The URL can be used to link to this page

Home My WebLink About221-052Originated: Delivered to:5-Jul-24 Alaska Oil & Gas Conservation Commiss 05Jul24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED CD4-586 50-103-20857-00-00 223-046 Colville River WL TTiX-PPROF FINAL FIELD 3-Mar-24 CD4-536 50-103-20863-00-00 223-079 Colville River WL TTiX-PPROF FINAL FIELD 7-Mar-24 2M-12 50-103-20181-00-00 192-090 Kuparuk River WL SCMT FINAL FIELD 8-Mar-24 1B-16A 50-029-22457-01-00 218-155 Kuparuk River WL RST FINAL FIELD 9-Mar-24 CD4-588 50-103-20853-00-00 223-029 Colville River WL TTiX-PPROF FINAL FIELD 22-Mar-24 CD5-23 50-103-20761-00-00 217-155 Colville River WL Packer Setting FINAL FIELD 24-Mar-24 3F-08 50-029-21464-00-00 185-246 Kuparuk River WL SCMT FINAL FIELD 30-Mar-24 2M-03 50-103-20160-00-00 191-141 Kuparuk River WL SCMT FINAL FIELD 31-Mar-24 2B-14 50-029-21143-00-00 184-111 Kuparuk River WL WFL FINAL FIELD 3-Apr-24 2T-41 50-103-20675-00-00 213-146 Kuparuk River WL PPROF FINAL FIELD 7-Apr-24 MT7-03A 50-103-20830-01-00 223-084 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 22-May-24 MT7-01 50-103-20832-00-00 221052 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 27-May-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39122 T39123 T39124 T39125 T39126 T39127 T39128 T39129 T39130 T39131 T39132 T39133MT7-01 50-103-20832-00-00 221052 Greater Mooses Tooth WL TTiX-Fiber FINAL FIELD 27-May-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.05 10:30:21 -08'00' TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Mooses Tooth DATE: 12/19/2023 Transmitted: North Slope, Mooses Tooth Unit Via hard drive data drop Moose's Tooth MT6-08 50-103-20772-00 218048_MT6-08_JetCutter_22Apr2022 218048_MT6-08_Puncher_02Feb2022 MT6-09 50-103-20779-00 218134_MT6-09_Puncher_18Feb2022 218134_MT6-09_SBHP_16Feb2022 218134_MT6-09_Tubing Cut_22Feb2022 MT7-01 50-10-320832-00 221052_MT7-01_Perf_29Oct2022 221052_MT7-01_PPROF_03Feb2023 MT7-02 50-103-20840-00 222026_MT7-02_ChemCut_21Dec2022 222026_MT7-02_Plug&Perf_17Apr2023 MT7-03 50-103-20830-00 221024_MT7-03_GR_12Aug23 221024_MT7-03_MechCutter_31Oct23 221024_MT7-03_RBP_1Nov23 MT7-05 50-103-20833-00 221087_MT7-05_PPROF_20Apr2023 221087_MT7-05_SCMT_25Dec2021 MT7-06 50-103-20831-00 221048_MT7-06_IBC-DSLT_04Oct2022 1of 3 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38419 T38420 T38421 T38422 T38423 T38424 T38425 2/29/2024 MT7-01 50-10-320832-00 221052_MT7-01_Perf_29Oct2022 221052_MT7-01_PPROF_03Feb2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 10:56:14 -09'00' Transmittal #1304 Detail Date: 5/2/2022 To (External Party): From (CPAI Contact): Email*: meredith.guhl@alaska.gov Email*: richard.e.elgarico@conocophillips.com First Name*: Meredith First Name*: Ricky Last Name*: Guhl Last Name*: Elgarico Phone Number:(907) 793-1235 Phone Number: (907) 265-6580 Company: AOGCC Company: ConocoPhillips Address: 333 W. 7th Ave. Address: 700 G Street City: Anchorage City: Anchorage State: AK State: Alaska Zip Code: 99501 Zip Code: 99501 Transmittal Info Sent Via: ShareFile Tracking #: Justification: Compliance Data Detail Quantity*: Description*: Type*: 1 CD5-93 Sonic TOC LAS, PDF 1 MT7-01 Sonic TOC LAS, PDF 1 MT7-03 Sonic TOC LAS, PDF 1 MT7-04 Sonic TOC LAS, PDF 1 MT7-05 Sonic TOC LAS, PDF 1 MT7-09 Sonic TOC LAS, PDF 1 MT7-96 Sonic TOC LAS, PDF Attachments: Received By: ___________________________ Signature: ___________________________ Date: _________________ Approver: ___________________________ Signature: ___________________________ Date: _________________ MT7-01 Sonic TOC PTD: 221-052 T36544 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.03 08:51:25 -08'00' 221-052 T36455 Originated: Halliburton Wireline & Perforating Attn: Fanny Haroun 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: 8-Apr-22 WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 1 MT7-01 50-103-20832-00 907726190 Greater M ooses Tooth Production Profile Field & Processed 25-Mar-22 0 1 2 3 MT7-01 is located in a federal oil and gas unit. Only with respect to the MT7-01 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com Meredith G u h I Digitally signed by Meredith Guhl Date: Signed: Date: 2022.04.08 10:21:20-08'00' ConocoPhillips TRANSMITTAL FROM: Sandra D. Lemke, ATO-704 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 71" Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: MT7-01 DATE: 03/17/2022 Transmitted: NPRA, Greater Moose's Tooth IVia SFTP Geolog Mud log data package MT7-01 J MT7-01_GEOLOG-Lithology_Per€entages_3434-19645ft_FINAL.las 221-052 T36412 320KB 3/17/2022 &44 AM LAS File MT7-01_01PB1is in a federal oil and gas unit. Only with respect to the MT7-01_01PB1 Well Data, CPAI hereby waives its rights to indefinitely confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for the wells not on state land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). Transmittal instructions: please promptly sign, scan, and e-mail to 5andra.D.LemkeOg2goc2phi//ips com CC: MT7-01 01 PB1 e-transmittal well folder Meredith Guhl Digitally signed by Meredith Guhl Receipt: Imo:. 2022.03.17 13:31:27-08'00' Alaska Data Support I ConocoPhillips Alaska I Office: 907.265 6947, Mobile 907.440.45t2 DATA SUBMITTAL COMPLIANCE REPORT 3/15/2022 Permit to Drill 2210520 Well Name/No. GMTU MT7-01 Pg 1 • Operator ConocoPhillips Alaska, Inc. API No. 50-103-20832-00-00 MD 19645 TVD 8295 Completion Date 11/29/2021 Completion Status 1-OIL Current Status 1-OIL UIC No REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes V/ DATA INFORMATION List of Logs Obtained: GR, RES, PWD, DIR, AZI, DEN, NEU, CALIPER, POROSITY, ACOUSTIC, NMR, NBI, SONIC, Mud, VisTrak (from Master Well Data/Logs) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED DF 36122 Digital Data 10514 10058 12/21/2021 Electronic Data Set, Filename: CPAI_MT7- 01 SCMT 15Nov21 Main Cr.las ED DF 36122 Digital Data 10460 8559 12/21/2021 Electronic Data Set, Filename: CPAI_MT7- 01_SCMT_15Nov21—Repeat _Cr.las ED DF 36122 Digital Data 12/21/2021 Electronic File: CPAI_MT7- 01 SCMT 15Nov21 Main Cr.dlis ED DF 36122 Digital Data 12/21/2021 Electronic File: CPAI_MT7- 01 SCMT 15Nov21 Main Pr.dlis ED DF 36122 Digital Data 12/21/2021 Electronic File: CPAI_MT7- 01_SCMT_15Nov21—Repeat _Cr.dlis ED DF 36122 Digital Data 12/21/2021 Electronic File: CPAI_MT7- 01_SCMT_15Nov21—Repeat _Pr.dlis ED DF 36122 Digital Data 12/21/2021 Electronic File: CPAI_MT7- 01 SCMT 15Nov21 Field Print. Pdf Log 36122 Log Header Scans 0 0 2210520 GMTU MT7-01 LOG HEADERS ED DF 36402 Digital Data 14093 14191 3/4/2022 Electronic Data Set, Filename: CPAI_MT7- 01 MEM 14135-14167' MD MADPASS.Ias ED DF 36402 Digital Data 16950 18206 3/4/2022 Electronic Data Set, Filename: CPAI_MT7- 01 MEM 16952-18188 MD MADPASS.Ias ED DF 36402 Digital Data 117 19645 3/4/2022 Electronic Data Set, Filename: CPAI_MT7- 01_MEM_COMP.las ED DF 36402 Digital Data �##############A 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TIME_MEM_RUN01.1as ED DF 36402 Digital Data 3/4/2022 Electronic Data Set, Filename: MT7- 01 _AP_T I M E_M E M_R U N 02. l a s AOGCC Page 1 of 7 Tuesday, March 15, 2022 DATA SUBMITTAL COMPLIANCE REPORT 3/15/2022 Permit to Drill 2210520 Well Name/No. GMTU MT7-01 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20832-00-00 MD 19645 TVD 8295 Completion Date 11/29/2021 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED DF 36402 Digital Data �###############a 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TI ME_MEM_RUN03.las ED DF 36402 Digital Data 4###############a 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TI ME_MEM_RUN04.las ED DF 36402 Digital Data �##########1####k 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TI ME_MEM_RUN05.las ED DF 36402 Digital Data �##############A 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TI ME_MEM_RUN06.las ED DF 36402 Digital Data �##############A 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TI ME_MEM_RUN07.las ED DF 36402 Digital Data �##############A 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TI ME_MEM_RUN08.las ED DF 36402 Digital Data �##############A 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TI ME_MEM_RUN09.las ED DF 36402 Digital Data �##############A 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TIME_MEM_RUN10.1as ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN01.ASC ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN02.ASC ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN03.ASC ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN04.ASC ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN05.ASC ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN06.ASC ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN07.ASC ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN08.ASC ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN09.ASC ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN 10.ASC AOGCC Page 2 of 7 Tuesday, March 15, 2022 DATA SUBMITTAL COMPLIANCE REPORT 3/15/2022 Permit to Drill 2210520 Well Name/No. GMTU MT7-01 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20832-00-00 MD 19645 TVD 8295 Completion Date 11/29/2021 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01 mem LTK R9 LMG100.dlis ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01 _m em_LTK_R9_LM G 100_0240scl. cg m ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7- 01 _m em_LTK_R9_LM G 100_0240scl. pdf ED DF 36402 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01_21VID_MEM_COMP.cgm ED DF 36402 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01 _2TV D_M E M_C O M P. cg m ED DF 36402 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01_51VID_MEM_COMP.cgm ED DF 36402 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01 _5TV D_M E M_C O M P. cg m ED DF 36402 Digital Data 3/4/2022 Electronic File: CPAI_MT7-01_MEM_AP-LOG TIME.cgm ED DF 36402 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01_2MD_MEM_COMP.pdf ED DF 36402 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 012TVD_MEM_COMP.pcif ED DF 36402 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01_5MD_MEM_COMP.pdf ED DF 36402 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01_5TVD_MEM_C0MP.pdf ED DF 36402 Digital Data 3/4/2022 Electronic File: CPAI_MT7-01_MEM_AP-LOG TIME.pdf ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7-01_NAD 27_Compass Surveys—Canvas-1 2202021.txt ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7-01_NAD 27_Compass Surveys —Definitive Survey Reports_12202021.pdf ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7-01_NAD 27_Compass Surveys—Macro-1 2202021.txt ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7-01_NAD 27_Compass Surveys—Petrel-1 2202021.txt ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7-01_NAD 27_Compass Surveys_Su rveys_12202021.txt AOGCC Page 3 of 7 Tuesday, March 15, 2022 DATA SUBMITTAL COMPLIANCE REPORT 3/15/2022 Permit to Drill 2210520 Well Name/No. GMTU MT7-01 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20832-00-00 MD 19645 TVD 8295 Completion Date 11/29/2021 Completion Status 1-0I1- Current Status 1-0I1- UIC No ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7-01_NAD 83_Compass Surveys—Canvas-1 2202021.txt ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7-01_NAD 83_Compass Surveys —Definitive Survey Reports_12202021.pdf ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7-01_NAD 83_Compass Surveys—Macro-1 2202021.txt ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7-01_NAD 83_Compass Surveys—Petrel-1 2202021.txt ED DF 36402 Digital Data 3/4/2022 Electronic File: MT7-01_NAD 83_Compass Surveys_Su rveys_12202021.txt ED DF 36403 Digital Data 117 10846 3/4/2022 Electronic Data Set, Filename: MT7- 01 PB1_COMPOSITE.las ED DF 36403 Digital Data �##############A 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TIME_MEM_RUN01.Ias ED DF 36403 Digital Data ##############A 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TI ME_MEM_RUN02.las ED DF 36403 Digital Data 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TI ME_MEM_RUN03.las ED DF 36403 Digital Data 3/4/2022 Electronic Data Set, Filename: MT7- 01_AP_TI ME_MEM_RUN04.las ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN01.ASC ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN02.ASC ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN03.ASC ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7- 01_AP_TIME_MEM_RUN04.ASC ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7-01PB1_mem_LTK_R3.dlis ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7- 01 PB1_mem_LTK_R3_IMG100_0240scl.cgm ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7- 01 PB1_mem_LTK_R3_IMG100_0240scl.pdf ED DF 36403 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01 PB1_2MD_MEM.cgm AOGCC Page 4 of 7 Tuesday, March 15, 2022 DATA SUBMITTAL COMPLIANCE REPORT 3/15/2022 Permit to Drill 2210520 Well Name/No. GMTU MT7-01 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20832-00-00 MD 19645 TVD 8295 Completion Date 11/29/2021 Completion Status 1-OIL Current Status 1-0I1- UIC No ED DF 36403 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01 PB1_2TVD_MEM.cgm ED DF 36403 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01 PB1_5MD_MEM.cgm ED DF 36403 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01 PB1_5TVD_MEM.cgm ED DF 36403 Digital Data 3/4/2022 Electronic File: CPAI_MT7-01PB1_MEM_AP- LOG TIME.cgm ED DF 36403 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01 PB1_2MD_MEM.pdf ED DF 36403 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01 PB1_2TVD_MEM.pdf ED DF 36403 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01 PB1_5MD_MEM.pdf ED DF 36403 Digital Data 3/4/2022 Electronic File: CPAI_MT7- 01 PB1_5TVD_MEM.pdf ED DF 36403 Digital Data 3/4/2022 Electronic File: CPAI_MT7-01PB1_MEM_AP- LOG TIME.pdf ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7-01 P131_NAD 27_Compass Surveys—Canvas-1 2202021.txt ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7-01 P131_NAD 27_Compass Surveys —Definitive Survey Reports_12202021.pdf ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7-01 P131_NAD 27_Compass Surveys—Macro-1 2202021.txt ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7-01 P131_NAD 27_Compass Surveys—Petrel-1 2202021.txt ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7-01 P131_NAD 27_Compass Surveys_Su rveysl_12202021.txt ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7-01P131_NAD 83_Compass Surveys—Canvas-1 2202021.txt ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7-01P131_NAD 83_Compass Surveys —Definitive Survey Reports_12202021.pdf ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7-01P131_NAD 83_Compass Surveys—Macro-1 2202021.txt ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7-01P131_NAD 83_Compass Surveys—Petrel-1 2202021.txt AOGCC Page 5 of 7 Tuesday, March 15, 2022 DATA SUBMITTAL COMPLIANCE REPORT 3/15/2022 Permit to Drill 2210520 Well Name/No. GMTU MT7-01 Operator ConocoPhillips Alaska, Inc. API No. 50-103-20832-00-00 MD 19645 TVD 8295 Completion Date 11/29/2021 Completion Status 1-OIL Current Status 1-OIL UIC No ED DF 36403 Digital Data 3/4/2022 Electronic File: MT7-01 PB1 NAD 83_Compass Surveys_Su rveys_12202021.txt ED DF 36412 Digital Data 3434 19645 3/15/2022 Electronic Data Set, Filename: MT7- 01 GEOLOG AMG G5 Corrected data 3434- 19645ft MD FINAL.Ias ED DF 36412 Digital Data 3434 10845 3/15/2022 Electronic Data Set, Filename: MT7- 01_GEOLOG _AMG G5_Lithology_Percentages_ 3434-10845ft MD Final.las ED DF 36412 Digital Data 3/15/2022 Electronic File: 50-103-20832-00- 00_MT7_01_GASLOG_19000ft MD.pdf ED DF 36412 Digital Data 3/15/2022 Electronic File: 50-103-20832-00- 00_MT7_01_MUDLOG_19645ft MD.pdf ED DF 36412 Digital Data 3/15/2022 Electronic File: MT7-01 End of Well Mudlogging report. pdf ED DF 36413 Digital Data 3434 10845 3/15/2022 Electronic Data Set, Filename: MT7- 01 GEOLOG AMG G5 Corrected data 6675- 10845ft MD Final.las ED DF 36413 Digital Data 3/15/2022 Electronic File: 50-103-20832-00- 70_MT7_01PB1_MUDLOG_10845ft MD FINAL.pdf ED DF 36413 Digital Data 3/15/2022 Electronic File: MT7- 01 PB1_GEOLOG_End_of_Well_Report.pdf Well Cores/Samples Information: Name Cuttings INFORMATION RECEIVED Completion Report D Production Test Information Y �11 Geologic Markers/Tops O COMPLIANCE HISTORY Completion Date: 11/29/2021 AOGCC Interval Total Start Stop Boxes Received 3500 19645 4 1/6/2022 Sample Set Number Comments 1798 Directional / Inclination Data 0 Mud Logs, Image Files, Digital Data (DIA Core Chips Y NA Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files O Core Photographs Y Daily Operations Summary G Cuttings Samples Y / NA Laboratory Analyses Y NA Page 6 of 7 Tuesday, March 15, 2022 Permit to Drill 2210520 Wei MD 19645 TVD 8295 Release Date: 8/26/2021 Description Comments: DATA SUBMITTAL COMPLIANCE REPORT 3/15/2022 ie/No. GMTU MT7-01 Operator ConocoPhillips Alaska, Inc. Completion Date 11/29/2021 Completion Status 1-0I1- Current Status 1-0I1- Date Comments API No. 50-103-20832-00-00 Compliance Reviewed By: M.GUhl Date: 3/15/2022 UIC No AOGCC Page 7 of 7 Tuesday, March 15, 2022 221-052 T36412 T36413 ConocoPhillips TRANSMITTAL FROM: Sandra D. Lemke, ATO-704 TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 71" Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: MT7-01/01 PB1 DATE: 03/15/2022 Transmitted: NPRA, Greater Moose's Tooth Via SFTP Geolog Mud log data package MT7-01 PB1 5D-1 D3-2D832-DD-7D_MT7_D1 PB1_MUDLOG_1 D845ft MD FINAL,pdf - MT7-01_GEOLOG_AMC, G5_Corrected data _6675-10845ft MD_Final,las MT7-D1 PB 1 _GFOLOG_End_cf_Well_Report,pdf MT7-01 el 5D-1 D3-2D832-DD-l}l}_MT7_D1_GASLOG_19000ft MD,pdf el 5D-103-20832-00-DD_MT7_01_MUDLOG_19645ft MD,pdf el MT7-DI End of Well Mudlogging report,pdf MT7-01_GEOLOG_AMG_G5_Corrected data _3434-19645ft MID FINAL,Ias MT7-D1_GEOLOG_AMG_GS_LithoIagy_Percentages_3434-1 D845ft MD_Final,las MT7-01_01PB1is in a federal oil and gas unit. Only with respect to the MT7-01_01PB1 Well Data, CPAI hereby waives its rights to indefinitely confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for the wells not on state land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke(@conocoohiilios.com CC: MT7-01 01 PB1 e-transmittal well folder Digitally signed by Meredith Guhl Meredith Guhl Receipt: Dat�e022.03.15 13:21:52-08'00' Alaska Data Support I ConocoPhillips Alaska I Office: 907.265.6947; Mobile 907 440 4512 221-052 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA March 4, 2022 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 T36402 Baker Hughes S Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-01 Greater Mooses Tooth API *: 50-103-20832-00 Permit No: 221-052 Rig: Doyon 25 The final deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: MWD/LWD Digital Las Data, Graphic Images CGM/PDF and Survey Files. MT7-01 is located in a federal oil and gas unit. Only with respect to the MT7-01 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). Thank you. Signature of receiver & date received: Meredith Guhl Please return transmittal letter to: Digitally signed by Meredith Guhl Date: 2022.03.04 15:50:10-09'00' Garrett Brown Garrett.Brown(cpconocophillips.com & Melissa LeMay Melissa.LeMay_@bakerhughes.com 221-052 T364O3 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA March 4, 2022 AOGCC Attention: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Baker Hughes Subject: Final Log Distribution for ConocoPhillips Alaska, Inc. MT7-01PB1 Greater Mooses Tooth API *: 50-103-20832-70 Permit No: 221-052 Rig: Doyon 25 The final deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: MWD/LWD Digital Las Data, Graphic Images CGM/PDF and Survey Files. MT7-01 is located in a federal oil and gas unit. Only with respect to the MT7-01 Well Data, CPAI hereby waives its right to indefinite confidentiality, under 5 U.S.C. 552(b)(4) and (9). Nothing in this communication should be construed as a waiver of indefinite confidentiality on any other wells. Please note that for wells not on State land, a state agency should seek consent from the landowner prior to the release of well data by the state agency. See, e.g., AS 43.55.025(f)(2)(C)(i). Here, the landowner is the Bureau of Land Management (BLM) and/or Arctic Slope Regional Corporation (ASRC). Thank you. Signature of receiver & date received: Meredith Guh I Digitally signed by Meredith Guhl Date: 2022.03.04 15:51:11-09'00' Please return transmittal letter to: Garrett Brown Garrett.Brown(cpconocophillips.com & Melissa LeMay Melissa.LeMay_@bakerhughes.com STATE OF ALASKA RECEIVED ALASKAOIL AND GAS CONSERVATION COMMISSION By Samantha Carlisle at 2:04 pm, Jan 10, 2022 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate p ' Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well Other: ❑ 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Development 71 Exploratory❑ Stratigraphic ❑ Service ❑ 221-052 3. Address: P.O. Box 100360 Anchorage, Alaska 99510-0360 6. API Number: 50-103-20832-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: AA081800, AA081781, AA081803 • MT7-01 ' 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Post Frac Job Report - Greater Moose's Tooth Rendezvous 11. Present Well Condition Summary: Total Depth measured 19,645 feet Plugs measured none feet true vertical 8,295 feet Junk measured none feet Effective Depth measured 19,645 feet Packer measured 10,487, 10,538, feet true vertical 8,295 feet true vertical 8,222, 8,243 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" x 34" 120' 120' Surface 3,384' 13-3/8" 3,424' 3,050' 5020 2260 Intermediate 1 9,220' 9-5/8", 9-7/8" 9,260' 7,440' 6330, 8860 3810, 8260 Intermediate 11 2,028' 7" 10,727' 8,310' 7240 5410 Liner 7,512' 4-1/2" 18,050' 8,303' 8430 17500 Perforation depth Measured depth 10,867-13,132 feet True Vertical depth 8,347-8,378 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 10,550' MD 8,248' TVD Packers and SSSV (type, measured and true vertical depth) Packer - Baker Premier 10,487' MD 8,222' TVD Packer - HRD-E ZXP Liner top Packer 10,538' MD 8,243' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10,867' MD, 11,592' MD, 12,361' MD, 13,132' MD Treatment descriptions including volumes used and final pressure: 4 Frac Stages, 640,000 Ibs proppant placed, 12,484 bbls, attached report has full Frac details 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 11,000 9000 0 1615 330 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Developmeng Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil p Gas ❑ WDSPL❑ Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 321-607 Digitally signed by Madeline —d- Madeline DN-Cddi—1 d,bJda.d.° E-.b I.. the—'d®°° -Phillips°°m.°'D5 Madeline Woodard Authorized Name and Iemthig—g°,°fthlsd° °me°t Contact Name: L... Woodard �°s'.y°urslgningl°°a-i°° °,° Digital Signature with Date: F-tPDFEdit,rJ;so 1100 Contact Email: madeline.e.woodard(cDconocophillips.co Authorized Title: Completion Engineer Contact Phone: 907-764-8095 Sr Pet Eng:VTL 01/24/2022 Sr Pet Geo: SFD 1/10/2022 Isr Res Eng: CDW 1/10/2022 Form 10-404 Revised 10/2021 RBDMS HEW 1/11/2022 Submit Within 30 days of Operations ® WNS PROD WELLNAME MT7-01 WELLBORE MT7-01 ConocoPhillips AEaSiCa, Inc. Well Attributes I Max Angle & MD TD Field Name Wellbore API/UWI Wellbore Status RENDE 501032083200 PROD I cI (°) 3.34 MD (ftKB) 18,161.75 Act Btm (ftKB) 19,645.0 Comment HIS (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ... - SSSV: NONE LAST WO: 39.50 11/29/2021 HORIZONTAL, MT7-01,1/10/2022 8:33:56 AM Last Rev Reason Vertical schematic (actual) Annotation End Data Wellbore Last Mod By ....................................................................................................................... Rev Reason: Post Frac / Tree Swap / Pre Flowback GLVD MT7-01 obTr HANGER; 34.9 Casing Strings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (I... Grade Top Thread CONDUCTOR 20 19.12 40.5 120.0 120.0 94.00 Casing Description OD (in) ID (in) Top IRKS) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Threatl SURFACE 13318 12.42 39.1 3,424.0 3,050.3 68.00 L-80 H563 Casing Description OD (in) ID (in) Top IRKS) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread INTERMEDIATE 95/8 8.76 37.3 9,260.0 7,440.2 43.50 L80 TXPM CONDUCTOR; 40.5-120.0 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread NIPPLE; 1,741.0 INTERMEDIATE 7 6.28 8,699.4 10,727.0 8,307.9 26.00 L-80 TSH 563 Casing Description GD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread LOWER COMPLETION 4 1/2 3.96 10,538.7 18,050.0 8,303.9 12.60 L-80 Hyd 563 Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (lb/ft) Grade Top Connection SURFACE; 39.1-3,424.0 Tubing -Production 4 1/2 3.96 34P 10,550.0 8,247.8 12.60 L-80 Hyd563 GAS LIFT; 4,175.9 Completion Details OD Top(TVD) Nominal ID Nominal Top (ftKB) (ftKB) Top Incl (°) Item Des (in) (in) Make Model Co. 34.9 34.9 0.00 HANGER 3.958 11.000 FMC TC-EMS FMC 4-1/2" Tubing Hanger Hydril HYD 563 Min ID 3.92" GAS LIFT; 8,156.E 1,741.0 1,723.3 18.81 NIPPLE 3.813 5.030 HES X Nipple NIPPLE,LANDING,4 1/2","X%3.813", H563 (1,670') 4,175.9 3,593.9 42.48 GAS LIFT 3.865 6.518 Camco KBMG 4-1/2" x 1" KBG2 GUM w/ DCK-2 SOV, 12.6# H563 BEK Latch (4,200') 8,156.6 6,547.8 35.55 GAS LIFT 3.860 6.640 Camco KBMG 4-1/2" x 1" KBG2 GUM w/ INTERMEDIATE; 37.3-9,260.0 DV, 12.6# H563 BK Latch (8,200') GAS LIFT; 10,318.2 10,318.2 8,148.0 62.10 GAS LIFT 3.865 6.518 Camco KBMG 4-1/2" x 1" KBG 4-5 GLM W/ DV, 12.6# H563 BK Latch (10,36S) 10,373.6 8,173.5 63.07 GAUGE 3.898 6.076 HES DHG Halliburton Opsis Mandrel PACKER; 10,487.8 w/ Downhole guage NIPPLE; 10,515.7 (10,460') 10,487.8 8,223.1 65.70 PACKER 3.880 6.580 Baker Premier Baker Premier Production Tubing; 10,537.9 Packer, 4 1/2" X 7"26# (10,522') 10,515.7 8,234.4 66.45 NIPPLE 3.813 5.125 DB NIPPLE,LANDING,4 Nipple 1/2","DB",3.75",w/RHC Plug, H563 (10,580') 10,546.7 8,246.E 67.37 MULE SHOE 3.958 4.500 HES Self orienting shoe INTERMEDIATE; 8,699.4- 10,727.0 Mandrel Inserts St all Stage; 10,867.0 on N Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Valve Sem Type Latch Port Type Size TRO (in) Run (psi) Run Data Co. 1 4,175.9 3,593.9 42.48 CAMCO KBG2 1 GAS LIFT GLV BEK 0.188 1,791.0 12/17/2021 2 8,156.6 6,547.8 35.55 CAMCO KBG2 1 GAS LIFT GLV BK 0.188 1,732.0 12/17/2021 Stage; 11,592.0 3 10,318.2 8,148.0 62.10 CAMCO KBG4-5 1 GASLIFT OV BK 0.313 12/17/2021 Hi - flow Stimulation Intervals Interva Mini frac; 13,132.0 I Numbe Proppant Proppant Vol Clean Vol Slurry Stage; 13,132.0 r Type Subtype Start Date Top (ftKB) Btm (ftKB) Designed (lb) Total (lb) Total (bbl) Total (bbl) 0 Mini frac 12/10/2021 13,132.0 13,135.0 0.0 0.0 0.00 0.00 1 Stage Frac Port -Open 12/10/2021 13,132.0 13,135.0 160,000.0 160,058.0 4,604.00 4,776.00 Hole 2 Stage Frac Port -Open 12/10/2021 12,361.0 12,361.0 160,000.0 164,558.0 2,232.00 2,409.00 Hole 3 Stage Frac Port -Open 12/10/2021 11,592.0 11,595.0 160,000.0 154,955.0 2,173.00 2,340.00 Hole 4 Stage Frac Port -Open 12/10/2021 10,867.0 10,870.0 160,000.0 145,020.0 2,802.00 2,958.00 j j Hole Notes: General & Safety End Date Annotation NOTE: LOWER COMPLETION; 10,538.7-18,050.0 DTTMSTART JOBTYP MT7-01 Frac Summary of Operations SUMMARYOPS 12/3/2021 DRILLING PULLED SOV & REPLACED W/ DV @ 4175' RKB, LRS PERFORM PASSING SUPPORT- PRESSURE TEST ON TBG & IA TO 4200 PSI, PULLED BALL & ROD @ 10,494, SLM, CAPITAL MADE 3 ATTEMPTS TO PULL RHC PLUG BODY @ 10,505' SLM, UNABLE TO LATCH PLUG. IN PROGRESS. 12/4/2021 DRILLING SUPPORT - CAPITAL 12/4/2021 DRILLING SUPPORT - CAPITAL 12/5/2021 DRILLING SUPPORT - CAPITAL 12/6/2021 DRILLING SUPPORT - CAPITAL 12/7/2021 DRILLING SUPPORT - CAPITAL 12/8/2021 DRILLING SUPPORT - CAPITAL Rig up, stretched liner, spotted the gel unit, blender, and outside bank of pumps. PULLED 3.75" RHC ON NO GO SUB FROM 10,515' RKB. JOB COMPLETE. Rig Up, Nippled up the goat head and the dart launcher valves and rotary,spotted the high pressure manifold, inside bank of pumps, started running hard line Rig Up, Completed hard line rig in,PRV line, bleed line. Spotted gel, chems, frac van, Ran restraints and network cables. ADP equipment issue, missile leak 20 gal. on containment, frack stack leak at the goat head lower 4 1/16 BX 155, crew houred out will resume in the AM The goat head was pulled with Great North launch stack, cleaned race, installed new BX155 ring gasket. When attempting to move fluid, the frac van computer UPS glitched shuting down the computer systems, The frac stack was then tested with LRS, a good test was charted. The frac vans new UPS arived and was instaled and is charting tonight for malfunction. 12/9/2021 DRILLING On the PT found a leaking Ground Valve, repaired. Second test high pressure seal was SUPPORT- found bad, third test, GV failed again, replaced GV. CAPITAL 4th PT, charted a good test, and ePRV tests. 12/10/2021 DRILLING completed D fit, step rate, mninifrac, and the first 2 intervals, all proppant away. SUPPORT- Interval 1, 311 minutes, max rate 31.2bpm average rate 29.1, max pressure 3658, avg. CAPITAL psi. 1887, avg. HHP 1239, max prop con. 6.02 Interval 2, 88 miutes, max rate 30.7 bpm, avg rate 27.5 bpm. max psi 3168, ag. psi 2499, avg HHP 1681, max prop con 6.04 12/10/2021 DRILLING completed the last 2 intervals all proppant away. SUPPORT- Interval 3, 117 minutes max rate 30.0, avg rate 27.6, max psi 2651, avg psi 2304, avg CAPITAL HHP 1445, max prop. con 4.94 (target 6) Interval 4 154 min max rate 30.8 bpm, avg rate 29.2bpm, max psi 3335, avg psi 2652 avg HHP 1876 max prop con 4.74 (target 6) 12/12/2021 DRILLING Started rig down at well removing the dart launcher , load and launch valves and goat SUPPORT- head. Found frozen risers to the well, and trating line delaying hand over to SL CAPITAL 12/12/2021 DRILLING ATTEMPT TO SET 3.75"DB-P @ 10,515' RKB, LEFT PLUG IN HOLE PACKED w/ FRAC SUPPORT- SAND. ATTEMPT TO PULL TWICE, PULLING TOOLS CAME BACK PACKED w/ FRAC CAPITAL SAND; PULLED 3.75" DB-P PLUG BODY @ 10,515 RKB; SET 3.66" EVO TRIEVE MID ELEMENT @ 4400' SLM; PULLED 1" DMY VLV @ 4176' RKB. READY FOR FMC. 12/14/2021 DRILLING (SEC) T X IA DDT (PASSED) TEST BPV (PASSED TO 1200 PSI) T POT (PASSED) SUPPORT - CAPITAL 12/15/2021 DRILLING (SEC) SWAP 10K THA AND TREE FOR 5K THA AND TREE (COMPLETE) T PPPOT SUPPORT- (PASSED) CAPITAL 12/15/2021 DRILLING STANDBY FOR TREE WORK, WING INSTALLED, SHELL TEST PASSED, BPV SUPPORT- PULLED, PULLED EVO-TRIEVE PLUG FROM 4400' SLM, RAN CATCHER TO 10,515' CAPITAL RKB, PULLED DVs @ 8200',10,300' RKB, SET GLVs AS PER PROCEDURE 4199', 8200' RKB, 5/16" OV @ 10300' RKB, PULLED CATCHER @ 10,515' RKB, JOB COMPLETE. 12/16/2021 TESTING LRS WAITING FOR POST FRAC TREE SWAP AND SLICKLINE WORK, ETC. TO BE COMPLETE ON MT7-01, THEN WILL RU HL TO THE TREE. 10:00 AM- ALPINE IN PHASE 2 WEATHER CONDITIONS FIELD WIDE. CURRENTLY ON WEATHER HOLD DUE TO WIND SPEEDS. _= FIELD BACK TO PHASE 1 AT 7:30PM. WELL SUPPORT INSTALLED WING VLV ON TREE. LRS PUMPERS AND DHD DOING A SHELL TEST ON TREE. _= ONCE COMPLETE, SLICKLINE WILL GET ON WELL TO START GLV WORK. 12/16/2021 DRILLING (SEC) INSTALL WING VALVE (COMPLETE) SHELL TEST (PASS TO 5000 PSI) T POT SUPPORT- (PASS) PULL BPV (COMPLETE) CAPITAL 12/17/2021 TESTING LRS CONTINUED TO STAND-BY FOR SLICKLINE GLV WORK, WELLHOUSE INSTALL, FLOWCROSS INSTALL AND TEMP HP GL HOSE TO BE INSTALLED ON MT7-01. HAL SLICKLINE MIRU, SET GLV'S IN STATIONS 1 & 2, SET OV IN STATION 3 RDMO AT 11 PM. LRS PUMPED 10 BBL METH SPEAR DOWN IA IN PREP TO START GL ONCE IT'S RU. INCREASING WINDS/WEATHER HALTED WELL SUPPORT WORK 12/18/2021 TESTING LRS CONTINUED TO STAND-BY FOR WELL SUPPORT TO COMPLETE POST FRAC WELL/TREE WORK. WELL SUPPORT INSTALLED TEMP GL LINE FROM MT7-06 TO MT7-01 WELL SUPPORT INSTALLED WELLHEAD PLATFORM AND SET WELLHOUSE. WELL SUPPORT INSTALLED FLOWCROSS. DHD SHOT IA F/L, WAS AT SURFACE. 12/19/2021 TESTING 1:OOAM - OPS START INJECTING LIFT GAS AT A RATE OF .5 MMSCF/D TO MT7- 01. 2:OOAM - WELL SUPPORT COMPLETED POST FRAC WELL/TREE WORK 2:30AM - LRS TESTING START RIG UP TO MT7-01 DHD SHOT IA F/L, WAS AT -4175' (AT THE 1 ST STATION) RU COMPLETE. (DUE TO HIGH WINDS / PHASE II CONDITIONS, PT WILL BE CONDUCTED 12/20.) 12/20/2021 TESTING LRS/OPS WALKED DOWN THE INLET RU AND SIGNED OFF CHECKLIST - GOOD LRS DID PT ON INLET HL PIPING / BALLCATCHER. - GOOD DHD SHOT IA F/L @ 3:30PM, WAS AT 5844' LRS POP WELL AT 3:45PM. AT 9:15PM, WELL STARTED LOADING UP/NOT FLOWING. LRS BLOCKED IN TO PROD AND DEPRESS SEP/SYSTEM TO THE TANK FARM, DROPPING BACKPRESS ON WELL. _= BY 12AM, FLUID RATE TO SEP / TF WAS UP TO -1200 - 1800 BFPD. (WAS PRODUCING MAINLY BRINE AND SOME DIESEL, NO SOLIDS). _= LRS NORMAL UP FLOW PATHS AT 12:40AM. APPEARS TOP STAT GLV NOT PASSING GAS (PLUGGED WITH FRAC SAND?). GL/IA STACKED OUT AT GLG HEADER PRESS (1995 PSI) AND STOPPED TAKING GL. HOPEFULLY 2ND STAT GLV WILL PASS GAS ONCE IA F/L REACHES 2ND STAT. 12/21/2021 TESTING LRS WILL CONTINUE TO FLOW/UNLOAD WELL PER PROCEDURE. DHD SHOT AN IA F/L @ 4:15PM, WAS AT 6,555' (ONLY GAINED 711' IN 24 HRS) LRS DECREASED LINE HEATER TEMP 20 DEGS (190 TO 170 DEGS) TO HELP WIF INJECTION ISSUES. 12/22/2021 TESTING LRS WILL CONTINUE TO FLOW/UNLOAD WELL PER PROCEDURE. LRS CONTINUES TO COLLECT FLUID & GAS SAMPLES PER PROCEDURE. (PROTECHNICS, ETC) WITH OPS AGREEMENT, LRS DIVERTED FLUIDS TO PRODUCTION AT 12:30PM. LRS WILL CONTINUE TO CLOSELY MONITOR WELL SPECS VIA SAMPLING/SHAKEOUTS, AND WILL DIVERT BACK TO TANKS IF/WHEN SPECS ARE NOT MET HAVING LRS DE -INVENTORY MT7 TF AND HAUL THE MT7-01 FLUIDS TO MT6 TF TO PUMP INTO THE COMMONLINE. 12/23/2021 TESTING LRS WILL CONTINUE TO FLOW/UNLOAD WELL PER PROCEDURE. LRS CONTINUES TO COLLECT FLUID & GAS SAMPLES PER PROCEDURE. (PROTECHNICS, ETC) DHG HOOKED UP, NOW READING IN IP21. UPDATED MORNING REPORT FOR "SOLIDS" TO REFLECT ACTUAL FLOWING CONDITIONS OF WELL UPSTREAM OF THE SAND CATCHER. 12/24/2021 TESTING LRS WILL CONTINUE TO FLOW/UNLOAD WELL PER PROCEDURE. (WORKING CHOKE OPEN) LRS CONTINUES TO COLLECT FLUID & GAS SAMPLES PER PROCEDURE. (PROTECHNICS, ETC) DHD SHOT IA F/L, WAS AT 6558'. (GAINED 3' IN 3 DAYS) MISTRAS PERFORMED UT INSPECTIONS ON SPECIFIED LOCATIONS OF THE HARDLINE PIPING AND ON PIPING IN THE TEST UNIT. NO EROSION CONCERNS WERE IDENTIFIED. SUPERSUCKER VAC'D SOLIDS OUT OF SPARGE TANK. 12/25/2021 TESTING LRS WILL CONTINUE TO FLOW/UNLOAD WELL PER PROCEDURE. (WORKING CHOKE OPEN) LRS CONTINUES TO COLLECT FLUID & GAS SAMPLES PER PROCEDURE. (PROTECHNICS, ETC) SUPERSUCKER VAC'D SOLIDS OUT OF SPARGE TANK. (DIDN'T GET IT ALL YESTERDAY) 12/26/2021 TESTING LRS CONTINUES TO FLOW/UNLOAD WELL PER PROCEDURE. (WORKING CHOKE OPEN) LRS CONTINUES TO COLLECT FLUID & GAS SAMPLES PER PROCEDURE. (PROTECHNICS, ETC) 12/27/2021 TESTING LRS CONTINUES TO FLOW/UNLOAD WELL PER PROCEDURE. (WORKING CHOKE OPEN) LRS CONTINUES TO COLLECT FLUID & GAS SAMPLES PER PROCEDURE. (PROTECHNICS, ETC) DHD SHOT IA F/L, WAS AT 6568' LRS BY-PASSED THE LINE HEATER AT 6PM. HAD TO PINCH THE CHOKE BACK TO CATCH THE WHIP SO WE DID NOT DUMP THE BHP TOO FAST. _= WORKING THE CHOKE OPEN AGAIN. 12/28/2021 TESTING LRS WORKING CHOKE BACK TO FULL OPEN AGAIN AFTER BY-PASSING LINE HTR. LRS CONTINUES TO COLLECT FLUID & GAS SAMPLES PER PROCEDURE. (PROTECHNICS, ETC) 12/29/2021 TESTING LRS CONTINUES TO COLLECT FLUID & GAS SAMPLES PER PROCEDURE. (PROTECHNICS, ETC) LRS STARTED THE ROCKING/SURGING PROCESS AT 4AM. EACH TIME, WELL WOULD ONLY PRESS UP TO -1550 PSI, AND ONLY FALL TO -1150 WHP WITH INLET CHOKE BY-PASSED. AT 2:30PM, OPS LINED WELL UP TO PRODUCTION, OPENED PROD CHOKE AND DROPPED WHP TO -750 PSI, CLOSED PROD CHOKE TO SEND SLUG THRU TEST UNIT. SAMPLED 1.2% FRAC SAND AFTER 1ST BOTTOMS UP. _= CONTINUED THIS PROCESS THROUGH -OUT THE NIGHT, DRAWING WHP DOWN AS LOW AS 500 PSI. HIGHEST SOLIDS SAMPLE THROUGH -OUT THE NIGHT WAS .53%. THE MAJORITY OF THE SAMPLES AVERAGED 0.2% OR LESS. MISTRAS DID UT INSPECTIONS ON SELECT LOCATIONS 12/30/2021 TESTING LRS TURNED WELL OVER TO OPS AT 10:OOAM LRS BLEW DOWN FB SPREAD, AND RD FROM TREE / BALLCATCHER, AND HL PIPING BACK TO THE PIPE RACK LOCATION. FLOWBACK/TEST SPREAD IS ISOLATED, DEPRESSURED, SECURED. JOB COMPLETE Hydraulic Fracturing Fluid Product Component Information Disclosure Job Start Date: Job End Date: State: County: API Number: Operator Name: Well Name and Number: Latitude: Longitude: Datum: Federal Well: Indian Well: True Vertical Depth: Total Base Water Volume (gal): Total Base Non Water Volume: 12/11 /2021 12/13/2021 Alaska Harrison Bay 50-103-20832-00-00 ConocoPhillips Company/Burlington Resources MT7-01 Hydraulic Fracturing Fluid Composition: 70.17331900 -151.69031700 NAD27 NO NO 8,295 489,765 r7c Chemical Disckosrure Registry GROUNDWATER 4 �Oil&Gas Chemical Maximum Maximum Abstract Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration Concentration Comments Number in Additive in HF Fluid (CAS #) (% by mass)** (% by mass)** Sea Water Operator Base Fluid Water 7732-18-5 81.92432 Density=8.520 Wanli 20/40 Wanli Proppant Proppant Company Listed Below WG-36 GELLING AGENT Halliburton Gelling Agent Listed Below CL-22 UC Halliburton Crosslinker Listed Below LVT 200 Pencro Freeze Protect Listed Below BE-6 MICROBIOCIDE Halliburton Biocide Listed Below LOSURF-300D Halliburton Non-ionic Surfactant Listed Below MO-67 Halliburton pH Control Additive Listed Below OPTIFLO-III DELAYED RELEASE BREAKER Halliburton Breaker Listed Below 77 Corundum 1302-74-5 65.00000 8.50764 Mullite 1302-74-5 45.00000 5.88990 Sodium chloride 7647-14-5 4.00000 3.41597 Hydrotreated Distillate, light 64742-47-8 100.00000 0.88308 Guar gum 9000-30-0 100.00000 0.34767 Potassium formate 590-29-4 60.00000 0.12399 Borate Salts Proprietary 60.00000 0.12399 Water 7732-18-5 100.00000 0.10109 Density=8.520 Ethanol 64-17-5 60.00000 0.04568 Oxylated phenolic resin Proprietary 30.00000 0.03045 Heavy aromatic petroleum naphtha 64742-94-5 30.00000 0.02284 Ammonium persulfate 7727-54-0 100.00000 0.01943 Sodium hydroxide 1310-73-2 30.00000 0.01173 Crystalline silica, quartz 14808-60-7 30.00000 0.00604 Cured acrylic resin Proprietary 30.00000 0.00583 Naphthalene 91-20-3 5.00000 0.00381 Poly(oxy-1,2-ethanediyl), alpha-(4-nonylphenyl)- omega-hydroxy-, branched 127087-87-0 5.00000 0.00381 Sodium glycollate 2836-32-0 1.00000 0.00207 Sodium carboxymethyl cellulose 9004-32-4 1.00000 0.00207 Acrylate Polymer Proprietary 1.00000 0.00207 2-Bromo-2-nitro1,3- propanediol 52-51-7 100.00000 0.00143 1,2,4 Trimethyl benzene 95-63-6 1.00000 0.00076 Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water Information is based on the maximum potential for concentration and thus the total may be over 100% If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date 12/11/2020 State: Alaska County: Harrison Bay API Number: 5010320832 CONOCOPHILLIPS NORTHSLOPE- Operator Name: EBUS Well Name and Number: MT7 01 Longitude: .161.6903088 Latitude: he 173316 Long/Lot Projection NAD27 IndiaNFederal: n Production Type Oil True Vertical Depth (TVD): 8,420 Total Water Volume (gal)": 489,765 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration in Ingredient Mass Comments Company First Name Last Name Email Phone Number (CAS (% by mass)** HF Fluid (%by Ibs #) mass)** Sea Water Operator Base Fluid Water 7732-18-5 81.92932R 4005873 Density=8520 BE-6 MICROBIOCIDE Hallibudm Bimide Listed Below Listed Below 0 NA CL-22 UC Hallibudm Crosslinker Listed Below Listed Below 0 NA LOSURF-300D Halliburtm Non-ionic Surfactant Listed Below Listed Below 0 NA MO-67 Hallibudm pH Control Additive Listed Below Listed Below 0 NA OPTIFLO-III DELAYED RELEASE Halliburtm Breaker Listed Below Listed Below 0 NA BREAKER W G-36 GELLING AGENT Halliburtm Gelling Agent Listed Belau Listed Below 0 NA LVT 200 Pencro Freeze Protect Listed Belau Listed Below 0 NA Wanll Wahl, 20/40 Prop pant Proppant Listed Below Listed Below 0 NA Company MSDS and Nm-MSDS Ingredients are listed below the green line Ingredients Listed Above Listed Above 1,2,4 Trimethylbenzene 95-63-6 1.00% 0.00076% 38 2-Bromo-2-n9ro-1,3-propanediol 52-51-7 100.00% 0.00143% 70 Denise Tuck, Hallibunm, 3000 N. DenialT Acrylate polymer Proprietary 1.00% 0.00207% 102 Sam Houstm Pk-Halliburton E., Houston, X Denise Tuck Halliburtm.m 281-871-6226 77032, 281-871- in 6226 Ammonium persulfate 7727-54-0 100.00% 0.01943% 950 Denise.Tuck@ Beale salts Proprietary 60.00% 0.12399% 6063 Halliburton Denise Tuck Halliburlm.co in 281-871-6226 Corundum 1302-74-5 65.00% 8.50764% 416001 Crystalline silica, quartz 14808-60-7 30.00% 0.006041 296 Danise.Tuck@ Cured acrylic resin proprietary 30.00% 0.00583% 285 Halliburton Denise Tuck Halliburtm.co 281-871-6226 Ethanol 64-17-5 60.00% 0.04568% 2234 Guar gum 9000-30-0 l00.00% 0.34767% 17000 Heavy aromatic petroleum naphtha 54742-94-5 30. 00% 0.02284% 1117 Hydmtreated Distillate, light 64742-47-8 100.00% 0.88308% 43181 Monitor 1302-93-8 45.00-- 5.88990% 288000 Naphthalene 91-20-3 5.00% 0.00381% 187 Denise,Tuck@ Oxylated phenolic resin Proprietary 30.001 0.0 ,15% 1490 Halliburton Denise Tuck Hallibuden.co in 281-871-6226 Poly(oxy-1,2-ethanediyl), alpha.(4- nmylitheny0-mega-hydroxy-, 127087-87-0 5.00% 0.00381% 187 branched Potassium formate 590-29-4 60.00% 0.12399% 6063 Sodium carboxymethyl cellulose 9004-32-4 1.00% 0.00207% 102 Sodium chloride 7647-14-5 4.00% 3.41591% 167034 Sodium glycollate 2836-32-0 1.00% 0.00207% 102 Sodium hytlroAde 1310-73-2 30.00% 0.01173% 574 Water 7732-18-5 100.00% 0.10109% 4944 ` Total Water Volume sources may include fresh water, produced water, and/or recycled water _ "" Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. All component information listed was obtained from the supplier's Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it. The Occupational Safety and Health Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary", "trade secret", and "confidential business information" and the criteria for how this in(ortnation is re oned on an MSDS is subect to 29 CFR 1910.1200 and A ndix D. TO: AOGCC 333 WEST 7T" SUITE 100 ANCH. AK. 99501 279-1433 OPERATOR: CPAI SAMPLE TYPE: Dry Cuttings SAMPLES SENT: MT7-01 3500-19645 4 Boxes SENT BY: M. McCRACKEN SAMPLE TRANSMITTAL a I-- ns2- 1 q'i b DATE: January 6, 2022 AIR BILL: N/A CPAL 2022010601 CHARGE CODE: N/A NAME: MT7-01 NUMBER OF BOXES: 4 Box �a 4 JAN p 6. AOGCC UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND RETURN A SIGNED COPY OF THIS FORM TO: CONOCOPHILLIPS, ALASKA 700 G ST ATO-380 ANCHORAGE, AK. 99510 ATTN: MIKE McCRACKEN Mike.mccracken@conocophillips.com RECEIVED: ?Fl ' 1 I ✓ ` 2Z RECEIVED By Samantha Carlisle at 12:31 pm, Dec 28, 2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil J Gas J SPLUG U Other U Abandoned -1 Suspended J 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development -1 Exploratory J GINJ U WINJ J WAG _] WDSPL U No. of Completions: Service J Stratigraphic Test J 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: ConocoPhillips Alaska, Inc. Aband.: 11/29/2021 X1-024/321-567 221-052 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 100360, Anchorage, AK 99510-0360 10/12/2021 50-103-20832-00-00 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 1015' FSL, 1947' FWL, S32 T10N R2E UM 11/23/2021 GMTU MT7-01/MT7-01PB Top of Productive Interval: 2590' FSL, 3938' FWL, S6 T9N R2E W 9. Ref Elevations: KB: 139.4 17. Field / Pool(s): GL:100.7 ' BF: Greater Mooses Tooth/Rendevous Pool Total Depth: 5024' FSL, 5008' FWL S36 T10N R1E UM 10. Plug Back Depth MD/TVD: 18. Property Designation: 8800'MD/7078'TVD AA081800, AA081781, AA081803 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 290025 y- 5915835 Zone- 4 •19645'MD/8295'TVD 932535000, 932516000. 932538000 TPI: x- 286768 y- 5912220 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 282781 y- 5920050 Zone- 4 N/A 979'MD/978'TVD 5. Directional or Inclination Survey: • Yes J (attached) No U 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic 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 within 90 days of completion, GR, RES, PWD, DIR, AZI, DEN, NEU, CALIPER, POROSITY, ACOUSTIC, NMR, NBI, SONIC, Mud, VisTrak 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD TOP BOTTOM TOP BOTTOM FT PULLED 20" 94 H-40 40.5' 120' 40.5' 120 42" 10 yrds 13 3/8" 68 L-80 39' 3424' 39' 3050' 16" Lead: 480bbls of 11ppg Tail: 73bbls of 15.8ppg Tail: 130bbls of 15.8ppg 9 5/8" 43.5 L-80 37' 9260' 37 7440' 12 1/4" Class G 7" 26 L-80 8699' 10727' 6995' 8308' 9 7/8" Tail: 50bbl 15.8 Class G 4.5" 12.6 L-80 10539' 18050' 8244' 8304' 9 7/8" 24. Open to production or injection? Yes , I No J 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perfd): 4.5' 10550' MD 10487' MD/8223' TVD Liner/Perfed Pup @ 10539'-18050'MD/ 8244'-8304'TVD Completion Date 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11/29/2021 Was hydraulic fracturing used during completion? Yes U No J Per 20 AAC 25.283 (i)(2) attach electronic information HEW DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Not Pre -Produced Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casinq Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Pet Eng VTL 01/31/2022 I Sr Pet Geo SFD 1/3/2022 Sr Res Eng Form 10-407 Revised 3/2020 1 RBDMS HEW 12/30/2021 G Submit within 30 days of Completion, Suspension, or Abandonment 28. CORE DATA Conventional Core(s): Yes U No Sidewall Cores: Yes U No U - If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. N/A 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes U No If yes, list intervals and formations tested, briefly summarizing test results. Attach Permafrost - Top Surface Surface Permafrost - Base 979 977 separate pages to this form, if needed, and submit detailed test information, C40 1086 1400 including reports, per 20 AAC 25.071. C30 1422 1649 C10 2038 1993 K-3 3364 3003 Albian 97 4217 3616 Albian 96 4477 3807 H RZ 9237 7459 N/A Kalubik 9361 7521 LCU/Miluveach 9508 7640 Top of Productive Interval (Alpine C): 10802 8337' Formation at total depth (TD) Alpine C: 19645 8176 Formation at TD (Alpine C) MT7-01 PB: 10845 18341 31. List of Attachments: Cement Report, Directional Survey, Well Schematic, Operations Summary Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Jenna Taylor Contact Name: Nina Anderson Authorized Title: Wells Engineering Technician Contact Email: nina.anderson @conocophillips.conl Authorized «= oo P om Contact Phone: 907-265-6487 :..,.. Si nature w/Date: INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment ® WNS PROD WELLNAME MT7-01 WELLBORE MT7-01 ConocoPhillips Alaska, inc. Well Attributes I Max Angle & MD TD Field Name RENDE Wellbore API/UWI 501032083200 Wellbore Status PROD Im l (°) 93.34 MD (ftKB) 18,161.75 Act Btm (ftKB) 9,645.0 Comment H2S (ppm) Date Annotation End Date KB-Grtl (ft) Rig Release Dale ... SSSV: NONE LAST WO: 39.50 11/29/2021 HORIZONTAL, MT7-01, 12/16/2021 3:48:21 PM Casing Strings Vertical schematic (actual) Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 40.5 Set Depth (ftKB) Set 120.0 120.0 Depth (TVD)... WVLen (I... 94.00 Grade Top Thread ............................................................... HANGER; 34.9 Casing Description SURFACE OD (in) 13 318 ID (in) 12.42 Top (ftKB) 39.1 Set Depth (ftKB) Set 3,424.0 3,050.3 Depth (TVD)... WtlLen (I... 68.00 Grade L-80 Top Thread H563 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread INTERMEDIATE 9 5/8 8.76 37.3 9,260.0 7,440.2 43.50 L80 TXPM Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread INTERMEDIATE 7 6.28 8,699.4 10,727.0 8,307.9 26.00 L-80 TSH 563 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread LOWER COMPLETION 14 1/2 13.96 110,538.7 118,050.0 18,303.9 112.60 1L-80 Hyd 563 -�-h� CONDUCTOR; 40.5-120.0 Tubing Strings NIPPLE; 1,741.0 Tubing Description String Ma... ID (in) Top (ftKB) Tubing -Production 4 1/2 3.96 34.9 Set Depth (ft.. Set Depth (TVD) (... 10,550.0 8,247.8 Wt (lb/ft) Grade Top Connection 12.60 L-80 Hyd563 Completion Details OD Top (TVD) Nominal ID Nominal Top (ftKB) (ftKB) Top Incl (°) Item Des (in) (in) Make Model Com SURFACE; 39.1-3,424.0 34.9 34.9 0.00 HANGER 3.958 11.000 FMC TC-EMS FMC 4-1/2" Tubing Hanger Hydril HYD 563 Min ID GAS LIFT; 4,175.9 3.92" 1,741.0 1,723.3 18.81 NIPPLE 3.813 5.030 HES XNipple NIPPLE,LANDING,4 1/2","X",3.813", H563 (1,670') GAS LIFT; 8,156.6 4,175.9 3,593.9 42.48 GAS LIFT 3.865 6.518 Camco KBMG 4-1/2" x 1" KBG2 GLM w/ DCK-2 SOV, 12.6# H563 BEK Latch (4,200') 8,156.6 6,547.8 35.55 GAS LIFT 3.860 6.640 Camco KBMG 4-1/2" x 1" KBG2 GLM w/ DV, 12.6# H563 BK Latch (8,200') 10,318.2 8,148.0 62.10 GAS LIFT 3.865 6.518 Camco KBMG 4-1/2" x 1" KBG 4-5 GLM w/ DV, 12.6# H563 BK Latch (10,365') INTERMEDIATE; 37.3-9,260.0 10,373.6 8,173.5 63.07 GAUGE 3.898 6.076 HES DHG Halliburton Opsis Mandrel w/ Downhole guage (10,460') GAS LIFr; 10,318.2 10,487.8 8,223.1 65.70 PACKER 3.880 6.580 Baker Premier Baker Premier Production Packer, 4 1 /2" X 7 " 26# (10,522') PACKER; 10,487.8 10,515.7 8,234.4 66.45 NIPPLE 3.813 5.125 DB Nipple NIPPLE,LANDING,4 1/2","DB",3.75", w/RHC NIPPLE; 10,515.7 Plug, H563 (10,580') Tubing; 10,537.9 10,546.7 8,246.E 67.37 1 MULE SHOE 3.958 4.500 HES Self orienting shoe Mandrel Inserts St ali on N Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Se, Vale Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 4,175.9 3,593.9 42.48 CAMCO KBG2 1 GAS LIFT SOV BEK 1.000 11/28/2021 INTERMEDIATE; 8,699.4- 2 8,156.6 6,547.8 35.55 CAMCO KBG2 1 GAS LIFT DMY BK 1.000 11/28/2021 10,727.0 3 10,318.2 8,148.0 62.10 CAMCO KBG4-5 1 GAS LIFT DMY BK 1.000 11/28/2021 Notes: General & Safety End Dale Annotation NOTE: LOWER COMPLETION; 10,538.7-18,050.01 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/10/2021 10/10/2021 1.50 MIRU, MOVE DMOB P Unplug power between complexes- 0.0 0.0 06:00 07:30 Casing shed, Sub, Pump room, & engine package 10/10/2021 10/10/2021 0.50 MIRU, MOVE DMOB P Stomp casing shed away f/ sub & stage 0.0 0.0 07:30 08:00 f/ move t/ MT7-01 SIMOPS- Continue to unplug electrical interconnects 10/10/2021 10/10/2021 0.50 MIRU, MOVE DMOB P Prep rig floor f/ skid & skid same 0.0 0.0 08:00 08:30 SIMOPS- Seperate power, pump, & pit complexes 10/10/2021 10/10/2021 0.50 MIRU, MOVE DMOB P Lower derrick. 0.0 0.0 08:30 09:00 SIMOPS- Continue to stomp casing shed away f/ sub 10/10/2021 10/10/2021 1.50 MIRU, MOVE DMOB P Stomp pipe shed away from sub. 0.0 0.0 09:00 10:30 10/10/2021 10/10/2021 1.50 MIRU, MOVE MOB P Stomp sub away f/ MT7-06 and onto 0.0 0.0 10:30 12:00 MT7-01. 10/10/2021 10/10/2021 0.50 MIRU, MOVE MOB P Laid matts for sub. 0.0 0.0 12:00 12:30 10/10/2021 10/10/2021 3.00 MIRU, MOVE MOB P Continued to stomp f/ MT7-06 to MT7- 0.0 0.0 12:30 15:30 01. 10/10/2021 10/10/2021 1.00 MIRU, MOVE MOB P Spot sub over MT7-01. SIMOPS: Lay 0.0 0.0 15:30 16:30 Matts and stomped pipeshed and pit complex. 10/10/2021 10/10/2021 2.00 MIRU, MOVE MOB P Continued to stomp pipe shed into 0.0 0.0 16:30 18:30 position in front of sub follow by pit, pump, and motor complex. 10/10/2021 10/10/2021 3.00 MIRU, MOVE MOB P Lined up pipe shed w/ sub. Stomped 0.0 0.0 18:30 21:30 into position w/ sub and pin together. 10/10/2021 10/11/2021 2.50 MIRU, MOVE MOB P Stomped pits, pump, motor and casing 0.0 0.0 21:30 00:00 complexes together and hooked up interconnects. 10/11/2021 10/11/2021 0.75 MIRU, MOVE MOB P Moved ball mill in place. 0.0 0.0 00:00 00:45 10/11/2021 10/11/2021 0.50 MIRU, MOVE MOB P Raised derrick. 0.0 0.0 00:45 01:15 10/11/2021 10/11/2021 0.50 MIRU, MOVE MOB P Skidded rig floor in place. 0.0 0.0 01:15 01:45 10/11/2021 10/11/2021 1.50 MIRU, MOVE MOB P Raised cattle chute and c-section. 0.0 0.0 01:45 03:15 10/11/2021 10/11/2021 1.25 MIRU, MOVE MOB P Worked on rig acceptance checklist 0.0 0.0 03:15 04:30 while electrician was plugging in modules. Rig accepted on 10/11/2021 at 0430hr. 10/11/2021 10/11/2021 1.50 MIRU, MOVE MOB P Install conductor valves, prep wellhead 0.0 0.0 04:30 06:00 f/ surface riser. SIMOPS- Scope derrick & bridle down. 10/11/2021 10/11/2021 6.00 MIRU, MOVE MOB P N/U surface riser, annular, Joe's box, 0.0 0.0 06:00 12:00 flow line, & jet lines. Install 90' mouse hole. SIMOPS- C/O upper & lower IBOP & saver sub, Take on spud mud, Prep pipe shed f/ 5" HWDP pick up. Swap t/ shore pwer @ 09:30 10/11/2021 10/11/2021 1.00 MIRU, MOVE MOB P Seal Joe's box, install master bushings, 0.0 0.0 12:00 13:00 P/U handling tools, Hook up hole fill lines. Page 1/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/11/2021 10/11/2021 0.50 MIRU, MOVE PRTS P Test mud lines t/ 3,500 psi f/ 5 minutes, 0.0 0.0 13:00 13:30 test good, blow down top drive. 10/11/2021 10/11/2021 1.50 MIRU, MOVE PULD P PJSM, P/U 5" HWDP &jars, rack same 0.0 0.0 13:30 15:00 back in derrick. 10/11/2021 10/11/2021 1.75 MIRU, MOVE BHAH P PJSM, P/U motor, stab, & NMPC, M/U 0.0 0.0 15:00 16:45 Bit. 10/11/2021 10/11/2021 1.00 MIRU, MOVE CIRC P Fill conductor & check f/ leaks, no leaks, 0.0 0.0 16:45 17:45 w/ circulating to fill conductor noticed high pump pressure for the GPM being pumped. GPM-120 PSI-1,800 10/11/2021 10/11/2021 1.25 MIRU, MOVE BHAH T Pumped through bleeder on rig floor and 0.0 0.0 17:45 19:00 observed no gravel at shakers. B/D top drive. L/D motor. Observed plug jets in pit. Removed small pea gravel from bit (Used high pressure jet washer to clean out bit). L/D motor #1. 10/11/2021 10/11/2021 1.00 MIRU, MOVE BHAH T P/U replacement motor and M/U stand. 0.0 0.0 19:00 20:00 Observed gravel inside motor #2. while on skate. Cleaned it out and M/U motor # 2 to stand and pumped through it open ended at 200 gpm for 6 minutes to clear potential debris. 10/11/2021 10/11/2021 1.50 MIRU, MOVE BHAH T R/B stand and continued to M/U BHA. 0.0 0.0 20:00 21:30 M/U stand and pump through BHA and motor#2. Observed high pressure while staging up pump rate to 1,575' psi at 194 gpm. 10/11/2021 10/11/2021 1.00 MIRU, MOVE CIRC T Pumped through bleeder on rig floor at 0.0 0.0 21:30 22:30 250 gpm w/ 600 psi. Observed no gravel at the shakers. B/D top drive. Observed no gravel in filter sub. Broke off bit and observed plugged jets and pea gravel again inside the bit. Removed gravel from the nozzles and inside the bit (Used high pressure jet washer to clean out bit).. 10/11/2021 10/11/2021 1.00 MIRU, MOVE CIRC T M/U motor to stand and circulated open 0.0 0.0 22:30 23:30 ended staging up the pumps to 450 gpm. 25 gpm @ 125 psi, & FO 3% 100 gpm @ 137 psi, & FO 7% 200 gpm @ 164 psi, & FO 19% 300 gpm @ 207 psi, & FO 27% 400 gpm @ 268 psi, & FO 30% 450 gpm @ 304 psi, & FO 32% Circulated at 450 gpm for 30 minutes. Total strokes = 2,776 10/11/2021 10/12/2021 0.50 MIRU, MOVE BHAH T R/B stand. Continued to M/U BHA. M/U 0.0 0.0 23:30 00:00 stand and BHA w/ motor # 2 and bit. 10/12/2021 10/12/2021 0.25 MIRU, MOVE CIRC P Circulated BHA w/ motor# 2 and bit. 0.0 120.0 00:00 00:15 Pump pressure was normal. RIH and tagged up at 105' MD. Washed down to 120' MD. 390 gpm w/ 466 psi Page 2/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConoAftllips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/12/2021 10/12/2021 3.75 SURFAC, DRILL DDRL P Drill 16" Surface f/ 120' t/ 301' 120.0 304.0 00:15 04:00 WOB- 2-5K RPM- 50 Torq.- 5-8 K GPM-500 On Btm PSI- 1085 Flow out- 58% ECD- 11.50 PPG P/U- 61 K S/O- 61 K Rot- 61 K AST- 0 ART- 1.2 ADT- 1.2 Total Bit Hrs- 1.2 Total Jars- 0 10/12/2021 10/12/2021 0.50 SURFAC, DRILL CIRC P Circ wellbore clean 304.0 304.0 04:00 04:30 GPM-500 PSI-1000 RPM-50 10/12/2021 10/12/2021 0.25 SURFAC, DRILL TRIP P TOH f/ 301' t/ 124' 304.0 124.0 04:30 04:45 10/12/2021 10/12/2021 1.25 SURFAC, DRILL BHAH P PJSM, M/U MWD, Scribe same t/ motor, 124.0 251.0 04:45 06:00 P/U stand 6" drill collars 10/12/2021 10/12/2021 0.25 SURFAC, DRILL WASH P WASH in Hole f/ 251' t/ 304' 251.0 304.0 06:00 06:15 GPM- 250 10/12/2021 10/12/2021 5.75 SURFAC, DRILL DDRL P Drill 16" Surface f/ 304' t/ 769' 304.0 769.0 06:15 12:00 WOB- 8-10K RPM- 50 Torq.- 5-7 K GPM-500 On Btm PSI- 1380 Flow out- 60% ECD- 11.14 PPG P/U- 89K S/O- 84K Rot- 86K AST-2 ART- 3.4 ADT- 3.6 Total Bit Hrs- 3.6 Total Jars- 1.5 10/12/2021 10/12/2021 2.50 SURFAC, DRILL DDRL P Drill 16" Surface f/ 769' t/ 815' 769.0 815.0 12:00 14:30 WOB- 8-10K RPM- 50 Torq.- 5-7K GPM-500 On Btm PSI- 1380 Flow out- 60% ECD- 11.14 PPG P/U- 90K S/O- 83K Rot- 88K AST-8 ART- 2.4 ADT- 3.2 Total Bit Hrs- 6.8 Total Jars- 4.7 Page 3/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/12/2021 10/12/2021 1.50 SURFAC, DRILL CIRC T Trouble shoot MWD losing pulses, 815.0 815.0 14:30 16:00 Recylced pumps, pump Lo Vis sweeps No success getting tool to pulse, Decision made to trip out of hole for MWD tool 10/12/2021 10/12/2021 1.75 SURFAC, DRILL PMPO T Pulled on elevators f/ 815' - 785' MD but 815.0 248.0 16:00 17:45 observed max OP of 30k at 120k hookload. Pumped out of hole f/ 785' to 248' MD. GPM 250 PSI 450 FO 21 % PU 90k SO 79k 10/12/2021 10/12/2021 2.25 SURFAC, DRILL BHAH T R/B collars. L/D BHA# 1 as per Baker 248.0 0.0 17:45 20:00 Hughes Rep. Cleaned and inspected bit (Good). Observed balling on bit and bottom two stabilisers. 10/12/2021 10/12/2021 0.50 SURFAC, DRILL CLEN T Cleaned and cleared rig floor. 0.0 0.0 20:00 20:30 10/12/2021 10/12/2021 1.50 SURFAC, DRILL BHAH T P/U and removed the BCPM f/ back up 0.0 0.0 20:30 22:00 tools. M/U BHA #2. Initial visual inspection of the pulser showed no evidence of nut plug blockage on the pulser top. 10/12/2021 10/12/2021 1.00 SURFAC, DRILL BHAH T Plugged into MWD to test and align 0.0 0.0 22:00 23:00 highside w/ GWD. 10/12/2021 10/12/2021 0.50 SURFAC, DRILL BHAH T Continued to M/U BHA #2. 0.0 157.0 23:00 23:30 10/12/2021 10/13/2021 0.50 SURFAC, DRILL TRIP T TIH f/ 157' to 625' MD w/ 5" DP f/ 157.0 625.0 23:30 00:00 derrick. SO 84k Monitored displacement on trip pit. 10/13/2021 10/13/2021 0.50 SURFAC, DRILL WASH T Washed down f/ 625' to 815' MD. 625.0 815.0 00:00 00:30 GPM 500 PSI1160 FO 35% RPM 50 TQ 2.5k ROT SO Wt 90k 10/13/2021 10/13/2021 5.50 SURFAC, DRILL DDRL P Drill 16" Surface f/ 815't/ 1,086' 815.0 1,086.0 00:30 06:00 WOB- 12-15K RPM- 60 Torq.- 5-7K GPM-650 On Btm PSI- 2172 Flow out- 37% ECD- 11.39 PPG P/U- 96K S/O- 88K Rot- 94K AST- 1.5 ART- 2.5 ADT- 4.0 Total Bit Hrs- 10.8 Total Jars- 8.7 Page 4/59 Report Printed: 12/16/2021 Rig: DOYON 25 Time Log Start Time End Time Dur (hr) 10/13/2021 10/13/2021 6.00 1 SU 06:00 12:00 10/13 12:00 18:00 10/13 18:00 00:00 Operations Summary (with Timelog Depths) MT7-01 Phase Activity Code Time P-T-X DRILL DDRL P 6.00 1 SURFAC, DRILL I DDRL I P RIG RELEASE DATE 11/29/20211 Operation Drill 16" Surface f/ 1,086't/ 1,558' WOB- 12-15K RPM- 60 Torq.- 5-7K GPM-775 On Btm PSI- 2600 Flow out- 53% ECD- 11.32 PPG P/U- 99K S/O- 98K Rot- 97K AST- 1.0 ART- 2.5 ADT- 3.5 Total Bit Hrs- 14.3 Total Jars- 12.2 Drill 16" Surface f/ 1,558' t/ 2,121' WOB- 7K RPM- 60 Torq.- 6K GPM-854 On Btm PSI- 2950 Flow out- 54% ECD- 11.32 PPG P/U- 106K S/O- 108K Rot- 108K AST- 2.1 ART- 2.4 ADT- 4.5 Total Bit Hrs- 18.8 Total Jars- 16.7 Pumped 25 bbl sweep at 2,129' (No increase in cuttings return). Drill 16" Surface f/ 2,121' t/ 2,729' WOB- 17K RPM- 60 Torq.- 7K GPM-874 On Btm PSI- 3450 Flow out- 58% ECD- 11.61 PPG P/U- 115K S/O- 111 K Rot- 109K Job: DRILLING ORIGINAL Start Depth (ftKB) End Depth (ftKB) 1,086.0 1,558.0 AST- 1.6 ART- 2.9 ADT- 4.5 Total Bit Hrs- 23.3 Total Jars- 21.2 Pumped 25 bbl sweep at 2,544' (20% increase in cuttings return). 1,558.01 2,121.01 Page 5/59 Report Printed: 12/16/2021 1 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/14/2021 10/14/2021 6.00 SURFAC, DRILL DDRL P Drill 16" Surface f/ 2,729' t/ 3,237'. 2,729.0 3,237.0 00:00 06:00 WOB- 17-25K RPM- 60-70 Torq.- 7-9K GPM-850 On Btm PSI- 3485 Flow out- 60% ECD- 11.67 PPG P/U- 127K S/O- 111 K Rot- 118K AST-6 ART- 4 ADT- 4.6 Total Bit Hrs- 27.9 Total Jars- 25.8 10/14/2021 10/14/2021 3.75 SURFAC, DRILL DDRL P Drill 16" Surface f/ 3,237' t/ 3,434'. 3,237.0 3,434.0 06:00 09:45 WOB- 17-35K RPM- 60-70 Torq.- 7-9K GPM-850 On Btm PSI- 3485 Flow out- 60% ECD- 11.7 PPG P/U- 130K S/O- 116K Rot- 119K AST- 0 ART- 3.1 ADT- 3.1 Total Bit Hrs- 31 Total Jars- 28.9 10/14/2021 10/14/2021 5.25 SURFAC, CASING CIRC P Circulate 2 Hi-vis sweeps surface t/ 3,434.0 2,877.0 09:45 15:00 surface racking a stand back after each sweep has reached surface f/ 3,434' to 2,877' MD. Circ 3 bottoms up rack a stand back each bottoms up. GPM-900 PSI-3350 RPM-90 Torq-4-5k ECD-11.3 PU 112k Total pumped strokes = 41,500 10/14/2021 10/14/2021 0.25 SURFAC, CASING OW FF P Flow check well, well satic 2,877.0 2,877.0 15:00 15:15 10/14/2021 10/14/2021 2.75 SURFAC, CASING BKRM P BROOH f/ 2,877' to 2,287' MD. 2,877.0 2,287.0 15:15 18:00 GPM-900 PSI-3350 RPM-60 Torq-5-8k FO 54% ECD-11.35 PU 103 @ full rate. Observed clay unloading at shakers at: 2,466', 2,442', 2,386', and 2,337' MD. Page 6/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/14/2021 10/15/2021 6.00 SURFAC, CASING BKRM P BROOH f/ 2,287'to 1,090' MD. 2,287.0 1,090.0 18:00 00:00 GPM-894 PSI-3020 RPM-60 Torq-3k FO 54% ECD-11.66 PU 88 @ full rate. Observed clay unloading at shakers at: 2,234', 2,235', 2,147', 2,071', 2,002', 1,980', 1,774', 1,549' MD, 1362', and 1,224' MD 10/15/2021 10/15/2021 0.50 SURFAC, CASING CIRC P CBU 2X Rot & Rec f/ 1,090' to 994' MD. 1,090.0 994.0 00:00 00:30 GPM 900 PSI 3085 FO 54% RPM 60 TQ 3k ECD 11.62 PU 87k @ rate. Total pump strokes = 5943 10/15/2021 10/15/2021 0.25 SURFAC, CASING TRIP P POOH on elevators while racking back 994.0 619.0 00:30 00:45 5" DP in derrick f/ 994' to first stand of HWDP at 619' MD. Up Wt 95k DN Wt 87k Monitored displacement at trip tank. 10/15/2021 10/15/2021 0.25 SURFAC, CASING OWFF P OWFF (Static). B/D Top Drive. 619.0 619.0 00:45 01:00 10/15/2021 10/15/2021 0.50 SURFAC, CASING TRIP P POOH on elevators while R/B HWDP 619.0 157.0 01:00 01:30 and DC in derrick f/ 619' to 157' MD. Up Wt 82k DN Wt 88k Monitored displacement at trip tank. 10/15/2021 10/15/2021 2.00 SURFAC, CASING BHAH P L/D BHA #2. 157.0 0.0 01:30 03:30 10/15/2021 10/15/2021 0.50 SURFAC, CASING CLEN P Cleaned and cleared rig floor of Surface 0.0 0.0 03:30 04:00 BHA #2. Monitored displacement at trip tank. 10/15/2021 10/15/2021 1.25 SURFAC, CASING RURD P Relay 13 3/8" casing running equipment 0.0 0.0 04:00 05:15 to rig floor. R/U casing running tools. 10/15/2021 10/15/2021 1.00 SURFAC, CASING PUTB P PJSM, RIH w/ 13 3/8" L80 68# casing f/ 0.0 162.0 05:15 06:15 shoe to a projected detph of 162'. Check floats, floats ok 10/15/2021 10/15/2021 2.25 SURFAC, CASING PUTB P Cont. RIH w/ 13 3/8" L80 68# casing f/ 162.0 1,016.0 06:15 08:30 162' t/ 1,016' Monitor returns on pit #2 10/15/2021 10/15/2021 0.50 SURFAC, CASING CIRC P Circ. bottoms up @ 1,016' @ the bottom 1,016.0 1,016.0 08:30 09:00 of the Perma-frost BPM-6 PSI-105 Page 7/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/15/2021 10/15/2021 5.50 SURFAC, CASING PUTB P Cont. RIH w/ 13 3/8" L80 68# casing f/ 1,016.0 3,384.0 09:00 14:30 1,016' t/ 3,384' Filling pipe every 10 jts. Monitor returns on pit #2 P/U-210 S/0-190 10/15/2021 10/15/2021 1.00 SURFAC, CASING WASH P Wash 13 3/8" casing f/ 3,384' t/ 3,424' 3,384.0 3,424.0 14:30 15:30 BPM-2 PSI- 200 10/15/2021 10/15/2021 2.50 SURFAC, CEMENT CIRC P Reciprocate casing w/ circulating & 3,424.0 3,424.0 15:30 18:00 condtioning mud for cement job f/ 3,424' to 3,420' MD. Staged pumps up f/ 2 bpm t/ 8 bpm GPM 328 PSI 281 FO 23% PU 206k SO 177k Total pump strokes = 6720 10/15/2021 10/15/2021 0.50 SURFAC, CEMENT RURD P B/D top drive and swapped over to 3,424.0 3,424.0 18:00 18:30 cement lines. Established circulation through cement line. 10/15/2021 10/15/2021 2.50 SURFAC, CEMENT CIRC P Reciprocate casing w/ circulating & 3,424.0 3,424.0 18:30 21:00 condtioning mud for cement job f/ 3,424' to 3,420' MD. Staged pumps up f/ 2 bpm t/ 8 bpm GPM 328 PSI 281 FO 23% PU 206k SO 177k Total pump strokes = xxxx SIMOPS: PJSM w/ cementers. 10/15/2021 10/16/2021 3.00 SURFAC, CEMENT CMNT P Performed cement job. Pressure tested 3,424.0 3,424.0 21:00 00:00 surface lines to 3,500 psi (Good test). Pump sequence was as follows: 104 bbls of 11 ppg Mud Push Il, Dropped bottom plug, and 480 bbls of 11 ppg Lead Cement. Reciprocated f/ 3424' to 3,411' MD. PU 220k SO 200k Page 8/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/16/2021 10/16/2021 2.00 SURFAC, CEMENT CMNT P Reciprocated f/ 3,424' to 3,420' MD. 3,424.0 3,424.0 00:00 02:00 while cementing (Stopped reciprocating 59 bbls into displacement).. PU 220k SO 204k Continued pumping cement as follows: 73 bbls of 15.8 ppg Tail Cement, Dropped top plug, Pumped 20 bbls H2O, Lined up to displace w/ the rig. Displaced w/ rig 480.5 bbls. Bumped plug w/ FCP of 468 psi (4062 strokes), - Pressure increased to 968 psi (Held for 5 min), - Bled off pressure, and - Checked floats (Floats held). Cement in place as of 10/16/2021 0156hr. 244 bbls 11.0 ppg lead cement returns on surface. 10/16/2021 10/16/2021 2.50 SURFAC, CEMENT RURD P R/D cement running equipment. L/D 3,424.0 3,424.0 02:00 04:30 landing joint. Cleaned and cleared rig floor. Flushed all cement contaminated lines thoroughly w/ black water. Flushed surface riser and annular w/ black water. Cleaned cement valves. Cleaned out Joe's box. 10/16/2021 10/16/2021 3.00 SURFAC, CEMENT NUND P N/D surface riser and annular. SIMOPS: 3,424.0 3,424.0 04:30 07:30 Pull FLO riser, remove jet lines, remove flow line, and slide joe box. 10/16/2021 10/16/2021 4.50 SURFAC, WHDBOP NUND P Install casing & tubing spool as per 3,424.0 3,424.0 07:30 12:00 FMC, Orient same, Nipple up drilling riser & BOPE SIMOPS- Clean pits, slide Joe's box, install flow line, choke & kill lines, N/U MPD equipment Test FMC wellhead seal t/ 1,000 psi f/ 10 minutes test witnessed by COPA (Brandon Book) 10/16/2021 10/16/2021 1.25 SURFAC, WHDBOP RURD P Install test plug and MPD cap. Flush and 3,424.0 3,424.0 12:00 13:15 circulated through MPD skid. 10/16/2021 10/16/2021 0.50 SURFAC, WHDBOP PRTS P Tested MPD orbit valve and shell test 0.0 0.0 13:15 13:45 250 psi (low)/1,000 psi (high) for 5 minutes each. Page 9/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/16/2021 10/16/2021 4.75 SURFAC, WHDBOP BOPE P Tested BOPE. All tests to 250 psi (low 0.0 0.0 13:45 18:30 for 5 minutes) and 3,500 psi (high for 10 minutes) all charted. With exception to manual operated and super choke tested to 250 psi (low) & 2,000 psi (high) for 5 charted minutes, w/ 5" test joint tested annular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR, Test choke valves 1- 15, Manual operated and super choke, choke and kill manuals and HCR's, 4" valve on kill line, 2 x 5" FOSV, 5" dart valve, Upper and lower IBOP. Blind/Shear rams; Performed Koomey draw down, ACC = 3000 pis, Manifold = 1500 psi, ACC = 1650 psi after all functions on bottles, sec for 200 psi. Build w/ 2 electric pumps, 95 sec to build full system pressure w/ 2 electrical and 2 air pumps, closing times annular = 23 sec. UPR = 10 sec, Blind / Shears = 16 sec, LPR = 16 sec, choke HCR = 2 sec, Kill HCR = 2 sec. Test PVT gain/loss and flow out alarms. Test LEL and 1-12S alarms, AOGCC rep Austin McCleod Waived witness at 0705hr on 10/15/2021. BLM rep Mutasim Elganzoory waived witness at 1447hr on 10/15/2021. 10/16/2021 10/16/2021 0.75 SURFAC, DRILLOUT RURD P R/D and B/D test equipment. 0.0 0.0 18:30 19:15 10/16/2021 10/16/2021 0.75 SURFAC, DRILLOUT RURD P Pull test plug and installed wear ring. 0.0 0.0 19:15 20:00 10/16/2021 10/16/2021 0.75 SURFAC, DRILLOUT RGRP P Hung blocks and changed out hookload 0.0 0.0 20:00 20:45 sensator on deadman. 10/16/2021 10/16/2021 1.25 SURFAC, DRILLOUT SLPC P Cut and slip 9 wraps (70'), Calbirated 0.0 0.0 20:45 22:00 blocks. 10/16/2021 10/16/2021 0.50 SURFAC, DRILLOUT SVRG P Serviced top drive and upper IBOP. 0.0 0.0 22:00 22:30 Chinked up flow box. 10/16/2021 10/16/2021 0.50 SURFAC, DRILLOUT RURD P Installed trip nipple and hole fill line. 0.0 0.0 22:30 23:00 10/16/2021 10/17/2021 1.00 SURFAC, DRILLOUT BHAH P M/U BHA# f/ surface to 83' MD. 0.0 83.0 23:00 00:00 PU 56k SO 56k 10/17/2021 10/17/2021 3.00 SURFAC, DRILLOUT BHAH P M/U BHA#3. Plugged in to verify tool 83.0 588.0 00:00 03:00 communications and loaded sources, Monitored displacement via trip tank. 10/17/2021 10/17/2021 3.00 SURFAC, DRILLOUT TRIP P TIH f/ 588'to 1,528' MD and shallow 588.0 3,130.0 03:00 06:00 tested MWD at 1,528' MD (Good). Resumed TIH to 3,130' MD. 10/17/2021 10/17/2021 1.00 SURFAC, DRILLOUT CIRC P Circulate & Condition mud prior to 3,130.0 3,130.0 06:00 07:00 casing test. GPM-900 PSI-2430 F/0-46% 4040 strokes pumped 10/17/2021 10/17/2021 1.50 SURFAC, DRILLOUT PRTS P Test 13 3/8" t/ 3,500 psi f/ 30 min. 3,130.0 3,130.0 07:00 08:30 charted test, 5.7 bbls pumped t/ reach test pressure, bled 5.7 bbls back t/ pits Page 10/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/17/2021 10/17/2021 0.50 SURFAC, DRILLOUT WASH P Wash f/ 3,130' t/ 3,319' Tag cement @ 3,130.0 3,319.0 08:30 09:00 3,319' GPM-500 PSI-870 10/17/2021 10/17/2021 0.25 SURFAC, DRILLOUT DRLG P Drill cement f/ 3,319' t/ 3,340' 3,319.0 3,340.0 09:00 09:15 GPM-500 PSI-925 RPM-60 Torq-5-7K P/U-130K S/0-110K Rot-121 K 10/17/2021 10/17/2021 2.75 SURFAC, DRILLOUT DRLG P Drill plugs (3,340'), float collar (3,342'), 3,340.0 3,422.0 09:15 12:00 and cement in shoe track, and shoe (3,414') f/ 3,340' t/ 3,422' MD. GPM- 500-700 PSI- 870-1625 RPM- 60-110 Torq- 5-1 OK FO- 20-40% Up Wt- 130K SO Wt- 110K RTW- 121K 10/17/2021 10/17/2021 1.75 SURFAC, DRILLOUT DDRL P Drilled shoe (3,424'), rat hole (3,434), 3,422.0 3,454.0 12:00 13:45 and 20' new formation f/ 3,422' to 3,454' MD. GPM- 500-700 PSI- 870-1625 RPM- 60-110 Torq- 5-1 OK FO- 20-40% Up Wt-130K SO Wt- 110K RTW- 121 K Displaced to 9.6 ppg LSND on the fly. 10/17/2021 10/17/2021 0.75 SURFAC, DRILLOUT CIRC P C & C whilst reciprocating pipe between 3,454.0 3,454.0 13:45 14:30 3,454' to 3,424' MD. GPM- 700 PSI- 1013 FO- 38% RPM- 100 TQ- 10k PU- 130K SO- 110K RTW- 117K Total pumped strokes = 8710 10/17/2021 10/17/2021 1.00 SURFAC, DRILLOUT FIT P Pulled up into casing. R/U and 3,454.0 3,454.0 14:30 15:30 performed FIT to 18.5 ppg EMW (1,420 psi) f/ 10 minutes charted. 3.3 bbls pumped and 1.9 bbls bled back. 10/17/2021 10/17/2021 0.50 INTRM1, DRILL OWFF P OWFF (Static). R/D and B/D test 3,454.0 3,454.0 15:30 16:00 1 1 equipment. Page 11/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/17/2021 10/17/2021 2.00 INTRM1, DRILL DDRL P Drilled 12.25" intermediate hole f/ 3,454' 3,454.0 3,786.0 16:00 18:00 to 3,786' MD. GPM- 900 PSI- 1704 RPM- 150 TQ- 5-11 K FO- 43% Up Wt- 138K SO Wt- 125K RTW- 132K ADT- 1.8 Total Bit Hours- 1.8 Total Jar Hours- 117.9 10/17/2021 10/18/2021 6.00 INTRM1, DRILL DDRL P Drilled 12.25" intermediate hole f/ 3,786' 3,786.0 4,874.0 18:00 00:00 to 4,874' MD. GPM- 1050 PSI- 2573 RPM-175 TQ- 5-11 K FO- 52% Up Wt- 150K SO Wt- 136K RTW- 137K ADT- 4.1 Total Bit Hours- 5.9 Total Jar Hours- 122.0 10/18/2021 10/18/2021 4.25 INTRM1, DRILL DDRL P Drilled 12.25" intermediate hole f/ 4,874' 4,874.0 5,577.0 00:00 04:15 t/ 5,577' MD. GPM- 1050 PSI- 2760 RPM-175 TQ- 12-16K FO- 47% Up Wt- 160K SO Wt- 140K RTW- 151 K ADT- 2.9 Total Bit Hours- 8.8 Total Jar Hours- 124.9 10/18/2021 10/18/2021 2.00 INTRM1, DRILL CIRC T Circ. bottoms up @ 5,575' w/ rotating & 5,575.0 5,575.0 04:15 06:15 reciprocating pipe GPM-1050 RPM-150 Page 12/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/18/2021 10/18/2021 1.75 INTRM1, DRILL RGRP T While backing out of stump observed 5,575.0 5,575.0 06:15 08:00 connection between the IBOP's break, Attempted to use rig tongs to retorque the connection but was unable to apply the make up tongs due to position of service loop. Loosen compression rings on 1-bop's & saver sub to raise back up wrench and re -torque upper I -bop, slide compression rings back in place on I - bop and torque & tiw wire same. Attempt t/ break out saver sub in stump again with no success, applied 46K to connection and still wouldn't break. Applied steam & attempted to break again with 55K applied, personnel observed upper 1-bop back out of top drive quit, Loosend compression rings on 1-bop and raised back up wrench on topdrive and retorqued I -bop and quil connection, re -installed compression clamp on break and torqued & tie wired same, Break saver sub between 1-bop & saver sub leaving saver sub made up into joint of drill pipe, L/D joint of drill pipe that had saver sub in it, M/U new saver sub t/ 1-bop, install compression ring on break between I -bop and saver sub, torque and tie wire bolts on compression clamp. Break circualtion whenever possible through out change out and retorquing. 10/18/2021 10/18/2021 4.00 INTRM1, DRILL DDRL P Drilled 12.25" intermediate hole f/ 5,575' 5,575.0 6,225.0 08:00 12:00 t/ 6,225' MD. GPM- 1050 PSI- 2890 RPM-175 TQ- 12-16K FO- 47% ECD-10.9 Up Wt- 173K SO Wt- 145K RTW- 153K ADT- 2.8 Total Bit Hours- 11.6 Total Jar Hours- 127.7 10/18/2021 10/18/2021 6.00 INTRM1, DRILL DDRL P Drilled 12.25" intermediate hole f/ 6,225' 6,225.0 7,060.0 12:00 18:00 t/ 7,060' MD. GPM- 1050 PSI- 3036 RPM-160 TQ- 12-16K FO- 46% ECD-11.09 Up Wt- 182K SO Wt- 159K RTW- 167K ADT- 3.9 Total Bit Hours- 15.5 Total Jar Hours- 131.6 Page 13/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/18/2021 10/19/2021 6.00 INTRM1, DRILL DDRL P Drilled 12.25" intermediate hole f/ 7,060' 7,060.0 8,064.0 18:00 00:00 t/ 8,064' MD. GPM- 1020 PSI- 3119 RPM-160 TQ- 12-16K FO- 48% ECD-10.9 Up Wt- 222K SO Wt- 170K RTW- 190K ADT- 4.0 Total Bit Hours- 19.5 Total Jar Hours- 135.6 10/19/2021 10/19/2021 2.00 INTRM1, DRILL DDRL P Drilled 12.25" intermediate hole f/ 8,064' 8,064.0 8,288.0 00:00 02:00 t/ 8,288' MD. GPM- 1050 PSI- 2980 RPM-150 TQ- 12-16K FO- 44% ECD-10.43 Up Wt- 222K SO Wt- 170K RTW- 190K ADT- 1.7 Total Bit Hours- 21.2 Total Jar Hours- 137.3 10/19/2021 10/19/2021 1.00 INTRM1, DRILL CIRC T Circulating while reciprocating pipe f/ 8,288.0 8,288.0 02:00 03:00 8,217' to 8,277' MD. Troubleshooted Amphion System. Electrician was mobilized to location and the SPC had to be reset. Electrical outlets on the rig were fluctuating between 8 Vac to 128 Vac. This is possibly a result of dirty Hi -Line power which might have effected the Amphion System. Contacted Alpine Electrical lead and informed him of the voltage fluctuations. He suspected that the MT6 Harmonic filter was effecting power to the MT7 pad. He turned off the MT6 Harmonic filter and electrical voltages stabilized. 10/19/2021 10/19/2021 3.00 INTRM1, DRILL DDRL P Drilled 12.25" intermediate hole f/ 8,288' 8,288.0 8,644.0 03:00 06:00 t/ 8,644' MD. GPM- 1050 PSI- 3110 RPM-150 TQ- 12-16K FO- 47% ECD-10.43 Up Wt- 225K SO Wt- 178K RTW- 193K ADT- 2.3 Total Bit Hours- 23.5 Total Jar Hours- 139.6 Page 14/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhimps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/19/2021 10/19/2021 6.00 INTRM1, DRILL DDRL P Drilled 12.25" intermediate hole f/ 8,644' 8,644.0 9,146.0 06:00 12:00 t/ 9,146' MD. GPM- 945 PSI- 3345 RPM-170 TQ- 12-16K FO- 47% ECD-11.42 Up Wt- 240K SO Wt- 180K RTW- 200K ADT- 4.5 Total Bit Hours- 28 Total Jar Hours- 144.1 10/19/2021 10/19/2021 2.50 INTRM1, DRILL DDRL P Drilled 12.25" intermediate hole f/ 9,146' 9,146.0 9,272.0 12:00 14:30 t/ 9,272' MD. GPM- 950 PSI- 3385 RPM-170 TQ- 12-16K FO- 47% ECD-11.42 Up Wt- 242K SO Wt- 180K RTW-201K ADT- 1.2 Total Bit Hours- 29.2 Total Jar Hours- 145.3 10/19/2021 10/19/2021 7.00 INTRM1, CASING CIRC P Circulated, rotated, and reciprocated 9,272.0 8,870.0 14:30 21:30 racking back one stand per bottoms up for the first two bottoms up, followed by one stand per two bottoms up f/ 9,272' t/ 8,870' MD. GPM 935 PSI 3144 FO 44% RPM 130 TQ 10k ECD 11.24 PU 210k SO 192k Total pumped strokes - 60500 Pumped a 60 bbl H-Vis Nut Plug Sweep. 10/19/2021 10/19/2021 0.50 INTRM1, CASING OWFF P OWFF (Static) 8,870.0 8,870.0 21:30 22:00 10/19/2021 10/19/2021 1.00 INTRM1, CASING TRIP P Attempted to POOH on elevators f/ 8,870.0 8,870.0 22:00 23:00 8.870' t/ 8,690' MD. Encountered tight spot and pulled to 30k OP at 8,748' MD. Hole was swabbing. RIH to, 8,870' MD. Established circulation at 900 gpm, 2,939 psi, 130 rpm, and TQ 10k.. PU 235k SO 169k 10/19/2021 10/20/2021 1.00 INTRM1, CASING PMPO P Pumped out of hole f/ 8,870't/ 8,493' 8,870.0 8,493.0 23:00 00:00 MD. GPM 923 PSI 3133 FO 43% PU 220k SO 170k Page 15/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/20/2021 10/20/2021 0.25 INTRM1, CASING PMPO P Pumped Out of hole f/ 8,493' MD t/ 8,493.0 8,408.0 00:00 00:15 8,408' MD. GPM 923 PSI 3030 FO 43% ECD 11.33 PU 215k 10/20/2021 10/20/2021 0.50 INTRM1, CASING TRIP P Attempted to POOH on elevators f/ 8,408.0 8,364.0 00:15 00:45 8,408' t/ 8,364' MD. PU 230k SO 160k Unsuccesful observed 40k OP. 10/20/2021 10/20/2021 0.50 INTRM1, CASING CIRC P RIH t/ 8,501 MD. Circulated, 8,364.0 8,408.0 00:45 01:15 reciprocated, and rotated pipe to 8,408' MD. GPM 900 PSI 2928 FO 43% ECD 11.38 RPM 130 TQ 10k PU 183k Total stokes pumped 5040. 10/20/2021 10/20/2021 1.00 INTRM1, CASING TRIP P POOH on elevators f/ 8,400't/ 8,255' 8,400.0 8,255.0 01:15 02:15 MD w/ 5" DP racked back in the derrick. PU 220k SO 160k Monitored displacement on Pit #2. Observed OP 2X. 10/20/2021 10/20/2021 0.50 INTRM1, CASING CIRC P RIH t/ 8,308' MD. Circulated, 8,308.0 8,303.0 02:15 02:45 reciprocated, and rotated pipe to 8,262' MD. GPM 923 PSI 3045 FO 45% ECD 11.37 RPM 130 TQ 9k UP Wt at rate 180k Total strokes pumped 2352 Stopped pumps and attempted to pull at 8,255' twice. Once w/ 50k OP and second w/ 60k OP. RIH to 8,303' MD. 10/20/2021 10/20/2021 3.00 INTRM1, CASING BKRM P BROOH f/ 8,303't/ 7,467' MD. 8,303.0 7,467.0 02:45 05:45 GPM 900 RPM 130-150 FO 44% PU at rate 181 k 10/20/2021 10/20/2021 1.50 INTRM1, CASING CIRC P Pump 50 bbls Hi-vis sweep w/ rotating & 7,467.0 7,368.0 05:45 07:15 reciprocating pipe f/ 7,467' t/ 7,368' GPM-900 PSI-2906 RPM-125 Torq- 11-13 Total strokes pumped- 15,560 Page 16/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConoAftllips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/20/2021 10/20/2021 4.75 INTRM1, CASING BKRM P BROOH f/ 7,368' t/ 6,330' MD. 7,368.0 6,330.0 07:15 12:00 GPM 900 PSI 2060 RPM 130-150 FO 44% Torq- 11-13 ECD 11.65 PU at rate 163k 10/20/2021 10/20/2021 6.00 INTRM1, CASING BKRM P BROOH f/ 6,330' U 4,540' MD. 6,330.0 4,540.0 12:00 18:00 GPM 900 PSI 2335 RPM 150 FO 43% Torq- 10 ECD 11.62 RTW 140k 10/20/2021 10/21/2021 6.00 INTRM1, CASING BKRM P BROOH f/ 4,540' U 3,977' MD. 4,540.0 3,977.0 18:00 00:00 GPM 900 PSI 2335 RPM 150 FO 43% Torq- 1 Ox ECD 11.62 PU at rate 140k Tight spots at 4,093' MD. 10/21/2021 10/21/2021 4.50 INTRM1, CASING BKRM P BROOH f/ 3,977' U 3,411' MD. 3,977.0 3,411.0 00:00 04:30 GPM 900 PSI 2060 RPM 130-150 FO 44% Torq- 11-13 ECD 11.65 PU at rate 163k 10/21/2021 10/21/2021 1.50 INTRM1, CASING CIRC P Circulated hole clean at shoe. Rotated 3,411.0 3,317.0 04:30 06:00 and reciprocated pipe f/ 3,411' t/ 3,317' MD. GPM 1000 PSI 2400 FO 45% RPM 80 TQ 5k ECD 11.04 RPM-125 PU 116k Total pumped strokes = 10,732 10/21/2021 10/21/2021 0.50 INTRM1, CASING OWFF P B/D Top drive. OWFF (Static) 3,317.0 3,315.0 06:00 06:30 10/21/2021 10/21/2021 0.25 INTRM1, CASING TRIP P POOH on elevators f/ 3,315' t/ 3,221' 3,315.0 3,221.0 06:30 06:45 MD. Observeed swabbing. PU 130k SO 117k 10/21/2021 10/21/2021 1.75 INTRM1, CASING PMPO P Pumped out of the hole f/ 3,221' t/ 2,560' 3,221.0 2,560.0 06:45 08:30 MD. GPM 1000 PSI 2423 FO 44% Page 17/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/21/2021 10/21/2021 1.00 INTRM1, CASING CIRC P Circulated, rotated, and reciprocated f/ 2,560.0 2,469.0 08:30 09:30 2,570' V 2,469' MD. GPM 1000 PSI 2321 FO 50% RPM 50 TQ 3k ECD 11.04 PU 108k SO 118k RTW 110k Total pumped strokes 9809 B/D top drive. 10/21/2021 10/21/2021 1.25 INTRM1, CASING TRIP P POOH on elevators f/ 2,469' V 620' MD. 2,469.0 620.0 09:30 10:45 PU 110k SO 100k Monitored displacement via trip tank. 10/21/2021 10/21/2021 0.25 INTRM1, CASING OWFF P OWFF (Static) 620.0 620.0 10:45 11:00 SIMOPS: Pull PS-21 and installed master bushings. 10/21/2021 10/21/2021 0.50 INTRM1, CASING TRIP P POOH on elevators f/ 620' V 126' MD 620.0 126.0 11:00 11:30 while racking back HWDP and DC stands in the derrick. Monitored displacement via trip tank. 10/21/2021 10/21/2021 2.50 INTRM1, CASING BHAH P L/D BHA#3. Monitored displacement via 126.0 0.0 11:30 14:00 trip tank. 10/21/2021 10/21/2021 1.00 INTRM1, CASING CLEN P Cleaned and cleared rig floor. 0.0 0.0 14:00 15:00 10/21/2021 10/21/2021 0.75 INTRM1, CASING WWWH P M/U wash tool and flush stack. 0.0 0.0 15:00 15:45 10/21/2021 10/21/2021 0.75 INTRM1, CASING RURD P B/D top drive and drained stack. 0.0 0.0 15:45 16:30 10/21/2021 10/21/2021 0.75 INTRM1, CASING RURD P Pull wear bushing. 0.0 0.0 16:30 17:15 10/21/2021 10/21/2021 1.00 INTRM1, CASING RURD P C/O upper VBR's to 9 5/8" SBR. 0.0 0.0 17:15 18:15 10/21/2021 10/21/2021 1.25 INTRM1, CASING RURD P Bring up casing tools and rig up Volant. 0.0 0.0 18:15 19:30 10/21/2021 10/21/2021 2.50 INTRM1, CASING RURD P R/U to test 9 5/8" and 9 7/8" test joints. 0.0 0.0 19:30 22:00 10/21/2021 10/22/2021 2.00 INTRM1, CASING PRTS P Test upper 9 5/8" solid body rams to 250 0.0 0.0 22:00 00:00 psi for 5 minutes and 3,500 psi for 10 minutes. 10/22/2021 10/22/2021 3.00 INTRM1, CASING PRTS P Test upper 9 7/8" test joint to 250 psi for 0.0 0.0 00:00 03:00 5 minutes and 3,500 psi for 10 minutes. 10/22/2021 10/22/2021 0.50 INTRM1, CASING RURD P L/D 9 7/8" test joint. C/O elevators and 0.0 0.0 03:00 03:30 P/U kick joint.Discussed with rig crew on closing in the well. SIMOPS: B/D chooke and kill lines. 10/22/2021 10/22/2021 2.50 INTRM1, CASING PUTB P M/U shoe track and RIH w/ 9 7/8" 0.0 120.0 03:30 06:00 casing to 120' MD. 10/22/2021 10/22/2021 6.00 INTRM1, CASING PUTB P Continue RIH 9 7/8" 62.8# L80 H523 x 9 120.0 1,792.0 06:00 12:00 5/8" 43.5# L80 INT casing as per CPAI running tally from 120' MD to 1792' MD 10/22/2021 10/22/2021 6.00 INTRM1, CASING PUTB P Continue RIH 9 7/8" 62.8# L80 H523 x 9 1,792.0 4,353.0 12:00 18:00 5/8" 43.5# L80 INT casing as per CPAI running tally from 1792' MD to 4353' MD P/U wt188k S/O wt176k Page 18/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/22/2021 10/22/2021 4.00 INTRM1, CASING PUTB P Continue RIH 9 7/8" 62.8# L80 H523 x 9 4,353.0 6,000.0 18:00 22:00 5/8" 43.5# L80 INT casing as per CPAI running talley from 4353' MD to 6000' MD P/U wt 255 S/O wt 222k 10/22/2021 10/23/2021 2.00 INTRM1, CASING CIRC P Stage pumps up as per CPAI, .5 bpm 6,000.0 6,000.0 22:00 00:00 every 15 min to 4 bpm Circulate Bottoms up .5 bpm @ 80 psi 1 bpm @ 145 psi 1.5 bpm @ 152 psi 2 bpm @ 170 psi 2.5 bpm @ 175 psi 3 bpm @ 172 psi 3.5 bpm @ 169 psi 4 bpm @ 164 psi Monitoring mud weight at mud pits. mud weight in 10.8 ppg mud weight out 10.8ppg P/U wt 250k S/O wt 225k Caught mud sample @ bottoms up 10/23/2021 10/23/2021 2.00 INTRM1, CASING CIRC P Stage pumps up as per CPAI, .5 bpm 6,000.0 6,000.0 00:00 02:00 every 15 min from 4.5 bpm to 6 bpm circulated 20 min @ 6 bpm shakers were clean 4.5 bpm @ 173 psi 5 bpm @ 188 psi 5.5 bpm @ 201 psi 6 bpm @ 210 psi @ 13% flow out. Monitoring mud weight at mud pits. mud weight in 10.8 ppg mud weight out 10.8ppg P/U wt 250k S/O wt 225k 10/23/2021 10/23/2021 4.00 INTRM1, CASING PUTB P Continue RIH 9 7/8" 62.8# L80 H523 x 9 6,000.0 7,970.0 02:00 06:00 5/8" 43.5# L80 INT casing as per CPAI running talley from 6000' MD to 7970' MD P/U wt 260 k S/O wt 235 k 10/23/2021 10/23/2021 3.00 INTRM1, CASING PUTB P Continue RIH 9 7/8" 62.8# L80 H523 x 9 7,950.0 9,200.0 06:00 09:00 5/8" 43.5# L80 INT casing as per CPAI running talley from 7970' MD to 9200' MD P/U wt 260 k S/O wt 235 k 10/23/2021 10/23/2021 3.00 INTRM1, CASING CIRC P Circulate @ 9200' Staging up flow rates 9,200.0 9,200.0 09:00 12:00 21 gpm @ 275 psi , 42 gpm @ 295 psi, 63 gpm @ 315 psi, 189 gpm @ 364 psi, 210 gpm @ 372 psi flow out 15% P/U wt 370k S/O wt 275k 10/23/2021 10/23/2021 1.50 INTRM1, CASING CIRC P Circulate @ 9200' to 9162' Staging up 9,200.0 9,162.0 12:00 13:30 flow rates 21 gpm @ 275 psi , 42 gpm @ 295 psi, 63 gpm @ 315 psi, 189 gpm @ 364 psi, 210 gpm @ 372 psi flow out 15% P/U wt 370k S/O wt 275k 10/23/2021 10/23/2021 4.50 INTRM1, CASING PUTB P P/U joint # 220 and pup joints and work 9,200.0 9,260.0 13:30 18:00 pipe and est circulation as CPAI rep f/ 9260 to 9211' P/U 400K S/O 265k 10/23/2021 10/23/2021 2.50 INTRM1, CASING CIRC P Continue to work down pipe joints and 9,560.0 9,260.0 18:00 20:30 establish circulation as per CPAI Rep.f/ 9211' to 9260' established circulation stage pumps up from .5 bpm to 6 bpm Page 19/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/23/2021 10/24/2021 3.50 INTRM1, CEMENT CMNT P SLB pump 5 bbls of fresh H2O. Tested 9,260.0 9,260.0 20:30 00:00 lines to 3500 psi high, pump 60 bbls of 11.5 ppg Mud Push II @ 4.2 bbls/min, 672 psi, Dropped bottom plug. (cement wet @ 22:16hrs) Pump 130 bbls of Class G 15.8 ppg cement @ bbls/min, ICP = 676 psi, FCP = 645 psi. Drop top plug & kick out with 20 bbls of fresh H2O. Swap to rig & displace w/ 10.8 ppg LSND mud @ 6 bbls/min,138 psi. @ 3214 strokes 380bbls displaced. 10/24/2021 10/24/2021 1.00 INTRM1, CEMENT CIRC P Cont. Displacing well @ 6BPM with 9,260.0 9,260.0 00:00 01:00 10.8ppg LSND @ 4455 strokes 529 bbls displaced land bottom plug, pressure increased to 450 psi,Lift pressure increased to 650psi ICP Slow pump rate to 2 BPM 20 barrel before bumping plug. Bump Plug with 1187 psi 500psi over ICP. Held pressure for 5 min Bled pressure 1.5 bbls back. Floats held. 10/24/2021 10/24/2021 5.00 INTRM1, CEMENT WOC P Waiting on cement to set up to 9,260.0 9,260.0 01:00 06:00 Compression Strength of 100 psi Monitoring well at rig floor 10/24/2021 10/24/2021 6.00 INTRM1, DRILLOUT WOC P WOC L/D un-needed casing equipment 9,260.0 9,260.0 06:00 12:00 prepare to remove mud from bop stack and casing joint to rig floor, Remove TDS 11 Guard, inspect and install TDS 11 Guard. Cont. Cleaning pits Load 7" casing on racks, P/U BHI BHA and equipment and tools for next run Load in pipe shed. Pump out 9.625" casing t/ ground levels 10/24/2021 10/24/2021 1.00 INTRM1, DRILLOUT NUND P Nipple Down between casing spool and 9,260.0 9,260.0 12:00 13:00 tubing spool and p/u risers and BOP stack. Found tubing spool had heavy wear marks and scaring from centralizers and lock rings. Made call to CPAI for instruction. Decition was made to change out tubing spool. 10/24/2021 10/24/2021 4.50 INTRM1, DRILLOUT WAIT P Waiting on orders as per CPAI - Clean 9,260.0 9,260.0 13:00 17:30 casing spool as per FMC rep SIMOPS change out upper rams to 4 1/2" x 7" VBRS 10/24/2021 10/24/2021 1.00 INTRM1, DRILLOUT WWSP P Install Emergency slips over pull 160k, 9,260.0 9,260.0 17:30 18:30 land out cut 5/8" casing. 10/24/2021 10/24/2021 1.50 INTRM1, DRILLOUT NUND P Remove Cut Joint 24.70' Nipple down 9,260.0 9,260.0 18:30 20:00 tubing spool. 10/24/2021 10/24/2021 0.50 INTRM1, DRILLOUT RURD P Rig down VOLANT tools and casing 9,260.0 9,260.0 20:00 20:30 equipment 10/24/2021 10/24/2021 2.75 INTRM1, DRILLOUT WWSP P Remove Tubing spool, inspect well head 9,260.0 9,260.0 20:30 23:15 and pack off sealing area, Sealing area checked out okau as per FMC, install and test packoff install tubing spool. Test packoff to 3040 psi for 15 min. Good test. 10/24/2021 10/25/2021 0.75 INTRM1, DRILLOUT NUND P Tighten breaks on BOP,Nipple up riser 9,260.0 9,260.0 23:15 00:00 and MPD equipment 10/25/2021 10/25/2021 1.50 INTRM1, DRILLOUT NUND P Tighten breaks on BOP,Nipple up riser 9,260.0 9,260.0 00:00 01:30 and MPD equipment R/U joes box, Air up flowline boots, P/U MPD cap, Hook up H2O to mud pump, Rig up Test Pump, fill stack with H2O work air out of MPD skid. Page 20/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/25/2021 10/25/2021 2.25 INTRM1, DRILLOUT PRTS P R/U PressureTest MPD equipment 250 9,260.0 9,260.0 01:30 03:45 low 5min 1250 high 5 min Good test on chart R/U test joint and Pressure test top ram 4 1/2" x 7" VBR's 250 psi low f/5 min 3500 psi high for 10 min. Chart is on file R/D test joint and equipment 10/25/2021 10/25/2021 0.75 INTRM1, DRILLOUT OTHR P Install 8.75" wearbushing and install 9,260.0 9,260.0 03:45 04:30 lockdown pins as per FMC Rep. L/D landing jt.Seal pollution pan 10/25/2021 10/25/2021 0.50 INTRM1, DRILLOUT OTHR P Install PS21 slips, Load pipe on pipe 9,260.0 9,260.0 04:30 05:00 rack. 10/25/2021 10/25/2021 3.25 INTRM1, DRILLOUT BHAH P P/U 8.5" Bit and Directional bha to 557' 0.0 557.0 05:00 08:15 MD pick up SLB expandable Reamers, cont. p/u hwdp and drilling jars. 10/25/2021 10/25/2021 3.75 INTRM1, DRILLOUT TRIP P TIH f/ 557' MD to 7807' with 5" drill pipe 557.0 7,807.0 08:15 12:00 P/U 170k S/O 142k Perform Shallowq test at 2430' Good test 10/25/2021 10/25/2021 1.00 INTRM1, DRILLOUT TRIP P Cont. TIH from 7807' MD to 9030' 7,807.0 9,030.0 12:00 13:00 Circulate and Condition Mud while slipping and cutting drill line 10 wraps 79' GPM 650 PSI 2851 FLOW 37 % P/U 224 S/O 160K Total Strokes 8391 10/25/2021 10/25/2021 0.50 INTRM1, DRILLOUT SLPC P B/D top drive and Calibrate and 9,030.0 9,030.0 13:00 13:30 Hookload test Crown o Matic. 10/25/2021 10/25/2021 0.50 INTRM1, DRILLOUT SVRG P Service top drive, Blocks and Crown 9,030.0 9,030.0 13:30 14:00 10/25/2021 10/25/2021 1.00 INTRM1, DRILLOUT PRTS P Casing test Test 9 5/8" casing to 3500 si 9,030.0 9,030.0 14:00 15:00 for 30 min on chart CPAI witness 10/25/2021 10/25/2021 6.00 INTRM1, DRILLOUT DRLG P Wash to and tag FC @ 9169' Drill F/ 9,030.0 9,169.0 15:00 21:00 9169' to 9292' MD 7442' TVD WOB 25k GPM 630 FLOW 35 PSI 2749 P/U 227 TQ 17-20 S/O 162 RT W 181 RPM 80 ECD 11.58 ppg ADT6 Total Bit Hrs 6 Total Jar Hrs 6 10/25/2021 10/25/2021 2.00 INTRM1, DRILLOUT CIRC P Circulate and condition mud at 9292' 9,292.0 9,292.0 21:00 23:00 MD 10.8 ppg in 10.8 ppg out GPM 630 FLOW 35 PSI 2749 P/U 227 S/O 162 RT W181 RPM 80 ECD 11.58 ppg Page 21/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/25/2021 10/25/2021 0.50 INTRM1, DRILLOUT FIT P Pull back up into casing 9,258.0 9,258.0 23:00 23:30 Rig up and Perform FIT equal to 14.ppg Psi 1238. Good Fit Test 1184 PSI equal 13.8PPG 10/25/2021 10/26/2021 0.50 INTRM2, DRILL OTHR P Blow down Top drive and test equip 9,258.0 9,258.0 23:30 00:00 10/26/2021 10/26/2021 1.00 INTRM2, DRILL CIRC P Circulate and condition mud bottoms up 9,258.0 9,258.0 00:00 01:00 to ensure well bore was clear of cement plug rubber to prevent plugging MPD chokes. 10/26/2021 10/26/2021 1.50 INTRM2, DRILL CIRC P Pump 40 bbls hi vis spacer, displace 9,258.0 9,297.0 01:00 02:30 well with 10.8 ppg KSI. @ 9297' 10/26/2021 10/26/2021 2.00 INTRM2, DRILL MPDA P Simulate connections with MPD 9,297.0 9,297.0 02:30 04:30 equipment before drilling to ensure proper ECD pressure and equip working properly. Equip working properly. 10/26/2021 10/26/2021 1.50 INTRM2, DRILL DDRL P Drill 8.5" x 9 5/8" Intermediate section f/ 9,297.0 9,316.0 04:30 06:00 9297' to 9316' MD GPM 640 PSI 2826 FLOW 28 WOB 30 TQ 10-12 ECD 12.33 P/U 235 S/O 159 RT WT 186 RPM 81 10/26/2021 10/26/2021 1.00 INTRM2, DRILL DDRL P Drill 8.5" x 9 5/8" Intermediate section f/ 9,316.0 9,390.0 06:00 07:00 9315' MD to 9390' MD 7524' TVD GPM 640 PSI 2826 FLOW 28 WOB 30 TQ 10-12 ECD 12.33 P/U 235 S/O 159 RT WT 186 RPM 81 10/26/2021 10/26/2021 1.00 INTRM2, DRILL DDRL P Open SLB reamer @ 9390' MD 9,390.0 9,390.0 07:00 08:00 Establish parameters and confirm reamer postion . GPM 640 TQ 8K PRE TRPM 5100 PRE SSP 2837 POST TQ 9K POST TRPM 4686 POST SSP 2638 Perform ledge test as per SLB Page 22/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/26/2021 10/26/2021 4.00 INTRM2, DRILL DDRL P Drill 8.5" x 9 7/8" Intermediate section f/ 9,390.0 9,557.0 08:00 12:00 9390' MD to 9557' MD 766 1'TVD GPM 740 PSI 3181 FLOW 35 WOB 30 TQ 10-12 ECD 12.33 P/U 232 S/O 161 RT WT 184 RPM 170 MPD PSI 120 Drilling MPD PSI 600 Connection 10/26/2021 10/26/2021 6.00 INTRM2, DRILL DDRL P Drill 8.5" x 9 7/8" Intermediate section f/ 9,557.0 9,818.0 12:00 18:00 9557' MD to 9818' MD 7836' TVD RPM 170 GPM 745 PSI 3167 FLOW 35 WOB 36 TQ 17 ECD 12.20 P/U 232 S/O 161 RT WT 184 MPD PSI 120 Drilling MPD PSI 600 Connection 10/26/2021 10/26/2021 4.50 INTRM2, DRILL DDRL P Drill 8.5" x 9 7/8" Intermediate section f/ 9,818.0 10,020.0 18:00 22:30 9818' MD to 10020' MD 7956' TVD Total Bit hrs 14.5 Total Jar Hrs 14.5 ADT 3.4 RPM 170 GPM 745 PSI 3167 FLOW 35 WOB 36 TQ 17 ECD 12.4 P/U 232 S/O 161 RT WT 184 MPD PSI 120 Drilling MPD PSI 600 Connection 10/26/2021 10/26/2021 0.50 INTRM2, DRILL SVRG P Rig Service Gease top drive, blocks 10,020.0 10,020.0 22:30 23:00 10/26/2021 10/27/2021 1.00 INTRM2, DRILL RGRP T Trouble shoot #1 Mud Pump /Charge 10,020.0 10,020.0 23:00 00:00 Pump, Charge pump not pump proper psi, swap to injector pump and back to drilling. Page 23/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConoAftllips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/27/2021 10/27/2021 6.00 INTRM2, DRILL DDRL P Drill 8.5" x 9 5/8" Intermediate section f/ 10,020.0 10,481.0 00:00 06:00 10020' MD to 10481' MD 7957' TVD Total Bit hrs 19.1 Total Jar Hrs 19.1 ADT 3.4 RPM 170 GPM 740 PSI 3190 FLOW 35 WOB 36 TO 17 ECD 12.42 P/U 242 S/O 156 RT WT 178 MPD PSI 120 Drilling MPD PSI 600 Connection 10/27/2021 10/27/2021 6.00 INTRM2, DRILL DDRL P Drill 8.5" x 9 5/8" Intermediate section f/ 10,481.0 10,821.0 06:00 12:00 10481' MD to 10821' MD 8306 TVD Total Bit hrs 24.4 Total Jar Hrs 24.4 ADT 5.3 RPM 170 GPM 740 PSI 3520 FLOW 38 WOB 36 TO 17-19 ECD 12.42 P/U 272 S/O 148 RT WT 177 MPD PSI 90 Drilling MPD PSI 600 Connection 10/27/2021 10/27/2021 1.50 INTRM2, DRILL DDRL P Drill 8.5" x 9 5/8" Intermediate section f/ 10,821.0 10,845.0 12:00 13:30 10821' MD TD to 10845 MD 8306 TVD Total Bit hrs 25.1 Total Jar Hrs 25.1 ADT .7 RPM 170 GPM 740 PSI 3520 FLOW 38 WOB 36 TO 17-19 ECD 12.53. P/U 260 S/O 140 RT WT 187 MPD PSI 90 Drilling MPD PSI 600 Connection 10/27/2021 10/27/2021 0.50 INTRM2, CASING SRVY P Cycle Reamer closed, Obtain final 10,845.0 10,845.0 13:30 14:00 survey. @ 10845' MD Page 24/59 Report Printed: 12/16/2021 Opera con000Phiwps Rig: DOYON 25 Time Log Start Time End Time Dur (hr) Phase 10/27/2021 10/27/2021 1 2.00 1 INTRM2, CASING 14:00 16:00 tions Summary (with Timelog Depths) MT7-01 10/27/2021 10/27/2021 0.50 INTRM2, CASING O 16:00 16:30 10/27/2021 10/27/2021 3.00 INTRM2, CASING S 16:30 19:30 10/27/2021 10/27/2021 2.25 INTRM2, CASING CI 19:30 21:45 Activity Code MPD Time P-T-X Operation RC P Circualte while Rot & Recip racking back 1 stnd every B/U F 10845' to 10632' MD GPM 640 TQ 17 RPM 125 FLOW OUT 37 ECD 12.2 P/U 262K S/O 140K RT WT 190K TOTAL STROKES PUMPED 18690 W FF P OW FF as per CPAI REP. P SOOH as per CPAI Stripping schedL 10632' to 9210' w/ 5" Drill pipe Monitoring well on pipe #2 ECD 12.3 P/U 290K S/O 140K RC P Circulate 2 B/U'S at 9210' MD GPM 660 PSI 3066 FLOW OUT 37 ECD 12.3 P/U 260 S/O 160 TOTAL STROKES PUMPED 11250 RIG RELEASE DATE 11/29/2021 Job: DRILLING ORIGINAL Start Depth (ftKB) End Depth (ftKB) 10,845.01 10,632.0 10,632.0 10,632.0 f/ 1 10,632.01 9,210.0 9,210.01 9,210.01 21:45 22:45 9459' and 9475' MD P/U 260 S/O 126 10/27/2021 10/28/2021 1.25 INTRM2, CASING REAM P Attempted to work thru tight Spots from 9,459.0 9,501.0 22:45 00:00 9459' to 9475' serval times not able to make it down. Talked to WSC decision was made to to wash down at 550 GPM's attempted serval times no go. GPM 660 PSI 3066 TQ 17 ECD 12.34 P/U 260 S/O 160 RTWT190 TSP 6605 strokes Page 25/59 Report Printed: 12/16/2021 1 Operations Summary (with Timelog Depths) f MT7-01 RIG RELEASE DATE 11/29/2021 ConoAftllips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time our (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/28/2021 10/28/2021 6.00 INTRM2, CASING REAM P Wash and Ream Through tight areas 9,501.0 9,819.0 00:00 06:00 from 9459'to 9819' MD GPM 660 PSI 3066 FLOW OUT 27% RPM 60-80 TO 10-17 ECD 12.34 P/U 255K S/O 152K RT WT 190K TIGHT SPOTS 9437' 9450' 9475' 9510, 9514,9640. 9790, 9819' 10/28/2021 10/28/2021 6.00 INTRM2, CASING REAM P Wash and Ream Through tight areas 9,819.0 9,995.0 06:00 12:00 from 9819' MD to 9995' MD GPM 200 / 660 PSI 1040-2455 3066psi FLOW OUT 27% RPM 60-80 TO 10-17 ECD 12.4 P/U 252K S/O 156K RT WT 190K TIGHT SPOTS 9872', 9910, 9940', 9985', M D Attempt to wash down with 200 GPM @ 9973' MD to 9985'MD with no good results. 10/28/2021 10/28/2021 6.00 INTRM2, CASING REAM P Wash and Ream Through tight areas 9,995.0 10,196.0 12:00 18:00 from 9995' MD to 10196' MD While waiting unp mud weight to 11.1 ppg GPM 565 PS 12455 FLOW OUT RPM 60 TO 10-17 ECD 12.8 P/U 252k S/O 156k RT WT 190k MPD maint. 12.8 ECD holding 750 psi on connections back side Page 26/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/28/2021 10/29/2021 6.00 INTRM2, CASING REAM P Wash and Ream Through tight areas 10,196.0 10,364.0 18:00 00:00 from 10196' MD to 10364' MD While waiting unp mud weight to 11.1 ppg phase 1 Weight to 11.3 ppg phase 2 GPM 565 PSI 2455 FLOW OUT RPM 60 TQ 10-17 ECD 12.8 P/U 252k S/O 156k RT WT 190k MPD maint. 12.8 ECD holding 750 psi on connections back side 10/29/2021 10/29/2021 6.00 INTRM2, CASING REAM P Wash and Ream Through tight areas 10,364.0 10,364.0 00:00 06:00 10364' MD to 10370' Hole packed off, reduce pump rate to from 562 GPM to 149 GPM Pipe torque up and stalled out, pipe free to rotating pipe , lost circulation 100% Lost 180BBLS total Slowly regain circulation @ 149 GPM 600 psi with minium loses Increase pump rate to 300 GPM @ 850 psi Weight to 11.3 ppg MPD 12.8 PPG phase 2 Note Mud Plant is building 550 bbls mud. 50BBI LCM sweep ready at Pits GPM 565 / 149 / 300 / 855 PSI 2455/600 FLOW OUT 27% /12% /15% RPM 60 TQ 10-17 ECD 12.8 / 12.3 P/U 252k S/O 156k RT WT 190k MPD maint. 12.3 ppg due to losses 10/29/2021 10/29/2021 1.25 INTRM2, CASING CIRC P Regan Circulation, Rot an RECIP f/ 10,337.0 10,364.0 06:00 07:15 10337' to 10364' MD GPM 300 PSI 850 F/O 13% TQ 12-17k RT/WT 197 10/29/2021 10/29/2021 4.75 INTRM2, CASING CIRC P Attempt t/ Rotate and Recip @ 565 10,364.0 10,364.0 07:15 12:00 GPM Encoutered packoff Immedially Establish Circualtion and slowly stage up mud pumps T 500 GPM w/ 1855 psi Verified reamer in open position closed reamer Page 27/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 10/29/2021 10/29/2021 2.00 INTRM2, CASING REAM P Index SLB under reamer and Verify in 10,364.0 10,327.0 12:00 14:00 closed position, Stage pumps up slowly T 500 GPM W/ 2038 Psi BROOH f/ 10364' to 10327' GPM 506 PSI 1996 TQ 13k Flow 15% 10/29/2021 10/29/2021 6.75 INTRM2, CASING REAM P Cont. BROOH from 10327' to 10248' 10,327.0 10,248.0 14:00 20:45 MD' 10/29/2021 10/29/2021 0.50 INTRM2, CASING SMPD P SOOH f/ 10248'MD to 10187'MD 10,248.0 10,187.0 20:45 21:15 Unsuccesful pulled inton tight spot @ 10187' MD observe overpull 35K MPD psi on slips 700psi Out of slips 580psi to maintain 12.8 PPG iNTIAL B/O 325 P/U 280K S/O 140 10/29/2021 10/30/2021 2.75 INTRM2, CASING CIRC P RIH F/ 10187' MD to 10202' MD and Re 10,187.0 10,202.0 21:15 00:00 -Establish Circulation. Cont. Work pipie as per CPAI plan. to ensure string is free P/U 280 S/O 140 GPM 104 PSI 808 Flow 5.6% b Hole packed off while move pipe in down position, Bled PSI start over with Stage up schedule. 10/30/2021 10/30/2021 6.00 INTRM2, CASING CIRC P Staging pumps up to Re -Establish 10,202.0 10,182.0 00:00 06:00 Circulation. Staging pump rate up to 200 GPM's Cont. Work pipe as per CPAI plan. to ensure string is free. Worked pipe only to over come packoff's and keep staging pumps up to GPM's Staged up to 225 GPM"s 965 PSi packed off bled PSI Started pump stage up. P/U 280 S/O 140 10/30/2021 10/30/2021 6.00 INTRM2, CASING CIRC P Re establish circulation @ 10182' MD 10,182.0 10,182.0 06:00 12:00 Bringing pump up in 10 stroke incriments slowly as per CPAI Rep Cont. work pipe to ensure string was free up t/ 10182 to 10183' GPM 265 PSI 830 RT wt182k 10/30/2021 10/30/2021 1.00 INTRM2, CASING CIRC P Re establish circulation @ 10182' MD 10,182.0 10,182.0 12:00 13:00 Bringing pump up in 10 stroke incriments slowly as per CPAI Rep Cont. work pipe to ensure string was free up t/ 10182 to 10183' GPM 333 PSI 1330 Hole packoff bled psi and start to re establish circulation BROOH WT 330 RT wt182k Page 28/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 con000Philfips Rig: DOYON 25 Time Log Start Time End Time Dur (hr) Phase 10/30/2021 10/30/2021 0.50 INTRM2, CASING 13:00 13:30 10/30/2021 10/30/2021 5.00 INTRM2, CASING 13:30 18:30 18:30 121:30 21:30 00:00 10/31/2021 10/31 00:00 06:00 06:00 111:00 RE R 10/31/2021 10/31/2021 1.00 INTRM2, CASING Cl 11:00 12:00 10/31/2021 10/31/2021 0.50 INTRM2, CASING Cl 12:00 12:30 10/31/2021 10/31/2021 1.00 INTRM2, CASING Cl 12:30 13:30 10/31/2021 10/31/2021 1.00 INTRM2, CASIN 13:30 14:30 10/31/2021 10/31/2021 3.50 INTRM2, CASIN 14:30 18:00 18:00 100:00 00:00 01:15 11/1/2021 11/1/2 01:15 01:45 11/1/2021 11/1/2 01:45 04:15 11/1/2021 11/1/2 04:15 05:15 O SM RIG RELEASE DATE 11/29/2021 Job: DRILLING ORIGINAL Activity Code Time P-T-X Operation RC P Staging up pumps to re-establish circulation T/ 200 gpm 700 psi, pressure increased to 1060 Start Depth (ftKB) End Depth (ftKB) 10,182.0 10,182.0 10,182.0 10,193.0 9,220.01 9,220.01 9,220.01 9,220.01 9,220.01 9,247.01 9,247.0 9,247.0 9,247.0 7,790.0 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/1/2021 11/1/2021 0.75 INTRM2, WHDBOP PULD P Pull wearbushing and Install Test plug to 0.0 0.0 05:15 06:00 Test BOPE 11/1/2021 11/1/2021 6.00 INTRM2, WHDBOP BOPE P BOPE Test 0.0 0.0 06:00 12:00 All tests to 250psi/5min 3500psi/10min w/ exception of manual and super choke t/ 2000 psi. 5" Test jt 1. Annular Preventer, Valves: 1, 13, 14, 15, 4" Kill Line (Rig Floor), Upper IBOP. 2. Upper Pipe Rams 2 7/8" x 5'/z' Valves: 2, 10, 12, HCR Kill, lower IBOP 3. Valves, 6, 9, 11, Manual Kill & 5% Dart Valve 4. Valves 5, 7, 8 & 5"- FOSV #1 5. Valve 3, 4" & 5"- FOSV #2 6. Lower Pipe Rams 7" Test Jt 7. Annular Preventer, HCR Choke 8. Upper 4" x 7" VBR'S, Manual Choke PErform Koomey drawndown test 6 bootles avg 1915 psi ACC 3000 psi MANIF. 1500 psi = 1450 psi after all functions on bottles were made 18 saec for 200 psi build with 2 Elec puimps 125 sec to buils full system psi w/2 Elec pumps 2 Air pumps. Closing times Annnular 23 sec Upr 18 sec Blind Shear 16 sec LPR 16 Sec Choke HCR 2 sec Test PVT GAin Loss Alarms And flow out alarms Test LEL and 1-12S alarms. AOGCC REP GUY COOK WAIVED WITNESS @ 11:08 on 10/31/21 11/1/2021 11/1/2021 1.50 INTRM2, WHDBOP BOPE P 9. Blind rams & CMV #4 0.0 0.0 12:00 13:30 10. Super and Manual choke test, 2000 psi. A & B 3.5" Test Jt 11. Annular Preventer 12. Lower 2 7/8" x 5'/2" VBR'S. 11/1/2021 11/1/2021 0.50 INTRM2, PLUG RURD P Pull Test Plug, Drain stack clear rig floor 0.0 0.0 13:30 14:00 of testing equip 11/1/2021 11/1/2021 0.50 INTRM2, PLUG WWSP P Install Wear ring asw per FMC Rep ID 0.0 0.0 14:00 14:30 8.5 OD 13.5 11/1/2021 11/1/2021 1.00 INTRM2, PLUG RURD P Rig up to Run 3.5" tubing 0.0 0.0 14:30 15:30 11/1/2021 11/1/2021 1.50 INTRM2, PLUG TRIP P P/U and 3.5" EUE L-80 tubing t/ 0.0 1,043.0 15:30 17:00 1043'MD 11/1/2021 11/1/2021 0.50 INTRM2, PLUG RURD P Rig UP DBL tong Change out PS 21 die 1,043.0 1,043.0 17:00 17:30 blocks to 5" install 5" elevators and X/O 11/1/2021 11/1/2021 4.50 INTRM2, PLUG TRIP P TIH f/ 1043'to x9260' MD w/ 5" drill 1,043.0 9,260.0 17:30 22:00 pipe, Monitoring Displacement@ trip Pit 11/1/2021 11/1/2021 0.50 INTRM2, PLUG OWFF P Record 9,260.0 9,260.0 22:00 22:30 P/U 176 S/O 165 TQ 5k At 20 6k @ 40 at 20 40 rpm's Page 30/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/1/2021 11/1/2021 0.50 INTRM2, PLUG TRIP P Cont. TIH f/ 9260' MD to 9460' MD 9,260.0 9,460.0 22:30 23:00 Took 10k wieight picked up work pipe. No able to work through P/U 188 S/O 153 11/1/2021 11/2/2021 1.00 INTRM2, PLUG CIRC T Stage up mud pumps while working pipe 9,460.0 9,460.0 23:00 00:00 to obstruction @ 9460' Max down weight 6 K P/U 189k S/O 153 11/2/2021 11/2/2021 6.00 INTRM2, PLUG CIRC T Attempt to work pipe through obstruction 9,460.0 9,460.0 00:00 06:00 @ 9460' MD Staged pumps up in 20 stroke incriments to 330 psi w/ 715 psi F/O 21 % Atempt to roate pipe to Obstruction RPM 20 with 7k TQ P/U 195K S/O 193K ROT 175K Continue washing to bottom @ 250 GPM w/ 560 PSI Observe 5k overpull each time we washed to 9460' MD Working pipe trying different GPM and PSI to help get through obstruction from 200 GPM to 330 GPM While waiting on Plan forward from CPAI 11/2/2021 11/2/2021 3.50 INTRM2, PLUG CIRC T Attempt to work pipe through obstruction 9,460.0 9,460.0 06:00 09:30 @ 9460' MD Staged pumps up in 20 stroke incriments to 330 psi w/ 715 psi F/O 21 % Atempt to roate pipe to Obstruction RPM 20 with 7k TQ P/U 195K S/O 193K ROT 175K Continue washing to bottom @ 250 GPM w/ 560 PSI Observe 5k overpull each time we washed to 9460' MD Working pipe trying different GPM and PSI to help get through obstruction from 200 GPM to 330 GPM While waiting on Plan forward from CPAI 11/2/2021 11/2/2021 2.50 INTRM2, PLUG CIRC T Shut down pumping Blow down Top- 9,460.0 9,433.0 09:30 12:00 drive, Hook up Cement hose and Manifold. Stage pump up slowly to 250 GPM w/ 522 PSI @ 9458' MD F/O 22% Pump 20 BBLS hi vis H2O Followed by 65 BBLS 13.5 VisPill Chased with 20 BBL Vis H2O P/U to 9433' MD circulate Bottoms up @ 300 GPM ICP 810 PSI w/ 21 % flow out 11/2/2021 11/2/2021 1.00 INTRM2, PLUG CIRC T Cont. t/ stage pumps up t/ 330 gpm @ 9,344.0 9,433.0 12:00 13:00 9433' MD f/o 22% TYotal strokes pumped 5667 11/2/2021 11/2/2021 1.50 INTRM2, PLUG CMNT T Pressure Test Cement Lines 3500 PSI 9,433.0 9,433.0 13:00 14:30 on chart, Llne up SLB pump 45.2 bbls Mud Push13.5 ppg, Mix and Pump 82.1 bbls 16.5 ppg cement, pump 14.9 bbls Mud Push II, and Displace A 294 GPM w/ 119 BBLS 11.3 PPG KSI mud as Per CPAI cement schedule Cement wet @ 13:26 Cement in Place 14.22 hrs 11/2/2021 11/2/2021 0.75 INTRM2, PLUG TRIP T POOH f/ 9433' to 8860' MD Montior 9,433.0 8,860.0 14:30 15:15 I displace at Trip pit. Page 31/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/2/2021 11/2/2021 1.75 INTRM2, PLUG CIRC T Circulate, Rotate and Recip. F/ 8860'to 8,860.0 8,776.0 15:15 17:00 8776' MD w/ 400 GPM ICP 1350 FCP 850 PSI 22 to 28 % flow out. P/U 174k S/O 145k Total SDtroke pumped 8297 11/2/2021 11/2/2021 0.25 INTRM2, PLUG OWFF T OWFF well Static 8,776.0 8,776.0 17:00 17:15 11/2/2021 11/2/2021 0.50 INTRM2, PLUG CIRC T Pump 25 BBL 13.5 ppg slug W/ 294 8,776.0 8,776.0 17:15 17:45 gpm 614 PSI Blow down top drive 11/2/2021 11/3/2021 6.25 INTRM2, PLUG TRIP T POOH f/ 8776' to 3500' MD w/ 5" drill 8,776.0 3,500.0 17:45 00:00 pipe to MD P/U 95 K Monitoring well on constant hole fill Checking Top tool joints for cement rings 11/3/2021 11/3/2021 2.25 INTRM2, PLUG TRIP T POOH f/ 3500' to 1047' MD w/ 5" drill 3,500.0 1,047.0 00:00 02:15 pipe to MD P/U 95 K Monitoring well on constant hole fill Checking Top tool joints for cement rings 11/3/2021 11/3/2021 0.50 INTRM2, PLUG RURD T PJSM R/U tubing handling equipment 1,047.0 1,047.0 02:15 02:45 and Tongs MAde up TIW to X/O back to 3.5" EUE 11/3/2021 11/3/2021 2.00 INTRM2, PLUG TRIP T TOOH L/D 3.5" EUE tubing to pipe shed 1,047.0 0.0 02:45 04:45 F/ 1047' to Surface All 3.5" Tubing and orange peel is accounted for. 11/3/2021 11/3/2021 0.50 INTRM2, PLUG RURD T Rig down tubing handling equipment 0.0 04:45 05:15 clear tools from rig floor P/U 5" pipe handling equipment. 11/3/2021 11/3/2021 0.75 INTRM2, PLUG CIRC T Make up BOP stack washer Wash @ 0.0 0.0 05:15 06:00 600 GPM w/ 600 PSI 130 RPM 36 STKS 2383 11/3/2021 11/3/2021 1.25 INTRM2, PLUG SLPC T Slip and cut 63' 8# wraps Drill 0.0 0.0 06:00 07:15 line Calibrate block height and crown o matic 11/3/2021 11/3/2021 3.75 INTRM2, PLUG BHAH T PJSM W/ BHI directional reps, Pickup 0.0 558.0 07:15 11:00 BHA#5 as per BHI Surface to 558' Maintaining constant hole fill and montioring displace and trip pit. P/U 103k S/O 104K 11/3/2021 11/3/2021 1.00 INTRM2, PLUG TRIP T TIH F/ 558' t/ 2440' MD W/ 5" drill pipe 558.0 2,440.0 11:00 12:00 P/U 104K S/O 104K @ 2400' MD Shallow Test @ 2400' MD 660 GPM 1990 PSI, Monitor Displacement on trip Tank 11/3/2021 11/3/2021 4.25 INTRM2, PLUG TRIP T TIH f/ 2440'to 8560' MD Filling pipe 2,440.0 8,560.0 12:00 16:15 every 20 stands. P/U 184k S/O 138k Monitor returns at trip pit. 11/3/2021 11/3/2021 2.00 INTRM2, PLUG WASH T Wash in Hole f/ 8560'to 8868' MD GPM 8,560.0 8,868.0 16:15 18:15 620 PSI 2750 F/O 32% P/U 2201k S/O 169k Tag hard cement w/ 11 k 11/3/2021 11/3/2021 1.50 INTRM2, PLUG DRLG T Drill 8 1/2" intermediate cement f/ 8868' 8,868.0 8,971.0 18:15 19:45 to 8971' MD w/ WOB 15k GPM 620 PSI 2700 RPM 80 TQ 11/12 F/O 32% ECD 12.3 P/U 220k S/O 169K RT 187k Observe 14K TQ while drilling cement indiacating ream was in open position. 11/3/2021 11/3/2021 0.75 INTRM2, PLUG CIRC T Circulate at 8940' MD w/ GPM 626 PSI 8,971.0 8,940.0 19:45 20:30 2540 F/O 32 Total strokes pumped 6200 Page 32/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/3/2021 11/4/2021 3.50 INTRM2, PLUG OTHR T Attempted to Cycle pumps indexing 8,940.0 8,940.0 20:30 00:00 underreamer to closed position ( after numerous attempts we were unsuccessful, we continuously pump to index reamer and standard pump to index reamer f/ 160-380 GPM Low to 620 -700 High GPM. While in teams meeting call, Reamer function to closed position after starting to rotate again reamer indexed to open position again. Call was made to TOOH 11/4/2021 11/4/2021 0.75 INTRM2, PLUG TRIP T OWFF F/ 10 min TOOH f/ 8971'to 8,940.0 8,472.0 00:00 00:45 8472' w/ 5" drill pipe P/U 218 S/O 173 Monitoring Displacement on trip pit 11/4/2021 11/4/2021 0.25 INTRM2, PLUG CIRC T Pump 30bbl slug @ 150 GPM PSi 390 8,472.0 8,472.0 00:45 01:00 Blow Down top drive Line up on trip Pit 11/4/2021 11/4/2021 4.00 INTRM2, PLUG TRIP T TOOH f/ 8472' MD to 109' MD w/ 5" drill 8,472.0 109.0 01:00 05:00 pipe racking in derrick P/U 70 S/O 70 Montioring dispalcement on trip pit 11/4/2021 11/4/2021 3.00 INTRM2, PLUG BHAH T L/D Schlumberger underreamer, P/U to 109.0 558.0 05:00 08:00 Bit and inspect Bit. S/O pickup RR reamer as per SLB rep. Shallow test Reamer open and closed all working properly TIH w/ remain bha to 558' 11/4/2021 11/4/2021 4.00 INTRM2, PLUG TRIP T TIH f/ 558' MD ro 8848' MD w/ 5" drill 558.0 8,848.0 08:00 12:00 pipe P/U 205 S/O 157 @ 8800' MD Monitoring displacement at trip pit 11/4/2021 11/4/2021 0.50 INTRM2, PLUG WASH T Wash and ream f/ 8848' to 8971' MD 8,848.0 8,971.0 12:00 12:30 GPM 640 PSI 2950 RPM 80 TQ 11-13 F/O 33% ECD 12.3 P/U 202 S/O 166K RT 173 Total strokes pumped 2580 11/4/2021 11/4/2021 3.00 INTRM2, PLUG REAM T Drill 8 1/2" x 9 7/8" Interm 2 hole cement 8,971.0 9,240.0 12:30 15:30 8971' to 9240' MD GPM 640 PSI 2950 RPM 80 TQ 11-13 F/O 34% ECD 12.3 P/U 202 S/O 166K RT 173 11/4/2021 11/4/2021 2.00 INTRM2, PLUG CIRC T Displace well with 10.5 ppg LSND 9,240.0 9,166.0 15:30 17:30 circulate rotate and recip. f/ 9240' to 9166' MD GPM 645 PSI 2400 ECD 11.3 F/O 34% RPM 80 11/4/2021 11/4/2021 0.25 INTRM2, PLUG OWFF T OWFF welll static 9,240.0 9,240.0 17:30 17:45 11/4/2021 11/4/2021 1.00 INTRM2, PLUG MPDA T Pull Trip nipple and install MPD bearing 9,240.0 9,240.0 17:45 18:45 11/4/2021 11/4/2021 1.25 INTRM2, PLUG MPDA T Obtain MPD parameters and cycle to 9,240.0 9,240.0 18:45 20:00 simulate connections with MPD 11/4/2021 11/4/2021 1.50 INTRM2, PLUG KOST T Drill 8 1/2" intermiate cement f/ 9240 to 9,240.0 9,270.0 20:00 21:30 9270' MD WOB 15k GPM 640 PSI 2400 RPM 80 TQ 11/13 F/O 33% ECD 11.3 P/U 224k S/O 163 11/4/2021 11/4/2021 1.00 INTRM2, PLUG KOST T Observe Excess increase in pressure 9,270.0 9,240.0 21:30 22:30 while working through shoe, CBU X@ ROT asnd RECIP f/ 9270' to 9240' W/ GPM 640 PSI 2400 F/O 20% RPM 80 TQ 9k ECD 11.35 stroke total 8829 Max Pressure @ packoff 3500psi 11/4/2021 11/5/2021 1.50 INTRM2, PLUG OTHR T Baker MWD tool sending down link 9,270.0 9,270.0 22:30 00:00 down hole to MWD tool wil not recieve command Attempting to work pipe to establish MWD signal. Done hard shut down and reboot system to estalish communication non successful. Page 33/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhimps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/5/2021 11/5/2021 0.75 INTRM2, PLUG SRVY T Cont. Trouble shoot MWD tools, Line up 9,270.0 9,270.0 00:00 00:45 to SOOH Establish circulation through injection line W/ mud pump 11/5/2021 11/5/2021 5.25 INTRM2, PLUG STRP T SOOH f/ 9270' to 1876' MD As per 9,270.0 1,876.0 00:45 06:00 MPD and CPAI Schedule. Holding 520 PSI Holding 440 PSI In slips 11/5/2021 11/5/2021 1.25 INTRM2, PLUG STRP T SOOH f/ 1876' to 652' MD As per MPD 1,876.0 652.0 06:00 07:15 and CPAI Schedule. Holding 520 PSI Holding 440 PSI In slips 11/5/2021 11/5/2021 1.25 INTRM2, PLUG OWFF T OWFF, PJSM w/ Beyond REP. Remove 652.0 652.0 07:15 08:30 RCD Bearing Install trip nipple as per Beyond Rep. Hook up hole fill lines and establish circulation flow through trip tanks 11/5/2021 11/5/2021 1.75 INTRM2, PLUG BHAH T TOOH racking back HWDP and Jars in 652.0 0.0 08:30 10:15 derrick F/652' to surface Manitaining constant hole fill over the top of hole and monitoring returns on trip pit 11/5/2021 11/5/2021 2.50 INTRM2, PLUG BHAH T Change out MWD and Steering head, 0.0 652.0 10:15 12:45 Inspect 8 1/2" bit, 8 1/2" x 9 7/8" reamer. TIH F/ BHA to 652' Shallow test MWD, Good test 11/5/2021 11/5/2021 0.50 INTRM2, PLUG T Shallow Test MWD W/ GPM 655 PSI 652.0 652.0 12:45 13:15 1540 FLow 33% P/U 61 k S/O 61 K Stks Pumped 1853 11/5/2021 11/5/2021 0.75 INTRM2, PLUG OWFF T OWFF Remove trip nipple, and install 652.0 652.0 13:15 14:00 MPD bearing. @ 652' 11/5/2021 11/5/2021 4.25 INTRM2, PLUG STRP T SIH F/ 652' to 5224' w/ 5" drill pipe 652.0 5,524.0 14:00 18:15 Filling pipe every 20 stands P/U 150 S/O 120K MPD 410 psi in slips MPD 370 psi out slips Monitoring Displacement @ trip pit 11/5/2021 11/5/2021 3.75 INTRM2, PLUG STRP T SIH F/ 5224' to 9216' w/ 5" drill pipe 5,524.0 9,216.0 18:15 22:00 Filling pipe every 20 stands P/U 150 S/O 120K MPD 400 psi in slips MPD 290 psi out slips Monitoring Displacement @ trip Pit 11/5/2021 11/6/2021 2.00 INTRM2, PLUG SLPC T PJSM, Blow Down top Drive Slip and 9,216.0 9,216.0 22:00 00:00 cut 9 wraps 73' drill line. Calibrate blocks Set COM 11/6/2021 11/6/2021 0.75 INTRM2, PLUG SLPC T PJSM, Blow Down top Drive Slip and 9,216.0 9,216.0 00:00 00:45 cut 9 wraps 73' drill line. Calibrate blocks Set COM 11/6/2021 11/6/2021 1.25 INTRM2, PLUG MPDA T Kelly up T/ STD #93 Set Depth, Obtain 9,220.0 9,220.0 00:45 02:00 Parameters @ 9220' MD With MPD and SLB reamr REP. Confirm reamer is closed. GPM 640 PSI 2625 F/O 24% ECD 11.54 ROT 80 TQ 9-11 P/U 220 S/O 169 RT WT 186 Turbine RPM 5200 Page 34/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/6/2021 11/6/2021 5.50 INTRM2, PLUG KOST T Sidetrack 8 1/2" interm2 f/ 9270' MD to 9,270.0 9,311.0 02:00 07:30 9311' MD Sample show 5% cement and 95% shale Had Packoff's at 9270' 9272' 9282' 9287' WOB 15 GPM 640 PSI 2567 TQ 11-14 P/U 220 S/O 169 RT/WT 189 RPM 80 MPD in Slips 400 MPD out Slips 80 11/6/2021 11/6/2021 2.50 INTRM2, PLUG KOST T Trough 8 1/2" interm 2 F/ 9311' to 9296' 9,314.0 9,296.0 07:30 10:00 MD GPM 640 PSI 2550 F/O 24 RPM 160 TQ 11.59 P/U 220 RT WT 186k 11/6/2021 11/6/2021 2.00 INTRM2, PLUG KOST T Sidetrack 8 1/2" interm 2 f/ 9311' MD to 9,311.0 9,314.0 10:00 12:00 9314 WOB 15 GPM 640 PSI 2567 TQ 11-14 P/U 220 S/O 169 RT/WT 189 RPM 80 MPD in Slips 400 MPD out Slips 80 11/6/2021 11/6/2021 6.00 INTRM2, PLUG KOST T Sidetrack 8 1/2" interm 2 f/' 9314'to 9,314.0 9,326.0 12:00 18:00 9326' MD WOB 15 GPM 640 PSI 2567 TQ 11-14 P/U 220 S/O 169 RT/WT 189 RPM 80 MPD in Slips 440 MPD out Slips 0 11/6/2021 11/6/2021 3.50 INTRM2, PLUG KOST T Sidetrack 8 1/2" interm 2 f/' 9326'to 9,326.0 9,336.0 18:00 21:30 9336'MD Not able to achieve side track. WOB 15 GPM 640 PSI 2567 TQ 11-14 P/U 220 S/O 169 RT/WT 189 RPM 80 MPD in Slips 440 MPD out Slips 0 Page 35/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/6/2021 11/6/2021 0.75 INTRM2, PLUG CIRC T Cycle pumps for survey, Circulate, Rot. 9,336.0 9,336.0 21:30 22:15 nad Recip f/ 9336' to 9290' MD Bottoms up, GPM 640 PSI 2567 TQ 9-15 ECD 11.6 P/U 220 S/O 169 RT/WT 189 RPM 80 MPD in Slips 440 MPD out Slips 0 11/6/2021 11/6/2021 0.75 INTRM2, PLUG STRP T SOOH F/ 9336'to 9275MD Racking 9,336.0 9,275.0 22:15 23:00 5" pipe in derrick, 30K overpull MPD in slips 400 MPD out slips 400 P/U 220 S/O 169 11/6/2021 11/7/2021 1.00 INTRM2, PLUG CIRC T Wash and Ream f/ 9275 to 9258' MD, 9,275.0 9,258.0 23:00 00:00 GPM 640 PSI 2681 F/O 25% RPM 80 ECD 11.7 RT WT 178 Clrculate Bottoms up to clear casing. Total strokes pumped 5220 Blow down top[ drive. 11/7/2021 11/7/2021 6.00 INTRM2, PLUG CIRC T SOOH F/ 9258' To 580' MD, w/ 5" Drill 9,258.0 580.0 00:00 06:00 pipe racking in derrick P/U 63 S/O 63 MPD In slips 400 MPD out slips 490 Monitoring well at trip pit 11/7/2021 11/7/2021 0.50 INTRM2, PLUG CIRC T OWFF well static 580.0 580.0 06:00 06:30 11/7/2021 11/7/2021 1.00 INTRM2, PLUG MPDA T Pull MPD bearing and install Trip nipple 580.0 580.0 06:30 07:30 P/U 66k S/O 66 11/7/2021 11/7/2021 2.50 INTRM2, PLUG BHAH T L/D BHA as per BAker DD/MWD 580.0 0.0 07:30 10:00 11/7/2021 11/7/2021 2.00 INTRM2, PLUG BHAH T P/U BHA# as per Baker DID and MWD 0.0 151.0 10:00 12:00 to 151' P/U 66 S/O 66 11/7/2021 11/7/2021 0.75 INTRM2, PLUG TRIP T TIH f/ 151'to 520' W/ HWDP 151.0 520.0 12:00 12:45 S/O 70k 11/7/2021 11/7/2021 0.50 INTRM2, PLUG MPDA T OWFF well static, PJSM remove trip 520.0 520.0 12:45 13:15 nipple, Install MPD bearing as Per MPD rep. 11/7/2021 11/7/2021 4.75 INTRM2, PLUG STRP T SIH F/ 520' to 5950' MD w/ 5" drill pipe 520.0 5,950.0 13:15 18:00 S/O 160K , MPD holding 400 psi in slips 320 psi out slips/ Monitoring displacement at pits 2,3,4 11/7/2021 11/7/2021 2.75 INTRM2, PLUG STRP T SIH F/ 5950' to 9215' MD w/ 5" drill pipe 520.0 5,950.0 18:00 20:45 S/O 160K , MPD holding 400 psi in slips 320 psi out slips/ Monitoring displacement at pits 2,3,4 11/7/2021 11/7/2021 0.50 INTRM2, PLUG SVRG T Servic e Top -drive and blocks, Grease 9,215.0 9,215.0 20:45 21:15 swivel packing 11/7/2021 11/7/2021 0.50 INTRM2, PLUG KOST T Wash in hole f/ 9215' to 9336' GPM 475 9,215.0 9,336.0 21:15 21:45 PSI 2110 F/O 19% RPM 20 TQ 9 ECG 11.75 P/U 217 S/O 164 RT 187 Total strokes pumps 1900 11/7/2021 11/7/2021 0.50 INTRM2, PLUG KOST T Work pipe orient mud motor as per 9,306.0 9,336.0 21:45 22:15 Baker DD f/ 9306' to 9336' GPM 475 PSI 2110 F/O 19% TQ 9 ECG 11.75 Page 36/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/7/2021 11/8/2021 1.75 INTRM2, PLUG KOST T Through with 8 1/2" bit and mud motor 9,306.0 9,336.0 22:15 00:00 as per Baker DD and program f/ 9306; to 9336' W/ GPM 475 PSI 2110 F/O 17% ECD 11.75 11/8/2021 11/8/2021 1.25 INTRM2, PLUG KOST T Through with 8 1/2" bit and mud motor 9,306.0 9,336.0 00:00 01:15 as per Baker DD and program f/ 9306; to 9336' W/ GPM 475 PSI 2110 F/O 17% ECD 11.75 11/8/2021 11/8/2021 5.50 INTRM2, PLUG KOST T Drill Side Track Time Drill w/ 8 1/2" bit 9,336.0 9,341.0 01:15 06:45 and mud motor as per Baker DD and program f/ 9336' to 9341' 'MD W/ GPM 475 PSI 2110 F/O 17% ECD 11.75 11/8/2021 11/8/2021 5.00 INTRM2, PLUG KOST T Drill Side Track Time Drill w/ 8 1/2" bit 9,341.0 9,351.0 06:45 11:45 and mud motor as per Baker DD and program f/ 9341' to 9351' 'MD W/ GPM 475 PSI 2110 F/O 17% ECD 11.75 11/8/2021 11/8/2021 0.25 INTRM2, PLUG KOST T Drill Side Track Time Drill w/ 8 1/2" bit 9,351.0 9,353.0 11:45 12:00 and mud motor as per Baker DD and program 5' ft/hr f/ 9351' to 9353' MD W/ GPM 475 PSI 2110 F/O 17% ECD 11.75 11/8/2021 11/8/2021 3.00 INTRM2, PLUG KOST T Drill Side Track Time Drill w/ 8 1/2" bit 9,353.0 9,366.0 12:00 15:00 and mud motor as per Baker DD and program 10' Ft/hr f/ 9353' to 9366' MD W/ GPM 475 PSI 2110 F/O 17% ECD 11.75 11/8/2021 11/8/2021 0.75 INTRM2, PLUG KOST T Drill Side Track Time Drill w/ 8 1/2" bit 9,366.0 9,386.0 15:00 15:45 and mud motor as per Baker DD and program 15 ft/hr f/ 9366' to 9386' MD MD W/ GPM 475 PSI 2110 F/O 17% ECD 11.75 With survey, Confirm we had Side tracked at 9386' MD Survey Depth @ 9338' inc 38.43 11/8/2021 11/8/2021 0.75 INTRM2, PLUG CIRC T Orient Motor as per Baker Rep. 9,386.0 9,205.0 15:45 16:30 Circulate f/ 9386' to 9205' MD GPM 475 PSI 1900 F/O 17% ECD 11.74 P/U 174k total strokes pumped 5300 11/8/2021 11/9/2021 7.50 INTRM2, PLUG CIRC T SOOH f/ 9205' to 3755' MD GPM on 9,205.0 3,755.0 16:30 00:00 backside 250, P/U 115 S/O 115K MPD 400 PSI in slips 510 Out slips Monitoring displacement o pits 2-5 11/9/2021 11/9/2021 4.00 INTRM2, PLUG CIRC T SOOH f/ 3755' to 520' MD MD GPM on 3,775.0 520.0 00:00 04:00 backside 250, P/U 115 S/O 115K MPD 400 PSI in slips 510 Out slips Monitoring displacement @ pits 2-5 11/9/2021 11/9/2021 0.50 INTRM2, PLUG OWFF T OWFF well static 520.0 520.0 04:00 04:30 11/9/2021 11/9/2021 0.50 INTRM2, PLUG MPDA T Remove MPD Bearing and install trip 520.0 520.0 04:30 05:00 nipple 11/9/2021 11/9/2021 2.00 INTRM2, PLUG TRIP T TOOH from 520' to 151' MD Racking 520.0 151.0 05:00 07:00 Hwdp and Jars in derrick Montor Via trip pit 11/9/2021 11/9/2021 0.50 INTRM2, PLUG OTHR T Clean and clear rig floor 151.0 151.0 07:00 07:30 11/9/2021 11/9/2021 2.25 INTRM2, PLUG BHAH T P/U BHA# 10 as per Baker DD to 181', 0.0 181.0 07:30 09:45 Montioring well on Trip pit. Note Complete Dertrick inspection while MWD was plugged into on rig floor 11/9/2021 11/9/2021 0.75 INTRM2, PLUG TRIP T RIH w/ BHA#10 Hwdp and Jars f/ 181' 181.0 558.0 09:45 10:30 to 558' MD MOntior displace at Trp pit. P/U 70 S/O 70 Shallow Hole test MWD w/ 600 GPM 1550 psi flow 33% Good Test Page 37/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/9/2021 11/9/2021 0.50 INTRM2, PLUG MPDA T Pull trip nipple and install MPD bearing 558.0 558.0 10:30 11:00 11/9/2021 11/9/2021 8.00 INTRM2, DRILL STRP T SIH f/ 558' to 9200' Hold 290 psi on 558.0 9,200.0 11:00 19:00 MPD in slips and 400 out slips. P/U 221 S/O 162 Montioring Displacement @ pit 2-5# 11/9/2021 11/9/2021 1.50 INTRM2, DRILL WASH T Wash in hole from 9200' to 9385' 9,200.0 9,385.0 19:00 20:30 11/9/2021 11/9/2021 1.50 INTRM2, DRILL CIRC T Circulate through tight areas from 9355' 9,355.0 9,385.0 20:30 22:00 to 9385' GPM 650 PSI 2900 F/O 23 RPM 60 TQ 10-19 ECD 11.72 P/U 220 S/O 160 RT 185 11/9/2021 11/9/2021 1.00 INTRM2, DRILL UREM T Drop 1 1/4" activation ball as per SLB 9,385.0 9,385.0 22:00 23:00 rep. Pump 100 GPM PSI 530 Int Turbine Rpm 5200, Ball on set 580 strokes at 1264 stroke observe increase PSi 1264' Turbine RPM 4600, Increased pump rate to 680 psi, observe 10k overpull @ 9355" MD Confirm reamer is open position. 11/9/2021 11/10/2021 1.00 INTRM2, DRILL DDRL T Drill 8 1/2" x 9 7/8" Interm2 hole section 9,385.0 9,428.0 23:00 00:00 from 9385' to 9428' GPM 680 PSI 2735 TQ 9-12 WOB 11-17 RPM 20 F/O 26.4 P/U 214 S/O 166 RT/W 200 MPD 400 11/10/2021 11/10/2021 6.00 INTRM2, DRILL DDRL T Drill 8 1/2" x 9 7/8" Interm2 hole 9,428.0 9,672.0 00:00 06:00 section from 9428' to 9672' MD GPM 680 PSI 2735 TQ 9-12 WOB 25-27 RPM 151 F/O 26.4 P/U 220 S/O 176 RT/W 200 MPD 400 11/10/2021 11/10/2021 6.00 INTRM2, DRILL DDRL T Drill 8 1/2" x 9 7/8" Interm2 hole 9,672.0 9,980.0 06:00 12:00 section from 9672' to 9980' MD GPM 680 PSI 2735 TQ 9-12 WOB 25-27 RPM 151 F/O 26.4 P/U 220 S/O 176 RT/W 200 MPD 500 11/10/2021 11/10/2021 1.50 INTRM2, DRILL DDRL T Drill 8 1/2" x 9 7/8" Interm2 hole 9,980.0 10,057.0 12:00 13:30 section from 9980'to 10057" MD GPM 680 PSI 2735 TQ 9-12 WOB 25-27 RPM 151 F/O 26.4 P/U 220 S/O 176 RT/W 200 MPD 500 11/10/2021 11/10/2021 1.00 INTRM2, DRILL SVRG T Rig Service ECD with injection pump on 10,057.0 10,057.0 13:30 14:30 backside, 630 PSI while changing out wash pipOe on top drive 11/10/2021 11/10/2021 3.50 INTRM2, DRILL DDRL T Drill 8 1/2" x 9 7/8" Interm2 hole 10,057.0 10,300.0 14:30 18:00 section from 10057' to 10300' MD GPM 680 PSI 2735 TQ 9-12 WOB 25- 27 RPM 151 F/O 26.4 P/U 220 S/O 176 RT/W 200 MPD 500 11/10/2021 11/11/2021 6.00 INTRM2, DRILL DDRL T Drill 8 1/2" x 9 7/8" Interm2 hole 10,057.0 10,657.0 18:00 00:00 section from 10300' to 10657 'MD GPM 680 PSI 2848 TQ 9-12 WOB 25- 27 RPM 130 F/O 26.4 P/U 220 S/O 176 RT/W 200 MPD 500 Page 38/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/11/2021 11/11/2021 2.00 INTRM2, DRILL DDRL T Drill 8 1/2" x 9 7/8" Interm2 hole 10,657.0 10,737.0 00:00 02:00 section from 1 0657'to 10737' MD GPM 680 PSI 2848 TQ 9-12 WOB 25-27 RPM 130 F/O 26.4 P/U 220 S/O 176 RT/W 200 MPD holding 715 psi Total bit hrs 36. Total Jar hrs 51. 11/11/2021 11/11/2021 0.50 INTRM2, CASING CIRC P Obtain SPR's Down Link Auto Trak, Rot 10,737.0 10,715.0 02:00 02:30 and Recip, 10737' to 10715' MD GPM 680 PSI 2848 TQ 9-12 WOB 25-27 RPM 130 F/O 26.4 P/U 220 S/O 176 RT/W 200 MPD holding 715 psi 11/11/2021 11/11/2021 0.50 INTRM2, CASING UREM P Drop 1.625" reamer close ball, Pump 10,737.0 10,715.0 02:30 03:00 down at 250 GPM 1013 PSI, F/O 19% RPM 30 TQ 11 k slow RATE AT 500 STROKES TO 1000 gpm 760 psi 14% F/O Ball on seat a 650 strokes, pressure increase t/ 2048 psi and observe reamer closed. pressure dropped to 820 psi, increase rate to 680 GPM 2900 psi F/O 25% Turbine speed 5400 and TQ 11 k @ 30 RPM confirmed closed 11/11/2021 11/11/2021 1.50 INTRM2, CASING BKRM P BROOH and Circulate F/ 10715'to 10,715.0 10,250.0 03:00 04:30 10531' At 1 B/U and shakers were clean, racked stand back total of 2 stands racked back, circualted 2 B/U Circulated total of 4 B/U and verified shaker were clean prior to BROOH. GPM 650 PSI 2900-2430, RPM 125, TQ 11K F/O 26% MPD back side 140psi U maintain 11.8 ECD 11/11/2021 11/11/2021 7.50 INTRM2, CASING BKRM P BROOH f/ 10715'to 9210' MD GPM 10,531.0 9,210.0 04:30 12:00 650 PSI 2900-2430, RPM 125, TQ 11K F/O 26% MPD back side 140psi t/ maintain 11.8 ECD 11/11/2021 11/11/2021 4.00 INTRM2, CASING CIRC P Circulate while weighting up mud 9,210.0 9,136.0 12:00 16:00 system to 11.0 ppg Rot and Recip @ 9210' to 9136' MD GPM 650 ITCP 2670 Final 2780 PSI F/O 23-26% RPM 125 ECD 11.7 ppg final ECD 12.2 P/U 186 S/O 177m,Total strokes pumped 29100 11/11/2021 11/11/2021 7.25 INTRM2, CASING STRP P SOOH f/ 9136' to 3374' MD MPD 9,136.0 3,374.0 16:00 23:15 holding ECD @ 12.2 P/U 186 S/O 177 11/11/2021 11/12/2021 0.75 INTRM2, CASING T Wait on Pason to Reboot, Holding 3,374.0 3,374.0 23:15 00:00 pressure on backside with MPD 320 psi 11/12/2021 11/12/2021 0.50 INTRM2, CASING SMPD P SOOH f/ 3374' MD to 3300' MD MPD 3,374.0 3,300.0 00:00 00:30 350 PSI in slips 440 PSI P/U 186K 11/12/2021 11/12/2021 0.50 INTRM2, CASING CIRC P PJSM Spot 45 bbls (380 Stk)12.4 PPG 3,300.0 3,300.0 00:30 01:00 Gel pill @ 125-145 GPM @ 388 PSI, 15% F/O. Chase with 45 bbls(380) stks of 13.5 PPG LSND @ 200 GPM 410 PSI F/O 13% 11/12/2021 11/12/2021 0.75 INTRM2, CASING SMPD P SOOH F/ 3300' to 2800' MD @ 25 FPM 3,300.0 2,800.0 01:00 01:45 P/U 110 11/12/2021 11/12/2021 0.75 INTRM2, CASING CIRC P Displace 11.0 PPG LSND to 13.5 PPG 2,800.0 01:45 02:30 LSND mud cap per MPD displacement schedule. Highest weight observed after displacement 13.3 PPG at surface. 11/12/2021 11/12/2021 4.50 INTRM2, CASING CIRC T Shut down Weight up pit volume to 13.5 2,800.0 2,800.0 02:30 07:00 ppg @ pits Continue displace well t/ 13.5 ppg @ 175 GPM Highest weight observed at surface 13.4 PPG. Decision made to continue SOOH. Page 39/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhillips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/12/2021 11/12/2021 2.50 INTRM2, CASING SMPD P SOOH f/ 2800' MD to 581' MD P/U 105K 2,800.0 581.0 07:00 09:30 11/12/2021 11/12/2021 0.50 INTRM2, CASING OWFF P Flow check (static). 581.0 581.0 09:30 10:00 11/12/2021 11/12/2021 0.50 INTRM2, CASING MPDA P Pull MPD bearing and install trip nipple. 581.0 581.0 10:00 10:30 11/12/2021 11/12/2021 2.00 INTRM2, CASING BHAH P LD BHA #9. Monitor well on TT. 581.0 0.0 10:30 12:30 11/12/2021 11/12/2021 1.00 INTRM2, CASING CLEN P Clean and clear rig floor. PJSM for liner 0.0 0.0 12:30 13:30 run. 11/12/2021 11/12/2021 1.50 INTRM2, CASING RURD P MU Baker dart launcher to single and 0.0 0.0 13:30 15:00 LD. RU to run liner. 11/12/2021 11/12/2021 4.50 INTRM2, CASING PUTB P RIH w/ 7" 26# L-80 HYD563 liner as 0.0 1,986.0 15:00 19:30 per tally to 1986' MD. Filling pipe on the fly and topping off every 10 jts. 11/12/2021 11/12/2021 1.00 INTRM2, CASING PUTB P Change out elevators. PU and RIH w/ 7" 1,986.0 2,036.0 19:30 20:30 liner hanger per Baker. Fill hanger w/ Zanplex. Fill liner and break circulation. 11/12/2021 11/12/2021 1.00 INTRM2, CASING MPDA P Retrieve trip nipple and install RCD 2,036.0 2,036.0 20:30 21:30 bearing. 11/12/2021 11/12/2021 2.00 INTRM2, CASING SMPD P SIH w/ 7" liner on DP f/ 2036' to 4006'. 2,036.0 4,006.0 21:30 23:30 MPD holding 160psi in slips/20psi out. 11/12/2021 11/13/2021 0.50 INTRM2, CASING CIRC P Circulate and displace 13.5 ppg mud 4,006.0 4,006.0 23:30 00:00 cap w/ 11.0 ppg LSND mud per MPD schedule. Initial flow rate 250 gpm/final flow rate 420gpm. Heaviest weight observed while displacing was 12.6 ppg. Final mud weight out was 11.2 ppg. 11/13/2021 11/13/2021 1.25 INTRM2, CASING CIRC P Continue to displace 13.5 ppg mud cap 4,006.0 4,006.0 00:00 01:15 w/ 11.0 ppg LSND mud per MPD schedule. Initial flow rate 250gpm/final flow rate420gpm. Heaviest weight observed while circulating was 12.6 ppg. Final mud weight out was 11.2 ppg. 11/13/2021 11/13/2021 4.75 INTRM2, CASING SMPD P SIH w/ 7" liner on DP f/ 4006' to 7780'. 4,006.0 7,950.0 01:15 06:00 11/13/2021 11/13/2021 1.25 INTRM2, CASING CIRC P Continue to displace 13.5 ppg mud cap 4,006.0 4,006.0 00:00 01:15 w/ 11.0 ppg LSND mud per MPD schedule. Initial flow rate 250gpm/final flow rate420gpm. Heaviest weight observed while circulating was 12.6 ppg. Final mud weight out was 11.2 ppg. 11/13/2021 11/13/2021 4.75 INTRM2, CASING SMPD P SIH w/ 7" liner on DP f/ 4006' to 7780'. 4,006.0 7,950.0 01:15 06:00 Observed pressure increase while filling pipe. 11/13/2021 11/13/2021 3.75 INTRM2, CASING WASH P Wash down f/ 7780' to 9003'. 250 gpm. 7,950.0 9,003.0 06:00 09:45 730 psi. SO 150k. 11/13/2021 11/13/2021 2.25 INTRM2, CASING CIRC P Circulate and displace 11.0 ppg LSND 9,003.0 9,100.0 09:45 12:00 to 10.5 ppg LSND mud. per MPD schedule. initial rate 343 gpm/824 psi. final rate 420 gpm/860 psi. 10.5 ppg in/out. 11/13/2021 11/13/2021 1.50 INTRM2, CASING SMPD P SIH w/ liner on DP f/ 91 00'to 9363'. 9,100.0 9,363.0 12:00 13:30 Taking weight while attempting to enter sidetrack 11/13/2021 11/13/2021 1.00 INTRM2, CASING SMPD P Rotate from 9363'to 9751'. 20 rpm. 10k 9,363.0 9,751.0 13:30 14:30 ft/lbs tq. 11/13/2021 11/13/2021 2.50 INTRM2, CASING SMPD P SIH w/ liner on DP f/ 9751' to 10702'. 9,751.0 10,702.0 14:30 17:00 Observed drag at 9739' (20k). Rotate thru tight spot w/ 20 rpm. 10k ft/lbs tq. Page 40/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/13/2021 11/13/2021 0.50 INTRM2, CEMENT PULD P PU and MU cement head and dart 10,702.0 10,727.0 17:00 17:30 launcher. SIH and land out at 10727'. Taking weight(20-30k) at 10720' Rotate to 10727' w/ 20 rpm and 12k ft/lbs tq. 11/13/2021 11/13/2021 0.50 INTRM2, CEMENT RURD P MU cement line to cement head. 10,727.0 10,727.0 17:30 18:00 11/13/2021 11/13/2021 3.50 INTRM2, CEMENT CIRC P Establish circulation and stage up to 4 10,727.0 10,727.0 18:00 21:30 bpm. PJSM w/ cementers and rig crew. SPP MPD 1 bpm- 973psi - 420psi 1.5bpm- 989psi - 420psi 2 bpm- 1010psi - 420psi 2.5bpm- 1055psi - 420psi 3 bpm - 1040psi - 400psi 3.5bpm - 990psi - 400psi 4 bpm - 1015psi - 380psi. 11/13/2021 11/13/2021 2.00 INTRM2, CEMENT CMNT P Perform 7" liner cement job 10,727.0 10,727.0 21:30 23:30 Flood lines and test to 4500psi. Pump 60bbls of 13.Oppg mud push @ 4 bpm. 1000-700psi. Drop 1st dart. Mix and pump 50bbls of 15.8ppg cement. Drop 2nd dart. Pump 20 bbls FW w/ cement unit. Swap over to rig pumps and displace at 4bpm 211 psi. At 73bbls into displacement observed decrease in returns and pressure increase to 1500psi (dart latched bottom plug) Pressure decreased to 1250psi. At120 bbls into displacement slow rate to 3 bpm 141 Opsi. Slowed rate to 2 bpm 1750psi at 160 bbls into displacement. Plug bumped at 197 bbls 1950psi (7 bbls early) at 23:30hrs 11/13/21. Total fluid lost during displacement 69bbls. 11/13/2021 11/14/2021 0.50 INTRM2, CEMENT CMNT P Set hanger per Baker procedure. 10,727.0 10,727.0 23:30 00:00 Pressure up to 3000psi. hold f/ 5 minutes. SO to confirm liner set 90k down. Bleed off pressure and check floats (good). 11/14/2021 11/14/2021 1.25 INTRM2, CEMENT PACK P Release running tool per Baker 10,727.0 8,699.0 00:00 01:15 procedure. PU to confirm release. Set liner top packer Baker procedure. Pressure up to 500 psi and PU observe pressure drop. Circulate and clear top of liner. Top of liner @ 8699.38' 11/14/2021 11/14/2021 1.00 INTRM2, CEMENT CIRC P Circulate BU @ 11 bpm 1251psi. No 8,699.0 8,699.0 01:15 02:15 mud push or cement observed at BU. 11/14/2021 11/14/2021 1.00 INTRM2, CEMENT OWFF P Flow check. Static. 8,699.0 8,699.0 02:15 03:15 11/14/2021 11/14/2021 0.50 INTRM2, CEMENT PRTS P Pressure test liner top packer to 1000 8,699.0 8,699.0 03:15 03:45 psi for 10 minutes. Good test. 11/14/2021 11/14/2021 1.00 INTRM2, CEMENT PULD P LD cement head and dart running tool. 8,699.0 8,699.0 03:45 04:45 11/14/2021 11/14/2021 0.50 INTRM2, CEMENT PULD P POOH LD 5" DP f/ 8699'to 8622' 8,699.0 8,606.0 04:45 05:15 11/14/2021 11/14/2021 0.50 INTRM2, CEMENT MPDA P Pull RCD bearing and install trip nipple. 8,606.0 8,606.0 05:15 05:45 11/14/2021 11/14/2021 9.75 INTRM2, CEMENT PULD P POOH LD 5" DP f/ 8622 to surface'. 8,606.0 0.0 05:45 15:30 Monitoring displacement on TT. Page 41/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/14/2021 11/14/2021 0.50 INTRM2, CEMENT PULD P LD Baker running tool. All tools looked 0.0 0.0 15:30 16:00 good per Baker. 11/14/2021 11/14/2021 0.75 INTRM2, CEMENT PULD P MU wash tool for BOPE and RIH 3 stds 0.0 0.0 16:00 16:45 of 5" HW DP. 11/14/2021 11/14/2021 0.75 INTRM2, CEMENT PULD P LD 3 stds of HWDP. 0.0 0.0 16:45 17:30 11/14/2021 11/14/2021 0.75 INTRM2, CEMENT CIRC P Jet BOPE area. 0.0 0.0 17:30 18:15 11/14/2021 11/14/2021 0.75 INTRM2, CEMENT PULD P Pull wear bushing per FMC. 0.0 0.0 18:15 19:00 11/14/2021 11/14/2021 0.75 INTRM2, CEMENT RURD P Change out upper pipe rams to 2 7/8" x 0.0 0.0 19:00 19:45 5 1/2" VBR. 11/14/2021 11/14/2021 1.00 INTRM2, CEMENT RURD P Install test plug per FMC 0.0 0.0 19:45 20:45 11/14/2021 11/15/2021 3.25 INTRM2, CEMENT BOPE P BOPE Test 0.0 0.0 20:45 00:00 All tests to 250psi/5min 3500psi/10min w/ exception of manual and super choke U 2000 psi. 4" Test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR Test choke valves 1-15. Manula operated and super choke. Coke manuals and HCR valves. 4" kill line valve. Test 2x 4" FO safetyvalves. 4" dart valve. 2x 5" FO safety valves. 5" dart valve. Test upper and lower IBOP. Blind/Shear rams. 11/15/2021 11/15/2021 3.50 INTRM2, CEMENT BOPE P Continue BOPE test. All tests to 0.0 0.0 00:00 03:30 250psi/5min 3500psi/10min w/ exception of manual and super choke t/ 2000 psi. 5" test jt: test annular/2 7/8" x 5 1/2" UPR/2 7/8" 5 1/2" LPR Perform Koomey drawndown test 6 bottles avg 1915 psi ACC 3000 psi MANIF. 1500 psi = 1450 psi after all functions on bottles were made 18 sec for 200 psi build with 2 Elec puimps 125 sec to build full system psi w/2 Elec pumps 2 Air pumps. Closing times Annnular 23 sec Upr 18 sec Blind Shear 16 sec LPR 16 Sec Choke HCR 2 sec. Kill HCR 2 sec. Test PVT GAin Loss Alarms And flow out alarms Test LEL and H2S alarms. 11/15/2021 11/15/2021 1.00 INTRM2, CEMENT BOPE P Pull 5" test jt and test plug. RD test 0.0 0.0 03:30 04:30 equipment. Page 42/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/15/2021 11/15/2021 1.50 INTRM2, CEMENT RURD P Change out saver sub to XT39. 0.0 0.0 04:30 06:00 11/15/2021 11/15/2021 0.50 INTRM2, CEMENT NUND P Install 8 3/4" wear bushing. 0.0 0.0 06:00 06:30 11/15/2021 11/15/2021 1.50 INTRM2, CEMENT SLPC P Slip/cut drill line. 121'. Calibrate ampion 0.0 0.0 06:30 08:00 and pason systems 11/15/2021 11/15/2021 3.00 INTRM2, CEMENT RURD T RU Eline for CBL run 0.0 0.0 08:00 11:00 11/15/2021 11/15/2021 4.50 INTRM2, CEMENT ELOG T RIH w/ Eline. Tag at 10428'. Log up w/ 0.0 0.0 11:00 15:30 CBL to TOIL liner at 8699'. 11/15/2021 11/15/2021 1.00 INTRM2, CEMENT RURD T RD Eline. 0.0 0.0 15:30 16:30 11/15/2021 11/15/2021 1.00 INTRM2, CEMENT CLEN P Clean and clear rig floor. Prep to PU 0.0 0.0 16:30 17:30 BHA. 11/15/2021 11/15/2021 3.00 INTRM2, CEMENT BHAH P MU and RIH w/ 6 1/8" production BHA 0.0 329.0 17:30 20:30 to 329'. 11/15/2021 11/16/2021 3.50 INTRM2, CEMENT PULD P Single in w/ 6 1/8" BHA on 4" 14# XT39 329.0 2,224.0 20:30 00:00 DP. f/ 329' to 2224'. Performed shallow test w/ MWD @ 2197' good test. 11/16/2021 11/16/2021 2.00 INTRM2, CEMENT PULD P Single in hole 6 1/8" BHA w/ 4" DP. 2,224.0 3,525.0 00:00 02:00 Note: total 101 singles of 4" DP RIH. 11/16/2021 11/16/2021 1.00 INTRM2, CEMENT PULD P Prepare pipeshed to PU doubles while 3,525.0 3,525.0 02:00 03:00 filling pipe and blow down TD. Held kick while drilling and spill drill. 11/16/2021 11/16/2021 9.00 INTRM2, CEMENT PULD P RIH 6 1/8" BHA w/ doubles of 4" DP 3,525.0 10,285.0 03:00 12:00 from pipeshed f/3525' to 10285' Note: Started logging w/ Sonic tool @ 5400' at 1800 Whr. 11/16/2021 11/16/2021 2.50 INTRM2, CEMENT CIRC P Circulate and condition mud 10.4ppg 10,285.0 10,285.0 12:00 14:30 in/out. 220gpm. 1515psi. ECD 11.05ppg emw. PU 144k. SO 137k. 11/16/2021 11/16/2021 0.50 INTRM2, CEMENT RURD P Blow down TD and RU to test 7" liner. 10,285.0 10,285.0 14:30 15:00 11/16/2021 11/16/2021 1.00 INTRM2, CEMENT PRTS P Perform casing test on 7" liner to 10,285.0 10,285.0 15:00 16:00 3500psi for 30 minutes. Good test. 11/16/2021 11/16/2021 2.50 INTRM2, CEMENT WASH P Wash/ream 10285' to 10636' 220gpm. 10,285.0 10,636.0 16:00 18:30 1375psi. 40 rpm. 5k tq. Soft cement @ 10610' 11/16/2021 11/16/2021 3.50 INTRM2, CEMENT DDRL P Drill out plugs/landing collar f/ 10636' to 10,636.0 10,757.0 18:30 22:00 10727'. Drill 20' new formation f/ 10737' MD to 10757' MD. 225 gpm. 1635 psi. 60 rpm. 5-1 Ok wob. 9k ft/lbs tq. 11/16/2021 11/16/2021 1.50 INTRM2, CEMENT CIRC P Circulate and condition mud f/ FIT. 220 - 10,757.0 10,757.0 22:00 23:30 275gpm. 1515-2230psi. 60 rpm. Reciprocate pipe. 11.04ppg ECD. SimOps: dumpimg mud and prep for displacement. 11/16/2021 11/17/2021 0.50 INTRM2, CEMENT RURD P POOH inside shoe. Flow check (static). 10,757.0 10,665.0 23:30 00:00 RU for FIT/LOT. 11/17/2021 11/17/2021 0.50 INTRM2, CEMENT LOT P Perform FIT/LOT at 7" shoe. 3 bbls 10,665.0 10,665.0 00:00 00:30 pumped 2.7bbls returned. Leak off pressure 1162psi. 13.Oppg EMW 11/17/2021 11/17/2021 0.50 PROD1, DRILL RURD P RD test equipment 10,665.0 10,665.0 00:30 �01:00 Page 43/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/17/2021 11/17/2021 1.50 PROD1, DRILL MPDA P Pull trip nipple. Install 4" RCD bearing 10,665.0 10,665.0 01:00 02:30 assembly. MU stand to run back to bottom. 11/17/2021 11/17/2021 2.75 PROD1, DRILL CIRC P PJSM on displacement to 8.8ppg 10,665.0 10,695.0 02:30 05:15 VersaPro fluid w/ all personnel involved. Pump 50bbls deep clean pill + 75bbls hi vis spacer + 8.8ppg VersaPro fluid. 230- 275gpm. 2300-3150psi. 10.6-10.77 ECD Once 8.8ppg Versapro MOBM to surface.SD pumps and rotary. close MPD and monitor well. Rotate and reciprocate IDS while displacing @ 40 rpm. 11/17/2021 11/17/2021 2.25 PROD1, DRILL CLEN P SD pumps close MPD 10,695.0 10,695.0 05:15 07:30 Clean pits/shakers. monitoring well on MPD. 11/17/2021 11/17/2021 0.50 PROD1, DRILL WASH P Take SPRs at 10695'. Wash down to 10,695.0 10,757.0 07:30 08:00 10757'. 260 gpm. 2168psi. 60 rpm. 9k ft/lbs tq. ECD 9.03ppg emw. PU 170k. SO 139k. Rot 150k. SPRs: MP#1-20spm 340psi. 30spm 620psi MP#2- 20spm 340psi. 30spm 620psi. 11/17/2021 11/17/2021 4.00 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 10757' and 10,757.0 10,950.0 08:00 12:00 to 10950' and 8370' tvd. WOB- 12k GPM- 260 PSI - 2150psi TQ-11k ECD - 9.18ppg emw PU - 170k SO - 139k ROT -150k MPD - Opsi 11/17/2021 11/17/2021 6.00 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 10950' and 10,950.0 11,600.0 12:00 18:00 to 11600' and 8408' tvd. WOB- 9k GPM- 260 PSI - 2248psi RPM 140 TQ - 1 Ok on bottom ECD - 9.35ppg emw PU - 195k SO - 136k ROT - 161 k MPD - Opsi SPRs @ 11326' MP#1- 20 spm-370psi/ 30 spm-620psi MP#2 - 20 spm-360psi/ 30 spm-620psi 11/17/2021 11/18/2021 6.00 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 11600' and 11,600.0 12,347.0 18:00 00:00 to 12347' and 8397" tvd. WOB- 9k GPM- 260 PSI - 2248psi RPM 140 TQ - 1 Ok on bottom ECD - 9.35ppg emw PU - 195k SO - 136k ROT - 161 k MPD - 35psi MW in/out 8.8/8.9ppg Page 44/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/18/2021 11/18/2021 0.25 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 12347' and 12,347.0 12,373.0 00:00 00:15 to 12373' and 8396" tvd. WOB- 9k GPM- 260 PSI - 2248psi RPM 140 TQ - 10k on bottom ECD - 9.35ppg emw PU - 195k SO - 136k ROT - 161 k MPD - 35psi MW in/out 8.8/8.9ppg 11/18/2021 11/18/2021 1.75 PROD1, DRILL CIRC P Circulate BU for trip to shoe. 275 gpm. 12,375.0 12,373.0 00:15 02:00 2508 psi. 60 rpm. 7k tq. 9.39 ECD. Reciprocate IDS f/ 12373' t/ 12274'. 11/18/2021 11/18/2021 2.00 PROD1, DRILL SMPD P SOOH f/ 12373' t/ 10667'. PU 188k. SO 12,373.0 10,667.0 02:00 04:00 138k. MPD 70psi out of slips. 10psi in slips. 11/18/2021 11/18/2021 1.00 PROD1, DRILL RURD P CO XT39 saver sub t/ 4 1/21F saver sub. 10,667.0 10,667.0 04:00 05:00 Monitor well w/ MPD. Observed 35psi on MPD. 11/18/2021 11/18/2021 1.75 PROD1, DRILL SMPD P SIH f/ 10667'to 12283' w/ 4" DP. Flow 10,667.0 12,283.0 05:00 06:45 check. 11/18/2021 11/18/2021 0.50 PROD1, DRILL MPDA P Pull 4" RCD bearing assembly and 12,283.0 12,283.0 06:45 07:15 install 5" RCD bearing assembly. 11/18/2021 11/18/2021 0.50 PROD1, DRILL WASH P Wash down f/ 12283'md t/ 12373' md. 12,283.0 12,373.0 07:15 07:45 260gpm. 2342psi. 50 rpm. 8k tq. 156k SO. 11/18/2021 11/18/2021 4.25 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 12373' and 12,373.0 12,914.0 07:45 12:00 to 12914' and '. WOB- 10k GPM- 275 PSI - 2565psi RPM 140 TQ - 9k on bottom ECD - 9.57ppg emw PU - 190k SO - 128k ROT -164k MPD - 35psi MW in/out 8.8/8.8ppg Note: Gas 8000 units at BU. SPRs 12926': MP#1 20spm-480psi/ 30spm- 700psi MP#@ 20spm-480psi/ 30spm-680psi 11/18/2021 11/18/2021 6.00 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 12914' and 12,914.0 13,628.0 12:00 18:00 to 13628' and 8377' tvd. WOB- 10k GPM- 275 PSI - 2565psi RPM 140 TQ - 10k on bottom TQ - 9k off bottom ECD - 9.70ppg emw PU - 194k SO - 138k ROT -166k MPD -50psi MW in/out 8.8/8.8ppg Page 45/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/18/2021 11/19/2021 6.00 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 13628' and 13,628.0 14,222.0 18:00 00:00 to 14222' and 8378' tvd. WOB- 6k GPM- 275 PSI - 2650psi RPM 140 TQ - 10k on bottom TQ - 9k off bottom ECD - 9.70ppg emw PU - 194k SO - 138k ROT - 166k MPD -50psi MW in/out 8.8/8.9ppg Observed seepage losses increase f/ 5- 10bph to 35bph @ 13380' MD. Add additional 1 ppb each of Safecarb 40 and Mix 2 medium. Losses increased to 60bph @ 13630'. Start adding 1ppb Walnut nutplug premium @13800'. Losses slowed to 20-30bph @ 14035'. Discontinue adding Walnut nutplug after pulse tool stopped pulsing twice. 11/19/2021 11/19/2021 6.00 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 14,222' and 14,222.0 15,072.0 00:00 06:00 to t/ 15,072' md. WOB- 6-8k GPM- 260 PSI - 2450 psi RPM 140 TQ - 14k on bottom TQ - 9k off bottom ECD - 9.79 ppg emw PU - 220k SO - 120k ROT - 171 k MPD - 45 psi ADT- 4.5 hrs TBH- 25.9 Losses increased to 90bbl/hr @ 14775' md.. increased to 1.5 ppb safecarb and 1.5 ppb Mix 2 medium. Losses decreased to 60 bph. Average loss per hr - 27bbls Back ground LCM per/hr: 1.5 ppb SafeCarb-40, 1 ppb Mix II medium, 1 ppb Mixll fine, 1 ppb SafeCarb 500, 1 ppb SafeCarb 750 Page 46/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/19/2021 11/19/2021 6.00 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 15,072' and 15,072.0 15,799.0 06:00 12:00 to t/ 15,799' md. WOB- 6-8k GPM- 250 PSI - 2350 psi RPM 140 TQ - 14k on bottom TQ - 9k off bottom ECD - 9.79 ppg emw PU - 220k SO - 120k ROT - 171 k MPD - 45 psi ADT- 4.2 TBH- 30.1 Average loss per hr - 29bbls Back ground LCM per/hr: 1.5 ppb SafeCarb-40, 1 ppb Mix II medium, 1 ppb Mixll fine, 1 ppb SafeCarb 500, 1 ppb SafeCarb 750 11/19/2021 11/19/2021 6.00 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 15,799' and 15,799.0 16,613.0 12:00 18:00 to t/ 16613' mid. WOB- 2.5k GPM- 240 PSI - 2264 psi RPM 140 TQ - 17k on bottom TQ - 15k off bottom ECD - 9.86 ppg emw PU - 268k SO - NA ROT -178k MPD - 25 psi ADT- 4.4 TBH- 34.5 Average loss per hr - 29bbls Back ground LCM per/hr: 1.5 ppb SafeCarb-40, 1 ppb Mix II medium, 1 ppb Mixll fine, 1 ppb SafeCarb 500, 1 ppb SafeCarb 750 Slowed ROP t/ 100' fph & GPM 240 @ 16,556' t/' to reduce losses. Page 47/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/19/2021 11/19/2021 2.25 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 16613' and 16,613.0 16,797.0 18:00 20:15 to t/ 16797' md. WOB- 2-5k GPM- 240 PSI - 2300 psi RPM 140 TQ - 17k on bottom TQ - 5k off bottom ECD - 9.76 ppg emw PU - 220k SO - 120k ROT - 171 k MPD - 45 psi ADT- TBH- Average loss per hr - 20bbls Continue w/ slower rop (100fph) for losses. No improvement. Back ground LCM per/hr: 1.5 ppb SafeCarb-40, 1 ppb Mix II medium, 1 ppb Mixll fine, 1 ppb SafeCarb 500, 1 ppb SafeCarb 750 11/19/2021 11/19/2021 0.75 PROD1, DRILL CIRC P Pump 40 bbl LCM sweep as follows: 16,797.0 16,797.0 20:15 21:00 Pump 40bbl 9.1 ppg LCM sweep + 5bbls base oil. Displace w/ 8.8ppg OBM to 500ft above bit at 240gpm. Slow rate to 174gpm confirri pulse tool off. continue displacing LCM pill to 7" shoe @ 10727' @ 175gpm. Pill recipe: 40bbl base oil.12 sks Safe Carb 500. 12 sks Safe Carb 750. 8 sks Mixll Fine. 8 sks Mix II Medium. 11/19/2021 11/20/2021 3.00 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 16797' and 16,797.0 17,085.0 21:00 00:00 to t/ 17085' md. WOB- 12k GPM- 260 PSI - 2530 psi RPM 140 TQ - 18-21 k on bottom TQ - 16k off bottom ECD - 9.86 ppg emw PU - 268k SO - NA ROT - 174k MPD - 30 psi ADT- 4.1 TBH- 38.6 Average loss per hr - 15bbls Stage rop rate back to 200fph @ 16890' Back ground LCM per/hr: 1.5 ppb SafeCarb-40, 1 ppb Mix II medium, 1 ppb Mixll fine, 1 ppb SafeCarb 500, 1 ppb SafeCarb 750 Page 48/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhimps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/20/2021 11/20/2021 6.00 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 17,085' and 17,085.0 17,936.0 00:00 06:00 to t/ 17,936' md. WOB- 12k GPM- 260 PSI - 2600 psi RPM 140 TQ - 18-21 k on bottom TQ - 16k off bottom ECD - 9.98 ppg emw PU - 272k SO - NA ROT - 173k MPD - 30 psi ADT- 4.6 TBH- 43.2 Average loss per hr -24 bbls Back ground LCM per/hr: 1.5 ppb SafeCarb-40, 1 ppb Mixll fine, 1 ppb SafeCarb 500, 11/20/2021 11/20/2021 4.00 PROD1, DRILL DDRL P Drill 6 1/8" production hole f/ 17,936' and 17,936.0 18,205.0 06:00 10:00 to t/ 18,205' md. WOB- 12k GPM- 260 PSI - 2655 psi RPM 140 TQ - 18-21 k on bottom TQ - 16k off bottom ECD - 9.77 ppg emw PU - 272k SO - NA ROT -173k MPD - 30 psi ADT- 3 TBH- 46.2 Average loss per hr -24 bbls Back ground LCM per/hr: 1.5 ppb SafeCarb-40, 1 ppb Mixll fine, 1 ppb SafeCarb 500, 11/20/2021 11/20/2021 1.50 PROD1, DRILL CIRC T Trouble shoot increase in stand pipe 18,205.0 18,205.0 10:00 11:30 pressure, Verified all surface equipment was clear, Suspected filter sub was partially plugged Max circulating GPM 50 and standpipe pressure was 4000 psi Decision was made to attempt to open well commander 11/20/2021 11/20/2021 3.50 PROD1, DRILL CIRC T Rack back stand & drop well 18,205.0 18,125.0 11:30 15:00 commander opening ball, Pump ball down GPM-50 PSI- 2275 RPM-20 TQ-16K Work pipe f/ 18,125' t/ 18,035' w/ pumping opening ball down No indication that ball made it to seat, decision made to finger print well and strip out of hole Page 49/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/20/2021 11/20/2021 1.00 PROD1, DRILL OWFF T Finger print well on MPD choke and well 18,125.0 18,125.0 15:00 16:00 built up 29 PSI 11/20/2021 11/20/2021 0.50 PROD1, DRILL OTHR T Blow down TDS & mud lines, Grease 18,125.0 18,125.0 16:00 16:30 topdrive 11/20/2021 11/20/2021 1.00 PROD1, DRILL SMPD T SOOH f/ 18,125' t/ 17,560' racking 5" 18,125.0 17,560.0 16:30 17:30 drill pipe back in derrick Holding 80 PSI in slips, 150 psi out of slips Monitoring fill ups on pits #3 & #5 P/U- 295K Floats not holding so screwing into every joint to keep OBM from covering rig 11/20/2021 11/20/2021 0.75 PROD1, DRILL CIRC T Attempt to open WC. Pump down DS at 17,560.0 16,560.0 17:30 18:15 80gpm. 3108psi. 20 rpm. 16k tq. No success. 11/20/2021 11/21/2021 5.75 PROD1, DRILL SMPD T SOOH f/ 17560't/ 14053' racking 5" drill 16,560.0 14,053.0 18:15 00:00 pipe back in derrick Holding 80 PSI in slips, 150 psi out of slips Monitoring fill ups on pits #3 & #5 P/U-230K Start SOOH on elevators at 16989'. 11/21/2021 11/21/2021 1.50 PROD1, DRILL SMPD T SOOH f/ 14053't/ 12310' racking 5" drill 14,053.0 12,310.0 00:00 01:30 pipe back in derrick Holding 80 PSI in slips, 150 psi out of slips Monitoring fill ups on pits #3 & #5 P/U-215K Sim-ops- Weight up surface pits to 9.1 ppg for trip margin. 11/21/2021 11/21/2021 0.50 PROD1, DRILL CIRC T Attempt to open well commander. Stage 12,310.0 12,310.0 01:30 02:00 up to 2bpm slowly monitoring pressure. no changes in pressure just gradual increase to 2500psi. 11/21/2021 11/21/2021 1.00 PROD1, DRILL OW FF T Flow check well. Blow down top drive. 12,310.0 12,310.0 02:00 03:00 Drop 2nd 1.75" opening ball into drill string @ 02:15 11/21/2021 11/21/2021 1.25 PROD1, DRILL MPDA T Pull 5" RCD bearing assembly and 12,310.0 12,310.0 03:00 04:15 install 4" RCD bearing assembly. MU XT 39 XO to topdrive 11/21/2021 11/21/2021 1.50 PROD1, DRILL SMPD T SOOH f/ 12,310' t/ 11,140' racking 4" 12,310.0 11,140.0 04:15 05:45 drill pipe back in derrick Holding 80 PSI in slips, 150 psi out of slips Monitoring fill ups on pits #3 & #5 P/U-215K Page 50/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/21/2021 11/21/2021 0.50 PROD1, DRILL CIRC T Pump down drill string @ 1-2 bpm to 11,140.0 11,140.0 05:45 06:15 open well commander. Verified ball on seat. Staged pressure up to 1300psi. held f/ 1 minute. Pressure up to 1800 psi. Stage up to 3500 psi in 500 psi increments. Well commander opened @ 3500 psi RPM-5 GPM-50 Note: 2 balls in Well commander ball catcher at 08:30hrs 11 /21 /21 11/21/2021 11/21/2021 2.25 PROD1, DRILL CIRC T Displace well f/ 8.8 ppg t/ 9.1 ppg w/ 11,140.0 11,045.0 06:15 08:30 rotating and reciprocating pipe f/ 11,140' U 11,045' GPM-260 RPM-20 TQ-8K ICP- 875 FCP-1055 Total strokes pumped 8,100 11/21/2021 11/21/2021 0.25 PROD1, DRILL OWFF T Flow check well @ 11,045' Well static 11,045.0 11,045.0 08:30 08:45 SIMOPS- Blow down mud lines & TDS 11/21/2021 11/21/2021 0.75 PROD1, DRILL SMPD T SOOH f/ 11,045't/ 10,665' racking 4" 11,045.0 10,665.0 08:45 09:30 drill pipe in the derrick Holding 10 psi w/ in slips & out Monitor hole fill on pit #3 & #5 11/21/2021 11/21/2021 1.00 PROD1, DRILL OWFF T Flow check well @ 10,665' Well static 10,665.0 10,665.0 09:30 10:30 SIMOPS- Remove 4" rotating head assembly & install trip nipple as per Beyond MPD Rep, Hook up trip tank fill up lines and verify flow through lines 11/21/2021 11/21/2021 6.50 PROD1, DRILL TRIP T TOOH f/ 10,665't/ 168' racking 4" drill 10,665.0 165.0 10:30 17:00 pipe in derrick Monitor hole fill on pits #3 & #5 11/21/2021 11/21/2021 2.00 PROD1, DRILL BHAH T LID 6 1/8" BHA f/ 165'to surface. 165.0 0.0 17:00 19:00 Note: one plugged jet. Fluid above pulse tool. Dry pipe below. 11/21/2021 11/21/2021 1.50 PROD1, DRILL CLEN T Clean and clear rig floor. Bring up tools 0.0 0.0 19:00 20:30 to floor for BHA #11. 11/21/2021 11/21/2021 2.50 PROD1, DRILL BHAH T MU and RIH w/6 1/8" BHA#11 to 304' 0.0 304.0 20:30 23:00 Note: Install closing ball on seat in well commander. 11/21/2021 11/21/2021 0.50 PROD1, DRILL SVRG T Service top drive. Adjust link tilts. 304.0 304.0 23:00 23:30 11/21/2021 11/22/2021 0.50 PROD1, DRILL TRIP T RIH w/ BHA#11 on 4" DP f/304'to 1243' 304.0 1,243.0 23:30 00:00 11/22/2021 11/22/2021 0.50 PROD1, DRILL TRIP T RIH w/ BHA#11 on 4" DP f/ 1243' to 1,243.0 2,225.0 00:00 00:30 2225' Page 51/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/22/2021 11/22/2021 0.50 PROD1, DRILL CIRC T Close well commander. Pump at 25gpm 2,225.0 2,225.0 00:30 01:00 stage up to 1300psi. Hold f/ 1 minute. Stage upt o 3825psi in 500psi increments. Sheared ball and close well commmander at 3825psi. Shallow test MWD. Note: 3 balls in well commander ball catcher as of 01:00hrs 11/22/21 11/22/2021 11/22/2021 5.50 PROD1, DRILL TRIP T Continue RIH w/ BHA#11 f/2,225't/ 2,225.0 10,644.0 01:00 06:30 10,644' Fill pipe every 20stds. Monitoring returns on pits #4 & #5 11/22/2021 11/22/2021 1.50 PROD1, DRILL SLPC P PJSM, hang blocks, slip & cut drill line, 10,644.0 10,644.0 06:30 08:00 Unhang blocks, recalibrate amphion & pason Cut 94' of drill line 11/22/2021 11/22/2021 2.25 PROD1, DRILL TRIP T Cont. t/ RIH w/ BHA#11 f/ 10,644' t/ 10,644.0 12,259.0 08:00 10:15 12,259' Filling pipe every 20 stands Monitor returns on pits #4 & #5 Washed f/ 11,118' t/ 11,210' GPM-225 RPM-60 Torq- 15K 11/22/2021 11/22/2021 0.75 PROD1, DRILL OTHR T Flow check well, well static 12,259.0 12,259.0 10:15 11:00 Pull trip nipple & install 5" rotating head assembly Break circulation through MPD equipment 11/22/2021 11/22/2021 3.50 PROD1, DRILL TRIP T SIH w/ BHA#11 w/ 5" drill pipe f/ 12,259' 12,259.0 16,966.0 11:00 14:30 t/ 16,966' Filling pipe every 20 stands Monitoring retruns on pits #4 & #5 MPD choke full open Lost slack off @ 16,966' 11/22/2021 11/22/2021 4.00 PROD1, DRILL REAM T Wash & ream f/ 16966' t/ 18205'. 16,966.0 18,205.0 14:30 18:30 GPM-230 PSI-2400 RPM-80 Torq-15K Page 52/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) f MT7-01 RIG RELEASE DATE 11/29/2021 ConoAftllips Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/22/2021 11/23/2021 5.50 PROD1, DRILL DDRL P Control drill 6 1/8" production hole f/ 18,205.0 18,382.0 18:30 00:00 18205' and to U 18382' md. Stage ROP f/ 30ft/hr to 100ft/hr WOB-10 k GPM- 240 PSI - 2255 psi RPM 120 TQ - 15k on bottom TQ - 14k off bottom ECD - 9.75 ppg emw PU -245 k SO - NA ROT - 173k MPD - psi ADT- 4.2 TBH- 4.2 Average loss per hr - 16bbls Back ground LCM per/hr: 1 ppb SafeCarb-40, 1 ppb Mix II medium, 1 ppb Mixll fine, 1 ppb SafeCarb 500, 1 ppb SafeCarb 750. Increase lube 776 from 1 % to 3%. 11/23/2021 11/23/2021 6.00 PROD1, DRILL DDRL P Control drill 6 1/8" production hole f/ 18,380.0 18,854.0 00:00 06:00 18,382' and U 18,854' md. WOB-5 k GPM- 245 PSI - 2285 psi RPM 140 TQ - 16k on bottom TQ - 14k off bottom ECD - 9.9 ppg emw PU -248 k SO - NA ROT -180k MPD - 45 psi ADT- 5.1 TBH- 9.3 Average loss per hr - 19 bbls Back ground LCM per/hr: 1 ppb SafeCarb-40, 1 ppb Mix II medium, 1 ppb Mixll fine, 1 ppb SafeCarb 500, 1 ppb SafeCarb 750. Increase lube 776 from 1 % to 3%. Page 53159 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/23/2021 11/23/2021 6.00 PROD1, DRILL DDRL P Control drill 6 1/8" production hole f/ 18,854.0 19,020.0 06:00 12:00 18,854' and t/ 19,020' md. WOB-5 k GPM- 260 PSI - 2355 psi RPM 140 TQ - 16k on bottom TQ - 14k off bottom ECD - 9.76 ppg emw PU -242 k SO - NA ROT - 181 k MPD - 40 psi ADT- 5.6 TBH- 14.9 Average loss per hr - 19 bbls Back ground LCM per/hr: 1 ppb SafeCarb-40, 1 ppb Mix II medium, 1 ppb Mixll fine, 1 ppb SafeCarb 500, 1 ppb SafeCarb 750. Increase lube 776 from 1 % to 3%. 11/23/2021 11/23/2021 7.00 PROD1, DRILL DDRL P Control drill 6 1/8" production hole f/ 19,020.0 19,645.0 12:00 19:00 19,020' and t/ 19645' md. TD @ 18:45hrs 11/23/21 WOB-5-15 k GPM- 260 PSI - 2355 psi RPM 140 TQ - 14k on bottom TQ - 14k off bottom ECD - 9.76 ppg emw PU -245 k SO - NA ROT - 183k MPD - 40 psi ADT- 5.2 TBH- 20.1 Average loss per hr - 19 bbls Back ground LCM per/hr: 1 ppb SafeCarb-40, 1 ppb Mix II medium, 1 ppb Mixll fine, 1 ppb SafeCarb 500, 1 ppb SafeCarb 750. Increase lube 776 from 1 % to 3%. 11/23/2021 11/24/2021 5.00 PROD1, CASING CIRC P Circulate hole clean while BROOH at 1 19,645.0 19,363.0 19:00 00:00 std per BU f/ 3 stds to 19363'. GPM:265 PSI: 2473 RPM: 140 TQ: 14k ECD 9.9ppg PU: 252k ROT: 182k Sini MU and rack back stds of 5" DP for liner run. Page 54/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/24/2021 11/24/2021 1.00 PROD1, CASING CIRC P Circulate hole clean while BROOH at 1 19,363.0 19,323.0 00:00 01:00 std per BU f/ 3 stds f/ 19363' to 19323' (3stds) GPM:265 PSI: 2473 RPM: 140 TQ:14k ECD 9.9ppg PU: 252k ROT: 182k Sini MU and rack back stds of 5" DP for liner run. 11/24/2021 11/24/2021 0.50 PROD1, CASING OW FF P Fingerprint well. close choke f/ 5min 19,323.0 19,323.0 01:00 01:30 open f/ 1 min. 1 st- 45psi 2nd-25psi 3rd-18psi 4th-16psi. 11/24/2021 11/24/2021 9.25 PROD1, CASING BKRM P BROOH f/ 19,323't/ 16,780'. 19,323.0 16,780.0 01:30 10:45 GPM:265 PSI: 2473 RPM: 120 TQ:14k ECD 9.6ppg PU: ROT: 166k SimOps: MU and rack back stds of 5" DP for liner run. 11/24/2021 11/24/2021 1.75 PROD1, CASING CIRC P Circ btms up f/ 16,780' t/ 16,674' w/ 16,780.0 16,674.0 10:45 12:30 rotating & reciprocating pipe RPM-120 Torq- 12K GPM-260 PSI-2335 ECD-9.66 P/U-220K S/0-138K 11/24/2021 11/24/2021 4.25 PROD1, CASING SMPD P SOOH f/ 16,674' t/ 12,470' racking back 16,674.0 12,470.0 12:30 16:45 5" drill pipe in derrick f/ 4.5" liner run Holding 70 psi while in slips & 150 psi while out of slips Motor returns on pits #3 & #5 11/24/2021 11/24/2021 2.25 PROD1, CASING CIRC P Displace well f/ 8.9 ppg t/ 9.1 ppg w/ 12,470.0 12,350.0 16:45 19:00 rotating & reciprocating pipe f/ 12,470' t/ 12,380' RPM-80 Torq-8K GPM-260 PSI-2063 Flow check well. 11/24/2021 11/24/2021 1.25 PROD1, CASING MPDA P Pull 5" RCD bearing assembly and 12,350.0 12,255.0 19:00 20:15 install trip nipple. CO elevators f/ 5" to 4". Page 55/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/24/2021 11/25/2021 3.75 PROD1, CASING PULD P POOH LID 4" DP f/ 12250' to9209'. 12,255.0 9,209.0 20:15 00:00 Montoring fill on trip tank. 11/25/2021 11/25/2021 9.50 PROD1, CASING PULD P POOH LID 4" DP f/9,209't/ 1,667'. 9,209.0 1,667.0 00:00 09:30 Several connections overtorqued. Montoring fill on trip tank. Average losses: 615ph 11/25/2021 11/25/2021 0.25 PROD1, CASING OTHR P PJSM, RIH w/ stand w/ 4" rotating head 1,667.0 1,667.0 09:30 09:45 & strip same off stand 11/25/2021 11/25/2021 1.75 PROD1, CASING PULD P POOH L/D 4" drill pipe f/ 1,667' t/ BHA 1,667.0 300.0 09:45 11:30 Monitoring returns on trip tanks 11/25/2021 11/25/2021 1.50 PROD1, CASING BHAH P PJSM, Rack back 4" HWDP, L/D well 300.0 0.0 11:30 13:00 commander, float sub, filter sub, & NMDC, Break bit, L/D bit, RSS, & MWD 11/25/2021 11/25/2021 0.50 COMPZN, CASING CLEN P Clean rig floor of OBM before rigging up 0.0 0.0 13:00 13:30 to run 4.5" liner 11/25/2021 11/25/2021 0.50 COMPZN, CASING SVRG P Grease topdrive & check oil in same 0.0 0.0 13:30 14:00 11/25/2021 11/25/2021 1.00 COMPZN, CASING RURD P PJSM, P/U casing tongs & 4.5" handling 0.0 0.0 14:00 15:00 equipment 11/25/2021 11/25/2021 8.50 COMPZN, CASING PUTB P PU and RIH w/ 4 1/2" Lower completion 0.0 7,470.0 15:00 23:30 per tally to 7470'. 11/25/2021 11/26/2021 0.50 COMPZN, CASING CIRC P Circulate liner volume to top perforated 7,470.0 7,470.0 23:30 00:00 joint. 11/26/2021 11/26/2021 0.50 COMPZN, CASING PUTB T LID bad joint of 4 1/2" liner. PU 7,470.0 7,470.0 00:00 00:30 replacement joint. (Same length). 11/26/2021 11/26/2021 1.00 COMPZN, CASING PULD P PU and MU 4 1/2" liner hanger and ZXP 7,470.0 7,586.0 00:30 01:30 packer per Baker. Fill tie back sleeve w/ Zan Plex. RIH w/ 1 std 4" HWDPto 7585' Take parameters: PU 108k. SO 110k. ROT 107k. 20rpni ft/lbs tq 30rpm= 3.5k ft/lbs tq. 11/26/2021 11/26/2021 3.50 COMPZN, CASING RUNL P RIH w/ 4 1/2" liner on 4" HWDP f/ 7585' 7,586.0 9,557.0 01:30 05:00 to 9557'. (66 joints 4" HWDP total). RIH @ 60ft/min. Note. No issues passing through TOIL @ 8699'. 11/26/2021 11/26/2021 7.00 COMPZN, CASING RUNL P RIH w/ 4 1/2" liner on 5" DP at 60fpm f/ 9,557.0 18,050.0 05:00 12:00 9,557' t/ 18,050' Gather torqed readings @ 10,700' 20 RPM 4.9 torq, 30 RPM 5.2 torq. Lost 20K slack off f/ 10,940' t/ 11,750' Monitor displacement on trip tanks 11/26/2021 11/26/2021 0.50 COMPZN, CASING CIRC P Establish returns & stage pumps up t/ 18,050.0 18,050.0 12:00 12:30 200 gpm & circ drill pipe volume before dropping Baker setting ball GPM-200 PSI-975 Page 56/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/26/2021 11/26/2021 1.00 COMPZN, CASING HOSO P Pump 10 bbl hi-vis spacer, drop 1 5/8" 18,050.0 18,050.0 12:30 13:30 setting ball followed by 10 bbls hi-vis spacer, pump ball down @ 200 gpm, slowed rate down t/ 100 gpm f/ last 500 strokes. Once ball on seat pressure up t/ 2,600 psi, verify hanger was set, Pressure up t/ 3,500 psi and set down 50K to shear liner top packer. Verified w/ Baker rep that packer was set 1,317 total strokes pumped t/ seat ball 11/26/2021 11/26/2021 1.50 COMPZN, CASING PRTS P Blown down TDS, Line up through kill 18,050.0 18,050.0 13:30 15:00 line & test liner top packer t/ 2,500 psi f/ 10 minutes, Test good. Note: shoe depth 18050' TOL depth 10538' 11/26/2021 11/26/2021 3.50 COMPZN, WELLPR CIRC P Displace well f/ 9.1 ppg OBM t/ 9.1 ppg 18,050.0 18,050.0 15:00 18:30 clear brine fluid GPM-250 PSI-800 11/26/2021 11/26/2021 3.00 COMPZN, WELLPR CLEN P Clean shakers/pits/flow lines/rotary. 18,050.0 18,050.0 18:30 21:30 Flow check well. Losses @ 3-5bph 11/26/2021 11/27/2021 2.50 COMPZN, WELLPR PULL P POOH LID 5" DP. f/ 10497'to 8089' 10,497.0 8,089.0 21:30 00:00 Monitoring displacement on trip tank. losses at 3bph. 11/27/2021 11/27/2021 6.25 COMPZN, WELLPR PULL P POOH LID 5" DP. f/ 8,089' t/ 2,042' 8,089.0 2,500.0 00:00 06:15 Monitoring displacement on trip tank. losses at 3-5bph. 11/27/2021 11/27/2021 0.50 COMPZN, WELLPR OTHR P C/O handling tools f/ 5" t/ 4" 2,500.0 2,500.0 06:15 06:45 11/27/2021 11/27/2021 3.25 COMPZN, WELLPR PULL P POOH f/ 2,042't/ liner running tools 2,500.0 0.0 06:45 10:00 Monitor displacement on trip tanks Losses averaging 3-5 bph 11/27/2021 11/27/2021 0.50 COMPZN, WELLPR PULL P Break apart & lay down Baker liner 0.0 0.0 10:00 10:30 running tool 11/27/2021 11/27/2021 0.50 COMPZN, RPCOMP OTHR P Pull wear bushing & L/D same as per 0.0 0.0 10:30 11:00 FMC 11/27/2021 11/27/2021 0.50 COMPZN, RPCOMP OTHR P M/U stack washing tool & wash stack 0.0 0.0 11:00 11:30 GPM-300 PSI-54 Strokes pumped-1550 11/27/2021 11/27/2021 4.00 COMPZN, RPCOMP RURD P PJSM, rig up Halliburton tee wire spool 0.0 0.0 11:30 15:30 & spooler, Remove PS-21's, Install master bushings & cavin air slips, Rig tee wire clamp tools, Hang tee wire sheave in derrick, R/U fill up hose 11/27/2021 11/27/2021 0.25 COMPZN, RPCOMP SFTY P PJSM w/ HIES, Baker, & Doyon casing 0.0 0.0 15:30 15:45 discussing upper completion run 11/27/2021 11/27/2021 0.75 COMPZN, RPCOMP RCST P RIH w/ Baker index shoe, mechanical 0.0 170.0 15:45 16:30 locator, SLB landing nipple, Baker production packer & 1 joint 4.5" tubing 11/27/2021 11/27/2021 2.00 COMPZN, RPCOMP RCST P P/U HES downhole gauge assembly & 170.0 242.0 16:30 18:30 test to 5000psi. Good test. MU GLM assembly#1 and RIH. Page 57/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 conocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/27/2021 11/28/2021 5.50 COMPZN, RPCOMP RCST P RIH w/ upper completion f/ 242' to 242.0 4,545.0 18:30 00:00 4545'. Checking control line every 1000' Installed GLM assembly #2 at 2375' per tally. Monitoring displacement on trip tank. Total losses last 24hrs.- 89bbls. 11/28/2021 11/28/2021 9.00 COMPZN, RPCOMP RCST P RIH w/ upper completion f/ 4,545' t/ 4,545.0 10,419.0 00:00 09:00 10,419'. Checking control line every 1000, Installed GLM assembly #3 at 6374' per tally. Monitoring displacement on trip tank. Ran 255 joints & tagged up on locator sub, Got space out measurements & laid down 3 joints of tubing 11/28/2021 11/28/2021 1.50 COMPZN, RPCOMP CIRC P Displace well with 316 bbls corrosion 10,419.0 10,419.0 09:00 10:30 inhibited brine chased by 161 bbls brine w/ .25% Safe Break GPM-225 PSI-420 Total strokes pumped-4730 11/28/2021 11/28/2021 2.25 COMPZN, RPCOMP HOSO P Make up space out pups as per CPAI 10,419.0 10,549.0 10:30 12:45 rep & Baker, Make up FMC tubing hanger & TEC wire through tubing hanger Pressure test splice V 5,000 psi f/ 10 minutes, Test witnessed by CPAI rep 11/28/2021 11/28/2021 3.00 COMPZN, RPCOMP OTHR P Drop 1 5/16" ball & rod, Test FMC 10,549.0 10,549.0 12:45 15:45 hanger seals t/ 2,500 psi f/ 10 mniutes w/ ball & rod drops Pressure up tubing V 3,000 psi f/ 5 minutes, bring tubing psi t/ 3,500 & hold f/ 30 minutes Bleed tubing down V 3,000 psi & bring pressure on IA V 3,500 psi & hold pressure f/ 30 minutes Bleed tubing V 0 psi V shear SOV Tubing & IA equalized & bled V 0 psi Observed IA for flow f/ 10 minutes, No flow 11/28/2021 11/28/2021 0.50 COMPZN, WHDBOP RURD P RD testing equipment. LID landing joint. 10,549.0 10,549.0 15:45 16:15 Install HP-BPV. 11/28/2021 11/28/2021 0.50 COMPZN, WHDBOP PRTS T Attempt to pressure test BPV. Valve 10,549.0 10,549.0 16:15 16:45 leaking by on mud pump.CO valve. 11/28/2021 11/28/2021 1.00 COMPZN, WHDBOP PRTS P Pressure test HP BPV from below to 10,549.0 10,549.0 16:45 17:45 2500ps f/ 15 minutes. Good test. 11/28/2021 11/28/2021 0.75 COMPZN, WHDBOP RURD P RD lines in cellar area. Blow down kill 10,549.0 10,549.0 17:45 18:30 and injection lines. 11/28/2021 11/28/2021 3.50 COMPZN, WHDBOP NUND P LD 90' MH. ND MPD. RD choke/kill 10,549.0 10,549.0 18:30 22:00 lines. ND stack and riser. Set BOP stack back. LID riser. SimOps: Cleaning mud pits. 11/28/2021 11/29/2021 2.00 COMPZN, WHDBOP NUND P Terrminate TEC control line at WH. Prep 10,549.0 10,549.0 22:00 00:00 hanger f/ adapter flange. Page 58/59 Report Printed: 12/16/2021 Operations Summary (with Timelog Depths) MT7-01 RIG RELEASE DATE 11/29/2021 ConocoPhiwps Rig: DOYON 25 Job: DRILLING ORIGINAL Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/29/2021 11/29/2021 1.00 COMPZN, WHDBOP NUND P Complete control line termination at WH. 10,549.0 10,549.0 00:00 01:00 NU adapter flange.Test flange adapter to 5000psi f/ 5 minutes. Good test 11/29/2021 11/29/2021 2.50 COMPZN, WHDBOP NUND P Install 10k Frac tree. Fill tree w/ desiel, 10,549.0 10,549.0 01:00 03:30 Test 250psi low f/ 10 min. 10,000psi f/ 10 min. Test witnessed by COPA rep Blow down testing equipment & rig down same SIMOPS- Remove 4" handling equipment f/ rig floor 11/29/2021 11/29/2021 1.00 COMPZN, WHDBOP NUND P Bleed off pressure f/ IA, Pull FMC test 10,549.0 10,549.0 03:30 04:30 dart & lay down same, R/U pump in sub U top of tree 11/29/2021 11/29/2021 1.00 DEMOB, MOVE OTHR P PJSM, R/U Lil Red services t/ freeze 10,549.0 10,549.0 04:30 05:30 protect well, Pressure test lines t/ 2,500 psi f/ 5 minutes 11/29/2021 11/29/2021 2.00 DEMOB, MOVE CIRC P Freeze protect well w/ Lil Red Services, 10,549.0 10,549.0 05:30 07:30 pumped 67 bbls diesel down the IA taking returns t/ pit #2 FCP-1325 psi @ 2 bpm IA psi after pumping 425 Disconnect Lil Red Services & line up t/ U-tube well f/ 1 hour, blow down lines & manifold SIMOPS- Hook hydraulic cylinders t/ well house, disconnect interconnect 11/29/2021 11/29/2021 1.50 DEMOB, MOVE OTHR P R/U FMC lubricator & install H-style 10,549.0 10,549.0 07:30 09:00 BPV as per FMC Remove & lay down lubricator Install frac tree cap & gauges Secure frac tree Rig released @ 09:00 on 11/29/21 Page 59/59 Report Printed: 12/16/2021 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:Gorham, Brad To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]FW: VARIANCE APPROVAL: Final Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) Date:Thursday, December 23, 2021 11:11:15 AM Victoria, No I had not previously seen this document and wasn’t aware that it needed to be submitted for each well as it will be almost identical. I will update the document with the depths for MT7-96 and send back. I will also communicate this requirement to our group so that it is included as an attachment moving forward. Thanks, Brad From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Thursday, December 23, 2021 11:05 AM To: Gorham, Brad <Brad.Gorham@conocophillips.com> Subject: [EXTERNAL]FW: VARIANCE APPROVAL: Final Int. 1 Casing Ram Variance MT7-01 (PTD 21- 052) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Brad, The attached word document for the variance is what I was looking for. It looks like I didn’t forward this to you. This detail could be an attachment in the PTD. Did I miss this in the PTD? Didn’t find it. Thanx, Victoria From: Loepp, Victoria T (CED) Sent: Thursday, October 21, 2021 3:23 PM To: Hobbs, Greg S (Greg.S.Hobbs@conocophillips.com) <Greg.S.Hobbs@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Melvin Rixse <melvin.rixse@alaska.gov>; McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: VARIANCE APPROVAL: Final Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) Greg, ConocoPhillips Alaska has requested a variance to 20 AAC 25.035 (e) (1) (C) (ii) on the MT7-01 Intermediate 1 Hole Section. The variance would allow utilizing a Kick-Joint while running approximately 1,600’ of 9-7/8” casing in a tapered casing string design with ~7,590’ of 9-5/8” casing above it. The attached variance is APPROVED with conditions as outlined in the variance document. 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 From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Wednesday, October 20, 2021 5:33 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Final Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) Victoria, After sending the previous mail, there was concern expressed from the rig that a drill that involved a make and break of the premium connection (Hydril 523) could gall the connection with the break and removal. The word document below, with “Final” in the title presents the drill that the rig would do with a complete run through the procedure, confirmation of tools, equipment and placement without actual make-up and break-out. Apologies for the second version. Please contact me with questions or concerns- Thank-you. Greg _____________________________________________ From: Hobbs, Greg S Sent: Wednesday, October 20, 2021 3:40 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) Victoria, Attached please find a variance request for 20 AAC 25.035 (e) (1) (C) (ii) for the casing run on the Intermediate 1 section of MT7-01. The variance is needed due to the inability to procure variable bore rams for the tapered casing string. The taper is required for casing wear considerations and design with a casing that we currently have in stock. The four-string design of this well is a contingency to eliminate the running and cementing issues experienced on the Intermediate 1 Longstring of the three earlier wells on the pad. Primary well control is not risked with this variance. Secondary control is maintained with 9 5/8” casing rams and a kick joint that is further described in the attached request. A Kick Drill utilizing the kick joint will be executed to assure proficiency in an emergency. Thank-you! Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263-4749 I C: (907) 231-0515 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:Gorham, Brad To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Regg, James B (OGC); Rixse, Melvin G (OGC); McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL]RE: VARIANCE APPROVAL: Final Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) Date:Thursday, December 23, 2021 11:27:43 AM Attachments:MT7-96 Int. 1 Casing Ram Variance Final.docx Victoria, Please see attached for the updated variance request. Let me know if you need anything else. Thanks, Brad From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Wednesday, December 22, 2021 2:13 PM To: Gorham, Brad <Brad.Gorham@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: [EXTERNAL]RE: VARIANCE APPROVAL: Final Int. 1 Casing Ram Variance MT7-01 (PTD 21- 052) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Brad, Please modify this variance request to be used for MT7-96 to be included in the PTD. Thanx, Victori From: Loepp, Victoria T (CED) Sent: Thursday, October 21, 2021 3:23 PM To: Hobbs, Greg S (Greg.S.Hobbs@conocophillips.com) <Greg.S.Hobbs@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Melvin Rixse <melvin.rixse@alaska.gov>; McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: VARIANCE APPROVAL: Final Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) Greg, ConocoPhillips Alaska has requested a variance to 20 AAC 25.035 (e) (1) (C) (ii) on the MT7-01 Intermediate 1 Hole Section. The variance would allow utilizing a Kick-Joint while running approximately 1,600’ of 9-7/8” casing in a tapered casing string design with ~7,590’ of 9-5/8” casing above it. The attached variance is APPROVED with conditions as outlined in the variance document. 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 From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Wednesday, October 20, 2021 5:33 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Final Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) Victoria, After sending the previous mail, there was concern expressed from the rig that a drill that involved a make and break of the premium connection (Hydril 523) could gall the connection with the break and removal. The word document below, with “Final” in the title presents the drill that the rig would do with a complete run through the procedure, confirmation of tools, equipment and placement without actual make-up and break-out. Apologies for the second version. Please contact me with questions or concerns- Thank-you. Greg _____________________________________________ From: Hobbs, Greg S Sent: Wednesday, October 20, 2021 3:40 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) Victoria, Attached please find a variance request for 20 AAC 25.035 (e) (1) (C) (ii) for the casing run on the Intermediate 1 section of MT7-01. The variance is needed due to the inability to procure variable bore rams for the tapered casing string. The taper is required for casing wear considerations and design with a casing that we currently have in stock. The four-string design of this well is a contingency to eliminate the running and cementing issues experienced on the Intermediate 1 Longstring of the three earlier wells on the pad. Primary well control is not risked with this variance. Secondary control is maintained with 9 5/8” casing rams and a kick joint that is further described in the attached request. A Kick Drill utilizing the kick joint will be executed to assure proficiency in an emergency. Thank-you! Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263-4749 I C: (907) 231-0515 ConocoPhillips Alaska MT7-96 Intermediate 1 Hole BOP Configuration Variance Request ConocoPhillips Alaska is requesting a variance to 20 AAC 25.035 (e) (1) (C) (ii) on the MT7-96 Intermediate 1 Hole Section. The variance would allow utilizing a Kick-Joint while running approximately 1,600’ of 9-7/8” casing in a tapered casing string design with ~7,081’ of 9-5/8” casing above it. ConocoPhillips has attempted to source VBR’s that would fit both 9-5/8” casing and 9-7/8” casing but has been unsuccessful in finding any to fit these Schaffer BOP’s. The 9-7/8” casing string is necessary as a heavy-heel design to provide protection against casing wear in these four string wells while utilizing existing casing stock. This variance will allow shut-in with 9-5/8” casing rams for a well control kill operation and allow rig personnel to quickly and safely shut-in the well if the need arises while the portion of the 9-7/8” casing is being run. The Kick Joint is designed with 9-7/8” H523 threads on top and bottom that will make up to the 9-7/8” casing and will fit our handling equipment for well control readiness (Figure 1). All internal connections will utilize connection cement to assure connection integrity with handling. Figure 1 The casing string is as follows: 9-5/8” Shoe track and float (82’) –> 1,600’ of 9-7/8” casing –> 7,081’ of 9-5/8” casing. Primary well control for running the 9-5/8” x 9-7/8” casing string would be as follows: The primary barrier is the fluid density at 11 ppg designed for mechanical stability of the HRZ shale section while running the tapered casing string. The Susitna Sand at 7,670 MD (6549’ TVD) will be penetrated with a 10.5 ppg mud system. The Susitna sand has been penetrated with a 9.8 ppg mud system and did not encounter any issues. A tested annular is a second barrier in an emergency flow situation. Secondary well control with variance approval is as follows: • Prior to making up the shoe-track: o The 9-5/8” solid body rams will be installed in the BOP’s and tested to 250 / 3,500 psi around the 9-5/8” test joint. o A 9-7/8” test joint will then be picked up and the Annular Preventer will be tested to 250 / 3,500 psi around it. o Crossovers from the 9-7/8” H523 to NC50 threads will be prepped with a FOSV and will be ready to be picked up on the floor. o The 9-5/8” kick stand will on the short side of the pipe skate, un-obstructed. • The procedure for shutting in while running the 9-7/8” casing will be: o Close the annular preventer around the 9-7/8” casing. o Pipe skate operator will move the Kick Joint to the rig floor o Latch onto the Kick Joint with the 9-7/8” elevators that are currently rigged up o Make the Kick Joint up to the 9-7/8” casing stump o With the annular still closed, strip the kick joint in the hole and space the 9-5/8” body of the Kick Joint around the upper pipe rams. o Close the 9-5/8” casing rams o Stab the crossover with the FOSV in and close the FOSV. Prior to running casing, a kick drill will be completed with the above procedure to assure competency before an actual event occurs. This drill will be a “mock” drill to pick up the kick joint and run it into the BOP stack to verify height at the floor for ram closure on the 9 5/8” section of the joint. It will also assure that procedure and tools are in place to properly install the FOSV on the top of the joint. This will align crews on the procedure and prevent damage to the connection from a make and break drill. The well control risk of this section is extremely low with an eleven pound per gallon mud system across the Susitna Sand and the casing shoe being set in the HRZ shale as illustrated in Figure 2. ConocoPhillips is making this request after significant issues arose with the three-string design on MT7- 04, MT7-03 and MT7-06. In these wells, there were issues with the shale sections that prevented successfully landing the intermediate 1 casing string and completing primary cement jobs. Please contact Greg Hobbs at 907-263-4749 or greg.s.hobbs@cop.com for any questions of comments. Figure 2 NADConversion Western North Slope GMT2 Rendezvous Pad MT7-01 ConocoPhillips Definitive Survey Report 20 December, 2021 Ili ConocoPhil lips r•' ConocoPhillips CormoPhillips Definitive Survey Report Baker Hughes Company: NADConversion Local Co-ordinate Reference: Well MT7-01 Project: Western North Slope TVD Reference: WELL @ 139.4usft (Original Well Elev) Site: GMT2 Rendezvous Pad MD Reference: WELL @ 139.4usft (Original Well Elev) Well: MT7-01 North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01 Database: EDT 15 Alaska Prod Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MT7-01 Well Position +N/-S 0.0 usft Northing: 5,915,835.96 usft Latitude: 70° 10' 23.950 N +E/-W 0.0 usft Easting: 290,025.72 usft Longitude: 151° 41' 25.142 W Position Uncertainty 0.0 usft Wellhead Elevation: usft Ground Level: 100.7usft Wellbore MT7-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2021 12/20/2021 14.67 80.40 57,142.84466532 Design MT7-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,274.4 Vertical Section: Depth From (TVD) +NI-S +E/-W Direction (usft) (usft) (usft) , (°) 38.7 0.0 0.0 298.60 Survey Program Date 12/20/2021 "WM From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 110.5 821.3 MT7-01PB1 Srvy 1 -Gyro (MT7-01PB1) SDI_Keeper_ADK SDI Keeper All -Attitude Drop Keeper 1.1 10/20/2021 8:1£ 822.3 3,356.5 MT7-01 PB1 Srvy 2 - BH MWD IFR + SA MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correc110/21/2021 9:3f 3,356.5 9,232.3 MT7-01 PB1 Srvy 3 - BH MWD IFR + SA MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correc110/21/2021 9* 9,232.3 9,274.4 MT7-01 PB1 Srvy 4 - BH MWD IFR + SA MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correc110/27/2021 9:1f 9,287.4 10,737.0 MT7-01 Srvy 1 - BH MWD IFR + SAG (M MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correc111/12/2021 10:21 10,695.0 19,611.3 MT7-01 Srvy 2 - BH MWD IFR + SAG (M MWD OWSG OWSG MWD - Standard 11/20/2021 8:52 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (I (I (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 38.7 0.00 0.00 38.7 100.7 0.0 0.0 5,915,836.0 290,025.7 0.0 0.00 UNDEFINED 110.5 0.26 249.90 110.5 28.9 -0.1 -0.2 5,915,835.9 290,025.6 0.4 0.11 SDI_Keeper_ADK(1) 205.8 0.35 260.16 205.8 -66.4 -0.2 -0.6 5,915,835.8 290,025.1 0.1 0.48 SD1_Keeper_ADK(1) 237.6 0.44 263.32 237.6 -98.2 -0.2 -0.9 5,915,835.8 290,024.8 0.3 0.65 SDI_Keeper_ADK(1) 329.6 0.62 268.95 329.6 -190.2 -0.3 -1.7 5,915,835.7 290,024.0 0.2 1.38 SDI_Keeper_ADK(1) 421.5 0.79 270.70 421.5 -282.1 -0.3 -2.8 5,915,835.8 290,022.9 0.2 2.37 SDI_Keeper_ADK(1) 514.4 1.14 271.76 514.4 -375.0 -0.2 4.4 5,915,835.9 290,021.3 0.4 3.76 SD1_Keeper_ADK(1) 608.8 1.58 278.44 608.7 -469.3 0.0 -6.6 5,915,836.1 290,019.1 0.5 5.82 SDI_Keeper_ADK(1) 702.8 1.76 261.91 702.7 -563.3 0.0 -9.3 5,915,836.2 290,016.4 0.5 8.19 SDI_Keeper_ADK(1) 796.5 2.29 237.30 796.4 -657.0 -1.2 -12.3 5,915,835.1 290,013.3 1.1 10.25 SDI_Keeper_ADK(1) 1212012021 6.45:59PM Page 2 COMPASS 5000.15 Build 91E r•' ConocoPhillips ConocoPhillips Definitive Survey Report Baker Hughes Company: NADConversion Local Co-ordinate Reference: Well MT7-01 Project: Western North Slope TVD Reference: WELL @ 139.4usft (Original Well Elev) Site: GMT2 Rendezvous Pad MD Reference: WELL @ 139.4usft (Original Well Elev) Well: MT7-01 North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01 Database: EDT 15 Alaska Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (ft) Survey Tool Name 822.3 2.54 235.13 822.2 -682.8 -1.8 -13.2 5,915,834.5 290,012.4 1.0 10.75 MWD+IFR2+SAG+MS (2) 916.8 4.17 211.72 916.4 -777.0 -6.0 -16.8 5,915,830.5 290,008.8 2.2 11.87 MWD+IFR2+SAG+MS (2) 1,011.0 5.84 204.87 1,010.3 -870.9 -13.2 -20.6 5,915,823.3 290,004.8 1.9 11.75 MWD+IFR2+SAG+MS (2) 1,104.3 7.54 203.40 1,102.9 -963.5 -23.1 -25.0 5,915,813.5 290,000.1 1.8 10.88 MWD+IFR2+SAG+MS (2) 1,292.7 10.21 199.93 1,289.1 -1,149.7 -50.2 -35.6 5,915,786.8 289,988.7 1.4 7.24 MWD+IFR2+SAG+MS (2) 1,386.5 11.35 198.91 1,381.2 -1,241.8 -66.7 -41.4 5,915,770.4 289,982.4 1.2 4.44 MWD+IFR2+SAG+MS (2) 1,482.7 13.53 197.63 1,475.2 -1,335.8 -86.4 -47.9 5,915,750.9 289,975.4 2.3 0.70 MWD+IFR2+SAG+MS (2) 1,576.2 15.03 195.24 1,565.8 -1,426.4 -108.5 -54.4 5,915,729.0 289,968.3 1.7 -4.18 MWD+IFR2+SAG+MS (2) 1,670.0 17.36 195.26 1,655.8 -1,516.4 -133.8 -61.3 5,915,703.9 289,960.7 2.5 -10.22 MWD+IFR2+SAG+MS (2) 1,764.8 19.29 196.42 1,745.8 -1,606.4 -162.4 -69.4 5,915,675.5 289,951.8 2.1 -16.78 MWD+IFR2+SAG+MS (2) 1,858.4 22.13 196.37 1,833.4 -1,694.0 -194.2 -78.8 5,915,644.0 289,941.6 3.0 -23.78 MWD+IFR2+SAG+MS (2) 1,950.4 25.01 197.33 1,917.7 -1,778.3 -229.4 -89.5 5,915,609.1 289,929.9 3.2 -31.25 MWD+IFR2+SAG+MS (2) 2,044.4 27.74 199.18 2,001.9 -1,862.5 -269.0 -102.6 5,915,569.9 289,915.7 3.0 -38.71 MWD+IFR2+SAG+MS (2) 2,138.7 30.19 200.06 2,084.4 -1,945.0 -312.1 -117.9 5,915,527.3 289,899.2 2.6 -45.83 MWD+IFR2+SAG+MS (2) 2,233.6 32.92 200.06 2,165.3 -2,025.9 -358.7 -135.0 5,915,481.1 289,880.9 2.9 -53.20 MWD+IFR2+SAG+MS (2) 2,328.6 35.67 199.99 2,243.7 -2,104.3 -409.0 -153.3 5,915,431.4 289,861.2 2.9 -61.17 MWD+IFR2+SAG+MS (2) 2,422.7 38.00 199.45 2,319.0 -2,179.6 -462.1 -172.3 5,915,378.9 289,840.7 2.5 -69.89 MWD+IFR2+SAG+MS (2) 2,517.4 40.03 200.04 2,392.6 -2,253.2 -518.2 -192.5 5,915,323.3 289,819.0 2.2 -79.06 MWD+IFR2+SAG+MS (2) 2,612.0 40.04 200.33 2,465.0 -2,325.6 -575.3 -213.4 5,915,266.8 289,796.4 0.2 -87.96 MWD+IFR2+SAG+MS (2) 2,705.4 41.35 200.39 2,535.9 -2,396.5 -632.4 -234.6 5,915,210.4 289,773.6 1.4 -96.68 MWD+IFR2+SAG+MS (2) 2,799.4 42.61 199.83 2,605.7 -2,466.3 -691.4 -256.3 5,915,151.9 289,750.4 1.4 -105.97 MWD+IFR2+SAG+MS (2) 2,894.1 43.02 200.49 2,675.2 -2,535.8 -751.8 -278.4 5,915,092.2 289,726.5 0.6 -115.40 MWD+IFR2+SAG+MS (2) 2,988.6 43.39 200.42 2,744.1 -2,604.7 -812.5 -301.0 5,915,032.2 289,702.3 0.4 -124.57 MWD+IFR2+SAG+MS (2) 3,082.0 44.15 199.44 2,811.5 -2,672.1 -873.2 -323.1 5,914,972.1 289,678.6 1.1 -134.31 MWD+IFR2+SAG+MS (2) 3,176.5 44.90 198.45 2,879.0 -2,739.6 -935.9 -344.6 5,914,910.0 289,655.3 1.1 -145.43 MWD+IFR2+SAG+MS (2) 3,270.8 45.95 198.47 2,945.1 -2,805.7 -999.6 -365.8 5,914,847.0 289,632.3 1.1 -157.24 MWD+IFR2+SAG+MS (2) 3,356.5 46.89 198.58 3,004.2 -2,864.8 -1,058.5 -385.6 5,914,788.7 289,610.9 1.1 -168.10 MWD+IFR2+SAG+MS (2) 3,466.6 46.89 199.37 3,079.5 -2,940.1 -1,134.5 -411.7 5,914,713.4 289,582.7 0.5 -181.55 MWD+IFR2+SAG+MS (3) 3,560.0 44.95 199.40 3,144.4 -3,005.0 -1,197.8 -434.0 5,914,650.7 289,558.7 2.1 -192.29 MWD+IFR2+SAG+MS (3) 3,653.4 44.44 199.90 3,210.8 -3,071.4 -1,259.7 -456.1 5,914,589.5 289,534.9 0.7 -202.51 MWD+IFR2+SAG+MS (3) 3,747.4 42.72 199.39 3,278.9 -3,139.5 -1,320.7 -477.9 5,914,529.1 289,511.4 1.9 -212.58 MWD+IFR2+SAG+MS (3) 3,842.1 42.79 198.32 3,348.4 -3,209.0 -1,381.5 -498.6 5,914,468.9 289,489.0 0.8 -223.46 MWD+IFR2+SAG+MS (3) 3,936.1 42.86 197.47 3,417.3 -3,277.9 -1,442.3 -518.3 5,914,408.7 289,467.7 0.6 -235.32 MWD+IFR2+SAG+MS (3) 4,030.9 42.58 196.76 3,487.0 -3,347.6 -1,503.8 -537.2 5,914,347.7 289,447.0 0.6 -248.13 MWD+IFR2+SAG+MS (3) 4,125.4 42.44 197.77 3,556.7 -3,417.3 -1,564.7 -556.1 5,914,287.3 289,426.4 0.7 -260.68 MWD+IFR2+SAG+MS (3) 4,220.1 42.52 197.73 3,626.5 -3,487.1 -1,625.6 -575.6 5,914,227.0 289,405.2 0.1 -272.71 MWD+IFR2+SAG+MS (3) 4,313.0 42.38 196.35 3,695.1 -3,555.7 -1,685.6 -594.0 5,914,167.6 289,385.2 1.0 -285.28 MWD+IFR2+SAG+MS (3) 4,408.1 42.46 195.49 3,765.3 -3,625.9 -1,747.3 -611.6 5,914,106.4 289,365.9 0.6 -299.35 MWD+IFR2+SAG+MS (3) 4,502.0 42.47 196.38 3,834.6 -3,695.2 -1,808.3 -629.0 5,914,045.9 289,346.8 0.6 -313.25 MWD+IFR2+SAG+MS (3) 4,596.5 42.57 197.23 3,904.2 -3,764.8 -1,869.4 -647.5 5,913,985.3 289,326.6 0.6 -326.30 MWD+IFR2+SAG+MS (3) 1212012021 6:45:59PM Page 3 COMPASS 5000.15 Build 91E r•' ConocoPhillips ConocoPhillips Definitive Survey Report Baker Hughes Company: NADConversion Local Co-ordinate Reference: Well MT7-01 Project: Western North Slope TVD Reference: WELL @ 139.4usft (Original Well Elev) Site: GMT2 Rendezvous Pad MD Reference: WELL @ 139.4usft (Original Well Elev) Well: MT7-01 North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01 Database: EDT 15 Alaska Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 4,691.0 42.60 198.09 3,973.8 -3,834.4 -1,930.3 -666.9 5,913,925.0 289,305.6 0.6 -338.43 MWD+IFR2+SAG+MS (3) 4,785.5 42.62 198.18 4,043.3 -3,903.9 -1,991.1 -686.8 5,913,864.8 289,284.0 0.1 -350.05 MWD+IFR2+SAG+MS (3) 4,880.3 42.57 197.91 4,113.1 -3,973.7 -2,052.1 -706.7 5,913,804.3 289,262.4 0.2 -361.80 MWD+IFR2+SAG+MS (3) 4,974.0 42.63 197.38 4,182.1 -4,042.7 -2,112.6 -725.9 5,913,744.4 289,241.5 0.4 -373.85 MWD+IFR2+SAG+MS (3) 5,068.5 42.58 198.30 4,251.6 -4,112.2 -2,173.4 -745.5 5,913,684.2 289,220.2 0.7 -385.79 MWD+IFR2+SAG+MS (3) 5,162.2 42.48 200.19 4,320.7 -4,181.3 -2,233.2 -766.4 5,913,624.9 289,197.7 1.4 -396.08 MWD+IFR2+SAG+MS (3) 5,255.6 42.62 200.36 4,389.5 -4,250.1 -2,292.5 -788.3 5,913,566.3 289,174.2 0.2 -405.23 MWD+IFR2+SAG+MS (3) 5,349.9 42.55 200.39 4,458.9 -4,319.5 -2,352.3 -810.5 5,913,507.2 289,150.3 0.1 -414.35 MWD+IFR2+SAG+MS (3) 5,444.2 42.56 200.58 4,528.4 -4,389.0 -2,412.1 -832.8 5,913,448.1 289,126.4 0.1 -423.35 MWD+IFR2+SAG+MS (3) 5,538.8 42.62 201.23 4,598.0 -4,458.6 -2,471.9 -855.6 5,913,388.9 289,101.9 0.5 -431.92 MWD+IFR2+SAG+MS (3) 5,632.3 42.56 202.24 4,666.9 -4,527.5 -2,530.6 -879.1 5,913,330.8 289,076.8 0.7 -439.48 MWD+IFR2+SAG+MS (3) 5,726.4 42.42 202.73 4,736.2 -4,596.8 -2,589.4 -903.4 5,913,272.8 289,050.9 0.4 -446.25 MWD+IFR2+SAG+MS (3) 5,821.2 42.60 201.50 4,806.1 -4,666.7 -2,648.7 -927.5 5,913,214.2 289,025.2 0.9 -453.48 MWD+IFR2+SAG+MS (3) 5,915.9 42.57 201.49 4,875.8 -4,736.4 -2,708.3 -950.9 5,913,155.2 289,000.0 0.0 -461.40 MWD+IFR2+SAG+MS (3) 6,010.4 42.57 201.04 4,945.4 -4,806.0 -2,767.9 -974.1 5,913,096.3 288,975.2 0.3 -469.56 MWD+IFR2+SAG+MS (3) 6,104.4 42.60 201.17 5,014.7 -4,875.3 -2,827.2 -997.0 5,913,037.6 288,950.7 0.1 -477.86 MWD+IFR2+SAG+MS (3) 6,199.0 42.35 201.25 5,084.4 -4,945.0 -2,886.8 -1,020.2 5,912,978.7 288,925.9 0.3 -486.07 MWD+IFR2+SAG+MS (3) 6,293.3 42.13 199.55 5,154.3 -5,014.9 -2,946.2 -1,042.3 5,912,919.9 288,902.1 1.2 -495.11 MWD+IFR2+SAG+MS (3) 6,387.6 42.61 198.47 5,224.0 -5,084.6 -3,006.3 -1,063.0 5,912,860.4 288,879.8 0.9 -505.70 MWD+IFR2+SAG+MS (3) 6,486.2 42.65 196.72 5,296.5 -5,157.1 -3,069.9 -1,083.1 5,912,797.4 288,857.9 1.2 -518.44 MWD+IFR2+SAG+MS (3) 6,576.6 42.60 196.32 5,363.0 -5,223.6 -3,128.6 -1,100.5 5,912,739.2 288,838.8 0.3 -531.24 MWD+IFR2+SAG+MS (3) 6,671.1 42.60 196.85 5,432.5 -5,293.1 -3,189.9 -1,118.8 5,912,678.5 288,818.9 0.4 -544.55 MWD+IFR2+SAG+MS (3) 6,766.0 42.61 197.14 5,502.4 -5,363.0 -3,251.4 -1,137.6 5,912,617.5 288,798.4 0.2 -557.49 MWD+IFR2+SAG+MS (3) 6,860.3 42.58 196.99 5,571.8 -5,432.4 -3,312.4 -1,156.3 5,912,557.1 288,778.0 0.1 -570.23 MWD+IFR2+SAG+MS (3) 6,954.1 42.58 197.61 5,640.9 -5,501.5 -3,373.0 -1,175.2 5,912,497.1 288,757.5 0.4 -582.67 MWD+IFR2+SAG+MS (3) 7,048.9 42.57 198.60 5,710.7 -5,571.3 -3,433.9 -1,195.1 5,912,436.7 288,735.8 0.7 -594.35 MWD+IFR2+SAG+MS (3) 7,143.7 42.58 199.25 5,780.6 -5,641.2 -3,494.6 -1,215.9 5,912,376.6 288,713.3 0.5 -605.13 MWD+IFR2+SAG+MS (3) 7,238.2 42.51 199.67 5,850.2 -5,710.8 -3,554.9 -1,237.2 5,912,317.0 288,690.4 0.3 -615.28 MWD+IFR2+SAG+MS (3) 7,332.5 42.49 199.39 5,919.7 -5,780.3 -3,614.9 -1,258.5 5,912,257.5 288,667.4 0.2 -625.32 MWD+IFR2+SAG+MS (3) 7,426.9 42.44 199.63 5,989.3 -5,849.9 -3,675.0 -1,279.8 5,912,198.1 288,644.5 0.2 -635.38 MWD+IFR2+SAG+MS (3) 7,521.2 42.52 199.62 6,058.9 -5,919.5 -3,735.0 -1,301.2 5,912,138.7 288,621.5 0.1 -645.32 MWD+IFR2+SAG+MS (3) 7,615.7 42.47 199.52 6,128.5 -5,989.1 -3,795.1 -1,322.6 5,912,079.2 288,598.4 0.1 -655.33 MWD+IFR2+SAG+MS (3) 7,710.0 42.30 199.72 6,198.2 -6,058.8 -3,855.0 -1,343.9 5,912,019.9 288,575.4 0.2 -665.25 MWD+IFR2+SAG+MS (3) 7,804.0 40.59 201.97 6,268.6 -6,129.2 -3,913.1 -1,366.0 5,911,962.4 288,551.7 2.4 -673.66 MWD+IFR2+SAG+MS (3) 7,897.3 38.72 207.74 6,340.5 -6,201.1 -3,967.1 -1,391.0 5,911,909.1 288,525.3 4.4 -677.60 MWD+IFR2+SAG+MS (3) 7,991.2 37.25 213.70 6,414.5 -6,275.1 -4,016.8 -1,420.4 5,911,860.3 288,494.5 4.2 -675.51 MWD+IFR2+SAG+MS (3) 8,083.7 36.17 219.37 6,488.7 -6,349.3 -4,061.2 -1,453.3 5,911,816.9 288,460.4 3.8 -667.92 MWD+IFR2+SAG+MS (3) 8,178.8 35.36 223.56 6,565.9 -6,426.5 -4,102.9 -1,490.1 5,911,776.2 288,422.5 2.7 -655.56 MWD+IFR2+SAG+MS (3) 8,272.8 34.79 228.92 6,642.8 -6,503.4 4,140.2 -1,529.0 5,911,740.0 288,382.5 3.3 -639.24 MWD+IFR2+SAG+MS (3) 8,367.5 34.28 234.52 6,720.8 -6,581.4 -4,173.4 -1,571.1 5,911,708.0 288,339.5 3.4 -618.19 MWD+IFR2+SAG+MS (3) 1212012021 6:45:59PM Page 4 COMPASS 5000.15 Build 91E r•' ConocoPhillips ConocoPhillips Definitive Survey Report Baker Hughes Company: NADConversion Local Co-ordinate Reference: Well MT7-01 Project: Western North Slope TVD Reference: WELL @ 139.4usft (Original Well Elev) Site: GMT2 Rendezvous Pad MD Reference: WELL @ 139.4usft (Original Well Elev) Well: MT7-01 North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01 Database: EDT 15 Alaska Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (ft) Survey Tool Name 8,460.8 34.10 239.76 6,798.1 -6,658.7 -4,201.9 -1,615.1 5,911,680.8 288,294.7 3.2 -593.14 MWD+IFR2+SAG+MS (3) 8,555.1 34.19 245.47 6,876.1 -6,736.7 4,226.2 -1,662.0 5,911,657.8 288,247.1 3.4 -563.58 MWD+IFR2+SAG+MS (3) 8,649.4 34.24 251.12 6,954.1 -6,814.7 4,245.7 -1,711.3 5,911,639.5 288,197.4 3.4 -529.74 MWD+IFR2+SAG+MS (3) 8,743.8 34.69 256.41 7,032.0 -6,892.6 -4,260.7 -1,762.5 5,911,626.1 288,145.7 3.2 -491.86 MWD+IFR2+SAG+MS (3) 8,837.8 35.63 262.41 7,108.8 -6,969.4 4,270.6 -1,815.7 5,911,617.6 288,092.3 3.8 -449.93 MWD+IFR2+SAG+MS (3) 8,932.0 36.73 268.25 7,184.9 -7,045.5 4,275.1 -1,871.1 5,911,614.7 288,036.8 3.8 -403.46 MWD+IFR2+SAG+MS (3) 9,026.0 37.74 273.48 7,259.7 -7,120.3 4,274.2 -1,927.9 5,911,617.1 287,980.1 3.5 -353.17 MWD+IFR2+SAG+MS (3) 9,120.1 39.12 277.79 7,333.5 -7,194.1 -4,268.4 -1,986.1 5,911,624.5 287,922.1 3.2 -299.31 MWD+IFR2+SAG+MS (3) 9,214.3 40.81 281.54 7,405.7 -7,266.3 4,258.2 -2,045.7 5,911,636.4 287,862.7 3.1 -242.06 MWD+IFR2+SAG+MS (3) 9,232.3 40.98 281.77 7,419.3 -7,279.9 4,255.8 -2,057.2 5,911,639.1 287,851.3 1.3 -230.79 MWD+IFR2+SAG+MS (4) 9,287.4 41.04 281.91 7,460.9 -7,321.5 4,248.4 -2,092.6 5,911,647.5 287,816.1 0.2 -196.18 MWD+IFR2+SAG+MS (5) 9,312.0 40.34 282.29 7,479.5 -7,340.1 -4,245.0 -2,108.3 5,911,651.3 287,800.6 3.0 -180.84 MWD+IFR2+SAG+MS (5) 9,360.6 36.53 283.90 7,517.6 -7,378.2 -4,238.2 -2,137.7 5,911,658.9 287,771.4 8.1 -151.74 MWD+IFR2+SAG+MS (5) 9,376.5 35.72 283.97 7,530.5 -7,391.1 4,236.0 -2,146.8 5,911,661.4 287,762.3 5.1 -142.64 MWD+IFR2+SAG+MS (5) 9,469.8 37.02 288.22 7,605.6 -7,466.2 -4,220.6 -2,199.9 5,911,678.2 287,709.6 3.0 -88.65 MWD+IFR2+SAG+MS (5) 9,562.2 39.68 292.53 7,678.1 -7,538.7 -4,200.6 -2,253.6 5,911,699.7 287,656.5 4.1 -31.92 MWD+IFR2+SAG+MS (5) 9,656.3 42.74 294.89 7,748.9 -7,609.5 -4,175.6 -2,310.4 5,911,726.3 287,600.5 3.6 29.83 MWD+IFR2+SAG+MS (5) 9,751.0 45.88 294.68 7,816.6 -7,677.2 -4,147.9 -2,370.4 5,911,755.6 287,541.3 3.3 95.78 MWD+IFR2+SAG+MS (5) 9,845.3 48.59 295.70 7,880.6 -7,741.2 -4,118.4 -2,433.1 5,911,786.8 287,479.4 3.0 164.94 MWD+IFR2+SAG+MS (5) 9,940.0 51.09 295.83 7,941.7 -7,802.3 -4,087.0 -2,498.2 5,911,820.1 287,415.2 2.6 237.19 MWD+IFR2+SAG+MS (5) 10,034.9 54.24 296.38 7,999.2 -7,859.8 -4,053.8 -2,565.9 5,911,855.1 287,348.4 3.4 312.56 MWD+IFR2+SAG+MS (5) 10,128.8 56.93 297.77 8,052.3 -7,912.9 -4,018.5 -2,634.9 5,911,892.3 287,280.4 3.1 390.01 MWD+IFR2+SAG+MS (5) 10,223.7 59.73 297.40 8,102.1 -7,962.7 -3,981.1 -2,706.5 5,911,931.7 287,210.0 3.0 470.71 MWD+IFR2+SAG+MS (5) 10,317.6 62.09 296.73 8,147.8 -8,008.4 -3,943.8 -2,779.6 5,911,971.0 287,137.9 2.6 552.78 MWD+IFR2+SAG+MS (5) 10,412.9 63.76 298.73 8,191.1 -8,051.7 -3,904.3 -2,854.6 5,912,012.6 287,064.0 2.6 637.58 MWD+IFR2+SAG+MS (5) 10,507.4 66.20 301.95 8,231.1 -8,091.7 -3,861.0 -2,928.5 5,912,057.9 286,991.3 4.0 723.14 MWD+IFR2+SAG+MS (5) 10,601.3 68.99 304.13 8,266.9 -8,127.5 -3,813.7 -3,001.3 5,912,107.2 286,919.9 3.7 809.72 MWD+IFR2+SAG+MS (5) 10,695.0 71.92 305.53 8,298.3 -8,158.9 -3,763.2 -3,073.8 5,912,159.6 286,848.9 3.4 897.49 MWD OWSG (6) 10,779.2 73.95 305.47 8,323.0 -8,183.6 -3,716.5 -3,139.2 5,912,208.1 286,784.7 2.4 977.32 MWD OWSG (6) 10,822.8 73.87 305.28 8,335.0 -8,195.6 -3,692.3 -3,173.4 5,912,233.3 286,751.2 0.5 1,018.93 MWD OWSG (6) 10,916.8 76.13 307.36 8,359.4 -8,220.0 -3,638.5 -3,246.6 5,912,289.2 286,679.6 3.2 1,108.97 MWD OWSG (6) 11,012.4 78.62 310.63 8,380.3 -8,240.9 -3,579.8 -3,319.0 5,912,349.8 286,608.8 4.2 1,200.67 MWD OWSG (6) 11,107.4 80.62 312.95 8,397.4 -8,258.0 -3,517.5 -3,388.7 5,912,414.0 286,540.9 3.2 1,291.63 MWD OWSG (6) 11,199.9 83.47 314.43 8,410.2 -8,270.8 -3,454.2 -3,454.9 5,912,479.1 286,476.4 3.5 1,380.08 MWD OWSG (6) 11,294.5 86.55 316.76 8,418.4 -8,279.0 -3,386.9 -3,520.9 5,912,548.2 286,412.4 4.1 1,470.17 MWD OWSG (6) 11,389.6 90.49 318.65 8,420.9 -8,281.5 -3,316.6 -3,584.8 5,912,620.3 286,350.4 4.6 1,559.99 MWD OWSG (6) 11,485.6 93.17 320.62 8,417.8 -8,278.4 -3,243.6 -3,646.9 5,912,695.0 286,290.4 3.5 1,649.49 MWD OWSG (6) 11,580.6 91.91 322.25 8,413.6 -8,274.2 -3,169.3 -3,706.1 5,912,770.9 286,233.3 2.2 1,737.00 MWD OWSG (6) 11,676.0 90.90 323.88 8,411.3 -8,271.9 -3,093.1 -3,763.4 5,912,848.7 286,178.1 2.0 1,823.81 MWD OWSG (6) 11,771.3 90.96 327.05 8,409.7 -8,270.3 -3,014.6 -3,817.4 5,912,928.6 286,126.3 3.3 1,908.77 MWD OWSG (6) 1212012021 6:45:59PM Page 5 COMPASS 5000.15 Build 91E r•' ConocoPhillips ConocoPhillips Definitive Survey Report Baker Hughes Company: NADConversion Local Co-ordinate Reference: Well MT7-01 Project: Western North Slope TVD Reference: WELL @ 139.4usft (Original Well Elev) Site: GMT2 Rendezvous Pad MD Reference: WELL @ 139.4usft (Original Well Elev) Well: MT7-01 North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01 Database: EDT 15 Alaska Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 11,866.2 90.90 330.65 8,408.2 -8,268.8 -2,933.4 -3,866.5 5,913,011.1 286,079.5 3.8 1,990.74 MWD OWSG (6) 11,961.5 91.05 332.32 8,406.6 -8,267.2 -2,849.7 -3,912.0 5,913,096.1 286,036.3 1.8 2,070.74 MWD OWSG (6) 12,056.7 91.42 333.27 8,404.5 -8,265.1 -2,765.1 -3,955.5 5,913,181.9 285,995.2 1.1 2,149.44 MWD OWSG (6) 12,151.4 91.36 333.39 8,402.2 -8,262.8 -2,680.5 -3,998.0 5,913,267.6 285,955.1 0.1 2,227.26 MWD OWSG (6) 12,246.5 91.39 332.09 8,399.9 -8,260.5 -2,595.9 -4,041.6 5,913,353.3 285,913.9 1.4 2,305.95 MWD OWSG (6) 12,340.7 91.39 332.56 8,397.6 -8,258.2 -2,512.5 -4,085.3 5,913,437.9 285,872.5 0.5 2,384.29 MWD OWSG (6) 12,436.2 91.39 332.12 8,395.3 -8,255.9 -2,427.9 -4,129.6 5,913,523.7 285,830.5 0.5 2,463.70 MWD OWSG (6) 12,528.2 91.45 333.25 8,393.0 -8,253.6 -2,346.3 -4,171.8 5,913,606.5 285,790.6 1.2 2,539.81 MWD OWSG (6) 12,622.5 90.99 334.58 8,391.0 -8,251.6 -2,261.6 -4,213.2 5,913,692.2 285,751.5 1.5 2,616.71 MWD OWSG (6) 12,713.8 91.91 333.55 8,388.7 -8,249.3 -2,179.5 -4,253.2 5,913,775.5 285,713.9 1.5 2,691.12 MWD OWSG (6) 12,807.5 91.91 333.74 8,385.6 -8,246.2 -2,095.6 -4,294.8 5,913,860.5 285,674.7 0.2 2,767.76 MWD OWSG (6) 12,902.5 91.57 333.26 8,382.7 -8,243.3 -2,010.6 -4,337.1 5,913,946.6 285,634.7 0.6 2,845.67 MWD OWSG (6) 12,996.4 91.45 333.33 8,380.2 -8,240.8 -1,926.8 -4,379.3 5,914,031.5 285,594.9 0.1 2,922.78 MWD OWSG (6) 13,092.2 90.93 333.30 8,378.3 -8,238.9 -1,841.2 -4,422.3 5,914,118.3 285,554.2 0.5 3,001.55 MWD OWSG (6) 13,186.3 90.28 334.17 8,377.3 -8,237.9 -1,756.8 -4,464.0 5,914,203.8 285,514.9 1.2 3,078.52 MWD OWSG (6) 13,280.5 89.88 333.38 8,377.1 -8,237.7 -1,672.3 -4,505.6 5,914,289.4 285,475.7 0.9 3,155.51 MWD OWSG (6) 13,374.9 89.98 333.47 8,377.2 -8,237.8 -1,587.8 -4,547.8 5,914,375.0 285,435.8 0.1 3,233.00 MWD OWSG (6) 13,469.8 89.85 333.28 8,377.4 -8,238.0 -1,503.1 -4,590.3 5,914,460.9 285,395.7 0.2 3,310.88 MWD OWSG (6) 13,564.3 89.98 332.23 8,377.5 -8,238.1 -1,419.0 -4,633.6 5,914,546.1 285,354.7 1.1 3,389.11 MWD OWSG (6) 13,658.9 89.91 332.35 8,377.6 -8,238.2 -1,335.3 -4,677.6 5,914,631.0 285,313.1 0.1 3,467.80 MWD OWSG (6) 13,753.2 89.91 332.44 8,377.8 -8,238.4 -1,251.7 -4,721.3 5,914,715.8 285,271.7 0.1 3,546.19 MWD OWSG (6) 13,846.7 89.97 332.26 8,377.9 -8,238.5 -1,168.9 -4,764.7 5,914,799.8 285,230.7 0.2 3,623.89 MWD OWSG (6) 13,940.6 89.94 332.32 8,377.9 -8,238.5 -1,085.8 -4,808.3 5,914,884.1 285,189.3 0.1 3,702.01 MWD OWSG (6) 14,035.7 89.91 332.24 8,378.1 -8,238.7 -1,001.6 -4,852.6 5,914,969.4 285,147.5 0.1 3,781.15 MWD OWSG (6) 14,129.4 89.88 332.18 8,378.2 -8,238.8 -918.7 -4,896.3 5,915,053.6 285,106.1 0.1 3,859.24 MWD OWSG (6) 14,223.4 89.91 332.19 8,378.4 -8,239.0 -835.6 -4,940.1 5,915,137.8 285,064.6 0.0 3,937.50 MWD OWSG (6) 14,318.7 89.94 331.95 8,378.5 -8,239.1 -751.3 -4,984.8 5,915,223.3 285,022.2 0.3 4,017.05 MWD OWSG (6) 14,413.2 90.44 331.98 8,378.2 -8,238.8 -667.9 -5,029.2 5,915,307.9 284,980.2 0.5 4,095.96 MWD OWSG (6) 14,506.9 91.02 331.88 8,377.0 -8,237.6 -585.3 -5,073.3 5,915,391.7 284,938.4 0.6 4,174.22 MWD OWSG (6) 14,601.1 92.09 331.82 8,374.5 -8,235.1 -502.2 -5,117.7 5,915,476.0 284,896.3 1.1 4,252.96 MWD OWSG (6) 14,695.5 92.71 333.16 8,370.5 -8,231.1 -418.6 -5,161.3 5,915,560.8 284,855.1 1.6 4,331.28 MWD OWSG (6) 14,789.1 92.80 333.77 8,366.0 -8,226.6 -334.9 -5,203.0 5,915,645.6 284,815.6 0.7 4,407.99 MWD OWSG (6) 14,881.4 92.43 333.37 8,361.8 -8,222.4 -252.3 -5,244.1 5,915,729.2 284,776.9 0.6 4,483.55 MWD OWSG (6) 14,976.2 91.79 332.86 8,358.3 -8,218.9 -167.9 -5,286.9 5,915,814.8 284,736.5 0.9 4,561.54 MWD OWSG (6) 15,068.8 92.09 333.47 8,355.2 -8,215.8 -85.3 -5,328.7 5,915,898.5 284,697.0 0.7 4,637.75 MWD OWSG (6) 15,164.2 91.97 334.04 8,351.8 -8,212.4 0.2 -5,370.9 5,915,985.2 284,657.2 0.6 4,715.74 MWD OWSG (6) 15,259.0 92.09 333.28 8,348.4 -8,209.0 85.1 -5,412.9 5,916,071.3 284,617.5 0.8 4,793.30 MWD OWSG (6) 15,353.5 91.45 332.72 8,345.5 -8,206.1 169.3 -5,455.8 5,916,156.6 284,577.0 0.9 4,871.22 MWD OWSG (6) 15,448.1 90.93 333.09 8,343.6 -8,204.2 253.4 -5,498.8 5,916,241.9 284,536.3 0.7 4,949.30 MWD OWSG (6) 15,541.7 90.99 333.62 8,342.0 -8,202.6 337.1 -5,540.8 5,916,326.7 284,496.7 0.6 5,026.23 MWD OWSG (6) 1212012021 6:45:59PM Page 6 COMPASS 5000.15 Build 91E r•' ConocoPhillips ConocoPhillips Definitive Survey Report Baker Hughes Company: NADConversion Local Co-ordinate Reference: Well MT7-01 Project: Western North Slope TVD Reference: WELL @ 139.4usft (Original Well Elev) Site: GMT2 Rendezvous Pad MD Reference: WELL @ 139.4usft (Original Well Elev) Well: MT7-01 North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01 Database: EDT 15 Alaska Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 15,635.9 90.41 333.11 8,340.8 -8,201.4 421.4 -5,583.1 5,916,412.1 284,456.8 0.8 5,103.63 MWD OWSG (6) 15,730.6 90.25 332.87 8,340.3 -8,200.9 505.7 -5,626.0 5,916,497.5 284,416.2 0.3 5,181.71 MWD OWSG (6) 15,824.8 89.91 333.37 8,340.2 -8,200.8 589.8 -5,668.7 5,916,582.8 284,375.9 0.6 5,259.39 MWD OWSG (6) 15,919.6 89.94 333.63 8,340.3 -8,200.9 674.6 -5,710.9 5,916,668.7 284,336.0 0.3 5,337.13 MWD OWSG (6) 16,014.4 90.01 333.24 8,340.3 -8,200.9 759.3 -5,753.3 5,916,754.6 284,296.0 0.4 5,414.88 MWD OWSG (6) 16,108.8 89.85 332.91 8,340.4 -8,201.0 843.5 -5,796.1 5,916,840.0 284,255.6 0.4 5,492.76 MWD OWSG (6) 16,202.5 89.85 333.68 8,340.7 -8,201.3 927.2 -5,838.2 5,916,924.8 284,215.8 0.8 5,569.78 MWD OWSG (6) 16,297.6 89.91 333.39 8,340.9 -8,201.5 1,012.3 -5,880.5 5,917,011.0 284,175.8 0.3 5,647.70 MWD OWSG (6) 16,390.7 89.88 333.06 8,341.1 -8,201.7 1,095.4 -5,922.5 5,917,095.3 284,136.2 0.4 5,724.31 MWD OWSG (6) 16,486.0 90.13 333.04 8,341.0 -8,201.6 1,180.4 -5,965.7 5,917,181.4 284,095.4 0.3 5,802.88 MWD OWSG (6) 16,581.1 89.91 333.24 8,341.0 -8,201.6 1,265.3 -6,008.7 5,917,267.4 284,054.8 0.3 5,881.27 MWD OWSG (6) 16,674.6 89.85 333.37 8,341.2 -8,201.8 1,348.8 -6,050.7 5,917,352.0 284,015.1 0.2 5,958.09 MWD OWSG (6) 16,768.8 89.94 333.36 8,341.4 -8,202.0 1,433.0 -6,092.9 5,917,437.4 283,975.2 0.1 6,035.53 MWD OWSG (6) 16,863.2 89.88 333.79 8,341.5 -8,202.1 1,517.5 -6,134.9 5,917,523.0 283,935.6 0.5 6,112.83 MWD OWSG (6) 16,958.5 89.88 332.13 8,341.7 -8,202.3 1,602.4 -6,178.2 5,917,609.1 283,894.6 1.7 6,191.53 MWD OWSG (6) 17,052.5 90.37 331.97 8,341.5 -8,202.1 1,685.4 -6,222.3 5,917,693.3 283,852.9 0.5 6,269.94 MWD OWSG (6) 17,147.4 91.36 331.84 8,340.1 -8,200.7 1,769.2 -6,267.0 5,917,778.3 283,810.5 1.1 6,349.26 MWD OWSG (6) 17,241.7 92.09 331.69 8,337.3 -8,197.9 1,852.2 -6,311.6 5,917,862.5 283,768.3 0.8 6,428.12 MWD OWSG (6) 17,336.2 92.13 331.80 8,333.8 -8,194.4 1,935.4 -6,356.3 5,917,946.9 283,725.9 0.1 6,507.21 MWD OWSG (6) 17,430.8 92.95 332.13 8,329.6 -8,190.2 2,018.8 -6,400.7 5,918,031.5 283,683.8 0.9 6,586.13 MWD OWSG (6) 17,525.3 92.89 332.57 8,324.8 -8,185.4 2,102.4 -6,444.5 5,918,116.3 283,642.4 0.5 6,664.63 MWD OWSG (6) 17,619.9 92.43 333.72 8,320.4 -8,181.0 2,186.7 -6,487.2 5,918,201.7 283,602.0 1.3 6,742.47 MWD OWSG (6) 17,714.3 92.95 333.89 8,315.9 -8,176.5 2,271.3 -6,528.8 5,918,287.5 283,562.8 0.6 6,819.52 MWD OWSG (6) 17,809.1 92.83 333.89 8,311.2 -8,171.8 2,356.3 -6,570.5 5,918,373.6 283,523.5 0.1 6,896.77 MWD OWSG (6) 17,903.1 91.97 333.54 8,307.2 -8,167.8 2,440.5 -6,612.0 5,918,458.9 283,484.3 1.0 6,973.56 MWD OWSG (6) 17,999.4 90.93 333.29 8,304.8 -8,165.4 2,526.7 -6,655.2 5,918,546.2 283,443.6 1.1 7,052.65 MWD OWSG (6) 18,091.0 90.90 333.38 8,303.3 -8,163.9 2,608.5 -6,696.3 5,918,629.1 283,404.8 0.1 7,127.91 MWD OWSG (6) 18,161.7 93.34 337.35 8,300.7 -8,161.3 2,672.7 -6,725.7 5,918,694.1 283,377.1 6.6 7,184.50 MWD OWSG (6) 18,255.9 91.66 336.68 8,296.6 -8,157.2 2,759.3 -6,762.5 5,918,781.8 283,342.8 1.9 7,258.23 MWD OWSG (6) 18,350.0 89.36 334.40 8,295.8 -8,156.4 2,844.9 -6,801.4 5,918,868.4 283,306.2 3.4 7,333.38 MWD OWSG (6) 18,444.1 89.85 333.30 8,296.4 -8,157.0 2,929.4 -6,842.8 5,918,953.9 283,267.1 1.3 7,410.21 MWD OWSG (6) 18,538.3 89.67 333.11 8,296.8 -8,157.4 3,013.5 -6,885.3 5,919,039.2 283,227.0 0.3 7,487.74 MWD OWSG (6) 18,632.9 90.13 333.80 8,297.0 -8,157.6 3,098.1 -6,927.6 5,919,125.0 283,187.1 0.9 7,565.38 MWD OWSG (6) 18,727.7 90.65 337.01 8,296.3 -8,156.9 3,184.3 -6,967.0 5,919,212.2 283,150.1 3.4 7,641.25 MWD OWSG (6) 18,822.5 92.49 340.22 8,293.7 -8,154.3 3,272.5 -7,001.6 5,919,301.3 283,118.0 3.9 7,713.84 MWD OWSG (6) 18,916.0 90.87 339.17 8,291.0 -8,151.6 3,360.2 -7,034.0 5,919,389.9 283,088.0 2.1 7,784.28 MWD OWSG (6) 19,010.4 87.86 336.97 8,292.0 -8,152.6 3,447.7 -7,069.3 5,919,478.3 283,055.2 4.0 7,857.10 MWD OWSG (6) 19,104.1 88.04 333.03 8,295.4 -8,156.0 3,532.6 -7,108.8 5,919,564.3 283,018.0 4.2 7,932.47 MWD OWSG (6) 19,197.1 87.95 332.54 8,298.6 -8,159.2 3,615.3 -7,151.4 5,919,648.1 282,977.8 0.5 8,009.38 MWD OWSG (6) 19,291.8 89.91 332.36 8,300.4 -8,161.0 3,699.1 -7,195.1 5,919,733.2 282,936.4 2.1 8,087.96 MWD OWSG (6) 1212012021 6:45:59PM Page 7 COMPASS 5000.15 Build 91E r•' ConocoPhillips ConocoPhillips Definitive Survey Report Baker Hughes Company: NADConversion Local Co-ordinate Reference: Well MT7-01 Project: Western North Slope TVD Reference: WELL @ 139.4usft (Original Well Elev) Site: GMT2 Rendezvous Pad MD Reference: WELL @ 139.4usft (Original Well Elev) Well: MT7-01 North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01 Database: EDT 15 Alaska Prod Survey MD Inc Azi TVD TVDSS (usft) (1) (1) (usft) (usft) 19,386.1 90.44 332.84 8,300.1 -8,160.7 19,480.9 90.40 331.82 8,299.4 -8,160.0 19,575.6 91.97 332.23 8,297.5 -8,158.1 19,611.3 91.94 332.41 8,296.3 -8,156.9 19,645.0 91.94 332.41 8,295.1 • -8,155.7 Map +N/-S +EI-W Northing (usft) (usft) (ft) 3,782.9 -7,238.5 5,919,818.0 3,866.9 -7,282.6 5,919,903.3 3,950.5 -7,327.0 5,919,988.1 3,982.1 -7,343.6 5,920,020.1 4,011.9 -7,359.1 5,920,050.3 Map Vertical Easting DLS Section (ft) (°/100-) (ft) Survey Tool Name 282,895.3 0.8 8,166.13 MWD OWSG (6) 282,853.6 1.1 8,245.04 MWD OWSG (6) 282,811.5 1.7 8,324.04 MWD OWSG (6) 282,795.9 0.5 8,353.70 MWD OWSG (6) 282,781.1 0.0 8,381.67 PROJECTED to TD 1212012021 6:45:59PM Page 8 COMPASS 5000.15 Build 91E NADConversion Western North Slope GMT2 Rendezvous Pad MT7-01 PB1 ConocoPhillips Definitive Survey Report 20 December, 2021 Ili M Mr- ConocoPhillips r•' ConocoPhillips CowcoPhillips Definitive Survey Report Baker Hughes Company: NADConversion Local Co-ordinate Reference: Well MT7-01 Project: Western North Slope TVD Reference: WELL @ 139.4usft (Original Well Elev) Site: GMT2 Rendezvous Pad MD Reference: WELL @ 139.4usft (Original Well Elev) Well: MT7-01 North Reference: True Wellbore: MT7-01 PB1 Survey Calculation Method: Minimum Curvature Design: MT7-01 PB1 Database: EDT 15 Alaska Prod Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well MT7-01 Well Position +N/-S 0.0 usft Northing: 5,915,835.96 usft Latitude: 70° 10' 23.950 N +E/-W 0.0 usft Easting: 290,025.72 usft Longitude: 151° 41' 25.142 W Position Uncertainty 0.0 usft Wellhead Elevation: usft Ground Level: 100.7usft Wellbore MT7-01PB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (1) (nT) BGGM2021 12/20/2021 14.67 80.40 57,142.84466532 Design MT7-01 P131 • Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 38.7 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (1) 38.7 0.0 0.0 221.29 Survey Program Date 12/20/2021 "w"w From To (usft) (usft) Survey (Wellbore) Tool Name Description Survey Date 110.5 1,266.9 MT7-01PB1 Srvy 1 -Gyro (MT7-01PB1) SDI_Keeper_ADK SDI Keeper All -Attitude Drop Keeper 1.1 10/20/2021 8:1E 822.3 3,356.5 MT7-01 PB1 Srvy 2 - BH MWD IFR + SA MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correc110/21/2021 9:3f 3,356.5 9,232.3 MT7-01 PB1 Srvy 3 - BH MWD IFR + SA MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correc110/21/2021 9:4( 9,232.3 10,814.5 MT7-01PB1 Srvy 4 - BH MWD IFR + SA MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correc110/27/2021 9:1f Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (1) (1) (usft) (usft) (usft) (usft) (ft) (ft) (°/100.) (ft) Survey Tool Name 38.7 0.00 0.00 38.7 100.7 0.0 0.0 5,915,836.0 290,025.7 0.0 0.00 UNDEFINED 110.5 0.26 249.90 110.5 28.9 -0.1 -0.2 5,915,835.9 290,025.6 0.4 0.14 SDI_Keeper_ADK(1) 205.8 0.35 260.16 205.8 -66.4 -0.2 -0.6 5,915,835.8 290,025.1 0.1 0.56 SDI_Keeper_ADK(1) 237.6 0.44 263.32 237.6 -98.2 -0.2 -0.9 5,915,835.8 290,024.8 0.3 0.73 SDI_Keeper_ADK(1) 329.6 0.62 268.95 329.6 -190.2 -0.3 -1.7 5,915,835.7 290,024.0 0.2 1.32 SDI_Keeper_ADK(1) 421.5 0.79 270.70 421.5 -282.1 -0.3 -2.8 5,915,835.8 290,022.9 0.2 2.07 SDI_Keeper_ADK(1) 514.4 1.14 271.76 514.4 -375.0 -0.2 -4.4 5,915,835.9 290,021.3 0.4 3.08 SDI_Keeper_ADK(1) 608.8 1.58 278.44 608.7 -469.3 0.0 -6.6 5,915,836.1 290,019.1 0.5 4.38 SDI_Keeper_ADK(1) 702.8 1.76 261.91 702.7 -563.3 0.0 -9.3 5,915,836.2 290,016.4 0.5 6.18 SDI_Keeper_ADK(1) 796.5 2.29 237.30 796.4 -657.0 -1.2 -12.3 5,915,835.1 290,013.3 1.1 9.07 SDI_Keeper_ADK(1) 822.3 2.54 235.13 822.2 -682.8 -1.8 -13.2 5,915,834.5 290,012.4 1.0 10.12 MWD+IFR2+SAG+MS (2) 1212012021 6:51:16PM Page 2 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillllps Definitive Survey Report Baker Hughes Company: NADConversion Local Co-ordinate Reference: Well MT7-01 Project: Western North Slope TVD Reference: WELL @ 139.4usft (Original Well Elev) Site: GMT2 Rendezvous Pad MD Reference: WELL @ 139.4usft (Original Well Elev) Well: MT7-01 North Reference: True Wellbore: MT7-01 P61 Survey Calculation Method: Minimum Curvature Design: MT7-01 P61 Database: EDT 15 Alaska Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 916.8 4.17 211.72 916.4 -777.0 -6.0 -16.8 5,915,830.5 290,008.8 2.2 15.54 MWD+IFR2+SAG+MS (2) 1,011.0 5.84 204.87 1,010.3 -870.9 -13.2 -20.6 5,915,823.3 290,004.8 1.9 23.51 MWD+IFR2+SAG+MS (2) 1,104.3 7.54 203.40 1,102.9 -963.5 -23.1 -25.0 5,915,813.5 290,000.1 1.8 33.89 MWD+IFR2+SAG+MS (2) 1,292.7 10.21 199.93 1,289.1 -1,149.7 -50.2 -35.6 5,915,786.8 289,988.7 1.4 61.22 MWD+IFR2+SAG+MS (2) 1,386.5 11.35 198.91 1,381.2 -1,241.8 -66.7 -41.4 5,915,770.4 289,982.4 1.2 77.49 MWD+IFR2+SAG+MS (2) 1,482.7 13.53 197.63 1,475.2 -1,335.8 -86.4 -47.9 5,915,750.9 289,975.4 2.3 96.56 MWD+IFR2+SAG+MS (2) 1,576.2 15.03 195.24 1,565.8 -1,426.4 -108.5 -54.4 5,915,729.0 289,968.3 1.7 117.46 MWD+IFR2+SAG+MS (2) 1,670.0 17.36 195.26 1,655.8 -1,516.4 -133.8 -61.3 5,915,703.9 289,960.7 2.5 140.97 MWD+IFR2+SAG+MS (2) 1,764.8 19.29 196.42 1,745.8 -1,606.4 -162.4 -69.4 5,915,675.5 289,951.8 2.1 167.88 MWD+IFR2+SAG+MS (2) 1,858.4 22.13 196.37 1,833.4 -1,694.0 -194.2 -78.8 5,915,644.0 289,941.6 3.0 197.92 MWD+IFR2+SAG+MS (2) 1,950.4 25.01 197.33 1,917.7 -1,778.3 -229.4 -89.5 5,915,609.1 289,929.9 3.2 231.41 MWD+IFR2+SAG+MS (2) 2,044.4 27.74 199.18 2,001.9 -1,862.5 -269.0 -102.6 5,915,569.9 289,915.7 3.0 269.82 MWD+IFR2+SAG+MS (2) 2,138.7 30.19 200.06 2,084.4 -1,945.0 -312.1 -117.9 5,915,527.3 289,899.2 2.6 312.29 MWD+IFR2+SAG+MS (2) 2,233.6 32.92 200.06 2,165.3 -2,025.9 -358.7 -135.0 5,915,481.1 289,880.9 2.9 358.59 MWD+IFR2+SAG+MS (2) 2,328.6 35.67 199.99 2,243.7 -2,104.3 -409.0 -153.3 5,915,431.4 289,861.2 2.9 408.43 MWD+IFR2+SAG+MS (2) 2,422.7 38.00 199.45 2,319.0 -2,179.6 -462.1 -172.3 5,915,378.9 289,840.7 2.5 460.88 MWD+IFR2+SAG+MS (2) 2,517.4 40.03 200.04 2,392.6 -2,253.2 -518.2 -192.5 5,915,323.3 289,819.0 2.2 516.36 MWD+IFR2+SAG+MS (2) 2,612.0 40.04 200.33 2,465.0 -2,325.6 -575.3 -213.4 5,915,266.8 289,796.4 0.2 573.10 MWD+IFR2+SAG+MS (2) 2,705.4 41.35 200.39 2,535.9 -2,396.5 -632.4 -234.6 5,915,210.4 289,773.6 1.4 629.99 MWD+IFR2+SAG+MS (2) 2,799.4 42.61 199.83 2,605.7 -2,466.3 -691.4 -256.3 5,915,151.9 289,750.4 1.4 688.61 MWD+IFR2+SAG+MS (2) 2,894.1 43.02 200.49 2,675.2 -2,535.8 -751.8 -278.4 5,915,092.2 289,726.5 0.6 748.62 MWD+IFR2+SAG+MS (2) 2,988.6 43.39 200.42 2,744.1 -2,604.7 -812.5 -301.0 5,915,032.2 289,702.3 0.4 809.12 MWD+IFR2+SAG+MS (2) 3,082.0 44.15 199.44 2,811.5 -2,672.1 -873.2 -323.1 5,914,972.1 289,678.6 1.1 869.28 MWD+IFR2+SAG+MS (2) 3,176.5 44.90 198.45 2,879.0 -2,739.6 -935.9 -344.6 5,914,910.0 289,655.3 1.1 930.60 MWD+IFR2+SAG+MS (2) 3,270.8 45.95 198.47 2,945.1 -2,805.7 -999.6 -365.8 5,914,847.0 289,632.3 1.1 992.45 MWD+IFR2+SAG+MS (2) 3,356.5 46.89 198.58 3,004.2 -2,864.8 -1,058.5 -385.6 5,914,788.7 289,610.9 1.1 1,049.71 MWD+IFR2+SAG+MS (2) 3,466.6 46.89 199.37 3,079.5 -2,940.1 -1,134.5 -411.7 5,914,713.4 289,582.7 0.5 1,124.11 MWD+IFR2+SAG+MS (3) 3,560.0 44.95 199.40 3,144.4 -3,005.0 -1,197.8 -434.0 5,914,650.7 289,558.7 2.1 1,186.35 MWD+IFR2+SAG+MS (3) 3,653.4 44.44 199.90 3,210.8 -3,071.4 -1,259.7 -456.1 5,914,589.5 289,534.9 0.7 1,247.41 MWD+IFR2+SAG+MS (3) 3,747.4 42.72 199.39 3,278.9 -3,139.5 -1,320.7 -477.9 5,914,529.1 289,511.4 1.9 1,307.62 MWD+IFR2+SAG+MS (3) 3,842.1 42.79 198.32 3,348.4 -3,209.0 -1,381.5 -498.6 5,914,468.9 289,489.0 0.8 1,367.05 MWD+IFR2+SAG+MS (3) 3,936.1 42.86 197.47 3,417.3 -3,277.9 -1,442.3 -518.3 5,914,408.7 289,467.7 0.6 1,425.66 MWD+IFR2+SAG+MS (3) 4,030.9 42.58 196.76 3,487.0 -3,347.6 -1,503.8 -537.2 5,914,347.7 289,447.0 0.6 1,484.36 MWD+IFR2+SAG+MS (3) 4,125.4 42.44 197.77 3,556.7 -3,417.3 -1,564.7 -556.1 5,914,287.3 289,426.4 0.7 1,542.68 MWD+IFR2+SAG+MS (3) 4,220.1 42.52 197.73 3,626.5 -3,487.1 -1,625.6 -575.6 5,914,227.0 289,405.2 0.1 1,601.29 MWD+IFR2+SAG+MS (3) 4,313.0 42.38 196.35 3,695.1 -3,555.7 -1,685.6 -594.0 5,914,167.6 289,385.2 1.0 1,658.50 MWD+IFR2+SAG+MS (3) 4,408.1 42.46 195.49 3,765.3 -3,625.9 -1,747.3 -611.6 5,914,106.4 289,365.9 0.6 1,716.43 MWD+IFR2+SAG+MS (3) 4,502.0 42.47 196.38 3,834.6 -3,695.2 -1,808.3 -629.0 5,914,045.9 289,346.8 0.6 1,773.73 MWD+IFR2+SAG+MS (3) 4,596.5 42.57 197.23 3,904.2 -3,764.8 -1,869.4 -647.5 5,913,985.3 289,326.6 0.6 1,831.85 MWD+IFR2+SAG+MS (3) 4,691.0 42.60 198.09 3,973.8 -3,834.4 -1,930.3 -666.9 5,913,925.0 289,305.6 0.6 1,890.41 MWD+IFR2+SAG+MS (3) 1212012021 6:51:16PM Page 3 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillllps Definitive Survey Report Baker Hughes Company: NADConversion Local Co-ordinate Reference: Well MT7-01 Project: Western North Slope TVD Reference: WELL @ 139.4usft (Original Well Elev) Site: GMT2 Rendezvous Pad MD Reference: WELL @ 139.4usft (Original Well Elev) Well: MT7-01 North Reference: True Wellbore: MT7-01 P61 Survey Calculation Method: Minimum Curvature Design: MT7-01 P61 Database: EDT 15 Alaska Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (1) (usft) (usft) (usft) (usft) (ft) (ft) (-/100-) (ft) Survey Tool Name 4,785.5 42.62 198.18 4,043.3 -3,903.9 -1,991.1 -686.8 5,913,864.8 289,284.0 0.1 1,949.25 MWD+IFR2+SAG+MS (3) 4,880.3 42.57 197.91 4,113.1 -3,973.7 -2,052.1 -706.7 5,913,804.3 289,262.4 0.2 2,008.23 MWD+IFR2+SAG+MS (3) 4,974.0 42.63 197.38 4,182.1 -4,042.7 -2,112.6 -725.9 5,913,744.4 289,241.5 0.4 2,066.32 MWD+IFR2+SAG+MS (3) 5,068.5 42.58 198.30 4,251.6 -4,112.2 -2,173.4 -745.5 5,913,684.2 289,220.2 0.7 2,124.97 MWD+IFR2+SAG+MS (3) 5,162.2 42.48 200.19 4,320.7 -4,181.3 -2,233.2 -766.4 5,913,624.9 289,197.7 1.4 2,183.69 MWD+IFR2+SAG+MS (3) 5,255.6 42.62 200.36 4,389.5 -4,250.1 -2,292.5 -788.3 5,913,566.3 289,174.2 0.2 2,242.67 MWD+IFR2+SAG+MS (3) 5,349.9 42.55 200.39 4,458.9 -4,319.5 -2,352.3 -810.5 5,913,507.2 289,150.3 0.1 2,302.26 MWD+IFR2+SAG+MS (3) 5,444.2 42.56 200.58 4,528.4 -4,389.0 -2,412.1 -832.8 5,913,448.1 289,126.4 0.1 2,361.87 MWD+IFR2+SAG+MS (3) 5,538.8 42.62 201.23 4,598.0 -4,458.6 -2,471.9 -855.6 5,913,388.9 289,101.9 0.5 2,421.89 MWD+IFR2+SAG+MS (3) 5,632.3 42.56 202.24 4,666.9 -4,527.5 -2,530.6 -879.1 5,913,330.8 289,076.8 0.7 2,481.51 MWD+IFR2+SAG+MS (3) 5,726.4 42.42 202.73 4,736.2 -4,596.8 -2,589.4 -903.4 5,913,272.8 289,050.9 0.4 2,541.65 MWD+IFR2+SAG+MS (3) 5,821.2 42.60 201.50 4,806.1 -4,666.7 -2,648.7 -927.5 5,913,214.2 289,025.2 0.9 2,602.15 MWD+IFR2+SAG+MS (3) 5,915.9 42.57 201.49 4,875.8 -4,736.4 -2,708.3 -950.9 5,913,155.2 289,000.0 0.0 2,662.44 MWD+IFR2+SAG+MS (3) 6,010.4 42.57 201.04 4,945.4 -4,806.0 -2,767.9 -974.1 5,913,096.3 288,975.2 0.3 2,722.50 MWD+IFR2+SAG+MS (3) 6,104.4 42.60 201.17 5,014.7 -4,875.3 -2,827.2 -997.0 5,913,037.6 288,950.7 0.1 2,782.22 MWD+IFR2+SAG+MS (3) 6,199.0 42.35 201.25 5,084.4 -4,945.0 -2,886.8 -1,020.2 5,912,978.7 288,925.9 0.3 2,842.21 MWD+IFR2+SAG+MS (3) 6,293.3 42.13 199.55 5,154.3 -5,014.9 -2,946.2 -1,042.3 5,912,919.9 288,902.1 1.2 2,901.47 MWD+IFR2+SAG+MS (3) 6,387.6 42.61 198.47 5,224.0 -5,084.6 -3,006.3 -1,063.0 5,912,860.4 288,879.8 0.9 2,960.26 MWD+IFR2+SAG+MS (3) 6,486.2 42.65 196.72 5,296.5 -5,157.1 -3,069.9 -1,083.1 5,912,797.4 288,857.9 1.2 3,021.39 MWD+IFR2+SAG+MS (3) 6,576.6 42.60 196.32 5,363.0 -5,223.6 -3,128.6 -1,100.5 5,912,739.2 288,838.8 0.3 3,076.95 MWD+IFR2+SAG+MS (3) 6,671.1 42.60 196.85 5,432.5 -5,293.1 -3,189.9 -1,118.8 5,912,678.5 288,818.9 0.4 3,135.06 MWD+IFR2+SAG+MS (3) 6,766.0 42.61 197.14 5,502.4 -5,363.0 -3,251.4 -1,137.6 5,912,617.5 288,798.4 0.2 3,193.66 MWD+IFR2+SAG+MS (3) 6,860.3 42.58 196.99 5,571.8 -5,432.4 -3,312.4 -1,156.3 5,912,557.1 288,778.0 0.1 3,251.82 MWD+IFR2+SAG+MS (3) 6,954.1 42.58 197.61 5,640.9 -5,501.5 -3,373.0 -1,175.2 5,912,497.1 288,757.5 0.4 3,309.81 MWD+IFR2+SAG+MS (3) 7,048.9 42.57 198.60 5,710.7 -5,571.3 -3,433.9 -1,195.1 5,912,436.7 288,735.8 0.7 3,368.78 MWD+IFR2+SAG+MS (3) 7,143.7 42.58 199.25 5,780.6 -5,641.2 -3,494.6 -1,215.9 5,912,376.6 288,713.3 0.5 3,428.12 MWD+IFR2+SAG+MS (3) 7,238.2 42.51 199.67 5,850.2 -5,710.8 -3,554.9 -1,237.2 5,912,317.0 288,690.4 0.3 3,487.42 MWD+IFR2+SAG+MS (3) 7,332.5 42.49 199.39 5,919.7 -5,780.3 -3,614.9 -1,258.5 5,912,257.5 288,667.4 0.2 3,546.59 MWD+IFR2+SAG+MS (3) 7,426.9 42.44 199.63 5,989.3 -5,849.9 -3,675.0 -1,279.8 5,912,198.1 288,644.5 0.2 3,605.73 MWD+IFR2+SAG+MS (3) 7,521.2 42.52 199.62 6,058.9 -5,919.5 -3,735.0 -1,301.2 5,912,138.7 288,621.5 0.1 3,664.96 MWD+IFR2+SAG+MS (3) 7,615.7 42.47 199.52 6,128.5 -5,989.1 -3,795.1 -1,322.6 5,912,079.2 288,598.4 0.1 3,724.24 MWD+IFR2+SAG+MS (3) 7,710.0 42.30 199.72 6,198.2 -6,058.8 -3,855.0 -1,343.9 5,912,019.9 288,575.4 0.2 3,783.31 MWD+IFR2+SAG+MS (3) 7,804.0 40.59 201.97 6,268.6 -6,129.2 -3,913.1 -1,366.0 5,911,962.4 288,551.7 2.4 3,841.59 MWD+IFR2+SAG+MS (3) 7,897.3 38.72 207.74 6,340.5 -6,201.1 -3,967.1 -1,391.0 5,911,909.1 288,525.3 4.4 3,898.64 MWD+IFR2+SAG+MS (3) 7,991.2 37.25 213.70 6,414.5 -6,275.1 -4,016.8 -1,420.4 5,911,860.3 288,494.5 4.2 3,955.37 MWD+IFR2+SAG+MS (3) 8,083.7 36.17 219.37 6,488.7 -6,349.3 -4,061.2 -1,453.3 5,911,816.9 288,460.4 3.8 4,010.43 MWD+IFR2+SAG+MS (3) 8,178.8 35.36 223.56 6,565.9 -6,426.5 -4,102.9 -1,490.1 5,911,776.2 288,422.5 2.7 4,066.00 MWD+IFR2+SAG+MS (3) 8,272.8 34.79 228.92 6,642.8 -6,503.4 -4,140.2 -1,529.0 5,911,740.0 288,382.5 3.3 4,119.72 MWD+IFR2+SAG+MS (3) 8,367.5 34.28 234.52 6,720.8 -6,581.4 4,173.4 -1,571.1 5,911,708.0 288,339.5 3.4 4,172.47 MWD+IFR2+SAG+MS (3) 8,460.8 34.10 239.76 6,798.1 -6,658.7 -4,201.9 -1,615.1 5,911,680.8 288,294.7 3.2 4,222.91 MWD+IFR2+SAG+MS (3) 1212012021 6:51:16PM Page 4 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Definitive Survey Report Baker Hughes Company: NADConversion Local Co-ordinate Reference: Well MT7-01 Project: Western North Slope TVD Reference: WELL @ 139.4usft (Original Well Elev) Site: GMT2 Rendezvous Pad MD Reference: WELL @ 139.4usft (Original Well Elev) Well: MT7-01 North Reference: True Wellbore: MT7-01 P131 Survey Calculation Method: Minimum Curvature Design: MT7-01 P131 Database: EDT 15 Alaska Prod Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) V) (usft) (usft) (usft) (usft) (ft) (ft) (°/100-) (ft) Survey Tool Name 8,555.1 34.19 245.47 6,876.1 -6,736.7 -4,226.2 -1,662.0 5,911,657.8 288,247.1 3.4 4,272.14 MWD+IFR2+SAG+MS (3) 8,649.4 34.24 251.12 6,954.1 -6,814.7 4,245.7 -1,711.3 5,911,639.5 288,197.4 3.4 4,319.34 MWD+IFR2+SAG+MS (3) 8,743.8 34.69 256.41 7,032.0 -6,892.6 -4,260.7 -1,762.5 5,911,626.1 288,145.7 3.2 4,364.38 MWD+IFR2+SAG+MS (3) 8,837.8 35.63 262.41 7,108.8 -6,969.4 -4,270.6 -1,815.7 5,911,617.6 288,092.3 3.8 4,406.89 MWD+IFR2+SAG+MS (3) 8,932.0 36.73 268.25 7,184.9 -7,045.5 -4,275.1 -1,871.1 5,911,614.7 288,036.8 3.8 4,446.81 MWD+IFR2+SAG+MS (3) 9,026.0 37.74 273.48 7,259.7 -7,120.3 -4,274.2 -1,927.9 5,911,617.1 287,980.1 3.5 4,483.62 MWD+IFR2+SAG+MS (3) 9,120.1 39.12 277.79 7,333.5 -7,194.1 -4,268.4 -1,986.1 5,911,624.5 287,922.1 3.2 4,517.68 MWD+IFR2+SAG+MS (3) 9,214.3 40.81 281.54 7,405.7 -7,266.3 -4,258.2 -2,045.7 5,911,636.4 287,862.7 3.1 4,549.38 MWD+IFR2+SAG+MS (3) 9,232.3 40.98 281.77 7,419.3 -7,279.9 -4,255.8 -2,057.2 5,911,639.1 287,851.3 1.3 4,555.21 MWD+IFR2+SAG+MS (4) 9,287.4 41.04 281.91 7,460.9 -7,321.5 -4,248.4 -2,092.6 5,911,647.5 287,816.1 0.2 4,572.98 MWD+IFR2+SAG+MS (4) 9,379.3 41.18 284.25 7,530.1 -7,390.7 -4,234.7 -2,151.5 5,911,662.8 287,757.7 1.7 4,601.54 MWD+IFR2+SAG+MS (4) 9,471.5 42.36 286.06 7,598.9 -7,459.5 -4,218.7 -2,210.7 5,911,680.5 287,698.9 1.8 4,628.58 MWD+IFR2+SAG+MS (4) 9,566.7 44.58 289.82 7,668.0 -7,528.6 -4,198.5 -2,273.0 5,911,702.4 287,637.2 3.6 4,654.47 MWD+IFR2+SAG+MS (4) 9,658.3 47.45 292.18 7,731.6 -7,592.2 4,174.8 -2,334.5 5,911,727.7 287,576.4 3.6 4,677.29 MWD+IFR2+SAG+MS (4) 9,753.2 49.87 294.04 7,794.3 -7,654.9 4,146.8 -2,400.0 5,911,757.5 287,511.7 2.9 4,699.51 MWD+IFR2+SAG+MS (4) 9,848.8 51.81 295.16 7,854.6 -7,715.2 -4,116.0 -2,467.4 5,911,790.3 287,445.2 2.2 4,720.79 MWD+IFR2+SAG+MS (4) 9,942.7 53.47 296.08 7,911.6 -7,772.2 -4,083.7 -2,534.7 5,911,824.4 287,378.8 1.9 4,740.94 MWD+IFR2+SAG+MS (4) 10,036.8 55.34 297.72 7,966.4 -7,827.0 4,049.1 -2,602.9 5,911,860.9 287,311.6 2.4 4,759.95 MWD+IFR2+SAG+MS (4) 10,129.9 57.57 298.31 8,017.9 -7,878.5 4,012.6 -2,671.4 5,911,899.2 287,244.1 2.5 4,777.77 MWD+IFR2+SAG+MS (4) 10,225.2 59.70 299.61 8,067.4 -7,928.0 -3,973.2 -2,742.6 5,911,940.6 287,174.1 2.5 4,795.12 MWD+IFR2+SAG+MS (4) 10,318.7 61.86 300.83 8,113.1 -7,973.7 -3,932.1 -2,813.1 5,911,983.6 287,104.8 2.6 4,810.78 MWD+IFR2+SAG+MS (4) 10,415.0 63.85 301.96 8,157.0 -8,017.6 -3,887.5 -2,886.3 5,912,030.3 287,032.8 2.3 4,825.51 MWD+IFR2+SAG+MS (4) 10,507.8 66.01 303.01 8,196.4 -8,057.0 -3,842.3 -2,957.2 5,912,077.4 286,963.2 2.5 4,838.37 MWD+IFR2+SAG+MS (4) 10,601.7 67.99 303.95 8,233.0 -8,093.6 -3,794.6 -3,029.3 5,912,127.0 286,892.5 2.3 4,850.12 MWD+IFR2+SAG+MS (4) 10,697.1 70.19 304.52 8,267.1 -8,127.7 -3,744.5 -3,102.9 5,912,179.2 286,820.3 2.4 4,861.06 MWD+IFR2+SAG+MS (4) 10,791.8 72.09 305.60 8,297.7 -8,158.3 -3,693.0 -3,176.3 5,912,232.7 286,748.4 2.3 4,870.78 MWD+IFR2+SAG+MS (4) 10,814.5 72.60 305.95 8,304.6 -8,165.2 -3,680.4 -3,193.7 5,912,245.8 286,731.2 2.7 4,872.85 MWD+IFR2+SAG+MS (4) 10,845.0 72.60 305.95 8,313.7 -8,174.3 -3,663.3 -3,217.3 5,912,263.5 286,708.1 0.0 4,875.57 PROJECTED to TD 1212012021 6:51:16PM Page 5 COMPASS 5000.15 Build 91E Cement Detail Report MT7-01 String: Surface String Cement Job: DRILLING ORIGINAL, 10/10/2021 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface String Cement 10/15/2021 22:02 10/16/2021 01:56 1 MT7-01 Comment Performed cement job. Pressure tested surface lines to 3,500 psi (Good test). Pump sequence was as follows: 104 bbls of 11 ppg Mud Push ll, Dropped bottom plug, 480 bbls of 11 ppg Lead Cement, 73 bbls of 15.8 ppg Tail Cement, Dropped top plug, Pumped 20 bbls H2O, Lined up to displace w/ the rig. Displaced w/ rig 480.5 bbls. Bumped plug w/ FCP of 468 psi (4062 strokes), Pressure increased to 968 psi (Held for 5 min), Bled off pressure, and Checked floats (Floats held). Reciprocated f/ 3424' to 3,420' MD (Stopped 59 bbls into displacement). PU 220k SO 200k Cement in place as of 10/16/2021 0156 hr. 244 bbls 11.0 ppg lead cement returns on surface. Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface String Cement Cement 13 3/8" Casing in 0.0 3,424.0 Yes 244.0 Yes Yes place. Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbI/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 2 3 8 1468.0 468.0 Yes No I Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Performed cement job. Pressure tested surface lines to 3,500 psi (Good test). Pump sequence was as follows: 104 bbls of 11 ppg Mud Push ll, Dropped bottom plug, 480 bbls of 11 ppg Lead Cement, 73 bbls of 15.8 ppg Tail Cement, Dropped top plug, Pumped 20 bbls H2O, Lined up to displace w/ the rig. Displaced w/ rig 480.5 bbls. Bumped plug w/ FCP of 468 psi (4062 strokes), Pressure increased to 968 psi (Held for 5 min), Bled off pressure, and Checked floats (Floats held). Reciprocated f/ 3424' to 3,420' MD (Stopped 59 bbls into displacement). PU 220k SO 200k Cement in place as of 10/16/2021 0156 hr. 244 bbls 11.0 ppg lead cement returns on surface. Page 1/2 Report Printed: 12/16/2021 1 Cement Detail Report MT7-01 CanocaPhillips String: Surface String Cement Job: DRILLING ORIGINAL, 10/10/2021 06:00 Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Lead Cement 40.0 2,924.0 1,415 G 480.0 Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) Plastic Viscosity (0) Thickening Time (hr) CmprStr 1 (psi) 1.92 6.73 11.00 177.0 6.38 Additives Additive Type Concentration I Conc Unit label Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 2,924.0 3,424.0 350 G 73.0 Yield (W/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.17 5.06 15.80 89.0 4.27 Additives Additive Type Concentration I Conc Unit label Stage # 2 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? e Primary— FE(bbl/m... Cement 9 7/8"x 9 5/8" 9,260.0 Yes 0.0 Yes Yes Casing in place Q Pump Init Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 2 2 7 650.0 1,187.0 INo No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment SLB pump 2 bbls fresh water to prime lines PT lines to 3000 psi Pump 60 bbl's 11.5 Mudpush II Drop bottom plug. SLB will pump 130 bbl's 15,8 ppg G blend tail cement. Drop top plug. SLB will pump 20 bbl's H-2/0 on top of plug. Displace cement with rig at 6 bpm rate with 10.8 LSND. Slow to 3 bpm 150 strokes prior to bumping plug. 659.7 bbl's of 10.8 LSND will be pumped to bump plug. Strokes to bump 5,581. Max strokes 5,608. Bump plug pressure up 500 psi over displacement pressure. Bleed off pressure check to verify floats hold. Cement in place as of 10/24/2021 12:47 hr. Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 9,272.0 G 130.0 Yield (W/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.08 15.80 Additives Additive Type Concentration I Conc Unit label Page 2/2 Report Printed: 12/16/2021 Cement Detail Report MT7-01 CanocaPhillips String: Intermediate String 1 Cement Job: DRILLING ORIGINAL, 10/10/2021 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate String 1 Cement 10/23/2021 22:16 10/24/2021 00:47 1 MT7-01 Comment SLB pump 2 bbls fresh water to prime lines PT lines to 3000 psi Pump 60 bbl's 11.5 Mudpush II Drop bottom plug. SLB will pump 130 bbl's 15,8 ppg G blend tail cement. Drop top plug. SLB will pump 20 bbl's H-2/0 on top of plug. Displace cement with rig at 6 bpm rate with 10.8 LSND. Slow to 3 bpm 150 strokes prior to bumping plug. 659.7 bbl's of 10.8 LSND will be pumped to bump plug. Strokes to bump 5,581. Max strokes 5,608. Bump plug pressure up 500 psi over displacement pressure. Bleed off pressure check to verify floats held. Cement in place as of 10/24/2021 12:47 hr Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate String 1 7,562.0 9,260.0 No 0.0 Yes Yes Cement Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 2 6 680.0 1,187.0 INo No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment SLB pump 2 bbls fresh water to prime lines PT lines to 3000 psi Pump 60 bbl's 11.5 Mudpush II Drop bottom plug. SLB will pump 130 bbl's 15,8 ppg G blend tail cement. Drop top plug. SLB will pump 20 bbl's H-2/0 on top of plug. Displace cement with rig at 6 bpm rate with 10.8 LSND. Slow to 3 bpm 150 strokes prior to bumping plug. 659.7 bbl's of 10.8 LSND will be pumped to bump plug. Strokes to bump 5,581. Max strokes 5,608. Bump plug pressure up 500 psi over displacement pressure. Bleed off pressure check to verify floats held. Cement in place as of 10/24/2021 12:47 hr Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Intermediate Cement 3,424.0 9,260.0 636 G 130.0 Yield (W/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.08 15.80 6.30 Additives Additive Type Concentration I Conc Unit label Page 1/1 Report Printed: 12/16/2021 Cement Detail Report MT7-01 ConocoPhillip6 String: Cement Plug Job: DRILLING ORIGINAL, 10/10/2021 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement Plug 11/2/2021 13:00 11/2/2021 14:22 1 MT7-01PB1 Comment Pressure Test Cement Lines 3500 PSI on chart, Llne up SLB pump 45.2 bbls Mud Push13.5 ppg, Mix and Pump 82.1 bbls 16.5 ppg cement, pump 14.9 bbls Mud Push II, and Displace A 294 GPM w/ 119 BBLS 11.3 PPG KSI mud as Per CPAI cement schedule Cement wet @ 13:26 Cement in Place 14.22 hrs Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Cement Plug 1 8,800.0 9,460.0 No 5.0 No No Q Pump Init (bbl/m... Q Pump Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 3 4 70.0 1 Yes 25.00 No I Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) 8,866.0 Drill Bit 9,460.0 9 7/8 Comment Pressure Test Cement Lines 3500 PSI on chart, Llne up SLB pump 45.2 bbls Mud Push13.5 ppg, Mix and Pump 82.1 bbls 16.5 ppg cement, pump 14.9 bbls Mud Push II, and Displace A 294 GPM w/ 119 BBLS 11.3 PPG KSI mud as Per CPAI cement schedule Cement wet @ 13:26 Cement in Place 14.22 hrs Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Abandonment 8,800.0 9,460.0 429 G 81.3 Cement Yield (W/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.06 4.11 16.50 10.00 Additives Additive Type Concentration I Conc Unit label Page 1/1 Report Printed: 12/16/2021 Cement Detail Report MT7-01 CanocaPhillips String: Intermediate String 2 Cement Job: DRILLING ORIGINAL, 10/10/2021 06:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate String 2 Cement 11/13/2021 21:45 11/13/2021 23:30 1 MT7-01 Comment PT lines to 4500 psi. Line up SLB to pump via Baker LFC swivel. SLB pumped 60 bbl Mud Push II 13 ppg, release #1 Dart, SLB pumped 50 bbl 15.8 G Blend Tail, release #2 dart. Chase with 20 bbl water. Displace with 10.5 ppg LSND. Dart #1 latched and released at 622 stk, pressured up and packing off. Plug bumped at 1672 stks, lost 69 bbl to formation.CIP 23:30 hrs Cement Stages Stage # 1 Description Objective Top Depth (ftKB) Bottom Depth (ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate String Cement liner to 10,000' 10,000.0 10,737.0 No Yes Yes Cement P TOC Q Pump Init (bbl/m...p Final (bbl/... Q Pump Avg (bbl/... P Pump Final (psi) P Plug Bump (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 4 3 1,745.0 3,000.0 No No Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Lost 69 bbl to formation during displacement Cement Fluids & Additives Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) Tail Cement 10,000.0 10,737.0 236 G 49.0 Yield (W/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) 1.16 5.06 15.80 80.0 Additives Additive Type Concentration I Conc Unit label Page 1/1 Report Printed: 12/16/2021 PTD: 2210520 E-Set: 36122 Originated: schlumberger PTS - PRINT CENTER 600 E 57th PI - Ste A Anchorage, AK 99518 "ELLNA API tMj CD5-19 50103207600000 SERVICE •' 9PF CRU Delivered to: Transmittal Date: 20-Dec-21 AOGCC Transmittal #: ATTN: Natural Resources Technician RECEIVED 333 W. 7th Ave., Suite 100 Anchorage, AK 99501-3539 By Abby Bell at 1:43 pm, Dec 21, 2021 SERVICE DELIVERABLE DATE • •' • • • WL Setting Record FINAL FIELD 3-Aug-21 CD5-19 50103207600000 CRU WL Setting Record FINAL FIELD 11-Aug-21 CD5-96 50103208110000 CRU WL PERF FINAL FIELD 21-Jul-21 CD2-310 50103208260000 CRU WL DCST FINAL FIELD 16-Sep-21 CD2-310 50103208260000 CRU WL USIT FINAL FIELD 24-Aug-21 CD2-310 50103208260000 CRU WL USIT FINAL FIELD 25-Aug-21 CD5-31 50103208280000 CRU WL PERF FINAL FIELD 27-May-21 CD1-01A 50103202990100 CRU WL RST FINAL FIELD 12-Sep-21 MT7-06 50103208310000 GMTU WL CORROSION FINAL FIELD 3-Oct-21 MT6-08 50103207720000 GMTU WL PSR FINAL FIELD 14-Sep-21 MT6-08 50103207720000 GMTU WL PSR FINAL FIELD 22-Oct-21 MT7-06 50103208310000 GMTU WL MECH CUTTER FINAL FIELD 2-Sep-21 MT7-06 50103208310000 GMTU WL USIT FINAL FIELD 12-Dec-21 MT7-06 50103208310000 GMTU WL USIT FINAL FIELD 16-Dec-21 MT7--01 50103208320000 GMTU WL SCMT FINAL FIELD 15-Nov-21 MT7-06 50103208310000 GMTU WL USIT FINAL FIELD 19-Feb-21 Lookout 1 50103203590000 GMTU WL RST FINAL FIELD 29-Mar-21 Lookout 1 50103203590000 GMTU WL RST FINAL FIELD 2-Apr-21 Delivery Receipt Abby Bell X �� Cj 12/21 /2021 Print Name Signat re Date Please return via courier or sign/scan and email a copy to Schlumberger. A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted SLB Auditor - JR RECEIVED By Meredith Guhl at 3:50 pm, Nov 29, 2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑✓ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Exploratory ❑ Development Stratigraphic ❑ Service 7-1 221-052 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20832-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MT7-01 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): AA081800, AA081781, AA081803 I Greater Mooses Tooth Rendezvous 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 19,645 8295 19,645 8295 7455 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" x 34" 120 120 Surface 3,384 13-3/8" 3,424 3,050 5,020 2,260 Intermediate II 9,220 9-5/8", 9-7/8" 9,260 7,440 6,330, 8,860 3,810, 8,260 Intermediate II 2,028 7" 10,727 8,310 7,240 5,410 Liner 7,512 4-1/2" 18,050 8,303 8,430 7,500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none n/a 4-1/2" L-80 10,550 Packers and SSSV Type: Baker Premier, no SSSV Packers and SSSV MD (ft) and TVD (ft): Packer: 10,487' MD / 8,222' TVD 12. Attachments: Proposal Summary L Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 12/4/2021 15. Well Status after proposed work: Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR [_1SPLUG ElAOGCC 16. Verbal Approval: Date: Representative: GINJ ElOp 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. Contact Name: Madeline Woodard Authorized Name and Madeline Woodard Madeline o®o°mamm. -5 Madeline.e.woodardlc'Dconocophillips. Digital Signature with Date: Woodard Contact Email: Com Contact Phone: 907-265-6086 Authorized Title: Completion Engineer AOGCC USE ONLY Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: 321-607 Plug Integrity ❑ BOP Test IT) Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS HEW 12/7/2021 Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No ® Subsequent Form Required: 1 0- ,1 ^ 0,1 Digitally signed by JessieL. Jessie L. Chmielowski Date:2021.12.02 14:04:53 APPROVED BY Approved by: Chmielow$ki COMMISSIONER THEAOGCC Date: 12/2/21 -09,00' Comm. dts Comm. JSr Pet EngVTL 12/2/21 I JSr Pet Geo Sr Res Eng DSR-11/29/21 Form 10-403 Revised 10/2021 Approved application is Valid for 12 montns trom the date of approval. CDW 12/01/2021 SECTION 1 - AFFIDAVIT 10 AAC 25.283 (A)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the Alaska Oil and Gas Conservation Commission in the Matter of the Request of ConocoPhillips Alaska, Inc. for Hydraulic fracturing for the MT7-01 Well under the Provisions of 20 AAC 25.280 STATE OF ALASKA THIRD JUDICIAL DISTRICT ) AFFIDAVIT OF Jason C. Parker Jason C. Parker, being first duly sworn, upon oath, deposes and states as follows: My name is Jason C. Parker. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. 1 am a Senior Land Negotiator for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 1 Pursuant to 20 AAC 25.283 (1) CPAI prepared the attached Notice of Operations ("Notice"). 4. On November 291h, 2021, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners, surface owners, and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 29th day of November, 2021. J son . LParKe-ir/ STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 291h day of November, 2021, by Jason C. Parker. Notary Public, St to of Alaska My Commission Expires: \\\\_\AWIII11I11////j/ 40 'NOTARY' PUBLIC... low- _1 Conocophillips Alaska November 29, 2021 VIA CERTIFIED MAIL To: Operator and Owners (shown on Exhibit 2) Re: Notice of Operations pursuant to 20 AAC 25,283 (1) for MT7-01 Well AA-081800, AA-081781, AA-081784, and AA-081736 Greater Mooses Tooth Unit, Alaska CPAI Contract No. 204278 Rear Operator and Owners: Jason C. Parker Senior Land Negotiator Land & Business Development P. O. Box 100360 Anchorage, AK 99510-0360 Office: 907-265-6297 Fax: 907-263-4966 jason.c.parker@cop.com ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Colville River Unit working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the MT7-01 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about November 29, 2021. This Notice is being provided pursuant to subsection of 20 AAC 25.283. The Well is currently planned to be drilled as a directional horizontal well on leases AA-081781, AA- 081800, and AA-081803, as depicted on Exhibit 1, and has locations as follows: Location FNL FEL Township Range Section Meridian Surface 4265' 3333' T10N R2E 32 Umiat Top Open Interval 2708' 1195' T9N R2E 6 Umiat Bottomhole 256' 271' T10N R2E 36 Umiat Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well ("Notification Area"), which includes the reservoir section. Exhibit 2 is a list of the names and addresses of all owners, landowners and operators of record of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. If you require any additional information, please contact the undersigned. Sincerely, 2son C. Pa Senior Lan Negotiator Attachments: Exhibits 1 & 2 Exhibit 1 ;, 4 ConocoPhillips Alaska ----__ __ MT7-01 Lease Plat I 11/2412021 1 i 1 AA081803 T1011, R IE, UA. 3� >a� �t 31 VJ 1 2 f 1 • Frac Ports - Open Interval Well Trajectory Half Mile Frac Port Buffer Half Mile Well Track Buffer Unit Boundary f ` Proposed Rendezvous PA Well Pad CPAI Leaso ® Kuukpik Surface[ASRC Subsurface T1 UM -'- -1 26 1 32 33 MT7 b 3 a J N 0 0.5 1 Miles Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attn: Vincent Lelarge, North Slope Asset Development Manager Owner (Nan -Operator): None Landowners: United States Department of Interior Bureau of Land Management Alaska State Office 222 West 7th Avenue, #13 Anchorage, Alaska 99513 Attn: Wayne Svejnoha, Branch Chief Energy and Minerals Surface Owner: United States Department of Interior Bureau of Land Management Alaska State Office 222 West 7th Avenue, #13 Anchorage, Alaska 99513 Attn: Wayne Svejnoha, Branch Chief Energy and Minerals SECTION 2 — PLAT 20 AAC 25.283 (A)(2) Plat 1: Wells within .5 miles AAO IN3 HOU . R • Frac Ports Open Entarval Wall Traleclary Half Mile F rae Port Buffer Hall M ile W4311 Track Bu4er Unrl Boundary J Npu5ed RendeZym PA 4 Well Pad C RAt Lease KLkukpik surfacelASRC Suhsurfam ConocoPhillips AI3,�ka MT7-01 Lease Plat 11r24M21 Table 1: Wells within .5 miles Well Name API Well Status Field Fluid Type Name MT7-01 PB1 50103208327000 PA GMT2 New Drill MT7-06PB1 50103208317000 PA GMT2 New Drill MT7-06 50103208310000 PROD New Drill GMT2 New Drill MT7-04 50103208290000 INJ New Drill GMT2 New Drill MT7-03 50103208300000 INJ New Drill GMT2 New Drill Rendezvous 2 50103203630000 EXPL PA GMT2 - SECTION 3 - FRESHWATER AQUIFERS 20 AAC 25.283(A)(3) There are no freshwater aquifers within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 5 of the Conservation Order CO 793 Amended, Greater Moose's Tooth -Rendezvous Oil Pool (ROP), which states "There are no freshwater aquifers in the proposed Affected Area of the ROP." SECTION 4 - PLAN FOR BASELINE WATER SAMPLING FOR WATER WELLS 20 AAC 25.283(A)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. SECTION 5 — DETAILED CEMENTING AND CASING INFORMATION 20 AAC 25.283(A)(5) All casing is cemented in accordance with 20 AAC 25.52(b) and tested in accordance with 20 AAC 25.030 (g) when completed. See Wellbore schematic for casing details. MT7-01 4-string Producer, Final Completion Schematic IHT1 TOC 7,117' MD 15,7G0' TV D 5u sitna 8062' MD G472' TVD Tap HRZ 9272' MD 17423' TVD dorm hale Gauge 10,373' M D Produetian Packer 10,487' MD ZP Liner Tap Packer 1D,538' MD 21)" Bd ppf H-40 Insulated Conductor 80 feet, cennenied to surface Surface Ca si nq 13-318" 68 ppf L-80 HYD563 3424' MD 1 3D50' TVD 4-112" 12.6 ppFL-90 HYD563 1) 4Y_"KLandingHippie (3.813'ID) 2) 45=' x 1' KBG-2 GLM (24 3) 45=' x 1' KBG-2 4-5 GLM (1 x) 4i H ES Opsis down hole Gauge 5) 4-'._' Baker Premier Production Packer 5i 4-'._' dB Landing Hippie vi, RHC Plug {3.75' ID) fi 3aker Liner Top Packer J Flex -Lock Hangerwt Tie Back sleeve INTERMEDIATE 1 9 518" 43-5 ppf L-80 TXP x (-1670') 9-718" £2.8 ppf L-80 HYD523 9260' MD) 7440' TVD INT2 TO TOC @ 9995' MD Per CFlL Top Alpine D 10,fi48' MD 18,282' TVD INTERMEDIATE 2 7" 2G ppf L-80 HYD5£3 Liner 10,727' M D 18310' TVD ------ --------- d <' 12.0 L-89 HYD563 Liner vr) frae 5AJB" Hole ports and perfjoints T7 @ 19.605' PAD +8,295' TVD Frao Ports 10,967' MD to 13,135' MD Toe @ 18,050' MD ) 8,3d3' TVD SECTION 6 - ASSESSMENT OF EACH CASING AND CEMENTING OPERATION TO BE PERFORMED TO CONSTRUCT OR REPAIR THE WELL 20 AAC 25.283(A)(6) Casing & Cement Assessments: 13-3/8" casing cement pump report on 10/16/2021 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 480 BBLS of 11.0 ppg DeepCRETE cement and 73 BBLS of 15.8 ppg Class G blend tail cement and displaced with 11.0 ppg mud. Full returns to surface were seen throughout the job. The plug bumped with 468 psi, and a pressure of 968 psi was held for 5 minutes. Pressure was bled off to check the floats and they held. The 9-5/8" x 9-7/8" casing cement report on 10/23/2021 shows that the job was pumped as designed, indicating competent cementing operations, with 130 bbls of Class G 15.8 ppg cement with full returns. Plugs bumped with 1187 psi, 500 psi over final circulating pressure. The rig waited for cement to reach 100 psi compressive strength per modeled setting times. The intermediate 2 section experienced signs of hole collapse and a decision was made to sidetrack and re -drill. On 11/2/2021, an 82 BBL 15.6 PPG cement plug was pumped above the collapsed hole and 200' into the 9-5/8" x 9-7/8" casing. When running in hole with the sidetrack BHA, cement was tagged as expected, the cement was drilled out to below the casing shoe and the intermediate 2 sidetrack hole was drilled successfully. The 7" liner cement report on 11/13/2021 shows that the initial job did not pump as planned with 70 BBL losses during the job. While pumping 50 bbls of Class G 15.8 ppg cement, and 197 BBL of displacement fluid the losses occurred 73 BBL into the displacement. Plugs bumped 7 BBL early with a pressure of 1950 psi. The liner hanger was set, and floats were confirmed to be holding. A dedicated CBL was run and confirmed top of cement at 9,995' MD as expected, and the cement job was deemed competent to continue operations. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE -TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 10/17/21 the 13-3/8" casing was pressure tested to 3,500 psi for 30 mins. On 10/25/21 the 9-5/8" by 9-7/8" casing was pressure tested to 3,500 psi for 30 mins. On 11/16/21 the 7" liner was pressure tested to 3,500 psi for 30 mins. On 11/28/21 The 9-5/8" by 9-7/8" casing and 7" liner were pressure tested to 3,500 psi for 30 mins during IA test. The strings will be tested again to 4,200 psi during post -rig wellwork. The 4.5" tubing will be pressure tested to 4,200 psi prior to frac'ing. AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 7,455 Annulus pressure during frac 3,800 Annulus PRV setpoint during frac 3,900 7" Annulus pressure test 4,200 4 1/2" Tubing pressure Test 4,155 E PRV 8,455 Highest pump trip 7,955 SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Table 2: Wellbore pressure ratings Size Weight 13-3/8" 68 9-5/8" 43.5 9-7/8" 62.8 7" 26 4.5" 12.6 Grade API Burst API Collapse L-80 5,020 psi 2,260 psi L-80 6,330psi 3,810psi L-80 8,860psi 8,260psi L-80 7,240psi 5,410psi L-80 8,430 psi 7,500 psi 02 a o p is F,^aw•II I m PUMP LOCAL NICKOUT PRESSURE FP1 MAPP-5Bopsi OPEN TOP TANK C PUMP LOCALPRIiWLCKCVT PRE63URE FP3 MAPP-500psf CUSTOMER SUPPLIED } I FP2 MAPP-500 pai T1 FP4 MPPP-500 psf PB1 T C I p L--K---_--_1J111: JEP2: rc -Jli FPa p4 FRAC TREE pFCTN li W vV li vV T lil c Cl V4 lil 2 I H VS li m lil i li H V6 li MAN IFOLD TRAILER li - -- T V1 V2 r T T ! ! T3 T2 T1' IL_ J PUMP LOCAL KICKCVT PRESSURE PUMP LOCH KRE OUf P-65 FPb MAPP-500 Dsf FP7 MAPP-500 Psi FRAC TANK FP6 MAPP-500 psf FP6 MAPP-500 Psi MAPP- MAXI M U M ALLOWABLE PUMPING PRESSURE FP - FRAC PUMP PT -PRESSURE TRUCK FA(ILL -EMERGENCY SHUTDOWN - BOOST PUMP S❑ -SPRING PRESSURE ©- HIGH PRESSUE PUMP RELIEF VALVE ELECTRONIC PRESSURE CONTROL LINE, Eleclriral ❑F-FLOWMETER RELIEF VALVE HIGH PRESSURE, 0-15 kpsi $ - CHECK VALVE DART -0 - BULL PLUG CHECKVALVE FLAPPER 0 - HYDRAULICVALVE LOW PRESSURE, 0-200 psi 0 - TRANSDUCER - 9' BVTTERFLY CUSTOMER SUPPLIED. 0-4 kpsl X - LO-TORO ®-LO-TORO WHEEL - 4• HYD BUTTERFLY CUSTOMER SUPPLIED. 0-5 k"I - CHOKE 0 - PALLLAUNCHER CUSTOMER SUPPLIED, 0 -10 kpsi R 7 1 R I F V71 - umEPauuuu®' r PRV SKID L_- __ NC� I CUSTOMER SUPPLIED NO. I---- ---T B j PFMI I ATT P 1 PRV® 5 NO >.ao 61 Va pi ENCLOSED TANK 2 ENCLOSEDTANKI i 3'"" rc. rsemw u� ,wo mexa Co—PI1II IIPs AK FW Rig -Up SIN61�1E raNJAfP8R010 IN.—FINI I $� �-"DDPFQCOP-4K�ENERAL-0CI SEr A rtn m NTS � .•a � scu•U661 ,1 or Alpine 1 OK Frac Tree R wal� sv —a ife ao rep SECTION 9 - DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(A)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine C interval is approximately 100' TVD thick at the heel of the lateral and gradually thickens to 120' TVD at the toe. The Alpine C sandstone is very fine to fine grained and quartz rich. The top of the Alpine C is estimated to be at 10,748' MD / - 8,174' TVDSS at the heel of the MT7-01. The estimated fracture gradient for the Alpine C sandstone is 11.3 ppg. The overlying confining zone consists of greater than 850' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ was encountered at 9,236' MD /-7,283' TVDSS. The underlying confining zone consists of approximately 1700' TVD of Kingak shales. The estimated fracture gradient for the Kingak interval ranges from 15-18 ppg. Fracture gradient increases down section. The shallowest Kingak shale interval encountered in the MT7-01 occurred at the toe at 17,361' MD/ - 8,193 TVDSS and the deepest Kingak shale interval was encountered at the heel at 11,444' MD /-8,280' TVDSS. SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: MT7-04: The 7 & 5/8" casing was cemented on 5/17/21. The cement job was pumped with 15.8ppg Class G slurry. During the execution of the job there were some partial losses however the cement was logged and the TOC was determined to be 10,605' MD. MT7-03: The 7-5/8" casing was cemented on 6/28/21. The primary cement job was pumped with 15.8 ppg Class G slurry, the plug bumped and floats held. There were some partial losses during the execution of the job but the cement was logged and the TOC was determined to be 11,050' MD. MT7-06/ MT7-06PB1: The 7-5/8" casing was cemented on 8/7/21 with remedial work completed on 8/12/21. The primary cement job was pumped with 15.8 ppg Class G slurry where almost all fluid was lost. Remediation was done where the 7-5/8" casing was perforated from 10,923' to 10,925' MD and 15.8 ppg Class G cement was squeezed into the perforations. The cement was logged and TOC was determined to be 9,650' MD with competent cement down to 10,950' MD. MT7-06PB1 was drilled and a liner run to 25,254' MD before the liner was separated. The top of the liner (fish) is located at 12,985' MD with the MT7-06 sidetrack point at 12,540' MD. MT7-01PB1: The 8-1/2" x 9-7/8" hole was plugged and abandoned on 11/2/21. The abandonment plug consisted of 82.1 bbls of 16.5 ppg Class G cement. The plug was then tagged with 11 klbs down with a drill bit. The MT7-01 wellbore was then kicked off from the abandonment plug. Rendezvous 2: Permanently abandoned per AOGCC regulations and witnessed by Lou Grimaldi of AOGCC on 4/4/2008. Top of Rendezvous Top of Rendezvous Top of Cement Top of Cement Top of Cement Cement Operations WELL NAME STATUS Casing Size Oil Pool (MD) Oil Pool (TVDSS) (MD) (TVDSS) Determined By Reservoir Status Zonal Isolation Summary Mechanical Integrity Primary: 61.1 bbls of 15.8 7/17/215, 7-5/8" casing MT7-03 ACTIVE 7-5/8" 11,768 8,196 11,050 7,965 log open hole liner for injection TOC 11,050' & Packer @ ppg class G cement, Stage: pressure tested to 2,500 11,473' 51bbls of 15.8 ppg class G cement psi for 30 mins 7/23/21, 7 5/8" casing TOC: 10,605' & Packer @ 75bbls of 15.8 class G M77-04 ACTIVE 7-5/8" 11,674 8,205 10,605' 7,835 log open hole liner for injection 11,595 cement pressure tested to 3,300 psi for 30 mins 8/9/21, 7 5/8" casing open hole liner for 107.5 bbls of 15.8 class G M77-06 ACTIVE 7-5/8" 12,198 8,143 9,650' 6,861 log production TOC: 9,650' &Packer @ 10,143 cement pressure tested to 4,200 psi for 30 mins Abandoned lateral with 8/9/21, 7 5/8" casing MT7-06PB1 PA 7-5/8" 12,198 8,143 9,650' 6,861 log parted liner (frac sleeves TOC: 9,650' & Packer @ 10,143 107.5 bbls of 15.8 class G pressure tested to 4,200 and swell packers) cement psi for 30 mins 82.1 bbls of ppg class tag hard cement w/ MT7-01P61 PA 7-5/8" 10,752 8,146 8,868 6,994 tag up w/ 11klbs Plugged & abandoned TOC: 8,868' drilled to 9,270' G cemmee nt 11klbs 36 bbls 15.6 ppg ARCTIC All casing & tubing strings Visual cement at Rendezvous 2 PA 7" 8,602' 8,602 Surface Surface Visual cement at surface Plugged & abandoned cemented to surface SET in OA and 28.4 bbls of surface ARCTICSET in IA SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that two potential fault or fracture systems transect the Alpine C formation within one half mile radius of the wellbore trajectory for MT7-01. The potential fault or fracture systems were encountered at 13,300' MD and 14,783' MD and were identified by mud -losses encountered while drilling. Both potential fault or fracture systems are sub -seismic and throw would be expected to be less than 5'. Any faults that are within the half mile radius of the wellbore do not extend up through the confining interval, and fracture gradients within the top seal intervals would not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults or fracture systems will not interfere with containment. Based on our knowledge of the principal stress direction in the Alpine C formation, along with the well path, all the fractures will be longitudinal, running parallel to the wellbore. Because of this the fractures will only intersect faults that intersect the wellbore. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. Well Name Fault Depth MD (ft) Fault Depth TVDSS (ft) Fault Vertical Displacement (ft) Fluid Losses (bbls/hr) MT7-01 13,300' -8238 <5' 35 MT7-01 14,783' -8227 <5' 30 Plat 2: MT7-01 Fault Analysis Z. 41 Poonp@F Faula • Ftac P13r15 - Open Irb9TV91 -mm TrAjbt4&y Halt Mile Frae FW Buffer "an Mile Well Track Pulmr Um Boundary Proposed kendmzvms PA O VOA Pad r7 CPAF Laasc �,� Kumo Surface+ANG Subsarfaae XD,IE I. Cor�oeoPhlllips Ahskn VT7-01 Fault Plat IQ4t2oz11 :5 Nff 91 SECTION 12 - PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(A)(12) MT7-01 was completed in 2021 as a horizontal producer in the Alpine C formation. The well was completed with 4.5" tubing. The liner is a 4.5" liner with dart actuated sliding sleeves and pre perforated joints. We will establish injection and drop a dart which will shift a sleeve open to establish the first frac stage. We will then pump the 1st stage and drop a dart after each remaining stage, these darts will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Halliburton Pumping Services: (Alpine C Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre-existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 1,200' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 25 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 1001 F seawater (approx. 8,641 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls useable volume per tank). 5. MIRU HES Frac Equipment. 6. PT Surface lines to 9,500 psi using a Pressure test fluid. 7. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 8. Bring up pumps and increase annulus pressure from 2,500 psi to 3,800 psi as the tubing pressures up. 9. Pump the Frac job by following attached HES schedule @ 35bpm with a maximum expected treating pressure of 7,455psi. 10. RDMO HES Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 11. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). Hydraulic Fracturing Fluid Product Component Information Disclosure Fracture Date 11/18/2021 State: Alaska County: Harrison Bay API Number: 5010320832 CONOCOPHILLIPS NORTH SLOPE - Operator Name: EBUS Well Name and Number: MT7 01 Longitude:-151.69 Latitude: 70.17 Long/Lat Projection NAD27 Indian/Federal: dome Production Type Oil True Vertical Depth (TVD): 0 Total Water Volume (gal)': 379,818 Hydraulic Fracturing Fluid Composition: Chemical Maximum Abstract Maximum Ingredient Ingredient Trade Name Supplier Purpose Ingredients Service Concentration in Additive Concentration In Ingredient Mass Comments Company First Name Last Name Email Phone Number (CAS (%by mass)** HF Fluid (%by Ibs #) mass)'" Sea Water Operator Base Fluid Water 7732-18-5 76.95297i 3092013 Densily=8.480 BE-6 MICROBIOCIDE Hallibudon Biocide Listed Below Listed Balm 0 NA CL-22 UC Hallibudon Crosslinker Listed Below Listed Below 0 NA CL-28M CROSSLINKER Hallibudon Crosslinker Listed Below Listed Bel- 0 NA CL-31 CROSSLINKER Hollibudon Crosslinker Listed Below Listed Belauu 0 NA LOSURF-300D Halliburton 1 Non-ionic Surfactant Listed Below Listed Below 0 NA MO-67 Hellibudon pH Control Additive Listed Below Listed BcI- 0 NA OPTIFLO-III DELAYED RELEASE Hailleurton Breaker Listed Below Listed Below 0 NA BREAKER SP BREAKER Hallibunon Breaker Listed Belau Listed Below 0 NA WG-36 GELLING AGENT Halliburtan Gelling Agent Listed Belau Listed Belau 0 NA LVr 200 Pencm Freeze Protect Listed Belau Listed Below 0 NA Wadi Wanli 20/40 Proppant Proppant Listed Below Listed Below 0 NA Company S and Non-MSDS Ingredients are listed below the green Ingredients Listed Above Listed Above 1,2,4 Trimethylbenzene 95-63-6 L. c.808735 29 2-13romo-2-nitro-1,3-propanedid 52-51-1 -08. 0o2 0.0o195t 57 Denise Tuck, Halliburton, 3000 N. Denise.Tuck@ Acrylate polymer Proprietary 1.808 0.002555 101 Sam Houston Pkwy E., Houston, TX Halliburton Denise Tuck Halliburton.co 281-8715226 77032, 281-871- in 6226 Ammonium persulfate 7727-54-0 too- 9.919281 760 Denise.Tuck@ Beale salts Proprietary 6o.00e 0.15292% 6028 Halliburton Denise Tuck Halliburton.co in 281-871-6226 Corundum 1302-74-5 63.00% 10.55640% 416052 Crystalline silica, quartz 14808-60-7 30.00% 0.00605% 240 Denise.Tuck@ Cured acrylic resin Proprietary 30.00% 0.00578% 228 Halliburon Denise Tuck Halliburton.co 281-871-6226 Ethanol 64-17-5 60.00& 0.04350% 1715 Guar gum 9000-30-0 1d0.00a 3.385591 115197 Heavy aranatic petroleum naphtha 64742-945 3o.006 0.021 % a58 HydroOesed Distillate, light 64742-47-8 loo.00a 1.22550% 48300 Deniae.Tuck@ Inorganic mineral Proprietary 5.00% 0.o0oo1& 1 Halliburton Denise Tuck Halllburt... in 281-871-6226 Mullile 1312-13-8 11,111 1,311211 211011 Naphthalene 91-20-3 5.00% 0.00363% 143 Denise.Tuck@ Oxylated phenolic resin Proprietary 30.00% 0.02900% 1144 Halliburton Denise Tuck Halliburton.co 281-871-6226 Poly(oxy-1,2-ethanedryl), alpha-(4- nonylphenyl)-ornega-hydroxy-, 127087-87-0 5.00% o.o0363% 143 branched Denise.Tuck@ Polymer Proprietary 1.001 0.00000% 1 Halliburton Denise Tuck Halliburton.co in 281-871-6226 Potassium formate 590-29-4 60.00% 0.15276% 6021 Potassium hydroxide 1310-58-3 5.00% o.o0o011 1 Potassium metaborate 13709-94-9 60.00% 0.0001'lb 7 Sodium caiboxymethyl cellulose 9004-32-4 1.00% 0.00255% 101 Sodium chloride 7647-14-5 4.00% 3.27219% 128966 Sodium glyccllate 2836-32-0 1.00% 0.00255% 101 Sodium hydroxide 1310-73-2 30.00% 0.02309% 909 Sodium persulfate 7775-27-1 100.00k 0.00127% 51 Sodium sulfate 7757-a2-6 0.10% 0.00000% 1 Water 7732-18-5 100.00% 0.15350% 6052 ' Total Water Volume sources may include fresh water, produced water, and/or recycled water _ " Information is based on the maximum potential for concentration and thus the total may be over 100% Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. All component information listed was obtained from the supplier's Material Safety Data Sheets (MSDS). As such, the Operator is not responsible for inaccurate and/or incomplete information. Any questions regarding the content of the MSDS should be directed to the supplier who provided it The Occupational Safety and Health Administration's (OSHA) regulations govern the criteria for the disclosure of this information. Please note that Federal Law protects "proprietary', 'trade secret", and "confidential business information" and the criteria for how this information is re orted on an MSDS is endto 29 CFR 1910.1200 and A endiz D. MT7-01 Top Top Propped Fracture Avg Fracture Stage Job Size (lb) MD TVD Half -Length Height (ft) Width (in) (ft) (ft) (ft) 1 160,000 13,132 8,258 620 120 0.301 2 160,000 12,361 8,277 620 120 0.301 3 160,000 11,592 8,293 620 120 0.301 4 160,000 10,867 1 8,227 620 120 0.301 Disclaimer Notice: This model was generated using commercially available modeling software and is based on engineering estimates of reservoir properties. Conoco Phillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results SECTION 13 - POST -FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(A)(13) After the fracture stimulation, ConocoPhillips ("CPAI") plans to flowback the well for cleanup purposes for an estimated 7 to 14 days. Since the drillsite and cross-country line will not be commissioned for startup at the time of the flowback, the fluids will be routed to tanks and the associated gas will be flared. Little Red Services (IRS") will be the flowback company utilized for the flowback. Once the well's flowback fluids meet Alpine Central Facility ("ACF") acceptance criteria it will be shut-in until the GMT2 drillsite is commissioned and ready to startup. CPAI plans to limit the flowback time and associated flaring to only what is necessary to achieve conforming production fluids required for drillsite start-up. The initial flowback period is intended to produce back the fracture fluids to tanks as quickly as possible, until the well is producing less than 10% water cut and less than 0.5% solids, at which time the produced fluids meet ACF acceptance criteria for start-up. Since the drillsite will not be active, nitrogen will be brought in and utilized as lift gas to kick off the well during the flowback period. Produced gas will be flared during the flowback process. There will be a tank farm on GMT2 pad to store the produced fluids from flowback operations. Estimated total flowback volumes are 14,000 to 56,000 barrels of fluid produced and 20 to 75 MMSCF gas flared. The flowback fluids not suitable for ACF processing will be hauled via truck from MT7 to either CD1-01 or 1 B-WIF for disposal. CPAI will work to separate and recover fluid that meets the facility specifications from the flowback fluids. A fluid manifest form will be completed for each load trucked offsite. Acceptable recovered fluids will be trucked from MT7 to an unloading tank farm at either MT6 or CD4 drillsite. Total oil volume to be used for allocation purposes will be measured by performing tank straps prior to pumping the fluids into the cross-country line from the tanks at each drillsite. The tank manufacturer volume conversion tables will be used to convert the tank strap measurement into a final fluid volume. The fluids will be pumped from the tanks into the cross-country line downstream of MT6 metering and commingled with Colville River Unit ("CRU") production, processed to sales quality at ACF, delivered to a common carrier line, and ultimately sold. CPAI will pay royalty based on the manifested volumes and gravity. From:WSC Operations Engineer To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Njoku, Johnson; WSC Rig Advisor; Anderson, Nina M; Hull, Celie; Lee, David L Subject:MT7-01 Intermediate 2 Liner Pressure Test and FIT Form Date:Wednesday, November 17, 2021 3:03:25 AM Attachments:image001.png MT7-01 Int 2 Liner test and FIT 11-16-21.xlsx MT7-01 Int 2 Liner test and FIT 11-16-21.pdf Hi Victoria, Attached is the MT7-01 intermediate 2 liner pressure test and formation integrity test form and sheet. If you have any questions, please let us know. Polaris – WSC Operations Engineer Justin Brady / Scott Kolstad wscopsengineer@conocophillips.com 907.263.4544 (Office) Well Name:Rig:Date: Drilling Supervisor:Pump used:3 Strokes Barrels 2 3 4 Casing Test Pressure Integrity Test Hole Size:1 0 RKB-CHF:37.3 Ft 10727.0 Ft-MD 8307.6 Ft-TVD 10757.0 Ft-MD 8325.0 Ft-TVD Strks psi Min psi Strks psi Min psi 6.276 8 0 0 0 3600 0 0 0.00 964 5 300 1 3600 2 72 0.25 950 Mud Weight: 10.4 ppg Mud Weight:10.4 ppg 10 520 2 3600 4 140 0.50 930 Mud 10 min Gel: 5.0 Lb/100 Ft2 Mud 10 min Gel:5.0 Lb/100 Ft2 15 775 3 3600 6 216 1.00 925 Test Pressure: 3500.0 psi Rotating Weight:Lbs 20 990 4 3600 8 306 1.50 920 Rotating Weight: ######Lbs Blocks/Top Drive Weight:43000.0 Lbs 25 1180 5 3600 10 397 2.00 915 Blocks/Top Drive Weight: 43000.0 Lbs Desired PIT EMW:13.5 ppg 30 1390 6 3600 12 490 2.50 914 Estimates for Test:4.7 bbls Estimates for Test:1339 psi 2.1 bbls 35 1600 7 3600 14 583 3.00 912 1 1 40 1800 8 3600 16 677 3.50 911 EMW = Leak-off Pressure + Mud Weight =45 2020 9 3600 18 767 4.00 910 0.052 x TVD 0.052 x 8308 50 2270 10 3600 20 850 4.50 910 13.09 ppg 55 2500 15 3600 22 930 5.00 909 60 2700 20 3600 24 1012 5.50 909 65 2920 25 3600 26 1096 6.00 908 70 3175 30 3600 28 1162 6.50 908 75 3390 30 1056 7.00 907 80 3610 7.50 907 8.00 907 8.50 907 9.00 907 9.50 906 10.00 906 11 905 12 905 13 905 14 904 15 904 8.1 Bbls 8.0 Bbls 3.0 Bbls 2.0 Bbls Comments:Test casing to 3500 psi CONOCOPHILLIPS Alaska, Inc. Pumping down EMW at 10727 Ft-MD (8307.55 Ft-TVD) =950 10.41162+PIT 15 Second Shut-in Pressure, psi Volume Pumped Volume Bled Back Volume Input PRESSURE INTEGRITY TEST Type of Test: Casing Test Pressure IntegrityTest Hole DepthCasing Shoe Depth Casing Size and Description: Pump Rate: 11/16/2021 R Reinhardt/L Shirley Volume/Stroke 5.00 Pumping 0.1007 MT7-01 Doyon 25 Volume Bled Back Shut-in Pumping Shut-in Volume Pumped 0 500 1000 1500 2000 2500 3000 3500 4000 0 1 2 3 4 5 6 7 8 9PRESSURE CASING TEST LEAK-OFF TEST PIT Point Barrels 0 5 10 15 20 25 30 Shut-In time, Minutes Lost 0 psi during test, held 100% of test pressure. MT7-01 Int 2 Liner test and FIT 11-16-21.xlsx Summary From:WSC Operations Engineer To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Njoku, Johnson; Lee, David L; Gorham, Brad; Hull, Celie; Anderson, Nina M; Klem, Adam; WSC Rig Advisor Subject:RE: MT7-01 Intermediate II 7" Liner Cement Evaluation Date:Monday, November 15, 2021 7:07:53 PM Attachments:image001.png CPAI_MT7-01_SCMT_15Nov21_SLB.Pdf MT7-01 SCMT Log Report 11152021.pdf All, Please see the attached Schlumberger analysis and log as promised. Thanks, Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) From: WSC Operations Engineer Sent: Monday, November 15, 2021 5:27 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Njoku, Johnson <Johnson.Njoku@conocophillips.com>; 'Lee, David L' <David.L.Lee@conocophillips.com>; 'Gorham, Brad' <Brad.Gorham@conocophillips.com>; Hull, Celie <Cecilia.Hull@conocophillips.com>; Anderson, Nina M <Nina.Anderson@conocophillips.com>; Klem, Adam <Adam.Klem@conocophillips.com>; WSC Rig Advisor <wscrigadvisor@conocophillips.com> Subject: MT7-01 Intermediate II 7" Liner Cement Evaluation All, Attached is the CBL for the MT7-01 intermediate II cement job and the cement job report. ConocoPhillips Cementing SME interpretation of cement evaluation log (CBL) is as follows: Based on the drop in Amplitude and Cement Map response we brought cement to the planned TOC of 10,000’ in the annulus. From 10,000 to ~10,200’ we are seeing poor to moderate bond indicating this cement is probably contaminated and could get better with time. Although not the preferred response it is doubtful that this portion of the annulus could be circulated. From 10,200’ to Total Log Depth of 10,428’ we see lower amplitude, better Cement Map Response and activity in the VDL, indicating much better Moderate cement/bond. This portion of the sheath should provide adequate isolation. Seeing the cement improve with depth we can anticipate better quality cement with depth below 10,428 to the shoe. This can be validated with the sonic log at time of drill out. To meet regulation height of 250’ TVD from the casing shoe, a cement top at 10,140’ MD is required, and the log confirms the cement top at 10,000’ MD. ConocoPhillips is requesting approval to proceed as per plan on MT7-01: 1. PU 6-1/8” production drilling BHA with SLB SonicScope 2. RIH and log for TOC on the 9-7/8” x 9-5/8” intermediate I casing (will log free ringing pipe above cement) 3. RIH and log 7” liner TOC down to tag depth with BHA 4. Conduct casing test, drill out shoe track, and 20’ of new formation 5. Conduct FIT on 7” liner 6. Drill MT7-01 production lateral to planned TD Note that the final log and Schlumberger analysis is still being completed. With the ConocoPhillips expert review of this log and the cement quality noted, ConocoPhillips requests approval of the above plan at this time. The Schlumberger analysis and final log will follow. Thanks, Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) STATE OF ALASKA Reviewed By: �J OIL AND GAS CONSERVATION COMMISSION P. 1. Supry BOPE Test Report for: GMTU MT7-01 - Comm Contractor/Rig No.: Doyon 25 PTD#: 2210520 DATE: 11/15/2021 Inspector Brian Bixby Insp Source Operator: ConocoPhillips Alaska, Inc. Operator Rep: R. Reinhardt / L. Shirley Rig Rep: E. Potter / C. Coleman Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopBDB211116095612 Rams: Annular: Valves: MASP: Type Test: BIWKLY 250/3500 250/3500 250/3500 ' 3093 - Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank P --P- System Pressure 3025 P Housekeeping: P Pit Level Indicators P P ' Pressure After Closure 1550 P PTD On Location P Flow Indicator P P 200 PSI Attained 17 P ' Standing Order Posted P Meth Gas Detector P "_ P _" Full Pressure Attained 114 P ' Well Sign P H2S Gas Detector P P Blind Switch Covers: YES P Dirt. Rig P_ MS Misc 0 NA Nitgn. Bottles (avg): 6ka_1750-'__ P Hazard Sec. P _ ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: Quantity P/F Upper Kelly —1 P Lower Kelly___ 1- P Ball Type 4 _ P ' Inside BOP 2 FP FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size PIF Quantity P/F Stripper 0 NA No. Valves 15 P - Annular Preventer 1 13.5/8 _ - -_ P - Manual Chokes 1 P #1 Rams 1 2 7/8x5 1/2' P - Hydraulic Chokes -_ 1 P ' #2 Rams 1 ' Blind/Shear" P ' CH Misc 0 NA #3 Rams 1 2 7/8x5 1/2 - P ' #4 Rams 0 NA #5 Rams _ 0_ _ _ NA_ INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 3 1/8 P - Quantity PIF HCR Valves 2 " 3 1/8 P ' Inside Reel Valves _- 0 NA Kill Line Valves _ 2 - 3 1_/8 _ P ' Check Valve 0 NA BOP Misc 0 NA Number of Failures: 1 -" Test Results Test Time 6.8 Remarks: Tested with 4" and 5" test joints, tested all gas alarms and PVT's. The 5" Dart valve was functioned and passed the retest Closer times, Annular = 21 sec, U Rams = 14 sec., L Rams = 13 sec., B Rams = 13 sec., Kill HCR = 2 sec, Choke HCR = 2 sec., 22 Precharge Bottles with average of 947 psi. ((,-Cri 5,tz- MT7-01 BOP TEST WITH 4" TEST JT. 11-15-21 1/ 1) ANNULAR; CV #1, # 13, # 14,# 15 & 4" KILL ON MUD LINE & 4'/z IF DART 2) UPPER 2 7/8 X 5'h VBR'S, CV #2, #10,#12, HCR KILL, 4'/2 IF FOSV #1. 3) CV #6, #9, #11, MANUAL KILL 4) CV #5, #7 & #8, 4'/s FOSV #2; 5) CV #3, XT-39 DART 6) LOWER 2 7/8 X 5'/z VBR, XT-39 FOSV #1 7) BLINDS, CV#4, XT-39 FOSV #2. 8) SUPER CHOKE; MANUAL CHOKE (2500 PSI) WITH 5" TEST JT. 9) ANNULAR; HCR CHOKE, UPPER IBOP 10) UPPER 2 7/8 X 5'/z VBR'S, MANUAL CHOKE, LOWER IBOP 11) LOWER 2 7/8 X 5%z VBR'S. INITIAL - ACC=3025_ PSI, MAN=_1500_ PSI, AFTER CLOSURE - ACC=_1550 PSI, 200 PSI ATTAINED IN 17 SEC, FULL PRESSURE ATTAINED IN 114 SEC, 6 NITROGEN BOTTLES WITH AN AVERAGE PRESSURE OF _1750_PSI. 22 PRE -CHARGE BOTTLE AVE. 947 From:Rixse, Melvin G (OGC) To:WSC Operations Engineer; Loepp, Victoria T (OGC); Hobbs, Greg S; Livingston, Erica J Cc:Anderson, Nina M; Gorham, Brad; Lee, David L; Njoku, Johnson; WSC Rig Advisor; Mills, Katie A Subject:RE: MT7-01 Int II Cement Evaluation (PTD #221-052) Date:Friday, November 12, 2021 3:50:32 PM Attachments:image001.png WSC Operations Engineer, If your cement job goes well, i.e., bump plug, good returns and lift pressure to carry TOC to 250’ TVD above hydrocarbon zone, etc. then we can wait for the LWD sonic. If your cement job is questionable, plan to run a CBL before drilling production hole. Ideally we would see a log from the shoe to TOC. (I would like to confirm cement across your confining zones.) Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Victoria Loepp From: WSC Operations Engineer <wscopsengineer@conocophillips.com> Sent: Friday, November 12, 2021 3:19 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Cc: Anderson, Nina M <Nina.Anderson@conocophillips.com>; Gorham, Brad <Brad.Gorham@conocophillips.com>; Lee, David L <David.L.Lee@conocophillips.com>; Njoku, Johnson <Johnson.Njoku@conocophillips.com>; WSC Rig Advisor <wscrigadvisor@conocophillips.com>; Mills, Katie A <Katie.A.Mills@conocophillips.com> Subject: MT7-01 Int II Cement Evaluation (PTD #221-052) Hi Mel, Can you please provide some clarification to the PTD regarding the conditions of approval for the intermediate 2 cement CBL required before drilling the production section? In the proposed drilling program ConocoPhillips planned the following after successfully cementing the 7” liner: 1. Pick up and RIH with 6-1/8” drilling assembly. Log top of cement with sonic tool. 2. Chart casing pressure test to 3,500 psi for 30 minutes. 3. Drill out intermediate 2 shoe track and 20’ of new formation. Perform LOT to a maximum of 13.5 ppg EMW. Minimum required leak-off for drilling ahead is 11.0 ppg EMW. 4. Drill 6-1/8” horizontal section to TD. 5. Pull out of hole with drilling BHA. If the 7” cementing operations do not go as per plan, there will be a discussion to obtain TOC and provide to AOGCC prior to drilling out the 7” shoe track. However, if cementing operations go as planned then ConocoPhillips would like to proceed as per the approval and provide the TOC to AOGCC once the drilling assembly is back at surface after drilling the production section to TD. Let us know if you have any concerns with this plan. Thanks, Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) From:Anderson, Nina M To:Loepp, Victoria T (OGC) Cc:WSC Operations Engineer Subject:FW: [EXTERNAL]APPROVAL to proceed with modified cement plug. MT7-01 Int2 Plugback and Sidetrack Request Date:Tuesday, November 2, 2021 4:44:24 PM Attachments:image001.png image001.png image001.png Victoria- I wanted to verify if we have verbal approval to proceed with sidetrack operations once we have confirmed that a successful cement plug was set. Our base plan of sidetracking in open hole is to kick off just below the intermediate 1 casing shoe. KOP will be +/- 9270’ MD with the hopes of getting away from the original wellbore. Operationally we are currently pulling out of hole after setting our cement plug. Please advise if you have any questions or would like additional information in regards to the MT7- 01 sidetrack and redrill of intermediate 2. I will follow up with the 10-403. Thanks, Nina Anderson Alpine Staff Drilling Engineer ConocoPhillips Alaska nina.anderson@conocophillips.com<mailto:nina.anderson@conocophillips.com> Office: (907) 265-6403 Cell: (907) 229-4008 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, November 2, 2021 6:20 AM To: WSC Operations Engineer <wscopsengineer@conocophillips.com> Subject: [EXTERNAL]APPROVAL to proceed with modified cement plug. MT7-01 Int2 Plugback and Sidetrack Request Sydney, Approval is granted to proceed with the modified plug as outlined below. Victoria Sent from my iPhone On Nov 2, 2021, at 4:07 AM, WSC Operations Engineer <wscopsengineer@conocophillips.com> wrote: Good morning, We ran in hole with the cementing string on MT7-01 and are unable to progress past 9,460’ MD. This places us 200’ outside the Intermediate 1 shoe at 9,260’ MD. The wellbore has continued to deteriorate from when we were last at this point. We cannot reach our planned depth for the base of cement of 9,760’ MD to achieve 500’ of cement in open hole as described below. We would like to pump cement at our current location to execute a sidetrack. This is a deviation from the approved plan outlined below. Could we please receive approval to proceed with the amended plan forward for setting cement at the present location? Thank you, Polaris – WSC Operations Engineer Sydney Deering / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Sunday, October 31, 2021 12:08 PM To: WSC Operations Engineer <wscopsengineer@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: [EXTERNAL]APPROVAL to proceed with cement plug. MT7-01 Int2 Plugback and Sidetrack Request CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Sydney, Approval is granted to proceed with the cement plug as outlined below. Please prepare and submit a Sundry for change of approved program as soon as possible. Thanx, Victoria Sent from my iPhone On Oct 31, 2021, at 11:41 AM, WSC Operations Engineer <wscopsengineer@conocophillips.com> wrote: Good morning, We have been experiencing significant issues with the Intermediate 2 wellbore of MT7-01. We drilled the hole to TD, tripped out to the Intermediate 1 shoe, and then attempted to perform the planned short trip. We were unable to progress in hole past 10,370’ MD which is in the Miluveach. The decision was made to recover the BHA while still possible and we assume the shales will continue to deteriorate and we are unable to salvage the wellbore. We will come out of the hole with this BHA. We will test BOP’s before picking up a cement stinger and laying in a 16.5ppg cement plug including 500’ in open hole and 100’ inside the Intermediate 1 shoe. The well will then be sidetracked, and the Intermediate 2 section redrilled. Details for that sidetrack are actively being worked. A sundry for this plan forward is forthcoming. Could we please receive verbal approval to proceed with the plan, as outlined above, with setting a cement plug? Please let me know if you have any questions or concerns. Thank you, Polaris – WSC Operations Engineer Sydney Deering / Scott Kolstad wscopsengineer@conocophillips.com 907.263.4544 (Office) From:WSC Operations Engineer To:Loepp, Victoria T (OGC); Rixse, Melvin G (OGC); Hobbs, Greg S; Livingston, Erica J Cc:Anderson, Nina M; Gorham, Brad; Lee, David L; Njoku, Johnson; WSC Rig Advisor; Zwarich, Nola R; Klem, Adam Subject:MT7-01 Intermediate II Liner (PTD #221-052 Date:Wednesday, November 10, 2021 12:40:28 PM Attachments:image001.png MT7-01 Intermediate II Schematic_R3.pdf Mel, Please see the attached schematic for reference. Doyon 25 conducted a sidetrack off the 16.5 ppg cement kick off plug at 9,360’ MD. The top of the cement plug was tagged inside the 9-7/8” intermediate I casing at 8,866’ MD. Currently Doyon 25 is drilling the intermediate II hole section at 10,000’ MD with a planned TD at 10,752’ MD / 8,315’ TVD in the Alpine D. The plan is to run and cement the 7” liner in place. ConocoPhillips is requesting approval to set the 7” liner top at ~8,710’ MD with a 550’ liner lap above intermediate I casing shoe. The reason for this change is to ensure that the liner top is placed above the 16.5 ppg kick off plug tag depth to ensure no cement sheath present while setting and testing liner top. ConocoPhillips is also requesting approval to place the TOC on the 7” liner at 10,000’ MD / 7,973’ TVD. The planned TOC would be 655’ MD / 312’ TVD above the planned top of Alpine D (originally planned TOC was at the liner top on 7” liner) . The reason for this change is to help reduce the cement column pressure on the wellbore and reduce the potential for losses when the cement is in place as it is approaching the formation break down pressure that was observed on the intermediate II PB1 wellbore of 13.9 ppg EMW. If you have questions or comments please let me know and thanks for your time. Thanks, Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) As Drilled MT7-01 11/6/2021 20" 94# H-40 Welded Conductor to 120' 13-3/8"68# L-80 HYD563 x BTCM 3,424' MD/ 3,050 TVD @ 47⁰ inc 9-5/8" 43.5# L80 TXP x 9-7/8" 62.8# L80 HYD563 9,260' MD/ 7,440' TVD @ 41⁰ inc Planned 8-1/2" x 9-7/8" Intermediate 2 TD In Alpine D 10,752' MD / 8,315' TVD @ 73° inc TOC 7,563' MD/ 6,088' TVD Planned TOC 10,000' MD / 7,973' TVD 8-1/2" x 9-7/8" Intermediate 2 PB1 10,845' MD / 8,313' TVD @ 72.6° inc Sidetrack Off 16.5 ppg KO Plug 9,360' MD Planned Top of 7" Liner 8710' MD / 7004' TVD Planned Top of Alpine D 10,655' MD / 8,285' TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVALS By Samantha Carlisle at 9:10 am, Nov 04, 2021 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑✓ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 221-052 3. Address: 6. API Number: P.O. Box 100360 Anchorage, Alaska 99510-0360 50-103-20832-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 793 MT7-01 Will planned perforations require a spacing exception? Yes ❑ No ❑ NA DLB 9. Property Designation (Lease Number): 10. Field/Pool(s): AA081800, AA081781, AA081803 I Greater Mooses Tooth, Rendezvous 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 80.5 20" 120 120 Surface 3010 13.375 3424 3050 5020 2260 Intermediate1 7511 / 9221 9.625 / 9.875 7551 / 9260 6058 / 7440 6330 / 8860 3810 / 8260 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary /1 Well bore schematic /1 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/3/2021 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Yes Date: 11/2/2021 AOGCC 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. Docusigned b : Contact Name: Nina Anderson Authorized Name and Chris BrilloC NOV-03-2021 nina.andersonCa-DconocoPhilliPs.com Digital Signature with Date: Contact Email: C579E72E81172446... Contact Phone: 907-229-4008 Authorized Title: Wells Engineering Manager AOGCC USE ONLY Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: 321-567 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: BOP test to 3500 psig RBDMS HEW 11/8/2021 Annular preventer test to 2500 psig Intermediate 2 cement CBL required before drilling production hole Post Initial Injection MIT Req'd? Yes ❑ No F Spacing Exception Required? Yes ❑ No ® Subsequent Form Required: 1 0-40,1" Digitally signed by Jeremy Price APPROVED BY Jeremy Price Date:202,.11.0513:02:19 11/5/21 Approved by:-08,00, COMMISSIONER THE AOGCC Date: Comm.dts 11/5/2021 Com Sr Pet Eng VTL 11/5/2 Sr Pet GecDLB 11/04/2021 Isr Res Eng DSR-11/4/21 Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 November 3rd, 2021 Alaska Oil and Gas Conservation Commission 333 West T" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry to Approved Program for MT7-01 Dear Sir or Madam: ConocoPhillips p ConocoPhillips Alaska, Inc. hereby applies for a Sundry to Change Approved Program for MT7-01, an onshore production well from the MT7 drilling pad currently being drilled with the Doyon 25 drilling rig. MT7-01 is planned to be a fracture stimulated horizontal producer within the Rendevouz reservoir. Due to challenges with shale stability while tripping out of the intermediate2 hole section on, Conoco is proposing pump cement to plug back the 8.5" x 9-7/8" Intermediate 2, sidetrack, and redrill the intermediate 2 holesection. The first attempt utilized a inhibited KSi mud system whereas the re -drill will use LSND mud. Sidetrack operations will begin on November 3rd, 2021. Please find attached the information for your review. Pertinent information attached to this application includes the following: 1. Proposed Drilling Program 2. Proposed completion schematic 3. Directional Plan If you have any questions or require further information, please contact Nina Anderson at 229-4008 (nina.andersonC&conocophillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: Docusigned by: MT7-01 Well File / Jenna Taylor ATO 1560 Nov-03-2021 David Lee ATO 1726 Chris Brillon ATO 1548 D9000896C6E049F... 114 Ilia rAIluci Null Drilling Engineer MT7-01 Proposed Sidetrack Program 1. RIH with 3-1/2" cement stinger to below the intermediatel casing shoe 2. Place a +/- 20' gel pill followed by 200' of cement in the OH and +/- 400' of cement inside the 9-7/8" casing. POOH with cement stinger. 3. MU 8-1/2" Intermediate 2 sidetrack BHA 4. RIH with 8-1/2" Intermediate2 BHA 5. Tag TOC 6. If competent cement, drill remaining cement to obtain a successful sidetrack 7. Begin to KO — 9280' MD (— 20' below INT1 shoe) 8. Drill 8-1/2" x 9-7/8" intermediate 2 hole section down to the TD of 10,736' MD 9. Circulate, condition and trip out of hole with BHA 10. Continue with steps to pick up 7" liner and run in hole to TD following the originally approved MT7-014- string program. MT7-01 wp10 P&A Schematic 11 /03/2021 20" 94# H-40 Welded Conductor to 115' Surface Casing 13-3/8" 68 ppf L-80 HYD563 3424' MD / 3050' TVD INTERMEDIATE 1 9 5/8" 43.5 ppf L-80 TXP x (-1600') 9-7/8" 62.8 ppf L-80 400' HYD523 Cement @ inside Shoe +/- 9260' MD / 7440' TVD ii outside shoe 16.5 ... Class G Cement to 46 20' Gel Pill Gel Pill to - •-.i 3-%" Stinger stopped at Bottom of 9-7/8" hole (- 10,744' MD) Bottom of 8-1/2" pilot hole 10,845' MD / 8314' TVD MT7-01_STwp03 4 string Producer, As Drilled / Proposed Completion Schematic Estimated TOC - 500' above Susitna 7587' MD Susitna 8086' MD / 6489' TVD Top HRZ 9227' MD / 7411' TVD Downhole Gauge Production Packer ZXP Liner Top Packer Actual Top Alpine D 10,751' MD / 8285' TVD 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface Tubina / Liner Completion: 1) 4 '/2" X Landing Nipple (3.813" ID) 2) 4-'/2" x 1" KBG-2 GLM (2x) 3) 4-'/2" x 1" KBG-2 4-5 GLM (1 x) 4) HES Downhole Gauge 5) 4-'/2" Baker Premier Production Packer 6) 4-'/2" DB Landing Nipple w/DFCV (3.75" ID) 7) Liner Top Packer / Hanger w/ Tie Back sleeve Surface Casino 13-3/8" 68 ppf L-80 HYD563 3424' MD / 3050' TVD 4-1/2" 12.6 ppf L-80 HYD563 Estimate INT2 TOC — Top of 7" LTP located +/-100' overlap into 9-7/8" casing @ 9147' MD INTERMEDIATE 1 9 5/8" 43.5 ppf L-80 TXP x (--1600') 9-7/8" 62.8 ppf L-80 HYD523 @ +/- 9260' MD / 7440' TVD INTERMEDIATE 2 7" 26 ppf L-80 HYD563 Liner 10,736' MD / 8310' TVD O EO T� O C --------- 4-1/2" 12.6# L-80 HYD563 Liner w/ frac ports and perf joints TD @ 20,736' MD / 8294' TVD ------------------ 1 6-1/8" Hole, TD UPDATED: 110221 ConocoPhillips Alaska Inc_WNS Western North Slope GMT2 Rendezvous Pad MT7-01 50103xxxxx00 MT7-01 Plan: MT7-01_wp03 Standard Proposal Report 03 November, 2021 ConocoPh i I I i ps �� ConocoPhillips Baker Hughes Standard Proposal Report Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 Wellbore: MT7-01 Design: MT7-01_wp03 Local Co-ordinate Reference: Well MT7-01 TVD Reference: Actual 100.7 + 38.71 @ 139.41 usft MD Reference: Actual 100.7 + 38.71 @ 139.41 usft North Reference: True Survey Calculation Method: Minimum Curvature Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site GMT2 Rendezvous Pad Site Position: Northing: 5,915,580.00 usft Latitude: 70' 10' 22.674 N From: Map Easting: 1,430,062.00 usft Longitude: 151' 41' 36.331 W Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: -1.59 ° Well MT7-01, GMT2 SW0l-107 Well Position +N/-S 0.08 usft Northing: 5,915,580.08 usft Latitude: 70' 10' 22.675 N +E/-W -0.16 usft Easting: 1,430,061.84 usft Longitude: 151' 41' 36.336 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 100.70 usft Wellbore MT7-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (') V) (nT) BGGM2020 10/29/2021 14.69 80.40 57,141.64 Design MT7-01_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,287.43 Vertical Section: Depth From (TVD) +NI-S +E/-W Direction (usft) (usft) (usft) (I 38.71 0.00 0.00 309.49 Plan Survey Tool Program Date 11/3/2021 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 9,287.43 9,487.00 MT7-01_wp03 (MT7-01) MWD-INC_ONLY (INC>10°) MWD-INC_ONLY_FILLER (IN 2 9,487.00 10,000.00 MT7-01_wp03 (MT7-01) MWD OWSG OWSG MWD - Standard 3 10,000.00 10,776.00 MT7-01_wp03(MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + D 4 10,776.00 10,976.00 MT7-01_wp03 (MT7-01) MWD-INC_ONLY (INC>10°) MWD-INC_ONLY_FILLER (IN 5 10,976.00 11,100.00 MT7-01_wp03 (MT7-01) MWD OWSG OWSG MWD - Standard 6 11,100.00 23,693.75 MT7-01_wp03(MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + P 111312021 1:59:40PM Page 2 COMPASS 5000.15 Build 91E ConocoPhillips Baker Hughes Standard Proposal Report Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 Wellbore: MT7-01 Design: MT7-01_wp03 Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Plan Sections Measured Vertical Depth Inclination Azimuth Depth +N/-S +E/-W (usft) (°) (°) (usft) (usft) (usft) 9,287.43 41.04 281.91 7,460.90 -4,248.40 -2,092.61 9,347.43 39.24 281.91 7,506.76 -4,240.42 -2,130.46 9,497.43 39.24 281.91 7,622.94 4,220.84 -2,223.30 10,736.53 73.00 306.00 8,310.48 -3,774.46 -3,120.76 10,776.53 73.00 306.00 8,322.18 -3,751.98 -3,151.71 11,498.51 90.00 323.10 8,429.28 -3,253.11 -3,655.08 11,598.51 90.00 323.10 8,429.28 -3,173.14 -3,715.12 11,932.26 90.86 333.08 8,426.78 -2,890.21 -3,891.32 23,693.75 90.86 333.08 8,251.26 7,595.30 -9,216.37 Well MT7-01 Actual 100.7 + 38.71 @ 139.41 usft Actual 100.7 + 38.71 @ 139.41 usft True Minimum Curvature Dogleg Build Turn Rate Rate Rate (°I100usft) (°/100usft) (°I100usft) 0.00 0.00 0.00 3.00 -3.00 0.00 0.00 0.00 0.00 3.14 2.72 1.94 0.00 0.00 0.00 3.31 2.35 2.37 0.00 0.00 0.00 3.00 0.26 2.99 0.00 0.00 0.00 TFO (°) Target 0.00 180.00 0.00 38.47 0.00 46.46 0.00 85.08 0.00 MT7-01 TD 102720 IV 111312021 1:59:40PM Page 3 COMPASS 5000.15 Build 91E Baker Hughes ConocoPhi I I i ps Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Actual 100.7 + 38.71 @ 139.41 usft Project: Western North Slope MD Reference: Actual 100.7 + 38.71 @ 139.41 usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01_wp03 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) (°/100usft) (°/100usft) (°/100usft) -0.09 0.00 0.00 -0.09 0.00 0.00 0.00 0.00 0.00 0.00 38.71 0.00 249.90 38.71 0.00 0.00 0.00 0.00 0.00 0.00 110.51 0.26 249.90 110.51 -0.06 -0.15 0.08 0.36 0.36 0.00 205.77 0.35 260.16 205.77 -0.18 -0.64 0.38 0.11 0.09 10.77 237.61 0.44 263.32 237.61 -0.21 -0.86 0.53 0.29 0.28 9.92 329.63 0.62 268.95 329.62 -0.26 -1.71 1.15 0.20 0.20 6.12 421.50 0.79 270.70 421.49 -0.26 -2.84 2.02 0.19 0.19 1.90 514.40 1.14 271.76 514.37 -0.23 -4.40 3.25 0.38 0.38 1.14 608.80 1.58 278.44 608.75 -0.01 -6.63 5.11 0.49 0.47 7.08 702.82 1.76 261.91 702.73 -0.02 -9.34 7.20 0.54 0.19 -17.58 796.54 2.29 237.30 796.39 -1.23 -12.34 8.74 1.07 0.57 -26.26 822.35 2.54 235.13 822.18 -1.84 -13.24 9.05 1.03 0.97 -8.41 916.79 4.17 211.72 916.46 -5.96 -16.77 9.15 2.22 1.73 -24.79 1,010.98 5.84 204.87 1,010.28 -13.22 -20.58 7.48 1.88 1.77 -7.27 1,104.29 7.54 203.40 1,102.96 -23.14 -25.01 4.58 1.83 1.82 -1.58 1,292.72 10.21 199.93 1,289.11 -50.20 -35.62 -4.44 1.44 1.42 -1.84 1,386.52 11.35 198.91 1,381.26 -66.74 -41.44 -10.47 1.23 1.22 -1.09 1,482.75 13.53 197.63 1,475.22 -86.43 -47.92 -17.99 2.28 2.27 -1.33 1,576.18 15.03 195.24 1,565.76 -108.54 -54.41 -27.03 1.72 1.61 -2.56 1,670.00 17.36 195.26 1,655.85 -133.78 -61.30 -37.78 2.48 2.48 0.02 1,764.77 19.29 196.42 1,745.82 -162.44 -69.44 -49.72 2.07 2.04 1.22 1,858.43 22.13 196.37 1,833.41 -194.21 -78.79 -62.71 3.03 3.03 -0.05 1,950.44 25.01 197.33 1,917.74 -229.41 -89.47 -76.85 3.16 3.13 1.04 2,044.37 27.74 199.18 2,001.89 -269.02 -102.57 -91.94 3.03 2.91 1.97 2,138.73 30.19 200.06 2,084.44 -312.06 -117.93 -107.46 2.64 2.60 0.93 2,233.66 32.92 200.06 2,165.32 -358.72 -134.96 -123.98 2.88 2.88 0.00 2,328.59 35.67 199.99 2,243.74 -408.97 -153.28 -141.81 2.90 2.90 -0.07 2,422.68 38.00 199.45 2,319.04 -462.07 -172.30 -160.89 2.50 2.48 -0.57 2,517.43 40.03 200.04 2,392.66 -518.20 -192.46 -181.04 2.18 2.14 0.62 2,611.99 40.04 200.33 2,465.06 -575.29 -213.45 -201.15 0.20 0.01 0.31 2,705.40 41.35 200.39 2,535.88 -632.39 -234.64 -221.11 1.40 1.40 0.06 2,799.40 42.61 199.83 2,605.76 -691.43 -256.25 -241.98 1.40 1.34 -0.60 2,894.06 43.02 200.49 2,675.19 -751.82 -278.42 -263.28 0.64 0.43 0.70 2,988.61 43.39 200.42 2,744.11 -812.47 -301.05 -284.39 0.39 0.39 -0.07 3,082.01 44.15 199.44 2,811.56 -873.21 -323.06 -306.03 1.09 0.81 -1.05 3,176.55 44.90 198.45 2,878.96 -935.91 -344.58 -329.30 1.08 0.79 -1.05 3,270.77 45.95 198.47 2,945.09 -999.57 -365.83 -353.38 1.11 1.11 0.02 3,356.49 46.89 198.58 3,004.18 -1,058.45 -385.56 -375.60 1.10 1.10 0.13 3,466.66 46.89 199.37 3,079.47 -1,134.51 -411.72 -403.79 0.52 0.00 0.72 3,560.04 44.95 199.40 3,144.43 -1,197.79 -433.98 -426.85 2.08 -2.08 0.03 3,653.45 44.44 199.90 3,210.83 -1,259.66 -456.07 -449.15 0.66 -0.55 0.54 3,747.42 42.72 199.39 3,278.90 -1,320.66 -477.85 -471.14 1.87 -1.83 -0.54 3,842.12 42.79 198.32 3,348.44 -1,381.50 -498.63 -493.80 0.77 0.07 -1.13 3,936.08 42.86 197.47 3,417.35 -1,442.28 -518.25 -517.31 0.62 0.07 -0.90 4,030.92 42.58 196.76 3,487.03 -1,503.77 -537.19 -541.80 0.59 -0.30 -0.75 4,125.42 42.44 197.77 3,556.69 -1,564.75 -556.14 -565.96 0.74 -0.15 1.07 4,220.08 42.52 197.73 3,626.50 -1,625.63 -575.63 -589.64 0.09 0.08 -0.04 4,313.05 42.38 196.35 3,695.10 -1,685.62 -594.02 -613.60 1.01 -0.15 -1.48 4,408.10 42.46 195.49 3,765.27 -1,747.28 -611.60 -639.24 0.62 0.08 -0.90 4,502.03 42.47 196.38 3,834.56 -1,808.26 -629.01 -664.59 0.64 0.01 0.95 4,596.52 42.57 197.23 3,904.21 -1,869.39 -647.48 -689.22 0.62 0.11 0.90 4,690.99 42.60 198.09 3,973.76 -1,930.30 -666.87 -712.99 0.62 0.03 0.91 4,785.52 42.62 198.18 4,043.34 -1,991.12 -686.79 -736.30 0.07 0.02 0.10 4,880.35 42.57 197.91 4,113.14 -2,052.14 -706.67 -759.77 0.20 -0.05 -0.28 111312021 1:59:40PM Page 4 COMPASS 5000.15 Build 91E Baker Hughes ConocoPhi I I i ps Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Actual 100.7 + 38.71 @ 139.41 usft Project: Western North Slope MD Reference: Actual 100.7 + 38.71 @ 139.41 usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01_wp03 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) (°/100usft) (°/100usft) (°/100usft) 4,974.04 42.63 197.38 4,182.11 -2,112.58 -725.89 -783.36 0.39 0.06 -0.57 5,068.49 42.58 198.30 4,251.63 -2,173.44 -745.48 -806.96 0.66 -0.05 0.97 5,162.21 42.48 200.19 4,320.70 -2,233.25 -766.36 -828.88 1.37 -0.11 2.02 5,255.65 42.62 200.36 4,389.53 -2,292.52 -788.25 -849.68 0.19 0.15 0.18 5,349.92 42.55 200.39 4,458.94 -2,352.32 -810.46 -870.57 0.08 -0.07 0.03 5,444.21 42.56 200.58 4,528.40 -2,412.05 -832.78 -891.34 0.14 0.01 0.20 5,538.83 42.62 201.23 4,598.06 -2,471.87 -855.63 -911.75 0.47 0.06 0.69 5,632.32 42.56 202.24 4,666.89 -2,530.64 -879.06 -931.04 0.73 -0.06 1.08 5,726.39 42.42 202.73 4,736.26 -2,589.35 -903.36 -949.63 0.38 -0.15 0.52 5,821.18 42.60 201.50 4,806.13 -2,648.69 -927.47 -968.76 0.90 0.19 -1.30 5,915.88 42.57 201.49 4,875.86 -2,708.31 -950.95 -988.56 0.03 -0.03 -0.01 6,010.37 42.57 201.04 4,945.44 -2,767.88 -974.13 -1,008.55 0.32 0.00 -0.48 6,104.40 42.60 201.17 5,014.68 -2,827.24 -997.04 -1,028.62 0.10 0.03 0.14 6,198.99 42.35 201.25 5,084.44 -2,886.79 -1,020.15 -1,048.66 0.27 -0.26 0.08 6,293.35 42.13 199.55 5,154.30 -2,946.24 -1,042.26 -1,069.40 1.23 -0.23 -1.80 6,387.64 42.61 198.47 5,223.97 -3,006.31 -1,062.96 -1,091.64 0.92 0.51 -1.15 6,486.21 42.65 196.72 5,296.49 -3,069.94 -1,083.14 -1,116.54 1.20 0.04 -1.78 6,576.58 42.60 196.32 5,362.99 -3,128.62 -1,100.54 -1,140.42 0.30 -0.06 -0.44 6,671.07 42.60 196.85 5,432.54 -3,189.91 -1,118.79 -1,165.32 0.38 0.00 0.56 6,766.06 42.61 197.14 5,502.46 -3,251.41 -1,137.59 -1,189.92 0.21 0.01 0.31 6,860.28 42.58 196.99 5,571.82 -3,312.37 -1,156.30 -1,214.25 0.11 -0.03 -0.16 6,954.09 42.58 197.61 5,640.89 -3,372.97 -1,175.18 -1,238.22 0.45 0.00 0.66 7,048.92 42.57 198.60 5,710.73 -3,433.95 -1,195.11 -1,261.62 0.71 -0.01 1.04 7,143.76 42.58 199.25 5,780.57 -3,494.64 -1,215.92 -1,284.16 0.46 0.01 0.69 7,238.24 42.51 199.67 5,850.17 -3,554.88 -1,237.21 -1,306.04 0.31 -0.07 0.44 7,332.55 42.49 199.39 5,919.71 -3,614.93 -1,258.51 -1,327.80 0.20 -0.02 -0.30 7,426.88 42.44 199.63 5,989.29 -3,674.96 -1,279.78 -1,349.56 0.18 -0.05 0.25 7,521.25 42.52 199.62 6,058.89 -3,734.99 -1,301.18 -1,371.22 0.09 0.08 -0.01 7,615.71 42.47 199.52 6,128.54 -3,795.11 -1,322.56 -1,392.96 0.09 -0.05 -0.11 7,710.00 42.30 199.72 6,198.19 -3,854.98 -1,343.90 -1,414.57 0.23 -0.18 0.21 7,804.00 40.59 201.97 6,268.65 -3,913.13 -1,366.01 -1,434.48 2.41 -1.82 2.39 7,897.32 38.72 207.74 6,340.52 -3,967.14 -1,390.97 -1,449.57 4.42 -2.00 6.18 7,991.20 37.25 213.70 6,414.53 -4,016.78 -1,420.41 -1,458.42 4.21 -1.57 6.35 8,083.73 36.17 219.37 6,488.73 -4,061.20 -1,453.28 -1,461.31 3.84 -1.17 6.13 8,178.85 35.36 223.56 6,565.93 -4,102.85 -1,490.06 -1,459.41 2.71 -0.85 4.40 8,272.77 34.79 228.92 6,642.81 -4,140.16 -1,528.99 -1,453.09 3.33 -0.61 5.71 8,367.46 34.28 234.52 6,720.83 -4,173.40 -1,571.08 -1,441.75 3.39 -0.54 5.91 8,460.84 34.10 239.76 6,798.09 -4,201.85 -1,615.12 -1,425.86 3.16 -0.19 5.61 8,555.08 34.19 245.47 6,876.11 -4,226.16 -1,662.04 -1,405.11 3.40 0.10 6.06 8,649.39 34.24 251.12 6,954.11 -4,245.75 -1,711.27 -1,379.58 3.37 0.05 5.99 8,743.83 34.69 256.41 7,032.00 -4,260.66 -1,762.54 -1,349.50 3.20 0.48 5.60 8,837.81 35.63 262.41 7,108.85 -4,270.57 -1,815.69 -1,314.78 3.81 1.00 6.38 8,932.02 36.73 268.25 7,184.92 -4,275.05 -1,871.06 -1,274.90 3.84 1.17 6.20 9,025.97 37.74 273.48 7,259.73 -4,274.16 -1,927.86 -1,230.51 3.53 1.08 5.57 9,120.11 39.12 277.79 7,333.49 -4,268.39 -1,986.05 -1,181.92 3.20 1.47 4.58 9,214.35 40.81 281.54 7,405.73 -4,258.20 -2,045.70 -1,129.42 3.12 1.79 3.98 9,232.36 40.98 281.77 7,419.34 -4,255.81 -2,057.24 -1,118.99 1.26 0.94 1.28 9,260.00 41.01 281.84 7,440.20 -4,252.10 -2,074.99 -1,102.93 0.20 0.11 0.25 9 7/8" x 12 1/4" 9,287.43 41.04 281.91 7,460.90 -4,248.40 -2,092.61 -1,086.98 0.20 0.11 0.25 9,300.00 40.66 281.91 7,470.41 -4,246.70 -2,100.66 -1,079.69 3.00 -3.00 0.00 9,347.43 39.24 281.91 7,506.76 -4,240.42 -2,130.46 -1,052.70 3.00 -3.00 0.00 9,400.00 39.24 281.91 7,547.48 -4,233.55 -2,162.99 -1,023.22 0.00 0.00 0.00 111312021 1:59:40PM Page 5 COMPASS 5000.15 Build 91E Baker Hughes ConocoPhi I I i ps Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Actual 100.7 + 38.71 @ 139.41 usft Project: Western North Slope MD Reference: Actual 100.7 + 38.71 @ 139.41 usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01_wp03 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) (°/100usft) (°/100usft) (°/100usft) 9,497.43 39.24 281.91 7,622.94 -4,220.84 -2,223.30 -968.60 0.00 0.00 0.00 9,500.00 39.30 281.99 7,624.93 -4,220.50 -2,224.89 -967.15 3.14 2.46 3.08 9,600.00 41.80 284.91 7,700.91 -4,205.34 -2,288.09 -908.74 3.14 2.50 2.92 9,700.00 44.36 287.56 7,773.95 -4,186.21 -2,353.64 -845.99 3.14 2.56 2.65 9,800.00 46.98 289.97 7,843.83 -4,163.17 -2,421.34 -779.09 3.14 2.62 2.41 9,900.00 49.64 292.19 7,910.34 -4,136.29 -2,491.00 -708.24 3.14 2.66 2.21 10,000.00 52.35 294.23 7,973.27 -4,105.64 -2,562.39 -633.65 3.14 2.70 2.05 10,100.00 55.08 296.13 8,032.45 -4,071.32 -2,635.32 -555.55 3.14 2.74 1.90 10,200.00 57.85 297.91 8,087.69 -4,033.44 -2,709.55 -474.17 3.14 2.76 1.78 10,300.00 60.64 299.58 8,138.83 -3,992.10 -2,784.88 -389.75 3.14 2.79 1.67 10,400.00 63.44 301.17 8,185.71 -3,947.43 -2,861.06 -302.55 3.14 2.81 1.58 10,500.00 66.27 302.67 8,228.19 -3,899.56 -2,937.88 -212.82 3.14 2.82 1.51 10,600.00 69.11 304.12 8,266.16 -3,848.64 -3,015.10 -120.85 3.14 2.84 1.44 10,700.00 71.96 305.50 8,299.48 -3,794.81 -3,092.50 -26.89 3.14 2.85 1.39 10,736.53 73.00 306.00 8,310.48 -3,774.46 -3,120.77 7.87 3.14 2.86 1.36 7-5/8" x 9-7/8" 10,776.53 73.00 306.00 8,322.18 -3,751.98 -3,151.71 46.05 0.00 0.00 0.00 10,800.00 73.54 306.59 8,328.93 -3,738.67 -3,169.83 68.49 3.31 2.29 2.51 10,900.00 75.84 309.06 8,355.34 -3,679.53 -3,246.00 164.89 3.31 2.30 2.47 11,000.00 78.17 311.48 8,377.83 -3,616.55 -3,320.33 262.30 3.31 2.33 2.42 11,100.00 80.52 313.86 8,396.32 -3,549.94 -3,392.57 360.41 3.31 2.35 2.38 11,200.00 82.89 316.21 8,410.75 -3,479.94 -3,462.49 458.89 3.31 2.37 2.35 11,300.00 85.26 318.53 8,421.07 -3,406.77 -3,529.84 557.40 3.31 2.38 2.32 11,400.00 87.65 320.84 8,427.26 -3,330.68 -3,594.41 655.62 3.31 2.38 2.31 11,498.51 90.00 323.10 8,429.28 -3,253.11 -3,655.08 751.77 3.31 2.39 2.30 11,500.00 90.00 323.10 8,429.28 -3,251.92 -3,655.98 753.22 0.00 0.00 0.00 11,598.51 90.00 323.10 8,429.28 -3,173.14 -3,715.12 848.96 0.00 0.00 0.00 11,600.00 90.00 323.14 8,429.28 -3,171.95 -3,716.02 850.41 3.00 0.26 2.99 11,692.97 90.24 325.92 8,429.08 -3,096.24 -3,769.96 940.19 3.00 0.26 2.99 MT7-01 _L a n d i n g_07162021 11,700.00 90.26 326.13 8,429.05 -3,090.41 -3,773.89 946.93 3.00 0.26 2.99 11,800.00 90.52 329.12 8,428.37 -3,005.96 -3,827.42 1,041.95 3.00 0.26 2.99 11,900.00 90.77 332.11 8,427.24 -2,918.84 -3,876.47 1,135.21 3.00 0.26 2.99 11,932.26 90.86 333.08 8,426.78 -2,890.21 -3,891.32 1,164.88 3.00 0.25 2.99 12,000.00 90.86 333.08 8,425.77 -2,829.81 -3,921.99 1,226.96 0.00 0.00 0.00 12,100.00 90.86 333.08 8,424.28 -2,740.66 -3,967.27 1,318.59 0.00 0.00 0.00 12,200.00 90.86 333.08 8,422.79 -2,651.51 -4,012.54 1,410.23 0.00 0.00 0.00 12,300.00 90.86 333.08 8,421.30 -2,562.36 -4,057.82 1,501.87 0.00 0.00 0.00 12,400.00 90.86 333.08 8,419.80 -2,473.21 -4,103.09 1,593.51 0.00 0.00 0.00 12,500.00 90.86 333.08 8,418.31 -2,384.06 -4,148.37 1,685.14 0.00 0.00 0.00 12,600.00 90.86 333.08 8,416.82 -2,294.91 -4,193.64 1,776.78 0.00 0.00 0.00 12,700.00 90.86 333.08 8,415.33 -2,205.75 -4,238.92 1,868.42 0.00 0.00 0.00 12,800.00 90.86 333.08 8,413.83 -2,116.60 -4,284.19 1,960.05 0.00 0.00 0.00 12,900.00 90.86 333.08 8,412.34 -2,027.45 -4,329.47 2,051.69 0.00 0.00 0.00 13,000.00 90.86 333.08 8,410.85 -1,938.30 -4,374.74 2,143.33 0.00 0.00 0.00 13,100.00 90.86 333.08 8,409.36 -1,849.15 -4,420.02 2,234.97 0.00 0.00 0.00 13,200.00 90.86 333.08 8,407.86 -1,760.00 -4,465.30 2,326.60 0.00 0.00 0.00 13,300.00 90.86 333.08 8,406.37 -1,670.85 -4,510.57 2,418.24 0.00 0.00 0.00 13,400.00 90.86 333.08 8,404.88 -1,581.70 -4,555.85 2,509.88 0.00 0.00 0.00 13,500.00 90.86 333.08 8,403.39 -1,492.55 -4,601.12 2,601.51 0.00 0.00 0.00 13,600.00 90.86 333.08 8,401.89 -1,403.39 -4,646.40 2,693.15 0.00 0.00 0.00 13,700.00 90.86 333.08 8,400.40 -1,314.24 -4,691.67 2,784.79 0.00 0.00 0.00 13,800.00 90.86 333.08 8,398.91 -1,225.09 -4,736.95 2,876.43 0.00 0.00 0.00 13,900.00 90.86 333.08 8,397.42 -1,135.94 -4,782.22 2,968.06 0.00 0.00 0.00 111312021 1:59:40PM Page 6 COMPASS 5000.15 Build 91E Baker Hughes ConocoPhi I I i ps Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Actual 100.7 + 38.71 @ 139.41 usft Project: Western North Slope MD Reference: Actual 100.7 + 38.71 @ 139.41 usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01_wp03 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) (°/100usft) (°/100usft) (°/100usft) 14,000.00 90.86 333.08 8,395.93 -1,046.79 -4,827.50 3,059.70 0.00 0.00 0.00 14,100.00 90.86 333.08 8,394.43 -957.64 -4,872.77 3,151.34 0.00 0.00 0.00 14,200.00 90.86 333.08 8,392.94 -868.49 -4,918.05 3,242.97 0.00 0.00 0.00 14,300.00 90.86 333.08 8,391.45 -779.34 -4,963.32 3,334.61 0.00 0.00 0.00 14,400.00 90.86 333.08 8,389.96 -690.19 -5,008.60 3,426.25 0.00 0.00 0.00 14,500.00 90.86 333.08 8,388.46 -601.03 -5,053.87 3,517.89 0.00 0.00 0.00 14,600.00 90.86 333.08 8,386.97 -511.88 -5,099.15 3,609.52 0.00 0.00 0.00 14,700.00 90.86 333.08 8,385.48 -422.73 -5,144.42 3,701.16 0.00 0.00 0.00 14,800.00 90.86 333.08 8,383.99 -333.58 -5,189.70 3,792.80 0.00 0.00 0.00 14,900.00 90.86 333.08 8,382.49 -244.43 -5,234.98 3,884.44 0.00 0.00 0.00 15,000.00 90.86 333.08 8,381.00 -155.28 -5,280.25 3,976.07 0.00 0.00 0.00 15,100.00 90.86 333.08 8,379.51 -66.13 -5,325.53 4,067.71 0.00 0.00 0.00 15,200.00 90.86 333.08 8,378.02 23.02 -5,370.80 4,159.35 0.00 0.00 0.00 15,300.00 90.86 333.08 8,376.52 112.17 -5,416.08 4,250.98 0.00 0.00 0.00 15,400.00 90.86 333.08 8,375.03 201.33 -5,461.35 4,342.62 0.00 0.00 0.00 15,500.00 90.86 333.08 8,373.54 290.48 -5,506.63 4,434.26 0.00 0.00 0.00 15,600.00 90.86 333.08 8,372.05 379.63 -5,551.90 4,525.90 0.00 0.00 0.00 15,700.00 90.86 333.08 8,370.56 468.78 -5,597.18 4,617.53 0.00 0.00 0.00 15,800.00 90.86 333.08 8,369.06 557.93 -5,642.45 4,709.17 0.00 0.00 0.00 15,900.00 90.86 333.08 8,367.57 647.08 -5,687.73 4,800.81 0.00 0.00 0.00 16,000.00 90.86 333.08 8,366.08 736.23 -5,733.00 4,892.44 0.00 0.00 0.00 16,100.00 90.86 333.08 8,364.59 825.38 -5,778.28 4,984.08 0.00 0.00 0.00 16,200.00 90.86 333.08 8,363.09 914.53 -5,823.55 5,075.72 0.00 0.00 0.00 16,300.00 90.86 333.08 8,361.60 1,003.69 -5,868.83 5,167.36 0.00 0.00 0.00 16,400.00 90.86 333.08 8,360.11 1,092.84 -5,914.10 5,258.99 0.00 0.00 0.00 16,500.00 90.86 333.08 8,358.62 1,181.99 -5,959.38 5,350.63 0.00 0.00 0.00 16,600.00 90.86 333.08 8,357.12 1,271.14 -6,004.66 5,442.27 0.00 0.00 0.00 16,700.00 90.86 333.08 8,355.63 1,360.29 -6,049.93 5,533.90 0.00 0.00 0.00 16,800.00 90.86 333.08 8,354.14 1,449.44 -6,095.21 5,625.54 0.00 0.00 0.00 16,900.00 90.86 333.08 8,352.65 1,538.59 -6,140.48 5,717.18 0.00 0.00 0.00 17,000.00 90.86 333.08 8,351.15 1,627.74 -6,185.76 5,808.82 0.00 0.00 0.00 17,100.00 90.86 333.08 8,349.66 1,716.89 -6,231.03 5,900.45 0.00 0.00 0.00 17,200.00 90.86 333.08 8,348.17 1,806.05 -6,276.31 5,992.09 0.00 0.00 0.00 17,300.00 90.86 333.08 8,346.68 1,895.20 -6,321.58 6,083.73 0.00 0.00 0.00 17,400.00 90.86 333.08 8,345.19 1,984.35 -6,366.86 6,175.37 0.00 0.00 0.00 17,500.00 90.86 333.08 8,343.69 2,073.50 -6,412.13 6,267.00 0.00 0.00 0.00 17,600.00 90.86 333.08 8,342.20 2,162.65 -6,457.41 6,358.64 0.00 0.00 0.00 17,700.00 90.86 333.08 8,340.71 2,251.80 -6,502.68 6,450.28 0.00 0.00 0.00 17,800.00 90.86 333.08 8,339.22 2,340.95 -6,547.96 6,541.91 0.00 0.00 0.00 17,900.00 90.86 333.08 8,337.72 2,430.10 -6,593.23 6,633.55 0.00 0.00 0.00 18,000.00 90.86 333.08 8,336.23 2,519.25 -6,638.51 6,725.19 0.00 0.00 0.00 18,100.00 90.86 333.08 8,334.74 2,608.41 -6,683.78 6,816.83 0.00 0.00 0.00 18,200.00 90.86 333.08 8,333.25 2,697.56 -6,729.06 6,908.46 0.00 0.00 0.00 18,300.00 90.86 333.08 8,331.75 2,786.71 -6,774.34 7,000.10 0.00 0.00 0.00 18,400.00 90.86 333.08 8,330.26 2,875.86 -6,819.61 7,091.74 0.00 0.00 0.00 18,500.00 90.86 333.08 8,328.77 2,965.01 -6,864.89 7,183.37 0.00 0.00 0.00 18,600.00 90.86 333.08 8,327.28 3,054.16 -6,910.16 7,275.01 0.00 0.00 0.00 18,700.00 90.86 333.08 8,325.78 3,143.31 -6,955.44 7,366.65 0.00 0.00 0.00 18,800.00 90.86 333.08 8,324.29 3,232.46 -7,000.71 7,458.29 0.00 0.00 0.00 18,900.00 90.86 333.08 8,322.80 3,321.61 -7,045.99 7,549.92 0.00 0.00 0.00 19,000.00 90.86 333.08 8,321.31 3,410.77 -7,091.26 7,641.56 0.00 0.00 0.00 19,100.00 90.86 333.08 8,319.82 3,499.92 -7,136.54 7,733.20 0.00 0.00 0.00 19,200.00 90.86 333.08 8,318.32 3,589.07 -7,181.81 7,824.83 0.00 0.00 0.00 19,300.00 90.86 333.08 8,316.83 3,678.22 -7,227.09 7,916.47 0.00 0.00 0.00 111312021 1:59:40PM Page 7 COMPASS 5000.15 Build 91 E Baker Hughes ConocoPhi I I i ps Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Actual 100.7 + 38.71 @ 139.41 usft Project: Western North Slope MD Reference: Actual 100.7 + 38.71 @ 139.41 usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01_wp03 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) (°/100usft) (°/100usft) (°/100usft) 19,400.00 90.86 333.08 8,315.34 3,767.37 -7,272.36 8,008.11 0.00 0.00 0.00 19,500.00 90.86 333.08 8,313.85 3,856.52 -7,317.64 8,099.75 0.00 0.00 0.00 19,600.00 90.86 333.08 8,312.35 3,945.67 -7,362.91 8,191.38 0.00 0.00 0.00 19,700.00 90.86 333.08 8,310.86 4,034.82 -7,408.19 8,283.02 0.00 0.00 0.00 19,800.00 90.86 333.08 8,309.37 4,123.97 -7,453.47 8,374.66 0.00 0.00 0.00 19,900.00 90.86 333.08 8,307.88 4,213.13 -7,498.74 8,466.30 0.00 0.00 0.00 20,000.00 90.86 333.08 8,306.38 4,302.28 -7,544.02 8,557.93 0.00 0.00 0.00 20,100.00 90.86 333.08 8,304.89 4,391.43 -7,589.29 8,649.57 0.00 0.00 0.00 20,200.00 90.86 333.08 8,303.40 4,480.58 -7,634.57 8,741.21 0.00 0.00 0.00 20,300.00 90.86 333.08 8,301.91 4,569.73 -7,679.84 8,832.84 0.00 0.00 0.00 20,400.00 90.86 333.08 8,300.41 4,658.88 -7,725.12 8,924.48 0.00 0.00 0.00 20,500.00 90.86 333.08 8,298.92 4,748.03 -7,770.39 9,016.12 0.00 0.00 0.00 20,600.00 90.86 333.08 8,297.43 4,837.18 -7,815.67 9,107.76 0.00 0.00 0.00 20,700.00 90.86 333.08 8,295.94 4,926.33 -7,860.94 9,199.39 0.00 0.00 0.00 20,800.00 90.86 333.08 8,294.45 5,015.49 -7,906.22 9,291.03 0.00 0.00 0.00 20,900.00 90.86 333.08 8,292.95 5,104.64 -7,951.49 9,382.67 0.00 0.00 0.00 21,000.00 90.86 333.08 8,291.46 5,193.79 -7,996.77 9,474.30 0.00 0.00 0.00 21,100.00 90.86 333.08 8,289.97 5,282.94 -8,042.04 9,565.94 0.00 0.00 0.00 21,200.00 90.86 333.08 8,288.48 5,372.09 -8,087.32 9,657.58 0.00 0.00 0.00 21,300.00 90.86 333.08 8,286.98 5,461.24 -8,132.59 9,749.22 0.00 0.00 0.00 21,400.00 90.86 333.08 8,285.49 5,550.39 -8,177.87 9,840.85 0.00 0.00 0.00 21,500.00 90.86 333.08 8,284.00 5,639.54 -8,223.15 9,932.49 0.00 0.00 0.00 21,600.00 90.86 333.08 8,282.51 5,728.69 -8,268.42 10,024.13 0.00 0.00 0.00 21,700.00 90.86 333.08 8,281.01 5,817.85 -8,313.70 10,115.76 0.00 0.00 0.00 21,800.00 90.86 333.08 8,279.52 5,907.00 -8,358.97 10,207.40 0.00 0.00 0.00 21,900.00 90.86 333.08 8,278.03 5,996.15 -8,404.25 10,299.04 0.00 0.00 0.00 22,000.00 90.86 333.08 8,276.54 6,085.30 -8,449.52 10,390.68 0.00 0.00 0.00 22,100.00 90.86 333.08 8,275.04 6,174.45 -8,494.80 10,482.31 0.00 0.00 0.00 22,200.00 90.86 333.08 8,273.55 6,263.60 -8,540.07 10,573.95 0.00 0.00 0.00 22,300.00 90.86 333.08 8,272.06 6,352.75 -8,585.35 10,665.59 0.00 0.00 0.00 22,400.00 90.86 333.08 8,270.57 6,441.90 -8,630.62 10,757.23 0.00 0.00 0.00 22,500.00 90.86 333.08 8,269.08 6,531.05 -8,675.90 10,848.86 0.00 0.00 0.00 22,600.00 90.86 333.08 8,267.58 6,620.21 -8,721.17 10,940.50 0.00 0.00 0.00 22,700.00 90.86 333.08 8,266.09 6,709.36 -8,766.45 11,032.14 0.00 0.00 0.00 22,800.00 90.86 333.08 8,264.60 6,798.51 -8,811.72 11,123.77 0.00 0.00 0.00 22,900.00 90.86 333.08 8,263.11 6,887.66 -8,857.00 11,215.41 0.00 0.00 0.00 23,000.00 90.86 333.08 8,261.61 6,976.81 -8,902.27 11,307.05 0.00 0.00 0.00 23,100.00 90.86 333.08 8,260.12 7,065.96 -8,947.55 11,398.69 0.00 0.00 0.00 23,200.00 90.86 333.08 8,258.63 7,155.11 -8,992.83 11,490.32 0.00 0.00 0.00 23,300.00 90.86 333.08 8,257.14 7,244.26 -9,038.10 11,581.96 0.00 0.00 0.00 23,400.00 90.86 333.08 8,255.64 7,333.41 -9,083.38 11,673.60 0.00 0.00 0.00 23,500.00 90.86 333.08 8,254.15 7,422.57 -9,128.65 11,765.23 0.00 0.00 0.00 23,600.00 90.86 333.08 8,252.66 7,511.72 -9,173.93 11,856.87 0.00 0.00 0.00 23,693.75 90.86 333.08 8,251.26 7,595.30 -9,216.37 11,942.78 0.00 0.00 0.00 MT7-01 TD 102720 MS 111312021 1:59:40PM Page 8 COMPASS 5000.15 Build 91E ConocoPhillips Baker Hughes Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Project: Western North Slope MD Reference: Site: GMT2 Rendezvous Pad North Reference: Well: MT7-01 Survey Calculation Method: Wellbore: MT7-01 Design: MT7-01_wp03 Well MT7-01 Actual 100.7 + 38.71 @ 139.41 usft Actual 100.7 + 38.71 @ 139.41 usft True Minimum Curvature Design Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape (1 (1) (usft) (usft) (usft) (usft) (usft) Latitude Longitude MT7-01 TD 102720 MS 0.00 0.00 8,251.26 7,595.30 -9,216.37 5,923,428.28 1,421,060.64 70° 11' 37.322 N 151° 46' 3.649 W plan hits target center Circle (radius 100.00) MT7-01_Landing _07162 0.00 0.00 8,429.28 -3,095.63 -3,769.09 5,912,590.59 1,426,208.34 70° 9' 52.219 N 151° 43' 25.501 W plan misses target center by 1.08usft at 11692.99usft MD (8429.08 TVD,-3096.22 N, -3769.97 E) Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 9,260.00 7,440.20 9 7/8" x 12 1/4" 9.875 12.250 10,736.53 8,310.48 7-5/8" x 9-7/8" 7.625 9.875 111312021 1:59:40PM Page 9 COMPASS 5000.15 Build 91E From:WSC Operations Engineer To:Loepp, Victoria T (OGC) Cc:Njoku, Johnson; WSC Rig Advisor; Anderson, Nina M; Hobbs, Greg S; Lee, David L Subject:MT7-01 Int2 Plugback and Sidetrack Request Date:Sunday, October 31, 2021 11:42:00 AM Attachments:image001.png Good morning, We have been experiencing significant issues with the Intermediate 2 wellbore of MT7-01. We drilled the hole to TD, tripped out to the Intermediate 1 shoe, and then attempted to perform the planned short trip. We were unable to progress in hole past 10,370’ MD which is in the Miluveach. The decision was made to recover the BHA while still possible and we assume the shales will continue to deteriorate and we are unable to salvage the wellbore. We will come out of the hole with this BHA. We will test BOP’s before picking up a cement stinger and laying in a 16.5ppg cement plug including 500’ in open hole and 100’ inside the Intermediate 1 shoe. The well will then be sidetracked, and the Intermediate 2 section redrilled. Details for that sidetrack are actively being worked. A sundry for this plan forward is forthcoming. Could we please receive verbal approval to proceed with the plan, as outlined above, with setting a cement plug? Please let me know if you have any questions or concerns. Thank you, Polaris – WSC Operations Engineer Sydney Deering / Scott Kolstad wscopsengineer@conocophillips.com 907.263.4544 (Office) From:Hobbs, Greg S To:Loepp, Victoria T (OGC) Cc:Regg, James B (OGC) Subject:RE: [EXTERNAL]APPROVAL: Request for variance of BOP testing interval (MT7-01 PTD 221-052) Date:Friday, October 29, 2021 5:00:21 PM Thank-you Victoria, For the both of you, I just came out of the Wells Support Center- We made it to 10,346’ MD working our way in the hole and packed off twice this morning, once losing rotation. We are now free. The decision was made to come out to the shoe, and we are currently at 10,300’ working our way to the intermediate 1 shoe. We are heading toward a plug back of this section at this time and assessing the re-drill. Greg From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, October 29, 2021 1:54 PM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: [EXTERNAL]APPROVAL: Request for variance of BOP testing interval (MT7-01 PTD 221-052) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Greg, A variance is approved to test the BOP after running and cementing the 7” liner. Victoria Sent from my iPhone On Oct 28, 2021, at 4:50 PM, Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> wrote: Apologies, I sent the sequence for the test on the 16th, not the chart- Greg <BOP test chart 10-16-21 MT7-01.jpg> _____________________________________________ From: Hobbs, Greg S Sent: Thursday, October 28, 2021 4:41 PM To: 'Loepp, Victoria T (CED)' <victoria.loepp@alaska.gov>; 'Regg, James B (CED)' <jim.regg@alaska.gov> Subject: RE: Request for variance of BOP testing interval (MT7-01 PTD 221-052) Victoria and Jim, As requested earlier today, here is the test chart for the upper VBR with a 7” Joint from 10/25/21. << File: MT7-01 4.5in x 7in VBR UPR with 5in TJ - 10-25-20211.pdf >> << OLE Object: Picture (Device Independent Bitmap) >> << File: MT7-01 Test Sequence and Koomey Test.pdf >> Also attached is the test chart from the 16th that has the test of the 5” in the VBR. We are still working back to TD in the intermediate 2 shale section. We are at 10,150’ MD, TD is 10,850’ after a smooth trip out to the intermediate one shoe. Greg _____________________________________________ From: Hobbs, Greg S Sent: Wednesday, October 27, 2021 6:27 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: Request for variance of BOP testing interval (MT7-01 PTD 221-052) Jim, and Victoria, After successful completion of the intermediate one section of this well, drilling of the intermediate two section was initiated on the 25th of October. Prior to drilling, anticipated rate of penetration for the section placed BOP testing after running and cementing of the 7” liner late on the 29th of October to mid-day on the 30th. The next BOP test is due by midnight on the 30th of October. A slower than anticipated ROP has set us back on timing. We are currently tripping out. The hole is currently in good shape with an inhibitive Potassium Silicate system in place across the shales. To test the effectiveness (or lack of effectiveness) of the new mud system, we would prefer to run and cement the 7” liner prior to a BOP test. As you all know, the shales at MT7 have been problematic, creating pack-off and failed primary cement jobs. This led to the four-string design in this well and the use of the potassium silicate system. We are respectfully requesting a variance to test the BOP after running and cementing our 7” liner. This allows assessment of the inhibitive system and the four-string design per the plan without a BOP test period muddying the result. As always, thank-you for the consideration, and apologies for the late evening mail. Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263-4749 I C: (907) 231-0515 <BOP test chart 10-16-21 MT7-01.jpg> 1 Guhl, Meredith D (OGC) From:Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent:Thursday, October 28, 2021 4:50 PM To:Loepp, Victoria T (OGC); Regg, James B (OGC) Subject:RE: Request for variance of BOP testing interval (MT7-01 PTD 221-052) Follow Up Flag:Follow up Flag Status:Flagged Apologies, I sent the sequence for the test on the 16th, not the chart‐ Greg 2 3 _____________________________________________ From: Hobbs, Greg S Sent: Thursday, October 28, 2021 4:41 PM To: 'Loepp, Victoria T (CED)' <victoria.loepp@alaska.gov>; 'Regg, James B (CED)' <jim.regg@alaska.gov> Subject: RE: Request for variance of BOP testing interval (MT7‐01 PTD 221‐052) Victoria and Jim, As requested earlier today, here is the test chart for the upper VBR with a 7” Joint from 10/25/21. << File: MT7‐01 4.5in x 7in VBR UPR with 5in TJ ‐ 10‐25‐20211.pdf >> << OLE Object: Picture (Device Independent Bitmap) >> << File: MT7‐01 Test Sequence and Koomey Test.pdf >> Also attached is the test chart from the 16th that has the test of the 5” in the VBR. We are still working back to TD in the intermediate 2 shale section. We are at 10,150’ MD, TD is 10,850’ after a smooth trip out to the intermediate one shoe. Greg _____________________________________________ From: Hobbs, Greg S Sent: Wednesday, October 27, 2021 6:27 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: Request for variance of BOP testing interval (MT7‐01 PTD 221‐052) Jim, and Victoria, After successful completion of the intermediate one section of this well, drilling of the intermediate two section was initiated on the 25th of October. Prior to drilling, anticipated rate of penetration for the section placed BOP testing after running and cementing of the 7” liner late on the 29th of October to mid‐day on the 30th. The next BOP test is due by midnight on the 30th of October. A slower than anticipated ROP has set us back on timing. We are currently tripping out. The hole is currently in good shape with an inhibitive Potassium Silicate system in place across the shales. To test the effectiveness (or lack of effectiveness) of the new mud system, we would prefer to run and cement the 7” liner prior to a BOP test. As you all know, the shales at MT7 have been problematic, creating pack‐off and failed primary cement jobs. This led to the four‐string design in this well and the use of the potassium silicate system. 4 We are respectfully requesting a variance to test the BOP after running and cementing our 7” liner. This allows assessment of the inhibitive system and the four‐string design per the plan without a BOP test period muddying the result. As always, thank‐you for the consideration, and apologies for the late evening mail. Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263‐4749 I C: (907) 231‐0515 1 Guhl, Meredith D (OGC) From:Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent:Thursday, October 28, 2021 4:41 PM To:Loepp, Victoria T (OGC); Regg, James B (OGC) Subject:RE: Request for variance of BOP testing interval (MT7-01 PTD 221-052) Attachments:MT7-01 4.5in x 7in VBR UPR with 5in TJ - 10-25-20211.pdf; MT7-01 Test Sequence and Koomey Test.pdf Follow Up Flag:Follow up Flag Status:Flagged Victoria and Jim, As requested earlier today, here is the test chart for the upper VBR with a 7” Joint from 10/25/21. Also attached is the test chart from the 16th that has the test of the 5” in the VBR. We are still working back to TD in the intermediate 2 shale section. We are at 10,150’ MD, TD is 10,850’ after a smooth trip out to the intermediate one shoe. Greg _____________________________________________ From: Hobbs, Greg S Sent: Wednesday, October 27, 2021 6:27 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: Request for variance of BOP testing interval (MT7‐01 PTD 221‐052) Jim, and Victoria, After successful completion of the intermediate one section of this well, drilling of the intermediate two section was initiated on the 25th of October. Prior to drilling, anticipated rate of penetration for the section placed BOP testing after 2 running and cementing of the 7” liner late on the 29th of October to mid‐day on the 30th. The next BOP test is due by midnight on the 30th of October. A slower than anticipated ROP has set us back on timing. We are currently tripping out. The hole is currently in good shape with an inhibitive Potassium Silicate system in place across the shales. To test the effectiveness (or lack of effectiveness) of the new mud system, we would prefer to run and cement the 7” liner prior to a BOP test. As you all know, the shales at MT7 have been problematic, creating pack‐off and failed primary cement jobs. This led to the four‐string design in this well and the use of the potassium silicate system. We are respectfully requesting a variance to test the BOP after running and cementing our 7” liner. This allows assessment of the inhibitive system and the four‐string design per the plan without a BOP test period muddying the result. As always, thank‐you for the consideration, and apologies for the late evening mail. Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263‐4749 I C: (907) 231‐0515 From:Hobbs, Greg S To:Loepp, Victoria T (OGC) Cc:Regg, James B (OGC); Rixse, Melvin G (OGC); McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL]VARIANCE APPROVAL: Final Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) Date:Thursday, October 21, 2021 3:25:24 PM Victoria, Thank-you! Greg From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, October 21, 2021 3:23 PM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Subject: [EXTERNAL]VARIANCE APPROVAL: Final Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Greg, ConocoPhillips Alaska has requested a variance to 20 AAC 25.035 (e) (1) (C) (ii) on the MT7-01 Intermediate 1 Hole Section. The variance would allow utilizing a Kick-Joint while running approximately 1,600’ of 9-7/8” casing in a tapered casing string design with ~7,590’ of 9-5/8” casing above it. The attached variance is APPROVED with conditions as outlined in the variance document. 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 From: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent: Wednesday, October 20, 2021 5:33 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Final Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) Victoria, After sending the previous mail, there was concern expressed from the rig that a drill that involved a make and break of the premium connection (Hydril 523) could gall the connection with the break and removal. The word document below, with “Final” in the title presents the drill that the rig would do with a complete run through the procedure, confirmation of tools, equipment and placement without actual make-up and break-out. Apologies for the second version. Please contact me with questions or concerns- Thank-you. Greg _____________________________________________ From: Hobbs, Greg S Sent: Wednesday, October 20, 2021 3:40 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: Int. 1 Casing Ram Variance MT7-01 (PTD 21-052) Victoria, Attached please find a variance request for 20 AAC 25.035 (e) (1) (C) (ii) for the casing run on the Intermediate 1 section of MT7-01. The variance is needed due to the inability to procure variable bore rams for the tapered casing string. The taper is required for casing wear considerations and design with a casing that we currently have in stock. The four-string design of this well is a contingency to eliminate the running and cementing issues experienced on the Intermediate 1 Longstring of the three earlier wells on the pad. Primary well control is not risked with this variance. Secondary control is maintained with 9 5/8” casing rams and a kick joint that is further described in the attached request. A Kick Drill utilizing the kick joint will be executed to assure proficiency in an emergency. Thank-you! Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263-4749 I C: (907) 231-0515 ConocoPhillips Alaska MT7-01 Intermediate 1 Hole BOP Configuration Variance Request ConocoPhillips Alaska is requesting a variance to 20 AAC 25.035 (e) (1) (C) (ii) on the MT7-01 Intermediate 1 Hole Section. The variance would allow utilizing a Kick-Joint while running approximately 1,600’ of 9-7/8” casing in a tapered casing string design with ~7,590’ of 9-5/8” casing above it. ConocoPhillips has attempted to source VBR’s that would fit both 9-5/8” casing and 9-7/8” casing but has been unsuccessful in finding any to fit these Schaffer BOP’s. The 9-7/8” casing string is necessary as a heavy-heel design to provide protection against casing wear in these four string wells while utilizing existing casing stock. This variance will allow shut-in with 9-5/8” casing rams for a well control kill operation and allow rig personnel to quickly and safely shut-in the well if the need arises while the portion of the 9-7/8” casing is being run. The Kick Joint is designed with 9-7/8” H523 threads on top and bottom that will make up to the 9-7/8” casing and will fit our handling equipment for well control readiness (Figure 1). All internal connections will utilize connection cement to assure connection integrity with handling. Figure 1 The casing string is as follows: 9-5/8” Shoe track and float (82’) –> 1,600’ of 9-7/8” casing –> 7,588’ of 9-5/8” casing. Primary well control for running the 9-5/8” x 9-7/8” casing string would be as follows: The primary barrier is the fluid density at 10.8 ppg designed for mechanical stability of the HRZ shale section while running the tapered casing string. The Susitna Sand at 8062 MD (6472’ TVD) was penetrated with a 9.8 ppg mud system without issue. A tested annular is a second barrier in an emergency flow situation. Secondary well control with variance approval is as follows: • Prior to making up the shoe-track: o The 9-5/8” solid body rams will be installed in the BOP’s and tested to 250 / 3,500 psi around the 9-5/8” test joint. o A 9-7/8” test joint will then be picked up and the Annular Preventer will be tested to 250 / 3,500 psi around it. o Crossovers from the 9-7/8” H523 to NC50 threads will be prepped with a FOSV and will be ready to be picked up on the floor. o The 9-5/8” kick stand will on the short side of the pipe skate, un-obstructed. • The procedure for shutting in while running the 9-7/8” casing will be: o Close the annular preventer around the 9-7/8” casing. o Pipe skate operator will move the Kick Joint to the rig floor o Latch onto the Kick Joint with the 9-7/8” elevators that are currently rigged up o Make the Kick Joint up to the 9-7/8” casing stump o With the annular still closed, strip the kick joint in the hole and space the 9-5/8” body of the Kick Joint around the upper pipe rams. o Close the 9-5/8” casing rams o Stab the crossover with the FOSV in and close the FOSV. Prior to running casing, a kick drill will be completed with the above procedure to assure competency before an actual event occurs. This drill will be a “mock” drill to pick up the kick joint and run it into the BOP stack to verify height at the floor for ram closure on the 9 5/8” section of the joint. It will also assure that procedure and tools are in place to properly install the FOSV on the top of the joint. This will align crews on the procedure and prevent damage to the connection from a make and break drill. The well control risk of this section is extremely low with ten pound per gallon mud system across the Susitna Sand and the casing shoe being set in the HRZ shale as illustrated in Figure 2. ConocoPhillips is making this request after significant issues arose with the three-string design on MT7- 04, MT7-03 and MT7-06. In these wells, there were issues with the shale sections that prevented successfully landing the intermediate 1 casing string and completing primary cement jobs. Please contact Greg Hobbs at 907-263-4749 or greg.s.hobbs@cop.com for any questions of comments. Figure 2 4-½” 12.6# L-80 HYD563 Liner w/ frac ports and perf joints TD @ 20,856' MD / 8294' TVD 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 6-1/8” Hole, TD 4-1/2" 12.6 ppf L-80 HYD563 Prognosed Top Alpine D 10,753' MD / 8278' TVD MT7-01wp10 4 string Producer, Proposed Completion Schematic Surface Casing 13-3/8" 68 ppf L-80 HYD563 @ 3485' MD / 3093' TVD X INTERMEDIATE 1 9 5/8" 43.5 ppf L-80 TXP w/9-7/8" 62.8 ppf L-80 HYD523 @ 9247' MD / 7425' TVD GLGL GLGL UPDATED: 09_24_21 Production Packer ZXP Liner Top Packer Downhole Gauge Prognosed Top HRZ 9227' MD / 7411' TVD INTERMEDIATE 2 7" 26 ppf L-80 HYD563 Liner @ 10,856' MD / 8309' TVD Prognosed Susitna 8087' MD / 6489' TVD Estimated TOC ~ 500' above Susitna 7587' MD Tubing / Liner Completion: 1) 4-½” X Landing Nipple (3.813" ID) 2) 4-½” x 1” KBG-2 GLM (2x) 3) 4-½” x 1” KBG-2 4-5 GLM (1x) 4) HES Downhole Gauge 5) 4-½” Baker Premier Production Packer 6) 4-½” DB Landing Nipple w/DFCV (3.75" ID) 7) Liner Top Packer / Hanger w/ Tie Back sleeve Estimate INT2 TOC ~ Top of 7" LTP located +/- 100' overlap into 9-7/8" casing @ 9147' MD Potential 2nd Stage Job Tusk sand ~ 4725' MD 9-5/8" HES Cementer From:Hobbs, Greg S To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]VARIANCE REQUEST MT7-01 : CPAI CRU CD2-162 (PTD 219-004) - Production Hole BOP Configuration Variance Approval Date:Tuesday, October 19, 2021 4:06:24 PM Thank-you Victoria, I passed it to the Wells Support Center to put together. We will get it to you tomorrow. Greg From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, October 19, 2021 9:03 AM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Cc: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]VARIANCE REQUEST MT7-01 : CPAI CRU CD2-162 (PTD 219-004) - Production Hole BOP Configuration Variance Approval CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Greg, Please prepare a variance request for GMT MT7-01 that also covers all conditions that were included in this variance request for CRU CD2-162 that is very similar to the variance you are requesting for MT7-01. Also include conditions that were previously included in your two emails. This variance will likely be granted on a well by well basis. Let me know if you have questions. Please forward email request for variance for review and approval. Thanx, Victoria From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, April 12, 2019 1:28 PM To: Kane, Danny (Danny.Kane@conocophillips.com) <Danny.Kane@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov> Subject: CPAI CRU CD2-162 (PTD 219-004) - Production Hole BOP Configuration Variance Approval Danny, A variance to 20 AAC 25.035 (e) (1)(B)(i) for the drilling of the CD2-162 Production Hole Section to allow the use of two 4-1/2” x 7” Variable Bore Rams (VBRs) with a kick-stand made-up for use with a tapered 5-7/8” x 4” drill string is approved with the following conditions: 1. The attached document ConocoPhillips Alaska CD2‐162 Production Hole BOP Configuration Variance Request outlines information on how CPAI intends to provide equivalent Well Control with the use of a Kick‐Stand. This approval is based on CPAI adhering to all aspects of this document. 2. 12 hour notice will be provided to the AOGCC Inspectors prior to tripping in the hole with the 4” drill pipe. 3. Kick drills using the Kick-Stand will be performed with both crews while tripping‐out with 4” drill pipe. 4. The standing order will be posted outlining well control steps to be taken upon detecting a kick while tripping 4” drill pipe. 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 From: Kane, Danny <Danny.Kane@conocophillips.com> Sent: Thursday, April 11, 2019 10:21 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Regg, James B (DOA) <jim.regg@alaska.gov> Subject: CPAI CRU CD2-162 (PTD 219-004) - Production Hole BOP Configuration Variance Request Victoria, ConocoPhillips Alaska would like to request a variance to 20 AAC 25.035 (e) (1) (A) (B) on the CD2- 162 Production (PROD) Hole Section to allow the use of two 4-1/2” x 7” Variable Bore Rams (VBRs) with a kick-stand made-up for use with a tapered 5-7/8” x 4” drill string. This would allow the use of two properly-sized pipe rams for the highest risk Production hole operations and the Kick-Stand would be used to allow the use of all secondary well control equipment when 4” drill pipe is at surface while tripping out of hole. In the attached PDF Document, I have provided additional information on how Well Control will be affected by this variance request and how ConocoPhillips Alaska intends to provide equivalent Well Control with the use of a Kick-Stand. This document includes detailed information on the Kick-Stand configuration, how the Well Control Plan would be modified for Kick-Stand use, and how crews will be drilled with the use of the Kick-Stand prior to drilling the Production Hole Section. Currently the rig is finishing the 7” Floated Liner run on CD2-162 and we have the liner within 100’ of being on bottom. Once on bottom, the Floated Liner will be flooded to convert it to a Conventional String, circulation will be established, and the hole will be conditioned for the liner cement job. This is the first time that ConocoPhillips Alaska has floated a liner in Alaska and the liner run has gone twice as fast within open hole than originally planned so that if all goes well tonight and the weather cooperates, Doyon 25 could be ready to release from the liner hanger by end-of-business tomorrow. At this point Doyon 25 will either lay-down or rack-back the 5-7/8” drill pipe depending upon whether or not the Variance Request is approved. Please contact me if you would like to discuss or have any additional questions. Regards, Danny Danny Kane ERD Drilling Engineer ConocoPhillips Alaska ATO 17-1792 Office: +1 907 265-6048 Mobile: +1 907 227-6037 danny.kane@conocophillips.com ConocoPhillips Alaska CD2‐162 Production Hole BOP Configuration Variance Request To Whom it May Concern, ConocoPhillips Alaska would like to request a variance to 20 AAC 25.035 (e) (1) (A) (B) on the CD2‐162 Production (PROD) Hole Section to allow the use of two 4‐1/2” x 7” Variable Bore Rams (VBRs) with a kick‐stand made‐up for use with a tapered 5‐7/8” x 4” drill string. This would allow the use of two properly‐sized pipe rams for the highest risk Production hole operations and the kick‐stand would be used to allow the use of all secondary well control equipment with 4” drill pipe at surface. The proposed PROD BHA would be as follows: 6” Bit  380’ 4‐3/4” BHA  11,000’ 4” Drill Pipe  11,620’ 5‐7/8” Drill Pipe to Surface Well control for the PROD Hole would be as follows:  Prior to picking‐up BHA, a 65’ Kick‐Stand would be made‐up and set in slips within the 90’ mouse hole on the rig floor. o The mousehole is immediately adjacent to well center and within reach of the top drive elevators; this is the same well control approach used while making‐up the Steerable Drilling Liner that was used on MT6 Pad with Doyon 19. o Crossovers from 4” XT‐39 to 4” NC‐50 and from 4” NC‐50 to 5‐7/8” XT‐M 57 would be on the rig floor that would allow making‐up the top drive with a 5‐7/8” XT‐M 57 Saver Sub to the 4” XT‐39 Box looking‐up on the Kick‐Stand. o A 65’ Kick‐Stand will be used to keep the FOSV beneath the top of the Doyon 25 wind walls when made‐up to the 4” XT‐39 drill pipe in the hole. See below for the Kick‐Stand configuration:  After pressure‐testing the 10‐3/4” INT1 Casing and 7” INT2 liner to 4,000 psig, the 6” PROD BHA and 11,000’ of 4” drill pipe would be picked‐up and run in hole. At this point the barriers in the well would be the INT2 kill‐weight fluid, pressure‐tested cemented casing, and the BOP stack. o Kick Drills using the Kick‐Stand will be performed with both crews while tripping‐in with the 4” drill pipe. o See below for location of BHA when first crossing‐over to 5‐7/8” drill pipe.  Doyon 25 would cross‐over to 5‐7/8” drill pipe above the 7” INT2 Liner Top. The rig would drill‐ out the INT2 Liner Shoe, drill the Production Hole, spot kill‐weight brine, and trip‐out to above the 7” Liner Top with 5‐7/8” drill pipe at surface. o Drilling fluid would be used for primary well control. o The annular, two sets of 4‐1/2” x 7” VBRs, and Blind/Shear rams would be used for secondary well control.  These operations with 5‐7/8” drill pipe at the surface have the greatest well control risk for the CD2‐162 PROD Hole Section. o The actual drilling of the PROD hole section will be < 12 hours because of its limited length. TD will be called after the LWD tools have logged the Kuparuk C. o See below for location of BHA after drilling the Kuparuk C and spotting the kill‐weight brine prior to starting the Trip Out to Surface.  After tripping out 11,620’ of 5‐7/8” drill pipe and prior to tripping out the first 4” drill pipe, the rig will perform the following: o 30‐minute flow check to re‐confirm the well is static. o Verify that all well control equipment is on the rig floor. This includes the Kick‐Stand set in slips within the 90’ mousehole and the cross‐overs required to make‐up the top drive XT‐M 57 saver sub to the top of the Kick Stand. o Hold a Safety‐Meeting with rig crews to review Kick‐Stand Well Control procedures.  The rig will trip‐out with the remaining 11,000’ of 4” drill pipe and the 380’ drilling BHA. o Drilling fluid would be used for primary well control. o The annular, two sets of 4‐1/2” x 7” VBRs (with Kick‐Stand), and Blind/Shear rams would be used for secondary well control.  Upon detecting a kick while tripping‐out with 4” drill pipe: o The rig would lower the 4” drill pipe to place in slips at the rig floor. o The rig would shut in the annular with a closed choke. Non‐ported drill pipe floats will be used for Managed Pressure Drilling. o The rig would pick‐up the Kick‐Stand with open FOSV in slips within the mousehole using the elevators (already at the rig floor) and make it up to the 4” drill pipe with the Iron Roughneck. o The rig would strip the Kick‐Stand through the annular to space the 5‐7/8” drill pipe joint across the BOP stack (across annular and all rams). o The rig would shut‐in the well by both closing the FOSV and the Upper 4‐1/2” x 7” VBRs against the Kick‐Stand 5‐7/8” drill pipe joint with a closed choke. o The rig would monitor SIDPP and SICP.  See below for location of BHA with 4” drill pipe first at surface while TOH. ConocoPhillips Alaska is making this request after encountering significant unplanned delays that puts completing CD2‐162 within the ice road season at risk. This planned 45‐day wells was to be completed by mid‐March but two weeks of rig mobilization delays and three weeks of drilling trouble time to date have pushed the completion of CD2‐162 to 23‐Apr‐2019. This coincides with the last day that the rig can move over the heavy‐haul ice road from CD2 Pad to CD5 pad based upon current weather forecasts. The CD2‐162 Production hole was planned with a 5” x 4” tapered drill string where two‐sets of 2‐7/8” x 5‐1/2” VBRs were to be used. Since 5‐7/8” drill pipe is being used to run the 7” INT2 liner, the plan was to lay‐down all the 5‐7/8” drill pipe and pick‐up replacement 5” drill pipe for the Production hole. However, if a 5‐7/8” x 4” tapered drill string could be used, an estimated 32 hours of laying‐down 5‐7/8” and picking‐up 5” drill pipe could be removed and allow completing CD2‐162 within the ice road season. Instead of laying‐down the 5‐7/8” drill pipe that was used while running the liner, it would be racked‐back and used for the PROD Hole Section. Unfortunately, VBRs that cover both 5‐7/8” and 4” drill pipe do not exist for Doyon 25’s Shaffer LXT BOP as only 2‐7/8” x 5‐1/2” and 4‐1/2” x 7” VBRs are available. Therefore, ConocoPhillips requests a variance to 20 AAC 25.035 (e) (1) (A) (B) on the CD2‐162 PROD Hole Section to allow the use of two 4‐1/2” x 7” Variable Bore Rams (VBRs) with a kick‐stand made‐up for use with a tapered 5‐7/8” x 4” drill string. Please contact Danny Kane at danny.kane@conocophillips.com or 907‐265‐6048 to discuss or for additional information. CD2-162 Fiord West Kuparuk Pilot Hole – PROD Hole SectionSlant Producer Completion (Actual Surveys / WP08)Last Updated: 11-Apr-2019 by Danny Kane20" Conductor12-¼” x 13-½” INT1 Hole10-¾” 65.7# L-80 Casing2,500' Hydril 563 MS above Hydril 523 12,348’ MD / 5,330' TVD250' TVD 15.8 ppg Class G Tail15.8 ppg Class G Stage 500' MD Above/ 250' TVD Below Qannik9-½” x 10-½” INT2 Hole 7" 29# L-80 Hydril 523 LinerPlanned Liner Top 11,935' MD22,476' MD / 7,121' TVD1,000' MD 15.8 ppg Class G6" PROD Hole22,799' MD / 7,317' TVDNechelik Opportunity23,390' MD / 7,656' TVDTop Kuparuk C ~7,146' TVDPrimary Cement to IsolateEstimated 25' Deep to Prog17-½" SURF Hole13-5/8" 88.2# L-80 Hydril 563 MS Casing4,714' MD / 4,011' TVD11.2 ppg DeepCRETE Lead500' 12.0 ppg LiteCRETE TailTop Qannik 4,832' MD / 4,066' TVDStage Collar at 5,585' MD / 4,364' TVDCurrent StatusDrilled 9-½” x 10-½” INT2 to 22,478' MD / 7,121' TVDEstimated Topset Kuparuk C by ~25' TVD / TD 01-AprCurrently running 7" INT2 Liner at 17,835' MD (13:30 11-Apr) From:WSC Operations Engineer To:Loepp, Victoria T (OGC); Hobbs, Greg S Cc:Njoku, Johnson; WSC Rig Advisor; Anderson, Nina M Subject:MT7-01 Surface Casing Pressure Test and FIT Form Date:Sunday, October 17, 2021 6:02:23 PM Attachments:image001.png MT7-01 Surface csg test FIT or LOT Pressure Integrity Test 10-17-21.xlsx MT7-01 Surface csg test FIT or LOT Pressure Integrity Test 10-17-21.pdf Hi Victoria, Attached is the MT7-01 surface casing pressure test and formation integrity test form and sheet. If you have any questions, please let us know. Polaris – WSC Operations Engineer Justin Brady / Keith Herring wscopsengineer@conocophillips.com 907.263.4544 (Office) Well Name: Rig: Date: Drilling Supervisor:Pump used:2 Strokes Barrels 2 3 4 Casing Test Pressure Integrity Test Hole Size:4 12.25 RKB-CHF:39.7 Ft 3424.0 Ft-MD 3050.3 Ft-TVD 3454.0 Ft-MD 3070.0 Ft-TVD Strks psi Min psi Strks psi Min psi 12.42 2 3 165 0 3610 2 101 0.00 1422 6 365 1 3609 4 189 0.25 1345 Mud Weight: 11.0 ppg Mud Weight:9.6 ppg 9 585 2 3606 6 300 0.50 1237 Mud 10 min Gel: 18.0 Lb/100 Ft2 Mud 10 min Gel:14.0 Lb/100 Ft2 12 808 3 3604 8 392 1.00 1014 Test Pressure: 3500.0 psi Rotating Weight:135000.0 Lbs 15 1036 4 3601 10 512 1.50 924 Rotating Weight: 135000.0 Lbs Blocks/Top Drive Weight:43000.0 Lbs 18 1225 5 3599 12 680 2.00 820 Blocks/Top Drive Weight: 43000.0 Lbs Desired PIT EMW:18.5 ppg 21 1423 6 3596 14 790 2.50 795 Estimates for Test:6 bbls Estimates for Test:1412 psi 2.6 bbls 24 1628 7 3594 16 900 3.00 750 1 1 27 1836 8 3592 18 1006 3.50 709 EMW = Leak-off Pressure + Mud Weight =30 2048 9 3590 20 1100 4.00 675 0.052 x TVD 0.052 x 3050.3 33 2255 10 3588 22 1192 4.50 651 18.6 ppg 36 2475 15 3580 24 1275 5.00 633 39 2686 20 3572 26 1358 5.50 619 42 2907 25 3566 28 1422 6.00 608 45 3123 30 3559 6.50 600 48 3345 7.00 593 51 3566 7.50 588 8.00 583 8.50 580 9.00 577 9.50 573 10.00 572 6.0 Bbls 5.7 Bbls 3.3 Bbls 1.9 Bbls Comments: CONOCOPHILLIPS Alaska, Inc. Pumping down EMW at 3424 Ft-MD (3050.3 Ft-TVD) =1345 9.61422+PIT 15 Second Shut-in Pressure, psi Volume Pumped Volume Bled Back Volume Input PRESSURE INTEGRITY TEST Type of Test: Casing Test Pressure IntegrityTest Hole DepthCasing Shoe Depth Casing Size and Description: Pump Rate: 10/17/2021 B. Book/P. Castro Volume/Stroke 6.00 Pumping 0.1183 MT7-01 Doyon 25 Volume Bled Back Shut-in Pumping Shut-in Volume Pumped 0 500 1000 1500 2000 2500 3000 3500 4000 0 1 2 3 4 5 6 7PRESSURE CASING TEST LEAK-OFF TEST PIT Point Barrels 0 5 10 15 20 25 30 Shut-In time, Minutes Lost 51 psi during test, held 98.6% of test pressure. MT7-01 Surface csg test FIT or LOT Pressure Integrity Test 10-17-21.xlsx Summary 1 Guhl, Meredith D (OGC) From:Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent:Thursday, October 14, 2021 6:42 PM To:Loepp, Victoria T (OGC) Subject:FW: MT7-01 (PTD 221-052) Sundry 321-057 Intermediate 1 Casing Operations for Well Control Compliance Follow Up Flag:Follow up Flag Status:Flagged Victoria, Apologies for a second mail on the same subject, the 9 7/8” casing at the shoe of the intermediate one provides protection against casing wear in these four string wells. That came to mind after I sent the first mail. Greg _____________________________________________ From: Hobbs, Greg S Sent: Thursday, October 14, 2021 5:49 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: MT7‐01 (PTD 221‐052) Sundry 321‐057 Intermediate 1 Casing Operations for Well Control Compliance Victoria, As noted in our latest sundry for MT7‐01, step 15, we are running a tapered string of 9 7/8” (1600’) and 9 5/8” (7800’). We are running the 9 7/8” section to use excess inventory effectively. As noted in step 14, we will install 9 5/8” solid body rams for the run. After significant effort, we have not sourced a VBR capable of both sizes for the run. 2 Without VBR’s, our plan for this run and future runs like it, until the 9 7/8” stock is exhausted, to best meet well control regulations is: 1. Test the annular with a 9 7/8” and 9 5/8” test joints during the BOP test. 2. In the event of a well control event while running the lower casing section, close the annular on the casing, pick up a kick joint as drawn below. This will maintain the use of the volant tool and casing elevators for pick‐up and make up. 3 3. Strip the kick joint into the BOP stack with alignment of the 9 5/8” section at the upper rams. 4. Stab a TIW valve in the top HYD523 box with a crossover from the HYD 523 to 4 ½” IF connection that has an open TIW valve in it. 5. Close the TIW. The TD of the hole section will be into the top of the HRZ shale. The only hydrocarbon zone that might be open would be a shallow interval if it is found in this part of the field. I know this does not meet the letter of the regulation, but it meets the intent with rams and an annular to manage a well kill in the remote event it is needed in this overburden section. Thank‐you for the review and consideration. Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263‐4749 I C: (907) 231‐0515 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Hobbs, Greg S To:Loepp, Victoria T (OGC) Subject:Re: [EXTERNAL]Doyon 25 BOP test date APPROVAL Date:Friday, October 8, 2021 7:47:57 AM Thank you. Get Outlook for iOS From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, October 7, 2021 10:07:18 PM To: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: [EXTERNAL]Doyon 25 BOP test date APPROVAL Greg, Approval granted to run the upper completion and nipple up tree before testing the BOPE. Thanx, Victoria From: "Hobbs, Greg S" <Greg.S.Hobbs@conocophillips.com> Date: October 7, 2021 at 5:55:09 PM AKDT To: "Loepp, Victoria T (CED)" <victoria.loepp@alaska.gov>, "Regg, James B (CED)" <jim.regg@alaska.gov> Subject: Doyon 25 BOP test date Alignment Good Evening Victoria and Jim, I did not intend to send this so late this evening. Currently, Doyon 25 has a BOP test due on the 9th for the AOGCC and the 12th for the BLM. Prior to the last liner run failure, we were going to restart the clock for both with the next well, MT7-01. With the liner run failure, we are laying down drillpipe now and should have our upper completion run and the wellhead nippled up and tested by the 9th. If we are not, could we capture the test on the 12th if we are still on the well? We are good either way, Rob Reinhardt, the company rep has conservatively sent out notice to test before picking up the upper completion is my current understanding. Thank-you for the consideration. Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263-4749 I C: (907) 231-0515 RECEIVED By Meredith Guhl at 10:51 am, Sep 27, 2021 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑✓ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 221-052 3. Address: 6. API Number: P.O. Box 100360 Anchorage, Alaska 99510-0360 50-103-20832-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MT7-01 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field/Pool(s): AA081800, AA081781, AA081803 I Greater Mooses Tooth, Rendezvous 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 80.5 20" 120 120 Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary ✓ I Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/26/2021 OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR [_1SPLUG ❑ 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: Chris Brillon Contact Name: Nina Anderson Authorized Title: Wells Engineering Manager Contact Email: nina.anderson conoco hill' s.com D.—Si nedby: Sep-27-2021 Contact Phone: 907-229-4008 Authorized Signature _ Date: c579E72E81F2446... COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 321-507 Plug Integrity ❑ BOP Test(] Mechanical Integrity Test ❑ Location Clearance ❑ Other: BOP test to 3500 psig Review sands present in Int 1 section and review cement job results with AOGCC to see if CBL Is needed. Annular Dreventer test to 2500 osia RBDMS HEW 10/1/2021 Diverter variance granted per 20 AAC 25.035(h)(2) Intermediate 2 cement CBL required before drilling production hole Surface casing LOT results to AOGCC as soon as obtained Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: File With PTD 1 0-407 Digitally signed by Jeremy Price APPROVED BY Jeremy PPIC2 10/1/21 Approved by: Date: 2021.10.01 COMMISSIONER THE COMMISSION Date: 13:18:34-08'00' Comm.dts 10/1/2021 1ComrrULC 10/1/2021 1 Sr Pet EngVTL 10/1/21 ISr Pet GecDLB 09/27/2021 ISr Res Eng Form 10-403 Revised 3/2020 Approved application is valid for 12 montns from the date of approval. ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 27, 2021 Alaska Oil and Gas Conservation Commission 333 West Th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry to Approved Program for MT7-01 Dear Sir or Madam: ConocoPhillips p ConocoPhillips Alaska, Inc. hereby applies for a Sundry to Change Approved Program for MT7-01, an onshore production well from the MT7 drilling pad currently being drilled with the Doyon 25 drilling rig. MT7-01 is planned to be a fracture stimulated horizontal producer within the Rendevouz reservoir. The MT7-01 permit to drill was approved on 8/26/2021 for a 3- string design similar to the previous 3 wells at MT7. Due to challenges with shale stability while running and cementing intermediate casing on the recently drilled MT7-06 well, Conoco is proposing to change the well design on MT7-01 to a conventionally drilled 4-string design with a potassium silicate mud system in the inermediate 2 liner section. The 4 string design allows the shales to be drilled with a higher mud weight and reduce shale exposure time with a shortened liner run. Estimated spud date for MT7-01 is Sunday September 30th, 2021. Please find attached the information for your review. Pertinent information attached to this application includes the following: 1. Form 10-403 Sundry Application Change to Approved Program 2. Proposed Drilling Program 3. Proposed completion schematic 4. Directional Plan If you have any questions or require further information, please contact Nina Anderson at 229-4008 (nina.anderson(&conocouhillips.com) or Chris Brillon at 907-265-6120. Sincerely, cc: EtDuSigned by: MT7-01 Well File / Jenna Taylor ATO 1560 27-2021 David Lee ATO 1726 Chris Brillon ATO 1548 00896C6E049F... 1\111U Al1UV1JV11 Drilling Engineer MT7-01 Proposed Drilling Program (Requirements of20 AAC 25.005 (c)(13)) 1. MIRU Doyon 25 onto GMTU MT7-01 2. Rig up diverter and test. Rig up riser; dewater cellar as needed. 3. Drill 16" hole to the surface casing point as per the directional plan. (LWD Program: GR). 4. Run and cement 13-3/8" surface casing to surface. 5. Install BOPE and MPD equipment. 6. Test BOPE to 250 psi low / 3500 psi high (24 - 48 hr. regulatory notice). 7. Pick up and run in hole with 12-1/4" drilling BHA to drill intermediate #1. 8. Chart casing pressure test to 3500 psi for 30 minutes. 9. Drill out surface shoe track and 20' of new hole. 10. Perform LOT to maximum EMW of 18.5 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. 11. Displace well to 9.6 ppg LSND mud. 12. Drill 12-1/4" hole to the Intermediate casing point at - 9247' MD / 7,425ft TVD. 13. Circulate wellbore clean and POOH. 14. Change upper VBRs to 9-5/8" solid body rams. Test same to 250 psi low / 3,500 psi high 15. Run 9-5/8" 43.5# L-80 TXP and 9-7/8" 62.8# L-80 HYD523 intermediate casing to TD. 16. Pump single stage cement job to isolate the casing shoe or 500' MD above uppermost hydro -carbon bearing zone. Evaluate any additional sands and notify AOGCC if two stage cement 'ob is required. Review sands present -and cemenf lob results with AOGCC to see if CBL is needed. 17. Change upper 9-5/8" solid body rams to VBRs. Test BOPE as timing needed to 250/3500 psi. VTL 10/1/21 18. Pick up and run in hole with 8-1/2" x 9-7/8" drilling BHA to drill intermediate 2 section. 19. Chart casing pressure test to 3500 psi for 30 minutes. 20. Drill out Intermediate 1 shoe track and 20' of new formation. Perform LOT to a maximum of 14.0 ppg. Minimum required leak off for drilling ahead is 12.5 ppg EMW. 21. Drill 8-1/2" x 9-7/8" hole to section TD of-10,856' MD. (LWD Program: GR/RES/ DENS/NEUT/SONIC). 22. Circulate wellbore clean and POOH. 23. Pick up and run in hole with the 7" 26# L-80 Hyd563 liner on 5" drill pipe. 24. Land 7" liner at TD. 25. Cement 7" liner to top of liner. �Wt ling�top Backer. Circulate elcess cement, from top p f li dpOOH with DP. un CC;; LL c ment eva uation og and review log 1Nit��C 26. Pick up and RIH with 6-1/8" drilling assembly. Log top of cement with sonic tools. VTL 10/1/21 27. Chart casing pressure test to 3500 psi for 30 minutes. 28. Drill out Intermediate 2 shoe track and 20' of new formation. Perform LOT to a maximum of 13.5 ppg. Minimum required leak -off for drilling ahead is 11.0 ppg EMW. 29. Drill 6-1/8" horizontal section to TD. 30. Pull out of hole with drilling BHA. 31. RIH with 4.5" 12.6# L-80 Hyd563 liner with frac sleeves, swell packers, and pre -perforated joints with liner hanger on 4"drill pipe. 32. Set liner top packer and release from liner. 33. Run 4.5" upper completion and continue with final completion steps from approved MT7-01 PTD. Casin and Cementing Program Csg1Tbg OD Hole Weight Grade Conn. Cement Program (in) Size (in) (Ib/ft) 20 42 94 H-40 Welded Cemented to surface with 10 yds slurry 13.375 16 68 L-80 H563 Cement to Surface 9.625 / 9.875 12.25 43.5 / L-80 TXP / H523 250' TVD or 500' MD, whichever is greater, above upper 62.8 most producing zone 7 8.5 x 26 L-80 H563 Plan to bring cement to 7" LTP 9.875 4.5 6.125 12.6 L-80 H563 Uncemented liner with frac ports and perf joints Cementing Calculations 13.375" Surface Casing run to 3484' MD / 3093' TVD Cement from 3484' MD to 2984' (500' of tail) with DeepCRETE + Add's. @ 11 PPG, and from 2984' to surface with 11 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1325' MD), zero excess in 20" conductor. Lead slurry from 2984' MD to surface with Arctic Lite Crete @ 11 ppg Total Volume = 4392 ft3 => 2300 sx of 11 ppg DeepCRETE + Add's @ 1.91 ft3 /sk Tail slurry from 3484' MD to 2984' MD with 15.8 ppg DeepCRETE + Add's Total Volume = 349 ft3 => 310 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk 9.625 & 9.875" Intermediatel Casing run to 9247' MD / 7425' TVD Top of slurry is designed to be at 7587' MD, which is 500'MD or 250' TVD above the prognosis shallowest hydrocarbon bearing zone the Susitna Sand. If a shallower hydrocarbon zone of producible volumes, is encountered while drilling, a 2-stage cement job will be performed to isolate this zone. Assume 40% excess annular volume. Tail slurry from 9247' MD to 7587' MD with 15.8 ppg Class G + Add's Total Volume = 128.5 bbls = 721 ft3 => 621 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk 7" Intermediate2 Liner run to 10,856' MD / 8309' TVD Top of slurry is designed to be at the liner top packer — 8897' MD. Tail slurry from 10865' MD to 8897' MD with 15.8 ppg Class G + Add's Total Volume = 120.4 bbls = 676 ft3 => 583 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Surface Intermediate1 Intermediate2 Production Hole Size in. 16 12.25 8.5 x 9.875 6.125 Casing Size in. 13.375 9.625 x 9.875 7 4.5 Mud System Ksi KLA Shield LSND KSi KLS Shield Versapro MOBM Density PPG 10.5 — 11.0 9.6 — 10.8 10.8 — 13.5 8.8 — 9.5 LSYP—Ibs/100ft2 10-20 10-12 10-14 4-6 YP Ib./100 ftz 25 - 45 20 — 30 20 — 32 13 - 18 10Sec Gels Ib/100ftz 13-21 8-15 8-15 6-15 10 Minute Gels Ib./100 ftz 16 — 32 < 20 < 20 8-20 API Fluid Loss cc/30 min. N.C. < 10.0 < 10 < 6 NA HPHT Fluid Loss cc/30 min. n/a < 10 < 10 < 5 pH 10-11.2 9.5-10.0 10.0-11.2 9.0-9.5 MT7-01wp10 4 string Producer, Proposed Completion Schematic Potential 2"d Stage Job Tusk sand — 4725' MD 9-5/8" HES Cementer Estimated TOC — 500' above Susitna 7587' MD Prognosed Susitna 8087' MD / 6489' TVD Prognosed Top HRZ 9227' MD / 7411' TVD 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface Tubing / Liner Completion: 1) 4 '/2" X Landing Nipple (3.813" ID) 2) 4-'/z" x 1" KBG-2 GLM (2x) 3) 4-'/z" x 1" KBG-2 4-5 GLM (1 x) 4) HES Downhole Gauge 5) 4-'/2" Baker Premier Production Packer 6) 4-'/i' DB Landing Nipple w/DFCV (3.75" ID) 7) Liner Top Packer / Hanger w/ Tie Back sleeve Surface Casina 13-3/8" 68 ppf L-80 HYD563 3485' MD / 3093' TVD 4-1/2" 12.6 ppf L-80 HYD563 Estimate INT2 TOC — Top of 7" LTP located +/- 100' overlap into 9-7/8" casing @ 9147' MD INTERMEDIATE 1 9 5/8" 43.5 ppf L-80 TXP w/9-7/8" 62.8 ppf L-80 HYD523 9247' MD / 7425' TVD INTERMEDIATE 2 7" 26 ppf L-80 HYD563 Liner 10,856' MD / 8309' TVD ZXP Liner Top Packer 1 0 Prognosed Top Alpine D 1 10,753' MD / 8278' TVD 4-%" 12.6# L-80 HYD563 Liner w/ frac ports and perf joints TD @ 20,856' MD / 8294' TVD - - - -- - - - - - - - --j�------- ----—-------------J�--------------------- 6-1/8" Hole, TD UPDATED: 092421 ConocoPhillips Alaska Inc WNS Western North Slope GMT2 Rendezvous Pad MT7-01 50103xxxxx00 MT7-01 Plan: MT7-01_wp10 Standard Proposal Report 27 August, 2021 ConocoPh i I I i ps ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 Wellbore: MT7-01 Design: MT7-01_wp10 Local Co-ordinate Reference: Well MT7-01 TVD Reference: 139.5 @ 139.50usft MD Reference: 139.5 @ 139.50usft North Reference: True Survey Calculation Method: Minimum Curvature Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site GMT2 Rendezvous Pad Site Position: Northing: 5,915,580.00 usft Latitude: 70° 10' 22.674 N From: Map Easting: 1,430,062.00 usft Longitude: 151° 41' 36.331 W Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: -1.59 Well MT7-01, GMT2 SW01-107 Well Position +NI-S 0.08 usft Northing: 5,915,580.08 usft Latitude: 70° 10' 22.675 N +E/-W -0.16 usft Easting: 1,430,061.84 usft Longitude: 151° 41' 36.336 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 100.00 usft Wellbore MT7-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (I (nT) BGGM2020 8/15/2021 14.78 80.40 57,150.73 BGGM2020 8/14/2021 14.78 80.40 57,150.85 Design Audit Notes: Version: Vertical Section: MT7-01 _wp 10 Phase: PLAN Depth From (TVD) +NI-S i (usft) (usft) 39.50 0.00 Tie On Depth: 39.50 +E/-W Direction (usft) (I 0.00 333.00 8/27/2021 11:40:10AM Page 2 COMPASS 5000.15 Build 91E ConocoPhillips Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 Wellbore: MT7-01 Design: MT7-01_wp10 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well MT7-01 139.5 @ 139.50usft 139.5 @ 139.50usft True Minimum Curvature Plan Survey Tool Program Date 8/27/2021 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.50 1,300.00 MT7-01_wp10 (MT7-01) GYD-GC-SS Gyrodata gyro single shots 2 1,300.00 2,300.00 MT7-01_wp10 (MT7-01) MWD OWSG OWSG MWD - Standard 3 2,300.00 3,485.00 MT7-01_wp10 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + I\ 4 3,485.00 3,985.00 MT7-01_wp10 (MT7-01) MWD-INC_ONLY (INC>10°) MWD-INC—ONLY—FILLER (INS 5 3,985.00 5,985.00 MT7-01_wp10 (MT7-01) MWD OWSG OWSG MWD - Standard 6 5,985.00 9,247.00 MT7-01_wp10 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + A 7 9,247.00 9,747.00 MT7-01_wp10 (MT7-01) MWD-INC_ONLY (INC>10°) MWD-INC—ONLY—FILLER (INS 8 9,747.00 10,896.00 MT7-01_wp10 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + f\ 9 10,896.00 11,396.00 MT7-01_wp10 (MT7-01) MWD-INC_ONLY (INC>10°) MWD-INC_ONLY_FILLER (INS 10 11,396.00 12,896.00 MT7-01_wp10 (MT7-01) MWD OWSG OWSG MWD - Standard 11 12,896.00 23,688.89 MT7-01_wp10 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + I\ 812712021 11:40:10AM Page 3 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 Wellbore: MT7-01 Design: MT7-01 wp10 Plan Sections Measured Vertical Depth Inclination Azimuth Depth +NI-S (usft) (°) (°) (usft) (usft) I I I 39.50 0.00 0.00 39.50 0.00 700.00 0.00 199.11 700.00 0.00 1,000.00 4.50 199.11 999.69 -11.13 1,300.00 10.50 199.11 1,296.99 -48.11 2,586.00 42.65 199.11 2,432.09 -584.62 7,767.41 42.65 199.11 6,243.05 -3,901.66 9,247.59 42.00 283.50 7,425.50 -4,288.68 9,347.59 42.00 283.50 7,499.81 4,273.06 10,858.78 73.00 308.00 8,310.48 -3,689.86 10,898.78 73.00 308.00 8,322.18 -3,666.31 11,619.72 89.97 324.93 8,429.33 -3,151.62 11,688.14 89.97 324.93 8,429.37 -3,095.63 11,961.76 90.86 333.09 8,427.39 -2,861.26 23,689.08 90.86 333.09 8,251.35 7,595.30 Local Co-ordinate Reference: Well MT7-01 TVD Reference: 139.5 @ 139.50usft MD Reference: 139.5 @ 139.50usft North Reference: True Survey Calculation Method: Minimum Curvature +E/-W (usft) 0.00 0.00 -3.85 -16.67 -202.56 -1,351.83 -2,049.51 -2,114.58 -3,213.89 -3,244.03 -3,729.78 -3,769.09 -3,909.84 -9,216.37 Dogleg Build Turn Rate Rate Rate (°/100usft) (°/100usft) (°/100usft) 0.00 0.00 0.00 0.00 0.00 0.00 1.50 1.50 0.00 2.00 2.00 0.00 2.50 2.50 0.00 0.00 0.00 0.00 3.63 -0.04 5.70 0.00 0.00 0.00 2.44 2.05 1.62 0.00 0.00 0.00 3.30 2.35 2.35 0.00 0.00 0.00 3.00 0.33 2.98 0.00 0.00 0.00 TFO (°) Target 0.00 199.11 -160.89 0.00 0.00 0.00 124.37 0.00 41.32 0.00 46.22 0.00 MT7-01_Landing_071 83.72 0.00 MT7-01 TD 102720 M 8/27/2021 11:40:10AM Page 4 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: 139.5 @ 139.50usft Project: Western North Slope MD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01 wp10 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) ' n V) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 39.50 0.00 0.00 39.50 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 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 0.00 199.11 700.00 0.00 0.00 0.00 0.00 0.00 0.00 800.00 1.50 199.11 799.99 -1.24 -0.43 -0.91 1.50 1.50 0.00 900.00 3.00 199.11 899.91 -4.95 -1.71 -3.63 1.50 1.50 0.00 1,000.00 4.50 199.11 999.69 -11.13 -3.85 -8.16 1.50 1.50 0.00 1,100.00 6.50 199.11 1,099.23 -20.18 -6.99 -14.81 2.00 2.00 0.00 1,200.00 8.50 199.11 1,198.37 -32.51 -11.27 -23.86 2.00 2.00 0.00 1,300.00 10.50 199.11 1,296.99 -48.11 -16.67 -35.30 2.00 2.00 0.00 1,400.00 13.00 199.11 1,394.89 -67.35 -23.34 -49.41 2.50 2.50 0.00 1,500.00 15.50 199.11 1,491.80 -90.61 -31.39 -66.48 2.50 2.50 0.00 1,600.00 18.00 199.11 1,587.55 -117.84 -40.83 -86.46 2.50 2.50 0.00 1,700.00 20.50 199.11 1,681.95 -148.99 -51.62 -109.31 2.50 2.50 0.00 1,800.00 23.00 199.11 1,774.83 -184.00 -63.75 -135.00 2.50 2.50 0.00 1,900.00 25.50 199.11 1,865.99 -222.80 -77.20 -163.47 2.50 2.50 0.00 2,000.00 28.00 199.11 1,955.29 -265.33 -91.93 -194.67 2.50 2.50 0.00 2,100.00 30.50 199.11 2,042.53 -311.49 -107.93 -228.55 2.50 2.50 0.00 2,200.00 33.00 199.11 2,127.56 -361.21 -125.15 -265.02 2.50 2.50 0.00 2,300.00 35.50 199.11 2,210.21 -414.39 -143.57 -304.04 2.50 2.50 0.00 2,400.00 38.00 199.11 2,290.33 -470.92 -163.16 -345.52 2.50 2.50 0.00 2,500.00 40.50 199.11 2,367.76 -530.70 -183.87 -389.38 2.50 2.50 0.00 2,586.00 42.65 199.11 2,432.09 -584.62 -202.56 -428.94 2.50 2.50 0.00 2,600.00 42.65 199.11 2,442.39 -593.58 -205.66 -435.52 0.00 0.00 0.00 2,700.00 42.65 199.11 2,515.94 -657.60 -227.84 -482.49 0.00 0.00 0.00 2,800.00 42.65 199.11 2,589.49 -721.62 -250.02 -529.46 0.00 0.00 0.00 2,900.00 42.65 199.11 2,663.04 -785.63 -272.20 -576.43 0.00 0.00 0.00 3,000.00 42.65 199.11 2,736.59 -849.65 -294.38 -623.40 0.00 0.00 0.00 3,100.00 42.65 199.11 2,810.14 -913.67 -316.57 -670.37 0.00 0.00 0.00 3,200.00 42.65 199.11 2,883.69 -977.69 -338.75 -717.34 0.00 0.00 0.00 3,300.00 42.65 199.11 2,957.24 -1,041.71 -360.93 -764.31 0.00 0.00 0.00 3,364.25 42.65 199.11 3,004.50 -1,082.84 -375.18 -794.49 0.00 0.00 0.00 K3 3,400.00 42.65 199.11 3,030.80 -1,105.72 -383.11 -811.28 0.00 0.00 0.00 3,484.57 42.65 199.11 3,093.00 -1,159.87 -401.87 -851.01 0.00 0.00 0.00 Surface Csg 3,500.00 42.65 199.11 3,104.35 -1,169.74 -405.29 -858.25 0.00 0.00 0.00 3,600.00 42.65 199.11 3,177.90 -1,233.76 -427.47 -905.22 0.00 0.00 0.00 3,700.00 42.65 199.11 3,251.45 -1,297.78 -449.65 -952.19 0.00 0.00 0.00 3,800.00 42.65 199.11 3,325.00 -1,361.80 -471.83 -999.16 0.00 0.00 0.00 3,900.00 42.65 199.11 3,398.55 -1,425.82 -494.01 -1,046.13 0.00 0.00 0.00 4,000.00 42.65 199.11 3,472.10 -1,489.83 -516.19 -1,093.10 0.00 0.00 0.00 4,100.00 42.65 199.11 3,545.65 -1,553.85 -538.37 -1,140.08 0.00 0.00 0.00 4,200.00 42.65 199.11 3,619.20 -1,617.87 -560.55 -1,187.05 0.00 0.00 0.00 4,201.77 42.65 199.11 3,620.50 -1,619.00 -560.95 -1,187.88 0.00 0.00 0.00 Albian 97 4,300.00 42.65 199.11 3,692.75 -1,681.89 -582.73 -1,234.02 0.00 0.00 0.00 4,400.00 42.65 199.11 3,766.30 -1,745.91 -604.92 -1,280.99 0.00 0.00 0.00 4,457.37 42.65 199.11 3,808.50 -1,782.64 -617.64 -1,307.94 0.00 0.00 0.00 Albian 96 8/27/2021 11:40:10AM Page 5 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 Wellbore: MT7-01 Design: MT7-01 wp10 Local Co-ordinate Reference: Well MT7-01 TVD Reference: 139.5 @ 139.50usft MD Reference: 139.5 @ 139.50usft North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) V) V) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 4,500.00 42.65 199.11 3,839.85 -1,809.92 -627.10 -1,327.96 0.00 0.00 0.00 4,600.00 42.65 199.11 3,913.40 -1,873.94 -649.28 -1,374.93 0.00 0.00 0.00 4,700.00 42.65 199.11 3,986.95 -1,937.96 -671.46 -1,421.90 0.00 0.00 0.00 4,725.22 42.65 199.11 4,005.50 -1,954.10 -677.05 -1,433.74 0.00 0.00 0.00 Albian 95 4,800.00 42.65 199.11 4,060.50 -2,001.98 -693.64 -1,468.87 0.00 0.00 0.00 4,900.00 42.65 199.11 4,134.05 -2,066.00 -715.82 -1,515.84 0.00 0.00 0.00 5,000.00 42.65 199.11 4,207.61 -2,130.01 -738.00 -1,562.81 0.00 0.00 0.00 5,100.00 42.65 199.11 4,281.16 -2,194.03 -760.18 -1,609.78 0.00 0.00 0.00 5,200.00 42.65 199.11 4,354.71 -2,258.05 -782.36 -1,656.75 0.00 0.00 0.00 5,300.00 42.65 199.11 4,428.26 -2,322.07 -804.54 -1,703.72 0.00 0.00 0.00 5,400.00 42.65 199.11 4,501.81 -2,386.09 -826.72 -1,750.69 0.00 0.00 0.00 5,463.48 42.65 199.11 4,548.50 -2,426.73 -840.80 -1,780.51 0.00 0.00 0.00 Albian 94 5,500.00 42.65 199.11 4,575.36 -2,450.11 -848.90 -1,797.67 0.00 0.00 0.00 5,600.00 42.65 199.11 4,648.91 -2,514.12 -871.08 -1,844.64 0.00 0.00 0.00 5,700.00 42.65 199.11 4,722.46 -2,578.14 -893.27 -1,891.61 0.00 0.00 0.00 5,800.00 42.65 199.11 4,796.01 -2,642.16 -915.45 -1,938.58 0.00 0.00 0.00 5,900.00 42.65 199.11 4,869.56 -2,706.18 -937.63 -1,985.55 0.00 0.00 0.00 6,000.00 42.65 199.11 4,943.11 -2,770.20 -959.81 -2,032.52 0.00 0.00 0.00 6,086.18 42.65 199.11 5,006.50 -2,825.37 -978.92 -2,073.00 0.00 0.00 0.00 Albian 93 6,100.00 42.65 199.11 5,016.66 -2,834.21 -981.99 -2,079.49 0.00 0.00 0.00 6,200.00 42.65 199.11 5,090.21 -2,898.23 -1,004.17 -2,126.46 0.00 0.00 0.00 6,300.00 42.65 199.11 5,163.76 -2,962.25 -1,026.35 -2,173.43 0.00 0.00 0.00 6,400.00 42.65 199.11 5,237.31 -3,026.27 -1,048.53 -2,220.40 0.00 0.00 0.00 6,500.00 42.65 199.11 5,310.86 -3,090.29 -1,070.71 -2,267.37 0.00 0.00 0.00 6,600.00 42.65 199.11 5,384.41 -3,154.30 -1,092.89 -2,314.34 0.00 0.00 0.00 6,700.00 42.65 199.11 5,457.97 -3,218.32 -1,115.07 -2,361.31 0.00 0.00 0.00 6,800.00 42.65 199.11 5,531.52 -3,282.34 -1,137.25 -2,408.28 0.00 0.00 0.00 6,900.00 42.65 199.11 5,605.07 -3,346.36 -1,159.43 -2,455.26 0.00 0.00 0.00 7,000.00 42.65 199.11 5,678.62 -3,410.38 -1,181.62 -2,502.23 0.00 0.00 0.00 7,100.00 42.65 199.11 5,752.17 -3,474.40 -1,203.80 -2,549.20 0.00 0.00 0.00 7,200.00 42.65 199.11 5,825.72 -3,538.41 -1,225.98 -2,596.17 0.00 0.00 0.00 7,300.00 42.65 199.11 5,899.27 -3,602.43 -1,248.16 -2,643.14 0.00 0.00 0.00 7,400.00 42.65 199.11 5,972.82 -3,666.45 -1,270.34 -2,690.11 0.00 0.00 0.00 7,500.00 42.65 199.11 6,046.37 -3,730.47 -1,292.52 -2,737.08 0.00 0.00 0.00 7,600.00 42.65 199.11 6,119.92 -3,794.49 -1,314.70 -2,784.05 0.00 0.00 0.00 7,700.00 42.65 199.11 6,193.47 -3,858.50 -1,336.88 -2,831.02 0.00 0.00 0.00 7,738.11 42.65 199.11 6,221.50 -3,882.90 -1,345.33 -2,848.92 0.00 0.00 0.00 Albian 92 7,767.41 42.65 199.11 6,243.05 -3,901.66 -1,351.83 -2,862.68 0.00 0.00 0.00 7,800.00 41.99 200.57 6,267.15 -3,922.30 -1,359.28 -2,877.69 3.63 -2.02 4.48 7,888.10 40.31 204.71 6,333.50 -3,975.79 -1,381.55 -2,915.24 3.63 -1.91 4.70 Albian 91 7,900.00 40.09 205.29 6,342.59 -3,982.75 -1,384.80 -2,919.97 3.63 -1.81 4.88 8,000.00 38.40 210.37 6,420.05 -4,038.68 -1,414.26 -2,956.42 3.63 -1.69 5.08 8,100.00 36.94 215.82 6,499.23 -4,089.85 -1,447.56 -2,986.90 3.63 -1.46 5.45 8,200.00 35.75 221.61 6,579.80 -4,136.07 -1,484.56 -3,011.29 3.63 -1.19 5.79 8,300.00 34.85 227.71 6,661.44 -4,177.15 -1,525.11 -3,029.48 3.63 -0.90 6.09 8,400.00 34.26 234.03 6,743.82 -4,212.92 -1,569.04 -3,041.41 3.63 -0.58 6.32 8,500.00 34.01 240.49 6,826.62 -4,243.24 -1,616.18 -3,047.02 3.63 -0.25 6.46 8,600.00 34.10 246.98 6,909.49 -4,267.98 -1,666.34 -3,046.30 3.63 0.09 6.49 8/27/2021 11:40:10AM Page 6 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 Wellbore: MT7-01 Design: MT7-01 wp10 Local Co-ordinate Reference: Well MT7-01 TVD Reference: 139.5 @ 139.50usft MD Reference: 139.5 @ 139.50usft North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) V) V) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 8,700.00 34.53 253.38 6,992.11 -4,287.06 -1,719.32 -3,039.24 3.63 0.43 6.40 8,800.00 35.28 259.60 7,074.14 -4,300.38 -1,774.91 -3,025.87 3.63 0.75 6.21 8,900.00 36.34 265.54 7,155.26 -4,307.90 -1,832.88 -3,006.26 3.63 1.06 5.94 9,000.00 37.68 271.15 7,235.13 -4,309.59 -1,892.99 -2,980.47 3.63 1.34 5.61 9,100.00 39.27 276.41 7,313.44 -4,305.44 -1,955.02 -2,948.61 3.63 1.59 5.26 9,200.00 41.07 281.30 7,389.88 -4,295.47 -2,018.70 -2,910.82 3.63 1.81 4.89 9,227.47 41.60 282.58 7,410.50 -4,291.71 -2,036.45 -2,899.41 3.63 1.93 4.66 HRZ 9,247.59 42.00 283.50 7,425.50 -4,288.68 -2,049.51 -2,890.79 3.63 1.98 4.57 9 5/8" Casing - 9-5/8" x 12-1/4" 9,300.00 42.00 283.50 7,464.45 -4,280.50 -2,083.61 -2,868.01 0.00 0.00 0.00 9,347.59 42.00 283.50 7,499.81 4,273.06 -2,114.58 -2,847.33 0.00 0.00 0.00 9,400.00 42.97 284.74 7,538.47 -4,264.43 -2,148.90 -2,824.05 2.44 1.85 2.37 9,500.00 44.85 286.99 7,610.51 -4,245.45 -2,215.60 -2,776.86 2.44 1.88 2.24 9,538.31 45.58 287.81 7,637.50 -4,237.32 -2,241.55 -2,757.84 2.44 1.91 2.14 LCU / Miluveach 9,600.00 46.77 289.09 7,680.21 -4,223.23 -2,283.76 -2,726.12 2.44 1.93 2.07 9,700.00 48.73 291.06 7,747.44 -4,197.82 -2,353.28 -2,671.92 2.44 1.96 1.97 9,800.00 50.72 292.91 7,812.08 -4,169.24 -2,424.01 -2,614.34 2.44 1.99 1.85 9,900.00 52.74 294.66 7,874.01 -4,137.56 -2,495.84 -2,553.51 2.44 2.02 1.75 10,000.00 54.79 296.32 7,933.12 -4,102.84 -2,568.64 -2,489.52 2.44 2.04 1.66 10,100.00 56.85 297.90 7,989.30 -4,065.13 -2,642.26 -2,422.50 2.44 2.06 1.58 10,200.00 58.94 299.40 8,042.45 -4,024.51 -2,716.58 -2,352.56 2.44 2.08 1.50 10,300.00 61.04 300.84 8,092.47 -3,981.05 -2,791.47 -2,279.84 2.44 2.10 1.44 10,400.00 63.15 302.22 8,139.27 -3,934.83 -2,866.78 -2,204.47 2.44 2.12 1.38 10,500.00 65.28 303.56 8,182.77 -3,885.93 -2,942.38 -2,126.58 2.44 2.13 1.33 10,600.00 67.42 304.84 8,222.88 -3,834.44 -3,018.13 -2,046.31 2.44 2.14 1.29 10,700.00 69.57 306.09 8,259.54 -3,780.46 -3,093.90 -1,963.81 2.44 2.15 1.25 10,755.88 70.77 306.77 8,278.49 -3,749.24 -3,136.19 -1,916.80 2.44 2.16 1.22 Alpine D 10,800.00 71.73 307.30 8,292.67 -3,724.08 -3,169.54 -1,879.24 2.44 2.16 1.20 10,856.04 72.94 307.97 8,309.68 -3,691.47 -3,211.82 -1,830.99 2.44 2.16 1.19 7" x 8-1/2" 10,858.78 73.00 308.00 8,310.48 -3,689.86 -3,213.89 -1,828.61 2.44 2.17 1.18 10,898.78 73.00 308.00 8,322.18 -3,666.31 -3,244.03 -1,793.95 0.00 0.00 0.00 10,899.55 73.02 308.02 8,322.40 -3,665.86 -3,244.61 -1,793.28 3.30 2.29 2.49 Alpine C 10,900.00 73.03 308.03 8,322.53 -3,665.59 -3,244.95 -1,792.89 3.29 2.28 2.49 11,000.00 75.33 310.49 8,349.80 -3,604.70 -3,319.43 -1,704.83 3.30 2.30 2.46 11,100.00 77.65 312.90 8,373.17 -3,540.03 -3,392.01 -1,614.25 3.30 2.32 2.41 11,200.00 79.99 315.27 8,392.56 -3,471.78 -3,462.46 -1,521.45 3.30 2.34 2.37 11,300.00 82.35 317.60 8,407.90 -3,400.18 -3,530.54 -1,426.75 3.30 2.36 2.33 11,400.00 84.73 319.91 8,419.15 -3,325.47 -3,596.03 -1,330.45 3.30 2.37 2.31 11,500.00 87.11 322.20 8,426.27 -3,247.90 -3,658.72 -1,232.87 3.30 2.38 2.29 11,600.00 89.49 324.48 8,429.24 -3,167.72 -3,718.39 -1,134.35 3.30 2.39 2.28 11,619.72 89.97 324.93 8,429.33 -3,151.62 -3,729.78 -1,114.83 3.30 2.39 2.28 11,688.14 89.97 324.93 8,429.37 -3,095.63 -3,769.09 -1,047.09 0.00 0.00 0.00 11,700.00 90.00 325.29 8,429.37 -3,085.90 -3,775.87 -1,035.34 3.00 0.33 2.98 11,800.00 90.33 328.27 8,429.08 -3,002.25 -3,830.65 -935.94 3.00 0.33 2.98 11,900.00 90.66 331.25 8,428.21 -2,915.87 -3,881.01 -836.12 3.00 0.33 2.98 11,961.76 90.86 333.09 8,427.39 -2,861.26 -3,909.84 -774.37 3.00 0.33 2.98 12,000.00 90.86 333.09 8,426.82 -2,827.17 -3,927.14 -736.14 0.00 0.00 0.00 12,100.00 90.86 333.09 8,425.32 -2,738.00 -3,972.39 -636.15 0.00 0.00 0.00 8/27/2021 11:40:10AM Page 7 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: 139.5 @ 139.50usft Project: Western North Slope MD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01 wp10 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) V) V) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 12,200.00 90.86 333.09 8,423.82 -2,648.84 -4,017.64 -536.16 0.00 0.00 0.00 12,300.00 90.86 333.09 8,422.32 -2,559.67 -4,062.89 -436.17 0.00 0.00 0.00 12,400.00 90.86 333.09 8,420.82 -2,470.51 -4,108.14 -336.18 0.00 0.00 0.00 12,500.00 90.86 333.09 8,419.31 -2,381.34 -4,153.39 -236.20 0.00 0.00 0.00 12,600.00 90.86 333.09 8,417.81 -2,292.18 -4,198.64 -136.21 0.00 0.00 0.00 12,700.00 90.86 333.09 8,416.31 -2,203.02 -4,243.89 -36.22 0.00 0.00 0.00 12,800.00 90.86 333.09 8,414.81 -2,113.85 -4,289.13 63.77 0.00 0.00 0.00 12,900.00 90.86 333.09 8,413.31 -2,024.69 -4,334.38 163.76 0.00 0.00 0.00 13,000.00 90.86 333.09 8,411.81 -1,935.52 -4,379.63 263.75 0.00 0.00 0.00 13,100.00 90.86 333.09 8,410.31 -1,846.36 -4,424.88 363.74 0.00 0.00 0.00 13,200.00 90.86 333.09 8,408.81 -1,757.20 -4,470.13 463.72 0.00 0.00 0.00 13,300.00 90.86 333.09 8,407.31 -1,668.03 -4,515.38 563.71 0.00 0.00 0.00 13,400.00 90.86 333.09 8,405.80 -1,578.87 -4,560.63 663.70 0.00 0.00 0.00 13,500.00 90.86 333.09 8,404.30 -1,489.70 -4,605.88 763.69 0.00 0.00 0.00 13,600.00 90.86 333.09 8,402.80 -1,400.54 -4,651.13 863.68 0.00 0.00 0.00 13,700.00 90.86 333.09 8,401.30 -1,311.38 -4,696.38 963.67 0.00 0.00 0.00 13,800.00 90.86 333.09 8,399.80 -1,222.21 -4,741.63 1,063.66 0.00 0.00 0.00 13,900.00 90.86 333.09 8,398.30 -1,133.05 -4,786.88 1,163.64 0.00 0.00 0.00 14,000.00 90.86 333.09 8,396.80 -1,043.88 -4,832.13 1,263.63 0.00 0.00 0.00 14,100.00 90.86 333.09 8,395.30 -954.72 -4,877.38 1,363.62 0.00 0.00 0.00 14,200.00 90.86 333.09 8,393.80 -865.55 -4,922.63 1,463.61 0.00 0.00 0.00 14,300.00 90.86 333.09 8,392.29 -776.39 -4,967.88 1,563.60 0.00 0.00 0.00 14,400.00 90.86 333.09 8,390.79 -687.23 -5,013.12 1,663.59 0.00 0.00 0.00 14,500.00 90.86 333.09 8,389.29 -598.06 -5,058.37 1,763.58 0.00 0.00 0.00 14,600.00 90.86 333.09 8,387.79 -508.90 -5,103.62 1,863.56 0.00 0.00 0.00 14,700.00 90.86 333.09 8,386.29 419.73 -5,148.87 1,963.55 0.00 0.00 0.00 14,800.00 90.86 333.09 8,384.79 -330.57 -5,194.12 2,063.54 0.00 0.00 0.00 14,900.00 90.86 333.09 8,383.29 -241.41 -5,239.37 2,163.53 0.00 0.00 0.00 15,000.00 90.86 333.09 8,381.79 -152.24 -5,284.62 2,263.52 0.00 0.00 0.00 15,100.00 90.86 333.09 8,380.28 -63.08 -5,329.87 2,363.51 0.00 0.00 0.00 15,200.00 90.86 333.09 8,378.78 26.09 -5,375.12 2,463.50 0.00 0.00 0.00 15,300.00 90.86 333.09 8,377.28 115.25 -5,420.37 2,563.49 0.00 0.00 0.00 15,400.00 90.86 333.09 8,375.78 204.41 -5,465.62 2,663.47 0.00 0.00 0.00 15,500.00 90.86 333.09 8,374.28 293.58 -5,510.87 2,763.46 0.00 0.00 0.00 15,600.00 90.86 333.09 8,372.78 382.74 -5,556.12 2,863.45 0.00 0.00 0.00 15,700.00 90.86 333.09 8,371.28 471.91 -5,601.37 2,963.44 0.00 0.00 0.00 15,800.00 90.86 333.09 8,369.78 561.07 -5,646.62 3,063.43 0.00 0.00 0.00 15,900.00 90.86 333.09 8,368.28 650.24 -5,691.87 3,163.42 0.00 0.00 0.00 16,000.00 90.86 333.09 8,366.77 739.40 -5,737.11 3,263.41 0.00 0.00 0.00 16,100.00 90.86 333.09 8,365.27 828.56 -5,782.36 3,363.39 0.00 0.00 0.00 16,200.00 90.86 333.09 8,363.77 917.73 -5,827.61 3,463.38 0.00 0.00 0.00 16,300.00 90.86 333.09 8,362.27 1,006.89 -5,872.86 3,563.37 0.00 0.00 0.00 16,400.00 90.86 333.09 8,360.77 1,096.06 -5,918.11 3,663.36 0.00 0.00 0.00 16,500.00 90.86 333.09 8,359.27 1,185.22 -5,963.36 3,763.35 0.00 0.00 0.00 16,600.00 90.86 333.09 8,357.77 1,274.38 -6,008.61 3,863.34 0.00 0.00 0.00 16,700.00 90.86 333.09 8,356.27 1,363.55 -6,053.86 3,963.33 0.00 0.00 0.00 16,800.00 90.86 333.09 8,354.77 1,452.71 -6,099.11 4,063.31 0.00 0.00 0.00 16,900.00 90.86 333.09 8,353.26 1,541.88 -6,144.36 4,163.30 0.00 0.00 0.00 17,000.00 90.86 333.09 8,351.76 1,631.04 -6,189.61 4,263.29 0.00 0.00 0.00 17,100.00 90.86 333.09 8,350.26 1,720.20 -6,234.86 4,363.28 0.00 0.00 0.00 17,200.00 90.86 333.09 8,348.76 1,809.37 -6,280.11 4,463.27 0.00 0.00 0.00 17,300.00 90.86 333.09 8,347.26 1,898.53 -6,325.36 4,563.26 0.00 0.00 0.00 17,400.00 90.86 333.09 8,345.76 1,987.70 -6,370.61 4,663.25 0.00 0.00 0.00 17,500.00 90.86 333.09 8,344.26 2,076.86 -6,415.86 4,763.23 0.00 0.00 0.00 8/27/2021 11:40:10AM Page 8 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: 139.5 @ 139.50usft Project: Western North Slope MD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01 wp10 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) V) V) (usft) ' (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 17,600.00 90.86 333.09 8,342.76 2,166.03 -6,461.10 4,863.22 0.00 0.00 0.00 17,700.00 90.86 333.09 8,341.26 2,255.19 -6,506.35 4,963.21 0.00 0.00 0.00 17,800.00 90.86 333.09 8,339.75 2,344.35 -6,551.60 5,063.20 0.00 0.00 0.00 17,900.00 90.86 333.09 8,338.25 2,433.52 -6,596.85 5,163.19 0.00 0.00 0.00 18,000.00 90.86 333.09 8,336.75 2,522.68 -6,642.10 5,263.18 0.00 0.00 0.00 18,100.00 90.86 333.09 8,335.25 2,611.85 -6,687.35 5,363.17 0.00 0.00 0.00 18,200.00 90.86 333.09 8,333.75 2,701.01 -6,732.60 5,463.15 0.00 0.00 0.00 18,300.00 90.86 333.09 8,332.25 2,790.17 -6,777.85 5,563.14 0.00 0.00 0.00 18,400.00 90.86 333.09 8,330.75 2,879.34 -6,823.10 5,663.13 0.00 0.00 0.00 18,500.00 90.86 333.09 8,329.25 2,968.50 -6,868.35 5,763.12 0.00 0.00 0.00 18,600.00 90.86 333.09 8,327.74 3,057.67 -6,913.60 5,863.11 0.00 0.00 0.00 18,700.00 90.86 333.09 8,326.24 3,146.83 -6,958.85 5,963.10 0.00 0.00 0.00 18,800.00 90.86 333.09 8,324.74 3,236.00 -7,004.10 6,063.09 0.00 0.00 0.00 18,900.00 90.86 333.09 8,323.24 3,325.16 -7,049.35 6,163.07 0.00 0.00 0.00 19,000.00 90.86 333.09 8,321.74 3,414.32 -7,094.60 6,263.06 0.00 0.00 0.00 19,100.00 90.86 333.09 8,320.24 3,503.49 -7,139.85 6,363.05 0.00 0.00 0.00 19,200.00 90.86 333.09 8,318.74 3,592.65 -7,185.09 6,463.04 0.00 0.00 0.00 19,300.00 90.86 333.09 8,317.24 3,681.82 -7,230.34 6,563.03 0.00 0.00 0.00 19,400.00 90.86 333.09 8,315.74 3,770.98 -7,275.59 6,663.02 0.00 0.00 0.00 19,500.00 90.86 333.09 8,314.23 3,860.14 -7,320.84 6,763.01 0.00 0.00 0.00 19,600.00 90.86 333.09 8,312.73 3,949.31 -7,366.09 6,863.00 0.00 0.00 0.00 19,700.00 90.86 333.09 8,311.23 4,038.47 -7,411.34 6,962.98 0.00 0.00 0.00 19,800.00 90.86 333.09 8,309.73 4,127.64 -7,456.59 7,062.97 0.00 0.00 0.00 19,900.00 90.86 333.09 8,308.23 4,216.80 -7,501.84 7,162.96 0.00 0.00 0.00 20,000.00 90.86 333.09 8,306.73 4,305.96 -7,547.09 7,262.95 0.00 0.00 0.00 20,100.00 90.86 333.09 8,305.23 4,395.13 -7,592.34 7,362.94 0.00 0.00 0.00 20,200.00 90.86 333.09 8,303.73 4,484.29 -7,637.59 7,462.93 0.00 0.00 0.00 20,300.00 90.86 333.09 8,302.23 4,573.46 -7,682.84 7,562.92 0.00 0.00 0.00 20,400.00 90.86 333.09 8,300.72 4,662.62 -7,728.09 7,662.90 0.00 0.00 0.00 20,500.00 90.86 333.09 8,299.22 4,751.79 -7,773.34 7,762.89 0.00 0.00 0.00 20,600.00 90.86 333.09 8,297.72 4,840.95 -7,818.59 7,862.88 0.00 0.00 0.00 20,700.00 90.86 333.09 8,296.22 4,930.11 -7,863.83 7,962.87 0.00 0.00 0.00 20,800.00 90.86 333.09 8,294.72 5,019.28 -7,909.08 8,062.86 0.00 0.00 0.00 20,900.00 90.86 333.09 8,293.22 5,108.44 -7,954.33 8,162.85 0.00 0.00 0.00 21,000.00 90.86 333.09 8,291.72 5,197.61 -7,999.58 8,262.84 0.00 0.00 0.00 21,100.00 90.86 333.09 8,290.22 5,286.77 -8,044.83 8,362.82 0.00 0.00 0.00 21,200.00 90.86 333.09 8,288.71 5,375.93 -8,090.08 8,462.81 0.00 0.00 0.00 21,300.00 90.86 333.09 8,287.21 5,465.10 -8,135.33 8,562.80 0.00 0.00 0.00 21,400.00 90.86 333.09 8,285.71 5,554.26 -8,180.58 8,662.79 0.00 0.00 0.00 21,500.00 90.86 333.09 8,284.21 5,643.43 -8,225.83 8,762.78 0.00 0.00 0.00 21,600.00 90.86 333.09 8,282.71 5,732.59 -8,271.08 8,862.77 0.00 0.00 0.00 21,700.00 90.86 333.09 8,281.21 5,821.75 -8,316.33 8,962.76 0.00 0.00 0.00 21,800.00 90.86 333.09 8,279.71 5,910.92 -8,361.58 9,062.74 0.00 0.00 0.00 21,900.00 90.86 333.09 8,278.21 6,000.08 -8,406.83 9,162.73 0.00 0.00 0.00 22,000.00 90.86 333.09 8,276.71 6,089.25 -8,452.08 9,262.72 0.00 0.00 0.00 22,100.00 90.86 333.09 8,275.20 6,178.41 -8,497.33 9,362.71 0.00 0.00 0.00 22,200.00 90.86 333.09 8,273.70 6,267.58 -8,542.58 9,462.70 0.00 0.00 0.00 22,300.00 90.86 333.09 8,272.20 6,356.74 -8,587.82 9,562.69 0.00 0.00 0.00 22,400.00 90.86 333.09 8,270.70 6,445.90 -8,633.07 9,662.68 0.00 0.00 0.00 22,500.00 90.86 333.09 8,269.20 6,535.07 -8,678.32 9,762.66 0.00 0.00 0.00 22,600.00 90.86 333.09 8,267.70 6,624.23 -8,723.57 9,862.65 0.00 0.00 0.00 22,700.00 90.86 333.09 8,266.20 6,713.40 -8,768.82 9,962.64 0.00 0.00 0.00 22,800.00 90.86 333.09 8,264.70 6,802.56 -8,814.07 10,062.63 0.00 0.00 0.00 22,900.00 90.86 333.09 8,263.20 6,891.72 -8,859.32 10,162.62 0.00 0.00 0.00 8/27/2021 11:40:10AM Page 9 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 Wellbore: MT7-01 Design: MT7-01 wp10 Local Co-ordinate Reference: Well MT7-01 TVD Reference: 139.5 @ 139.50usft MD Reference: 139.5 @ 139.50usft North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) V) V) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 23,000.00 90.86 333.09 8,261.69 6,980.89 -8,904.57 10,262.61 0.00 0.00 0.00 23,100.00 90.86 333.09 8,260.19 7,070.05 -8,949.82 10,362.60 0.00 0.00 0.00 23,200.00 90.86 333.09 8,258.69 7,159.22 -8,995.07 10,462.58 0.00 0.00 0.00 23,300.00 90.86 333.09 8,257.19 7,248.38 -9,040.32 10,562.57 0.00 0.00 0.00 23,400.00 90.86 333.09 8,255.69 7,337.55 -9,085.57 10,662.56 0.00 0.00 0.00 23,500.00 90.86 333.09 8,254.19 7,426.71 -9,130.82 10,762.55 0.00 0.00 0.00 23,600.00 90.86 333.09 8,252.69 7,515.87 -9,176.07 10,862.54 0.00 0.00 0.00 23,689.08 90.86 333.09 8,251.35 7,595.30 -9,216.37 10,951.60 0.00 0.00 0.00 Design Targets Target Name hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape (I V) (usft) (usft) (usft) (usft) (usft) Latitude Longitude MT7-01 TD 102720 MS 0.00 0.00 8,251.35 7,595.30 -9,216.37 5,923,428.28 1,421,060.64 70' 11' 37.322 N 151° 46' 3.649 W plan hits target center Circle (radius 100.00) MT7-01_Landing_07162 0.00 0.00 8,429.37 -3,095.63 -3,769.09 5,912,590.59 1,426,208.34 70° 9' 52.219 N 151° 43' 25.501 W plan hits target center Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) ' Name (in) (in) 3,484.57 3,093.00 Surface Csg 13.375 16.000 9,247.59 7,425.50 9-5/8" x 12-1/4" 9.625 12.250 10,856.04 8,309.68 7" x 8-1/2" 7.000 8.500 Formations Mir Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology (1) (�) 3,364.25 3,004.50 K3 Empty 0.00 4,201.77 3,620.50 Albian 97 Empty 0.00 4,457.37 3,808.50 Albian 96 Empty 0.00 4,725.22 4,005.50 Albian 95 Empty 0.00 5,463.48 4,548.50 Albian 94 Empty 0.00 6,086.18 5,006.50 Albian 93 Empty 0.00 7,738.11 6,221.50 Albian 92 Empty 0.00 7,888.10 6,333.50 Albian 91 0.00 9,227.47 7,410.50 HRZ Empty 0.00 9,538.31 7,637.50 LCU / Miluveach Empty 0.00 10,755.88 8,278.49 Alpine D 0.00 10,899.55 8,322.40 Alpine C Empty 0.00 8/27/2021 11:40:10AM Page 10 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 Company: ConocoPhillips Alaska Inc_WNS TVD Reference: 139.5 @ 139.50usft Project: Western North Slope MD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01 wp10 'Ian Annotations Measured Vertical Local Coordinates Depth Depth +NI-S +E/-W (usft) (usft) 1 (usft) (usft) 1 Comment Mh 9,247.59 7,425.50-4,288.68-2,049.51 9 5/8" Casing 8/27/2021 11:40:10AM Page 11 COMPASS 5000.15 Build 91E THE STATE 'ALASKA GOVLRNOR MIKE DUNLRAVY Chris Brillon Wells Engineering Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Greater Mooses Tooth Field, Rendezvous Oil Pool, MT7-01 Alaska Oil and Gas Conservation Commission ConocoPhillips Alaska, Inc. Permit to Drill Number: 221-052 Surface Location: 1015' FSL, 1947' FWL, SESW, S32, T10N, R2E Bottomhole Location: 1954' FNL, 2132' FEL, SWNE, S25, T10N, R1E Dear Mr. Brillon: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the permit to drill the above referenced 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, Jerem Digitally signed Y by Jeremy Price Date: 2021.08.26 Price 15:11:01 _08'00' Jeremy M. Price Chair DATED this 26 day of August, 2021. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED By Meredith Guhl at 8:32 am, Jul 30, 2021 1 a. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill El Lateral ❑ Stratigraphic Test ❑ Development - Oil 0 Service - Winj ❑ Single Zone Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: Blanket 0 Single Well ❑ 11. Well Name and Number: ConocoPhillips Bond No. 59-52-180 MT7-01 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, Alaska, 99510-0360 MD: 23842 TVD: 8251 Greater Mooses Tooth Rendezvous 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1015' FSL, 1947' FWL, SESW S32 T1ON R2E AA081800, AA081781, AA081803 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 2457' FSL, 1287' FEL, NESE S6 T9N R2E 932535000, 932516000, 932538000 8/25/2021 9. Acres in Property: 14. Distance to Nearest Property: Total Depth: 1954' FNL, 2132' FEL, SWNE S25 T1 ON R1 E 3776, 5720, 5756 7108' to AA081784 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 139.50' (per CoP ) 5. Distance to Nearest Well Open Surface: x- 290025 y- 5915835 Zone-4 GL / BF Elevation above MSL (ft): 100.00- to Same Pool: 723' to Rendezvous 2 16. Deviated wells: Kickoff depth: 700 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 90 degrees Downhole: 3945 Surface: 3093 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 80.5 40 40 120 120 10 yards 16.. 13.375" 68.00 L-80 Hyd563 3444 40 40 3484 3093 2300sx 11 ppg, 310sx 15.8 ppg 9-7/8"x11" 7.625" 29.7 / 33.7 L-80 Hyd563/TXP 10826 40 40 10865 8310 280sx 15.8 ppg Class G 6.5" 4.5" 1 12.60 L-80 Hyd563 13127 10715 8323 23842 8251 Uncemented liner w/frac sleeves and perfjoints 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Hydraulic Fracture planned? Yes❑✓ No ❑ 20. Attachments: Property Plat El BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements 21. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Nina Anderson Authorized Name: Chris Brillon Contact Email: nina.anderson c0 .com Authorized Title: Wells Engineering Manager Contact Phone: 907-265-6403 �DocuSigned by: (din Date: 3 U1-29-2021 Authorized Signature: t, s i° C579E72E81F2445... Commission Use Only Permit to Drill API Number: Permit Approval 8/26/21 See cover letter for other Number: 221-052 50-103-20832-00-00 Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: BOP test to 3500 psig Samples req'd: Yes ❑ Nok] Mud log req'd: Yes❑ NobE Annular preventer test to 2500 psig H2S measures: Yes ❑ NoX] Directional svy req'd: YesR] No❑ Diverter variance granted per 20 AAC 25.035(h)(2) Spacing exception req'd: Yes ❑ No[k Inclination -only svy req'd: Yes❑ No0 Intermediate cement CBL required before drilling production hole. Post initial injection MIT req'd: Yes ❑ NoW Surface casing LOT results to AOGCC as soon as obtained Digitally signed by Jeremy Price Price APPROVED BY 8/26/21 Approved by: .Jeremy Date: 2021.08.2615:12:03-08'00' COMMISSIONER THE COMMISSION Date: Comm. CommJLC 8/26/2021 Sr Pet Eng VTL 8/26/21 I Sr Pet Geo DLB 08/05/2021 ISr Res Eng DSR-8/2/21 Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 27, 2021 Alaska Oil and Gas Conservation Commission 333 West 71 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill MT7-01 Dear Sir or Madam: ConocoPhillips p ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine C-Sand Producer well from the MT7 drilling pad. The intended spud date for this well is 8/25/2021. It is intended that Doyon 25 be used to drill the well. MT7-01 will utilize a 16" surface hole and will TD above the K3 sand and then 13.375" casing will be set and cemented to surface. The 9-5/8" x I I" intermediate hole will be drilled into the top of the Alpine D and landed at an inclination of — 730. A 7.625" casing string will be set and cemented from TD to secure the shoe and cover 500'MD or 250'TVD above any hydrocarbon -bearing zones. The production interval will be comprised of a 6.5" horizontal hole that will be geo-steered in the Alpine C sand. The well will be completed as a fracture stimulated Producer with 4.5" uncemented liner with frac sleeves and swell packers. The upper completion will incude a production packer with GLM's and tied back to surface. It is requested that a variance of the diverter requirement under 20 AAC25.035 (h)(2) is granted. At MT7 there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. DLB 08/05/2021 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. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) 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 Nina Anderson at 265-6403 (nina.anderson@conocophillips.com) or Chris Brillon at 265-6120. Sincerely, DocuSigned by: cc: MT7-01 Well File / Jenna Taylor ATO 1560 w Dave Lee ATO 1726 Nina And,. os000as6C6Eo49F... Chris Brillon ATO 1548 Drilling Engineer Kathryn Hoffineister ATO 1760 MT7-01 Application for Permit to Drill Document ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 ()9)............................................................ 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2))............................................ 2 3. Proposed Drilling Program......................................................................................3 4. Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) ................................................................................................................................... 4 5. MASP Calculations...................................................................................................4 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5))............................................................................................................... 5 7. Casing and Cementing Program.............................................................................6 S. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8))....................................7 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 7 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10))..........................................7 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)).........................8 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12))...................................8 13. Discussion of Mud and Cuttings Disposal and Annular Disposal .......................8 (Requirements of 20 AAC 25.005 (c)(14))............................................................................. 8 14. Drilling Hazards Summary.......................................................................................9 15. Proposed Completion Schematic.........................................................................11 MT7-06 Page 1 of 11 Printed: 29-Jul-21 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as MT7-01 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ages Location at Surface 1015' FSL, 1947' FWL, SESW S32 T10N R2E, UM NAD 1983 RKB Elevation 39.5' AMSL Northings: 1430062 Eastings: 5915580 Pad Elevation 100.0' AMSL Top of Productive Horizon Heel 2457' FSL, 1287' FEL, NESE S6 T9N R2E, UM NAD 1983 Northings: 1426734 Eastings: 5911833 Measured Depth, RKB: 10906' Total Vertical Depth, RKB: 8322' Total Vertical Depth, SS.- 8183' Total Depth Toe 1954' FNL, 2132' FEL, SWNE S25 T10N R1E, UM NAD 1983 Northings: 1421060 Eastings: 5923428 Measured Depth, RKB: 23842' Total Vertical Depth, RKB: 8251' Total Vertical Depth, SS: 8111, ------------------- .............. L-- - �M��®� ® ® �� [-----------I a..°ateI ® ®®®® -- ---- ®O® -- - = p O® - *' _ _ -- �— — - - -- - ®R o o �a cNn,rts>.xc MT70 SITE PLAN — r - ss-r MT7-06 Page 2 of 11 Printed: 29-Jul-21 Well Stick Diagram Reservoir Target 7I Producer toeNInjector Surface Conductor Bti S 3. Proposed Drilling Program The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. MIRU Doyon 25 onto MT7-01 2. Rig up and test riser, dewater cellar as needed. 3. Drill 16" hole to the surface casing point as per the directional plan (LWD Program: GR). 4. Run and cement 13.375" surface casing to surface. 5. Install BOPE and MPD equipment. 6. Test BOPE to 250 psi low / 3500 psi high (24-48 hr regulatory notice). 7. Pick up and run in hole with 9-7/8 x 11" drilling BHA to drill the intermediate hole section. 8. Chart casing pressure test to 3000 psi for 30 minutes. 9. Drill out 20' of new hole and perform LOT. Maximum LOT to 18.5 ppg. Minimum LOT required to drill ahead is 12.5 ppg EMW. 10. Drill 9-7/8 x 11" hole to section TD, using Managed Pressure Drilling to maintain near constant bottom hole pressure on connections in shale formation (LWD Program: GR/RES). 11. Change out upper pipe rams to 7.625" solid bodies and test same to 3,500 psi. 12. Run 7.625" casing and cement to 250' TVD above the hydrocarbon bearing zones (cementing schematic attached). Run CBL cement evaluation log and review log with AOGCC. 13. Change upper pipe rams to 3-1/2" x 6" VBRs. MT7-06 Page 3 of 11 Printed: 29-Jul-21 14. Test BOPE to 250 psi low / 3,500 psi high (24-48 Regulatory notice). 15. Pick up and run in hole with 6.5" drilling BHA. Log top of cement with sonic tool in recorded mode. 16. Chart casing pressure test to 3500 psi for 30 minutes. 17. Drill out shoe track and 20 feet of new formation. Perform LOT to a maximum of 16.0 ppg. Minimum required leak -off value is 11.0 ppg EMW. 18. Drill 6.5" hole to section TD (LWD Program: GR/RES). 19. Pull out of hole with drilling BHA. Review cement job details and sonic log TOC. 20. Run 4.5" liner with frac sleeves, swell packers, and perforate joints with liner hanger to TD. 21. Run 4.5" upper completion with production packer, landing nipple, ball seat, gas lift mandrel(s), and downhole gauge. Displace mud in production casing to kill weight brine, space out and land tubing hanger with pre - installed and pre -tested BPV. 22. Pressure test hanger seals to 5,000 psi. 23. Drop ball and rod to set production packer, test tubing to 4200 psi, chart test. 24. Bleed tubing pressure to 2200 psi and test IA to 4200 psi, chart test. 25. Install HP-BPV and test to 2500 psi. 26. Nipple down BOP. 27. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes. 28. Freeze protect down tubing and annulus. 29. Secure well. Rig down and move out. 4. Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP schematics on file for Doyon 25. It is requested that a variance of the diverter requirement under 20 AAC 25.035 (h)(2) is granted. At MT7, there has not been a significant indication of shallow gas or gas hydrates through the surface hole interval. 5. MASP Calculations The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size in Csg Setting Depth MD/TVD ft Fracture Gradient(psi) Pore pressure ASP Drilling (psi) 20 120 / 120 10.9 51 54 13.375 3484/ 3093 14.5 1383 2023 7.625 10865/ 8323 12.5 3,751 3093 4.5 23842/ 8251 12.5 3,945 n/a PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB MT7-06 Page 4 of 11 Printed: 29-Jul-21 OR 2) ASP =FPP - (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS 1. Drilling below 20" conductor ASP = [(FG x 0.052) - 0.1] D = [(10.9 x 0.052) - 0. 1] x 115 = 54 psi OR ASP = FPP - (0.1 x D) = 1383 - (0.1 x 3093) = 1074 psi Minimum MWE needed=8.6 ppg 2. Drilling below 13.375" surface casing ASP = [(FG x 0.052) - 0.1] D = [(14.5 x 0.052) - 0.1] x 3093= 2023 psi OR ASP = FPP - (0.1 x D) = 3751 - (0.1 x 8323) = 2918 psi Minimum MWE needed=8.7 ppg 3. Drilling below 7.625" intermediate casing ASP = [(FG x 0.052) - 0.1] D = [(12.5 x 0.052) - 0.1] x 8323= 4578 psi OR ASP = FPP - (0.1 x D) = 3945- (0.1 x 8251)= 3120 psi Minimum MWE needed=9.1 ppg DLB (8/5/2021) (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 6. Procedure for Conducting Formation Integrity Tests (Requirements of20aac 25.005 ©(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. MT7-06 Page 5 of 11 Printed: 29-Jul-21 7. Casing and Cementing Program Casing and Cerne fing Program Csg/Tbg Hole Size Weight Grade Conn. Cement Program OD (in) (in) (Ib/ft) 20 42 94 H-40 Welded Cemented to surface with 10 yds slurry 13.375 16 68 L-80 H563 Cement to Surface 7.625 9-7/8 x 11 29.7 / L80 Hyd563/TXP 250' TVD or 500' MD, whichever is greater, above upper 33.7 most producing zone 4.5 6.5 12.6 L-80 Hyd563 Uncemented liner with frac sleeves Cementinq Calculations 13.375" Surface Casing run to 3484' MD / 3093' TVD Cement from 3484' MD to 2984' (500' of tail) with DeepCRETE + Add's. @ 11 PPG, and from 2984' to surface with 11 ppg DeepCrete. Assume 250% excess annular volume in permafrost and 50% excess below the permafrost (1325' MD), zero excess in 20" conductor. Lead slurry from 2984' MD to surface with Arctic Lite Crete @ 11 ppg Total Volume = 4392 ft3 => 2300 sx of 11ppg DeepCRETE + Add's @ 1.91 ft3 /sk Tail slurry from 3484' MD to 2984' MD with 15.8 ppg DeepCRETE + Add's Total Volume = 349 ft3 => 310.0 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk 7.625" Intermediate Casing run to 10865' MD / 8323' TVD Top of slurry is designed to be at 10250' MD, which is 500'MD or 250' TVD above the prognosis shallowest hydrocarbon bearing zone Alpine C. If a shallower hydrocarbon zone of producible volumes, is encountered while drilling, a 2 stage cement job will be performed to isolate this zone. Assume 40% excess annular volume. Tail slurry from 10865' MD to 10250' MD with 15.8 ppg Class G + Add's Total Volume = 322 ft3 => 280 sx of 15.8 ppg Class G + Add's@ 1.16 ft3/sk MT7-06 Page 6 of 11 Printed: 29-Jul-21 8. Drilling Fluid Program (Requirements of20AAC25.005(c)(8)) Surface Intermediate Production Hole Size in. 16 9-7/8 x 11 6.5 Casing Size in. 13.375 7.625 4.5 Density PPG 9.0 — 10.5 9.6 — 11.2 8.8 — 9.5 PV cP 30 - 80 10 15 YP Ib./100 ft2 100 - 200 20 - 28 15 - 20 Funnel Viscosity s/qt. 300 50 - 60 60 - 80 Initial Gels Ib./100 ft2 50 10 10 10 Minute Gels Ib./100 ft2 60 15 15 API Fluid Loss cc/30 min. N.C. — 15.0 5.0 4.0 HPHT Fluid Loss cc/30 min. n/a 8.0 — 12.0 10.0 pH 11.0 9.5-10.0 9.0-9.5 Surface Hole: A potassium silicate freshwater drilling fluid will be used for the surface interval. Mud engineer to perform regular mud checks to maintain proper levels of silicate concentration and pH level. The mud weight will be maintained at <10.0 ppg by use of solids control system and dilutions where necessary. Intermediate Fresh water polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is a slight potential for lost circulation, particularly after the reservoir is penetrated. Maintain mud weight at or below 12.0 ppg for formation stability and be prepared to add loss circulation material if necessary. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining wellbore stability. The mud will be weighted up to 10.8 — 11.2 ppg before pulling out of the hole. Note: Managed Pressure Drilling (MPD) will be utilized for adding backpressure during connections to mitigate shale instability and cycling. Production Hole: The horizontal production interval will be drilled with an oil -based mud drill -in fluid VersaPro weighted to 8.8 — 9.5 ppg with calcium carbonate. MPD will be used to hold back pressure during connections keeping the well dynamically balanced. Diagram of Doyon 25 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of20AAC25.005 (c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. MT7-06 Page 7 of 11 Printed: 29-Jul-21 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well MT7-01 will be injected into a permitted annulus on the MT7 pad or hauled to an approved Class 1 disposal well on CD 1. The MT7-01 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to —2000' TVD. There will be 500' of cement placed above the top of the Alpine reservoir along with 500' above any other reservoir that is encountered per regulations. Once MT7-01 has been drilled and completed, consideration may be given to submit this well for annular injection sundry approval. An application for Sundry Operations form 10-403 will then be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080 could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in shale near the base of the C5 interval, above the K3. The upper confining barrier is composed of 1,000 feet TVD of shale and siltstone of the Upper Cretaceous Colville Group. The lower barrier is composed of over 3,000 feet TVD of Torok Group, primarily marine shale with some interbedded thin sands. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (3093') + 1,500 psi = 3430 psi Pore Pressure = 1,208 psi Therefore Differential = 3430— 1,208 = 2222 psi. The internal casing pressure is conservative since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: OD Wt Grade Range Connection Collapse 85% of Burst 85% of (ppf) Type Collapse Burst 13.375" 68 L-80 3 H563 2260 psi 1921 psi 5020 psi 4267 psi 7.625" j 29.7 j L80 j 3 j Hyd563 j 4790 psi I 4071 psi j 6890 psi j 5856 psi MT7-06 Page 8 of 11 Printed: 29-Jul-21 14. Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 16" Hole 13.375" Casina Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low First well on Pad, traveling cylinder diagrams Gas Hydrates Low If observed — control drill, reduce pump rates and circulating time, reduce mud temperatures Clay Balling Medium Maintain planned mud parameters and flow rates, Increase mud weight, use weighted sweeps, reduce fluid viscosity, control ROP Abnormal Pressure in Low Diverter drills, increased mud weight. Shallow Surface Formations hazard study noted minimal risk Lost Circulation Medium Reduce pump rates, mud rheology, add lost circulation material, use of low density cement slurries, port collar, control pipe running seeds 9-7/8 x 11" Hole /7.625" Liner - Casing Interval Event Risk Level Mitigation Strategy Sloughing shale, Tight High MPD for shale stability, Steerable Drilling Liner, hole Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring,Liner will be in place at TD Abnormal Reservoir Low Well control drills, check for flow during Pressure connections, increase mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Sloughing shale, Tight Medium MPD for shale stability, Steerable Drilling Liner, hole Increase mud weight, control ROP, connection and trip speeds, sweeps, and real time equivalent circulating density (ECD) monitoring, run casing as liner 6.5" Hole / 4.5" Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Medium Reduce trip speeds, condition mud properties, proper hole filling, um out of hole, real time ECD MT7-06 Page 9 of 11 Printed: 29-Jul-21 monitoring Abnormal Reservoir Low Well control drills, check for flow during Pressure connections, increased mud weight Differential Sticking Low Uniform reservoir pressure along lateral, keep pipe moving, control mud weight Hydrogen Sulfide gas Low HzS drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: MT7 will be a multi -well pad, containing an original plan of 36 wells. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely, the rig will be prepared to weight up if required. Weak sand stringers could be present in the overburden. LCM material will be available to seal in losses in the intermediate section. Lower Shale Stability: HRZ/Kalubik/Miluveach will require higher mud weights than historically used to enhance wellbore stability. Managed Pressure Drilling will be used in conjunction with a 4-string casing design if needed, to mitigate shale instability in the aforementioned formations. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. MT7-06 Page 10 of 11 Printed: 29-Jul-21 15. vroposea c:ompietlon Scnematic MT7-01wp08 - 3 String Producer, Proposed Schematic (updated 07.28.21) 20" 94 ppf H-40 Insulated Conductor 80 feet, cemented to surface 13-3/8" 68# L-80 Hyd563 Surface Casing set @ 3,484' MD / 3093' TVD 4-1/2" 12.6# L-80 Hyd563 Tubing / Liner Completion 1) 4 %" Landing Nipple (3.813" ID) 2) 4 %" x 1" GLM (2-3x) 3) HES Downhole Gauge 4) Production Packer 5) 4-'/2" Landing Nipple (3.75" ID) 6) Liner Top Packer / Hanger w/ Tie Back sleeve Top of 7-5/8" 29.7# L-80 H563 Casing to --8,500' MD, —2365' of 33.7# L-80 TXP BTC-SR G� Downhole Gauge OHG Production Packer@ 10,665' MD / 8,395' TVD TOC @ 10,250' MD / ZXP Liner Top Packer 8,060' TVD @ 10,715' MD Top Alpine C 10,906' MD / 8,322' TVD 4-1/2" 12.6# L-80 Hyd563 Liner w/ 4 swell packers and 4 closeable frac ports followed by pert joints to 23,842' MD 7-5/8" 29.7# HYD563 / 33.7# L-80 TXP BTC-SR Intermediate Casing @ 10,865' MD / 8,310' TVD Production Hole TD 23,842' MD / 8,251' TVD 07/28/21 NA MT7-06 Page 11 of 11 Printed: 29-Jul-21 MT7-01 -_wp08 DDI plan Surnma 7.139 N 3 fn 0 00 Intermediate Csg Surface Csg 3000 6000 9000 12000 15000 18000 21000 24000 Measured Depth -■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■■ �!= ■■■■■■■■I,■■■■■■■■■■■■r--------- 7■■■■■■ I■■■■■■■mum ■■■■1 ?!■■■■■■ ■■■■►AME ■■■■Y ii■■MEMO MENNEN . ■■ - - • - • ■■■■■■■■■■■■■■■■■■■■■■ -2000 0 2000 4000 6000 8000 10000 Vertical Section at 333.00' 0 1000 2000 3000 4000 5000 6000 7000 Measured Depth Date: 2017-03-21T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 39.50 1300.00 MT7-01-_wp08 (MT7-01) GYD-GC-SS 1300.00 2300.00 MT7-01 =wp08 (MT7-01) MWD OWSG 2300.00 3485.00 MT7-01 =wp08 (MT7-01) MWD+IFR2+SAG+MS 3485.00 3985.00 MT7-01 =wp08 (MT7-01) MWD-INC-ONLY (INC>10') 3985.00 5985.00 MT7-01 =wp08 (MT7-01) MWD OWSG 5985.00 10865.00 MT7-01 =wp08 (MT7-01) MWD+IFR2+SAG+MS 10865.00 11865.00 MT7-01-_wp08 (MT7-01) MWD-INC ONLY (INC>10°) 11865.00 13365.00 MT7-01- wp08 (MT7-01) MWD OWSG 13365.00 23842.79 MT7-01-_wp08 (MT7-01) MWD+IFR2+SAG+MS Surface Location North / 5915580.08 East / 1430061.84 Ground / 100.00 7 `•. \ .. .........:.. \ f% \ \ MT7-06_wp0 MT7-02 wp 0 .................................................................. MT7-99 wp0 40 700 MT7-0 330 -' 30 GMT2-205 wp 1 700 890 890 1070 _ 9 1070 1260 $00 -- 1260 1440 1440 1630 . . 995. ..' 7r1� y, 60 1630 - 1810 0 810 - 2000 97�" - 0 .- 2000 - 2930 8 2930 3850 3850 - 4780 270 1 Q 40 90 4780 5700 - 5700 - 6630 • 40_-..-' _ 6630 - 7550 5 6' 94 7550 8480 - 8480 - 9400 - l 9400 - 11240 240 120 11240 - 13080 -- - 13080 - 14910 " .. 90 MT7-96 Wp0 14910 16750 16750 - 18590 MT7-0 210 ...._. ._.-'•-" 150 18590 20430 ' MT7-0 180 20430 22270 - 22270 - 24103 TVD MD Name 3093.00 3484.57 Surface Csg 8310.48 10865.33 Intermediate Csg Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 700.00 0.00 199.11 700.00 0.00 0.00 0.00 199.11 0.00 31000.00 4.50 199.11 999.69 -11.13 -3.85 1.50-160.89 -8.16 41300.00 10.50 1 99. 111296.99 -48.11 -16.67 2.00 0.00 -35.30 5 2586.00 42.65 199.11 2432.09-584.62-202.56 2.50 0.00-428.94 67767.41 42.65 199.11 6243.05-3901.66-1351.83 0.00 0.00-2862.68 710865.33 73.00 313.50 8310.48-3865.26-3193.20 3.00 119.20-1994.29 80885.33 73.00 313.50 8316.33-3852.10-3207.08 0.00 0.00-1976.26 91621.23 89.61 329.31 8427.87-3286.02-3656.06 3.09 44.741268.05 101842.65 89.61 329.31 8429.37-3095.63-3769.09 0.00 0.00-1047.09 MT7-01_Landing_07162021 1111999.55 90.86 333.02 8428.73-2958.21-3844.74 2.50 71.47-890.31 1923842.79 90.86 333.02 8251.35 7595.30-9216.37 0.00 0.000951.60 MT7-01 TD 102720 MS Mag Model & Date: BGGM2020 15-Aug-21 Magnetic North is 14.78' East of True North (Magnetic Mag Dip & Field Strength: 80.40° 57150.73nT FORMATION TOP DETAILS I TVDPathFormation Annotation 949.519ase of Permafrost 1407.28 C40 Start Build 1.50 1662.79 C30 2012.59 C10 3042.62 K3 3649.07 Albian 97 3881.35 Albian 96 4061.42 Albian 95 4703.42 Albian 94 5040.72 Albian 93 6328.22 Albian 92 7407.52 H RZ 7652.52 LCU 8322.38 Alpine C/TPI By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.) approve it as the basiis the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared b Checked by ccepted b r roved b Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 (GMT2 SW01-107) Wellbore: MT7-01 Design: MT7-01- w 08 Section View 0 U00 300 3000 :3 Surface Csg 0 CD o0 � b ;z o S000 NC U CO 3 O '1000 � 6000 400 I� v a Intermediate Csg g000 MT7-01 Landing 07162021 00 O O ' MT7-01 TD 102720 MS � o O O O A W -3000 0 3000 6000 9000 Vertical Section at 333.00' (1500 usft/in) Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 (GMT2 SW01-107) Wellbore: MT7-01 Design: MT7-01-_w 08 Plan View 'x 1o�l�M s�o1, M�� 01 lG 4000 c y 0 0 0 O Z s O V) 0 000 /406 .................. Surface Csg 4000 Intermediate Csg o� 15000 6n,, -4000--p 00 -12000 -8000 -4000 0 4000 West( -)/East(+) (2000 usft/in) ConocoPhillips Alaska Inc WNS Western North Slope GMT2 Rendezvous Pad MT7-01 (GMT2 SW01-107) 50103xxxxx00 MT7-01 Plan: MT7-01-_wp08 Standard Proposal Report 22 July, 2021 ConocoPh i I I i ps ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 (GMT2 SW01-107) Wellbore: MT7-01 Design: MT7-01-_wp08 Local Co-ordinate Reference: Well MT7-01 (GMT2 SW01-107) TVD Reference: 139.5 @ 139.50usft MD Reference: 139.5 @ 139.50usft North Reference: True Survey Calculation Method: Minimum Curvature Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site GMT2 Rendezvous Pad Site Position: Northing: 5,915,580.00 usft Latitude: 70° 10' 22.674 N From: Map Easting: 1,430,062.00 usft Longitude: 151' 41' 36.331 W Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: -1.59 ° Well MT7-01 (GMT2 SW01-107) Well Position +NI-S 0.08 usft Northing: 5,915,580.08 usft Latitude: 70' 10' 22.675 N +E/-W -0.16 usft Easting: 1,430,061.84 usft Longitude: 151' 41' 36.336 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 100.00 usft Wellbore MT7-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (1) (1 (nT) BGGM2020 8/15/2021 14.78 80.40 57,150.73 BGGM2020 8/14/2021 14.78 80.40 57,150.85 Design MT7-01-_wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From (TVD) +NI-S +E/-W Direction i (usft) (usft) (usft) (1) 39.50 0.00 0.00 333.00 7/22/2021 2:07:26PM Page 2 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 (GMT2 SW01-107) Wellbore: MT7-01 Design: MT7-01-_wp08 Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Plan Survey Tool Program Date 7/22/2021 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.50 1,300.00 MT7-01-_wp08 (MT7-01) GYD-GC-SS Gyrodata gyro single shots 2 1,300.00 2,300.00 MT7-01-_wp08 (MT7-01) MWD OWSG OWSG MWD - Standard 3 2,300.00 3,485.00 MT7-01-_wp08 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + I\ 4 3,485.00 3,985.00 MT7-01-_wp08 (MT7-01) MWD-INC_ONLY (INC>10°) MWD-INC-ONLY-FILLER (INS 5 3,985.00 5,985.00 MT7-01-_wp08 (MT7-01) MWD OWSG OWSG MWD - Standard 6 5,985.00 10,865.00 MT7-01-_wp08 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + 11 7 10,865.00 11,865.00 MT7-01-_wp08 (MT7-01) MWD-INC_ONLY (INC>10°) MWD-INC-ONLY-FILLER (IN, 8 11,865.00 13,365.00 MT7-01-_wp08 (MT7-01) MWD OWSG OWSG MWD - Standard 9 13,365.00 23,842.79 MT7-01-_wp08 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + A Well MT7-01 (GMT2 SW01-107) 139.5 @ 139.50usft 139.5 @ 139.50usft True Minimum Curvature Plan Sections Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) (°) Target 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 0.00 700.00 0.00 199.11 700.00 0.00 0.00 0.00 0.00 0.00 199.11 1,000.00 4.50 199.11 999.69 -11.13 -3.85 1.50 1.50 0.00 -160.89 1,300.00 10.50 199.11 1,296.99 -48.11 -16.67 2.00 2.00 0.00 0.00 2,586.00 42.65 199.11 2,432.09 -584.62 -202.56 2.50 2.50 0.00 0.00 7,767.41 42.65 199.11 6,243.05 -3,901.66 -1,351.83 0.00 0.00 0.00 0.00 10,865.33 73.00 313.50 8,310.48 -3,865.26 -3,193.20 3.00 0.98 3.69 119.29 10,885.33 73.00 313.50 8,316.33 -3,852.10 -3,207.08 0.00 0.00 0.00 0.00 11,621.23 89.61 329.31 8,427.87 -3,286.02 -3,656.06 3.09 2.26 2.15 44.74 11,842.65 89.61 329.31 8,429.37 -3,095.63 -3,769.09 0.00 0.00 0.00 0.00 MT7-01-Land ing_071 11,999.55 90.86 333.02 8,428.73 -2,958.21 -3,844.74 2.50 0.79 2.37 71.47 23,842.79 90.86 333.02 8,251.35 7,595.30 -9,216.37 0.00 0.00 0.00 0.00 MT7-01 TD 102720 N 712212021 2:07:26PM Page 3 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 (GMT2 SW01-107) Company: ConocoPhillips Alaska Inc_WNS TVD Reference: 139.5 @ 139.50usft Project: Western North Slope MD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 (GMT2 SW01-107) Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01-_wp08 Planned Survey ■ Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) (1) V) (usft) ' (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 39.50 0.00 0.00 39.50 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 0.00 0.00 400.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 0.00 0.00 700.00 0.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 800.00 1.50 199.11 799.99 -1.24 -0.43 -0.91 1.50 1.50 0.00 Start Build 2.00 900.00 3.00 199.11 899.91 -4.95 -1.71 -3.63 1.50 1.50 0.00 949.68 3.75 199.11 949.50 -7.71 -2.67 -5.66 1.50 1.50 0.00 Base of Permafrost 1,000.00 4.50 199.11 999.69 -11.13 -3.85 -8.16 1.50 1.50 0.00 1,100.00 6.50 199.11 1,099.23 -20.18 -6.99 -14.81 2.00 2.00 0.00 Start DLS 2.50 TFO 37.83 1,200.00 8.50 199.11 1,198.37 -32.51 -11.27 -23.86 2.00 2.00 0.00 1,300.00 10.50 199.11 1,296.99 -48.11 -16.67 -35.30 2.00 2.00 0.00 1,400.00 13.00 199.11 1,394.89 -67.35 -23.34 -49.41 2.50 2.50 0.00 1,412.73 13.32 199.11 1,407.28 -70.09 -24.28 -51.42 2.50 2.50 0.00 C40 1,500.00 15.50 199.11 1,491.80 -90.61 -31.39 -66.48 2.50 2.50 0.00 1,600.00 18.00 199.11 1,587.55 -117.84 -40.83 -86.46 2.50 2.50 0.00 1,679.58 19.99 199.11 1,662.79 -142.31 -49.31 -104.41 2.50 2.50 0.00 C30 1,700.00 20.50 199.11 1,681.95 -148.99 -51.62 -109.31 2.50 2.50 0.00 1,800.00 23.00 199.11 1,774.83 -184.00 -63.75 -135.00 2.50 2.50 0.00 1,900.00 25.50 199.11 1,865.99 -222.80 -77.20 -163.47 2.50 2.50 0.00 2,000.00 28.00 199.11 1,955.29 -265.33 -91.93 -194.67 2.50 2.50 0.00 2,065.41 29.64 199.11 2,012.59 -295.12 -102.25 -216.53 2.50 2.50 0.00 C10 2,100.00 30.50 199.11 2,042.53 -311.49 -107.93 -228.55 2.50 2.50 0.00 2,200.00 33.00 199.11 2,127.56 -361.21 -125.15 -265.02 2.50 2.50 0.00 2,300.00 35.50 199.11 2,210.21 -414.39 -143.57 -304.04 2.50 2.50 0.00 2,400.00 38.00 199.11 2,290.33 -470.92 -163.16 -345.52 2.50 2.50 0.00 2,500.00 40.50 199.11 2,367.76 -530.70 -183.87 -389.38 2.50 2.50 0.00 2,586.00 42.65 199.11 2,432.09 -584.62 -202.56 -428.94 2.50 2.50 0.00 2,591.71 42.65 199.11 2,436.29 -588.27 -203.82 -431.62 0.00 0.00 0.00 Start 5196.97 hold at 2591.71 MD 2,600.00 42.65 199.11 2,442.39 -593.58 -205.66 -435.52 0.00 0.00 0.00 2,700.00 42.65 199.11 2,515.94 -657.60 -227.84 -482.49 0.00 0.00 0.00 2,800.00 42.65 199.11 2,589.49 -721.62 -250.02 -529.46 0.00 0.00 0.00 2,900.00 42.65 199.11 2,663.04 -785.63 -272.20 -576.43 0.00 0.00 0.00 3,000.00 42.65 199.11 2,736.59 -849.65 -294.38 -623.40 0.00 0.00 0.00 3,100.00 42.65 199.11 2,810.14 -913.67 -316.57 -670.37 0.00 0.00 0.00 3,200.00 42.65 199.11 2,883.69 -977.69 -338.75 -717.34 0.00 0.00 0.00 3,300.00 42.65 199.11 2,957.24 -1,041.71 -360.93 -764.31 0.00 0.00 0.00 3,400.00 42.65 199.11 3,030.80 -1,105.72 -383.11 -811.28 0.00 0.00 0.00 3,416.08 42.65 199.11 3,042.62 -1,116.02 -386.67 -818.83 0.00 0.00 0.00 K3 3,484.57 42.65 199.11 3,093.00 -1,159.87 -401.87 -851.01 0.00 0.00 0.00 Surface Csg 7/22/2021 2:07:26PM Page 4 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 (GMT2 SW01-107) Wellbore: MT7-01 Design: MT7-01-_wp08 Local Co-ordinate Reference: Well MT7-01 (GMT2 SW01-107) TVD Reference: 139.5 @ 139.50usft MD Reference: 139.5 @ 139.50usft North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) V) V) (usft) ' (usft) ' (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 3,500.00 42.65 199.11 3,104.35 -1,169.74 -405.29 -858.25 0.00 0.00 0.00 3,600.00 42.65 199.11 3,177.90 -1,233.76 -427.47 -905.22 0.00 0.00 0.00 3,700.00 42.65 199.11 3,251.45 -1,297.78 -449.65 -952.19 0.00 0.00 0.00 3,800.00 42.65 199.11 3,325.00 -1,361.80 -471.83 -999.16 0.00 0.00 0.00 3,900.00 42.65 199.11 3,398.55 -1,425.82 -494.01 -1,046.13 0.00 0.00 0.00 4,000.00 42.65 199.11 3,472.10 -1,489.83 -516.19 -1,093.10 0.00 0.00 0.00 4,100.00 42.65 199.11 3,545.65 -1, 553.85 -538.37 -1,140.08 0.00 0.00 0.00 4,200.00 42.65 199.11 3,619.20 -1,617.87 -560.55 -1,187.05 0.00 0.00 0.00 4,240.61 42.65 199.11 3,649.07 -1,643.87 -569.56 -1,206.12 0.00 0.00 0.00 Albian 97 4,300.00 42.65 199.11 3,692.75 -1,681.89 -582.73 -1,234.02 0.00 0.00 0.00 4,400.00 42.65 199.11 3,766.30 -1,745.91 -604.92 -1,280.99 0.00 0.00 0.00 4,500.00 42.65 199.11 3,839.85 -1,809.92 -627.10 -1,327.96 0.00 0.00 0.00 4,556.42 42.65 199.11 3,881.35 -1,846.04 -639.61 -1,354.46 0.00 0.00 0.00 Albian 96 4,600.00 42.65 199.11 3,913.40 -1,873.94 -649.28 -1,374.93 0.00 0.00 0.00 4,700.00 42.65 199.11 3,986.95 -1,937.96 -671.46 -1,421.90 0.00 0.00 0.00 4,800.00 42.65 199.11 4,060.50 -2,001.98 -693.64 -1,468.87 0.00 0.00 0.00 4,801.25 42.65 199.11 4,061.42 -2,002.78 -693.91 -1,469.46 0.00 0.00 0.00 Albian 95 4,900.00 42.65 199.11 4,134.05 -2,066.00 -715.82 -1,515.84 0.00 0.00 0.00 5,000.00 42.65 199.11 4,207.61 -2,130.01 -738.00 -1,562.81 0.00 0.00 0.00 5,100.00 42.65 199.11 4,281.16 -2,194.03 -760.18 -1,609.78 0.00 0.00 0.00 5,200.00 42.65 199.11 4,354.71 -2,258.05 -782.36 -1,656.75 0.00 0.00 0.00 5,300.00 42.65 199.11 4,428.26 -2,322.07 -804.54 -1,703.72 0.00 0.00 0.00 5,400.00 42.65 199.11 4,501.81 -2,386.09 -826.72 -1,750.69 0.00 0.00 0.00 5,500.00 42.65 199.11 4,575.36 -2,450.11 -848.90 -1,797.67 0.00 0.00 0.00 5,600.00 42.65 199.11 4,648.91 -2,514.12 -871.08 -1,844.64 0.00 0.00 0.00 5,674.11 42.65 199.11 4,703.42 -2,561.57 -887.52 -1,879.45 0.00 0.00 0.00 Albian 94 5,700.00 42.65 199.11 4,722.46 -2,578.14 -893.27 -1,891.61 0.00 0.00 0.00 5,800.00 42.65 199.11 4,796.01 -2,642.16 -915.45 -1,938.58 0.00 0.00 0.00 5,900.00 42.65 199.11 4,869.56 -2,706.18 -937.63 -1,985.55 0.00 0.00 0.00 6,000.00 42.65 199.11 4,943.11 -2,770.20 -959.81 -2,032.52 0.00 0.00 0.00 6,100.00 42.65 199.11 5,016.66 -2,834.21 -981.99 -2,079.49 0.00 0.00 0.00 6,132.71 42.65 199.11 5,040.72 -2,855.15 -989.24 -2,094.85 0.00 0.00 0.00 Albian 93 6,200.00 42.65 199.11 5,090.21 -2,898.23 -1,004.17 -2,126.46 0.00 0.00 0.00 6,300.00 42.65 199.11 5,163.76 -2,962.25 -1,026.35 -2,173.43 0.00 0.00 0.00 6,400.00 42.65 199.11 5,237.31 -3,026.27 -1,048.53 -2,220.40 0.00 0.00 0.00 6,500.00 42.65 199.11 5,310.86 -3,090.29 -1,070.71 -2,267.37 0.00 0.00 0.00 6,600.00 42.65 199.11 5,384.41 -3,154.30 -1,092.89 -2,314.34 0.00 0.00 0.00 6,700.00 42.65 199.11 5,457.97 -3,218.32 -1,115.07 -2,361.31 0.00 0.00 0.00 6,800.00 42.65 199.11 5,531.52 -3,282.34 -1,137.25 -2,408.28 0.00 0.00 0.00 6,900.00 42.65 199.11 5,605.07 -3,346.36 -1,159.43 -2,455.26 0.00 0.00 0.00 7,000.00 42.65 199.11 5,678.62 -3,410.38 -1,181.62 -2,502.23 0.00 0.00 0.00 7,100.00 42.65 199.11 5,752.17 -3,474.40 -1,203.80 -2,549.20 0.00 0.00 0.00 7,200.00 42.65 199.11 5,825.72 -3,538.41 -1,225.98 -2,596.17 0.00 0.00 0.00 7,300.00 42.65 199.11 5,899.27 -3,602.43 -1,248.16 -2,643.14 0.00 0.00 0.00 7,400.00 42.65 199.11 5,972.82 -3,666.45 -1,270.34 -2,690.11 0.00 0.00 0.00 7,500.00 42.65 199.11 6,046.37 -3,730.47 -1,292.52 -2,737.08 0.00 0.00 0.00 7,600.00 42.65 199.11 6,119.92 -3,794.49 -1,314.70 -2,784.05 0.00 0.00 0.00 7,700.00 42.65 199.11 6,193.47 -3,858.50 -1,336.88 -2,831.02 0.00 0.00 0.00 7/22/2021 2:07:26PM Page 5 COMPASS 5000.15 Build 91E ConocoPhillips Database: EDT 15 Alaska Prod Company: ConocoPhillips Alaska Inc_WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 (GMT2 SW01-107) Wellbore: MT7-01 Design: MT7-01-_wp08 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ConocoPhillips Standard Proposal Report Well MT7-01 (GMT2 SW01-107) 139.5 @ 139.50usft 139.5 @ 139.50usft 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) (°/100usft) (°/100usft) (°/100usft) 7,767.41 42.65 199.11 6,243.05 -3,901.66 -1,351.83 -2,862.68 0.00 0.00 0.00 7,788.68 42.34 199.94 6,258.73 -3,915.20 -1,356.63 -2,872.57 3.00 -1.45 3.89 Start DLS 3.00 TFO 120.43 7,800.00 42.18 200.38 6,267.11 -3,922.35 -1,359.26 -2,877.75 3.00 -1.43 3.92 7,881.73 41.06 203.67 6,328.22 -3,972.66 -1,379.59 -2,913.34 3.00 -1.37 4.02 Albian 92 7,900.00 40.82 204.42 6,342.02 -3,983.59 -1,384.47 -2,920.87 3.00 -1.30 4.13 8,000.00 39.61 208.68 6,418.39 -4,041.34 -1,413.29 -2,959.23 3.00 -1.21 4.26 8,100.00 38.57 213.15 6,496.02 -4,095.42 -1,445.65 -2,992.73 3.00 -1.04 4.47 8,200.00 37.70 217.80 6,574.69 -4,145.69 -1,481.45 -3,021.27 3.00 -0.87 4.66 8,300.00 37.03 222.62 6,654.18 -4,192.02 -1,520.59 -3,044.78 3.00 -0.68 4.82 8,400.00 36.55 227.57 6,734.29 -4,234.27 -1,562.97 -3,063.19 3.00 -0.48 4.95 8,500.00 36.28 232.61 6,814.78 -4,272.33 -1,608.47 -3,076.45 3.00 -0.27 5.04 8,600.00 36.23 237.69 6,895.43 -4,306.10 -1,656.96 -3,084.52 3.00 -0.05 5.08 8,700.00 36.39 242.75 6,976.04 -4,335.48 -1,708.32 -3,087.38 3.00 0.16 5.06 8,800.00 36.76 247.76 7,056.37 -4,360.39 -1,762.40 -3,085.03 3.00 0.37 5.00 8,900.00 37.34 252.65 7,136.20 -4,380.77 -1,819.05 -3,077.46 3.00 0.58 4.89 9,000.00 38.11 257.39 7,215.31 -4,396.55 -1,878.12 -3,064.71 3.00 0.77 4.74 9,100.00 39.06 261.96 7,293.49 -4,407.70 -1,939.45 -3,046.80 3.00 0.96 4.56 9,200.00 40.19 266.32 7,370.53 -4,414.18 -2,002.86 -3,023.78 3.00 1.13 4.36 9,248.64 40.79 268.37 7,407.52 -4,415.64 -2,034.41 -3,010.77 3.00 1.24 4.21 HRZ 9,300.00 41.47 270.47 7,446.21 -4,415.98 -2,068.19 -2,995.73 3.00 1.32 4.10 9,400.00 42.90 274.41 7,520.32 -4,413.09 -2,135.25 -2,962.71 3.00 1.42 3.94 9,500.00 44.45 278.13 7,592.66 -4,405.52 -2,203.86 -2,924.81 3.00 1.55 3.72 9,584.87 45.85 281.13 7,652.52 -4,395.43 -2,263.16 -2,888.91 3.00 1.66 3.53 LCU 9,600.00 46.11 281.65 7,663.03 -4,393.28 -2,273.83 -2,882.15 3.00 1.71 3.43 9,700.00 47.88 284.97 7,731.24 -4,376.43 -2,344.97 -2,834.83 3.00 1.77 3.32 9,800.00 49.74 288.10 7,797.10 -4,354.99 -2,417.08 -2,782.99 3.00 1.86 3.13 9,900.00 51.68 291.07 7,860.43 -4,329.03 -2,489.97 -2,726.77 3.00 1.94 2.96 10,000.00 53.69 293.87 7,921.06 -4,298.61 -2,563.43 -2,666.32 3.00 2.01 2.81 10,100.00 55.76 296.53 7,978.82 -4,263.84 -2,637.27 -2,601.81 3.00 2.07 2.66 10,200.00 57.88 299.07 8,033.55 -4,224.79 -2,711.28 -2,533.42 3.00 2.13 2.53 10,300.00 60.06 301.49 8,085.10 -4,181.57 -2,785.26 -2,461.33 3.00 2.17 2.42 10,400.00 62.27 303.80 8,133.33 -4,134.32 -2,859.01 -2,385.74 3.00 2.22 2.31 10,500.00 64.53 306.02 8,178.11 -4,083.14 -2,932.31 -2,306.86 3.00 2.25 2.22 10,600.00 66.81 308.15 8,219.31 -4,028.19 -3,004.98 -2,224.91 3.00 2.29 2.14 10,700.00 69.12 310.22 8,256.82 -3,969.62 -3,076.81 -2,140.11 3.00 2.31 2.07 10,800.00 71.46 312.22 8,290.54 -3,907.58 -3,147.61 -2,052.69 3.00 2.34 2.00 10,865.33 73.00 313.50 8,310.48 -3,865.26 -3,193.21 -1,994.29 3.00 2.35 1.96 Intermediate Csg 10,885.33 73.00 313.50 8,316.33 -3,852.10 -3,207.08 -1,976.26 0.00 0.00 0.00 10,900.00 73.32 313.83 8,320.58 -3,842.40 -3,217.24 -1,963.01 3.09 2.20 2.27 10,906.30 73.46 313.98 8,322.38 -3,838.21 -3,221.59 -1,957.30 3.09 2.20 2.27 Alpine C/TPI 11,000.00 75.54 316.08 8,347.42 -3,774.34 -3,285.39 -1,871.43 3.09 2.21 2.24 11,100.00 77.77 318.28 8,370.51 -3,702.98 -3,351.51 -1,777.82 3.09 2.23 2.20 11,200.00 80.02 320.44 8,389.77 -3,628.52 -3,415.41 -1,682.48 3.09 2.25 2.16 11,300.00 82.28 322.57 8,405.16 -3,551.19 -3,476.90 -1,585.66 3.09 2.26 2.13 11,400.00 84.56 324.68 8,416.62 -3,471.21 -3,535.80 -1,487.65 3.09 2.27 2.11 11,435.38 85.36 325.43 8,419.72 -3,442.32 -3,555.98 -1,452.75 3.09 2.28 2.10 Start 200.00 hold at 11435.38 MD 7/22/2021 2:07:26PM Page 6 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 (GMT2 SW01-107) Company: ConocoPhillips Alaska Inc_WNS TVD Reference: 139.5 @ 139.50usft Project: Western North Slope MD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 (GMT2 SW01-107) Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01-_wp08 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) ' n V) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 11,500.00 86.84 326.78 8,424.12 -3,388.81 -3,591.94 -1,388.75 3.09 2.28 2.09 11,600.00 89.13 328.86 8,427.64 -3,304.24 -3,645.15 -1,289.23 3.09 2.29 2.09 11,621.23 89.61 329.31 8,427.87 -3,286.02 -3,656.06 -1,268.05 3.09 2.29 2.08 11,635.38 89.61 329.31 8,427.97 -3,273.85 -3,663.28 -1,253.93 0.00 0.00 0.00 Start 20.00 hold at 11636.38 MD 11,655.38 89.61 329.31 8,428.10 -3,256.66 -3,673.49 -1,233.97 0.00 0.00 0.00 Start DLS 2.50 TFO 69.86 11,700.00 89.61 329.31 8,428.40 -3,218.29 -3,696.27 -1,189.45 0.00 0.00 0.00 11,800.00 89.61 329.31 8,429.08 -3,132.30 -3,747.31 -1,089.66 0.00 0.00 0.00 11,842.65 89.61 329.31 8,429.37 -3,095.63 -3,769.09 -1,047.09 0.00 0.00 0.00 11,900.00 90.07 330.66 8,429.53 -3,045.97 -3,797.77 -989.83 2.50 0.79 2.37 11,999.55 90.86 333.02 8,428.73 -2,958.21 -3,844.74 -890.31 2.50 0.79 2.37 12,100.00 90.86 333.02 8,427.22 -2,868.70 -3,890.30 -789.87 0.00 0.00 0.00 12,118.68 90.86 333.02 8,426.94 -2,852.05 -3,898.78 -771.19 0.00 0.00 0.00 Start 11986.87 hold at 12118.68 MD 12,200.00 90.86 333.02 8,425.72 -2,779.59 -3,935.66 -689.88 0.00 0.00 0.00 12,300.00 90.86 333.02 8,424.23 -2,690.48 -3,981.01 -589.89 0.00 0.00 0.00 12,400.00 90.86 333.02 8,422.73 -2,601.37 -4,026.37 -489.90 0.00 0.00 0.00 12,500.00 90.86 333.02 8,421.23 -2,512.26 -4,071.73 -389.92 0.00 0.00 0.00 12,600.00 90.86 333.02 8,419.73 -2,423.15 4,117.08 -289.93 0.00 0.00 0.00 12,700.00 90.86 333.02 8,418.23 -2,334.04 -4,162.44 -189.94 0.00 0.00 0.00 12,800.00 90.86 333.02 8,416.74 -2,244.93 -4,207.79 -89.95 0.00 0.00 0.00 12,900.00 90.86 333.02 8,415.24 -2,155.82 -4,253.15 10.04 0.00 0.00 0.00 13,000.00 90.86 333.02 8,413.74 -2,066.71 -4,298.51 110.03 0.00 0.00 0.00 13,100.00 90.86 333.02 8,412.24 -1,977.60 -4,343.86 210.02 0.00 0.00 0.00 13,200.00 90.86 333.02 8,410.75 -1,888.49 -4,389.22 310.01 0.00 0.00 0.00 13,300.00 90.86 333.02 8,409.25 -1,799.38 -4,434.57 409.99 0.00 0.00 0.00 13,400.00 90.86 333.02 8,407.75 -1,710.27 -4,479.93 509.98 0.00 0.00 0.00 13,500.00 90.86 333.02 8,406.25 -1,621.16 -4,525.29 609.97 0.00 0.00 0.00 13,600.00 90.86 333.02 8,404.76 -1,532.05 -4,570.64 709.96 0.00 0.00 0.00 13,700.00 90.86 333.02 8,403.26 -1,442.94 -4,616.00 809.95 0.00 0.00 0.00 13,800.00 90.86 333.02 8,401.76 -1,353.83 -4,661.36 909.94 0.00 0.00 0.00 13,900.00 90.86 333.02 8,400.26 -1,264.72 -4,706.71 1,009.93 0.00 0.00 0.00 14,000.00 90.86 333.02 8,398.76 -1,175.61 -4,752.07 1,109.92 0.00 0.00 0.00 14,100.00 90.86 333.02 8,397.27 -1,086.50 -4,797.42 1,209.91 0.00 0.00 0.00 14,200.00 90.86 333.02 8,395.77 -997.39 -4,842.78 1,309.89 0.00 0.00 0.00 14,300.00 90.86 333.02 8,394.27 -908.28 -4,888.14 1,409.88 0.00 0.00 0.00 14,400.00 90.86 333.02 8,392.77 -819.17 -4,933.49 1,509.87 0.00 0.00 0.00 14,500.00 90.86 333.02 8,391.28 -730.06 -4,978.85 1,609.86 0.00 0.00 0.00 14,600.00 90.86 333.02 8,389.78 -640.95 -5,024.20 1,709.85 0.00 0.00 0.00 14,700.00 90.86 333.02 8,388.28 -551.84 -5,069.56 1,809.84 0.00 0.00 0.00 14,800.00 90.86 333.02 8,386.78 -462.73 -5,114.92 1,909.83 0.00 0.00 0.00 14,900.00 90.86 333.02 8,385.29 -373.62 -5,160.27 2,009.82 0.00 0.00 0.00 15,000.00 90.86 333.02 8,383.79 -284.51 -5,205.63 2,109.80 0.00 0.00 0.00 15,100.00 90.86 333.02 8,382.29 -195.40 -5,250.98 2,209.79 0.00 0.00 0.00 15,200.00 90.86 333.02 8,380.79 -106.29 -5,296.34 2,309.78 0.00 0.00 0.00 15,300.00 90.86 333.02 8,379.29 -17.18 -5,341.70 2,409.77 0.00 0.00 0.00 15,400.00 90.86 333.02 8,377.80 71.93 -5,387.05 2,509.76 0.00 0.00 0.00 15,500.00 90.86 333.02 8,376.30 161.04 -5,432.41 2,609.75 0.00 0.00 0.00 15,600.00 90.86 333.02 8,374.80 250.15 -5,477.76 2,709.74 0.00 0.00 0.00 15,700.00 90.86 333.02 8,373.30 339.26 -5,523.12 2,809.73 0.00 0.00 0.00 15,800.00 90.86 333.02 8,371.81 428.37 -5,568.48 2,909.71 0.00 0.00 0.00 15,900.00 90.86 333.02 8,370.31 517.48 -5,613.83 3,009.70 0.00 0.00 0.00 7/22/2021 2:07:26PM Page 7 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 (GMT2 SW01-107) Company: ConocoPhillips Alaska Inc_WNS TVD Reference: 139.5 @ 139.50usft Project: Western North Slope MD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 (GMT2 SW01-107) Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01-_wp08 Planned Survey Measured Vertical Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Section Rate Rate Rate (usft) V) V) (usft) (usft) (usft) (usft) (°/100usft) (°/100usft) (°/100usft) 16,000.00 90.86 333.02 8,368.81 606.59 -5,659.19 3,109.69 0.00 0.00 0.00 16,100.00 90.86 333.02 8,367.31 695.70 -5,704.55 3,209.68 0.00 0.00 0.00 16,200.00 90.86 333.02 8,365.82 784.81 -5,749.90 3,309.67 0.00 0.00 0.00 16,300.00 90.86 333.02 8,364.32 873.92 -5,795.26 3,409.66 0.00 0.00 0.00 16,400.00 90.86 333.02 8,362.82 963.03 -5,840.61 3,509.65 0.00 0.00 0.00 16,500.00 90.86 333.02 8,361.32 1,052.14 -5,885.97 3,609.64 0.00 0.00 0.00 16,600.00 90.86 333.02 8,359.82 1,141.25 -5,931.33 3,709.62 0.00 0.00 0.00 16,700.00 90.86 333.02 8,358.33 1,230.36 -5,976.68 3,809.61 0.00 0.00 0.00 16,800.00 90.86 333.02 8,356.83 1,319.47 -6,022.04 3,909.60 0.00 0.00 0.00 16,900.00 90.86 333.02 8,355.33 1,408.58 -6,067.39 4,009.59 0.00 0.00 0.00 17,000.00 90.86 333.02 8,353.83 1,497.69 -6,112.75 4,109.58 0.00 0.00 0.00 17,100.00 90.86 333.02 8,352.34 1,586.80 -6,158.11 4,209.57 0.00 0.00 0.00 17,200.00 90.86 333.02 8,350.84 1,675.91 -6,203.46 4,309.56 0.00 0.00 0.00 17,300.00 90.86 333.02 8,349.34 1,765.02 -6,248.82 4,409.55 0.00 0.00 0.00 17,400.00 90.86 333.02 8,347.84 1,854.13 -6,294.17 4,509.53 0.00 0.00 0.00 17,500.00 90.86 333.02 8,346.35 1,943.24 -6,339.53 4,609.52 0.00 0.00 0.00 17,600.00 90.86 333.02 8,344.85 2,032.35 -6,384.89 4,709.51 0.00 0.00 0.00 17,700.00 90.86 333.02 8,343.35 2,121.46 -6,430.24 4,809.50 0.00 0.00 0.00 17,800.00 90.86 333.02 8,341.85 2,210.57 -6,475.60 4,909.49 0.00 0.00 0.00 17,900.00 90.86 333.02 8,340.35 2,299.68 -6,520.95 5,009.48 0.00 0.00 0.00 18,000.00 90.86 333.02 8,338.86 2,388.79 -6,566.31 5,109.47 0.00 0.00 0.00 18,100.00 90.86 333.02 8,337.36 2,477.90 -6,611.67 5,209.46 0.00 0.00 0.00 18,200.00 90.86 333.02 8,335.86 2,567.01 -6,657.02 5,309.44 0.00 0.00 0.00 18,300.00 90.86 333.02 8,334.36 2,656.12 -6,702.38 5,409.43 0.00 0.00 0.00 18,400.00 90.86 333.02 8,332.87 2,745.23 -6,747.73 5,509.42 0.00 0.00 0.00 18,500.00 90.86 333.02 8,331.37 2,834.34 -6,793.09 5,609.41 0.00 0.00 0.00 18,600.00 90.86 333.02 8,329.87 2,923.45 -6,838.45 5,709.40 0.00 0.00 0.00 18,700.00 90.86 333.02 8,328.37 3,012.56 -6,883.80 5,809.39 0.00 0.00 0.00 18,800.00 90.86 333.02 8,326.88 3,101.67 -6,929.16 5,909.38 0.00 0.00 0.00 18,900.00 90.86 333.02 8,325.38 3,190.78 -6,974.52 6,009.37 0.00 0.00 0.00 19,000.00 90.86 333.02 8,323.88 3,279.89 -7,019.87 6,109.36 0.00 0.00 0.00 19,100.00 90.86 333.02 8,322.38 3,369.00 -7,065.23 6,209.34 0.00 0.00 0.00 19,200.00 90.86 333.02 8,320.88 3,458.11 -7,110.58 6,309.33 0.00 0.00 0.00 19,300.00 90.86 333.02 8,319.39 3,547.22 -7,155.94 6,409.32 0.00 0.00 0.00 19,400.00 90.86 333.02 8,317.89 3,636.33 -7,201.30 6,509.31 0.00 0.00 0.00 19,500.00 90.86 333.02 8,316.39 3,725.44 -7,246.65 6,609.30 0.00 0.00 0.00 19,600.00 90.86 333.02 8,314.89 3,814.55 -7,292.01 6,709.29 0.00 0.00 0.00 19,700.00 90.86 333.02 8,313.40 3,903.66 -7,337.36 6,809.28 0.00 0.00 0.00 19,800.00 90.86 333.02 8,311.90 3,992.77 -7,382.72 6,909.27 0.00 0.00 0.00 19,900.00 90.86 333.02 8,310.40 4,081.88 -7,428.08 7,009.25 0.00 0.00 0.00 20,000.00 90.86 333.02 8,308.90 4,170.99 -7,473.43 7,109.24 0.00 0.00 0.00 20,100.00 90.86 333.02 8,307.41 4,260.10 -7,518.79 7,209.23 0.00 0.00 0.00 20,200.00 90.86 333.02 8,305.91 4,349.21 -7,564.14 7,309.22 0.00 0.00 0.00 20,300.00 90.86 333.02 8,304.41 4,438.32 -7,609.50 7,409.21 0.00 0.00 0.00 20,400.00 90.86 333.02 8,302.91 4,527.43 -7,654.86 7,509.20 0.00 0.00 0.00 20,500.00 90.86 333.02 8,301.41 4,616.54 -7,700.21 7,609.19 0.00 0.00 0.00 20,600.00 90.86 333.02 8,299.92 4,705.65 -7,745.57 7,709.18 0.00 0.00 0.00 20,700.00 90.86 333.02 8,298.42 4,794.76 -7,790.92 7,809.16 0.00 0.00 0.00 20,800.00 90.86 333.02 8,296.92 4,883.87 -7,836.28 7,909.15 0.00 0.00 0.00 20,900.00 90.86 333.02 8,295.42 4,972.98 -7,881.64 8,009.14 0.00 0.00 0.00 21,000.00 90.86 333.02 8,293.93 5,062.09 -7,926.99 8,109.13 0.00 0.00 0.00 21,100.00 90.86 333.02 8,292.43 5,151.20 -7,972.35 8,209.12 0.00 0.00 0.00 21,200.00 90.86 333.02 8,290.93 5,240.31 -8,017.71 8,309.11 0.00 0.00 0.00 21,300.00 90.86 333.02 8,289.43 5,329.42 -8,063.06 8,409.10 0.00 0.00 0.00 7/22/2021 2:07:26PM Page 8 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference: Well MT7-01 (GMT2 SW01-107) Company: ConocoPhillips Alaska Inc_WNS TVD Reference: 139.5 @ 139.50usft Project: Western North Slope MD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad North Reference: True Well: MT7-01 (GMT2 SW01-107) Survey Calculation Method: Minimum Curvature Wellbore: MT7-01 Design: MT7-01-_wp08 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) (°/100usft) (°/100usft) (°/100usft) 21,400.00 90.86 333.02 8,287.94 5,418.53 -8,108.42 8,509.09 0.00 0.00 0.00 21,500.00 90.86 333.02 8,286.44 5,507.64 -8,153.77 8,609.07 0.00 0.00 0.00 21,600.00 90.86 333.02 8,284.94 5,596.75 -8,199.13 8,709.06 0.00 0.00 0.00 21,700.00 90.86 333.02 8,283.44 5,685.86 -8,244.49 8,809.05 0.00 0.00 0.00 21,800.00 90.86 333.02 8,281.94 5,774.96 -8,289.84 8,909.04 0.00 0.00 0.00 21,900.00 90.86 333.02 8,280.45 5,864.07 -8,335.20 9,009.03 0.00 0.00 0.00 22,000.00 90.86 333.02 8,278.95 5,953.18 -8,380.55 9,109.02 0.00 0.00 0.00 22,100.00 90.86 333.02 8,277.45 6,042.29 -8,425.91 9,209.01 0.00 0.00 0.00 22,200.00 90.86 333.02 8,275.95 6,131.40 -8,471.27 9,309.00 0.00 0.00 0.00 22,300.00 90.86 333.02 8,274.46 6,220.51 -8,516.62 9,408.98 0.00 0.00 0.00 22,400.00 90.86 333.02 8,272.96 6,309.62 -8,561.98 9,508.97 0.00 0.00 0.00 22,500.00 90.86 333.02 8,271.46 6,398.73 -8,607.33 9,608.96 0.00 0.00 0.00 22,600.00 90.86 333.02 8,269.96 6,487.84 -8,652.69 9,708.95 0.00 0.00 0.00 22,700.00 90.86 333.02 8,268.47 6,576.95 -8,698.05 9,808.94 0.00 0.00 0.00 22,800.00 90.86 333.02 8,266.97 6,666.06 -8,743.40 9,908.93 0.00 0.00 0.00 22,900.00 90.86 333.02 8,265.47 6,755.17 -8,788.76 10,008.92 0.00 0.00 0.00 23,000.00 90.86 333.02 8,263.97 6,844.28 -8,834.11 10,108.91 0.00 0.00 0.00 23,100.00 90.86 333.02 8,262.47 6,933.39 -8,879.47 10,208.90 0.00 0.00 0.00 23,200.00 90.86 333.02 8,260.98 7,022.50 -8,924.83 10,308.88 0.00 0.00 0.00 23,300.00 90.86 333.02 8,259.48 7,111.61 -8,970.18 10,408.87 0.00 0.00 0.00 23,400.00 90.86 333.02 8,257.98 7,200.72 -9,015.54 10,508.86 0.00 0.00 0.00 23,500.00 90.86 333.02 8,256.48 7,289.83 -9,060.90 10,608.85 0.00 0.00 0.00 23,600.00 90.86 333.02 8,254.99 7,378.94 -9,106.25 10,708.84 0.00 0.00 0.00 23,700.00 90.86 333.02 8,253.49 7,468.05 -9,151.61 10,808.83 0.00 0.00 0.00 23,800.00 90.86 333.02 8,251.99 7,557.16 -9,196.96 10,908.82 0.00 0.00 0.00 23,842.79 90.86 333.02 8,251.35 7,595.30 -9,216.37 10,951.60 0.00 0.00 0.00 Design Targets Target Name hit/misstarget Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude MT7-01 TD 102720 MS 0.00 0.00 8,251.35 7,595.30 -9,216.37 5,923,428.28 1,421,060.64 70° 11' 37.322 N 151° 46' 3.649 W plan hits target center Circle (radius 100.00) MT7-01 Int Csg 102720 0.00 0.00 8,413.42 -3,491.79 -3,518.18 5,912,187.62 1,426,448.12 70° 9' 48.323 N 151° 43' 18.228 W plan misses target center by 2.39usft at 11372.79usft MD (8413.89 TVD,-3493.22 N, -3520.04 E) Circle (radius 100.00) MT7-01 Landing_07162 0.00 0.00 8,429.37 -3,095.63 -3,769.09 5,912,590.59 1,426,208.34 70° 9' 52.219 N 151° 43' 25.501 W plan hits target center Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) ■ (usft) Name (in) (in) 3,484.57 3,093.00 Surface Csg 13.375 16.000 10,865.33 8,310.48 Intermediate Csg 7.625 11.000 7/22/2021 2:07:26PM Page 9 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Standard Proposal Report Database: EDT 15 Alaska Prod Local Co-ordinate Reference Company: ConocoPhillips Alaska Inc_WNS TVD Reference: Project: Western North Slope MD Reference: Site: GMT2 Rendezvous Pad North Reference: Well: MT7-01 (GMT2 SW01-107) Survey Calculation Method: Wellbore: MT7-01 Design: MT7-01-_wp08 Formations Well MT7-01 (GMT2 SW01-107) 139.5 @ 139.50usft 139.5 @ 139.50usft True Minimum Curvature Measured Vertical Dip Depth Depth Dip Direction (usft) (usft) Name Lithology 949.68 949.50 Base of Permafrost Empty 1,412.73 1,407.28 C40 Empty 1,679.58 1,662.79 C30 Empty 2,065.41 2,012.59 C10 Empty 3,416.08 3,042.62 K3 Empty 4,240.61 3,649.07 Albian 97 Empty 4,556.42 3,881.35 Albian 96 Empty 4,801.25 4,061.42 Albian 95 Empty 5,674.11 4,703.42 Albian 94 Empty 6,132.71 5,040.72 Albian 93 Empty 7,881.73 6,328.22 Albian 92 Empty 9,248.64 7,407.52 HRZ Empty 9,584.87 7,652.52 LCU Empty 10,906.30 8,322.38 Alpine C/TPI Empty Plan Annotations Measured Depth (usft) 700.00 800.00 1,100.00 2,591.71 7,788.68 11,435.38 11,635.38 11, 655.38 12,118.68 24,105.56 Vertical Local Coordinates Depth +NI-S +E/-W (usft) (usft) (usft) Comment 700.00 0.00 0.00 Start Build 1.50 799.99 -1.24 -0.43 Start Build 2.00 1,099.23 -20.18 -6.99 Start DLS 2.50 TFO 37.83 2,436.29 -588.27 -203.82 Start 5196.97 hold at 2591.71 MD 6,258.73 -3,915.20 -1,356.63 Start DLS 3.00 TFO 120.43 8,419.72 -3,442.32 -3,555.98 Start 200.00 hold at 11435.38 MD 8,427.97 -3,273.85 -3,663.28 Start 20.00 hold at 11635.38 MD 8,428.10 -3,256.66 -3,673.49 Start DLS 2.50 TFO 59.86 8,426.94 -2,852.05 -3,898.78 Start 11986.87 hold at 12118.68 MD TD at 24105.55 7/22/2021 2:07:26PM Page 10 COMPASS 5000.15 Build 91E ConocoPhillips Alaska Inc WNS Western North Slope GMT2 Rendezvous Pad MT7-01 (GMT2 SW01-107) MT7-01 50103xxxxx00 MT7-01-_wp08 ConocoPhillips Clearance Summary Anticollision Report 22 July, 2021 Tray. Cylinder North Proximity Scan on Current Survey Data (Highside Reference) Reference Design: GMT2 Rendezvous Pad - MT7-01 (GMT2 SW01-107) - MT7-01 - MT7-01-_wp08 Well Coordinates: 5,915,580.08 N, 1,430,061.84 E (70° 10' 22.67" N, 151' 41' 36.34" W) Datum Height: 139.5 @ 139.50usft Scan Range: 0.00 to 23,842.79 usft. Measured Depth. Scan Radius is Unlimited . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft Geodetic Scale Factor Applied Version: 5000.15 Build: 91E Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: ConocoPhillips ConocoPh i I I i ps ConocoPhillips Alaska Inc WNS Western North Slope Anticollision Report for MT7-01 (GMT2 SW01-107) - MT7-01-_wp08 Tray. Cylinder North Proximity Scan on Current Survey Data (Highside Reference) Reference Design: GMT2 Rendezvous Pad - MT7-01 (GMT2 SW01-107) - MT7-01 - MT7-01-_wp08 Scan Range: 0.00 to 23,842.79 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factorcutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft 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 GMT2 Rendezvous Pad MT7-02 (GMT2 SW02-207) - MT7-02 - MT7-02 wp04 500.00 19.90 500.00 16.05 500.00 5.172 Centre Distance Pass - MT7-02 (GMT2 SW02-207) - MT7-02 - MT7-02 wp04 599.99 19.96 599.99 15.55 600.00 4.530 Ellipse Separation Pass - MT7-02 (GMT2 SW02-207) - MT7-02 - MT7-02 wp04 10,569.26 251.97 10,569.26 164.11 10,000.00 2.868 Clearance Factor Pass - MT7-03 (GMT2 SW03-108) - MT7-03 - MT7-03 2,525.95 34.83 2,525.95 23.29 2,500.00 3.019 Centre Distance Pass - MT7-03 (GMT2 SW03-108) - MT7-03 - MT7-03 2,626.50 35.80 2,626.50 21.50 2,600.00 2.504 Ellipse Separation Pass - MT7-03 (GMT2 SW03-108) - MT7-03 - MT7-03 2,726.00 41.78 2,726.00 22.85 2,700.00 2.207 Clearance Factor Pass - MT7-03 (GMT2 SW03-108) - MT7-03 - MT7-03 wp03 1,202.93 33.91 1,202.93 28.03 1,200.00 5.771 Centre Distance Pass - MT7-03 (GMT2 SW03-108) - MT7-03 - MT7-03 wp03 2,624.31 36.68 2,624.31 25.73 2,600.00 3.351 Ellipse Separation Pass - MT7-03 (GMT2 SW03-108) - MT7-03 - MT7-03 wp03 23,772.73 1,198.95 23,772.73 599.87 24,696.09 2.001 Clearance Factor Pass - MT7-04 (GMT2 SW04-208) - GMT2-SW04 - MT7-04 w 498.92 59.90 498.92 55.94 500.00 15.155 Centre Distance Pass - MT7-04 (GMT2 SW04-208) - GMT2-SW04 - MT7-04 w 698.83 60.24 698.83 55.29 700.00 12.166 Ellipse Separation Pass - MT7-04 (GMT2 SW04-208) - GMT2-SW04 - MT7-04 w 4,073.17 975.23 4,073.17 863.96 4,300.00 8.764 Clearance Factor Pass - MT7-04 (GMT2 SW04-208) - GMT2-SW04 - MT7-04 498.89 55.97 498.89 52.33 500.00 15.356 Centre Distance Pass - MT7-04 (GMT2 SW04-208) - GMT2-SW04 - MT7-04 799.29 56.14 799.29 51.41 800.00 11.877 Ellipse Separation Pass - MT7-04 (GMT2 SW04-208) - GMT2-SW04 - MT7-04 4,073.19 968.58 4,073.19 857.59 4,300.00 8.727 Clearance Factor Pass - MT7-05 (GMT2 SWO5-109) - MT7-05 - MT7-05 wp03 1,928.38 67.50 1,928.38 58.96 1,900.00 7.905 Centre Distance Pass - MT7-05 (GMT2 SWO5-109) - MT7-05 - MT7-05 wp03 2,236.31 69.39 2,236.31 56.75 2,200.00 5.489 Ellipse Separation Pass - MT7-05 (GMT2 SW05-109) - MT7-05 - MT7-05 wp03 23,829.41 2,407.34 23,829.41 1,707.71 25,492.44 3.441 Clearance Factor Pass - MT7-06 (GMT2 SW06-209) - MT7-06 - MT7-06 39.50 99.84 39.50 98.51 39.55 74.857 Centre Distance Pass - MT7-06 (GMT2 SW06-209) - MT7-06 - MT7-06 896.54 102.39 896.54 95.98 895.65 15.984 Clearance Factor Pass - MT7-06 (GMT2 SW06-209) - MT7-06 - MT7-06_wp09 499.05 99.83 499.05 95.99 500.00 25.972 Centre Distance Pass - MT7-06 (GMT2 SW06-209) - MT7-06 - MT7-06_wp09 901.08 100.02 901.08 94.40 900.00 17.802 Ellipse Separation Pass - MT7-06 (GMT2 SW06-209) - MT7-06 - MT7-06_wp09 4,056.02 1,076.57 4,056.02 962.88 4,300.00 9.469 Clearance Factor Pass - MT7-07 (GMT2 SW07-110) - MT7-07 - MT7-07 wp02 1,213.87 115.58 1,213.87 109.42 1,200.00 18.755 Centre Distance Pass - MT7-07 (GMT2 SW07-110) - MT7-07 - MT7-07 wp02 1,317.57 115.58 1,317.57 108.96 1,300.00 17.447 Ellipse Separation Pass - MT7-07 (GMT2 SW07-110) - MT7-07 - MT7-07 wp02 4,012.74 558.99 4,012.74 464.55 4,000.00 5.919 Clearance Factor Pass - MT7-09 (GMT2 SW09-111) - MT7-09 - MT7-09 wp02 600.00 159.90 600.00 155.60 600.00 37.189 Centre Distance Pass - MT7-09 (GMT2 SW09-111) - MT7-09 - MT7-09 wp02 1,219.02 159.92 1,219.02 153.75 1,200.00 25.917 Ellipse Separation Pass - 22 July, 2021 - 14:09 Page 2 of 6 COMPASS ConocoPhillips Alaska Inc WNS ConocoPh i I I i ps Western North Slope Anticollision Report for MT7-01 (GMT2 SW01-107) - MT7-01-_wp08 Tray. Cylinder North Proximity Scan on Current Survey Data (Highside Reference) Reference Design: GMT2 Rendezvous Pad - MT7-01 (GMT2 SW01-107) - MT7-01 - MT7-01- wp08 Scan Range: 0.00 to 23,842.79 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft 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 MT7-09 (GMT2 SW09-111) - MT7-09 - MT7-09 wp02 4,008.46 706.84 4,008.46 610.44 4,000.00 7.333 Clearance Factor Pass - MT7-14 (GMT2 SW14-213) - GMT2-SW13 - GMT2-213 414.50 259.89 414.50 256.42 400.00 74.912 Ellipse Separation Pass - MT7-14 (GMT2 SW14-213) - GMT2-SW13 - GMT2-213 4,017.73 1,657.18 4,017.73 1,530.30 4,300.00 13.061 Clearance Factor Pass - MT7-96 (GMT2 NE04-105) - MT7-96 - MT7-96 wp02 797.46 73.23 797.46 68.52 800.00 15.567 Ellipse Separation Pass - MT7-96 (GMT2 NE04-105) - MT7-96 - MT7-96 wp02 22,528.28 2,374.88 22,528.28 1,807.60 21,797.21 4.186 Clearance Factor Pass - MT7-99 (GMT2 NE01-206) - MT7-99 - MT7-99 wp02 500.00 20.11 500.00 16.37 500.00 5.380 Centre Distance Pass - MT7-99 (GMT2 NE01-206) - MT7-99 - MT7-99 wp02 599.99 20.11 599.99 15.81 600.00 4.680 Ellipse Separation Pass - MT7-99 (GMT2 NE01-206) - MT7-99 - MT7-99 wp02 699.91 20.62 699.91 15.88 700.00 4.354 Clearance Factor Pass - Prelim: 2017 - GMT2 NE03-205 - GMT2-NE03 - GMT2 714.13 98.49 714.13 94.33 700.00 23.692 Ellipse Separation Pass - Prelim: 2017 - GMT2 NE03-205 - GMT2-NE03 - GMT2 9,000.00 1,991.19 9,000.00 1,865.26 10,500.00 15.812 Clearance Factor Pass - Prelim: 2017 - GMT2 NE05-204 - GMT2-NE05 - GMT2 714.03 138.45 714.03 134.29 700.00 33.306 Ellipse Separation Pass - Prelim: 2017 - GMT2 NE05-204 - GMT2-NE05 - GMT2 1,000.00 152.41 1,000.00 147.53 1,000.00 31.222 Clearance Factor Pass - Prelim: 2017 - GMT2 NE06-104 - GMT2-NE06 - GMT2 810.24 151.68 810.24 147.46 800.00 35.922 Ellipse Separation Pass - Prelim: 2017 - GMT2 NE06-104 - GMT2-NE06 - GMT2 4,004.56 941.89 4,004.56 829.07 4,100.00 8.349 Clearance Factor Pass - Prelim: 2017 - GMT2 NE07-203 - GMT2-NE07 - GMT2 713.93 178.43 713.93 174.27 700.00 42.925 Ellipse Separation Pass - Prelim: 2017 - GMT2 NE07-203 - GMT2-NE07 - GMT2 4,011.99 1,795.01 4,011.99 1,745.94 4,700.00 36.585 Clearance Factor Pass - Prelim: 2017 - GMT2 NE08-103 - GMT2-NE08 - GMT2 713.17 197.39 713.17 193.39 700.00 49.348 Ellipse Separation Pass - Prelim: 2017 - GMT2 NE08-103 - GMT2-NE08 - GMT2 4,020.12 1,385.93 4,020.12 1,277.04 4,300.00 12.728 Clearance Factor Pass - Prelim: 2017 - GMT2 NE09-202 - GMT2-NE09 - GMT2 713.83 218.42 713.83 214.26 700.00 52.545 Ellipse Separation Pass - Prelim: 2017 - GMT2 NE09-202 - GMT2-NE09 - GMT2 4,048.90 2,559.91 4,048.90 2,502.10 5,200.00 44.276 Clearance Factor Pass - Prelim: 2017 - GMT2 NE10-102 - GMT2-NE10 - GMT2 314.50 238.61 314.50 236.13 300.00 96.312 Centre Distance Pass - Prelim: 2017 - GMT2 NE10-102 - GMT2-NE10 - GMT2 414.49 238.78 414.49 235.85 400.00 81.291 Ellipse Separation Pass - Prelim: 2017 - GMT2 NE10-102 - GMT2-NE10 - GMT2 4,032.02 1,942.60 4,032.02 1,832.63 4,600.00 17.665 Clearance Factor Pass - Prelim: 2017 - GMT2 NE11-201 - GMT2-NE11 - GMT2- 713.73 258.41 713.73 254.25 700.00 62.167 Ellipse Separation Pass - Prelim: 2017- GMT2 NE11-201-GMT2-NE11-GMT2- 1,175.59 297.19 1,175.59 291.67 1,200.00 53.795 Clearance Factor Pass - Prelim: 2017 - GMT2 SW08-210 - GMT2-SW08 - GMT 514.50 139.89 514.50 136.30 500.00 39.038 Centre Distance Pass - Prelim: 2017 - GMT2 SW08-210 - GMT2-SW08 - GMT 614.49 140.18 614.49 136.26 600.00 35.741 Ellipse Separation Pass - Prelim: 2017 - GMT2 SW08-210 - GMT2-SW08 - GMT 11,781.44 2,499.09 11,781.44 2,224.66 10,100.00 9.107 Clearance Factor Pass - Prelim: 2017 - GMT2 SW10-211 - GMT2-SW10 - GMT2 514.50 179.89 514.50 176.30 500.00 50.201 Ellipse Separation Pass - Prelim: 2017 - GMT2 SW10-211 - GMT2-SW10 - GMT2 4,022.47 1,385.57 4,022.47 1,271.86 4,300.00 12.185 Clearance Factor Pass - 22 July, 2021 - 14:09 Page 3 of 6 COMPASS ConocoPhillips Alaska Inc WNS ConocoPh i I I i ps Western North Slope Anticollision Report for MT7-01 (GMT2 SW01-107) - MT7-01-_wp08 Tray. Cylinder North Proximity Scan on Current Survey Data (Highside Reference) Reference Design: GMT2 Rendezvous Pad - MT7-01 (GMT2 SW01-107) - MT7-01 - MT7-01-_wp08 Scan Range: 0.00 to 23,842.79 usft. Measured Depth. Scan Radius is Unlimited. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is 1,000.00 usft 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 Prelim: 2017 - GMT2 SW11-112 - GMT2-SW011 - GMT 514.50 199.89 514.50 196.18 500.00 53.882 Centre Distance Pass - Prelim: 2017 - GMT2 SW11-112 - GMT2-SW011 - GMT 614.50 200.05 614.50 195.98 600.00 49.125 Ellipse Separation Pass - Prelim: 2017 - GMT2 SW11-112 - GMT2-SW011 - GMT 4,014.50 878.07 4,014.50 780.15 4,000.00 8.967 Clearance Factor Pass - Prelim: 2017 - GMT2 SW12-212 - GMT2-SW12 - GMT 414.50 219.89 414.50 216.75 400.00 70.044 Centre Distance Pass - Prelim: 2017 - GMT2 SW12-212 - GMT2-SW12 - GMT 514.50 220.02 514.50 216.35 500.00 59.810 Ellipse Separation Pass - Prelim: 2017 - GMT2 SW12-212 - GMT2-SW12 - GMT 4,012.69 1,525.67 4,012.69 1,412.89 4,300.00 13.529 Clearance Factor Pass - Prelim: 2017 - GMT2 SW13-113 - GMT2-SW013 - GMT 514.50 239.89 514.50 236.42 500.00 68.953 Ellipse Separation Pass - Prelim: 2017 - GMT2 SW13-113 - GMT2-SW013 - GMT 4,015.68 1,030.51 4,015.68 933.18 4,000.00 10.588 Clearance Factor Pass - Survey tool program From To (usft) (usft) 39.50 1,300.00 MT7-01-_wp08 1,300.00 2,300.00 MT7-01-_wp08 2,300.00 3,485.00 MT7-01-_wp08 3,485.00 3,985.00 MT7-01-_wp08 3,985.00 5,985.00 MT7-01-_wp08 5,985.00 10,865.00 MT7-01-_wp08 10,865.00 11,865.00 MT7-01-_wp08 11,865.00 13,365.00 MT7-01-_wp08 13,365.00 23,842.79 MT7-01-_wp08 Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey/Plan Survey Tool GYD-GC-SS MWD OWSG M WD+IFR2+SAG+M S MWD-INC_ONLY (INC>10°) MWD OWSG MWD+IFR2+SAG+MS MWD-INC—ONLY (INC>10°) MWD OWSG MWD+IFR2+SAG+MS 22 July, 2021 - 14:09 Page 4 of 6 COMPASS ConocoPhilli s p Anticollision Report for MT7-01 (GMT2 SW01-107) - MT7-01-_wp08 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to 139.5 @ 139.50usft. Northing and Easting are relative to MT7-01 (GMT2 SW01-107). Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is-150.00°, Grid Convergence at Surface is: -1.59 °. X Ladder Plot 0 4500 9000 13500 18000 22500 Measured Depth (4500 usfUin) ConocoPhillips Alaska Inc WNS Western North Slope $ NM-02 (GMT2 SV02-207), NM-02, NM-02 wp04 VO $ NM-03 (GMT2 SWU3-108), MT7-03, M17-03 VO MT7-03 (GMT2 SV\103-108), MT7-03, MT7-03 wp03 VO $ MT7-04 (GMT2 SW04-208), GMT2-SW04, MT7-04 VO $ MT7-04 (GMT2 SVW4-208), GMT2-SVW4, KU-04wp03 VO $ MT7-05 (GMT2 SVW5-109), MT7-05, MT7-05wp03 VO $ MT7-06 (GMT2 SVW6-209), M17-06, MT7-06 VO $ MT7-06 (GMT2 SW06-209), MT7-06, MT7-06_wp09 VO $ MT7-07 (GMT2 SVW7-110), MT7-07, MT7-07 wp02 VO $ MT7-09 (GMT2 SW09-111), NM-09, MT7-09 wp02 VO -4— NM-14 (GMT2 SW14-213), GMT2-SW13, GMT2-213 wp01 V $ MT7-96 (GMT2 NE04-105), NM-96, MT7-96 wp02 VO $ MT7-99 (GMT2 NEO1-206), NM-99, MT7-99 wp02 VO $ Prelim: 2017-GMT2NE03-205,GMT2-NE03,GMT2-205wpO ` $ Prelim: 2017-GMT2NE05-204,GMT2-NE05,GMT2-204WpO ` $ Prelim: 2017-GMT2NE06-104,GMT2-NE06,GMT2-104Wp0 $ Prelim: 2017-GMT2NE07-203,GMT2-NE07,GMT2-203wp0 $ Prelim: 2017- GMT2 NE08-103, GMT2-NE08, GMT2-103 wpO Prelim: 2017-GMT2NE09-202,GMT2-NE09,GMT2-202WpO $ Prelim: 2017-GMT2NE10-102,GMT2-NE10,GMT2-102wpO $ Prelim: 2017-GMT2NE11-201,GMT2-NE11,GMT2-201wpO ` $ Prelim: 2017-GNnSW08-210,GMT2SW08,GMT2-210wp $ Prelim: 2017-GMT2SW10-211,GMT2-SW10,GRM-211wp $ Prelim: 2017-GMT2SW11-112,GMT2-SVW11,GMT2-112wp Y $ Prelim: 2017-GMT2SW12-212,GMT2SVV12,GNM-212wp 22 July, 2021 - 14:09 Page 5 of 6 COMPASS ConocoPhilli s p Anticollision Report for MT7-01 (GMT2 SW01-107) - MT7-01 =wp08 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor 10. [1f=lmvllmlmim 7.50 c 0 6.25 - 0 U (6 LL 0 5.00 m (!j 3.75 Normal Operations Caution MonitorClc Take Immediate Action 1.25 STOP Drilling 0 2000 4000 6000 8000 10000 12000 14000 16000 18000 20000 22000 24000 Measu-ed Depth (4000 usf rin) ConocoPhillips Alaska Inc WNS Western North Slope LEGEND MT7-02 (GMT2 SW02-207), M17-02, MT7-02 wp04 VO MT7-03 (GMT2 SW03-108), MT7-03, MT7-03 VO MT7-03 (GMT2 SW03-108), M17-03, MT7-03 wp03 VO MT7-04 (GMT2 SW04-208), GMT2-SW04, MT7-04 VO MT7-04 (GMT2 SW04-208), GMT2-SW04, MT7-04 wp03 VO MT7-05 (GMT2 SW05-109), NM-05, MT7-05 wp03 VO NM-06 (GMT2 SW06-209), KM-06, NM-06 VO MT7-06 (GMT2 SW06-209), M17-06, MT7-06 wp09 VO MT7-07 (GMT2 SW07-110), MT7-07, MT7-07 wp02 VO MT7-09 (GMT2 SW09-111), MT7-09, MT7-09 wp02 VO M17-14(GMT2SW14-213),GMT2-SW13,GMT2-213wp01 VO MT7-96 (GMT2 NE04-105), MT7-96, MT7-96 wp02 VO MT7-99 (GMT2 NE01-206), MT7-99, MT7-99 wp02 VO Prelim: 2017-GMT2NE03-205,GMT2-NE03,GMT2-205wp01 V Prelim: 2017-GMT2NE05-204,GMT2-NE05,GMT2-204wp01 V Prelim: 2017-GNMNE06-104,GMT2-NE06,GMT2-104wp01 V Prelim: 2017-GNMNE07-203,GMT2-NE07,GMT2-203wp01 V Prelim:2017 -GMT2 NE08-103, GMT2-NE08, GMT2-103 wp01 V Prelim: 2017-GNMNE09-202,GMT2-NE09,GMT2-202wp01 V Prelim: 2017-GNMNE10-102,GMT2-NE10,GMT2-102wp01 V Prelim:2017-GKMNE11-201,GMT2-NE11,GMT2-201wp01 V Prelim: 2017-GMT2SW08-210,GMT2-SW08,GMT2-210wp01 V Prelim: 2017-GWUSW10-211,GMT2-SW10,GMT2-211 wp01 V Prelim: 2017 - GMT2 SW11-112, GMT2-SWO11, GMT2-112 wp01 Prelim: 2017-GMT2SW12-212,GMT2SW12,GMT2-212wp01 V Prelim: 2017 - GMT2 SW13-113, GMT2-SW013, GMT2-113 wp01 22 July, 2021 - 14:09 Page 6 of 6 COMPASS ConocoPhillips ConocoPhillips Alaska Inc WNS Western North Slope GMT2 Rendezvous Pad MT7-01 (GMT2 SW01-107) 50103xxxxx00 MT7-01 Plan: MT7-01-_wp08 Error Ellipse Survey Report 22 July, 2021 Baker Hughes ConocoPhillips ConocoPhillips Error Ellipse Report Baker Hughes Company: ConocoPhillips Alaska Inc WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 (GMT2 SW01-107) Wellbore: MT7-01 Design: MT7-01-_wp08 Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well MT7-01 (GMT2 SW01-107) 139.5 @ 139.50usft 139.5 @ 139.50usft True Minimum Curvature 2.00 sigma EDT 15 Alaska Prod Project _ Western North Slope, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site GMT2 Rendezvous Pad Site Position: • Northing: 5,915,580.00 usft Latitude: 70° 10' 22.674 N From: Map Easting: 1,430,062.00 usft Longitude: 151° 41' 36.331 W Position Uncertainty: 0.00 usft Slot Radius: 13.200 in Grid Convergence: -1.59 ° Well MT7-01 (GMT2 SW01-107) Well Position +NI-S 0.00 usft Northing: 5,915,580.08 usft Latitude: 70° 10' 22.675 N +EI-W 0.00 usft Easting: 1,430,061.84 usft Longitude: 151° 41' 36.336 W Position Uncertainty 0.00 usft Wellhead Elevation: 0.00 usft Ground Level: 100.00 usft Wellbore MT7-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2020 8/15/2021 14.78 80.40 57,150.73 BGGM2020 8/14/2021 14.78 80.40 57,150.85 Design MT7-01-_wp08 Audit Notes: Version: Phase: PLAN Tie On Depth: 39.50 Vertical Section: Depth From (TVD) +NI-S +E/-W Direction (usft) (usft) (usft) 39.50 0.00 0.00 333.00 Survey Tool Program Date 7/22/2021 From To (usft) (usft) Survey (Wellbore) Tool Name Description 39.50 1,300.00 MT7-01-_wp08 (MT7-01) GYD-GC-SS Gyrodata gyro single shots 1,300.00 2,300.00 MT7-01-_wp08 (MT7-01) MWD OWSG OWSG MWD - Standard 2,300.00 3,485.00 MT7-01-_wp08 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 3,485.00 3,985.00 MT7-01-_wp08 (MT7-01) MWD-INC—ONLY (INC>10°) MWD-INC—ONLY—FILLER ( INC>10°) 3,985.00 5,985.00 MT7-01-_wp08 (MT7-01) MWD OWSG OWSG MWD - Standard 5,985.00 10,865.00 MT7-01-_wp08 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 10,865.00 11,865.00 MT7-01-_wp08 (MT7-01) MWD-INC—ONLY (INC>10°) MWD-INC—ONLY—FILLER ( INC>10°) 11,865.00 13,365.00 MT7-01-_wp08 (MT7-01) MWD OWSG OWSG MWD - Standard 13,365.00 23,842.79 MT7-01-_wp08 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi -Station Correction 7/22/2021 2:10:47PM Page 2 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Error Ellipse Report Baker Hughes Company: ConocoPhillips Alaska Inc WNS Local Co-ordinate Reference: Well MT7-01 (GMT2 SW01-107) Project: Western North Slope TVD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad MD Reference: 139.5 @ 139.50usft Well: MT7-01 (GMT2 SW01-107) North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01-_wp08 Output errors are at 2.00 sigma Database: EDT 15 Alaska Prod Plan Survey Tool Program Date 7/22/2021 Depth From Depth To (usft) (usft) Survey (Wellbore) Tool Name Remarks 1 39.50 1,300.00 MT7-01-_wp08 (MT7-01) GYD-GC-SS Gyrodata gyro single shots 2 1,300.00 2,300.00 MT7-01-_wp08 (MT7-01) MWD OWSG OWSG MWD - Standard 3 2,300.00 3,485.00 MT7-01- wp08 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + 4 3,485.00 3,985.00 MT7-01-_wp08 (MT7-01) MWD-INC-ONLY (INC>10°) MWD-INC-ONLY-FILLER (IP 5 3,985.00 5,985.00 MT7-01-_wp08 (MT7-01) MWD OWSG OWSG MWD - Standard 6 51985.00 10,865.00 MT7-01-_wp08 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + 7 10,865.00 11,865.00 MT7-01-_wp08 (MT7-01) MWD-INC_ONLY (INC>10°) MWD-INC-ONLY-FILLER (IP 8 11,865.00 13,365.00 MT7-01- wp08 (MT7-01) MWD OWSG OWSG MWD - Standard 9 13,365.00 23,842.79 MT7-01- wp08 (MT7-01) MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (1) 39.50 0.00 0.00 39.50 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 0.18 0.00 0.18 0.00 2.30 0.00 0.00 0.18 0.18 0.00 GYD-GC-SS(1) 200.00 0.00 0.00 200.00 0.46 0.00 0.46 0.00 2.30 0.00 0.00 0.46 0.46 0.00 GYD-GC-88(1) 300.00 0.00 0.00 300.00 0.75 0.00 0.75 0.00 2.30 0.00 0.00 0.75 0.75 0.00 GYD-GC-SS(1) 400.00 0.00 0.00 400.00 1.04 0.00 1.04 0.00 2.30 0.01 0.01 1.04 1.04 0.00 GYD-GC-88(1) 500.00 0.00 0.00 500.00 1.33 0.00 1.33 0.00 2.30 0.02 0.02 1.33 1.33 0.00 GYD-GC-SS(1) 600.00 0.00 0.00 600.00 1.62 0.00 1.62 0.00 2.31 0.03 0.03 1.62 1.62 0.00 GYD-GC-SS(1) 700.00 0.00 0.00 700.00 1.78 0.00 1.78 0.00 2.31 0.04 0.04 1.78 1.78 0.00 GYD-GC-SS(1) 800.00 1.50 199.11 799.99 1.85 0.00 1.85 0.00 2.32 0.06 0.06 1.85 1.85 135.00 GYD-GC-88(1) 900.00 3.00 199.11 899.91 1.96 0.00 1.96 0.00 2.32 0.08 0.08 1.96 1.96 108.60 GYD-GC-SS(1) 949.68 3.75 199.11 949.50 2.10 -0.01 2.11 0.00 2.33 0.10 0.10 2.11 2.11 108.03 GYD-GC-SS(1) 1,000.00 4.50 199.11 999.69 2.10 -0.01 2.11 0.00 2.33 0.10 0.10 2.11 2.11 108.03 GYD-GC-SS(1) 1,100.00 6.50 199.11 1,099.23 2.27 -0.01 2.29 0.00 2.33 0.12 0.12 2.29 2.29 103.44 GYD-GC-88(1) 1,200.00 8.50 199.11 1,198.37 2.46 -0.01 2.50 0.00 2.33 0.15 0.15 2.50 2.49 21.39 GYD-GC-SS(1) 1,300.00 10.50 199.11 1,296.99 2.67 -0.02 2.74 0.00 2.34 0.18 0.18 2.74 2.72 20.09 GYD-GC-88(1) 1,400.00 13.00 199.11 1,394.89 2.78 -0.02 2.90 0.00 2.66 0.00 0.02 2.90 2.87 19.94 MWD OWSG (2) 1,412.73 13.32 199.11 1,407.28 2.81 -0.02 3.11 0.00 2.70 0.00 0.02 3.11 2.94 19.19 MWD OWSG (2) 1,500.00 15.50 199.11 1,491.80 2.81 -0.02 3.11 0.00 2.70 0.00 0.02 3.11 2.94 19.19 MWD OWSG (2) 7/22/2021 2:10:47PM Page 3 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Error Ellipse Report Baker Hughes Company: ConocoPhillips Alaska Inc WNS Local Co-ordinate Reference: Well MT7-01 (GMT2 SW01-107) Project: Western North Slope TVD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad MD Reference: 139.5 @ 139.50usft Well: MT7-01 (GMT2 SW01-107) North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01-_wp08 Output errors are at 2.00 sigma Database: EDT 15 Alaska Prod Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (I (I (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) . 1,600.00 18.00 199.11 1,587.55 2.90 -0.02 3.54 0.00 2.75 0.00 0.02 3.54 3.07 19.07 MWD OWSG (2) 1,679.58 19.99 199.11 1,662.79 3.05 -0.02 4.20 0.00 2.82 0.00 0.02 4.20 3.25 19.04 MWD OWSG (2) 1,700.00 20.50 199.11 1,681.95 3.05 -0.02 4.20 0.00 2.82 0.00 0.02 4.20 3.25 19.04 MWD OWSG (2) 1,800.00 23.00 199.11 1,774.83 3.25 -0.02 5.06 0.00 2.89 0.00 0.02 5.06 3.47 19.04 MWD OWSG (2) 1,900.00 25.50 199.11 1,865.99 3.50 -0.02 6.08 0.00 2.97 0.00 0.02 6.08 3.73 19.03 MWD OWSG (2) 2,000.00 28.00 199.11 1,955.29 3.80 -0.02 7.27 0.00 3.08 0.00 0.02 7.27 4.02 19.04 MWD OWSG (2) 2,065.41 29.64 199.11 2,012.59 4.13 -0.02 8.58 0.00 3.20 0.00 0.02 8.58 4.34 19.04 MWD OWSG (2) 2,100.00 30.50 199.11 2,042.53 4.13 -0.02 8.58 0.00 3.20 0.00 0.02 8.58 4.34 19.04 MWD OWSG (2) 2,200.00 33.00 199.11 2,127.56 4.50 -0.02 10.03 0.00 3.35 0.00 0.02 10.03 4.68 19.04 MWD OWSG (2) 2,300.00 35.50 199.11 2,210.21 4.90 -0.02 11.59 0.00 3.53 0.00 0.02 11.59 5.04 19.04 MWD OWSG (2) 2,400.00 38.00 199.11 2,290.33 5.07 -0.02 12.56 0.00 3.44 0.00 0.02 12.56 5.46 19.05 MWD+IFR2+SAG+MS (3) 2,500.00 40.50 199.11 2,367.76 5.04 -0.02 12.92 0.00 3.49 0.00 0.02 12.92 5.52 19.05 MWD+IFR2+SAG+MS (3) 2,586.00 42.65 199.11 2,432.09 5.02 -0.02 13.29 0.00 3.55 0.00 0.02 13.29 5.59 19.05 MWD+IFR2+SAG+MS (3) 2,591.71 42.65 199.11 2,436.29 5.03 -0.02 13.35 0.00 3.55 0.00 0.02 13.35 5.60 19.05 MWD+IFR2+SAG+MS (3) 2,600.00 42.65 199.11 2,442.39 5.03 -0.02 13.35 0.00 3.55 0.00 0.02 13.35 5.60 19.05 MWD+IFR2+SAG+MS (3) 2,700.00 42.65 199.11 2,515.94 5.13 -0.02 13.84 0.00 3.67 0.00 0.02 13.84 5.68 19.05 MWD+IFR2+SAG+MS (3) 2,800.00 42.65 199.11 2,589.49 5.26 -0.02 14.36 0.00 3.81 0.00 0.02 14.36 5.77 19.05 MWD+IFR2+SAG+MS (3) 2,900.00 42.65 199.11 2,663.04 5.42 -0.02 14.93 0.00 3.97 0.00 0.02 14.93 5.88 19.04 MWD+IFR2+SAG+MS (3) 3,000.00 42.65 199.11 2,736.59 5.60 -0.02 15.52 0.00 4.15 0.00 0.02 15.52 6.00 19.04 MWD+IFR2+SAG+MS (3) 3,100.00 42.65 199.11 2,810.14 5.81 -0.02 16.15 0.00 4.33 0.00 0.02 16.15 6.14 19.04 MWD+IFR2+SAG+MS(3) 3,200.00 42.65 199.11 2,883.69 6.03 -0.02 16.80 0.00 4.53 0.00 0.02 16.80 6.28 19.03 MWD+IFR2+SAG+MS (3) 3,300.00 42.65 199.11 2,957.24 6.28 -0.02 17.48 0.00 4.74 0.00 0.02 17.48 6.45 19.03 MWD+IFR2+SAG+MS (3) 3,400.00 42.65 199.11 3,030.80 6.54 -0.02 18.18 0.00 4.96 0.00 0.02 18.18 6.62 19.03 MWD+IFR2+SAG+MS (3) 3,416.08 42.65 199.11 3,042.62 6.68 -0.02 18.72 0.00 4.16 0.99 1.32 18.72 6.36 19.03 WD-INC ONLY (INC>10°) (4) 3,484.57 42.65 199.11 3,093.00 6.68 -0.02 18.72 0.00 4.16 0.99 1.32 18.72 6.36 19.03 WD-INC_ONLY (INC>10°) (4) 3,500.00 42.65 199.11 3,104.35 6.68 -0.02 18.72 0.00 4.16 0.99 1.32 18.72 6.36 19.03 WD-INC ONLY (INC>10°) (4) 3,600.00 42.65 199.11 3,177.90 6.73 -0.02 21.21 0.00 4.20 1.04 1.40 21.21 6.39 19.05 WD-INC_ONLY (INC>100) (4) 3,700.00 42.65 199.11 3,251.45 6.81 -0.02 29.57 0.00 4.27 1.10 1.47 29.57 6.44 19.08 WD-INC ONLY (INC>100) (4) 3,800.00 42.65 199.11 3,325.00 6.93 -0.02 44.83 0.00 4.37 1.15 1.55 44.83 6.52 19.10 WD-INC_ONLY (INC>10°) (4) 3,900.00 42.65 199.11 3,398.55 7.09 -0.02 66.32 0.00 4.50 1.21 1.63 66.32 6.61 19.10 WD-INC ONLY (INC>100) (4) 4,000.00 42.65 199.11 3,472.10 7.19 -0.02 78.73 0.00 5.63 0.00 0.02 78.73 7.26 19.11 MWD OWSG (5) 4,100.00 42.65 199.11 3,545.65 7.24 -0.02 79.05 0.00 5.73 0.00 0.02 79.05 7.33 19.11 MWD OWSG (5) 4,200.00 42.65 199.11 3,619.20 7.33 -0.02 79.41 0.00 5.85 0.00 0.02 79.41 7.42 19.11 MWD OWSG (5) 4,240.61 42.65 199.11 3,649.07 7.48 -0.02 79.83 0.00 6.00 0.00 0.02 79.83 7.54 19.11 MWD OWSG (5) 4,300.00 42.65 199.11 3,692.75 7.48 -0.02 79.83 0.00 6.00 0.00 0.02 79.83 7.54 19.11 MWD OWSG (5) 4,400.00 42.65 199.11 3,766.30 7.67 -0.02 80.29 0.00 6.18 0.00 0.02 80.29 7.69 19.11 MWD OWSG (5) 4,500.00 42.65 199.11 3,839.85 7.90 -0.02 80.79 0.00 6.38 0.00 0.02 80.79 7.86 19.10 MWD OWSG (5) 4,556.42 42.65 199.11 3,881.35 8.16 -0.02 81.34 0.00 6.60 0.00 0.02 81.34 8.05 19.10 MWD OWSG (5) 4,600.00 42.65 199.11 3,913.40 8.16 -0.02 81.34 0.00 6.60 0.00 0.02 81.34 8.05 19.10 MWD OWSG (5) 4,700.00 42.65 199.11 3,986.95 8.46 -0.02 81.93 0.00 6.84 0.00 0.02 81.93 8.26 19.10 MWD OWSG (5) 4,800.00 42.65 199.11 4,060.50 8.79 -0.02 82.57 0.00 7.10 0.00 0.02 82.57 8.49 19.10 MWD OWSG (5) 4,801.25 42.65 199.11 4,061.42 9.15 -0.02 83.24 0.00 7.37 0.00 0.02 83.24 8.74 19.10 MWD OWSG (5) 4,900.00 42.65 199.11 4,134.05 9.15 -0.02 83.24 0.00 7.37 0.00 0.02 83.24 8.74 19.10 MWD OWSG (5) 5,000.00 42.65 199.11 4,207.61 9.53 -0.02 83.96 0.00 7.66 0.00 0.02 83.96 9.00 19.10 MWD OWSG (5) 5,100.00 42.65 199.11 4,281.16 9.94 -0.02 84.71 0.00 7.96 0.00 0.02 84.71 9.28 19.10 MWD OWSG (5) 5,200.00 42.65 199.11 4,354.71 10.36 -0.02 85.51 0.00 8.27 0.00 0.02 85.51 9.57 19.10 MWD OWSG (5) 5,300.00 42.65 199.11 4,428.26 10.80 -0.02 86.34 0.00 8.59 0.00 0.02 86.34 9.88 19.10 MWD OWSG (5) 5,400.00 42.65 199.11 4,501.81 11.25 -0.02 87.20 0.00 8.92 0.00 0.02 87.20 10.20 19.10 MWD OWSG (5) 5,500.00 42.65 199.11 4,575.36 11.71 -0.02 88.11 0.00 9.26 0.00 0.02 88.11 10.52 19.10 MWD OWSG (5) 5,600.00 42.65 199.11 4,648.91 12.19 -0.02 89.04 0.00 9.61 0.00 0.02 89.04 10.86 19.10 MWD OWSG (5) 5,674.11 42.65 199.11 4,703.42 12.68 -0.02 90.01 0.00 9.96 0.00 0.02 90.01 11.20 19.10 MWD OWSG (5) 5,700.00 42.65 199.11 4,722.46 12.68 -0.02 90.01 0.00 9.96 0.00 0.02 90.01 11.20 19.10 MWD OWSG (5) 5,800.00 42.65 199.11 4,796.01 13.18 -0.02 91.01 0.00 10.32 0.00 0.02 91.01 11.56 19.10 MWD OWSG (5) 5,900.00 42.65 199.11 4,869.56 13.68 -0.02 92.05 0.00 10.68 0.00 0.02 92.05 11.92 19.10 MWD OWSG (5) 7/22/2021 2:10:47PM Page 4 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Error Ellipse Report Baker Hughes Company: ConocoPhillips Alaska Inc WNS Local Co-ordinate Reference: Well MT7-01 (GMT2 SW01-107) Project: Western North Slope TVD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad MD Reference: 139.5 @ 139.50usft Well: MT7-01 (GMT2 SW01-107) North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01-_wp08 Output errors are at 2.00 sigma Database: EDT 15 Alaska Prod Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (I (I (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (°) 6,000.00 42.65 199.11 4,943.11 13.94 -0.02 92.68 0.00 10.90 0.00 0.02 92.68 12.12 19.10 MWD+IFR2+SAG+MS (6) 6,100.00 42.65 199.11 5,016.66 13.95 -0.02 92.91 0.00 10.97 0.00 0.02 92.91 12.18 19.10 MWD+IFR2+SAG+MS(6) 6,132.71 42.65 199.11 5,040.72 13.97 -0.02 93.15 0.00 11.05 0.00 0.02 93.15 12.25 19.10 MWD+IFR2+SAG+MS(6) 6,200.00 42.65 199.11 5,090.21 13.97 -0.02 93.15 0.00 11.05 0.00 0.02 93.15 12.25 19.10 MWD+IFR2+SAG+MS (6) 6,300.00 42.65 199.11 5,163.76 14.01 -0.02 93.39 0.00 11.15 0.00 0.02 93.39 12.32 19.10 MWD+IFR2+SAG+MS(6) 6,400.00 42.65 199.11 5,237.31 14.06 -0.02 93.65 0.00 11.25 0.00 0.02 93.65 12.40 19.10 MWD+IFR2+SAG+MS (6) 6,500.00 42.65 199.11 5,310.86 14.12 -0.02 93.91 0.00 11.36 0.00 0.02 93.91 12.49 19.10 MWD+IFR2+SAG+MS (6) 6,600.00 42.65 199.11 5,384.41 14.19 -0.02 94.18 0.00 11.47 0.00 0.02 94.18 12.59 19.10 MWD+IFR2+SAG+MS (6) 6,700.00 42.65 199.11 5,457.97 14.27 -0.02 94.45 0.00 11.60 0.00 0.02 94.45 12.70 19.10 MWD+IFR2+SAG+MS (6) 6,800.00 42.65 199.11 5,531.52 14.37 -0.02 94.74 0.00 11.73 0.00 0.02 94.74 12.82 19.10 MWD+IFR2+SAG+MS (6) 6,900.00 42.65 199.11 5,605.07 14.47 -0.02 95.03 0.00 11.87 0.00 0.02 95.03 12.94 19.10 MWD+IFR2+SAG+MS (6) 7,000.00 42.65 199.11 5,678.62 14.59 -0.02 95.34 0.00 12.01 0.00 0.02 95.34 13.07 19.10 MWD+IFR2+SAG+MS (6) 7,100.00 42.65 199.11 5,752.17 14.71 -0.02 95.64 0.00 12.17 0.00 0.02 95.64 13.21 19.10 MWD+IFR2+SAG+MS(6) 7,200.00 42.65 199.11 5,825.72 14.85 -0.02 95.96 0.00 12.33 0.00 0.02 95.96 13.35 19.10 MWD+IFR2+SAG+MS (6) 7,300.00 42.65 199.11 5,899.27 15.00 -0.02 96.29 0.00 12.49 0.00 0.02 96.29 13.51 19.10 MWD+IFR2+SAG+MS (6) 7,400.00 42.65 199.11 5,972.82 15.15 -0.02 96.62 0.00 12.67 0.00 0.02 96.62 13.66 19.10 MWD+IFR2+SAG+MS (6) 7,500.00 42.65 199.11 6,046.37 15.32 -0.02 96.96 0.00 12.85 0.00 0.02 96.96 13.83 19.10 MWD+IFR2+SAG+MS (6) 7,600.00 42.65 199.11 6,119.92 15.50 -0.02 97.31 0.00 13.03 0.00 0.02 97.31 14.00 19.10 MWD+IFR2+SAG+MS (6) 7,700.00 42.65 199.11 6,193.47 15.68 -0.02 97.66 0.00 13.22 0.00 0.02 97.66 14.18 19.10 MWD+IFR2+SAG+MS(6) 7,767.41 42.65 199.11 6,243.05 15.81 -0.02 97.90 0.00 13.35 0.00 0.02 97.90 14.30 19.10 MWD+IFR2+SAG+MS (6) 7,788.68 42.34 199.94 6,258.73 15.96 -0.02 98.00 0.00 13.42 0.00 0.02 98.02 14.36 19.10 MWD+IFR2+SAG+MS (6) 7,800.00 42.18 200.38 6,267.11 15.96 -0.02 98.00 0.00 13.42 0.00 0.02 98.02 14.36 19.10 MWD+IFR2+SAG+MS (6) 7,881.73 41.06 203.67 6,328.22 17.47 -0.02 97.97 0.00 13.62 0.00 0.02 98.38 14.55 19.11 MWD+IFR2+SAG+MS (6) 7,900.00 40.82 204.42 6,342.02 17.47 -0.02 97.97 0.00 13.62 0.00 0.02 98.38 14.55 19.11 MWD+IFR2+SAG+MS (6) 8,000.00 39.61 208.68 6,418.39 20.51 -0.02 97.40 0.00 13.83 0.00 0.02 98.74 14.74 19.13 MWD+IFR2+SAG+MS (6) 8,100.00 38.57 213.15 6,496.02 24.77 -0.02 96.23 0.01 14.04 0.00 0.02 99.09 14.94 19.17 MWD+IFR2+SAG+MS(6) 8,200.00 37.70 217.80 6,574.69 29.85 -0.02 94.38 0.01 14.25 0.00 0.02 99.44 15.14 19.22 MWD+IFR2+SAG+MS (6) 8,300.00 37.03 222.62 6,654.18 35.42 -0.02 91.81 0.01 14.47 0.00 0.02 99.77 15.34 19.29 MWD+IFR2+SAG+MS (6) 8,400.00 36.55 227.57 6,734.29 41.20 -0.02 88.52 0.01 14.68 0.00 0.02 100.10 15.56 19.37 MWD+IFR2+SAG+MS (6) 8,500.00 36.28 232.61 6,814.78 46.94 -0.02 84.52 0.01 14.90 0.00 0.02 100.41 15.78 19.47 MWD+IFR2+SAG+MS (6) 8,600.00 36.23 237.69 6,895.43 52.43 -0.02 79.86 0.01 15.11 0.00 0.02 100.71 16.02 19.59 MWD+IFR2+SAG+MS (6) 8,700.00 36.39 242.75 6,976.04 57.48 -0.02 74.65 0.02 15.33 0.00 0.02 100.99 16.27 19.72 MWD+IFR2+SAG+MS (6) 8,800.00 36.76 247.76 7,056.37 61.95 -0.01 69.00 0.02 15.55 0.00 0.02 101.26 16.55 19.86 MWD+IFR2+SAG+MS (6) 8,900.00 37.34 252.65 7,136.20 65.72 -0.01 63.06 0.02 15.77 0.00 0.02 101.51 16.86 20.02 MWD+IFR2+SAG+MS(6) 9,000.00 38.11 257.39 7,215.31 68.73 -0.01 56.99 0.02 15.99 0.00 0.02 101.75 17.21 20.19 MWD+IFR2+SAG+MS (6) 9,100.00 39.06 261.96 7,293.49 70.97 -0.01 50.95 0.02 16.21 0.00 0.02 101.96 17.61 20.38 MWD+IFR2+SAG+MS(6) 9,200.00 40.19 266.32 7,370.53 72.43 -0.01 45.09 0.02 16.44 0.00 0.02 102.15 18.07 20.58 MWD+IFR2+SAG+MS (6) 9,248.64 40.79 268.37 7,407.52 73.16 -0.01 39.58 0.02 16.66 0.00 0.02 102.33 18.59 20.79 MWD+IFR2+SAG+MS (6) 9,300.00 41.47 270.47 7,446.21 73.16 -0.01 39.58 0.02 16.66 0.00 0.02 102.33 18.59 20.79 MWD+IFR2+SAG+MS (6) 9,400.00 42.90 274.41 7,520.32 73.22 -0.01 34.58 0.02 16.89 0.00 0.02 102.48 19.18 21.02 MWD+IFR2+SAG+MS (6) 9,500.00 44.45 278.13 7,592.66 72.65 -0.01 30.27 0.02 17.12 0.00 0.02 102.62 19.85 21.25 MWD+IFR2+SAG+MS (6) 9,584.87 45.85 281.13 7,652.52 71.54 0.00 26.85 0.02 17.35 0.00 0.02 102.73 20.61 21.50 MWD+IFR2+SAG+MS (6) 9,600.00 46.11 281.65 7,663.03 71.54 0.00 26.85 0.02 17.35 0.00 0.02 102.73 20.61 21.50 MWD+IFR2+SAG+MS (6) 9,700.00 47.88 284.97 7,731.24 69.94 0.00 24.52 0.02 17.58 0.00 0.02 102.82 21.45 21.75 MWD+IFR2+SAG+MS (6) 9,800.00 49.74 288.10 7,797.10 67.93 0.00 23.41 0.02 17.82 0.00 0.02 102.88 22.39 22.00 MWD+IFR2+SAG+MS (6) 9,900.00 51.68 291.07 7,860.43 65.57 0.00 23.51 0.02 18.06 0.00 0.02 102.93 23.42 22.26 MWD+IFR2+SAG+MS (6) 10,000.00 53.69 293.87 7,921.06 62.91 0.00 24.65 0.02 18.30 0.00 0.02 102.95 24.53 22.52 MWD+IFR2+SAG+MS (6) 10,100.00 55.76 296.53 7,978.82 60.01 0.00 26.55 0.02 18.54 0.00 0.02 102.96 25.73 22.78 MWD+IFR2+SAG+MS(6) 10,200.00 57.88 299.07 8,033.55 56.91 0.00 28.96 0.02 18.79 0.00 0.02 102.94 27.01 23.03 MWD+IFR2+SAG+MS (6) 10,300.00 60.06 301.49 8,085.10 53.67 0.00 31.68 0.02 19.04 0.00 0.02 102.90 28.36 23.28 MWD+IFR2+SAG+MS (6) 10,400.00 62.27 303.80 8,133.33 50.32 0.00 34.57 0.02 19.30 0.00 0.02 102.85 29.77 23.51 MWD+IFR2+SAG+MS(6) 10,500.00 64.53 306.02 8,178.11 46.92 0.00 37.55 0.02 19.56 0.00 0.02 102.77 31.23 23.73 MWD+IFR2+SAG+MS (6) 10,600.00 66.81 308.15 8,219.31 43.50 0.00 40.54 0.02 19.82 0.00 0.02 102.68 32.74 23.93 MWD+IFR2+SAG+MS (6) 10,700.00 69.12 310.22 8,256.82 40.12 0.00 43.53 0.02 20.09 0.00 0.02 102.58 34.29 24.11 MWD+IFR2+SAG+MS (6) 7/22/2021 2:10:47PM Page 5 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Error Ellipse Report Baker Hughes Company: ConocoPhillips Alaska Inc WNS Local Co-ordinate Reference: Well MT7-01 (GMT2 SW01-107) Project: Western North Slope TVD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad MD Reference: 139.5 @ 139.50usft Well: MT7-01 (GMT2 SW01-107) North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01-_wp08 Output errors are at 2.00 sigma Database: EDT 15 Alaska Prod Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (I (I (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (I 10,800.00 71.46 312.22 8,290.54 36.82 0.00 46.49 0.02 20.36 0.00 0.02 102.47 35.85 24.27 MWD+IFR2+SAG+MS (6) 10,865.33 73.00 313.50 8,310.48 34.60 -0.16 48.07 -0.10 17.61 3.59 11.76 103.34 38.04 25.69 WD-INC_ONLY (INC>100) (7) 10,885.33 73.00 313.50 8,316.33 34.60 -0.16 48.10 -0.10 17.61 3.60 11.79 103.34 38.08 25.69 WD-INC_ONLY (INC>10') (7) 10,900.00 73.32 313.83 8,320.58 34.11 -0.22 48.46 -0.17 17.62 3.60 11.81 103.34 38.12 25.68 WD-INC_ONLY (INC>10') (7) 10,906.30 73.46 313.98 8,322.38 30.82 -0.69 51.74 -0.61 17.65 3.64 11.96 103.40 39.31 25.48 WD-INC_ONLY (INC>100) (7) 11,000.00 75.54 316.08 8,347.42 30.82 -0.69 51.74 -0.61 17.65 3.64 11.96 103.40 39.31 25.48 WD-INC ONLY (INC>10') (7) 11,100.00 77.77 318.28 8,370.51 27.71 -1.16 57.87 -1.05 17.70 3.68 12.11 103.68 43.80 24.54 WD-INC_ONLY (INC>10') (7) 11,200.00 80.02 320.44 8,389.77 24.88 -1.64 68.89 -1.49 17.79 3.70 12.24 104.68 53.42 21.55 WD-INC ONLY (INC>10') (7) 11,300.00 82.28 322.57 8,405.16 22.43 -2.13 86.01 -1.92 17.91 3.73 12.37 107.94 67.51 13.32 WD-INC_ONLY (INC>100) (7) 11,400.00 84.56 324.68 8,416.62 20.49 -2.61 109.47 -2.35 18.05 3.74 12.50 118.28 80.95 175.98 WD-INC ONLY (INC>100) (7) 11,435.38 85.36 325.43 8,419.72 19.17 -3.10 139.01 -2.78 18.22 3.75 12.61 141.35 87.62 160.15 WD-INC_ONLY (INC>10')(7) 11,500.00 86.84 326.78 8,424.12 19.17 -3.10 139.01 -2.78 18.22 3.75 12.61 141.35 87.62 160.15 WD-INC ONLY (INC>100) (7) 11,600.00 89.13 328.86 8,427.64 18.55 -3.57 174.28 -3.20 18.43 3.75 12.72 174.64 89.67 153.17 WD-INC_ONLY (INC>100) (7) 11,621.23 89.61 329.31 8,427.87 18.52 -3.67 182.48 -3.29 18.47 3.75 12.75 182.68 89.84 152.39 WD-INC ONLY (INC>10') (7) 11,635.38 89.61 329.31 8,427.97 18.70 -3.67 214.95 -3.29 18.66 3.75 12.83 214.99 90.16 150.47 WD-INC_ONLY (INC>10') (7) 11,655.38 89.61 329.31 8,428.10 18.70 -3.67 214.95 -3.29 18.66 3.75 12.83 214.99 90.16 150.47 WD-INC ONLY (INC>100) (7) 11,700.00 89.61 329.31 8,428.40 18.70 -3.67 214.95 -3.29 18.66 3.75 12.83 214.99 90.16 150.47 WD-INC_ONLY (INC>100) (7) 11,800.00 89.61 329.31 8,429.08 18.95 -3.67 261.29 -3.29 18.91 3.76 12.93 261.29 90.25 149.26 WD-INC ONLY (INC>10') (7) 11,842.65 89.61 329.31 8,429.37 19.07 -3.67 282.76 -3.29 19.03 3.76 12.98 282.76 90.24 148.97 WD-INC ONLY (INC>100)(7) 11,900.00 90.07 330.66 8,429.53 19.12 -3.72 297.35 -3.42 19.12 3.72 5.18 297.49 90.08 148.82 MWD OWSG (8) 11,999.55 90.86 333.02 8,428.73 19.18 -3.70 296.59 -3.37 19.15 3.72 5.18 297.34 90.03 148.74 MWD OWSG (8) 12,100.00 90.86 333.02 8,427.22 19.24 -3.70 296.46 -3.37 19.20 3.72 5.18 297.25 89.96 148.66 MWD OWSG (8) 12,118.68 90.86 333.02 8,426.94 19.33 -3.70 296.40 -3.37 19.29 3.72 5.18 297.21 89.89 148.58 MWD OWSG (8) 12,200.00 90.86 333.02 8,425.72 19.33 -3.70 296.40 -3.37 19.29 3.72 5.18 297.21 89.89 148.58 MWD OWSG (8) 12,300.00 90.86 333.02 8,424.23 19.45 -3.70 296.40 -3.37 19.41 3.72 5.18 297.24 89.81 148.51 MWD OWSG (8) 12,400.00 90.86 333.02 8,422.73 19.60 -3.70 296.45 -3.37 19.56 3.72 5.18 297.32 89.74 148.43 MWD OWSG (8) 12,500.00 90.86 333.02 8,421.23 19.78 -3.70 296.57 -3.37 19.74 3.72 5.18 297.46 89.66 148.36 MWD OWSG (8) 12,600.00 90.86 333.02 8,419.73 19.99 -3.70 296.74 -3.37 19.95 3.72 5.18 297.67 89.59 148.29 MWD OWSG (8) 12,700.00 90.86 333.02 8,418.23 20.23 -3.70 296.97 -3.37 20.19 3.72 5.18 297.93 89.51 148.22 MWD OWSG (8) 12,800.00 90.86 333.02 8,416.74 20.50 -3.70 297.27 -3.37 20.46 3.72 5.18 298.24 89.44 148.16 MWD OWSG (8) 12,900.00 90.86 333.02 8,415.24 20.79 -3.70 297.61 -3.37 20.75 3.72 5.18 298.62 89.37 148.09 MWD OWSG (8) 13,000.00 90.86 333.02 8,413.74 21.11 -3.70 298.02 -3.37 21.07 3.72 5.18 299.06 89.29 148.03 MWD OWSG (8) 13,100.00 90.86 333.02 8,412.24 21.45 -3.70 298.49 -3.37 21.41 3.72 5.18 299.55 89.22 147.97 MWD OWSG (8) 13,200.00 90.86 333.02 8,410.75 21.81 -3.70 299.01 -3.37 21.77 3.72 5.18 300.10 89.15 147.92 MWD OWSG (8) 13,300.00 90.86 333.02 8,409.25 22.20 -3.70 299.59 -3.37 22.16 3.72 5.18 300.70 89.08 147.87 MWD OWSG (8) 13,400.00 90.86 333.02 8,407.75 22.40 -3.70 299.91 -3.37 22.36 3.72 5.18 301.04 89.03 147.82 MWD+IFR2+SAG+MS (9) 13,500.00 90.86 333.02 8,406.25 22.41 -3.70 299.92 -3.37 22.37 3.72 5.18 301.06 89.02 147.80 MWD+IFR2+SAG+MS (9) 13,600.00 90.86 333.02 8,404.76 22.43 -3.70 299.95 -3.37 22.39 3.72 5.18 301.10 89.01 147.78 MWD+IFR2+SAG+MS (9) 13,700.00 90.86 333.02 8,403.26 22.45 -3.70 299.99 -3.37 22.41 3.72 5.18 301.15 89.01 147.76 MWD+IFR2+SAG+MS (9) 13,800.00 90.86 333.02 8,401.76 22.49 -3.70 300.04 -3.37 22.45 3.72 5.18 301.21 89.00 147.74 MWD+IFR2+SAG+MS (9) 13,900.00 90.86 333.02 8,400.26 22.54 -3.70 300.11 -3.37 22.50 3.72 5.18 301.29 88.99 147.72 MWD+IFR2+SAG+MS (9) 14,000.00 90.86 333.02 8,398.76 22.59 -3.70 300.18 -3.37 22.55 3.72 5.18 301.37 88.98 147.70 MWD+IFR2+SAG+MS (9) 14,100.00 90.86 333.02 8,397.27 22.66 -3.70 300.27 -3.37 22.61 3.72 5.18 301.47 88.97 147.68 MWD+IFR2+SAG+MS(9) 14,200.00 90.86 333.02 6,395.77 22.73 -3.70 300.37 -3.37 22.69 3.72 5.18 301.57 88.97 147.66 MWD+IFR2+SAG+MS (9) 14,300.00 90.86 333.02 8,394.27 22.81 -3.70 300.47 -3.37 22.77 3.72 5.18 301.69 88.96 147.64 MWD+IFR2+SAG+MS (9) 14,400.00 90.86 333.02 8,392.77 22.90 -3.70 300.60 -3.37 22.86 3.72 5.18 301.82 88.96 147.62 MWD+IFR2+SAG+MS (9) 14,500.00 90.86 333.02 8,391.28 23.00 -3.70 300.73 -3.37 22.96 3.72 5.18 301.96 88.95 147.60 MWD+IFR2+SAG+MS (9) 14,600.00 90.86 333.02 8,389.78 23.11 -3.70 300.87 -3.37 23.06 3.72 5.18 302.12 88.95 147.58 MWD+IFR2+SAG+MS (9) 14,700.00 90.86 333.02 8,388.28 23.22 -3.70 301.03 -3.37 23.18 3.72 5.18 302.28 88.94 147.57 MWD+IFR2+SAG+MS (9) 14,800.00 90.86 333.02 8,386.78 23.35 -3.70 301.20 -3.37 23.30 3.72 5.18 302.46 88.94 147.55 MWD+IFR2+SAG+MS (9) 14,900.00 90.86 333.02 8,385.29 23.48 -3.70 301.38 -3.37 23.44 3.72 5.18 302.64 88.94 147.54 MWD+IFR2+SAG+MS (9) 15,000.00 90.86 333.02 8,383.79 23.62 -3.70 301.57 -3.37 23.58 3.72 5.18 302.84 88.94 147.52 MWD+IFR2+SAG+MS (9) 15,100.00 90.86 333.02 8,382.29 23.77 -3.70 301.77 -3.37 23.72 3.72 5.18 303.05 88.93 147.51 MWD+IFR2+SAG+MS(9) 15,200.00 90.86 333.02 8,380.79 23.92 -3.70 301.99 -3.37 23.88 3.72 5.18 303.28 88.93 147.49 MWD+IFR2+SAG+MS (9) 7/22/2021 2:10:47PM Page 6 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Error Ellipse Report Baker Hughes Company: ConocoPhillips Alaska Inc WNS Local Co-ordinate Reference: Well MT7-01 (GMT2 SW01-107) Project: Western North Slope TVD Reference: 139.5 @ 139.50usft Site: GMT2 Rendezvous Pad MD Reference: 139.5 @ 139.50usft Well: MT7-01 (GMT2 SW01-107) North Reference: True Wellbore: MT7-01 Survey Calculation Method: Minimum Curvature Design: MT7-01-_wp08 Output errors are at 2.00 sigma Database: EDT 15 Alaska Prod Position uncertainty and bias at survey station Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Semi -minor Depth Depth Error Bias Error Bias Error Bias of Bias Error Error Azimuth Tool (usft) (I (I (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (I 15,300.00 90.86 333.02 8,379.29 24.09 -3.70 302.21 -3.37 24.04 3.72 5.18 303.51 88.93 147.48 MWD+IFR2+SAG+MS (9) 15,400.00 90.86 333.02 8,377.80 24.26 -3.70 302.45 -3.37 24.21 3.72 5.18 303.75 88.93 147.47 MWD+IFR2+SAG+MS (9) 15,500.00 90.86 333.02 8,376.30 24.44 -3.70 302.70 -3.37 24.39 3.72 5.18 304.01 88.93 147.45 MWD+IFR2+SAG+MS (9) 15,600.00 90.86 333.02 8,374.80 24.62 -3.70 302.96 -3.37 24.58 3.72 5.18 304.28 88.94 147.44 MWD+IFR2+SAG+MS (9) 15,700.00 90.86 333.02 8,373.30 24.81 -3.70 303.23 -3.37 24.77 3.72 5.18 304.55 88.94 147.43 MWD+IFR2+SAG+MS (9) 15,800.00 90.86 333.02 8,371.81 25.01 -3.70 303.51 -3.37 24.97 3.72 5.18 304.84 88.94 147.42 MWD+IFR2+SAG+MS (9) 15,900.00 90.86 333.02 8,370.31 25.22 -3.70 303.80 -3.37 25.17 3.72 5.18 305.14 88.95 147.41 MWD+IFR2+SAG+MS (9) 16,000.00 90.86 333.02 8,368.81 25.43 -3.70 304.11 -3.37 25.39 3.72 5.18 305.46 88.95 147.40 MWD+IFR2+SAG+MS (9) 16,100.00 90.86 333.02 8,367.31 25.65 -3.70 304.43 -3.37 25.60 3.72 5.18 305.78 88.95 147.39 MWD+IFR2+SAG+MS(9) 16,200.00 90.86 333.02 8,365.82 25.87 -3.70 304.75 -3.37 25.83 3.72 5.18 306.11 88.96 147.38 MWD+IFR2+SAG+MS (9) 16,300.00 90.86 333.02 8,364.32 26.10 -3.70 305.09 -3.37 26.06 3.72 5.18 306.46 88.97 147.37 MWD+IFR2+SAG+MS (9) 16,400.00 90.86 333.02 8,362.82 26.34 -3.70 305.44 -3.37 26.29 3.72 5.18 306.81 88.97 147.36 MWD+IFR2+SAG+MS (9) 16,500.00 90.86 333.02 8,361.32 26.58 -3.70 305.80 -3.37 26.54 3.72 5.18 307.18 88.98 147.35 MWD+IFR2+SAG+MS (9) 16,600.00 90.86 333.02 8,359.82 26.83 -3.70 306.17 -3.37 26.78 3.72 5.18 307.56 88.99 147.35 MWD+IFR2+SAG+MS (9) 16,700.00 90.86 333.02 8,358.33 27.08 -3.70 306.56 -3.37 27.04 3.72 5.18 307.94 89.00 147.34 MWD+IFR2+SAG+MS (9) 16,800.00 90.86 333.02 8,356.83 27.34 -3.70 306.95 -3.37 27.29 3.72 5.18 308.34 89.01 147.33 MWD+IFR2+SAG+MS (9) 16,900.00 90.86 333.02 8,355.33 27.60 -3.70 307.36 -3.37 27.56 3.72 5.18 308.75 89.02 147.33 MWD+IFR2+SAG+MS (9) 17,000.00 90.86 333.02 8,353.83 27.87 -3.70 307.77 -3.37 27.83 3.72 5.18 309.17 89.03 147.32 MWD+IFR2+SAG+MS (9) 17,100.00 90.86 333.02 8,352.34 28.14 -3.70 308.20 -3.37 28.10 3.72 5.18 309.61 89.04 147.32 MWD+IFR2+SAG+MS(9) 17,200.00 90.86 333.02 8,350.84 28.42 -3.70 308.64 -3.37 28.38 3.72 5.18 310.05 89.05 147.31 MWD+IFR2+SAG+MS (9) 17,300.00 90.86 333.02 8,349.34 28.70 -3.70 309.08 -3.37 28.66 3.72 5.18 310.50 89.07 147.31 MWD+IFR2+SAG+MS (9) 17,400.00 90.86 333.02 8,347.84 28.99 -3.70 309.54 -3.37 28.94 3.72 5.18 310.96 89.08 147.31 MWD+IFR2+SAG+MS (9) 17,500.00 90.86 333.02 8,346.35 29.28 -3.70 310.01 -3.37 29.23 3.72 5.18 311.44 89.09 147.30 MWD+IFR2+SAG+MS (9) 17,600.00 90.86 333.02 8,344.85 29.57 -3.70 310.49 -3.37 29.53 3.72 5.18 311.92 89.11 147.30 MWD+IFR2+SAG+MS (9) 17,700.00 90.86 333.02 8,343.35 29.87 -3.70 310.98 -3.37 29.83 3.72 5.18 312.42 89.13 147.30 MWD+IFR2+SAG+MS (9) 17,800.00 90.86 333.02 8,341.85 30.18 -3.70 311.49 -3.37 30.13 3.72 5.18 312.92 89.14 147.30 MWD+IFR2+SAG+MS (9) 17,900.00 90.86 333.02 8,340.35 30.48 -3.70 312.00 -3.37 30.44 3.72 5.18 313.43 89.16 147.30 MWD+IFR2+SAG+MS (9) 18,000.00 90.86 333.02 8,338.86 30.79 -3.70 312.52 -3.37 30.75 3.72 5.18 313.96 89.18 147.30 MWD+IFR2+SAG+MS (9) 18,100.00 90.86 333.02 8,337.36 31.10 -3.70 313.05 -3.37 31.06 3.72 5.18 314.50 89.20 147.30 MWD+IFR2+SAG+MS(9) 18,200.00 90.86 333.02 8,335.86 31.42 -3.70 313.59 -3.37 31.38 3.72 5.18 315.04 89.21 147.30 MWD+IFR2+SAG+MS (9) 18,300.00 90.86 333.02 8,334.36 31.74 -3.70 314.15 -3.37 31.70 3.72 5.18 315.60 89.23 147.30 MWD+IFR2+SAG+MS (9) 18,400.00 90.86 333.02 8,332.87 32.07 -3.70 314.71 -3.37 32.02 3.72 5.18 316.16 89.26 147.30 MWD+IFR2+SAG+MS (9) 18,500.00 90.86 333.02 8,331.37 32.39 -3.70 315.28 -3.37 32.35 3.72 5.18 316.74 89.28 147.30 MWD+IFR2+SAG+MS (9) 18,600.00 90.86 333.02 8,329.87 32.72 -3.70 315.87 -3.37 32.68 3.72 5.18 317.32 89.30 147.30 MWD+IFR2+SAG+MS (9) 18,700.00 90.86 333.02 8,328.37 33.06 -3.70 316.46 -3.37 33.01 3.72 5.18 317.92 89.32 147.30 MWD+IFR2+SAG+MS (9) 18,800.00 90.86 333.02 8,326.88 33.39 -3.70 317.06 -3.37 33.35 3.72 5.18 318.52 89.34 147.31 MWD+IFR2+SAG+MS (9) 18,900.00 90.86 333.02 8,325.38 33.73 -3.70 317.68 -3.37 33.69 3.72 5.18 319.14 89.37 147.31 MWD+IFR2+SAG+MS (9) 19,000.00 90.86 333.02 8,323.88 34.07 -3.70 318.30 -3.37 34.03 3.72 5.18 319.76 89.39 147.31 MWD+IFR2+SAG+MS (9) 19,100.00 90.86 333.02 8,322.38 34.41 -3.70 318.93 -3.37 34.37 3.72 5.18 320.40 89.42 147.32 MWD+IFR2+SAG+MS(9) 19,200.00 90.86 333.02 8,320.88 34.76 -3.70 319.58 -3.37 34.72 3.72 5.18 321.04 89.44 147.32 MWD+IFR2+SAG+MS (9) 19,300.00 90.86 333.02 8,319.39 35.11 -3.70 320.23 -3.37 35.07 3.72 5.18 321.70 89.47 147.33 MWD+IFR2+SAG+MS (9) 19,400.00 90.86 333.02 8,317.89 35.46 -3.70 320.89 -3.37 35.42 3.72 5.18 322.36 89.50 147.33 MWD+IFR2+SAG+MS (9) 19,500.00 90.86 333.02 8,316.39 35.81 -3.70 321.56 -3.37 35.77 3.72 5.18 323.03 89.53 147.34 MWD+IFR2+SAG+MS (9) 19,600.00 90.86 333.02 8,314.89 36.17 -3.70 322.25 -3.37 36.13 3.72 5.18 323.71 89.56 147.34 MWD+IFR2+SAG+MS (9) 19,700.00 90.86 333.02 8,313.40 36.53 -3.70 322.94 -3.37 36.48 3.72 5.18 324.40 89.58 147.35 MWD+IFR2+SAG+MS (9) 19,800.00 90.86 333.02 8,311.90 36.89 -3.70 323.64 -3.37 36.84 3.72 5.18 325.10 89.61 147.36 MWD+IFR2+SAG+MS (9) 19,900.00 90.86 333.02 8,310.40 37.25 -3.70 324.35 -3.37 37.21 3.72 5.18 325.81 89.65 147.36 MWD+IFR2+SAG+MS (9) 20,000.00 90.86 333.02 8,308.90 37.61 -3.70 325.06 -3.37 37.57 3.72 5.18 326.53 89.68 147.37 MWD+IFR2+SAG+MS (9) 20,100.00 90.86 333.02 8,307.41 37.98 -3.70 325.79 -3.37 37.94 3.72 5.18 327.26 89.71 147.38 MWD+IFR2+SAG+MS(9) 20,200.00 90.86 333.02 8,305.91 38.35 -3.70 326.53 -3.37 38.30 3.72 5.18 328.00 89.74 147.39 MWD+IFR2+SAG+MS (9) 20,300.00 90.86 333.02 8,304.41 38.72 -3.70 327.28 -3.37 38.67 3.72 5.18 328.74 89.77 147.39 MWD+IFR2+SAG+MS (9) 20,400.00 90.86 333.02 8,302.91 39.09 -3.70 328.03 -3.37 39.05 3.72 5.18 329.50 89.81 147.40 MWD+IFR2+SAG+MS (9) 20,500.00 90.86 333.02 8,301.41 39.46 -3.70 328.79 -3.37 39.42 3.72 5.18 330.26 89.84 147.41 MWD+IFR2+SAG+MS (9) 20,600.00 90.86 333.02 8,299.92 39.84 -3.70 329.57 -3.37 39.79 3.72 5.18 331.03 89.88 147.42 MWD+IFR2+SAG+MS (9) 7/22/2021 2:10:47PM Page 7 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Error Ellipse Report Baker Hughes Company: ConocoPhillips Alaska Inc WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 (GMT2 SW01-107) Wellbore: MT7-01 Design: MT7-01-_wp08 Position uncertainty and bias at survey station Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well MT7-01 (GMT2 SW01-107) 139.5 @ 139.50usft 139.5 @ 139.50usft True Minimum Curvature 2.00 sigma EDT 15 Alaska Prod Measured Inclination Azimuth Vertical Highside Lateral Vertical Magnitude Semi -major Depth Depth Error Bias Error Bias Error Bias of Bias Error (usft) M M (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) (usft) 20,700.00 90.86 333.02 8,298.42 40.21 -3.70 330.35 -3.37 40.17 3.72 5.18 331.81 20,800.00 90.86 333.02 8,296.92 40.59 -3.70 331.14 -3.37 40.55 3.72 5.18 332.60 20,900.00 90.86 333.02 8,295.42 40.97 -3.70 331.94 -3.37 40.93 3.72 5.18 333.40 21,000.00 90.86 333.02 8,293.93 41.35 -3.70 332.75 -3.37 41.31 3.72 5.18 334.21 21,100.00 90.86 333.02 8,292.43 41.73 -3.70 333.56 -3.37 41.69 3.72 5.18 335.02 21,200.00 90.86 333.02 8,290.93 42.12 -3.70 334.39 -3.37 42.08 3.72 5.18 335.85 21,300.00 90.86 333.02 8,289.43 42.50 -3.70 335.22 -3.37 42.46 3.72 5.18 336.68 21,400.00 90.86 333.02 8,287.94 42.89 -3.70 336.06 -3.37 42.85 3.72 5.18 337.52 21,500.00 90.86 333.02 8,286.44 43.28 -3.70 336.91 -3.37 43.24 3.72 5.18 338.37 21,600.00 90.86 333.02 8,284.94 43.67 -3.70 337.77 -3.37 43.63 3.72 5.18 339.22 21,700.00 90.86 333.02 8,283.44 44.06 -3.70 338.64 -3.37 44.02 3.72 5.18 340.09 21,800.00 90.86 333.02 8,281.94 44.45 -3.70 339.51 -3.37 44.41 3.72 5.18 340.96 21,900.00 90.86 333.02 8,280.45 44.84 -3.70 340.40 -3.37 44.80 3.72 5.18 341.84 22,000.00 90.86 333.02 8,278.95 45.24 -3.70 341.29 -3.37 45.20 3.72 5.18 342.73 22,100.00 90.86 333.02 8,277.45 45.63 -3.70 342.19 -3.37 45.59 3.72 5.18 343.63 22,200.00 90.86 333.02 8,275.95 46.03 -3.70 343.09 -3.37 45.99 3.72 5.18 344.53 22,300.00 90.86 333.02 8,274.46 46.43 -3.70 344.01 -3.37 46.39 3.72 5.18 345.44 22,400.00 90.86 333.02 8,272.96 46.83 -3.70 344.93 -3.37 46.79 3.72 5.18 346.36 22,500.00 90.86 333.02 8,271.46 47.23 -3.70 345.86 -3.37 47.19 3.72 5.18 347.29 22,600.00 90.86 333.02 8,269.96 47.63 -3.70 346.80 -3.37 47.59 3.72 5.18 348.22 22,700.00 90.86 333.02 8,268.47 48.03 -3.70 347.74 -3.37 47.99 3.72 5.18 349.17 22,800.00 90.86 333.02 8,266.97 48.43 -3.70 348.70 -3.37 48.39 3.72 5.18 350.12 22,900.00 90.86 333.02 8,265.47 48.83 -3.70 349.66 -3.37 48.79 3.72 5.18 351.07 23,000.00 90.86 333.02 8,263.97 49.24 -3.70 350.62 -3.37 49.20 3.72 5.18 352.04 23,100.00 90.86 333.02 8,262.47 49.64 -3.70 351.60 -3.37 49.60 3.72 5.18 353.01 23,200.00 90.86 333.02 8,260.98 50.05 -3.70 352.58 -3.37 50.01 3.72 5.18 353.99 23,300.00 90.86 333.02 8,259.48 50.46 -3.70 353.57 -3.37 50.42 3.72 5.18 354.97 23,400.00 90.86 333.02 8,257.98 50.86 -3.70 354.57 -3.37 50.82 3.72 5.18 355.97 23,500.00 90.86 333.02 8,256.48 51.27 -3.70 355.57 -3.37 51.23 3.72 5.18 356.97 23,600.00 90.86 333.02 8,254.99 51.68 -3.70 356.58 -3.37 51.64 3.72 5.18 357.97 23,700.00 90.86 333.02 8,253.49 52.09 -3.70 357.60 -3.37 52.05 3.72 5.18 358.99 23,800.00 90.86 333.02 8,251.99 52.50 -3.70 358.63 -3.37 52.46 3.72 5.18 360.01 23,842.79 90.86 333.02 8,251.35 52.68 -3.70 359.07 -3.37 52.64 3.72 5.18 360.45 Semi -minor Error Azimuth Tool (usft) V) 89.91 147.43 MWD+IFR2+SAG+MS (9) 89.95 147.44 MWD+IFR2+SAG+MS (9) 89.99 147.45 MWD+IFR2+SAG+MS (9) 90.02 147.46 MWD+IFR2+SAG+MS (9) 90.06 147.47 MWD+IFR2+SAG+MS (9) 90.10 147.48 MWD+IFR2+SAG+MS (9) 90.14 147.49 MWD+IFR2+SAG+MS (9) 90.18 147.50 MWD+IFR2+SAG+MS (9) 90.22 147.51 MWD+IFR2+SAG+MS (9) 90.26 147.53 MWD+IFR2+SAG+MS (9) 90.30 147.54 MWD+IFR2+SAG+MS (9) 90.35 147.55 MWD+IFR2+SAG+MS (9) 90.39 147.56 MWD+IFR2+SAG+MS (9) 90.43 147.57 MWD+IFR2+SAG+MS (9) 90.48 147.59 MWD+IFR2+SAG+MS (9) 90.52 147.60 MWD+IFR2+SAG+MS (9) 90.57 147.61 MWD+IFR2+SAG+MS (9) 90.61 147.63 MWD+IFR2+SAG+MS (9) 90.66 147.64 MWD+IFR2+SAG+MS (9) 90.70 147.65 MWD+IFR2+SAG+MS (9) 90.75 147.67 MWD+IFR2+SAG+MS (9) 90.80 147.68 MWD+IFR2+SAG+MS (9) 90.85 147.70 MWD+IFR2+SAG+MS (9) 90.90 147.71 MWD+IFR2+SAG+MS (9) 90.94 147.73 MWD+IFR2+SAG+MS (9) 90.99 147.74 MWD+IFR2+SAG+MS (9) 91.04 147.76 MWD+IFR2+SAG+MS (9) 91.10 147.77 MWD+IFR2+SAG+MS (9) 91.15 147.79 MWD+IFR2+SAG+MS (9) 91.20 147.80 MWD+IFR2+SAG+MS (9) 91.25 147.82 MWD+IFR2+SAG+MS (9) 91.30 147.83 MWD+IFR2+SAG+MS (9) 91.33 147.84 MWD+IFR2+SAG+MS (9) Design Targets Target Name • hittmiss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting Shape V) (I (usft) (usft) (usft) (usft) (usft) Latitude Longitude MT7-01 TD 102720 MS 0.00 0.00 8,251.35 7,595.30-9,216.37 5,923,428.28 1,421,060.64 70' 11' 37.322 N 151' 46' 3.649 W plan hits target center Circle (radius 100.00) MT7-01 IntCsg 102720 0.00 0.00 8,413.42-3,491.79-3,518.18 5,912,187.62 plan misses target center by 2.39usft at 11372.79usft MD (8413.89 TVD,-3493.22 N,-3520.04 E) Circle (radius 100.00) MT7-01_Landing_07162 0.00 0.00 8,429.37-3,095.63-3,769.09 5,912,590.59 plan hits target center Point 1,426,448.12 70' 9' 48.323 N 151 ° 43' 18.228 W 1,426,208.34 70' 9' 52.219 N 151 ° 43' 25.501 W 7/22/2021 2:10:47PM Page 8 COMPASS 5000.15 Build 91E ConocoPhillips ConocoPhillips Error Ellipse Report Baker Hughes Company: ConocoPhillips Alaska Inc WNS Project: Western North Slope Site: GMT2 Rendezvous Pad Well: MT7-01 (GMT2 SW01-107) Wellbore: MT7-01 Design: MT7-01-_wp08 Casing Points Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Well MT7-01 (GMT2 SW01-107) 139.5 @ 139.50usft 139.5 @ 139.50usft True Minimum Curvature 2.00 sigma EDT 15 Alaska Prod Measured Vertical Casing Depth Depth Diameter (usft) (usft)mi Name (in) 3,484.57 3,093.00 Surface Csg 13.375 16.000 10,865.33 8,310.48 Intermediate Csg 7.625 11.000 Formations Measured Vertical Dip Depth Depth 7w Dip Direction (usft) (usft) Lithology (°) (°) 949.68 949.50 Base of Permafrost Empty 1,412.73 1,407.28 C40 Empty 1,679.58 1,662.79 C30 Empty 2,065.41 2,012.59 C10 Empty 3,416.08 3,042.62 K3 Empty 4,240.61 3,649.07 Albian 97 Empty 4,556.42 3,881.35 Albian 96 Empty 4,801.25 4,061.42 Albian 95 Empty 5,674.11 4,703.42 Albian 94 Empty 6,132.71 5,040.72 Albian 93 Empty 7,881.73 6,328.22 Albian 92 Empty 9,248.64 7,407.52 HRZ Empty 9,584.87 7,652.52 LCU Empty 10,906.30 8,322.38 Alpine C/TPI Empty Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (usft) (usft) (usft) (usft) Comment 700.00 700.00 0.00 0.00 Start Build 1.50 800.00 799.99 -1.24 -0.43 Start Build 2.00 1,100.00 1,099.23 -20.18 -6.99 Start DLS 2.50 TFO 37.83 2,591.71 2,436.29 -588.27 -203.82 Start 5196.97 hold at 2591.71 MD 7,788.68 6,258.73 -3,915.20 -1,356.63 Start DLS 3.00 TFO 120.43 11,435.38 8,419.72 -3,442.32 -3,555.98 Start 200.00 hold at 11435.38 MD 11,635.38 8,427.97 -3,273.85 -3,663.28 Start 20.00 hold at 11635.38 MD 11,655.38 8,428.10 -3,256.66 -3,673.49 Start DLS 2.50 TFO 59.86 12,118.68 8,426.94 -2,852.05 -3,898.78 Start 11986.87 hold at 12118.68 MD 24,105.56 TO at 24105.55 Checked By: Approved By: Date: Hole Diame 7/22/2021 2:10:47PM Page 9 COMPASS 5000.15 Build 91E From:Anderson, Nina M To:Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]GMT MT7-01(PTD 221-052) Surface casing kick tolerance calculations Date:Sunday, August 15, 2021 10:09:56 AM Attachments:MT7-01 KT Surface_08_13_21.xlsx Victoria – Attached is the kick tolerance spreadsheet for MT7-01. Please let me know if you have any questions. Thanks. Nina Anderson Alpine Staff Drilling Engineer ConocoPhillips Alaska nina.anderson@conocophillips.com Office: (907) 265-6403 Cell: (907) 229-4008 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Thursday, August 5, 2021 9:48 AM To: Anderson, Nina M <Nina.Anderson@conocophillips.com> Subject: [EXTERNAL]GMT MT7-01(PTD 221-052) Surface casing kick tolerance calculations CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Nina, Please send kick tolerance calculations for the surface casing shoe. 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@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 MT7-01 KT Surface_08_13_21 (002).xlsx 4/13/2022 11:04 AM Well: MT7-01 <== Data Input Name: Nina Anderson <== Data Input Mud Weight (ppg) 9.50 <== Data Input Weak point or LOT - Measured depth (ft) 3,484'<== Data Input Weak point or LOT True vertical depth (ft) 3,093'<== Data Input Weak point or LOT - Hole angle (deg) 42.7º<== Data Input Weak point or LOT - Hole size (in) 11.000"<== Data Input Weak point pressure or LOT - EMW (ppg) 12.00 <== Data Input Zone of interest - Measured depth (ft) 10,865'<== Data Input Zone of interest - True vertical depth (ft) 8,310'<== Data Input Zone of interest - Hole angle (deg) 73.0º<== Data Input Zone of interest - Hole size (in) 11.000"<== Data Input Zone of interest - Pore pressure EMW (ppg) 9.40 <== Data Input Gas gradient (psi/ft) 0.10 <== Data Input Bottom hole assembly OD (in) 6.750"<== Data Input Bottom hole assembly length (ft)300'<== Data Input Drill pipe OD (in) 5.000"<== Data Input BHA annular vol. @ zone of interest (bbl/ft)0.0733 DP annular vol. @ zone of interest (bbl/ft)0.0933 DP annular vol. @ weak point (bbl/ft)0.0933 Additional safety margin (psi) 0.00 <== Data Input Weak point pressure (psi):Plo 1,930 psi Weak point pressure - Safety margin:Pmax 1,930 psi Pmax EMW 12.00 ppg Max anticipated formation pressure (psi):Pf 4,062 psi Weak Pt to Zone of Interest distance (TVD ft):OH {TVD}5,217' Weak Pt to Zone of Interest distance (MD ft):OH {MD}7,381' Maximum influx height at the bit (TVD ft):H {TVD}1,130' Maximum influx height at the bit (MD ft):H {MD}3,866' Calc. volume of {H} around BHA:V1bha 22.0 bbl Calc. volume of {H} around drill pipe:V1dp 332.5 bbl Calc. volume that H equals @ initial shut in:V1 354.5 bbl Calc. vol. that H equals @ weak point (MD ft):Vwp 143.3 bbl Calc. volume of Vwp @ initial shut in:V2 68.1 bbl Kick Tolerance: V2 68.1 bbl NOTE: Spreadsheet revised by: G. S. Walz 3/9/99 TRANSMITTAL LETTER CHECKLIST WELL NAME: MT7-01 PTD: 221-052 X Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: GMTU2 POOL: Rendezvous Oil 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 Pilot Hole well 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. Spacing Approval to produce/inject is contingent upon issuance of Exception a conservation order approving a spacing exception. ( ) as 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- well ( ) until after ( ) Conventional has designed and implemented a water well testing program to provide Well baseline data on water quality and quantity. ( ) 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 X of well logs to be run. In addition to the well logging program proposed by ( ) 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 X within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool GRTR MOOSES TOOTH, RENDEZV OIL - 2822 Company ConocoPhillips Alaska, Inc. Initial Class/Type Well Name: GMTU MT7-01 Program DEV Well bore seg ElPTD#:2210520 DEV / PEND GeoArea 890 Unit 10750 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate- - - - Yes 3 Unique well name and number Yes 4 Welllocatedinadefinedpool-------------------------------------- Yes--------------------------------------------------------------------------- 5 Well located proper distance_from- drilling unit boundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 6 Well located proper distance from other wells_ Yes 7 Sufficient acreage available in drilling unit- - - - - Yes 8 -If-deviated, is_we_llbore plat -included No - - - - - Land plat not included._ Directional_ plan view included._ 9 Operator onlyaff_ectedparty--------------------------------------- Yes--------------------------------------------------------------------------- 10 Operator has appropriate -bond in force- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes - - - 13 Can permit be approved before 15-day wait_ - - - - - - - - - - Yes DLB 8/2/2021 14 Well located within area and strata authorized by -Injection Order # (put_10# in -comments) -(For NA- - - - 15 All wells within 1/4_mile area of review identified (For service well only_) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre -produced injector; duration of pre production less_than_3 months_(For service well only) _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2_.A-D) - - - - - - NA_ 18 Conductor string -provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - W conductor driven _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Engineering 19 Surface casing protects all known_ USDWs Yes Surface casing set to 3444' MD 20 CMT_vol adequate to circulate on conductor_& surf csg Yes - - - - - - - 225%-excess - - - 21 CMT_vol _adequate _to tie-in long string to surf csg_ - - No 22 CMT_will cover all known productive horizons- - - - - - - - - - - - - - - - - - - - - - - - - - - - - No_ - - - - - - - Prod uctiv_e_interval will be completed with_uncemented perforated joints- - - - - - - - - - - - - - - - - - - - - - - - 23 Casing designs adequate for O, T, B & permafrost Yes - - - - - - 24 Adequate tankage or reserve pit _ Yes _ _ _ _ _ _ Rig has steel tanks; all -waste -to approved disposal wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 If a re -drill, has a 10-403 for abandonment been approved NA_ 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete. _No_ major risk failures_ 27 If diverter required, does it _meet_ regulations Yes - - - - - - - Diverter waived per 20 AAC_ 25.035(h)(2)- - - - - - - - - - - - - - - - - Appr Date 28 Drilling fluid program schematic &_ equip list adequate _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Max reservoir pressure is 3945_psi(8.9 ppg_EMW); will -drill- w/ 8.8-11.2 ppg EMW VTL 8/10/202, 29 BOPEs,_do-they meet_regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 BOPE_press rating appropriate; test to (put psig in comments)_ - - - - - - - - - - - Yes MPSP is 3093 psi; will test BOPS to 3500 psig_ - - - - - - - 31 Choke_ manifold complies w/API_RP-53(May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable No 34 Mechanical condition of wells within AOR verified (For -service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ _ _ _ _ _ _ _ _ _ _ _ 35 Permit can be issued w/o hydrogen_sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ New field w/o H2S at early stage of development. Geology 36 Data -presented on potential overpressure zones Yes Appr Date 37 Seismic analysis_ of shallow gas_zones- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - DLB 8/2/2021 38 Seabed condition survey (if off -shore) - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA 39 Contact name/phone for weekly_progress reports -[exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date JLC 8/26/2021 JMP 8/26/21