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Home My WebLink About215-114 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 9, 2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Jessie Chmielowski: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitors, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Brennen Green or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, ConocoPhillips Well Integrity Field Supervisor RBDMS JSB 081425 Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.08.11 16:34:01-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green ConocoPhillips Alaska Inc.Well Name API # PTD #Initial top of cementVol. of Portland Type I cement pumpedFinal top of cementCement top off date Corrosion inhibitorCorrosion inhibitor/ sealant datein gal in gal1C-17 50-029-22872-00-00 198-224 N/AN/A post SC Repair8" N/A 0.85 8/7/20251C-150 50-029-23496-00-00 213-120 N/AN/A Rig cemented to surface4" N/A 3 8/7/20251C-152 50-029-23548-00-00 215-114 50" 34.4 9" 7/31/2025 2.13 8/7/20251C-153 50-029-23549-00-00 215-116 N/AN/A Rig cemented to surface9" N/A 1.73 8/7/20251C-154 50-029-23559-00-00 215-166 70" 51.8 10" 7/31/2025 3.4 8/7/20251C-155 50-029-23561-00-00 215-180 64" 35.8 8" 7/31/2025 1.7 8/7/20251C-15650-029-23750-00-00 223-023 25" 12.00 10" 7/31/2025 5.1 8/7/20251C-157 50-029-23754-00-00 223-038 57" 30.28 9" 7/31/2025 2.2 8/7/20251C-15850-029-23761-00-00 223-056 3"N/A Rig cemented to surface10" 7/31/2025 4.25 8/7/20251C-501 50-029-23757-00-00 223-045 139" 11.40 8" 7/31/2025 3.8 8/7/20251H-107 50-029-23795-00-00 224-092 34" 14.80 10" 7/31/2025 5.25 8/7/20251H-11250-029-23787-01-00 224-032 47" 33.19 7" 7/31/2025 4.25 8/7/20251H-12050-029-23794-01-00 224-081 30" 13.70 8" 7/31/2025 4 8/7/20253H-3550-103-20805-00-00 219-064 45" 32.20 7" 8/1/2025 3.6 8/8/20253H-3650-103-20838-00-00 222-014 60" 44.20 8" 8/1/2025 3.4 8/8/20253H-3750-103-20822-00-00 219-194 35" 23.00 8" 8/1/2025 3.4 8/8/2025Date 08/09/251C, 1H, and 3H PadsKuparuk FieldReport of Sundry Operations (10-404)Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off1C-15250-029-23548-00-00215-11450"34.49"7/31/20252.138/7/2025 Originated: Delivered to:10-Oct-24 Alaska Oil & Gas Conservation Commiss 10Oct24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 3T-621 50-103-20882-00-00 224-022 Kuparuk River WL FMI-MSIP-PEX-ZAIT-XPT FINAL FIELD 11-Mar-24 3S-722 50-103-20886-00-00 224-066 Kuparuk River WL HSD FINAL FIELD 18-Sep-24 1C-152 50-029-23548-00-00 215-114 Kuparuk River WL TTiX-IPROF FINAL FIELD 22-Sep-24 1J-154 50-029-23254-00-00 205-035 Kuparuk River WL TTiX-WFL FINAL FIELD 25-Sep-24 1C-152 50-029-23548-00-00 215-114 Kuparuk River WL IPROF FINAL FIELD 27-Sep-24 1D-05 50-029-20417-00-00 179-095 Kuparuk River WL SCMT FINAL FIELD 28-Sep-24 2K-07 50-029-21351-00-00 189-071 Kuparuk River WL PPROF FINAL FIELD 1-Oct-24 1R-08 50-029-21333-00-00 185-073 Kuparuk River WL IPROF FINAL FIELD 5-Oct-24 1R-10 50-029-21351-00-00 185-096 Kuparuk River WL IPROF FINAL FIELD 6-Oct-24 3S-722 50-103-20886-00-00 224-066 Kuparuk River WL TTiX-Perf FINAL FIELD 9-Oct-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39651 T39652 T39652 T39653 T39653 T39654 T39655 T39656 T39657 T39658 1C-152 50-029-23548-00-00 215-114 Kuparuk River WL TTiX-IPROF FINAL FIELD 22-Sep-24 1C-152 50-029-23548-00-00 215-114 Kuparuk River WL IPROF FINAL FIELD 27-Sep-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.11 08:44:58 -08'00' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop Kuparuk 1A-09 50-029-20669-00 181152_1A-09_IPROF_27May2022 1A-15 50-029-20711-00 182017_1A-15_iProf_02Jun2022 1A-22 50-029-22127-00 191003_1A-22_RBP-LSL_22June2022 191003_1A-22_SBHPS-RBP_09June2022 1B-101 50-029-23173-00 203133_1B-101_MechCut_24Jun2023 1B-14 50-029-22452-00 194030_1B-14_CHC_15Mar2022 194030_1B-14_RCT Cutter_24Feb2022 194030_1B-14_UPCT Cutter_20Jun2022 194030_1B-14_Whipstock_13Apr2022 19430_1B-14_CHC_21Mar2022 1C-09 50-029-20859-00 182185_1C-09_IPROF_15Jan2023 1C-133 50-029-23013-00 201077_1C-133_RBP_07Apr2022 1C-152 50-029-23548-00 215114_1C-152_IPROF_20Mar2023 1C-15L1 50-029-22932-60 203032_1C-15L1_CHC_04Feb2022 1D-01 50-029-20393-00 179059_1D-01_PPROF_25Jun2023 1of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38308 T38309 T38310 T38312 T38311 T38274 T38276 T38314 T38315 T38316 2/29/2024 1C-152 50-029-23548-00 215114_1C-152_IPROF_20Mar2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 11:11:35 -09'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-07-11_22545_KRU_1C-152_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22545 KRU 1C-152 50-029-23548-00 Injection Profile 11-Jul-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 215-114 T37858 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.19 13:19:00 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-07-09_15935_KRU_1C-152_InjectionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 19535 KRU 1C-152 50-029-23548-00 Injection Profile 09-Jul-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 215-114 T37839 Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.12 10:23:17 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-152 KUPARUK RIV UNIT 1C-152 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1C-152 50-029-23548-00-00 215-114-0 W SPT 3833 2151140 1500 1090 1091 1089 1087 104 240 238 234 4YRTST P Austin McLeod 5/13/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1C-152 Inspection Date: Tubing OA Packer Depth 420 1810 1740 1730IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220514075412 BBL Pumped:1.2 BBL Returned:1 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 09:30:50 -08'00' MEMORANDiJ�I�i • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 16,2018 TO: Jim Regg P.I.Supervisor 'Rep *3118 SUBJECT: Mechanical Integrity Tests (( CONOCOPHILLIPS ALASKA,INC. 1C-152 FROM: Austin McLeod KUPARUK RIV UNIT 1C-152 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J87` NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-152 API Well Number 50-029-23548-00-00 Inspector Name: Austin McLeod Permit Number: 215-114-0 Inspection Date: 5/13/2018 Insp Num: mitSAM180514083853 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IC-152 Type Inj O TVD I 3833 Tubing 1773 1773 1772 • 1769 ' PTD I 2151140 Type Test SPT Test psi 1500 IA 160 2600 � 2485 ' 2475 BBL Pumped: 2 TBB2.1 OA L Returned: 4 10 10 10 Interval 4YRTST P/F P 11 Notes: MIT-IA %CONE° JUN 0 1" Wednesday,May 16,2018 Page 1 of 1 • i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,June 29,2017 TO: Jim Regg P.I.Supervisor r• e-eil 7(-7(r/ SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-152 FROM: Lou Laubenstein KUPARUK RIV UNIT 1C-152 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-152 API Well Number 50-029-23548-00-00 Inspector Name: Lou Laubenstein 215-114-0 Inspection Number: Insp Num: mitLOL170625191259 Date: 6/25/2017 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IC-I52 'Type Inj G ' TVD 3833 - Tubing 1737 1736 - 1735- 1733 - PTD 2151140 lType Test SPT Test psi 1500 - IA 1510 2500 - 2440 - 2430 BBL Pumped: 0.8 - IBBL Returned: 0.9 OA 451 488 - 487- 487 , Interval OTHER P/F P Notes: Post WINJ to WAG conversion MITIA per sundry#317-131 ✓ ? --.AIASL (bozo SCANNED AUG 2 2?0i7 Thursday,June 29,2017 Page 1 of 1 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon I Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: WINJ to WAG P.- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 215-114-0 3.Address: Stratigraphic Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23548-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649, 25638 KRU 1C-152 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 12406 feet Plugs(measured) None true vertical 3871 feet Junk(measured) None Effective Depth measured 12367 feet Packer(measured) 4783 true vertical 3871 feet (true vertical) 3838 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81' 20 123' 123' SURFACE 2766' 10 2653' S 7 INTERMEDIATE 4896' 7 5/84 4935' 3848' `9°D�� V 201 LINER 7585' 41/2 12367' 3870' RECEIVED Perforation depth: Measured depth: slotted liner 4,840'-12,134' JUN 1 4 2017 True Vertical Depth: 3,841'-3,862' f/'��'�� O CC Tubing(size,grade,MD,and TVD) 4 1/2 ,L-80,4814 MD, 3838 TVD Packers&SSSV(type,MD,and TVD) Packer= Baker HRD-E ZXP w/HD's,4,783'MD, 3,833'ND, SSSV=None 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 650 1280 660 Subsequent to operation 1200 880 1600 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 1 Exploratory r Development r Service 17 Stratigraphic Copies of Logs and Surveys Run 16.Well Status after work: Oil Gas WDSPL Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG £' GINJ r SUSP r SPLUG r 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: 317-131 Contact Marina Krvsinski Email: marina.l.krvsinskicop.com Printed Name Marina Krvsinski Title: Drillsite Petroleum Engineer Signature _ Phone:263-4906 Date (pi I�'20 I, __ K.,,,o,0.--.-..-. v1"1l° Ji ) 19 ,,/ ianl 7 Form 10-404 Revised 5/2015 /" Submit Original Only RBDMS vv JUN 1 4 2017 • • 1C-152 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/03/17ICommenced WAG injection. KUP INJ • 1C-152 Conoco Phillips t+eeit Attr t utes v : an gle& . . . ID ( Wellbore APIIUWI Field Name '•Wellbore Status ncl(°) MD(BOB) Act Btm(ftKB) GxvxcilVeihps 500292354800 WEST SAK INJ 91.96 7,453.22 12,406.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date °.° 1C-192,12/30/2015 3.1900 PM SSSV:NIPPLE Last WO: 39.97 9/14/2015 Vwtwal.ruhomaW/onlvalJ •• Annotation Depth(ttKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O pproven 12/17/2015 s sed HANGER,340- ww 5g 'cF" 1 .SAI CONDUCTOR stringson �n) " _ 08..�. �� t .. ••••,;:•,, '.. Casing Casing Description OD(in) ID(in) Top(flKB) Set Depth(BOB) Set Depth(TVD) WULen p...Grae Top Thread - - •------- -------- - 20 19.250 420 1230 123.0 78.70 B / Casing Description OD pn) ID(in) Top(ttKB) Set Depth(RKB( Set Depth(TVD)...Wt/Len(I...Grade Top Thread '' SURFACE 10 3i4 9.950 42.1 2,807.7 2,652.9 45.50 L-80 11:51-1.n5,63 Casing Description 0D(In) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade op read ,......- .,,,.,.., INTERMEDIATE 75/8 6.875 39.1 4,934.8 3,8482 29.70 L-80 Hydri1563 T... rill . Casing Description OD(in) ID(in) Top(ROB) Set Depth(RKB) Set Depth(TVD)...Wt/Len p...Grade Top Thread I LINER 41/2 3.958 4,782.7 12,367.3 3,870.5 1260 L-80 IBT-m ' Liner Details SAN. i :,: A .. N.,,,,,,,,-,,;,,,,,, ominal lD Top(flKB) Top(TVD)(flKB) Top Incl r) Item Des Com (in) 4,782.7 3,833.1 81.30 PACKER BAKER HRD-E ZXP W/HD'S 4.920 4,802.7 3,836.0 82.12 NIPPLE BAKER RS NIPPLE 4.950 4,805.5 3,836.3 82.23 HANGER BAKER DG FLEX LOCK HANGER 4.830 4,815.3 3,837.6 82.64 SBE BAKER SEAL BORE EXTENSION 4.750 12,148.5 3,862.5 87.39 SWELL TAM SWELL PACKER A 3.958 PACKER I Tithing StnngS,. \ - 4 p CONDUCTOR,42.0-123.0- ` Tubing Description Siting Ma..ID(in) (Top(ttKB) Set Depth(ft..Set Depth(TVD((...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3958 34.51 4,83181 383971 1260 L-80 I HY0563 Completion Detai s .. , t om.,&...- X41, \ �..., _ Nominal ID NIPPLE;498.9 4€ Top(flKB) Top(TVD)(flKB) Top Incl(°) Item Des Com (in) --= 34.5 34.5 0.09 HANGER VETCO OFFSET TUBING HANGER TYPE MB-222A 3.875 498.9 498.8 3.93 NIPPLE CAMCO DB NIPPLE 3.813 4,149.1 3,681.8 64.63 NIPPLE CAMCO DB NIPPLE W/NO GO PROFILE 3.750 II 4,791.5 3,834.4 81.66 LOCATOR BAKER MECHANICAL LOCATOR 3.880 4,814.4 3 837 5 82.60 SEAL ASSY BAKER BONDED SEAL ASSEMBLY W/MULE SHOE 33.8500 GAS LIFT;2,603.7 ,, - a -- Pelforations&Slots . . . . Shot Dens Top(TVD) Btm(TVD) (shotslf Top(ttKB) B"12,733.8 tm(ttKB) (flKB) "13'861.9 RKB( Zone Dat t) Type C L4,840.1 12,133 8 3 840 6 3 861 9 9/13/2015 SLOTS Slotted Liner cement Squeezes, : ` \\ . Top(TVD) 0;3,,,d,87905),':::::: tm(TVD) Top(RKB) Btm(RKB) (RKB( (flKB) Des Start Date Com SURFACE;42.1-2,807.7-� 4,292.0 4,965.0 3,733.7 3,849.5 Remedial 9/5/2015 SLB pumped 3 bbl 11-.:::::ppg 1.5 ppg MudPush,PT lines to Cement Squeeze 600 low/3000 psi hi.Pumped total 20.4 bbl of 11.5 ppg MudPush,insert wiper ball(6"wiper ball,had to cut down due wrong size),SLB pmped 25.4 bbl 15.8 ppg Tail Cement,followed with 5.7 bbl 11.5 ppg GAS LIFT;4,090.8 MudPush and 1.5 bbl of water to get MudPush to the floor.Blow down to cementers. Pull up hole 8 stands to 4206'MD,circulate 1.5 bottoms up then commence squeeze operations. Open kill line and pump to remove air,Close annular and perform hesitation squeeze,pumping down DP and Kill Iine.Rig pumped to squeeze cement @.5 bpm.Squeeze#1-Pumped ,11 4.23 bbl to achieve 687 psi,shut in hold 10 min, pressure bled off to 449 psi.(OA=700 psi)Squeeze NIPPLE;4,149.1 #2-Pumped additional 1 bbl to bump up from 449 psi to 687 psi,shut in and hold ten minutes dropped to 582 psi.#3-Pumped.6 bbl(5.8 total)to bump up pressure from 582 to 687 psi.Shut in 10 minutes and pressure dropped to 494 psi.(0A=700)#4-Another.6 • bbl(6.4 total)to bump up from 494 to 687 psi,shut in 16 min-dropped to 449 psi.#5-Increased prerssure to 730 psi,pumped.85 bbl(7.25 total)bump from 449 psi to 730 psi.Shut in and hold 10 minutes,bled off to 526 psi. Bled off annular pressure,bled back 1.2 bbl, LOCATOR;4,791.5 total cement sqeezed away=6.05 bbl Mandrel Inserts St att Top(ND) Valve Latch Port Size TRO Run N Top 1RKB) (ftKB) Make Model OD(in) Sere Type Type (In) (psi) Run Date Com : -r 2,603.7 2,457.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/15/2015 16.21 I deg SEALASSY;4.814.4 Z, 2 4,080.8 3,650.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/15/2015 61.40 11 deg 11 Natesi General&Safety 44 \\ ,.., . End Date Annotation NOTE: -.iv . INTERMEDIATE;39.2-0,934.8 9 SLOTS;4,040.1-12,133.0 LINER;4,782.7-12,367.3 VOF Tk THE STATE• • s Alaska Oil and Gas 9 1,410111471,X.Ali ofZLVA Conservation Commission 41* 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF S.tc.p. Fax: 907.276.7542 www.aogcc.alaska.gov Marina Krysinski Drillsite Petroleum Engineer scat*E° ,11A.: ;A x � 'v}}" ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1C-152 Permit to Drill Number: 215-114 Sundry Number: 317-131 Dear Ms. Krysinski: 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. oerster Chair DATED this 25 day of May,2017. RBDMS jt., t1AY 3 0 2017 RECEIVED • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 9 201 APPLICATION FOR SUNDRY APPROVALS 9 20 AAC 25.280 AOGC 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate J, Repair Well r Operations shutdown fl Suspend r Perforate r Other Stimulate fl Pull Tubing r Change Approved Program Rug for Redrill 1- Perforate New Pool fl Re-enter Susp Well r Alter Casing r Other: WINJ to WAG F. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 215-114-0 • 3.Address: Service 6.API Number: Stratigraphic P. O. Box 100360,Anchorage, Alaska 99510 50-029-23548-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes " No '.. / KRU 1C-152 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25649,25638 Kuparuk River Field/West Sak 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): 12406' 3871 • 12367' % s 3871' 1205 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 81' 20 123' 123' SURFACE 2766' 10 3/4 2808' 2653' INTERMEDIATE 4896' 7 5/8 4935' 3848' LINER 7585' 4 1/2 12367' 3870' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): slotted liner 4,840'-12,134' . 3,841'-3,862' 4 1/2 L-80 4814 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=None PACKER=BAKER HRD-E ZXP w/HD's . MD=4,783',ND=3,833' 12.Attachments: Proposal Summary pl. WellBore Schematic 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic Development ' Service 17 . 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations: 04/20/17 OIL l WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG wt GSTOR r SPLUG Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Marina Krysinski Printed Name Marina Krysinski Phone:263-4906 Email: marina.l.krysinski(a,cop.com Title: Drillsite Petroleum Engineer Signature //w .. Date: 61 24 1 '1:011 /�\J Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317- 13 Rug Integrity r BOP Test r Mechanical Integrity Test Location Clearance Other: /c[Jpct,r-t. A vvcll5 /C—O� IC- a5 e /C - ' , n-yv5l h4vc OA �oh,'7-0rcc� c!a/fy CA.f dvvtv5�- Gori for-r-t Wifh ZD A.'C 25 . 4 OZ (.f ) Post Initial Injection MIT Req'd? Yes Iv No r Spacing Exception Required? Yes r No Subsequent Form Required: /D fD �, RBDMS `, , MAY 3 0 20'7 APPROVED BY Approved by:2 22 . .e.-.,(1.--- COMMISSIONER THE COMMISSION Date:5_2z" /7 7144j�j "i0 J 3 l t..5/24//7 Submit Form and Form 10-403 Revised 11/2015 p r v c l td for 12 months from the date of approval. Attachments in Duplicate • 1C-152 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1C-152 (PTD# 215-114)from Water Injection service to Water Alternating Gas Injection service. Area of Review: West Sak well 1C-152 was completed as an injector on 10/18/15 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This supports existing producers 1C-151 and 1C-153. The top of the Ugnu A sand was found at 3,940' MD/3,574'ND The top of the Wsak D sand was found at 4,782' MD/3,833'ND Area Map with Y4 mile radius around target injection zone(see attached): The map attached shows that, in addition to the offset producers (1C-153 & 1C-151), there are four Kuparuk wells that have penetrations of the West Sak interval located within a 1/4 mile radius of the 1C-152 penetrations of the West Sak interval. These wells are 1C-05, 1 C-07A, 1C-11, and 1C-13. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 1C-152 is good and is classified as a"Single Casing"well. The injection tubing/casing annulus is isolated via a Baker HRD-E ZXP packer located at 4782' and (3833'tvd). A last state-witnessed MITIA was performed on 1/2/2016 to 2400 psi. CBL and interpretation of the cement quality: See attached AOR detail for offset well condition. The 20"Conductor was cemented with 368 sx ASI. The 10-3/4" Surface casing was cemented with 486 bbls LiteCrete followed by 227 bbls LiteCrete. Top job consisted of 35 bbls of LiteCrete. The 7-5/8" Intermediate casing was cemented with 46 bbls Class"G" retarded cement followed by 52 bbls Class"G" non-retarded tail slurry. Remedial job consisted of 6 bbls Class"G"cement squeezed away. Conditions for approval (if applicable): Daily OA pressure monitoring is in place for well 1C-05 for conformance compliance per 20 AAC 25.402 (f). • • -, -8 €° Q 1 • LL F n P.$ g v s ...1 .1 0 1N R ryPh N vl ! 0 ((_/� v 0 24.' 0 Q C N N p N N x . _ V m .Q o N 4 r x ry 4 ,! § ! M g $ n 1. r rn rd n a a E 2 C e s a 2 s 2 J gk C C N m a E E U U N U .6: . O O C Q O 9 O y s a °^ n t m V a 11 N tl `� N N ✓ F ry1 J G NCS V U 8 1N m 4 U k N G N if O C ary g O .B — cI ri a g a a m *8 $ 10 51 a � n m o p. v v; Pr!.-t N O > w Q Cg y 3 O E N O. cW 6 $ 88 U U W 3 A O vi ti III • 2 Nry u ^a.`0 . auaa ;ur O'. m N N t74� N nb E N m_ 11 Or �A,`.4., _a � 0wxvi w pO E � of _i.A� m°aN l37 Ni g x „.- a4l %N° %Nu ` ou d �uu4Xuu � t „No v � : �.2 ... .:2 '? 1,44 m E VmU . yOmp = a R Vy 0- lU.-i 1 N oro Qin « . m- 0YnoN.j ��E L^ ryroN n v d ti m V N yp 0 Q - V Na U m " v 'nuN p "'or-',.°1 NY 'tilt 2 63 = 22= 22— _ 1 to 20 ' E 1a2 Yf N " a- na81i aa o E g o « mo = w a0 c w u E u E E YY c y m m m .0 = u'- V' o 0 N w w .',5 . w OY = O E O O G9 0V n= =9a O? OC C ' n �' n d a a n °' a W E VE N dc N N N W8 c — . 8 O a .q — £ u 1.1b-g r L6. 4'8 .80 a „ 0 0 . Q E L'C d m N n e Q oni m 2 a 8 e a m a ^ 0 0_ lgm a 5 g n1 of M c T n n g Fp 71, t�D O N n N 1 d v vi v v v _ H O m m m m m m fa = E _ •_ N $ u 0 o g ^ V L. 3 `« r,. e O y 2, m O N N N m O q N 8 8 E 8 N N m ,. n o m a n ,,-., 4 F4 LA ry N° ry .°1i N' I AD L025638 ws D Wes t Sak PA r ADL04744: ADL025639 ' g2 ' '4 ADL025648 }1 n D r r 4VS o b N J C ADL02824 c, n c� w 3 E.:. O n d �.p WS \c,:.\$ 1C-172A WS �� .V wsD WSD' U ABi p AD L025649 ' iIwsD (' rf b 1c X ATDB Form.Picks: West Sak D 1C-152 Well Trajectory it iiii 1C-152 Open Interval co 0. N ConocoPhillips Ell IC-152 01 Quarter Mile Radius Alaska,Inc. Wells within Open Interval Radius ` j____I West Sak PA 1 C_152 H Well Pad 0 0.2 0.4 0.6 Injection Sundry Nimisom CPAI Leases Mlles 1. 3/6/2017 KUP INJ • 1C-152 ConocoPhillipsWell Attributes Max Angle&MD TD AL-is/s,Ilk:. Wellbore API/UWI Field Name Wellbore Status ncl(3 MD(ftKB) Act Btm(ftKB) c „..,;,,.mfillips 500292354800 WEST SAK INJ 91.96 7,453.22 12,406.0 ... Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-152,12/30/20153'.19'.08 PM SSSV:NIPPLE Last WO: 39.97 9/14/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag'. Rev Reason:GLV C/O pproven 12/17/2015 NANOER;34.6 I�,rf ill Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len 0...Grade Top Thread CONDUCTOR 20 19.250 42.0 123.0 123.0 78.70 B El Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread t ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,a„a„aa„aa,,,,,a,,,aa 1. ,�,,,u,,,,,,,,,,,c SURFACE 10 3/4 9.950 42.1 2,807.7 2,652.9 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 7 5/8 6.875 39.1 4,934.8 3,848.2 29.70 L-80 Hydri1563 l El Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 4,782.7 12,367.3 3,870.5 12.60 L-80 1BT-m Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(*) Item Des Com (in) 4,782.7 3,833.1 81.30 PACKER BAKER HRD-E ZXP W/HD'S 4.920 4,802.7 3,836.0' 82.12 NIPPLE BAKER RS NIPPLE 4.950 ._ ..�n.h/". 4,805.5 3,836.3 82.23 HANGER BAKER DG FLEX LOCK HANGER 4.830 ww. 4,815.3 3,837.6 82.64 SBE BAKER SEAL BORE EXTENSION 4.750 • 12,148.5 3,862.5 87.39'SWELL TAM SWELL PACKER A 3.958 PACKER Tubing Strings CONDUCTOR;42.0-123.0-k4 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(16/t) Grade Top Connection TUBING 41/2 3.958 34.5 4,831.8 3,839.7 12.60 L-80 HYD563 Completion Details - Nominal ID NIPPLE;498.9 i e Top(ftKB) Top(TVD)(ftKB) Top Incl(3 Kent Des Com (in) 34.5 34.5 0.09 HANGER VETCO OFFSET TUBING HANGER TYPE MB-222A 3.875 498.9 498.8 3.93 NIPPLE CAMCO DB NIPPLE 3.813 4,149.1 3,681.8 64.63 NIPPLE CAMCO DB NIPPLE W/NO GO PROFILE 3.750 • 4,791.5 3,834.4' 81.66 LOCATOR BAKER MECHANICAL LOCATOR 3.880 • 4,814.4 3,837.5 82.60 SEAL ASSY BAKER BONDED SEAL ASSEMBLY W/MULE SHOE 3.850 GAS LIFT;2,603.7 Perforations&Slots Shot - Dens Top(ND) Btm(ND) (shots/( Top(ft613) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 4,840.1 12,133.8 3,840.6 3,861.9 9/13/2015 SLOTS Slotted Liner Cement Squeezes Top(ND) Btm(ND) Top(kKB) Btm(ftKB) (kKB) (ftKB) Des Start Date Com SURFACE,42.1-2,807.7- J 4,292.0 4.965.0 3,733.7 3,849.5 Remedial 9/5/2015 SLB pumped 3 bbl 11.5 ppg MudPush,PT lines to Cement Squeeze 600(ow/3000 psi hi.Pumped total 20.4 bbl of 11.5 ppg MudPush,insert wiper ball(6"wiper ball,had to cut down due wrong size),SLB pmped 25.4 bbl 15.8 ppg Tail Cement,followed with 5.7 bbl 11.5 ppg GAS LIFT 4,080.8 1. MudPush and 1.5 bbl of water to get MudPush to the floor.Blow down to cementers. Pull up hole 8 stands to 4206'MD,circulate 1.5 bottoms up then commence squeeze operations. Open kill line and pump to - remove air,Close annular and perform hesitation squeeze,pumping down DP and Kill Iine.Rig pumped "- to squeeze cement @.5 bpm.Squeeze#1-Pumped 4.23 bbl to achieve 687 psi,shut in hold 10 min, pressure bled off to 449 psi.(OA=700 psi)Squeeze NIPPLE,4,149.1 #2-Pumped additional 1 bbl to bump up from 449 psi to 687 psi,shut in and hold ten minutes dropped to 582 psi.#3-Pumped.6 bbl(5.8 total)to bump up - pressure from 582 to 687 psi.Shut in 10 minutes and pressure dropped to 494 psi.(OA=700)#4-Another.6 bbl(6.4 total)to bump up from 494 to 687 psi,shut in 16 min-dropped to 449 psi.#5-Increased prerssure to 730 psi,pumped.85 bbl(7.25 total)bump from 449 psi to 730 psi.Shut in and hold 10 minutes,bled off to 526 psi. Bled off annular pressure,bled back 1.2 bbl, LOCATOR;4791.5 total cement sqeezed away=6.05 bbl Mandrel Inserts St ad on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,603.7 2,457.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/15/2015 16.21 deg SEAL ASSY;4.814.4 2 4,080.8 3,650.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/15/2015 61.40 deg Notes:General&Safety End Date Annotation NOTE: lar- INTERMEDIATE;39.2-4,934.8--. 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Ac� 1G+ 05 7ek+ - 1G1°°L .� 8 a z f s: o ,pY,piik- E 0 Z 3i a m CJIY ° y Ql m Y a 3-- ♦ m ! 'm c m in 23 _ o_ m r = t- Q N IMFA +6+' .. y d m d N N a e O - 3 ¢ O 'S V .` 3 i +610+ - x. COCL 2 0 3 13 CO YC aJN L1 2u • • Loepp, Victoria T (DOA) From: Jensen, Marc D <Marc.D.Jensen@conocophillips.com> Sent: Wednesday, May 24, 2017 10:19 AM To: Loepp,Victoria T(DOA) Cc: Krysinski, Marina L Subject: RE: 1C-150& 1C-152 Sundry Application Work Session Follow-Up Victoria, The WI line to DS1C was SI on 5/10/2017 for a line coating project.The current work is scheduled to be completed at the end of August.Current operational best practices for mitigating matrix bypass events recommend shutting in offset producers when pattern injection is lost for a significant time-period. We plan to SI wells 1C-151, 1C-153,and 1C-155 if we cannot restore injection temporarily to adhere to this best practice. Thanks, Marc From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, May 24,2017 9:07 AM To:Jensen, Marc D<Marc.D.Jensen@conocophillips.com> Cc:Krysinski, Marina L<Marina.L.Krysinski@conocophillips.com> Subject: [EXTERNAL]RE: 1C-150& 1C-152 Sundry Application Work Session Follow-Up Marc, During our meeting, it was mentioned that WI was going to be down for a period of time and the conversion of these wells was needed to maintain I/W. Please provide more detail on this situation and opportunity. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa�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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From:Jensen, Marc D [mailto:Marc.D.Jensen@conocophillips.com] Sent:Tuesday, May 23,2017 2:11 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> 1 • • Cc:Simek,Jill<Jill.Simek@conocophillips.com>;Targac,Gary<Gary.Targac@conocophillips.com>;Wallace,Chris D (DOA)<chris.wallace@alaska.gov>; Roby, David S(DOA)<dave.roby@alaska.gov>; Schwartz,Guy L(DOA) <guy.schwartz@alaska.gov>; Krysinski, Marina L<Marina.L.Krysinski@conocophillips.com> Subject: RE: 1C-150& 1C-152 Sundry Application Work Session Follow-Up Victoria, The attachment should address the remaining action item from our worksession regarding recovery benefit from VRWAG. It summarizes sector model derived rates for the two wells in question. Please let me know if you have any questions or concerns. Thanks, Marc From: Krysinski, Marina L Sent: Friday, May 19, 2017 12:02 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Simek,Jill<Jill.Simek@conocophillips.com>;Targac,Gary<Gary.Targac@conocophillips.com>;Jensen, Marc D <Marc.D.Jensen@conocophillips.com>;chris.wallace@alaska.gov;dave.roby@alaska.gov;guy.schwartz@alaska.gov Subject: 1C-150& 1C-152 Sundry Application Work Session Follow-Up All, I've reviewed our action items from yesterday's work session and my findings are summarized below.The data can also be found in the attached presentation. I did find CBL's for both 1C-04 and 1C-08.The 1C-04 CBL indicates that the top of cement is around 1,250' MD,which is 50'deeper than the calculated TOC of 1,200' MD.The one CBL I was able to locate on 1C-08 was only run from surface to 2000'. For 1C-06,there was a question about the calculated/expected top of cement in comparison to where it was identified on the CBL. I could not find the expected tops in the drilling program, but using the hole size of 8-3/4"with 7"casing run, 173 bbl of cement should cover 6,461'of annular space,assuming zero washout.This comes to a calculated top of cement of 3,765' MD,which is roughly 1,500'shallower than the CBL indicated,but still below the surface casing set depth. OA shoe pumping info is as follows: 1C-04—Arctic pack job pumped on rig. 50 bbl cement(936' in 13-3/8"x 9-5/8"annulus)+ 116 bbl diesel displacement (2,174' in 13-3/8"x 9-5/8"annulus).Surface casing set depth at 2,910' MD. 1C-05—Arctic pack job pumped on rig.41 bbl cement(844' in 10-3/4"x 7"annulus)+108 bbl diesel displacement (2,223' in 10-3/4"x 7"annulus).Surface casing set depth at 2,782' MD. 1C-06—Arctic pack job pumped on rig.41 bbl cement(844' in 10-3/4"x 7"annulus)+112 bbl diesel displacement (2,306' in 10-3/4"x 7"annulus).Surface casing set depth at 3,287' MD. 1C-07A—Arctic pack job pumped on rig.41 bbl cement(844'in 10-3/4"x 7"annulus)+114 bbl diesel displacement (2,347' in 10-3/4"x 7"annulus).Surface casing set depth at 3,086' MD. 1C-08—Arctic pack job pumped on rig.44 bbl cement(906' in 10-3/4"x 7"annulus)+112 bbl diesel displacement (2,306' in 10-3/4"x 7"annulus).Surface casing set depth at 2,714' MD. I've added the Ugnu "C"tops to the visualizations in the presentation.All Ugnu sands are deeper than the set depth of the surface casing in the five wells of interest. 2 I will be out of the office until May 30th. Please contact Marc Jensen (cc'd in this it or at 265-6573) in my absence with any questions. He will also be providing the data that was requested from the reservoir models. Thanks again for your time yesterday! Marina Krysinski Drillsite Petroleum Engineer I West Sak 1BCD ConocoPhillips Alaska, Inc. I ATO-1312 1907-263-4906 3 • 410 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday, May 10,2017 9:35 AM To: Sullivan, Michael Cc: Krysinski, Marina L Subject: RE: KRU 1C-150 (PTD 213-120, Sundry 317-130);KRU 1C-152 (PTD 213-114, Sundry 317-131)Conversion to WAG: Michael, Marina, From the AIO 2C application, CPAI states: "Injection wells and associated pattern producers selected for VRWAG service will be screened to ensure injection of fluid into West Sak Formation will not result in an increased risk of fluid movement into underground sources of drinking ware or other hydrocarbon bearing formations. The initial selection criterion includes an evaluation of the drilling and completion of all West Sak, Kuparuk,and Exploration wells in the proposed area. Wells will be evaluated for initial cement placement information,cement tops,and cement integrity data, including bond logs where available to verify compliance with 20 AAC 25.030. Additionally,the mechanical integrity and completion style of each injection well and associated patter producers will be evaluated to ensure that all wells in each pattern have acceptable completions and sound integrity." CPAI committed to doing the same level of evaluation for injectors and offset wells for all areas they want to inject WRWAG as they did for the pilot wells and the 1E and 11 wells that comprised the initial expansion of VRWAG. CPAI also stated there were additional potential injectors in the"core area"that would require rig workover of offset producers to replace packerless ESP completions or possibly install additional casing strings. We need an in depth analysis of the injectors and offset wells before we can approve converting the 1C wells to VRWAG service. Let me know when you are ready to schedule a review. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a)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 Victoria Loepp at(907)793-1247 or Victoria.Loeop@alaska.gov From: Krysinski, Marina L[mailto:Marina.L.Krysinski@conocophillips.com] Sent: Monday,April 10,2017 3:44 PM • I To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: KRU 1C-150(PTD 213-120,Sundry 317-130)Conversion to WAG Victoria, I believe the information you are looking for on 1C-07A and 1C-08 is included in the table.The top of the D-sand interval in 1C-07A is located at 4,752 MD and the top of the cement is located at a calculated depth of 1,756' MD.The top of the D-sand interval in 1C-08 is located at 4,547' MD and the top of cement is calculated to extend to 2,700' MD. I've attached the updated map with the quarter-mile radius extending the entire length of the wellbore, rather than just including the D-sand interval. Thanks! Marina Krysinski Dri isite Petroleum Engineer I West Sak 1BCD ConocoPhillips Alaska, Inc. I ATO-1312 1907-263-4906 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.govj Sent: Monday,April 10,2017 10:17 AM To: Krysinski, Marina L<Marina.L.Krysinski@conocophillips.com> Subject: [EXTERNAL]KRU 1C-150(PTD 213-120,Sundry 317-130)Conversion to WAG Marina, Please update your table to include whether or not there is cement across the WSak D in Kuparuk wells 1C-07A and 1C- 08. Conditions of approval for PTD 213-120, KRU 1C-150 included daily monitoring of the OA for Kuparuk wells 1C-07A, and 1C-08. Please provide OA pressure plots for these three wells since injection was initiated in KRU 1C-150. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppno 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 2 • • Loepp, Victoria T (DOA) From: Sullivan, Michael <Michael.Sullivan@conocophillips.com> Sent: Thursday,April 27,2017 10:17 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 1C-150, KRU 1C-152 (PTD 213-120, 215-114) Follow Up Flag: Follow up Flag Status: Flagged Victoria, 1C-150 was BOL 3/7/14 1C-152 was BOL 12/17/15 Thanks, -Michael at Kuparuk through 5/4, 907-659-7234 From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent:Thursday,April 27,2017 9:59 AM To:Sullivan, Michael<Michael.Sullivan@conocophillips.com> Subject: [EXTERNAL]KRU 1C-150, KRU 1C-152(PTD 213-120, 215-114) Michael, Could you please tell me when water injection began into Well KRU 1C-150 and 1C-152? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp aC�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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Monday,April 10,2017 10:17 AM To: 'marina.l.krysinski@cop.com' Subject: KRU 1C-152(PTD 215-114, Sundry 317-131) Conversion to WAG Marina, Please update your AOR map and table to include Kuparuk wells 1C-04 and 1C-06. Conditions of approval for PTD 215- 114, KRU 1C-152 included daily monitoring of the OA for Kuparuk wells 1C-04, 1C-05 and 1C-06. Please provide OA pressure plots for these three wells since injection was initiated in KRU 1C-152. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 f, Victoria.LoeppCa?alaska.00v 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 • •N in a 0 ,V N co E (•ri ? a = > D > -4 N V) C co C o y 0 CO o m o o 0 o E a t O in in If) 6 v ' V U ei 0 8 8 2 ° m N N - �--� 0 ails'azea HO 8 8 8 8 8 8 N 0 0 v m N - 0 0 snN L y_ O L 0 (.n 0v a. a) a Q ,m -� CO O co st `-I ( o > O N °C N cn O w O 'L e- E 1 M � D. o � M U 0 0 c N Z: O v 04-1 0 0 CD CU 0 in E cu co 4= a) -Q E t° cc i O U CO > >, o a, o V 4) cu (9 10 Q • , a < 4J "a O •� 0_ O� c Oo ® N OC I-- Q. , N > 0 6 S • Ferguson, Victoria C (DOA) From: Ferguson,Victoria L(DOA) Sent Friday,January 03, 2014 10:14 AM To: Ferguson,Victoria L(DOA) Subject FW:1C-150 Permit to Inject(PTD 213-120,Sundry 313-585) Note to file An issue with converting West Sak well 1C-150 to injection is that two Kuparuk producers(1C-07A and 1C-08) within the quarter mile radius have surface casing set above the West Sak. The cement for the intermediate casing doesn't cover the WSak either. The OA is open to the WSak in these wells. Conditions for approval of this WI conversion include monitoring of the OA annulus and conformance with 20AAC25.402(f). Concerns within the AOGCC are that there may be issues similar to Meltwater where injected fluids are moving outside the injection zone resulting in pressures on surrounding wells OA.Awareness of this issue is important for other WSak and Kuparuk wells. From: Schwartz, Guy L(DOA) Sent:Tuesday, December 31,2013 9:36 AM To: Ferguson,Victoria L(DOA) Subject FW: iC-150 Permit to Inject Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Bettis, Patricia K(DOA) Sent: Friday, December 13,2013 9:04 AM To:Wallace,Chris D (DOA); Schwartz, Guy L(DOA) Subject: FW: 1C-1S0 Permit to Inject From: Roby, David S(DOA) Sent:Thursday, December 12, 2013 6:20 PM To: Bettis, Patricia K(DOA) Subject: RE: 1C-150 Permit to Inject Hrm, the two Kuparuk wells(1C-07A and 1C-08)that aren't cemented across the West Sak are a bit troublesome. Additionally,the fact that they say the other two Kuparuk wells (1C-11 and 1C-17) are cemented across the West Sak but make no mention of the quality of the cement job is a little concerning. 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V¢ .11 .,O1lIllIllirll .ill / a _ iiiiee-- O l_ -f O O 1i' ; 1 y r 43 o 1C.UBLiPB2_ o- m 161 1 161041 x O 3 . v m f ..0 a: o m o ¢ m to oo to 1B 1• ye,.._, ‘ii �a ' a 0 3 vnJ;^w J G f•_I_3' 03:. , 1& ^ 1-1471.-3L i„ a I a- fa 2 N M • 13 ca OC W N — 111 2V r1 STATE OF ALASKA t 0 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL /r tf 1(ri 20 AAC 25.005 1 a.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj ❑' ' Single Zone E ' 1 c.Specify if well is proposed for: Drill 0. Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply El Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill 0 Reentry❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal 0 Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket E Single Well❑ 11.Well Name and Number: ConocoPhillips Alaska Inc Bond No. 59-52-180 • KRU 1C-152 ` 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 12,505' , ND: 3,860' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1279'FNL,4415'FEL, T 11N,R 10E,S 12,Umiat . ADL 025649,ADL 025638 West Sak Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2327.0'FNL,720.8'FEL, T 12N,R 10E,S 35,Umiat 931695 8/1/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2327'FNL,720.8'FEL, T 12N,R 10E,S 35,Umiat ^ 2560,2560 \ --/q,0 _r'q,0 4136 ft 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: .99.5 feet 15.Distance to Nearest Well Open Surface: x- 561870 y- 5968956 Zone-4 GL Elevation above MSL: - 60.0 feet to Same Pool: 665 ft 16.Deviated wells: Kickoff depth: ' 312 feet 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 93.26 degrees Downhole: 1726 psi Surface: 1301 psi 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) 42" 20" 94# H40 Welded 80 40 40 120 120 200 cf of ArcticCRETE 13.5" 10.75" 45.5# L-80 Hydril 563 2731 40 40 2771 2615 1379 sx DeepCRETE Lead,205 sx DeepCRETE Tail 9.875" 7.625" 29.7# L-80 Hydril 563 4872 40 40 4912 3840 535 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 7743 4762 3833 12505 3860 ICD Liner Completion(no cement) 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat BOP Sketch Drilling Program % Time v.Depth Plot Shallow Hazard Analysis ,,• Diverter Sketch Seabed Report Drilling Fluid Program✓y'I'V 20 MC/25.050 requirements"- 21. Verbal Approval: Commission Representative: Date f/-- "f 6/29/2015 22. I hereby certify that the foregoing is true and correct. J Contact Duncan Hyder/@ 265-6862 Email duncan.p.hydenAcop.com Printed Name G.Alvord Title Alaska Drilling Manager A- cakSignature Phone 265-6120 Date 6i(ti.Lze tS Commission Use Only Permit to Drill _ API Number: Permit Approval See cover letter for other Number: ;41.) ` ]1 j 50- p 4..9- ,)�.'s yd-03-CAD Date: --7 !-"I(5 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: E{ Other: [34PfeSf to 35-00 i71 Samples req'd: Yes❑ Nog Mud log req'd:Yes 0,Nog /}✓I!-t /a v o)-C ye. tL - fe5t tb 2 j O o PS/ H2S measures: Yes[✓( No❑' Directional svy req'd:Yes[J No❑ 574 t.fe W/ fh C 55 eV/ M I T- /+A Spacing exception req'd: Yes❑ Nogg Inclination-only svy req'd:Yes[2:1Noe t-rv/re- 41C-r1- sfa Ji' ✓ /; ed i .-JJcCf/'or) /t"1-,13 r-v/r. !AJ C'/5 /C-o4 1C-c52 IC-04, mvSf h Gt V c OA 0-v7 v n / IL r-cc; d G?i f y cx r7 C/ rvi v,5)4 C o h fa r ter, t� Y-ti a O .s}.H C 2 5, 4 O Z (f APPROVED BY /� Approved by: i "'-- COMMISSIONER THE COMMISSION Date: ? � " submit Form and Form 10-401 evised 10/2012) I F r 4 o hs from the date of appy v I(20 AAC 25.005(9)) Attachments in Duplicate • t<RAA r CJS/c4c^ Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Thursday,July 14, 2016 7:51 AMe>i 1(14 11(c:To: Regg, James B (DOA) (1 Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: LPP/SSV returned to service on CPAI well 1C-152 Jim, The low pressure pilot (LPP) on well 1C-152 (PTD# 215-114)was returned to service today, 7/14/16. The well is currently stabilizing at a wellhead injection pressure of 570 psig and rate at 1500 BWPD. The well has been removed from the "Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley SCANNED NOV 2 2 2016 West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com 1 • � c z- att PTA 74 5114-0 Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Monday, July 11, 2016 6:07 PM `' e7 ?(/?/Jit To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI well 1C-152 Jim, The low pressure pilot(LPP) on well 1C-152 (PTD#215-114)was defeated today, 7/11/16, after the injection pressure dropped below 500 psig following a long shut in period during the CPF-1 facility shut down. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." ,- The well is currently injecting 1400 BWPD at a wellhead injection pressure of 390 psig. The AOGCC will be notified when the injection pressure has increased to above 500 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497sCANNED NOV 2 22016 n1638@conocophillips.com 1 • KOit (C-15-z_ Regg, James B (DOA) P ZL$114t From: Hall, Tyler A <Tyler.A.Hall@conocophillips.com> I 1 i( D Sent: Tuesday,January 19, 2016 8:02 PM \c1 rl To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; CPF1&2 Ops Supt; Sullivan, Michael;Jensen, Marc D; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; Haakinson, David Subject: LPP/SSV on well 1C-152 was returned to service Jim, The low pressure pilot(LPP) on well 1C-152 (PTD#215-114)was returned to service and removed from the safety defeat log today, January 19th, 2016, after the wellhead injection pressure increased above the LPP trip point of 500 PSI. This notification is in accordance with "Administrative Approval No. CO 406B.001." The current wellhead injection pressure is 565 psi at an injection rate of 2,000 BWPD. Please let me know if you have any questions. Kind Regards, Tyler Hall / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 CANNED n1638@conocophillips.com 1 i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday,January 06,2016 _ P.I.Supervisor I�Lz`j (I 1��l(., SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-152 FROM: Bob Noble KUPARUK RIV UNIT IC-152 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IC-152 API Well Number 50-029-23548-00-00 Inspector Name: Bob Noble Permit Number: 215-114-0 Inspection Date: 1/2/2016 Insp Num: mitRCNl60103155836 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ------ - . � Welles iC-152 . 1Type Inj W.TVD 3837 Tubing 231 233 233 _ 232 - PTD 2151140 Type Test SPT'Test psi l 1500 IA 1 763 2400 - 2310 - 2295 - Interval INITAL p�I P ✓ OA 136 135 - 135 135 Notes: SCANNED Wednesday,January 06,2016 Page 1 of I • Pro 2e5-- 114 Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Wednesday, September 09, 2015 10:25 AM To: 'Hyden, Duncan P' Subject: RE: KRU 1C-152 Intermediate Shoe Squeeze - Permit# 215-114 Thank you for the update. Victoria From: Hyden, Duncan P [mailto:Duncan.P.Hyden@ conocophillips.cor ] SCANNED i:rt '' ,4 6 r(no Sent: Wednesday, September 09, 2015 10:16 AM To: Loepp, Victoria T(DOA) Subject: KRU 1C-152 Intermediate Shoe Squeeze - Permit # 215-114 Victoria, The cement squeeze of the 7-5/8" intermediate casing shoe went really well, see attached report.After allowing sufficient time for the cement to set up,the top of the plug was successfully tested to 1000 psi. Subsequently,the cement was drilled to the initial FIT test depth of 4965'where a successful FIT to 13.0ppg EMW was achieved and an additional 20' of new formation was drilled to 4985'where a successful 13.2ppg EMW FIT was achieved. Going forward the cement will be logged using a Sonic tool to prove integrity and the results will be sent through the normal channels. Please let me know if you have any questions or concerns. dh Duncan Hyden Drilling Engineer I Direct:907-265-6862 I Mobile:907-317-1910 duncan.p.hyden@cop.com 1 • • 0 Cement Detail Report i 1C-152 conga 'hiliips Alaska String: Remedial Cement Squeeze Job: DRILLING ORIGINAL,8/21/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Remedial Cement Squeeze 9/5/2015 09:30 9/5/2015 13:45 1C-152 Comment SLB pumped 3 bbl 11.5 ppg MudPush, PT lines to 600 low/3000 psi hi.Pumped total 20.4 bbl of 11.5 ppg MudPush,insert wiper ball(6"wiper ball,had to cut down due wrong size),SLB pmped 25.4 bbl 15.8 ppg Tail Cement,followed with 5.7 bbl 11.5 ppg MudPush and 1.5 bbl of water to get MudPush to the floor. Blow down to cementers. Pull up hole 8 stands to 4206'MD,circulate 1.5 bottoms up then commence squeeze operations. Open kill line and pump to remove air,Close annular and perform hesitation squeeze,pumping down DP and Kill line.Rig pumped to squeeze cement @.5 bpm.Squeeze#1-Pumped 4.23 bbl to achieve 687 psi,shut in hold 10 min,pressure bled off to 449 psi.(0A=700 psi) Squeeze#2-Pumped additional 1 bbl to bump up from 449 psi to 687 psi,shut in and hold ten minutes dropped to 582 psi.#3-Pumped.6 bbl(5.8 total)to bump up pressure from 582 to 687 psi.Shut in 10 minutes and pressure dropped to 494 psi.(OA=700)#4-Another.6 bbl(6.4 total)to bump up from 494 to 687 psi,shut in 16 min-dropped to 449 psi.#5-Increased prerssure to 730 psi, pumped.85 bbl(7.25 total)bump from 449 psi to 730 psi.Shut in and hold 10 minutes,bled off to 526 psi. Bled off annular pressure,bled back 1.2 bbl,total cement sqeezed away=6.05 bbl Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Remedial Cement Squeeze intermediate 4,292.0 4,965.0 No No No Squeeze shoe for satisfactory FIT Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbi/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 6 5 333.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment SLB pumped 20.4 bbl 11.5 ppg Mud Push,25.4 bbl 15.8 ppg tail cement.Rig displaced with 35 bbl as balanced plug,pulled out 8 stands to 4206'MD and applied 687 psi squeeze pressure(13.0 ppg EMW)4 times,then 730(13.2 ppg EMW)psi one time.Total volume cement squeezed away 6.05 bbl. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 4,292.0 4,965.0 122 G 25.4 Yield(WIsack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.08 15.80 108.0 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.015 gal/sx Page 111 Report Printed: 9/9/2015 pro 2/5 -/Je-f, 0 0 Loepp. Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Sunday, August 30, 2015 9:13 AM To: Hyden, Duncan P; DOA AOGCC Prudhoe Bay; Regg,James B (DOA) Subject: Re: Permit#215-114: 1C-152 Surface Cement -Top Joba Please submit a 10-403 for the top job as soon as possible. Thank, Victoria Sent from my iPhone On Aug 29, 2015, at 8:05 AM, Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>wrote: Duncan, As we discussed,the AOGCC inspectors should be notified to witness. You have verbal approval to proceed with the top job. Thanx, Victoria Sent from my iPhone On Aug 29, 2015, at 3:51 AM, Hyden, Duncan P<Duncan.P.Hyden@conocophillips.com>wrote: Victoria, On the 28th we performed a primary cement job on 1C-152 well. The cement job went as follows: 75.4bbls CW100 76.6bbls MudPush II 483.4bbls 11ppg Lead (256%excess in permafrost) 65.4bbls 12ppg Tail Plugs bumped on calculated strokes Floats held 16bbls of 11.0ppg cement back to surface Cement in place at 18:06. We nippled down our diverter and checked the TOC and found that it had fallen to 68' below the landing ring. There was a loss of 35 BBLS throughout the cement job. We are currently preparing to perform a cement top job. I will call prior to pumping to the job (07:30-08:00)to obtain verbal approval. 1 • I will prepare a 10.to be submitted Monday 8/31/2015. Duncan Hyden ()Riling Engineer I Direct:907-265-6862 I Mobile:907-317-1910 duncan.p.hyden@cop.com 2 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg cOlIS DATE: 8/29/15 P. I. Supervisor FROM: Bob Noble SUBJECT: Surface Casing Top Job Petroleum Inspector KRU 1C-152 CPAI PTD 2151140 8/29/15: Early morning of 8/29/15 I received and email from CPAI Doyon 25 rig rep. Paul Smith stating that their surface casing cement had fallen back from surface and they needed to do a top job. I called out to the rig and got Doyon 25 rig reps. Paul Smith and Granville Rizek .They told me that they had: - Pumped 75.4 BBLs of CCW100; - Followed by 76.6 BBLs of MudPush II; - Followed by 483.4 BBLs of 11 ppg Lead cement; - Followed by 65.4 BBLs of 12 ppg tail cement. They said they got 16 BBLs of 11 ppg cement back to surface. After nippling down the cement had fallen back and the top of cement (TOC) was found at 68 ft. I arrived on location at 8:00 am and got with Granville Rizek and his plans for the top job. He told me that he had verbal approval from AOGGC rep Victoria Loepp to proceed with the procedure. Two %-inch tubing strings were run down opposing sides of the conductor. Both hit TOC at 77 ft - or 19 BBLs of annulus space. They pumped 58 BBLs of water to clean out the well. The returns looked to be clean water with a little cement color. Then 11 ppg LiteCrete cement was mixed and pumped. At 24.1 BBLs pumped they were getting 11 ppg returns. They pump another 11.1 BBLs of LiteCrete cement (already mixed) to make a total of 35.2 BBLs of 11 ppg LiteCrete cement pumped on the top job. They looked to have good cement at surface. Summary: I witnessed a successful top job for the surface casing cement at KRU 1C-152. Attachments: none p�NE® JIJL eh '6\c 2015-0829 Surface_Csg_TopJob KRU 1C-152 bn.docx Page 1 of 1 w i cvo N o 9 • • co V) CO ,co O. 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Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska.Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK Problem Well Supv [mailto:n1617Ca�conocophillips.com] Sent: Sunday, January 03, 2016 1:21 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L(DOA); DOA AOGCC Prudhoe Bay Subject: Recent MITs at Kuparuk Attached are the MIT files for the tests completed yesterday at Kuparuk. Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659-7224 Pager(907) 659-7000 pgr 909 1 tom, iiKUP INJ • 1C-152 Conocorh ll1 hpsWell Attributes Max Angle&MD TD Al • aska Inc• Wellbore API/UWI Field Name Wellbore Status ncl(`) MD(11KB) Act Btm(ftKB) Knee,aNlilhps , 500292354800 WEST SAK INJ 91,96 7,453.22 12,406.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-152,12/30/20153.19.08 PM SSSV.NIPPLE Last WO: 39,97 9/14/2015 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:GLV C/O pproven 12/17/2015 HANGER;34.6- i t all �� Casing Strings . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread -- --- ---- = ----CONDUCTOR 20 19.250 42.0 123.0 123.0 78.70 B • • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ,, ,•,,,, ,•,,;; SURFACE - 10 3/4 9.950 42.1 2,807.7 2,652.9 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread ........,.._............... ...._._............ ;; ......_.......,.INTERMEDIATE 75/8 6.875 39.1 4,934.8 3,848.2 29.70 L-80 Hydri1563 Ell El Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread LINER 4 1/2 3.958 4,782.7 12 367 3 3,870.5 12.60 L-80 IST m Liner Details t Nominal ID r: rt& Top(ftKB) Top(TVD)(ftKB) Top Incl El Item Des Com (in) - 4,782.7 3,833.1 81.30 PACKER BAKER HRD-E ZXP WI HD'S 4.920 4,802.7 3,836.0 82.12 NIPPLE BAKER RS NIPPLE 4.950 4,805.5 3,836.3 82.23 HANGER BAKER DG FLEX LOCK HANGER 4.830 4,815.3 3,837.6 82.64 SBE BAKER SEAL BORE EXTENSION 4.750 12,148.5 3,862.5 87.39 SWELL TAM SWELL PACKER A 3.958 PACKER Tubing Strings CONDUCTOR;420-123.0-4 Tubing Description 'String Ma,,.ID(in) Top(nKB) Set Depth(tt..Set Depth(TVD)(...Wl(ib/ft) Grade Top Connection TUBING 4 1/21 3.950 34.51 4,831.81 3,839.71 12.60 L-80 I HYD563 Completion Details Nominal ID NIPPLE.498.9 a%7, Top((tKB) Top(ND)(11(8) Top Incl(3 Item Des Com (in) 34.5 34.5 0.09 HANGER VETCO OFFSET TUBING HANGER TYPE MB-222A 3.875 498.9 498.8 3.93 NIPPLE CAMCO DB NIPPLE 3.813 ill 4,149.1 3,681.8 64.63 NIPPLE CAMCO DB NIPPLE W/NO GO PROFILE 3.750 4,791.5 3,834.4 81.66 LOCATOR BAKER MECHANICAL LOCATOR ' ' 3 880 4,814.4 3 837.5 82.60 SEAL ASSY BAKER BONDED SEAL ASSEMBLY W/MULE SHOE 3.850 GAS LIFT,2,603.7 Perforations&Slots snot [ ; Den Top(ND) Btm(ND) (shots/f Top(8)(13) Btm(ftKB) (11601 (ftKB) Zone Date II Type Com 4,840.1 12,133.8 3,840.6 3,861.9 9/13/2015 SLOTS Slotted Liner Cement Squeezes Top(ND) Btm(TVD)Top(nKB) Otm(ftKB) (ftKB) (ftKB) Des Start Date Com SURFACE,42.1-2,807.7-. 4,292.0 4,965.0 3,733.7 3,849.5 Remedial 9/5/2015 SLB pumped 3 bbl 11.5 ppg MudPush,PT lines to Cement Squeeze 600 low/3000 psi hi.Pumped total 20.4 5510111.5 ppg MudPush,insert wiper ball(6"wiper ball,had to cut down due wrong size),SLB pmped 25.4 bbl 15.8 ppg Tail Cement,followed with 5.7 bbl 11.5 ppg GAS LIFT:4,080.9 MudPush and 1.5 bbl of water to get MudPush to the floor.Blow down to cementers.Pull up hole 8 stands IF to 4206'MD,circulate 1.5 bottoms up then commence squeeze operations. Open kill line and pump to remove air,Close annular and perform hesitation squeeze,pumping down DP and Kill line.Rig pumped to squeeze cement @.5 bpm.Squeeze#1-Pumped 4.23 bbl to achieve 687 psi,shut in hold 10 min, pressure bled off to 449 psi.(OA=700 psi)Squeeze NIPPLE;4.149.1 #2-Pumped additional 1 bbl to bump up from 449 psi to 687 psi,shut in and hold ten minutes dropped to I 582 psi.#3-Pumped.6 bbl(5.8 total)to bump up pressure from 582 to 687 psi.Shut in 10 minutes and pressure dropped to 494 psi.(OA=700)#4-Another.6 bbl(6.4 total)to bump up from 494 to 687 psi,shut in 16 min-dropped to 449 psi.#5-Increased prerssure lijr • to 730 psi,pumped.85 bbl(7.25 total)bump from 449 psi to 730 psi.Shut in and hold 10 minutes,bled off to 526 psi. Bled off annular pressure,bled back 1.2 bbl, LOCATOR,0.791.5 qq rr total cement sqeezed away=6.05 bbl N f Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sew Type Type lin) (psi) Run Date Com 11. 1' 2,603.7 2,457.2 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/15/2015 16.21 it II deg SEAL ASSY:4,814.4 2 4,080.8 3,650.3 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 12/15/2015 61.40 NI 1 deg Notes:General&Safety End Date Annotation NOTE. lP it I ..- INTERMEDIATE,39.2.4,934.8 • SLOTS;4,840.1-12,133,8- LINER;4,782.7-12.367.3 EC 1R 215114 !;I=C 6 • 16x61 Schlumberger AOGCC Transmittal#: 16DEC15-S1301 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery t i1/2016 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1C-152 `RFVISIf1N-1*' Date Dispatched: 16-Dec-15 Job#: 15AKA0093 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: N/A Contents on CD N/A >IUN*Service 2"TVD x ETON*Service MD x SIGN#Service TVD LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x rVISION-1** As-Built Survey N/A Contents on CD N/A Nad83 x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt **REV-1** x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgarico c(�conocophillips.com AlaskaPTSPrintCenterslb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580p�y Received By: ) 2../Z cti 215114 • 16 36 1 RECEIVED )LC, 16 2u1,, AOGCC Schkirnberger 15-DECEMBER-2015 Notice of Revisions Please find the enclosed data set for well 1C-152 to supersede all previous edi- tions received. Revisions made were isolated to the Nad27 survey only. Stephanie Pacillo Schlumberger Petro Technical Services STEPHANIE PACILLO SCI ILUMBERGER ALASKA 16411 A STREET ANCHORAGE,AK 99518 I EMAIL:SPACILLO@SLB.COM I DIR 907.273.1770 FAX 907.273.4760 21 51 14 6 36 1 RECEIVED D REVISED 16 4:13 pm, Dec 11, 2015 ',OCC NADConversion Kuparuk River Unit Kuparuk 1C Pad 1C-152 Definitive Survey Report 25 November, 2015 NAD 27 • • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: True Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States 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 1C-152 Well Position +NI-S 0.00 usft Northing: 5,968,956.10 usfi Latitude: 70° 19'32.591 N +E/-W 0.00 usft Easting: 561,869.93 usfi Longitude: 149°29'53.846 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 57.60 usft Wellbore 1C-152 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2015 8/25/2015 19.00 80.99 57,507 Design 1C-152 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.97 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.97 0.00 0.00 345.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 83.03 1,965.03 1C-152 Srvy#1 GYD-GC-SS(1C-152) GYD-GC-SS Gyrodata gyro single shots 8/26/2015 9:0, 2,023.14 2,734.01 1C-152 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 12:5E 1 2,833.47 2,833.47 1C-152 Srvy#3 INC+TREND(1C-152) INC+TREND Inclinometer+known azi trend 9/1/2015 1:00 2,863.03 4,882.60 1C-152 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 1:01 4,882.60 12,345.49 1C-152 Srvy#5 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 1:03 12,406.00 12,406.00 1C-152 Srvy#6-Projection to TD(1C-1;BLIND Blind drilling 9/23/2015 2:3: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 39.97 0.00 0.00 39.97 -57.60 0.00 0.00 5,968,956.10 561,869.93 0.00 0.00 UNDEFINED 123.00 0.30 70.61 123.00 25.43 0.07 0.20 5,968,956.17 561,870.13 0.36 0.02 GYD-GC-SS(1) NOT an Actual Survey 20"x 42" 171.30 0.47 70.61 171.30 73.73 0.18 0.51 5,968,956.28 561,870.44 0.36 0.04 GYD-GC-SS(1) 265.73 0.84 76.61 265.72 168.15 0.47 1.55 5,968,956.58 561,871.47 0.40 0.05 GYD-GC-SS(1) 361.07 1.08 38.97 361.05 263.48 1.33 2.79 5,968,957.45 561,872.71 0.69 0.56 GYD-GC-SS(1) 453.55 2.91 21.23 453.47 355.90 4.19 4.19 5,968,960.33 561,874.08 2.07 2.97 GYD-GC-SS(1) 547.56 5.02 15.90 547.25 449.68 10.37 6.18 5,968,966.52 561,876.02 2.28 8.42 GYD-GC-SS(1) 640.05 6.88 8.63 639.24 541.67 19.74 8.12 5,968,975.91 561,877.89 2.17 16.97 GYD-GC-SS(1) 733.46 8.50 4.60 731.81 634.24 32.16 9.51 5,968,988.33 561,879.18 1.83 28.60 GYD-GC-SS(1) 11/25/2015 10:00:16AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: True Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 828.16 10.55 5.13 825.20 727.63 47.77 10.85 5,969,003.95 561,880.39 2.17 43.33 GYD-GC-SS(1) 922.47 11.03 4.14 917.84 820.27 65.37 12.27 5,969,021.56 561,881.66 0.55 59.96 GYD-GC-SS(1) 1,017.36 13.56 10.14 1,010.55 912.98 85.38 14.89 5,969,041.59 561,884.11 2.98 78.61 GYD-GC-SS(1) 1,112.15 15.72 17.68 1,102.26 1,004.69 108.55 20.75 5,969,064.81 561,889.78 3.03 99.49 GYD-GC-SS(1) 1,205.91 16.00 19.39 1,192.46 1,094.89 132.85 28.89 5,969,089.17 561,897.72 0.58 120.84 GYD-GC-SS(1) 1,300.08 16.76 18.87 1,282.80 1,185.23 157.94 37.59 5,969,114.33 561,906.22 0.82 142.82 GYD-GC-SS(1) 1,394.89 20.49 24.82 1,372.64 1,275.07 185.94 48.99 5,969,142.42 561,917.38 4.41 166.93 GYD-GC-SS(1) 1,490.51 22.51 27.29 1,461.60 1,364.03 217.40 64.40 5,969,174.01 561,932.53 2.31 193.33 GYD-GC-SS(1) 1,585.67 22.81 27.10 1,549.42 1,451.85 250.01 81.16 5,969,206.75 561,949.02 0.32 220.49 GYD-GC-SS(1) 1,680.58 26.89 27.15 1,635.52 1,537.95 285.50 99.34 5,969,242.39 561,966.91 4.30 250.06 GYD-GC-SS(1) 1,775.24 30.45 28.69 1,718.56 1,620.99 325.61 120.63 5,969,282.66 561,987.86 3.84 283.29 GYD-GC-SS(1) 1,868.28 33.61 29.82 1,797.43 1,699.86 368.64 144.76 5,969,325.89 562,011.63 3.46 318.61 GYD-GC-SS(1) 1,964.34 34.33 34.25 1,877.11 1,779.54 414.10 173.23 5,969,371.58 562,039.73 2.68 355.16 GYD-GC-SS(1) 2,069.71 34.04 38.27 1,964.28 1,866.71 461.82 208.23 5,969,419.58 562,074.32 2.16 392.19 MWD+IFR-AK-CAZ-SC(2) 2,117.93 29.94 38.28 2,005.17 1,907.60 481.87 224.05 5,969,439.76 562,089.97 8.50 407.47 MWD+IFR-AK-CAZ-SC(2) 2,162.76 27.40 38.48 2,044.50 1,946.93 498.73 237.40 5,969,456.73 562,103.18 5.67 420.30 MWD+IFR-AK-CAZ-SC(2) 2,211.99 24.44 38.15 2,088.78 1,991.21 515.61 250.74 5,969,473.71 562,116.39 6.02 433.15 MWD+IFR-AK-CAZ-SC(2) 2,260.94 22.73 37.58 2,133.64 2,036.07 531.07 262.76 5,969,489.27 562,128.28 3.52 444.97 MWD+IFR-AK-CAZ-SC(2) 2,307.42 23.46 37.81 2,176.39 2,078.82 545.50 273.91 5,969,503.79 562,139.31 1.58 456.02 MWD+IFR-AK-CAZ-SC(2) 2,402.27 19.48 44.61 2,264.66 2,167.09 571.69 296.61 5,969,530.16 562,161.78 4.94 475.44 MWD+IFR-AK-CAZ-SC(2) 2,448.74 16.86 50.37 2,308.81 2,211.24 581.51 307.24 5,969,540.06 562,172.34 6.83 482.17 MWD+IFR-AK-CAZ-SC(2) 2,496.69 17.04 50.88 2,354.67 2,257.10 590.37 318.05 5,969,549.02 562,183.07 0.49 487.94 MWD+IFR-AK-CAZ-SC(2) 2,591.82 16.21 48.54 2,445.83 2,348.26 607.96 338.81 5,969,566.77 562,203.68 1.12 499.55 MWD+IFR-AK-CAZ-SC(2) 2,686.65 16.21 42.56 2,536.89 2,439.32 626.47 357.68 5,969,585.44 562,222.40 1.76 512.55 MWD+IFR-AK-CAZ-SC(2) 2,733.32 16.23 42.15 2,581.71 2,484.14 636.11 366.47 5,969,595.15 562,231.11 0.25 519.58 MWD+IFR-AK-CAZ-SC(2) 2,807.70 17.37 38.81 2,652.91 2,555.34 652.47 380.40 5,969,611.62 562,244.90 2.01 531.78 NOT an Actual Survey 10 3/4"x 13-1/2 2,957.15 19.81 33.27 2,794.56 2,696.99 691.04 408.29 5,969,650.42 562,272.47 2.01 561.82 MWD+IFR-AK-CAZ-SC(4) 3,051.78 23.27 27.21 2,882.58 2,785.01 721.08 425.64 5,969,680.60 562,289.57 4.34 586.35 MWD+IFR-AK-CAZ-SC(4) 3,146.91 26.47 20.40 2,968.90 2,871.33 757.68 441.63 5,969,717.33 562,305.25 4.51 617.56 MWD+IFR-AK-CAZ-SC(4) 3,241.92 29.58 15.96 3,052.77 2,955.20 800.09 455.46 5,969,759.84 562,318.74 3.94 654.95 MWD+IFR-AK-CAZ-SC(4) 3,336.61 33.11 10.22 3,133.64 3,036.07 848.04 466.48 5,969,807.87 562,329.36 4.88 698.41 MWD+IFR-AK-CAZ-SC(4) 3,431.25 35.77 3.98 3,211.71 3,114.14 901.10 472.99 5,969,860.98 562,335.43 4.67 747.97 MWD+IFR-AK-CAZ-SC(4) 3,526.54 38.74 0.52 3,287.56 3,189.99 958.71 475.20 5,969,918.61 562,337.16 3.81 803.06 MWD+IFR-AK-CAZ-SC(4) 3,621.67 41.88 356.55 3,360.10 3,262.53 1,020.20 473.55 5,969,980.07 562,335.01 4.26 862.87 MWD+IFR-AK-CAZ-SC(4) 3,716.79 45.61 353.24 3,428.81 3,331.24 1,085.67 467.64 5,970,045.49 562,328.56 4.60 927.64 MWD+IFR-AK-CAZ-SC(4) 3,811.79 48.58 353.10 3,493.48 3,395.91 1,154.76 459.36 5,970,114.49 562,319.71 3.13 996.52 MWD+IFR-AK-CAZ-SC(4) 3,906.65 52.35 353.30 3,553.85 3,456.28 1,227.39 450.71 5,970,187.05 562,310.46 3.98 1,068.92 MWD+IFR-AK-CAZ-SC(4) 4,001.58 56.60 353.34 3,609.00 3,511.43 1,304.11 441.72 5,970,263.68 562,300.84 4.48 1,145.34 MWD+IFR-AK-CAZ-SC(4) 4,097.38 61.40 352.88 3,658.33 3,560.76 1,385.61 431.87 5,970,345.09 562,290.32 5.03 1,226.62 MWD+IFR-AK-CAZ-SC(4) 11/25/2015 10:00:16AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: True Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 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 4,150.38 64.71 352.86 3,682.34 3,584.77 1,432.48 426.00 5,970,391.91 562,284.07 6.25 1,273.41 MWD+IFR-AK-CAZ-SC(4) 4,191.55 67.11 353.03 3,699.14 3,601.57 1,469.78 421.39 5,970,429.16 562,279.14 5.84 1,310.63 MWD+IFR-AK-CAZ-SC(4) 4,238.80 70.16 353.03 3,716.36 3,618.79 1,513.45 416.05 5,970,472.78 562,273.45 6.46 1,354.20 MWD+IFR-AK-CAZ-SC(4) 4,286.46 71.71 352.87 3,731.92 3,634.35 1,558.15 410.52 5,970,517.44 562,267.55 3.27 1,398.81 MWD+IFR-AK-CAZ-SC(4) 4,381.61 75.93 351.15 3,758.43 3,660.86 1,648.62 397.81 5,970,607.79 562,254.09 4.76 1,489.49 MWD+IFR-AK-CAZ-SC(4) 4,427.43 77.27 351.44 3,769.05 3,671.48 1,692.68 391.06 5,970,651.78 562,246.98 2.99 1,533.79 MWD+IFR-AK-CAZ-SC(4) 4,476.22 79.00 350.68 3,779.08 3,681.51 1,739.84 383.64 5,970,698.88 562,239.18 3.86 1,581.27 MWD+IFR-AK-CAZ-SC(4) 4,571.39 79.65 349.06 3,796.71 3,699.14 1,831.91 367.19 5,970,790.80 562,221.97 1.81 1,674.45 MWD+IFR-AK-CAZ-SC(4) 4,666.26 79.99 346.14 3,813.48 3,715.91 1,923.09 347.14 5,970,881.81 562,201.17 3.05 1,767.72 MWD+IFR-AK-CAZ-SC(4) 4,760.37 80.38 345.99 3,829.53 3,731.96 2,013.10 324.81 5,970,971.61 562,178.10 0.44 1,860.43 MWD+IFR-AK-CAZ-SC(4) 4,852.24 84.15 345.38 3,841.89 3,744.32 2,101.29 302.30 5,971,059.61 562,154.87 4.16 1,951.45 MWD+IFR-AK-CAZ-SC(4) 4,882.60 85.30 345.40 3,844.68 3,747.11 2,130.54 294.68 5,971,088.79 562,147.00 3.79 1,981.68 MWD+IFR-AK-CAZ-SC(4) 4,934.80 86.99 345.87 3,848.19 3,750.62 2,180.99 281.76 5,971,139.13 562,133.67 3.36 2,033.75 NOT an Actual Survey(5) 7-5/8"x 9-7/8" 4,976.01 88.32 346.24 3,849.88 3,752.31 2,220.95 271.83 5,971,179.01 562,123.42 3.36 2,074.92 MWD+IFR-AK-CAZ-SC(5) 4,987.58 88.63 346.32 3,850.19 3,752.62 2,232.19 269.09 5,971,190.22 562,120.58 2.77 2,086.48 MWD+IFR-AK-CAZ-SC(5) 5,081.84 90.89 344.65 3,850.58 3,753.01 2,323.43 245.47 5,971,281.25 562,096.21 2.98 2,180.73 MWD+IFR-AK-CAZ-SC(5) 5,176.97 91.47 343.92 3,848.62 3,751.05 2,414.98 219.71 5,971,372.58 562,069.70 0.98 2,275.83 MWD+IFR-AK-CAZ-SC(5) 5,272.12 91.58 342.95 3,846.09 3,748.52 2,506.15 192.59 5,971,463.51 562,041.83 1.03 2,370.91 MWD+IFR-AK-CAZ-SC(5) 5,366.78 90.99 343.72 3,843.97 3,746.40 2,596.81 165.45 5,971,553.94 562,013.95 1.02 2,465.51 MWD+IFR-AK-CAZ-SC(5) 5,461.27 91.03 344.00 3,842.30 3,744.73 2,687.56 139.19 5,971,644.46 561,986.94 0.30 2,559.96 MWD+IFR-AK-CAZ-SC(5) 5,556.47 90.86 344.23 3,840.73 3,743.16 2,779.11 113.13 5,971,735.79 561,960.14 0.30 2,655.14 MWD+IFR-AK-CAZ-SC(5) 5,651.78 90.93 345.19 3,839.24 3,741.67 2,871.04 88.00 5,971,827.49 561,934.25 1.01 2,750.43 MWD+IFR-AK-CAZ-SC(5) 5,745.67 90.89 344.65 3,837.75 3,740.18 2,961.68 63.58 5,971,917.92 561,909.08 0.58 2,844.31 MWD+IFR-AK-CAZ-SC(5) 5,841.20 90.31 345.33 3,836.75 3,739.18 3,053.95 38.84 5,972,009.97 561,883.59 0.94 2,939.83 MWD+IFR-AK-CAZ-SC(5) 5,935.76 89.83 344.72 3,836.63 3,739.06 3,145.30 14.41 5,972,101.11 561,858.40 0.82 3,034.39 MWD+IFR-AK-CAZ-SC(5) 6,029.96 89.90 345.09 3,836.86 3,739.29 3,236.25 -10.12 5,972,191.84 561,833.13 0.40 3,128.59 MWD+IFR-AK-CAZ-SC(5) 6,125.21 90.03 345.77 3,836.91 3,739.34 3,328.43 -34.09 5,972,283.82 561,808.41 0.73 3,223.84 MWD+IFR-AK-CAZ-SC(5) 6,219.78 89.90 346.76 3,836.97 3,739.40 3,420.30 -56.54 5,972,375.49 561,785.20 1.06 3,318.39 MWD+IFR-AK-CAZ-SC(5) 6,314.78 89.86 347.79 3,837.17 3,739.60 3,512.96 -77.46 5,972,467.97 561,763.51 1.09 3,413.31 MWD+IFR-AK-CAZ-SC(5) 6,409.37 89.86 348.14 3,837.40 3,739.83 3,605.47 -97.19 5,972,560.30 561,743.03 0.37 3,507.77 MWD+IFR-AK-CAZ-SC(5) 6,504.15 90.21 348.73 3,837.34 3,739.77 3,698.33 -116.19 5,972,652.99 561,723.27 0.72 3,602.38 MWD+IFR-AK-CAZ-SC(5) 6,599.66 90.14 349.22 3,837.05 3,739.48 3,792.07 -134.45 5,972,746.57 561,704.23 0.52 3,697.66 MWD+IFR-AK-CAZ-SC(5) 6,694.55 90.17 348.52 3,836.80 3,739.23 3,885.18 -152.77 5,972,839.51 561,685.15 0.74 3,792.33 MWD+IFR-AK-CAZ-SC(5) 6,789.67 90.14 346.96 3,836.54 3,738.97 3,978.13 -172.97 5,972,932.28 561,664.19 1.64 3,887.34 MWD+IFR-AK-CAZ-SC(5) 6,884.12 90.21 346.55 3,836.25 3,738.68 4,070.06 -194.61 5,973,024.03 561,641.79 0.44 3,981.75 MWD+IFR-AK-CAZ-SC(5) 6,978.13 89.90 346.87 3,836.16 3,738.59 4,161.55 -216.22 5,973,115.33 561,619.43 0.47 4,075.71 MWD+IFR-AK-CAZ-SC(5) 7,074.57 89.48 345.70 3,836.68 3,739.11 4,255.24 -239.08 5,973,208.82 561,595.79 1.29 4,172.13 MWD+IFR-AK-CAZ-SC(5) 7,168.63 90.58 344.55 3,836.63 3,739.06 4,346.15 -263.23 5,973,299.51 561,570.90 1.69 4,266.18 MWD+IFR-AK-CAZ-SC(5) 7,263.53 91.85 342.96 3,834.62 3,737.05 4,437.23 -289.77 5,973,390.37 561,543.62 2.14 4,361.04 MWD+IFR-AK-CAZ-SC(5) 11/25/2015 10:00:16AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: True Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,358.34 91.51 342.90 3,831.84 3,734.27 4,527.83 -317.59 5,973,480.72 561,515.05 0.36 4,455.74 MWD+IFR-AK-CAZ-SC(5) 7,453.22 91.96 342.33 3,828.97 3,731.40 4,618.33 -345.92 5,973,570.98 561,485.97 0.77 4,550.50 MWD+IFR-AK-CAZ-SC(5) 7,548.45 91.92 341.86 3,825.74 3,728.17 4,708.90 -375.18 5,973,661.29 561,455.97 0.50 4,645.55 MWD+IFR-AK-CAZ-SC(5) 7,643.66 91.30 342.61 3,823.07 3,725.50 4,799.53 -404.22 5,973,751.67 561,426.19 1.02 4,740.61 MWD+IFR-AK-CAZ-SC(5) 7,738.48 90.21 344.11 3,821.82 3,724.25 4,890.37 -431.37 5,973,842.28 561,398.30 1.96 4,835.38 MWD+IFR-AK-CAZ-SC(5) 7,832.79 90.51 345.88 3,821.23 3,723.66 4,981.46 -455.79 5,973,933.15 561,373.13 1.90 4,929.68 MWD+IFR-AK-CAZ-SC(5) 7,927.82 90.34 345.09 3,820.52 3,722.95 5,073.45 -479.60 5,974,024.94 561,348.56 0.85 5,024.71 MWD+IFR-AK-CAZ-SC(5) 7,979.73 89.04 343.68 3,820.80 3,723.23 5,123.44 -493.58 5,974,074.81 561,334.18 3.69 5,076.61 MWD+IFR-AK-CAZ-SC(5) 8,022.94 87.77 343.12 3,822.01 3,724.44 5,164.83 -505.91 5,974,116.09 561,321.50 3.21 5,119.78 MWD+IFR-AK-CAZ-SC(5) 8,117.49 87.90 341.84 3,825.58 3,728.01 5,254.93 -534.36 5,974,205.94 561,292.32 1.36 5,214.17 MWD+IFR-AK-CAZ-SC(5) 8,212.82 87.94 344.80 3,829.04 3,731.47 5,346.18 -561.70 5,974,296.95 561,264.23 3.10 5,309.39 MWD+IFR-AK-CAZ-SC(5) 8,307.00 89.49 347.53 3,831.15 3,733.58 5,437.59 -584.21 5,974,388.17 561,240.96 3.33 5,403.51 MWD+IFR-AK-CAZ-SC(5) 8,401.02 89.97 348.93 3,831.59 3,734.02 5,529.63 -603.39 5,974,480.04 561,221.03 1.57 5,497.38 MWD+IFR-AK-CAZ-SC(5) 8,496.48 90.41 348.19 3,831.28 3,733.71 5,623.19 -622.32 5,974,573.43 561,201.33 0.90 5,592.66 MWD+IFR-AK-CAZ-SC(5) 8,589.29 89.69 348.66 3,831.20 3,733.63 5,714.11 -640.94 5,974,664.19 561,181.96 0.93 5,685.30 MWD+IFR-AK-CAZ-SC(5) 8,685.55 89.90 349.39 3,831.54 3,733.97 5,808.61 -659.27 5,974,758.52 561,162.86 0.79 5,781.32 MWD+IFR-AK-CAZ-SC(5) 8,782.80 89.86 350.98 3,831.74 3,734.17 5,904.44 -675.85 5,974,854.20 561,145.49 1.64 5,878.17 MWD+IFR-AK-CAZ-SC(5) 8,877.01 89.97 351.65 3,831.88 3,734.31 5,997.57 -690.07 5,974,947.20 561,130.50 0.72 5,971.81 MWD+IFR-AK-CAZ-SC(5) 8,971.82 89.93 350.56 3,831.97 3,734.40 6,091.23 -704.73 5,975,040.73 561,115.07 1.15 6,066.08 MWD+IFR-AK-CAZ-SC(5) 9,067.25 89.93 348.98 3,832.08 3,734.51 6,185.14 -721.68 5,975,134.49 561,097.35 1.66 6,161.17 MWD+IFR-AK-CAZ-SC(5) 9,161.79 89.49 347.73 3,832.56 3,734.99 6,277.73 -740.76 5,975,226.91 561,077.51 1.40 6,255.55 MWD+IFR-AK-CAZ-SC(5) 9,255.98 89.42 346.33 3,833.46 3,735.89 6,369.51 -761.90 5,975,318.51 561,055.61 1.49 6,349.67 MWD+IFR-AK-CAZ-SC(5) 9,350.72 89.62 345.57 3,834.25 3,736.68 6,461.42 -784.90 5,975,410.21 561,031.86 0.83 6,444.40 MWD+IFR-AK-CAZ-SC(5) 9,446.13 89.42 344.51 3,835.05 3,737.48 6,553.59 -809.53 5,975,502.16 561,006.48 1.13 6,539.80 MWD+IFR-AK-CAZ-SC(5) 9,540.60 89.76 343.90 3,835.73 3,738.16 6,644.49 -835.24 5,975,592.84 560,980.02 0.74 6,634.26 MWD+IFR-AK-CAZ-SC(5) 9,636.88 89.31 342.91 3,836.51 3,738.94 6,736.75 -862.74 5,975,684.87 560,951.76 1.13 6,730.50 MWD+IFR-AK-CAZ-SC(5) 9,732.08 89.35 343.09 3,837.62 3,740.05 6,827.79 -890.57 5,975,775.66 560,923.18 0.19 6,825.63 MWD+IFR-AK-CAZ-SC(5) 9,825.67 89.38 342.55 3,838.66 3,741.09 6,917.20 -918.21 5,975,864.83 560,894.81 0.58 6,919.15 MWD+IFR-AK-CAZ-SC(5) 9,919.96 89.52 342.55 3,839.56 3,741.99 7,007.14 -946.49 5,975,954.53 560,865.80 0.15 7,013.35 MWD+IFR-AK-CAZ-SC(5) 10,014.56 90.03 343.12 3,839.94 3,742.37 7,097.53 -974.40 5,976,044.67 560,837.14 0.81 7,107.88 MWD+IFR-AK-CAZ-SC(5) 10,110.17 89.90 344.28 3,839.99 3,742.42 7,189.29 -1,001.24 5,976,136.21 560,809.55 1.22 7,203.46 MWD+IFR-AK-CAZ-SC(5) 10,205.84 90.00 345.20 3,840.08 3,742.51 7,281.59 -1,026.42 5,976,228.28 560,783.61 0.97 7,299.13 MWD+IFR-AK-CAZ-SC(5) 10,300.14 90.45 346.86 3,839.71 3,742.14 7,373.10 -1,049.18 5,976,319.59 560,760.10 1.82 7,393.41 MWD+IFR-AK-CAZ-SC(5) 10,397.27 89.28 347.40 3,839.94 3,742.37 7,467.78 -1,070.82 5,976,414.09 560,737.68 1.33 7,490.47 MWD+IFR-AK-CAZ-SC(5) 10,490.83 89.48 347.92 3,840.95 3,743.38 7,559.18 -1,090.81 5,976,505.30 560,716.94 0.60 7,583.93 MWD+IFR-AK-CAZ-SC(5) 10,585.64 88.83 347.02 3,842.35 3,744.78 7,651.72 -1,111.38 5,976,597.66 560,695.61 1.17 7,678.64 MWD+IFR-AK-CAZ-SC(5) 10,680.53 88.90 346.48 3,844.23 3,746.66 7,744.06 -1,133.12 5,976,689.82 560,673.11 0.57 7,773.46 MWD+IFR-AK-CAZ-SC(5) 10,774.67 89.55 345.59 3,845.50 3,747.93 7,835.41 -1,155.84 5,976,780.96 560,649.64 1.17 7,867.58 MWD+IFR-AK-CAZ-SC(5) 10,870.23 89.45 345.08 3,846.33 3,748.76 7,927.85 -1,180.03 5,976,873.20 560,624.69 0.54 7,963.13 MWD+IFR-AK-CAZ-SC(5) 10,962.96 90.03 344.51 3,846.75 3,749.18 8,017.33 -1,204.35 5,976,962.47 560,599.64 0.88 8,055.86 MWD+IFR-AK-CAZ-SC(5) 11/25/2015 10:00::16AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: True Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 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 11,055.17 89.90 343.39 3,846.81 3,749.24 8,105.95 -1,229.84 5,977,050.86 560,573.42 1.22 8,148.05 MWD+IFR-AK-CAZ-SC(5) 11,147.08 89.97 343.58 3,846.92 3,749.35 8,194.07 -1,255.97 5,977,138.75 560,546.57 0.22 8,239.93 MWD+IFR-AK-CAZ-SC(5) 11,240.29 89.97 344.08 3,846.96 3,749.39 8,283.59 -1,281.93 5,977,228.05 560,519.87 0.54 8,333.12 MWD+IFR-AK-CAZ-SC(5) 11,332.67 89.21 344.72 3,847.63 3,750.06 8,372.56 -1,306.77 5,977,316.80 560,494.30 1.08 8,425.49 MWD+IFR-AK-CAZ-SC(5) 11,425.77 88.90 343.54 3,849.16 3,751.59 8,462.10 -1,332.22 5,977,406.12 560,468.11 1.31 8,518.57 MWD+IFR-AK-CAZ-SC(5) 11,515.52 89.62 345.27 3,850.32 3,752.75 8,548.54 -1,356.35 5,977,492.34 560,443.28 2.09 8,608.30 MWD+IFR-AK-CAZ-SC(5) 11,607.85 89.62 344.42 3,850.93 3,753.36 8,637.65 -1,380.49 5,977,581.25 560,418.41 0.92 8,700.63 MWD+IFR-AK-CAZ-SC(5) 11,697.96 89.31 344.37 3,851.77 3,754.20 8,724.44 -1,404.73 5,977,667.82 560,393.46 0.35 8,790.73 MWD+IFR-AK-CAZ-SC(5) 11,791.11 89.04 344.61 3,853.11 3,755.54 8,814.18 -1,429.63 5,977,757.36 560,367.81 0.39 8,883.86 MWD+IFR-AK-CAZ-SC(5) 11,883.00 88.90 345.01 3,854.77 3,757.20 8,902.85 -1,453.70 5,977,845.81 560,343.01 0.46 8,975.74 MWD+IFR-AK-CAZ-SC(5) 11,973.26 88.36 343.77 3,856.92 3,759.35 8,989.75 -1,477.99 5,977,932.50 560,318.02 1.50 9,065.97 MWD+IFR-AK-CAZ-SC(5) 12,066.77 88.42 344.91 3,859.55 3,761.98 9,079.76 -1,503.22 5,978,022.28 560,292.05 1.22 9,159.43 MWD+IFR-AK-CAZ-SC(5) 12,158.68 87.26 343.86 3,863.02 3,765.45 9,168.21 -1,527.94 5,978,110.52 560,266.60 1.70 9,251.27 MWD+IFR-AK-CAZ-SC(5) 12,250.13 87.94 345.44 3,866.85 3,769.28 9,256.31 -1,552.12 5,978,198.42 560,241.69 1.88 9,342.63 MWD+IFR-AK-CAZ-SC(5) 12,345.49 88.42 345.87 3,869.87 3,772.30 9,348.65 -1,575.74 5,978,290.55 560,217.32 0.68 9,437.94 MWD+IFR-AK-CAZ-SC(5) 12,367.30 88.53 345.99 3,870.46 3,772.89 9,369.80 -1,581.04 5,978,311.65 560,211.85 0.75 9,459.74 'NOT an Actual Survey 4 1/2"x 6-3/4" 12,406.00 88.72 346.21 3,871.38 3,773.81 9,407.36 -1,590.33 5,978,349.13 560,202.25 0.75 9,498.42 Projection to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Q Yes ❑ No I have checked to the best of my ability that the following data is correct: U Surface Coordinates n Declination & Convergence U GRS Survey Corrections Survey Tool Codes Vincent cn-Vmant Oral. SLB DE: Osara DoM.T015DY]31/3M?WDU !• 442.Mgt* SDusa Client Representative: 2- `� '°°�"`°` Date: 23-Sep-2015 11/25/2015 10:00:16AM Page 6 COMPASS 5000.1 Build 74 • . Guhl, Meredith D (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Wednesday, November 04, 2015 8:41 AM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K(DOA); Haggerty-Sherrod,Ann (Northland Staffing Services) Subject: RE: KRU 1C-152, PTD 215-114, Complete list of Geologic Markers Meredith, please find the revised formation tops for 1C-152. 1C-152 NAME MD TVD TOP PERMAFROST Surface Surface BASE PERMAFROST 1855 1786 UGNU A 3940 3574 WEST SAK D 4782 3833 TD IN WEST SAK D 12406 3871 If you have any questions or concerns please let me know. Thanks David From: Guhl, Meredith D (DOA) Sent: Friday, October 30, 2015 3:11 PM To: 'Hyden, Duncan P' Cc: Bettis, Patricia K(DOA) Subject: KRU 1C-152, PTD 215-114, Complete list of Geologic Markers Duncan, During a review of the 10-407 form submitted for KRU 1C-152, PTD 215-114, completed 9/14/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by November 13, 2015. If you have any questions, please contact me. Thank you, Meredith • • Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 r RECEIVE') • STATE OF ALASKA • OCT13 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOArn la.Well Status: 01, ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ lb.Well Class: 20AAC 25.105 20AAC 25.11t7 Development ❑ Exploratory El GINJ ❑ WINJ ❑J - WAG❑ WDSPL❑ No.of Completions: Service ❑✓ . Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: '9/14/2015 215-114/315-543 3.Address: 7. Date Spudded: 15.API Number: P. O. Box 100360,Anchorage,AK 99501 .8/25/2015 .50-029-23548-00 - 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 1279'FNL, 865'FWL, Sec. 12,T11N, R10E, UM .9/9/2015 - KRU 1C-152• Top of Productive Interval: 9. KB(ft above MSL): `97.6' 17. Held/Pool(s): 754'FSL, 1186'FWL, Sec. 1,T11 N, R10E, UM GL(ft above MSL): . 57.6' ' Kuparuk River Field/West Sak Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2432'FNL,720'FEL,Sec. 35,T12N, R10E, UM . 12367'MD/3870'TVD ADL 025649, 025638 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 561870 y- 5968956 Zone- 4 •12406'MD/3871'TVD 931695 TPI: x- 562173 y- 5970992 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 560203 y- 5978349 Zone- 4 nipple @ 499'MD/499'TVD 1855'MD/1786'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 na (ft MSL) not applicable 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/Sonic 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 78.7# B 42' 123' 42' 123' 42" 193 sx ASI, 175 sx ASI 10.75" 45.5# L-80 42' 2808' 42' 2653' 13.5" 1451 sx LiteCRETE,227 sx LiteCRETE 105 sx LiteCRETE top job 7.625" 29.7# L-80 39' 4935' 39' 3848' 9.875" 222 sx Class G,249 sx Class G 4.5" 12.6# L-80 4783' 12367' 3833' 3870' 6.75" liner completion 24.Open to production or injection? Yes 0 No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 4.5" 4832'MD 4783'MD/3833'TVD slotted liner from 4840-12134'MD 3841'-3862'TVD 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. UP ' Was hydraulic fracturing used during completion? Yes❑ No 0 e' Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 4292-4965 cement squeeze 122 sx Class G 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on facility hook-up . Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period .-4 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate 11.- Form Form 10-407 Revised 5/2015 (/n_ !m/2 3//,j CONTINU DIONIPAGE 2 RBDMS1OCT 1 4 2015 Submit ORIGINIAL on 28.CORE DATA Conventional CAj: Yes ❑ No E Sidewall Cores:Ilks ❑ No 0 If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. not applicable 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1855' 1786' Attach separate pages to this form, if needed,and submit detailed test information,including reports,per 20 AAC 25.071. Top West Sak D 4782' 3833' Base West Sak D 12260' 3867' Formation at total depth: West Sak D 31. List of Attachments: Summary of Daily Operations,schematic,final directional survey, cement detail repors Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. _ / Contact: Duncan Hyden @ 265-6862 Email: Duncan.P.Hvden@cop.comR., Printed Name: Graham L.Alvord Title: Alaska Drilling Manager Signature: e_. 04 A Phone: 265-6120 Date: 1°0 71Z'"`S `111 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: 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 lb: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: 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 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records 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. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. 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. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only • • Guhl, Meredith D (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Wednesday, November 04, 2015 8:41 AM To: Guhl, Meredith D (DOA) Cc: Bettis, Patricia K(DOA); Haggerty-Sherrod,Ann (Northland Staffing Services) Subject: RE: KRU 1C-152, PTD 215-114, Complete list of Geologic Markers Meredith, please find the revised formation tops for 1C-152. 1C-152 NAME MD TVD TOP PERMAFROST Surface Surface BASE PERMAFROST 1855 1786 UGNU A 3940 3574 WEST SAK D 4782 3833 TD IN WEST SAK D 12406 3871 If you have any questions or concerns please let me know. Thanks David From: Guhl, Meredith D (DOA) Sent: Friday, October 30, 2015 3:11 PM To: 'Hyden, Duncan P' Cc: Bettis, Patricia K(DOA) Subject: KRU 1C-152, PTD 215-114, Complete list of Geologic Markers Duncan, During a review of the 10-407 form submitted for KRU 1C-152, PTD 215-114,completed 9/14/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by November 13, 2015. If you have any questions, please contact me. Thank you, Meredith 1 • Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 KUP SVC 1C-152 ConocoPhillips ° Well Attributes • Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Btm(ftKB) �� 500292354800 WESTSAK SVC 91.96 7,453.22 12,406.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-152,9/30/2015 239:00 PM SSSV:NIPPLE Last WO: 39.97 9/14/2015 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL smsmith 9/25/2015 HANGER;34.6- V;ill Casing Strings •• Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread --------------------------------- CONDUCTOR 20 19.250 42.0 123.0 123.0 78.70 B Casing Description '013(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread w ata SURFACE 103/4 9.950 42.1 2,807.7 2,652.9 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread __...._..._.._ .........._....__..........._...._............. _._......._..INTERMEDIATE 75/8 6.875 39.1 4,934.8 3,848.2 29.70 L-80 HydriI563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 4,782.7 12,367.3 3,870.5 12.60 L-80 IBT-m Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Inel(°) Item Des Com (in) 4,782.7 3,833.1 81.30 PACKER BAKER HRD-E ZXP W/HD'S ' 4.920 4,802.7 3,836.0 82.12 NIPPLE BAKER RS NIPPLE 4.950 4,805.5 3,836.3 82.23 HANGER BAKER DG FLEX LOCK HANGER 4.830 4,815.3 3,837.6 82.64 SBE BAKER SEAL BORE EXTENSION 4.750 12,148.5 3,862.5 87.39 SWELL TAM SWELL PACKERA 3.958 PACKER Tubing Strings CONDUCTOR;42.0-123.0 CI TubingDescription StringMa...IDTopftKB Set Depth(ft..Set Depth TVD Wt lb/fl Grade TopConnection P (in) (ftKB) P P (TVD)( ( ) TUBING 41/2 3.958 34.5 4,831.8 3,839.7 12.60 L-80 HYD563 J Completion Details Nominal ID NIPPLE;498.9 LI; it Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 34.5 34.5 0.09 HANGER VETCO OFFSET TUBING HANGER TYPE MB-222A 3.875 498.9 498.8 3.93 NIPPLE CAMCO DB NIPPLE 3.813 4,149.1 3,681.8 64.63 NIPPLE CAMCO DB NIPPLE W/NO GO PROFILE W/RHC 3.750 PLUG 1111 4,791.5 3,834.4 81.66 LOCATOR BAKER MECHANICAL LOCATOR 3.880 GAS LIFT;2,603.7 4,814.4 3,837.5 82.60 SEAL ASSY BAKER BONDED SEAL ASSEMBLY W/MULE SHOE 3.850 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) OMB) (ftKB) Zone Date t) Type Com 4,840.1 12,133.8 3,840.6 3,861.9 9/13/2015 SLOTS Slotted Liner Cement Squeezes Top(ND) Btm(TVD) SURFACE;42.1-2,807.7--. J Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 4,292.0 4,965.0 3,733.7 3,849.5 Remedial 9/5/2015 SLB pumped 3 bbl 11.5 ppg Mucpush,PT lines to Cement Squeeze 600 low/3000 psi hi.Pumped total 20.4 bbl of 11.5 ppg MudPush,insert wiper ball(6"wiper ball,had to cut down due wrong size),SLB pmped 25.4 bbl 15.8 GAS LIFT;4,080.8 ppg Tail Cement,followed with 5.7 bbl 11.5 ppg MudPush and 1.5 bbl of water to get MudPush to the floor.Blow down to cementers.Pull up hole 8 stands to 4206'MD,circulate 1.5 bottoms up then commence squeeze operations. Open kill line and pump to remove air,Close annular and perform hesitation squeeze,pumping down DP and Kill line.Rig pumped to squeeze cement @.5 bpm.Squeeze#1-Pumped 4.23 bbl to achieve 687 psi,shut in hold 10 min, NIPPLE;4,149.1 pressure bled off to 449 psi.(OA=700 psi)Squeeze #2-Pumped additional 1 bbl to bump up from 449 psi 1': to 687 psi,shut in and hold ten minutes dropped to 1-.- 582 psi.#3-Pumped.6 bbl(5.8 total)to bump up I pressure from 582 to 687 psi.Shut in 10 minutes and pressure dropped to 494 psi.(0A=700)#4-Another.6 bbl(6.4 total)to bump up from 494 to 687 psi,shut in I',- it 16 min-dropped to 449 psi.#5-Increased prerssure to 730 psi,pumped.85 bbl(7.25 total)bump from 449 psi to 730 psi.Shut in and hold 10 minutes,bled off to LOCATOR;4,751.5 526 psi. Bled off annular pressure,bled back 1.2 bbl, „. total cement sqeezed away=6.05 bbl l Mandrel Inserts St I otl Top(ND) Valve Latch Port Size TRO Run N, Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com V 1 2,603.7 2,457.2 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/13/2015 16.21 SEAL ASSY;4.814.4 ! deg I'= 2 4,080.8 3,650.3 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 0.0 9/13/2015 61.40 deg Notes:General&Safety End Date Annotation NOTE. 1 1 I 11 I 1 INTERMEDIATE;39.2-4,934.8- ' i SLOTS; 9.2 4,934.8- SLOTS;4,840.1-12,133.8 /wr LINER;4,782.7-12,367.3 • S ConocoP'hillips Time Log & Summary Weliview Web Reporting Report Well Name: 1C-152 Rig Name: DOYON 25 Job Type: DRILLING ORIGINAL Rig Accept: 8/24/2015 12:00:00 AM Rig Release: 9/14/2015 6:00:00 AM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 08/21/2015 24 hr Summary DMOB and move sub and casing complex to KCC. Stage sub and casing complex at KCC for move to 1C-152. Rig move distance 5.4 miles. 00:00 06:30 6.50 MIRU MOVE RURD P Unplug electrical in interconnects. Move parts trailer, skid rig floor and walk out motor shed. Lay down derrick, un-pin pipe shed and walk out from under sub and stage mats. 06:30 08:00 1.50 MIRU MOVE MOB P Head to 1C with parts trailer. 08:00 12:00 4.00 MIRU MOVE RURD P Walk sub around and hook up jeep and ready shop. Hook up trucks to sub and casing complexes. 12:00 18:00 6.00 MIRU MOVE MOB P Stage mats on spine road and move sub and casing complexes and to KOC. 18:00 00:00 6.00 MIRU MOVE MOB P Stage mat on spine road and move pits to KOC. 08/22/2015 Stage rig at KCC, palce mats on 1C access road. 00:00 12:00 12.00 MIRU MOVE RURD P Continue to move and prep pump and power complexes for move to KCC. 12:00 00:00 12.00 MIRU MOVE MOB P Move and stage pump and power complex at KCC. Remove mats from Spine road and place on 1C access road. X8/23/2015 Move rig from KCC to 1C-152. Begin rigging up. Moved 5.4 miles from 1D to 1C. 00:00 12:00 12.00 MIRU MOVE MOB P Move pump complex, power and pit complex, and sub to 1C-152. Move distance 5.4 miles 1D-145 to 1C-152. 12:00 00:00 12.00 MIRU MOVE MOB P Lay mats on pad. Spot sub and complexes, R/U sub and complexes, interconnects,electrical, air and fluids. Rig Accepted 23:59 hours 8/23/15 08/24/2015 Continue to RU and spot rig. Marry interconnects and position modules, Scope derrick and swap power to rig generators. PU and MU top drive components and rotary table components. Perform pipe management with 5"and 4"drill)pipe. 00:00 12:00 12.00 MIRU MOVE RURD P Continue R/U of electrical, air, interconnects and scope derrick. N/U diverter, riser, flow line and Joe's box. Install PS-21 slips, elevators and mouse hole. 12:00 15:00 3.00 MIRU MOVE PULD P Verify pipe count in tubs and PU 27 joints of 5" DP and build 9 stands in the mouse hole. Page 1 of 31 Time Logs 11110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 21:00 6.00 MIRU MOVE PULD P PU 78 joints of 4"DP and build 26 stands in the mouse hole. Single/double building 19 additional stands for a total of 45 stands stood back in derrick. 21:00 23:00 2.00 MIRU MOVE PULD P PU 5 stands HWDP, 1 Jar stand and load GYRO. 23:00 00:00 1.00 MIRU MOVE BHAH P Pull slips and master bushings and PU DC's for BHA#1. 08/25/2015 PU 5",4", and BHA#1. Drill to 223'and POOH and PU BHA#2. Drill ahead to 1060'with Gyro surveys. 00:00 01:00 1.00 MIRU MOVE BHAH P Continue to PU BHA#1, HWDP and 7 1/4" NM DC. 01:00 02:00 1.00 MIRU MOVE BOPE P Test Diverter and draw down test on Koomey. Test witness waived by AOGCC Chuck Scheve. 02:00 02:30 0.50 MIRU MOVE SFTY P Rig evacuation drill, requested by AOGCC. Performed with CRT=3 min 15 sec. 02:30 05:00 2.50 0 98 MIRU MOVE BHAH P Continue to MU BHA#1. RIH and tag at 98'with 10K down weight. Junk observed in the conductor; orange hard hat in the hole. 05:00 06:00 1.00 98 118 MIRU MOVE DRLG P Clean out 20"conductor and retrieve orange hard hat. 06:00 07:00 1.00 118 223 SURFA( DRILL DDRL P Drill from 118'to 223', pumping 500 gpm with 330 psi,40 rpm with 1K TQ,WOB 6K, PU=52K, SO=52K and ROT=51K. 07:00 08:00 1.00 223 0 SURFA( DRILL TRIP P POOH from 223'to 0'for BHA#2 and inspect bit; Good. 08:00 08:15 0.25 0 0 SURFA( DRILL SFTY P PJSM for BHA handling. 08:15 11:15 3.00 0 155 SURFA( DRILL BHAH P PU and MU BHA#2. Scribe Gyro pulse to mud motor and MWD ARC. Continue to PU BHA to 173'. Pull back and prep to wash down to obtasin Gyro surveys. 11:15 12:00 0.75 155 223 SURFA( DRILL SRVY P Perform survey points at 155'and 214'. Some washing down needed to get back to bottom and to get to survey points. 12:00 13:45 1.75 223 404 SURFA( DRILL DDRL P Drill 13 1/2" hole from 223'to 404'at 550 GPM with 720 psi,69% FO,45 RPM with 4K torque and 20K WOB. PU=66K, SO=71K, Rot=65K. 13:45 14:15 0.50 404 404 SURFA( DRILL BHAH P Stand back one stand and PU Jar Stand and RIH back and perform gyro survey. 14:15 18:00 3.75 404 684 SURFA( DRILL DDRL P Drill 13 1/2"hole from 404'to 684'at 550 GPM with 920 psi, 44% FO,60 RPM with 4K torque and 25K WOB. PU=82K, S0=80K, Rot=81K. Page 2 of 31 • Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 684 1,060 SURFA( DRILL DDRL P Drill 13 1/2"hole from 684'to 1060'at 600 GPM with 1265 psi,43% FO, 60 RPM with 6K torque and 25K WOB. PU=90K, SO=92K, Rot=92K. AST=2.95,ART=3.42,ADT=6.37, TTL bit hours=7.54, Jars=7.54 hours. No losses this tour. No losses for day. 38/26/2015 Continue to drill ahead in 13 1/2"surface hole from 1060'to 1643. POOH for close approach assessment per policy and procedure. Resolve close approach issues and drill ahead to 2220'. 00:00 06:00 6.00 1,060 1,439 SURFA( DRILL DDRL P Drill 13 1/2"hole from 1060'to 1439' at 600 GPM with 1030 psi,42% FO, 60 RPM with 6K torque and 25K WOB. PU= 102K, SO=95K, Rot= 99K. 06:00 09:00 3.00 1,439 1,630 SURFA( DRILL DDRL P Drill 13 1/2"hole from 1439'to 1630' at 600 GPM with 1140 psi, 42%FO, 60 RPM with 6K torque and 28-36K WOB. PU= 103K, SO=99K, Rot= 102K. 09:00 09:30 0.50 1,630 1,443 SURFA( DRILL PMPO T POOH due to Close approach encroachment on TC plots, pumping 3 BPM with 144 psi,26% FO, PU= 101K, S0=95K. Observe good displacement while pulling. 09:30 10:00 0.50 1,443 1,630 SURFA( DRILL TRIP T RIH from 1443'to 1630'on elevators with good displacement monitor via pits. 10:00 10:30 0.50 1,630 1,643 SURFA( DRILL DDRL P Drill 13 1/2" hole from 1630'to 1643' at 450 GPM with 750 psi,41% FO, and 38K WOB. PU= 102K, SO= 95K, Rot=99K. AST=2.60,ART= 1.57,ADT=4.17, TTL bit hours= 11.99,Jars= 10.82 hours. 10:30 12:00 1.50 1,643 1,233 SURFA( DRILL PMPO T POOH, pumping 3 BPM with 215 psi, 26% FO, PU= 104K. Crew change. No losses for tour. 12:00 13:00 1.00 1,233 0 SURFA( DRILL PMPO T Continue to POOH, pumping 3 BPM with 215 psi, 26% FO, PU= 104K. 13:00 14:00 1.00 1,060 1,156 SURFA( DRILL TRIP T Trip in from 1060'to 1469'. POOH from 1469'to 1156 14:00 14:15 0.25 1,156 1,156 SURFA( DRILL SVRG P Service rig top drive and blocks. 14:15 14:45 0.50 1,156 1,156 SURFA( DRILL RGRP T Replace cuttings tank discharge hose. Circulate and recip at 3 BPM with 150 psi and 24%FO. 14:45 15:30 0.75 1,156 1,633 SURFA( DRILL TRIP T RIH on elevators from 1156'to 1633'. PU=98K, SO=95K. Page 3 of 31 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code - Subcode T Comment 15:30 00:00 8.50 1,633 2,220 SURFA( DRILL DDRL P Drill 13 1/2"hole from 1643'to 2220' at 650 GPM with 1400 psi,47% FO, 70 RPM with 4K torque, and 9K WOB. PU= 116K, S0= 105K, Rot= 106K. AST=3.06,ART= 1.23, ADT=4.29,TTL bit hours= 15.11, Jars= 13.94 hours. Crew change. No losses for tour. 08/27/2015 Continue to drill ahead from 2220'to 2813'TD. Circulate hole clean, BROOH to HWDP and POOH, LD BHA. RU casing handling equipment and PJSM for Casing run. 00:00 01:00 1.00 2,220 2,292 SURFA( DRILL DDRL P Drill 13 1/2" hole from 2220'to 2292' at 650 GPM with 1400 psi, 47% FO, 70 RPM with 4K torque, and 9K WOB, PU= 116K, SO= 105K, Rot= 106K. 01:00 01:30 0.50 2,292 2,292 SURFA( DRILL SRVY P Obtain surveys at 2141'and 2113'for DLS delineation. 650 GPM with1312 psi. 01:30 05:00 3.50 2,292 2,535 SURFA( DRILL DDRL P Drill 13 1/2"hole from 2292'to 2535' at 650 GPM with 1400 psi,47% FO, 70 RPM with 4K torque, and 9K WOB. PU= 116K, S0= 105K, Rot= 106K. 05:00 05:30 0.50 2,535 2,535 SURFA( DRILL SRVY P Obtain surveys at 2141'and 2113'for DLS delineation. 650 GPM with1312 psi. 05:30 09:00 3.50 2,535 2,813 SURFA( DRILL DDRL P Drill 13 1/2" hole from 2535'to 2813' at 650 GPM with 1400 psi,47% FO, 70 RPM with 4K torque, and 9K WOB. PU= 116K, SO= 105K, Rot= 106K. 09:00 11:00 2.00 2,813 2,535 SURFA( CASING CIRC P Rotate and recip from 2813'to 2574', stand back one each BU, pumping 550 GPM with 1365 psi, 46% FO,70 RPM with 4K. PU= 140K, SO= 115K, Rot= 125K. Pumped 1330 BBL total. 11:00 11:15 0.25 2,535 2,535 SURFA( CASING SFTY P PJSM for BROOH, monitor well for flow; Static. 11:15 12:00 0.75 2,535 2,201 SURFA( CASING BKRM P BROOH from 2535'to 2201',650 GPM with 1490 psi, 41% FO, 70 RPM with 6-8K torque. PU= 116K, SO= 105K, Rot= 111K. No losses this tour. 12:00 17:00 5.00 2,201 781 SURFA( CASING BKRM P BROOH from 2201'to 781', 600 GPM with 1100 psi, 44% FO, 70 RPM with 3K torque. PU= 116K, S0= 105K, Rot= 111K. Reaming returns increased to load shakers. Slowed pulling speed and reamed out 1st stand of HW. 17:00 17:12 0.20 781 781 SURFA( CASING OWFF P Observe well for flow for 10 minutes; Static. 17:12 19:00 1.80 781 125 SURFA( CASING TRIP P POOH from 781'to 125'; BHA. 19:00 21:15 2.25 125 0 SURFA( CASING BHAH P LD BHA#2 per DD and MWD. Page 4 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:15 22:00 0.75 0 0 SURFA( CASING BHAH P Clean and clear floor of BHA components. Remove master bushings and install PS-21 slip system. 22:00 00:00 2.00 0 0 SURFA( CASING RURD P PU Volant tools and RU. Install bale extensions. RU to run casing. 38/28/2015 Run casing per detail and schedule to 2813'. C&C mud for cement and perform cement job with returns to surface. Floats held. RD casing handling equipment, clean and clear rigfloor and ND diverter. 00:00 00:15 0.25 0 0 SURFA( CASING SFTY P PJSM for Running 10 3/4" L-80 Hyd 563 Dopeless casing with Doyon casing, rig crew and WSL. 00:15 06:00 5.75 0 1,485 SURFA( CASING PUTB P PU shoe track and BakerLok connections to the pin on the 4th joint. Check float; Good. RIH with casing filling on-the-fly and topping off every 10 joints.Torque connections to 21,400 ft-Ib, RIH to 1485'. 06:00 07:00 1.00 1,485 2,015 SURFA( CASING PUTB P Continue to RIH with 10 3/4"casing with Volant tool, filling on-the-fly and topping off every 10 joints. Torque connections to 22,400,to 1485'to 2015'. 07:00 08:45 1.75 2,015 2,015 SURFA( CASING CIRC P Circulate staging pumps from 3 BPM with 175 psi,4 BPM with 140 psi, 5 BPM with 145 psi,6 BPM with 165 psi, 7 BPM with 190 psi. Stage to 8 BPM with 218 psi. Total pumped 427 BBL. 08:45 11:00 2.25 2,015 2,760 SURFA( CASING PUTB P Continue to RIH with 10 3/4"casing filling on-the-fly and topping off every 10 joints.Torque connections to 22,400, to 2760'. 11:00 12:00 1.00 2,760 2,760 SURFA( CASING HOSO P PU and MU hanger and landing joint to string and engage Volant. 12:00 12:30 0.50 2,760 2,760 SURFA( CEMEN-RURD P Blow down top drive. PJSM for RU of cement hose, RU cement hose. 12:30 14:00 1.50 2,760 2,760 SURFA( CEMEN-CIRC P Reciprocate from 2805'to 2775'and establish circulation with cement hose with 3 BPM with 175 psi, 17% FO. 3.5 BPM with 145 psi, 17% FO, 4 BPM with 200 psi,24% FO. 5 BPM with 240 psi, 33% FO. 6 BPM with 280 psi, 34% FO. 7 BPM with 335 psi, 22%FO. 8 BPM with 400 psi 22% FO. PU= 153K. 14:00 14:45 0.75 2,760 2,813 SURFA( CEMEN-CIRC P While circulating, hold PJSM for Cement job with SLB, truck pusher, rig crew, mud engineer and WSL. 8 BPM with 400 psi,23% FO. Blow down cement line to SLB. Total pumped 855 BBL. Mud properties before/after circ: Weight 9.6/9.8 ppg, FVis 66/44, PV 11/20 cP,YP 64/16 Ib/100ft2. Page 5of31 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:45 18:30 3.75 2,813 0 SURFA( CEMEN-CMNT P With SLB pump 5 BBL of CW100 and test lines to 3500 psi for 6 minutes. Pump 75.4 BBL total of CW100. Batch and pump 76.6 BBL of 10.5 ppg MudPush II with 2 gallons of red dye. Pump 483.4 BBL of 11 ppg cement Lead(256%of gauge hole above the permafrost, 1451 sacks, 1.87 yield, 6.491 gal/sk),with 65.4 BBLs of 12.0 ppg Tail(227 sacks, 16.2 yield, 5.461 gal/sk). The plug bumped on 2510 strokes 364 psi and held 965 psi for and the float held. 16 BBLs of 11.0 ppg cement back to surface with cement in place at 18:06, 8/28. There was a loss of 35 BBLS throughout the cement job. 18:30 20:00 1.50 0 0 SURFA( CEMEN RURD P RD Volant and casing handling equipment. Blow down all lines and blow cement lines back to SLB. Drain stack and pull landing joint. Flush stack with black water pill and function annular, remove PS-21 and clean and clear equipment and all lines of cement. 20:00 00:00 4.00 0 0 SURFA( CEMEN NUND P ND diverter and flow line, Joe's box and mud lines. 08/29/2015 Continue to ND diverter. Measure TOC and decision made to perform top job due to depth of TOC.At 24.1 BBL pumped 11.0 ppg cement was returnedto surface, pumped 35.2 BBLs total. Cement Top Job witnessed by AOGCC Bob Noble. CIP 17:05 8/29 Begin NU of BOPE. 00:00 01:00 1.00 0 0 SURFA( CEMEN-NUND P ND diverter, install seal sub and hold down flange as per Vetco wellhead rep. Jake. 01:00 02:00 1.00 0 0 SURFA( CEMEN'RURD T After nippling down the diverter, checked the TOC and found that it had fallen to 68'below the landing ring. RU for top job. Dress top drive for 4" DP. Change bales,work 7 5/8"casing. Make notifications for top job on surface. 02:00 04:00 2.00 0 0 SURFA( CEMEN-WAIT T Waiting on authorization to proceed with cement top job from SOA AOGCC. Perform housekeeping, change out liners, valves, seats and swabs on#2 pump. Inventory Top Job kit equipment. 04:00 06:00 2.00 0 0 SURFA( CEMEN RURD P PJSM, Install PS-21 slip system, remove long bales, change out saver sub and install short bales. SIMOPs; clean pits. load and tally 7 5/8"casing in shed. Page 6of31 Time Logs • Date From To Dur S. Depth E. DepthPhase Code Subcode T Comment 06:00 11:00 I 5.00 0 0 SURFA( CEMEN-WAIT T Wait on cementers to arrive with cement. SIMOPs; continue to change out liners, valves,seats and swabs on#2 pump. Install 4"risers on the conductor. Perform PM on top drive, stage annulus valves in the cellar. Stage top job equipment for cement. 11:00 11:30 0.50 0 SURFA( CEMEN-SFTY T PJSM for top job cementing with crew on running 3/4"pipe into the 20"x 10-3/4"annulus through Vetco gray hanger flutes. 11:30 12:00 0.50 0 0 SURFA( CEMEN PULD T PU 3/4"top job pipe and run in the 20"x 10 3/4"annulus to refusal at 77'below the landing ring. Clean out cellar with SS truck. Crew change. 12:00 15:30 3.50 0 0 SURFA( CEMEN-PULD T Continue to MU 3/4"pipe and run in annulus on DS to 76.82'and run second string on ODS to 77.08'. Rig up manifold and fittings to pipe strings. Check the pipe with pumping water and clean annulus by pumping 38 BBL. Rig up to Dowell cementers. 15:30 15:45 0.25 0 SURFA( CEMEN-SFTY T PJSM on pumping top job through(2) 3/4"lines run into the 20"x 10-3/4" annulus to 77' below the starting ring. 15:45 17:15 1.50 0 0 SURFA( CEMEN-CMNT T SLB pressure test lines with 2 BBL water to 700 psi; Good. Pump 20 BBL water at 1.3 BPM with 100-200 psi. Shut down. Batch11.0 ppg LiteCrete cement(1.88 cuft/sk, Mix water 6.543 gal/sk,thickening time 4 hr 15 min)( .2%BWOB D046 antifoam, .07 gal/sk Dispersant, .05 gal/sk D186 Accelarator) and pumped 35.2 BBL(105.1 sk). ICP= 300 psi @ 1.7 BPM, FCP= 125 @ 1 BPM. At 24.1 BBL pumped 11.0 ppg cement was returned to surface. Pumped 35.2 BBLs total. Cement Top Job witnessed by AOGCC rep Bob Noble. CIP 17:05 8/29/15 17:15 18:30 1.25 0 0 SURFA( CEMEN-PULD T RD and pull 3/4"pipe, flush and clean pipe and rigging. LD 3/4"pipe. 18:30 21:30 3.00 0 0 SURFA( CEMEN WAIT T Monitor and strap TOC on 15 minute intervals. Clean out cellar box of cement. Remove 4"riser from conductor. Prep for NU of BOPE. Last measure of TOC 3'below landing ring. Page 7 of 31 Time Logs 410 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 0 0 SURFA( WHDBO NUND P Install sub seal and hold down flange. NU wellhead. NU 2'spool and 14' riser. NU BOPE. Test seals on wellhead to 2000 psi for 10 minutes good. Witnessed by CPAI rep P. Smith Crew change. 08/30/2015 Continue to NU BOPE and test to 3500 psi. Witness waived by AOGCC Johnnie Hill. LD 5" DP, MU BHA#4 and RIH. Perform 30 minute casing test to 3000 psi; Good. 00:00 03:30 3.50 0 0 SURFA( WHDBO NUND P Complete testing pack-off; Good. NU BOPE 5M 13 5/8"; NU riser and install choke lines and kill lines, install 2 1/16"OA and IA valves. Shim BOP carrier to align riser to low P riser. 03:30 05:00 1.50 0 0 SURFA( WHDBO RURD P RU for testing, fill BOPs and lines with water. PU and MU Vetco Gray lower test plug and 4"test joint. Perform body P test; Good. 05:00 11:15 6.25 0 0 SURFA( WHDBO BOPE P Test BOPE;Witness of test waived by AOGCC inspector Johnnie Hill. Pressure test BOPE to 250/3,500 psi for 5 minutes to chart recorder. With 4"test joints test annular, upper 2-7/8" lower casing rams,with 7 5/8"test joint tested 7 5/8" UPR. Manual operated and super choke tested to 250/2,000 psi for 5 minutes to chart recorder. Test choke valves 1-15, manual&auto choke, choke& kill manuals, HCR valves,4"valve on kill line, 5"TIW, 5"dart valve, and Upper&lower IBOP.5"and 9-5/8" test joints were used. Perform Koomey drawdown test. Accumulator PSI=2950 psi, Manifold=1,500 psi, System pressure1625 psi after all functions on bottles. 200 psi attained=22 sec with 2 electric pumps, full system pressure attained= 103 sec with 2 electric and 2 air pumps.6 bottle N2 average=1966 psi. Closing times for annular=23 sec, UPR= 18 sec, BSR= 15 sec, LPR= 15 sec, Choke _ HCR=2 sec, Kill HCR=2 sec. 11:15 12:00 0.75 0 0 SURFA( WHDBO RURD P RD test equipment, blow down lines, choke and kill, pull test plug and LD test joint. 12:00 12:30 0.50 0 0 SURFA( CEMEN-RURD P Install wear bushing 12.5" ID, 13.5" OD, 12:30 13:15 0.75 0 0 SURFA( CEMEN RURD P Remove PS-21 and install strip-o-matic and install PS-21 with 5"inserts. 13:15 14:15 1.00 0 2,085 SURFA( CEMEN TRIP P TIH with 5"DP from derrick to 2085'. 14:15 17:00 2.75 2,085 0 SURFA( CEMEN PULD P LD 5" DP doubles and store in tubs. Page 8 of 31 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 17:30 0.50 0 0 SURFA( CEMEN-BHAH P Clean and clear floor. Stage BHA to floor and in pipe shed. 17:30 18:45 1.25 0 182 SURFA( CEMEN-BHAH P PJSM, PU and MU BHA#4 per SLB DD and MWD to 182'. 18:45 19:45 1.00 182 737 SURFA( CEMEN PULD P PU HWDP and RIH with singles to 737' 19:45 20:45 1.00 737 1,693 SURFA( CEMEN-TRIPP Trip in with 4" DP from 737 to 1693' 20:45 21:15 0.50 1,693 1,693 SURFA( CEMEN SVRG P Service top drive and blocks. 21:15 21:30 0.25 1,693 1,693 SURFA( CEMEN DHEQ P Shallow pulse test MWD; Good. 530 GPM with 1435 psi, 29% FO. 21:30 22:00 0.50 1,693 2,642 SURFA( CEMEN TRIP P Trip in hole from 1693'to 2642' 22:00 22:30 0.50 2,642 2,717 SURFA( CEMEN-COCF P Wash down at 3 BPM 130 psi, 7% FO. Tag cement 2708'with 5K down weight. Circulate @ 520 GPM with 1740 psi, 28%FO,20 RPM with 4K torque. PU= 103K, SQ=86K, Rot= 94K. 22:30 22:45 0.25 2,717 2,717 SURFA( CEMEN-SFTY P Rig crew hold Table Top Stripping Drill. 22:45 00:00 1.25 2,717 2,717 SURFA( CEMEN-PRTS P Pressure test casing to 3000 psi for 30 minutes to chart against inner OA valve and outer IA valve; Good. 3.6 BBL to pressure up and 3.5 BBL bled back. RD testing equipment. Crew change. Measure TOC at 5'below landing ring. 08/31/2015 Drilling out shoe track and shoe at 2809, drill 20'new hole, perform FIT to 13.9 EMW. Drill 9.875" intermediate hole section to 4159'. 00:00 00:30 0.50 2,717 2,717 SURFA( CEMEN CIRC P Obtain parameters; 550 GPM with 1850 psi, 30% FO, 50 RPM with 4K torque. PU=90K, SO=92K, Rot= 92K. SPR @ 2642' MD 2536'TVD. MW= 9.5 ppg Time=0030 #1 MP-20/30 SPM with 80/120 psi #2 MP-20/30 SPM with 80/120 psi 00:30 05:30 5.00 2,717 2,813 SURFA( CEMEN-DRLG P Drill cement and shoe track from 2717'to shoe at 2808'and continue drilling to 2809'. Drill rat hole to 2813' with 600 GPM with 2047 psi, 31% FO, 3K WOB and 40 RPM with 4K torque. Measure TOC at 5'below landing ring; Static and Set. 05:30 06:00 0.50 2,813 2,833 SURFA( CEMEN DDRL P Drill 20'of new hole from 2813 to 2833'at 550 GPM with 1750 psi, 29%FO, 8 WOB and 70 RPM with 5K torque. 06:00 06:45 0.75 2,833 2,833 SURFA( CEMEN CIRC P Circulate, rotate and recip from 2832' to 2737'. CBU at 600 GPM with 2060 psi, 31% FO,40 RPM with 4K torque. Page 9of31 Time Logs 4111)' 4111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 08:30 1.75 2,833 2,733 SURFA( CEMEN-DISP P Displace surface Drill-plex mud with LSND 9.3 ppg mud at 650 GPM with 2120 psi, 32% FO. Rotate 40 RPM with 4K torque. Monitor well for 10 minutes; Static. Pull bit to 2733'for FIT test. 08:30 09:30 1.00 2,733 2,733 SURFA( CEMEN-FIT P PJSM, RU for test. Perform FIT 2X; 1st test unsatisfactory, retest good. 2nd Test; Fill lines, close annular, pump down kill line and drill string with 4 SPM. Pump 9 strokes to 638 psi, drop to 492 psi in 10 minutes. Bleed back 0.9 BBL. FIT= 13.9 EMW. Note: Performed second test to confirm if a isolation valve was contributing to a fall off of pressure during the 10 minute monitoring. Both tests had the same fall off. First test FIT to 13.7 ppg, second to 13.9 ppg. 09:30 10:00 0.50 2,733 2,833 INTRMI DRILL SVRG P Service rig; Top drive and blocks, grease wash pipe. Inspect top drive and traveling blocks. Change out Top drive guide shoe retaining bolt. RD form testing. 10:00 12:00 2.00 2,833 2,930 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 2833'to 2930'at 600 GPM with 1310 psi, 36% FO, 60 RPM with 3K torque and 2K WOB. PU= 106K, SO=87K, Rot=94K. ADT=0.73, TTL bit hours=0.73, Jars=29.61 hours. Crew change. No losses this tour 12:00 16:00 4.00 2,930 3,304 INTRM1 DRILL DDRL P Drill 9 7/8"hole from 2930'to 3304'at 600 GPM with 1310 psi, 36% FO, 60 RPM with 3K torque and 2K WOB. PU= 106K, SO=87K, Rot=94K. 16:00 16:30 0.50 3,304 3,304 INTRM1 DRILL SVRG P Service rig; top drive and blocks. 16:30 17:00 0.50 3,304 3,304 INTRM1 DRILL RGRP T Notice pressure drop of—500 psi while drilling. Trouble-shoot pressure loss with#2 pump. Pull caps, inspect valves and seats, inspect suction and discharge valves. Nothing abnormal found. Circ 8 BPM with 590 psi with pump #1 while working. 17:00 23:30 6.50 3,304 4,159 INTRMI DRILL DDRL P Drill 9 7/8"hole from 3304'to 4159'at 600 GPM with 2500 psi, 35% FO, 120 RPM with 6K torque and 3K WOB. PU= 123K, SO=93K, Rot= 104K. Page 10 of 31 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:30 00:00 0.50 4,159 4,159 INTRM1 DRILL RGRP T Trouble-shoot pressure loss with#2 pump. Pull caps, inspect valves and seats, inspect suction and discharge valves. Suspect something under valves, but nothing found in pump. Circ 8 BPM with 690 psi with pump #1 while working. 09/01/2015 Directional drill 9-7/8"section to TD 4945' MD 3850'TVD. Circulate and BROOH to shoe, Circulate clean and POOH, L/D BHA. R/U to run 7-5/8"casing. 00:00 01:00 1.00 4,159 4,211 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate section from 4159' MD to 4211'MD, 3710'TVD, 675 gpm, 1670 psi, 31% flow out, 120 rpm,TQ on/off=5k/4k, WOB=9k, ECD=9.6 ppg EMW, P/U=123k, S/O=94k, ROT=105k. 01:00 01:30 0.50 4,211 4,211 INTRM1 DRILL SVRG P Service top drive and traveling blocks. SPR's @ 4091' MD, 3655'TVD, 9.2 ppg, 01:30 hrs. #1-20 spm=180 psi, 30 spm=200 psi #2-20 spm=160 psi, 30 spm=200 psi 01:30 01:45 0.25 4,211 4,211 INTRM1 DRILL RGRP T Trouble-shoot pressure loss with#2 pump. Pull caps, inspect valves and seats, inspect suction and discharge valves. Found piece of ceramic debris in#3 discharge valve. Circulate 327 gpm with pump#1 while R&R from 4161' MD to 4076' MD, 660 psi, 20%flow out,40 rpm, TQ=4-5k. P/U=123k, S/O=94k, ROT=105k. 01:45 06:00 4.25 4,211 4,472 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate section from 4211'MD to 4537'MD, 3779'TVD,675 gpm,2260 psi, 34% flow out, 120 rpm,TQ on/off=8k/6k, WOB=9k, ECD=9.91 ppg EMW, P/U=119k, S/O=94k, ROT=101k. 06:00 11:00 5.00 4,472 4,945 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate section from 4537' MD to 4945' MD, 3850'TVD(Section TD)685 gpm, 2385 psi, 34%flow out, 110 rpm,TQ on/off=8k/6k,WOB=9k, ECD=9.99 ppg EMW, P/U=116k, 5/0=90k, ROT=102k. ADT=4.59, Total bit hrs= 12.7, Total jar hrs=40.85. SPR's @ 4721' MD, 3813'TVD, 9.25 ppg, 08:00 hrs. #1-20 spm=180 psi, 30 spm=260 psi #2-20 spm=180 psi, 30 spm=200 psi Page 11 of 31 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 11:00 12:00 1.00 4,945 4,945 INTRMI CASING CIRC P Circulate while rotate and reciprocate from 4945' MD to 4855' MD @ 671 gpm, 2385 psi, 33%flow out, 120 rpm, 4.5k TQ, P/U= 116k, S/0=102k, ROT= 102k. Total strokes pumped 6286-2 bottoms up. SPR's @ 4940'MD, 3848'TVD, 9.25 ppg, 11:15 hrs. #1-20 spm=180 psi, 30 spm=240 psi #2-20 spm=180 psi, 30 spm=240 psi 12:00 12:15 0.25 4,945 4,945 INTRM1 CASING CIRC P Continue to circulate while rotate and reciprocate from 4945' MD to 4855' MD @ 671 gpm, 2385 psi, 33%flow out, 120 rpm, 5k TQ, P/U= 116k, 5/0=102k, ROT= 102k.Total cummulative strokes pumped 10900, 3 bottoms up. Mud weight 9.3 ppg. 12:15 12:30 0.25 4,945 4,945 INTRM1 CASING OWFF P Monitor well for flow 10 minutes- static 12:30 16:45 4.25 4,945 2,798 INTRMI CASING BKRM P Backream out of hole from 4945' MD to 2798' MD @ 675 gpm, 2010 psi, 36%flow out, 120 rpm,4k TQ, 9.89 ppg ECD, P/U=97k, 5/0=85k. 16:45 17:45 1.00 2,798 2,798 INTRM1 CASING CIRC P Circulate casing clean @ 2798' MD to 2710' MD @ 675 gpm, 1900 psi, 33%flow out, 120 rpm, 3k TQ, ECD=9.56 ppg EMW, mud weight in 9.2 ppg, out=9.3 ppg. Total strokes pumped 10357, 5 bottoms up in casing. Monitor well 5 minutes- static. 17:45 20:00 2.25 2,798 550 INTRMI CASING TRIP P Trip out of hole on elevators from 2798' MD to 550'MD, monitoring displacement via trip tank. 20:00 22:00 2.00 550 0 INTRM1 CASING BHAH P Lay down BHA per SLB DD/MWD from 550'MD. Calculated disp for trip=35.1 bbl,Actual disp=38.9 bbl. 22:00 22:30 0.50 0 0 INTRM1 CASING BHAH P Clean and clear rig floor 22:30 22:45 0.25 0 0 INTRM1 CASING RURD P Pull wear bushing per GE/Vetco rep. 22:45 00:00 1.25 0 0 INTRM1 CASING RURD P Rig up to run 7-5/8"casing. Change to 180"bails and install 40"bail extensions, R/U double stack tongs and M/U Volant CRT with cement swivel. 09/02/2015 Run and cement 7-5/8"L-80 Hydril 563 dopeless casing. Perform LOT and annular flush on annulus. Begin P/U 4"drill pipe for production section. 00:00 01:00 1.00 0 0 INTRM1 CASING RURD P Continue rigging up to run 7-5/8" casing. C/O PS-21 inserts, PJSM on running casing. Page 12 of 31 Time Logs . • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 06:00 5.00 0 2,775 INTRM1 CASING PUTB P Pick up 7-5/8"29.7#L-80 Hydril 563 Silver bullet shoe,shoe track, Float collar, Baker lock first four joints. Fill pipe and check floats-good. Establish circulation through shoe track-good. Continue picking up 7-5/8"29.7#L-80 Hydril 563 Dopeless casing with centralizers and stop rings pre-installed on first 50 jts from 174'to 2775'MD, making up with power tongs, filling each joint with fill up hose,topping off every ten joints with Volant CRT. P/U=99k, 5/0=105k. 06:00 07:00 1.00 2,775 2,775 INTRM1 CASING CIRC P Establish circulation and circulate bottoms up with Volant CRT, stage pumps up from 2 bpm 100 psi, 11% flow out, 4 bpm 140 psi 13%flow out, 5 bpm 168 psi 15%flow out, 6 bpm 250 psi 17%flow out. Mud weight 9.3 ppg in/out, pumped 1438 strokes total. Reciprocate pipe while pumping. 07:00 11:00 4.00 2,775 4,934 INTRM1 CASING PUTB P Continue picking up 7-5/8"29.7# L-80 Hydril 563 Dopeless casing with Volant CRT and double stack casing tongs,torquing to 14,400 ft/lbs to the mark. Flilling each joint on the fly with fill up hose and topping off every ten joints with Volant. RIH from 2775' MD to 4853' MD, M/U fluted hanger and landing joint,wash down to 4934' MD @ 3 bpm, 210 psi, 15%flow out. P/U=162k, 5/0=130k, Blocks=40k. 11:00 11:30 0.50 4,934 4,934 INTRM1 CEMEN-RURD P PJSM, blow down top drive, R/U to pump through cement lines. R/D 200 ton elevators and 4'bail extensions. 11:30 12:00 0.50 4,934 4,934 INTRM1 CEMEN-CIRC P Establish circulation 2 bpm, stage up to 4 bpm, 245 psi, 13%flow out. P/U=162k, S/O= 130k, Blocks=40k. Circulate 675 strokes thru cement line. 12:00 15:30 3.50 4,934 4,934 INTRM1 CEMEN-CIRC P Continue circulation while recirocating pipe from 4931' MD to 4918'MD, staging rate up to 7 bpm. 4 bpm=245 psi, 12%flow out, 5 bpm=300 psi, 15%flow out, 6 bpm=360 psi, 16%flow out, 7 bpm=410 psi ICP,405 FCP 18%flow out. Land casing on hanger every 5 strokes. Mud weight in 9.35 ppg, out 9.4 ppg.Total strokes pumped 14151, P/U=164k, 5/O=113k. Page 13 of 31 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T - Comment 15:30 17:15 1.75 4,934 4,934 INTRM1 CEMEN'CMNT P R/U SLB and pressure test lines with water to 3500 psi for 10 minutes charted. Pumped 40.3 bbl 11.5 ppg MudPush II spacer. Drop bottom plug, pump 46 bbl 15.8 ppg Tail D177 retarded cement @ 5.3-6.4 bpm, follow with 51.5 bbl 15.8 ppg non-retarded Tail slurry @ 5-6.4 bpm. 17:15 18:00 0.75 4,934 4,934 INTRM1 CEMEN-CMNT P Drop top plug and kick out with 10.3 bbl water from SLB unit. Displace with rig pumps @ 6 bpm, 114 psi ICP, 1035 psi FCP 13%flow out. Reduce rate to 3 bpm @ 202 bbl away,850 psi 10%flow out. Plug on seat @ 2112 stks, pressure up to 1400 psi and hold for 5 min.Bleed off pressure and check floats-good. Bled off 1.2 bbl to trip tank. Losses for cement job=0 bbl. 18:00 18:45 0.75 4,934 0 INTRM1 CEMEN-RURD P Rig down Volant CRT and cement swivel, pull landing joint and LID same. Blow down lines. 18:45 20:15 1.50 0 0 INTRM1 CEMEN-WWSP P Set 7-5/8"packoff and test to 5000 psi for 10 minutes. CPAI DSL witnessed test. SIMOPS-Change out bails to 132" set. 20:15 21:15 1.00 0 0 INTRM1 CEMEN BOPE P Set test plug and flood lines with water, R/U and test annular preventer and 2-7/8"x5-1/2" LPR's with 4'/2' test jont.Tested each to 250/3500 psi charted 5 minutes each. Blow down test lines. 21:15 21:45 0.50 0 0 INTRM1 CEMEN BOPE P Pull test plug and set wear bushing per GE-Vetco rep.Wear ring ID= 12.25", OD= 13.375", length=3.17' 21:45 23:00 1.25 0 0 INTRM1 CEMEN LOT P R/U and perform annular LOT of 10-3/4"x7-5/8"annulus. Pressure up @.5 bpm to 550 psi. Call engineer to notify. Re-attempt test to 650 psi, pressure still cimbing. Notify enginner, continue pumping up to 1220 psi and observe breakover, pressure dropped to 650 psi,then again climbed to 910 psi, breaking over again to 620 psi.Total strokes pumped testing 90 strokes. Final SIP=710 psi, SIP after 10 minutes 560 psi. 23:00 00:00 1.00 0 569 INTRM1 CEMEN-FRZP P Perform annular flush on OA with 120 bbl water, total 1244 strokes @ 2 bpm, ICP=1200 psi, FCP=1100 psi. SIMOPS-P/U 4"drill pipe to 569' MD, monitor displacement via trip tank. Page 14of31 Time Logs • i Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/03/2015 24 hr Summary Continue picking up 4"DP and HWDP for production section. Pump freeze protection Isotherm. P/U BHA and single in on 4" DP. Cleanout to FC, perform casing test. Begin drilling out float equipment. 00:00 03:45 3.75 569 3,751 INTRM1 CEMEN-PULD P P/U 75 jts 4" DP and 45 jts 4" HWDP from 569'MD to 3751'MD. P/U=111k, S/O=98k. SIMOPS-PJSM with Litte Red Svc, R/U LRS to annulus. PT lines to 2500 psi-good. Pump total 82 bbl Isotherm freeze protect, chased with 1 bbl diesel. Pumped @ 2 bpm 1087 psi, Initial SIP 540 psi, final SIP 550 psi. 03:45 06:00 2.25 3,751 0 INTRM1 CEMEN-TRIPP POOH from 3751' MD, racking back 4"HWDP and 4" DP. 06:00 07:30 1.50 0 0 INTRMI CEMEN-RURD P Clean and clear rig floor, pull PS-21 slips, install master bushing. 07:30 08:30 1.00 0 0 INTRM1 CEMEN-SVRG P PJSM with NOV Derrick inspector. Inspect derrick and sub structure. Service top drive and blocks. 08:30 11:30 3.00 0 402 INTRMI CEMEN-BHAH P PJSM, P/U 6.75" BHA to 402'MD per SLB DD/MWD reps. 11:30 12:00 0.50 402 877 INTRMI CEMEN"PULD P RIH, picking up 4"DP singles from 402' MD to 877' MD. P/U=57k, S/0=61k. Monitor displacement via trip tank. OA pressure 550 psi. 12:00 13:30 1.50 877 1,825 INTRMI CEMEN PULD P Continue RIH picking up 4" DP singles from 877'MD to 1825'MD. 13:30 13:45 0.25 1,825 1,825 INTRM1 CEMEN-DHEQ P Shallow hole test MWD @ 210 gpm, 880 psi, 14%flow out. Good test. 13:45 16:30 2.75 1,825 4,671 INTRMI CEMEN-PULD P Continue RIH picking up 4" DP singles from 1845'MD to 4671'MD, monitor displacement via trip tank. 16:30 18:00 1.50 4,671 4,671 INTRMI CEMEN SLPC P Cut 62.8'of 6x19 extra IMP plow steel drill line, slip on same. 18:00 18:30 0.50 4,671 4,671 INTRMI CEMEN-SVRG P Service top drive, blocks and crown. C/O washpipe. 18:30 18:45 0.25 4,671 4,671 INTRM1 CEMEN SLPC P Calibrate Ampion, SLB and Totco block height. (Part of slip/cut) 18:45 20:00 1.25 4,671 4,671 INTRM1 CEMEN CIRC P CBU while rotate and reciprocate from 4671'MD to 4576'MD treating cement contaminated mud, 180 gpm, 930 psi, 13%flow out,20 rpm, 5k Tq. P/U=117k, S/O=80k. 20:00 20:45 0.75 4,671 4,843 INTRM1 CEMEN-COCF P Wash/ream down from 4671' MD to 4843'MD @ 150 gpm, 760 psi, 17% flow out,40 rpm, 5k Tq. Tag firm cement at 4795' MD,drill cement strngers with 9k WOB. Tag plugs @ 4843' MD. Confirm plugs with no rotary and set down 15k. Page 15 of 31 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 21:15 0.50 4,843 4,730 INTRMI CEMEN-RURD P Stand back one stand, R/U head pin and hose, R/U for casing test. Establish circulation through hose, pump string volume @ 200 gpm, 1200 psi, 18%flow out. 21:15 22:15 1.00 4,730 4,730 INTRM1 CEMEN-PRTS P Close annular, flood lines and perform casing test to 3500 psi for 30 minutes charted. R/D test equipment. 22:15 00:00 1.75 4,730 4,844 INTRMI CEMEN-DRLG P Drill out float equipment. Drill plugs to 4844' MD @ 170 gpm, 990 psi,40 rpm, 5.3k Tq. 09/04/2015 Drill out FC, shoe trac and shoe,20'formation to 4965'. Displace to 9.4 ppg FloPro,attempt to perform acceptable FIT to 13.0 ppg EMW. Observed unnacceptable build rate and potential communication with OA, observed losses during FIT tests. POOH, P/U 3'/z' EUE stinger, RIH to perform cement squeeze. 00:00 04:00 4.00 4,844 4,945 INTRM1 CEMEN DRLG P Continue drilling float equipment, drilling plugs at 4845'MD with 10-17k WOB,210 gpm, 1732 psi, 17%flow out,40-70 rpm, 5.5k Tq, Drill shoe track 6-9k WOB,tag float shoe at 4932' MD, drill out shoe and rathole to 4945'MD 240 gpm, 1384 psi, 15% flow out, 60 rpm, 5k Tq. 04:00 04:30 0.50 4,945 4,965 INTRM1 CEMEN-DDRL P Drill new formation from 4945' MD to 4965'MD, 3851'TVD, 229 gpm, 1358 psi, 15%flow out, 60 rpm, 5.5k Tq, 5k WOB. 04:30 06:00 1.50 4,965 4,965 INTRM1 CEMEN-DISP P PJSM,displace well to 9.4 ppg Flo Pro mud, pump 88 bbl Hi Vis spacer, 230 gpm, 1350 psi, 15%flow out.60 rpm, 5k Tq, chase with 9.4 ppg Flo Pro 230 gpm, 1530 psi-1681 psi FCP. Total strokes pumped 3302, 9.4 ppg in/out. SPR's 4965' MD, 3850'TVD, 9.4 ppg, 05:40 hrs #1-20 spm=340 psi, 30 spm=500 psi #2-20 spm=380 psi, 30 spm=580 psi 06:00 06:15 0.25 4,965 4,860 INTRM1 CEMEN-RURD P Rack back a stand to 4860'MD, monitor well 10 min. blow down top drive, R/U to perform FIT. Page 16 of 31 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:15 10:30 4.25 4,860 4,860 INTRM1 CEMEN-FIT T Attempt to perform FIT. Pump.5 bpm for 5 bbl, achieve 480 psi, bled off due suspected leaking valve. Re-try.5 bpm for 5.3 bbl to achieve 585 psi, bled to 325 psi 10 minutes, bled back 2.1 bbl.Test not building pressure at expected rate. Bleed pressure to 0, check surface lines, annular,test equipment for leaks. Re-attempt test @.7 bpm, pumped 6.6 bbl to achieve 720 psi, bled off to 450 in 10 minutes,volume bled back only 3.1 bbl. Observe OA pressure building and falling with IA pressure. Consult with engineer. OA pressure @ 09:00=300 psi. 10:30 12:00 1.50 4,860 4,860 INTRM1 CEMEN FIT T Re-attempt FIT, pumping @.7 bpm, pumped 7 bbl to achive 695 psi, pressure bled off to 528 psi, OA pressure tracking with IA.Volume bled back=3.1 bbl. 12.00 13:45 1.75 4,860 4,860 INTRM1 CEMEN-WAIT T Wait on orders after FIT, develope plan forward. Complete work orders, MP2's, clean and organize rig, sub structure inspection. Process 4'/z'slotted and blank liner in pipe shed. Drift 3'/2' Hydril 563 to 3.833"would not drift to 3.89"on box end. 13:45 14:00 0.25 4,860 4,860 INTRM1 CEMEN RURD T Downlink MWD/Periscope to neutral. Blow down top drive. 14:00 17:30 3.50 4,860 219 INTRM1 CEMEN TRIP T Trip out of hole on elevators from 4860' MD to 219'MD,standing back flex collars. Monitor displacement via trip tank. 17:30 18:30 1.00 219 0 INTRM1 CEMEN BHAH T Lay down BHA#4 as per DD/MWD. Calc Disp=30.2 bbl,Actual disp=32.3 bbl. 18:30 19:00 0.50 0 0 INTRM1 CEMEN-BHAH T Clean and clear rig floor. 19:00 20:00 1.00 0 0 INTRM1 CEMEN-RURD T R/U to run 3'/z'9.2#EUE 8rd tubing cement string. Mobilize and process tubing in pipeshed. 20:00 21:30 1.50 0 953 INTRM1 CEMEN-PULD T RIH to 953'MD picking up 3'/z' EUE-8rd tubing,torque connections to 2400 ft/lbs. Monitor displacement via TT. 21:30 22:00 0.50 953 953 INTRM1 CEMEN-RURD T Rig down tubing equipment, change handling equipment to 4" DP. 22:00 00:00 2.00 953 4,111 INTRM1 CEMEN-TRIPT Continue RIH,XO to XT39(.99), P/U single(31.51), RIH on stands 4"DP to 4111'MD. 39/05/2015 RIH, displace hole to Powervis mud system, R/U and perform cement squeeze. CBU x 2, POOH and L/D 3'/2" stinger. Begin testing BOPE, notified AOGCC John Crisp waived witness. 00:00 00:30 0.50 4,111 4,873 INTRM1 CEMEN-TRIPT Continue to RIH with 953'cement stinger on 4"drill pipe from 411' MD to 4873' MD, P/U=108k, S/O=81k. Page 17 of 31 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:30 01:00 0.50 4,873 4,965 INTRM1 CEMEN-WASH T Wash down from 4873'MD to 4965' MD @ 2 bpm,220 psi. Tag bottom @ 4965' MD 01:00 02:30 1.50 4,965 4,965 INTRM1 CEMEN'CIRC T Stage pumps up to 5 bpm and CBU, 210 gpm, 300 psi, P/U=109k, S/O=83k, 14%flow out. 02:30 03:30 1.00 4,965 4,965 INTRM1 CEMEN-DISP T Displace well from 9.4 ppg Flo Pro to 9.4 ppg Powervis WBM, 210 gpm, 300 psi, P/U=109k, S/O=83k 14% flow out, reciprocate while displacing 4964' MD to 4930' MD 03:30 04:00 0.50 4,965 4,965 INTRM1 CEMEN-RURD T Blow down top drive, R/U headpin swing,T, valve and cement hose. 04:00 09:00 5.00 4,935 4,935 INTRM1 CEMEN WAIT T Pick up string to shoe, circulate at 1.5 bpm while waiting on cementers. SIMOPS-Take on more Powervis mud into pits, service and clean rig, perform PM's. 09:00 09:30 0.50 4,935 4,960 INTRMI CEMEN-SFTY T PJSM on cement squeeze job, blow air to SLB truck. Batch up 11.5 ppg Mud Push and 15.8 ppg tail cement. 09:30 10:30 1.00 4,960 4,960 INTRMI CEMEN CMNT T SLB pumped 3 bbl 11.5 ppg MudPush, PT lines to 600 low/3000 psi hi. Pumped total 20.4 bbl of 11.5 ppg MudPush, insert wiper ball(6" wiper ball, had to cut down due wrong size), SLB pmped 25.4 bbl 15.8 ppg Tail Cement,followed with 5.7 bbl 11.5 ppg MudPush and 1.5 bbl of water to get MudPush to the floor. Blow down to cementers. 10:30 10:45 0.25 4,960 4,960 INTRM1 CEMEN-CMNT T Rig displaced cement with 35 bbl (347 stks)of 9.4 ppg Powervis WBM. Shut down.Verify fluid dropping in pipe, rig down pumping equipment. 10:45 11:45 1.00 4,960 4,206 INTRM1 CEMEN-TRIPT POOH on elevators 8 stands from 4960' MD to 4206' MD @ 20 fpm, P/U=105k, S/O=78k. Monitor displacement via trip tank. 11:45 12:00 0.25 4,206 4,206 INTRMI CEMEN'CIRC T Insert wiper ball in pipe(6"wiper ball, had to cut down due wrong size), establish circulation. 12:00 12:30 0.50 4,206 4,206 INTRM1 CEMEN CIRC T Continue CBU x 1.5 @ 6 bpm, 270 psi, 16%flow out,total strokes pumped 1956. OA pressure=350 psi Page 18of31 9 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 13:45 1.25 4,206 4,206 INTRM1 CEMEN-SQEZ T Open kill line and pump to remove air, Close annular and perform hesitation squeeze, 5 total pumping down DP and Kill line.Rig pumped to squeeze cement @.5 bpm. Squeeze#1-Pumped 4.23 bbl to achieve 687 psi, shut in hold 10 min, pressure bled off to 449 psi.(OA=700 psi) Squeeze#2-Pumped additional 1 bbl to bump up from 449 psi to 687 psi,shut in and hold ten minutes dropped to 582 psi.#3-Pumped .6 bbl (5.8 total)to bump up pressure from 582 to 687 psi. Shut in 10 minutes and pressure dropped to 494 psi. (OA=700)#4-Another.6 bbl(6.4 total)to bump up from 494 to 687 psi,shut in 16 min-dropped to 449 psi.#5-Increased prerssure to 730 psi, pumped .85 bbl(7.25 total) bump from 449 psi to 730 psi. Shut in and hold 10 minutes, bled off to 526 psi. Bled off annular pressure, bled back 1.2 bbl, total cement sqeezed away=6.05 bbl 13:45 14:45 1.00 4,206 4,206 INTRM1 CEMEN-CIRC T Circulate bottoms up x 1.52©6 bpm, 270 psi, 16%flow out, Total strokes pumped 1956. Rig down and blow down circ lines. 14:45 16:00 1.25 4,206 2,502 INTRM1 CEMEN-TRIP T Trip out of hole on elevators from 4206'MD to 2502' MD, monitor displacement via trip tank. 16:00 16:30 0.50 2,502 2,502 INTRMI CEMEN-SVRG T Service rig 16:30 17:00 0.50 2,502 2,502 INTRMI CEMEN-SVRG T Service brake on drawworks, install shims 17:00 18:00 1.00 2,502 2,502 INTRM1 CEMEN.CIRC T Circulate©2502'MD @ 8 bpm, 195 psi,20%flow out,total strokes pumped 3779. 18:00 18:45 0.75 2,502 953 INTRM1 CEMEN.TRIP T Continue trip out 4"DP on elevators from 2502'MD to 953' MD 18:45 19:45 1.00 953 953 INTRM1 CEMEN'RURD T Lay down single and XO to 3'/z' EUE, C/O PS-21 slip inserts for 31/2" tubing, R/U tubing handling equipment. 19:45 21:00 1.25 953 0 INTRM1 CEMEN PULD T Lay down 3'/2' EUE cement string from 953'MD to mule shoe. 21:00 21:45 0.75 0 0 INTRM1 CEMEN RURD T Rig down casing running equipment, clean and clear rig floor. 21:45 22:30 0.75 0 0 INTRM1 WHDBO RURD T Pull wear bushing, install test plug, rig up test equipment, flood lines with fresh water for BOP test. Obtained UCA for squeezed cement, 12 hr 43 min for 500 psi compressive strength. Page 19 of 31 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:30 00:00 1.50 0 0 INTRM1 WHDBO BOPE T Test BOPE to 250/3500 psi 5 min ea charted.AOGCC John Crisp waived witness of test. Manual operated and auto choke tested to 250/2000 psi 5 min ea charted.With 4"test joint,tested annular preventer, choke valves 7-15, manual and HCR choke,4"valve on kill line, 4"TIW#1,4"Dart. OA pressure=50 psi 09/06/2015 Complete BOPE testing with 4"and 4'/2'test jts. P/U BHA and RIH to—4100' MD,test top to 1000 psi, drill cement to 4965' MD, FIT 13.0. Drill 20 more feet, FIT to 13.0 ppg. Displace to 9.4 ppg FloPro and drill production section. 00:00 02:45 2.75 0 0 INTRM1 WHDBO BOPE T Continue testing all BOPE to 250 psi low, 3500 psi hi for 5 min each on chart. Witness waived by AOGCC John Crisp. Manual and super choke tested to 250/2000 psi for 5 min each. Tested with 4"test joint,test annular, choke valvesl-15, manual operated and super choke, manual and HCR kill valves, 4"valve on kill line,4"TIW#1,4" Dart valve, upper and lower IBOP, 2-7/8"x 5-1/2" LPR's.4%"test joint tested annular, HCR choke and kill, manual kill, lower 2-7/8"x 5-1/2"variable rams. Pull test joint,tested blind rams, valve 4,5. 02:45 03:15 0.50 0 0 INTRM1 WHDBO BOPE T Perform accumulator drawdown test, Accumulator pressure=3050 psi, Manifild=1500 psi, Pressure after functioning= 1650 psi, 200 psi attained= 18 sec with 2 electric pumps, full system recovery= 114 seconds with 2 electric and 2 air pumps. 03:15 04:30 1.25 0 0 INTRM1 WHDBO RURD T R/D testing equipment, pull test plug, suck out stack, set wear ring and RILDS. Blow down top drive, choke manifold and kill line. 04:30 06:00 1.50 0 402 INTRM1 CEMEN-BHAH T PJSM, P/U 6%"production BHA per MWD/DD to 402'MD. 06:00 06:45 0.75 402 1,824 INTRM1 CEMEN-TRIPT Continue RIH from 402 MD to 1824' MD, fill pipe and shallow pulse test MWD.-Good. 06:45 08:30 1.75 1,824 4,195 INTRM1 CEMEN-TRIPT Continue RIH from 1824'MD to 4195' MD, P/U=111k, S/O=83k. 08:30 09:00 0.50 4,195 4,383 INTRM1 CEMEN-WASH T Wash down @ 3 bpm 452 psi from 4195' MD to 4383' MD. P/U=112k, S/O=82k. 09:00 10:15 1.25 4,383 4,383 INTRM1 CEMEN-PRTS T R/U to pressure test casing. Charted and monitored IA and OA pressures. Pressure up to 700 psi, shut in for 5 min. Increase pressure to 1000 psi and held 10 minutes. Page 20 of 31 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T - Comment 10:15 11:30 1.25 4,383 4,567 INTRMI CEMEN-WASH T Continue to wash down @ 2 bpm from 4383'MD to TOC @ 4567' MD. String took 10k weight and 70 psi increase. P/U=115k, S/0=85k. 11:30 12:00 0.50 4,567 4,642 INTRMI CEMEN-DRLG T Drill up cement in casing from 4567' MD to 4642' MD, 250 gpm, 1290 psi, P/U=115k, S/O=85k, ROT=93k. OA pressure=40 psi 12:00 14:45 2.75 4,642 4,965 INTRM1 CEMEN-DRLG T Control drill cement from 4642'MD to 4965'MD @ 250 gpm, 1330 psi, 16%flow out, 60 rpm, 5k Tq, 6k WOB, P/U=119k, 5/0=84k. 14:45 15:45 1.00 4,965 4,965 INTRM1 CEMEN-CIRC T Circulate while R&R from 4963'MD to 4888' MD @ 250 gpm, 1300 psi, 15%flow out, 60 rpm,4.5k Tq, Mud weight in/out 9.5 ppg.Total strokes pumped 2833. 15:45 17:15 1.50 4,965 4,965 INTRM1 CEMEN FIT T R/U and flood lines for FIT. Perform FIT to 13.0 ppg EMW. 10 strokes to pressure up @.5 bpm, 1 bbl bled off. Rig down test equipment. 17:15 17:30 0.25 4,965 4,985 INTRM1 CEMEN-DDRL T Drill 6%"production hole from 4965' MD to 4985' MD @ 250 gpm, 1320 psi, 16%flow out, 60 rpm, 5k Tq, 6k WOB, P/U=119k, 5/O=84k, ROT=94k. 17:30 18:30 1.00 4,985 4,985 INTRM1 CEMEN-CIRC T Circulate while R&R from 4985'MD to 4945'MD @ 250 gpm, 1320 psi, 16%flow out, 60 rpm 4.5k Tq. Mud weight in/out 9.5 ppg.Total strokes pumped 3050. 18:30 19:45 1.25 4,985 4,985 INTRM1 CEMEN-FIT P R/U and flood lines for FIT. Perform FIT to 13.2 ppg EMW. Pumped 8 strokes to pressure up to 740 psi, bled back.6 bbl. Rig down test equipment. 19:45 00:00 4.25 4,985 5,220 PROD1 DRILL DDRL P Directional drill 6'/2'production section from 4985'MD to 5220'MD, 3849'TVD @ 260 gpm, 1505 psi, 19%flow out, 120 rpm,Tq on/off=5.5k/4.5k Tq, 2K WOB, ECD=10.36 ppg, P/U=120k, S/0=80k, ROT=95k,ADT=2.62, Total bit hrs=2.62,Total Jar Hrs=43.75. Displace to 9.4 ppg Flo Pro while drilling ahead from 4985' MD to 5036' MD. OA pressure=225 psi SPR's @ 5035'MD, 3851'TVD, 9.4 ppg,20:45 hrs #1-=20 spm=240 psi, 30 spm=380 psi #2-20 spm=260 psi, 30 spm=400 psi Page 21 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 39/07/2015 24 hr Summary Directional drill 6%"production section per program/Geologist from 5220' MD to 7894' MD, 3821'TVD.Avg 111 fph for the day, Max 225 fph instantaneous drilling rate. Optimize ROP using ECD and T&D trends. Drill 4 concretions,total 13. 00:00 02:30 2.50 5,220 5,472 PROD1 DRILL DDRL P Directional drill 6%"production hole from 5220'MD to 5472' MD, 3841' TVD, 260 gpm @ 1575 psi, 20%flow out, 120 rpm, Tq on/off=5.4k/4.5k,2k WOB, ECD=10.45 ppg EMW, P/U=118k, S/0=81k, ROT=97k. 02:30 03:00 0.50 5,472 5,472 PROD1 DRILL SVRG P Service top drive and blocks 03:00 03:30 0.50 5,472 5,472 PROD1 DRILL RGRP T Replace hydraulic hose on top drive pump due pinhole leak at fitting. 03:30 06:00 2.50 5,472 5,714 PROD1 DRILL DDRL P Directional drill 6%"production hole from 5472'MD to 5714'MD, 3836' TVD, 270 gpm © 1674 psi, 19%flow out, 130 rpm, Tq on/off=6.2k/5k, 2k WOB, ECD=10.65 ppg EMW, P/U=119k, S/O=80k, ROT=94k. 06:00 12:00 6.00 5,714 6,443 PROD1 DRILL DDRL P Directional drill 6%"production hole from 5714' MD to 6443'MD,3837' TVD, 270 gpm @ 1794 psi, 20%flow out, 130 rpm, Tq on/off=6.2k/6.1 k, 2k WOB, ECD=10.65 ppg EMW, P/U=122k, S/O=76k, ROT=97k. ADT=7.21,Total Bit Hrs=9.83, Total Jar Hrs=50.96 12:00 18:00 6.00 6,443 7,134 PROD1 DRILL DDRL P Directional drill 6%"production hole from 6443'MD to 7134' MD,3837' TVD, 270 gpm @ 1680 psi, 20%flow out, 130 rpm, Tq on/off=7k/7k, 2.5k WOB, ECD=10.66 ppg EMW, P/U=127k, S/O=72k, ROT=94k. ADT=4.26,Total Bit Hrs=14.09, Total Jar Hrs=55.22 18:00 00:00 6.00 7,134 7,888 PROD1 DRILL DDRL P Directional drill 6%"production hole from 7134'MD to 7894' MD, 3837' TVD, 270 gpm @ 1870 psi, 21%flow out, 130 rpm, Tq on/off=8k/7.5k,2k WOB, ECD=10.67 ppg EMW, P/U=128k, S/0=71k, ROT=93k. ADT=4.03,Total Bit Hrs=18.12, Total Jar Hrs=59.25 OA pressure=400 psi 09/08/2015 Directional drill 6%"production section per program/Geologist from 7894' MD to 10850' MD, 3821'TVD.Avg 123 fph for the day, Max 225 fph instantaneous drilling rate. Optimize ROP using ECD and T&D trends. Drill 7 concretions,total of 20. Page 22 of 31 Time Logs 11111 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 7,888 8,371 PROD1 DRILL DDRL P Directional drill 6%"production hole from 7894' MD to 8371' MD,3832' TVD, 270 gpm @ 1917 psi, 20%flow out, 130 rpm, Tq on/off=8.4k/8.3k, 1.6k WOB, ECD=10.72 ppg EMW, P/U=134k, S/0=63k, ROT=97k. ADT=4.02. SPR's @ 8459'MD, 3832'TVD, 9.4 ppg,06:14 hrs #1-20 spm=520 psi, 30 spm=760 psi #2-20 spm=460 psi, 30 spm=630 psi OA pressure=380 psi 06:00 12:00 6.00 8,371 9,131 PROD1 DRILL DDRL P Directional drill 6%"production hole from 8371' MD to 9131' MD, 3832' TVD, 270 gpm @ 2009 psi, 21%flow out, 130 rpm, Tq on/off=8.5k/8k, 2k WOB, ECD=11.2 ppg EMW, P/U=139k, S/O=63k, ROT=100k. ADT=4.03,Total Bit Hrs=26.17,Total Jar Hrs=67.3 SPR's @ 8937' MD, 3832'TVD, 9.4 ppg, 10:23 hrs #1-20 spm=470 psi, 30 spm=740 psi #2-20 spm=410 psi, 30 spm=580 psi 12:00 18:00 6.00 9,131 10,051 PROD1 DRILL DDRL P Directional drill 6%"production hole from 9131'MD to 10051' MD, 3841' TVD, 270 gpm @ 2200 psi, 22%flow out, 130 rpm, Tq on/off=9k/8.5k,2k WOB, ECD=11.39 ppg EMW, P/U=147k, 5/0=54k, ROT=98k. ADT=4.4, Total Bit Hrs=30.57,Total Jar Hrs=71.7 OA pressure=350 psi 18:00 00:00 6.00 10,051 10,850 PROD1 DRILL DDRL P Directional drill 6%"production hole from 10051' MD to 10850' MD, 3846' TVD, 270 gpm @ 2170 psi, 21%flow out, 130 rpm, Tq on/off=9.5k/9k, 3k WOB, ECD=11.34 ppg EMW, P/U=156k, S/0=40k, ROT=99k. ADT=3.86,Total Bit Hrs=34.43,Total Jar Hrs=75.56 SPR's 0 9982'MD, 3840'TVD, 9.4 ppg, 17:45 hrs #1-20 spm=620 psi, 30 spm=760 psi #2-20 spm=640 psi, 30 spm=780 psi 09/09/2015 Directional drill 6%"production section per program/Geologist from 10850' MD to TD of 12406' MD, 3871' TVD.Avg 118 fph for the interval, Max 225 fph instantaneous. Circulate and dilute mud per program, begin backream out of lateral @ 1500 fpm, full drilling rates. Page 23 of 31 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 10,850 11,442 PROD1 DRILL DDRL P Directional drill 63/4'production hole from 10850' MD to 11442' MD, 3851' TVD, 270 gpm @ 2372 psi, 19%flow out, 130 rpm, Tq on/off=10.7k/10.2k, 2.1k WOB, ECD=11.52 ppg EMW, P/U=164k, S/O=<40k, ROT=106k. SPR's @ 11116' MD, 3846'TVD, 9.4 ppg, 02:47 hrs #1-20 spm=520 psi, 30 spm=700 psi #2-20 spm=590 psi, 30 spm=840 psi OA pressure=300 psi 06:00 12:00 6.00 11,442 12,034 PROD1 DRILL DDRL P Directional drill 63/4'production hole from 11442' MD to 12034' MD, 3855' TVD, 270 gpm @ 2420 psi, 19%flow out, 130 rpm, Tq on/off=11.8k/11.2k, 2-3k WOB, ECD=11.41 ppg EMW, P/U=175k, S/O=<40k, ROM-111k. ADT=7.7, Total Bit Hrs=41.7, Total Jar Hrs=83.05 SPR's© 11759'MD, 3852'TVD, 9.4 ppg, 08:55 hrs #1-20 spm=600 psi, 30 spm=770 psi #2-20 spm=540 psi, 30 spm=730 psi 12:00 15:45 3,75 12,034 12,406 PROD1 DRILL DDRL P Directional drill 6%"production hole from 12034' MD to 12406' MD, 3871'• TVD, 270 gpm @ 2530 psi, 18%flow out, 130 rpm, Tq on/off=10.5k/10k, 2k WOB, ECD=11.53 ppg EMW, P/U=200k, S/O=<40k, ROT=115k. ADT=2.92, Total Bit Hrs=44.62,Total Jar Hrs=85.75. 15:45 20:00 4.25 12,406 12,406 PROD1 CASING CIRC P Circulate while R&R from 12406'MD to 12307' MD @ 270 gpm, 2530 psi, 18%flow out, 180 rpm, 8.5k Tq, Perform 290 bbl dump and dilute per program and add 2%Lube 776 to mud system. Mud weight in/out 9.45 ppg. Total strokes pumped= 15335. P/U weight dropped from 200k to 157k, S/O weight went from <40k to 80k. ROT=116k, Tq reduced from 10k to 8.5k. 20:00 20:30 0.50 12,406 12,406 PROD1 CASING OWFF P Obtain SPR's and Observe well for 10 minutes, slight drop. SPR's© 12406'MD, 3871'TVD, 9.45 ppg, 20:00 hrs #1-20 spm=650 psi,30 spm=800 psi #2-20 spm=680 psi,30 spm=820 psi Page 24 of 31 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 00:00 3.50 12,406 10,460 PROD1 CASING BKRM P Backream out of hole from 12406' MD to 10460' MD @ 1500 fph, 270 gpm, 2300 psi, 16%flow out, 130 rpm, 5.5k Tq. Monitor displacement via pits 2-4. P/U=124k, 5/0=76k. Losses for tour14.9 bbl. 09/10/2015 Backream out to casing shoe @ 4935' MD, circulate casing clean. POOH performing MAD pass from 5100'-2829'MD, logging and laying down drill pipe. POOH from 2829"laying down 4" DP. L/D BHA. 00:00 05:30 5.50 10,460 7,612 PROD1 CASING BKRM P Backream out of hole from 10460' MD to 7612' MD @ 270 gpm, 2005 psi, 17%flow out, 130 rpm, 4.7k Tq, Monitor displacement via pits 2-4 average 5 bph losses. P/U=112k, S/O=86k, ROT=96k. 05:30 12:00 6.50 7,612 5,015 PROD1 CASING BKRM P Continue backreaming out of hole while laying down doubles from 7612' MD to 5015' MD @ 270 gpm, 1785 psi, 17%flow out, 130 rpm, 3.6k Tq, Monitor displacement via pit 2-4, P/U=102k, 5/0=93k, ROT=99k. Losses for tour=38.5 bbl OA pressure=140 psi 12:00 12:15 0.25 5,015 4,930 PROD1 CASING BKRM P Continue backreaming out of hole while laying down doubles from 5015' MD to 4930' MD @ 270 gpm, 1785 psi, 17%flow out, 130 rpm, 3.5k Tq, Monitor displacement via pit 2-4, P/U=102k, 5/O=93k, ROT=99k. 12:15 13:30 1.25 4,930 4,930 PROD1 CASING CIRC P Circulate while R&R form 4928'MD to 4857' MD @ 270 gpm, 1785 psi, 17%flow out, 80 rpom,2.5k Tq, 10.3 ppg ECD, total strokes pumped 4402, MW in/out=9.4 ppg. 13:30 14:00 0.50 4,930 4,930 PROD1 CASING OWFF P Monitor well for 30 minutes-Drop 1' in 30 min. 14:00 14:45 0.75 4,930 4,955 PROD1 CASING DLOG P RIH to 5100' MD(out of casing)and sent downlink to Sonicscope. MAD pass @ 900 fph from 5100'MD to 4955'MD racking back 2 stands. 14:45 15:45 1.00 4,955 4,576 PROD1 CASING DLOG P MAD pass while POOH from 4955' MD to 4576' MD @ 900 fph, laying down doubles. Monitor displacement via trip tank. 15:45 16:30 0.75 4,576 4,320 PROD1 CASING DLOG P Continue MAD pass while POOH from 4576'MD to 4320'MD @ 900 fph, laying down singles. Monitor displacement via trip tank. 16:30 16:45 0.25 4,320 4,320 PROD1 CASING OTHR T Swap rig power from Hi-Line to 3516's. Had to get off highline power while 7ES gets hooked up. 16:45 17:15 0.50 4,320 4,130 PROD1 CASING DLOG P Continue MAD pass while POOH from 4320' MD to 4130'MD @ 900 fph laying down singles. 17:15 17:30 0.25 4,130 4,130 PROD1 CASING OTHR T Swap rig power from 3516's back to Hi-Line power after 7ES on line. Page 25 of 31 Time Logs Date From ' To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 21:00 3.50 4,130 2,829 PROD1 CASING DLOG P Continue MAD pass while POOH from 4130'MD to 2829'MD @ 900 fph laying down singles. 21:00 23:15 2.25 2,829 402 PROD1 CASING PULD P POOH laying down singles from 2829' MD to 402'MD. 23:15 00:00 0.75 402 219 PROD1 CASING BHAH P Lay down HWDP,Jars and NMDC and BHA to 219' MD per DD. Losses for tour= 18.4 bbl,total 56.9 bbl for the day. OA pressure= 150 psi 09/11/2015 L/D BHA#5, P/U BHA#6 casing scraper run, RIH to 4935' MD and perform scraper run, CBU and POOH installing supersliders on liner running string. R/U and run 4'/2'IBTM slotted liner. 00:00 01:15 1.25 219 0 PROD1 CASING BHAH P Continue L/D BHA#5 from 219' MD as per DD. 01:15 01:45 0.50 0 0 PROD1 CASING BHAH P Clean and clear rig floor. 01:45 02:00 0.25 0 23 COMPZ CASING BHAH T M/U string mill BHA#6 as per Baker rep. 02:00 02:30 0.50 23 23 COMPZ CASING SVRG T Lubricate rig, service top drive and blocks. 02:30 05:30 3.00 23 4,912 COMPZ CASING TRIP T RIH with scraper assembly (watermelon mill)from 23' MD to 4912' MD. No string weight or obstruction observed. P/U=115k, 5/0=105k. 05:30 06:00 0.50 4,912 4,912 COMPZ CASING REAM T Pull back up to 4725' MD, establish circulation@ 294 gpm 800 psi, ream down to 4912'@ 100 rpm, 2.3k Tq. P/U=115k, S/O105k. 06:00 07:15 1.25 4,912 4,912 COMPZ CASING CIRC T CBU x 2 @ 294 gpm, 780 psi, 100 rpm,2.3k Tq, reciprocating from 4912' MD to 4890' MD. 07:15 07:30 0.25 4,912 4,912 COMPZ CASING OWFF T Shut down, blow down top drive, monitor well 10 minutes-static. Drop 2.38"metal Rabbit with 110'wire down liner running string. 07:30 08:30 1.00 4,912 3,345 COMPZ CASING TRIP T POOH from 4912'MD to 3345'MD, rack back all 4"HWDP in derrick. 08:30 12:00 3.50 3,345 497 COMPZ CASING TRIP T Continue POOH from 3345'MD to 497'MD installing supersliders on every joint of 4" DP and racking back in derrick. Losses for tour=20 bbl OA pressure=25 psi 12:00 13:00 1.00 497 55 COMPZ CASING TRIP T Continue POOH from 497' MD to 55' installing supersliders on every joint of drill pipe, racking back in derrick. Retrieve 2.38"rabbit @ BHA. 13:00 13:30 0.50 55 0 COMPZ CASING BHAH T PJSM and L/D Baker string mill BHA 13:30 13:45 0.25 0 0 COMPZ CASING RURD P Clear rig floor and change out handling equipment. Page 26 of 31 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 15:00 1.25 0 0 COMPZ CASING OTHR P P/U Seal bore, liner hanger, RS seal assy and ZXP assembly, Baker hand inspect and prep assembly. M/U to XO and first joint of 4" DP, rack back in derrick. 15:00 16:00 1.00 0 0 COMPZ CASING RURD P Clear floor of un-necessary equipment, M/U TIW valve to XO, rig up to run liner.Verify count in pipe shed. 16:00 16:15 0.25 0 0 COMPZ CASING SFTY P PJSM on running liner. 16:15 00:00 7.75 0 6,375 COMPZ CASING PUTB P P/U 4'/2"orange peel shoe,4 blank joints of 4'/z' 12.6#IBTM L-80, 1 6.38"water activated swell packer, followed by 4'/2' 12.6#IBTM L-80 slotted liner to 6375' MD. IBTM connections torqued up to mark @ 4000 ft/lbs. Losses for tour=0 OA pressure=25 psi. 39/12/2015 Continue P/U liner to 7537' MD, M/UI liner hanger and ZXP,XO to DP and RIH on 4"DP. Set liner hanger, ZXP and test. POOH laying down DP. R/U and run 4%H563 upper completion, locate and P/U space out pups. 00:00 01:15 1.25 6,375 7,561 COMPZ CASING PUTB P Continue RIH with 4%"IBTM 12.6# L-80 slotted liner from 6375' MD to 7561' MD as per detail. 01:15 02:00 0.75 7,561 7,688 COMPZ CASING OTHR P Change out elevators, M/U liner/ hanger assembly and first stand of drill pipe to 7688'MD. Establish circulation through hanger @ 2 bpm, 60 psi, 7%flow out. SIMOPS-Rig down power tongs, change out slip inserts. 02:00 04:30 2.50 7,688 12,367 COMPZ CASING RUNL P RIH with liner on 4"drill pipe from 7688' MD to 12385'MD. P/U=140k, S/O=85k. Pick up to setting depth 12365'MD. 04:30 05:00 0.50 12,367 12,367 COMPZ CASING CIRC P Establish circulation and pump 1 string volume 45 bbl© 168 gpm, 360 psi. 05:00 05:45 0.75 12,367 12,367 COMPZ CASING PACK P Drop 1.75"phenolic ball per Baker rep, pump ball down on seat @ 105 gpm, 270 psi. Ball on seat @ 322 stks. Pressure up to 1000 psi, then pressure on up 3000 psi slowly, slight pressure bobble at 2700 psi. Bleed pressure to 1000 psi and shut in. Slack off from 132k to 32k to confirm hanger set. P/U to 150k, not released 1st try. Pressure up to 3000 psi, bleed to 0. P/U weight 117k, released. P/U 6'to expose dogs, S/O to 40k, observe shear out at 71k. P/U to 120k, rotate 20 rpm 2.8k Tq, slack off to 35k. P/U and kill rotary. Page 27 of 31 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:30 0.75 12,367 12,367 COMPZ CASING PRTS P Close annular, open kill line and pressure up annulus to 3500 psi to test packer seals, hold for 30 minutes charted. Bleed pressure off, open annular and blow down kill line. 06:30 07:00 0.50 12,367 4,702 COMPZ WELLPF TRIP P Unsting from liner assembly, lay down single in shed. Rack back one stand in derrick to get running tool _ out of liner top. 07:00 08:00 1.00 4,775 4,775 COMPZ WELLPF DISP P PJSM,displace well to 9.4 ppg brine, pump 50 bbl Hi Vis spacer, 40 bbl Soap Pill and chase with 220 bbl 9.4 ppg brine. 08:00 09:30 1.50 4,775 4,775 COMPZ WELLPF SLPC P PJSM, cut and slip drilling line. Cut 11 wraps, 88'of drilling line and slip on same. Calibrate Amphion, Totco and SLB block height. SIMOPS-Cleaning under shakers, trip tank and pits to take on more brine. 09:30 10:00 0.50 4,775 4,775 COMPZ WELLPF SVRG P Lubricate and service rig SIMOPS-Finish cleaning trip tanks and fill with brine for POOH. 10:00 11:45 1.75 4,775 3,322 COMPZ WELLPF PULD P POOH laying down 4"HWDP singles from 4775'MD to 3322' MD. P/U=90k, 5/0=87k, monitor hole fill via trip tank. 11:45 12:00 0.25 3,322 3,132 COMPZ WELLPF PULD P Continue POOH laying down 4"DP from 3322'MD to 3132'MD leaving supersliders on the DP. P/U=88k, 5/0=86k. Monitor hole fill via trip tank. 12:00 15:30 3.50 3,132 0 COMPZ WELLPF PULD P Lay down remaining DP singles from 3132' MD to surface, leaving supersliders on every joint. 15:30 16:00 0.50 0 0 COMPZ WELLPF BHAH P Change out slip inserts, lay down Baker liner running tool per BOT rep. 16:00 16:45 0.75 0 0 COMPZ WELLPF PULD P Change out slip inserts, M/U mule shoe and RIH with 4 stands of 4" DP from derrick, lay down same in singles. 16:45 17:15 0.50 0 0 COMPZ RPCOM RURD P M/U running tool on a double and pull wear bushing. L/D running tool. 17:15 17:45 0.50 0 0 COMPZ RPCOM WWWH P M/U stack flushing tool,flush stack @ 757 gpm, 200 psi, lay down stack washer and DP double to the pipe shed. Blow down topdrive, SIMOPS-R/U double stack power tongs. 17:45 18:00 0.25 0 0 COMPZ RPCOM RURD P Change out handling equipment, verify pipe count and jewelry alignment in pipe shed. Page 28 of 31 Time Logs S 4110 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 23:00 5.00 0 4,717 COMPZ RPCOM PUTB P PJSM, P/U and RIH with 41/2" 12.6# L-80 Hydril 563 completion string per running order to 4717'MD,torque all connections to 3800 ft/lbs. Monitor displacement via trip tank. P/U=89k, S/O=77k, SIMOPS-Extend diverter line additional 70'. 23:00 00:00 1.00 4,717 4,754 COMPZ RPCOM HOSO P Locate out, running joints#111,#112 and#113 tagging no-go 34.5' in on joint#113 @ 4834'MD. Lay down joints#113,#112,#111 and P/U pup joints 7.73', 9.77', 9.80'and 9.82'to 4754' MD. OA pressure=50 psi. 39/13/2015 P/U hanger and landing jt. Run in and locate with pump, P/U and reverse in inhibited brine. Land and RILDS. Test hanger seals,test IA, Drop ball/rod test Tbg,test IA. Shear out SOV. Set BPV and test, N/D stack, N/U BOPE. Pull BPV, setTWC,test tree, FP,secure well. 00:00 00:30 0.50 4,754 4,795 COMPZ RPCOM THGR P P/U tubing hanger with 41'joint, M/U to string, set slip under hanger. Make up landing joint to hanger. 00:30 02:00 1.50 4,795 4,810 COMPZ RPCOM HOSO T Lowered hanger below table to remove 10'pup off top of hanger due bad(egged)collar. Remove collar from pup and change out. 02:00 03:00 1.00 4,810 4,815 COMPZ RPCOM HOSO P M/U pumping equipment on top of remaining landing joint and to IA. Pump down tubing @ 1 bpm while stinging into seal bore, observe 200 psi increase @ 4815'MD confirming space out. 03:00 03:15 0.25 4,815 4,815 COMPZ RPCOM CRIH P P/U to 4800'MD,Attempt to reverse circulate, 1 bpm 800 psi. Seals still in liner tieback. 03:15 04:00 0.75 4,815 4,790 COMPZ RPCOM CRIH T Unsting from top of liner, pull hanger back to floor, bringing seals at top of ZXP to reverse in brine. Change out 0-rings on hanger and landing joint. 04:00 05:30 1.50 4,790 4,790 COMPZ RPCOM CRIH P Line up to reverse circulate, close annular. Establish circulation down IA taking returs out the tubing, 3 bpm 300 psi. Pump 20 bbl 9.4 ppg corrosion inhibited brine,chase with 105 bbl 9.4 ppg 3% KCI brine 05:30 05:45 0.25 4,790 4,790 COMPZ RPCOM OWFF P Bleed all pressure off, open annular and observe well for flow for 10 minutes-static. 05:45 06:15 0.50 4,790 4,790 COMPZ RPCOM RURD P Drain stack, blow down choke and kill manifold, leaving annulus valve open for landing hanger. 06:15 07:45 1.50 4,790 4,832 COMPZ RPCOM THGR P Pull slip inserts, lower string and land hanger.Vetco RILDS. Seal assembly mule shoe @ 4831.77' MD, spaced 1.97'off fully located. Page 29 of 31 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 08:30 0.75 4,832 4,832 COMPZ RPCOM THGR P Pressure test lower hanger seals to 5000 psi for 15 minutes witnessed by CPAI rep. 08:30 09:15 0.75 4,832 4,832 COMPZ RPCOM PRTS P Rig up to pump down IA, Perform pressure test on IA to 1000 psi with tubing open, test 10 minutes on chart confirming seals fully engaged. 09:15 10:45 1.50 4,832 4,832 COMPZ RPCOM PRTS P R/D headpin off landing joint,drop ball and rod w/rollers. 1.3"ball, 11 rollers. Rod=8.55'long, Barrel OD=1.89", Rod OD=.87", Roller OD=2.89".Allow ball/rod to fall for 15 minutes. R/U headpin, pressure test tubing to 3500 psi for 30 minutes charted. 10:45 11:30 0.75 4,832 4,832 COMPZ RPCOM PRTS P Bleed pressure on tubing to 2200 psi and shut in. Line up to pressure test IA, pressure up to 3000 psi, hold 30 minutes charted. 11:30 11:45 0.25 4,832 0 COMPZ RPCOM CIRC P Bleed all pressure off tubing and IA. Leave tubing open and line up to pump down IA to shear out SOV. Pressure up to 2500 psi,did not shear. Bleed pressure off. Pressure up to 3350 psi and shear out SOV, all pressure to 0 psi. 11:45 12:00 0.25 0 0 COMPZ RPCOM RURD P Rig down testing equipment, pull landing joint. OA pressure=140 psi. 12:00 13:00 1.00 0 0 COMPZ WHDBO MPSP P Suck out stack, Set BPV, line up test equipment. 13:00 13:45 0.75 0 0 COMPZ WHDBO MPSP P Test BPV from below pumping down IA @ 2000 psi for 10 minutes charted. Pumped 2.3 bbl, 2.2 bbl bled back. Monitor well 30 minutes. All barriers in place. 13:45 16:00 2.25 0 0 COMPZ WHDBO NUND P Blow down injection line, hole fill and HP mud line. N/D BOPE, riser and extension,flowline, strip-o-matic, flow box, choke and kill lines. SIMOPS-Prep Derrick for scoping. 16:00 17:00 1.00 0 0 COMPZ WHDBO NUND P Mobilize tree to cellar, prep wellhead for tree. SIMOPS-Clean pits. 17:00 20:30 3.50 0 0 COMPZ WHDBO NUND P Lower tree to cellar and N/U, CPAI production ops verified orientation of tree and valves. N/U actuator and valves. SIMOPS-Prep rig floor for rig move, disconnect all un-needed lines and innerconnects, P/U lubricator via beaverslide, install bridle yokes on topdrive. 20:30 21:00 0.50 0 0 COMPZ WHDBO PRTS P Test tree flange and void to 5000 psi for 10 mnutes,witnessed by CPAI rep. Page 30of31 Time Logs 1111 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 22:00 1.00 0 0 COMPZ WHDBO MPSP P Dry rod out BPV and set TWC. Fill tree with diesel and test to 5000 psi 10 minutes witnessed by CPAI rep. 22:00 23:30 1.50 0 0 COMPZ WHDBO FRZP P Flush injection line with diesel, surface test lines to 15900 psi. Freeze protect well pumping 87 bbl diesel down IA,taking returns out tubing @ 54 gpm with injection pump. ICP=300 psi, FCP=625 psi, 5%flow out. SIMOPS-Lower cattle chute to pipe shed, continue cleaning pits. 23:30 00:00 0.50 0 0 COMPZ WHDBO FRZP P U-tube diesel communicating IA and tubing through squeeze manifold. SIMOPS-Prep modules for separation. 09/14/2015 Complete diesel equalize across the top. Blow down lines. Secure well, (stall well sign on well and RDMO rig to 1C-153. 00:00 01:30 1.50 0 0 COMPZ WHDBO FRZP P Finish U-tubing diesel through squeeze manifold. Final pressure OA=130 psi, Tubing= 130 psi, OA= 50 psi. Blow down hoses and injection lines back to freeze protect tank. Shut in valves and rig down hoses. SIMOPS-Prep rig modules for separation. 01:30 03:00 1.50 0 0 COMPZ WHDBO MPSP P Lower Vetco lubricator to cellar. Rig up hydraulic lines and install lubricator on tree. Fill lubricator with diesel and pressure test to 1000 psi. Vetco rep install BPV. SIMOPS-Prep Derrick to scope down, blow down water, disconnect all innerconnects. Start all C6 cold starts. 03:00 06:00 3.00 0 0 DEMOB MOVE RURD P Scope down derrick, prep to raise C-section, un-spool line off DW and deadman. Pin topdrive in place on guide rails. Secure energy track and bails to derrick. Raise C-section and pin in place, Open doors and remove hatches for derrick rams. Swap power to cold start all modules, disconnect remaining innerconnects. SIMOPS-Secure well and cellar. Rig released @ 06:00 9/14/15 0 DEMOB Page 31 of 31 • NADConversion Kuparuk River Unit Kuparuk 1C Pad 1C-152 ►z coCrs- ste1 r Definitive Survey Report 23 September, 2015 NAD 27 • Schlumberger 0 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: Grid Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska, United States 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 1C-152 Well Position +N/-S 0.00 usft Northing: 5,968,956.10 usfi Latitude: 70° 19'32.591 N +EI-W 0.00 usft Easting: 561,869.93 usfi Longitude: 149°29'53.846 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 57.60 usft Wellbore 1C-152 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 8/25/2015 19.00 80.99 57,507 Design 1C-152 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.97 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.97 0.00 0.00 344.53 Survey Program Date ',„�4�`i q" ' From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 83.03 1,965.03 1C-152 Srvy#1 GYD-GC-SS(1C-152) GYD-GC-SS Gyrodata gyro single shots 8/26/2015 9:0, 2,023.14 2,734.01 1C-152 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 12:5E 2,833.47 2,833.47 1C-152 Srvy#3 INC+TREND(1C-152) INC+TREND Inclinometer+known azi trend 9/1/2015 1:00 2,863.03 4,882.60 1C-152 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 1:01 4,882.60 12,345.49 1C-152 Srvy#5 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 1:03 • 12,406.00 12,406.00 1C-152 Srvy#6-Projection to TD(1C-1f BLIND Blind drilling 9/23/2015 2:3: 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 39.97 0.00 0.00 39.97 -57.60 0.00 0.00 5,968,956.10 561,869.93 0.00 0.00 UNDEFINED 123.00 0.30 70.14 123.00 25.43 0.07 0.20 5,968,956.17 561,870.13 0.36 0.02 GYD-GC-SS(1) NOT an Actual Survey 20"x 42" 171.30 0.47 70.14 171.30 73.73 0.18 0.51 5,968,956.28 561,870.44 0.36 0.04 GYD-GC-SS(1) 265.73 0.84 76.14 265.72 168.15 0.48 1.54 5,968,956.58 561,871.47 0.40 0.05 GYD-GC-SS(1) 361.07 1.08 38.50 361.05 263.48 1.35 2.78 5,968,957.45 561,872.71 0.69 0.56 GYD-GC-SS(1) 453.55 2.91 20.76 453.47 355.90 4.23 4.16 5,968,960.33 561,874.09 2.07 2.97 GYD-GC-SS(1) 547.56 5.02 15.43 547.25 449.68 10.43 6.10 5,968,966.52 561,876.03 2.28 8.42 GYD-GC-SS(1) 640.05 6.88 8.16 639.24 541.67 19.81 7.96 5,968,975.91 561,877.89 2.17 16.97 GYD-GC-SS(1) 733.46 8.50 4.13 731.81 634.24 32.24 9.25 5,968,988.33 561,879.18 1.83 28.60 GYD-GC-SS(1) 9/23/2015 2:54:57PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger 41111 Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: Grid Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 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 828.16 10.55 4.66 825.20 727.63 47.86 10.46 5,969,003.95 561,880.39 2.17 43.33 GYD-GC-SS(1) 922.47 11.03 3.67 917.84 820.27 65.47 11.74 5,969,021.56 561,881.67 0.55 59.96 GYD-GC-SS(1) 1,017.36 13.56 9.67 1,010.55 912.98 85.50 14.19 5,969,041.59 561,884.12 2.98 78.61 GYD-GC-SS(1) 1,112.15 15.72 17.21 1,102.26 1,004.69 108.72 19.86 5,969,064.81 561,889.78 3.03 99.49 GYD-GC-SS(1) 1,205.91 16.00 18.92 1,192.46 1,094.89 133.08 27.80 5,969,089.17 561,897.73 0.58 120.84 GYD-GC-SS(1) 1,300.08 16.76 18.40 1,282.80 1,185.23 158.24 36.30 5,969,114.32 561,906.23 0.82 142.82 GYD-GC-SS(1) 1,394.89 20.49 24.35 1,372.64 1,275.07 186.34 47.46 5,969,142.42 561,917.39 4.41 166.93 GYD-GC-SS(1) 1,490.51 22.51 26.82 1,461.60 1,364.03 217.93 62.62 5,969,174.00 561,932.55 2.31 193.33 GYD-GC-SS(1) 1,585.67 22.81 26.63 1,549.42 1,451.85 250.67 79.11 5,969,206.75 561,949.03 0.32 220.49 GYD-GC-SS(1) 1,680.58 26.89 26.68 1,635.52 1,537.95 286.31 97.00 5,969,242.38 561,966.92 4.30 250.06 GYD-GC-SS(1) 1,775.24 30.45 28.22 1,718.56 1,620.99 326.58 117.96 5,969,282.65 561,987.88 3.84 283.29 GYD-GC-SS(1) 1,868.28 33.61 29.35 1,797.43 1,699.86 369.81 141.74 5,969,325.88 562,011.65 3.46 318.61 GYD-GC-SS(1) 1,964.34 34.33 33.78 1,877.11 1,779.54 415.61 169.83 5,969,371.57 562,039.75 2.68 355.16 GYD-GC-SS(1) 2,069.71 34.04 37.80 1,964.28 1,866.71 463.51 204.43 5,969,419.57 562,074.34 2.16 392.19 MWD+IFR-AK-CAZ-SC(2) 2,117.93 29.94 37.81 2,005.17 1,907.60 483.69 220.09 5,969,439.75 562,090.00 8.50 407.47 MWD+IFR-AK-CAZ-SC(2) 2,162.76 27.40 38.01 2,044.50 1,946.93 500.66 233.30 5,969,456.71 562,103.21 5.67 420.30 MWD+IFR-AK-CAZ-SC(2) 2,211.99 24.44 37.68 2,088.78 1,991.21 517.65 246.51 5,969,473.70 562,116.41 6.02 433.15 MWD+IFR-AK-CAZ-SC(2) 2,260.94 22.73 37.11 2,133.64 2,036.07 533.21 258.40 5,969,489.26 562,128.31 3.52 444.97 MWD+IFR-AK-CAZ-SC(2) 2,307.42 23.46 37.34 2,176.39 2,078.82 547.73 269.43 5,969,503.77 562,139.34 1.58 456.02 MWD+IFR-AK-CAZ-SC(2) 2,402.27 19.48 44.14 2,264.66 2,167.09 574.10 291.91 5,969,530.15 562,161.81 4.94 475.44 MWD+IFR-AK-CAZ-SC(2) 2,448.74 16.86 49.90 2,308.81 2,211.24 584.00 302.46 5,969,540.05 562,172.37 6.83 482.17 MWD+IFR-AK-CAZ-SC(2) 2,496.69 17.04 50.41 2,354.67 2,257.10 592.96 313.20 5,969,549.00 562,183.10 0.49 487.94 MWD+IFR-AK-CAZ-SC(2) 2,591.82 16.21 48.07 2,445.83 2,348.26 610.72 333.82 5,969,566.76 562,203.72 1.12 499.55 MWD+IFR-AK-CAZ-SC(2) 2,686.65 16.21 42.09 2,536.89 2,439.32 629.38 352.54 5,969,585.42 562,222.44 1.76 512.55 MWD+IFR-AK-CAZ-SC(2) 2,733.32 16.23 41.68 2,581.71 2,484.14 639.09 361.24 5,969,595.13 562,231.14 0.25 519.58 MWD+IFR-AK-CAZ-SC(2) 2,807.70 17.37 38.34 2,652.91 2,555.34 655.56 375.04 5,969,611.60 562,244.94 2.01 531.78 MWD+IFR-AK-CAZ-SC(4) I 10 3/4"x 13-112 NOT an Actual Survey 2,957.15 19.81 32.80 2,794.56 2,696.99 694.36 402.61 5,969,650.39 562,272.50 2.01 561.82 MWD+IFR-AK-CAZ-SC(4) 3,051.78 23.27 26.74 2,882.58 2,785.01 724.55 419.71 5,969,680.58 562,289.60 4.34 586.35 MWD+IFR-AK-CAZ-SC(4) 3,146.91 26.47 19.93 2,968.90 2,871.33 761.28 435.40 5,969,717.30 562,305.29 4.51 617.56 MWD+IFR-AK-CAZ-SC(4) 3,241.92 29.58 15.49 3,052.77 2,955.20 803.80 448.89 5,969,759.82 562,318.78 3.94 654.95 MWD+IFR-AK-CAZ-SC(4) 3,336.61 33.11 9.75 3,133.64 3,036.07 851.83 459.52 5,969,807.85 562,329.40 4.88 698.41 MWD+IFR-AK-CAZ-SC(4) 3,431.25 35.77 3.51 3,211.71 3,114.14 904.94 465.59 5,969,860.96 562,335.48 4.67 747.97 MWD+IFR-AK-CAZ-SC(4) 3,526.54 38.74 0.05 3,287.56 3,189.99 962.57 467.32 5,969,918.58 562,337.21 3.81 803.06 MWD+IFR-AK-CAZ-SC(4) 3,621.67 41.88 356.08 3,360.10 3,262.53 1,024.05 465.18 5,969,980.05 562,335.06 4.26 862.87 MWD+IFR-AK-CAZ-SC(4) 3,716.79 45.61 352.77 3,428.81 3,331.24 1,089.47 458.73 5,970,045.46 562,328.61 4.60 927.64 MWD+IFR-AK-CAZ-SC(4) 3,811.79 48.58 352.63 3,493.48 3,395.91 1,158.48 449.89 5,970,114.47 562,319.77 3.13 996.52 MWD+IFR-AK-CAZ-SC(4) 3,906.65 52.35 352.83 3,553.85 3,456.28 1,231.04 440.63 5,970,187.02 562,310.52 3.98 1,068.92 MWD+IFR-AK-CAZ-SC(4) 4,001.58 56.60 352.87 3,609.00 3,511.43 1,307.68 431.02 5,970,263.66 562,300.91 4.48 1,145.34 MWD+IFR-AK-CAZ-SC(4) 4,097.38 61.40 352.41 3,658.33 3,560.76 1,389.10 420.50 5,970,345.06 562,290.39 5.03 1,226.62 MWD+IFR-AK-CAZ-SC(4) 9/23/2015 2:54:57PM Page 3 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: Grid Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100') (ft) Survey Tool Name 4,150.38 64.71 352.39 3,682.34 3,584.77 1,435.92 414.25 5,970,391.89 562,284.14 6.25 1,273.41 MWD+IFR-AK-CAZ-SC(4) 4,191.55 67.11 352.56 3,699.14 3,601.57 1,473.18 409.33 5,970,429.14 562,279.22 5.84 1,310.63 MWD+IFR-AK-CAZ-SC(4) 4,238.80 70.16 352.56 3,716.36 3,618.79 1,516.81 403.63 5,970,472.76 562,273.52 6.46 1,354.20 MWD+IFR-AK-CAZ-SC(4) 4,286.46 71.71 352.40 3,731.92 3,634.35 1,561.46 397.74 5,970,517.42 562,267.63 3.27 1,398.81 MWD+IFR-AK-CAZ-SC(4) 4,381.61 75.93 350.68 3,758.43 3,660.86 1,651.83 384.28 5,970,607.77 562,254.18 4.76 1,489.49 MWD+IFR-AK-CAZ-SC(4) 4,427.43 77.27 350.97 3,769.05 3,671.48 1,695.83 377.18 5,970,651.76 562,247.07 2.99 1,533.79 MWD+IFR-AK-CAZ-SC(4) 4,476.22 79.00 350.21 3,779.08 3,681.51 1,742.93 369.37 5,970,698.86 562,239.27 3.86 1,581.27 MWD+IFR-AK-CAZ-SC(4) 4,571.39 79.65 348.59 3,796.71 3,699.14 1,834.85 352.17 5,970,790.78 562,222.06 1.81 1,674.45 MWD+IFR-AK-CAZ-SC(4) 4,666.26 79.99 345.67 3,813.48 3,715.91 1,925.87 331.37 5,970,881.79 562,201.27 3.05 1,767.72 MWD+IFR-AK-CAZ-SC(4) 4,760.37 80.38 345.52 3,829.53 3,731.96 2,015.69 308.30 5,970,971.60 562,178.20 0.44 1,860.43 MWD+IFR-AK-CAZ-SC(4) 4,852.24 84.15 344.91 3,841.89 3,744.32 2,103.69 285.07 5,971,059.59 562,154.98 4.16 1,951.45 MWD+IFR-AK-CAZ-SC(4) 4,882.60 85.30 344.93 3,844.68 3,747.11 2,132.88 277.21 5,971,088.78 562,147.11 3.79 1,981.68 MWD+IFR-AK-CAZ-SC(4) 4,934 80 86.99 345.40 3,848.19 3,750.62 2,183.23 263.87 5,971,139.12 562,133.78 3.36 2,033.75 MWD+IFR-AK-CAZ-S (5) NOT an Actual Survey 7-5/8"x 9-7/8" 4,976.01 88.32 345.77 3,849.88 3,752.31 2,223.11 253.62 5,971,178.99 562,123.53 3.36 2,074.92 MWD+IFR-AK-CAZ-S. ko) 4,987.58 88.63 345.85 3,850.19 3,752.62 2,234.32 250.79 5,971,190.20 562,120.70 2.77 2,086.48 MWD+IFR-AK-CAZ-SC(5) 5,081.84 90.89 344.18 3,850.58 3,753.01 2,325.36 226.42 5,971,281.24 562,096.33 2.98 2,180.73 MWD+IFR-AK-CAZ-SC(5) 5,176.97 91.47 343.45 3,848.62 3,751.05 2,416.70 199.91 5,971,372.57 562,069.82 0.98 2,275.83 MWD+IFR-AK-CAZ-SC(5) 5,272.12 91.58 342.48 3,846.09 3,748.52 2,507.64 172.05 5,971,463.51 562,041.96 1.03 2,370.91 MWD+IFR-AK-CAZ-SC(5) 5,366.78 90.99 343.25 3,843.97 3,746.40 2,598.08 144.17 5,971,553.93 562,014.08 1.02 2,465.51 MWD+IFR-AK-CAZ-SC(5) 5,461.27 91.03 343.53 3,842.30 3,744.73 2,688.61 117.16 5,971,644.46 561,987.08 0.30 2,559.96 MWD+IFR-AK-CAZ-SC(5) 5,556.47 90.86 343.76 3,840.73 3,743.16 2,779.95 90.36 5,971,735.78 561,960.28 0.30 2,655.14 MWD+IFR-AK-CAZ-SC(5) 5,651.78 90.93 344.72 3,839.24 3,741.67 2,871.66 64.48 5,971,827.49 561,934.40 1.01 2,750.43 MWD+IFR-AK-CAZ-SC(5) 5,745.67 90.89 344.18 3,837.75 3,740.18 2,962.11 39.31 5,971,917.92 561,909.24 0.58 2,844.31 MWD+IFR-AK-CAZ-SC(5) 5,841.20 90.31 344.86 3,836.75 3,739.18 3,054.16 13.81 5,972,009.97 561,883.74 0.94 2,939.83 MWD+IFR-AK-CAZ-SC(5) 5,935.76 89.83 344.25 3,836.63 3,739.06 3,145.31 -11.37 5,972,101.11 561,858.56 0.82 3,034.39 MWD+IFR-AK-CAZ-SC(5) 6,029.96 89.90 344.62 3,836.86 3,739.29 3,236.05 -36.64 5,972,191.84 561,833.29 0.40 3,128.59 MWD+IFR-AK-CAZ-SC(5) 6,125.21 90.03 345.30 3,836.91 3,739.34 3,328.04 -61.36 5,972,283.82 561,808.58 0.73 3,223.84 MWD+IFR-AK-CAZ-SC(5) 6,219.78 89.90 346.29 3,836.97 3,739.40 3,419.72 -84.56 5,972,375.49 561,785.37 1.06 3,318.39 MWD+IFR-AK-CAZ-SC(5) 6,314.78 89.86 347.32 3,837.17 3,739.60 3,512.21 -106.25 5,972,467.97 561,763.69 1.09 3,413.31 MWD+IFR-AK-CAZ-SC(5) 6,409.37 89.86 347.67 3,837.40 3,739.83 3,604.55 -126.73 5,972,560.31 561,743.21 0.37 3,507.77 MWD+IFR-AK-CAZ-SC(5) 6,504.15 90.21 348.26 3,837.34 3,739.77 3,697.25 -146.49 5,972,653.00 561,723.45 0.72 3,602.38 MWD+IFR-AK-CAZ-SC(5) 6,599.66 90.14 348.75 3,837.05 3,739.48 3,790.84 -165.52 5,972,746.58 561,704.42 0.52 3,697.66 MWD+IFR-AK-CAZ-SC(5) 6,694.55 90.17 348.05 3,836.80 3,739.23 3,883.80 -184.60 5,972,839.52 561,685.35 0.74 3,792.33 MWD+IFR-AK-CAZ-SC(5) 6,789.67 90.14 346.49 3,836.54 3,738.97 3,976.57 -205.56 5,972,932.29 561,664.39 1.64 3,887.34 MWD+IFR-AK-CAZ-SC(5) 6,884.12 90.21 346.08 3,836.25 3,738.68 4,068.33 -227.95 5,973,024.04 561,642.00 0.44 3,981.75 MWD+IFR-AK-CAZ-SC(5) 6,978.13 89.90 346.40 3,836.16 3,738.59 4,159.64 -250.31 5,973,115.35 561,619.64 0.47 4,075.71 MWD+IFR-AK-CAZ-SC(5) 7,074.57 89.48 345.23 3,836.68 3,739.11 4,253.14 -273.94 5,973,208.83 561,596.01 1.29 4,172.13 MWD+IFR-AK-CAZ-SC(5) 7,168.63 90.58 344.08 3,836.63 3,739.06 4,343.84 -298.83 5,973,299.53 561,571.12 1.69 4,266.18 MWD+IFR-AK-CAZ-SC(5) 7,263.53 91.85 342.49 3,834.62 3,737.05 4,434.71 -326.12 5,973,390.38 561,543.84 2.14 4,361.04 MWD+IFR-AK-CAZ-SC(5) 9/23/2015 2:54:57PM Page 4 COMPASS 5000.1 Build 74 Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: Grid Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 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 7,358.34 91.51 342.43 3,831.84 3,734.27 4,525.07 -354.68 5,973,480.74 561,515.28 0.36 4,455.74 MWD+IFR-AK-CAZ-SC(5) 7,453.22 91.96 341.86 3,828.97 3,731.40 4,615.34 -383.76 5,973,571.00 561,486.21 0.77 4,550.50 MWD+IFR-AK-CAZ-SC(5) 7,548.45 91.92 341.39 3,825.74 3,728.17 4,705.66 -413.76 5,973,661.31 561,456.21 0.50 4,645.55 MWD+IFR-AK-CAZ-SC(5) 7,643.66 91.30 342.14 3,823.07 3,725.50 4,796.06 -443.54 5,973,751.70 561,426.43 1.02 4,740.61 MWD+IFR-AK-CAZ-SC(5) 7,738.48 90.21 343.64 3,821.82 3,724.25 4,886.67 -471.43 5,973,842.30 561,398.55 1.96 4,835.38 MWD+IFR-AK-CAZ-SC(5) 7,832.79 90.51 345.41 3,821.23 3,723.66 4,977.55 -496.59 5,973,933.18 561,373.39 1.90 4,929.68 MWD+IFR-AK-CAZ-SC(5) 7,927.82 90.34 344.62 3,820.52 3,722.95 5,069.35 -521.16 5,974,024.96 561,348.82 0.85 5,024.71 MWD+IFR-AK-CAZ-SC(5) 7,979.73 89.04 343.21 3,820.80 3,723.23 5,119.22 -535.54 5,974,074.83 561,334.44 3.69 5,076.61 MWD+IFR-AK-CAZ-SC(5) 8,022.94 87.77 342.65 3,822.01 3,724.44 5,160.51 -548.22 5,974,116.12 561,321.76 3.21 5,119.78 MWD+IFR-AK-CAZ-SC(5) 8,117.49 87.90 341.37 3,825.58 3,728.01 5,250.37 -577.40 5,974,205.97 561,292.59 1.36 5,214.17 MWD+IFR-AK-CAZ-SC(5) 8,212.82 87.94 344.33 3,829.04 3,731.47 5,341.40 -605.49 5,974,296.98 561,264.50 3.10 5,309.39 MWD+IFR-AK-CAZ-SC(5) 8,307.00 89.49 347.06 3,831.15 3,733.58 5,432.62 -628.75 5,974,388.20 561,241.24 3.33 5,403.51 MWD+IFR-AK-CAZ-SC(5) 8,401.02 89.97 348.46 3,831.59 3,734.02 5,524.50 -648.68 5,974,480.07 561,221.31 1.57 5,497.38 MWD+IFR-AK-CAZ-SC(5) 8,496.48 90.41 347.72 3,831.28 3,733.71 5,617.90 -668.38 5,974,573.47 561,201.62 0.90 5,592.66 MWD+IFR-AK-CAZ-SC(5) 8,589.29 89.69 348.19 3,831.20 3,733.63 5,708.67 -687.75 5,974,664.22 561,182.25 0.93 5,685.30 MWD+IFR-AK-CAZ-SC(5) 8,685.55 89.90 348.92 3,831.54 3,733.97 5,803.02 -706.84 5,974,758.56 561,163.15 0.79 5,781.32 MWD+IFR-AK-CAZ-SC(5) 8,782.80 89.86 350.51 3,831.74 3,734.17 5,898.70 -724.21 5,974,854.24 561,145.79 1.64 5,878.17 MWD+IFR-AK-CAZ-SC(5) 8,877.01 89.97 351.18 3,831.88 3,734.31 5,991.71 -739.20 5,974,947.24 561,130.81 0.72 5,971.81 MWD+IFR-AK-CAZ-SC(5) 8,971.82 89.93 350.09 3,831.97 3,734.40 6,085.25 -754.62 5,975,040.77 561,115.38 1.15 6,066.08 MWD+IFR-AK-CAZ-SC(5) 9,067.25 89.93 348.51 3,832.08 3,734.51 6,179.02 -772.34 5,975,134.53 561,097.66 1.66 6,161.17 MWD+IFR-AK-CAZ-SC(5) 9,161.79 89.49 347.26 3,832.56 3,734.99 6,271.45 -792.18 5,975,226.95 561,077.83 1.40 6,255.55 MWD+IFR-AK-CAZ-SC(5) 9,255.98 89.42 345.86 3,833.46 3,735.89 6,363.06 -814.07 5,975,318.55 561,055.94 1.49 6,349.67 MWD+IFR-AK-CAZ-SC(5) 9,350.72 89.62 345.10 3,834.25 3,736.68 6,454.77 -837.82 5,975,410.25 561,032.19 0.83 6,444.40 MWD+IFR-AK-CAZ-SC(5) 9,446.13 89.42 344.04 3,835.05 3,737.48 6,546.73 -863.20 5,975,502.21 561,006.81 1.13 6,539.80 MWD+IFR-AK-CAZ-SC(5) 9,540.60 89.76 343.43 3,835.73 3,738.16 6,637.42 -889.66 5,975,592.89 560,980.35 0.74 6,634.26 MWD+IFR-AK-CAZ-SC(5) 9,636.88 89.31 342.44 3,836.51 3,738.94 6,729.46 -917.91 5,975,684.91 560,952.11 1.13 6,730.50 MWD+IFR-AK-CAZ-SC(5) 9,732.08 89.35 342.62 3,837.62 3,740.05 6,820.26 -946.49 5,975,775.71 560,923.53 0.19 6,825.63 MWD+IFR-AK-CAZ-SC(5) 9,825.67 89.38 342.08 3,838.66 3,741.09 6,909.44 -974.86 5,975,864.88 560,895.16 0.58 6,919.15 MWD+IFR-AK-CAZ-SC(5) 9,919.96 89.52 342.08 3,839.56 3,741.99 6,999.15 -1,003.87 5,975,954.58 560,866.15 0.15 7,013.35 MWD+IFR-AK-CAZ-SC(5) 10,014.56 90.03 342.65 3,839.94 3,742.37 7,089.30 -1,032.53 5,976,044.73 560,837.50 0.81 7,107.88 MWD+IFR-AK-CAZ-SC(5) 10,110.17 89.90 343.81 3,839.99 3,742.42 7,180.85 -1,060.12 5,976,136.26 560,809.92 1.22 7,203.46 MWD+IFR-AK-CAZ-SC(5) 10,205.84 90.00 344.73 3,840.08 3,742.51 7,272.93 -1,086.05 5,976,228.34 560,783.98 0.97 7,299.13 MWD+IFR-AK-CAZ-SC(5) 10,300.14 90.45 346.39 3,839.71 3,742.14 7,364.25 -1,109.57 5,976,319.65 560,760.47 1.82 7,393.41 MWD+IFR-AK-CAZ-SC(5) 10,397.27 89.28 346.93 3,839.94 3,742.37 7,458.76 -1,131.97 5,976,414.14 560,738.06 1.33 7,490.47 MWD+IFR-AK-CA7-SC(5) 10,490.83 89.48 347.45 3,840.95 3,743.38 7,549.98 -1,152.72 5,976,505.36 560,717.32 0.60 7,583.93 MWD+IFR-AK-CAZ-SC(5) 10,585.64 88.83 346.55 3,842.35 3,744.78 7,642.35 -1,174.04 5,976,597.72 560,696.00 1.17 7,678.64 MWD+IFR-AK-CAZ-SC(5) 10,680.53 88.90 346.01 3,844.23 3,746.66 7,734.52 -1,196.54 5,976,689.88 560,673.50 0.57 7,773.46 MWD+IFR-AK-CAZ-SC(5) 10,774.67 89.55 345.12 3,845.50 3,747.93 7,825.67 -1,220.01 5,976,781.03 560,650.04 1.17 7,867.58 MWD+IFR-AK-CAZ-SC(5) 10,870.23 89.45 344.61 3,846.33 3,748.76 7,917.92 -1,244.95 5,976,873.26 560,625.10 0.54 7,963.13 MWD+IFR-AK-CAZ-SC(5) 10,962.96 90.03 344.04 3,846.75 3,749.18 8,007.20 -1,270.01 5,976,962.53 560,600.05 0.88 8,055.86 MWD+IFR-AK-CAZ-SC(5) 9/23/2015 2:54:57PM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: Grid Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) ((t) (°/100') (ft) Survey Tool Name 11,055.17 89.90 342.92 3,846.81 3,749.24 8,095.60 -1,296.22 5,977,050.92 560,573.83 1.22 8,148.05 MWD+IFR-AK-CAZ-SC(5) 11,147.08 89.97 343.11 3,846.92 3,749.35 8,183.50 -1,323.07 5,977,138.82 560,546.98 0.22 8,239.93 MWD+IFR-AK-CAZ-SC(5) 11,240.29 89.97 343.61 3,846.96 3,749.39 8,272.81 -1,349.76 5,977,228.12 560,520.30 0.54 8,333.12 MWD+IFR-AK-CAZ-SC(5) 11,332.67 89.21 344.25 3,847.63 3,750.06 8,361.57 -1,375.33 5,977,316.87 560,494.73 1.08 8,425.49 MWD+IFR-AK-CAZ-SC(5) 11,425.77 88.90 343.07 3,849.16 3,751.59 8,450.90 -1,401.52 5,977,406.19 560,468.54 1.31 8,518.57 MWD+IFR-AK-CAZ-SC(5) 11,515.52 89.62 344.80 3,850.32 3,752.75 8,537.13 -1,426.35 5,977,492.42 560,443.71 2.09 8,608.30 MWD+IFR-AK-CAZ-SC(5) 11,607.85 89.62 343.95 3,850.93 3,753.36 8,626.05 -1,451.22 5,977,581.32 560,418.85 0.92 8,700.63 MWD+IFR-AK-CAZ-SC(5) 11,697.96 89.31 343.90 3,851.77 3,754.20 8,712.63 -1,476.17 5,977,667.90 560,393.90 0.35 8,790.73 MWD+IFR-AK-CAZ-SC(5) 11,791.11 89.04 344.14 3,853.11 3,755.54 8,802.17 -1,501.81 5,977,757.43 560,368.26 0.39 8,883.86 MWD+IFR-AK-CAZ-SC(5) 11,883.00 88.90 344.54 3,854.77 3,757.20 8,890.64 -1,526.61 5,977,845.89 560,343.47 0.46 8,975.74 MWD+IFR-AK-CAZ-SC(5) 11,973.26 88.36 343.30 3,856.92 3,759.35 8,977.34 -1,551.60 5,977,932.58 560,318.48 1.50 9,065.97 MWD+IFR-AK-CAZ-SC(5) 12,066.77 88.42 344.44 3,859.55 3,761.98 9,067.13 -1,577.57 5,978,022.37 560,292.51 1.22 9,159.43 MWD+IFR-AK-CAZ-SC(5) 12,158.68 87.26 343.39 3,863.02 3,765.45 9,155.38 -1,603.01 5,978,110.60 560,267.07 1.70 9,251.27 MWD+IFR-AK-CAZ-SC(5) 12,250.13 87.94 344.97 3,866.85 3,769.28 9,243.29 -1,627.92 5,978,198.50 560,242.17 1.88 9,342.63 MWD+IFR-AK-CAZ-SC(5) 12,345.49 88.42 345.40 3,869.87 3,772.30 9,335.43 -1,652.29 5,978,290.64 560,217.80 0.68 9,437.94 MWD+IFR-AK-CAZ-SC(5) 12,367.30 88.53 345.52 3,870.46 3,772.89 9,356.53 -1,657.76 5,978,311.74 560,212.33 0.75 9,459.74 BLIND(6) NOT an Actual Survey 4 1/2"x 6-3/4" 12,406.00 88.72 345.74 3,871.38 3,773.81 9,394.01 -1,667.36 5,978,349.21 560,202.73 0.75 9,498.42 Projection to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. (� Yes ❑ No l have checked to the best of my ability that the following data is correct: [] Surface Coordinates [] Declination & Convergence GRS Survey Corrections [] Survey Tool Codes Digni.iyg„e,b„ ,,, r, Vincent @i cr.-V;iegrt fnia. °-5[tu4 bciym.°uSdd;T.A�1.YyG. SLB DE: Asara 'r,TWa ;4 malt Client Representative: zecex';n 3'S es Date: 23-Sep-2015 9/232015 2:54:57PM Page 6 COMPASS 5000.1 Build 74 • Cement Detail Report .*'-'44411111.0140%� 1C-152 04. conocoPhitiips yr- String: Conductor Cement Job: DRILLING ORIGINAL, 8/21/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Conductor Cement 6/25/2015 12:00 6/25/2015 12:00 1C-152 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement position conductor 75.0 118.0 No No No Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment First stage pumped to position and set conductor at depth to mitigate floating conductor. Pump 193 sacks for 15.7 ppg Slurry. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Surface Cement AS1 75.0 118.0 193 B Yield(fV/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 15.70 Additives Additive Type Concentration Conc Unit label Stage#2 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Conductor Cement cement conductor to 42.0 75.0 No No No surface Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Second stage to bring returns to surface and finalize set on surface conductor. Pump 175 sacks for 15.7 ppg slurry. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Surface Cement AS1 37.0 75.0 175 B Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 15.70 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 10/6/2015 • • Cement Detail Report 1C-152 f+tiElips String: Surface Cement Job: DRILLING ORIGINAL, 8/21/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Cement 8/28/2015 14:00 8/28/2015 18:06 1C-152 Comment With SLB pump 5 BBL of CW100 and test lines to 3500 psi for 6 minutes. Pump 75.4 BBL total of CW100. Batch and pump 76.6 BBL of 10.5 ppg MudPush II with 2 gallons of red dye. Pump 483.4 BBL of 11 ppg cement Lead(256%of gauge hole above the permafrost, 1451 sacks, 1.87 yield, 6.491 gal/sk),followed by 65.4 BBLs of 12.0 ppg Tail(227 sacks, 16.2 yield,5.461 gal/sk). The plug bumped on 2510 strokes 364 psi and held 965 psi for and the float held. Bled back 1.4 BBL when bleeding off pressure from bumping plug. 16 BBLs of 11.0 ppg cement back to surface with cement in place at 18:06, 8/28.There was a loss of 35 BBLS throughout the cement job. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Cement 119.0 2,813.0 No 16.0 Yes Yes Q Pump Mit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 7 7 364.0 364.0 Yes No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment With SLB pump 5 BBL of CW100 and test lines to 3500 psi for 6 minutes. Pump 75.4 BBL total of CW100. Batch and pump 76.6 BBL of 10.5 ppg MudPush II with 2 gallons of red dye. Pump 483.4 BBL of 11 ppg cement Lead(256%of gauge hole above the permafrost, 1451 sacks, 1.87 yield, 6.491 gal/sk),with 65.4 BBLs of 12.0 ppg Tail(227 sacks, 16.2 yield, 5.461 gal/sk). The plug bumped on 2510 strokes 364 psi and held 965 psi for and the float held. 16 BBLs of 11.0 ppg cement back to surface with cement in place at 18.06,8/28.There was a loss of 35 BBLS throughout the cement job. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 42.0 2,307.0 1,451 LiteCrete 486.4 Yield(ft'/sack) Mix 1-120 Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.87 6.49 11.00 5.20 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.07 gal/sx Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,307.0 2,813.0 227 LiteCrete 227.0 Yield(fV/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.62 5.46 12.00 3.80 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.07 gal/sx Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Page 1/1 Report Printed: 10/6/2015 • • Ow 4 Cement Detail Report 1C-152 W'dlbps_ Atatlaa String: Surface top out Job: DRILLING ORIGINAL, 8/21/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface top out 8/29/2015 14:38 8/29/2015 17:05 1C-152 Comment PJSM for top job cementing with crew on running 3/4"pipe into the 20"x 10-3/4"annulus through Vetco gray hanger flutes. PU 3/4"top job pipe and run in the 20"x 10 3/4"annulus to refusal at 77'below the landing ring. Clean out cellar with SS truck.Continue to MU 3/4"pipe and run in annulus on DS to 76.82'and run second string on ODS to 77.08'. Rig up manifold and fittings to pipe strings. Check the pipe with pumping water and clean annulus by pumping 38 BBL. Rig up to Dowell cementers. PJSM on pumping top job through(2)3/4"lines run into the 20"x 10-3/4"annulus to 77'below the starting ring. SLB pressure test lines with 2 BBL water to 700 psi;Good. Pump 20 BBL water at 1.3 BPM with 100-200 psi. Shut down. Batch11.0 ppg LiteCrete cement(1.88 cuft/sk, Mix water 6.543 gal/sk,thickening time 4 hr 15 min)(.2%BWOB D046 antifoam, .07 gal/sk Dispersant, .05 gal/sk D186 Accelerator) and pumped 35.2 BBL(105.1 sk). ICP=300 psi @ 1.7 BPM, FCP=125 @ 1 BPM. At 24.1 BBL pumped 11.0 ppg cement was returned to surface. Pumped 35.2 BBLs total. Cement Top Job witnessed by AOGCC rep Bob Noble. CIP 17:05 8/29/15 RD and pull 3/4"pipe,flush and clean pipe and rigging. LD 3/4"pipe. Monitor and strap TOC on 15 minute intervals. Clean out cellar box of cement. Remove 4"riser from conductor. Prep for NU of BOPE©2130 hrs 8/29/2015.. Last measure of TOC 5'below landing ring. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface top out Top job on surface 47.0 119.0 Yes 11.1 No No cement. Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 2 1 1 125.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Primary cement TOC fell to 77'below the landing ring. PJSM for top job cementing with crew on running 3/4"pipe into the 20"x 10-3/4"annulus through Vetco gray hanger flutes. PU 3/4"top job pipe and run in the 20"x 10 3/4"annulus to refusal at 77'below the landing ring. Clean out cellar with SS truck.Continue to MU 3/4"pipe and run in annulus on DS to 76.82'and run second string on ODS to 77.08'. Rig up manifold and fittings to pipe strings. Check the pipe with pumping water and clean annulus by pumping 38 BBL. Rig up to Dowell cementers. PJSM on pumping top job through(2)3/4"lines run into the 20"x 10-3/4"annulus to 77'below the starting ring. SLB pressure test lines with 2 BBL water to 700 psi;Good. Pump 20 BBL water at 1.3 BPM with 100-200 psi. Shut down. Batch11.0 ppg LiteCrete cement(1.88 cuft/sk, Mix water 6.543 gal/sk,thickening time 4 hr 15 min)(.2%BWOB D046 antifoam, .07 gal/sk Dispersant, .05 gal/sk D186 Accelerator) and pumped 35.2 BBL(105.1 sk). ICP=300 psi @ 1.7 BPM, FCP= 125 @ 1 BPM. At 24.1 BBL pumped 11.0 ppg cement was returned to surface. Pumped 35.2 BBLs total. Cement Top Job witnessed by AOGCC rep Bob Noble. CIP 17:05 8/29/15 RD and pull 3/4"pipe,flush and clean pipe and rigging. LD 3/4"pipe. Monitor and strap TOC on 15 minute intervals. Clean out cellar box of cement. Remove 4"riser from conductor. Prep for NU of BOPE @ 2130 hrs 8/29/2015.. Last measure of TOC 5'below landing ring. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Water flush 58.0 Yield(fV/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 8.34 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Surface Cement-Top 45.0 119.0 105 LiteCRETE 35.2 Job Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.88 6.54 11.00 4.25 Additives Additive Type Concentration Conc Unit label D186 Accelerator 0.05 gal/sx Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOB Additive Type Concentration Conc Unit label D185 Dispersant 0.07 gal/sx Page 1/1 Report Printed: 10/6/2015 • • Cement Detail Report 45119:011A g"It 1C-152 Qm000thillips AY 6a String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 8/21/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 9/2/2015 15:30 9/2/2015 18.00 1C-152 Comment R/U SLB and pressure test lines with water to 3500 psi for 10 minutes charted. Pumped 40.3 bbl 11.5 ppg MudPush II spacer. Drop bottom plug, pump 46 bbl 15.8 ppg Tail D177 retarded cement @ 5.3-6.4 bpm,follow with 51.5 bbl 15.8 ppg non-retarded Tail slurry @ 5-6.4 bpm. Drop top plug and kick out with 10.3 bbl water from SLB unit. Displace with rig pumps @ 6 bpm, 114 psi ICP, 1035 psi FCP 13%flow out. Reduce rate to 3 bpm @ 202 bbl away,850 psi 10%flow out. Plug on seat©2112 stks, pressure up to 1400 psi and hold for 5 min.Bleed off pressure and check floats-good. Bled off 1.2 bbl to trip tank. Losses for cement job=0 bbl. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Cement 7-5/8"casing 2,932.0 4,945.0 Yes Yes Yes Cement and 500'above the Ugnu C Q Pump!nit(bbllm...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 6 6 800.0 1,400.0 Yes 16.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pumped 40.3 bbl 11.5 ppg MudPush II spacer. Drop bottom plug, pump 46 bbl 15.8 ppg Tail D177 retarded cement @ 5.3-6.4 bpm,follow with 51.5 bbl 15.8 ppg non-retarded Tail slurry©5-6.4 bpm. Drop top plug and kick out with 10.3 bbl water from SLB unit. Displace with rig pumps @ 6 bpm, 114 psi ICP, 1035 psi FCP 13%flow out. Reduce rate to 3 bpm @ 202 bbl away, 850 psi 10%flow out. Plug on seat @ 2112 stks, pressure up to 1400 psi and hold for 5 min.Bleed off pressure and check floats-good.Bled off 1.2 bbl to trip tank. Losses for cement job=0 bbl. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement with 2,932.0 3,934.0 222 G 46.0 extra retarder Yield(W/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 134.0 5.25 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.04 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 3,934.0 4,945.0 249 G 51.5 Yield(fP/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa's) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 134.0 5.25 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Page 1/1 Report Printed: 10/6/2015 • • Cement Detail Report W`F s r 1C-152 Corw000Phithips String: Remedial Cement Squeeze Job: DRILLING ORIGINAL, 8/21/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Remedial Cement Squeeze 9/5/2015 09:30 9/5/2015 13.45 1C-152 Comment SLB pumped 3 bbl 11.5 ppg MudPush, PT lines to 600 low/3000 psi hi. Pumped total 20.4 bbl of 11.5 ppg MudPush, insert wiper ball(6"wiper ball, had to cut down due wrong size), SLB pmped 25.4 bbl 15.8 ppg Tail Cement,followed with 5.7 bbl 11.5 ppg MudPush and 1.5 bbl of water to get MudPush to the floor. Blow down to cementers. Pull up hole 8 stands to 4206'MD,circulate 1.5 bottoms up then commence squeeze operations. Open kill line and pump to remove air, Close annular and perform hesitation squeeze, pumping down DP and Kill line.Rig pumped to squeeze cement @ .5 bpm. Squeeze#1-Pumped 4.23 bbl to achieve 687 psi,shut in hold 10 min, pressure bled off to 449 psi.(OA=700 psi) Squeeze#2-Pumped additional 1 bbl to bump up from 449 psi to 687 psi,shut in and hold ten minutes dropped to 582 psi.#3-Pumped.6 bbl(5.8 total)to bump up pressure from 582 to 687 psi.Shut in 10 minutes and pressure dropped to 494 psi. (OA=700)#4-Another.6 bbl(6.4 total)to bump up from 494 to 687 psi,shut in 16 min-dropped to 449 psi.#5-Increased prerssure to 730 psi, pumped.85 bbl(7.25 total)bump from 449 psi to 730 psi. Shut in and hold 10 minutes, bled off to 526 psi. Bled off annular pressure,bled back 1.2 bbl,total cement sqeezed away=6.05 bbl Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Remedial Cement Squeeze intermediate 4,292.0 4,965.0 No No No Squeeze shoe for satisfactory FIT Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 6 5 333.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment SLB pumped 20.4 bbl 11.5 ppg Mud Push,25.4 bbl 15.8 ppg tail cement. Rig displaced with 35 bbl as balanced plug, pulled out 8 stands to 4206'MD and applied 687 psi squeeze pressure(13.0 ppg EMW)4 times,then 730(13.2 ppg EMW)psi one time.Total volume cement squeezed away 6.05 bbl. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 4,292.0 4,965.0 122 G 25.4 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa-s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.08 15.80 108.0 0.00 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.015 gal/sx Page 1/1 Report Printed: 10/6/2015 t I Loepp, Victoria T (DOA) From: Lee, David L <David.L.Lee@conocophillips.com> Sent: Wednesday, October 01, 2014 5:25 PM To: Loepp, Victoria L(DOA) Cc: Hallford, Kelsey Subject: RE: KRU 1D-142(PTD 214-149)West Sak Follow Up Flag: Follow up Flag Status: Completed Hi Victoria, answers to questions are below: 1. 1D-142 did not fail anti-collision with 1D-12, it just failed with 1D-117. Did you have a different question regarding 1D-12. 1D-117 went through the Tolerable Collision Risk(TCR) process which is a ConocoPhillips Alaska process. This process accesses the risk of what would happen if we collided with the well that is a concern,and if the risk is deemed acceptable (based on NPV and environmental and safety risks)then the well can be drilled. 1D-117 is an active injector, but ConocoPhillips is going to shut this well in prior to starting drilling 1D-142 and it will stay shut in for the entire length of drilling the well. Since the well will be shut in there will be no risk of a well control issue because if 1D-117 is hit we would be colliding with the well with kill weight fluid in the hole. 2. 1 0 • Roa d E O S_ 1—a — 1 1= ; 411 Also,just let me know if there are any other questions or concerns. You can give me a shout to discuss also. 907-263-3741 is my desk Thanks David Lee From: Loepp, Victoria L(DOA) [mailto:victoria.loepp(aalaska.gov] Sent: Wednesday, October 01, 2014 3:02 PM To: Lee, David L Subject: [EXTERNAL]KRU 1D-142(PTD 214-149) West Sak David, 1. Anti-collision analysis: 1D-117, 1D-12 laterals are major risk failures that are now pass-minor. Please explain this process. What steps will be taken with these wells to mitigate risk of collision during drilling 10-142? 2. Please provide a pad schematic showing the rig at the well location and the route of the diverter line including approximate lengths. 3. Area of Review:Why aren't the mechanical conditions of the West Sak wells reviewed?For the cement jobs on the 1D wells,did the cement jobs go as planned? Plugs bumped,floats held? For Well 1D-12, is there cement data available? Thanx in advance for addressing these questions, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusor, 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 Victoria Ferguson at(907)793-1247 or Victoria.Ferguson@alaska.gov 3 • • 215114 26361 Schlumberger . +gg Drilling & Measurements Transmittal#: 150CT15-SPO1 DATA LOGGED MWD/LWD Log Product Delivery `0/2.242015 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1C-152 Date Dispatched: 15-Oct-15 Job#: 15AKA0093 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2"MD x x Scope Resistivity 2'TVD x x Scope Resistivity 5'MD x x Scope Resistivity 5'TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgarico(a�conocophillips.com AlaskaPTSPrintCenterslb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 Received By: iLI✓w ,- / �„ ,�� • 215114 26361 FINAL NADConversion Kuparuk River Unit Kuparuk 1C Pad 1C-152 OCT 1 5 :.. AOGCL Definitive Survey Report 23 September, 2015 NAD 27 o‘c)06°'',-- \,\C lam' • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: Grid Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States 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 1C-152 Well Position +N/-S 0.00 usft Northing: 5,968,956.10 usfi Latitude: 70° 19'32.591 N +E/-W 0.00 usft Easting: 561,869.93 usfi Longitude: 149°29'53.846 W Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 57.60 usft Wellbore 1C-152 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2015 8/25/2015 19.00 80.99 57,507 Design 1C-152 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.97 Vertical Section: Depth From(TVD) +NI-S +EI-W Direction (usft) (usft) (usft) (°) 39.97 0.00 0.00 344.53 Survey Program Date From To )' L,•‘S; _•': :, (usft) (usft) Survey(Wellbore) Tool'Name '" `'"Description Survey Date 83.03 1,965.03 1C-152 Srvy#1 GYD-GC-SS(1C-152) GYD-GC-SS Gyrodata gyro single shots 8/26/2015 9:0. 2,023.14 2,734.01 1C-152 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 12:5E 2,833.47 2,833.47 1C-152 Srvy#3 INC+TREND(1C-152) INC+TREND Inclinometer+known azi trend 9/1/2015 1:00. 2,863.03 4,882.60 1C-152 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 1:01 4,882.60 12,345.49 1C-152 Srvy#5 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 1:03, 12,406.00 12,406.00 1C-152 Srvy#6-Projection to TD(1C-1:BLIND Blind drilling 9/23/2015 2:3: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section Lw (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.97 0.00 0.00 39.97 -57.60 0.00 0.00 5,968,956.10 561,869.93 0.00 0.00 UNDEFINED 123.00 0.30 70.14 123.00 25.43 0.07 0.20 5,968,956.17 561,870.13 0.36 0.02 GYD-GC-SS(1) NOT an ActualSurv€ 20"x 42" 171.30 0.47 70.14 171.30 73.73 0.18 0.51 5,968,956.28 561,870.44 0.36 0.04 GYD-GC-SS(1) 265.73 0.84 76.14 265.72 168.15 0.48 1.54 5,968,956.58 561,871.47 0.40 0.05 GYD-GC-SS(1) 361.07 1.08 38.50 361.05 263.48 1.35 2.78 5,968,957.45 561,872.71 0.69 0.56 GYD-GC-SS(1) 453.55 2.91 20.76 453.47 355.90 4.23 4.16 5,968,960.33 561,874.09 2.07 2.97 GYD-GC-SS(1) 547.56 5.02 15.43 547.25 449.68 10.43 6.10 5,968,966.52 561,876.03 2.28 8.42 GYD-GC-SS(1) 640.05 6.88 8.16 639.24 541.67 19.81 7.96 5,968,975.91 561,877.89 2.17 16.97 GYD-GC-SS(1) 733.46 8.50 4.13 731.81 634.24 32.24 9.25 5,968,988.33 561,879.18 1.83 28.60 GYD-GC-SS(1) 9/23/2015 2:54:57PM Page 2 COMPASS 5000.1 Build 74 0 Schlumberger IP Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: Grid Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 828.16 10.55 4.66 825.20 727.63 47.86 10.46 5,969,003.95 561,880.39 2.17 43.33 GYD-GC-SS(1) 922.47 11.03 3.67 917.84 820.27 65.47 11.74 5,969,021.56 561,881.67 0.55 59.96 GYD-GC-SS(1) 1,017.36 13.56 9.67 1,010.55 912.98 85.50 14.19 5,969,041.59 561,884.12 2.98 78.61 GYD-GC-SS(1) 1,112.15 15.72 17.21 1,102.26 1,004.69 108.72 19.86 5,969,064.81 561,889.78 3.03 99.49 GYD-GC-SS(1) 1,205.91 16.00 18.92 1,192.46 1,094.89 133.08 27.80 5,969,089.17 561,897.73 0.58 120.84 GYD-GC-SS(1) 1,300.08 16.76 18.40 1,282.80 1,185.23 158.24 36.30 5,969,114.32 561,906.23 0.82 142.82 GYD-GC-SS(1) 1,394.89 20.49 24.35 1,372.64 1,275.07 186.34 47.46 5,969,142.42 561,917.39 4.41 166.93 GYD-GC-SS(1) 1,490.51 22.51 26.82 1,461.60 1,364.03 217.93 62.62 5,969,174.00 561,932.55 2.31 193.33 GYD-GC-SS(1) 1,585.67 22.81 26.63 1,549.42 1,451.85 250.67 79.11 5,969,206.75 561,949.03 0.32 220.49 GYD-GC-SS(1) 1,680.58 26.89 26.68 1,635.52 1,537.95 286.31 97.00 5,969,242.38 561,966.92 4.30 250.06 GYD-GC-SS(1) 1,775.24 30.45 28.22 1,718.56 1,620.99 326.58 117.96 5,969,282.65 561,987.88 3.84 283.29 GYD-GC-SS(1) 1,868.28 33.61 29.35 1,797.43 1,699.86 369.81 141.74 5,969,325.88 562,011.65 3.46 318.61 GYD-GC-SS(1) 1,964.34 34.33 33.78 1,877.11 1,779.54 415.51 169.83 5,969,371.57 562,039.75 2.68 355.16 GYD-GC-SS(1) 2,069.71 34.04 37.80 1,964.28 1,866.71 463.51 204.43 5,969,419.57 562,074.34 2.16 392.19 MWD+IFR-AK-CAZ-SC(2) 2,117.93 29.94 37.81 2,005.17 1,907.60 483.69 220.09 5,969,439.75 562,090.00 8.50 407.47 MWD+IFR-AK-CAZ-SC(2) 2,162.76 27.40 38.01 2,044.50 1,946.93 500.66 233.30 5,969,456.71 562,103.21 5.67 420.30 MWD+IFR-AK-CAZ-SC(2) 2,211.99 24.44 37.68 2,088.78 1,991.21 517.65 246.51 5,969,473.70 562,116.41 6.02 433.15 MWD+IFR-AK-CAZ-SC(2) 2,260.94 22.73 37.11 2,133.64 2,036.07 533.21 258.40 5,969,489.26 562,128.31 3.52 444.97 MWD+IFR-AK-CAZ-SC(2) 2,307.42 23.46 37.34 2,176.39 2,078.82 547.73 269.43 5,969,503.77 562,139.34 1.58 456.02 MWD+IFR-AK-CAZ-SC(2) 2,402.27 19.48 44.14 2,264.66 2,167.09 574.10 291.91 5,969,530.15 562,161.81 4.94 475.44 MWD+IFR-AK-CAZ-SC(2) 2,448.74 16.86 49.90 2,308.81 2,211.24 584.00 302.46 5,969,540.05 562,172.37 6.83 482.17 MWD+IFR-AK-CAZ-SC(2) 2,496.69 17.04 50.41 2,354.67 2,257.10 592.96 313.20 5,969,549.00 562,183.10 0.49 487.94 MWD+IFR-AK-CAZ-SC(2) 2,591.82 16.21 48.07 2,445.83 2,348.26 610.72 333.82 5,969,566.76 562,203.72 1.12 499.55 MWD+IFR-AK-CAZ-SC(2) 2,686.65 16.21 42.09 2,536.89 2,439.32 629.38 352.54 5,969,585.42 562,222.44 1.76 512.55 MWD+IFR-AK-CAZ-SC(2) 2,733.32 16.23 41.68 2,581.71 2,484.14 639.09 361.24 5,969,595.13 562,231.14 0.25 519.58 MWD+IFR-AK-CAZ-SC(2) 2,807.70 17.37 38.34 2,652.91 2,555.34 655.56 375.04 5,969,611.60 562,244.94 2.01 531.78 MWD+IFR-AK-CAZ-SC(4) 103/4"x13-112 NOT an Actual Survey 2,957.15 19.81 32.80 2,794.56 2,696.99 694.36 402.61 5,969,650.39 562,272.50 2.01 561.82 MWD+IFR-AK-CAZ-SC(4) 3,051.78 23.27 26.74 2,882.58 2,785.01 724.55 419.71 5,969,680.58 562,289.60 4.34 586.35 MWD+IFR-AK-CAZ-SC(4) 3,146.91 26.47 19.93 2,968.90 2,871.33 761.28 435.40 5,969,717.30 562,305.29 4.51 617.56 MWD+IFR-AK-CAZ-SC(4) 3,241.92 29.58 15.49 3,052.77 2,955.20 803.80 448.89 5,969,759.82 562,318.78 3.94 654.95 MWD+IFR-AK-CAZ-SC(4) 3,336.61 33.11 9.75 3,133.64 3,036.07 851.83 459.52 5,969,807.85 562,329.40 4.88 698.41 MWD+IFR-AK-CAZ-SC(4) 3,431.25 35.77 3.51 3,211.71 3,114.14 904.94 465.59 5,969,860.96 562,335.48 4.67 747.97 MWD+IFR-AK-CAZ-SC(4) 3,526.54 38.74 0.05 3,287.56 3,189.99 962.57 467.32 5,969,918.58 562,337.21 3.81 803.06 MWD+IFR-AK-CAZ-SC(4) 3,621.67 41.88 356.08 3,360.10 3,262.53 1,024.05 465.18 5,969,980.05 562,335.06 4.26 862.87 MWD+IFR-AK-CAZ-SC(4) 3,716.79 45.61 352.77 3,428.81 3,331.24 1,089.47 458.73 5,970,045.46 562,328.61 4.60 927.64 MWD+IFR-AK-CAZ-SC(4) 3,811.79 48.58 352.63 3,493.48 3,395.91 1,158.48 449.89 5,970,114.47 562,319.77 3.13 996.52 MWD+IFR-AK-CAZ-SC(4) 3,906.65 52.35 352.83 3,553.85 3,456.28 1,231.04 440.63 5,970,187.02 562,310.52 3.98 1,068.92 MWD+IFR-AK-CAZ-SC(4) 4,001.58 56.60 352.87 3,609.00 3,511.43 1,307.68 431.02 5,970,263.66 562,300.91 4.48 1,145.34 MWD+IFR-AK-CAZ-SC(4) 4,097.38 61.40 352.41 3,658.33 3,560.76 1,389.10 420.50 5,970,345.06 562,290.39 5.03 1,226.62 MWD+IFR-AK-CAZ-SC(4) 9/23/2015 2:54:57PM Page 3 COMPASS 5000.1 Build 74 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: Grid Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 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 4,150.38 64.71 352.39 3,682.34 3,584.77 1,435.92 414.25 5,970,391.89 562,284.14 6.25 1,273.41 MWD+IFR-AK-CAZ-SC(4) 4,191.55 67.11 352.56 3,699.14 3,601.57 1,473.18 409.33 5,970,429.14 562,279.22 5.84 1,310.63 MWD+IFR-AK-CAZ-SC(4) 4,238.80 70.16 352.56 3,716.36 3,618.79 1,516.81 403.63 5,970,472.76 562,273.52 6.46 1,354.20 MWD+IFR-AK-CAZ-SC(4) 4,286.46 71.71 352.40 3,731.92 3,634.35 1,561.46 397.74 5,970,517.42 562,267.63 3.27 1,398.81 MWD+IFR-AK-CAZ-SC(4) 4,381.61 75.93 350.68 3,758.43 3,660.86 1,651.83 384.28 5,970,607.77 562,254.18 4.76 1,489.49 MWD+IFR-AK-CAZ-SC(4) 4,427.43 77.27 350.97 3,769.05 3,671.48 1,695.83 377.18 5,970,651.76 562,247.07 2.99 1,533.79 MWD+IFR-AK-CAZ-SC(4) 4,476.22 79.00 350.21 3,779.08 3,681.51 1,742.93 369.37 5,970,698.86 562,239.27 3.86 1,581.27 MWD+IFR-AK-CAZ-SC(4) 4,571.39 79.65 348.59 3,796.71 3,699.14 1,834.85 352.17 5,970,790.78 562,222.06 1.81 1,674.45 MWD+IFR-AK-CAZ-SC(4) 4,666.26 79.99 345.67 3,813.48 3,715.91 1,925.87 331.37 5,970,881.79 562,201.27 3.05 1,767.72 MWD+IFR-AK-CAZ-SC(4) 4,760.37 80.38 345.52 3,829.53 3,731.96 2,015.69 308.30 5,970,971.60 562,178.20 0.44 1,860.43 MWD+IFR-AK-CAZ-SC(4) 4,852.24 84.15 344.91 3,841.89 3,744.32 2,103.69 285.07 5,971,059.59 562,154.98 4.16 1,951.45 MWD+IFR-AK-CAZ-SC(4) 4,882.60 85.30 344.93 3,844.68 3,747.11 2,132.88 277.21 5,971,088.78 562,147.11 3.79 1,981.68 MWD+IFR-AK-CAZ-SC(4) 4,934.80 86.99 345.40 3,848.19 3,750.62 2,183.23 263.87 5,971,139.12 562,133.78 3.36 2,033.75 MWD+IFR-AK-CAZ-S .(51 7-5/8"x 9-7/8" NOT an Actual Sur 4,976.01 88.32 345.77 3,849.88 3,752.31 2,223.11 253.62 5,971,178.99 562,123.53 3.36 2,074.92 MWD+IFR-AK-CAZ-Sl.(o) 4,987.58 88.63 345.85 3,850.19 3,752.62 2,234.32 250.79 5,971,190.20 562,120.70 2.77 2,086.48 MWD+IFR-AK-CAZ-SC(5) 5,081.84 90.89 344.18 3,850.58 3,753.01 2,325.36 226.42 5,971,281.24 562,096.33 2.98 2,180.73 MWD+IFR-AK-CAZ-SC(5) 5,176.97 91.47 343.45 3,848.62 3,751.05 2,416.70 199.91 5,971,372.57 562,069.82 0.98 2,275.83 MWD+IFR-AK-CAZ-SC(5) 5,272.12 91.58 342.48 3,846.09 3,748.52 2,507.64 172.05 5,971,463.51 562,041.96 1.03 2,370.91 MWD+IFR-AK-CAZ-SC(5) 5,366.78 90.99 343.25 3,843.97 3,746.40 2,598.08 144.17 5,971,553.93 562,014.08 1.02 2,465.51 MWD+IFR-AK-CAZ-SC(5) 5,461.27 91.03 343.53 3,842.30 3,744.73 2,688.61 117.16 5,971,644.46 561,987.08 0.30 2,559.96 MWD+IFR-AK-CAZ-SC(5) 5,556.47 90.86 343.76 3,840.73 3,743.16 2,779.95 90.36 5,971,735.78 561,960.28 0.30 2,655.14 MWD+IFR-AK-CAZ-SC(5) 5,651.78 90.93 344.72 3,839.24 3,741.67 2,871.66 64.48 5,971,827.49 561,934.40 1.01 2,750.43 MWD+IFR-AK-CAZ-SC(5) 5,745.67 90.89 344.18 3,837.75 3,740.18 2,962.11 39.31 5,971,917.92 561,909.24 0.58 2,844.31 MWD+IFR-AK-CAZ-SC(5) 5,841.20 90.31 344.86 3,836.75 3,739.18 3,054.16 13.81 5,972,009.97 561,883.74 0.94 2,939.83 MWD+IFR-AK-CAZ-SC(5) 5,935.76 89.83 344.25 3,836.63 3,739.06 3,145.31 -11.37 5,972,101.11 561,858.56 0.82 3,034.39 MWD+IFR-AK-CAZ-SC(5) 6,029.96 89.90 344.62 3,836.86 3,739.29 3,236.05 -36.64 5,972,191.84 561,833.29 0.40 3,128.59 MWD+IFR-AK-CAZ-SC(5) 6,125.21 90.03 345.30 3,836.91 3,739.34 3,328.04 -61.36 5,972,283.82 561,808.58 0.73 3,223.84 MWD+IFR-AK-CAZ-SC(5) 6,219.78 89.90 346.29 3,836.97 3,739.40 3,419.72 -84.56 5,972,375.49 561,785.37 1.06 3,318.39 MWD+IFR-AK-CAZ-SC(5) 6,314.78 89.86 347.32 3,837.17 3,739.60 3,512.21 -106.25 5,972,467.97 561,763.69 1.09 3,413.31 MWD+IFR-AK-CAZ-SC(5) 6,409.37 89.86 347.67 3,837.40 3,739.83 3,604.55 -126.73 5,972,560.31 561,743.21 0.37 3,507.77 MWD+IFR-AK-CAZ-SC(5) 6,504.15 90.21 348.26 3,837.34 3,739.77 3,697.25 -146.49 5,972,653.00 561,723.45 0.72 3,602.38 MWD+IFR-AK-CAZ-SC(5) 6,599.66 90.14 348.75 3,837.05 3,739.48 3,790.84 -165.52 5,972,746.58 561,704.42 0.52 3,697.66 MWD+IFR-AK-CAZ-SC(5) 6,694.55 90.17 348.05 3,836.80 3,739.23 3,883.80 -184.60 5,972,839.52 561,685.35 0.74 3,792.33 MWD+IFR-AK-CAZ-SC(5) 6,789.67 90.14 346.49 3,836.54 3,738.97 3,976.57 -205.56 5,972,932.29 561,664.39 1.64 3,887.34 MWD+IFR-AK-CAZ-SC(5) 6,884.12 90.21 346.08 3,836.25 3,738.68 4,068.33 -227.95 5,973,024.04 561,642.00 0.44 3,981.75 MWD+IFR-AK-CAZ-SC(5) 6,978.13 89.90 346.40 3,836.16 3,738.59 4,159.64 -250.31 5,973,115.35 561,619.64 0.47 4,075.71 MWD+IFR-AK-CAZ-SC(5) 7,074.57 89.48 345.23 3,836.68 3,739.11 4,253.14 -273.94 5,973,208.83 561,596.01 1.29 4,172.13 MWD+IFR-AK-CAZ-SC(5) 7,168.63 90.58 344.08 3,836.63 3,739.06 4,343.84 -298.83 5,973,299.53 561,571.12 1.69 4,266.18 MWD+IFR-AK-CAZ-SC(5) 7,263.53 91.85 342.49 3,834.62 3,737.05 4,434.71 -326.12 5,973,390.38 561,543.84 2.14 4,361.04 MWD+IFR-AK-CAZ-SC(5) 9/23/2015 2:54:57PM Page 4 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: Grid Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,358.34 91.51 342.43 3,831.84 3,734.27 4,525.07 -354.68 5,973,480.74 561,515.28 0.36 4,455.74 MWD+IFR-AK-CAZ-SC(5) 7,453.22 91.96 341.86 3,828.97 3,731.40 4,615.34 -383.76 5,973,571.00 561,486.21 0.77 4,550.50 MWD+IFR-AK-CAZ-SC(5) 7,548.45 91.92 341.39 3,825.74 3,728.17 4,705.66 -413.76 5,973,661.31 561,456.21 0.50 4,645.55 MWD+IFR-AK-CAZ-SC(5) 7,643.66 91.30 342.14 3,823.07 3,725.50 4,796.06 -443.54 5,973,751.70 561,426.43 1.02 4,740.61 MWD+IFR-AK-CAZ-SC(5) 7,738.48 90.21 343.64 3,821.82 3,724.25 4,886.67 -471.43 5,973,842.30 561,398.55 1.96 4,835.38 MWD+IFR-AK-CAZ-SC(5) 7,832.79 90.51 345.41 3,821.23 3,723.66 4,977.55 -496.59 5,973,933.18 561,373.39 1.90 4,929.68 MWD+IFR-AK-CAZ-SC(5) 7,927.82 90.34 344.62 3,820.52 3,722.95 5,069.35 -521.16 5,974,024.96 561,348.82 0.85 5,024.71 MWD+IFR-AK-CAZ-SC(5) 7,979.73 89.04 343.21 3,820.80 3,723.23 5,119.22 -535.54 5,974,074.83 561,334.44 3.69 5,076.61 MWD+IFR-AK-CAZ-SC(5) 8,022.94 87.77 342.65 3,822.01 3,724.44 5,160.51 -548.22 5,974,116.12 561,321.76 3.21 5,119.78 MWD+IFR-AK-CAZ-SC(5) 8,117.49 87.90 341.37 3,825.58 3,728.01 5,250.37 -577.40 5,974,205.97 561,292.59 1.36 5,214.17 MWD+IFR-AK-CAZ-SC(5) 8,212.82 87.94 344.33 3,829.04 3,731.47 5,341.40 -605.49 5,974,296.98 561,264.50 3.10 5,309.39 MWD+IFR-AK-CAZ-SC(5) 8,307.00 89.49 347.06 3,831.15 3,733.58 5,432.62 -628.75 5,974,388.20 561,241.24 3.33 5,403.51 MWD+IFR-AK-CAZ-SC(5) 8,401.02 89.97 348.46 3,831.59 3,734.02 5,524.50 -648.68 5,974,480.07 561,221.31 1.57 5,497.38 MWD+IFR-AK-CAZ-SC(5) 8,496.48 90.41 347.72 3,831.28 3,733.71 5,617.90 -668.38 5,974,573.47 561,201.62 0.90 5,592.66 MWD+IFR-AK-CAZ-SC(5) 8,589.29 89.69 348.19 3,831.20 3,733.63 5,708.67 -687.75 5,974,664.22 561,182.25 0.93 5,685.30 MWD+IFR-AK-CAZ-SC(5) 8,685.55 89.90 348.92 3,831.54 3,733.97 5,803.02 -706.84 5,974,758.56 561,163.15 0.79 5,781.32 MWD+IFR-AK-CAZ-SC(5) 8,782.80 89.86 350.51 3,831.74 3,734.17 5,898.70 -724.21 5,974,854.24 561,145.79 1.64 5,878.17 MWD+IFR-AK-CAZ-SC(5) 8,877.01 89.97 351.18 3,831.88 3,734.31 5,991.71 -739.20 5,974,947.24 561,130.81 0.72 5,971.81 MWD+IFR-AK-CAZ-SC(5) 8,971.82 89.93 350.09 3,831.97 3,734.40 6,085.25 -754.62 5,975,040.77 561,115.38 1.15 6,066.08 MWD+IFR-AK-CAZ-SC(5) 9,067.25 89.93 348.51 3,832.08 3,734.51 6,179.02 -772.34 5,975,134.53 561,097.66 1.66 6,161.17 MWD+IFR-AK-CAZ-SC(5) 9,161.79 89.49 347.26 3,832.56 3,734.99 6,271.45 -792.18 5,975,226.95 561,077.83 1.40 6,255.55 MWD+IFR-AK-CAZ-SC(5) 9,255.98 89.42 345.86 3,833.46 3,735.89 6,363.06 -814.07 5,975,318.55 561,055.94 1.49 6,349.67 MWD+IFR-AK-CAZ-SC(5) 9,350.72 89.62 345.10 3,834.25 3,736.68 6,454.77 -837.82 5,975,410.25 561,032.19 0.83 6,444.40 MWD+IFR-AK-CAZ-SC(5) 9,446.13 89.42 344.04 3,835.05 3,737.48 6,546.73 -863.20 5,975,502.21 561,006.81 1.13 6,539.80 MWD+IFR-AK-CAZ-SC(5) 9,540.60 89.76 343.43 3,835.73 3,738.16 6,637.42 -889.66 5,975,592.89 560,980.35 0.74 6,634.26 MWD+IFR-AK-CAZ-SC(5) 9,636.88 89.31 342.44 3,836.51 3,738.94 6,729.46 -917.91 5,975,684.91 560,952.11 1.13 6,730.50 MWD+IFR-AK-CAZ-SC(5) 9,732.08 89.35 342.62 3,837.62 3,740.05 6,820.26 -946.49 5,975,775.71 560,923.53 0.19 6,825.63 MWD+IFR-AK-CAZ-SC(5) 9,825.67 89.38 342.08 3,838.66 3,741.09 6,909.44 -974.86 5,975,864.88 560,895.16 0.58 6,919.15 MWD+IFR-AK-CAZ-SC(5) 9,919.96 89.52 342.08 3,839.56 3,741.99 6,999.15 -1,003.87 5,975,954.58 560,866.15 0.15 7,013.35 MWD+IFR-AK-CAZ-SC(5) 10,014.56 90.03 342.65 3,839.94 3,742.37 7,089.30 -1,032.53 5,976,044.73 560,837.50 0.81 7,107.88 MWD+IFR-AK-CAZ-SC(5) 10,110.17 89.90 343.81 3,839.99 3,742.42 7,180.85 -1,060.12 5,976,136.26 560,809.92 1.22 7,203.46 MWD+IFR-AK-CAZ-SC(5) 10,205.84 90.00 344.73 3,840.08 3,742.51 7,272.93 -1,086.05 5,976,228.34 560,783.98 0.97 7,299.13 MWD+IFR-AK-CAZ-SC(5) 10,300.14 90.45 346.39 3,839.71 3,742.14 7,364.25 -1,109.57 5,976,319.65 560,760.47 1.82 7,393.41 MWD+IFR-AK-CAZ-SC(5) 10,397.27 89.28 346.93 3,839.94 3,742.37 7,458.76 -1,131.97 5,976,414.14 560,738.06 1.33 7,490.47 MWD+IFR-AK-CAZ-SC(5) 10,490.83 89.48 347.45 3,840.95 3,743.38 7,549.98 -1,152.72 5,976,505.36 560,717.32 0.60 7,583.93 MWD+IFR-AK-CAZ-SC(5) 10,585.64 88.83 346.55 3,842.35 3,744.78 7,642.35 -1,174.04 5,976,597.72 560,696.00 1.17 7,678.64 MWD+IFR-AK-CAZ-SC(5) 10,680.53 88.90 346.01 3,844.23 3,746.66 7,734.52 -1,196.54 5,976,689.88 560,673.50 0.57 7,773.46 MWD+IFR-AK-CAZ-SC(5) 10,774.67 89.55 345.12 3,845.50 3,747.93 7,825.67 -1,220.01 5,976,781.03 560,650.04 1.17 7,867.58 MWD+IFR-AK-CAZ-SC(5) 10,870.23 89.45 344.61 3,846.33 3,748.76 7,917.92 -1,244.95 5,976,873.26 560,625.10 0.54 7,963.13 MWD+IFR-AK-CAZ-SC(5) 10,962.96 90.03 344.04 3,846.75 3,749.18 8,007.20 -1,270.01 5,976,962.53 560,600.05 0.88 8,055.86 MWD+IFR-AK-CAZ-SC(5) 9/23/2015 2:54:57PM Page 5 COMPASS 5000.1 Build 74 SSchlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: Grid Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 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 11,055.17 89.90 342.92 3,846.81 3,749.24 8,095.60 -1,296.22 5,977,050.92 560,573.83 1.22 8,148.05 MWD+IFR-AK-CAZ-SC(5) 11,147.08 89.97 343.11 3,846.92 3,749.35 8,183.50 -1,323.07 5,977,138.82 560,546.98 0.22 8,239.93 MWD+IFR-AK-CAZ-SC(5) 11,240.29 89.97 343.61 3,846.96 3,749.39 8,272.81 -1,349.76 5,977,228.12 560,520.30 0.54 8,333.12 MWD+I FR-AK-CAZ-SC(5) 11,332.67 89.21 344.25 3,847.63 3,750.06 8,361.57 -1,375.33 5,977,316.87 560,494.73 1.08 8,425.49 MWD+IFR-AK-CAZ-SC(5) 11,425.77 88.90 343.07 3,849.16 3,751.59 8,450.90 -1,401.52 5,977,406.19 560,468.54 1.31 8,518.57 MWD+IFR-AK-CAZ-SC(5) 11,515.52 89.62 344.80 3,850.32 3,752.75 8,537.13 -1,426.35 5,977,492.42 560,443.71 2.09 8,608.30 MWD+IFR-AK-CAZ-SC(5) 11,607.85 89.62 343.95 3,850.93 3,753.36 8,626.05 -1,451.22 5,977,581.32 560,418.85 0.92 8,700.63 MWD+IFR-AK-CAZ-SC(5) 11,697.96 89.31 343.90 3,851.77 3,754.20 8,712.63 -1,476.17 5,977,667.90 560,393.90 0.35 8,790.73 MWD+IFR-AK-CAZ-SC(5) 11,791.11 89.04 344.14 3,853.11 3,755.54 8,802.17 -1,501.81 5,977,757.43 560,368.26 0.39 8,883.86 MWD+IFR-AK-CAZ-SC(5) 11,883.00 88.90 344.54 3,854.77 3,757.20 8,890.64 -1,526.61 5,977,845.89 560,343.47 0.46 8,975.74 MWD+IFR-AK-CAZ-SC(5) 11,973.26 88.36 343.30 3,856.92 3,759.35 8,977.34 -1,551.60 5,977,932.58 560,318.48 1.50 9,065.97 MWD+IFR-AK-CAZ-SC(5) 12,066.77 88.42 344.44 3,859.55 3,761.98 9,067.13 -1,577.57 5,978,022.37 560,292.51 1.22 9,159.43 MWD+IFR-AK-CAZ-SC(5) 12,158.68 87.26 343.39 3,863.02 3,765.45 9,155.38 -1,603.01 5,978,110.60 560,267.07 1.70 9,251.27 MWD+IFR-AK-CAZ-SC(5) 12,250.13 87.94 344.97 3,866.85 3,769.28 9,243.29 -1,627.92 5,978,198.50 560,242.17 1.88 9,342.63 MWD+IFR-AK-CAZ-SC(5) 12,345.49 88.42 345.40 3,869.87 3,772.30 9,335.43 -1,652.29 5,978,290.64 560,217.80 0.68 9,437.94 MWD+IFR-AK-CAZ-SC(5) 12,367.30 88.53 345.52 3,870.46 3,772.89 9,356.53 -1,657.76 5,978,311.74 560,212.33 0.75 9,459.74 BLIND(6) 4 1/2"x 6-3/4" NOT an Actual Survey 12,406.00 88.72 345.74 3,871.38 3,773.81 9,394.01 -1,667.36 5,978,349.21 560,202.73 0.75 9,498.42 Projection to TD Final Definitive Survey Verified and Signed off All targets and/or well position objectives have been achieved. Yes ❑ No I have checked to the best of my ability that the following data is correct: [2] Surface Coordinates R Declination & Convergence ❑ GRS Survey Corrections p Survey Tool Codes Vincent °q'""4 '"" '°ran a.0.. .n,Osa.., o-Schlunebirgss,Du-Seiu9. SLB DE: OSa ra .w"�""°"m"eo 139.10.-sired by Mom Client Representative: 12-- 20,s 'WADS Date: 23-Sep-2015 9/23/2015 2:54:57PM Page 6 COMPASS 5000.1 Build 74 i • X15114 16361 FINAL ConocoPhillips (Alaska) Inc. -Kup1 Kuparuk River Unit Kuparuk 1C Pad 1C-152 cam. \; o Definitive Survey Report 23 September, 2015 NAD 83 • Schlumberger 0 Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: True Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Project Kuparuk River Unit, North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 1C-152 Well Position +N/-S 0.00 usft Northing: 5,968,707.86 usfi Latitude: 70° 19'31.546 N +E/-W 0.00 usft Easting: 1,701,901.84 usfi Longitude: 149°30'5.025 W' Position Uncertainty 0.00 usft Wellhead Elevation: usfi Ground Level: 57.60 usft Wellbore 1C-152 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2015 8/25/2015 19.00 80.99 57,507 Design 1C-152 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.97 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.97 0.00 0.00 345.00 Survey Program Date 9/23/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 83.03 1,965.03 1C-152 Srvy#1 GYD-GC-SS(1C-152) GYD-GC-SS Gyrodata gyro single shots 8/26/2015 9:0, 2,023.14 2,734.01 1C-152 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 12:5E 2,833.47 2,833.47 1C-152 Srvy#3 INC+TREND(1C-152) INC+TREND Inclinometer+known azi trend 9/1/2015 1:00 2,863.03 4,882.60 1C-152 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 1:01. 4,882.60 12,345.49 1C-152 Srvy#5 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/1/2015 1:03, 12,406.00 12,406.00 1C-152 Srvy#6-Projection to TD(10-1°BLIND Blind drilling 9/23/2015 2:3: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 39.97 0.00 0.00 39.97 -57.60 0.00 0.00 5,968,707.86 1,701,901.84 0.00 0.00 UNDEFINED 123.00 0.30 70.61 123.00 25.43 0.07 0.20 5,968,707.93 1,701,902.04 0.36 0.02 GYD-GC-SS(1) NOT an Actual SurvE 20"x 42" 171.30 0.47 70.61 171.30 73.73 0.18 0.51 5,968,708.04 1,701,902.35 0.36 0.04 GYD-GC-SS(1) 265.73 0.84 76.61 265.72 168.15 0.47 1.55 5,968,708.34 1,701,903.38 0.40 0.05 GYD-GC-SS(1) 361.07 1.08 38.97 361.05 263.48 1.33 2.79 5,968,709.21 1,701,904.62 0.69 0.56 GYD-GC-SS(1) 453.55 2.91 21.23 453.47 355.90 4.19 4.19 5,968,712.09 1,701,905.99 2.07 2.97 GYD-GC-SS(1) 547.56 5.02 15.90 547.25 449.68 10.37 6.18 5,968,718.28 1,701,907.93 2.28 8.42 GYD-GC-SS(1) 640.05 6.88 8.63 639.24 541.67 19.74 8.12 5,968,727.67 1,701,909.80 2.17 16.97 GYD-GC-SS(1) 733.46 8.50 4.60 731.81 634.24 32.16 9.51 5,968,740.09 1,701,911.09 1.83 28.60 GYD-GC-SS(1) 9/23/2015 2:37:53PM Page 2 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: True Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 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 828.16 10.55 5.13 825.20 727.63 47.77 10.85 5,968,755.71 1,701,912.30 2.17 43.33 GYD-GC-SS(1) 922.47 11.03 4.14 917.84 820.27 65.37 12.27 5,968,773.32 1,701,913.58 0.55 59.96 GYD-GC-SS(1) 1,017.36 13.56 10.14 1,010.55 912.98 85.38 14.89 5,968,793.35 1,701,916.03 2.98 78.61 GYD-GC-SS(1) 1,112.15 15.72 17.68 1,102.26 1,004.69 108.55 20.75 5,968,816.57 1,701,921.69 3.03 99.49 GYD-GC-SS(1) 1,205.91 16.00 19.39 1,192.46 1,094.89 132.85 28.89 5,968,840.92 1,701,929.64 0.58 120.84 GYD-GC-SS(1) 1,300.08 16.76 18.87 1,282.80 1,185.23 157.94 37.59 5,968,866.08 1,701,938.13 0.82 142.82 GYD-GC-SS(1) 1,394.89 20.49 24.82 1,372.64 1,275.07 185.94 48.99 5,968,894.18 1,701,949.29 4.41 166.93 GYD-GC-SS(1) 1,490.51 22.51 27.29 1,461.60 1,364.03 217.40 64.40 5,968,925.76 1,701,964.45 2.31 193.33 GYD-GC-SS(1) 1,585.67 22.81 27.10 1,549.42 1,451.85 250.01 81.16 5,968,958.50 1,701,980.94 0.32 220.49 GYD-GC-SS(1) 1,680.58 26.89 27.15 1,635.52 1,537.95 285.50 99.34 5,968,994.14 1,701,998.83 4.30 250.06 GYD-GC-SS(1) 1,775.24 30.45 28.69 1,718.56 1,620.99 325.61 120.63 5,969,034.41 1,702,019.79 3.84 283.29 GYD-GC-SS(1) 1,868.28 33.61 29.82 1,797.43 1,699.86 368.64 144.76 5,969,077.64 1,702,043.56 3.46 318.61 GYD-GC-SS(1) 1,964.34 34.33 34.25 1,877.11 1,779.54 414.10 173.23 5,969,123.33 1,702,071.66 2.68 355.16 GYD-GC-SS(1) 2,069.71 34.04 38.27 1,964.28 1,866.71 461.82 208.23 5,969,171.33 1,702,106.25 2.16 392.19 MWD+IFR-AK-CAZ-SC(2) 2,117.93 29.94 38.28 2,005.17 1,907.60 481.87 224.05 5,969,191.51 1,702,121.91 8.50 407.47 MWD+IFR-AK-CAZ-SC(2) 2,162.76 27.40 38.48 2,044.50 1,946.93 498.73 237.40 5,969,208.47 1,702,135.12 5.67 420.30 MWD+IFR-AK-CAZ-SC(2) 2,211.99 24.44 38.15 2,088.78 1,991.21 515.61 250.74 5,969,225.46 1,702,148.32 6.02 433.15 MWD+IFR-AK-CAZ-SC(2) 2,260.94 22.73 37.58 2,133.64 2,036.07 531.07 262.76 5,969,241.02 1,702,160.22 3.52 444.97 MWD+IFR-AK-CAZ-SC(2) 2,307.42 23.46 37.81 2,176.39 2,078.82 545.50 273.91 5,969,255.53 1,702,171.25 1.58 456.02 MWD+IFR-AK-CAZ-SC(2) 2,402.27 19.48 44.61 2,264.66 2,167.09 571.69 296.61 5,969,281.90 1,702,193.72 4.94 475.44 MWD+IFR-AK-CAZ-SC(2) 2,448.74 16.86 50.37 2,308.81 2,211.24 581.51 307.24 5,969,291.81 1,702,204.27 6.83 482.17 MWD+IFR-AK-CAZ-SC(2) 2,496.69 17.04 50.88 2,354.67 2,257.10 590.37 318.05 5,969,300.76 1,702,215.01 0.49 487.94 MWD+IFR-AK-CAZ-SC(2) 2,591.82 16.21 48.54 2,445.83 2,348.26 607.96 338.81 5,969,318.52 1,702,235.62 1.12 499.55 MWD+IFR-AK-CAZ-SC(2) 2,686.65 16.21 42.56 2,536.89 2,439.32 626.47 357.68 5,969,337.18 1,702,254.34 1.76 512.55 MWD+IFR-AK-CAZ-SC(2) 2,733.32 16.23 42.15 2,581.71 2,484.14 636.11 366.47 5,969,346.89 1,702,263.05 0.25 519.58 MWD+IFR-AK-CAZ-SC(2) 2,807.70 17.37 38.81 2,652.91 2,555.34 652.47 380.40 5,969,363.36 1,702,276.85 2.01 531.78 MWD+IFR-AK-CAZ-SC(4) NOT an Actual Survey 10 3/4"x 13-1/2 2,957.15 19.81 33.27 2,794.56 2,696.99 691.04 408.29 5,969,402.15 1,702,304.41 2.01 561.82 MWD+IFR-AK-CAZ-SC(4) 3,051.78 23.27 27.21 2,882.58 2,785.01 721.08 425.64 5,969,432.33 1,702,321.51 4.34 586.35 MWD+IFR-AK-CAZ-SC(4) 3,146.91 26.47 20.40 2,968.90 2,871.33 757.68 441.63 5,969,469.06 1,702,337.20 4.51 617.56 MWD+IFR-AK-CAZ-SC(4) 3,241.92 29.58 15.96 3,052.77 2,955.20 800.09 455.46 5,969,511.58 1,702,350.69 3.94 654.95 MWD+IFR-AK-CAZ-SC(4) 3,336.61 33.11 10.22 3,133.64 3,036.07 848.04 466.48 5,969,559.61 1,702,361.31 4.88 698.41 MWD+IFR-AK-CAZ-SC(4) 3,431.25 35.77 3.98 3,211.71 3,114.14 901.10 472.99 5,969,612.71 1,702,367.39 4.67 747.97 MWD+IFR-AK-CAZ-SC(4) 3,526.54 38.74 0.52 3,287.56 3,189.99 958.71 475.20 5,969,670.34 1,702,369.12 3.81 803.06 MWD+IFR-AK-CAZ-SC(4) 3,621.67 41.88 356.55 3,360.10 3,262.53 1,020.20 473.55 5,969,731.80 1,702,366.97 4.26 862.87 MWD+IFR-AK-CAZ-SC(4) 3,716.79 45.61 353.24 3,428.81 3,331.24 1,085.67 467.64 5,969,797.22 1,702,360.52 4.60 927.64 MWD+IFR-AK-CAZ-SC(4) 3,811.79 48.58 353.10 3,493.48 3,395.91 1,154.76 459.36 5,969,866.23 1,702,351.68 3.13 996.52 MWD+IFR-AK-CAZ-SC(4) 3,906.65 52.35 353.30 3,553.85 3,456.28 1,227.39 450.71 5,969,938.78 1,702,342.43 3.98 1,068.92 MWD+IFR-AK-CAZ-SC(4) 4,001.58 56.60 353.34 3,609.00 3,511.43 1,304.11 441.72 5,970,015.42 1,702,332.82 4.48 1,145.34 MWD+IFR-AK-CAZ-SC(4) 4,097.38 61.40 352.88 3,658.33 3,560.76 1,385.61 431.87 5,970,096.82 1,702,322.30 5.03 1,226.62 MWD+IFR-AK-CAZ-SC(4) 9/23/2015 2:37:53PM Page 3 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: True Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 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 4,150.38 64.71 352.86 3,682.34 3,584.77 1,432.48 426.00 5,970,143.64 1,702,316.05 6.25 1,273.41 MWD+IFR-AK-CAZ-SC(4) 4,191.55 67.11 353.03 3,699.14 3,601.57 1,469.78 421.39 5,970,180.90 1,702,311.13 5.84 1,310.63 MWD+IFR-AK-CAZ-SC(4) 4,238.80 70.16 353.03 3,716.36 3,618.79 1,513.45 416.05 5,970,224.52 1,702,305.43 6.46 1,354.20 MWD+IFR-AK-CAZ-SC(4) 4,286.46 71.71 352.87 3,731.92 3,634.35 1,558.15 410.52 5,970,269.17 1,702,299.54 3.27 1,398.81 MWD+IFR-AK-CAZ-SC(4) 4,381.61 75.93 351.15 3,758.43 3,660.86 1,648.62 397.81 5,970,359.52 1,702,286.09 4.76 1,489.49 MWD+IFR-AK-CAZ-SC(4) 4,427.43 77.27 351.44 3,769.05 3,671.48 1,692.68 391.06 5,970,403.52 1,702,278.98 2.99 1,533.79 MWD+IFR-AK-CAZ-SC(4) 4,476.22 79.00 350.68 3,779.08 3,681.51 1,739.84 383.64 5,970,450.62 1,702,271.17 3.86 1,581.27 MWD+IFR-AK-CAZ-SC(4) 4,571.39 79.65 349.06 3,796.71 3,699.14 1,831.91 367.19 5,970,542.53 1,702,253.97 1.81 1,674.45 MWD+IFR-AK-CAZ-SC(4) 4,666.26 79.99 346.14 3,813.48 3,715.91 1,923.09 347.14 5,970,633.55 1,702,233.18 3.05 1,767.72 MWD+IFR-AK-CAZ-SC(4) 4,760.37 80.38 345.99 3,829.53 3,731.96 2,013.10 324.81 5,970,723.35 1,702,210.11 0.44 1,860.43 MWD+IFR-AK-CAZ-SC(4) 4,852.24 84.15 345.38 3,841.89 3,744.32 2,101.29 302.30 5,970,811.35 1,702,186.88 4.16 1,951.45 MWD+IFR-AK-CAZ-SC(4) 4,882.60 85.30 345.40 3,844.68 3,747.11 2,130.54 294.68 5,970,840.54 1,702,179.02 3.79 1,981.68 MWD+IFR-AK-CAZ-SC(4) 4,934.80 86.99 345.87 3,848.19 3,750.62 2,180.99 281.76 5,970,890.88 1,702,165.69 3.36 2,033.75 MWD+IFR-AK-CAZ- 7-5/8"x 9-7/8" NOT an Actual Sun 4,976.01 88.32 346.24 3,849.88 3,752.31 2,220.95 271.83 5,970,930.75 1,702,155.44 3.36 2,074.92 MWD+IFR-AK-CAZ- u( ) 4,987.58 88.63 346.32 3,850.19 3,752.62 2,232.19 269.09 5,970,941.96 1,702,152.60 2.77 2,086.48 MWD+IFR-AK-CAZ-SC(5) 5,081.84 90.89 344.65 3,850.58 3,753.01 2,323.43 245.47 5,971,033.00 1,702,128.24 2.98 2,180.73 MWD+IFR-AK-CAZ-SC(5) 5,176.97 91.47 343.92 3,848.62 3,751.05 2,414.98 219.71 5,971,124.33 1,702,101.73 0.98 2,275.83 MWD+IFR-AK-CAZ-SC(5) 5,272.12 91.58 342.95 3,846.09 3,748.52 2,506.15 192.59 5,971,215.26 1,702,073.87 1.03 2,370.91 MWD+IFR-AK-CAZ-SC(5) 5,366.78 90.99 343.72 3,843.97 3,746.40 2,596.81 165.45 5,971,305.69 1,702,045.99 1.02 2,465.51 MWD+IFR-AK-CAZ-SC(5) 5,461.27 91.03 344.00 3,842.30 3,744.73 2,687.56 139.19 5,971,396.21 1,702,018.99 0.30 2,559.96 MWD+IFR-AK-CAZ-SC(5) 5,556.47 90.86 344.23 3,840.73 3,743.16 2,779.11 113.13 5,971,487.54 1,701,992.19 0.30 2,655.14 MWD+IFR-AK-CAZ-SC(5) 5,651.78 90.93 345.19 3,839.24 3,741.67 2,871.04 88.00 5,971,579.25 1,701,966.31 1.01 2,750.43 MWD+IFR-AK-CAZ-SC(5) 5,745.67 90.89 344.65 3,837.75 3,740.18 2,961.68 63.58 5,971,669.68 1,701,941.14 0.58 2,844.31 MWD+IFR-AK-CAZ-SC(5) 5,841.20 90.31 345.33 3,836.75 3,739.18 3,053.95 38.84 5,971,761.73 1,701,915.65 0.94 2,939.83 MWD+IFR-AK-CAZ-SC(5) 5,935.76 89.83 344.72 3,836.63 3,739.06 3,145.30 14.41 5,971,852.87 1,701,890.47 0.82 3,034.39 MWD+IFR-AK-CAZ-SC(5) 6,029.96 89.90 345.09 3,836.86 3,739.29 3,236.25 -10.12 5,971,943.60 1,701,865.20 0.40 3,128.59 MWD+IFR-AK-CAZ-SC(5) 6,125.21 90.03 345.77 3,836.91 3,739.34 3,328.43 -34.09 5,972,035.58 1,701,840.49 0.73 3,223.84 MWD+IFR-AK-CAZ-SC(5) 6,219.78 89.90 346.76 3,836.97 3,739.40 3,420.30 -56.54 5,972,127.25 1,701,817.28 1.06 3,318.39 MWD+IFR-AK-CAZ-SC(5) 6,314.78 89.86 347.79 3,837.17 3,739.60 3,512.96 -77.46 5,972,219.73 1,701,795.60 1.09 3,413.31 MWD+IFR-AK-CAZ-SC(5) 6,409.37 89.86 348.14 3,837.40 3,739.83 3,605.47 -97.19 5,972,312.07 1,701,775.12 0.37 3,507.77 MWD+IFR-AK-CAZ-SC(5) 6,504.15 90.21 348.73 3,837.34 3,739.77 3,698.33 -116.19 5,972,404.75 1,701,755.36 0.72 3,602.38 MWD+IFR-AK-CAZ-SC(5) 6,599.66 90.14 349.22 3,837.05 3,739.48 3,792.07 -134.45 5,972,498.34 1,701,736.33 0.52 3,697.66 MWD+IFR-AK-CAZ-SC(5) 6,694.55 90.17 348.52 3,836.80 3,739.23 3,885.18 -152.77 5,972,591.28 1,701,717.25 0.74 3,792.33 MWD+IFR-AK-CAZ-SC(5) 6,789.67 90.14 346.96 3,836.54 3,738.97 3,978.13 -172.97 5,972,684.05 1,701,696.30 1.64 3,887.34 MWD+IFR-AK-CAZ-SC(5) 6,884.12 90.21 346.55 3,836.25 3,738.68 4,070.06 -194.61 5,972,775.80 1,701,673.91 0.44 3,981.75 MWD+IFR-AK-CAZ-SC(5) 6,978.13 89.90 346.87 3,836.16 3,738.59 4,161.55 -216.22 5,972,867.10 1,701,651.55 0.47 4,075.71 MWD+IFR-AK-CAZ-SC(5) 7,074.57 89.48 345.70 3,836.68 3,739.11 4,255.24 -239.08 5,972,960.59 1,701,627.92 1.29 4,172.13 MWD+IFR-AK-CAZ-SC(5) 7,168.63 90.58 344.55 3,836.63 3,739.06 4,346.15 -263.23 5,973,051.29 1,701,603.03 1.69 4,266.18 MWD+IFR-AK-CAZ-SC(5) 7,263.53 91.85 342.96 3,834.62 3,737.05 4,437.23 -289.77 5,973,142.14 1,701,575.75 2.14 4,361.04 MWD+IFR-AK-CAZ-SC(5) 9/23/2015 2:37:53PM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: True Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 7,358.34 91.51 342.90 3,831.84 3,734.27 4,527.83 -317.59 5,973,232.50 1,701,547.19 0.36 4,455.74 MWD+IFR-AK-CAZ-SC(5) 7,453.22 91.96 342.33 3,828.97 3,731.40 4,618.33 -345.92 5,973,322.76 1,701,518.12 0.77 4,550.50 MWD+IFR-AK-CAZ-SC(5) 7,548.45 91.92 341.86 3,825.74 3,728.17 4,708.90 -375.18 5,973,413.07 1,701,488.12 0.50 4,645.55 MWD+IFR-AK-CAZ-SC(5) 7,643.66 91.30 342.61 3,823.07 3,725.50 4,799.53 -404.22 5,973,503.45 1,701,458.34 1.02 4,740.61 MWD+IFR-AK-CAZ-SC(5) 7,738.48 90.21 344.11 3,821.82 3,724.25 4,890.37 -431.37 5,973,594.06 1,701,430.45 1.96 4,835.38 MWD+IFR-AK-CAZ-SC(5) 7,832.79 90.51 345.88 3,821.23 3,723.66 4,981.46 -455.79 5,973,684.93 1,701,405.29 1.90 4,929.68 MWD+IFR-AK-CAZ-SC(5) 7,927.82 90.34 345.09 3,820.52 3,722.95 5,073.45 -479.60 5,973,776.72 1,701,380.73 0.85 5,024.71 MWD+IFR-AK-CAZ-SC(5) 7,979.73 89.04 343.68 3,820.80 3,723.23 5,123.44 -493.58 5,973,826.59 1,701,366.35 3.69 5,076.61 MWD+IFR-AK-CAZ-SC(5) 8,022.94 87.77 343.12 3,822.01 3,724.44 5,164.83 -505.91 5,973,867.88 1,701,353.67 3.21 5,119.78 MWD+IFR-AK-CAZ-SC(5) 8,117.49 87.90 341.84 3,825.58 3,728.01 5,254.93 -534.36 5,973,957.73 1,701,324.49 1.36 5,214.17 MWD+IFR-AK-CAZ-SC(5) 8,212.82 87.94 344.80 3,829.04 3,731.47 5,346.18 -561.70 5,974,048.74 1,701,296.41 3.10 5,309.39 MWD+IFR-AK-CAZ-SC(5) 8,307.00 89.49 347.53 3,831.15 3,733.58 5,437.59 -584.21 5,974,139.96 1,701,273.15 3.33 5,403.51 MWD+IFR-AK-CAZ-SC(5) 8,401.02 89.97 348.93 3,831.59 3,734.02 5,529.63 -603.39 5,974,231.83 1,701,253.22 1.57 5,497.38 MWD+IFR-AK-CAZ-SC(5) 8,496.48 90.41 348.19 3,831.28 3,733.71 5,623.19 -622.32 5,974,325.22 1,701,233.52 0.90 5,592.66 MWD+IFR-AK-CAZ-SC(5) 8,589.29 89.69 348.66 3,831.20 3,733.63 5,714.11 -640.94 5,974,415.98 1,701,214.16 0.93 5,685.30 MWD+IFR-AK-CAZ-SC(5) 8,685.55 89.90 349.39 3,831.54 3,733.97 5,808.61 -659.27 5,974,510.32 1,701,195.06 0.79 5,781.32 MWD+IFR-AK-CAZ-SC(5) 8,782.80 89.86 350.98 3,831.74 3,734.17 5,904.44 -675.85 5,974,605.99 1,701,177.70 1.64 5,878.17 MWD+IFR-AK-CAZ-SC(5) 8,877.01 89.97 351.65 3,831.88 3,734.31 5,997.57 -690.07 5,974,698.99 1,701,162.71 0.72 5,971.81 MWD+IFR-AK-CAZ-SC(5) 8,971.82 89.93 350.56 3,831.97 3,734.40 6,091.23 -704.73 5,974,792.53 1,701,147.29 1.15 6,066.08 MWD+IFR-AK-CAZ-SC(5) 9,067.25 89.93 348.98 3,832.08 3,734.51 6,185.14 -721.68 5,974,886.29 1,701,129.57 1.66 6,161.17 MWD+IFR-AK-CAZ-SC(5) 9,161.79 89.49 347.73 3,832.56 3,734.99 6,277.73 -740.76 5,974,978.71 1,701,109.74 1.40 6,255.55 MWD+IFR-AK-CAZ-SC(5) 9,255.98 89.42 346.33 3,833.46 3,735.89 6,369.51 -761.90 5,975,070.31 1,701,087.85 1.49 6,349.67 MWD+IFR-AK-CAZ-SC(5) 9,350.72 89.62 345.57 3,834.25 3,736.68 6,461.42 -784.90 5,975,162.01 1,701,064.10 0.83 6,444.40 MWD+IFR-AK-CAZ-SC(5) 9,446.13 89.42 344.51 3,835.05 3,737.48 6,553.59 -809.53 5,975,253.97 1,701,038.72 1.13 6,539.80 MWD+IFR-AK-CAZ-SC(5) 9,540.60 89.76 343.90 3,835.73 3,738.16 6,644.49 -835.24 5,975,344.64 1,701,012.26 0.74 6,634.26 MWD+IFR-AK-CAZ-SC(5) 9,636.88 89.31 342.91 3,836.51 3,738.94 6,736.75 -862.74 5,975,436.67 1,700,984.01 1.13 6,730.50 MWD+IFR-AK-CAZ-SC(5) 9,732.08 89.35 343.09 3,837.62 3,740.05 6,827.79 -890.57 5,975,527.47 1,700,955.44 0.19 6,825.63 MWD+IFR-AK-CAZ-SC(5) 9,825.67 89.38 342.55 3,838.66 3,741.09 6,917.20 -918.21 5,975,616.64 1,700,927.07 0.58 6,919.15 MWD+IFR-AK-CAZ-SC(5) 9,919.96 89.52 342.55 3,839.56 3,741.99 7,007.14 -946.49 5,975,706.34 1,700,898.06 0.15 7,013.35 MWD+IFR-AK-CAZ-SC(5) 10,014.56 90.03 343.12 3,839.94 3,742.37 7,097.53 -974.40 5,975,796.48 1,700,869.41 0.81 7,107.88 MWD+IFR-AK-CAZ-SC(5) 10,110.17 89.90 344.28 3,839.99 3,742.42 7,189.29 -1,001.24 5,975,888.02 1,700,841.82 1.22 7,203.46 MWD+IFR-AK-CAZ-SC(5) 10,205.84 90.00 345.20 3,840.08 3,742.51 7,281.59 -1,026.42 5,975,980.09 1,700,815.89 0.97 7,299.13 MWD+IFR-AK-CAZ-SC(5) 10,300.14 90.45 346.86 3,839.71 3,742.14 7,373.10 -1,049.18 5,976,071.40 1,700,792.38 1.82 7,393.41 MWD+IFR-AK-CAZ-SC(5) 10,397.27 89.28 347.40 3,839.94 3,742.37 7,467.78 -1,070.82 5,976,165.90 1,700,769.97 1.33 7,490.47 MWD+IFR-AK-CAZ-SC(5) 10,490.83 89.48 347.92 3,840.95 3,743.38 7,559.18 -1,090.81 5,976,257.12 1,700,749.23 0.60 7,583.93 MWD+IFR-AK-CAZ-SC(5) 10,585.64 88.83 347.02 3,842.35 3,744.78 7,651.72 -1,111.38 5,976,349.48 1,700,727.91 1.17 7,678.64 MWD+IFR-AK-CAZ-SC(5) 10,680.53 88.90 346.48 3,844.23 3,746.66 7,744.06 -1,133.12 5,976,441.63 1,700,705.41 0.57 7,773.46 MWD+IFR-AK-CAZ-SC(5) 10,774.67 89.55 345.59 3,845.50 3,747.93 7,835.41 -1,155.84 5,976,532.78 1,700,681.95 1.17 7,867.58 MWD+IFR-AK-CAZ-SC(5) 10,870.23 89.45 345.08 3,846.33 3,748.76 7,927.85 -1,180.03 5,976,625.02 1,700,657.00 0.54 7,963.13 MWD+IFR-AK-CAZ-SC(5) 10,962.96 90.03 344.51 3,846.75 3,749.18 8,017.33 -1,204.35 5,976,714.29 1,700,631.95 0.88 8,055.86 MWD+IFR-AK-CAZ-SC(5) 9/23/2015 2:37:53PM Page 5 COMPASS 5000.1 Build 74 Schlumberger • Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1C-152 Project: Kuparuk River Unit TVD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Site: Kuparuk 1C Pad MD Reference: Actual:57.6+39.97 @ 97.57usft(Doyon25) Well: 1C-152 North Reference: True Wellbore: 1C-152 Survey Calculation Method: Minimum Curvature Design: 1C-152 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,055.17 89.90 343.39 3,846.81 3,749.24 8,105.95 -1,229.84 5,976,802.68 1,700,605.74 1.22 8,148.05 MWD+IFR-AK-CAZ-SC(5) 11,147.08 89.97 343.58 3,846.92 3,749.35 8,194.07 -1,255.97 5,976,890.57 1,700,578.89 0.22 8,239.93 MWD+IFR-AK-CAZ-SC(5) 11,240.29 89.97 344.08 3,846.96 3,749.39 8,283.59 -1,281.93 5,976,979.87 1,700,552.20 0.54 8,333.12 MWD+IFR-AK-CAZ-SC(5) 11,332.67 89.21 344.72 3,847.63 3,750.06 8,372.56 -1,306.77 5,977,068.63 1,700,526.64 1.08 8,425.49 MWD+IFR-AK-CAZ-SC(5) 11,425.77 88.90 343.54 3,849.16 3,751.59 8,462.10 -1,332.22 5,977,157.95 1,700,500.45 1.31 8,518.57 MWD+IFR-AK-CAZ-SC(5) 11,515.52 89.62 345.27 3,850.32 3,752.75 8,548.54 -1,356.35 5,977,244.17 1,700,475.62 2.09 8,608.30 MWD+IFR-AK-CAZ-SC(5) 11,607.85 89.62 344.42 3,850.93 3,753.36 8,637.65 -1,380.49 5,977,333.08 1,700,450.76 0.92 8,700.63 MWD+IFR-AK-CAZ-SC(5) 11,697.96 89.31 344.37 3,851.77 3,754.20 8,724.44 -1,404.73 5,977,419.66 1,700,425.81 0.35 8,790.73 MWD+IFR-AK-CAZ-SC(5) 11,791.11 89.04 344.61 3,853.11 3,755.54 8,814.18 -1,429.63 5,977,509.19 1,700,400.17 0.39 8,883.86 MWD+IFR-AK-CAZ-SC(5) 11,883.00 88.90 345.01 3,854.77 3,757.20 8,902.85 -1,453.70 5,977,597.65 1,700,375.38 0.46 8,975.74 MWD+IFR-AK-CAZ-SC(5) 11,973.26 88.36 343.77 3,856.92 3,759.35 8,989.75 -1,477.99 5,977,684.34 1,700,350.39 1.50 9,065.97 MWD+IFR-AK-CAZ-SC(5) 12,066.77 88.42 344.91 3,859.55 3,761.98 9,079.76 -1,503.22 5,977,774.12 1,700,324.42 1.22 9,159.43 MWD+IFR-AK-CAZ-SC(5) 12,158.68 87.26 343.86 3,863.02 3,765.45 9,168.21 -1,527.94 5,977,862.36 1,700,298.98 1.70 9,251.27 MWD+IFR-AK-CAZ-SC(5) 12,250.13 87.94 345.44 3,866.85 3,769.28 9,256.31 -1,552.12 5,977,950.26 1,700,274.07 1.88 9,342.63 MWD+IFR-AK-CAZ-SC(5) 12,345.49 88.42 345.87 3,869.87 3,772.30 9,348.65 -1,575.74 5,978,042.39 1,700,249.71 0.68 9,437.94 MWD+IFR-AK-CAZ-SC(5) 12,367.30 88.53 345.99 3,870.46 3,772.89 9,369.80 -1,581.04 5,978,063.49 1,700,244.23 0.75 9,459.74 BLIND(6) NOT an Actual Survey 4 1/2"x 6-3/4" 12,406.00 88.72 346.21 3,871.38 3,773.81 9,407.36 -1,590.33 5,978,100.97 1,700,234.63 0.75 9,498.42 Projection to TD Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Yes ❑ No 1 have checked to the best of my ability that the following data is correct: Q Surface Coordinates R Declination & Convergence [1] GRS Survey Corrections D Survey Tool Codes Vincent °40"""�a"`""� al-Wca.Our; SLB DE: OSdrd Data""""° ° `��a Client Representative: e-111/1- 0"' ""806 Date: 23-Sep-2015 9/23/2015 2:37:53PM Page 6 COMPASS 5000.1 Build 74 �" k� • 21 51 14 40 OCT2636Q O 15 2 J 1:J AOCSchiumbergerTransmittal#: 150CT15-SPO2 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery %°/22/2°15 Iv1 K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 1C-152 Date Dispatched: 15-Oct-15 Job#: 15AKA0093 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A SonicScope Top of Cement x x LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Richard.E.Elgarico@conocophillips.com AlaskaPTSPrintCenter@slb.com Ricky Elgarico Attn:Stephanie Pacillo 907-265-6580 Received By: AI vaga,frulLi - / ...6-4-14;,. Ati OF Tfj� • • sv THE STATE Alaska Oil and Gas ti�'�►�"��M of jj AS14(siA. Conservation Commission �'= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 iletrArMain: 907.279.1433 OFALASY'.. Fax: 907.276.7542 www.aogcc.alaska.gov Duncan Hyden _ Drilling Engineerti ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sok Oil Pool, KRU 1C-152 Sundry Number: 315-543 Dear Mr. Hyden: 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, Oty SOA Cathy P. FoersterRBDM SEP Q 9 2015 Chair DATED this day of September, 2015 Encl. RECEIVED • STATE OF ALASKA S 0 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION A '5 lir 1� APPLICATION FOR SUNDRY APPROVALS AOGGC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Top Job n 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc ' Exploratory ❑ Development 215-114 ' 3.Address: . 6.API Number: Stratigraphic El [+/� �'' P.O. Box 100360 Anchorage,AK 99510-0360 50-029-23548-00-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A I Will planned perforations require a spacing exception? Yes ❑ No ❑ KRU 1C-152 • 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL 025649, ADL 025638 - Kuparuk River Field/West Sak 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): 2813 2653 2813 2653 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 123 120 Surface 2766 10-3/4" 2808 2653 5210 247 Intermediate Production 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 0 13.Well Class after proposed work: Detailed Operations Program r] BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development L1 Service _i 14. Estimated Date for 8/29/2015 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ E' WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 8/29/2015 GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: Victoria Loepp ✓ GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Duncan Hyden Email duncan.p.hydencop.com Printed Name Duncan HydenTitle Drilling Engineer r SignatureI L / / Phone 907-265-6862 Date 9/1/2015 L `� COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 315-5y3 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No LTJ Subsequent Form Required: /0 — 4 L 4 APPROVED BY Q Approved by: r J2 / COMMISSIONER TH COMMISSION Date: �fp-,(Q(�-h1S� V . 113/,5---- /,J/ , ?Vs ��f� Q� SEpsariFF2Or nd Form 10-403 Revised 5/2015 QR4 GI a i 4aor 12 months �from the dat//offaappy Attachments in Duplicate • • , kOthaltb Cement Detail Report -virs''� 1C-152 ConocoPhillip!s String: Surface Cement Job: DRILLING ORIGINAL, 8/21/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Cement 8/28/2015 14:00 8/28/2015 18:06 1C-152 Comment With SLB pump 5 BBL of CW100 and test lines to 3500 psi for 6 minutes. Pump 75.4 BBL total of CW100. Batch and pump 76.6 BBL of 10.5 ppg MudPush II with 2 gallons of red dye. Pump 483.4 BBL of 11 ppg cement Lead(256%of gauge hole above the permafrost, 1451 sacks, 1.87 yield,6.491 gal/sk),followed by 65.4 BBLs of 12.0 ppg Tail(227 sacks, 16.2 yield, 5.461 gal/sk). The plug bumped on 2510 strokes 364 psi and held 965 psi for and the float held. Bled back 1.4 BBL when bleeding off pressure from bumping plug. 16 BBLs of 11.0 ppg cement back to surface with cement in place at 18:06, 8/28.There was a loss of 35 BBLS throughout the cement job. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Surface Cement 119.0 2,813.0 No 16.0 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 4 7 7 364.0 364.0 Yes No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment With SLB pump 5 BBL of CW100 and test lines to 3500 psi for 6 minutes. Pump 75.4 BBL total of CW100. Batch and pump 76.6 BBL of 10.5 ppg MudPush II with 2 gallons of red dye. Pump 483.4 BBL of 11 ppg cement Lead(256%of gauge hole above the permafrost, 1451 sacks, 1.87 yield,6.491 gal/sk),with 65.4 BBLs of 12.0 ppg Tail(227 sacks, 16.2 yield, 5.461 gal/sk). The plug bumped on 2510 strokes 364 psi and held 965 psi for and the float held. 16 BBLs of 11.0 ppg cement back to surface with cement in place at 18:06,8/28.There was a loss of 35 BBLS throughout the cement job. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 42.0 2,307.0 1,451 LiteCrete 486.4 Yield ye/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.87 6.49 11.00 5.20 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.07 gal/sx Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,307.0 2,813.0 227 LiteCrete 227.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.62 5.46 12.00 3.80 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.07 gal/sx Additive Type Concentration Conc Unit label Retarder D177 0.02 gal/sx Page 1/1 Report Printed: 9/1/2015 • • Hyden, Duncan P From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Sent: Sunday,August 30, 2015 9:13 AM To: Hyden, Duncan P; DOA AOGCC Prudhoe Bay; Regg,James B (DOA) Subject: [EXTERNAL]Re: Permit#215-114: 1C-152 Surface Cement- Top Job Follow Up Flag: Follow up Flag Status: Flagged Please submit a 10-403 for the top job as soon as possible. Thank, Victoria Sent from my iPhone On Aug 29, 2015,at 8:05 AM, Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>wrote: Duncan, As we discussed,the AOGCC inspectors should be notified to witness. You have verbal approval to proceed with the top job. Thanx, Victoria Sent from my iPhone On Aug 29, 2015, at 3:51 AM, Hyden, Duncan P<Duncan.P.Hyden@conocophillips.com>wrote: Victoria, On the 28th we performed a primary cement job on 1C-152 well. The cement job went as follows: 75.4bbls CW100 76.6bbls MudPush II 483.4bbls 11ppg Lead (256%excess in permafrost) 65.4bbls 12ppg Tail Plugs bumped on calculated strokes Floats held 16bbls of 11.0ppg cement back to surface Cement in place at 18:06. We nippled down our diverter and checked the TOC and found that it had fallen to 68' below the landing ring. There was a loss of 35 BBLS throughout the cement job. 1 • • We are currently preparing to perform a cement top job. I will call prior to pumping to the job(07:30-08:00)to obtain verbal approval. I will prepare a 10-403 to be submitted Monday 8/31/2015. Duncan Hyden Drilling Engineer I Direct:907-265-6862 I Mobile:907-317-1910 duncan.o.hvden@cop.com 2 OF T4.1. • wA , THE STATE Alaska Oil and. Gas Conservation Commission of ALA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sok Oil Pool, KRU 1C-152 ConocoPhillips Alaska, Inc. Permit No: 215-114 Surface Location: 1279' FNL,4415' FEL, T11N, R10E, S12, UM Bottomhole Location: 2327' FNL, 720.8' FEL, T12N, R10E, S35, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this 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 AOGCC 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 AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 41 ' 5 Cathy '. Foerster Chair DATED this 2-1/ day of July, 2015. RECEIVED • STATE OF ALASKA 1 JUN 3 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 la.Type of Work: lb.Proposed Well Class: Development-Oil ❑ Service- Winj 0 ' Single Zone n ' lc.Specify if well is proposed for: Drill 111, Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry P. Exploratory ❑ Service- WAG ❑ Service-Disp El Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket❑✓ Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska Inc • Bond No. 59-52-180 • KRU 1C-152 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 12,505' . TVD: 3,860' • Kuparuk River Field • 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1279'FNL,4415'FEL, T 11N,R 10E,S 12,Umiat , ADL 025649,ADL 025638 West Sak Oil Pool ' Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2327.0'FNL,720.8'FEL, T 12N,R 10E,S 35,Umiat 931695 8/1/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2327'FNL,720.8'FEL, T 12N,R 10E,S 35,Umiat x 2560,2560 / '/2.0 4136 ft 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: '99.5 feet 15.Distance to Nearest Well Open Surface: x. 561870 y- 5968956 Zone-4 - GL Elevation above MSL: • 60.0 feet to Same Pool: 665 ft 16.Deviated wells: Kickoff depth: ' 312 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 93.26 degrees Downhole: 1726 psi.. Surface: 1301 psi • 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) 42" 20" 94# H40 Welded 80 40 40 120 120 200 cf of ArcticCRETE 13.5" 10.75" 45.5# L-80 Hydril 563 2731 40 40 2771 2615 1379 sx DeepCRETE Lead,205 sx DeepCRETE Tail 9.875" 7.625" 29.7# L-80 Hydril 563 4872 40 40 4912 3840 535 sx Class'G' 6.75" 4.5" 11.6# L-80 Hydril 563 7743 4762 3833 12505 3860 ICD Liner Completion(no cement) 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 BOP Sketch Drilling Program '." Time v.Depth Plot Shallow Hazard Analysis IrrDiverter Sketch Seabed Report Drilling Fluid Program Vol., 20 AAC 25.050 requirements i 21. Verbal Approval: Commission Representative: Date 7,_,//1/1/ ___ 6/29/2015 22. I hereby certify that the foregoing is true and correct. Contact Duncan Hyd @ 265-6862 Email duncan.p,hyderlAcop.com Printed Name G.Alvord Title Alaska Drilling Manager Signature A. c. a.k. 6+Phone 265-6120 Date (t1.(,Zo is Commission Use Only Permit to DrillAPI Number: _ Permit Approval r See cover letter for other Number: 4 l� ` l' 50- 0 ,C1- 3�V$-gyp--O Date: I di I J requirements. 1 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: f3Q p f e51 to 3 5-00 f7 / Samples req'd: Yes[i] No[ Mud log req'd:Yes❑ No[V]� /Ir./e1 u /Q Y p rC Ve1,1 f c .. fe5f fp ZS DO p5/ H2S measures: Yes VNo❑ Directional svy req'd:YesIE No❑ $fGr,fe VV/✓f_J- C55c0/ N)/T- /A Spacing exception req'd: Yes❑ NoL 1 Inclination-only svy req'd:Yes❑ No[j rev,ired afffr 5f4 6, 1;3c'd /,-7 jc-c f/'ar> / pa ry/C lit/ Cl/5 /C-o 41 / C-05"4- /C-O( m u5f h a vc OA mon forCedt c/ally drrC/ vnu✓S1L Cohi - - wi 'LhaD ✓`FAC �5. 4oZ(f) - /� APPROVED BY /� Approved by: /' ' 71-7 -- COMMISSIONER THE COMMISSION Date: 7 7 ` submit form and Form 10-401 evised 10/2012) rF4 from the date of appy v 1(20 AAC 28.005(g)) Attachments in Duplicate v'r` 7//b//c OR1GTNAL ��°�� • RECEIVED ConocoPhillipsJUN 3 0 2015 Alaska AOGCC Post Office Box 100360 Anchorage, Alaska 99510-0360 Duncan Hyden Phone (907) 265-6862 June 30th, 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Injector, 1C-152 ' Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill a grass roots onshore injector well, a horizontal well in the West Sak"D"sand. The expected spud date for 1C-152 is, August 1st, 2015. The West Sak in the 1C area is a shallow marine sequence comprised of very fine grained, single and amalgamated hummocky cross stratified sandstone beds. The 1C-152 well will be drilled in the D Sand, down structure to the North with a planned lateral length of approximately 7593'. 3 fault crossings have been identified along the planned well path. There are no known H2S issues associated with the drilling of this well or is it anticipated to see any pressures higher than 9.4 ppg equivalent during the drilling of this well. A FIT test to a minimum of 11.0 ppg will be performed after setting the surface casing and drilling out 20'of new formation, and a FIT test of 11.0 ppg equivalent will be performed after setting the intermediate string and drilling 20'of new formation. A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of the surface hole for the 1C-152. A 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete the well. It will be tested to 3500 psi (annular preventer to 3500 psi) and will be tested on a 14 day test cycle in accordance with COP and AOGCC policy while drilling the intermediate and production sections of the well. Properly sized VBR's and pipe rams will be installed to allow closing in on any size of tubular in the hole in the case of an unexpected event. Also a FOSV with proper DP crossover shall be kept on the floor in the open position at all times. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for the wellbore. Sincerely, Digitally signed by iV 1� Datee::2(]— DaHy062015.06.. 29 15:25:24-08'00' Duncan Hyden ConocoPhillips Drilling Engineer • Ap ation for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 Permit - West Sak Well #1C-152 Application for Permit to Drill Document r MaxWell Maximize W II VQIvB Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(f) 3 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 Requirements of 20 AAC 25.005(c)(4) 4 4. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005(c)(5) 4 5. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 5 6. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 5 7. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program(Spud Mud) 5 Intermediate Hole Mud Program (LSND) 6 Lateral Mud Program (MI Flo-Pro WBM) 6 8. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25.005(c)(9) 6 9. Seismic Analysis 6 Requirements of 20 AAC 25.005(c)(10) 6 10.Seabed Condition Analysis 6 Requirements of 20 AAC 25.005(c)(11) 6 11.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 12.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 1C-152 PERMIT Page 1 of 13 Printed:29-Jun-15 Appl}lion for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 13.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 14.Plat of All Wells Within 1/4 Mile Radius of Injection Well 8 Requirements of 20 AAC 25.402(c) (1) 8 15.List of Operators / Surface Owners 8 Requirements of 20 AAC 25.402(c) (2) 8 16.Affidavit to Operators / Surface Owners Proving Notice of Injection 8 Requirements of 20 AAC 25.402(c) (3) 8 17.Description of Operation 8 Requirements of 20 AAC 25.402(c) (4) 8 18.Name and Descroption of Affected Pools 8 Requirements of 20 AAC 25.402(c) (5) 8 19.Name and Description of Affected Formations 8 Requirements of 20 AAC 25.402(c) (6) 8 20.Logs of Off-Set Injection Wells 9 Requirements of 20 AAC 25.402(c) (7) 9 21.Casing Design and Mechanical Integrity 9 Requirements of 20 AAC 25.402(c) (8) 9 22.Fluid Injection Data 10 Requirements of 20 AAC 25.402(c) (9) 10 23.Injection Pressure 10 Requirements of 20 AAC 25.402(c) (10) 10 24.Reservoir Containment 10 Requirements of 20 AAC 25.402(c) (11) 10 25.Formation Water Analysis 11 Requirements of 20 AAC 25.402(c) (12) 11 26.Freshwater Exemptions 12 Requirements of 20 AAC 25.402(c) (13) 12 27.Increase in Hydrocarbon Recovery 12 Requirements of 20 AAC 25.402(c) (14) 12 28.Offset Wells Mechanical Conditions 12 Requirements of 20 AAC 25.402(c) (15) 12 29.Attachments 13 Attachment 1 Directional Plan 13 Attachment 2 Drilling Hazards Summary 13 Attachment 3 Cement Program Summary 13 1C-152 PERMIT Page 2 of 13 Printed:29-Jun-15 • Applytion for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 Attachment 4 Well Schematic 13 Attachment 5 Quarter Mile Plat13 Attachment 6 Doyon 25 BOP Stack Configuration 13 Attachment 7 Doyon 25 on 1C-153 13 1. Well Name Requirements of 20 AAC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1C-152. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration,• (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at,Surface 1279' FNL,4415' FEL, T 11N, R 10E, S 12, Umiat ASP Zone 4 NAD 27 Coordinates RKB Elevation 99.5'AMSL Northings 5,968,956.3 Eastings:561,869.5 Pad Elevation 60.0'AMSL Location at Top of Productive• 2327,0'FNL 720.8'FEL T 12N R 10E S 35, Umiat Interval (West Sak"j,•"Sand) r F r ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 4702' Northings: 5,970,908.2 Eastings:562,175.0 Total Vertical Depth, RKB: 3829' Total Vertical Depth, SS: 3740' Location at Total Depth 2327'FNL, 720.8' FEL, T 12N, R 10E, S 35, Umiat ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12505' Northings: 5,978,454.0 Eastings: 560,200.2 Total Vertical Depth, RKB: 3860' Total Vertical Depth, SS: 3740' and (D)other information required by 20 AAC 25.050(6); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent we//bores within 200 feet of any portion of the proposed well,• Please see Attachment 1: Directional Plan 1C-152 and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application.' 1C-152 PERMIT Page 3 of 13 Printed:29-Jun-15 • Ap ation for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 MC 25.037,as applicable; An API 13-5/8"x 5000 psi BOP stack will be utilized to drill and complete well 1C-152. Please see information on the Doyon Rig 25 blowout prevention equipment placed on file with the Commission. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1C area are 0.447 psi/ft, or 8.6 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient(0.11), and the deepest planned vertical depth of the West Sak"D"sand formation is 1,301 psi, calculated thusly: MPSP = (3860 ft TVD)(0.447 - 0.11 psi/ft) = 1,301 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2: 1C-152 Drilling Hazards Summary. 4. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 MC 25.030(1); 1C-152 will be completed with a 7-5/8" intermediate casing landed in the West Sak D sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the"Formation Integrity Test Procedure"that ConocoPhillips Alaska placed on file with the Commission. 1C-152 PERMIT Page 4 of 13 Printed:29-Jun-15 • App' tion for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 5. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item a/ready on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre- perforated liner,or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole 'Fop Btm Csg/Tbg Size Weight a ngt MD/TVD MDffVD I OD(in) (in) (lb/ft) Grade Connection (f) (ft) (ft) Cement Program 20 42 62.5 H40 Welded 80 40/ 40 120/ 120 Cemented to surface 200 cf ArdicCRETE Cemented to Surface 1379 sx 11 ppg 10.75 13.5 45.5 L-80 Hydril 563 2731 40/40 2771 / 2615 DeepCRETE Lead, 205 sx 12 ppg DeepCRETE Tail Cement Top planned @ 7.625 9.875 29.7 L-80 Hydril 563 4872 40/ 40 4912 / 3840 2921'MD/275 Cemented w/53535 sx sx 15.8 ppg Class'G' 4.5 ICD 6.75 11.6 L-80 Hydril 563 7743 4762 / 3833 12505/ 3860 ICD-no cement 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1C-152 surface hole. Please see diagrams of the Doyon 25 diverter system on file with the Commission. 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (Spud Mud) Spud to Surface TD Density(ppg) 8.5 - 9.3 LSYP(cP) 30 - 50 API Fluid Loss No Control (mL/30 min) Chlorides(mg/L) <1000 pH 10.8— 11.2 1C-152 PERMIT Page 5 of 13 Printed:29-Jun-15 App'i1C3tion for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 Intermediate Hole Mud Program (LSND) Lateral Mud Program (MI Flo-Pro WBM) 10,75"Csg Shoe to 7-5/8"Csg Point Density(ppg) 9.2 ./ Density(ppg) 9.2 Fann 35 6 RPM Fann 35 6 RPM (lb/100 ft2) 5 -8 (lb/100 ft2) 10 - 12 HTHP Fluid Loss <10 API Filtrate <6 (ml/30min) (cc/30 min) Kla-Stop 2-3% pH 9.5 - 10.0 pH 9.5 - 10.0 Drill Solids <7 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 25. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f),• Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom-founded structure,jack-up rig, or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(6),• Not applicable: Application is not for an offshore well. 11.Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 MC 25.025{Bonding}have been met,' Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 12.Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20"x 42"insulated conductor to ± 120'RKB. Install landing ring on conductor. / 2. Move in/ rig up Doyon Rig 25. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 13.5"hole to casing point at ±2771'MD/ 2615'TVD as per directional plan. Run MWD tools as required for directional monitoring (gamma ray, resistivity). 1C-152 PERMIT Page 6 of 13 Printed:29-Jun-15 App ion for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 4. Run and cement 10.75", 45.5#, L80, Hydril 563 casing to surface. Displace cement with mud and check floats upon bumping plug. Perform top job if required. 5. Remove diverter system, install and test 13-5/8"x 5,000 psi BOP's to 3500 psi (annular preventer to y: 3500 psi). Notify AOGCC 24 hrs before test. 6. PU 9.875"bit and 6.75"drilling assembly, with MWD (gamma ray, resistivity). RIH, clean out cement to top of float equipment and test casing to 3000 psi for 30min. 7. Drill out cement and, between 20'and 50' of new hole. Perform formation integrity test to 11.0ppg EMW, recording results. 8. Directionally drill to 7-5/8"casing point at 4912' MD/ 3840'TVD. Backream out of hole on to the surface casing shoe. 9. Run 7.625", 29.7# L80, Hydril 563 casing to surface. (top of cement to be 2921'MD/ 2758'TVD which corresponds to 500'above the Ugnu C formation). ✓ 10. Install wellhead x 7.625"packoff and test to 3500 psi. 11. Flush 10.75"x 7.625"annulus with water, followed by diesel. 12. PU 6.75"PDC Bit and 4.5"drilling assembly, with MWD and LWD logging tools (gamma ray, resistivity, sonic)./RIH, clean out cement to top of float equipment. Test casing to 3000 psi for 30 minutes. 13. A sonic tool will be in the BHA so after casing test perform MAD pass with sonic tool in memory mode to ensure cement quality. 14. Drill out cement and 20'- 50'of new hole. Displace hole to lateral drilling Flo-Pro WBM system. Perform formation integrity test to 11.0ppg EMW, recording results. 15. Directionally drill 6.75"hole to West Sak D Sand to TD at ± 12505'MD/ 3860'TVD as per directional plan. 16. POOH to 7.625"shoe. TIH and perform final circulations. Pump out of Hole. 17. PU and run 4-1/2"ICD liner. 18. Once all the liner is in the hole, rig up false rotary table and trip 2 7/8 wash pipe string into the entire length of the liner. Make up liner hanger running tool. 19. Finish running liner to TD to land liner, then displace well to MI breaker through washpipe. 20. Set liner hanger @ ± 4762'MD/ 3833'TVD, set liner top packer. POOH. 21. PU 4.5"tubing as required and RIH to depth. Land tubing. Set BPV 22. Nipple down BOPE, nipple up tree and test. Pull BPV. 23. Freeze protect well with diesel by pumping into 4.5"x 7.625"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 24. Set BPV and move rig off. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or 1C-152 PERMIT Page 7 of 13 Printed:29-Jun-15 • Apption for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 14.Plat of All Wells Within 1/4 Mile Radius of Injection Well Requirements of 20 AAC 25.402(c) (1) An application for injection must include:(1)a plat showing the location of each proposed injection well,abandoned or other unused well,production well,dry hole,and other well within one-quarter mile of each proposed injection well; The plot for 1C-152 quarter-mile injection review can be found in attachment #5 15.List of Operators / Surface Owners Requirements of 20 AAC 25.402(c) (2) An application for injection must include:(2)a list of all operators and surface owners within a one-quarter mile radius of each proposed injection well; N/A since we are in the existing Kuparuk unit. 16.Affidavit to Operators / Surface Owners Proving Notice of Injection Requirements of 20 AAC 25.402(c) (3) An application for injection must include:(3)an affidavit showing that the operators and surface owners within a one-quarter mile radius have been provided a copy of the application for injection,• N/A since we are in the existing Kuparuk unit. 17.Description of Operation Requirements of 20 AAC 25.402(c) (4) An application for injection must include:(4)a full description of the particular operation for which approval is requested; Enhanced recovery injection well 1C-152 will be used for the introduction of additional fluids into the reservoir to increase the ultimate recovery of oil. This well will support existing producer 1C-151 and planned producer 1C-153. As of December 31, 2014, there were 108 active wells in the West Sak Pool — 54 producers, 49 water injectors, and 5 water alternating gas injectors (1E-117, 1E-119, 13-122, 13-164 and 13-170). Produced water from the Kuparuk Central Processing Facilities (CPFs) and treated seawater from the Saltwater Treatment Plant(STP) were used for the West Sak waterflood. 1C-152 will inject produced water and/or treated seawater into the West Sak Pool. 18.Name and Descroption of Affected Pools Requirements of 20 AAC 25.402(c) (5) An application for injection must include:(5) the names,descriptions,and depths of the pools to be affected; The D Sand interval of the West Sak Formation, within the Kuparuk Unit, will be affected by the 1C-152 injection well. The West Sak Pool is defined by Rule 2 of Conservation Order No. 406 as the strata that are common to, and correlated with, the accumulation found in the Atlantic Richfield Company West Sak River State No. 1 Well between the depths of 3,552 and 4,156 feet, measured depth. 19.Name and Description of Affected Formations Requirements of 20 AAC 25.402(c) (6) An application for injection must include:(6) the name,description,depth,and thickness of the formation into which fluids are to be injected,and appropriate geological data on the injection zone and confining zone,including lithologic descriptions and geologic names; 1C-152 PERMIT Page 8 of 13 Printed:29-Jun-15 • AppllCation for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 The West Sak Formation is overlain by a 100-140 thick mudstone and clay formation (Ugnu A). The West Sak Pool is defined by Rule 2 of Conservation Order No. 406 as the strata that are common to, and correlated with, the accumulation found in the Atlantic Richfield Company West Sak River State No. 1 Well between the depths of 3,552 and 4,156 feet, measured depth. The West Sak Formation is underlain by the Colville Group, a sequence of impermeable inter-bedded mudstones and shales over 1000 feet in thickness. The Colville Group lithologies have similar confining properties as the overlaying Ugnu sequence, and no injection or fraction propagation below the West Sak is anticipated. 20.Logs of Off-Set Injection Wells Requirements of 20 AAC 25.402(c) (7) An application for injection must include:(7) logs of the injection wells if not already on file with the commission; All injection wells previously drilled will have the logs on file with the commission. 21.Casing Design and Mechanical Integrity Requirements of 20 AAC 25.402(c) (8) An application for injection must include:(8) a description of the proposed method for demonstrating mechanical integrity of the casing and tubing under 20 AAC 25.412 and for demonstrating that no fluids will move behind casing beyond the approved injection zone,and a description of In order to ensure that no fluids will move behind the casing and beyond the approved injection zone the intermediate casing will be set into the West Sak D and cemented. To demonstrate the integrity of the cement job a sonic cement bond log has been run in order to prove the top of cement is covering all the --- required zones. To demonstrate the mechanical integrity of the intermediate casing and tubing strings, both strings will be pressured tested. The intermediate casing will be pressure tested to 3500 psi for 30 minutes and the tubing will be pressure tested to 3500 psi for 30 minutes. Also pressure test tubing x intermediate casing annulus to 1000 psi for 30 minutes. (A) the casing of the injection wells if the wells are existing;or N/A as 1C-152 is a new well. 1C-152 PERMIT Page 9 of 13 Printed:29-Jun-15 • Ap tion for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 (8) the proposed casing program,if the injection wells are new; Casing and cementing program for the new 1C-152 well. Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Leh MD/TVD MD/TVD OD(in) (in) (Ibtft) Grade Connection (ft) (ft) (ft) Cement Program 20 42 62.5 H40 Welded 80 40/ 40 120/ 120 Cemented to surface 200 cf ArcticCRETE Cemented to Surface 1379 sx 11 ppg 10.75 13.5 45.5 L-80 Hydril 563 2731 40/ 40 2771 / 2615 DeepCRETE Lead, 205 sx 12 ppg DeepCRETE Tail Cement Top planned @ 7.625 9.875 29.7 L-80 Hydril 563 4872 40/40 4912/ 3840 2921'MD/2758'TVD Cemented w/535 sx 15.8 ppg Class'G' 4.5 ICD 6.75 11.6 L-80 Hydril 563 7743 4762/ 3833 12505/ 3860 ICD-no cement 22.Fluid Injection Data Requirements of 20 AAC 25.402(c) (9) An application for injection must include;(9) a statement of the type of fluid to be injected, the fluid's composition,the fluid's source, the estimated maximum amounts to be injected daily,and the fluid's compatibility with the injection zone; Produced water from the Kuparuk Central Processing Facilities (CPFs) and treated seawater from the Saltwater Treatment Plant(STP) were used for the West Sak waterflood. 1C-152 will inject produced water and/or treated seawater into the West Sak Pool. Compositions of the injection water from the CPF, and SPT were submitted previously as part of the AIO 2B application. The estimate maximum amount to be injected daily is 2000 bbl/day. 23.Injection Pressure Requirements of 20 AAC 25.402(c) (10) An application for injection must include;(10) the estimated average and maximum injection pressure; West Sak Water Injection: Estimated Bottomhole Pressure: 2702 psi (average) and 3088 psi (maximum) Estimated Wellhead Pressure: 1023 psi (average) and 1409 psi (maximum) (Based on a well depth of 3860'TVDSS, Average injection gradient is 0.7 psi/ft and maximum injection gradient is 0.8 psi/ft) 24.Reservoir Containment Requirements of 20 AAC 25.402(c) (11) An application for injection must include:(11) evidence to support a commission finding that each proposed injection well will not initiate or propagate fractures through the confining zones that inight enable the injection fluid or formation fluid to enter freshwater strata; The estimated maximum injection rates for the 1C-152 injection well will not initiate or propagate fractures through the confining strata and, therefore, will not allow injection or formation fluid to enter 1C-152 PERMIT Page 10 of 13 Printed:29-Jun-15 • Aption for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 any freshwater strata. There are no indications of injection out of zone for the current water injectors at West Sak. Existing water injection operations in the West Sak Oil Pool have been at or above formation parting pressure to improve oil recovery of oil. In no instance have such injection pressures breached the integrity of the confining zone. The West Sak Formation is overlain by a 100-140'thick mudstone and clay formation (Ugnu). This confining sequence tends to behave as a plastic medium and can be expected to contain significantly higher pressures than the West Sak formation sandstones. Extensive fracture testing confirmed that even at the bottom hole pressure significantly above the initial parting pressure, the fluids continued to be confined by a relative thin (' 15-20 ft) shale/mudstone interval, provided that an adequate casing cement bond is present. All injectors that are currently online have had a cement bond log to confirm adequate cement isolation between the West Sak formation and the above strata prior to commencing water injection service. Fracture stimulation data from the West Sak Formation indicate a fracture gradient between 0.6 and 0.7 psi/ft under initial conditions. Proppant injection pressures as high as 7,000 psi (about 2.0 psi/ft injection gradient) showed to fracture growth across any confining shale zones. In addition, long-term water injection above 0.9 psi/ft in the West Sak sands tend to part the formation horizontally, rather than fracture vertically, thus keeping all injection fluids within the intended interval. The West Sak Formation is underlain by the Colville Group, a sequence of impermeable inter-bedded mudstones and shales over 1000 feet in thickness. The Colville Group lithologies have similar confining properties as the overlaying Ugnu sequence, and no injection or fraction propagation below the West Sak is anticipated. 25.Formation Water Analysis Requirements of 20 AAC 25.402(c) (12) An application for injection must include:(12) a standard laboratory water analysis,or the results of another method acceptable to the commission, to determine the quality of the water within the formation into which fluid injection is proposed; Compositions of the injection water from the CPF, and SPT were submitted previously as part of the AIO 2B application. The West Sak Oil Pool connate water composition is provided below. West Sak Oil Pool Connate Water Composition Kuparuk Lab Analytical Report Date: June 4th, 1998 DS 1D Water Sample(#AA43724) Component Concentration (ppm) Chloride 1290 Fluoride <10 Iodide 4.8 Sulfate 18 1C-152 PERMIT Page 11 of 13 Printed:29-Jun-15 tAp ation for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 Calcium 9.8 Iron <1.0 Magnesium 19 Sodium 3480 Barium 3 Strontium 1.4 Silicon 8 Potassium 62 Aluminum 0.3 Chromium <.1 Manganese <.1 Lithium 1 Boron 15 Phosphorus 1 PH 7.7 Bicarbonate 6538 26.Freshwater Exemptions Requirements of 20 AAC 25.402(c) (13) An application for injection must include:(13) a reference to any applicable freshwater exemption issued under 20 AAC 25.440; All aquifers or portions of aquifers lying below and within one-quarter mile of the Kuparuk River Unit are exempted aquifers. (ref. 40 CFR 147.1092(b)(3) and 20 ACC 25.440(c).) 27.Increase in Hydrocarbon Recovery Requirements of 20 AAC 25.402(c) (14) An application for injection must include;(14) the expected incremental increase in ultimate hydrocarbon recovery;and The 1C-152 VRWAG pattern is expected to yield oil recovery of 17.9% OOIP in the West Sak Oil Pool by 2040. This includes approximately 14% OOIP recovery due to waterflooding and 4% OOIP of incremental VRWAG benefits over waterflood. 28.Offset Wells Mechanical Conditions Requirements of 20 AAC 25.402(c) (15) An application for injection must include:(15) a report on the mechanical condition of each well that has penetrated the injection zone within a one-quarter mile radius of a proposed injection well. 1C-152 PERMIT Page 12 of 13 Printed:29-Jun-15 • Pation for Permit to Drill,Well 1C-152 Revision No.0 Saved: 15-Jul-15 1C-04 is permitted as a Kuparuk C Producer. 13 3/8"surface casing set at 2910'MD (2708'ND). 9 5/8" casing set at 6936'MD (6258 TVD)and 254 bbls of lead followed by 55.5 bbls of Class G tail cement was pumped. Top of West Sak sands logged at 4126'MD(3716'ND).Total of 254 bbls of cement pumped covering 4912'to 2024'MD. Cement job went to plan. ,0 G h©r at, k'- 1C-05 is permitted as a Kuparuk C Injector. 10 3/a"surface casing set at 2782'MD (2695'ND). 7"casing set at 7723'MD(7024'ND) and 115 bbls of lead followed by 60 bbls of Class G tail cement was pumped. Top of West Sak sands logged at 4024'MD(3770'TVD). Total of 175 bbls of cement pumped covering 6424'to 1299'MD. Cement job went to plan. .6e y,, t" .c,,. ; 5 1C-06 is permitted as a Kuparuk C Injector. 10 3/4"surface casing set at 3287 MD(2685'ND). 7"liner set at 10226'MD (7090'ND)and 143 bbls of lead followed by 59 bbls of Class G tail cement was pumped. Top of West Sak sands logged at 5332'MD(3834'TVD).Total of 202 bbls of cement pumped covering 7544'to 2682'MD. Cement job went to plan. , r) - 4:, re,5. 5` 1C-07A is Kuparuk C producer.The original 7"Production casing was set at 9766'MD/6566'ND and 207 bbls of Class G lead followed by 62 bbls of Class G tail was pumped.Top of West Sak sands logged at 4751'MD. Total of 269 bbls of cement pumped covering 8010'to 1756'(inside 10 3/4"surface casing). Cement job went to plan. A CBL was ran from 9643'MD to 2000'MD showing a good bond. 28 years later the well was sidetracked in the C-sand with 2 laterals.The window was milled at 8934'MD/6542' ND and the liner top packer was set at 8646'MD/6364'ND. 1C-11 is permitted as a Kuparuk C WAG Producer. 9 5/8"surface casing set at 6945'MD (4439'ND). 7" casing set at 10465'MD (6373'ND) and 23 bbl of Class G cement was pumped. Surface casing was set deeper than the West Sak sands so we do have cement across the�dfWest Sak interval. !.✓' 9...:�. 7 5 /� 5 V`i-Cf 1C-13 is permitted as a Kuparuk C Producer. 9 5/8"surface casing set at 5705'MD (4446'TVD). 7" casing set at 8235'MD(6356'ND)and 28 bbl of Class G cement was pumped. Surface casing was set deeper than the West Sak sands so we do have cement across the West Sak interval. 1C-18 is permitted as a Kuparuk C Injector. 9 5/8"surface casing set at 4817'MD (4343'ND). 7"casing set at 7578'MD (6308'TVD)and 35 bbl of Class G cement was pumped. Surface casing was set deeper than the West Sak sands so we do have cement across the West Sak interval. 29.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic Attachment 5 Quarter Mile Plat Attachment 6 Doyon 25 BOP Stack Configuration Attachment 7 Doyon 25 on 1C-152 1C-152 PERMIT Page 13 of 13 Printed:15-Jul-15 • • Loepp, Victoria T (DOA) From: Hyden, Duncan P <Duncan.P.Hyden@conocophillips.com> Sent: Wednesday,July 15, 2015 5:36 PM To: Loepp,Victoria T(DOA); Lee, David L Subject: RE:West Sak 1C-152(PTD 215-114)AOR Attachments: 1C-152 PERMIT pg 13.pdf Victoria, You are correct,all the wells listed are Kuparuk C wells. 1C-07A is Kuparuk C producer.The original 7" Production casing was set at 9766' MD/6566'TVD and 207 bbls of Class G lead followed by 62 bbls of Class G tail was pumped.Top of West Sak sands logged at 4751' MD.Total of 269 bbls of cement pumped covering 8010'to 1756' (inside 10%"surface casing). Cement job went to plan.A CBL was ran from 9643' MD to 2000' MD showing a good bond. 28 years later the well was sidetracked in the C-sand with 2 laterals.The window was milled at 8934' MD/6542'TVD and the liner top packer was set at 8646' MD/6364'TVD. 1C-07A's OA is continuously monitored via RT transmitter and bled approximately once every 3 weeks this pattern has not changed since 1C-150 came on injection. Thanks and let me know if you have any other questions. Duncan Hyden Drilling Engineer I Direct:907-265-6862 I Mobile:907-317-1910 duncan.p.hyden(a cop.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.govl Sent:Wednesday,July 15, 2015 10:05 AM To: Hyden, Duncan P; Lee, David L Subject: [EXTERNAL]West Sak 1C-152(PTD 215-114)AOR Duncan, In the list of offset wells mechanical condition, 1C-04,05,06, 11, 13 and 18 are listed as West Sak injectors and producers. Aren't these Kuparuk wells? Should 1C-07A be included in the AOR? One of the conditions for the conversion of 1C-150 to an injector was that the OA of 1C-07A was to be monitored daily. What is the OA history on 1C-07A? Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�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 1 • ApOtion for Permit to Drill,Well 1C-152 Revision No.0 Saved:29-Jun-15 1C-04 is permitted as a West Sak Producer. 13 3/8"surface casing set at 2910'MD (2708'TVD). 9 5/8" casing set at 6936'MD (6258 TVD) and 254 bbls of lead followed by 55.5 bbls of Class G tail cement was pumped. Top of West Sak sands logged at 4126'MD (3716'TVD). Total of 254 bbls of cement pumped covering 4912'to 2024'MD. Cement job went to plan. 1C-05 is permitted as a West Sak Injector. 10 3/4"surface casing set at 2782' MD (2695'TVD). 7"casing set at 7723'MD (7024'TVD)and 115 bbls of lead followed by 60 bbls of Class G tail cement was pumped. Top of West Sak sands logged at 4024'MD (3770'TVD). Total of 175 bbls of cement pumped covering 6424'to 1299'MD. Cement job went to plan. ✓ Se not a rroS, w SA 1C-06 is permitted as a West-S;akc Injector. 10 3/4"surface casing set at 3287 MD (2685'TVD). 7"liner set at 10226'MD (7090'TVD) and 143 bbls of lead followed by 59 bbls of Class G tail cement was pumped. Top of West Sak sands logged at 5332'MD (3834'ND). Total of 202 bbls of cement pumped covering 7544'to 2682'MD. Cement job went to plan. z C ,i-of .cc rosy 14 sa k 1 - is permitted as a West Sak WAG Produce . 9 5/8"surface casing set at 6945'MD (4439'TVD). 7" casing-set at 10465'MD.(6373'TVD) and 23 bbl of Class G cement was pumped. Surface casing was set deeper than the West Sak sands so we do have cement across the West Sak interval. ✓ a C Lmf f o croS3 �✓ S� . 1C-13 is permitted as a West Sak Producer. 9 5/8"surface casing set at 5705'MD (4446'ND). 7"casing set at 8235'MD (6356'TVD) and 28 bbl of Class G cement was pumped. Surface casing was set deeper than the West Sak sands so we do have cement across the West Sak interval. w5^-11-- .0 C L"vt-r vv-f n c � �S 1C-18 is permitted as a West Sak Injector. 9 5/8"surface casing set at 4817'MD (4343'ND). 7"casing set at 7578'MD (6308'TVD) and 35 bbl of Class G cement was pumped. Surface casing was set deeper than the West Sak sands so we do have cement across the West Sak interval. I: 5G' CCrntvif ttCv055 VIS.� 29.Attachments K.1' 'ERSEDIED Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary -- — --- - T- ---- Attachment 4 Well Schematic v" h r r,,5- 1 C O 74-) Attachment 5 Quarter Mile Plat Attachment 6 Doyon 25 BOP Stack Configuration Attachment 7 Doyon 25 on 1C-153 SUPERSEDED 1C-152 PERMIT Page 13 of 13 Printed:29-Jun-15 • DA 1 C...i 52wpo4 6 . 787 Plan Summary pg--- \ - Top WSD Base Permafrost , -5 t 1 -- , § - 'D w ' cn ; 1; _ ri . 0 II o ''' I I I' I 1. 1 1 I fill ( i i 1 1 i 1 I , , • 0 3000 1 6000 9000 12000 ; < = • 2T x 421 110-3/4"x 13-1/217-5/8"x 9-7/81asured Depth ; . , , • , c.--,,..07,_ 20"x 42'1 Geodetic Datum: North American Datum 1983 0 .... . .....irir , , . , Depth Reference: Plan:60+39.5 @ 99.50usft(Doyon 25) < , , • Rig: Doyon 25 - iiiiwmi i..._ ii 1413 , .<,.. tr) o 2. .., (00-3/4"x 13-1/21 ; , , . = - ‘P , 14-1/2 x 6-3/41 - 1' 17-5/8 x 9-7/T1 N ; ' • o 0 300. o 0 ct 50,,d:,, ri r, a/ . ri 0 r• 0 o . . < C") '43.... c2 A CD I,..0 ON 1 CV , .. _ ...... , ' .. . . . , - I I I I .-4 6 I `-'t I6 eggi I i 1 I I I I , 40 - 312 0 1500 300 4500 6000 7500 9000 0 312 - 500 Horizontal Departure 500 - 680 .fo.c2a I '11h1:. •_.i..t-;2j.,,.,2,.2..1111I11011 1.12,I,ll1:1:.-',.1,.-.-C2-.=,..---5-3---i,-t-p6--. A•i4ll0i*1%1#0i 1 860 - 1050 0 c60 - 1 3 _ 1 ,29PB1wp04 ,oej 680 - 860 1050 - 1230 'I: \ V)I110 1 1 10.- 1 1C-172A1 1C-29 wp04 300 . 60 1230 -- 1420 j.j. ' 1420 - 1600 (/) I ' -kc 12'' il • ,' ' 't-C-1721 < 1600 - 2050 2, 2050 2500 s's"10.1/2.AL2P132 41C-06 4.010 :114ii , , \ „de 1 II , , . tifigAIVIL --,- -,-,,,,,,g,. 2500 - 2950 (c-S 30 mrp If" \1G-172AL2PB1 4,,t4t-Ilekittilk,_ i ••••:, ii,......*•,: i 90 2950 - 3400 .2. . I 2"pvgekiAgormv3400 - 3850 Ic-172AL2 ..,,,,..,,,,----4-A-.. gijA,-...vt.•,-A ,,,,,p,a,n,--,.--„,,. !gfAeatAttgliZAVir :.' :;11Lli'411111414 3850 - 4300 1C-172AL1 0 i*-,,-„1,-.%,:-Vg.4,044P404,0 ,-'44--4%•.ftf4;kV 4300 - 4750 0 i 1 1 I I I I I I I I I I I I I I I I I 'Iw'JIN*742,..70g2r0.040k=24-24,-,4-40...w2.2222.-2..-....."W -2-2K -0,ss„,,,,,01 4750 - 5200 4.,,,,,,SP-KeZAVINife6.2041,;,WK;:,1,4, k," r '5200 - 6110 0 2000 4000 6000 8000 10000 12000 240 I0,A10. ...wtillte7ter.4tA74•20t.r.2k,z'--., V 120 5reiriktiV,. 6110 - 7030 SURVEY PROGRAM S,,, rip 4,, 1,ft,-,-- --ittititypr...ki, ,or 7030 - 7940 Surface Locationif;-4,1fr44,Vilf, 17' 7940 - 8850 , . ,'VOUj-I4P1..,,,V , ti Iepth From Depth To Survey/Plan Tool hc-,,i'l,,.0,1- ''''''..*'"*".` 1',1,yrilt.°Zitit'.-A.-• 8850 - 9770 39.50 1850.00 1C-152wp04(Plan 1C-152) GYD-GC-SS Pad Elevation:60.00 210 '''''''''''''''Aq'Z'u.2:21N1 1850.00 2770.77 1C-152wp04(Plan 1C-152) MWD \ i'•---;'''AiOZWL"1-• ' 9770 10680 T.o .. _.,.. 2770.77 4270.77 1C-152wp04(Plan 1C-152) MWD 180 10680 -"- 11590 2770.77 4912.18 1C-152wp04(Plan 1C-152) MWD+IFR-AK-CAZ-SC CASING DETAILS lic-•21 11590 - 12505 4912.18 6412.18 1C-152wp04(Plan 1C-152) MWD TVD MD Name Pit 4912.18 12505.27 1C-152wp04(Plan 1C-152) MWD+IFR-AK-CAZ-SC 119.50 119.50 20"x 42" Magnetic Model: BGGM2015 -r 2614.50 2770.77 10-3/4"x 13-1/2" Magnetic Model Date: 25-Aug-15 3839.50 4912.18 7-5/8 x 9-7/8" Magnetic Declination: 19.00° 3859.50 12505.27 4-1/2"x 6-3/4" To convert a Magnetic Direction to a True Direction,Add 19.00°East SECTION DETAILS -1811.5 Sec MD Inc Azi TVD 4-1,1/-S .I.E/-W Dleg TFace VSect Target Annotation 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 311.50 0.00 0.00 311.50 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5./100'DLS,0°TF,for 300.31' 3 611.81 4.50 0.00 611.50 11.80 0.00 1.50 0.00 11.40 Start 2.5./100'DLS,10°TF,for 303.37' 4 915.18 12.05 6.30 911.50 55.24 3.48 2.50 10.00 52.46 Adjust TF to 37°,for 925.5' 5 1840.68 33.51 31.67 1761.50 372.97 150.20 2.50 37.00 321.39 Hold for 119.93' 6 1960.61 33.51 31.67 1861.50 429.32 184.96 0.00 0.00 366.82 Start 4.1./100'DLS,165.96°TF,for 447.07' 7 2407.68 16.26 47.49 2265.94 577.91 296.85 4.10 165.96 481.39 Hold for 400' 8 2807.68 16.26 47.49 2649.93 653.62 379.42 0.00 0.00 533.14 Start 4.11100'DLS,-64.71°TF,for 1894.72' 9 4702.40 85.00 345.00 3828.50 1949.65 321.57 4.10 -64.71 1799.99 1C-152 01.Top D 27Oct14 DL Start 3.51100'DLS,6.32°TF,for 68.55' 10 4770.95 87.38 345.26 3833.05 2015.76 304.02 3.50 6.32 1868.39 Hold for 168.12' 11 4939.08 87.38 345.26 3840.73 2178.18 261.30 0.00 0.00 2036.33 Start 3.5./100'DLS,15.71°TF,for 77.62' 12 5016.69 90.00 346.00 3842.50 2253.34 242.05 3.50 15.71 2113.91 1C-152 02.T1 270ct14 DL Start 2./100'DLS,-67.99.TF,for 3.77' 13 5020.46 90.03 345.93 3842.50 2257.00 241.13 2.00 -67.99 2117.69 Hold for 1138.77' 14 6159.23 90.03 345.93 3841.94 3361.61 -35.71 0.00 0.00 3256.31 Start 21100'DLS,4.12°TF,for 48.71' 15 6207.95 91.00 346.00 3841.50 3408.86 -47.52 2.00 4.12 3305.01 1C-152 03.12 270c04 DL Adjust TF to-10.81°,for 115.21' 16 6323.15 93.26 345.57 3837.22 3520.46 -75.80 2.00 -10.81 3420.12 Hold for 341.35' 17 6664.51 93.26 345.57 3817.78 3850.50 -160.74 0.00 0.00 3760.90 Start 21100'DLS,169.17°TF,for 115.21' Base Permafrost 18 6779.71 91.00 346.00 3813.50 3962.09 -189.01 2.00 169.17 3876.01 1C-152 04.T3 27oct14 DL Adjust TF to-162.58°,for 42.98' 19 6822.70 90.18 345.74 3813.06 4003.77 -199.50 2.00 -162.58 3918.98 Hold for 1763.32' 20 8586.02 90.18 345.74 3807.52 5712.77 -633.77 0.00 0.00 5682.15 Start 21100'DLS,124.93°TF,for 15.7' 21 8601.71 90.00 346.00 3807.50 5728.00 -637.60 2.00 124.93 5697.84 1C-152 05.14 270ct14 DL Adjust TF to-104.77°,for 16.42' 22 8618.14 89.92 345.68 3807.51 5743.92 -641.62 2.00 -104.77 5714.27 Hold for 835.93' 23 9454.07 89.92 345.68 3808.73 6553.89 -848.34 0.00 0.00 6550.14 Start 21100'DLS,170.59°TF,for 97.12' 24 9551.19 88.00 346.00 3810.50 6648.04 -872.09 2.00 170.59 6647.22 1C-152 06.T5 270ct14 DL Start 2.98./100'DLS,135.71°TF,for 49.24' 25 9600.43 86.95 347.03 3812.67 6695.87 -883.56 2.98 135.71 6696.39 Hold for 265.32' 26 9865.75 86.95 347.03 3826.78 6954.05 -943.05 0.00 0.00 6961.18 Start 2.981100'DLS,-26.58°TF,for 76.94' 27 9942.69 89.00 346.00 3829.50 7028.81 -960.98 2.98 -26.58 7038.03 1C-152 07.T6 27Oct14 DL Start 21100'DLS,-102.71°TF,for 20.41' 28 9963E9 88.91 34E60 3829.87 7048.60 -965.99 2.00 -102.71 705844 Hold for 1222.79' 29 11185.88 88.91 345.60 3853.13 8232.77 -1269.99 0.00 0.00 8280.94 Start 21100'DLS,77.3°TF,for 20.41' 30 11206.29 89.00 34E00 3853.50 8252.55 -1275.00 2.00 77.30 8301.34 1C-152 08.T7 270ct14 DL Start 2.5./100'DLS,-8.69°TF,for 30.1' 31 1123E40 89.74 345.89 3853.83 8281.75 -1282.31 2.50 -8.69 8331.44 Hold for 1268.87' 32 12505.27 89.74 345.89 3859.50 9512.30 -1591.72 0.00 0.00 9600.15 1C-152 09.10 270ct14 DL TD:1250E27'MD,3859.5'ND 3821%0 WSD 10-By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured it's completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basis for the final well plan and wellsite drawings.I also acknowledge that,unless notified othemise,all targets have a 100 feet lateral tolerance. 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A N N LL a LL CO LL LL lL E C ❑ C ❑ C 021022 CI- 0 0 E CO C C`6 C CO `) C6 C (O CO (0 G CO 7 CO C CO CO C CO C CO CO CO N N (q a) O N O N O N O () N C T a a N N N r CO CA CO LO V N N 7 (n Q Q N N- N- N- O CO N CO N CO CO (C) U 7- CO O O O) V LO LO M CO. CC CY f6 r CO Cfl (O N Lf) V' M LO CO - •,-- U LL LL V co V CO 0 0 0 0 0 0 0 0 0 0 0 a 000 ,60 0 0 0 0 0 CD 2 O Ln O O N LO O O )O O O O .CO O N- O LO N N O CO N LO LO 0 CON M M V M LO N M W CA 16 7 N N p2 p V W LO N O N M LO CO O CO Cr CO V r N CO O r O r r o VVVMM 7- O CO CO CC N N C. y N- 7- N N N N CO W a N co O O O O CA r CT r O r - - d- a CA O 0, V M CO LO 0,-, M 2 00 O N CO r CO O LO V VC a • L - O V coM CO coM CO CC m ' N N N CO V CO LO N M O) C E. a W O V '- r- (V (V N d cu a L) Z d 0 N co - M O LO LO N CO M N N C CO CO CO CO N CO V r • E U N N u'i CD N M CO CO CO CO i C w N- 7- N N N M N N CO CO C V O• •E N O O 0as ^ ,_ p 6 a. A a a a. O O O O W N CA r O r N W a CA O O V CO CO LO CO CO CO Cr V V V V V C in Z., v W O W CO n O O LO V 4 SZ a a 11 fl Q N CL r C a =0. 2 L N Q y N N N co V M LO N co O) O) 3 3 3 3 3 3 2 W I C 3W CO p CO CO - CV (V N N N N N N U w N x CC f O O O O m O r v `- CO U U U U U U a 2 E .CO 'I CO _8 a 0) N O N m C L() ? E o r r 0 co r 3 a) co f m 0 c •EO r• r N• C c I 00 O O O N N CO o a) ❑C 0 O p C N O O a Q O N r N 6 V O C 3 r Tco C O' a 3 3 H V N V V CO N 9 CO CO E al F. .c."5 o $) 3 3 co CO a 2 3 N a 7 m LO LO V U N 0 )O W U a) J J 0 s- O O▪ 'm0 C (4 C a `o v v Cl. T N CO - m — c CD m o 7 7 c� r) a s m O O r r W W 2 �' aN) rn i 0 LL a, 0 0 LO Ln 3 3 0 d c4 LO O r r o d, - C O R 16 Cu Z 3 .- - h- Lo a N i O) O O O N N CO C - OO 'y C Nl c m U U 3 U O o m M m rn GI. N 0 y -c d }) C a 9 O O C C U N LL .C.. N N '7 •V O U N N L CO CO � N a a CO CO ' U C CO N (6 CO v a m a v 3 3 m -0) Co O (n v v r r m o P 0) C a) ' v i+• N ' i J J w m (0 CD E 0 3 E v v 'v 0 o U U U CA CCt d `• o CO CO c a)0 LO x CO N CO N- - N 6 O`" o a cN m z U U c c ° ° ° ° 3 0 C 0. 7 LO - a U U x- U CO CO c c z 0 CO CO m N L Y O CO d N N �- LL N N .Z C C O C p w Qi c E v CO0 d d y La 'm CO c n CO c C O C C C CO r M M r r i i m ',In C C 0 • Z O) O CO lO Cu m LO LO LO (A W E m .La) a) O -0 COV▪- 'm O m d m n. 0_ LL T v .- - - .- N N 1-3 r .a C CC = A CO V V ,d, C C U U U U U U N N a) LL O IO• C CO ✓a z 0. N- N- N- Lb 00 2 -O C m C U y .T U C a E C C C C C C C O C U C C co m w CO CO CO CO CO CO a) U C O }1 U d . U U U U U U d d 11 LL a. LL C N C (0 N t0 0) U Cr) Q CO CO m CD CD y < F` y W o us ❑ 0 Q • View w 1157 June 12 2015 L e1 1C-152w 04 ad e pThe Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. 2 o a . I� 3 ryygi — ti 0 U (GAL) (L)U oo ci 8 300 41, f� 1P1111x1, i ' In fi ii n _I r 1 I li ! 1111 HI L\ ' III I , Y C O tlolll�,n'6II I to l,i II Ig,I j 1 1 It ! 'd i I PI 4��IdiI��1�fllll1 ��r di ail 150 911elkll�, Ii® �pIDllpl I I 'I. Ii._ ®�itmllllifil FII1 ijo�� )�I1'i1 11111��1 I 1 � 009; i� 1 II' Ifo i - nnpUlllllllllillll 1 l� Illi IN Ilea..1 U _ dill r��I>� aUl lhl 01 I Bili plV�li I SII .,Iafi lglulgliiMlle 1 Equivelant Magnetic Distance I I I I I I I I I I I I I I 1 1 1 I I I I I I I 1 I I 0 2000 4000 6000 8000 10000 12000 Displayed interval could be less than entire well:Measured Depth 39.50 To 12505.27 SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.50 1850.00 1C-152wp04 (Plan 1C-152) GYD-GC-SS 119.50 119.50 20"x 42" 1850.00 2770.77 1C-152wp04 (Plan 1C-152) MWD 2614.50 2770.77 10-3/4" x 13-1/2" 2770.77 4270.77 1C-152wp04 (Plan 1C-152) MWD 3839.50 4912.18 7-5/8"x 9-7/8" 2770.77 4912.18 1C-152wp04 (Plan 1C-152) MWD+IFR-AK-CAZ-SC 3859.50 12505.27 4-1/2"x 6-3/4" 4912.18 6412.18 1C-152wp04 (Plan 1C-152) MW D 4912.18 12505.27 1C-152wp04 (Plan 1C-152) MWD+IFR-AK-CAZ-SC E. :1 F- U U o o so II I1E1 ilk ' $( I , 1 1 01 , 1 1 . 1 o fcsI iI 1 1111 in �0"4� ` T - 1- . . 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Ius-ft ®' ,i , r, [ : Legal Description(NAD27 only) Starting Coordinates: Legal Description X: 11701901.45 _ Township: Range 011 N 010 t ': 159613707.97 Meridian: u .. Section: l2 � 1....., JFNL 11279.0840 [ -�- � FFEL -r14415.2719 F. Transform Quit Help 1 C-152wp04 Top West Sak D ttj CPA.Coordinate Converterili »,L :22.1,...-L- --From: To: Datum INAD83 Region: Ialaska l Datum: JNAD27 Region: alaska ad Latitude/Longitude Decimal Degrees r r Latitude/Longitude Decimal Degrees UTM Zone: l-" South r 'JTM Zone: True,... r South State Plane Zone: .. Units: us ft CState Plane Zone: True Units: rus-ft Legal Description(N D27 only) r-Starting Coordinates. ----- ____W Legal Description---__ i X: 11702207.00 Township: Range: l 011 N 1010 E Y: 15970660.00 l i [ ' Meridian: U ,.• Section: 1i FNL 14609.4931 FEL 1. 14092A531 -..,, -rartsforrri i Quit Help • • 1C-152wp04 Intermediate Casing I P,t i Coordinate Converter ,7. x Fr Oro To: . Datum: NNAD83 -- Region: alaska T Datum: INAD27 Region: ski J C Latitude/Longitude !Decimal Degreesl C Latitude/Longitude [Decimal Degrees • UTM Zone: 1 r South r UTM Zone: True r South • State Plane Zone: 4 Ur ts: `us-ft C State Plane Zone: .r.True Units: .• us ft r°"h m e-e D.,- ,,,h°r f tN ,C?27 -r1F 31 t Legal Description(11,A027 only) Starting Coordinates: i < Legal Description - X: 11702151.91 Township: 1011 N .. Range 010E A Y: 15970862' Meridian: u , aection: 1 • FNL 14406.9386 FEL T 14145.7563 1 / t. Transform Quit Help 11 1 C-152wp04 TD Froin: To: Datum NAD83 Region: alaska ! ( Datum: NAD27 Region: alaska " atitude/Longitude Decimal Degrees ___ t Latitude/Longitude [Decimal Degrees UTM Zone: 1 r South r UTM Zone: True fl South *' State Plane Zone: 4 , Units: us-ft �. C°` State Plane Zone: True .. Units: us-ft Legal Description(NAD27 only) Stag Coordinates:_ .. _ , Legal Description w...a..- z. , X: 1700232.00 Township: 1012 N Range: 010 1E I Y 15978206,00 ? Meridian: U Section: 35 Fl. NI_ 12327.0132 FEL 720.80615 i Transform QuitHelp hM✓w.rc __..i '::a rn new n -_ �sauwr�: r.i3.♦.'.9i.i2&u1QMWcii.tJ:�Y','3ilWti..vmwu .sm.,:.,x�m+«;.�:w« • • 1C-152 Drilling Hazards Summary 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures,Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds,proper hole filling (use of trip sheets), pumping out Washouts/Hole Sloughing Low Cool mud temperatures, minimize circulating times when possible 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight,use weighted sweeps. Stuck Pipe Low Good hole cleaning,pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM Anti-Collision Moderate Follow real time surveys very closely, shut in 1D-117. Hole swabbing on trips Moderate Trip speeds,proper hole filling(use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning,PWD tools monitoring and analysis, decreased mud weight Lost Circulation Moderate Reduced pump rates,mud rheology, LCM program, additional fluid stored on location during completion run. Differential Sticking Moderate Follow mud program,keep pipe moving when able Hole Swabbing on Trips Moderate Trip speeds,proper hole filling (use of trip sheets),pumping out or backreaming Fault Crossings and Moderate Use developed best practices for concretion drilling. Concretions Getting Liner to Bottom Moderate Maintain solids free water based mud properties and lubricity while running liner lower completion, monitor torque and drag. Attachment 2-1C-152 Drilling Hazards Summary 6/29/201512:36:44 PM 1 C-152 Schlumberger CemCADE Preliminary Job Design 10 3/4" Surface Casing (V2) Preliminary Job Design based on limited input data.For estimate purposes only. Volume Calculations and Cement Systems Rig: Doyon 25 Volumes are based on 250%excess in the permafrost and 50% excess below the Location: Kuparuk permafrost. The top of the tail slurry is designed to be at 2271' MD. Client: CPAI Revision Date: June 29, 2015 Prepared by: Jenna Houston Location:Anchorage, AK Lead Slurry Minimum pump time: -240 min. (pump time plus 120 min.) Phone: (907)263-4207 DeepCRETE @ 11.00 ppg -1.91 ft3/100 lb sk Mobile: (907)223-8916 email:jhouston2@s1b.com 1.339 ft3/ft x 120 x 1.0 (0% excess) = 161 ft3 0.3637 ft3/ft x(1876-120) x 3.50 (250% excess) = 2236 ft3 < TOC at Surface 0.3637 ft3/ft x(2271-1876) x 1.50 (50% excess) = 216 ft3 2236 ft3+ 161 ft3+216 fti= 2612 ft3 2613 ft3/1.91 ft3/sk = 1369 sks (-1379 sks) Have additional 11#on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: -190 min. (pump time plus 120 min.) 12.0 ppg DeepCRETE-1.63 ft3/1001b sk 0.3637 ft3/ft x(2771-2271) x 1.50 (50% excess) = 273 ft3 0.54000 ft3/ft x 80' (Shoe Joint) = 44 ft3 273 ft3+44 ft3 = 317 ft3 317 ft3/1.63 ft3/sk = 195 sks Round up to 205 sks BHST= 59°F, Estimated BHCT =72°F. (Based on 2.1°F/100 ft. from surface) PUMP SCHEDULE < Base of Permafrost at Stage Cumulative 1'876'MD Stage Pump Rate Stage Time Volume Time (bpm) (bbl) (min) (min) CW 100 7.00 75.0 10.7 10.7 MUDPUSH II 7.00 75.0 10.7 21.4 Pause 0.00 0.0 5.0 26.4 < Top of Tail at 11 ppg DeepCRETE 7.00 465.1 66.4 92.8 Lead 2,271'MD Surface Tail 7.00 56.3 8.0 DeepCRETE Slurry 100.8 Pause 0.00 0.0 5.0 105.8 Fresh Water 7.00 10.0 1.4 107.2 Pause 0.00 0.0 5.0 112.2 Drilplex 8.00 238.8 29.9 142.1 Drilplex 3.00 10.0 3.3 145.4 < 10 3/4",45.5#casing MUD REMOVAL in 13.5"OH Expected Mud Properties:9.3 ppg, Pv<20, Ty<20 TD at 2,771 MD Spacer Properties: 10.5 ppg MudPUSH* II, Pv 17-21, T„m 20-25 (2,615'TVD) Centralizers: As per CPAi program. Mark of Schlumberger 1 C-1 52 ' . SCMUMberger CemCADE Preliminary Job Design 7 5/8" Intermediate (V2) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 25 Volume Calculations and Cement Systems Location: Kuparuk Client: CPAi Revision Date:June 29, 2015 Volumes are based on 40%excess. Prepared by:Jenna Houston Location:Anchorage, AK Tail Slurry Minimum thickening time: -190 min. (pump time plus 120 min.) Phone: (907)263-4207 15.8 ppg Class G +adds- 1.16 ft3/sk Mobile: (907)223-8916 email:jhouston2@slb.com 0.2148 ft3/ft x(4912'-2921')x 1.4(40% excess) = 599 ft3 Shoe Volume: 0.2578 ft3/ft x 80' x 1.00 (no excess) = 21 ft3 Totals: 599 ft3+21 ft3= 620 ft3 620 ft3/1.16 ft3/sk = 535 sks (545 sks) BHST= 101 °F, Estimated BHCT=79 °F. (BHST calculated using a gradient of 2.1 °F/100 ft. from surface) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) MUDPUSH II 6.00 40.0 6.7 6.7 10 3/4",45.5#casing Pause 0.00 0.0 5.0 11.7 at 2771'MD Tail Slurry 6.00 110.3 18.4 30.1 Pause 0.00 0.0 5.0 35.1 Fresh Water 6.00 10.0 1.7 36.8 Pause 0.00 0.0 5.0 41.8 Mud 6.00 201.9 33.7 75.5 Top of Tail at Mud 3.00 10.0 3.3 78.8 end of pumping < 2912'MD MUD REMOVAL Recommended Mud Properties:9.4 ppg, Pv<20, Ty<20. As thin and light as possible to aid in mud removal during cementing. 7 5/8",29.7# Spacer Properties: 11.5 ppg MudPUSH* II, Pv 25-30, TY 30-40 in 9 7/8"hole Centralizers: As per CPAi program TD at--4912'MD (3839'TVD) Mark of Schlumberger • • . , f . ' HP ' ' 8 I 1 O r Y 1 I y 1 I1 I I 1 I1 1 I 1 ; 1 'O 9 L C 3 W m `vim z I 1 •,a.G ' ; I 1 1 0 ' :a P. ©/� I � I.. I N ' 1 O m Q G T I 1 U a. t ---5I C i`1 1 N 1 II 1 I " on ' U m v b •v g 0s ..x0 4, •E ,-a a U (V> Q .W x�� H ,, „, . N,,, . : ,t. gi.z. u ® 1 G - N q ,..., ,....),„ O C C O N:2^ c 1 \ C� a 4 x v o vi:. 5.a.D x ri ' 6 _^ + � V�\ .. ;El �_ z, y M V A i a 52 - U c '2 `O m o• E. wry_m z c c M am mNp � l pFt0 C F Wm 9 a V.2 y_ rJOL IV,`°. T W c d V N O i a F, h r NMI Y00 ' o 3 :a 1' 1��1 1 l i Well Schematic 1C-152(Injector) 1C_152PIanSchematicWP04 1::��In(�� EE ii 6,29/2015 ityl3 a)-n r ma arinca p•rru rr ern n-t..- -- • we CL CO 1H-13 1H-15 a C-11 11 C-1 1 iA 1C-174 t 1C-170 l C-11 1C-178L1 • 1 H-09 : ,1C-178 {t •1C-111 -0 1 V 1t-11 L1-02 44025638 ic-it i ADL047449 Ab 02564 I:lC-0C-07AL1P: `, ADL028242 ' 1C0 N W AK 1 • A 1c_06 1 1C-19 1C-16 1 e7APB1 1C-07A i \ ‘ • • • 1 C-17811 PB2 41 1 C-13 1 C 08L'F 1 \i' t .\.. 1C-081; _ C-170RB1 1C L1PB1 • 1C 14 1C-e / 1C-1511 1641.1 \1C-178LBi .J' t ' \ i Legend :..":1D-103 :r **. West Sak Sands • ' .... syr. Open Section • }4f ''`�;:, f'•, ! 1C152TRAJ t}' WSAKSWPT ►,``\, Well Trajectory 1C-119 r '"1 O-1 17 ��\ ��' _ 1 -08A A.--.............'_: .....—... ' �� . i 1 •VVell Pad B SURV '` EY_POINTS NAD83 V Events r (, {, C-. ' :1` f KRU — — j'. I t 1 C-03A•°•• ' ••-• NAK • 1C-104P131......7' •1'C�172AL2PB1, • 014411'1 . WSAK 1 : r•. t: / ill if-133 ' ATDB.WELL HEADER NAD83 V Events d1C-121 t /.•' :' C-01L1-02 — — _ •. -123 •I a 1D-10i Producer:Oil I:: • • INJ: MWAG ` •"lt-24 i • i • NN hil INJ: PW 1C;03 '&'1 C-1022 i E 1 1 1 C )2 '- Suspended/Inactive/OPSH 1 1C-102L1 .1L-1D8L1 - P+A c q L 3 1 C-172AL2PB2 • t LAK Units 1 11 C- 0A 1 1 1C-17211c.1 27 '4 D-143L3 fe��°'`'A�1�L�2241D-143L1 : i_--jAK Participating Areas-black aW2-91 ..i.L2 1 C-13! . 1 C-125 A •1, _ • 1 1C152TRAJqtrBuff •161-11402 1 i-1.. D-140 ADL. Gravel 10'.14 k1 D-14011 I ICPAI �1D-111 A1D-01 ; z • 1D ConocoPhillips 4 • +- 1 Alaska, Inc. 1D-113 ::t D- �' D-14. ' °s�?� ?QA 1C-152 1/4 Mile Radius with West Sak Sand Penetrations • 10-114 ' •'�••'•. i,10-109 Q9 N x.25 Q.5 E . • 1:1 D Y 11\ Mies r OE ' ' 1..11-1-13 ,,1F1-15 1 C-11[1 c.-1 1 1C-1741C-17O 1` C-11 01C-17RL1 7';• - \ ,1H-00 1C-178 \ �9 C 11 L -0 ry 1' -11 L11-02 y . i • • ADL047449 A .92 8 01c-1:71. I� C- ; � � ; 1C-Q7AL' � �'k A .r 12 4 0 .1 1 C,07AL 1 P 1 �-77. A L9282 2 '; 1C-0 01C-06„a0-1 C-19 1 C-16 . 1 i7APB1 W.SAK 1 1C-07A . ./ ' 1 / 1. 1C 178t {P82 t 1C-13 1C-08L';111 � 1 C-081. ^ ..� , _ l� • C170R81 A1C i•L1PB1 19 -08, , 7 1 C- 14 1Gr . 1C15L1 X‘—`1-67-*;8 � I 1C=111 Legend 1 C 178E B1 �; ;� i 9 • '1D-103 �• ' • ' West Sak Sands .° , _ _.__. 1C1520PEN a°, ria Open Section 1 C *- LAK S'N13 Well Trajectory 10119 *• •10197 +► . .;: ` . 1 -08A ------.;;;?4,i, .. ,� `' ' I 1 Well Pad a 1C=44 ' ATDB.SURVEY POINTS_NAD83_V Events i.,,,. 1 a"• 1 KR U 1 s1C;03d • •. �.ti, NAK ^' g. ;i°C 172AL2P8101 C1 • WSAK £.1 C-104P81,,.= , 1 C-01 L1-021 ATDB.WELL_HEADER_NAD83_,V Events • .• PI:: • � .... 133 ;, ;;.*::: . I 1 C-121 C 123x 1 Ll-1 R Producer:C7l • • . INJ: MWAG s 24 .* ' INJ: PW a 10;03 '".1 .11%1...111 1002 ; SuspendedlinactivelOPSH : 1Q2L1 ..1-A,1 •,- P+A R =1 C-1 4°"1 .1 C-172ALAPB2 x _.IAK Units 2 1 C-10 10172 r '1 Q 143L3 : _ 1 0 � 1 C-127 ;11 -143L1 ° I !AK Participating Areas-black . 1 1C-1;i 1 11 2 1 %ALL *' '—; . 1` 1C152Tf2AJgtrBuff 1121 t-70: �i �-140 A Gravel a `� ' D-140L1 m , 1 1CPAI 1 GA14 , a 1D-111. 1D 01 ;y .1E} 1© t�nt�CoPhillips a ° it ae 11'G ska,Inc. . 1D113 '.;� t1»10A -14{ P A -, )• Sak114 SandMile PenetrationsRadiuswith •.. 1D-114:- s N '"'`•. 1 t?-1 0 a 00:.75 05 ' • 0 91'1_ 'r.. • • I i a 25 BOP Configuration veil# Top of Rofatv Tok)ie . , m .__. _ _„ ---- "Shaffer M_ Annular b S 1 � o ; 13.5 Shier . -S �"Shaffer SIVI (~hBlind Harm sN A ..RA� d"YfiNh6h "'-'-'+L'. { ',...R hiAttili __ MANUAL HC R f 11110 1S11 i El) Ear !r 'oke Line 1 I -5 8 Shaffer 5M x,7/8" VBA 0 r-----...... • / ...,.... "' 3 `'` — x • m i O < xoi-clE .' .,, I ,fTl rt SP aN o -0— C _ II O C] m'',II -o-i- -0 P. n ,i 12 i 01 , ❑17 8 II- 0 ra�R 1 '1 11 8102 rrrI I ❑104 ❑106 ❑10 I 01091.,- . ❑111 `:: :" ❑113 �� 53 °0115 1314 151 ° ' II ❑117 ❑119 16 r hi (/) ❑121 — 1 • 0123 5 El - m ❑125 18 m ❑ m gL127 j m ❑129 4 ❑ 172-E113 1 0 131 = 174❑ nj ❑133 = ❑135 28❑ 151 ° n 14 ❑178❑ 0* 3 El _ D �- � 150 ° v ! 21 ❑ v . 20❑ 155 ° 0 :513 70 0 N 1 15❑"— -i- .. 2 ❑- I 24❑=-..— .�2 ❑ E 4 Fp 10 ❑ 25F1.- - E 26❑ 190❑ z 27C " No N 1 LLJ�J ➢7 O 1 z 0 m 0 NP N r O N In m C) • • Bettis, Patricia K (DOA) From: Hyden, Duncan P <Duncan.P.Hyden@conocophillips.com> Sent: Monday,July 06, 2015 6:10 AM To: Bettis, Patricia K (DOA) Subject: RE: KRU 1C-152: Permit to Drill Application (PTD 215-114) Good morning Patricia, ConocoPhillips does not plan on pre-producing at this time. Thanks, Duncan Duncan Hyden Ord;nF i:ngn er Direct:907 289 0802 ( Mobile:907 917.1910 duncan.p.hylenf"7a cop.corn From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday,July 01, 2015 3:29 PM To: Hyden, Duncan P Subject: [EXTERNAL]KRU 1C-152: Permit to Drill Application (PTD 215-114) Good afternoon Duncan, Does ConocoPhillips plan to pre-produce the KRU 1C-152, and if so,for what duration? 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 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, July 01, 2015 3:29 PM To: duncan.p.hyden@cop.com Subject: KRU 1C-152: Permit to Drill Application (PTD 215-114) Good afternoon Duncan, Does ConocoPhillips plan to pre-produce the KRU 1C-152, and if so,for what duration? 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 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 Patricia Bettis at(907)793-1238 or patricia.bettis( alaska.gov. 1 • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITTAL LETTER CHECKLIST WELL NAME: KRL 1S Z PTD: 15 -1l y Development 'Service Exploratory Stratigraphic Test _Non-Conventional FIELD: �miJ` POOL: g,U, k, ,S Check ,S./� (�! Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) 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 Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion,suspension or abandonment of this well. Revised 2/2015 s • 00 co • p a 0. N Cl) C' N c (0 Q U' co co 0 W cn ° t, > a 0, c m' • E O ° 3 W o rn 0 ° '� 3 Q a C)); a)a a), N. O; �; a' a o. , . �, a a ❑ O N ' a C I— Df a. f0 00O 0 3' N D 06O L CE rO Q >. 3 C; In VOA � •3� °� � N. . `� U a- a; c� --0 �; n: �: o �� W: o; �, �; I- H _i .c 33 E V; m a E; c(13 a r") o a 4 , o. co ❑ M; O i' . a d� ao Y W cN co c� CO �� 0 4 m: 0, N. �� E. f d �; c. a �i; �, N E. 3. '00.5a. '� 4 Y c �; E' o 0 'o a)' Y, >., �, E' CD •o -a5, ;' ca W. O. V• a N. c, a). U. 0 ' �' . U' a o. ,ya. 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