46 698 2.9 187897 111.92/57.60 2.987 Reaming 12-Apr 10375 10.20 102 52 14 13/20/28 2.2 118/66/49/31/12/11 0/2 17.3 72 / 10 3.17 973 2.9 167864 131.94/42.25 2.865 TIH 9 5/8" Liner 13-Apr 10375 10.20 90 45 12 12/18/29 2.2 102/57/42/26 0/2 17.8 71.5/10 2.91 979 1.9 168879 140.71/34.91 2.813 RIH with 9 5/8 " Liner 14-Apr 10375 10.20 120 51 16 16/29/34 2.3 118/67/53/36/11/10 0/2 18.3 71/10 n/a n/a n/a n/a 151.08/26.06 2.754 Displacing with 9.8 ppg Brine 15-Apr 10375 10.20 145 49 19 17/27/35 2.2 119/69/53/35/12/11 0/2 17.8 71/10.5 n/a n/a n/a n/a 138.16/39.30 2.840 Changing Rams Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 13-Aug 10229 10.20 59 16 18 6/9/15 4.4 50/34/26/16/5/4 2/0 6.8 2.0/89.0 0.05 1.50 10.4 NA 0.50/1.25 44000 400 Displace 9.8 brine w/ 10.2 Mud 14-Aug 10395 10.30 62 20 25 8/9/13 3.8 65/45/37/25/8/6 2/0 6.8 1.0/90.0 0.05 1.75 10.4 1.0 0.4/1.3 42000 320 Pre job on loading nukes 15-Aug 10475 10.25 61 19 27 8/10/13 3.6 65/46/37/26/8/7 2/0 7.4 2.5/88.0 0.10 1.50 10.5 1.0 0.5/1.2 42000 300 Drilling ahead 16-Aug 11386 10.20 53 18 32 10/12/15 3.8 68/50/41/30/12/10 2/0 7.4 4.5/86.0 0.10 1.40 9.9 5.0 0.5/1.3 43000 260 Drilling ahead 17-Aug 11705 10.20 58 22 35 12/14/15 3.2 79/57/46/35/12/10 2/0 8.1 5.0/85.0 0.10 0.90 9.9 9.0 0.40/1.10 39000 260 Drilling ahead 18-Aug 12285 10.20 56 22 41 12/14/17 3.2 85/63/53/38/14/12 2/0 8.1 5.5/84.5 0.05 0.70 10.0 10.0 0.40/1.00 40000 320 Drilling ahead 19-Aug 12285 10.20 61 25 39 10/12/14 3.2 89/64/50/34/11/10 2/0 7.9 5.5/84.5 0.10 1.10 10.6 10.0 0.70/1.50 44000 260 Rig Maintenance 20-Aug 12747 10.20 59 23 41 13/16/19 3.9 87/64/55/37/14/12 2/0 8.5 5.5/84 0.50 1.10 10.3 11.5 0.7/1.9 42000 260 Drilling ahead 21-Aug 12749 10.30 56 19 37 14/18/22 3.4 75/56/47/36/13/13 2/0 8.9 5.0/84 0.10 NA 10.5 12.0 1.00/1.80 44000 240 Tripping out 22-Aug 12749 11.00 71 22 42 17/20/23 3.5 86/64/53/42/18/16 2/0 9.9 5.0/83.0 0.05 NA 10.0 12.0 0.90/1.60 45000 240 Testing BOPs 23-Aug 12749 11.00 55 20 35 10/13/15 2.6 75/55/45/33/10/9 2/0 9.8 4.0/84.0 0.05 NA 10.3 12.0 0.80/1.60 45000 280 Displacing at shoe 24-Aug 12986 10.20 55 16 28 11/12/12 3.6 60/44/36/27/11/9 2/0 6.9 4.0/87.0 0.05 NA 10.3 10.0 0.40/1.00 43000 280 Circulating bottoms up 25-Aug 12986 12.00 62 27 33 10/12/14 3.8 87/60/44/30/10/9 2/0 13.6 3.5/81.0 0.05 NA 10.5 9.0 0.3/1.00 42000 280 Tripping out 25-Oct-2013 21-Mar-2013 W a t e r a n d O i l B a s e d M u d Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 26-Aug 12986 10.20 51 23 33 11/13/14 3.6 79/56/46/34/11/9 2/0 6.8 3.5/87.5 0.01 NA 8.5 8.5 1.0/1.40 44000 280 Running 7" Casing 27-Aug 12986 10.20 50 19 35 10/12/13 3.6 73/54/45/34/10/9 2/0 7.4 3.5/87.0 0.05 NA 10.2 8.0 0.90/1.30 42000 240 Rigging up for cement 28-Aug 12986 10.20 50 23 32 11/13/15 NA 78/55/44/34/11/9 2/0 7.0 4.0/87.0 NA NA 10.5 7.0 0.80/1.20 41000 280 Servicing rig Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Alka POM Excess Lime Elec Stab CaCl2 WPS LGS/HGS ASG Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%ml ppb volts ppb ppm ppb ASG 2-Oct 12986 10.00 27 ---------------Nipple up/down BOPs 3-Oct 12986 10.00 27 ---------------Tripping in hole 4-Oct 12686 10.20 96 32 19 10/16/21 9.2 83/51/38/25/8/7 0/2 12.0 74.5/13.0 7.38 793 -123976 33.11/123.83 3.717 Drilling cement 5-Oct 12990 10.20 93 32 19 10/16/21 8.9 83/51/38/25/8/7 0/2 12.4 73.0/14.0 9.32 810 3.4 125542 40.32/116.94 3.628 Picking up BHA #10 6-Oct 13222 7.65 55 12 9 5/9/14 9.8 33/21/16/11/5/4 0/2 2.5 85.5/11.5 4.40 1127 4.3 129234 22.49/0.72 2.631 Drilling lateral section 7-Oct 14069 7.70 52 11 10 5/7/9 10.3 32/21/16/11/5/4 0/2 2.4 87.1/12.9 4.53 1223 2.4 127006 17.97/6.38 2.888 Time drilling 8-Oct 14249 7.65 51 12 9 5/8/10 9.8 33/21/16/11/6/5 0/2 2.6 86/11 3.50 1382 2.9 112837 21.75/2.81 2.719 Drilling Lateral Section 9-Oct 14810 7.70 52 12 10 6/8/10 9.6 34/22/17/12/6/5 0/2 3.0 85.5/11 4.01 1487 2.4 127848 26.83/0.55 2.620 Preparing to Sidetrack 10-Oct 14810 7.70 54 13 11 6/9/12 9.6 37/24/18/13/6/5 0/2 2.9 85.6/11 5.44 1674 2.3 126832 25.79/1.35 2.650 Time Drilling 11-Oct 13673 10.20 97 33 19 9/15/22 6.7 85/52/39/25/8/7 0/2 12.3 74/13 7.12 867 3.4 145636 38.77/118.32 3.646 Lay down BHA 12-Oct 13673 10.20 97 33 20 9/13/19 7.4 86/53/40/25/8/7 0/2 12.4 74/13 7.51 912 4.3 133059 40.29/117.58 3.630 Tripping in the hole 13-Oct 14145 7.80 58 13 11 6/10/13 8.8 37/24/19/13/6/5 0/2 3.6 85/11 6.86 1596 3.8 111786 31.56/2.3 2.669 Time drilling 14-Oct 14177 7.70 57 12 11 6/10/13 8.0 35/23/18/12/6/5 0/2 2.6 85.5/11.5 7.38 1782 4.3 121005 19.48/6.26 2.865 Reaming 15-Oct 14224 7.70 56 12 11 6/9/12 7.6 35/23/17/12/6/5 0/2 2.6 85.0/12.0 7.51 1981 4.3 116551 19.93/5.53 2.834 Time drilling 16-Oct 14334 10.20 85 22 26 15/19/27 6.8 70/48/39/28/13/11 0/2 12.3 73.5/13.5 7.51 994 4.3 140199 40.08/116.79 3.629 Tripping out 17-Oct 14334 10.20 99 24 27 13/19/27 6.8 75/51/41/29/12/10 0/2 13.4 73/13 6.73 1136 3.8 128696 59.25/101.82 3.425 Tripping in 18-Oct 14334 10.40 110 25 27 13/19/28 6.8 77/52/42/31/12/11 0/2 12.4 73/14 5.83 1260 3.4 114141 27.31/139.07 3.815 Tripping in 19-Oct 14339 7.80 60 14 10 4/6/9 7.4 38/24/17/12/6/5 0/2 3.7 84/12 7.51 1998 3.8 95075 32.83/0.9 2.627 Drilling 20-Oct 15612 7.85 64 15 12 5/7/12 7.6 42/27/20/14/6/5 0/2 3.7 84/12 7.38 1988 4.3 94574 29.89/5.97 2.776 Drilling 21-Oct 15843 7.90 62 11 12 6/8/11 7.2 34/23/17/12/6/5 0/2 3.6 83/13 7.45 1898 3.8 91035 26.75/10.47 2.912 Drilling 22-Oct 16710 7.90 68 10 11 6/8/11 7.2 31/21/16/11/6/5 0/2 4.6 83/12 6.80 1917 2.9 96075 44.22/.01 2.520 Drilling 23-Oct 17672 8.00 61 11 10 6/8/12 7.6 32/21/17/12/6/5 0/2 5.1 82./12.6 6.15 1908 2.9 86494 45.83/0.32 2.607 Drilling 24-Oct 18727 8.15 64 15 12 5/8/12 7.0 42/27/19/13/6/5 0/2 6.1 82/11.5 6.22 1785 2.4 94513 55.23/1.05 2.619 Drilling 25-Oct 19868 8.30 62 18 12 8/14/21 6.8 48/30/24/17/7/6 0/2 7.2 89.2/10.8 5.83 1812 0.4 100552 63.08/3.58 2.654 Back Reaming 26-Oct 19868 8.30 74 19 13 8/14/24 4.2 51/32/23/18/8/7 0/2 7.4 84.2/8.0 4.92 1722 2.4 130468 66.79/1.58 2.623 Circulating at shoe 27-Oct 19868 10.20 78 32 24 12/20/35 5.8 88/56/44/27/11/9 0/2 13.4 70.0/16.0 7.64 1120 3.4 101319 61.85/97.96 3.392 Tripping out 28-Oct 19868 10.20 82 120 27 13/25/39 6.4 87/57/44/29/11/10 0/2 13.5 70.0/16.0 7.51 1077 3.6 101096 62.11/97.70 3.389 Tripping out 29-Oct 19868 10.20 78 29 30 14/22/35 6.6 88/59/45/30/11/10 0/2 13.9 70.0/15.5 7.51 1102 3.4 112699 70.48/90.50 3.31 Running Liner 30-Oct 19868 10.10 87 29 24 13/22/35 6.2 82/53/41/27/12/10 0/2 13.4 84.9/15.1 7.51 1094 4.3 133059 66.25/90.36 3.33 Circulating 31-Oct 19868 10.10 84 28 26 13/21/36 6.4 82/54/41/27/12/10 0/2 13.8 84.2/15.8 7.12 1030.0 3.0 126412 64.04/77.93 3 Tripping out of Hole Casing Record 16" Conductor @ 158' MD, 158'TVD 11.75" Casing @ 5283' MD, 3333'TVD 9.625" Liner @ 10365' MD, 5565'TVD 7" Casing @ 12952' MD, 6443'TVD W a t e r a n d O i l B a s e d M u d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 1 100 1 Baker Hughes MXL-1V 14.5 158 2816 2658 23.36 0.6995 114 22 60 2050 650 2-1-WT-M-E-I-NO-BHA Surface - POOH to bend motor 2 200 1rr1 Baker Hughes MXL-1V 14.5 2816 5294 2478 30.58 0.6995 81 40 130 3350 850 5-2-WT-M-E-2-FC-TD Surface TD 3 300 2 Baker Hughes GT-C1 10.625 5294 5294 --0.9419 -----1-1-WT-A-E-I-CD-TD Clean Out Run 4 400 3 HDBS FXG65s 10.625 5294 10375 5081 48.61 1.3530 105 18 160 4500 750 0-0-NO-A-X-I-NO-TD Intermiediate 1 TD 6 600 4 Baker Hughes VM-3 8.50 10375 10395 20 0.73 0.9419 27.0 18 80 2850 700 4-1-BT-N3-E-I-CD-BHA Clean Out Run 7 700 5 HDBS SFE56 8.50 10395 12749 2354 60.84 1.1083 39.0 32 150 4450 715 1-3-BT-T-X-1-CT-PR POOH due to issue w/ reamer 8 800 6 HDBS FX56 8.50 12749 12986 237 4.9 1.1083 48.0 15 80 4475 650 1-0-CT-C-X-I-NO-TD Intermediate 2 9 900 7 Baker Hughes STX-1 6.125 12986 12990 4 0.28 0.9204 14.0 3 40 4280 270 1-0-CT-N2-E-I-NO-BHA Clean Out Run 10a 1000 8a HDBS FXG64 6.125 12990 14810 1820 22.87 0.3889 80.0 8 140 2700 245 N/A Production PB1 TD 10b 1100 8b HDBS FXG64 6.125 13585 13673 88 22.74 0.3389 4.0 8 80 2310 220 0-0-ER-T-X-I-NO-BHA Trough in preparation to sidetrack 11 1200 9 HDBS FXG64 6.125 13673 14334 661 44.04 0.3889 15.0 15 120 2750 240 0-0-NO-A-X-I-NO-BHA POOH to P/U motor assembly 12 1300 10 HDBS MM64 6.125 14334 14334 --0.3889 -----0-0-NO-A-X-I-NO-BHA Lost comms w/ MWD due to Agitator 13 1400 10rr1 HDBS MM64 6.13 14334 19868 5534 94.77 0.3889 58.0 12 80 4350 240 1-3-BT-N-X-I-CT-TD Production TD WELL NAME:ODSN-04 LOCATION:Oooguruk OPERATOR:Pioneer Natural Resources AREA:North Slope MUD CO: SPERRY JOB:AK-AM-0900261430 TD:25-Oct-2013 Baroid STATE:Alaska RIG:Nabors 19AC SPUD:21-Mar-2013 B i t R e c o r d . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize Grade 907-670-6636Unit Phone: 0 Todd A. Wilson Maximum Report By:Logging Engineers:Todd A. Wilson 0 0 0 0 Units* Casing Summary Lithology (%) 0 MBT 0' pH 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type C-5n 0.0 C-2 0 in 0Minimum Depth Time: Max gas = 0 units, Avg Gas = 0 units 0 Depth 0' 0' 0' Max @ ft Current N/A0.0 Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Joe Polya / Paul Carey ShClyst TuffGvlCoal cP Footage Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Move Rig to ODSN-04 PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 000 Depth in / out Mud Type Lst Type Average 00Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 Fluids = 0 bbls lost downhole ConditionBit #Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 1 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth 21-Mar-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l Rig down ODSN-24 and move rig to ODSN-04. Change out BOP stack during move. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize Grade 907-670-6636Unit Phone: 0 Todd A. Wilson Maximum Report By:Logging Engineers:Todd A. Wilson 0 0 0 0 Units* Casing Summary Lithology (%) 0 MBT 0' pH 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type C-5n 0.0 C-2 0 in 0Minimum Depth Time: Max gas = 0 units, Avg Gas = 0 units 0 Depth 0' 0' 0' Max @ ft Current N/A0.0 Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) Joe Polya / Paul Carey ShClyst TuffGvlCoal cP Footage Ss (ppb Eq) C-1 C-5i AK-AM-900261430 R/U ODSN-04 PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 000 Depth in / out Mud Type Lst Type Average 00Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 Fluids = 0 bbls lost downhole ConditionBit #Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 2 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth 22-Mar-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l Finished changing out stack and moving rig to ODSN-04. Rig up ODSN-04 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize Grade 907-670-6636Unit Phone: 0 Todd A. Wilson Maximum Report By:Logging Engineers:Todd A. Wilson 0 0 0 0 Units* Casing Summary Lithology (%) 0 MBT 0' pH 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type C-5n 0.0 C-2 0 in 0Minimum Depth Time: hole. Serviced top drive. Pick up 5" drill pipe and replace link tilt float valve. Proceed picking up 5" drill pipe. 0 Depth 0' 0' 0' Max @ ft Current N/A0.0 Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 0.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) 5.0 Joe Polya / Paul Carey ShClyst TuffGvlCoal cP 22123 Footage Ss (ppb Eq) C-1 C-5i AK-AM-900261430 P/U 5" Drill Pipe PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 000 SPUD 7.60'55 Depth in / out Mud Type Lst Type Average 00Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 Fluids = 0 bbls lost downhole Max gas = 0 units, Avg Gas = 0 units ConditionBit # 2.38.808.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth 23-Mar-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 Chlorides mg/l 19,500 Continued rigging up ODSN-04. Nipple up riser and spacer spools. Laid down 207 joints of 4" drill pipe in mouse Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 0 0 Cly 1044 Set AtSize Grade 907-670-6636Unit Phone: 0 Todd A. Wilson Maximum Report By:Logging Engineers:Todd A. Wilson 0 105 - - Units* Casing Summary Lithology (%) 0 MBT 722' pH 0.700 4 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type C-5n 281' 26.0 C-2 19 in 2 287'Minimum Depth Time: Rigged up Gyro. Made up 14.5" surface BHA. Cleaned out the conductor. Drilled from 158' MD to 226' MD. Pulled out of the hole 4 Fluids = 0 bbls lost downhole Depth 0' 722' 722' Max @ ft Current 628'- Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 301.0 Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) 6.5 Joe Polya / Paul Carey ShClyst TuffGvlCoal cP 22115 Footage Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Drill Ahead PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 000 SPUD 7.2450'51 Depth in / out Mud Type Lst Type Average N/A55Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 158' WOB 100% Gas In Air=10,000 UnitsN/AConnection 6 Max gas = 0 units, Avg Gas = 0 units connection. to adjust the BHA. Directionally drilling 14.5" surface interval. Drill ahead from 226' MD to 722' MD, running Gyro at every ConditionBit # 1 4.6 14.50'' 9.10 Baker / MXL - 1V 9.10 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 4 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth 24-Mar-2013 12:00 AM Current Pump & Flow Data: - Max 0 Chlorides mg/l 19,500 Finished picking up 5" drill pipe. Slip and cut drill line and serviced the top drive. Changed out solenoid valve. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize Grade 907-670-6636Unit Phone: 0 Todd A. Wilson Maximum Report By:Logging Engineers:Todd A. Wilson 0 0 651 154 Units* Casing Summary Lithology (%) 0 MBT 2280' pH 0.700 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type C-5n 17.0 C-2 0 in 0Minimum Depth Time: shakers. Continue to drill ahead. 0 Depth 722' 2280' 1558' Max @ ft Current -- Date: Avg to722' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) 10.0 Joe Polya / Paul Carey ShClyst TuffGvlCoal cP 22105 Footage Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Drill Ahead PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 000 SPUD 7.82280'41 Depth in / out Mud Type Lst Type Average N/A0Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 158' WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 Fluids = 0 bbls lost downhole Max gas = 0 units, Avg Gas = 0 units ConditionBit # 1 6.2 14.50'' 9.30 Baker / MXL - 1V 9.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Depth 25-Mar-2013 12:00 AM Current Pump & Flow Data: 1850 Max 0 Chlorides mg/l 17,500 Drill ahead from 722' MD to 2257' MD. Pumped 25 barrels SAPP sweep at 1995' MD. Minimal clay returns at Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize Grade 907-670-6636Unit Phone: 0 Todd A. Wilson Maximum Report By:Logging Engineers:Todd A. Wilson 0 0 651 154 Units* Casing Summary Lithology (%) 0 MBT 3100' pH 0.700 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type C-5n - C-2 0 in 0Minimum Depth Time: Drill from 2811' MD to 2816' MD. Pulled out of the hole for BHA #2. Wash and ream from 345' MD to 2816' MD. Continue to drill 0 Depth 2280' 3100' 820' Max @ ft Current -- Date: Avg to2280' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) 10.5 Joe Polya / Paul Carey ShClyst TuffGvlCoal cP 22120 2658' Footage 23.36 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Drill Ahead PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) 10.10 000 60.0 SPUD 6.42935'43 Depth in / out Mud Type Lst Type Average N/A0Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 22.0158' 2816' WOB 100% Gas In Air=10,000 UnitsN/AConnection 0 Fluids = 0 bbls lost downhole Max gas = 0 units, Avg Gas = 0 units ahead to 3100' MD. Condition 2-1-WT-M-E-I-NO-BHA Bit # 1 6.8 14.50'' 9.40 Baker / MXL - 1V 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 6 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Depth 26-Mar-2013 12:00 AM Current Pump & Flow Data: 1850 Max 0 Chlorides mg/l 20,000 Drill ahead from 2547' MD to 2811' MD. Pumped 50 barrels of 10.5 ppg hi-vis sweep which returned at 5571 strokes Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continue to drill ahead from 3100' MD to 4545' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 20,000 0 27-Mar-2013 12:00 AM Current Pump & Flow Data: 1850 Max 2-1-WT-M-E-I-NO-BHA ROP ROP (ft/hr) 6.51 @ Mud Data Depth Morning Report Report # 7 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: ConditionBit # 2 7.4 14.50'' 9.50 Baker / MXL - 1V 9.50 Size 1 Fluids = 0 bbls lost downhole 100% Gas In Air=10,000 UnitsN/AConnection 0 Tools API FL Chromatograph (ppm) 22.0 2816' WOB Avg Min Comments RPM ECD (ppg) ml/30min Background (max)Trip Average N/A Mud Type Lst Type 60.0Baker / MXL - 1V SPUD 10.0 158' 4501'48 2816' Depth in / out YP (lb/100ft2) 10.20 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Drill Ahead PV 1296 14.50''0.700 Footage 23.36 2658' Joe Polya / Paul Carey ShClyst TuffGvlCoal cP Gas Summary 0 0 0 (current) Date: Avg to3100' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Max gas = 0 units, Avg Gas = 0 units 0 Depth 3100' 4545' 1445' Max @ ft Current Minimum Depth Time: - in 0 0 C-5n - C-2 0 SPP (psi) Gallons/stroke TFABit Type - Flow In (spm) 12.0 MBT 4545' pH 0.700 0 0 0 Siltst 651 154 Units* Casing Summary Lithology (%) 00 0 907-670-6636Unit Phone: 0 Todd A. Wilson Maximum Report By:Logging Engineers:Todd A. Wilson Set AtSize Grade (max)(current) 0 0 Cly 0 . . * 24 hr Recap: 0 Cly Set AtSize (max)(current) 131 Grade 907-670-6636Unit Phone: 0 Todd A. Wilson Maximum Report By:Logging Engineers:Todd A. Wilson 7359 0 114 850 203 Units* Casing Summary Lithology (%) 0 5294' pH 0.700'' 0 32 0 Siltst SPP (psi) Gallons/stroke TFABit Type 45.4 Flow In (spm) 13.0 MBT 5285' 0.0 C-2 74 2 5164' Ss 5 Depth Time: 5006' in C-5n 10.9 ppg high vis sweep at 5002' MD, returned at 9400 strokes with a moderate increase in cuttings. Circulated two bottoms up. 10 Fluids = 0 bbls lost downhole Depth 4545' 5294' 749' Max @ ft Current Date: Avg to4545' Yesterday's Depth: Current Depth: 24 Hour Progress: 167.0 Flow In (gpm) Gas Summary 0 61 0 (current) Minimum R. Klepzig / Bill Vigil ShClyst TuffGvlCoal cP 14.50''0.700 Footage 23.36 2658' 0 (ppb Eq) C-1 C-5i AK-AM-900261430 Tripping PV 24 hr Max Weight 0 Hours C-3 YP 9 0 CementChtSilt C-4i C-4n (lb/100ft2) 9.90 000 60.0Baker / MXL - 1V SPUD 10.8 158' 5294'40 2816' Depth in / out 1 98 Mud Type Lst Type Average N/ABackground (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Chromatograph (ppm) 22.0 2816' WOB 100% Gas In Air=10,000 UnitsN/AConnection 59 Max gas = 0 units, Avg Gas = 0 units spots at 1234' MD, 1700' MD, and 4630' MD. Tripped out of the hole from 5002' MD to 165' MD. Tight spots at 2379' MD. Tripped in the hole from 165' MD to 5294' MD. Tight ConditionBit # 2 2-1-WT-M-E-I-NO-BHA 7.3 14.50'' 9.50 Baker / MXL - 1V 9.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 8 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Tools API FL Depth 0 Chlorides 28-Mar-2013 12:00 AM Current Pump & Flow Data: 1850 Max mg/l 20,000 Drilled from 4545' MD to 5294' MD. Pumped carbide pill at 5288' MD, returned 1500 strokes early. Pumped 50 barrel Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: 0 Cly Set AtSize (max)(current) 0 Grade 907-670-6636Unit Phone: 0 Todd A. Wilson Maximum Report By:Logging Engineers:Todd A. Wilson 0 0 0 0 0 Units* Casing Summary Lithology (%) 0 5294' pH 0.700 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type - Flow In (spm) 15.0 MBT - C-2 Ss Depth Time: - in C-5n 12000 strokes. Circulated three bottoms up and spotted 300 barrels of fresh new mud on bottom. Tripped out of the hole from Depth 5294' 5294' 0' Max @ ft Current Date: Avg to5294' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Gas Summary 0 0 0 (current) Minimum R. Klepzig / Bill Vigil ShClyst TuffGvlCoal cP 14.50''0.700 Footage 23.36 2658' 30.58 0 (ppb Eq) C-1 C-5i AK-AM-900261430 Clean out run PV 24 hr Max Weight 0 Hours C-3 YP 10 0 CementChtSilt C-4i C-4n (lb/100ft2) 9.10 000 60.0Baker / MXL - 1V SPUD 12.8 158' 5294'28 2816' Depth in / out 1 48 Mud Type Lst Type Average N/ABackground (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min 130.0 Chromatograph (ppm) 22.0 40.02816' 5294' WOB 2478' 100% Gas In Air=10,000 UnitsN/AConnection 0 Fluids = 0 bbls lost downhole Max gas = 0 units, Avg Gas = 0 units 5294' MD to surface. Condition 5-2-WT-M-E-2-FC-TD Bit # 2 2-1-WT-M-E-I-NO-BHA 7.3 14.50'' 9.55 Baker / MXL - 1V 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Tools API FL Depth 0 Chlorides 29-Mar-2013 12:00 AM Current Pump & Flow Data: 0 Max mg/l 22,000 Stage pumps up to 850 GPM and pumped 50 barrel 10.5 ppg high vis sweep. Noted 100% increase in cuttings at Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: 0 Cly Set AtSize 60.0 (max)(current) 0 L-80 Grade 11.75'' 907-670-6636Unit Phone: 0 Kerry Garner Maximum Report By:Logging Engineers:Kerry Garner / Todd A. Wilson 0 0 0 0 0 Units* Casing Summary Lithology (%) 0 5294' pH 0.700 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type - Flow In (spm) 17.5 MBT 5294' - C-2 54 0 5294' Ss Depth Time: - in C-5n Broke circulation and staged up pumps to 12 bpm. Rigged up cement tools, held safety meeting. Pumped 10 barrels of water, 100 10 Fluids = 52 bbls lost downhole Depth 5294' 5294' 0' Max @ ft Current Date: Avg to5294' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Gas Summary 0 0 0 (current) Minimum R. Klepzig / Bill Vigil ShClyst TuffGvlCoal cP 14.50''0.700 Footage 23.36 2658' 30.58 0 (ppb Eq) C-1 C-5i AK-AM-900261430 Service Rig / Nipple Up PV 24 hr Max Weight 0 Hours C-3 YP 15 0 CementChtSilt C-4i C-4n (lb/100ft2) 9.10 000 60.0Baker / MXL - 1V SPUD 12.8 158' 5294'30 2816' Depth in / out 1 62 Mud Type Lst Type Average N/ABackground (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min 130.0 Chromatograph (ppm) 22.0 40.02816' 5294' WOB Hydril 2478' 100% Gas In Air=10,000 UnitsN/AConnection 0 Max gas = 54 units, Avg Gas = 10 units 10.8 ppg cement at 2780 strokes and there was eight samples taken during cement job. Flush lines and clean surface equipment. barrel 10.0 ppg spacer. 522 barrel lead cement, 132 barrel tail cement, and 20 barrels of water. Return spacer at 2415 strokes, 5284' Condition 5-2-WT-M-E-2-FC-TD Bit # 2 2-1-WT-M-E-I-NO-BHA 8.9 14.50'' 9.70 Baker / MXL - 1V 9.70 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 10 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Tools API FL Depth 0 Chlorides 30-Mar-2013 12:00 AM Current Pump & Flow Data: 0 Max mg/l 21,000 Complete 11.75" casing run from 2403' MD to 5284' MD, filling every 10 joints. Landed casing a 9:00 AM at 5284' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: 0 Cly Set AtSize 60.0 (max)(current) 0 L-80 Grade 11.75'' 907-670-6636Unit Phone: 0 Kerry Garner Maximum Report By:Logging Engineers:Kerry Garner / Todd A. Wilson 0 0 0 0 0 Units* Casing Summary Lithology (%) 0 5294' pH 0.700 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type - Flow In (spm) 15.0 MBT - C-2 0 0 Ss Depth Time: - in C-5n seal on rams. Test BOP stack to 4500 psi. Begin picking up BHA #3. 0 Depth 5294' 5294' 0' Max @ ft Current Date: Avg to5294' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Gas Summary 0 0 0 (current) Minimum R. Klepzig / Bill Vigil ShClyst TuffGvlCoal cP 14.50''0.700 Footage 23.36 2658' 30.58 0 (ppb Eq) C-1 C-5i AK-AM-900261430 TIH PV 24 hr Max Weight 0 Hours C-3 YP 13 0 CementChtSilt C-4i C-4n (lb/100ft2) 9.50 000 60.0Baker / MXL - 1V SPUD 14.0 158' 5294'38 2816' Depth in / out 1 66 Mud Type Lst Type Average N/ABackground (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min 130.0 Chromatograph (ppm) 22.0 40.02816' 5294' WOB Hydril 2478' 100% Gas In Air=10,000 UnitsN/AConnection 0 Fluids = 0 bbls lost downhole Max gas = 0 units, Avg Gas = 0 units 5284' Condition 5-2-WT-M-E-2-FC-TD Bit # 2 2-1-WT-M-E-I-NO-BHA 8.9 14.50'' 10.30 Baker / MXL - 1V 9.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 11 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Tools API FL Depth 0 Chlorides 31-Mar-2013 12:00 AM Current Pump & Flow Data: 0 Max mg/l 21,000 Nipple up and down BOP stack and clean pits. Service mud pumps and test BOPs. Troubleshoot issue with hinge Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: 0 Cly Set AtSize 60.0 (max)(current) 0 L-80 Grade 11.75'' 907-670-6636Unit Phone: 0 Kerry Garner Maximum Report By:Logging Engineers:Kerry Garner / Todd A. Wilson 0 0 0 0 0 Units* Casing Summary Lithology (%) 0 5294' pH 0.942 0 0 0 Siltst SPP (psi) Gallons/stroke TFABit Type - Flow In (spm) 12.5 MBT - C-2 0 0 Ss Depth Time: - in C-5n 3500 psi for 30 minutes. Ream and wash from 5187' MD to 5195' MD. Drill cement from 5195' MD to 5294' MD, circulate 700 gpm. 0 Depth 5294' 5294' 0' Max @ ft Current Date: Avg to5294' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Gas Summary 0 0 0 (current) Minimum R. Klepzig / Bill Vigil ShClyst TuffGvlCoal cP 14.50''0.700 Footage 30.58 2478' 0 (ppb Eq) C-1 C-5i AK-AM-900261430 TIH PV 24 hr Max Weight 0 Hours C-3 YP 23 0 CementChtSilt C-4i C-4n (lb/100ft2) 11.20 000 130.0Baker / MXL - 1V SPUD 16.6 2816' 5294'12 5294' Depth in / out 2 90 Mud Type Lst Type Average N/ABackground (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Chromatograph (ppm) 40.0 5294' WOB Hydril 100% Gas In Air=10,000 UnitsN/AConnection 0 Fluids = 0 bbls lost downhole Max gas = 0 units, Avg Gas = 0 units Trip out of the hole to surface. 5284' Condition Clean out run Bit # 3 5-2-WT-M-E-2-FC-TD 13.6 10.625'' 10.30 Baker / GT-C1 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 12 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Tools API FL Depth 0 Chlorides 1-Apr-2013 12:00 AM Current Pump & Flow Data: 0 Max mg/l 20,000 Picked up BHA #3 with clean out assembly. Tripped into 5187' MD, tagged stingers. Run casing pressure test to Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Pick up BHA #4, shallow pulse test and load nukes. Trip into the hole to 2935' MD. Slip and cut drill line. Trip in the Density (ppg) out (sec/qt) Viscosity 3782 ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 13 Customer: Well: Area: Location: Rig: ODSN-04 2-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 11.03 Cor Solids 10.82 Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 5808 16.0 10.57 MaxMWD Summary 96% %Mud Type Enviromul 2.6 Ratio Mud Data Depth 5294'Hydril 10.30 WOB HDBS FXG65s TFA ConditionBit # 4 10.625''5294' Clean out run3 Max Gas = 150 units, Avg Gas = 85 units Drilled from 5314' MD to 6009' MD. strokes. Dumped 50 barrel spacer and 35 barrel interface. Drilled ahead to 5314' MD. Performed FIT to 12.5 ppg at the shoe. 100% Gas In Air=10,000 UnitsN/AConnection Comments 23Background Trip (max) Average N/A Mud (lb/bbl)ml/30min 2.27- Lst (lb/100ft2) 10.30 Type 15 Baker / GT-C1 5294' 3.97 0' 84/15 - 3682 C-4i C-4n 0 C-3 100 Chromatograph (ppm) 275 215 151 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 Drill Ahead PV cP Weight Siltst Casing Summary Lithology (%) 1.353 2692 10.625''0.942 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools Gamma and Resistivity API FL Depth 6000' Avg to5294' Yesterday's Depth: Current Depth: 24 Hour Progress: 211 SPP (psi) Max @ ft Current 5647'81.00.0 125.0 0 5294' 6000' 706' Lime TuffGvl C-5n Date: Time: 750 Alkal Coal hole to 5294' MD. Displace to 10.3 ppg MOBM. Pumped high vis spacer followed by MOBM at 7 bpm. Spacer returned at 6400 85 Fluids = 0 bbls lost downhole. 0 5975' 0 113 0150 0'Minimum Depth Maximum in Gallons/stroke 0 9521 29 46 0 110 15377 00 C-2 Gas Summary 907-670-6636Unit Phone: 43 Kerry Garner Set AtSize 60.0 L-80 Grade Depth in / outBit Type RPM 5294' - Report By: 11.75'' Logging Engineers:Kerry Garner / Todd A. Wilson (max)(current) Cly . . * 24 hr Recap:Troubleshoot GEO pump. Drilled from 6009' MD to 6054' MD. Troubleshoot pack off between CCU and RSC. Density (ppg) out (sec/qt) Viscosity 0 ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 14 Customer: Well: Area: Location: Rig: ODSN-04 3-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 10.88 Cor Solids 10.83 Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 6054 16.4 10.62 MaxMWD Summary 96% %Mud Type Enviromul 2.1 Ratio Mud Data Depth 5294'Hydril 10.30 WOB HDBS FXG65s TFA ConditionBit # 4 10.625''5294' Clean out run3 Fluids = 0 bbls lost downhole. Max Gas = 150 units, Avg Gas = 85 units 100% Gas In Air=10,000 UnitsN/AConnection Comments 0Background Trip (max) Average N/A Mud (lb/bbl)ml/30min 4.47- Lst (lb/100ft2) 10.30 Type 19 Baker / GT-C1 5294' 3.97 0' 84.3/15.7 - 3041 C-4i C-4n 0 C-3 100 Chromatograph (ppm) 94 48 83 Size Hours 49 Cement C-1 C-5i Sh AK-AM-900261430 Troubleshooting PV cP Weight Siltst Casing Summary Lithology (%) 1.353 31120 10.625''0.942 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools Gamma and Resistivity API FL Depth 6054' Avg to6000' Yesterday's Depth: Current Depth: 24 Hour Progress: 0 SPP (psi) Max @ ft Current 6054'1.80.0 79.6 28 6000' 6054' 54' Lime TuffGvl C-5n Date: Time: 0 Alkal Coal Miscellaneous rig service conducted. 68 51 6010' 0 44 0146 6000'Minimum Depth Maximum in Gallons/stroke 58 5501 13 16 17 41 3943 1409147 C-2 Gas Summary 907-670-6636Unit Phone: 30 Kerry Garner Set AtSize 60.0 L-80 Grade Depth in / outBit Type RPM 5294' - Report By: 11.75'' Logging Engineers:Kerry Garner / Todd A. Wilson (max)(current) Cly . . * 24 hr Recap:Continue to clear cutting line. Trip out the hole from 5215' MD to 5064' MD. Began reaming and staging up pumps Density (ppg) out (sec/qt) Viscosity 3888 ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 15 Customer: Well: Area: Location: Rig: ODSN-04 4-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 10.98 Cor Solids 10.87 Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 6054 16.4 10.62 MaxMWD Summary 96% %Mud Type Enviromul 2.4 Ratio Mud Data Depth 5294'Hydril 10.25 WOB HDBS FXG65s TFA ConditionBit # 4 10.625''5294' Clean out run3 Fluids = 0 bbls lost downhole. Max Gas = 304 units, Avg Gas = 139 units 100% Gas In Air=10,000 Units272Connection Comments 257Background Trip (max) Average N/A Mud (lb/bbl)ml/30min 4.40- Lst (lb/100ft2) 10.30 Type 18 Baker / GT-C1 5294' 3.97 0' 70/13 - 829 C-4i C-4n 0 C-3 100 Chromatograph (ppm) 591 201 238 Size Hours 28 Cement C-1 C-5i Sh AK-AM-900261430 Drill ahead PV cP Weight Siltst Casing Summary Lithology (%) 1.353 27127 10.625''0.942 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools Gamma and Resistivity API FL Depth 7220' Avg to6054' Yesterday's Depth: Current Depth: 24 Hour Progress: 213 SPP (psi) Max @ ft Current 6330'108.0105.0 189.0 0 6054' 7220' 1166' Lime TuffGvl C-5n Date: Time: 744 Alkal Coal to 700 gpm. Drill from 6054' MD to 6736' MD. Service top drive, flushed cuttings line with purple pill and continued drilling ahead. 139 18 7006' 13 50 12304 6054'Minimum Depth Maximum in Gallons/stroke 47 13086 12 24 14 78 33194 1289161 C-2 Gas Summary 907-670-6636Unit Phone: 17 Kerry Garner Set AtSize 60.0 L-80 Grade Depth in / outBit Type RPM 5294' - Report By: 11.75'' Logging Engineers:Kerry Garner / Todd A. Wilson (max)(current) Cly . . * 24 hr Recap: Max Gas = 416 units, Avg Gas = 185 units Fluids = 0 bbls lost downhole. Drilled from 7211' MD to 8160' MD. Slow pump rate at 7780' MD. Drilled from 8160' MD to 8729' MD. Service top Density (ppg) out (sec/qt) Viscosity 4327 ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 16 Customer: Well: Area: Location: Rig: ODSN-04 5-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 11.19 Cor Solids 11.03 Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 6054'16.4 10.67 MaxMWD Summary 96% %Mud Type Enviromul 2.4 Ratio Mud Data Depth 5294'Hydril 10.25 WOB HDBS FXG65s TFA ConditionBit # 4 10.625''5294' Clean out run3 Max Gas = 416 units, Avg Gas = 185 units Slow pump rate at 8729' MD. 100% Gas In Air=10,000 Units375Connection Comments 131Background Trip (max) Average N/A Mud (lb/bbl)ml/30min 4.14- Lst (lb/100ft2) 10.30 Type 20 Baker / GT-C1 5294' 3.97 0' 84/15 - 1672 C-4i C-4n 0 C-3 100 Chromatograph (ppm) 1483 576 560 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 Drill ahead PV cP Weight Siltst Casing Summary Lithology (%) 1.353 2589 10.625''0.942 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools Gamma and Resistivity API FL Depth 9150' Avg to7220' Yesterday's Depth: Current Depth: 24 Hour Progress: 209 SPP (psi) Max @ ft Current 8271'118.0113.0 252.0 0 7220' 9150' 1930' Lime TuffGvl C-5n Date: Time: 739 Alkal Coal drive. Drilled from 8729' MD to 8825' MD. Mud pump #2 pup off, troubleshoot issue and repair. Dril from 8825' MD to 9140' MD. 185 19 7584' 0 156 0416 7220'Minimum Depth Maximum in Gallons/stroke 0 17479 33 79 0 226 45230 048 C-2 Gas Summary 907-670-6636Unit Phone: 36 Kerry Garner Set AtSize 60.0 L-80 Grade Depth in / outBit Type RPM 5294' - Report By: 11.75'' Logging Engineers:Kerry Garner / Todd A. Wilson (max)(current) Cly . . * 24 hr Recap: Max Gas = 590 units, Avg Gas = 194 units Drilled from 9140' MD to 9848' MD. Packed off while reaming at 9848' MD, increased LCM additions. Worked pipe Fluids = 110 bbls lost downhole. Density (ppg) out (sec/qt) Viscosity 4438 ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 17 Customer: Well: Area: Location: Rig: ODSN-04 6-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 12.78 Cor Solids 11.15 Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 6054'16.4 10.85 MaxMWD Summary 96% %Mud Type Enviromul 2.6 Ratio Mud Data Depth 5294'Hydril 10.30 WOB HDBS FXG65s TFA ConditionBit # 4 10.625''5294' Clean out run3 Max Gas = 590 units, Avg Gas = 194 units Circulate and rack back one stand every 45 minutes. 100% Gas In Air=10,000 Units340Connection Comments 31Background Trip (max) Average N/A Mud (lb/bbl)ml/30min 4.92- Lst (lb/100ft2) 10.30 Type 23 Baker / GT-C1 5294' 3.97 0' 84.3/15.7 - 1648 C-4i C-4n 0 C-3 100 Chromatograph (ppm) 2302 880 924 Size Hours 5 Cement C-1 C-5i Sh AK-AM-900261430 CBU PV cP Weight Siltst Casing Summary Lithology (%) 1.353 2587 10.625''0.942 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools Gamma and Resistivity API FL Depth 10375' Avg to9150' Yesterday's Depth: Current Depth: 24 Hour Progress: 204 SPP (psi) Max @ ft Current 9500'156.00.0 243.0 0 9150' 10375' 1225' Lime TuffGvl C-5n Date: Time: 745 Alkal Coal and circulated bottoms up at 600 gpm. Drill from 9848' MD to 10346' MD. Service top drive. Drill from 10346' MD to 10375' MD TD 194 18 9839' 0 258 0590 10344'Minimum Depth Maximum in Gallons/stroke 5 19798 22 131 0 163 55584 0122 C-2 Gas Summary 907-670-6636Unit Phone: 60 Kerry Garner Set AtSize 60.0 L-80 Grade Depth in / outBit Type RPM 5294' - Report By: 11.75'' Logging Engineers:Kerry Garner / Todd A. Wilson (max)(current) Cly . . * 24 hr Recap:Circulate six bottoms up from 10375' MD to 10147' MD. Trip out of the hole from 10147' MD to 9600' MD. Log open Fluids = 60 bbls lost downhole. Density (ppg) out (sec/qt) Viscosity 2375 ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 18 Customer: Well: Area: Location: Rig: ODSN-04 7-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: 11.11 Cor Solids 11.02 Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 10375'16.4 10.84 MaxMWD Summary 96% %Mud Type Enviromul 2.4 Ratio Mud Data Depth 5294'Hydril 10.30 WOB HDBS FXG65s TFA ConditionBit # 4 10.625''5294' Clean out run3 Max Gas = 178 units, Avg Gas = 40 units to 325 gpm. Began loosing mud over the shakers. 100% Gas In Air=10,000 UnitsN/AConnection Comments 68Background Trip (max) Average 178 Mud (lb/bbl)ml/30min 4.40- Lst (lb/100ft2) 10.30 Type 20 Baker / GT-C1 5294' 3.97 0' 84.3/15.7 - 1041 C-4i C-4n 0 C-3 Chromatograph (ppm) 532 194 199 Size Hours 52 Cement C-1 C-5i Sh AK-AM-900261430 TOOH / Circulating PV cP Weight Siltst Casing Summary Lithology (%) 1.353 20132 10.625''0.942 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools API FL Depth Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 144 SPP (psi) Max @ ft Current ---- 2 10375' 10375' 0' Lime TuffGvl C-5n Date: Time: 526 Alkal Coal hole from 7823' MD to 5533' MD. Trip out from 5533' MD to 5215' MD. Service the rig. Circulate at 5215' MD and stage up pumps 40 25 0 55 0178 Minimum Depth Maximum in Gallons/stroke 79 4412 15 23 18 94 18606 85698 C-2 Gas Summary 907-670-6636Unit Phone: 3 Kerry Garner Set AtSize 60.0 L-80 Grade Depth in / outBit Type RPM 5294' - Report By: 11.75'' Logging Engineers:Kerry Garner / Todd A. Wilson (max)(current) Cly . . * 24 hr Recap:Back reamed from 5215' MD to 3505' MD and staged up pumps to 725 gpm. Serviced top drive and mud pump #2. Fluids = 0 bbls lost downhole. Density (ppg) out (sec/qt) Viscosity 1012 ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 19 Customer: Well: Area: Location: Rig: ODSN-04 8-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 10375'15.8 MaxMWD Summary 96% %Mud Type Enviromul 2.5 Ratio Mud Data Depth 5294'Hydril 10.25 10375' WOB HDBS FXG65s TFA Condition 0-0-NO-A-X-i-NO-TD Bit # 4 10.625''5294' Clean out run3 Max Gas = 21 units, Avg Gas = 2 units Began tripping in the hole. 100% Gas In Air=10,000 UnitsN/AConnection Comments 13Background Trip (max) Average N/A Mud (lb/bbl)ml/30min 4.92- Lst (lb/100ft2) 10.25 Type 22 Baker / GT-C1 5294' 3.97 0' 48.61 70/13.5 - 18.0 00 C-4i C-4n 0 C-3 Chromatograph (ppm) 0 0 0 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 TIH PV cP Weight Siltst Casing Summary Lithology (%) 1.353 14100 5081' 10.625''0.942 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools API FL Depth Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 91 SPP (psi) Max @ ft Current ---- 0 10375' 10375' 0' Lime TuffGvl C-5n Date: Time: 323 Alkal Coal Continued to back from 3505' MD to 1000' MD. Trip out of the hole from 1000' MD to 561' MD. Laid down BHA. Made up BHA #5. 2 0 0 0 021 Minimum Depth Maximum in Gallons/stroke 0 0 0 0 0 0 0 00 C-2 Gas Summary 907-670-6636Unit Phone: 0 Todd A. Wilson Set AtSize 60.0 L-80 Grade Depth in / outBit Type RPM 5294' - 160.0 Report By: 11.75'' Logging Engineers:Kerry Garner / Todd A. Wilson (max)(current) Cly . . * 24 hr Recap:Tripped into the hole from 3953' MD to 5283' MD. Slowed pump rates at 5300' MD. Pumped down radio frequency drive. Reamed from 6804' MD to 7125' MD at 800 gpm. Density (ppg) out (sec/qt) Viscosity 3576 ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 20 Customer: Well: Area: Location: Rig: ODSN-04 9-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 10375'16.4 MaxMWD Summary 96% %Mud Type Enviromul 2.6 Ratio Mud Data Depth 5294'Hydril 10.30 WOB Bull Nose TFA Condition Clean out run Bit # 5 8.125''10375' 0-0-NO-A-X-I-NO-TD4 500 psi pressure drop was noticed. Verified reamer was open. Reamed from 6735' MD to 6804' MD at 800 gpm. Serviced top Worked pipe and picked up to 6208' MD and staged pumps up to 800 gpm. Reamed from 6208' MD to 6735' MD where a sudden 100% Gas In Air=10,000 UnitsN/AConnection Comments 69Background Trip (max) Average N/A Mud (lb/bbl)ml/30min 4.66- Lst (lb/100ft2) 10.25 Type 20 HDBS FXG65s 5294' 48.61 5081' 84.3/15.7 18 00 C-4i C-4n 0 C-3 Chromatograph (ppm) 0 0 0 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 Reaming PV cP Weight Siltst Casing Summary Lithology (%) - 3473 10.625''1.353 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools API FL Depth Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 226 SPP (psi) Max @ ft Current ---- 0 10375' 10375' 0' Lime TuffGvl C-5n Date: Time: 806 Alkal Coal identifier device to open 11.75" reamer. Reamed from 5300' MD to 6328' MD pumping at 820 gpm. Packed off at 6328' MD. 52 Max Gas = 278 units, Avg Gas = 52 units Fluids = 178 bbls lost downhole. 0 0 0 0278 Minimum Depth Maximum in Gallons/stroke 0 0 0 0 0 0 0 00 C-2 Gas Summary 907-670-6636Unit Phone: 0 Charles Sinn Set AtSize 60.0 L-80 Grade Depth in / outBit Type RPM 10375' 160 Report By: 11.75'' Logging Engineers:Kerry Garner / Charles Sinn (max)(current) Cly . . * 24 hr Recap:Continued opening hole with 11.75" reamer from 7125' MD to 9083' MD pumping at 800 gpm. Serviced top drive. Density (ppg) out (sec/qt) Viscosity 4172 ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 21 Customer: Well: Area: Location: Rig: ODSN-04 10-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 10375'16.8 MaxMWD Summary 96% %Mud Type Enviromul 2.2 Ratio Mud Data Depth 5294'Hydril 10.25 WOB Bull Nose TFA Condition Clean out run Bit # 5 8.125''10375' 0-0-NO-A-X-I-NO-TD4 Fluids = 100 bbls lost downhole. Max Gas = 277 units, Avg Gas = 52 units 100% Gas In Air=10,000 UnitsN/AConnection Comments 63Background Trip (max) Average N/A Mud (lb/bbl)ml/30min 4.66- Lst (lb/100ft2) 10.20 Type 23 HDBS FXG65s 5294' 48.61 5081' 84.8/15.2 18 00 C-4i C-4n 0 C-3 Chromatograph (ppm) 0 0 0 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 Reaming PV cP Weight Siltst Casing Summary Lithology (%) - 3671 10.625''1.353 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools API FL Depth Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 226 SPP (psi) Max @ ft Current ---- 0 10375' 10375' 0' Lime TuffGvl C-5n Date: Time: 806 Alkal Coal Reamed from 9083' MD to 9369' MD pumping at 800 gpm. Steelseal additions started at 9200' MD. 52 0 0 0 0277 Minimum Depth Maximum in Gallons/stroke 0 0 0 0 0 0 0 00 C-2 Gas Summary 907-670-6636Unit Phone: 0 Charles Sinn Set AtSize 60.0 L-80 Grade Depth in / outBit Type RPM 10375' 160 Report By: 11.75'' Logging Engineers:Kerry Garner / Charles Sinn (max)(current) Cly . . * 24 hr Recap: Max Gas = 124 units, Avg Gas = 46 units Continued opening hole with 11.75" reamer from 9368' MD to 10375' MD pumping at 800 gpm. Deactivated reamer Fluids = 77 bbls lost downhole. Density (ppg) out (sec/qt) Viscosity 3562 ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 22 Customer: Well: Area: Location: Rig: ODSN-04 11-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 10375'16.2 MaxMWD Summary 96% %Mud Type Enviromul 2.2 Ratio Mud Data Depth 5294'Hydril 10.25 WOB Bull Nose TFA Condition Clean out run Bit # 5 8.125''10375' 0-0-NO-A-X-I-NO-TD4 Max Gas = 124 units, Avg Gas = 46 units top dive. Tripped out of the hole from 9463' MD to 5473' MD. Began tripping out of the hole. 100% Gas In Air=10,000 UnitsN/AConnection Comments 11Background Trip (max) Average N/A Mud (lb/bbl)ml/30min 2.46- Lst (lb/100ft2) 10.20 Type 22 HDBS FXG65s 5294' 48.61 5081' 87.3/12.7 18 00 C-4i C-4n 0 C-3 Chromatograph (ppm) 0 0 0 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 TOOH PV cP Weight Siltst Casing Summary Lithology (%) - 3884 10.625''1.353 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools API FL Depth Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: 226 SPP (psi) Max @ ft Current ---- 0 10375' 10375' 0' Lime TuffGvl C-5n Date: Time: 806 Alkal Coal with chip. Circulated seven bottoms up at 84000 strokes while pulling from 10375' MD to 9463' MD pumping at 775 gpm. Serviced 46 0 0 0 0124 Minimum Depth Maximum in Gallons/stroke 0 0 0 0 0 0 0 00 C-2 Gas Summary 907-670-6636Unit Phone: 0 Charles Sinn Set AtSize 60.0 L-80 Grade Depth in / outBit Type RPM 10375' 160 Report By: 11.75'' Logging Engineers:Kerry Garner / Charles Sinn (max)(current) Cly . . * 24 hr Recap: Max Gas = 62 units, Avg Gas = 9 units Reamed from 5473' MD to 5284' MD, lost approximately 40 barrels at the shoe. Reamed and washed in casing Fluids = 65 bbls lost downhole. Density (ppg) out (sec/qt) Viscosity ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 23 Customer: Well: Area: Location: Rig: ODSN-04 12-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 10375'17.3 MaxMWD Summary 96% %Mud Type Enviromul 2.2 Ratio Mud Data Depth 5294'Hydril 10.25 WOB Bull Nose TFA Condition Clean out run Bit # 5 8.125''10375' 0-0-NO-A-X-I-NO-TD4 Max Gas = 62 units, Avg Gas = 9 units up then down BOPs and changed RAMS. Tested BOPs and troubleshot RAMS with a good test. Rigged down test equipment. 100% Gas In Air=10,000 UnitsN/AConnection Comments N/ABackground Trip (max) Average N/A Mud (lb/bbl)ml/30min 3.17- Lst (lb/100ft2) 10.20 Type 14 HDBS FXG65s 5294' 48.61 5081' 87.8/12.2 18 00 C-4i C-4n 0 C-3 Chromatograph (ppm) 0 0 0 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 Test BOPs PV cP Weight Siltst Casing Summary Lithology (%) - 52102 10.625''1.353 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools API FL Depth Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Max @ ft Current ---- 0 10375' 10375' 0' Lime TuffGvl C-5n Date: Time: Alkal Coal from 5284' MD to 1199' MD pumping at 800 gpm. Tripped out of the hole from 1199' MD to surface. Laid down BHA #5. Nippled 9 0 0 0 062 Minimum Depth Maximum in Gallons/stroke 0 0 0 0 0 0 0 00 C-2 Gas Summary 907-670-6636Unit Phone: 0 Charles Sinn Set AtSize 60.0 L-80 Grade Depth in / outBit Type RPM 10375' 160 Report By: 11.75'' Logging Engineers:Kerry Garner / Charles Sinn (max)(current) Cly . . * 24 hr Recap: Max Gas = 0 units, Avg Gas = 0 units Finished testing BOPs and rigged down testing equipment. Rigged up TESCO equipment and ran in the hole with Fluids = 130 bbls lost downhole. Density (ppg) out (sec/qt) Viscosity ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 24 Customer: Well: Area: Location: Rig: ODSN-04 13-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 10375'17.3 MaxMWD Summary 96% %Mud Type Enviromul 2.2 Ratio Mud Data Depth 5294'Hydril 10.25 10375' WOB Bull Nose TFA Condition Clean out run Bit # 5 8.125''10375' 0-0-NO-A-X-I-NO-TD4 Max Gas = 0 units, Avg Gas = 0 units drill pipe to 6189' MD. Staged up pumps to 1.5 bpm. Ran in the hole to 6224' MD 100% Gas In Air=10,000 UnitsN/AConnection Comments N/ABackground Trip (max) Average N/A Mud (lb/bbl)ml/30min 3.17- Lst (lb/100ft2) 10.20 Type 14 HDBS FXG65s 5294' 48.61 5081' - 87.8/12.2 18 - 00 C-4i C-4n 0 C-3 Chromatograph (ppm) 0 0 0 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 Running Liner PV cP 40.0 Weight Siltst Casing Summary Lithology (%) - 52102 0' 10.625''1.353 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools API FL Depth Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Max @ ft Current ---- 0 10375' 10375' 0' Lime TuffGvl C-5n Date: Time: Alkal Coal 9-5/8" liner to 5229' MD. Staged up pumps to 1 bpm and circaulted bottoms up. Rigged down TESCO and ran in the hole with 5" 0 0 0 Minimum Depth 9.63'' Maximum in Gallons/stroke 0 0 0 0 0 0 0 00 C-2 Gas Summary 907-670-6636Unit Phone: 0 Charles Sinn Set AtSize 60.0 L-80 Grade L-80 Depth in / outBit Type RPM 10375' 160 - Report By: 11.75'' Logging Engineers:Kerry Garner / Charles Sinn (max)(current) Liner Cly . . * 24 hr Recap: 12.5 ppg cement, 36 barrel 15.8 ppg cement, 20 barrel seawater and chased with 9.8 ppg brine. Bumped plug at 4530 strokes. Fluids = 472 bbls lost downhole. Continued running in the hole with 9-5/8" liner from 6224' MD to 7552' MD. Circulated and stepped rate up to 1.5 Max Gas = 266 units, Avg Gas = 18 units Density (ppg) out (sec/qt) Viscosity ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 25 Customer: Well: Area: Location: Rig: ODSN-04 14-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 10375'18.3 MaxMWD Summary 96% %Mud Type Enviromul 2.3 Ratio Mud Data Depth 5294'Hydril 10.25 10375' WOB Bull Nose TFA Condition Clean out run Bit # 5 8.125''10375' 0-0-NO-A-X-I-NO-TD4 12.5 ppg cement, 36 barrel 15.8 ppg cement, 20 barrel seawater and chased with 9.8 ppg brine. Bumped plug at 4530 strokes. Circulated bottoms up and pressure tested cement lines to 4000 psi. Pumped 10 barrel seawatter, 60 barrel spacer, 52 barrel 100% Gas In Air=10,000 UnitsN/AConnection Comments 227Background Trip (max) Average N/A Mud (lb/bbl)ml/30min 2.91- Lst (lb/100ft2) 10.20 Type 16 HDBS FXG65s 5294' 48.61 5081' - 87.7/12.3 18 - 00 C-4i C-4n 0 C-3 Chromatograph (ppm) 0 0 0 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 Running Liner PV cP 40.0 Weight Siltst Casing Summary Lithology (%) - 51120 0' 10.625''1.353 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools API FL Depth Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Max @ ft Current ---- 0 10375' 10375' 0' Lime TuffGvl C-5n Date: Time: Alkal Coal bpm after 100 barrels pumped, 24 barrels were lost. Ran in the hole from 7552' MD to 10365' MD. Rigged up cement equipment. 18 Fluids = 472 bbls lost downhole. 0 0 0 0266 Minimum Depth 9.63'' Maximum in Gallons/stroke 0 0 0 0 0 0 0 00 C-2 Gas Summary 907-670-6636Unit Phone: 0 Charles Sinn Set AtSize 60.0 L-80 Grade L-80 Depth in / outBit Type RPM 10375' 160 - Report By: 11.75'' Logging Engineers:Kerry Garner / Charles Sinn (max)(current) Liner Cly . . * 24 hr Recap: Nipple up then down BOP and change out RAMS. Fluids = 0 bbls lost downhole. Rigged down cement equipment and displaced MOBM in casing with 9.8 ppg brine at 6 bpm. Brine returned at Max Gas = 0 units, Avg Gas = 0 units Density (ppg) out (sec/qt) Viscosity ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 26 Customer: Well: Area: Location: Rig: ODSN-04 15-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 10375'17.8 MaxMWD Summary 96% %Mud Type Enviromul 2.2 Ratio Mud Data Depth 5294'Hydril 10.25 10375' WOB Bull Nose TFA Condition Clean out run Bit # 5 8.125''10375' 0-0-NO-A-X-I-NO-TD4 Nipple up then down BOP and change out RAMS. Pumped CONDET sweeps and fresh brine. Tripped out from 5706' MD to surface. Tested casing to 3500 psi for 30 minutes. 10375' 100% Gas In Air=10,000 UnitsN/AConnection Comments N/ABackground Trip (max) Average N/A Mud (lb/bbl)ml/30min 2.84- Lst (lb/100ft2) 10.25 Type 19 HDBS FXG65s 5294' 48.61 5081' - 71/10.5 18 - 00 C-4i C-4n 0 C-3 Chromatograph (ppm) 0 0 0 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 Change out rams PV cP 40.0 Weight Siltst Casing Summary Lithology (%) - 50145 0' 10.625''1.353 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools API FL Depth Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Max @ ft Current ---- 0 10375' 10375' 0' Lime TuffGvl C-5n Date: Time: Alkal Coal 4600 strokes. Tripped out from 5105' MD to surface. Laid down tools. Tripped in the hole with Johnny Whacker to 5706' MD. Fluids = 0 bbls lost downhole. 0 0 0 Minimum Depth 9.625'' Maximum in Gallons/stroke 0 0 0 0 0 0 0 00 C-2 Gas Summary 907-670-6636Unit Phone: 0 Charles Sinn Set AtSize 60.0 L-80 Grade L-80 Depth in / outBit Type RPM 10375' 160 - Report By: 11.75'' Logging Engineers:Kerry Garner / Charles Sinn (max)(current) Liner Cly . . * 24 hr Recap: Fluids = 0 bbls lost downhole. Nipple up then down BOPs. Test BOPs to 4500 psi. Ran in the hole with Johnny Whacker on 2-7/8" to 6463' MD. Density (ppg) out (sec/qt) Viscosity ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 27 Customer: Well: Area: Location: Rig: ODSN-04 16-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: MaxMWD Summary 96% %Mud Type Ratio Mud Data Depth 5294'Hydril 10375' WOB Bull Nose TFA Condition Clean out run Bit # 5 8.125''10375' 0-0-NO-A-X-I-NO-TD4 Max Gas = 0 units, Avg Gas = 0 units 160' MD with tubing. 10375' 100% Gas In Air=10,000 UnitsN/AConnection Comments N/ABackground Trip (max) Average N/A Mud (lb/bbl)ml/30min Lst (lb/100ft2) Type HDBS FXG65s 5294' 48.61 5081' - 18 - 00 C-4i C-4n 0 C-3 Chromatograph (ppm) 0 0 0 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 RIH w/ tubing PV cP 40.0 Weight Siltst Casing Summary Lithology (%) -0' 10.625''1.353 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools API FL Depth Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Max @ ft Current ---- 0 10375' 10375' 0' Lime TuffGvl C-5n Date: Time: Alkal Coal Flushed pipe and circulated at 350 gpm. Tripped out of the hole to surface. Rigged uo to run 2-7/8" tubing. Ran in the the hole to 0 0 0 Minimum Depth 9.625'' Maximum in Gallons/stroke 0 0 0 0 0 0 0 00 C-2 Gas Summary 907-670-6636Unit Phone: 0 Charles Sinn Set AtSize 60.0 L-80 Grade L-80 Depth in / outBit Type RPM 10375' 160 - Report By: 11.75'' Logging Engineers:Kerry Garner / Charles Sinn (max)(current) Liner Cly . . * 24 hr Recap: Fluids = 0 bbls lost downhole. Cut and slip drill line. Prepare to move the rig to ODSN-02. Density (ppg) out (sec/qt) Viscosity ROP ROP (ft/hr) R. Klepzig / Bill Vigil 24 hr Max Morning Report Report # 28 Customer: Well: Area: Location: Rig: ODSN-04 17-Apr-2013 12:00 AM Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Cor Solids Avg Min YP 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: MaxMWD Summary 96% %Mud Type Ratio Mud Data Depth 5294'Hydril 10375' WOB Bull Nose TFA Condition Clean out run Bit # 5 8.125''10375' 0-0-NO-A-X-I-NO-TD4 10375' 100% Gas In Air=10,000 UnitsN/AConnection Comments N/ABackground Trip (max) Average N/A Mud (lb/bbl)ml/30min Lst (lb/100ft2) Type HDBS FXG65s 5294' 48.61 5081' - 18 - 00 C-4i C-4n 0 C-3 Chromatograph (ppm) 0 0 0 Size Hours 0 Cement C-1 C-5i Sh AK-AM-900261430 Prepare for rig move PV cP 40.0 Weight Siltst Casing Summary Lithology (%) -0' 10.625''1.353 Footage (current) Units* ClystSsChtSilt Flow In (gpm) Flow In (spm) Oil / Water ECD (ppg)Tools API FL Depth Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: SPP (psi) Max @ ft Current ---- 0 10375' 10375' 0' Lime TuffGvl C-5n Date: Time: Alkal Coal Max Gas = 0 units, Avg Gas = 0 units 0 0 0 Minimum Depth 9.625'' Maximum in Gallons/stroke 0 0 0 0 0 0 0 00 C-2 Gas Summary 907-670-6636Unit Phone: 0 Charles Sinn Set AtSize 60.0 L-80 Grade L-80 Depth in / outBit Type RPM 10375' 160 - Report By: 11.75'' Logging Engineers:Kerry Garner / Charles Sinn (max)(current) Liner Cly . . * Pick up 5" drill pipe from 504' to 10237' at 300 gpm. Pressure test casing shoe to 3500 psi for 5 minutes. Begin drilling Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner Depth in / out Coal Clyst Bit Type RPM 40.0 Weight Size Hours 907-670-6636 Unit Phone: 0 Todd A. Wilson Set At Size 60.0 L-80 Grade 0 C-2 Gas Summary 0 0 0 0 0 0 0 0 Minimum Depth 9.625'' Maximum in (current) 00 0 Pick up 5" drill pipe to 3520'. Pump 9.3 ppg dry job and trip out of the hole from 3500' to surface. Pick up new BHA to 504'. 136 SPP (psi) Flow In (spm) 10375' 10375' 0' Yesterday's Depth: Current Depth: 24 Hour Progress: Depth to Units* Date: Alkal Lime Tuff Gvl L-80 Gallons/stroke Ss Cht Silt Siltst Cly Casing Summary Lithology (%) 0.942 16 59 Footage Sh AK-AM-900261430 Displacing brine PV cP Flow In (gpm) Oil / Water Tools C-1 C-5i Chromatograph (ppm) C-3 C-5n 0 Cement 00 C-4i C-4n 0 Comments Lst (lb/100ft 2) 10.20 Type 18 N/A Mud (lb/bbl) ml/30min 1.50 (max) Average 10 Background Trip Connection 0 0 0 0 Fluids = 0 bbls lost downhole. Max Gas = 0 units, Avg Gas = 0 units cement on landing collar at 10237' and begin displacement of 9.8 ppg brine with 10.2 ppg LSND mud. 10375' 100% Gas In Air =10,000 Units N/A Bit # 6 8.5" 10375' 5294' Hydril 10.20 WOB Baker Hughes / VM-3 TFA Condition MWD Summary 96% %Mud Type LSND 4.4 Ratio Mud Data Depth 2.09/89.0 6.51 @ Current Pump & Flow Data: Nabors 19AC Report For: 10375'6.8 Cor Solids Avg Min YP Max ECD (ppg) API FL Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Rig Activity: Max @ ft Current Morning Report Report # 29 Customer: Well: Area: Location: Rig: ODSN-04 13-Aug-2013 12:00 AM Time: 1686 ROP ROP (ft/hr) R. Klepzig / T. Deranger 24 hr Max 508 Avg 24 hr Recap: Density (ppg) out (sec/qt) Viscosity . . * 24 hr Recap: Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 43 0 Bit Type Maximum Cly 708 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 0 0 1 0 105 9.625'' 697 196 Units* Casing Summary Lithology (%) cP 20 62 SPP (psi) Gallons/stroke TFA L-80 MBT 0' pH 0.942 10376' 0.0 C-2 26 in 12 10388'Minimum Depth C-5n Drilled out cement shoe track and rathole from 10,237' to 10,375'. Displaced 9.8 brine with 10.2 ppg LSND mud while drilling. 14 26 units at 10,376'. 10375' 10395' 20' Max @ ft Current 10376'49.3 Date: Time: Avg to 0' Yesterday's Depth: Current Depth: 24 Hour Progress: 84.0 Flow In (gpm) Flow In (spm) Depth Gas Summary 0 9 0 (current) R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Footage Siltst 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Picking up BHA PV 24 hr Max 40.0 Weight 3 Hours C-3 0 0 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 10.40 000 LSND 3.8 10395'25 Depth in / out Mud Type Lst Type Average 01Background (max) Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) 10375' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 18 Fluids = 0 bbls lost downhole. Max Gas = 26 units, Avg Gas = 14 units BHA. Prepared Geo tap tool, and began pre job for loading nukes. While drilling average gas was 14 units and max gas was mud weight. Pumped 35 bbls 13.3 ppg dry job and triped out of hole from 10,358' to 504'. Laid down BHA and began picking up new Drilled from 10,375' to 10,395', circulated 1.5 bottoms up at 700 gpm. Performed formation integrity test to a 13.5 ppg equivalent 10375' 5294' Bit # 6 6.8 8.5" 10.30 Baker Hughes / VM-3 10.30 Size 1.0 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Morning Report Report # 30 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition 14-Aug-2013 12:00 AM Current Pump & Flow Data: 2920 Max 0 mg/l 42000.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 42000.00 0 15-Aug-2013 12:00 AM Current Pump & Flow Data: 3863 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 31 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.24 Nabors 19AC Report For: Bit # 6 7.4 8.5" 10.25 Baker Hughes / VM-3 10.25 Size 10.3 Fluids = 0 bbls lost downhole. Max Gas = 32 units, Avg Gas = 19 units Currently drilling ahead. While drilling average gas was 19 units and max gas was 32 units at 10,494'. Washed reamer down from 10,224' to 10,395'. Rotary drilled from 10,395' to 10,548' at 700 gallons per min. Tripped in the hole to 3538'. Filled pipe break in Geo-pilot per directional driller. Tripped in the hole from 3538' to 10,224'. 10375' 5294' 100% Gas In Air =10,000 Units 23 Connection 17 Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 9.95 12.85 Avg Min Comments RPM ECD (ppg) ml/30min 15 Background (max) Trip Average 39 Mud Type Lst 10 Type LSND 3.6 10475'27 Depth in / out YP (lb/100ft 2) 10.50 0590 161.6 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 70 0 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Drilling Ahead PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 5 0 (current) Avg to 10395' Yesterday's Depth: Current Depth: 24 Hour Progress: 86.7 Flow In (gpm) Flow In (spm) Depth 10395' 10498' 217' Max @ ft Current 10478'6.2 Date: Time: Picked up BHA number 7 to 220' and tested. Cut drilling line, loaded nukes and continued to pick up BHA to 688'. 19 Max trip gas was 39 units and there was a connection gas of 23 units. in 2 10398'Minimum Depth C-5n 10494' 55.7 C-2 32 SPP (psi) Gallons/stroke TFA L-80 MBT 10498' pH 0.942 9.625'' 693 195 Units* Casing Summary Lithology (%) cP 19 61 20 0 0 4 9 196 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 1484 Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 50 9 . . * 24 hr Recap: Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 219 0 Bit Type Maximum Cly 4220 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 51 0 18 0 1049 9.625'' 714 201 Units* Casing Summary Lithology (%) cP 18 53 20 SPP (psi) Gallons/stroke TFA L-80 MBT 11443' pH 0.942 10615' 31.6 C-2 55 in 8 10733'Minimum Depth C-5n Rotary drilled from 10,548' to 10,573'. Cycled pumps to activate reamer and cut reamer ledge from 10,557' to 10,562'. 21 10498' 11443' 945' Max @ ft Current 10765'58.5 Date: Time: Avg to 10498' Yesterday's Depth: Current Depth: 24 Hour Progress: 119.8 Flow In (gpm) Flow In (spm) Depth Gas Summary 0 31 0 (current) R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Footage Siltst 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Drilling Ahead PV 24 hr Max 40.0 Weight 46 Hours C-3 60 9 0 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 9.90 060 LSND 3.8 11386'32 Depth in / out Mud Type Lst 20 Type Average N/A 12 Background (max) Trip 12.70 13.01 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 100% Gas In Air =10,000 Units 47 Connection 83 Fluids = 0 bbls lost downhole. Max Gas = 55 units, Avg Gas = 21 units Max connection gas was 47 units, with an average of 25 units. While drilling average gas was 21 units and max gas was 55 units at 10,615'. Picked up 230K against shoe at 10,546'. Rotary drilled from 10,573' to 11,441'. Currently drilling ahead. 10375' 5294' Bit # 6 7.4 8.5" 10.20 Baker Hughes / VM-3 10.20 Size 5.0 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.32 Nabors 19AC Report For: Morning Report Report # 32 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition 16-Aug-2013 12:00 AM Current Pump & Flow Data: 4012 Max 1 mg/l 43000.00 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 39000 1 17-Aug-2013 12:00 AM Current Pump & Flow Data: 4395 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 33 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.23 Nabors 19AC Report For: Bit # 6 8.1 8.5" 10.20 Baker Hughes / VM-3 10.20 Size 9.0 Fluids = 0 bbls lost downhole. Max Gas = 170 units, Avg Gas = 16 units While drilling average gas was 16 units and max gas was 170 units at 11,484'. Serviced top drive, and changed out decoder. Drilling ahead at report time. Drilled ahead from11,447' to 11,487' and experienced high torque. Treated mud with lubes, rotary drilled from 11,487' to 11,620'. 10375' 5294' 100% Gas In Air =10,000 Units 40 Connection 16 Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 12.75 13.01 Avg Min Comments RPM ECD (ppg) ml/30min 8Background (max) Trip Average N/A Mud Type Lst 10 Type LSND 3.2 11705'35 Depth in / out YP (lb/100ft 2) 9.90 040 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 22 Hours C-3 90 0 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Drilling Ahead PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 6 0 (current) Avg to 10498' Yesterday's Depth: Current Depth: 24 Hour Progress: 108.2 Flow In (gpm) Flow In (spm) Depth 11443' 11820' 377' Max @ ft Current 11543'51.3 Date: Time: Rotary drilled to 11,447', developed leak on stand pipe union. Replaced gasket on standpipe and tested to 4500 psi. 16 Max connection gas was 40 units, with an average of 18 units. in 8 11770'Minimum Depth C-5n 11484' 74.3 C-2 170 SPP (psi) Gallons/stroke TFA L-80 MBT 11820' pH 0.942 9.625'' 700 197 Units* Casing Summary Lithology (%) cP 22 58 0 9 4 614 227 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 967 Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 44 9 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 40000 1 18-Aug-2013 12:00 AM Current Pump & Flow Data: 4344 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 34 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.27 Nabors 19AC Report For: Bit # 6 8.1 8.5" 10.20 Baker Hughes / VM-3 10.20 Size 10.0 Fluids = 0 bbls lost downhole. Max Gas = 80 units, Avg Gas = 16 units to 12,169'. Stopped rotation of drill string from 12,222 to 12,190'. Set tool face position per GEO-TAP at 12,221. Performing Performed MAD pass from 12,190' to 12,168' at 600 gallons per minute. MWD reset depth, and repeated MAD pass from 12,177' union, serviced top drive. Drilled ahead from 12,121' to 12,285'. Circulated one bottoms up while pulling up to 12,190'. 10375' 5294' 100% Gas In Air =10,000 Units 29 Connection 129 Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 12.05 13.00 Avg Min Comments RPM ECD (ppg) ml/30min 15 Background (max) Trip Average N/A Mud Type Lst 40 Type LSND 3.2 12285'41 Depth in / out YP (lb/100ft 2) 10.00 050 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 35 Hours C-3 60 16 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Testing GeoTap PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 45 2 (current) Avg to 10498' Yesterday's Depth: Current Depth: 24 Hour Progress: 126.1 Flow In (gpm) Flow In (spm) Depth 11820' 12286' 466' Max @ ft Current 12115'52.5 Date: Time: Rotary drilled from 11,810' to 11,965', closed reamer and drilled 8.5" hole from 11,695' to 12,121'. Replaced gasket on standpipe 16 GEO-TAP at report time. While drilling average gas was 16 units and max gas was 80 units at 12,099'. Max connection gas was 29 units, with an average of 20 units. in 6 12072'Minimum Depth C-5n 12099' 49.6 C-2 80 SPP (psi) Gallons/stroke TFA L-80 MBT 12286' pH 0.942 9.625'' 611 172 Units* Casing Summary Lithology (%) cP 22 56 0 14 0 846 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 7228 Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 297 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 44000 1 19-Aug-2013 12:00 AM Current Pump & Flow Data: 4093 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 35 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.32 Nabors 19AC Report For: Bit # 6 7.9 8.5" 10.20 Baker Hughes / VM-3 10.20 Size 10.0 Fluids = 115 bbls lost downhole. Max Gas = 123 units, Avg Gas = 8 units some pack off from 11,910' to 12,000. Reamed/washed down from 12,000 to 12,285'. Packed off at 12,260', 35 bbl losses. to open reamer but unable. Circulated from 11,950' to 11,910', began packing off and observed 23 bbls mud loss. Circulated with performed work from 12,205' to 12,106'. Open hole GEO-TAP at 12,212'. Tripped out of the hole from 12,212' to 11,950', attempted 10375' 5294' 100% Gas In Air =10,000 Units 30 Connection 215 Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 11.63 13.00 Avg Min Comments RPM ECD (ppg) ml/30min 13 Background (max) Trip Average N/A Mud Type Lst Type LSND 3.2 12285'39 Depth in / out YP (lb/100ft 2) 10.60 020 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 14 Hours C-3 29 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Rig maintenance PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 74 18 (current) Avg to 12286' Yesterday's Depth: Current Depth: 24 Hour Progress: 72.3 Flow In (gpm) Flow In (spm) Depth 12286' 12286' 0' Max @ ft Current 12312'61.7 Date: Time: Performed GEO-TAP work from 12,222 to 12,098'. Replaced gasket on mud pump number 1. Oriented GEO-TAP tool and 8 Circulated and started MWD/LWD tools, serviced top drive. Testing MWD equipment at report time. Max connection gas was 30 units, with an average of 29 units. While circulating average gas was 8 units and max gas was 123 units at 11,953'. in 0 12263'Minimum Depth C-5n 11953' 0.0 C-2 123 SPP (psi) Gallons/stroke TFA L-80 MBT 12286' pH 0.942 9.625'' 668 188 Units* Casing Summary Lithology (%) cP 25 61 0 6 0 398 59 907-670-6636 Unit Phone: 21 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 11120 Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 489 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 42000 0 20-Aug-2013 12:00 AM Current Pump & Flow Data: 3947 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 36 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.33 Nabors 19AC Report For: Bit # 6 8.5 8.5" 10.20 Baker Hughes / VM-3 10.20 Size 11.5 Fluids = 0 bbls lost downhole. Max Gas = 35 units, Avg Gas = 9 units While drilling average gas was 9 units and max gas was 35 units at 12369'. from 12,746' to 12,749' encounter hard spot. Drilling hard spot at report time. swab on number 2 mud pump. Drilled ahead from 12,710' to 12,746', GEO-PILOT not working properly. Drilled 10375' 5294' 100% Gas In Air =10,000 Units 35 Connection 69 Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 12.61 13.00 Avg Min Comments RPM ECD (ppg) ml/30min 8Background (max) Trip Average N/A Mud Type Lst 5 Type LSND 3.9 12747'41 Depth in / out YP (lb/100ft 2) 10.30 010 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 10 Hours C-3 95 13 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Drilling ahead PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 43 11 (current) Avg to 10498' Yesterday's Depth: Current Depth: 24 Hour Progress: 95.0 Flow In (gpm) Flow In (spm) Depth 12286' 12749' 463' Max @ ft Current 12575'53.3 Date: Time: Drilled ahead from 12,285' to 12,607', power failure on rig. Started generators and drilled from 12,607' to 12,710'. Changed 9 Max connection gas was 35 units, with an average of 14 units. in 5 12642'Minimum Depth C-5n 12369' 0.0 C-2 35 SPP (psi) Gallons/stroke TFA L-80 MBT 12749' pH 0.942 9.625'' 636 179 Units* Casing Summary Lithology (%) cP 23 59 0 5 0 307 38 907-670-6636 Unit Phone: 16 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 3212 Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 121 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 44000 0 21-Aug-2013 12:00 AM Current Pump & Flow Data: 15 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 37 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.24 Nabors 19AC Report For: Bit # 6 8.9 8.5" 10.30 Baker Hughes / VM-3 10.30 Size 12.0 Fluids = 0 bbls lost downhole. Max Gas = 14 Avg Gas = 4 or lagged gas. 12095'. Tripping out at report time. While circulating average gas was 4 units and max gas was 14 units. No connection Tripped out from 12749' to 3918'. Pumped 72 bbls 17.0 ppg kill weight mud at 12749', pump 20 bbls 17.0 ppg kill weight mud at 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 12.86 13.03 Avg Min Comments RPM ECD (ppg) ml/30min N/A Background (max) Trip Average N/A Mud Type Lst Type LSND 3.4 12749'37 Depth in / out YP (lb/100ft 2) 10.50 000 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Tripping out PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to 10498' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 12749' 12749' 0' Max @ ft Current N/A N/A Date: Time: Back reamed from 12747' to 12468' at 680 gpm. Drilled from 12747' to 12749' at 650 gpm, pumped 2nd Carbide pill. 4 in 0 NA Minimum Depth C-5n NA N/A C-2 14 SPP (psi) Gallons/stroke TFA L-80 MBT 12749' pH 0.942 9.625'' N/A N/A Units* Casing Summary Lithology (%) cP 19 56 0 0 0 0 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 0 Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 0 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 45000 0 22-Aug-2013 12:00 AM Current Pump & Flow Data: 10 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 38 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 18.06 Nabors 19AC Report For: Bit # 6 9.9 8.5" 1.00 Baker Hughes / VM-3 11.00 Size 12.0 Fluids = 0 bbls lost downhole Max Gas = N/A Avg Gas = N/A No gas samples collected. Tripped out of hole to surface, and laid down BHA. Serviced rig, and rigged up to test BOPs. Testing BOPs at report time. Tripped out to 2019', pumped 178 bbls 17.0 ppg kill weight mud at 6 barrels per minute. Highest returns were 15.7 - 16.0 ppg. 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 14.07 16.90 Avg Min Comments RPM ECD (ppg) ml/30min N/A Background (max) Trip Average N/A Mud Type Lst Type LSND 3.5 12749'42 Depth in / out YP (lb/100ft 2) 10.00 000 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Testing BOP PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to 10498' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 12749' 12749' 0' Max @ ft Current N/A N/A Date: Time: Tripped out of hole from 4013' to 2493'. Pumped 50 bbls 17.0 ppg spacer, and chased with 35 bbls 17.0 ppg kill weight mud. N/A in N/A Minimum Depth C-5n N/A C-2 N/A SPP (psi) Gallons/stroke TFA L-80 MBT 12749' pH 0.942 9.625'' N/A N/A Units* Casing Summary Lithology (%) cP 22 71 0 0 0 0 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 0 Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 0 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 45000 0 23-Aug-2013 12:00 AM Current Pump & Flow Data: 1180 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 39 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 14.42 Nabors 19AC Report For: Bit # 6 9.8 8.5" 11.00 Baker Hughes / VM-3 11.00 Size 12.0 Fluids = 0 bbls lost downhole Max Gas = 6 Avg Gas = 2 Tripped in hole from 6490' to 10365'. Displacing hole to 11.0 ppg LSND mud at 250 gpm at report time. 250 gpm. Tripped in hole from 3025' to 6490'. Displaced hole with 11.0 ppg LSND mud at 250 gpm. hole from surface to 2974'. Cut 45' of drill line. Tripped in hole from 2974' to 3025'. Displaced hole with 11.0 ppg LSND mud at 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 13.05 13.75 Avg Min Comments RPM ECD (ppg) ml/30min 2Background (max) Trip Average N/A Mud Type Lst Type LSND 2.6 12749'35 Depth in / out YP (lb/100ft 2) 10.30 000 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Displacing at the shoe PV Footage Siltst J. Polya / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to 10498' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 12749' 12749' 0' Max @ ft Current N/A N/A Date: Time: Tested BOPs to 4500 psi, and rigged down test equipment. Picked up BHA #8, and shallow pulse tested at 450 gpm. Tripped in 2 While circulating average gas was 2 units and max gas was 6 units. No connection or lagged gas. in 0 N/A Minimum Depth C-5n N/A N/A C-2 6 SPP (psi) Gallons/stroke TFA L-80 MBT 12749' pH 0.942 9.625'' 252 71 Units* Casing Summary Lithology (%) cP 20 55 0 0 0 0 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 0 Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 0 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 43000 1 24-Aug-2013 12:00 AM Current Pump & Flow Data: 22 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 40 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.66 Nabors 19AC Report For: Bit # 6 6.9 8.5" 10.20 Baker Hughes / VM-3 10.20 Size 10.0 Fluids = 150 bbls lost downhole Max Gas = 98 Avg Gas = 8 Waiting for returns at time of report. Added lost circulation material as pulling to shoe. Pumped high viscosity weighted sweep at the shoe. Drilled ahead from 12749' to 12986', target depth. Circulated at target depth, began taking losses 0.5 - 1.0 bbl/min. 10375' 5294' 100% Gas In Air =10,000 Units 37 Connection 0 Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 12.78 13.02 Avg Min Comments RPM ECD (ppg) ml/30min 18 Background (max) Trip Average 98 Mud Type Lst 60 Type LSND 3.6 12986'28 Depth in / out YP (lb/100ft 2) 10.30 030 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 15 Hours C-3 30 0 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Circulating bottoms up PV Footage Siltst J. Polya / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to 10498' Yesterday's Depth: Current Depth: 24 Hour Progress: 70.8 Flow In (gpm) Flow In (spm) Depth 12749' 12986' 237' Max @ ft Current 12870'52.8 Date: Time: Circulated 3 bottoms up at the shoe. Tripped in hole to 12749'. Began reducing active system mud weight to 10.2 ppg. 8 While drilling average gas was 8 units, max gas was trip gas of 98 units. Max connection gas was 37 units, with an average of 27 units. in 2 12895'Minimum Depth C-5n N/A N/A C-2 98 SPP (psi) Gallons/stroke TFA L-80 MBT 12986' pH 0.942 9.625'' 604 170 Units* Casing Summary Lithology (%) cP 16 55 10 0 7 4 385 190 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 0 Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 0 10 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 42000 0 25-Aug-2013 12:00 AM Current Pump & Flow Data: 9 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 41 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.70 Nabors 19AC Report For: Bit # 6 13.6 8.5" 12.00 Baker Hughes / VM-3 12.00 Size 9.0 Fluids = 0 bbls lost downhole Max Gas = 1142 Avg Gas = 77 monitored well 15 minutes for static losses. Continuing to trip out at report time. Pumped 50 bbl spacer and displaced hole to 12.0 ppg LSND mud. Tripped out of hole from 12986' to 10293', and circulated. Pumped a 50 bbl high viscosity weighted sweep, two bottoms up, and was 1200 strokes late. 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 12.83 13.17 Avg Min Comments RPM ECD (ppg) ml/30min 32 Background (max) Trip Average 1142 Mud Type Lst Type LSND 3.8 12986'33 Depth in / out YP (lb/100ft 2) 10.50 000 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 $6,692.56 $263,152.60 Tripping out PV Footage Siltst J. Polya / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to 10498' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 12986' 12986' 0' Max @ ft Current N/A N/A Date: Time: Pumped high viscosity sweep at 10293', no significant increase in cuttings. Tripped in hole from 10293' to 12986' and 77 While circulating average gas was 77 units, max gas was trip gas of 1142 units. No connection or lagged gas. in 0 N/A Minimum Depth C-5n N/A N/A C-2 1142 SPP (psi) Gallons/stroke TFA L-80 MBT 12986' pH 0.942 9.625'' N/A N/A Units* Casing Summary Lithology (%) cP 27 62 0 0 0 0 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 0 Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 0 0 . . * 24 hr Recap: Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 0 0 Bit Type Maximum Cly 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 0 0 0 0 0 9.625'' NA NA Units* Casing Summary Lithology (%) cP 23 51 SPP (psi) Gallons/stroke TFA L-80 MBT 12986' pH 0.942 N/A N/A C-2 52 in 0 N/A Minimum Depth C-5n Tripped out of hole from 7631' to 5064'. Pumped 35 bbl high viscosity spacer. Tripped out to 4589' and displaced to 13.9 ppg kill 5 12986' 12986' 0' Max @ ft Current N/A N/A Date: Time: Avg to 10498' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth Gas Summary 0 0 0 (current) J. Polya / J. Haberther Sh Clyst Tuff Gvl Coal Footage Siltst 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Running 7" casing PV 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 10.50 000 LSND 3.6 12986'33 Depth in / out Mud Type Lst Type Average N/A 0Background (max) Trip N/A 12.91 Avg Min Comments RPM ECD (ppg) ml/30min Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 Fluids = 0 bbls lost downhole Max Gas = 52 Avg Gas = 5 While circulating average gas was 5 units and max gas was 52 units. No connection, trip, or lagged gas. Rigged up to run 7" 26# L-80 casing. Running in hole with casing at time of report. weight mud and monitored well. Tripped out to surface and laid down BHA. Changed out RAMs to 7' and tested BOPs. 10375' 5294' Bit # 6 6.8 8.5" 10.20 Baker Hughes / VM-3 10.20 Size 8.5 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 42 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition 26-Aug-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 mg/l 44000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 42000 0 27-Aug-2013 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 43 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: N/A Nabors 19AC Report For: Bit # 6 7.4 8.5" 10.20 Baker Hughes / VM-3 10.20 Size 8.0 Fluids = 0 bbls lost downhole Max Gas = 0 Avg Gas = 0 No gas samples collected. Circulating and pressure testing cement lines at 4000 psi during time of report. 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Gamma, Res. PWD, Geo-Tap API FL Chromatograph (ppm) 10375' WOB Hydril N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average N/A Mud Type Lst Type LSND 3.6 12986'35 Depth in / out YP (lb/100ft 2) 10.20 000 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Rigging up for cement PV Footage Siltst J. Polya / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to 10498' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 12986' 12986' 0' Max @ ft Current N/A N/A Date: Time: Ran in hole with 7" casing from 771' to 12962'. Rigged down TESCO equipment. Rigged up cement equipment. 0 in 0 N/A Minimum Depth C-5n N/A N/A C-2 0 SPP (psi) Gallons/stroke TFA L-80 MBT 12986' pH 0.942 9.625'' NA NA Units* Casing Summary Lithology (%) cP 19 50 0 0 0 0 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 0 Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 0 0 . . * 24 hr Recap: Report By: 11.75'' Logging Engineers: Todd A. Wilson/Makenzie Jorgensen (max) (current) Liner 0 0 Bit Type Maximum Cly 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 0 0 0 0 0 9.625'' N/A N/A Units* Casing Summary Lithology (%) cP 21 57 SPP (psi) Gallons/stroke TFA L-80 MBT pH N/A N/A C-2 0 in 0 N/A Minimum Depth C-5n Rigged down for rig move to ODSN-02. Skidded rig over ODSN-02. Rigging and nippling up for BOP test at time of report. 0 11740' 11740' 0' Max @ ft Current N/A N/A Date: Time: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth Gas Summary 0 0 0 (current) J. Polya / J. Haberther Sh Clyst Tuff Gvl Coal Footage Siltst 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Rig up PV 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 10.60 000 LSND 3.4 11740'28 Depth in / out Mud Type Lst Type Average N/A 0Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 Fluids = 0 bbls lost downhole Max Gas = 0 Avg Gas = 0 No gas samples collected. 10375' 5294' Bit # 6.9 10.20 10.20 Size 7.0 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 44 Customer: Well: Area: Location: Rig: ODSN-02 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition 29-Aug-2013 12:00 AM Current Pump & Flow Data: N/A Max 0 mg/l 41000 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - 0 2-Oct-2013 12:00 AM Current Pump & Flow Data: N/A Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 45 Customer: Well: Area: Location: Rig: ODSN-02 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: N/A Nabors 19AC Report For: Bit # -10.00 10.00 Size - Fluids = 0 bbls lost downhole Max Gas = 0 Avg Gas = 0 Nipple up BOPE's and drilling risers. Rig up to test TWC, set TWC and test to 3500 psi for 5 min. Rig down and circulate lines. Nipple down tree and set test dart. 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 0 Tools API FL Chromatograph (ppm) WOB Hydril N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average N/A Mud Type Lst Type Brine -11740'- Depth in / out YP (lb/100ft 2) - 000 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 Nipple up/down BOPs PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 12986' 12986' 0' Max @ ft Current N/A N/A Date: Time: Moved rig over to ODSN-04 well and rigged up. Displace diesel freeze protect out of hole with seawater and 10 ppg brine. 0 in 0 N/A Minimum Depth C-5n N/A N/A C-2 0 SPP (psi) Gallons/stroke TFA L-80 MBT pH 9.625'' N/A N/A Units* Casing Summary Lithology (%) cP -27 0 0 0 0 0 907-670-6636 Unit Phone: 0 Todd A. Wilson Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 0 Report By: 11.75'' Logging Engineers: Todd A. Wilson / Dave Mckechnie (max) (current) Liner 0 0 . . * 24 hr Recap: Report By: 11.75'' Logging Engineers: Todd A. Wilson / Dave McKechnie (max) (current) Liner 0 0 Bit Type Maximum Cly 0 907-670-6636 Unit Phone: 0 David McKechnie Set At Size 60.0 L-80 Grade 0 0 0 0 0 9.625'' N/A N/A Units* Casing Summary Lithology (%) cP -27 SPP (psi) Gallons/stroke TFA L-80 MBT pH N/A N/A C-2 0 in 0 N/A Minimum Depth C-5n Nippled up BOPs. Pressure tested 7" casing shoe to 3500 psi for 30 minutes. Pulled tubing hanger and tripped out of the hole 0 12986' 12986' 0' Max @ ft Current N/A N/A Date: Time: Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth Gas Summary 0 0 0 (current) R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Footage Siltst 0 Ss (ppb Eq) C-1 C-5i AK-AM-900261430 TIH W/Cleanout BHA PV 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) - 000 Brine -11740'- Depth in / out Mud Type Lst Type Average N/A 0Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools API FL Chromatograph (ppm) WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 Fluids = 0 bbls lost downhole Max Gas = 0 Avg Gas = 0 detection equipment. wear bushing and picked up cleanout BHA. Tripping in the hole with cleanout assembly at report time. Calibrated and tested gas from 2325' MD to surface. Picked up test tools and tested MPD to 2500 psi. Pulled MPD and installed trip nipple. Intalled 6 3/8" 10375' 5294' Bit # -10.00 10.00 Size - Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 46 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition 3-Oct-2013 12:00 AM Current Pump & Flow Data: N/A Max 0 mg/l - Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 7.38 0 4-Oct-2013 12:00 AM Current Pump & Flow Data: 3892 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 47 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: N/A Nabors 19AC Report For: Bit # 12.0 10.20 10.20 Size 85.1/14.9 Fluids = 0 bbls lost downhole Max Gas = 39 Avg Gas = 5 Displaced from 12,591' to 12,660'. Drilled cement from 12.660' to 12,952'. Drilling cement at time of report. tagged cement at 12,395'. Drilled cement from 12,395' to 12,591', began displacement of brine to 10.2 ppg MOBM. Tripped in the hole from 8,255' to 8,448'. Cut and slipped drilling line. Tripped in the hole from 8,448' to 12,359, 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 0 Tools HTHP Chromatograph (ppm) WOB Hydril N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min 10 Background (max) Trip Average N/A Mud Type Lst Type ENVIROMUL 9.2 12686'19 Depth in / out YP (lb/100ft 2) 3.717 000 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Ss Ratio C-1 C-5i AK-AM-900261430 Drilling out cement PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal Gas Summary 0 0 0 (current) Avg to Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 12986' 12986' 0' Max @ ft Current N/A N/A Date: Time: Picked up drill pipe from 1,266' to 7,517'. Repaired broken gear shaft on iron rough neck. Picked up drill pipe from 7,517' to 8,255'. 5 While circulating max gas was 39 units with an average of 5 units. No connection or significant trip gas. in 0 N/A Minimum Depth C-5n N/A N/A C-2 39 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 9.625'' 267 75 Units* Casing Summary Lithology (%) cP 32 96 0 0 0 0 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade Bit Type Maximum Cly 0 Report By: 11.75'' Logging Engineers: Todd A. Wilson / Makenzie Jorgensen (max) (current) Liner 0 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 9.32 0 5-Oct-2013 12:00 AM Current Pump & Flow Data: 0 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 48 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: N/A Nabors 19AC Report For: Bit # 9 12.4 6.125'' 10.20 PDC - Long gauge 10.20 Size 83.9/16.1 Fluids = 14 bbls lost during trip Max Gas = 81 Avg Gas = 7 up BHA #10 at report time. While circulating max gas was 81 units with an average of 7 units. No connection or trip gas. at 5750'. Laid down BHA and downloaded Bat sonic logs. Picked up BHA #10, broke in Geo-Pilot, and loaded nukes. Picking sonic logs from 12,984' to 11,339' and from 10,854' to 10,857'. Tripped out of the hole from 10,857' to 368'. Pumped 15 bbl dry job 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average N/A Mud Type Lst Hydril Type ENVIROMUL 8.9 12990'19 Depth in / out YP (lb/100ft 2) 3.628 000 0 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Ss Ratio C-1 C-5i AK-AM-900261430 Picking up BHA #10 PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 0 0 0 (current) Avg to 12990' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 12986' 12990' 4' Max @ ft Current N/A N/A Date: Time: Drilled cement from 12,952' to 12,990'. Circulated two bottoms up, and monitored well. Pumped dry job. Performed Bat 7 in 0 N/A Minimum Depth C-5n N/A N/A C-2 81 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 9.625'' 0 0 Units* Casing Summary Lithology (%) cP 32 93 0 0 0 0 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 0 Report By: 11.75'' 7" Logging Engineers: Todd A. Wilson / Makenzie Jorgensen (max) (current) Liner 0 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 4.40 24 6-Oct-2013 12:00 AM Current Pump & Flow Data: 2646 Max ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition Morning Report Report # 49 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 13.22 Nabors 19AC Report For: Bit # 9 2.5 6.125'' 7.65 PDC - Long gauge 7.65 Size 88.1/11.9 Fluids = 10 bbls lost during trip in Max Gas = 1709 Avg Gas = 109 with an average of 109 units. Max connection gas was 110 units and max trip gas was 120 units. Drilled ahead from 12,990' to 13,010' and circulated bottoms up. Performed formation integrity test to 12.5 ppg, and Cut and slipped drilling line and installed RCD element. Displaced well from a 10.2 ppg MOBM to a 7.6 ppg MOBM at 12,990'. Tripped in the hole from 3282' to 11,076'. Monitored the well for 10 minutes. Tripped in the hole to 12,904'. 10375' 5294' 100% Gas In Air =10,000 Units 110 Connection 1002 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 9.51 9.88 Avg Min Comments RPM ECD (ppg) ml/30min 83 Background (max) Trip Average 120 Mud Type Lst 80 Hydril Type ENVIROMUL 9.8 13222'9 Depth in / out YP (lb/100ft 2) 2.631 854 9 13 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 425 Hours C-3 10 104 0 Ss Ratio C-1 C-5i AK-AM-900261430 Drilling Lateral Section PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 2 189 23 (current) Avg to 12990' Yesterday's Depth: Current Depth: 24 Hour Progress: 121.9 Flow In (gpm) Flow In (spm) Depth 12990' 13346' 356' Max @ ft Current 13323'87.9 Date: Time: Picked up BHA from 150' to 395'. Tripped in the hole from 395' to 3282'. Filled drill pipe, tested MWD, and broke in Geo-Pilot. 109 bled down to 12 ppg. Drilled ahead from 13,010' to 13.097' and performed pore pressure test. Test formation pressure Max gas of 1709 units was circulated after pore pressure test. While drilling max gas was 373 units at 13099' was equal to 8.8 ppg EMW. Drilled ahead from 13,097' to 13,289'. Serviced top drive and blocks. Drilling ahead at time of report. in 32 13012'Minimum Depth C-5n 13099' 100.0 C-2 373 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 9.625'' 238 67 Units* Casing Summary Lithology (%) cP 12 55 4 184 21 10263 1140 907-670-6636 Unit Phone: 22 Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 41300 10 Report By: 11.75'' 7" Logging Engineers: Todd A. Wilson / Makenzie Jorgensen (max) (current) Liner 2090 46 . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Todd A. Wilson / Makenzie Jorgensen (max) (current) Liner 2168 164 L-80 12984' Bit Type Maximum Cly 82593 907-670-6636 Unit Phone: 21 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 1198 30 368 162 14728 9.625'' 238 67 Units* Casing Summary Lithology (%) cP 11 52 5 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 13327' 0.0 C-2 736 in 35 13964'Minimum Depth C-5n Drilled ahead from 13,333' to 13,962', serviced top drive. Drilled ahead from 13,962' to 14,069'. Picked up to 14,035' and 158 Max connection gas was 243 units with an average of 181 units. 13346' 14069' 723' Max @ ft Current 14006'109.6 Date: Time: Avg to 12990' Yesterday's Depth: Current Depth: 24 Hour Progress: 145.3 Flow In (gpm) Flow In (spm) Depth Gas Summary 21 120 23 (current) R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal 25.7 Footage Siltst 27 Ss Ratio C-1 C-5i AK-AM-900261430 Time drilling PV 24 hr Max 40.0 Weight 735 Hours C-3 63 81 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 2.888 28 119 26 ENVIROMUL 10.3 14069'10 Depth in / out Mud Type Lst 95 Hydril Type Average N/A 18 Background (max) Trip 9.64 9.93 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air =10,000 Units 243 Connection 633 Fluids = 0 bbls lost downhole Max Gas = 736 Avg Gas = 158 to 14,037'. Time drilling at report time. While drilling max gas was 736 units from 13327' with an average of 158 units. from 14,035' to 14,005 in an attempt to trough. Reamed/washed down from 14,035' to 13,990'. Time drilled from 14,035' troughed to 14,050'. Reamed/washed down from 14,035' to 14,058', reamed dogleg. Reamed/washed down 10375' 5294' Bit # 9 2.4 6.125'' 7.70 PDC - Long gauge 7.70 Size 87.1/12.9 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.22 Nabors 19AC Report For: Morning Report Report # 50 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition 7-Oct-2013 12:00 AM Current Pump & Flow Data: 2656 Max 52 (lb/bbl) 4.53 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Todd A. Wilson / Makenzie Jorgensen (max) (current) Liner 340 271 L-80 12984' Bit Type Maximum Cly 7505 907-670-6636 Unit Phone: 10 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 8048 12 81 95 3442 9.625'' 238 67 Units* Casing Summary Lithology (%) cP 12 51 5 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 14285' 35.2 C-2 117 stand and changed out SVR sub. Ran back in the hole to 14,249'. Drilled ahead from 14,249' to 14,345'. in 18 14099'Minimum Depth C-5n Time drilled from 14,037' to 14,040' at 1 foot an hour. Time drilled from 14,040' to 14,045' at 1.25 feet a hour. 50 through dog leg from 14,205' to 14,185'. Drilled ahead from 14,205' to 14,249'. Serviced top drive, racked back one Drilling ahead at report time. 14069' 14346' 277' Max @ ft Current 14147'74.8 Date: Time: Avg to 12990' Yesterday's Depth: Current Depth: 24 Hour Progress: 131.4 Flow In (gpm) Flow In (spm) Depth Gas Summary 0 51 10 (current) R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal 25.7 Footage Siltst 0 Ss Ratio C-1 C-5i AK-AM-900261430 Drilling lateral section PV 24 hr Max 40.0 Weight 167 Hours C-3 10 21 28 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 2.719 126 1 ENVIROMUL 9.8 14249'9 Depth in / out Mud Type Lst 85 Hydril Type Average N/A 69 Background (max) Trip 9.69 9.93 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air =10,000 Units 87 Connection 161 Fluids = 0 bbls lost downhole Max Gas = 117 Avg Gas = 50 Max connection gas was 87 units with an average of 67 units. While drilling max gas was 117 units from 14285' with an average of 50 units. Changed out bad bearing on RCD element. Drilled ahead from 14,155' to 14,205', washed and reamed Time drill from 14,053' to 14,055' at 2 ft a hour. Drilled ahead from 14,055' to 14,155'. Serviced top drive. Time drilled from 14,045' to 14,050' at 1.5 feet an hour. Time drilled from 14,050' to 14,053' at 2.5 feet a hour. 10375' 5294' Bit # 9 2.6 6.125'' 7.65 PDC - Long gauge 7.65 Size 88.7/11.3 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.17 Nabors 19AC Report For: Morning Report Report # 51 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition 8-Oct-2013 12:00 AM Current Pump & Flow Data: 2813 Max 11 (lb/bbl) 3.50 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Todd A. Wilson / Makenzie Jorgensen (max) (current) Liner 1082 345 L-80 12984' Bit Type Maximum Cly 30692 907-670-6636 Unit Phone: 12 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 7056 26 252 170 12118 9.625'' 220 62 Units* Casing Summary Lithology (%) cP 12 52 5 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 14417' 0.0 C-2 334 from 14,770 to 13,555'. Laid down one joint off the top of a stand. Serviced top drive and blocks. Reamed/washed down from in 18 14810'Minimum Depth C-5n Drilled ahead from 14,345' to 14,635'. Serviced top drive and blocks. Drilled ahead from 14,635' to 14,715'. 137 MPD had a computer failure. Closed bags and held 720 psi on well. Fixed the computer and began tripping out of the hole 13,555 to 13,585'. Starting trough to prepare for sidetrack at time of report. 14346' 14811' 465' Max @ ft Current 14789'81.6 Date: Time: Avg to 12990' Yesterday's Depth: Current Depth: 24 Hour Progress: 149.6 Flow In (gpm) Flow In (spm) Depth Gas Summary 2 80 13 (current) R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal 25.7 Footage Siltst 9 Ss Ratio C-1 C-5i AK-AM-900261430 Preparing to sidetrack PV 24 hr Max 40.0 Weight 574 Hours C-3 5 39 56 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 2.620 12 70 13 ENVIROMUL 9.6 14810'10 Depth in / out Mud Type Lst 90 Hydril Type Average N/A 19 Background (max) Trip 9.74 9.96 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air =10,000 Units 264 Connection 366 Fluids = 0 bbls lost downhole Max Gas = 334 Avg Gas = 137 Max connection gas was 264 units with an average of 170 units. While drilling max gas was 334 units from 14417' with an average of 137 units. to 14,765'. Washed/reamed down from 14,760' to 14,810' to smooth the hole. Tripped out of the hole from 14,810' to 14,770'. Washed/reamed down from 14,786' to 14,371'. Drilled ahead from 14,786' to 14,810'. Washed/reamed down from 14,810' Shot directional surveys at 14,715' and 14,710'. Drilled ahead from 14,715' to 14,786'. Shot directional survey at 14,784'. 10375' 5294' Bit # 9 3.0 6.125'' 7.70 PDC - Long gauge 7.70 Size 88.6/11.4 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.24 Nabors 19AC Report For: Morning Report Report # 52 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition 9-Oct-2013 12:00 AM Current Pump & Flow Data: 2303 Max 32 (lb/bbl) 4.01 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Todd A. Wilson / Makenzie Jorgensen (max) (current) Liner 0 0 L-80 12984' Bit Type Maximum Cly 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 0 0 0 0 0 9.625'' 192 54 Units* Casing Summary Lithology (%) cP 13 54 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 N/A 0.0 C-2 28 While circulating max gas was 28 units with an average of 16 units. No connection gas. in 0 N/A Minimum Depth C-5n Drilled trough from 13,555' to 13,585'. Time drilled from 13,585' to 13,588' at one foot per hour. Time drilled and worked pipe 16 from 13,610 to 13,621' with 4k weight on bit. Time drilling at report time. 14811' 14811' 0' Max @ ft Current N/A N/A Date: Time: Avg to 12990' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth Gas Summary 0 0 0 (current) R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal 25.7 Footage Siltst 0 Ss Ratio C-1 C-5i AK-AM-900261430 Time Drilling PV 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 2.650 000 ENVIROMUL 9.6 14810'11 Depth in / out Mud Type Lst Hydril Type Average N/A 19 Background (max) Trip 9.75 9.87 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 Fluids = 0 bbls lost downhole Max Gas = 28 Avg Gas = 16 hour from 13,595' to 13,600' and two foot per hour from 13,600' to 13,610'. Function tested BOPs. Continued to time drill stand at one foot per hour from 13,594' to 13,610'. Time drilled 1.25 foot per hour from 13,594' to 13,595'. Drilled 1.5 foot per from 13,588' to 13,545' as per Directional Driller. Drilled ahead from 13,588' to 13,590' at one foot per hour. Time drilled first 10375' 5294' Bit # 9 2.9 6.125'' 7.70 PDC - Long gauge 7.70 Size 88.6 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.00 Nabors 19AC Report For: Morning Report Report # 53 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 6.51 @ Mud Data Depth Condition 10-Oct-2013 12:00 AM Current Pump & Flow Data: 2284 Max 0 (lb/bbl) 5.44 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Todd A. Wilson / Makenzie Jorgensen (max) (current) Liner 560 32 L-80 12984' Bit Type Maximum Cly 12546 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 791 0 136 14 7868 9.625'' 0 0 Units* Casing Summary Lithology (%) cP 33 97 SPP (psi) Gallons/stroke TFA L-80 Oil/Water 13673' ASG 0.390 13670 0.0 C-2 128 While drilling max gas was 128 units from 13670' MD with an average of 92 units. No connection gas. in 26 13644 Minimum Depth C-5n Time drilled at 8 feet per hour from 13,621' to 13,641'. Serviced top drive and greased blocks. Time drilled at 12 to 92 hole from 2,030' to 395'. Laid down BHA from 395' to 115' and unloaded nukes. Laying down BHA at report time. 13585' 13673' 88' Max @ ft Current 13665'45.2 Date: Time: Avg to 12990' Yesterday's Depth: Current Depth: 24 Hour Progress: 55.7 Flow In (gpm) Flow In (spm) Depth Gas Summary 0 48 6 (current) R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal 25.7 Footage Siltst 0 Ss Ratio C-1 C-5i AK-AM-900261430 Laying down BHA PV 24 hr Max 40.0 Weight 353 Hours C-3 23 3 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 3.646 031 1 ENVIROMUL 6.7 13673'19 Depth in / out Mud Type Lst Hydril Type Average N/A 0Background (max) Trip 9.70 9.87 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 213 Fluids = 5 bbls lost during trip Max Gas = 128 Avg Gas = 92 trip nipple. Tripped out of the hole from 13,578' to 2,030'. Cut and slipped 74' of drill line and serviced top drive. Tripped out of the 7.7 ppg MOBM to a 10.2 ppg MOBM. Changed rotating head rubber, monitored well, and removed RCD element and installed 40 feet per hour from 13,641' to 13,674'. Circulated while trouble shooting the Geo-Pilot. Displaced well from a 10375' 5294' Bit # 9 12.3 6.125'' 10.20 PDC - Long gauge 10.20 Size 85.1/14.9 Job No.: Daily Charges: Total Charges: MWD Summary 0% Rig Activity: 10.02 Nabors 19AC Report For: Morning Report Report # 54 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 0.00 @ Mud Data Depth Condition 11-Oct-2013 12:00 AM Current Pump & Flow Data: 0 Max 15 (lb/bbl) 7.12 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers:Todd A. Wilson / Makenzie Jorgensen (max)(current) Liner 0 0 L-8012984' Bit Type Maximum Cly 0 907-670-6636Unit Phone: 0 Makenzie Jorgensen Set AtSize 60.0 L-80 Grade 0 0 0 0 0 9.625'' Units* Casing Summary Lithology (%) cP SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 0.0 C-2 No gas samples analyzed. in Minimum Depth C-5n Laid down BHA #10 from 115' to surface. Prepared tools and BHA #11 for trip into hole. Removed wear bushings, picked Geo-Pilot. Tripped in the hole from 3,763' to 10,497'. Filled pipe at 7,125' and 10,497'. Tripping in the hole at report time. 13673' 0' Max @ ft Current Date: Time: Avg to13673' Yesterday's Depth: Current Depth: 24 Hour Progress: Flow In (gpm) Flow In (spm) Depth Gas Summary 0 0 0 (current) R. Klepzig / J. Haberther ShClyst TuffGvlCoal 25.7 Footage Siltst 0 Ss Ratio C-1 C-5i AK-AM-900261430 $6,691.56 $359,214.84 PV 24 hr Max 40.0 Weight 0 Hours C-3 0 0 CementChtSilt C-4i C-4n YP (lb/100ft2) 000 ENVIROMUL Depth in / out Mud Type Lst Hydril Type Average 153Background (max)Trip Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air=10,000 UnitsConnection 0 Fluids = 7 bbls lost during trip in Max Gas = N/A Avg Gas = N/A tools. Circulated and shallow pulse tested tools, loaded nukes. Tripped in the hole from 395' to 3,763'. Filled pipe and broke in blew down lines. Set wear bushings, blew down choke and kill lines. Picked up BHA #11, downloaded MWD up test tools, and filled stack. Made up test tools and tested BOPs at 250 and 4000 psi. Laid down test tools, rigged down, and 10375' 5294' Bit # 9 6.125''PDC - Long gauge Size Job No.: Daily Charges: Total Charges: MWD Summary 0% Rig Activity: Nabors 19AC Report For: Morning Report Report # 55 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 0.00 @ Mud Data Depth Condition 12-Oct-2013 12:00 AM Current Pump & Flow Data: Max 0 (lb/bbl) Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Todd A. Wilson / Makenzie Jorgensen (max) (current) Liner 1831 141 L-80 12984' Bit Type Maximum Cly 49118 907-670-6636 Unit Phone: 24 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 4487 3 335 41 22221 9.625'' 171 48 Units* Casing Summary Lithology (%) cP 13 58 5 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 14139' 0.0 C-2 430 Max connection gas was 248 units with an average of 213 units. There was trip gas of 153 units. in 24 13683'Minimum Depth C-5n Tripped in the hole from 10,497' to 13,482'. Pulled trip nipple and installed RCD bearing. Filled MPD lines with pre charge pump. 198 While drilling max gas was 430 units from 13683' with an average of 198 units. 13673' 14148' 475' Max @ ft Current 13973'93.1 Date: Time: Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: 165.3 Flow In (gpm) Flow In (spm) Depth Gas Summary 0 140 26 (current) R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal 25.7 Footage Siltst 0 Ss Ratio C-1 C-5i AK-AM-900261430 Time Drilling PV 24 hr Max 40.0 Weight 928 Hours C-3 5 67 7 Cement Cht Silt C-4i C-4n YP (lb/100ft 2) 2.669 876 11 ENVIROMUL 8.8 14145'11 Depth in / out Mud Type Lst 90 Hydril Type Average 153 22 Background (max) Trip 9.70 9.92 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air =10,000 Units 248 Connection 628 Fluids = 0 bbls lost down hole Max Gas = 430 Avg Gas = 198 foot per hour. Time drilled from 14,143' to 14,148' at 1.2 foot per hour. Time drilling at report time. Geo-Pilot through sidetrack at 13,585'. Drilled ahead from 13,673' to 14,138' Time drilled from 14,138' to 14,143' at one Displaced well from a 10.2 ppg MOBM to a 7.7 ppg MOBM. Reamed and washed down from 13,482' to 13,673'. Oriented 10375' 5294' Bit # 9 3.6 6.125'' 7.80 PDC - Long gauge 7.80 Size 88.5/11.5 Job No.: Daily Charges: Total Charges: MWD Summary 0% Rig Activity: 11.72 Nabors 19AC Report For: Morning Report Report # 56 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 0.00 @ Mud Data Depth Condition 13-Oct-2013 12:00 AM Current Pump & Flow Data: 1753 Max 37 (lb/bbl) 6.86 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 7.38 8 14-Oct-2013 12:00 AM Current Pump & Flow Data: 2066 Max ROP ROP (ft/hr) 0.00 @ Mud Data Depth Condition Morning Report Report # 57 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 0% Rig Activity: 10.02 Nabors 19AC Report For: Bit # 9 2.6 6.125'' 7.70 PDC - Long gauge 7.70 Size 88.1/11.9 Fluids = 0 bbls lost down hole Max Gas = 141 Avg Gas = 56 to 14,161'. Pulled out of the hole to 14,155' and reamed/washed down to 14,173'. Pulled out of the hole and reamed/washed in primary muster area and returned to work after fire was extinguished. Reamed/washed down from 14,155' from 14,160' to 14,174'. Shut in well and evacuated rig because of fire in well bay 1. All persons were accounted for 10375' 5294' 100% Gas In Air =10,000 Units 26 Connection 155 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 9.74 9.89 Avg Min Comments RPM ECD (ppg) ml/30min 10 Background (max) Trip Average N/A Mud Type Lst Hydril Type ENVIROMUL 8.0 14177'11 Depth in / out YP (lb/100ft 2) 2.865 121 2 8 Cement Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 146 Hours C-3 17 0 Ss Ratio C-1 C-5i AK-AM-900261430 Reaming PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 0 39 8 (current) Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: 52.4 Flow In (gpm) Flow In (spm) Depth 14148' 14178' 30' Max @ ft Current 14176'27.4 Date: Time: Time drilled from 14,148' to 14,161'. Drilled ahead from 14,161' to 14,177'. Reamed/washed down to smooth out hole 56 down from 14,141' to 14,164'. Reaming/washing at time of report. While drilling max gas was 141 units from 14174' with an average of 56 units. There was a connection gas of 26 units. in 19 14162 Minimum Depth C-5n 14174 0.0 C-2 141 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 9.625'' 199 56 Units* Casing Summary Lithology (%) cP 12 57 0 54 10 4293 339 907-670-6636 Unit Phone: 7 Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 15841 Report By: 11.75'' 7" Logging Engineers: Todd A. Wilson / Makenzie Jorgensen (max) (current) Liner 505 16 . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Makenzie Jorgensen (max) (current) Liner 304 20 L-80 12984' Bit Type Maximum Cly 8915 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 704 0 55 7 5024 9.625'' 192 54 Units* Casing Summary Lithology (%) cP 12 56 5 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 14206' 0.0 C-2 90 in 14 14178'Minimum Depth C-5n Time drilled from 14,160' to 14,170'. Worked pipe as necessary to stop Geo-Pilot housing roll. Time drillied 61 14178' 14232' 54' Max @ ft Current 14209'14.1 Date: Time: Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: 22.3 Flow In (gpm) Flow In (spm) Depth 30 Gas Summary 0 21 0 (current) R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal 25.7 Footage Siltst 0 Ss Ratio C-1 C-5i AK-AM-900261430 Time Drilling PV 24 hr Max 40.0 Weight 170 Hours C-3 10 0 Sid Cht Silt C-4i C-4n YP (lb/100ft 2) 2.834 012 0 ENVIROMUL 7.6 14224'11 Depth in / out Mud Type Lst 65 Hydril Type Average N/A 20 Background (max) Trip 9.74 9.91 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air =10,000 Units 71 Connection 97 Fluids = 0 bbls lost down hole Max Gas = 90 Avg Gas = 61 While drilling max gas was 90 units from 14206' with an average of 61 units. There was a connection gas of 71 units. Drilled ahead from 14,217' to 14,230'. Time drilled from 14,230' to 14,232'. Time drilling at report time. from 14,170' to 14,178'. Rotary drilled from 14,178' to 14,217'. Serviced top drive and cleaned suction screens. 10375' 5294' Bit # 9 2.6 6.125'' 7.70 PDC - Long gauge 7.70 Size 87.6/12.4 Job No.: Daily Charges: Total Charges: MWD Summary 0% Rig Activity: 10.17 Nabors 19AC Report For: Morning Report Report # 58 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 0.00 @ Mud Data Depth Condition 15-Oct-2013 12:00 AM Current Pump & Flow Data: 2044 Max 5 (lb/bbl) 7.51 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 7.51 6 16-Oct-2013 12:00 AM Current Pump & Flow Data: 742 Max ROP ROP (ft/hr) 0.00 @ Mud Data Depth Condition Morning Report Report # 59 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 0% Rig Activity: 10.35 Nabors 19AC Report For: Bit # 9 12.3 6.125'' 10.20 PDC - Long gauge 10.20 Size 84.5/15.5 Fluids = 0 bbls lost down hole Max Gas = 120 Avg Gas = 54 the hole at report time. head and rubber, removed RCD bearing, and installed trip nipple. Tripped out of the hole from 14,334' to 12,231'. Tripping out of Circulated and took a survey. Displaced well from a 7.7 ppg MOBM to a 10.2 ppg kill weight MOBM. Changed rotating 10375' 5294' 100% Gas In Air =10,000 Units 120 Connection 61 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 9.74 9.92 Avg Min Comments RPM ECD (ppg) ml/30min 15 Background (max) Trip Average N/A Mud Type Lst 95 Hydril Type ENVIROMUL 6.8 14334'26 Depth in / out YP (lb/100ft 2) 3.629 013 0 9 Sid Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 127 Hours C-3 8 0 Ss Ratio C-1 C-5i AK-AM-900261430 Tripping out PV Footage Siltst R. Klepzig / J. Haberther Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 0 15 0 (current) Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: 11.5 Flow In (gpm) Flow In (spm) Depth 14232' 14335' 103' Max @ ft Current 14330'8.8 Date: Time: Time drilled from 14,232' to 14,262'. Reamed/washed down from 14,180' to 14,240'. Drilled ahead from 14,262' to 14,334'. 54 While drilling max gas was connection gas of 120 units from 14250' with an average of 54 units. No other connection or trip gas. in 22 14233 Minimum Depth C-5n 14250 0.0 C-2 120 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 9.625'' 0 0 Units* Casing Summary Lithology (%) cP 22 85 5 4 48 25 4052 754 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 13302 Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Makenzie Jorgensen (max) (current) Liner 213 48 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 6.73 0 17-Oct-2013 12:00 AM Current Pump & Flow Data: 781 Max ROP ROP (ft/hr) 0.00 @ Mud Data Depth Condition Morning Report Report # 60 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 0% Rig Activity: N/A Nabors 19AC Report For: Bit # 9 13.4 6.125'' 10.20 PDC - Long gauge 10.20 Size 84.9/15.1 Fluids = 5 bbls lost during trip out Max Gas = N/A Avg Gas = N/A No significant gas detected. 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min N/A Background (max) Trip Average N/A Mud Type Lst Hydril Type ENVIROMUL 6.8 14333'27 Depth in / out YP (lb/100ft 2) 3.425 000 0 Sid Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Ss Ratio C-1 C-5i AK-AM-900261430 Tripping in PV Footage Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 0 0 0 (current) Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 14335' 14335' 0' Max @ ft Current N/A N/A Date: Time: Tripped out from 12231' to surface. Laid down BHA #11. Picked up BHA #12. Ran in hole from surface to 7166'. N/A in N/A N/A Minimum Depth C-5n N/A N/A C-2 N/A SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 9.625'' 0 0 Units* Casing Summary Lithology (%) cP 24 99 0 0 0 0 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 0 Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Makenzie Jorgensen (max) (current) Liner 0 0 . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Makenzie Jorgensen (max) (current) Liner 0 0 L-80 12984' Bit Type Maximum Cly 0 907-670-6636 Unit Phone: 0 Makenzie Jorgensen Set At Size 60.0 L-80 Grade 0 0 0 0 0 9.625'' 0 0 Units* Casing Summary Lithology (%) cP 25 110 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 N/A N/A C-2 N/A in N/A N/A Minimum Depth C-5n Tripped out from 7166' to 1527' and troubleshot with MWD. Tripped out to surface, laid down BHA# 12. Tested BOPs. Picked up N/A 14335' 14335' 0' Max @ ft Current N/A N/A Date: Time: Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth Gas Summary 0 0 0 (current) J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Footage Siltst 0 Ss Ratio C-1 C-5i AK-AM-900261430 Tripping in PV 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Sid Cht Silt C-4i C-4n YP (lb/100ft 2) 3.185 000 ENVIROMUL 6.8 14334'27 Depth in / out Mud Type Lst Hydril Type Average N/A N/A Background (max) Trip 12.48 12.59 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 Fluids = 0 bbls lost Max Gas = N/A Avg Gas = N/A BHA# 13 and tripped into hole to 6204'. No significant gas detected. 10375' 5294' Bit # 9 12.4 6.125'' 10.40 PDC - Long gauge 10.40 Size 83.9/16.1 Job No.: Daily Charges: Total Charges: MWD Summary 0% Rig Activity: 12.65 Nabors 19AC Report For: Morning Report Report # 61 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 0.00 @ Mud Data Depth Condition 18-Oct-2013 12:00 AM Current Pump & Flow Data: 0 Max 0 (lb/bbl) 5.83 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 7.51 19 19-Oct-2013 12:00 AM Current Pump & Flow Data: 2829 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Condition Morning Report Report # 62 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.72 Nabors 19AC Report For: Bit # 9 3.7 6.125'' 7.80 PDC - Long gauge 7.80 Size 87.5/12.5 Fluids = 3 bbls lost during trip in. Max Gas = 1622 Avg Gas = 156 Max gas was trip gas of 1622 units. While drilling max gas was 398 units from 14557' with an average of 156 units. from 14334' to 14580' at 190 gpm. Drilling ahead at time of report. Circulated and staged up pumps, displaced well to 7.7 ppg MOBM, and took returns to active at 6340 strokes. Drilled ahead 10375' 5294' 100% Gas In Air =10,000 Units 155 Connection 418 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 9.77 10.12 Avg Min Comments RPM ECD (ppg) ml/30min 80 Background (max) Trip Average 1622 Mud Type Lst 90 Hydril Type ENVIROMUL 7.4 14399'10 Depth in / out YP (lb/100ft 2) 2.627 535 12 7 Sid Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 576 Hours C-3 44 0 Ss Ratio C-1 C-5i AK-AM-900261430 Drilling ahead PV Footage Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 0 90 16 (current) Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: 96.5 Flow In (gpm) Flow In (spm) Depth 14335' 14584' 249' Max @ ft Current 14389'68.7 Date: Time: Tripped in hole from 6204' to 12945'. Tested MWD, cut and slipped drill line. Tripped in to 14334', installed RCD. 156 Max connection gas was 155 units with an average of 108 units. in 22 14352 Minimum Depth C-5n 14557 91.0 C-2 398 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 9.625'' 206 58 Units* Casing Summary Lithology (%) cP 14 60 10 4 196 31 15996 6168 907-670-6636 Unit Phone: 15 Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 32902 Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Makenzie Jorgensen (max) (current) Liner 1270 112 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 44 20-Oct-2013 12:00 AM Current Pump & Flow Data: 3796 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Condition Morning Report Report # 63 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.24 Nabors 19AC Report For: Bit # 9 6.125''PDC - Long gauge Size Fluids = 0 bbls lost down hole Max Gas = 947 units Avg Gas = 470 units Max connection gas was 884 units with an average of 703 units. Max gas was 947 units while drilling from 15026' with an average of 470 units. seawater infiltrated active system with minimal effects. Drilling ahead at time of report. 10375' 5294' 100% Gas In Air =10,000 Units 884 Connection 580 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 9.67 10.01 Avg Min Comments RPM ECD (ppg) ml/30min 200 Background (max) Trip Average N/A Mud Type Lst 95 Hydril Type ENVIROMUL Depth in / out YP (lb/100ft 2) 18 96 19 78 Sid Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 1181 Hours C-3 63 17 Ss Ratio C-1 C-5i AK-AM-900261430 Drilling Ahead PV Footage Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 14 135 26 (current) Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: 176.9 Flow In (gpm) Flow In (spm) Depth 14584' 15624' 1040' Max @ ft Current 14913'77.4 Date: Time: Drilled from 14580' to 15612' at 240 gpm. Blew pop-off while pumping seawater for wells group. Less than 5 bbls 470 in 40 14810 Minimum Depth C-5n 15026 83.0 C-2 947 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 9.625'' 238 67 Units* Casing Summary Lithology (%) cP 5 35 382 299 52868 33060 907-670-6636 Unit Phone: 30 Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 111286 Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Makenzie Jorgensen (max) (current) Liner 2025 859 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 7.45 38 21-Oct-2013 12:00 AM Current Pump & Flow Data: 3189 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Condition Morning Report Report # 64 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.37 Nabors 19AC Report For: Bit # 9 3.6 6.125'' 7.90 PDC - Long gauge 7.90 Size 86.5/13.5 Fluids = 0 bbls lost down hole Max Gas = 1110 units Avg Gas = 432 units Max connection gas was 1110 units with an average connection gas of 471 units. Max gas was connection gas of 1110 units from 15636' with an average of 432 units. Continued drilling from 15885' to 16023' at 230 gpm. Drilling ahead at time of report. 10375' 5294' 100% Gas In Air =10,000 Units 1110 Connection 633 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 9.85 10.12 Avg Min Comments RPM ECD (ppg) ml/30min 150 Background (max) Trip Average N/A Mud Type Lst 95 Hydril Type ENVIROMUL 7.2 15843'12 Depth in / out YP (lb/100ft 2) 2.912 20 87 19 0 Sid Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 987 Hours C-3 69 0 Ss Ratio C-1 C-5i AK-AM-900261430 Drilling ahead PV Footage Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 0 153 32 (current) Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: 124.5 Flow In (gpm) Flow In (spm) Depth 15624' 16024' 400' Max @ ft Current 15716'61.3 Date: Time: Drilled from 15612' to 15885' at 240 gpm. Troubleshot MWD tools as there was no detection over 20 RPM. 432 in 3 15783 Minimum Depth C-5n 15636 80.0 C-2 1110 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 9.625'' 227 64 Units* Casing Summary Lithology (%) cP 11 62 5 0 321 0 46122 0 907-670-6636 Unit Phone: 30 Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 125428 Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Makenzie Jorgensen (max) (current) Liner 2154 0 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 6.80 50 22-Oct-2013 12:00 AM Current Pump & Flow Data: 3262 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Condition Morning Report Report # 65 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.46 Nabors 19AC Report For: Bit # 9 4.6 6.125'' 7.90 PDC - Long gauge 7.90 Size 87.4/12.6 Fluids = 0 bbls lost down hole Max Gas = 915 units Avg Gas = 453 units Max connection gas was 915 units with an average connection gas of 566 units. Max gas was connection gas of 915 units from 16603' with an average of 453 units. 10375' 5294' 100% Gas In Air =10,000 Units 915 Connection 676 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 9.68 10.17 Avg Min Comments RPM ECD (ppg) ml/30min 250 Background (max) Trip Average N/A Mud Type Lst 100 Hydril Type ENVIROMUL 7.2 16710'11 Depth in / out YP (lb/100ft 2) 2.520 25 110 24 25 Sid Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 1394 Hours C-3 75 8 Ss Ratio C-1 C-5i AK-AM-900261430 Drilling ahead PV Footage Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 3 164 35 (current) Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: 155.2 Flow In (gpm) Flow In (spm) Depth 16024' 17025' 1001' Max @ ft Current 16516'79.9 Date: Time: Drilled from 16023' to 17025' at 240 gpm. Serviced top drive and checked shaker screens. 453 in 34 16066 Minimum Depth C-5n 16603 83.0 C-2 915 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 9.625'' 238 67 Units* Casing Summary Lithology (%) cP 10 68 9 440 60 49956 1620 907-670-6636 Unit Phone: 37 Makenzie Jorgensen Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 103106 Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Makenzie Jorgensen (max) (current) Liner 2209 104 . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 6.15 49 23-Oct-2013 11:59 PM Current Pump & Flow Data: 3269 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Condition Morning Report Report # 66 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.53 Nabors 19AC Report For: Bit # 9 5.1 6.125'' 8.00 PDC - Long gauge 8.00 Size 86.7/13.3 Fluids = 0 bbls lost down hole Max Gas = 1141 units Avg Gas = 456 units sandstone. Max connection gas was 1141 units with an average connection gas of 568 units. The Cuttings have been predominantly drive at 17850' MD. Max gas was connection gas of 1141 units from 17563 ' MD with an average of 456 units. 10375' 5294' 100% Gas In Air =10,000 Units 1141 Connection 613 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 10.00 10.29 Avg Min Comments RPM ECD (ppg) ml/30min 144 Background (max) Trip Average N/A Mud Type Lst 100 Hydril Type ENVIROMUL 7.6 17672'10 Depth in / out YP (lb/100ft 2) 2.607 31 115 28 55 Sid Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 1295 Hours C-3 65 21 Ss Ratio C-1 C-5i AK-AM-900261430 $7,647.59 $428,042.50 Drilling ahead PV Footage Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 16 150 33 (current) Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: 178.5 Flow In (gpm) Flow In (spm) Depth 17025' 17935' 910' Max @ ft Current 17031'71.4 Date: Time: Drilled from 17025' MD to 17935' MD at 240 gpm. Changed rotating head rubber and RCD bearing at 17083' MD. Serviced top 456 in 37 17746 Minimum Depth C-5n 17563 56.9 C-2 1141 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 9.625'' 68 242 Units* Casing Summary Lithology (%) cP 11 61 19 409 99 48856 1569 907-670-6636 Unit Phone: 38 Martin Nnaji Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 130881 Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Martin Nnaji (max) (current) Liner 2361 134 . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Martin Nnaji (max) (current) Liner 2041 0 L-80 12984' Bit Type Maximum Cly 85443 907-670-6636 Unit Phone: 38 Martin Nnaji Set At Size 60.0 L-80 Grade 50 0 410 0 33450 9.625'' 238 67 Units* Casing Summary Lithology (%) cP 15 64 SPP (psi) Gallons/stroke TFA L-80 Oil/Water ASG 0.390 18238 90.0 C-2 770 in 13 18456 Minimum Depth C-5n Drilled from 17935' MD to 18916' MD, 240 gpm. Serviced the top drive. Max gas was 770 units from 18238 ' MD with an average 319 17935' 18916' 981' Max @ ft Current 18508'73.9 Date: Time: Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: 184.6 Flow In (gpm) Flow In (spm) Depth Gas Summary 0 155 36 (current) J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Footage Siltst 0 Ss Ratio C-1 C-5i AK-AM-900261430 Drilling ahead PV 24 hr Max 40.0 Weight 1207 Hours C-3 63 0 Sid Cht Silt C-4i C-4n YP (lb/100ft 2) 2.619 34 122 30 ENVIROMUL 7.0 18727'12 Depth in / out Mud Type Lst 100 Hydril Type Average N/A 160 Background (max) Trip 9.99 10.39 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air =10,000 Units 708 Connection 594 Fluids = 0 bbls lost down hole Max Gas = 770 units Avg Gas = 319 units predominantly uncolsolidated sandstone. of 319 units. Max connection gas was 708 units with an average connection gas of 370 units. The Cuttings have been 10375' 5294' Bit # 9 6.1 6.125'' 8.15 PDC - Long gauge 8.15 Size 87.7/12.3 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.71 Nabors 19AC Report For: Morning Report Report # 67 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth Condition 24-Oct-2013 11:59 PM Current Pump & Flow Data: 3988 Max 49 (lb/bbl) 6.22 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 5.83 52 25-Oct-2013 11:59 PM Current Pump & Flow Data: 2896 Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Condition Morning Report Report # 68 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.84 Nabors 19AC Report For: Bit # 9 7.2 6.125'' 8.30 PDC - Long gauge 8.20 Size 89.2/10.8 Fluids = 0 bbls lost down hole Max Gas = 1120 units Avg Gas = 355 units connection gas of 498 units. Cuttings have been predominantly unconsolidated sandstone. Max gas was 1120 units from 19475' MD with an average of 355 units. Max connection gas was 1050 units with an average 10375' 5294' 100% Gas In Air =10,000 Units 1050 Connection 799 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 10.05 10.49 Avg Min Comments RPM ECD (ppg) ml/30min 138 Background (max) Trip Average N/A Mud Type Lst 100 Hydril Type ENVIROMUL 6.8 19868'12 Depth in / out YP (lb/100ft 2) 2.654 37 131 32 100 Sid Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 1403 Hours C-3 83 34 Ss Ratio C-1 C-5i AK-AM-900261430 Backreaming PV Footage Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 29 196 42 (current) Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: 158.0 Flow In (gpm) Flow In (spm) Depth 18916' 19868' 952' Max @ ft Current 19434'77.0 Date: Time: Drilled from 18916' MD to TD at 19868' MD. Backreamed from 19868' MD to 19105' MD, 190 gpm, 700-800 fpm. Replaced RCD. 355 in 34 19843'Minimum Depth C-5n 19475' 0.0 C-2 1120 SPP (psi) Gallons/stroke TFA L-80 Oil/Water 19868' ASG 0.390 9.625'' 192 54 Units* Casing Summary Lithology (%) cP 18 62 37 449 292 36850 25827 907-670-6636 Unit Phone: 47 Martin Nnaji Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 122406 Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Martin Nnaji (max) (current) Liner 3085 894 . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Martin Nnaji (max) (current) Liner 0 0 L-80 12984' Bit Type Maximum Cly 0 907-670-6636 Unit Phone: 0 Martin Nnaji Set At Size 60.0 L-80 Grade 0 0 0 0 0 9.625'' 212 60 Units* Casing Summary Lithology (%) cP 19 74 SPP (psi) Gallons/stroke TFA L-80 Oil/Water 19868' ASG 0.390 N/A N/A C-2 284 in 0 N/A Minimum Depth C-5n Backreamed from 19105' MD to 12942' MD, 190 gpm. Mad pass from 14460' MD to 13060' MD, 250-275 fpm. Max gas was 40 19868' 19868' 0' Max @ ft Current N/A N/A Date: Time: Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth Gas Summary 0 0 0 (current) J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Footage Siltst 0 Ss Ratio C-1 C-5i AK-AM-900261430 Circulating at Shoe PV 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Sid Cht Silt C-4i C-4n YP (lb/100ft 2) 2.623 000 ENVIROMUL 4.2 19868'13 Depth in / out Mud Type Lst Hydril Type Average N/A N/A Background (max) Trip 9.95 10.21 Avg Min Comments RPM ECD (ppg) ml/30min Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 Fluids = 2 bbls lost down hole Max Gas = 284 units Avg Gas = 40 units 284 units and Average gas was 40 units while circulating. Circulating at shoe at report time 10375' 5294' Bit # 9 7.4 6.125'' 8.30 PDC - Long gauge 8.30 Size 91.3/8.7 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.44 Nabors 19AC Report For: Morning Report Report # 69 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth Condition 26-Oct-2013 11:59 PM Current Pump & Flow Data: 164 Max 0 (lb/bbl) 4.92 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 7.64 0 27-Oct-2013 11:59 PM Current Pump & Flow Data: N/A Max ROP ROP (ft/hr) 3.55 @ Mud Data Depth Condition Morning Report Report # 70 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Nabors 19AC Report For: Bit # 9 13.4 6.125'' 10.20 PDC - Long gauge 10.20 Size 70.0/16.0 Fluids = 9 bbls lost down hole Max Gas = 302 units Avg Gas = 17 units gas of 17 units recorded while circulating. 210 gpm. Install trip nipple and trip out from TD to 12945' MD. Slip and cut drill line. Max gas of 302 units and average 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 0 Tools Full Service HTHP Chromatograph (ppm) 12990' WOB Hydril Avg Min Comments RPM ECD (ppg) ml/30min N/A Background (max) Trip Average N/A Mud Type Lst Hydril Type ENVIROMUL 5.8 19868'24 Depth in / out YP (lb/100ft 2) 3.392 000 0 Sid Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Ss Ratio C-1 C-5i AK-AM-900261430 Tripping Out PV Footage Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 0 0 0 (current) Avg to 13673' Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 19868' 19868' 0' Max @ ft Current N/A N/A Date: Time: Trip into hole to TD and establish circulation. Displace well to 10.2 ppg KW MOBM, 10.2 ppg returns at 8650 strokes, 17 in 0 N/A Minimum Depth C-5n N/A N/A C-2 302 SPP (psi) Gallons/stroke TFA L-80 Oil/Water 19868' ASG 0.390 9.625'' N/A N/A Units* Casing Summary Lithology (%) cP 32 78 0 0 0 0 0 907-670-6636 Unit Phone: 0 Martin Nnaji Set At Size 60.0 L-80 Grade L-80 12984' Bit Type Maximum Cly 0 Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Martin Nnaji (max) (current) Liner 0 0 . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Martin Nnaji (max) (current) Liner 0 0 L-80 12984' Bit Type Maximum Cly 0 907-670-6636 Unit Phone: 0 Martin Nnaji Set At Size 60.0 L-80 Grade 0 0 0 0 0 9.625'' N/A N/A Units* Casing Summary Lithology (%) cP 120 82 SPP (psi) Gallons/stroke TFA L-80 Oil/Water N/A ASG 0.390 N/A N/A C-2 N/A in N/A N/A Minimum Depth C-5n Trip out of hole from 12945' MD to 4734' MD, lubricate while laying down drill pipe from 4734' MD to 1560' MD. Pump N/A 19868' 19868' 0' Max @ ft Current N/A N/A Date: Time: Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth Gas Summary 0 0 0 (current) J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Footage Siltst 0 Ss Ratio C-1 C-5i AK-AM-900261430 Tripping Out PV 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Sid Cht Silt C-4i C-4n YP (lb/100ft 2) 3.389 000 ENVIROMUL 6.4 19868'27 Depth in / out Mud Type Lst Hydril Type Average N/A N/A Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools HTHP Chromatograph (ppm) 12990' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 Fluids = 14 bbls lost downhole Max Gas = 0 units, Avg Gas = 0 units dry job and lay down from 1560' MD to 133' MD, remove nukes and lay down MWD. 10375' 5294' Bit # 9 13.5 6.125'' 10.20 PDC - Long gauge 10.20 Size 70.0/16.0 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 71 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth Condition 28-Oct-2013 11:59 PM Current Pump & Flow Data: N/A Max 0 (lb/bbl) 7.51 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: Report By: 11.75'' 7" Logging Engineers: Kerry Garner / Martin Nnaji (max) (current) Liner 0 0 L-80 12984' Bit Type Maximum Cly 0 907-670-6636 Unit Phone: 0 Martin Nnaji Set At Size 60.0 L-80 Grade 0 0 0 0 0 9.625'' N/A N/A Units* Casing Summary Lithology (%) cP 29 87 SPP (psi) Gallons/stroke TFA L-80 Oil/Water N/A ASG 0.390 N/A N/A C-2 N/A in N/A N/A Minimum Depth C-5n Ran 4.5" liner into hole from 3644' MD to 7052' MD. Rig down Tesco. Ran from 7052' MD to 7214' MD with 4.5" liner, circulate N/A 19868' 19868' 0' Max @ ft Current N/A N/A Date: Time: Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth Gas Summary 0 0 0 (current) J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 5534' Footage 179.18 Siltst 0 Ss Ratio C-1 C-5i AK-AM-900261430 Running Liner PV 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Sid Cht Silt C-4i C-4n YP (lb/100ft 2) 3.332 000 80.0 ENVIROMUL 6.2 19868'24 Depth in / out Mud Type Lst Hydril Type Average N/A N/A Background (max) Trip N/A N/A Avg Min Comments RPM ECD (ppg) ml/30min Tools HTHP Chromatograph (ppm) 12klb 14334' 19868' WOB Hydril 100% Gas In Air =10,000 Units N/A Connection 0 Fluids = 0 bbls lost downhole Max Gas = 0 units, Avg Gas = 0 units and stage up to 1.5 BPM. Circulating at report time. and condition mud at 1.5 BPM. Continued tripping into hole with 4.5" liner from 7214' MD to 12925' MD. Break circulation 10375' 5294' 1-3-BT-N-X-I-CT-TD Bit # 13 10 13.4 6.125'' 10.10 PDC - Long gauge 10.10 Size 84.9/15.1 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: N/A Nabors 19AC Report For: Morning Report Report # 72 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope ROP ROP (ft/hr) 3.55 @ Mud Data Depth Condition 30-Oct-2013 11:59 PM Current Pump & Flow Data: N/A Max 0 (lb/bbl) 7.51 Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime . . * 24 hr Recap: N/A Units* trip out of hole from 12754' MD to 7961' MD. Continue pulling out of hole at report time. 12925' MD to 19858' MD and set liner. Circulate, drop ball and set liner hanger on seat. Lay down drill pipe, pump dry job and Circulate bottoms up at 1.5 to 2 bpm at 12925' MD and condition mud. Continue to run into hole with liner on 4" drill pipe from Fluids = 0 bbls lost downhole Max Gas = 0 units, Avg Gas = 0 units Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 0 31-Oct-2013 11:59 PM Current Pump & Flow Data: N/A Max ROP ROP (ft/hr) 3.55 @ Mud Data MWD Summary HTHP Avg Min Depth Condition Morning Report Report # 73 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: 96% Rig Activity: N/A Nabors 19AC Report For: Tools N/A N/A 1-3-BT-N-X-I-CT-TD Bit # 13 10 13.8 6.125'' 10.10 PDC - Long gauge 10.20 Size 84.2/15.8 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 0 Chromatograph (ppm) 12klb 14334' 19868' WOB Hydril Comments RPM ECD (ppg) ml/30min N/A Background (max) Trip Average N/A Mud Type Lst Hydril Type in Minimum 80.0 ENVIROMUL 6.4 19868'26 Depth in / out YP (lb/100ft 2) 3.340 000 0 Sid Cht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 0 0 Ss Ratio C-1 C-5i AK-AM-900261430 Tripping Out PV 5534' Footage 179.18 Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 0 0 0 (current) Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 19868' 19868' 0' Max @ ft Current N/A N/A Date: Time: N/A N/A Depth C-5n N/A N/A C-2 N/A SPP (psi) Gallons/stroke TFA L-80 Oil/Water N/A ASG 0.390 9.625'' N/A N/A Casing Summary Size 60.0 L-80 Grade Lithology (%) cP 28 84 00 Set At 0 0 907-670-6636 Unit Phone: 0 Martin Nnaji Report By: 0 L-80 12984' Bit Type Maximum Cly 0 11.75'' 7" Logging Engineers: Kerry Garner / Martin Nnaji (max) (current) Liner 0 0 . . * 24 hr Recap: N/A Units* equipment. Lay down 4" drill pipe from 7961' MD to 66' MD. Test BOP and rig down test equipment. Rig up Tesco and Halliburton Fluids = 0 bbls lost downhole Max Gas = 0 units, Avg Gas = 0 units Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 0 1-Nov-2013 11:59 PM Current Pump & Flow Data: N/A Max ROP ROP (ft/hr) 3.55 @ Mud Data MWD Summary HTHP Avg Min Depth Condition Morning Report Report # 74 Customer: Well: Area: Location: Rig: ODSN-04 Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: 96% Rig Activity: N/A Nabors 19AC Report For: Tools N/A N/A 1-3-BT-N-X-I-CT-TD Bit # 13 10 6.125'' 10.10 PDC - Long gauge 10.10 Size 19868' WOB Hydril 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection RPM ECD (ppg) ml/30min 80.0 ASG 12klb Comments 0 Chromatograph (ppm) (max) Trip N/A Background Average N/A Mud Type Lst Hydril Type in Minimum Brine 19868' Depth in / out 0.390 YP (lb/100ft 2) 000 0 Sid Cht Silt C-4i C-4n 40.0 Weight 0 Hours C-3 0 14334' Ss Ratio C-1 C-5i AK-AM-900261430 R/U to Run 4.5" Tubing PV 24 hr Max 5534' Footage 179.18 Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl Coal 25.7 Gas Summary 0 0 0 (current) Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Flow In (spm) Depth 19868' 19868' 0' Max @ ft Current N/A N/A Date: Time: N/A N/A 0 C-5n N/A N/A C-2 N/A SPP (psi) Gallons/stroke TFA L-80 Oil/Water N/A 9.625'' N/A N/A Casing Summary Size 60.0 L-80 Grade L-80 12984' cP 28 00 Set At Depth 0 0 907-670-6636 Unit Phone: 0 Martin Nnaji Report By: 0 Logging Engineers: Bit Type Maximum Cly 0 11.75'' 7" Kerry Garner / Martin Nnaji (max) (current) Liner 0 0 Lithology (%) . . * 24 hr Recap: Kerry Garner / Martin Nnaji (max) (current) Liner 0 0 Lithology (%) 0 Logging Engineers: Bit Type Maximum Cly 0 0 0 907-670-6636 Unit Phone: Martin Nnaji Report By: 00 Set At Depth Casing Summary Size 60.0 L-80 Grade L-80 12984' 11.75'' 7" L-80 Oil/Water N/A 9.625'' N/A N/A cP 28 N/A C-2 N/A N/A N/A 0 C-5n N/A 0 Date: Time: SPP (psi) Gallons/stroke Flow In (spm) Depth 19868' 19868' 0' Max @ ft Current N/A N/A Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Coal 25.7 Gas Summary 0 0 0 (current) Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl 5534' Footage 179.18 TFA Ss Ratio C-1 C-5i AK-AM-900261430 TIH with 4.5" Tubing PV 24 hr Max 40.0 Weight 0 Hours C-3 0 14334' Sid Cht Silt C-4i C-4n 000 0 Brine 19868' Depth in / out 0.390 Mud Type Lst Hydril Type in Minimum Average N/A (max) Trip N/A Background Comments 0 Chromatograph (ppm) RPM ECD (ppg) ml/30min 80.0 ASG 12klb YP (lb/100ft 2) 19868' WOB Hydril 10375' 5294' 100% Gas In Air =10,000 Units N/A Connection 1-3-BT-N-X-I-CT-TD Bit # 13 10 6.125'' 10.10 PDC - Long gauge 10.10 Size 96% Rig Activity: N/A Nabors 19AC Report For: Tools N/A N/A Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Depth Condition Morning Report Report # 75 Customer: Well: Area: Location: Rig: ODSN-04 ROP ROP (ft/hr) 3.55 @ Mud Data MWD Summary HTHP Avg Min 2-Nov-2013 11:59 PM Current Pump & Flow Data: N/A Max 0 (lb/bbl) Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime Fluids = 0 bbls lost downhole Max Gas = 0 units, Avg Gas = 0 units N/A Units* Routine maintenance of mudloggers gas equipment in progress. for 10min. Trip into hole with 4.5" tubing from 139' MD to 12426' MD, cannon clamp every connection.Continue tripping into hole. Hang control line sheave and trip into hole with 4.5" tubing to 139' MD. Make up ROC guage and test control line to 500 psi . . * 24 hr Recap: Kerry Garner / Martin Nnaji (max) (current) 0 0 Lithology (%) 0 Logging Engineers: Bit Type Maximum Cly 0 0 0 907-670-6636 Unit Phone: Martin Nnaji Report By: 00 Set At Depth Casing Summary Size Grade Oil/Water N/A N/A N/A cP 28 N/A C-2 N/A N/A N/A 0 C-5n N/A 0 Date: Time: SPP (psi) Gallons/stroke Flow In (spm) Depth 0' 0' 0' Max @ ft Current N/A N/A Avg to N/A Yesterday's Depth: Current Depth: 24 Hour Progress: N/A Flow In (gpm) Coal Gas Summary 0 0 0 (current) Siltst J. Polya / T. DeRanger Sh Clyst Tuff Gvl Footage TFA Ss Ratio C-1 C-5i AK-AM-900261430 Rig Move PV 24 hr Max Weight 0 Hours C-3 0 Sid Cht Silt C-4i C-4n 000 0 Brine 19868' Depth in / out Mud Type Lst Type in Minimum Average N/A (max) Trip N/A Background Comments 0 Chromatograph (ppm) RPM ECD (ppg) ml/30min ASG YP (lb/100ft 2) WOB 100% Gas In Air =10,000 Units N/A Connection Bit # 13 10.10 10.10 Size 96% Rig Activity: N/A Nabors 19AC Report For: Tools N/A N/A Pioneer Natural Resources Oooguruk North Slope Job No.: Daily Charges: Total Charges: Depth Condition Morning Report Report # 76 Customer: Well: Area: Location: Rig: ROP ROP (ft/hr) 3.55 @ Mud Data MWD Summary HTHP Avg Min 3-Nov-2013 11:59 PM Current Pump & Flow Data: N/A Max 0 (lb/bbl) Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime Fluids = 0 bbls lost downhole Max Gas = 0 units, Avg Gas = 0 units N/A Units* WELL INFORMATION Created On : Nov 15 2013 Customer :Pioneer Natural Resources, Inc. Well Name :ODSN-04 PB1 Job Number :AK-XX-0900261430 Rig Name :Nabors 19AC Field Name :Oooguruk Country :USA Survey Report DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 42.70 0.00 0.00 42.70 0.00 N 0.00 E 0.00 0.00 112.00 0.48 26.30 112.00 0.26 N 0.13 E 0.19 0.69 174.00 1.19 320.91 173.99 0.99 N 0.16 W 0.98 1.75 201.00 1.94 309.55 200.98 1.50 N 0.69 W 1.65 2.99 263.00 2.42 301.95 262.94 2.86 N 2.61 W 3.62 0.90 356.00 4.89 284.85 355.74 4.92 N 8.11 W 7.55 2.87 448.00 7.48 301.23 447.21 9.03 N 17.02 W 14.65 3.38 541.00 11.08 306.95 538.98 17.54 N 29.34 W 27.09 3.99 637.00 16.68 305.79 632.14 31.15 N 47.91 W 46.57 5.84 732.00 20.18 307.43 722.25 49.09 N 71.99 W 72.10 3.72 774.62 22.52 311.69 761.95 58.99 N 83.92 W 85.69 6.58 870.41 25.53 307.68 849.43 83.82 N 113.97 W 119.82 3.57 965.82 25.86 306.69 935.41 108.82 N 146.92 W 155.18 0.57 1060.78 27.64 303.55 1,020.21 133.37 N 181.89 W 190.86 2.39 1158.91 31.45 307.91 1,105.57 161.69 N 221.08 W 231.59 4.46 1253.31 31.34 310.24 1,186.15 192.68 N 259.25 W 274.44 1.29 1346.25 31.25 316.29 1,265.59 225.73 N 294.37 W 318.07 3.38 1441.64 33.89 322.68 1,346.00 264.78 N 327.60 W 366.61 4.54 1539.14 34.36 327.67 1,426.73 309.66 N 358.80 W 419.81 2.91 1629.82 33.18 331.63 1,502.11 353.12 N 384.28 W 469.59 2.75 1726.75 36.11 338.96 1,581.88 403.15 N 407.16 W 524.52 5.25 1818.84 36.88 343.11 1,655.93 454.93 N 424.93 W 579.21 2.81 1917.03 41.42 348.78 1,732.08 515.03 N 439.82 W 640.58 5.88 2010.33 43.80 350.53 1,800.74 577.16 N 451.14 W 702.53 2.85 2104.90 46.99 351.69 1,867.14 643.67 N 461.53 W 768.21 3.48 2201.72 48.91 352.43 1,931.99 714.88 N 471.45 W 838.08 2.06 2297.04 50.46 352.48 1,993.66 786.93 N 480.99 W 908.59 1.63 2389.45 54.12 353.13 2,050.17 859.45 N 490.14 W 979.40 4.00 2486.35 56.99 354.61 2,104.98 938.89 N 498.65 W 1056.42 3.22 2579.35 60.23 355.02 2,153.41 1,017.94 N 505.82 W 1132.58 3.50 2675.53 59.59 354.48 2,201.63 1,100.81 N 513.44 W 1212.45 0.82 2770.12 64.22 353.33 2,246.17 1,183.76 N 522.31 W 1292.86 5.01 INSITE V8.0.0 Page 1Job No:AK-XX-0900261430 Well Name:ODSN-04 PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2861.85 66.78 356.02 2,284.21 1,266.85 N 530.04 W 1372.99 3.86 2957.20 66.70 354.94 2,321.86 1,354.18 N 536.94 W 1456.74 1.04 3053.86 64.00 352.89 2,362.18 1,441.52 N 546.23 W 1541.40 3.39 3147.12 63.78 351.99 2,403.22 1,524.54 N 557.25 W 1622.65 0.90 3241.30 63.71 353.29 2,444.88 1,608.30 N 568.07 W 1704.54 1.24 3337.04 63.45 353.54 2,487.48 1,693.48 N 577.90 W 1787.37 0.36 3431.96 64.04 354.11 2,529.47 1,778.11 N 587.06 W 1869.45 0.82 3526.22 64.68 354.57 2,570.26 1,862.67 N 595.44 W 1951.18 0.81 3620.86 65.21 353.55 2,610.34 1,947.95 N 604.31 W 2033.75 1.13 3716.97 64.70 353.40 2,651.03 2,034.46 N 614.21 W 2117.85 0.55 3812.31 63.59 351.70 2,692.61 2,119.52 N 625.32 W 2201.05 1.98 3907.31 64.94 352.84 2,733.86 2,204.32 N 636.83 W 2284.15 1.79 4002.73 66.49 353.60 2,773.10 2,290.68 N 647.09 W 2368.25 1.78 4097.78 65.80 352.86 2,811.54 2,377.01 N 657.34 W 2452.30 1.02 4192.46 64.58 353.57 2,851.27 2,462.34 N 667.50 W 2535.40 1.46 4286.51 64.15 353.45 2,891.96 2,546.59 N 677.08 W 2617.28 0.47 4382.61 61.86 353.42 2,935.58 2,631.65 N 686.87 W 2699.99 2.38 4478.55 62.40 353.32 2,980.42 2,715.90 N 696.66 W 2781.94 0.57 4572.77 62.63 355.68 3,023.91 2,799.09 N 704.67 W 2862.26 2.24 4668.11 63.59 356.26 3,067.03 2,883.91 N 710.64 W 2943.35 1.14 4763.20 63.42 354.83 3,109.46 2,968.75 N 717.25 W 3024.69 1.36 4857.09 63.74 353.78 3,151.23 3,052.42 N 725.60 W 3105.57 1.06 4952.65 64.20 353.35 3,193.17 3,137.75 N 735.22 W 3188.47 0.63 5048.13 64.16 352.56 3,234.76 3,223.04 N 745.76 W 3271.67 0.75 5143.34 63.18 351.98 3,276.99 3,307.60 N 757.24 W 3354.53 1.17 5238.40 64.12 352.00 3,319.18 3,391.95 N 769.11 W 3437.35 0.99 5320.00 64.14 353.52 3,354.78 3,464.79 N 778.36 W 3508.49 1.68 5371.78 63.74 353.06 3,377.53 3,510.98 N 783.80 W 3553.45 1.11 5467.39 64.21 354.99 3,419.49 3,596.43 N 792.74 W 3636.21 1.88 5562.63 64.48 354.64 3,460.72 3,681.92 N 800.50 W 3718.58 0.44 5657.38 64.74 354.41 3,501.35 3,767.13 N 808.66 W 3800.83 0.35 5752.70 64.40 354.49 3,542.28 3,852.81 N 816.99 W 3883.58 0.36 5847.78 64.21 354.38 3,583.50 3,938.09 N 825.30 W 3965.95 0.23 5942.61 64.08 355.16 3,624.86 4,023.07 N 833.08 W 4047.85 0.75 6036.56 63.79 354.83 3,666.14 4,107.14 N 840.44 W 4128.75 0.44 6132.10 63.67 354.78 3,708.42 4,192.46 N 848.20 W 4210.95 0.13 6224.71 63.87 355.21 3,749.36 4,275.22 N 855.44 W 4290.59 0.47 6322.72 64.41 354.73 3,792.11 4,363.07 N 863.18 W 4375.14 0.71 6417.83 64.55 355.10 3,833.08 4,448.57 N 870.79 W 4457.45 0.38 6512.73 64.47 355.28 3,873.92 4,533.93 N 877.97 W 4539.48 0.19 6607.37 63.79 354.03 3,915.22 4,618.71 N 885.90 W 4621.25 1.39 6702.87 63.65 355.08 3,957.50 4,703.95 N 894.02 W 4703.52 1.00 6798.37 63.09 354.25 4,000.31 4,788.95 N 901.96 W 4785.49 0.97 6891.40 63.14 354.45 4,042.38 4,871.52 N 910.13 W 4865.29 0.20 6987.87 63.30 355.19 4,085.84 4,957.29 N 917.90 W 4947.92 0.70 INSITE V8.0.0 Page 2Job No:AK-XX-0900261430 Well Name:ODSN-04 PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 7083.12 63.54 355.18 4,128.46 5,042.17 N 925.05 W 5029.50 0.25 7177.84 64.08 355.96 4,170.27 5,126.91 N 931.62 W 5110.73 0.93 7270.68 64.35 356.37 4,210.65 5,210.32 N 937.21 W 5190.36 0.49 7366.93 64.21 356.49 4,252.42 5,296.87 N 942.61 W 5272.84 0.18 7461.72 64.42 356.15 4,293.51 5,382.12 N 948.09 W 5354.14 0.39 7556.46 64.01 354.30 4,334.72 5,467.12 N 955.19 W 5435.81 1.81 7651.42 63.80 356.32 4,376.49 5,552.11 N 962.16 W 5517.42 1.92 7747.28 64.07 355.71 4,418.61 5,638.01 N 968.15 W 5599.51 0.64 7840.95 64.37 355.62 4,459.35 5,722.12 N 974.53 W 5680.08 0.33 7934.71 64.27 354.35 4,499.98 5,806.29 N 981.91 W 5761.08 1.23 8028.65 64.00 353.91 4,540.97 5,890.38 N 990.56 W 5842.47 0.51 8124.90 64.34 353.97 4,582.90 5,976.53 N 999.70 W 5925.96 0.36 8221.76 64.22 354.44 4,624.94 6,063.34 N 1,008.51 W 6009.94 0.45 8316.01 64.42 354.12 4,665.78 6,147.86 N 1,016.98 W 6091.66 0.37 8408.97 64.22 354.57 4,706.06 6,231.23 N 1,025.23 W 6172.23 0.49 8504.62 64.20 353.81 4,747.68 6,316.91 N 1,033.95 W 6255.13 0.72 8601.35 63.93 354.45 4,789.98 6,403.44 N 1,042.85 W 6338.88 0.66 8696.80 63.68 354.20 4,832.12 6,488.67 N 1,051.32 W 6421.26 0.35 8791.47 64.07 354.30 4,873.80 6,573.24 N 1,059.83 W 6503.04 0.42 8885.77 64.00 354.12 4,915.09 6,657.59 N 1,068.39 W 6584.64 0.19 8980.14 63.85 354.26 4,956.57 6,741.92 N 1,076.97 W 6666.22 0.21 9075.61 64.07 354.80 4,998.48 6,827.31 N 1,085.14 W 6748.65 0.56 9169.87 63.87 354.70 5,039.85 6,911.65 N 1,092.90 W 6829.94 0.23 9265.51 63.85 355.19 5,081.98 6,997.17 N 1,100.46 W 6912.27 0.46 9360.79 64.09 355.19 5,123.80 7,082.49 N 1,107.64 W 6994.25 0.25 9455.74 64.36 355.55 5,165.08 7,167.71 N 1,114.54 W 7076.05 0.44 9549.72 64.22 355.79 5,205.85 7,252.14 N 1,120.93 W 7156.93 0.27 9647.28 63.95 355.49 5,248.49 7,339.64 N 1,127.60 W 7240.76 0.39 9742.22 64.02 355.76 5,290.13 7,424.71 N 1,134.11 W 7322.28 0.27 9837.04 64.41 355.17 5,331.38 7,509.82 N 1,140.87 W 7403.92 0.70 9930.55 64.61 354.84 5,371.62 7,593.91 N 1,148.21 W 7484.83 0.38 10026.77 64.14 355.21 5,413.24 7,680.34 N 1,155.74 W 7567.98 0.60 10122.59 63.86 354.12 5,455.24 7,766.09 N 1,163.75 W 7650.67 1.06 10215.44 64.07 353.96 5,496.00 7,849.06 N 1,172.41 W 7731.03 0.27 10311.87 64.21 354.01 5,538.06 7,935.36 N 1,181.50 W 7814.64 0.15 10342.37 64.22 354.05 5,551.32 7,962.67 N 1,184.36 W 7841.09 0.12 10445.79 64.14 354.03 5,596.37 8,055.26 N 1,194.02 W 7930.76 0.08 10538.73 64.13 354.41 5,636.92 8,138.47 N 1,202.45 W 8011.24 0.37 10634.01 64.26 353.84 5,678.40 8,223.79 N 1,211.23 W 8093.83 0.56 10729.76 64.56 353.43 5,719.75 8,309.62 N 1,220.80 W 8177.17 0.50 10826.05 65.03 352.69 5,760.76 8,396.10 N 1,231.33 W 8261.48 0.85 10920.84 65.38 353.91 5,800.51 8,481.56 N 1,241.37 W 8344.65 1.23 11017.61 64.89 353.99 5,841.20 8,568.87 N 1,250.62 W 8429.26 0.51 11112.57 65.10 352.26 5,881.34 8,654.31 N 1,260.92 W 8512.50 1.67 11207.52 64.90 351.35 5,921.47 8,739.48 N 1,273.19 W 8596.23 0.89 INSITE V8.0.0 Page 3Job No:AK-XX-0900261430 Well Name:ODSN-04 PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 11302.45 65.05 351.28 5,961.63 8,824.52 N 1,286.18 W 8680.09 0.17 11397.89 65.03 351.69 6,001.90 8,910.09 N 1,298.99 W 8764.39 0.39 11492.65 64.96 351.62 6,041.96 8,995.06 N 1,311.45 W 8847.99 0.10 11588.46 65.31 346.93 6,082.26 9,080.43 N 1,327.63 W 8933.34 4.46 11683.69 65.92 343.81 6,121.59 9,164.34 N 1,349.54 W 9019.43 3.05 11778.82 67.22 342.65 6,159.41 9,247.91 N 1,374.73 W 9106.41 1.77 11873.85 69.30 342.06 6,194.61 9,332.02 N 1,401.48 W 9194.47 2.26 11968.41 71.04 341.11 6,226.69 9,416.41 N 1,429.59 W 9283.29 2.07 12057.59 73.05 339.73 6,254.18 9,496.34 N 1,458.02 W 9368.07 2.69 12155.55 73.49 336.61 6,282.39 9,583.41 N 1,492.90 W 9461.87 3.08 12254.12 75.42 335.60 6,308.80 9,670.23 N 1,531.37 W 9556.74 2.19 12347.92 77.33 333.11 6,330.90 9,752.39 N 1,570.83 W 9647.66 3.29 12443.74 79.46 331.19 6,350.18 9,835.37 N 1,614.68 W 9740.94 2.97 12538.91 80.33 330.11 6,366.87 9,917.04 N 1,660.60 W 9833.77 1.44 12634.53 82.15 328.07 6,381.44 9,998.11 N 1,709.14 W 9927.00 2.84 12714.27 84.51 325.58 6,390.70 10,064.39 N 1,752.48 W 10004.57 4.29 12722.03 84.47 325.84 6,391.44 10,070.77 N 1,756.83 W 10012.10 3.37 12818.82 85.96 322.11 6,399.52 10,148.76 N 1,813.55 W 10105.47 4.14 12914.81 84.78 322.05 6,407.27 10,224.23 N 1,872.35 W 10197.27 1.23 12944.74 84.28 321.89 6,410.12 10,247.70 N 1,890.70 W 10225.84 1.75 13013.79 84.94 322.54 6,416.61 10,302.03 N 1,932.82 W 10291.84 1.34 13060.60 88.15 323.52 6,419.43 10,339.36 N 1,960.92 W 10336.88 7.17 13112.77 90.07 324.18 6,420.24 10,381.47 N 1,991.69 W 10387.35 3.89 13156.91 90.38 323.67 6,420.07 10,417.15 N 2,017.68 W 10430.08 1.35 13253.77 90.26 322.62 6,419.53 10,494.65 N 2,075.77 W 10523.50 1.09 13349.68 91.37 323.45 6,418.17 10,571.27 N 2,133.44 W 10615.95 1.44 13445.77 89.68 319.44 6,417.29 10,646.39 N 2,193.31 W 10707.81 4.53 13541.94 88.96 319.85 6,418.43 10,719.68 N 2,255.58 W 10798.85 0.86 13635.88 90.62 320.74 6,418.77 10,791.94 N 2,315.59 W 10888.10 2.01 13732.24 91.00 322.35 6,417.40 10,867.39 N 2,375.51 W 10980.29 1.71 13828.85 91.31 320.29 6,415.46 10,942.79 N 2,435.87 W 11072.59 2.16 13925.26 90.06 319.10 6,414.31 11,016.31 N 2,498.23 W 11163.87 1.79 14023.18 88.26 317.86 6,415.75 11,089.61 N 2,563.13 W 11255.89 2.23 14070.26 86.32 318.82 6,417.98 11,124.74 N 2,594.38 W 11300.04 4.61 14118.30 87.29 319.64 6,420.66 11,161.07 N 2,625.71 W 11345.34 2.64 14212.80 91.79 323.74 6,421.42 11,235.18 N 2,684.26 W 11435.77 6.44 14264.39 90.67 322.64 6,420.31 11,276.47 N 2,715.16 W 11485.53 3.05 14308.96 90.81 321.78 6,419.74 11,311.69 N 2,742.47 W 11528.32 1.96 14405.58 91.55 322.42 6,417.74 11,387.92 N 2,801.81 W 11621.01 1.01 14501.94 91.12 321.82 6,415.50 11,463.95 N 2,860.96 W 11713.46 0.77 14599.02 91.12 320.07 6,413.60 11,539.32 N 2,922.11 W 11806.02 1.80 14695.67 92.42 320.40 6,410.62 11,613.58 N 2,983.90 W 11897.78 1.38 14695.67 92.42 320.40 6,410.62 11,613.58 N 2,983.90 W 11897.78 1.38 14751.21 93.04 321.27 6,407.97 11,656.59 N 3,018.94 W 11950.66 1.92 14810.00 93.04 321.27 6,404.86 11,702.39 N 3,055.67 W 12006.75 0.01 INSITE V8.0.0 Page 4Job No:AK-XX-0900261430 Well Name:ODSN-04 PB1 Survey Report WELL INFORMATION Created On : Nov 15 2013 Customer :Pioneer Natural Resources, Inc. Well Name :ODSN-04 Job Number :AK-XX-0900261430 Rig Name :Nabors 19AC Field Name :Oooguruk Country :USA Survey Report DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 42.70 0.00 0.00 42.70 0.00 N 0.00 E 0.00 0.00 112.00 0.48 26.30 112.00 0.26 N 0.13 E 0.19 0.69 174.00 1.19 320.91 173.99 0.99 N 0.16 W 0.98 1.75 201.00 1.94 309.55 200.98 1.50 N 0.69 W 1.65 2.99 263.00 2.42 301.95 262.94 2.86 N 2.61 W 3.62 0.90 356.00 4.89 284.85 355.74 4.92 N 8.11 W 7.55 2.87 448.00 7.48 301.23 447.21 9.03 N 17.02 W 14.65 3.38 541.00 11.08 306.95 538.98 17.54 N 29.34 W 27.09 3.99 637.00 16.68 305.79 632.14 31.15 N 47.91 W 46.57 5.84 732.00 20.18 307.43 722.25 49.09 N 71.99 W 72.10 3.72 774.62 22.52 311.69 761.95 58.99 N 83.92 W 85.69 6.58 870.41 25.53 307.68 849.43 83.82 N 113.97 W 119.82 3.57 965.82 25.86 306.69 935.41 108.82 N 146.92 W 155.18 0.57 1060.78 27.64 303.55 1,020.21 133.37 N 181.89 W 190.86 2.39 1158.91 31.45 307.91 1,105.57 161.69 N 221.08 W 231.59 4.46 1253.31 31.34 310.24 1,186.15 192.68 N 259.25 W 274.44 1.29 1346.25 31.25 316.29 1,265.59 225.73 N 294.37 W 318.07 3.38 1441.64 33.89 322.68 1,346.00 264.78 N 327.60 W 366.61 4.54 1539.14 34.36 327.67 1,426.73 309.66 N 358.80 W 419.81 2.91 1629.82 33.18 331.63 1,502.11 353.12 N 384.28 W 469.59 2.75 1726.75 36.11 338.96 1,581.88 403.15 N 407.16 W 524.52 5.25 1818.84 36.88 343.11 1,655.93 454.93 N 424.93 W 579.21 2.81 1917.03 41.42 348.78 1,732.08 515.03 N 439.82 W 640.58 5.88 2010.33 43.80 350.53 1,800.74 577.16 N 451.14 W 702.53 2.85 2104.90 46.99 351.69 1,867.14 643.67 N 461.53 W 768.21 3.48 2201.72 48.91 352.43 1,931.99 714.88 N 471.45 W 838.08 2.06 2297.04 50.46 352.48 1,993.66 786.93 N 480.99 W 908.59 1.63 2389.45 54.12 353.13 2,050.17 859.45 N 490.14 W 979.40 4.00 2486.35 56.99 354.61 2,104.98 938.89 N 498.65 W 1056.42 3.22 2579.35 60.23 355.02 2,153.41 1,017.94 N 505.82 W 1132.58 3.50 2675.53 59.59 354.48 2,201.63 1,100.81 N 513.44 W 1212.45 0.82 2770.12 64.22 353.33 2,246.17 1,183.76 N 522.31 W 1292.86 5.01 INSITE V8.0.0 Page 1Job No:AK-XX-0900261430 Well Name:ODSN-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2861.85 66.78 356.02 2,284.21 1,266.85 N 530.04 W 1372.99 3.86 2957.20 66.70 354.94 2,321.86 1,354.18 N 536.94 W 1456.74 1.04 3053.86 64.00 352.89 2,362.18 1,441.52 N 546.23 W 1541.40 3.39 3147.12 63.78 351.99 2,403.22 1,524.54 N 557.25 W 1622.65 0.90 3241.30 63.71 353.29 2,444.88 1,608.30 N 568.07 W 1704.54 1.24 3337.04 63.45 353.54 2,487.48 1,693.48 N 577.90 W 1787.37 0.36 3431.96 64.04 354.11 2,529.47 1,778.11 N 587.06 W 1869.45 0.82 3526.22 64.68 354.57 2,570.26 1,862.67 N 595.44 W 1951.18 0.81 3620.86 65.21 353.55 2,610.34 1,947.95 N 604.31 W 2033.75 1.13 3716.97 64.70 353.40 2,651.03 2,034.46 N 614.21 W 2117.85 0.55 3812.31 63.59 351.70 2,692.61 2,119.52 N 625.32 W 2201.05 1.98 3907.31 64.94 352.84 2,733.86 2,204.32 N 636.83 W 2284.15 1.79 4002.73 66.49 353.60 2,773.10 2,290.68 N 647.09 W 2368.25 1.78 4097.78 65.80 352.86 2,811.54 2,377.01 N 657.34 W 2452.30 1.02 4192.46 64.58 353.57 2,851.27 2,462.34 N 667.50 W 2535.40 1.46 4286.51 64.15 353.45 2,891.96 2,546.59 N 677.08 W 2617.28 0.47 4382.61 61.86 353.42 2,935.58 2,631.65 N 686.87 W 2699.99 2.38 4478.55 62.40 353.32 2,980.42 2,715.90 N 696.66 W 2781.94 0.57 4572.77 62.63 355.68 3,023.91 2,799.09 N 704.67 W 2862.26 2.24 4668.11 63.59 356.26 3,067.03 2,883.91 N 710.64 W 2943.35 1.14 4763.20 63.42 354.83 3,109.46 2,968.75 N 717.25 W 3024.69 1.36 4857.09 63.74 353.78 3,151.23 3,052.42 N 725.60 W 3105.57 1.06 4952.65 64.20 353.35 3,193.17 3,137.75 N 735.22 W 3188.47 0.63 5048.13 64.16 352.56 3,234.76 3,223.04 N 745.76 W 3271.67 0.75 5143.34 63.18 351.98 3,276.99 3,307.60 N 757.24 W 3354.53 1.17 5238.40 64.12 352.00 3,319.18 3,391.95 N 769.11 W 3437.35 0.99 5320.00 64.14 353.52 3,354.78 3,464.79 N 778.36 W 3508.49 1.68 5371.78 63.74 353.06 3,377.53 3,510.98 N 783.80 W 3553.45 1.11 5467.39 64.21 354.99 3,419.49 3,596.43 N 792.74 W 3636.21 1.88 5562.63 64.48 354.64 3,460.72 3,681.92 N 800.50 W 3718.58 0.44 5657.38 64.74 354.41 3,501.35 3,767.13 N 808.66 W 3800.83 0.35 5752.70 64.40 354.49 3,542.28 3,852.81 N 816.99 W 3883.58 0.36 5847.78 64.21 354.38 3,583.50 3,938.09 N 825.30 W 3965.95 0.23 5942.61 64.08 355.16 3,624.86 4,023.07 N 833.08 W 4047.85 0.75 6036.56 63.79 354.83 3,666.14 4,107.14 N 840.44 W 4128.75 0.44 6132.10 63.67 354.78 3,708.42 4,192.46 N 848.20 W 4210.95 0.13 6224.71 63.87 355.21 3,749.36 4,275.22 N 855.44 W 4290.59 0.47 6322.72 64.41 354.73 3,792.11 4,363.07 N 863.18 W 4375.14 0.71 6417.83 64.55 355.10 3,833.08 4,448.57 N 870.79 W 4457.45 0.38 6512.73 64.47 355.28 3,873.92 4,533.93 N 877.97 W 4539.48 0.19 6607.37 63.79 354.03 3,915.22 4,618.71 N 885.90 W 4621.25 1.39 6702.87 63.65 355.08 3,957.50 4,703.95 N 894.02 W 4703.52 1.00 6798.37 63.09 354.25 4,000.31 4,788.95 N 901.96 W 4785.49 0.97 6891.40 63.14 354.45 4,042.38 4,871.52 N 910.13 W 4865.29 0.20 6987.87 63.30 355.19 4,085.84 4,957.29 N 917.90 W 4947.92 0.70 INSITE V8.0.0 Page 2Job No:AK-XX-0900261430 Well Name:ODSN-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 7083.12 63.54 355.18 4,128.46 5,042.17 N 925.05 W 5029.50 0.25 7177.84 64.08 355.96 4,170.27 5,126.91 N 931.62 W 5110.73 0.93 7270.68 64.35 356.37 4,210.65 5,210.32 N 937.21 W 5190.36 0.49 7366.93 64.21 356.49 4,252.42 5,296.87 N 942.61 W 5272.84 0.18 7461.72 64.42 356.15 4,293.51 5,382.12 N 948.09 W 5354.14 0.39 7556.46 64.01 354.30 4,334.72 5,467.12 N 955.19 W 5435.81 1.81 7651.42 63.80 356.32 4,376.49 5,552.11 N 962.16 W 5517.42 1.92 7747.28 64.07 355.71 4,418.61 5,638.01 N 968.15 W 5599.51 0.64 7840.95 64.37 355.62 4,459.35 5,722.12 N 974.53 W 5680.08 0.33 7934.71 64.27 354.35 4,499.98 5,806.29 N 981.91 W 5761.08 1.23 8028.65 64.00 353.91 4,540.97 5,890.38 N 990.56 W 5842.47 0.51 8124.90 64.34 353.97 4,582.90 5,976.53 N 999.70 W 5925.96 0.36 8221.76 64.22 354.44 4,624.94 6,063.34 N 1,008.51 W 6009.94 0.45 8316.01 64.42 354.12 4,665.78 6,147.86 N 1,016.98 W 6091.66 0.37 8408.97 64.22 354.57 4,706.06 6,231.23 N 1,025.23 W 6172.23 0.49 8504.62 64.20 353.81 4,747.68 6,316.91 N 1,033.95 W 6255.13 0.72 8601.35 63.93 354.45 4,789.98 6,403.44 N 1,042.85 W 6338.88 0.66 8696.80 63.68 354.20 4,832.12 6,488.67 N 1,051.32 W 6421.26 0.35 8791.47 64.07 354.30 4,873.80 6,573.24 N 1,059.83 W 6503.04 0.42 8885.77 64.00 354.12 4,915.09 6,657.59 N 1,068.39 W 6584.64 0.19 8980.14 63.85 354.26 4,956.57 6,741.92 N 1,076.97 W 6666.22 0.21 9075.61 64.07 354.80 4,998.48 6,827.31 N 1,085.14 W 6748.65 0.56 9169.87 63.87 354.70 5,039.85 6,911.65 N 1,092.90 W 6829.94 0.23 9265.51 63.85 355.19 5,081.98 6,997.17 N 1,100.46 W 6912.27 0.46 9360.79 64.09 355.19 5,123.80 7,082.49 N 1,107.64 W 6994.25 0.25 9455.74 64.36 355.55 5,165.08 7,167.71 N 1,114.54 W 7076.05 0.44 9549.72 64.22 355.79 5,205.85 7,252.14 N 1,120.93 W 7156.93 0.27 9647.28 63.95 355.49 5,248.49 7,339.64 N 1,127.60 W 7240.76 0.39 9742.22 64.02 355.76 5,290.13 7,424.71 N 1,134.11 W 7322.28 0.27 9837.04 64.41 355.17 5,331.38 7,509.82 N 1,140.87 W 7403.92 0.70 9930.55 64.61 354.84 5,371.62 7,593.91 N 1,148.21 W 7484.83 0.38 10026.77 64.14 355.21 5,413.24 7,680.34 N 1,155.74 W 7567.98 0.60 10122.59 63.86 354.12 5,455.24 7,766.09 N 1,163.75 W 7650.67 1.06 10215.44 64.07 353.96 5,496.00 7,849.06 N 1,172.41 W 7731.03 0.27 10311.87 64.21 354.01 5,538.06 7,935.36 N 1,181.50 W 7814.64 0.15 10342.37 64.22 354.05 5,551.32 7,962.67 N 1,184.36 W 7841.09 0.12 10445.79 64.14 354.03 5,596.37 8,055.26 N 1,194.02 W 7930.76 0.08 10538.73 64.13 354.41 5,636.92 8,138.47 N 1,202.45 W 8011.24 0.37 10634.01 64.26 353.84 5,678.40 8,223.79 N 1,211.23 W 8093.83 0.56 10729.76 64.56 353.43 5,719.75 8,309.62 N 1,220.80 W 8177.17 0.50 10826.05 65.03 352.69 5,760.76 8,396.10 N 1,231.33 W 8261.48 0.85 10920.84 65.38 353.91 5,800.51 8,481.56 N 1,241.37 W 8344.65 1.23 11017.61 64.89 353.99 5,841.20 8,568.87 N 1,250.62 W 8429.26 0.51 11112.57 65.10 352.26 5,881.34 8,654.31 N 1,260.92 W 8512.50 1.67 11207.52 64.90 351.35 5,921.47 8,739.48 N 1,273.19 W 8596.23 0.89 INSITE V8.0.0 Page 3Job No:AK-XX-0900261430 Well Name:ODSN-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 11302.45 65.05 351.28 5,961.63 8,824.52 N 1,286.18 W 8680.09 0.17 11397.89 65.03 351.69 6,001.90 8,910.09 N 1,298.99 W 8764.39 0.39 11492.65 64.96 351.62 6,041.96 8,995.06 N 1,311.45 W 8847.99 0.10 11588.46 65.31 346.93 6,082.26 9,080.43 N 1,327.63 W 8933.34 4.46 11683.69 65.92 343.81 6,121.59 9,164.34 N 1,349.54 W 9019.43 3.05 11778.82 67.22 342.65 6,159.41 9,247.91 N 1,374.73 W 9106.41 1.77 11873.85 69.30 342.06 6,194.61 9,332.02 N 1,401.48 W 9194.47 2.26 11968.41 71.04 341.11 6,226.69 9,416.41 N 1,429.59 W 9283.29 2.07 12057.59 73.05 339.73 6,254.18 9,496.34 N 1,458.02 W 9368.07 2.69 12155.55 73.49 336.61 6,282.39 9,583.41 N 1,492.90 W 9461.87 3.08 12254.12 75.42 335.60 6,308.80 9,670.23 N 1,531.37 W 9556.74 2.19 12347.92 77.33 333.11 6,330.90 9,752.39 N 1,570.83 W 9647.66 3.29 12443.74 79.46 331.19 6,350.18 9,835.37 N 1,614.68 W 9740.94 2.97 12538.91 80.33 330.11 6,366.87 9,917.04 N 1,660.60 W 9833.77 1.44 12634.53 82.15 328.07 6,381.44 9,998.11 N 1,709.14 W 9927.00 2.84 12714.27 84.51 325.58 6,390.70 10,064.39 N 1,752.48 W 10004.57 4.29 12722.03 84.47 325.84 6,391.44 10,070.77 N 1,756.83 W 10012.10 3.37 12818.82 85.96 322.11 6,399.52 10,148.76 N 1,813.55 W 10105.47 4.14 12914.81 84.78 322.05 6,407.27 10,224.23 N 1,872.35 W 10197.27 1.23 12944.74 84.28 321.89 6,410.12 10,247.70 N 1,890.70 W 10225.84 1.75 13013.79 84.94 322.54 6,416.61 10,302.03 N 1,932.82 W 10291.84 1.34 13060.60 88.15 323.52 6,419.43 10,339.36 N 1,960.92 W 10336.88 7.17 13112.77 90.07 324.18 6,420.24 10,381.47 N 1,991.69 W 10387.35 3.89 13156.91 90.38 323.67 6,420.07 10,417.15 N 2,017.68 W 10430.08 1.35 13253.77 90.26 322.62 6,419.53 10,494.65 N 2,075.77 W 10523.50 1.09 13349.68 91.37 323.45 6,418.17 10,571.27 N 2,133.44 W 10615.95 1.44 13445.77 89.68 319.44 6,417.29 10,646.39 N 2,193.31 W 10707.81 4.53 13541.94 88.96 319.85 6,418.43 10,719.68 N 2,255.58 W 10798.85 0.86 13555.00 89.19 319.97 6,418.64 10,729.67 N 2,263.99 W 10811.23 1.98 13604.76 87.40 319.62 6,420.12 10,767.65 N 2,296.09 W 10858.35 3.67 13636.81 87.15 320.45 6,421.64 10,792.19 N 2,316.66 W 10888.72 2.70 13732.18 89.18 319.25 6,424.70 10,865.04 N 2,378.11 W 10979.05 2.47 13828.96 91.46 319.45 6,424.16 10,938.46 N 2,441.15 W 11070.50 2.37 13925.43 92.83 319.77 6,420.54 11,011.88 N 2,503.62 W 11161.74 1.46 14021.98 91.43 321.94 6,416.95 11,086.71 N 2,564.53 W 11253.70 2.67 14119.29 90.01 328.18 6,415.73 11,166.43 N 2,620.22 W 11348.31 6.58 14180.50 88.17 329.59 6,416.70 11,218.82 N 2,651.85 W 11408.66 3.79 14213.24 87.61 329.49 6,417.90 11,247.03 N 2,668.44 W 11440.98 1.75 14301.61 86.45 331.22 6,422.49 11,323.72 N 2,712.08 W 11528.34 2.35 14399.02 91.14 329.63 6,424.53 11,408.39 N 2,760.14 W 11624.75 5.08 14495.45 91.64 324.82 6,422.19 11,489.42 N 2,812.31 W 11719.28 5.01 14592.24 94.67 324.24 6,416.87 11,568.12 N 2,868.38 W 11813.07 3.19 14689.77 94.67 324.32 6,408.92 11,647.04 N 2,925.13 W 11907.32 0.08 14784.86 93.25 321.93 6,402.36 11,722.92 N 2,982.05 W 11998.80 2.92 14880.97 90.78 318.54 6,398.98 11,796.73 N 3,043.48 W 12090.02 4.36 INSITE V8.0.0 Page 4Job No:AK-XX-0900261430 Well Name:ODSN-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 14977.73 89.60 318.91 6,398.65 11,869.45 N 3,107.31 W 12181.10 1.28 15074.30 90.53 317.71 6,398.55 11,941.56 N 3,171.53 W 12271.76 1.57 15170.57 90.96 318.18 6,397.29 12,013.04 N 3,236.01 W 12361.92 0.66 15266.02 90.10 316.38 6,396.41 12,083.16 N 3,300.76 W 12450.92 2.09 15363.56 90.90 315.95 6,395.57 12,153.51 N 3,368.31 W 12541.17 0.93 15460.86 90.41 315.83 6,394.46 12,223.37 N 3,436.03 W 12631.02 0.52 15555.68 89.78 316.34 6,394.30 12,291.67 N 3,501.80 W 12718.71 0.85 15652.36 90.34 313.33 6,394.19 12,359.83 N 3,570.35 W 12807.28 3.17 15749.13 89.48 311.27 6,394.34 12,424.95 N 3,641.92 W 12894.14 2.31 15798.79 89.79 312.74 6,394.66 12,458.18 N 3,678.82 W 12938.60 3.02 15843.60 89.72 317.58 6,394.85 12,489.95 N 3,710.41 W 12979.75 10.80 15939.80 88.18 318.24 6,396.61 12,561.32 N 3,774.88 W 13069.81 1.74 16037.01 90.22 321.15 6,397.97 12,635.44 N 3,837.74 W 13161.84 3.65 16132.28 90.16 323.08 6,397.66 12,710.63 N 3,896.24 W 13253.26 2.03 16228.53 91.39 324.09 6,396.35 12,788.07 N 3,953.37 W 13346.28 1.66 16324.95 91.70 323.71 6,393.75 12,865.95 N 4,010.16 W 13439.57 0.51 16421.38 92.20 323.77 6,390.47 12,943.66 N 4,067.16 W 13532.78 0.51 16518.89 90.59 322.02 6,388.09 13,021.40 N 4,125.97 W 13626.69 2.43 16612.64 90.53 322.40 6,387.18 13,095.48 N 4,183.41 W 13716.70 0.41 16710.35 89.91 325.75 6,386.80 13,174.59 N 4,240.73 W 13811.33 3.49 16806.28 89.36 327.08 6,387.42 13,254.50 N 4,293.79 W 13905.15 1.50 16903.61 89.60 323.48 6,388.31 13,334.49 N 4,349.22 W 13999.90 3.71 16998.75 90.16 325.71 6,388.51 13,412.03 N 4,404.33 W 14092.26 2.42 17095.28 90.78 324.13 6,387.72 13,491.02 N 4,459.81 W 14186.10 1.76 17192.02 91.21 324.49 6,386.05 13,569.58 N 4,516.24 W 14279.90 0.58 17287.76 90.03 323.14 6,385.01 13,646.84 N 4,572.76 W 14372.52 1.87 17383.93 88.05 320.83 6,386.61 13,722.59 N 4,631.97 W 14464.73 3.16 17480.52 89.73 321.63 6,388.48 13,797.88 N 4,692.44 W 14556.96 1.92 17530.83 89.85 321.55 6,388.67 13,837.30 N 4,723.69 W 14605.11 0.29 17576.97 88.80 322.30 6,389.21 13,873.62 N 4,752.15 W 14649.35 2.79 17627.20 90.03 323.90 6,389.72 13,913.79 N 4,782.30 W 14697.78 4.02 17672.60 89.36 326.18 6,389.97 13,950.99 N 4,808.31 W 14741.94 5.23 17724.08 90.22 326.38 6,390.15 13,993.81 N 4,836.89 W 14792.26 1.72 17769.48 89.23 327.27 6,390.37 14,031.80 N 4,861.73 W 14836.72 2.93 17865.73 89.05 326.88 6,391.82 14,112.59 N 4,914.04 W 14931.07 0.45 17961.80 89.42 325.73 6,393.11 14,192.51 N 4,967.34 W 15024.99 1.26 18057.46 89.42 325.09 6,394.08 14,271.25 N 5,021.64 W 15118.17 0.67 18153.64 89.54 324.02 6,394.96 14,349.61 N 5,077.41 W 15211.53 1.12 18248.97 90.34 322.67 6,395.06 14,426.09 N 5,134.33 W 15303.57 1.65 18345.48 90.28 321.61 6,394.53 14,502.28 N 5,193.55 W 15396.19 1.10 18441.43 89.73 321.42 6,394.52 14,577.38 N 5,253.26 W 15487.98 0.61 18539.04 90.41 321.48 6,394.41 14,653.72 N 5,314.09 W 15581.32 0.70 18634.39 90.41 321.97 6,393.73 14,728.57 N 5,373.16 W 15672.64 0.51 18727.00 91.27 321.89 6,392.38 14,801.47 N 5,430.26 W 15761.42 0.94 18827.60 90.65 321.98 6,390.69 14,880.67 N 5,492.27 W 15857.85 0.62 INSITE V8.0.0 Page 5Job No:AK-XX-0900261430 Well Name:ODSN-04 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 18924.04 90.65 321.62 6,389.60 14,956.45 N 5,551.91 W 15950.24 0.37 19019.72 91.02 323.51 6,388.20 15,032.41 N 5,610.05 W 16042.25 2.01 19115.71 90.90 322.57 6,386.59 15,109.10 N 5,667.76 W 16134.77 0.99 19211.89 90.90 319.40 6,385.09 15,183.81 N 5,728.30 W 16226.50 3.30 19308.52 91.39 319.05 6,383.16 15,256.97 N 5,791.39 W 16317.72 0.62 19403.12 91.40 318.83 6,380.86 15,328.28 N 5,853.51 W 16406.86 0.23 19500.25 91.21 319.05 6,378.65 15,401.50 N 5,917.29 W 16498.39 0.30 19596.01 92.38 319.94 6,375.66 15,474.27 N 5,979.46 W 16588.91 1.54 19692.19 92.63 319.86 6,371.45 15,547.77 N 6,041.35 W 16680.01 0.27 19783.79 92.94 319.38 6,367.01 15,617.47 N 6,100.63 W 16766.61 0.62 19868.00 92.94 319.38 6,362.69 15,681.30 N 6,155.38 W 16846.09 0.00 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 338.45 degrees (True) - A total correction of 19.52 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 19,868.00 feet is 16,846.12 feet along 338.57 degrees (True) WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.0.0 Page 6Job No:AK-XX-0900261430 Well Name:ODSN-04 Survey Report
