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218-171
ConocoPhillips 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-39 50103207950000 2181710 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-39 (PTD 218-171) MIT-OA Failed Date:Tuesday, February 18, 2025 8:38:28 AM From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, February 17, 2025 7:47 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: KRU 2M-39 (PTD 218-171) MIT-OA Failed Hi Chris, KRU 2M-39 (PTD 218-171) passed its SCLD down to 1000 ft with 1100 psi. This confirms the OA’s open shoe and concludes CPAI’s suspected OA integrity investigation. Thanks, Jaime From: Well Integrity Specialist CPF2 Sent: Monday, February 10, 2025 9:16 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2M-39 (PTD 218-171) MIT-OA Failed Hi Chris, KRU 2M-39 (PTD 218-171) is a WAG injection well currently on water injection. When the well was WAG’ed from MI to water Operations requested support on target pressures for the IA and OA to help monitor for changes in well integrity. Our drilling reports suggest the well possibly has an open shoe. I requested DHD conduct an MIT-OA to verify the status of the shoe. This MIT-OA failed on 2/7/2025 at 830 psi. DHD intends to conduct a SCLD to verify the surface casing integrity down to 1000ft. The well is still currently on water injection as at this time CPAI expects the well has an open shoe rather than a mechanical failure. The SCLD will verify this and action will be taken to shut in the well if the SCLD fails. Please let me know if you disagree with the plan or have any questions. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 1 Gluyas, Gavin R (OGC) From:Wallace, Chris D (OGC) Sent:Monday, February 10, 2025 12:27 PM To:AOGCC Records (CED sponsored) Subject:FW: KRU 2M-39 (PTD 218-171) MIT-OA Failed Attachments:AnnComm Surveillance TIO for 2M-39.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, February 10, 2025 9:16 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2M-39 (PTD 218-171) MIT-OA Failed Hi Chris, KRU 2M-39 (PTD 218-171) is a WAG injection well currently on water injection. When the well was WAG’ed from MI to water Operations requested support on target pressures for the IA and OA to help monitor for changes in well integrity. Our drilling reports suggest the well possibly has an open shoe. I requested DHD conduct an MIT-OA to verify the status of the shoe. This MIT-OA failed on 2/7/2025 at 830 psi. DHD intends to conduct a SCLD to verify the surface casing integrity down to 1000ft. The well is still currently on water injection as at this time CPAI expects the well has an open shoe rather than a mechanical failure. The SCLD will verify this and action will be taken to shut in the well if the SCLD fails. Please let me know if you disagree with the plan or have any questions. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 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. 2M-39 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2M-39 2025-01-30 472 245 -227 OA 2M-39 2025-02-07 380 780 400 OA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By LAST TAG:2M-39 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Converted from pre-production to injection on 10/11/19 10/16/2019 2M-39 pproven Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 18.50 Top (ftKB) 36.8 Set Depth (ftKB) 170.0 Set Depth (TVD) … 170.0 Wt/Len (l… 154.19 Grade Top Thread Casing Description SURFACE OD (in) 13 3/8 ID (in) 12.42 Top (ftKB) 37.4 Set Depth (ftKB) 2,860.0 Set Depth (TVD) … 2,646.8 Wt/Len (l… 68.00 Grade L-80 Top Thread Hydril 563 Casing Description INTERMEDIATE 1A OD (in) 9 5/8 ID (in) 8.68 Top (ftKB) 34.7 Set Depth (ftKB) 16,012.6 Set Depth (TVD) … 5,803.3 Wt/Len (l… 40.00 Grade L80 Top Thread Hydril 563 Casing Description INTERMEDIATE 2 OD (in) 7 ID (in) 6.28 Top (ftKB) 15,786.6 Set Depth (ftKB) 17,895.0 Set Depth (TVD) … 6,149.0 Wt/Len (l… 26.00 Grade L-80 Top Thread TSH 563 Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 17,702.0 Set Depth (ftKB) 24,761.0 Set Depth (TVD) … 6,207.4 Wt/Len (l… 12.60 Grade L-80 Top Thread Hyd563 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 17,702.0 6,115.9 80.03 SBE 11.05' Seal Bore Extension 4.000 17,725.2 6,119.9 80.03 HANGER DG Flex-Lock Liner Hanger 4.200 17,745.0 6,123.4 80.03 SBE Seal Bore Extension 4.000 18,045.5 6,168.4 84.25 SWELL PACKER Packer, Swell 5.5" , HYD563 "A" 3.958 18,588.0 6,149.8 95.02 SWELL PACKER Packer, Swell 5.5" , HYD563 "B" 3.958 20,380.2 6,163.3 87.65 SWELL PACKER Packer, Swell 5.5" , HYD563 "C" 3.958 21,009.8 6,197.2 87.04 SWELL PACKER Packer, Swell 5.5" , HYD563 "D" 3.958 21,512.1 6,204.8 90.46 SWELL PACKER Packer, Swell 5.5" , HYD563 "E" 3.958 22,051.0 6,205.2 88.87 SWELL PACKER Packer, Swell 5.5" , HYD563 "F" 3.958 23,318.6 6,203.9 92.12 SWELL PACKER Packer, Swell 5.5" , HYD563 "G" 3.958 23,935.8 6,193.7 90.11 SWELL PACKER Packer, Swell 5.5" , HYD563 "H" 3.958 Tubing Strings Tubing Description TUBING PRODUCTION String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.8 Set Depth (ft… 17,769.0 Set Depth (TVD) (… 6,127.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection Hyd563 Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.8 31.8 0.00 HANGER Cameron 4-1/2" Tubing Hanger 3.950 78.9 78.9 0.01 XO REDUCING X-O 4-1/2" Hyd563 box X 3-1/2" Hyd 563 Pin 3.950 2,169.8 2,102.9 28.99 NIPPLE Landing Nipple 3-1/2" DS 2.813" 2.813 16,125.6 5,835.9 73.76 NIPPLE Landing Nipple DS 2.75" 2.750 17,718.2 6,118.7 80.03 NO GO LOCATOR Locator No Go (5" OD) 2.992 17,719.1 6,118.9 80.03 SEAL ASSY GBH-22 Seal Assembly 2.992 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 5 2,718.2 2,541.9 Camco KBMG 5 GAS LIFT DMY BK 0.000 0.0 9/28/2019 4 6,241.9 3,700.3 Camco KBMG 5 GAS LIFT DMY BK 0.000 0.0 9/29/2019 3 10,272.1 4,551.3 Camco KBMG 5 GAS LIFT DMY BK 0.000 0.0 9/29/2019 2 12,859.2 5,096.7 Camco KBMG 5 GAS LIFT DMY BK 0.000 0.0 9/30/2019 1 15,001.8 5,544.6 Camco KBMG 5 GAS LIFT DMY BK 1.000 0.0 7/16/2019 Notes: General & Safety End Date Annotation 8/13/2019 NOTE: WELLVIEW SCHEMATIC w/Alaska Schematic10.0 10/11/2019 NOTE: Converted from pre-production to injection HORIZONTAL, 2M-39, 10/16/2019 4:07:26 PM Vertical schematic (actual) LINER; 17,702.0-24,761.0 INTERMEDIATE 2; 15,786.6- 17,895.0 SEAL ASSY; 17,719.1 NO GO LOCATOR; 17,718.2 NIPPLE; 16,125.6 INTERMEDIATE 1A; 34.7- 16,012.6 GAS LIFT; 15,001.8 GAS LIFT; 12,859.2 GAS LIFT; 10,272.1 GAS LIFT; 6,241.9 SURFACE; 37.4-2,860.0 GAS LIFT; 2,718.1 NIPPLE; 2,169.8 CONDUCTOR; 36.8-170.0 XO REDUCING; 78.9 HANGER; 31.8 KUP INJ KB-Grd (ft) 36.75 Rig Release Date 7/17/2019 2M-39 ... TD Act Btm (ftKB) 24,800.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032079500 Wellbore Status INJ Max Angle & MD Incl (°) 95.56 MD (ftKB) 18,798.55 WELLNAME WELLBORE2M-39 Annotation LAST WO: End DateH2S (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-39 KUPARUK RIV UNIT 2M-39 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 2M-39 50-103-20795-00-00 218-171-0 W SPT 6119 2181710 1530 1154 1159 1159 1150 432 504 499 495 4YRTST P Sully Sullivan 6/22/2024 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-39 Inspection Date: Tubing OA Packer Depth 170 2000 1970 1960IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240624200833 BBL Pumped:7.4 BBL Returned:5 Thursday, July 25, 2024 Page 1 of 1 MEMORANDUM TO: Jim Regg �1 , 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-39 KUPARUK RIV UNIT 2M-39 Sre: Inspector Reviewed By: P.I. Supry Comm Well Name KUPARUK RfV UNIT 2M-39 API Well Number 50-103-20795-00-00 Inspector Name: Adam Earl Insp Num: mitAGE200617113151 Permit Number: 218-171-0 Inspection Date: 6/13/2020 ✓' Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2M-39 Type jp� W .'f\/]) 6119 - TUbing 1395 - 1410 - 1410 - 1410 " 2181710 'type 'fest FlInterval $PT Test psl 1530 jA 650 2200 - 2160 - 2150 ped: 6.5 BBL - �.�-- Returned: 6.5 _ pA 440 - 510 _ 4vRTST IP1— P Notes: MIT IA Wednesday, June 17, 2020 Page 1 of l DATA SUBMITTAL COMPLIANCE REPORT 10/31/2019 Permit to Drill 2181710 Well Name/No. KUPARUK RIV UNIT 2M-39 �-t ��(� Operator ConocoPhillips Alaska, Inc. API No. 50-103-20795-00-00 MD 24800 TVD 6208 Completion Date 7/17/2019 Completion Status 1-0IL Current Status WAGIN UIC Yes REQUIRED INFORMATION Mud Log No ✓ Samples No ✓ Directional Survey Yes f DATA INFORMATION List of Logs Obtained: GR/Res/Sonic Scope Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED C 31107 Digital Data ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C ED C 31107 Digital Data 31107 Digital Data 31107 Digital Data 31107 Digital Data 31107 Digital Data 31107 Digital Data 31107 Digital Data 31107 Digital Data 31107 Digital Data 31107 Digital Data 31107 Digital Data 31107 Digital Data (from Master Well Data/Logs) Log Log Run Interval CHI Scale Media No Start Stop CH Received Comments 195 465 8/15/2019 Electronic Data Set, Filename: CPAI_2M- 39PB1_Scope Gamma Ray_LWD001_RM.las 370 2773 8/15/2019 Electronic Data Set, Filename: CPAI_2M- 39PB1_Scope Gamma Ray_LWD002_RM.las 2523 15988 8/15/2019 Electronic Data Set, Filename: CPAI_2M- 39 VISION Service RM LAS LWC006.las 15946 17864 8/15/2019 Electronic Data Set, Filename: CPAI_2M- 39 VISION Service RM LAS LWD007.las 17774 20836 8/15/2019 Electronic Data Set, Filename: CPAI_2M- 39 VISION Service RM LAS LWD008.las 20746 24770 8/15/2019 Electronic Data Set, Filename: CPAI_2M- 39_VISION_Service_RM_LAS LWD009.las 101 24770 8/15/2019 Electronic Data Set, Filename: CPAI_2M- 39 VISION Service RM LAS.las 8/15/2019 Electronic File: CPAI_2M-39 Scope GR_LW D001 Drilling Pass_RM.dlis 8/15/2019 Electronic File: CPAI_2M-39_Scope GR_LW D001 Drilling Pass_RM.html 8/15/2019 Electronic File: CPAI_2M-39 Scope GR_LW D002_Drilling Pass_RM.dlis 8/15/2019 Electronic File: CPAI_2M-39_Scope GR_LWD002_Drilling Pass_RM.html 8/15/2019 Electronic File: CPAI_2M-39_Scope GR_LWD002_Ream Up Pass_RM.dIis 8/15/2019 Electronic File: CPAI_2M-39_Scope GR_LWD002_Ream Up Pass_RM.html AOGCC Page I of 5 1Lursday, October 31, 2019 DATA SUBMITTAL COMPLIANCE REPORT 10/31/2019 Permit to Drill 2181710 Well Name/No. KUPARUK RIV UNIT 2M-39 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20795.00-00 MD 24800 TVD 6208 Completion Date 7/17/2019 Completion Status 1-0I1- Current Status WAGIN UIC Yes ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI 2M- 39_VISION Service_RM_DLIS_LWD006.dlis ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI _2M- 39_VISION Semice_RM_DLIS_LWD006.html ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI 2M- 39_VISION Service_RM_DLIS_LWD007.diis ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI 2M- 39_VISION Service_RM_DLIS_LWD007.htm1 ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI 2M- 39_VISION Service_RM_DLIS_LWD008.diis ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI_2M- 39_VISION Service_RM_DLIS_LWD008.html ED C 31107 Digital Data 811512019 Electronic File: CPAI_2M- 39_VISION Service_RM_DLIS_LW0009.diis ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI-2M- PAI2M- 39 — VISION 39_VISION Service_RM_DLIS_LWD009.html ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI _2M- 39_VISION Service_RM_DLISAlis ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI-2M- 39—VISION Semice_RM_DLIS.html ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI _2M- 39_VIS ION_Service_2MD_RM.pdf ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI_2M- 39_V ISION_Semice_2TVD_RM.pdf ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI_2M- 39_VIS ION_Service_5MD_RM. pdf ED C 31107 Digital Data 8/15/2019 Electronic File: CPAI - _2M 39_V I S ION_Service_5TVD_RM. pdf ED C 31107 Digital Data 8/15/2019 Electronic File: 2M-39 NAD27 EOW Compass Surveys [Canvas].W ED C 31107 Digital Data 8/15/2019 Electronic File: 2M-39 NAD27 EOW Compass Surveys [Macro].t# ED C 31107 Digital Data 8/15/2019 Electronic File: 2M-39 NAD27 EOW Compass Surveys [Petrel].txt ED C 31107 Digital Data 8/15/2019 Electronic File: 2M-39 NAD27 EOW Compass Surveys [Survey].txt AOGCC Page 2 of 5 Thursday, October 31, 2019 DATA SUBMITTAL COMPLIANCE REPORT 10131/2019 Permit to Drill 2181710 Well NamelNo. KUPARUK RIV UNIT 2M-39 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20795-00-00 MD 24800 TVD 6208 Completion Date 7/17/2019 Completion Status 1-0I1- Current Status WAGIN UIC Yes ED C 31107 Digital Data 8/15/2019 Electronic File: 2M-39 NAD27 EOW Compass Surveys.pdf ED C 31107 Digital Data 8/15/2019 Electronic File: 2M-39 NAD83 EOW Compass Surveys [Canvas].txt ED C 31107 Digital Data 8/15/2019 Electronic File: 2M-39 NAD83 EOW Compass Surveys [Macro].txt ED C 31107 Digital Data 8/15/2019 Electronic File: 2M-39 NA083 EOW Compass Surveys [Petrel].txt ED C 31107 Digital Data 8/15/2019 Electronic File: 2M-39 NAD83 EOW Compass Surveys [Survey]Axt ED C 31107 Digital Data 8/15/2019 Electronic File: 2M-39 NAD83 EOW Compass Surveys.pdf Log 31107 Log Header Scans 0 0 2181710 KUPARUK RIV UNIT 2M-39 LOG HEADERS Log 31107 Log Header Scans 0 0 2181710 KUPARUK RIV UNIT 2M-39 PB1 LOG HEADERS ED C 31108 Digital Data 195 465 8/15/2019 Electronic Data Set, Filename: CPAI_2M- 39PB1_Scope Gamma Ray_LWD001_Miss ED C 31108 Digital Data 370 2773 8/15/2019 Electronic Data Set, Filename: CPAI_2M- 39PB1_Scope Gamma Ray_LWD002_RM.las ED C 31108 Digital Data 2773 15798 8/15/2019 Electronic Data Set, Filename: CPAI 2M- 39PB1_VISION Resistivity_LWD003_RM.las ED C 31108 Digital Data 195 15798 8/15/2019 Electronic Data Set, Filename: CPAI_2M- 39PB1_VISION Resistivity_RM.las ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI_2M-39PB1_Scope GR_LW D001_Ddlling Pass_RM.dlis ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI_2M-39PB1_Scope GR_LWD001_Drilling Pass_RM.html ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI_2M-39PB1_Scope GR_LWD002_Drilling Pass_RM.dlis ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI_2M-39PB1_Scope GR_LWD002_Drilling Pass_RM.html ED C 31108 Digital Data 8/15/2019 Electronic File: CPA] _2M-39PB1 Scope GR_LWD002_Ream Up Pass_RM.dlis ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI_2M-39PB1_Scope GR_LWD002_Ream Up Pass_RM.html AOGCC Page 3 of 5 Thursday, October 31, 2019 DATA SUBMITTAL COMPLIANCE REPORT 10/31/2019 Permit to Drill 2161710 Well Name/No. KUPARUK RIV UNIT 21VI-39 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20795-00-00 MD 24800 TVD 6208 Completion Date 7/17/2019 Completion Status 1-0I1- Current Status WAGIN UIC Yes ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI_2M-39P81_VISION Resistivity_LW D003_Drilling Pass_RMAlis ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI 2M-39PB1 VISION Resistivity_LW D003_Drilling Pass _RM.html ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI_2M-39PB1 VISION Resistivity_RM.dlis ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI_2M-39PB1 VISION Resistivity_RM.html ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI 2M- 39PB 1 _VIS ION_Resistivity_2MD_RM.pdf ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI_21vI- 39PB 1 _VIS ION_Resistivity_2TVD_RM. pdf ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI 2M- 39PB 1 _VISI ON_Resistivity_5MD_RM.pdf ED C 31108 Digital Data 8/15/2019 Electronic File: CPAI 2M- 39PB 1 _VISI ON_Resistivity_5TVD_RM.pdf ED C 31108 Digital Data 8/15/2019 Electronic File: 2M-39PB1 NAD27 EOW Compass Surveys [Canvas].txt ED C 31108 Digital Data 8/15/2019 Electronic File: 2M-39PB1 NAD27 EOW Compass Surveys [Macro].txt ED C 31108 Digital Data 8/15/2019 Electronic File: 2M-39PB1 NAD27 EOW Compass Surveys [Petrel].txt ED C 31108 Digital Data 8/15/2019 Electronic File: 2M -39P81 NAD27 EOW Compass Surveys [Survey].txt ED C 31108 Digital Data 8/15/2019 Electronic File: 2M-39PB1 NAD27 EOW Compass Surveys.pdf ED C 31108 Digital Data 8/15/2019 Electronic File: 2M-39PB1 NAD83 EOW Compass Surveys [Canvas].txt ED C 31108 Digital Data 8/15/2019 Electronic File: 2M-39PB1 NAD83 EOW Compass Surveys [Macro].txt ED C 31108 Digital Data 8/15/2019 Electronic File: 2M-39PB1 NAD83 EOW Compass Surveys [Petrel].txt ED C 31108 Digital Data 8/15/2019 Electronic File: 2M-39PB1 NAD83 EOW Compass Surveys [Survey].txt ED C 31108 Digital Data 8/15/2019 Electronic File: 2M-39PB1 NAD83 EOW Compass Surveys.pdf AOGCC Page 4 of 5 Thursday, October 31, 2019 DATA SUBMITTAL COMPLIANCE REPORT 10/3112019 Permit to Drill 2181710 Well Name/No. KUPARUK RIV UNIT 2M-39 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20795-00-00 MD 24800 TVD 6208 Completion Date 7/17/2019 Completion Status 1 -OIL Current Status WAGIN UIC Yes Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED � Completion Report /0 Directional / Inclination Data s✓ Mud Logs, Image Files, Digital Data Y / t® Core Chips Y PrL' � Production Test Informations, -,r NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files D Core Photographs Y Geologic Markers/Tops ' r ) Daily Operations Summary YS Cuttings Samples Y /0 Laboratory Analyses Y COMPLIANCE HISTORY Completion Date: 7/17/2019 Release Date: 1/8/2019 Description Date Comments Comments: Compliance Reviewed 13y: Y ( t, Date: AOGC( Page 5 of 5 Thursday. October 31. 2019 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Mandy Pogany Staff Petroleum Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-39 Permit to Drill Number: 218-171 Sundry Number: 319-431 Dear Ms. Pogany: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .aogcc.alaska.gov Enclosed is the approved application for the 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, opf---� Daniel T. Seamount, Jr. Commissioner DATED this 2-L dayof September, 2019. RMSIC' OCT 0 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 90 AAC 25 980 1. Type of Request: Abandon LJ Plug Perforations LJ Fracture Stimulate Li Repair Well LJ Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ PROD to WAG Other: ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhllll s Alaska Inc. Exploratory ❑ Development 21 Stratigraphic ❑ Service ❑ 218-171 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 501032079500-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? - KRU 2M-39 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Least: Number): 10. Field/Pool(s): r ADL 25585, ADL 25586, ADL 25590 1 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): 24,800' 6,208' 24,761' 6,207' 3182 Casing Length Size MD TVD Burst Collapse Structural Conductor 133' 20" 170' 170' Surface 2,823' 133/8" 2,860' 2,647' Intermediate 1A 15,978' 95/8" 16,013' 5,803' Intermediate 2,108' 7" 17,895' 6,149' Liner 7,059' 4 1/2" 24,761' 16,207' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 18,689'-24,761' MD 6,140'-6,207' TVD 3.500" L-80 17,769' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Sealbore and Seal Assembly, no SSSV 17,719' MD / 6,119' TVD 12. Attachments: Proposal Summary LIJ Wellbore schematic Ld 13. Well Class after proposed work: Detailed Operations Program ❑ AOR Detail ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/25/2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Mandy Pogany Contact Name. Mandy Pogany Authorized Title: St Pe oleum Engineer Contact Email: mandy.w. pogany@cop.com Contact Phone: 907-263-4148 Authorized Signature: Date: 9/19/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3 I VNI W31 —/ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Ltj Location Clearance El Other: Post Initial Injection MIT Req'd? Yes `U' No ❑ Spacing Exception Required? Yes ❑ No Belo' Subsequent Form Required: M 9 APPROVED BY 77 /C, Y �lL l ` Approved by: COMMISSIONER THE COMMISSION Date: `,�a_'11311, Submit Form and ��s (� `�L 9i,25%q ORIGINAL RBDMS>C OCT 01 ?p�q r.rm So-ao a vises 4/ 017 Approved application is valid for 12 months from the date of approval. c a mems in nupllwte ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 September 19, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 2M-39 (PTD# 218-171). We are requesting approval to convert this well from oil production service to water -alternating -gas injection service. This request for conversion concludes the pre -production period for this rotary horizontal well in the Kuparuk River Oil Pool. If you have any questions regarding this matter, please contact me at 907-263-4148. Sincerely, Ma dy Pogany Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Proposal Schematic 2M-39 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 21VI-39 (PTD# 218-171) from oil production service to water alternating gas injection service. Area of Review: KRU Well 21VI-39 was completed as a rotary horizontal producer 7/17/19. The long-term plan for the well is to provide injection support for producer 21VI-40. The top of the Kuparuk was found at 17,823' MD/ 6,137' TVD Area map with 1/4 mile radius around target injection zone (see attachment) The attached map shows that there are no wells withing the 1/4 mile radius of the 2M-39 penetration of the Kuparuk sand. Mechanical condition of the well to be converted: The mechanical condition of KRU Well 21VI-39 is good. Isolation of the injection tubing / casing annulus is provided by a GBH -22 seal assemby at 17,719' MD / 6,119' TVD and a liner Seal Bore Extension at 17,745' MD / 6,123' TVD. A State -witnessed MIT -IA will be performed once 21VI-39 is converted to water injection, online and stabilized Interpretation of cement quality: The 13-3/8" surface casing was cemented with 1536sx of 11.0 ppg Class G and 243 sx of 12.0 ppg Class G. The 9-5/8" intermediate 1A casing was cemented with 847 sx of 15.8 Class G. The 7" intermediate 2 casing was cemented with 605 sx of 15.8 Class G. SonicScope log indicates top of cement at 15,786' MD MUSTANGIA MUSTANG 1 ADL390680 t' i i UJ cc ADL380051 ADL025585 T11NRaE T10NR8E ADL025590 N N w ADL025603 q mll% N 2S -13L1 NW 0 o.z o.a o.s Miles ADL025586 z 2M -0i ADL025589 Well Path — Well Trajectory Open Interval OQuarter Mile Open Interval Buffer Other Wells Active ---- Drilled Suspended P&A'd CPAI Lease BRPC Lease ConocoPhillips Alaska 2M-39 Injection Analysis 9/12/2019 vI � dl � 71 � ADL390691 =� Y d1 y tol Y ry0^ I ! a i� j� a MUSTANGIA MUSTANG 1 ADL390680 t' i i UJ cc ADL380051 ADL025585 T11NRaE T10NR8E ADL025590 N N w ADL025603 q mll% N 2S -13L1 NW 0 o.z o.a o.s Miles ADL025586 z 2M -0i ADL025589 Well Path — Well Trajectory Open Interval OQuarter Mile Open Interval Buffer Other Wells Active ---- Drilled Suspended P&A'd CPAI Lease BRPC Lease ConocoPhillips Alaska 2M-39 Injection Analysis 9/12/2019 21 81 71 31107 218171 31108 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑� Gas❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development EJ Exploratory F1 GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions: Service ❑ Stratigraphic Test [_1 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Abend.: 7/17/2019 ' 218-1711319-267 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 4/26/2019 50-103-20795-00.00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: Surface: 5167' FNL, 5150' FEL, Sec 27, T11N, R8E, UM 717/2019 KRU 2M-39/2M-39PB1 Top of Productive Interval: 9. Ref Elevations: KB:137.45 17. Field / Pool(s): 3405' FNL, 2867' FEL, Sec 31, T11N, R8E, UM GL: 100.7 BF: Kuparuk River FieldlKuparuk Oil Pool Total Depth: 4945' FNL, 4184' FEL, Sec 6, T1 ON, RBE, UM 10. Plug Back Depth MDITVD: 2476116207 18. Property Designation: r ADL 25586, ADL 25585, ADL 25590 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 487970 y- 5948985 Zone- 4 11. Total Depth MD/TVD: 2480016208 19. DNR Approval Number: 931894000,931893000,931698000 TPI: x- 474416 y- 5945501 . Zone- 4 12. SSSV Depth MDlrVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 473103 y- 5938686 ' Zone- 4 N/A 1491/1476 ' 5. Directional or Inclination Survey: Yes ❑� (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 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/Sonic Scope Aloy AIPItiI "IbIM10( 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20 154 H-40 37 170 37 170 42 Installed 133/8 68 L-80 37 2860 37 2647 16 1536sx 11 ppg Class G, 243sx 12ppq Class G 9518 40 L-80 35 16013 35 5803 12114 847sx 15.8 Class G 7 26 L-80 15787 17895 5739 6149 8 112x9 7/8 605sx 15.8 Class G 41/2 12.6 L-80 17702 24761 6116 6207 161/8 Perforated Liner 24. Open to production or injection? Yes I] No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perld):i :71e3lzai SIZE DEPTH SET (MD) 1PACKEIR SET (MD/TVD) 31/2 17769 N/A PERFORATED LINER@: 18689-24761 MD and 6140-6207 TVD COMPLETION 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE Was hydraulic fracturing used during completion? Yes ❑ No ❑r Per 20 AAC 25.283 (i)(2) attach electronic and printed information VERIFIEd DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): 8/8/2019 GAS LIFT Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 8/9/2019 1 9.50hrs Test Period 1430 923 678 112bean 646 Flow Tubing Press. 283 Casing Press: IM ICalculated 124 -Hour Rate Oil -Bbl: Gas -MCF: 2264 Water -Bbl: 1655 Oil Gravity - API (corr): Not Yet Available Form 10-407 Revised 5/2017 rT7- 16/13/19 CONTINUED N PAGE 2 RBDMS.=^AUG Z 3 1019 St �IIAL only l o�iq /y Id 14 28. CORE DATA Conventional Core(s): Yes ❑ No El Sidewall Cores: Yes ❑ No ❑� If Yes, list formations and intervals cored (MD[TVD, Fromrro), 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 ❑� Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Surface Permafrost - Base 1491 1476 Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval 17823 6137 , information, including reports, per 20 AAC 25.071. Formation @ TPI -Kuparuk C 2M-39PB1 15798 5802 TO 24800 6208 r Formation at total depth: Ku aruk C 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, paleontoloaical report, production or well test results, perg 7 . 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: G. L. Alvord Contact Name: Keith Herrin Authorized Title: Alaska Drilling Manager Contact Email: Keith.E.Herrin i KUP PROD WELLNAME 2M-39 WELLBORE 2M-39 c/� oc(;ry Well Altrihuh max TD �..Vr N�rM e•�'llp5 Laid Name Wellb¢re Asan. Wellorereame ncI5(D 1hund879 ACI B+m IXMBI Alaska. Inc. KUPARUK RIVER UNIT 5010320)9500 PROD SSfi 18798 55 24,8000 NIPPLE MORDoxru, 2M Y, a+vm+se s+aT AM Last7ag VwtiulacMmh(aNW) Annotation Depth Mae) EM Get Museum Iu1MaOBy xPNGEfl, 318 .AST T"su if 1 1 121M-39 Iennelt ......................... Last Rev Reason DN Aat WNIMxe Iu1Mo0By ---.-....--""'-"-. ........... �"-�� ��� """"" "REV GLion ul REASON: PUII PIu9, innall new GLD 81312019 2M-39 lennalt Casing Strings zo Rarc1.: ffia Casing Description M0.) IG(nl Top (XNB1 Depth mee) sal Dset Depth(T Du .. annuen(I Grace CONDUCTOR 20 18.50 36.8 1]00 170.0 154.19 T¢peaa rm CONDJCTOR:Dai Casing Isecnpron Mg.) .Dern TOP(ftl BN DeNM1 anal BN Dead (TAR.-MUm11... SURFACE 1338 12.42 37.4 2,860.0 2,6468 GnM 68.00 L-80 TOpTbrye Hying M3 xlvvLs:2+We easlt, DesprlNbn Der (in) lO and T0I W.Pa IM(B) BN Dander Tri U INTERMEDIATE IA 9518 8.68 3 16,012.6 5,803.3 M. (1... Gtee 40.00 LBO Top h. Hydnl 563 el se DB) sN Drom MD),.. casing Desenpltn OD (in) Mhig Tepryucorderorder MB INTERMEDIATE 7 6.28 15,786.6 17,895.0 6,1490 wuLen(I Grin. 26.00 L-80 TOPrnreae TBH 563 GAs 11FT', 2.11.1 cram. GeecnpMn OD OM ID (In) rcP MBB) BN Deppe mat, Bet Depu firviq. Much ll... fusee PRODUCTION 412 396 7,702.0 24.7610 6,20]4 12.60 L$0 T_Tnreae Hytl5fi3 Tubing Strings TOOInOGesenpign B+11np se -jun UPPER 3112 1iN 299 Top IXNB) 31.8 Set Depth IX.. 177690 set De IND)... 6127.5 WIDand) 930 Grace L-80 Top Gonnac+pn HyP5fi3 SURFACE, T 4.aaaU COMPLETION Completion Details (NSIIFi: &2at9 Top (TVD) TOPInd Top(M1MB) MMB) C) Mm Des Com Nominal 10 (1.) 31.8 31. 0.00 HANGER Cameron 4-12' Tubing Hanger 390 Dns LIFT: bpapt+ 70.9 709 0.01 XO Redudng X-0 412" HyG5fi3 box X 3-12 Hyd 563 Pin 3.950 2,169.8 2,102.9 28,99 NIPPLE Landmg NIPPI. 3-112"DS 2T13 813 GASLIFT128692 16,125.6 5,835.9 73.76 NIPPLE Landing NiPPIe DS 275" 2.750 17,718.2 6,118.7 80.03 N7UU Locator NS On (FOD) 2992 LOCATOR GAsr-cTla.ama 17,]19.1 6,1189 80.03 SEAL ASSY GBH -22 Seal Assembly 2992 Mandrel Inserts n Ni H ToMe) VaWe WCX TOP IXMBI MBB. Mab MMeI On fin) Sery Tyq Tape ID Run PotBM T (P-1) (In) Ip31) Ran pat COm 5 2,718.2 2,541 9 ammo KBMG 5 GAS LIFT GLV BK 0.156 1,73). 7292019 INTERMENAMM., 1.M24 4 6241.9 3,]00.3 Campo KBMG 5 GAS LIFT GLV BK 0.188 i,J50.0 7129/2019 3 1 7.1 4,5513 Cameo KBMG 5 GAS LIFT GLV BK 0.188 1,326.0 .1302019 mFxe'.'Dart 21 128592 5,096.7Campo KBMG I 5 I.. LIFT ItJV BK I 0250 1 8'12019 1 15001.8 5,544.6 lCmrpp. KBMG 1 5 lGAS LIFT JU.y I I 1.000 I I ..16'2019 Notes: General 8 Safety Enc Dale Annotation NO GG LOCATOR. 17,7182 8/312019 NOTE:W"'a'W SCHEMA TIC wIRuaska Spbenneac100 tri Assv: tr.rl..t IMERMEDNTIIIJIS]M.. 1".. I PRODUCTION: 17.M 2a,]41 a'\- operations Summary (with Timelog Depths) 2M-39 IMF Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stan T ne I End Time Dur (hr) Phase Op Code Activity Code Tine P -T -x Opeiabon (ItKB) End Depth (flKB) 4/22/2019 14127J2019 6.00 MIRU MOVE MOB P Trouble shoot top drive, repair same. 0.0 0.0 00:00 06:00 Survice drag chain. Tie off geronimo line. 4/22/2019 4/22/2019 6.00 MIRU MOVE MOB P R/D pit and motor complex. Reposition 0.0 0.0 06:00 12:00 and stage complex. Skid rig floor forward. 4/22/2019 4/22/2019 6.00 MIRU MOVE MOB P Move sub and line up on 2M-39well. 0.0 0.0 12:00 18:00 Install BOP's onto pedestal. Secure same. 4/22/2019 4/23/2019 6.00 MIRU MOVE MOB P Spot sub over 2M-39 well center. Shim 0.0 0.0 18:00 00:00 and level rig. Set stompers. Spread hurculite and place rig mats for pit, motor and pipe shed complex. Move same into position. Skid rig floor to drilling position. Note: Rig/Road clearance 65' upper measurement and 75' lower measurement 4/23/2019 4/23/2019 6.00 MIRU MOVE MOB P Spot motor and pit complex, hook 0.0 0.0 00:00 06:00 survice lines, tarp off cellar area, hook up mud lines 4/23/2019 4/23/2019 6.00 MIRU MOVE MOB P Bring drilling tools to rig floor, (trouble 0.0 0.0 06:00 12:00 shooting top drive) 4/23/2019 4/23/2019 6.00 MIRU MOVE MOB P (Trouble shooting top drive) working 0.0 0.0 12:00 18:00 on rig acceptance checklist, welding projects on cuttings shoot and drag chain, adjust suction linkage in pits, prepair derrick board for drilling operations. 4/23/2019 4/24/2019 6.00 MIRU MOVE MOB P M/U saver sub and inspect top drive, 0.0 0.0 18:00 00:00 R/U controls on knife valve on diverter line and 21-1/4" annular. Install heater above drag chain cuttings dump. load pipe shed with 5-7/8" HWT drill pipe. 4/24/2019 4/24/2019 12.00 MIRU MOVE MOB P Continue with pre -spud checklist, 0.0 0.0 00:00 12:00 Weld brackets for hose reels, Swap rotator lines on top drive, Install riser and install air boot on same, On high line power at 10:30 his 4/24/2019 4/24/2019 6.00 MIRU MOVE MOB P Continue with pre -spud checklist, 0.0 0.0 1200 18:00 Install flow line, Install mouse hole, Mobilize drilling tools to rig floor, R/U drilling bails and 5-7/8" elevators. Trouble shoot pipe skate controls, Install hose reels for rig floor pressure washer. 4/24/2019 4/25/2019 6.00 MIRU MOVE MOB P Continue with pre -spud checklist, 0.0 0.0 18:00 00:00 Check out drilling equipment, P/U 5- 7/8" HWT drill pipe and rack back. Stock pits with mud products, Charge up Koomey system (no leaks) Continue prep mud pits. Take on first load of 8.7ppg spud mud. 4/25/2019 4/25/2019 6.00 MIRU MOVE MOB P Continue with pre -spud checklist, Take 0.0 0.0 00:00 06:00 on 8.7ppg spud mud. Spot and berm cutting tanks. 4/25/2019 4/25/2019 2.00 MIRU MOVE MOB P Diverter function test (44sec, close 0.0 0.0 06:00 08:00 knife valve 2sec.) Test PVT, flow meter and gas alarms. Witness waived by AOGCC Guy Cook. Page 1149 Report Printed: 7/1812019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time log Start Depth Start Time End Time Dur(hn Phase Op Code AaMfty Code Time P-T-X Operation (ftKB) End Dept(fiKB) 4/25/2019 4/25/2019 4.00 MIRU MOVE MOB P Flush black water line, mud manifold. 0.0 0.0 08:00 12:00 Break diverter line and inspect valve. HSE walk through with Doyon Drilling and CPAI rep's. 4/25/2019 4/25/2019 6.00 MIRU MOVE MOB P Continue re-installing diverter line and 0.0 0.0 1200 18:00 knife valve, center riser and inflate air boot. Work on cuttings shute dump line. Clean pin/box on 5-7/8" XT-M57 drill pipe. PIU and rack back in derrick. 4/25/2019 4/25/2019 2.50 MIRU MOVE MOB P Pick up and rack back 23 stands of 5- 0.0 0.0 1800 20:30 7/8" drill pipe while installing emergence dump drag chain shute and hose, Continue with acceptance checklist. 4/25/2019 4/26/2019 3.50 MIRU MOVE MOB P Continue installing emergence dump 0.0 0.0 2030 00:00 drag chain shute and hose. Continue with acceptance checklist. 4/26/2019 4/26/2019 5.00 MIRU MOVE MOB P Finish with drag chain cuttings chute, 0.0 0.0 00:00 05:00 Function drag chain E-Stop and E- Dump valve, Rig Accepted at 0500 hrs. 4/26/2019 4/26/2019 2.00 MIRU MOVE SEOP P Pressure test surface lines, mud 0.0 0.0 05:00 07:00 pumps, Kelly hose, & cement lines to 3500 psi (good) 4/26/2019 4/26/2019 3.00 MIRU MOVE RURD P Finalize inspection checklist. Build 0.0 0.0 0700 10:00 working platform around cuttings tanks. Dress shakers. 4/26/2019 4/26/2019 0.75 MIRU MOVE RURD P C/O elevators to 350 T 5-7/8". Bring 0.0 0.0 1000 10:45 remaining BHA components to rig floor. PJSM on BHA 4/26/2019 4/26/2019 1.25 MIRU MOVE RURD P M/U 16" surface BHAas per SLB to 0.0 43.0 1045 12:00 43'. (16" Kymera bit, mud motor, NM stabilizer) 4/26/2019 4/26/2019 1.25 SURFAC DRILL DDRL P Spud well & drill out w/300 - 400 gpm, 43.0 195.0 1200 13:15 230 - 430 psi, 10 - 20 rpm 3 - 5 k ft/lbs trq from 43' MD to 170' MD. Drill 25' new formation 170' MD to 195' MD. Riser & flow line packed off with clay and rock. 4/26/2019 4/26/2019 3.50 SURFAC DRILL OTHR T Mud over flowed rig drip pan & spilled 195.0 150.0 13:15 16:45 into cellar with 200 gal spill in containment & 40 gal outside on pad (240 gal total). Clean up spill. Work on getting flow un-packed off from clay Every time we would break circ. Hole would un-load clay cuttings & re-pack off flow line. Cont. to clean up flow line & conductor of clay. 4/26/2019 4/26/2019 1.25 SURFAC DRILL TRIP T POOH with BHA from 150' MD. 150.0 0.0 16:45 18:00 4/26/2019 4/26/2019 2.00 SURFAC DRILL OTHR T Clear flowline with clay-rock 0.0 0.0 1800 2000 obstruction with supersucker. Add I% drilzone to mud system. 4/26/2019 4/26/2019 1.75 SURFAC DRILL BHAH T M/U 16" surface BHA as per SLB to 0.0 195.0 20:00 21:45 43'. (16" Kymera bit, mud motor, NM stabilizer) Wash and ream from 37' MD to 195' MD at 350-450gpm 410psi 20 rpm lklbs-torque. Clean and clear clay from conductor and displace conductor with 1 % drilzone. Page 2149 Report Printed: 7/18/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth start Time End Time Dur (hr) Phase Op code Adviry cone rime P-T-X Operaflon (ftKB) End Depth (IIKB) 4/26/2019 4/26/2019 1.00 SURFAC DRILL BKRM T Back ream from 195' MD to 130' MD, 195.0 130.0 21:45 22:45 Flow line packing off again. flow rate dropped to 150gpm. Attempt to jet clean with black water line without success. 4/26/2019 4/26/2019 0.50 SURFAC DRILL TRIP T POOH with BHA from 130' MD. 130.0 0.0 22:45 23:15 4/2612019 4/27/2019 0.75 SURFAC DRILL OTHR T Remove flow line from riser and clean 0.0 0.0 23:15 00:00 1 lout section of flow line. 4/27/2019 4/27/2019 1.50 SURFAC DRILL OTHR T Cont. to remove flow line from riser 0.0 0.0 00:00 01:30 and clean out section of flow line. 4/27/2019 4/27/2019 0.25 SURFAC DRILL TRIP T RIH to 102' MD 0.0 102.0 01:30 01:45 4/27/2019 4/27/2019 0.25 SURFAC DRILL CIRC T Break circ & confirm flow line clear. 102.0 102.0 01:45 02:00 4/27/2019 4/27/2019 0.25 SURFAC DRILL TRIP T POOH f/102' MD to 37' MD. 102.0 37.0 02:00 02:15 4/27/2019 4/27/2019 3.25 SURFAC DRILL BHAH P PJSM. M/U BHA#2 as per SLB. 37.0 181.0 02:15 05:30 (MWD tools & Scientific GWD tools) 4/27/2019 4/27/2019 0.25 SURFAC DRILL REAM P W&R fmm181' MD to TD of 195' MD 181.0 195.0 05:30 05:45 w/425 gpm, 480 psi, 30 rpm, 1-2 k fl/lbs trq 4/27/2019 4/27/2019 2.75 SURFAC DRILL DDRL P Drill ahead froml95' MD to 465' MD / 195.0 465.0 05:45 08:30 465' TVD, ADT 1.8 hrs, 500 gpm, 850 psi, PU wt 100 k, SO wt 95 k, ROT wt 97 Is, 50 rpm, 312 On/Off k/ft Ibis trq 4/27/2019 4/27/2019 0.50 SURFAC DRILL OTHR T Observe hole trying to pack off along 465.0 465.0 08:30 09:00 with significant amounts of hugr clay balls trying to pack off flow line. Attempt to work flow clean with no success. 4/27/2019 4/27/2019 6.00 SURFAC DRILL TRIP T POOH while pumping and back 465.0 0.0 09:00 15:00 reaming. Removing significant amounts of clay cuttings from flow line. Worked our way out of the hole to 170' MD and observed riser completely packed off with clay. Shut down, pull bushings & remove clay from riser & flow line. Cont. to POOH cleaning clay off of BHA components, riser & flow line. 4/27/2019 4/27/2019 1.00 SURFAC DRILL BHAH T M/U clean out BHA RIH from to'85' 0.0 85.0 15:00 16:00 MD 4/27/2019 4/27/2019 0.75 SURFAC DRILL WASH T Wash and ream in hole from 85' MD to 85.0 165.0 16:00 16:45 165' MD. 250-525gpm 180430psi. (pump 39bbls nut plug sweep, well unload significant amounts of day cuttings) 4/27/2019 4127/2019 0.75 SURFAC DRILL TRIP T POOH from 165' MD. Clean clay from 165.0 0.0 16:45 17:30 BHA. 412712019 4127/2019 1.00 SURFAC DRILL BHAH T PJSM. M/U BHA#3 as per SLB. to 0.0 181.0 17:30 18:30 181' MD (MWD tools & Scientific GWD tools) 4/27/2019 4127/2019 1.75 SURFAC DRILL WASH T Wash and ream in hole from 181' MD 181.0 49-5 0 18:30 20:15 to 465' MD. 250-525gpm 180430psi. (pump 39bbls nut plug sweep, well unload significant amounts of clay cuttings) 4/27/2019 4/27/2019 0.75 SURFAC DRILL DDRL P Drill ahead from 465' MD to 560' MD 465.0 560.0 20:15 21:00 560' TVD, ADT .51 hrs, 550 gpm, 780 psi, PU wt 106 k, SO wt 99 k, ROT wt 97 k, 40 rpm, 312 On/Off k/ft lbs trq Page 3149 Report Printed: 711812019 e Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sten Depth Sted Time End Time our(hr) Prase Op Code Activity Code Time P -T -X Operation (flKB) End Depth(1KB) 4/27/2019 4/27/2019 0.75 SURFAC DRILL CIRC T Lost 100% returms, PIU off btm and 560.0 560.0 21:00 21:45 regained circulation. stage pumps up 84-575gpm 110-820psi 540rpm (Pump 39bbls nut plug and drizone sweep) 4/27/2019 4/27/2019 0.50 SURFAC DRILL DDRL P Drill ahead from 560' MD to 620' MD 560.0 620.0 21:45 22:15 620' TVD, ADT .58 hrs, 550 gpm, 780 psi, PU wt 106 k, SO wl 99 k, ROT wt 97 k, 40 rpm, 3/2 On/Off k/ft Itis trq 4/27/2019 4/27/2019 0.75 SURFAC DRILL CIRC T Lost 100% returms, P/U off btm and 620.0 620.0 22:15 23:00 regained circulation. stage pumps up 100-550gpm 140-780psi 10-30rpm (Pump 39bbls nut plug and drizone sweep) 4/27/2019 4127/2019 0.25 SURFAC DRILL DDRL P Drill ahead from 620' MD to 637' MD 620.0 637.0 23:00 23:15 634' TVD, ADT .14 hrs, 550 gpm, 780 psi, PU wt 106 k, SO wt 99 k, ROT wt 97 k, 40 rpm, 3/2 On/Off k/ft Ibs trq 4/27/2019 4/28/2019 0.75 SURFAC DRILL DDRL P Take GYRO survey at 637' MD, B/R 637.0 637.0 23:15 00:00 1 from 637' MD to 545' MD 4/28/2019 4/28/2019 4.25 SURFAC DRILL CIRC T Work on staging flow rate up from 120 637.0 637.0 00:00 04:15 gpm to 300 gpm. Observe an increase in losses. Pump bit balling sweep (Mut plug, drilzone). Start W&R from 545' MD to 610' MD & observe losses. Pimp sweep (Nut Plug, Drilzone, Sap) Regain full returns. BROOH to 460' MD and clean hole up. (Niger torque and packing off at 525' MD). W&R back to TO of 637' with no issue. Full returns. 4/28/2019 4/28/2019 7.75 SURFAC DRILL DDRL P Drill ahead from 637' MD to 1,230' MD 637.0 1,230.0 0415 12:00 1,222' TVD, ADT 3.69 hrs, 575 gpm, 810 psi, PU wt 130 k, SO wt 120 k, ROT wt 125 k, 50 rpm, 3/2 On/Off kilt His trq (Having issues with hole packing off after sliding.) Partial losses during pack offs). Pumping bit balling sweeps as needed. (Nut plug drilzone, Sap) Adding cup of Sap in drill string on every connection. 4/28/2019 4/28/2019 9.75 SURFAC DRILL DDRL P Drill ahead from 1,230' MD to 1,850' 1,230.0 1,850.0 12:00 21:45 MD 1,819' TVD, ADT 5.33 hrs, 575- 625 gpm, 810-1130psi, PU wt 130 k, SO wt 120 k, ROT wt 125 k, 50 rpm, 3/2 On/Off k/ft Itis trq. Pumping bit balling sweeps as needed. (Nut plug, drilzone, Sap) Adding cup of Sap in drill string on every connection. 4/28/2019 4/2812019 1.25 SURFAC DRILL CIRC T Circulate at 1,850' MD while trouble 1,850.0 1,850.0 21:45 23:00 shoot Survey tools. 84-700gpm 150- 1140psi 10-50rpm 24k/ft lbs torque. 4/28/2019 4/2812019 0.25 SURFAC DRILL DDRL P Drill ahead from 1,850' MD to 1,859' 1,850.0 1,859.0 23:00 23:15 MD 1,810' TVD, ADT 3.69 hrs, 700 gpm, 1140 psi, PU wt 135 k, SO wt 130 k, ROT wt 135 k, 50 rpm, 4/3 On/Off k/ft His Ind. Page 4149 Report Printed: 7118120191 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Too Dur (1m) Phase Op cote AcWq Code Time P -T -K Operation (ftKB) End Depth(ftKB) 4/28/2019 4/29/2019 0.75 SURFAC DRILL CIRC T Circulate at 1,859' MD while trouble 1,859.0 1,859.0 23:15 00:00 shoot Survey tools and reboot surface computer. 84-700gpm 150-1140psi 10 -50rpm 2Ak/ft lbs torque. Mud lost to formation last 24hrs: 210bbls Mud lost to formation, hole section: 371bb1s 4/29/2019 4/29/2019 11.00 SURFAC DRILL DDRL P Drill ahead from 1,859' MD to TO of 1,859.0 2,868.0 00:00 11:00 2,868' MD 2,652' TVD, ADT 6.82 hrs, 800 gpm, 1810 psi, PU wt 165 k, SO wt 140 k, ROT wt 150 k, 50 rpm, 6/6 On/Off k/ft lbs trq. 4/29/2019 4/29/2019 2.00 SURFAC CASING CIRC P Pump sweep & circ hole clean for 2 2,868.0 2,706.0 11:00 13:00 B/U w/800 gpm, 1550 psi, 50 rpm, 5 k trq. Rack back 1 stand after each B/U to 2,706' MD. 4/29/2019 4/29/2019 0.25 SURFAC CASING OWFF P F/C (static) 2,706.0 2,706.0 13:00 13:15 4/29/2019 4/29/2019 5.25 SURFAC CASING BKRM P BROOH from 2,706' MD to 1,483' MD. 2,706.0 1,483.0 13:15 18:30 800gpm 1560psi 50rpm 4-6k/ft lbs torque. Al 1,670' MD pump 60 bbls procor LCM pill whill BROOH to 1,483' MD. 4/29/2019 4/29/2019 0.25 SURFAC CASING OWFF P F/C (static) 1,483.0 1,483.0 18:30 18:45 4/29/2019 4/29/2019 1.75 SURFAC CASING TRIP P POOH from 1,483' MD to 660' MD. 1,483.0 660.0 18:45 20:30 (Observed tight spots at 949' MD, 850' MD 20/30k over and 660' MD 45k). 4/29/2019 4/29/2019 1.25 SURFAC CASING BKRM P TIH from 660' MD to 825' MD, 660.0 737.0 20:30 21:45 Circulate and ream from 825' MD to 737' MD. 400-600gpm 400-70( 20rpm 2k/ft lbs torque. 4/29/2019 4/29/2019 1.00 SURFAC CASING TRIP P POOH from 737' MD to 181' MD. (No 737.0 181.0 21:45 22:45 issues) 4/29/2019 4/29/2019 0.25 SURFAC CASING OWFF P F/C (static) 181.0 181.0 22:45 23:00 4/29/2019 4/29/2019 0.25 SURFAC CASING CIRC P Circulate at 181' MD, Pump 39bbls nut 161.0 181.0 23:00 23:15 plug, drilzone, sapp Sweep at 500gpm 500psi 20rpm 1 k/ft lbs torque. Sweep returned 12bbls early on calculated volume. 4/29/2019 4/30/2019 0.75 SURFAC CASING BHAH P POOH from 181' MD to 1 50'MD. BD 181.0 150.0 23:15 00:00 top drive, Derrick management P/U and rack back stand of 5-7/8" Drill pipe used for safety joint. Formation losses last 24 hours= 59 bbls Formation losses hole section= 430 bbls 4/30/2019 4/30/2019 0.25 SURFAC CASING OWFF P OWFF (static while PJSM UD BHA) 150.0 150.0 00:00 00:15 4/30/2019 4/30/2019 4.75 SURFAC CASING BHAH P POOH from 1 50'MD UD 16" BHA. 150.0 0.0 00:15 05:00 1 1 Clear BHA tools from rig floor. Page 5149 ReportPrinted: 7/18/2019 Uperations Summary (with Timelog Depths) 2M-39 0g: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time our (hr) Phase Op Code Activity Coda Time P -T -X Operation (flKB) End Depth (flKB) 4/30/2019 4/30/2019 4.50 SURFAC CASING RURD T Make up 13 3/8" hanger to landing 0.0 0.0 05:00 09:30 joint. Perform dummy run. Hanger landed at 15.00' MD. Lay down hanger and landing joint. Lower section of diverter riser ID is 18.75" and hanger OD is 18.71 ". 4/30/2019 4130/2019 4.00 SURFAC CASING RURD P Install diverter riser, R/U 13-3/8" CRT 0.0 0.0 09:30 13:30 1 1 and casing running equipment. 4/30/2019 4/30/2019 8.50 SURFAC CASING PUTS P P/U 13 3/8 L-80 563 Hydril casing, 0.0 1,620.0 13:30 22:00 bakedoc shoe track assy. , GBR torque casing to 25k. install bow spring cent, fill casing and check floats at 160' MD (good) Continue RIH from 160' MD to 950' MD. (Hole not taking proper displacement from 200' MD to 800' MD) Noticed SIO weight increased 15-20k, Fill casing, Stage pump rate 57-152gpm 60-91 psi (good returns) Continue RIH from 950' MD to 1,020' MD Stage pump rate 70- 144gpm 60-104psi(good returns) Continue RIH from 1,020' MD to 1,315' MD Noticed S/O weight increased 15-20k, Decreased in displacement at (1,280' MD). Stage pump rate 47-100gpm 117-150psi (good returns) Attempt to increase rale to 150gpm and returns decreased to 100% losses, Drop rate to 97gpm 130psi with 100% losses (MW out 9.8+, In 9.5ppg) Mud in annulus moved with direction of pipe movement. (Attempt to RIH to place shoe below base of permafrost and possible regain circulation)At 1,531' MD and 1,620' MD attempt to circulate 42gpm 11 Opal without sucess. 4/30/2019 5/1/2019 2.00 SURFAC CASING PULL T Pump OOH UD 13-3/8" casing from 1,620.0 1,443.0 22:00 00:00 1,620' MD to 1,443' MD attempting to regain circulation. 5/1/2019 5/1/2019 6.50 SURFAC CASING PULL T Pump OOH UD 13-3/8" casing from 1,443.0 966.0 00:00 06:30 1,443' MD to 966' MD attempting to regain circulation. Damaged joints #35 land #36 galling threads. 5/1/2019 5/1/2019 2.50 SURFAC CASING CIRC T Attempt to regain circulation at 966' 966.0 966.0 06:30 09:00 MD working pipe and pumping at 126gpm 60psi. Unsuccessful, Decision to RIH. 5/1/2019 5/1/2019 4.50 SURFAC CASING PUTS T P/U 13 3/8 L-80 563 Hydril rasing, 966.0 1,620.0 09:00 13:30 GBR torque rasing to 25k. from 966' MD to 1620' MD. (Attempt to circulate at 1,531' MD 24gpm 81psi without success) 5/1/2019 5/112019 1.75 SURFAC CASING PUTB P P/U 13 318 L-80 563 Hydril casing, 1,620.0 2,024.0 13:30 15:15 GBR torque casing to 25k. from 1,620' MD to 2024' MD. 5/1/2019 5/1/2019 3.25 SURFAC CASING CIRC T Attempt to regain circulation at 2024' 2,024.0 2,024.0 15:15 18:30 MD working pipe and pumping at 23- 183gpm 80-110psi. Unsuccessful, Decision to RIH. 5/1/2019 5/1/2019 3.50 SURFAC CASING 1150 r P P/U 13 3/8 L-80 563 Hydril casing, 2,024.0 2,860.0 18:30 22:00 1 GBR torque casing to 25k. from 2,024' MD to 2,860' MD. Page 6149 Report Printed: 711812019 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Time End Time Dur (hr) Phase Op Code Actively Code Time P8 -X Operation Stan Depth (ftK8) End Depth (MB) 5/1/2019 5/2/2019 2.00 SURFAC CASING CIRC T Attempt to regain circulation at 2,860' 2,024.0 2,024.0 22:00 00:00 MD working pipe and pumping at 55- 74gpm 80-160psi. on up stroke (occasions pump at 15gpm 150psi on down stroke) while mixing 50bbls Procor 30#/bbl LCM pill. Losses while running 13-3/8" casing last 24 hours= 765 bbls Losses while running 13-3/8" casing total= 881 bbls Formation losses hole section= 1311 bbls 5/2/2019 5/2/2019 14.25 SURFAC CEMENT CIRC P Attempt to regain circulation at 2,860' 2,024.0 2,860.0 00:00 14:15 MD working pipe and pumping at 55- 74gpm 80-160psi. on up stroke (occasions pump at 15gpm 150psi on down stroke) Pump 50bbls Procor 30#/bbl LCM pill. Continue circulate and recipricate pipe 0300hrs regain 15% returns and at 0500hrs 100% returns (Procor pill still in casing). Continue increase pump rate from 42- 330gpm 140psi PIU: 255k S/O: 175k. while preparation of pumping cement and setting emergence slips. Losses last 24 hours= 204 bbls Formation losses hole section= 1515 bbls 5/2/2019 5/2/2019 2.50 SURFAC CEMENT CIRC P BIG, volant CRT and change out cup 2,860.0 2,860.0 14:15 16:45 seal, M/U and continue circulating at 352gpm 120psi P/U: 256k S/O: 171k 5/2/2019 5/2/2019 5.75 SURFAC CEMENT CMNT P PJSM, Line up & SLB pump 5 bbls 2,860.0 2,860.0 16:45 22:30 water. Pressure test lines to 2500 psi, good. Pump 40.2 bbls of CW100 @ 5 bpm, 60 psi, P/U: 255k SIO: 175k. Pump 73.6 bbls of 10.5 ppg MP 11 @ 4 bpm, 40 psi. Drop bottom plug at 2100hrs & start batching lead. Pump 519.8 bbls of 11.0 ppg lead cement at 5 bpm, 80-140 psi. (MP II at surface with 505 bbls of Lead away) Batch and pump 70.4 bbls of 12 ppg tail cement @ 5 bpm, 80-140 psi. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/ 9.5 ppg spud mud @ 8 bpm, 510-680 psi, 11 ppg lead cement at surface at 135 bbls of displacement away. Reduced rate to 3bpm 400psi. Bump plug with 406 bbls, Pressure up to 1000 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 22:09 hrs 05/02/2019. Good 269bb1 11 ppg cement to surface. Full returns. 5/2/2019 5/2/2019 0.50 SURFAC CEMENT OWFF P OWFF(Static) 2,860.0 2,860.0 22:30 23:00 5/2/2019 5/3/2019 1.00 SURFAC CEMENT RURD P Blow down and RID SLB cement lines, 2,860.0 2,860.0 23:00 00:00 Drain and flush stack. Clean and clear rig floor. Disconnect knife valve. Blow down all surface lines. 5/3/2019 5/3/2019 3.25 SURFAC CEMENT RURD P PJSM, RID bleeder, hole fill lines, flow 0.0 0.0 00:00 03:15 line and diverter flow line. R/U and lift diverter system. Page 7149 Report Printed: 7/1812019 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log smrt Damm Stan[ Time End Time our (hr) Phase Op Code ApWlly Cdde Time P -T -X Operabon (ftKB) End Depth (ftKB) 5/3/2019 5/3/2019 2.25 SURFAC WHDBOP RURD P Measured cement hight 40" from 0.0 0.0 0315 05:30 ground level. Set CIW emergency slips with 110k1bs. Drain and rought cut 13-3/8" casing. UD same. 5/3/2019 5/312019 1.75 SURFAC WHDBOP RURD P RID 13-3/8" Volant CRT and side entry 0.0 0.0 05:30 07:15 assembly. 5/3/2019 5/3/2019 4.75 SURFAC WHOBOP RURD P PJSM, N/D surface riser, and 21-1/4" 0.0 0.0 07:15 12:00 diverter system. Move completion equipment and stage MPD equipment in cellar. 5/3/2019 5/312019 6.00 SURFAC WHDBOP W WSP P Clear cellar starter head and tools, 0.0 0.0 12:00 18:00 Make final cut/bevel on 13-3/8" casing. Install, preheat to 350" and weld CIW emergency hanger connection. Let cool below 200'. 5/3/2019 5/312019 0.50 SURFAC WHDBOP WWWH P R/U and test emergency hanger 0.0 0.0 18:00 18:30 connection with nitrogen 250psi 5min/1000psi IOmin. Good test. 5/3/2019 5/3/2019 1.00 SURFAC WHDBOP WWWH P Install CtW 13-5/8" 5k MBS well head. 0.0 0.0 18:30 19:30 1 1 1 Test to 5000psi 10min. Good test 5/3/2019 5/3/2019 1.00 SURFAC WHDBOP WWWH P Re -orient TBG spool as per Document 0.0 0.0 19:30 20:30 drawing PDA-MlXX-5249 in 21M-39 Well Program. 5/3/2019 5/3/2019 0.75 SURFAC WHDBOP RURD P Clear cellar area, Remove section of 0.0 0.0 20:30 21:15 diverter line to make room for 21-1/4" diverter system. 5/3/2019 5/4/2019 2.75 SURFAC WHDBOP NUND P N/U 13-5/8" 5k spacer spool, N/U 13- 0.0 0.0 21:15 00:00 5/8" 5k BOP's. 514/2019 5/4/2019 8.00 SURFAC WHDBOP NUND P N/U 13-518" 5k spacer spool, N/U 13- 0.0 0.0 00:00 08:00 5/8" 5k BOP's. Install bell guide on top drive. Note: Extra time on N/U on BOPs due to completly install all componets after ig move. 5/4/2019 5/4/2019 4.00 SURFAC WHDBOP MPDA P R/U Beyond MPD equipment on stack 0.0 0.0 06:00 12:00 and install flow box. 5/4/2019 5/4/2019 4.50 SURFAC WHDBOP BOPE P Install flow line, mud bucket line, 0.0 0.0 12:00 16:30 bleeder lines and secure stack with tumbuckles. R/U 5-7/8" test joint and test plug. Fill stack with water and prpair to test BOP's. 5/4/2019 5/4/2019 5.50 SURFAC WHDBOP BOPE P Test ROPE w/5-7/8" test joint. Annular 0.0 0.0 1630 22:00 250 / 3500 psi for 5 min, Remaining test 250 / 3500 psi for 5 min. 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper 3-1/2" X 6" VBR's 8 blind rams, 5-7/8" Dart/FOSV, HCR / Man choke/kill, Accumulator test, Initial 3075 psi, final 1450 psi, (precharge 1000psi on bottles checkec 5-4-2019) 1 st 200 psi recharge = 27 sec's, full recharge = 153 seconds. Nitrogen Bottles x4 = 2,050 psi. Gas alarms and PVT alarms tested. Tested draw down on hydralic chokes 1100psi. AOGCC Austin McLeod witness test. (F/P on manual IBOP) 5/4/2019 5/4/2019 1.25 SURFAC WHDBOP BOPE P Change ram packers on lower 3-1/2" 0.0 0.0 22:00 23:15 j j j X 6" rams and change out 4" bonnet j and seat on kill line. 5/4/2019 5/5/2019 0.75 SURFAC WHDBOP BOPE P Test 4" kill to 250 13500 psi for 5 0.0 0.0 23:15 00:00 1 I I I min/5min. Page 8/49 Report Printed; 711812019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth SUM Tune End Time Da (hr) Phase op Cade Activity Code Time P -T -X Opereuon (WB) End Depth (WEI) 515/2019 5/5/2019 SURFAC 0.0 00:00 00:00 515/2019 5/5/2019 1.00 SURFAC WHDBOP BOPE P Test 3-1/2 X 6" LPR to 250 /3500 psi 0.0 0.0 00:00 01:00 for 5 min/5min. and Accumulator test. 5/5/2019 5/5/2019 0.25 SURFAC WHDBOP RURD P Rig down BOP test joint and install 0.0 0.0 01:00 01:15 MPD blank test cap Test 250 / 1200psi 5min/5min. 515/2019 5/5/2019 1.00 SURFAC WHDBOP RURD P Pull test cap and test plug, Blow down 0.0 0.0 01:15 02:15 1 surface equipment. 5/5/2019 5/5/2019 0.75 SURFAC WHDBOP RURD P Install trip nipple and set CIW wear 0.0 0.0 02:15 03:00 1 ring. 12.375" ID 13.5" OD X 38-1/4" 5/5/2019 5/5/2019 1.25 SURFAC WHDBOP BHAH P Stage BHA tools and equipment on 0.0 0.0 03:00 04:15 1 rig floor. 5/5/2019 5/5/2019 1.50 SURFAC WHDBOP BHAH P Derrick management, Lay down 12 0.0 0.0 04:15 05:45 joints 5-7/8" HWT drill pipe. 5/5/2019 5/5/2019 0.50 SURFAC WHDBOP CLEN P Clean and clear rig floor, prepare for 0.0 0.0 05:45 06:15 P/U 12-1/4" BHA. 5/5/2019 515/2019 2.50 SURFAC CEMENT SHAH P PJSM, PIU 12-1/4" BHA (369.54) 0.0 370.0 06:15 08:45 5/5/2019 515/2019 2.00 SURFAC CEMENT TRIP P RIH with 12-1/2" BHA to 2,623' MD. 370.0 2,623.0 08:45 10:45 5/5/2019 515/2019 0.75 SURFAC CEMENT CIRC P Shallow test MWD at 2,623' MD with 2,623.0 2,623.0 10:45 11:30 650gpm 820psi. (good lest) 5/5/2019 5152019 2.00 SURFAC CEMENT SLPC P Slip and cut 68' drill line. Service 2,623.0 2,623.0 11:30 13:30 equipment. 5/5/2019 5/5/2019 2.00 SURFAC CEMENT PRTS P Blow down, test 13-3/8" casing to 2,623.0 2,623.0 13:30 15:30 3000psi for 30 min. (good test) Bled to Opsi (5.5bbls pumped, 3bbls returned) blow down surface lines. 5/5/2019 5/52019 3.25 SURFAC CEMENT MPDA P Remove trip nipple and install RCD 2,623.0 2,623.0 15:30 18:45 bearing, Break circulation 42gpm 70psi, stage pumps up to 900gpm 1580psi 1 Orpm 51k/fl lbs trq.. Break in bearing and tune chokes. 5/5/2019 5152019 0.75 SURFAC CEMENT MPDA P Remove RCD bearing and install trip 2,623.0 2,623.0 18:45 19:30 nipple. 5/5/2019 5/512019 1.75 SURFAC CEMENT WASH P UD two joints 5-7/8" Drill pipe with bad 2,623.0 2,766.0 19:30 21:15 threads. Wash in hole from 2,623 MD, Tagged cement at 2,766' MD 5/52019 5/6/2019 2.75 SURFAC CEMENT DRLG P Drill cement and plugs from 2,766' MD 2,766.0 2,772.0 21:15 00:00 to 2,772' MD350gpm/800gpm 275psi/1250psi 20/100rpm PU wt 150 k, SO wt 135 k, ROT wl 145 k, 4-8k/ft lbs trq. 5162019 5/6/2019 5.00 SURFAC CEMENT DRLG P Drill cement, plugs and shoe from 2,772.0 2,868.0 00:00 05:00 2,772' MD to 2,860' MD (wash rat hole to 2,868' MD) 350gpm/800gpm 275psi/1250psi 20/100rpm PU wt 150 k, SO wt 135 k, ROT wt 145 k, 4-8k/ft lbs trq. 5/62019 5/6/2019 0.25 SURFAC CEMENT DRLG P Drill ahead from 2,868' MD to 2,888' 2,868.0 2,888.0 05:00 05:15 MD 2,666' TVD 900 gpm, 1700 psi, PU wt 150 k, SO wl 135 k, ROT wt 145 k, 100 rpm, 4-11 k/ft lbs Inc. 5/6/2019 5/6/2019 0.75 SURFAC CEMENT CIRC P BROOH from 2,888' MD to 2,812' MD, 2,888.0 2,812.0 05:15 06:00 Circulate and condition mud 9.5ppg iniout. 900gpm 1700psi. 5/62019 516/2019 0.75 SURFAC CEMENT FIT P R/U and perform LOT with 9.5ppg 2,812.0 2,812.0 06:00 06:45 mud, Leak off at 771 psi EMW 15.1 ppg. Pumped 2.2bbls returned 1 bbl. k-- Page 9149 Report Printed: 711 812 01 9 operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hr) Phase Op code Activity Cod. Tree P -T -X Operation (KB) End Depth (M(B) 5/6/2019 5/6/2019 0.75 INTRMI CEMENT WASH P Wash and ream from 2,812' MD to 2,812.0 2,888.0 06:45 07:30 2,888' MD 700gpm 1000psi 80rpm 4- 6k/ft Ibs trq. 5/6/2019 5/6/2019 4.50 INTRMI DRILL DDRL P Drill 12-1/4" from 2,888' MD to 3,283' 2,888.0 3,283.0 07:30 12:00 MD 2,919' TVD ADT 3.53hrs ECD: 10.07ppg 900gpm 1290psi 160rpm PU wt 153 k, SO wt 137 k, ROTwt 1 k, 4-8k/ft lbs trq. 5/6/2019 5/7/2019 12.00 INTRMI DRILL DDRL P Drill 12-1/4" from 3,283' MD to 4,694' 3,283.0 4,694.0 12:00 00:00 MD 3,297' TVD ADT 8.82hrs ECD: 10.41ppg 1000gpm 1670psi 180rpm PU wt 159 k, SO wt 139 k, ROT wt 147 k, 4.5-8k/ft lbs trq. 5/7/2019 5/7/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 4,694' MD to 5,440' 4,694.0 5,440.0 00:00 06:00 MD 3,456' TVD ECD: 10.69ppg 1000gpm 1860psi 180rpm PU wt 169 k, SO wt 147 k, ROT wt 150 k, 6- 10.4k/ft lbs trq. 5/7/2019 5/7/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 5,440' MD to 6,106' 5,440.0 6,106.0 06:00 12:00 MD 3,606' TVD ADT 8.96hrs ECD: 10.76ppg 1000gpm 1910psi 180rpm PU wt 176 k, SO wt 145 k, ROT wt 155 k, 6.4-11 k/ft lbs trq. 5/7/2019 5/7/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 6,106' MD to 6,766' 6,106.0 6,766.0 12:00 18:00 MD 3,755'TVD ECD: 10.74ppg 1000gpm 2070psi 180rpm PU wt 187 it, SO wt 145 k, ROT wl 162 k, 8- 13.5k/ft lbs trq. 5/7/2019 5/8/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 6,766' MD to 7,424' 6,766.0 7,424.0 18:00 00:00 MD 3,902' TVD ADT 9.4hrs ECD: 10.67ppg 1000gpm 2030psi 180rpm PU wt 200 k, SO wt 155 it, ROT wt 170 k, 8-14k/ft Ibs trq. Pumped 40 bbl, Hi -Vis (+2 ppb DouVis), 10 ppb walnut medium every 300' for hole cleaning. Increased active system meologys at 5,470' pumped 40 bbl 2 ppg over weighted walnut sweeps every 300' for hole cleaning. Magnets: 9lbs last 24hrs. Magnets: 9lbs hole section. 5/8/2019 5/8/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 7,424' MD to 8.091' 7,424.0 8,091.0 00:00 06:00 MD 4,052' TVD ECD: 10.67ppg 1000gpm 2170psi 180rpm PU w1213 k, SO wt 147 k, ROT wt 165 k, 9-16k/ft Ibs trq. Pumped 40 bbl 2 ppg over weighted walnut sweeps every 300' for hole cleaning at 7,148' MD and 7,523' MD with very little signs cuttings returned, Spaced weighted sweeps to 500' intervals and pumped 40 bbl 2 ppg over weighted walnut sweep at 8,000' MD very little signs cuttings returned. Page 10149 ReportPrinted: 711812019 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth Start Time End Tim Dur(ho Phase Op Coo AcWty Code Time P -T -X Operation (ftKe) End Depth IRKS) 5/8/2019 5/8/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 8,091' MD to 8.718' 8,091.0 8,718.0 06:00 12:00 MD 4,193' TVD ADT 9.59hrs ECD: 10.76ppg 1000gpm 2290psi 180rpm PU wt 222 k, SO wt 148 k, ROT wt 173 k, 10-14k/ft lbs trq. Pumped 30 bbls 9.5 ppg low vis sweep followed by a 40 bbls 11.5ppg high vis sweep at 8,666' MD very little signs cuttings returned. 5/8/2019 5/8/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 8,718' MD to 9,213' 8,718.0 9,213.0 12:00 18:00 MD 4,304' TVD ECD: 10.98ppg 1000gpm 2490psi 180rpm PU wt 225 k, SO wt 157 k, ROT wt 174 k, 12.5- 16.5k1ft lbs trq. 5/8/2019 5/912019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 9,213' MD to 9,700' 9,213.0 9,700.0 18:00 00:00 MD 4,412' TVD ADT: 9.35 ECD: 10.89ppg 1000gpm 2460psi 180rpm PU wt 225 k, SO wl 159 k, ROT wl 177 k, 10.5-17k/ft lbs trq. 2100hrs add in system 1% Lotorq lubricant. Pumped 30 bbls 9.5 ppg low vis sweep followed by a 40 bbls 11.5ppg high vis sweep at 9,789' MD very little signs cuttings returned. 5/9/2019 5/9/2019 4.75 INTRMI DRILL DDRL P Drill 12-1/4" from 9,700' MD to 10,154' 9,700.0 10,154.0 00:00 04:45 MD 4514' TVD ADT: 3.96 ECD: 10.98ppg 1000gpm 2220psi 180rpm PU wt 225 k, SO wt 160 k, ROT wt 170 k, 9.2-16.2k/ft lbs trq. Pumped 30 bbls 9.5 ppg low vis sweep followed by a 40 bbls 11.5ppg high vis sweep at 9,789' MD very little signs cuttings returned. 5/9/2019 5/9/2019 1.00 INTRMI DRILL CIRC P Circulate hole clean at 10,154' MD. 10,154.0 10,154.0 04:45 05:45 1000gpm 2220psi 180rpm 10k/ft lbs trq. 5/9/2019 5/9/2019 0.25 INTRMI DRILL OWFF P OWFF at 10,154' MD (slight flow with 10,154.0 10,154.0 05:45 06:00 steady decreasing) PJSM to install RCD bearing assembly. 5/9/2019 5/9/2019 1.00 INTRMI DRILL MPDA P Pull trip nipple and install RCD bearing 10,154.0 10,154.0 06:00 07:00 assembly. 5/9/2019 5/9/2019 0.75 INTRMI DRILL LOT P Perform open hole at 10,154' MD 10,154.0 10,154.0 07:00 07:45 20rpm pump at 0.51bprn leak off at 170psi EMW 10.3ppg pumped 9bbls. 5/9/2019 5/9/2019 6.50 INTRMI DRILL CIRC T Pump LCM sweeps at 10154' MD. 10,154.0 10,154.0 07:45 14:15 1st 40bbl LCM Pill: Base -SND 5ppb MIX II Medium 35ppb NPM (150bph to 70bph) 2nd 401bbl LCM Pill: Base -SND 5pp1b MIX II Medium 15ppb NPM, 20ppb NPF (70bph) 3rd 40bbl LCM Pill: Base -SND 5ppb MIX II Medium 15ppb NPM, 20ppb NPF (70bph to 20bph) 4th 40bbl LCM Pill: Base LSND 5ppb MIX II Medium 15ppb NPM, 20ppb NPF (20bph to 10-20bph) Page 11/49 Report Printed: 7/1 812 01 9 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log smn oapm Siert Time EM Time Our (hr) Phase Op Code Activity Code Time P -T -X operation (flKB) End Depth (KKB) 5/9/2019 5/9/2019 8.50 INTRMI DRILL DDRL P Drill 12-1/4" from 10,154'MD to 10,154.0 10,812.0 14:15 22:45 10,812' MD 4,663' TVD ADT. 3.96 ECD: 10.95ppg 900gpm 1910psi 180rpm PU wt 230 k, SO wt 155 k, ROT wt 180 it, 12.5-18.2k/ft lbs trq. C-37 top 10,720' MD 4,642' TVD Pump 40bbl LCM pill at 10,599' MD while drilling Base LSND 35ppb ProV+, 5ppb SB Superceal (20bph to I Obph) Flow out increased when pill reached 7,034' MD and 3,498' MD Pump 40bbl LCM pill at 10,732' MD while drilling Base LSND 35ppb ProV+, 5ppb SB Superceal (20bph to Obph) Flow out increased when pill reached 6,798' MD. 519/2019 5/10/2019 1.25 INTRMI DRILL CIRC P Circulate hole dean at 10,812' MD. 10,812.0 10,812.0 22:45 00:00 900gpm 1920psi 120rpm 13k/ft lbs trq. Formation losses last 24 hours= 960 bbls Formation losses hole section= 960 bbls Magnets: 6lbs last 24hrs. Magnets: 15lbs hole section. 5/10/2019 5/10/2019 1.75 INTRMI DRILL OWFF P Draw down test at 10,812'MD 4,663' 10,812.0 10,812.0 00:00 01:45 TVD Holding 185psi, chokes continued flowing back 15/26gpm (10min) Shut chokes and pressure stabilized at 216 psi. Bleed for 15 sec's/3 bbls. Shut in for 5 mins and build to 214 psi. Bleed for 15 secs/3 Wis. Shut in for 5 mins and build to 212 psi. Bleed for 15 sec's/2.8 bbls. Shut in for 5 mins and build to 21 Opal. Bleed for 30 sec's/2 Wis. Shut in for 5 mins and build to 208 psi. Bleed for 30 sec's/ 1.8bbls. Shut in for 5 mins and build to 205 psi. Bleed for 30 sec's/2.7 bbls. Shut in for 5 mins and build to 201 psi. Bleed for 30 seds/3.3 bbls. Shut in for 5 mins and build to 199psi. Bleed for 30 sec's/2.8 bbls. Shut in for 5 mins and build to 196psi. Bleed for 30 sec's/3.1 bbls. Shut in for 5 mins and build to 195psi. Bleed for 120 sec's/13 bbls. Shut in for 5 mins and build to 176psi. Bleed for 120 sees/9.5 bbls. Shut in for 5 mins and build to 166psi. Abort test torque increasing (start 13- 14k end 15-19k) Total 49.1 bbls bled back pressure dropped from 216psi to 166psi. 5/10/2019 5/10/2019 1.00 INTRMI DRILL UHC P Circulate hole clean at 10,812' MD. 10,812.0 10,812.0 01:45 02:45 1 1 900gpm 1920psi 120rpm'I 3k/fl lbs lrq. (No gas on BTM's up) 100% returns Page 12149 Report Printed: 711 812 01 9 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time our (hp Phase Op Code AcOviry Code Time P -T -X Operation (ftKB) End Depth (M(6) 5/1012019 5/10/2019 3.25 INTRMI DRILL DDRL P Drill 12-1/4" from 10,812' MD to 10,812.0 11,019.0 02:45 06:00 11,019' MD 4,709' TVD ECD: 10.85ppg 900gpm 1830psi 180rpm PU wt 237 k, SO wt 143 k, ROT wt 174 k, 12-19k1ft lbs trq. 5110/2019 5/10/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 11,019'MD to 11,019.0 11,471.0 06:00 12:00 11,471' MD 4,811' TVD ADT: 5.98 ECD: 11.04ppg 900gpm 2010psi 180rpm PU wt 240 k, SO wt 145 k, ROT wt 185 k, 16.5-23k/ft lbs trq. Increase LOTORQ from 1% to 1.5%, due to increasing torque. 5/10/2019 5/10/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 11,471'MD to 11,471.0 11,986.0 12:00 18:00 11,986' MD 4,928' TVD ECD: 11.01ppg 900gpm 2090psi 180rpm PU wt 250 k, SO wt 152 k, ROT wt 189 k, 18.5-23k/ft lbs trq. Pump 40bbl LCM pill at 11,639' MD while drilling Base LSND 35ppb ProV+, 5ppb SB Superceal (70-80bph to 40bph) Flow out increased when pill reached 8,013' MD and Gose to shoe area. Pump 40bbl LCM pill at 11,794' MD while drilling Base LSND 35ppb Prot/+, 5ppb SB Superceal (40bph to 0-10bph) Flow out increased when pill reached close to same areas on first sweep. 5110/2019 5/10/2019 0.75 INTRMI DRILL DDRL P Drill 12-1/4" from 11,986'MD to 11,986.0 12,037.0 18:00 18:45 12,036' MD 4,938' TVD ECD: 11.01ppg 900gpm 2090psi 180rpm PU wt 250 k, SO wt 152 k, ROT wt 189 k, 18.5-23k/ft lbs trq. 5110/2019 5/10/2019 2.00 INTRMI DRILL CIRC T Lost communication with top drive. 12,037.0 12,037.0 18:45 20:45 Circulate hole clean at 12,036' MD. 900gpm 1920psi 120rpm 13k/ft lbs trq. 100% returns 5/10/2019 5/10/2019 2.00 INTRMI DRILL DDRL P Drill 12-1/4" from 12,036' MD to 12,037.0 12,183.0 20:45 22:45 12,183' MD 4,972' TVD ECD: 10.99ppg 900gpm 2040psi 180rpm PU wt 250 k, SO wt 152 k, ROT wt 189 k, 18.5-29k/ft be trq. 100% returns 5/10/2019 5111/2019 1.25 INTRMI DRILL CIRC T Lost Communication with top drive. 12,183.0 12,183.0 22:45 00:00 Circulate hole clean at 12,183' MD. Rack back stand and continue circulate at 900gpm 1920psi 120rpm 13k/ft lbs tm. 100% returns Formation losses last 24 hours= 415 bbls Total Formation Losses Hole section= 1375 bbls Magnets: 4lbs last 24hrs. Magnets: 191bs hole section. Page 13149 ReportPrinted: 7/1 812 01 9 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time Our (hr) Phase Op code Activity Code Tim P-T-X Operation (KKB) End Depth (ftKB) 5/11/2019 5/11/2019 3.00 INTRMI DRILL CIRC T Lost communication with top drive. 12,183.0 12,183.0 00:00 03:00 Circulate hole clean at 12,183' MD. Rack back stand and continue circulate at 900gpm 1920psi 120rpm 13k/ft lbs trq. 100% returns, While repair top drive. Wash back to bottom to 12,183' MD. 5/11/2019 5/11/2019 3.00 INTRMI DRILL DDRL P Drill 12-1/4" from 12,183'MD to 12,183.0 12,443.0 03:00 06:00 12,443' MD 5,030' TVD ECD: 11.14ppg 900gpm 2200psi 180rpm PU wt 260 k, SO wt 145 k, ROT wt 190 k, 16-25k/ft lbs trq. Pumped 40bb1 LCM Pill at 12,333'MD. Base LSND 5ppb MIX II Medium 15ppb NPM 20ppb NPF (50bph to 35bph) 5/11/2019 5/11/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 12,443' MD to 12,443.0 12,977.0 06:00 12:00 12,977' MD 5,149' TVD ADT: 6.04 ECD: 11.27ppg 900gpm 2230psi 180rpm PU wt 265 k, SO wt 148 k, ROT wt 195 k, 16-24k/ft Its trq. Pumped 40bbl LCM Pill at 12,614'MD. Base LSND 35ppb ProV+, 5ppb SB Superceal (40bph to 30bph) Pumped 40bb1 LCM Pill at 12,820'MD. Base LSND 35ppb ProV+, 5ppb SB Superceal (Loss rate 80bph no change) 5/11/2019 5/11/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 12,977' MD to 12,977.0 13,494.0 12:00 16:00 13,494' MD 5,267' TVD ECD: 11.23ppg 900gpm 2260psi 180rpm PU wt 265 k, SO wt 150 k, ROT wt 195 k, 20-27k/ft Has trq. Pumped 40bbl LCM Pill at 13,023'MD. Base -SND 35ppb ProV+, 5ppb SB Superceal (Loss rate 80-100bph no change) Pumped 40bbl LCM Pill at 13,190'MD. Base -SND 35ppb ProV+, 5ppb SB Superceal (Loss rate 100bph to 70bph) Pumped 40bbl LCM Pill at 13,380'MD. Base LSND 35ppb ProV+, 5ppb SB Superceal (Loss rate 70bph to 50bph) Page 14149 Report Printed: 7/16/2019 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Dept, start Time EM Time Dur (hr) Phase Op Code Activity Code Time P -T -X Operation (MB) End Dept, (RKB) 5/11/2019 5/12/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 13,494' MD to 13,494.0 14,014.0 18:00 00:00 14,014' MD 5,383' TVD ADT. 7.85 ECD: 11.17ppg 900gpm 2200psi 180rpm PU wt 280 k, SO wt 150 k, ROT wt 202 k, 19.5-29k/ft lbs trq. Pumped 40bbl LCM Pill at 13,946'MD. Base LEND 35ppb ProV+, 5ppb SB Superceal. Loss rate decreased from 50bph to 20-40 bph Formation losses last 24 hours= 527 bbls Total Formation Losses Hole section= 1902 bbls Magnets: Slbs last 24hrs. Magnets: 24lbs hole section. 5112/2019 5/12/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 14,014' MD to 14,014.0 14,630.0 00:00 06:00 14,630' MD 5,520' TVD ECD: 11.17ppg 9009pm 2200psi 180rpm PU wt 280 k, SO wt 150 k, ROT wt 202 k, 19.5-29k/ft lbs trq. Pumped 40bbls LCM Pill: Base LSND 5ppb MIX II Medium 15ppb NPM, 20ppb NPF, Hole Cleaning. No Losses 5/12/2019 5/12/2019 6.00 INTRMI DRILL DDRL P Drill 12-1/4" from 14,630' MD to 14,630.0 15,141.0 06:00 12:00 15,141' MD 5,646' TVD ECD: 11.21ppg 900gpm 2100psi 180rpm PU wt 300 k, SO wt 155 k, ROT wt 215 k, 24-28k/ft lbs trq. Pumped 40bbi LCM Pill at 14,690' MD: Base -SND 5ppb MIX II Medium 15ppb NPM, 20ppb NPF, Hole Cleaning. No Losses 5/12/2019 5112/2019 5.75 INTRMI DRILL DDRL P Drill 12-1/4" from 15,141' MD to 15,141.0 15,798.0 12:00 17:45 15,798' MD 5,805' TVD ECD: 11.22ppg 900gpm 2150psi 180rpm PU wt 310 k, SO wt 165 k, ROT wt 214 k, 26.5-31 k/ft lbs trq. Pumped 40bbl LCM Pill at 15,688'MD. Base LSND 35ppb ProV+, 5ppb SB Superceal. Hole Cleaning. No Losses Pumped 40bbl LCM Pill at 15,710'MD. Base LSND 35ppb ProV+, 5ppb SB Superceal. Hole Cleaning. No Losses Page 15/49 Report Printed: 711812019 Operations Summary (with Timelog Depths) a 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Tan, Er Time Dur (hr) Phase Op Cade A vay Cade rime P-T-X Operation (ftKB) End Depth (ftKa) 5/12/2019 5/13/2019 6.25 INTRMI CASING CIRC P Circulate and Condition mud at 15,798.0 15,518.0 17:45 00:00 15,798' MD 5,805' TVD (Hole section TD.) Back ream from 15,798' MD to 15,518' MD, Racking back one stand/bottoms up. ECD: 11.22ppg 900gpm 2150psi 180rpm. ECD: dropped from 11.22ppg to Il.O6ppg. Adding 2% Lotorq Pumped 40bbl LCM Pill at 15,798'MD. Base LSND 35ppb ProV+, 5ppb SB Superceal. Hole Cleaning. No Losses Pumped 40bbl LCM Pill at 15,688'MD. Base LSND 35ppb ProV+, 5ppb SB Superceal. Hole Cleaning. No Losses Formation losses last 24 hours= 0 bbls Total Formation Losses Hole section= 1902 bbls Magnets: 2lbs last 24hrs. Magnets: 26lbs hole section. 5/13/2019 5/13/2019 7.50 INTRMI CASING CIRC P Back ream from 15,518' MD to 15,296' 15,518.0 15,296.0 00:00 0730 MD, Racking back one stand/bottoms up. 900-300gpm 2180-580psi 180- 50rpm. 25-28k/ft lbs trq. 5/13/2019 5/13/2019 2.00 INTRMI CASING OWFF P OWFF at 15,296' MD (Verify well 15,296.0 15,296.0 07:30 09:30 breathing 85-51 psi 21bbls returned) 10rpm 26k/ft lbs trq. 5/13/2019 5/13/2019 3.25 INTRMI CASING SMPD P SOOH from 15,296' MD to 14,842' 15,296.0 14,842.0 09:30 12:45 MD. Overpull at 14,784' MD. Work string to 14,784' MD break circulation. 5/13/2019 5/13/2019 6.75 INTRMI CASING BKRM P BROOH from 14,842' MD to 13,542' 14,842.0 13,542.0 12:45 19:30 MD at 32011/min. 325-300gpm 670- 570psi 80rpm 24k/ft lbs trq. 66% returns 5/13/2019 5/13/2019 0.25 INTRMI CASING SMPD P Attempt to SOOH from 13,542' MD, 13,542.0 13,622.0 19:30 19:45 Overpull at 13,525' MD (40K) Attempt to work through without sucess. RIH to 13,622' MD. 5/13/2019 5/13/2019 1.00 INTRMI CASING BKRM P BROOH from 13,662' MD to 13,415' 13,622.0 13,415.0 19:45 20:45 MD at 3201t/min. 300gpm 570psi 80rpm 22.5k/ft lbs trq. 60% returns 5/13/2019 5/14/2019 3.25 INTRMI CASING SMPD P SOOH from 13,415' MD to 11,565' 13,415.0 11,565.0 20:45 00:00 MD. Maintain 10.7ppg while stripping. (Tight connections Limit out surface equipment to 60K) Heat and rattle (with hammer) connections to break. Formation losses last 24 hours= 396 bbls Total Formation Losses Hole section= 2298 bbis 5/14/2019 5/14/2019 1.50 INTRMI CASING SMPD P SOOH f/ 11,565'to 10.710'w/ MPD 11,565.0 10,710.0 00:00 01:30 120/40psi out/in slips. Observe 30k overpull attempt 3 times with no success. 5/14/2019 5/14/2019 4.50 INTRMI CASING BKRM P BROOH f/ 10,710'to 10.208'200- 10,710.0 10,208.0 01:30 06:00 300gpm. 390-500psi. 40-80 rpm. 16- 20k tq. Tight spots 10,641',10,582', 10,349',10,309- 0,349',10,309'5/14/2019 T/1-4/2019 5/14/2019 3.00 INTRMI CASING SMPD P SOOH f/ 10,208'to 9,706' w/ MPD 10,208.0 9,706.0 06:00 09:00 120/40psi outtin slips. Observe 40k overpull attempt 3 times with no success. Page 16149 Report Printed: 7/18/2019 Uperations Summary (with Timelog Depths) 2M-39 ,, Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Starr Depth Stall Time End Time Dur (hr) phase Op Code Activity Code Time P -T -X Operation (hKB) End Depth (RKB) 5/14/2019 5/14/2019 3.00 INTRMI CASING BKRM P BROOH f/ 9,706'to 9,118' 300gpm. 9,706.0 9,118.0 09:00 12:00 480psi. 80 rpm. 16k tq. Start cutting mud back to 10.3ppg f/ 10.5ppg 5/14/2019 5/14/2019 4.75 INTRMI CASING BKRM P BROOH f/ 9,118'to 7,706'300gpm. 9,118.0 7,706.0 12:00 16:45 380470psi. 80 rpm. 13.5k -15.5k tq. Continue cutting mud back to 10.3ppg f/ 10.5ppg 5/14/2019 5/14/2019 2.50 INTRMI CASING CIRC P Circulate and condition mud. Cut mud 7,706.0 7,706.0 16:45 19:15 weight back to 10.3ppg in/out. 300gpm. 440psi. 80 rpm 12.5k tq. rt wt 160k. 5/14/2019 5/14/2019 1.00 INTRMI CASING OWFF P Flow check. Perform exhale test. close 7,706.0 7,766-0- 19:15 20:15 in and build for 5 minutes then bleed off for 1 minute. 108-11 psi buildup each time. flow slowed each time bled Off from 7bbls to 3 bbls. 5/14/2019 511412019 2.25 INTRMI CASING CIRC P BROOH f/ 7706'to 7424'. Circulating 7,706.0 7,424.0 20:15 22:30 bottoms up 300gpm. 370 psi. 80 rpm. 12.5k tq. 5/14/2019 5114/2019 0.50 INTRM1 CASING SMPD P SOOH f/ 7424. 40k over pull @ 7401' 7,424.0 7,424.0 22:30 23:00 Attempt to work though with no success. backream stand. 5/14/2019 5/15/2019 1.00 INTRMI CASING SMPD P SOOH f/ 7424'to 7260'. 40k overpull 7,424.0 7,260.0 23:00 00:00 @ 7260'. Attempt to work through with no success. 5/15/2019 5/15/2019 3.50 INTRMI CASING BKRM P BROOH f/ 7260'to 6858'. 450 gpm. 7,260.0 6,858.0 00:00 03:30 1580 psi. 80 rpm. 12k tq. 5/15/2019 5/15/2019 5.00 INTRMI CASING SMPD P SOOH f/ 6858' to 4974'. w/ MPD 6,858.0 4,974.0 03:30 08:30 holding 150/60 psi out/in slips. pull 30k over @ 4974'. Attempt to work through 3 limes w/ no success. 5/15/2019 5115/2019 3.50 INTRMI CASING BKRM P BROOH f/ 4974' to 4694'. stage up 4,974.0 4,694.0 08:30 12:00 rale f/ 450-725gpm. 540-1100psi. 80- 120 rpm. 8-10k tq. Pumped nutplug sweep @ 4784'. 5/15/2019 5/15/2019 6.50 INTRMI CASING BKRM P BROOH f/ 4694'to 2812'. 600gpm 4,694.0 2,812.0 12:00 18:30 820psi. 80 rpm. 6k tq. Rotated through shoe w/ 40rpm. 6k tq. 5/15/2019 5/15/2019 0.50 INTRM1 CASING CIRC P Circulate 30 bbl nut plug sweep 2,812.0 2,812.0 18:30 19:00 around. No increase in cuttings when sweep came across shakers. 5/15/2019 5/15/2019 1.75 INTRMI CASING OWFF P Take SPRs. flow check. initial 43 bph 2,812.0 2,812.0 19:00 20:45 and slowed to 10bph. 5/15/2019 5/15/2019 0.50 INTRMI CASING SMPD P SOOH f/ 2812'to 2500'. Take 30k 2,812.0 2,500.0 20:45 21:15 1 1 overpull @ 2500'. 5/15/2019 5/15/2019 1.25 INTRMI CASING PMPO P Pump out of hole. f/ 2529' to 2124'. 2,500.0 2,124.0 21:15 22:30 600gpm. 700psi. Attempt to SOON. 20k overpull 2113', 5/15/2019 5/15/2019 0.50 INTRMI CASING PMPO P Pump out of hole if 2124'to 1777'. 2,124.0 1,777.0 22:30 23:00 600gpm. 710psi. Attempt to SOOH 25k overpull @ 1762'. 5/15/2019 5/16/2019 1.00 INTRMI CASING PMPO P Pump out of hole N 1777'to 1119'. 1,777.0 1,119.0 23:00 00:00 400gpm. 280 psi. 5/16/2019 5/16/2019 1.25 INTRMI CASING PMPO P Pump out of hole H 1119'to 490'. 1,119.0 490.0 00:00 01:15 1 1 400gpm. 300psi. 5/16/2019 5/16/2019 3.00 INTRMI CASING OWFF P Flow check. Well breathing. Slowly 490.0 490.0 01:15 04:15 drop from 1 Obbls/hr to 3.5 bbls/hr. Simops: Prep to pull bearing and install trip nipple. 5/16/2019 5/16/2019 0.50 INTRMI CASING MPDA P Retrieve MPD bearing and install trip 490.0 490.0 04:15 04:45 nipple. 5/16/2019 5/16/2019 0.75 INTRMI CASING PMPO P Pump out of hole f/ 490' to 272'. 490.0 272.0 04:45 05:30 300gpm. 170psi. Page 17149 Report Printed: 711812019 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth StartTme End Tune Our (hn Phase Op Code Activity Corte Time P -T -X Operation (flKB) End Depth (fiKB) 5/16/2019 5/16/2019 2.75 INTRMI CASING SHAH P PJSM and UD BHA. Satbilzer and bit 272.0 0.0 05:30 08:15 packed off w/ clay/cuttings. 5/16/2019 5/16/2019 0.25 INTRMI CASING OWFF P Flow check. Flow steadily slowing. 0.0 0.0 08:15 08:30 confirm well breathing. 5/16/2019 511612019 1.00 INTRM1 WHDBOP RURD P RU and jet BOPE. 22bpm. 620psi. 10 0.0 0.0 08:30 09:30 rpm. 5/16/2019 5/16/2019 4.00 INTRM1 WHDBOP RURD P Blow down TD, Drain stack, Pull wear 0.0 0.0 09:30 13:30 bushing. Change out upper rams to 9 5/8 casing rams. RU to test BOPE. Monitoring well on TT. Static. 5/16/2019 5/16/2019 2.00 INTRMI WHDBOP RURD P Install test plug and lest it. Fill stack 0.0 0.0 1330 15:30 and manifold. 5/16/2019 5/1612019 0.50 INTRMI WHDBOP BOPE T Attempt to test annular and observed 0.0 0.0 15:30 16:00 test plug leaking. 5/16/2019 5/16/2019 1.50 INTRMI WHDBOP RURD T Pull test plug.Replaoe seals on test 0.0 0.0 16:00 17:30 plug. Install test plug. 5/16/2019 5/16/2019 5.00 INTRMI WHDBOP BOPE P BOPE test: Test annular and upper 0.0 0.0 17:30 22:30 rams w/ 9 518" test it 25013500psi f/ 5 min ea. Test valves 1-14, 5 7/8" TIW1dart, Auto/Man IBOP. needle valve, 4" kill, Man kill/choke, HCR kill/choke, Blind rams 25013500psi f/ 5 min ea. Test annular, Who rams w/ 5 7/8" test jt 250/3500psi f/ 5 min ea. Test hydraulicl manual chokes to 1100psi. Perform accumulator lest FSP= 2975psi. PAC= 1700psi. 19 sees to 200psi. 106 sec to FSP2050psi 4 bottles N2 avg. ( Witness of lest waived by Jeff Jones). 5/16/2019 5/16/2019 0.75 INTRMI WHDBOP RURD P B/D lines. R/D test equipment. 0.0 0.0 22:30 23:15 Retrieve test plug. UD test jt. 5/16/2019 5/17/2019 0.75 INTRMI CASING RURD P M/U safety valve if 9 5/8" casing run. 0.0 0.0 23:15 00:00 P/U csg equipment. 5/17/2019 5/17/2019 3.25 INTRMI CASING RURD P Perform dummy run w/ hanger to 0.0 0.0 00:00 03:15 verify clearance. RU csg equipment. 5/17/2019 5/17/2019 5.75 INTRMI CASING PUTB P PJSM. MU and RIH 9 5/8" shoe track 0.0 2,753.0 03:15 09:00 assembly. Threadlock connections. Continue RIH w/ 9 5/8" 47# csg to 2753'. 5/17/2019 5/17/2019 1.00 INTRMI CASING CIRC P Circulate BU stage up rate f/ 50- 2,753.0 2,753.0 09:00 10:00 250gpm. 80/130 psi. 5/17/2019 5/17/2019 3.50 INTRMI CASING PUTB P Continue RIH w/ 9 5/8" csg to 4634'. 2,753.0 4,634.0 10:00 13:30 5/17/2019 5/17/2019 1.50 INTRMI CASING CIRC P Circulate BU stage up rate f/ 50- 4,634.0 4,634.0 13:30 15:00 220gpm. 130-156psi. 5/17/2019 5117/2019 5.50 INTRMI CASING PUTB P RIH f/ 4634' to 6928' w/ 9 518" csg. 4,634.0 6,928.0 15:00 20:30 (Break circulation @ 6163') 5/17/2019 5117/2019 3.00 INTRMI CASING CIRC P Attempt to circulate BU. Minimal 6,928.0 6,928.0 20:30 23:30 returns. Reciprocate pipe and regain 30% returns. Reciprocating pipe up w/ 1-2 bbVmin/ down w/ no pumps. 263k up/168k down. 5/17/2019 5/18/2019 0.50 INTRMI CASING PUTS P RIH fl 6928' to 7138'w/ 9 5/8" csg. SO 6,928.0 7,138.0 23:30 00:00 160k. 5/18/2019 5/18/2019 4.00 INTRMI CASING PUTS P RIH w/ 9 5/8" 47# L-80 casing f/ 7138' 7,138.0 9,068.0 00:00 04:00 to 9068' Dn wt 150k. 5/18/2019 5/18/2019 2.50 INTRMI CASING CIRC P Attempt to circulate: 25-90gpm @ 290 9,068.0 9,068.0 04:00 06:30 -350psi. Reciprocating pipe. No returns. Pumps on upstroke. Pumps off on downstroke. up 325k. do 145k. Page 18149 Report Printed: 711812019 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sten Depth Start Time End Tans Our (hr) Phase Op Code A vAy Cafe Time P -T -X Operation (ftKB) End Depth (NKS) 5/18/2019 5/18/2019 6.00 INTRMI CASING PUTS P RIH w/ 9 5/8" 47# L-80 casing f/ 9068' 9,068.0 11,966.0 06:30 12:30 to 11966' SO 115-150k. 5/18/2019 5/18/2019 0.50 INTRMI CASING CIRC P Attempt to circulate. 25-120 gpm. 460- 11,966.0 11,966.0 12:30 13:00 530psi. up 350-400k breakover. do 150-160k. Unable to regain circulation 5/18/2019 5/18/2019 6.75 INTRMI CASING PUTS P RIH w/ 9 5/8" 47# L-80 casing f/ 11,966.0 15,062.0 13:00 19:45 11966'to 15062' SO 115-150k. 5/18/2019 5/19/2019 4.25 INTRMI CASING CIRC P Taking weight @ 15062'. Work casing 15,062.0 15,199.0 19:45 00:00 through tight spots to 15199'. max up 520k. down 70k. flow rale 30-50 gpm. 710-1000psi. 5/19/2019 5/19/2019 2.25 INTRMI CASING PUTS P RIH w/ 9 5/8" 47# L-80 casing 15,199.0 15,662.0 00:00 02:15 f/15,199'to 15,662'. (Wash down f/15,199' to 15,413' with no returns to improve slack off wt) PU wt 485 k / SO wt 160 k 5/19/2019 5/19/2019 0.25 INTRMI CASING RURD P C/O wash cup on Volant 15,662.0 15,662.0 02:15 02:30 5/19/2019 5/19/2019 0.50 INTRMI CASING PUTB P RIH w/ 9 5/8" 47# L-80 casing 15,662.0 15,744.0 02:30 03:00 f/15,662' to 15,744'. SO wt 160 k 5/19/2019 5/19/2019 0.25 INTRMI CASING HOSO P M/U hanger & landing jt & land casing 15,744.0 15,785.0 03:00 03:15 1 1 1 on hanger @ 15,784.9' 5/19/2019 5/19/2019 2.75 INTRMI CEMENT CIRC P Attempt to establish cirulalion with no 15,785.0 15,785.0 03:15 06:00 succes. Pumping @.2 - 2 bpm with no returns. Reciprocate pipe 20'. PU wt 425 k / SO wl 165k. (Max PU wt 495 k) 5/19/2019 5/19/2019 2.50 INTRMI CEMENT OWFF P Back Volanl out of casing in attempt to 15,785.0 15,785.0 06:00 08:30 R/U cemenlers. Floats not holding. Sting back in to casing & monitor well for flow. Well ballooning & slowing down 5/19/2019 5/19/2019 1.50 INTRMI CEMENT RURD P R/U cement head, cement lines & 15,785.0 15,785.0 08:30 10:00 cementers. SIMOPS - Cont. to monitor well for flow. Still ballooning, slowing down to static. 5/19/2019 5/19/2019 0.75 INTRMI CEMENT CIRC P PJSM on cementing. PT lines to 3500 15,785.0 15,785.0 10:00 10:45 psi (good). Establish injection rate with rig pumps. 2 bpm = 500 psi, 4 bpm = 650 psi, 6 bpm = 750 psi, 8 bpm = 950 psi. No returns with annulus static. 5/19/2019 5/19/2019 5.00 INTRMI CEMENT CMNT P Dowell PT lines to 3500 psi (good). 15,785.0 15,785.0 10:45 15:45 Pump 66.1 bbls 13.0 p[pg Mud push with 5 bpm. Drop bottom plug. Pump 167.2 bbis 15.8 ppg, 1.16 yld Class G tail cement w/5 bpm. Drop tap plug. Pump 10.1 bbls H2O w/4 bpm. Tum over to rig for displacement. Rig pump 1142 bbls If 139 bbls casing cap + 3 bbls = 1/2 shoe track) 10.3 ppg LSND w/2%776. Final circulating rate 3 bpm 690 psi. No returns during cement job. Did not bump the plug. Check floats & floats not holding. (Had 400 psi on casing, bled off 200 psi & shut back in. Pressure built immediately built to 300 psi). CIP 15:15 Hrs. Monitor casing shut in on pressure gage & monitor annulus on trip tank. Annulus is static. 5/19/2019 5/20/2019 8.25 INTRM1 CEMENT WOC T W.O.C. - SIMOPS - Clean/clear dg 0.0 0.0 15:45 00:00 floor. Prep pits for taking on mud. Load pipe shed w/ 4" drill pipe. Page 19149 Report Printed: 7/18/2019 . Operations Summary (with Timelog Depths) 2M-39 ... Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depm Start Time End Time Dur (hr) Phase Op code Acbriy code Time P -T -X Operation (ttKB) End Depth (flKB) 5/20/2019 5/20/2019 4.00 INTRMI CEMENT WOC T W.O.C. - SIMOPS - Clean/clear rig 0.0 0.0 00:00 04:00 floor. Prep pits for taking on mud. Load pipe shed w/ 4" drill pipe. MP2's. Prep BHA tools & equipment. 5120/2019 5/20/2019 1.50 INTRMI CEMENT RURD P R/D cement head & landing jt. 0.0 0.0 04:00 05:30 5120/2019 5/20/2019 2.50 INTRMI CEMENT W WSP P Set pack off. RILDS & test to 0.0 0.0 05:30 08:00 250/5000 psi for 10 min. SIMOPS - R/D Volant. Prep to C/O rams. C/O XT -M saver sub on top drive. 5/20/2019 5/2012019 1.25 INTRMI CEMENT BOPE P C/O upper rams to 4-1/2" X 7" VBR's. 0.0 0.0 08:00 09:15 SIMOPS - Cont. to C/O XT -M saver sub on top drive. H2O flush & freeze protect OA. 5/20/2019 5120/2019 0.75 INTRM1 CEMENT RURD P RIH w/1 stand on 5-7/8" HWDP. Prep 0.0 0.0 09:15 10:00 to slip & cut drill line. 5/20/2019 5/20/2019 1.25 INTRMI CEMENT SLPC P Slip & cut 83' drill Iine.Rig on 0.0 0.0 10:00 11:15 generators at 11:00 Hrs 5/20/2019 5/20/2019 0.50 INTRMI CEMENT SVRG P Service rig. 0.0 0.0 11:15 11:45 5/20/2019 5/20/2019 0.25 INTRMI CEMENT PULD P UD 1 stand of 5-7/8" HWDP 0.0 0.0 11:45 1200 5/20/2019 5/20/2019 0.25 INTRMI CEMENT RURD P Calibrate block 0.0 0.0 12:00 12:15 5/20/2019 5/20/2019 0.75 INTRMI CEMENT BOPE P Set test plug as per Cameron rep. R/U 0.0 0.0 12:15 1300 to test BOPE. 5/20/2019 5/20/2019 2.00 INTRMI CEMENT BOPE P Test annular & upper 4-1/2" X 7" 0.0 0.0 13:00 15:00 VBR's w15-7/8" & 7" test joints to 25013500 psi for 5 min. 5/20/2019 5/20/2019 1.50 INTRMI CEMENT RURD P R/D test equipment. Retrieve test 0.0 0.0 15:00 16:30 plug. Clean/clear rig floor. 5/20/2019 5/20/2019 3.00 INTRMI CEMENT SHAH P PJSM. P/U and RIH w/ 8.5 x 9.875 0.0 360.0 16:30 19:30 BHA to 360'. 5/20/2019 5/20/2019 2.50 INTRMI CEMENT TRIP P RIH fl 360'to 411 9'filling DP as 20 360.0 4,119.0 19:30 22:00 stds. 5/20/2019 5120/2019 0.50 INTRMI CEMENT DHEQ P Shallow test MWD. 450 gpm. 111 Opsi. 4,119.0 4,119.0 22:00 22:30 Good test. 5/20/2019 5121/2019 1.50 INTRMI CEMENT TRIP P RIH f/ 4119'to 6101'. Fill DP as 20 4,119.0 6,101.0 22:30 00:00 stds. 5/21/2019 5/21/2019 4.00 INTRMI CEMENT TRIP P RIH 06,101'to 11,653'. Fill OP every 6,101.0 11,653.0 00:00 04:00 20 skis. P/U wt =200k / SO wt = 1451k. 5/21/2019 5/21/2019 1.75 INTRMI CEMENT QEVL P Downlink and log down f/ 11,653'to 11,653.0 11,842.0 04:00 05:45 11,842'w/500 gpm, 1710 psi, 40 rpm, 12 k/tq. Log to confirm free ringing pipe. 5/21/2019 5/21/2019 1.25 INTRMI CEMENT TRIP P RIH f/ 11,842'to 12,975'. P/U wt = 11,842.0 12,975.0 05:45 07:00 225k / S/O wt =140k. 5/21/2019 5/21/2019 3.00 INTRMI CEMENT QEVL P CBL down f/ 12,975'to 13,255'w/500 12,975.0 13,808.0 07:00 10:00 gpm, 1570 psi., 40rpm, 15 k1tq. Cont. CBL down fl 13,255' to 13,808'w/ no pumps/rotary. Set down 15k 13,808'. Make several attempts to work thru with no success. Break circulation w/500 gpm, 1700 psi, 40 rpm, 16 k trq. Attempt to work thru with top drive stalling out. Make several attempts trying to ream with no success. 5/21/2019 5/21/2019 2.00 INTRMI CEMENT CIRC P Circ B/U w/ 500 gpm, 1600 psi, 50 13,808.0 13,808.0 10:00 1200 rpm, 19 k/tq. Observe cement and top plug across shakers, mixed in with cement cuttings, sand, shale, & nut plug. Page 20149 ReportPrinted: 7118/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sten Depth Start Imre End Time our (W) Phase Op Cade Achvty Code Trme P -T -x Operation (ftKB) End Dep (ftKB) 5/21/2019 5/21/2019 0.50 INTRMI CEMENT COCF P Drill out plug and cement f/13,808'to 13,808.0 13,812.0 12:00 12:30 13,812' w/ 500 gpm, 1660 psi, 60 rpm, 23k trq. PIU wt = 245k, SIO wt = 140k, ROT wt = 175k. Decision made to circ B/U and test casing. 5/21/2019 5/21/2019 0.50 INTRMI CEMENT COCF P Circ B/U w/ 500gpm, 1650psi, 50rpm, 13,812.0 13,812.0 12:30 13:00 9 k/trq. Cont. to see cement and top plug across shakers, and significant amounts of cement cuttings, sand, shale, & nut plug. 5/21/2019 5/21/2019 0.50 INTRMI CEMENT RURD P Rack back one std f/13,812' 13,726'. 13,812.0 13,726.0 13:00 13:30 R/U to test casing. Test lines to 3500psi. 5/21/2019 5/21/2019 1.00 INTRMI CEMENT PRTS P Attempt to test 95/8"casing. Pump 13,726.0 13,726.6- 13:30 14:30 11.7 Wis. to 1100psi. Pressure dropped to 650 psi & it appears we were injecting fluid. Pump an additional 2 bbls Q 650 - 600 psi & confirm injecting fluid. Shut in w/500 psi and monitor pressure for 15 min. Bleed back 3 bbls to trip tank. RID Vest equipment 5/21/2019 5/21/2019 1.25 INTRMI CEMENT REAM P Wash down to 13812'. Cont. to drill out 13,726.0 13,857.0 14:30 15:45 cement f/13,812' to 13,857'W/500 gpm, 1890 psi, 60rpm, 19-24 kttq, ROT wt 175 k. Start taking losses 60 bbls/hr. Shut down to take on mud. 5/21/2019 5/21/2019 0.75 INTRMI CEMENT OWFF P F/C on trip tank while bringing on mud. 13,857.0 13,857.6- 15:45 16:30 Breathing back initial 10 bbls/hr, to slight flow, to static. 5/21/2019 5/21/2019 0.50 INTRMI CEMENT COCF P Cont. to drill out cement f/13,857 to 13,857.0 13,915.0 16:30 17:00 13,860' w/450gpm, 1660psi., 60rpm., 19-25k trq., ROT wt = 177k. Continue to observe losses. Broke thru cement 13,860'& washed to 13,915' whit no wt on bit. (Drilled through total of 52' cement from 13,808' to 13,860') 5/21/2019 5/21/2019 0.50 INTRMI CEMENT TRIP P RIH f/13,915'to 14,196'. SID wt 146k. 13,915.0 14,196.0 17:00 17:30 Decision made to pull back up hole to 13,850'& cont w/CBL. 5/21/2019 5/21/2019 0.50 INTRMI CEMENT TRIP P POOH f/14,196'to 13,821'. 14,196.0 13,821.0 17:30 18:00 5/21/2019 5/21/2019 0.25 INTRMI CEMENT QEVL P Downlink to MWD for bond log. 13,821.0 13,821.0 18:00 18:15 5/21/2019 5/22/2019 5.75 INTRMI CEMENT QEVL P CBL down f/13,821'to 15,312' @ 600- 13,821.0 15,693.0 18:15 00:00 800 ft1hr. Cont. CBL while washing down f/15,312' to 15,693' wl00gpm., 40opsi. Did no observe any excess drag of cement stringers while logging. 5/22/2019 5/22/2019 0.50 INTRMI CEMENT QEVL P Cont. CBL while washing down 15,693.0 15,710.0 00:00 00:30 fit 5,693' wl00 gpm., 400psi. Tag float collar with out rotation @ 15,710'. Did no observe any excess drag of cement stringers while logging. 5122/2019 5/22/2019 2.00 INTRMI CEMENT CIRC P Circ B/U w/500 gpm, 1750 psi. Lost 20 15,710.0 15,710.0 00:30 0230 bbls to formation while circulating. 5122/2019 5/22/2019 1.00 INTRMI CEMENT OWFF P F/C. Ballooning back with decreasing 15,710.0 15,710.0 02:30 0330 to static. 5/22/2019 5/22/2019 0.50 INTRMI CEMENT TRIP P POOH 2 stands f/15,71 O'to 15,513' 15,710.0 15,513.0 03:30 04:00 5/22/2019 5/22/2019 0.25 INTRMI CEMENT OWFF P F/C. Static 15,513.0 15,513.0 04:00 04:15 1 I I Page 21149 Report Printed: 7118/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time our (hr) Phase Op cede AcWty CoEe Time P -T -X Operation (W) End Depth (WB) 5/22/2019 5/22/2019 2.25 INTRMI CEMENT PACK T M/U storm packer as per Baker rep. 15,513.0 15,641.0 04:15 06:30 RIH 1 stand to bit depth 15,641' & hang on drill string on storm packer. (Center of element 114.93) Pressure test top of storm packer to 1000 psi (good). 5/22/2019 5/22/2019 9.75 INTRMI CEMENT RGRP T B/D service lines. Remove flow line & 0.0 0.0 06:30 16:15 hole fill lines. Pull trip nipple & remove flow box. Empty pits. Back away from sub pits & motors complex. Skid rig floor. Raise stompers & shim back of pad with 3x12's. Lower stompers & level rig. Skid floor back into drilling position. Move pits & motors complex back into position & hook up service lines. R/U flow box, hole flVbleeder lines & flow line. Install trip nipple. Finalize rig is ready to resume drilling operations. 5/22/2019 5/22/2019 2.50 INTRMI CEMENT PACK T M/U storm packer retrieval BHA as per 15,641.0 15,513.0 16:15 18:45 Baker rep. RIH & engage storm packer release packer as per Baker rep. Pull packer to rig floor. UD packer & send back to Baker shop for re- configuration. 5/22/2019 5/22/2019 0.25 INTRMI CEMENT OTHR T Establish break over torque 15,513.0 15,513.0 18:45 19:00 parameters for lest packer run @ 15,513'. 10 rpm = 8 wraps @ 28.5 k Mbs of break over torque. Free rotating torque = 26k Nlbs. PU wt 325k. SO 135k. 5/22/2019 5/22/2019 1.50 INTRMI CEMENT CIRC T Circ B/U w/450 gpm, 1730 psi. 15,513.0 15,513.0 19:00 20:30 5/22/2019 5/22/2019 0.50 INTRMI CEMENT OWFF T FIC. Ballooning back with decreasing 15,513.0 15,513.0 20:30 21:00 flow to static. 5/22/2019 5/23/2019 3.00 INTRMI CEMENT PMPO T Pump OOH f/15,513' to 14274' due to 15,513.0 14,274.0 21:00 00:00 swabbing. 5/23/2019 5/23/2019 2.75 INTRMI CEMENT PMPO T Pump OOH f/ 14274'to 13070'. 2.5 14,274.0 13,070.0 00:00 02:45 bpm. 410psi. 5/23/2019 5/23/2019 0.25 INTRMI CEMENT CIRC T Downlink to MWD tools for logging. 13,070.0 13,070.0 02:45 03:00 5/23/2019 5/23/2019 0.75 INTRMI CEMENT OEVL T CBL up f/13,070' to 12,877'. Hole stillP12,877.0 12,877.0 03:00 03:45 swabbing. 5/23/2019 5/23/2019 0.25 INTRMI CEMENT OWFF T Flow check. static. 12,877.0 03:45 04:00 5/23/2019 5/23/2019 0.75 INTRMI CEMENT MPDA T Pull trip nipple. Install MPD bearing 12,877.0 04:00 04:45 assembly. Line up to SOOH. 5/23/2019 5/23/2019 2.25 INTRM1 CEMENT OEVL T SOOH logging f/ 12877'to 12403'. w/ 12,403.0 04:45 07:00 MPD holding 145/30psi out/in slips. Observed swabbing 15k overpull @ 12403'. 5/23/2019 5/23/2019 2.50 INTRMI CEMENT CIRC T Circulate hi -vis sweep around. 12,403.0 12,313.0 07:00 09:30 500gpm. 40 rpm. 18k tq. No increase in cuttings when sweep came across shakers, 5/23/2019 5/23/2019 8.00 INTRMI CEMENT OEVL T SOOH logging f/ 12313'to 8735'. 12,313.0 8,735.0 09:30 17:30 Holding 140psi out/in slips 5/23/2019 5/23/2019 2.00 INTRMI CEMENT CIRC T Circulate hi -vis sweep around and 8,735.0 8,735.0 17:30 19:30 condition mud w,500 gpm, 1280 psi, 50 rpm, 13 k lrq. 5/23/2019 5/23/2019 0.25 INTRMI CEMENT OWFF T Flow check. Static 8,735.0 8,735.0 19:30 19:45 5/23/2019 5/24;019 4.25 INTRMI CEMENT SMPD T SOOH f/ 8735to 3696' Holding 8,735.0 3,696.0 19:45 00:00 140psi out/in slips. Page 22/49 ReportPrinted: 711812019 r Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Sten DePN Stan Time End Time our (no Phase Op Dade Acdviry Code Time P -T -X Operation (RKB) End Depth (fiKB) 5/24/2019 5/24/2019 2.50 INTRMI CEMENT SMPD T SOOH f/ 3696'to 548'. Holding 140psi 3,696.0 548.0 00:00 02:30 outtiin slips. 5/24/2019 5/24/2019 0.25 INTRMI CEMENT OWFF T Flow check. Static 548.0 548.0 02:30 02:45 5/24/2019 5/2412019 0.25 INTRMI CEMENT MPDA T Retrieve MPD bearing assembly and 548.0 548.0 02:45 03:00 install trip nipple. 5/2412019 5/24/2019 0.25 INTRMI CEMENT TRIP T POOH f/ 548'to 360'. 548.0 360.0 03:00 03:15 5/24/2019 5/24/2019 0.50 INTRMI CEMENT OWFF T Flow check. Static. Function test rams. 360.0 360.0 03:15 03:45 PJSM on LD BHA. 5/24/2019 5/24/2019 3.00 INTRMI CEMENT BHAH T UD BHA f/360' as per SLB 360.0 0.0 03:45 06:45 5/24/2019 5/24/2019 1.75 INTRMI CEMENT CLEN T Clean/Clear dg floor. 0.0 0.0 06:45 08:30 5/24/2019 5/24/2019 3.50 INTRMI CEMENT TRIP T MU 9 5/8" CIBP and RIH to 3181'. 0.0 3,181.0 08:30 12:00 5/24/2019 5/24/2019 0.50 INTRMI CEMENT MPSP T Obtain parameters and set CIBP as 3,181.0 3,115.0 12:00 12:30 per baker rep. PU 140k. SO 130k. Rot 138k. 10 rpm 2k tq. Confirm plug set and released w/ 95k set down x 2. Rack back one std. to 3115' 51242019 5/24/2019 0.50 INTRMI CEMENT PRTS T Pressure test 9 5/8" CIBP set at 3181' 3,115.0 3,115.0 12:30 13:00 to 2500psi for 15 minuites. Good test. Note: Witnessing of test by AOGGC waived per Robert Noble 5/24/2019 512412019 2.00 INTRMI CEMENT TRIP T POOH f/ 3115 to to surface with CIBP 3,115.0 0.0 13:00 15:00 running tool. UD running tool. 524/2019 512412019 0.75 INTRMI CEMENT RURD T RU hard lines to bleed off freeze 0.0 0.0 15:00 15:45 protect diesel f/ OA to tiger tank. Bled off OA to opsi. 4bbls total bled to tank. 5/24/2019 5124/2019 2.00 INTRMI CEMENT WAIT T Waiting on tool hand. Simops: Stage 0.0 0.0 15:45 17:45 tools to dg floor. load pipeshed w/ 3 11 /2" tubing for cementing. 5/24/2019 5242019 2.25 INTRMI CEMENT TRIP T MU casing cutter assembly and RIH to 0.0 3,181.0 1745 20:00 3181'. Tag CIBP @ 3181'w/ 5k. Note: Bled off OA (280psi) to tiger tank. 5/24/2019 524/2019 0.25 INTRMI CEMENT CUTP T PU to 3178' putting cutters at 3175'. 3,181.0 3,178.0 20:00 20:15 Obtain parameters. up 135k. down 130k. rot.. 135k. 60 rpm. 3k tq. 250gpm. 1260 psi. 3-7k tq with cutters engaged. Observed OA pressure increase to 460psi. SO w/ 120gpm. 630psi to engage cutters in cut. Confirm good cut. 5/24/2019 5/24/2019 1.50 INTRMI CEMENT CIRC T Close upper rams and displace freeze 3,178.0 3,178.0 20:15 21:45 protect diesel from OA to tank 120- 164gpm. 70-680psi. 271bbls pumped. 277bbls to tiger tank. 10.3ppg mud to surface. 5/2412019 5/24/2019 0.50 INTRMI CEMENT OWFF T Flow check. Static 3,178.0 3,178.0 21:45 22:15 52412019 5/24/2019 0.75 INTRMI CEMENT CIRC T Open rams and CBU 220gpm. 3,178.0 3,178.0 22:15 23:00 1020psi. 5/2412019 5/2412019 0.25 INTRMI CEMENT OWFF T Flow check. Static 3,178.0 3,178.0 23:00 23:15 5/24/2019 5/252019 0.75 INTRM1 CEMENT TRIP T POOH w/ Casing cutter assembly f/ 3,178.0 2,736.0 23:15 00:00 3178' to 2736' 5252019 51252019 3.00 INTRMI CEMENT TRIP T POOH w/ casing cutter f/ 2736' to 2,736.0 0.0 00:00 03:00 surface. 5/25/2019 525/2019 0.25 INTRMI CEMENT OWFF T Flow check. Static. 0.0 0.0 03:00 03:15 Page 23149 Report Printed: 7/18/2019 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Siert Time End Time Dw (hr) Phase Op Code Activity Cada Time PJA Operation mK8) End Deplh (flKe) 5/25/2019 5/25/2019 0.50 INTRMI CEMENT BHAH T UD cutter assembly. Clean/clear rig 0.0 0.0 03:15 03:45 floor. 5/25/2019 5/25/2019 1.75 INTRMI CEMENT BOPE T PJSM. C/O upper rams to 9 5/8" 0.0 0.0 03:45 05:30 casing rams. 5/25/2019 5/25/2019 0.50 INTRMI CEMENT WWSP T Retrieve wear bushing. 0.0 0.0 05:30 06:00 5/25/2019 5/25/2019 3.50 INTRMI CEMENT BOPE T RU test equipment. Test annular/9 5/8" 0.0 0.0 06:00 09:30 casing rams on 9 5/8" test jt. 250/2500 low/high 5min ea. Test annular/lower VBR on 3 1/2" test it. 250/2500psi low/high 5 min ea. R/D lets equipment. 5/25/2019 5/25/2019 2.50 INTRMI CEMENT WWSP T MU running tool to retrieve packoff. 0.0 0.0 09:30 12:00 Engage packoff and pull to surface. 5/25/2019 5/25/2019 8.25 INTRMI CEMENT WAIT T Waitng on csg equipment to arrive. 0.0 0.0 12:00 20:15 Sim -ops: Perform rig maintence.clean/clear pipe shed/rig floor. Mud pump inspection. C/O shaker screens. 5/25/2019 5/25/2019 1.25 INTRMI CEMENT RURD T RU casing equipment to pull 9 5/8" 0.0 0.0 20:15 21:30 casing. 5/25/2019 5/25/2019 1.00 INTRMI CEMENT PULL T MU landing joint to hanger and 3,175.0 3,175.0 21:30 22:30 retrieve hanger. PU 181 k. LD landing joint and hanger. 5/25/2019 5/26/2019 1.50 INTRMI CEMENT PULL T POOH laying down 9 5/8" casing f/ 3,175.0 2,875.0 2230 00:00 3175'to 2875'. 5/26/2019 5/26/2019 5.25 INTRMI CEMENT PULL T POOH laying down 9 5/8" casing 2,875.0 0.0 00:00 05:15 f/2875' to surface. (75 its & 1 cut jt) 5/26/2019 5/26/2019 1.00 INTRMI CEMENT RURD T R/D casing running tools & equipment. 0.0 0.0 05:15 06:15 Clean & Gear floor. 5/26/2019 5/26/2019 3.25 INTRMI CEMENT BOPE T C/O upper rams to 4-1/2" X 7" VBR's.0.0 0.0 06:15 09:30 Test w/5-7/8" test joint. Annular 250/2500 psi & upper rams to 250/3500 psi. RID testing equip & set wear ring. 5/26/2019 5/26/2019 1.25 INTRMI CEMENT RURD T Mobilize tubing running tools & 0.0 0.0 09:30 10:45 equipment to rig floor. 5/26/2019 5/26/2019 0.25 INTRMI CEMENT RURD T Cameron set 12.25" wear ring. 0.0 0.0 10:45 11:00 5/26/2019 5/26/2019 1.00 INTRMI CEMENT RURD T R/U to run 3-1/2" tubing. 0.0 0.0 11:00 12:00 5/26/2019 5/26/2019 1.25 INTRMI CEMENT PUTB T Pick &RIH w/3-1/2" cement stinger 0.0 1,090.0 12:00 13:15 assy to 1,090'. (Mule shoe, 35 its 3- 12" EUE tubing, & XO's) 5/262019 5/26/2019 2.00 INTRMI CEMENT TRIP T C/O handling equipment & RIH 1,090.0 3,180.6- 13:15 15:15 cement stiner assy on 5-7/8" DP to 3,180' 5/26/2019 5/26/2019 0.50 INTRMI CEMENT RURD T M/U head pin, halliburton valve & 3,180.0 3,180.0 15:15 15:45 cement hose. 5/26/2019 5/26/2019 0.50 INTRMI CEMENT CIRC T Circ & cond mud for cement job 300 3,180.0 3,180.0 15:45 16:15 gpm, 300 psi. SIMOPS - PJSM for cement job. 5/26/2019 5/26/2019 1.50 INTRMI CEMENT CMNT T Dowell pump 2 bbls H2O & PT lines to 3,180.0 3,180.0 16:15 17:45 3500 psi (good). Pump 40 bbls 13.0 ppg Mud push w/5 bpm, Pump 125 WE 15.8 ppg, 1.16 yid Class G tail cement w/5 bpm, Pump 5 bbls 13.0 ppg Mud push w/5 bpm. Tum over to rig for displacement. Rig pump 36 bbls 10.3 ppg LSND w/6 bpm @ 180 psi. Pump last 4 bbls for 40 bbls total w/2 bpm @ 20 psi. Page 24/49 ReportPrinted: 711812019 operations Summary (with Timelog Depths) -41, 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Slat Time End Time Dr (hr) phase Op Code Activity Cade Time P -T -X Operation (ws) End Depth (ftKB) 5/26/2019 5/26/2019 0.25 INTRMI CEMENT RURD T R/D cement lines & halliburton valve. 3,180.0 3,180.0 17:45 18:00 5/26/2019 5/26/2019 0.75 INTRMI CEMENT TRIP T POOH @ 1500 ft/hr f/3,180'to 2,560' 3,180.0 2,560.0 18:00 18:45 5/26/2019 5/26/2019 1.25 INTRMI CEMENT CIRC T Install 2x wiper balls in DP. Circulate 2,560.0 2,560.0 18:45 20:00 @ 540 gpm. 400psi. 35bbls good cement to surface. 5/26/2019 5/26/2019 1.25 INTRMI CEMENT TRIP T POOH f/ 2560'to 1090'to first joint of 2,560.0 1,090.0 20:00 21:15 3.5"tbg. 5/26/2019 5/26/2019 0.50 INTRMI CEMENT OWFF T Flow check. Static. Simops RU to LD 1,090.0 1,090.0 21:15 21:45 3.5" tbg. 5/26/2019 5/26/2019 1.75 INTRMI CEMENT PULD T POOH LD 3.5" tbg. 1,090.0 0.0 21:45 23:30 5/26/2019 5/27/2019 0.50 INTRMI CEMENT RURD T RD tbg equipment. Clean/clear dg 0.0 0.0 23:30 00:00 floor. 5/27/2019 5/27/2019 0.50 INTRMI CEMENT RURD T Cont. UD tubing handling equipment. 0.0 0.0 00:00 00:30 Clean/Gear rig floor. 5/27/2019 5/27/2019 1.25 INTRMI CEMENT WWWH T M/U Johnny Wacker &flush stack 0.0 0.0 00:30 01:45 w/11 bpm @ 160 psi 5/27/2019 5/27/2019 2.25 INTRMI WHDBOP RURD T M/U wear ring retrieval tool & pull 0.0 0.0 01:45 04:00 wear ring.. R/U to test BOPE. Flood lines & purge air from system. 5/27/2019 5/27/2019 6.75 INTRMI WHDBOP BOPE T Test BOPE w/5-7/8" & 7" test joints 0.0 0.0 04:00 10:45 Annular 250/3500 psi for 5 min, Remaining lest 250/3500 psi for 5 min. 4" Demon, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper 4- 1/2" X 7" VBR's & Lower 3-1/2" X 6" VBR's & blind rams, 5-7/8" DarVFOSV, HCR / Man choke/kill, Accumulator test, Initial 3000 psi, final 1500 psi, 1st 200 psi recharge = 24 sec's, full recharge = 140 seconds. Nitrogen Bottles x4 = 2100 psi. Gas alarms and PVT alarms tested. Tested draw down on hydraulic chokes 1100psi. AOGCC Bob Noble waived witness. 5/27/2019 5/27/2019 1.25 INTRMI WHDBOP RURD T RID testing equipment. Set 12.25" 0.0 0.0 1045 12:00 long wear ring. Clean & clear floor. 5/27/2019 5/27/2019 4.00 INTRMI CEMENT WOC T W.O.C. SIMOPS - Housekeeping, 0.0 0.0 12:00 16:00 condition mud for drilling ahead, MP2's, rig maintenance, mobilize BHA tools & equipment to rig floor. 5/27/2019 5/27/2019 2.25 INTRMI DRILL BHAH T M/U and RIH w/ 12-1/4" Intermediate 00362.0 16:00 18:15 BHA#1 as per SLB to 362' 5/27/2019 5/27/2019 2.50 INTRMI DRILL TRIP T RIH f/ 362'to 2429' PU 120k/ SO 110k 362.0 2,429.0 18:15 20:45 5/27/2019 5/27/2019 0.25 INTRMI DRILL CIRC T Fill pipe and shallow test MWD tools. 2,429.0 2,429.0 20:45 21:00 All good. 5/27/2019 5/27/2019 1.25 INTRMI DRILL SLPC T PJSM. Slip/cut 75' drill line. Circulate 2,429.0 2,429.0 21:00 22:15 and condition mud. 5/27/2019 5/27/2019 0.50 INTRMI DRILL SVRG T Service Top Drive/blocks/drawworks. 2,429.0 2,429.0 22:15 22:45 5/27/2019 5/28/2019 1.25 INTRMI DRILL CIRC T Circulate and condition mud. Build 4A29.0 2,429.0 22:45 00:00 mud for intermediate section. Load pipeshed w/ 9 5/8" casing. Park rig maintenance. 5/28/2019 5/28/2019 9.75 IN DRILL WOC T Wah on Cement. Building mud/load 2,429.0 2,429.0 00:00 09:45 pipeshed w/ 9 5/8" casing/perform rig maintenance. 5/28/2019 5/28/2019 1.00 INTRMI DRILL WASH T Washlream f/ 2429'to 2566' (top of 2,429.0 2,566.0 09:45 10:45 cement.). 350gpm. 220psi. 40 rpm. 3.5k tq. Set 5k down. Page 25149 Report Printed: 7/18/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth start Tree End Time Our (hr) Phase op Code Activity Code Time P -T -X Cpereeon (ftKB) End Depth (IIKa) 5/28/2019 5/28/2019 3.75 INTRMI DRILL DDRL T Drill out cement f/ 2566'to 2868'(FC 2,566.0 2,868.0 10:45 14:30 @ 2860) 600-750gpm. 580-750psi. 80 rpm. 5-12k tq.3-8k WOB. 5/28/2019 5/28/2019 5.00 INTRMI DRILL KOST T Time drill to KO f/ 2868' to 2995'. 2,868.0 2,995.0 14:30 19:30 750gpm. 850psi. 100rpm. 5-71k tq. PU155k/SO 1351k (pumps off). 5/28/2019 5/29/2019 4.50 INTRMI DRILL DDRL T Drill 2995'to 3371'. 8509pm. 1050psi. 2,995.0 3,371.0 19:30 00:00 10orpm. 8k tq. ADT=7.95hrs. (displaced well to reconditioned 9.5ppg LSND w/ drilling ahead. (Observed increase in cuttings when hi -vis pill came across shakers). 5/29/2019 5/29/2019 12.00 INTRMI DRILL DDRL T Drill 121/4" hole f/ 3371'to 4620'. 3,371.0 4,620.0 00:00 12:00 1000gpm. 1600psi. 180 rpm. 5/7k wob. 8.8/6.3k tq ontoff bottom. PU 170k. SO 143k. Rot 152k. 10.10.48 ECD. ADT=9.03hrs. Pumping sweeps every third std. 5/29/2019 5/30/2019 12.00 INTRMI DRILL DDRL T Drill 121/4" hole f/ 4620'to 5998'. 4,620.0 5,998.0 12:00 00:00 1000gpm. 1820psi. 7/9k wob.180 rpm. 12/8k tq on/off bottom. PU 171 k. SO 137k. Rot 1541k. ADT=9.03hrs. 10.48 ECD. Pumping sweeps every third std. 5/30/2019 5/30/2019 13.50 INTRMI DRILL DDRL T Drill 12 1/4" hole f/ 5998'to 7420'. 5,998.0 7,420.0 00:00 13:30 1000gpm. 1790psi. 12/14k wob.180 rpm. 16/9.5k tq on/off bottom. PU 197k. SO 145k. Rot 167k. ADT=8.86hm. 10.71 ECD. Pumping sweeps every third std. 5/30/2019 5/30/2019 0.50 INTRMI DRILL CIRC T Circulate BU. 100gpm. 1900psi. 150 7,420.0 7,420.0 13:30 14:00 rpm. 10.4k tq. 5/30/2019 5/30/2019 0.25 INTRMI DRILL OWFF T Flow check. Static. 7,420.0 7,420.0 14:00 14:15 5/30/2019 5/30/2019 0.75 INTRMI DRILL MPDA T Retrieve trip nipple. Install MPD 7,420.0 7,420.0 14:15 15:00 bearing assembly. Circulate through MPD system. 5/30/2019 5/31/2019 9.00 INTRMI DRILL DDRL T Drill 121/4"hole f/7420'to 8202'. 7,420.0 8,202.0 15:00 00:00 1000gpm. 1980psi. 16/18kwob.180 rpm. 18.1/12.1k tq onloff bottom. PU 220k. SO 131 k. Rot 160k. ADT=6.94hrs. 10.91 ECD. 5/31/2019 5/31/2019 3.75 INTRMI DRILL DDRL T Drill 12 1/4" hole f/ 8202'to 8551'. 8,202.0 8,551.0 00:00 03:45 1000gpm. 1980psi. 16/181k wob.180 rpm. 18.1/12.1 k tq on/off bottom. 10.91 ECD. 5/31/2019 5/31/2019 0.50 INTRMI DRILL CIRC T Circulate BU. I000gpm. 2050psi. 180 8,551.0 8,551.0 03:45 04:15 rpm. 15k tq. Prep to pull MBP bearing assembly. 5/31/2019 5/31/2019 0.25 INTRMI DRILL OWFF T Flow check. Static 8,551.0 8,551.0 04:15 04:30 5/31/2019 5/31/2019 0.75 INTRMI DRILL MPDA T Retrieve MPD bearing assembly. 8,551.0 8,551.0 04:30 05:15 1 1 1 Install trip nipple. 5/31/2019 5/31/2019 6.75 INTRMI DRILL DDRL T Drill 121/4" hole f/ 8551'to 9115'. 8,551.0 9,115.0 05:15 12:00 1000gpm. 2200psi. 10/13k wob.190 rpm. 17.8/12.7k tq on/off bottom. PU 220k. SO 147k. Rol 170k. 10.59 ECD. ADT=8.22 hrs Page 26149 ReportPrinted: 7118120191 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Tme Dur (hr) Phase Op Code A Wty Cade Time P -T -X Operation (tlKB) End Depth (ftKB) 5/31/2019 6/1/2019 12.00 INTRMI DRILL DDRL T Drill 12 114" hole f/ 9115'to 10233'. 9,115.0 10,233.0 12:00 00:00 1000gpm. 2140psi. 9/1 Ok wob.190 rpm. 15.5/12k tq on/off bottom. PU 230k. SO 155k. Rot 1821k. 10.52 ECD. ADT=9.12 hrs 6/1/2019 6/1/2019 0.25 INTRMI DRILL DDRL T Drill 121/4" hole f/ 10233'to 10245'. 10,233.0 10,245.0 00:00 00:15 1000gpm. 2140psi. 9/1 Ok wob.190 rpm. 15.5/12k tq on/off bottom. PU 230k. SO 155k. Rot 1821k. 10.52 ECD. ADT=.08 hrs 6/1/2019 6/1/2019 1.25 INTRMI DRILL CIRC T Circulate sweep surface to surface. 10,245.0 10,245.0 00:15 01:30 Condition mud for wiper trip. 6/1/2019 6/1/2019 0.25 INTRMI DRILL OWFF T Flow check. Static. 10,245.0 10,245.0 01:30 01:45 611/2019 6/1/2019 10.25 INTRMI DRILL BKRM T Backream OOH f/ 10245'to 7044'. 10,245.0 7,044.0 01:45 12:00 1000 gpm. 1850psi. 190 rpm. 13k tq. PU157k. SO 153k. 6/1/2019 6/2/2019 12.00 INTRMI DRILL BKRM T Backream OOH f/7044'to 4030'. 7,044.0 4,086.0 12:00 00:00 1000 gpm. 1700psi. 190 rpm. 7.5k tq. PU155k. SO 130k. Rot 142k. ECD 10.25 6/2/2019 612/2019 7.50 INTRMI DRILL BKRM T Backream OOH f/4030'to 2806'. 4,086.0 2,806.0 00:00 07:30 1450psi. 190 rpm. 5k tq. Observed pack off @ 3486'. 6/212019 6/2/2019 1.75 INTRMI DRILL CIRC T Circulate 2 sweeps around while 2,806.0 2,806.0 07:30 09:15 conditioning mud. 6/2/2019 602019 0.25 INTRMI DRILL OWFF T Flow check. Static. 2,806.0 2,806.0 09:15 09:30 6/212019 6/2/2019 1.75 INTRMI DRILL GLEN T Remove clay from rotary/drip pan/flow 2,806.0 2,806.0 09:30 11:15 box. 6/2/2019 6/2/2019 1.25 INTRMI DRILL SLPC T PJSM. Slip/cut 30' drill line 2,806.0 2,806.0 11:15 12:30 6/2/2019 612/2019 0.50 INTRMI DRILL SVRG T Service rig. 2,806.0 2,806.0 12:30 13:00 6/212019 612/2019 2.00 INTRMI DRILL RURD T PJSM. Change out saver sub. Rig up 2,806.0 2,806.0 13:00 15:00 load cell and check torque values on top drive. 6/212019 6/2/2019 3.50 INTRMI DRILL TRIP T RIH f/ 2806'to 6572'. Filling pipe every 2,806.0 6,572.0 15:00 18:30 10 stds. 6/212019 6122019 1.00 INTRMI DRILL CIRC T Circulate BU. 6,572.0 6,572.0 18:30 19:30 62/2019 6/22019 3.50 INTRMI DRILL TRIP T RIH f/ 6572'to 10056'. Filling pipe 6,572.0 10,056.0 19:30 23:00 every 10 stds. 6212019 6/32019 1.00 INTRMI DRILL WASH T Wash/ream to 10200'. 660-1000gpm. 10,056.0 10,200.0 23:00 00:00 1030-2000p5i. 140rpm. 13k tq. ECD 10.2ppg 6/3/2019 6/32019 0.25 INTRMI DRILL WASH T Wash down to 10245'. 1000gpm. 10,200.0 10,245.0 00:00 00:15 2020psi. 180 rpm. 14k tq. 6/312019 6/3/2019 0.25 INTRM1 DRILL OWFF T Flow check. Static. 10,245.0 10,245.0 00:15 00:30 6/3/2019 6/3/2019 0.50 INTRMI DRILL MPDA T PJSM. Retrieve trip nipple and install 10,245.0 10,245.0 00:30 01:00 RCD bearing assembly. 6/32019 6132019 1.50 INTRMI DRILL CIRC T Stage up pumps. check RCD bearing 10,245.0 10,245.0 01:00 02:30 and lines. Start 580 bbl mud dilution. 6/32019 6132019 6.00 INTRMI DRILL DDRL T Drill 10245'to 10810'. 100gpm. 10,245.0 10,810.0 02:30 08:30 2110psi. 190 rpm. 9/11k wob. 17k/12.5k tq on/off bottom. ECD 10.87ppg 6132019 6/32019 1.00 INTRMI DRILL CIRC T Circulate bottoms up 100gpm. 10,810.0 10,810.0 08:30 09:30 I 2100psi. 180 rpm. 15k tq. 613/2019 6/32019 0.25 INTRMI DRILL SIPB T Perform MPD drawdown test in C-37 10,810.0 10,810.0 09:30 09:45 sands. Static. Page 27/49 Report Printed: 7/181201i - Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start rime Erb Time our inn Phase Op Code Activi(y Code Tim P -T -X Operation (ftKB) End Depth (aK8) 6/32019 6/3/2019 2.25 INTRMI DRILL DDRL T Drill 10810'to 10985'. 1000gpm. 10,810.0 10,985.0 09:45 12:00 2110psi. 190 rpm. 9111 k wob. 171</12.5k tq on/off bottom. PU 225k. SO 148k. ROT 180k. ECD 10.87ppg ADT = 6.1. Pumping sweeps every 3rd std. 6/3/2019 6/4/2019 12.00 INTRMI DRILL DDRL T Drill 10985'to 12222'. 1000gpm. 10,985.0 12,222.0 12:00 00:00 2330psi. 190 rpm. 10/12k wob. 17k/12.5k tq ontoff bottom. PU 253k. SO 150k. ROT 190k. ECD 10.94 ADT = 9.21 Pumping sweeps every 3rd std. 6/4/2019 6/4/2019 12.00 INTRMI DRILL DDRL T Drill 12222'to 13370'. 10009pm. 12,222.0 13,370.0 00:00 12:00 2540psi. 190 rpm. 13/15k wob. 24.5k/1 8k tq on/off bottom. PU 274k. SO 158k. ROT 191 k. ECD 11.06. ADT = 8.92 6/4/2019 6/5/2019 12.00 INTRMI DRILL DDRL T Drill 13370'to 14389'. 1000gpm. 13,370.0 14,389.0 12:00 00:00 2520psi. 190 rpm. 15/16k wob. 27.5122k tq onloff bottom. PU 280k. SO 157k. ROT 205k. ECD 10.90. ADT = 10.04 6/512019 6/5/2019 9.50 INTRMI DRILL DDRL T Drill 14389'to 15128'. 900gpm. 14,389.0 15,128.0 00:00 09:30 2080psi. 190 rpm. 18120k wob. 30/18k tq on/off bottom. PU 297k. SO 165k. ROT 207k. ECD 10.83. ADT 7.58 6/5/2019 6/5/2019 0.25 INTRMI DRILL CIRC T Circulate and condition mud while 15,128.0 15,128.0 09:30 09:45 repairing shaker#3. 700gpm. 1330psi. 190 rpm. 25k tq. 6/5/2019 6152019 11.75 INTRMI DRILL DDRL T Drill 15128'to 16023'. 1000gpm. 15,128.0 16,023.0 09:45 21:30 2670psi. 120-180 rpm. 10112k wob. 31/29k tq on/off bottom. PU 325k. SO 175k. ROT 225k. ECD 10.94. ADT 9.16 6/5/2019 6/612019 2.50 INTRMI CASING CIRC T Circulate hole clean. I000gpm. 16,023.0 15,895.0 21:30 00:00 2530psi. 180rpm. 26k tq. Rack back 1 std per bottoms up. 6/6/2019 6162019 2.25 INTRMI CASING CIRC T Circulate hole cleanracking back 1 std 15,895.0 15,800.0 00:00 02:15 per bottoms up f/ 15895' to 15800. 950gpm. 2500psi. 180rpm. 25k tq. ECD 10.9 6/612019 6/6/2019 3.25 INTRMI CASING CIRC T Weight up system f/ 9.6ppg to 15,800.0 15,706.0 02:15 05:30 1O.Oppg. 750 gpm. 1650psi. 160 rpm. 25k tq. ECD 11.05 6/6/2019 6/6/2019 0.75 INTRMI CASING CIRC T Circulate bottoms up and condition 15,706.0 15,706.0 05:30 06:15 mud. 750 gpm. 1650pis. 160 rpm. 24k tq. ECD 11.13 6/62019 6/6/2019 2.00 INTRMI CASING BKRM T Bacream OOH f/ 15706' to 15235'. 15,706.0 15,235.0 06:15 08:15 700gpm. 1560psi. 160 rpm. 24k tq. 11.12 ECD 6/6/2019 6/6/2019 2.50 INTRMI CASING CIRC T Circulate 40bbl H2O & 30bbi hi -vis 15,235.0 15,235.0 08:15 10:45 sweep around. 700gpm. 1530psi. 140 rpm. 23k tq. 11.1 ECD 616/2019 6!7/2019 13.25 INTRMI CASING BKRM T Backream OOH f/ 15235'to 11300'. 15,235.0 11,300.0 10:45 00:00 650-700gpm. 1150-1350psi. 120 rpm. 11 7-23k tq. ECD 11.10-11.2. 6/7/2019 6!7/2019 3.50 INTRMI CASING BKRM T Backream OOH f/ 11300'to 10245'. 11,300.0 10,245.0 00:00 03:30 700-725gpm. 1290-1360psi. 140rpm. 19-22k tq. 6/7/2019 6/7/2019 2.25 INTRMI CASING CIRC T Pump 40bbl H2O sweep and 35bbl 10,245.0 10,245.0 03:30 0545 hihis nutplug sweep surface to surface. Minimal increase in cuttings across shakers when sweeps came around. Page 28149 Report Printed: 7/182019 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stannme End Time Our (hr) Phase Op Code Activity Code Time P -T -X Operdon (fto) End Depth (tlKa) 6/7/2019 6/7/2019 1.75 INTRMI CASING CIRC T Weight up system f/ IO.Oppg to 10,245.0 10,245.0 05:45 07:30 10.3ppg. 617/2019 6/7/2019 0.25 INTRMI CASING OWFF T Flow check. Static. 10,245.0 10,245.0 07:30 07:45 6!7/2019 617/2019 0.25 INTRMI CASING SMPD T SOOH. Observed 40k Overpull @ 10,245.0 10,064.0 07:45 08:00 10064'. dh TO 10150' 617/2019 617/2019 1.50 INTRMI CASING CIRC T Circulate BU 550gpm. 850psi. 80 rpm. 10,064.0 10,064.0 08:00 09:30 116ktq. 617/2019 617/2019 0.50 INTRMI CASING MPDA T PJSM. Retrieve RCD bearing 10,064.0 10,064.0 09:30 10:00 assembly. Install trip nipple. 6/7/2019 618/2019 14.00 INTRMI CASING BKRM T Backream OOH f/ 10064' to 7255' 10,064.0 7,255.0 10:00 00:00 600-800gpm. 900-1300psi.120- 170rpm. 13-18k tq. Maintain below 11.0ppg ecd. Tight spots 846277364'17337'/7292'/7283'/7272'. 6/8/2019 6/8/2019 5.75 INTRMI CASING BKRM T Backream OOH f/ 7255'to 7140'. 550- 7,255.0 7,140.0 00:00 05:45 800gpm. 710-1370psi. 150-185 rpm. 13.5-14k tq. Maintain ECD below 11.0ppg. tight spots and ECD spikes. Circulated hi vis nutplug sweep around with no increase in cuttings. 6/8/2019 618/2019 2.25 INTRMI CASING CIRC T Circulate aroumnd 20 bbl H20130 bbl 7,140.0 7,140.0 05:45 08:00 weighted sweep 11.3ppg. minimal increase in cuttings. 1000gpm. 1900psi. 200rpm. 12.5k tq. 6/8/2019 6/8/2019 4.00 INTRMI CASING BKRM T Backream OOH f/ 7140-7037'. 900- 7,140.0 7,037.0 08:00 12:00 1000gpm. 1600-1900psi. 200rpm. 13k tq. pumped 30bbl nut plug/drilzone sweep. 6/8/2019 6/9/2019 12.00 INTRMI CASING BKRM T Backream 0011111 7037'to 5125'. 7,037.0 5,125.0 12:00 00:00 1 900gpm. 1540psi.200rpm. 12.5k tq. 6/9/2019 6/9/2019 6.75 INTRMI CASING BKRM T Backream OOH f/ 5125'to 4780'. 5,125.0 4,780.0 00:00 06:45 900gpm. 1540psi. 200rpm. 10k tq. Pumped 30bbl hi vis weighted sweep @ 4825'w/ no increase in cutttit observed at shakers. 6/9/2019 6/9/2019 3.00 INTRMI CASING CIRC T RIH to 4860'. circulate 2 30bbi hi vis 4,780.0 4,860.0 06:45 09:45 weighted sweeps arounf. obeserve cuttings increase across shakers. 6/9/2019 6/9/2019 6.75 INTRMI CASING BKRM T Backream OOH f/ 4860' to 4640'. 4,860.0 4,689.0 09:45 16:30 900gpm. 1550psi. 170rpm. 1 O tq. Packing off. Wash down to 4689'. 290 bbl dilution. @ 4670' 6/9/2019 6/9/2019 2.00 INTRMI CASING CIRC T Circulate 4 BU 550-1000gpm. 610- 4,689.0 4,689.0 16:30 18:30 1740psi. 80rpm. 5k tq. Pumped 30 bbl 11.3ppg hivis sweep. Minimal increase in cuttings across shakers. 6/9/2019 6/9/2019 5.00 INTRMI CASING BKRM T Backream OOH f/ 4689' to 4557', 600- 4,689.0 4,557.0 18:30 23:30 900 gpm. 850-1440psi. 80-150rpm. 5- 12k tq. Packing off with ECD spikes @ 4557'. 6/9/2019 6/10/2019 0.50 INTRMI CASING CIRC T MU a std and wash back down to 4,557.0 4,689.0 23:30 00:00 1 1 14689'. 6/10/2019 6/10/2019 4.00 INTRMI CASING BKRM T Be kream OOH f/ 4689' to 4581'. 650- 4,689.0 4,581.0 00:00 04:00 1000gpm.880-1750psi. 30-200rpm.6- 8ktq. Pumped 35 bbl hivis/nut plug sweep with no increase of cuttings across shaker. 6/10/2019 6/10/2019 5.50 INTRMI CASING PMPO T Pump OOH f/ 4581 to 4300'. 700gpm. 4,581.0 4,300.0 04:00 09:30 940psi. Page 29149 Report Printed: 7/18/2019 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth StartTime End Time Dur hr) Phase Op Code Activity Code Time P -T-% OpereOon (ftKB) End Depth (WB) 6/10/2019 6/10/2019 2.00 INTRMI CASING CIRC T Circulate and condition hole. 700- 4,300.0 4,300.0 0930 11:30 1000gpm. 940-1780psi. 100-140rpm. 5-6k tq. Pumped 30 bbis hi vis/nutplug sweep with no increase in cuttings across shakers. 6/10/2019 6/10/2019 0.50 INTRMI CASING PMPO T Pump OOH f/ 4300'to 4260'. 700gpm. 4,300.0 4,260.0 11:30 12:00 970psi, 6/10/2019 6/10/2019 10.00 INTRMI CASING PMPO T Pump OOH f/ 4260'to 2820'. 200gpm. 4,260.0 2,820.0 1200 2200 150psi. Observed 10-20k overpull @ 3055' and 3043'. Stage pumps up to 500gpm. 1Orpm. work through spots. Drop back through spots and pull through with no rotary. 6/10/2019 6/10/2019 1.75 INTRMI CASING CIRC T CBreak circulation. Stage pumps up to 2,820.0 2,617.0 2200 2345 1000gpm. 80rpm. 3.5k lq. 1620psi. ECD 10.87ppg. Rack back 1 std per BU. Pumped 40 bbl hivis/nutplug sweep. with minimal increase of cuttings across shakers. 6/10/2019 6/11/2019 0.25 INTRMI CASING OWFF T Flow check. Static. 2,617.0 2,617.0 2345 0000 6/11/2019 6/11/2019 0.50 INTRMI CASING TRIP T POOH f/ 2617' to 2332'. Started 2,617.0 2,332.0 00:00 00:30 1 1 swabbing. 6/11/2019 6/11/2019 1.25 INTRMI CASING BKRM T Backream OOH f/ 2332'to 2050'. 650- 2,332.0 2,050.0 00:30 01:45 800gpm. 710-980psi. 30-50rpm. 1-3k tq. 6/11/2019 6/11/2019 1.75 INTRMI CASING PMPO T Pump OOH f/2050'to 1020'. 800gpm. 2,050.0 1,020.5- ,020.001:45 01 45 0330 980psi. 6/11/2019 6/11/2019 0.50 INTRMI CASING CIRC T Circulate BU 1000gpm. 1440psi. 80 1,020.0 1,020.0 0330 0400 rpm. 3k tq. Large increase in cuttings across shakers. Circulate until cleaned up. 6/11/2019 6/11/2019 2.00 INTRMI CASING PMPO T Pump OOH f/ 1020'to 330'. 400gpm. 1,020.0 330.0 04:00 06:00 1 1 1250psi, 6/11/2019 6/11/2019 025 INTRMI CASING OWFF T Flow Check, Static 330.0 330.0 0600 0615 6/11/2019 6/11/2019 1.75 INTRMI CASING BHAH T PJSM. LID BHA. 330.0 0.0 0615 0800 6/11/2019 6/11/2019 0.75 INTRMI CASING CLEN T Clean and clear rig floor. 0.0 0.0 0800 0845 6/11/2019 6/11/2019 0.75 INTRMI CASING BOPE T MU jetting tool. RIH and jet stack. 0.0 0.0 08:45 0930 1000gpm. 650psi. 20 rpm. 1k tq. 6/11/2019 6/11/2019 0.75 INTRMI CASING BOPE T Drain stack. B/D topdrive. Retrieve 0.0 0.0 09:30 1015 wear bushing. 6/11/2019 6/11/2019 1.75 INTRMI CASING BOPE T Change out upper rams to 9 5/8" 0.0 0.0 10:15 12:00 casing rams. 6/11/2019 6/11/2019 1.50 INTRMI WHDBOP RURD T RIH w/ 5 7/8" test joint. fill stack and 0.0 0.0 12:00 13:30 ensure seals holding. Pull 5 718" test joint and RIH w. 9 5/8" test joint. RU test equipment. flood system and purge air out. Page 30/49 Report Printed: 7/18/2019 e Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log SW Depth SWn ima End Time Our (hr) Phaco Op Code Activity Code Time PJA Operation (MB) End Depth (ftn) 6/11/2019 6/11/2019 5.00 INTRMI WHDBOP ROPE T Test BOPE w/5-7/8" & 9 5/8" test joints 0.0 0.0 13:30 18:30 Annular 250/3500 psi for 5 min, Remaining test 250/3500 psi for 5 min. 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper 4- 1/2" X 7" VBR's & Lower 3-1/2" X 6" VBR's & blind rams, 5-7/8" Dart/FOSV. HCR / Man choke/kill, Accumulator test, Initial 3000 psi, final 1500 psi, 1st 200 psi recharge = 24 sec's, full recharge = 140 seconds. Nitrogen Bottles x4 = 2100 psi. Gas alarms and PVT alarms tested. Tested draw down on hydraulic chokes 1100psi. ( Test witnessed by AOGCC Austin Mcleod.) 6/11/2019 6/11/2019 0.75 INTRM1 WHDBOP RURD T R/D test equipment. Retrieve test 0.0 0.0 18:30 19:15 plug. 6/11/2019 6/11/2019 1.75 INTRMI CASING RURD T RU csg equipment to run 9 5/8" csg. 0.0 0.0 19:15 21:00 Remove bails/elevators. Install master bushing. 6/11/2019 6/12/2019 3.00 INTRMI CASING SVRG T Service rig/ Top drive. Change out drill 0.0 0.0 21:00 00:00 link system and function. Wait on clamps for 500 ton bails to arrive. 6/12/2019 6112/2019 2.00 INTRMI CASING RURD T RU bails and volant tool w/ torque turn 0.0 0.0 00:00 02:00 1 1 1 sub. 6/12/2019 6/12/2019 7.00 INTRMI CASING PUTB T PJSM. MU shoe track and test same. 0.0 2,779.0 02:00 09:00 Continue RIH w/ 9 5/8" casing to 2779'. (MU 13k tq. using torque turn). 6/12/2019 6112/2019 1.50 INTRMI CASING CIRC T Circulate BU staging up rate to 5 bpm. 2,779.0 2,779.0 09:00 10:30 100psi. 6/12/2019 6/12/2019 1.00 INTRMI CASING RURD T Change out bails to 15 ft 250 ton bails. 2,779.0 2,779.0 10:30 11:30 MU side entry sub above torque turn sub. 6/12/2019 6/1212019 2.25 INTRMI CASING PUTB T RIH w/ 9 5/8" 40# casing f/ 2779' to 2,779.0 3,952.0 11:30 13:45 1 1 13952'. (Circulate BU every 1000'). 6/12/2019 6/12/2019 0.75 INTRMI CASING CIRC T Circulate BU staging pumps up 130- 3,952.0 3,952.0 13:45 14:30 175 gpm. 180-150psi. 177k PUM 62k SO. 6/12/2019 6/12/2019 1.50 INTRMI CASING PUTB T RIH w/ 9 5/8" 40# casing f/ 3952' to 3,952.0 4,743.0 14:30 16:00 4743'. (Circulate BU every 1000'). 6/12/2019 6/12/2019 1.25 INTRMI CASING CIRC T Circulate BU staging pumps up 120- 4,743.0 4,743.0 16:00 17:15 175 gpm. 140-130psi. 180k PU/160k SO. 6112/2019 6/12/2019 1.75 INTRMI CASING PUTB T RIH w/ 9 5/8" 40# casing fl 4743' to 4,743.0 5,732.0 17:15 19:00 1 1 15732'. (Circulate BU every 1000'). 6/1212019 6/12/2019 1.50 INTRMI CASING CIRC T Circulate BU staging pumps up 130- 5,732.0 5,732.0 19:00 20:30 175 gpm. 170-170psi. 192k PU/165k SO. 6/12/2019 6/12/2019 1.50 INTRMI CASING PUTB T RIH w/ 9 5/8" 40# casing f/ 5732' to 5,732.0 6,720.0 20:30 22:00 6720'. (Circulate BU every 1000'). 6/12/2019 6/12/2019 1.25 INTRMI CASING CIRC T Circulate BU staging pumps up 100- 6,720.0 6,720.0 22:00 23:15 250 gpm. 190-250psi. 198k PU1160k SO. 6/12/2019 6/13/2019 0.75 INTRMI CASING PUTB T RIH w/ 9 5/8" 40# casing f/ 6720' to 6,720.0 7,038.0 23:15 00:00 1 1 7038'. (Circulate BU every 1000'). 6113/2019 6/13/2019 1.00 INTRMI CASING PUTB T RIH w/ 9 5/8" 40# casing f/ 7038' to 7,038.0 7,517.0 00:00 01:00 7517'. SO 155k 611312019 6/13/2019 1.25 INTRMI CASING CIRC T Circulate BU. Stage rate up to 7,517.0 7,517.0 01:00 0215 250gpm. 240psi. PU 21 Ok. SO 165k. 6/13/2019 6/13/2019 2.25 INTRMI CASING PUTB T RIH w/95/8"40#casing f/7517'to 7,517.0 8,525.0 02:15 04:30 8525'. SO 150k 6/13/2019 6/13/2019 1.75 INTRMI CASING CIRC T Circulate BU. Stage rate up to 8,525.0 8,525.0 04:30 06:15 250gpm. 300psi. PU 220k. SO 155k. Page 31149 ReportPrinted: 711812019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Srert Dept SWTIM End Time Dur (hr) Phase Op Cade Activity Code Time P-T-X Operation (WB) End Depth(fIKB) 6/13/2019 6/1312019 4.25 INTRMI CASING PUTB T RIH w/ 9 5/8" 40# casing f/ 8525'to 8,525.0 10,386.0 06:15 10:30 10386'. SO 160k 6/13/2019 6/13/2019 3.50 INTRMI CASING CIRC T Circulate BU. Stage rate up to 10,386.0 10,386.0 10:30 14:00 250gpm. 370psi. PU 245k. SO 165k. 6/13/2019 6/13/2019 4.75 INTRMI CASING PUTB T RIH w/ 9 5/8" 40# rasing f/ 10386' to 10,386.0 12,396.0 14:00 18:45 12396'. SO 165k 6/13/2019 6/13/2019 3.00 INTRMI CASING CIRC T Circulate BU. Stage rate up to 12,396.0 12,396.0 18:45 21:45 1350gpm. 500psi. PU 260k. SO 155k. 6/13/2019 6/14/2019 2.25 INTRMI CASING PUTB T RIH w/ 9 5/8" 40# casing f/ 12396' to 12,396.0 13,097.0 21:45 00:00 13097'. SO 160k 6/14/2019 6114/2019 2.50 INTRMI CASING PUTB T RIH w/ 9 5/8" 40# casing f/ 13097' to 13,097.0 13,801.0 00:00 02:30 13801'. SO 145k 6/14/2019 6/14/2019 2.50 INTRMI CASING CIRC T Circulate BU. Stage rate up to 13,801.0 13,801.0 02:30 05:00 350gpm. 580psi. PU 300k. SO 150k. 6114/2019 6/14/2019 3.75 INTRMI CASING PUTB T RIH w/ 9 5/8"40# rasing f/ 13801' to 13,801.0 15,004.0 05:00 08:45 15004'. SO 145k. Taking weight 20k @ 13861'. (Wash down f/ 13861'to 13903'/14592' to 14632'. 60gpm. 370psi.) 6/1412019 6/14/2019 3.25 INTRMI CASING CIRC T Circulate BU. Stage rate up to 15,004.0 15,004.0 08:45 12:00 300gpm. 610psi. PU 300k. SO 150k. 6/14/2019 6/14/2019 6.75 INTRMI CASING PUTB T RIH w/ 9 5/8" 40# casing f/ 15004' to 15,004.0 15,970.0 12:00 18:45 15970'. Taking weight (35k) @ 15326'. Wash f/ 15326' to 15492'. 25- 200gpm. 430-670psi. Regained SO weight and continue RIH. 6/14/2019 6/14/2019 0.75 INTRMI CASING HOSO T MU 9 5/8" hanger and landing joint. 15,970.0 16,013.0 18:45 19:30 Land hanger. PU and re-land to confirm. Drain stack and confirm landed. Shoe @ 16013' 6/14/2019 6/15/2019 4.50 INTRMI CEMENT CIRC T Break circulation. Circulate and 16,013.0 16,013.0 19:30 00:00 reciprocate 25-230gpm. 560-840psi. 375k PU. 100k SO. Started taking weight and increase in pressure. Landed hanger and stage rates to 230gpm. Observed several packoffs. Slow rates and stabilized pressures. Stage rates up to 200gpm slowly with good return flow and pressures. Minimal losses observed. 6/15/2019 6/15/2019 3.75 INTRMI CEMENT CIRC T Circ & cond mud for cement job w/4.5 16,013.0 16,013.0 00:00 03:45 - 8 bpm, 650 - 710 psi. Hole attempting to pack off reduce rate to 6 bpm, 560 psi 6/15/2019 6/15/2019 0.25 INTRMI CEMENT OWFF T FIC static 16,013.0 16,013.0 03:45 04:00 6/15/2019 6/15/2019 1.00 INTRMI CEMENT RURD T B/D top drive. C/O packer cup on 16,013.0 16,013.0 04:00 05:00 Volant. R/U cement lines. 6/15/2019 6/15/2019 1.00 INTRMI CEMENT CIRC T Break circulation thru cement lines 5.5 16,013.0 16,013.0 05:00 06:00 bpm @ 590 psi, 7 bpm @ 800 psi. SIMOPS - PJSM on cementing. Page 32149 Report Printed: 7118/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth start Time End Time our (hr) Phese Op Code Activity Code Time P -T -X Operation (ftKB) End Depth(fiK0) 6/15/2019 6/15/2019 6.50 INTRMI CEMENT CMNT T Dowell pump 5 bbls H2O & PT lines to 16,013.0 16,013.0 06:00 12:30 3000 psi (good). Pump 61.6 bbls 13.0 ppg Mud push with 5 - 2.5 bpm. Drop bottom plug. Pump 175.3 bbls 15.8 ppg, 1.16 yld Class G tail cement w/5 bpm. Drop 2 top plugs. Pump 10.2 bbls H2O w/4 bpm. Turn over to rig for displacement. Rig pump 1214 bbls 10.3 ppg LSND w/2%776. Final circulating rate 3 bpm @ 1380 psi. (Hole started packing off 750 bbls into displacement & lost returns 900 bbls into displacement. Started to see minimal returns 1050 bbls into displacement) Bumped plug w/10,200 stks, pressure 500 psi over f/1380 psi to 1880 psi & hold for 5 min. Check floats (good). CIP @ 12:20 Hrs. Lost total 300 bbls to formation. 6/15/2019 6/15/2019 0.50 INTRMI CEMENT OWFF T F/C (Slight ooze & slowing). SIMOPS - 0.0 0.0 12:30 13:00 R/D cement lines from Volant & back Volant out of landing it. Service rig & draw works. Clean & clear floor. 6/15/2019 6/15/2019 2.25 INTRMI CEMENT RURD T UD landing it. R/D Volant. R/U 12' 0.0 O.O 13:00 15:15 bales & 5-7/8" handling equipment. Install bell guide on top drive. SIMOPS - F/C (Slight ooze & slowing) 6/15/2019 6115/2019 0.75 INTRMI CEMENT WWWH T M/U Johnny Wacker & flush stack. 0.0 0.0 15:15 16:00 6/15/2019 6/15/2019 2.00 INTRMI CEMENT W WSP T Set Cameron pack off & lest to 5000 0.0 0.0 16:00 18:00 1 psi for min. 6/15/2019 6/15/2019 1.50 INTRMI WHDBOP RURD P C/O upper rams to 4-1/7" X 7" VBR's. 0.0 0.0 18:00 19:30 Set upper test plug & R/U to test BOPE. 6/15/2019 6/15/2019 2.00 INTRMI WHDBOP BOPE P Test annular & upper rams w/5-7/8" & 0.0 0.0 19:30 21:30 7" test joints to 250/3500 psi for 5 min 6/15/2019 6/15/2019 1.75 INTRMI WHDBOP RURD P R/D testing equipment. Pull test plug & 0.0 0.0 21:30 23:15 set 12-1/4" ID wear ring. 6/15/2019 6/16/2019 0.75 INTRMI CEMENT SHAH P M/U 8-1/2" X 9-7/8" Intermediate #2 0.0 80.0 23:15 00:00 j BHA as per SLB to 80'. 6/16/2019 6/16/2019 2.50 INTRMI CEMENT BHAH P M/U 8-1/2" X 9-7/8" Intermediate #2 80.0 355.0 00:00 02:30 BHA as per SLB f/80'to 355' 6/16/2019 6/16/2019 1.00 INTRMI CEMENT TRIP P RIH f/355'to 2,234' 355.0 2,234.0 02:30 03:30 6/16/2019 6/16/2019 0.75 INTRMI CEMENT DHEQ P Shallow hole test MWD tools w/475 2,234.0 2,234.0 03:30 04:15 gpm @ 1080 psi 6/16/2019 6/16/2019 1.00 INTRMI CEMENT SLPC P Slip & cut drill line while circ w/2 bpm 2,234.0 2,234.0 04:15 05:15 @ 80 psi 6/16/2019 6/16/2019 0.50 INTRMI CEMENT SVRG P Service rig 2,234.0 2,234.0 05:15 05:45 6/16/2019 6/16/2019 5.75 INTRMI CEMENT TRIP P RIH N2,234'to 9766'. SIMOPS-H2O 2,234.0 9,766.0 05:45 11:30 flush & freeze protect on OA 6/16/2019 6/16/2019 0.50 INTRMI CEMENT DHEQ P Downlink to LWD tools & activate 9,766.0 9,766.0 11:30 12:00 sonic log CBL tool w/475 gpm, 1560 psi 6/16/2019 6/16/2019 2.25 INTRMI CEMENT TRIP P Log free ringing pipe f/9,766' to 9,954'. 9,766.0 13,255.0 12:00 14:15 Cont to RIH to 13,255' 6/16/2019 6/16/2019 5.50 INTRMI CEMENT QEVL P CBL f/13,255'to 15,939' Wash down 13,255.0 15,939.0 14:15 19:45 last std. 150gpm. 490psi. Tag FC without rotation @ 15939'. 6/16/2019 6/16/2019 1.50 INTRMI CEMENT CIRC P Rack back 1 std. to 15885'. Circulate 15,939.0 15,885.0 19:45 21:15 BU conditioning mud for casing test. 10.3ppg in/out. Page 33149 Report Printed: 711 812 01 9 -, Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Start Time End Time our (M) Phase op Code Activity Code Time P -T -X operation (ftKa) EM Depth (flKe) 6/16/2019 6/16/2019 0.25 INTRMI CEMENT OWFF P Flow check. Static. 15,885.0 15,885.0 21:15 21:30 6/16/2019 6/16/2019 0.50 INTRMI CEMENT RURD P RU to test casing. 15,885.0 15,885.0 21:30 22:00 6/16/2019 6116/2019 1.50 INTRMI CEMENT PRTS P Pressure up to 3500psi @ 1/2 bpm. 15,885.0 15,885.0 22:00 23:30 Held for 30 minutes. Good lest. Initial 3520psi. Final 3510psi. RID test equipment. 6/16/2019 6/17/2019 0.50 INTRMI CEMENT REAM P Wash/ream to 15934.5'. 4509pm. 15,885.0 15,934.0 23:30 00:00 11710psi. 40 rpm. 20k tq. 195k rot. 6/17/2019 6117/2019 2.75 INTRMI CEMENT DRLG P Drill float collar & shoe track f/15,934' 15,934.0 16,003.0 00:00 02:45 to 16,003', 425 - 500 gpm, 1580 - 2100 psi, 40 - 60 rpm, 31-33 k trq 6/17/2019 6/17/2019 1.50 INTRMI CEMENT CIRC P Circ B/U w/525 rpm, 2050 psi, 40 rpm, 16,003.0 16,003.0 02:45 04:15 32 k trq 6/17/2019 6/17/2019 1.00 INTRMI CEMENT DRLG P Cont. to drill out shoe w/525 rpm, 16,003.0 16,018.0 04:15 05:15 2050 psi, 15 - 60 rpm, 32 - 38 k trq. Torque appears to be high. Decision made to displace to new/reconditioned 10.5 ppg -SND. 6/17/2019 6/17/2019 2.00 INTRMI CEMENT DISP P Displace to new/reconditioned 10.5 16,018.0 16,018.0 05:15 07:15 ppg LSND w/350 - 525 gpm, 1110 - 2120 psi, 40 rpm, 32 - 38 k trq. 6/17/2019 6/17/2019 1.25 INTRMI CEMENT DRLG P Drill out shoe & rat hole to 15,023' 16,018.0 16,023.0 07:15 08:30 w/400 - 450 gpm, 1400 - 1700 psi, 40 - 60 rpm, 30 - 34 k trq (FC @ 15,930' & shoe @ 16,023') 6/17/2019 6/17/2019 0.50 INTRMI CEMENT DDRL P Drill 20'new formation fit 6,023'to 16,023.0 16,043.0 08:30 09:00 16,043' MD / 5,812' TVD, ADT .5 Hrs, 12.74 ppg ECD, 525 gpm, 2120 psi, PU wt 295 It, SO wt 125 K, ROT wt 190 k, 80 rpm, 34 k ft lbs trq 6/17/2019 6/17/2019 1.00 INTRMI CEMENT CIRC P Circ B/U for FIT. Mouse hole stand to 16,043.0 15,981.0 09:00 10:00 15,981' 6/17/2019 6/17/2019 0.25 INTRMI CEMENT OWFF P FIC (static) 15,981.0 15,981.0 10:00 10:15 6/17/2019 6117/2019 1.25 INTRMI CEMENT FIT P R/U testing equipment. FIT to 16.0 15,981.0 15,981.0 10:15 11:30 ppg (1660 psi w/10.5 ppg mud). R/D testing equipment. SIMOPS - PJSM on RCD bearing. 6/17/2019 6/17/2019 1.00 INTRM2 DRILL MPDA P Pull trip nipple & install RC D bearing. 15,981.0 16,043.0 11:30 12:30 Break in bearing & perform mock Connections as per MPD advisor. Wash & ream back down to TD of 16,043' 6/17/2019 6/17/2019 2.50 INTRM2 DRILL DDRL P Drill ahead 8-1/2" pilot hole f/16,043' 16,043.0 16,185.0 12:30 15:00 to 16,185' 6/17/2019 6/17/2019 0.25 INTRM2 DRILL CIRC P Open reamer as per SLB. Base 16,043.0 16,185.0 15:00 15:15 Parameters: Reamer closed = 532 gpm, 2310 psi, 27341rpm / Reamer open = 532 gpm, 1950 psi, 2187 trpm. Open 5' of hole & stacked 10 k on lower ledge, Picked up & pulled 10 k against upper ledge. Top of 9-7/8" hole @ 16,022' 6117/2019 6/18/2019 8.75 INTRM2 DRILL DDRL P Drill ahead 8-1/2" X 9-7/8" hole 16,185.0 16,520.0 15:15 00:00 f/16,185'to 16520'. 500-525 gpm. 2090-2180 psi. 80-130 rpm. 36k tq. 11 -18k wob. ECD 13.4-13.6 ppg. 9.87 hrs ADT Page 34149 ReportPrinted: 7/18/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time EM Time our (h) Phase Op Code ActrAy Cone Time P -T -X Operation mKB) End Depth (IIKB) 6/18/2019 6/18/2019 12.00 INTRM2 DRILL DORL P Drill ahead 8-1/2" X 9-7/8" hole 16,520.0 17,040.0 00:00 12:00 f/16,520' to 17,040' MD / 6,003' TVD, ADT 10.18 Hrs, 13.42 ppg ECD, 500 gpm, 2060 psi, PU wt 285 k, SO wt 115 K, ROT wt 175 k, 140 rpm, Torque On/Off 32/22k ft lbs trq 6/18/2019 6/19/2019 12.00 INTRM2 DRILL DDRL P Drill ahead 8-1/2" X 9-7/8" hole 17,040.0 17,585.0 12:00 00:00 f/17,040' to 17,585' MD / 6,095' TVD, ADT 10.33 Hrs, 13.10 ppg ECD, 500 gpm, 1978 psi, PU wt 285 k, SO wt 117 K, ROT wt 181 k, 125 rpm, Torque On/Off 35/32k ft lbs trq 6/19/2019 6/19/2019 9.75 INTRM2 DRILL DDRL P Will ahead 6-1/2" X 9-7/8" hole 17,585.0 17,896.0 00:00 09:45 fit 7,585'to TD of 17,896' MD / 6,149' TVD, ADT 6.99 Hrs, 13.18 ppg ECD, 600 gpm, 2320 psi, PU wt 290 k, SO wt 110 K, ROT wt 200 k, 150 rpm, Torque On/Off 28/23k ft Itis trq 6/19/2019 6/19/2019 1.75 INTRM2 CASING CIRC P Pump up final survey. Circ B/U w/600 17,896.0 17,896.0 09:45 11:30 gpm, 2250 psi, 150 rpm, 28 k trq 6/19/2019 6/19/2019 0.50 INTRM2 CASING OWFF P F/C. Perform draw down test for 20 17,896.0 17,896.0 11:30 1200 min. No increase in pressure. F/C on TT for 10 min. (static) 6/19/2019 6/19/2019 2.25 INTRM2 CASING CIRC P Wt up from 10.5 ppg to 10.8 ppg while 17,896.0 17,896.0 12:00 14:15 Rotating and Reciprocating, 600 gpm, 2260 psi, 150 rpm, 26k To, Rot Wt 180k. 6/19/2019 6/19/2019 0.25 INTRM2 CASING OWFF P Close Reamer per SLB Rep, Initial 17,896.0 17,896.0 14:15 14:30 TRPM 2343 @j 550 gpm, 2080 psi, 80 rpm, 191k To, Reduce rate to 240 gpm, 930 psi for 2 min, inc rate to 550 gpm, 2310 psi, Final TRPM 2929 confirming reamer closed. 6/19/2019 6/19/2019 0.25 INTRM2 CASING CIRC P Obtain SPRs with 10.8 ppg mud. Drop 17,896.0 17,772.0 14:30 14:45 2.36" hollow drift, line up MPD to Strip OOH with back Pressure. Strip OOH from 17896 to 17,772' MD holding 50/250 psi infout slips. PU 325k. 6/19/2019 6/19/2019 5.75 INTRM2 CASING SMPD P Strip OOH from 17,772'to 15,981'. 17,772.0 15,981.0 14:45 20:30 hold 50/250 psi in/out slips. PU 3151k. 6/19/2019 6/19/2019 1.75 INTRM2 CASING CIRC P Circulate BU (x2) until clean. Rotate 15,981.0 15,981.0 20:30 22:15 and Reciprocate, 550 gpm, 2400 psi, 120 rpm, 17k TO, Rot Wt 180k. Good cutting returns Q 1st BU, cleaned up at 1.5 BU, clean at 2 BU. 6/19/2019 6/19/2019 0.50 INTRM2 CASING OWFF P Observe Well for Flow. (STATIC) 15,981.0 15,981.0 22:15 22:45 6/19/2019 6/20/2019 1.25 INTRM2 CASING SMPD P Strip OOH from 15,981'to 15,183'. 15,981.0 15,183.0 22:45 00:00 hold 50/350 psi in/out slips. PU 285k. 6/20/2019 6/20/2019 12.25 INTRM2 CASING SMPD P Strip OOH from 15,183'to 1,857' as 15,183.0 1,857.0 00:00 12:15 per stripper schedule. 6/20/2019 6/20/2019 0.25 INTRM2 CASING OWFF P F/C (static). SIMOPs on pulling RCD 1,857.0 1,857.0 12:15 12:30 bearing 6/20/2019 6/20/2019 0.50 INTRM2 CASING MPDA P Pull RCD bearing & install trip nipple. 1,857.0 1,857.0 12:30 13:00 6/20/2019 6/20/2019 0.25 INTRM2 CASING CIRC P Pump 22 bbl dry job 1,857.0 1,857.0 13:00 13:15 6/20/2019 6/20/2019 1.75 INTRM2 CASING PULD P POOH & UD 48 jts 5-718" DP 1,857.0 355.0 13:15 15:00 6/20/2019 6/20/2019 0.25 INTRM2 CASING OWFF P F/C (static) 355.0 355.0 15:00 15:15 6/20/2019 6/20/2019 0.75 INTRM2 CASING PULD P UD HWDP & Jars 355.0 229.0 15:15 16:00 Page 35/49 Report Printed: 7118/2019 . Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start rime End Time our (hr) Phase Op GDd8 Activity Code Time P -T -X Operation (flKB) End Depth MKB) 6/20/2019 6/20/2019 2.25 INTRM2 CASING BHAH P PJSM. UD BHA as per SLB. (Remove 229.0 0.0 16:00 18:15 sources) 6/20/2019 6/20/2019 1.75 INTRM2 CASING RURD P CLN - CLR rig frloor of excess tools, 0.0 0.0 18:15 20:00 R/U casing equip. to run 7" csgt. per detail, PJSM on rumming csg. 6/20/2019 6/21/2019 4.00 INTRM2 CASING PUTB P M/U 7" HYD 563 liner per detail T/ 0.0 1,736.0 20:00 0000 1736' U/D wt. 91K 6/21/2019 6/21/2019 0.50 INTRM2 CASING PUTB P M/U 7"Cont. to PIU & RIH 7" Hyd 563 1,736.0 2,066.0 00:00 0030 liner f/1736' to 2,066' UID wt. 100K 6/21/2019 6/21/2019 0.50 INTRM2 CASING RURD P CIU handling equipment. 2,066.0 2,066.0 00:30 01:00 6/21/2019 6/21/2019 0.75 INTRM2 CASING OTHR P M/U liner hanger/packer assy f/2,066' 2,066.0 2,108.0 01:00 01:45 to 2,108' 6/21/2019 6/21/2019 0.50 INTRM2 CASING CIRC P RIH 1 stand DP f/2,108'to 2,206'. 2,108.0 2,206.0 01:45 02:15 Obtain base parameters: 3 bpm, 160 psi, PU wt 110 k, SO wt 105 k 6/21/2019 6/212019 9.75 INTRM2 CASING RUNL P RIH liner on DPf/2,206'to 10,323' 2,206.0 10,323.0 02:15 12:00 6/21/2019 6/21/2019 8.50 INTRM2 CASING RUNL P RIH liner on DP f/10,323'to 15,952' 10,323.0 15,950.0 12:00 20:30 circ bottoms up, Spp 800, spm 61, max gas 300 units, P/U 240k, SIO 165k, 6/21/2019 6/21/2019 1.50 INTRM2 CASING RUNL P RIH liner on DP f/1 5950'T/ 17090' 15,950.0 17,090.0 20:30 22:00 SIO 120 k, p/u 270k, 6/21/2019 6222019 2.00 INTRM2 CASING RUNL P Circulate stands down F/ 17090' T/ 17,090.0 17,800.0 22:00 00:00 17,800', S/O 65k, P/U 295 k, spm 7, spp 480 / 590, 622/2019 6/22/2019 1.25 INTRM2 CASING RUNL P Cont. to wash liner down f/17,800'to 17,800.0 17,896.0 00:00 01:15 1 1 1 TD of 17,896' w/1.5 bpm @ 570 psi 6/22/2019 622/2019 0.50 INTRM2 CEMENT RURD P M/U baker cement swivel 17,896.0 17,896.0 01:15 01:45 6/22/2019 6/22/2019 3.50 INTRM2 CEMENT CIRC P Circ & cond mud for cement jab .5 - 17,896.0 17,896.0 01:45 05:15 4.5 bpm, 580 - 700 psi, Reciprocate pipe, PI wt 310 k / SO wt 137 k 6/22/2019 6/22/2019 1.25 INTRM2 CEMENT RURD P R/U cement lines to cement swivel 17,896.0 17,896.0 05:15 06:30 6/22/2019 6222019 0.75 INTRM2 CEMENT CIRC P Circ w/4.5 bpm, 670 psi. SIMOPS - 17,896.0 17,896.0 06:30 07:15 PJSM on cementing 6/22/2019 6/22/2019 3.25 INTRM2 CEMENT CMNT P Dowell pump 5 bbls H2O & PT lines to 17,896.0 17,896.0 07:15 10:30 3800 psi (good). Pump 47 bbls 13.0 ppg Mud Push, Drop bottom dart, Pump 125 bbls 15.8 ppg, 1.16 yld Class G tail cement, Drop top dart, Pump 10 bbls H2O w/4 - 5 bpm. Tum over to rig for displacement. Rig pump 429 bbls 10.8 ppg -SND. Final circulating rate 3 bpm @ 1050 psi. (Saw bottom dart @ 2945 stks & top dart land @ 3071 slks). Bumped plug w/3635 slks. Pressure up 1500 psi & hold for 5 min. Check floats (good). CIP CEJ 10:35 Hrs 6/22/2019 6/22/2019 0.25 INTRM2 CEMENT OWFF P F/C (static) 17,896.0 17,896.0 10:30 10:45 1 1 I I Page 36149 Report Printed: 7/18/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log seen Depar Start Time End Time our (hr) Phase, Op Code Activity Code Time P -T -X Operation (W13) End Depth (11KB) 6/22/2019 6/22/2019 1.25 INTRM2 CEMENT PACK P Pressure up to 3000 psi to set liner 17,896.0 15,786.0 1045 12:00 hanger. S/O w/50 k and confirm set. Pressure up to 3650 psi to release from liner. Liner not released. R/U test pump & pressure up to 4200 psi to release liner. Saw indication of shear. Pull dog sub out of liner & confirm liner released. S/O w/50 k WOB & set packer. Confirm packer set. Pressure up to 1000 psi & pull packer easy out of liner. Pressure drop to 350 psi & confirm seals out of liner. (Liner shoe @ 17,895' & TOL @ 15,786') 6122/2019 6/22/2019 2.25 INTRM2 CEMENT CIRC P Line up to reverse circ. Close annular 17,896.0 15,786.0 12:00 14:15 preventer. Reverse circ & cond mud w/initial of 370 gpm @ 1790 psi & final 240 gpm @ 1040 psi. Dumped 291 bbls of mud push, cement & cement contaminated mud. Saw indication of good cement to surface. 6/22/2019 6/22/2019 0.50 INTRM2 CEMENT RURD P RID cement lines. UD cement swivel 17,896.0 15,773.0 14:15 14:45 & 2Its DP to 15,767' 6/22/2019 6/22/2019 0.50 INTRM2 CEMENT TRIP P POOH & rack back 2 stands DP to 15,773.0 15,580.0 14:45 15:15 1 1 15,580 6/22/2019 6/22/2019 1.00 INTRM2 CEMENT PRTS P R/U & test liner top packer to 1000 psi 15,580.0 15,580.0 1515 1615 & chart for 10 min (good). R/D testing equipment 6/2212019 6/22/2019 1.75 INTRM2 CEMENT SLPC P Slip & cut drill line. SIMOPS -circ & 15,580.0 15,580.0 16:15 18:00 cond mud 6/22/2019 6/22/2019 0.50 INTRM2 CEMENT SVRG P Service rig, inspect elect motors, TO 15,580.0 15,580.0 18:00 18:30 hyd system, pump 28 bbl dry job, 6/22/2019 6/23/2019 5.50 INTRM2 CEMENT TRIP P TOOH on elevators F/ 15678 T/ 7107'. 15,580.0 7,023.0 18:30 00:00 6/23/2019 6/23/2019 5.00 INTRM2 CEMENT TRIP P POOH f/7,107'to 708' 7,107.0 708.0 00:00 05:00 6/23/2019 6/23/2019 2.00 INTRM2 CEMENT PULD P UD 21 jts drill pipe & liner running 708.0 0.0 05:00 07:00 tools. 6/2312019 6/23/2019 0.50 INTRM2 CEMENT CLEN P Clean and dear rig floor. 0.0 0.0 07:00 07:30 6/23/2019 6/23/2019 1.00 INTRM2 CEMENT W W WH P R/U & flush stack, w/ 11.5 bpm, 130 0.0 0.0 07:30 08:30 psi. 6/23/2019 6/23/2019 4.50 INTRM2 WHDBOP RURD P C/O upper rams to 3-1/2" X 6" VBR's. 0.0 0.0 08:30 13:00 C/O blind rams. SIMOPS - C/O XTM- 57 saver sub & perform derrick inspection. 6/23/2019 6/23/2019 1.75 INTRM2 WHDBOP RURD P Pull wear ring. Set lest plug. R/U to 0.0 0.0 13:00 14:45 test BOPE's. M/U test It & 4" safety valves. Fill stack w/1-120 & purge air From system. 6/23/2019 6/23/2019 6.00 INTRM2 WHDBOP BOPE P Test BOPE w/4" & 5-7/8" test joints to 0.0 0.0 14:45 20:45 250 low & 3500 psi high for 5 min. 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper & Lower 3 -1/2" X 6" VBR's & blind rams, 5-7/8" DaiVFOSV, 4" Darf/FOSV, HCR / Man choke/kill, Accumulator test, Initial 3025 psi, final 1600 psi, tat 200 psi recharge = 23 sec's, full recharge = 120 seconds. Nitrogen Bottles x4 = 2050 psi. Gas alarms and PVT alarms tested. Tested draw down on hydraulic chokes 1100psi. AOGCC Brian Bixby waived witness. Page 37149 Report Printed: 7/18/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depth Stan Time End Time Dur (hr) Plisse Op COOe Activity Code Time P -T -X Operation (RKe) End Depth (ftKe) 6/23/2019 6/23/2019 1.00 INTRM2 WHDBOP RURD P RID testing equipment. Pull test plug. 0.0 0.0 20:45 21:45 Set wear 12.25" ID marring. B/D lines. 6/23/2019 6/23/2019 1.25 INTRM2 CEMENT RURD P Bring BHA tools & equipment to rig 0.0 0.0 21:45 23:00 floor. R/U drillers side tongs. C/O handling equipment to 4" 6/23/2019 6/24/2019 1.00 INTRM2 CEMENT BHAH P M/U 6 1/8" BHA as per SLB to 81' 0.0 81.0 23:00 00:00 6/24/2019 6/24/2019 2.50 INTRM2 CEMENT BHAH P Cont. M/U 6 1/8" BHA as per SLB f/81' 81.0 354.0 00:00 02:30 to 354' 6/24/2019 6/24/2019 2.00 INTRM2 CEMENT PULD P RIH while picking up 4" DP f/354' to 354.0 2,244.0 02:30 04:30 2,244' 6/24/2019 6/24/2019 0.75 INTRM2 CEMENT DHEQ P Shallow hole test MWD tools w1250 2,244.0 2,244.0 04:30 05:15 gpm, 1500 psi 6/24/2019 6/24/2019 2.00 INTRM2 CEMENT PULD P RIH while picking up 4" DP f/2,244'to 2,244.0 4,137.0 05:15 07:15 4,137' 6/24/2019 6/24/2019 1.25 INTRM2 CEMENT QEVL P Downlink tools to turn on logging. Log 4,137.0 4,518.0 07:15 08:30 free ringing pipe f/4,137' to 4,518'. Downlink to tools & turn off logging. 6/24/2019 6/24/2019 7.25 INTRM2 CEMENT PULD P RIH while picking up 4" DP f/4,518'to 4,518.0 10,859.0 08:30 15:45 10,761'. P/U 3Its 5" DP to 10,859' 6/24/2019 6/24/2019 3.50 INTRM2 CEMENT TRIP P RIH w/5-7/8" DP out of derrick 10,859.0 15,469.0 15:45 19:15 f/10,859'to 15,469" 6/24/2019 6/24/2019 0.50 INTRM2 CEMENT DHEQ P Circ T/ downlink & activate MWD 15,469.0 15,469.0 19:15 19:45 SonicScpe F/ CBL @ 240 gpm, 2201 psi @ 15,469' 6/24/2019 6/24/2019 1.50 INTRM2 CEMENT QEVL P RIH w/5-7/8" DP out of derrick 15,469.0 16,289.0 19:45 21:15 f/15,469' to 16,289', @ 800 FPH F/ CBL 6/24/2019 6/24/2019 1.00 INTRM2 CEMENT COCF P Wash and ream F/ 16,289' T/ 16,383' 16,289.0 16,383-0- 21:15 22:15 cmenl stringer @ 150 gpm, 1090 SPP, 40 RPM, ROT 175k, IOK lrq, p/u 220, SIO 140k w/ pumps. 6/24/2019 6/25/2019 1.75 INTRM2 CEMENT TRIP P Contue RIH w/5-7/8" DP out of derrick 16,383.0 16,987.0 22:15 00:00 f/ 16,383 T/ 16,987'SIO 135K 6/25/2019 6/25/2019 1.50 INTRM2 CEMENT TRIP P TIH F/16,987' MD -T/17,721' MD w/5- 16,987.0 17,721.0 00:00 01:30 7/8" Drillpipe CBL Down (Tag cement at 17,721' MD) 6/25/2019 6/25/2019 1.00 INTRM2 CEMENT COCF P Drill cement F/17,721' MD -T/17,754' 17,721.0 17,754.0 01:30 02:30 MD 150 gpm, 40-60 rpm,12-14k torque 6/25/2019 6/25/2019 0.25 INTRM2 CEMENT TRIP P POOH F/ 17,754' MD -T/ 17,729' MD 17,754.0 17,729.0 02:30 02:45 6/25/2019 6/25/2019 2.75 INTRM2 CEMENT CIRC P Circulate bottoms up /condition mud 17,729.0 17,729.0 02:45 05:30 prior to casing test at 17,729' MD. 240 gpm, 1,975 psi Sim -ops PJSM, Slip and cut 53' drill line, Service topdrive, blocks and draworks 6/25/2019 6/25/2019 1.50 INTRM2 CEMENT PRTS P PJSM, Rig up and test 7" casing to 17,729.0 17,729.0 05:30 07:00 3,500 psi for 30 minutes Charted and good test 6/25/2019 6/25/2019 5.00 INTRM2 CEMENT DRLG P Ddg shoe track F/ 17,759 T/ 17,896', 17,729.0 17,896.0 07:00 12:00 W/ 150 to 220 gpm, 11200/ 1800 spp, 40/80 RPM, 19/24 k lorq. 6/25/2019 6/25/2019 0.50 INTRM2 CEMENT DRLG P Ddg F/ 17,896' T/ 17,916', ADT .37 17,896.0 17,916.0 12:00 12:30 hrs, Tvd = 6172'. 6/25/2019 6/2512019 2.50 INTRM2 CEMENT CIRC P Circulate and condution mud F/ FIT 17,916.0 17,916.0 12:30 15:00 test. GPM 240, SPP 2040, RT. WT. 180K, RPM 80, TQ 24K. 6/25/2019 6/25/2019 0.50 INTRM2 CEMENT FIT P OWFF, well static 17,916.0 17,916.0 15:00 15:30 Page 38/49 Report Printed: 711812019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depen Start Time End Time our (hr) Phase Op Code Activity Corte Time P-T-X Operation (NCB) End Depth (eKB) 6/25/2019 6/25/2019 1.00 INTRM2 CEMENT FIT P PJSM, R/U test equip. Perform FIT @ 17,916.0 17,916.0 15:30 16:30 14.5 EMW. mud wt. 10.6+ ppg, MW T/ 1231 psi, F/ 10 min, chart test, 5.6 bbls T/ test, 4.2 bbls on bleed ogg, rig dwn teste equip. 6/25/2019 6/25/2019 0.75 PROD1 DRILL MPDA P OWFF, PJSM, install MPD RCD per 17,916.0 17,916.0 16:30 17:15 Beyond Rep. Circ thru system F/ clear flow path, p/u 285K, a/c 125k, rot 180k, rpm 80, tq 25k. 6/25/2019 6/26/2019 6.75 PROD1 DRILL DISP P Displace well T/ 9.2 ppg FLOPRO 17,916.0 17,916.0 17:15 00:00 mud. circ @ 240 gpm, 2060 psi, 80 RPM, 26K tq. ICP 2080 psi, FCP 1980 psi 6/26/2019 6/26/2019 0.25 PROD1 DRILL DISP P Finish displacement T/9.2 ppg, flopro, 17,916.0 17,916.0 00:00 00:15 240 gpm,1,890 psi, 80 rpm, 14.5k Torque 6/26/2019 6/26/2019 0.50 PROD1 DRILL MPDA P 17,823' MD, Perform formation 17,916.0 17,823.0 00:15 00:45 drawdown test v;/MPD 6/26/2019 6/26/2019 0.50 PROD1 DRILL REAM P Wash and ream F/17,916' MD- 17,823.0 17,916.0 00:45 01:15 T/17,823' wl 240 gpm, 1,875 psi,80 rpm,14.5 torque 6/26/2019 6/26/2019 1.25 PROD1 DRILL DDRL P Drill F/17,916' MD-T/17,990' w/ 240 17,916.0 17,790.0 01:15 02:30 gpm,1,875 psi,80 rpm,14.5 torque 6/26/2019 6/26/2019 1.00 PROD1 DRILL CIRC P 17,990' MD- circulate out gas through 17,990.0 17,990.0 02:30 03:30 MGS. 240 gpm, 1,875 psi, 80 rpm,14.5 torque. Max gas units 9,330. 6/26/2019 6/26/2019 8.00 PROD1 DRILL DDRL P 17,990-T/18,671' Drill-6-1/8" 17,990.0 18,671.0 03:30 11:30 Production hole. 6/26/2019 6/26/2019 2.25 PROD1 DRILL CIRC P Circ out gas @ 18671' ( 8250 units) 18,671.0 18,671.0 11:30 13:45 thru degasser, hold 11 ppg emw W/ MPD, GPM 245, SPP 2160, RPM 100, TRQ 19.5K. Mointor gas F/ 2X BTMS up W/ 240 psi BP. Continue drilling W/ MPD holding EMW @ 11 emw. 6/26/2019 6127/2019 10.25 PROD1 DRILL DDRL P . Continue drilling W/ MPD holding 18,671.0 19,400.0 13:45 00:00 EMW @ 11 emw F/ 18,671 T/19,400', GPM 260, SPM 51, WOB 10/14k, RPM 150, SPP 2380 on bot, 2190 off bot, TQ on bot 25.5k,TQ off bot 15k 6/27/2019 6/27/2019 0.25 PROD1 DRILL DDRL P Drill from 19,400' MD-T/19,423" MD. 19,400.0 19,423.0 00:00 00:15 10-13k WOB, 250 gpm, 2,000 psi, 150 rpm, 25.5k Torque 6/27/2019 6/27/2019 2.00 PRODt DRILL CIRC P Circulate out gas at 19,423' MD. 250 - 19,423.0 19,423.0 00:15 02:15 gpm, 100 rpm, 22k torque, holding 11.2 PPG/EMW via MPD. 6/27/2019 6127/2019 9.75 PROD1 DRILL DDRL P Drill F/19,423' MD-T/19,769' MD. 19,423.0 19,769.0 02:15 12:00 6,147' TVD 10k Bit wt. 100 rpm, 270 gpm- 2,450 psi, 140 rpm, Torque on 25.5 k, Torque off 15.5k. ADT - 7.76 hrs. 61272019 6/27/2019 6.00 PROD1 DRILL DDRL P Drill F/19,769' MD - T/20075' MD. 19,769.0 20,075.0 12:00 18:00 6,155' TVD 8/13k Bit wt. 140 rpm, 270 gpm- 2,510 psi, 140 rpm, Torque on 26 k, Torque off 15.5k. 6/27/2019 6/2712019 1.00 PROD? DRILL DDRL P Drill 6 118 Production hole F/20075' 20,075.0 20,125.0 16:00 19:00 MD-T20125'MD. 6,153' TVD, WOB 9/11 k. RPM 140, GPM 270, SPP 2,540 on bol, 2500 off bot. RPM 95 ROT 179K,Torque on 19.5 k, Torque off 17k, P/U 268K, 6/27/2019 627/2019 1.25 PROD1 DRILL DDRL T Troubleshoot MWD per DD, pick up off 20,125.0 20,125.0 19:00 20:15 bottom Cycle pumps 2X to down link F/ PWRDRV RSS sys Steer Coms.Tools link up continue T/ Drill. Page 39149 Report Printed: 7118/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan DePm Stan Time I Ertl Tmi our (no Phase Cp Code Act$Vlly Cotle Time P-T-X Operation (510) End Depm(fiKa) 6/27/2019 6/28/2019 3.75 PRODI DRILL DDRL T Continue Drilling 6 1/8 Prod. hole FI 20,125.0 20,283.0 2015 00:00 20,125 T/20,283, WOB 14/18K, RPM 95, GPM 270, SPP 2550 on bot, 2530 psi off bot, TO on bot 20.5 k, To off bot 19k, ROT WT. 180K, P/U 270K ADT 9.5 hrs BIT hrs 31.06 Jar hrs 31.06 6/28/2019 6/28/2019 6.00 PROD1 DRILL DDRL P Drill Production section F/20,283' MD- 20,283.0 20,407.0 00:00 06:00 7/20,407' MD 6,164' TVD 270 gpm, 2,515 psi, 95 rpm, 16k torque, 3k bit wt. Flow out 10%, Gas units- 230, Hold 11.2 PPG/EMW w/MPD drilling & Connections. Rot wt. 173k, Torque off- 15.5k, 2,500 psi off, ADT 4.86, Bit & Jar hrs. 35.92 6/28/2019 6/28/2019 6.00 PROD1 DRILL DDRL P Drill Production section F/20,407' MD- 20,407.0 20,708.0 06:00 12:00 T/ 20,708' MD 6,188' TVD 270 gpm, 2,530 psi, 95 rpm, 26.5k torque, 8-1 Ok bit wt. Flow out 10%, Gas units- 370, Hold 11.2 PPG/EMW w/MPD drilling & Connections. Rot wt. 250k, Up 185k, Dn 133k,Torque off- 13k, 2450 psi off, ADT 5.16, Bit & Jar hrs. 41.08 628/2019 6/2812019 3.00 PROD1 DRILL DDRL P Drill Production section F20,708' MD- 20,708.0 20,866.0 12:00 15:00 T/ 20,866' WOB 10/12 K, SPP 2550, GPM 2 70, To on bolt 26 k, ROT 258K, PIU 258K, SIO 127k, rot WT. 176k, adt 1.67 HR, Bit hrs 41.75, Jar hrs 41.75 6/28/2019 6/28/2019 1.00 PRODI DRILL DDRL P Encounter 20 deg DLS on survey. P/U 20,866.0 20,832.0 15:00 16:00 to 20,832', dend DN/Link, circulate F/ 1 hour W/270 gpm, SPP 2570, 100 rpm, trq 12.5k 6128/2019 6/28/2019 4.50 PRODI DRILL DDRL P Time drill @ 1 / 4' HR F/20,832 T/ 20,832.0 20,844.0 16:00 20:30 20844', TVD 6186', HLDG 11.2 EMW, with MPD, GPM 270, SPP 2570, RPM 100, Torq 13K, MWD tool dropped DWN link. 6/28/2019 6/28/2019 3.25 PROD1 DRILL DDRL T PIU to 20,843' perform SLB anti-Jam 20,844.0 20,844.0 20:30 23:45 procedure as per DD. W/ 120-280 gpm, 1250 T/ 2390 psi, 13.5K torq, DNLINK DRV T/Neutral 6/28/2019 6/29/2019 0.25 PRODI DRILL OWFF P Perform Draw down test as per MPD 20,844.0 20,844.0 23:45 00:00 rep. 600 psi Init. shutin - bleed dwn T/ 399 psi. 6/29/2019 612912019 0.75 PRODI DRILL OWFF T Complete draw down test, taking 20,843.0 20,843.0 00:00 00:45 returns to TT. initial SIP 625, finial SIP 376 psi, Bleed 3 bola total 629/2019 6/29/2019 0.25 PROW DRILL BKRM T Back ream out of hole F/ 20843'T/ 20,843.0 20,837.0 00:45 01:00 20837'W/ 250 gpm, 2100 spp, 100 rpm, trq 22k, flow out 11 %, p/u 188k. 6/29/2019 612912019 3.00 PROD1 DRILL CIRC T CBU @ 20837'W/ 250 gpm, 2100 20,843.0 20,837.0 01:00 04:00 spp, 100 rpm, trq 22k, flow out 11%, p/u 188k 6/29/2019 6129/2019 8.00 PROD1 DRILL BKRM T Back ream out of hole F/ 20,837 T/ 20,837.0 18,859.0 04:00 12:00 18859'w/ 250 gpm, 100 rpm, 17/18k torq, rot wt 178k, p/u 184k. HLDG 510 psi (11ppg emw) with MPD in slips. 6/292019 6/292019 3.25 PROD? DRILL BKRM T Continue Back ream out of hole F/ 18,859.01 18,643.0 12:00 15:15 18859 T/ 18643'w/ 250 gpm, 2070 spp, 130 rpm, 18/20k torq, rot wt 185k, p/u 250k. HLDG 510 psi (11 ppg emw ) with MPD in slips. Page 40149 Report Printed: 711812019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log SWI Depth Stat Time End Time Our (m) Phase Op Code Activity Code Time P-T-X Opembon (W) End DepM(ftKa) 6/29/2019 6/29/2019 4.00 PROW DRILL PMPO T Pump out of hole F/ 18671 T/ 17823', 18,643.0 17,823.0 15:15 19:15 250 gpm, 2000 spp, Vo 10%, p/u 245K, holding 11 emw with mpd 6/29/2019 6/30/2019 4.75 PROD1 DRILL CIRC T CBU 2 X, (14288 stks) gpm 250, SPP 17,823.0 19:15 00:00 2030, Rt wt 190k. S/0 160k, RPM 42, TRQ 10k, holding 510 psi w/ MPD =11.0 EMW 6/30/2019 6/30/2019 0.75 PROD1 DRILL CIRC T 17,823' MD complete circulation of 17,823.0 17,823.0 00:00 00:45 bottoms up X 2, Rotating and reciprocating. 250 gpm, 2,000 psi, 40 rpm,1 Ok torque, flow out 10% Hold 11.0 PPG/EMW w/ MPDF 6/30/2019 6/30/2019 1.00 PRODt DRILL CIRC T Spot 120 bbl's Hi-Vis KW Brine spacer 17,823.0 17,823.0 00:45 01:45 in annulus (KW= 11.0 PPG) 6/30/2019 6/30/2019 2.50 PROD1 DRILL SMPD T Strip OOH F/17,823'MID -T/17,164' 17,823.0 17,164.0 01:45 04:15 MD Hold 11. PPG / EMW w/MPD 6/30/2019 6/30/2019 1.00 PRODt DRILL MPDA T Work rollover calculations over again. 17,184.0 17,164.0 04:15 05:15 Verify correct, PJSM prior to beginning displacemt w/KW fluid. Rig crew and Vac truck drivers 6/30/2019 6/30/2019 4.75 PRODI DRILL CIRC T at 17,161'MD. Displace well from 9.3 17,164.0 17,164.0 05:15 10:00 Flo-pro over to 11 PPG brine KW fluid. Holding 11.0 ppg/EMW on formation with MPD. 250 gpm ICP= 1,510 psi / FIC at 200 gpm = 1,220 psi Flow out 5% 6/30/2019 6/30/2019 0.75 PROW DRILL OWFF T Monitor well via MPD corealis until 17,164.0 17,164.0 10:00 10:45 shows zero flow. Open up 2" Bleeder valve below MPD bearing monitor for well static. (Static) 6/30/2019 6/30/2019 1.25 PROD1 DRILL SMPD T Strip OOH F/17,164' MD-T/ 16,694' 17,164.0 16,694.0 10:45 12:00 MD. Use trip schedule and hold (11.0 PPG/EMW) with MPD. Up wt. 227Kk. Initial pulling speed 500' per hour. 6/30/2019 6/30/2019 9.25 PROD1 DRILL SMPD T Strip OOH F/16,694' T/ 10,590MD. 16,694.0 10,950.0 12:00 21:15 Use trip schedule and hold 40/60 psill.0 PPG/EMW with MPD. Up wt. 164k. Initial pulling speed 1500' per hour. 6/30/2019 6/30/2019 0.50 PROD! DRILL OWFF T OWFF ( 2.5 BPH static loss rale) 10,950.0 10,950.0 21:15 21:45 calcuted hole fill F/ 5.875 DP = 69.3 bbls, Actual hole fill = 123bbls, PJSM on changing RCD'S 6/30/2019 7/1/2019 2.25 PROD1 DRILL MPDA T POOH F/ 10,950' T/ 10,757' Remove 10,950.0 10,757.0 21:45 00:00 5.875 bearing, install 4" bearing per MPD rep. 7/112019 711/2019 2.00 PROD1 DRILL SMPD T Strip OOH Rack back 4" drillpipe in 10,757.0 7,917.0 00:00 02:00 derrick F/10,757' MD - T/7,917' MD Up wt. 150k. 7/1/2019 7/1/2019 0.25 PRODt DRILL RURD T Rig up to lay down 80 stands 4" 7,917.0 7,917.0 02:00 02:15 drillpipe 711/2019 7/1/2019 8.00 PROD1 DRILL SMPD T Strip out of hole F/7,917' MD - T/446' 7,917.0 446.0 02:15 10:15 MD laying down 4" Drillpipe to shed. MPD Chokes fully open 7/1/2019 7/1/2019 0.25 PROD1 DRILL OWFF T Monitor well for flow-hole taking fluid 446.0 446.0 10:15 10:30 7/1/2019 711/2019 0.75 PROD1 DRILL MPDA T PJSM/ Pull RCD R Install trip nipple 446.0 446.0 10:30 11:15 7/1/2019 7/1/2019 0.75 PRODi DRILL OWFF T Monitor well for flow-30 Minutes well 446.0 446.0 11:15 12:00 1 1 I took fluid at a 7 bph rate. 7/1/2019 7/1/2019 2.50 PRODi DRILL BHAH T PJSM, Lay down BHA F/446' MD to 446.0 0.0 12:00 14:30 1 I surface per DD. Hole laking fluid at 7 bph rate Page 41149 Report Printed: 7/1812019 Gperations Summary (with Timelog Lepths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time End Time our (hr) Phase Op Code Aoevo Code Time P -T -X Operaaen (fiKe) End DepM (RKB) 7/1/2019 7/1/2019 0.50 PROD1 DRILL CLEN T Clear and clean rig floor 0.0 0.0 14:30 15:00 7/1/2019 7/2/2019 9.00 PROD1 DRILL BOPE T Rig up and test BOPE 250 low psi 5 0.0 0.0 15:00 00:00 min. 3,500 high psi 5, min. BOPE equipment tested - Annular, 3.5 X 6 VBR upper & lower rams, kill valved 1,2,4,thru 14, /BOP. kill & choke, 5.875 dart / fosv's, 4" dart / fpsv's, T/ 250 psi low, 3500 psi high F/ 5min. ea.perfor koomey test, (Lost 40 bbls to formation while testing BOP'S) AOGCC Lou Labenslein waived wetness of test. 7/2/2019 7/212019 0.50 PRODI DRILL BOPE T Test blind rams, # 3 choke valve @ 0.0 0.0 00:00 00:30 250/3500 psi F/ 5 min ea. perform drawdown test on koomey. 7/2/2019 7/2/2019 0.50 PROD1 DRILL BOPE T Install 12.375 wear bushing 0.0 0.0 00:30 01:00 7/2/2019 7/2/2019 1.00 PRODI DRILL BOPE T RID test equipment, B/D choke 0.0 0.0 01:00 02:00 masnifold, top drive, store safety valves. 7/2/2019 7/2/2019 0.25 PROD1 DRILL BHAH T PIU BHA components to dg floor. 0.0 0.0 02:00 02:15 7/2/2019 7/212019 2.75 PROD1 DRILL SHAH T P/U 6 1/8 production hole BHA. 0.0 323.0 02:15 05:00 7/2/2019 7/212019 2.50 PROD1 DRILL TRIP T RIH w/ 4" DP F/ derrick F/ 323'T/ 323.0 3,159.0 05:00 07:30 3159' 7/2/2019 7/2/2019 10.00 PRODI DRILL PULD T Single in hole W/ 4" DP F/ 3159 3,159.0 10,729.0 07:30 17:30 T/10729', filling pipe every 20 stds. S/O 102K 7/2/2019 712/2019 3.50 PROD1 DRILL TRIP T MIN 5" stand, XO'S T/ 5.875, RIH F 10,729.0 13,557.0 17:30 21:00 10828'T/ 13557" Filling pipe every 20 stds. ( observed cement scale from pipe on std # 141, rattle pipe to remove scale) 7/2/2019 713/2019 3.00 PROD1 DRILL TRIP T Continue TIH putting stands in mouse 13,557.0 15,250.0 21:00 00:00 hole and rattlig full slots. F/ 13557'T/ 15,250' 7/3/2019 7/3/2019 4.00 PRODI DRILL TRIP T RIH with 5.875 F/ 15253'T/ 17890', 15,253.0 17,890.0 00:00 04:00 ringing stds in mouse hole T/ remove cmt from pipe. P/U wt 235k, S/O 130K @ shoe. 7/3/2019 7/312019 0.75 PROW DRILL MPDA T pull tdp nipple and install RCD. 17,890.0 17,890.0 04:00 04:45 7/3/2019 7/3/2019 1.25 PROD1 DRILL CIRC T CBU @ 17890'W/ 190 gpm, 1500 psi. 17,890.0 17,890.0 04:45 06:00 7/3/2019 7/3/2019 1.00 PROD1 DRILL SLPC T PJSM, Slip and cut 60" DRLG Line. 17,890.0 17,890.0 06:00 07:00 713/2019 7/3/2019 0.50 PROD1 DRILL SVRG T Service Rig, TD, Blocks, DW. 17,890.0 17,890.0 07:00 0730 7/3/2019 7/3/2019 2.25 PROD1 DRILL RGRP T C/O 5.675 Saver Sub. 17,890.0 17,890.0 07:30 0945 7/3/2019 7/3/2019 4.75 PRODI DRILL DISP T Pump 90 bbl Hi Vis spacer & displace 17,890.0 17,890.0 09:45 14:30 11.0 kill fluid T/ 9.4 ppg Flo Pro, W/ 150/260 GPM, ICP = 1775 psi. FCP = 2385 psi 7/3/2019 7/3/2019 6.75 PRODI DRILL TRIP T Continue tripping in hole, Tight spot @ 17,890.0 19,025.0 14:30 21:15 18458, wash and ream T/19025' , GPM 250, SPP 2250, RPM 100, Trq 14k, RT wt 175k, MPD choke @ 0, holding 510 psi on connectiuons. Page 42/49 ReportPrinted: 7/18/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Stan Depm Start'rima End Time Dur (hr) Phase Op coEe Aat Ay Cafe Time P -T -X Opataaon (WB) End Dept (flKe) 7/3/2019 774/2019 2.75 PROD1 DRILL TRIP T Continue RIH on elevators F/19025 T/ 19,025.0 20,714.0 21:15 00:00 20149' fill pipe, continue TIH T/ 20714 on elevators. MPD holding 240 while stripping in and 510 psi in slips. S/O 125 / 100k 7/4/2019 7/4/2019 1.25 PRODI DRILL REAM T Wash and ream F/20714 T/ 20838', 20,714.0 20,838.0 0000 01:15 GPM 250, SPP 2270, RPM 90, TRQ 20k Trip calc. 177 bbls, Actual - 116.5 bbls 7/4/2019 7/4/2019 4.00 PROD1 DRILL DDRL P Time Drill F/ 20838'T/ 20862' gpm 20,838.0 20,862.0 01:15 05:15 250, spp 2260, rpm 90/100, Trq 11114k, 7/4/2019 7/4/2019 0.75 PRODI DRILL DDRL P Cont. DRLG F/ 20862' T/ 20902', 20,862.0 20,902.0 0515 06:00 GPM 250, SPP 2330, Trq 22.5K, WOB 8/10k, Flo 10%, (off bolt ROT 183k, Trq 14.5k SPP 2280) Max Gas 1390 units, MPD HLDG 11# EMW 7/4/2019 7/4/2019 6.00 PROD? DRILL DDRL P Cont. DRLG 6 1/8 hole F/ 20,902' T/ 20,902.0 21,292.0 06:00 12:00 21,292' GPM 250, SPP 2330, Trq 24.5k, wob 10/12K, Flo out 10%, PIU 257k, S/O 120K, ROT 257K ADT 7.05 hrs, Bit Hrs 7.05 Jar Hrs 49.80 7/4/2019 7/4/2019 4.50 PRODI DRILL DDRL P Drill 61/8 F/ 21292'T/ 21659', Gpm 21,292.0 21,659.0 12:00 16:30 250, SPP 2320, WOB 10/13K, 105 rpm, Trq 24.5K, P/U 260, S/O 125K, ROT 165K, MPD holding 11.2 EMW, 7/4/2019 7/4/2019 6.00 PROD1 DRILL RGRP T Trouble shoot top drive. M/U, BIO and 21,659.0 21,659.0 16:30 22:30 Torq system, change out 5.718 saver sug, circulate W/ 250 gpm, 2240 SPP, P/U 2 75K, s/o 125K. 7/4/2019 7/5/2019 1.50 PROD1 DRILL DDRL P Continue Drilling 6 1/8 production hole 21,659.0 21,776.0 22:30 00:00 F/ 21,659' T/21,776',6200- TVD, GPM 250, SPP 2240,Trq 25.4, off bol 13.5K, wob 6/8, ROT 175K, P/U 265K, S/O 125K, MPD holding 11.2 emw ADT 4.81 hrs, Bit 11.86 hrs, Jar hrs =54.61 7/5/2019 7/5/2019 6.00 PRODI DRILL DDRL P Drill 1/8 Prod. Hole F/ 21,776 T/ 21,776.0 22,004.0 00:00 06:00 22,004 (TVD 6202' GPM 250, SPP 2330 off bot 2280, RPM 90, Torq 21.5k off bot 14K, WOB 3K, ROT 183 K, ADT 5.89 Bit hrs 17.45 Jar hrs 60.2 7/5/2019 7/5/2019 6.00 PROD1 DRILL DDRL P Continue Drilling 6 1/8 hole F/22,004' 22,004.0 22,129.0 06:00 12:00 T/ 22,129' TVD 6208'- GPM 250, SPP 2220 off bot 2280, RPM 90, Torq 21 k off bot 14K, WOB 5/8K, P/U 267k, S/O 127k, ROT 186k off bot 127 k K, ADT 11.6 Bit hrs 23.02 Jar hrs 65.77, HLDG 11/11.2 emw W/ MPD Max gas 5130 units 7/5/2019 7/6/2019 12.00 PROD1 DRILL DDRL P Continue Drilling 61/8 hole F/22,129' 22,129.0 22,915.0 12:00 00:00 T/ 22915f TVD 6218'- GPM 250, SPP 2220 off bot 2290, RPM 95, Torq 25k off bot 15K, WOB 10/5K, PIU 270k, SIO 115k, ROT 192k off bot 127 k K, ADT 11.6 Bit hrs 23.02 Jar hrs 65.77, HLDG 11/11.2 emw W/ MPD Max gas 761 units Page 43149 Report Printed: 711812019 '- Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End Time Dw(no Phase Op Code AoeMy Code Time P -T -X Opetetlon (W[3) End Depth(WEIT 7/6/2019 7/6/2019 6.00 PRODi DRILL DDRL P Drill Production hole F 122915'T/ 22,915.0 23,357.0 0000 06:00 23,357', TVD 6202, SPM 51, GPM 250' SPP 2330, RPM 95, TRQ 27K, WOB 10/12, P/U 275k, S/o 112k, ROT 185K, MPD holding 11.2 emw on connections, ADT 4.59 hrs, Bit hrs 36.92, 7/6/2019 7/6/2019 6.00 PROD1 DRILL DDRL P Drill Production hole F / 23,357'T/ 23,357.0 23,809.0 06:00 12:00 23,809', (TVD 6192'), SPM 51, GPM 250' SPP 2350, RPM 100, TRQ 28.51K, TQ off bot 17K, WOB 8/10, P/U 280k, S/o 105k, ROT 183K, MPD holding 11.2 emw on connections, ADT 5.11 hrs, Bit hrs 42.03, Jar hrs hr 84.78 7/6/2019 7/6/2019 6.00 PROD1 DRILL DDRL P Drill Production hole F 123,809'T/ 23,809.0 24,193.0 12:00 18:00 24193', (TVD 6193'), SPM 51, GPM 250' SPP 2360, RPM 100, TRQ 26.51K, TO off bot 17K, WOB 2/4, P/U 290k, S/o 105k, ROT 200K, MPD holding 11.2 emw on connections, ADT 4.98 hrs, Bit his 47.01, Jar hrs hr 89.76 7/6/2019 7/7/2019 6.00 PRODt DRILL DDRL P Drill Production hole F /24,193'T/ 24,193.0 24,253.0 1800 00:00 24,253", (TVD 6193'), SPM 55, GPM 250' SPP 2380, RPM 90, TRQ 27.5K, TQ off bot 16.51K, WOB 5/6, P/U 290k, S/) 105k, ROT 200K, MPD holding 11.2 emw on connections, ADT 5.37 hrs, Bit hrs 52.38, Jar his 95.13 7/7/2019 7/712019 6.00 PROD1 DRILL DDRL P Drill Production hole F 124,253" T/ 24,253.0 24,522.0 00:00 06:00 24522", TVD 6204, SPM 51, GPM 260' SPP 24500, RPM 80, TRQ 26.5K, TRQ off 17K, WOB 8/10, P/U 285k, S/0100k, ROT 190K, MPD holding 11.2 emw on connections, ADT 3.43 hrs, Bit hrs 55.81 Jar hrs 98.56, 7/7/2019 7/7/2019 3.25 PROD1 DRILL DDRL P Drill Production hole F/24,522'T/ 24,522.0 24,800.0 06:00 09:15 24800", (TVD 6206'), SPM 51, GPM 260' SPP 2450, RPM 80, TRQ 27.5K, TQ off bot 17K, WOB 10/15, P/U 297k, SIO 97k, ROT 190K, MPD holding 11.2 emw on connections, ADT 3.32 hrs, Bit his 59.13, Jar hrs hr 101.88 7/7/2019 7/7/2019 6.50 PROD1 CASING CIRC P Obtain on bottom survey, CBU W/ 270 24,800.0 24,800.0 09:15 15:45 GPM, SPP 2580, RPM 100, TRQ 30K Max gas 7898 units, circulate thru gas buster. 77/2019 7/712019 0.50 PROD1 CASING OWFF P Conduct finger print on formation,@ 24,800.0 24,715.0 15:45 16:15 10.7 ppg 77/2019 77/2019 3.25 PRODi CASING CIRC P cbu @ 24,715'@ 270 GPM, 100 rpm, 24,715.0 24,715.0 16:15 19:30 29k TORO, mw 9.4, 1342 units gas. 7/7/2019 7/8/2019 4.50 PRODi CASING SMPD P BROOH F/ 24,696 T/ 23,163', GPM 24,715.0 23,163.0 19:30 00:00 250, SPP 2450, RPM 100, TRQ i 8K, P/U 272K, SIO 123K, ROT 190K MPD holding 250 D BP psi, & 500 S BP psi 7/8/2019 7/8/2019 1.75 PROD1 CASING BKRM P BROOH F/ 23,163 T/ 22,595', GPM 23,163.0 22,595.0 00:00 01:45 250, SPP 2350, RPM 80, TRQ 20K, P/U 272K, S/O 123K, ROT 190K MPD holding 250 D BP psi, & 500 S BP psi Page 44149 Report Printed: 7/18/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time I EM Time our (lin Phase Op Code A viy Cone Time P -T -X Operation (ttKB) EM Depth(ftKB) 7/8/2019 7/8/2019 2.25 PROW CASING CIRC P Circ gas out, line up on MGS, pump @ 22,595.0 22,595.0 01:45 04:00 250 GPM, 2450 SPP, 80 RPM, 20K TORO, MPD holding 200 psiBK psi, Max - 3250 units gas 7/8/2019 7/8/2019 9.25 PROD1 CASING BKRM P BROOH F/ 22,595 T/ 19,771" W/ 250 22,595.0 19,771.0 04:00 13:15 GPM, 2520 SPP, 90 RPM, 16K Torq, MPD holding 5102 psi in slips, 200 psi out of slips. (Drift side TRK F/ 20,714 T/ 20,809' D = 120K 7/8/2019 7/8/2019 0.25 PROD1 CASING SVRG P C/O swivel packing @ 19771'. 19,771.0 19,771.0 13:15 13:30 7/8/2019 7/812019 0.50 PROD1 CASING RGRP T Lost Hi -Line power, put rig on 19,771.0 19,771.0 13:30 14:00 Generator power. 7/8/2019 7/8/2019 1.50 PROD1 CASING CIRC T Circulate while trouble shooting SCR'S 19,771.0 19,771.0 14:00 15:30 - pump @ 250 GPM, 2450 SPP, 80 RPM, 13K TORO, P/U 185K, S/0 130K, ROT 180K, MPD holding 200 psiBK psi, 7/8/2019 7/8/2019 1.50 PROD1 CASING BKRM P Cont. BROOH F/ 19,771'T/ 19,300', 19,771.0 19,300.0 15:30 17:00 1 1 1 W/ 250 GPM, 2450 SPP, 80 RPM, 7/8/2019 7/8/2019 0.75 PROD1 CASING CIRC P Circulate @ 19,300', W11430 cgpm, 19,300.0 19,300.0 17:00 17:45 1430 SPP, 80 rpm, 12K trq. 7/8/2019 7/8/2019 0.50 PROD1 CASING RGRP T Change out breaker on SCR, Rig 19,300.0 19,300.0 17:45 18:15 back on HI -Line 7/8/2019 7/9/2019 5.75 PROD1 CASING BKRM P Cont. BROOH F/ 19,300'T/ 18530', 19,300.0 18,530.0 18:15 00:00 W/ 180 GPM, 1290 SPP, 85 RPM, 81K TRQ. 180K PIU, 130K SIO, 175K ROT. 7/9/2019 7/9/2019 6.00 PROD1 CASING BKRM P BROOH F/ 18,530'T/ 17,890' with 260 18,530.0 17,890.0 00:00 06:00 GPM, 1370-1450 PSI, 100 RPM, 12- 15 TQ, (Slight pack -off observed with no over pull while pulling into shoe. 7/9/2019 7/9/2019 0.75 PROD1 CASING CIRC P Circ. with 230 psi, 1410 PSI, 50 RPM, 17,890.0 17,890.0 06:00 06:45 1 O TQ, drop 3.51 OD rabbit. (SIMOPS PJSM on displacement) 7/9/2019 7/9/2019 2.00 PROD1 CASING CIRC P Lay in spacer F/ 17,890' T/ 17,230' MD 17,890.0 17,230.0 06:45 08:45 with 85 BBLs 11.0 ppg spacer with 3 bpm and 460 psi (U/D 240/135K 7/9/2019 7/9/2019 3.25 PROD1 CASING CIRC P Displace to 11.0 ppg brine with 17,230.0 17,230.0 08:45 12:00 2001175 gpm, 700 PSI, 30 RPM with 10K tq. 7/9/2019 7/9/2019 0.25 PROD1 CASING CIRC P Continue to displace T/ 11.0 ppg Brine 17,230.0 17,230.0 12:00 12:15 @ 17,230' MD, TVD 6017' MD with 200 gpm and 650 psi with 35 RPMs, 9.8 TO, SPR @ 12;15 hour MP # 2 20/200 psi, 30/430 psi 7/9/2019 7/9/2019 0.50 PROD1 CASING OWFF P Flow check well @ 17, 230' MD, 17,230.0 17,230.0 12:15 12:45 (Static). 7/9/2019 7/10/2019 11.25 PROD1 CASING PMPO P POOH, pumping out with 100 gpm, 17,230.0 11,208.0 12:45 00:00 300 psi, F 17,230.0 T/ 11,208' MD, PUW/SOW= 170/115K.( Lost 68 bbls total of mud last 24 hours) 7/10/2019 7/10/2019 0.25 PROD1 CASING PMPO P POOH, pumping out with 100 gpm, 11,208.0 10,922.0 00:00 00:15 300 psi, f/11,208' to 10,922' MD, PUW/SOW= 160/105K. 7/10/2019 7/10/2019 0.25 PROD1 CASING OWFF P F/C (static) 10,922.0 10,922.0 00:15 00:30 7/10/2019 7/10/2019 0.50 PROD1 CASING CIRC P Pump 30 bbls 12 ppg dry job 10,922.0 10,922.0 00:30 01:00 1 I I 7/10/2019 7/10/2019 0.50 PROD1 CASING MPDA P Pull RCD bearing & C/O handling 10,922.0 10,922.0 01:00 01:30 1 1 I I I equipment. 7/10/2019 7/10/2019 0.25 PROD1 CASING TRIP P Rack 1 stand 5-718" & 1 stand 5" DP 10,922.0 10,729.0 01:30 01:45 I I I f/10,922' to 10,729' 1 Page 45149 Report Printed: 7118/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log start Depth start Tme End Time Dv (hr) Phase Op Code Activity Code Tme P -T -X Operetion (aKB) End Depth (Wlt) 7/10/2019 7/10/2019 0.75 PROD? CASING MPDA P Install 4" RCD bearing & C/O handling 10,729.0 10,729.0 01:45 02:30 equipment. 7/10/2019 7/10/2019 1.75 PROD? CASING SMPD P Strip OOH f/10,729' to 8,366'. (Rack 10,729.0 8,366.0 02:30 04:15 back 26 stands of 4" DP in derrick) 7/10/2019 7/10/2019 7.25 PROW CASING PULD P Strip OOH laying down 4" DP f/8,366' 8,366.0 1,741.0 04:15 11:30 to 1,741' 7/10/2019 7/10/2019 0.50 PRODt CASING MPDA P Pull RCD bearing & install trip nipple 1,741.0 1,741.0 11:30 12:00 7/10/2019 7/10/2019 2.00 PROD1 CASING PULD P POOH & UD 4" DP, HWDP &jars 1,741.0 175.0 12:00 14:00 f/1,7411 to 175' 7/10/2019 7/10/2019 2.50 PROD1 CASING BHAH P PJSM. UD BHA as per SLB 175.0 0.0 14:00 16:30 j 7/10/2019 7/10/2019 2.00 COMPZN CASING CLEN P Clean and clear rig floor, Rig up to run 0.0 0.0 16:30 18:30 4.5" liner. 7/10/2019 7/10/2019 0.50 COMPZN CASING SFTY P PJSM on running casing and verify 0.0 0.0 18:30 19:00 running order in shed. 7/10/2019 7/10/2019 1.75 COMPZN CASING PUTB P Run 4.5" liner as per details T/ 985' 0.0 985.0 19:00 20:45 7/10/2019 7/10/2019 0.75 COMPZN CASING OTHR T Shut down and inspect Top Drive and 985.0 985.0 20:45 21:30 rails in Derrick due to dropped nut. 7/10/2019 7/10/2019 0.50 COMPZN CASING SVRG P Perform Derrick inspection, Service rig 985.0 985.0 21:30 22:00 7/10/2019 7/11/2019 2.00 COMPZN CASING PUTB P Cont. to run 4.5" liner as per detail F/ 985.0 2,689.0 22:00 00:00 985'T/2689'MD, PUW/SOW= 85K/90K. (Total loss for last 24 hours= 66 BBLS) 7/11/2019 7/11/2019 00:00 00:00 7/11/2019 7/11/2019 00:00 00:00 7/11/2019 7/11/2019 4.75 COMPZN CASING PUTS P Run 4.5" 12.6 # 563 hydril as per 2,689.0 6,957.0 00:00 04:45 detail PU/SOW= 105/93K, F/ 2,689'T/ 6,957' MD. 7/11/2019 7/11/2019 1.25 COMPZN CASING PUTS P M/U seal Bore assembly, 6,957.0 7,042.0 04:45 06:00 hanger,Packer as per Baker Rep. F/ 6,957'T/ 7„042' MD 7/11/2019 7/11/2019 0.50 COMPZN CASING RUNL P Change out handling equipment, RIH 7,042.0 7,134.0 06:00 06:30 1 1 1with 4" dp F/ 7,042' T/ 7,134' 7/11/2019 7/11/2019 0.50 COMPZN CASING CIRC P Obtain Parameters with 3 bpm, 100 7,134.0 7,134.0 06:30 07:00 psi, 10/20 RPM, 2.2/2.5 Tq, U/D/R= 110/95/105K 7/11/2019 7/11/2019 2.00 COMPZN CASING TRIP P RIH with 4" dp F/ 7,134'T/ 9,497' MD, 7,134.0 9,497.0 07:00 09:00 D= t00K. 7/11/2019 7/11/2019 0.75 COMPZN CASING PULD P M/U swivel Master as per Rubicon 9,497.0 9,713.0 09:00 09:45 Rep. F/ 9.497' T/ 9713' on btm of 5" dp stand, XO, F/ 4" to 5.875" Change out handling equipment. 7/11/2019 7/11/2019 1.25 COMPZN CASING CIRC P Circ. @ 3bpm with 140 psi, UID:-: 9,713.0 9,713.0 09:45 11:00 1 1 1130/120K. 7/11/2019 7/11/2019 1.00 COMPZN CASING TRIP P RIH F/ 9,713' T/ 10,655' MD with 9,713.0 10,655.0 11:00 12:00 5.875" dp, D= 108K. 7/11/2019 7/11/2019 0.50 COMPZN CASING TRIP P RIH with 4.5" Liner on dp F/ 10,655' 10,655.0 11,032.0 12:00 12:30 T/ 11,032' MD, Stopped trip due to cement in drill pipe coming out. 7/11/2019 7/11/2019 2.25 COMPZN CASING TRIP T Decision made to POOH to liner 11,032.0 9,619.0 12:30 14:45 running tool to inspect, F/ 11,032" T/ 9,619' MD 7/11/2019 7/11/2019 2.75 COMPZN CASING TRIP T Change out handling equipment to 5" 9,619.0 7,019.0 14:45 17:30 and 4" and laid down rubicon swivel, Cont. to POOH with 4" dp F/ 9,497'T/ 7,019' MD Page 46149 ReportPrinted: 75812019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log shin Depth Start Time End Time Dm(M) Phase Op Code Activity Code Time P -T -X Operetlon (WEI) End Depth(IIKB) 7/11/2019 7/11/2019 3.00 COMPZN CASING PULD T Inspect liner running tool- Good, F/ 7,019.0 6,959.0 1730 20:30 7,019' T/ 6,959' MD, PUW/SOW= 110/95 K, WU one more joint 4.5" liner, SBE and liner hanger F/ 6,959' T/ 7,085' Rig down power tongs and lay down. (Ordered out Baker circ. sub. pinned for 3400/3500 psi and made sure 1-518" and 1-3/4" balls passed through) 7/11/2019 7/11/2019 2.25 COMPZN CASING TRIP T M/U circ sub and RIH with 4"dp 26 7,019.0 9,538.0 2030 2245 stands from Derrick F/ 7,019' T/ 9,538' MD 7/11/2019 7/11/2019 0.25 COMPZN CASING TRIP T M/U Rubicon swivel on end of 5" stand 9,538.0 9,661.0 2245 2300 dp, install TIW and monitor well on trip tank. 7/11/2019 7/12/2019 1.00 COMPZN CASING PULD T C/O elevators and lay down 5.875" dp 9,661.0 9,661.0 23:00 00:00 from derrick (three stands) (Some connection were light) (Total mud lost last 24 hours= 81 bbls) 7/12/2019 7/12/2019 4.50 COMPZN CASING PULD T UD 57 its of 5-7/8" DP via mouse 9,661.0 9,661.0 00:00 04:30 hole. 7/12/2019 7/12/2019 3.25 COMPZN CASING RUNL T RIH w/liner while picking up 66 jts of 5 9,661.0 11,731.0 04:30 07:45 1 -718" DIDf/9,661'to 11,731' 7/12/2019 7/12/2019 4.25 COMPZN CASING RUNL P RIH w/liner with stands out of derrick 11,731.0 15,310.0 07:45 12:00 F/ 11,731' T/ 15,310' MD; (Checking DP for cement) U/D= 215/130K. 7/12/2019 7/12/2019 4.50 COMPZN CASING RUNL P RIH whiner with stands out of derrick 15,310.0 17,850.0 12:00 16:30 F/ 15,310' T/ 17,850.0' MD, Took weight at 18, 245' MD and 7/12/2019 7/12/2019 0.25 COMPZN CASING CIRC P At 17,850' MD Brk Circ. with 150 gpm, 17,850.0 17,850.0 16:30 16:45 210 pdi, Obtain parameters as per Baker rep. with no pumps, U/D wt.= 250K/135K, rot= 200K, 10120/40 RPM @ 8K torque, U/D wt= 225K/160K, with 10 rpm. 7/12/2019 7/13/2019 7.25 COMPZN CASING RUNL P F/17850' T/ 22,280' cont. RIH with 4.5" 17,850.0 22,280.0 16:45 00:00 liner on 5.875" dp, SOW= 105K, Took wt @ 18,250' MD, due to dogleg and took wt agian at 18,490' MD, Worked through OK and continue on. .(Loss 44 bbls of mud last 24 hours) 7/13/2019 7/13/2019 4.75 COMPZN CASING RUNL P RIH liner f/22,280' to set depth of 22,280.0 24,761.0 00:00 04:45 24,761'. PU wt 335 k / SO wt 100 k 7/13/2019 7/13/2019 0.50 COMPZN CASING CIRC P Break circ w/3 bpm @ 216 psi. Obtain 24,761.0 17,702.0 04:45 05:15 parameters as per Baker rep. with no pumps, U/D wt.= 335 k/100 k, ROT = 240 k, 10 rpm = 16 k trq, 20 rpm = 17 k trq, 40 rpm = 20 k trq. U/D wt= 270 k/195 k with 10 rpm. 7/13/2019 7/13/2019 2.25 COMPZN RPCOMP PACK P Drop 1-5/8" ball @ 5:22 hrs. Ball on 24,761.0 17,702.0 05:15 07:30 seal @ 2700 stks. Pressure up to 2500 psi & set hanger. Slack off & confirm liner set. Cont. to pressure up to 4000 psi. PIU & expose dog sub. Rotate 10 rpm w/18 k trq & set packer. P/U & confirm liner released. PU wt 3051 SO wt 140 k TOL @ 17,702' 7/13/2019 7/13/2019 1.25 COMPZN RPCOMP PRTS P R/U to test. Shut in upper rams & test 17,702.0 17,702.0 07:30 08:45 liner top packer to 3300 psi & chart for 10 min. (good). R/D testing equipment. 7/13/2019 7/13/2019 0.50 COMPZN WELLPR TRIP P Pump liner running tools out of liner 17,702.0 17,702.0 08:45 09:15 w/1 bpm Page 47149 Report Printed: 7/18/2019 Operations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Start Time End! Time our (hr) Phase Op Code Adkity Code Torre P -T -X Operation (ftKB) End Depth (WS) 7/13/2019 7/13/2019 3.25 COMPZN WELLPR CIRC P Pump high vis sweep & circ casing 17,702.0 17,702.0 09:15 12:30 clean w/3.5 - 8 bpm 1210 - 720 psi. SIMOPS - slip & cut 90' drill line. 7/13/2019 7/13/2019 4.50 COMPZN WELLPR CRIH P Pump 1010 bbis Cl brine & displace 17,702.0 17,702.0 12:30 17:00 with 50 bbls non inhibited brine w/5 bpm / 500 psi. 7/1312019 7/13/2019 0.50 COMPZN WELLPR OWFF P F/C (static) 17,702.0 17,702.0 17:00 17:30 7113/2019 7/14/2019 6.50 COMPZN WELLPR PULD P POOH & L/D DP f/17,702'to 16,080.' 17,702.0 16,080.0 17:30 00:00 MD, Plu= 305K, to 338K (Total loss for last 24 hourd= 45 bbs) 7114/2019 7114/2019 12.00 COMPZN WELLPR PULD P POOH & L/D DP fit 6,080'to 10,800'. 16,080.0 10,800.0 00:00 12:00 PU wt 230 K 7/14/2019 7/15/2019 12.00 COMPZN WELLPR PULD P POOH & L/D DP f/10,800'to 2900' 10,800.0 2,900.0 12:00 00:00 MD, P/U wt= 230-97K @ 3700' MD drill pipe started pulling wet, try to pump 20 bbl dry job, but psi increased with no clear path thru drill pipe. Pull out wet. (Loss 21 bbis last 24 hrs.) 7/15/2019 7/15/2019 5.00 COMPZN WELLPR PULD P POOH & L/D DP f/2900'& UD liner 2,900.0 0.0 00:00 05:00 running tools. (Running tools packed off with cement) 7/15/2019 7/15/2019 0.50 COMPZN WELLPR CLEN P Clean& clear floor. SIMOPS -F/C 0.0 0.0 05:00 05:30 (static) 7/15/2019 7/15/2019 0.25 COMPZN WELLPR RURD P Pull wear ring 0.0 0.0 05:30 05:45 7/15/2019 7/15/2019 1.75 COMPZN WELLPR W W WH P R/U & Johnny Wach stack. SIMOPS - 0.0 0.0 05:45 07:30 R/U to test BOPE 7/15/2019 7/15/2019 5.50 COMPZN WHDBOP BOPE P Test BOPE w/3-1/2" & 4-1/2" test 0.0 0.0 07:30 13:00 joints to 250 low & 3500 psi high for 5 min. 4" Demco, Choke valves 1 - 14; IBOP's, Choke needle valve, Upper & Lower 3-1/2" X 6" VBR's & blind rams, 4" Dart/FOSV, HCR / Man choke/kill, Accumulator test, Initial 3100 psi, final 1500 psi, list 200 psi recharge = 23 sec's, full recharge = 148 seconds. Nitrogen Bottles x4 = 2000 psi. Gas alarms and PVT alarms tested. Tested draw down on hydraulic chokes 1100psi. AOGCC Jeff Jones waived witness. 7/15/2019 7/15/2019 1.00 COMPZN WHDBOP WWWH P Johnny Wack stack. SIMOPS -R/D 0.0 0.0 13:00 14:00 testing equipment. Bring tubing tools & equipment to rig floor. 7/15/2019 7/15/2019 1.50 COMPZN RPCOMP RURD P R/U to min tubing. (3-1/2" handling 0.0 0.0 14:00 15:30 equipment, power tongs) 7/15/2019 7/16/2019 8.50 COMPZN RPCOMP RCST P PJSM. RIH 3-1/2" Hyd 563 upper 0.0 6,200.0 15:30 00:00 completion to 6,200' MD, UID Wt= 92K/85K. ( PT Dual Flapper to 500 psi, Good) (Total loss last 24 hours= 42 bbis) 7116/2019 7116/2019 11.50 COMPZN RPCOMP RCST P RIH 3-1/2" Hyd 563 upper completion 6,200.0 17,771.0 00:00 11:30 f/6,200'to 17,771.45'& fully locate. PU wt 145 k/SO wt 70k 7116/2019 7/16/2019 0.50 COMPZN RPCOMP PRTS P Pressure up on IA to 500 psi to 17,771.0 17,771.0 11:30 12:00 confirm seals are engaged. (good) 7/16/2019 7/16/2019 1.25 COMPZN RPCOMP HOSO P UD 4 jts 3-1/2" tubing. M/U Space out 17,771.0 17,769.0 12:00 13:15 joint, XO, 1 jt 4-1/2" Hyd 563 tubing & land on hanger @ 17,766.96'. (2.5' from fully located) 7/16/2019 7/16/2019 0.75 COMPZN RPCOMP THGR P RILDS. Test pack off & test hanger 17,769.0 17,769.0 13:15 14:00 seals to 5000 psi for 15 min. (good). SIMOPS - R/U testing equipment. Page 48149 Report Printed: 7/18/2019 Uperations Summary (with Timelog Depths) 2M-39 Rig: DOYON 19 Job: DRILLING ORIGINAL Time Log Start Depth Stan Time EM Tima our (hr) Phase Op Code Acdivdy Cade Time P -T -X Operation (fIKB) End Depth^13) 7/16/2019 7/16/2019 1.75 COMPZN RPCOMP PRTS P Pressure test tubing to 3500 psi & 17,769.0 17,769.0 14:00 15:45 chart for 30 min (good). Bleed tubing to 2000 psi. Pressure test IA to 3300 psi & chart for 30 min (good). Bleed off IA&then bleed off tubing. Pressure up to 2500 psi & shear SOV. Circ down tubing taking returns thru IA & confirm SOV sheared. 7/16/2019 7/16/2019 0.25 COMPZN RPCOMP OWFF P F/C (static). SIMOPS - R/D circulating 0.0 0.0 15:45 16:00 1 1 lines. UD landing joint. 7/16/2019 7/16/2019 0.75 COMPZN RPCOMP MPSP P Cameron set TWC & test in direction 0.0 0.0 16:00 16:45 of flow thru IA to 2500 psi 15 min on chart.(good) 7/16/2019 7/16/2019 1.50 COMPZN WHDBOP RURD P Back out landing it & UD same. R/D 0.0 0.0 16:45 18:15 tubing running tools & equipment. Clean & clear floor. SIMOPS - N/D MPD equipment & clean pits. 7/16/2019 7/16/2019 2.00 COMPZN WHDBOP MPDA P N/D MPD equip. UD KatchKan, Orbit 0.0 0.0 18:15 20:15 valve 7/16/2019 7/16/2019 2.75 COMPZN WHDBOP NUND P N/D flow line, hole fill & bleeder lines. 0.0 0.0 20:15 23:00 1 1 1 N/D BOPE & rack back on pedestal. 7/16/2019 7/17/2019 1.00 COMPZN WHDBOP NUND P N/U Production tree per Cameron 0.0 0.0 23:00 00:00 Rep. 7/1712019 7/17/2019 3.00 COMPZN WHDBOP NUND P N/U Production tree per Cameron 0.0 0.0 00:00 03:00 Rep. Pad Op verify tree orientation. SIMOPS - Install annulus gauges, disconnect mud lines, clean & clear floor, prep for rig move. 7/17/2019 7/1712019 2.00 COMPZN WHDBOP PRTS P Test tree to 5,000 psi W chart for 15 0.0 0.0 03:00 05:00 min. SIMOPS - Cont. to clean pits & prep for rig move. 7/17/2019 7/17/2019 1.50 COMPZN WHDBOP MPSP P Pull TWC & set "11" Type BPV. Test in 0.0 0.0 05:00 06:30 direction of flow down IA to 2500 psi (good) 7/17/2019 7/17/2019 5.50 DEMOB MOVE RURD P Prep for rig move. Clean rig floor & 0.0 0.0 06:30 12:00 clean pits. Move pipe shed. Rig on highline @ 8:00 Hrs Rig Released 12:00 Hrs Page 49/49 Report Printed: 7/18/2019 NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-39 2M-39 ConocoPhillips Definitive Survey Report 16 July, 2019 Final Definitive Survey Verified and Signed -off All targets and/or welt position objectives have been achieved. L] Yes ❑ No I have checked to the hest of my ability that the following data is correct: CJ Surface Coordinates n Declination & Convergence GRS Survey Corrections Survey Tod Codes Brandon Temrt-��le Digitally signed by Brandon Temple SIB DE: M Date: 2019.07.161353:57-08'00' Kith Herring Digitally mgrva by Reith Herring eerr Client Representatives 9 nate: 2019.071616,0249 _GSW Date: 07/16/2019 ConocoPhillips ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2M-39 Project: Kupamk River Unit TVD Reference: 210-39 actual @ 137.45usft (D19) Site: Kupamk 2M Pad MD Reference: 2M-39 actual @ 137.45usft (D19) Well: 2M-39 North Reference: True Wellbore: 2M-39 Survey Calculation Method: Minimum Curvature Design: 2M-39 Database: OAKEDMP7 Pmject Kuparuk River Unit, North Slope Alaska, United States 36.75 Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) lust[) Using Well Reference Point Map Zone: Alaska Zone 04 (usf) Using geodetic scale factor (usll) (R) (ft) (°/100') Well 2M-39 OWSG MWD +IFR2+Sag +Muli-Station Comact4/28/2019 (wit) Well Position +N/ -S 0.00 usft Northing: GYD-GC-SS +E/ -W 0.00 usft Easting: Position Uncertainty Tie On Depth: 0.00 usft Wellhead Elevation: Wellbore 2M-39 magnetics Model Name Sample Date BGGM2018 6/1/2019 5,948,985.25 usft Latitude: 487,969.82 usft Longitude: 0.00 usft Ground Level: 70° 16' 18.574 N 150° 5'50.270 W 100.70 usft Declination Dip Angle Field Strength 1°I (1) (nT) 16.44 80.79 57,403 Design 2M-39 To OWSG MWD +IFR2+Sag +Muli-Station Comact4/28/2019 (wit) (wf) Survey (Wellbore) Audit Notes: 71.94 1,440.40 2M-39 SrW 1 - SLB GWD70 (2M-39PB1) GYD-GC-SS 1,480.76 Version: 1.0 Phase: ACTUAL Tie On Depth: 2,809.37 Vertical Section: Depth From (TVD) +WS +E/4N Direction MWD+IFR2+SAG+MS (usft) (usft) (usft) (°) 24,735.742M-39 SrVy 7- SLB_MWD+GMAG(2N1.3 36.75 0.00 0.00 235.20 Date From To OWSG MWD +IFR2+Sag +Muli-Station Comact4/28/2019 (wit) (wf) Survey (Wellbore) Tool Name 71.94 1,440.40 2M-39 SrW 1 - SLB GWD70 (2M-39PB1) GYD-GC-SS 1,480.76 2,701.242M-39 Srvy 2- SLB _MWD+GMAG(2M-3 MWD+IFR2+SAG+MS 2,741.40 2,809.372M-39 Srvy 3- SLB _MWD+SAG(2M-39 MWD OWSGM 2,903.18 15,957.082M-39 Srvy 4-SLB_WD+GMAG(2M-3 MWD+IFR2+SAG+MS 16,056.30 17,828.46 2M-39 Srvy 5- SLB _MWD+GMAG (2M-3 MWD+IFR2+SAG+MS 17,857.52 17,857.522M-39 Srvy 6-SLB_MWIMNC-ONLY-Fi MWD-INC_ONLY 17,951.66 24,735.742M-39 SrVy 7- SLB_MWD+GMAG(2N1.3 MWD+IFR2+SAG+MS Description Survey Date Gyrodata gyro single shots 4/27/2019 8:11:1 OWSG MWD +IFR2+Sag +Muli-Station Comact4/28/2019 8:17:1 OWSG MWD - Standard 4/28/2019 8:11:1 OWSG MWD +IFR2+Sag +Multi -Station Co"CIS/27/2019 9:12: OWSG MWD + IFR2 + Sag + Multi -Station Conec16/17/2019 9:12: MWD-INC_ONLY_FILLER 6/24/2019 1:21, OWSG MWD + IFR2 + Sag + Multi -Station Conec16/24/2019 1:32: - Survey Lisp Lisp Vertical MD In AN TVD TVDSS +N/S +E/4N Northing Eating DLS Section lust[) p) (1) (usft) (usf) (waft) (usll) (R) (ft) (°/100') (ft) Survey Tod Name 36.75 0.00 0.00 36.75 -100.70 0.00 ODD 5,948,985.25 487,969.82 0.00 0.00 UNDEFINED 71.94 0.00 0.00 71.94 -65.51 0.00 0.00 5,948,985.25 487,969.82 0.00 0.00 GYD-GCSS(1) 171.07 0.21 333.54 171.07 33.62 0.16 -0.013 5,948,985.41 487,969.74 0.21 -0.03 GYD-GCSS(1) 226.10 1.83 313.51 226.09 88.64 0.86 -0.76 5,948,986.11 487,969.06 2.97 0.14 GYD-GCSS(1) 319.16 3.19 312.36 319.06 181.61 3.63 41.75 5,948,988.88 487,966.07 1.46 1.01 GYD-GCSS(1) 411.70 4.13 313.95 411.41 273.96 7.67 -8.06 5,948,992.94 4137,961.78 1.02 2.24 GYD-GC-SS(1) 501.72 4.73 315.09 501.16 363.71 12.55 -13.01 5,948,997.132 487,956.83 0.67 3.52 GYD-GGSS(1) 594.05 4.95 315.18 593.16 455.71 18.07 -18.51 5,949,003.35 487,951.35 0.24 4.88 GYD-GC-SS(1) 687.40 5.31 310.96 686.14 548.69 23.76 -24.61 5,949,009.05 487,945.25 0.56 6.64 GYD-GC-SS(1) 71162019 1:47:02PM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2M-39 Project: Kupamk River Unit WD Reference: 2M-39 actual ® 137.45usft (D19) Site: Kupamk 2M Pad No Reference: 210-39 actual ® 137.45usft lot 9) Well: 2M-39 North Reference: Tme Wellbore: 2M-39 Survey Calculation Method: Minimum Curvature Design: 2M-39 Database: OAKEDMP7 Survey Map Map Vertical MD Inc Azi TVD TVDSS +W3 +E1 -W Northing Seating DLS Section (usft) (°) (°) (usft) Wit) (usft) (usln (ft) (ft) (°/100') (ft) Survey Tool Name 782.58 667 308.85 780.79 643.34 30.12 -32.24 5,949,015.41 487,937.63 145 9.28 GYD-GC-SS(1) 876.81 8.98 305.86 874.14 736.69 37.86 42.6 5,949,023.17 487,927.42 2.49 13.26 GYD-GCSS(1) 969.49 8.62 302.17 %5.73 828.28 45.79 54.20 5,949,031.13 487,915.70 0.72 18.37 GYD-GCSS(1) 1,063.92 9.45 300.67 1,058.99 921.54 53.52 4i6.66 5,949,038.87 487,903.05 0.91 24.35 GYD-GCSS(1) 1,158.79 10.02 296.10 1,152.49 1,015.04 61.12 50.97 5,949,046.49 487,888.95 1.01 31.60 GYD-GCSS(1) 1,252.39 11.51 293.73 1,244.44 1,106.99 68.46 -%.83 5,949,053.86 487,873.11 1.66 40.43 GYD-GCSS(1) 1,346.63 11.95 293.38 1,33672 1,199.27 76.12 -114.40 5,949,061.54 487,855.56 0.47 50.49 GYD-GCSS(1) 1,440.40 16.52 292.68 1,427.58 1,290.13 85.11 -135.62 5,949,070.57 487,834.35 4.88 62.78 GYD-GCSS(1) 1,480.76 16.81 291.47 1,466.25 1,328.80 89.46 -146.35 5,949,074.94 487,823.63 1.12 69.10 MWD+IFR2+SAG+MS(2) 1,574.22 17.04 291.18 1,555.66 1,418.21 99.36 -171.69 5,949,089.87 487,798.31 0,26 89.26 MWD+IFR2+SAG+MS(2) 107.73 18.34 291.24 1,644.]5 1,507.30 109.64 -198.18 5,949,095.19 487,771.84 1.39 100.15 MWD+IFR2+SAG+MS(2) 1,762.47 22.33 289.48 1,733.56 1,5%.11 121.04 -229.05 5,949,106.65 487,740.98 4.26 118.99 MWD+IFR2+SAG+MS(2) 1,855.43 22.45 290.11 1,819.52 1,682.07 133.03 -262.37 5,949,118.69 487,707.69 0.29 139.50 MWD+IFR2+SAG+MS(2) 1,950.29 24.48 289.06 1,9%.53 1,769.08 145.68 -297.96 5,949,131.39 487,672.13 2.18 161.50 MWD+IFR2+SAG+MS(2) 2,045.46 26.31 286.48 1,992.50 1,855.05 158.41 -336.82 5,949,143.88 487,633.28 2.25 186.32 MWD+IFR2+SAG+MS(2) 2,138.26 27.67 284.53 2,075.19 1,937.74 169.35 -377.41 5,949,155.18 487,592.72 1.75 213.23 MWD+IFR2+SAG+MS(2) 2,233.00 31.64 281.72 2,157.51 2,020.06 179.92 423.05 5,949,165.83 487,547.10 4.44 244.67 MWD+IFR2+SAG+MS (2) 2,327.60 33.16 281.69 2,237.38 2,099.93 190.20 472.68 5,949,176.19 487,497.49 1.61 279.56 MWD+IFR2+SAG+M$(2) 2,421.35 35.33 281.43 2,314.88 2,177.43 200.77 524.37 5,949,186.84 487,445.82 2.32 315.97 MWD+IFR2+SAG+MS(2) 2,515.39 38.80 278.70 2,389.91 2,252.46 210.62 -580.16 5,949,196.77 487,390.05 4.08 356,16 MWD+IFR2+SAG+MS(2) 2.609.30 42.13 277.73 2,461.35 2,323.90 219.31 640.48 5,949,205.55 487,329.76 3.61 400.72 MWD+IFR2+SAG+MS(2) 2,701.24 42.38 276.91 2,529.40 2,391.95 227.18 -701.80 5,949,213.53 487,268.46 0.66 446.57 MWD+IFR2+SAG+MS(2) 2,741.40 42.14 276.88 2,559.12 2,421.67 230.43 -728.61 5,949,216.82 487,241.65 0.60 465.74 MWD OWSG (3) 2,809.37 42.41 274.99 2,609.41 2,471.96 235.15 -774.08 5,949,221.61 487,196.19 1.91 501.38 MWD OWSG(3) 2,903.18 42.20 278.82 2,678.80 2,541.35 242.73 536.74 5,949,229.30 487,133.55 2.76 598.50 MWD+IFR2+SAG+MS(4) 2,932.88 41.44 279.31 2,700.94 2;563.49 245.85 556.30 5,949,232.45 487,114.00 2.79 562.78 MWD+IFR2+SAG+MS(4) 3,027.00 41.54 280.50 2,771.44 2,633.99 256.58 4)1772 5,949,243.27 487,052.60 0.84 607.09 MWD+IFR2+SAG+MS(4) 3,120.96 45.47 279.67 2,839.58 2,702.13 267.89 4181.39 5,949,254.68 486,988.96 4.23 652.92 MWD+IFR2+SAG+MS(4) 3,214.55 49.09 274.37 2,%3.09 2,765.64 276.19 -1,049.59 5,949,263.09 466,920.78 5.68 704.17 MWD+11FR2+SAG+MS (4) 3,309.61 51.93 273.05 2,%3.53 2,826.08 280.92 -1,122.79 5,949,267.94 486,847.60 3.17 761.58 MWD+IFR2+SAG+MS(4) 3,403.83 54.74 270.86 3,019.80 2,882.35 283.47 -1,198.31 5,949,270.61 486,772.09 3.52 822.13 MWD+11`112+SAG+MS(4) 3,498.01 58.01 267.27 3,071.95 2,934.50 282.15 -1,276.69 5,949,269.41 486,693.72 4.70 887.25 MWD+IFR2+SAG+MS (4) 3,592.01 61.81 268.20 3,119.07 2,981.62 278.95 -1,357.94 5,949,266.34 486612.46 4.13 955.79 MWD+IFR2+SAG+MS(4) 3,687.08 66.23 267.% 3,160.71 3,023.26 276.08 -144333 5,949,263.61 486,527.08 4.65 1,027.54 MWD+IFR2+SAG+MS(4) 3,780.70 70.46 268.09 3,195.25 3,057.80 273.08 -1,530.27 5,949,260.75 486,440.14 4.52 1,100.64 MWD+IFR2+SAG+MS(4) 3,874.26 73.99 267.43 3,223.81 3,086.36 269.60 -1,619.28 5,949,257.41 486,351.13 3.83 1,175.72 MND+IFR2+SAG+MS(4) 3,968.83 78.71 266.18 3,246.12 3,108.67 264.47 -1,711.01 5,949,252.42 486,259.40 5.15 1253.136 MWD+IFR2+SAG+MS(4) 4,063.69 80.14 264.79 3,263.53 3,126.08 257.12 -1,803.97 5,949,245.23 486,166.45 2.09 1,334.48 MWD+IFR2+SAG+MS(4) 4,15244 79.50 262.54 3,280.10 3,142.65 246.94 -1,895.67 5,949,235.20 486,074.74 2.46 1,415.59 MWD+IFR2+SAG+M$(4) 4,251.44 79.83 258.82 3,296.97 3,159.52 231.97 -1,986.91 5,949,220.37 485,983.49 3.91 1499.05 MWD+IFR2+SAG+MS(4) 71162019 1:47:02PM Page 3 COMPASS 5000.14 Build 85D Survey ConocoPhillips Definitive Survey Report Map Company. NADConversion Local Co-ordinate Reference: Well 210-39 PwjecC Kupaluk River Unit TVD Reference: 2M-39 actual @ 137.45usft (D19) Site: Kuparuk 2M Pad MD Reference: 210-39 actual @ 137.45usft (D19) Wall: 210-39 North Reference: True Wellbore: 210-39 Survey Calculation Method: Minimum Curvature Design: 2M-39 Database: OAKEDMPI Survey 7116/2019 1:47:02PM Page 4 COMPASS 5000.14 Build 850 Map Map Vertical MD Inc A[I TVD TVDSS +N143 +E/ -W Northing Easting DLS Section (usft) (1) (1 (wall) (usft) (usft) (usft) (ft) (ft) (-/100') (ft) Survey Tool Name 4,345.01 78.42 257.75 3,314.62 3,177.17 213.31 -2,076.88 5,949,201 86 485,893.49 1 88 1,583.57 MWD+IFR2+SAG+MS (4) 4,439.27 78.31 258.75 3,333.63 3,196.18 194.51 -2,167.27 5,949,183.21 485,803.08 1.05 1,668.52 MWD+IFR2+SAG+MS(4) 4,534.34 78.24 259.28 3,352.95 3,215.50 176.78 -2,258.65 5,949,165.62 485,711.68 0.55 1,753.68 MWD+IFR2+SAG+MS(4) 4,627.41 78.30 260.40 3,371.87 3,234.42 160.70 -2,348.34 5,949,149.69 485,621.97 1.18 1,836.50 MWD+IFR2+SAG+MS(4) 4,721.51 78.54 261.90 3,390.76 3,253.31 146.52 -2,439.43 5,949,135.65 485,530.87 1.58 1,919.39 MWD+IFR2+SAG+MS(4) 4,814.45 78.42 262.48 3,409.33 3,271.88 134.14 -2,529.65 5,949,123.42 485,440.64 0.62 2,000.53 MWD+IFR2+SAG+MS(4) 4,908.09 78.30 263.76 3,428.22 3,290.77 123.16 -2,620.70 5,949,112.58 485,349.58 1.34 2,081.57 MM+IFR2+SAG+MS(4) 5,002.46 78.24 264.05 3,447.40 3,309.95 113.35 -2,712.58 5,949,102.92 485,257.70 0.31 2,162.61 MWD+IFR2+SAG+MS 14) 5,096.47 78.46 264.03 3,466.39 3,328.94 103.79 -2,804.15 5,949,093.51 485,166.12 0.23 2,243.26 MWD+IFR2+SAG+MS(4) 5,190.78 78.48 264.15 3,485.24 3,347.79 94.27 -2,896.07 5,949,084.14 485,074.19 0.13 2,324.16 MWD+IFR2+SAG+MS(4) 5,285.37 78.64 262.74 3,504.00 3,366.55 83.69 -2,968.17 5,949,073.71 484,982.08 1.47 2,405.83 MWD+IFR2+SAG+MS(4) 5,380.28 78.47 261.10 3,522.84 3,385.39 70.61 3,080.27 5,949,060.78 484,889.98 1.70 2,488.91 MWD+IFR2+SAG+MS(4) 5,474.97 78.58 259.67 3,541.67 3,404.22 55.12 3,171.76 5,949,045.43 484,798.47 1.48 2,572.88 MM+IFR2+SAG+MS(4) 5,567.79 78.47 260.58 3,560.14 3,422.69 39.51 3,261.37 5,949,029.97 484,708.84 0.97 2,655.37 MWD+IFR2+SAG+MS(4) 5,661.68 77.88 262.35 3,579.38 3,441.93 25.88 3,352.25 5,949,016.48 484,617.95 1.95 2,737.77 MWD+IFR2+SAG+MS(4) 5,757.49 77.71 262.63 3599.64 3,462.19 13.64 -3,445.09 5,949,004.39 484,525.10 0.34 2,820.99 MWD+IFR2+SAG+MS(4) 5,852.46 77.96 262.39 3,619.65 3,482.20 1.49 3,537.13 5,948,992.40 484,433.05 0.40 2,903.49 MWD+IFR2+SAG+MS(4) 5,946.29 78.02 262.90 3,639.17 3,501.72 -10.29 -3,628.15 5,948,980.76 484,342.02 0.59 2,984.95 MWD+IFR2+SAG+MS(4) 6,040.48 77.92 262.85 3.658.81 3,521.36 -21.72 3,719.56 5,948,969.48 484,250.61 0.12 3,066.53 MWO+IFR2+SAG+MS(4) 6,134.62 78.04 262.76 3,678.41 3,540.96 33.25 3,810.91 5,948,958.09 484,159.25 0.16 3,148.12 MWD+IFR2+SAG+MS(4) 6,228.22 78.38 261.42 3,697.54 3,560.09 45.86 3.901.66 5,948,945.63 484,068.48 1.45 3,229.84 MWD+IFR2+SAG+MS(4) 6,323.16 78.21 261.29 3,716.80 3,579.35 59.84 3,993.57 5,948,931.80 483,976.56 0.22 3,313.28 MWD+IFR2+SAG+MS(4) 6,416.84 78.24 261.20 3,735.91 3,598.46 -73.60 4,084.21 5,948,917.99 483,885.91 0.10 3,395.67 MWD+IFR2+SAG+MS(4) 6,510.94 77.55 261.58 3,755.65 3,618.20 -87.57 4,175.18 5.948,904.36 483,794.93 0.83 3,478.23 MWD+IFR2+SAG+MS(4) 6,606.27 77.70 261.80 3,776.08 3,638.63 -101.03 4,267.31 5,948,891.05 483,702.78 0.27 3,561.57 MWD+IFR2+SAG+MS(4) 6,700.48 77.57 261.21 3,796.25 3,658.80 -114.62 4,358.33 5,948,877.61 483,611.75 0.63 3,644.06 MWD+IFR2+SAG+MS(4) 6,794.96 77.60 261.45 3,816.56 3,679.11 -128.53 4.449.55 5,948,863.84 483,520.52 0.25 3,726.89 MWD+IFR2+SAG+MS(4) 6,888.08 77.67 261.13 3,836.50 3,699.05 -142.31 4,539.46 5,948,850.21 483,430.60 0.34 3,808.58 MWD+IFR2+SAG+MS(4) 6,962.11 77.42 261.25 3,856.78 3,719.33 -156.37 4,630.19 5,948,836.30 483,339.85 0.29 3,891.11 MWD+IFR2+SAG+MS(4) 7,076.10 77.58 261.75 3,877.13 3,739.68 -169.93 4,720.94 5,948,822.88 483,249.08 0.55 3,973.37 MWD+IFR2+SAG+MS(4) 7,171.02 77.70 262.48 3,897.45 3,760.00 -182.65 4,812.79 5,948,810.31 483,157.23 0.76 4,056.04 MWD+IFR2+SAG+MS(4) 7,264.89 77.72 262.25 3,917.43 3,779.98 -194.84 4.903.69 5,948,798.27 483,066.31 0.24 4,137.64 MWD+IFR2+SAG+MS(4) 7,358.80 77.66 261.93 3,937.45 3,800.00 -207.46 4,994.57 5,948,785.79 482,975.42 0.34 4,219.47 MWD+IFR2+SAG+MS(4) 7,452.41 77.75 262.44 3,957.38 3,819.93 -219.90 -5,085.18 5,948,773.50 482,884.80 0.54 4,300.97 MWD+IFR2+SAG+MS(4) 7,546.60 77.84 262.03 3,977.30 3,839.85 -232.34 -5,176.40 5,948,761.21 482,793.57 0.44 4,382.97 MWD+IFR2+SAG+MS(4) 7,640.70 77.78 262.39 3,997.16 3,859.71 -244.80 5,267.53 5,948,748.89 482,702.43 0.38 4,464.91 MWD+IFR2+SAG+MS(4) 7,735.14 77.72 262.90 4,017.20 3,879.75 -256.62 -5,359.06 5,948,737.22 482,610.89 0.53 4,546.81 MWD+IFR2+SAG+MS(4) 7,829.05 77.63 262.75 4,037.25 3,899.80 -268.08 5,450.09 5,948,725.91 482,519.86 0.18 4,628.09 MWD+IFR2+SAG+MS(4) 7,923.19 77.71 261.67 4,057.35 3,919.90 -260.54 -5,541.20 5,948,713.59 482,428.73 1.12 4,710.02 MWD+IFR2+SAG+MS(4) 8,016.94 78.09 261.17 4,077.00 3,939.55 -294.22 .6,631.85 5,948,700.06 482,338.07 0.66 4,792.26 MWD+IFR2+SAG+MS(4) 7116/2019 1:47:02PM Page 4 COMPASS 5000.14 Build 850 Conocoftillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2M-39 Project: Kuparuk River Unit TVD Reference: 2M-39 actual @ 137.45usft (D19) Site: Kuparuk 2M Pad MD Reference: 2M-39 actual @ 137.45usft (1319) Well: 2M-39 North Reference: True Wellbore: 2M-39 Survey Calculation Method: Minimum Curvature Design: 2M-39 Database: OAKEDMP7 Survey Map Map vertical MD Inc Azi TVD TVDSS +WS +E/ -W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,111.64 78.68 261.31 4,096.07 3,958.62 308.35 -5,723.52 5,94$686.08 462,246.38 0.64 4,875.60 MWD+IFR2+SAG+MS(4) 8,205.98 78.37 261.51 4,114.84 3,977.39 -322.16 5,814.94 5,948,672.42 482,154.95 0.39 4,958.54 MWD+IFR2+SAG+MS(4) 8,300.72 77.89 260.76 4,134.33 3,996.88 336.44 5,906.55 5,948,658,28 482,63.33 0.93 5,041.91 MWD+IFR2+SAG+MS(4) 8,395.11 77.85 260.81 4,154.16 4,016.71 -351.22 -5,97.64 5,948,643.65 481,972.23 0.07 5,125.14 MWD+IFR2+SAG+MS(4) 8,489.68 77.36 260.76 4,174.50 4,037.05 366.04 6,089.00 5,948,628.98 481,880,85 0.52 5,208.63 MWD+IFR2+SAG+M$(4) 8,582.73 77.34 261.28 4,194.84 4,057.39 380.19 5,178,49 5,948,614.98 481,791.35 0.55 5,290.17 MWD+IFR2+SAG+MS(4) 8,676.99 77.21 261.71 4,215.60 4,078.15 -393.78 6,269.42 5,948,601.53 481]00,40 0.47 5,372.60 MWD+IFR2+SAG+MS(4) 8,770.57 77.38 261.90 4,236.18 4,098.73 406.80 6,359.78 5,948,588.66 481,610.03 0.27 5,454,22 MWD+IFR2+SAG+MS(4) 8,865.14 77.16 26175 4,257.02 4,119.57 419.91 6,451.09 5,948,575.69 481,518,71 0.28 5,536.68 MWD+IFR2+SAG+MS(4) 8,958.&1 77.26 262.15 4,277.72 4,140.27 432.68 6,541,36 5,948,563.7 481428.43 0.43 5,618,09 MWD+IFR2+SAG+MS(4) 9,052.76 77.14 262.61 4,298.57 4,161,12 -044.85 6,632.34 5,948,551.04 481,337.44 0.49 5,699.74 MWD+IFR2+SAG+MS(4) 9,148.07 77.92 263.16 4,319.15 4,181.70 456.38 6,724.68 5,948,539.67 481,245.09 0.99 5,782,14 MWD+IFR2+SAG+MS(4) 9,242.65 77.74 263.50 4,339.09 4,201+64 467.12 6,816.51 5,94$529.06 481,153.25 0.40 5,863.67 MWD+IFR2+SAG+MS(4) 9,335.90 77.83 263.98 4,358.82 4,221.37 477.05 6,907,11 5,948,519.28 481,062.65 0.51 5,943,73 MWD+IFR2+SAG+MS (4) 9,429.93 78.35 264.10 4,378.22 4,24477 486.61 6,998.61 5,948,509.88 480,971.14 0,57 6,024.32 MWD+IFR2+SAG+MS(4) 9,523.55 78.28 263.59 4,397.19 4,259.74 496.44 -7,089.77 5,948,500.19 480,879.98 0.54 6,104.78 MWD+IFR2+SAG+MS(4) 9,618,22 78,24 261.43 4,416.45 4,279.00 506.52 -7,181.66 5,948,488.26 480,788.08 2,23 6,187.13 MWD+IFR2+SAG+MS(4) 9,714.44 78.27 261.27 4,436.04 4,298.59 522,69 -7,274.79 5,948,474.24 480,694.93 0,17 6,271.69 MND+IFR2+SAG+MS (4) 9,808.86 78.43 260.20 4,455.10 4,317.65 537.58 -7,366.06 5,948,459.50 480,603.65 1.12 6,355.12 MWD+IFR2+SAG+MS(4) 9,902.29 78.09 259.20 4,474.11 4,336.66 553,93 -7,456.06 5,948,443.29 480,513.63 1.11 6,438.36 MWD+IFR2+SAG+MS(4) 9,995.83 78.11 259.09 4,493.40 4,355.95 571.17 -7,545.95 5,948,426.20 480,423.72 0.12 6,522.01 MWD+IFR2+SAG+MS(4) 10,090.04 77.93 259.24 4,512.96 4,375.51 588,49 -7,636.47 5,948,409.02 480,333.19 0,25 6,606.22 MWD+IFR2+SAG+MS(4) 10,182,06 77.78 259.31 4,532,32 4,394.87 605.23 -7.724.86 5,948,392.42 480,244.78 0.18 6,688.35 MWD+IFR2+SAG+MS(4) 10,277.64 77.93 259.45 4,552.43 4,414.98 622.45 -7,816.70 5,948,375.35 480,152.92 0.21 6,773.59 MWD+IFR2+SAG+MS(4) 10,371.42 78.02 259.97 4,571,96 4,434.51 638.84 -7,906.94 5,948,359.11 480,62.66 0.55 6,857.04 MWD+IFR2+SAG+MS(4) 10,465.33 78.02 259.81 4,591.46 4,454.01 654.96 -7,997.38 5,948,343.13 479,972.20 0.17 6,940.51 MWD+IFR2+SAG+MS(4) 10,558.98 77.66 259,91 4,611.18 4,473.73 671.08 6,087.50 5,948,327.16 479,882.07 0.40 7,023.70 MWD+IFR2+SAG+MS(4) 10,652.80 77.45 260.52 4,631.40 4,493.95 686.65 48,177.78 5,948,311.74 479,791.77 0.67 7,106.72 MWD+IFR2+SAG+MS(4) 10,746,94 77.58 261.09 4,651.75 4,514.30 -701.34 6,268.51 5,948,297.20 479,701.02 0.61 7.189.61 MWD+IFR2+SAG+MS(4) 10,841.30 77.70 26177 4,671,95 4,534.50 -715.07 -8,359.66 5,948,283.61 479,609.87 0.72 7,272.28 MWD+IFR2+SAG+MS(4) 10,935.67 77.45 262.62 4,692.26 4,554.61 -727.59 5,450,96 5,948,271.24 479,518.55 0.92 7,354.40 MWD+IFR2+SAG+MS(4) 11,030.69 77.51 263,65 4,712,86 4,575.41 -738.68 -8,543.06 5.M,260,30 479,426.45 1.06 7,436.34 MWD+IFR2+SAG+MS(4) 11,124.45 77.70 263,62 4,732.98 4,595.53 -748.83 5,634.07 5,948,250.30 479,335.43 0.21 7,516.87 MND+IFR2+SAG+MS(4) 11,218.36 77.60 263,75 4,753.07 4,615.62 -758.92 -8,725.25 5,948,240,35 479,244.24 0.17 7,597.50 MND+IFR2+SAG+MS (4) 11,311.06 77.75 262.91 4,772.86 4,635.41 -769.44 5,815.20 5,948,229.98 479,154,29 0.90 7,677.36 MND+IFR2+SAG+MS(4) 11,405.90 77.90 262.09 4,792.86 4.655.41 -781.54 -8,907.11 5,948,218,03 479,62.36 0.86 7,759,73 MND+IFR2+SAG+MS (4) 11,498.26 77.83 261.43 4,812.27 4,674.82 -794.48 -8,996.47 5,948,205.23 478,972.99 0.70 7,840.50 MWD+IFR2+SAG+M$(4) 11,593.75 78.23 260.93 4832.08 4,694.63 508.80 5,088,78 5,948,191.05 478,880.67 0.66 7,924,47 MWD+IFR2+SAG+MS(4) 11,688.57 78.22 261.15 4,851.43 4,713.98 -823.26 -8,180.47 5,M.176.75 478,788.96 0.23 8,008,01 MND+IFR2+SAG+MS(4) 11,783.56 78.17 261.32 4,870.86 4,733,41 537,43 5,272.37 5,94$162.73 478,697.05 0.18 8,091.55 MND+IFR2+SAG+MS(4) 7116/2019 1:47:02PM Page 5 COMPASS 5000.14 Build 650 ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2M-39 Project Kuparuk River Unit TVD Reference: 2M-39 actual @ 137.45usft (D19) She: Kuparuk 2M Pad MD Reference: 2M-39 actual @ 137.45usft (D19) Well: 2M-39 North Reference: True Wellbore: 2M-39 Survey Calculation Method: Minimum Curvature Design: 2M-39 Database: OAKEDMPI Survey 711WO19 1:47:02PM Page 6 COMPASS 500014 Build 85D Map Map Vertical MD Inc Azi TVD TVDSS +W -S +E14N Northing Easting DLS Section (-ft) p) (1) (usft) (usft) (MR) (MR) (ft) (ft) (°1100') (ft) Survey Tool Name 11,877.31 77.84 262.75 4,890.35 4,752.90 -950.14 -9,363.18 5,948,150.16 478,606.23 1.53 8,173.37 MWD+IFR2+SAG+MS(4) 11,972.43 77.55 264.20 4,910.62 4,773.17 -960.70 5,455.51 5,948,139.75 478,513.89 1.52 8,255.21 MVA+IFR2+SAG+MS (4) 12,066.47 78.09 263.93 4,930.6 4,793.01 -870.20 -9,546.94 5,948,130.39 478,422.45 0.64 8,335.71 MVA+IFR2+SAG+MS(4) 12,160.62 77.80 263.72 4,950.12 4,812.67 -850.11 5,638.48 5,948,120.64 478,330.91 0.3B 8,416.53 MWD+IFR2+SAG+MS(4) 12,254.57 77.93 262.18 4,969.87 4,832.42 -891.38 -9,729.64 5,948,109.51 478,239.74 1.61 8,497.81 MWD+IFR2+SAG+MS(4) 12,349.05 77.93 261.85 4,989.63 4,852.18 504.22 5,821.13 5,948,096.82 478,148.24 0.34 8,580.26 MWD+IFR2+SAG+MS(4) 12,443.34 77.77 260.79 5,009.48 4,872.03 -918.13 -9,912.25 5,948,083.06 478,057.10 1.11 8,663.02 MWD+IFR2+SAG+MS(4) 12,538.90 77.99 260.82 5,029.54 4,892.09 533.06 -10,004.48 5,948,068.28 477,964.86 0.23 8,747.27 MWD+IFR2+SAG+MS(4) 12,632.12 77.99 260.25 5,048.94 4,911.49 -948.05 -10,094.42 5,948,053.43 477,874.91 0.60 8,829.68 MWD+IFR2+SAG+MS(4) 12,726.28 77.80 260.18 5,068.68 4,931.23 -963.70 -10,185.15 5,948,037.93 477,784.16 0.21 8,913.10 MWD+IFR2+SAG+MS(4) 12,820.16 77.84 260.29 5,088.49 4,951.04 -979.26 -10,275.58 5,948,022.51 477,693.71 0.12 8,996,25 MWD+IFR2+SAG+MS(4) 12,914.24 77.93 260.24 5,108.24 4,970.79 594.81 -10,366.24 5,948,007.11 477,603.04 0.11 9,079.57 MVA+IFR2+SAG+MS(4) 13,008.71 77.78 260.51 5,128.11 4,990.66 -1,010.26 -10,457.30 5,947,991.81 477,511.96 0.32 9,163.14 MVA+IFR2+SAG+MS(4) 13,104.00 77.76 261.47 5,14a.30 5,010.85 -1,024.84 -10,549.28 5,997,977.37 477,419.97 0.98 9,246.99 MWD+IFR2+SAG+MS(4) 13,197.90 77.56 261.99 5,168.36 5,030.91 -1,036.03 -10,640.05 5,947,964.33 477,329.18 0.58 9,329.06 MVA+IFR2+SAG+MS(4) 13,291.29 77.81 263.50 5,188.28 5,050.83 -1,049.92 -10,730.51 5,947,952.59 4T,238.71 1.13 9,410.12 MWD+IFR2+SAG+MS(4) 13,386.28 77.93 263.00 5,208.24 5,070.79 -1,061.21 -10,822.69 5,947,941.45 477,146.52 0.13 9,492.25 MWG+IFR2+SAG+MS (4) 13,480.12 77.93 262.26 5,227.87 5,090.42 -1,072.98 -10,913.70 5,947,929.83 477,055.51 0.77 9,573.70 MVA+IFR2+SAG+MS 14) 13,573.00 77.84 261.42 5,247.36 5,109.91 -1,085.87 -11,003.59 5,947,917.08 476,965.60 0.89 9,654.87 MND+IFR2+SAG+MS(4) 13,668.79 77.93 261.24 5,267.46 5,130.01 -1,099.98 -11,096.1B 5,947,903.11 476,873.00 0.21 9,738.95 MWD+IFR2+SAG+MS(4) 13,763.93 77.78 261.19 5,287.48 5,150.03 -1,114.19 -11,188.10 5,947,889.06 476,781.07 0.17 9,822.53 MWD+IFR2+SAG+MS(4) 13,856.31 77.62 261.50 5,307.16 5,169.71 -1,127.77 -11,277.33 5,947,875.62 476,691.83 0.37 9,903.55 MND+IFR2+SAG+MS(4) 13,951.72 78.06 261.97 5,327.26 5,189.81 -1,141.18 -11,369.63 5,947,862.36 476,599.52 0.67 9,986.99 MV4D+IFR2+SAG+MS(4) 14,046.22 77.98 261.78 5,346.87 5,209.42 -1,154.24 -11,461.14 5,997,849.44 476,507.99 0.21 10,069.59 MVA+IFR2+SAG+MS(4) 14,138.92 78.01 262.18 5,366.15 5,228.70 -1,166.89 -11550.93 5,997,836.94 476,418.19 0.42 10,150.53 MV4D+IFR2+SAG+MS(4) 14,233.50 78.20 262.11 5,385.65 5,248.20 -1,179.54 -11,642.61 5,947,824.43 476,326.50 0.21 10,233.03 MVA+IFR2+SAG+MS(4) 14,326.86 78.02 262.06 5,404.88 5,267.43 -1,192.12 -11,133.10 5,947,812.00 476,236.00 0.20 10,314.51 MVA+IFR2+SAG+MS(4) 14,419.78 77.84 261.63 5,424.31 5,286.86 -1,205.01 -11,823.04 5,947,799.26 476,146.05 0.49 10,395.72 MWD+IFR2+SAG+MS(4) 14,514.84 77.85 261.94 5,444.33 5,306.88 -1,218.29 -11,915.02 5,947,786.13 476,054.06 0.32 10,478.82 MWD+IFR2+SAG+MS(4) 14,609.48 77.67 261.64 5,464.39 5,326.94 -1,231.50 -12,006.56 5,947,773.07 475,962.51 0.36 10,561.53 MWD+IFR2+SAG+MS(4) 14,703.51 77.31 261.42 5,484.76 5,347.31 -1,245.02 -12,097.36 5,947,759.69 475,871.70 0.45 10,643.80 MWD+IFR2+SAG+MS(4) 14,797.66 78.19 260.40 5,504.74 5,367.29 -1,259.56 -12,188.20 5,947,745.30 475,780.84 1.41 10,726.69 MWD+IFR2+SAG+MS(4) 14,891.48 79.11 258.92 5,523.20 5,385.75 -1,27607 -12,278.69 5,947,728.94 475,690.33 1.83 10,810.41 MWD+IFR2+SAG+MS(4) 14,986.48 78,62 256.68 5,541.55 5,404.10 -1,295.76 -12,369.79 5,947,709.39 475,599.21 2.37 10,896.46 MWD+IFR2+SAG+MS(4) 15,080.64 77.48 254.73 5,561.05 5,423.60 -1,318.50 -12,459.05 5,947,686.79 475,509.92 2.36 10,982.73 MND+IFR2+SAG+MS (4) 15,173.25 77.01 252.02 5,581,50 5,444.06 -1,344.34 -12,645.59 5,947,661.10 475,423.35 2.90 11,068.54 MWD+IFR2+SAG+MS(4) 15,M7.BB 76.09 249.15 5,603.52 5,466.07 -1,374.93 -12,632.39 5,947,630.65 475,336.51 3.11 11,157.26 MWD+IFR2+SAG+MS(4) 15,361.05 74.73 245.38 5,626.99 5,489.54 -1,Q9.76 -12,715.53 5,947,595.96 475,253.32 4.18 11,245.41 MVA+IFR2+SAG+MS (4) 15,456.26 74.90 241.52 5,651.94 5,514.49 -1,450.82 -12,797.71 5,947,555.03 475,171.09 3.92 11,336.33 MWD+IFR2+SAG+MS(4) 15,549.83 74.70 238.16 5,676.48 5,539.03 -1,496.18 -12,875.77 5,947,509.80 475,092.96 3.47 11,426.31 MWD+IFR2+SAG+MS(4) 711WO19 1:47:02PM Page 6 COMPASS 500014 Build 85D ConocoPhillips Definttive Survey Report Company: NADConversion Local Coordinate Reference: Well 2M-39 Project Kuparuk River Unit TVD Reference: 2M-39 actual Q 137.45usft (D19) Slte: Kuparuk 2M Pad MD Reference: 2M-39 actual ® 137.45usft (D19) Wen; 2M-39 North Reference: True Wenbcre: 2M-39 Survey Calculation Method: Minimum Curvature Design: 21 Database: OAKEDMPI Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +E/ -W Northing Easting DLS Section ("it) (°) (1) (usft) (usft) (usft) (usm (ft) (R) (-11901 (1t) Survey Tool Nam 15,643.74 7508 235.68 5,700.96 5,563.51 -1,545.66 -12,95173 5,947,460.45 475,016.93 2.58 11,516.92 MWD+IFR2+SAG+MS(4) 15,738.54 74.49 231.60 5,725.85 5,588.40 -1,599.88 -13,025.38 5,947,406.36 474,943.20 4.20 11,608.35 MWD+IFR2+SAG+MS(4) 15,833.25 73.76 227.52 5,751.77 5,614.32 -1,658.95 -13,D94.70 5,947,347.40 474,873.79 4.21 11,698.98 MWD+IFR2+SAG+MS(4) 15,928.23 73.12 222.16 5,778.86 5,641.41 -1,723.47 -13,158.87 5,947,282.93 474,809.52 5.45 11,788.60 MWD+IFR2+SAG+MS(4) 15,957.23 73.10 220.44 5,78728 5,649.83 -1,744.31 -13,177.19 5,947,262.17 474,791.18 5.68 11,815.44 MWD+IFR2+SAG+MS(4) 16,056.45 73.28 216.56 5,815.99 5,678.54 -1,818.63 -13,236.30 5,947,187.96 474,731.95 3.75 11,906.39 MWD+IFR2+SAG+MS(5) 16,103.53 73.10 213.07 5,829.61 5,692.16 -1,855.63 -13,262.02 5,947,151.01 474,706.17 7.11 11,948.63 MWD+IFR2+SAG+MS(5) 16,197.23 75.92 206.28 5,854.66 5,717.21 -1,934.04 -13,306.66 5,947,072.68 474,661.41 7.60 12,030.04 MWD+IFR2+SAG+M5(5) 16,291.42 76.90 203.24 5,876.79 5,739.34 -2,017.16 -13,395.00 5,946989.62 474,622.95 3.31 12,108.96 MWD+IFR2+SAG+MS(5) 16,386.06 78.56 200.02 5,896.91 5,759.46 -2,103.12 -13,379.07 5,946903.73 474,588.74 3.76 12,166.00 MWD+IFR2+SAG+MS(5) 16,479.55 79.90 196.52 5,914.39 5,776.94 -2,190.32 -13,407.85 5,946816.59 474,559.82 3.95 12,259.41 MWD+IFR2+SAG+MS (5) 16,574.27 80.89 191.12 5,930.20 5,792.75 -2,280.97 -13,430.15 5,946,725.98 474,537.39 5.72 12,329.46 MWD+IFR2+SAG+MS(5) 16,669.35 81.05 187.45 5,945.13 5,807.68 -2,373.63 -13,445.29 5,946633.35 474,522.09 3.82 12,394.79 MWD+IFR2+SAG+MS(5) 16,763.12 80.99 186.07 5,959.77 5,822.32 -2,465.60 -13,456.20 5,946,541.41 474,511.04 1.46 12,456.23 MYV13HFR2+SAG+MS (5) 16,857.20 80.99 186.69 5,974.50 5,837.05 -2,557.94 -13,466.52 5,946,449.09 474,500.57 0.65 12,517.41 MWD+IFR2+SAG+MS (5) 16,951.10 80.96 186.51 5,989.23 5,851.78 -2,650.07 -13,477.18 5,946,356.99 474,489.77 0.19 12,578.75 MWD+IFR2+SAG+MS (5) 17,045.68 81.02 185.78 6,004.04 5,866.59 -2,742.94 -13,487.18 5,946,264.14 474,479.62 0.76 12,639.97 MWD+IFR2+SAG+MS(5) 17,138.95 81.01 185.14 6,018.61 5,881.16 -2,834.65 -13,495.95 5,946172.46 474,470.71 0.68 12,699.51 MWD+IFR2+SAG+MS(5) 17,233.81 79.77 182.92 6,034.45 5,897.00 -2,927.94 43,502.52 5,946079.19 474,463.98 2.65 12,758.16 MWD+IFR2+SAG+MS(5) 17,328.32 80.07 182.40 6050.99 5,913.54 -3,020.89 -13,506.84 5,945,985.26 474,459.52 0.63 12,814.76 MWD+IFR2+SAG+MS(5) 17,422.34 79.98 183.69 6,067.28 5,929.83 3,113.35 -13,511.76 5,945,893.81 474,454.45 1.35 12,871.58 MWD+IFR2+SAG+MS(5) 17,517.02 80.03 183.88 6,083.71 5,946.26 -3,206.39 -13,517.91 5,945,800.79 474,448.15 0.20 12,929.74 MWD+IFR2+SAG+MS(5) 17,611.13 79.92 185.37 6,100.09 5,962.64 -3,298.76 -13,525.39 5,945,708.44 474,440.53 1.56 12,988.59 MWD+IFR2+SAG+MS(5) 17,705.57 80.03 186.24 6,116.53 5,979.08 -3,391.28 -13,534.79 5,945,615.94 474,430.98 0.91 13,049.13 MWD+IFR2+SAG+MS(5) 17,797.36 80.02 186.64 6,132.43 5,994.98 3,481.11 -13,544.93 5,945,526.14 474,420.69 0.43 13,108.73 MW3+IFR2+SAG+MS(5) 17,828.61 80.16 187.21 6,137.81 6,000.36 -3,511.67 -13,598.69 5,945,495.59 474,416.93 1.85 13,129.22 MWD+IFR2+SAG+MS(5) 17,857.67 79.99 187.30 6,142.82 6,005.37 3,540.07 -13,552.26 5,945,467.20 474,413.27 0.66 13,148.39 Wv/34NC_0NLY(6) 17,951.81 82.21 187.01 6,167.38 6,019.93 3,632.35 -13,563.84 5,945,374.95 474,401.55 2.38 13,210.57 MWD+IFR2+SAG+MS(7) 18,045.84 84.26 186.84 6,168.46 6,031.01 3,725.03 -13,575.10 5,945,282.29 474,390.14 2.19 13,272.72 MWD+IFR2+SAG+MS(7) 18,139.92 88.97 166.98 6,174.01 6,036.56 3,818.24 -13,586.39 5,945,189.11 474,378.70 5.01 13,335.20 MWD+IFR2+SAG+MS(7) 18,234.11 93.29 186.45 6,172.15 6,034.70 3,911.74 -13,597.40 5,946095.63 474,367.54 4.62 13,397.61 MWD+IFR2+SAG+MS(7) 18,328.34 93.07 186.11 6166.93 6,029.48 4,005.26 -13,607.69 5,946002.14 474,357.10 0.43 13,459.44 MWD+IFR2+SAG+MS(7) 18,422.11 93.34 186.20 6,161.68 6,024.23 4,098.35 -13,617.73 5,944,909.08 474,346.91 0.30 13,520.81 MWD+IFR2+SAG+MS(7) 18,516.92 94.17 187.27 6,155.48 6,018.03 4,192.30 -13,628.83 5,944,815.16 474,335.67 1.43 13,583.55 MWD+IFR2+SAG+MS(7) 18,610.63 95.29 184.94 6,147.75 6010.30 4,285.15 -13,638.76 5,944,722.33 474,325.59 2.75 13,644.70 MWD+IFR2+SAG+MS(7) 16704.93 95.31 183.89 6,139.04 6,001.59 4,378.77 -13,645.99 5,944,628.73 474,318.21 1.11 13,709.07 MWD+IFR2+SAG+MS(7) 18,798.55 95.56 182.80 6,130.17 5,992.72 -0,471.81 -13,651.43 5,944,535.71 474,312.63 1.19 13,761.64 MWD+IFR2+SAG+MS(7) 18,892.26 93.60 182.15 6,122.69 5,985.24 -0,565.13 -13,655.6 5,944,442.41 474,308.44 2.20 13,818.22 MWD+IFR2+SAG+MS(7) 18,987.36 89.68 181.60 6,119.96 5,982.51 3,660.12 -13,658.57 5,944,347.43 474,305.18 4.16 13,874.99 MWD+IFR2+SAG+MS(7) 19,080.73 88.57 180.67 6,121.39 5,983.94 4,753.46 -13,660.42 5,944,254.11 474,303.19 1.55 13,929.78 MWD+IFR2+SAG+MS(7) 7/16/2019 1:47:02PM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConvereion Local Coordinate Reference: Well 210-39 Project: Kuperuk River Unit TVD Reference: 2M-39 actual @ 137.45usft (D19) Site: Kuparuk 2M Pad MD Reference: 2M-39 actual @ 137.45usft (D19) Well: 210-39 North Reference: True Wellbore: 2M-39 Survey Calculation Method: Minimum Curvature Design: 2M-39 Database: OAKEDMPI Survey Map Map Vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Emoting DIS Section (usll) 11 (•) (usft) (usft) (waft) (usft) (In (ft) (°/1001 (ft) Survey Tool Name 19,174.85 88.5B 181.77 6,123.73 5,986.28 4,847.53 -13,66242 5,944,160.05 474,301.03 1.17 13,985.12 MND+IFR2+SAG+MS(7) 19,268.98 88.27 184.04 6,126.32 5,988.87 4,94149 -13,667A9 5,944,066.10 474,296.11 2.43 14,042.67 MWD+IFR2+SAG+MS(7) 19,363.41 88.33 190.96 0129.12 5,991.67 5,035.02 -13,679.50 5,943,972.61 474,283.65 7.33 14,106.16 MWD+IFR2+SAG+MS(7) 19,457.18 89.06 196.83 6,131.26 5,993.81 5,125.98 -13,702.01 5,943,881.69 474,261.01 6.31 14,176.56 MND+IFR2+SAG+MS(7) 19,551.84 86.88 197.64 6,134.61 5,997.16 -5,216.32 -13,730.03 5,943,791.40 474,232.84 246 14,251.14 MWD+IFR2+SAG+MS(7) 19,645.68 86.49 193.86 6,140.04 6,002.59 5,306.47 -13,755.46 5,943,701.30 474,207.27 4.04 14,323.47 MN4D+IFR2+SAG+MS (7) 19,740.38 88.95 192.82 6,143.81 6,006.36 5,396.54 -13,777.29 5,940609.28 474,185.30 2.82 14,393.94 MWD+IFR2+SAG+MS(7) 19,831.45 89.00 193.39 6,145.44 6,007.99 5,487.22 -13,797.93 5,943,520.64 474,164.51 0.63 14,461.52 MWD+IFR2+SAG+MS(7) 19,925.6 87.17 194.67 6,148.58 0011.13 5,578.37 43,820.71 5,943,429.53 474,141.59 2.38 14,532.24 MND+IFR2+SAG+MS(7) 20,022.25 89.29 197.14 6,151.57 6,014.12 5,671.40 -13,847.22 5,943,336.56 47014.94 3.36 14,607.11 MWD+IFR2+SAG+MS(7) 20,116.27 89.00 195.17 6,152.97 6,015.52 5,761.69 -13,873.37 5,943,246.32 474,088.64 2.12 14,680.12 MND+IFR2+SAG+MS (7) 20,210.73 87.40 191.74 6,155.94 6,018.49 5,853.50 -13,895.34 5,943,154.56 474,066.53 4.01 14,75056 MND+IFR2+SAG+MS(7) 20,305.13 87.52 195.48 6,160.13 6,022.68 5,945.14 -13,917.53 5,943,062.96 474,044.20 3.96 14,821.09 MND+IFR2+SAG+MS (7) 20,399.11 87.68 195.62 6,164.06 6,026.61 5,035.60 -13,942.70 5,942,972.55 474,018.88 0.23 14,893.39 MND+IFR2+SAG+MS (7) 20,493.66 84.69 193.38 6,170.35 6,032.90 5,126.82 -13,966.29 5,942,881.37 473,995.14 3.95 14,964.83 MWD+IFR2+SAG+MS(7) 20587.55 85.60 192.12 6,178.30 6,040.85 5,218.16 -13,986.96 5,942,790.07 473,974.33 1.65 15,033.93 MND+IFR2+SAG+MS (7) 20,682.16 88.93 192.35 6,182.81 6,045.36 5,310.50 -14,006.99 5,942,697.77 473,954.16 3.53 15,103.08 MWD+IFR2+SAG+MS(7) 20776.64 87.72 191.48 6,185.58 6,048.13 8,402.91 -14p26.48 5,942,605.41 473,934.52 1.58 15,171.84 MWD+IFR2+SAG+MS(7) 20840.95 86.66 192.46 6,188.73 0051.28 5,465.74 -14,039.81 5,942,542.60 473,921.10 2.24 15,218.64 MWD+IFR2+SAG+MS (7) 20,935.22 87.40 193.01 6,193.61 6,056.16 8,557.57 -14,060.56 5,942,45082 473,900.20 0.98 16,288.09 MWD+IFR2+SAG+MS(7) 21,028.75 85.95 193.77 6,198.22 0060.77 8,648.44 -14,082.19 5,942,359.99 473,878.43 0.94 15,357.72 MND+IFR2+SAG+MS (7) 21,124.49 87.64 193.71 6,202.74 6,065.29 8,741.34 -14,104.91 5,942,267.14 473,855.57 0.72 15,429.40 MWD+IFR2+SAG+MS(7) 21,217.84 88.84 193.38 6,205.61 6,068.16 5,832.05 -14,126.76 5,942,176.47 473,833.57 1.33 15,499.12 MND+IFR2+SAG+MS(7) 21,314.13 90.21 191.32 6,206.41 6,068.96 8,926.10 -14,147.35 5,942,082.46 473,812.83 2.57 15,569.71 MND+1FR2+SAG+MS (7) 21,406.72 90.65 190.86 6,205.71 6,068.26 -7,016.96 -14,165.16 5,991,991.64 473,794.88 0.69 15,635.19 MND+IFR2+SAG+MS (7) 21501.24 90.41 191.19 6,204.84 6,067.39 -7,109.73 -14,183.24 5,941,898.91 473,776.66 0.43 15,703.98 MWD+IFR2+SAG+MS (7) 21,594.57 90.83 191.47 6,203.83 6,066.38 -7,201.23 -14,201.57 5,941,B07.44 473,758.18 0.54 15,771.27 MWD+IFR2+SAG+MS (7) 21,689.59 91.31 191.84 6,202.05 6,064.60 -7,294.28 -14,220.76 5,941,714.44 473,738.84 0.64 15,840.14 MWD+IFR2+SAG+MS (7) 21,783.96 90.72 191.12 6,200.38 6,062.93 -7,386.74 -14,239.54 5,941,622.01 473,719.91 0.99 15,90B.W MWD+IFR2+SAG+MS(7) 21,877.88 89.18 189.87 6,200.46 6,063.01 -7,479.09 -14,256.65 5,941,529.70 473,702.66 2.11 15,975.09 MND+IFR2+SAG+MS (7) 21,971.92 87.83 185.90 6,202.92 6,065.47 -7,572.19 -14,269.54 5,941,436.64 473,689.62 4.46 16,038.81 MWD+IFR2+SAG+MS(7) 22,067.59 89.09 184.88 6,205.49 6,068.04 -7,667.40 -14,278.52 5,941,391.45 473,680.48 1.69 16,100.53 MWD+IFR2+SAG+MS(7) 22,161.17 88.60 185.91 6,2D7.38 6,069.93 -7,760.54 -14,267.32 5,941,248.33 473,671.54 1.22 16,160.92 MWD+1FR2+SAG+MS(7) 22,254.73 88.67 187.67 6,209.60 6,072.15 -7,853.42 -14,298.38 5,941,155.48 473,660.33 1.88 10223.01 MWD+IFR2+SAG+MS(7) 22,348.44 88.46 191.24 6,211.95 6,074.50 -7,945.81 -14,313.77 5,941,063.12 473,644.80 3.82 16,288.38 MWD+IFR2+SAG+MS(7) 22,442.31 88.73 194.72 6,214.25 6,076.80 8,037.24 -14,334.84 5,940,971.74 473,623.58 3.72 16,357.87 MWD+1FR2+SAG+MS(7) 22,536.00 88.73 197.69 6,216.33 6,078.88 5,127.17 -14,360.98 5,940881.85 473,597.30 3.17 16,430.67 MWD+IFR2+SAG+MS(7) 22,630.95 89.39 198.01 6,217.89 6,080.44 8,217.54 -14,390.08 5,940,791.54 473,568.06 0.77 16,506.14 MWD+IFR2+SAG+MS(7) 22,726.31 89.90 195.41 6,218.48 6,081.03 8,308.86 -14,417.49 5,940700.27 473,540.50 2.78 16,580.78 MWD+IFR2+SAG+MS(7) 22,817.97 90.04 191.45 6,218.53 0081.08 8,398.00 -14,438.78 5,940,611.18 473,519.08 4.32 16,649.13 MWD+IFR2+SAG+MS(7) 7/162019 1:47:02PM Page S COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2M-39 Project: Kuparuk River Unit TVD Reference: 2M-39 actual @ 137.45usft (D19) Site: Kuparuk 2M Pad MD Reference: 2M-39 actual @ 137.45usft (D19) Well: 214-39 North Reference: True Wellbore: 2M-39 Survey Calculation Method: Minimum Curvature Design: 2M-39 Database: OAKEDMPI Survey Map Map vertical MD Inc Azi TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usfq (1) (') (-ft) (usfl) (usft) (usft) (ft) (ft) ('/100') (ft) Survey Tool Name 22,912.47 90.42 190.02 6,218.15 6,080.70 -8,490.84 -14,456.38 5.940 518.37 473,501.33 1.57 16716.58 MWD+11`112+SAG+10S (7) 23,006.33 91.62 189.60 6,216.48 6,079.03 4,583.31 -14,472.37 5,940,425.94 473,485.19 1.35 16,782.49 MWD+IFR2+SAG+MS (7) 23,100.52 92.44 191.51 6,213.14 6,075.69 -8,675.85 -14,489.61 5,940,333.44 473,467.81 2.21 16,849.46 MWD+IFR2+SAG+MS(7) 23,194.22 92.40 193.22 6,208.18 6,071.73 4,767.29 -14,509.66 5,940,242.04 473,447.62 1.82 16,918.11 MWD+IFR2+SAG+MS(7) 23,288.50 92.56 193.17 6,205.11 6,067.66 -8,858.99 -14,531.16 5,940,150.38 473,425.97 0.17 16,988.11 MWD+IFR2+SAG+MS(7) 23,382.22 91.20 193.31 6,202.05 6,064.60 -8,950.17 -14,552.61 5,940,059.24 473,404.38 1.45 17,057.77 MWD+IFR2+SAG+MS(7) 23,476.29 91.60 189.33 6,199.75 6X2.30 4,042.36 -14,571.07 5,939,967.09 473,385.77 4.25 17,125.55 MWD+IFR2+SAG+MS(7) 23,570.24 89.77 184.70 6,198.62 6,061.17 4,135.58 -14,582.54 5,939,873.91 473,374.16 5.30 17,18B.17 MWD+IFR2+SAG+MS(7) 23,662.64 92.13 185.37 6,197.09 6,059.64 4,227.60 -14,590.64 5,939,781.91 473,365.90 2.66 17,247.35 MWD+IFR2+SAG+MS(7) 23,758.06 90.27 186.46 6,195.09 6,057.64 4,322.48 -14,600.47 5,939,687.04 473,355.92 2.26 17,309.58 MWD+IFR2+SAG+MS(7) 23,854.82 90.69 189.23 6,194.28 6,056.83 4,418.33 -14,613.68 5,939,591.23 473,342.56 2.90 17,375.13 MWD+IFR2+SAG+MS(7) 23,946.28 90.09 188.63 6,193.70 6,056.25 -9,508.67 -14,627.88 5,939,500.92 473,328.23 0.97 17,438.35 MWD+IFR2+SAG+MS (7) 24,039.91 89.41 184.46 6,194.15 6,056.70 -9,601.67 -14,638.55 5,939,407.95 473,317.41 4.50 17,500.20 MWD+IFR2+SAG+MS (7) 24,135.81 90.89 1WAS 6,193.90 6,056.45 4,697.15 -14,64].44 5,939,312.49 473,308.37 2.37 17,561.99 MWD+IFR2+SAG+MS(7) 24,229.35 88.70 188.82 6,194.23 6,056.78 4,789.88 44,659.64 5,939,219.79 473,296.01 3.67 17,624.94 MWD+IFR2+SAG+MS(7) 24,324.90 87.91 192.74 6,197.06 6,059.61 5,883.68 -14,677.50 5,939,126.03 473,278.00 4.18 17,693.15 MWD+IFR2+SAG+MS(7) 24,419.36 87.84 196.48 6,200.56 6,063.11 4,975.01 -14,701.31 5,939,034.75 473,254.05 3.96 17,764.82 MWD+IFR2+SAG+MS(7) 24,514.08 88.77 199.78 6,203.37 6,065.92 -10,064.97 -14,730.77 5,938,944.84 473,224.46 3.62 17,840.36 MWD+IFR2+SAG+MS(7) 24,607.22 89.15 203.28 6,205.06 6,067.61 -10,151.59 -14,764.94 5,938,858.29 473,190.15 3.76 17,917.86 MWD+IFR2+SAG+MS(7) 24,702.49 89.35 210.68 6,206.31 6,068.86 -10,236.42 -14,808.13 5,938,773.53 473,146.83 777 18,001.74 MWD+IFR2+SAG+MS(7) 24,735.74 88.81 205.43 6,206.84 6,069.39 -10,265.75 -14,823.76 5,938,744.23 473,131.15 15.87 18,031.32 MWD+IFR2+SAG+MS (7) 24,800.00 88.81 205.43 6,208.18 6,070.73 -10,323.77 -14,851.34 5,938,686.26 473,103.48 O.W 18,087.09 PROJECTED to TD 7/1612019 1:47: 02PM Page 9 COMPASS 5000.14 Build 85D NADConversion Kuparuk River Unit Kuparuk 2M Pad 2M-39PB1 2M-39PB1 ConocoPhillips Definitive Survey Report 16 July, 2019 Final Definitive Survey Verified and Signed -off All targets and/or well position objectives have beer[ achieved. n Yes ❑ No I have checked to the lest of my ability that the tollowing data is correct: 0 Surface Coordinates O Declination & Convergence GRS Suwey Conections C Survey Tod Codes SLB DE: Client Representative: Brandon Temrt'e Digitally signed by Brandon Temple P' Date: 2019.07.161353:57 -08'00' Keith Herrin Digitally sigaag by Neill Hening 9 Data 201907.161692,19-08W Date: 0711612019 ConocoPhillips ConocoPhillips I Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 210-39 Project: Kuparuk River Unit TVD Reference: 2M-39 actual @ 137.45usft lot 9) Site: Kuparuk 2M Pad MD Reference: 210-39 actual @ 137.45usft (D19) Well: 210-39 North Reference: True Wellbore: 2M-39PB1 Survey Calculation Method: Minimum Curvature Design: 2M-39PB1 Database: OAKEDMPI 'roject Kupamk River Unit, North Slope Alaska, United States lap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level iso Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor WON 210-39 ACTUAL Depth From (TVD) +N/S Well Position +N/S 0.00 usft Northing: 5,948,985.25 usft +E/ -W 0.00 usft Easting: 487,969.82 usft Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Wellbore 2M-39PB1 Magnetics Model Name BGGM2018 Design 2M-39PB1 Audit Notes: Version: 1.0 Vertical Section: Sample Date 5/1/2019 Declination (1) Phase: ACTUAL Depth From (TVD) +N/S (usft) (usft) 36.75 0.00 16,49 Latitude: Longitude: Ground Level Dip Angle 80.79 Tie On Depth: +E/ -W (usf) 0.00 36 75 Direction (1) 267.94 70' 16'18.574 N 150° 5'50.270 W 100.70 usft Field Strength (nn 57,406 Description Survey Date Gyrodata gyro single shots 4/27/2019 E OWSG MWD +IFR2+Sag +Mufti -Station Comed4/28/2019 E OWSG MWD - Standard 4/28/2019 E OWSG MWD + IFR2 + Sag + Multi -Station Corrocl5/2/2019 8: Survey Survey Program Dab From To (usft) (usft) Survey (Wellbore) Tool Name 71.94 1,440.40 2M-39 Srvy 1 -SLB GWD70 (2M-39PB7) GYD-GC-SS 1,480.76 2,701.242M-39 Srvy 2- SLB _MWD+GMAG(2M-3 MWD+IFR2+SAG+MS 2,741.40 2,809.37 210-39 Srvy 3-SLB_MWD+SAG (2M-39 MWD OWSG 2,903.00 15,728.44 2M-39PB1 Srvy 1-SLB_MWD+GMAG ( MWD+IFR2+SAG+MS Latitude: Longitude: Ground Level Dip Angle 80.79 Tie On Depth: +E/ -W (usf) 0.00 36 75 Direction (1) 267.94 70' 16'18.574 N 150° 5'50.270 W 100.70 usft Field Strength (nn 57,406 Description Survey Date Gyrodata gyro single shots 4/27/2019 E OWSG MWD +IFR2+Sag +Mufti -Station Comed4/28/2019 E OWSG MWD - Standard 4/28/2019 E OWSG MWD + IFR2 + Sag + Multi -Station Corrocl5/2/2019 8: Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/.S +EI -W Northing Easting DLS Section (usft) (') (1) (usft) (usft) (MR) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 36.75 0.00 0.00 36.75 -100.70 ODD 0.00 5998,985.25 487,969.82 0.00 0.00 UNDEFINED 71.94 0.00 0.00 71.94 65.51 0.00 0.00 5,998985.25 487,96982 0.00 0.00 GYD-GCSS(1) 171.07 0.21 333.54 171.07 33.62 0.16 -0.08 5,948,985.41 487,969.74 0.21 0.13 GYD-GCSS(1) 226.10 1.83 313.51 226.09 88.64 0.86 -0.76 5,948,986.11 487,969.06 2.97 0.99 GYD-GCSS(1) 319.16 3.19 312.36 319.06 181.61 3.63 5.75 5,948,988.88 487,966.07 1.46 4.69 GYD-GC-SS(1) 411.70 4.13 313.95 411.41 273.% 7.67 6.06 5,948,992.94 487,961.78 1.02 10.03 GYD-GC-SS(1) 501.72 4.73 315.09 501.16 363.71 12.55 -13.01 5,948,997.82 487,956.83 0.67 16.24 GYD-GCSS(1) 594.05 4.95 315.18 593.16 455.71 18.07 -16.51 5,949,003.35 487,951.35 0.24 23.17 GYD-GCSS(1) 687.40 5.31 310.96 686.14 548.69 23.76 -24.61 5,949,009.05 487,945.25 0.56 30.73 GYD-GCSS(1) 782.58 6.67 308.85 780.79 643.34 30.12 52.24 5,949,015.41 487,937.63 1.45 39.95 GYD-GCSS(1) 876.81 8.98 305.85 674.14 736.69 37.86 42.46 5,949,023.17 487,927.42 2.49 52.06 GYDGCSS(1) 7/182019 1:42:100M Page 2 COMPASS 5000.14 Build 850 ConocoPhillips Definifive Survey Report Company: NADConversion Local Coordinate Reference: Well 2M-39 Project: Kuparuk River Unit TVD Reference: 2M-39 actual @ 137.45usft (D19) Site: Kuparuk 2M Pad MO Reference: 21VI-39 actual @ 137.45us0 (D19) Well: 2M-39 North Reference: True Wellbore: 2M-39PB1 Survey Calculation Method: Minimum Curvature Design: 2M39PB1 Database: OAKEDMPI Survey 71182019 1:42:10PM Page 3 COMPASS 5000.14 Build 85D Map Map vertical MD Inc AN TVD TVDSS +W.S +E/4N Northing Eastlng DLS Section (usft) (1) (1 (uslp Wait) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tooi Name 969.49 8.62 302.17 965.73 828.28 45.79 54.20 5,949,031.13 487,915.70 0.72 65.67 GYD-GC-SS(1) 1,063.92 9.45 300.67 1,058.99 921.54 53.52 56.86 5,949,038.87 487,903.05 0.91 80.09 GYD-GC-SS(1) 1,158.79 10.02 296.10 1,152.49 1,015.04 61.12 50.97 5,949,046.49 487,868.95 1.01 95.86 GYD-GGSS(1) 1,252.39 11.51 293.73 1,244.44 1,106.99 68.46 -96.83 5,949,053.86 487,873.11 1.66 113.21 GYD-GCSS(1) 1,346.63 11.95 293.38 1.336.72 1,199.27 76.12 -114.40 5,949,061.54 487,855.56 0.47 132.28 GYD-GCSS(1) 1,440.40 16.52 292.68 1,427.58 1,290.13 85.11 -135.62 5,949,070.57 487,834.35 4.88 155.24 GYD-GCSS(1) 1,480.76 16.81 291.47 1,466.25 1,328.80 89.6 -145.35 5,949,074.94 487,823.63 1.12 166.79 MWD+IFR2+SAG+MS(2) 1,574.22 17.04 291.18 1,555.66 1,418.21 99.36 -171.69 5,949,084.87 487,798.31 0.26 193.95 MVVD+IFR2+SAG+MS(2) 1,667.73 18.34 291.24 1,644.75 1,507.30 109.64 -198.18 5,94$095.19 487,771.84 1.39 222.32 MV4D+IFR2+SAG+MS(2) 1,762.47 22.33 289.8 1733.56 1,596.11 121.04 -229.05 5,949,106.65 481740.98 4.26 255.20 MWD+IFR2+SAG+MS(2) 1,855.43 22.45 290.11 1,819.52 1,682.07 133.03 -262.37 5,949,118.69 487,707.69 0.29 290.59 MWD+IFR2+SAG+MS(2) 1,950.29 24.48 289.06 1,906.53 1,769.08 145.68 -297.% 5,949,131.39 487,672.13 2.18 328.34 MWD+IFR2+SAG+MS(2) 2,045.6 26.31 286.48 1,992.50 1,855.06 158.11 336.82 5,949143.88 487,633.28 2.25 369.15 MWD+IFR2+SAG+MS (2) 2,138.26 27.67 284.53 2,075.19 1,937.74 169.35 377.41 5,949,155.18 487,592.72 1.75 411.22 MWD+IFR2+SAG+MS(2) 2,233.00 31.64 281.72 2,157.51 2,020.06 179.92 423.05 5,949,16583 487,547.10 4.44 457.90 MWD+IFR2+SAG+MS(2) 2,327.60 33.16 281.69 2,237.38 2,099.93 190.20 -072.68 5,949,176.19 487,497.49 1.61 508.29 MWD+IFR2+SAG+MS(2) 2,421.% 35.33 281.43 2,314.88 2,177.43 200.77 524.37 5,949,186.84 487,445.82 2.32 560.72 MWD+IFR2+SAG+MS(2) 2,515.39 38.80 278.70 2,389.91 2252.46 210.62 580.16 5,949,196.77 487,390.05 4.08 616.83 MWD+IFR2+SAG+MS(2) 2,609.30 42.13 277.73 2,461.35 2,323.90 219.31 540.48 5,949,205.56 487,329.76 3.61 676.89 MWD+IFR2+SAG+MS(2) 2,701.24 42.38 276.91 2,529.40 2,391.95 227.18 -701.80 5,949,213.53 487,268.46 0.66 737.65 MWD+IFR2+SAG+MS(2) 2,741.40 42.14 276.88 2,559.12 2,421.67 230.43 -728.61 5,949,216.82 487,241.65 0.60 764.16 MWD OWSG(3) 2,809.37 42.41 274.99 2,609.41 2,471.96 235.15 -774.08 5,949,221.61 487,196.19 1.91 808.88 MWD OWSG(3) 2,903.00 43.63 276.87 2,677.87 2,540.42 241.76 437.61 5,949,228.33 487,132.68 1.89 871.35 MWD+IFR2+SAG+MS(4) 2,935.79 44.95 276.50 2,701.34 2,563.89 244.43 560.35 5,949,231.03 487,109.95 4.10 893.81 MWD+IFR2+SAG+MS (4) 3,029.52 47.89 275.08 2,765.95 2,628.50 251.25 527.90 5,949,237.96 487,042.42 3.32 960.17 MWD+IFR2+SAG+MS(4) 3,122.65 51.37 272.53 2,826.27 2,688.82 255.92 -998.67 5,949,242.74 486,971.66 4.28 1,028.95 MWD+IFR2+SAG+MS(4) 3,218.14 64.95 269.28 2,883.52 2,746.07 257.8 -1,075.06 5,949,244.02 486,895.28 4.63 1,101.97 MWD+IFR2+SAG+MS(4) 3,313.83 59.00 266.72 2,935.67 2,798.22 254.24 -1,155.21 5,949,241.31 486,815.13 4.79 1,177.35 MWD+IFR2+SAG+MS(4) 3,407.56 62.91 265.03 2,981.17 2,843.72 248.32 -1,235.92 5,949,235.52 486,733.42 4.46 1,253.26 MWD+IFR2+SAG+MS(4) 3,501.99 66.61 264.46 3,021.43 2,883.99 240.49 -1,321.96 5,949,227.83 486,648.38 3.96 1,331.76 MWD+IFR2+SAG+MS(4) 3,596.30 70.25 263.94 3,056.09 2,918.64 231.63 -1,409.20 5,949,219.10 486,561.13 3.89 1,412.02 MWD+IFR2+SAG+MS(4) 3,691.22 75.01 261.91 3,084.43 2,946.98 220.45 -1,499.07 5,949,208.07 486,471.26 5.41 1494.08 MWD+IFR2+SAG+MS(4) 3,784.84 78.50 259.92 3,105.88 2,968.43 206.05 -1,589.03 5,949,193.82 485381.28 4.26 1,575.23 MWD+IFR2+SAG+MS(4) 3,877.84 77.82 259.42 3,124.96 2,987.51 189.73 -1,678.58 5,949,177.65 486,291.72 0.90 1,655.40 MWD+IFR2+SAG+MS(4) 3,972.65 77.80 257.94 3,144.98 3,007.53 171.54 -1,769.44 5,949,159.60 486,200.83 L53 1,736.24 MWD+IFR2+SAG+MS(4) 4,066.97 78.01 257.62 3,164.74 3,027.29 152.02 -1,859.58 5,949,140.23 486,110.67 0.40 1,815.98 MWD+IFR2+SAG+MS(4) 4,161.31 77.95 256.66 3,184.39 3,046.94 1WAS -1,949.54 5,949,119.84 486,020.69 1.00 1,895.24 MWD+IFR2+SAG+MS(4) 4,255.27 77.92 255.77 3,204.03 3,066.58 109.59 -2,038.77 5,949,098.9 485,931.43 0.93 1,973.39 MWD+IFR2+SAG+MS(4) 4,349.29 77.95 255.69 3,223.68 3,086.23 86.93 -2,127.88 5,949,075.57 485,842.30 0.09 2,051.18 MWD+IFR2+SAG+MS(4) 4,443.79 78.04 256.04 3,243.34 3,105.89 64.35 -2217.51 5,949,053.14 485,752.63 0.37 2,129.51 MWD+IFR2+SAG+MS(4) 71182019 1:42:10PM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2M-39 Project: Kuparuk River Unit TVD Reference: 2M-39 actual @ 137.45usft (D19) Site: Kuparuk 2M Pad MD Reference: 2M-39 actual @ 137.45usft (D19) Well: 2M-39 North Reference: True Wellbore: 2M -39P81 Survey Calculation Method: Minimum Curvature Design: 2M-39PB1 Database: OAKEDMPI Survey Map Map Vertical MD Inc AN TVD TVDSS +NIS +E/ -W Northing Easting DLS Section (usft) r) r) (usft) (waft) (usft) (uaR) (It) (ft) (01100') (ft) Survey Tool Name 4,537.95 78.10 257.39 3,262.80 3,125.35 43.19 -2,307.17 5,949,032.12 485,552.95 1.40 2,208.28 MWD+IFR2+SAG+MS(4) 4,631.89 77.98 258.03 3,282.27 3,144.82 23.62 -2,396.97 5,949,012.70 485,573.13 0.68 2,287.69 MWD+IFR2+SAG+MS(4) 4,725.12 78.01 258.08 3,301.66 3,164.21 4.75 -2,486.18 5,948,993.97 485,483.90 0.06 2,366.75 MWD+IFR2+SAG+MS (4) 4,818.28 77.98 257.91 3,321.04 3,183.59 -14.20 -2,575.31 5,948,975.16 485,394.75 0.18 2,445.71 MWD+IFR2+SAG+MS(4) 4,912.34 77.99 258.39 3,340.62 3,203.17 -33.10 -2.665.35 5,948,956.42 485,304.69 0.50 2,525.55 MM+IFR2+SAG+MS (4) 5,006.13 77.56 258.50 3,360.48 3,223.03 51.46 -2,755.16 5,948,930.20 485,214.86 0.47 2,605.33 MWD+IFR2+SAG+MS (4) 5,100.36 77.42 259.65 3,380.89 3,243.4 58.89 -2,845.48 5,948,920.91 485,124.52 1.20 2,685.89 MWD+IFR2+SAG+MS(4) 5,194.36 77.58 261.11 3,401.24 3,263.79 -84.23 -2,935.95 5,948,905.72 485,034.02 1.53 2,767.25 MWD+IFR2+SAG+MS(4) 5,289.15 77.13 262.29 3,421.99 3,284.54 -97.58 3,027.48 5,948,892.52 484,942.49 1.30 2,850.20 MWD+IFR2+SAG+MS(4) 5,383.35 76.94 263.80 3,443.12 3,305.67 -108.70 -3,118.60 5,998,881.55 48.851.36 1.58 2,933.47 MWD+IFR2+SAG+MS(4) 5,477.42 77.33 264.61 3,464.07 3,326.62 -117.95 -3,209.84 5,948,872.44 48.760.12 0.94 3,017.42 MWD+IFR2+SAG+MS(4) 5,571.89 76.79 263.78 3,485.22 3,347.77 -127.27 -3,301.44 5,948,863.27 484,668.52 1.03 3,101.69 MWD+IFR2+SAG+MS(4) 5,666.03 76.99 263.14 3,506.58 3,369.13 -137.71 3,392.52 5,948,852.98 484,577.42 0.70 3,185.14 MWD+IFR2+SAG+MS(4) 5,760.33 77.01 263.12 3,527.79 3,390.34 -148.70 -3,483.75 5,948,842.13 484,486.19 0.03 3,268.54 MWD+IFR2+SAG+MS(4) 5,854.94 77.11 262.59 3,548.97 3,411.52 -160.17 -3,575.24 5,948,830.81 48.394.69 0.56 3,352.05 MWD+IFR2+SAG+MS (4) 5,948.34 76.88 261.71 3,569.99 3,432.54 -172.59 -3,665.36 5,948,818.53 484,304.55 0.95 3,433.96 MWD+IFR2+SAG+MS (4) 6,043.31 77.08 261.76 3,591.39 3,453.94 -185.90 3,756.96 5,948,805.37 484,212.95 0.22 3,517.00 MWD+IFR2+SAG+MS(4) 6,136.84 77.01 262.20 3,612.36 3,474.91 -198.62 -3,847.21 5,948,792.80 484,122.68 0.46 3,598.95 MWD+IFR2+SAG+MS(4) 6,231.35 76.92 262.17 3,633.67 3,496.22 -211.14 -3,938.43 5,948,780.43 484,031.45 0.10 3,681.88 MWD+IFR2+SAG+MS(4) 6,325.38 76.92 262.48 3,654.95 3,517.50 -223.37 -0,029.20 5,948,768.34 483,940.67 0.32 3,764.47 MWD+IFR2+SAG+MS(4) 6,419.86 77.01 263.16 3,676.26 3,538.81 -234.87 -0,120.53 5,948,756.99 463,849.33 0.71 3,847.81 MWD+IFR2+5AG+MS(4) 6,514.22 77.10 261.33 3,697.40 3,559.95 -247.28 4,211.64 5,948,744.73 483,758.21 1.89 3,930.67 MWD+IFR2+SAG+MS (4) 6,607.82 77.07 260.87 3,718.32 3,580.87 -261.40 4,301.78 5,948,730.76 483,658.06 0.48 4,012.07 MWD+IFR2+SAG+MS(4) 6,702.67 77.48 260.42 3,739.22 3,601.77 -276.43 -4,393.07 5,948,715.86 483,576.76 0.63 .094.29 MWD+IFR2+SAG+MS(4) 6,796.71 76.85 259.44 3,760.11 3,622.66 -292.47 4,4BIM 5,948,699.98 483,486.46 1.22 4,175.24 MWD+IFR2+SAG+MS(4) 6,891.31 76.93 260.20 3,781.57 3,644.12 -308.75 4,574.03 5,948,683.89 483,395.76 0.79 4,256.50 MWD+IFR2+SAG+MS(4) 6,985.09 77.05 260.68 3,802.68 3,665.23 -323.92 -4,664.13 5,948,668.81 483,305.65 0.51 4,337.55 MWD+IFR2+SAG+MS(4) 7,079.01 76.95 260.66 3,823.80 3,686.35 -338.76 4,754.43 5,948,654.12 483,215.33 0.11 4,418.89 MWD+IFR2+SAG+MS(4) 7,173.21 77.04 260.89 3,845.00 3,707.55 353.47 -0,845.03 5,948,639.56 483,124.72 0.26 4,500.54 MWD+IFR2+SAG+MS(4) 7,266.04 77.07 261.20 3,865.80 3,728.35 -367.56 4,934.40 5,948,625.62 483,035.34 0.33 4,581.23 MWD+IFR2+SAG+MS(4) 7,360.55 77.01 260.51 3,886.99 3,749.54 -382.20 5,025.M 5,948,611.13 482,944.39 0.71 4,663.23 MWD+IFR2+SAG+MS(4) 7,455.32 77.14 261.02 3,908.19 3,770.74 -397.02 5,116.50 5,948,596.45 482,853.20 0.54 4,745.40 MW13+IFR2+SAG+MS(4) 7,549.52 76.92 260.55 3,929.33 3,791.88 411.72 5,2D7.11 5,948,581.90 982,762.58 0.54 4,827.08 MWD+IFR2+SAG+MS(4) 7,643.41 77.04 261.21 3,950.49 3,813.04 426.22 5,297.43 5,948,567.54 482,672.25 0.70 4,908.54 MWD+IFR2+SAG+MS(4) 7,736.63 77.16 261.0 3,971.30 3,833.85 -040.27 5,387.20 5,948,553.64 482,582.6 0.25 4,989.62 MWD+IFR2+SAG+MS(4) 7,831.21 77.16 262.18 3,992.32 3,854.87 45375 5,478.42 5,948,540.30 482,491.22 1.22 5,072.25 MWD+IFR2+SAG+MS(4) 7,925.69 76.98 261.68 4,013.46 3,876.01 466.68 -5,569.60 5,948,527.52 482,400.4 0.55 5,155.01 MWD+IFR2+SAG+MS (4) 8,019.50 77.02 261.66 4,034.56 3,897.11 479.92 5,660.04 5,948,514.42 482,309.59 0.05 5,236.97 MWD+IFR2+SAG+MS (4) 8,113.09 77.04 262.13 4,055.57 3,918.12 -092.78 5,750.33 5,948,501.71 482,219.28 0.49 5,318.91 MWD+IFR2+SAG+MS(4) 8,208.28 7208 261.48 4,076.88 3,939.43 -M6.01 5,842.15. 5,948,488.63 462,127.45 0.67 5,402.20 MWD+IFR2+8AG+MS(4) 7/162019 1:42:10PM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 214-39 Project: Kuparuk River Unit TVD Reference: 2M-39 actual @ 137.45usft (D19) Site: Kuparuk 2M Pad MD Reference: 2M-39 actual @1137.45usft (1)19) Well: 21M-39 North Reference: True Wellbore: 2M-39PB1 Survey Calculation Method: Minimum Curvature Design: 2M-39PB1 Database: OAKEDMPI Survey 711WO19 1:42:10PM Page 5 COMPASS 5000.14 Build 85D Map Map Vertical MD Inc Azl ND NDSB +WS +EI -W Northing Easting OLS Section (usft) (') (') (usft) (ustq (usfq (uslt) (ft) (ft) (.1100') (ft) Survey Tool Name 8,302.64 76.89 261.88 4,098.13 3,960.68 519.31 5,933.12 5,948,475,48 482,036.47 0.46 5,484.64 MND+IFR2+SAG+MS (4) 8,396.82 77.01 261.82 4,119.40 3,981.95 532.32 -6,023.94 5,948,462.62 481,945.63 0.14 5,567.04 MWD+IFR2+SAG+MS (4) 8,490.69 77.16 262.28 4,140.38 4,002.93 544.97 41,114.56 5,948,450.11 481,855.01 0.50 5,649.35 MWD+IFR2+SAG+MS(4) 8,585.10 76.98 261.15 4,161.51 4,024.06 558.23 -6,205.61 5,948,437.00 481,763.94 1.18 5,731.90 MWD+IFR2+SAG+MS(4) 8,678.38 76.92 261.57 4,182.57 4,045.12 -571.88 -6,295.45 5,948,423.49 481,674.09 0.44 5,813.16 MWD+IFR2+SAG+MS(4) 8,772.44 77.08 261.81 4,203.73 4,066.28 585.13 -6,386.14 5,948,410.39 481,583.39 0.30 5,895.36 MWD+IFR2+SAG+MS(4) 8,866.83 76.94 261.49 4,224.95 4,087.50 598.48 41,477.14 5,948,397.18 481,492.38 0.36 5,977.82 MWD+IFR2+SAG+MS(4) 8,960.48 77.32 262.41 4,245.81 4,108.36 511.27 -6,567.54 5,94$384.54 181401.97 1.04 6,059.88 MWD+IFR2+SAG+MS(4) 9,055.48 77.21 261.62 4,266.75 4,129.30 4124.14 41,659.30 5,948,371.82 481,310.20 0.82 6,143.22 MWD+IFR2+SAG+MS (4) 9,149.42 77.21 262.54 4,287.54 4,150.09 -636.76 -6,750.03 5,948,359.34 481,219.45 0.96 6,225.65 MWD+IFR2+5AG+MS(4) 9,244.37 77.22 261.39 4,308.56 4,171.11 -649.70 -6,841.72 5,948,346.55 481,127.75 1.18 6,308.89 MWD+IFR2+SAG+MS(4) 9,337.83 77.17 261.65 4,329.27 4,191.82 563.14 -6,931.86 5,948,333.25 481,037.60 0.28 6,390.51 MWD+IFR2+SAG+M$(4) 9,430.96 77.03 262.21 4,350.06 4,212.61 -675.89 -7,021.74 5,948,320.65 480,947.71 0.61 6,472.09 MWD+IFR2+SAG+MS(4) 9,525.84 77.19 262.03 4,371.23 4,233.78 -688.57 -7,113.35 5,948,308.12 480,856.08 0.25 6,555.35 MWD+IFR2+SAG+M$(4) 9,619.15 77.19 261.36 4,391.92 4,254.47 -701.71 -7,203.39 5,948,295.12 480,766.04 0.70 6,636.95 MWD+IFR2+SAG+MS(4) 9,713.33 77.29 261.30 4,412.72 4,275.27 -715.56 -7,294.19 5,948,281.42 480,675.22 0.12 6,719.08 MND+IFR2+SAG+MS (4) 9,807.72 77.16 260.73 4,433.59 4,296.14 -729.93 -7,385.11 5,948,267.19 480,584.29 0.60 6,801.15 MWD+IFR2+SAG+MS(4) 9,901.72 77.10 260.33 4,450.53 4,317.08 -745.01 -7,475.50 5,948,252.26 480,493.88 0.42 6,882.50 MWD+IFR2+SAG+MS(4) 9,995.65 76.95 260.20 4,475.62 4,338.17 -760.49 -7,56572 5,948,236.93 480,403.65 0.21 6,963.56 MWD+IFR2+SAG+MS(4) 10,090.04 76.90 259.82 4,496.97 4,359.52 -776.44 -7,656.27 5,948,221.13 480,313.09 0.40 7,004.79 MWD+IFR2+SAG+MS(4) 10,184.84 76.93 259.42 4,518.43 4,380.98 -793.07 -7,747.09 5,948,204.64 480,222.24 0.41 7,126.08 MWD+IFR2+SAG+MS(4) 10,279.14 76.93 259.40 4,539.76 4,402.31 -809.96 -7,837.39 5,948,187.90 480,131.93 0.02 7,206.78 MWD+IFR2+SAG+MS(4) 10,373.25 76.96 259.28 4,561.02 4,423.57 926.91 -7,927.48 5,948,171.09 480,041.82 0.13 7,287.27 MWD+IFR2+SAG+MS (4) 10,467.03 76.96 259.70 4,6a2.18 4,444.73 943.58 -8,017.31 5,948,154.57 479,951.97 0.44 7,367.60 MWD+IFR2+SAG+MS (4) 10,560.99 76.89 259.54 4,603.43 4,465.98 4160.07 9,107.34 5,948,138.23 479,861.93 0.18 7,448.17 MWD+IFR2+SAG+MS(4) 10,655.18 76.90 259.35 4,624.79 4,487.34 976.87 -8,197.52 5,948,121.57 479,771.73 0.20 7,528.79 MWD+IFR2+$AG+M$(4) 10,748.15 77.05 259.48 4,645.74 4,508.29 -893.51 -8,286.56 5,948,105.07 479,682.67 0.21 7,608.37 MWD+IFR2+SAG+MS(4) 10,841.88 77.01 259.38 4,666.78 4,529.33 910.27 9,376.35 5,948,088.46 479,592.87 0.11 7,688.63 MWD+IFR2+SAG+MS(4) 10,936.86 77.21 259.66 4,687.97 4,550.52 -827.11 -8,467.39 5,948,071.77 479,501.81 0.36 7,770.06 MWD+IFR2+SAG+MS(4) 11,030.88 76.61 260.21 4,709.26 4,571.81 -943.11 9,557.56 5,948,055.91 479,411.62 0.86 7,850.91 MWD+IFR2+SAG+MS (4) 11,125.17 77.06 261.19 4,730.74 4,593.29 -957.95 -8,648.16 5,948,041.22 479,321.00 1.12 7,932.54 MWD+IFR2+SAG+MS (4) 11,219.13 76.89 262.02 4,751.91 4,614.46 -971.31 9,738.72 5,948,028.00 479,230.43 0.88 8,014.58 MND+IFR2+SAG+MS (4) 11,313.72 76.96 261.40 4,773.31 4,635.86 +484.60 9,829.89 5,948,014.86 479,139.24 0.64 8,097.23 MWD+IFR2+SAG+MS(4) 11,408.11 77.02 261.35 4,794.66 4,657.11 598.39 -8,920.82 5,948,001.22 479,048.30 0.08 8,179.49 MWD+IFR2+SAG+MS(4) 11,502.03 76.76 261.19 4,815.86 4,678.41 -1,012.27 9,011.23 5,947,987.48 478,957.88 0.32 8,261.22 MWD+IFR2+SAG+MS(4) 11,596.00 76.99 262.32 4,837.20 4,699.75 -1,025.40 -9,101.80 5,947,974.50 478,867.30 1.20 8,343.35 MWD+IFR2+SAG+MS(4) 11,690.70 77.27 262.48 4,858.30 4,720.85 -1,037.61 -9,193.31 5,947,962.44 478,775.78 0.34 8,426.64 MND+IFR2+SAG+MS(4) 11,784.14 76.95 262.19 4,879.14 4,741.69 -1,049.76 -9,283.58 5,947,950.44 478.685.50 0.46 8,508.78 MND+IFR2+SAG+MS (4) 11,879.07 76.96 262.40 4,900.57 4,763.12 -1,062.16 -9,375.23 5,947,938.19 478,593.84 0.22 8,592.15 MWD+IFR2+SAG+MS(4) 11,971.91 77.11 262.53 4,921+40 4,783.95 -1,074.02 -9,464.92 5,947,926.47 478,504.14 0.21 8.673+83 MWD+IFR2+SAG+MS (4) 711WO19 1:42:10PM Page 5 COMPASS 5000.14 Build 85D ConocoPhillips Definitive Survey Report Company: NADConversion Local Coordinate Reference: Well 2M-39 project: Kuparuk River Unit TVD Reference: 2M-39 actual @ 137.45usft (D19) SRO: Kuparuk 2M Pad MD Reference: 2M-39 actual @ 137.45usft (D19) Wan: 2M39 North Reference: True Wellbore: 2M39PB1 Survey Calculation Method: Minimum Curvature Design: 2M-39PB1 Database: CAKEDMP7 Survey Map Map Vertical MD Inc Azi TVD TVDSS +WS +E/ -W Northing Seating DLS Section (usft) (`) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°I100-) (ft) Survey Tool Name 12,066.44 76.88 261.96 4,94267 4,805.22 -1,086.45 3,556.18 5,947,914.19 478,412.87 0.64 8,756.83 MWD+IFR2+SAG+MS(4) 12,160.11 77.44 262.17 4,%3.49 4,826.04 -1,099.06 41,646.63 5,947,901.72 478,322.40 0.64 8,839.00 MV4D+IFR2+SAG+MS(4) 12,254.23 77.12 260.63 4,984.21 4,84676 -1,11278 -9,737.41 5,947,888.14 478,231.62 1.63 8,921.13 MWD+IFR2+SAG+MS(4) 12,348.14 77.04 260.62 5,005.21 4,867.76 -1,127.69 -9,827.72 5,947,873.38 478,141.29 0.09 9,002.45 MV4D+IFR2+SAG+MS(4) 12,442.22 76.92 260.74 5,026.40 4,888.95 -1,142.54 -9,918.17 5,947.858.68 478,050.83 0.18 9,083.93 MWD+IFR2+SAG+MS(4) 12,536.52 77.05 261.09 5,047.64 4,910.19 -1,157.05 -10,008.90 5,947,844.32 477,960.09 0.39 9,165.78 MWD+IFR2+SAG+MS(4) 12,630.84 76.86 260.42 5,068.93 4,931.48 -1,171.81 -10,099.59 5,947,829.70 477,869.38 0.72 9,247.51 MWD+IFR2+SAG+MS(4) 12,724.66 76.93 261.05 5,090.20 4,952.75 -1,186.52 -10,189.77 5,947,815.14 4]],779.18 0.66 9,328.78 MWD+IFR2+SAG+MS(4) 12,819.19 76.80 260.83 5,111.69 4,974.24 -1,201.01 -10,280.68 5,947,800.79 477.668.26 0.27 9,410.80 MWD+IFR2+SAG+MS (4) 12,913.02 77.05 262.17 5,132.91 4,995.46 -1,214.52 -10,371.07 5,947,787.43 477,597.86 1.42 9,492.64 MWD+IFR2+SAG+MS(4) 13,008.40 76.96 262.07 5,154.36 5,016.91 -1,227.26 40,463.13 5,947,774.83 477,505.79 0.14 9,576.29 MWD+IFR2+SAG+MS(4) 13,102.75 76.89 262.02 5,175.71 5,038.26 4,239.98 -10,554.15 5,947,762.26 477,414.76 0.09 9,658.97 MWD+IFR2+SAG+MS(4) 13,197.15 77.08 262.77 5,196.97 5,059.52 -1,252.16 -10,645.32 5,947,750.24 477,323.58 0.80 9,741.95 MWD+IFR2+SAG+MS(4) 13,291.29 77.08 262.00 5,218.01 5,080.55 -1,264.31 -10,736.26 5,947,738.22 477,232.62 0.80 9,824.73 MWD+IFR2+5AG+MS(4) 13,385.62 77.05 262.10 5,239.13 5,101.68 -1,277.03 -10,827.31 5,947,725.65 477,141.56 0.11 9,907.44 MWD+IFR2+SAG+MS(4) 13,478.78 77.01 262.10 5,260.04 5,122.59 -1,289.51 -10,917.24 5,947,713.32 477,051.63 0.04 9,989.15 MWD+IFR2+SAG+MS(4) 13,572.95 77.14 262.03 5,261.10 5.143.65 -1,302.18 -11,008.14 5,947,700.80 476,960.71 0.16 10,071.73 MWD+IFR2+SAG+MS(4) 13,667.33 76.91 262.17 5,302.29 5,164.84 -1,314.82 -11,099.24 5,947,688.30 476,869.60 0.28 10,154.50 MWD+IFR2+SAG+MS(4) 13,761.11 77.32 262.24 5,323.21 5,185.76 -1,327.22 -11,189.81 5,947,676.05 476,779.02 0.44 10,236.85 MWD+IFR2+SAG+MS(4) 13,856.76 77.28 262.33 5,344.23 5,206.78 -1,339.74 -11,282.28 5,947,663.67 476,686.54 0.10 10,320.% MWD+IFR2+SAG+MS (4) 13,949.55 77.28 261.43 5,364.67 5,227.22 -1,352.53 -11,371.88 5,947,651.03 476,596.93 0.95 10,402.27 MWD+IFR2+SAG+MS (4) 14,043.63 77.16 261.54 5,385.48 5,248.03 -1,356.11 -11,462.62 5,947,637.59 476,506.18 0.17 10,484.41 MWD+IFR2+SAG+MS (4) 14,137.49 77.07 260.18 5,406.41 5,268.96 -1,380.65 -11,552.95 5,947,623.21 476,415.83 1.42 10,565.87 MWD+11`112+SAG+MS(4) 14,231.25 77.11 260.18 5,427.36 5,289.91 -1,396.23 -11,643.00 5,947,607.77 476,325.76 0.04 10,646.74 MWD+IFR2+SAG+MS(4) 14,325.16 76.98 259.86 5,448.41 5,310.96 -1,412.10 -11,733.14 5,947,592.05 476,235.61 0.36 10,727.61 MWD+IFR2+SAG+MS(4) 14,419.87 77.19 260.14 5,469.58 5,332.13 -1,428.13 -11,824.05 5,947,576.17 476,144.68 0.35 10,809.16 MWD+IFR2+SAG+MS(4) 14,513.67 77.19 259.23 5,490.37 5,352.92 -1,444.60 -11,914.04 5,947,559.94 476,054.68 0.95 10,889.73 MWD+IFR2+SAG+MS(4) 14,607.09 77.20 260.33 5,511.08 5,373.63 -1,460.67 -12,003.69 5,947,543.92 475,965.01 1.15 10,970.04 MWD+IFR2+SAG+MS(4) 14,701.20 77.70 258.55 5,531.53 5,394.08 -1,477.50 -12,093.99 5,947,527.23 475,874.69 1.92 11,050.76 MWD+IFR2+SAG+MS (4) 14,795.47 77.80 256.32 5551.54 5,414.09 -1,497.54 -12,183.90 5,947,507.33 475,784.76 2.31 11,130.13 MWD+IFR2+SAG+MS(4) 14,888.87 77.07 254.81 5,571.86 5,434.41 -1,520.26 -12,272.18 5,947,484.75 475,696.45 1.76 11,207.12 MWD+IFR2+SAG+MS(4) 14,983.33 75.26 250.81 5,594.45 5,457.00 -1,547.35 -12,359.78 5,947,457.81 475,608.81 4.54 11,282.12 MWD+IFR2+SAG+MS (4) 15,077.35 74.25 246.49 5,619.10 5,481.73 -1,580.36 -12,444.25 5,947,424.94 475,524.30 4.56 11,352.31 MWD+IFR2+SAG+MS(4) 15,172.04 75.24 243.29 5,641.10 5,506.65 -1,619.13 -12,526.95 5,947,386.31 475,441.55 3.42 11,419.05 MWD+IFR2+SAG+MS(4) 15,265.96 75.46 239.04 5,667.87 5,530.42 -1,662.94 -12,6%.53 5,947,342.63 475,361.91 4.38 11,481.26 MWD+IFR2+SAG+MS(4) 15,360.37 75.70 235.51 5,691.39 5,553.94 -1,712.36 -12,683.44 5,947,293.33 475,284.93 3.63 11,539.21 MWD+IFR2+SAG+MS(4) 15,454.81 75.58 231.66 5,714.82 5,577.37 -1,766.66 -12,757.05 5,947,239.16 475,211.24 3.95 11,592.51 MWD+IFR2+SAG+MS (4) 15,548.98 75.16 226.95 5,738.61 5,601.16 -1,826.05 -12,826.11 5,947,179.88 475,142.08 4.86 11.639.92 MWD+IFR2+SAG+MS(4) 15,642.38 75.18 222.44 5,762.53 5,625.08 -1,890.22 -12,889.60 5,947,115.83 475,078.50 4.67 11,680.55 MWD+IFR2+SAG+MS(4) 15,728.44 75.59 216.98 5,784.25 5.646.80 -1,953.33 -12,943.90 5,947,052.81 475,024.11 3.92 11,712.78 MWD+IFR2+SAG+MS(4) 7H82019 1:42:1OPM Page 6 COMPASS 5"..14 Build 85D Company: NADConversion Project Kuparuk River Unit Site: Kuparuk 2M Pad Wap: 2M-39 Wellbore: 2M-39PB7 Design: 2M-39PB7 Survey ConocoPhillips Definitive Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map MD Inc Azi TVD TVDSS -MIS +E/ -W Northing (usft) P) (1) (usft) (usft) (usft) (usft) (ft) 15,790.00 75.59 210.98 5,801.56 5,664.11 -2,005.70 -1298628 5,947.000.51 Well 2M-39 2M-39 actual @ 137.45usft (D19) 2M-39 actual @ 137.45usft (D19) True Minimum Curvature OAKEDMPI Map Vertical Easting DLS Section (ft) (°/1001 (f) Survey Tool Name 474,981.65 0.00 11,736.96 PROJECTED to TO 7/16/2019 142: 1OPM Page 7 COMPASS 5000.14 Budd 85D e ., Cement Detail Report LL 2M-39 String: Surface Casing Cement Job: DRILLING ORIGINAL, 4/22/2019 00:00 Cement Details Description Surface Casing Cement Cementing Start Date 5/2/2019 17:23 Cementing Entl Date 5/2/2019 22:15 Wellbore Name 2M-39 Comment PJSM, Line up & SLB pump 5 bbls water. Pressure test lines to 2500 psi, good. Pump 40.2 bbls of CW100 @ 5 bpm, 60 psi, PIU: 255k S/O: 175k. Pump 73.6 bbls of 10.5 ppg MP II @ 4 bpm, 40 psi. Drop bottom plug at 2100hrs & start batching lead. Pump 519.8 bbls of 11.0 ppg lead cement at 5 bpm, 80-140 psi. (MP II at surface with 505 bbls of Lead away) Batch and pump 70.4 bbls of 12 ppg tail cement @ 5 bpm, 80-140 psi. Drop top plug & kick out with 10 bbls of fresh H2O. Swap to rig & displace w/ 9.5 ppg spud mud @ 8 bpm, 510-680 psi, 11 ppg lead cement at surface at 135 bbls of displacement away. Reduced rate to 3bpm 400psi. Bump plug with 406 bbls, Pressure up to 1000 psi & hold for 5 minutes. Bleed off pressure, floats held. CIP 22:09 hrs 05/02/2019. Good 269bbi 11 ppg cement to surface. Full returns. Cement Stages Stage 01 Description Surface Casing Cement jObjective Top Depth IRKS) Cement to Surface 37.5 Bottom Depth (ftKB) 2,860.0 Full Return?Vl Yes Cement... 2069.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bblim... 8 Q Pump Final lbbli... 3 Q Pump Avg (bbll... 6 P Pump Final (psi) 400.0 P Plug Bump (psi) 1,000.0 Recip7 Yes stroke (ft) 130.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) 2,767.0 Tag Method Drill Bit Depth Plug Drilled Out To (ftKB) 2,860.0 1121/4 Drill Out Diameter (in) Comment bumped plug at calc. strokes, reciprocated 7.5' until pumped lead. 241 bbl. cement back to surface. 153.7bbl. losses. floats held, successful cement job. Cement Fluids & Additives Fluid Fluid Type CW100 Fluid Description Estimated Top (ftKB) 0.0 Est Bon (ftKB) 0.0 Amount (sacks) 1 Class Volume Pumped (bbl) 40.2 Yield (W/sack) Mix H2O Ratio (gallas... Free Water (%) Density (Ibigal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type MudPush II Fluid Description ESUmated Top (ftKB) 0.0 Est Btm (ftKB) 0.0 Amount (sacks) Class Volume Pumped (bbl) 80.0 Yield (ft'lsack) Mix H2O Ratio (gallsa... Free Water (%) Density (Ib/gal) Plastic Viscosity (CP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Cone Unft label Fluid Fluid Type Lead Fluid Description Estimated Top (ftKB) 0.0 Est Bor (ftKB) 2,360.0 Amount (sacks) 1,536 Class G Volume Pumped (bbl) 519.8 Yield (ft /sack) 1.90 Mix H2O Ratio (galisa... 6.81 Free Water 1%) Density (lb/gal) 11.00 Plastic Viscosity (cP) Thickening Time (hr) 0.00 Cmpr5tr 1 (psi) Additives Additive Type Concentration Cone Unit label Fluid Fluid Type Tail Fluid Description Estimated Top (ftKB) 2,360.0 Est etm (ftKB) 2,860.0 Amount (sacks) 243 Class G Volume Pumped (bbl) 70.4 Yield Ift /sack) 1.65 Mix H2O Ratio (gallas... 5.57 Free Water (%) Density (Iblgal) 12.00 Plastic Viscosity (CP) Thickening Time (hr) 0.00 CmprStr 1 (psi) Additives Additive Type Concentration Cone Unit label Page 111 Report Printed: 818/2019 Cement Detail Report a 2M-39 String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 4/22/2019 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 6/15/2019 06:00 6/15/2019 1230 2M-39 Comment Dowell pump 5 bbis H2O & PT lines to 3000 psi (good). Pump 61.6 bbis 13.0 ppg Mud push with 5 - 2.5 bpm. Drop bottom plug. Pump 175.3 bbis 15.8 ppg, 1.16 yid Class G tail cement w/5 bpm. Drop 2 top plugs. Pump 10.2 bbls H2O w/4 bpm. Tum over to rig for displacement. Rig pump 1214 bbis 10.3 ppg LSND w/2% 776. Final circulating rate 3 bpm @ 1380 psi. (Hole started packing off 750 bbis into displacement & lost returns 900 bbls into displacement. Started to see minimal returns 1050 bbis into displacement) Bumped plug w/10,200 silks, pressure 500 psi over f/1380 psi to 1880 psi & hold for 5 min. Check floats (good). CIP 12:20 His. Lost total 300 bbis to formation. Cement Stages Stage # 1 Description Objective lTop Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Bum Plug? Intermediate Casing Cement 9-5/8" Casing 13,886.0 16,013.0 No Yes Yes Cement Q Pump ]nit (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbll... P Pump Final (psi) P Plug Bump (psi) IRecip? Stroke (ftt Rotated? Pipe RPM (rpm) 5 3 3 1,380.0 1,880.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Lost returns 900 bbis into displacement. 300 bbis total losses to formation. Cement Fluids & Additives Fluid Fluid Type Fluid Description Eat Top Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement I 13,866.0 15,927.0 847 G 175.2 Yield (ft'/sack) Mix H2O Ratio (gal/sa... Free Water (%1 Density (lb/gal) Plastic Viscosity (OP) Thickening Time (hr) CmprStr i (psi) 1.16 5.0 1 130.6 11.00 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 81812019 e - Cement Detail Report 2M-39 String: Intemediate 2 Liner Cement Job: DRILLING ORIGINAL, 4/22/2019 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intemediate 2 Liner Cement 6/22/2019 07:30 6/22/2019 10:30 2M-39 Comment Dowell pump 5 bbis H2O & PT lines to 3800 psi (good). Pump 47 bbis 13.0 ppg Mud Push, Drop bottom dart, Pump 125 bbis 15.6 ppg, 1.16 yid Class G tail cement, Drop top dart, Pump 10 bbls H2O w/4 - 5 bpm. Tum over to rig for displacement. Rig pump 429 bbis 10.6 ppg LSND. Final circulating rate 3 bpm @ 1050 psi. (Saw bottom dart @ 2945 stks & top dart land @ 3071 stks). Bumped plug w/3635 stks. Pressure up 1500 psi & hold for 5 min. Check floats (good). CIP @ 10:35 Hrs Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Stan Plug? Intemediate 2 Liner Cement Liner 15,786.0 17,895.0 Yes Yes Yes Cement Q Pump Ind (bbl/m... O Pump Final (bbll... O Pump Avg (bbl/...P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 5 3 4 1,050.0 1,500.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Dowell pump 5 bbis H2O & PT lines to 3800 psi (good). Pump 47 bbis 13.0 ppg Mud Push, Drop bottom dart, Pump 125 bbis 15.8 ppg, 1.16 yid Class G tail cement, Drop top dart, Pump 10 bbis H2O w/4 - 5 bpm. Tum over to rig for displacement. Rig pump 429 bbis 10.6 ppg LSND. Final circulating rate 3 bpm @ 1050 psi. (Saw bottom dart @ 2945 stks & top dart land @ 3071 silks). Bumped plug w/3635 stks. Pressure up 1500 psi & hold for 5 min. Check floats (good). CIP @ 10:35 Hrs Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 15,786.0 17,895.0 605 G 125.0 Yield (ft-Isack) Mix H2O Ratio (gallsa... Free Water (%) Density (lblgag Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.00 1 15.80 130.6 6.00 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 81812019 Loepp, Victoria T (CED) From: Sent: To: Cc: Subject: Follow Up Flag: Flag Status: Thanks Victoria. W, proaig-/7-i Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sunday, June 23, 2019 11:21 AM Loepp, Victoria T (CED) Herring, Keith E Re: [EXTERNAL]KRU 2M-39(PTD 218-171) Intermediate 2 Cement Follow up Completed On Jun 23, 2019, at 9:44 AM, Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> wrote: Nick, Looks very good. Approval is granted to proceed as planned. Thanx, Victoria Sent from my iPhone On Jun 23, 2019, at 9:03 AM, Lehman, Nick R <Nick.R.Lehman@conocophillips.com> wrote: Good morning Victoria, We completed the 7" 26# Intermediate 2 liner cementjob yesterday. The cement job information is attached above, the job went very well with full returns, ^220 psi of lift pressure, plugs bumped and floats held. We are currently finishing up laying down the liner running tools. Moving forward, we will be pressure testing BOPE today, then run in hole with the production drilling BHA, log the 7" liner cement with the Sonic tool in recorded mode, and progress with the original drilling plan. Please let me know if you approve of this plan or if you have any questions. Regards, Nick Lehman Drilling Engineer 1 ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehman@ConocoPhillips.com From: Loepp, Victoria T (CED) <yictoria.loepp@alaska.gov> Sent: Thursday, June 20, 2019 11:58 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: Re: [EXTERNAL]KRU 2M-39(PTD 218-171) Intermediate 1 Cement Nick, Cement appears good. Thanx for the log. Victoria Sent from my iPhone On Jun 20, 2019, at 11:04 PM, Lehman, Nick R <Nick R Lehman@conocophillips.com> wrote: Good evening Victoria, We just received the processed cement evaluation log from the SonicVision tool on the 2M-39 Intermediate II drilling BHA; I attached it above. Good cement behind 9-5/8" Intermediate I casing was observed with top of cement picked at 14,500' MD. With the 9-5/8" casing shoe at 16,013' MD / 5,803' TVD, top of cement is 1513' MD / 362' TVD above the shoe. Please let me know if you have any questions or concerns. Currently, we are moving forward with running the 7" Intermediate II liner. Regards, Nick Lehman Drilling Engineer I Conoco Phillips Alaska Office (907)163-4951 1 Cell (832)499-6739 Nick. R. Lehman@ConocoPhilllps. com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Sent: Sunday, June 16, 2019 7:13 AM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: Re: [EXTERNAL]KRU 2M-39(PTD 218-171) Intermediate 1 Cement Nick, Thanx for the cement summary. Approval is granted to proceed as planned. Victoria Sent from my iPhone On Jun 16, 2019, at 2:22 AM, Lehman, Nick R <Nick.R.LehmanC@conocophillips.com> wrote: Good evening Victoria, We finished pumping our INTRMI cement job on 2M-39 (PTD 218-171) this afternoon. Below are the operational details for the job: Schlumberger cementers pumped 61.6 bbis of 13.Oppg Mudpush followed by 175.3 bbls of 15.8ppg Class G, and 10.2 bbis of water. Swapped to the rig and displaced with 1204 bbis of 10.3ppg LSND. Initial rate of 7 bpm 370 psi with full returns. Rate was decreased rate to 4 bpm and then 3 bpm when total losses observed after 750 bbis into displacement. At 900 bbis, partial returns was observed. At 3 bpm with 1003 bbis pumped, circulating pressure was 1020 psi. Final circulating pressure prior to bumping plug at 3 bpm was 1390 psi. Overall, we observed -80 psi of lift pressure. We bumped the plug and confirmed floats were holding. As previously mentioned, there are no hydrocarbon zones open in this interval. Please see attached pdf for further details. We are currently moving forward as per original plan. We will be running the SonicVision 675 with INTRM2 drilling BHA for logging cement in recorded mode and will retrieve the data once we finish drilling the INTRM2 section. Please let me know if you have any questions or concerns with our plan forward. At this point, we'll be picking up the INTRM2 BHA sometime this morning. Regards, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman @ConocoPhillias. corn From: Loepp, Victoria T (DOA) <victoria loepp aalaskapov> Sent: Tuesday, March 12, 2019 8:53 AM To: Lehman, Nick R <Nick R.Lehi an@conocophillips.com> Subject: [EXTERNAL]KRU 2M-39(PTD 218-171) Intermediate 1 Cement Nick, The following changes are approved for KRU 2M-39(PTD 218-171): The cement evaluation log of 9-5/8" intermediate 1 casing is not required. A summary of the cement job with calculated TOC and job plots as soon as the job is completed is required. For the 7" intermediate 2 casing, these requirements remain unchanged from the approved PTD. A summary of the cement job with calculated TOC and job plots as soon as the job is completed is required. Cement evaluation log will be performed for the 7" intermediate 2 casing as planned. Please include this approval with the approved PTD. 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. Loe(10 Walaska.go 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. It 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 Loeoo@alaska.aov From: Lehman, Nick R <Nick R Lehman@conocophillips.com> Sent: Tuesday, March 5, 2019 9:34 AM To: Loepp, Victoria T (DOA) <victoria. loepp@a la ska.gov> Subject: RE: [EXTERNAL]KRU 2M- 39(PTD 218-171) Cement Logs Victoria, I've summarized our discussion this morning with a few bullet points listed below: 2M-39 Kuparuk Injector, PTD #218-171 o Drilling Rig • Original plan was to drill 2M- 39 with Doyon 142. • Due to delays on 2M-41 prior to exploration, Doyon 142 did not spud 2M-39 in January as originally planned. • During exploration, the decision was made to send Doyon 142 to drill 2 x wells on 3G pad once it finishes its scope out on the ice. • The tentative plan is to spud 2M-39 on April 28, 2019 with Doyon 19. Once this is confirmed, I will send a separate email asking for approval of the rig swap. o Cement Evaluation • The approved PTD requested a cement evaluation log behind the 9- 5/8" 5 intermediate 1 casing. • AOGCC confirmed 3/5/19 that cement evaluation log of 9-5/8" intermediate 1 casing is not required and instead will accept a summary of the cement job with calculated TOC and job plots once the job is completed. • Cement evaluation log will be performed for the 7" intermediate 2 casing as planned. Also, 7" intermediate 2 cement job summary will be provided to AOGCC. Thanks for your time and please let me know if you have any questions. Regards, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499- 6739 Nick. R. Lehman @ConocoPhillips. com From: Loepp, Victoria T (DOA) <victorialcepp alaska Rov> Sent: Tuesday, March 5, 2019 7:15 AM To: Lehman, Nick R <Nk k. R. Lehman@conocophillip_s.c orn> Subject: FW: [EXTERNAL]KRU 2M- 39(PTD 218-171) Cement Logs N Nick, For the rig change send a complete email request and the approval can be handled with email. Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Monday, March 4, 2019 3:46 PM To: Lehman, Nick R <Nick,R.Lehman@conoco hilli s.com> Subject: Re: [EXTERNAL]KRU 2M- 39(PTD 218-171) Cement Logs I will call you tomorrow AM. Sent from my iPhone On Mar 4, 2019, at 9:51 AM, Lehman, Nick R <Nick R Lehman@conocophillips.com> wrote: Victoria, When convenient, would you please give me a call at 907-263- 4951 to discuss the cement evaluation of intermediate 1 casing on 2M-39 PTD #218- 171? Also, due to rig schedule changes, the current plan is to drill 2M-39 with a rig other than Doyon 142 with expected spud in late April 2019. Once we are certain on the rig (most likely Doyon 19), will a new PTD submission be required to accommodate the rig change or can we obtain approval of the change via email? Thanks for your time, Nick Lehman Drilling Engineer ConocoPhillips Alaska Office (907)263-4951 Cell(832)499-6739 Nick. R. Lehman PCono oPhillips.com From: Loepp, Victoria T (DOA) <victoria.loeppPa laska. gov> Sent: Tuesday, January 8, 2019 1:39 PM To: Lehman, Nick R <Nick.R.Lehman Pcono cophillips.com> Subject: [EXTERNAL]KRU 2M- 39(PTD 218-171) Cement Logs Nick, The PTD is approved and ready for pick up. will get back to you on the cement evaluation log for the 9-5/8". It is currently required as a part of the approved PTD. 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 Victona.Loeop analaska.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 Loeoo@alaska gov From: Lehman, Nick R <Nick.R.Lehman@cono cophillios.com> Sent: Tuesday, January 8, 2019 1:33 PM To: Loepp, Victoria T (DOA) <victoria.loeopCa@alaska. gov> Subject: RE: [EXTERNAL]RE: KRU 2M-39(PTD 218-171) Cement, Anti -collision and Op SD Victoria, - The Intermediate II 7" casing will be the main isolation between the overburden and the reservoir. I was planning on running Sonic tool on the 6-1/8" production BHA to evaluate the cement behind the Intermediate II casing. 9 o Line #23 of the Propos ed Drilling progra m in the PTD request should have include d "Sonic" in the 6 -1/8 - BHA assemb ly.I realize I failed to include it originall y -my apologi es. The Intermediate 1 9-5/8" casing will be run to help minimize drilling issues on this well. For the 9-5/8" Intermediate I casing, I was planning on evaluating cement based on the 9-5/8" cementing operations and a successful FIT at the shoe once we drillout. Regards, Nick Lehman 10 Drilling Engineer ConocoPhillips Alaska Office (907)263-4951 Cell (832)499-6739 Nick. R. L ehmon @Conoc oPhillips. com From: Loepp, Victoria T ( DOA) <victoria.loe pp@a laska. gov> Sent: Tuesday, January 8,20199:51 AM To: Lehman, Nick R <N ick. R. Lehman Lacon o cophillips.com> Subject: [EXTERNAL]RE: KRU 2M-39(PTD 218- 171) Cement, Anti - collision and Op SD Nick, I don't see a cement evaluation log for the Intermediate 1 and 2. What are your plans? 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. Loeoo(aalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate 11 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 Loeoo@alaska aov From: Loepp, Victoria T (DOA) Sent: Tuesday, January 8, 2019 9:30 AM To:'Lehman, Nick R' <Nick. R.Lehman (@conn cophillips.com> Subject: KRU 2M- 39(PTD 218-171) Cement, Anti -collision and Op SD Nick, Thank you for the information. Please submit a diverter equipment schematic with each PTD although this information is on file with the AOGCC. The schematic you submitted was what I would like to see. 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. LoeppCaia laska.Ooy CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska 12 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: Lehman, Nick R <Nick.R.Lehman@cono cophillips.com> Sent: Sunday, January 6, 2019 8:12 PM To: Loepp, Victoria T (DOA) <victoria.loepp alaska. gov> Cc: Woodard, Madeline <Madeline.E.Woodard @conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2M-39(PTD 218-171) Cement and Anti - collision Victoria, Thank you for your email. I apologize for any confusion and I appreciate your patience. I corrected the schematic and attached above to reflect TOC @ 250' TVD 13 above the 9- 5/8„ Intermediate 1 shoe. Attached above is the equipment schematic for the diverter on Doyon 142 as well as the rig- on-diverter layout map (page 12 of PTD application request). o I was working under the belief thatthe diverter equipm ent informa tion for D142 was already on file with AOGC- please let me know if the D142 diverter equipm ent schema tic needs to be submitt ed with every PTD request moving 14 forward Attached above is a modified cover letter to include temporary suspension of 2M-39 allowing for Doyon 142 to assist with exploration drilling out on the ice. o Current ly,Iam estimat ing we will be able to drill, case, and cement the surface section before explora tion needs Doyon 142. Howev e r, please note that it is a moving target right now since explora tion needs the rig in a specific timefra me and is 2M-41 comple tion date could push back if any unexpe cted issues are encoun tered. 2M-09/2M- 09A M-09/2M- 09A is a Kuparuk injector that has been permanently plugged/aband oned, cut-off below ground level, and backfilled as of July 17, 2018. This well has been minor - risked and we will be utilizing gyro -while - drilling to take surveys as needed to ensure we drill to plan. Please let me know if you have any questions or need any other information. Regards, Nick Lehman Drilling Engineer ConocoPhillips Alaska Office (907)263-4951 1 Cell(832)499-6739 Nick. R. Lehman (@Conoc ophillips.com 16 From: Loepp, Victoria T (DOA) <victoria.loepppaIaska. ov> Sent: Thursday, January 3, 2019 9:47 AM To: Lehman, Nick R <Nick.R.Lehman@conn cophillips.com> Cc: Woodard, Madeline E <Madeline.E.Woodard @conocophillips.com> Subject: [EXTERNAL]RE: KRU 2M-39(PTD 218- 171) Cement and Anti- collision I now notice that the well class is listed as both a service well and development well. I will delete the development well class. The cement calculations should be based on 250' TVD above the shoe in the intermediate. Please correct the schematic. Please provide a diverter equipment diagram with sizing. I understand that there will be an Operations Shutdown of drilling operations after the surface hole. This should be included in the PTD in the cover letter outlining the current plans and how the well will be left. Thanx, Victoria From: Loepp, Victoria T (DOA) 17 Sent: Wednesday, January 2, 2019 11:11 AM To: Lehman, Nick R <Nick.R.Lehman@cono cophillips.com> Subject: KRU 2M- 39(PTD 218-171) Cement and Anti - collision Nick, Please review the cementing calculations for the Intermediate #1: The shoe is at 15722' MD or 5800' TVD; cement is to be 500' TVD above shoe or 5300' TVD; 5300' TVD corresponds to 13600' MD I notice the cement calculations show cement 250' TVD above shoe while the schematic has 500' TVD above shoe. Also, the schematic is labeled as an injector. Please correct as needed. Also, please explain what mitigation measures will be in place for the failed major risk with 2M-09/ 2M -09A. Will 2M-09 be shut in with a deep plug? 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 18 Victoria. Loeoppa laska.00v CONFIDENTIALITY NOME, 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 907)7931247 or Victoria.Loeoo@olaska oov <2M-39 INTRMI Cement Job Detalls.pdf> <ConocoPhi11ips_2M-39_sonic_Top_of Cement_LWD007_9750- 17750ftMD_1000.pdf> <2M-39 INTRM2 - Cement Job Info.pdf> 19 COMPANY: ConocoPhillips Alaska I.I.C. n U) T WELL: 2M-39 O__r P—' STATE: Alaska k River 'Zi M !- D COUNTRY: USA z � Location Z m n v # . r m � � • CDT�NC� PO w8o N O Cl)CD � a = o cfl n Ov 7z- e% • CD,3 • CD." n D • M11111111111111110 77, a) 11111111111111111• F- 17- r0 0 a)om r -n v g v � FOLD HERE: The well name, location and borehole reference dab were furnished by the customer. Any interpretation, research, analysis, data, results, estimates, or recommendation furnished with the services or otherwise communicated by Schlumberger to ft customer at any time in connection with the services are opinions based at inferences Pan measurements, empirical relationships, andfor assumptions; which, inferences, empirical relationships and/or assumptions are not infallible and with respect to which professionals in the industry may differ. Accordingly, Schlumberger cannot and does not warrant the accuracy, correctness, or completeness of any such interpretation, research, analysis, dala, results, estimates, or recommendation. The customer acknowledges that it is accepting the services "as is," that Schlumberger makes no representation or warranty, express or implied, of any kind or description in respect thereto, and that such services are delivered with the explicit understanding and agreement That arry action taken based on the services received shall be at its own risk and responsibility, and no claim shall be made against Schlumberger as a consequence thereof. Svc. Order #: OP Vers: Processed by: Process Date: 7/02/2019 Location: Techlog 2018 e-mail:jburt2@slb.00m I Company: ConocoPhillips Alaska, Inc. Well:2M-39 Field: Kuparuk River State: Alaska API: 50-103-20795-00-00 Schlumberger Loepp, Victoria T (CED) From: Sent: To: Cc: Subject: Attachments: Follow Up Flag: Flag Status: Good afternoon Victoria, Herring, Keith E <Keith.E.Herring@conocophillips.com> Tuesday, July 2, 2019 4:52 PM Loepp, Victoria T (CED) Lehman, Nick R KRU 2M-39 (PTD 218-171) Intermediate II cement evaluation Co nocoPh it I ips_2M-39_SonicScope_TOC.pdf Follow up Flagged We just received the processed cement evaluation log from the SonicVision tool on the 2M-39 Production drilling BHA; attached above. Good cement behind 7" Intermediate II liner was observed with cement to the liner top at 15786' MD. The 7" Intermediate II liner casing shoe is at 17,895' MD. Please let me know if you have any questions or concerns. Thanks, Keith Herring Drilling Engineer 907.263.4321 (Office) 907.570.2410 (Mobile) 700 G Street, ATO — 1560 Keith .C.Ho i,,�ac ....... ophflhp,com �/ ConocoPhillips AlaSka Loepp, Victoria T (CED) From: Sent: To: Cc: Subject: Follow Up Flag: Flag Status: Thanks Victoria. Nick p -FD 2i8-/7-1 Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sunday, June 16, 2019 9:25 AM Loepp, Victoria T (CED) Herring, Keith E Re: [EXTERNAL]KRU 2M-39(PTD 218-171) Intermediate 1 Cement Follow up Flagged On Jun 16, 2019, at 7:12 AM, Loepp, Victoria T (CED) <victoria.loepp@alaska.eov> wrote: Nick, Thanx for the cement summary. Approval is granted to proceed as planned. Victoria Sent from my iPhone On Jun 16, 2019, at 2:22 AM, Lehman, Nick R <Nick. R.Lehman@conocophillips.com> wrote: Good evening Victoria, We finished pumping our INTRMl cement job on 2M-39 (PTD 218-171) this afternoon. Below are the operational details for the job: - Schlumberger cementers pumped 61.6 bbls of 13.Oppg Mudpush followed by 175.3 bbls of 15.8ppg Class G, and 10.2 bbls of water. - Swapped to the rig and displaced with 1204 bbls of 10.3ppg LSND. Initial rate of 7 bpm 370 psi with full returns. Rate was decreased rate to 4 bpm and then 3 bpm when total losses observed after 750 bbls into displacement. At 900 bbls, partial returns was observed. At 3 bpm with 1003 bbls pumped, circulating pressure was 1020 psi. Final circulating pressure prior to bumping plug at 3 bpm was 1390 psi. Overall, we observed -80 psi of lift pressure. We bumped the plug and confirmed floats were holding. As previously mentioned, there are no hydrocarbon zones open in this interval. Please see attached pdf for further details. We are currently moving forward as per original plan. We will be running the SonicVision 675 with INTRM2 drilling BHA for logging cement in recorded mode and will retrieve the data once we finish drilling the INTRM2 section. Please let me know if you have any questions or concerns with our plan forward. At this point, we'll be picking up the INTRM2 BHA sometime this morning. Regards, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehman@ConocoPhillii)s.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Tuesday, March 12, 2019 8:53 AM To: Lehman, Nick R <Nick. R. Lehman(a)conocophillips.com> Subject: [EXTERNAL]KRU 2M-39(PTD 218-171) Intermediate 1 Cement Nick, The following changes are approved for KRU 2M-39(PTD 218-171): The cement evaluation log of 9-5/8" intermediate 1 casing is not required. A summary of the cement job with calculated TOC and job plots as soon as the job is completed is required. For the 7" intermediate 2 casing, these requirements remain unchanged from the approved PTD. A summary of the cement jab with calculated TOC and job plots as soon as the job is completed is required. Cement evaluation log will be performed for the 7" intermediate 2 casing as planned. Please include this approval with the approved PTD. 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. Loeoo(@.alaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victorio.LoeooCalaska.aov 2M-39wp17 Current Wellbore after INTRMI Cement Job ConoeoPhillips —y--� unaa.a: dta/Ie I I MNktbtman Conductor Installed: 20- Heald-Walldr' en to 170' MD 119 TVD wo 16.010'M0 16" Surface Holo Surface Cnsinr: Below Wcst sat 13-1/A' "01 -M 1I,Aril S61 ),Rrn' MO / 78' Tangent 12-1/4" Intermediate 1 Hole TD at 16,023' MD / 5,806' ND 175.3 bbls 15.8e09 Cfass G avnent eunlDefl w/ TOC talwlated el 13,773' MD / 5,189ND 35% washuut NO HYDROCARBON BEARING ZONES EXPOSED IN INTERMEDIATE 1 SECTION • Cement Slurry: • 984 sacks 15.8 ppg tail cement • Job Comments: • Maintained proper cement mixing density. • Observed -80 psi of lift pressure once cement turned corner • Full returns at start of job and up to 750 bbls into displacement, then partial to no returns for remaining portion of cement job. • Unable to reciprocate pipe during cement job • Bumped plug and floats held. • TOC calculated to 13,773' MD / 5,289' TVD with 35 % excess • 2245' MD / 515' ND above top of shoe • No hydrocarbon bearing zones open in this interval • Casing will be pressure tested to 3,500 psi for 30 min once INTRM2 Drilling BHA is run in hole to float collar. 2M-39 Pump Chart r�. Pumyhmun —11N• --Nfo Floor Vressu - my � m•,•e a,vo r ,•v,o I Cons -80 psi lift rressure on :ement job I :oPhillips PiO 1�/5-17-1 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Monday, June 10, 2019 12:25 PM To: Lehman, Nick R Cc: Regg, James B (CED); DOA AOGCC Prudhoe Bay Subject: Re: 2M-39 (PTD218-171): Request for BOPE Test Variance Nick, Approval is granted for a BOP test extension until out of hole with Int 1 drilling assembly. Thanx, Victoria Sent from my iPhone On Jun 10, 2019, at 11:02 AM, Lehman, Nick R <Nick.R.Lehman(a)conocophillips com> wrote: Good morning Victoria, As discussed, due to hole condition issues we have encountered on the re -drill of the 12-1/4" INTRMI section of 2M-39 (PTD# 218-171) with Doyon 19, ConocoPhillips requests approval for a variance to c' i M) until we are out of hole with the Intermediate 1 drilling >semhf As proven in our prior abandonment/plugback/re-drill, this well has proven to be very challenging in this Intermediate 1 section - by allowing us to pull out of hole to surface before testing BOPE, we minimize the out -of -hole time to give us the best chance of a successful casing run and cement job. However, if it is required, we do have a storm packer on location to set in the 13-3/8" surface casing. Please note, we performed a full ROPE test on 5/27/19 prior to running in with drilling assembly. For more detailed timeline of events, please see list below. Also, communication with field AOGCC inspector attached above. 2M-39 TIMELINE BOPE originally installed and tested 5/4/19 12-1/4" INTRM1 section drilled to TD of 15,798' MD, reaching TD 5/12/19 Backreaming out of hole was challenging due to hole conditions, but was out of hole by 5/16/19 Re -tested BOPE 5/16/19 prior to running casing o While forecast showed we should have had enough time to get casing on bottom and cemented prior to scheduled BOPE test, we were proactive and tested BOPE to ensure we did not exceed our 2 -week cycle - Ran 9-5/8" casing to bottom and performed cement job. - Ran in with INTRM2 drilling BHA, tagged up top plug high, found leak in casing, Pull out of hole - Abandoned hole section and cut/pull 9-5/8" casing, and spot cement kickoff plug - Re -test BOPE 5/27/19 o Performed full BOPE test prior to making up INTRM1 drilling BHA to give us as much time as possible to drill this challenging hole section - Sidetracked below surface shoe and re -drilled 12-1/4" INTRM1 hole section to TD of 16,023', reached TD on 6/5/19. Weighted up and started backreaming out of hole. Encounter hole issues from 7300' onwards. Currently backreaming out at —4300' MD (13-3/8" shoe is at 2860' MD) Based on current rate of progress, expect to be out of hole with BHA laid down no later than 12:00 hrs on 6/12/19 o The original plan was to perform full BOPE test once out of hole prior to running 9-5/8" casing. See email attached above for field BOPE test notification made on 6/6/19 for expected test of 6/7/19. At this point, we theoretically would have had enough time to get casing to bottom and cemented prior to the end of the 2 -week cycle — however, we wanted to be proactive and ensure we didn't have any issues with exceeding the 2 -week cycle, so we planned for a full test. o On morning of 6/7/19, we realized we could not pull out of hole on elevators and had to backream out, extending the estimated test time to morning of 6/8/19 o At 19:00 hrs on 6/7/19, we started seeing the hole try to packoff and pull tight — since then, we have been doing our best to get out of hole given the challenging hole conditions. Thanks, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman pConocoPhillios. com <mime -attachment> Loepp, Victoria T (CED) From: Doyon 19 Company Man <doyonl @conocophillips.com> Sent: Monday, June 10, 2019 10:37 AM To: Lehman, Nick R Subject: FW: [EXTERNAL]RE: AOGCC Test Witness Notification Request: BOPE, Doyon 19, 2M-39, Kuparuk Rick Bjorhus / Lloyd Shirley Doyon 19 Drilling Supervisors 907-670-4350 From: Doyon 19 Company Man Sent: Monday, June 10, 2019 10:35 AM To: Cook, Guy D (CED) <guy.cook@alaska.gov> Cc: Herrera, Matthew F (CED) <matthew.herrera@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prud hoe. bay@alaska.gov> Subject: RE: [EXTERNAL]RE: AOGCC Test Witness Notification Request: BOPE, Doyon 19, 2M-39, Kuparuk We are currently at 4,300' having hole issues and are having trouble getting out, I will have a storm packer on location when we finally get to the shoe at 2,860' to set it and begin testing the BOPE's. I will advise as things progress. Thanks, Rick Bjorhus / Lloyd Shirley Doyon 19 Drilling Supervisors 907-670-4350 From: Cook, Guy D (CED) <guy.cook@alaska.gov> Sent: Saturday, June 8, 2019 7:13 AM To: Doyon 19 Company Man <doyonlPconocophillips.com> Cc: Herrera, Matthew F (CED) <matthew.herreraPalaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe. bay 2alaska.gov> Subject: Re: [EXTERNAL]RE: AOGCC Test Witness Notification Request: BOPE, Doyon 19, 2M-39, Kuparuk Thanks for the update. Update us again tomorrow afternoon please. Thank you, Guy Cook AOGCC Sent from my iPhone On Jun 8, 2019, at 7:09 AM, Doyon 19 Company Man <doyon I (a conocophillips.com> wrote: We are having some hole issues on out journey out. My best update would be for a test tomorrow night at 18:OOhrs. I will update you again this evening. Thanks, Rick Bjorhus / Lloyd Shirley Doyon 19 Drilling Supervisors 907-670-4350 From: Herrera, Matthew F (CED) <matthew.herrera@alaska.eov> Sent: Friday, June 7, 2019 5:37 PM To: Doyon 19 Company Man <doyonl@conocophillips.com>; DOA AOGCC Prudhoe Bay <doa.aoecc.prudhoe. bav alaska.gov> Subject: RE: [EXTERNAL]RE: AOGCC Test Witness Notification Request: BOPE, Doyon 19, 2M-39, Kuparuk Notification received will look for your update Thank You From: Doyon 19 Company Man <doyonl@conocophillips.com> Sent: Friday, June 7, 2019 4:57 PM To: Herrera, Matthew F (CED) <matthew.herrera@alaska.aov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe. bay@alaska.Kov> Subject: RE: [EXTERNAL]RE: AOGCC Test Witness Notification Request: BOPE, Doyon 19, 2M-39, Kuparuk We had to start back reaming OOH. Our new anticipated BOPE test time is tomorrow night at 20:OOhrs. I can update again in the morning. Thanks, Rick Bjorhus / Lloyd Shirley Doyon 19 Drilling Supervisors 907-670-4350 From: Herrera, Matthew F (CED) <rnatthew.herrera@alaska.eov> Sent: Friday, June 7, 2019 6:22 AM To: Doyon 19 Company Man <doyonl@conocophillips.com>; DOA AOGCC Prudhoe Bay <doa.aoecc. Prudhoe. bav@alaska.eov> Subject: RE: [EXTERNAL]RE: AOGCC Test Witness Notification Request: BOPE, Doyon 19, 2M-39, Kuparuk Notification Received please update tonight as you are closer to testing Thank You From: Doyon 19 Company Man <dovonl@conocophillips.com> Sent: Friday, June 7, 2019 6:17 AM To: Herrera, Matthew F (CED) <matthew.herrera@alaska.eov>; DOA AOGCC Prudhoe Bay <doa.aoecc. Prudhoe. bav@alaska.Rov> Subject: RE: [EXTERNAL]RE: AOGCC Test Witness Notification Request: BOPE, Doyon 19, 2M-39, Kuparuk Good morning, we are currently looking at testing the BOPE's at 3:00am tomorrow morning. I can up date later today if so desired. Have a safe day, Rick Bjorhus / Lloyd Shirley Doyon 19 Drilling Supervisors 907-670-4350 From: Herrera, Matthew F (CED) <matthew.herrera@alaska.gov> Sent: Thursday, June 6, 2019 6:26 AM To: Doyon 19 Company Man <doyonl@conocophillips.com>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe .bav alaska.eov> Subject: [EXTERNAL]RE: AOGCC Test Witness Notification Request: BOPE, Doyon 19, 2M-39, Kuparuk Notification received please update tomorrow morning Thank You From: Rick Bjorhus <noreply@formresponse.com> Sent: Thursday, lune 6, 2019 6:06 AM To: DOA AOGCC Prudhoe Bay<doa.aoecc.prudhoe. bav@alaska.aov> Subject: AOGCC Test Witness Notification Request: BOPE, Doyon 19, 2M-39, Kuparuk Question Answer Type of Test Requested: BOPE Requested Time for Inspection 06-07-2019 2:00 PM Location Doyon 19,2M-39, Kuparuk Name Rick Bjorhus E-mail doyon l Aconocophillips.com Phone Number (907) 670-4350 Company Conoco Phillips Alaska Inc. Other Information: We have TD'd the Int #1 section and are BROOH. We can update as we get closer to surface. Rick Submission ID: 4356391786214233654 THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-39 Permit to Drill Number: 218-171 Sundry Number: 319-267 Dear Mr. Alvord: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. aogcc.olaska.gov Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner DATED this2-1-- of May, 2019. RBDMS� MAY 2 8 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 R k. fiy+fr �P�6'...,,ii `3a� � 9 Cd ran u MAY 2 4 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well El 4 Operations shutdown LJ Suspend ❑„ p Perforate El Other Stimulate ❑ Pull Tubing E] Change Approved Programnr Plug for Redrill V vPertorate New Pool ElRe-enter Susp Well ElAlter Casing L�1 Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development Stratigraphic ❑ Service ❑ 218-171 3. Address: 6. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 50-103-20795-00-00 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-39 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL025586 / ADL025585 / ADL025590 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): Casing Length Size MD TVD Burst Collapse Structural Conductor 133 20 170 170 Surface 2823 13.375 2860 2646 5020 2260 Intermediate 15748 9.625 15785 5798 6870 4750 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): t'19ze: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development R] Service ❑ 14. Estimated Date for 5/24/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑' GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: 5/23/2019 Commission Representative: Victoria Loepp¢ GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Chip Alvord Nick Lehman / Authorized Name: Contact Name: Authorized Title: Alaska Drilling Manager Contact Email: nick.r.lehman COnOCO hilli S.COm Y Contact Phone: 907-263-4951 Authorized Signature: C� (f(Qf I Date: q Fbt COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: h✓ (� Plug Integrity BOP Test L Mechanical Integrity Test ❑ Location Clearance ❑ Other /7 ?'My176�f 25 pp -3 L /1 rlvlaV/J✓Yliln 'rte s S(/FJiYti'4 T 1—CV 5CO' )P7 -1fo-AwGll J Post Initial Injection MIT Req'd? Yes ❑ N0 Wil $i5 t2 j—a- � c for r{dr Ll Spacing Exception Required? Yes ❑ No Re Subsequent Form Required: I Q— 40 RBDMS AY MAY 2 8 2019 APPROVED COMMISSIONER HE COMMISSION Date: Approved by:�ye 111191 n M A I I I A q d,�a�tlt4 vT�/2-1i9 U- orm 1 403 Revised 412017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate *O -.B 5441 Application for Sundry to PlugBack, Well 2M-39 Saved: 24 -May -19 May 23, 2019 Alaska Oil and Gas Conservation Commission 333 West 71h Avenue; Suite 100 Anchorage, Alaska 99501 Re: Application for Sundry to PlugBack Well 2M-39, a Kuparuk Injector Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to plugback 2M-39 PTD# 218-171, an onshore grassroots injector well from the 2M pad, with the intent of using the existing surface casing and wellhead for sidetrack operations. Doyon 19 reached TO of the 12-1/4" intermediate 1 section of 15,798' MD / 5801' TVD on 05/12/19. After pulling out of hole, the 9-5/8" 47 lb/ft Hydril 563 intermediate 1 casing string was run to bottom and cemented in place on 5/19/19. The cement job was pumped with no returns to surface due to inability to establish circulation on bottom. The top plug did not bump and floats did not hold, but good lift pressure was observed. On 5/21/19 while tripping in the hole with the 8-1/2" x 9-7/8" intermediate 2 BHA, the top plug was tagged at 13,808' MD (1,888' high). After drilling through the plug and finding hard cement below it, a pressure integrity test of the 9-5/8" casing was performed at 13,812' MD that confirmed the casing had a leak in it. The cement was drilled to 13,860' and dynamic losses started occurring while pumping. The BHA was tripped in from 13,860' and tagged the float collar at 15,712' MD — no cement was observed inside the 9-5/8" casing from 13,860 — 15,712' MD. There are no hydrocarbon zones exposed in the intermediate I interval. The decision was made to plug and abandon the current Intermediate 1 section, cut/pull the 9-5/8" casing, and sidetrack below the surface shoe off of a cement kickoff plug to re -drill the intermediate 1 section. Future drilling operations will be for 2M -39A injector. The expected operational date for plugback is May 241h, 2019 at 07:00 firs. It is planned to use rig Doyon 19. The sidetracking procedures will be covered in a separate revision to the 2M-39 Permit to Drill. 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 10-403. 2. Proposed abandonment program. 3. 2M-39 Post Plugback Schematic. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling 3. Diagram of riser set up. If you have any questions or require further informa (niek.r.lehman@cop.com) or Chip Alvord at 265-6120. Sincerely, Nick Lehman Drilling Engineer )y 20 Doyon 19 2M-39 Plugback Procedure The proposed scope of work for this sundry application is included below. 1. Doyon 19 is currently rigged up on 2M-39. Finish pulling out of hole and laying down 8-1/2" x 9-7/8" BHA. 2. RIH with Cast Iron Bridge Plug (CIBP) on 5-7/8" drill pipe and set inside the 9-5/8" 47# INTRMI casing at a depth of 3,18 P MD (-321' below the 13-3/8" surface shoe that is set at 2860' MD). 3. Pressure test CIBP to 2500 psi / 15 minutes and confirm integrity —Notify AOGCC inspector 24 hours prior for witness of this test. 4. RIH with cutter on 5-7/8" DP, tag CIBP, cut 9-5/8" casing above CIBP, and circulate OA clean. 5. Make up landing joint, pull casing free, and lay down 9-5/8" casing. 6. RIH with 3.5" cement stinger on 5-7/8" drill pipe to pump cement for kickoff plug. 7. Tag top of CIBP and pump 1 x 500' long balanced 15.8 ppg cement kickoff plug from CIBP to 200' inside 13-3/8" surface casing shoe for sidetracking 2M -39A. 8. Pull above plug, circulate clean, pull out of hole, and lay down 3.5" cement stinger. 9. Pick up 12-1/4" drilling BHA and RIH. Wait on cement UCA as needed. 10. RIH and tag top of kickoff plug. 11. Transfer to PTD for 2M -39A. 2M-39 Pre -Abandonment Schematic Updated: 5/23/19 Conductor Installed: by Mck Lehman 20" Heavy -Wall driven to 170' MD surface Casing 1.3-3/8" 6817 L-0 Hydril 563 cemented in place at 2,860' MD / 2,646' ND TVI) 77" INC / 261" AZI Tangent L1P 13,807 h9D/5,337 TVD Top Cement Plug Tagged @ 13,808' MD / 5334' ND Base of cement below top plug found inside casing @ 13,860' MD Hole in Casing expected below 13,808' MD HRZ @ 15.763' RM / 5.793' TVD Intermediate 1 12-1/4" Intermediate Hole. TD at 15,798' MD / 5801' ND / 760 INC NO HYDROCARBON BEARING ZONES EXPOSED IN INTRMI HOLE SECTION Kuparuk C -Sand estimated 0 17.037 MD / 6,071' TVD 2M-39 Post -Abandonment Schematic Updated: 5/23/19 Conductor Installed: by Pack Lehman 20" Heavy -Wali driven to 170' MD Top of Cement Kickoff Plug Planned @ 2,660' MD / 2,499' ND Surface Casine 13-3/8" 68# L80 H563 cemented to surface @ 2,860' MD / 2,646' TVD Top of Cast Iron Bridge Plug at 3181' MD / 2861' TVD (middle of C-50 La 8,517 MD 14,148' TVD C-37 0 10,720' MD/4,642 ND Original TOC estimate @ 13,663' MD / 5301' ND prior to discovering hale in casing C-35 @ 13,807 MP/5,337' ND Top Cement Plugcement Tagged @ 13.808' MD si 5334' ND Base of cement below top plug found inside casing @ 13,860' MD Hole in Casing expected below 13,808' MD HRZ @ 13,763' MD / Intermediate 1 Casing: 12-1/4" Intermediate Hole. TD at 15,798' MD / 5801' ND / 76° INC NO HYDROCARBON BEARING ZONES EXPOSED IN INTRMI HOLE SECTION Kuparuk C -Sand estimated 17.037' MD 16.071' TVD Loepp, Victoria T (CED) From: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sent: Thursday, May 23, 2019 8:15 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]Re: 2M-39 (PTD# 218-171) Plan Forward - Cut/Pull/Sidetrack Thanks, will do. Nick Lehman Drilling Engineer ] ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman@ConocoPhillips. com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, May 23, 2019 8:13 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: Re: [EXTERNAL]Re: 2M-39 (PTD# 218-171) Plan Forward - Cut/Pull/Sidetrack Yes, pressure test of the bridge plug. Sent from my iPhone On May 23, 2019, at 7:51 PM, Lehman, Nick R <Nick.R.Lehman@conocophillips.com> wrote: Victoria, Throughout our abandonment operations listed below, would you like the AOGCC field inspectors to have the opportunity to come witness the bridge plug test and/or tagging on our kickoff plug inside surface casing? Nick Lehman Drilling Engineer ] ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehman@ConocoPhillips.com From: Lehman, Nick R Sent: Thursday, May 23, 2019 6:52 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Rohlfing, Jenaya J<Jenava.J.Rohlfing@conocophillips.com>; Alvord, Chip <Chip.Alvord@conocophillips.com>; Herbert, Frederick O <Frederick.O.Herbert@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J. Livingston @conocophillips.com> Subject: RE: [EXTERNAL]Re: 2M-39 (PTD# 218-171) Plan Forward - Cut/Pull/Sidetrack Will do — thank you. Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman@ConocoPhillips.com From: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Sent: Thursday, May 23, 2019 6:51 PM To: Lehman, Nick R <Nick R Lehman@conocophillips.com> Subject: [EXTERNAL]Re: 2M-39 (PTD# 218-171) Plan Forward - Cut/Pull/Sidetrack Nick, Approval is granted for the plan forward outlined below. Please submit a 10-403 Sundry for setting the bridge plug and the cut and pull. Follow with a revised PTD for the sidetrack. Tha nx, Victoria Sent from my iPhone On May 23, 2019, at 6:24 PM, Lehman, Nick R <Nick R.Lehman@conocophillips.com> wrote: Victoria, Following up on our discussion this afternoon regarding 2M-39 (PTD# 218-171), here is our proposed plan forward. When possible, would you please confirm approval of this plan? Previous Operations - We ran our 9-5/8", 47lb/ft Intermediate 1 casing to bottom and cemented in place in the HRZ shale at 15,785' MD / 5,798' TVD / 75.9- - The cement job was pumped with no returns to surface, we did not bump the plug, and the floats did not hold. We did see over 500psi of lift pressure. - We ran in hole with the 8-1/2" x 9-7/8" Intermediate 2 drilling assembly and tagged up on the top cement plug at 13,808' MD. The top of the float collar was set at 15,696' MD, so we tagged 1888' higher than planned - We drilled through the plug @ 13,808' and ^'2' of cement and then stopped at 13,812' to test our casing — we were unable to get a pressure test on it and observed leak -off. We continued to drill cement and started observing losses while circulating. In total, we drilled through 52' of hard cement to 13,860'. From 13,860' MD to the float collar at 15,696' MD, we did not observe any cement inside the 9-5/8" casing. Abandonment & Sidetrack Plan Forward - Finish pulling OOH and lay down drilling BHA, expect to be finished at 03:00 hrs 5/24/19 - RIH with a cast-iron bridge plug and set inside the 9-5/8" casing —300' below the surface casing shoe (surface shoe at 2860' MD / 2646' TVD) o As previously mentioned, there are no hydrocarbon zones open in the Intermediate 1 hole section that we drilled. - Pressure test to 2500 psi - Cut 9-5/8" casing above bridge plug and lay down casing. Pump a kickoff cement plug from the cast-iron bridge plug to 200' inside surface casing shoe. o I will submit an abandonment sundry in the morning with schematics detailing the plan. Perform a sidetrack below surface casing shoe and re -drill 12-1/4" Intermediate 1 hole section We will shift the wellplan to get sufficient separation from the existing wellbore and then parallel it to TD. We will make up what we can with returning to original wellplan trajectory on the intermediate 2 section. The remaining portion will be made up on the start of the production section and we will drill the lateral on the same trajectory as proposed in the original 2M-39 PTD with the same planned TD and bottomhole location o Once I have final modified wellplan, I will add changes in red to the original 2M-39 PTD and send for your approval. Thanks for your time and help, Nick Lehman Drilling Engineer I ConocoPhillips Alaska office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehman@ConocoPhillii)s.com Loepp, Victoria T (DOA) From: Sent: To: Subject: Follow Up Flag: Flag Status: Thanks Victoria. Will do. Regards, Nick Lehman pro 7�/F-.171 Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Tuesday, March 12, 2019 9:52 AM Loepp, Victoria T (DOA) RE: [EXTERNAL]KRU 2M-39(PTD 218-171) Intermediate 1 Cement Follow up Flagged Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R, Lehmon6DConocoPhillios. com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, March 12, 2019 8:53 AM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: (EXTERNAL]KRU 2M-39(PTD 218-171) Intermediate 1 Cement Nick, The following changes are approved for KRU 2M-39(PTD 218-171): The cement evaluation log of 9-5/8" intermediate 1 casing is not required. A summary of the cement job with calculated TOC and job plots as soon as the job is completed is required. For the 7" intermediate 2 casing, these requirements remain unchanged from the approved PTD. A summary of the cement job with calculated TOC and job plots as soon as the job is completed is required. Cement evaluation log will be performed for the 7" intermediate 2 casing as planned. Please include this approval with the approved PTD. 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. LoeooCdalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or VicIoria.I oeoo@alaska.cLov From: Lehman, Nick R <Nick.R.Lehman@conocophillips com> Sent: Tuesday, March 5, 2019 9:34 AM To: Loepp, Victoria T (DOA) <victoria.loeppPalaska.¢ov> Subject: RE: [EXTERNALJKRU 2M-39(PTD 218-171) Cement Logs Victoria, I've summarized our discussion this morning with a few bullet points listed below: 2M-39 Kuparuk Injector, PTD #218-171 o Drilling Rig • Original plan was to drill 2M-39 with Doyon 142. • Due to delays on 2M-41 prior to exploration, Doyon 142 did not spud 2M-39 in January as originally planned. During exploration, the decision was made to send Doyon 142 to drill 2 x wells on 3G pad once it finishes its scope out on the ice. The tentative plan is to spud 2M-39 on April 28, 2019 with Doyon 19. Once this is confirmed, I will send a separate email asking for approval of the rig swap. Cement Evaluation The approved PTD requested a cement evaluation log behind the 9-5/8" intermediate 1 casing. AOGCC confirmed 3/5/19 that cement evaluation log of 9-5/8" intermediate 1 casing is not required and instead will accept a summary of the cement job with calculated TOC and job plots once the job is completed. Cement evaluation log will be performed for the 7" intermediate 2 casing as planned. Also, 7" intermediate 2 cement job summary will be provided to AOGCC. Thanks for your time and please let me know if you have any questions. Regards, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehman@ConocoPhillins.com From: Loepp, Victoria T (DOA) <victoria.loeppPalaska.gov> Sent: Tuesday, March 5, 2019 7:15 AM To: Lehman, Nick R <Nick.R.Lehman@conocophillips com> Subject: FW: [EXTERNAL)KRU 2M-39(PTD 218-171) Cement Logs Nick, For the rig change send a complete email request and the approval can be handled with email. Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Monday, March 4, 2019 3:46 PM To: Lehman, Nick R <Nick.R.LehmanPconocophillips com> Subject: Re: [EXTERNAL]KRU 2M-39(PTD 218-171) Cement Logs I will call you tomorrow AM. Sent from myiPhone On Mar 4, 2019, at 9:51 AM, Lehman, Nick R < > wrote: Victoria, When convenient, would you please give me a call at 907-263-4951 to discuss the cement evaluation of intermediate 1 casing on 2M-39 PTD #218-171? Also, due to rig schedule changes, the current plan is to drill 2M-39 with a rig other than Doyon 142 with expected spud in late April 2019. Once we are certain on the rig (most likely Doyon 19), will a new PTD submission be required to accommodate the rig change or can we obtain approval of the change via email? Thanks for your time, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman PConocoPhillias. com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, January 8, 2019 1:39 PM To: Lehman, Nick R <Nick. R. Lehman(@conocophillips.com> Subject: [EXTERNAL)KRU 2M-39(PTD 218-171) Cement Logs Nick, The PTD is approved and ready for pick up. I will get back to you on the cement evaluation log for the 9- 5/8". It is currently required as a part of the approved PTD. 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. Loeopoalaska.cov, 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). If 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 AOG,C is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793- 1247 or Victoria Loeoo@alaska aov From: Lehman, Nick R <Nick.R Lehman CcDconocophilllps com> Sent: Tuesday, January 8, 2019 1:33 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Subject: RE: [EXTERNAL]RE: KRU 2M-39(PTD 218-171) Cement, Anti -collision and Op SD Victoria, The Intermediate 11 7" casing will be the main isolation between the overburden and the reservoir. I was planning on running Sonic tool on the 6-1/8" production BHA to evaluate the cement behind the Intermediate II casing. o Line #23 of the Proposed Drilling program in the PTD request should have included "Sonic" in the 6-1/8" BHA assembly. I realize I failed to include it originally - my apologies. The Intermediate 19-5/8" casing will be run to help minimize drilling issues on this well. For the 9-5/8" Intermediate I casing, I was planning on evaluating cement based on the 9-5/8" cementing operations and a successful FIT at the shoe once we drillout. Regards, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman PConocoPhillios com From: Loepp, Victoria T (DOA) <victoria.loeppPalaska aov> Sent: Tuesday, January 8, 2019 9:51 AM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2M-39(PTD 218-171) Cement, Anti -collision and Op SD Nick, I don't see a cement evaluation log for the Intermediate 1 and 2. What are your plans? Tha nx, 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.LoeoolrDalaska 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 of (9071793- 1247 or Victoria Loeoa@alaska aov From: Loepp, Victoria T (DOA) Sent: Tuesday, January 8, 2019 9:30 AM TO: 'Lehman, Nick R' <Nick.R.Lehmanftconoconhillips com> Subject: KRU 2M-39(PTD 218-171) Cement, Anti -collision and Op SD Nick, Thank you for the information. Please submit a diverter equipment schematic with each PTD although this information is on file with the AOGCC. The schematic you submitted was what I would like to see. 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 LoeooCcDalaska oov 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 low. 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 if to you, contact Victoria Loepp of (907)793- 1247 or Vicfska goy From: Lehman, Nick R <Nick R Lehman(d)conocophillips com> Sent: Sunday, January 6, 2019 8:12 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska aov> Cc: Woodard, Madeline E <Madeline.E.Woodard @conocophillips com> Subject: RE: [EXTERNAL)RE: KRU 2M-39(PTD 218-171) Cement and Anti -collision Victoria, Thank you for your email. I apologize for any confusion and I appreciate your patience. I corrected the schematic and attached above to reflect TOC @ 250' TVD above the 9-5/8" Intermediate 1 shoe. Attached above is the equipment schematic for the diverter on Doyon 142 as well as the rig-on- diverter layout map (page 12 of PTD application request). o I was working under the belief that the diverter equipment information for D142 was already on file with AOGC - please let me know if the D142 diverter equipment schematic needs to be submitted with every PTD request moving forward. Attached above is a modified cover letter to include temporary suspension of 2M-39 allowing for Doyon 142 to assist with exploration drilling out on the ice. o Currently, I am estimating we will be able to drill, case, and cement the surface section before exploration needs Doyon 142. However, please note that it is a moving target right now since exploration needs the rig in a specific timeframe and 2M-41 completion date could push back if any unexpected issues are encountered. 21V-09 / 2M -09A is a Kuparuk injector that has been permanently plugged/abandoned, cut-off below ground level, and backfilled as of July 17, 2018. This well has been minor -risked and we will be utilizing gyro -while -drilling to take surveys as needed to ensure we drill to plan. Please let me know if you have any questions or need any other information. Regards, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman @ConocoPhillips. com From: Loepp, Victoria T (DOA) <yictoria.loepp@alaska.aov> Sent: Thursday, January 3, 2019 9:47 AM To: Lehman, Nick R <Nick. R. Lehman@conocophillips.com> Cc: Woodard, Madeline E <Madeline.E.Woodard@conocophilIips.com> Subject: (EXTERNAL]RE: KRU 2M-39(PTD 218-171) Cement and Anti -collision I now notice that the well class is listed as both a service well and development well. I will delete the development well class. The cement calculations should be based on 250' TVD above the shoe in the intermediate. Please correct the schematic. Please provide a diverter equipment diagram with sizing. I understand that there will be an Operations Shutdown of drilling operations after the surface hole. This should be included in the PTD in the cover letter outlining the current plans and how the well will be left. Tha nx, Victoria From: Loepp, Victoria T (DOA) Sent: Wednesday, January 2, 2019 11:11 AM To: Lehman, Nick R <Nick. R. Lehman@conocophiIIips.com> Subject: KRU 2M-39(PTD 218-171) Cement and Anti -collision Nick, Please review the cementing calculations for the Intermediate #1: The shoe is at 15722' MD or 5800' TVD; cement is to be 500' TVD above shoe or 5300' TVD; 5300' TVD corresponds to 13600' MD I notice the cement calculations show cement 250' TVD above shoe while the schematic has 500' TVD above shoe. Also, the schematic is labeled as an injector. Please correct as needed. Also, please explain what mitigation measures will be in place for the failed major risk with 2M-09/ 2M - 09A. Will 2M-09 be shut in with a deep plug? 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 Loeoolcilalaska oov 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 Loeoo@alaska aov THE STATE oIALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-39 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-171 (revised) Surface Location: 5167' FNL, 5150' FEL, SEC. 27, TI IN, R8E, UM Bottomhole Location: 946' FNL, 4515' FEL, SEC. 7, T10N, R8E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v, -oogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the 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, 0'11/� Daniel T. Seamount, Jr. Commissioner 416 DATED this I d day f May, 2019. L u; d Specifications aw Top -Setting Depth -BVInstaIJed STATE OF ALASKA Hole Casing MAY 2 8 2019 ALASKA OIL AND GAS CONSERVATION COMMISSION n'C R(� I PERMIT TO DRILL Y J itstage data) 20 AAC 25.005 94# H-40 1a. Type o r . . oposed Well Class: Exploratory- Gas❑ Drill 17 Pn Service - WAGE] Service - Disp❑ 1c. Specify if well is proposed for: L,t.e Stratigraphic Tep Development - DIP Service - Winj ❑ Single Zone ❑ Coalbed gas Gas Hyci tes Redo Reenvy Exploratory - Oil❑ Development - G9 Service - Suppl>A Multiple Zone ❑ Geotherrl�r I Shale Gans 2. Operator Name: 5. Bond: Blan(dt Single WeLl 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 KRU 2M-39 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360, Anchorage, AK 99510-0360 MD: 26,034' ND: 6,167' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Kuparuk Oil Pool ' Surface: 5167' FNL & 5150' FEL, Sec 27, T11 N, R8E, UM ADL025586 / ADL025585 / ADL025590 6-1/8" 4-112" Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 3004' FNL & 2838' FEL, Sec 31, T11 N, RBE, UM 931894000 % 931893000 / 931898000 + 5/28/2018 Re -Drill Total Depth: 946' FNL & 4515' FEL, Sec 7, T10N, R8E, UM 9. Acres in Property: 2560 / 2491 / 2501 14. Distance to Nearest Property: -Base 526' to ADL390680 4b. Location of Well (State Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 139.7. 15. Distance to Nearest Well Open Surface: x- 487970 y- 5948985.25 Zone- 4 GL / BF Elevation above MSL (ft): 100.7. to Same Pool: 1568' to 2M-38 16. Deviated wells: Kickoff depth: 300 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hnln Annla oz o7 ne,..ve� 170 n ............... .. 18. Casing Program: Specifications aw Top -Setting Depth -BVInstaIJed vCement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD itstage data) 42" 20 94# H-40 Welded 80 Surf Surf 119lled16" 13-3/8" 68# L-80 Hyd 563 2822 Surf Surf 2861 sx 11ppg lead, 232 sx 12ppg tail 5/8" 40# L-80Hyd 563 16021 Surf Surf 16058x 15.8 ppg Class G 7" 26# L-80 Hyd 5631504 15858 5769 17363x 15.8 ppg Class G 6-1/8" 4-112" 12.6# L-80 Hyd 5638872 17162603626034Un-cemented Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft):iTotal5TVD Plugs (measured): Effect. Depth MD (ft): Effect. Depth ND (ft): Junk (measured): Size Cement Volume MD ND 20 Driven 170 Med 13.375 1536 sx itppg and 243 sx 12ppg 170 2860 2647 Perforation Depth MD (ft): N/A Perforation Depth ND (ft): N/A _. .-.. ._r............ ,ca IVU 20. Attachments: Property Plat ❑ BOP Sketch t7 Drilling Program 21 Time v. Depth Plot ❑ Shallow Hazard AnalysiG Diverter Sketch O Seabed Report ❑ Drilling Fluid Program � 20 AAC 25.050 requirementO 21. Verbal Approval: Commission Representative: Victoria Loeppf Date 5/28/2019 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be ,r c deviated from without prior written approval. // Contact Name: Nick Lehman Authorized Name: Chip Alvord Contact Email: nick r lehman(OconocobhilliDs com Authorized Title: a a Drilling Man r - Contact Phone: 907-263-4951 Date: on Use ------ renlm,appioval See cover letter for other Number: $—''�. 50-lOB-d0�'� -pp- Date: ' requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me ane, as hydrates, or gas contained in shlvs: Other: 30P 7e-5 7"_ f"0 ,3500 sr _ SSragmples req'd: Yep Ro Mud log req'd: Y^�' WNo y�rxn vl a � � r� Vl ✓3 r S � fD Z S �y ri;W measures: Ye+.X Qkoo Directional svy req'd: Y95 ❑ No Spacing exception req'd: YeP flKo Inclination -only svy req'd: YnW'NNo Post initial injection MIT req'd: YL ❑ No �t 2 CtmGri' Job 'ay) C/ Ctmrn7' eVccl any I q�' a,55ocr� !q5 each l3 aVaf7aGlc by: Ased 5/2017 This per I vrc 5/z9/1 9 APPROVED BY THE COMMISSION proval per 20 AAC 25.005(g) Aer/�� Date .Sunm 2d 11 Attachments in Duplicate rA8 s/zsl l ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 May 26, 2019 Commissioner Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, Alaska 99501 Re: Revision to Permit to Drill 218-171, Kuparuk Producer, 2M-39 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a revision to the permit to drill #218-171 for 2M-39, a development grassroots onshore injector with a single lateral horizontal well in the Kuparuk C sand. The well is currently undergoing abandonment plugback operations under sundry # 319-267 and is expected to be ready to sidetrack below the existing surface casing on May 281, 2019 using rig Doyon 19. All remaining intervals will utilize Doyon 19's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on a 14 -day cycle in accordance with COP and AOGCC policy. The first intermediate hole section will be a 12-1/4" hole sidetracked below the existing surface casing shoe with 9-5/8" casing run to total depth & cemented in place. The second intermediate section will be drilled with a 8-1/2" bit and underreamed to 9-7/8" with a 7" liner run to total depth and cemented in place. The 6-1/8" production lateral will be geo-steered in the Kuparuk C sand and lined with 4-1/2" pre -perforated liner. The bottom -hole location is the same for the revision, however the overall length of the lateral had to be increased by 400' in order to accommodate for the sidetrack and and the offset distance from the original wellbore. The wellbore trajectory will resume the original permitted wellbore trajectory in the reservoir section. The upper completion will be run with 3-1/2" tubing. Please see amendment below to original PTD. Revisions in red are modifications made due to 2M-39PB 1 plugged back INTRMI section and sidetrack out of surface casing. Bottomhole location and reservoir targets are the same —the depths had to be modified to allow for separation from the plugged back wellbore. 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 Nick Lehman at 263-4951 (nick. r.lehman(a)conocophillips.com) or Chip Alvord at 305-6120. Sincerely, Nick Lehman ��4, Drilling Engineer 'G Application for Permit to Drill Document Kuparuk Well 2M-39 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 2M-39 Location Summary Requirements of 20 AAC 25.005(c)(2) An applica6an fin a i erntit m Drill roast he i"ompanted by each of,Aw folf raving irems, except for an item already on file i iA the commission and identified in the apphcanime (2) a plat identifying the pr'opem and the property's on nets mid shah ring (A)Ne coordinates of the proposed location of die well at the,sa,face, at the rop ofeach objeetive,ionwtion, and at unal depth, referent d to governmental se, lion lines. (8) the coordinates orthe proposed location of the well at the surface, referenced to the state plane coordinate s_yatenz.for this sine or nuthilained by the National Gealetic Sarvev in the National Oceanic and Annospheric Adminislmlion: (C) the proposed depth nfthe nvell al the top of eooh objec'live formation mud at anal depth: Location at Surface 5167' FNL, 5150' FEL, Sec 27, T11N, R008E, UM NGS Coordinates Northings: 5948985.25' Eastings: 487969.82' RKBElevation 139.7' AMSL - Pad Elevation 100.7' AMSL Location at Top of Production Interval (Ku aruk C -sand) 3004' FNL, 2838' FEL, Sec 31, Tl 1N, ROME, UM NGS Coordinates Northings: 5945901.45' Eastings: 474445.01' Measured De th, RKB: 17362' Total Vertical Depth, RKB: 1 6071' Total Vertical Depth, SS: 1 5934' Location at Total Depth 946' FNL, 4515' FEL, Sec 07, TION, R010E, UM NGS Coordinates Northings: 593740738' Eastings: 472772.63' Measured Depth, RKB: 1 26034' Total Vertical Depth, RKB: 1 6167' Total Vertical Depth, SS: I .69aw- and (D) other inform ion requires! by 20 AAC 25.050(h); 607;' 1 w Clq Requirements of 20 AAC 25.050(b) Iia M1 is lobe inrennonall y deviated, one appheatfon fura Permit to Drill (horn 10401) must (1) include a pha, dnnrn to a s'uiudd, se'ale, .slowing the path of the proposed welfharr, including all adjacent mellbores within 200feen ofarm/nmitio of the proposed well; Please see Attachment: Directional Plan And (2) for all welle n'ithin 20ojeei nfihe proposed vellbol'e (A) list the mines of the nl>enaors tf Ihnse wells, to the extent that (hose names are karma nr i istorerable in public records, anti show that ecah maned operator Inas been furnished a color at the application by certified mail; or O),staie that the applicant is the rndv affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application far. Permit m Drill must be a, c'ornpanwil In each al the follmrin' it S, except fun' an item ah eadr on file with the cominlssloe and identified in the application: (3) a diagram and description ofthe fila wear prevention equip rneal ('BOPF,) as required by 20 AAC 2A035, 20 AAC 25(/36, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 142 & within this PTD application. Due to lower formation pressure in the overburden, a fixed stack ram placement will be utilized to fulfill all barrier requirements during well construction operations of the Intermediate 1 section, graphic attached. Drilling Hazards Information Requirements of 20 AAC 25.005 (d(4) An application fare Pennil la Drill nurse be ac't'mnpanied b)' each of the fnllmcing items, eccepi for an dein already uq/ile w -0h the conrnw'sion and identified in the application: (4) in/arnralion nn drilling hazards, including (A) the n avirmmn dounhnle pressure that ntr0y be ene'ountemd, criteria used In determine it, anti annimum lvientiudsarface pressure based on a nretlane gradient The maximum potential surface pressure (MPSP) while drilling 2M-39 is calculated using an estimated maximum reservoir pressure of 3316 psi (estimate from reservoir simulator based on offset well injection/pressure data), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk C sand at 6,073' TVD: C Sand Estimated. BHP = 3,316 psi C Sand estimated depth = 6,073' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 607 psi (6,073' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 2,709 psi (3,316 psi — 607 psi) (B) data on potential gas v..er; The wellbore is not expected to penetrate any shallow gas zones. And (C) do,,, con'erning palm sial causes o/hole problenrs.cuc'h as aboard!, geo-press'ared strata, last circulation sones, u,ad tones that have a propensin firr di fjemndal.stickin,g: See attached 2M-39 Drilling Hazards Summary Requirements of 20 AAC 25.005 (c)(5) Art applicalion lar a Pennil a Drill oast be accompanied by each o/ ohi following Leans. except foran item already on file with the cnrnorission and identfed in the applicminn: (5) a description o(the procedw'e fmconducling formadon integr'in, tests, as required under 20 AAC 25.030(j); A procedure is on file with the commission for performing FIT/LOT'S. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An alrplicarion.fi r it Permit to Drill anus, he awns! inied by each aJ'Ihe ftrllowing hear., eecepl foran dear ah'eadv nn file it ah the cormnis'.siar and hkoodied in the applice,inn: (6) a complete proposed rasing aml cernenting pmgran as required ht'20AAC 25.030, and a descrynion of nnyslatted liner. pre-iterfnrnted liner, or .screen ra be installed Casing and Cement Program Casing and Cementing Program Hole Casing Weight Grade Coupling Length Top Top TVD Bottom MD BottomMD TVD Cement Details 42" 20" 94# H-40 Welded 80 Surface Surface 119' 119, Installed 16" 13-3/8" 68# L-80 Hyd 563 2,822' Surface Surface 2,861' 2,640' 1546 sx 11.0 ppg Lead, 232 sx 12.0 ppg Tail 12.25" 9-58" 40# L-80 Hyd 563 16,021 Surface Surface 16,058' 5,820' 388 sx 15.8 ppg Class G 8-12 x 9-7/8" 7" 26# L-80 Hyd 563 1,504' 15,858' 5,769' 17,363' 6,070' 424 sx 15.8 ppg Class G 6-1/8" 4-12" 12.6# L-80 Hyd 563 8,872' 17,162' 6,036' 26,034' 6,167' N/A: Uncemented liner 13-3/8" Surface casine run to 2,861' MD / 2,640' TVD Cement surface casing back to surface. Pump a 500'of tail slurry with 12.0 ppg DeepCRETE and a lead slurry with 11.0 ppg LiteCRETE. Assume 200% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. 13-3/8" SURFACE CEMENT CALCS Design: UniSLURRY Class G 15.8ppg Cement to 250' TVD above shoe Design: 500' of Tail Cott @ 50%excess in OH a Lead Con to surface to 20D% excess in OH Ta it Cement yield= r 1.65k^3/sk I Lead Cement yield= 1.91k^3/sk 1507U MD 11.0 ppg LiteCRETE Lead Slurry 80'x0.0732bbl/ftx1.0(0%excess) CONDUCTOR= 119' x 0.1862 bbl/ft x 1.010%excess) 22.2 bbls BIm of Lead [o Co" = 2361' -119' x 0.0]49 bbl/k x 31200%excess 503.8 ,6,615 Total Lead Cement= 526bbb or 2953.2 k^3 or 1546 sks 450.6ft^3 or 12.0 ppg DeepCRETE Tail Slurry or Shoetrack= 1 500' x 0.1497 bbl/kx 1.010%excess) 12.0 bbls Shoe to To of Tail= (2861'- 2361') x 0.0749 bb Vft x 1.5 50%excess) 56.2 bbls Taal Tail cement= 68.2 bbls or 882.7k^3 or 1232 sks Displacement = 12861'-80'1x 0.1497 bbl/k= 416A bblz 9-5/8" Intermediate I casing run to 16,058' MD / 5,820' TV D Single stage 15.8ppg Class G slurry is designed to be placed from TD to 15,070' MD/5,570' TVD with 35% excess annular volume. 9-5/8" Intrm 1 Cement Calculations Design: UniSLURRY Class G 15.8ppg Cement to 250' TVD above shoe Cement yield = 1.16 ft^3/sk I Planned TOC= 1507U MD Shoe Track 80'x0.0732bbl/ftx1.0(0%excess) 5.9 bbls Shoe toTopofCement= (16058'- 15070') x 0.0558 bbl/ft x 1.35(35% excess) 74.4 bbls Total Cement Volume= 80.3bbls or 450.6ft^3 or 388 sks or Displacement= 1 (16058'-80')x0.0732 bbl/ft= 1169,7,6,615 7" Intermediate II Liner run to 17,363' MD / 6,070' TVD Single stage 15.8ppg Class G slurry is designed to be placed from TD to the 7" liner top at 15,858' MD / 5,769' TVD with 35% excess annular volume. 7" Intrm 2 Cement Calculations Design: UniSLURRY Class G 15.8 ppgCementto 7" UnerTop Cement yield= 1.16ft^3/sk Planned TOC = 15858'MD Shoe Track 80'x 0.0383 bbl/ft x 1.0 (01Y excess) 3.1 bbls 8-1/2" OH x 7" Annulus 110'x 0.0226 bbl/ft x 1.35 (35% excess) 3.4 bbls 9-7/8" OH x 7" Annulus 1194'x0.0471bbl/ft x1.35(35%excess) 76.0 bbls 9-5/8" Csg x 7" Annulus 200'x 0.0256 bbl/ft x 1.0 (0% excess) 5.1 bbls Total Cement Volume= 87,5bbls or 491.3ft^3 or 424 sks Displacement = 1 (17282'- 15858') x 0.0383 bbl/ft+ 15858'x 0.0235 bbl/ft =1 427.1 bbls Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applicadan fora Permit to Drill roust he accompanied by each of thefnlloving itea.v, eccept for an item alt eadlnn file ri ah the commission and identified in the application: (7) a diagram and description of dre divetter system as required by 20 AAC 25035, unless this requirement is waived by the commission under 20 AAC 25 035(h)(2), Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) +an a to 1), ill nasi be a, a,npaaied by each of ih, follon tall items, except J'nr an item already on file with the mntmission and (8) a dri//Ing rima program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25033, Mud Program Summary 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. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (e)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Surface 16" Hole 13-3/8" Casing Intermediate 1 12-1/4" Hole 9-5/8" Casing Intermediate 2 8-1/2" x 9-7/8" Hole 7" Liner Production 6-118" Hole 4-1/2" Liner Mud System Spud BM -SND BM) LSND (WBM) Flo -Pro NT (WBM Density 8.8-9.5 9.5-10.5 10.5-12.2 10.5-12.2 PV 30-50 10-20 10-20 10-20 yP 30-80 16-24 17-28 16-24 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD WA 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 120 F N/A < 10 < 10 < 10 H 9.0-10.0 9.0-10.0 9.0-10.0 9.5-10.0 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. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (e)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An appInalion furs Per'mh to 0,di,ou st items, except for an item already i n F(e with the cornrnission and identified in rhe applitmion: The proposed drilling program follows. Please refer to attachment for proposed well schematic. 1. Move in / rig up Doyon Rig 142. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill Whole to casing point as per directional plan with 5-7/8" DP. Survey & log with MWD, GWD, GR. 3. Run and cement 13-3/8", 68#, L80, Hydril 563 casing to surface. Displace cement with mud & check floats upon bumping plug. Perform top job if required after notifying AOGCC. 4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP'S to 3500 psi high and 250 psi low. Notify AOGCC 24 Ins before test. 5. PU 12-1/4" bit and directional drilling assembly, with MWD, Gamma Ray, & Resistivity. RIH to 100' above float collar with 5-7/8" OR Test surface casing to 3,000 psi for 30 minutes, charted. 6. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 12.5 ppg EMW, record results. 7. Directionally drill to 12-1/4" intermediate 1 hole to TO at +/- 15,722' MD/5,800' TVD in the HRZ. 8. BROOH to surface shoe, circulate well clean then POOH on elevators. 9. Lay down intermediate I BHA. 10. Run 9-5/8", 47#/40# L80, Hydril 563 casing from surface to TD. 11. Pump cement job as per Schlumberger proposal. Displace cement with mud and check floats upon bumping plug. Top cement to be placed @ +/- 14,702' MD/5,550' TVD. 12. Install 9-5/8" packoff & test to 5000 psi. 13. Abandoned original wellbore due to leak in 9-5/8" INTRM I casing per Sundry #319-267. Cast -Iron Bridge Plug was set at 3,181' MD and tested to 2500 psi / 10 min and 9-5/8" casing cut/pulled from 3,175' MD to surface. A cement kickoff plug was spotted from 3,181' MD to 2660' MD (200' inside the 13-3/8" surface casing). 14. PU 12-1/4" bit and directional drilling assembly, with MWD, Gamma Ray, & Resistivity. RIH and tag kickoff plug. Cleanout cement to shoe. 15. Sidetrack below existing surface casing and establish separation with 2M-39PB1 wellbore. 16. Directionally drill to 12-1/4" intermediate 1 hole to TD at +/- 16,058' MD/ 5,820' TVD in the HRZ. 17. BROOH to surface shoe, circulate well clean then POOH on elevators. 18. Lay down intermediate 1 BHA. 19. Run 9-5/8", 40# 1.80, Hydril 563 casing from surface to TD. 20. Pump cement job as per Schlumberger proposal. Displace cement with mud and check floats upon bumping plug. Top cement to be placed @ +/- 15,070' MD / 5,570' TVD. Send cement job report to AOGCC oncejob is completed. 21. Install 9-5/8" packoff & test to 5000 psi. 22. PU 8-1/2" bit, and drilling assembly with underreamer, MWD, Gamma Ray, Resistivity, and Neutron Density. 23. RIH on 5-7/8" DP to top of float equipment. Test casing to 3,500 psi for 30 minutes. 24. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 12.0 ppg EMW recording results. 25. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel to freeze protect. 26. Directionally drill 8-1/2" x 9-7/8" hole to TD in the Kupamk C sand at+/- 17,362' MD / 6,070' TVD. 27. Circulate 1 BU and flow check. POOH on elevators to 9-5/8" shoe. CBU to clean casing & POOH on elevators. 28. Lay down intermediate 2 BHA. 29. Rig up & Run 7", 26#, L-80, Hydril 563 liner and liner top packer. Change out handling gear and RIH with 7" Liner on 5-7/8" DP to bottom. 30. Pump cementjob as per Schlumberger proposal. Displace cement with mud. Top of cement to be at the liner hanger +/- 15,858' MD/5,769'TVD. /Z��2 V/C PL" CGN'7e I-/ j " b WJ 31. Release liner running tool and set packer. PU and pressure test packer to 1,000 psi for 10 minutes. 32. PU 6-1/8" bit and drilling assembly with MWD, Gamma Ray, Resistivity, Neutron Density, SonicScope, & PeriScope. RIH and log cement behind 7" liner. Clean out cement to float equipment. Test the liner to 3,500 psi for 30 min, record results. 33. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 13.0 ppg EMW, recording results. 34. Directionally drill the 6-1/8" production section, geo-steering in the Kuparuk C sand to TD of +/- 26,034' MD / 6,167' TVD. 35. Circulate Ix BU at TD and flow check. 36. BROOH to the 7" shoe. CBU and POOH on elevators. 37. Lay down the 6-1/8" production BHA. Send cement job summary and cement bond log results to AOGCC. 38. PU and run 4-1/2", 12.6# pre -perforated liner with liner hanger & packer. 39. Set liner hanger & packer. 40. Pressure test liner top packer to 3,000 psi, chart results. 41. Flow check well. 42. POOH with finer running tools and lay down. 43. Run 3-1/2" 9.3#, L-80, Hydril 563 upper completion and land tubing. 44. Nipple down BOPE and nipple up tree. Test tree and freeze protect well. Install BPV. 45. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An applicant,,fora Femtit to Drill nwsle be acamgxudad hr ,,It ,f1he fnll(nvh,g items, escep(hn'an iletn alreude an file .4th the commission and identified in dm applie'ation: (M a geeer'al des<Al'1ian ofho" the operator' plans to dispose ofdrilling nuid and castings and a statement u(n'hether the operator intends at request awhor'iauion under 20 AA 25.080 for an annular disposal operation in the trell.: Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class Ii disposal well at the IB Facility. If needed, excess cuttings generated will be hauled to Milne Point or 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 (if free of hazardous substances) used on pads and roads in the Kupamk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 BOP Ram Placement for Intermediate I Section Attachment 2 Well Schematic Attachment 3 Diverter Layout Diagram Attachment 4 Directional Plan Attachment 5 Drilling Hazards Summary 2M-39wp17 E•.iposed Wellbore Schematic ✓ Injector ConocoPhillips 2M-39 wp17 91 s 13 3/a" x 166250 10500 1 e7�1/2" by 9 _'tl800 4-1/2" x Measured Depth o—-- _-- - 2M-39 actual @ 137.45usft (D19) 0 3500 7000 10500 aAnnal 17500 21000 9 5/tT' x 8-1/2" by 9-7/8" 4-1/2"7x 6-1/8" Horizontal ver Pad Elevation: 100.70 MD Name 802860.00 13 318" x 16" 00605767 9 5/8" x 12 1/4" 4573627iik 8-12" by 9-7/8" 7@6033.96 4-12" x 8-iB" Plan fails against: 2M-39PB1 - TCR removes Wells NO-GO Circles NO-GO circles from 7000' MD to 16200'MD are removed from TC plot due to TCR process. V. Osara I Huv Bui 270 I F DDI 7.467 plan Summa 0 a28109 zeas — 29910 2990 — 3180 3100 — 3330 3390 — 3550 3550 — 3730 3730 — 3920 3921 — 4100 4100 — :of0 5010 IX ff 5930 staff 6840 — 7750 7750 6ee0 8680 9570 9570 10490 14010 — 1323ff 3230 — 15060 5030 18390 8890 1673ff ..a 20550 0550 22370 23]0 24210 4210 23034 180 0 2 Magnetic North is 16.44° East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.79° 57401 nT Uthology Cdumn .s.ns n -T-3 frcxo K-15 0 .774 Base Perm 9�o poo 0 0 0 0 z..w,m®n,.,u am%.,mvnamvo-9 o o", 0 0 , _..r_.^ 0 0 0 10 a 11- . 0 i o–�_g-c ca o O m -a-......- o 0 aAHItl�Bw p Rn,P.C.49d ePfr,tree lea+nm,.o-nrs 13 3/8" x ifi' • luxrwWi.o- .a•rn,,. �+ N N N N 2 �fr,aafr � N N C-37 / Iceberg 0 3500 7000 10500 aAnnal 17500 21000 9 5/tT' x 8-1/2" by 9-7/8" 4-1/2"7x 6-1/8" Horizontal ver Pad Elevation: 100.70 MD Name 802860.00 13 318" x 16" 00605767 9 5/8" x 12 1/4" 4573627iik 8-12" by 9-7/8" 7@6033.96 4-12" x 8-iB" Plan fails against: 2M-39PB1 - TCR removes Wells NO-GO Circles NO-GO circles from 7000' MD to 16200'MD are removed from TC plot due to TCR process. V. Osara I Huv Bui 270 I F DDI 7.467 plan Summa 0 a28109 zeas — 29910 2990 — 3180 3100 — 3330 3390 — 3550 3550 — 3730 3730 — 3920 3921 — 4100 4100 — :of0 5010 IX ff 5930 staff 6840 — 7750 7750 6ee0 8680 9570 9570 10490 14010 — 1323ff 3230 — 15060 5030 18390 8890 1673ff ..a 20550 0550 22370 23]0 24210 4210 23034 180 Magnetic Model & Date: BGGM20013Jun-19 Magnetic North is 16.44° East of True North (Magnetic Declination) Magnetic Dip & Field Strength: 80.79° 57401 nT Uthology Cdumn .s.ns n -T-3 frcxo K-15 cv � .774 Base Perm ewmwnnw am.ro;r'a xbe" W Sak D wvus isa,o-av aww,mm.nw �e eoe o -®d Base WS z..w,m®n,.,u am%.,mvnamvo-9 Camp SS aAHItl�Bw p Rn,P.C.49d ePfr,tree lea+nm,.o-nrs • luxrwWi.o- .a•rn,,. C-50 ma �fr,aafr C-37 / Iceberg M9iV 4,911N Mmfru-,N.4,gR �s.owvmv .a *'em--"ia an mx 7-35 na,w GKLB a..ens,saxuan ,os maw By signing this I ac nmvledge that I have been informed of all asks, checked that th, data is correct, ensured it's completeness, and all surrounding wells are assigned to Me proper position, and I approve the scan and collision avoidance plan as set out i Ne audit pack.l approve it as the basis far the final well plan and wellsite tlrewings. I also acknowledge that unless notified otherwise all targets have a 1W feel lateral ccepted by: Approved by: I Erik Sterk N. Lehman Compass Workspace m,la ra.v za zc 2M-39 wp17 T2860.00 To 26033.96 Spider 0 5 �p "o�i -06 2 O 4 _y-08A 5017 '.. A �f 1 is V_1 1 9a 15 05 -36 2-22 To2 o -2 _ 0 0 h o 12 fib`' 1 04 SAK 120 A-25 .21 a p1 2 50 50 y0 l' A 14 60.¢(1_p £>9.12 6613 0 -03 -01 o �tt�l 40 -26 0 21 CO so 5011 @®. 09 5@R-04 q0 O o -. 1 L1 F692 ��- v Qy,-05 o g0 2M-41 2 0 :n 01 60 -'QOM" y �Q095 ai1S2H-' cM3 yo _v 211-37 2 _. -',i I! _ I�I 0 @g_ !¢@ 03 ��-0 D°4 -01 c e o o -25 vo82 213-03A 2."03 7 @04 M-38 -_"24o M-07 3^-05 50 C 60 0: QO O 50 0- o 2G -D .DRi- LH 0 O 1_2 z -31 3 gg�� 0!C'1 @d-10 o .08 2P.b y. X02 M 7' 4 h - Lt 2K. 2K-0 1 60qK SO 50' 2P81 2514 gM- 2M-32 PB2 1 m G 2G-.1 G P61 2M-39 wp 7 3 2 26 '1 1ALt- it 2S-09A O"'o'm 60 - " 2L-03 2S-0 213-07 2S-0 o. p , 8 l 3.. G 0 2S- o y0 o2K K" 0 0 ¢@ SI'12 bQ 2K2 2S 2 -21 266Kp-22 2K-2 L 608 0 3Y9,rvoi 0 30 fifi p00 b0 ZZ�( ZZ22 2K-2 L2-07_ 14p02 2 2 -22A A4 SG1"01 2 0 3 9 Easting (6500 usftln) 2M-39 wp17 Plan Vmew o ao 0 0 0 0 d 0 13 3/8" 16" x 9 5/8" x 12 1/4" C o 0 -2000 o a 960, 17000 7" x 8-1/2" by 9-7/8" 18000 2M-39 T01 Heel 020818 J -4000 �+- 1.9000 2M-39 T03 020818 J z2M-39 T04 020818 J -6000 2.00.00 2M-39 T05 020818 J _ 2 9 T06 020818 J 2M-39 T07 020818 J -8000 - - - _ 2M-39 TOB 020818 J 23.0.0 2M-39 T09 020818 JIM 2M-39 T10 020818 J 24400, -10000 2M-39 T11 013018 J 2 2M-39 T12 013018 J -- -- 2M -39T1313918 J -12000 1 12M-39 T15 Tce 013018 J -16000 -140 00 -8000 -6000 -4000 -2000 0 West( -)/East(+) 2M-39 wp17 Plan View ooa 13 0 � -2000 $ O 9 5/8" x 12 1/4" 00 �d17000 . -4000 7" x 8-1/2" by 9-7/8' 18000 19 + c 19000 r 0 z L -6000 20000 5 21000 22000 -8000 2300p 24000 -100nn 4-1/2" x 6-1/8" 26000 �M-39 wp17 -16000 -14000 -12000 -10000 -8000 -6000 -4000 -2000 0 West( -)/East(+) 2M-39 wo17 Cnr-tion \/Gn1,ei 1000 Camp SS '.. --�®p� --�-- C-50 -C-37 FIceberg C-35 THRZ K-1 Top Kup 13 3/8" x 16" Top Kup' M b , BHRZ/TKLB oo e ,,o oo 00 O.cO mi. n.o cav �o° 9 5/8" x 12 1/4" 0� 0 o p 0 7„ x 8-1/2" by 9-7/8" _ _.._..__.._ 4-1/2" x 6-1/8" � I I I 10000 --- ---------T—.. .I-- _i 0 2500 5000 7500 10000 12500 15000 17500 Vertical Section at 232.00° 3 II ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit _2 Kuparuk 2M Pad Rig: 2M-39 50103132079500 2M-39 Plan: 21VI-39 wp17 Standard Proposal Report 28 May, 2019 _.----- - FL ConocoPhillips ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River UnR_2 Site: Kupawk 2M Pad Well: Rig: 2M-39 Wellbore: 2M-39 Design: 2M39 wp17 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Rig: 21VI-39 (03't + I GOP ^ e TVD Reference: 2M-39 actual @ ]3Z.d6ueft (D19) �Fty MD Reference: 2M-39 actual @ 137.45usft (D19) lZ$1 �9 North Reference: True U b Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit 2, 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: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.10 ° Well Rig: 2M-39 Weil Position +N/ -S Northing: Latitude: +EI -W Easting: Longitude: Position Uncertainty Tie On Depth: 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 100.70 usft rflbo- 2M-39 Model Name Sample Date Declination Dip Angle Field Strength (nT) BGGM2018 6/1/2019 16.44 80.79 57,401 Design 2M-39 wp17 Audit Notes: Date 5/2412019 Depth From Version: Phase: PLAN Tie On Depth: 2,809.37 Vertical Section: Depth From (TVD) +W -S +E/ -W Direction 4,360.00 (usft) (usft) lusit) (°) 36.75 0.00 0.00 232.00 W82019 8:16:46AM Page 2 COMPASS 5000.14 Build 85O Plan Survey Tool Program Date 5/2412019 Depth From Depth To (usfl) (usft) Survey (Wellbore) Tool Name Remarks 1 2,609.37 4,360.00 210-39 wp17 (2M-39) MWD OWSG OWSG MWD - Standard 2 2,809.37 16,057.67 2M-39 wp17(2M-39) MWD+IFR2+SAG+MS OWSG MWD+ IFR2+Sag +p 3 16,057.67 17,362.44 2M-39 wp17 (210-39) MWD OWSG OWSG MWD - Standard 4 16,057.67 17,362.44 2M-39 wp17(2M-39) MWD+IFR2+SAG+MS OWSG MWD+ IFR2+Sag +A 5 17,362.44 18,862.44 2M-39 wp17 (210-39) MWD OWSG OWSG MWD - Standard 6 17,362.44 26,033.96 2M-39 wp17(2M-39) MWD+IFR2+SAG+MS OWSG MWD+IFR2+Sag +A W82019 8:16:46AM Page 2 COMPASS 5000.14 Build 85O �x ConocoPhillips Conoco Phil lips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Rig: 210-39 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: 2M-39 actual @ 137.45usft (D19) Project: Kuparuk River Unit_2 MD Reference: 2M-09 actual @ 137.45usft (D19) Site: Kupamk 2M Pad North Reference: True Well: Rig: 210-39 Survey Calculation Method: Minimum Curvature Wellbore: 210-39 Depth Inclination Design: 2M-39 wpl7 +N/ -S +EbW Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +EbW Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) rill)( isft) (°1100usft) (°/100usft) (°) Target 2,809.37 42.41 274.99 2,609.41 235.21 -774.11 0.00 0.00 0.00 0.00 2,860.00 42.41 274.99 2,646.80 238.18 -808.13 0.00 0.00 0.00 0.00 2,890.00 42.41 274.99 2,668.95 239.94 -828.28 0.00 0.00 0.00 0.00 2,960.00 40.66 278.28 2,721.35 245.28 -874.37 4.00 -2.51 4.70 130.00 3,260.00 51.34 270.63 2,929.62 260.70 -1,088.98 4.00 3.56 -2.55 -30.00 3,860.00 75.34 270.63 3,196.90 266.57 -1,621.23 4.00 4.00 0.00 0.00 4,160.00 77.83 261.74 3,266.65 247.07 -1,912.04 3.00 0.83 -2.96 -75.00 14,840.00 77.83 261.74 5,518.58 -1,252.87 -12,243.62 0.00 0.00 0.00 0.00 16,057.67 75.28 211.63 5,820.00 -1,877.86 -13,199.69 4.00 -0.21 A.12 -99.00 16,077.67 75.28 211.63 5,825.08 -1,894.33 -13,209.84 0.00 0.00 0.00 0.00 16,589.00 79.96 191.23 5,935.78 -2,356.72 -13,390.49 4.00 0.91 -3.99 -79.14 17,058.20 79.96 191.23 6,017.58 -2,809.88 -13,480.50 0.00 0.00 0.00 0.00 17,162.44 80.00 187.00 6,035.72 -2,911.22 -13,496.76 4.00 0.04 -4.06 -89.82 17,362.44 80.00 187.00 6,070.45 -3,106.71 -13,520.76 0.00 0.00 0.00 0.00 17,708.87 92.12 187.04 6,094.19 -3,449.09 -13,562.91 3.50 3.50 0.01 0.18 18,439.82 92.12 187.04 6,067.09 4,174.04 -13,652.41 0.00 0.00 0.00 0.00 18,507.38 90.00 186.00 6,065.84 A,241.15 -13,660.08 3.50 -3.15 -1.54 -153.962M-39 T03020818 JA 18,553.21 89.07 184.69 6,066.21 A,285.77 -13,664.35 3.50 -2.03 -2.85 -125.38 19,084.12 89.07 184.69 6,074.82 A,815.84 -13,707.77 0.00 0.00 0.00 0.00 19,194.45 89.20 188.00 6,076.46 4,925.46 -13,719.97 3.00 0.12 3.00 87.80 210-39 T04 020818 JA 19,352.32 89.91 192.68 6,077.71 5,080.71 -13,748.29 3.00 0.45 2.97 81.42 20,145.37 89.91 192.68 6,078.98 -5,854.42 -13,922.41 0.00 0.00 0.00 0.00 20,241.22 88.00 192.50 6,080.73 -5,947.94 -13,943.30 2.00 -1.99 -0.19 -174.53 2M-39 T05 020818 JA 20,301.58 86.81 192.31 6,083.46 -6,006.83 -13,956.25 2.00 -1.97 -0.32 -170.77 20,815.39 86.81 192.31 6,112.07 -6,508.06 -14,065.59 0.00 0.00 0.00 0.00 20,874.99 88.00 192.33 6,114.77 5,566.22 -14,078.30 2.00 2.00 0.04 1.15 2M-39706020818 JA 20,963.63 89.77 192.34 6,116.49 5,652.79 -14,097.23 2.00 2.00 0.02 0.45 21,420.45 89.77 192.34 6,118.30 -7,099.05 -14,194.89 0.00 0.00 0.00 0.00 21,474.13 88.70 192.30 6,119.02 -7,151.49 -14,206.34 2.00 -2.00 -0.08 -177.66 2M-39707020818 JA 21,522.45 87.73 192.27 6,120.52 -7,198.68 -14,216.62 2.00 -2.00 -0.06 -178.23 22,019.61 87.73 192.27 6,140.18 -7,684.10 -14,322.19 0.00 0.00 0.00 0.00 22,132.92 90.00 192.30 6,142.42 -7,794.79 -14,346.30 2.00 2.00 0.03 0.76 2M-39708020818 JA 22,207.63 91.49 192.34 6,141.45 -7,867.77 -14,362.23 2.00 2.00 0.05 1.36 22,470.01 91.49 192.34 6,134.61 -8,124.00 -14,418.27 0.00 0.00 0.00 0.00 22,504.77 90.80 192.38 6,133.91 -8,157.95 -14,425.71 2.00 -2.00 0.13 176.33 2M-39 T09 020818 JA 22,527.86 90.34 192.40 6,133.68 -8,180.50 A4,430.66 2.00 -2.00 0.09 177.38 23,198.89 90.34 192.40 6,129.71 -8,835.87 -14,574.76 0.00 0.00 0.00 0.00 23,216.71 90.00 192.29 6,129.66 -8,853.28 -14,578.57 2.00 -1.90 -0.62 -161.87 210J9 T10 020818 JA 23,305.46 88.23 192.29 6,131.03 -8,939.98 -14,597.46 2.00 -2.00 0.00 -179.99 24,239.25 88.23 192.29 6,159.96 -9,851.93 -14,796.13 0.00 0.00 0.00 0.00 24,252.37 87.90 192.33 6,160.40 -9,864.74 -14,798.93 2.50 -2.48 0.31 172.99 2M-39771013018 JA 24,268.13 87.51 192.36 6,161.03 -9,880.12 -14,802.29 2.50 -2.49 0.21 175.27 24,596.93 87.51 192.36 6,175.34 -10,200.99 -14,872.62 0.00 0.00 0.00 0.00 24,716.68 90.50 192.30 6,177.42 -10,317.95 -14,898.19 2.50 2.50 -0.05 -1.20 2M-39 T12013018 JA 24,827.41 93.27 192.21 6,173.78 -10,426.09 -14,921.68 2.50 2.50 -0.08 -1.85 24,943.47 93.27 192.21 6,167.17 -10,539.34 -14,946.19 0.00 0.00 0.00 0.00 25,096.81 90.20 192.20 6,162.53 -10,689.12 -14,978.59 2.00 -2.00 -0.01 -179.802M-39713013018 JA 25,108.02 90.00 192.30 6,162.51 -10,700.08 -14,980.97 2.00 -1.81 0.86 154.54 5282019 8:16:46AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMP1 Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kupawk River Unit_2 Site: Kuparuk 2M Pad Well: Rig: 2M-39 Wellbore: 2M-39 Design: 2M-39 wpl7 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Rig: 2M-39 2M39 actual Q 137.45usft (D19) 2M-39 actual @ 137.45usft (D19) True Minimum Curvature 25,541.59 90.00 192.30 6,162.53 -11,123.71 -15,073.30 0.00 0.00 0.00 0.00 25,544.27 90.00 192.35 6,162.53 -11,126.32 -15,073.87 2.00 0.09 2.00 87.28 2M-39T14013018Jf 26,033.96 89.00 192.47 6,166.78 -11,604.55 -15,179.10 0.20 -0.20 0.02 173.252M-39 T15 Toe 01301 5/28/2019 8:16-46AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMP7 Local Co-ordinate Reference: Company: ConocoPhillips Alaska lnc Kuparuk WD Reference: Project Kuparuk River Unit -2 MD Reference: Site: Kupamk 2M Pad North Reference: Well: Rig: 2M-39 Survey Calculation Method: Waltham: 2M-39 Dogleg Design: 2M-39 wpl7 Depth Inclination ConocoPhillips Standard Proposal Report Well Rig: 2M-39 2M-39 actual @ 137.45usft (1319) 2M-39 actual Q 137.45usft (1319) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E( -W Section Rate Rate Rate (usft) (°) (') (usft' (usft) (usft) (usft) ('1100usft) ('1100usft) ('1100usft) 2,809.37 42.41 274.99 2,609.41 235.21 -774.11 465.20 0.00 0.00 0.00 Adjust TF to 0', for 50.63' 2,860.00 42.41 274.99 2,646.80 238.18 -808.13 490.18 0.00 0.00 0.00 Adjust TF to 0', for 30'- 13 318" x 16" 2,890.00 42.41 274.99 2,668.95 239.94 -828.28 504.98 0.00 0.00 0.00 Start 4'1100' DLS, 130' TF, for 70' 2,900.00 42.15 275.45 2,676.34 240.55 -834.98 509.88 4.00 -2.56 4.57 2,960.00 40.66 278.28 2,721.35 245.28 -874.37 538.01 4.00 -2.50 4.73 Adjust TF to -30', for 300' 3,000.00 42.05 277.09 2,751.38 248.81 -900.56 556.47 4.00 3.48 -2.99 3,100.00 45.58 274.37 2,823.53 255.66 -969.43 606.52 4.00 3.53 -2.72 3,200.00 49.16 271.96 2,891.25 259.67 -1,042.87 661.92 4.00 3.59 -2.41 3,260.00 51.34 270.63 2,929.62 260.70 -1,088.98 697.63 4.00 3.62 -2.21 Adjust TF to 0', for 600' 3,282.36 52.23 270.63 2,943.45 260.90 -1,106.55 711.35 4.00 4.00 0.00 Camp SS 3,300.00 52.94 270.63 2,954.17 261.05 -1,120.56 722.29 4.00 4.00 0.00 3,400.00 56.94 270.63 3,011.61 261.95 -1,202.39 786.22 4.00 4.00 0.00 3,500.00 60.94 270.63 3,063.19 262.90 -1,288.03 853.12 4.00 4.00 0.00 3,600.00 64.94 270.63 3,108.68 263.88 -1,377.05 922.67 4.00 4.00 0.00 3,700.00 68.94 270.63 3,147.85 264.90 -1,469.04 994.53 4.00 4.00 0.00 3,800.00 72.94 270.63 3,180.50 265.94 -1,563.53 1,068.35 4.00 4.00 0.00 3,860.00 75.34 270.63 3,196.90 266.57 -1,621.23 1,113.43 4.00 4.00 0.00 Start 3°1100' OLS, -75' TF, for 300' 3,900.00 75.65 269.44 3,206.92 266.60 -1,659.96 1,143.93 3.00 0.78 -2.99 4,000.00 76.46 266.46 3,231.03 263.12 -1,756.94 1,222.49 3.00 0.81 -2.98 4,100.00 77.30 263.50 3,253.73 254.59 -1,853.94 1,304.18 3.00 0.84 -2.96 4,160.00 77.83 261.74 3,266.65 247.07 -1,912.04 1,354.60 3.00 0.87 -2.94 Hold for 10680' 4,200.00 77.83 261.74 3,275.08 241.45 -1,950.74 1,388.55 0.00 0.00 0.00 4,300.00 77.83 261.74 3,296.17 227.41 -2,047.48 1,473.43 0.00 0.00 0.00 4,400.00 77.83 261.74 3,317.25 213.36 -2,144.22 1,558.31 0.00 0.00 0.00 4,500.00 77.83 261.74 3,338.34 199.32 -2,240.95 1,643.18 0.00 0.00 0.00 4,600.00 77.83 261.74 3,359.42 185.27 -2,337.69 1,728.06 0.00 0.00 0.00 4,700.00 77.83 261.74 3,380.51 171.23 -2,434.43 1,812.94 0.00 0.00 0.00 4,800.00 77.83 261.74 3,401.59 157.18 -2,531.17 1,897.81 0.00 0.00 0.00 4,900.00 77.83 261.74 .3,422.68 143.14 -2,627.90 1,982.69 0.00 0.00 0.00 5,000.00 77.83 261.74 .3,443.77 129.09 -2,724.64 2,067.57 0.00 0.00 0.00 5,100.00 77.83 261.74 3,464.85 115.05 -2,821.38 2,152.44 0.00 0.00 0.00 5,200.00 77.83 261.74 3,485.94 101.01 -2,918.12 2,237.32 0.00 0.00 0.00 5,300.00 77.83 261.74 3,507.02 86.96 -3,014.85 2,322.20 0.00 0.00 0.00 5,400.00 77.83 261.74 3,528.11 72.92 -3,111.59 2,407.07 0.00 0.00 0.00 5,500.00 77.83 261.74 3,549.19 58.87 -3,208.33 2,491.95 0.00 0.00 0.00 5,600.00 77.83 261.74 3,570.28 44.83 -3,305.07 2,576.83 0.00 0.00 0.00 5,700.00 77.83 261.74 3,591.36 30.78 -3,401.80 2,661.71 0.00 0.00 0.00 5,800.00 77.83 261.74 3,612.45 16.74 -3,498.54 2,746.58 0.00 0.00 0.00 5,900.00 77.83 261.74 3,633.54 2.70 -3,595.28 2,831.46 0.00 0.00 0.00 6,000.00 77.83 261.74 3,654.62 -11.35 -3,692.02 2,916.34 0.00 0.00 0.00 6,100.00 77.83 261.74 3,675.71 -25.39 -3,788.75 3,001.21 0.00 0.00 0.00 6,200.00 77.83 261.74 3,696.79 -39.44 -3,885.49 3,086.09 0.00 0.00 0.00 6,300.00 77.83 261.74 3,717.88 -53.48 -3,982.23 3,170.97 0.00 0.00 0.00 6,400.00 77.83 261.74 3,738.96 67.53 4,078.97 3,255.84 0.00 0.00 0.00 6,500.00 7783 261.74 3,760.05 -81.57 4,175.70 3,340.72 0.00 0.00 0.00 5282019 8.16:46AM Page 5 COMPASS 5000 14 Build 85D ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: Planned Survey Measured Depth (usft) 6,600.00 6,700.00 6,800.00 6,900.00 7,000.00 7,100.00 7,200.00 7,300.00 7,400.00 7,500.00 7,600.00 7,700.00 7,800.00 7,900.00 8,000.00 8,100.00 8,200.00 8,300.00 8,342.03 C-50 8,400.00 8,500.00 8,600.00 8,700.00 8,800.00 8,900.00 9,000.00 9,100.00 9,200.00 9,300.00 9,400.00 9,500.00 9,600.00 9,700.00 9,800.00 9,900.00 10,000.00 10,100.00 10,200.00 10,300.00 10,400.00 10,500.00 10,600.00 10,700.00 10,703.83 C-371 Iceberg 10,800.00 10,900.00 11,000.00 11,100.00 11,200.00 11,300.00 11,400.00 OAKEDMPI ConocoPhillips Alaska Inc_Kupawk Kupanik River Unit_2 Kuparuk 2M Pad Rig: 2M-39 2M-39 2M-39 wpl7 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well Rig: 2M-39 210-39 actual @ 137.45usft (D19) 2M-39 actual @ 137.45usft (D19) True Minimum Curvature 528/2019 8:16:46AM Page 6 COMPASS 5000.14 Build 85D Vertical Vertical Dogleg Build Turn Inclination Azimuth Depth +N/ -S +Ei-W Section Rate Rate Rate (usft) (usft) (usft) (usft) (°1100us@) ('/100usft) (°/100usft) 77.83 261.74 3,781.13 -95.62 4,272.44 3,425.60 0.00 0.00 0.00 77.83 261.74 3,802.22 -109.66 -4,369.18 3,510.47 0.00 0.00 0.00 77.83 261.74 3,823.31 -123.70 4,465.92 3,595.35 0.00 0.00 0.00 77.83 261.74 3,844.39 -137.75 4,562.65 3,680.23 0.00 0.00 0.00 77.83 261.74 3,865.48 -151.79 4,659.39 3,765.10 0.00 0.00 0.00 77.83 261.74 3,886.56 -165.84 -4,756.13 3,849.98 0.00 0.00 0.00 77.83 261.74 3,907.65 -179.68 -4,852.87 3,934.86 0.00 0.00 0.00 77.83 261.74 3,928.73 -193.93 4,949.60 4,019.73 0.00 0.00 0.00 77.83 261.74 3,949.82 -207.97 -5,046.34 4,104.61 0.00 0.00 0.00 77.83 261.74 3,970.90 -222.02 -5,143.08 4,189.49 0.00 0.00 0.00 77.83 261.74 3,991.99 -236.06 -5,239.82 4,274.37 0.00 0.00 0.00 77.83 261.74 4,013.08 -250.10 5,336.55 4,359.24 0.00 0.00 0.00 77.83 261.74 4,034.16 -264.15 -5,433.29 4,444.12 0.00 0.00 0.00 77.83 261.74 4,055.25 -278.19 -5,530.03 4,529.00 0.00 0.00 0.00 77.83 261.74 4,076.33 -292.24 -5,626.77 4,613.87 0.00 0.00 0.00 77.83 261.74 4,097.42 -306.28 -5,723.50 4,698.75 0.00 0.00 0.00 77.83 261.74 4,118.50 -320.33 -5,820.24 4,783.63 0.00 0.00 0.00 77.83 261.74 4,139.59 -334.37 -5,916.98 4,868.50 0.00 0.00 0.00 77.83 261.74 4,148.45 -340.27 -5,957.63 4,904.17 0.00 0.00 0.00 77.83 261.74 4,160.67 -348.42 -6,013.72 4,953.38 0.00 0.00 0.00 77.83 261.74 4,181.76 -362.46 5,110.45 5,038.26 0.00 0.00 0.00 77.83 261.74 4,202.85 -376.50 -6,207.19 5,123.13 0.00 0.00 0.00 77.83 261.74 4,223.93 -390.55 -6,303.93 5,208.01 0.00 0.00 0.00 77.83 261.74 4,245.02 -404.59 -6,400.67 5,292.89 0.00 0.00 0.00 77.83 261.74 4,266.10 -418.64 -6,497.41 5,377.76 0.00 0.00 0.00 77.83 261.74 4,287.19 -432.68 6,594.14 5,462.64 0.00 0.00 0.00 77.83 261.74 4,308.27 446.73 6,690.88 5,547.52 0.00 0.00 0.00 77.83 261.74 4,329.36 -460.77 -6,787.62 5,632.39 0.00 0.00 0.00 77.83 261.74 4,350.44 474.81 -6,884.36 5,717.27 0.00 0.00 0.00 77.83 261.74 4,371.53 488.86 -6,981.09 5,802.15 0.00 0.00 0.00 77.83 261.74 4,392.62 -502.90 -7,077.83 5,887.02 0.00 0.00 0.00 77.83 261.74 4,413.70 -516.95 -7,174.57 5,971.90 0.00 0.00 0.00 77.83 261.74 4,434.79 -530.99 -7,271.31 6,056.78 0.00 0.00 0.00 77.83 261.74 4,455.87 -545.04 -7,368.04 6,141.66 0.00 0.00 0.00 77.83 261.74 4,476.96 -559.08 -7,464.78 6,226.53 0.00 0.00 0.00 77.83 261.74 4,498.04 -573.13 -7,561.52 6,311.41 0.00 0.00 0.00 77.83 261.74 4,519.13 -587.17 -7,658.26 6,396.29 0.00 0.00 0.00 77.83 261.74 4,540.21 -601.21 -7,754.99 6,481.16 0.00 0.00 0.00 77.83 261.74 4,561.30 -615.26 -7,851.73 6,566.04 0.00 0.00 0.00 77.83 261.74 4,582.38 -629.30 -7,948.47 6,650.92 0.00 0.00 0.00 77.83 261.74 4,603.47 643.35 -8,045.21 6,735.79 0.00 0.00 0.00 77.83 261.74 4,624.56 657.39 -8,141.94 6,820.67 0.00 0.00 0.00 77.83 261.74 4,645.64 -671.44 -8,238.68 6,905.55 0.00 0.00 0.00 77.83 261.74 4,646.45 -671.97 -8,242.39 6,908.80 0.00 0.00 0.00 77.83 261.74 4,666.73 -685.48 -8,335.42 6,990.42 0.00 0.00 0.00 77.83 261.74 4,687.81 699.53 6,432.16 7,075.30 0.00 0.00 0.00 77.83 261.74 4,708.90 -713.57 -8,528.89 7,160.18 0.00 0.00 0.00 77.83 261.74 4,729.98 -727.61 -8,625.63 7,245.05 0.00 0.00 0.00 77.83 261.74 4,751.07 -741.66 -8,722.37 7,329.93 0.00 0.00 0.00 77.83 261.74 4,772.15 -755.70 6,819.11 7,414.81 0.00 0.00 0.00 77.83 261.74 4,793.24 -769.75 -8,915.84 7,499.68 0.00 0.00 0.00 528/2019 8:16:46AM Page 6 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMP7 Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc Kuparuk TVD Reference: Project: Kuparuk River Unit_2 MD Reference: Site: Kuparuk 2M Pad North Reference: Well: Rig: 2M-39 Survey Calculation Method: Wellbore: 2M-39 Dogleg Design: 2M-39 wpl7 Depth ConocoPhillips Standard Proposal Report Well Rig: 210-39 2M-39 actual @ 137.45usft (D19) 210-39 actual @ 137.45usft (Dl 9) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inctination Azimuth Depth +N/ -S +El -W Section Rate Rate Rate (usftl (o) (^) (usft) (usft) (usft) (usft) (°1100usft) ("1100usft) (°1100usft) 11,600.00 77.83 261.74 4,835.41 -797.84 -9,109.32 7,669.44 0.00 0.00 0.00 11,700.00 77.83 261.74 4,856.50 -811.88 -9,206.06 7,754.32 0.00 0.00 0.00 11,800.00 77.83 261.74 4,877.58 -825.92 -9,302.79 7,839.19 0.00 0.00 0.00 11,900.00 77.83 261.74 4,898.67 -839.97 -9,399.53 7,924.07 0.00 0.00 0.00 12,000.00 77.83 261.74 4,919.75 4354.01 -9,496.27 8,008.95 0.00 0.00 0.00 12,100.00 77.83 261.74 4,940.84 -868.06 -9,593.01 8,093.82 0.00 0.00 0.00 12,200.00 77.83 261.74 4,961.92 -882.10 -9,689.74 8,178.70 0.00 0.00 0.00 12,300.00 77.83 261.74 4,983.01 -896.15 -9,786.48 8,263.58 0.00 0.00 0.00 12,400.00 77.83 261.74 5,004.10 -910.19 -9,883.22 8,348.45 0.00 0.00 0.00 12,415.91 77.83 261.74 5,007.45 -912.43 -9,898.61 8,361.96 0.00 0.00 0.00 Base Iceberg/Growler 12,500.00 77.83 261.74 5,025.18 -924.24 -9,979.96 8,433.33 0.00 0.00 0.00 12,600.00 77.83 261.74 5,046.27 -938.28 -10,076.69 8,518.21 0.00 0.00 0.00 12,700.00 77.83 261.74 5,067.35 -952.32 -10,173.43 8,603.08 0.00 0.00 0.00 12,800.00 77.83 261.74 5,088.44 -966.37 -10,270.17 8,687.96 0.00 0.00 0.00 12,900.00 77.83 261.74 5,109.52 -980.41 -10,366.91 8,772.84 0.00 0.00 0.00 13,000.00 77.83 261.74 5,130.61 -994.46 -10,463.65 8,857.71 0.00 0.00 0.00 13,100o0 77.83 261.74 5,151.69 -1,008.50 -10,560.38 8,942.59 0.00 0.00 0.00 13,200.00 77.83 261.74 5,172.78 -1,022.55 -10,657.12 9,027.47 0.00 0.00 0.00 13,300.00 77.63 261.74 5,193.87 -1,036.59 -10,753.86 9,112.34 0.00 0.00 0.00 13,400.00 77.83 261.74 5,214.95 -1,050.64 -10,850.60 9,197.22 0.00 0.00 0.00 13,500.00 77.83 261.74 5,236.04 -1,064.68 -10,947.33 9,282.10 0.00 0.00 0.00 13,600.00 77.83 261.74 5,257.12 -1,078.72 -11,044.07 9,366.98 0.00 0.00 0.00 13,700.00 77.83 261.74 5,278.21 -1,092.77 -11,140.81 9,451.85 0.00 0.00 0.00 13,800.00 77.83 261.74 5,299.29 -1,106.81 -11,237.55 9,536.73 0.00 0.00 0.00 13,900.00 77.83 261.74 5,320.38 -1,120.86 -11,334.28 9,621.61 0.00 0.00 0.00 13,995.19 77.83 261.74 5,340.45 -1,134.23 -11,426.37 9,702.40 0.00 0.00 0.00 C35 14,000.00 77.83 261.74 5,341.46 -1,134.90 -11,431.02 9,706.48 0.00 0.00 0.00 14,100.00 77.83 261.74 5,362.55 -1,148.95 -11,527.76 9,791.36 0.00 0.00 0.00 14,200.00 77.83 261.74 5,383.64 -1,162.99 -11,624.50 9,876.24 0.00 0.00 0.00 14,300.00 77.83 261.74 5,404.72 -1,177.03 -11,721.23 9,961.11 0.00 0.00 0.00 14,400.00 77.83 261.74 5,425.81 -1,191.08 -11,817.97 10,045.99 0.00 0.00 0.00 14,500.00 77.83 261.74 5,446.89 -1,205.12 -11,914.71 10,130.87 0.00 0.00 0.00 14,600.00 77.83 261.74 5,467.98 -1,219.17 -12,011.45 10,215.74 0.00 0.00 0.00 14,700.00 77.63 261.74 5,489.06 -1,233.21 -12,108.18 10,300.62 0.00 0.00 0.00 14,800.00 77.83 261.74 5,510.15 -1,247.26 -12,204.92 10,385.50 0.00 0.00 0.00 14,840.00 77.83 261.74 5,518.58 -1,252.87 -12,243.62 10,419.45 0.00 0.00 0.00 Start 4.1100' DLS, -99° TF, for 1217.67' 14,900.00 77.46 259.31 5,531.42 -1,262.52 -12,301.42 10,470.94 4.00 -0.61 -4.05 15,000.00 76.90 255.25 5,553.61 -1,283.98 -12,396.52 10,559.09 4.00 -0.56 -4.06 15,100.00 76.41 251.17 5,576.70 -1,312.08 -12,489.65 10,649.77 4.00 -0.50 4.08 15,200.00 75.98 247.07 5,600.58 -1,346.68 -12,580.36 10,742.56 4.00 -0.43 4.10 15,300.00 75.62 242.96 5,625.12 -1,387.60 -12,668.22 10,836.99 4.00 -0.36 4.11 15,400.00 75.33 238.84 5,650.20 -1,434.66 -12,752.79 10,932.60 4.00 -0.29 -4.12 15,500.00 75.12 234.71 5,675.72 -1,487.63 -12,833.66 11,028.93 4.00 -0.22 -4.13 15,600.00 74.97 230.58 5,701.53 -1,546.23 -12,910.43 11,125.52 4.00 -0.14 -4.14 15,700.00 74.91 226.43 5,727.53 -1,610.20 -12,982.74 11,221.88 4.00 -0.07 4.14 15,800.00 74.92 222.29 5,753.57 -1,679.21 -13,050.24 11,317.55 4.00 0.01 4.14 15,900.00 75.00 218.15 5,779.53 -1,752.93 -13,112.58 11,412.07 4.00 0.08 4.14 16,000.00 75.16 214.01 5,805.29 -1,831.01 -13,169.47 11,504.97 4.00 0.16 AA4 16,012.35 75.18 213.50 5,808.45 -1,840.94 -13,176.11 11,516.31 4.00 0.20 -4.13 THRZ 5/28/2019 8.16:46AM Page 7 COMPASS 5000.14 Build 85D 11011-1, ConocoPhillips Database: OAKEDMPI Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: Project: Kupamk River Unit -2 MD Reference: Site: Kuparuk 2M Pad North Reference: Well: Rig: 2M-39 Survey Calculation Method: Wellbore: 210-39 Rate Design: 2M-39 wpl7 (usft) Planned Survey ConocoPhillips Standard Proposal Report Well Rig: 2M-39 2M-39 actual @ 137.45usft (D19) 2M39 actual @j 137.45usft (D19) True Minimum Curvature Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NIS +E/ -W Section Rate Rate Rate (usft) (1) (_) (usft) (usft) (usft) (usft) ('1100usit) ell00usft) r/100usftj 16,057.67 75.28 211.63 5,820.00 -1,877.86 -13,199.69 11,557.63 4.00 0.22 4.13 Hold for 20'- 9 518" x 12 1/4" 16,077.67 75.28 211.63 5,825.08 -1,894.33 -13,209.84 11,575.76 0.00 0.00 0.00 Start 4°1100' DLS, .79.14° TF, for 511.33' 16,100.00 75.45 210.72 5,830.72 -1,912.82 -13,221.02 11,595.96 4.00 0.76 4.06 16,200.00 76.26 206.68 5,855.17 -1,997.85 -13,267.58 11,685.00 4.00 0.80 -4.04 16,300.00 77.13 202.67 5,878.20 -2,086.26 -13,308.19 11,771.43 4.00 0.87 4.01 16,400.00 78.06 198.69 5,899.69 -2,177.62 -13,342.67 11,854.84 4.00 0.93 -3.98 16,500.00 79.04 194.73 5,919.56 -2,271.47 -13,370.84 11,934.82 4.00 0.99 -3.96 16,589.00 79.96 191.23 5,935.78 -2,356.72 -13,390.49 12,002.79 4.00 1.03 -3.93 Fold for 469.2' 16,600.00 79.96 191.23 5,937.70 -2,367.35 -13,392.60 12,011.00 0.00 0.00 0.00 16,700.00 79.96 191.23 5,955.13 -2,463.93 -13,411.78 12,085.58 0.00 0.00 0.00 16,793.61 79.96 191.23 5,971.45 -2,554.35 -13,429.74 12,155.39 0.00 0.00 0.00 K-1 16,800.00 79.96 191.23 5,972.56 -2,560.51 -13,430.97 12,160.15 0.00 0.00 0.00 16,900.00 79.96 191.23 5,990.00 -2,657.10 -13,450.15 12,234.73 0.00 0.00 0.00 17,000.00 79.96 191.23 6,007.43 -2,753.68 -13,469.33 12,309.31 0.00 0.00 0.00 17,000.12 79.96 191.23 6,007.45 -2,753.79 -13,469.35 12,309.40 0.00 0.00 0.00 BHRZITKLB 17,058.20 79.96 191.23 6,017.58 -2,809.88 -13,480.50 12,352.71 0.00 0.00 0.00 Start 4°1100' DLS, .89.82° TF, or 104.24' 17,100.00 79.97 189.54 6,024.86 -2,850.37 -13,487.92 12,383.49 4.00 0.02 -4.06 17,162.44 80.00 187.00 6,035.72 -2,911.22 -13,496.76 12,427.91 4.00 0.05 4.06 Hold or 200' 17,200.00 80.00 187.00 6,042.24 -2,947.93 -13,501.26 12,454.07 0.00 0.00 0.00 17,300.00 80.00 187.00 6,059.61 -3,045.68 -13,513.27 12,523.71 0.00 0.00 0.00 17,362.44 80.00 167.00 6,070.45 -3,106.71 -13,520.76 12,567.19 0.00 0.00 0.00 Start 3.5°/100' DLS, 0.18° TF, for 346.43'. Top Kup - 7" x 8-1/2" by 9-718" 17,400.00 81.31 187.00 6,076.55 -3,143.50 -13,525.28 12,593.39 3.50 3.50 0.01 17,500.00 84.81 187.02 6,088.62 -3,242.01 -13,537.39 12,663.59 3.50 3.50 0.01 17,600.00 88.31 187.03 6,094.61 -3,341.06 -13,549.59 12,734.19 3.50 3.50 0.01 17,700.00 91.81 187.04 6,094.50 -3,440.30 -13,561.83 12,804.92 3.50 3.50 0.01 17,708.87 92.12 187.04 6,094.19 -3,449.09 -13,562.91 12,811.19 3.50 3.50 0.01 Hold or 730.96' 17,800.00 92.12 187.04 6,090.82 -3,539.47 -13,574.07 12,875.63 0.00 0.00 0.00 17,900.00 92.12 187.04 6,087.11 -3,638.65 -13,586.32 12,946.34 0.00 0.00 0.00 18,000.00 92.12 187.04 6,083.40 -3,737.83 -13,598.56 13,017.05 0.00 0.00 0.00 18,100.00 92.12 187.04 6,079.69 -3,837.01 -13,610.80 13,087.76 0.00 0.00 0.00 18,200.00 92.12 187.04 6,075.98 -3,936.19 -13,623.05 13,158.47 0.00 0.00 0.00 18,300.00 92.12 187.04 6,072.28 -4,035.37 -13,635.29 13,229.18 0.00 0.00 0.00 18,400.00 92.12 187.04 6,068.57 -4,134.54 -13,647.54 13,299.88 0.00 0.00 0.00 18,439.82 92.12 187.04 6,067.09 A, 174.04 -13,652.41 13,328.04 0.00 0.00 0.00 Start 3.5`/100' DLS, -153.96° TF, for 67.56' 18,500.00 90.23 186.11 6,065.86 4,233.81 -13,659.30 13,370.27 3.50 -3.15 -1.54 18,507.38 90.00 186.00 6,065.84 -4,241.15 -13,660.08 13,375.40 3.50 -3.15 -1.54 Adjust TF to -126.38`, for 45.82' 18,553.21 89.07 184.69 6,066.21 -4,286.77 -13,664.35 13,406.85 3.50 -2.03 -2.85 Hold or 530.92' 18,600.00 69.07 184.69 6,066.97 4,333.40 -13,668.18 13,438.58 0.00 0.00 0.00 18,700.00 89.07 184.69 6,068.59 4,433.05 -13,676.35 13,506.37 0.00 0.00 0.00 5r2ar2019 8:16:46AM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPI Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc_Kuparuk ND Reference: Project: Kupanik River Unit -2 MD Reference: Site: Kupawk 2M Pad North Reference: Well: Rig: 2M-39 Survey Calculation Method: Wellbore: 2M-39 Dogleg Design: 2M-39 wpl7 Depth Inclination Azimuth ConocoPhillips Standard Proposal Report Well Rig: 2M-39 210-39 actual @ 137.45usft (D19) 210-39 actual @ 137.45usft (D19) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +EI -W Section Rate Rate Rate (usft) (1) (1 (usft) (usft) (usft) (usft) ('/tOOusft) (`1100usft) ('1100usft) 18,900.00 89.07 184.69 6,071.83 -4,632.35 -13,692.71 13,641.97 0.00 0.00 0.00 19,000.00 89.07 164.69 6,073.45 4,732.01 -13,700.89 13,709.76 0.00 0.00 0.00 19,084.12 89.07 184.69 6,074.82 4,815.84 -13,707.77 13,766.80 0.00 0.00 0.00 Start 3.1100' DLS, 87.8° TF, for 110.33' 19,100.00 89.09 185.17 6,075.07 4,831.65 -13,709.14 13,777.61 3.00 0.12 3.00 19,194.45 89.20 188.00 6,076.48 4,925.46 -13,719.97 13,843.90 3.00 0.12 3.00 Adjust TF to 81.42', for 157.86' 19,200.00 89.22 188.16 6,076.56 4,930.95 -13,720.74 13,847.89 3.00 0.45 2.97 19,300.00 89.67 191.13 6,077.52 5,029.52 -13,737.50 13,921.78 3.00 0.45 2.97 19,352.32 89.91 192.66 6,077.71 -5,080.71 -13,748.29 13,961.80 3.00 0.45 2.97 Hold for 793.06' 19,400.00 89.91 192.68 6,077.79 -5,127.23 -13,758.76 13,998.69 0.00 0.00 0.00 19,500.00 89.91 192.68 6,077.95 -5,224.79 -13,780.72 14,076.06 0.00 0.00 0.00 19,600.00 89.91 192.68 6,078.11 -5,322.35 -13,802.67 14,153.42 0.00 0.00 0.00 19,700.00 89.91 192.68 6,078.27 -5,419.91 -13,824.63 14,230.79 0.00 0.00 0.00 19,800.00 89.91 192.68 6,078.43 -5,517.47 -13,846.59 14,308.15 0.00 0.60 0.00 19,900.00 89.91 192.68 6,078.59 -5,615.03 -13,668.54 14,385.52 0.00 0.00 0.00 20,000.00 89.91 192.68 6,078.75 -5,712.59 -13,890.50 14,462.88 0.00 0.00 0.00 20,100.00 89.91 192.68 6,078.91 -5,810.15 -13,912.45 14,540.25 0.00 0.00 0.00 20,145.37 89.91 192.68 6,078.98 -5,854.42 -13,922.41 14,575.35 0.00 0.00 0.00 Start 2°1100' DLS, -174.53' TF, for 95.84' 20,200.00 88.82 192.58 6,079.59 -5,907.72 -13,934.36 14,617.58 2.00 -1.99 -0.19 20,241.22 88.00 192.50 6,080.73 -5,947.94 -13,943.30 14,649.39 2.00 -1.99 -0.19 Adjust TF to -170.77', for 60.36' 20,300.00 86.84 192.31 6,083.38 -6,005.29 -13,955.92 14,694.64 2.00 -1.97 -0.32 20,301.58 86.81 192.31 6,083.46 -6,006.83 -13,956.25 14,695.85 2.00 -1.97 -0.32 Hold for 513.81' 20,400.00 86.81 192.31 6,088.94 -6,102.84 .13,977.20 14,771.46 0.00 0.00 0.00 20,500.00 86.81 192.31 6,094.51 -6,200.39 -13,998.48 14,848.29 0.00 0.00 0.00 20,600.00 86.81 192.31 6,100.08 -6,297.94 -14,019.76 14,925.12 0.00 0.00 0.00 20,700.00 86.81 192.31 6,105.65 -6,395.49 -14,041.04 15,001.95 0.00 0.00 0.00 20,800.00 86.81 192.31 6,111.21 -6,493.04 -14,062.32 15,078.77 0.00 0.00 0.00 20,815.39 86.81 192.31 6,112.07 5,508.06 -14,065.59 15,090.60 0.00 0.00 0.00 Start 2'/100' DLS, 1.15° TF, for 59.59' 20,874.99 88.00 192.33 6,114.77 -6,566.22 -14,078.30 15,136.42 2.00 2.00 0.04 Adjust TF to OAS', for 88.64' 20,90000 88.50 192.33 6,115.53 5,590.64 -14,083.63 15,155.66 2.00 2.00 0.02 20,963.83 89.77 192.34 6,116.49 -6,652.79 -14,097.23 15,204.64 2.00 2.00 0.02 Hold for 456.82' 21,000.00 89.77 192.34 6,116.64 -6,688.32 -14,105.01 15,232.64 0.00 0.00 0.00 21,100.00 89.77 192.34 6,117.03 -6,786.01 -14,126.38 15,309.63 0.00 0.00 0.00 21,200.00 89.77 192.34 6,117.43 -6,883.70 -14,147.76 15,386.62 0.00 0.00 0.00 21,300.00 89.77 192.34 6,117.83 -6,981.39 -14,169.14 15,463.60 0.00 0.00 0.00 21,400.00 89.77 192.34 6,118.22 .7,079.07 -14,190.52 15,540.59 0.00 0.00 0.00 21,420.45 89.77 192.34 6,118.30 -7,099.05 -14,194.89 15,556.34 0.00 0.00 0.00 Start 2'1100' DLS, .177.66' TF, for 53.68' 21,474.13 88.70 192.30 6,119.02 -7,151.49 -14,206.34 15,597.65 2.00 -2.00 -0.08 Adjust TF to -178.23', for 48.32' 21,500.00 88.18 192.28 6,119.72 -7,176.76 -14,211.85 15,617.54 2.00 -2.00 -0.06 21,522.45 87.73 192.27 6,120.52 -7,198.68 -14,216.62 15,634.80 2.00 -2.00 -0.06 Hold for 497.16' 21,600.00 87.73 192.27 6123.59 -7,274.40 -14,233.09 15,694.39 0.00 0.00 0.00 5/28/2019 8.16:46AM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips Database: Company: Project: Site: Well: Wellbore: Design: OAKEDMPI ConocoPhillips Alaska Inc_ Kuparuk River Unit_2 Kuparuk 2M Pad Rig: 2M-39 2M-39 2M-39 wp17 Planned Survey MD Reference: 2M-39 actual @ 137.45usft (D19) North Reference: Measured Survey Calculation Method: Minimum Curvature Section Depth inclination Azimuth Rate (usft( (usft) V) (1) (*1100usft) 21,700.00 87.73 192.27 -7,372.04 21,800.00 87.73 192.27 0.00 21,900.00 87.73 192.27 -14,275.56 22,000.00 87.73 192.27 0.00 22, 019.61 87.73 192.27 15,924.93 Start 2°1100' DLS, 0.76° TF, for 113.31' 0.00 22,100.00 89.34 192.29 16,001.78 22,132.92 90.00 192.30 6,140.18 Adjust TF to 1.36', for 74.72' -14,322.19 16,016.85 22,200.00 91.34 192.33 6,142.23 22,207.63 91.49 192.34 2.00 Hold for 262.37' 0.03 6,142.42 -7,794.79 22,300.00 91.49 192.34 2.00 22,400.00 91.49 192.34 -14,360.60 22,470.01 91.49 192.34 0.05 Start 2.1100' DLS, 176.33° TF, for 34.77' -14,362.23 22,500.00 90.90 192.37 0.05 22,504.77 90.80 192.38 16,232.56 Adjust TF to 177.38°, for 23.08' 0.00 0.00 22,527.86 90.34 192.40 16,309.51 Hold for 671.03' 0.00 0.00 6,134.61 22,600.00 90.34 192.40 0.00 22,700.00 90.34 192.40 -8,153.30 22,800.00 90.34 192.40 -2.00 22,900.00 90.34 192.40 -14,425.71 23,000.00 90.34 192.40 0.13 23,100.00 90.34 192.40 16,407.93 23,198.89 90.34 192.40 6,133.25 Start 2.1100' DLS, -161.87' TF, for 17.82' 16,463.52 23,200.00 90.32 192.39 6,132.66 23, 216.71 90.00 192.29 0.00 Adjust TF to -179.99°, for 88.75' 6,132.07 -8,446.29 23,300.00 88.33 192.29 0.00 23,305.46 88.23 192.29 -14,510.58 Hold for 933.79' 0.00 0.00 0.00 23,400.00 88.23 192.29 16,771.73 23,500.00 88.23 192.29 6,130.30 23,600.00 88.23 192.29 0.00 23,700.00 88.23 192.29 -8,835.87 23,800.00 88.23 192.29 0.00 23,900.00 88.23 192.29 -14,575.00 24,000.00 88.23 192.29 -0.62 24,100.00 88.23 192.29 16,938.69 24,200.00 88.23 192.29 6,130.87 24,239.25 88.23 192.29 2.00 Start 2.5°1100' DLS, 172.99' TF, for 13.12' 6,131.03 24,252.37 87.90 192.33 2.00 Adjust TF to 175.27°, for 15.76' 6,133.96 -9,032.31 24,268.13 87.51 192.36 0.00 Hold for 328.8' 6,137.06 -9,129.97 -14,638.85 24,300.00 87.51 192.36 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Rig: 2M-39 Kuparuk TVD Reference: 2M39 actual @ 137.45usft (D19) MD Reference: 2M-39 actual @ 137.45usft (D19) North Reference: True Survey Calculation Method: Minimum Curvature Vertical Vertical Dogleg Build Turn Depth -NI-S *El -W Section Rate Rate Rate (usft( (usft) (usft( (usft) (*1100usft) ("1100usft) (°I100usft) 6,127.54 -7,372.04 -14,254.32 15,771.24 0.00 0.00 0.00 6,131.50 -7,469.68 -14,275.56 15,848.09 0.00 0.00 0.00 6,135.45 -7,567.32 -14,296.79 15,924.93 0.00 0.00 0.00 6,139.40 -7,664.96 -14,318.03 16,001.78 0.00 0.00 0.00 6,140.18 -7,684.10 -14,322.19 16,016.85 0.00 0.00 0.00 6,142.23 -7,762.62 -14,339.29 16,078.66 2.00 2.00 0.03 6,142.42 -7,794.79 -14,346.30 16,103.99 2.00 2.00 0.03 6,141.63 -7,860.32 -14,360.60 16,155.61 2.00 2.00 0.05 6,141.45 -7,867.77 -14,362.23 16,161.48 2.00 2.00 0.05 6,139.04 -7,957.98 -14,381.96 16,232.56 0.00 0.00 0.00 6,136.43 -8,055.64 -14,403.32 16,309.51 0.00 0.00 0.00 6,134.61 -8,124.00 -14,418.27 16,363.38 0.00 0.00 0.00 6,133.98 -8,153.30 -14,424.68 16,386.47 2.00 -2.00 0.13 6,133.91 -8,157.95 -14,425.71 16,390.15 2.00 -2.00 0.13 6,133.68 -8,180.50 -14,430.66 16,407.93 2.00 -2.00 0.09 6,133.25 -8,250.96 -14,446.15 16,463.52 0.00 0.00 0.00 6,132.66 -8,348.63 -14,467.63 16,540.57 0.00 0.00 0.00 6,132.07 -8,446.29 -14,489.10 16,617.62 0.00 0.00 0.00 6,131.48 -8,543.96 -14,510.58 16,694.67 0.00 0.00 0.00 6,130.89 -6,641.62 -14,532.05 16,771.73 0.00 0.00 0.00 6,130.30 -8,739.29 -14,553.53 16,848.78 0.00 0.00 0.00 6,129.71 -8,835.87 -14,574.76 16,924.97 0.00 0.00 0.00 6,129.71 .8,836.95 -14,575.00 16,925.83 2.00 .1.90 -0.62 6,129.66 .8,853.28 -14,578.57 16,938.69 2.00 .1.90 -0.62 6,130.87 -8,934.64 -14,596.30 17,002.76 2.00 -2.00 0.00 6,131.03 -8,939.98 -14,597.46 17,006.96 2.00 -2.00 0.00 6,133.96 -9,032.31 -14,617.58 17,079.65 0.00 0.00 0.00 6,137.06 -9,129.97 -14,638.85 17,156.54 0.00 0.00 0.00 6,140.16 -9,227.63 -14,660.13 17,233.43 0.00 0.00 0.00 6,143.26 -9,325.29 -14,681.40 17,310.33 0.00 0.00 0.00 6,146.35 -9,422.95 -14,702.68 17,387.22 0.00 0.00 0.00 6,149.45 -9,520.61 -14,723.95 17,464.11 0.00 0.00 0.00 6,152.55 -9,618.27 -14,745.23 17,541.00 0.00 0.00 0.00 6,155.65 -9,715.94 -14,766.51 17,617.89 0.00 0.00 0.00 6,158.74 -9,813.60 -14,787.78 17,694.78 0.00 0.00 0.00 6,159.96 -9,851.93 -14,796.13 17,724.97 0.00 0.00 0.00 6,160.40 -9,864.74 -14,798.93 17,735.06 2.50 -2.48 0.31 6,161.03 -9,880.12 -14,802.29 17,747.18 2.50 -2.49 0.21 6,162.42 -9,911.23 -14,809.11 17,771.70 0.00 0.00 0.00 5/28/2019 8..16.'46AM Page 10 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Rig: 2M-39 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: 2M-39 actual @ 137.45usft (D19) Project: Kupawk River Unit -2 MD Reference: 2M-39 actual @ 137.45usft (D19) Site: Kuparuk 2M Pad North Reference: True Well: Rig: 2M-39 Survey Calculation Method: Minimum Curvature Wellbore: 2M-39 192.31 24,716.66 Design: 2M-39 wpl7 Adjust TF to - SS%far 110.73' 2.50 planned Survey Vertical Depth Measured (usft) (usft) Depth Inclination Azimuth (usft) (') r) 24,500.00 87.51 192.36 24,596.93 87.51 192.36 Start 2.5°1100' DLS, -1.2' TF, for 119.75' 24,600.00 87.58 192.36 24,700.00 90.08 192.31 24,716.66 90.50 192.30 Adjust TF to - SS%far 110.73' 2.50 24,800.00 92.58 192.23 24,827.41 93.27 192.21 Hold for 116.06' -14,898.19 18,092.30 24,900.00 93.27 192.21 24,943.47 93.27 192.21 Start 2*1100' DLS, -179.8° TF, for 153.34' 25,000.00 92.14 192.21 25,096.81 90.20 192.20 Adjust TF to 164.54°, for 11.22' 0.00 25,100.00 90.14 192.23 25,108.02 90.00 192.30 Hold for 433.57' 18,309.81 2.00 25,200.00 90.00 192.30 25,300.00 90.00 192.30 25,400.00 90.00 192.30 25,500.00 90.00 192.30 25,541.59 90.00 192.30 Stan 2°1100' DLS, 87.28° TF, for 2.68' 25,544.27 90.00 192.35 TD: 25544.27' MD, 6162.53' TVD 0.00 25,600.00 89.89 192.36 25,700.00 89.68 192.39 25,800.00 89.48 192.41 25,900.00 89.28 192.44 26,000.00 89.07 192.46 26,033.96 89.00 192.47 TD at 26033.96 0.00 -15,073.87 Vertical Vertical Depth +NIS (usft) (usft) 6,171.12 -10,106.40 6,175.34 -10,200.99 6,175.47 -10,203.99 6,177.50 -10,301.66 6,177.42 -10,317.95 6,175.18 -10,399.34 6,173.78 -10,426.09 6,169.64 -10,496.92 6,167.17 -10,539.34 6,164.50 -10,594.53 6,162.53 -10,689.12 6,162.52 -10,692.24 6,162.51 -10,700.08 6,162.51 -10,789.95 6,162.52 -10,887.66 6,162.52 -10,985.36 6,162.53 -11,083.07 6,162.53 -11,123.71 6,162.53 -11,126.32 6,162.58 -11,180.76 6,162.96 -11,278.44 6,163.69 -11,376.10 6,164.77 -11,473.76 6,166.21 -11,571.39 6,166.78 -11,604.55 5/28/2019 8:16:46AM Page 11 COMPASS 5000.14 Build 85D Vertical Dogleg Build Turn +E -W Section Rate Rate Rate (usft) (usft) (°/100usft) (°NOOusft) (°1100usft) -14,851.89 17,925.57 0.00 0.00 0.00 -14,872.62 18,000.14 0.00 0.00 0.00 -14,873.28 18,002.51 2.50 2.50 -0.05 -14,894.64 18,079.47 2.50 2.50 -0.05 -14,898.19 18,092.30 2.50 2.50 -0.05 -14,915.88 18,156.35 2.50 2.50 -0.08 -14,921.68 18,177.38 2.50 2.50 -0.08 -14,937.01 18,233.07 0.00 0.00 0.00 -14,946.19 18,266.42 0.00 0.00 0.00 -14,958.13 18,309.81 2.00 -2.00 -0.01 -14,978.59 18,384.17 2.00 -2.00 -0.01 -14,979.26 18,386.62 2.00 -1.81 0.86 -14,980.97 18,392.79 2.00 -1.81 0.86 -15,000.55 18,463.56 0.00 0.00 0.00 -15,021.85 18,540.49 0.00 0.00 0.00 -15,043.15 18,617.43 0.00 0.00 0.00 -15,064.45 18,694.36 0.00 0.00 0.00 -15,073.30 18,726.36 0.00 0.00 0.00 -15,073.87 18,728.42 2.00 0.09 2.00 -15,085.80 18,771.34 0.20 -0.20 0.02 -15,107.23 18,848.36 0.20 -0.20 0.02 -15,128.70 18,925.41 0.20 -0.20 0.02 -15,150.22 19,002.48 0.20 -0.20 0.02 -15,171.77 19,079.58 0.20 -0.20 0.02 -15,179.10 19,105.76 0.20 -0.20 0.02 5/28/2019 8:16:46AM Page 11 COMPASS 5000.14 Build 85D Design Targets ConocoPh illi ps ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Rig: 2M-39 Company: ConocoPhillips Alaska Inc_Kupawk TVD Reference: 2M-39 actual @ 137.45usft (D19) Project: Kupamk River Unil_2 MD Reference: 2M-39 actual @ 137.45usft (D19) Site: Kupamk 2M Pad North Reference: True Well: Rig: 2M-39 Survey Calculation Method: Minimum Curvature Wellbore: 2M-39 (usft) (usft) Design: 2M-39 wp17 0.00 0.00 Design Targets Target Name -hiVmiss target Dip Angle Dip Dir. TVD +W -S +FJ -W -Shape (1) (°) (usft) (usft) (usft) 2M-39 T03 020818 JM 0.00 0.00 6,065.84 -4,241.15 -13,570.08 - plan misses target center by 89.50usft at 18497.08usft MD (6065.87 TVD, -4230.90 N, -13658.99 E) -Circle (radius 100.00) 2M-39 TO1 Heel 020818 0.00 0.00 6,070.45 -3,206.71 -13,370.76 - plan misses target center by 161.53usft at 17442.84usft MD (6082.46 TVD, -3185.61 N, -13530.45 E) -Circle (radius 100.00) 2M-39 T04020818 JM 0.00 0.00 6,076.48 -4,925.46 -13,719.97 - plan hits target center -Circle (radius 100.00) 2M39 T05 020818 JM 0.00 0.00 6,080.73 -5,947.94 -13,943.30 - plan hits target center -Circle (radius 100.00) 21M39 T06020818 JM 0.00 0.00 6,114.77 -6,566.22 -14,078.30 - plan hits target center - Circle (radius 100.00) 2M-39 T07020818 JM 0.00 0.00 6,119.02 -7,151.49 -14,206.34 - plan hits target center - Circle (radius 100.00) 2M-39 T10 020818 JM 0.00 0.00 6,129.66 -8,853.28 -14,578.57 - plan hits target center -Circle (radius Wood) 210-39 T09020818 JM 0.00 0.00 6,133.91 -8,157.95 -14,425.71 - plan hits target center -Circle (radius 100.00) 2M39 T08020818 JM 0.00 0.00 6,142.42 -7,794.79 -14,346.30 - plan hits target center - Circle (radius 100.00) 210-39 T11013018 JM 0.00 0.00 6,160.40 -9,864.74 -14,798.93 - plan hits target center -Circle (radius 100.00) 2M-39 T14 013018 JM 0.00 0.00 6,162.53 -11,126.32 -15,073.87 - plan hits target center - Circle (radius 100.00) 2M-39 T13 013018 JM 0.00 0.00 6,162.53 -10,689.12 -14,978.59 - plan hits target center - Circle (radius 100.00) 2M-39 T15 Toe 013018, 0.00 0.00 6,166.78 -11,604.55 -15,179.10 - plan hits target center - Circle (radius 100.00) 2M39 T12 013018 JM 0.00 0.00 6,177.42 -10,317.95 -14,898.19 - plan hits target center - Circle (radius 100.00) &28/2019 8:16:46AM Page 12 COMPASS 5000.14 Build 85D �/ ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Rig: 2M-39 Vertical Company: ConocoPhillips Alaska Inc_Kuparuk Depth TVD Reference: 2M-39 actual @ 137.45usft (D19) Project: Kuparuk River Unit_2 Name MD Reference: 2M-39 actual 137.45usft (D19) Site: Kuparuk 2M Pad 580.29 North Reference: True Well: Rig: 2M-39 Base Perm Survey Calculation Method: Minimum Curvature 2,011.45 Wellbore: 2M-39 2,801.30 2,603.45 Base WS Design: 2M-39 wpl7 Camp SS 0.00 8,342.03 4,148.45 Casing Points 0.00 10,703.83 4,646.45 C-37 / Iceberg 0.00 12,415.91 Measured Vertical Base Iceberg/Growler 0.00 Casing Hole G-35 Depth Depth 16,012.35 5,808.45 Diameter Diameter 16,793.61 (usft) (usft) K-1 Name (in) On) BHRZ/TKLB 2,860.00 2,646.80 13 3/8" x 16" 6,070.45 13.325 16.000 16,057.67 5,820.00 9 5/8" x 121/4" 9,625 12.250 17,362.44 6,070.45 7" x B-1/2" by 9-7/8" 7.000 9.875 26,033.96 6,166.78 4-1/7' x 6-1/8" 4.500 6.125 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 450.85 450.45 T-3 580.29 579.45 K-15 1,492.46 1,477.45 Base Perm 2,066.63 2,011.45 W Sak D 2,801.30 2,603.45 Base WS 3,282.36 2,943.45 Camp SS 0.00 8,342.03 4,148.45 C-50 0.00 10,703.83 4,646.45 C-37 / Iceberg 0.00 12,415.91 5,007.45 Base Iceberg/Growler 0.00 13,995.19 5,340.45 G-35 0.00 16,012.35 5,808.45 THRZ 0.00 16,793.61 5,971.45 K-1 17,000.12 6,007.45 BHRZ/TKLB 17,362.44 6,070.45 Top Kup 5/28/2019 8:16:46AM Page 13 COMPASS 5000.14 Build 85D i� ConocoPhillips Database: OAKEDMPI Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc_Kuparuk ND Reference: Project Kupamk River Unit_2 MD Reference: Site: Kuparuk 2M Pad North Reference: Well: Rig: 2M-39 Survey Calculation Method: Wellbore: 2M-39 (usft) Design: 2M-39 wpl7 2,609.41 ConocoPhillips Standard Proposal Report Well Rig: 2M-39 2M-39 actual Q 137.45usft (D19) 2M-39 actual Q 137.45usft (D19) True Minimum Curvature Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +EI -W lush) (usft) (usft) (usft) Comment 2,809.37 2,609.41 235.21 -774.11 Adjust TF to 0°, for 50.63' 2,860.00 2,646.80 238.18 -808.13 Adjust TF to 0°, for 30' 2,890.00 2,668.95 239.94 -828.28 Start 4°/100' DLS, 130° TF, for 70' 2,960.00 2,721.35 245.28 -874.37 Adjust TF to -30°, for 300' 3,260.00 2,929.62 260.70 -1,088.98 Adjust TF to 0*, for 600' 3,860.00 3,196.90 266.57 -1,621.23 Start Y/100'OILS, -75°TF, for 300' 4,160.00 3,266.65 247.07 -1,912.04 Hold for 10680' 14,840.00 5,518.58 -1,252.87 -12,243.62 Start 4°/100' DLS, -99' TF, for 1217.67' 16,057.67 5,820.00 -1,877.86 -13,199.69 Hold for 20' 16,077.67 5,825.08 -1,894.33 -13,209.84 Start 4-/l00'DLS,-79.14°TF, for 511.33' 16,589.00 5,935.78 -2,356.72 -13,390.49 Hold for 469.2' 17,058.20 6,017.58 -2,809.88 -13,480.50 Start 4°/100' DLS, -89.82' TF, for 104.24' 17,162.44 6,035.72 -2,911.22 -13,496.76 Hold for 200' 17,362.44 6,070.45 -3,106.71 -13,520.76 Start 3.5°/100' DLS, 0.18" TF, for 346.43' 17,708.87 6,094.19 -3,449.09 -13,562.91 Hold for 730.96' 18,439.82 6,067.09 0,174.04 -13,652.41 Start 3.5°/100' DLS, -153.96° TF, for 67.56' 18,507.38 6,065.84 0,241.15 -13,660.08 Adjust TF to -125.38°, for 45.82' 18,553.21 6,066.21 0,286.77 -13,664.35 Hold for 530.92' 19,084.12 6,074.82 0,815.84 -13,707.77 Start 3"/100' DLS, 87.8° TF, for 110.33' 19,194.45 6,076.48 0,925.46 -13,719.97 Adjust TF to 81.42°, for 157.86' 19,352.32 6,077.71 -5,080.71 -13,748.29 Hold for 793.06' 20,145.37 6,078.98 -5,854.42 -13,922.41 Start 2°/100' DLS, -174.53° TF, for 95.84' 20,241.22 6,080.73 -5,947.94 -13,943.30 Adjust TF to -170.77°, for 60.36' 20,301.58 6,083.46 -6,006.83 -13,956.25 Hold for 513.81' 20,815.39 6,112.07 -6,508.06 -14,065.59 Start 2°/100' DLS, 1.15° TF, for 59.59' 20,874.99 6,114.77 -6,566.22 -14,078.30 Adjust TF to 0.45°, for 88.64' 20,963.63 6,116.49 -6,652.79 -14,097.23 Hold for 456.82' 21,420.45 6,118.30 -7,099.05 -14,194.89 Start 2"/100' DLS, -177.66° TF, for 53.68' 21,474.13 6,119.02 -7,151.49 -14,206.34 Adjust TF to -178.23°, for 48.32' 21,522.45 6,120.52 -7,198.68 -14,216.62 Hold for 497.16' 22,019.61 6,140.18 -7,684.10 -14,322.19 Start 2.1100' DLS, 0.76° TF, for 113.31' 22,132.92 6,142.42 -7,794.79 -14,346.30 Adjust TF to 1.36°, for 74.72' 22,207.63 6,141.45 -7,867.77 -14,362.23 Hold for 262.37' 22,470.01 6,134.61 -8,124.00 -14,418.27 Start 2°/100' DLS, 176.33"TF, for 34.77' 22,504.77 6,133.91 -8,157.95 -14,425.71 Adjust TF to 177.38°, for 23.08' 22,527.86 6,133.68 -8,180.50 -14,430.66 Hold for 671.03' 23,198.89 6,129.71 -8,835.87 -14,574.76 Start 2"/100'OILS, -161.87°TF, for 17.82' 23,216.71 6,129.66 -8,853.28 -14,578.57 Adjust TF to A 79.99°, for 88.75' 23,305.46 6,131.03 -8,939.98 -14,597.46 Hold for 933.79' 24,239.25 6,159.96 -9,851.93 -14,796.13 Start 2.5"/100' DLS, 172.99' TF, for 13.12' 24,252.37 6,160.40 -9,864.74 -14,798.93 Adjust TF to 175.27', for 15.76' 24,268.13 6,161.03 -9,880.12 -14,802.29 Hold for 328.8' 24,596.93 6,175.34 -10,200.99 -14,872.62 Start 2.5°/100' DLS, -1.2° TF, for 119.75' 24,716.68 6,177.42 -10,317.95 -14,898.19 Adjust TF to -1.85°, for 110.73' 24,827.41 6,173.78 -10,426.09 -14,921.68 Hold for 116.06' 24,943.47 6,167.17 -10,539.34 -14,946.19 Start 2°/100' DLS, -179.8° TF, for 153.34' 25,096.81 6,162.53 -10,689.12 -14,978.59 Adjust TF to 154.54', for 11.22' 25,108.02 6,162.51 -10,700.08 -14,980.97 Hold for 433.57' 25,541.59 6,162.53 -11,123.71 -15,073.30 Start 2°/100' DLS, 87.28" TF, for 2.68' 25,544.27 6,162.53 -11,126.32 -15,073.87 TD: 25544.27'MD, 6162.53'TVD 26,033.96 6,166.78 -11,604.55 -15,179.10 TD at 26033.96 5282019 8.16:46AM Page 14 COMPASS 5000.14 Build 85D ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit _2 Kuparuk 2M Pad Rig: 2M-39 2M39 50103132079500 2M-39 wp17 ConocoPhillips Clearance Summary Anticollision Report 28 May, 2019 Tray, cylinder North Proximity Scan an current Survey Data )North Reference) Reference Design: Kuparuk2MPad-Rig:2M-39-2M-39-2M-39wp17 weli Ccordlnates: Datum Height: 2M39 actual @ 137,d5ush )D19) Scan Range: 2,860.00to 26,034.32 daft. Measured Depth. Scan Radiusic2,79S76usfl. Llearan,aFactorrmmffis Unlimited Max Ellipse Separation is Unlimited Geodetic Scale Fador Applied Version: 5000.14 Build 850 Scan Type: _ Scan Type: " "® ConocoPhillips ConocoPhillips Anticollision Report for Rig: 2M-39 - 2M-39 ill C000coPhillips Alaska Inc_Kuparuk Kuparuk River Unit -2 Trial. Cylinder Nor01 Proximity San on Current Survey Dam (North Reference) 26230 4,288,16 1W.79 Reference Design: Kupamk2MPad-RIg:2M-99-2M-39-2M49wp12 3221 Clearance Factor Pass - 2,889.25 Scan Range: 2,860.0 to 26,034.32 usft Measured Depth. 2,88925 1,284.90 3,200.00 San Radius is 2,799.76 oft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation a Unlimited Pass - 4,208.93 Measured Minimum @Measuretl Ellipse @Measured Clearance Summary Based on Site Name Depth Clarence Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wetmore Name - Design (..ft) (usft) (u6ft) (usft) usft Kuparuk 2M Pad 214-01-214-01-214-01 214-02-2M-02-214-02 214-02-214-02-214-02 2M -03-2M-03-214-03 2M43 -2M -03-2M-03 214-04-2M*,l-214.4 214 -05 -2M -05-2M-05 2M46 -2M -06-2M-06 2M4)7 -2M -07-2M-07 214 -07 -2M -07-2M-07 214 -f0 -2M -10-2M-10 2M -11 -2M -11-2M-11 2M-11 -2M-11 -211 214-12.214-02-2M-12 2M -13 -2M -13-2M-13 2M -13.2M-13-214-13 2M-15.21il 214-15 214 -16 -2M -16-2M-16 2M -27-2M-27-2!1-27 2M -27-21487-2M-27 2N&48-21438-214-28 2M38 -2M-28-21488 21438-214-28-214.28 21]49-214-29-214-29 21439 -2M -29-2M-29 2M30 -2M -30-2M-30 2M30 -2M-30-211 2Md1- 2M-31 - 2M-31 4,26816 26230 4,288,16 1W.79 4,100.OD 3221 Clearance Factor Pass - 2,889.25 1,326.62 2,88925 1,284.90 3,200.00 31798 Ellipse Separation Pass - 4,208.93 2,19300 4,208.93 2,090.84 4,400.00 21.465 Clearance Factor Pass - 3,797.91 167.99 3,797,91 96.48 3,600.00 2.348 Centre Distance Pass - 3,877.85 173.71 3,82].05 9299 3,70.00 2.152 Clearance Factor Pass - 2,86000 2,815.82 2,86000 2,523.14 4,000.00 61.282 Clearance Factor Pass - 2,906.64 501.52 2,906.64 460.55 3,100.00 12,226 Clearance Factor Pass - 2,86000 1,265.93 2,860.00 1,224,42 3,300.00 30.4% Clearance Factor Pass - 2,098.32 1,841.31 2,89032 1,799.38 3,60000 43.913 Ellipse Separation Pass - 3,253.00 2,210.84 3,253.80 2,16000 4,100.00 43,493 Clearance Factor Pass - 2,903.26 1,04060 2,903.26 1,00084 3,40000 26.170 Clearance Factor Pass - 2,860.00 1,29526 2,88000 1.753.60 3,80000 43.099 Ellipse Separation Pass - 2,986.26 1,673.65 2,988.26 1,829.24 3,90000 42.192 Clearance Facer Pass - 2,929.40 1,206.79 2,929.40 1,172.98 3,50000 35692 Clearance Fetor Pass - 2,90863 265066 2,900.03 2,606.15 4,50000 59.552 Ellipse Separation Pass - 2,991.43 2,239.83 2,991.43 2,693.39 4,80000 59.005 Clearance Factor Pass - 2,914.23 1.346.48 2,914.23 1,312.18 3,600.0 39.249 Clearance Factor Pass - 2,960.00 2445.21 2,960.00 2,408.21 4,500.00 86.082 Clearance Factor Pass - 2,912.12 81890 2,917.17 572.37 2,900.00 14,903 Ellipse Separation Pasn- 4,249.65 96162 4,249.65 861.93 4,200.011 9.655 assume Factor Pass - 2,885.10 64894 2,085.10 81131 2,800.00 17243 Centre Distance Pass - 5,11182 698.12 5,11182 598.95 4]00.00 2.040 Elipse Separation Pass - 5,82102 78069 5,821.07 855.98 5,500.0 6.264 Clearance Factor Pass - 2,903.11 1,050.22 2,903.11 1,009.90 2,900.00 26,013 Ellipse Separation Pass - 4,26661 1,396.15 4,266.61 1,297.20 3,000.00 14.110 Clearance Factor Pass - 2,909.42 1,254.12 2,909.42 1,212.99 3000.00 30451 Ellipse Separation Pass - 4,216.20 1,782.05 4,216.20 1,68565 4,000.00 17.624 Clearance Factor Pass - 2,860.00 703.52 286000 656.12 3,100.00 14.042 Ellipse Separation Pass - 26 May, 2019- 826 Page 2of6 COMPASS ConocoPhillips ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit_2 Anticollision Report for Rig: 2M-39 - 2M-39 wp17 Tru. Cylinder North Proximity Scan on current Survey Data (North Reference) Reference Design: Kuparuk2MPad-Ri9:2M39-2M49-2M39WI7 Scan Range: 2,960.00 to 26,034.32 usft. Measured Depth. Scan Radius Is ZTS%76 usft, Clearance Factor tutor is Unlimited. Max Ellipse Separation Is Ungraded Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Dlatance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name -Wellbore Name - Design (.sit) (deal )usft) (usft) deft 21431-21431-214-31 9.464D4 1,96345 9,484.04 1818.78 9,500.00 5697 Clearance Factor Pass - 2M32 -21432-21432 2,860.00 1,918.Ofi 2,06000 189440 3,300.00 81.340 Ellipse Separation Pass - 2M32 -2M32 -2M-32 4,239.47 2,42372 4,239.47 2,334.91 4,000.00 27292 Clearance Factor Pass- 2M32.2M32Li-2M-32L1 2,860.01) 1,918.06 2,860.0 1,89448 3,300.00 81,348 Ellipse Separation Pass - 2M32 -214321-1-2143211 4,239.47 2,423.72 4,23947 2,33491 4,000.00 27,292 Clearance Factor Pasa- 21432-214-3211-01-2143211-01 2,860.00 1918.06 2,060.00 1.89440 3,300.00 81.348 Ellipse Separation Pass - 2M32 -214-3211-01-2143211-01 4,239.47 2,423.72 4,239.47 2,334.91 4,000.00 27,292 Clearance Factor Pass- 2M32-2M-32L1PB1-2h432LI PBI 2,860.00 1,91806 2,06000 1,894.48 3,300.00 81.348 Ellipse Sepamon Pass- 2M32-2M-32LlPBi-2M-32L1 PB1 4,239.47 2,423]2 4,239.47 2,334.91 4,000.00 27.292 Clearance Factor Pass - 2M32-2M-32L1PB2-2M-32LI P82 2,860.00 1.918.06 2,880.00 1,894.48 3,30000 81.348 Ellipse Separation Pass - 2M32-2M-32L1PB2-214-3211 PB2 4,239.47 2423.72 4,239.47 2,334.91 4,00000 27.292 Clearance Factor Pass - 2M33 -214-33-21433 2,885.79 1,557.11 2,885.79 1,510.69 3,400.00 33.545 Ellipse Separation Pass - 2M -33-2M-33-214-33 4,20192 2,007.91 4,201.92 1,897.85 4,10000 19.245 Clearance Factor Pass - 2M36 -21036-214-38 2,907.81 272.94 2,907.81 247.43 2,90000 10700 Ellipse Separation Pass - 2M36 -21036-214-36 4,225.85 378.02 4,225.85 285.32 4,20000 4.078 Clearance Factor Pass - 2M36-214-36PB1-2M36PB1 2,907.81 272.94 2.907.81 247.30 2,90000 10,646 Ellipse Separation Pass - 2M36-2M-36P91.2M-36PB1 4,206.01 377.72 4,206.01 284.05 4,200.00 4,032 Clearance Factor Pass - 21437 -214-37-2M-37 2,891.13 51155 2,891.13 48863 200000 22,320 Ellipse Separation Pass - 21437 -2M37-21437 10,09707 139800 10,097.07 999.17 10,00000 4.357 Clearance Factor Pass - 2M38 -21038-214-38 15901.11 330.19 15,901.11 148.48 16,50000 1.822 Centra Distance Pass - 2M38 -21438-21438 1$.99161 377.89 15,991.61 79.90 16,70000 1.266 Clearance Factor Pass - Plan :2M-40-PIan:2M-00-214i0wpi3 2,911]3 259.81 2,91113 23773 2,900.00 11.763 Ellipse Separation Pace - Plan :2M -40 -Plan: 214-00-2M-40"13 9,596SO 551.55 9,596.80 327.59 9,400.00 2.463 Clearence Factor Pass- Rig: 21439-2M-39PB1-2M-39PB1 3,201.21 25.31 3301.21 23.24 3,200.00 12.227 Cenae Distance Pass - Rig: 2M39-2M-39PB1-2M-39PBI Rig: 2M-39 - 2M-39PB1-2M-39PR Kuparuk 2S Pad 2S -14-2S-14-2514 26,029.52 1,917.34 26,029.52 1,64329 17,900.00 6.996 Clearance Factor Pass - 26 May, 2019- 6:26 Pa, 3 of COMPASS ConocoPhillips Antic olIision Report for Rig: 2M-39 - 2M-39 vvp17 Survey tool n(OOTam Frain To Survey/Plan Survey Tool luaa) loan) 171.07 1,44040 GVD-GC S 1,480.76 2,701.24 MMAFR2+SAG+MS 2,741.40 2,809.37 MWD 2,809.37 4,360.00 21,149 ap17 MWD OWSG 2,80937 16,057.87 21,1419 apt? MWD+IFR2+5AG+MS 16,05767 17,36244 2M4i9 wp17 MWD OWSG 16,057.67 17,36244 2M49 wp17 MWD+IFR2+SAG+MS 17,382.44 18,86244 26149 wp17 MVID OWSG 17,36244 26,033.96 2M -39a I7 MWD+IFR2+5AG+MS Ellipse error terms are wnelaWal across survey tool tiean points. Calculated ellipses incorporate surface snom Sspamfion is the equal Distance beMeen ellipsoids. Distance Between wines u the straight line distance beMeen wellbore centres. Cleamnce Factor = Distance Beneath Profiles I (Distance Behseen Profiles- Ellipse Separation). All station coo anstes aere calculaUal using the Minimum Curvature method ConocoPhillips Alaska Inc_Kuparuk Kupamk River Unit -2 26 May 2019 - &26 Page 4 06 COMPASS ConocoPhillips Alaska Inc_Kuparuk Kuparuk River Unit _2 Kuparuk 2M Pad Rig: 2M-39 2M-39 50103132079500 2M-39 wp17 ConocoPhillips Clearance Summary Anticollision Report 23 May, 2019 Tray. cylinder Nor1n Proximity Scan on current survey Data (Notln References Reference Design: Ku pawk 2M Pad - Rig: 2M -39 -2M -39-2M-39 wpl7 Wail coordinates: Datum Height. 2Md9 actual@ 137.0.5usft(D19) Scan Range: 2.86000 to 26,034.32 usft. Measured Depth, Scan Radius is 2,79916 usft. Clearance Factor cutoff is Unlimited Max Ellipse Separation is Unlimited Geodetic Scale Faclar Applied Version: 5000.14 Build: 85D Scan Type: Scan Type: 2500 c . ConocoPhillips .- ConocoPhillips Anticollision Report for Rig: 2M-39 - 2M-39 wpl7 ConocoPllillips Alaska Inc—Kuparuk Kuparuk River Unit -2 Tray. Cylinder North Proximity Scan on Current Survey DM (North Reference) 262.20 4,310.77 175.74 Riano.ce Design: Kuparuk 2M Patl - Rig: 2M49 -2M49. 21149 Wp17 3.033 Claimants Factor Pass - 2,85427 Scan Range: 2,860.00 to 26,034.32 usft. Measured Depth. 2,86427 1,247.41 3,150.00 Scan Radius is 2,799]6 usft. Clearance Factor outman Is Unlimited. Max Ellipse Separation is Unlimited Pass - 4,29726 Measured Minimum amms..rel Ellipse @Measured Clearance Summary Based on Silo Nem. Depth Distance Depth Separation Depth Factor Minimum Separation blaming Comparison Well Name - Wellbore Name - assign (usft) )usft) (usft) )usft) toff Kuparuk 2M Pad 211-01-2M-01-211-01 211-02-211-02-21142 2M -02 -2M -02-2M-02 2M -03-2M-03-211-03 2M -03-2M43.211-03 211 -04 -2M414 -2M-04 211-05-2M-05-2WM 2M -0e -2M-06-211-06 2M-06-211-06-21WW 2M -07 -2M -07-2M-07 2M-10. 2M-10-211-10 2M -10-211-10-2M-10 211-11 .2M -11 -2M -it 2M -11 -2M -11-2M-11 210.12-211-12-211-12 211-12-21442-211-12 2M -13 -2M -13-2M-13 2M-13-211-13-211-13 2M -15 -2M -15-2M-15 2M-15-211-15.211-15 2M -16 -2M -16-2M46 211-16-2M-16.211-16 2M -27-2M-27-211-27 211-27-2M-27-211.27 211 -28 -2M -28.2M-28 2M38 -2M -28-2M-28 2M -26-2M-28-211-26 2M-29-211-29-210-29 20 May. 2019- &25 4,31077 262.20 4,310.77 175.74 4,12500 3.033 Claimants Factor Pass - 2,85427 1,208.61 2,86427 1,247.41 3,150.00 31,275 Ellipse Separation Pass - 4,29726 2,271.50 4,297,26 2,163.42 4,52500 21.017 Clearance Factor Pass - 3,818.93 167.40 3,818.93 93.D1 3,62560 2.249 Centre Distance Pass - 3,859]2 17026 3,059.72 91.03 3,675.00 2.149 Clearance Factor Pass - 2,869.11 2,571.71 2.869.11 2,52890 3,95).00 60071 Clearance Factor Pass - 2,879.10 488.68 2,079.10 448.28 3,07560 12.095 Clearance Factor Pass - 2,861.51 1,265.93 2,061.51 1]24.39 3,300.00 30.474 Ellipse Separation Pass - 2,949.92 1,319.93 2,949.92 1,276.58 3,375.00 30.446 Clearance Factor Pass - 2,86115 1,706.85 2,861.15 1,74560 3,525.00 43.325 Clearance Factor Pass - 2,869.89 1,024.69 2,86989 955.65 3,37500 26,264 Ellipse Separa118n Pass - 2,956.76 1,056.17 2.956]6 1,015.16 342500 25.757 Clearance Factor Pass - 2,867.36 1.79524 2,867.36 1,753.43 3,800.00 42.930 Ellipse Separation Pass - 2,969.07 1,83475 2,969.7 1,79074 3,850.00 41.697 Clearance Factor Pass - 2,873.21 1.177.61 2,87321 1,14465 3,45000 35.733 Ellipse Separation Pass - 2,960.00 1,22080 2,96000 1,186.69 352500 35.607 Clearance Factor Pass - 2,869.11 2,65109 2,869.11 2,607.48 4,500.00 60.801 Ellipse Sepamgon Pass - 2,975.64 2,673.25 2,97564 2,627.22 4,525.00 58.075 Clearance Factor Pass - 2,M.48 1,335.19 2,877.48 1;301.44 3,57500 39.558 Ellipse Separation Pass - 2,959.50 1,357.34 2,959.50 1,322.32 3,62500 38757 Clearance Factor Pass - 2,866.40 2,42335 2,866.0 2,38801 4,475.00 68,569 Ellipse Separation Pass - 2,96o60 2,44521 2.960.00 2,40821 4,500.00 66,082 Clearence Factor Pass - 2,8&.90 604.84 2,860.90 564.02 2,850.00 14.619 Ellipse Separation Pass - 4,269.55 969.37 4,269.55 06095 4,225.& 9,653 Clearance Factor Pass - 2,86462 640.97 2,864.62 03.76 2,775011 17.228 Centre Distance Pass- 5,135.47 699.02 5,135.47 598.94 4)25.00 6964 Ellipse S.paretion Pass - 5,871.07 780.59 5,871.07 6550 5.51)().00 6264 Clearance Factor Pass - 2,875.02 1,023.27 2,875.02 983.42 2.850.00 25,683 Ellipse Separation Pass Page 2 orb COMPASS ConocoPhillips ConocoPhillips Alaska Inc Kuparuk Kuparuk River Unil_2 Anticollision Report for Rig: 2M-39 - 2M-39 wp17 Tay. Cylinder North Proximity Scan on Current Survey Darts )North Reference) Reference Design: Kuparuk 2M Pad - Rig: 2M -39 -2M39 -2M-39 wp17 Sean Range: 2,880.00 to 28,03432 watt Measured Depth. Scan Radius Is 2,799.76 ustt. Clearance Factor cutoff Is Unlimited Max Ellipse Separation is Unlimited Measured Minimum @Meuured Ellipse @Measured Clearance Summary eased on Site Name Depth Ustance Depth Separation Depth Factor Minimum Separation Warring Comparison Weil Name -Waltham Name - Design loan) (astt) (ush) Man) ostt 2M,29 -2M89 -2M-29 4,288.64 1.401,36 4288.64 1,299.21 3,82500 13,718 Clearance Factor Pass - 2M30 -26130-26130 2,85933 1,210.38 2869.33 1,170.14 2,925.00 30.083 Ellipse Separation Pass - 2M -30-2M-30-261-30 4,290.30 1,83330 4,29030 1,726.69 4,100.00 17,211 Clearance Factor Pass - 2hi-261-31-21031 2,867.58 703A0 2,867.58 655.90 3,10000 14.788 Ellipse Separation Pass - 2M31 -261-31-26131 9,415.94 1,951.32 9,415.94 1,608.77 9,450.0 5,695 Clearance Factor Pass- 2M32 -2M -32-2M-32 2,870.46 1,896.11 2,870.46 4,87443 3,275.00 80,156 Ellipse Separation Pass - 2M32 -2M -32-2M32 4,294.17 2,465.03 4,294.17 2,372.31 4,075.00 26.588 Clearance Factor Pass - 2M32 -2M -32L1 -2M -32L1 2,870.46 1,898.11 2,870.46 1,87/43 3,275.0 SCM Ellipse Separagon Pass - 2M42 -2M -32L1 -2M -32L1 4,294.17 2,465.03 4294.17 2,372.31 4,075.0 26,588 Cleamnce Factor Pass - 2M32 -2M -32L1-01-2613211-01 2,87046 1,898.11 2,870A6 1,87443 3,275.00 80.156 Ellipse Separation Pass - 2M32 -2613211-01-261-3211-01 4,294.17 2,465.03 4294.17 2,372.31 4,075.00 26588 Clearance Factor Pass- 2M32-2M-32Li P81-2M-32Li FIB 2,07046 1,898.11 2,87046 1,874.43 3,275.0 00.156 Ellipse Separation Pass- 2M32-2M-32Li Pet -2M -32L1 Pill 4,294.17 2,455.03 4,294.17 2,372.31 4,075.00 26.588 Clearance Factor Pass - 2M32 -2M -32L1 PB2-2M-32L1 P132 2,87046 1,898.11 2,870A6 1,874.43 3,275.00 80.158 Ellipse Separation Pass - 2M3 2 -2 61321_1 P82-2M32L1 PB2 4,294.17 2,/65.03 4,294.17 2,37231 4,075.0 26588 Clearance Factor Pass - 2M33 -21033-2M-33 2,876.11 1,539.20 2,876.11 1,49304 3,375.00 33.344 Ellipse Separation Pass- 2Md3-261.33-211 4,287.69 2049.41 4,287.69 1,933.17 4,200.00 17.630 Clearance Factor Pasa- 2M36-26136-26136 2,88154 269.26 2,881.64 244.22 2,875.00 10.755 Ellipse Separagon Pass - 2M36-2M-36-2M_M 4,294.59 388.04 4,294.59 291.06 4,275.0 3.947 Clearance Factor Pass- 2M-36-2M-36PS1-2M-35PB1 2,881.64 269.26 2,881.64 244.09 2,87500 10]00 Ellipse Separation Pass - 2M-36-2M36PB1-2M-36PB1 4,298.06 396.64 4,295.06 298.34 4,300.00 3.955 Clearance Factor Pass- 2M3L2M37-2M-37 2,865.64 506]8 2,865.64 484.31 2,77500 22,548 Ellpse Separation Pass - 2M37 -26137-26137 10,097.07 1,29600 10,097.07 999.17 10,000.00 4,357 Clearance Factor Pass- 2M38 -2M-38-26138 15001.11 330.19 15901.11 146.97 16,500.00 1022 Centre Distance Pass - 2MJ8-2M-38-26138 15,982.00 367.16 15,90200 79.36 16,075.00 1.276 Ellipse Separation Pass - 2M -38-2M-38-21038 15,99157 377.08 15,991.67 79.83 16,700.0 1268 Clearance Factor Pass - Plan :2M -40 -Plan : 2M40-2M40wp13 2,868.97 245.31 2,060.97 223.52 2,850.00 11,260 Ellipse Separation Pass - Plan :2M -40 -Plan: 2M40-21,1140wp13 9,57202 550.10 9,572.02 326.73 9,37500 2463 Clearance Factor Pass- Rig: 261-39-2M39PB1-2M-39PB1 3,12543 18.63 3,12543 16.52 3,125.00 8830 Centre Distance Pass - Rig: 2M-39- 2M-39PB1- 2M-39PB1 - - 28 May, 2019- 825 Page3of6 COMPASS `I ConocoPhillips Anticollision Report for Rig: 2111 - 2M-39 wp17 ConceoPhillips Alaska Inc_Kuparuk Kuparuk River Unit_2 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Survey Tool (usft) (usft) ReferenceDesign: Kupamk2M Pad -Rig: 2M39 -2M39 -2M-39 wp17 GYD-GCSS 1,480,76 2,70124 MWn+IFR2+SAG+MS Scan Range: 2,860.00 to 28,034.32 oak Measured Depth. MWD 2,809.37 4,360.00 21a3g"17 MWD OWSG Scan Radius is 2,799.76 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited MWD#IFR2+SAG+MS 16,057.67 17,362.44 2M-39wp17 Measured Minimum ®Measured Ellipse ®Measured Clearance Summary Based on She Name Depth Distance Depth Separation Depth Factor Minimum Separation vlaming Compatlsod Well Name - Wellbore Name - design (usft) (usft) (usft) (..ft) use Rig: 2M-39-2M-39PB1-2M-39PB1 Dlatunce Between centres u Me sought line distance behaeen wellbore centres. Clearance Factor= Distance Indianian Profiles I (Distance BeN.reen Prones - Ellipse Separation). All station candidates were calculated using the Minimum Comate method. - - Kuparuk 2S Pan 25-14-25-14-2514 26,029.52 1,817,34 26,029.52 1,64329 17,900.00 6.9% Clearance Factor Survey tool orooram From To Sumeyfi len Survey Tool (usft) (usft) 171.07 1,440A0 GYD-GCSS 1,480,76 2,70124 MWn+IFR2+SAG+MS 2,741.40 2,809.37 MWD 2,809.37 4,360.00 21a3g"17 MWD OWSG 2,809.37 16,057.67 2M39wp17 MWD#IFR2+SAG+MS 16,057.67 17,362.44 2M-39wp17 MMOWSG 16,05767 17,362.44 2139 wp17 MWO+IFR2+SAG+MS 17,362.4 18,862.44 21,139 wp17 MWD OWSG 17,362.44 28,033.96 2M-39 ml MWD+IFR2+SAG+MS Ellipse error lams are correlated across survey seal tie dpoints. Cekulated eilipses incapoate surras emors. Separation is the actual distance l ttween ellipsoids. Dlatunce Between centres u Me sought line distance behaeen wellbore centres. Clearance Factor= Distance Indianian Profiles I (Distance BeN.reen Prones - Ellipse Separation). All station candidates were calculated using the Minimum Comate method. Pass - 28 May 2019 - 825 Page 4 of 6 COMPASS 8:29, May 2e 2019 2M-39 wp17 Ladder View m�N n m a N a w a N N N 300 1, — c 0 R I N � m--.-. 150 - -. --- 0 c V Equivalent Magnetic Distance 3500 7000 10500 14000 17500 21000 24500 Measured Depth SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool VD MD Name 171.07 1440.40 2M-39 Srvy 1 - SLB GWD70 (2ffa99B4$S 2646.80 2860.00 13 3/8" x 16" 1480.76 2701.24 2M-39 Srvy 2 - SLB _MWD+GL%W(GRR? +MS 5820.0016057.67 9 5/8" x 12 1/4" 2741.40 2809.37 2M-39 Srvy 3 - SLB_MWD+SRG{mM-39PB1) 6070.4517362. 74 x 8-1/2" by 9-7/8" 2809.37 4360.00 2M-39 wp17 (2M-39) MWD OWSG 6166.7826033.96 4-1/2" x 6-1/8" 2809.3716057.67 2M-39 wp17 (2M-39) MWD+IFR2+SAG+MS 16057.6717362.44 2M-39 wp17 (2M-39) MWD OWSG 46@57.6717362.44 2M 39 wp!7 (2M 39) M�k9-IFR2-9AG,M9 17362.4418862.44 2M-39 wp17 (2M-39) MWD OWSG 17362.4426033.96 2M-39 wp17 (2M-39) MWD+IFR2+SAG+MS 20- 0 Q. Q.co I a � L N I w10 - — — U 0 >v c U Equivalent Magnetic Distance 0 2875 2900 2925 2950 2975 3000 Partial Measured Depth e:a7my o zo+e - 2M-39 wp17 Ladder View M mm APPLIED■ N N 300 i ----- _0 o f m d I v ac i 150 _ -- U o i � w I U i Equivalent Magnetic Distance 0 3500 7000 10500 14000 17500 21000 24500 Measured Depth SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool VD MD Name 171.07 1440.40 2M-39 Srvy 1 - SLB GWD70 (2W4398B1,$S 2646.80 2860.00 13 3/8" x 16" 1480.76 2701.24 2M-39 Srvy 2 - SLB _MWD+G (QRR ¢+MS 5820.0016057.67 9 5/8" x 12 1/4" 2741.40 2809.37 2M-39 Srvy 3 - SLB_MWD+SAGNOM-39PB1) 6070.4517362.44 x 8-1/2" by 9-7/8" 2809.37 4360.00 2M-39 wp17 (2M-39) MWD OWSG 6166.7826033.96 4-1/2" x 6-1/8" 2809.3716057.67 2M-39 wp17 (2M-39) MWD+IFR2+SAG+MS 16057.6717362.44 2M-39 wp17 (2M-39) MWD OWSG 17362.4418862.44 2M-39 wp17 (2M-39) MWD OWSG 17362.4426033.96 2M-39 wp17 (2M-39) MWD+IFR2+SAG+MS 20– 0 – — c .0 m a i I d N w 10 ._ i o I I i U Equivalent Magnetic Distance 0 I 2875 2900 2925 2950 2975 3000 Partial Measured Depth 8:39, May 28 2919 2M-39 wp17 TC View SURVEY PROGRAM SECTION DETAILS From To Tool MD Inc Azi TVD Deg TFace Target Annotation 171.071440.40 GYD-GC-SS 2809.37 42.41 274.992609.41 0.00 0.00 Adjust TF to 0°, for 50.63' 1480.762701.24 MWD+IFR2+SAG+MS 2860.00 42.41 274.99 2646.80 0.00 0.00 Adjust TF to O°, for 30 2741.402809.37 MWD 2890.00 42.41 274.99 2668.95 0.00 0.00 Start 4°/100' DLS, 130° TF, for 70' 2809.374360.00 MWD OWSG 2960.00 40.66 278.28 2721.35 4.00 130.00 Adjust TF to -30°, for 300' 2809.3{5057.67 MWD+IFR2+SAG+MS 3260.00 51.34 270.63 2929.62 4.00 -30.00 Adjust TF to 0°, for 600' 16057.617362.44 MWD OWSG 3860.00 75.34 270.63 3196.90 4.00 0.00 Start 3°/100' DLS, -75° TF, for 300' 16057.617362.44 MWD+IFR2+SAG+MS 4160.00 77.83 261.74 3266.65 3.00 -75.00 Hold for 10680' 17362.408862.44 MWD OWSG 14840.00 77.83 261.74 5518.58 0.00 0.00 Start 4°/100' DLS, -99° TF, for 1217.67' 17362.426033.96 MWD+IFR2+SAG+MS 16057.6775.28211.635820.00 4.00-99.00 Hold for 20' 16077.67 75.28 211.63 5825.08 0.00 0.00 Start 4°/100' DLS, -79.14° TF, for 511.33' 16589.00 79.96 191.23 5935.78 4.00 -79.14 Hold for 469.2' 17058.20 79.96 191.23 6017.58 0.00 0.00 Start 4°1100' DLS, -89.82° TF, for 104.24' 17162.44 80.00 187.00 6035.72 4.00 -89.82 Hold for 200' 17362.44 80.00 187.00 6070.45 0.00 0.00 Start 3.5°/100' DLS, 0.18° TF, for 346.43' 17708.86 92.12 187.04 6094.19 3.50 0.18 Hold for 730.96' 18439.82 92.12 187.04 6067.09 0.00 0.00 Start 3.5°/100' DLS, -153.96° TF, for 67.56' 18507.38 90.00 186.00 6065.84 3.50-153.96 2W39 T03 020818 JMAdjust TF to -125.38°, for 45.82' 18553.21 89.07 184.69 6066.21 3.50-125.38 Hold for 530.92' 19084.12 89.07 184.69 6074.82 19194.45 89.20 188.00 6076.48 19352.32 89.91 192.686077.71 0.00 0.00 Start 3°/100' DLS, 87.8° TF, for 110.33' 3.00 87.80 2M-39 T04 020818 JMAdjustTF to 81.42°, for 157.86' 3.00 81.42 Hold for 793.06' CASING DETAILS TVD MD Name 20145.37 89.91 192.68 6078.98 0.00 0.00 Start 2°1100' DLS, -174.53° TF, for 95.84' 2646.86860.00 13 3/8" x 19' 20241.22 88.00 192.50 6080.73 2.00-174.53 2M-39 T05 020818 JMAdjust TF to -170.77°, for 60.36' 5820.115057.679 518" x 12 i/4" 20301.58 86.81 192.31 6083.46 2.00-170.77 Hold for 513.81' 6070.71M61'.443-1/2" by 9-718" 20815.39 86.81 192.31 6112.07 0.00 0.00 Start 2°/100' DLS, 1.15° TF, for 59.59' 616626(13396 4-112" x 6-1/8" 20874.99 88.00 192.33 6114.77 2.00 1.15 2M-39 T06 020818 JMAdjust TF to 0.45°, for 88.64' 20963.63 89.77 192.34 6116.49 2.00 0.45 Hold for 456.82' 21420.45 89.77 192.34 6118.30 0.00 0.00 Start 2°/100' DLS, -177.66° TF, for 53.68' 21474.13 88.70 192.30 6119.02 2.00-177.66 2M-39 T07 020818 JMAdjust TF to -178.23°, for 48.32' 21522.45 87.73 192.27 6120.52 2.00-178.23 Hold for 497.16' 22019.61 87.73 192.27 6140.18 0.00 0.00 Start 2°/100' DLS, 0.76° TF, for 113.31' 22132.92 90.00 192.30 6142.42 2.00 0.76 21.1-39 TOB 020818 JMAdjust TF to 1.36°, for 74.72' 1. 22207.63 91.49 192.34 6141.45 2.00 1.36 Hold for 262.3T 22470.00 91.49 192.34 6134.61 0.00 0.00 Start 2°/100' DLS, 176.33° TF, for 34.77 22504.77 90.80 192.386133.91 2.00 176.33 2M-39 T09 020818 JMAdjust TF to 177.38°, for 23.08' 23198.89 9 34 192.406129.71 0.00 0.00 Start 2°/100' DLS, -161. 7o TF, for 17.82' 2 M 03 J 23216 719 00 192.29 6129.66 2.00-161.87 2M-39 T70 020818 JMAdjusl TF to -179.99°, 88.75' 11 .03 2.00-179.99 Hold for 933.79' _ 23T!32: 00 0.00 Start 2.5°/100' DLS, 17 99° TF, for 13.12' 330 - 24252 37 B 90 19233 2.9 2W39 T71 013018 JMAdjust TF to 175.27°, fo VV Hold for 328.8' 15.76' - _ ,11426E 13 87 5117 �22 24596.93 8 51-1 2 36 617sT. Start 2.5°1100' DLS-1. TF, for 19.75' r _ 24716 68 9 50 192 30 617742 2 66, 1 20 - 39 T12 013018 JMAdjust F to .1.85 -,'for 0.73' 2809 ' f 2482741 927192 21 6173 78 24943-4.Z- 9i.27-LaZ 21 6167 17 �SU968 9d. 2�7)6230B162S3 2 50 - 9,85, 000 0 20017980 3 13018 Hold for 116.06' Start 2°/100 DLS 179 JMAdjust TF to 15454°, to o 201619153.31V 1122' 2990- 2990 3180 2510£ 2 90 00 192 30 6162'51- 554169 90 00 192 3G 6162 53 2 00 154 54 Hold for 433.57' �Q0 0 00 Start 2°/100 DLS, 87 2 TF, for 2.68' / i -.° '' __ Z�9C4001923561625s 61667 - 04_79247 6166 70 �t I00 :87.28 2M-39 0 C I?3,25 2M 39 T ToF > B JMTD: 2554427MD, 610 01AfIPrHt 26033.96 OV 5334N - 300 3360 3550 3550 - 3730 RM 3730 3920 %- �� 3920 - 4100 4100 - 5010 \ 5010 5930 5930 - 6840 270 6840 - 7750 7750 - 8660 - 8660 9570 ��•.� ��`„ - �s jII 9570 10490 10490 - 11400 ' 11400 - 13230 240�y 1�M �� 120 13230 - 15060 I ��i! 15060 - 16890 1P2I / y 16890 - 18720 FF 18720 - 20550 % 20550 22370 210 22370 24210 2M-39PB1 24210 - 26034 180 8:0, May 28 2018 f 2M-39 wp17 TC View SURVEY PROGRAM SECTION DETAILS From To Tool MD Inc Azi TVD Dleg TFace Target Annotation 171.071440.40 GYD-GC-SS 2809.37 42.41 274.992609.41 0.00 0.00 Adjust TF to D. for 50.63' 1480.762701.24 MWD+IFR2+SAG+MS 2860.00 42.41 274.99 2646.80 0.00 0.00 Adjust TF to 0°, for 30' 2741.402809.37 MWD 2890.00 42.41 274.99 2668.95 0.00 0.00 Start 4°/100' OLS, 130° TF, for 70' 2809.374360.00 MWD OWSG 2960.00 40.66 278.28 2721.35 4.00 130.00 Adjust TF to -30°, for 300' 2809 3V5057.67 MWD+IFR2+SAG+MS 3260.00 51.34 270.63 2929.62 4.00 -30.00 Adjust TF to 0°, for 600' 16057.697362.44 MWD OWSG 3860.00 75.34 270.63 3196.90 4.00 0.00 Start 3°/100' OLS, -75° TF, for 300' 16057.697362.44 MWD+IFR2+SAG+MS 4160.00 77.83 261.74 3266.65 3.00 -75.00 Hold for 10680' 17362.4118862.44 MWD OWSG 14840.00 77.83 261.74 5518.58 0.00 0.00 Start 4°/100' OLS, -99' TF, for 1217.6T 17362.426033.96 MWD+IFR2+SAG+MS 16057.67 75.28 211.63 5820.00 4.00 -99.00 Hold for 20' 16077.67 75.28 211.63 5825.08 0.00 0.00 Start 4°/100' OLS, -79.14° TF, for 511.33' 16589.00 79.96 191.23 5935.78 4.00 -79.14 Hold for 469.2' 17058.20 79.96 191.23 6017.58 0.00 0.00 Start 4°/100' OLS, -89.82° TF, for 104.24' 17162.44 80.00 187.00 6035.72 4.00 -89.82 Hold for 200' 17362.44 80.00 187.00 6070.45 0.00 0.00 Start 3.51106 OLS, 0.18° TF, for 346.43' 17708.86 92.12 187.04 6094.19 3.50 0.18 Hold for 730.96' 18439.82 92.12 187.04 6067.09 0.00 0.00 Start 3.5°/106 OLS, -153.96° TF, for 67.56' 18507.38 90.00 186.00 6065.84 3.50-153.96 2M-39 T03 020818 JMAdjust TF to -125.38°, for 45.82' 18553.21 89.07 184.696066.21 3.50-125.38 Hold for 530.92' 19084.12 89.07 184.69 6074.82 19194.45 89.20 188.00 6076.48 19352.32 89.91 192.686077.71 0.00 0.00 3.00 87.80 3.00 81.42 Start 3°/100' OLS, 87.8° TF, for 110.33' 2M-39 T04 020818 JMAdjust TF to 81.42°, for 157.86' Hold for 793.06' CASING DETAILS TVD MD Name 20145.37 89.91 192.68 6078.98 0.00 0.00 Start 2°/100' DLS, -174.53° TF, for 95.84' 2646.82660.00 13 3/8" x 16' 20241.22 88.00 192.50 6080.73 2.00-174.53 2M-39 T05 020818 JMAdjust TF to -170.770, for 60.36' 5820.1 MS7.679 5/8" x 12 1/4" 20301.58 86.81 192.31 6083.46 2.00-170.77 Hata for 513.81' 6070.11ffi62'AM-1/2" by 9-78" 20815.39 66.81 192.31 6112.07 0.00 0.00 Start 2'/100' DLS, 1.15° TF, for 59.59 616626033.96 4-1/2" x 6-1/8" 20874.99 88.00 192.33 6114.77 2.00 1.15 2M39 T06 020818 JMAdjust TF to 0.45°, for 88.64' 20963.63 89.77 192.34 6116.49 2.00 0.45 Hold for 456.82' 21420.45 89.77 192.34 6118.30 0.00 0.00 Start 2°/100' DLS, -177.66° TF, for 53.68' 21474.13 88.70 192.30 6119.02 2.00-177.66 2M-39 T07 020818 JMAdjust TF to -178.23°, for 48.32' 21522.45 87.73 192.27 6120.52 2.00-178.23 Hold for 497.16' 22019.61 87.73 192.27 6140.18 0.00 0.00 Start 2°/100' DLS, 0.76° TF, for 113.31' 22132.92 90.00 192.30 6142.42 2.00 0.76 2M-39 T08 020818 JMAdjust TF to 1.36°, for 74.72' TCR APP1.1FD 22207.63 91.49 192.34 6141.45 2.00 1.36 Hold for 262.3T 22470.00 91.49 192.346134.61 0.00 0.00 Start 2°/100' DLS, 176.33' TF, for 34.77 22504.77 90.80 192.386133.91 2.00 176.33 2M-39 T09 020818 JMAdjust TF to 177.38°, for 23.08' 2M-�3 22627.05 9 .54 192.40 8 59.8e 23198.89 9 134 192.406129.71 23216.71 9 .00 192.29 6129.66 2.8e 0.00 0.00 2.00-161.87 Start 2°/100' DLS, -161. 2M-39 T10 020818 JMAdjust TF to -179.99°, f 7° TF, for 17.82' 88.75' 0 8 .23 192296 3103 2.00-179.99 Hold for 933.79' 66 5 8 .23 192.29 6159.96 0.00 0.00 Start 2.5°/100' DLS, 17 99° TF, for 13.12' 330 '37`3$ -24252.37 192.33 6160.40 2.50 172.999,�r�M-39 T11 013018 JMAdjust TF to 175.27, to V 15.76' .13 8919 03 2.50 175.2W Hold for 328.8' 24598.93 8 $1 1 2.36 6175. 00 0.00 Start 2.5°/100' DLS, -1. TF, far19.75' d 2809 24716.66 9 50 192.30 6177.42 2. -1.20 2M-39 T12 013018 JMAdjust TF to -1.85°, for 0.73' 24827.41 9 27192.21 6173.78 2.50 - 5 Hold for 116.06' 249 .21 6167:17 0.00 0. Start 2'/100' DLS, -179. ° �811.i9153.34' 2990 6.81 9 . .53 2.00-779.80 -39 T13 013016 JMAtljust TF to 154.54°, to 11.22' 25108.02 9 00 192.306162. 2.00 154.54 Hold for 433.57 2990 3180 25541.59 9 00 192.30 6162.53 0.00 Start 2°/100' DLS, 87.212 TF, for 2.68' 25544.27 9 00 192.35 6162.53 2.0 87.28 2M-39 4 013018 JMTD: 25544.27' MD, 616 533r}.gp - 3360 300 260 47 6166.78 0:20 1 25 2M-39 T Toe 01301.Wr 26033.86 0 �U 3360 - 3550 3550 3730 60 3730 - 3920 3920 - 4100 4100 - 5010 3 5010 5930 5930 - 6840 270 _29251 90 "1,10; 6840 - 7750 3 7750 8660 p 8660 - 9570 9570 - 10490 ---;lll 60 - - - 10490 - 11400 ---- 11400 - 13230 240 =__: 90 120 13230 - 15060 15060 - 16890 120 16890 - 18720 18720 - 20550 20550 22370 150 210 4507 150 22370 24210 2M-39261 24210 26034 180 NeY i 2M-39 wp17 2860.00 To 26034.32 C Wells Only s_ 2M 13 50 *06 11 90 010 24P a0 60 2M-36 22M-36RRPB1 0 30 2M-37 'io dYy0 2M-01_ Alm 2M11 0 0 0 O 2M-38 c M 4 30 0p 60 0 0 3 0 40 c o 2M-39 I C - O -30 60 2M-31 O 0 0 4 w Y gq 2 o FM022M-0 ¢ iIN-14 Z S0 50 50n q50 M a 2M-40 1-J3 2M 32L1 t°'"0a -08 9koo 2S-14 2M32 L1 PB2 2M-39 wp 7 -2M-32 L1 2M-32L1-01' 2M-08L1-01 2M-08L1 60 0 N Easting (4500 usfUin) AC Flipbook 6- Mq M 2319 2M-39 wp17 2860.00 To 4000.00 AC Flipbook SURVEY PROGRAM 0 2809 pth Fr045eplh To Tool 171.071440.40 GYD-GC-SS 1480 762701.24 MWD+IFR2+SAG+ '2809 -'2990 2741A02809.37 MWD 0 2809 374360 00 MVV`D OWSG 2990-3180 2809.396057.67 MWD,I R2 SAG+ 90 16057.677362 44 MWD OWSG 16057.677362.44 MWD+IFR2+SAG+ 330 30 3180 3360 17362A49862.44 MWD OWSG 17362.486033.96 MWD+IFR2+SAG+ 3360 3550 3550 3730 rASING AILS 60 3730 3920 WD MD Name 2646 89860.00 13 3/8" x 16" 5820.06057.679 5/8" x 12 1/4" 300 60 6070.4153671448-1/2" by 9-7/8" 3920 4100 6166.2e033.96 4-1/2" x 6-1/8" 4100 5010 MD ft TFem 30 70093] 2)+.99 000 5010 5930 23fi0o0 17499 0.00 2890oo 17499 om 29600017928 13000 5930 - 6840 W6000 27063 -30.00 3860.00 270.63 000 4160A0 261]4-75.00 14'0.00 6840 - 7750 w5lu 211.3 1697],6] 21163 9000 27Q _ 90 16m901 +9+.23 -79,14 7750 8660 1]050.20 19123 0.00 1716244 18],00 -8982 17382" 187.W °W 8660 9570 17708 Be 0.,9 18439.82187.' 000 1850736 186.09 -153969570 1655321 16469-12536 - 10490 18 00 ie°e 3 es 0 &W 8 8 19352.3219268 81.42 10490 11400 M W 5.37 19260 0 W MOM 192,50 174.5' MMIM 192.31 -non 11400 -13230 M815.N 192.31 OM M UN 19233 1.15 240 120 phew 1M34 046 13230 -15060 21274.13 192.30 .M.66 214245 192.17 .veM 60 15060 -16890 17019.61 192.27 0.00 171324 IRM 0.]6 Z OTO '444 196 nOom 192.34 a.0o 16890 - 18720 19236 17833 nW47] 174763 19240 177.36 M,93w 19240 0.00 223-39P81 18720 - 20550 2321071 19229 -16187 210 150 M30546 19229 17999 =2523, ;s23 0550 22370 ,7246 so 24288,3 192.36 1753] 245939319233 009160 22370 24210 7471966 19230 -1.29 2462741 19221 -1:6 249434] 1922 a 04210 250W.81 182.20 -17980 26034 25108.02 19293 154.' 2354159 19230 0.00 E5442] 193.35 0].20 B:A, Ney2b $019 2M-39 wp17 3900.00 To 7000.00 AC Flipbook SURVEY ROGRAM 0 2809 pth Fm16epth To Tool 171.071440.40 GYD-GC-SS 1480.762701.24 MWD+IFR2+SAG+ 2809-2990 2741 402809.37 MWD 0 2809 3743.00 MWD OWSG 90 2990-3180 2809.3%057.67 MWD+I R2 SAG+ 16057.677362.44 MWD OWSG 30 16057.677362 44 MWD+IFR2+SAG+ 330 3180-3360 17362.448862.44 MWD OWSG 17362.486033.96 MWD+IFR2+SAG+ 3360 3550 3550 3730 CASING DETAILS 60 3730 - 3920 TVD MD Name 2646.80860.00 13 3/8" x i6" 300 60 5820.06057.679 5/8" x 12 1/4" 3920 4100 6070S367-446-102"cy94/6• 6166.26033.96 4-1/2" x 6-1/8" 4100 - 5010 NO MD n4 w� Tuan 30 5010 5930 2984 W 2]<.93 Oe0 z050.W 2]a" 0.00 NOD 2!0.2013000 5930-6840 3280.00 27063 -30.00 356000 270.63 0.00 4,0000 Wt 74 -7500 68401607,67 - 7750 1404000 281.14 0.00 211, 1607]67 21183 9000 16589.00 191.23 2%0 90 7750 8660 -78W 17058,M 191,23 000 17182" 107.00 -ee" 17352" 13700 0.00 8660 - 9570 17708 A 107. 0.18 IM398218T04 0.00 '350739 186 00 -'5396 9570 -10490 1855321 184.69 -12538 1084,12 18469 0.00 30 ,919445 ID. DD 87W 10490 11400 05232 ,9266 e,A2 2m45n ,ez ee o.W 2°24'. '9 50 -,14.50 2033,58 19231 -170 77 11400 -13230 2081539 19231 0.00 M8744)19233 1.15 20003.63 152." 0.45 2qp 120 13230 -15060 2142045 192.31 0 W 30. 2,474,3 ,92mW 2152245 ,922+-17823 15060 - 16890 220,9°1 192P 000 22132.92 IQ 0]8 212(263 19234 1.38 �I+ 16890 -18720 2247000 19234 om 22504.77 19238 178.33 '.„41 22527.85 192.4° 11.38 2319689 , 00092 18720 - 20550 19240 61 2321671 29 4 87 210 150 2330545 ,9229 17999 24239.25 ,92x9 0.W 0550 22370 24252.37 192.33 IR.99 24169.13 192.36 175.27 245°6°319236 0,00 leo 2370 24210 2471668192.30 -1.20 24827.41 192.21 -1.85 UN3471%2' 0,00 4210 26034 2.96.81 19$.20 -17980 25108 W 192.. 154.54 2554159192.30 0.°0 25544 V 19235 87N am, rase Nils 2M-39 wp17 6900.00 To 16100.00 AC Flipbook SURVEY PROGRAM 0 2809 : pM FroiDepth To Tool 171 071440.40 GYD-GC-SS F 14M762701 24 MWD+IFR2+SAG+ 2809--- 2990 2741.402809.37 MWD 0 2809,374360 00 MWD OWSG- 2809.376057.67 MWD+IFR2+SAG ----" �-:e -- `-' `�`� 2990- 3180 16057.691362 .44 MWD OWSG 16057.6T7362 44 MWD+IFR2+SAG 330 ,�\ -- 30 3180 3360 17362.448862 44 MWD OWSG 17362.486033.96 MWD+IFR2+SAG+ 3360 - 3550 \\ 3550 3730 3730 - 3920 CA ING DETAIL TVD MD Name 2646.80660.00 13 3/8" x 16" 300 60 5820.08057.679 5/8" x /2 l/4" 6076.27136x406-121" by 9-7/8" _ - - -� 3920 - 4100 616628033.96 4-1/2" z 6-1/8" 4100-5010 280933 2749s 667 Moo. W4:W 667 289999 2,499 099 296767 23628 ,]9.00 --_ �� _ \. ` \ \�. \\ 5010 5930 32550. no 63 a000 316000 Q. 000 _ \ = � �\\ � 5930 6840 416000 96,.74 -75.67 14140 W 20, 74 000 \�\\\�\ /� - A� �. - A Q 'A\ 6840 7750 160 7.67 21183 -99.M 18073.67 21183 oW 1BW9-W 19,.23 -3314 270 �_ ��_ ��A� A V 5 A� ��\VA V \\� 90 7750 8660 17 62.44 10100 -0342 17x2e4,87.0o am ,776688 ,17.04 618 ,1439.8218104 0.67 �\ \ \\ \\\\\� \ \�\\� \ 8660 9570 185513° ,8669-15'91 1853'21 WeeowA 16784.12 184.55 o.W 1918445 118 80 .0 81 115232 1926 68 01.40 \ \� \ y A �V A\ �A� \ \ 9570 10490 10490 11400 mush 192 oe om 20]012819131174.63��1A\Vr�\ 2033,39 ,92.3, 17677 �\, 1 1 1, 11400 13230 2711939 1923' 615 �67^� ,9233 L11 240 �1\\�v"" V �1 ��1 v�A��v�"� 1,11 1: ' i2o -15060 209633315234 0.49 2147045 19234 0-W 13230 21274.;2 192.27 -,7855 X11, � M029.43 19227 -"621 22132Q ie'o 076 60 1������: \\ 1��! 1\\\iy;'1.. 15060 16890 990783 192.34 1x n470 W 19234 0 W ���1 16890 18720 225M.37 19238 178.33 .W B5 19240 13338 M198019240 696 18720 20550 2321671 191.28 -16187 2330546 -17399 210 50 1922. 2a2�'sz.3n7 19229 212:11 90 0550 22370 2428813 14723675 .27 245560192.360.01 180 22370 24210 2471855 192.30 -1.20 24823 41 -1.85 1W922 2494'4 1x2.21 o W Mae 8119220-17967 24210 26034 25108.67 192.36 154.54 25541.55 192.30 0.00 25N42! 192.35 8128 ff.00, May 28.W89 2M-39 wp17 6900.00 To 16100.00 FAC Flipbook URVEY PROGRAM 0 2809 pth Frorbepth To Tool 171.071440.40 GYD-GC-SS 1480.762701.24 MWD+IFR2+SAG+ 2809 2990 2741.402809.37 MWD 0 TCR NIPPLILD 2809.3743.00 MWD OWSG 2809.316057.67 MWD+1 R2 SAG+ 90 2990 3180 16057.697362.44 MWD OWSG 16057.677362 44 MWD+IFR2+SAG+ 330 30 3180 3360 17362.448862.44 MWD OWSG 17362.486033.96 MWD+IFR2+SAG+ 3360 - 3550 60 3550 3730 - 3730 - 3920 CASING DETAILS TVD MD Name 2646.80860.00 13 3/8" x 16" 5820.08057 .679 5/8" x 12 1/4" 300 60 6070.4E36Y498-1rz"h99-7/8" 3920- 4100 6166.26033.96 4-1/2" x SAM" 4100-5010 Mo m Fam 30 28"37.d89 °06 5010 5930 2960.30 174.99 0 W ze9o.ao 214.99 e.w IDBOW 27828130.00 s2eo.W 270.63 36.00 5930 - 6840 388030 17063 000 416pW 26v4 .75.W 14WO. 261.74 D. 7750 1606767 211,60 -6840 16077.67 21163 90 W 270 90 1658900 191.23 3814 7750 8660 17058.20 19123 0. W 0162." 187.00 -aBN 173 62" 18160 9I 8660 9570 n708.W 18104 0.16 18439.62187.04 0.00 J30 18507.38 188.00 -15966 16553.21 184.69 -12536 9570 10490 19384.12 164.66 0.00 '240 19194.45165.00 87W 05232 1066 6142 10490 -11400 2014537192" 0.00 )120x96363192.34045 2@4123 1MW 174.53 Mool58 19231 -non 11400 13230 M81538 192.31 0 W A87489 182331.15 13230 15060 2142045 19234 0W 21474.13 192.30 -17186 21522" 192.27 -179 220f 961 192.27 000 so 15060 16890 3213292 19230 076 Y220763 19234 1.35 22<76W 19234 9W 16890 -18720 22504.77 192.38 nB 33 22527.85 192.40 177.38 23198.69 192.40 0.00 18720 20550 M216.71 192.29 -16187 210 150 2330546 19229 -17999 AMM ,32331n99 90 0550 22370 2426e 13 192.36 75 V 2459893 19236 0.00 x716.68 192.30 p 180 2370 24210 -1 24827.4119221 -185 2494547 192.21 0.03 25098.81 18230 -176.W 24210 26034 25108.02 192.30 15454 2554158 19230 0W 2554427 19 35 8128 2M-39 wp17 16100.00 To 26033.96 AC Flipbook SURVEY PROGRAM 0 2809 pth FroiDepth To Tool 17 071440.40 GVD-GC-SS 1480.762701.24 MWD+IFR2+SAG+ 2809 2990 2741.402809 37 MWD 0 2809.374360 . 00 MWD OWSG 2809.376057.67 MWD+I R2 SAG+ 90 2990 - 3180 16057.697362.44 MWD OWSG 16057.697362.44 MWD+IFR2+SAG+ 330 30 3180 3360 17362.4718862.44 MWD DWSG 17362.486033.96 MWD+IFR2+SAG+ 60 3360 3550 3730 3550 3730 3920 CASING DETAIL TVD MID Name 26 6.8086 00 13 3/8" X 16" 5820.08057.679 5/8" x 12 1/4" 300 60 6070.41BWPf4a18-v2 by 9-7/8" 3920 - 4100 6166,26033.964 -1/2".6 -IM" 4100 - 5010 MD ku TFaa 0 2809.37 '099 000 zeeo.00 '491 O.oO .50.o0 5010 5930 '4.99 3.00 298000 '9.28 130.00 =0.00 no63 3000 5930 - 6840 386000 270 63 000 416003 25174 -]500 14840'057.00 261.74 000 6840 7750 900 16076] 21163 67 21103 80°0 7 27C 90 1659100 191.23 -79.14 7750 8660 1)05820 191.23 000 17162. 18].W -89.82 "3670666167. 24.187" 0'8 1704 n1e 8660 9570 IM3102 187.04 0 W 18507.38 18600 15309 1655321 184.69-126Y 9570- 10490 14064.12184.68 000 1919445 188.00 87.80 3C 1835232 18268 81.42 10490 11400 2°100 19288 aW 20241.' 192W -174.53 203°1. ' W 31 -1J077 11400 - 13230 M81539 1W 31 O.W "BUM 192.33 1.15 '240 120 2008J83 tB2'34 °45 214204519234 003 13230 15060 2147413 19230 -1]78 21S22 eei inz zi"0.00 60 15060 16890 MM. 19233 0]9 '20763 18234 135 '47000 19234 0.00 16890 -18720 22504.7] 192.38 17633 '52].85192.40 171.% 2]'966' 192.46 0.00 18720 20550 233 V 1671 192.29 -161.8] 1 210 150 3]3]5M 192.29 -1]9.99 ,uz= ;33,7z� so 0550 22370 1]5.27 24268NWO.13 19 W93 JWW N711666 162.30 Oe6 160 2370 24210 248� 41 19221 -1a 2494347 19221 0.00 25°°681 192.20 -179.80 4210 - 26034 2510002 1WW 154.54 25541.59 18230 0.00 25544'23e BL28 ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit _2 Kuparuk 2M Pad Rig: 2M-39 50103132079500 2M-39 Plan: 2M-39 wp17 Error Ellipse Survey Report 28 May,2019 Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Site: Kupawk 2M Pad Well: Rig: 2M-39 Wellbore: 2M-39 Design: 2M-39 wpl7 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 2M-39 2M-39 actual @ 137.45usft (D19) 2M39 actual (go 137.45usft (D19) True Minimum Curvature 2.00 sigma OAKEDMPI Project Kuparuk River Unit 2, 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 Kupamk 2M Pad Site Position: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.10 ° fell Rig: 2M-39 From fell Position +NI -S 0.00 usft Northing: Latitude: Version: +E/.W 0.00 usft Easting: Longitude: osition Uncertainty Depth From (TVD) 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 100.70 u: Wellbore Magnetics 2M-39 Model Name Sample Date Declination Dip Angle V) r) 6/1/2019 16.44 Field Strength (nT) 80.79 57,401 Design 2M-39 wp17 Data 5/2412019 From Audit Notes: (usft) (usft) Survey (Wellbore) Version: Phase: PLAN Tie On Depth: 2,809.37 Vertical Section: Depth From (TVD) +NI -S +EI -W Direction 2,741.40 (usft) (usft) (usft) r) 4,360.00 2M-39 wpl7(2M-39) 36.75 0.00 0.00 232.00 Survey Tool Program Data 5/2412019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 171.07 1,440.40 2M-39 Srvy 1 - SLB GWD70 (2M-39PB1) GYD-GC-SS Gyrodata gyro single shots 1,480.76 2,701.24 2M-39 Srvy 2- SLB _MWD+GMAG(2M-39 MWD+IFR2+SAG+MS OWSG MWD +IFR2+Sag +Multi -Station Correction 2,741.40 2,809.37 2M-39 Srvy 3-SL13_MWD+SAG(2M-39P MWD MWD - Standartl 2,809.37 4,360.00 2M-39 wpl7(2M-39) MWD OWSG OWSG MWD - Standard 2,809.37 16,057.67 2M-39 wpl7(2M-39) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 16,057.67 17,362.44 2M-39 wpl7(2M-39) MWD OWSG OWSG MWD - Standartl 16,057.67 17,362.44 2M-39 wpl7(2M-39) MWD+IFR2+SAG+MS OWSG MWD +IFR2+Sag +Multi -Station Correction 17,362.44 18,862.44 2M-39 wpl7(2M-39) MWDOWSG OWSG MWD - Standard 17,362.44 26,033.96 2M-39 wpl7(2M-39) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 5/28/2019 8:27:09AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips Alaska Inc_Kuparuk Local Coordinate Reference: Well Rig: 2M-39 Project: Kupanik River Unit -2 TVD Reference: 2M-39 actual 137.45usft (D79) Site: Kupamk 2M Pad MD Reference: 2M-39 actual 137.45usft (D79) Well: Rig: 2M-39 North Reference: True Wellbore: 2M-39 Survey Calculation Method: Minimum Curvature Design: 2M-39 wpl7 Output errors are at 2.00 sigma OWSG MWD + IFR2 + Sag + Database: OAKEDMP7 Plan Survey Tool Program Date 5/24/2019 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 171.07 1,440.40 2M-39 Srvy 1 - SLB GWD70 (2M GYD-GC-SS Veracal Mi9hsid. Lateral Gyrodata gyro single shots 2 1,480.76 2,701.242M-39 Srvy 2- SLB _MWD+GMA MWD+IFR2+SAG+MS D.p1h OWSG MWD + IFR2 + Sag + 3 2,741.40 2,809.372M-39 Srvy 3- SLB _MWD+SAG MWD Bias Error Bias MWD - Standard 4 2,809.37 4,360.002M-39 wpl7(2M-39) MWD OWSG (asn) P) r) OWSG MWD - Standard 5 2,809.37 16,057.672M-39 wp17(2M-39) MWD+IFR2+SAG+MS (usa) (.am (uah) OWSG MWD + IFR2 + Sag + 6 16,057.67 17,362.44 2M-39 wpl7 (2M-39) MWD OWSG 42.41 27499 2,609.41 OVJSG MWD - Standard 7 16,057.67 17,362.44 2M-39 wpl7 (2M-39) MWD+IFR2+SAG+MS 066 0.90 12.07 OWSG MWD + IFR2 + Sag + 8 17,362.44 18,862.44 2M-39 wpl7 (2M-39) MWD OWSG 27499 2.616.00 584 OWSG MWD - Standard 9 17,362.44 26,033.96 2M-39 wpl7 (2M-39) MWD+IFR2+SAG+MS 028 12.32 6.46 OWSG MWD + IFR2 + Sag + Position uncertainty and bias at survey station Measured Incenahon PaimuM Veracal Mi9hsid. Lateral Vertical M.,...& s.mi+nalpr sersmi., D.p1h Depth Error Bias E. Bias Error Bias of Bias Error Error Avmuth Toel (asn) P) r) luso) lush) (ush) (usft) (usa) (usa) (.am (uah) (..ft) (pse) r) 2.809.3] 42.41 27499 2,609.41 5.83 -0.02 1201 41.21 3.11 066 0.90 12.07 6.16 10183 MWO(1, 3) 2,86000 42A1 27499 2.616.00 584 -002 12.26 -0.20 3.84 001 028 12.32 6.46 101.82 MWD OWSG(1, 4) 2,890.00 42.41 27699 2,88695 585 -0.02 12.50 -0.28 IN 0.01 028 12.56 647 totw MWD OWSG(1. 4) 2,90000 42.15 275.45 2.676.34 5.86 4.03 12.60 4.28 3.87 0.01 028 1265 6.47 101.54 MWD OWSG(1, 4) 2,960.00 40.66 270.28 2M1.35 592 AM 13.31 4.27 3.94 0.01 0.20 1332 6.51 101.04 MWD OWSG(1. 4) 3,000.00 4205 277.09 2.751.38 591 -0.03 13.85 0.27 3.99 0.01 028 13.87 6.54 10074 MWD OWSG (1, 4) 3,100.0D 45.50 274.37 2,92353 594 -0.02 1563 4.28 4.11 0.01 0.28 15.88 866 9972 MWO OWSG(1, 4) 3,200.00 49.16 271.96 2,89125 8.03 -0.01 17.95 -028 4.27 001 0.28 18.05 6.83 9639 MWD OWSG(1, 4) 3260.00 51.34 270.63 2,92962 6,12 -001 less -0.28 639 0.01 0.20 19.70 6.95 97.53 MWD OWSG(1, 4) 3,20236 5223 27063 2,943.45 6.16 4.01 2039 -0.28 4.48 0.01 028 20.90 7.03 96.97 MWD OWSG(1, 4) 3,30000 5294 27063 2,954.17 6.16 -0.01 20,79 .028 4A8 0.01 028 20.90 7.03 96.7 MWD OWSG(1. 4) 3.40000 55.94 270.63 3101161 6.29 -001 24.14 428 078 0.01 0.28 24.23 7.24 9575 MWD OMG(1. 4) 3,50000 60.94 270.63 3,063.19 6.50 4,01 27.90 428 5.14 001 028 27.97 7.45 9461 MWD OWBG(1. 4) 3,600.00 64.84 27083 3.1W68 677 4,01 32.01 4.28 556 0.01 028 32.06 7.66 9409 MWD OWSG (1, 4) 3,700.00 60.94 27063 3,147a5 7.10 401 36.41 4.28 604 0.01 0.28 3645 7.85 93.53 MWD OWSG (1, 4) 3,80000 7294 9083 3.18050 747 -001 41.05 -0.28 6.50 0.01 029 41.09 8.03 93.11 MWD OWSG (1, 4) 3,86000 75.34 27063 Massa 7.71 -0.01 43.93 -028 893 001 028 43.97 8.13 92.90 MWD OWSG (1, 4) 3.900.00 75.65 26944 3,20692 796 -0.01 45.93 -028 7.17 001 0.29 45.91 8.19 82.75 MWD OWSG (1, 4) 5/2872019 8:27:09AM Page 3 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc-Kupawk Project: Kupawk River Unit -2 Site: Kupawk 2M Pad Well: Rig: 2M-39 Wellbore: 2M-39 Design: 2M39 wp17 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 2M-39 2M39 actual @ 137.45usft (D19) 2M-39 actual a 137.45usft (D19) True Minimum Curvature 2.00 sigma OAKEDMPI Measor d IMMa6M p .ffi Vertical Higpside Latent Yertical Magnitude Se.l r Se vi lnor Dep18 DepO Ern, Mas Errer ales Ertor Bias 0Blas Error Error Azinu6 Tool (usft) r) f) (usft) (usft) (usft) (usft) (usn) Wo ftl (usft) lush) (--ft) (usft) r) 4,00000 7846 265.46 3.231.03 8.60 a00 5052 4.28 7.80 001 028 5077 8.35 9223 MWD OWSG(1, 4) 4,1W.W 77.30 263.50 3.25373 9.28 000 55.07 -0.28 845 001 0.28 5560 8.50 9155 MWD 0WSG(1, 4) 4,16000 77.83 26174 3,266.65 970 0.00 57.73 -0.27 884 0.01 028 5840 8.60 9108 MWD OWSG(1, 4) 4,200.00 77.83 26174 3,275.00 9.97 0.00 59.67 -0.27 9.11 0.01 0.28 60.40 867 9076 MWD OWW(1, 4) 4,30000 77,83 26174 3,296.17 1066 O.W 64.54 4.27 979 001 0.28 65.22 803 90.05 MWD+IFR2+6AG+M8(2.4) 4,400.0 77.83 26174 3,317.25 7.62 0.00 3345 4.27 7.16 001 0.28 3382 8.21 90.62 MWD+IFR2+SAG+MS(2,4) 4.500.00 77.83 261.74 3.33834 7.99 000 35.55 427 7.53 001 0.28 35.89 8.32 8991 MWD+IFR2+SAG+MS(2,4) 4,60000 TrA3 261.74 3,35942 8.38 0.00 37.67 -0.27 7.90 001 0.28 37.98 e." 89.27 MWD+IFR2+SAG+MS(2.4) 4.700.00 77.83 26174 3,380.51 875 0.00 39.80 -0.27 829 0.01 020 40.09 855 88.79 MWD+IM2+SAGWS(2,4) 4,800.00 7183 26174 3,401.59 9.14 000 4194 4.27 868 001 0.20 42.21 8.67 88.35 MWD+IFR2+SAG+M5(2, 4) 4,900.W 77.83 26174 3.422.68 9.53 000 44.10 -0.27 9.07 001 028 4435 878 87.98 MWD+IFR2+SAG+MS(2,4) 50W.W 77.83 26174 3,"377 9.93 ON 46.26 4.27 9.47 0.01 028 46.50 8.90 STU MWD+IFR2+8AG+MS (2.4) 5.1W.W 77.83 261.74 3.461.65 10.34 O.W 48.44 -0.27 987 0.01 028 4866 9.01 87,33 MWD+IFR2+SAG+MS(2, 4) 6,200.00 77.83 261.74 3,485.94 10.74 OW 50.62 -027 10.28 001 028 Was 9.13 87,05 M FFR2+SAG+"5(2,4) 5,300.00 7783 261.74 3,507.02 11.15 OW 5280 427 1068 0.01 0.28 53.00 924 0579 MWD+IFR2+SAG+MS(2,4) 5,4W.W 77.83 261.74 3,52811 11.57 ow 5500 027 1109 001 0.28 55.19 936 88.56 MWD+IFR2+SAG+MS(2,4) S,SW.W 77.83 26174 3.549.19 11.99 0.03 57.19 4.27 11.51 0.01 028 57.37 9.48 86.35 MWD+IFR2+SAG+MS(2,4) 51800.00 77.83 261.74 3,57028 1240 000 59.40 4.27 11.92 0.01 028 59.57 9.59 86.15 MWD+IFR2+8AG+M8(2.4) 5,700.00 77.83 26174 3.59135 12.83 OAD 61.60 4.27 12.34 001 028 61.77 971 85.97 MWD+IFR2+SAG+MS(2,4) 5.800.00 77.83 261.74 3,61245 13.25 0.00 8381 -027 12.76 0.01 0.20 6397 9.63 05.80 M IFR2+SAG+108(2,4) 5,900.00 77.83 26174 3,633.54 13.67 0.00 6802 A.27 13.18 0.01 028 WA7 9.95 85.64 MWD WK+SAG+MS(2,4) 6,WO.W 77.83 26174 3,85482 14.10 O.W 6824 4.27 13.60 0.01 0.28 6838 10.07 85.50 MWD+IFR2+SAG+MS(2,4) 6,1W.W 7,83 26174 3,675.71 1453 0.00 70.46 4.27 14.02 0.01 028 70.59 10.19 8535 MWD+IFR2+SAG+MS(2,4) 6.2W.W 77.63 26174 3.696.79 14.% 000 72.67 -0.27 14.45 0.01 0.28 72.81 10.31 8524 MWD+IFR2+SAG+MS(2, 4) 6,300.00 77.83 261.74 3.717,08 15.39 OW 74.9D -0.27 14.87 001 028 75.02 10." 85.12 MWD+IFR2+SAG+MS(2,4) 6,400.00 77.83 261.74 3,738.98 15.82 0.00 77.12 .027 1530 0.01 0.28 77.24 1058 8501 MWD+IFR2+SAG+MS(2, 4) 8,500.00 77.83 261.74 3.780.05 16.28 O.W 79.35 A.27 1513 001 028 79.47 10.68 MAD MWT3+IFR2+SAG+MS(2.4) 6.600.00 77.83 26174 3,781.13 16.69 O.W 81.57 4.27 16.16 001 0.28 8169 10.81 84.60 MWD+IFR2+SAG+MSR4) 6,70.W 7A3 261.74 3.802.22 17.12 0.03 83.60 4.27 16.50 0.01 0.28 63.91 10.94 84,71 1AWD+IFR2+SAG+MS(2, 4) 6.8W.W 77.83 261.74 3,823.31 17.56 000 86.03 -027 17.01 0.01 0.28 08.14 1106 8483 MWD+IFR2+SAG+MS(2.4) 6,900.00 77.83 26174 3,0".39 18.00 GM 88.26 -0.27 1744 0.01 028 00.37 11.19 8454 MWD+IFR2+SAG+M8(2, 4) 7,00000 Ta3 26174 3.86548 18.43 0.00 9.50 -027 17.87 0.01 028 90.60 1132 84.46 MWD+IFR2+SAG+MS($4) 7,100.00 77.83 26174 3,886.56 10.07 0.60 9273 -0.27 18.31 0.01 0.20 9283 1145 84.39 MWD WK+SAG+MS(2,4) 7,200.00 77.83 261.74 3,9785 19.31 0.W 94,96 027 16.74 001 0.28 9560 11.58 84.32 MW Wit+SAG+MS(2.4) 7,30000 77.83 261.74 3,92873 1975 0 W 97.20 4.27 19.17 0.01 028 97.29 11.71 84.25 MWD+IFR2+SAG+MS (2,41 7,40.W 77.83 28174 3.94982 20.19 0.00 9944 41.27 19.60 0.01 0.28 9953 11.85 84.19 MWD+IFR2+SAG+MS(2,4) 7,5W.W 77.83 26174 3,970.90 2063 GM 1D1.67 0.27 20.04 0.01 0.28 101.76 11.98 84.13 MWD+IFR2+GAG+M8(2,4) 7,600.00 77.03 26174 3,99199 21.07 0 103.91 -027 2047 0.01 028 104.00 12.12 8407 MWD+IFR2+SAG+MS(2,4) 7,70000 77.83 261.74 4,013.00 21.51 am 106.15 -027 2090 001 0.28 106.23 12.25 84.01 MMAFR2+SAG+MS(2,4) 7,800.00 7703 261.74 4.034.16 21.95 OW 108.39 427 21.34 0.01 0.28 10847 1239 83.96 MWD+IFR2+SAG+MS(2,4) 7,90000 77,83 26174 4,055.25 22.39 O.W 110.63 4.27 2177 0.01 028 110.71 12.52 83.91 M 1FR2+SAG+MS(2,4) B,W0.00 77.83 261.74 4,076.33 22.84 O.W 11287 -0.27 22.21 001 0.28 112.95 1266 83.86 MWD+IFR2+SAG+MS(2,4) 8,10.W 77.83 26174 4,097.42 2328 0.60 115.11 4.27 22.64 0.01 028 115.19 12.00 83.02 M +IFR2+SAG+MS(2,4) 8200.60 77.83 26174 4,11850 23.72 0.00 117.36 -027 23.08 0.01 028 11]43 12.94 8377 MWD+IFR2+SAG+MS(2,4) 8,30000 7.83 26174 4.139.59 24.17 000 11960 427 23.51 0.01 028 11967 13.08 8373 MWD+IFR2+SAG+MS(2,4) 8,342.03 77.83 26174 4,14845 2461 0.00 121.84 -0.27 23.95 0.01 0.20 121.91 13.22 8$.69 MWD+IFR2+SAG+MS (2.4) 8.400.00 77.83 261.74 4,16067 24.61 0.00 121.84 427 23.95 0.01 028 12191 13.22 83.69 MWD+IFR2+SAG+MS(2,4) 5,500.00 77.83 26174 4,18176 25.05 O.W 12408 4.27 24.36 0.01 0.28 124.15 13.36 83.65 MWD+IFR2+SAG+106(2.4) 8.60.0 77.83 261.74 4,20285 25.50 ON 128,33 4.27 24.82 0.01 0.28 128.39 13.51 83.61 M IFR2+SAG+MS(2,4) 8,7W.W 77.83 261.74 4223.93 2591 0.00 120.57 AV 2526 0.01 028 12864 13.65 83.57 MWD+IFR2+6AG+M5(2.4) B,BW.W 77.83 26174 4,245.02 26.39 0.00 130.02 4.27 25.69 001 028 130.88 13.79 83.54 MWD+IFR2+SAG+MS(2,4) 8.900.W 77.83 261.74 4,256.10 26.83 000 133.06 -027 26.13 0.01 028 133.12 13.94 8360 MWD+IFn+SAG+MSR4) 91000.00 77,83 26174 4,237.19 27.28 O.W 13531 -0.27 2657 0.01 0.28 13537 14M 8347 MWD+IFR2+SAG+MS(2,4) 9,100.00 77.83 261.74 4,308.27 27.72 0.00 137.55 -0.27 27.01 001 028 137.61 1423 83.44 MWD+IFR2+SAG+M8(2,4) 5/282019 8:27:09AM Page 4 COMPASS 5000.14 Build 65D Company: ConocoPhillips Alaska Inc_Kuparuk Project Kupamk River Unit -2 Site: Kupamk 2M Pad Well: Rig: 2M-39 Wellbore: 2M-39 Design: 2M-39 wp17 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 2M-39 210-39 actual @ 137.45usft (1319) 2M-39 actual @ 137.45usfi (D79) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inchnz6an AzimuN 9er8cal ai9hside 9abn1 yemcal Ma9niNde semlmmor Semianbror OepN Depth Error Eras Error eus E. files 9r EWs E., E. AMmuth Tool (..ft) P) R (mftl lusftl (.sal (--ft) (usft) lusftl luau) (U -ft) Juin) lusft) 1'1 9,20000 77.03 261.74 4,32936 20.17 000 13980 -0.27 27.44 001 028 13986 1438 8341 MWD+1FR2+8AG+MS(2,4) 9,300.00 77.03 261.74 4,397.44 2861 ),W 14204 -0.27 27.88 0.01 028 14210 14.52 8338 MWD+1FR2+6AG+MS(2, 4) 9.400.00 77.83 261)4 4,371.53 2906 000 144.29 -0.27 28.32 0.01 0.28 144.35 14.67 83.35 MWD+1FR2+SAG+M5(2. 4) 9.500.00 77.83 281]4 4,392.62 29.50 000 146.54 4)27 2876 001 0.28 146.59 14.82 8332 MWD+11`R2+EAG+MS(2,4) 9,600.00 77.03 261.74 4,41370 29.95 0.00 148.78 -0.27 2920 0.01 028 14884 14.97 83.30 MWG+IFR2+SAG+MS (2. 4) 9,700.00 77,83 261 )4 4,43439 30.40 0.00 151 03 427 29.63 001 0.28 151.08 15.12 83.27 MWD+IFR2+SAG+MS (2, 4) 9,800.00 77.83 261.74 4,45587 WA4 0.00 15328 4.27 30.07 0.01 028 153.33 1527 83.24 MWD+IFR2+5AG+M5(2,4) 9,90000 77.83 261.74 4.476.96 3129 0.00 155.53 4.27 30.51 001 028 15558 15.42 8322 MWD+1FR2+SAG+MS(2,4) 10,000.00 77.63 281]4 4,490.04 31.74 0.00 15].]7 -027 3095 001 028 157.82 15.58 8320 MWD+1FR2+SAG+MS(2,4) 10,100.00 77.03 261.74 4,519.13 n1a D.W 18002 -0.27 31.39 001 0.28 160.07 15.73 83.17 MWD+IFR2+SAG+MS(2,4) 10,200.00 7703 261.]4 4,54021 3263 0.00 162.27 -027 31.83 001 028 162.32 1588 8315 MWD+IFR2+SAG+MS(2,4) 10,39700 7].83 261.74 4,561.30 33.08 000 164.52 4.27 3227 0.01 0.28 164.57 1604 83.13 MWD+1FR2+SAG+MS(2.4) 10,40000 7183 261.74 4,582.38 33.52 000 166.77 4).27 32.71 0.01 028 156.82 18.19 83.11 MWD+1FR2+SAG+MS(2, 4) 10,50000 ]).03 26134 4,803.47 33.97 0.00 18902 -0.27 33.15 001 0.28 16906 16.35 83.09 MWD+1FR2+SAG+MSR. 4) 10,600.00 77.83 261.74 4,62456 34.42 0.00 171.27 -027 33.58 001 028 171.34 1050 0307 MWD+1FR2+SAG+MS(2,4) 10,79700 77.83 26134 4.64564 36.87 0.97 173.52 O27 34.02 0.01 028 173.56 16.66 83.05 MWD+1FR2+SAG+MS(2.4) 10,70383 77.83 261.74 4,64845 3531 000 17576 4,27 34.46 001 0.28 175.81 16.82 8303 MWD+1F1U+SAG+MS(2,4) 10,800.00 77.83 261.74 4,666.73 35.31 0.00 175.76 -027 34.46 0.01 0.26 175.81 16.82 8303 MWD+IFR2+SAG+MS(2,4) 10,900.97 77.83 261.74 4,68781 35.76 0.W 178.01 -0.27 34.90 0.01 028 178.06 1898 8301 MWD+IFR2+SAG+MS(2,4) 11,0W.W 77.83 281]4 4,708.90 38.21 O.W 180.26 -0.27 35.34 001 0.28 18031 17.13 8299 MWD+IFR2+SAG+MS(2,4) 11,197.00 7].03 281.74 4,]2998 3666 0.m 182.51 4.27 35.78 0.01 028 182.56 1729 8297 MW 1FR2+SAG+MS(2,4) 11.297.00 77.93 261.74 4.751.07 37.11 ON 184.76 -027 36.22 0.01 020 104.80 17.45 82.96 MWD+1FR2+5AG+MS(2.4) 11,300.00 77.83 261]4 4,772.15 37.55 0.W 187.01 4.27 3656 001 0.28 107,05 17.61 8294 MWD+1F1U+SAG+MS(2.4) 11.400.0 ]).83 281]4 4,793.24 38U0 O.W 18926 -0.27 37.10 001 028 189.30 1778 82.93 MWD+IFR2+SAG+MS(2. 4) 11,597.00 77.83 261.74 4,814.33 38.45 OW 191.51 -027 37.54 0.01 028 191.55 17.94 82.91 MWD+IFR2+SAG+MS(2, 4) 11.897.00 77.83 281.74 4,MAI 38.90 OW 193.76 0.27 37.98 0.01 028 193.80 18.10 82.89 MWDWI +SAG+MS(2,4) 11,70000 77.83 261.74 4.858.50 39.35 0.00 196.01 -027 38A2 0.01 0.28 196.05 18.26 82.08 MWD+1FR2+SAG+MS(2,4) 11,800.00 7763 26174 4,8]).50 3980 0.00 198.27 -027 38.86 0.01 0.28 198.30 18.42 8288 MWD+1FR2+SAG+M8(2.4) 11,900.97 77.83 261.74 4,698.67 4024 0.0D 200.52 4.27 39.30 0.01 028 20055 1859 8285 MW0+1FR2+SAG+MS(2,4) 12,.400.97 77.83 261.74 4.919.75 4069 OW 202.77 4.27 3974 0.01 028 202.80 18.75 82.84 MWD+IFR2+SAG+MS(2.4) 12,1W.00 77.83 261.74 4,94084 41.14 OW 205.02 -0.27 40.18 001 0.28 20505 18.02 82.82 MWD+IFR2+SAG+MS(2,4) 12,20.00 7783 281.74 4,931.92 4159 0.00 207.27 627 4062 0.01 028 207.30 1908 8281 MWD+IFR+SAG+MS(2,4) 12,300.00 7783 261.74 4,963.01 42.04 0.00 209.52 -027 41.97 001 0.28 2W.W 1925 8280 MWD+1FR2+SAG+MS(2, 4) 12.400.00 ]).83 261 ]4 5,974.10 4249 OW 211.]] -0.27 4151 0.01 028 211.81 1942 82.78 MWD+IFR2+SAG+MS(2,4) 12,415.91 77.83 26174 S,W7.45 4294 0.97 21402 4.27 41.95 001 0.28 21408 1958 82.77 MWD+1FR2+SAG+MS(2,4) 12.597.00 77.83 261.]4 5,975.18 4294 000 214.02 -0.27 41.95 0.01 028 214.06 19.58 8277 MWD+IFR2+SAG+MS(2,4) 12,6W00 77.83 261.74 5,04627 43.38 O.W 216.27 -0.27 4239 001 0.28 21631 19.75 82.76 MWD+1FR2+SAG+MS(2,4) 12,700.00 7783 261.74 5,05735 43.83 0.00 218.53 .027 42.83 0.01 028 218.56 19.92 8275 MWD+1FK+6AG+MS(2,4) 12,80000 77.83 261.74 5,05844 44.28 0.00 M78 -0.27 43.27 0.01 028 220.81 20.09 8273 MWD+1FR2+SAG+MS(2,4) 12,9W.00 7783 281]4 5,109.52 44.73 ON 223.03 -027 43.71 0.01 028 223.06 2026 82.72 MWD+1FR2+SAG+MS(2,4) 130".97 77.83 26134 5,13061 45.18 OW 225.20 4.27 44.15 0.01 0.28 225.31 2043 8271 MWD+)FR2+8AG+MS(2,4) 13,1W.00 77.83 26174 5,151.69 4563 0.00 227.53 -0.27 4459 0.01 028 227.56 20.60 8210 MWD+1FR2+SAG+MS(2,4) 13297.00 77.83 281]4 5.1]2.]8 46.08 0.00 229.78 -0.27 4503 0.01 0.28 229.82 20.77 82.69 MWD+IFR2+SAG+MS(2,4) 13.300.00 77.83 281.74 5,193.07 46.53 O.W 232.04 4.27 4547 0.01 028 232.07 20.94 82.68 MWD+IFR2+SAG+MS(2,4) 13,400.0 77.83 261.74 5,214.95 4698 O.W 234.29 427 45.91 0.01 0.28 234.32 21.11 8267 MWD+1FR2+8AG+MS(2,4) 13,500.00 77.83 261]4 5,23604 4].43 OW 236.54 4.27 46.35 0.01 0.28 238.57 21.28 82.66 MWD+1FR2+SAG+M3(2.4) 13,600.00 77.83 261.74 5,25].12 4788 OW 23879 427 4690 0.01 0.28 238.82 21.46 8265 MWD+1FR2+SAG+MS(2, 4) 13,70.00 77.83 261.74 5,278.21 48.33 0.00 241.04 .027 4724 0.01 0.28 241.07 2163 8284 MWD+IFR2+SAG+MS(2, 4) 13.800.97 77.83 261.74 5,299.29 48.7a 0.W 243.30 -0.27 4760 0.01 0.28 243.33 21.80 8263 MWD+IF1U+SAG+M5(2.4) 13,900.W 77.83 26114 5,32(1.38 49.22 097 245.55 -0.27 4812 0.01 028 245.58 2198 8262 MWD+1FR2+SAG+MS(2,4) 13,995.19 77.83 261.74 5,340.45 4967 ON 247.80 -027 48.56 0.01 028 247.83 22.15 8261 MWD+1FR2+SAG+MS(2,4) 14.00).W 77.83 261]4 5.341.46 Oar 000 247.80 4.27 48.56 0.01 028 247.83 22.15 82.61 MWD+1FR2+SAG+MS (2,4) 14,197.00 77.83 261.74 5,362.55 50.12 000 250.05 4)27 4900 0.01 028 250.08 22.33 0260 MWD+IFR2+SAG+MS(2,4) 1429700 7783 261.74 5,383.64 50.57 ON 252.31 -027 49A4 0.01 028 MM 22.50 8259 M IFR2+SAG+MS(2,4) 52872019 8:27:09AM Page 5 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kupawk River Unit -2 Site: Kuparuk 2M Pad Well: Rig: 2M-39 Wellbore: 2M-39 Design: 2M-39 wpl7 Position uncertainty and blas at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 2M-39 2M39 actual @ 137.45usft (D19) 2M-39 actual @ 137.45usft (DI 9) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Inclination Azimuth vertical MgMide Lateral Verlkal Magnitude 3emi.najor 6emiminor Gegth Depth Error Be. Error Was Error Blas W alas Eno, Emir Atlmuth Toel (usnl r) r) lush (esn) Wan) (usB) Juan) Want (usn) (usm (usal (usg) r) 1430000 77.63 261.74 5,404]2 51.02 0.00 254.55 A27 49,68 001 028 254.59 2268 82.58 MWLI+IFR2+SAG+MS (2. 4) 14,4WOO 77.83 261.74 5425.81 51.47 0.00 256.81 0.27 50.33 0.01 020 258.84 22.66 0256 MW3+IFR2+SAG+MS(2, 4) 14,50D 00 77.83 26174 5,446.89 51.92 OW 25906 -0.27 5077 0.01 0.28 25909 23.03 8257 MWD+IFR2+&kG+MS (2. 4) 14,800.00 77.93 281]4 5,467.98 52.37 O.W 261.32 -027 51.21 001 028 20134 23.21 8256 MWD+IFR2+S4G+Ms(2,4) 14,700.00 77,83 261.74 5,489.0 52.82 090 263,57 -0.27 51,65 001 028 263.59 23.39 82.55 MWO+IFR2+SAG+MS(2, 4) 14,800.00 77,63 26174 5.510.15 53.27 000 265.62 -0.27 5209 0.01 028 26585 2357 82M MWD+IFR2+SAG+M6(2, 4) 14,840.W 77.83 26114 5,518.58 53.45 0.00 26672 4.27 52.27 001 0.20 28675 2364 82.54 MWD+IFR2+GAG+MS (2,4) 14,900,00 77,46 259.31 5,53142 53.72 0.90 267.67 -0.27 5253 001 0.28 268.0 23.75 82.53 MWD+IFR2+SAG+MS (2. 4) 15,00.00 76.90 255.25 5.55361 54.43 001 268.12 -0.27 52.97 001 028 27026 23.93 8249 MWD+1FR2+SAG+MS(2,4) 15.10.00 7641 251.17 5,576.70 55.52 0.01 267.16 -0.26 53,41 0.01 0.28 27.35 24.11 8241 MW IFR2+60G+M5(2 4) 15,20.00 7596 247.07 5.600.58 57,04 002 264.75 4)26 53.65 001 026 274.33 2430 8232 MW0+IFR2+SAG+MS(2,4) 15,300.00 7562 242.96 5,625.12 58.97 002 280.90 4),25 5429 0.01 028 276.18 24.48 8220 MWD+IFR2+SAG+MS(2, 4) 15,40000 75.33 238.84 5.60.20 6126 0.03 255sl) -0.24 54.72 0.01 0,28 277.91 24.88 82.00 1AWD+IFR2+SAG+MS(2, 4) 15.500.00 75.12 23471 5,67572 63.82 0.03 248.87 -0.23 55.16 0.01 0.26 2790 24.64 61.90 MWD+IFR2+SAG+MS(2,4) 15,6000 7497 23058 5,701.53 66.57 ON 24074 0.22 55.59 001 028 28093 25.01 81.74 MWD+IFR2+SAG+MS (2. 4) 15]00.00 74.91 226.43 5,727.53 69.37 004 231.25 -020 56.03 0.01 0.28 282.21 25.19 01.57 MWD+IFR2+SAG+MS 2, 4) 15,8060 74.92 22229 5,753.57 72.11 0.05 22045 -0.19 5846 001 028 28334 25.37 8140 MW0+1FR2+SAG+MS(2, 4) 15,900.00 75.W 218.15 579.53 7469 005 208.41 -D.17 56.89 001 028 284.31 25.55 8122 MWD+IFR2+SAG+MS(2, 4) 16,000.00 75.16 214.01 5,105.29 78.98 OW 195.20 -0.16 57.32 0.01 028 285.13 2574 81.06 MWD+IFR2+SAG+MS(2,4) 16,012.35 75.16 213.50 5,808.45 78.15 005 187.09 -0.15 57.57 001 028 285.53 2585 6097 MWO+IFR2+SAG+MS(2,4) 16,057,67 75,28 211.63 5.820.00 78.15 0.05 187.09 4.15 57.57 001 028 285.53 25.85 80.97 MWD 0W5G (2. 5) 16,077.67 75.28 21163 5,825.08 78.18 005 187.26 4.15 57.52 0.01 0.28 286.26 23,69 6100 MWD OWSG (2, 5) 18,100.00 75.45 210.72 5,83072 7824 0.05 194.00 41.14 57.52 001 0.28 286.36 23.71 80.98 MWD OWSG (2, 5) 16,20D.00 76.25 206.68 5,655,17 78.14 005 168.96 -0.13 57.53 0.01 0.28 as 80 23.95 W.87 MWD OWSG(2, 5) 16,30.00 77.13 20267 5,878.20 77.,46 0.05 15331 -0.11 57.55 001 028 287.21 2442 8014 MWD OWSG(2, 5) 16,400.00 78.06 19869 51899.69 7823 005 137.17 4)09 57.56 0.01 0.26 287.59 25.12 8061 MWD OWSG(2, 5) 16,0000 79.04 194.73 5,919.56 74.53 0.04 120.69 A.07 57,62 0.01 028 287.93 26.04 8047 MWD 0W5G(2, 5) 16,58900 79.96 191.23 5,935.78 7208 0.04 105.88 -0.06 57.67 0.01 026 288,M 2705 8033 MWD 0WSG(2, 5) 10,80000 7996 191.23 5.93770 7268 0.04 105.99 Al 57.67 0.01 028 288.23 27.18 8032 MWD OWSG (2. 5) 16,70000 79.95 19123 5,955.13 72,73 0.04 107.10 A0 5774 0.01 0.28 288.52 20.53 80.16 MWD OWSG (2. 5) 16,793.61 79.96 191.23 5.971.45 72.79 006 108.28 Al 57,81 0.01 028 28881 30.0 80.00 MWD OWSG (2, 6) 16,800.W 79.96 191.23 5.972.58 7279 0.04 10828 0.0 5791 0.01 028 28881 3006 80.00 MWD OWS(3 (2,5) 16.900.00 7996 191.23 5.990.00 72.85 ON 10952 AM 5789 001 028 289.11 31.74 79.84 Munn OWSG(2,5) 17,000.00 7996 19123 000743 7282 0.04 11Dso -006 57.96 001 028 26942 33.55 79.86 MWD OWSG(2, 5) 17,10.12 7996. 191.23 6,W745 72.92 0.04 110.03 -0.06 57.98 001 028 28942 3355 7968 MM OWSG(2,5) 17,058.20 7990 19123 501758 7297 001 111.62 4).06 5804 001 028 289.60 3484 79.50 MWD OWSG(2, 5) 17,100.00 7997 189.54 6,024.86 73.25 004 104.80 -0.05 5608 0.01 028 289.73 3545 79.51 MWD 0W8G(2. 5) 17,16244 8000 18700 6.0572 73st) 0.04 94.40 -0.04 50.15 0.01 026 289.90 3671 7940 MWD OWSG(2, 5) 17,200.00 WAO 18]00 6,042.24 7363 0.04 94.99 -0.04 58.19 0.01 0.28 20.0 37.48 7933 MWD OWSG(2. 5) 17,300.00 80.00 197.00 6,05961 7322 0.04 96.62 -0.04 58.31 0.01 0.28 290.26 3962 79.15 MWD 0WSG(2,5) 9,36244 W.00 187.00 6,070.45 7379 0.01 97.67 -0.06 58.39 001 028 290.43 4099 7904 MWD 01VEG(3,6) 17,400.0 81.31 187.00 0076.55 690 00 8668 -0.04 57.76 0.01 028 287.64 27.56 60.34 MWD OW5G (3. 6) 17.500.00 84.81 167.02 6,00862 62.01 002 8767 -0.04 5737 0.01 0.28 288.06 28.31 00.19 MWD OW6G(3.6) 17,600.00 6831 167,03 6,094.61 5609 0.90 88.76 -0.04 5779 001 0.28 26829 29.32 00.04 MWD OWSG (3, 6) 17,7W.00 9181 187.04 8,094.50 58.71 -0.02 89.94 4).04 57.02 0.01 0.28 280.52 W57 79.09 MWD OWSG(3, 6) 17,708.87 92.12 187.04 6,094.19 58W -002 90.05 -0.04 57.82 0.01 028 200.54 30.68 79.67 MWD OWSG (3, 6) 17,800.00 92.12 187.04 6,(190.82 5902 -0.02 91.17 4).04 57.86 0.01 028 20078 3201 7973 MWD oma (3, 6) 17,900.00 92.12 18704 8.17.11 5907 -0.02 92.48 -0.04 57.91 0.01 028 20900 3363 7957 MWD OWSG(3, 6) 18,00000 92.12 18104 6.08340 59.13 -0.02 loss 0W 57.97 001 028 28925 3541 7941 MWD census (3, 0) 18.100.0 92.12 187.04 6,07969 59.20 -0.02 9535 A04 5804 001 0.28 28950 3731 7924 MWD OWSG(3.6) 18200.0 92.12 18704 6,075.98 59.27 -0.02 96W 0.06 58.12 001 028 289.76 30.32 7907 MWD OWSG(3,6) 18,300.00 92.12 18704 807226 59.35 -0,0 98.52 004 58.21 0.01 0.28 29002 4143 78.89 MWD 0WSG(3,6) 10,40000 92.12 18704 6,068.57 59.0 4).02 100.22 -0.04 58.31 001 0.28 290.28 4361 78.71 MWD 0WSG(3,6) 18,439.82 9212 107.04 6,067.09 59.51 A.02 100.91 -004 5835 001 028 29040 44.49 70.64 MWD OWSG(3,6) &2&12019 8..27..09AM Page 6 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kupanik River Unit -2 Site: Kupamk 2M Pad Well: Rig: 2M-39 Wellbore: 2M-39 Design: 2M-39 wp17 Position uncertainty and blas at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 210-39 2M-39 actual @ 137.45usfl (D19) 2M-39 actual @ 137.45usft (D19) True Minimum Curvature 2.00 sigma OAKEDMPI Maasumd Inclina8en Axl u wHical Higbslde Lateral Venin] M ... ftw. semvnajer Semiminor O PM papa Error elan Eno, Bias Error Blas MBias Ermr E., M..M Tool N.") r) r) (usl) (usft) (-eft) (esC) (usa) (usa) (usft) (elft) (-A) (.aft) r) 18.500.00 90.23 188.11 6.06506 56.47 -001 98.06 �a03 5842 0.01 028 290.56 4585 78.53 MWD OWSG(3.6) 10,507.38 90.00 18600 6%584 58.43 -061 97.72 -003 58.43 0.01 028 29058 46.03 7852 MWD OWSG(3, 6) 10,553.21 8907 184.69 6066.21 58.51 0.00 93.12 -003 5849 0.01 0.28 290.69 47.10 78.43 MWD OWW(3,6) 18,60000 89.07 164.69 6,066.97 58.57 0.00 94.03 -0.03 58.54 0.01 028 290.01 4621 7834 MWD 05056(3, 6) 18,700.00 89.07 184.69 8068.59 50.70 000 96.04 -0.03 50.68 001 0.28 29107 50.63 78.15 MWD OWSG(3,6) 10.800.00 09.07 18469 6.070.21 58.04 0.00 98.10 403 58.82 0.01 028 291.32 53.09 77.96 MWD OWSG(3. 6) 10,900.00 8907 10489 6,071.63 58.19 000 82.93 -0.03 58.17 0.01 020 288.99 36.10 79.50 MWD+IFR2+SAG+MS(4, 6) 19.00000 89.07 184.69 6,073.45 5825 000 83.56 -0.03 5823 0.01 0.20 209.07 36.90 79.54 MWD+IFR2+SAG+MS(4.6) 19,084.12 8907 18469 6,074.82 50.30 0.00 84.10 -0.03 56.28 001 028 289.14 37.75 79.49 MWD41FR2+SAG+MS(4, 6) 19,100.00 89.09 185.7 6,075.07 50.31 0.00 8626 4.03 50.29 0.01 0.20 28915 3790 7949 MWD+IFR2+SAG+MS(4,6) 19,19445 89.20 188.W 6,076.48 58.35 0.00 99.17 -0.04 58.35 0.01 0.28 28923 30.77 7943 MWD+IFR2+SAG+MS(4, 6) 19.200.00 8922 188.16 6,076.56 58.35 0.00 99.92 -0.04 58.35 001 0.28 289.24 3882 7943 MWD+IFR2+5AG+MS(4,6) 19,300.00 69.67 191.13 6,07.52 50.39 -001 113.44 -0.06 50.42 001 028 299.34 39.73 7937 MWD+IFR2+SAG+MS(4,6) 19,35232 89.91 192.66 6.07.71 50.44 4.01 120.47 4.06 5845 0.01 028 28840 40.20 7934 MWD+IFR2+SAG+MS(4,6) 19,400.00 89.91 192.68. 6,07739 5840 -0Ot 12073 -006 5849 0.01 0.28 2W,15 4063 7981 MW0+IFR2+SAG+MS(4,6) 19,50000 8991 19260 6077,95 58.55 -0.01 121.29 -0.06 50.56 001 0.20 289.57 41.53 7925 MWD+IFR2+3AG+MS(4,6) 19.600.00 89.91 19260 6,078.11 50.83 -0.01 121.07 41.% 58.63 001 0.28 28969 4265 79.19 MWD+IFR2+SAG+M8(4,6) 19,700.00 89.91 19268 6,078.27 W.70 -001 122.45 QW 58.71 001 028 289.81 4538 79.13 MWD+IFR2+SAG+MS(4,6) 19.800.00 0991 192.68 6,078A3 58.79 -0.Gt 12305 -006 SB.W 001 0.28 289.93 44.33 79.06 MWD+IFR2+5AG+MS(4,6) 19,90000 8991 19268 6.078.59 58.87 4.01 123.65 -050 5888 0.01 028 290.06 45.20 7800 MWD+IFR2+SAG+MS(4, 6) W.000,W 8991 19260 6,070.75 5898 -0.01 12829 -0% 58.97 001 0.28 290.18 4825 7894 MWD+IFR2+SAG+M8(4.6) 2010050 8991 19288 6.07891 59.06 4.01 124.92 008 5807 0.01 028 290.31 47.23 7887 MWD+IFR2+SAG+MS(4, 6) 20,145.37 69.91 192.68 6,07898 59.10 -0M 12521 4.06 59.11 0.01 0.28 290.37 47,68 70.84 MWD+IFR2+8AG+MS(4,6) 20,200.00 88.82 19258 6,079.59 59.26 0.00 125.12 -006 5916 0.01 0.28 290.43 48.22 7880 MWD+1FR2+SAG+MS(4,6) 20,241.22 saw 192.50 6,080.73 59.65 0.00 125.% -0.06 5921 0.01 020 2049. 40.63 70]0 MWD+IFR2+SAG+MS(4.6) 20300.50 8684 192.31 6108330 60.60 001 124.66 -0.W 5826 0.01 028 29056 4922 7874 MWD+IFR2+BAG+MS(4,6) 20,301.58 6681 192.31 6,W3A6 6063 0.01 124.65 4.W 59.27 0.01 0.28 290.56 4924 7874 MWD+IFR2+SAG+MS(4.6) 20,400.00 86.81 192.31 6.0894 6073 0.01 125.31 406 $9.37 0.01 028 29069 50.23 70.67 MWD+IFR2+SAG+MS(4, 6) 20.500.00 W81 19231 6,094.51 60.83 0.01 125s9 AN 59A0 0,01 0.20 290.02 51.25 70.60 WND+IFR2+SAG+MS (4.6) 20,600.00 86.81 192.31 6.100.06 60.94 0.01 126.69 -006 59.59 0.01 028 290.95 52.28 7853 MWD+1FR2+SAG+MS(4, 6) 2070000 06.81 192.31 6,150.85 6105 0.01 127.39 -0.06 59.70 001 028 29108 5331 7846 MWD+IFR2+8AG+MS(4,6) 20800.00 88.01 19231 6.111.21 61.17 001 120.11 4W 59.02 001 026 29122 54.35 7839 MWD+IFR2+SAG+MS(4,6) 20,815.39 Mal 192.31 6,112.07 61.16 0.01 12822 4.06 5963 0.01 0.20 291.24 M51 78.37 MWD+IFR2+SAG+MS(4,6) 20,874.99 W.00 19233 6,114.77 6035 0.00 12875 -0.06 5891 0.01 028 291.32 55.13 70.33 MWD+IFR2+SAG+MS(4, 6) 20,900.00 80.50 19233 6,115.53 60.14 000 126.95 -0.W 59.94 001 028 291.35 55.39 7831 MWD+IFR2+SAG+MS(4,6) 20,%3.63 8937 192.34 6,116.49 59.99 -001 129.46 O% 60.01 001 028 29144 56W 7826 MWD+IFR2+SAG+M8(4,6) 21050.00 69.77 192.34 6,11664 6004 4,01 129.72 -0.06 60.06 0.01 0.28 291,49 56.44 78.24 MWD+IFR2+SAG+MS(4,6) 21,100.00 09.77 19234 6.117.0 60.17 -0.01 130A7 -006 60.18 0.01 0.20 291.63 57.49 76.16 MWD+IFR2+SAG+MS(4.6) 21,20000 09.77 19234 6,17.43 60.29 -0.01 131.22 -0.06 80.31 0.01 0.20 29177 50.55 70,09 MWD+IFR2+SAG+MS(4,6) 2130000 89.77 19234 6,117.83 60.43 -0.01 131.99 -0.% 6045 0.01 028 291.91 59.61 78.01 MWD+IFR2+SAG+MS(4, 6) 21,400.0 894 192.34 6,110.22 60.56 AAt 13276 -0.06 W.50 001 028 29206 6060 n,93 MWD+IFR2+SAG+MS(4,6) 21,420.45 09.77 192.34 6.118.30 6059 -001 132.92 -0.% 60.61 0.01 020 292.09 60.90 77,91 MWD+IFR2+SAG+MS(4, 6) 21,474.13 88.70 192.30 6,11902 60.81 0.00 133.16 0.06 6050 0.01 0.20 292.16 61,47 77,87 MW0+IFR2+SAG+MS (4,6) 21,500.00 00.18 192.20 6.119]2 61.06 0.00 133.30 Ans 60.72 0.01 028 292.20 61.75 77,85 MWD+IFR2+SAG+MS(4, 6) 21,522.45 87.73 192.27 6,120.52 61.34 0.00 133.42 -0.W 6015 0.01 0.28 29223 61.99 7703 MWD+IFR2+5AG+MS(4,6) 21,600,W 07.73 19227 6,123.59 61.45 000 13404 AM 60.86 001 020 29235 62.82 77.77 M [FR2+SAG+MS(4,6) 21.7W.W 6733 19227 6,127.54 6159 000 13484 -0.W 61.01 0.01 028 29249 6390 77.69 MWD+IFR2+SAG+MS(4,6) 21,800.00 0733 19227 6,13150 6174 0.50 13565 4.06 61.15 0.01 0.28 29264 64.98 77,61 MWD+IFR2+SAG+MS(4,6) 21.%0.00 07.73 192.27 6,135A5 61.69 0.50 IMA7 -0.W 61.30 0.01 0.20 29280 66.06 77.52 MWD+IFR2+6AG+MS(4,6) 22,W000 87.73 192.27 6.13940 6204 0.W 137.30 -006 61.46 0.01 028 292.95 67.15 77,44 MWD+IFR2+SAG+MS(4, 6) 22,019.61 87.73 19227 6,140.10 62,07 0.00 137.46 A.06 61.49 0.01 028 292.98 6]36 7742 MWD+IFR2+SAG+M5(4, 6) 22,1 W.W 09.34 19229 6,142.23 61.61 000 130.22 -0.% 61.62 0.01 020 293.10 68.24 7.35 MWD+IFR2+SAG+MS(4,6) 22,132.92 9000 192.30 6,142.42 61.67 -0.01 13853 -0.03 61.67 0.01 0.20 293.15 66.59 7732 MWD+IFR2+SAG+M8(4.6) 22,200.00 91.34 192.33 8,14183 82.23 4.01 139.22 4.06 61.77 0.01 0.28 293.26 69.32 77.26 MWD+IFR2+SAG+MS(4, 6) 52872019 8.27.094M Page 7 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska Inc Kuparuk Project: Kuparuk River Unit_2 She: Kuparuk 2M Pad Well: Rig: 21039 Wellbore: 2M-39 Design: 2M-39 wp17 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 2M-39 2M39 actual @ 137.45usft (D19) 2M-39 actual @ 137.45usft (D19) True Minimum Curvature 2.00 sigma OAKEDMPI Position uncertainty and bias at survey station a.a,-fae Indinmun Azlm-O var0cal Hi90nida IrtMm1 wmN .l Magni da Se ajor SemimMor EXPO EXPO Emor am E.r Biqa Error Bias W BMs Emor Error AvmuO Teo] IPaftl fl f) (-aft) (usft) (usft) (usft) (waft) (usft) (usft) (usn) (usft) (waft) 0 22,20783 91.49 192.34 6,14145 62.34 -001 139.30 -006 6179 0.01 028 29327 69.40 77,26 MWD+1FR2+8AG+M5(4, 6) 2$300.00 9149 192.34 6,139.04 6249 '3ol WAS 4).% 61.94 001 028 29342 70.41 77.18 MWD+1FR2+SAG+MS(4,6) 22,400.00 91.49 19234 6,136.43 6265 .0.01 140.94 4.00 62.10 0.01 0.28 293.58 71,49 77.09 MND+IFR2+SAG+MS(4,6) 22,470.01 91.49 19234 613461 6277 4).01 141.54 -008 62.22 001 028 29369 72.26 77.02 MWD+1FR2+SAG+MS(4, 6) 22.50000 9090 192.37 6,133.98 62.51 UM 141.95 4).% 6227 0.01 028 29374 72.58 77.00 MW1)+]FR2+SAG+MS(4, 6) 22,504,77 90.80 192.38 6,133.91 6248 -0.01 142.01 -0.06 6228 0.01 020 29375 72.63 76.98 MMOFR2+SAG+MS(4,6) 22.527.86 90.34 192.40 6,133.68 62.38 4).01 14230 -0.06 62.32 001 0.26 293.78 72.89 76.97 MWD+1FR2+SAG+MS(4,6) 22,800.00 90.34 192.40 6,133.25 6250 -0.01 142.92 U.% 62.44 001 028 293.90 73.67 7690 MWD+IFR2+SAG+MS(4,6) 22,700.00 90.34 19240 6,132.66 62.67 4).01 14380 -0.08 62.61 0.01 028 29407 74.77 7681 MND+IFR2+SAG+MS(4,6) 22.800.00 90.34 19240 6,13207 62.85 41.01 144.69 -0.% 62.79 0.01 0.28 294.24 75.86 76.72 MND+IFR+SAG+M6(4,6) 22,90000 9034 192.40 6,131.48 63.03 -0.01 145.58 -008 6297 0.01 028 29440 76.95 7862 MWD+1FR2+SAG+MS(4,6) 23,000.00 90.34 192.40 6,130.89 63.21 -001 146.40 -0.06 6115 0.01 0.28 2&4.58 78.05 76.53 MAD+IFR2+SAG+MS(4.6) 23,100.00 90.34 192.40 6.130.30 6340 4).01 147.39 405 63.34 0.01 028 29435 79.14 76.43 MND+1FR2+SAG+MS(4.6) 23,190.89 9034 19240 6,129.71 63.58 43.01 148.29 4.% 83.52 001 028 2%.92 8023 7633 MWD+IFR2+SAG+MS(4, 6) 2320000 9032 19239 6,129.71 63.50 -0.01 148.27 -0.06 63.52 001 028 29192 0024 76.33 MND+IFR2+SAG+MS(4,6) 23,216.71 moo 192.29 6,129.66 63.56 4).01 148.04 4).06 63.56 0.01 0.28 294.95 8042 7631 MND+1FR2+SAG+MS(4, 6) 23,30000 88.33 192.29 6,130.87 63.95 0.00 148.81 UAB 63.71 0.01 0.28 29510 81.34 7823 MM-1M2+SAG+108(4,6) 23.305.46 8823 192.9 6,13103 64.02 000 148.88 -0.06 63.72 0.01 0.28 295.11 8140 76.23 MM+1FR2+SAG+MS(4,6) 23,400.W 08.23 192.29 6,133.96 U." am 149.74 4).06 63.91 0.01 0.28 29528 8244 76.13 MWD+IF112+SAG+MS(4,6) 23.50.00 88.23 19229 6,137.06 64.40 OM 15067 4.% 81.10 001 028 295.46 8354 76.03 MWD+IFn+SAG+MS(4,6) 23,60000 88.23 19229 6.140.16 64.59 0.00 151.61 -0.06 64.30 0.01 028 295.64 84.00 7593 MWD+1FR2+8AG+MB(4,6) 23,700.00 00.23 19229 6,143.26 64.79 OW 152.58 4).% 64.50 001 0.28 295.83 85.74 75.82 MWD+IFR2+3AG+MS(4,6) 23,8W.W 8623 192.29 6,146.35 6500 0.00 153.52 -0.00 13431 0.01 0.28 296.01 86.84 75.72 MND+1FR2+SAG+MS(4,6) 23,90.00 8823 19229 6,14945 6520 ow 154.48 -0.06 64.91 0.01 028 2%20 87.94 7561 MvVD+1FR2+SAG+MS(4, 8) 24,000.00 88.23 19229 6,152.55 65.41 000 155.44 .006 65.12 0.01 0.28 29839 89.04 75.W MWD+1FR2+SAG+MS(4,6) 24.100.00 88.23 19229 6,15585 65.82 0.00 156.41 U.06 6533 001 0.28 296.59 90.14 75.39 MND+IFR2+SAG+MS(4,6) 24200.00 8823 192.29 6,158.74 65.83 0.00 15739 -O.W 65.55 0.01 028 296.78 9123 7528 MND+1FR2+SAG+MS(4,6) 24.239.25 88.23 19229 81159.96 65.91 0.0) 15737 4).% 6563 0.01 0.28 2%.86 War 7524 MWD+1F(U+5AG+MS(4, 6) 24,252.37 87.90 192.33 6,160.40 66.10 000 15805 4),% 65.66 0.01 028 296.89 91.81 75.22 M IFR2+SAG+MS(4.6) 24,268.13 87.51 192.36 6,161.03 66.37 0.00 158.32 4)08 6569 001 0.26 296.92 91.98 7521 MND+1FR2+SAG+MS(4, 6) 24,300.00 Psi 19238 6,162.42 66.44 O.W 158.63 -o06 65.76 0.01 0.28 296.98 92.33 75.17 MWD+1FR2+SAG+MB(4.6) 24,400.00 87.51 192.35 6,166.77 88.65 0.00 15962 U.% 65.% 001 0.28 297.18 93.43 7508 MWD+]FR2+SAG+MS(4, 8) 24,500.00 8751 192.36 6.171.12 W37 0.00 16061 4),00 6620 0.01 028 29738 94.52 74.94 MWD+IFR2+SAG+MS(4,6) 24,596.93 87.51 192.36 8,175.34 67.08 ow 161.57 -006 66.42 0.01 0.28 297.58 95.59 7463 MWD+IFR2+SAG+MS(4,6) 24,60QW 87.58 192.36 6,175.47 67.04 000 16160 4).% 86.42 0.01 0.28 297.59 9562 7483 MND+1FR2+34G+MS(4,6) 24,700.03 %.08 192.31 8,177,50 NAG 4.01 152.42 4).05 6665 0.01 020 29780 96.71 74.71 MM+1FR2+SAG+MS(4,6) 24,71668 9050 192.30 6,177.42 66.78 -0.01 162.56 -006 INN 0.01 0.28 297.83 96.89 7469 MW 1FR2+SAG+MS(4,6) 24,800.00 92.58 192.23 6,175.18 68.18 -0.02 163.16 -0.06 65.88 0.01 028 29800 97.80 74.59 MWD+IFR2+SAG+MS(4, 6) 24,827.41 93.27 192.21 6,17378 68.92 .002 16336 4.06 W94 001 028 290.06 96.10 74.56 MND+IFR6+SAG+MS(4,6) 24,90.W 93.27 19221 6,16964 6008 43.02 164.09 4)06 67.11 001 028 29821 90.89 7447 MM+IFR2+SAG+MS(4, 6) 2494347 9327 19221 6.167.17 69.10 -0.02 164.53 4.06 67.21 0.01 028 298.31 99.38 7442 MW 1FR2+SAG+MS(4,6) 25.000.00 92.14 192.21 61164.50 68.27 4.02 18509 U.% 67.34 0.01 028 298.43 99.97 7435 MWD+1FR2+8AG+01S(4, 8) 25.096.81 90.20 19220 6,162.53 67.59 Uoi 166.06 4.06 6756 0.01 0.28 290.63 10102 74.23 MND+1FR2+SAG+MS(4,6) 25,100.00 WA4 192.9 6,162.52 67,59 -0.01 1%.19 -006 67.57 0.01 028 29864 101.06 74.23 MWD+IFR2+SAG+MS(4,6) 25,10802 90.00 19200 6,162.51 67.59 -001 166.51 -0.06 6)59 0.01 0.28 29863 101.15 74.22 MM 1FR2+SAG+MS(4,6) 25.20.00 00.00 192.30 6,16251 67,81 U.01 16745 4.06 67.81 o01 0.20 298.86 102.15 74.10 MWD+11`112+SAG+MS(4,6) 25,30000 90.00 19230 6,162.52 68.05 4.01 168.48 4.06 68.05 001 028 299.08 10323 7398 MND+1FR2+SAG+MS(4, 6) 25,600.00 90.00 19230 6,162.52 6829 4).01 16952 4).% 6829 001 09 29960 10431 73.85 MWD+IFR2+SAG+MS(4, 5) 25,50.00 90.00 192.30 6.162.53 68.53 -0.01 170.56 600 6&53 0.01 0.28 299.53 10540 7372 MM 1FR2+SAG+MS(4.6) 25,541.59 90M 192.30 6,16253 68.63 4).01 170.99 006 6863 0.01 028 299.63 105.85 7367 MWS Wn+SAG+MS(4,6) 25,54427 90.00 19235 6,162.53 6664 -0.01 171.20 -0.06 60.84 0.01 028 299.83 10568 7387 MWD+IFR2+SAG+108(4,6) 25.600.00 B9.89 192.35 61162M 6837 -0.01 171.83 -0.10 W.78 0.01 028 299.76 IW48 73.80 MND+IFR2+SAG+MS(4,6) 25,70.00 8968 192.39 6,162.96 W.W -001 17295 0.06 69.02 001 0.28 29999 107.% 7346 MWD+IFR2+SAG+MS(4,6) 25,800.W 89.48 192.41 616369 6926 4,01 174.08 4)06 69.27 001 0.28 30.23 10863 73.33 MWO+1FR2+5AG+M5(4,6) 512872019 8:27:09AM Page 8 COMPASS 5000.14 Build 85D Company: Project: Site: Well: Wellbore: Design: ConocoPhillips Alaska lnc Kuparuk Kuparuk River Unh_2 Kuparuk 2M Pad Rig: 2M-39 2M-39 2M-39 wpl7 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 2M-39 2M-39 actual @ 137.45usft (D19) 2M39 actual @ 137.45usft (D19) True Minimum Curvature 2.00 sigma OAKEDMPI Position uncertainty and bias at survey station lk"Sure Inclination AzimuO Verfl.l Highside laleral Verllcl MggnimVe Semimajor semlminor oepM oepm Error Bias Erre, Blas Error 61az of Bias Error Error Azlmuei Tool (use) hl PI (usn) (usn) (usn) (usn) (use) (usel (usn) (use) (uSn) tusnl (•) 25,900.00 89.28 192." 6,164,77 69.52 0.00 17532 006 69.53 0.01 028 3W.46 109.71 7320 MWo+IFR2+8AGWS(4,6) 26.000.00 89.07 19348 6,165.21 69.80 000 176.36 -006 69.78 001 028 300]0 110J8 7308 MRD+IFR2+SAG+M8(4,6) 2603.98 89.00 192.47 6,166.78 6990 0.00 176.74 -0.06 69.87 0.01 0.28 300.79 111.15 7302 MW IFR2+SAG+MS(4,6) Y282019 8:27.'09AM Page 9 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska lnc Kupawk Project Kupawk River Until Site: Kupamk 2M Pad Well: Rig: 2M-39 Wellbore: 2M-39 Design: 2M-39 wpl7 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 210-39 2M-39 actual @ 137.45usft (D19) 2M39 actual @ 137.45usft (D19) True Minimum Curvature 2.00 sigma OAKEDMPI Design Targets Target Name -hi0miss target Dip Angle Dip Dir. TVD ♦WS +PJ•W -Shape (1 (1) (usft) (usft) (usft) 2M-39 T03 020818 JM 0.00 0.00 6,065.84 -4,241.15 -13,570.08 - plan misses target center by 89.50usft at 18497.08usft MD (6065.87 TVD, -4230.90 N, -13658.99 E) -Circle (radius 100.00) 2M-39 T01 Heel 020818 0.00 0.00 6,070.45 -3,206.71 -13,370.76 - plan misses target center by 161.53usft at 17442.84usft MD (6082.46 TVD, -3185.61 N, -13530.45 E) - Circle (radius 100.00) 2M-39 T04 020818 JM 0.00 0.00 6,076.48 -4,925.46 -13,719.97 - plan hits target center - Circle (radius 100.00) 21V-39 T05 020818 JM 0.00 0.00 6,080.73 -5,947.94 -13,943.30 - plan hits target center - Circle (radius 100.00) 2M-39 T06 020818 JM 0.00 0.00 6,114.77 -6,566.22 -14,078.30 - plan hits target center -Circle (radius 100.00) 2M-39 T07 020818 JM 0.00 0.00 6,119.02 -7,151.49 -14,206.34 - plan hits target center -Circle (radius 100.00) 2M-39 T70020818 JM 0.00 0.00 6,129.66 -8,853.28 -14,578.57 - plan hits target center - Circle (radius 100.00) 2M39 709020818 JM 0.00 0.00 6,133.91 -8,157.95 -14,425.71 - plan hits target center - Circle (radius 100.00) 2M-39 TOB 020818 JM 0.00 0.00 6,142.42 -7,794.79 -14,346.30 - plan hits target center -Circle (radius 100.00) 2M-39 T11 013018 JM 0.00 0.00 6,160.40 -9,864.74 -14,798.93 - plan hits target center -Circle (radius 100.00) 2M39 714013018 JM 0.00 0.00 6,162.53 -11,126.32 -15,073.87 - plan hits target center -Circle (radius 100.00) 2M-39 77 3 013018 JM 0.00 0.00 6,162.53 -10,689.12 -14,978.59 - plan hits target center - Circle (radius 100.00) 210-39 T75 Toe 013018. 0.00 0.00 6,166.78 -11,604.55 -15,179.10 - plan hits target center -Circle (radius 100.00) 2M-39 T12013018 JM 0.00 0.00 6,177.42 -10,317.95 -14,898.19 - plan hits target center -Circle (radius 100.00) 5@8/2019 8..27:09AM Page 10 COMPASS 5000.14 Build 850 Company: ConocoPhillips Alaska lnc Kupamk Project: Kupamk River Unit -2 Site: Kuparuk 2M Pad Well: Rig: 2M-39 Wellbore: 2M-39 Design: 2M-39 wpl7 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 2M-39 2M-39 actual (a) 137.45usft (Dig) 2M-39 actual @ 137.45usft (D19) True Minimum Curvature 2.00 sigma OAKEDMPI Casing Points - Measured Measured Vertical Dip Casing Hole Depth Depth (usft) Diameter Diameter (usft) (usft) Name (in) (in) 2,860.00 2,646.80 13 3/8" x 16" 13.325 16.000 16,057.67 5,820.00 9 5/8" x 121/4" 9.625 12.250 17,362.44 6,070.45 7'x8-1/2"by9-7/6" 7.000 9.875 26,033.96 6,166.78 4-1/2"x6-1/8" 4.500 6.125 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology r) 11) 3,282.36 2,943.45 Camp SS 0.00 8,342.03 4,148.45 C-50 0.00 10,703.83 4,646.45 C-37 / Iceberg 0.00 12,415.91 5,007.45 Base Iceberg/Growler 0.00 13,995.19 5,340.45 C-35 0.00 16,012.35 5,808.45 THRZ 0.00 16,793.61 5,971.45 K-1 17,000.12 6,007.45 BHRZ/TKLB 17,362.44 6,070.45 Top Kup 5`2812019 8.27.09AM Page 11 COMPASS 5000.14 Build 85D Company: ConocoPhillips Alaska lnc_Kuparuk Project: Kupawk River Unit -2 Site: Kuparuk 2M Pad Well: Rig: 2M-39 Wellbore: 2M-39 Design: 21V-39 wpl7 Plan Annotations ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Rig: 2M-39 2M39 actual @ 137.45usft (Di 9) 2M-39 actual @ 137.45usft (D19) True Minimum Curvature 2.00 sigma OAKEDMPI Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 2,809.37 2,609.41 235.21 -774.11 Adjust TF to O", for 50.63' 2,860.00 2,646.80 238.18 -808.13 Adjust TF to 0°, for 30' 2,890.00 2,668.95 239.94 -828.28 Start 4'/100' DLS, 130° TF, for 70' 2,960.00 2,721.35 245.26 -874.37 Adjust TF to -30°, for 300- 3,260.00 2,929.62 260.70 -1,088.98 Adjust TF to 0*, for 600' 3,860.00 3,196.90 266.57 -1,621.23 Start 3°/100' DLS, -75° TF, for 300- 4,160.00 3,266.65 247.07 -1,912.04 Hold for 10680- 14,840.00 5,518.58 -1,252.87 -12,243.62 Start 4-/100'DLS,-99' TF, for 1217.67' 16,057.67 5,820.00 -1,877.86 -13,199.69 Hold for 20' 16,077.67 5,825.08 -1,894.33 -13,2139.84 Start 4°/100' DLS, -79.14° TF, for 511.33' 16,589.00 5,935.78 -2,356.72 -13,390.49 Hold for 469.2- 17,058.20 6,017.58 -2,809.88 -13,480.50 Start 4.1100' DLS, -89.82° TF, for 104.24- 17,162.44 6,035.72 -2,911.22 -13,496.76 Hold for 200' 17,362.44 6,070.45 -3,106.71 -13,520.76 Start 3.5°/100' DLS, 0.18' TF, for 346.43' 17,708.87 6,094.19 -3,449.09 -13,562.91 Hold for 730.96' 18,439.82 6,067.09 -4,174.04 -13,652.41 Start 3.5°/100' DLS, -153.96° TF, for 67.56' 18,507.38 6,065.84 4,241.15 -13,660.08 Adjust TF to -125.38-, for 45.82' 18,553.21 6,066.21 -4,286.77 -13,664.35 Hold for 530.92' 19,084.12 6,074.82 -4,815.84 -13,707.77 Start 3°/100' DLS, 87.8° TF, for 110.33' 19,194.45 6,076.48 4,925.46 -13,719.97 Adjust TF to 81.42', for 157.86' 19,352.32 6,077.71 -5,080.71 -13,748.29 Hold for 793.06' 20,145.37 6,078.98 -5,854.42 -13,922.41 Start 2.1100' DLS, -174.53° TF, for 95.84' 20,241.22 6,080.73 -5,947.94 -13,943.30 Adjust TF to -170.77', for 60.36' 20,301.58 6,063.46 -6,006.83 -13,956.25 Hold for 513.81' 20,815.39 6,112.07 -6,508.06 -14,065.59 Start 2°/100'DLS, 1.15' TF, for 59.59' 20,874.99 6,114.77 -6,566.22 -14,078.30 Adjust TF to 0.45°, for 88.64- 20,963.63 6,116.49 -6,652.79 -14,097.23 Hold for 456.82' 21,420.45 6,118.30 -7,099.05 -14,194.89 Start 2"/100'DLS, -177.66-TF, for 53.68' 21,474.13 6,119.02 -7,151.49 -14,206.34 Adjust TF to -178.23-, for 48.32' 21,522.45 6,120.52 -7,198.68 -14,216.62 Hold for 497.16' 22,019.61 6,140.18 -7,684.10 -14,322.19 Start 2°/100' DLS, 0.76" TF, for 113.31' 22,132.92 6,142.42 -7,794.79 -14,346.30 Adjust TF to 1.36°, for 74.72- 22,207.63 6,141.45 -7,867.77 -14,362.23 Hold for 262.37' 22,470.01 6,134.61 -8,124.00 -14,418.27 Start 2°/100' DLS, 176.33" TF, for 34.77' 22,504.77 6,133.91 -8,157.95 -14,425.71 Adjust TF to 177.38°, for 23.08' 22,527.86 6,133.68 -8,180.50 -14,430.66 Hold for 671.03' 23,198.89 6,129.71 -8,835.87 -14,574.76 Start 2-1100'DLS, -161.87°TF, for 17.82- 23,216.71 6,129.66 -8,853.28 -14,578,57 Adjust TF to -179.99', for 88.75' 23,305.46 6,131.03 -8,939.98 -14,597.46 Hold for 933.79' 24,239.25 6,159.96 -9,851.93 -14,796.13 Start 2.5°/100' DLS, 172.99° TF, for 13.12' 24,252.37 6,160.40 -9,864.74 -14,798.93 Adjust TF to 175.27°, for 15.76' 24,268.13 6,161.03 -9,880.12 -14,802.29 Hold for 328.8' 24,596.93 6,175.34 -10,200.99 -14,872.62 Start 2.5°/100' DLS, -1.2' TF, for 119.75' 24,716.68 6,177.42 -10,317.95 -14,898.19 Adjust TF to -1.85", for 110.73' 24,827.41 6,173.78 -10,426.09 -14,921.68 Hold for 116.06' 24,943.47 6,167.17 -10,539.34 -14,946.19 Start 2"/100' DLS, -179.8° TF, for 153,34' 25,096.81 6,162.53 -10,689.12 -14,978.59 Adjust TF to 154.54°, for 11.22' 25,108.02 6,162.51 -10,700.08 -14,980.97 Hold for 433.57' 25,541.59 6,162.53 -11,123.71 -15,073.30 Start 2°/100' DLS, 87.28° TF, for 2.68' 25,544.27 6,162.53 -11,126.32 -15,073.87 TD: 25544.27'MD, 6162.53'TVD 26,033.96 6,166.78 -11,604.55 -15,179.10 TO at 26033.96 Checked By: Approved By: Date: I 54282019 8.'27:09AM Page 12 COMPASS 5000.14 Build 85D Pool Report 9'27, May 282019 2M-39 wp17 LL'ELLBCRE .;a M 24.ID ra.1.. i4R TPIRILB M.84 .7O MAP CPCPOIIMlE9) , ,1. 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Region: alaska r Latitude/Longitude IDecimalDegrees r Latitude/Longitude IDecimalDegrees I C UTM Zone: F— r- South T UTM Zone: True r South r Legal Description NAD27 only) Units us -ft II �r Legal Description (NAD27 Units: us Ft -- i G State Plane Zone: J 1 - Starting Coordinates:--- ----- ---------- -Ending Coordinates --------- --- - --- X: 1627195.05 X: 487162.157737788 I Y: 5948974.82 Y: 5949224.7461697 ......................................................... .Transform ! Quill Help 2M-39w 17 Intermediate I Casing CPAI Coordinate Converter — ❑ X From: ___. _ ___—____ -To:— Datum: NAD63 Region alaska I Datum:NAp27 Region: alaska C Latitude/Longitude Decimal Degrees t' Latitude/Longitude IDecimal Degrees r UTM Zone: F -- r South II" C UTM Zone: True r South t� State Plane Zone: .J Units: us-ft----1 State Plane Zone: �� Units: us--ft i f Legal Description (NAD27 only) C' Legal Description (NAD27 only) F Starting Coordinates.-- --- -- — r Ending Coordinates - - -- - ------ X 1614801.24 1 i X: I 474768.898608905 Y: 15946879.43 Y. r594712,9.61422578 (.............. .Transform...,,,,.,,,,..,,.y quit Help 2M-39wp17 Intermediate II Casing CPA[ Coordinate Converter — ❑ X �-From: To: - Datum: NAD83 � Region: alaskaDatum: NAD27 Region alaska r Latitude/Longitude Decimal Degrees Y' Latitude/Longitude IDecimal Degrees t' UTM Zone: r r- South r' UTM Zone: True r South t: State Plane Zone: �� Units: us-6 �� i �' State Plane Zone: I' J Units: - -ft r Legal Description (NAD27 only) t' Legal Description (NAD27 only) r- Starting Coordinates: — - —--; - Ending Coordinates: --- -- - X: 1614478.18 X 474445.007285054 t Y. 5945651.24 '., � I Y: 5945901.44888225 ......... .... ........ ._....._....---..._—.., €Transform quit Help 2M -39w 17 Top of Production Horizon CPAI Coordinate Converter - ❑ X From:----- - -- ----_.-- ------ Datum:NAD83 Region: alaska j C' Latitude/Longitude IDecimalDegrees C' UTM Zone: r- South t: State Plane Zone: Unita: P, -ft f Legal Description (NAD27 only) To:.. Datum: NAp27 Region: alaska t' Latitude/Longdude IDecimalDegrees _ r UTM Zone: True r South C•' State Plane Zone: 14 --:-D Units: urft f Legal Description (NAD27 only) Starting Coordinates: -- Ending Coordinates:-- ---- X: 1614478.16 'i X: 474445.007285054 Y: 5945651.24 Y: 5945901.44888225 Transform r Out Help 2M-39wp17 TD M CPAI Coordinate Converter - ❑ X -From: _._._ -_ _____. To: .. Datum: INAD83 Region: jalaska 11 Datum: NAD27 J Region: alaska r Latitude/Longitude IDecimalDegrees r Latitude/Longitude IDecimalDegrees —� C' UTM Zone: i South r UTM Zone: True r South G State Plane Zone: Units: usfl - r State Plane Zone: ,�� Units: usft i C` Legal Description (NAD27 only) C Legal Description (NAD27 only) Starting Coordinates:----- ---- ---------- Ending Coordinates:---------- --- --- X: 11612806 X: 472772.630340161 Y: 15937157 Y: 15937407.3839219 Transform Quit Help I 21V1-39wp17 Surface Location I M CPAI Coordinate Converter i From --.. - Datum: NAD83 Region: alaska t' Latitude/Longitude IDecimalDegrees r UTM Zone: I— F South Y.' State Plane Zone: Units: us fl . �"' Legal Gas._�iphon IPlFi,D c7 onlyl '. ❑ X To: Datum:NAD27 Region: alaska I- Latitude/Longitude IDecimaiDegrees t" UTM Zone: True r South (' State Plane Zone: F-----] Units: us -fl C. Legal Description (NAD27 onlyj Starting Coordinates: Legal Description -- X: 1628002.70 Township: Foil- 1"J Range: 008 Y: 5946735.34 Meridian: I" J Section:27 FNL _ '.5166.6026 FEL 5150.4794 2M-39wp17 Surface Casing M CPAI Coordinate Converter -Fran:.._-_--_-__. Datum: NAD83 . Region: alaska C Latitude/Longitude IDecimaiDegrees 71 r UTM Zone: 1 — r South F State Plane Zone: Units: us -Ft ( Legal D e..,ription;N AL127 cnyj r Starting Coordinates: I x: 1627195.05 5948974.82 - - TiansForm Quit Help — ❑ X To: Datum: NA027� Region: falaska C Latitude/Longitude IDecimalDegrees r UTM Zone: True r- South (" State Plane Zone: I' ---J Units: us -Fl C Legal Description (NAD27 only) Legal Description-- --- --------- Township: 011 FN—, -1 Range:008 [E7, Meridian: U . 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Region: alaska t' Latitude/Longitude IDecimalDegrees fUTM Zone: True r South t' State Plane Zone:4 Units: us -ft 17 G Legal Description (NAD27 only] Township: 011 I"J Range: 008 I` J Meridian: Section: 31 FNL - 3004.4656 IFEL 2838.1928 Transform Quit I HeIp Datum: NAD83 Region:alaska . i C' Latitude/Longitude IDecimalDegrees r UTM Zone: 1 — r South G State Plane Zone: F-.-:] Units: us -fl t' L.aaI DF.:r_npti_rt jplA.D2'ailvj - Starting Coordinates: --- X:- 1612806 Y: 5937157 - ❑ X Datum: INAD27 Region: jalaska C Latitude/Longitude IDecimal Degrees _ f•UTM Zone:True r South • State Plane Zone: Units: usdt . G Legal Description (NAD27 ony) - Legal Description- Township: oto N . Range: 008 I` J Meridian: IU Section:F FNL 945.54543 FEL 4514.8939 (.................Transform_.....,,....71 Quit Help Tollerable Collision Risk Worksheet 'aNoi"1 ms in nrady/Philip Hayden -- RISK Location: Anchorage Today's Date: 12"/2018 INHERENT RIM RESIDUAL RISK ASSESSMENT Risk: Dasner: Chief En ineer MATRI.Y MGY9E— sono —pXOIFApai19_ IRaapRol lGusEl Wnsoo vy nos MMEHOEDMIIW'RTpla adv 3 pE pEyypryElalE pu Wle [MMENIS ApNs amain rai.ra.mrrerx mrlame..rermrc w mmwe�ywagxmwn sorra uwxa emuua.nnrn Webipyonamanmxl F'�m nIERl�rbrmnwlryrul �+nM1Poulro vpwrvgamu�bmeercmer..N ae gh.�.eunaue Yn: Viptlnmoupmaanl 13-VI'OY4a/B'urt intMmLnBn3aMtl�llpm'mp mulrKinne¢meM m Mrm p6nrrc0-3Ma9Ma be yuxrrawN bair:wl esn a+ererm YlmllnmeroT maw xerM3MAn'� PnlYlirp rFea�rBbq„euoe eanrern Sw. mw/ mngerm .mewrtarem reapm x rlualHrenvwvni9vei waleen naawxs[I.q.aaemnnn Mveare aanprmrtrn mrcaerpmeaaw Pn gxwk somaoamMmxemntr I, [^a'gaee as.vrc/Broig4gwmN bpecu bxropetlm3YwcyIW waYpan. P WlWenwupmuNM abtrep brpampw aryelxaxmeanC'S3Mu As -built EV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 3 8/19/1 LGM JLS AB 37 & 38 Per K16DO05ACS 4 9/25/1 LGM JLS Revised Per K180005ACS ASP GRID F z 1 15 14 13 2A 26 • 25 • 24 • 23 38423 21 22 4—COR R 4 22 • 21 • PROJECT LOCATION 20 • 19 0 28 25 27 26 18 2H 34 X ZM 17• 33 • / 16• VICINITY MAP 31 • 14 • 1"= 1 MILE 13 • BASIS 1. OF LOCATION AND ELEVATION IS D52M MONUMENTATION PER*LOUNSBURY & ASSOC. DS2M 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 12 • 3. ELEVATIONS ARE B.P.M.S.L. 11 • • 30 9 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 27 & 28, TOWNSHIP 11 NORTH, *9 RANGE 8 EAST, UMIAT MERIDIAN, ALASKA 899A 7 SA 5. DATES OF MOST RECENT SURVEY: 9/23/2018 6 • BK: L18-36 PG: 18-22. 44; 5 6. ALL DISTANCES SHOWN ARE GROUND 2 6A ALEGEdQ 1 SA 27 34 27 ®AS—BUILT CONDUCTOR LOCATION EXISTING CONDUCTOR LOCATION 36 •• 28 33 3• XPLUGGED & ABANDON CONDUCTOR LOCATION 29 • 30 2A GRAPHIC SCALE o so Too 200 32, 37:99 ' 1 inch = 100 ft. LOUNSBURY 1A& PMOCIAT6s, INC. SEE SHEET 2, 3 & 4 FOR LOCATION INFORMATION s4a r°"" '"°°""° ° ""� AREA: 2M MODULE: XXXX UNIT: D2 ConocoPhillipsDS2M WELL CONDUCTOR Alaska, Inc. ASBUILT LOCATION CADD FILE N0. DRAWING N0. PART: REV: LK6213D29 1/13/07 CEA—D2MX-6213D29 1 OF 4 1 4 3 I8/19/1gLGM I JLS I IAB 37 & 38 Per K160005ACS 14 I9/24/18ILGM I JLS I IRevised Per K180005ACS] CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 27, T. 10 N., R. 8 E., UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27Section Geographic Coordinates Offset Elev. Y X Lot. Long. F.S.L. I F.W.L. O.G. I PAD 21 1 5,948,985.88 488,319.18 N 70' 16' 18.585" W 150' 05' 40.098" 114' 479' 99.7' 105.3' 22 5,948,985.77 488,344.40 N 70' 16' 18.585" W 150' 05' 39.364" 114' 504' 99.7' 105.0' *23 5,948,985.83 488,368.91 N 70' 16' 18.586" W 150' 05' 38.650" 114' 529' 99.6' 104.9' 24 5,948,985.75 488,394.29 N 70' 16' 18.585" W 150' 05' 37.911" 114' 554' 99.5' 104.9' 25 5,948,985.79 488,419.22 N 70' 16' 18.586" W 150' 05' 37.186" 114' 579' 99.4' 104.9' 26 5,948,985.92 488,434.76 N 70' 16' 18.588" W 150' 05' 36.733" 115' 594' 99.4' 104.9' 27 5,948,985.97 487,844.42 N 70' 16' 18.579" W 150' 05' 53.921" 114' 4' 100.9' 105.5' 31 5,948,985.64 488,156.27 N 70' 16' 18.581" W 150' 05' 44.841" 114' 316' 100.2' 104.7' 33 5,948,985.93 488,206.85 N 70' 16' 18.584" W 150' 05' 43.369" 114' 367' 100.0' 104.7' 34 5,948,985.32 488,232.32 N 70' 16' 18.579" W 150' 05' 42.627" 114' 392' 99.9' 104.6' 35 5,948,986.23 488,256.36 N 70' 16' 18.588" W 150' 05' 41.928" 115' 416' 99.9' 104.7' 38 5,948,986.00 488,364.41 N 70' 16' 18.591" W 150' 05' 38.781" 115' 524' 101.0' 101.3' *39 5,948,985.25 487,969.82 N 70' 16' 18.574" W 150' 05' 50.270" 113' 129' 100.7' 100.7' 5,948,985.28 487,899.20 N 70' 16' 18.573" W 150' 05' 52.326" 113' 59' 100.8' 100.7' [40 41 5,948,985.35 488,281.25 N 70' 16' 18.580" W 150' 05' 41.203" 114' 441' 99.9' 100.5' * CONDUCTOR ASBUILT THIS SURVEY ** PLUGGED AND ABANDONED WELLS A'I') 1 LOUNSBURY e AssoCUT6s, INC. S- TORS MGIMM PL NRRS AREA: 2M MODULE: XXXX UNIT: D2 GwocoPhilli pS DS2M Alaska, WELL CONDUCTOR ASBUILT LOCATION CADD FILE NO. DRAWING N0. LK6213D29 1/13/07 _ CEA-D2MX-6213D29 1 PART.3 OF 4 1 ��` 4 Appendix ■ Tier 1: Standard • Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation • Drilling within 30' of horizontal inclination AND drilling within 30°of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering • Driller's Target of 50' Radius or Less • Lease line constraint • Small Geologic Target • Failure of Major Risk Rule (Close Approach) • Defined during directional planning, based on the positional uncertainty • Theoretical intersection of the path of the well being planned with an offset well • If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges 6'0^1'�'�t=.'? ConomPhillips ■ Tier 1 (Standard): Directional interval across which no special mitigations are needed ■ Tier 2 (Challenging Orientation): • Increase non-magnetic insulation of MWD tool in the BHA • Take rotational check shots and/or increase survey frequency at the start of a BHA run • Alter well directional plan, if feasible • Consider gyro surveys where feasible ■ Tier 3 (Critical Steering): • Increase survey frequency across critical interval • Increase correction frequency across critical interval • Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run • Define escalation based on deviation from plan • Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations Tier 4 (Critical Steering & Challenging Orientation): • Consider all Tier 2 & 3 mitigations � ?ei'•�i �st��_,. ConocoPhillias Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Tuesday, May 28, 2019 7:45 AM To: Lehman, Nick R Subject: RE: KRU 2M-39 (PTD# 218-171) Verbal Approval to Kickoff Nick, Received the PTD. Thank you. Please prepare a new 10-401 form with the revised information in red and with an approval signature. In the upper right hand corner write "REVISED" in red. Also, please send over the new directional survey. Please hand deliver these at your earliest convenience. Thanx, Victoria -----Original Message ----- From: Loepp, Victoria T (CED) Sent: Tuesday, May 28, 2019 7:37 AM To: Lehman, Nick R <Nick. R. Lehman @conocophillips.com> Subject: KRU 2M-39 (PTD# 218-171) Verbal Approval to Kickoff Nick, Approval is granted to proceed as outlined in the PTD submitted to the AOGCC this morning. 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@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793- 1247 or Victoria.Loepp@alaska.gov -----Original Message ----- From: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sent: Monday, May 27, 2019 5:59 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Re: [EXTERNAL]Re: 2M-39 (PTD# 218-171) Plan Forward - Cut/Pull/Sidetrack Ok I will give you a call at 7am. Thanks, Nick > On May 27, 2019, at 2:28 PM, Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> wrote: > Contact me with status tomorrow morning at —7 AM and request verbal approval. > Tha nx, > Victoria > Sent from my iPhone >> On May 27, 2019, at 8:29 AM, Lehman, Nick R <Nick.R.Lehman@conocophillips.com> wrote: >> Good morning Victoria, >> Please see attached the revised 2M-39 PTD for Re -drill of the Intermediate 1 section as well as the original PTD that was approved. You requested that I red -line the existing permit and re -submit— please note this is my first time doing this specific type of revision so please let me know if you need any other information. As previously mentioned, the reservoir targets and bottomhole location of the well have not changed from the original plan — the depths had to be increased slightly to accommodate for the sidetrack and separation from the original wellbore. Also, please note that, due to the anti -collision error ellipse with the plugged back wellbore as we get deeper in the new intermediate 1 section, we minor -risked the 2M-39PB1 wellbore and will take surveys as needed to ensure we maintain necessary separation. >> Currently, we have finished spotting our cement kickoff plug and are testing BOPE. We are expecting to be ready to tag the kickoff plug tomorrow, Tuesday morning 5/28/19 at 08:00 hrs. Please let me know if we have verbal approval to move forward with sidetracking below the surface casing to start drilling the new INTRM1 section on 2M-39. Since today is a holiday and everyone is out of the office, I will hand -carry over the revised PTD first thing in the morning to your office. >> Regards, >> Nick Lehman >> Drilling Engineer I ConocoPhillips Alaska Office (907)263-49511 Cell >>(832)499-6739 >> Nick.R.Lehman@ConocoPhillips.com<mailto:Nick.R.Lehman@ConocoPhillips. >> com> >> From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> >> Sent: Thursday, May 23, 2019 6:51 PM >> To: Lehman, Nick R <Nick.R.Lehman@conocophill ips.com> >> Subject: [EXTERNAL]Re: 2M-39 (PTD# 218-171) Plan Forward - >> Cut/Pull/Sidetrack >> Nick, >> Approval is granted for the plan forward outlined below. Please submit a 10-403 Sundry for setting the bridge plug and the cut and pull. Follow with a revised PTD for the sidetrack. >> Thanx, >> Victoria >> Sent from my iPhone >> On May 23, 2019, at 6:24 PM, Lehman, Nick R <Nick.R.Lehman@conocophillips.com<mailto:Nick.R.Lehman@conocophillips.com>> wrote: >> Victoria, >> Following up on our discussion this afternoon regarding 2M-39 (PTD# 218-171), here is our proposed plan forward. When possible, would you please confirm approval of this plan? >> Previous Operations >> * We ran our 9-5/8", 47lb/ft Intermediate 1 casing to bottom and cemented in place in the HRZ shale at 15,785' MD / 5,798' TVD / 75.9 - >>* 5.9°>>* The cement job was pumped with no returns to surface, we did not bump the plug, and the floats did not hold. We did see over 500psi of lift pressure. >> * We ran in hole with the 8-1/2" x 9-7/8" Intermediate 2 drilling assembly and tagged up on the top cement plug at 13,808' MD. The top of the float collar was set at 15,696' MD, so we tagged 1888' higher than planned >>* We drilled through the plug @ 13,808' and ^'2' of cement and then stopped at 13,812' to test our casing —we were unable to get a pressure test on it and observed leak -off. >>* We continued to drill cement and started observing losses while circulating. In total, we drilled through 52' of hard cement to 13,860'. >>* From 13,860' MD to the float collar at 15,696' MD, we did not observe any cement inside the 9-5/8" casing. >> Abandonment & Sidetrack Plan Forward >> * Finish pulling OOH and lay down drilling BHA, expect to be finished at 03:00 hrs 5/24/19 >> * RIH with a cast-iron bridge plug and set inside the 9-5/8" casing —300' below the surface casing shoe (surface shoe at 2860' MD / 2646' TVD) >> * As previously mentioned, there are no hydrocarbon zones open in the Intermediate 1 hole section that we drilled. >> * Pressure test to 2500 psi >> * Cut 9-5/8" casing above bridge plug and lay down casing. >> * Pump a kickoff cement plug from the cast-iron bridge plug to 200' inside surface casing shoe. >> * I will submit an abandonment sundry in the morning with schematics detailing the plan. >> * Perform a sidetrack below surface casing shoe and re -drill 12-1/4" Intermediate 1 hole section >> * We will shift the wellplan to get sufficient separation from the existing wellbore and then parallel it to TD. >> * We will make up what we can with returning to original wellplan trajectory on the intermediate 2 section. The remaining portion will be made up on the start of the production section and we will drill the lateral on the same trajectory as proposed in the original 2M-39 PTD with the same planned TD and bottomhole location >> * Once I have final modified wellplan, I will add changes in red to the original 2M-39 PTD and send for your approval. >> Thanks for your time and help, >> Nick Lehman >> Drilling Engineer I ConocoPhillips Alaska Office (907)263-49511 Cell >>(832)499-6739 >> Nick.R.Lehman@ConocoPhillips.com<mailto:Nick.R.Lehman@ConocoPhillips. >> com> >> <2M-39 Revised PTD #218-171 For Re-Drill.pdf> >> <2M-39 APPROVED 10-401 PTD NEW WELL Application.pdf> Loepp, Victoria T (CED) From: Sent: To: Subject: Follow Up Flag: Flag Status: Ok I will give you a call at lam. Thanks, Nick Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Monday, May 27, 2019 5:59 PM Loepp, Victoria T (CED) Re: [EXTERNAL]Re: 2M-39 (PTD# 218-171) Plan Forward - Cut/Pull/Sidetrack Follow up Completed > On May 27, 2019, at 2:28 PM, Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> wrote: > Contact me with status tomorrow morning at -7 AM and request verbal approval. > Thanx, > Victoria > Sent from my iPhone >> On May 27, 2019, at 8:29 AM, Lehman, Nick R <Nick.R.Lehman@conocophillips.com> wrote: >> Good morning Victoria, >> Please see attached the revised 2M-39 PTD for Re -drill of the Intermediate 1 section as well as the original PTD that was approved. You requested that I red -line the existing permit and re -submit - please note this is my first time doing this specific type of revision so please let me know if you need any other information. As previously mentioned, the reservoir targets and bottomhole location of the well have not changed from the original plan - the depths had to be increased slightly to accommodate for the sidetrack and separation from the original wellbore. Also, please note that, due to the anti -collision error ellipse with the plugged back wellbore as we get deeper in the new intermediate 1 section, we minor -risked the 2M-39PB1 wellbore and will take surveys as needed to ensure we maintain necessary separation. >> Currently, we have finished spotting our cement kickoff plug and are testing BOPE. We are expecting to be ready to tag the kickoff plug tomorrow, Tuesday morning 5/28/19 at 08:00 hrs. Please let me know if we have verbal approval to move forward with sidetracking below the surface casing to start drilling the new INTRMI section on 2M-39. Since today is a holiday and everyone is out of the office, I will hand -carry over the revised PTD first thing in the morning to your office. >> Regards, >> Nick Lehman >> Drilling Engineer ( ConocoPhillips Alaska Office (907)263-49511 Cell >>(832)499-6739 >> Nick. R.Lehman@Conoco Phil Iips.com<mailto:Nick. R.Lehman @ConocoPhillips. >> com> >> From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> >> Sent: Thursday, May 23, 2019 6:51 PM >> To: Lehman, Nick R <Nick.R.Lehman @conocophillips.com> >> Subject: [EXTERNAL]Re: 2M-39 (PTD# 218-171) Plan Forward - >> Cut/Pull/Sidetrack >> Nick, >> Approval is granted for the plan forward outlined below. Please submit a 10-403 Sundry for setting the bridge plug and the cut and pull. Follow with a revised PTD for the sidetrack. >> Thanx, >> Victoria >> Sent from my iPhone >> On May 23, 2019, at 6:24 PM, Lehman, Nick R < Nick. R. Lehman @co nocophillips.com<mailto:Nick. R. Leh man@conocophillips.com>> wrote: >> Victoria, >> Following up on our discussion this afternoon regarding 2M-39 (PTD# 218-171), here is our proposed plan forward. When possible, would you please confirm approval of this plan? >> Previous Operations >>* We ran our 9-5/8", 471b/ft Intermediate 1 casing to bottom and cemented in place in the HRZ shale at 15,785' MD / 5,798' TVD / 75.9 - >>* 5.9°>>* The cement job was pumped with no returns to surface, we did not bump the plug, and the floats did not hold. We did see over 500psi of lift pressure. >> * We ran in hole with the 8-1/2" x 9-7/8" Intermediate 2 drilling assembly and tagged up on the top cement plug at 13,808' MD. The top of the float collar was set at 15,696' MD, so we tagged 1888' higher than planned >>* We drilled through the plug @ 13,808' and ^2' of cement and then stopped at 13,812' to test our casing —we were unable to get a pressure test on it and observed leak -off. >> * We continued to drill cement and started observing losses while circulating. In total, we drilled through 52' of hard cement to 13,860'. >>* From 13,860' MD to the float collar at 15,696' MD, we did not observe any cement inside the 9-5/8" casing. >> Abandonment & Sidetrack Plan Forward >> * Finish pulling OOH and lay down drilling BHA, expect to be finished at 03:00 hrs 5/24/19 >>* RIH with a cast-iron bridge plug and set inside the 9-5/8" casing —300' below the surface casing shoe (surface shoe at 2860' MD / 2646' TVD) >> * As previously mentioned, there are no hydrocarbon zones open in the Intermediate 1 hole section that we drilled. >> * Pressure test to 2500 psi >> * Cut 9-5/8" casing above bridge plug and lay down casing. >>* Pump a kickoff cement plug from the cast-iron bridge plug to 200' inside surface casing shoe. >> * I will submit an abandonment sundry in the morning with schematics detailing the plan. >>* Perform a sidetrack below surface casing shoe and re -drill 12-1/4" Intermediate 1 hole section >>* We will shift the wellplan to get sufficient separation from the existing wellbore and then parallel it to TD. >> * We will make up what we can with returning to original wellplan trajectory on the intermediate 2 section. The remaining portion will be made up on the start of the production section and we will drill the lateral on the same trajectory as proposed in the original 21VI-39 PTD with the same planned TO and bottomhole location >> * Once I have final modified wellplan, I will add changes in red to the original 2M-39 PTD and send for your approval. >> Thanks for your time and help, >> Nick Lehman >> Drilling Engineer I ConocoPhillips Alaska Office (907)263-49511 Cell >> (832)499-6739 >> Nick.R.Lehman@ConocoPhillips.com<mailto:Nick.R.Lehman@ConocoPhillips. >> com> >> <21VI-39 Revised PTD #218-171 For Re-Drill.pdf> >> <2M-39 APPROVED 10-401 PTD NEW WELL Application.pdf> R E V.r SFb TRANSMITTAL LETTER CHECKLIST WELL NAME: k R U, a M -�. C P, e- V 1 5 4) PTD: 9- [ S - 1 7� 1 Development V/ Service —Exploratory Stratigraphic Test —Non -Conventional FIELD: Kupa&uk X 1 VP -k' POOL: Ku n dV u K R IV2V- Q i 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' sam le 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 Engineering ineerin Public Revision: Abd intermediate 1 section, sidetrack well to same UHL v i L Commissioner: Commissioner: Geologic Date: Date Commissioner Date J -/c 6-1AgM E1 Field &Pool KUPARUK RIVER, KUPARUK RIV OIL -490100 — Well Name: KUPARUK RIV NIT 2M-39 Program SER Well bore seg ao Unit 111so On/off Shore On Annular Dispc WELL PERMIT CHECKLIST PTD#:2181710 Company C NQ OCOPL-IILLASKA, INC. Initial Class/type $ER I PEND GeoArea — Administration '1 Permit fee attached _ _ _ - - - - NA - Yes- - - - - - - _ - - 2 Lease number appropriate .--... 3 Unique well. name and number - - _ _ - -- Yes - 4 _ ___ __ Well located in a defined pool - - - .. - � - - - � - - - - � - - Yes _ _______ ............... - - - - 5 Well located proper distance fromdrilling unit. boundary _ _ _ _ _ Yes - - - - - - - - - - - - - - - - - - - - - - 6 Well located proper distance from other walls. _ - - - . - - - - - - - - � � --- Yes 7 Sufficient acreage available in drilling unit. _ - - - - - - - - - - - - - - - - Yes No. - - - - - - - - - - - - - - - - - - - - - Spider map shows wellpath- - - - - - - - - - - - - - - - - 8 If deviated, is. wellbore plat included - - - - - - _ 9 Operator only affected Party...... Yes _ . . . . . .. . . ..... - 10 Operator has appropriate bond in force _ - - _ _ Yes Yes - - - - - - - - - - - - - - - - - - - - - - - - - - Kuparuk River Oil Pool, govemed by Conservation Order No. 432D 11 Permit can be issued without conservation order .. _ _ _ _ - _ - - - . 12 Permit can be issued without administrative. approval _ _ - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - Appr Date DLB 5/28/2019 13 Can permit be approved before 15 -day wait _ - - - - - - - � - - - - authorized by Injection Order # (put 10# in comments) (For Yes Yes - - _ Area Injection Order No. -2C --Kuparuk River Unit - 14 15 Well located within area and strata All wells within 114.mile area of review identified (For service wait only) _ _ Yes - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA _ - - - Well will not be pre -produced -par Cop. - - 17 Nonconven, gas conforms to ASa1,05 030(j1.A),Q,2.A-D) _ _ _ _ _ NA - - - - - - - - - - - - - - - - - - - - - - - - - Yes 80' conductor installed. - 18 Conductor stringprovided_ _ _ _ - _ _ _ Yes - - - Surface shoe set at 2861' MD - Engineering 19 Surface casing_ protects all known USDWS _ _ _ - _ - _ Yes _ 177°%_excess cement planned 20 CMT_vot adequate. to circulate on conductor& surf csg - _ _ - - _ - - 21 CMT. vol adequate. to tie-in long string to surf csg. _ _ _ _ - - _ _ _ No No.. Productive_ interval will be completed withuncementedpreperforated liner with swell packers 22 CMT.will cover all known productive horizons. _ _ _ _ _ - .. - - _ _ _ _ 23 Casing designs adequate for C, T, B & permafrost_ _ _ ... Yes Yes Rig has steel tanks; all. waste. to approved disposal wells. 24 Adequate tankage_or reserve pit _ - - .. - - - - - - - � � - - - - � - - - � - - - _ - - _ 25 If a. re -drill, has.a 10-403 for abandonment been approved . _ - - - - - - - NA Yes Anti -collision analysis complete; no major risk failures - - - - - - - 26 Adequate wellbore separation proposed- - - - - - -- - - - - - - - - - - - - - - Yes - 16" diverter meets regulation as doesthe- route. 27 If diverter required, does it meet regulations _ .. _ _ _ _ _ _ Yes .. - - Max formation pressure is 3316 psig(10.5 ppg EMW ); will drill w/ 8.8-12,2. ppg EMW 28 _.. Drilling Fluid. program schematic & equip list adequate _ _ . _ _ - _ ---- �-- Appr Date VTL 5/29/2019 29 BOPEs, do they meet regulation _ .. - - - - - - _ - - - - - - - - - - Yes ..-.. Yes -_..-�---�--- -- -- ---- - -- MPSP is 2709 prig; will test BOPS to 35Q0-Psig 30 BOPE press rating appropriate: fast to(putprig in comments)- - - - - - - - � - - � � � - - 31 Choke. manifold complies w/API. RP -53 (May 64)- - - - - - -- - - - - - - - - Yes No Op SD will occur to -allow Doyon 142 to assist with exploration operations during ics road season 32 Work will occur without operation shutdown.. _ _ _ _ - _ Yes _ H2S measures required - 33 Is presence of H2$ gas -probable - - _ _ _ - - - . - - - - - - - of wells within AOR verified (For service wall only) _ ... - _ .. - - - _ _ - Yes - - - - - _ .. - No other wells within the. 114 mile AOR 34 Mechanical condition No Wells 2M -Pad are KS -bearing. H2S measures required. . 35 Permit can be issued w/o hydrogen. sulfide measures - - - - . - _ .. - - . - - - - - - - - - - -on Geology 36 Data presented on potential overpressure zones - - - Yes Appr Date 37 Seismic analysis of shallow gas zones_ _ - - .. - _ _ .. - _ _.-_-_ _-_ -. NA NA ... ...... ............ __ DLB 5/28/2019 38 Seabed condition survey (if off -shore) _ . - - .. - - - - - - - - - -- ._ NA - - - - ---- 39 ContaGtname/Dhone for weekty.P-rogress reports [exploratory only] - _ - . - - -_---, Engineering ineerin Public Revision: Abd intermediate 1 section, sidetrack well to same UHL v i L Commissioner: Commissioner: Geologic Date: Date Commissioner Date J -/c 6-1AgM E1 Loepp, Victoria T (DOA) From: Sent: To: Subject: Follow Up Flag: Flag Status: Thanks, will do. Nick Lehman Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Friday, March 22, 2019 9:46 AM Loepp, Victoria T (DOA) KRU 2M-39(PTD 218-171) Rig Change to Doyon 19 Follow up Flagged Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R.Lehmc7n@ConocoPhillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, March 22, 2019 9:39 AM To: Lehman, Nick R <Nick. R. Leh man @conocophillips.com> Subject: [EXTERNAL]KRU 2M-39(PTD 218-171) Rig Change to Doyon 19 Nick, Approval is granted for the rig change to Doyon 19. Please include this approval with the approved PTD. 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. Loeoo(a)alaska. gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepo 4_alaska.clov From: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Sent: Friday, March 22, 2019 7:41 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 2M-39(PTD 218-171) Cement Logs Good morning Victoria, I have received confirmation that Doyon 19 will be coming to Kuparuk and drilling LtA-39 (PTD# 218-171) with an estimated spud date of April 28, 2019. As previously discussed, 21V-39 was originally permitted to be drilled with Doyon 142. Please let me know if you need any other information relating to the rig swap. Thanks, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehman@ConocoPhillips.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, March 5, 2019 7:15 AM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: FW: [EXTERNAL]KRU 2M-39(PTD 218-171) Cement Logs Nick, For the rig change send a complete email request and the approval can be handled with email. Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Monday, March 4, 2019 3:46 PM To: Lehman, Nick R <Nick. R. Leh man@conocophillips.com> Subject: Re: [EXTERNAL]KRU 2M-39(PTD 218-171) Cement Logs I will call you tomorrow AM. Sent from my iPhone On Mar 4, 2019, at 9:51 AM, Lehman, Nick R <Nick.R.Lehman@conocophillips.com> wrote: Victoria, When convenient, would you please give me a call at 907-263-4951 to discuss the cement evaluation of intermediate 1 casing on 2M-39 PTD #218-171? Also, due to rig schedule changes, the current plan is to drill 21V-39 with a rig other than Doyon 142 with expected spud in late April 2019. Once we are certain on the rig (most likely Doyon 19), will a new PTD submission be required to accommodate the rig change or can we obtain approval of the change via email? Thanks for your time, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick.R.Lehman@ConocoPhillips.com From: Loepp, Victoria T (DOA) <yictoria.loepp@alaska.gov> Sent: Tuesday, January 8, 2019 1:39 PM To: Lehman, Nick R <Nick.R.Leh man@conocophillips.com> Subject: [EXTERNAL]KRU 2M-39(PTD 218-171) Cement Logs Nick, The PTD is approved and ready for pick up. I will get back to you on the cement evaluation log for the 9- 5/8". It is currently required as a part of the approved PTD. 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. LoeopCa.alaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907) 793- 1247 or Victoria Loepp@alaska.aov From: Lehman, Nick R<Nick. R. Lehman@conocophillips.com> Sent: Tuesday, January 8, 2019 1:33 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Subject: RE: [EXTERNAL]RE: KRU 2M-39(PTD 218-171) Cement, Anti -collision and Op SD Victoria, The Intermediate 117" casing will be the main isolation between the overburden and the reservoir. I was planning on running Sonic tool on the 6-1/8" production BHA to evaluate the cement behind the Intermediate II casing. o Line #23 of the Proposed Drilling program in the PTD request should have included "Sonic" in the 6-1/8" BHA assembly. I realize I failed to include it originally - my apologies. The Intermediate 19-5/8" casing will be run to help minimize drilling issues on this well. For the 9-5/8" Intermediate I casing, I was planning on evaluating cement based on the 9-5/8" cementing operations and a successful FIT at the shoe once we drillout. Regards, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)163-4951 1 Cell (832)499-6739 Nick. R. Lehman@COnocoPhilhDs. com From: Loepp, Victoria T (DOA) <yictoria.loepp@alaska.eov> Sent: Tuesday, January 8, 2019 9:51 AM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2M-39(PTD 218-171) Cement, Anti -collision and Op SD Nick, I don't see a cement evaluation log for the Intermediate 1 and 2. What are your plans? 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. Loeppc5a laska. 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 Victorio.Loeoo@alaska.aov From: Loepp, Victoria T (DOA) Sent: Tuesday, January 8, 2019 9:30 AM To:'Lehman, Nick R' <Nick.R.Lehman@conocophillips.com> Subject: KRU 2M-39(PTD 218-171) Cement, Anti -collision and Op SD Nick, Thank you for the information. Please submit a diverter equipment schematic with each PTD although this information is on file with the AOGCC. The schematic you submitted was what I would like to see. 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. Loeppoa laska.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 Victoda.Loeoo@alaska.aov From: Lehman, Nick R<Nick. R. Lehman@conocophillips.com> Sent: Sunday, January 6, 2019 8:12 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Cc: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2M-39(PTD 218-171) Cement and Anti -collision Victoria, Thank you for your email. I apologize for any confusion and I appreciate your patience. - I corrected the schematic and attached above to reflect TOC @ 250' TVD above the 9-5/8" Intermediate 1 shoe. Attached above is the equipment schematic for the diverter on Doyon 142 as well as the rig-on- diverter layout map (page 12 of PTD application request). o I was working under the belief that the diverter equipment information for D142 was already on file with AOGC - please let me know if the D142 diverter equipment schematic needs to be submitted with every PTD request moving forward. Attached above is a modified cover letter to include temporary suspension of 21V-39 allowing for Doyon 142 to assist with exploration drilling out on the ice. o Currently, I am estimating we will be able to drill, case, and cement the surface section before exploration needs Doyon 142. However, please note that it is a moving target right now since exploration needs the rig in a specific timeframe and 2M-41 completion date could push back if any unexpected issues are encountered. 2M-09 / 2M -09A is a Kuparuk injector that has been permanently plugged/abandoned, cut-off below ground level, and backfilled as of July 17, 2018. This well has been minor -risked and we will be utilizing gyro -while -drilling to take surveys as needed to ensure we drill to plan. Please let me know if you have any questions or need any other information. Regards, Nick Lehman Drilling Engineer I ConocoPhillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman @ConocoPhillips. com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Sent: Thursday, January 3, 2019 9:47 AM To: Lehman, Nick R <Nick. R. Lehman@conocophillips.com> Cc: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2M-39(PTD 218-171) Cement and Anti -collision I now notice that the well class is listed as both a service well and development well. I will delete the development well class. The cement calculations should be based on 250' TVD above the shoe in the intermediate. Please correct the schematic. Please provide a diverter equipment diagram with sizing. I understand that there will be an Operations Shutdown of drilling operations after the surface hole. This should be included in the PTD in the cover letter outlining the current plans and how the well will be left. Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Wednesday, January 2, 2019 11:11 AM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: KRU 2M-39(PTD 218-171) Cement and Anti -collision Nick, Please review the cementing calculations for the Intermediate #1: The shoe is at 15722' MD or 5800' TVD; cement is to be 500' TVD above shoe or 5300' TVD; 5300' TVD corresponds to 13600' MD I notice the cement calculations show cement 250' TVD above shoe while the schematic has 500' TVD above shoe. Also, the schematic is labeled as an injector. Please correct as needed. Also, please explain what mitigation measures will be in place for the failed major risk with 2M-09/ 2M - 09A. Will 2M-09 be shut in with a deep plug? 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(Caalaska.go CONFIDENTIALRY 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 LoeoUl�4k ska,cgov i THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2M-39 ConocoPhillips Alaska, Inc. Permit to Drill Number: 218-171 Alaska Oil and Gas Conservation Commission Surface Location: 5167' FNL, 5150' FEL, SEC. 27, TI IN, R8E, UM Bottomhole Location: 946' FNL, 4515' FEL, SEC. 7, TI ON, R8E, UM Dear Mr. Alvord: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced development 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, Hollis S. French Chair �l DATED this day of January, 2019. STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL a. Type of Work: 11b. Proposed Well Class: Exploratory -Gas trill 10 Lateral ElStratigraphic Test ElDevelopment - Oil ill❑ i.x Reentry❑ ExnImstnry-Oil ❑ Develooment-Ga Inc. Box 100360, Anchorage, AK 99510-0360 Location of Well (Governmental Section): ace: 5167' FNL & 5150' FEL, Sec 27, T11 N, RBE, UM of Productive Hodzon: 3104' FNL & 2688' FEL, Sec 31, T1114, RBE, UM I Depth: 946' FNL & 4515' FEL, Sec 7, T10N, RBE, UM x-487970 y- 5948985.25 Zone- 4 ad wells: Kickoff depth: 300 feet Maximum Hole Angle: 95.66 degrees WAG W Service -Disp ❑ Winj ❑ Single Zone ❑ Bupply ❑ Multiple Zone ❑ Blanket p Single Well ❑ Sq -57-i RD MD: 25,636' TVD: 6,169- 7- Property Designation: . ADL025586 / ADL025585 / ADL025590 8. DNR Approval Number: 931894000/931893000/931898000 9. Acres in Property: 2560 / 2491 / 2501 10. KB Elevation above MSL (ft): 139.7 GL / BE Elevation above MSL (ft): 100.7 17. Maximum Potential Pressures in psig (see 20 Downhole: 3316 ' Surface: "CFEEIVE DEC 17 2018 1 c. Specify if well is fob Coalbed Gas Elr �rl� 4 C Geothermal 11 Shale Gas �� 11. Well Name and Number: KRU 21039 12. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 13. Approximate Sud Date: 1/17/201 �L 14. Distance to Nearest Property: 526to ADL390680 15. Distance to Nearest Well Open to Same Pool: 1568' to 2M-38 25.035) 2709 - 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 Sud Sud fie 119 Installed 16" 13-3/8" 68# L-80 Hyd 563 2822 Sud Sud 2861 • 2640 1546 sx 11 ppg lead, 232 sx 12ppg tail 12-1/4" 9-5/8" 47# L-80 Hyd 563 15683 Sud Sud 15722 5800 400 sx 15.8 ppg Class G 3-1/2" x 9-7/8 7" 21 L-80 Hyd 563 1517 15522 5751 17039 6073 428 sx 15.8 ppg Class G 6-1/8" 4-1/2" 12.6# L-80 Hyd 563 8797 16839 6035 25636 6169 N/A: Un -cemented Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (#): Total Depth TVD (h): Plugs (measured): Effect. Depth MD (11i Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (0): N/A Perforation Depth TVD (ft): WA Yes❑ No ID I20. Attachments: Property Plat ❑ BOP Sketch Q Drilling Program El Time v. Depth Plot ❑ Shallow Hazard Analysieo Diverter Sketch O Seabed Report ❑ Drilling Fluid Program O 20 AAC 25.050 requirement 21. Verbal Approval: Commission Representative: Date from without prior written approval. I IN... Chip Alvord Date: Contact Contact Contact I rermn To unit p Hrl rvumoef. rermn ApprovalI%q See cover laner ror Omer Number: a. 18' I I 50- Q 3 �'d,Q �. —p Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce ce Ibed meth ne, gas hydrates, or gas contained in shales: Qi Other: 6JO le -5 y- f0 35-00 P - ,�}Saa9mrrplleeassreq'd: Yes❑ Noi Mud log req'd: Yed] NoUK fjv9 ✓t v lez /- �r�r / + tU �ts f fa z 5-000 _ l ures: YesV No❑ Directional svy req'd: YadV Na❑ i-7,rGl Spacing exception req'd: Yes❑ Ni Inclination -only svy req'd: YeED/ Ni bC Sv m , Post initial injection MIT req'd: Yed Ni �r 10 1,2 pperic�f`or25 9hlifdawvl. 16-go,3>o bG Svbm,ylcd fo l CS�ly C opercz7/`o r15 aficr vlhfr;L >7. ✓7'Cw,GZv+7 I ofvlcf�"nt 2 Cewtevt� jabsa�cJ ern" a! X09 �1�J7 W/�IOlaCG (�°Lr^'1rCw+cval log f'C w r avallaJ/C APPROVED BY 1 Approved by: Lam- COMMISSIONER THE COMMISSION Date: ORIGINAL Submit Form and Fwm 10-401 Revised W017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(gg)) Attachments in DupRi a ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 December 17,2018 Commissioner Alaska Oil and Gas Conservation Commission 333 West 7' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, Kuparuk Producer, 2M-39 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for a permit to drill 2M-39, a development grassroots onshore injector with a single lateral horizontal well in the Kuparuk C sand. The expected spud date for this well is January 17th, 2018. It is planned to use rig Doyon 142. A 16" surface hole will be drilled on diverter & 13-3/8" surface casing will be ran to total depth and cemented to surface. The remaining intervals will utilize Doyon 142's 13-5/8" x 5000 psi BOP stack with required ram installations and tested on a 14 -day cycle in accordance with COP and AOGCC policy. The first intermediate hole section will be a 12-1/4" hole with 9-5/8" casing run to total depth & cemented in place. The second intermediate section will be drilled with a 8-1/2" bit and underreamed to 9-7/8" with a 7" liner run to total depth and cemented in place. The 6-1/8" production lateral will be geo-steered in the Kuparuk C sand and lined with 4-1/2" pre -perforated liner. The upper completion will be run with 3-1/2" tubing. Please note that 2M-39 will be temporarily suspended once the ice road opens to allow for Doyon 142 to assist with exploration operations. Operations will be suspended at a casing point and a kill string will be run to freeze protect the well. The exact timing of suspension on 2M-39 will depend on the progress of the previous well, 2M-41. After the exploration season is completed, Doyon 142 will return to 2M-39 and complete the well. 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 10401 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 Me at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser setup. If you have any questions or require further information, please contact Nick Lehman at 263-4951 (nick.r.lehman@conocophillips.coml or Chip Alvord at 265-6120. Sincerely, Nick Lehman Drilling Engineer ConocoMillips Post Office Box 100360 Anchorage, Alaska 99510.0360 December 17, 2018 Commissioner Alaska Oil and Gas Conservation Commission 333 West 7" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for ('¢molt to Drill, Kuparuk Producer, 2M-39 Dear Commissioners: \ / ConocoPhillips Alaska, Inc. her y applies for a permit to drill 2M-39, a Bevel ment grassroots onshor injector with a single lateral horizontal well in [h uparuk C sand. The expected spud Bat or this well is January 17 [ is planned to use rig Doyon 142. A 16" surface hole will be drilled on div er & 13-3/8" surface casi will be run to total depth and cemented to surface. The remaining intervals will utilize Doyon 42's 13-5/8" x 5000 p ' BOP stack with required ram installations and tested on a 14 -day cycle in accordance with COP d AOGCC policy. a first intermediate hole section will be a 12-1/4" hole with - ' casing run to total depth & ceme d in place. second intermediate section will be drilled with a 8-1/2" bit and underreamed to 9-7/8" with a 7" liner to total d th and cemented in place. The 6-1/8" production lateral will be geo-steered in the Kuparuk C sand and Tined ith 4-1/ " pre -perforated liner. The upper completion will be run with 3-1/2" tubing. Please find attached the information required y 0 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this an in es th following: p r 1. Form 10-401 Application for mut to Drill r 20 ACC 25.005 (a). C <� �(V 2. Pressure information as req 'red by 20 ACC 2 035 (d) (2). t' V 3. Casing and Cementing pr am. 4. A drilling fluids progr summary. 5. A proposed drilling pr gram. 6. Directional drilling/ Vision avoidance infomtation a required by 20 ACC 25.050 (b). 7. A proposed comp tion diagram. Informati/,p*ertinentto a application that is presently on file at a AOGCC:1.the BOP equipment, divener equipment and cho manifold lay out as required by 20 5 (a) and (b). 2.on of the drilling fluids handling system. 3.f riser set up. If you hastions or require further information, please contact 'ck Lehman at 263-4951 nick.r.leho hilli s.com or Chip Alvord at 265-6120. l Engineer Application for Permit to Drill Document Kuparuk Well 2M-39 Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as KRU 2M-39 Location Summary Requirements of 20 AAC 25.005(c)(2) An application fora Permit In Drill nam be u, ompam d by each r f the fllmyimg items, except jor an item already ort file with the commission and identified in the application: (2) a phot idemifying the property and the promrsyfs owners and showing (Aahe coordinates of the proposed location of the well at the surface, at dee top ofeach objeetire formation, mal at total depth, referenced to gorrmmental.senimt lines. (N) the coordmates of the proposed location ofdae is ell at the surface, referenced to the soaeplane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceank acrd Aonospherk Administration; (C) the proposed depth of the well at the lop of eaedt objective fonnntion and at total depth; Location at Surface 5167' FNL, 5150' FEL, Sec 27, TI IN, R008E, UM NGS Coordinates Northings: 5948985.25' Eastings: 487969.82' i RKB Elevation139.7' AMSL Pad Elevation 100.7' AMSL Location at Top of Production Interval (Ku aruk C -sand 3104' FNL, 2688' FEL, Sec 31, T I I N, R008E, UM NGS CoordinatesMeasured Northings: 5945801.74' Eastings: 474594.93' De tit, RKB: 17039' Total Vertical Depith, RKB: 6073' Total Vertical D5,21h, SS: 5933' Location at Tota] Depth 946' FNL, 4515' FEL, Sec 07, T I ON, ROI OE, UM NGS coordinates Northings: 5937907.38' Eastings: 472772.63' Measured De tit, RKB: 25636' I Total Vertical De th, RKB: 6169' Total Vertical Depth, SS.' 6029' and (D) other information required by 20 AAC 25050(b)t Reauirements of 20 AAC 25.050(b) if,, well is to be intentionally devoted, lite application, for a Permit it, Drill (Form 10-401) not sl (1) include a plat, drawn to a ,suitable scale, showing the path oflhe proposed wellbore, including all adjacent weUbores within 200feel ofany, pop don of the proposed well; Please see Attachment: Directional Plan And (2) for all welts within 200feel rdete proposed wellbore (A) list the names of the opersuars oftluse welts, ro he event that tlmse names are known arm discoverable in publumcords. and ,show thin each named operator hos been furnished a enty (f the application by certified mail: or (N) state that One applicant is dre onily affected miner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An applicatio n f n a Peril to Drill rnuv be accvmpmtied by each of thre fallowing heow, except for an item all ends au fle wuh the etnmaissiou and identified in the application; (3) it diagram and description of the blon out prevention equipment (NOPE.) as required by 20 AAC 25.035, 20 AAC 25.036, at 20 AAC 25.027, as applicable; Please reference BOP schematics on file for Doyon 142 & within this PTD application. Due to lower formation pressure in the overburden, a fixed stack ram placement will be utilized to fulfill all barrier requirements during well construction operations of the Intermediate I section, graphic attached. Drilling Hazards Information Reauirements of 20 AAC 25.005 (c)(4) An applie'ation fma Permit In lbill roast he accnrnpan al by each ofibe f dlnwing irerns, except.f n' an dent alt'eat(v onf ek, with the cnntmissi'm and identified in the application: (4) mformntlnn nn ddifing hazards, including (A I the masimmn downhole pressure that wav be e uournered, criteria used m deremrine it, and maxims en potential surface pressure bared nn u methane gradient; The maximum potential surface pressure (MPSP) while drilling 2M-39 is calculated using an estimated maximum reservoir pressure of 3316 psi (estimate from reservoir simulator based on offset well injection/pressure data), a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk C sand at 6,073' TVD: ) 041 C Sand Estimated. BHP = 3,316 psi 33 �t4 p� C Sand estimated depth = 6,073' TVD /" 3 �i 10 '15 onGas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 607 psi (6,073' TVD * 0.10 psi/ft) MPSP = BHP — gas column = 2,709 psi (3,316 psi — 607 psi) pp data an poterthat gas -ones: The wellbore is not expected to penetrate any shallow gas zones. And (C) data com erring potential causes ol'hole problems such as abanernally gen-prev.sured .straa, love circulation zones, and Zones that have a teropeasuy.for di(ferentialstic'kbr,4; See attached 2M-39 Drilling Hazards Summary Reauirentents of 20 AAC 25.005 (c)(5) An applie ation ftrr a Permit to Drill native be accompanied by each ofthe following items, except for an item already oq(ile with the commission and identified in the application: (5) a description of the procedure for t onducting formmitm integ rite mets, as required reader 20 AAC 25.030(/); A procedure is on file with the commission for performing FTT/LOT's. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An apph,euiun for a Pronto ra ]),,It nnrsi be acmmpnnied breach ofdre fallowing ilemx except f a -an item at, edy an fele nidi the canmzssion ,in/ idenaid,d in the applicalwa: (6) a coneplea, proposed casing and cementing prngreva at required by 20 AAC 25.030, and desctiplion ofan)ulottel liner. pre -perforated liner, or screen to be rowelled Casing and Cement Program 13-3/811 Surface casing run to 2,861' MD / 2,640' TVD Cement surface casing back to surface. Pump a 500'of tail slurry with 12.0 ppg DeepCRETE and a lead slurry with 11.0 ppg LiteCRETE. Assume 200% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. Casing and Cementing Program Hole Casing Weight Grade Coupling Length Top MD Top TVD Bottom MD Bottom TVD Cemen[Details 42" 20" 94# H40 Welded 80 Surface Surface 119' 119' Installed 16" 13-318" 68# L-80 Hyd 563 2,822' Surface Surface 2,86 P 2,640' 1546 sx 11.0 ppg Lead, 232 sx 12.0 ppg Tail 12.25" 9-5/8" 474 Ir80 Hyd 563 15,683' Surface Surface 15,722' 5,800' 400 sx 15.8 ppg Class G 8-12 x 9.7/8„ 7" 264 t.80 Hyd 563 y 1,517' 15,522' 5,751' 17,039' 6,073' 428 sx 15.8 ppg Class G 6-1/8" 4-12" 12.64 480 Hyd 563 8,797' 16,839' 6,035' 25,636' 6,169' N/A: Uncemented liner 13-3/811 Surface casing run to 2,861' MD / 2,640' TVD Cement surface casing back to surface. Pump a 500'of tail slurry with 12.0 ppg DeepCRETE and a lead slurry with 11.0 ppg LiteCRETE. Assume 200% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor. 13-3/8" SURFACE CEMENT CALCS 7" Intrm 2 Cement Calculations Design: SOD' of Tail Cmt @ 50% excess in OH & Lead Cmt to surface @ 200% excess in OH Tail Cement yield= r 1.65ft-3/sk Lead Cement yield= 1.91 f[^3/sk I Planned TOC= 11.0 ppg LiteCRETE Lead Slurry Shoe Track 80'x 0.0732 bbl/ft x 1.0 (0% excess) CONDUCTOR= 119'. 0.1862 bbl/ftx 1.0(0%excess) 22.2 bbis B[m of Leatl to Co" = (2361'- 119'1 x 0.0749 bbl/ft x excess) 503.6 bbis Total Lead Cement= 100% 526 bbis or 2953.2 k^3 or 3546sks or 400 sks 12.0 ppg DeepCRETE Tail Slurry Displacement= (15722'-80')x 0.0732 bbl/ft= Shoetrack= 500'. 0.1497 bbl/ft x 1.0(0% excess) 12.0 bbis Shoe to Top of Tail= (2861'-2361') x 0.0749 bbl/ft x 1.5 (50% 56.2 bbis Total Tail Cement= I 68.2bbis I or 1382.7ft43 1 or 232sks Displacement= I (2861'-80')x O.1497bbl/ft= 416.4bbls 9-5/811 Intermediate I casing run to 15,722' MD / 5,800' TVD Single stage 15.8ppg Class G slurry is designed to be placed from TD to 14,702' MD/5,550' TVD with 35% excess annular volume. 9-5/8" Intrm 1 Cement Calculations 7" Intrm 2 Cement Calculations Design: UnISLURRY Class G 15.8 ppg Cement to 250' TVD above shoe Design: UnISLURRY Class G 15.8 ppg Cement to 7' Liner Top Cement yield= 1.16ftA3/sk Cement yield= I Planned TOC= 14702'MD Shoe Track 80'x 0.0732 bbl/ft x 1.0 (0% excess) 5.9 bbls Shoe to Top of Cement= (15722'- 147021) x 0.0558 bbl/ft x 1.35 (35% excess) 76.8 bbis Total Cement Volume= 82.7bbls 1 or 464.1ft^3 or 400 sks 5.1 bbis Displacement= (15722'-80')x 0.0732 bbl/ft= 1145.Ibbls T' Intermediate II Liner run to 17,039' MD / 6,073' TVD 5 -5* -1 -TVD Single stage 15.8ppg Class G slurry is designed to be placed from TD to the 7" liner top at 15,522' MD with 35% excess annular volume. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An rtpplicmiun fru a Permit m Drill must he ac,,w,W,nied by each vi'Mclollou in, tiem.s, except lot'wt item ah eadv un file u,iih the emnrnusiort mvl idenH%ted in the application: (7) a diagram and description ofthe dlvertersystem as required by 10 AAC25035, unless this requirement is waived by the commission under 10 AAC 25035(h)(2), Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An npplicanon fnr a Permit to Orill nmst be m'eonynmied hr each r f the following he U. ext ept furan item ah'eadY on file with the ennnnusion and ideny(ed in the application: 7" Intrm 2 Cement Calculations Design: UnISLURRY Class G 15.8 ppg Cement to 7' Liner Top Cement yield= 1.16ft^3/sk I Planned TOC = 15523'MD Shoe Track 80'x 0.0383 Will, x 1.010% excess) 3.1 bbis 8-1/2" OH x7"Annulus 110'x 0,0226 bbl/ftx 1.35 (35% excess) 3.4 bills 9-7/8" OH x7"Annulus 1207' x0.0471 Will, x 1.35 (35% excess) 76.8 bbis 9-5/8"Csg x 7- Annulus 200'. 0.0256 bbl/ft x 1.0(0% excess) 5.1 bbis Total Cement Volume= 88.3 bbis or 496 ftA3 I or 428 sks Displacement= (16959'-15522') x 0.0383 Wirt+ 15522' x 0.0235 With: 419.8 bbis Diverter System Information Requirements of 20 AAC 25.005(c)(7) An rtpplicmiun fru a Permit m Drill must he ac,,w,W,nied by each vi'Mclollou in, tiem.s, except lot'wt item ah eadv un file u,iih the emnrnusiort mvl idenH%ted in the application: (7) a diagram and description ofthe dlvertersystem as required by 10 AAC25035, unless this requirement is waived by the commission under 10 AAC 25035(h)(2), Please reference attachment for diverter schematic. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An npplicanon fnr a Permit to Orill nmst be m'eonynmied hr each r f the following he U. ext ept furan item ah'eadY on file with the ennnnusion and ideny(ed in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25033, Mud Program Summary 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. Abnormally Pressured Formation Information Reauirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Reauirements of 20 AAC 25.005 (e)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An applirmiun fin a Penult to Drillmins, be nccampauied by each gflhe fohow'ing hems, except for un item alreadp on file w'iah the eomrnission and idunifted in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. Aw f CCn $;5'ktK+ aalaLtN-� 2��g Ids Surface 16" Hole 13.318" Casing Intermediate 1 12-1/4" Hole 9-5/8" Casing Intermediate 2 8-1/2" x 9-7/8" Hole 7" Liner Production 6-1/8" Hole 4-1/2" Liner Mud System Spud BM LSND WBM) 1 -SND (WBM) Flo -Pro NT (WBM Density 8.8-9.5 9.5-10.5 10.5-12.2 10.5-12.2 PV 30-50 10-20 10-20 10-20 yP 30-80 16-24 17.28 16.24 Funnel Viscosity 250-300 Permafrost Base 100-150 to TD 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 120 F N/A <10 < 10 < 10 H 9.0-10.0 9.0-10.0 9.0-10.0 9.5-10.0 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. Abnormally Pressured Formation Information Reauirements of 20 AAC 25.005 (c)(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Reauirements of 20 AAC 25.005 (e)(10) N/A - Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An applirmiun fin a Penult to Drillmins, be nccampauied by each gflhe fohow'ing hems, except for un item alreadp on file w'iah the eomrnission and idunifted in the application: The proposed drilling program follows. Please refer to attachment for proposed well schematic. Aw f CCn $;5'ktK+ aalaLtN-� 2��g Ids 1. Move in / rig up Doyon Rig 142. Install 21-1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 16" hole to casing point as per directional plan with 5-7/8" OR Survey & log with MWD, GWD, GR. 3. Run and cement 13-3/8", 68#, L80, Hydril 563 casing to surface. Displace cement with mud & check floats upon bumping plug. Perform top job if required after notifying AOGCC. 4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP 's to 3500 psi high and 250 psi low. Notify AOGCC 24 hrs before test. 5. PU 12-1/4" bit and directional drilling assembly, with MWD, Gamma Ray, & Resistivity. RIH to 100' above float collar with 5-7/8" DP. Test surface casing to 3,000 psi for 30 minutes, charted. 6. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 12.5 ppg EMW, record S G results. 7. Directionally drill to 12-1/4" intermediate I hole to TD at+/- 15,722' MD/5,800' TVD in the HRZ. 8. BROO14 to surface shoe, circulate well clean then POOH on elevators. 9. Lay down intermediate 1 BHA. 10. Run 9-5/8", 47#/40# L80, Hydril 563 casing from surface to TD. 11. Pump cement job as per Schlumberger proposal. Displace cement with mud and check floats upon bumping plug. Top cement to be placed @ +1- 14,702' MD/5,550' TVD. -J:N ¢ / 12. Install 9-5/8" packoff & test to 5000 psi. 13. PU 8-1/2" bit, and drilling assembly with underreamer, MWD, Gamma Ray, Resistivity, and Neutron Density. 14. RIH on 5-7/8" DP to top of float equipment. Test casing to 3,500 psi for 30 minutes. 15. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 12.0 ppg EMW recording results. -T-nj-1 4✓'� 16. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel to freeze protect. _J�'f- 2- 17. 17. Directionally drill 8-1/2" x 9-7/8" hole to TD in the Kuparuk C sand at+/- 17,039' MD/6,073' TVD. Gest 17 1 18. Circulate 1 BU and flow check. POOH on elevators to 9-5/8" shoe. CBU to clean casing &POOH on elevators. 1/a 19. Lay down intermediate 2 BHA. 101 20. Rig up &Run 7", 26#, L-80, Hydril 563 liner and liner top packer. Change out handling gear and RIH with 7" rc �v1Ytc� Liner on 5-7/8" DP to bottom. 21. Pump cementjob as per Schlumberger proposal. Displace cement with mud. Top of cement to be at the liner hanger +/- 15,522' MD/5,751' TVD. 22. Release liner running tool and set packer. PU and pressure test packer to 1,000 psi for 10 minutes. 23. PU 6-1/8" bit and drilling assembly with MWD, Gamma Ray, Resistivity, Neutron Density, & PeriScope. RIH and clean out cement to float equipment. Test the liner to 3,500 psi for 30 min, record results. 24. Drill out shoe track and 20' of new formation. Perform LOT/FIT to a minimum of 13.0 ppg EMW, recording results. 25. Directionally drill the 6-1/8" production section, geo-steering in the Kuparuk C sand to TD of+/- 25,636' MD/6,169' TVD. 26. Circulate I x BU at TO and flow check. 27. BROOH to the 7" shoe. CBU and POOH on elevators. 28. Lay down the 6-1/8" production BHA. 29. PU and run 4-1/2", 12.6# pre -perforated liner with liner hanger & packer. 30. Set liner hanger & packer. 31. Pressure test liner top packer to 3,000 psi, chart results. 32. Flow check well. 33. POOH with liner running tools and lay down. 34. Run 3-1/2" 9.3#, 1,80, Hydril 563 upper completion and land tubing. 35. Nipple down BOPE and nipple up tree. Test tree and freeze protect well. Install BPV. 36. RDMO. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An applicaurni jor a Pennit m Didl mucic he ace onnpanied by eueh q(ihe following items, ercepi jar an hem ub'eady mrJle wilh 11'e comnuaimn aril identi(rd in the applicadae: (14) a genual desmInion r f hnuthe operator plans m dispose of drilling mid and Cuttings and a slatemem ofwhether' dee opemtnr intends ne ,,pest aallunizalOn under20 MC 25.080 f.. un an /a, disposal operation in the wr11.1 Waste fluids and cuttings generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well at the 1B Facility. If needed, excess cuttings generated will be hauled to Milne Point or 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 (if free of hazardous substances) used on pads and roads in the Kupamk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 ROP Ram Placement for Intermediate I Section Attachment 2 Well Schematic Attachment 3 Diverter Layout Diaeram Attachment 4 Directional Plan Attachment 5 Drilliniz Hazards Summary Intrm 1 BOP *This is for the Intrm #1 section only, the subsequent sections will have a configuration with VBRs in the upper cavity. FiTIN Fixed Blind s-.nufYIII IH(W)blinO'X'� V 6 R Intrm 2 & Production Operations Spud mud 8.6-9.5 PPG MD 2M-39wp1_ roposed Wellbore Schematic Injector ConocoPhillips TVD 10,808' MD / 4,675' ND Conductor Installed: 20" set at 119' Updated: 12/12/18 by Lehman 16" Surface Hole Surface Casine: Below West Salt 13-3/8" 68# L-80 Hydril 563 2,861' MD / 2,640' ND 1 I I I Tub 77'Tangent 3ubl" 9.3# L-80 HYD563 12-1/4" Intermediate Hole TOC 250' ND above shoe HRD-E 2%P Packer 7" z 9 5/8" Flex -Lock liner hanger MD / 5,813' TVD Intermediate 1: 9 5/8" 47#. L HRD-E ZXP Packer 17,039' MD / 6,073' ND I H 1 7" x 4-%" Baker Flex Lock Liner 8-1/2" x 9-7/8" Intermediate Hole 4-1/2" 12.6# L-80 HYD563 +/-25,636' MD/6,169 ND 2M-39wp1:� roposed Wellbore Schematic �. Injector Conoco Phillips DOYON 142 21-1/4" DIVERTER WME-al I O O I RIG FLOOR HYDRILL DIVERTER ANNULAR MSP 21-1/4" a 2000 PSI STUD z FLANGE RX -73 19" 150 PSI FULL OPENING HYDRAULICALLY ACTUATED KNIFE GATE VALVE 16" DIVERTER LINE DIVERTER SPOOL 2000 PSI 21-1/4" FLANGE z FLANGE WITH 19" OUTLET RX -73 CLAMP HUH CONDUCTOR GROUND LEVEL DRILL SITE 2M To DS21L SCALE •• • 50 104 ConocoPhillips TITLE: DS2M LAYOUT DRAWING Alaska, Inc. DRAWN BY: ALKET MICI I DATE: ftw ba 2018 1 aee 1 2M-39wpl5 13-3/8 x 16 9-5/8 x 12-1/Qpleasured Depth 7" x 8-1/2 by 9-7/8" _ --- 7-7+s Built: 39 + 100.7 @ 139.70usft (Doyon14 0 rE w, U _ -le_ DDI 7.443 plan Summa -- _ 1 Lithology 19620 21630 30 001300.00 2M3A 15 (Plan: 0139) Gy6GC-SS East / X: ��tPP3 Aw: V. Osara • �. 1J. SSI M. Woodard 190 suT-3 1300.002060.65 21049v,15 (Plan: 2%39) MWD+IFR-AK-CA -SC ND MD Name �i�mass m imIr'sus 23830 — 256M 2650.854360.65 21(Man: Nn: 21439) MWD 2640.00 2860.65 133/8x16 Iz.Tr.,n7c,r w.nam.or.o-.ar 2000.635721.70 21 3a,15 (Plan: 2%39) MWDeIFR-AK-C -SC • Magnetic Model & Date: BGGMZMSan-19 15721.706875.00 21X39a,45 (Pian: 2%39) MWD avrm®ne.w �mm« ria' 5800.00 15721.70 9-5/6 x 12-114 Magnetic North is 16.64° East of True North (Magnetic Declination 9 ( 9 15721.707030.55 2M,39a,15 (Mr: 2%39) MWDMFR-AK.CQSC 1703x.5 8375.00 2W39ap15 (PMn'. 2%39) MWD 17038.545535.09 2M-39,115 (Plan' 2139) MWD11FR-AK-CA SL 6072.70 17038.557" x 8-1 f2 by 9-718" 6169.03 25636.09 4-v2 x 6 -ire Magnetic Dip & Field Strength: 80.80° 57415nT WSakD ,i�a:i�mv oAami azi�w ��"ro7'�os��b•Iv�ffia nn n ar :iaA+wn °w um wm �+ 7em.�ev Base WS mrsm N 1. wd TFn1? on°.nns s®A7 N9 sR 6 dI... 1M tt sns. II iY p - .'. Yp >NipW9 9 00.An&TR.b wN .zssiluna .'M .i��Rvna aanoomce.w .coram-�aa.o-en Camp SS imna wr re.o-na reoreea. nu fr.�na.o-.e _ wmnans� n.l.1 J /fir," \ �< s' • 1 iro r�.onMH "roes.asre.o- wcu C-50 _ 41. I.sv.imur u o m�nm'a`n aareaime». w'aA �v.rc><.o-za C-37 / Icebei .:aw..® ®a �.xn wmm.,,e,z.�snm em nmwss® ae7unmv.. corm®w.e�zm�w 1 � I lent Magnetic Distance sssAl C-35 ��CLB pn �� 1 6500 9750 13000 16250 19500 22750 MeasuredDgr s, 1, 3,M FrooDe14h To Survey.Plan Tool'' Checked by:ccepted 1 Lithology 19620 21630 30 001300.00 2M3A 15 (Plan: 0139) Gy6GC-SS East / X: am n.o-am V. Osara 21630 23830 1300.002300.00 2139apIS(Plan'. 21439) MWOPM M. Woodard 190 suT-3 1300.002060.65 21049v,15 (Plan: 2%39) MWD+IFR-AK-CA -SC ND MD Name �i�mass m imIr'sus 23830 — 256M 2650.854360.65 21(Man: Nn: 21439) MWD 2640.00 2860.65 133/8x16 Iz.Tr.,n7c,r w.nam.or.o-.ar 2000.635721.70 21 3a,15 (Plan: 2%39) MWDeIFR-AK-C -SC • Magnetic Model & Date: BGGMZMSan-19 15721.706875.00 21X39a,45 (Pian: 2%39) MWD avrm®ne.w �mm« ria' 5800.00 15721.70 9-5/6 x 12-114 Magnetic North is 16.64° East of True North (Magnetic Declination 9 ( 9 15721.707030.55 2M,39a,15 (Mr: 2%39) MWDMFR-AK.CQSC 1703x.5 8375.00 2W39ap15 (PMn'. 2%39) MWD 17038.545535.09 2M-39,115 (Plan' 2139) MWD11FR-AK-CA SL 6072.70 17038.557" x 8-1 f2 by 9-718" 6169.03 25636.09 4-v2 x 6 -ire Magnetic Dip & Field Strength: 80.80° 57415nT nw Checked by:ccepted TIiP VAatt d sus "usz Lithology Column B. Temple am n.o-am V. Osara s a m u'a M. Woodard 9� n Men aav>f.o- Iwai. nroaaay.Tn.o-um suT-3 a��x �i�mass m imIr'sus ,vmex:�.w n im .w wo�e.o- n nmw K-15 Iz.Tr.,n7c,r w.nam.or.o-.ar �a.o-z+x • �;.: as Base Perm avrm®ne.w �mm« ria' bisin:�m-Ia°e01.isiii nmoAed a�z v s;rn awimaa as a?mey ^mos.+ae rF.n iz�. WSakD ,i�a:i�mv oAami azi�w ��"ro7'�os��b•Iv�ffia nn n ar :iaA+wn °w um wm �+ 7em.�ev Base WS mrsm N 1. wd TFn1? on°.nns s®A7 N9 sR 6 dI... 1M tt sns. II iY p - .'. Yp >NipW9 9 00.An&TR.b wN .zssiluna .'M .i��Rvna aanoomce.w .coram-�aa.o-en Camp SS imna wr re.o-na reoreea. nu fr.�na.o-.e _ wmnans� n.l.1 � 711 iro r�.onMH "roes.asre.o- wcu C-50 _ 41. I.sv.imur u o m�nm'a`n aareaime». w'aA �v.rc><.o-za C-37 / Icebei .:aw..® ®a �.xn wmm.,,e,z.�snm em nmwss® ae7unmv.. corm®w.e�zm�w sssAl C-35 ��CLB By signing this I acknowledge that 1 have been informed of all risks, checked that Me data is correct, ensured its completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and mllislon avoidance plan as set out in the audit pack,I approve it as the basis for Me final v 11 plan I and wellsite drawings. I also aclmoWeage that unless notified othermse all targets have a 100 feet lateral tolerance. repared by Checked by:ccepted by: Approved by: B. Temple V. Osara J. Ryan M. Woodard 2M-39wp15 39.00 To 25636.09 Spider All Wells 2M-39wp15 15 2M-32L1PB1 2S-14 / / F2M-32L1PB2 2M-35 2S-11 2S -09A 12S-04 / r25 Easting (2500 usfUin) 1 2M-16 2M-17 2M-14 2M-09 L1 2M-39wp15 39.00 To 25636.09 Spider AC Only 2M-39wp15 7 Plan Vmew While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise. 13-3/8 x 1 _ 0 d o- d o 0 0 0 d cg o 0 0 ' 9-5/8 x 12-10 o 0 -2500 / 7600 0 7" x 8-1/2 by 9-7666 2M-39 T01 Heel 020818 M --- 2M-39 T02 020818 J 0 _ _ 2M-39 T03 020818 J —+5000- /---- - 2M-39 T04 020818 J 9000 2M-39 T05 02081 8 J ? 20000__ 2M-39 T06 020818 J r 2M-39 T07 02081"J ° 7500 c� 000 2M-39 T08 02081"J 2tT�p 2M-39 T09 020818 J -- 2M-39 T10 0208188* 23000 2M-39 T11 013018 J -10000 4II 2M-39 T12 013018 J 200-- --- ---- 2M-39 T13 013018 J 2�0• 2M-39 T14 013018 J 4-1/2 x 6-1/8---, g 2M-39 T15 Toe 013018 M -12500 2M_'-'' -17500 -15000 -12500 -10000 -7500 -5000 -2500 0 West(-)/East(+) 1 2M-39wpl5 T-3 K-15 Base Perm 0 A,, , W Sak D Base WS 1000 Camp SS 0 0 ---�ao�.� o 0 -'v (0 0 0 C-50 C-37 / Iceberg (0 o0 0 0, o C-35 13-3/8 x 16 ^ CID o 0 o THRZK ,'o 0 0 o O -1 ='�o--- o ---- ----------- '-- ----- 'B iRZTLBN KTo o Kup . _______________.___..__...___________ToO_ �, ''O___ '___.___ -.________..______.-- CD p� _ -'O 0 6 O -0 (D___...____ M. ...©_ �a�i ----------------------------------------- --------'-------------- _ -- --- ---------- ------ O p 7" x 8-1/2 by 9-7/8" 9-5/8 x 12-1/4 4-1/2 x 6-1/8 0 2500 5000 7500 10000 12500 15000 17500 Vertical Section at 250.000 20000 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-39 50103xxxxx00 Plan: 2M-39 Plan: 2M-39wp15 Standard Proposal Report 11 December, 2018 ConoZcoPhillips ConocoPhillips Database: OAKEDMPI Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kuparuk 2M Pad Well: Plan: 210-39 Wellbore: Plan: 2M-39 Design: 2M-39Wp15 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 210-39 ND Reference: As Built: 39+ 100.7 @ 139.70usft Design 2M-39Wp15 (Doyon142) MD Reference: As Built: 39 + 100.7 @ 139.70usft Northing: (Doyon142) 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: Northing: Latitude: From: Map Easting: Longitude: Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.10' Well Plan: 2M-39 Design 2M-39Wp15 Well Position +N/ -S -0.45 usft Northing: Latitude: +E/ -W 110.38 usft Easting: Longitude: Fashion Uncertainty Vertical Section: 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: Wellbore Plan: 2M-39 Magnetics Model Name Sample Date BGGM2018 1/20/2019 Declination 16.64 Dip Angle 80.8 100.70 usft Field Strength (nT) 0 57.415 39.00 Direction (°) 250.00 1211112018 9.29:09AM Page 2 COMPASS 5000.14 Build 85D Design 2M-39Wp15 Audit Notes: Version: Phase: PLAN Te On Depth: Vertical Section: Depth From (TVD) +N/S +E/ -W (usft) (usft) (usft) 39.00 0.00 0,00 100.70 usft Field Strength (nT) 0 57.415 39.00 Direction (°) 250.00 1211112018 9.29:09AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEOMP7 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kupawk 2M Pad Well: Plan: 2M-39 Wellbore: Plan: 2110-39 Daslgn: 2M-39wp15 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Plan Survey Tool Program Date 12/7/2018 Depth From Depth To (usft) (usR) Survey (Wellbore) Tool Name Remarks 1 39.00 1,300.00 2M-39wp15 (Plan: 2M-39) GVD-GC-SS Gyrodata gyro single shots 2 1,300.00 2,300.00 2M-39wpl5(Plan: 2M-39) MWD MWD - Standard 3 1,300.00 2,860.65 2M-39wpl5(Plan: 21VI-39) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4 2,860.65 4,360.65 2M-39wp15(Plan: 2M-39) MWD MWD - Standard 5 2,860.65 15,721.70 2M-39wpl5 (Plan: 2M-39) MWD+IFR-AK-CAZ-SC MWD -IFR AK CAZ SCC 6 15,721.70 16,875.00 2M-39wp15(Plan: 2M-39) MWD MWD - Standard 7 15,721.70 17,038.55 2M-39wpl 5 (Plan: 2M-39) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8 17,038.55 18,375.00 2M-39wpl5(Plan: 2M-39) MWD MWD - Standard 9 17,038.55 25,636.09 2M-39wpl5 (Plan: 2M-39) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ConocoPhillips Standard Proposal Report Well Plan: 2M-39 As Built: 39 + 100.7 @ 139.70usft (Doyon142) As Built: 39+ 100.7 @ 139.70usft (Doyon142) True Minimum Curvature 12111/2018 9: 29: 09AM Page 3 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan: 21 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: As Built: 39+ 100.7 @ 139.70usft (Doyonl42) Project: Kuparuk River Unit MD Reference: As Built: 39+100.7 @ 139.70usft (Doyon142) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 210-39 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-39 Design: 2M-39wp15 Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°1100usft) (°HOOusft) (°/100usft) (') Target 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 1,000.00 10.50 305.00 996.09 36.69 -52.39 1.50 1.50 0.00 305.00 1,448.76 18.81 291.00 1,430.00 86.17 -153.64 2.00 1.85 -3.12 -30.00 1,554.41 18.81 291.00 1,530.00 98.37 -185.44 0.00 0.00 0.00 0.00 2,860.65 43.67 274.17 2,640.00 208.54 -843.22 2.00 1.90 -1.29 -27.00 2,880.65 43.67 274.17 2,654.47 209.55 -856.99 0.00 0.00 0.00 0.00 3,780.65 77.01 261.00 3,095.05 182.05 -1,624.17 3.91 3.70 -1.46 -22.68 14,660.65 77.01 261.00 5,545.16 -1,499.45 -12,114.46 0.00 0.00 0.00 0.00 16,320.82 78.71 193.72 5,933.40 -2,519.75 -13,217.67 4.00 0.10 -4.10 -96.66 16,754.50 78.71 193.72 6,018.29 -2,932.91 -13,318.50 0.00 0.00 0.00 0.00 16,838.55 79.00 190.30 6,034.54 -3,013.55 -13,335.66 4.00 0.34 4.06 -85.42 17,038.55 79.00 190.30 6,072.70 -3,206.71 -13,370.76 0.00 0.00 0.00 0.00 2M-39 T01 Heel 0208 17,594.17 95.66 190.78 6,098.48 -3,750.44 -13,471.95 3.00 3.00 0.09 1.66 17,759.96 95.66 190.78 6,082.13 -3,912.51 -13,502.81 0.00 0.00 0.00 0.00 18,095.90 89.13 192.35 6,068.09 4,241.15 -13,570.08 2.00 -1.94 0.47 166.41 2M-39 T03 020818 JA 18,097.50 89.10 192.36 6,068.11 4,242.72 -13,570.42 2.00 -2.00 0.10 177.04 18,729.47 89.10 192.36 6,078.07 -4,859.97 -13,705.64 0.00 0.00 0.00 0.00 18,796.52 89.77 192.32 6,078.73 4,925.46 -13,719.97 1.00 1.00 -0.05 -2.96 2M-39 T04 020818 JA 19,843.11 89.77 192.32 6,082.98 -5,947.94 -13,943.30 0.00 0.00 0.00 0.00 2M-39 T05 020818 JA 20,050.45 85.62 192.31 6,091.32 -6,150.30 -13,987.48 2.00 -2.00 -0.01 -179.84 20,278.39 85.62 192.31 6,108.73 -6,372.35 -14,035.94 0.00 0.00 0.00 0.00 20,477.05 89.59 192.34 6,117.02 -6,566.22 -14,078.30 2.00 2.00 0.02 0.45 2M-39 T06 020818 JA 21,076.18 89.59 192.34 6,121.27 -7,151.49 -14,206.34 0.00 0.00 0.00 0.00 2M-39707020818 JA 21,202.35 67.07 192.24 6,124.94 -7,274.70 -14,233.19 2.00 -2.00 -0.08 -177.82 21,442.09 87.07 192.24 6,137.19 -7,508.69 -14,283.97 0.00 0.00 0.00 0.00 21,735.03 90.00 192.33 6,144.67 -7,794.79 -14,346.30 1.00 1.00 0.03 1.75 2M-39708020818 JA 21,951.66 92.17 192.32 6,140.58 -8,006.38 -14,392.54 1.00 1.00 -0.01 -0.36 22,015.60 92.17 192.32 6,138.16 -8,068.80 -14,406.17 0.00 0.00 0.00 0.00 22,106.90 90.34 192.40 6,136.16 -8,157.95 -14,425.71 2.00 -2.00 0.09 177.522M-39 T09020818 JA 22,107.13 90.35 192.40 6,136.16 -8,158.18 -14,425.75 2.00 1.91 0.61 17.70 22,800.65 90.35 192.40 6,131.97 -8,835.51 -14,574.69 0.00 0.00 0.00 0.00 22,818.84 90.00 192.29 6,131.91 -8,853.28 -14,578.57 2.00 -1.91 -0.61 -162.30 2M-39 T10 020818 JA 22,907.56 88.23 192.29 6,133.28 -8,939.95 -14,597.46 2.00 -2.00 0.00 -179.98 23,837.88 88.23 192.29 6,162.09 -9,848.51 -14,795.38 0.00 0.00 0.00 0.00 23,854.50 87.90 192.35 6,162.65 -9,864.74 -14,798.93 2.00 -1.96 0.39 168.86 2M-39 T11 013018 JA 23,870.64 87.58 192.37 6,163.29 -9,880.50 -14,802.38 2.00 -2.00 0.13 176.39 24,197.41 87.58 192.37 6,177.10 -10,199.39 -14,872.34 0.00 0.00 0.00 0.00 24,318.79 90.00 192.22 6,179.67 -10,317.95 -14,898.19 2.00 2.00 -0.13 -3.61 2M-39 T12 013018 JA 24,464.33 93.64 192.20 6,175.05 -10,460.10 -14,928.95 2.50 2.50 -0.02 -0.36 24,553.36 93.64 192.20 6,169.40 -10,546.94 -14,947.72 0.00 0.00 0.00 0.00 24,698.94 90.00 192.30 6,164.78 -10,689.12 -14,978.59 2.50 -2.50 0.07 178.47 2M-39713013018 JA 25,146.41 90.00 192.30 6,164.78 -11,126.32 -15,073.87 0.00 0.00 0.00 0.00 2M-39 T14013018 JA 25,172.64 89.49 192.41 6,164.90 -11,151.95 -15,079.49 2.00 -1.95 0.44 167.16 25,636.09 89.49 192.41 6,169.03 -11,604.55 -15,179.10 0.00 0.00 0.00 0.00 2M-39 T15 Toe 01301 12/112018 9:29:09AM Page 4 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan: 2M-39 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: As Built: 39 + 100.7 QO 139.70usft (Doyon142) Project: Kuparuk River Unit MD Reference: As Built: 39+ 100.7 @ 139.70usft (Doyon142) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 2M-39 Survey Calculation Method: Minimum Curvature Wellborn: Plan: 2M-39 Design: 2M-39Wp15 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (•) (_) (usft) (usft) (usft) (usft) (°1100usft) (°/100usft) (°/100usft) 39.00 0.00 0.00 39.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 1.50 305.00 399.99 0.75 -1.07 0.75 1.50 1.50 0.00 500.00 3.00 305.00 499.91 3.00 -4.29 3.00 1.50 1.50 0.00 600.00 4.50 305.00 599.69 6.75 -9.65 6.75 1.50 1.50 0.00 700.00 6.00 305.00 699.27 12.00 -17.14 12.00 1.50 1.50 0.00 800.00 7.50 305.00 798.57 18.74 -26.77 18.74 1.50 1.50 0.00 900.00 9.00 305.00 897.54 26.97 -38.52 26.97 1.50 1.50 0.00 1,000.00 10.50 305.00 996.09 36.69 -52.39 36.69 1.50 1.50 0.00 1,100.00 12.27 300.29 1,094.12 47.27 -69.04 48.70 2.00 1.77 -4.71 1,200.00 14.11 296.77 1,191.48 58.13 -89.09 63.84 2.00 1.83 -3.52 1,300.00 15.98 294.05 1,288.05 69.22 -112.54 82.08 2.00 1.87 -2.72 1,400.00 17.88 291.90 1,383.71 80.56 -139.35 103.40 2.00 1.90 -2.16 1,448.76 18.81 291.00 1,430.00 86.17 -153.64 114.90 2.00 1.91 -1.84 1,500.00 18.81 291.00 1,478.50 92.09 -169.06 127.37 0.00 0.00 0.00 1,554.41 18.81 291.00 1,530.00 98.37 -185.44 140.61 0.00 0.00 0.00 1,600.00 19.63 289.77 1,573.05 103.60 -199.51 152.04 2.00 1.79 -2.70 1,700.00 21.44 287.38 1,666.70 114.74 -232.76 179.48 2.00 1.82 -2.38 1,600.00 23.29 285.36 1,759.17 125.44 -269.27 210.13 2.00 1.85 -2.03 1,900.00 25.16 283.62 1,850.36 135.68 -309.00 243.96 2.00 1.87 -1.74 2,000.00 27.04 282.10 1,940.16 145.45 -351.89 280.92 2.00 1.89 -1.51 2,100.00 28.94 280.77 2,028.46 154.74 -397.89 320.97 2.00 1.90 -1.33 2,200.00 30.86 279.59 2,115.15 163.53 -446.95 364.06 2.00 1.91 -1.18 2,300.00 32.78 278.54 2,200.12 171.82 -499.01 410.15 2.00 1.92 -1.05 2,400.00 34.71 277.59 2,283.27 179.60 -554.00 459.16 2.00 1.93 -0.95 2,500.00 36.64 276.73 2,364.50 186.86 -611.86 511.05 2.00 1.94 -0.86 2,600.00 38.58 275.94 2,443.71 193.58 -672.52 565.75 2.00 1.94 -0.79 2,700.00 40.53 275.22 2,520.81 199.76 -735.90 623.20 2.00 1.95 -0.72 2,800.00 42.48 274.55 2,595.70 205.40 -801.92 683.31 2.00 1.95 -0.67 2,860.65 43.67 274.17 2,640.00 208.54 -843.22 721.04 2.00 1.95 -0.63 2,880.65 43.67 274.17 2,654.47 209.55 -856.99 733.64 0.00 0.00 0.00 2,900.00 44.36 273.75 2,668.38 210.48 -870.41 745.93 3.91 3.61 -2.15 3,000.00 47.99 271.75 2,737.62 213.90 -942.45 812.46 3.91 3.63 -2.00 3,100.00 51.65 269.97 2,802.13 215.02 -1,018.83 883.85 3.91 3.66 -1.78 3,200.00 55.34 268.36 2,861.61 213.82 -1,099.19 959.77 3.91 3.68 -1.61 3,300.00 59.04 266.89 2,915.79 210.31 -1,183.14 1,039.86 3.91 3.70 -1.47 3,400.00 62.76 265.52 2,964.41 204.51 -1,270.31 1,123.75 3.91 3.72 -1.36 3,500.00 66.49 264.25 3,007.26 196.44 -1,360.28 1,211.06 3.91 3.73 -1.27 3,600.00 70.23 263.04 3,044.13 186.14 -1,452.64 1,301.37 3.91 3.74 -1.20 3,700.00 73.98 261.90 3,074.85 173.66 -1,546.96 1,394.28 3.91 3.75 -1.15 3,780.65 77.01 261.00 3,095.05 162.05 -1,624.17 1,470.79 3.91 3.75 -1.11 3,800.00 77.01 261.00 3,099.40 159.10 -1,642.79 1,489.30 0.00 0.00 0.00 3,900.00 77.01 261.00 3,121.87 143.85 -1,739.03 1,584.95 0.00 0.00 0.00 4,000.00 77.01 261.00 3,144.35 128.61 -1,835.27 1,680.60 0.00 0.00 0.00 4,100.00 77.01 261.00 3,166.83 113.37 -1,931.51 1,776.25 0.00 0.00 0.00 4,200.00 77.01 261.00 3,189.31 98.12 -2,027.75 1,871.90 0.00 0.00 0.00 4,300.00 77.01 261.00 3,211.79 82.88 -2,123.99 1,967.55 0.00 0.00 0.00 4,400.00 77.01 261.00 3,234.26 67.64 -2,220.24 2,063.21 0.00 0.00 0.00 4,500.00 77.01 261.00 3,256.74 52.39 -2,316.48 2,158.86 0.00 0.00 0.00 4,600.00 77.01 261.00 3,279.22 37.15 -2,412.72 2,254.51 0.00 0.00 0.00 12111/2018 9:29:09AM Page 5 COMPASS 5000 14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Co-ordinate Reference: Well Plan: 2M-39 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: As Built: 39+ 100.7 a 139.70usft (Doyon142) Project. Kuparuk River Unit MD Reference: As Built: 39+ 100.7 ® 139.70usft (Doyon142) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 2M-39 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-39 Design: 2M-39wpl5 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N1 -S +EI -W Section Rate Rate Rate (usft) (I V) (usft) (usft) (usft) (usft) (°1100usft) ("/100usft) (°1100usft) 4,700.00 77.01 261.00 3,301.70 21.91 -2,508.96 2,350.16 0.00 0.00 0.00 4,800.00 77.01 261.00 3,324.18 6.67 -2,605.20 2,445.81 0.00 0.00 0.00 4,900.00 77.01 261.00 3,346.65 -8.58 -2,701.44 2,541.46 0.00 0.00 0.00 5,000.00 77.01 261.00 3,369.13 -23.82 -2,797.68 2,637.11 0.00 0.00 0.00 5,100.00 77.01 261.00 3,391.61 -39.06 -2,893.92 2,732.76 0.00 0.00 0.00 5,200.00 77.01 261.00 3,414.09 -54.31 -2,990.17 2,828.41 0.00 0.00 0.00 5,300.00 77.01 261.00 3,436.57 -69.55 -3,086.41 2,924.06 0.00 0.00 0.00 5,400.00 77.01 261.00 3,459.05 -84.79 -3,182.65 3,019.71 0.00 0.00 0.00 5,500.00 77.01 261.00 3,481.52 -100.04 -3,278.89 3,115.36 0.00 0.00 0.00 5,600.00 77.01 261.00 3,504.00 -115.28 -3,375.13 3,211.01 0.00 0.00 0.00 5,700.00 77.01 261.00 3,526.48 -130.52 -3,471.37 3,306.66 0.00 0.00 0.00 5,800.00 77.01 261.00 3,548.96 -145.77 -3,567.61 3,402.31 0.00 0.00 0.00 5,900.00 77.01 261.00 3371.44 -161.01 -3,663.85 3,497.97 0.00 0.00 0.00 6,000.00 77.01 261.00 3,593.91 -176.25 -3,760.10 3,593.62 0.00 0.00 0.00 6,100.00 77.01 261.00 3,616.39 -191.50 -3,856.34 3,689.27 0.00 0.00 0.00 6,200.00 77.01 261.00 3,638.87 -206.74 -3,952.56 3,784.92 0.00 0.00 0.00 6,300.00 77.01 261.00 3,661.35 -221.98 4,048.82 3,880.57 0.00 0.00 0.00 6,400.00 77.01 261.00 3,683.83 -237.22 4,145.06 3,976.22 0.00 0.00 0.00 6,500.00 77.01 261.00 3,706.30 -252.47 4,241.30 4,071.87 0.00 0.00 0.00 6,600.00 77.01 261.00 3,728.78 -267.71 4,337.54 4,167.52 0.00 0.00 0.00 6,700.00 77.01 261.00 3,751.26 -282.95 4,433.78 4,263.17 0.00 0.00 0.00 6,800.00 77.01 261.00 3,773.74 -298.20 -4,530.03 4,358.82 0.00 0.00 0.00 6,900.00 77.01 261.00 3,796.22 -313.44 -4,626.27 4,454.47 0.00 0.00 0.00 7,000.00 77.01 261.00 3,618.69 -326.68 -4,722.51 4,550.12 0.00 0.00 0.00 7,100.00 77.01 261.00 3,841.17 -343.93 -4,818.75 4,645.77 0.00 0.00 0.00 7,200.00 77.01 261.00 3,863.65 -359.17 -4,914.99 4,741.42 0.00 0.00 0.00 7,300.00 77.01 261.00 3,886.13 -374.41 -5,011.23 4,837.07 0.00 0.00 0.00 7,400.00 77.01 261.00 3,908.61 -389.66 -5,107.47 4,932.73 0.00 0.00 0.00 7,500.00 77.01 261.00 3,931.09 -404.90 -5,203.71 5,028.38 0.00 0.00 0.00 7,600.00 77.01 261.00 3,953.56 -420.14 -5,299.96 5,124.03 0.00 0.00 0.00 7,700.00 77.01 261.00 3,976.04 -435.39 -5,396.20 5,219.68 0.00 0.00 0.00 7,800.00 77.01 261.00 3,998.52 -450.63 -5,492.44 5,315.33 0.00 0.00 0.00 7,900.00 77.01 261.00 4,021.00 -465.87 -5,588.68 5,410.98 0.00 0.00 0.00 8,000.00 77.01 261.00 4,043.48 481.11 -5,684.92 5,506.63 0.00 0.00 0.00 8,100.00 77.01 261.00 4,065.95 496.36 -5,781.16 5,602.28 0.00 0.00 0.00 8,200.00 77.01 261.00 4,088.43 -511.60 -5,877.40 5,697.93 0.00 0.00 0.00 8,300.00 77.01 261.00 4,110.91 -526.84 -5,973.64 5,793.58 0.00 0.00 0.00 8,400.00 77.01 261.00 4,133.39 -542.09 -6,069.89 5,889.23 0.00 0.00 0.00 8,500.00 77.01 261.00 4,155.87 -557.33 -6,166.13 5,984.88 0.00 0.00 0.00 8,600.00 77.01 261.00 4,178.34 -572.57 -6,262.37 6,080.53 0.00 0.00 0.00 8,700.00 77.01 261.00 4,200.82 -587.82 -6,358.61 6,176.18 0.00 0.00 0.00 8,800.00 77.01 261.00 4,223.30 -603.06 -6,454.85 6,271.83 0.00 0.00 0.00 8,900.00 77.01 261.00 4,245.78 -618.30 -6,551.09 6,367.49 0.00 0.00 0.00 9,000.00 77.01 261.00 4,268.26 -633.55 -6,647.33 6,463.14 0.00 0.00 0.00 9,100.00 77.01 261.00 4,290.73 -648.79 -6,743.57 6,558.79 0.00 0.00 0.00 9,200.00 77.01 261.00 4,313.21 -664.03 -6,839.82 6,654.44 0.00 0.00 0.00 9,300.00 77.01 261.00 4,335.69 -679.28 -6,936.06 6,750.09 0.00 0.00 0.00 9,400.00 77.01 261.00 4,358.17 -694.52 -7,032.30 6,845.74 0.00 0.00 0.00 9,500.00 77.01 261.00 4,380.65 -709.76 -7,128.54 6,941.39 0.00 0.00 0.00 9,600.00 77.01 261.00 4,403.13 -725.00 -7,224.78 7,037.04 0.00 0.00 0.00 9,700.00 77.01 261.00 4,425.60 -740.25 -7,321.02 7,132.69 0.00 0.00 0.00 1211112018 9:29:09AM Page 6 COMPASS 5000.14 Build 85D 10-11 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP7 Local Coordinate Reference: Well Plan: 2M-39 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: As Built: 39 + 100.7 @ 139.70usft (Doyonl42) Project: Kuparuk River Unit MD Reference: As Built: 39+ 100.7 @ 139.70usft (Doyonl42) Site: Kupamk 2M Pad North Reference: True Well: Plan: 2M-39 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-39 Design: 2M-39wp15 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) O (1) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) 9,900.00 77.01 261.00 4,470.56 -770.73 -7,513.51 7,323.99 0.00 0.00 0.00 10,000.00 77.01 261.00 4,493.04 -785.98 -7,609.75 7,419.64 0.00 0.00 0.00 10,100.00 77.01 261.00 4,515.52 -801.22 -7,705.99 7,515.29 0.00 0.00 0.00 10,200.00 77.01 261.00 4,537.99 -816.46 -7,802.23 7,610.94 0.00 0.00 0.00 10,300.00 77.01 261.00 4,560.47 -831.71 -7,898.47 7,706.59 0.00 0.00 0.00 10,400.00 77.01 261.00 4,582.95 -846.95 -7,994.71 7,802.25 0.00 0.00 0.00 10,500.00 77.01 261.00 4,605.43 -662.19 -8,090.95 7,897.90 0.00 0.00 0.00 10,600.00 77.01 261.00 4,627.91 -877.44 -8,187.19 7,993.55 0.00 0.00 0.00 10,700.00 77.01 261.00 4,650.38 -892.68 -8,283.44 8,089.20 0.00 0.00 0.00 10,800.00 77.01 261.00 4,672.86 -907.92 -8,379.68 8,184.85 0.00 0.00 0.00 10,900.00 77.01 261.00 4,695.34 -923.17 -8,475.92 8,280.50 0.00 0.00 0.00 11,000.00 77.01 261.00 4,717.82 -938.41 -8,572.16 8,376.15 0.00 0.00 0.00 11,100.00 77.01 261.00 4,740.30 -953.65 -8,668.40 8,471.80 0.00 0.00 0.00 11,200.00 77.01 261.00 4,762.77 -968.89 -8,764.64 8,567.45 0.00 0.00 0.00 11,300.00 77.01 261.00 4,785.25 -984.14 -8,860.88 8,663.10 0.00 0.00 0.00 11,400.00 77.01 261.00 4,807.73 -999.38 -8,957.12 8,758.75 0.00 0.00 0.00 11,500.00 77.01 261.00 4,830.21 -1,014.62 -9,053.37 8,854.40 0.00 0.00 0.00 11,600.00 77.01 261.00 4,852.69 -1,029.87 -9,149.61 8,950.05 0.00 0.00 0.00 11,700.00 77.01 261.00 4,875.17 -1,045.11 -9,245.85 9,045.70 0.00 0.00 0.00 11,800.00 77.01 261.00 4,897.64 -1,060.35 -0,342.09 9,141.35 0.00 0.00 0.00 11,900.00 77.01 261.00 4,920.12 -1,075.60 -9,438.33 9,237.01 0.00 0.00 0.00 12,000.00 77.01 261.00 4,942.60 -1,090.84 -9,534.57 9,332.66 0.00 0.00 0.00 12,100.00 77.01 261.00 4,965.08 -1,106.08 -9,630.81 9,428.31 0.00 0.00 0.00 12,200.00 77.01 261.00 4,987.56 -1,121.33 -9,727.05 9,523.96 0.00 0.00 0.00 12,300.00 77.01 261.00 5,010.03 -1,136.57 -9,823.30 9,619.61 0.00 0.00 0.00 12,400.00 77.01 261.00 5,032.51 -1,151.81 -9,919.54 9,715.26 0.00 0.00 0.00 12,500.00 77.01 261.00 5,054.99 -1,167.06 -10,015.78 9,810.91 0.00 0.00 0.00 12,600.00 77.01 261.00 5,077.47 -1,182.30 -10,112.02 9,906.56 0.00 0.00 0.00 12,700.00 77.01 261.00 5,099.95 -1,197.54 -10,208.26 10,002.21 0.00 0.00 0.00 12,800.00 77.01 261.00 5,122.42 -1,212.78 -10,304.50 10,097.86 0.00 0.00 0.00 12,900,00 77.01 261.00 5,144.90 -1,228.03 -10,400.74 10,193.51 0.00 0.00 0.00 13,000.00 77.01 261.00 5,167.38 -1,243.27 -10,496.98 10,289.16 0.00 0.00 0.00 13,100.00 77.01 261.00 5,189.86 -1,258.51 -10,593.23 10,384.81 0.00 0.00 0.00 13,200.00 77.01 261.00 5,212.34 -1,273.76 -10,689.47 10,480.46 0.00 0.00 0.00 13,300.00 77.01 261.00 5,234.81 -1,289.00 -10,785.71 10,576.11 0.00 0.00 0.00 13,400.00 77.01 261.00 5,257.29 -1,304.24 -10,881.95 10,671.77 0.00 0.00 0.00 13,500.00 77.01 261.00 5,279.77 -1,319.49 -10,978.19 10,767.42 0.00 0.00 0.00 13,600.00 77.01 261.00 5,302.25 -1,334.73 -11,074.43 10,863.07 0.00 0.00 0.00 X11.00 _ 77.01 -361.00 -24.73- -1,349.97 -11,170.67 10,958.72 0.00 0.00 0.00 13,800.00 77.01 261.00 5,347.21 -1,365.22 -11,266.91 11,054.37 0.00 0.00 0.00 13,900.00 77.01 261.00 5,369.68 -1,380.46 -11,363.16 11,150.02 0.00 0.00 0.00 14,000.00 77.01 261.00 5,392.16 -1,395.70 -11,459.40 11,245.67 0.00 0.00 0.00 14,100.00 77.01 261.00 5,414.64 -1,410.94 -11,555.64 11,341.32 0.00 0.00 0.00 14,200.00 77.01 261.00 5,437.12 -1,426.19 -11,651.88 11,436.97 0.00 0.00 0.00 14,300.00 77.01 261.00 5,459.60 -1,441.43 -11,748.12 11,532.62 0.00 0.00 0.00 14,400.00 77.01 261.00 5,482.07 -1,456.67 -11,844.36 11,628.27 0.00 0.00 0.00 14,500.00 77.01 261.00 5,504.55 -1,471.92 -11,940.60 11,723.92 0.00 0.00 0.00 14,600.00 77.01 261.00 5,527.03 -1,487.16 -12,036.84 11,819.57 0.00 0.00 0.00 14,680.65 77.01 261.00 5,545.16 -1,499.45 -12,114.46 11,896.72 0.00 0.00 0.00 14,700.00 76.92 260.21 5,549.52 -1,502.53 -12,133.06 11,915.24 4.00 -0.46 -4.08 14,800.00 76.50 256.12 5,572.52 -1,522.48 -12,226.29 12,011.56 4.00 -0.42 -4.09 14,900.00 76.15 252.02 5,596.17 -1,549.14 -12,321.71 12.108.45 4.00 -0.35 -4.10 1211112018 9:29:09AM Page 7 COMPASS 5000.14 Build 85D ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP1 Local Coordinate Reference: Well Plan: 2M-39 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: As Built: 39+ 100.7 @ 139.70usft (Doyon142) Project: Kupamk River Unit MD Reference: As Built: 39 + 100.7 @ 139.70usft (Doyonl42) Site: Kuparuk 2M Pad North Reference: True Well: Plan: 210-39 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-39 Design: 2M-39wpl5 Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth +N/ -S +E/ -W Section Rate Rate Rate (usft) (_) (1) (usft) (usft) (usft) (usft) (°1100usft) (°/100usft) ("/100usft) 15,000.00 75.87 247.91 5620.36 -1,582.37 -12,412.85 12,205.46 4.00 -0.28 -4.11 15,100.00 75.65 243.79 5,644.97 -1,622.01 -12,501.27 12,302.11 4.00 -0.21 4.12 15,200.00 75.51 239.66 5,669.88 -1,667.87 -12,586.55 12,397.93 4.00 -0.14 4.13 15,300.00 75.44 235.53 5,694.97 -1,719.74 -12,668.26 12,492.45 4.00 -0.07 4.13 15,400.00 75.44 231.40 5,720.13 -1,777.34 -12,746.00 12,585.21 4.00 0.00 4.13 15,500.00 75.51 227.27 5,745.22 -1,840.41 -12,819.41 12,675.76 4.00 0.07 -4.13 15,600.00 75.66 223.14 5,770.12 -1,908.64 -12,688.12 12,763.67 4.00 0.15 -4.13 15-.700-00 75.88 219.0 4. 2 -1,981.69 -12,951.80 12,848.49 4.00 0.22 -4.12 15,800.00 76.6 214.91 5,818.88 -2,059.21 -13,010.13 12,929.81 4.00 0.29 4.11 15,900.00 76.52 210.81 5,842.51 -2,140.82 -13,062.84 13,007.25 4.00 0.36 4.10 16,000.00 76.94 206.72 5,865.47 -2,226.12 -13,109.66 13,080.42 4.00 0.42 4.09 16,100.00 77.43 202.65 5,887.66 -2,314.70 -13,150.36 13,148.97 4.00 0.49 -4.07 16,200.00 77.97 198.59 5,908.97 -2,406.12 -13,184.76 13,212.57 4.00 0.55 4.06 16,300.00 78.58 194.55 5,929.30 -2,499.95 -13,212.68 13,27089 4.00 0.61 4.04 16,320.82 78.71 193.72 5,933.40 -2,519.75 -13,217.67 13,28235 4.00 0.64 4.03 16,400.00 78.71 193.72 5,948.90 -2,595.18 -13,236.08 13,325.45 0.00 0.00 0.00 16,500.00 78.71 193.72 5,968.47 -2,690.45 -13,259.33 13,379.88 0.00 0.00 0.00 16,600.00 78.71 193.72 5,988.05 -2,785.71 -13,282.58 13,434.31 0.00 0.00 0.00 16,700.00 78.71 193.72 6,007.62 -2,880.98 -13,305.83 13,488.75 0.00 0.00 0.00 16,754.50 78.71 193.72 6,018.29 -2,932.91 -13,318.50 13,518.41 0.00 0.00 0.00 16,800.00 78.86 191.87 6,027.14 -2,976.43 -13,328.38 13,542.58 4.00 0.33 4.06 16,838.55 79.00 190.30 6,034.54 -3,013.55 -13,335.66 13,562.11 4.00 0.36 4.06 16,900.00 79.00 190.30 6,046.26 -3,072.90 -13,346.44 13,592.55 0.00 0.00 0.00 17,000.00 79.00 190.30 6,065.34 -3,169.48 -13,364.00 13,642.08 0.00 0.00 0.00 17,038.55 79.00 190.30 6,072.70 -3,206.71 -13,370.76 13,661.17 0.00 0.00 0.00 17,100.00 80.84 190.36 6,083.45 -3,266.23 -13,381.61 13,691.72 3.00 3.00 0.09 17,200.00 83.84 190.44 6,096.78 -3,363.70 -13,399.50 13,741.86 3.00 3.00 0.09 17,300.00 86.84 190.53 6,104.90 -3,461.70 -13,417.64 13,792.42 3.00 3.00 0.09 17,400.00 89.84 190.61 6,107.80 -3,559.95 -13,435.97 13,843.26 3.00 3.00 0.09 17,500.00 92.84 190.70 6,105.46 -3,658.18 -13,454.45 13,894.22 3.00 3.00 0.09 17,594.17 95.66 190.78 6,098.48 -3,750.44 -13,471.95 13,942.22 3.00 3.00 0.09 17,600.00 95.66 190.78 6,097.91 -3,756.14 -13,473.04 13,945.19 0.00 0.00 0.00 17,700.00 95.66 190.78 6,088.04 -3,853.90 -13,491.65 13,996.11 0.00 0.00 0.00 17,759.96 95.66 190.78 6,082.13 -3,912.51 -13,502.81 14,026.64 0.00 0.00 0.00 17,800.00 94.88 190.97 6,078.45 -3,951.67 -13,510.33 14,047.10 2.00 -1.94 0.47 17,900.00 92.94 191.44 6,071.63 4,049.53 -13,529.71 14,098.79 2.00 -1.94 0.47 18,000.00 90.99 191.91 6,068.19 4,147.40 -13,549.93 14,151.26 2.00 -1.94 0.47 18,095.90 89.13 192.35 6,068.09 4,241.15 -13,570.08 14,202.26 2.00 -1.94 0.47 18,097.50 89.10 192.36 6,068.11 -4,242.72 -13,570.42 14,203.12 2.00 -2.00 0.10 18,100.00 89.10 192.36 6,068.15 -4,245.16 -13,570.96 14,204.46 0.00 0.00 0.00 18,200.00 89.10 192.36 6,069.73 -4,342.83 -13,592.35 14,257.97 0.00 0.00 0.00 18,300.00 89.10 192.36 6,071.30 -4,440.50 -13,613.75 14,311.48 0.00 0.00 0.00 18,400.00 89.10 192.36 6,072.88 -4,538.17 -13,635.14 14,364.99 0.00 0.00 0.00 18,500.00 89.10 192.36 6,074.45 4,635.84 -13,656.54 14,418.50 0.00 0.00 0.00 18,600.00 89.10 192.36 6,076.03 4,733.51 -13,677.94 14,472.01 0.00 0.00 0.00 18,700.00 89.10 192.36 6,077.60 4,831.18 -13,699.33 14,525.52 0.00 0.00 0.00 18,729.47 89.10 192.36 6,078.07 4,859.97 -13,705.64 14,541.30 0.00 0.00 0.00 18,796.52 89.77 192.32 6,078.73 -4,925.46 -13,719.97 14,577.16 1.00 1.00 -0.05 18,800.00 89.77 192.32 6,078.74 -4,928.87 -13,720.71 14,579.02 0.00 0.00 0.00 18,900.00 89.77 192.32 6,079.15 -5,026.56 -13,742.05 14,632.49 0.00 0.00 0.00 19,000.00 89.77 192.32 6,079.56 -5,124.26 -13,763.39 14,685.95 0.00 0.00 0.00 19100.00 89.77 192.32 6,079.96 -5,221.95 -13,784.73 14,739.42 0.00 0.00 0.00 12/11/2018 9:29:OQAM Page 8 COMPASS 5000.14 Build 85D ConocoPhillips Database Company Project: Site: Well: Wellbore: Design: Planned Survey Measured Depth (usft) 19,200.00 19,300.00 19,400.00 19,500.00 19,600.00 19,700.00 19,800.00 19,843.11 19,900.00 20,000.00 20,050.45 20,100.00 20,200.00 20,278.39 20,300.00 20,400.00 20,477.05 20,500.00 20,600.00 20,700.00 20,800.00 20,900.00 21,000.00 21,076.18 21,100.00 21,200.00 21,202.35 21,300.00 21,400.00 21,442.09 21,500.00 21,600.00 21,700.00 21,735.03 21,800.00 21,900.00 21,951.66 22,000.00 22,015.60 22,100.00 22,106.90 22,107.13 22,200.00 22,300.00 22,400.00 22,500.00 22,600.00 22,700.00 22,800.00 22,800.65 22,818.84 22,900.00 OAKEDMPI ConocoPhillips (Alaska) Inc.-Kup2 Kupawk River Unit Kupamk 2M Pad Plan: 2M-39 Plan: 2M-39 2M-39wp15 Inclination Azimuth TVD Reference: As Built: 39+ 100.7 @ 139.70usft 89.77 192.32 89.77 192.32 89.77 89.77 89.77 89.77 89.77 89.77 88.63 86.63 85.62 85.62 85.62 85.62 86.05 88.05 89.59 69.59 89.59 89.59 89.59 89.59 89.59 89.59 89.12 87.12 87.07 87.07 87.07 87.07 87.65 88.65 89.65 90.00 90.65 91.65 92.17 92.17 92.17 90.48 90.34 90.35 90.35 90.35 90.35 90.35 90.35 90.35 90.35 90.35 90.00 88.38 192.32 192.32 192.32 192.32 192.32 192.32 192.32 192.31 192.31 192.31 192.31 192.31 192.31 192.33 192.34 192.34 192.34 192.34 192.34 192.34 192.34 192.34 192.32 192.25 192.24 192.24 192.24 192.24 192.26 192.29 192.32 192.33 192.33 192.32 192.32 192.32 192.32 192.39 192.40 192.40 192.40 192.40 192.40 192.40 192.40 Vertical Depth (usft) 6,080.37 6,080.77 6,081.18 6,081.59 6,081.99 6,082.40 6,082.81 6,082.98 6,083.78 6,087.91 6,091.32 6,095.11 6,102.74 6,108.73 6,110.30 6,115.44 6,117.02 6,117.18 6,117.89 6,118.60 6,119.31 6,120.02 6,120.73 6,121.27 6,121.54 6,124.82 6,124.94 6,129.93 6,135.04 6,137.19 6,139.85 6,143.08 6,144.56 6,144.67 6,144.30 6,142.30 6,140.58 6,138.75 6,138.16 6,136.21 6,136.16 6,136.16 6,135.60 6,134.99 6,134.39 6,133.78 6,133.18 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Plan: 2M-39 TVD Reference: As Built: 39+ 100.7 @ 139.70usft 192.40 (Doyon142) MD Reference: As Built: 39+ 100.7 @ 139.70usft 192.40 (Doyon142) North Reference: True Survey Calculation Method: Minimum Curvature -N/-S (usft) -5,319.65 -5,417.34 -5,515.04 -5,612.74 -5,710.43 -5,808.13 -5,905.82 -5,947.94 -6,003.51 -6,101.12 -6,150.30 -6,198.57 -6,295.99 -6,372.35 -6,393.41 -6,490.97 -6,566.22 -6,588.64 -6,686.33 -6,784.02 -6,881.70 -6,979.39 -7,077.08 -7,151.49 -7,174.76 -7,272.42 -7,274.70 -7,370.01 -7,467.61 -7,508.69 -7,565.22 -7,662.88 -7,760.57 -7,794.79 -7,858.26 -7,955.94 -8,006.38 -8,053.57 -8,068.80 -8,151.22 -8,157.95 -8,158.18 -8,248.88 -8,346.55 -8,444.22 -8,541.88 -8,639.55 +E/ -W (usft) -13,806.07 -13,827.41 -13,848.75 -13,870.08 -13,891.42 -13,912.76 -13,934.10 -13,943.30 -13,955.44 -13,976.75 -13,987.48 -13,998.01 -14,019.27 -14,035.94 -14,040.53 -14,061.84 -14,078.30 -14,083.20 -14,104.57 -14,125.95 -14,147.32 -14,168.69 -14,190.06 -14,206.34 -14,211.43 -14,232.69 -14,233.19 -14,253.88 -14,275.06 -14,283.97 -14,296.25 -14,317.50 -14,338.82 -14,346.30 -14,360.17 -14,381.52 -14,392.54 -14,402.84 -14,406.17 -14,424.22 -14,425.71 -14,425.75 -14,445.70 -14,467.17 -14,488.65 -14,510.12 -14,531.60 192.40 6,132.57 -8,737.21 -14,553.07 192.40 6,131.97 -8,834.88 -14,574.55 192.40 6,131.97 -8,835.51 -14,574.69 192.29 6,131.91 -8,853.28 -14,578.57 192.29 6,133.06 -8,932.57 -14,595.85 Vertical Dogleg Build Tum Section Rate Rate Rate (usft) (°1100usft) (°/100usft) (°N00usft) 14,792.89 0.00 0.00 0.00 14,846.35 0.00 0.00 0.00 14,899.82 0.00 0.00 0.00 14,953.28 0.00 0.00 0.00 15,006.75 0.00 0.00 0.00 15,060.22 0.00 0.00 0.00 15,113.68 0.00 0.00 0.00 15,136.73 0.00 0.00 0.00 15,167.15 2.00 -2.00 -0.01 15,220.56 2.00 -2.00 -0.01 15,247.46 2.00 -2.00 -0.01 15,273.87 0.00 0.00 0.00 15,327.16 0.00 0.00 0.00 15,368.94 0.00 0.00 0.00 15,380.46 2.00 2.00 0.02 15,433.85 2.00 2.00 0.02 15,475.05 2.00 2.00 0.02 15,487.33 0.00 0.00 0.00 15,540.82 0.00 0.00 0.00 15,594.32 0.00 0.00 0.00 15,647.81 0.00 0.00 0.00 15,701.31 0.00 0.00 0.00 15,754.80 0.00 0.00 0.00 15,795.55 0.00 0.00 0.00 15,808.29 2.00 -2.00 -0.08 15,861.67 2.00 -2.00 -0.08 15,862.92 2.00 -2.00 -0.08 15,914.96 0.00 0.00 0.00 15,968.24 0.00 0.00 0.00 15,990.67 0.00 0.00 0.00 16,021.54 1.00 1.00 0.03 16,074.91 1.00 1.00 0.03 16,128.35 1.00 1.00 0.03 16,147.08 1.00 1.00 0.03 16,181.83 1.00 1.00 -0.01 16,235.30 1.00 1.00 -0.01 16,262.90 1.00 1.00 -0.01 16,288.73 0.00 0.00 0.00 16,297.06 0.00 0.00 0.00 16,342.22 2.00 -2.00 0.09 16,345.91 2.00 -2.00 0.09 16,346.04 2.00 1.91 0.61 16,395.80 0.00 0.00 0.00 16,449.38 0.00 0.00 0.00 16,502.97 0.00 0.00 0.00 16,556.55 0.00 0.00 0.00 16,610.13 0.00 0.00 0.00 16,663.72 0.00 0.00 0.00 16,717.30 0.00 0.00 0.00 16,717.65 0.00 0.00 0.00 16,727.38 2.00 -1.91 -0.61 16,770.73 2.00 -2.00 0.00 12/1112018 9:29:09AM Page 9 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMP7 Local Coordinate Reference: Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Project. Kuparuk River Unit MD Reference: Site: Kuparuk 2M Pad North Reference: Well: Plan: 2M-39 Survey Calculation Method: Wellbore: Plan: 2M-39 Dogleg Design: 2M-39wpl5 Depth ConocoPhillips Standard Proposal Report Well Plan: 210-39 As Built: 39 + 100.7 @ 139.70usft (Doyon142) As Built: 39+ 100.7 @ 139.70usft (Doyon142) True Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Tum Depth Inclination Azimuth Depth -NIS +EAW Section Rate Rate Rate (usft) (^) (1) (usft) (usft) (usft) (usft) (°1100usft) (°I100usft) (°1100usft) 22,907.56 88.23 192.29 6,133.28 -8,939.95 -14,597.46 16,774.76 2.00 -2.00 0.00 23,000.00 88.23 192.29 6,136.15 -9,030.23 -14,617.12 16,824.12 0.00 0.00 0.00 23,100.00 88.23 192.29 6,139.24 -9,127.89 -14,638.40 16,877.52 0.00 0.00 0.00 23,200.00 88.23 192.29 6,142.34 -9,225.55 -14,659.67 16,930.91 0.00 0.00 0.00 23,300.00 88.23 192.29 6,145.44 -9,323.22 -14,680.95 16,984.31 0.00 0.00 0.00 23,400.00 88.23 192.29 6,148.53 -9,420.88 -14,702.22 17,037.70 0.00 0.00 0.00 23,500.00 88.23 192.29 6,151.63 -9,518.54 -14,723.50 17,091.10 0.00 0.00 0.00 23,600.00 88.23 192.29 6,154.72 -9,616.20 -14,744.77 17,144.49 0.00 0.00 0.00 23,700.00 88.23 192.29 6,157.82 -9,713.86 -14,766.05 17,197.88 0.00 0.00 0.00 23,800.00 88.23 192.29 6,160.92 -9,811.52 -14,787.32 17,251.28 0.00 0.00 0.00 23,837.88 88.23 192.29 6,162.09 -9,848.51 -14,795.38 17,271.50 0.00 0.00 0.00 23,854.50 87.90 192.35 6,162.65 -9,864.74 -14,798.93 17,280.38 2.00 -1.96 0.39 23,870.64 87.58 192.37 6,163.29 -9,880.50 -14,802.38 17,289.02 2.00 -2.00 0.13 23,900.00 87.58 192.37 6,164.53 -9,909.15 -14,808.67 17,304.72 0.00 0.00 0.00 24,000.00 87.58 192.37 6,168.76 -10,006.74 -14,830.08 17,358.22 0.00 0.00 0.00 24,100.00 87.58 192.37 6,172.99 -10,104.33 -14,851.49 17,411.72 0.00 0.00 0.00 24,197.41 87.58 192.37 6,177.10 -10,199.39 -14,872.34 17,463.83 0.00 0.00 0.00 24,200.00 87.63 192.37 6,177.21 -10,201.92 -14,872.90 17,465.22 2.00 2.00 -0.13 24,300.00 89.62 192.25 6,179.61 -10,299.59 -14,894.21 17,518.64 2.00 2.00 -0.13 24,318.79 90.00 192.22 6,179.67 -10,317.95 -14,898.19 17,528.67 2.00 2.00 -0.13 24,400.00 92.03 192.21 6,178.23 -10,397.31 -14,915.37 17,571.95 2.50 2.50 -0.02 24,464.33 93.64 192.20 6,175.05 -10,460.10 -14,928.95 17,606.19 2.50 2.50 -0.02 24,500.00 93.64 192.20 6,172.79 -10,494.90 -14,936.47 17,625.16 0.00 0.00 0.00 24,553.36 93.64 192.20 6,169.40 -10,546.94 -14,947.72 17,653.53 0.00 0.00 0.00 24,600.00 92.47 192.23 6,166.91 -10,592.47 -14,957.58 17,678.36 2.50 -2.50 0.07 24,698.94 90.00 192.30 6,164.78 -10,689.12 -14,978.59 17,731.16 2.50 -2.50 0.07 24,700.00 90.00 192.30 6,164.78 -10,690.16 -14,978.81 17,731.73 0.00 0.00 0.00 24,800.00 90.00 192.30 6,164.78 -10,787.86 -15,000.11 17,785.16 0.00 0.00 0.00 24,900.00 90.00 192.30 6,164.78 -10,885.57 -15,021.40 17,838.58 0.00 0.00 0.00 25,000.00 90.00 192.30 6,164.78 -10,983.27 -15,042.70 17,892.01 0.00 0.00 0.00 25,100.00 90.00 192.30 6,164.78 -11,080.98 -15,063.99 17,945.44 0.00 0.00 0.00 25,146.41 90.00 192.30 6,164.78 -11,126.32 -15,073.87 17,970.24 0.00 0.00 0.00 25,172.64 89.49 192.41 6,164.90 -11,151.95 -15,079.49 17,984.27 2.00 -1.95 0.44 25,200.00 89.49 192.41 6,165.14 -11,178.67 -15,085.37 17,998.94 0.00 0.00 0.00 25,300.00 89.49 192.41 6,166.03 -11,276.33 -15,106.86 18,052.54 0.00 0.00 0.00 25,400.00 89.49 192.41 6,166.93 -11,373.98 -15,128.35 18,106.13 0.00 0.00 0.00 25,500.00 89.49 192.41 6,167.82 -11,471.64 -15,149.85 18,159.73 0.00 0.00 0.00 25,600.00 89.49 192.41 6,168.71 -11,569.30 -15,171.34 18,213.33 0.00 0.00 0.00 25,636.09 89.49 192.41 6,169.03 -11,604.55 -15,179.10 18,232.67 0.00 0.00 0.00 121112018 9:29:09AM Page 10 COMPASS 5000.14 Build 85D ConocoPhillips Database: OAKEDMPI 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: 210-39 Survey Calculation Method: Wellbore: Plan: 2M-39 Design: 2M-39wpl5 Design Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/S +E/ -W Northing -Shape V) V) (usft) (usft) (usft) (usft) 2M-39 T03 020818 JM 0.00 0.00 6,068.09 4,241.15 -13,570.08 - plan hits target center - Circle (radius 100.00) 2M-39 T01 Heel 020818 0.00 0.00 6,072.70 -3,206.71 -13,370.76 - plan hits target center - Circle (radius 1,320.00) 2M-39 T04 020818 JM 0.00 0.00 6,078.73 -4,925.46 -13,719.97 - plan hits target center - Circle (radius 100.00) 2M-39 T05020818 JM 0.00 0.00 6,082.98 -5,947.94 -13,943.30 - plan hits target center - Circle (radius 100.00) 2M-39 702020818 JM 0.00 0.00 6,093.62 -3,877.61 -13,492.71 - plan misses target center by 8.57usft at 17722.82usft MD (6085.79 TVD, -3876.21 N, -13495.89 E) - Circle (radius 100.00) 2M-39 TO6 020818 JM 0.00 0.00 6,117.02 -6,566.22 -14,078.30 - plan hits target center - Circle (radius 100.00) 2M-39 T07 020818 JM 0.00 0.00 6,121.27 -7,151.49 -14,206.34 - plan hits target center - Circle (radius 100.00) 2M-39 T10020818 JM 0.00 0.00 6,131.91 -8,853.28 -14,578.57 - plan hits target center - Circle (radius 100.00) 2M-39 T09020818 JM 0.00 0.00 6,136.16 -8,157.95 -14,425.71 - plan hits target center - Circle (radius 100.00) 2M-39 T08020818 JM 0.00 0.00 6,144.67 -7,794.79 -14,346.30 - plan hits target center - Circle (radius 100.00) 2M-39 T11 013018 JM 0.00 0.00 6,162.65 -9,864.74 -14,798.93 - plan hits target center - Circle (radius 100.00) 210-39 T14013018 JM 0.00 0.00 6,164.78 -11,126.32 -15,073.87 - plan hits target center - Circle (radius 100.00) 2M-39 T13013018 JM 0.00 0.00 6,164.78 -10,689.12 -14,978.59 - plan hits target center - Circle (radius 100.00) 210-39 T15 Toe 013018, 0.00 0.00 6,169.03 -11,604.55 -15,179.10 - plan hits target center - Circle (radius 1,320.00) 2M-39 T12013018 JM 0.00 0.00 6,179.67 -10,317.95 -14,898.19 - plan hits target center - Circle (radius 100.00) ConocoPhillips Standard Proposal Report Well Plan: 2M-39 As Built: 39 + 100.7 (03 139.70usft (Doyon142) As Built: 39 + 100.7 Q 139.70usft (Doyon142) True Minimum Curvature Easting (usft) Latitude Longitude 12111/2018 9: 29.09AM Page 11 COMPASS 5000.14 Build 85D V--1 ConocoPhillips ConocoPhillips Standard Proposal Report Database: OAKEDMP7 Local Co-ordinate Reference: Well Plan: 2M-39 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: As Built: 39+ 100.7 aQ 139.70usft Dip Direction (usft) (usft) (Doyon142) Project: Kuparuk River Unit 452.70 MD Reference: As Built: 39+ 100.7 ® 139.70usft 581.96 581.70 K-15 0.00 (Doyon142) Site: Kuparuk 2M Pad 0.00 North Reference: True Well: Plan: 2M-39 2,813.59 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-39 2,978.70 Camp SS 0.00 Design: 2M-39wpl5 C-50 0.00 10,808.18 Casing Points C-37/Iceberg 0.00 13,971.25 5,385.70 C-35 Measured Vertical 15,774.21 5,812.70 Casing Hole 0.00 Depth Depth 5,973.70 K-1 Diameter Diameter 16,710.62 (usft) (usft) BHRZ/rKLB Name (in) (in) 6,072.70 2,860.65 2,640.00 13-3/8 x 16 13.375 16.000 15,721.70 5,800.00 9-5/8 x 12-1/4 9.625 12.250 17,038.55 6,072.70 7"x8-1 /2 by 9-7/8" 7.000 9.875 25,636.09 6,169.03 4-1/2x6-1/8 4.500 6.125 Formations Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1 (1) 452.74 452.70 T-3 0.00 581.96 581.70 K-15 0.00 1,501.27 1,479.70 Base Perm 0.00 2,083.16 2,013.70 W Bak D 0.00 2,813.59 2,605.70 Base WS 0.00 3,431.85 2,978.70 Camp SS 0.00 8,597.13 4,177.70 C-50 0.00 10,808.18 4,674.70 C-37/Iceberg 0.00 13,971.25 5,385.70 C-35 0.00 15,774.21 5,812.70 THRZ 0.00 16,526.70 5,973.70 K-1 0.00 16,710.62 6,009.70 BHRZ/rKLB 0.00 • 17,038.55 6,072.70 Top Kup 0.00 12/1112018 9:29:09AM Page 12 COMPASS 5000.14 Build 86D Plan Annotagons Measured Vertical ConocoPhillips ConocoPhillips Depth Depth Standard Proposal Report Database: OAKEDMPI Local Co-ordinate Reference: Well Plan: 2M-39 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: As Built: 39+ 100.7 @ 139.70usft Comment 39.00 (Doyon142) Project: Kuparuk River Unit MD Reference: As Built: 39+ 100.7 @ 139.70usft 300.00 300.00 (Doyon142) Site: Kupamk 2M Pad North Reference: True Well: Plan: 210-39 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2M-39 1,448.76 1,430.00 Design: 2M-39wpi5 -153.64 Start 2°/100' DLS, -27" TF, for 1306.24' Plan Annotagons Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 39.00 39.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 305° TF, for 700' 300.00 300.00 0.00 0.00 Start Tit 00' DLS, -30' TF, for 448.76' 1,000.00 996.09 36.69 -52.39 Hold for 105.64' 1,448.76 1,430.00 86.17 -153.64 Start 2°/100' DLS, -27" TF, for 1306.24' 1,554.41 1,530.00 98.37 -185.44 Hold for 20' 2,860.65 2,640.00 208.54 -843.22 Start 3.91 °/100' DLS, -22.68° TF, for 900' 2,880.65 2,654.47 209.55 -856.99 Hold for 10900' 3,780.65 3,095.05 162.05 -1,624.17 Start 4°/100' DLS, -96.66° TF, for 1640.17' 14,680.65 5,545.16 -1,499.45 -12,114.46 Hold for 433.68' 16,320.82 5,933.40 -2,519.75 -13,217.67 Start 4°/100'DLS, -85.42°TF, for 84.05' 16,754.50 6,018.29 -2,932.91 -13,318.50 Hold for 200' 16,838.55 6,034.54 -3,013.55 -13,335.66 Start 3°/100' DLS, 1.66° TF, for 555.62' 17,038.55 6,072.70 -3,206.71 -13,370.76 Hold for 165.79' 17,594.17 6,098.48 -3,750.44 -13,471.95 Start 2°1100' DLS, 166.41` TF, for 335.94' 17,759.96 6,082.13 -3,912.51 -13,502.81 Adjust TF to 177.04", for 1.61' 18,095.90 6,068.09 -4,241.15 -13,570.08 Hold for 631.97' 18,097.50 6,068.11 -4,242.72 -13,570.42 Start 1°/100-DLS,-2.96` TF, for 67.05' 18,729.47 6,078.07 -4,859.97 -13,705.64 Hold for 1046.59' 16,796.52 6,078.73 -4,925.46 -13,719.97 Start 2°/100' DLS, -179.84' TF, for 207.34' 19,843.11 6,082.98 -5,947.94 -13,943.30 Hold for 227.95' 20,050.45 6,091.32 -6,150.30 -13,987.48 Start 21100' DLS, 0.45° TF, for 198.66' 20,278.39 6,108.73 -6,372.35 -14,035.94 Hold for 599.13' 20,477.05 6,117.02 -6,566.22 -14,078.30 Start 2°/100' DLS, -177.82" TF, for 126.17' 21,076.18 6,121.27 -7,151.49 -14,206.34 Hold for 239.75' 21,202.35 6,124.94 -7,274.70 -14,233.19 Start 1'/100' DLS, 1.75' TF, for 292.93' 21,442.09 6,137.19 -7,508.69 -14,283.97 Adjust TF to -0.36°, for 216.64' 21,735.03 6,144.67 -7,794.79 -14,346.30 Hold for 63.93' 21,951.66 6,140.58 -8,006.38 -14,392.54 Start 2°/100' DLS, 177.52° TF, for 91.3' 22,015.60 6,138.16 -8,068.80 -14,406.17 Adjust TF to 17.7°, for 0.23' 22,107.13 6,136.16 -8,158.18 -14,425.75 Hold for 693.53' 22,800.65 6,131.97 -8,835.51 -14,574.69 Start 2.1100' DLS, -162.3° TF, for 18.18' 22,818.84 6,131.91 -8,853.28 -14,578.57 Adjust TF to -179.98°, for 88.72' 22,907.56 6,133.28 -8,939.95 -14,597.46 Hold for 930.32' 23,837.88 6,162.09 -9,848.51 -14,795.38 Start 2°/100' DLS, 168.86° TF, for 16.62' 23,854.50 6,162.65 -9,864.74 -14,798.93 Adjust TF to 176.39°, for 16.15' 23,870.64 6,163.29 -9,880.50 -14,802.38 Hold for 326.76' 24,197.41 6,177.10 -10,199.39 -14,872.34 Start 2.1100' DLS, -3.61 ° TF, for 121.38' 24,318.79 6,179.67 -10,317.95 -14,898.19 Start 2.5°/100' DLS, -0.36° TF, for 145.54' 24,464.33 6,175.05 -10,460.10 -14,928.95 Hold for 89.03' 24,553.36 6,169.40 -10,546.94 -14,947.72 Start 2.5'/100'DLS, 178.47* TF, for 145.59' 24,698.94 6,164.78 -10,689.12 -14,978.59 Hold for 447.47' 25,146.41 6,164.78 -11,126.32 -15,073.87 Start 2°1100' DLS, 167.16* TF, for 26.23' 25,172.64 6,164.90 -11,151.95 -15,079.49 Hold far 463.45' 25,636.09 6,169.03 -11,604.55 -15,179.10 TD: 25636.09'MD, 6169.03'TVD 1211112018 9,29:09AM Page 13 COMPASS 5000.14 Build 85D ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-39 Plan: 2M-39 50103xxxxx00 2M-39wp15 ConocoPhillips Clearance Summary Anticollision Report 11 December, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad -Plan: 2M-39 -Plan: 2M-39 - 2M-39wp15 Well Coordinates: Datum Height: As Built: 39+100.7@ 139.70usft(Doyon142) Scan Range: 0.00 to 25,636.09 usft. Measured Depth. Scan Radius is 2,759.71 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85D Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: ConocoPhillips ConocoPhillips Anticollision Report for Plan: 2M-39 - 2M-39wp15 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M.39 - Plan: 211139 - 2M39wp15 Scan Range: 0.00 to 26,636.09 usft Measured Depth. Scan Radius is 2,769.71 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 Kuparuk 2M Pad - 2M -01 -2M -01-2M-01 1,313.56 89.12 1,313.56 56.96 1,300.00 2.771 Centre Distance Pass - Major Risk 2M -01 -2M -01-2M-01 2,132.30 101.42 2,132.30 46.00 2,100.00 1.830 Clearance Factor Pass - Major Risk 2M -02 -2M -02-2M-02 497.53 95.09 497.53 83.57 500.00 8.254 Centre Distance Pass - Major Risk 2M -02 -2M -02-2M-02 598.87 95.26 598.87 81.21 600.00 6.78D Clearance Factor Pass - Major Risk 2M -03 -2M -03-2M-03 808.68 149.29 808.68 130.50 800.00 7.945 Centre Distance Pass - Major Risk 2M -03 -2M -03-2M-03 3,555.20 207.47 3,555.20 100.32 3,400.00 1.936 Clearance Factor Pass - Major Risk 2M -04 -2M -04-2M-04 193.70 80.29 193.70 76.31 200.00 20.154 Centre Distance Pass - Major Risk 2M-04 - 2M-04 - 210-04 395.11 82.20 395.11 73.18 400.00 9.116 Clearance Factor Pass - Major Risk 2M -05-2M-05.210-05 896.30 32.80 896.30 11.12 900.00 1.513 Clearance Factor Pass - Major Risk 210-06 - 2M-06 - 2M-06 596.55 43.48 596.55 29.57 600.00 3.125 Centre Distance Pass - Major Risk 2M-06 - 2M-06 - 2M-06 697.03 43.53 697.03 27.10 700.00 2.650 Clearance Factor Pass - Major Risk 2M-07 - 2M-07 - 2M-07 595.18 29.63 595.18 15.68 600.00 2.124 Clearance Factor Pass - Major Risk 2M-08 - 2M-08 - 2M-08 192.70 20.02 192.70 16.05 200.00 5.043 Centre Distance Pass - Major Risk 2M -06 -2M -08-210-O8 292.66 20,35 292.68 13.67 300.00 3.142 Clearance Factor Pass -Major Risk 2M -08 -2M -0811-2M-081-1 192.70 20.02 192.70 16.35 200.00 5.459 Centre Distance Pass - Major Risk 2M -08 -2M -081-1-2M-081-1 292.68 20.35 292.68 14.17 300.00 3.296 Clearance Factor Pass - Major Risk _ 2M-08 - 2M-0811-01 - 210-081-1-01 192.70 20.02 192.70 16.35 200.00 5.459 Centre Distance Pass - Major Risk 2M -08-210-081-1-01-2M-0811-01 292.68 20.35 292.68 14.17 300.00 3.296 Clearance Factor Pass - Major Risk 2M -09-2M-09-210-09 r193.70 5.54 193.70 1.61 200.00 1.408 Centre Distance Pass -Major Risk 2M -09 -2M -09-2M-09 ? - 2M-09 - 2M -09A - 210-09A - 193.70 5.54 193.70 1.82 200.00 1.489 Centre Distance Pass - Major Risk 2M-09 - 2M -09A - 2M -09A 2M -10 -2M -10-2M-10 191.70 10.02 191.70 6.35 200.00 2.727 Centre Distance Pass - Major Risk 2M -10 -2M -10-2M-10 391.43 12.75 391.43 4.06 400.00 1.468 Clearance Factor Pass -Major Risk 2M-11 - 210-11 - 2M-11 191.70 34.84 191.70 31.17 200.00 9.479 Centre Distance Pass - Major Risk 2M -11 -2M -11-2M-11 391.01 36.04 391.01 27.42 400.00 4.178 Clearance Factor Pass -Major Risk 2M -12 -2M -12-2M-12 292.70 59.09 292.70 52.67 300.00 9.201 Centre Distance Pass - Major Risk 2M -12-210-12-2M-12 391.55 59.72 391.55 50.82 400.00 6.705 Clearance Factor Pass - Major Risk 11 December, 2018 - 10:43 Page 2 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: 2M-39 - 2M-39wp15 7ray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Pian: 2M -39 -Plan: 2M-39. 2M-39wp15 Scan Range: 0.00 to 26,636.09 usft. Measured Depth. Scan Radius is 2,759.71 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit 11 December, 2018 - 10.43 Page 3 of 7 COMPASS 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 -13 -2M -13-2M-13 191.70 149.98 191.70 146.30 200.00 40.799 Centre Distance Pass - Major Risk 2M -13 -2M -13-2M-13 388.77 152.84 388.77 144.21 400.00 17.712 Clearance Factor Pass - Major Risk 2M -14 -2M -14-2M-14 293.69 173.46 293.69 166.98 300.00 26.796 Centre Distance Pass - Major Risk 2M -14 -2M -14-2M-14 390.25 173.89 390.25 164.97 400.00 19.497 Clearance Factor Pass - Major Risk 2M -15 -2M -15-2M-15 191.70 199.40 191.70 195.46 200.00 50.594 Centre Distance Pass - Major Risk 2M -15 -2M -15-2M-15 387.92 200.66 387.92 191.96 400.00 22.573 Clearance Factor Pass - Major Risk 2M -16 -2M -16-2M-16 198.70 224.65 198.70 221.05 200.00 59.179 Centre Distance Pass - Major Risk 2M -16 -2M -16-2M-16 394.12 227.38 394.12 218.62 400.00 25.948 Clearance Factor Pass - Major Risk 2M -27 -2M -27-2M-27 905.28 97.02 905.28 75.26 900.00 4.458 Centre Distance Pass - Major Risk 2M -27 -2M -27-2M-27 1,005.51 97.74 1,005.51 73.38 1,000.00 4.012 Clearance Factor Pass - Major Risk 2M -28 -2M -28-2M-28 907.70 116.71 907.70 95.12 900.00 5.405 Clearance Factor Pass - Major Risk 2M -29 -2M -29-2M-29 604.69 177.55 604.69 163.24 600.00 12.405 Clearance Factor Pass - Major Risk 2M -30 -2M -30-2M-30 193.70 195.38 193.70 191.42 200.00 49.285 Centre Distance Pass - Major Risk 2M -30 -2M -30-2M-30 397.76 197.50 397.76 188.53 400.00 22.029 Clearance Factor Pass - Major Risk 2M-31 - 2M-31 -2M-31 192.70 186.66 192.70 163.65 200.00 62.087 Centre Distance Pass - Major Risk 2M-31 - 2M-31 - 21VI-31 389.11 188.35 369.11 182.40 400.00 31.624 Clearance Factor Pass - Major Risk 2M -02 -2M -32-2M-32 193.68 227.58 193.68 224.26 200.00 68.666 Centre Distance Pass - Major Risk 2M-32 - 2M-32 - 2M-32 293.66 229.27 293.66 224.26 300.00 45.764 Clearance Factor Pass - Major Risk 2M -32 -2M -32L7 -2M-321-1 193.68 227.58 193.66 224.56 200.00 75.553 Centre Distance Pass - Major Risk 2M -32 -2M -32L7 -2M-321-1 293.66 229.27 293.66 224.56 300.00 48.700 Clearance Factor Pass - Major Risk 2M -32 -2M -321-1-01-2M-3211-01 193.68 227.58 193.68 224.56 200.00 75.553 Centre Distance Pass - Major Risk 2M -32 -2M -32L1 -01-2M-321-1-01 293.66 229.27 293.66 224.56 300.00 48.700 Clearance Factor Pass - Major Risk 2M-32-2M-32L1PB1-2M-32L1PBi 193.68 227.58 193.68 224.45 200.00 72.905 Centre Distance Pass -Major Risk 2M-32-2M-32L1PBi-2M-32L1PB1 293.66 229.27 293.66 224.45 300.00 47.594 Clearance Factor Pass -Major Risk 2M -32 -2M -32L1 PB2-2M-32L1 PB2 193.68 227.58 193.68 224.00 200.00 63.571 Centre Distance Pass - Major Risk 2M -32 -2M -32L1 PB2-2M-3211 PB2 293.66 229.27 293.66 223.99 300.00 43.459 Clearance Factor Pass - Major Risk 2M -33 -2M -33-2M-33 853.57 206.13 853.57 190.13 900.00 12.862 Centre Distance Pass - Major Risk 2M -33 -2M -33-2M-33 944.45 206.40 944.45 187.94 1,000.00 11.18D Clearance Factor Pass - Major Risk 2M -36 -2M -36-2M-36 1,325.74 93.15 1,325.74 71.43 1,300.00 4.289 Centre Distance Pass - Major Risk 2M -36 -2M -36-2M-36 1,425.38 93.52 1,425.38 70.57 1,400.00 4.075 Clearance Factor Pass - Major Risk 11 December, 2018 - 10.43 Page 3 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: 2M-39 - 2M-39wp15 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M39 - Plan: 2M39-2M39wp15 Scan Range: 0.00 to 25,636.09 usft. Measured Depth. Scan Radius is 2,759.71 usft. Clearance Factor cutoff Is Unlimited. Max Ellipse Separation is Unlimited Site Name Comparison Well Name - Wellbore Name - Design 2M-36-2M-36PB1-2M-36PBi 2M-36 - 2M-36PB1 - 2M-36PBI 2M37 -2M -37-2M-37 2M-38 - 2M-38 - 210-38 2M38 -2M -38-2M-38 Plan: 2M-40 - Plan: 2M-40 - 2M40wp12 Plan: 2M40 - Plan: 2M40 - 2M-40wpi2 Kuparuk 2S Pad 2S-14 - 25-14.25-14 Survey foo/ program ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum Separation Warning (usft) (usft) (usft) (usft) usft 4,360.65 2M-39wp15 MWD 1,325.74 93.15 1,325.74 71.30 1,300.00 4.263 Centre Distance Pass - Major Risk 1,425.38 93.52 1,425.38 70.44 1,400.00 4.052 Clearance Factor Pass - Major Risk 1,473.95 232.18 1,473.95 208.5D 1,400.00 9.807 Clearance Factor Pass - Major Risk 15,486.69 370.85 15,486.69 160.82 16,200.00 1.766 Centre Distance Pass - Major Risk 15,585.70 420.64 15,585.70 132.46 16,400.00 1.460 Clearance Factor Pass - Major Risk 1,208.46 49.93 1,206.46 29.00 1,200.00 2.386 Centre Distance Pass - Major Risk 1,308.57 50.98 1,308.57 28.14 1,300.00 2.232 Clearance Factor Pass - Major Risk 25,633.29 1,917.35 25,633.29 1,611.99 17,900.00 6.279 Clearance Factor From To Survey/Plan Survey Tool (usft) (usft) 39.00 1,300.00 2M-39wp15 GYD-GC-SS 1,300.00 2,300.00 2M-39wp15 MWD 1,300.00 2,660.65 2M-39wp15 MWD+IFR-AK-CAZ-SC 2,860.65 4,360.65 2M-39wp15 MWD 2,860.65 15,721.70 2M-39wp15 MWD+IFR-AK-CAZ-SC 15,721.70 16,875.OD 2M-39WP15 MWD 15,721.70 17,038.55 2M-39wp15 MWD+IFR-AK-CAZ-SC 17,038.55 18,375.00 2M-39wp15 MWD 17,038.55 25,636.09 2M-39Wp15 MWD+IFR-AK-CAZ-SC Pass - Major Risk 11 December, 2018 - 10..43 Page 4 of 7 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-39 Plan: 2M-39 50103xxxxx00 2M-39wp15 ConocoPhillips Clearance Summary Anticollision Report 11 December, 2018 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad -Plan: 2M-39 -Plan: 2M-39 - 2M-39wp15 Well Coordinates: Datum Height: As Built: 39+100.7 @ 139.70usft (Doyon142) Scan Range: 0.00 to 25,636.09 ash. Measured Depth. Scan Radius is 2,759.71 ash. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 5000.14 Build: 85D Scan Type: • • - Scan Type: 25.00 ConocoPhillips V-� ConocoPhillips 1,313.56 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan: 2M-39 - 2M-39wp15 56.96 1,300.00 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Centre Distance Pass - Major Risk Reference Design: Kuparuk 2M Pad - Plan: 2M-39 - Plan: 21049.2M-39wp1S 2,183.56 102.17 Scan Range: 0.00 to 26,636.09 usfL Measured Depth. 45.66 2,150.00 Scan Radius is 2,769.71 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Clearance Factor Pass - Major Risk 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) just) (usft) usft Pass - Major Risk Kuparuk 2M Pad 210-01-210-01-2M-01 1,313.56 89.12 1,313.56 56.96 1,300.00 2.771 Centre Distance Pass - Major Risk 210-01-210-01-210-01 2,183.56 102.17 2,183.56 45.66 2,150.00 1.808 Clearance Factor Pass - Major Risk 2M-02-210-02-210-02 548.30 94.75 548.30 81.96 550.00 7.410 Centre Distance Pass - Major Risk 2M-02-210-02-210-02 624.06 95.84 624.06 81.15 625.00 6.527 Clearance Factor Pass - Major Risk 210-03-210-03-210-03 808.68 149.29 808.68 130.50 800.00 7.945 Centre Distance Pass - Major Risk 210-03-210-03-2M-03 3,555.20 207.47 3,555.20 100.32 3,400.00 1.936 Clearance Factor Pass - Major Risk 2M -04 -2M -04-2M-04 193.70 80.29 193.70 76.31 200.00 20.154 Centre Distance Pass - Major Risk 2M -04 -2M -04-2M-04 369.77 81.53 369.77 73.15 375.00 9.719 Clearance Factor Pass - Major Risk 2M -05 -2M -05-2M-05 896.30 32.60 896.30 11.12 900.00 1.513 Centre Distance Pass - Major Risk 2M -05 -2M -05-2M-05 920.95 32.88 920.95 10.56 925.00 1.473 Clearance Factor Pass - Major Risk 2M -O6 -210-06-2M-06 646.65 42.92 646.85 27.75 650.00 2.829 Centre Distance Pass - Major Risk 2M -DS -2M -06 -2M -O6 697.03 43.53 697.03 27.10 700.00 2.650 Clearance Factor Pass - Major Risk 2M -07 -2M -07-2M-07 595.18 29.63 595.18 15.68 600.00 2.124 Centre Distance Pass - Major Risk 2M -07-210-07-2M-07 620.01 30.11 620.01 15.54 625.00 2.067 Clearance Factor Pass - Major Risk 2M -08 -2M -08-2M-08 242.69 19.93 242.69 14.71 250.00 3.820 Centre Distance Pass - Major Risk 2M -08 -2M -08-2M-08 317.73 20.87 317.73 13.77 325.00 2.939 Clearance Factor Pass - Major Risk 2M -08 -2M -0811-2M-0811 242.69 19.93 242.69 15.02 250.00 4.054 Centre Distance Pass - Major Risk 210-08-2M-0811-210-0811 317.73 20.87 317.73 14.07 325.00 3.070 Clearance Factor Pass - Major Risk 2M-08-210-0811-01-210-081-1-01 242.69 19.93 242.69 15.02 250.00 4.054 Centre Distance Pass - Major Risk 2M -08 -2M -08L1 -D1-210-081-1-01 317.73 20.87 317.73 14.07 325.00 3.070 Clearance Factor Pass - Major Risk 210 -09 -2M -09-2M-09 118.70 5.27 118.70 2.88 125.00 2.207 Centre Distance Pass - Major Risk 2M -09 -2M -09-2M-09 iiiiiiiiiiiiilimi- 2M-09-2M-09A-2M-09A 118.70 5.27 118.70 3.09 125.00 2.423 Centre Distance Pass - Major Risk 2M-09 - 2M -09A - 2M -09A - 2M-10-210-10-210-10 116.70 9.65 116.70 7.30 125.00 4.101 Centre Distance Pass - Major Risk 210-10-2M-10-210-10 366.52 12.D0 366.52 3.94 375.00 1.488 Clearance Factor Pass - Major Risk 2M -11 -2M -11-2M-11 116.70 34.65 116.70 32.30 125.00 14.729 Centre Distance Pass - Major Risk 2M-11 - 2M-11 - 2M-11 415.81 36.61 415.81 27.37 425.00 3.963 Clearance Factor Pass- Major Risk 11 December, 2018 - 10:44 Page 2 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: 2M-39 - 2M-39wp15 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M-39 - Plan: 2M-39 - 2M-39wp15 Scan Range: 0.00 to 25,636.09 usft Measured Depth. Scan Radius is 2,759.71 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit 11 December, 2018 - 10:44 Page 3 of 7 COMPASS 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 -12 -2M -12-2M-12 317.48 59.06 317.48 52.02 325.00 8.382 Centre Distance Pass - Major Risk 2M -12 -2M -12-2M-12 440.90 60.80 440.90 50.65 450.00 5.992 Clearance Factor Pass - Major Risk 2M.13 -2M -13-2M-13 116.70 149.61 116.70 147.25 125.00 63.574 Centre Distance Pass - Major Risk 2M -13 -2M -13-2M-13 340.38 151.41 340.36 144.00 350.00 20.432 Clearance Factor Pass - Major Risk 2M -14 -2M -14-2M-14 342.12 173.32 342.12 165.62 350.00 22.507 Centre Distance Pass - Major Risk 2M -14 -2M -14-2M-14 390.25 173.89 390.25 164.97 400.00 19.497 Clearance Factor Pass - Major Risk 2M -15 -2M -15-2M-15 116.70 199.27 116.70 196.65 125.00 76.106 Centre Distance Pass - Major Risk 2M -15 -2M -15-2M-15 387.92 200.86 367.92 191.96 400.00 22.573 Clearance Factor Pass - Major Risk 2M -16 -2M -16-2M-16 123.70 224.42 123.70 221.94 125.00 90.613 Centre Distance Pass - Major Risk 2M -16 -2M -16-2M-16 370.29 226.74 370.29 218.58 375.00 27.805 Clearance Factor Pass - Major Risk 2M -27 -2M -27-2M-27 955.41 96.50 955.41 73.44 950.00 4.184 Centre Distance Pass - Major Risk 2M -27 -2M -27-2M-27 980.43 96.90 980.43 73.19 975.00 4.087 Clearance Factor Pass - Major Risk 2M -28 -2M -28-2M-28 656.98 116.27 856.96 95.94 850.00 5.717 Centre Distance Pass - Major Risk 2M -28 -2M -28-2M-28 933.03 117.25 933.03 95.03 925.00 5.276 Clearance Factor Pass - Major Risk 2M -29 -2M -29-2M-29 553.04 177.04 553.04 164.00 550.00 13.578 Centre Distance Pass - Major Risk 2M -29 -2M -29-2M-29 604.69 177.55 604.69 163.24 600.00 12.405 Clearance Factor Pass - Major Risk 2M -30 -2M -30.2M-30 193.70 195.38 193.70 191.42 200.00 49.285 Centre Distance Pass - Major Risk 2M -30 -2M -30.2M-30 371.69 196.74 371.69 188.40 375.00 23.610 Clearance Factor Pass - Major Risk 2M -31 -2M -31-2M-31 117.70 166.52 117.70 184.51 125.00 92.690 Centre Distance Pass - Major Risk 2M -31 -2M -31-2M-31 341.06 167.40 341.06 182.16 350.00 35.788 Clearance Factor Pass - Major Risk 2M -32 -2M -32-2M-32 118.69 226.75 118.69 224.57 125.00 104.326 Centre Distance Pass - Major Risk 2M -32 -2M -32-2M-32 243.68 228.12 243.68 223.97 250.00 54.932 Clearance Factor Pass - Major Risk 2M -32 -2M -321-1-2M-321-1 116.69 226.75 118.69 224.88 125.00 121.169 Centre Distance Pass - Major Risk 2M -32 -2M -3211-2M-3211 243.68 228.12 243.66 224.27 250.00 59.241 Clearance Factor Pass - Major Risk 2M -32 -2M -321-1-01-2M-3211-01 118.69 226.75 118.69 224.88 125.00 121.169 Centre Distance Pass - Major Risk 2M -32 -2M -321-1-01-2M-321-1-01 243.68 228.12 243.66 224.27 250.00 59.241 Clearance Factor Pass - Major Risk 2M -32-2M-321-1 P81 -2M-321-1 PB1 116.69 226.75 118.69 224.77 125.00 114.478 Centre Distance Pass - Major Risk 2M -32-2M-3211 PB1 -2M-32Li PB1 243.68 228.12 243.66 224.16 250.00 57.605 Clearance Factor Pass - Major Risk 2M -32-2M-3211 PB2 -2M-32Li PB2 116.69 226.75 118.69 224.31 125.00 92.966 Centre Distance Pass - Major Risk 2M -32-2M-321-1 P82 -2M-321-1 PB2 243.68 228.12 243.68 223.97 250.00 54.932 Clearance Factor Pass - Major Risk 11 December, 2018 - 10:44 Page 3 of 7 COMPASS ConocoPhillips Anticollision Report for Plan: 2M-39 - 2M-39wp15 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2M Pad - Plan: 2M49 - Plan: 2M49-2M49wp15 Scan Range: 0.00 to 25,636.09 usft. Measured Depth. Scan Radius is 2,759.71 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 -33 -2M -33-2M-33 899.14 205.78 899.14 188.57 950.00 11.954 Centre Distance Pass - Major Risk 2M -33 -2M -33-2M-33 944.45 206.40 944.45 187.94 1,000.00 11.180 Clearance Factor Pass - Major Risk 2M -36 -2M -36-2M36 1,375.70 92.34 1,375.70 7D.01 1,350.00 4.135 Clearance Factor Pass - Major Risk 2M36-2M-36PB7-2M-36PB1 1,375.70 92.34 1,375.70 69.88 1,350.00 4.111 Clearance Factor Pass - Major Risk 2M -37 -2M -37-2M-37 1,423.80 231.81 1,423.80 208.73 1,350.00 10.045 Centre Distance Pass - Major Risk 2M -37 -2M -37-2M-37 1,449.81 231.82 1,449.81 208.44 1,375.00 9.917 Clearance Factor Pass - Major Risk 2M -38 -2M -38-2M-38 15,460.75 368.69 15,460.75 181.34 16,150.00 1.968 Centre Distance Pass - Major Risk 2M -38 -2M -38-2M-38 15,575.00 411.43 15,575.00 129.53 16,375.00 1.459 Clearance Factor Pass - Major Risk Plan: 2M -40 -Plan: 2M-40-2M40wpl2 1,183.40 49.92 1,183.40 29.46 1,175.00 2.441 Centre Distance Pass - Major Risk Plan: 2M40 -Plan: 2M40-2M40wp12 1,308.57 50.98 1,308.57 28.14 1,300.00 2.232 Clearance Factor Pass - Major Risk Kuparuk 2S Pad 25-14-25-14-2S-14 25,633.29 1,917.35 25,633.29 1,611.99 17,900.00 6.279 Clearance Factor Pass - Major Risk Survey too/ program From To Survey/Plan Survey Tool (usft) (usft) 39.00 1,30D.00 2M-39wp15 GVD-GC-SS 1,300.00 2,30D.00 2M-39wp15 MWD 1,300.00 2,860.65 2M-39wp15 MWD+IFR-AK-CAZ-SC 2,860.65 4,360.65 2M-39wp15 MWD 2,860.65 15,721.70 2M-39wp15 MWD+IFR-AK-CAZ-SC 15,721.70 16,875.00 2M-39wp15 MWD 15,721.70 17,038.55 2M-39wp15 MWD+IFR-AK-CAZ-SC 17,038.55 18,375.00 2M-39wpl5 MWD 17,038.55 25,636.09 2M-39wp15 MWD+IFR-AK-CAZ-SC 11 December, 2018 - 10.44 Page 4 of COMPASS 9:37December 11 2019 2M-39wp15 Ladder View m Y n m o 300 N n Cl -' j Q q, 150 U q) C U I Equivalent Magnetic Distance i 0 0 3500 7000 10500 14000 17500 21000 24500 Measured Depth SURVEY PROGRAM CASING DETAILS Depth From Depth To Survey/Plan Tool TVD MD Name 39.00 1300.00 2M-39wpl5 (Plan: 2M-39) GYD-GC-SS 2640.00 2860.65 13-3/8 x 16 1300.00 2300.00 2M-39wpl5 (Plan: 2M-39) MWD 5800.0015721.70 9-5/8 x 12-1/4 1300.00 2860.65 2M-39wpl5 (Plan: 2M-39) MWD+IFR-AK-CAZ-SC 6072.7017038.55 x 8-1/2 by 9-7/8" 2860.65 4360.65 2M-39wp15 (Plan: 2M-39) MWD 6169.0325636.09 4-1/2 x 6-1/8 2860.6515721.70 2M-39wpl5 (Plan: 2M-39) MWD+IFR-AK-CAZ-SC 15721.7016875.00 2M-39wpl5 (Plan: 2M-39) MWD 1MWD+IFR-AK-GAZ-SC 17038.5518375.00 2M-39wpl5 (Plan: 2M-39) MWD 17038.5525636.09 2M-39wp15 (Plan: 2M-39) MWD+IFR-AK-CAZ-SC 60- 9 c 0 77 `m a U) U a 30- 0 0 o m m v c d U o Equivalent Magnetic Distance 0 0 450 900 1350 1800 2250 Partial Measured Depth 9:41 December H 2018 2M-39wp15 TC View SURVEY PROGRAM SECTION DETAILS From To Tool MD Inc Azi TVD Dleg TFace Target Annotation 39.6§00.00 GYD-GC-SS 39.00 0.00 0.00 39.00 0.00 0.00 KOP: Start 1.5'/100' DLS, 305' TF, for 700' 1300.00 2300.00 MWD 300.00 0.00 0.00 300.00 0.00 0.00 Start 2°/100' DLS, -30" TF, for 448.76' 1300.00 2860.65 MWD+IFR-AK-CAZ-SC 1000.00 10.50 305.00 996.09 1.50 305.00 Hold for 105.64' 2860.65 4360.65 MWD 1448.76 18.81 291.00 1430.00 2.00 -30.00 Start 2°/100' DLS, -27" TF, for 1306.24' 2860.695721.70 MWD+IFR-AK-CAZ-SC 1554.41 18.81 291.00 1530.00 0.00 0.00 Hold for 20' 15721.706875.00 MWD 2860.65 43.67 274.17 2640.00 2.00 -27.00 Start 3.91°/100' DLS, -22.68° TF, for 900' 15721.707038.55 MWD+IFR-AK-CAZ-SC 2880.65 43.67 274.17 2654.47 0.00 0.00 Hold for 10900' 17038.55 8375.00 MWD 3780.65 77.01 261.00 3095.05 3.91 -22.68 Stan 4°/100' DLS, -96.66° TF, for 1640.17' 17038.5525636.09 MWD+IFR-AK-CAZ-SC 14680.65 77.01 261.00 5545.16 0.00 0.00 Hold for 433.68' 16320.82 78.71 193.72 5933.40 4.00 -96.66 Stan 4'/100' DLS, -85.42' TF, for 84.05' 16754.50 78.71 193.72 6018.29 0.00 0.00 Hold for 200' 16838.55 79.00 190.30 6034.54 4.00 -85.42 Stan 3'/100' DLS, 1.66° TF, for 555.62' 17038.55 79.00 190.30 6072.70 0.00 0.00 2M-39 T01 Heel 020818 JBbld for 165.79 17594.17 95.66 190.78 6098.48 3.00 1.66 Start 2°/100' DLS, 166.41' TF, for 335.94' 17759.96 95.66 190.78 6082.13 0.00 0.00 Adjust TF to 177.04', for 1.61' 18095.90 89.13 192.35 6068.09 2.00 166.41 2M-39 T03 020818 JM Hold for 631.97' 18097.50 89.10 192.36 6068.11 2.00 177.04 Stan 1"/100' OLS, -2.96° TF, for 67.05' 18729.47 89.10 192.36 6078.07 0.00 0.00 Hold for 1046.59' CASING DETAILS 18796.52 89.77 192.32 6078.73 1.00 -2.96 2M-39 T04 020818 JM Start 21100' DLS, -179.84' TF, for 207.34' 19843.11 89.77 192.32 6082.98 0.00 0.00 2M39 T05 020818 JM Hold for 227.95' TVD MD Name 20050.44 85.62 192.31 6091.32 2.00 -179.84 Start 2°/100' DLS, 0.45° TF, for 198.66' 2640.002860.65 13-3/8 x 16 20278.39 85.62 192.31 6108.73 0.00 0.00 Hold for 599.13' 5800.005721.70 9-5/8 x 12-1/4 20477.05 89.59 192.34 6117.02 2.00 0.45 2M-39 T06 020818 JM Stan 2.1100' DLS, -177.82° TF, for 126.17' 6072.707038.95x 8-12 by 9-7/8" 21076.18 89.59 192.34 6121.27 0.00 0.00 2M-39 T07 020818 JM Hold for 239.76 6169.035636.09 4-12 x 6-1/8 21202.34 87.07 192.24 6124.94 2.00 -177.82 Stan 1'M W DLS, 1.75" TF, for 292.93' 21442.09 87.07 192.24 6137.19 0.00 0.00 Adjust TF to -0.36°, for 216.64' 21735.02 90.00 192.33 6144.67 1.00 1.75 2M39 T08 020618 JM Hold for 63.93 21951.66 92.17 192.32 6140.58 1.00 -0.36 Start 2°/100' DLS, 177.52° TF, for 91.3' 22015.60 92.17 192.32 6138.16 0.00 0.00 Adjust TF to 17.7°, for 0.23 22106.90 90.34 192.40 6136.16 2.00 177.52 2M39 T09 020818 JM Hold for 693.53' 22107.13 90.35 192.40 6136.16 2.00 17.70 Hold for 693.53' 22800.65 90.35 192.40 6131.96 0.00 0.00 Start 2°/100' DLS, -162.3" TF, for 18.18' 22818.84 90.00 192.29 6131.91 2.00 -162.30 210-39 T10 020818 JM Adjust TF to -179.98°, for 88.72' 22907.56 88.23 192.29 6133.28 2.00 -179.98 Hold for 930.32' 23854.50 87 35 6162.65 2.00 168.86 2M-39 T71 013018 JM Adjust TF to 176.39°, or 16.16 23870.64 I�i:S 163.29 2.00 176.39 Hold for 326.76' 2 1 7700 0.00 0.00 Stan 2°/100' DLS, -3. t- TF, for 121.38' 1798? .00 -3.61 2M-39 T12 013018 JM Stan 2.5°/100' DLS, .36° TF, for 145.50' 330 50 \ -0.3 0 for 39.03 Stan 5.1100' DLS, 8.47' TF, for 145.59' / 1039 Tl3 013018 JM Hold for 447.4T e 0. 39 T14 013018 JM Start 2.1100 DLS, 1 .16* TS Jor 26.23' 300 .90 Hold for 463.45' 1 8769: .00 018 JOID: 25636.09' MD, 6 69.0910%% 490 115 490-670 670 -860 300 % 60 860 - 1040 1040- 1230 60 1230 - 1410 1410 1600 1600 -2600 1, � � F 3 `13 2600 3600 2 2w> 90 3600 - 4600 -t' 4600 - 5600 5600 6600 10 2 6600 - 7600 7600 - 8600 12 8600 9600 9600 - 11610 240 .� 120 11610 - 13610 13610 15610 2 15610 - 17620 17620 - 19620 2W* 19620 21630 150 21630 23630 'gp 23630 - 25636 --T60- ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad Plan: 2M-39 50103xxxxx00 Plan: 2M-39 Plan: 2M-39wp15 Error Ellipse Survey Report 11 December, 2018 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kupamk River Unit Site: Kupawk 2M Pad Well: Plan: 2M-39 Wellbore: Plan: 210-39 Design: 2M-39wpl5 ConocoPhillips Error Ellipse Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M-39 As Built: 39 + 100.7 @ 139.70usft (Doyon142) As Built: 39 + 100.7 @ 139.70usft (Doyonl42) True Minimum Curvature 1.00 sigma OAKEDMPI 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 She Kuparuk 2M Pad She Position: Northing: Latitude: From: Map Easting: Longitude: Postion Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: -0.10, Well Plan: 2M-39 Well Position +N/ -S 0.00 usft Northing: +E/ -W 0.00 usft Easting: Position Uncertainty 0.00 usft Wellhead Elevation: Latitude: Longitude: 0.00 usft Ground Level: 100.70 Vellbore Plan: 2M-39 lagnetics Model Name Sample Date Declination Dip Angle Field Strength (1) C) W) BGGM2018 1/20/2019 16.64 80.80 57,415 Design Audit Notes: Version: Vertical Section: 2M-39wp15 Phase: PLAN Tie On Depth: 39.00 Depth From (TVD) +NI -S +E/ -W Direction (usft) (usft) (usft) V) 39.00 0.00 0.00 250.00 Survey Tool Program Data 120=18 From To (usft) (usft) Survey(Wetlbore) Tool Name Description 39.00 1,300.00 2M-39wpi5 (Plan: 2M-39) GYD-GCSS Gyrodata gyro single shots 1,300.00 2,300.00 2M-39wpl 5 (Plan: 2M-39) MWD MWD -Standard 1,300.00 2,860.65 2M-39Wp15(Plan: 2M-39) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 2,860.65 4,360.65 2M-39wpl5(Plan: 2M-39) MWD MWD -Standard 2,860.65 15,721.70 2M-39wp15(Plan: 2M-39) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 15,721.70 16,875.00 2M-39wpl5(Plan: 2M-39) MWD MWD -Standard 15,721.70 17,038.55 2M-39wpl5(Plan: 2M-39) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 17,038.55 18,375.00 2M-39wpl5(Plan: 2M-39) MWD MWD- Standard 17,038.55 25,636.09 2M-39wp15(Plan: 2M-39) MWD+IFR-AK-CAZSC MWD+IFR AK CAZ SCC 12/11/2018 10.46.51AM Page 2 COMPASS 5000.14 Build 85D ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Project: Kupaluk River Unit TVD Reference: Site: Kupamk 2M Pad MD Reference: Well: Plan: 21JI-39 North Reference: Wellbore: Plan: 2M-39 Survey Calculation Method: Design: 2M-39wpl5 Output errors are at 2 1,300.00 Database: Plan Survey Tool Program Date 120/2018 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.00 1,300.002M-39wp15(Pian: 2M-39) GYD-GC-SS Vertical Highside Lateral Gyrodata gyro single shots 2 1,300.00 2,300.00 2M-39wpl5 (Plan: 2M-39) MWD ingr Depth MWD - Standard 3 1,300.00 2,860.65 2M-39wpl 5 (Plan: 2M-39) MWD-IFR-AK-CAZ-SC Error Blas E. MWD+IFR AK CAZ SCC 4 2,860.65 4,360.65 2M-39wp15 (Plan: 2M-39) MWD (uaft) P) MWD - Standard 5 2,860.65 15,721.70 2M-39wpl 5 (Plan: 2M-39) MWD+IFR-AK-CAZ-SC (uael Nem fuss) MWD+IFR AK CAZ SCC 6 15,721.70 16,875.00 2M-39wpl5 (Plan: 2M-39) MWD 39.00 0.00 0.00 MWD - Standard 7 15,721.70 17,038.552M-39wpl5(Plan:21VI-39) MWD+IFR-AK-CAZ-SC 0.00 0.00 0.00 MWD+IFR AK CAZ SCC 8 17,038.55 18,375.00 2M-39wpl5 (Plan: 2M-39) MWD 0.00 0.00 100.00 MWD - Standard 9 17,038.55 25,636.09 2M-39wp15 (Plan: 2M-39) MWD+IFR-AK-CAZ-SC 0.00 0.00 0.00 MWD+IFR AK CAZ SCC Well Plan: 2M-39 As Built: 39+ 100.7 @ 139.70usft (Doyon142) As Built 39 + 100.7 @ 139.70usft (Doyon142) Time Minimum Curvature 1.00 sigma OAKEDMPI Position uncertainty and bias at survey station Measured Inclination Anmmh Vertical Highside Lateral veeical MagrdtuCe Semi+nah,r Seem ingr Depth Depth E., Blas Error Blas E. alas Uaias Emr Evor Azimuth Tod (uaft) P) 19 (.aft) fuer) (urn) (--ft) (uael Nem fuss) (uen) (usn) luaft) (% 39.00 0.00 0.00 38.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 100.00 0.00 0.00 100.00 0.00 0.00 0.00 GoO 0.00 0.00 0.00 0.00 0.00 0.00 UNDEFINED 200.00 0.00 0.00 20oW 0.07 0.00 0.07 0.00 1.15 0.00 0.00 0,07 0.07 0.00 GYP-GGSS(1, 1) 300,00 0.00 0.00 300.00 0.22 0.00 0.22 OAO 1.15 0.00 0.00 0.22 0.22 0.00 GYD-GGSS (1, 1) 400.00 1.50 305.00 399.99 0.35 000 0.35 0.00 1.15 0.01 0.01 0.35 0.35 45.00 GYD-GGSS(1, 1) 500.00 3.00 305,00 499.81 0.48 0.00 0.48 0.00 1.15 0.02 0.02 0.48 0.48 45.00 GYD-GGSS (1, 1) 600.00 4.50 305.00 599.69 0.62 0,00 0.62 0.00 1.15 0.03 0.03 0.62 0.62 34.10 GYD-GGSS (1, 1) 700.00 6.00 305.00 699.27 0.76 0.00 0.77 0.00 1.15 ON 0.04 on 0.77 45.00 GYD-GGSS (1, 1) 800.00 7,50 305.00 790.57 0.90 0.00 0.92 0.00 1.15 0.m 0.06 0.92 0.92 126.32 GYD-GGSS (1, 1) 900.00 9.00 305A0 897.54 1.05 -0.01 1.08 0.00 1.15 0.08 0.08 1.08 1.07 125.67 GYD-GGSS (1, 1) 1,000.00 10.50 305.00 998.09 1.20 -0.01 1.25 0.00 1.15 0.10 oto 1.25 1.22 125.46 GYD-GGSS h. 1) 1,100.00 12.27 300.29 1094.12 1.35 -0.01 1.43 0.00 1.16 0.12 0.12 1.43 1.37 125.47 GYD-GCSS(1, 1) 1,200.00 14.11 296.77 1,191.48 1.50 -0.02 1.61 0.00 1.16 0.15 0.15 1.61 1.53 124.70 GY0. SS (1, 1) 11300.00 15.90 294.05 1.288.05 1.65 -0.02 1.01 0.00 1.16 0.18 0.18 1.81 1.66 123.15 GYD-GGSS(1, 1) 1,4110.00 17.88 291.90 1,383.71 1.73 -0.03 1.92 -0.02 1.16 0.21 0.21 1.93 1.77 121.94 MM (1, 2) 1.448]8 18.81 291.00 1430.00 1.73 -0.W 1.97 4.05 1.16 0.22 0.23 197 1.78 119.95 MM (1, 2) 12/112018 10:46:51AM Page 3 COMPASS 5000.14 Build 85D Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupawk 2M Pad Well: Plan: 2M-39 Wellbore: Plan: 2M-39 Design: 2M-39wp15 Position uncertainty and blas at survey station ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MO Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M-39 As Built: 39+ 100.7 @ 139.70usft (Doyon142) As Built: 39 + 100.7 @ 139.70usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMPI Measured Induration Avmuth Vertical Highside Lateral Verdian Magnitude Semianaim 6emlanheir Depth Depth a. Bias Error Bus Error Bias of Biu Error Eeor Adruth Tool lusm 1"I r) (usft) (Left) leery (usn) (Lam (Lae) (uanl ("'n) (edit) (use) r) 1,500.00 16.81 29100 1.47850 1.74 -0.03 205 -0.08 1.16 0.24 0.26 2.05 179 119.25 MWD(1, 2) 155441 18.81 291.00 1,53000 1.75 -0.03 2.16 -0.11 1.16 0.26 0.29 2.17 1.81 11507 MWD(1, 2) 1,800.00 19.63 209.77 1,573.05 1.76 -0.03 2.29 -0.14 1.17 0.27 0.31 2.29 1.82 113]9 MWp(1, 2) 1,700.00 21.44 287.38 1,666.70 1.80 -0.03 2.63 -0.21 1.17 0.31 0.38 2.63 1.87 111.60 MWD (1, 2) 1,800,00 2329 285.36 1,759.17 1.85 -0.04 3.00 -0.29 1.18 0.35 0.46 3.09 1,93 109,89 MWD(1, 2) 1,900.00 25.16 283.82 1,050.36 1.92 -004 3.62 -0.38 1.19 0.39 0.56 3.63 2.01 108.43 Memo (1. 2) 2,000.00 27.04 282.10 1.940.16 2.01 -0.04 4.24 -0.49 1.21 0,43 0.67 4.25 2.10 107.16 MWD (1, 2) 2,100.00 28.94 280,77 2,028.46 2.12 -0.05 4.93 -0.61 1.24 0.47 0,80 4.95 2.20 108.01 MM (1, 2) 2,200.00 30.86 279.59 2,115.15 2.24 -0,06 569 -025 1.28 0.51 0.94 5.71 2.31 10498 MWD(1, 2) 2,300,00 32.78 278.54 2,200.12 2.38 4+06 6.52 4.90 1.33 0.56 1.10 6.54 2.43 104.03 MM (1. 2) 2,400.00 3421 277.59 2,283.27 2.05 -0.15 3.61 0.03 1,25 0.80 0.64 3.62 2.23 10.99 MVX)-IFR-M4-SC (2,2) 2,500.00 35.64 276.73 2,964,50 2.11 4.10 3.86 0.04 128 0.64 0a9 3.97 2.31 100.05 MVdD+IFR-AK-CA2-SC(2.2) 2,600.00 30.58 275.94 2,"3.71 2.18 -0.0 4.34 0.04 1.32 0.69 0.75 4.35 288 99.23 MM+IFR-AK-CAZ-SC(2,2) 2,70.00 40.53 275,22 2,520.81 2.26 -0.23 4.74 004 1.38 0.73 0.80 4.75 2.46 98.50 MM-H`R-AK-CAZ-SC(2, 2) 2.800.00 42.48 274.55 2,595.70 2.34 -0.25 5.17 0.05 1.42 0.78 0.88 5.17 2.54 92.&5 MMAFR-AK-CAZ-SC (2,2) 2,860.65 43.87 274.17 2,640.0 2.35 -0.27 5.41 4.03 1.39 0.80 0.89 5.42 2.60 97.72 MWD (2, 3) 2,W0.65 43.67 274.17 2,654.47 2.35 -0.27 5.50 -0.09 1.39 0.81 0.91 5.51 2.60 97.68 MWD (2, 3) 2.930.00 44.36 273.75 2,668,38 2.35 -028 5.60 -0.14 1.39 0.82 0.93 5.61 2.61 97.63 MWD (2. 3) 3,000.0 47.99 27135 2,737.62 2.32 -0.33 6.21 -0A1 1.41 0.86 1.06 6.23 2.64 97.03 MWD(2,3) 3,10.00 51.65 289.97 2.802.13 2.33 -0.38 7.04 -0.72 1.48 0.90 1.27 7.07 2.69 96.05 MIND (2.3) 3,20,0 55.34 260.96 2,881.81 2.38 -0.43 8.04 -1.06 1.54 0.94 1.53 8.09 2.76 94.91 MM (2.3) 3,300.00 59.04 265.89 2,915.79 2.48 -0.48 9.18 -1.43 1.68 0.97 1.85 9.24 2.83 93.73 MWD(2,3) 3,400.00 62.76 285.52 2.864.41 2.57 -0.53 10.43 -1.82 1.86 1.0 2.21 10.50 2.91 92.59 MWD (2, 3) 3.500.00 66.49 2(u.25 3,07.28 271 -0.59 11.76 -2.24 2.07 1.02 2.61 11.85 2.98 9153 MWD (2, 3) 3.600.00 70,23 263.04 3,04/.13 2.88 -0.65 13.15 .2.68 2.32 1,04 3.03 13.25 3.07 0.54 MWD (2, 3) 3700.00 73.90 261.90 3,074.85 3.07 4.72 14.58 -3.13 2.60 1.06 3.48 1471 3.14 89.61 MWD (Z 3) 3,78e65 77.01 261.00 3,095.05 3.23 4.78 15,76 -3.51 2.84 1.07 3.85 15.90 3.19 88.91 MWD (2.3) 3,80.00 77.01 261.00 3,099.40 3.29 -0.78 16.05 -3.60 2.90 1.07 3.94 16.19 3.21 88.75 MWD (2, 3) 3,900.00 77.01 261.00 3,121,87 3.81 -0.78 17.59 -4.10 3.22 1.08 4.41 17.72 3.28 87.99 MM (2. 3) 4,000.00 77.01 261.00 3,1".35 3.93 -0.78 19.15 4.59 3.55 1.0 4.89 1927 3.32 87.35 MMA (2.3) 4,100.00 77,01 26100 3,166.83 4.26 -0.78 20.72 -5.0 3,88 1.11 5.37 20.82 3.37 0.82 MM (2, 3) 4,2110.00 77.01 26100 3,189.31 4.0 -098 22.30 -5.58 4.21 1.12 5,85 22.39 3.43 86,36 MM (2, 3) 4,300.00 77.01 261.00 3,211.79 4.94 478 23.08 -507 4.55 1.13 6.34 23.97 3.48 85,0 MWD(3,3) 4,40.00 T,41 28100 3,234.26 2.95 -0.36 11.04 0.18 2.68 1.14 1.62 11.12 3.09 87.98 MWD+IFR-AR-CAZ-SC(3,3) 4,50.00 not 261.00 3,256.74 3.11 -0.86 1156 0.18 2.83 1.15 1.66 11.63 3.12 87.53 MVA+IFR-AK-CAZ-5C(3,3) 4,60.0 77.01 261.00 3,279.22 3.28 -0.86 12.09 0.18 2.99 1.17 1.71 12.15 3.14 87.13 MWD+1FR-AK-CAZ-SC (3.3) 4,700.0 77.01 281.00 3,301.70 3.42 -0.86 12.62 0.10 3.15 1.18 1.76 12.68 3.17 86.77 MWD+IFR-AK-CAZ-SC(3,3) 4,600.00 77.01 261.00 3,324.10 3.58 -0.66 13.15 0.18 381 1.19 4.81 13.21 3.20 86.44 MWD+IFR-AK-0A2-60(3,3) 4,900.00 7701 261.0 3,346.65 3.74 -0.86 13.69 0.18 3.47 1.20 1.86 13.74 3.22 06.14 MWD+1FR-AK-CAZ-SC(3,3) 5,00.00 77.01 261.00 3,369.13 3,90 -0.06 14.23 0.18 3.63 122 let 14.28 325 05.88 MWD+IFR-AK-0AZSC(3,3) 5,100,00 77.01 261.00 3,391.61 4,0 -0.86 14.78 0.18 3.79 1.23 1.96 14.82 3.28 05.61 MWD+IFR-AK-CAZSC(3,3) 5,20.00 77.01 281.00 3,414.09 4.23 -0.56 15.33 0.18 3.95 1.24 2.01 15.37 3.31 85.38 MWD+IFR-AK-CAZSC (3,3) 5,30.00 not 261.00 3,436.57 4.39 -0.86 15.88 0.18 4.12 1.28 2.07 15.92 3.33 85.17 MWD+IFR-AK-CAZ4iC(3, 3) 5.40.0 77.01 261.00 3,459.05 4.58 .0.86 1843 0.18 4.29 1.27 2.12 16.47 3.36 84.97 M WD+IFR-AR-CAZSC (3.3) 5,500.00 7201 281.00 3,481,52 4.73 -0.86 16.98 0.18 4.45 128 2.18 17.02 3.39 84.79 MWD+IFR-AK-CAZ-S) (3, 3) 5,00.00 77.01 261.00 3,504.00 4.89 .0.86 9.54 0.18 4.62 1.30 2.23 17.57 3.41 84.63 MWD+IFR-AK43AZ-SC(3,3) 5,700.00 77.01 261.00 3.526.40 5.06 -0.86 18.10 0.18 4.79 131 2.29 18.13 3." 8447 MWD+IFR-MK-0-SC (3,3) 51800.00 77.01 261.00 3,548.98 5.23 -0.86 18.66 0.18 4.95 133 2.35 18.69 3.47 84.32 MVA+IFR-AK-CAZ-SC(3.3) 5100.00 77.01 261.00 3,571." 5,40 -0,85 19.22 0.18 5.12 1.34 2.41 19.25 3.50 84.19 MlM3+IFR-AK-CAZ-SC (3.3) 6,00.00 77.01 261.00 3.593.91 5.57 4.86 19.78 0.18 5.29 185 2.47 19.81 153 84.0 MMAFR-AK-CAZ-SC (3,3) Q10.00 71.01 261.00 3,616.39 5.74 -0.86 20.34 0.18 5.46 1.37 2.53 20.37 3.56 83.95 MWD+IFR-AK-CAZ-60(3,3) 6,20.00 77.01 261.00 3,638.87 5.91 -0.86 20.91 0.18 5.63 1.38 2.59 20.93 3.59 83.83 MWD+IFR-AK-CAZ-SC(3,3) 6.300.00 not 281.00 3.861.35 6.08 -0.86 21.47 0.18 5.80 1.40 2.65 21.50 3.61 83.73 MW0+1FR-AK-CAZSC(3,3) 12/11/2018 10:48:51AM Page 4 COMPASS 5000.14 Build 95D Company: ConocoPhillips(Alaska) Inc.-Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well. Plan: 2M-39 Wellbore: Plan: 2M-39 Design: 2M-39wpl5 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 21,11-39 As Built: 39 + 100,7 @ 139.70usft (Doyonl42) As Built: 39 + 100.7 @ 139.70usft (Doyonl42) True Minimum Curvature 1.00 sigma OAKEDMPI Measured Inclination Aanoth Vatleal Mghside Lateral Vertical Magnitude Semi+nalor Seml+ninvr Math Depth E. Bias East Blas Is. Blas or Bias Emor Emw AvmWti TOW (us") P) n (Left) (-a) loss) lush) (daft) (ash) local (usnl (um) sum) V) 6,40099 77.01 261,00 3.683.83 6.25 -086 22.04 018 596 1.41 231 22,06 3.64 6163 MVe➢+IFR-AK-CAZ-SC(3,3) 6,500.00 77.01 MAO 3,706,30 6.43 -0.86 22.61 OAS 6.13 1.43 278 22.63 3.67 03.54 MM+IFR-AK-CAZ-SC(J,3) 6,600.00 77.01 261.00 3,728.78 6.60 -0.86 23.17 0.18 6.30 1.44 2.84 23.19 3.70 83.45 MND+IFR-AK-CAZ-SC(3, 3) 6700.00 n.01 261.00 3,751.26 e.n -0.86 23.74 0.18 6.47 1.46 2,90 23]8 373 03.37 MWD+IFR-AK-CAZSC(3, 3) 6,800,00 77.01 261.00 3,773.74 6.94 -0.06 24.31 0.18 6.64 167 2.97 24.33 336 83.29 MM -IFR -AK -CA 4iC(3,3) 6,900.00 77.1 261.00 3,796.22 7.12 -0.86 24.00 0.18 6.81 1.49 3.W 24.90 3.79 83.22 MV IFR-AK-CAZ-SC(3, 3) 7,000.00 77.01 281.00 3.818,69 7.29 4).66 25.45 0.18 6.96 1,50 3.10 25.47 3.83 83.15 MVA+IFR-AK-CAZ-SC(3, 3) 7,100.00 77.01 261.00 3,841,9 7.46 -0.86 26.02 0,18 7,15 1.52 3.17 28.04 3.86 03.00 MND+1FR-AK-CAZ-SC(3,3) 7,200.00 77.01 261.00 3,863.65 7.64 -0.85 26.59 0.10 Z32 1.54 324 Mal 3.89 83.02 MM+IFR-AK-CAZ-SC(3,3) 7,300.00 77.01 261.00 3.886.13 7.81 -ON 27.16 0.18 7.49 1.55 3.31 27.18 3.92 82.96 MWD+IFR-AK-CAZ-SC(3.3) 7,400.0 n.01 Men 3,908.61 Tell -0.86 27.74 0.18 7.66 157 3.38 27.75 3,95 82.90 MM+IFR-AK-CAZ-SC(3,3) 7,500.00 77.01 261.00 3,931.09 0.16 -0.86 28.31 0.18 7.0 1.59 3.45 28.32 3.98 82.85 MVA+IFR-AK-CAZSC(3,3) 7,600.00 77.01 261.00 3,953.56 8.33 -0.86 28.88 0.18 8.00 1.60 352 28.90 4.02 82]9 MWDAFR-AK-CAZSC(3.3) 7.700,00 77.01 261.00 3.876.04 8,50 -0,88 29.46 0.18 8.18 1.62 3.59 28.47 4.05 82.74 MVID+IFR-AK-CAZSC(3,3) 7,800.00 77.01 281.00 3,998.52 8.68 -0.88 30.03 0.18 895 1.64 3.66 30.04 6.08 82.69 MV,D+lFR-AK-CAZ-SC(3,3) 7,900.00 77.01 261.00 4,021.00 8.65 -0.86 30.60 0.18 8.52 1.65 3.74 30.62 4.11 8265 IFNDNFR-AK-CAZSC(3,3) a,o00.00 77,01 281.00 6,043,48 9.03 -0.85 31.18 0,18 8,69 1.67 3.81 31,19 4.15 02,60 MV IFR-Pl(-CAZ-SC(3,3) 8,100.00 77.01 261.00 4,065.95 9.20 -0.86 31.75 0.16 0.86 1.69 3.88 31.76 4.18 82.5 M%VDNFR-AK-CAZ-SC (3, 3) 0.200.00 77.01 261.00 4.080.43 9.38 -0.86 32.33 0.10 9.03 170 3.96 32.34 4.21 82.52 MVA+IFR-AK-0AZ-SC (3, 3) 6300.00 77.01 261.00 4.110.91 9.55 -0.86 32,90 0.18 9.20 1.72 4.03 32.91 4.25 82.40 MWD*IFR-AK-CAZ-SC(3,3) 8,400.00 77.01 261.00 4,133.39 9.73 -0.86 33.46 0118 9.37 1.74 4.11 33.49 428 02.45 MW0+1FR-AK-CAZ-SC(3,3) 8,500.00 77.01 261.00 4,155.87 9.90 -0.86 34.05 0.18 9.54 176 4.19 34.08 4.32 82.41 1,413+1FR-AK-CAZ-SC(3,3) 8.600,00 n.01 261.00 4,178.34 10.08 -0.86 34.83 0.18 9.72 1.77 427 34.84 4.35 82.38 1JWD+IFR-AK-CAZ-SC(3,3) 8,700.00 77.01 261.00 4,200.82 10.25 .0.86 35.21 0.18 9.89 1.79 4.36 35.22 4.39 82.34 MWD+IFR-AK-CAZSC(3.3) 8,85.00 77.01 261.00 4,223.30 10.43 -0.86 35.70 0.18 10.06 1.81 4.42 3539 4.42 82.31 lvM+IFR-AK-LAZ-SC(3,3) 8,900.00 77.01 261.00 4,245.70 10.60 -0,86 36.36 0.18 10.23 1.83 4.50 3637 4.46 82.28 MVIDAFR-AK-CAZ-SC(3,3) 9,000.00 77.01 261.00 4,268.26 10.78 -D.06 36.94 0.10 10.40 1.85 4.58 36.94 4.49 82,25 MPANFR-AK-CAZ-SC (3,3) 9,10000 77,01 261.00 4,290.73 10.95 4).85 37.51 0.18 10.57 1.87 4.68 37,52 4.53 82,22 MWD+IFR-AK-CAZ-SC(3, 3) 9,200.00 77.01 261.00 4,313.21 11.13 -0.86 38.09 0.18 10.74 1.88 434 38.10 4.56 82.19 MVA+IFR-AK-CAZ-SC(3, 3) 9,300.00 77.01 261.00 4,335.69 11.30 -0.86 38.67 0.10 10.92 1.90 4.83 30.67 4.60 82,16 MVADAFR-AK-CAZ-W(3, 3) 9,400.00 77.01 261.00 4,358.17 11.40 AN 39.24 0.18 11.09 1.92 4.91 39.25 4.63 82,14 MVA+IFR-AK-0AZ-SC (3,3) 9,50.0 not 281.00 4,380.65 11.65 -0.96 39.82 0.18 11.28 1.94 4.99 39.83 4.87 82.11 MVrD+IFR-AK-CAZ-W(3,3) 9,600.00 77.01 261.00 4,403.13 11.83 -0.86 40.40 0.18 11.43 1.96 5.08 40.41 4.70 82.09 MWD+IFR-AK-CAZ-50(3,3) 9,700.00 77.01 261.00 4,425.60 12,01 -0.86 40.98 0.18 11.60 1.98 5,16 40.98 4,74 82.07 Ml4D+IFR-AK-CA2.SC(3,3) 9,800.00 77.01 261.00 4,44800 12,18 -0.86 41.56 0.18 11.77 2.00 525 41.56 4.78 82.04 MVVDAFR-AK-CAZSC(3, 3) 9,900.00 77.01 261.00 4,470.56 12.36 -0.86 42.13 0.18 11.95 2.02 5.33 42.14 4.81 82.02 MWD+IFR-AK-CAZSC(3,3) 10,000,00 77.01 261.00 4,493.04 12.53 -0.88 42.71 0.18 12.12 2.04 5,42 4232 4.05 82.0 M V D+IFR-AK-CAZSC (3,3) 10,100.00 77.01 261.00 4,515.52 12.71 -0.96 43.29 0.18 12.29 2.06 5.51 43.30 4.89 81.0 MM+IFR-AK-CAZSC(3,3) 10,200.00 77.01 261.00 4,537.99 12.88 -0.86 43.87 0.18 12.46 2.0 5.60 4387 4.93 81.98 MWD+IFR-AWCAZSC(3,3) 10,300.00 77.01 281.00 4,560,47 13.06 -0.86 44.45 0.18 12,83 2.10 5.88 44,45 4.96 61.94 MVVD+IFR-AK6CAZSC(3,3) 10,600.00 77,01 261.00 4,502.95 13.24 -0.86 45.03 0.10 12.61 2.12 SA 45.03 5.00 81.92 MMAFR-AK-CAZ-SC(3,3) 14500.00 77.01 281.00 4.605,43 13.41 -0.86 45,60 0,18 12:98 2,14 5.86 45,81 5,04 61.90 MWD+1FR-AK-CA2-SC(3,31 10,600.0 77,01 261.00 4,60.91 13.59 .0.86 46,18 0,18 13.15 2,16 5.95 46,19 5.07 81.88 MVA+IFR-AK-CAZ-SC(3,3) 10,700.5 77.01 261.00 4,65.30 13.76 -0.86 4636 0.18 13.32 2.18 6.04 46.77 5.11 81.86 MVA+IFR-AK-CAZ-8O(3, 3) 10,810.00 77.01 Mine 4,872,85 13,94 -0.86 47.34 0.18 13.49 2.20 6.14 47.35 5.15 81,05 MVAHFR-AK-CAZ-SC(3,3) 10,900.5 n.01 261.00 4,695.34 14,12 .0.86 0.92 0.18 13.67 2.22 6.23 47.92 5.19 81.03 MVANFR-AK-CAZ-SC(3,3) 11.00.0 77.01 261.00 4,717.82 14.29 -0.86 40.50 0.18 13.84 2.24 6,32 48.50 5.23 81,81 MVADAFR-AK-CA2-SC(3,3) 11,100.00 77.01 261.00 4,740.30 14.0 -0,88 49.08 0.18 14.01 2.26 641 49.08 5.28 01.00 MVAHFR-AR-CAZ-SC(3,3) 11,200.5 not 261.00 4,762.77 14.64 -0.86 49.66 0.18 14.18 2.29 6.51 49.66 5.30 81.70 MV VAFR-MKC -SC (3, 3) 11.300.00 77.01 261.00 4,J85.25 14,82 -0.86 50.24 0.18 14.35 2.31 6,60 50.24 5,34 81.77 MVVDAMMKC -SC (3, 3) 11,400.00 77.01 261.00 4,007.73 15.00 -0.86 $0.82 0118 14.53 2.33 6.70 50.82 5.38 01.75 MVA+IFR-AK-CAZ-SC(3, 3) 11,500.00 77.01 261.00 4,830.21 15.17 -0.86 51.40 0.18 14.70 2.35 6.80 51.40 5.42 81.74 MVA+IFR-AK-CA2-SC (3,3) 12/112018 10:46:51AM Page 5 COMPASS 5000.14 Build 85D Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad ConocoPhillips Error Ellipse Report Local Coordinate Reference: TVD Reference: MD Reference: Well: Plan: 2M-39 North Reference: Wellbore: Plan: 2M-39 Survey Calculation Method: Design: 2M-39Wp15 Output errors are at Seni+mjor U.I.I. Database: Position uncertainty and bias at survey station Well Plan: 2M-39 As Built: 39 + 100.7 @ 139.70usft (Doyon142) As Built: 39+ 100.7 @ 139.70usR (Doyonl42) True Minimum Curvature 1.00 sigma OAKEDMPI Measured Indinatbn Az wh Venlcal RI98eMe latent Vedical Me9nKude Seni+mjor U.I.I. Depth Deoh ERar Bke E. Bks Error eke Male. Error ERer A moth Tad Josh) rl (1) (Deft) (.0o (-Mn luea) (use) (--ft) lusn) Juan) (uea) (Nft) (1) 11.600.00 77.01 26180 4.85269 15.35 -0.86 51.97 0.18 14.09 2.37 6.89 51.98 5.46 81.72 MWD+IFR-AK-CA -SG (3 3) 11,700.00 77.01 261.00 4,875.17 15.53 -0.86 52.55 0.18 15.04 2.39 6.99 52.56 5.50 61.71 MM -IFR -AK -CA -SC (3, 3) 11,80080 77.01 261.00 4,897.64 15.70 -0.86 53.13 0.18 15.21 2.42 7.09 53.14 5.54 81.70 MVA+IFR-AK-CA -SC (3. 3) 11,900.00 77.01 281.00 4.920.12 15.88 .0.86 53.71 0.18 15.39 2.44 7.19 53.72 5.57 81.68 MM11FR-AK-C ZSC(3,3) 12,000.00 77.01 261.00 4,942.60 16.05 -0.86 54.29 0.18 15.56 2.46 7.28 54.30 5.61 81.67 MWD+1FR-M-CASC(3, 3) 12,100.00 77.01 26180 4,965.08 16.23 -0.88 54.87 0.18 15.73 2.48 7.38 Use 5.65 81.66 MWD+1FR-AK{ -$C(3, 3) 12,200.00 77.01 261A0 4,987.56 16.41 -0.88 55.45 0.18 15.90 251 7.48 55.46 5.69 81.65 MWD+IFR-AK-CPLSC(3, 3) 12,300.00 77.01 281.00 5,010.03 16.58 -0.85 56.03 0.10 16.07 2.53 7.59 58.04 533 81.63 MM -IFR -AK -CA -SC (3, 3) 12,400.00 77.01 281.00 5,032.51 16.76 -0.86 56.61 0.10 16.25 2.55 7.69 56.62 5.77 81.62 MW IFR -AK -CA -SC (3, 3) 12.500.00 77.01 261.00 6.054.99 18.94 4.88 57.19 0.18 16.42 2.58 7.79 57.20 5.81 81.61 MW IFR -AK -CA -SC (3, 3) 12,600.00 T7.01 261.00 5,077.47 17.11 -0.86 57.r 0.18 16.59 2.60 7.89 57.78 5.a5 81.60 MWD+IFR-AK-CA -SC (3, 3) 12,700.00 77.01 261.00 5,099.95 17.29 -0.86 50.35 0.18 16.76 2.62 8.00 5136 5.89 81.59 MM -IFR -AK -CA SC (3, 3) 12,800.00 71.01 261.00 5,122.42 17.47 -086 58.93 0.18 16.94 2.65 8.10 58.94 5.93 81.58 MWD+IFR-AK-CA -SC (3. 3) 12.900.00 r.01 261.00 5.144.90 17.64 .0.86 59.51 0.18 17.11 2.67 8.20 59.52 5.97 81.57 MWD+1FR-AK-CASC(3, 3) 13,000.00 77.01 281.00 5,167.38 17.82 -0.86 60.09 0.18 17.28 2.88 8.31 60.10 6.01 81.56 MWD+IFR-AK-CAZSC(3, 3) 13,100.00 77.01 261.00 5,189.86 10.00 -0.88 80.67 0.18 17.45 2.72 8.42 60.68 6.05 81.55 MWD+IFR-MK- ,SC (3.3) 13,200.00 77.01 261.00 5,212.34 18.17 -0.86 61.25 0.18 1262 234 0.52 81.26 6.09 81.54 MWD+1FR-M-CA-SC (3.3) 13,300.00 77.01 261.00 5,234.81 18.35 -0.86 61.84 0.18 17.80 2.77 8.63 61.64 6.13 81.53 MWD+1FR-AK-CA-SC(3,3) 13,400.00 77.01 261.00 5,257.29 18.52 -om 6242 0.18 17A7 239 834 62.42 6,17 81.52 MWD+1FR-AK-CA-SC(3,3) 13.607.00 77.01 281.00 5,279.77 18.70 -0.80 63.00 0.10 18.14 2.81 8.85 63.00 8.21 81.51 MPA+1FR-AK-CA -ac (3,3) 13,80080 77.01 arm 5,302.25 18.80 -0.85 63.58 0.18 18.31 2.84 6.95 63.58 6.25 81.50 MP JFR-AK-CA-SC(3,3) 13,700.00 77.01 261.00 5,324.73 19.05 -0.86 64.16 0.18 18.19 2.86 am 64.16 6.29 81.49 MN JFR-AK-CA-SC(3. 3) 13.80000 77.01 261.00 5.347.21 19.23 -0.86 64.74 0.18 18.66 2.89 9.17 64.74 6.33 01.48 MW IFR -AK -CA -SC (3,3) 13,900.00 77.01 261.00 5,369.68 19.41 -0.86 65.32 0.18 18.83 2.91 9.28 65.32 6.38 01.48 MWD+IFR-AK-CA-SC(3,3) 14,00000 77.01 28100 5,392.16 19.58 486 65.90 0.18 19.00 2.94 900 65.90 6.42 81.47 MWD+IFR-AK-CA -SC (3,3) 14,100.00 77.01 281.00 5,414.64 19.76 -0.86 66.48 0.18 19.18 2.90 951 88.48 6.46 81.46 MVM+IFR-AK-CAZ C(3,3) 14,200.00 77.01 261.00 5,437.12 19.94 -0.86 67.06 0.18 19.35 2.99 9.62 67.06 6.50 81.45 MWD+IFR-AK-CA2..9C(3,3) 14.300.00 77.01 261.00 5.459.80 20.11 .0.86 67.64 0.18 19.52 3.01 9.73 67.64 6.54 al.44 MWD+1FR-AK-CA SC(3,3) 14,400.00 r.01 281+00 5,482.07 20.29 -0.86 68.22 0.18 19.69 804 ass 68.22 6.58 81.44 MM+IFR-AR-CAZSC(3,3) 14,500.00 77.01 261.00 5,074.55 20.47 -0.86 Man 0.18 19.87 3.07 9.96 6880 6.62 81.43 MWD+IFR-MK--SC(3,3) 14.800.00 77.01 261.00 5.527.03 20.64 .0.86 69.38 0.18 20.04 3.09 10.08 69.30 6.66 81.42 MM+IFR-M4- -SC (3.3) 14,680.65 77.01 261.00 5,545.16 20.79 -0.86 69.85 0.18 20.18 3.11 10.17 69.85 630 81.41 MM+IFR-M-CA -SC (3.3) 14,700.00 76.92 260.21 5,549.52 20.80 -084 69.94 0.32 20.21 3.12 10.19 69.95 6.70 81.41 MWD+IFR-MK--SC (3.3) 14,800.00 76.50 256.12 5.572.52 20.92 -0.78 70.11 1.01 20.38 3.15 10.31 70.41 635 81.39 MM+IFR-AK-CAZSC(3,3) 14,900.00 76.15 252.02 5,596.17 21.09 -034 69.92 131 20.55 3.17 10.43 70.84 6.79 81.34 MM+IFR-AK-C -SC (3,3) 15,000.00 75.87 247.91 5,620.36 21.32 -0.72 69.35 2.41 20.72 3.20 10.55 7126 6.83 81.27 MWD+1FR-AK-CA-SC (3.3) 15,100.00 75.65 243.79 5.644.97 21.63 -0.73 68.40 3.11 20.89 3.23 10.67 71.65 6.87 81.18 MWD+1FR-M-CA-SC (3,3) 15,200.00 75.51 239.66 5.669.88 21.99 -0.77 67.09 3.80 21.08 3.26 10.78 72.02 6.91 81.08 MWD+1FR-AK-C-SC (3,3) 15,300.00 75.44 235.53 5,694.97 22.40 483 65.42 4.49 2123 3.30 10.90 72.36 6.95 80.96 MMA)+IFR.M.CA2-SC(3.3) 15,400.00 75.4 231.40 5,720.13 22.85 0.92 63.39 5.15 21.40 3.33 11.01 72.67 7.00 80.82 MWD+1FR-AK-CA-SC (3,3) 15,500.00 75.51 227.27 5,745.22 23.31 -1.03 61.02 5.80 21.57 3.36 11.12 72.95 7.06 80.68 MWD+IFR-M-CA2-SC(3,3) 15.600.00 75.66 223.14 5,770.12 23.76 -1.17 58.33 6.43 2134 3.39 11.23 73.21 7.12 80.53 MWD+1FR-M-CA2-SC(3,3) 15]00.00 75.88 219.02 5,794.72 24.10 -1.32 55.33 7.03 21.91 3.42 11.33 73.44 7.20 80.38 MWD+1FR-AK-CA-SC (3,3) 15,800.00 76.16 214.91 5,818.00 24.40 -1.49 52.22 7.52 21.98 3.45 11.37 73.86 6.96 80.17 MVM (3, 4) 15,900.00 76.52 210.81 5,842.51 24M -1.67 49.07 7.91 21.98 3.48 11.35 74.32 7.05 79.70 MWD (3, 4) 18000.00 76.94 206]2 5,865.47 24.78 -1.86 45.73 8.31 22.00 3.51 11.36 74.76 7.28 79.38 Main (3,4) 16,100.00 rA3 202.85 54887.86 24.83 -2.06 42.24 830 22.01 3.54 11.38 75.16 7.65 78.90 MM (3,4) 18,200.00 77.97 Tee% 5,908.97 24.81 .2.26 38.63 9.10 22.03 3.56 1142 75.54 8.14 78.41 MM (3,4) 16,300.00 78.58 194.55 5,929.30 24.71 .2.45 34.94 9.50 22.06 3.59 11.49 75.89 8.76 77.89 MM (3,4) 16,320.82 78.71 193.72 5,83340 24.86 .2.50 34.17 9.58 22.07 3.59 11.51 75.96 8.90 77.78 MM (3,4) 18,400.00 78.71 193.72 5,948.90 24.71 -250 34.85 9.61 MAO 3.61 Mm 76.21 9.38 77.37 MM (3,4) 18,070.00 78.71 19332 5,968.47 24.74 -2.50 35.70 9.63 22.14 3.64 11.66 76.54 9.93 76.85 MOM (3, 4) 18,800.00 78.71 193.72 5,988+5 24.78 .2.50 36.59 am 22.18 3.66 11.75 76.87 10.57 76.33 MM (3 4) 12/1112018 10:48:51AM Page 6 COMPASS 5000.14 Build 85D 0 Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: Well: Plan: 2M-39 North Reference: Wellbore: Plan: 2M-39 Survey Calculation Method: Design: 2M-39wpl5 Output errors are at Semimajor Samiminw Database: Position uncertainty and bias at survey station Well Plan: 2M-39 As Built: 39 + 100.7 @ 139.70usft (Doyon142) As Built: 39 + 100.7 @ 139.70usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMPI Measured Indinarion ".Wh vertical 16,Wde Laces) Venice) M89n@ede Semimajor Samiminw Depth Depth Emir at. Eno, Bus Error Blas ar Bus E., Emir Admuth Ted 1.11) (1 (T (uif) Neff) (heft) (u5ft) (eSr) (u51t) Wen) (..ft) hedn (-it) V) 1670000 70]1 193.72 6,007.62 24.83 -250 37.51 9.69 22.23 368 11.84 77.21 11.27 7539 MWD(3, 4) 16,751.50 78.71 193.72 6,018.29 24.86 -2.50 38.02 971 22.26 3.70 11.88 77.41 11.67 75.49 MM (3.4) 16,803.0 78.86 191.87 6,027.14 24.88 -2.57 36.39 9.91 2229 371 11.93 77.57 12.03 75.24 MV (3, 4) 16,038.55 79.00 190.30 8,034.54 24.89 -2.64 35.01 10.07 22.31 372 11.97 7730 12.34 75.02 1AVJD(3, 4) 16900.00 79.00 190,30 6,046.26 24.58 -2.67 28,50 10.35 22.07 3.73 12.17 74.70 8.16 70.75 MM -FR -AK -CA -SC (4,4) 17,000.00 79.00 190.30 6065.34 24.60 -2.67 2&76 10.35 22.09 375 111 74.85 8.37 70.60 MMAFR-AK-CAZSC (4, 4) 17,038,55 79.00 190,30 6,072.70 24.60 -267 28,86 10.35 22,09 3.76 12.25 74.88 8.46 78.53 1JwD+1FR-AK-CA -SC (4, 4) 17,100.00 80.84 190.36 6,083.45 23.75 -2.86 29.23 10.36 22.09 3.78 12.30 75.04 0.37 78.30 MM (4, 5) 17,200.0 83.81 190.44 609678 22.69 -3.17 30.11 10.41 22.10 3.79 12.41 75.30 074 77,79 M44D (4, 5) 17,300.00 88.84 190.53 6104.90 22.13 -3A8 31.03 10.46 22.11 3.80 12.51 75.58 9.25 77,27 MWD (4, 5) 17,400.00 89.84 190.81 6107.80 22.11 -379 32.01 10,52 22,12 3.80 12.60 75.87 9.87 7674 MWD (4, 5) 17,500.00 92.84 190.70 6,105.46 22.62 -4.09 33.03 10.57 22.15 3.80 12.60 76.17 10.58 76.19 MWD (4, 5) 17.594.17 95.66 190.70 6,090.48 23.56 -4.37 34.01 10.62 22.17 3.80 12.75 76,46 11.30 75.68 MM (4, 5) 17,600.00 95.86 190.78 6.097.91 2158 4.37 34.07 10.62 22.17 3.80 12.76 76.40 11.35 75.64 MWD(4,5) 47,700.00 95.66 190.70 8,000.04 23.59 3.37 35.03 10.60 22.21 3.79 12.83 76.80 12.17 75.08 MIND (4,5) 17,759,96 Was 190.70 6,082.13 23.61 3.37 35,66 10.71 22.23 3.79 12,87 77.00 12.68 74.74 M`hD (4, 5) 17,800.00 Use 190.97 6078.45 23.34 3.29 36,24 10.71 22.25 378 12.90 77.13 12.92 74.53 MWD (4.5) 17,900.00 92.90 191.44 6071.63 2279 3.10 37.57 10.72 2230 338 12.98 77.45 13.29 74.2 MWD (4, 5) 10,000.00 90.99 191.91 6,068.19 22.46 -3.89 38.94 1072 22,35 378 13.05 7779 1375 73,50 MM (4, 5) 18,095.90 89.13 192,35 8,088.09 22,35 -3.08 40.29 10,71 22.40 378 13.13 78.14 14.26 72.99 MM (4, 5) 18,097.50 89.10 192.36 6038.11 22.36 -3.67 40.30 10.71 22A1 370 13.13 78.14 14.27 72.98 MM (4, 5) 18,100.00 89.10 192.38 6.058.15 22.36 3,87 40.33 10.71 22.41 376 13.13 78,15 14,29 72.96 MM (4, 5) 18,203.00 89.10 192.36 8,03973 22,42 .3.67 41,35 10.75 22.0 378 13.21 78.54 15.11 72.39 MM (4, 5) 18,300.00 09.10 192.36 6,071.30 22.49 -3.67 42.42 10.80 22.54 378 13.28 78.91 15.95 71.80 MM (4, 5) 18400.00 09.10 192.38 6.072.88 22.17 .3.67 34.51 10.12 22.22 376 12,78 78.09 10,30 78.42 MWD+1FR-AK-CA2-SC (5, 5) 18,500.00 89.10 192.36 6,074.45 22.19 -3.67 34.0 10.12 22.24 378 1283 76.19 10.57 76.26 MM+IFR-AWCAZ-SC(5, 5) 18.600,00 89.10 192.36 6,076.03 22.21 5.67 35,13 10.12 22,26 3,78 12,87 78.29 10.85 76.09 MWD+IFR-AK-CA -SC (5, 5) 10,700.00 89.10 192.36 8,077.60 22.23 -3.67 35.43 10.12 22.28 3.79 12.92 76.39 11.14 75.93 MM -IFR -AK -GA -SC (5,5) 18,729.47 89.10 192.36 6078.07 22.24 -3.67 35.52 10.12 22.29 3.79 12.93 76.42 11.23 75.88 MWD+1FR-AK-CA-W(5,5) 10.796,52 8977 192.32 607873 22.29 4.76 35.69 10,13 22,30 3.79 12.96 76.49 11.43 7576 MWD+IFR-AK-CAZ-SC(5, 5) 10,800.00 89.77 192,32 8,07874 22.29 676 35.71 10.13 22,31 3.79 12.93 76.49 11.44 75.76 1JWD+1FR-AK-CAZ-SC(5, 5) 18,900.00 8977 192.32 6079.15 22.31 -376 36.02 10.13 22.33 379 13.01 76.59 11.76 75,58 MNID+IFR-AR-CAZ-SC(5. 5) 19,000,00 8977 192.32 6,079.56 22.34 3,76 36.35 10,13 22.36 3.78 13.05 76.70 12.08 7541 MWMIFR-M-CAZ-SC(5, 5) 19,100.00 89.77 192,32 6,079,96 22.37 -378 36.60 10.13 22.39 379 13.10 76.80 12.42 75.23 MWD+IFR-AK-CAZ-SC(5,5) 19,200.00 8977 192.32 6080.37 22.40 -376 37.01 10.13 22.42 379 13.14 76.91 12.76 7&06 MW IFR-AK-CAZSG(5, 5) 19.30.00 89.77 192.32 6,080,77 22,43 -376 37.36 10.13 22.45 3.79 13.19 77.02 13.11 74.87 MWD+IFR-AK-CAZSC(5, 5) 19,400.00 89.77 192.32 6,081.18 22.46 -376 3770 10.13 22.48 379 1324 77.13 13.46 74.69 MM+IFR-AKSAZSG(5, 5) 19,500.00 09.77 192.32 6,081.59 22.50 -376 38.06 10.13 22.51 379 13.28 77.24 13.82 7451 MWD+1FR-AK-CAL8C (5, 5) 19,600.00 09.77 192.32 6,001.99 22.53 -378 38.41 10.13 22.55 379 13.33 77.35 14.18 74.32 MWD+IFR-AK-CAZ-13C (5,5) 19,700.00 8977 192.32 6,082.40 22.57 -376 38.78 10.13 22.59 379 13.38 77.46 14.55 74.13 MWD+1FR-AK-0A2-SC(5. 5) 19,800.00 0937 192.32 6.082.01 22.61 -376 39.15 10.13 22.62 379 13.43 77.58 14.92 7394 MWD+IFR-AK-C -SC (5, 5) 19,043.11 89.77 192.32 6,082.98 22.62 -376 39.31 10.13 22.64 379 13.45 77.63 15.08 73.85 MWD+IFR-AK-CAbSC(5. 5) 19,900.00 88.63 192.32 600378 22.61 -3.60 39.45 10.13 22.56 379 13.48 77.69 15.17 7376 MWD+IFR-AK-CAZ SC (5, 5) 20000,00 66.63 192.31 6,087.91 22.75 -3.31 39.60 10,13 22,70 3.79 13.53 77,78 15.09 73.64 MM+IFR-AK-C -SC (5, 5) 20,05045 85.62 192,31 6,091.32 22.91 4.16 39.67 10.13 2232 3.00 13,55 77.83. 15.06 7358 MM+IFR-AK-CAZ-SC(5.5) 20100.00 85.62 192.31 6.095.11 22.93 -3.16 39.81 10.13 22.75 3.00 13.59 77.88 15.14 73.50 MWD+1FR-AK-CAZ-9C(5, 5) 20,20000 85.62 192,31 6,102.74 22,88 -3.16 40.18 10.13 22.79 3.01 13.86 78.00 15.51 73.31 MWD+1FR-AK-GAZ-SC(5,5) 26278.39 95.62 192.31 610873 23.01 -3.16 40.47 10.13 22.82 3.82 1371 78.10 15.80 73.16 MMID+1FR-AK-0AZ-5C (5, 5) 0.300.00 Was 192.31 6,110.30 22,95 3.23 40.55 10.13 22.83 382 43.72 78.12 15.08 73.11 MWD+1FR-AK-CAZ-SC(5, 5) 20,400.00 88.05 192.33 6,115A4 2283 -3.53 4095 10.13 22.88 3.82 1378 70.25 16.25 72.92 MWD+IFR-AK-CAZ-SC(5, 5) 0,477.05 89.59 192.34 6,117.02 22.89 -336 41.26 10.13 2292 3.82 13.82 70.34 16.54 72.76 MM IFR-AK-CAZ-SC(5, 5) 20,500.00 89,59 192.34 6,117,18 22,90 .376 41.35 10.13 22.93 3.82 13,83 78.37 16.63 72.72 MWWIFR-AK-CAZSG(65) 12/112018 10:48:51AM Page 7 COMPASS 6000 14 Build 86D Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kupaluk 2M Pad Well: Plan: 2M-39 Wellbore: Plan: 21,11-39 Design: 2M-39wp15 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Coordinate Reference ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M-39 As Built: 39+ 100.7 @ 139.70usft (Doyon142) As Built 39 + 100.7 @j 139.70usft (Doyonl42) True Minimum Curvature 1.00 sigma OAKEDMPI Measured Indlnab,n Azimuth Vertical R,haiiM lateral Vertical Magnitude Semi+najar Semi+nin t, Depth Dean Error Biu Egger Bias ED9r Bias in Inas Error E. AxlauM Taal (usb) r) (9 lead) waft) less) (,5x1 (..ft) (ass) (..it) (um) lash) (uss) (1) 20,60000 89.59 lWail 6,117,89 22.95 -3.76 41.74 ie13 22.97 3.82 13,88 78.50 17.01 M.51 MWD+IFR-AK-CAZ-SC(5, 5) 20.700.00 09.59 192.34 8,118.60 23.00 -336 42.13 10.13 23.02 3.82 13.93 78.63 17,39 72.31 MWD+1FR-AK-CAZ-SC(5, 5) 20.800.00 89.59 192.34 6,119.31 23.05 -3.76 42,53 10,13 23,08 3.82 13.99 78.76 17.77 72.10 MWD+IFR-AK-CAV-33(5, 5) 0.900.00 89.59 192.34 6,120.02 23.10 .3.76 42.93 10,13 2313 3.83 14.04 78.89 18.15 71.89 MINDHFR-AK-CAV-SC(5,5) 21,000.00 89.59 19234 6,120,73 23.15 -336 43.34 10.13 23.18 383 14.09 7902 18.54 71,68 MWD+1FR-AK-CAVSC(5, 5) 21,076A8 69.59 192.34 6,121.27 2120 -3.76 43.65 10.13 23.22 383 14.13 79.13 16.03 71.52 MNA+IFR-AK-CAZSC(5, 5) 21,100.00 89.12 192.32 6.121.54 23.19 -3.69 43.70 10.13 23.24 3,03 14.14 79.15 18.87 71.48 MWD+IFR-AK-CAV-SC(5, 5) 21,200.00 87.12 192.25 6.124.02 23,30 -3.36 4335 10.14 23.29 3.03 14.20 79.25 18.77 71.37 MWTIHFR-AK-CAZ-SC(5, 5) 21.202.35 87.07 192.24 6,124.94 2330 -3.35 4335 10.14 23.29 3.83 14.20 7925 18.77 71.36 MMd)+1FR-M-CA -SC (5. 5) 21,300.00 87.07 192.24 6,129.93 23.36 -3.36 44.02 lead 23.35 3.03 14.27 79.37 18.92 71.21 11FWD+IFR-AK-CAZ-SC(5, 5) 21,400.00 8207 192.24 6,135.04 23.41 4.36 44+43 10.14 23.41 3.84 14.33 79.50 law 70.99 MWD+IFR-AK-CAZ-SC(5, 5) 2144209 87,07 19224 6,137.19 23.44 -336 44.60 10A41 23.43 3.84 1435 79.58 19,46 70,90 MWD+IFR-AK-CAV-SC(5, 5) 2150000 87.65 192.26 6,139.85 23.44 -3.45 44.86 10.14 2347 3.84 14.39 7961 19.68 7037 MWD+1FR-AK-CAV-SC(5, 5) 21,600.00 88.65 192.29 6,14304 23.49 -3,02 45,31 10,13 23.53 3.85 14.45 7939 20.06 70.55 MWD+1FR-AK-OAT-SG(5, 5) 21,700,00 89.65 192.32 6,144.56 23.57 -3.79 45.76 10.13 23.59 3.85 14.51 79,93 20.44 70.33 MM+IFR-AK-CAVSC(5, 5) 21,735.03 9000 192.33 6,144.67 23.61 -3.85 45.92 10.13 23,81 365 14.53 79.98 20.57 70.25 MWD+1FR-AK-CAZSC(5,5) 21,800.00 90.65 192.33 6,144,30 23.72 -3.96 46.19 10.13 23.65 385 14.56 80.08 20.82 70.11 MWD+IFR-AK-CAVS0(5.5) 21,900,00 91.65 192.32 6,142.30 23.92 -4.13 46.61 10.13 23.72 3,85 14,61 80,23 21.20 69.08 MWD+1FR-AK-CAVSC(5, 5) 21,951.66 92.17 192.32 6,140.50 2404 1.21 46.83 10.13 2375 385 14.63 00.30 21.40 69.77 MWD+1FR-M-CAZ-SC(5,5) 22,000.90 92.17 192.32 6.138.75 24,07 -4.21 47.03 10.13 23.79 3.04 14.66 80.38 21.59 69.65 MYVD+IFR-MK- -SC (8, 5) 22015.60 92.17 192.32 6,130.16 24.08 4.21 47.10 10.13 23.80 3.84 14,88 80.40 21.64 69.62 MWD+1FR-MK AZ -SC (5, 5) 2$100.00 90+48 192.39 6,135.21 23.90 -3.93 47.41 10.12 23.85 3.64 14.71 00.51 2136 69.48 MWD+IFR-AK-CAZ-SC(5, 5) 22,106.90 90.34 192.40 8,136.16 23.89 -3.90 47+43 10.11 23.88 18,1 14.71 00.52 21,77 69.47 MWD+IFR-AK-CAZ-SC is. 5) 22107,13 90,35 192+40 6,136.18 23.09 5.90 47.43 tell 23.86 384 14.71 80.52 21.A 69.47 MWD+IFR-AK-CAZ-SC(5, 5) 22,200.00 90.35 192.10 6,135.80 23.95 .3.90 47.83 10.11 23.92 3.64 14.76 8166 22.12 89.25 MWD+1FR-AK-CAZ-SC(5, 5) 22300.00 90.35 192.60 6,134.99 24.02 .3.90 40.27 10.11 23.99 3.84 14.81 80.81 22,50 69,02 MWJFR-AK-CAZ-Etc(5, 5) 22,400,00 90,35 192.40 6134.39 24.09 -3.90 48.71 10.11 24.06 3.84 14.87 00.97 22.08 68.79 MW IFR-AK-CAZ-SC (5,5) 22,500.00 90.35 192.40 6,13338 24.16 .3.90 49.15 10.11 24.13 3,64 14.92 81.13 23.25 68.55 MWD+IFR-AK-C =(S. 5) 22,600.00 90.35 192,40 6,133.18 24.23 4.90 49.59 10.11 24.21 3.84 14.97 81.30 23.63 68.31 MW IFR-AK-CAZ-SC(5, 5) 22,700.00 90.35 192.40 6132.57 24.31 -3.90 50.04 10.11 24,28 3.84 15.03 81.46 24.01 68.06 MWDAFR-AK-CAZ-SC(5. 5) 22,800.00 90.35 192.40 8.131 97 24.38 -3,90 50.49 10.11 24.35 3.84 15.08 81.63 24.38 87.82 MWD+IFR-AK-CAZ-SC (5, 5) 22.00085 90.35 192.40 6,131,97 24.38 -3.90 50.49 10.11 24.35 3.84 15.08 81,63 24.38 67.82 MWD+1FR-AK-CAZSC(5, 5) 22810.04 90.00 192.29 6,131.91 24.37 4.84 50.,14 10.13 24.37 3.84 15.09 81+66 24.41 6739 MM+IFR-AK-CAZSC(5, 5) 22,900.00 88.38 192.29 6.133.06 24.36 4,54 50.52 10.13 24,43 3.84 15.14 8134 24.32 67.71 MWD+IFR-AK-CAVSC(5, 5) 22907.55 8823 192.29 8,133.20 24.39 -3.51 50.53 10.13 24.44 181 15.15 81,74 2431 6731 MM,HP-AK-CAZ-SG(5, 5) 23,000.00 80.23 192.29 6,1%.15 24.46 -3.51 50.79 10.13 24.51 3.84 15.21 01.87 24.43 67.55 MWD+1FR-AK-CA2-SC(5, 5) 23,10000 00.23 192.29 6.139,24 24,53 -3.51 51.24 10.13 24.59 3.05 15.27 82.04 24.80 67.31 MWD+1FR-AK-CA2-8C(6, 5) 23,200,00 88.23 192.29 a142.34 24.61 -3.51 51.69 10.13 24.66 3.85 15.33 8221 25.17 07.06 MWD+IFR-AKLA-SC(5, 5) 23,300,00 88.23 192.29 6,145.44 24.69 -3.51 5215 10.13 24.74 3.05 15.40 82.39 25.54 65.81 MWD+IFR-AK-CA-SC(5, 5) 23,400.00 88.23 192.29 a140.53 24.78 5.51 52.61 10.13 24.03 3.05 15.46 82.57 25,91 66.56 M=+IFR-AK-CAZ-SC(5, 5) 23,500.00 88.23 19229 6,151.63 24.06 -3.51 53.07 10.13 24.91 3.06 15.53 8235 26.27 65.30 MWD+IFR-AR-CAZ-SC(5, 5) 2$600.00 88.23 192.29 6,15432 24.94 4.51 53.53 10.13 24.99 3.05 15.59 82.93 26.06 6605 MWD+IFR-MK--SC (5.5) 23,700.00 88.23 192,29 8,157.82 25.03 41.51 53.99 10.13 25.08 3.05 15.06 83.12 27,00 55.79 1JMA+1FR-AK-CAZ-SC(5,5) 23,000.00 88.23 192.29 6,160.92 25.11 -351 54.46 10,13 25.16 3.85 15]3 83.30 27.36 65.53 MM+IFR-AK-CA -W (5, 5) 23,837.88 88.23 192,29 6,162.09 25.14 .3.51 54.64 10.13 25.19 3.87 15.75 83.38 27.50 65A3 MWD+IFR-AK-CAZ-Sic(5, 5) 23,854.50 87.90 192.35 6,162.65 25.17 -3.44 54.75 10.12 25.21 3.87 15.76 03.40 27.52 65.40 MWD+1FR-AK-CAZ-SC(5,5) 23.870.64 87,50 192.37 6,163.29 25.19 -3.38 54.78 10,12 25.22 3.87 15.71 83.42 27.50 8539 MW0+1FR-AK-0AV-SC(5, 5) 23,9110.00 87.58 192,37 6184.53 25.22 .3.30 54.86 10.12 25.25 3.87 15.79 83.46 27.53 65,34 MWD+1FR-AK-CAV-8C(5, 5) 24,000.00 87,58 192.37 616836 25.31 -3.38 55.33 10.12 25.33 3.87 15.86 0.65 27.89 65.08 MVVD+1FR-AK-CAZ-SC(5,5) 24,100.00 07.58 192.37 6.172.99 25.39 -3.38 55.80 10.12 25.42 3.88 15.93 83.85 28.25 64,81 MWD+IFR-AK-CAZ-GC(5, 5) 24,197+41 87.58 192.37 6,177.10 25.48 -3.38 56.26 10,12 25.51 3.88 16.00 84.04 20.59 64.56 MWD+IFR-AK-CAZ-SC(5, 5) 24,200.00 87.63 192.37 6177.21 25.48 -3.39 56.27 10.12 25.51 3.88 16.00 84.04 28.60 64,55 MWD+IFR-AK-CAZSC(5,5) 24.300.00 89.62 192.25 6,179.61 25,58 -3.00 56.63 10.14 25.60 3.88 16.07 84.24 28.95 64.20 MWD+IFR-AK-CAZSC(5, 5) 12/11/2018 10..46:51AM Page 8 COMPASS 5000.14 Build 85D Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Plan: 2M-39 Wellbore: Plan: 2M-39 Design: 2M-39wpl5 Position uncertainty and bias at survey station ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output error are at Database: Well Plan: 2M-39 As Built: 39 + 100.7 Q 139.70usit (Doyon142) As Built: 39 + 100.7 @ 139.70usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMP7 W..d Inclination AzimaS Vai..1 Rlualee Lateral VerOml Ma9neuee Semimajm Semi+niner Depm Mph Errs Bias Error Bps E., apo, daias Error Emr Azimuth Tod (ush) 19 1°I (usrt) loan) (um) lush) fum) (.ft) lud) (UM) (--ft) (-ft) (1) 24.318.79 90.00 192.22 6,17967 2562 -3.88 5630 10.15 25.62 3.68 16.08 84.28 29.02 64.23 NMAFR-W-CA -SC (5. 5) 24,400.00 92.03 19211 6,170.23 25.93 -4.30 57.07 10.15 25.69 3.88 16.13 84.44 29.30 64.01 MWD+IFR-AK-CA -SC (5, 5) 24.464.33 93.64 192.20 6,175.05 28.32 .4.63 57.37 10.15 25.75 3.88 16.18 84.58 29.53 63,84 MM+IFR-AK-CA-SC(5, 5) 24,500.00 93.64 192.20 8,172.79 26.35 -4.63 57.54 10.15 25.78 3.68 16.17 8665 29.65 63.74 MW -IFR-AK-CA -SC (5, 5) 24,553.36 93.64 192.20 6,169.40 26.40 -4.63 57.79 10.15 25.83 3.88 16.19 84.76 29.84 63.60 MWO11FR-AK-CA-SC(5, 5) 24,600.00 92.47 192.23 6,1fi6.91 26.19 -4.39 57.95 10.15 25.86 3.87 16.22 84.83 29.89 83.52 MP +IFR-AK-CA-SC(5, 5) 24,690.94 90.00 192.30 6.164.78 25.97 -3.87 58.09 10.13 25.7 3.87 16.27 04.93 29.76 63.45 MMNFR-AK-CA-SC(5. 5) 24,J00.00 90.05 192.30 6.164.78 25.97 -787 0.09 10.13 25.7 3.87 16.27 04.93 29.76 WA5 MWWIFR-AK-CA -SC (5, 5) 24,800.00 90.00 192.30 6,164.78 26.7 -3.7 58.57 10.13 26.07 3.87 16.33 85.14 30.10 0.18 MWSHIFR-M-CA-SC(5, 51 24,900.00 90.00 192.30 6,164.78 26.16 -387 59.05 10.13 26.16 3.87 16.39 85.35 30.44 62.90 MWD+IFR-AI(- -SC (5,5) 25.000.00 90.00 192.30 6,164.78 28.26 -3.87 59.54 10.13 26.26 3.87 16.45 85.57 3038 62.63 MWDNFR-AK-CA -SG (5, 5) 25,100.00 90.00 192.30 6,164.78 26.35 -3.87 60.02 10.13 28.35 3.87 16.51 85.79 31.12 62.35 MwD*IFR-AK-CPZ-SC(5, 5) 25,146.41 90.00 192.30 6,164.78 26.40 4.7 60.25 10.13 26.40 3.87 16.54 85.09 31.28 62.22 MWD+IFR-AK-CA-SC(5, 5) 25.172.64 89.49 192.41 6,184.90 26.40 -3.76 60.43 10.11 26.43 3.87 16.56 85.93 31.30 62.18 MM+1FR-AK-0A -SC (5. 5) 25,200.00 89.49 192.41 6.165.14 2 A2 -3.76 60.51 10.11 26.45 3.87 16.57 85.97 31.33 62.13 MWDEFR-AK-CA2-SC (5,5) 25,300.00 89.49 192.41 6,166.03 26.52 4.76 60.99 10.11 26.55 3.87 16.64 86.20 31.67 01.86 MMOFR-AK-C -SC (5, 5) 2$.400.00 89.49 192.41 6,166.93 26.62 -336 61.40 10.11 26.85 3.87 16.70 86.42 32.00 61.58 MWD+IFR-AK-CA-SC(5,5) 25,500.00 89.49 192.41 6,167.02 26.72 -336 61.97 10.11 26.75 3.87 16.77 86.65 32.33 61.29 MM+IM-AK-CA-SC(6, 5) 25,600.00 89.49 192.11 6.10.71 26.83 -3.76 62.46 10.11 26.85 3.88 16.83 88.88 32.65 61.01 MMOFR-AK-GA-SC(5.5) 25,636.09 89.49 192.41 6.169.03 26.88 -336 62.64 WAI 26.89 3.88 18.85 06,97 32.77 6D.91 MM+IM-AK-CA-W(5. 5) 12111/2018 10: 46.51AM Page 9 COMPASS 5000.14 Build 85D 9 ConocoPhillips Error Ellipse Report Company: ConocoPhillips (Alaska) Inc. -Kup2 Local Co-ordinate Reference: Well Plan: 2M-39 Project: Kupamk River Unit TVD Reference: As Built 39+ 100.7 @ 139.70usft (Doyonl42) Site: Kuparuk 2M Pad MO Reference: As Built, 39+ 100.7 @ 139.70usft +E/ -W Northing -Shape V) (Doyonl42) Well: Plan: 2M-39 North Reference: True Wellbore: Plan: 2M-39 Survey Calculation Method: Minimum Curvature Design: 2M-39wpl5 Output errors are at 1.00 sigma Database: OAKEDMPI Design Targets Target Name -hil/miss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing -Shape V) (1) (usft) (usft) (usft) (usft) 2M-39 T03 020818 JM 0.00 0.00 6,068.09 -4,241.15 -13,570.08 - plan hits target center - Circle (radius 100.00) 2M-39 T01 Heel 020818 0.00 0.00 6,072.70 -3,206.71 -13,370.76 - plan hits target center - Circle (radius 1,320.00) 2M-39 T04 020818 JM 0.00 0.00 6,078.73 4,925.46 -13,719.97 - plan hits target center - Circle (radius 100.00) 2M-39 T05 020818 JM 0.00 0.00 6,082.98 -5,947.94 -13,943.30 - plan hits target center - Circle (radius 100.00) 2M-39 T02020818 JM 0.00 0.00 6,093.62 -3,877.61 -13,492.71 - plan misses target center by 8.57usft at 17722.82usft MD (6085.79 TVD, -3876.21 N. -13495.89 E) - Circle (radius 100.00) 2M-39 T06 020818 JM 0.00 0.00 6,117.02 -6,566.22 -14,078.30 - plan hits target center - Circle (radius 100.00) 2M-39 T07 020818 JM 0.00 0.00 6,121.27 -7,151.49 -14,206.34 - plan hits target center - Circle (radius 100.00) 2M-39 T10020818 JM 0.00 0.00 6,131.91 -8,853.28 -14,578.57 - plan hits target center - Circle (radius 100.00) 2M-39709020818 JM 0.00 0.00 6,136.16 -8,157.95 -14,425.71 - plan hits target center - Circle (radius 100.00) 2M-39 T08 020818 JM 0.00 0.00 6,144.67 -7,794.79 -14,346.30 - plan hits target center - Circle (radius 100.00) 2M-39771013018 JM 0.00 0.00 6,162.65 -9,864.74 -14,798.93 - plan hits target center - Circle (radius 100.00) 2M-39 T14013018 JM 0.00 0.00 6,164.78 -11,126.32 -15,073.87 - plan hits target center - Circle (radius 100.00) 2M-39 T13 013018 JM 0.00 0.00 6,164.78 -10,689.12 -14,978.59 - plan hits target center - Circle (radius 100.00) 2M-39 T15 Toe 013018. 0.00 0.00 6,169.03 -11,604.55 -15,179.10 - plan Yu[s target center - Circle (radius 1,320.00) 2M-39 T12 013018 JM 0.00 0.00 6,179.67 -10,317.95 -14,898.19 - plan hits target center - Circle (radius 100.00) Easting (usft) Latitude Longitude 12/112018 10..46:51AM Page 10 COMPASS 5000.14 Build 85D Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Plan: 2M-39 Wellbore: Plan: 2M-39 Design: 2M-39wp15 Casing Points Hole Diameter Measured Vertical (in) Depth Depth 9.625 (usft) (usft) 9.875 2,860.65 2,640.00 13-318 x 16 15,721.70 5,800.00 9-5/8 x 12-1/4 17,038.55 6,072.70 7" x 8-1/2 by 9-7/8" 25,636.09 6,169.03 4-1/2x6-1/8 Formations ConocoPhillips Error Ellipse Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Name Well Plan: 2M-39 As Built: 39 + 100.7 @ 139.70usft (Doyon -142) As Built: 39 + 100.7 @ 139.70usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMPI Casing Hole Diameter Diameter (in) (in) 13.375 16.000 9.625 12.250 7.000 9.875 4.500 6.125 Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (0) (�) 452.74 452.70 T-3 0.00 581.96 581.70 K-15 0.00 1,501.27 1,479.70 Base Penn 0.00 2,083.16 2,013.70 W Sak D 0.00 2,813.59 2,605.70 Base WS 0.00 3,431.85 2,978.70 Camp SS 0.00 8,597.13 4,177.70 C-50 0.00 10,808.18 4,674.70 0-37 / Iceberg 0.00 13,971.25 5,385.70 C-35 0.00 15,774.21 5,812.70 THRZ 0.00 16,526.70 5,973.70 K-1 0.00 16,710.62 6,009.70 BHRZ/TKLB 0.00 17,038.55 6,072.70 Top Kup 0.00 1211112018 10'46'51AM Page 11 COMPASS 5000.14 Build 85D Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2M Pad Well: Plan: 210-39 Wellbore: Plan: 2M-39 Design: 2M-39wp15 Plan Annotations ConocoPhillips Error Ellipse Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well Plan: 2M-39 As Built: 39 + 100.7 @ 139.70usft (Doyonl42) As Built: 39 + 100.7 @ 139.70usft (Doyon142) True Minimum Curvature 1.00 sigma OAKEDMPI Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 39.00 39.00 0.00 0.00 KOP: Start 1.5°/100' DLS, 305" TF, for 700' 300.00 300.00 0.00 0.00 Start 2°/100' DLS, -30° TF, for 448.76' 1,000.00 996.09 36.69 -52.39 Hold for 105.64' 1,448.76 1,430.00 86.17 -153.64 Start 2°/100' DLS, -27° TF, for 1306.24' 1,554.41 1,530.00 98.37 -185.44 Hold for 20' 2,860.65 2,640.00 208.54 -843.22 Start 3.91*/100'DLS, -22.68°TF, for 900' 2,880.65 2,654.47 209.55 -856.99 Hold for 10900' 3,780.65 3,095.05 162.05 -1,624.17 Start 4"/100' DLS, -96.66° TF, for 1640.17' 14,680.65 5,545.16 -1,499.45 -12,114.46 Hold for 433.68' 16,320.82 5,933.40 -2,519.75 -13,217.67 Start 4'/100'DLS, -85.42°TF, for 84.05' 16,754.50 6,018.29 -2,932.91 -13,318.50 Hold for 200' 16,838.55 6,034.54 -3,013.55 -13,335.66 Start Will 00' DLS, 1.66' TF, for 555.62' 17,038.55 6,072.70 -3,206.71 A3,370.76 Hold for 165.79' 17,594.17 6,098.48 -3,750.44 -13,471.95 Start Tit 00' DLS, 166.41° TF, for 335.94' 17,759.96 6,082.13 -3,912.51 -13,502.81 Adjust TF to 177.04°, for 1.61' 18,095.90 6,068.09 4,241.15 -13,570.08 Hold for 631.97' 18,097.50 6,068.11 4,242.72 -13,570.42 Start 1°/100' DLS, -2.96°TF, for 67.05' 18,729.47 6,078.07 4,859.97 -13,705.64 Hold for 1046.59' 18,796.52 6,078.73 4,925.46 -13,719.97 Start 2°/100' DLS, -179.84° TF, for 207.34' 19,843.11 6,062.98 -5,947.94 -13,943.30 Hold for 227.95' 20,050.45 6,091.32 -6,150.30 -13,987.48 Start 2°/100' DLS, 0.45° TF, for 198.66' 20,278.39 6,108.73 -6,372.35 -14,035.94 Hold for 599.13' 20,477.05 6,117.02 -6,566.22 -14,078.30 Start 2°/100' DLS, -177.82° TF, for 126.17' 21,076.18 6,121.27 -7,151.49 -14,206.34 Hold for 239.75' 21,202.35 6,124.94 -7,274.70 -14,233.19 Start 1°/100' DLS, 1.75° TF, for 292.93' 21,442.09 6,137.19 -7,508.69 -14,283.97 Adjust TF to -0.36°, for 216.64' 21,735.03 6,144.67 -7,794.79 -14,346.30 Hold for 63.93' 21,951.66 6,140.56 -8,006.38 -14,392.54 Start 2°/100' DLS, 177.52° TF, for 91.3' 22,015.60 6,138.16 -8,068.80 -14,406.17 Adjust TF to 17.7°, for 0.23' 22,107.13 6,136.16 -8,158.18 -14,425.75 Hold for 693.53' 22,800.65 6,131.97 -8,835.51 -14,574.69 Start 2.1100' DLS, -162.3° TF, for 18.18' 22,818.84 6,131.91 -8,853.28 -14,578.57 Adjust TF to -179.98°, for 88.72' 22,907.56 6,133.28 -8,939.95 -14,597.46 Hold for 930.32' 23,837.88 6,162.09 -9,848.51 -14,795.38 Start Till 00- DLS, 168.86° TF, for 16.62' 23,854.50 6,162.65 -9,864.74 -14,798.93 Adjust TF to 176.39°, for 16.15' 23,870.64 6,163.29 -9,880.50 -14,802.38 Hold for 326.76' 24,197.41 6,177.10 -10,199.39 -14,872.34 Start 2°/100'DLS, -3.61°TF, for 121.38' 24,318.79 6,179.67 -10,317.95 -14,898.19 Start 2.5°/100'DLS. -0.36°TF, for 145.54' 24,464.33 6,175.05 -10,460.10 -14,928.95 Hold for 89.03' 24,553.36 6,169.40 -10,546.94 -14,947.72 Start 2.51100' DLS, 178.47° TF, for 145.59' 24,698.94 6,164.78 -10,689.12 -14,978.59 Hold for 447.47' 25,146.41 6,164.78 -11,126.32 -15,073.87 Start Till 00' DLS, 167.16* TF, for 26.23' 25,172.64 6,164.90 -11,151.95 -15,079.49 Hold for 463.45' 25,636.09 6,169.03 -11,604.55 -15,179.10 TD: 25636.09'MD, 6169.03'TVD Checked By: Approved By: Date: 1211112018 10,46:51AM Page 12 COMPASS 5000.14 Build 85D Pool Report K3 v .IV �t IV 2.7-1 v I F2 I I ;rM '2M-40wp12 9:45, December 112018 210-39wp15 WELLBORE Nur210-39 210-39 T03 OM020618 JM TARGET DETAILS (MAP CO-ORDINATES) ND 0.00) BOR.70Ckcle (Casis (Radius 1320.00) adius 100.00) Quarter Mile View 21039 OB 020818 JM 210-39 TOS 020818 JM 80>298 Case(Radius 10000) 6002.98 Ctrtle (Radius: 100.M 21639 TM 020810 JM 0117.02 Circle (RaOXIS: MOD) 28439 TOT 020810 JM 2N1-30 TOB 020810 JM 6121.27 C" (Rai 100.00) 6144.67 Ciade (Radius 100.00) 28439 TO9 02M18 JM6136.10 21039 T10 02M18 Jul Cftk (RaElus: 100.00) 0131.91 C1rct (Rdli IN.Oq AC Only 21030 T11013018 JM 28439 T12013018 JM 6102.65 Clot Radius 100JM) 617917 CCI=(Riii 110110) 210-39 T13013018 JM T14013013 JM 6161]8 Cute (Rai 1100M)21039 615078 CMA (Radius 1000i 21Ar3 15 Toe 01301 It - WiriJa (Radws 132000) 28103 02061 2 C,d (Radius 10000) 3500 n a � o m 6 O da N OtWI®� o om 1 O 7 C) -3500 ° z -7000 M-," 1I? � 7 210.04 210-09 U) 210-gpWP12' -08 -10500 '2& 14 2M32L1PB2 <� 210-0 1-01 2M-OBi-i -14000 -21000 -17500 -14000 -10500 -7000 -3500 0 3500 7000 9:59, December 112019 2M-39wp15 Quarter Mile View O All Wells Y 3500 0-� 6 o -3500 0 Co L L Z —7000 WELLBORE TARGET OETAIL6 (MAP Cp OIHA7E5) oom TVG 69., 2M-39 T01 Hee1420016 JM 0072.7=C (R.fta 132D.M 2M R TW 020618 JM 0088.08 Letle (Radius: IDO.OD) 2M39 70/020818 JM 8078.73 CW(Rales: 100.00) 2M 9 705 020616 JM 6082.98 CnIe (Halos: 100.M 2M-39705020610 JM 6117.0201 (Radius: 100AD) 2M-39 T0702D610 JM 6121.27 Cede (Radius: 100.00) 2M O T00 020810 JM 6111.67 Cetle (Rad s.. MOD) 2M 9T09020818 JM 61WAR Ci,r (RaWS 100.00) 2M 9TIO OM18 JM 6131.91 Link(Ra'lu.'. 100.00) 2M d'9 Al D1MI8 JM 6162.65 Cltl (RadWs'. 10000) 2 9T120t3018 JM 8179.87 Cirq (Rains: 10000) 2M 9 T13 0=8 JM 0161)9 Gtle (Rains: 100.00) U) "vl.gDWPiy? 4 -10500 ZS -14 241-32E.1 P82 _.... _. 2M-392�`lv 2 z 'W 1 2M. -x. 0 -01 1 -14000 -21000 -17500 -14000 -10500 -7000 -3500 WPstl_1lFast/+1 13..,;nn iicft/int ,1 4 2M -D9 Y 0 3500 io;S1i 110:02, December 11 2016 01171. C) -3500 Co Z -7000 7 O 10500 6U111161 2M-39wp15 WELLBORE TARGET DETAILS (MAP C6ORDINATES) Nama ND 69a, 6138.10 Cite (Radius'. 100A0) Q All Wells — Encroachment Only 210-39 T01 Heel 029818 JM 6072.70C ucte (Radius: 1320.80) 6131.91 Circle Radus: 10(1,00) 6179.67 SCiie!eass, (Radius: 10000) 699.0> CNcb (Rados: 100A0) YY 210-35 T03 020010 JM 2!1039 TW 020018 JM 0088.09 C¢Ge (Radius: 100.00) 80]8.]3 Clyde (Radius: 100.00) Quarter Mile View 21039 T. 020810 JM 05 8082.98 CNe (Radius: MOD) 6164J8 Cade (Radius 10000) C (R(Redas110000j'. O 28439 TOB 020810 JM 2W39T0T 020818 JM 2111M JM 819.02 ODc1e (Radius: 100.00) 6121.27 CMe (Rediva: 1C0.0p) 6110 B]CYd Red '1000 000362Ord, O 21039 TOB 02 18 JM 6138.10 Cite (Radius'. 100A0) Q All Wells — Encroachment Only 21049 T10 020818 JM 21449 T11013D18 JM 21039 T120 13010 JM 6131.91 Circle Radus: 10(1,00) 6179.67 SCiie!eass, (Radius: 10000) 699.0> CNcb (Rados: 100A0) YY 21039 711013018 JM 618418 CIMe (Rados: MOD) N 2NL39 T1{ 013016 JM 2� T15 Toe 14 6164J8 Cade (Radius 10000) C (R(Redas110000j'. O 210 t902W18 JJ18 M 000362Ord, aW ft®4 - Ii _. 6000 /0100 .....110.0 '... _. I N a 2K-29 6100 ro y o Y -047 4 6jp0 00 -21000 -17500 -14000 -10500 -7000 -3500 0 3500 7000 2M-39wp15 Surface M CPAI Coordinate Converter Now Datum: NAD83 Region: alaska T Latitude/Longitude IDecimal Degrees f UTM Zone: F- r South T State Plane Zone: 1" .-] Units: us -ft I- Legal Description (NAD27 only) Starting Coordinates. - - -- - — X: 1628002.70 Y: 5940735.34 M-39wp15 Surface M CPAI Coordinate Converter nom. Datum: NAD63 Region: alaska C' Latitude/Longilude IDecimal Degrees . !i f UTM Zone: r- r- South G State Plane Zone I' J Units: us -fl C' L>p: y'Dc'.nipli-x:(i•li=.i :7 aayl ❑ x To:— Datum: o: Datum: INAD27 — Region: alaska . C Latitude/Longitude Decimal Degrees * UTM Zone: True r South f• State Plane Zone: r -7D Units: us -ft C Legal Description (NAD27 only( - Ending Coordinates -- --- X 487969.819328432 Y.* 5948985-2544432 ': Transform Quit Help - ❑ x Datum NAD27 Region: alaska . C Latiude/Longitude IDecimalDegrees * UTM Zane: True r South * State Plane Zone: Unls: us -It f Legal Description (NAD27 only( F,I,ng Coordinates:-- -- rLegalDescription- X 162800270 Township: 011 rN -,I Range: 008 Y: 5948735.34 Meridian: I" ----,l Section: 27 FAL 5166.6026 FEL 5150.4794 Transform I Quit I Help 12M-39wi315 Production Horizon I D CPAI Coordinate Converter Datum: INAD83 Region: lalaska C Latitude/Longitude IDecirnalDegrees C UTM Zone: 1-- r South * State Plane Zone:Units: us -fl C Legal Description (NAD27 only) - ❑ x To:_ Datums F627 --:D Region: alaska * Latkude/Longitude IDecimal Degrees f UTM Zone: Trw r South * State Plane Zone: I' Units: us -ft r Legal Description (NAD27 orr(yr Starting Coordinates: Ending Coordinates: X: 1614628.10 X: 474594.92763131 Y: 5945551.53 ! Y: 5945801.73785128 2M-39wp15 Production Horizon M CPAI Coordinate Converter DatumNAD83 Region: alaska !` Latitude/Longilude IDecimalDegrees C UTM Zone: F— r"" South R Slate Plane Zone. I" -�-:] Units: us -It r^ _ n„ spat Starting Coordinates: X: 1614626.10 i Y. 5945551.53 ___Tranorm__ Quit Help - ❑ x Datum NAD27 Region: alaska r Latitude/Longitude 1i)ecimal Degrees r UTM Zone: True r South • State Plane Zone: 1' -J Units: us -0 S Legal Descriplicn (NAD27 only) - Legal Deso ipliom-----_.--..-- ----- Township: 011 I"J Range: DOB Meridian: 1" J Section 31 FNL 3103.6866 FEL . 26.88.3066 ,.,.,.Transform ; Quit I Help 2M-39wp15 TD M CPAI Coordinate Converter From:-- Datum: NAD83 Region:alaska f Latitude/Longitude IDecimalDegrees C UTM Zone: r- r South G State Plane Zone: Units: usdt r Legal Descrgrtion (NAD27 only) ❑ x To. - Datum: NAp27 Region: alaska f Latitude/Longitude IDecimaiDegrees r UTM Zone: True r South G State Plane Zone: F --J] Unks us -fl r Legal Description(NAD27ordyj r Starting Coordinates - - Endng Coordinates: ------ X: 4 X: 1612806 72772.638340161 Y: 5937157 Y 5937407.3839219 _ Transform_ QuitHelp 2M-39wp15 TD ra CPAI Coordinate Converter From: - — Datum: NAD83 . Region: Alaska f Latitude/Longitude IDecimalDegrees f UTM Zone: r South G Slate Plane Zone:Units: usft t' L-os!De-r;,roia(IJ::.p2, Dotal Coordinates: -- X: 1612806 Y. 5937157 - ❑ x To, Datum NAD27 Region: Alaska - (' Latitude/Longitude Decimal Degrees !, r UTM Zone: True r- South T State Plane Zane: Unlr. Ifuft t ' Legal Description (NAD27 only) - Legal Description- - - -- --- Township: 010 P`=t Range: 008 1` J Meridian: r----� Section:�- FNL 1945.54543 FEL 4514.8939 Quit I Help .............................. Tollerable Collision Risk Worksheet 3 18/19/lq LGM I JLS I I AB 37 & 38 Per K160005ACS 14 19/25/11 LGM I JLS I lRevilsed Per K180005ACIt ITM77-1 ASP GRI z 16 15 14 2ACHOF 13 DS2M 26 • 25 • 24 • 38423 22 • 21 • 20 • 41 19• 35X18 34 • 17• 33 • 16• 1531• 14• 13• 12 • 11 • 10 • 39 *9 869A 608A 4045 2Y6A 19 5A 27 34 23 21 22 d_r. LO sim-=11M NOTES: 1. BASIS OF LOCATION AND ELEVATION IS D52M MONUMENTATION PER LOUNSBURY & ASSOC. 2. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, N.A.D. 27, AND GEODETIC COORDINATES ARE NAD 27. 3. ELEVATIONS ARE B.P.M.S.L. 4. ALL CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIONS 27 & 28, TOWNSHIP 11 NORTH, RANGE 8 EAST, UMIAT MERIDIAN, ALASKA 5. DATES OF MOST RECENT SURVEY: 9/23/2018 BK: L18-36 PG: 18-22. 6. ALL DISTANCES SHOWN ARE GROUND LEGEND o AS—BUILT CONDUCTOR LOCATION 36 • • EXISTING CONDUCTOR LOCATION 36 28 33 XPLUGGED & ABANDON CONDUCTOR LOCATION 29; 30 22ggA g 32,A ?R 37499 SEE SHEET 2, 3 & 4 FOR LOCATION INFORMATION ips 3, Inc. 1 GRAPHIC SCALE 0 50 100 200 1 inch = 100 ft. LOUNSBURY & ASSOCIATES, INC. :M.m BNGN . PIWIN DS2M WELL CONDUCTOR CEA-D2MX-6213D29 EV DATE DY CK APP DESCRIPTION REV DATE aY CK APP DESORPHON 3 8/19/1 LGM JLS AB 37 & 38 Per K160005AC$ 4T9/24/11 LGM JLS Revised Per K180005ACS CONDUCTORS T. ARE LOCATED 10 N., R. 8 E., IN PROTRACTED SECTION 27, UMIAT MERIDIAN Well No. NAD 27 ASP Coordinates NAD 27 Geographic Coordinates Section Offset Elev. Y X Lat. Long. F.S.L. F.W.L. O.G. PAD 21 5,948,985.88 488,319.18 N 70' 16' 18.585" W 150' 05' 40.098" 114' 479' 99.7' 105.3' 22 5,948,985.77 488,344.40 N 70' 16' 18.585" W 150' 05' 39.364" 114' 504' 99.7' 105.0' *23 5,948,985.83 488,368.91 N 70' 16' 18.586" W 150' 05' 38.650" 114' 529' 99.6' 104.9' 24 5,948,985.75 488,394.29 N 70' 16' 18.585" W 150' 05' 37.911" 114' 554' 99.5' 104.9' 25 5,948,985.79 488,419.22 N 70' 16' 18.586" W 150' 05' 37.186" 114' 579' 99.4' 104.9' 26 5,948,985.92 488,434.76 N 70' 16' 18.588" W 150' 05' 36.733" 115' 594' 99.4' 104.9' 27 5,948,985.97 487,844.42 N 70' 16' 18.579" W 150' 05' 53.921" 114' 4' 100.9' 105.5' 31 5,948,985.64 488,156.27 N 70' 16' 18.581" W 150' 05' 44.841" 114' 316' 100.2' 104.7' 33 5,948,985.93 488,206.85 N 70' 16' 18.584" W 150' 05' 43.369" 114' 367' 100.0' 104.7' 34 5,948,985.32 488,232.32 N 70' 16' 18.579" W 150' 05' 42.627" 114' 392' 99.9' 104.6' 35 5,948,986.23 488,256.36 N 70' 16' 18.588" W 150' 05' 41.928" 115' 416' 99.9' 104.7' 38 5,948,986.00 488,364.41 N 70' 16' 18.591" W 150' 05' 38.781" 115' 524' 101.0' 101.3' *39 5,948,985.25 487,969.82 N 70' 16' 18.574" W 150' 05' 50.270" 113' 129' 100.7' 100.7' *40 5,948,985.28 487,899.20 N 70' 16' 18.573" W 150' 05 * CONDUCTOR ASBUILT THIS SURVEY ** PLUGGED AND ABANDONED WELLS LOUNSBURY e ASSOCIATES, INC. S�EY0R9 ENCINESRS PWNNSRS ConocoPhillips Alaska, Inc. AREA: 2M MODULE: XXXX DS2M WELL CONDUCTOR ASBUILT LOCATION UNIT: D2 CADD FILE N0. LK6213D29 1/13/07 DRA9NG NO. CEA-D2MX-6213D29 PART: 3 OF 4 REV: 4 ' 52.326" 113' 59' 100.8' 100.7' *41 5,948,985.35 488,281.25 N 70' 16' 18.580" W 150' 05' 41.203" 114' 441' 99.9' 100.5' ■ Tier 1: Standard ■ Intervals without issues noted for Tier 2 or 3 ■ Tier 2: Challenging Orientation ■ Drilling within 30' of horizontal inclination AND drilling within 30' of magnetic East/West azimuth in extreme northern or southern locations ■ Tier 3: Critical Steering ■ Driller's Target of 50' Radius or Less ■ Lease line constraint ■ Small Geologic Target ■ Failure of Major Risk Rule (Close Approach) ■ Defined during directional planning, based on the positional uncertainty ■ Theoretical intersection of the path of the well being planned with an offset well ■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented ■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges ■ Tier 1 (Standard): ■ Directional interval across which no special mitigations are needed ■ Tier 2 (Challenging Orientation): ■ Increase non-magnetic insulation of MWD tool in the BHA ■ Take rotational check shots and/or increase survey frequency at the start of a BHA run ■ Alter well directional plan, if feasible ■ Consider gyro surveys where feasible ■ Tier 3 (Critical Steering): ■ Increase survey frequency across critical interval ■ Increase correction frequency across critical interval ■ Take rotational check shots and/or increase survey frequency if the critical interval is at the start of a BHA run ■ Define escalation based on deviation from plan ■ Minor Risked close approach intervals with a high financial or scope risk should strongly consider the use of relevant mitigations ■ Tier 4 (Critical Steering & Challenging Orientation): ■ Consider all Tier 2 & 3 mitigations A_•iei�siii Sun: n aff ConocoPhillips 2M-39 Drilling Hazards Summary 16" Surface Section - 13-3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low Reduced pump rate and low mud temperatures. Additions of ScreenKleen. Abnormal Reservoir Pressure Moderate Offset well 2M-36 experienced severe mud loss and 2M - Lost Circulation Moderate 38 had minor losses. Ensure enough lost circulation material on location. Reduce drilling ROP and trip speed Lost Circulation Moderate when necessary. Hole swabbing on trips Moderate Reduce tripping speed, proper hole filling (use of trip sheets , um out of hole if necessary. Hole swabbing on trips Moderate Monitor real time surveys closely, run gyro survey to Anti -Collision Low 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" INTRM 1 Section - 9-5/8" Casing Interval Hazard Risk Level Mitigation Strate Stuck Pipe Loi„ Keep good hole cleaning practices, monitor ECD via PWD and torque/drag real time The Iceberg formation pressure is estimated to be Abnormal Reservoir Pressure Moderate l0.1ppg. Weight up mud to 10.3 ppg before drill into Iceber formation. Monitor ECD to below expected formation fracture Lost Circulation Moderate gradient. Prepare enough lost circulation material on location. Reduce drilling ROP and trip speed when necessary . Perform OR FIT if necessary. Hole swabbing on trips Moderate Reduce tripping speed, proper hole filling (use of trip sheets), pump out of hole if necessary. U3 8-1/2"x9-7/8" INTRM2 Section -7" Liner Hazard Risk Level Mitigation Strategy Keep good hole cleaning practices, monitor ECD and Stuck Pipe Low torque/drag real time. Maintain constant bottom hole Abnormal Reservoir Pressure Moderate ressure with MPD. The intermediate II section is penetrating into the reservoir of Kuparuk C, which is estimated to be up to 10.5 Abnormal Reservoir Pressure Moderate ppg on this well. Utilize MPD for shale stability and pore pressure management. Shut in nearby injectors to prevent Lost Circulation Moderate ore pressure rise. Differential Sticking Low Monitor real time equivalent circulating density (ECD) to below expected formation fracture gradient. Prepare Lost Circulation Moderate enough lost circulation material on location. Reduce drilling ROP and trip seed when necessary. Hole swabbing on trips ModerateUse Reduce tripping speed, proper hole filling (use of trip Hole swabbing on trips Moderate sheets), pump out of hole if necessary 6-1/8" Production Section - 4-1/2" Liner Interval Hazard Risk Level Mitigation Strate The reservoir pore pressure of Kuparuk C on this well is estimated to be 6.5-10.5 ppg. Utilize MPD to manage and Abnormal Reservoir Pressure Moderate ensure wellbore overbalance. Shut in nearby injectors to revent ore ressure rise. Keep good hole cleaning practices, use PWD tools Stuck Pipe Low monitoring, stabilized BHA Reduced pump rates, mud rheology, use LCM program, Lost Circulation Moderate control ECD below expected fracture gradient Differential Sticking Low Follow mud program, keep pipe moving when able Monitor T&D real time for early signs of issues, properly Getting Liner to bottom Moderate clean hole prior to pulling out of hole to run liner. proper tripping speed, monitor proper hole fill (use Hole swabbing on trips ModerateUse of trip sheets), pumping or backreamin out if necessar Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, January 2, 2019 11:11 AM To: Lehman, Nick R Subject: KRU 2M-39(PTD 218-171) Cement and Anti -collision Nick, Please review the cementing calculations for the Intermediate #1: The shoe is at 15722' MD or 5800' TVD; cement is to be 500' TVD above shoe or 5300' TVD; 5300' TVD corresponds to 13600' MD shoe. I notice the cement calculations show cement 250' TVD above shoe while the schematic has 500' TVD above Also, the schematic is labeled as an injector. Please correct as needed. Also, please explain what mitigation measures will be in place for the failed major risk with 2M-09/ 2M -09A. Will 2M-09 be shut in with a deep plug? 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. Loeppaalaska.aov 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 of (907)793-1247 or Victoria.Loeoo@alaskaaaov Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, January 8, 2019 9:30 AM To: 'Lehman, Nick R' Subject: KRU 2M-39(PTD 218-171) Cement, Anti -collision and Op SD Nick, Thank you for the information. Please submit a diverter equipment schematic with each PTD although this information is on file with the AOGCC. The schematic you submitted was what I would like to see. 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. LoeooCa)alaska.00v CONFIDENTIALRY 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). If 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 if, 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.Loeoip@cilaska.gov From: Lehman, Nick R <Nick. R. Lehman@conocophillips.com> Sent: Sunday, January 6, 2019 8:12 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Woodard, Madeline E <Madeline. E.Wooda rd @conocophillips.com> Subject: RE: [EXTERNAL]RE: KRU 2M-39(PTD 218-171) Cement and Anti -collision Victoria, Thank you for your email. I apologize for any confusion and I appreciate your patience. I corrected the schematic and attached above to reflect TOC @ 250' TVD above the 9-5/8" Intermediate 1 shoe. Attached above is the equipment schematic for the diverter on Doyon 142 as well as the rig-on-diverter layout map (page 12 of PTD application request). o I was working under the belief that the diverter equipment information for D142 was already on file with AOGC - please let me know if the D142 diverter equipment schematic needs to be submitted with every PTD request moving forward. Attached above is a modified cover letter to include temporary suspension of 2M-39 allowing for Doyon 142 to assist with exploration drilling out on the ice. o Currently, I am estimating we will be able to drill, case, and cement the surface section before exploration needs Doyon 142. However, please note that it is a moving target right now since exploration needs the rig in a specific timeframe and 2M-41 completion date could push back if any unexpected issues are encountered. 21V-09 / 2M -09A is a Kuparuk injector that has been permanently plugged/abandoned, cut-off below ground level, and backfilled as of July 17, 2018. This well has been minor -risked and we will be utilizing gyro -while - drilling to take surveys as needed to ensure we drill to plan. Please let me know if you have any questions or need any other information. Regards, Nick Lehman Drilling Engineer I Conoco Phillips Alaska Office (907)263-4951 1 Cell (832)499-6739 Nick. R. Lehman@Conoco Phillips. com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, January 3, 2019 9:47 AM To: Lehman, Nick R <Nick.R.Lehman conocophillips.com> Cc: Woodard, Madeline E <Madeline.E.Woodard@conocophillips.com> Subject: [EXTERNAL]RE: KRU 2M-39(PTD 218-171) Cement and Anti -collision I now notice that the well class is listed as both a service well and development well. I will delete the development well class. The cement calculations should be based on 250' TVD above the shoe in the intermediate. Please correct the schematic. Please provide a diverter equipment diagram with sizing. I understand that there will be an Operations Shutdown of drilling operations after the surface hole. This should be included in the PTD in the cover letter outlining the current plans and how the well will be left. Thanx, Victoria From: Loepp, Victoria T (DOA) Sent: Wednesday, January 2, 2019 11:11 AM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: KRU 2M-39(PTD 218-171) Cement and Anti -collision Nick, Please review the cementing calculations for the Intermediate #1: The shoe is at 15722' MD or 5800' TVD; cement is to be 500' TVD above shoe or 5300' TVD; 5300' TVD corresponds to 13600' MD I notice the cement calculations show cement 250' TVD above shoe while the schematic has 500' TVD above shoe Also, the schematic is labeled as an injector. Please correct as needed. Also, please explain what mitigation measures will be in place for the failed major risk with 2M-09/ 2M -09A. Will 2M-09 be shut in with a deep plug? 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 Loeoo(dialaska.aov 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 Loeoa@alaska.aov From: Lehman, Nick R To: Boyer, David L (DOA) Subject: RE: [EXTERNAL]Digital Survey File for KRU 2M-39 PTD Application Date: Wednesday, December 19, 2018 2:39:38 PM Attachments: 2M-39wo15 data for AOGCC 1 2-19-18 zlsx Dave, Attached is requested digital survey file for 2M-39wp15. We will not be pre -producing 2M-39. Please let me know if you have any other questions and have a Merry Christmas. Regards, Nick Lehman. Drilling Engineer ConocoPhillips Alcsko Office (907)263-4951 1 Cell (832)499-6739 Nick R Lehmun(@ConocoPhifli sp com From: Boyer, David L (DOA) <david.boyer2@alaska.gov> Sent: Wednesday, December 19, 2018 2:15 PM To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com> Subject: [EXTERNAL] Digital Survey File for KRU 2M-39 PTD Application Hi Nick, I just began reviewing the PTD packet for KRU 2M-39 well today. Is it possible to e-mail over a digital survey file in Excel or ASCII format so we can input the data into the Graphics database? This saves a lot of time in the review process vs. scanning hard copies with associated optical reading errors. Also, is ConocoPhillips planning to pre produce this future WAG injector? Thanks, Dave Boyer Senior Geologist AOGCC Transform Points Source coordinate system Target coordinate system State Plane 1927 - Alaska Zone 4 Albers Equal area (-150) Datum: Datum: NAD 1927 - North America Datum of 1927 (Mean) NAD 1927 - North America Datum of 1927 (Mean) b ,RU,� 'Typevalues into the spreadsheet or copy and paste columns of data from a spreadsheet using the keyboard shortcuts Ctd+C to �opy and Ctd+V to paste. Then dick on the appropriate arrow button to transform the points to the desired coordinate system. < Back Finish Cancel Help TRANSMITTAL LETTER CHECKLIST WELL NAME: K R (A- 2�1 M��3T__ PTD: ::�L1 $ - 1 --7- 1 Development t/ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: KupavrukI r POOL: KU pa P—(4 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 f 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, vv 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 KUPARUK RIVER, KUPARUK RIV OIL - 490100 Well Name: KUPARUK RIV UNIT 2M-39 Program SER Well bore seg ❑ PTD#:2181710 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER / PEND_ _GeoArea 890 Unit 11180 On/Off Shore On-- Annular Disoosal ❑ Appr Date NA.. DLB 12/19/2018 12 NA.. _ 13 Leasenumberappropriate.--- ----- .._ 14 .... . . . . . . .... . . . . . 15 Yes 16 Well Located in a_ defined pool_ _ _ _ _ _ _ _ _ _ ...... _ _ _ _ _ _ _ .. _ _ _ _ _ 18 Engineering 19 Appr Date VTL 1/3/2019 Geology Appr Date 37 DLB 12/19/2018 38 Nonconven. gas conforms to A531,05,030(1.1.A),lj,2.A-D) . _ _ _ _ _ NA.. Permit. fee attached_ _ _ _ _ _ _ .. _ NA.. _ _ _ _ _ _ . . . . . .. . .... . . . . . .... . . . . . . ......... . . . . . Leasenumberappropriate.--- ----- .._ Yes------------------------------------------------------------------ .... . . . . . . .... . . . . . Uniquewell_nameandnumber _ _ _ Yes Well Located in a_ defined pool_ _ _ _ _ _ _ _ _ _ ...... _ _ _ _ _ _ _ .. _ _ _ _ _ Yes ....... Well located proper distance from drilling unit boundary, _ _ _ _ _ _______ _ _ _ _ _ Yes ----------------------- --- ---------- Well located proper distance from other wells.. _ _ _ _ _ _ _ _ _ _ _ _ _ Yes -------- ---- Sufficient acreage available in drilling unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes If deviated, is wellbore plat included _ _ _ .. _ _ _ _ _ ...... No.. _ _ Spider map shows wellpath, _ _ _ _ _ _ _____ Operator only affected party _ _ _ _ _ Yes Operator has appropriate bond in force _ _ _ _ _ .. _ Yes Permit can be issued without conservation order ...... Yes _ Kuparuk River OR Pool, governed by Conservation Order No. 4320 Permit can be issued without administrative.approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Can permit be approved before 15 -day wait_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes ... _ Area Injection Order No. 2C -_Kuparuk River Unit ... All wells _withio 1/4_mile area of review identified (For service well only).. _ _ _ Yes _ _ _ _ _ _ _ ____ Pre -produced injector: duration of pre production less than 3 months (For service well only) _ NA _ . _ .. _ . Well will not be pre -produced per COP. Conductor string provided _______ Yes ..... _ _ 80' conductor installed Surface casing, protects all known USDWs _ _ _ _ _ _ _ _ _ _ _ _ . Yes .... _ _ _ Surface shoe set at 2861' MD CMT vol adequate to circulate on conductor & surf esg _ _ _ ... _ _ _ ... Yes _ _ _ . 177% excess cement planned CMT vol adequate to tie-in long string to surf cs9. . . . . . . . .. . . . . ..... . . No. CMT will cover all known productive horizons.. _ _ _ _ _ _ No ..... Productive. interval will be completed with uncemented preperforoted liner. with swell packers Casing designs adequate for CJ, B &.permafrost .. . . . . . ......... . . . Yes Adequate tankage or reserve pit . . . . . . .......... . . . ... . . . . . . Yes _ Rig has steel tanks; all waste. to approved disposal wells If a. re -drill, has.a 10-403 for abandonment been approved _____ _ _ _ _ _ _ _ _ _ ____ _ _ NA _ _ ..... Adequate wellbore separation proposed ..... . . . . . . .. . . . . . ....... . _ Yes .. _ _ Anti -collision analysis complete; major risk failure 2Mr09/21VI-09A P&A'd If diverter required, does it meet regulations_ _ ..... .. _ _ _ _ Yes _ _ _ 16" diverter meets regulation as does the, route_ _ _ _ _ _ ______ Drilling fluid. program schematic & equip list adequate_ .... _ _ _ Yes ... Max formation pressure is 3316 psig(10.5 ppg EMW); will drill.w/ 8.8-12,2. ppg EMW _ BOPEs,.do they meet regulation _ _ _ _ ...... _ ....... Yes BOPE.press rating appropriate; test to (put psig in comments)__ _ _ _ _ ___ _ _ _ _ _ Yes . _ .. _ _ _ MPSP (s 2709 psig; will test BOPs_to 3500 psig Choke. manifold complies w/API RP -53 (May 84).. _ _ _ _ _ _ _ Yes Work will occur without operation shutdown, _ _ _ _ _ _ _ _ _ _ _ _ No _ _ .. _ Op SO will occur to allow Doyon 142 to assist with exploration operations during_ice road. season. Is presence of H2S gas probable _ _ _ _ Yes 1-12S measures required. Mechanical condition of wells within AOR verified (For service well only) _ Yes _ _ _ No other wells within the 114 mile AOR Permit can be issued w/o hydrogen sulfide measures _ _ _ _ _ _ No . Wells on 2M -Pad are KS -bearing, H2S measures required.. Data. presented on potential overpressure zones _ _ _ _ _ _ _ _ Yes Seismic analysis of shallow gas.zones_ _ . _ . . . . ....... . . NA_ Seabed condition survey (if off -shore). _ _ _ _ ..... _ _ _ .. ... _ _ NA Contact name/phone for weekly progress reports (exploratory only) . . . ........ . . . NA_ Geologic Engineering CoOm�sioner i Date: o ssioner. Date Date r ( e' I 1-,,
