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Home My WebLink About216-082ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 27, 2025 FFROM:Anu Ambatipudi TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC 700 G Street 333 W.7th Ave., Suite 100 Anchorage AK 99501 Anchorage, Alaska DATA TRANSMITTAL Kuparuk River Unit/Field Well API #PTD #Comments 1H-112 50029237870100 2240320 3B-16A 50029212890100 2231250 2B-03B 50029211510200 2230800 2M-39 50103207950000 2181710 3S-612 50103207770000 2181110 3S-611 50103207740000 2181030 1H-108B 50029236080200 2180820 1H-110 50029236010000 2180310 1H-116 50029235940000 2180120 2S-06 50103207470000 2160850 2M-37 50103207450000 2160820 1D-39 50029229970000 2002160 1D-40A 50029229690100 2001900 2N-302 50103203800000 2011150 1R-03A 50029214060100 2000210 3H-37 50103208220000 2191940 2S-09A 50103207490100 2161280 T40450 T40451 T40452 T40453 T40454 T40455 T40456 T40457 T40458 T40459 T40460 T40461 T40462 T40463 T40464 T40465 T40466 By Gavin Gluyas at 1:15 pm, May 28, 2025 2M-37 50103207450000 2160820 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD5-31 50103208280000 2210020 CD5-96 50103208110000 2191620 CD4-499 50103208100000 2191610 CD5-26 50103208060000 2191070 CD5-98 50103208030000 2190590 CD5-24 50103207990000 2190060 CD5-23 50103207610000 2171550 CD5-19 50103207600000 2171210 CD5-22 50103207590000 2170890 CD5-316 50103207560000 2170400 CD3-111A 50103205260100 2170040 CD3-198 50103206370000 2110240 CD4-24 50103206020000 2090970 CD4-26 50103206000000 2090490 CD2-15 50103203860000 2011590 CD2-12 50103204550000 2030730 CD4-214 50103205370000 2061450 CD4-17 50103205340000 2061180 CD2-73 50103205900000 2081960 T40467 T40468 T40469 T40470 T40471 T40472 T40473 T40474 T40475 T40476 T40477 T40478 T40479 T40480 T40481 T40482 T40483 T40484 T40487 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT7-99 50103208450000 2221020 T40485 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2M-37 (PTD: 216-082) Suspected Integrity IAxOA Date:Monday, March 24, 2025 10:24:18 AM Attachments:AnnComm Surveillance TIO for 2M-37.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Friday, March 21, 2025 2:07 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2M-37 (PTD: 216-082) Suspected Integrity IAxOA Hi Chris, CPAI has concluded our monitoring of the IA and OA pressures for possible communication in KRU 2M-37 (PTD 216-082). When the PWI rate stabilized the IA and OA pressure remained stable and separate. We’ve also recently monitored the well on gas injection with the same conclusion. Please let me know if you have any questions, the TIOs, bleed log and schematic are attached. Thank you. Jaime Bronga From: Well Integrity Specialist CPF2 Sent: Thursday, December 12, 2024 11:10 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2M-37 (PTD: 216-082) Suspected Integrity IAxOA Hi Chris, KRU 2M-37 (PTD 216-082) is a WAG injection well with a canceled AA for IAxOA. The AA - AIO 2C.048 Amended - which was cancelled on July 12, 2024 was for slow IAxOA communication through suspected thread leaks in the production casing. A 2024 RWO replaced the upper 500’ of production casing. Following, the well was monitored and did not exhibit signs of IAxOA communication. In review of the TIO plots this month, this well is exhibiting possible slow IAxOA communication. CPAI intends to conduct monitoring of the well and confirm the communication and direction of communication. Please let me know if you have any questions or disagree with this plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2M-37 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2M-37 2025-03-04 365.0 120 -245.0 OA 2M-37 2025-03-15 1.0 37 36.0 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (stalled out due to deviation) 13,459.0 2M-37 2/6/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull IBP 2M-37 5/19/2024 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE:pproven NOTE: WAIVERED FOR IAXOA COMMUNICATION 7/4/2019 freebd Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 32.0 162.0 162.0 94.00 H-40 SURFACE 13 3/8 12.42 30.3 3,150.9 2,653.6 68.00 L-80 HYD 563 LINER INTERMEDIATE I 9 5/8 8.84 2,025.8 12,450.0 5,751.3 40.00 L-80 BTCM Tie-Back String 7" re- run top 500' 7 6.28 0.0 12,253.2 5,685.7 26.00 L-80 BTC-m LINER INTERMEDIATE II 7 6.47 12,243.5 13,894.0 6,054.7 26.00 L-80 TSH 563 LINER PROD. 4 1/2" 4 1/2 3.96 13,729.5 17,484.2 6,038.0 12.60 L-80 TXP-M Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 13,783.0 Set Depth … 6,046.9 String Max No… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.0 25.0 0.30 Hanger 13.500 4.5" FMC Gen V Tubing Hanger, H- BPV (5" ACME Top x 4 1/2" BTBG- M Btm) FMC MM# 1339000 4, PN# P100087 918 3.900 11,592.3 5,466.2 70.54 Mandrel 3.500 3.5" x 1" SLB KBMM GLM (SN#: 20893-18) slb PN: 12131- 01, Ser #20893- 18 2.818 12,680.3 5,827.7 70.77 Nipple - DB, XN, DS, D 3.500 3.5" x 2.813" DS-Nipple (No-Go) HYD563 BxP (SN#: 427336-01) Camco PN: 33376- 000- 0002, SN: 427337- 01 2.813 13,733.0 6,043.1 85.45 Locator 4.990 Baker Locator (4.99" OD No-Go) Baker PN: H453-01 -0065, Control # 1056688 98 2.990 13,734.6 6,043.2 85.46 Seal Assembly 3.500 Baker 80-40 Seal Assembly (6' space out), (SN#: NOR57943-0003- 01) Baker PN: H453-01 -0065, Control # 1056688 98 3.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 11,592.3 5,466.2 70.54 1 GAS LIFT DMY BK 1 5/7/2024 SLB KBMM Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 0.0 0.0 0.00 D141 ORKB to load shoulder 28.07'. Nordic 3 RKB to load shoulder = 28.00' 0.000 D141 ORKB to load shoulder 28.07'. Nordic 3 RKB to load shoulder = 28.00' 0.000 12,240.3 5,681.5 70.73 Locator 7.000 7" BTC-M Box X HYD513 Pin, No- Go Crossover (8.25" OD No-Go) 6.276 13,729.5 6,042.8 85.44 PACKER 5.000 Baker HRD-E ZXP 5" x 7" Liner top packer L-80 5" Hyd 521 pin - 165' liner lap Baker PN: H296- 45-0109, Control # 103516216 4.340 13,749.4 6,044.3 85.51 NIPPLE 5.000 Baker 5" "RS" Packoff Seal Nipple 15 ppf L-80 Hyd 521 box x box Baker H294-01- 0553, Control No.: 104247694 4.260 15,424.8 6,084.4 89.78 Swell Packer 4.500 Baker 5.75" OD Self Energizing Reactive Packer Assy B - 63' above fault Baker SN# 50154880- 04, FSC- 124 Rubber Compound 3.930 15,626.0 6,082.6 92.89 Swell Packer 4.500 Baker 5.75" OD Self Energizing Reactive Packer Assy A- 128' below fault Baker SN# 50154880- 05, FSC- 124 Rubber Compound 3.930 HORIZONTAL, 2M-37, 5/20/2024 1:02:30 AM Vertical schematic (actual) LINER PROD. 4 1/2"; 13,729.4- 17,484.2 LINER INTERMEDIATE II; 12,243.5-13,894.0 Nipple - DB, XN, DS, D; 12,680.3 BALL & ROD; 12,674.3 LINER INTERMEDIATE I; 2,025.8-12,450.0 Tie-Back String 7" re-run top 500'; 0.0-12,253.2 Mandrel; 11,592.3 SURFACE; 30.3-3,150.9 CONDUCTOR; 32.0-162.0 Hanger; 25.0 KUP INJ KB-Grd (ft) 27.42 RR Date 1/1/2017 Other Elev… 2M-37 ... TD Act Btm (ftKB) 17,510.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032074500 Wellbore Status INJ Max Angle & MD Incl (°) 94.09 MD (ftKB) 15,702.03 WELLNAME WELLBORE2M-37 Annotation Last WO: End Date 4/19/2024 H2S (ppm) DateComment SSSV: NIPPLE CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2M-37 (PTD: 216-082) Suspected Integrity IAxOA Date:Thursday, December 12, 2024 2:10:05 PM Attachments:AnnComm Surveillance TIO for 2M-37.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Thursday, December 12, 2024 11:10 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2M-37 (PTD: 216-082) Suspected Integrity IAxOA Hi Chris, KRU 2M-37 (PTD 216-082) is a WAG injection well with a canceled AA for IAxOA. The AA - AIO 2C.048 Amended - which was cancelled on July 12, 2024 was for slow IAxOA communication through suspected thread leaks in the production casing. A 2024 RWO replaced the upper 500’ of production casing. Following, the well was monitored and did not exhibit signs of IAxOA communication. In review of the TIO plots this month, this well is exhibiting possible slow IAxOA communication. CPAI intends to conduct monitoring of the well and confirm the communication and direction of communication. Please let me know if you have any questions or disagree with this plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2M-37 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2M-37 2024-12-11 725 300 -425 OA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (stalled out due to deviation) 13,459.0 2M-37 2/6/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pull IBP 2M-37 5/19/2024 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE:pproven NOTE: WAIVERED FOR IAXOA COMMUNICATION 7/4/2019 freebd Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 32.0 162.0 162.0 94.00 H-40 SURFACE 13 3/8 12.42 30.3 3,150.9 2,653.6 68.00 L-80 HYD 563 LINER INTERMEDIATE I 9 5/8 8.84 2,025.8 12,450.0 5,751.3 40.00 L-80 BTCM Tie-Back String 7" re- run top 500' 7 6.28 0.0 12,253.2 5,685.7 26.00 L-80 BTC-m LINER INTERMEDIATE II 7 6.47 12,243.5 13,894.0 6,054.7 26.00 L-80 TSH 563 LINER PROD. 4 1/2" 4 1/2 3.96 13,729.5 17,484.2 6,038.0 12.60 L-80 TXP-M Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 13,783.0 Set Depth … 6,046.9 String Max No… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.0 25.0 0.30 Hanger 13.500 4.5" FMC Gen V Tubing Hanger, H- BPV (5" ACME Top x 4 1/2" BTBG- M Btm) FMC MM# 1339000 4, PN# P100087 918 3.900 11,592.3 5,466.2 70.54 Mandrel 3.500 3.5" x 1" SLB KBMM GLM (SN#: 20893-18) slb PN: 12131- 01, Ser #20893- 18 2.818 12,680.3 5,827.7 70.77 Nipple - DB, XN, DS, D 3.500 3.5" x 2.813" DS-Nipple (No-Go) HYD563 BxP (SN#: 427336-01) Camco PN: 33376- 000- 0002, SN: 427337- 01 2.813 13,733.0 6,043.1 85.45 Locator 4.990 Baker Locator (4.99" OD No-Go) Baker PN: H453-01 -0065, Control # 1056688 98 2.990 13,734.6 6,043.2 85.46 Seal Assembly 3.500 Baker 80-40 Seal Assembly (6' space out), (SN#: NOR57943-0003- 01) Baker PN: H453-01 -0065, Control # 1056688 98 3.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 11,592.3 5,466.2 70.54 1 GAS LIFT DMY BK 1 5/7/2024 SLB KBMM Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 0.0 0.0 0.00 D141 ORKB to load shoulder 28.07'. Nordic 3 RKB to load shoulder = 28.00' 0.000 D141 ORKB to load shoulder 28.07'. Nordic 3 RKB to load shoulder = 28.00' 0.000 12,240.3 5,681.5 70.73 Locator 7.000 7" BTC-M Box X HYD513 Pin, No- Go Crossover (8.25" OD No-Go) 6.276 13,729.5 6,042.8 85.44 PACKER 5.000 Baker HRD-E ZXP 5" x 7" Liner top packer L-80 5" Hyd 521 pin - 165' liner lap Baker PN: H296- 45-0109, Control # 103516216 4.340 13,749.4 6,044.3 85.51 NIPPLE 5.000 Baker 5" "RS" Packoff Seal Nipple 15 ppf L-80 Hyd 521 box x box Baker H294-01- 0553, Control No.: 104247694 4.260 15,424.8 6,084.4 89.78 Swell Packer 4.500 Baker 5.75" OD Self Energizing Reactive Packer Assy B - 63' above fault Baker SN# 50154880- 04, FSC- 124 Rubber Compound 3.930 15,626.0 6,082.6 92.89 Swell Packer 4.500 Baker 5.75" OD Self Energizing Reactive Packer Assy A- 128' below fault Baker SN# 50154880- 05, FSC- 124 Rubber Compound 3.930 HORIZONTAL, 2M-37, 5/20/2024 1:02:30 AM Vertical schematic (actual) LINER PROD. 4 1/2"; 13,729.4- 17,484.2 LINER INTERMEDIATE II; 12,243.5-13,894.0 Nipple - DB, XN, DS, D; 12,680.3 BALL & ROD; 12,674.3 LINER INTERMEDIATE I; 2,025.8-12,450.0 Tie-Back String 7" re-run top 500'; 0.0-12,253.2 Mandrel; 11,592.3 SURFACE; 30.3-3,150.9 CONDUCTOR; 32.0-162.0 Hanger; 25.0 KUP INJ KB-Grd (ft) 27.42 RR Date 1/1/2017 Other Elev… 2M-37 ... TD Act Btm (ftKB) 17,510.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032074500 Wellbore Status INJ Max Angle & MD Incl (°) 94.09 MD (ftKB) 15,702.03 WELLNAME WELLBORE2M-37 Annotation Last WO: End Date 4/19/2024 H2S (ppm) DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2M-37 KUPARUK RIV UNIT 2M-37 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 2M-37 50-103-20745-00-00 216-082-0 W SPT 6043 2160820 1800 1887 1880 1875 1877 430 2000 1945 1935 REQVAR P Sully Sullivan 6/22/2024 MIT-OA to 1800 psi per AIO 2C.048 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 2M-37 Inspection Date: Tubing OA Packer Depth 514 854 846 839IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240624194645 BBL Pumped:4.6 BBL Returned:4.4 Thursday, July 25, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 MIT-OA AIO 2C.048 OA James B. Regg Digitally signed by James B. Regg Date: 2024.07.25 15:00:19 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2M-37 KUPARUK RIV UNIT 2M-37 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 2M-37 50-103-20745-00-00 216-082-0 W SPT 6043 2160820 3000 1884 1884 1881 1877 466 776 778 783 REQVAR P Sully Sullivan 6/22/2024 MITIA to MAIP per AIO 2C.048 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 2M-37 Inspection Date: Tubing OA Packer Depth 500 3310 3260 3250IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240624194227 BBL Pumped:4 BBL Returned:3.7 Thursday, July 25, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9MITIA AIO 2C.048 James B. Regg Digitally signed by James B. Regg Date: 2024.07.25 14:55:26 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replace Tubing Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 17510'feet 13853'feet true vertical 6038' feet None feet Effective Depth measured 13459'feet 2026', 13729'feet true vertical 6020'feet 1920', 6043'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth)3-1/2" L-80 13783' 6047' Packers and SSSV (type, measured and true vertical depth)2026' 13729' 1920' 6043' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Kuparuk Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 324-132 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker HRD-E ZXP Packer: Baker HRD-E ZXP SSSV: None Dusty Ward dusty.ward@conocophillips.com (907) 265-6531Staff RWO/CTD Engineer None None 1650'7" measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf MDSize 162' Well Shut-In measured TVD 9-5/8" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 216-082 50-103-20745-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025586, ADL0025585 Kuparuk River Field/ Kuparuk Oil Pool KRU 2M-37 Plugs Junk measured LengthCasing 5751' 5686' 12450' 12253' 13894'6055' 3124' 162'Conductor Surface Intermediate 20" 13-3/8" 135' 3151'2654' Burst Collapse Liner 3754'4-1/2"17484'6038' Tie-Back Intermediate 2 10424' 12226' Fra O s 6. A PG , C g Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 11:08 am, May 16, 2024 RBDMS JSB 052124 DSR-5/20/24 Page 1/5 2M-37 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/11/2024 14:00 4/11/2024 18:00 4.00 MIRU, MOVE MOB P Pull support equipment away from rig (cuttings tank and highline trailer). Pull berm down from around cellar. Move off 2M-03. Prep 2M-37 for backing over well. Spot well head equipment (Tbg head adapter) behind well. Back over 2M-37 0.0 0.0 4/11/2024 18:00 4/11/2024 22:00 4.00 MIRU, MOVE RURD P Rig up and safe out over well. Spot cuttings tank and High-line Trailer. Complete pre-accept checklist. Rrep pits to bring on seawater. Spot cuttings tank. RU hardline to tiger tank and open top tank. 0.0 0.0 4/11/2024 22:00 4/12/2024 00:00 2.00 MIRU, MOVE RURD P Take on 9.3# Brine. Rig up circ. manifold and cellar hoses for well kill operations. **** Rig Accepted @ 00:00 4/12/24 0.0 0.0 4/12/2024 00:00 4/12/2024 01:30 1.50 MIRU, WELCTL PRTS P Flood lines to tiger tank and open top. PT hardline to 2500 psi. Blow down lines. 0.0 0.0 4/12/2024 01:30 4/12/2024 04:00 2.50 MIRU, WELCTL WAIT P Wait for truck of 9.3 show up from 1B. 0.0 0.0 4/12/2024 04:00 4/12/2024 07:30 3.50 MIRU, WELCTL KLWL P Verify tank straps and confirm 35 bbl deep clean pill is built. Pump 35 bbls deep clean pill. Kill well w/ 9.3# KWF @ 4BPM and 900 psi. Swap to open top with 320 bbls in tiger tank. Measure clean 9.3# KWF brine at IA returns. Pumped a total of 570 bbls of KWF. SD pumps. 0.0 0.0 4/12/2024 07:30 4/12/2024 08:00 0.50 MIRU, WELCTL OWFF P Blowdown lines. OWFF for 30-min. 0.0 0.0 4/12/2024 08:00 4/12/2024 09:30 1.50 MIRU, WELCTL MPSP P Install H Type BPV. Test BPV 1000 psi 10 min from below. Good test. Blowdown lines. 0.0 0.0 4/12/2024 09:30 4/12/2024 11:00 1.50 MIRU, WELCTL RURD P Rig down circulating hoses. Prep cellar for ND operations. 0.0 0.0 4/12/2024 11:00 4/12/2024 22:30 11.50 MIRU, WELCTL NUND P ND Tree. Set test plug. Tubing Hanger neck threads in good condition. Plan to re-use tubing head adapter. NU 13 5/8" spacer spool (1.8' tall blanked off flow cross). NU BOP's. Change LPRs to 7" fixed. Perform BWM on BOP stack. 0.0 0.0 4/12/2024 22:30 4/13/2024 00:00 1.50 MIRU, WELCTL OTHR P Perform BWM 0.0 0.0 4/13/2024 00:00 4/13/2024 03:00 3.00 MIRU, WELCTL OTHR P Perform BWM. 0.0 0.0 4/13/2024 03:00 4/13/2024 05:00 2.00 MIRU, WHDBOP RURD P Measure RKBs // Rig up bop test equipment // Flood lines shell test. Found leak @ kill swivel connections. Tightenup and retest. Good test. 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/19/2024 Page 2/5 2M-37 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/13/2024 05:00 4/13/2024 15:00 10.00 MIRU, WHDBOP BOPE P Initial BOPE test, Tested BOPE at 250/3000 PSI for 5 Min each, Tested annular, UVBR's w/ 3 1/2" test joints. Annular would not test with 3 1/2" Test Joint. Continue on with remaining tests and repair annular tests after bag is replaced. Test blinds rams. Test LPR (Fixed 7" Rams) and Annular w/ 7" test jt 250/3000 5min each Choke valves #1 to #13, upper and lower top drive well control valves. Test 3 1/2" IF FOSV and IBOP. Test 3 ½” EUE FOSV. Test 2" rig floor Demco kill valve MM #13. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=3000 PSI, after closure=1650 PSI, 200 PSI attained =22 sec, full recovery attained =114 sec. UVBR's= 3 sec, LPR’s= 3 sec. Annular= 14 sec. Simulated blinds= 3 sec. HCR choke & kill= 1 sec each. 4 back up nitrogen bottles average =2150 PSI. Test gas detectors, PVT and flow show. Witness waived by AOGCC rep Kam St.John 0.0 0.0 4/13/2024 15:00 4/13/2024 18:30 3.50 MIRU, WHDBOP BOPE T Continue with BOP testing past allocated time 0.0 0.0 4/13/2024 18:30 4/14/2024 00:00 5.50 MIRU, WHDBOP BOPE T Trouble time. Replace annular and retest w/ 3 1/2" and 7" Test Joints. On trouble time until final BOP test is completed. 0.0 0.0 4/14/2024 00:00 4/14/2024 10:45 10.75 MIRU, WHDBOP BOPE T Trouble time. Replace annular and retest w/ 3 1/2" and 7" Test Joints. On trouble time until final BOP test is completed. 0.0 0.0 4/14/2024 10:45 4/14/2024 11:15 0.50 COMPZN, RPCOMP RURD P Rig down test equipment. Blow down surface lines. 0.0 0.0 4/14/2024 11:15 4/14/2024 14:00 2.75 COMPZN, RPCOMP SLPC P Slip and Cut Drill Line. 0.0 0.0 4/14/2024 14:00 4/14/2024 14:30 0.50 COMPZN, RPCOMP RURD P Drain Stack. RU GBR pipe handling equipment. 0.0 0.0 4/14/2024 14:30 4/14/2024 15:00 0.50 COMPZN, RPCOMP MPSP P Pull test dart and BPV. 0.0 0.0 4/14/2024 15:00 4/14/2024 15:30 0.50 COMPZN, RPCOMP THGR P Make up 4.5" x 5" RH-ACME landing jt // Screw in TD. Set 10K down. BOLDS. Function test casing head also. Good. LDS's Pull hanger to rig floor dragging @ 110 K (pulled free from hanger @ 100K). Suck hanger over to DS to clear top of riser. 13,782.0 13,754.0 4/14/2024 15:30 4/14/2024 17:30 2.00 COMPZN, RPCOMP CIRC P Circ BU (6500 strokes). 13,754.0 13,754.0 4/14/2024 17:30 4/14/2024 18:15 0.75 COMPZN, RPCOMP OWFF P OWFF for 30-minutes. L/D landing joint and Tubing Hanger 13,754.0 13,754.0 4/14/2024 18:15 4/15/2024 00:00 5.75 COMPZN, RPCOMP CIRC P Well unbalanced due to light fluid in pits // Weight up pits to 9.3 // Circ S x S to balance well still out of balance // Circ 3rd B/U well ballanced // flow check static 13,754.0 13,754.0 Rig: NORDIC 3 RIG RELEASE DATE 4/19/2024 Page 3/5 2M-37 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/15/2024 00:00 4/15/2024 05:30 5.50 COMPZN, RPCOMP PULL P Pull 3 1/2" Completions from 13,754' to 3,744'. Replaced GLM @ 2,800' with new Full Joint #1 @ 31.10' long. Replaced GLM @ 5,896' with new Full Joint #2 @ 30.00' long. Replaced GLM @ 8,348' with new Full Joint #3 @ 30.97'. Replaced GLM @10,200' with new Full Joint #4 @ 30.94'. 13,754.0 3,744.0 4/15/2024 05:30 4/15/2024 06:00 0.50 COMPZN, RPCOMP SVRG P Crew C/O. Rig Service. Service Crown. Repair bailer brake coolant system. 3,744.0 3,744.0 4/15/2024 06:00 4/15/2024 10:00 4.00 COMPZN, RPCOMP PULL P Cont. pulling 3 1/2" Completions from 3,744' to surface. Did not replace GLM @ 11,581' with new joint. Will replace GLM length at at top of 3 1/2" during re- run. Total of 4 new 3 1/2" Joints used to make full stands during TOOH. No other bad joints found. Kickout junk completions jewelry. Kickout Seals for redress. Kickout DS Nipple to be sent to WL shop for RHC plug. 3,744.0 0.0 4/15/2024 10:00 4/15/2024 10:30 0.50 COMPZN, RPCOMP CLEN P Clean and clear rig floor. 0.0 0.0 4/15/2024 10:30 4/15/2024 15:30 5.00 COMPZN, RPCOMP RURD P Reconfigure GBR power tongs for 7" casing. Drain Stack. Prep to pull 7" pack-off. RU OA bleed. Spot bleed tank. Bleed OA to 0 psi. Bled off small volume of diesel. Bleed of residual gas. Monitor open bleed for 30-min. 0 psi. No build up. 0.0 12,253.0 4/15/2024 15:30 4/15/2024 20:15 4.75 COMPZN, RPCOMP THGR P PU 3 ½” IF working joint w/ XO, and FMC pack-off running tool (4 ½” IF Box x Pin). BOLDS. Pull pack-off. Pulled free @ 25K over. MU landing Joint. Screw into 7" mandrel hanger. Pull 7" hanger out of casing head. Unseated @ 315K. PU 5'. Close bag. Mark Landing Joint. Attempt to pull seals free from SBE. PU to 370K. SD. Slack off to neutral. Trap 500 psi on 7" (against IBP). Repeart PU to 370K. Gained 2'. Repeat cycle w/ 600 psi against IBP. Gained 0.5'. Final attempt with 700 psi against IBP (850 psi differential). Pulled to 380K. Seals unstung from SBE. Wt dropped off to 215K. See 400 psi on backside. Trapped pressure dropped off. Confirmed unstung. Mark Landing Joint. Measured 11.9' to unsting from SBE. Est 12.5' stroke below the bag. Very close. Close bag with 750 psi pressure. 12,253.0 12,241.0 4/15/2024 20:15 4/15/2024 21:30 1.25 COMPZN, RPCOMP DISP P Circ BU to clear OA freeze protect. 5 BPM @ 425 psi. Circing out OA freeze protect (gelled diesel/Isotherm). Pumped 401 BBLS 9.3# Brine down 7" Casing taking OA returns. Pumped pits empty. Backside return density <8.4# (diluted Iso-Therm freeze protect). SD Pumps. Backside pressure at xxx psi. 12,241.0 12,241.0 Rig: NORDIC 3 RIG RELEASE DATE 4/19/2024 Page 4/5 2M-37 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/15/2024 21:30 4/16/2024 00:00 2.50 COMPZN, RPCOMP WAIT T Waiting on Vac Trucks for more 9.3# Brine. Kuparuk Wells Dispatch sold out. No upright tanks available either. 3rd party vac truck options (Worley) are stuck behind rig move in Prudhoe. 12,241.0 12,241.0 4/16/2024 00:00 4/16/2024 05:00 5.00 COMPZN, RPCOMP WAIT T Waiting on Vac Trucks for more 9.3# Brine. Kuparuk Wells Dispatch sold out. No upright tanks available either. 3rd party vac truck options (Worley) are stuck behind rig move in Prudhoe. // Fluid on location @ 04:45 fill pits w/ 9.3 Brine 12,241.0 12,241.0 4/16/2024 05:00 4/16/2024 06:00 1.00 COMPZN, RPCOMP CIRC P Circulate 150 bbls fluid down tubing up OA // Mud wt out 9.5 - 9.7 not cleaned up shut down to wait for truck of 9.3 12,241.0 12,241.0 4/16/2024 06:00 4/16/2024 08:00 2.00 COMPZN, RPCOMP WAIT T Waiting on Vac Trucks for more 9.3# Brine. Kuparuk Wells Dispatch sold out. No upright tanks available either. 3rd party vac truck options (Worley) are stuck behind rig move in Prudhoe. // Fluid on location @ 04:45 fill pits w/ 9.3 Brine 12,241.0 12,241.0 4/16/2024 08:00 4/16/2024 09:00 1.00 COMPZN, RPCOMP OWFF P Observe well for flow for 30-min. Open Bag. 12,241.0 12,241.0 4/16/2024 09:00 4/16/2024 12:00 3.00 COMPZN, RPCOMP PULL P Pull 7" hanger to the rig floor. L/D landing joint and 7" hanger. Pull ~500' 7" casing. PUW = 265K, Inspect 7" casing for thread damages or holes. Suspect leak at approx. 380'. 12,241.0 11,741.0 4/16/2024 12:00 4/16/2024 14:30 2.50 COMPZN, RPCOMP PUTB P Run 7" 26# HYD 563 casing as per Tally. Torque Turn 7" HYD563 to 9,300 Ft-Lbs. 11,741.0 12,241.0 4/16/2024 14:30 4/16/2024 15:30 1.00 COMPZN, RPCOMP THGR P Pick up casing mandrel hanger make up to casing // Run in below bag close ensure circulation // Run down 10' engage seals test with pump 500psi good test confirm good space out // Pick up below bag for circulating CI and freeze protect 12,241.0 12,241.0 4/16/2024 15:30 4/16/2024 18:00 2.50 COMPZN, RPCOMP WAIT T Wait for truck of CI no available trucks and ours had 2 flat tires 12,241.0 12,241.0 4/16/2024 18:00 4/16/2024 19:30 1.50 COMPZN, RPCOMP RURD P Blow down hardline, Blow down cement line. Off load 290 bbls 9.3 PPG to 1B storage. 12,241.0 12,241.0 4/16/2024 19:30 4/16/2024 22:36 3.10 COMPZN, RPCOMP DISP P Space out, Close annular, Displace 290 BBls 9.3 PPG CI followed by 255 BBls diesel FP, FCP=500 PSI @ 5 BPM 12,241.0 12,241.0 4/16/2024 22:36 4/16/2024 22:54 0.30 COMPZN, RPCOMP PACK P Strip in 7" casing. Land 11.40' Rig down circ equipment 12,241.0 12,252.0 4/16/2024 22:54 4/17/2024 00:00 1.10 COMPZN, RPCOMP BOPE P Break out and lay down landing joint. M/U pack off running tool. Set packoff, Run in LDS 12,252.0 12,252.0 4/17/2024 00:00 4/17/2024 01:00 1.00 COMPZN, RPCOMP PACK P Run in LDS for 7" pack off. Test. Unable to get test 12,252.0 12,252.0 4/17/2024 01:00 4/17/2024 04:30 3.50 COMPZN, RPCOMP PACK T Trouble shoot pack off. Reset and re torque LDS. No good. P/U Landing joint. pull packoff. No seals appear damaged. All O rings look good. Get back up pack off heading this way. 12,252.0 12,252.0 4/17/2024 04:30 4/17/2024 06:30 2.00 COMPZN, RPCOMP PACK P New packoff on location, Prep and run // Test 5000psi good test 12,252.0 12,252.0 Rig: NORDIC 3 RIG RELEASE DATE 4/19/2024 Page 5/5 2M-37 Report Printed: 5/14/2024 Operations Summary (with Timelog Depths) Job: RECOMPLETION Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 4/17/2024 06:30 4/17/2024 09:00 2.50 COMPZN, RPCOMP PRTS P Rig and pressure test OA 1800 psi 30min ( 100 stks @ .0583bbls/stk ) // First test pass but with dip in middle // Line up re-test 1800psi 30 min ( 94 stks @ .0583 bbls/stk ) 12,252.0 12,252.0 4/17/2024 09:00 4/17/2024 10:00 1.00 COMPZN, RPCOMP CLEN P Rig down test equipment // Clean up floor from PT of OA 12,252.0 0.0 4/17/2024 10:00 4/17/2024 11:00 1.00 COMPZN, RPCOMP RURD P Rig up to run 3.5" completion 0.0 0.0 4/17/2024 11:00 4/17/2024 22:00 11.00 COMPZN, RPCOMP PUTB P Pick up and run 3.5" completion Hyd 563 with torq turn 0.0 12,860.0 4/17/2024 22:00 4/18/2024 00:00 2.00 COMPZN, RPCOMP PUTB T Service loop caught tong lift cylendeter damaging hydraiulic fitting. Shut down to repair 12,860.0 129,102.0 4/18/2024 00:00 4/18/2024 03:30 3.50 COMPZN, RPCOMP PULD P Continue in 12912 to 13687. wash down from 13687 to pressure increase @ 13769' top of PBR. Fully locate @ 13875., PUW=103K. SOW=69K. Lay down 3 joints. Make up space out pups 9.73' and 9.68', P/U 31.32. P/U hanger and hanger pup 12,912.0 13,785.0 4/18/2024 03:30 4/18/2024 05:30 2.00 COMPZN, RPCOMP DISP P PJSM, Displace 7" X 3 1/2" annulas to CI 9.3 PPG brine 13,785.0 13,785.0 4/18/2024 05:30 4/18/2024 06:30 1.00 COMPZN, RPCOMP PACK P Run hanger into well. 25.6'. Set down 10 K. FMC to run in LDS's 13,785.0 13,785.0 4/18/2024 06:30 4/18/2024 09:30 3.00 COMPZN, RPCOMP RURD P Rig up to pt tubing and casing // Bleed air from lines // leak in gasket replace with new // 13,785.0 0.0 4/18/2024 09:30 4/18/2024 11:30 2.00 COMPZN, RPCOMP PRTS P Pressure test Tubing 3500psi 30 min // Bleed down tubing to 1500psi // Pressure test IA 3000psi 30min // Shear SOV 0.0 0.0 4/18/2024 11:30 4/18/2024 13:00 1.50 COMPZN, WHDBOP RURD P Rig down test equipment and pull landing jt 0.0 0.0 4/18/2024 13:00 4/18/2024 14:30 1.50 COMPZN, WHDBOP MPSP P Install BPV , test 1000 psi 5 min good test Blow down circulating equipment in cellar and R/D 0.0 0.0 4/18/2024 14:30 4/18/2024 17:30 3.00 COMPZN, WHDBOP NUND P Nipple down BOPs, ND 13 5/8" spacer spool. Prep hanger neck 0.0 0.0 4/18/2024 17:30 4/18/2024 18:30 1.00 COMPZN, WHDBOP NUND P Nipple up production tree 0.0 0.0 4/18/2024 18:30 4/18/2024 20:30 2.00 COMPZN, WHDBOP NUND P Nipple up old tree with old tubing head adapter. Test hanger void 5K / 10 minutes. Open SSV. 0.0 0.0 4/18/2024 20:30 4/18/2024 22:00 1.50 COMPZN, WHDBOP RURD P Rig up LRS to test tree and pump FR 0.0 0.0 4/18/2024 22:00 4/18/2024 23:12 1.20 COMPZN, WHDBOP PRTS P Fill tree purging air. Test LRS lined to 5K. Pressure test to 5K. Needle valve on tree leaking. Bleed off. Change out valvr. Start retest. 0.0 0.0 4/18/2024 23:12 4/19/2024 00:00 0.80 COMPZN, WHDBOP MPSP P Good test on tree. Bleed off. R/U and pull BPV 0.0 0.0 4/19/2024 00:00 4/19/2024 01:12 1.20 DEMOB, MOVE DISP P Pump 80 BBls freeze protect diesel down IA 0.0 0.0 4/19/2024 01:12 4/19/2024 02:12 1.00 DEMOB, MOVE OTHR P S/D pump FPP=1150 PSI @ b2 BPM. Rig up U tube. Allow fluid to you tube one hour 0.0 0.0 4/19/2024 02:12 4/19/2024 02:42 0.50 DEMOB, MOVE RURD P Rig down surface you tube 0.0 0.0 4/19/2024 02:42 4/19/2024 06:00 3.30 DEMOB, MOVE MOB P Work rig down check lists / RDMO RIG RELEASE 0600 0.0 0.0 Rig: NORDIC 3 RIG RELEASE DATE 4/19/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (stalled out due to deviation) 13,459.0 2M-37 2/6/2024 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled SOV, set DMY. Pulled B&R and RHC. 2M-37 5/8/2024 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE:pproven NOTE: WAIVERED FOR IAXOA COMMUNICATION 7/4/2019 freebd Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 32.0 162.0 162.0 94.00 H-40 SURFACE 13 3/8 12.42 30.3 3,150.9 2,653.6 68.00 L-80 HYD 563 LINER INTERMEDIATE I 9 5/8 8.84 2,025.8 12,450.0 5,751.3 40.00 L-80 BTCM Tie-Back String 7" re- run top 500' 7 6.28 0.0 12,253.2 5,685.7 26.00 L-80 BTC-m LINER INTERMEDIATE II 7 6.47 12,243.5 13,894.0 6,054.7 26.00 L-80 TSH 563 LINER PROD. 4 1/2" 4 1/2 3.96 13,729.5 17,484.2 6,038.0 12.60 L-80 TXP-M Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 0.0 Set Depth … 13,783.0 String Max No… 3 1/2 Set Depth … 6,046.9 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.0 25.0 0.30 Hanger 13.500 4.5" FMC Gen V Tubing Hanger, H- BPV (5" ACME Top x 4 1/2" BTBG- M Btm) FMC MM# 1339000 4, PN# P100087 918 3.900 11,592.3 5,466.2 70.54 Mandrel 3.500 3.5" x 1" SLB KBMM GLM (SN#: 20893-18) slb PN: 12131- 01, Ser #20893- 18 2.818 12,680.3 5,827.7 70.77 Nipple - DB, XN, DS, D 3.500 3.5" x 2.813" DS-Nipple (No-Go) HYD563 BxP (SN#: 427336-01) Camco PN: 33376- 000- 0002, SN: 427337- 01 2.813 13,733.0 6,043.1 85.45 Locator 4.990 Baker Locator (4.99" OD No-Go) Baker PN: H453-01 -0065, Control # 1056688 98 2.990 13,734.6 6,043.2 85.46 Seal Assembly 3.500 Baker 80-40 Seal Assembly (6' space out), (SN#: NOR57943-0003- 01) Baker PN: H453-01 -0065, Control # 1056688 98 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 13,853.0 6,052.3 86.11 IBP 2 1/8" IBP 10.84' OAL 1.375" JDC FISHING NECK 3/21/2024 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 11,592.3 5,466.2 70.54 1 GAS LIFT DMY BK 1 5/7/2024 SLB KBMM Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 0.0 0.0 0.00 D141 ORKB to load shoulder 28.07'. Nordic 3 RKB to load shoulder = 28.00' 0.000 D141 ORKB to load shoulder 28.07'. Nordic 3 RKB to load shoulder = 28.00' 0.000 12,240.3 5,681.5 70.73 Locator 7.000 7" BTC-M Box X HYD513 Pin, No- Go Crossover (8.25" OD No-Go) 6.276 13,729.5 6,042.8 85.44 PACKER 5.000 Baker HRD-E ZXP 5" x 7" Liner top packer L-80 5" Hyd 521 pin - 165' liner lap Baker PN: H296- 45-0109, Control # 103516216 4.340 13,749.4 6,044.3 85.51 NIPPLE 5.000 Baker 5" "RS" Packoff Seal Nipple 15 ppf L-80 Hyd 521 box x box Baker H294-01- 0553, Control No.: 104247694 4.260 15,424.8 6,084.4 89.78 Swell Packer 4.500 Baker 5.75" OD Self Energizing Reactive Packer Assy B - 63' above fault Baker SN# 50154880- 04, FSC- 124 Rubber Compound 3.930 HORIZONTAL, 2M-37, 5/14/2024 10:45:41 AM Vertical schematic (actual) LINER PROD. 4 1/2"; 13,729.4- 17,484.2 LINER INTERMEDIATE II; 12,243.5-13,894.0 IBP; 13,853.0 Nipple - DB, XN, DS, D; 12,680.3 BALL & ROD; 12,674.3 LINER INTERMEDIATE I; 2,025.8-12,450.0 Tie-Back String 7" re-run top 500'; 0.0-12,253.2 Mandrel; 11,592.3 SURFACE; 30.3-3,150.9 CONDUCTOR; 32.0-162.0 Hanger; 25.0 KUP INJ KB-Grd (ft) 27.42 RR Date 1/1/2017 Other Elev… 2M-37 ... TD Act Btm (ftKB) 17,510.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032074500 Wellbore Status INJ Max Angle & MD Incl (°) 94.09 MD (ftKB) 15,702.03 WELLNAME WELLBORE2M-37 Annotation Last WO: End Date 4/19/2024 H2S (ppm) DateComment SSSV: NIPPLE Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 15,626.0 6,082.6 92.89 Swell Packer 4.500 Baker 5.75" OD Self Energizing Reactive Packer Assy A- 128' below fault Baker SN# 50154880- 05, FSC- 124 Rubber Compound 3.930 HORIZONTAL, 2M-37, 5/14/2024 10:45:42 AM Vertical schematic (actual) LINER PROD. 4 1/2"; 13,729.4- 17,484.2 LINER INTERMEDIATE II; 12,243.5-13,894.0 IBP; 13,853.0 Nipple - DB, XN, DS, D; 12,680.3 BALL & ROD; 12,674.3 LINER INTERMEDIATE I; 2,025.8-12,450.0 Tie-Back String 7" re-run top 500'; 0.0-12,253.2 Mandrel; 11,592.3 SURFACE; 30.3-3,150.9 CONDUCTOR; 32.0-162.0 Hanger; 25.0 KUP INJ 2M-37 ... WELLNAME WELLBORE2M-37 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 17510 None Casing Collapse Conductor Surface Intermediate 7" TIEBACK Intermediate 2 Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng None 1650' 4-1/2" None 17484'3754' 3-1/2" 6038' 7" 13-3/8" 9-5/8" 3124' 10424' Perforation Depth MD (ft): 7"12226' MD 2654' 5751' 5686' 3151' 12450' 6055'13894' 12253' Length Size Proposed Pools: 162' 162' TVD Burst PRESENT WELL CONDITION SUMMARY 135' 20" 6038' 13459 6020' 2177 13711' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025585, ADL025586 216-082 P.O. Box 100360, Anchorage, AK 99510 50-103-20745-00-00 ConocoPhillips Alaska, Inc. KRU 2M-37 NoneKuparuk River Oil PoolKuparuk River Field N/A Tubing Grade: Tubing MD (ft): Packer: 12244'MD/5683'TVD 13730'MD/6043'TVD SSSV: None Perforation Depth TVD (ft): Tubing Size: L-80 13783' 4/10/2024 Packer: Baker HRD-E ZXP Packer: Baker HRD-E ZXP SSSV: None 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dusty Ward dusty.ward@conocophillips.com (907) 265-6531 CTD/RWO Engineer Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:19 am, Mar 05, 2024 324-132 DSR-3/5/24 X X 10-404 A.Dewhurst 07MAR24 BOP test to 3000 psig Annular preventer test to 2500 psig X VTL 3/7/2024JLC 3/8/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.03.08 09:12:59 -09'00'03/08/24 RBDMS JSB 030824 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 4, 2024 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Dusty K Ward Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Injector 2M-37 (PTD# 216-082-0). Well 2M-37 was drilled and completed in January of 2017 as a WAG injector into the Kuparuk sands. The well has failed an MIT-OA by showing OA x IA communication. It is believed a thread is leaking around ~380' RKB on the 7" Production Casing. The well was pushed to RWO to repair the 7" casing leak so that it can be put on WAG injection. If you have any questions or require any further information, please contact me at +1503-476-2519. The tubing will be pulled. Then approximately ~500' of the 7" casing will be pulled and replaced. The 7" will be re- landed out. Then the 4.5" x 3.5" injection string will be re-ran. 2M-37 RWO Procedure Kuparuk Injector PTD #216-082 Page 1 of 2 Remaining Pre-Rig Work 1. IC-POT, IC-POTS, T-PPPOT, and T-POT tests. 2. Set IBP below SBE at 13772’ RKB in middle of one of the three 4.5” upper joints in the liner. 3. PT IBP and perform DDT to confirm isolated from formation. 4. Open lowest GLM in upper completion. Dummy off remaining GLMs. 5. Prepare well within 48 hrs of rig arrival. Rig Work MIRU 1. MIRU Nabors Nordic 3 on 2M-37. (No BPV will be set due to risk assessment done on Nordic 3.) 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3000 psi. Test annular 250/3000 psi. Retrieve Tubing Section and Replace Top Section of PC 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 4-1/2” x 3.5” tubing down to seal (~13735’ RKB) racking back completion. 6. Pull upper ~500’ of 7” casing. Re-run new 7”, 26#, HYD563 casing. Re-land in seals. a. Close annular and strip in/out as need to circulate out/in diesel in OA. Right when seals un-engage from SBE, diesel will want to utube. Reverse process when re-landing new 7”. Use annular for routine task of moving workover fluid above a plug. 7. Test OA to confirm good test. a. 1800 psig for at least 10 minutes. 8. Re-run 3.5” tubing. a. 4.5” hanger crosses over to 3.5” within first joint b. Swap GLMs for new tubing, except deepest GLM. c. Swab seals or any other part of tubing needed to be new. 9. Once on depth, set packer and space out as needed. Sting into seals. 10. Drop ball and rod. 11. Pressure test tubing to 3500 psi for 30 minutes and chart. 12. Pressure test inner annulus to 3000 psi for 30 minutes on chart. ND BOP, NU Tree 13. Confirm pressure tests, then shear out SOV with pressure differential. 14. Install BPV. 15. ND BOPE. NU tree. 16. Pull BPV, freeze protect well, and set BPV if necessary. 17. RDMO. Post-Rig Work 18. Pull ball and rod. 19. Install DV. 20. Pull RHC plug and IBP. 21. Turn over to production ops. 2M-37 RWO Procedure Kuparuk Injector PTD #216-082 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen V Unihead, 5M psi top flange Production Engineer: Adam Becia Reservoir Development Engineer: Kevin Wiggs Estimated Start Date: 4/10/2024 Workover Engineer: Dusty Ward (265-6531/ dusty.ward@conocophillips.com) Current Operations: This well is currently shut in. Well Type: Injector Scope of Work: Pull the existing 3-1/2” completion down through seals. Swap upper ~500’ of 7” casing for new. Re- run 3-1/2” completion. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Passed 6/27/2022 MIT-IA Failed 6/28/2022 MIT-OA Failed 6/18/2022 IC POT &PPPOT PASSED – 6/28/2024 TBG POT &PPPOT PASSED – 6/28/2024 MPSP: 2177 psi using 0.1 psi/ft gradient Static BHP: 2778 psi / 6014’ TVD measured on 02/08/2024 Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:2M-37 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added production casing leak @ 373' RKB (Vivid tools run 2/21/23) 2M-37 2/21/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE:pproven NOTE: WAIVERED FOR IAXOA COMMUNICATION 7/4/2019 freebd Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 20 19.12 32.0 162.0 162.0 94.00 H-40 SURFACE 13 3/8 12.42 30.3 3,150.9 2,653.6 68.00 L-80 HYD 563 LINER INTERMEDIATE I 9 5/8 8.84 2,025.8 12,450.0 5,751.3 40.00 L-80 BTCM 7" INTERMEDIATE TIEBACK 7 6.28 28.1 12,253.2 5,685.7 26.00 L-80 BTC-m LINER INTERMEDIATE II 7 6.47 12,243.5 13,894.0 6,054.7 26.00 L-80 TSH 563 LINER PROD. 4 1/2" 4 1/2 3.96 13,729.5 17,484.2 6,038.0 12.60 L-80 TXP-M Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 25.0 Set Depth … 13,783.0 Set Depth … 6,046.9 String Ma… 3 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd 563 ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 25.0 25.0 0.30 HANGER 13.500 4-1/2" FMC Tubing Hanger FMC MM# 1339000 4, PN# P100087 918 3.900 2,880.5 2,511.5 55.78 GAS LIFT 5.390 3-1/2" x 1" Camco KBMG w/ DV, 2,880' MD / 2511' TVD SN# 141AF07 Camco KBMG 2.915 5,895.8 3,612.5 70.14 GAS LIFT 5.390 3-1/2" x 1" Camco KBMG w/ DV, 5895' MD / 3612' TVD SN# 152AF07 Camco KBMG 2.915 8,341.8 4,409.6 71.77 GAS LIFT 5.390 3-1/2" x 1" Camco KBMG w/ DV, 8341' MD / 4409' TVD TVD SN# 145AF07 Camco KBMG 2.915 10,193.6 5,002.9 71.18 GAS LIFT 5.390 3-1/2" x 1" Camco KBMG w/ Dv, 10193' MD / 5003' TVD SN# 19436- 02 Camco KBMG 2.915 11,574.2 5,460.2 70.54 GAS LIFT 5.390 3-1/2" x 1" KBMG w/ DV, 11574' MD / 5460' TVD, SN#19436-04 Camco KBMG 2.915 12,631.0 5,811.5 70.74 GAS LIFT 3.500 3-1/2" x 1" KBMG DCK-2 SOV, 12630' MD / 5811' TVD, SN#19436- 03 Camco KBMG 2.818 12,689.1 5,830.6 70.77 NIPPLE 3.500 Camco 3-1/2" x 2.813" No-Go "DS" Nipple Hydril 563 SN# 427336-01 Camco PN: 33376- 000- 0002, SN: 427337- 01 2.813 13,710.8 6,041.3 85.37 PLUG - SHEARED OPEN 3.500 Mirage Plug, 775 psi Rupture disc installed, Rig did not shear ***SHEARED BY CTU POST RIG ON 1/13/17*** Halliburt on SAP # 1019995 34 2.880 13,733.3 6,043.1 85.45 LOCATOR 4.990 Baker Locator Baker PN: H453-01 -0065, Control # 1056688 98 2.990 13,734.5 6,043.2 85.46 SEAL ASSY 3.500 Baker 80-40 GBH Locator Seal Assembly Baker PN: H453-01 -0065, Control # 1056688 98 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 373.0 372.9 2.58 LEAK - CASING PRODUCTION CASING LEAK IDENTIFIED W/ARCHER VIVID LDL @ 373' RKB ON 2/21/23 2/22/2023 6.280 12,689.0 5,830.6 70.77 TUBING PLUG 2.812" CSA-2 Plug (27" OAL) 6/23/2022 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,880.5 2,511.5 55.78 1 GAS LIFT DMY BK 1 0.0 7/30/2017 CAMCO MMG 0.000 5,895.8 3,612.5 70.14 2 GAS LIFT DMY BK 1 0.0 7/30/2017 Schlumb erger Camco BK 0.000 8,341.8 4,409.6 71.77 3 GAS LIFT DMY BK 1 0.0 7/30/2017 Schlumb erger Camco BK 0.000 HORIZONTAL, 2M-37, 2/22/2023 5:09:12 AM Vertical schematic (actual) LINER PROD. 4 1/2"; 13,729.4- 17,484.2 Shoe; 17,474.5-17,484.2 Perf Pups; 17,356.1-17,396.6 Perf Pups; 17,194.2-17,234.7 Perf Pups; 17,031.4-17,071.8 Perf Pups; 16,869.6-16,909.4 Perf Pups; 16,707.8-16,747.6 Perf Pups; 16,544.6-16,585.0 Perf Pups; 16,380.9-16,421.5 Perf Pups; 16,218.5-16,258.5 Perf Pups; 16,057.0-16,097.4 Perf Pups; 15,894.6-15,934.7 Perf Pups; 15,731.4-15,771.8 Swell Packer; 15,626.0-15,636.6 Swell Packer; 15,424.8-15,435.4 Perf Pups; 15,329.1-15,369.6 Perf Pups; 15,166.3-15,206.7 Perf Pups; 15,003.3-15,043.9 Perf Pups; 14,842.1-14,882.7 Perf Pups; 14,681.0-14,720.0 Perf Pups; 14,520.0-14,559.2 Perf Pups; 14,357.3-14,397.7 Perf Pups; 14,196.4-14,235.7 Perf Pups; 14,036.9-14,076.7 Perf Pups; 13,915.3-13,955.3 LINER INTERMEDIATE II; 12,243.5-13,894.0 FLOAT SHOE; 13,891.1- 13,894.0 SBE; 13,772.1-13,791.2 LANDING COLLAR; 13,757.9- 13,761.4 SEAL ASSY; 13,734.5 HANGER; 13,752.3-13,761.5 NIPPLE; 13,749.4-13,752.3 PACKER; 13,729.4-13,749.4 LOCATOR; 13,733.3 PLUG - SHEARED OPEN; 13,710.8 TUBING PLUG; 12,689.0 GAS LIFT; 12,631.0 LINER INTERMEDIATE I; 2,025.8-12,450.0 FLOAT SHOE; 12,446.8- 12,450.0 FLOAT COLLAR; 12,405.9- 12,409.2 LANDING CLLAR; 12,360.9- 12,365.1 HANGER; 12,269.0-12,278.3 NIPPLE; 12,266.2-12,269.0 PACKER; 12,243.5-12,266.2 7" INTERMEDIATE TIEBACK ; 28.1-12,253.2 Seal Assembly; 12,241.7- 12,253.2 GAS LIFT; 11,574.2 GAS LIFT; 10,193.6 GAS LIFT; 8,341.8 GAS LIFT; 5,895.8 SURFACE; 30.3-3,150.9 Float Shoe; 3,147.7-3,150.9 GAS LIFT; 2,880.5 HANGER; 2,048.8-2,057.9 PACKER; 2,025.8-2,048.8 LEAK - CASING; 373.0 CONDUCTOR; 32.0-162.0 XO Reducing (Tubing); 56.4 Casing Hanger; 30.3-30.8 Casing Hanger; 28.1-29.3 HANGER; 25.0 KUP INJ KB-Grd (ft) 27.42 RR Date 1/1/2017 Other Elev… 2M-37 ... TD Act Btm (ftKB) 17,510.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032074500 Wellbore Status INJ Max Angle & MD Incl (°) 94.09 MD (ftKB) 15,702.03 WELLNAME WELLBORE2M-37 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 10,193.6 5,002.9 71.18 4 GAS LIFT DMY BK 1 0.0 7/30/2017 Schlumb erger Camco BK 0.000 11,574.2 5,460.2 70.54 5 GAS LIFT DMY BK 1 0.0 7/29/2017 Schlumb erger Camco BK 0.000 12,631.0 5,811.5 70.74 6 GAS LIFT DMY BK 1 9/19/2018 Schlumb erger Camco BK 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 13,729.5 6,042.8 85.44 PACKER 5.000 Baker HRD-E ZXP 5" x 7" Liner top packer L-80 5" Hyd 521 pin - 165' liner lap Baker PN: H296- 45-0109, Control # 103516216 4.340 13,749.4 6,044.3 85.51 NIPPLE 5.000 Baker 5" "RS" Packoff Seal Nipple 15 ppf L-80 Hyd 521 box x box Baker H294-01- 0553, Control No.: 104247694 4.260 15,424.8 6,084.4 89.78 Swell Packer 4.500 Baker 5.75" OD Self Energizing Reactive Packer Assy B - 63' above fault Baker SN# 50154880- 04, FSC- 124 Rubber Compound 3.930 15,626.0 6,082.6 92.89 Swell Packer 4.500 Baker 5.75" OD Self Energizing Reactive Packer Assy A- 128' below fault Baker SN# 50154880- 05, FSC- 124 Rubber Compound 3.930 HORIZONTAL, 2M-37, 2/22/2023 5:09:13 AM Vertical schematic (actual) LINER PROD. 4 1/2"; 13,729.4- 17,484.2 Shoe; 17,474.5-17,484.2 Perf Pups; 17,356.1-17,396.6 Perf Pups; 17,194.2-17,234.7 Perf Pups; 17,031.4-17,071.8 Perf Pups; 16,869.6-16,909.4 Perf Pups; 16,707.8-16,747.6 Perf Pups; 16,544.6-16,585.0 Perf Pups; 16,380.9-16,421.5 Perf Pups; 16,218.5-16,258.5 Perf Pups; 16,057.0-16,097.4 Perf Pups; 15,894.6-15,934.7 Perf Pups; 15,731.4-15,771.8 Swell Packer; 15,626.0-15,636.6 Swell Packer; 15,424.8-15,435.4 Perf Pups; 15,329.1-15,369.6 Perf Pups; 15,166.3-15,206.7 Perf Pups; 15,003.3-15,043.9 Perf Pups; 14,842.1-14,882.7 Perf Pups; 14,681.0-14,720.0 Perf Pups; 14,520.0-14,559.2 Perf Pups; 14,357.3-14,397.7 Perf Pups; 14,196.4-14,235.7 Perf Pups; 14,036.9-14,076.7 Perf Pups; 13,915.3-13,955.3 LINER INTERMEDIATE II; 12,243.5-13,894.0 FLOAT SHOE; 13,891.1- 13,894.0 SBE; 13,772.1-13,791.2 LANDING COLLAR; 13,757.9- 13,761.4 SEAL ASSY; 13,734.5 HANGER; 13,752.3-13,761.5 NIPPLE; 13,749.4-13,752.3 PACKER; 13,729.4-13,749.4 LOCATOR; 13,733.3 PLUG - SHEARED OPEN; 13,710.8 TUBING PLUG; 12,689.0 GAS LIFT; 12,631.0 LINER INTERMEDIATE I; 2,025.8-12,450.0 FLOAT SHOE; 12,446.8- 12,450.0 FLOAT COLLAR; 12,405.9- 12,409.2 LANDING CLLAR; 12,360.9- 12,365.1 HANGER; 12,269.0-12,278.3 NIPPLE; 12,266.2-12,269.0 PACKER; 12,243.5-12,266.2 7" INTERMEDIATE TIEBACK ; 28.1-12,253.2 Seal Assembly; 12,241.7- 12,253.2 GAS LIFT; 11,574.2 GAS LIFT; 10,193.6 GAS LIFT; 8,341.8 GAS LIFT; 5,895.8 SURFACE; 30.3-3,150.9 Float Shoe; 3,147.7-3,150.9 GAS LIFT; 2,880.5 HANGER; 2,048.8-2,057.9 PACKER; 2,025.8-2,048.8 LEAK - CASING; 373.0 CONDUCTOR; 32.0-162.0 XO Reducing (Tubing); 56.4 Casing Hanger; 30.3-30.8 Casing Hanger; 28.1-29.3 HANGER; 25.0 KUP INJ 2M-37 ... WELLNAME WELLBORE2M-37 2M-37 Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 162 162 20 19.12 94 H40 Surface 3151 2654 13-3/8 12.42 68 L80 HYD563 HYD563 Liner Intermediate 1 12450 5751 9-5/8 8.84 40 L80 BTCM BTCM Tie-back Intermediate 12253 5686 7 6.28 26 L80 HYD563 BTCM Liner Intermediate 2 13894 6055 7 6.47 26 L80 HYD563 HYD563 Produciton Liner 17484 6038 4.5 3.96 12.6 L80 TXPM TXPM Tubing 13783 6047 3.5 2.99 9.3 L80 HYD563 HYD563 PROPOSED 7.0" RECOMPLETION Swap out uppder 500' of 7.0" HYD563 PROPOSED 3.5" COMPLETION 3-1/2" 9.3# L-80 HYD563 Tubing to surface 3-1/2" Camco MMG gas lift mandrel @ TBD 3-½" X landing nipple at xxxx' RKB (2.813" min ID) Baker 3-1/2" Seals @ 13734' RKB REMAINING COMPLETION LEFT IN HOLE 4.5" Production Liner @ Top 13730' SBE for 3-1/2" Tubing Seals Perf Pups 13-5/8" Surface Casing 4.5" Liner and Perf Pups Conductor 9-5/8" Intermediate 1 Casing 7" Intermediate 2 Casing 7" Intermediate Tie-Back C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-02-21_20261_KRU_2M-37_ArcherVividAcousticLDL_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 20261 KRU 2M-37 50-103-20745-00 Archer Vivid Acoustic LDL 21-Feb-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC ***Please replace previous upload with revised folder upload. Attn: Natural Resources Technician VIVID Leak Report added*** 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 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-02-21_20261_KRU_2M-37_ArcherVividAcousticLDL_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 20261 KRU 2M-37 50-103-20745-00 Archer Vivid Acoustic LDL 21-Feb-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 C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\OLDB5O34\2023-01-23_15904_KRU_2M-37_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 15904 KRU 2M-37 50-103-20745-00 LeakPoint Survey 23-Jan-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 By Meredith Guhl at 8:05 am, Jan 26, 2023 216-082 T37469 Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.26 08:07:40 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2M-37 KUPARUK RIV UNIT 2M-37 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/20/2022 2M-37 50-103-20745-00-00 216-082-0 W SPT 6043 2160820 1800 2242 2240 2230 230 1990 1760 REQVAR F Adam Earl 6/18/2022 MIT-OA tested as per AIO 2C.048 to 1800psi 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 2M-37 Inspection Date: Tubing OA Packer Depth 210 580 890IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220622100335 BBL Pumped:5.5 BBL Returned: Wednesday, July 20, 2022 Page 1 of 1          Exceeded maximum allowed pressure loss (10%). P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 13, 2020 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 was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, 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 Roger Winter or Roger Mouser at 907-659-7506, if you have any questions. Sincerely, Roger Mouser ConocoPhillips Well Integrity Field Supervisor Roger Mouser Digitally signed by Roger Mouser Date: 2020.10.13 13:10:42 -08'00' By Samantha Carlisle at 1:21 pm, Oct 13, 2020 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 10/13/20 2K 2M 3K 3O 3Q 3R 3S pad Well Name API # PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 2K-30 50103207580000 2170720 22" 0.3 6" 3/8/2020 2.5 9/29/2020 2K-32 50103207570000 2170420 29" 0.5 6" 3/8/2020 3 9/29/2020 2M-37 50103207450000 2160820 30" 0.4 9" 7/31/2020 2.1 9/29/2020 2M-38 50103207460000 2160830 4" N/A 4" N/A 2.5 9/29/2020 3K-32 50029227630000 1970760 10"Conductor extension 10" 4/27/2019 2.5 9/27/2020 3K-34 50029228790000 1980770 14" Conductor extension 14" 4/27/2019 9 9/27/2020 3O-01A 50029218360000 2151910 62" 0.70 11" 3/8/2020 4.25 9/27/2020 3O-19 50029227530000 1970500 13"Conductor extension 13" 4/27/2019 4.25 9/27/2020 3O-20 50029227500000 1970450 21 5.00 17" 9/27/2020 6 9/27/2020 3Q-22 50029226250000 1951860 20' 3.25 8" 3/8/2020 4.25 9/26/2020 3R-101 50029235740000 2170130 21" 0.40 8" 8/14/2020 1 9/26/2020 3R-102 50029235720000 2161570 54" 1.10 6" 8/14/2020 6 9/26/2020 3R-105 50029236510000 2191340 22" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-106 50029236410000 2190970 36" 0.60 9" 8/14/2020 3.5 9/26/2020 3R-107 50029236600000 2191810 32" 0.60 9.5" 8/14/2020 1 9/26/2020 3R-111 50029236430000 2191050 25" 0.40 11" 8/14/2020 3.5 9/26/2020 3R-112 50029236370000 2190850 36" 0.60 14"8/14/2020 7 9/26/2020 3S-611 50103207740000 2181030 11' 10" 2.50 8"6/30/2019 2.5 9/27/2020 3S-612 50103207770000 2181110 43" 0.75 8" 6/30/2019 3.5 9/27/2020 3S-613 50103207350000 2160200 22" 0.75 8" 6/30/2019 1.7 9/27/2020 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 17, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2M-37 KUPARUK RIV UNIT 2M-37 Src: Inspector Reviewed By: P.I. Supry 1 IZ Comm Well Name KUPARUK RIV UNIT 2M-37 API Well Number 50-103-20745-00-00 Inspector Name: Adam Earl Permit Number: 216-082-0 Inspection Date: 6/13/2020 Insp Num: mitAGE200617112400 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2Ma7 jTypeInj w'TVD 6043 - Tubing 2070 2070 2065 2070PTD nwszo Test sPT Test psi 3400 ' IA use 3750 - 3600 - 60 - BBL Pumped: 4.8 BBL Returned: 4s OA 625 920 - 930 935 i Interval REQVAR P/F P Notes: MIT ]A tested as per AIO 2C.048 to MAIP ✓ Wednesday, June 17, 2020 Page 1 of I MEMORANDUM TO: Jim Regg I �e�G rv/2L ze,z�, P.I. Supervisor / FROM: Adam Earl Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 17, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2M-37 KUPARUK RIV UNIT 2M-37 Sre: Inspector Reviewed By: P.I. Supry t,j gtz - Comm Well Name KUPARUK RIV UNIT 2M-37 API Well Number 50-103-20745-00-00 Inspector Name: Adam Earl Permit Number: 216-082-0 Inspection Date: 6/13/2020 insp Num: mitAGE200617112820 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2M-37 -Type Inj W TVD 6043 " Tubing 2105 2080 zona - ' 2085 2080 VBJBLPnped 160820 Type Test SPT est psi 1800 IA 1065 1152 - wo 1250 1285 : 4 BBL Returned: a - OA doo z000 1960 930 9zo - Interval REQVAR P/F P Notes: MIT OA tested as per AIO 2C.048 to 1800psi ✓ -J-x x PA 6�) M., c,,: «� Wednesday, June 17, 2020 Page l of I Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: a AOGCC ATTN: Natural Resources Technician 11 Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 .ft Anchorage, AK 99501 21COU a2 3125 7 27 -Sep -19 275ep1941111101 21111-37 50-103.20745-00 SERVICE ORDER EOSH-00096 FIELD NAME DESCRIPTION KUPARUK RIVER DELIVERABLE WL DESCRIPTIONDATA IPROF TYPE FINAL FIELD DATELOGGED Prints 10 -Sep -19 CD's 1 3N-09 50.029.21541-00 DWUJ-00125 KUPARUK RIVER WL LDL FINAL FIELD 15 -Sep -19 1 1A-12 50.029-20688-00 DWUJ-00128 KUPARUK RIVER WL Caliper FINAL FIELD 18 -Sep -19 1 1H-114 50-029-23584-00 EDWI-00018 KUPARUK RIVER WL [PROF-WFL FINAL FIELD 19 -Sep -19 1 1H-118 50.029-23578.00 EDWI-00019 KUPARUK RIVER WL [PROF-WFL FINAL FIELD 20 -Sep -19 1 1H-119 50-029-23591-00 EDWI-00020 KUPARUK RIVER WL IPROF-WFL FINAL FIELD 21 -Sep -19 1 3G-18 50-103-20142.00 EDWI-00021 KUPARUK RIVER WL Caliper FINAL FIELD 23 -Sep -19 1 1 3F-03 50.029-21448-00 EOSH-00098 KUPARUK RIVER WL IPROF FINAL FIELD 25 -Sep -19 1 8 Signature _ /I v Date return via courier or sign/scan and email a copy tol Syhlumberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log with ACX: 2M-37 Run Date: 12/2/2018 216062 30340 January 10, 2019 RECEIVED FEB 0 5 2019 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS-ANC@halliburton.com 2M-37 Digital Data in LAS format, Digital Log file, and Interpretation Report 1 CD Rom 50-103-20745-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: o2... TZ�2 - Signed: • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,June 18,2018 '17 P.I.Supervisor •811 67 CI e l I s SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2M-37 FROM: Matt Herrera KUPARUK RIV UNIT 2M-37 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J�- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-37 API Well Number 50-103-20745-00-00 Inspector Name: Matt Herrera Permit Number: 216-082-0 Inspection Date: 6/14/2018 - Insp Num: mitMFH180615122258 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-37 ;Type Inj W ;TVD 6043 Tubing 2010 2000 - 2005 - 2005 PTD 2160820 Type Test SPT Test psi 1800 - IA 1315 1424 1423 1423 -- _-__ _— --- - --- __-- - -- i BBL Pumped: 1.9 ,IBBL Returned: 2.1 - OA 1310 2000 v 1990 - 1985 _ Intervalj_ REQVAR 111/F P ► Notes: MITOA per AA AIO 2C.048 MAOP on OA. OA tested to 2000 PSI per Operator SatitiED JUN 21friS Monday,June 18,2018 Page 1 of 1 MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 18,2018 TO: gg P�LnSupervisor Te,761,6/i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2M-37 FROM: Matt Herrera KUPARUK RIV UNIT 2M-37 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry. ga NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-37 API Well Number 50-103-20745-00-00 Inspector Name: Matt Herrera Permit Number: 216-082-0 Inspection Date: 6/14/2018 Insp Num: mitMFH180615120838 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min J Well 2M-37 ler I ' W TVD Ype n6043 Tubing l 2010 - 2010• 2020 - 2015 ' Type PTT) 2160822 0 Type Test SPT (Test psi 3000 jA 1250 33000 -3210 3170 • BBL Pumped: 1 3.8 ' BBL Returned: 3.5 OA 1025 1241 - 1253 • 1260 Intervale REQVAR P/F P - Notes: MITIA to MAIP per AIO 2C.048 IA Pressure tested to 3300 PSI per operator SGM JUN 2 2104 Monday,June 18,2018 Page 1 of 1 • 21668,2: WELL LOG TRANSMITTAL #904804367 2 9 3 1 2 To: Alaska Oil and Gas Conservation Comm. June 4, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 JUN 12 2018 AOGCC RE: Leak Detect Log with ACX: 2M-37 Run Date: 4/21/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRSANC@halliburton.com 2M-37 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-103-20745-00 Leak Detect Log with ACX (Processed Log) 1 Color Log 50-103-20745-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. WOW JUN 2 1 I')I Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com / . Date: Le/ /V 201F. %`' l Si ned: IAkId g • • 21 6082 WELL LOG TRANSMITTAL #904690550 2 9 1 4 5 To: Alaska Oil and Gas Conservation Comm. March 19, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED MAR 222018 RE: Leak Detect Log with ACX: 2M-37 Run Date: 3/4/2018 AO G C C The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2M-37 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-103-20745-00 Leak Detect Log with ACX(Processed Log) 1 Color Log 50-103-20745-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska SCOlitu Office: 907-275-2605 FRS_ANC@halliburton.com Dat : 5] 16 Signed: AkillIP„LSZ____. • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday, September 28, 2017 6:18 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of OA repressurization 2M-37 (PTD 216-082) updated 9-28-17 Attachments: 2M-37 AA application packet 9-28-17.pdf Chris, After adjusting the pressures, with the IA above OA,communication has resumed. Therefore I've put together an AA application for your consideration. CPAI intends to keep the well on water-only injection service while the paperwork is processing. Attached is an electronic copy for your reference. The physical copy is in the mail. Let me know if there are any questions. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224cotiED Mobile Phone (907)943-0170 From: NSK Well Integrity Supv CPF1 and 2 Sent: Friday,September 08, 2017 2:57 PM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> c:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Sub t: RE: Report of OA repressurization 2M-37 (PTD 216-082) updated 9-8-17 Chris, Since being reported la onth, 2 MITIA's(one diagnostic test on August 9 and one AOGCC-witnessed test on August 28)and an MITOA(performei in August 11)all passed. When the well was reported,the IA was above the OA. After adjusting the pressures to put the A below the OA,they have maintained a good differential throughout the 30 day monitor period. There have been sones inor pressure fluctuations but they appear to be thermally induced. We would like to extend the monitor period outfor an additional 30 days and readjust the pressures to bring the IA back above the OA to ensure there is not a one-way k present. Proper paperwork will be submitted at the conclusion of the monitor. Please let us know if you disagree with e path forward. Attached are the MIT forms for all 3 tests and an updated 90 •.y TIO plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone(907) 943-0170 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission •f DATE: Monday,September 11,2017 TO: 11m Regg P.I.Supervisor t 9�143�(7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2M-37 FROM: Lou Laubenstein KUPARUK RIV UNIT 2M-37 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,)p12-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-37 API Well Number 50-103-20745-00-00 Inspector Name: Lou Laubenstein Permit Number: 216-082-0 Inspection Date: 8/28/2017 Insp Num: mitLOL170828151534 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-37 • Type Inj W' TVD 6043 Tubing 2110 - 2110 2110 - 2110 PTD 2160820 Type Test SPT Test psi 1511 - IA 0 2805 - 2750 - 2740 - BBL Pumped: 4.5 • BBL Returned: 4.5 _ OA 488 491 494 - 497 - Interval 1NITAL P/F P ✓ Notes: Initial MITIA post conversion to injection per sundry#317-185 SCANNED ::EB 1 3 � J Monday,September 11,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, September 8, 2017 2:57 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of OA repressurization 2M-37 (PTD 216-082) updated 9-8-17 Attachments: 2M-37 90 day TIO 9-8-17.JPG; MIT KRU 2M-37 08-28-17.xlsx; MIT KRU 2M-37 Diagnostic 8-9-17.xlsx; MIT KRU 2M-37 Diagnostic MITOA 8-11-17.xlsx Chris, Since being reported last month,2 MITIA's(one diagnostic test on August 9 and one AOGCC-witnessed test on August 28)and an MITOA(performed on August 11)all passed. When the well was reported,the IA was above the OA. After adjusting the pressures to put the IA below the OA,they have maintained a good differential throughout the 30 day monitor period. There have been some minor pressure fluctuations but they appear to be thermally induced. We would like to extend the monitor period out for an additional 30 days and readjust the pressures to bring the IA back above the OA to ensure there is not a one-way leak present. Proper paperwork will be submitted at the conclusion of the monitor. Please let us know if you disagree with the path forward. Attached are the MIT forms for all 3 tests and an updated 90 day TIC plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Mobile Phone (907) 943-0170 • : NSK Well Integrity Supv CPF1 and 2 Sent: • •ay,August 07, 2017 3:06 PM To:Wallace, C' ' D (DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Tyler ' Ier.Senden@conocophillips.com> Subject: Report of OA repr- urization 2M-37 (PTD 216-082)8-7-17 Chris, WAG injector 2M-37 (PTD 216-082)was re z tly converted from production to water injection service on August 3, 2017. There have been several bleeds of the IA . d OA performed in the last several days which is usually routine when initially bringing on a well. However, because of the •own IAxOA communication history while on gas-lifted production service, I thought it prudent to report sooner rather than . -r. During the diagnostics performed in January and February,an MITIA, MITOA and IC-POTs passed, indicating a do, •hole gas-only leak path. A passing MITIA was performed on August 1,2017, prior to initial injectio . There is still possibility that this is only a thermal response, but DHD will be mobilized to confirm that the MITIA can sti :.ss when the well is on injection. Proper dP between the IA and OA will be established; after which,the we ill be placed on a 30 day monitor period. A follow-up email will be provided at the conclusion of the monitor. Please let now if you disagree with the path forward. Attached are the 90 day TIC plot and schematic and pre-injection MITIA data. 1 STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon H Plug Perforations U Fracture Stimulate ❑ Pull Tubing U Operations shutdown H Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: _PROD to WAG El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: _ ConocoPhillips Alaska,Inc. Development 0 Exploratory ❑ 216-082 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.0.Box 100360,Anchorage,Alaska 99510 50-103-20745-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25586,ADL 25585 KRU 2M-37 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): 1V/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 17,484.2' feet Plugs measured g/A feet true vertical 6,038' feet Junk measured WA feet Effective Depth measured 17484.2' feet Packer measured 13,729.5' feet true vertical 6038' feet true vertical 6,042.8' feet Casing Length Size MD TVD Burst Collapse Conductor 130' 20" 162' 162' Surface 3120.6' 13-3/8" 3150.9' 2654' Intermediate#1 5997 9-5/8" 12450' 5751' Intermediate#2 1716' 7" 13894' 6054.7' Liner 3693' 4-1/2" 17484.2' 6038' RECEIVED AUG 302017 Perforation depth Measured depth 13916-15425; feet 15731-17475 AOGCC True Vertical depth 6056-6084; feet 6076-6038 Tubing(size,grade,measured and true vertical depth) 3 1/2" L-80 13783'MD 6046'TVD Packers and SSSV(type,measured and true vertical depth) SSSV:None; Baker HRD-E ZXP Paker 13,729.5'MD 6,042.8'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): KIA SCANNED 3 2017 Treatment descriptions including volumes used and final pressure: NOVU t 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1233 2289 35 1020 229 Subsequent to operation: 0 0 3906 38 2087 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-185 Authorized Name: Mark Shulman Contact Name: Mark Shulman Authorized Title: Senoir PetroleumleEngineer c Contact Email: Mark.shulmanACOP.com Authorized Signature: k(--- 211(// Date: c/2*//7 Contact Phone: 263-3782 V Ti- jo/1 V 17- Form 10-404 Revised 4/2017 ,1,97;f/j RBDMS 0,- AUG 3 0 2017 Submit Original Only • • Event Summary 8/1/2017: MIT-IA(Passed to 3000 psi) 8/3/2017: Convert to Produced Water Injection. Well brought online 8/7/2017: Email to AOGCC: WAG injector 2M-37 (PTD 216-082)was recently converted from production to water injection service on August 3, 2017. There have been several bleeds of the IA and OA performed in the last several days which is usually routine when initially bringing on a well. However, because of the known IAxOA communication history while on gas-lifted production service, I thought it prudent to report sooner rather than later. During the diagnostics performed in January and February, an MITIA, MITOA and IC-POTs passed, indicating a downhole gas-only leak path. A passing MITIA was performed on August 1, 2017, prior to initial injection. There is still possibility that this is only a thermal response, but DHD will be mobilized to confirm that the MITIA can still pass when the well is on injection. Proper dP between the IA and OA will be established; after which, the well will be placed on a 30 day monitor period. A follow-up email will be provided at the conclusion of the monitor. Please let us know if you disagree with the path forward. Attached are the 90 day TIO plot and schematic and pre-injection MITIA data. 8/9/2017: MIT-IA(Passed to 3300 psi). 8/11/2017: MIT-OA(Passed to 1800 psi) 8/28/2017: State Witnessed ISW(Lou Laubenstein) MIT-IA(Passed to 2805 psi) KUP I 2M-37 4ConocoPhilips - Well Attribute Max Angle a TD Ala ka,Ir)ry. Wellbore APIIUWI Field Name Wellbore Status Incl C) MD(ftKB) Act Btm(ftKB) • c rnooaphiurps • 501032074500 KUPARUK RIVER UNIT INJ 94.09 15,702.03 17,510.0 • ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2M-37,0/29/201710:35:55 AM SSSV:NIPPLE Last WO: 27.42 1/1/2017 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag. Rev Reason:PULL DHSIT pproven 6/6/2017 HANGER,25.0 asing rings • • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ,. i. t .. CONDUCTOR 20 19.124 32.0 162.0 162.0 94.00 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len p...Grade Top Thread SURFACE 13 3/8 12.415 30.3 3,150.9 2,653.6 68.00 L-80 HYD 563 Casing Description OD(in) ID(in) Top(kKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread XO Reducing(Tubing);56.4 'r LINER INTERMEDIATE 9 5/8 8.835 2,025.8 12,450.0 5,751.3 40.00 L-80 BTCM II I li Liner Details "^-"-CONDUCTO3 R; 2.0.162.0 Nominal ID M' Ill Top(kKB) Top(ND)(kKB) Top Incl n Item Des Com (in) -� r.- 2,025.8 1,919.6 36.57 PACKER Baker HRD-E ZXP Liner top Packer 8.835 2,048.8• 1,938.0 37.23 HANGER Baker FlexLock Liner hanger 9.410 i L.' 2,057.9 1,945.2 37.49 Casing Coupling crossover 9 5/8"X 10 3/4"BTC 8.410 Casing Description OD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT;2,880.5 7"INTERMEDIATE 7 6.276 28.1 12,253.2 5,685.7 26.00 L-80 BTC-m TIEBACK Casing Description OD(in) SID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread I LINER INTERMEDIATE 7 6.473 12,243.5 13,894.0 6,054.7 26.00 L-80 TSH 563 SURFACE;30.3-3,150.8 Liner Details Nominal ID iiiir GAS LIFT;5,895.8 kr. Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Coin (in) AM 12,243.5 5,682.5 70.73 PACKER Baker HRDE ZXP Liner Top Packer 6.190 12,2662 5,690.0 70.67 NIPPLE RS pack-off Nipple 6.190 GAS LIFT;8,341.8 12,269.0 5,691.0 70.66 HANGER Baker Flex-Lock Liner Hanger 6.200 Mir Casing Description OD(in) ID lin) Top(kKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread GAS LIFT;10,193.6 LINER PROD.41/2" I 41/21 3.9581 13,729.51 17484.21 6,038.01 12.60IL-80 TXP-M Liner Details Nominal ID • GAS LIFT;11,574.2 IC Top(ftKB) Top(TVD)(kKB) Top Incl 1 I Item Des Corn (in) 13,729.5 6,0428 85.44 PACKER Baker HRD-E ZXP 5"x 7"Liner top packer L-80 5" 4.340 ■ 11 Hyd 521 pin-165'liner lap -INTERMEDIATE TiEeAOK: 13,749.4 6,044.3 85.51 NIPPLE Baker 5""RS"Packoff Seal Nipple 15 ppf L-80 Hyd 4.260 28.1-12,253.2-^ 521 box x box 13,752.3 6,044.6 85.52 HANGER Baker 5"x 7"DG Flex-Lock Liner Hanger L-80 Hyd 4.360 521 pin x pin 13,772.1 6,046.1 85.59 SBE Baker 80-40 Sealbore Extension,5"L-80 Hyd 521 pin 4.000 x 4.5"Hyd 521 box LINER INTERMEDIATE I; 15,424.8 6,084.4 89.78 Swell Packer Baker 5.75"OD Self Energizing Reactive Packer 3.930 2,025.8-12,450.0 Assy B-63'above fault GAS LIFT;12,631.0 'r. INERA 15,626.0 6,082.6 92.89 Swell Packer Baker 5.75"OD Self Energizing Reactive Packer 3.930 ME Assy A-128'below fault ION Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection PLUG;13,710.8 = TUBING-UPPER 3 1/2 2.992 25.0 13,783 0 6,046.9 9.30 L-80 Hyd 563 ;i COMPLETION Completion Details LOCATOR;13,7333 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl Cl Item Des Com (in) IF SEAL ASSY;13,734.5 1 I I 25.0 25.0 0.30 HANGER 4-1/2"FMC Tubing Hanger 3.900 i-;-t 12,689.1 5,830.6 70.77 NIPPLE Camco 3-1/2"x 2.813"No-Go"DS"Nipple Hydril 563 2.813 SN#427336-01 13,710.8 6,041.3 85.37 PLUG Mirage Plug,775 psi Rupture disc installed,Rig did not 2.880 shear LINER INTERMEDIATE Ii; j' 13,733.3 6,043.1 85.45 LOCATOR Baker Locator 2.990 12,243.5-13,894.0 kttdll 13,734.5 6,043.2 85.46 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly 3.000 EEL Mandrel Inserts ELL. St ati iLl' on Top(ND) Valve Latch Port Size TRO Run El/i' N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com aa.. 1 2,880.5 2,511.5 Camco KBMG 1 GAS LIFT GLV BK 0.156 1,319.0 1/11/2017 En 2 5,895.8 3,612.5 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,287.0 1/11/2017 MI 3 8,341.8 4,409.6 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,276.0 1/11/2017 • - 4 10,193.6 5,002.9 Camco KBMG - 1 GAS LIFT GLV BK 0.188 1,302.0 1/11/2017 5 11,574.2 5,460.2 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,288.0 1/10/2017 MN 6 12,631.0 5,811.5 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 1/10/2017 . Notes:General&Safety End Date I Annotation NOTE: Mill I 6331 elasi EA rami mai LINER PROD 41/7';13,729.4 17,484.2\ I I • S Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday, August 7, 2017 3:06 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of OA repressurization 2M-37 (PTD 216-082) 8-7-17 Attachments: 2M-37 schematic.pdf;2M-37 90 day TIO 8-7-17.JPG; MIT KRU 2M-37 Diagnostic 8-1-17.xlsx Chris, WAG injector 2M-37 (PTD 216-082)was recently converted from production to water injection service on August 3, 2017. There have been several bleeds of the IA and OA performed in the last several days which is usually routine when initially bringing on a well. However, because of the known IAxOA communication history while on gas-lifted production service, I thought it prudent to report sooner rather than later. During the diagnostics performed in January and February,an MITIA, MITOA and IC-POTs passed, indicating a downhole gas-only leak path. A passing MITIA was performed on August 1,2017, prior to initial injection. There is still possibility that this is only a thermal response, but DHD will be mobilized to confirm that the MITIA can still pass when the well is on injection. Proper dP between the IA and OA will be established; after which,the well will be placed on a 30 day monitor period. A follow-up email will be provided at the conclusion of the monitor. Please let us know if you disagree with the path forward. Attached are the 90 day TIO plot and schematic and pre-injection MITIA data. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 ��g ',E r' 2 20- Mobile Phone (907)943-0170 " 1 � KUP PROD • 2M-37 ConocoPhillips a "I Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Btm(ftKB) ,,,,.4," 501032074500 KUPARUK RIVER UNIT PROD 94.09 15,702.03 17,510.0 ..- Comment 112S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2M-37,616/20171:56:31 PM SSSV.NIPPLE Last WO: 27.42 1/1/2017 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -- - -- Last Tag: Rev Reason:PULL DHSIT pproven 6/6/2017 HANGER;250-�. r� Casing Strings L, © Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ............._....._..._....__...._....._....._...._... _.. CONDUCTOR 20 19.124 32.0 162.0 162.0 94.00 H-40 'U e Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 13 3/8 12.415 30.3 3,150.9 2,653.6 68.00 L-80 HYD 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 00 Reducing(Tubing);58.4 I,� LINER INTERMEDIATE 95/8 8.835 2,025.8 12,450.0 5,751.3 40.00 L-80 BTCM I Liner Details CONDUCTOR;32.0-162.0 TopftKB Top(TVD)ftKB Top Incl° Item Des Com Nominal ID (ftKB) 1( ) (1 (in) 2,025.8 1,919.6 36.57'PACKER Baker HRD-E ZXP Liner top Packer 8.835 E j 2,048.8 1,938.0 37.23 HANGER Baker FlexLock Liner hanger 9.410 2,057.9 1,945.2 37.49'Casing Coupling crossover 9 5/8"X 10 3/4"BTC 8.410 • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT;2,880.5 7"INTERMEDIATE 7 6.276 28.1 12,253.2 5,685.7 26.00 L-80 BTC-m TIEBACK Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER INTERMEDIATE 7 6.473 12,243.5 13,894.0 6,054.7 26.00 L-80 TSH 563 II SURFACE;30.3-3,150.9 Liner Details _ Nominal ID GAS LIFT;5,885.8 { Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 12,243.5 5,682.5 70.73 PACKER Baker HRDE ZXP Liner Top Packer 6.190 12,266.2 5,690.0 70.67 NIPPLE RS pack-off Nipple 6.190 GAS LIFT;8,341.8 12,269.0 5,691.0 70.66 HANGER Baker Flex-Lock Liner Hanger 6.200 Il lCasing Description OD(in) ID(in) Top(ftKB) Sat Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT;10,193.6 ' LINER PROD.41/2" 4112 3.958 13,729.5 17,484.2 6,038.0 12.60 L-80 TXP-M 6I Liner Details I Nominal ID GAS LIFT;11,574.2 ! d. Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) I 13,729.5 6,042.8 85.44 PACKER Baker HRD-E ZXP 5"x 7"Liner top packer L-80 5" 4.340 Hyd 521 pin-165'liner lap 7"INTERMEDIATE TIEBACK; 13,749.4 6,044.3 85.51 NIPPLE Baker 5""RS"Packoff Seal Nipple 15 ppf L-80 Hyd 4.260 28.1-12,253.2 521 box x box 13,752.3 6,044.6 85.52 HANGER Baker 5"x 7"DG Flex-Lock Liner Hanger L-80 Hyd 4.360 521 pin x pin • 13,772.1 6,046.1 85.59 SBE Baker 80-40 Sealbore Extension,5"L-80 Hyd 521 pin 4.000 x 4.5"Hyd 521 box LINER INTERMEDIATE I; 15,424.8 6,084.4 89.78 Swell Packer Baker 5.75"OD Self Energizing Reactive Packer 3.930 2,025.8-12,450.0 ` Assy B-63'above fault GAS LIFT;12,631.0 15,626.0 6,082.6 92.89 Swell Packer Baker 5.75"OD Self Energizing Reactive Packer 3.930 l Assy A-128'below fault Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING-UPPER 3 1/2 2.992 25.0 13,783.0 6,046.9 9.30 L-80 Hyd 563 PLUG;13,710.8 ipt COMPLETION Completion Details LOCATOR;13,733.3 Nominal ID n Top(ftKB( Top(TVD)MKS) Top Incl(°) Item Des Com (in) 25.0 25.0 0.30 HANGER 4-1/2"FMC Tubing Hanger 3.900 SEAL ASSY;13,734.5 I:I; 12,689.1 5,830.6 70.77 NIPPLE Camco 3-1/2"x 2.813"No-Go"DS"Nipple Hydril 563 SN# 2.813 i ` 427336-01 -.I:. 13,710.8 6,041.3 85.37 PLUG "Mirage Plug,775 psi Rupture disc installed,Rig did not 2.880 shear 13,733.3 6,043.1 85.45 LOCATOR Baker Locator 2.990 LINER INTERMEDIATE II; 12,243.0.13,854.0 13,734.5 Mandrel6,043.2 85.46 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly 3.000 Inserts on St ati Top(NO) Valve Latch Port Size TRO Run N Top(ftKB)ftK8) (ftKB) Make Model OD(in) Se, Type Type (in) (psi) Run Date Com 171 f 2,880.5 2,511.5 Camco KBMG 1'GAS LIFT 'GLV BK 0.156 1,319.0 1/11/2017 ISV 2 5,895.8 3,612.5 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,287.0 1/11/2017 ' 1 1.1 3 8,341.8 4,409.6 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,276.0 1/11/2017 4 10,193.6 5,002.9 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,302.0 1/11/2017 �B® 5 11,574.2 5,460.2 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,288.0 1/10/2017 56 12,631.0 5,811.5 Comm KBMG 1 GAS LIFT OV BK 0.250 0.0 1/10/2017 Notes:General&Safety End Date Annotation NOTE: lir 1:1 IIIA fl'. NM 1'1 UM t:l: M 17. I:r -.G: 17': '17: LINER PROD.412-;13.729.4- ` 17,484.2 l cv ,.... w w co t 0 V p j v o ¢ 3Wr( aJ O L , M t.. co CD o 0 a t 0 O _ 1 Co N Z on T (o Ohm O N Oro O -0 Q\Y V a a C C O Oar (0 a) (p .L '-' W 4-, C f- x 0 o a a m QC J u, N N N N N N N N N N N v 0 J r `) L a1 u I_ Q l7 , C C C C C C C C C C E + s -a O `n J J J J 7 7 7 7 J J J -p Y L N M M _) -, _) M -) _) v- C - t0 n H o N n CO 0) 0) o M 'Cr In 0 0 cu C Z Z 0 N N N N O v (O \ C Q i > 6 v O C i H ~ — u ~ (o O 0 0 0 0 0 0 0 0 0 0 0 C a) .. LU J J J J J J J J J J J CIO O } W W W W W W W W W W W ',� C F- LL LL LL LL LL LL LL LL LL LL LL , a) a) a) -O 0 - Q J J J J J J J J J J J - > w Q Q Q Q Q Q Q Q Q Q Q N v C w . C c 0 Z Z Z Z Z Z Z Z Z Z Z N N ro 0 v • LL LL LL LL LL LL LL LL LL LL LL cc ^ > C OG 2 0 Q v u v .» U w p C O m . C H ) 1 ) -c C ... oa J F- > U QJ ++ C O ) C LL C 03 a o O Cp VVI J v Q v a v C a 0 a a c7 C7 N �:. m d U 0 R 0 O Q H al a' 99 J Q '� ; 0 N. (aa o 00 O d 0 �, ml M x O h °a) !0 z — Q x o X w 0 .� os 0 0x9 u d J J J J J J J J J J J 1 2 o zap � � la W L. Z 0 XIZ P ccrxrcrecemcecrccc E ae UJWLUWWWWWWWW J 1J W > > > > > > > > > > > — 2rereCeCeXW rrfXreWcc v V9 z Y Y Y Y Y Y Y Y Y Y Y > > 7 > > > > > > > > 0 Q OJ d' Ce W Q' Ce d' d' d' X Cr CX �' W Q Q Q Q Q Q Q Q Q Q Q4 T EZ a LL d Q. d d d d d a o_ Q W _ > > > > > > > > > > > o Y Y Y Y Y Y Y Y Y Y Y ''C a3 U , tp CO _ x �, N ♦ , CC Q C) co N O N M V 0) O (p v O N O M M M M M O O 0 0 0 a a a a a a aE W Q1 0 O O O O O O O O O O O �„�� 0 O O O O O O O O O O O u N- O 7 0 0 0 O O co co W C Z 0 > 2 co 0 co co co co h 2 2 2 @ w O C C C C D O D O C D O W Q xvi cco CC 0ra C O O O O O O O O O 0 C O o 0 0 0 0 0 0 0 0 0 pa o) N Ii) r) v N o N In v CO N 121V N V 0 CO CO N 0 M V In N N N N CO N V O 0 u N . C9 0 0 0 M N N 0 N ,- O N - N N N NNN N N N N N _0 R O O) M M O O T O) M O O) a) �, RN N O O N N N N O N N '� Q1 O O O O O O a O O O O O O O O O O O O ON 0 a) coHC In In Il) u) )[) In In In In If) I) O. U �i ES CD ui v fC au CO?. H °�' a > u w c w CC C41) u C N Z �; no Q O 1- M M O O N- N O N N. O ro Y E y N en v J LL Y 2 2 W p d' V) 2 LL to 1- a C ' d Q O N ` ...I M N N .- M M N Z a) (o O Cr a ~ ' Lv v o Q H a a Q • •V OF 715", • �i�\\I%7;cs., THE STATE Alaska Oil and Gas i.g� -=>, ,.+- i�--7� Of a T ASKA Conservation Commission e!"Ai - � l 1L 1. 2 i� 333 West Seventh Avenue 1;*110PP, ` GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 A 6 Fax: 907.276.7542 www.aogcc.alaska.gov Mark Shulman Petroleum Engineer , ConocoPhillips Alaska, Inc. ED `li y . r�`J I!'. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-37 Permit to Drill Number: 216-082 Sundry Number: 317-185 Dear Mr. Shulman: 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 f 4 day of June, 2017. RBDMS L,-z Jui4 1 6 2017 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION G� 6 MAY 201 APPLICATION FOR SUNDRY APPROVALS �°'� / �` / 7 20 AAC 25.280 A�.JGC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: PROD to WAG ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑✓ . 216-082 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service P.O.Box 100360,Anchorage,Alaska 99510 50-103-20745-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑., / KRU 2M-37 F 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25586,ADL 25585 • I Kuparuk River Field/Kuparuk River 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): 17,510 ' 6038 ' 17510" 6038' • 3800 None None Casing Length Size MD TVD Burst Collapse Conductor 130' 20" 162' 162' Surface 3120.6' 13-3/8" 3150.9' 2654' Intermediate#1 5997' 9-5/8" 12450.0' 5751' Intermediate#2 1716' 7" 13894' 6054.7' Liner 3693' 4-1/2" 17484.2' 6038' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13916-15425,15731-17475 6056-6084,6076-6038 3-1/2" L-80 13783' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV:NONE;Packer: Baker HRD-E ZXP SSSV:NONE;Packer:13,729.5'MD(6,042.8'TVD) • 12.Attachments: Proposal Summary Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development❑ Service ❑✓ - 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 6/15/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ ' GSTOR ❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Mark Shulman Contact Name: Mark Shulman Authorized Title: Petroleum Engineer Contact Email: mark.shulman(Cr7cop.com /�>/ /> Contact Phone: (907)263-3782 Authorized Signature: ,( .J .�G"' Date: Chr 17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317- \%e Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test EK Location Clearance ❑ t"i i c ,(t.4 1 4 Other: A-/a z C' Gip itr, Post Initial Injection MIT Req'd? Yeso ❑ Spacing Exception Required? Yes ❑ No u Subsequent Form Required: L 0 — 4-0 RBDMS IA V JUN 1 6 2017 APPROVED BY Approved by: later COMMISSIONER THE THE COMMISSION Date:4 _/ (— 17 (7is 4/ 0 A' fl(13 �'I fjq/(7 Submit Form and Form 10-403 Revised 4/2017 p I t i valid for 12 months from the date of approval. / Attachments in Duplicate • S Mark Shulman Petroleum Engineer P.O.Box 100360 Anchorage,AK 99510-0360 ConocoPhil I i ps Phone:(907)263-3782 May 8, 2017 RECEIVED MAY 0 8 2017 AOGCC Commissioner AOGCC State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well 2M-37 from Production service to Water Alternating Gas Injection service. Enclosed you will find 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2M-37 (PTD#216-082). If you have any questions regarding this matter, please contact myself at 263-3782. Sincerely, Mark Shulman Attachments Sundry application Proposal Summary Well schematic Area Map AOR Detail • • ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 2M-37 (PTD# 216-082)from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: West Sak Kuparuk well 2M-37 was completed as an injector on 1/1/17 to provide enhanced recovery injection into the reservoir to increase the ultimate recovery of oil. This well will support existing producers 2M-38. The top of the Kuparuk C sand was found at 13776' MD/6045'TVD ^ d'' 5--.01 2 Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that, with the exception of the offset producers (2M-38), there are no additional production/injection wells located within a 1/4 mile radius of the 2M-37 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 2M-37 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 13729'MD (6043'TVD). On 02/19/17 we contact the AOGCC about possible IAxOA communication however, it passed a M11D and appears to be a gas-only leak. Additionally, we don't believe it will have communication once the IA has been fluid packed and injection begins. The well will be monitored under AIO 2C and if any signs of communication exist, it will be reported at that time and diagnostics will be done as needed. Upon conversion to injection, the internal waiver to allow the OA to operate at 1400 psi will be cancelled and the well will operate under normal service well criteria. A State-witnessed MIT-IA will be performed once well 2M-37 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: The intermediate casing CBL indicates sufficient formation bond (12269' - 13894' MD/5691' -6055'TVD) to insure injection zone conformance. The CBL interpretation was completed on the PTD's. The 20" Conductor was pre-driven The 13-5/8" Surface casing was cemented with 1465 sx 11.0 ppg bbls DeepCrete, 239 sx 12.0 ppg DeepCrete. The 9-5/8" Intermediate casing was cemented with 832 sx 15.6 Class"G" The 7" Intermediste casing was cemented with 526 sx 15.8 ppg Class"G" • • • Loepp. Victoria T (DOA) From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Thursday, May 11, 2017 2:21 PM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2M-37(PTD 216-082, Sundry 317-185)Conversion to WAG Attachments: well_2M_37_injection_sundry_20170510.png Follow Up Flag: Follow up Flag Status: Flagged Victoria, Below is KRU 2M-37's MIT-IA history: On 1/1/2017, KRU 2M-37 had a MIT-OA to 2,500 psi, MIT-T to 3000 psi and MIT-IA to 3,500 psi on the rig and charted,all passed. On 1/18/2017,The well was initially put on production.On 1/24/2017,the AOGGC was notified of the OA pressure increase and diagnostics. KRU 2M-37 had continuous diagnostics and gas samples from 1/21/2017 through 2/20/2017. Earlier in the diagnostic process,the IAxOA communication theory was discounted because the IA and OA gas samples (taken repeatedly for confirmation)did not match compositionally. However, on 02/12/2017,the lift gas was shut off and IA bled down to flowline pressure("310psi),with the OA bled off to"100psi above the IA. During the initial 3.5 hr. monitor period,the OA only climbed 11psi with no additional buildup observed overnight.As soon as the lift gas was returned to the well,only then did the OA begin to build pressure again. It is suspected that the proprietary gelled-diesel that fills most of the OA is scrubbing the migrating lift gas of its heavier components,causing the gas samples to not match.The well passed an MITOA to 1800 psi on 02/02/17 and inner casing packoff testing on 02/12/17 and 01/22/17, indicating this is a downhole gas-only leak. On 2/19/2017 CPAI waivered the well for IAxOA communication and allow the OA to equalize with the IA, up to a gas lift header pressure of 1400psi and the AOGCC was notified of the internal wavier Also attached is an updated area map for 2M-37,which includes 2M-38. In anticipation of this sundry, I had the previous map made a little early(when 2M-38 was still being drilled.) Sorry for the confusion. Please let me know if you need any additional information. Thanks, Mark (907)263-3782 From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, May 10,2017 8:44 AM To:Shulman, Mark<Mark.Shulman@conocophillips.com> Subject: [EXTERNAL]KRU 2M-37(PTD 216-082,Sundry 317-185)Conversion to WAG Mark, On the area of review'A mile radius map, I do not see Producer KRU 2M-38? Please provide the MIT-IA history on KRU 2M-37. Thanx, Victoria 1 KUP PROD 2M-37 r- ConocoPhillips r Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status lIncl 7) MD(ftKB) Act Btm(ftKB) ccr000wru, 501032074500 KUPARUK RIVER UNIT PROD 94.09 15,702.03 17,510.0 ••- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-2M-37,522017527.28 PM - SSSV:NIPPLE Last WO: 27.42 1/1/2017 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:NEW WELL pproven 5/1/2017 HANGER',25.n- r� Casing Strings [ IJ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 32.0 162.0 162.0 94.00 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(1003) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 13 3/8 12.415 30.3 3,150.9 2,653.6 68.00 L-80 HYD 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread DO Reducing(Tubing);564 V LINER INTERMEDIATE 9 5/8 8.835 2,025.8 12,450.0 5,751.3 40.00 L-80 BTCM ® I Liner Details "4 -1620 N-Ati I- w\ Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) tl _ 2,025.8 1,919.6 36.57 PACKER Baker HRD-E ZXP Liner top Packer 8.835 2,048.8 1,938.0 37.23 HANGER Baker FlexLock Liner hanger 9.410 2,057.9' 1,945.2 37.49 Casing Coupling crossover 9 5/8"X 10 3/4"BTC 8.410 Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len 0...Grade Top Thread GAS LIFT,2,880.57"INTERMEDIATE 7 6.276 28.1 12,253.2 5,685.7 26.00 L-80 BTC-m TIEBACK Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER INTERMEDIATE 7 6.473 12,243.5 13,894.0 6,054.7 26.00 L-80 TSH 563 II SURFACE;30.3-3,150.9-e. Liner Details Nominal ID GAS LIFT;5,895.8 Top(ftKB) Top(TVD)(ftKB) Top Incl 71 Item Des Corn (in) 12,243.5 5,682.5 70.73 PACKER Baker HRDE ZXP Liner Top Packer 6,190 'INI- 12,266.2 5,690.0 70.67 NIPPLE RS pack-off Nipple 6.190 GAS LIFT;8,341.8 12,269.0 5,691.0 70.66 HANGER Baker Flex-Lock Liner Hanger 6.200 IS Casing Description OD(in) ID(in) -Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1...Grade p Thread GAS UFT;70,793.6 LINER PROD.41/2" f 41/21 3.958 13,729.51 17,484.21 6,038.01 12.601 L-80 IMP Liner Details Nominal ID GAS LIFT:11,574.2 Top(ft613) Top(TVO)IftKB) Top Incl 71 Item Des Corn (in) W. 13,729.5 6,042.8 85.44 PACKER Baker HRD-E ZXP 5"x 7"Liner top packer L-80 5" 4.340 Hyd 521 pin-165'liner lap 7"INTERMEDIATE TIEBACK;_ 13,749.4 6,044.3 85.51 NIPPLE Baker 5"'RS"Packoff Seal Nipple 15 ppf L-80 Hyd 4.260 28.1-12,253.2 521 box x box 13,752.3 6,044.6 85.52 HANGER Baker 5"x 7"DG Flex-Lock Liner Hanger L-80 Hyd 4.360 521 pin x pin 1 13,772.1 6,046.1 85.59 SBE Baker 80-40 Sealbore Extension,5"L-80 Hyd 521 pin 4.000 x 4.5"Hyd 521 box LINER INTERMEDIATE I; 15,424.8 6,084.4 89.78 Swell Packer Baker 5.75"OD Self Energizing Reactive Packer 3.930 2,025.8-12,450.0 Assy B-63'above fault GAS LIFT;12,631.0 ; 15,626.0 6,082.6 92.89 Swell Packer Baker 5.75"OD Self Energizing Reactive Packer 3.930 IM Assy A-128'below fault fiki MI Tubing Strings la Tubing Description String Ma...ID(in) Top(560) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection MN TUBING-UPPER 31/2 2.992 25.0 13,783.0 6,046.9 9.30 L-80 Hyd 563 PLUG;13,710.8 t• COMPLETION Completion Details LOCATOR;13,733.3 ``■�� Top(ftKB) Top(ND)(ftKB) Top Incl CI Item Des Corn Nominal I ID 1 `. 25.0 25.0 0.30 HANGER 4-1/2"FMC Tubing Hanger 3.900 SEAL ASSY;13,734.5 I1=III 12,689.1 5,830.6 70.77 NIPPLE Camco 3-1/2"x 2.813"No-Go"DS"Nipple Hyddl 563 SN# 2.813 i 427336-01 13,710.8 6,041.3 85.37 PLUG Mirage Plug,775 psi Rupture disc installed,Rig did not 2.880 shear 13,733.3 6,043.1 85.45 LOCATOR Baker Locator 2.990 LINER INTERMEDIATE II; 12,243.5-13,894.0 13,734.5 6,043.2 85.46 SEAL ASSY Baker 80-40 GBH Locator Seal Assembly 3.000 El. Min ee Mandrel Inserts St !AT ati ligg on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn M. 1 2,880.5 2,511.5 Camco KBMG 1 GAS LIFT GLV BK 0.156 1,319.0 1/11/2017 Mil E; 2 5,895.8 3,612.5 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,287.0 1/11/2017 ICE 3 8,341.8 4,409.6 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,276.0 1/11/2017 4 10,193.6 5,002.9 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,302.0 1/11/2017 ,MI 5 11,574.2 5,460.2 Camco KBMG 1 GAS LIFT GLV BK 0.188 1,288.0 1/10/2017 = 6 12,631.0 5,811.5 Camco KBMG 1 GAS LIFT OV BK 0.250 0.0 1/10/2017 - tit sl Notes:General&Safety End Date Annotation sir NOTE lii] ICE MI MN ICE IRE ata: ilial iEL ; ME i:ec LINER PROD.412";13,729.4- 17,484.2 • � i i I 24 23� ,. i r 2'4 22 ., 1�6 .15� ADL391548 ! 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AD L390503 � II ADL392628 ADL025571 ADL390690 p a 2M-37 2M ADL390691 p ADL025585 Kuparuk PA ADL025586 Southern Miluveach Unit Kuparuk River Unit Well Trajectory ADL025590 ADL025589 3M-37 Open Interval 3M-37 01 Quarter Mile Radius ConocoPhillips Kuparuk PA N Alaska,Inc. I AK Unit CI Well Pad 2M-37 BRPC 0 0.2 0.4 0.6 0.8 1 Injection Sundry CPAI Leases Mlles 3/14/2017 • • LL N� O N d N ` E O V U Q ^i > W O a ti'> a m 0 T N ti 3 = 1• a 03 U Q d r o .75 U « a o c t w N a TS N m ^ 3 •E o a 0 0 0 o Q., c o 0 0 1-ti'« c o W vi al 1'!1 N C N O 03 2 o W N E > F 2- 1- E o H N "" � a H o a r' - — N 00 00 h Ha, V m ti N a m � � a E N '° CO U E22 Gti v. N v u 0-0. wanc Lo es O w ti U V N m to , Om. N n a a N a , W_ o o co L v o E _ y V W E g6 U J 3 N o, u H . ' E,1 a a a w o u m w v tiw m w x 0 c . o m 0 rfl 01 h ~ a To 0 t co N v C wc w c c o c .,,E-4.v.,..-.,. 0 0 o a 0 0 v a 't a CLL n a +• T C 0 d E , m c_ U E U CO O W Cf... o 1 O d o vO c E O o n f u u vi c U o co m 1- ^E'" ti - C > M O N z to Q O O 0. 0 PI P' DQ Q aTo 0 o - o n o a O Fo 0 .-i -1 0 m L., c 1- > O O 1- a a W Q Nm z N W N N 0 0 0 0 6 0 0 0 6 0 v v Q o 0 N N di T 0 O - 6 O N N N co co 9 0 C 6 O. N N N N • • Loepp, Victoria T (DOA) From: Shulman, Mark <Mark.Shulman@conocophillips.com> Sent: Wednesday,June 14,2017 9:15 AM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL] RE: KRU 2M-37(PTD 216-082, Sundry 317-185)Conversion to WAG Attachments: CoP 2M-37 SonicScope Top of Cement.pdf Victoria, Attached is the sonic log for the 2M-37 top of cement. I updated the AOR table,the previous AOR incorrectly included the 2nd intermediate casing cement depths instead of the production liner cement depths. Also,the top of cement for 2M-38 is calculated and not determined by a CBL. Below is the updated AOR with the correct depths which match the sonic log. Tsang Taa cA C-Said Twat Tap at PTDdRPI i4El@ NAME STATUS oft Cii!Ptrml Carmen, CeramTrp¢TSemens Aiesers+ ! Pari C 9 MOSS! 416175 111V37353Deseen+asoed Sy Status I w1 Iv:46m s r Gemoer a 5 @tiaa s Sz msrtuaf } 5:.Sc 3 32?7-5 w� h a 9st.:r:y :3—76 E.443 12 25; 5.3E5 Ss�cs!cpe P r!scaer.+er aargar ti. :r>3 13-=.x`14.95 x�ctcg"7 �6�r:� ^ b39 `ag prow c te9T 6, 3`'5, P61 Dg CHET€.S 5 s 7,3;"1",15.5 kG`s 2S Cfn5`. { 8 1{9-t6 sx I ce?ece“e•a4 Cecsenc,ISS5 Y;3 5v 9'1.,N.17 4 A' ....Ts T.i1t ;PZ1;a@+ 641,14 .5.1*5" 9755' riN+6'e^E Certs carr•a! V�.eer e'z'35.5 1' te-,`.rete Leaf femer�t a�tte�+.net Y4" product en +5,533 'Y:S: L•re-:,ate P-5=1 3:•s se 1,4 3ARE.C ass.G 324 s'15.0 put Class u' Please let me know if you have any more questions. Thanks, Mark From: Loepp,Victoria T(DOA) [ma ilto:victoria.loepp@alaska.gov] Sent:Tuesday,June 13,2017 1:55 PM To:Shulman, Mark<Mark.Shulman@conocophillips.com> Subject: [EXTERNAL] RE: KRU 2M-37(PTD 216-082,Sundry 317-185)Conversion to WAG Mark, In the AOR table,the TOC for 2M-37 is 10,200'MD as determined by a CBL. Please provide the log section that shows the TOC. Thanx, Victoria 1 • • • From:Shulman, Mark [mailto:Mark.Shulman@conocophiilips.com] Sent:Tuesday,June 13, 2017 10:17 AM To: Loepp,Victoria T(DOA)<victoria.loepp(oDalaska.gov> Subject: RE: KRU 2M-37(PTD 216-082,Sundry 317-185)Conversion to WAG Victoria, I was hoping to get an update on KRU 2M-37(sundry 317-185)conversion to WAG status? We submitted the application 5/5/2017 and submitted a response to your questions 5/8/2017. Please let me know if I can help answer any questions you may have. Thanks, Mark From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, May 10,2017 8:44 AM To:Shulman, Mark<Mark.Shulman@conocophillips.com> Subject: [EXTERNAL]KRU 2M-37(PTD 216-082,Sundry 317-185)Conversion to WAG Mark, On the area of review'A mile radius map, I do not see Producer KRU 2M-38? Please provide the MIT-IA history on KRU 2M-37. 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(aalaska.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.loepo@alaska.gov 2 � r r Zr® -� =1 ® K CV f si,6 I . . CD = cr en r 2 ``D 0 -1 0 • = Q (An CC G- 0- O CCM 0 3 m isel ..... cr En co ID ... cinS i 0 ID ormik C) W so 0 m NO s o * —1 C O to D ) v CD 3 CO w D, IV rola na O ti■ ul o 0 O m z cn a g v • a LID fD a . .... N O m FOLD HERE: lie well name,loca5cn and baehde n3ference data werefurished by fie("storm Any irtecntlm,reseerdi,ardysis,data,resat,estintes,a recarrrrerdation itnished with the services a cherwise ccmiuhicated by Sdiur elgar b the customer at any time in oomectiai with the sevioes are opirias based m inferences from measuerrents,empirical relationships,ands asstnptias;which,intsrences,empirical rdatianshps ands assurptic s at not infallible ad with respect b wlich poessiars in the irdty may fifer.Acoordrgy,Sdiulrirerger carnct and does rrotwarrart the accumy,ccmactrEss,a corrcieteress of ay such interpettc ,research,analysis,date rests,estimstes,a-neocare datiat the asthma-admowledges Cha ft is accepting the saviC"as is,"that:Scillt1rberger mates no regeserktm a wdrd ky,express a implied,day kind a ckscr on in reseed hereto,ad tit such services ae delivered with the explicit i derslandrg ad aggeerre t that ay aeon taken Chased on the services received shall beat its own risk and responsibility,ad no dam shall be made agent Sdiixrberger as a oorsequerte thereof. Svc.Order#: Interpretation Center: Analyst:3 Burt 2 Process Date: 29 Dec 2016 Location:AKA Techiog Vers: 2015.3 Y 111 • M N ne 9 ' v w (�t M I1 y II M � h m9( I M 44, I M H M p -13475 ` ' , ill : F� li•h If —13500 I +Y�i', X31„ fib, lkr , ' r — —13525 • '' . 1 I 1 1 if ....N.,..._4Vv\--- f 1 pt dYY- , —1390 !II, _______,\IL„.......,„„) V----- -1 'i7i 5 If s i : il IL' 4 I I I I 1 —13600 '..`” ', '+ ak. {:('':',1,:',,, l'',(,'.,'-';','''''1•'` 1: , ,„., --------.AA,--------1.\i-r*— _13525 Virk ` � �` + e 4� 1 — I I — �. �� Te V 6 �x F+, 1 41. Iii 1, :11,,`:,11,,,}5,,,., i 1 ir if), :F.: ,„, ' , i l . —73650 -13675 I r —,11 13700 # 1 ) iFd+i `1 .ii 4 d/1,,:l ,. :d r —13725 ` b w EF,.51 } �` —13750 r —13775 ';:' =z=r� ,' I i its, _.I • . , :1(11 \::;(t' 111,17;iit, 1 ii :'.1, r a-..—id"A 1 r---—4 I 4 H/' A-7 O u) Lry) Lf) LC0 (0 0 ( P Casing om �) t� cg (r- :0 � 0 0 0 O 0 0 0 0 0 r ;;SID_PREVEIW rojection V 5 in 8 -29.53 CSOD_PREVEIW SPR MH_FA_R_1 WF_FILT_MH 2 - R 1 WFA_MHT- R 1 5 in 8 0 us _ 3000 0 us 3000 DTSH MH FAR i eferenc _ _ _ (it) DTCO.MH_FA_R_1 ) Casing Amplitude :2� ' -20 unitless 100 • • • Loepp, Victoria T (DOA) From: Loepp, Victoria T(DOA) Sent: Tuesday,June 13, 2017 1:55 PM To: Shulman, Mark Subject: RE: KRU 2M-37(PTD 216-082, Sundry 317-185) Conversion to WAG Mark, In the AOR table,the TOC for 2M-37 is 10,200'MD as determined by a CBL. Please provide the log section that shows the TOC. Thanx, Victoria From:Shulman, Mark [mailto:Mark.Shulman@conocophillips.com] Sent:Tuesday,June 13,2017 10:17 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: KRU 2M-37(PTD 216-082,Sundry 317-185)Conversion to WAG Victoria, I was hoping to get an update on KRU 2M-37(sundry 317-185)conversion to WAG status? We submitted the application 5/5/2017 and submitted a response to your questions 5/8/2017. Please let me know if I can help answer any questions you may have. Thanks, Mark From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent:Wednesday, May 10, 2017 8:44 AM To:Shulman, Mark<Mark.Shulman@conocophillips.com> Subject: [EXTERNAL]KRU 2M-37(PTD 216-082,Sundry 317-185)Conversion to WAG Mark, On the area of review%mile radius map, I do not see Producer KRU 2M-38? Please provide the MIT-IA history on KRU 2M-37. 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.Loeppaa laska.gov 1 • . . Loepp, Victoria T (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday,June 13, 2017 1:40 PM To: Loepp,Victoria T(DOA) Subject FW: KRU 2M-37, PTD 216-082, Sonic/MADPass/CBL? FYI From:Guhl, Meredith D (DOA) Sent: Friday,June 9, 2017 4:25 PM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov> Subject: FW: KRU 2M-37, PTD 216-082,Sonic/MADPass/CBL? Hi Chris, I think the problem is a difference in terms.You are looking for a sonic log or TOC which I think means Top of Cement. Whereas CPAI runs a SonicScope which records TOC meaning Total Organic Carbon. If you look at the logs you will the LWD005 run in the 6.125 section has that data captured. Not sure how to fix this problem,we'll probably need to ask for clearer acronyms? Thanks, Meredith From: Elgarico, Richard E [mailto:Richard.E.Elgarico@conocophillips.corn] Sent: Monday, May 22,2017 6:19 PM To:Guhi, Meredith D(DOA)<meredith.guhl(a alaska.gov>; Lemke,Sandra D<Sandra.D.Lemke@conocophillips.corn> Cc:Wallace,Chris D(DOA)<chris.wallace@alaska.gov>; Cookson, Robert J<Robert.Cookson@conocophillips.corn> Subject: RE: KRU 2M-37, PTD 216-082,Sonic/MADPass/CBL? Hi Meredith, I have verified with our Kuparuk 2M Driller and Geo that there were no Sonic log nor CBL completed on this well.There was an LWD-Sonicscope TOC log that was run. Please let me know if you need anything else. Thanks, Ricky Ricky Elgarico Well Data Associate GGRE—Alaska IT ConocoPhillips 907 265-6580 1 • • • From:Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent:Wednesday, May 17,2017 10:01 AM To: Lemke,Sandra D<Sandra.D.Lemke@conocophillips.com>; Elgarico, Richard E <Richard.E.Elgarico@conocophillips.com> Cc:Wallace,Chris D (DOA)<chris.wallace@alaska.gov> Subject: [EXTERNAL]KRU 2M-37, PTD 216-082,Sonic/MADPass/CBL? Hi Sandra and Ricky, In the daily report for 12/22/2106 and 12/23/2016 there's mention of a sonic log being run, however to date we have only received a mudlog and the Schlumberger Vision service logging. Also in sundries there is mention of a CBL being evaluated. Can you please review the logs completed on this well and supply any outstanding logs and digital data that the AOGCC has not yet received. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, 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 DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2160820 Well Name/No. KUPARUK RIV UNIT 2M-37 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20745-00-00 MD 17510 TVD 6038 Completion Date 1/1/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No REQUIRED INFORMATION Q Mud Logv l r Samples No V//Directional Survey Yes V// DATA INFORMATION "oe Types Electric or Other Logs Run: GR/Res/Neutron/Density/Sonic TOC/Mud Log (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 27915 Digital Data 108 3160 1/17/2017 Electronic Data Set, Filename: CPAI 2M-37 . VISION Resistivity_RM_LWD001.1as ED C 27915 Digital Data 3082 12442 1/17/2017 Electronic Data Set, Filename: CPAI 2M-37 VISION Resistivity_RM_LWD002.las ED C 27915 Digital Data 12338 13896 1/17/2017 Electronic Data Set, Filename: CPAI 2M-37 VISION Service_RM_LWD004.las ED C 27915 Digital Data 13758 17510 1/17/2017 Electronic Data Set, Filename: CPAI 2M-37 • VISION Service_RM_LWD005.las ED C 27915 Digital Data 108 17510 1/17/2017 Electronic Data Set, Filename: CPAI 2M-37 VISION Service RM_LAS.Ias ED C 27915 Digital Data 147 17510 1/17/2017 Electronic Data Set, Filename: CPAI 2M-37 VISION_Custom_Channel_LAS _29Dec16.las ED C 27915 Digital Data 1/17/2017 Electronic File: CPAI 2M-37 VISION Resistivity RM LWD002 DLIS.dlis ED C 27915 Digital Data 1/17/2017 Electronic File: CPAI 2M-37 VISION Resistivity RM LWD002 DLIS.html ED C 27915 Digital Data 1/17/2017 Electronic File: CPAI 2M-37 VISION Service RM , LWD004 DLIS.dlis ED C 27915 Digital Data 1/17/2017 Electronic File: CPAI 2M-37 VISION Service RM LWD004 DLIS.html ' ED C 27915 Digital Data 1/17/2017 Electronic File: CPAI 2M-37 VISION Service RM LWD005 DLIS.dlis ED C 27915 Digital Data 1/17/2017 Electronic File: CPAI 2M-37 VISION Service RM . LWD005 DLIS.html ED C 27915 Digital Data 1/17/2017 Electronic File: CPAI 2M-37 VISION Resistivity RM LWD001 DLIS.dlis AOGCC Page I of 18 Wednesday, April 26, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2160820 Well Name/No. KUPARUK RIV UNIT 2M-37 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20745-00-00 MD 17510 ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C Log C Log C ED C ED C TVD 6038 Completion Date 1/1/2017 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Digital Data 27915 Log Header Scans 27935 Log Header Scans 27935 Digital Data 27935 Digital Data Completion Status 1 -OIL AOGCC Page 2 of 18 0 0 0 0 3161 17510 3160 17510 Current Status 1 -OIL UIC No 1/17/2017 Electronic File: CPAI 2M-37 VISION Resistivity RM LWD001 DLIS.html 1/17/2017 Electronic File: CPAI 2M-37 VISION Service RM DLIS.dlis 1/17/2017 Electronic File: CPAI 2M-37 VISION Service RM DLIS.html 1/17/2017 Electronic File: CPAI (� `1/17/2017 _2M- 37_VISION_Service_2in_MD.pdf Electronic File: CPAI_2M- P 37_VISION_Service_2in_TVD.pdf . /17/2017 Electronic File: CPAI _2M- 37 VISION Service 5in MD.pdf ' 1/17/2017 Electronic File: CPAI 2M - 1P 37_VI S I ON_Service_5in_TV D. pdf 1/17/2017 Electronic File: 2M-37 Nad27 EOW CompassSurveys.pdf 1/17/2017 Electronic File: 2M-37 Nad27 [Canvas].txt 1/17/2017 Electronic File: 2M-37 Nad27 [Macro].txt' 1/17/2017 Electronic File: 2M-37 Nad27 [Petrel].txt- 1/17/2017 Electronic File: 2M-37 Nad27 [Survey].txt 1/17/2017 Electronic File: 2M-37 Nad83 EOW . CompassSurveys.pdf 1/17/2017 Electronic File: 2M-37 Nad83 [Canvas].txt• 1/17/2017 Electronic File: 2M-37 Nad83 [Macro].txt• 1/17/2017 Electronic File: 2M-37 Nad83 [Petrel].txt - 1/17/2017 Electronic File: 2M-37 Nad83 [Survey].txt, 2160820 KUPARUK RIV UNIT 2M-37 LOG HEADERS 2160820 KUPARUK RIV UNIT 2M-37 LOG HEADERS 1/30/2017 Electronic Data Set, Filename: 2M-37 Chromatograph.las 1/30/2017 Electronic Data Set, Filename: 2M-37 Lith Cuttings.las Wednesday, April 26, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2160820 Well Name/No. KUPARUK RIV UNIT 21VI-37 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20745-00-00 MD 17510 TVD 6038 Completion Date 1/1/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 27935 Digital Data 3160 17509 1/30/2017 Electronic Data Set, Filename: 21VI-37 Lith. Interp.las ED C 27935 Digital Data 3160 17510 1/30/2017 Electronic Data Set, Filename: 21VI-37 Mudlog.las ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37 FINAL END OF WELL - P REPORT.pdf ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37 2MD DEL.emf - ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37 21VID FEL.emf' ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37 21VID GRL.emf ' ED C 27935 Digital Data 1/30/2017 Electronic File: 21VI-37 21VID DEL.pdf - ED C 27935 Digital Data P1/30/2017 Electronic File: 2M-37 2MD FEL.pdf ' ED C 27935 Digital Data %01/30/2017 Electronic File: 2M-37 21VID GRL.pdf' ED C 27935 Digital Data 1/30/2017 Electronic File: 21VI-37 2MD DEL.tif , ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37 21VID FEL.tif - ED C 27935 Digital Data 1/30/2017 Electronic File: 21VI-37 21VID GRL.tif ' ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_11520MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_'3660'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10020'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10050'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10080'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10110'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10140'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10170'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10200'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10230'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10260'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10290'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10320'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10350'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10380'MD.jpg AOGCC Page 3 of 18 Wednesday, April 26, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2160820 Well Name/No. KUPARUK RIV UNIT 21VI-37 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20745-00-00 MD 17510 TVD 6038 Completion Date 1/1/2017 Completion Status 1-0IL Current Status 1-0I1- UIC No ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10410'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10440'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10470'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10500'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10530'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10560'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10590'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10620'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10650'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10680'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_10710'MD.jpg ED C 27935 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2M-37_5280'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_5310'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_5340'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_5370'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_5400'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_5430'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_5460'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_5490'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_5520'MD.jpg AOGCC Page 8 of 18 Wednesday, April 26, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2160820 Well Name/No. KUPARUK RIV UNIT 21VI-37 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20745-00-00 MD 17510 TVD 6038 Completion Date 1/1/2017 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_5550'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 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Well Name/No. KUPARUK RIV UNIT 21VI-37 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20745-00-00 MD 17510 TVD 6038 Completion Date 1/1/2017 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_6420'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_6450'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_6480'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_6510'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_6540'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_6570'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_6630'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_6660'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_6690'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_6720'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_6750'MD.jpg ED C 27935 Digital Data 1/30/2017 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Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20745-00-00 MD 17510 TVD 6038 Completion Date 1/1/2017 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9060'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9090'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9120'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9150'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9180'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9210'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9240'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9270'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9300'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9330'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9360'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_9390'MD.jpg ED C 27935 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UNIT 21VI-37 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20745-00-00 MD 17510 TVD 6038 Completion Date 1/1/2017 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_13770'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_13780'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_13790'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_13800'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_13810'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_13820'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_13830'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_13840'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_13850'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_13860'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 2M-37_13870'MD.jpg ED C 27935 Digital Data 1/30/2017 Electronic File: 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2M-37_17510'MD.jpg Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED AOGC'(' Page 17 of 18 Wednesday, April 26, 2017 DATA SUBMITTAL COMPLIANCE REPORT 4/26/2017 Permit to Drill 2160820 Well Name/No. KUPARUK RIV UNIT 2M-37 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20745-00-00 MD 17510 TVD 6038 Completion Date 1/1/2017 Completion Status 1-0I1- Current Status 1-0I1- UIC No Completion Report 0 Directional / Inclination Data D Mud Logs, Image Files, Digital Dat 6NA Core Chips Y A Production Test Informatior�NA Mechanical Integrity Test Information Y /� Composite Logs, Image, Data File,, Core Photographs Y NA Geologic Markers/Tops Daily Operations Summary OY Cuttings Samples Y / NA) Laboratory Analyses Y / A COMPLIANCE HISTORY Completion Date: 1/1/2017 Release Date: 7/7/2016 Description Date Comments Comments: Compliance F -- -_ - A( -- Date: AOGCC Page 18 of 18 Wednesday, April 26, 2017 nTo a1�--ng2— Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, February 19, 2017 4:35 PM To: Loepp, Victoria T (DOA) Cc: Senden, R. Tyler Subject: RE: Report of sustained casing pressure of OA on KRU producer 2M-37 (PTD 216-082-0) 01-24-17 update 2-19-17 Follow Up Flag: Follow up Flag Status: Flagged Victoria, It does appear that 2M -37's elevated OA pressure is due to a case of IAxOA communication. Earlier in the diagnostic process, the IAxOA communication theory was discounted because the IA and OA gas samples (taken repeatedly for confirmation) did not match compositionally. However, on 02/12/17, the lift gas was shut off and IA bled down to flowline pressure (-310psi), with the OA bled off to—100psi above the IA. During the initial 3.5 hr monitor period, the OA only climbed 11psi with no additional buildup observed overnight. As soon as the lift gas was returned to the well, only then did the OA begin to build pressure again. It is suspected that the proprietary gelled -diesel that fills most of the OA is scrubbing the migrating lift gas of its heavier components, causing the gas samples to not match. The well passed an MITOA to 1800 psi on 02/02/17 and inner casing packoff testing on 02/12/17 and 01/22/17, indicating this is a downhole gas -only leak. CPAI intends to waiver this well for IAxOA communication and allow the OA to equalize with the IA, up to a gas lift header pressure of 1400psi. Please let us know if you have any questions. Kelly Lyons / Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, January 25, 2017 9:21 AM To: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Subject: [EXTERNAL]RE: Report of sustained casing pressure of OA on KRU producer 2M-37 (PTD 216-082-0) 01-24-17 Thanx for the update. Let me know the plan forward when it is developed. 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)alas ka.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: NSK Well Integrity Supv CPF1 and 2[mailto:n1617@conocophillips.comj Sent: Tuesday, January 24, 2017 5:23 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.TVIer.Senden@conocophillips.com> Subject: Report of sustained casing pressure of OA on KRU producer 2M-37 (PTD 216-082-0) 01-24-17 Victoria, Newly drilled KRU Gas -lifted Producer 2M-37 (PTD 216-082-0) is experiencing sustained casing pressure of the OA above the DNE of 1000psi. The well was initially put on production on January 18, 2017. There has been a repeated need for bleeding to maintain the OA below the DNE. The OA is completed with a proprietary gelled diesel product. Due to the extended nature of the continued buildup in OA pressure, it is not clear whether there is some form of communication present or if this is simply a prolonged thermal response, hampered by the gelled fluid. On January 22, the OA was allowed to rise above the DNE so that we could determine its equalization point. It has now been maintaining a pressure of—1165psi for a couple of days now, with a simultaneous gas lift IA pressure of 1300psi. 2M-37 is completed with an L-80, 68#, 13-3/8" surface casing string which has a burst rating of 5020psi. Therefore the current elevated pressure only represents ^23% of burst. Over the next several days we will continue to perform repeated diagnostic bleeding and monitoring (and possibly other well intervention logging if needed) to help determine the cause of the elevated pressure. A follow-up email will be provided once a path forward has been established. Let me know if you have any questions. Attached is a schematic for reference. Kelly Lyons / Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED --r-r. 9 2 201/ WELL COMPLETION OR RECOMPLETION REPORT AND LOO 1a. Well Status: Oil [21 • Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ 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.: 1/1/2017 216-082/ 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 11/23/2016 50-103-20745-00-00 . 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 5166' FNL, 116' FEL, Sec 28, T11 N, R8E, UM 12/27/2016 KRU 2M-37 Top of Productive Interval: 9. Ref Elevations: KB:129.7 17. Field / Pool(s): 4299' FNL, 748' FEL, Sec 30, T11 N, R8E, UM GL: 102.3 BF: Kupurak River Field/Kuparuk Oil Pool Total Depth: .1.114. 3900' FNL, 4322' FEL, Sec 30, i4R8E, UM 10. Plug Back Depth MD/TVD: N/A 18. Property Designation: ADL 25586, ADL 25585 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 487726 y- 5948986 Zone- 4 17510/6038 931894000,931893000 TPI: x- 476533 y- 5949884 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 472959 y- 5950290 Zone- 4 N/A 1509/1470 5. Directional or Inclination Survey: Yes E] (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 N/A (ft MSL) N/A 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/Neutron/Density/Sonic TOC/Mud Log 23. CASING, LINER AND CEMENTING RECORD WT. PER CASING FT GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 94 H-40 32 162 32 162 42 Cement in Place 13.375 68 L-80 30 3151 30 2654 16 1465 sx 11.0 ppg DeepCrete, 239 sx 12.0 ppg DeepCrete 9.625 40 L-80 2038 12450 11929 15751 112.25 1832 sx 15.6 ppg Class G 726 L-80 28 13894 28 6054 8.5x9.875 526 sx 15.8 ppg Class G 4.5 12.6 L-80 1 13729 17484 16043 6038 16.125 Liner w/Perforated Joints 24. Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number): 3 1/2 13783 2028/1929 Perf Pup @ 13915-13955 MD and 6055 -6057 TVD, Perf Pup @ 14037 - 12243/5682 14077 MD and Perf Pups @14196 - 14236 MD and 6055 -6054 TVD, 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Perf Pup @ 14357 - 14398 MD and 6052 -6052 TVD, Perf Pup @ - 14520 - 14559 MD and 6052 -6052 TVD, Perf Pup @ 14681 - 14720 MD and 6054 - 6054 TVD, Perf Pup @ 14842 - 14882 MD and 6057 - 6058 TVD, Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Perf Pup @ 15003 - 15044 MD and 6067 -6071 TVD, Perf Pup @ - 15166 - 15207 MD and 6078 - 6079 TVD, Perf Pup @ 15329 - 15370 MD and 6082 -6084 TVD, Perf Pup @ 15731 - 15772 MD and 6076 -6073 TVD, Perf Pup @15894 - 15935 MD and 6067 - 6066 TVD, Perf Pup @ 16057 - 16097 MD and 6061 - 6059 TVD, Pert Pup @ 16219 -16258 MD and (-0MPl_ l= TION 6052 - 6050 TVD, Perf Pup @ 16381 - 15421 MD and 6044 - 6041 TVD, nATr Perf Pup @ 16545 -16585 MD andf 6036 - 6035 TVD, Perf Pup @ 16708 - 16748 MD and 6033 - 6033 TVD, Perf Pup @ 16870 - 16909 MD and 6034- 6035 TVD, Perf Pup @ 17031 - 17072 MD and 6038 - 6039 TVD, -- F:p r�Fn Perf Pup @ 17194 - 17235 MD, and 6042 - 6041 TVD, Perf Pup @ 17356 L V 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 1/18/2017 GAS LIFT Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 1/30/2017 10 HRS Test Period 1246 1248 20 100% 884 Flow Tubing Casinq Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravitv - API (corr): Press. 260 si 1253 si 24 -Hour Rate 2652 3131 45 Form 10-407 Revised 1��0�5�G� �T��`�`` 2 r7Submit ORIGINIAL onlue COWED ID��J L- F�� J 2 28. CORE DATA Conventional Core(s): Yes ❑ No 0 Sidewall Cores: Yes ❑ No ❑� 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. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Surface Permafrost - Base 1509 1470 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 13766 6045 information, including reports, per 20 AAC 25.071. Top W Sak 2125 1998 Base W Sak 2991 2572 C-80 3654 2877 C-37 9195 4681 HRZ 12410 5738 Upper Kalubik 12823 5875 Lower Kalubik 13099 5959 TD 17150 6038 Formation at total depth: Ku aruk A4 31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, aleon of ical rer)ort, r)roduction 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: Kurt Alexa Cil 263-4933 Email: Kurt.J.Alexa co .com Printed Name: G. Alvord Title: Alaska Drilling Manager Signature: - - Phone: 265-6120 Date: 2-(2- LO ' 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 1 a: 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 1 b: 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, Ground Level, and Base Flange 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 11/2015 Submit ORIGINAL Only 2M-37 Final Wellbore Schematic ConocoPhillips Updated: 01/03/17 by K. Alexa Conductor To Be Installed: 20" driven to +/-162' ;U i.iAh Tubing: 3-%2" 9.3# L-80 HYD563 12-1/4" Intermediate Hole 9,200' MD/4,680' TVD C .3.#'aober '.... 10,191' MD/5,000' TVD TOC @ +/-10,200' MD HRD-E ZXP Packer: 12,244' MD 7" x 9 5/8" Flex -Lock liner hanger: 12,269' MD/ 5,691' TVD 12,405' MD/5,731' TVD kL Intermediate 1: 9 5/8" 40#, L80,BTC-M +/-12,450' MD/5,751' TVD — 8-1/2" x 9-7/8" LSND WBM 1.0,5-12.3 PP" Intermediate Hole HRD-E ZXP Packer: 13,729' MD/6,043'TVD C -Sand Top: 13,776' MD/6,045' TVD 7" x 4-h" Baker Flex Lock Liner hanger: 13,752' MD 6,044' TVD ..... ................. ersn iate� 7"..26#, LSO,.Hydnl56 13894' MI?/6i!55 Int`:vi ............ ......... ...................... ;. ..... 6',i.:..otutiot:Ht�l O.W. lsiwl :::: M Ppg wif.:tiiNP&:rte::::::::::: 000 000 000 000 000 000 000 000 coo 000 000 000 000 000 000 000 000 000 000 000 000 000 00 000 000 000 000 a4MD= 2&t5524,MD.:; . f tiI Production Liner: 4-1/2"12.6# L-80 TXP +/-17,484' MD/6,038 TVD Every 3'd joint perforated e =�Y Operations Summary (with Timelog Depths) ' 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/21/2016 11/21/2016 1.50 MIRU MOVE MOB P Load camp and shop on trucks, load 10:30 12:00 pipe sheds onto trucks and spot on edge of pad. 11/21/2016 11/21/2016 2.00 MIRU MOVE MOB P Continue to rig down modules. Hook 12:00 14:00 up and position boiler/power/pump/pits & sub on pad. 11/21/2016 11/21/2016 0.50 MIRU MOVE MOB P Move modules to the spine road 14:00 14:30 11/21/2016 11/21/2016 1.50 MIRU MOVE MOB P Continue to move rig modules to M- 14:30 16:00 pad 11/21/2016 11/21/2016 1.00 MIRU MOVE MOB P Position modules on M -pad and set up 16:00 17:00 sub to crab 11/21/2016 11/21/2016 3.75 MIRU MOVE MOB P Crab sub and spot over well 17:00 20:45 11/21/2016 11/22/2016 3.25 MIRU MOVE MOB P Spot pits pump and power. Begin 20:45 00:00 spotting boiler room and stage pipe shed. 11/22/2016 11/22/2016 2.00 MIRU MOVE MOB P Spot boiler complex 00:00 02:00 11/22/2016 11/22/2016 2.00 MIRU MOVE MOB P Spot rock washer and pipe sheds. 02:00 04:00 Hook up mud and electrical innerconnects (sim-ops) 11/22/2016 11/22/2016 1.50 MIRU MOVE RURD P Spot camp, shop. Get steam, water, 04:00 05:30 and air going throughout the rig. Continue with electrical innerconnects, swap rig power over for cold starts to 3512's 11/22/2016 11/22/2016 2.00 MIRU MOVE RURD P Lower stair around rig, update well 05:30 07:30 sign. Spot envior vac, berm enviro vac, cuttings tank, berm around rock washer. Install skate rail. 11/22/2016 11/22/2016 2.00 MIRU MOVE RURD P Install surface riser, secure surface 07:30 09:30 annular, building spud mud in pits. Put pumps back together and primed. 11/22/2016 11/22/2016 2.50 MIRU MOVE RURD P Weld bracket on cement line on rig 09:30 12:00 floor, misc welding on rig floor. Continue building 30 ppg gel unweighted spud mud in pits. Work on T/D brake's, continue rig up of MWD and DD. Spot mud logging shack. Build and install manifold on annular and diverter. Hook up accumulator lines to annular. 11/22/2016 11/22/2016 6.00 MIRU MOVE RURD P Continue building the 30 ppb gel 12:00 18:00 unweighted spud mud. Finish NU on diverter tee. Remove kelly hose and install MWD sensor tee on stand pipe. Re -install kelly hose and run sensor line from MWD sensor on stand pipe to rig floor. Install 4" pipe and valves on conductor. BO and remove 4" XT - 39 Saver sub and install 4-1/2" IF saver sub on top drive. Change iron roughneck dies to 5". Load and tally 5" DP 11/22/2016 11/22/2016 1.00 MIRU MOVE SFTY P Pre -spud meeting with crew. 18:00 19:00 Page 1/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Cade Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/22/2016 11/22/2016 0.50 MIRU MOVE BOPE P Complete diverter test (witness of test 19:00 19:30 waived by Lou Grimalde at 14:45) 11/22/2016 11/22/2016 3.00 MIRU MOVE RURD P Continue loading the 5" DP, Strap 19:30 22:30 same, (SIMOPS assist MWD with rig up). 11/22/2016 11/23/2016 1.50 MIRU MOVE PULD P P/U and stand back 16 stands of 5" dp 22:30 00:00 in derrick. 11/23/2016 11/23/2016 7.75 MIRU MOVE PULD P Continue to make stands and rack 00:00 07:45 back 5" Drill pipe and HWDP. 64 stands total of 5" DP and 8 stands of 5" HWDP. RIH and tag Gravel at 37- 1 11/23/2016 11/23/2016 0.75 MIRU MOVE SFTY P Jake Voss presented Pre spud 07:45 08:30 meeting to the crews and operational personnel 11/23/2016 11/23/2016 0.25 MIRU MOVE SEQP P Pressure test surface mud lines to 08:30 08:45 3000 psi 11/23/2016 11/23/2016 1.25 MIRU MOVE BHAH P Mobilize BHA to the rig floor 08:45 10:00 11/23/2016 11/23/2016 1.50 MIRU MOVE SLPC P Slip and cut 57' of drilling line, 9 10:00 11:30 wraps. Service TD, blocks, drawworks and calibrate block height. 11/23/2016 11/23/2016 0.50 SURFAC DRILL BHAH P PJSM - Pick up surface BHA as per 11:30 12:00 DD. 11/23/2016 11/23/2016 1.00 SURFAC DRILL DDRL P Pressure test flood lines (HI -Pressure 12:00 13:00 lines) @ 3500 psi. BD top drive. 11/23/2016 11/23/2016 0.75 SURFAC DRILL BHAH P PJSM for spuding and BHA. MU mud 13:00 13:45 motor. Stab and XO. 11/23/2016 11/23/2016 2.50 SURFAC DRILL DDRL P Drilling from 28' MD to 222' MD, TVD 28.0 222.0 13:45 16:15 = 222'. AST = 0, ART = 2.17, ADT = 2.17, Bit HRS = 2.17. Total jar HRS = 64.90. PU WT = 50 lbs, SO WT = 50 lbs, ROT WT = 50, TQ ON = 1 -2K, TQ off = 0, ECD = 0, Flow out = 42%, WOB = 5-10K, RPM = 40, GPM = 559, SPM = 130 11/23/2016 11/23/2016 3.50 SURFAC DRILL BHAH P POOH and stand back two stands P/U 222.0 222.0 16:15 19:45 MWD tools and orient motor. 11/23/2016 11/23/2016 2.25 SURFAC DRILL WAIT T General house keeping and MP2 work 222.0 222.0 19:45 22:00 orders while waiting on communications to be setup. 11/23/2016 11/23/2016 1.50 SURFAC DRILL DHEQ P P/U NM DC and one joint of HWT and 222.0 222.0 22:00 23:30 obtain shallow hole test. 11/23/2016 11/24/2016 0.50 SURFAC DRILL DDRL P Drlg F/ 222'T/ 305' MD, TVD = 305'. 222.0 305.0 23:30 00:00 AST =.67, ART = 0.0, ADT =.67, Bit HRS = 2.84. Total jar HRS = 65.57. PU WT = 55 lbs, SO WT = 55 lbs, ROT WT=505 TQ ON=2 11/24/2016 11/24/2016 6.00 SURFAC DRILL DDRL P Drlg F/ 305'T/ 602' MD, TVD = 601'. 305.0 602.0 00:00 06:00 AST = 2.24., ART = 1.49, ADT = 1.56., Bit HRS = 6.57 . Total jar HRS = 69.30. PU WT = 66K lbs, SO WT = 66K lbs, ROT WT = 66K lbs TQ ON = 3.5K, TQ OFF = 0, Flow out = 48%, WOB = 5-20K, RPM = 40, GPM = 450, Bit Speed - 139 RPM's, PSI ON = 800, PSI OFF = 550, Max. (Gas =0) Page 2140 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (WEI) 11/24/2016 11/24/2016 6.00 SURFAC DRILL DDRL P Drlg F/ 602'T/ 967' MD, TVD = 967'. 602.0 967.0 06:00 12:00 AST = 1.54., ART = 2.28, ADT = 3.82., Bit HRS = 10.39 . Total jar HRS = 73.12. PU WT =83K lbs, SO WT = 80K lbs, ROT WT = 82K lbs TQ ON = 3.5K, TQ OFF = 3, Flow out = 47%, WOB = 20-25K, RPM = 40, GPM = 500, Bit Speed - 139 RPMs, PSI ON = 1200, PSI OFF = 550, (Max. Gas =0) 11/24/2016 11/24/2016 6.00 SURFAC DRILL DDRL P Drlg F/ 967'T/ 1345' MD, TVD = 967.0 1,345.0 12:00 18:00 1331'. AST = 2.41., ART = 2.26, ADT =4.67, Bit HRS = 15.06 . Total jar HRS = 77.39. PU WT =88K lbs, SO WT = 80K lbs, ROT WT = 80K lbs TQ ON = 1 OK, TQ OFF = 3, Flow out = 50%, WOB = 25-30K, RPM = 40, GPM = 550, Bit Speed - 139 RPM'S, PSI ON = 1200, PSI OFF = 550, (Max. Gas = 0) 11/24/2016 11/25/2016 6.00 SURFAC DRILL DDRL P Drlg F/ 1345'T/ 1698' MD, TVD = 1,345.0 1,698.0 18:00 00:00 1642'. AST =2.06., ART = 2.79, ADT =4.85, Bit HRS = 19.91 . Total jar HRS = 82.64. PU WT =92K lbs, SO WT = 88K lbs, ROT WT = 92K lbs TQ ON = 7K, TQ OFF = 3, Flow out = 52%, WOB = 5-20K, RPM = 40, GPM = 650, Bit Speed - 139 RPMs, PSI ON = 1700, , (Max. Gas = 0) 11/25/2016 11/25/2016 6.00 SURFAC DRILL DDRL P Drlg F/ 1698'T/ 2073' MD, TVD = 1,698.0 2,073.0 00:00 06:00 1946'. AST =2.76., ART = 1.54, ADT =4.30, Bit HRS = 24.21 . Total jar HRS = 86.94. PU WT = 104K lbs, SO WT = 91 K lbs, ROT WT = 95K lbs TQ ON = 7K, TQ OFF = 4, Flow out = 48%, WOB = 30K, RPM = 40, GPM = 650, Bit Speed - 139 RPM's, PSI ON = 1650, , (Max. Gas = 0) 11/25/2016 11/25/2016 6.00 SURFAC DRILL DDRL P Drlg F/ 2073'T/ 2425' MD, TVD = 2,073.0 2,425.0 06:00 12:00 2223'. AST =2.46., ART = 1.96, ADT =4.42, Bit HRS = 28.63 . Total jar HRS = 91.36. PU WT = 115K lbs, SO WT = 93K lbs, ROT WT = 95K lbs TQ ON = 8K, TQ OFF = 4, Flow out = 51 %, WOB = 30K, RPM = 40, GPM = 700, Bit Speed - 139 RPM's, PSI ON = 1800, , (Max. Gas = 0) 11/25/2016 11/25/2016 6.00 SURFAC DRILL DDRL P Drlg F/ 2425' T/ 2780' MD, TVD = 2,425.0 2,780.0 12:00 18:00 2453'. AST =2.57., ART = 2.21, ADT =4.78, Bit HRS = 33.41. Total jar HRS = 69.14. PU WT = 108K lbs, SO WT = 94K lbs, ROT WT = 97K lbs TQ ON = 8K, TQ OFF = 3, Flow out = 51 %, WOB = 30K, RPM = 40, GPM = 700, Bit Speed - 139 RPMs, PSI ON = 2150, (Max. Gas = 0) Page 3/40 ReportPrinted: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Depth (ftKB) 11/25/2016 11/26/2016 6.00 SURFAC DRILL DDRL P Drlg F/ 2780' T/ 3113' MD, TVD = 2,780.0 3,113.0 18:00 00:00 2636'. AST =1.99., ART = 2.1, ADT = 4.09, Bit HRS = 37.50. Total jar HRS = 100.23. PU WT = 112K lbs, SO WT = 100K lbs, ROT WT = 93K lbs TQ ON = 1 OK, TQ OFF = 5, Flow out = 52%, WOB = 30K, RPM = 40, GPM = 700, Bit Speed - 139 RPMs, PSI ON = 2175, (Max. Gas = 0) 11/26/2016 11/26/2016 1.00 SURFAC DRILL DDRL P Drlg F/ 3113' T/ 3160' MD, TVD = 3,113.0 3,160.0 00:00 01:00 2657'. AST =.68., ART =.25, ADT = 4.09, Bit HRS = 38.43. Total jar HRS = 101.16. PU WT = 115K lbs, SO WT = 92K lbs, ROT WT = 97K lbs TQ ON = 8K, TQ OFF = 6, Flow out = 52%, WOB = 30K, RPM = 40, GPM = 700, Bit Speed - 139 RPMs, PSI ON = 2150, (Max. Gas = 0) 11/26/2016 11/26/2016 1.75 SURFAC CASING CIRC P CBU @ 850 gpm, while back reaming 3,160.0 3,099.0 01:00 02:45 out slowly, Rack stand back every bottoms up for CBU-X -2. F/ 3160' T/3099' MD, 60 RPM, 5K Tq, 2590 psi. 11/26/2016 11/26/2016 0.50 SURFAC CASING OWFF P Blow down Top Drive and monitor well 3,099.0 3,099.0 02:45 03:15 for 30 mins. 11/26/2016 11/26/2016 6.75 SURFAC CASING BKRM P BROOH F/ 3099'T/ 1575' MD, @ 850 3,099.0 1,575.0 03:15 10:00 gpm 2600 psi, 60 rpm, 3-6 Tq, At the base of permafrost CBU x 2.5 times, P/U= 95K, S/O= 87K, Rot= 90K. 11/26/2016 11/26/2016 1.50 SURFAC CASING TRIP P Pull on Elevators F/ 1575'T/ 247" 1,575.0 247.0 10:00 11:30 Calc disp= 18.78 bbls, Actual Disp= 21.93 bbls. 11/26/2016 11/26/2016 0.50 SURFAC CASING BHAH P PJSM, L/D BHA as per -DD F/ 247'T/ 247.0 121.0 11:30 12:00 121' MD 11/26/2016 11/26/2016 2.25 SURFAC CASING BHAH P Continue L/D BHA F 121'T/ 0.0' MD 121.0 0.0 12:00 14:15 Calc Disp= 27.13, Actual Disp= 32.30 bbls. 11/26/2016 11/26/2016 1.50 SURFAC CASING RURD P Clean and clear rig floor of BHA subs 0.0 0.0 14:15 15:45 and stabilizers, bring up tools for casing run. 11/26/2016 11/26/2016 1.75 SURFAC CASING RURD P PJSM, R/U Doyon casing tools for 13- 0.0 0.0 15:45 17:30 3/8" casing run. 11/26/2016 11/26/2016 2.00 SURFAC CASING OTHR P Add pup to landing joint, while making 0.0 0.0 17:30 19:30 dummy run with hanger. Brk hanger off and leave on rig and lay down landing joint. (Marked landing joint while landed) 11/26/2016 11/27/2016 4.50 SURFAC CASING PUTB P Run 17 joints of 13.375" 68# L-80 0.0 593.0 19:30 00:00 Hydril 563 casing F/ 0' T/ 593' MD, Laid two joints down due to cross threads Jts # 16 and # 17, replaced with jts # 80 and # 93. (0.26' longer). S/O wt= 50 K. Losses seen= 15 bbls. 11/27/2016 11/27/2016 3.25 SURFAC CASING PUTB P Contiue to RIH with 13.375" L-80 563 593.0 1,572.0 00:00 03:15 casing, filling on the fly and top off every 10 joints, S/O wt= 80 K, Calc Disp= 19.84, Actaul Disp= 10 bbls. Page 4/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) k 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Cade Time P-T-X Operation (ftKB) End Depth (WEI) 11/27/2016 11/27/2016 0.75 SURFAC CASING CIRC P Circ casing volume while working pipe 1,572.0 1,531.0 03:15 04:00 F/ 1572'T/ 1531' staging pumps up to 8 bpm with 175 psi, P/U 130 K, S/O wt= 95 K, 6 bbls loss for circulation 11/27/2016 11/27/2016 5.50 SURFAC CASING PUTB P RIH with 13.375" L-80 563 Hydril 1,572.0 3,117.0 04:00 09.30 casing F/1531' T/ 3117' MD, P/U wt= 225' S/O wt= 135 K, Calc Disp= 36, AQctaul Disp= 25 bbls. 11/27/2016 11/27/2016 1.00 SURFAC CASING HOSO P M/U hanger and landing joint RIH to 3,117.0 3,150.0 09:30 10:30 3150' MD,whilecirc @ 1.5 bpm with 200 psi, land on load shoulder on depth @ 3150' MD, P/U wt= 225 K, S/O wt= 135 K. 11/27/2016 11/27/2016 1.50 SURFAC CEMENT CIRC P Stage pumps up to 8 bpm with 225 3,150.0 3,140.0 10:30 12:00 psi, while reciprocating F/ 3150'T/ 3140' MD, P/U wt= 225 K, S/O wt= 135 K, 5 bbls loss while circulating. 11/27/2016 11/27/2016 0.75 SURFAC CEMENT CIRC P Continue circulating & conditioning 3,140.0 3,150.0 12:00 12:45 Mud for cement @ 8 bpm and 225 psi while working pipe, P/U wt= 225 K, S/O wt= 135 K. 11/27/2016 11/27/2016 0.50 SURFAC CEMENT RURD P Blow down Top Drive and R/U cement 3,150.0 3,150.0 12:45 13:15 line. 11/27/2016 11/27/2016 4.50 SURFAC CEMENT CIRC P Circulate and prep pits and trucks for 3,150.0 3,140.0 13:15 17:45 cement job. Had 10.0 ppg mud wt coming back, water back and haul off to make room for cement job. P/U wt= 225 K, S/O wt= 140 K. 11/27/2016 11/27/2016 5.25 SURFAC CEMENT CMNT P PJSM, Pumped 5 bbls CW-100 and 3,140.0 3,150.0 17:45 23:00 tested cement lines to 3500 psi followed by 35 bbls of CW-100, pumped 70.9 bbls of Mud Push 10.5 ppg, droped bottom plug followed by 514 bbls of Deep Crete 11.0 ppg lead cement, batched up and pumped 70 bbls of 12.0 ppg tail cement, dropped top plug with 10 bbls of water, switched over to rig and displaced with 7 bpm with 400 psi folowed by 3 bpm for last 10 bbls and bumped plug with calculated strokes 4459. P/U to 1200 psi and held for 5 mins, bled off psi and checked flaots good. Got back 230 bbls of cement to surface. 11/27/2016 11/27/2016 0.50 SURFAC CEMENT RURD P R/D Cement lines and flush line and 3,150.0 3,150.0 23:00 23:30 divert and flow line out with black water, Monitor well 11/27/2016 11/28/2016 0.50 SURFAC CEMENT RURD P R/D Volant tool and landing joint. 3,150.0 3,150.0 23:30 00:00 11/28/2016 11/28/2016 3.00 SURFAC CEMENT RURD P Continue rigging down bails 00:00 03:00 extentions, send out casing equipment, Volant, flush and work annular with black water, clean cement demco valves, clean pits, clean rock washer while loading pipe in shed. 11/28/2016 11/28/2016 3.50 SURFAC CEMENT NUND P N/D diverter line, knife vlve, diverter T 03:00 06:30 surface annular and remove from the cellar area, Locate top of cement 4" below conductor ports. Page 5/40 Report Printed: 1/17/2017 ° Operations Summary (with Timelog Depths) 2M-37 k Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/28/2016 11/28/2016 5.50 SURFAC WHDBOP NUND P Nipple up casiing head and orient, 06:30 12:00 Break apart tubing head and orient correctly, install tree adapter and verify correct orientation, remove adapter, bring RCD head, air valve control panel into cellar, remove dutch riser adapter from annular. 11/28/2016 11/28/2016 5.00 SURFAC WHDBOP NUND P PJSM, Continue N/U BOPE, Install 12:00 17:00 RCD adapter spool & clamp with air valve, rig up air lines, take on mud to pits, clean out suction and manifolds on nud pump 1 & 2. 11/28/2016 11/28/2016 5.50 SURFAC WHDBOP SVRG P PJSM, Perform BWM on BOPE and 17:00 22:30 1istall chke line. 11/28/2016 11/29/2016 1.50 SURFAC WHDBOP RURD P PJSM, R/U to test BOPE, flood stack 22:30 00:00 check for leaks. (State Rep Louis Grimadi waived witness of test) 11/29/2016 11/29/2016 2.75 SURFAC WHDBOP RURD T Fill stack, choke, Attempt body test. 00:00 02:45 Pull lower test plug and replace seal rubber. Install upper test plug / fluid pack. Perform body test / bleed down 11/29/2016 11/29/2016 7.00 SURFAC WHDBOP BOPE P Test BOP with 5" test joint 250/3500. 02:45 09:45 Test tubing / casing spool flange to 3500 PSI. Test annular to 2500 PSI. Test #1 3.5" X 6" top rams, valve 1, 12,13,14 and manual kill #2 upper IBOP, HRC kill, Valves 9, 11, #3 lower IBOP, Valves 5,8,10, #4.5 Dart valve, Valves 4,67 #5.5" floor valve. Valve 2 #6 HRC Choke, 4" Kill line, Demco valve, #7 Manual Choke valve. HRC Kill #8 annular preventer, #9 3.5" X 6" Lower pipe rams, #10 blind rams, valve 3, Test manual / Super choke to / 1500 PSI Drawdown. Accumulator test : System Pressure = 2,950 Pressure after closed = 1,750 200 PSI attained = 38 sec full pressure attained = 189 Secs Nitrogen bottles avg = 1,925 11/29/2016 11/29/2016 1.25 SURFAC WHDBOP BOPE P Remove test plug, RD test equipment 09:45 11:00 drain stack, B/D choke manifold, test pump. Choke, Kill line, install wear ring run in LDS. Install 5" elevators and pick up install mouse hole. 11/29/2016 11/29/2016 0.25 SURFAC CEMENT SFTY P Pre job safety meeting. 11:00 11:15 11/29/2016 11/29/2016 4.75 SURFAC CEMENT PULD P PU D/P MU stands in mouse hole rack 11:15 16:00 back in derrick. 11/29/2016 11/29/2016 1.00 SURFAC CEMENT BHAH P PJSM / Pick up Schlumberger BHA to 16:00 17:00 rig floor. 11/29/2016 11/29/2016 2.00 SURFAC CEMENT BHAH P PJSM PU / MU BHA 916' MD 17:00 19:00 11/29/2016 11/29/2016 1.25 SURFAC i CEMENT i PULD P Single while RIH to 2,878' MD. 19:00 20:15 I Page 6/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 11/29/2016 11/29/2016 1.00 SURFAC CEMENT CIRC P RU test equipment for casing test, 20:15 21:15 Circulate bottoms up to vacate air. 115K up WT / 88K DWN. 80 SPM @ 480 PSI. 11/29/2016 11/29/2016 1.50 SURFAC CEMENT PRTS P Casing pressure test. 62 strokes to 21:15 22:45 gain 3,600 PSI. 30 min test passed. 5.6 BBL bleed back volume. Rig dwn test equip / prepare for milling operattions. Inspect casing being loaded into pipe shed. All joints grater than 44' at this time shorter than 46'. Will discuss handeling proceedures. All joints will have to be loaded on skate with bridge crane. 11/29/2016 11/29/2016 0.50 SURFAC CEMENT COCF P RIH to 2,878' MD to —3,065' MD while 22:45 23:15 Washing to ensure no stringers left from cement job. Perform shallow hole test. 600 GPM @ 1,300 PSI. 11/29/2016 11/30/2016 0.75 SURFAC CEMENT DRLG P Begin rotation tag float at 3,069.55' 23:15 00:00 Drill float equipment .630 GPM @ 1,300 PSI. ROT 60 RPM, TQ = 5020 FTLB, ROT WT = 104, WOB 15K. 11/30/2016 11/30/2016 3.75 SURFAC CEMENT DRLG P Continue drilling on cement plugs and 3,069.0 3,076.0 00:00 03:45 float collar from 3069 - 3076'. 300-625 GPM, 400-1280 psi, 5-20K WOB, 5-11 K torque. 11/30/2016 11/30/2016 1.00 SURFAC CEMENT DRLG P Drill Cement from 3076 - 3140'. 600 3,076.0 3,140.0 03:45 04:45 GPM, 1340 psi, 5-11 K WOB, 60 RPM, 3-6K TQ. 11/30/2016 11/30/2016 1.50 SURFAC CEMENT CIRC T P/U off bottom and condition mud duer 3,140.0 3,140.0 04:45 06:15 to heavy mud colaboration. 11/30/2016 11/30/2016 1.75 SURFAC CEMENT DRLG P Continue drilling through cement and 3,140.0 3,180.0 06:15 08:00 shoe from 3140' to 3150'. 600 GPM, 1100 psi,80 RPM, 5-11 K TQ, 2-5K WOB. Drill additional 20 ft of open hole. 11/30/2016 11/30/2016 1.00 SURFAC CEMENT CIRC P Condition mud for LOT/FIT test. P/U 3,180.0 3,100.0 08:00 09:00 into cased hole for test. 11/30/2016 11/30/2016 1.50 SURFAC CEMENT FIT P FIT test 900 psi with 9.6# mud in/out. 3,100.0 3,100.0 09:00 10:30 Good test = 16 PPG equivelant MW. 11/30/2016 11/30/2016 0.75 INTRM1 DRILL CIRC P TI to bottom, Circulate hole over to 3,100.0 3,180.0 10:30 11:15 9.5# LSRV mud. Page 7/40 ReportPrinted: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 11/30/2016 11/30/2016 6.75 INTRM1 DRILL DDRL P Begin Drilling ahead - control drill first 3,180.0 3,714.0 11:15 18:00 3 stands. // Drilled to 3714' MD / 2,908' TVD. Up WT = 114K Dwn WT = 86K. ECD = 10.27PPG with base LSND @ 9.5PPG. WOP = 8-11 K, RPM 900 with 7-13K FT LB torque. 900 GPM pump rate at 1,750 PSI. Maximum gas units witnessed = — 455. ROP — 120 - 150' FPH Slow pump rates; #1 30 SPM = 100 PSI 40 SPM = 120 PSI #2 30 SPM = 100 PSI 40 SPM = 120 PSI Have changed screens several times to optimize. Inclination average — 70deg. all is well. 11/30/2016 12/1/2016 6.00 INTRM1 DRILL DDRL P Drilled to 4,183' MD / 3.063' TVD. Up 3,714.0 4,183.0 18:00 00:00 WT = 118K Dwn WT = 88K. ECD = 10.35PPG with base LSND @ 9.5PPG. WOB = 8-12K, RPM 900 with 5-1 OK FT LB torque. 900 GPM pump rate at 2,020 PSI. Maximum gas units witnessed = 253. ROP — 120 - 150' FPH Slow pump rates; #1 30 SPM = 120 PSI 40 SPM = 150 PSI #2 30 SPM = 120 PSI 40 SPM = 150 PSI Pills and sweeps are proving great cleaning action. Inclination average — 70deg. all is well. 12/1/2016 12/1/2016 6.00 INTRM1 DRILL DDRL P Continue drilling from 4183' to 4836'. 4,183.0 4,836.0 00:00 06:00 P/U weight 123K, SO WT 90K, ROT WT 98 K, TQ on 10-13K, TQ off 5-8K, ECD 10.43, WOB 10-15K, RPM 110, SPM 214 @ 2250 psi, ROP 150 fph. 12/1/2016 12/1/2016 6.00 INTRM1 DRILL DDRL P Conitnue drilling from 4183' to 5350'. 4,836.0 5,350.0 06:00 12:00 P/U Weight 133, S/O weight 88, ROT WT 101, TQ on 10-13 K, TQ off 6-7K, ECD 10.55, WOB 10-15K, RPM 110, GPM 900/SPM 214 @ 2650 psi, ROP 150 fph. Bit hours = 18.70 hrs / Jar hours = 119.15 Max gas= 113 SPR @ 5209' MP#1 30 = 160 psi / 40 = 200 psi MP# 2 30 = 160 psi / 40 = 210 psi. Page 8/40 Report Printed: 1/17/2017 x Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/1/2016 12/1/2016 6.00 INTRM1 DRILL DDRL P Drilled to 5,848' MD / 3,595' TVD. Up 5,350.0 5,848.0 12:00 18:00 WT = 124K Dwn WT = 95K. ECD = 10.73PPG with base LSND @ 9.7PPG. WOB = 8-12K, RPM 900 with 5-1 OK FT LB torque. 900 GPM pump rate at 2,750 PSI. Maximum gas units witnessed = 345. ROP — 110 - 125' FPH Slow pump rates; #1 30 SPM = 170 PSI 40 SPM = 220 PSI #2 30 SPM = 180 PSI 40 SPM = 220 PSI Pills and sweeps are proving great cleaning action. Inclination average — 70deg. 12/1/2016 12/2/2016 6.00 INTRM1 DRILL DDRL P Drilled to 6,390' MD / 3,779' TVD. Up 5,848.0 6,390.0 18:00 00:00 WT = 142 K Dwn WT = 100K. ECD = 10.54PPG with base LSND @ 9.7 + PPG. WOB = 7-12 K, RPM 130 with 6- 15 K FT LB torque. 900 GPM pump rate at 2,950 PSI. Maximum gas units witnessed = — 45. ROP — 125 ' FPH Slow pump rates; #1 30 SPM = 170 PSI 40 SPM = 220 PSI #2 30 SPM = 180 PSI 40 SPM = 220 PSI Pump HI -Vis sweeps every 300'70% increase in cuttings. 12/2/2016 12/2/2016 6.50 INTRM1 DRILL DDRL P Drilling ahead 6,390.0 7,030.0 00:00 06:30 12/2/2016 12/2/2016 1.50 INTRM1 DRILL RGRP T Had to stop drilling ahead due to max 7,030.0 7,000.0 06:30 08:00 power amperage use and unsuccessful load sharing cap with Gen/Hi-line. Inverter fan for Top drive VFD down due to failed bearings. Overheating the TD, which is drawing more amperage than normal. SLowly circulated off bottom while troublehsooting., 12/2/2016 12/2/2016 2.00 INTRM1 DRILL CIRC T Ciruclate a B/U. 7,000.0 7,030.0 08:00 10:00 Take final survey @ 7030' OWFF for 15 mins. 12/2/2016 12/2/2016 4.50 INTRM1 DRILL TRIP T PJSM - TOOH on elevators 7,000.0 7,020.0 10:00 14:30 12/2/2016 12/2/2016 2.00 INTRM1 DRILL SLPC P Sit up inside the shoe and perform 7,020.0 7,020.0 14:30 16:30 repairs to the VFD cooling fan, attempt to sync/load share the gens with HI - line and Slip and cut dril line at the same time. Slow Circ rate of 2 bpm when possible. 12/2/2016 12/2/2016 4.50 INTRM1 DRILL RGRP T Perform repairs to the VFD cooling 7,020.0 7,020.0 16:30 21:00 fan, attempt to sync/load share the gens with HI -line Page 9/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) w 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/2/2016 12/3/2016 3.00 INTRM1 DRILL TRIP T Surface tested all equipment with 7,020.0 7,020.0 21:00 00:00 passing grade. RIH to bottom to circulate and condition mud. 12/3/2016 12/3/2016 6.50 INTRM1 DRILL CIRC T Condition mud once back on bottom. 7,020.0 7,020.0 00:00 06:30 Heavy MW 10.3# and higher rheology propeties. Continue to circ mud around and condition. 12/3/2016 12/3/2016 6.50 INTRM1 DRILL DDRL P Start drilling ahead; 7,020.0 7,633.0 06:30 13:00 From 6,390' MD / 3,779' TVD to 7,633 MD / 4,175' TVD. Up WT = 150 K Dwn WT = 94K. ECD = 10.43PPG with base LSND @ 9.7 + PPG. WOB = 10-13 K, RPM 130 with 12-16 K FT LB torque. 900 GPM pump rate at 3,340 PSI. Maximum gas units witnessed = — 85. ROP — 115 ' FPH Slow pump rates; #1 30 SPM = 180 PSI 40 SPM = 220 PSI #2 30 SPM = 190 PSI 40 SPM = 240 PSI Pump HI -Vis sweeps every 300'70% increase in cuttings during pill return. 12/3/2016 12/4/2016 11.00 INTRM1 DRILL DDRL P Drill from 7,633' MD / 4,175" TVD to 7,633.0 8,530.0 13:00 00:00 8,530' MD / 4,467' TVD. Up WT = 155 K Dwn WT = 101K. ECD = 10.88PPG with base LSND @ 10 PPG in/out . WOB = 10-13 K, RPM 130 with 12-16 K FT LB torque. 860 GPM pump rate at 3,600 PSI. Maximum gas units witnessed = — 161. ROP — 130'FPH Slow pump rates; #1 30 SPM = 240 PSI 40 SPM = 280 PSI #2 30 SPM = 230 PSI 40 SPM = 300 PSI Pump HI -Vis sweeps every 300' Started to pump pills every second stand to prep for mud WT increase prior to C-37 ---- 70% increase in cuttings during pill return. 12/4/2016 12/4/2016 6.00 INTRM1 DRILL DDRL P Drlg from 8510' MD to 9034' MD, TVD 8,530.0 9,034.0 00:00 06:00 = 4630', ADT = 5.16, Bit Hrs = 52.08, Total Jar Hrs = 152.53. P/U WT = 160K, S/O WT = 100K, ROT. WT = 116K, TQ ON = 13-19K, TQ OFF = 8- 20K, ECD = 11.3. Flow out = 48%, WOB = 10-12K, RPM = 130, GPM = 834, SPM = 197, PSI = 3700, MAX GAS = 179 12/4/2016 12/4/2016 0.50 INTRM1 DRILL SRVY P Shoot survey, pump out from 9034' 9,034.0 9,034.0 06:00 06:30 MD to 8940' MD. Blow down top drive and monitor well (static). 12/4/2016 12/4/2016 0.25 INTRM1 DRILL REAM P Wash and ream from 8940' MD to 9,034.0 9,034.0 06:30 06:45 9034' MD at 670 GPM, 2700 psi, 43% flow, 60 RPM, TQ = 10-15K Page 10/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftK6) 12/4/2016 12/4/2016 3.00 INTRMI DRILL BKRM T BROOH from 9034' MD to 7730' at 9,034.0 7,730.0 06:45 09:45 834 GPM, 3700 psi, 48% flow, 130 RPM, TQ = 9-12K (Pulling 1000 FPH) 12/4/2016 12/4/2016 0.75 INTRM1 DRILL BKRM T Hole unloading, shakers flowing over, 7,730.0 7,730.0 09:45 10:30 circ hole clean @ 800 GPM, 3400 psi, 47% flow, 130 RPM, TQ -10-11 K 12/4/2016 12/4/2016 1.50 INTRM1 DRILL BKRM T BROOH 500 FPH from 7730' MD to 7,730.0 7,077.0 10:30 12:00 7440' MD at 850 GPM, 3600 psi, 48% flow, 130 RPM, TQ=11-12K. Pull 1000 FPH from 7440' MD to 7077' MD. Actual displacement = 27. Calculated displacement = 19.2 12/4/2016 12/4/2016 8.50 INTRM1 DRILL BKRM T PJSM & continue to BROOH from 7,077.0 3,150.0 12:00 20:30 7077' MD at 1,000 FPH 12/4/2016 12/4/2016 1.00 INTRM1 DRILL CIRC T Circulate last 30 BBL high vis gel pill 3,150.0 3,150.0 20:30 21:30 while rotating at 60 RPM. ECD 11 PPG. 12/4/2016 12/4/2016 1.00 INTRM1 DRILL OWFF T Monitor well service top drive. Re- 3,150.0 3,150.0 21:30 22:30 adjust Kelly hose. Re -adjust Bail drive control arms. 12/4/2016 12/5/2016 1.50 INTRM1 DRILL TRIP T RBIH to bottom to continue drilling. 3,150.0 5,050.0 22:30 00:00 While RIH found leak on top of flow line in pits. Perform repair while continuing to RIH. Fill pipe at 5,050' MD. 12/5/2016 12/5/2016 2.00 INTRM1 DRILL DDRL P PJSM - RIH From 5023'to 8944' 5,050.0 8,944.0 00:00 02:00 Filling every 20 stands. 12/5/2016 12/5/2016 2.00 INTRM1 DRILL DDRL P Wash and ream from 8944' to 9034'@ 8,944.0 9,034.0 02:00 04:00 4.5 BPM. Circ and condition mud pumping 5.5 bpm @ 600 psi. 12/5/2016 12/5/2016 8.00 INTRM1 DRILL DDRL P Drilling ahead - 9,034.0 9,596.0 04:00 12:00 Drlg from 9,034' MD to 9,596' MD, TVD = 4,805', ADT = 4.79, P/U WT = 160K, S/O WT = 98K, ROT. WT = 130K, TQ ON = 12-23K, TQ OFF = 14 -20K, ECD = 10.97. Flow out = 45%, WOB = 10-12K, RPM = 160, GPM = 820, ,PSI = 3700, MAX GAS = 1494 12/5/2016 12/6/2016 12.00 INTRM1 DRILL DDRL P Drilling ahead - 9,596.0 10,042.0 12:00 00:00 Drlg from 9,596' MD to 10,042' MD, TVD = 4,952', ART = 3.82, P/U WT = 160K, S/O WT = 105K, ROT. WT = 105K, TQ ON = 10-20K, TQ OFF = 14K, ECD = 10.59. Flow out = 45%, WOB = 5-20K, RPM = 160, GPM = 832, ,PSI = 3550, MAX GAS = 246 12/6/2016 12/6/2016 6.00 INTRM1 DRILL DDRL P Drill form 10042' to 10526' (TVD = 10,042.0 10,526.0 00:00 06:00 5108'). ADT = 4.28 hrs. Bit hrs = 71.3 hrs, Total jar hrs = 171.75 hrs. P/U = 175 kips, S/O = 109 kips, Rot wt = 130 kips, Torque On = 18-21 k ft -lbs, Torque Off = 13-16 k ft -lbs, ECD = 11.01 ppg EWM. Flow out = 47%, WOB = 12-16 kips, Top drive RPM = 160 rpm, GPM = 826 gpm (195 total spm), Standpipe pressure = 3680 psi, Max gas = 196 units Page 11/40 Report Printed: 1/17/2017 Uperations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code AGhvity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/6/2016 12/6/2016 6.00 INTRMI DRILL DDRL P Drill form 10526' to 11088' (TVD = 10,526.0 11,088.0 06:00 12:00 5293'). ADT = 4.59 hrs. Bit hrs = 75.89 hrs, Total jar hrs = 176.34 hrs. P/U = 180 kips, S/O = 108 kips, Rot wt = 140 kips, Torque On = 20-21 k ft -lbs, Torque Off = 14-21 k ft -lbs, ECD = 11.70 ppg EWM. Flow out = 44%, WOB = 10-15 kips, Top drive RPM = 160 rpm, GPM = 789 gpm (186 total spm), Standpipe pressure = 3670 psi, Max gas = 864 units 12/6/2016 12/6/2016 4.00 INTRM1 DRILL DDRL P Drill form 11088' to 11360' (TVD = 11,088.0 11,360.0 12:00 16:00 5384'). ADT = 3.36 hrs. Bit hrs = 79.25 hrs, Total jar hrs = 179.7 hrs. P/U = 180 kips, S/O = 113 kips, Rot wt = 135 kips, Torque On = 20-22 k ft -lbs, Torque Off = 16 k ft -lbs, ECD = 11.06 ppg EWM. Flow out = 43%, WOB = 10-12 kips, Top drive RPM = 160 rpm, GPM = 776 gpm (184 total spm), Standpipe pressure = 3600 psi, Max gas = 799 units. At 11360' unable to get weight transferred to the bit. 12/6/2016 12/6/2016 3.25 INTRM1 DRILL BKRM T Back ream out of the hole from 11360' 11,360.0 10,343.0 16:00 19:15 to 10343' at 550-650 fph while pumping 778 gpm (184 total spm), Standpipe pressure = 3600 psi. Top drive RPM = 160 rpm, Torque = 10-20 k ft -lbs, ECD = 11.09 ppg EMW 12/6/2016 12/6/2016 1.00 INTRM1 DRILL CIRC T Continue circulating for a total of 3 10,343.0 10,343.0 19:15 20:15 bottoms up including time backreaming. ECD decreased to 10.97 ppg EMW. 12/6/2016 12/6/2016 0.50 INTRM1 DRILL TRIP T RIH from 10343'to 11277'. W/O = 10,343.0 11,277.0 20:15 20:45 104 kips 12/6/2016 12/6/2016 0.25 INTRM1 DRILL WASH T Break circulation and wash and ream 11,277.0 11,360.0 20:45 21:00 from 11277' to 11360'. Pumping at 771 gpm (182 total spm), Standpipe pressure = 3600 psi, Rot 160 kips, Torque = 15 k ft -lbs 12/6/2016 12/7/2016 3.00 INTRM1 DRILL DDRL P Drill form 11360' to 11490' (TVD = 11,360.0 11,490.0 21:00 00:00 5428'). ADT = 2.39 hrs. Bit hrs = 81.64 hrs, Total jar hrs = 182.09 hrs. P/U = 180 kips, S/O = 114 kips, Rot wt = 135 kips, Torque On = 20-24 k ft -lbs, Torque Off = 16 k ft -lbs, ECD = 10.94 ppg EWM. Flow out = 45%, WOB = 5- 14 kips, Top drive RPM = 160 rpm, GPM = 791 gpm (187 total spm), Standpipe pressure = 3650 psi, Max gas = 429 units. 12/7/2016 12/7/2016 6.00 INTRM1 DRILL DDRL P Drill form 11490' to 12040 (TVD = 11,490.0 12,040.0 00:00 06:00 5611'). ADT = 4.91 hrs. Bit hrs = 86.55 hrs, Total jar hrs = 187.00 hrs. P/U = 190 kips, S/O = 113 kips, Rot wt = 146 kips, Torque On = 21-22 k ft -lbs, Torque Off = 16-18 k ft -lbs, ECD = 11.16 ppg EWM. Flow out = 44%, WOB = 11-15 kips, Top drive RPM = 160 rpm, GPM = 767 gpm (182 total spm), Standpipe pressure = 3670 psi, Max gas = 336 units. Page 12/40 Report Printed: 1/17/2017 ski Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/7/2016 12/7/2016 4.00 INTRM1 DRILL DDRL P Drill form 12040' to 12442' (TVD = 12,040.0 12,442.0 06:00 10:00 5477'). ADT = 3.06 hrs. Bit hrs = 89.61 hrs, Total jar hrs = 1890.06 hrs. P/U = 200 kips, S/O = 112 kips, Rot wt = 150 kips, Torque On = 21-25 k ft -lbs, Torque Off = 16-24 k ft -lbs, ECD = 11.36 ppg EWM. Flow out = 44%, WOB = 6-10 kips, Top drive RPM = 160 rpm, GPM = 750 gpm (178 total spm), Standpipe pressure = 3675 psi, Max gas = 1762 units. 12/7/2016 12/7/2016 0.25 INTRM1 CASING SRVY P Obtain survey. Record slow pump 12,442.0 12,442.0 10:00 10:15 rates and parameters 10:05 hrs: Slow pump rates @ 12442', 5744' TVD, MW = 10.5 ppg Pump 30 spm 40 spm 1 300 psi 340 psi 2 350 psi 360 psi 12/7/2016 12/7/2016 1.50 INTRM1 CASING CIRC P Circulate and condition mud at 786 12,442.0 12,442.0 10:15 11:45 gpm, 2650 psi. Dilute with new 10.5 ppg mud 12/7/2016 12/7/2016 0.25 INTRM1 CASING OWFF P Monitor well for flow -STATIC 12,442.0 12,442.0 11:45 12:00 12/7/2016 12/8/2016 12.00 INTRM1 CASING BKRM P Backream out of the hole from 12442' 12,442.0 7,544.0 12:00 00:00 to 7544', Initiallly circulate at 800-850 gpm, 3500 psi, ECD = 11.32 ppg EMW, Rotate at 160 rpm, Final circulation rate = 900 gpm @ 3600 psi. Calculated displacement = 38.49 bbl Actual displacement = 80.76 bbl. Sent — 40 bbl sand and cuttings to cuttings tank. 12/8/2016 12/8/2016 8.50 INTRM1 CASING BKRM P BROOH from 7554' up past shoe @ 7,544.0 3,110.0 00:00 08:30 3147' 12/8/2016 12/8/2016 1.00 INTRM1 CASING CIRC P Pump Hi-visc sweep inside the shoe 3,110.0 3,110.0 08:30 09:30 and circulate surface to surface volume. Once shakers cleaned up stop pumping. 12/8/2016 12/8/2016 0.50 INTRM1 CASING OWFF P OWFF for 30 mins, Drop 2.5" drift from 3,110.0 3,110.0 09:30 10:00 surface. 12/8/2016 12/8/2016 3.00 INTRM1 CASING PMPO P Attempt to pull OOH on elevators, 3,110.0 1,000.0 10:00 13:00 swabbing in well and excess drag. Pump OOH to HWDP 12/8/2016 12/8/2016 1.00 INTRM1 CASING TRIP P Pull out on elevators, stand back 1,000.0 280.0 13:00 14:00 HWDP. 12/8/2016 12/8/2016 2.50 INTRM1 CASING BHAH P Lay down BHA 280.0 0.0 14:00 16:30 12/8/2016 12/8/2016 1.00 INTRM1 CASING BHAH P Clear and clean rig floor 0.0 16:30 17:30 12/8/2016 12/8/2016 2.75 INTRM1 CASING BOPE P Flush BOP stack. Pull wear bushing. 17:30 20:15 Change Upper Pipe Rams to 9-5/8" casing rams 12/8/2016 12/8/2016 1.75 INTRM1 CASING BOPE P Rig up and test Upper Pipe Rams to 20:15 22:00 250-3500 psi and Annular to 250- 2500 psi with 9-5/8" test joint. Rig down 12/8/2016 12/8/2016 0.50 INTRM1 CASING RURD P Set wear ring 22:00 22:30 Page 13/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) x 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/8/2016 12/9/2016 1.50 INTRM1 CASING PULD P Pick up 18 joints of 5" HWDP and rack 22:30 00:00 back in derrick. Drifted HWDP with 2- 5/8" drift. 12/9/2016 12/9/2016 2.00 INTRM1 CASING RURD P R/U DDI casing tools and handling 0.0 0.0 00:00 02:00 equipment. 12/9/2016 12/9/2016 1.50 INTRM1 CASING PUTB P PJSM Run 9 5/8", 40#, L-80 Hydril 0.0 250.0 02:00 03:30 563 casing with Float shoe, float collar and Landing collar. Test float equipment at surface - Good test. 12/9/2016 12/9/2016 6.25 INTRM1 CASING PUTB P P/U 9 5/8" 40#, L-80, BCT -M Casing 250.0 3,145.0 03:30 09:45 as per running liner order. Install free floating hydroform centralizers up to cement top of 10,200' Total of 55 Centralizers ran including the shoe track assembly. 12/9/2016 12/9/2016 1.50 INTRM1 CASING CIRC P Circulate and condition mud/clean 3,145.0 3,145.0 09:45 11:15 cased hole prior to running into OH. 7 bpm @ 250 psi P/U weight 130K, Down 105K. Pumped 2X B/U, shakers and mud cleaned up. 12/9/2016 12/9/2016 7.75 INTRM1 CASING PUTB P Continue P/U casing from 3145' to 3,145.0 7,590.0 11:15 19:00 7590'. TIH using volant tool filling every 10 joints. 12/9/2016 12/9/2016 2.00 INTRM1 CASING CIRC P Circulate bottoms up at 5 bpm, 350 7,590.0 7,590.0 19:00 21:00 psi. P/U = 208 kips, S/0 = 130 kips. 12/9/2016 12/10/2016 3.00 INTRM1 CASING PUTB P Continue P/U casing from 7590'to 7,590.0 9,376.0 21:00 00:00 9376'. TIH using volant tool filling every 10 joints. 12/10/2016 12/10/2016 2.00 INTRMI CASING PUTB P RIH from 9370' to 10,384' 9,376.0 10,384.0 00:00 02:00 12/10/2016 12/10/2016 1.50 INTRM1 CASING OTHR P R/D casing equipment and Volant 10,384.0 10,384.0 02:00 03:30 Tool. M/U Baker liner hanger and liner top packer and mix/fill with Pal Mix. 12/10/2016 12/10/2016 3.00 INTRM1 CASING RUNL P P/U and RIH with HWDP & DP. Stop 1 10,384.0 12,442.0 03:30 06:30 stand above TD and break circulation pumping 2 bpm @ 480 psi. Tag Bottom @ 12,442' P/U weight 325 K, Down weight 135K. P/U 1Oft mark pipe and record depths/weights. 12/10/2016 12/10/2016 4.00 INTRM1 CEMENTCIRC P Circulate and condition mud while 12,442.0 12,442.0 06:30 10:30 cycling pipe off bottom. IRURD Mud coming back 9.8# heavy Yield point 32. 12/10/2016 12/10/2016 1.00 INTRM1 CEMENT P Lay down single joint and P/U 1Oft and 12,442.0 12,442.0 10:30 11:30 5ft pup with Baker Plug launching head. 12/10/2016 12/10/2016 1.50 INTRM1 CEMENT CIRC P Tag Bottom again - P/U 10 ft to setting 12,432.0 12,432.0 11:30 13:00 depth P/U weight 325K. Circulate aditional B/U - Mud weight 10.5# heavy / YP 24. Total circulation 1720 bbls - surface to surface volume is 1620 bbls Held PJSM fopr cement job with all parties involved. Page 14/40 ReportPrinted: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/10/2016 12/10/2016 4.25 INTRM1 CEMENT CMNT P Pressure test SLB lines to 4500 psi. 12,432.0 12,442.0 13:00 17:15 Perform Cement job: 5 bbls FW 40 bbls CW 100 60 bbls MP II 12.5# Drop lower Plug - indicator pin opened. Pressure increase on latch 340 psi @ 25.2 bbls away. 170 bbls Class G 15.8# cement Drop UPR dart - indicator pin opened - Pressure up on Latch 1430 psi 25.3 bbls away. 10 bbls FW with SLB Swapped to Rig pump @ 7 bpm/500 psi. Plug did not bump - total strokes 9399 stks. Open up bleeders - floats holding 12/10/2016 12/10/2016 0.50 INTRM1 CEMENT PACK P Set liner on bottom at 12442' and set 12,442.0 2,018.0 17:15 17:45 liner top packer with 75 kips. Top of liner at 2018' Released liner running tool. CIP @ 17:15 hours. 12/10/2016 12/10/2016 0.50 INTRM1 CEMENT RURD P Rig down cementing head and blow 2.,018.0 2,018.0 17:45 18:15 down lines and top drive 12/10/2016 12/10/2016 0.50 INTRM1 CEMENT PRTS P Pressure test liner top packer to 1000 2,018.0 2,018.0 18:15 18:45 psi for 10 minutes. Recorded test on chart recorder. 12/10/2016 12/10/2016 1.75 INTRM1 CEMENT TRIP P POOH with liner running string. Lay 2,018.0 0.0 18:45 20:30 down 18 joints of 5" HWDP and liner setting tool 12/10/2016 12/10/2016 1.00 INTRM1 CEMENT OTHR P Flush BOP stack with fresh water 0.0 0.0 20:30 21:30 12/10/2016 12/10/2016 0.50 INTRM1 CEMENT WWWH P Pull wear ring 0.0 0.0 21:30 22:00 12/10/2016 12/10/2016 1.50 INTRM1 CEMENT RURD P Change upper pipe rams back to 3- 0.0 0.0 22:00 23:30 1/2" x 6" VBR's and rig up to test BOPE 12/10/2016 12/11/2016 0.50 INTRM1 WHDBOP RURD P Set test plug 0.0 23:30 00:00 12/11/2016 12/11/2016 4.50 INTRM1 WHDBOP BOPE P Test BOPE 250/3500 psi both 4" & 5" 0.0 0.0 00:00 04:30 Test joint. - Witness waived by Jeff Jones 1) UPR VBR, CV 1, 12,13,14 & Manual Kill. 2) UPR IBOP, HCR Kill, CV 9 & 11 3) LWR IBOP, CV 5,8 & 10. 4) Floor valve, CV 4,6 & 7 5) Dart Valve, CV 2 & 6, HCR choke 6) HCR choke, 4" Kill Line, Demco Valve 7) Manual choke valve, HCR kill, CV #8 8) Annular preventer 250/2500 psi 9)LWR pipe rams 10) Blind rams CV #3. Kummi test 3000 psi, 1900 after close, 52 secs/250 psi, 181 secs full pressure. 12/11/2016 12/11/2016 0.50 INTRM1 WHDBOP RURD P RD test equipment, blow down lines & 0.0 0.0 04:30 05:00 TD 12/11/2016 12/11/2016 2.00 INTRM1 CEMENT SLPC P SLip and cut drilline, service TD and 0.0 0.0 05:00 07:00 drawowrks. Page 15/40 Report Printed: 1/17/2017 ;= Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/11/2016 12/11/2016 10.00 INTRM1 CEMENT RURD P R/U MPD equipment. - load, strap and 0.0 0.0 07:00 17:00 tally 7" casing in the pipe shed. 12/11/2016 12/11/2016 1.00 INTRM1 WHDBOP RURD P Pull test head and install trip nipple. 0.0 0.0 17:00 18:00 Pull test plug and install wear ring 12/11/2016 12/11/2016 0.50 INTRM1 CEMENT PULD P Lay down 4 stands of 5" HWDP from 0.0 0.0 18:00 18:30 derrick 12/11/2016 12/11/2016 1.00 INTRM1 CEMENT BHAH P Mobilize BHA components to the rig 0.0 0.0 18:30 19:30 floor. Sim -ops: pressure test choke #2 on MPD skid. 12/11/2016 12/11/2016 2.00 INTRM1 CEMENT BHAH P Make up BHA #4 and RIH to 499' 0.0 499.0 19:30 21:30 12/11/2016 12/11/2016 0.50 INTRM1 CEMENT TRIP P Trip in with BHA #4 from 499'to 1526' 499.0 1,526.0 21:30 22:00 12/11/2016 12/11/2016 0.25 INTRM1 CEMENT DHEQ P Shallow test MWD equipment @ 600 1,526.0 1,526.0 22:00 22:15 gpm-1500 psi. Blow down top drive 12/11/2016 12/12/2016 1.75 INTRM1 CEMENT TRIP P Continue RIH with BHA #4 from 1526' 1,526.0 4,699.0 22:15 00:00 to 4699'. P/U = 100 kips, S/O = 85 kips 12/12/2016 12/12/2016 3.50 INTRM1 CEMENT TRIP P RIH from 4699' to 12,253' filling evry 4,699.0 12,253.0 00:00 03:30 20 Stands. P/U weight 215K / Dn 60K 12/12/2016 12/12/2016 2.50 INTRM1 CEMENT MPDA P R/U MPD & install MPD bearing. 12,253.0 12,253.0 03:30 06:00 Calibrate chokes. 600 gpm, 3150 psi. 12/12/2016 12/12/2016 1.50 INTRM1 CEMENT PRTS P Perform casing test 3500 psi / 30 mins 12,253.0 12,253.0 06:00 07:30 charted. Good test. 12/12/2016 12/12/2016 1.50 INTRM1 CEMENT RURD P Flush all lines & Pull RCD bearing 12,253.0 12,253.0 07:30 09:00 12/12/2016 12/12/2016 7.50 INTRM1 CEMENT CIRC T Circ and condition mud - High torque 12,253.0 12,253.0 09:00 16:30 values. 27K at 50 rpm. Continue to condition mud, add Io torque and lube 776. No improvement. 12/12/2016 12/12/2016 2.00 INTRM1 CEMENT CIRC T Displace well to new LSND 12,253.0 12,253.0 16:30 18:30 12/12/2016 12/12/2016 0.10 INTRMI CEMENT COCF Wash from 2253 to 12256 12,253.0 12,256.0 18:30 18:36 12/12/2016 12/13/2016 5.40 INTRM1 CEMENT DRLG P Wash down and tag cement at 12256'. 12,256.0 12,285.0 18:36 00:00 Drill cement and plugs to 12285' pushing plug debris downhole. 12/13/2016 12/13/2016 4.00 INTRM1 CEMENT DRLG P Drill plugs from 12285' to 12291'. 12,285.0 12,291.0 00:00 04:00 Unable to get deeper 12/13/2016 12/13/2016 0.50 INTRM1 CEMENT OWFF T Monitor well -static. Obtain slow pump 12,291.0 12,291.0 04:00 04:30 rates. Blow down top drive. Slow pump rates as follows: Depth = 12248' TVD = 5684' MW = 10.5 ppg Time = 4:08 hrs Pump #1 #2 30 SPM 300 psi 300 psi 40 SPm 360 psi 340 psi 12/13/2016 12/13/2016 4.75 INTRM1 CEMENT TRIP T POOH on elevators from 12291'to 12,291.0 499.0 04:30 09:15 499' 12/13/2016 12/13/2016 2.50 INTRMI CEMENT BHAH T Rack back 3 stands of HWDP and two 499.0 0.0 09:15 11:45 stands of NMDC's. Lay down underreamer. Unload Nuclear sources from LWD tools Page 16/40 ReportPrinted: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/13/2016 12/13/2016 0.25 INTRM1 CEMENT BHAH T Clear rig floor 0.0 0.0 11:45 12:00 12/13/2016 12/13/2016 1.25 INTRM1 CEMENT BHAH T Make up mill tooth bit BHA (BHA #5) 0.0 394.0 12:00 13:15 12/13/2016 12/13/2016 3.50 INTRMI CEMENT TRIP T Trip in the hole from 394'to 11219' 394.0 11,219.0 13:15 16:45 12/13/2016 12/14/2016 7.25 INTRM1 CEMENT DRLG T Wash from 11219' to 12291'. Clean 11,219.0 12,329.0 16:45 00:00 out plugs and cement from 12291' to 12329'. WOB = 5-35 kips, Flowrate = 850-2000 psi, Rotation of top drive = 40 - 100 rpm, Torque on bottom = 13- 22 k-ft-lbs 12/14/2016 12/14/2016 6.00 INTRM1 CEMENT DRLG T Contrinue to Drill out plugs and 12,329.0 12,365.0 00:00 06:00 cement from 12329' to 12365'. WOB = 5-35 kips, Flowrate = 850-2000 psi, Rotation of top drive = 40 - 100 rpm, Torque on bottom = 13-22 k-ft-lbs Finally drilled through and increased ROP. 12/14/2016 12/14/2016 0.50 INTRM1 CEMENT DDRL P Drill f rom 12365' to 12462' TVD = 12,365.0 12,462.0 06:00 06:30 5755'. ADT = .86 hr, Bit hrs = .86 hrs, Jar hrs = 152.2 hrs, P/U = 190 kips, S/O = 102 kips, ROT = 136 kips, WOB = 5-7 kips, Torque On = 22 k-ft-lbs, Torque off = 18 k-ft-lbs, Rotarty = 80 rpm, Flowrate = 465 gpm SPP = 1450 psi, Max gas = 0 units 12/14/2016 12/14/2016 1.00 INTRM1 CEMENT CIRC P Circulate and condition mud @ 740 12,462.0 12,462.0 06:30 07:30 gpm, 2800 psi 12/14/2016 12/14/2016 0.50 INTRM1 CEMENT RURD P Pull back to 12426' and rig up to 12,462.0 12,426.0 07:30 08:00 perform FIT test 12/14/2016 12/14/2016 0.50 INTRM1 CEMENT FIT P Perform FIT to 16.0 ppg EMW. 12,426.0 12,426.0 08:00 08:30 Pumped 8 bbl and bled back 5 bbl. max pressure = 1650 psi with 10.5 ppg mud in the well. TVD of shoe @ 5745' 12/14/2016 12/14/2016 0.25 INTRM2 DRILL RURD P Rig down test equipment and blow 12,426.0 12,426.0 08:30 08:45 down top drive 12/14/2016 12/14/2016 0.75 INTRM2 DRILL MPDA T Pull trip nipple and install RCD bearing 12,426.0 12,426.0 08:45 09:30 per MPD representative 12/14/2016 12/14/2016 0.25 INTRM2 DRILL CIRC P Circulate through MPD unit holding 12,426.0 12,426.0 09:30 09:45 150 psi on wellbore 12/14/2016 12/14/2016 6.25 INTRM2 DRILL SMPD P POOH from 12426' to 1000' all the 12,426.0 1,000.0 09:45 16:00 while holding 150 psi back pressure via the MPD system. 12/14/2016 12/14/2016 0.25 INTRM2 DRILL OWFF P Observe well for flow--static 1,000.0 1,000.0 16:00 16:15 12/14/2016 12/14/2016 0.75 INTRM2 DRILL MPDA P Pull MPD bearing and re-install trip 1,000.0 1,000.0 16:15 17:00 nipple 12/14/2016 12/14/2016 0.50 INTRM2 DRILL TRIP P POOH from 1000' to 500' 1,000.0 500.0 17:00 17:30 12/14/2016 12/14/2016 1.00 INTRM2 DRILL BHAH P Stand back HWDP, jars and NMDC's. 500.0 0.0 17:30 18:30 Lay down BHA #5. 12/14/2016 12/14/2016 0.75 INTRM2 DRILL BHAH P Clear and clean the rig floor 0.0 0.0 18:30 19:15 12/14/2016 12/14/2016 1.50 INTRM2 DRILL BHAH P Make up BHA #6 and install 0.0 500.0 19:15 20:45 radioactive sources. Page 17/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) t4'^af W _ � 1 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/14/2016 12/14/2016 0.50 INTRM2 DRILL TRIP P Trip into 2360'. Fill drillpipe and verify 500.0 2,360.0 20:45 21:15 that the MWD/LWD is functioning properly 12/14/2016 12/15/2016 2.75 INTRM2 DRILL TRIP P Continue RIH with BHA #6 from 2360' 2,360.0 11,696.0 21:15 00:00 to 11695.53' 12/15/2016 12/15/2016 0.50 INTRM2 DRILL TRIP P Trip in the hole from 11695' to 12441' 11,696.0 12,441.0 00:00 00:30 P/U = 200 kips, S/O = 73 kips, 12/15/2016 12/15/2016 1.00 INTRM2 DRILL SLPC P Cut and slip 65' of drilling line 12,441.0 12,441.0 00:30 01:30 12/15/2016 12/15/2016 0.50 INTRM2 DRILL SVRG P Service rig and top drive 12,441.0 12,441.0 01:30 02:00 12/15/2016 12/15/2016 0.50 INTRM2 DRILL MPDA P Pull trip nipple and install RCD bearing 12,441.0 12,441.0 02:00 02:30 12/15/2016 12/15/2016 0.50 INTRM2 DRILL MPDA P Break in RCD bearing. Obtain slow 12,441.0 12,441.0 02:30 03:00 pump rates: @ 12441' MD 5755' TVD Mud weight = 10.5 ppg Pump # 30 spm 40 spm 1 320 psi 420 psi 2 320 psi 400 psi 12/15/2016 12/15/2016 1.00 INTRM2 DRILL DDRL P Drill from 12441' to 12513' TVD = 12,441.0 12,513.0 03:00 04:00 5772'. ADT = .65 hr, Bit hrs = .65 hrs, Jar hrs = 152.87 hrs, P/U = 200 kips, S/O = 73 kips, ROT = 121 kips, WOB = 6 kips, Torque On = 16-18 k -ft -lbs, Torque off = 14-16 k -ft -lbs, Rotary = 90 rpm, Flowrate = 526 gpm SPP = 3110 psi, Max gas =258 units 12/15/2016 12/15/2016 5.25 INTRM2 DRILL RGRP T Lost power to top drive and #1 mud 12,513.0 12,513.0 04:00 09:15 pump. Breaker for SCR #1 would not reset. Electician trouble shot and resolved the issue while circulating with one mud pump @ 270 gpm, 1110 psi. 12/15/2016 12/15/2016 1.75 INTRM2 DRILL DDRL P Drill from 12513' to 12565' TVD = 12,513.0 12,565.0 09:15 11:00 5791'. ADT = 1.42 hr, Bit hrs = 1.42 hrs, Jar hrs = 153.64 hrs, P/U = 200 kips, S/O = 73 kips, ROT = 121 kips, WOB = 20-25 kips, Torque On = 16- 18 k -ft -lbs, Torque off = 15 k -ft -lbs, Rotary = 50 rpm, Flowrate = 600 gpm SPP = 2500 psi, Max gas =258 units. ECD = 11.98 ppg EMW 12/15/2016 12/15/2016 1.00 INTRM2 DRILL DHEQ P Open Underrreamer. Drop RFID 12,565.0 12,565.0 11:00 12:00 chips and pump down at 600 gpm. Slow pumps to 250 gpm. Rotate at 40 rpm. Observed pressure drop indicating cutters opened. Attempted to rotate but topdrive stalled at 25 k-ft- Ibs of torque. Decision made to close cutters and recycle the tool. Page 18/40 Report Printed: 1/17/2017 ' Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/15/2016 12/15/2016 2.50 INTRM2 DRILL DDRL P Close underreamer. Drill from 12565' 12,565.0 12,575.0 12:00 14:30 to 12575' TVD = 5870'. ADT = .13 hr, Bit hrs = 1.55 hrs, Jar hrs = 1537.44 hrs, P/U = 185 kips, S/O = 95 kips, ROT = 126 kips, WOB = 18-25 kips, Torque On = 15-20 k -ft -lbs, Torque off = 15 k -ft -lbs, Rotary = 80 rpm, Flowrate = 600 gpm SPP = 2500 psi, Max gas =258 units. ECD = 11.98 ppg EMW Pick up to 12570' and open underreamer. Work underreamer from 12570' to 12575' Pick up and over pull = 15 kips on underreamer at 12565'. 12/15/2016 12/15/2016 3.50 INTRM2 DRILL DDRL P Drill from 12575' to 12809' TVD = 12,575.0 12,809.0 14:30 18:00 5870'. ADT = 3.67 hr, Bit hrs = 5.22 hrs, Jar hrs = 157.44 hrs, P/U = 185 kips, S/O = 85 kips, ROT = 125 kips, WOB = 15-22 kips, Torque On = 23 k - ft -lbs, Torque off = 21 k -ft -lbs, Rotary = 140 rpm, Flowrate = 720 gpm Total strokes = 200 spm, SPP = 3200 psi, Max gas =207 units. ECD = 12.67 ppg EMW 12/15/2016 12/16/2016 6.00 INTRM2 DRILL DDRL P Drill from 12809' to 13300' TVD = 12,809.0 13,300.0 18:00 00:00 6001'. ADT = 3.42 hr, Bit hrs = 8.64 hrs, Jar hrs = 160.88 hrs, P/U = 185 kips, S/O = 80 kips, ROT = 125 kips, WOB = 20-30 kips, Torque On = 22 k - ft -lbs, Torque off = 20 k -ft -lbs, Rotary = 140 rpm, Flowrate = 737 gpm Total strokes = 206 spm, SPP = 3400 psi, Max gas =525 units. ECD = 12.82 ppg EMW 12/16/2016 12/16/2016 5.25 INTRM2 DRILL DDRL P Drill from 13,300 -ft / TVD = 6001 -ft to 13,300.0 13,749.0 00:00 05:15 13,749 -ft MD / ADT = 4.19 hr, Bit hrs = 12.83 hrs, Jar hrs = 165.05 hrs, P/U = 193 kips, S/O = 82 kips, ROT = 127 kips, WOB = 17-20 kips, Torque On = 24-25 k -ft -lbs, Torque off = 15 k -ft -lbs, Rotary = 140 rpm, Flow Rate = 730 gpm Total strokes = 203 spm, SPP = 3325 psi, Max gas =775 units. ECD = 12.48 ppg EMW 12/16/2016 0.75 INTRM2 DRILL PULD P Pull out @ drlg rate f/ 13,749 -ft MD U 13,749.0 13,749.0 05:15 112116/2016 06:00 1 13,562 -ft MD. RIH w/ 6 jts. 5" DP out of the pipeshed to 13,749 -ft. Page 19/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) "F 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/16/2016 12/16/2016 3.75 INTRM2 DRILL DDRL P Drill from 13,749 -ft to 13897' TVD = 13,749.0 13,897.0 06:00 09:45 6054' ADT = 3.20 hr, Bit hrs = 16.03 hrs, Jar hrs = 168.25 hrs, P/U = 195 kips, S/O = 80 kips, ROT = 123 kips, WOB = 4-5 kips, Torque On = 25 k-ft- Ibs, Torque off = 15 k -ft -lbs, Rotary = 140 rpm, Flow Rate = 742 gpm Total strokes = 206 spm, SPP = 3380 psi, Max gas =1275 units. ECD = 12.75 ppg EMW Slow pump rates taken at 08:06 Depth = 13841' MD, 6052' TVD Mud weight = 10.5 ppg Pump 30 spm 40 spm #1 435 psi 565 psi #2 515 psi 555 psi 12/16/2016 12/16/2016 2.00 INTRM2 CASING CIRC P Circulate and drop RFID tags. Pump 13,897.0 13,897.0 09:45 11:45 at 732 gpm for 2600 strokes. Reduce rate to 250 gpm for 1200 strokes. Verified underreamer closed when pressure increased by 200 psi. Continue to circulate bottoms up 12/16/2016 12/16/2016 0.25 INTRM2 CASING OWFF P Perform draw down test; Bled off 450 13,897.0 13,897.0 11:45 12:00 psi and pressure built up 250 psi and stabilized. Took a 2.38 bbl gain to trip tank. 12/16/2016 12/16/2016 4.00 INTRM2 CASING CIRC P Circulate and condition mud at 650 13,897.0 13,897.0 12:00 16:00 gpm, 3150 psi while rotating at 140 rpm. Rotational torque (off bottom) _ 20 k -ft -lbs 12/16/2016 12/17/2016 8.00 INTRM2 CASING CIRC P Circulate and increase mud weight 13,897.0 13,897.0 16:00 00:00 from 10.5 ppg to 11.8 ppg (desired mud weight = 12.0 ppg). Circulating at 650 gpm @ 3150 psi 12/17/2016 12/17/2016 2.75 INTRM2 CASING CIRC P Continue circulate and increase mud 13,897.0 13,839.0 00:00 02:45 weight from 11.8 ppg to 12.0 ppg. While reciprocating and rotating F/ 13,893 -ft MD T/ 13, 839 -ft MD Circulating at 450 gpm, 2,022 psi, 75 rpm, 16K TQ, 46% F/O, MW= 12.0 ppg In/Out, Obtain SPR's 12/17/2016 12/17/2016 0.50 INTRM2 CASING OWFF P Monitor well for 30 minutes -- STATIC 13,839.0 13,839.0 02:45 03:15 12/17/2016 12/17/2016 2.25 INTRM2 CASING SMPD P Blow down and line up Mud Pump #1. 13,839.0 12,432.0 03:15 05:30 Strip out of the hole from 13839' to 12432' holding 80 psi on RCD. 12/17/2016 12/17/2016 1.75 INTRM2 CASING CIRC P Circulate bottoms up @ 450 gpm, 12,432.0 12,432.0 05:30 07:15 1527 psi, 140 rpm, Monitor well -- STATIC 12/17/2016 12/17/2016 7.25 INTRM2 CASING SMPD P Drop 2.51" hollow rabitt and continue 12,432.0 2,026.0 07:15 14:30 stripping out of the hole from 12432' to 2026' following tripping schedule to determine back pressure 12/17/2016 12/17/2016 0.75 INTRM2 CASING CIRC P Circulate bottoms up at 450 gpm, 2,026.0 2,026.0 14:30 15:15 Blow down top drive 12/17/2016 12/17/2016 0.50 INTRM2 CASING SMPD P Continue to strip out of the hole from 2,026.0 1,000.0 15:15 15:45 2026 to 1000' 12/17/2016 12/17/2016 0.25 INTRM2 CASING OWFF P Monitor well --Static. 1,000.0 1,000.0 15:45 16:00 I Page 20/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) ,r. 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/17/2016 12/17/2016 1.00 INTRM2 CASING MPDA P Pull MPD bearing and install trip 1,000.0 1,000.0 16:00 17:00 nipple 12/17/2016 12/17/2016 0.50 INTRM2 CASING SVRG P Service rig and top drive 1,000.0 1,000.0 17:00 17:30 12/17/2016 12/17/2016 0.50 INTRM2 CASING TRIP P POOH from 1 000'to 530'. Monitor well 1,000.0 530.0 17:30 18:00 --STATIC 12/17/2016 12/17/2016 2.00 INTRM2 CASING BHAH P Lay down BHA 530.0 0.0 18:00 20:00 12/17/2016 12/17/2016 1.75 INTRM2 CASING WWWH P Rig up and flush BOP Stack 0.0 0.0 20:00 21:45 12/17/2016 12/17/2016 0.25 INTRM2 CASING BOPE P Pull wear ring and install test plug 0.0 0.0 21:45 22:00 12/17/2016 12/17/2016 1.00 INTRM2 CASING BOPE P Change upper pipe rams to 7" casing 0.0 0.0 22:00 23:00 rams 12/17/2016 12/18/2016 1.00 INTRM2 CASING BOPE P Rig up 7" test joint and pressure test 0.0 0.0 23:00 00:00 upper pipe rams to 250 psi low/ 3500 psi high. Test annular to 250 psi low and 2500 psi high. Rig down test equipment. Pull test plug 12/18/2016 12/18/2016 0.50 INTRM2 CASING RURD P Install 12.25" wear ringand Run in 2 0.0 0.0 00:00 00:30 lock downs. RD running tool 12/18/2016 12/18/2016 2.00 INTRM2 CASING RURD P RU Doyon casing equipment to Run 0.0 0.0 00:30 02:30 1,650-ft of 7" 26#, L-80 Hydril 563 casing. 12/18/2016 12/18/2016 0.50 INTRM2 CASING SFTY P PJSM with all on PU and RIH w/ 7" 0.0 0.0 02:30 03:00 Intermediate section 12/18/2016 12/18/2016 3.50 INTRM2 CASING PUTB P PU, and fill shoe track - (check floats) 0.0 1,651.0 03:00 06:30 - Good. Continue to RIH w/ 7", 26#, L- 80 Hydria 563 casing to 1,610-ft. installing 34 turbulator centralizers, while filling pipe every 10 jts. Torquing all connections to 9,400-ft lbs. PU Baker 7" x 9-5/8" Flex lock / ZXP Liner hanger assembly and MU same. Mix and fill annulus from RS Pack -off to top tie back setting sleeve. Calc. Disp. = 15 bbl's. Act Disp. = 11 bbl's - pushed away 4 bbl's. 12/18/2016 12/18/2016 0.75 INTRM2 CASING RUNL P RIH w/ 7" Intermediate from 1,651-ft 1,651.0 2,029.0 06:30 07:15 to 2,029-ft on 5" DP Up wt = 67K, Dn wt = 67K 12/18/2016 12/18/2016 0.50 INTRM2 CASING CIRC P Circfulate while reciprocating from 2,029.0 2,029.0 07:15 07:45 2,029-ft to 1,967-ft MD. Staging pumps up 8 bpm @ 170 psi, 16% F/O B/D TD. 12/18/2016 12/18/2016 7.25 INTRM2 CASING RUNL P RIH w/ 7" Intermediate from 2,029-ft 2,029.0 12,385.0 07:45 15:00 to 12,385-ft on 5" DP at 60-ft / min. Monitoring displacement and filling pipe every 20 stands. Up wt = 165K, Dn wt = 90K 12/18/2016 12/18/2016 2.50 INTRM2 CASING CIRC P CBU @ 6 bpm @ 850 psi w/ 13% flow 12,385.0 12,385.0 15:00 17:30 12/18/2016 12/18/2016 1.50 INTRM2 CASING RUNL P Continue running 7" drilling liner on 5" 12,385.0 13,870.0 17:30 19:00 drillpipe from 12385' to 13870' P/U = 220 kips, S/O = 105 kips 12/18/2016 12/18/2016 0.50 INTRM2 CASING HOSO P Make up top drive and wash down at 5 13,870.0 13,904.0 19:00 19:30 bpm, Tag bottom at 13904'. Rack back one stand Page 21/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/18/2016 12/18/2016 0.50 INTRM2 CEMENT RURD P Make up liner cementing head, a 13,904.0 13,904.0 19:30 20:00 single and a 10' pup jt and space out 10' above bottom. TOL @ 12243.51', 12/18/2016 12/19/2016 4.00 INTRM2 CEMENT CIRC P Circulate and condition mud at 7 bpm, 13,904.0 13,904.0 20:00 00:00 1100 psi, 12/19/2016 12/19/2016 2.50 INTRM2 CEMENT CIRC P Continue circulating and conditioning 13,904.0 13,904.0 00:00 02:30 mud until 12 ppg In / Out at 8 BPM at 1,090 psi with 15% 12/19/2016 12/19/2016 0.50 INTRM2 CEMENT SFTY P Held PJSM with all involved with 13,904.0 13,904.0 02:30 03:00 cementing. 12/19/2016 12/19/2016 2.00 INTRM2 CEMENT CMNT P Pump 5 bbl's fresh water, test SLB 13,904.0 13,904.0 03:00 05:00 cementers treating lines to 4,500 psi. Proceed with planned cement program. Pump 40 bbl's of CW100 @ 3 bpm @ 900 psi w/ 7% flow. Followed by 45.9 bbl's of 13 ppg Mud Push II @ 3.5 bpm @ 1,200 psi. w/ 10% Flow. Drop 1 st dart. Mix and pump 108.5 bbl's of 15.8 ppg Class G cement @ 3 bpm @ 600 psi w/ 7% flow. Drop 2nd dart and chase with of H2O @ 3 bpm @ 500 psi w/ 7% flow. Swap over to the rig and displace @ 8 bpm @ 760 psi - Reduce flow to 3.5 bpm @ 110 psi. Observe dart latch up @ 998 strokes and plug release @ 1,790 psi. Observed plug land @ 1,672 stks. Second dart latched up at 2,265 stks and second plug @ 1,240 psi. and bumped plug @ 3 bpm @ 560 psi 2,945 stks. Cement on depth @ 04:57 12/19/2016 12/19/2016 0.50 INTRM2 CEMENT PACK P Pressure up to 3,000 psi and set Flex 13,904.0 12,243.0 05:00 05:30 lock hanger, S/O to 45K to ensure hanger set. Pressure up to 4,200 psi, hold for 5 minutes, Bleed off pressure and check floats - good. PU and observe free travel @ 180K. Dogged out and set 60K down, pressure up to 700 psi and pull pack -off. 12/19/2016 12/19/2016 2.25 INTRM2 CEMENT CIRC P Circulate approximately 15 bbl cement 12,243.0 12,243.0 05:30 07:45 and contaminated mud off top of liner at 8 bpm, 3750 psi. FCP = 1750 psi. 12/19/2016 12/19/2016 1.00 INTRM2 CEMENT RURD P Pull seals out of liner top and lay down 12,243.0 12,156.0 07:45 08:45 cementing head and circulating equipment 12/19/2016 12/19/2016 1.25 INTRM2 CEMENT CIRC P Circulate bottoms up at 15 bpm, 1659 12,156.0 12,156.0 08:45 10:00 psi 12/19/2016 12/19/2016 1.00 INTRM2 CEMENT PRTS P Rig up test equipment. Close annular 12,156.0 12,156.0 10:00 11:00 and test liner top packer to 1000 psi for 10 minutes. Rig down test equipment 12/19/2016 12/19/2016 1.00 INTRM2 CEMENT WWWH P Flush stack with black -water pill. Sim- 12,156.0 12,156.0 11:00 12:00 ops empty pit #6 and build high vis spacer. Begin cleaning demco valves Page 22140 Report Printed: 1/17/2017 x Operations Summary (with Timelog Depths) f W� 2M-37 Awl Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Cade Time P -T -X Operation (ftKB) End Depth (WEI) 12/19/2016 12/19/2016 5.00 INTRM2 CEMENT CIRC P Pump 70 bbl hi -vis spacer and 12,156.0 12,156.0 12:00 17:00 displace well with freshwater at 7 bpm. ICP = 1500 psi, FCP = 550 psi. 12/19/2016 12/19/2016 1.00 INTRM2 CEMENT OWFF P Monitor well for flow. Blow down top 12,156.0 12,156.0 17:00 18:00 drive and prepare to lay down drillpipe 12/19/2016 12/20/2016 6.00 INTRM2 CEMENT PULD P Lay down 5" drillpipe from 12156' to 12,156.0 1,426.0 18:00 00:00 1426' 12/20/2016 12/20/2016 2.50 INTRM2 CEMENT PULD P Pull OOH sideways laying down 5" DP 1,426.0 0.0 00:00 02:30 f/ 1426' to surface, monitoring displacement on pit #5. Lay down ZXP running tool. Note: Packoff element on running tool was washed out. 12/20/2016 12/20/2016 2.00 INTRM2 CEMENT PULD P M/U muleshoe and RIH w/ remaining 0.0 0.0 02:30 04:30 5" DP stands to 1588'. Pull OOH sideways laying down 5" DP f/ 1588' to surface, monitoring displacement on pit #5. 12/20/2016 12/20/2016 1.00 INTRM2 CEMENT WWWH P Pull wearbushing, make up stack 0.0 0.0 04:30 05:30 washer, and jet stack w/ 8 bpm, 40 psi, 45% F/O, 50 rpm, 4k Tq. Blow down top drive. SIMOPS - Load / strap 7" casing in pipe shed. 12/20/2016 12/20/2016 1.25 INTRM2 CEMENT SLPC P PJSM. Slip / cut 65' drilling line. 0.0 0.0 05:30 06:45 SIMOPS - Load / strap 7" casing in pipe shed. 12/20/2016 12/20/2016 0.50 INTRM2 CEMENT SVRG P Service top drive, roughneck, 0.0 0.0 06:45 07:15 drawworks, and blocks. SIMOPS - Load / strap 7" casing in pipe shed. 12/20/2016 12/20/2016 2.00 INTRM2 CEMENT RURD P PJSM. Mobilize casing equipment to 0.0 0.0 07:15 09:15 rig floor, R/D 5" handling equipment, and R/U Volant tool and 7" casing handling equipment. SIMOPS - Load / strap 7" casing in pipe shed. 12/20/2016 12/20/2016 2.75 INTRM2 CEMENT OTHR P Load / strap 7" casing in pipe shed. 0.0 0.0 09:15 12:00 SIMOPS - Clean / clear rig floor, service crown, conduct derrick inspection, and perform general rig maintenance. 12/20/2016 12/20/2016 0.50 INTRM2 CEMENT RURD P Make up hanger and perform dummy 0.0 0.0 12:00 12:30 run. SIMOPS - Load / strap 7" casing in pipe shed. Page 23/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/20/2016 12/20/2016 3.50 INTRM2 CEMENT OTHR P Load / strap 7" casing in pipe shed. 0.0 0.0 12:30 16:00 Total of 260 joints BTC-m and 55 joints H563 loaded in shed. 7 x spare joints H563 outside. SIMOPS - Perform general rig maintenance. 12/20/2016 12/20/2016 3.50 INTRM2 CEMENT PUTB P PJSM. Make up seal assembly and 0.0 2,000.0 16:00 19:30 RIH on 7", 26#, L-80, BTC-m casing to 2000' using Doyon Casing Volant tool, allowing pipe to self-fill, PUW 75k, SOW 75k, monitoring displacement on pit #5. 12/20/2016 12/20/2016 0.75 INTRM2 CEMENT CIRC P Establish circulation above 9-5/8" 2,000.0 2,044.0 19:30 20:15 linter top packer at 13 bpm, 140 psi, 33% F/O, and wash down joint f/ 2000' - 2044', SOW 77k. No issues running through liner top packer. Circulate total of 1 x bottoms up and blow down top drive. 12/20/2016 12/21/2016 3.75 INTRM2 CEMENT PUTB P RIH on 7", 26#, L-80, BTC-m casing f/ 2,044.0 5,279.0 20:15 00:00 2044'- 5279' using Doyon Casing Volant tool, allowing pipe to self-fill, PUW 75k, SOW 75k, monitoring displacement on pit #5. 12/21/2016 12/21/2016 5.00 INTRM2 CEMENT PUTB P RIH on 7", 26#, L-80, BTC-m casing f/ 5,279.0 8,150.0 00:00 05:00 5279'- 8150' using Doyon Casing Volant tool, allowing pipe to self-fill, monitoring displacement on pit #5. 12/21/2016 12/21/2016 1.25 INTRM2 CEMENT CIRC P Observed fluid u-tubing up casing. 8,150.0 8,150.0 05:00 06:15 Circulate 1 x surface-to-surface volume w/ 12 bpm, 300 psi, 22% F/O, total 711 bbls pumped. Blow down top drive. 12/21/2016 12/21/2016 4.00 INTRM2 CEMENT PUTB P RIH on 7", 26#, L-80, BTC-m casing f/ 8,150.0 10,198.0 06:15 10:15 8150'- 10198' using Doyon Casing Volant tool, allowing pipe to self-fill, monitoring displacement on pit #5. Note: Lay out joint # 215 & 216 due to cross threading. Replace with joint # 259 and 260. 12/21/2016 12/21/2016 0.50 INTRM2 CEMENT CIRC P Perform pipe management in shed to 10,198.0 10,198.0 10:15 10:45 prepare for switching to H563 casing. Circulate well w/ 12 bpm, 400 psi, 25% F/O, total 292 bbls pumped. 12/21/2016 12/21/2016 1.00 INTRM2 CEMENT PUTB P M/U XO to H563 and RIH on 7", 26#, 10,198.0 10,835.0 10:45 11:45 L-80, Hydril 563 Doped casing f/ 10198'- 10835' using Doyon Casing Volant tool, allowing pipe to self-fill, monitoring displacement on pit #5, PUW 250k, SOW 100k. Note: Lay out joint # 253 due to damaged box from Volant CRT dies. Replace with joint # A from outside. 12/21/2016 12/21/2016 0.75 INTRM2 CEMENT EQRP T Observe fluid leaking by cup on Volant 10,835.0 10,835.0 11:45 12:30 I tool. Change out cup. Page 24140 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) ' 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/21/2016 12/21/2016 2.50 INTRM2 CEMENT PUTB P RIH on 7", 26#, L-80, Hydril 563 10,835.0 12,237.0 12:30 15:00 Doped casing f/ 10835'- 12237' using Doyon Casing Volant tool, allowing pipe to self -fill, monitoring displacement on pit #5, PUW 255k, SOW 100k. 12/21/2016 12/21/2016 0.50 INTRM2 CEMENT WASH P Wash down w/ 2 bpm, 70 psi and 12,237.0 12,255.0 15:00 15:30 observe pressure increase to 280 psi @ 12244'. Bleed off pressure and continue RIH, no-go at 12255.01'. 12/21/2016 12/21/2016 1.50 INTRM2 CEMENT HOSO P Lay down joints # 278, 277, and 276. 12,252.0 12,227.0 15:30 17:00 Make up 19.78' pup and joint # 276 to space out 1.85' off fully located. Make up hanger and landing joint. 12/21/2016 12/21/2016 0.50 INTRM2 CEMENT PRTS P RIH and engage seals into seal bore 12,227.0 12,252.0 17:00 17:30 receptable. Line up and pressure test OA to 1000 psi / 10 min - good test. 12/21/2016 12/21/2016 1.00 INTRM2 CEMENT RURD P Pick up above liner top to 12237' and 12,252.0 12,237.0 17:30 18:30 rig up to reverse circulate„ closing annular. Establish cirulation at 5.5 bpm, 334 psi. 12/21/2016 12/21/2016 1.25 INTRM2 CEMENT CRIH P Reverse circulate 290 bbls Corrosion- 12,237.0 12,237.0 18:30 19:45 Inhibited Freshwater with rig pump at 5 bpm, 266 psi, 12/21/2016 12/21/2016 2.25 INTRM2 CEMENT FRZP P Hold PJSM with LRS for freeze 12,237.0 12,237.0 19:45 22:00 protect, rig up and reverse circulate 210 bbls Isotherm down annulus at 2- 3 bpm, ICP 250 psi, FCP 600 psi. 12/21/2016 12/21/2016 0.50 INTRM2 CEMENT HOSO P Strip down through annular and sting 12,237.0 12,255.0 22:00 22:30 seals into seal bore. Pressure up to 1000 psi w/ LRS to confirm seals stung in. Bleed off pressure, open annular, and land off hanger. Note: Tieback string spaced out 1.85' above fully located, bottom of seal assembly @ 12253.16'. 12/21/2016 12/21/2016 0.75 INTRM2 CEMENT RURD P Blow down lines, drain stack, L/D 12,255.0 0.0 22:30 23:15 landing joint, remove 7" elevators and dog bones, and install 5" elevators. 12/21/2016 12/22/2016 0.75 INTRM2 CEMENT WWSP P Make up pack off and running tool. 0.0 0.0 23:15 00:00 RIH and set packoff. RILDS. 12/22/2016 12/22/2016 1.50 INTRM2 CEMENT WWSP P Run in lock down screws. Pressure 0.0 0.0 00:00 01:30 test seals on packoff to 250 / 5000 psi for 5 / 15 min, witnessed by CPAI - good test. 12/22/2016 12/22/2016 1.00 INTRM2 CEMENT PRTS P Line up LRS and pressure test 7" x 9- 0.0 0.0 01:30 02:30 5/8" x 13-5/8" outer annulus w/ Isotherm to 2500 psi / 30 min - good test. R/D LRS and blow down lines. 12/22/2016 12/22/2016 3.00 INTRM2 CEMENT BOPE P Change out upper rams from 7" solid 0.0 0.0 02:30 05:30 body casing rams to 3-1/2" x 6" VBR's. SIMOPS Change out saver sub from 4 -1/2" IF to XT39 and load/strap 4" DP in shed. 12/22/2016 12/22/2016 1.50 INTRM2 WHDBOP RURD P Rig up for testing BOPE, fill stack with 0.0 0.0 05:30 07:00 water, and perform shell test. Page 25/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/22/2016 12/22/2016 5.00 INTRM2 WHDBOP BOPE P Tested BOPE with 3-1/2" and 4-1/2" 0.0 0.0 07:00 12:00 test joint. 250/3500 psi, charted for 5 minutes each. Witnessed by AOGCC Rep. Matt Herrera. Install 3-1/2"" Test Joint and test: Test #1 - Annular, CV#1, #12, #13, #14, and manual kill. Test #2 - Upper 3-1/2" x 6-1/2" VBR's, Upper IBOP, HCR Kill, CV #9 and #11. Test #3 - Lower IBOP, CV #5, #8, and #10. Test #4 - Dart valve, CV #4, #6, and #7. Test #5 - Floor Valve and CV #2. Test #6 - HCR choke, 4" kill line, and Demco valve. Test #7 - Manual choke valve and HCR kill. Test #8 - Lower 3-1/2" x 6" VBR's Test #9 - Blind rams and CV #3 Install 4-1/2" Test joint and test: Test #10 - Annular Test #11 - Upper 3-1/2" x 6" VBR's Test #12 - Lower 3-1/2" x 6" VBR's Test #13 - Manual super choke to 3000 psi Test #14 - Hydraulic super choke to 3000 psi Perform Koomey draw down test. Observed initial system pressure at ACC - 2975 PSI. After Closure observed ACC - 1800 PSI, 200 PSI increase in 43 seconds w/ 1 x electric pump, full pressure at 230 seconds w/ 1 x electric pump and 2 x air pumps. Observed 5 nitrogen bottles with an average PSI of 2000 PSI. Tested all gas and PVT alarms, both audio and visual - good tests. 12/22/2016 12/22/2016 1.00 INTRM2 WHDBOP RURD P R/D test equipment and blow down 0.0 0.0 12:00 13:00 lines. Pull test plug and install 8.75" ID wearbushing 12/22/2016 12/22/2016 0.50 INTRM2 CEMENT RURD P PJSM. Install mouse hole and C/O 0.0 0.0 13:00 13:30 elevators to 4". 12/22/2016 12/22/2016 3.50 INTRM2 CEMENT PULD P Build 31 x stands 4" DP and 15 x 0.0 0.0 13:30 17:00 stands 4" HWDP using mousehole and rack back in derrick. 12/22/2016 12/22/2016 1.50 INTRM2 CEMENT BHAH P PJSM. Mobilize BHA to floor. 0.0 0.0 17:00 18:30 12/22/2016 12/22/2016 2.00 INTRM2 CEMENT BHAH P M/U BHA #7 for drilling 6-1/8" 0.0 335.0 18:30 20:30 production section as per DD/MWD to top of HWDP at 335'. Note: 3 x float subs pressure tested offline at rig to 600 psi w/ 2 x non - ported flapper valves and 1 x non - ported plunger valve. Page 26/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (WEI) 12/22/2016 12/22/2016 1.00 INTRM2 CEMENT PULD P Run in hole on 4" DP singles f/ 335'- 335.0 1,750.0 20:30 21:30 1750', monitoring displacement on pit #5. 12/22/2016 12/22/2016 0.50 INTRM2 CEMENT DHEQ P Perform shallow hole test as per SLB 1,750.0 7750.0 21:30 22:00 w/ 220 gpm, 800 psi, 14% F/O, PUW 50k, SOW 50k. 12/22/2016 12/23/2016 2.00 INTRM2 CEMENT PULD P Run in hole on 4" DP singles f/ 1750'- 1,750.0 5,000.0 22:00 00:00 5000', filling pipe every 20 x stands, monitoring displacement on pit #5. 12/23/2016 12/23/2016 5.50 INTRM2 CEMENT PULD P Run in hole on 4" DP singles f/ 5000'- 5,000.0 11,239.0 00:00 05:30 11239', filling pipe every 20 x stands, monitoring displacement on pit #5. Note: Load last delivery of 4" DP from API once enough room on bottom row in pipe shed and strap/tally. 12/23/2016 12/23/2016 0.75 INTRM2 CEMENT OTHR P Finish strapping /tallying 4" DP 11,239.0 11,239.0 05:30 06:15 singles and confirm tally correct. 12/23/2016 12/23/2016 0.75 INTRM2 CEMENT PULD P Run in hole on 4" DP singles f/ 11239' 11,239.0 11,975.0 06:15 07:00 - 11975', monitoring displacement on pit #5. 12/23/2016 12/23/2016 0.50 INTRM2 CEMENT CIRC P Establish circulation w/ 240 gpm, 1580 11,975.0 11,975.0 07:00 07:30 psi, 5% F/O and downlink to setup tools for logging cement. 12/23/2016 12/23/2016 0.75 INTRM2 CEMENT QEVL P Run in hole on 4" DP singles f/ 11975' 11,975.0 12,450.0 07:30 08:15 - 12450', logging cement at 800 ft/hr, monitoring displacement on pit #5. 12/23/2016 12/23/2016 2.75 INTRM2 CEMENT DISP P PJSM. Displace well from freshwater 12,450.0 12,450.0 08:15 11:00 to 12.Oppg LSND at 7" liner top packer w/ 180 gpm, ICP 703 psi, FCP 2076 psi, 60 rpm, 13k Tq, pump 30 bbl hi - vis sweep chased with 442 bbls 12.0 ppg LSND. Obtain new SPR's and blow down top drive. SPRs @ 12250' MD, 5678' TVD, MW=12.0 ppg, 10:30 hours MP#1: 30 spm=1320 psi, 40 spm=1720 psi. MP #2: 30 spm=1300 psi, 40 spm=1700 psi. 12/23/2016 12/23/2016 4.50 INTRM2 CEMENT QEVL P Run in hole on 4" DP singles f/ 12450' 12,450.0 13,587.0 11:00 15:30 - 13587', logging cement at 800 ft/hr, monitoring displacement on pit #5. 12/23/2016 12/23/2016 0.25 INTRM2 CEMENT COCF P Wash down on 4" DP stands from 13,587.0 13,615.0 15:30 15:45 derrick f/ 13587'- 13615'w/ 2 bpm, 1500 psi, SOW 6k. Tag top of cement @ 13615' w/ 5k WOB. 12/23/2016 12/23/2016 0.25 INTRM2 CEMENT COCF P Ream down on 4" DP stands f/ 13615' 13,615.0 13,635.0 15:45 16:00 - 13635'w/ 165 gpm, 2500 psi, 60 rpm, 13k Tq, 0-2k WOB. 12/23/2016 12/23/2016 1.75 INTRM2 CEMENT CIRC P Circulate and condition mud for casing 13,635.0 13,588.0 16:00 17:45 test w/ 165 gpm, 2300 psi, 60 rpm, 10- 13k Tq, until even in/out 12.0 ppg. 12/23/2016 12/23/2016 0.50 INTRM2 CEMENT RURD P Blow down top drive and change out 13,588.0 13,588.0 17:45 18:15 master bushings to split bushings. Page 27/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/23/2016 12/23/2016 1.25 INTRM2 CEMENT PRTS P Rig up and pressure test casing to 13,588.0 13,588.0 18:15 19:30 3500 psi for 30 min - good test. Rig down and blow down lines. 12/23/2016 12/23/2016 1.50 INTRM2 CEMENT COCF P Ream down on 4" DP stands f/ 13635' 13,588.0 13,755.0 19:30 21:00 - 13755' cleaning out hard cement w/ 164 gpm, 2200 psi, 14% F/O, 80 rpm, 13k Tq, 5-10k WOB. ROT 100k. 12/23/2016 12/23/2016 2.00 INTRM2 CEMENT DRLG P Drill out plugs and landing collar f/ 13,755.0 13,762.0 21:00 23:00 13755'- 13762'w/ 164 gpm, 2200 psi, 50 rpm, 10-17k Tq, 5-13k WOB, ROT 100k. 12/23/2016 12/24/2016 1.00 INTRM2 CEMENT DRLG P Drill hard cement, float collar, and 13,762.0 13,825.0 23:00 00:00 hard cement f/ 13762'- 13825'w/ 163 gpm, 2000 psi, 50-80 rpm, 13-15k Tq, 7-16k WOB, ROT 100k. SPRs @ 13775' MD, 6046' TVD, MW=12.0 ppg, 23:15 hours MP#1: 20 spm=1000 psi, 30 spm=1220 psi. MP #2: 20 spm= 980 psi, 30 spm=1200 psi. OA pressure = 350 psi 12/24/2016 12/24/2016 0.75 INTRM2 CEMENT DRLG P Drill out hard cement f/ 13825'- 13,825.0 13,891.0 00:00 00:45 13891'w/ 163 gpm, 1,954 psi, 80 rpm, 13k Tq, 7-16k WOB, ROT 100k. 12/24/2016 12/24/2016 0.50 INTRM2 CEMENT DRLG P Drill out shoe f/ 13891'- 13894' and 13,891.0 13,897.0 00:45 01:15 rathole to 13897'w/ 235 gpm, 2,875 psi, 6-7% F/O, 80 rpm, 15k Tq, 2-5k WOB. Note: Upon initial tag of shoe, string stalled out multiple times. Worked several times and continued drilling with no further issues. 12/24/2016 12/24/2016 0.50 INTRM2 CEMENT DDRL P Drilling 6-1/8" Production hole from 13,897.0 13,917.0 01:15 01:45 13,897' to 13,917' MD / 6,056' TVD, ADT = AT Bit Hrs = .47, Total Jar hrs = 124.02, PU wt = 190K, S/O wt = 93K, ROT wt = 100K, TQ On = 15K, TQ Off = 15K, ECD = 14.38, Flow Out = 6 - 8%, WOB = 5-15K, RPM = 80, GPM = 235, SPM = 55, SPP = 2,900 psi, Max Gas = 0. 12/24/2016 12/24/2016 1.75 INTRM2 CEMENT RURD P Pull into shoe and rack back stand 13,917.0 13,869.0 01:45 03:30 #144, Circulate and condition the hole in preparation for FIT. CBU @ 166 gpm, 1,700 psi with 6% F/O while rotating at 80 RPM with 15K torque. 12/24/2016 12/24/2016 1.00 INTRM2 CEMENT FIT P Blow down TD, Rig up and perform 13,869.0 13,869.0 03:30 04:30 FIT to 14.5 ppg EMW w/ 12.0 ppg LSND mud at 7" casing shoe, 13894' MD / 6055' TVD. Pumped 1.3 bbl's to reach 790 psi, 1.1 bbl's bled back - Rig down test equipment. Page 28/40 Report Printed: 1/17/2017 s Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 12/24/2016 12/24/2016 2.00 PROD1 DRILL MPDA P PJSM. Pull trip nipple and install MPD 13,869.0 13,869.0 04:30 06:30 bearing. Line up and establish circulation to calibrate chokes w/ 165 gpm, 1960 psi, 6% F/O, 80 rpm, 15k Tq. 12/24/2016 12/24/2016 2.25 PROD1 DRILL DISP P PJSM. Displace well from 12.Oppg 13,869.0 13,888.0 06:30 08:45 LSND to 10.5 ppg Flo -Pro. Pump 30 bbls 10.5ppg Hi -Vis Sweep followed by 500 bbls 10.5ppg FloPro at 172 gpm, ICP 1800 psi, FCP 2350 psi, 9% F/O, 80 rpm, 15k Tq. Run in hole to 13911' once 10.5ppg reached the bit, 1500 strokes, and increase pump rate to 223 gpm to turn on PWD tool for monitoring ECD, ICP 2947 psi, FCP 2434 psi, Initial ECD 14.17ppg drop to 12.03 ppg. Circulate total 5889 stokes, final MW in/out 10.5ppg. 12/24/2016 12/24/2016 3.25 PROD1 DRILL CIRC P Decrease flow rate to 180 gpm, 1700 13,888.0 13,866.0 08:45 12:00 psi, 15% F/O, 80 rpm, 15k Tq, pull back into shoe, and circulate while cleaning pits. SPRs @ 13917' MD, 6056' TVD, MW=10.5 ppg, 12:00 hours MP#1: 20 spm=560 psi, 30 spm=830 psi. MP #2: 20 spm= 575 psi, 30 spm=830 psi. 12/24/2016 12/24/2016 6.00 PROD1 DRILL DDRL P RIH to bottom and Directionally drill 6- 13,866.0 14,246.0 12:00 18:00 1/8" production section f/ 13917' - 14246' MD, 6053' TVD, ADT 3.87 hrs, Bit hrs 4.34, Jar hrs 128.36, PUW 190k, SOW 52k, ROT 100k, Tq on 14- 16k, Tq off 14k, ECD 12.67ppg, 15% F/O, WOB 9-13k, 120 rpm, 230 gpm, 2575 psi, Max Gas 1933 units. Hold 350 psi backpressure on connections with MPD. Note: Out of target zone from 13897' to 14220'. Re-entered target pay at 14220'. Page 29/40 Report Printed: 1/17/2017 y Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/24/2016 12/25/2016 6.00 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 14,246.0 14,625.0 18:00 00:00 section f/ 14246'- 14625' MD, 6050' TVD, ADT 3.4 hrs, Bit hrs 7.74, Jar hrs 131.76, PUW 185k, SOW 52k, ROT 100k, Tq on 15k, Tq off 15k, ECD 12.89ppg, 13% F/O, WOB 5-8k, 120 rpm, 230 gpm, 2650 psi, Max Gas 6413 units. Hold 350-400 psi backpressure on connections with MPD. SPRs @ 14525' MD, 6051' TVD, MW=10.5 ppg, 22:45 hours MP#1: 20 spm=640 psi, 30 spm=885 psi. MP #2: 20 spm= 640 psi, 30 spm=905 psi. 24 hr losses = 8 bbls OA pressure = 525 psi. 12/25/2016 12/25/2016 2.00 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 14,625.0 14,818.0 00:00 02:00 section f/ 14625'- 14818' MD, 6066' TVD, ADT 1.26 hrs, Bit hrs 9.0, Jar hrs 133.02, PUW 190k, SOW 55k, ROT 100k, Tq on 16k, Tq off 15.5k, ECD 12.87ppg, 15% F/O, WOB 5-8k, 120 rpm, 236 gpm, 2725 psi, Max Gas 8038 units, MW 10.5ppg. Hold 400 psi backpressure on connections with MPD. 12/25/2016 12/25/2016 1.00 PROD1 DRILL CIRC T Observed fluid flowing up drill pipe at 14,818.0 14,818.0 02:00 03:00 connection break at 14817', holding 400 psi dynamically on the backside (11.8ppg EMW). Make up topdrive and backream stand with 235 gpm, 2671 psi, 20% F/O, 120 rpm, 15k Tq, 12.98ppg ECD. Bleed off drill pipe pressure, shut in bleeder, and monitor for pressure buildup on drillpipe with 400 psi on backside - none observed. Break connection and observe minimal flow up drill pipe. 12/25/2016 12/25/2016 3.50 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 14,818.0 15,013.0 03:00 06:30 section f/ 14818'- 15013' MD, 6077' TVD, ADT 2.0 hrs, Bit hrs 11.0, Jar hrs 135.02, PUW 190k, SOW 55k, ROT 100k, Tq on 16k, Tq off 15.5k, ECD 12.91 ppg, 15% F/O, WOB 5-12k, 120 rpm, 236 gpm, 2775 psi, Max Gas 6940 units, MW 10.5 ppg. Hold 400 psi backpressure dynamically on connections with MPD. Note: Pumped 30 bbl hi-vis sweep to help clean out potential plugging in floats. Observed large amount of gas at surface correlating to bottoms up from when we saw flow up drill pipe. Page 30/40 ReportPrinted: 1/17/2017 z Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/25/2016 12/25/2016 2.50 PROD1 DRILL CIRC T Observed fluid flowing up drill pipe at 15,013.0 15,013.0 06:30 09:00 connection break at 15013', holding 400 psi dynamically on the backside (11.8ppg EMW). Make up topdrive and backream stand with 237 gpm, 2690 psi, 16% F/0, 120 rpm, 15k Tq, 12.88ppg ECD, pumping 30 bbl hi -vis sweep around bit. Increase MPD backpressure to 475 psi (12.Oppg EMW), bleed off drill pipe pressure, shut in bleeder, and monitor for pressure buildup on drillpipe - none observed. Break connection and observe minimal flow up drill pipe. Time flow up drill pipe at 1ft in 49 seconds, then 1ft in 85 seconds. 12/25/2016 12/25/2016 3.00 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 15,013.0 15,160.0 09:00 12:00 section f/ 15013'- 15160' MD, 6082' TVD, ADT 2.49 hrs, Bit hrs 13.49, Jar hrs 137.51, PUW 190k, SOW 55k, ROT 100k, Tq on 15.5k, Tq off 15k, ECD 12.83ppg, 15% F/0, WOB 5-1Ok, 120 rpm, 235 gpm, 2800 psi, Max Gas 6530 units, MW 10.5 ppg. Hold 475 psi backpressure dynamically on connections with MPD. OA pressure at noon = 750 psi 12/25/2016 12/25/2016 6.00 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 15,160.0 15,574.0 12:00 18:00 section f/ 15160'- 15574' MD, 6082' TVD, ADT 4.41 hrs, Bit hrs 17.90, Jar hrs 141.92, PUW 190k, SOW 42k, ROT 98k, Tq on 16-18k, Tq off 16k, ECD 13.01 ppg, 14% F/0, WOB 5-1 Ok, 120 rpm, 240 gpm, 2890 psi, Max Gas 8379 units, MW 10.5 ppg. Increase MPD backpressure dynamically on connections from 475 psi to 500 psi (12.1 ppg EMW) from 15386' onward. SPRs @ 15290' MD, 6083' TVD, MW=10.5 ppg, 14:15 hours MP#1: 20 spm=705 psi, 30 spm=940 psi. MP #2: 20 spm= 680 psi, 30 spm=980 psi. Note: Crossed large fault @ 15498' MD, throwing us down out of zone into the A3 formation. Start building up to re-enter target zone. Page 31/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (ftKB) End Depth (ftKB) 12/25/2016 12/26/2016 6.00 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 15,574.0 15,954.0 18:00 00:00 section f/ 15574'- 15954' MD, 6060' TVD, ADT 4.54 hrs, Bit hrs 22.44, Jar hrs 146.46, PUW 195k, SOW 45k, ROT 100k, Tq on 16-17k, Tq off 16- 16.5k, ECD 13.25ppg, 12% F/O, WOB 5-8k, 141 rpm, 240 gpm, 3000 psi, Max Gas 4582 units, MW 10.5 ppg. Hold 500 psi (12.1 ppg EMW) backpressure dynamically on connections with MPD. Losses for 24 hours = 56 bbls OA pressure at midnight = 925 psi 12/26/2016 12/26/2016 6.00 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 15,954.0 16,328.0 00:00 06:00 section f/ 15954'- 16328' MD, 6045' TVD, ADT 4.22 hrs, Bit hrs 26.66, Jar hrs 150.68, PUW 190k, SOW 45k, ROT 92k, Tq on 15-16k, Tq off 15k, ECD 13.11 ppg, 38% F/O, WOB 5-12k, 141 rpm, 238 gpm, 2900 psi, Max Gas 3699 units, MW 10.5 ppg. Hold 500 psi (12.1 ppg EMW) backpressure dynamically on connections with MPD. SPRs @ 16238' MD, 6051' TVD, MW=10.5 ppg, 04:30 hours MP#1: 25 spm=700 psi, 35 spm=1000 psi. MP #2: 25 spm= 900 psi, 35 spm=1000 psi. 12/26/2016 12/26/2016 6.00 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 16,328.0 16,614.0 06:00 12:00 section f/ 16328'- 16614' MD, 6035' TVD, ADT 3.15 hrs, Bit hrs 29.81, Jar hrs 153.83, PUW 200k, Unable to get SOW, have to rotate down for connection, ROT 90k, Tq on 16-17k, Tq off 15-16k, ECD 12.90ppg, 44% F/O, WOB 8-12k, 140 rpm, 240 gpm, 2888 psi, Max Gas 7126 units, MW 10.5 ppg. Hold 500 psi (12.1 ppg EMW) backpressure dynamically on connections with MPD. Pump 29 bbl hi -vis sweep @ 16526'. OA pressure @ noon = 975 psi Note: Re-entered target Kuparuk C4 zone at 16495' MD. Page 32/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) ... 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/26/2016 12/26/2016 6.00 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 16,614.0 16,903.0 12:00 18:00 section f/ 16614'- 16903' MD, 6033' TVD, ADT 4.29 hrs, Bit hrs 34.10, Jar hrs 158.83, PUW 190k, Unable to get SOW, have to rotate down for connection, ROT 100k, Tq on 17-19k, Tq off 17-18k, ECD 12.92ppg, 34% F/O, WOB 5-11 k, 141 rpm, 240 gpm, 2874 psi, Max Gas 7126 units, MW 10.5 ppg. Hold 500 psi (12.1 ppg EMW) backpressure dynamically on connections with MPD. Pump 29 bbl hi -vis sweep @ 16526'. Note: Lost ability to get slackoff weight from 16709' onward 12/26/2016 12/27/2016 6.00 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 16,903.0 17,002.0 18:00 00:00 section f/ 16903'- 17002' MD, 6038' TVD, ADT 5.06 hrs, Bit hrs 39.16, Jar hrs 163.18, PUW 202k, Unable to get SOW, have to rotate down for connection, ROT 100k, Tq on 16-19k, Tq off 17k, ECD 12.81ppg, 29% F/O, WOB 3-10k, 120 rpm, 250 gpm, 3050 psi, Max Gas 5330 units, MW 10.5 ppg. Hold 500 psi (12.1 ppg EMW) backpressure dynamically on connections with MPD. Note: While trying to drop angle to 87° for geosteering, we drilled into a hard spot at 16945' that deflected us up —3.3° inclination at bit to 90.8° - decreased ROP, WOB, and RPMS, increased flow rate to work bit down through hard spot to remain in target zone and not go out the top. OA pressure at midnight = 1025 psi 24 hour losses = 69 bbls 12/27/2016 12/27/2016 6.00 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 17,002.0 17,103.0 00:00 06:00 section f/ 17002'- 17103' MD, 6039' TVD, ADT 3.96 hrs, Bit hrs 43.12, Jar hrs 167.14, PUW 200k, SOW 35k, ROT 100k, Tq on 16-18k, Tq off 15- 16k, ECD 12.91 ppg, 28% F/O, WOB 3 -10k, 120-140 rpm, 240 gpm, 2850 psi, Max Gas 1671 units, MW 10.5 ppg. Hold 500 psi (12.1 ppg EMW) backpressure dynamically on connections with MPD. Note: Continue to work bit down through hard spot to remain in target zone and not go out the top. Penetrate through stringer at 17040' MD. Page 33/40 ReportPrinted: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/27/2016 12/27/2016 6.00 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 17,103.0 17,391.0 06:00 12:00 section f/ 17103'- 17391' MD, 6037' TVD, ADT 3.73 hrs, Bit hrs 46.85, Jar hrs 170.87, PUW 195k, Unable to attain slackoff weight, have to rotate down, ROT 105k, Tq on 16-17k, Tq off 15-16k, ECD 12.97ppg, 46% F/O, WOB 5-8k, 140 rpm, 240 gpm, 2930 psi, Max Gas 2813 units, MW 10.5 ppg. Hold 500 psi (12.1 ppg EMW) backpressure dynamically on connections with MPD. SPRs @ 17262' MD, 6040' TVD, MW=10.5 ppg, 09:30 hours MP#1: 25 spm=725 psi, 35 spm=1065 psi. MP #2: 25 spm= 720 psi, 35 spm=1020 psi. OA pressure @ noon = 1150 psi 12/27/2016 12/27/2016 1.75 PROD1 DRILL DDRL P Directionally drill 6-1/8" production 17,391.0 17,510.0 12:00 13:45 section from 17391' to TD of 17510' MD, 6037' TVD, ADT 1.5 hrs, Bit hrs 48.35, Jar hrs 172.37, PUW 186k, SOW 56k, ROT 106k, Tq on 17-18k, Tq off 15, ECD 12.99 ppg, 40% F/O, WOB 5-8k, 140 rpm, 240 gpm, 2990 psi, Max Gas 5624 units, MW 10.5 ppg. Hold 500 psi (12.1 ppg EMW) backpressure dynamically on connections with MPD. Note: In target Kuparuk C4 zone for 2307 ft (64%) of lateral. 12/27/2016 12/27/2016 1.75 PROD1 CASING CIRC P Circulate 1 x bottoms up, take SPR's 17,510.0 17,510.0 13:45 15:30 at TD and obtain final survey w/ 240 gpm, 2950 psi, 140 rpm, 16k Tq, ROT 110k. SPRs @ 17510' MD, 6037' TVD, MW=10.5 ppg, 14:30 hours MP#1: 25 spm=725 psi, 35 spm=1020 psi. MP #2: 25 spm= 705 psi, 35 spm=1016 psi. 12/27/2016 12/27/2016 1.00 PROD1 CASING OWFF P Rack back stand to 17446', Blow down 17,510.0 17,446.0 15:30 16:30 topdrive, and Perform MPD drawdown test. Determine pore pressure to be at 11.5 ppg (315 psi surface pressure w/ 10.5ppg MW, 6085' TVD at deepest part of well). 12/27/2016 12/27/2016 1.50 PROD1 CASING CIRC P Run in to TD and circulate 1 x bottoms 17,446.0 17,510.0 16:30 18:00 up w/ 240 gpm, 2950 psi, 140 rpm, 15k Tq, Max gas at bottoms up = 5624 units. 12/27/2016 12/27/2016 4.75 PROD1 CASING BKRM P Backream OOH f/ 17510'- 15883' MD 17,510.0 15,883.0 18:00 22:45 w/ 240 gpm, ICP 2880 psi, FCP 2680 psi, 50% F/O, ECD initial 12.8ppg decrease to 12.61 ppg, 130-140 rpm, 13-15k Tq, target 1000 ft/hr pulling speed. Hold 500 psi (12.1ppg EMW) backpressure at surface with MPD system on connections. Page 34/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 12/27/2016 12/28/2016 1.25 PROD1 CASING BKRM P Observe hole packoff and stall out at 15,883.0 15,857.0 22:45 00:00 15883'. Work stand down and observe packoff tendency at 15931'. Work through section and backream slowly to 15898' and observe packoff tendencies. Continue to work stand through section to 15857'w/ 240-250 gpm, 2880 psi, 50% F/O, 130-140 rpm, 13.5k Tq, 12.82ppg ECD. Hold 500 psi (12.1 ppg EMW) backpressure at surface with MPD system on connections. OA pressure at midnight = 1100 psi Total losses for 24 hours = 59 bbls 12/28/2016 12/28/2016 3.25 PROD1 CASING BKRM P Backream OOH f/ 15857'- 15370'w/ 15,857.0 15,370.0 00:00 03:15 240-250 gpm, 2850 psi, 50% F/O, 130 -140 rpm, 13.5k Tq, 12.78ppg ECD, pulling BHA through across fault section at 100-400 ft/hr working through minor packoffs. Hold 500 psi (12.1 ppg EMW) backpressure at surface with MPD system on connections. 12/28/2016 12/28/2016 5.00 PROD1 CASING BKRM P Backream OOH f/ 15370'- 13869'w/ 15,370.0 13,869.0 03:15 08:15 240 gpm, ICP 2850 psi, FCP 1846 psi, 50% F/O, 140 rpm, 13k Tq, target pulling speed 1000 ft/hr. Hold 500 psi (12.1 ppg EMW) backpressure at surface with MPD system on connections. 12/28/2016 12/28/2016 2.75 PROD1 CASING CIRC P Circulate 2.5 bottoms up until shakers 13,869.0 13,774.0 08:15 11:00 cleaned up w/ 200 gpm, 1910 psi, 42% F/O, 12.25ppg ECD, 120 rpm, 11.5k Tq, reciprocating from 13869' - 13774'. Hold PJSM for laying in hi vis pill and displacing well to 12.1 ppg potassium formate. 12/28/2016 12/28/2016 0.50 PROD! CASING DISP P Pump 60 bbl hi -vis spacer followed by 13,774.0 13,774.0 11:00 11:30 64 bbls 12.1+ppg Potassium Formate w/ 200 gpm, 1764 psi, 44% F/O, 120 rpm, 11.5k Tq, 12.32ppg ECD. 12/28/2016 12/28/2016 1.75 PROD! CASING OTHR T Observed brine at shakers and 13,774.0 13,774.0 11:30 13:15 confirmed improper lineup. Shut down pumps and troubleshoot. Charge pump for mud pump #1 that was circulating across the top of the well through MPD lines was pulling from potassium formate pit instead of FloPro pit. Total of 96 bbls of 12.1+ppg Potassium Formate brine diverted to rockwasher. Maintain 500 psi (12.1 ppg EMW) on backside with MPD while confirming correct lineup. OA pressure at noon = 800 psi 12/28/2016 12/28/2016 0.25 PROD1 CASING DISP P RIH f/ 13774'- 13872' and pump 13,774.0 13,872.0 13:15 13:30 12.1+ppg Potassium Formate w/ 180 gpm, 1250 psi, 46% F/O down drill pipe with mud pump #1 to place hi -vis spacer at bit. Page 36140 Report Printed: 1 /1 712 01 7 S Operations Summary (with Timelog Depths) 2M-37 .� .iW. Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 12/28/2016 12/28/2016 0.50 PROD1 CASING DISP P Lay in 500' hi-vis pill w/ 70 gpm, 330 13,872.0 13,397.0 13:30 14:00 psi, 28% F/O f/ 13872'- 13397', pulling at 2400 ft/hr. Maintain 500 psi (12.1 ppg EMW) on backside with MPD. 12/28/2016 12/28/2016 0.50 PROD1 CASING SVRG P Service topdrive, blocks, and 13,397.0 13,397.0 14:00 14:30 drawworks. 12/28/2016 12/28/2016 1.50 PROD1 CASING WAIT T Wait on trucks with potassium 13,397.0 13,397.0 14:30 16:00 formate. SIMOPS perform derrick inspection. Nordic camp moved past rig on 2M-pad. 12/28/2016 12/28/2016 0.50 PROD1 CASING OTHR T Load pits with additional 12.1+ppg 13,397.0 13,397.0 16:00 16:30 potassium formate to pit #5. 12/28/2016 12/28/2016 1.25 PROD1 CASING DISP P Displace well to 12.1+ppg Kill Weight 13,397.0 13,397.0 16:30 17:45 Potassium Formate, pumping 511 bbls until good 12.1+ in/out observed at surface with 190 gpm, ICP 1500 psi, FCP 1800 psi, 50 rpm, 13k Tq, Initial ECD 12.38ppg, Final ECD 12.94ppg. 12/28/2016 12/28/2016 1.00 PROD1 CASING OWFF P Blow down topdrive, shut in MPD 13,397.0 13,397.0 17:45 18:45 choke and monitor for pressure buildup - none observed. Open choke and line up returns to cellar to monitor for flow. Wellbore breathing confirmed with initial time to fill vis cup of 2 seconds decreasing to static over 30 minutes. SIMOPS: Clean pits 12/28/2016 12/28/2016 1.25 PROD1 CASING MPDA P Pull MPD bearing and install trip 13,397.0 13,397.0 18:45 20:00 nipple. Flush MPD lines with freshwater, blow down lines, remove 4" MPD hose from flow line and cap line. SIMOPS: Clean pits 12/28/2016 12/28/2016 0.75 PROD1 CASING RURD P Clean flow line in pits under shakers. 13,397.0 13,397.0 20:00 20:45 12/28/2016 12/29/2016 3.25 PROD1 CASING TRIP P Pull OOH on elevators f/ 13397'- 13,397.0 7,243.0 20:45 00:00 7243', racking back 4" DP stands in derrick and monitoring displacement on trip tank. OA pressure at midnight = 460 psi 12/29/2016 12/29/2016 2.75 PROD1 CASING TRIP P Pull OOH on elevators f/ 7243'- 429', 7,243.0 429.0 00:00 02:45 racking back 4" DP, monitoring displacement on trip tank. 12/29/2016 12/29/2016 0.25 PROD1 CASING OWFF P Monitor well for flow - well static. 429.0 429.0 02:45 03:00 12/29/2016 12/29/2016 2.50 PROD1 CASING BHAH P PJSM. Pull OOH laying down BHA f/ 429.0 0.0 03:00 05:30 429' to surface as per SLB. Bit was in gauge and minimal wear, graded 1-1- WT-A-X-0-NO-TD. All three floats were retrieved in closed position and still functioned open/close properly. No washing observed around seals or in float sub bore. 12/29/2016 12/29/2016 0.75 PROD1 CASING BHAH P Clean / clear rig floor of BHA tools and 0.0 0.0 05:30 06:15 MPD equipment. 12/29/2016 12/29/2016 1.25 COMPZN CASING RURD --[P Mobilize casing equipment to rig floor 0.0 0.0 06:15 07:30 and rig up to run 4-1/2" liner. Page 36/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 12/29/2016 12/29/2016 4.25 COMPZN CASING PUTB P PJSM. RIH with 4-1/2" 12.6# L-80 0.0 3,722.0 07:30 11:45 TXP-m perforated liner as per tally to 3722', torquing connections to 7000 ft - lbs, monitoring displacement on trip tank. OA pressure at noon = 0 psi 12/29/2016 12/29/2016 1.25 COMPZN CASING OTHR P Change out tongs and make up liner 3,722.0 3,767.0 11:45 13:00 hanger/packer and fill tieback with pal mix as per Baker. 12/29/2016 12/29/2016 0.50 COMPZ1 CASING CIRC P RIH w/ 1 x stand 4" DP to 3861' and 3,767.0 3,861.0 13:00 13:30 pump through hanger/packer assembly w/ 2 bpm, 50 psi for 10 bbls. Blow down topdrive. 12/29/2016 12/29/2016 7.00 COMPZN CASING RUNL P RIH w/ liner on 4" DP stands f/ 3861'- 3,861.0 13,813.0 13:30 20:30 13813', filling pipe every 20 x stands, monitoring displacement on pit #5. 12/29/2016 12/29/2016 0.75 COMPZN CASING CIRC P Circulate 1 x drill pipe volume w/ 145 13,813.0 13,813.0 20:30 21:15 gpm, 500 psi, 18% F/O, 12.1+ppg in/out potassium formate. Obtain parameters, PUW 163k, SOW 77k, ROT 110k w/ 20 rpm, 9k Tq 12/29/2016 12/30/2016 2.75 COMPZN CASING RUNL P RIH w/ liner on 4" DP stands f/ 3861'- 13,813.0 17,282.0 21:15 00:00 13813', filling pipe every 20 x stands, monitoring displacement on pit #5. 12/30/2016 12/30/2016 0.25 COMPZN CASING RUNL P Cont to RIH w/ 4-1/2" TXP liner on 4" 17,282.0 17,484.0 00:00 00:15 HWDP f/ 17282' MD to 17484' MD. 12/30/2016 12/30/2016 0.75 COMPZN CASING CIRC P Circulate drill pipe volume @ 3.5 17,484.0 17,484.0 00:15 01:00 bpm=840 psi w/ 18 % FO, 1670 strokes. 12/30/2016 12/30/2016 1.00 COMPZN CASING PACK P Set FlexLock and ZXP as follows. 17,484.0 17,484.0 01:00 02:00 Drop 1.625" OD ball and pump down @ 3.5 bpm=650 psi, slow pumps to 2 bpm=390 psi @ 1000 strokes. Observe ball land at 1380 strokes, —20 bbls early. Pressure up to 2000 psi to set liner hanger, S/O and check to see if liner is hung, no go. P/U to 21 OK and pressure up to 2200 psi, S/O to 35K to confirm liner is hung. Pressure up to 3400 psi to release, P/U to expose dogs and slack off to set ZXP liner top packer. Observed dog sub shear w/ 50K down weight.. P/U and rotate @ 20 rpm's, 7K Tq and set down 50K ensure ZXP is set. Liner shoe set at 17484.21', liner top packer set at 13729.46'. 12/30/2016 12/30/2016 0.50 COMPZN CASING PRTS P Pressure test ZXP liner top packer to 17,484.0 13,729.5 02:00 02:30 3500 psi f/ 10 min, good test. Page 37/40 ReportPrinted: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 12/30/2016 12/30/2016 1.50 COMPZN WELLPR CIRC P Pick up 13' to pull out of RS pack -off, 13,729.5 13,726.0 02:30 04:00 pump @ 2 bpm, 230 psi while pulling up out of ZXP liner top packer w/ running tools. Pick up to 13676' MD, clear of tie -back sleeve and increase pumps @ 5.5 bpm= 1600 psi and circulate 10.5 ppg mud out of the hole that was displaced by liner, diverting 50 bbls of mud/brine mixture to rockwasher to prevent contaminating potassium formate in pits. Observe good 12.1+ppg potassium formate in/out after 1 x bottoms up. 12/30/2016 12/30/2016 0.50 COMPZN WELLPR OWFF P Monitor well for flow - observe well 13,726.0 13,726.0 04:00 04:30 breathing back initially and decreasing to staticslight flow to static. 12/30/2016 12/30/2016 1.50 COMPZN WELLPR SLPC P Slip and cut 73' of drilling line, service 13,726.0 13,726.0 04:30 06:00 rig. 12/30/2016 12/30/2016 1.25 COMPZN WELLPR CIRC P Well out of balance, transfer fluid from 13,726.0 13,726.0 06:00 07:15 trip tank to active. Circulate and condition fluid, pump @ 5 bpm= 1313 psi, 17% FO 12/30/2016 12/30/2016 8.75 COMPZN WELLPR PULD P Pull OOH on elevators laying out 4" 13,726.0 1,227.0 07:15 16:00 HWDP and 4" DP f/ 13726'- 1227', monitoring displacement on trip tank. 12/30/2016 12/30/2016 1.75 COMPZN WELLPR WAIT T Shut down operations due to phase 3 1,227.0 1,227.0 16:00 17:45 weather conditions. Monitor well on trip tank, observe 1 bbl/hr static losses. 12/30/2016 12/30/2016 1.50 COMPZN WELLPR PULD P Pull OOH on elevators laying out 4" 1,227.0 0.0 17:45 19:15 DP and liner running tools f/ 1227' to surface, monitoring displacement on trip tank. Observe good indication of shear on rotating dog sub. 12/30/2016 12/30/2016 1.75 COMPZN RPCOMP RURD P Clean / clear floor. Pull wearbushing, 0.0 0.0 19:15 21:00 C/O split bushings, and Rig up to run 3-1/2" upper completion. Confirm pipe count and jewlery placement correct. 12/30/2016 12/30/2016 1.00 COMPZN RPCOMP PUTB P PJSM. Make up Baker seal assembly, 0.0 144.0 21:00 22:00 Halliburton Mirage plug, and 2 x joints 3-1/2" 9.3# L-80 H563 to 144'. 12/30/2016 12/30/2016 0.25 COMPZN RPCOMP PRTS P Fill pipe full, rig up head pin and test 144.0 144.0 22:00 22:15 pump to tubing and pressure test Mirage plug to 1000 psi / 5 min - good test. 12/30/2016 12/30/2016 1.50 COMPZN RPCOMP PUTB P RIH on 3-1/2" 9.3# L-80 H563 tubing f/ 144.0 1,226.0 22:15 23:45 144'- 1226', making up 2.813" DS nipple (no plug installed) and GLM w/ 2500 psi casing -to -tubing SOV, filling pipe on the fly and topping off every 15 xjoints. 12/30/2016 12/31/2016 0.25 COMPZN RPCOMP PRTS P Fill pipe full, rig up head pin and test 1,226.0 1,226.0 23:45 00:00 pump to tubing and pressure test Mirage plug and SOV to 1000 psi / 5 min - good test. Page 38/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr} Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 12/31/2016 12/31/2016 9.00 COMPZN RPCOMP PUTB P RIH on 3-1/2" 9.3# L-80 H563 tubing f/ 1,226.0 13,777.0 00:00 09:00 1226'- 13777' as per tally, filling pipe on the fly and topping off every 15 x joints. 12/31/2016 12/31/2016 0.75 COMPZN RPCOMP HOSO P Make upjt # 431, RIH and fully locate 13,777.0 13,796.0 09:00 09:45 at no-go at 13796'. Pick up off no-go, keeping seals stabbed in, rig up and pressure test IA to 500 psi / 5 min to confirm integrity of seals - good test. 12/31/2016 12/31/2016 1.00 COMPZN RPCOMP HOSO P Lay down joints 431, 430, and 429. 13,796.0 13,710.0 09:45 10:45 Make up 2 x 3-1/2" pups, 7.82' and 9.78', XO, and 1 xjoint 4-1/2" IBT. 12/31/2016 12/31/2016 0.50 COMPZN RPCOMP THGR P Make up tubing hanger and landing 13,710.0 0.0 10:45 11:15 joint. RIH and land off hanger w/ seals spaced out 6.27' off no-go. 12/31/2016 12/31/2016 0.75 COMPZN RPCOMP THGR P Run in lock down screws. SIMOPS 0.0 0.0 11:15 12:00 Rig up to test tubing and IA. 12/31/2016 12/31/2016 1.50 COMPZN RPCOMP PRTS P Pressure test 3-1/2" tubing to 3000 0.0 0.0 12:00 13:30 psi / 30 min - good test. Bleed pressure on tubing down to 2000 psi and pressure test IA to 3500 psi / 30 min - good test. Bleed off pressure rapidly on tubing and shear out casing -to-tubing shear out valve to establish TBG -IA communication. 12/31/2016 12/31/2016 0.25 COMPZN RPCOMP RURD P Rig down test equipment and lay 0.0 0.0 13:30 13:45 down landing joint. 12/31/2016 12/31/2016 0.50 COMPZN RPCOMP OWFF P Monitor well for 30 min - well static. 0.0 0.0 13:45 14:15 12/31/2016 12/31/2016 0.50 COMPZN WHDBOP MPSP P Install BPV w/ dry rod. Rig up and 0.0 0.0 14:15 14:45 pressure test IA to 2500 psi / 15 min to test BPV in direction of flow - good test. 12/31/2016 12/31/2016 1.00 COMPZN WHDBOP OTHR P Blow down lines and rig down test 0.0 0.0 14:45 15:45 equipment. Clean / clear rig floor. 12/31/2016 12/31/2016 3.25 COMPZN WHDBOP NUND P PJSM. Nipple down BOPE and 0.0 0.0 15:45 19:00 scaffolding. 12/31/2016 12/31/2016 1.25 COMPZN WHDBOP NUND P Nipple up FMC tree adapter as per 0.0 0.0 19:00 20:15 FMC and pressure test void to 500 / 5000 psi for 5/15 min. witnessed by CPAI - good test. Note: This wellhead system is not configured to allow testing of upper hanger seals prior to N/U of tree adapter. Testing void after N/U of tree adapter will also test hanger neck seals, outer seals, and lockdown screws. 12/31/2016 12/31/2016 0.75 COMPZN WHDBOP NUND P Nipple up FMC tree to adaptor flange. 0.0 0.0 20:15 21:00 12/31/2016 12/31/2016 1.25 COMPZN WHDBOP NUND T Re -arrange valve alignment per DSO / 0.0 0.0 21:00 22:15 FMC, rotating master valve, swab valve, and wing valve 180°. 12/31/2016 12/31/2016 0.75 COMPZN WHDBOP RURD P DTH rig up scaffolding around tree. 0.0 0.0 22:15 23:00 12/31/2016 1/1/2017 1.00 COMPZN WHDBOP NUND P Nipple up flow cross on top of tree per 0.0 0.0 23:00 00:00 DSO / FMC. 1/1/2017 1/1/2017 0.50 COMPZN WHDBOP NUND P PJSM. Cont to nipple up flow cross as 0.0 0.0 00:00 00:30 per plan. Page 39/40 Report Printed: 1/17/2017 Operations Summary (with Timelog Depths) 2M-37 Wids Rig: DOYON 141 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation Start Depth (ftKB) End Depth (ftKB) 1/1/2017 1/1/2017 0.75 COMPZN WHDBOP MPSP P Pull BPV and install TWC as per FMC. 0.0 0.0 00:30 01:15 1/1/2017 1/1/2017 0.50 COMPZN WHDBOP OTHR P Fill tree with diesel and rig up to test 0.0 0.0 01:15 01:45 tree. 1/1/2017 1/1/2017 1.00 COMPZN WHDBOP PRTS P Pressure test tree to 250/5000 psi for 0.0 0.0 01:45 02:45 15 min each. 1/1/2017 1/1/2017 0.50 COMPZN WHDBOP MPSP P Pull TWC as per FMC rep. 0.0 0.0 02:45 03:15 1/1/2017 1/1/2017 0.75 COMPZN WHDBOP FRZP P Rig up to freeze protect well. 0.0 0.0 03:15 04:00 1/1/2017 1/1/2017 1.00 COMPZN WHDBOP FRZP P PJSM, pressure test lines to 3000 psi. 0.0 0.0 04:00 05:00 Pump 56 bbls of diesel @ 2 bpm=1200 psi, slow pumps to 1.8 bpm=1950 psi. 1/1/2017 1/1/2017 2.00 COMPZN WHDBOP OTHR P PJSM, C/O saver sub from 4" XT -39 0.0 0.0 05:00 07:00 to 4-1/2" IF. SIMOPS, allow well to U- tube. 1/1/2017 1/1/2017 0.50 COMPZN WHDBOP MPSP P Install BPV as per FMC rep, 0 psi= 0.0 0.0 07:00 07:30 Tubing, 0 psi = IA, 0 psi= OA. 1/1/2017 1/1/2017 1.25 COMPZN WHDBOP OTHR P Blow down and rig down freeze 0.0 0.0 07:30 08:45 protect wells and R/U to UD 4" DP. SIMOPS, reposition flow cross. 1/1/2017 1/1/2017 0.25 COMPZN WHDBOP PRTS P Test flow cross to 5000 psi, good. 0.0 0.0 08:45 09:00 1/1/2017 1/1/2017 1.50 COMPZN MOVE RURD P Secure well, remove rig valves OA/IA 0.0 0.0 09:00 10:30 and install needle valves on tree. Rig down scaffolding around tree and place in tub. 1/1/2017 1/1/2017 3.00 DEMOB MOVE PULD P PJSM, L/D 45 stands of 4" XT -39 drill 0.0 0.0 10:30 13:30 pipe out of derrick using mouse hole. UD mousehole. 1/1/2017 1/1/2017 4.50 DEMOB MOVE MOB P PJSM. Prep for moving to 2M-38. 0.0 0.0 13:30 18:00 RDMO to 2M-38. Rig released at 1800 hrs. Page 40/40 Report Printed: 1/17/2017 NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-37 Definitive Survey Report 09 January, 2017 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 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 2M-37 Date Well Position +N/ -S 0.00 usft Northing: 5,948,985.74 usft Latitude: 70° 16' 18.575 N +E/ -W 0.00 usft Easting: 487,726.18 usft Longitude: 150° 5'57.364 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 102.30 usft Wellbore 2M-37 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (°) (nT) BGGM2016 12/13/2016 17.73 80.88 57,534 Design 2M-37 Date Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 27.42 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 82.10 2M-37 Srvy 1 - SLB INC (2M-37) (usft) (usft) (usft) (°) 136.96 27.42 0.00 0.00 275.00 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 82.10 82.10 2M-37 Srvy 1 - SLB INC (2M-37) INC+TREND Inclinometer+ known azi trend 11/23/2016 11:21 136.96 812.27 2M-37 Srvy 2 - SLB_GWD70 (2M-37) GYD-GC-SS Gyrodata gyro single shots 11/23/2016 11:4: 850.13 3,060.65 2M-37 Srvy 3 - SLB_MWD+GMAC (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/24/2016 11:4 3,154.18 3,154.18 2M-37 Srvy 4 - SLB_Inc+Filler (2M-37) INC+TREND Inclinometer + known azi trend 11/30/2016 934 3,179.69 12,377.53 2M-37 Srvy 5 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/30/2016 9:36 12,461.04 12,461.04 2M-37 Srvy 6 - SLB_INC+Filler (2M-37) INC+TREND Inclinometer + known azi trend 12/15/2016 10:1 12,553.02 13,826.19 2M-37 Srvy 7 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/15/2016 10:1 13,924.48 17,447.91 2M-37 Srvy 8 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/27/2016 9:3F Survey 1/9/2017 9:26:48AM Page 2 COMPASS 5000.1 Build 74 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 27.42 0.00 0.00 27.42 -102.30 0.00 0.00 5,948,985.74 487,726.18 0.00 0.00 UNDEFINED 82.10 1.00 253.19 82.10 -47.62 -0.14 -0.46 5,948,985.60 487,725.72 1.83 0.44 INC+TREND(1) 136.96 1.62 253.19 136.94 7.22 -0.50 -1.66 5,948,985.24 487,724.52 1.13 1.61 GYD-GC-SS (2) 168.55 1.34 258.04 168.52 38.80 -0.71 -2.45 5,948,985.04 487,723.73 0.97 2.38 GYD-GC-SS (2) 256.36 1.10 268.08 256.31 126.59 -0.95 -4.29 5,948,984.80 487,721.88 0.37 4.19 GYD-GC-SS (2) 353.37 2.06 315.89 353.29 223.57 0.27 -6.44 5,948,986.02 487,719.74 1.60 6.44 GYD-GC-SS (2) 446.75 4.53 330.22 446.51 316.79 4.68 -9.44 5,948,990.44 487,716.75 2.77 9.81 GYD-GC-SS (2) 539.10 6.96 330.28 538.39 408.67 12.71 -14.02 5,948,998.47 487,712.18 2.63 15.08 GYD-GC-SS (2) 1/9/2017 9:26:48AM Page 2 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 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) (°/100') (ft) Survey Tool Name 631.34 10.70 335.84 629.52 499.80 25.38 -20.30 5,949,011.15 487,705.92 4.15 22.44 GYD-GC-SS (2) 719.55 9.39 338.03 716.38 586.66 39.52 -26.35 5,949,025.30 487,699.90 1.55 29.69 GYD-GC-SS (2) 812.27 11.66 336.02 807.53 677.81 55.10 -32.98 5,949,040.89 487,693.29 2.48 37.66 GYD-GC-SS (2) 850.13 12.23 335.73 844.57 714.85 62.25 -36.19 5,949,048.04 487,690.10 1.51 41.47 MWD+IFR-AK-CAZ-SC (3) 945.23 15.32 335.79 936.92 807.20 82.90 -45.48 5,949,068.70 487,680.84 3.25 52.53 MWD+IFR-AK-CAZ-SC (3) 1,035.97 14.97 335.98 1,024.51 894.79 104.53 -55.17 5,949,090.35 487,671.19 0.39 64.07 MWD+IFR-AK-CAZ-SC (3) 1,130.23 15.45 334.09 1,115.47 985.75 126.95 -65.61 5,949,112.78 487,660.78 0.73 76.42 MWD+IFR-AK-CAZ-SC (3) 1,225.08 17.47 333.77 1,206.43 1,076.71 151.09 -77.42 5,949,136.94 487,649.01 2.13 90.30 MWD+IFR-AK-CAZ-SC (3) 1,317.38 20.91 334.87 1,293.59 1,163.87 178.43 -90.55 5,949,164.30 487,635.93 3.75 105.75 MWD+IFR-AK-CAZ-SC (3) 1,409.70 23.05 332.89 1,379.19 1,249.47 209.44 -105.78 5,949,195.33 487,620.75 2.45 123.63 MWD+IFR-AK-CAZ-SC (3) 1,503.43 24.00 331.83 1,465.13 1,335.41 242.58 -123.14 5,949,228.50 487,603.44 1.11 143.82 MWD+IFR-AK-CAZ-SC (3) 1,596.51 26.18 329.23 1,549.43 1,419.71 276.91 -142.59 5,949,262.86 487,584.06 2.62 166.18 MWD+IFR-AK-CAZ-SC (3) 1,689.85 27.53 327.66 1,632.70 1,502.98 312.83 -164.66 5,949,298.81 487,562.04 1.63 191.30 MWD+IFR-AK-CAZ-SC (3) 1,786.16 28.76 323.13 1,717.63 1,587.91 350.18 -190.47 5,949,336.20 487,536.30 2.56 220.27 MWD+IFR-AK-CAZ-SC (3) 1,879.92 31.24 319.94 1,798.83 1,669.11 386.84 -219.66 5,949,372.90 487,507.17 3.14 252.54 MWD+IFR-AK-CAZ-SC (3) 1,972.74 35.05 314.66 1,876.55 1,746.83 424.02 -254.13 5,949,410.13 487,472.77 5.15 290.12 MWD+IFR-AK-CAZ-SC (3) 2,065.38 37.71 309.90 1,951.14 1,821.42 460.91 -294.80 5,949,447.08 487,432.16 4.19 333.85 MWD+IFR-AK-CAZ-SC (3) 2,158.51 39.52 308.66 2,023.90 1,894.18 497.69 -339.79 5,949,483.93 487,387.23 2.11 381.88 MWD+IFR-AK-CAZ-SC (3) 2,253.18 41.94 304.24 2,095.65 1,965.93 534.32 -389.49 5,949,520.64 487,337.60 3.98 434.57 MWD+IFR-AK-CAZ-SC (3) 2,345.37 43.15 298.35 2,163.60 2,033.88 566.64 -442.72 5,949,553.04 487,284.42 4.51 490.42 MWD+IFR-AK-CAZ-SC (3) 2,439.86 45.52 294.98 2,231.19 2,101.47 596.23 -501.73 5,949,582.72 487,225.47 3.54 551.79 MWD+IFR-AK-CAZ-SC (3) 2,530.32 47.86 291.71 2,293.25 2,163.53 622.27 -562.16 5,949,608.86 487,165.09 3.69 614.25 MWD+IFR-AK-CAZ-SC (3) 2,622.67 49.04 286.56 2,354.52 2,224.80 644.88 -627.42 5,949,631.58 487,099.87 4.36 681.24 MWD+IFR-AK-CAZ-SC (3) 2,717.09 51.37 283.18 2,414.96 2,285.24 663.46 -697.52 5,949,650.27 487,029.81 3.69 752.69 MWD+IFR-AK-CAZ-SC (3) 2,808.52 54.24 281.98 2,470.23 2,340.51 679.30 -768.60 5,949,666.23 486,958.76 3.31 824.88 MWD+IFR-AK-CAZ-SC (3) 2,900.80 56.22 281.40 2,522.85 2,393.13 694.66 -842.83 5,949,681.70 486,884.57 2.21 900.16 MWD+IFR-AK-CAZ-SC (3) 2,995.44 58.18 280.34 2,574.12 2,444.40 709.65 -920.95 5,949,696.82 486,806.48 2.27 979.29 MWD+IFR-AK-CAZ-SC (3) 3,060.65 59.37 279.57 2,607.92 2,478.20 719.29 -975.87 5,949,706.55 486,751.58 2.09 1,034.85 MWD+IFR-AK-CAZ-SC (3) 3,150.00 59.83 281.09 2,653.14 2,523.42 733.11 -1,051.68 5,949,720.49 486,675.80 1.55 1,111.57 INC+TREND (4) 13318" x 16" 3,154.18 59.85 281.16 2,655.24 2,525.52 733.80 -1,055.23 5,949,721.19 486,672.25 1.55 1,115.17 INC+TREND (4) 3,179.69 60.43 281.07 2,667.94 2,538.22 738.07 -1,076.94 5,949,725.49 486,650.55 2.29 1,137.17 MWD+IFR-AK-CAZ-SC (5) 3,272.74 62.09 278.79 2,712.69 2,582.97 752.12 -1,157.29 5,949,739.68 486,570.23 2.79 1,218.44 MWD+IFR-AK-CAZ-SC (5) 3,366.84 63.19 276.31 2,755.94 2,626.22 763.09 -1,240.13 5,949,750.78 486,487.41 2.62 1,301.92 MWD+IFR-AK-CAZ-SC (5) 3,460.10 64.30 273.85 2,797.20 2,667.48 770.49 -1,323.43 5,949,758.31 486,404.13 2.65 1,385.55 MWD+IFR-AK-CAZ-SC (5) 3,556.03 65.56 272.48 2,837.85 2,708.13 775.28 -1,410.19 5,949,763.24 486,317.39 1.84 1,472.39 MWD+IFR-AK-CAZ-SC (5) 3,648.96 67.19 271.82 2,875.09 2,745.37 778.47 -1,495.27 5,949,766.57 486,232.33 1.87 1,557.43 MWD+IFR-AK-CAZ-SC (5) 3,743.64 68.68 271.39 2,910.65 2,780.93 780.93 -1,582.98 5,949,769.17 486,144.64 1.63 1,645.02 MWD+IFR-AK-CAZ-SC (5) 3,835.03 70.01 271.13 2,942.89 2,813.17 782.81 -1,668.47 5,949,771.19 486,059.15 1.48 1,730.35 MWD+IFR-AK-CAZ-SC (5) 3,929.08 71.42 269.54 2,973.95 2,844.23 783.32 -1,757.23 5,949,771.85 485,970.40 2.19 1,818.82 MWD+IFR-AK-CAZ-SC (5) 1/9/2017 9:26:48AM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,023.26 71.67 269.47 3,003.76 2,874.04 782.55 -1,846.57 5,949,771.22 485,881.07 0.27 1,907.74 MWD+IFR-AK-CAZ-SC (5) 4,117.36 71.50 270.36 3,033.49 2,903.77 782.42 -1,935.85 5,949,771.24 485,791.80 0.92 1,996.67 MWD+IFR-AK-CAZ-SC (5) 4,209.95 71.64 271.20 3,062.76 2,933.04 783.61 -2,023.68 5,949,772.58 485,703.98 0.87 2,084.28 MWD+IFR-AK-CAZ-SC (5) 4,301.89 71.00 270.98 3,092.21 2,962.49 785.27 -2,110.76 5,949,774.37 485,616.91 0.73 2,171.17 MWD+IFR-AK-CAZ-SC (5) 4,394.41 71.02 269.70 3,122.32 2,992.60 785.79 -2,198.24 5,949,775.04 485,529.44 1.31 2,258.36 MWD+IFR-AK-CAZ-SC (5) 4,489.51 71.08 269.63 3,153.20 3,023.48 785.26 -2,288.19 5,949,774.66 485,439.50 0.09 2,347.92 MWD+IFR-AK-CAZ-SC (5) 4,583.50 71.05 268.20 3,183.70 3,053.98 783.58 -2,377.07 5,949,773.12 485,350.63 1.44 2,436.32 MWD+IFR-AK-CAZ-SC (5) 4,674.88 71.05 268.29 3,213.38 3,083.66 780.93 -2,463.46 5,949,770.61 485,264.24 0.09 2,522.15 MWD+IFR-AK-CAZ-SC (5) 4,770.41 70.96 266.26 3,244.47 3,114.75 776.64 -2,553.68 5,949,766.47 485,174.02 2.01 2,611.65 MWD+IFR-AK-CAZ-SC (5) 4,862.73 70.96 266.31 3,274.59 3,144.87 770.99 -2,640.76 5,949,760.96 485,086.94 0.05 2,697.91 MWD+IFR-AK-CAZ-SC (5) 4,955.39 71.03 264.99 3,304.77 3,175.05 764.34 -2,728.12 5,949,754.45 484,999.58 1.35 2,784.35 MWD+IFR-AK-CAZ-SC (5) 5,048.17 71.02 264.40 3,334.93 3,205.21 756.23 -2,815.48 5,949,746.48 484,912.22 0.60 2,870.68 MWD+IFR-AK-CAZ-SC (5) 5,139.12 70.96 263.13 3,364.56 3,234.84 746.89 -2,900.96 5,949,737.29 484,826.73 1.32 2,955.02 MWD+IFR-AK-CAZ-SC (5) 5,234.58 71.01 263.48 3,395.66 3,265.94 736.37 -2,990.59 5,949,726.91 484,737.09 0.35 3,043.39 MWD+IFR-AK-CAZ-SC (5) 5,327.67 71.66 264.60 3,425.46 3,295.74 727.21 -3,078.31 5,949,717.90 484,649.36 1.34 3,129.98 MWD+IFR-AK-CAZ-SC (5) 5,418.25 71.87 267.14 3,453.80 3,324.08 721.02 -3,164.11 5,949,711.85 484,563.56 2.67 3,214.91 MWD+IFR-AK-CAZ-SC (5) 5,513.53 70.87 269.60 3,484.25 3,354.53 718.45 -3,254.35 5,949,709.42 484,473.33 2.66 3,304.58 MWD+IFR-AK-CAZ-SC (5) 5,607.51 69.96 270.31 3,515.75 3,386.03 718.37 -3,342.89 5,949,709.49 484,384.80 1.20 3,392.78 MWD+IFR-AK-CAZ-SC (5) 5,701.67 70.81 270.93 3,547.36 3,417.64 719.34 -3,431.58 5,949,710.60 484,296.12 1.10 3,481.22 MWD+IFR-AK-CAZ-SC (5) 5,795.36 70.35 271.76 3,578.51 3,448.79 721.41 -3,519.92 5,949,712.82 484,207.79 0.97 3,569.40 MWD+IFR-AK-CAZ-SC (5) 5,887.78 70.14 271.67 3,609.75 3,480.03 724.01 -3,606.86 5,949,715.56 484,120.87 0.25 3,656.23 MWD+IFR-AK-CAZ-SC (5) 5,980.19 70.11 271.57 3,641.16 3,511.44 726.47 -3,693.73 5,949,718.16 484,034.01 0.11 3,742.99 MWD+IFR-AK-CAZ-SC (5) 6,075.29 70.14 271.33 3,673.49 3,543.77 728.73 -3,783.13 5,949,720.57 483,944.61 0.24 3,832.25 MWD+IFR-AK-CAZ-SC (5) 6,169.07 70.08 270.44 3,705.40 3,575.68 730.09 -3,871.31 5,949,722.07 483,856.45 0.89 3,920.21 MWD+IFR-AK-CAZ-SC (5) 6,261.32 70.15 270.06 3,736.78 3,607.06 730.47 -3,958.06 5,949,722.59 483,769.71 0.39 4,006.66 MWD+IFR-AK-CAZ-SC (5) 6,355.18 70.04 269.38 3,768.73 3,639.01 730.04 -4,046.31 5,949,722.31 483,681.47 0.69 4,094.54 MWD+IFR-AK-CAZ-SC (5) 6,448.04 70.16 268.31 3,800.34 3,670.62 728.28 4,133.60 5,949,720.69 483,594.18 1.09 4,181.35 MWD+IFR-AK-CAZ-SC (5) 6,542.29 70.58 268.37 3,832.01 3,702.29 725.71 -4,222.34 5,949,718.26 483,505.45 0.45 4,269.52 MWD+IFR-AK-CAZ-SC (5) 6,635.88 70.48 266.52 3,863.20 3,733.48 721.78 -4,310.49 5,949,714.47 483,417.31 1.87 4,356.99 MWD+IFR-AK-CAZ-SC (5) 6,729.69 71.06 266.45 3,894.10 3,764.38 716.35 -4,398.89 5,949,709.19 483,328.90 0.62 4,444.59 MWD+IFR-AK-CAZ-SC (5) 6,821.90 71.20 266.35 3,923.92 3,794.20 710.87 -4,485.98 5,949,703.85 483,241.81 0.18 4,530.86 MWD+IFR-AK-CAZ-SC (5) 6,912.78 71.22 267.32 3,953.20 3,823.48 706.12 -4,571.88 5,949,699.24 483,155.91 1.01 4,616.02 MWD+IFR-AK-CAZ-SC (5) 6,957.34 71.25 267.20 3,967.53 3,837.81 704.10 -4,614.02 5,949,697.29 483,113.77 0.26 4,657.83 MWD+IFR-AK-CAZ-SC (5) 7,009.44 71.66 267.67 3,984.10 3,854.38 701.89 -4,663.37 5,949,695.16 483,064.43 1.16 4,706.80 MWD+IFR-AK-CAZ-SC (5) 7,103.00 71.26 269.29 4,013.85 3,884.13 699.54 -4,752.04 5,949,692.95 482,975.76 1.70 4,794.92 MWD+IFR-AK-CAZ-SC (5) 7,197.93 71.20 269.78 4,044.40 3,914.68 698.81 -4,841.92 5,949,692.37 482,885.89 0.49 4,884.40 MWD+IFR-AK-CAZ-SC (5) 7,290.88 71.27 270.80 4,074.30 3,944.58 699.25 -4,929.92 5,949,692.96 482,797.89 1.04 4,972.11 MWD+IFR-AK-CAZ-SC (5) 7,384.99 71.08 270.15 4,104.67 3,974.95 699.99 -5,018.99 5,949,693.84 482,708.83 0.68 5,060.90 MWD+IFR-AK-CAZ-SC (5) 7,478.31 71.23 270.59 4,134.81 4,005.09 700.56 -5,107.31 5,949,694.56 482,620.53 0.47 5,148.93 MWD+IFR-AK-CAZ-SC (5) 7,569.15 71.14 269.71 4,164.11 4,034.39 700.79 -5,193.29 5,949,694.92 482,534.55 0.92 5,234.61 MWD+IFR-AK-CAZ-SC (5) 1/9/2017 9:26:48AM Page 4 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,661.91 71.11 269.10 4,194.12 4,064.40 699.87 -5,281.06 5,949,694.16 482,446.79 0.62 5,321.96 MWD+IFR-AK-CAZ-SC (5) 7,755.49 71.17 268.69 4,224.37 4,094.65 698.17 -5,369.60 5,949,692.59 482,358.26 0.42 5,410.02 MWD+IFR-AK-CAZ-SC (5) 7,846.67 71.45 268.34 4,253.58 4,123.86 695.93 -5,455.94 5,949,690.50 482,271.92 0.48 5,495.84 MWD+IFR-AK-CAZ-SC (5) 7,939.53 71.54 267.04 4,283.06 4,153.34 692.38 -5,543.93 5,949,687.09 482,183.94 1.33 5,583.18 MWD+IFR-AK-CAZ-SC (5) 8,035.39 71.64 266.52 4,313.33 4,183.61 687.27 -5,634.74 5,949,682.13 482,093.13 0.53 5,673.20 MWD+IFR-AK-CAZ-SC (5) 8,127.56 71.63 266.74 4,342.37 4,212.65 682.13 -5,722.06 5,949,677.13 482,005.81 0.23 5,759.74 MWD+IFR-AK-CAZ-SC (5) 8,221.67 71.72 267.87 4,371.96 4,242.24 677.93 -5,811.30 5,949,673.08 481,916.57 1.14 5,848.27 MWD+IFR-AK-CAZ-SC (5) 8,315.83 71.75 268.72 4,401.47 4,271.75 675.27 -5,900.67 5,949,670.56 481,827.20 0.86 5,937.07 MWD+IFR-AK-CAZ-SC (5) 8,408.12 71.81 269.01 4,430.33 4,300.61 673.53 -5,988.32 5,949,668.97 481,739.56 0.31 6,024.24 MWD+IFR-AK-CAZ-SC (5) 8,504.21 71.76 270.79 4,460.37 4,330.65 673.37 -6,079.59 5,949,668.96 481,648.30 1.76 6,115.14 MWD+IFR-AK-CAZ-SC (5) 8,597.08 71.25 270.57 4,489.83 4,360.11 674.42 -6,167.66 5,949,670.15 481,560.24 0.59 6,202.97 MWD+IFR-AK-CAZ-SC (5) 8,690.85 71.17 271.02 4,520.03 4,390.31 675.65 -6,256.42 5,949,671.52 481,471.49 0.46 6,291.50 MWD+IFR-AK-CAZ-SC (5) 8,784.82 71.14 269.83 4,550.39 4,420.67 676.31 -6,345.35 5,949,672.33 481,382.57 1.20 6,380.15 MWD+IFR-AK-CAZ-SC (5) 8,877.59 71.17 268.91 4,580.35 4,450.63 675.34 -6,433.14 5,949,671.51 481,294.79 0.94 6,467.52 MWD+IFR-AK-CAZ-SC (5) 8,968.63 71.28 268.47 4,609.65 4,479.93 673.37 -6,519.31 5,949,669.68 481,208.62 0.47 6,553.19 MWD+IFR-AK-CAZ-SC (5) 9,065.21 71.78 267.22 4,640.25 4,510.53 669.93 -6,610.65 5,949,666.38 481,117.09 1.33 6,644.08 MWD+IFR-AK-CAZ-SC (5) 9,159.14 72.07 267.85 4,669.39 4,539.67 666.09 -6,700.06 5,949,662.68 481,027.88 0.71 6,732.62 MWD+IFR-AK-CAZ-SC (5) 9,251.99 71.58 269.19 4,698.36 4,568.64 663.81 -6,788.25 5,949,660.55 480,939.70 1.47 6,820.27 MWD+IFR-AK-CAZ-SC (5) 9,346.26 71.56 268.24 4,728.15 4,598.43 661.80 -6,877.66 5,949,658.69 480,850.29 0.96 6,909.17 MWD+IFR-AK-CAZ-SC (5) 9,438.83 71.13 267.82 4,757.74 4,628.02 658.79 -6,965.32 5,949,655.82 480,762.63 0.65 6,996.24 MWD+IFR-AK-CAZ-SC (5) 9,531.83 71.12 267.14 4,787.83 4,658.11 654.92 -7,053.24 5,949,652.09 480,674.72 0.69 7,083.48 MWD+IFR-AK-CAZ-SC (5) 9,623.83 71.02 267.31 4,817.67 4,687.95 650.70 -7,140.16 5,949,648.02 480,587.80 0.21 7,169.70 MWD+IFR-AK-CAZ-SC (5) 9,718.47 70.98 266.57 4,848.49 4,718.77 645.93 -7,229.52 5,949,643.39 480,498.45 0.74 7,258.30 MWD+IFR-AK-CAZ-SC (5) 9,809.76 71.09 266.89 4,878.15 4,748.43 641.00 -7,315.71 5,949,638.61 480,412.25 0.35 7,343.74 MWD+IFR-AK-CAZ-SC (5) 9,903.84 70.98 267.47 4,908.73 4,779.01 636.62 -7,404.57 5,949,634.38 480,323.39 0.59 7,431.88 MWD+IFR-AK-CAZ-SC (5) 9,997.82 71.09 268.89 4,939.27 4,809.55 633.80 -7,493.40 5,949,631.70 480,234.56 1.43 7,520.13 MWD+IFR-AK-CAZ-SC (5) 10,089.68 70.92 269.44 4,969.17 4,839.45 632.54 -7,580.25 5,949,630.57 480,147.72 0.60 7,606.54 MWD+IFR-AK-CAZ-SC (5) 10,182.83 71.19 269.44 4,999.41 4,869.69 631.67 -7,668.35 5,949,629.86 480,059.63 0.29 7,694.23 MWD+IFR-AK-CAZ-SC (5) 10,276.05 71.08 270.77 5,029.56 4,899.84 631.84 -7,756.56 5,949,630.16 479,971.43 1.36 7,782.11 MWD+IFR-AK-CAZ-SC (5) 10,369.80 71.05 270.71 5,059.98 4,930.26 632.98 -7,845.23 5,949,631.45 479,882.77 0.07 7,870.55 MWD+IFR-AK-CAZ-SC (5) 10,462.79 71.01 271.35 5,090.21 4,960.49 634.56 -7,933.16 5,949,633.18 479,794.86 0.65 7,958.27 MWD+IFR-AK-CAZ-SC (5) 10,555.27 70.55 272.70 5,120.65 4,990.93 637.65 -8,020.43 5,949,636.40 479,707.60 1.47 8,045.48 MWD+IFR-AK-CAZ-SC (5) 10,649.22 70.54 272.25 5,151.94 5,022.22 641.47 -8,108.93 5,949,640.37 479,619.12 0.45 8,133.98 MWD+IFR-AK-CAZ-SC (5) 10,742.54 70.50 272.15 5,183.06 5,053.34 644.85 -8,196.84 5,949,643.89 479,531.22 0.11 8,221.85 MWD+IFR-AK-CAZ-SC (5) 10,836.68 70.60 272.22 5,214.41 5,084.69 648.23 -8,285.54 5,949,647.42 479,442.53 0.13 8,310.51 MWD+IFR-AK-CAZ-SC (5) 10,931.44 70.57 272.60 5,245.91 5,116.19 651.99 -8,374.84 5,949,651.32 479,353.25 0.38 8,399.79 MWD+IFR-AK-CAZ-SC (5) 11,023.86 70.48 272.94 5,276.72 5,147.00 656.20 -8,461.87 5,949,655.68 479,266.24 0.36 8,486.86 MWD+IFR-AK-CAZ-SC (5) 11,116.07 70.34 273.36 5,307.64 5,177.92 660.98 -8,548.61 5,949,660.59 479,179.51 0.46 8,573.69 MWD+IFR-AK-CAZ-SC (5) 11,208.43 70.61 273.18 5,338.51 5,208.79 665.94 -8,635.52 5,949,665.70 479,092.62 0.35 8,660.70 MWD+IFR-AK-CAZ-SC (5) 11,301.45 70.54 272.20 5,369.45 5,239.73 670.06 -8,723.14 5,949,669.96 479,005.01 1.00 8,748.35 MWD+IFR-AK-CAZ-SC (5) 1/9/2017 9:2648AM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) V) V) (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 11,393.69 70.57 271.41 5,400.15 5,270.43 672.80 -8,810.08 5,949,672.84 478,918.09 0.81 8,835.19 MWD+IFR-AK-CAZ-SC (5) 11,487.55 70.57 269.90 5,431.38 5,301.66 673.81 -8,898.58 5,949,673.99 478,829.59 1.52 8,923.45 MWD+IFR-AK-CAZ-SC (5) 11,581.15 70.54 269.81 5,462.54 5,332.82 673.59 -8,986.84 5,949,673.91 478,741.34 0.10 9,011.35 MWD+IFR-AK-CAZ-SC (5) 11,673.66 70.57 269.48 5,493.33 5,363.61 673.05 -9,074.08 5,949,673.52 478,654.12 0.34 9,098.21 MWD+IFR-AK-CAZ-SC (5) 11,765.97 70.63 269.78 5,524.00 5,394.28 672.48 -9,161.14 5,949,673.10 478,567.06 0.31 9,184.89 MWD+IFR-AK-CAZ-SC (5) 11,859.09 70.60 270.30 5,554.90 5,425.18 672.54 -9,248.98 5,949,673.30 478,479.23 0.53 9,272.40 MWD+IFR-AK-CAZ-SC (5) 11,952.57 70.60 270.54 5,585.95 5,456.23 673.19 -9,337.15 5,949,674.09 478,391.07 0.24 9,360.29 MWD+IFR-AK-CAZ-SC (5) 12,045.20 70.53 270.99 5,616.78 5,487.06 674.36 -9,424.50 5,949,675.40 478,303.73 0.46 9,447.41 MWD+IFR-AK-CAZ-SC (5) 12,136.77 70.60 271.85 5,647.24 5,517.52 676.50 -9,510.82 5,949,677.68 478,217.42 0.89 9,533.59 MWD+IFR-AK-CAZ-SC (5) 12,230.08 70.76 272.57 5,678.12 5,548.40 679.89 -9,598.81 5,949,681.22 478,129.45 0.75 9,621.54 MWD+IFR-AK-CAZ-SC (5) 12,322.45 70.53 272.54 5,708.73 5,579.01 683.78 -9,685.87 5,949,685.24 478,042.40 0.25 9,708.61 MWD+IFR-AK-CAZ-SC (5) 12,377.53 70.52 273.12 5,727.09 5,597.37 686.34 -9,737.74 5,949,687.89 477,990.54 0.99 9,760.50 MWD+IFR-AK-CAZ-SC (5) 12,442.00 70.47 273.38 5,748.62 5,618.90 689.79 -9,798.41 5,949,691.44 477,929.88 0.39 9,821.24 INC+TREND (6) 9-518" x 12-1/4" 12,461.04 70.45 273.46 5,754.99 5,625.27 690.86 -9,816.32 5,949,692.54 477,911.98 0.39 9,839.18 INC+TREND (6) 12,553.02 70.60 273.84 5,785.66 5,655.94 696.38 -9,902.86 5,949,698.20 477,825.45 0.42 9,925.87 MWD+IFR-AK-CAZ-SC (7) 12,645.96 70.77 273.83 5,816.40 5,686.68 702.25 -9,990.37 5,949,704.21 477,737.96 0.18 10,013.56 MWD+IFR-AK-CAZ-SC (7) 12,738.26 70.77 274.59 5,846.80 5,717.08 708.64 -10,077.29 5,949,710.75 477,651.06 0.78 10,100.70 MWD+IFR-AK-CAZ-SC (7) 12,831.51 70.81 276.83 5,877.48 5,747.76 717.40 -10,164.90 5,949,719.65 477,563.47 2.27 10,188.75 MWD+IFR-AK-CAZ-SC (7) 12,924.41 71.23 277.91 5,907.70 5,777.98 728.67 -10,252.02 5,949,731.06 477,476.38 1.19 10,276.52 MWD+IFR-AK-CAZ-SC (7) 13,018.65 72.94 278.87 5,936.69 5,806.97 741.76 -10,340.73 5,949,744.29 477,387.70 2.06 10,366.03 MWD+IFR-AK-CAZ-SC (7) 13,113.03 75.58 277.56 5,962.29 5,832.57 754.73 -10,430.63 5,949,757.41 477,297.83 3.10 10,456.72 MWD+IFR-AK-CAZ-SC (7) 13,206.62 78.19 278.03 5,983.52 5,853.80 767.10 -10,520.93 5,949,769.92 477,207.56 2.83 10,547.75 MWD+IFR-AK-CAZ-SC (7) 13,301.65 80.81 277.74 6,000.84 5,871.12 779.91 -10,613.48 5,949,782.88 477,115.05 2.77 10,641.06 MWD+IFR-AK-CAZ-SC (7) 13,395.34 83.55 278.86 6,013.59 5,883.87 793.31 -10,705.31 5,949,796.43 477,023.24 3.16 10,733.72 MWD+IFR-AK-CAZ-SC (7) 13,489.19 85.07 279.11 6,022.89 5,893.17 807.90 -10,797.55 5,949,811.16 476,931.04 1.64 10,826.88 MWD+IFR-AK-CAZ-SC (7) 13,582.08 85.30 279.73 6,030.69 5,900.97 823.05 -10,888.86 5,949,826.46 476,839.76 0.71 10,919.16 MWD+IFR-AK-CAZ-SC (7) 13,677.07 85.24 279.61 6,038.52 5,908.80 838.95 -10,982.19 5,949,842.51 476,746.47 0.14 11,013.51 MWD+IFR-AK-CAZ-SC (7) 13,769.85 85.59 280.00 6,045.94 5,916.22 854.70 -11,073.32 5,949,858.41 476,655.37 0.56 11,105.67 MWD+IFR-AK-CAZ-SC (7) 13,826.19 85.53 279.31 6,050.30 5,920.58 864.12 -11,128.69 5,949,867.92 476,600.02 1.23 11,161.66 MWD+IFR-AK-CAZ-SC (7) 13,894.00 87.00 280.09 6,054.72 5,925.00 875.52 -11,195.39 5,949,879.43 476,533.35 2.45 11,229.09 MWD+IFR-AK-CAZ-SC (8) 7" x 8-3/4" 13,924.48 87.66 280.44 6,056.14 5,926.42 880.95 -11,225.35 5,949,884.90 476,503.40 2.45 11,259.41 MWD+IFR-AK-CAZ-SC (8) 13,995.70 89.21 281.85 6,058.08 5,928.36 894.71 -11,295.19 5,949,898.78 476,433.58 2.94 11,330.19 MWD+IFR-AK-CAZ-SC (8) 14,089.77 90.00 280.42 6,058.73 5,929.01 912.87 -11,387.49 5,949,917.09 476,341.33 1.74 11,423.72 MWD+IFR-AK-CAZ-SC (8) 14,184.17 93.35 278.69 6,055.97 5,926.25 928.53 -11,480.52 5,949,932.90 476,248.33 3.99 11,517.76 MWD+IFR-AK-CAZ-SC (8) 14,280.73 90.52 278.54 6,052.71 5,922.99 942.99 -11,575.93 5,949,947.51 476,152.96 2.93 11,614.07 MWD+IFR-AK-CAZ-SC (8) 14,373.56 90.13 276.21 6,052.18 5,922.46 954.90 -11,667.98 5,949,959.57 476,060.93 2.54 11,706.81 MWD+IFR-AK-CAZ-SC (8) 14,469.51 90.35 275.98 6,051.78 5,922.06 965.09 -11,763.39 5,949,969.92 475,965.55 0.33 11,802.74 MWD+IFR-AK-CAZ-SC (8) 14,564.58 89.31 270.69 6,052.06 5,922.34 970.62 -11,858.26 5,949,975.60 475,870.70 5.67 11,897.73 MWD+IFR-AK-CAZ-SC (8) 1/9/2017 9:26 48AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 210-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 210-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 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 14,658.82 89.14 267.63 6,053.34 5,923.62 969.24 -11,952.47 5,949,974.37 475,776.49 3.25 11,991.46 MWD+IFR-AK-CAZ-SC (8) 14,753.11 88.37 265.54 6,055.39 5,925.67 963.62 -12,046.57 5,949,968.91 475,682.40 2.36 12,084.71 MWD+IFR-AK-CAZ-SC (8) 14,848.52 89.24 271.53 6,057.38 5,927.66 961.19 -12,141.88 5,949,966.63 475,587.09 6.34 12,179.45 MWD+IFR-AK-CAZ-SC (8) 14,943.47 85.54 271.55 6,061.70 5,931.98 963.74 -12,236.68 5,949,969.33 475,492.31 3.90 12,274.11 MWD+IFR-AK-CAZ-SC (8) 15,039.09 84.16 272.16 6,070.29 5,940.57 966.82 -12,331.86 5,949,972.57 475,397.14 1.58 12,369.20 MWD+IFR-AK-CAZ-SC (8) 15,134.04 87.82 273.94 6,076.93 5,947.21 971.86 -12,426.43 5,949,977.77 475,302.59 4.28 12,463.84 MWD+IFR-AK-CAZ-SC (8) 15,227.36 89.10 279.06 6,079.43 5,949.71 982.42 -12,519.08 5,949,988.47 475,209.97 5.65 12,557.06 MWD+IFR-AK-CAZ-SC (8) 15,323.43 87.59 282.46 6,082.21 5,952.49 1,000.34 -12,613.40 5,950,006.55 475,115.68 3.87 12,652.59 MWD+IFR-AK-CAZ-SC (8) 15,417.62 89.82 286.32 6,084.34 5,954.62 1,023.74 -12,704.59 5,950,030.09 475,024.54 4.73 12,745.47 MWD+IFR-AK CAZSC (8) 15,512.41 89.30 286.97 6,085.07 5,955.35 1,050.89 -12,795.41 5,950,057.39 474,933.78 0.88 12,838.31 MWD+IFR-AK-CAZ-SC (8) 15,608.70 92.62 285.80 6,083.45 5,953.73 1,078.04 -12,887.76 5,950,084.69 474,841.48 3.66 12,932.68 MWD+IFR-AK-CAZ-SC (8) 15,702.03 94.09 284.88 6,077.99 5,948.27 1,102.69 -12,977.61 5,950,109.48 474,751.68 1.86 13,024.33 MWD+IFR-AK-CAZ-SC (8) 15,798.24 94.04 282.29 6,071.17 5,941.45 1,125.23 -13,070.88 5,950,132.17 474,658.45 2.69 13,119.21 MWD+IFR-AK-CAZ-SC (8) 15,893.10 91.33 280.97 6,066.73 5,937.01 1,144.33 -13,163.68 5,950,151.42 474,565.69 3.18 13,213.32 MWD+IFR-AK-CAZ-SC (8) 15,987.17 92.12 277.12 6,063.89 5,934.17 1,159.11 -13,256.52 5,950,166.35 474,472.89 4.18 13,307.10 MWD+IFR-AK-CAZ-SC (8) 16,083.35 93.08 272.27 6,059.53 5,929.81 1,166.97 -13,352.25 5,950,174.37 474,377.18 5.14 13,403.15 MWD+IFR-AK-CAZ-SC (8) 16,177.21 93.15 270.79 6,054.43 5,924.71 1,169.48 -13,445.94 5,950,177.02 474,283.51 1.58 13,496.70 MWD+IFR-AK-CAZ-SC (8) 16,273.77 92.95 270.48 6,049.29 5,919.57 1,170.54 -13,542.35 5,950,178.25 474,187.10 0.38 13,592.84 MWD+IFR-AK-CAZ-SC (8) 16,367.19 93.08 270.35 6,044.38 5,914.66 1,171.22 -13,635.64 5,950,179.08 474,093.83 0.20 13,685.83 MWD+IFR-AK-CAZSC (8) 16,463.12 93.32 271.48 6,039.02 5,909.30 1,172.75 -13,731.41 5,950,180.76 473,998.07 1.20 13,781.37 MWD+IFR-AK-CAZ-SC (8) 16,552.98 90.64 270.40 6,035.92 5,906.20 1,174.22 -13,821.19 5,950,182.38 473,908.30 3.22 13,870.94 MWD+IFR-AK-CAZ-SC (8) 16,644.61 91.57 272.83 6,034.15 5,904.43 1,176.80 -13,912.76 5,950,185.11 473,816.74 2.84 13,962.38 MWD+IFR-AK-CAZ-SC (8) 16,737.91 89.81 271.54 6,033.03 5,903.31 1,180.36 -14,005.98 5,950,188.82 473,723.54 2.34 14,055.56 MWD+IFR-AK-CAZ-SC (8) 16,828.16 89.81 274.77 6,033.33 5,903.61 1,185.33 -14,096.08 5,950,193.93 473,633.46 3.58 14,145.75 MWD+IFR-AK-CAZSC (8) 16,920.63 87.66 276.02 6,035.37 5,905.65 1,194.02 -14,188.11 5,950,202.77 473,541.45 2.69 14,238.19 MWD+IFR-AK-CAZ-SC (8) 17,012.31 89.11 278.73 6,037.95 5,908.23 1,205.78 -14,278.99 5,950,214.68 473,450.60 3.35 14,329.74 MWD+IFR-AK-CAZ-SC (8) 17,105.17 87.24 277.18 6,040.91 5,911.19 1,218.62 -14,370.90 5,950,227.68 473,358.72 2.62 14,422.42 MWD+IFR-AK-CAZ-SC (8) 17,198.99 91.57 279.69 6,041.88 5,912.16 1,232.38 -14,463.67 5,950,241.58 473,265.98 5.33 14,516.04 MWD+IFR-AK-CAZ-SC (8) 17,289.10 91.30 278.41 6,039.63 5,909.91 1,246.55 -14,552.63 5,950,255.90 473,177.05 1.45 14,605.90 MWD+IFR-AK-CAZ-SC (8) 17,381.93 90.48 278.67 6,038.18 5,908.46 1,260.34 -14,644.42 5,950,269.83 473,085.30 0.93 14,698.54 MWD+IFR-AK-CAZ-SC (8) 17,447.91 89.96 279.40 6,037.93 5,908.21 1,270.70 -14,709.58 5,950,280.30 473,020.16 1.36 14,764.35 MWD+IFR-AK-CAZ-SC (8) 17,484.00 89.96 279.40 6,037.96 5,908.24 1,276.59 -14,745.18 5,950,286.25 472,984.57 0.00 14,800.34 4 1/2" x 6-1/8" 17,510.00 89.96 279.40 6,037.97 5,908.25 1,280.84 -14,770.83 5,950,290.54 472,958.93 0.00 14,826.26 PROJECTED to TD 1/9/2017 9.26:48AM Page 7 COMPASS 5000.1 Build 74 Cement Detail Report 2M-37 String: Surface Casing Cement Job: DRILLING ORIGINAL, 11/21/201610:30 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 11/27/2016 17:45 11/27/2016 23:00 2M-37 Comment PJSM, Pumped 5 bbls CW -100 and tested cement lines to 3500 psi followed by 35 bbls of CW -100, pumped 70.9 bbls of Mud Push 10.5 ppg, droped bottom plug followed by 514 bbls of Deep Crete 11.0 ppg lead cement, batched up and pumped 70 bbls of 12.0 ppg tail cement, dropped top plug with 10 bbls of water, switched over to rig and displaced with 7 bpm with 400 psi folowed by 3 bpm for last 10 bbls and bumped plug with calculated strokes 4459. P/U to 1200 psi and held for 5 mins, bled off psi and checked flaots good. Got back 230 bbls of cement to surface. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return. Vol Cement... Top Plug? Btm Plug? Surface Casing Cement Cement 16" OH x 13-3/8 32.0 3,160.0 Yes 230.0 No Yes Annular Volume Q Pump Init (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) 5 7 5 750.0 800.0 Yes 15.00 No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 3,069.0 Drill Bit Comment Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 32.0 2,651.0 1,465 G 514.0 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.97 7.09 11.00 45.7 8.38 Additives Additive Type Concentration Cone Unit label D186 Accelerator 0.1 gal/sx Additive Type Concentration Cone Unit label D046 Antifoam 0.2 %BWOB Additive Type Concentration Cone Unit label D185 Dispersant 0.01 gal/sx Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,651.0 3,151.0 239 G 70.1 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) 1.64 5.57 12.00 231.6 5.22 Additives Additive Type Concentration Cone Unit label D186 Accelerator 0.1 gal/sx Additive Type Concentration Cone Unit label D046 Antifoam 0.2 %BWOB Additive Type Concentration Cone Unit label D185 Dispersant 0.25 gal/sx Additive Type ConcentrationCone Unit label D255 Fluid Loss 1 0.3 %BWOB Page 1/1 Report Printed: 2/2/2017 Cement Detail Report 2M-37 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 11/21/2016 10:30 Cement Details Description Intermediate Casing Cement Cementing Start Date 12/11/2016 13:00 Cementing End Date 12/10/2016 17:15 Wellbore Name 2M-37 Comment Cement Stages Stage # 1 Description Intermediate Casing10,200.0 Cement Objective Top Depth (ftKB) Bottom Depth (ftKB) 12,450.0 Full Return? Yes Vol Cement... Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m... 3 Q Pump Fin7T; p Avg (bbl/... 6 P Pump Final (psi) 700.0 P Plug Bump (psi) Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) thod Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Pre Flush Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Yield (ft°/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 10,200.0 Est Btm (ftKB) 12,432.0 Amount (sacks) 832 Class Volume G Pumped (bbl) 172.0 Yield (ft'/sack) 1.161 Mix H2O Ratio (gal/sa... 5.06 Free Water (%) Density (Ib/gal) Plastic 15.60 Viscosity (Pa -s) Thickening Time (hr) CmprStr 4.90 1 (psi) Additives Additive D167 Type Concentration 0.4 Cone Unit label gal/sx Additive D-177 Type Concentration 0.035 Cone Unit label Additive D-46 Type Concentration 0.2 Cone Unit label %BWOC Additive D-65 Type 1 Concentration 1 0.25 Cone Unit label %BWOC Page 1/1 Report Printed: 2/2/2017 y Cement Detail Report 2M-37 String: Liner Cement Job: DRILLING ORIGINAL, 11/21/201610:30 Cement Details Description Liner Cement Cementing Start Date 12/19/2016 02:40 Cementing End Date 12/19/2016 04:57 Wellbore Name 2M-37 Comment Cement Stages Stage # <Stage Number?> Description Liner Cement Objective 1 Top Depth (ftKB) 12,243.5 Bottom Depth (ftKB) 13,894.0 Full Return? Yes Vol Cement... 15.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m...Q 3 Pump Final (bbl/... 3 Q Pump Avg (bbl/... 6 P Pump Final (psi) 700.0 P Plug Bump (psi) 1,500.0 Recip? No Stroke (ft) I Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Cement Fluids & Additives Fluid Fluid Type Pre Flush Fluid Description Estimated Top (ftKB) 0.0 Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) 40.0 Yield (ft /sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) 8.40 Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type MudPush II Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Ciass Volume Pumped (bbl) 45.9 Yield (ft/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Ib/gal) 13.00 Plastic Viscosity (Pa -s) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 12,243.5 Est Btm (ftKB) 13,894.0 Amount (sacks) 526 Class G Volume Pumped (bbl) 108.6 Yield (ft/sack) 1.16 Mix H2O Ratio (gal/sa... 5.10 Free Water (%) Density (Ib/gal) 15.80 Plastic Viscosity (Pa -s) Thickening Time (hr) 0.00 CmprStr 1 (psi) Additives Additive D167 Type Concentration 0.4 Cone Unit label %BWOC Additive D177 Type Concentration 0.04 Cone Unit label gal/sx Additive D46 Type Concentration 0.2 Cone Unit label %BWOC Additive D65 Type 1 Concentration 0.25 Cone Unit label %BWOC Page 1/1 Report Printed: 2/2/2017 Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Tuesday, January 24, 2017 5:23 PM To: Loepp, Victoria T (DOA) Cc: Senden, R. Tyler Subject: Report of sustained casing pressure of OA on KRU producer 2M-37 (PTD 216-082-0) 01-24-17 Attachments: 2M-37 schematic.PNG Follow Up Flag: Follow up Flag Status: Flagged Victoria, Newly drilled KRU Gas -lifted Producer 2M-37 (PTD 216-082-0) is experiencing sustained casing pressure of the OA above the DNE of 1000psi. The well was initially put on production on January 18, 2017. There has been a repeated need for bleeding to maintain the OA below the DNE. The OA is completed with a proprietary gelled diesel product. Due to the extended nature of the continued buildup in OA pressure, it is not clear whether there is some form of communication present or if this is simply a prolonged thermal response, hampered by the gelled fluid. On January 22, the OA was allowed to rise above the DNE so that we could determine its equalization point. It has now been maintaining a pressure of—1165psi for a couple of days now, with a simultaneous gas lift IA pressure of 1300psi. 2M-37 is completed with an L-80, 68#, 13-3/8" surface casing string which has a burst rating of 5020psi. Therefore the current elevated pressure only represents —23% of burst. Over the next several days we will continue to perform repeated diagnostic bleeding and monitoring (and possibly other well intervention logging if needed) to help determine the cause of the elevated pressure. A follow-up email will be provided once a path forward has been established. Let me know if you have any questions. Attached is a schematic for reference. Kelly Lyons / Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907) 943-0170 21 6982 RECEIVED 27 9 3 5 FEB01 2017 n li p AOGCC TRANSMITTAL FROM: Sandra D. Lemke, AT007-704 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC DATA LOGGED Z /2- /201'7 P.O. Box 100360 Anchorage Pouch Mail M K. BENDER Anchorage AK 99510-0360 RE: 2M-37 DATE: 01/30/2017 Kuparuk River Unit, Alaska 2M-37 1 CD of final report w/ log images and 1 color hardcopy print each log Halliburton Surface Data Logging - End of well report for 2M-37; 12/28/2016; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one set each for wellbore. Formation Evaluation log - MD Gas ratio - MD Drilling Engineering Log - MD CD contains Final log files, End of well report, final LAS exports, log viewers Please promptly sign, scan and return electronically to Sandra. D. Lemke(a)COP.com CC: 2M-37 transmittal folder, production well files, eSearch Receipt,.. ,/: GIS -Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 R EC =1VE SchlumbergerAOGCGDrilling & Measurements MWD/LWD Log Product Delivery Customer: ConocoPhillips Alaska Dispatched To: Well No: 21VI-37 Date Dispatched: Job#: 16AKA0118 Dispatched By: 21 6082 2791 5 Transmittal #: 17JAN17-SP01 DATA LOGGED t /30/201-7 M K. BENDER AOGCC: Makana Bender 17 -Jan -17 Stephanie Pacillo Well / Product Description Hardcopy Digital Copy E -Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service VISION*Service VISION*Service VISION*Service 2" MD 2" TVD 5" MD 5" TVD x x x x x x 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 Graphics: pdf/tiff Surveys: pdf/txt x x x Please sign and email a copy to: Please sign and email a copy to: Tom. Osterkamp(cDconocophilIips.com AlaskaPTSPrintCenter(aD_slb.com Tom Osterkamp Attn: Stephanie Pacillo 907-263-4795 Received By: �t✓ 21 6982 27915 RECED'E'D !AN 17 1017 FINAL AoGcc NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-37 Definitive Survey Report 09 January, 2017 NAD 27 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 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 2M-37 Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Wellbore 2M-37 Magnetics Model Name BGGM2016 Sample Date 12/13/2016 5,948,985.74 usft 487,726.18 usft usft Declination (°) 17.73 Latitude: Longitude: Ground Level Dip Angle 80.88 70° 16' 18.575 N 150° 5' 57.364 W 102.30 usft Field Strength (nT) 57,534 Design 2M-37 Date Audit Notes: From To Map Version: 1.0 Phase: ACTUAL Tie On Depth: 27.42 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction 82.10 2M-37 Srvy 1 - SLB_INC (2M-37) (usft) (usft) (usft) (°) 136.96 27.42 000 0.00 275.00 Survey Program Date From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 82.10 82.10 2M-37 Srvy 1 - SLB_INC (2M-37) INC+TREND Inclinometer + known azi trend 11/23/2016 11:21 136.96 812.27 2M-37 Srvy 2 - SLB_GWD70 (2M-37) GYD-GC-SS Gyrodata gyro single shots 11/23/2016 11:4: 850.13 3,060.65 2M-37 Srvy 3 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/24/2016 11:4, 3,154.18 3,154.18 2M-37 Srvy 4 - SLB_Inc+Filler (2M-37) INC+TREND Inclinometer + known azi trend 11/30/2016 9:34 3,179.69 12,377.53 2M-37 Srvy 5 - SLB_MWD+GMAG (21\11-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/30/2016 9:36 12,461.04 12,461.04 2M-37 Srvy 6 - SLB_INC+Filler (2M-37) INC+TREND Inclinometer + known azi trend 12/15/2016 10:1 12,553.02 13,826.19 2M-37 Srvy 7 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/15/2016 10:1, 13,924.48 17,447.91 2M-37 Srvy 8 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/27/2016 9:3E 1/9/2017 g.26.48AM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.42 0.00 0.00 27.42 -102.30 0.00 0.00 5,948,985.74 487,726.18 0.00 0.00 UNDEFINED 82.10 1.00 253.19 82.10 -47.62 -0.14 -0.46 5,948,985.60 487,725.72 1.83 0.44 INC+TREND (1) 136.96 1.62 253.19 136.94 7.22 -0.50 -1.66 5,948,985.24 487,724.52 1.13 1.61 GYD-GC-SS (2) 168.55 1.34 258.04 168.52 38.80 -0.71 -2.45 5,948,985.04 487,723.73 0.97 2.38 GYD-GC-SS (2) 256.36 1.10 268.08 256.31 126.59 -0.95 -4.29 5,948,984.80 487,721.88 0.37 4.19 GYD-GC-SS (2) 353.37 2.06 315.89 353.29 223.57 0.27 -6.44 5,948,986.02 487,719.74 1.60 6.44 GYD-GC-SS (2) 446.75 4.53 330.22 446.51 316.79 4.68 -9.44 5,948,990.44 487,716.75 2.77 9.81 GYD-GC-SS (2) 539.10 6.96 330.28 538.39 408.67 12.71 -14.02 5,948,998.47 487,712.18 2.63 15.08 GYD-GC-SS (2) 1/9/2017 g.26.48AM Page 2 COMPASS 5000.1 Build 74 Company: NADConversion Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-37 Wellbore: 2M-37 Design: 2M-37 Survey Schlumberger Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2M-37 2M-37 Actual @ 129.72usft (Doyon 141) 2M-37 Actual @ 129.72usft (Doyon 141) True Minimum Curvature OAKEDMP2 119/2017 9:26:48AM Page 3 COMPASS 5000 1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +El -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 631.34 10.70 335.84 629.52 499.80 25.38 -20.30 5,949,011.15 487,705.92 4.15 22.44 GYD-GC-SS (2) 719.55 9.39 338.03 716.38 586.66 39.52 -26.35 5,949,025.30 487,699.90 1.55 29.69 GYD-GC-SS (2) 812.27 11.66 336.02 807.53 677.81 55.10 -32.98 5,949,040.89 487,693.29 2.48 37.66 GYD-GC-SS (2) 850.13 12.23 335.73 844.57 714.85 62.25 -36.19 5,949,048.04 487,690.10 1.51 41.47 MWD+IFR-AK-CAZ-SC (3) 945.23 15.32 335.79 936.92 807.20 82.90 -45.48 5,949,068.70 487,680.84 3.25 52.53 MWD+IFR-AK-CAZ-SC (3) 1,035.97 14.97 335.98 1,024.51 894.79 104.53 -55.17 5,949,090.35 487,671.19 0.39 64.07 MWD+IFR-AK-CAZ-SC (3) 1,130.23 15.45 334.09 1,115.47 985.75 126.95 -65.61 5,949,112.78 487,660.78 0.73 76.42 MWD+IFR-AK-CAZ-SC (3) 1,225.08 17.47 333.77 1,206.43 1,076.71 151.09 -77.42 5,949,136.94 487,649.01 2.13 90.30 MWD+IFR-AK-CAZ-SC (3) 1,317.38 20.91 334.87 1,293.59 1,163.87 178.43 -90.55 5,949,164.30 487,635.93 3.75 105.75 MWD+IFR-AK-CAZ-SC (3) 1,409.70 23.05 332.89 1,379.19 1,249.47 209.44 -105.78 5,949,195.33 487,620.75 2.45 123.63 MWD+IFR-AK-CAZ-SC (3) 1,503.43 24.00 331.83 1,465.13 1,335.41 242.58 -123.14 5,949,228.50 487,603.44 1.11 143.82 MWD+IFR-AK-CAZ-SC (3) 1,596.51 26.18 329.23 1,549.43 1,419.71 276.91 -142.59 5,949,262.86 487,584.06 2.62 166.18 MWD+IFR-AK-CAZ-SC (3) 1,689.85 27.53 327.66 1,632.70 1,502.98 312.83 -164.66 5,949,298.81 487,562.04 1.63 191.30 MWD+IFR-AK-CAZ-SC (3) 1,786.16 28.76 323.13 1,717.63 1,587.91 350.18 -190.47 5,949,336.20 487,536.30 2.56 220.27 MWD+IFR-AK-CAZ-SC (3) 1,879.92 31.24 319.94 1,798.83 1,669.11 386.84 -219.66 5,949,372.90 487,507.17 3.14 252.54 MWD+IFR-AK-CAZ-SC (3) 1,972.74 35.05 314.66 1,876.55 1,746.83 424.02 -254.13 5,949,410.13 487,472.77 5.15 290.12 MWD+IFR-AK-CAZ-SC (3) 2,065.38 37.71 309.90 1,951.14 1,821.42 460.91 -294.80 5,949,447.08 487,432.16 4.19 333.85 MWD+IFR-AK-CAZ-SC (3) 2,158.51 39.52 308.66 2,023.90 1,894.18 497.69 -339.79 5,949,483.93 487,387.23 2.11 381.88 MWD+IFR-AK-CAZ-SC (3) 2,253.18 41.94 304.24 2,095.65 1,965.93 534.32 -389.49 5,949,520.64 487,337.60 3.98 434.57 MWD+IFR-AK-CAZ-SC (3) 2,345.37 43.15 298.35 2,163.60 2,033.88 566.64 -442.72 5,949,553.04 487,284.42 4.51 490.42 MWD+IFR-AK-CAZ-SC (3) 2,439.86 45.52 294.98 2,231.19 2,101.47 596.23 -501.73 5,949,582.72 487,225.47 3.54 551.79 MWD+IFR-AK-CAZ-SC (3) 2,530.32 47.86 291.71 2,293.25 2,163.53 622.27 -562.16 5,949,608.86 487,165.09 3.69 614.25 MWD+IFR-AK-CAZ-SC (3) 2,622.67 49.04 286.56 2,354.52 2,224.80 644.88 -627.42 5,949,631.58 487,099.87 4.36 681.24 MWD+IFR-AK-CAZ-SC (3) 2,717.09 51.37 283.18 2,414.96 2,285.24 663.46 -697.52 5,949,650.27 487,029.81 3.69 752.69 MWD+IFR-AK-CAZ-SC (3) 2,808.52 54.24 281.98 2,470.23 2,340.51 679.30 -768.60 5,949,666.23 486,958.76 3.31 824.88 MWD+IFR-AK-CAZ-SC (3) 2,900.80 56.22 281.40 2,522.85 2,393.13 694.66 -842.83 5,949,681.70 486,884.57 2.21 900.16 MWD+IFR-AK-CAZ-SC (3) 2,995.44 58.18 280.34 2,574.12 2,444.40 709.65 -920.95 5,949,696.82 486,806.48 2.27 979.29 MWD+IFR-AK-CAZ-SC (3) 3,060.65 59.37 279.57 2,607.92 2,478.20 719.29 -975.87 5,949,706.55 486,751.58 2.09 1,034.85 MWD+IFR-AK-CAZ-SC (3) 3,150.00 59.83 281.09 2,653.14 2,523.42 733.11 -1,051.68 5,949,720.49 486,675.80 1.55 1,111.57 NOT an Actual Survey 1 3,154.18 59.85 281.16 2,655.24 2,525.52 733.80 -1,055.23 5,949,721.19 486,672.25 1.55 1,115.17 INC+TREND (4) 3,179.69 60.43 281.07 2,667.94 2,538.22 738.07 -1,076.94 5,949,725.49 486,650.55 2.29 1,137.17 MWD+IFR-AK-CAZ-SC (5) 3,272.74 62.09 278.79 2,712.69 2,582.97 752.12 -1,157.29 5,949,739.68 486,570.23 2.79 1,218.44 MWD+IFR-AK-CAZ-SC (5) 3,366.84 63.19 276.31 2,755.94 2,626.22 763.09 -1,240.13 5,949,750.78 486,487.41 2.62 1,301.92 MWD+IFR-AK-CAZ-SC (5) 3,460.10 64.30 273.85 2,797.20 2,667.48 770.49 -1,323.43 5,949,758.31 486,404.13 2.65 1,385.55 MWD+IFR-AK-CAZ-SC (5) 3,556.03 65.56 272.48 2,837.85 2,708.13 775.28 -1,410.19 5,949,763.24 486,317.39 1.84 1,472.39 MWD+IFR-AK-CAZ-SC (5) 3,648.96 67.19 271.82 2,875.09 2,745.37 778.47 -1,495.27 5,949,766.57 486,232.33 1.87 1,557.43 MWD+IFR-AK-CAZ-SC (5) 3,743.64 68.68 271.39 2,910.65 2,780.93 780.93 -1,582.98 5,949,769.17 486,144.64 1.63 1,645.02 MWD+IFR-AK-CAZ-SC (5) 3,835.03 70.01 271.13 2,942.89 2,813.17 782.81 -1,668.47 5,949,771.19 486,059.15 1.48 1,730.35 MWD+IFR-AK-CAZ-SC (5) 3,929.08 71.42 269.54 2,973.95 2,844.23 783.32 -1,757.23 5,949,771.85 485,970.40 2.19 1,818.82 MWD+IFR-AK-CAZ-SC (5) 119/2017 9:26:48AM Page 3 COMPASS 5000 1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 Database: OAKEDMP2 Survey 1/9/2017 9:26.48AM Page 4 COMPASS 5000.1 Build 74 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 4,023.26 71.67 269.47 3,003.76 2,874.04 782.55 -1,846.57 5,949,771.22 485,881.07 0.27 1,907.74 MWD+IFR-AK-CAZ-SC (5) 4,117.36 71.50 270.36 3,033.49 2,903.77 782.42 -1,935.85 5,949,771.24 485,791.80 0.92 1,996.67 MWD+IFR-AK-CAZ-SC (5) 4,209.95 71.64 271.20 3,062.76 2,933.04 783.61 -2,023.68 5,949,772.58 485,703.98 0.87 2,084.28 MWD+IFR-AK-CAZ-SC (5) 4,301.89 71.00 270.98 3,092.21 2,962.49 785.27 -2,110.76 5,949,774.37 485,616.91 0.73 2,171.17 MWD+IFR-AK-CAZ-SC (5) 4,394.41 71.02 269.70 3,122.32 2,992.60 785.79 -2,198.24 5,949,775.04 485,529.44 1.31 2,258.36 MWD+IFR-AK-CAZ-SC (5) 4,489.51 71.08 269.63 3,153.20 3,023.48 785.26 -2,288.19 5,949,774.66 485,439.50 0.09 2,347.92 MWD+IFR-AK-CAZ-SC (5) 4,583.50 71.05 268.20 3,183.70 3,053.98 783.58 -2,377.07 5,949,773.12 485,350.63 1.44 2,436.32 MWD+IFR-AK-CAZ-SC (5) 4,674.88 71.05 268.29 3,213.38 3,083.66 780.93 -2,463.46 5,949,770.61 485,264.24 0.09 2,522.15 MWD+IFR-AK-CAZ-SC (5) 4,770.41 70.96 266.26 3,244.47 3,114.75 776.64 -2,553.68 5,949,766.47 485,174.02 2.01 2,611.65 MWD+IFR-AK-CAZ-SC (5) 4,862.73 70.96 266.31 3,274.59 3,144.87 770.99 -2,640.76 5,949,760.96 485,086.94 0.05 2,697.91 MWD+IFR-AK-CAZ-SC (5) 4,955.39 71.03 264.99 3,304.77 3,175.05 764.34 -2,728.12 5,949,754.45 484,999.58 1.35 2,784.35 MWD+IFR-AK-CAZ-SC (5) 5,048.17 71.02 264.40 3,334.93 3,205.21 756.23 -2,815.48 5,949,746.48 484,912.22 0.60 2,870.68 MWD+IFR-AK-CAZ-SC (5) 5,139.12 70.96 263.13 3,364.56 3,234.84 746.89 -2,900.96 5,949,737.29 484,826.73 1.32 2,955.02 MWD+IFR-AK-CAZ-SC (5) 5,234.58 71.01 263.48 3,395.66 3,265.94 736.37 -2,990.59 5,949,726.91 484,737.09 0.35 3,043.39 MWD+IFR-AK-CAZ-SC (5) 5,327.67 71.66 264.60 3,425.46 3,295.74 727.21 -3,078.31 5,949,717.90 484,649.36 1.34 3,129.98 MWD+IFR-AK-CAZ-SC (5) 5,418.25 71.87 267.14 3,453.80 3,324.08 721.02 -3,164.11 5,949,711.85 484,563.56 2.67 3,214.91 MWD+IFR-AK-CAZ-SC (5) 5,513.53 70.87 269.60 3,484.25 3,354.53 718.45 -3,254.35 5,949,709.42 484,473.33 2.66 3,304.58 MWD+IFR-AK-CAZ-SC (5) 5,607.51 69.96 270.31 3,515.75 3,386.03 718.37 -3,342.89 5,949,709.49 484,384.80 1.20 3,392.78 MWD+IFR-AK-CAZ-SC (5) 5,701.67 70.81 270.93 3,547.36 3,417.64 719.34 -3,431.58 5,949,710.60 484,296.12 1.10 3,481.22 MWD+IFR-AK-CAZ-SC (5) 5,795.36 70.35 271.76 3,578.51 3,448.79 721.41 -3,519.92 5,949,712.82 484,207.79 0.97 3,569.40 MWD+IFR-AK-CAZ-SC (5) 5,887.78 70.14 271.67 3,609.75 3,480.03 724.01 -3,606.86 5,949,715.56 484,120.87 0.25 3,656.23 MWD+IFR-AK-CAZ-SC (5) 5,980.19 70.11 271.57 3,641.16 3,511.44 726.47 -3,693.73 5,949,718.16 484,034.01 0.11 3,742.99 MWD+IFR-AK-CAZ-SC (5) 6,075.29 70.14 271.33 3,673.49 3,543.77 728.73 -3,783.13 5,949,720.57 483,944.61 0.24 3,832.25 MWD+IFR-AK-CAZ-SC (5) 6,169.07 70.08 270.44 3,705.40 3,575.68 730.09 -3,871.31 5,949,722.07 483,856.45 0.89 3,920.21 MWD+IFR-AK-CAZ-SC (5) 6,261.32 70.15 270.06 3,736.78 3,607.06 730.47 -3,958.06 5,949,722.59 483,769.71 0.39 4,006.66 MWD+IFR-AK-CAZ-SC (5) 6,355.18 70.04 269.38 3,768.73 3,639.01 730.04 -4,046.31 5,949,722.31 483,681.47 0.69 4,094.54 MWD+IFR-AK-CAZ-SC (5) 6,448.04 70.16 268.31 3,800.34 3,670.62 728.28 -4,133.60 5,949,720.69 483,594.18 1.09 4,181.35 MWD+IFR-AK-CAZ-SC (5) 6,542.29 70.58 268.37 3,832.01 3,702.29 725.71 -4,222.34 5,949,718.26 483,505.45 0.45 4,269.52 MWD+IFR-AK-CAZ-SC (5) 6,635.88 70.48 266.52 3,863.20 3,733.48 721.78 -4,310.49 5,949,714.47 483,417.31 1.87 4,356.99 MWD+IFR-AK-CAZ-SC (5) 6,729.69 71.06 266.45 3,894.10 3,764.38 716.35 -4,398.89 5,949,709.19 483,328.90 0.62 4,444.59 MWD+IFR-AK-CAZ-SC (5) 6,821.90 71.20 266.35 3,923.92 3,794.20 710.87 -4,485.98 5,949,703.85 483,241.81 0.18 4,530.86 MWD+IFR-AK-CAZ-SC (5) 6,912.78 71.22 267.32 3,953.20 3,823.48 706.12 -4,571.88 5,949,699.24 483,155.91 1.01 4,616.02 MWD+IFR-AK-CAZ-SC (5) 6,957.34 71.25 267.20 3,967.53 3,837.81 704.10 -4,614.02 5,949,697.29 483,113.77 0.26 4,657.83 MWD+IFR-AK-CAZ-SC (5) 7,009.44 71.66 267.67 3,984.10 3,854.38 701.89 -4,663.37 5,949,695.16 483,064.43 1.16 4,706.80 MWD+IFR-AK-CAZ-SC (5) 7,103.00 71.26 269.29 4,013.85 3,884.13 699.54 -4,752.04 5,949,692.95 482,975.76 1.70 4,794.92 MWD+IFR-AK-CAZ-SC (5) 7,197.93 71.20 269.78 4,044.40 3,914.68 698.81 -4,841.92 5,949,692.37 482,885.89 0.49 4,884.40 MWD+IFR-AK-CAZ-SC (5) 7,290.88 71.27 270.80 4,074.30 3,944.58 699.25 -4,929.92 5,949,692.96 482,797.89 1.04 4,972.11 MWD+IFR-AK-CAZ-SC (5) 7,384.99 71.08 270.15 4,104.67 3,974.95 699.99 -5,018.99 5,949,693.84 482,708.83 0.68 5,060.90 MWD+IFR-AK-CAZ-SC (5) 7,478.31 71.23 270.59 4,134.81 4,005.09 700.56 -5,107.31 5,949,694.56 482,620.53 0.47 5,148.93 MWD+IFR-AK-CAZ-SC (5) 7,569.15 71.14 269.71 4,164.11 4,034.39 700.79 -5,193.29 5,949,694.92 482,534.55 0.92 5,234.61 MWD+IFR-AK-CAZ-SC (5) 1/9/2017 9:26.48AM Page 4 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 Database: OAKEDMP2 Survey 119/2017 9:26:48AM Page 5 COMPASS 5000.1 Build 74 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 7,661.91 71.11 269.10 4,194.12 4,064.40 699.87 -5,281.06 5,949,694.16 482,446.79 0.62 5,321.96 MWD+IFR-AK-CAZ-SC (5) 7,755.49 71.17 268.69 4,224.37 4,094.65 698.17 -5,369.60 5,949,692.59 482,358.26 0.42 5,410.02 MWD+IFR-AK-CAZ-SC (5) 7,846.67 71.45 268.34 4,253.58 4,123.86 695.93 -5,455.94 5,949,690.50 482,271.92 0.48 5,495.84 MWD+IFR-AK-CAZ-SC (5) 7,939.53 71.54 267.04 4,283.06 4,153.34 692.38 -5,543.93 5,949,687.09 482,183.94 1.33 5,583.18 MWD+IFR-AK-CAZ-SC (5) 8,035.39 71.64 266.52 4,313.33 4,183.61 687.27 -5,634.74 5,949,682.13 482,093.13 0.53 5,673.20 MWD+IFR-AK-CAZ-SC (5) 8,127.56 71.63 266.74 4,342.37 4,212.65 682.13 -5,722.06 5,949,677.13 482,005.81 0.23 5,759.74 MWD+IFR-AK-CAZ-SC (5) 8,221.67 71.72 267.87 4,371.96 4,242.24 677.93 -5,811.30 5,949,673.08 481,916.57 1.14 5,848.27 MWD+IFR-AK-CAZ-SC (5) 8,315.83 71.75 268.72 4,401.47 4,271.75 675.27 -5,900.67 5,949,670.56 481,827.20 0.86 5,937.07 MWD+IFR-AK-CAZ-SC (5) 8,408.12 71.81 269.01 4,430.33 4,300.61 673.53 -5,988.32 5,949,668.97 481,739.56 0.31 6,024.24 MWD+IFR-AK-CAZ-SC (5) 8,504.21 71.76 270.79 4,460.37 4,330.65 673.37 -6,079.59 5,949,668.96 481,648.30 1.76 6,115.14 MWD+IFR-AK-CAZ-SC (5) 8,597.08 71.25 270.57 4,489.83 4,360.11 674.42 -6,167.66 5,949,670.15 481,560.24 D.59 6,202.97 MWD+IFR-AK-CAZ-SC (5) 8,690.85 71.17 271.02 4,520.03 4,390.31 675.65 -6,256.42 5,949,671.52 481,471.49 0.46 6,291.50 MWD+IFR-AK-CAZ-SC (5) 8,784.82 71.14 269.83 4,550.39 4,420.67 676.31 -6,345.35 5,949,672.33 481,382.57 1.20 6,380.15 MWD+IFR-AK-CAZ-SC (5) 8,877.59 71.17 268.91 4,580.35 4,450.63 675.34 -6,433.14 5,949,671.51 481,294.79 0.94 6,467.52 MWD+IFR-AK-CAZ-SC (5) 8,968.63 71.28 268.47 4,609.65 4,479.93 673.37 -6,519.31 5,949,669.68 481,208.62 0.47 6,553.19 MWD+IFR-AK-CAZ-SC (5) 9,065.21 71.78 267.22 4,640.25 4,510.53 669.93 -6,610.85 5,949,666.38 481,117.09 1.33 6,644.08 MWD+IFR-AK-CAZ-SC (5) 9,159.14 72.07 267.85 4,669.39 4,539.67 666.09 -6,700.06 5,949,662.68 481,027.88 0.71 6,732.62 MWD+IFR-AK-CAZ-SC (5) 9,251.99 71.58 269.19 4,698.36 4,568.64 663.81 -6,788.25 5,949,660.55 480,939.70 1.47 6,820.27 MWD+IFR-AK-CAZ-SC (5) 9,346.26 71.58 268.24 4,728.15 4,598.43 661.80 -6,877.66 5,949,658.69 480,850.29 0.96 6,909.17 MWD+IFR-AK-CAZ-SC (5) 9,438.83 71.13 267.82 4,757.74 4,628.02 658.79 -6,965.32 5,949,655.82 480,762.63 0.65 6,996.24 MWD+IFR-AK-CAZ-SC (5) 9,531.83 71.12 267.14 4,787.83 4,658.11 654.92 -7,053.24 5,949,652.09 480,674.72 0.69 7,083.48 MWD+IFR-AK-CAZ-SC (5) 9,623.83 71.02 267.31 4,817.67 4,687.95 650.70 -7,140.16 5,949,648.02 480,587.80 0.21 7,169.70 MWD+IFR-AK-CAZ-SC (5) 9,718.47 70.98 266.57 4,848.49 4,718.77 645.93 -7,229.52 5,949,643.39 480,498.45 0.74 7,258.30 MWD+IFR-AK-CAZ-SC (5) 9,809.76 71.09 266.89 4,878.15 4,746.43 641.00 -7,315.71 5,949,638.61 480,412.25 0.35 7,343.74 MWD+IFR-AK-CAZ-SC (5) 9,903.84 70.98 267.47 4,908.73 4,779.01 636.62 -7,404.57 5,949,634.38 480,323.39 0.59 7,431.88 MWD+IFR-AK-CAZ-SC (5) 9,997.82 71.09 268.89 4,939.27 4,809.55 633.80 -7,493.40 5,949,631.70 480,234.56 1.43 7,520.13 MWD+IFR-AK-CAZ-SC (5) 10,089.68 70.92 269.44 4,969.17 4,839.45 632.54 -7,580.25 5,949,630.57 480,147.72 0.60 7,606.54 MWD+IFR-AK-CAZ-SC (5) 10,182.83 71.19 269.44 4,999.41 4,869.69 631.67 -7,668.35 5,949,629.86 480,059.63 0.29 7,694.23 MWD+IFR-AK-CAZ-SC (5) 10,276.05 71.08 270.77 5,029.56 4,899.84 631.84 -7,756.56 5,949,630.16 479,971.43 1.36 7,782.11 MWD+IFR-AK-CAZ-SC (5) 10,369.80 71.05 270.71 5,059.98 4,930.26 632.98 -7,845.23 5,949,631.45 479,882.77 0.07 7,870.55 MWD+IFR-AK-CAZ-SC (5) 10,462.79 71.01 271.35 5,090.21 4,960.49 634.56 -7,933.16 5,949,633.18 479,794.86 0.65 7,958.27 MWD+IFR-AK-CAZ-SC (5) 10,555.27 70.55 272.70 5,120.65 4,990.93 637.65 -8,020.43 5,949,636.40 479,707.60 1.47 8,045.48 MWD+IFR-AK-CAZ-SC (5) 10,649.22 70.54 272.25 5,151.94 5,022.22 641.47 -8,108.93 5,949,640.37 479,619.12 0.45 8,133.98 MWD+IFR-AK-CAZ-SC (5) 10,742.54 70.50 272.15 5,183.06 5,053.34 644.85 -8,196.84 5,949,643.89 479,531.22 0.11 8,221.85 MWD+IFR-AK-CAZ-SC (5) 10,836.68 70.60 272.22 5,214.41 5,084.69 648.23 -8,285.54 5,949,647.42 479,442.53 0.13 8,310.51 MWD+IFR-AK-CAZ-SC (5) 10,931.44 70.57 272.60 5,245.91 5,116.19 651.99 -8,374.84 5,949,651.32 479,353.25 0.38 8,399.79 MWD+IFR-AK-CAZ-SC (5) 11,023.86 70.48 272.94 5,276.72 5,147.00 656.20 -8,461.87 5,949,655.68 479,266.24 0.36 8,486.86 MWD+IFR-AK-CAZ-SC (5) 11,116.07 70.34 273.36 5,307.64 5,177.92 660.98 -8,548.61 5,949,660.59 479,179.51 0.46 8,573.69 MWD+IFR-AK-CAZ-SC (5) 11,208.43 70.61 273.18 5,338.51 5,208.79 665.94 -8,635.52 5,949,665.70 479,092.62 0.35 8,660.70 MWD+IFR-AK-CAZ-SC (5) 11,301.45 70.54 272.20 5,369.45 5,239.73 670.06 -8,723.14 5,949,669.96 479,005.01 1.00 8,748.35 MWD+IFR-AK-CAZ-SC (5) 119/2017 9:26:48AM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 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 11,393.69 70.57 271.41 5,400.15 5,270.43 672.80 -8,810.08 5,949,672.84 478,918.09 0.81 8,835.19 MWD+IFR-AK-CAZ-SC (5) 11,487.55 70.57 269.90 5,431.38 5,301.66 673.81 -8,898.58 5,949,673.99 478,829.59 1.52 8,923.45 MWD+IFR-AK-CAZ-SC (5) 11,581.15 70.54 269.81 5,462.54 5,332.82 673.59 -8,986.84 5,949,673.91 478,741.34 0.10 9,011.35 MWD+IFR-AK-CAZ-SC (5) 11,673.66 70.57 269.48 5,493.33 5,363.61 673.05 -9,074.08 5,949,673.52 478,654.12 0.34 9,098.21 MWD+IFR-AK-CAZ-SC (5) 11,765.97 70.63 269.78 5,524.00 5,394.28 672.48 -9,161.14 5,949,673.10 478,567.06 0.31 9,184.89 MWD+IFR-AK-CAZ-SC (5) 11,859.09 70.60 270.30 5,554.90 5,425.18 672.54 -9,248.98 5,949,673.30 478,479.23 0.53 9,272.40 MWD+IFR-AK-CAZ-SC (5) 11,952.57 70.60 270.54 5,585.95 5,456.23 673.19 -9,337.15 5,949,674.09 478,391.07 0.24 9,360.29 MWD+IFR-AK-CAZ-SC (5) 12,045.20 70.53 270.99 5,616.78 5,487.06 674.36 -9,424.50 5,949,675.40 478,303.73 0.46 9,447.41 MWD+IFR-AK-CAZ-SC (5) 12,136.77 70.60 271.85 5,647.24 5,517.52 676.50 -9,510.82 5,949,677.68 478,217.42 0.89 9,533.59 MWD+IFR-AK-CAZ-SC (5) 12,230.08 70.76 272.57 5,678.12 5,548.40 679.89 -9,598.81 5,949,681.22 478,129.45 0.75 9,621.54 MWD+IFR-AK-CAZ-SC (5) 12,322.45 70.53 272.54 5,708.73 5,579.01 683.78 -9,685.87 5,949,685.24 478,042.40 0.25 9,708.61 MWD+IFR-AK-CAZ-SC (5) 12,377.53 70.52 273.12 5,727.09 5,597.37 686.34 -9,737.74 5,949,687.89 477,990.54 0.99 9,760.50 MWD+IFR-AK-CAZ-SC (5) 12,442.00 70.47 273.38 5,748.62 5,618.90 689.79 -9,798.41 5,949,691.44 477,929.88 0.39 9,821.24 NOT an Actual Suey 9-5/8" x 12-1/4" 12,461.04 70.45 273.46 5,754.99 5,625.27 690.86 -9,816.32 5,949,692.54 477,911.98 0.39 9,839.18 INC+TREND (6) 12,553.02 70.60 273.84 5,785.66 5,655.94 696.38 -9,902.86 5,949,698.20 477,825.45 0.42 9,925.87 MWD+IFR-AK-CAZ-SC (7) 12,645.96 70.77 273.83 5,816.40 5,686.68 702.25 -9,990.37 5,949,704.21 477,737.96 0.18 10,013.56 MWD+IFR-AK-CAZ-SC (7) 12,738.26 70.77 274.59 5,846.80 5,717.08 708.64 -10,077.29 5,949,710.75 477,651.06 0.78 10,100.70 MWD+IFR-AK-CAZ-SC (7) 12,831.51 70.81 276.83 5,877.48 5,747.76 717.40 -10,164.90 5,949,719.65 477,563.47 2.27 10,188.75 MWD+IFR-AK-CAZ-SC (7) 12,924.41 71.23 277.91 5,907.70 5,777.98 728.67 -10,252.02 5,949,731.06 477,476.38 1.19 10,276.52 MWD+IFR-AK-CAZ-SC (7) 13,018.65 72.94 278.87 5,936.69 5,806.97 741.76 -10,340.73 5,949,744.29 477,387.70 2.06 10,366.03 MWD+IFR-AK-CAZ-SC (7) 13,113.03 75.58 277.56 5,962.29 5,832.57 754.73 -10,430.63 5,949,757.41 477,297.83 3.10 10,456.72 MWD+IFR-AK-CAZ-SC (7) 13,206.62 78.19 278.03 5,983.52 5,853.80 767.10 -10,520.93 5,949,769.92 477,207.56 2.83 10,547.75 MWD+IFR-AK-CAZ-SC (7) 13,301.65 80.81 277.74 6,000.84 5,871.12 779.91 -10,613.48 5,949,782.88 477,115.05 2.77 10,641.06 MWD+IFR-AK-CAZ-SC (7) 13,395.34 83.55 278.86 6,013.59 5,883.87 793.31 -10,705.31 5,949,796.43 477,023.24 3.16 10,733.72 MWD+IFR-AK-CAZ-SC (7) 13,489.19 85.07 279.11 6,022.89 5,893.17 807.90 -10,797.55 5,949,811.16 476,931.04 1.64 10,826.88 MWD+IFR-AK-CAZ-SC (7) 13,582.08 85.30 279.73 6,030.69 5,900.97 823.05 -10,888.86 5,949,826.46 476,839.76 0.71 10,919.16 MWD+IFR-AK-CAZ-SC (7) 13,677.07 85.24 279.61 6,038.52 5,908.80 838.95 -10,982.19 5,949,842.51 476,746.47 0.14 11,013.51 MWD+IFR-AK-CAZ-SC (7) 13,769.85 85.59 260.00 6,045.94 5,916.22 854.70 -11,073.32 5,949,858.41 476,655.37 0.56 11,105.67 MWD+IFR-AK-CAZ-SC (7) 13,826.19 85.53 279.31 6,050.30 5,920.58 864.12 -11,128.69 5,949,867.92 476,600.02 1.23 11,161.66 MWD+IFR-AK-CAZ-SC (7) 13,894.00 87.00 280.09 6,054.72 5,925.00 875.52 -11,195.39 5,949,879.43 476,533.35 2.45 11,229.09 NOT an Actual Suryey `> 7" x 8-3/4" 13,924.48 87.66 280.44 6,056.14 5,926.42 880.95 -11,225.35 5,949,884.90 476,503.40 2.45 11,259.41 MWD+IFR-AK-CAZ-SC (8) 13,995.70 89.21 261.85 6,058.08 5,928.36 894.71 -11,295.19 5,949,898.78 476,433.58 2.94 11,330.19 MWD+IFR-AK-CAZ-SC (8) 14,089.77 90.00 280.42 6,058.73 5,929.01 912.87 -11,387.49 5,949,917.09 476,341.33 1.74 11,423.72 MWD+IFR-AK-CAZ-SC (8) 14,184.17 93.35 278.69 6,055.97 5,926.25 928.53 -11,480.52 5,949,932.90 476,248.33 3.99 11,517.76 MWD+IFR-AK-CAZ-SC (8) 14,280.73 90.52 278.54 6,052.71 5,922.99 942.99 -11,575.93 5,949,947.51 476,152.96 2.93 11,614.07 MWD+IFR-AK-CAZ-SC (8) 14,373.56 90.13 276.21 6,052.18 5,922.46 954.90 -11,667.98 5,949,959.57 476,060.93 2.54 11,706.81 MWD+IFR-AK-CAZ-SC (8) 14,469.51 90.35 275.98 6,051.78 5,922.06 965.09 -11,763.39 5,949,969.92 475,965.55 0.33 11,802.74 MWD+IFR-AK-CAZ-SC (8) 14,564.58 89.31 270.69 6,052.06 5,922.34 970.62 -11,858.26 5,949,975.60 475,870.70 5.67 11,897.73 MWD+IFR-AK-CAZ-SC (8) 1/9/2017 9:26:48AM Page 6 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 Database: OAKE DM P2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 14,658.82 89.14 267.63 6,053.34 5,923.62 969.24 -11,952.47 5,949,974.37 475,776.49 3.25 11,991.46 MWD+IFR-AK-CAZ-SC (8) 14,753.11 88.37 265.54 6,055.39 5,925.67 963.62 -12,046.57 5,949,968.91 475,682.40 2.36 12,084.71 MWD+IFR-AK-CAZ-SC (8) 14,848.52 89.24 271.53 6,057.38 5,927.66 961.19 -12,141.88 5,949,966.63 475,587.09 6.34 12,179.45 MWD+IFR-AK-CAZ-SC (8) 14,943.47 85.54 271.55 6,061.70 5,931.98 963.74 -12,236.68 5,949,969.33 475,492.31 3.90 12,274.11 MWD+IFR-AK-CAZ-SC (8) 15,039.09 84.16 272.16 6,070.29 5,940.57 966.82 -12,331.86 5,949,972.57 475,397.14 1.58 12,369.20 MWD+IFR-AK-CAZ-SC (8) 15,134.04 87.82 273.94 6,076.93 5,947.21 971.86 -12,426.43 5,949,977.77 475,302.59 4.28 12,463.84 MWD+IFR-AK-CAZ-SC (8) 15,227.36 89.10 279.06 6,079.43 5,949.71 982.42 -12,519.08 5,949,988.47 475,209.97 5.65 12,557.06 MWD+IFR-AK-CAZ-SC (8) 15,323.43 87.59 282.46 6,082.21 5,952.49 1,000.34 -12,613.40 5,950,006.55 475,115.68 3.87 12,652.59 MWD+IFR-AK-CAZ-SC (8) 15,417.62 89.82 286.32 6,084.34 5,954.62 1,023.74 -12,704.59 5,950,030.09 475,024.54 4.73 12,745.47 MWD+IFR-AK-CAZ-SC (8) 15,512.41 89.30 286.97 6,085.07 5,955.35 1,050.89 -12,795.41 5,950,057.39 474,933.78 0.88 12,838.31 MWD+IFR-AK-CAZ-SC (8) 15,608.70 92.62 285.80 6,083.45 5,953.73 1,078.04 -12,887.76 5,950,084.69 474,841.48 3.66 12,932.68 MWD+IFR-AK-CAZ-SC (8) 15,702.03 94.09 284.88 6,077.99 5,948.27 1,102.69 -12,977.61 5,950,109.48 474,751.68 1.86 13,024.33 MWD+IFR-AK-CAZ-SC (8) 15,798.24 94.04 282.29 6,071.17 5,941.45 1,125.23 -13,070.88 5,950,132.17 474,658.45 2.69 13,119.21 MWD+IFR-AK-CAZ-SC (8) 15,893.10 91.33 280.97 6,066.73 5,937.01 1,144.33 -13,163.68 5,950,151.42 474,565.69 3.18 13,213.32 MWD+IFR-AK-CAZ-SC (8) 15,987.17 92.12 277.12 6,063.89 5,934.17 1,159.11 -13,256.52 5,950,166.35 474,472.89 4.18 13,307.10 MWD+IFR-AK-CAZ-SC (8) 16,083.35 93.08 272.27 6,059.53 5,929.81 1,166.97 -13,352.25 5,950,174.37 474,377.18 5.14 13,403.15 MWD+IFR-AK-CAZ-SC (8) 16,177.21 93.15 270.79 6,054.43 5,924.71 1,169.48 -13,445.94 5,950,177.02 474,283.51 1.58 13,496.70 MWD+IFR-AK-CAZ-SC (8) 16,273.77 92.95 270.48 6,049.29 5,919.57 1,170.54 -13,542.35 5,950,178.25 474,187.10 0.38 13,592.84 MWD+IFR-AK-CAZ-SC (8) 16,367.19 93.08 270.35 6,044.38 5,914.66 1,171.22 -13,635.64 5,950,179.08 474,093.83 0.20 13,685.83 MWD+IFR-AK-CAZ-SC (8) 16,463.12 93.32 271.48 6,039.02 5,909.30 1,172.75 -13,731.41 5,950,180.76 473,998.07 1.20 13,781.37 MWD+IFR-AK-CAZ-SC (8) 16,552.98 90.64 270.40 6,035.92 5,906.20 1,174.22 -13,821.19 5,950,182.38 473,908.30 3.22 13,870.94 MWD+IFR-AK-CAZ-SC (8) 16,644.61 91.57 272.83 6,034.15 5,904.43 1,176.80 -13,912.76 5,950,185.11 473,816.74 2.84 13,962.38 MWD+IFR-AK-CAZ-SC (8) 16,737.91 89.81 271.54 6,033.03 5,903.31 1,180.36 -14,005.98 5,950,188.82 473,723.54 2.34 14,055.56 MWD+IFR-AK-CAZ-SC (8) 16,828.16 89.81 274.77 6,033.33 5,903.61 1,185.33 -14,096.08 5,950,193.93 473,633.46 3.58 14,145.75 MWD+IFR-AK-CAZ-SC (8) 16,920.63 87.66 276.02 6,035.37 5,905.65 1,194.02 -14,188.11 5,950,202.77 473,541.45 2.69 14,238.19 MWD+IFR-AK-CAZ-SC (8) 17,012.31 89.11 278.73 6,037.95 5,908.23 1,205.78 -14,278.99 5,950,214.68 473,450.60 3.35 14,329.74 MWD+IFR-AK-CAZ-SC (8) 17,105.17 87.24 277.18 6,040.91 5,911.19 1,218.62 -14,370.90 5,950,227.68 473,358.72 2.62 14,422.42 MWD+IFR-AK-CAZ-SC (8) 17,198.99 91.57 279.69 6,041.88 5,912.16 1,232.38 -14,463.67 5,950,241.58 473,265.98 5.33 14,516.04 MWD+IFR-AK-CAZ-SC (8) 17,289.10 91.30 278.41 6,039.63 5,909.91 1,246.55 -14,552.63 5,950,255.90 473,177.05 1.45 14,605.90 MWD+IFR-AK-CAZ-SC (8) 17,381.93 90.48 278.67 6,038.18 5,908.46 1,260.34 -14,644.42 5,950,269.83 473,085.30 0.93 14,698.54 MWD+IFR-AK-CAZ-SC (8) 17,447.91 89.96 279.40 6,037.93 5,908.21 1,270.70 -14,709.58 5,950,280.30 473,020.16 1.36 14,764.35 MWD+IFR-AK-CAZ-SC (8) 17,484.00 89.96 279.40 6,037.96 5,908.24 1,276.59 -14,745.18 5,950,286.25 472,984.57 0.00 14,800.34 NOT an Actual Survey 17,510.00 89.96 279.40 6,037.97 5,908.25 1,280.84 -14,770.83 5,950,290.54 472,958.93 0.00 14,826.26 PROJECTED to TD 1/9/2017 9 26 48AM Page 7 COMPASS 5000.1 Build 74 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. 0 Yes F-1 No I have checked to the best of my ability that the following data Is correct: Q Surface Coordinates Declination & Convergence Q GRS Survey Corrections Q Dgifaly signed M' Vbrcem Dura Survey Tool Codes Vincent DN: <�=vm<emo ara odchWmberger, SLB DE; ou�5chlumtrerger, Osara n�osua�aioc� <=uz Date: ]Oi7Di.b40ry4p•75 -09.00' Client Representative: Date: 09 -Jan -2017 21 F082 27915 RECEIVED FINAL' SAN 17 Zon AOGCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M-37 Definitive Survey Report 06 January, 2017 NAD 83 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: 2M-37 Wellbore: 2M-37 Design: 2M-37 Schlumberger Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2M-37 2M-37 Actual @ 129.72usft (Doyon 141) 2M-37 Actual @ 129.72usft (Doyon 141) True Minimum Curvature 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 2M-37 Well Position +N/ -S 0.00 usft Northing: 5,948,735.82 usft Latitude: 70° 16' 17.469 N +E/ -W 0.00 usft Easting: 1,627,759.06 usft Longitude: 150° 6'8.549 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 102.30 usft Wellbore 2M-37 Magnetics Model Name Sample Date Declination Dip Angle Field Strength V) (1) (nT) BGGM2016 12/13/2016 17.73 80.88 57,534 Design 2M-37 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 27.42 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) V) 27.42 0.00 0.00 275.00 Survey Program Date 1/6/2017 From To Map Map (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 82.10 82.10 2M-37 Srvy 1 - SLB -INC (2M-37) INC+TREND Inclinometer+ known azi trend 11/23/2016 11:2f 136.96 812.27 2M-37 Srvy 2 - SLB _GWD70 (2M-37) GYD-GC-SS Gyrodata gyro single shots 11/23/2016 11:4: 850.13 3,060.65 2M-37 Srvy 3 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/24/2016 11:4. 3,154.18 3,154.18 2M-37 Srvy 4 - SLB_Inc+Filler (2M-37) INC+TREND Inclinometer + known azi trend 11/30/2016 9:34 3,179.69 12,377.53 2M-37 Srvy 5 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/30/2016 9:36 12,461.04 12,461.04 2M-37 Srvy 6 - SLB_INC+Filler (2M-37) INC+TREND Inclinometer + known azi trend 12/15/2016 10:1 12,553.02 13,826.19 2M-37 Srvy 7 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/15/2016 10:1 13,924.48 17,447.91 2M-37 Srvy 8 - SLB_MWD+GMAG (2M-3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/27/2016 9:3E Survey 1/6/2017 3:03:46PM Page 2 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi ND TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.42 0.00 0.00 27.42 -102.30 0.00 0.00 5,948,735.82 1,627,759.06 0.00 0.00 UNDEFINED 82.10 1.00 253.19 82.10 -47.62 -0.14 -0.46 5,948,735.68 1,627,758.61 1.83 0.44 INC+TREND (1) 136.96 1.62 253.19 136.94 7.22 -0.50 -1.66 5,948,735.32 1,627,757.40 1.13 1.61 GYD-GC-SS (2) 168.55 1.34 258.04 168.52 38.80 -0.71 -2.45 5,948,735.12 1,627,756.62 0.97 2.38 GYD-GC-SS (2) 256.36 1.10 268.08 256.31 126.59 -0.95 -4.29 5,948,734.88 1,627,754.77 0.37 4.19 GYD-GC-SS (2) 353.37 2.06 315.89 353.29 223.57 0.27 -6.44 5,948,736.11 1,627,752.63 1.60 6.44 GYD-GC-SS (2) 446.75 4.53 330.22 446.51 316.79 4.68 -9.44 5,948,740.52 1,627,749.63 2.77 9.81 GYD-GC-SS (2) 539.10 6.96 330.28 538.39 408.67 12.71 -14.02 5,948,748.55 1,627,745.06 2.63 15.08 GYD-GC-SS (2) 1/6/2017 3:03:46PM Page 2 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad MD Reference: Well: 2M-37 North Reference: Wellbore: 2M-37 Survey Calculation Method: Design: 2M-37 Database: Well 2M-37 2M-37 Actual @ 129.72usft (Doyon 141) 2M-37 Actual @ 129.72usft (Doyon 141) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (usft) (1 (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 631.34 10.70 335.84 629.52 499.80 25.38 -20.30 5,948,761.23 1,627,738.81 4.15 22.44 GYD-GC-SS (2) 719.55 9.39 338.03 716.38 586.66 39.52 -26.35 5,948,775.38 1,627,732.79 1.55 29.69 GYD-GC-SS (2) 812.27 11.66 336.02 807.53 677.81 55.10 -32.98 5,948,790.97 1,627,726.18 2.48 37.66 GYD-GC-SS (2) 850.13 12.23 335.73 844.57 714.85 62.25 -36.19 5,948,798.13 1,627,722.98 1.51 41.47 MWD+IFR-AK-CAZ-SC (3) 945.23 15.32 335.79 936.92 807.20 82.90 -45.48 5,948,818.79 1,627,713.73 3.25 52.53 MWD+IFR-AK-CAZ-SC (3) 1,035.97 14.97 335.98 1,024.51 894.79 104.53 -55.17 5,948,840.44 1,627,704.08 0.39 64.07 MWD+IFR-AK-CAZ-SC (3) 1,130.23 15.45 334.09 1,115.47 985.75 126.95 -65.61 5,948,862.87 1,627,693.67 0.73 76.42 MWD+IFR-AK-CAZ-SC (3) 1,225.08 17.47 333.77 1,206.43 1,076.71 151.09 -77.42 5,948,887.02 1,627,681.90 2.13 90.30 MWD+IFR-AK-CAZ-SC (3) 1,317.38 20.91 334.87 1,293.59 1,163.87 178.43 -90.55 5,948,914.39 1,627,668.83 3.75 105.75 MWD+IFR-AK-CAZ-SC (3) 1,409.70 23.05 332.89 1,379.19 1,249.47 209.44 -105.78 5,948,945.42 1,627,653.65 2.45 123.63 MWD+IFR-AK-CAZ-SC (3) 1,503.43 24.00 331.83 1,465.13 1,335.41 242.58 -123.14 5,948,978.58 1,627,636.34 1.11 143.82 MWD+IFR-AK-CAZ-SC (3) 1,596.51 26.18 329.23 1,549.43 1,419.71 276.91 -142.59 5,949,012.95 1,627,616.96 2.62 166.18 MWD+IFR-AK-CAZ-SC (3) 1,689.85 27.53 327.66 1,632.70 1,502.98 312.83 -164.66 5,949,048.90 1,627,594.95 1.63 191.30 MWD+IFR-AK-CAZ-SC (3) 1,786.16 28.76 323.13 1,717.63 1,587.91 350.18 -190.47 5,949,086.29 1,627,569.20 2.56 220.27 MWD+IFR-AK-CAZ-SC (3) 1,879.92 31.24 319.94 1,798.83 1,669.11 386.84 -219.66 5,949,122.99 1,627,540.08 3.14 252.54 MWD+IFR-AK-CAZ-SC (3) 1,972.74 35.05 314.66 1,876.55 1,746.83 424.02 -254.13 5,949,160.22 1,627,505.67 5.15 290.12 MWD+IFR-AK-CAZ-SC (3) 2,065.38 37.71 309.90 1,951.14 1,821.42 460.91 -294.80 5,949,197.18 1,627,465.07 4.19 333.85 MWD+IFR-AK-CAZ-SC (3) 2,158.51 39.52 308.66 2,023.90 1,894.18 497.69 -339.79 5,949,234.03 1,627,420.14 2.11 381.88 MWD+IFR-AK-CAZ-SC (3) 2,253.18 41.94 304.24 2,095.65 1,965.93 534.32 -389.49 5,949,270.74 1,627,370.51 3.98 434.57 MWD+IFR-AK-CAZ-SC (3) 2,345.37 43.15 298.35 2,163.60 2,033.88 566.64 -442.72 5,949,303.15 1,627,317.34 4.51 490.42 MWD+IFR-AK-CAZ-SC (3) 2,439.86 45.52 294.98 2,231.19 2,101.47 596.23 -501.73 5,949,332.83 1,627,258.39 3.54 551.79 MWD+IFR-AK-CAZ-SC (3) 2,530.32 47.86 291.71 2,293.25 2,163.53 622.27 -562.16 5,949,358.97 1,627,198.01 3.69 614.25 MWD+IFR-AK-CAZ-SC (3) 2,622.67 49.04 286.56 2,354.52 2,224.80 644.88 -627.42 5,949,381.69 1,627,132.79 4.36 681.24 MWD+IFR-AK-CAZ-SC (3) 2,717.09 51.37 283.18 2,414.96 2,285.24 663.46 -697.52 5,949,400.38 1,627,062.73 3.69 752.69 MWD+IFR-AK-CAZ-SC (3) 2,808.52 54.24 281.98 2,470.23 2,340.51 679.30 -768.60 5,949,416.35 1,626,991.68 3.31 824.88 MWD+IFR-AK-CAZ-SC (3) 2,900.80 56.22 281.40 2,522.85 2,393.13 694.66 -842.83 5,949,431.82 1,626,917.49 2.21 900.16 MWD+IFR-AK-CAZ-SC (3) 2,995.44 58.18 280.34 2,574.12 2,444.40 709.65 -920.95 5,949,446.95 1,626,639.40 2.27 979.29 MWD+IFR-AK-CAZ-SC (3) 3,060.65 59.37 279.57 2,607.92 2,478.20 719.29 -975.87 5,949,456.68 1,626,784.50 2.09 1,034.85 MWD+IFR-AK-CAZ-SC (3) 3,150.00 59.83 281.09 2,653.14 2,523.42 733.11 -1,051.68 5,949,470.62 1,626,708.72 1.55 1,111.57 NOT an Actual Survey F1 13-3/8" x 16" 3,154.18 59.85 281.16 2,655.24 2,525.52 733.80 -1,055.23 5,949,471.33 1,626,705.18 1.55 1,115.17 INC+TREND (4) 3,179.69 60.43 281.07 2,667.94 2,538.22 738.07 -1,076.94 5,949,475.63 1,626,683.48 2.29 1,137.17 MWD+IFR-AK-CAZ-SC (5) 3,272.74 62.09 278.79 2,712.69 2,582.97 752.12 -1,157.29 5,949,489.82 1,626,603.15 2.79 1,218.44 MWD+IFR-AK-CAZ-SC (5) 3,366.84 63.19 276.31 2,755.94 2,626.22 763.09 -1,240.13 5,949,500.92 1,626,520.34 2.62 1,301.92 MWD+IFR-AK-CAZ-SC (5) 3,460.10 64.30 273.85 2,797.20 2,667.48 770.49 -1,323.43 5,949,508.46 1,626,437.06 2.65 1,385.55 MWD+IFR-AK-CAZ-SC (5) 3,556.03 65.56 272.48 2,837.85 2,708.13 775.28 -1,410.19 5,949,513.40 1,626,350.32 1.84 1,472.39 MWD+IFR-AK-CAZ-SC (5) 3,648.96 67.19 271.82 2,875.09 2,745.37 778.47 -1,495.27 5,949,516.73 1,626,265.26 1.87 1,557.43 MWD+IFR-AK-CAZ-SC (5) 3,743.64 68.68 271.39 2,910.65 2,780.93 780.93 -1,582.98 5,949,519.33 1,626,177.56 1.63 1,645.02 MWD+IFR-AK-CAZ-SC (5) 3,835.03 70.01 271.13 2,942.89 2,813.17 782.81 -1,668.47 5,949,521.36 1,626,092.08 1.48 1,730.35 MWD+IFR-AK-CAZ-SC (5) 3,929.08 71.42 269.54 2,973.95 2,844.23 783.32 -1,757.23 5,949,522.02 1,626,003.32 2.19 1,818.82 MWD+IFR-AK-CAZ-SC (5) 1/6/2017 3:03:46PM Page 3 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Site: Kuparuk 2M Pad MD Reference: Well: 2M-37 North Reference: Wellbore: 2M-37 Survey Calculation Method: Design: 2M-37 Database: Well 2M-37 2M-37 Actual @ 129.72usft (Doyon 141) 2M-37 Actual @ 129.72usft (Doyon 141) True Minimum Curvature OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E1 -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,023.26 71.67 269.47 3,003.76 2,874.04 782.55 -1,846.57 5,949,521.40 1,625,914,00 0.27 1,907.74 MWD+IFR-AK-CAZ-SC (5) 4,117.36 71.50 270.36 3,033.49 2,903.77 782.42 -1,935.85 5,949,521.42 1,625,824.73 0.92 1,996.67 MWD+IFR-AK-CAZ-SC (5) 4,209.95 71.64 271.20 3,062.76 2,933.04 783.61 -2,023.68 5,949,522.76 1,625,736.91 0.87 2,084.28 MWD+IFR-AK-CAZ-SC (5) 4,301.89 71.00 270.98 3,092.21 2,962.49 785.27 -2,110.76 5,949,524.56 1,625,649.84 0.73 2,171.17 MWD+IFR-AK-CAZ-SC (5) 4,394.41 71.02 269.70 3,122.32 2,992.60 785.79 -2,198.24 5,949,525.23 1,625,562.37 1.31 2,258.36 MWD+IFR-AK-CAZ-SC (5) 4,489.51 71.08 269.63 3,153.20 3,023.48 785.26 -2,288.19 5,949,524.85 1,625,472.43 0.09 2,347.92 MWD+IFR-AK-CAZ-SC (5) 4,583.50 71.05 268.20 3,183.70 3,053.98 783.58 -2,377.07 5,949,523.32 1,625,383.55 1.44 2,436.32 MWD+IFR-AK-CAZ-SC (5) 4,674.88 71.05 268.29 3,213.38 3,083.66 780.93 -2,463.46 5,949,520.82 1,625,297.17 0.09 2,522.15 MWD+IFR-AK-CAZ-SC (5) 4,770.41 70.96 266.26 3,244.47 3,114.75 776.64 -2,553.68 5,949,516.68 1,625,206.95 2.01 2,611.65 MWD+IFR-AK-CAZ-SC (5) 4,862.73 70.96 266.31 3,274.59 3,144.87 770.99 -2,640.76 5,949,511.17 1,625,119.86 0.05 2,697.91 MWD+IFR-AK-CAZ-SC (5) 4,955.39 71.03 264.99 3,304.77 3,175.05 764.34 -2,728.12 5,949,504.67 1,625,032.51 1.35 2,784.35 MWD+IFR-AK-CAZ-SC (5) 5,048.17 71.02 264.40 3,334.93 3,205.21 756.23 -2,815.48 5,949,496.71 1,624,945.14 0.60 2,870.68 MWD+IFR-AK-CAZ-SC (5) 5,139.12 70.96 263.13 3,364.56 3,234.84 746.89 -2,900.96 5,949,487.51 1,624,859.65 1.32 2,955.02 MWD+IFR-AK-CAZ-SC (5) 5,234.58 71.01 263.48 3,395.66 3,265.94 736.37 -2,990.59 5,949,477.15 1,624,770.01 0.35 3,043.39 MWD+IFR-AK-CAZ-SC (5) 5,327.67 71.66 264.60 3,425.46 3,295.74 727.21 -3,078.31 5,949,468.14 1,624,682.29 1.34 3,129.98 MWD+IFR-AK-CAZ-SC (5) 5,418.25 71.87 267.14 3,453.80 3,324.08 721.02 -3,164.11 5,949,462.09 1,624,596.49 2.67 3,214.91 MWD+IFR-AK-CAZ-SC (5) 5,513.53 70.87 269.60 3,484.25 3,354.53 718.45 -3,254.35 5,949,459.67 1,624,506.25 2.66 3,304.58 MWD+IFR-AK-CAZ-SC (5) 5,607.51 69.96 270.31 3,515.75 3,386.03 718.37 -3,342.89 5,949,459.74 1,624,417.72 1.20 3,392.78 MWD+IFR-AK-CAZ-SC (5) 5,701.67 70.81 270.93 3,547.36 3,417.64 719.34 -3,431.58 5,949,460.85 1,624,329.04 1.10 3,481.22 MWD+IFR-AK-CAZ-SC (5) 5,795.36 70.35 271.76 3,578.51 3,448.79 721.41 -3,519.92 5,949,463.08 1,624,240.72 0.97 3,569.40 MWD+IFR-AK-CAZ-SC (5) 5,887.78 70.14 271.67 3,609.75 3,480.03 724.01 -3,606.86 5,949,465.83 1,624,153.79 0.25 3,656.23 MWD+IFR-AK-CAZ-SC (5) 5,980.19 70.11 271.57 3,641.16 3,511.44 726.47 -3,693.73 5,949,468.43 1,624,066.93 0.11 3,742.99 MWD+IFR-AK-CAZ-SC (5) 6,075.29 70.14 271.33 3,673.49 3,543.77 728.73 -3,783.13 5,949,470.84 1,623,977.54 0.24 3,832.25 MWD+IFR-AK-CAZ-SC (5) 6,169.07 70.08 270.44 3,705.40 3,575.68 730.09 -3,871.31 5,949,472.35 1,623,889.37 0.89 3,920.21 MWD+IFR-AK-CAZ-SC (5) 6,261.32 70.15 270.06 3,736.78 3,607.06 730.47 -3,958.06 5,949,472.88 1,623,802.63 0.39 4,006.66 MWD+IFR-AK-CAZ-SC (5) 6,355.18 70.04 269.38 3,768.73 3,639.01 730.04 -4,046.31 5,949,472.59 1,623,714.39 0.69 4,094.54 MWD+IFR-AK-CAZ-SC (5) 6,448.04 70.16 268.31 3,800.34 3,670.62 728.28 -4,133.60 5,949,470.98 1,623,627.10 1.09 4,181.35 MWD+IFR-AK-CAZ-SC (5) 6,542.29 70.58 268.37 3,832.01 3,702.29 725.71 -4,222.34 5,949,468.56 1,623,538.37 0.45 4,269.52 MWD+IFR-AK-CAZ-SC (5) 6,635.88 70.48 266.52 3,863.20 3,733.48 721.78 -4,310.49 5,949,464.77 1,623,450.23 1.87 4,356.99 MWD+IFR-AK-CAZ-SC (5) 6,729.69 71.06 266.45 3,894.10 3,764.38 716.35 -4,398.89 5,949,459.49 1,623,361.82 0.62 4,444.59 MWD+IFR-AK-CAZ-SC (5) 6,821.90 71.20 266.35 3,923.92 3,794.20 710.87 -4,485.98 5,949,454.16 1,623,274.74 0.18 4,530.86 MWD+IFR-AK-CAZ-SC (5) 6,912.78 71.22 267.32 3,953.20 3,823.48 706.12 -4,571.88 5,949,449.56 1,623,188.83 1.01 4,616.02 MWD+IFR-AK-CAZ-SC (5) 6,957.34 71.25 267.20 3,967.53 3,837.81 704.10 -4,614.02 5,949,447.61 1,623,146.69 0.26 4,657.83 MWD+IFR-AK-CAZ-SC (5) 7,009.44 71.66 267.67 3,984.10 3,854.38 701.89 -4,663.37 5,949,445.48 1,623,097.35 1.16 4,706.80 MWD+IFR-AK-CAZ-SC (5) 7,103.00 71.26 269.29 4,013.85 3,884.13 699.54 -4,752.04 5,949,443.28 1,623,008.68 1.70 4,794.92 MWD+IFR-AK-CAZ-SC (5) 7,197.93 71.20 269.78 4,044.40 3,914.68 698.81 -4,841.92 5,949,442.70 1,622,918.81 0.49 4,884.40 MWD+IFR-AK-CAZ-SC (5) 7,290.88 71.27 270.80 4,074.30 3,944.58 699.25 -4,929.92 5,949,443.29 1,622,830.82 1.04 4,972.11 MWD+IFR-AK-CAZ-SC (5) 7,384.99 71.08 270.15 4,104.67 3,974.95 699.99 -5,018.99 5,949,444.18 1,622,741.75 0.68 5,060.90 MWD+IFR-AK-CAZ-SC (5) 7,478.31 71.23 270.59 4,134.81 4,005.09 700.56 -5,107.31 5,949,444.90 1,622,653.45 0.47 5,148.93 MWD+IFR-AK-CAZ-SC (5) 7,569.15 71.14 269.71 4,164.11 4,034.39 700.79 -5,193.29 5,949,445.27 1,622,567.47 0.92 5,234.61 MWD+IFR-AK-CAZ-SC.(5) 1/6/2017 3:03:46PM Page 4 COMPASS 5000 1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 Database: OAKEDMP2 Survey 1/6/2017 3:03:46PM Page 5 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (°) (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,661.91 71.11 269.10 4,194.12 4,064.40 699.87 -5,281.06 5,949,444.51 1,622,479.71 0.62 5,321.96 MWD+IFR-AK-CAZ-SC (5) 7,755.49 71.17 268.69 4,224.37 4,094.65 698.17 -5,369.60 5,949,442.95 1,622,391.18 0.42 5,410.02 MWD+IFR-AK-CAZ-SC (5) 7,846.67 71.45 268.34 4,253.58 4,123.86 695.93 -5,455.94 5,949,440.85 1,622,304.84 0.48 5,495.84 MWD+IFR-AK-CAZ-SC (5) 7,939.53 71.54 267.04 4,283.06 4,153.34 692.38 -5,543.93 5,949,437.45 1,622,216.86 1.33 5,583.18 MWD+IFR-AK-CAZ-SC (5) 8,035.39 71.64 266.52 4,313.33 4,183.61 687.27 -5,634.74 5,949,432.50 1,622,126.05 0.53 5,673.20 MWD+IFR-AK-CAZ-SC (5) 8,127.56 71.63 266.74 4,342.37 4,212.65 682.13 -5,722.06 5,949,427.50 1,622,038.73 0.23 5,759.74 MWD+IFR-AK-CAZ-SC (5) 8,221.67 71.72 267.87 4,371.96 4,242.24 677.93 -5,811.30 5,949,423.45 1,621,949.49 1.14 5,848.27 MWD+IFR-AK-CAZ-SC (5) 8,315.83 71.75 268.72 4,401.47 4,271.75 675.27 -5,900.67 5,949,420.94 1,621,860.12 0.86 5,937.07 MWD+IFR-AK-CAZ-SC (5) 8,408.12 71.81 259.01 4,430.33 4,300.61 673.53 -5,988.32 5,949,419.35 1,621,772.48 0.31 6,024.24 MWD+IFR-AK-CAZ-SC (5) 8,504.21 71.76 270.79 4,460.37 4,330.65 673.37 -6,079.59 5,949,419.35 1,621,681.22 1.76 6,115.14 MWD+IFR-AK-CAZ-SC (5) 8,597.08 71.25 270.57 4,489.83 4,360.11 674.42 -6,167.66 5,949,420.54 1,621,593.16 0.59 6,202.97 MWD+IFR-AK-CAZ-SC (5) 8,690.85 71.17 271.02 4,520.03 4,390.31 675.65 -6,256.42 5,949,421.92 1,621,504.41 0.46 6,291.50 MWD+IFR-AK-CAZ-SC (5) 8,784.82 71.14 269.83 4,550.39 4,420.67 676.31 -6,345.35 5,949,422.73 1,621,415.49 1.20 6,380.15 MWD+IFR-AK-CAZ-SC (5) 8,877.59 71.17 268.91 4,580.35 4,450.63 675.34 -6,433.14 5,949,421.91 1,621,327.71 0.94 6,467.52 MWD+IFR-AK-CAZ-SC (5) 8,968.63 71.28 268.47 4,609.65 4,479.93 673.37 -6,519.31 5,949,420.09 1,621,241.54 0.47 6,553.19 MWD+IFR-AK-CAZ-SC (5) 9,065.21 71.78 267.22 4,640.25 4,510.53 669.93 -6,610.85 5,949,416.80 1,621,150.01 1.33 6,644.08 MWD+IFR-AK-CAZ-SC (5) 9,159.14 72.07 267.85 4,669.39 4,539.67 666.09 -6,700.06 5,949,413.11 1,621,060.80 0.71 6,732.62 MWD+IFR-AK-CAZ-SC (5) 9,251.99 71.58 269.19 4,698.36 4,568.64 663.81 -6,788.25 5,949,410.98 1,620,972.62 1.47 6,820.27 MWD+IFR-AK-CAZ-SC (5) 9,346.26 71.58 268.24 4,728.15 4,598.43 661.80 -6,877.66 5,949,409.12 1,620,883.21 0.96 6,909.17 MWD+IFR-AK-CAZ-SC (5) 9,438.83 71.13 267.82 4,757.74 4,628.02 658.79 -6,965.32 5,949,406.25 1,620,795.55 0.65 6,996.24 MWD+IFR-AK-CAZ-SC (5) 9,531.83 71.12 267.14 4,787.83 4,658.11 654.92 -7,053.24 5,949,402.53 1,620,707.64 0.69 7,083.48 MWD+IFR-AK-CAZ-SC (5) 9,623.83 71.02 267.31 4,817.67 4,687.95 650.70 -7,140.16 5,949,398.47 1,620,620.72 0.21 7,169.70 MWD+IFR-AK-CAZ-SC (5) 9,718.47 70.98 266.57 4,848.49 4,718.77 645.93 -7,229.52 5,949,393.84 1,620,531.37 0.74 7,258.30 MWD+IFR-AK-CAZ-SC (5) 9,809.76 71.09 266.89 4,878.15 4,748.43 641.00 -7,315.71 5,949,389.06 1,620,445.17 0.35 7,343.74 MWD+IFR-AK-CAZ-SC (5) 9,903.84 70.98 267.47 4,908.73 4,779.01 636.62 -7,404.57 5,949,384.83 1,620,356.31 0.59 7,431.88 MWD+IFR-AK-CAZ-SC (5) 9,997.82 71.09 268.89 4,939.27 4,809.55 633.80 -7,493.40 5,949,382.16 1,620,267.48 1.43 7,520.13 MWD+IFR-AK-CAZ-SC (5) 10,089.68 70.92 269.44 4,969.17 4,839.45 632.54 -7,580.25 5,949,381.04 1,620,180.64 0.60 7,606.54 MWD+IFR-AK-CAZ-SC (5) 10,182.83 71.19 269.44 4,999.41 4,869.69 631.67 -7,668.35 5,949,380.33 1,620,092.55 0.29 7,694.23 MWD+IFR-AK-CAZ-SC (5) 10,276.05 71.08 270.77 5,029.56 4,899.84 631.84 -7,756.56 5,949,380.64 1,620,004.35 1.36 7,782.11 MWD+IFR-AK-CAZ-SC (5) 10,369.80 71.05 270.71 5,059.98 4,930.26 632.98 -7,845.23 5,949,381.93 1,619,915.69 0.07 7,870.55 MWD+IFR-AK-CAZ-SC (5) 10,462.79 71.01 271.35 5,090.21 4,960.49 634.56 -7,933.16 5,949,383.66 1,619,827.78 0.65 7,958.27 MWD+IFR-AK-CAZ-SC (5) 10,555.27 70.55 272.70 5,120.65 4,990.93 637.65 -8,020.43 5,949,386.89 1,619,740.52 1.47 8,045.48 MWD+IFR-AK-CAZ-SC (5) 10,649.22 70.54 272.25 5,151.94 5,022.22 641.47 -8,108.93 5,949,390.87 1,619,652.03 0.45 8,133.98 MWD+IFR-AK-CAZ-SC (5) 10,742.54 70.50 272.15 5,183.06 5,053.34 644.85 -8,196.84 5,949,394.39 1,619,564.14 0.11 8,221.85 MWD+IFR-AK-CAZ-SC (5) 10,836.68 70.60 272.22 5,214.41 5,084.69 648.23 -8,285.54 5,949,397.92 1,619,475.45 0.13 8,310.51 MWD+IFR-AK-CAZ-SC (5) 10,931.44 70.57 272.60 5,245.91 5,116.19 651.99 -8,374.84 5,949,401.83 1,619,386.17 0.38 8,399.79 MWD+IFR-AK-CAZ-SC (5) 11,023.86 70.48 272.94 5,276.72 5,147.00 656.20 -8,461.87 5,949,406.19 1,619,299.16 0.36 8,486.86 MWD+IFR-AK-CAZ-SC (5) 11,116.07 70.34 273.36 5,307.64 5,177.92 660.98 -8,548.61 5,949,411.11 1,619,212.43 0:46 8,573.69 MWD+IFR-AK-CAZ-SC (5) 11,208.43 70.61 273.18 5,338.51 5,208.79 665.94 -8,635.52 5,949,416.22 1,619,125.54 0.35 8,660.70 MWD+IFR-AK-CAZ-SC (5) 11,301.45 70.54 272.20 5,369.45 5,239.73 670.06 -8,723.14 5,949,420.48 1,619,037.93 1.00 8,748.35 MWD+IFR-AK-CAZ-SC (5) 1/6/2017 3:03:46PM Page 5 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 Database: OAKEDM P2 Survey 1/62017 3:03.46PM Page 6 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (") (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,393.69 70.57 271.41 5,400.15 5,270.43 672.80 -8,810.08 5,949,423.37 1,618,951.01 0.81 8,835.19 MWD+IFR-AK-CAZ-SC (5) 11,487.55 70.57 269.90 5,431.38 5,301.66 673.81 -8,898.58 5,949,424.53 1,618,862.51 1.52 8,923.45 MWD+IFR-AK-CAZ-SC (5) 11,581.15 70.54 269.81 5,462.54 5,332.82 673.59 -8,986.84 5,949,424.45 1,618,774.26 0.10 9,011.35 MWD+IFR-AK-CAZ-SC (5) 11,673.66 70.57 269.48 5,493.33 5,363.61 673.05 -9,074.08 5,949,424.06 1,618,687.04 0.34 9,098.21 MWD+IFR-AK-CAZ-SC (5) 11,765.97 70.63 269.78 5,524.00 5,394.28 672.48 -9,161.14 5,949,423.64 1,618,599.98 0.31 9,184.89 MWD+IFR-AK-CAZ-SC (5) 11,859.09 70.60 270.30 5,554.90 5,425.18 672.54 -9,248.98 5,949,423.85 1,618,512.15 0.53 9,272.40 MWD+IFR-AK-CAZ-SC (5) 11,952.57 70.60 270.54 5,585.95 5,456.23 673.19 -9,337.15 5,949,424.65 1,618,423.99 0.24 9,360.29 MWD+IFR-AK-CAZ-SC (5) 12,045.20 70.53 270.99 5,616.78 5,487.06 674.36 -9,424.50 5,949,425.96 1,618,336.65 0.46 9,447.41 MWD+IFR-AK-CAZ-SC (5) 12,136.77 70.60 271.85 5,647.24 5,517.52 676.50 -9,510.82 5,949,428.25 1,618,250.34 0.89 9,533.59 MWD+IFR-AK-CAZ-SC (5) 12,230.08 70.76 272.57 5,678.12 5,548.40 679.89 -9,598.81 5,949,431.79 1,618,162.37 0.75 9,621.54 MWD+IFR-AK-CAZ-SC (5) 12,322.45 70.53 272.54 5,708.73 5,579.01 683.78 -9,685.87 5,949,435.82 1,618,075.32 0.25 9,708.61 MWD+IFR-AK-CAZ-SC (5) 12,377.53 70.52 273.12 5,727.09 5,597.37 686.34 -9,737.74 5,949,438.47 1,618,023.46 0.99 9,760.50 MWD+IFR-AK-CAZ-SC (5) 12,442.00 70.47 273.38 5,748.62 5,618.90 689.79 -9,798.41 5,949,442.02 1,617,962.81 0.39 9,821.24 tT an Actual Survey 9-5/8" x 12-1/4" 12,461.04 70.45 273.46 5,754.99 5,625.27 690.86 -9,816.32 5,949,443.12 1,617,944.90 0.39 9,839.18 INC+TREND (6) 12,553.02 70.60 273.84 5,785.66 5,655.94 696.38 -9,902.86 5,949,448.79 1,617,858.37 0.42 9,925.87 MWD+IFR-AK-CAZ-SC (7) 12,645.96 70.77 273.83 5,816.40 5,686.68 702.25 -9,990.37 5,949,454.80 1,617,770.88 0.18 10,013.56 MWD+IFR-AK-CAZ-SC (7) 12,738.26 70.77 274.59 5,846.80 5,717.08 708.64 -10,077.29 5,949,461.34 1,617,683.99 0.78 10.,100.70 MWD+IFR-AK-CAZ-SC (7) 12,831.51 70.81 276.83 5,877.48 5,747.76 717.40 -10,164.90 5,949,470.25 1,617,596.40 2.27 10,188.75 MWD+IFR-AK-CAZ-SC (7) 12,924.41 71.23 277.91 5,907.70 5,777.98 728.67 -10,252.02 5,949,481.66 1,617,509.30 1.19 10,276.52 MWD+IFR-AK-CAZ-SC (7) 13,018.65 72.94 278.87 5,936.69 5,806.97 741.76 -10,340.73 5,949,494.90 1,617,420.63 2.06 10,366.03 MWD+IFR-AK-CAZ-SC (7) 13,113.03 75.58 277.56 5,962.29 5,832.57 754.73 -10,430.63 5,949,508.02 1,617,330.76 3.10 10,456.72 MWD+IFR-AK-CAZ-SC (7) 13,206.62 78.19 278.03 5,983.52 5,853.80 767.10 -10,520.93 5,949,520.53 1,617,240.49 2.83 10,547.75 MWD+IFR-AK-CAZ-SC (7) 13,301.65 80.81 277.74 6,000.84 5,871.12 779.91 -10,613.48 5,949,533.50 1,617,147.97 2.77 10,641.06 MWD+IFR-AK-CAZ-SC (7) 13,395.34 83.55 278.86 6,013.59 5,883.87 793.31 -10,705.31 5,949,547.06 1,617,056.17 3.16 10,733.72 MWD+IFR-AK-CAZ-SC (7) 13,489.19 85.07 279.11 6,022.89 5,893.17 807.90 -10,797.55 5,949,561.80 1,616,963.96 1.64 10,826.88 MWD+IFR-AK-CAZ-SC (7) 13,582.08 85.30 279.73 6,030.69 5,900.97 823.05 -10,888.86 5,949,577.10 1,616,872.69 0.71 10,919.16 MWD+IFR-AK-CAZ-SC (7) 13,677.07 85.24 279.61 6,038.52 5,908.80 838.95 -10,982.19 5,949,593.15 1,616,779.40 0.14 11,013.51 MWD+IFR-AK-CAZ-SC (7) 13,769.85 85.59 280.00 6,045.94 5,916.22 854.70 -11,073.32 5,949,609.06 1,616,688.30 0.56 11,105.67 MWD+IFR-AK-CAZ-SC (7) 13,826.19 85.53 279.31 6,050.30 5,920.58 864.12 -11,128.69 5,949,618.57 1,616,632.95 1.23 11,161.66 MWD+IFR-AK-CAZ-SC (7) 13,894.00 87.00 280.09 6,054.72 5,925.00 875.52 -11,195.39 5,949,630.08 1,616,566.28 2.45 11,229.09 NOT an Actual Survey' 7" x 8-314" 13,924.48 87.66 280.44 6,056.14 5,926.42 880.95 -11,225.35 5,949,635.56 1,616,536.33 2.45 11,259.41 MWD+IFR-AK-CAZ-SC (8) 13,995.70 89.21 281.85 6,058.08 5,928.36 894.71 -11,295.19 5,949,649.43 1,616,466.52 2.94 11,330.19 MWD+IFR-AK-CAZ-SC (8) 14,089.77 90.00 280.42 6,058.73 5,929.01 912.87 -11,387.49 5,949,667.75 1,616,374.26 1.74 11,423.72 MWD+IFR-AK-CAZ-SC (8) 14,184.17 93.35 278.69 6,055.97 5,926.25 928.53 -11,480.52 5,949,683.57 1,616,281.26 3.99 11,517.76 MWD+IFR-AK-CAZ-SC (8) 14,280.73 90.52 278.54 6,052.71 5,922.99 942.99 -11,575.93 5,949,698.18 1,616,185.89 2.93 11,614.07 MWD+IFR-AK-CAZ-SC (8) 14,373.56 90.13 275.21 6,052.18 5,922.46 954.90 -11,667.98 5,949,710.25 1,616,093.87 2.54 11,706.81 MWD+IFR-AK-CAZ-SC (8) 14,469.51 90.35 275.98 6,051.78 5,922.06 965.09 -11,763.39 5,949,720.60 1,615,998.49 0.33 11,802.74 MWD+IFR-AK-CAZ-SC (8) 14,564.58 89.31 270.69 6,052.06 5,922.34 970.62 -11,858.26 5,949,726.29 1,615,903.63 5.67 11,897.73 MWD+IFR-AK-CAZ-SC (8) 1/62017 3:03.46PM Page 6 COMPASS 5000.1 Build 74 Schlumberger Definitive Survey Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well 2M-37 Project: Kuparuk River Unit TVD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Site: Kuparuk 2M Pad MD Reference: 2M-37 Actual @ 129.72usft (Doyon 141) Well: 2M-37 North Reference: True Wellbore: 2M-37 Survey Calculation Method: Minimum Curvature Design: 2M-37 Database: OAKEDMP2 Survey 1/6/2017 3.03:46PM Page 7 COMPASS 5000.1 Build 74 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (usft) (1) (1 (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 14,658.82 89.14 267.63 6,053.34 5,923.62 969.24 -11,952.47 5,949,725.06 1,615,809.43 3.25 11,991.46 MWD+IFR-AK-CAZ-SC (8) 14,753.11 88.37 265.54 6,055.39 5,925.67 963.62 -12,046.57 5,949,719.61 1,615,715.34 2.36 12,084.71 MWD+IFR-AK-CAZ-SC (8) 14,848.52 89.24 271.53 6,057.38 5,927.66 961.19 -12,141.88 5,949,717.33 1,615,620.03 6.34 12,179.45 MWD+IFR-AK-CAZ-SC (8) 14,943.47 85.54 271.55 6,061.70 5,931.98 963.74 -12,236.68 5,949,720.04 1,615,525.24 3.90 12,274.11 MWD+IFR-AK-CAZ-SC (8) 15,039.09 84.16 272.16 6,070.29 5,940.57 966.82 -12,331.86 5,949,723.28 1,615,430.07 1.58 12,369.20 MWD+IFR-AK-CAZ-SC (8) 15,134.04 87.82 273.94 6,076.93 5,947.21 971.86 -12,426.43 5,949,728.48 1,615,335.53 4.28 12,463.84 MWD+IFR-AK-CAZ-SC (8) 15,227.36 89.10 279.06 6,079.43 5,949.71 982.42 -12,519.08 5,949,739.19 1,615,242.90 5.65 12,557.06 MWD+IFR-AK-CAZ-SC (8) 15,323.43 87.59 282.46 6,082.21 5,952.49 1,000.34 -12,613.40 5,949,757.27 1,615,148.62 3.87 12,652.59 MWD+IFR-AK-CAZ-SC (8) 15,417.62 89.82 286.32 6,084.34 5,954.62 1,023.74 -12,704.59 5,949,780.82 1,615,057.48 4.73 12,745.47 MWD+IFR-AK-CAZ-SC (8) 15,512.41 89.30 286.97 6,085.07 5,955.35 1,050.89 -12,795.41 5,949,808.12 1,614,966.72 0.88 12,838.31 MWD+IFR-AK-CAZ-SC (8) 15,608.70 92.62 285.80 6,083.45 5,953.73 1,078.04 -12,887.76 5,949,835.43 1,614,874.42 3.66 12,932.68 MWD+IFR-AK-CAZ-SC (8) 15,702.03 94.09 284.88 6,077.99 5,948.27 1,102.69 -12,977.61 5,949,860.23 1,614,784.62 1.86 13,024.33 MWD+IFR-AK-CAZ-SC (8) 15,798.24 94.04 282.29 6,071.17 5,941.45 1,125.23 -13,070.88 5,949,882.92 1,614,691.40 2.69 13,119.21 MWD+IFR-AK-CAZ-SC (8) 15,893.10 91.33 280.97 6,066.73 5,937.01 1,144.33 -13,163.68 5,949,902.17 1,614,598.64 3.18 13,213.32 MWD+IFR-AK-CAZ-SC (8) 15,987.17 92.12 277.12 6,063.89 5,934.17 1,159.11 -13,256.52 5,949,917.11 1,614,505.83 4.18 13,307.10 MWD+IFR-AK-CAZ-SC (8) 16,083.35 93.08 272.27 6,059.53 5,929.81 1,166.97 -13,352.25 5,949,925.13 1,614,410.13 5.14 13,403.15 MWD+IFR-AK-CAZ-SC (8) 16,177.21 93.15 270.79 6,054.43 5,924.71 1,169.48 -13,445.94 5,949,927.79 1,614,316.46 1.58 13,496.70 MWD+IFR-AK-CAZ-SC (8) 16,273.77 92.95 270.48 6,049.29 5,919.57 1,170.54 -13,542.35 5,949,929.02 1,614,220.05 0.38 13,592.84 MWD+IFR-AK-CAZ-SC (8) 16,367.19 93.08 270.35 6,044.38 5,914.66 1,171.22 -13,635.64 5,949,929.85 1,614,126.77 0.20 13,685.83 MWD+IFR-AK-CAZ-SC (8) 16,463.12 93.32 271.48 6,039.02 5,909.30 1,172.75 -13,731.41 5,949,931.54 1,614,031.02 1.20 13,781.37 MWD+IFR-AK-CAZ-SC (8) 16,552.98 90.64 270.40 6,035.92 5,906.20 1,174.22 -13,821.19 5,949,933.17 1,613,941.24 3.22 13,870.94 MWD+IFR-AK-CAZ-SC (8) 16,644.61 91.57 272.83 6,034.15 5,904.43 1,176.80 -13,912.76 5,949,935.90 1,613,849.69 2.84 13,962.38 MWD+IFR-AK-CAZ-SC (8) 16,737.91 89.81 271.54 6,033.03 5,903.31 1,180.36 -14,005.98 5,949,939.62 1,613,756.49 2.34 14,055.56 MWD+IFR-AK-CAZ-SC (8) 16,828.16 89.81 274.77 6,033.33 5,903.61 1,185.33 -14,096.08 5,949,944.73 1,613,666.40 3.58 14,145.75 MWD+IFR-AK-CAZ-SC (8) 16,920.63 87.66 276.02 6,035.37 5,905.65 1,194.02 -14,188.11 5,949,953.58 1,613,574.40 2.69 14,238.19 MWD+IFR-AK-CAZ-SC (8) 17,012.31 89.11 278.73 6,037.95 5,908.23 1,205.78 -14,278.99 5,949,965.49 1,613,483.55 3.35 14,329.74 MWD+IFR-AK-CAZ-SC (8) 17,105.17 87.24 277.18 6,040.91 5,911.19 1,218.62 -14,370.90 5,949,978.49 1,613,391.67 2.62 14,422.42 MWD+IFR-AK-CAZ-SC (8) 17,198.99 91.57 279.69 6,041.88 5,912.16 1,232.38 -14,463.67 5,949,992.40 1,613,298.93 5.33 14,516.04 MWD+IFR-AK-CAZ-SC (8) 17,289.10 91.30 278.41 6,039.63 5,909.91 1,246.55 -14,552.63 5,950,006.72 1,613,210.00 1.45 14,605.90 MWD+IFR-AK-CAZ-SC (8) 17,381.93 90.48 278.67 6,038.18 5,908.46 1,260.34 -14,644.42 5,950,020.66 1,613,118.25 0.93 14,698.54 MWD+IFR-AK-CAZ-SC (8) 17,447.91 89.96 279.40 6,037.93 5,908.21 1,270.70 -14,709.58 5,950,031.13 1,613,053.11 1.36 14,764.35 MWD+IFR-AK-CAZ-SC (8) 17,484.00 89.96 279.40 6,037.96 5,908.24 1,276.59 -14,745.18 5,950,037.08 1,613,017.52 0.00 14,800.34 NOT an Actual Survey 4 112" x 8-1/8" 17,510.00 89.96 279.40 6,037.97 5,908.25 1,280.84 -14,770.83 5,950,041.37 1,612,991.88 0.00 14,826.26 PROJECTED to TD 1/6/2017 3.03:46PM Page 7 COMPASS 5000.1 Build 74 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have been achieved. ❑Q Yes [J No I have checked to the best of my ability that the following data Is correct: Q Surface Coordinates Q Declination & Convergence p GRS Survey Corrections (] Survey Tool Codes Vincent Digitally algned by Vince.0— DN—=V6 tOsara, o-sdilumberger, SLB DE: OSara —schlumberger, emallsry Oslbc C=US Data: 7017.01.09 ODAO3 WDO' Client Representative: .aT LFxft ) Date: 09 -Jan -2017 7.'�,� - �e_.s._i_:r� .�:�.:. r.�:..�'�'�_��. _..�.�. �>.i�. S4 a•5 � w�. THE STATE o1A LASKA I -I GOVERNOR BILL WALKER G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Alaska ..ia and Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-37 ConocoPhillips Alaska, Inc. Permit to Drill Number: 216-082 Surface Location: 5166' FNL, 116' FEL, SEC. 28, TI IN, R8E, UM Bottomhole Location: 4021'FNL, 4318' FEL, SEC. 30, TI IN, R8E, 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, Cathy . Foerster Chair DATED this /' day of July, 2016. STATE OF ALASKA AL XAA OIL AND GAS CONSERVATION COMN,t/` ON PERMIT TO DRILL 20 AAC 25.005 RECEIVED ,JUN 0 0 2016 1 a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill Il ` Lateral ❑ Stratigraphic Test ❑ Development - Oil ❑ Service - Winj El ` Single Zone 0 Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket [2] Single Well ❑ 11. Well Name and Number: ConocoPhilli s Alaska Inc Bond No. 59-52-180 KRU 2M-37 , 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 17403 TVD: 6049 Kuparuk River Field Kuparuk Oil Pool 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: 5166 FNL 116 FEL, Sec. 28 Twn 11 N Rng 8E, UM ADL025586, ADL025585 i Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4355 FNL 321 FEL, Sec. 30 Twn 11 N Rng 8E, UM 931894000, 931893000 7/10/2016 Total Depth: 9. Acres in Property: 14. Distance to Nearest Propertv: 4021 FNL 4318 FEL, Sec. 30 Twn 11 N Rng 8E, UM 2560, 2491 690 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 144.1 Distance to Nearest Well Open Surface: x- 487724 y- 5948986.1 Zon( 4 GL Elevation above MSL (ft): 105.1 115. to Same Pool: 2100' @ top C 16. Deviated wells: Kickoff depth: 275 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 94.5 degrees Downhole: 3861 psi f Surface: 3257 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# H-40 Welded 80 39 39 119 119 cement in place 16" 13.375" 68# L-80 Hydril563 3122 39 39 3161 2634 737Ts-7171 ppg DeepuRE I E -79 -s -R 15.8 pog Class 'G' 12.25" 9.625" 40# L-80 BTCM 10033 2000 1899 12033 5646 557 sx 15.8ppg Class 'G' 75"x9.875' 7" 26# L-80 dril 563/BTJ 13610 39 39 13649 6059 1515 sx 15.8ppg Class 'G' 6.125" 1 4.5" 12.6# 1 L-80 I IBTM 1 17364 39 1 39 17403 r 6049 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 E] Time v. Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not Haibin Guo @ 265-1487 be deviated from without prior written approval. Contact Email Haibin.Guo@COP.com Printed Name G. Alvord Title Alaska Drilling Manager oA, C(6 /1��6 Signature L. Phone 265-6120 Date Commission Use Only Permit to Drill API Number: Permit Approval+^ See cover letter for other Number: 11,�- OV, 50- Q - ()� - Ob Date: -7(710,0 W requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed metha�ne, gas hydrates, or gas contained in shales: 21 Other: 801D t_1_5 7`0 3Tov/0s r9 Z OD 161 v ft's" fz f � S Samples req'd: Yes El Nol/ �' )JHzS Mud log req'd: Yes❑ Nov ,,I P7 -)C/ n 1"e- ve-'7 5 measures: Yes No[] Directional svy req'd: Yesv No❑ Spacing exception req'd: Yes ❑ Now Inclination -only svy req'd: Yes❑' Nov Post initial injection MIT req'd: Yes[Y] No❑ APPROVED BY 7--7 Approved by: COMMISSIONER THE COMMISSION Date: Submit Form and Form 10-401 (Revised 11/2015) 0 Rh 1.G t Is Na A L o n t h s from the date of approval (20 AAC 25.005(g)) Attachments in Duplicate Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 263-4180 June 3, 2016 Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501 Application for Permit to Drill, Well 2M-37 JUN 0 6 z�)ii Re: Application for Permit to Drill Well 2M-37, a Kuparuk C Sand Pre -Produce Injector AOGCC Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots pre -produce (6 months) injector well from the 2M pad. The expected spud date for this well is July 15, 2016. It is planned to use rig Doyon 142.,/ 21VI-37 is planned to be a horizontal well in the Kuparuk C sand. The surface section will be drilled with 16" bit and run 13-3/8" casing to +/-3,161'MD / 2,634'TVD. The intermediate section (I) will be drilled with 12-1/4" bit and run 9-5/8" casing to 12,033'MD / 5,646'TVD. The intermediate section (II) will be drilled with 8-3/4" bit with 9-7/8" under reamer and run 7" casin p 13,649'MD / 6,059'TVD. The production hole will be drilled with 6-1/8" bit and run 4-1/2" perforated liner to +/- 17,403'MD / 6,049'TVD. The upper completion will be run with 3-1/2" tubing. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d) (2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Haibin Guo at 265-1487 (Haibin.Guokconocophillips.com) or Chip Alvord at 265-6120. Sincerely, Chip Alvord Drilling Manager Permit It - Kuparuk Well 21VI-37 Application Table of Contents Document Application for Permit to Drill, Well 2M-37 1. Well Name.................................................................................................................. 3 Requirements of 20 AAC 25.005(0........................................................................................................ 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 4. Drilling Hazards Information..................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4)........................................................................................................ 3 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 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 13. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7 Requirements of 20 AAC 25.005 (c)(14)................................................................................................ 7 14. Attachments............................................................................................................... 8 Attachment1 Directional Plan............................................................................................................... 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Program Summary ............................................................................................. 8 Attachment4 Well Schematic................................................................................................................ 8 Attachment 5 Pad with diverter schematic............................................................................................. 8 ration for Permit to Drill, Well 2M-37 1. Well Name Requirements of 20 AAC 25.005 (0 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 ivell ivith multiple well branches, each branch must similarly be identified by a unique name and API number by adding 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 2M-37 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 identifi,ing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surjace, 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 Top of Productive 4355 FNL 321 FEL, Sec. 30 Twn 11N Rng 8E, UM Location at Surface 5166 FNL 116 FEL, Sec. 28 Twn 11N Rng 8E, UM ASP Zone 4 NAD 27 Coordinates ASP Zone 4 NAD 27 Coordinates Northings 5,948,986.1 Eastings: 487,724.4 Total Vertical Depth, RKB: 5,646' RKB Elevation 144.1' AMSL Total Vertical Depth, SS: 5,502' 1 Pad Elevation 105.1'AMSL Location at Top of Productive 4355 FNL 321 FEL, Sec. 30 Twn 11N Rng 8E, UM Interval (Ku aruk "C" Sand) Total Vertical Depth, RKB: 6,049' ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12,033' Total Vertical Depth, RKB: 5,646' Northings: 5,949,822.2 Eastings: 476,960.0 Total Vertical Depth, SS: 5,502' Location at Total Depth 1 4021 FNL 4318 FEL, Sec. 30 Twn 1 1N Rng 8E, UM ASP Zone 4 NAD 27 Coordinates Northings: 5,950,170.2 Eastings: 472, 962.9 Measured Depth, RKB: 17,403' Total Vertical Depth, RKB: 6,049' Total Vertical Depth, SS: 5,905' and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) lira 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 wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 2M-37 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 far an item already, on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142. 4. 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: ration for Permit to Drill, Well 2M-37 (4) information on drilling haiards, 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 maximum potential surface pressure (MPSP),wIAe drilling 2M-37 is calculated using an estimated maximum reservoir pressure of 3,861 psi (12.3 ppg, based on nearby 2M wells), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk C sand at 6,036' TVD (WP12): C Sand Estimated. BHP = 3,861 psi C Sand estimated depth (WP12) = 6,036' TVD Gas Gradient = 0.10 psi/ft { as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 604 psi (6,036' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 3,257 psi (3,861 psi — 604 psi) (B) data on potential gas zones, The well bore is not expected to penetrate any shallow gas zones. And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation Bones, and :ones that have a propenshy for differential sticking; See attached 2M-37Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) An application for a permit to Drill must be accompanied by each of the folloiring 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 AAC 25.0300; A procedure is on file with the commission for performing LOT'S. ration for Permit to Drill, Well 2M-37 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 already 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 Surface 16" Hole 13-3/8" Casing See also Attachment 3: Cement Summary Intermediate 8-3/4 x 9-7/8" Hole 7" Casing Csg/Tbg Hole iz(Ib/ft) Weight Grade Conn. Length Top MD/TVD Btm MD/TVD Cement Program OD (in) 10.5-12.5 PV 30-50 10-20 (ft) (ft) (ft) 40-80 20 42 94 H-40 Welded 80 Surf 120/120 Cement in place 13-3/8 16 68 L-80 Hydril 3,122 Surf 3161/2634 1373 sx 11 ppg DeepCRET�E, 330 sx 'G' API Filtrate NC < 6 < 6 563 HTHP Fluid Loss at 160 F N/A < 10 15.8ppg Class 9-5/8 12-1/4 40 L-80 BTCM 10,033 2000/ 1899 12033/ 5646 557 sx 15.8ppg Class 'G' 8-3/4 Hydril 7 x 9- 26 L-80 563/ 13,610 Surf 13649/ 6059 515 sx 15.8ppg Class 'G' 7/8 BTCM 41/2 6-1/8 12.6 L-80 IBT-M 3,904 13499/ 6049 17403/ 6049 Liner w/ perf pups 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 folloloing 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 tinder 20 AAC 25.035(h)(2): Please reference diverter schematics on file for Doyon 142. 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: Mud Program Summary Surface 16" Hole 13-3/8" Casing Intermediate 12-1/4" Hole 9-5/8" Casing Intermediate 8-3/4 x 9-7/8" Hole 7" Casing Production 6-1/8" Hole 4-1/2" Liner Mud System Spud mud (WBM) LSND (WBM) LSND (WBM) FLO-PRO NT (WBM) Density 8.3-10 9.2 - 10.5 10.5-12.5 10.5-12.5 PV 30-50 10-20 10-20 10-20 YP 40-80 16-24 17-28 16-24 Funnel Viscosity 200-300 N/A N/A N/A Initial Gel 30-50 10-12 11-15 5-8 10 minute Gel 30-50 10-18 12-22 5-12 API Filtrate NC < 6 < 6 < 6 HTHP Fluid Loss at 160 F N/A < 10 < 10 < 10 pH 9.0-10.0 9.0-10.0 9.0-10.0 9.5-10.0 -ation for Permit to Drill, Well 2M-37 Diagram of Doyon 142 Mud System is on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 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 AAC 25.03369: 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 smell. a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1O.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: (1 l) for a well drilled front an offshore platform. mobile bottom founded stricture, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. II.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 AAC 25.025 (Bonding)have been rnel 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_ile 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" conductor to +/- 120' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 142. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/-3161' MD / 2634' TVD as per directional plan. (LWD Program: GR/RES) f 4. Run and cement 13-3/8", 68#, L80, casing to surface. Displace cement with mud and check floats upon bumping plug. 5. Remove diverter system, install and test 13-5/8" x 5,_000_ psi BOP's to 3500 psi (annular preventer to 2500 psi). Notify AOGCC 24 hrs before test. -L- 6. 6. PU 12-1/4" bit and drilling assembly with MWD. RIH, clean out cement to top of float equipment and test using to 3500 psi for 30min. 7. Drill out cement and 20' of new hole. Perform formation integrity test to minimum 12.5ppg EMW, recording results. ration for Permit to Drill, Well 2M-37 8. Directionally drill 12-1/4" hole to casing point at +/-12033' MD / 5646' TVD in the top of HRZ. (LWD Program: GR/RES/PWD). J 9. Circulate wellbore clean and pull out of the hole. 10. Run 9-5/8", 40# L80, liner and liner top packer. Top of cement to be +/-10530' MD / 5137' TVD which is +/- 1500' above the intermediate casing shoe. 11. PU 8-3/4" x 9-7/8" rotary steerable system and under reamer. RIH, clean out cement to top of float equipment and test casing to 3500 psi/30min. 12. Drill out cement and 20' of new hole. Perform formation integrity test to a minimum of 13.5ppg EMW, recording results. 13. Directionally drill 8-3/4" x 9-7/8" hole to c sing point at 13649' MD / 6059' TVD in the Kupa��A C sand. (LWD Program: GR/RES/NEU/DEN/PWD).se Managed Pressure Drilling (MPD) technology/in this section and next for wellbore stability and pore pressure management. � 14. Circulate well clean, condition mud, flow check and pull out of hole. 15. Run 7", 26# L80 liner and liner top packer. Top of cement to be at the liner top packer. 16. Run 7", 26# L80 tie -back. Prior to stinging into the seal bore extension displace 7" x 9-5/8" x 13-3/8" annulus to corrosion inhibited brine and freeze protect with Isothermal diesel. 17. PU 6-1/8" PDC Bit and drilling assembly, with MWD and LWD logging tools. RIH and clean out cement to top of float equipment. Test casing to 3500 psi/30min. 18. Drill out cement and 20' of new hole. Perform formation integrity_test_to a minimum__of_13_5ppg-_EMW, recording results. Displace hole to lateral drilling system. 19. Directionally drill 6-1/8" hole into the Kuparuk C sand and to TD at +/-17403' MD / 6049' TVD as per directional plan. (LWD Program: GR/RES/NEU/DEN/Sonic/PWD). 20. Circulate well clean and pull out of hole. 21. PU and run 4-1/2", 12.6# L80 lower completion with perforated liners. 22. PU and run 3-1/2", 9.3# L80 EUE tubing upper completion, circulate around with kill weight brine 23. Land tubing. Set BPV 24. Nipple down BOPE, nipple up tree and test. Pull BPV. 25. Freeze protect well with diesel by pumping into 3.5" x 7" annulus, taking returns from tubing and allowing to equalize. 26. Set BPV, secure well and move rig off. 27. No fractured stimulation is planned on 2M-37. 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 authori_ation 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 hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and 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. ration for Permit to Drill, Well 2M-37 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Program Summary Attachment 4 Well Schematic Attachment 5 Pad with diverter schematic 2M -37w p12.1 DI 6.886 Plan Summary 1030 - 1220 300 60 1220 - 1410 6 1410 - 1600 SURVEY PROGRAM 1600 - 2260 TDtnC4�� 2260 2930 2M-37wp12.1 (Plan: 2M-37) _.�-__- 8 _ ------ ---- Base -HR , 5 13-3/8" x 16 - � t � I I 'Join Top C/ 270 u.n in I HRZ 'K 1.� Fatil 2 50.70' DTE m 700.00 1700.00 a al °as Fault 1 (cross In CSB), / - as z z y I Iceberg " i o r 13470 1478 5570 6240 _ C-80 C) Be enn rost CajnpS$ C-�37\� C-3'5- t '� MWD -AK -AK -SC 6900 - 8210 14780 - 1609 0 0 4660.83 2M-37wp12.1 (Plan: 2M-37) r0 4000 8000 12000 16000 MWD CASING DETAILS zMazuaez 20" x 42" Measured Depth 3160.83 12032.53 2M-37wp12.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC 0 Depth Reference: Plan: 105.1+39 @ 144.10usft (Doyon 142) 13-3/8" x 16' Rig: Doyon 142 Name 12032.53 ,$ o 2M-37wp12.1 (Plan: 2M-37) o b 119.00 119.00 20" x42" Magnetic Model: BGGM2016 T 7" x 8 13648.88 2M-37wp12.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC n m o 0 0 0 4-1/2" x 6-1/8" 13-3/8" x 16" Magnetic Model Date: 13 -Sep -16 I! 13648.88 15148.88 2M-37wp12.1 (Plan: 2M-37) MWD 564610 12032.53 9-5/8" x 12-1/4" Magnetic Declination: 17.87c 13648.88 17403.05 2M-37wp12.1 (Plan: 2M-37) 39 275 0 2000 4000 6000 8000 10000 12000 a140(>8 Add 17.87° East 0 275 - aso Horizontal Departure 120 r 460 - 650 1494.1 330 ---- -----�- . 30 ....---- ..--- :---- '---- 650 - 840 Sec MDInc 9 840 - 1030 ------------ --- •.:". 1030 - 1220 300 60 1220 - 1410 6 1410 - 1600 SURVEY PROGRAM 1600 - 2260 3 zM-asaer 2260 2930 2M-37wp12.1 (Plan: 2M-37) 2930 - 3590 270 u.n 3590 - 4250 700.00 1700.00 a al °as 4250 -'"" 4910 - as z z 4910 - 5570 13470 1478 5570 6240 _ 6240 - 6900 MWD -AK -AK -SC 6900 - 8210 Intermediate II hole Iceberg 5309.1 size changed from 4¢7-3�175 r1 tr 564'10 1 (cross in C ) Surface Location 8-3/4 by 9-1/2" to Top HRZ is subject to Change 8-3/4" by 9-7/8". R...,.I,$o 70PDTE Kaiik 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 -Ilis on nvoi ng get out n the aud t p sonrove �l'-s -1- a-gs for the final well plan nnl wpli4e drnvjinn-q I al�n acknowledne that une-- nntilled oto : erwisA All tAraetq onvp. a Inn feet lateral tolerance Prepared by: Checked by: Accepted by: Approved by: Brij Potnis Nate Beck Erik Sterk Guo, Crews 0 2000 4000 6000 8000 10000 12000 Pad Elevation: 105.10 240 zMas .noz e { 120 8210 - 9530 9530 -"- 1084 10840 - 1215 12150 - 1347 SURVEY PROGRAM epth From DepthTo Survey/Plan Tool 39.00 700.00 2M-37wp12.1 (Plan: 2M-37) GYD-GC-SS 10 2aso 700.00 1700.00 2M-37wp12.1 (Plan: 2M-37) MWD 12mz� ` 13470 1478 700.00 3160.83 2M-37wp12.1 (Plan: 2M-37) MWD -AK -AK -SC Bet -0 14780 - 1609 3160.83 4660.83 2M-37wp12.1 (Plan: 2M-37) MWD CASING DETAILS zMazuaez 16090 - 1740 3160.83 12032.53 2M-37wp12.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC TVD MD Name 12032.53 13532.53 2M-37wp12.1 (Plan: 2M-37) MWD 119.00 119.00 20" x42" Magnetic Model: BGGM2016 T 12032.53 13648.88 2M-37wp12.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC 2633.94 3160.83 13-3/8" x 16" Magnetic Model Date: 13 -Sep -16 13648.88 15148.88 2M-37wp12.1 (Plan: 2M-37) MWD 564610 12032.53 9-5/8" x 12-1/4" Magnetic Declination: 17.87c 13648.88 17403.05 2M-37wp12.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC 6059.10 13648.88 7" x 8-3/4" by 9-7/8" To convert a Magnetic Direction to a True Direction, Add 17.87° East SECTION DETAILS 1494.1 Sec MDInc Azi TVD +N/ -S +E/ -W Deg TFace VSect Target Annotation 1 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 2 275.00 0.00 0.00 275.00 0.00 0.00 0.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 10° TF, for 125.02' 3 400.02 1.88 10.00 400.00 2.01 0.36 1.50 10.00 -0.25 Adjust TF to -68", for 200.26' 4 600.29 4.09 327.11 600.00 11.25 -2.96 1.50 -68.00 3.54 Start 2.5°/100' DLS, 0° TF, for 879.63' Base Permafrost 5 1479.92 26.08 327.11 1444.10 202.34 -126.55 2.50 0.00 136.97 Hold for 111.34' 6 1591.26 26.08 327.11 1544.10 243.45 -153.14 0.00 0.00 165.67 Start 3.5°/100' DLS, -68.23° TF, for 1569.57' 7 3160.83 67.51271.75 2633.94 581.68 -1142.26 3.50 -68.23 1171.14 Hold for 20' 8 3180.83 67.51 271.75 2641.59 582.25 -1160.73 0.00 0.00 1189.61 Start 3.5°/100' DLS, -26.2° TF, for 84.59' 9 3265.41 70.17 270.36 2672.12 583.70 -1239.59 3.50 -26.20 1268.44 Hold for 8629.41' 10 11894.82 70.17 270.36 5599.10 635.11 -9357.28 0.00 0.00 9377.70 2M-37 1.Fault1C35 020515 JC Start 2.08'/100' DLS, 95.54° TF, for 137.7' 2946.1 11 12032.53 69.92 273.40 5646.10 639.35 -9486.63 2.08 95.54 9507.09 Hold for 20' 12 12052.53 69.92 273.40 5652.97 640.46 -9505.38 0.00 0.00 9525.87 Start 2.08°/100' DLS, 81.02° TF, for 252.68' 13 12305.20 70.83 278.90 5737.89 665.97 -9741.89 2.08 81.02 9763.40 Hold for 508.7' 14 12813.90 70.83 278.90 5904.96 740.29 -10216.59 0.00 0.0010241.33 Start 2.08°/100' DLS, -8.27° 717, for 635.82' Campss 1 5 13449.72 83.93 277.00 6043.60 825.65 -10829.75 2.08 -8.2710858.12 2M-37 2. Top C 021815 JC New Y Start 3.25°/100' DLS, 90.16" TF, for 38.74' 16 13488.46 83.93 278.27 6047.70 830.77 -10867.93 3.25 90.1610896.52 Hold for 3.13' 17 13491.60 83.93 278.27 6048.03 831.21 •10871.02 0.00 0.00 10899.62 Start 3.32°/100' DLS, -38.79° TF, for 157.29' 18 13648.88 88.00 275.00 6059.10 849.32 -11026.81 3.32 -38.7911056.15 2M-37 3.Landing 051616 JC Hold for 20' - 3951.1 19 13668.88 88.00 275.00 6059.80 851.06 -11046.72 0.00 0.0011076.12 Start 3°/100' DLS, -80.02° TF, for 10.85' 20 13679.73 88.06 274.68 6060.17 851.98 -17057.53 3.00 -80.0211086.96 Hold for 1737.55' 21 15417.29 88.06 274.68 6119.10 993.64 -12788.29 0.00 0.0012822.77 2M-37 4.Fault2 020515 JC Start 5°/100' DLS, 0° TF, for 128.87' 22 15546.16 94.50 274.68 6 11 6.23 1004.15 -12916.63 5.00 0.0012951.48 Hold for 700' C-50 23 16246.16 94.50 274.68 6061.31 1061.07 -13612.15 0.00 0.0013649.03 Start 3°/100' DLS, 177.35° TF, for 138.24- 24 16384.40 90.36 274.87 6055.45 1072.57 -13749.76 3.00 177.35 13787.05 Hold for 1018.65' 25 17403.05 90.36 274.87 6049.10 1159.06 -14764.71 0.00 0.00 14805.14 2M-37 5.TD 020515 JC TD: 17403.05' MD, 6049.1' TVD 479f d72d4, 4 Intermediate II hole Iceberg 5309.1 size changed from 4¢7-3�175 r1 tr 564'10 1 (cross in C ) Surface Location 8-3/4 by 9-1/2" to Top HRZ is subject to Change 8-3/4" by 9-7/8". R...,.I,$o 70PDTE Kaiik 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 -Ilis on nvoi ng get out n the aud t p sonrove �l'-s -1- a-gs for the final well plan nnl wpli4e drnvjinn-q I al�n acknowledne that une-- nntilled oto : erwisA All tAraetq onvp. a Inn feet lateral tolerance Prepared by: Checked by: Accepted by: Approved by: Brij Potnis Nate Beck Erik Sterk Guo, Crews 11:50, June 02 2016 P N m 0 0 0 M_ c s 0 z 2M-37wp1 .1 13 -36 -31 Easting (3000 usftlin) 2M 2M-21 2M-06 2 -11 2M-19 2A-05 2 18 2M-20 2M-05 0 2H-16 2 -17 ^ ` 2M-16 03 upai'uk 2M Pad 2M-25 15 M-271 2M-26 2M-24 2H-13 0 2H -14A s 2H-14 1 w O O 2M-22 c 2M-17 2H-14 0 2M A 2M-02 RA n7 Y2K -03 )2W3Qjj *AK 15 K-29 2M -32L1 P61 2M-33 /2)",-35 M-08 2M-09 4 -06 - 8APB1 1 2S-14wp10 [Whale] - 2M -32L1 PB2 2M-34 2'iK-AA 2M-08 L2_wp04 2K- -13 -14 2�;a1i1 2S-11 2K-13AL2 2S-09wp07 [Tiger] 2M-08A_wp05 -28 K-28NLIIPff Easting (3000 usft/in) 2M-37wp12.1 Plan View While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 2M-37 Polygon 052316 B 4000 P a 3 M 7" x 8-3/4" by 9-7/8" z 4-1/2" x 6-1/8" 9-5/8" x 12-1/4" 13-3/8" x 16" 2000— 20" x 42" o 0 00 o co 0 0 0 O LO v ch o `. O 0 -2000 2M-37 1.FauIt1C35 020515 C 2M-37 2. Top C 021815 JC New Y 2M-37 31anding 051616 J 2M-37 4.Fault2 020515 J -4000 2M-37 5.TD 020515J -14000 -12000 -10000 -8000 -6000 -4000 -2000 0 West( -)/East(+) 2M-37wp12.1 Section View -2000— Base Permafrost 0 0° 20" x 42" 1000, -' CampSS 2000 � �® o C-50 oo Iceberg -FO--- o Base HRZ/Top Kalubik _ o 13-3/8" x 16" CO o ' ^o 0 o C-37 C-35 Fault 1 (cross in C-35) K-1 Fault 2 50-70' DTE Z3 4000 - - a, - oo - Top HRZ Top C -- - O TD in C4TID ,' __ _ -- -_.- -- _:__-____ ___ -- o o i n C c^' --. --- ------ -----'-'--- - -_ --COar ' lfZ _------- r ,� c7 ' CO .- 6 000 =-- - _: - - II 7 11 11 x 8-3/4 by 9-7/8 4-1 x 6-11g' o 0 o W 8000--L_r .......... .......... 7 0 2000 4000 6000 8000 10000 12000 14000 Vertical Section at 273.000 2M-37wp12.1 Section View Fault 1 (cross in C-35) 5550— 550 -- 0 0 (IV Top HRZ I 5700--jBase HRZ/Top Kalubik 9-5/8" x 12-1/4" j K-1 Q a) r _ 5850 ca Top C ami ti TD in C4 Fault 2 50-70' DTE TD in C4 G' 6000- o ry 0 00 -- o - 00 LO °' C) o o o CDW Ln CD - o 6150 7" x 8-3/4" by 9-7/8" 4-1/2" x 6-1/8" 9100 9800 10500 11200 11900 12600 13300 14000 14700 Vertical Section at 273.000 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-37 Plan: 2M-37 Plan: 2M-37wp12.1 Standard Proposal Report 02 June, 2016 Database: EDM Production Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Plan: 2M-37 Wellbore: Plan: 2M-37 Design: 2M-37wp12.1 SLB Standard Proposal Report Local Co-ordinate Reference: Well Plan: 2M-37 TVD Reference: Plan: 105.1+39 @ 144.10usft (Doyon 142) MD Reference: Plan: 105.1+39 @ 144.10usft (Doyon 142) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: System Datum: Mean Sea Level Geo Datum: Using Well Reference Point Map Zone: Using geodetic scale factor Site Kuparuk 2M Pad Site Position: usft From: Map usft Position Uncertainty: 0.00 usft Slot Radius: 0" Well Plan: 2M-37 Surface Location is subjectto Change Well Position +N/ -S 0.00 usft +E/ -W 0.00 usft Position Uncertainty 0.00 usft Ground Level: 105.10 usft Wellbore Plan: 2M-37 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) BGGM2016 9/13/2016 17.87 80.88 57,537 Design 2M-37wpl21 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 39.00 0.00 0.00 273.00 6/2/2016 11:43:58AM Page 2 COMPASS 5000,1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 2M-37 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 105.1+39 @ 144.10usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 105.1+39 @ 144.10usft (Doyon 142) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 2M-37 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-37 Design: 2M-37wpl2.1 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (usft) (°) (°) (usft) usft (usft) (usft) (°/100usft) (°1100usft) (°/100usft) (°) 39.00 0.00 0.00 39.00 -105.10 0.00 0.00 0.00 0.00 0.00 0.00 275.00 0.00 0.00 275.00 130.90 0.00 0.00 0.00 0.00 0.00 0.00 400.02 1.88 10.00 400.00 255.90 2.01 0.36 1.50 1.50 0.00 10.00 600.29 4.09 327.11 600.00 455.90 11.25 -2.96 1.50 1.11 -21.42 -68.00 1,479.92 26.08 327.11 1,444.10 1,300.00 202.34 -126.55 2.50 2.50 0.00 0.00 1,591.26 26.08 327.11 1,544.10 1,400.00 243.45 -153.14 0.00 0.00 0.00 0.00 3,160.83 67.51 271.75 2,633.94 2,489.84 581.68 -1,142.26 3.50 2.64 -3.53 -68.23 3,180.83 67.51 271.75 2,641.59 2,497.49 582.25 -1,160.73 0.00 0.00 0.00 0.00 3,265.41 70.17 270.36 2,672.12 2,528.02 583.70 -1,239.59 3.50 3.15 -1.64 -26.20 11,894.82 70.17 270.36 5,599.10 5,455.00 635.11 -9,357.28 0.00 0.00 0.00 0.00 12,032.53 69.92 273.40 5,646.10 5,502.00 639.35 -9,486.63 2.08 -0.18 2.20 95.54 12,052.53 69.92 273.40 5,652.97 5,508.87 640.46 -9,505.38 0.00 0.00 0.00 0.00 12,305.20 70.83 278.90 5,737.89 5,593.79 665.97 -9,741.89 2.08 0.36 2.18 81.02 12,813.90 70.83 278.90 5,904.96 5,760.86 740.29 -10,216.59 0.00 0.00 0.00 0.00 13,449.72 83.93 277.00 6,043.60 5,899.50 825.65 -10,829.75 2.08 2.06 -0.30 -8.27 13,488.46 83.93 278.27 6,047.70 5,903.60 830.77 -10,867.93 3.25 -0.01 3.27 90.16 13,491.60 83.93 278.27 6,048.03 5,903.93 831.21 -10,871.02 0.00 0.00 0.00 0.00 13,648.88 88.00 275.00 6,059.10 5,915.00 849.32 -11,026.81 3.32 2.59 -2.08 -38.79 13,668.88 88.00 275.00 6,059.80 5,915.70 851.06 -11,046.72 0.00 0.00 0.00 0.00 13,679.73 88.06 274.68 6,060.17 5,916.07 851.98 -11,057.53 3.00 0.52 -2.96 -80.02 15,417.29 88.06 274.68 6,119.10 5,975.00 993.64 -12,788.29 0.00 0.00 0.00 0.00 15,546.16 94.50 274.68 6,116.23 5,972.13 1,004.15 -12,916.63 5.00 5.00 0.00 0.00 16,246.16 94.50 274.68 6,061.31 5,917.21 1,061.07 -13,612.15 0.00 0.00 0.00 0.00 16,384.40 90.36 274.87 6,055.45 5,911.35 1,072.57 -13,749.76 3.00 -3.00 0.14 177.35 17,403.05 90.36 274.87 6,049.10 5,905.00 1,159.06 -14,764.71 0.00 0.00 0.00 0.00 6/2/2016 11:43:58AM Page 3 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 2M-37 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 105.1+39 @ 144.10usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 105.1+39 @ 144.10usft (Doyon 142) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 2M-37 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-37 Vert Section (usft) -105.10 197.10 Design: 2M-37wpl2.1 0.00 0.00 0.00 0.00 Planned Survey 0.00 0.00 0.00 0.00 0.00 the line before it. 0.00 0.01 1.50 Measured 0.36 1.50 Vertical 0.36 1.50 Depth Inclination Azimuth 1.50 Depth TVDss +N/ -S (usft) (°) (°) (usft) usft (usft) 39.00 0.00 0.00 39.00 -105.10 0.00 100.00 0.00 0.00 100.00 -44.10 0.00 119.00 0.00 0.00 119.00 -25.10 0.00 20" x 42" -108.15 2.50 117.11 -126.55 2.50 200.00 0.00 0.00 200.00 55.90 0.00 275.00 0.00 0.00 275.00 130.90 0.00 KOP: Start 1.5°/100' DLS, 10° TF, for 125.02' 300.00 0.37 10.00 300.00 155.90 0.08 400.00 1.87 10.00 399.98 255.88 2.01 400.02 1.88 10.00 400.00 255.90 2.01 Adjust TF to -68°, for 200.26' 500.00 2.81 340.28 499.90 355.80 5.93 600.00 4.09 327.13 599.72 455.62 11.23 600.29 4.09 327.11 600.00 455.90 11.25 Start 2.5°/100' DLS, 0° TF, for 879.63' 700.00 6.59 327.11 699.27 555.17 19.04 800.00 9.09 327.11 798.33 654.23 30.49 900.00 11.59 327.11 896.70 752.60 45.55 1,000.00 14.09 327.11 994.19 850.09 64.21 1,100.00 16.59 327.11 1,090.63 946.53 86.41 1,200.00 19.09 327.11 1,185.81 1,041.71 112.13 1,300.00 21.59 327.11 1,279.57 1,135.47 141.31 1,400.00 24.09 327.11 1,371.72 1,227.62 173.90 1,479.92 26.08 327.11 1,444.10 1,300.00 202.34 Hold for 111.34' 1,500.00 26.08 327.11 1,462.14 1,318.04 209.76 1,535.59 26.08 327.11 1,494.10 1,350.00 222.90 Base Permafrost 1,591.26 26.08 327.11 1,544.10 1,400.00 243.45 Start 3.5°/100' DLS, -68.23° TF, for 1569.57' 1,600.00 26.20 326.46 1,551.95 1,407.85 246.67 1,700.00 27.71 319.49 1,641.11 1,497.01 282.76 1,800.00 29.53 313.24 1,728.91 1,584.81 317.33 1,900.00 31.61 307.70 1,815.02 1,670.92 350.25 2,000.00 33.90 302.81 1,899.13 1,755.03 381.40 2,100.00 36.37 298.49 1,980.92 1,836.82 410.66 2,200.00 38.97 294.66 2,060.08 1,915.98 437.93 2,300.00 41.68 291.24 2,136.32 1,992.22 463.10 2,400.00 44.49 288.17 2,209.36 2,065.26 486.08 2,500.00 47.36 285.40 2,278.92 2,134.82 506.78 2,600.00 50.30 282.88 2,344.74 2,200.64 525.13 2,700.00 53.29 280.56 2,406.58 2,262.48 541.05 2,800.00 56.33 278.42 2,464.21 2,320.11 554.50 2,900.00 59.39 276.42 2,517.41 2,373.31 565.41 3,000.00 62.49 274.55 2,565.98 2,421.88 573.75 +E/ -W DLS Vert Section (usft) -105.10 197.10 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 1.50 -0.01 0.36 1.50 -0.25 0.36 1.50 -0.25 -0.19 1.50 0.50 -2.95 1.50 3.53 -2.96 1.50 3.54 -8.00 2.50 8.98 -15.40 2.50 16.98 -25.15 2.50 27.50 -37.21 2.50 40.52 -51.57 2.50 56.02 -68.21 2.50 73.98 -87.08 2.50 94.35 -108.15 2.50 117.11 -126.55 2.50 136.97 -131.35 0.00 142.15 -139.85 0.00 151.32 -153.14 0.00 165.67 -155.25 3.50 167.95 -182.56 3.50 197.10 -215.62 3.50 231.93 -254.31 3.50 272.30 -298.50 3.50 318.05 -348.01 3.50 369.03 -402.66 3.50 425.03 -462.25 3.50 485.85 -526.55 3.50 551.26 -595.32 3.50 621.03 -668.31 3.50 694.88 -745.25 3.50 772.54 -825.84 3.50 853.73 -909.79 3.50 938.13 -996.79 3.50 1,025.45 6/2/2016 11:43:58AM Page 4 COMPASS 5000.1 Build 74 Database: EDM Production Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 2M Pad North Reference: Well: Plan: 2M-37 Survey Calculation Method: Wellbore: Plan: 2M-37 Design: 2M-37wpl2.1 Azimuth SLB Standard Proposal Report Well Plan: 2M-37 Plan: 105.1+39 @ 144.10usft (Doyon 142) Plan: 105.1+39 @ 144.10usft (Doyon 142) True Minimum Curvature Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (1) (°) (usft) usft (usft) (usft) 2;465.64 3,100.00 65.60 272.78 2,609.74 2,465.64 579.48 -1,086.50 3.50 1,115.34 3,160.83 67.51 271.75 2,633.94 2,489.84 581.68 -1,142.26 3.50 1,171.14 Hold for 20'- 13-318" x 16" 3,180.83 67.51 271.75 2,641.59 2,497.49 582.25 -1,160.73 0.00 1,189.61 Start 3.5°/100' DLS, -26.2° TF, for 84.59' 3,200.00 68.11 271.43 2,648.83 2,504.73 582.74 -1,178.48 3.50 1,207.36 3,265.41 70.17 270.36 2,672.12 2,528.02 583.70 -1,239.59 3.50 1,268.44 Hold for 8629.41' 3,300.00 70.17 270.36 2,683.85 2,539.75 583.90 -1,272.13 0.00 1,300.94 3,400.00 70.17 270.36 2,717.77 2,573.67 584.50 -1,366.20 0.00 1,394.91 3,500.00 70.17 270.36 2,751.69 2,607.59 585.09 -1,460.27 0.00 1,488.89 3,600.00 70.17 270.36 2,785.61 2,641.51 585.69 -1,554.34 0.00 1,582.86 3,700.00 70.17 270.36 2,819.53 2,675.43 586.29 -1,648.41 0.00 1,676.83 3,800.00 70.17 270.36 2,853.45 2,709.35 586.88 -1,742.48 0.00 1,770.80 3,900.00 70.17 270.36 2,887.36 2,743.26 587.48 -1,836.55 0.00 1,864.78 4,000.00 70.17 270.36 2,921.28 2,777.18 588.07 -1,930.62 0.00 1,958.75 4,073.17 70.17 270.36 2,946.10 2,802.00 588.51 -1,999.45 0.00 2,027.51 CampSS 4,100.00 70.17 270.36 2,955.20 2,811.10 588.67 -2,024.69 0.00 2,052.72 4,200.00 70.17 270.36 2,989.12 2,845.02 589.26 -2,118.76 0.00 2,146.69 4,300.00 70.17 270.36 3,023.04 2,878.94 589.86 -2,212.83 0.00 2,240.67 4,400.00 70.17 270.36 3,056.96 2,912.86 590.46 -2,306.90 0.00 2,334.64 4,500.00 70.17 270.36 3,090.88 2,946.78 591.05 -2,400.97 0.00 2,428.61 4,600.00 70.17 270.36 3,124.79 2,980.69 591.65 -2,495.04 0.00 2,522.58 4,700.00 70.17 270.36 3,158.71 3,014.61 592.24 -2,589.11 0.00 2,616.55 4,800.00 70.17 270.36 3,192.63 3,048.53 592.84 -2,683.18 0.00 2,710.53 4,900.00 70.17 270.36 3,226.55 3,082.45 593.43 -2,777.25 0.00 2,804.50 5,000.00 70.17 270.36 3,260.47 3,116.37 594.03 -2,871.32 0.00 2,898.47 5,100.00 70.17 270.36 3,294.39 3,150.29 594.63 -2,965.39 0.00 2,992.44 5,200.00 70.17 270.36 3,328.31 3,184.21 595.22 -3,059.46 0.00 3,086.42 5,300.00 70.17 270.36 3,362.22 3,218.12 595.82 -3,153.53 0.00 3,180.39 5,400.00 70.17 270.36 3,396.14 3,252.04 596.41 -3,247.60 0.00 3,274.36 5,500.00 70.17 270.36 3,430.06 3,285.96 597.01 -3,341.67 0.00 3,368.33 5,600.00 70.17 270.36 3,463.98 3,319.88 597.60 -3,435.74 0.00 3,462.30 5,700.00 70.17 270.36 3,497.90 3,353.80 598.20 -3,529.81 0.00 3,556.28 5,800.00 70.17 270.36 3,531.82 3,387.72 598.80 -3,623.88 0.00 3,650.25 5,900.00 70.17 270.36 3,565.74 3,421.64 599.39 -3,717.95 0.00 3,744.22 6,000.00 70.17 270.36 3,599.66 3,455.56 599.99 -3,812.02 0.00 3,838.19 6,100.00 70.17 270.36 3,633.57 3,489.47 600.58 -3,906.09 0.00 3,932.17 6,200.00 70.17 270.36 3,667.49 3,523.39 601.18 -4,000.16 0.00 4,026.14 6,300.00 70.17 270.36 3,701.41 3,557.31 601.77 -4,094.23 0.00 4,120.11 6,400.00 70.17 270.36 3,735.33 3,591.23 602.37 -4,188.30 0.00 4,214.08 6,500.00 70.17 270.36 3,769.25 3,625.15 602.97 -4,282.37 0.00 4,308.06 6,600.00 70.17 270.36 3,803.17 3,659.07 603.56 -4,376.44 0.00 4,402.03 6,700.00 70.17 270.36 3,837.09 3,692.99 604.16 -4,470.51 0.00 4,496.00 6/2/2016 11:43:58AM Page 5 COMPASS 5000.1 Build 74 Database: EDM Production Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 2M Pad North Reference: Well: Plan: 2M-37 Survey Calculation Method: Wellbore: Plan: 2M-37 Vert Section Design: 2M-37wpl2.1 (1) Planned Survey SLB Standard Proposal Report Well Plan: 2M-37 Plan: 105.1+39 @ 144.10usft (Doyon 142) Plan: 105.1+39 @ 144.10usit (Doyon 142) True Minimum Curvature Meas u red Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (1) (1) (usft) usft (usft) (usft) 6,800.00 70.17 270.36 3,871.00 3,726.90 604.75 -4,564.58 0.00 4,589.97 6,900.00 70.17 270.36 3,904.92 3,760.82 605.35 -4,658.65 0.00 4,683.94 7,000.00 70.17 270.36 3,938.84 3,794.74 605.95 -4,752.72 0.00 4,777.92 7,036.14 70.17 270.36 3,951.10 3,807.00 606.16 -4,786.71 0.00 4,811.88 C-50 7,100.00 70.17 270.36 3,972.76 3,828.66 606.54 -4,846.79 0.00 4,871.89 7,200.00 70.17 270.36 4,006.68 3,862.58 607.14 -4,940.86 0.00 4,965.86 7,300.00 70.17 270.36 4,040.60 3,896.50 607.73 -5,034.93 0.00 5,059.83 7,400.00 70.17 270.36 4,074.52 3,930.42 608.33 -5,129.00 0.00 5,153.81 7,500.00 70.17 270.36 4,108.44 3,964.34 608.92 -5,223.07 0.00 5,247.78 7,600.00 70.17 270.36 4,142.35 3,998.25 609.52 -5,317.14 0.00 5,341.75 7,700.00 70.17 270.36 4,176.27 4,032.17 610.12 -5,411.21 0.00 5,435.72 7,800.00 70.17 270.36 4,210.19 4,066.09 610.71 -5,505.28 0.00 5,529.70 7,900.00 70.17 270.36 4,244.11 4,100.01 611.31 -5,599.35 0.00 5,623.67 8,000.00 70.17 270.36 4,278.03 4,133.93 611.90 -5,693.42 0.00 5,717.64 8,100.00 70.17 270.36 4,311.95 4,167.85 612.50 -5,787.49 0.00 5,811.61 8,200.00 70.17 270.36 4,345.87 4,201.77 613.09 -5,881.56 0.00 5,905.58 8,300.00 70.17 270.36 4,379.78 4,235.68 613.69 -5,975.63 0.00 5,999.56 8,400.00 70.17 270.36 4,413.70 4,269.60 614.29 -6,069.70 0.00 6,093.53 8,500.00 70.17 270.36 4,447.62 4,303.52 614.88 -6,163.77 0.00 6,187.50 8,600.00 70.17 270.36 4,481.54 4,337.44 615.48 -6,257.84 0.00 6,281.47 8,700.00 70.17 270.36 4,515.46 4,371.36 616.07 -6,351.91 0.00 6,375.45 8,800.00 70.17 270.36 4,549.38 4,405.28 616.67 -6,445.98 0.00 6,469.42 8,900.00 70.17 270.36 4,583.30 4,439.20 617.26 -6,540.05 0.00 6,563.39 9,000.00 70.17 270.36 4,617.21 4,473.11 617.86 -6,634.12 0.00 6,657.36 9,100.00 70.17 270.36 4,651.13 4,507.03 618.46 -6,728.19 0.00 6,751.34 9,200.00 70.17 270.36 4,685.05 4,540.95 619.05 -6,822.26 0.00 6,845.31 9,300.00 70.17 270.36 4,718.97 4,574.87 619.65 -6,916.33 0.00 6,939.28 9,315.12 70.17 270.36 4,724.10 4,580.00 619.74 -6,930.55 0.00 6,953.49 C-37 9,400.00 70.17 270.36 4,752.89 4,608.79 620.24 -7,010.40 0.00 7,033.25 9,500.00 70.17 270.36 4,786.81 4,642.71 620.84 -7,104.47 0.00 7,127.22 9,509.71 70.17 270.36 4,790.10 4,646.00 620.90 -7,113.60 0.00 7,136.35 Iceberg 9,600.00 70.17 270.36 4,820.73 4,676.63 621.43 -7,198.54 0.00 7,221.20 9,700.00 70.17 270.36 4,854.65 4,710.55 622.03 -7,292.61 0.00 7,315.17 9,800.00 70.17 270.36 4,888.56 4,744.46 622.63 -7,386.68 0.00 7,409.14 9,900.00 70.17 270.36 4,922.48 4,778.38 623.22 -7,480.75 0.00 7,503.11 10,000.00 70.17 270.36 4,956.40 4,812.30 623.82 -7,574.82 0.00 7,597.09 10,100.00 70.17 270.36 4,990.32 4,846.22 624.41 -7,668.89 0.00 7,691.06 10,200.00 70.17 270.36 5,024.24 4,880.14 625.01 -7,762.96 0.00 7,785.03 10,300.00 70.17 270.36 5,058.16 4,914.06 625.60 -7,857.03 0.00 7,879.00 10,400.00 70.17 270.36 5,092.08 4,947.98 626.20 -7,951.10 0.00 7,972.97 10,500.00 70.17 270.36 5,125.99 4,981.89 626.80 -8,045.17 0.00 8,066.95 10,600.00 70.17 270.36 5,159.91 5,015.81 627.39 -8,139.24 0.00 8,160.92 6/2/2016 11:43:58AM Page 6 COMPASS 5000.1 Build 74 Database: EDM Production Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Plan: 2M-37 Wellbore: Plan: 2M-37 Design: 2M-37wpl2.1 Planned Survey Measured +E/ -W DLS Vertical (usft) Depth Inclination Azimuth Depth TVDss (usft) (I V) (usft) usft 10,700.00 70.17 270.36 5,193.83 5,049.73 10,800.00 70.17 270.36 5,227.75 5,083.65 10,900.00 70.17 270.36 5,261.67 5,117.57 11,000.00 70.17 270.36 5,295.59 5,151.49 11,039.84 70.17 270.36 5,309.10 5,165.00 C-35 -8,891.80 0.00 8,912.70 632.75 11,100.00 70.17 270.36 5,329.51 5,185.41 11,200.00 70.17 270.36 5,363.42 5,219.32 11,300.00 70.17 270.36 5,397.34 5,253.24 11,400.00 70.17 270.36 5,431.26 5,287.16 11,500.00 70.17 270.36 5,465.18 5,321.08 11,600.00 70.17 270.36 5,499.10 5,355.00 11,700.00 70.17 270.36 5,533.02 5,388.92 11,741.52 70.17 270.36 5,547.10 5,403.00 Fault 1 (cross in C-35) 2.08 9,570.48 652.58 11,800.00 70.17 270.36 5,566.94 5,422.84 11,894.82 70.17 270.36 5,599.10 5,455.00 Start 2.08°/100' DLS, 95.54° TF, for 137.7' -9,830.35 11,900.00 70.16 270.48 5,600.86 5,456.76 12,000.00 69.98 272.68 5,634.95 5,490.85 12,032.53 69.92 273.40 5,646.10 5,502.00 Hold for 20'- Top HRZ - 9-5/8" x 12-1/4" 0.00 12,052.53 69.92 273.40 5,652.97 5,508.87 Start 2.08°/100' DLS, 81.02° TF, for 252.58' 0.00 12,100.00 70.08 274.44 5,669.20 5,525.10 12,200.00 70.43 276.62 5,702.99 5,558.89 12,300.00 70.81 278.79 5,736.18 5,592.08 12,305.20 70.83 278.90 5,737.89 5,593.79 Hold for 508.7' 12,400.00 70.83 278.90 5,769.02 5,624.92 12,500.00 70.83 278.90 5,801.87 5,657.77 12,600.00 70.83 278.90 5,834.71 5,690.61 12,700.00 70.83 278.90 5,867.55 5,723.45 12,780.84 70.83 278.90 5,894.10 5,750.00 Base HRZ/Top Kalubik 12,800.00 70.83 278.90 5,900.39 5,756.29 12,813.90 70.83 278.90 5,904.96 5,760.86 Start 2.08°/100' DLS, -8.27° TF, for 635.82' 12,900.00 72.60 278.63 5,931.97 5,787.87 13,000.00 74.66 278.32 5,960.15 5,816.05 13,003.59 74.73 278.31 5,961.10 5,817.00 K-1 13,100.00 76.72 278.02 5,984.87 5,840.77 13,200.00 78.78 277.72 6,006.08 5,861.98 13,300.00 80.84 277.43 6,023.77 5,879.67 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: SLB Standard Proposal Report Well Plan: 2M-37 Plan: 105.1+39 @ 144.10usft (Doyon 142) Plan: 105.1+39 @ 144.10usft (Doyon 142) True Minimum Curvature +N/ -S +E/ -W DLS Vert Section (usft) (usft) 5,049.73 627.99 -8,233.31 0.00 8,254.89 628.58 -8,327.38 0.00 8,348.86 629.18 -8,421.45 0.00 8,442.84 629.77 -8,515.52 0.00 8,536.81 630.01 -8,552.99 0.00 8,574.25 630.37 -8,609.59 0.00 8,630.78 630.97 -8,703.66 0.00 8,724.75 631.56 -8,797.73 0.00 8,818.73 632.16 -8,891.80 0.00 8,912.70 632.75 -8,985.87 0.00 9,006.67 633.35 -9,079.94 0.00 9,100.64 633.94 -9,174.01 0.00 9,194.61 634.19 -9,213.06 0.00 9,233.63 634.54 -9,268.08 0.00 9,288.59 635.11 -9,357.28 0.00 9,377.70 635.14 -9,362.15 2.08 9,382.56 637.73 -9,456.12 2.08 9,476.53 639.35 -9,486.63 2.08 9,507.09 640.46 -9,505.38 0.00 9,525.87 643.51 -9,549.89 2.08 9,570.48 652.58 -9,643.56 2.08 9,664.50 665.22 -9,737.04 2.08 9,758.51 665.97 -9,741.89 2.08 9,763.40 679.82 -9,830.35 0.00 9,852.46 694.43 -9,923.67 0.00 9,946.41 709.04 -10,016.99 0.00 10,040.37 723.65 -10,110.30 0.00 10,134.32 735.46 -10,185.74 0.00 10,210.27 738.26 -10,203.62 0.00 10,228.27 740.29 -10,216.59 0.00 10,241.33 752.75 -10,297.38 2.08 10,322.67 766.89 -10,392.28 2.08 10,418.17 767.39 -10,395.70 2.08 10,421.62 780.65 -10,488.19 2.08 10,514.67 794.04 -10,584.98 2.08 10,612.03 807.01 -10,682.54 2.08 10,710.14 61212016 11:43:58AM Page 7 COMPASS 5000.1 Build 74 Database: EDM Production Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 2M Pad North Reference: Well: Plan: 2M-37 Survey Calculation Method: Wellbore: Plan: 2M-37 Vert Section Design: 2M-37wpl2.1 (1) Planned Survey SLB Standard Proposal Report Well Plan: 2M-37 Plan: 105.1+39 @ 144.10usft (Doyon 142) Plan: 105.1+39 @ 144.10usft (Doyon 142) True Minimum Curvature Measured Vertical Depth Inclination Azimuth Depth TVDss +Nl-S +E/ -W DLS Vert Section (usft) (1 (1) (usft) usft (usft) (usft) 5,892.00 13,385.72 82.61 277.18 6,036.10 5,892.00 817.80 -10,766.68 2.08 10,794.72 Top C 13,400.00 82.90 277.14 6,037.90 5,893.80 819.57 -10,780.73 2.08 10,808.85 13,449.72 83.93 277.00 6,043.60 5,899.50 825.65 -10,829.75 2.08 10,858.12 Start 3.25°/100' DLS, 90.16° TF, for 38.74' 13,488.46 83.93 278.27 6,047.70 5,903.60 830.77 -10,867.93 3.25 10,896.52 Hold for 3.13' 13,491.60 83.93 278.27 6,048.03 5,903.93 831.21 -10,871.02 0.00 10,899.62 Start 3.32°/100' DLS, -38.79° TF, for 157.29' 13,500.00 84.15 278.09 6,048.90 5,904.80 832.40 -10,879.29 3.32 10,907.94 13,501.95 84.20 278.05 6,049.10 5,905.00 832.67 -10,881.21 3.32 10,909.88 TD in C4 13,600.00 86.73 276.01 6,056.85 5,912.75 844.63 -10,978.21 3.32 11,007.37 13,648.88 88.00 275.00 6,059.10 5,915.00 849.32 -11,026.81 3.32 11,056.15 Hold for 20' - 7" x 8-3/4' by 9-7/8" 13,668.88 88.00 275.00 6,059.80 5,915.70 851.06 -11,046.72 0.00 11,076.12 Start 3°/700' DLS, -80.02° TF, for 10.85' 13,679.73 88.06 274.68 6,060.17 5,916.07 851.98 -11,057.53 3.00 11,086.96 Hold for 1737.55' 13,700.00 88.06 274.68 6,060.86 5,916.76 853.63 -11,077.71 0.00 11,107.21 13,800.00 88.06 274.68 6,064.25 5,920.15 861.78 -11,177.32 0.00 11,207.11 13,900.00 88.06 274.68 6,067.64 5,923.54 869.93 -11,276.93 0.00 11,307.01 14,000.00 88.06 274.68 6,071.03 5,926.93 878.09 -11,376.54 0.00 11,406.91 14,100.00 88.06 274.68 6,074.42 5,930.32 886.24 -11,476.15 0.00 11,506.81 14,200.00 88.06 274.68 6,077.82 5,933.72 894.39 -11,575.76 0.00 11,606.71 14,300.00 88.06 274.68 6,081.21 5,937.11 902.55 -11,675.37 0.00 11,706.61 14,400.00 88.06 274.68 6,084.60 5,940.50 910.70 -11,774.98 0.00 11,806.51 14,500.00 88.06 274.68 6,087.99 5,943.89 918.85 -11,874.59 0.00 11,906.40 14,600.00 88.06 274.68 6,091.38 5,947.28 927.01 -11,974.20 0.00 12,006.30 14,700.00 88.06 274.68 6,094.77 5,950.67 935.16 -12,073.81 0.00 12,106.20 14,800.00 88.06 274.68 6,098.16 5,954.06 943.31 -12,173.42 0.00 12,206.10 14,900.00 88.06 274.68 6,101.56 5,957.46 951.47 -12,273.03 0.00 12,306.00 15,000.00 88.06 274.68 6,104.95 5,960.85 959.62 -12,372.64 0.00 12,405.90 15,100.00 88.06 274.68 6,108.34 5,964.24 967.77 -12,472.25 0.00 12,505.80 15,200.00 88.06 274.68 6,111.73 5,967.63 975.93 -12,571.86 0.00 12,605.70 15,300.00 88.06 274.68 6,115.12 5,971.02 984.08 -12,671.46 0.00 12,705.60 15,387.80 88.06 274.68 6,118.10 5,974.00 991.24 -12,758.92 0.00 12,793.31 Fault 2 50-70' DTE 15,400.00 88.06 274.68 6,118.51 5,974.41 992.23 -12,771.07 0.00 12,805.50 15,417.29 88.06 274.68 6,119.10 5,975.00 993.64 -12,788.29 0.00 12,822.77 Start 5°/100' DLS, 0° TF, for 128.87' 15,500.00 92.19 274.68 6,118.92 5,974.82 1,000.39 -12,870.71 5.00 12,905.43 15,546.16 94.50 274.68 6,116.23 5,972.13 1,004.15 -12,916.63 5.00 12,951.48 Hold for 700' 15,600.00 94.50 274.68 6,112.00 5,967.90 1,008.52 -12,970.13 0.00 13,005.14 6/2/2016 11:43:58AM Page 8 COMPASS 5000.1 Build 74 Database: EDM Production Local Co-ordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 2M Pad North Reference: Well: Plan: 2M-37 Survey Calculation Method: Wellbore: Plan: 2M-37 Design: 2M-37wp12.1 SLB Standard Proposal Report Well Plan: 2M-37 Plan: 105.1+39 @ 144.10usft (Doyon 142) Plan: 105.1+39 @ 144.10usft (Doyon 142) True Minimum Curvature 6/2/2016 11:43:58AM Page 9 COMPASS 5000.1 Build 74 Planned Survey Measured Vertical Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W DLS Vert Section (usft) (1) (1 (usft) usft (usft) (usft) 5,960.06 15,700.00 94.50 274.68 6,104.16 5,960.06 1,016.66 -13,069.49 0.00 13,104.79 15,800.00 94.50 274.68 6,096.31 5,952.21 1,024.79 -13,168.85 0.00 13,204.44 15,900.00 94.50 274.68 6,088.46 5,944.36 1,032.92 -13,268.21 0.00 13,304.09 16,000.00 94.50 274.68 6,080.62 5,936.52 1,041.06 -13,367.57 0.00 13,403.73 16,100.00 94.50 274.68 6,072.77 5,928.67 1,049.19 -13,466.93 0.00 13,503.38 16,200.00 94.50 274.68 6,064.93 5,920.83 1,057.32 -13,566.29 0.00 13,603.03 16,246.16 94.50 274.68 6,061.31 5,917.21 1,061.07 -13,612.15 0.00 13,649.03 Start 3°/100' DLS, 177.35° TF, for 138.24' 16,300.00 92.89 274.75 6,057.84 5,913.74 1,065.49 -13,665.70 3.00 13,702.73 16,384.40 90.36 274.87 6,055.45 5,911.35 1,072.57 -13,749.76 3.00 13,787.05 Hold for 1018.65' 16,400.00 90.36 274.87 6,055.35 5,911.25 1,073.89 -13,765.30 0.00 13,802.64 16,500.00 90.36 274.87 6,054.73 5,910.63 1,082.39 -13,864.94 0.00 13,902.59 16,600.00 90.36 274.87 6,054.11 5,910.01 1,090.88 -13,964.58 0.00 14,002.53 16,700.00 90.36 274.87 6,053.48 5,909.38 1,099.37 -14,064.21 0.00 14,102.48 16,800.00 90.36 274.87 6,052.86 5,908.76 1,107.86 -14,163.85 0.00 14,202.42 16,900.00 90.36 274.87 6,052.24 5,908.14 1,116.35 -14,263.49 0.00 14,302.37 17,000.00 90.36 274.87 6,051.61 5,907.51 1,124.84 -14,363.12 0.00 14,402.31 17,100.00 90.36 274.87 6,050.99 5,906.89 1,133.33 -14,462.76 0.00 14,502.25 17,200.00 90.36 274.87 6,050.37 5,906.27 1,141.82 -14,562.40 0.00 14,602.20 17,300.00 90.36 274.87 6,049.74 5,905.64 1,150.31 -14,662.04 0.00 14,702.14 17,400.00 90.36 274.87 6,049.12 5,905.02 1,158.80 -14,761.67 0.00 14,802.09 17,403.05 90.36 274.87 6,049.10 5,905.00 1,159.06 -14,764.71 0.00 14,805.14 TD: 17403.05' MD, 6049.1' TVD 6/2/2016 11:43:58AM Page 9 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 2M-37 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 105.1+39 @ 144.10usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 105.1+39 @ 144.10usft (Doyon 142) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 2M-37 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-37 (usft) (usft) Design: 2M-37wp12.1 0.00 6,119.10 Targets Measured Target Name Casing Hole Depth Depth hit/miss target Dip Angle Dip Din TVD +N/ -S +E/ -W Shape (°) (°) (usft) (usft) (usft) 2M-37 4.Fault2 020515 JC 0.00 0.00 6,119.10 993.64 -12,788.29 plan hits target center 119.00 20" x 42" 20 42 13,648.88 Circle (radius 100.00) 7" x 8-3/4" by 9-7/8" 7 9-7/8 12,032.53 5,646.10 2M-37 2. Top C 021815 JC New Y 0.00 0.00 6,043.60 825.65 -10,829.75 - plan hits target center -Circle (radius 100.00) 2M-37 Polygon 052316 BP 0.00 0.00 0.00 948.99 -11,018.65 plan misses target center by 5839.24usft at 11560.40usft MD (5485.67 TVD, 633.11 N, -9042.69 E) Polygon Point 1 0.00 0.00 0.00 Point 0.00 144.31 -1,761.38 Point 3 0.00 309.73 -3,737.72 Point 4 0.00 110.41 -3,754.41 Points 0.00 -55.02 -1,777.91 Point 6 0.00 -199.35 -16.33 2M-37 5.TD 020515 JC 0.00 0.00 6,049.10 1,159.06 -14,764.71 plan hits target center Circle (radius 100.00) 2M-37 31anding 051616 JC 0.00 0.00 6,059.10 849.32 -11,026.81 plan hits target center Circle (radius 100.00) 2M-37 1.Fault1C35 020515 JC 0.00 0.00 5,599.10 635.11 -9,357.28 plan hits target center Circle (radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name 3,160.83 2,633.94 13-3/8" x 16" 13-3/8 16 17,403.05 6,049.10 4-1/2"x6-1/8" 4-1/2 6-1/8 119.00 119.00 20" x 42" 20 42 13,648.88 6,059.10 7" x 8-3/4" by 9-7/8" 7 9-7/8 12,032.53 5,646.10 9-5/8" x 12-1/4" 9-5/8 12-1/4 6/2/2016 11:43:58AM Page 10 COMPASS 5000.1 Build 74 SLB Standard Proposal Report Database: EDM Production Local Co-ordinate Reference: Well Plan: 2M-37 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 105.1+39 @ 144.10usft (Doyon 142) Project: Kuparuk River Unit MD Reference: Plan: 105.1+39 @ 144.10usft (Doyon 142) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 2M-37 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-37 6,036.10 Top C Design: 2M-37wpl 2.1 C-50 4,073.17 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (usft) (usft) Name Lithology 12,780.84 5,894.10 Base HRZ/Top Kalubik 9,509.71 4,790.10 Iceberg 13,501.95 6,049.10 TD in C4 13,385.72 6,036.10 Top C 7,036.14 3,951.10 C-50 4,073.17 2,946.10 CampSS 12,032.53 5,646.10 Top HRZ 9,315.12 4,724.10 C-37 13,003.59 5,961.10 K-1 15,387.80 6,118.10 Fault 2 50-70' DTE 11,039.84 5,309.10 C-35 1,535.59 1,494.10 Base Permafrost 11,741.52 5,547.10 Fault 1 (cross in C-35) Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 275.00 275.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 10° TF, for 125.02' 400.02 400.00 2.01 0.36 Adjust TF to -68°, for 200.26' 600.29 600.00 11.25 -2.96 Start 2.5°/100' DLS, 0° TF, for 879.63' 1,479.92 1,444.10 202.34 -126.55 Hold for 111.34' 1,591.26 1,544.10 243.45 -153.14 Start 3.5°/100' DLS, -68.23° TF, for 1569.57' 3,160.83 2,633.94 581.68 -1,142.26 Hold for 20' 3,180.83 2,641.59 582.25 -1,160.73 Start 3.5°/100' DLS, -26.2° TF, for 84.59' 3,265.41 2,672.12 583.70 -1,239.59 Hold for 8629.41' 11,894.82 5,599.10 635.11 -9,357.28 Start 2.08°/100' DLS, 95.54° TF, for 137.7' 12,032.53 5,646.10 639.35 -9,486.63 Hold for 20' 12,052.53 5,652.97 640.46 -9,505.38 Start 2.08°/100' DLS, 81.02° TF, for 252.68' 12,305.20 5,737.89 665.97 -9,741.89 Hold for 508.7' 12,813.90 5,904.96 740.29 -10,216.59 Start 2.08°/100' DLS, -8.27° TF, for 635.82' 13,449.72 6,043.60 825.65 -10,829.75 Start 3.25°/100' DLS, 90.16° TF, for 38.74' 13,488.46 6,047.70 830.77 -10,867.93 Hold for 3.13' 13,491.60 6,048.03 831.21 -10,871.02 Start 3.32°/100' DLS, -38.79° TF, for 157.29' 13,648.88 6,059.10 849.32 -11,026.81 Hold for 20' 13,668.88 6,059.80 851.06 -11,046.72 Start 3°/100' DLS, -80.02° TF, for 10.85' 13,679.73 6,060.17 851.98 -11,057.53 Hold for 1737.55' 15,417.29 6,119.10 993.64 -12,788.29 Start 5°/100' DLS, 0° TF, for 128.87' 15,546.16 6,116.23 1,004.15 -12,916.63 Hold for 700' 16,246.16 6,061.31 1,061.07 -13,612.15 Start 3°/100' DLS, 177.35° TF, for 138.24' 16,384.40 6,055.45 1,072.57 -13,749.76 Hold for 1018.65' 17,403.05 6,049.10 1,159.06 -14,764.71 TD: 17403.05' MD, 6049.1' TVD 6/212016 11:43:58AM Page 11 COMPASS 5000.1 Build 74 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-37 Plan: 2M-37 2M-37wp12.1 Clearance Summary Anticollision Report 02 June, 2016 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M-37 - Plan: 2M-37 - 2M-37wp12.1 Datum Height: Plan: 105.1+39 @ 144.10usft (Doyon 142) Scan Range: 0.00 to 17,403.05 usft. Measured Depth. Scan Radius is 1,936.40 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.1 Build: 74 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 Anticollision Report for Plan: 2M-37 - 2M-37wp12.1 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M-37 - Plan: 2M-37 - 2M-37wp12.1 Scan Range: 0.00 to 17,403.05 usft. Measured Depth. Scan Radius is 1,936.40 usft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Site Name Depth Distance Depth Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) Kuparuk 2M Pad 2M-01 - 2M-01 - 2M-01 2M-01 - 2M-01 - 2M-01 2M-02 - 2M-02 - 2M-02 2M-02 - 2M-02 - 2M-02 2M-03 - 2M-03 - 2M-03 2M-03 - 2M-03 - 2M-03 2M-04 - 2M-04 - 2M-04 2M-04 - 2M-04 - 2M-04 2M-05 - 2M-05 - 2M-05 2M-05 - 2M-05 - 2M-05 2M-06 - 2M-06 - 2M-06 2M-06 - 2M-06 - 2M-06 2M-07 - 2M-07 - 2M-07 2M-07 - 2M-07 - 2M-07 2M-08 - 2M-08 - 2M-08 2M-08 - 2M-08 - 2M-08 2M-08 - 2M -08A - 2M-08A_wp05 2M-08 - 2M -08A - 2M-08A_wp05 2M-08 - 2M-08AL1 - 2M-08AL1_wp03 2M-08 - 2M-08AL1 - 2M-08AL1_wp03 2M-08 - 2M-08AL1-01 - 2M-08AL1-01_wp02 2M-08 - 2M-08AL1-01 - 2M-08AL1-01_wp02 2M-08 - 2M-08AL2 - 2M-08AL2_wp04 2M-08 - 2M-08AL2 - 2M-08AL2_wp04 2M-09 - 2M-09 - 2M-09 2M-09 - 2M-09 - 2M-09 2M-09 - 2M -09A - 2M -09A 2M-09 - 2M -09A - 2M -09A 02 June, 2016 - 11:44 Ellipse @Measured Separation Depth (usft) usft 543.47 128.25 543.47 115.24 640.35 129.35 640.35 113.94 591.37 146.66 591.37 132.35 662.13 147.44 662.13 131.42 47.10 80.16 47.10 77.86 907.95 90.89 907.95 69.80 587.84 155.07 587.84 140.62 610.88 155.24 610.88 140.21 48.10 179.95 48.10 177.20 495.14 183.29 495.14 171.25 399.20 194.58 399.20 185.27 1,288.91 215.44 1,288.91 181.50 423.18 209.35 423.18 199.77 589.66 211.53 589.66 197.74 468.60 221.16 468.60 210.40 538.55 222.26 538.55 209.67 468.60 221.16 468.60 210.85 538.55 222.26 538.55 210.13 468.60 221.16 468.60 210.85 538.55 222.26 538.55 210.13 468.60 221.16 468.60 210.85 538.55 222.26 538.55 210.13 468.60 221.16 468.60 210.85 538.55 222.26 538.55 210.13 422.64 238.99 422.64 229.48 492.91 239.85 492.91 228.51 422.64 238.99 422.64 229.48 492.91 239.85 492.91 228.51 Page 2 of 6 550.00 650.00 600.00 675.00 50.00 925.00 600.00 625.00 50.00 500.00 400.00 1,325.00 425.00 600.00 475.00 550.00 475.00 550.00 475.00 550.00 475.00 550.00 475.00 550.00 425.00 500.00 425.00 500.00 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Clearance Summary Based on Factor Minimum 9.854 Centre Distance 8.395 Clearance Factor 10.249 Centre Distance 9.200 Clearance Factor 34.945 Centre Distance 4.310 Clearance Factor 10.732 Centre Distance 10.325 Clearance Factor 65.543 Centre Distance 15.231 Clearance Factor 20.901 Centre Distance 6.348 Clearance Factor 21.847 Centre Distance 15.341 Clearance Factor 20.554 Centre Distance 17.657 Clearance Factor 21.469 Centre Distance 18.324 Clearance Factor 21.469 Centre Distance 18.324 Clearance Factor 21.469 Centre Distance 18.324 Clearance Factor 21.469 Centre Distance 18.324 Clearance Factor 25.133 Centre Distance 21.149 Clearance Factor 25.133 Centre Distance 21.149 Clearance Factor Separation Warning Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk Pass - Major Risk COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2M-37 - 2M-37wp12.1 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 21VI-37 - Plan: 21VI-37 - 2M-37wpI2.1 Scan Range: 0.00 to 17,403.05 usft. Measured Depth. Scan Radius is 1,936.40 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft) (usft) usft 2M-27 - 2M-27 - 2M-27 423.10 118.78 423.10 109.19 425.00 12.383 Centre Distance Pass - Major Risk 2M-27 - 2M-27 - 2M-27 520.37 119.78 520.37 107.71 525.00 9.919 Clearance Factor Pass - Major Risk 2M-28 - 2M-28 - 2M-28 148.10 105.08 148.10 102.17 150.00 36.133 Centre Distance Pass - Major Risk 2M-28 - 2M-28 - 2M-28 496.29 107.33 496.29 95.88 500.00 9.375 Clearance Factor Pass - Major Risk 2M-29 - 2M-29 - 2M-29 422.98 64.16 422.98 54.58 425.00 6.699 Centre Distance Pass - Major Risk 2M-29 - 2M-29 - 2M-29 691.11 65.02 691.11 48.81 700.00 4.010 Clearance Factor Pass - Major Risk 2M-30 - 2M-30 - 2M-30 569.93 39.87 569.93 26.64 575.00 3.014 Centre Distance Pass - Major Risk 2M-30 - 2M-30 - 2M-30 594.30 40.23 594.30 26.38 600.00 2.906 Clearance Factor Pass - Major Risk 2M-32 - 2M-32 - 2M-32 372.90 15.04 372.90 8.23 375.00 2.209 Centre Distance Pass - Major Risk 2M-32 - 2M-32 - 2M-32 397.75 15.16 397.75 7.93 400.00 2.097 Clearance Factor Pass - Major Risk 2M-32 - 2M-3211 - 2M-3211 372.90 15.04 372.90 8.23 375.00 2.209 Centre Distance Pass - Major Risk 2M-32 - 2M-3211 - 2M -32L1 397.75 15.16 397.75 7.93 400.00 2.097 Clearance Factor Pass - Major Risk 2M-32 - 2M-321-1-01 - 2M-32LI-01 372.90 15.04 372.90 8.69 375.00 2.369 Centre Distance Pass - Major Risk 2M-32 - 2M-32LI-01 - 2M-321-1-01 397.75 15.16 397.75 8.39 400.00 2.239 Clearance Factor Pass - Major Risk 2M-32 - 2M-32LI PB1 - 2M-321-1 PB1 372.90 15.04 372.90 8.23 375.00 2.209 Centre Distance Pass - Major Risk 2M-32 - 2M-3211 PBI - 2M-321-1 PB1 397.75 15.16 397.75 7.93 400.00 2.097 Clearance Factor Pass - Major Risk 2M-32 - 2M-321-1 PB2 - 2M-3211 PB2 372.90 15.04 372.90 8.69 375.00 2.369 Centre Distance Pass - Major Risk 2M-32 - 2M-3211 PB2 - 2M-321-1 P132 397.75 15.16 397.75 8.39 400.00 2.239 Clearance Factor Pass - Major Risk 2M-36 - 2M-36 - 2M-36 501.77 90.89 501.77 82.43 500.00 10.738 Centre Distance Pass - Major Risk 2M-36 - 2M-36 - 2M-36 575.30 91.41 575.30 81.70 575.00 9.407 Clearance Factor Pass - Major Risk 2M-36 - 2M-36PB1 - 2M-36PB1 501.77 90.89 501.77 82.30 500.00 10.575 Centre Distance Pass - Major Risk 2M-36 - 2M-36PB1 - 2M-36PB1 575.30 91.41 575.30 81.57 575.00 9.282 Clearance Factor Pass - Major Risk Plan: 2M-39 - 2M-39 - 2M-39 wp02 790.03 65.92 790.03 52.38 775.00 4.867 Centre Distance Pass - Major Risk Plan: 2M-39 - 2M-39 - 2M-39 wp02 941.35 67.26 941.35 51.06 925.00 4.152 Clearance Factor Pass - Major Risk 02 June, 2016 - 11:44 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2M-37 - 2M-37wp12.1 Survey tool program From To Survey/Plan Survey Tool (usft) (usft) 39.00 700.00 2M-37wpl2.1 GYD-GC-SS 700.00 1,700.00 2M-37wpl2.1 MWD 700.00 3,160.83 2M-37wp12.1 MWD+IFR-AK-CAZ-SC 3,160.83 4,660.83 2M-37wp12.1 MWD 3,160.83 12,032.53 2M-37wp12.1 MWD+IFR-AK-CAZ-SC 12,032.53 13,532.53 2M-37wp12.1 MWD 12,032.53 13,648.88 2M-37wp12.1 MWD+IFR-AK-CAZ-SC 13,648.88 15,148.88 2M-37wp12.1 MWD 13,648.88 17,403.05 2M-37wp12.1 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 02 June, 2016 - 11:44 Page 4 of 6 COMPASS 300 a) 150 U 0 0 Ladder View 11.44, June 02 2016 21x1�/� - 3 7 w p 1 2■ 1 The Reference Well is along the X-axis. Error Ellipses are the Sum of the Reference and Offset Well Errors. Equivelant Magnetic Distance 2000 4000 6000 8000 10000 12000 Displayed interval could be less than entire well:Measured Depth 39.00 To 17403.05 I SURVEY PROGRAM I CASING DETAILS I Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 700.00 2M-37wpl2.1 (Plan: 2M-37) GYD-GC-SS 119.00 119.00 20" x 42" 700.00 1700.00 2M-37wp12.1 (Plan: 2M-37) MWD 2633.94 3160.83 13-3/8" x 16" 700.00 3160.83 2M-37wpl2.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC 5646.10 12032.53 9-5/8" x 12-1/4" 3160.83 4660.83 2M-37wp12.1 (Plan: 2M-37) MWD 6059.10 13648.88 7" x 8-3/4" by 9-7/8" 3160.83 12032.53 2M-37wpl2.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC 6049.10 17403.05 4-1/2" x 6-1/8" 12032.53 13532.53 2M-37wpl2.1 (Plan: 2M-37) MWD 12032.53 13648.88 2M-37wpl2.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC 0 500 1000 1500 2000 2500 3000 3500 Partial Measured Depth Equivelant Magnetic Distance 2M-37wp12.1 39.00 To 17403.05 11:45, June 02 2016 CASING DETAILS TVD MD Name 119.00 119.00 20" x 42" 2633.94 3160.83 13-3/8" x 16" 5646.10 12032.53 9-5/8" x 12-1/4" 6059.10 13648.0' x 8-3/4" by 9-7/8" 6049.10 17403.05 4-1/2" x 6-1/8" Sumy PR- ...... RGGRAMmOep.M To 8�rveyl Pl an Tool 39.88 I..- 2,37T 12.1 (Plan: 2M-371 GYB-GC-55 711.1: 1):0.01 2X:,171 12.1 (Plan: 2M-37) ]00.10 3168.03 2M-J]u,p12.1 (Plan: 2M-]]1 MMI*IFR-AK-CA2-SC 3160.8) 46fiB.8] 2M- 1Ta 2.1 (Plan: 2X-37) 3161.83 12:]2.SJ 21-31p12.1 (Plan: 2M-37) R-AM-LAZ-SC 12033.53 1)5]2.53 2M -3T 12.1 (Plan: 2MT3 Z'IF 12032.53 13648.88 2M-37,12.1 (Plan: 2M-1)) MWaI FR-AK-CAZ-SC 13648.88 15148.08 2-7 12.1 (Plan: 2M -37j MW 13648.88 17403.05 2M-71 12.1 (P1 n. 2M-371 -FR.AR-CA2 MD Inc Azi TVD DIeg TFace Target 39.00 0.00 0.00 39.00 0.00 0.00 275.00 0.00 0.00 275.00 0.00 0.00 400.02 1.88 10.00 400.00 1.50 10.00 600.29 4.09 327.11 600.00 1.50 -68.00 1479.92 26.08 327.111444.10 2.50 0.00 1591.26 26.08 327.11 1544.10 0.00 0.00 3160.83 67.51271 .75 2633.94 3.50 -68.23 3180.83 67.51 271.75 2641.59 0.00 0.00 3265.41 70.17 270.36 2672.12 3.50 -26.20 11894.82 70.17 270.36 5599.10 0.00 0.00 2M-37 1.Fau1t1C35 020515 JC 12032.53 69.92 273.40 5646.10 2.08 95.54 12052.53 69.92 273.40 5652.97 0.00 0.00 12305.20 70.83 278.90 5737.89 2.08 81.02 12813.90 70.83 278.90 5904.96 0.00 0.00 13449.72 83.93 277.00 6043.60 2.08 -8.27 2M-37 2. Top C 021815 JC New Y 13488.46 83.93 278.27 6047.70 3.25 90.16 13491.60 83.93 278.27 6048.03 0.00 0.00 13648.88 88.00 275.00 6059.10 3.32 -38.79 2M-37 3.Landing 051616 JC 13668.88 88.00 275.00 6059.80 0.00 0.00 13679.73 88.06 274.68 6060.17 3.00 -80.02 15417.29 88.06 274.68 6119.10 0.00 0.00 2M-37 4.Fault2 020515 JC 15546.16 94.50 274.68 6116.23 5.00 0.00 16246.16 94.50 274.68 6061.31 0.00 0.00 17403.05 90.36 274.87 6049.10 0.00 0.00 2M-37 5.TD 020515 JC 0/360 225 -30/330 210 30 195 180 165 150 135 -60/300 120 10 90 7 275 460 460 �- 650 650 840 840 1030 1030 1220 1220 1410 1410 "" 1600 1600 2260 2260 2930 2930 3590 3590 4250 4250 --- 4910 4910 5570 5570 6240 6240 ---- -- 6900 6900 -- 8210 8210 9530 9530 10840 10840 10840 12150 12150 13470 13470 14780 14780 16090 16090 17403 sir�llyemo '�'�`aJ�q01J�� P i.. �o:■r,r r�� ,�,� \1� a d!to, ! a! i4�/�t5 MARRO ,t! �i��V1��i6� X01 �EIPV,C�f� y ri?Mv"-�.."`"g��,. -------------- WN ill 4yI 1 11:48, June 02 2 M-37wp 1 .1 c_ Easting (3000 usft/in) Easting (3000 usft/in) 2M-06 `4J/QIk7 2M-08A_wp05 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-37 Plan: 2M-37 Plan: 2M-37wp12.1 Error Ellipse Survey Report 02 June, 2016 Company: ConocoPhillips (Alaska) Inc -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Plan: 2M-37 Wellbore: Plan: 2M-37 Design: 2M-37wp12.1 SLB Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M-37 Plan: 105.1+39 @ 144.10usft (Doyon 142) Plan: 105.1+39 @ 144.10usft (Doyon 142) True Minimum Curvature 1.00 sigma EDM Production Survey Tool Program Date 6/2/2016 Azimuth Vertical From To Vertical (usft) (usft) Survey (Wellbore) Tool Name Description 39.00 700.00 2M-37wp12.1 (Plan: 2M-37) GYD-GC-SS Gyrodata gyro single shots 700.00 1,700.00 2M-37wpl2.1 (Plan: 2M-37) MWD MWD - Standard 700.00 3,160.83 2M-37wp12.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3,160.83 4,660.83 2M-37wp12.1 (Plan: 2M-37) MWD MWD - Standard 3,160.83 12,032.53 2M-37wp12.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC MWD+I FR AK CAZ SCC 12,032.53 13,532.53 2M-37wpl2.1 (Plan: 2M-37) MWD MWD - Standard 12,032.53 13,648.88 2M-37wpl2.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 13,648.88 15,148.88 2M-37wpl2.1 (Plan: 2M-37) MWD MWD - Standard 13,648.88 17,403.05 2M-37wpl2.1 (Plan: 2M-37) MWD+IFR-AK-CAZ-SC MWD+I FR AK CAZ SCC Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi+najor Semi+ninor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 119.00 0.00 0.00 119.00 0.19 0.00 0.19 0.00 1.15 0.00 0.00 0.19 0.19 0.00 GYD-GC-SS (1, 1) 275.00 0.00 0.00 275.00 0.30 0.00 0.30 0.00 1.15 0.00 0.00 0.30 0.30 0.00 GYD-GC-SS (1, 1) 400.02 1.88 10.00 400.00 0.48 0.00 0.48 0.00 1.15 0.01 0.01 0.48 0.48 135.00 GYD-GC-SS (1, 1) 600.29 4.09 327.11 600.00 0.76 0.00 0.76 0.00 1.15 0.03 0.03 0.76 0.76 45.00 GYD-GC-SS (1, 1) 1,479.92 26.08 327.11 1,444.10 1.43 -0.05 3.58 -0.31 1.14 0.24 0.40 3.58 1.52 146.17 MWD (1, 2) 1,535.59 26.08 327.11 1,494.10 1.60 -0.05 4.32 -0.40 1.17 0.28 0.50 4.32 1.67 146.24 MWD (1, 2) 1,591.26 26.08 327.11 1,544.10 1.60 -0.05 4.32 -0.40 1.17 0.28 0.50 4.32 1.67 146.24 MWD (1, 2) 3,160.83 67.51 271.75 2,633.94 2.76 -0.53 7.76 0.21 2.04 0.80 0.98 8.19 2.92 111.67 MWD+IFR-AK-CAZ-SC(2,2) 3,180.83 67.51 271.75 2,641.59 2.77 -0.53 7.87 0.16 2.01 0.80 0.98 8.30 2.99 111.63 MWD (2, 3) 3,265.41 70.17 270.36 2,672.12 2.70 -0.57 8.38 -0.23 2.03 0.81 1.03 8.84 3.00 110.17 MWD (2,3) 4,073.17 70.17 270.36 2,946.10 4.19 -0.57 19.04 -4.29 3.64 0.97 4.51 19.16 3.75 96.73 MWD (2,3) 7,036.14 70.17 270.36 3,951.10 7.35 -0.57 26.47 0.22 6.77 1.69 3.45 26.51 4.71 93.50 MWD+IFR-AK-CAZ-SC (3,3) 9,315.12 70.17 270.36 4,724.10 11.18 -0.57 39.78 0.22 10.43 2.43 5.61 39.79 5.76 91.89 MWD+IFR-AK-CAZ-SC (3,3) 9,509.71 70.17 270.36 4,790.10 11.52 -0.57 40.94 0.22 10.76 2.50 5.82 40.96 5.86 91.81 MWD+IFR-AK-CAZ-SC (3,3) 11,039.84 70.17 270.36 5,309.10 14.08 -0.57 49.73 0.22 13.18 3.08 7.52 49.74 6.61 91.35 MWD+IFR-AK-CAZ-SC (3,3) 11,741.52 70.17 270.36 5,547.10 15.28 -0.57 53.65 0.22 14.32 3.37 8.39 53.86 6.98 91.19 MWD+IFR-AK-CAZ-SC (3,3) 11,894.83 70.17 270.36 5,599.10 15.44 -0.57 54.41 0.22 14.47 3.41 8.51 54.42 7.03 91.17 MWD+IFR-AK-CAZ-SC (3,3) 12,032.53 69.92 273.40 5,646.10 15.79 -0.53 55.01 -0.19 14.70 3.47 8.68 55.06 7.10 91.17 MWD (3,4) 12,052.53 69.92 273.40 5,652.97 15.81 -0.53 55.12 -0.24 14.71 3.48 8.71 55.16 7.11 91.17 MWD (3,4) 12,305.20 70.83 278.90 5,737.89 16.15 -0.71 56.39 -2.28 14.74 3.59 9.21 56.87 7.19 91.40 MWD (3,4) 12,780.84 70.83 278.90 5,894.10 16.34 -0.71 60.43 -4.79 14.92 3.81 10.71 60.85 7.49 92.10 MWD (3,4) 12,813.90 70.83 278.90 5,904.96 16.35 -0.71 60.56 -4.87 14.93 3.81 10.76 60.98 7.50 92.12 MWD (3,4) 13,003.59 74.73 278.31 5,961.10 16.21 -1.69 63.40 -6.22 15.13 3.92 11.81 63.69 7.70 92.53 MWD (3,4) 13,385.72 82.61 277.18 6,036.10 16.06 -2.75 66.65 -7.72 15.41 3.97 13.00 66.83 7.88 92.91 MWD (3, 4) 13,449.72 83.93 277.00 6,043.60 16.03 -2.93 67.22 -7.98 15.46 3.98 13.21 67.38 7.90 92.97 MWD (3, 4) 13,488.46 83.93 278.27 6,047.70 16.09 -2.95 67.53 -8.41 15.50 3.98 13.37 67.81 7.92 93.02 MWD (3, 4) 13,491.60 83.93 278.27 6,048.03 16.09 -2.95 67.57 -8.43 15.51 3.98 13.38 67.85 7.93 93.02 MWD (3, 4) 13,501.95 84.20 278.05 6,049..10 15.26 -3.43 56.45 -0.50 14.94 3.99 10.58 58.61 7.45 91.74 MWD+IFR-AK-CAZ-SC (4,4) 13,648.88 88.00 275.00 6,059.10 15.14 -3.65 56.76 -0.46 14.94 4.00 10.62 58.85 7.54 91.77 MWD (4, 5) 13,668.88 88.00 275.00 6,059.80 15.14 -3.65 58.90 -0.57 14.94 4.00 10.64 58.99 7.55 91.78 MWD (4, 5) 13,679.73 88.06 274.68 6,060.17 15.14 -3.66 59.00 -0.58 14.94 4.00 10.66 59.07 7.55 91.79 MWD (4, 5) 15,387.80 88.06 274.68 6,116.10 15.47 -3.66 63.10 -0.27 15.28 4.05 12.07 63.16 7.80 92.13 MWD+IFR-AK-CAZ-SC (5,5) 15,417.29 88.06 274.68 6,119.10 15.47 -3.66 63.15 -0.27 15.28 4.05 12.08 63.21 7.80 92.14 MWD+IFR-AK-CAZ-SC (5,5) 15,546.16 94.50 274.68 6,116.23 14.84 -4.93 63.53 -0.27 15.33 4.05 12.18 63.59 7.82 92.17 MWD+IFR-AK-CAZ-SC (5,5) 16,246.16 94.50 274.68 6,061.31 15.18 -4.93 65.70 -0.27 15.66 4.01 12.59 65.75 7.93 92.33 MWD+IFR-AK-CAZ-SC (5,5) 16,364.40 90.36 274.87 6,055.45 15.70 -4.08 66.13 -0.31 15.74 4.01 12.68 66.19 7.95 92.36 MWD+IFR-AK-CAZ-SC (5, 5) 17,403.05 90.36 274.87 6,049.10 16.37 -4.08 69.64 -0.31 16.40 4.00 13.45 69.70 8.12 92.59 MWD+IFR-AK-CAZ-SC (5,5) 6/2/2015 11:51:38AM Page 2 COMPASS 5000.1 Build 74 2M-37wp12 Section View � Top C w w 0 rn _0 6025 TD in C4 N I I I --.. - --------- - -- ---- --- --- -- ----------- -------- L --------- 6050--- I I I I I I 0 4-1 x /8" o 0 0CL d) 7" x 8-3/4" by 9-1/2 r v 6075 v- Co a ) 00 L ~ o "7 oo Fault 2 50-70' DTE 6100- 100612561507500 LO 6125- 6150- 75009000 10500 12000 13500 15000 Vertical Section at 273.000 2M-37 -irillint! Hazards &.inmary 16" Hole / 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Gas Hydrates Low Monitor well at base of permafrost, controlled drilling rates, low mud temperatures. Additions of Lecithin. Abnormal Reservoir Pressure Moderate Offset well 2M-36 experienced sever mud lost. Monitor real time equivalent circulating density (ECD) to below Lost Circulation Moderate expected formation fracture gradient. Prepare enough lost Lost Circulation Low circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of Hole swabbing on trips Moderate hole if necessary. Monitor real time surveys closely, shut in nearby wells Anti -Collision Low that we have collision concerns with, run gyro survey to eliminate magnetic interference from nearby wells when needed Washouts /Hole Sloughing Moderate Keep mud temperatures as low as possible, minimize circulating time when possible 12-1/4" Hole - 9-5/8" Liner Interval Hazard Risk Level I Mitigation Strategy Stuck Pipe Low Keep good hole cleaning practices, monitor ECD and torque/drag real time The Iceberg formation pressure is estimated to be Abnormal Reservoir Pressure Moderate 10.1ppg. Weight up mud to 10.4-10.5ppg before drill into Iceberg formation. Monitor ECD to below expected formation fracture Lost Circulation Low gradient. Prepare enough lost circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of hole if necessary Attachment 2 - 2M-37 Drilling Hazards Summary.docx 6/5/2016 6:02:38 PM 8-3/4"x9-7/8" INTRM2 Section -7" Liner w/ Tieback Hazard Risk Level I Mitigation Strategy Stuck Pipe Low Keep good hole cleaning practices, monitor ECD and Abnormal Reservoir Pressure Moderate torque/drag real time The intermediate II section is penetrating into the reservoir of Kuparuk C, which is estimated to be 12.1 - Abnormal Reservoir Pressure Moderate 12.3 ppg. Utilize MPD for shale stability and pore pressure management. Shut in nearby injectors to prevent, Lost Circulation Moderate pore pressure rise. Monitor real time equivalent circulating density (ECD) to Lost Circulation Moderate below expected formation fracture gradient. Prepare Getting Liner to bottom Moderate enough lost circulation material on location. Reduce drilling ROP and trip speed when necessary. Hole swabbing on trips Moderate Reduce tripping speed, lower mud rheology, pump out of hole if necessary 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy The reservoir pore pressure of Kuparuk C is estimated to Abnormal Reservoir Pressure Moderate be 12.1-12.3 ppg. Utilize MPD pore pressure management to ensure wellbore overbalance. Shut in nearby injectors to prevent pore pressure rise. Stuck Pipe Low Keep good hole cleaning practices, use PWD tools monitoring and analysis, stabilized BHA Lost Circulation Moderate Reduced pump rates, mud rheology, use LCM program, control ECD below expected fracture gradient Differential Sticking Low Follow mud program, keep pipe moving when able Getting Liner to bottom Moderate Monitor T&D real time for early signs of issues, properly clean hole prior to pulling out of hole to run liner. Hole swabbing on trips Moderate Use proper tripping speed, monitor proper hole fill (use of trip sheets), pumping backreaming out if necessary Attachment 2 - 2M-37 Drilling Hazards Summary.docx 6/5/2016 6:02:38 PM Rig: Doyon 142 Location: Kuparuk Client: CPAI Revision Date: June 2, 2016 Prepared by: Britton Schlotz Location: Anchorage, AK Phone: (314) 600-1987 Email: bschlotz@slb.com < TOC at surface previous csg. < 20" casing at 110' MD < base of permafrost at 1,536' MD < top of tail at 2,661' MD �p < 13-3/8", 68 # casing in 16" OH TD at 3,161' MD Injector Preliminary Job Design Schlumberger 13-3/8" Surface Casing (initial) Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement S stems Z Volumes are based on 200% excess in the permafrost and 50% excess below the permafrost. The top of the tail slurry is designed to be at 2,661' MD. Lead Slurry Minimum thickening time: - 297 mn (pump time plus 120 mn) DeepCRETE @ 11 ppg - 1.91 ft3/sk 1.0191 ft3/ft x (1101) x 1.00 (no excess) = 112 ft3 0.4206 ft3/ft x (1536 - 110') x 3.00 (200% excess) = 1799 ft3 0.4206 ft3/ft x (2661 - 1536) x 1.50 (50% excess) = 710 ft3 112 ft3 + 1799 ft3 +710 ft3 = 2621 ft3 2621 ft3/ 1.91 ft3/sk = 1,373 sks (- 1,383 sks) Please have extra DeepCRETE on location for top out. 0.00 Tail Slurry Minimum thickening time: - 220 mn (pump time plus 120 mn) UniSLURRY @ 15.8 ppg - 1.16 ft3/sk 11 ppg DeepC23.6RETE Lead 0.4206 ft3/ft x (3161 - 2661) x 1.50 (50% excess) = 315 ft3 0.8407 ft3/ft x 80' (Shoe Joint) = 67 ft3 315 ft3 + 67 ft3 = 383 ft3 383 ft3 / 1.16 ft3/sk = 330 sks Round up to 340 sks BHST = 78 °F, Estimated BHCT = 75 °F. (based on Kuparuk temp. gradient) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (11111311 (mn) Innn1 CW100 7.00 20.0 2.9 2.9 2.9MUDPUSH II 7.00 75.0 10.7 13.6 13.6Pause 0.00 0.0 10.0 23.6 11 ppg DeepC23.6RETE Lead 7.00 466.8 66.7 g0.3 90.3Pause 0.00 0.00 10.0 100.3 15.8 ppg UniSL100.3URRY 7.00 68.2 9.7 110.0 110.OPause 0.00 0.0 10.0 120.0 Fresh 120.0 Water 7.00 10.0 1.4 121.4 121.4Pause 0.001 0.0 10.0 131.4 131.4Mud 8.00 444.3 55.2 186.6 186.6Mud 3.00 10.01 3.31 189.9 MUD REMOVAL Expected Mud Properties: 10.0 ppg, Pv < 20, TY < 20 Spacer Properties: 10.5 ppg MucIPUSH* II, Pv � 17-21, TY � 20-25 Centralizers: per CPAI program Client: CPA[ Revision Date: June 2, 2016 Prepared by: Britton Schlotz Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (314) 600-1987 Email: bschlotz@slb.com < 5", 19.5 # drill pipe r L 13-3/8", 68 # casing at 3,161' MD Top slurry at end of pumping < 10,530' MD < 9-5/8", 40 # casing in 12-1/4" hole TD at - 12,033' MD Injector Preliminary Job Design 9-5/8" Intermediate Liner (initial) Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 30% excess. Schlumberger Tail Slurry Minimum thickening time: - 227 mn (pump time plus 120 mn) 15.8 ppg Class G + adds - 1.16 ft3/sk Annular Volume: 0.3132 ft3/ft x (12033'- 10530') x 1.3 (30% excess) = 612 ft3 Shoe Volume: 0.4258 ft3/ft x 80'x 1.00 (no excess) = 34 ft3 Totals.- 612 otals:612 ft3 +34 ft3 = 646 ft3 646 ft3 / 1.16 ft3/sk = 557 sks (567 sks) BHST = 147 °F, Estimated BHCT = 108 °F. (BHST calculated using Kupurak temperature polynomial gradient) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume (bbl) Stage Time (mn) Cumulative Time (mn) CW100* 7.0 40.0 5.7 5.7 MUDPUSH II* 7.0 40.0 5.7 11.4 Pause 0.0 0.0 10.0 21.4 15.8 cement 7.0 115.1 16.4 37.9 Pause 0.0 0.0 10.0 47.9 Fresh Water 7.0 10.0 1.4 49.3 Pause 0.0 0.0 10.0 59.3 LSND mud 7.0 388.0 55.4 114.7 LSND mud 3.0 10.0 3.3 118.1 MUD REMOVAL Recommended Mud Properties: 10.5 ppg, Pv < 20, Tv < 20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.5 ppg MudPUSH* II, Pv � 25 - 30, Tv � 30 - 40 Centralizers: 1 centralizer per joint for cemented interval Client: CPAI Revision Date: June 2, 2016 Prepared by: Britton Schlotz Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (314) 600-1987 Email: bschlotz@slb.com < 5", 19.5 # drill pipe ,.� < TOC at 11,783' MD ys ` < liner hanger at 11,883' MD 9-5/8", 40 # casing at 12,033' MD < 7", 26 # casing in 8-3/4" x 9-7/8" hole TD at - 13,649' MD Injector Preliminary Job Design 7" Intermediate Liner (initial) Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 30% excess. Schlumberger Tail Slurry Minimum thickening time: - 227 mn (pump time plus 120 mn) 15.8 ppg Class G + adds - 1.16 ft3/sk Annular Volume: 0.1585 ft3/ft x (12033'- 11783') x 1.0 (no excess) = 40 ft3 0.2646 ft3/ft x (13544'- 12033') x 1.3 (30% excess) = 520 ft3 0.0383 ft3/ft x (13649' - 13544') x 1.3 (30% excess) = 20 ft3 Shoe Volume: 0.2148 ft3/ft x 80' x 1.0 (no excess) = 17 ft3 Totals: 40 ft3 + 520 ft3 + 20 ft3 + 17 ft3 = 597 ft3 609 ft3 / 1.16 ft3/sk = 515 sks (525 sks) BHST = 158 °F, Estimated BHCT = 129 °F. (BHST calculated using Kupurak temperature polynomial gradient) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume (bbl) Stage Time (mn) Cumulative Time (mn) CW100* 7.0 40.0 5.7 5.7 MUDPUSH II* 7.0 40.0 5.7 11.4 Pause 0.0 0.0 10.0 21.4 15.8 cement 7.0 107.5 15.4 36.8 Pause 0.0 0.0 10.0 46.8 Fresh Water 7.0 10.0 1.4 48.2 Pause 0.0 0.0 10.0 58.2 LSND mud 7.0 256.6 36.7 94.9 LSND mud 3.0 10.0 3.3 98.2 MUD REMOVAL Recommended Mud Properties: 12.5 ppg, Pv < 20, Tv < 20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 14.0 ppg MudPUSH* II, Pv �t 25 - 30, Tv � 30 - 40 Centralizers: 1 centralizer per joint for cemented interval 2M-37 Proposed Wellbore Schematic ConocoPhillips Spud mud 8.6-9.5 PPG :::W�St:$ak...... : 4,073' MD/2,946' TVD LSND WBM 9.5-10.5 PPG 9,509' MD/4,790' TVD - LSND WBM 10.5-12.5 PPG Conductor To Be Installed: 20" set @ +/-120' 9 5/8" x 13 3/8" Liner hanger: +/-2000' MD/1899'TVD Surface Casing: Below West Sak 13-3/8" 68# L-80 Hydril 563 o �c�wwn i� co wrin lll� .::::i: .......... Tubing: 3-%" 9.3# L-80 EUE8RD TOC @ +/-10,530' MD 9 5/8" x 7" liner hanger +/-11,883' MD Intermediate 1: 9 5/8" 40#, 1-80,13TCM +/-12,033' MD/5,646' TVD Updated: 06/05/16 by Guo 16" Surface Hole 12-1/4" Intermediate Hole 8-3/4" x 9-7/8" Intermediate Hole C -Sand Top: 13,386' MD/6,036' TVD HUU 7" x 4-%" Baker Flex Lock Liner hanger 7".7xP Liner Top Parker+/ -1 i 499' MD :.:. :.:: 26#;V.D$HInteimedai:27f :....::.:.: .: Bi TC_:M::..::::::.r::�.::::.::•=::i K;':: i::ii c=i ...=..........................:.............. i:yi;di.:. l.�...+/ 13 649RDJS 059': :.:.. �j�dz . sin .....::::::::: = =: ............... .. 000 000 000 000 000 000 000 000 000 Doo Doo 000 coo 000 coo 000 000 coo 000 000 S<. Doo 000 coo 000 000 oo 000 000 coo o00 . . . . . . . . . . . . . . . . . . . . . Production Liner: 4-1/2" 12.6# L-80 IBTM +/-17,403' MD/6,049' TVD Perforated Pups To DS2L (31 3 28 SA 6A 8A 9A 31 33 34 35 29 1361 2711 21 4 $ 6 17 �1 9 1P71113816 1p 1k lr 1k 1t I J1 1 38 1 SWSA To CPF-2 Well: 2M-37 — Data Input Name: V Loepp — Data Input Mud Weight (ppg) 12.50 j — Data Input Weak point or LOT - Measured depth (ft) 3,161' — Data Input Weak point or LOT True vertical depth (ft) 2,634' <== Data Input Weak point or LOT - Hole angle (deg) 67.00 <== Data Input Weak point or LOT - Hole size (in) 13.375" — Data Input Weak point pressure or LOT - EMW (ppg) 12.50 — Data Input Zone of interest - Measured depth (ft) 13,649' — Data Input Zone of interest - True vertical depth (ft) 6,059' — Data Input Zone of interest - Hole angle (deg) 88.00 — Data Input Zone of interest - Hole size (in) 12.250" — Data Input Zone of interest - Pore pressure EMW (ppg) 12.30 — Data Input Gas gradient (psi/ft) 0.10 — Data Input Bottom hole assembly OD (in) 8.0" — Data Input 200' Bottom hole assembly length (ft) — Data Input 5.500" Drill pipe OD (in) — Data Input BHA annular vol. @ zone of interest (bbllft) 0.0836 DP annular vol. @ zone of interest (bbl/ft) 0.1164 DP annular vol. weak point (bbl/ft) 0.1444 Additional safety margin (psi) 0.00 — Data Input Weak point pressure (psi): PIO 1,712 psi Wank nniof n—.... n - s.fuh. --in- Pmov 1 717 nci TRANSMITTAL LETTER CHECKLIST WELL NAME:--3�- PTD: � 16 - bp� Development ✓ Service _ Exploratory Stratigraphic Test _ Non -Conventional FIELD: POOL: iJky" kyl&r�I 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 WELL PERMIT CHECKLIST Field & Pool K PTD#: 2160820 —Com Administration I1 Appr Date PKB 6/8/2016 Engineering Appr Date VTL 7/5/2016 Geology Appr Date PKB 6/8/2016 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 K RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 2M-37 Program SER Well bore seg ❑ ny CONOCOPHILLIPS ALASKA INC Initial Class/Type SER/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal Permit fee attached_ --------- -NA--------------- ------------ ------------------ lease number appropriate_ - - -- - - - - - - - - - - - - -- - - - - - Yes - - - - - - - ADL0025586, Surf Loc; ADL0025585, Top Prod_ Intery &_TD. - - - - - - - - - _ - - - - - _ _ - - - - Unique well name and number _ - - Yes -- - - _ _ KRU 2M-37 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --------------------- Welllocated in_a_defined -pool - - - - - - - - - - - - - Yes - - - _ _ _ KUPARUK RIVER,_KUPARUK RIV OIL _- 4901.00,_goyerned_by Conservation_ Order No. 43-2D.- 32D.Welllocated Well-locatedproper distance from drilling unit -boundary -------- - - - - Yes - - - - - - - CO 432D contains no spacing restrictions with respect to drilling unit boundaries. - - - - - - - - - - - Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - _ - - Yes - - - - - _ _ CO 432D has no interwell spacing restrictions. _ _ _ _ - - - - - - - - - - - - - - - - Sufficient acreage available in -drilling unit - - - - - - - - - - - - - _ - Yes - - - - - - _ - - - - - _ - - - - - - - - - - - - - - _ - - - _ - - - - - - - - - - - - - - - - - - - - - _ - - - - - - - - - - - If_deviated, is wellbore plat included _ ---- ------- Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Operator only affected party- - - - - - - - - - - - - - - - - - - - - - - - - . Yes Wellbore_will be more than 500' from an external property line -where ownership or landownership -changes. - Operator has -appropriate bond in force - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Permit_ can be issued without conservation order_ -- - - - - - Yes - - - - - - -- - - - - - -- - - - - - - - - - - - - - - - - - -- - - - - Permit_can be issued without administrative approval . _ _ _ _ _ Yes _ - _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - Can permit -be approved before l5-daywait----------------- ------------ Yes - - - - -------------------------------- ------------------------------- Well located within area and -strata authorized by Injection Order # (put_ 10# in_comments)_(For_ Yes - - - - - A10.2C-Kuparuk River Unit. _ - - - - _ _ - - - - - - All wells -within 1/4—mile—area—of review identified (For service wel_I only)_ - _ _ - - - - _ - - - Yes - - - _ None- - - - - - - - - - - - - - - - - - . _ - - - - - - - - - - - - - - - - - - - - - - Pre -produced injector,. duration of pre production less than 3 months (For service well. only) Yes Operator -plans to_pre-produce for 6 months. - - - - - - Nonconven. ga_s conforms to AS31.05,030(1.1_.A),(j.2.A-D) - - - _ - - - - - - - - - - - - - - NA_- ------------------------- - - - - - - - - - - - - - 18 Conductor string_ provided - - - - - - _ - -------------------- -- - - - - - Yes - - - _ 80' conductor set- - - - - - - - - - - - - - - - - - - - - - - 19 Surface casing_ protectsall-known USDWs - - - - - - - - - - - - - - - - - - - - - - - Yes - - --3161'_MD _ - -- - - - - - -- - - - -- - - - - - - - - - - - - . - 20 CMT_ vol_adequate_to circulate_on conductor & surf_csg _ - - - - - - - - - - _ _ - - - - Yes - - - _ - - 126%_excess --------------------------- - - - - - - - 21 CMT vol adequate to tie-in long string to surf csg--------- - No_ - - - - - - - - - - - - - - - - - - - - - - - - - - 22 CMT will coverall -known -productive horizons_ - - - - - - - - - N_o- - - - - - - Productive interval will be completed with perforated pup liner_ 23 Casing designs adequate for C, -T, B &_ permafrost --- - - - - - - - _ Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage -or reserve pit Yes Rig has steel tanks; all waste approved disposal wells_ 25 -if _a_re-drill_, has_a 10-403 for abandonment been approved - - - - - NA. _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequate wellbore separation_ proposed- - - - - Yes - - - - - Anti -collision analysis complete; no major risk failures _ - - - - 27 If_diverter required, does it meet regulations_ -- - _ _ Yes - - - - - - _ Diverter is acceptable - - - - - - - - - - - - - - - - - - - - - - -- - - - . - . - _ _ - - - - - - - - 28 Drilling fluid_ program schematic-&- equip list adequate_ - - - - -- - Yes - - - Max formation_ pressure is_ 3861 psi(! 2.3 ppg EMW); will drill w/ 8.3-12.5 ppg-EMW 29 BOPEs,_do they meet regulation - - - - - - - - - - - - - - ----------- ---- - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPE.press rating appropriate; test to -(put psig in comments)_ - - - - - - - - - - - - - . Yes - - - - - - _ MPSP is 3257 psi; will test BOPs to 3500 psig------------- - - - - - - - - - - - - - - - - 31 Choke -manifold complies w/API_RP-53 (May 84)_ _ - - - - - - - - I Yes - - - - - - . - - - _ _ - - - - - 32 Work will occur without operation shutdown_ _ _ _ - - - - -- Yes - - _ _ - - - _ - _ - 33 Is presence of H2S gas probable_ - - - - - Yes - . - 1-12S measures required_ - - - - - - - - - - - - - - - - - - - - - - 34 Mechanical -condition of wells within AOR verified (For_ service well only) -- - - - - - _ - Yes - - - AOR complete; no wells. in 1/4 mile radius - - - - - - - - _ -- - - - - - - - - - - 35 Permit can be issued w/o hydrogen_ sulfide measures - - - - - - - - - No - - - - - - Wells_on 2M -Pad are H2S-bearing. H2Smesures required-- - - - - - - - - - - - 36 -Data-presented on potential overpressure zones - - ------- ---------- - - - - Yes . - - - - - Expected reservoir -pressure is 12.3 ppg EMW, will be drilled using -8.3 to 12.5 ppg mud. 37 Seismic_analysis of shallow gas_zones_ - - - - - - - - _ - - - - . - - - - - -N-A- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - 38 Seabed condition survey (if off -shore) . - - - - - - N'4 39 Contact name/phone for weekly. -progress reports [exploratory only] -- - - - - - - - - - - - - - - - NA_ - - - - _ Onshore service well- to be drilled. - - - - - - - - _ - _ . - - - - - - - _ .. - - Geologic Engineering Public Commissioner: Date: Commissioner- Date Commissioner Date