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Home My WebLink About220-073MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. CD5-93 COLVILLE RIV UNIT CD5-93 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 CD5-93 50-103-20827-00-00 220-073-0 W SPT 7451 2200730 1863 824 824 821 821 272 418 379 361 4YRTST P Austin McLeod 9/10/2023 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:COLVILLE RIV UNIT CD5-93 Inspection Date: Tubing OA Packer Depth 90 2210 2110 2100IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230911184223 BBL Pumped:5.4 BBL Returned:5.4 Tuesday, October 17, 2023 Page 1 of 1          1 Regg, James B (OGC) From:NSK DHD Field Supervisor <n2238@conocophillips.com> Sent:Monday, August 7, 2023 11:14 AM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:WNS Integrity Subject:CPAI 10-426 form for Non-witnessed shut in tests on CD5-90 and 93 on 8/6/23 Attachments:MIT CRU CD5-90 and 93 SI TESTS 08-06-23.xlsx Please see the attached 10‐426 form for Non‐witnessed shut in MIT‐IA’s that were performed at CD5 pad on 8/6/23. Please let me know if you have any questions or concerns. Thank you, Shelby Sumrall / Bruce Richwine DHD Field Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659‐7022 Cell phone: (907) 943‐0167 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. CRU CD5-93PTD 2200730 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2191890 Type Inj N Tubing 542 544 544 544 Type Test P Packer TVD 7184 BBL Pump 3.1 IA 170 2200 2140 2130 Interval 4 Test psi 1796 BBL Return 3.1 OA 38 43 44 43 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2200730 Type Inj N Tubing 4 11 14 14 Type Test P Packer TVD 7451 BBL Pump 4.4 IA 510 2200 2110 2095 Interval 4 Test psi 1863 BBL Return 4.3 OA 263 376 355 342 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Alpine / CRU / CD5 PAD Miller 08/06/23 Notes: Notes: CD5-90 CD5-93 Notes: Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2023-0806_MIT_CRU_CD5-93      J. Regg; 10/12/2023  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: _________________ CD5-93 Sonic TOC PTD: 220-073 T36543 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.03 08:46:49 -08'00' ! ""# $% &' $' () *+ % , - -. ' '- $/+ 0*'+ '- !1 ' ! !-.- 0 /- +' ''!'0* + +' ' 0&+''-&#2" (1- 0 , * 23# .0 * % &#2"23 ,0045 ! 6""#2 ,%"2 233" Digitally signed by Jenna Taylor DN: C=US, CN=Jenna Taylor, E=jenna.l.taylor@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2022.01.10 10:14:45-09'00' Foxit PDF Editor Version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igitally signed by Jenna TaylorDN: C=US, CN=Jenna Taylor, E=jenna.l.taylor@conocophillips.comReason: I am the author of this documentLocation: your signing location hereDate: 2022.01.10 10:16:07-09'00'Foxit PDF Editor Version: 11.0.0 RBDMS HEW 1/12/2022 October 14, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Third Quarter, 2021 To whom it may concern: Please find attached the third quarter 2021 annular disposal reports for active Colville River Unit wells. This report shows the volumes disposed into surface casing by production casing annuli during first quarter of 2021. Unfortunately, there were no disposal operations in the reporting period. There is one well with an open annular disposal sundry. An AD sundry was approved for CD5-93 in February of 2021. Doyon 25 operated on the MT7 Pad for the entire third quarter. Future sundries will follow for drilling operations on the MT7 Pad. Please call Jenna Taylor at 263-4522 should you have any questions. Sincerely, Jenna Taylor Senior Wells Analyst Attachments: CD5-93 10-423 Jenna Taylor Senior Wells Analyst Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4749 Digitally signed by Jenna Taylor DN: C=US, CN=Jenna Taylor, E=jenna.l.taylor@conocophillips. com Reason: I am the author of this document Location: your signing location here Date: 2021.10.14 10:50:34-08'00' Foxit PDF Editor Version: 11.0.0 220-0737. Well Name:5a. Sundry Number:321-08210 (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added.(h)(2) drill rig wash fluids and drill rig domestic waste water(h)(3) Other Commission approved substances (include descriptions in block 12)Volume (bbls): Number of days disposal occurred:Disposal Beginning Dates:Disposal Ending Dates:Source Wells:Previous totals (bbls):2021/Q122078298.001 01/31/21 01/31/21 Initial Water Flush and Freeze Protect2021/Q2000.0002021/Q3000.0002021Q4Total Ending Volume (bbls):220.000.0078.00298.00 1.00 Other (Explain) Title: Senior Wells Analyst Contact Phone: 907-263-4522Certified Signature:Contact Email: jenna.l.taylor@cop.comReport is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter.The report will be submitted each quarter, even with zero volumes, until the application expires.Date of Revision:I hereby certify that the foregoing is true and correct to the best of my knowledge.Name: Jenna TaylorRevision? 12. Remarks and Approved SubstancesDescription(s):Diesel Freeze Protect11. Attach Required Disposal Performance Data: Pressure vs. Time Step Rate Test Ball Mill Injection Record noting initial and highest pressure noted during pumping.Initial Disposal Continuation Final4a. Well Class: Stratigraphic Service GINJ WINJ WDSPL STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONREPORT OF ANNULAR DISPOSALDevelopment Exploratory6. Permit to Drill Number:8. API Number:1. Operator:5b. Sundry approval date:2/17/20219. Field: Colville River Unit - Alpine Field3. (Check one box only)ConocoPhillips Alaska, Inc.2. Address:4b. Well Status: Oil Gas WAG 50-103-20827-00-00CD5-93PO Box 100360, Anchorage, Alaska Exploratory Service Gas WAG WINJ WDSPL Form 10-423 Revised 3/2021 20 AAC 25.080(f)Submit in PDF format to aogcc.reporting@alaska.govDigitally signed by Jenna TaylorDN: C=US, CN=Jenna Taylor, E=jenna.l.taylor@conocophillips.comReason: I am the author of this documentLocation: your signing location hereDate: 2021.10.14 10:52:26-08'00'Foxit PDF Editor Version: 11.0.0RBDMS HEW 10/26/2021 July 12, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, Second Quarter, 2021 To whom it may concern: Please find attached the second quarter 2021 annular disposal reports for active Colville River Unit wells. This report shows the volumes disposed into surface casing by production casing annuli during first quarter of 2021. Unfortunately, there were no disposal operations in the reporting period. There is one well with an open annular disposal sundry. An AD sundry was approved for CD5-93 in February of 2021. The annulus was not used for primary disposal because the long distance to the well from CD5-31 presented freezing concerns. Future sundries will follow for drilling operations on the MT7 Pad. Please call Jenna Taylor at 263-4522 should you have any questions. Sincerely, Jenna Taylor Wells Technician Attachments: CD5-93 10-423 Jenna Taylor Wells Technician Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4749 Digitally signed by 4b05089e-b090-4fb0-9bb3-410505d45d8 a DN: CN=4b05089e-b090-4fb0-9bb3-410505d 45d8a Reason: I am the author of this document Location: your signing location here Date: 2021.07.12 13:54:30-08'00' Foxit PhantomPDF Version: 10.1.3 220-0737. Well Name:5a. Sundry Number:321-08210 (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added.(h)(2) drill rig wash fluids and drill rig domestic waste water(h)(3) Other Commission approved substances (include descriptions in block 12)Volume (bbls): Number of days disposal occurred:Disposal Beginning Dates:Disposal Ending Dates:Source Wells:Previous totals (bbls):2021/Q122078298.001 01/31/21 01/31/21 Initial Water Flush and Freeze Protect2021/Q2000.0002021/Q32021Q4Total Ending Volume (bbls):220.000.0078.00298.00 1.00 Other (Explain) 2. Address:4b. Well Status: Oil Gas WAG 50-103-20827-00-00CD5-93PO Box 100360, Anchorage, AlaskaInitial Disposal Continuation Final4a. Well Class: Stratigraphic Service GINJ WINJ WDSPL STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSIONREPORT OF ANNULAR DISPOSALDevelopment Exploratory6. Permit to Drill Number:8. API Number:1. Operator:5b. Sundry approval date:2/17/20219. Field: Colville River Unit - Alpine Field3. (Check one box only)ConocoPhillips Alaska, Inc.Title: Wells TechnicianContact Phone: 907-263-4522Certified Signature:Contact Email: jenna.l.taylor@cop.comReport is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter.The report will be submitted each quarter, even with zero volumes, until the application expires.Date of Revision:I hereby certify that the foregoing is true and correct to the best of my knowledge.Name: Jenna TaylorRevision? 12. Remarks and Approved SubstancesDescription(s):Diesel Freeze Protect11. Attach Required Disposal Performance Data: Pressure vs. Time Step Rate Test Ball Mill Injection Record noting initial and highest pressure noted during pumping. Continuation Final Exploratory Service Gas WAG WINJ WDSPL Form 10-423 Revised 3/2021 20 AAC 25.080(f)Submit in PDF format to aogcc.reporting@alaska.govDigitally signed by 4b05089e-b090-4fb0-9bb3-410505d45d8aDN: CN=4b05089e-b090-4fb0-9bb3-410505d45d8aReason: I am the author of this documentLocation: your signing location hereDate: 2021.07.12 13:59:12-08'00'Foxit PhantomPDF Version: 10.1.3e:RBDMS HEW 7/13/2021 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20827-00-00Well Name/No. COLVILLE RIVER UNIT CD5-93Completion StatusWAGINCompletion Date2/13/2021Permit to Drill2200730Operator ConocoPhillips Alaska, Inc.MD26177TVD7327Current StatusWAGIN5/26/2021UICYesWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR, Res, PWD, Sonic, Neu, DensityNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF4/7/202114209 13290 Electronic Data Set, Filename: CD5-93_MFC_18FEB21_Centered.las34914EDDigital DataDF4/7/202114209 13290 Electronic Data Set, Filename: CD5-93_MFC_18FEB21_Uncentered.las34914EDDigital DataDF4/7/2021 Electronic File: CD5-93_MFC_18FEB21.pdf34914EDDigital DataDF4/7/2021 Electronic File: CD5-93_MFC_18FEB21_img.tiff34914EDDigital Data0 0 2200730 COLVILLE RIVER UNIT CD5-93 LOG HEADERS34914LogLog Header ScansDF5/25/2021111 26176 Electronic Data Set, Filename: CPAI_CD5-93_FE COMP_MEM.las35160EDDigital DataDF5/25/2021################Electronic Data Set, Filename: CPAI_CD5-93_RUN 01_AP_MEM_UNIX.las35160EDDigital DataDF5/25/2021################Electronic Data Set, Filename: CPAI_CD5-93_RUN 02_AP_MEM_UNIX.las35160EDDigital DataDF5/25/2021################Electronic Data Set, Filename: CPAI_CD5-93_RUN 03_AP_MEM_UNIX.las35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_2MD_MEM.cgm35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_2TVD_MEM.cgm35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_5MD_MEM.cgm35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_5TVD_MEM.cgm35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_AP-TIME_MEM.cgm35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_RUN 01_AP_MEM.ASC35160EDDigital DataWednesday, May 26, 2021AOGCCPage 1 of 3CPAI_CD5-,93_FE COMP_MEM.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20827-00-00Well Name/No. COLVILLE RIVER UNIT CD5-93Completion StatusWAGINCompletion Date2/13/2021Permit to Drill2200730Operator ConocoPhillips Alaska, Inc.MD26177TVD7327Current StatusWAGIN5/26/2021UICYesWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalDF5/25/2021 Electronic File: CPAI_CD5-93_RUN 02_AP_MEM.ASC35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_RUN 03_AP_MEM.ASC35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_2MD_MEM.PDF35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_2TVD_MEM.PDF35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_5MD_MEM.PDF35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_5TVD_MEM.PDF35160EDDigital DataDF5/25/2021 Electronic File: CPAI_CD5-93_AP-TIME_MEM.PDF35160EDDigital DataDF5/25/2021 Electronic File: CD5-93_NAD 27_Compass Surveys_Canvas_03092021.txt35160EDDigital DataDF5/25/2021 Electronic File: CD5-93_NAD 27_Compass Surveys_Macro_03092021.txt35160EDDigital DataDF5/25/2021 Electronic File: CD5-93_NAD 27_Compass Surveys_Petrel_03092021.txt35160EDDigital DataDF5/25/2021 Electronic File: CD5-93_NAD 27_Compass Surveys_Surveys_03092021.txt35160EDDigital DataDF5/25/2021 Electronic File: CD5-93_NAD 27_Definitive Survey Report_03092021.pdf35160EDDigital DataDF5/25/2021 Electronic File: CD5-93_NAD 83_Compass Surveys_Canvas_03092021.txt35160EDDigital DataDF5/25/2021 Electronic File: CD5-93_NAD 83_Compass Surveys_Macro_03092021.txt35160EDDigital DataDF5/25/2021 Electronic File: CD5-93_NAD 83_Compass Surveys_Petrel_03092021.txt35160EDDigital DataDF5/25/2021 Electronic File: CD5-93_NAD 83_Compass Surveys_Surveys_03092021.txt35160EDDigital DataDF5/25/2021 Electronic File: CD5-93_NAD 83_Definitive Survey Report_03092021.pdf35160EDDigital Data0 0 2200730 COLVILLE RIVER UNIT CD5-93 LOG HEADERS35160LogLog Header ScansWednesday, May 26, 2021AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-103-20827-00-00Well Name/No. COLVILLE RIVER UNIT CD5-93Completion StatusWAGINCompletion Date2/13/2021Permit to Drill2200730Operator ConocoPhillips Alaska, Inc.MD26177TVD7327Current StatusWAGIN5/26/2021UICYesINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date:2/13/2021Release Date:12/18/2020Wednesday, May 26, 2021AOGCCPage 3 of 3M. Guhl5/26/2021 1058 Baker Hughes Drive Broussard,LA 70518,USA May AOGCC Attention: 333 W.7th Ave.,Suite 100 Anchorage,Alaska 99501 Subject: The final deliverables were uploaded via Items delivered:MWD/LWD Thankyou. Signature of receiver Please return transmittal letter to: Garrett Brown Garrett.Brown@conocophillips.com Melissa LeMay Melissa.LeMay@bakerhughes.com T + 1 337.856- 1058 Baker Hughes Drive Broussard,LA 70518,USA May 25,2021 AOGCC Attention:Natural Resources Technician 333 W.7th Ave.,Suite 100 Anchorage,Alaska 99501 Subject: The final deliverables were uploaded via Items delivered:MWD/LWD Thankyou. Signature of receiver Please return transmittal letter to: Garrett Brown Garrett.Brown@conocophillips.com Melissa LeMay Melissa.LeMay@bakerhughes.com -7201 1058 Baker Hughes Drive Broussard,LA 70518,USA Natural Resources Technician 333 W. 7th Ave.,Suite 100 Anchorage,Alaska 99501 The final deliverables were uploaded via Items delivered:MWD/LWD Signature of receiver &date received Please return transmittal letter to: Garrett Brown Garrett.Brown@conocophillips.com Melissa LeMay Melissa.LeMay@bakerhughes.com Natural Resources Technician Anchorage,Alaska 99501-3539 Final Log Distribution for CD5- Colville River Unit North Slope Borough, Alaska API #: Permit No: 220 Rig: The final deliverables were uploaded via Items delivered:MWD/LWD Digital Las & date received Please return transmittal letter to: Garrett.Brown@conocophillips.com Melissa.LeMay@bakerhughes.com Natural Resources Technician Final Log Distribution for -93 Colville River Unit North Slope Borough, Alaska API #:50-103-20827 Permit No: 220-073 Rig:Doyon 25 The final deliverables were uploaded via https://copsftp.sharefile.com/ Las Data,Graphic Images & date received: Final Log Distribution for ConocoPhillips Alaska, Colville River Unit North Slope Borough, Alaska 20827-00 073 https://copsftp.sharefile.com/ Data,Graphic Images CGM/PDF and SurveyFiles ConocoPhillips Alaska, North Slope Borough, Alaska https://copsftp.sharefile.com/for the above wells. CGM/PDF and SurveyFiles ConocoPhillips Alaska,Inc. for the above wells. CGM/PDF and SurveyFiles for the above wells. CGM/PDF and SurveyFiles PTD: 2200730 E-Set: 35160 Received by the AOGCC 05/25/2021 05/25/2021 MEMORANDUM TO: Jim Regg 2ef`f 5/N/'4G P.I. Supervisor C l FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Monday, April 26, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. CD5-93 COLVILLE RIVER UNIT CD5-93 Ste: Inspector Reviewed By: P.I. Supry Jur — Comm Well Name COLVILLE RIVER UNITC135-93 API Well Number 50-103-20827-00.00 Inspector Name: Bob Noble Permit Number: 220-073-0 Inspection Date: 4/15/2021 Insp Num: mhRCNzloazoloossz Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well cn5-93 Type Inj I w - TVD 7451 Tubing 1166 _ 1166 1167 1167 PTD 2200730 - Type Test SPT est psi 1863 - IA 630 2200 - 2110 _ 2100 - BBL Pumped: 3.9 1 BBL Returned: 3.8 OA 277 - 373 - 347 _ 331 Interval MITAL ✓ P/F P Notes: Monday, April 26, 2021 Page 1 of 1 April 14, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Annular Disposal Reports, First Quarter, 2021 To whom it may concern: Please find attached the first quarter 2021 annular disposal reports for active Colville River Unit wells. This report shows the volumes disposed into surface casing by production casing annuli during first quarter of 2021. Unfortunately, there were no disposal operations in the reporting period. There are two wells with open annular disposal sundries. CD5-26, a well that never allowed disposal after initial flush and freeze protect. Periodic injectivity tests confirmed its lack of disposal capability, and it expired in March of 2021. An AD sundry was approved for CD5-93 in February of 2021 in an appreciated rush request by me. The approved sundry allowed disposal contingency of CD5-31 wastes if the CD1-01A disposal well had issues. The annulus was not used for primary disposal as a long term flowback of the well was occurring with external equipment, and the long distance to the well from CD5-31 presented freezing concerns. Future sundries will follow for drilling operations on the MT7 Pad. Doyon 25 is drilling its first well there following CD5-31. Please call Greg Hobbs at 263-4749 should you have any questions. Sincerely, G. S. Hobbs Regulatory Engineer Attachments: CD5-26 10-423 CD5-93 10-423 CD5-93 Annular Injection Log G. S. Hobbs Regulatory Engineer Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4749 Digitally signed by Greg Hobbs DN: OU=Regulatory Engineer, O=ConocoPhillips Wells, CN=Greg Hobbs, E=greg.s.hobbs@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.04.15 17:14:41-08'00' Foxit PhantomPDF Version: 10.1.0 Greg Hobbs 220-073 7. Well Name: 5a. Sundry Number: 321-082 10 (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added. (h)(2) drill rig wash fluids and drill rig domestic waste water (h)(3) Other Commission approved substances (include descriptions in block 12) Volume (bbls):Number of days disposal occurred: Disposal Beginning Dates: Disposal Ending Dates: Source Wells: Previous totals (bbls): 2021/Q1 220 78 298.00 1 01/31/21 01/31/21 Initial Water Flush and Freeze Protect 2021/Q2 2021/Q3 2021Q4 Total Ending Volume (bbls): 220.00 0.00 78.00 298.00 1.00 Other (Explain) 2. Address:4b. Well Status: Oil Gas WAG 50-103-20827-00-00 CD5-93 PO Box 100360, Anchorage, Alaska Initial Disposal Continuation Final 4a. Well Class: Stratigraphic Service GINJ WINJ WDSPL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL Development Exploratory 6. Permit to Drill Number: 8. API Number: 1. Operator: 5b. Sundry approval date: 2/17/2021 9. Field:Colville River Unit - Alpine Field3. (Check one box only) ConocoPhillips Alaska, Inc. Title: Regulatory Engineer Contact Phone: 907-263-4749Certified Signature: Contact Email: greg.s.hobbs@cop.com Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter. The report will be submitted each quarter, even with zero volumes, until the application expires. Date of Revision: I hereby certify that the foregoing is true and correct to the best of my knowledge. Name: Greg Hobbs Revision? 12. Remarks and Approved Substances Description(s): Diesel Freeze Protect 11. Attach Required Disposal Performance Data: Pressure vs. Time Step Rate Test Ball Mill Injection Record noting initial and highest pressure noted during pumping. Form 10-423 Revised 3/2021 20 AAC 25.080(f)Submit in PDF format to aogcc.reporting@alaska.gov RBDMS HEW 5/3/2021 Injecting into well: TONY KELLEY GRANT ROSKOS CONOCOPHILLIPS SUPERVISORDOWELL INJECTION SUPERVISOR CONOCOPHILLIPS-DAILY ANNULAR INJECTION RECORD DATE CD5-93 RIG #: 0000 HRS 7.6 220 78 305.6 0 305.6 TOTAL VOLUMES FOR DAY: D-25 D-25 H2O H2O ULSD 3.8 3.8 170 50 78 3.8 3.8 170 50 78 10.6 10.6 8.3 8.3 6.8 55 27 27 24 LOT LOT Water Flush Water Flush Freeze Protect BARRELS INJECTED ( List under Proper fluid Type) FOR MUD ONLY MUD TOTAL FOR TODAY Cummulative Total from Previous Day New TotalWATERDIESELOTHER 1940 2000 2015 2120 2220 1950 2010 2120 2220 2300 .5 .5 3.5 2.6 2 0 0 0 0 610 380 400 900 880 910 2359 HRS 1-31-20211-31-2021 to PAGE_____of ______ WASH WATER DOYON 25 MUD WATER for Overflushing WELL DIESEL for Freeze Protecting OTHER (Specify) TOTAL Cummulative Volume Weight (PPG) Funnel Viscosity CommentsStop Time Origin Of Fluids Start Time PUMP RATE (BPM) Static Pressure (PSI) Injection Pressure (PSI) Operation that generated Waste MUD Rig Wash Water 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 ID ID Wt Visc 600 300 Temp % Solids NIGHT INJECTION SUPERVISOR DAY INJECTION SUPERVISOR ID Wt Visc 600 300 Temp %Solids RPM Fluid Properties RPM RPM ID Wt Visc 600 300 Temp %Solids Water Based Mineral Oil BasedWater Based 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Temporary convert to production ConocoPhillips Alaska, Inc. Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 26,177 feet N/A feet true vertical 7,255 feet N/A feet Effective Depth measured 26,177 feet 14,246 feet true vertical 7,255 feet 7,451 feet Perforation depth Measured depth 14,828 - 16,482 feet True Vertical depth 7,476 - 7,524 feet Tubing (size, grade, measured and true vertical depth) 4.5" L-80 16,493' 7,476' Packers and SSSV (type, measured and true vertical depth) Packer Baker Premiere 14,246' 7,451' SSSV MCX Injection Valve 2,511' 2,498' 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: David Neville Contact Name:David Neville Authorized Title:Staff Production Engineer Contact Email:David.J.Neville@conocophillips.com Contact Phone:907-265-6220 WINJ WAG 1162 Water-Bbl MD 120' 2,194' 14,527' 2824 Oil-Bbl measured true vertical Packer P.O. Box 100360, Anchorage, AK 99510-03603. Address: 4. Well Class Before Work: 267 Representative Daily Average Production or Injection Data 4231012 Casing Pressure Tubing Pressure ASRC-NPR4, ASRC-NPR3, ASRC-NPR2, ASRC-NPR1 1686 1632 CRU CD5-93 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 220-073 50-103-20827-00-00 N/A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) N/A Gas-Mcf measuredPlugs Junk measured N/A 5. Permit to Drill Number: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1015 Size Colville River Unit / Alpine Pool Surface Intermediate Authorized Signature with date: Authorized Name: Length 82' 2,155' 14,490' Casing Conductor 42" 13.5" 9.875" TVD 120' 2,188' 7,475' Burst 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse Development Service GINJ SUSP SPLUG Gas WINJ WAG Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Digitally signed by David Neville DN: OU=North Slope Development, O=ConocoPhillips Alaska Inc., CN=David Neville, E=david.j.neville@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2021.04.13 14:27:07-08'00' Foxit PhantomPDF Version: 10.1.0 David Neville By Samantha Carlisle at 2:40 pm, Apr 13, 2021 RBDMS HEW 4/15/2021 7327 VTL 5/5/21 DSR-4/14/21 SFD 4/15/2021 SFD 4/15/2021 Last Tag Annotation Depth (ftKB)End Date Wellbore Last Mod By LAST TAG:CD5-93 jennalt Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Normal Up for Injection 4/2/2021 CD5-93 boehmbh Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 38.1 Set Depth (ftKB) 120.0 Set Depth (TVD)… 120.0 Wt/Len (l… 94.00 Grade Top Thread Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 38.9 Set Depth (ftKB) 2,194.1 Set Depth (TVD)… 2,187.9 Wt/Len (l… 45.50 Grade L-80 Top Thread TXP-M Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.88 Top (ftKB) 37.2 Set Depth (ftKB) 14,526.7 Set Depth (TVD)… 7,474.5 Wt/Len (l… 29.70 Grade L80 Top Thread TXPM Tubing Strings Tubing Description TUBING String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 35.0 Set Depth (ft… 16,492.9 Set Depth (TVD) (… 7,475.8 Wt (lb/ft) 12.60 Grade L-80 Top Connection TS Blue Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des Com Nominal ID (in) 35.0 35.0 0.00 HANGER FMC 4-1/2" Tubing Hanger Hydril HYD 563 Min ID 3.92" 3.958 2,511.2 2,497.9 12.83 NIPPLE NIPPLE,LANDING,4 1/2",X,3.813" 3.813 14,246.2 7,451.4 84.78 PACKER Baker Premier Packer, TC-II for 29.7# (~14,250' MD)3.850 14,314.5 7,457.4 84.98 NIPPLE XN LANDING Nipple ,4 1/2",XN, 3.725", TSBlue 3.813 14,374.5 7,462.7 85.01 NIPPLE Baker Hydrotrip Ball Seat, 4 1/2", 12.6#, L80 2.810 16,492.4 7,475.8 89.85 FLOAT SHOE NS Dissolving Shoe 3.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in)SN 2,511.0 2,497.7 12.83 INJ VALVE 4.5" MCX Inj Valve on 3.812" X Lock 4/2/2021 1.563 0004042783-3 Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB)Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in)Serv Valve Type Latch Ty pe Port Size (in) TRO Run (psi)Run Date Com 1 5,658.5 4,346.4 Camco KBMG/ 11141- 11BVC S/ 21752- 09 6.288 GAS LIFT DMY BK 3/28/2021 2 14,178.3 7,445.0Camco KBMG/ 11141- 11BVC S/ 21752- 17 6.298 GAS LIFT DMY BK 4/2/2021 Intergr al Top Sub HORIZONTAL, CD5-93, 4/7/2021 2:49:44 PM Vertical schematic (actual) FLOAT SHOE; 16,492.4 INTERMEDIATE; 37.3-14,526.7 NIPPLE; 14,374.5 NIPPLE; 14,314.5 PACKER; 14,246.2 GAS LIFT; 14,178.3 GAS LIFT; 5,658.5 INJ VALVE; 2,511.0 NIPPLE; 2,511.2 SURFACE; 38.9-2,194.1 CONDUCTOR; 38.1-120.0 HANGER; 35.0 Liner; 0.0 WNS INJ KB-Grd (ft) 39.07 Rig Release Date 2/14/2021 CD5-93 ... TD Act Btm (ftKB) 26,177.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032082700 Wellbore Status INJ Max Angle & MD Incl (°) 96.19 MD (ftKB) 26,098.72 WELLNAME WELLBORE Annotation LAST WO: End DateH2S (ppm)DateComment SSSV: NONE Summary of Events CD5-93 was temporarily converted from injector to producer from 2/25/21 – 3/26/21. Wellwork summary for production setup: 2/15/2021 DRIFT TBG TO 14,260' SLM BEFORE STALLING OUT DUE TO DEVIATION. SHAKE OFF CATCHER & CHASE DOWN TO 14,250' SLM. ATTEMPT PULL DV @ 14,178' RKB. IN PROGRESS. 2/16/2021 PULLED DV @ 5685' RKB & REPLACED WITH GLV. MADE MULTIPLE ATTEMPTS TO PULL DV @ 14,178' RKB, UNABLE TO LOCATE OR SEE MANDREL. IN PROGRESS. 2/17/2021 RAN DOUBLE KNUCKLED JD TO STA# 2 @ 14,178' RKB, UNABLE TO SET DOWN OR LATCH, RAN DECENTRALIZER ON OMK ( @ 12 O CLOCK) TO STA#2 @ 14,178' RKB, UNABLE TO LATCH, RAN KJ, OMK JD TO STA# 2 @ 14,178' RKB, UNABLE TO LOCATE LATCH OR SET DOWN, IN PROGRESS 2/18/2021 RAN 4 1/2 OK-6 KOT, 1.25''JD TO 14,211' SLM, UNABLE TO LOCATE OR SET DOWN, RAN CALIPER FROM 14,205' SLM 1000' UP, UNABLE TO SEE MANDREL, RE RAN CALIPER w/ PUMPING DOWN @ 2 BPM FROM 14,213' SLM TO 14,241' SLM, ABLE TO LOG MANDREL & LOWER HANDLER PUP, IN PROGRESS 2/19/2021 RAN OK-6 TO STA# 2 @ 14,178' RKB, UNABLE TO LOCATE OR SET DN, RAN SAME KOT, ON DECENTRALIZER ARM CLOCKED @ 2:30 LOOKING DN, STILL UNABLE TO LOCATE OR SET DN, RAN OMK NO KNUCKLE TO STA#2 @ 14,178' RKB, PULLED DV, IN PROGRESS 2/20/2021 PUMPED 270 BBLS SLICK DIESEL, ATTEMPT TO SET OV @ 14,178' RKB, GOT STUCK, WORK WIRE FOR FEW HRS, GOT UNSTUCK @ END OF DAY, IN PROGRESS 2/21/2021 MEASURE BHP @ 14,128' RKB ( 3492 PSI / 167 DEG), RAN OMK, OV TO STA# 2 @14,178'' 84.9 DEG, UNABLE TO SET, RAN OK- 6, LOCATED, UNABLE TO SET DOWN w/ DIFFERENT PUMP RATES, POCKET STILL OPEN, IN PROGRESS 2/22/2021 SET OV @ 14,178' RKB, PULLED CATCHER ASSY' @ 14,314' RKB, JOB COMPLETE Surface piping was configured to allow production testing via the CD5 test separator. Production is summarized below and reported by monthly production report 10-405. CD5-93 Production Oil Vol. [MSTB] Water Vol. [MBW] Form. Gas Vol. [MMSCF] Days online Feb-21 2 1 4 4 Mar-21 14 6 33 25 Following the production period, the well was restored to injection service. Wellwork summary for restoration to injection: 3/27/2021 SPOT UP ON LOC, ISSUES W/ EQUIPMENT, BEGIN JOB TOMORROW. IN PROGRESS 3/28/2021 SET 4.5" SLIP STOP CATCHER @ 5772' SLM, PULLED VALVE IN ST #1 @ 5658' RKB, SET DV IN ST #1 @ SAME, PULLED 4.5" SLIP STOP CATCHER, LRS PUMPED 218 BBLS OF SLICK-DIESEL, FAILED ATTEMPT TO PULL ST #2 @ 14,178' RKB. IN PROGRESS 3/29/2021 PULLED OV (1/4" ORIFICE) FROM STA #2 @ 14,216' SLM / 14,178' RKB. IN PROGRESS 3/30/2021 DISPLACE IA WITH 372 BBLS OF SLICK DIESEL. JOB COMPLETE 3/31/2021 MAKE MULTIPLE ATTEMPTS TO SET DGLV IN STA #2 @ 14,178' RKB. IN PROGRESS 4/1/2021 SET 1" DGLV IN STA #2 @ 14,178' RKB, UNABLE TO GET DRAW DOWN TEST, MAKE MULTIPLE ATTEMPTS TO SEAT VLV IN POCKET, TRY TO PULL VLV FROM STA #2, UNSUCCESSFUL. IN PROGRESS 4/2/2021 PULL & SET 1" DGLV IN STA #2 @ 14,178' RKB, GOOD DRAW DOWN TEST ON IA, LRS MIT-IA TO 2500psi, GOOD TEST, SET 4.5" MCX INJ VLV (SER#: 0004042783-3, 1.5625" BEAN, OAL=35") @ 2511' RKB, GOOD DRAW DOWN TEST. JOB COMPLETE A schematic of the wellbore following the operation is attached. Injection piping was installed, and the well was brought on water injection 4/3/21. w T-. ME 0 E V m F. WE E 000 V e-'1 V W Ln O i CP ++ Ol O o Y L z Y N i L > M Ln — dN , m Q N s o 06 c 1 W i v y m CT V L L z O R L Y O N N = 3 Q w Q O r j i F. 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,QWHUPHGLDWH6WULQJ&HPHQW 3DJH &' 5HSRUW3ULQWHG &HPHQW $GGLWLYHV $GGLWLYH 7\SH &RQFHQWUDWLRQ &RQF8QLWODEHO )OXLG )OXLG7\SH 'LVSODFHPHQW )OXLG'HVFULSWLRQ (VWLPDWHG7RSIW.% (VW%WPIW.% $PRXQWVDFNV &ODVV 9ROXPH3XPSHGEEO <LHOGIWñVDFN 0L[+5DWLRJDOVDFN )UHH:DWHU 'HQVLW\OEJDO 3ODVWLF9LVFRVLW\F3 7KLFNHQLQJ7LPHKU &PSU6WUSVL $GGLWLYHV $GGLWLYH 7\SH &RQFHQWUDWLRQ &RQF8QLWODEHO ,QWHUPHGLDWH6WULQJ&HPHQW ConocoPhillips Definitive Survey Report 09 March, 2021 NADConversion Western North Slope CD5 Alpine West Pad CD5-93 CD5-93 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope CD5 Alpine West Pad ConocoPhillips Definitive Survey Report Well: Wellbore: CD5-93 (12A) CD5-93 Survey Calculation Method:Minimum Curvature Real D25 @ 72.67usft (D25) Design:CD5-93 Database:EDT 15 Alaska Prod MD Reference:Real D25 @ 72.67usft (D25) North Reference: Well CD5-93 (12A) True Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Western North Slope, North Slope Alaska, United States Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Well Position Longitude: Latitude: Easting: Northing: usft +E/-W +N/-S Position Uncertainty usft usft usftGround Level: CD5-93 (12A) usft usft 0.00 0.00 5,965,953.61 349,674.33 33.60Wellhead Elevation:0.00 usft0.00 70° 18' 50.765 N 151° 13' 6.149 W Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) CD5-93 Model NameMagnetics BGGM2020 12/31/2020 15.29 80.64 57,281.01 Phase:Version: Audit Notes: Design CD5-93 1.0 ACTUAL Vertical Section:Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:39.07 332.000.000.0039.07 From (usft) Survey Program DescriptionTool NameSurvey (Wellbore) To (usft) Date 3/9/2021 Survey Date GYD-GC-SS Gyrodata gyro single shots121.00 615.00 CD5-93 Srvy 1 - GYD-GC-SS (CD5-93)1/18/2021 2:18:00PM MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Correction708.97 2,124.48 CD5-93 Srvy 2 - BH_MWD_IFR+SAG (C 1/18/2021 2:25:00PM MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Correction2,221.55 14,513.20 CD5-93 Srvy 3 - BH_MWD_IFR + SAG (1/19/2021 9:22:00PM MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag + Multi-Station Correction14,604.86 26,098.73 CD5-93 Srvy 4 - BH_MWD_IFR + SAG (2/5/2021 6:04:00PM MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 39.07 0.00 0.00 39.07 0.00 0.0033.60 5,965,953.61 349,674.33 0.00 0.00 UNDEFINED Surface Quarter Mile Radiuos 121.00 0.60 141.07 121.00 -0.33 0.27-48.33 5,965,953.27 349,674.59 0.73 -0.42 GYD-GC-SS (1) 182.00 0.71 146.12 181.99 -0.90 0.68-109.32 5,965,952.70 349,674.99 0.20 -1.11 GYD-GC-SS (1) 242.00 0.78 142.68 241.99 -1.53 1.14-169.32 5,965,952.06 349,675.44 0.14 -1.88 GYD-GC-SS (1) 334.00 1.62 149.69 333.97 -3.15 2.17-261.30 5,965,950.41 349,676.44 0.93 -3.80 GYD-GC-SS (1) 424.00 2.13 143.50 423.92 -5.59 3.81-351.25 5,965,947.94 349,678.03 0.61 -6.73 GYD-GC-SS (1) 520.00 2.58 149.20 519.84 -8.88 5.98-447.17 5,965,944.61 349,680.13 0.53 -10.65 GYD-GC-SS (1) 615.00 2.83 150.17 614.73 -12.75 8.24-542.06 5,965,940.69 349,682.31 0.27 -15.13 GYD-GC-SS (1) 708.97 3.01 150.77 708.58 -16.92 10.60-635.91 5,965,936.48 349,684.59 0.19 -19.91 MWD+IFR2+SAG+MS (2) 803.23 3.00 152.49 802.71 -21.27 12.94-730.04 5,965,932.09 349,686.85 0.10 -24.85 MWD+IFR2+SAG+MS (2) 3/9/2021 9:50:08AM COMPASS 5000.15 Build 91E Page 2 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope CD5 Alpine West Pad ConocoPhillips Definitive Survey Report Well: Wellbore: CD5-93 (12A) CD5-93 Survey Calculation Method:Minimum Curvature Real D25 @ 72.67usft (D25) Design:CD5-93 Database:EDT 15 Alaska Prod MD Reference:Real D25 @ 72.67usft (D25) North Reference: Well CD5-93 (12A) True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 896.55 3.22 151.08 895.89 -25.73 15.34-823.22 5,965,927.58 349,689.15 0.25 -29.92 MWD+IFR2+SAG+MS (2) 991.30 3.44 150.39 990.48 -30.53 18.03-917.81 5,965,922.73 349,691.75 0.24 -35.42 MWD+IFR2+SAG+MS (2) 1,085.37 3.57 153.88 1,084.38 -35.61 20.71-1,011.71 5,965,917.59 349,694.33 0.27 -41.17 MWD+IFR2+SAG+MS (2) 1,179.09 2.72 148.77 1,177.96 -40.13 23.15-1,105.29 5,965,913.02 349,696.67 0.95 -46.30 MWD+IFR2+SAG+MS (2) 1,276.13 1.58 143.55 1,274.93 -43.18 25.14-1,202.26 5,965,909.94 349,698.60 1.19 -49.93 MWD+IFR2+SAG+MS (2) 1,369.32 1.97 149.82 1,368.07 -45.60 26.71-1,295.40 5,965,907.49 349,700.12 0.47 -52.80 MWD+IFR2+SAG+MS (2) 1,464.30 1.36 171.37 1,463.01 -48.12 27.70-1,390.34 5,965,904.95 349,701.06 0.91 -55.49 MWD+IFR2+SAG+MS (2) 1,558.18 1.44 239.91 1,556.87 -49.81 26.85-1,484.20 5,965,903.27 349,700.17 1.68 -56.59 MWD+IFR2+SAG+MS (2) 1,653.41 2.77 285.05 1,652.04 -49.82 23.59-1,579.37 5,965,903.33 349,696.92 2.13 -55.06 MWD+IFR2+SAG+MS (2) 1,747.07 4.69 293.41 1,745.50 -47.71 17.89-1,672.83 5,965,905.56 349,691.26 2.13 -50.52 MWD+IFR2+SAG+MS (2) 1,840.84 5.97 294.43 1,838.86 -44.17 9.93-1,766.19 5,965,909.25 349,683.37 1.37 -43.66 MWD+IFR2+SAG+MS (2) 1,935.85 7.38 298.17 1,933.22 -39.24 0.05-1,860.55 5,965,914.37 349,673.60 1.55 -34.67 MWD+IFR2+SAG+MS (2) 2,029.07 9.02 299.66 2,025.49 -32.80 -11.58-1,952.82 5,965,921.05 349,662.10 1.77 -23.53 MWD+IFR2+SAG+MS (2) 2,124.48 10.52 303.07 2,119.51 -24.35 -25.38-2,046.84 5,965,929.78 349,648.47 1.68 -9.58 MWD+IFR2+SAG+MS (2) 2,194.00 10.94 305.09 2,187.82 -17.09 -36.09-2,115.15 5,965,937.24 349,637.91 0.81 1.85 MWD+IFR2+SAG+MS (3) 13 3/8" 2,221.55 11.11 305.85 2,214.86 -14.03 -40.38-2,142.19 5,965,940.39 349,633.68 0.81 6.57 MWD+IFR2+SAG+MS (3) 2,231.34 11.13 305.21 2,224.46 -12.94 -41.92-2,151.79 5,965,941.51 349,632.16 1.28 8.26 MWD+IFR2+SAG+MS (3) 2,324.72 12.25 304.49 2,315.91 -2.13 -57.45-2,243.24 5,965,952.63 349,616.86 1.21 25.09 MWD+IFR2+SAG+MS (3) 2,419.22 12.74 301.01 2,408.17 8.92 -74.64-2,335.50 5,965,964.02 349,599.89 0.95 42.92 MWD+IFR2+SAG+MS (3) 2,513.64 12.83 297.61 2,500.25 19.14 -92.86-2,427.58 5,965,974.60 349,581.88 0.80 60.49 MWD+IFR2+SAG+MS (3) 2,611.66 17.02 302.47 2,594.94 31.89 -114.61-2,522.27 5,965,987.78 349,560.39 4.46 81.97 MWD+IFR2+SAG+MS (3) 2,702.67 19.87 305.86 2,681.27 48.11 -138.39-2,608.60 5,966,004.47 349,536.94 3.34 107.45 MWD+IFR2+SAG+MS (3) 2,797.72 22.59 309.11 2,769.87 69.09 -165.65-2,697.20 5,966,025.99 349,510.11 3.12 138.77 MWD+IFR2+SAG+MS (3) 2,891.71 25.30 311.56 2,855.76 93.81 -194.70-2,783.09 5,966,051.28 349,481.57 3.07 174.23 MWD+IFR2+SAG+MS (3) 2,986.28 29.59 312.49 2,939.67 123.00 -227.05-2,867.00 5,966,081.12 349,449.81 4.56 215.19 MWD+IFR2+SAG+MS (3) 3,081.75 31.97 313.03 3,021.69 156.17 -262.91-2,949.02 5,966,115.00 349,414.62 2.51 261.32 MWD+IFR2+SAG+MS (3) 3,174.34 34.63 314.48 3,099.07 191.34 -299.61-3,026.40 5,966,150.89 349,378.64 3.00 309.60 MWD+IFR2+SAG+MS (3) 3,266.41 36.89 314.50 3,173.77 229.04 -337.99-3,101.10 5,966,189.35 349,341.02 2.45 360.90 MWD+IFR2+SAG+MS (3) 3,360.72 39.63 315.28 3,247.82 270.26 -379.35-3,175.15 5,966,231.39 349,300.50 2.95 416.72 MWD+IFR2+SAG+MS (3) 3,457.57 42.05 315.11 3,321.09 315.19 -423.98-3,248.42 5,966,277.20 349,256.78 2.50 477.34 MWD+IFR2+SAG+MS (3) 3,552.43 44.14 314.66 3,390.35 360.92 -469.90-3,317.68 5,966,323.83 349,211.79 2.23 539.28 MWD+IFR2+SAG+MS (3) 3,646.75 47.14 313.41 3,456.29 407.77 -518.38-3,383.62 5,966,371.65 349,164.25 3.32 603.41 MWD+IFR2+SAG+MS (3) 3,741.36 49.13 313.92 3,519.43 456.42 -569.35-3,446.76 5,966,421.30 349,114.28 2.14 670.29 MWD+IFR2+SAG+MS (3) 3,835.02 51.68 313.14 3,579.12 506.12 -621.67-3,506.45 5,966,472.03 349,062.96 2.80 738.73 MWD+IFR2+SAG+MS (3) 3,926.66 53.57 312.50 3,634.74 555.61 -675.09-3,562.07 5,966,522.58 349,010.55 2.14 807.51 MWD+IFR2+SAG+MS (3) 4,023.07 55.69 312.02 3,690.55 608.47 -733.27-3,617.88 5,966,576.59 348,953.44 2.24 881.50 MWD+IFR2+SAG+MS (3) 4,116.28 58.67 311.52 3,741.06 660.64 -791.69-3,668.39 5,966,629.91 348,896.08 3.23 954.99 MWD+IFR2+SAG+MS (3) 4,210.54 61.89 310.14 3,787.79 714.14 -853.63-3,715.12 5,966,684.64 348,835.23 3.64 1,031.30 MWD+IFR2+SAG+MS (3) 4,305.50 64.19 310.50 3,830.84 768.91 -918.16-3,758.17 5,966,740.68 348,771.82 2.45 1,109.95 MWD+IFR2+SAG+MS (3) 4,399.03 66.74 310.56 3,869.67 824.19 -982.82-3,797.00 5,966,797.25 348,708.28 2.73 1,189.13 MWD+IFR2+SAG+MS (3) 3/9/2021 9:50:08AM COMPASS 5000.15 Build 91E Page 3 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope CD5 Alpine West Pad ConocoPhillips Definitive Survey Report Well: Wellbore: CD5-93 (12A) CD5-93 Survey Calculation Method:Minimum Curvature Real D25 @ 72.67usft (D25) Design:CD5-93 Database:EDT 15 Alaska Prod MD Reference:Real D25 @ 72.67usft (D25) North Reference: Well CD5-93 (12A) True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 4,493.10 67.93 309.91 3,905.92 880.26 -1,049.09-3,833.25 5,966,854.63 348,643.15 1.42 1,269.74 MWD+IFR2+SAG+MS (3) 4,585.90 68.47 310.30 3,940.39 935.77 -1,114.99-3,867.72 5,966,911.44 348,578.38 0.70 1,349.69 MWD+IFR2+SAG+MS (3) 4,681.11 67.83 311.10 3,975.82 993.39 -1,181.99-3,903.15 5,966,970.39 348,512.55 1.03 1,432.02 MWD+IFR2+SAG+MS (3) 4,774.90 67.65 312.15 4,011.35 1,051.05 -1,246.87-3,938.68 5,967,029.33 348,448.84 1.05 1,513.39 MWD+IFR2+SAG+MS (3) 4,868.30 66.91 311.85 4,047.42 1,108.69 -1,310.89-3,974.75 5,967,088.24 348,385.99 0.85 1,594.35 MWD+IFR2+SAG+MS (3) 4,961.55 67.27 311.35 4,083.72 1,165.72 -1,375.13-4,011.05 5,967,146.54 348,322.92 0.63 1,674.85 MWD+IFR2+SAG+MS (3) 5,054.88 67.03 309.30 4,119.97 1,221.37 -1,440.69-4,047.30 5,967,203.49 348,258.49 2.04 1,754.77 MWD+IFR2+SAG+MS (3) 5,149.03 67.26 308.10 4,156.54 1,275.62 -1,508.40-4,083.87 5,967,259.07 348,191.89 1.20 1,834.45 MWD+IFR2+SAG+MS (3) 5,243.19 67.60 306.99 4,192.68 1,328.60 -1,577.34-4,120.01 5,967,313.42 348,124.03 1.15 1,913.60 MWD+IFR2+SAG+MS (3) 5,337.86 68.22 306.60 4,228.28 1,381.14 -1,647.58-4,155.61 5,967,367.35 348,054.85 0.76 1,992.97 MWD+IFR2+SAG+MS (3) 5,430.96 68.40 306.27 4,262.69 1,432.52 -1,717.18-4,190.02 5,967,420.11 347,986.30 0.38 2,071.00 MWD+IFR2+SAG+MS (3) 5,525.69 68.45 306.81 4,297.52 1,484.97 -1,787.96-4,224.85 5,967,473.96 347,916.59 0.53 2,150.54 MWD+IFR2+SAG+MS (3) 5,619.44 68.37 307.46 4,332.02 1,537.59 -1,857.45-4,259.35 5,967,527.96 347,848.17 0.65 2,229.63 MWD+IFR2+SAG+MS (3) 5,711.35 68.31 308.23 4,365.95 1,590.00 -1,924.91-4,293.28 5,967,581.70 347,781.79 0.78 2,307.57 MWD+IFR2+SAG+MS (3) 5,805.53 68.27 307.75 4,400.78 1,643.86 -1,993.87-4,328.11 5,967,636.93 347,713.92 0.48 2,387.50 MWD+IFR2+SAG+MS (3) 5,900.33 68.20 306.80 4,435.94 1,697.18 -2,063.92-4,363.27 5,967,691.64 347,644.95 0.93 2,467.47 MWD+IFR2+SAG+MS (3) 5,994.10 68.29 306.22 4,470.69 1,748.99 -2,133.92-4,398.02 5,967,744.84 347,576.01 0.58 2,546.09 MWD+IFR2+SAG+MS (3) 6,088.55 68.40 306.37 4,505.54 1,800.96 -2,204.67-4,432.87 5,967,798.21 347,506.32 0.19 2,625.18 MWD+IFR2+SAG+MS (3) 6,180.80 68.14 307.07 4,539.70 1,852.19 -2,273.36-4,467.03 5,967,850.80 347,438.67 0.76 2,702.67 MWD+IFR2+SAG+MS (3) 6,275.62 67.79 307.15 4,575.27 1,905.22 -2,343.46-4,502.60 5,967,905.22 347,369.66 0.38 2,782.40 MWD+IFR2+SAG+MS (3) 6,370.26 68.13 308.04 4,610.79 1,958.74 -2,412.96-4,538.12 5,967,960.12 347,301.24 0.94 2,862.28 MWD+IFR2+SAG+MS (3) 6,464.22 69.09 309.48 4,645.06 2,013.51 -2,481.18-4,572.39 5,968,016.24 347,234.14 1.76 2,942.67 MWD+IFR2+SAG+MS (3) 6,557.72 68.57 310.06 4,678.82 2,069.29 -2,548.19-4,606.15 5,968,073.34 347,168.26 0.80 3,023.38 MWD+IFR2+SAG+MS (3) 6,652.95 67.99 309.35 4,714.07 2,125.81 -2,616.26-4,641.40 5,968,131.21 347,101.35 0.92 3,105.23 MWD+IFR2+SAG+MS (3) 6,747.74 67.97 309.10 4,749.61 2,181.38 -2,684.33-4,676.94 5,968,188.12 347,034.41 0.25 3,186.26 MWD+IFR2+SAG+MS (3) 6,842.79 67.75 309.41 4,785.43 2,237.09 -2,752.50-4,712.76 5,968,245.18 346,967.37 0.38 3,267.45 MWD+IFR2+SAG+MS (3) 6,937.31 67.74 309.69 4,821.22 2,292.79 -2,819.96-4,748.55 5,968,302.22 346,901.05 0.27 3,348.30 MWD+IFR2+SAG+MS (3) 7,030.26 67.68 310.09 4,856.48 2,347.94 -2,885.95-4,783.81 5,968,358.68 346,836.18 0.40 3,427.98 MWD+IFR2+SAG+MS (3) 7,122.51 67.69 310.78 4,891.51 2,403.29 -2,950.90-4,818.84 5,968,415.32 346,772.35 0.69 3,507.35 MWD+IFR2+SAG+MS (3) 7,216.24 67.72 310.99 4,927.07 2,460.06 -3,016.47-4,854.40 5,968,473.38 346,707.94 0.21 3,588.25 MWD+IFR2+SAG+MS (3) 7,310.30 68.23 311.46 4,962.34 2,517.52 -3,082.05-4,889.67 5,968,532.14 346,643.53 0.71 3,669.77 MWD+IFR2+SAG+MS (3) 7,404.69 67.82 312.56 4,997.66 2,576.10 -3,147.09-4,924.99 5,968,592.01 346,579.68 1.16 3,752.03 MWD+IFR2+SAG+MS (3) 7,500.42 67.99 313.39 5,033.67 2,636.57 -3,211.98-4,961.00 5,968,653.75 346,516.01 0.82 3,835.88 MWD+IFR2+SAG+MS (3) 7,593.76 67.83 313.24 5,068.77 2,695.90 -3,274.91-4,996.10 5,968,714.33 346,454.29 0.23 3,917.81 MWD+IFR2+SAG+MS (3) 7,687.60 67.84 312.67 5,104.18 2,755.12 -3,338.52-5,031.51 5,968,774.80 346,391.89 0.56 3,999.96 MWD+IFR2+SAG+MS (3) 7,782.00 67.93 312.64 5,139.71 2,814.38 -3,402.83-5,067.04 5,968,835.33 346,328.78 0.10 4,082.48 MWD+IFR2+SAG+MS (3) 7,875.35 67.69 311.84 5,174.97 2,872.48 -3,466.82-5,102.30 5,968,894.70 346,265.97 0.83 4,163.83 MWD+IFR2+SAG+MS (3) 7,970.15 67.78 310.50 5,210.89 2,930.23 -3,532.86-5,138.22 5,968,953.76 346,201.10 1.31 4,245.82 MWD+IFR2+SAG+MS (3) 8,063.23 68.33 310.00 5,245.68 2,986.01 -3,598.76-5,173.01 5,969,010.85 346,136.34 0.77 4,326.01 MWD+IFR2+SAG+MS (3) 8,154.73 68.48 309.96 5,279.35 3,040.68 -3,663.95-5,206.68 5,969,066.80 346,072.26 0.17 4,404.88 MWD+IFR2+SAG+MS (3) 3/9/2021 9:50:08AM COMPASS 5000.15 Build 91E Page 4 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope CD5 Alpine West Pad ConocoPhillips Definitive Survey Report Well: Wellbore: CD5-93 (12A) CD5-93 Survey Calculation Method:Minimum Curvature Real D25 @ 72.67usft (D25) Design:CD5-93 Database:EDT 15 Alaska Prod MD Reference:Real D25 @ 72.67usft (D25) North Reference: Well CD5-93 (12A) True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 8,249.57 68.26 309.55 5,314.31 3,097.06 -3,731.73-5,241.64 5,969,124.52 346,005.63 0.46 4,486.48 MWD+IFR2+SAG+MS (3) 8,344.66 68.49 310.01 5,349.36 3,153.62 -3,799.66-5,276.69 5,969,182.43 345,938.85 0.51 4,568.31 MWD+IFR2+SAG+MS (3) 8,439.36 68.47 310.28 5,384.09 3,210.42 -3,867.00-5,311.42 5,969,240.56 345,872.66 0.27 4,650.08 MWD+IFR2+SAG+MS (3) 8,533.95 67.87 309.81 5,419.27 3,266.91 -3,934.22-5,346.60 5,969,298.38 345,806.59 0.78 4,731.52 MWD+IFR2+SAG+MS (3) 8,628.43 67.83 308.68 5,454.89 3,322.27 -4,001.99-5,382.22 5,969,355.08 345,739.95 1.11 4,812.21 MWD+IFR2+SAG+MS (3) 8,721.39 67.68 307.70 5,490.08 3,375.47 -4,069.62-5,417.41 5,969,409.62 345,673.41 0.99 4,890.93 MWD+IFR2+SAG+MS (3) 8,816.46 67.79 307.39 5,526.10 3,429.08 -4,139.37-5,453.43 5,969,464.62 345,604.74 0.32 4,971.02 MWD+IFR2+SAG+MS (3) 8,909.81 67.88 307.51 5,561.32 3,481.65 -4,208.01-5,488.65 5,969,518.54 345,537.18 0.15 5,049.65 MWD+IFR2+SAG+MS (3) 9,005.88 67.88 308.45 5,597.50 3,536.42 -4,278.16-5,524.83 5,969,574.70 345,468.15 0.91 5,130.95 MWD+IFR2+SAG+MS (3) 9,098.15 67.90 309.64 5,632.23 3,590.27 -4,344.55-5,559.56 5,969,629.86 345,402.85 1.20 5,209.66 MWD+IFR2+SAG+MS (3) 9,192.64 67.98 309.77 5,667.72 3,646.21 -4,411.92-5,595.05 5,969,687.14 345,336.62 0.15 5,290.68 MWD+IFR2+SAG+MS (3) 9,287.00 68.19 310.41 5,702.94 3,702.59 -4,478.89-5,630.27 5,969,744.84 345,270.79 0.67 5,371.90 MWD+IFR2+SAG+MS (3) 9,381.62 68.22 310.29 5,738.07 3,759.47 -4,545.85-5,665.40 5,969,803.05 345,205.00 0.12 5,453.56 MWD+IFR2+SAG+MS (3) 9,476.49 68.21 309.78 5,773.28 3,816.14 -4,613.30-5,700.61 5,969,861.05 345,138.70 0.50 5,535.26 MWD+IFR2+SAG+MS (3) 9,570.15 68.15 309.57 5,808.09 3,871.65 -4,680.22-5,735.42 5,969,917.89 345,072.91 0.22 5,615.69 MWD+IFR2+SAG+MS (3) 9,665.63 68.20 309.99 5,843.59 3,928.36 -4,748.34-5,770.92 5,969,975.95 345,005.94 0.41 5,697.75 MWD+IFR2+SAG+MS (3) 9,759.40 68.20 310.03 5,878.41 3,984.34 -4,815.02-5,805.74 5,970,033.25 344,940.40 0.04 5,778.48 MWD+IFR2+SAG+MS (3) 9,854.66 68.17 310.25 5,913.81 4,041.35 -4,882.63-5,841.14 5,970,091.60 344,873.95 0.22 5,860.56 MWD+IFR2+SAG+MS (3) 9,947.95 68.22 310.31 5,948.46 4,097.35 -4,948.71-5,875.79 5,970,148.90 344,809.01 0.08 5,941.02 MWD+IFR2+SAG+MS (3) 10,040.90 68.15 310.87 5,983.00 4,153.49 -5,014.24-5,910.33 5,970,206.34 344,744.62 0.56 6,021.36 MWD+IFR2+SAG+MS (3) 10,134.87 68.11 310.57 6,018.01 4,210.39 -5,080.33-5,945.34 5,970,264.54 344,679.68 0.30 6,102.62 MWD+IFR2+SAG+MS (3) 10,229.88 68.12 310.44 6,053.42 4,267.65 -5,147.37-5,980.75 5,970,323.13 344,613.81 0.13 6,184.65 MWD+IFR2+SAG+MS (3) 10,325.89 68.18 310.18 6,089.15 4,325.30 -5,215.32-6,016.48 5,970,382.13 344,547.03 0.26 6,267.46 MWD+IFR2+SAG+MS (3) 10,419.18 68.13 309.87 6,123.87 4,380.99 -5,281.63-6,051.20 5,970,439.13 344,481.86 0.31 6,347.76 MWD+IFR2+SAG+MS (3) 10,513.05 68.03 309.92 6,158.91 4,436.84 -5,348.44-6,086.24 5,970,496.30 344,416.18 0.12 6,428.44 MWD+IFR2+SAG+MS (3) 10,606.27 68.10 310.29 6,193.73 4,492.54 -5,414.58-6,121.06 5,970,553.32 344,351.18 0.38 6,508.67 MWD+IFR2+SAG+MS (3) 10,701.47 68.04 310.34 6,229.29 4,549.68 -5,481.92-6,156.62 5,970,611.78 344,285.00 0.08 6,590.73 MWD+IFR2+SAG+MS (3) 10,796.00 68.13 310.82 6,264.57 4,606.73 -5,548.53-6,191.90 5,970,670.15 344,219.55 0.48 6,672.38 MWD+IFR2+SAG+MS (3) 10,888.82 67.86 310.86 6,299.35 4,663.01 -5,613.63-6,226.68 5,970,727.72 344,155.59 0.29 6,752.63 MWD+IFR2+SAG+MS (3) 10,983.00 67.92 311.01 6,334.80 4,720.18 -5,679.55-6,262.13 5,970,786.19 344,090.84 0.16 6,834.06 MWD+IFR2+SAG+MS (3) 11,077.09 67.89 310.74 6,370.19 4,777.23 -5,745.47-6,297.52 5,970,844.55 344,026.08 0.27 6,915.38 MWD+IFR2+SAG+MS (3) 11,172.14 67.97 310.57 6,405.90 4,834.62 -5,812.30-6,333.23 5,970,903.25 343,960.42 0.19 6,997.42 MWD+IFR2+SAG+MS (3) 11,266.42 67.88 310.44 6,441.33 4,891.36 -5,878.73-6,368.66 5,970,961.32 343,895.14 0.16 7,078.71 MWD+IFR2+SAG+MS (3) 11,360.65 67.92 310.26 6,476.78 4,947.89 -5,945.26-6,404.11 5,971,019.16 343,829.76 0.18 7,159.86 MWD+IFR2+SAG+MS (3) 11,454.92 67.90 310.31 6,512.24 5,004.37 -6,011.90-6,439.57 5,971,076.96 343,764.27 0.05 7,241.01 MWD+IFR2+SAG+MS (3) 11,549.14 68.08 310.10 6,547.55 5,060.76 -6,078.61-6,474.88 5,971,134.67 343,698.70 0.28 7,322.12 MWD+IFR2+SAG+MS (3) 11,643.47 67.91 309.31 6,582.89 5,116.63 -6,145.90-6,510.22 5,971,191.87 343,632.56 0.80 7,403.04 MWD+IFR2+SAG+MS (3) 11,737.25 67.87 309.17 6,618.19 5,171.59 -6,213.19-6,545.52 5,971,248.16 343,566.38 0.14 7,483.16 MWD+IFR2+SAG+MS (3) 11,831.34 67.87 309.25 6,653.63 5,226.69 -6,280.72-6,580.96 5,971,304.60 343,499.97 0.08 7,563.51 MWD+IFR2+SAG+MS (3) 11,925.34 67.91 309.30 6,689.01 5,281.82 -6,348.14-6,616.34 5,971,361.06 343,433.68 0.07 7,643.84 MWD+IFR2+SAG+MS (3) 3/9/2021 9:50:08AM COMPASS 5000.15 Build 91E Page 5 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope CD5 Alpine West Pad ConocoPhillips Definitive Survey Report Well: Wellbore: CD5-93 (12A) CD5-93 Survey Calculation Method:Minimum Curvature Real D25 @ 72.67usft (D25) Design:CD5-93 Database:EDT 15 Alaska Prod MD Reference:Real D25 @ 72.67usft (D25) North Reference: Well CD5-93 (12A) True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 12,001.25 68.11 309.62 6,717.44 5,326.56 -6,402.48-6,644.77 5,971,406.88 343,380.24 0.48 7,708.85 MWD+IFR2+SAG+MS (3) 2017 CD5 (12A) Heel 082817 12,019.06 68.16 309.70 6,724.07 5,337.10 -6,415.20-6,651.40 5,971,417.68 343,367.74 0.48 7,724.14 MWD+IFR2+SAG+MS (3) 12,043.75 68.16 309.79 6,733.25 5,351.76 -6,432.83-6,660.58 5,971,432.68 343,350.41 0.33 7,745.35 MWD+IFR2+SAG+MS (3) CD5-93 Top Heel 090120 12,112.79 68.17 310.03 6,758.93 5,392.87 -6,481.99-6,686.26 5,971,474.77 343,302.09 0.33 7,804.73 MWD+IFR2+SAG+MS (3) 12,207.07 68.14 310.09 6,794.01 5,449.19 -6,548.96-6,721.34 5,971,532.41 343,236.26 0.07 7,885.90 MWD+IFR2+SAG+MS (3) 12,302.15 68.20 310.43 6,829.37 5,506.23 -6,616.32-6,756.70 5,971,590.78 343,170.06 0.34 7,967.89 MWD+IFR2+SAG+MS (3) CD5-93 T01 H 072120 12,396.66 68.18 311.18 6,864.48 5,563.57 -6,682.73-6,791.81 5,971,649.44 343,104.81 0.74 8,049.70 MWD+IFR2+SAG+MS (3) 12,491.10 68.19 311.18 6,899.58 5,621.30 -6,748.72-6,826.91 5,971,708.47 343,040.00 0.01 8,131.65 MWD+IFR2+SAG+MS (3) 12,585.09 68.14 311.07 6,934.53 5,678.68 -6,814.45-6,861.86 5,971,767.15 342,975.44 0.12 8,213.17 MWD+IFR2+SAG+MS (3) 12,678.87 68.19 310.85 6,969.41 5,735.75 -6,880.18-6,896.74 5,971,825.52 342,910.87 0.22 8,294.42 MWD+IFR2+SAG+MS (3) 12,773.65 68.19 311.17 7,004.63 5,793.49 -6,946.59-6,931.96 5,971,884.58 342,845.64 0.31 8,376.57 MWD+IFR2+SAG+MS (3) 12,868.13 68.06 310.24 7,039.83 5,850.67 -7,013.05-6,967.16 5,971,943.07 342,780.34 0.92 8,458.26 MWD+IFR2+SAG+MS (3) 12,962.52 68.05 310.51 7,075.11 5,907.39 -7,079.75-7,002.44 5,972,001.10 342,714.79 0.27 8,539.65 MWD+IFR2+SAG+MS (3) 13,057.31 68.05 310.38 7,110.54 5,964.42 -7,146.66-7,037.87 5,972,059.46 342,649.04 0.13 8,621.42 MWD+IFR2+SAG+MS (3) 13,152.49 68.06 309.97 7,146.11 6,021.37 -7,214.11-7,073.44 5,972,117.75 342,582.75 0.40 8,703.38 MWD+IFR2+SAG+MS (3) 13,246.89 68.04 310.22 7,181.40 6,077.77 -7,281.09-7,108.73 5,972,175.47 342,516.92 0.25 8,784.61 MWD+IFR2+SAG+MS (3) 13,340.83 68.43 313.98 7,216.24 6,136.24 -7,345.81-7,143.57 5,972,235.23 342,453.39 3.74 8,866.63 MWD+IFR2+SAG+MS (3) 13,434.41 69.19 318.53 7,250.08 6,199.26 -7,406.11-7,177.41 5,972,299.44 342,394.36 4.61 8,950.58 MWD+IFR2+SAG+MS (3) 13,528.70 70.30 321.98 7,282.73 6,267.27 -7,462.65-7,210.06 5,972,368.56 342,339.20 3.63 9,037.17 MWD+IFR2+SAG+MS (3) 13,623.26 71.31 323.39 7,313.82 6,338.29 -7,516.78-7,241.15 5,972,440.64 342,286.51 1.77 9,125.30 MWD+IFR2+SAG+MS (3) 13,716.46 72.46 324.74 7,342.80 6,410.02 -7,568.76-7,270.13 5,972,513.39 342,235.98 1.85 9,213.02 MWD+IFR2+SAG+MS (3) 13,810.81 73.26 325.69 7,370.61 6,484.06 -7,620.19-7,297.94 5,972,588.44 342,186.04 1.28 9,302.55 MWD+IFR2+SAG+MS (3) 13,904.74 75.47 327.19 7,395.92 6,559.44 -7,670.19-7,323.25 5,972,664.80 342,137.57 2.81 9,392.57 MWD+IFR2+SAG+MS (3) 13,998.86 78.33 328.56 7,417.25 6,637.06 -7,718.92-7,344.58 5,972,743.38 342,090.40 3.35 9,483.99 MWD+IFR2+SAG+MS (3) 14,092.61 81.11 329.11 7,433.98 6,715.99 -7,766.65-7,361.31 5,972,823.24 342,044.26 3.02 9,576.09 MWD+IFR2+SAG+MS (3) 14,187.54 84.46 329.10 7,445.90 6,796.79 -7,815.00-7,373.23 5,972,904.99 341,997.54 3.53 9,670.13 MWD+IFR2+SAG+MS (3) 14,281.89 84.97 328.29 7,454.59 6,877.06 -7,863.82-7,381.92 5,972,986.21 341,950.35 1.01 9,763.93 MWD+IFR2+SAG+MS (3) 14,367.01 85.01 328.21 7,462.03 6,949.17 -7,908.44-7,389.36 5,973,059.19 341,907.18 0.10 9,848.54 MWD+IFR2+SAG+MS (3) CD5-93 T01 H 090120 14,367.80 85.01 328.21 7,462.10 6,949.84 -7,908.85-7,389.43 5,973,059.87 341,906.78 0.10 9,849.32 MWD+IFR2+SAG+MS (3) CD5-93 T01 H 032520 14,373.48 85.01 328.20 7,462.59 6,954.64 -7,911.83-7,389.92 5,973,064.73 341,903.90 0.10 9,854.97 MWD+IFR2+SAG+MS (3) CD5-93 (12A) T01 Heel 091218 14,375.81 85.01 328.20 7,462.79 6,956.62 -7,913.06-7,390.12 5,973,066.73 341,902.72 0.10 9,857.29 MWD+IFR2+SAG+MS (3) 14,470.70 85.88 328.96 7,470.33 7,037.34 -7,962.37-7,397.66 5,973,148.42 341,855.04 1.22 9,951.71 MWD+IFR2+SAG+MS (3) 14,513.20 85.58 329.01 7,473.50 7,073.66 -7,984.21-7,400.83 5,973,185.17 341,833.93 0.72 9,994.03 MWD+IFR2+SAG+MS (3) 14,604.86 86.07 330.46 7,480.17 7,152.62 -8,030.28-7,407.50 5,973,265.02 341,789.45 1.67 10,085.37 MWD+IFR2+SAG+MS (4) 14,699.52 85.83 332.02 7,486.85 7,235.39 -8,075.71-7,414.18 5,973,348.68 341,745.69 1.66 10,179.78 MWD+IFR2+SAG+MS (4) 3/9/2021 9:50:08AM COMPASS 5000.15 Build 91E Page 6 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope CD5 Alpine West Pad ConocoPhillips Definitive Survey Report Well: Wellbore: CD5-93 (12A) CD5-93 Survey Calculation Method:Minimum Curvature Real D25 @ 72.67usft (D25) Design:CD5-93 Database:EDT 15 Alaska Prod MD Reference:Real D25 @ 72.67usft (D25) North Reference: Well CD5-93 (12A) True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 14,795.88 85.70 332.48 7,493.97 7,320.43 -8,120.45-7,421.30 5,973,434.60 341,702.66 0.49 10,275.88 MWD+IFR2+SAG+MS (4) 14,890.43 83.88 332.01 7,502.56 7,403.76 -8,164.30-7,429.89 5,973,518.77 341,660.50 1.99 10,370.03 MWD+IFR2+SAG+MS (4) 14,983.18 83.73 330.77 7,512.57 7,484.70 -8,208.45-7,439.90 5,973,600.58 341,617.98 1.34 10,462.24 MWD+IFR2+SAG+MS (4) 15,079.66 85.27 332.27 7,521.81 7,569.11 -8,254.24-7,449.14 5,973,685.89 341,573.89 2.22 10,558.26 MWD+IFR2+SAG+MS (4) 15,173.74 85.73 332.17 7,529.19 7,652.09 -8,297.96-7,456.52 5,973,769.72 341,531.85 0.50 10,652.05 MWD+IFR2+SAG+MS (4) 15,268.23 87.77 332.26 7,534.55 7,735.55 -8,341.93-7,461.88 5,973,854.03 341,489.56 2.16 10,746.38 MWD+IFR2+SAG+MS (4) 15,362.74 89.98 332.27 7,536.41 7,819.18 -8,385.90-7,463.74 5,973,938.52 341,447.27 2.34 10,840.87 MWD+IFR2+SAG+MS (4) 15,457.23 92.77 330.95 7,534.14 7,902.27 -8,430.81-7,461.47 5,974,022.49 341,404.04 3.27 10,935.32 MWD+IFR2+SAG+MS (4) 15,553.63 94.83 330.58 7,527.75 7,986.20 -8,477.78-7,455.08 5,974,107.34 341,358.76 2.17 11,031.48 MWD+IFR2+SAG+MS (4) 15,648.51 93.32 330.52 7,521.01 8,068.61 -8,524.31-7,448.34 5,974,190.66 341,313.89 1.59 11,126.09 MWD+IFR2+SAG+MS (4) 15,743.04 94.84 329.94 7,514.28 8,150.46 -8,571.13-7,441.61 5,974,273.42 341,268.73 1.72 11,220.33 MWD+IFR2+SAG+MS (4) 15,837.69 94.71 330.94 7,506.40 8,232.50 -8,617.66-7,433.73 5,974,356.37 341,223.85 1.06 11,314.61 MWD+IFR2+SAG+MS (4) 15,932.25 95.76 330.87 7,497.78 8,314.78 -8,663.45-7,425.11 5,974,439.54 341,179.72 1.11 11,408.76 MWD+IFR2+SAG+MS (4) 16,027.94 94.90 329.96 7,488.89 8,397.63 -8,710.49-7,416.22 5,974,523.32 341,134.35 1.31 11,504.00 MWD+IFR2+SAG+MS (4) 16,122.54 92.16 330.43 7,483.06 8,479.56 -8,757.41-7,410.39 5,974,606.16 341,089.08 2.94 11,598.36 MWD+IFR2+SAG+MS (4) 16,216.80 91.23 331.63 7,480.27 8,561.98 -8,803.05-7,407.60 5,974,689.47 341,045.11 1.61 11,692.56 MWD+IFR2+SAG+MS (4) 16,311.85 91.45 331.31 7,478.05 8,645.47 -8,848.43-7,405.38 5,974,773.84 341,001.41 0.41 11,787.58 MWD+IFR2+SAG+MS (4) 16,406.93 90.71 331.02 7,476.26 8,728.75 -8,894.28-7,403.59 5,974,858.02 340,957.24 0.84 11,882.64 MWD+IFR2+SAG+MS (4) 16,501.53 89.76 330.50 7,475.87 8,811.29 -8,940.49-7,403.20 5,974,941.46 340,912.70 1.14 11,977.21 MWD+IFR2+SAG+MS (4) 16,596.21 89.76 330.50 7,476.27 8,893.69 -8,987.11-7,403.60 5,975,024.78 340,867.74 0.00 12,071.86 MWD+IFR2+SAG+MS (4) 16,690.84 89.79 331.34 7,476.64 8,976.39 -9,033.10-7,403.97 5,975,108.37 340,823.41 0.89 12,166.47 MWD+IFR2+SAG+MS (4) 16,785.70 89.79 331.65 7,476.99 9,059.75 -9,078.37-7,404.32 5,975,192.62 340,779.82 0.33 12,261.33 MWD+IFR2+SAG+MS (4) 16,880.68 89.76 331.35 7,477.36 9,143.22 -9,123.69-7,404.69 5,975,276.97 340,736.19 0.32 12,356.30 MWD+IFR2+SAG+MS (4) 16,974.88 89.70 331.87 7,477.80 9,226.09 -9,168.48-7,405.13 5,975,360.72 340,693.07 0.56 12,450.50 MWD+IFR2+SAG+MS (4) 17,069.59 91.14 331.99 7,477.11 9,309.66 -9,213.05-7,404.44 5,975,445.15 340,650.19 1.53 12,545.20 MWD+IFR2+SAG+MS (4) 17,163.97 91.11 332.02 7,475.26 9,392.98 -9,257.34-7,402.59 5,975,529.33 340,607.58 0.04 12,639.56 MWD+IFR2+SAG+MS (4) 17,261.25 91.14 332.28 7,473.35 9,478.97 -9,302.78-7,400.68 5,975,616.22 340,563.88 0.27 12,736.83 MWD+IFR2+SAG+MS (4) 17,353.06 91.14 331.98 7,471.52 9,560.12 -9,345.68-7,398.85 5,975,698.20 340,522.60 0.33 12,828.62 MWD+IFR2+SAG+MS (4) 17,448.36 91.08 332.16 7,469.67 9,644.30 -9,390.31-7,397.00 5,975,783.25 340,479.67 0.20 12,923.90 MWD+IFR2+SAG+MS (4) 17,543.08 91.60 332.20 7,467.46 9,728.05 -9,434.51-7,394.79 5,975,867.86 340,437.17 0.55 13,018.59 MWD+IFR2+SAG+MS (4) 17,637.54 92.19 331.91 7,464.34 9,811.45 -9,478.75-7,391.67 5,975,952.12 340,394.61 0.70 13,113.00 MWD+IFR2+SAG+MS (4) 17,732.32 92.22 332.02 7,460.69 9,895.05 -9,523.26-7,388.02 5,976,036.59 340,351.78 0.12 13,207.71 MWD+IFR2+SAG+MS (4) 17,827.10 92.31 332.38 7,456.94 9,978.82 -9,567.43-7,384.27 5,976,121.23 340,309.30 0.39 13,302.42 MWD+IFR2+SAG+MS (4) 17,921.82 91.76 332.28 7,453.58 10,062.66 -9,611.39-7,380.91 5,976,205.92 340,267.03 0.59 13,397.07 MWD+IFR2+SAG+MS (4) 18,016.57 91.48 332.43 7,450.90 10,146.56 -9,655.34-7,378.23 5,976,290.67 340,224.78 0.34 13,491.78 MWD+IFR2+SAG+MS (4) 18,111.05 91.30 332.32 7,448.61 10,230.24 -9,699.13-7,375.94 5,976,375.21 340,182.67 0.22 13,586.23 MWD+IFR2+SAG+MS (4) 18,205.91 91.30 332.28 7,446.46 10,314.21 -9,743.22-7,373.79 5,976,460.04 340,140.28 0.04 13,681.07 MWD+IFR2+SAG+MS (4) 18,300.67 90.25 332.18 7,445.18 10,398.05 -9,787.36-7,372.51 5,976,544.74 340,097.82 1.11 13,775.82 MWD+IFR2+SAG+MS (4) 18,395.47 89.76 332.18 7,445.17 10,481.89 -9,831.61-7,372.50 5,976,629.44 340,055.27 0.52 13,870.62 MWD+IFR2+SAG+MS (4) 18,490.51 89.30 332.31 7,445.95 10,565.99 -9,875.86-7,373.28 5,976,714.41 340,012.71 0.50 13,965.65 MWD+IFR2+SAG+MS (4) 3/9/2021 9:50:08AM COMPASS 5000.15 Build 91E Page 7 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope CD5 Alpine West Pad ConocoPhillips Definitive Survey Report Well: Wellbore: CD5-93 (12A) CD5-93 Survey Calculation Method:Minimum Curvature Real D25 @ 72.67usft (D25) Design:CD5-93 Database:EDT 15 Alaska Prod MD Reference:Real D25 @ 72.67usft (D25) North Reference: Well CD5-93 (12A) True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 18,585.51 90.10 332.05 7,446.44 10,650.01 -9,920.20-7,373.77 5,976,799.29 339,970.07 0.89 14,060.65 MWD+IFR2+SAG+MS (4) 18,680.27 90.16 331.49 7,446.23 10,733.50 -9,965.02-7,373.56 5,976,883.65 339,926.93 0.59 14,155.41 MWD+IFR2+SAG+MS (4) 18,774.92 90.13 331.73 7,445.99 10,816.76 -10,010.02-7,373.32 5,976,967.80 339,883.61 0.26 14,250.06 MWD+IFR2+SAG+MS (4) 18,870.07 90.78 331.77 7,445.23 10,900.58 -10,055.06-7,372.56 5,977,052.49 339,840.26 0.68 14,345.20 MWD+IFR2+SAG+MS (4) 18,965.05 91.42 332.80 7,443.41 10,984.64 -10,099.22-7,370.74 5,977,137.41 339,797.79 1.28 14,440.16 MWD+IFR2+SAG+MS (4) 19,060.50 91.24 332.43 7,441.20 11,069.37 -10,143.11-7,368.53 5,977,223.00 339,755.61 0.43 14,535.58 MWD+IFR2+SAG+MS (4) 19,155.30 91.27 332.32 7,439.12 11,153.35 -10,187.06-7,366.45 5,977,307.83 339,713.36 0.12 14,630.35 MWD+IFR2+SAG+MS (4) 19,250.08 90.50 332.64 7,437.66 11,237.39 -10,230.85-7,364.99 5,977,392.73 339,671.26 0.88 14,725.12 MWD+IFR2+SAG+MS (4) 19,344.95 90.28 332.10 7,437.01 11,321.44 -10,274.84-7,364.34 5,977,477.63 339,628.96 0.61 14,819.98 MWD+IFR2+SAG+MS (4) 19,439.95 90.28 332.56 7,436.55 11,405.57 -10,318.96-7,363.88 5,977,562.63 339,586.54 0.48 14,914.98 MWD+IFR2+SAG+MS (4) 19,535.12 90.25 332.20 7,436.10 11,489.90 -10,363.08-7,363.43 5,977,647.81 339,544.12 0.38 15,010.15 MWD+IFR2+SAG+MS (4) 19,630.25 90.22 333.06 7,435.71 11,574.38 -10,406.81-7,363.04 5,977,733.14 339,502.09 0.90 15,105.27 MWD+IFR2+SAG+MS (4) 19,725.36 90.34 332.77 7,435.25 11,659.05 -10,450.12-7,362.58 5,977,818.67 339,460.49 0.33 15,200.37 MWD+IFR2+SAG+MS (4) 19,820.38 90.25 332.45 7,434.76 11,743.42 -10,493.83-7,362.09 5,977,903.89 339,418.48 0.35 15,295.38 MWD+IFR2+SAG+MS (4) 19,915.07 90.22 333.03 7,434.37 11,827.59 -10,537.20-7,361.70 5,977,988.90 339,376.81 0.61 15,390.06 MWD+IFR2+SAG+MS (4) 20,010.44 90.31 330.93 7,433.93 11,911.78 -10,582.00-7,361.26 5,978,073.96 339,333.71 2.20 15,485.43 MWD+IFR2+SAG+MS (4) 20,105.46 90.28 331.97 7,433.44 11,995.24 -10,627.41-7,360.77 5,978,158.31 339,289.98 1.09 15,580.44 MWD+IFR2+SAG+MS (4) 20,200.38 90.34 331.88 7,432.93 12,078.99 -10,672.08-7,360.26 5,978,242.93 339,247.00 0.11 15,675.36 MWD+IFR2+SAG+MS (4) 20,294.59 90.74 332.04 7,432.04 12,162.14 -10,716.37-7,359.37 5,978,326.94 339,204.39 0.46 15,769.56 MWD+IFR2+SAG+MS (4) 20,389.68 91.82 331.38 7,429.92 12,245.85 -10,761.42-7,357.25 5,978,411.53 339,161.02 1.33 15,864.63 MWD+IFR2+SAG+MS (4) 20,484.24 91.82 331.79 7,426.91 12,328.98 -10,806.40-7,354.24 5,978,495.54 339,117.73 0.43 15,959.14 MWD+IFR2+SAG+MS (4) 20,579.46 91.76 331.97 7,423.94 12,412.91 -10,851.25-7,351.27 5,978,580.35 339,074.56 0.20 16,054.31 MWD+IFR2+SAG+MS (4) 20,674.07 91.23 331.98 7,421.47 12,496.40 -10,895.69-7,348.80 5,978,664.70 339,031.81 0.56 16,148.89 MWD+IFR2+SAG+MS (4) 20,768.81 91.27 331.48 7,419.40 12,579.82 -10,940.55-7,346.73 5,978,749.00 338,988.63 0.53 16,243.60 MWD+IFR2+SAG+MS (4) 20,863.65 90.84 331.47 7,417.66 12,663.14 -10,985.83-7,344.99 5,978,833.20 338,945.03 0.45 16,338.42 MWD+IFR2+SAG+MS (4) 20,958.52 89.70 331.30 7,417.21 12,746.42 -11,031.27-7,344.54 5,978,917.36 338,901.27 1.21 16,433.28 MWD+IFR2+SAG+MS (4) 21,054.06 89.70 331.75 7,417.71 12,830.40 -11,076.82-7,345.04 5,979,002.23 338,857.42 0.47 16,528.82 MWD+IFR2+SAG+MS (4) 21,149.19 88.81 332.06 7,418.95 12,914.31 -11,121.62-7,346.28 5,979,087.02 338,814.31 0.99 16,623.94 MWD+IFR2+SAG+MS (4) 21,244.34 88.26 331.37 7,421.38 12,998.07 -11,166.69-7,348.71 5,979,171.66 338,770.93 0.93 16,719.06 MWD+IFR2+SAG+MS (4) 21,339.30 87.83 329.30 7,424.62 13,080.53 -11,213.66-7,351.95 5,979,255.04 338,725.62 2.23 16,813.92 MWD+IFR2+SAG+MS (4) 21,433.57 88.66 330.48 7,427.51 13,162.04 -11,260.92-7,354.84 5,979,337.47 338,680.00 1.53 16,908.07 MWD+IFR2+SAG+MS (4) 21,529.15 88.63 332.46 7,429.77 13,245.99 -11,306.56-7,357.10 5,979,422.31 338,636.06 2.07 17,003.62 MWD+IFR2+SAG+MS (4) 21,624.97 90.19 330.71 7,430.75 13,330.25 -11,352.15-7,358.08 5,979,507.46 338,592.17 2.45 17,099.43 MWD+IFR2+SAG+MS (4) 21,719.72 91.05 329.23 7,429.73 13,412.27 -11,399.56-7,357.06 5,979,590.41 338,546.41 1.81 17,194.11 MWD+IFR2+SAG+MS (4) 21,815.03 91.02 328.76 7,428.01 13,493.95 -11,448.65-7,355.34 5,979,673.05 338,498.97 0.49 17,289.27 MWD+IFR2+SAG+MS (4) 21,910.76 91.11 330.15 7,426.23 13,576.38 -11,497.29-7,353.56 5,979,756.43 338,451.99 1.45 17,384.89 MWD+IFR2+SAG+MS (4) 22,005.97 91.08 331.33 7,424.41 13,659.43 -11,543.82-7,351.74 5,979,840.39 338,407.14 1.24 17,480.05 MWD+IFR2+SAG+MS (4) 22,101.33 91.14 332.82 7,422.56 13,743.67 -11,588.47-7,349.89 5,979,925.50 338,364.19 1.56 17,575.39 MWD+IFR2+SAG+MS (4) 22,196.69 91.79 332.65 7,420.12 13,828.40 -11,632.14-7,347.45 5,980,011.08 338,322.23 0.70 17,670.71 MWD+IFR2+SAG+MS (4) 22,291.93 92.37 332.95 7,416.67 13,913.06 -11,675.64-7,344.00 5,980,096.58 338,280.43 0.69 17,765.88 MWD+IFR2+SAG+MS (4) 3/9/2021 9:50:08AM COMPASS 5000.15 Build 91E Page 8 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope CD5 Alpine West Pad ConocoPhillips Definitive Survey Report Well: Wellbore: CD5-93 (12A) CD5-93 Survey Calculation Method:Minimum Curvature Real D25 @ 72.67usft (D25) Design:CD5-93 Database:EDT 15 Alaska Prod MD Reference:Real D25 @ 72.67usft (D25) North Reference: Well CD5-93 (12A) True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 22,387.28 92.37 332.77 7,412.72 13,997.83 -11,719.10-7,340.05 5,980,182.21 338,238.68 0.19 17,861.14 MWD+IFR2+SAG+MS (4) 22,481.95 92.34 332.87 7,408.83 14,081.98 -11,762.31-7,336.16 5,980,267.20 338,197.17 0.11 17,955.72 MWD+IFR2+SAG+MS (4) 22,577.35 91.64 335.43 7,405.52 14,167.77 -11,803.88-7,332.85 5,980,353.80 338,157.33 2.78 18,050.99 MWD+IFR2+SAG+MS (4) 22,672.76 91.57 338.08 7,402.85 14,255.40 -11,841.51-7,330.18 5,980,442.15 338,121.46 2.78 18,146.02 MWD+IFR2+SAG+MS (4) 22,767.98 91.67 333.41 7,400.15 14,342.15 -11,880.60-7,327.48 5,980,529.67 338,084.12 4.90 18,240.97 MWD+IFR2+SAG+MS (4) 22,862.69 91.60 330.77 7,397.45 14,425.81 -11,924.91-7,324.78 5,980,614.18 338,041.49 2.79 18,335.64 MWD+IFR2+SAG+MS (4) 22,958.25 91.64 331.83 7,394.75 14,509.59 -11,970.78-7,322.08 5,980,698.86 337,997.31 1.11 18,431.15 MWD+IFR2+SAG+MS (4) 23,053.22 91.91 331.63 7,391.81 14,593.19 -12,015.74-7,319.14 5,980,783.34 337,954.04 0.35 18,526.07 MWD+IFR2+SAG+MS (4) 23,148.48 91.88 331.83 7,388.66 14,677.04 -12,060.84-7,315.99 5,980,868.07 337,910.64 0.21 18,621.28 MWD+IFR2+SAG+MS (4) 23,243.53 91.97 331.68 7,385.46 14,760.73 -12,105.79-7,312.79 5,980,952.64 337,867.37 0.18 18,716.28 MWD+IFR2+SAG+MS (4) 23,338.60 91.85 331.74 7,382.30 14,844.40 -12,150.82-7,309.63 5,981,037.18 337,824.03 0.14 18,811.29 MWD+IFR2+SAG+MS (4) 23,433.52 91.79 329.57 7,379.28 14,927.09 -12,197.32-7,306.61 5,981,120.78 337,779.20 2.29 18,906.13 MWD+IFR2+SAG+MS (4) 23,528.53 91.45 330.00 7,376.60 15,009.16 -12,245.11-7,303.93 5,981,203.79 337,733.06 0.58 19,001.03 MWD+IFR2+SAG+MS (4) 23,624.08 90.25 331.47 7,375.18 15,092.50 -12,291.81-7,302.51 5,981,288.04 337,688.04 1.99 19,096.55 MWD+IFR2+SAG+MS (4) 23,718.81 88.41 331.79 7,376.29 15,175.85 -12,336.82-7,303.62 5,981,372.26 337,644.72 1.97 19,191.26 MWD+IFR2+SAG+MS (4) 23,813.93 87.37 331.73 7,379.79 15,259.59 -12,381.80-7,307.12 5,981,456.88 337,601.43 1.10 19,286.32 MWD+IFR2+SAG+MS (4) 23,909.59 88.75 331.17 7,383.03 15,343.56 -12,427.49-7,310.36 5,981,541.75 337,557.43 1.56 19,381.91 MWD+IFR2+SAG+MS (4) 24,004.90 88.99 331.80 7,384.91 15,427.29 -12,472.98-7,312.24 5,981,626.37 337,513.63 0.71 19,477.20 MWD+IFR2+SAG+MS (4) 24,099.78 89.09 331.60 7,386.50 15,510.82 -12,517.95-7,313.83 5,981,710.77 337,470.34 0.24 19,572.07 MWD+IFR2+SAG+MS (4) 24,195.53 88.32 331.53 7,388.66 15,595.00 -12,563.53-7,315.99 5,981,795.84 337,426.46 0.81 19,667.79 MWD+IFR2+SAG+MS (4) 24,290.91 88.04 330.89 7,391.69 15,678.55 -12,609.44-7,319.02 5,981,880.28 337,382.23 0.73 19,763.11 MWD+IFR2+SAG+MS (4) 24,386.87 87.43 330.94 7,395.48 15,762.34 -12,656.05-7,322.81 5,981,964.99 337,337.31 0.64 19,858.98 MWD+IFR2+SAG+MS (4) 24,481.16 87.49 333.21 7,399.66 15,845.56 -12,700.17-7,326.99 5,982,049.07 337,294.88 2.41 19,953.17 MWD+IFR2+SAG+MS (4) 24,575.85 88.41 332.73 7,403.05 15,929.86 -12,743.17-7,330.38 5,982,134.20 337,253.57 1.10 20,047.78 MWD+IFR2+SAG+MS (4) 24,671.23 88.90 332.48 7,405.29 16,014.52 -12,787.04-7,332.62 5,982,219.72 337,211.41 0.58 20,143.13 MWD+IFR2+SAG+MS (4) 24,766.50 89.33 332.39 7,406.76 16,098.96 -12,831.13-7,334.09 5,982,305.02 337,169.03 0.46 20,238.39 MWD+IFR2+SAG+MS (4) 24,860.86 89.98 332.33 7,407.33 16,182.55 -12,874.90-7,334.66 5,982,389.46 337,126.94 0.69 20,332.74 MWD+IFR2+SAG+MS (4) 24,957.01 90.47 332.45 7,406.95 16,267.75 -12,919.46-7,334.28 5,982,475.53 337,084.10 0.52 20,428.89 MWD+IFR2+SAG+MS (4) 25,052.75 90.90 332.75 7,405.80 16,352.74 -12,963.52-7,333.13 5,982,561.38 337,041.75 0.55 20,524.62 MWD+IFR2+SAG+MS (4) 25,148.20 91.45 333.05 7,403.85 16,437.70 -13,006.99-7,331.18 5,982,647.18 336,999.99 0.66 20,620.04 MWD+IFR2+SAG+MS (4) 25,243.59 92.77 333.16 7,400.33 16,522.71 -13,050.11-7,327.66 5,982,733.04 336,958.59 1.39 20,715.34 MWD+IFR2+SAG+MS (4) 25,338.71 93.42 332.24 7,395.20 16,607.11 -13,093.67-7,322.53 5,982,818.28 336,916.73 1.18 20,810.31 MWD+IFR2+SAG+MS (4) 25,434.31 94.22 332.07 7,388.83 16,691.45 -13,138.22-7,316.16 5,982,903.50 336,873.87 0.86 20,905.70 MWD+IFR2+SAG+MS (4) 25,529.70 93.39 332.15 7,382.50 16,775.58 -13,182.75-7,309.83 5,982,988.49 336,831.05 0.87 21,000.88 MWD+IFR2+SAG+MS (4) 25,624.71 93.51 331.93 7,376.78 16,859.34 -13,227.21-7,304.11 5,983,073.12 336,788.27 0.26 21,095.72 MWD+IFR2+SAG+MS (4) 25,719.36 94.28 331.57 7,370.35 16,942.53 -13,271.91-7,297.68 5,983,157.18 336,745.25 0.90 21,190.15 MWD+IFR2+SAG+MS (4) 25,814.50 94.74 331.14 7,362.87 17,025.76 -13,317.37-7,290.20 5,983,241.30 336,701.47 0.66 21,284.98 MWD+IFR2+SAG+MS (4) 25,908.88 95.39 331.19 7,354.54 17,108.12 -13,362.71-7,281.87 5,983,324.54 336,657.79 0.69 21,378.99 MWD+IFR2+SAG+MS (4) 26,003.48 95.64 331.15 7,345.45 17,190.61 -13,408.12-7,272.78 5,983,407.92 336,614.04 0.27 21,473.14 MWD+IFR2+SAG+MS (4) 26,098.73 96.19 330.83 7,335.63 17,273.46 -13,454.07-7,262.96 5,983,491.67 336,569.77 0.67 21,567.87 MWD+IFR2+SAG+MS (4) 3/9/2021 9:50:08AM COMPASS 5000.15 Build 91E Page 9 Project: Company:Local Co-ordinate Reference: TVD Reference: Site: NADConversion Western North Slope CD5 Alpine West Pad ConocoPhillips Definitive Survey Report Well: Wellbore: CD5-93 (12A) CD5-93 Survey Calculation Method:Minimum Curvature Real D25 @ 72.67usft (D25) Design:CD5-93 Database:EDT 15 Alaska Prod MD Reference:Real D25 @ 72.67usft (D25) North Reference: Well CD5-93 (12A) True MD (usft) Inc (°) Azi (°) +E/-W (usft) +N/-S (usft) Survey TVD (usft) TVDSS (usft) Map Northing (ft) Map Easting (ft) Vertical Section (ft) DLS (°/100')Survey Tool Name 26,177.00 96.19 330.83 7,327.19 17,341.41 -13,491.99-7,254.52 5,983,560.36 336,533.21 0.00 21,645.66 PROJECTED to TD CD5-93 T02 T 090120 - CD5-93 T02 T 032520 - CD5-93 (12A) T02 Toe 091218 3/9/2021 9:50:08AM COMPASS 5000.15 Build 91E Page 10 !! 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" (-** * **+-*..;.4 3((33 -1500-1250-1000-750-500-250025050075010001250South(-)/North(+) (500 usft/in)-2000 -1750 -1500 -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 1500 1750 2000 2250West(-)/East(+) (500 usft/in)CD5-93 (12A)CD5-01CD5-03CD5-04CD5-06CD5-07CD5-11CD5-17CD5-22CD5-90CD5-98CD5-01CD5-02CD5-02CD5-02CD5-03CD5-03CD5-04CD5-05CD5-05CD5-06CD5-06CD5-07CD5-10CD5-11CD5-12CD5-12CD5-17CD5-17CD5-17CD5-19CD5-22CD5-22CD5-23CD5-23CD5-90CD5-92CD5-92CD5-96CD5-98CD5-98CD5-98CD5-99CD5-99CD5-90CD5-93 (12A)Plan ViewCD5-93 Page 1/1 CD5-93 Report Printed: 2/11/2021 Cement Detail Report Cement Details Description Surface String Cement Cementing Start Date 1/17/2021 10:15 Cementing End Date 1/17/2021 13:30 Wellbore Name CD5-93 Comment Cement Stages Stage # 1 Description Primary – Full Bore Objective Cement 10.75" Surface casing in place Top Depth (ftKB) 39.0 Bottom Depth (ftKB) 2,194.0 Full Return? Yes Vol Cement … 54.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 6 Q Pump Final (bbl/… 6 Q Pump Avg (bbl/… 6 P Pump Final (psi) 437.0 P Plug Bump (psi) 700.0 Recip? Yes Stroke (ft) 20.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Lead: Class G 11.0ppg, Yield 1.91 scf/sack, Mix Water 6.650 gal/sack, 250% Excess above BOPF, 50% Excess below, Estimated TOC = Surface. Tail: Class G 15.8ppg, Yield 1.16 scf/sack, Mix Water 5.083 gal/sack, 50 % Excess. Estimated TOC = 1415'. No losses and floats held. 54 bbls cement returns to surface. Cement Fluids & Additives Fluid Fluid Type Spacer Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class *NOT IN LIBRARY Volume Pumped (bbl) 75.0 Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) 10.50 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Lead Cement Fluid Description Estimated Top (ftKB) 38.9 Est Btm (ftKB) 1,415.0 Amount (sacks) 1,005 Class G Volume Pumped (bbl) 342.0 Yield (ft³/sack) 1.91 Mix H20 Ratio (gal/sa… 6.65 Free Water (%) Density (lb/gal) 11.00 Plastic Viscosity (cP) 265.0 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 1,415.0 Est Btm (ftKB) 2,194.0 Amount (sacks) 281 Class G Volume Pumped (bbl) 58.1 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sa… 5.08 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 156.0 Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Surface String Cement Job: DRILLING ORIGINAL, 1/11/2021 12:00 !" ! ! "#$!%&' "#$! %&' (! )*+ ! %& )*+ ! %&,$*-'*. !%& ,$*-'*. !%& (/0! # $ %&' (( # $ )*)+ *&,(( #-./!$$0- 1 . *&*2%34 *&*2%3 %)55 '&) (( )&2 ((1*""!46 (" 4 #7 ##8 9#$ 1 1 1 6 '')) +'-4: *&2*("1 *2* ;;;//<=6& >#- %)?'&*," !-@%)55&++" !4A.?&B5)*0)261 ! = 4464 #7 #13/4#0%035 6 0(/(* 1 ! =- 1 7+--+ /8$8""+2 Page 4/22 CD5-93 Report Printed: 2/11/2021 Operations Summary (with Timelog Depths) 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) 1/15/2021 08:30 1/15/2021 10:30 2.00 SURFAC, CASING CIRC P Circulate Bottoms Up X4 while racking back a stand each BU from 2204' MD to 1824 MD. 850 gpm, 2412 psi, 50 rpm, 3- 5k tq, 69% flow out, 124k up wt, 113k dn wt, 120k rot wt. Total strokes pumped = 15058. 2,204.0 1,824.0 1/15/2021 10:30 1/15/2021 11:00 0.50 SURFAC, CASING OWFF P Flow check, Observe well for flow - No Flow. 1,824.0 1,824.0 1/15/2021 11:00 1/15/2021 12:30 1.50 SURFAC, CASING TRIP P POOH on elevators F/1824' MD to 1133' MD, W 5" DP, Rack back in derrick. PU Wt =115k, S/O Wt = 105k while monitoring displacement on pit 2. 1,824.0 1,133.0 1/15/2021 12:30 1/15/2021 13:30 1.00 SURFAC, CASING PMPO P Pump out of hole F/ 1133' MD T/ 691' MD, 500 gpm, 943 psi, 35% FO. PU Wt =100k, S/O Wt = 87k while monitoring displacement on pit 1-4. 1,133.0 691.0 1/15/2021 13:30 1/15/2021 14:30 1.00 SURFAC, CASING TRIP P POOH on elevators F/691' MD to 135' MD, W 5" DP, Rack back in derrick. PU Wt =115k, S/O Wt = 105k while monitoring displacement on pit 2. 691.0 135.0 1/15/2021 14:30 1/15/2021 15:00 0.50 SURFAC, CASING OWFF P Observe well for flow - No Flow. - PJSM for lay down BHA. 135.0 135.0 1/15/2021 15:00 1/15/2021 17:30 2.50 SURFAC, CASING BHAH P Lay down BHA #1 as per Baker rep F/ 135' to surface, PU Wt 60k, S/O wt 55k, Monitor displacement on pit #2. Bit and BHA came out clean. 135.0 0.0 1/15/2021 17:30 1/15/2021 18:30 1.00 SURFAC, CASING CLEN P Clean and clear rig floor in preparation to pick up casing. Lay down BHI subs as per Baker rep. Blow down jet line and fill the hole. 0.0 0.0 1/15/2021 18:30 1/15/2021 20:45 2.25 SURFAC, CASING RURD P PU Casing equipment. Rig up Volant tool, swivel sub. Torque to top drive @ 37k lbs. Rig up 6' pony bails and 125T side door elevator. Rig up PS-21 slips F 10-3/4" casing. PU floor valve XO and MU. Pick up strap tongs. 0.0 0.0 1/15/2021 20:45 1/16/2021 00:00 3.25 SURFAC, CASING PUTB P PJSM - PU 10-3/4" TXP, 45.5#, L-80 casing, installing centralizers and Baker locking the shoe track as per completion detail F/ surface to 665' MD. PU Wt 78k, S/O Wt 83k. Fill shoe track and test floats. Running casing W/ Volant tool as per Doyon casing rep. Torquing TXP connections to 27,200 ft/lbs. Maintaining constant hole fill over the top and topping off every 10th joint W Volant tool. **Encountered obstruction @ 665' MD. Attempt to wash through, stage pumps up slowly to 252 gpm while working pipe. ICP = 98 psi, FCP = 65 psi. Tour losses = 0 bbl. 0.0 665.0 1/16/2021 00:00 1/16/2021 06:00 6.00 SURFAC, CASING PUTB T Continue working 10.75 in, 45.5#, L80, TXP casing in the hole F/ 665' - T/ 710' MD. Stage pumps to 6 BPM, 64 psi, 34% flow out, 76k up wt, 88k dn wt, Apply quarter turns while working pipe F/ 700' - T/ 708' MD. Begin rotating at 1 RPM while applying 5k-12k over dn wt. 2-6k tq. Minimal gravel, clay and wood coming over the shakers. 665.0 710.0 Rig: DOYON 25 Page 5/22 CD5-93 Report Printed: 2/11/2021 Operations Summary (with Timelog Depths) 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) 1/16/2021 06:00 1/16/2021 10:00 4.00 SURFAC, CASING PUTB T Continue rotating 10.75 in, 45.5#, L80, TXP casing in the hole F/ 710' - 775' MD, 6 bpm, 90 psi, 34% flow out, 3-5 rpm, 5-6k tq, 76k up wt, 88k dn wt, 75k rot wt. Minimal gravel, clay and wood coming over the shakers. 710.0 775.0 1/16/2021 10:00 1/16/2021 12:30 2.50 SURFAC, CASING PUTB P Wash 10.75 in, 45.5#, L80, TXP casing in the hole F/ 775' - 1,424' MD, 6 bpm, 110 psi, 54% flow out, 108k up wt, 98k dn wt. Monitor displacement on pits #2 and #3. Begin bleeding in Gelplex pill. 775.0 1,424.0 1/16/2021 12:30 1/16/2021 13:30 1.00 SURFAC, CASING CIRC P Circulate bottoms up while reciprocating F/1,386' - T/ 1,424' MD, 8 bpm, 153 psi, 32% flow out, 115k up wt, 104k dn wt. 3,069 total strokes. 1,424.0 1,424.0 1/16/2021 13:30 1/16/2021 22:00 8.50 SURFAC, CASING PUTB T Continue rotating 10.75 in, 45.5#, L80, TXP casing in the hole F/ 1,424' - T/ 1,811' MD, stage up pumps F/ 6 bpm - 11 bpm, 90- 215 psi, 3-5 rpm, 4-6k tq, 54-64% flow out, 128k up wt, 124k dn wt, 120k rot wt. 1,424.0 1,811.0 1/16/2021 22:00 1/17/2021 00:00 2.00 SURFAC, CASING PUTB P Increase pumps to 12 bpm and wash 10.75 in, 45.5#, L80, TXP casing down F/1,811' - T/2,005' MD with 10-15k below dn wt, 235 psi. 45% flow out, 130k up wt, 126k dn wt. 1,811.0 2,005.0 1/17/2021 00:00 1/17/2021 04:15 4.25 SURFAC, CASING PUTB P Continue to P/U and run 10-3/4" 45.5# L -80 TXP casing, installing centralizers per detail. Washing down casing as needed from 2,005' MD to 2,194' MD, washing down through 36' of fill on bottom. Picked up pups, XO joint, hanger and landing joint.Washed down landing joint @ 6-11 bpm, 90-226 psi, P/U=151k, S/O=124k. Land on hanger at 2,194' MD. 2,005.0 2,194.0 1/17/2021 04:15 1/17/2021 09:00 4.75 SURFAC, CEMENT CIRC P Circulate and condition mud for cement through Volant tool, stage pumps up to 8 bpm, reciprocate 20' strokes landing on the ring every 5th stroke. P/U=144, S/O=140k. 2,194.0 2,194.0 1/17/2021 09:00 1/17/2021 09:30 0.50 SURFAC, CEMENT RURD P Shut down mud pump, blow down top drive and R/U to circulate through cement hose. 2,194.0 2,194.0 1/17/2021 09:30 1/17/2021 10:15 0.75 SURFAC, CEMENT CIRC P Circulate through cement hose, reciprocating from 2,194' MD to 2,174' MD, 2 bpm=108 psi, 3 bpm=118 psi, 4 bpm=153 psi, 5 bpm=170 psi, 6 bpm=205 psi 24% flow, 7 bpm=240 psi 28% flow, 8 bpm=280 psi 30% flow out. P/U=144k, S/O=140k. SIMOPS- PJSM on cementing surface casing with SLB, MI, DDI, CPAI, ASRC 2,194.0 2,194.0 1/17/2021 10:15 1/17/2021 12:45 2.50 SURFAC, CEMENT CMNT P Shut down rig pumps, swap to SLB. Pump 5 bbl water and PT lines to 700 psi/3500 psi good. SLB pumped 75 bbl 10.5 ppg Mud Push II, rig dropped bottom plug. SLB followed with 341.8 bbl 11.0 ppg Lead cement, 58.1 bbl 15.8 ppg Tail cement. Rig dropped top plug. SLB kicked out plug with 20 bbl water. 2,194.0 2,194.0 Rig: DOYON 25 Page 6/22 CD5-93 Report Printed: 2/11/2021 Operations Summary (with Timelog Depths) 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) 1/17/2021 12:45 1/17/2021 13:30 0.75 SURFAC, CEMENT DISP P Rig displaced cement with 9.8 ppg KSI Klashield mud @ 4 bpm, 550-700 psi with full returns. Plug bumped @ 1865 stks, pressured up to 1630 psi and held for 5 minutes. 2,194.0 2,194.0 1/17/2021 13:30 1/17/2021 14:00 0.50 SURFAC, CEMENT OWFF P Check floats - good no flow. Flow check annulus very slight drop in riser. 2,194.0 0.0 1/17/2021 14:00 1/17/2021 16:00 2.00 SURFAC, CEMENT CLEN P Flush and clean flow box, flowline, riser, cuttings tank and all lines to Ball Mill 0.0 0.0 1/17/2021 16:00 1/17/2021 20:00 4.00 SURFAC, WHDBOP NUND P Nipple down the flow box, flow line and surface annular. Drained the stack and nipple down the riser, blinded tee and starting head. Clean equipment and send outside. removed 4" conductor valves and cap off. 0.0 0.0 1/17/2021 20:00 1/17/2021 23:30 3.50 SURFAC, WHDBOP OTHR P Clean wellhead and prepare for epoxy cap. Mix and poor cement/epoxy mixture per HES rep. Allow 1 hour for thickening time. SIMOPS- Rig up the test pump, pick up wellhead to the rig floor and stage in the BOP deck. Clean pits, cement line valves, gas anilizer and flow paddle. Load the floor with BHI drilling tools, LD 90' mouse hole, assemble FOSV and IBOP dart valve. 0.0 0.0 1/17/2021 23:30 1/18/2021 00:00 0.50 SURFAC, WHDBOP NUND P Nipple up FMC Gen 5 wellhead, test seals to 1,000 psi for 10 minutes. (tested good) 0.0 0.0 1/18/2021 00:00 1/18/2021 05:00 5.00 SURFAC, WHDBOP NUND P Finish nipple up FMC Gen 5 wellhead, nipple up DSA, high pressure drilling riser, and BOP's. Install the flowline rig floor drains, joes box, choke and kill lines. Install MPD hoses per MPD rep. Install 90' mouse hole and measure RKB's 0.0 0.0 1/18/2021 05:00 1/18/2021 06:00 1.00 SURFAC, WHDBOP RURD P Pick up 5 in test joint and install the test plug. Rig up to test BOP's. Fill lines and purge air out of equipment. 0.0 0.0 1/18/2021 06:00 1/18/2021 10:30 4.50 SURFAC, WHDBOP BOPE P Test BOPE all tests 250psi low, 3,500psi high for 5 minutes each with exception of manual and super chokes tested to 2,000psi. With 5" test joint test annular and 2 7/8" x 5 1/2" UPR and LPR, test choke valves 1-15, manual and super choke, choke and kill manual's and HCR's, 4" valve on kill line, 5" FOSV, 5" dart valve, upper and lower IBOP, blind/shear rams. Perform Koomey drawdown, ACC=2900 psi, manifold=1500psi initial. After all functions, accumulator=1500 psi, 19 secs to 200 psi with two electric pumps, 113 secs to build to full system pressure with two electric and two air pumps. Closing times, annular=23secs, UPR=18secs, blind/shears=16secs, LPR=16 secs, choke HCR=2 secs, kill HCR=2secs. 6 Nitrogen bottles back-up avg=1885psi, CPAI witnessed. Tested PVT, gain/loss, flow out, LEL and H2S alarms. Test witnessed by AOGCC Lou Laubenstein 0.0 0.0 Rig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age 1/2 CD5-93 Report Printed: 2/11/2021 Cement Detail Report Cement Details Description Intermediate String 1 Cement Cementing Start Date 1/28/2021 23:27 Cementing End Date 1/31/2021 05:00 Wellbore Name CD5-93 Comment Cement Stages Stage # 1 Description Stage Cementing Objective Top Depth (ftKB) 11,960.0 Bottom Depth (ftKB) 14,525.0 Full Return? Yes Vol Cement … 0.0 Top Plug? Yes Btm Plug? Yes Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 4 P Pump Final (psi) 480.0 P Plug Bump (psi) 1,000.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 60 bbls of 13.0 ppg Mud Push II, dropped bypass plug, pumped 140 bbls of 15.8 Qannik Slurry Blend @ 4 bpm, dropped shutoff plug, pumped 20 bbls water and dispaced with rig at 4bpm due to losses incurred while running casing. Plugs did not bump during displacement b/c baffle collar was inadvertently not ran in casing string. Well was over displaced & leaving a wet shoe due to stroke counter discrepancy. Cement Fluids & Additives Fluid Fluid Type Spacer Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) 60.0 Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) 13.00 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 12,169.0 Est Btm (ftKB) 14,526.0 Amount (sacks) 677 Class G Volume Pumped (bbl) 140.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sa… 5.02 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 131.0 Thickening Time (hr) 5.22 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Displacement Fluid Description Estimated Top (ftKB) 0.0 Est Btm (ftKB) 14,526.0 Amount (sacks) Class Volume Pumped (bbl) 651.0 Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) 10.60 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Stage # 2 Description Stage Cementing Objective Top Depth (ftKB) 4,535.0 Bottom Depth (ftKB) 6,050.0 Full Return? Yes Vol Cement … 0.0 Top Plug? Yes Btm Plug? No Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 2 Q Pump Avg (bbl/… 4 P Pump Final (psi) 342.0 P Plug Bump (psi) 1,800.0 Recip? No Stroke (ft) Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment Pumped 10 bbls of FW @ 3.2 bpm & pressure tested lines 3500 psi high (good test), Pumped 34 bbls of 13.0 ppg Mud Push II, 58 bbls of 15.8 ppg Qannik slurry, dropped plug, pumped 20 bbls of FW, & displaced with 259.7 bbls of 10.6 mud all at 4 bpm. At 10 bbls short of bumping slowed rate to 2 bpm & bumped plug. Pressured up to 1800 psi & held for 2 min to shift stage tool closed. Bled off pressure, 2.0 bbls returned, observed flow (no flow), Repressured up to 1800 psi & held for 2 min before bleeding off pressure. Cement Fluids & Additives Fluid Fluid Type Spacer Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) Class Volume Pumped (bbl) 40.0 Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) 13.00 Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Intermediate String 1 Cement Job: DRILLING ORIGINAL, 1/11/2021 12:00 Page 2/2 CD5-93 Report Printed: 2/11/2021 Cement Detail Report Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 4,535.0 Est Btm (ftKB) 6,050.0 Amount (sacks) 281 Class G Volume Pumped (bbl) 58.0 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sa… 5.04 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 103.0 Thickening Time (hr) 3.97 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Displacement Fluid Description Estimated Top (ftKB) 0.0 Est Btm (ftKB) 6,050.0 Amount (sacks) Class Volume Pumped (bbl) 260.7 Yield (ft³/sack)Mix H20 Ratio (gal/sa…Free Water (%) Density (lb/gal) Plastic Viscosity (cP) Thickening Time (hr) CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Intermediate String 1 Cement Job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age 13/22 CD5-93 Report Printed: 2/11/2021 Operations Summary (with Timelog Depths) 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) 1/26/2021 14:00 1/26/2021 17:00 3.00 INTRM1, CASING BHAH P PJSM, Pulled & LD BHA F/ 465' T/ Surface. 465.0 0.0 1/26/2021 17:00 1/26/2021 18:00 1.00 INTRM1, CASING WWWH P Wash stack and clean up rig floor from TOOH. 0.0 0.0 1/26/2021 18:00 1/26/2021 18:30 0.50 INTRM1, CASING PULD P PJSM, Pull wear bushing per wellhead hands rec. 0.0 0.0 1/26/2021 18:30 1/26/2021 19:30 1.00 INTRM1, CASING RURD P CO upper VBR's to 7 5/8" fixed rams 0.0 0.0 1/26/2021 19:30 1/26/2021 21:00 1.50 INTRM1, CASING BOPE P Fill the stack test BOP's 250 low & 2,500 psi high for the annular & 3,500 psi high on the rams for 5 min. 0.0 0.0 1/26/2021 21:00 1/26/2021 22:00 1.00 INTRM1, CASING RURD P PJSM, MU 7 5/8" casing running equipment and prep for running casing 0.0 0.0 1/26/2021 22:00 1/27/2021 00:00 2.00 INTRM1, CASING PUTB P PU & MU 7 5/8" #29.7 L-80 shoe track. Pump & verify floats (passed) T/ 340' MD 0.0 340.0 1/27/2021 00:00 1/27/2021 06:00 6.00 INTRM1, CASING PUTB P RIH w/ 7-5/8" #29.7 L-80 TXP, F/ 340' T/ 2,852' MD, top off every joint & fill every 10 jts. PU 102k, SO 98k 340.0 2,852.0 1/27/2021 06:00 1/27/2021 08:30 2.50 INTRM1, CASING PUTB P RIH w/ 7-5/8" #29.7 L-80 TXP, F/ 2,852' T/ 4,744' MD, top off every joint & fill every 10 jts. PU 102k, SO 98k 2,852.0 4,744.0 1/27/2021 08:30 1/27/2021 09:30 1.00 INTRM1, CASING CIRC P Circ BU at the Qannik @ 6 bpm, 253 psi, 22% flow out, PU 170k, SO 156k. 4,744.0 4,744.0 1/27/2021 09:30 1/27/2021 17:30 8.00 INTRM1, CASING PUTB P RIH w/ 7-5/8" #29.7 L-80 TXP, F/ 4,744' T/ 8,630' MD, top off every joint & fill every 10 jts. PU 102k, SO 98k 4,744.0 8,630.0 1/27/2021 17:30 1/27/2021 19:00 1.50 INTRM1, CASING CIRC P Circ to condition mud & improve casing running @ 6 bpm, 253 psi, 22% flow out, PU 170k, SO 156k. 8,630.0 8,630.0 1/27/2021 19:00 1/28/2021 00:00 5.00 INTRM1, CASING PUTB P RIH w/ 7-5/8" #29.7 L-80 TXP, F/ 8,630' T/ 11,492' MD, top off every joint & fill every 10 jts. SO 147k 8,630.0 11,492.0 1/28/2021 00:00 1/28/2021 03:00 3.00 INTRM1, CASING PUTB P Continue RIH w/ 7-5/8" #29.7 L-80 TXP, F/ 11,492' T/ 13,049' MD, top off every joint & fill every 10 jts. SO 147k 11,492.0 13,049.0 1/28/2021 03:00 1/28/2021 06:00 3.00 INTRM1, CASING CIRC T Circ F/ 13,049' T/ 13,088' MD. Staged pumps up to 6 bpm, for 30 min then losses were observed. Stepped pumps down but returns were lossed. Began to work pipe and slowly work mud out of the hole. 13,049.0 13,088.0 1/28/2021 06:00 1/28/2021 12:00 6.00 INTRM1, CASING CIRC T Continued working pipe F/ 13,088' T/ 13,128' MD to circulate out heavy mud and slowly regained circulation. Began stepping the pumps up to 4.5 bpm @ 480 psi & 22% flow out. 13,088.0 13,128.0 1/28/2021 12:00 1/28/2021 15:30 3.50 INTRM1, CASING PUTB P Continue RIH w/ 7-5/8" #29.7 L-80 TXP, F/ 13,128' T/ 14,485' MD, top off every joint & fill every 10 jts. SO 147k 13,128.0 14,485.0 1/28/2021 15:30 1/28/2021 23:00 7.50 INTRM1, CASING CIRC P MU hanger & landing Jt RIH T/ 14,527' MD. Tag and verify landing. Slowly stage up pumps to 6 bpm 14,485.0 14,527.0 1/28/2021 23:00 1/29/2021 00:00 1.00 INTRM1, CEMENT CMNT P PJSM, pressure test lines to 3,500 psi, begin puming 60 bbls of mud push ll, drop bypass plug, 140 bbls of #15.8 ppg cmt, drop shut-off plug, 20 bbls FW, & displace w/ 647 bbls of displacement 14,527.0 14,527.0 Rig: DOYON 25 Page 14/22 CD5-93 Report Printed: 2/11/2021 Operations Summary (with Timelog Depths) 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) 1/29/2021 00:00 1/29/2021 04:30 4.50 INTRM1, CEMENT CMNT P Continue pumping 60 bbls MP II 13.0 ppg, bottom plug, 140 bbls 15.8 ppg Qannik Slurry, top plug, 20 bbls FW, 647 bbls 10.6 ppg mud displacement @ 4 bpm. Plugs did not bump. Pumped 1/2 shoe track (3 bbls). Plugs still did not bump 14,527.0 14,527.0 1/29/2021 04:30 1/29/2021 06:00 1.50 INTRM1, CEMENT RURD T RD casing equipment & RU 5" handling equipment in order to lay down 5" DP 14,527.0 14,527.0 1/29/2021 06:00 1/29/2021 11:30 5.50 INTRM1, CEMENT PULD T LD 5" DP in derrick 14,527.0 14,527.0 1/29/2021 11:30 1/29/2021 12:00 0.50 INTRM1, CEMENT RURD T RU volant & cement lines 14,527.0 14,527.0 1/29/2021 12:00 1/29/2021 12:30 0.50 INTRM1, CEMENT PRTS T Pressure test surface lines T/ 3,500 psi, attempt to pressure up T/ 3,000 psi to shift stage tool open. Pressure up to 1,250 psi pressure dropped while pumping, Pressure up again T/ 1,070 psi and pressure dropped to 500 psi 14,527.0 14,527.0 1/29/2021 12:30 1/29/2021 13:45 1.25 INTRM1, CEMENT WAIT T Wait till cement built comp strength 14,527.0 14,527.0 1/29/2021 13:45 1/29/2021 14:00 0.25 INTRM1, CEMENT CIRC T Pump 10 bbls @ 4 BPM, pressure up T/ 930 psi then it dropped off, bleed off pressure, BD cmt linges 14,527.0 14,527.0 1/29/2021 14:00 1/29/2021 15:00 1.00 INTRM1, CEMENT CIRC T Drop free fall opening plug & wait 45 min. pumped 30 bbls, pressure up T/ 900 psi, then bled off T/ 640. Increased rate to 6 bpm, pressured up to 740 psi and bled to 700 psi. NOTE!! It was discovered later this evening that the baffle collar was not run in the asing string as planned. There was no collar for the 1st stage shut-off plug to land on. 14,527.0 14,527.0 1/29/2021 15:00 1/29/2021 17:00 2.00 INTRM1, CEMENT RURD T RD volant & cmt equipment, PU rig floor, & PU 4" handling equipment 14,527.0 14,527.0 1/29/2021 17:00 1/29/2021 19:00 2.00 INTRM1, CEMENT RURD T C/O saver sub from 4-1/2" IF to XT39. 14,527.0 14,527.0 1/29/2021 19:00 1/29/2021 19:30 0.50 INTRM1, CEMENT PULD T Drain stack & pull landing joint per FMC rec. 14,527.0 14,527.0 1/29/2021 19:30 1/29/2021 21:30 2.00 INTRM1, CEMENT SVRG T PJSM, Slip & cut drill line 11 wraps 14,527.0 14,527.0 1/29/2021 21:30 1/29/2021 23:00 1.50 INTRM1, WHDBOP RURD P CO 7-5/8" casing rams to 2-7/8" x 5-1/2" VBR's 14,527.0 14,527.0 1/29/2021 23:00 1/29/2021 23:30 0.50 INTRM1, WHDBOP WWWH P PU wash tool, flush wellhead & stack 14,527.0 14,527.0 1/29/2021 23:30 1/30/2021 00:00 0.50 INTRM1, WHDBOP RURD P Install test plug per FMC rec, flood lines & stack for testing 14,527.0 14,527.0 1/30/2021 00:00 1/30/2021 00:45 0.75 INTRM1, WHDBOP RURD P Flood stack & lines. Shell test BOP but unable to obtain pressure 14,527.0 14,527.0 1/30/2021 00:45 1/30/2021 01:30 0.75 INTRM1, WHDBOP SVRG P Found 4" kill line valve was washed out and had to change it out. Re-shell test to 3,500 psi and achived good test 14,527.0 14,527.0 Rig: DOYON 25 Page 15/22 CD5-93 Report Printed: 2/11/2021 Operations Summary (with Timelog Depths) 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) 1/30/2021 01:30 1/30/2021 05:00 3.50 INTRM1, WHDBOP BOPE P Test BOPE, all test T/ 250 psi low, & 3,500 psi hight for 5 min charted. W/ exception of manual operated & superchoke tested T/ 2,000 psi for 3 min & bled dn T/ 1,500 psi for 3 min. Tested with both 4" & 4.5" test joints Wnnular, 2 7/8" x 5 1/2" UPR, 2 7/8" x 5 1/2" LPR, tested choke valves 1-15, , choke & kill manuals & HCR's, 4" valve on kill line, 4" FOSV, 4" Dart valve, upper & lower IBOP & blind/shear rams. Koomey drawdown test, ACC= 3025 psi, Manif= 1500 psi, ACC= 1750 psi, after all functions on bottles, 13 sec for 200 psi, & 80 sec for full pressure on 2 electric pumps & 2 air pumps. Closing time on ann= 23 s, UPR= 18 sec, blind/shear= 16 sec, LPR= 16 sec, choke HCR= 2 sec, kill HCR= 2 sec. 1866 psi ave on 6 backup bottles. Tested PVT bain/loss & flow out alarms, tested LEL & H2S alarms. AOGCC rep Adam Earl waived witness 1/28/21 @ 18:53 14,527.0 14,527.0 1/30/2021 05:00 1/30/2021 06:15 1.25 INTRM1, CEMENT WWSP P Install upper packer off per FMC rep. Pressure test to ensure seal. Install wear bushing 14,527.0 14,527.0 1/30/2021 06:15 1/30/2021 07:00 0.75 INTRM1, CEMENT PULD T Clear & clean rig floor. SIMOPS- load & process 4" DP in casing shed 14,527.0 14,527.0 1/30/2021 07:00 1/30/2021 07:45 0.75 INTRM1, CEMENT SVRG T Grease TDS traction motor & service Iron Roughneck 14,527.0 14,527.0 1/30/2021 07:45 1/30/2021 08:30 0.75 INTRM1, CEMENT PULD T Gather BHA & finish processing 4" DP in the pipe shed 14,527.0 14,527.0 1/30/2021 08:30 1/30/2021 15:00 6.50 INTRM1, CEMENT TRIP T MU Johnny wacker & stabilizer. XO to DP T/ 5,734' PU- 117k & SO- 112k. Push free falling plug into stage tool 8.5k 0.0 5,734.0 1/30/2021 15:00 1/30/2021 16:00 1.00 INTRM1, CEMENT CIRC T Circ, rot, & recip pipe @ 340 gpm, 660 psi. PU117k, SO 112k. & BD TDS 5,734.0 5,734.0 1/30/2021 16:00 1/30/2021 16:30 0.50 INTRM1, CEMENT TRIP T Cont RIH on singles F/ 5,734' T/ 6,057' MD PU 117k, SO- 110k, Set down 8k DW to seat free falling opening plug 5,734.0 6,057.0 1/30/2021 16:30 1/30/2021 19:00 2.50 INTRM1, CEMENT CIRC T Stage pumps T/ 723 psi & shifted tool open. Lined up and circulated BU @ 4.5 bpm 6,057.0 6,057.0 1/30/2021 19:00 1/30/2021 22:00 3.00 INTRM1, CEMENT TRIP T POOH rack back DP T/ Surface. LD BHA 6,057.0 0.0 1/30/2021 22:00 1/30/2021 22:30 0.50 INTRM1, CEMENT CIRC T MU into last stand and wash stack 0.0 0.0 1/30/2021 22:30 1/30/2021 23:30 1.00 INTRM1, CEMENT RURD T Drain stack, pull wear ring, & pull upper packoff 0.0 0.0 1/30/2021 23:30 1/31/2021 00:00 0.50 INTRM1, CEMENT RURD T PU & MU landing joint. PU cement head, verify tattle tail, MU cross over to landing joint and screw on cement head 0.0 0.0 1/31/2021 00:00 1/31/2021 00:45 0.75 INTRM1, CEMENT RURD P MU cement head XO, PU cement head & install cement lines. Loaded top plug (witnessed by COP rep) 0.0 0.0 1/31/2021 00:45 1/31/2021 02:00 1.25 INTRM1, CEMENT CIRC P Stage pump up to 6 bpm @ 227 psi, 21% flow out & circulated bottoms up 0.0 0.0 Rig: DOYON 25 Page 16/22 CD5-93 Report Printed: 2/11/2021 Operations Summary (with Timelog Depths) 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) 1/31/2021 02:00 1/31/2021 05:00 3.00 INTRM1, CEMENT CMNT P Pumped 10 bbls of FW @ 3.2 bpm & pressure tested lines 3500 psi high (good test), Pumped 34 bbls of 13.0 ppg Mud Push II, 58 bbls of 15.8 ppg Qannik slurry, dropped plug, pumped 20 bbls of FW, & displaced with 259.7 bbls of 10.6 mud all at 4 bpm. At 10 bbls short of bumping slowed rate to 2 bpm & bumped plug. Pressured up to 1800 psi & held for 2 min to shift stage tool closed. Bled off pressure, 2.0 bbls returned, observed flow (no flow), Repressured up to 1800 psi & held for 2 min before bleeding off pressure. 0.0 0.0 1/31/2021 05:00 1/31/2021 05:30 0.50 INTRM1, CEMENT OWFF P Flow checked the well (no flow) SIMOPS: RD cement head, clean head, BD lines & clean out cement valves 0.0 0.0 1/31/2021 05:30 1/31/2021 06:30 1.00 INTRM1, CEMENT WWSP P Pull landing joint per FMC, PU test joint & install upper packoff. Pressure test T/ 250 psi & T/ 5,000 psi for 10 min. Test witnessed by COP rep 0.0 0.0 1/31/2021 06:30 1/31/2021 07:00 0.50 INTRM1, CEMENT RURD P Install wear ring per FMC rep 0.0 0.0 1/31/2021 07:00 1/31/2021 07:30 0.50 INTRM1, CEMENT SVRG P Service TDS SIMOPS: Bring BHA to the floor 0.0 0.0 1/31/2021 07:30 1/31/2021 09:15 1.75 INTRM1, CEMENT BHAH T PJSM, PU BHA #4 per BHI DD T/ 269' MD. Monitor via TT 0.0 269.0 1/31/2021 09:15 1/31/2021 16:00 6.75 INTRM1, CEMENT TRIP T TIH F/ 269' T/ 5,901' MD picking up singles to ~2,300' MD & swapping to doubles. PU 122k, SO 115k, fill every 20 stds & monitor via TT 269.0 5,901.0 1/31/2021 16:00 1/31/2021 17:00 1.00 INTRM1, CEMENT WASH T Wash F/ 5,901' T/ 6,054' MD @ 225 gpm, 750 psi, 23% flow out, PU 122k, SO 112k, TO 116k, 5k TQ 5,901.0 6,054.0 1/31/2021 17:00 1/31/2021 22:00 5.00 INTRM1, CEMENT MILL T Mill stage collar & cement stringers F/ 6,054' MD T/ 6,180' MD. @ 225 gpm, 740 psi, 60 rpm, 5k TQ, 20% flow out, PU 122k, SO 118k, RT 116k. Once through the stage collar worked through collar tool 2 times. On the last time killed the pumps & rotary to slack off past tool and no bobbles seen. SIMOPS: Freeze protected the well; pressure tested lines to 3,000 psi, pressured up to 6,054.0 6,180.0 1/31/2021 22:00 1/31/2021 23:00 1.00 INTRM1, CEMENT TRIP T TIH F/ 6,180' T/ 7,252' MD, PU 124k & SO 118k. Monitor via TT 6,180.0 7,252.0 1/31/2021 23:00 1/31/2021 23:30 0.50 INTRM1, CEMENT SVRG T Service TDS & blocks 7,252.0 7,252.0 1/31/2021 23:30 2/1/2021 00:00 0.50 INTRM1, CEMENT TRIP T TIH F/ 7,252' T/ 7,952' MD, PU 126k, SO 120k monitor via TT 7,252.0 7,952.0 2/1/2021 00:00 2/1/2021 01:15 1.25 INTRM1, CEMENT TRIP T Continue TIH F/ 7,952' T/ 9,000' MD monitor via TT. & fill every 2,000' 7,952.0 9,000.0 2/1/2021 01:15 2/1/2021 07:00 5.75 INTRM1, CEMENT TRIP T TIH at 1,800'/hr to log cement F/ 9,000' T/ 14,318' MD monitor via TT. & fill every 2,000' 9,000.0 14,318.0 2/1/2021 07:00 2/1/2021 07:45 0.75 INTRM1, CEMENT WASH T Wash & ream F/ 14,318' T/ 14,428' MD @ 232 gpm, 1,385 psi, 24% flow out, 14k TQ, PU 220k, SO 120k, & RT 168k 14,318.0 14,428.0 2/1/2021 07:45 2/1/2021 08:00 0.25 INTRM1, CEMENT WASH T PU, kill rotary, wash down and confirm bottom @ 14,428' MD w/ 10k wt 14,428.0 14,428.0 Rig: DOYON 25 !"" #$ %&' "% () $% () $%*+,(-% (+!,% -*+,(-*+. ,(- !"### $!% % !% $%% %!/01! ! ! $! /2! ! ! & $! %!/! ! ! $% ! ! ! !! ! $ ! /34/5453/2 !' 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C:\Users\vtloepp\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\N3IL9ADU\2 10216_CD5-93 note to file.doc Note to File CD5-93 (PTD 2200730, Sundry 321-082) Colville River Unit (Alpine Oil Pools) ConocoPhillips Alaska, Inc ConocoPhillips has made application to authorize annular disposal in the subject well. This document examines the pertinent information for the well and recommends approval of ConocoPhillips’ request. -- No unusual events were reported while drilling the surface hole of the well (CD5-93). -- 10 3/4” Surface casing was cemented to surface successfully with no losses experienced. Cement report put excess cement to surface of 54 bbls with 400 bbl Class G cement pumped. No problems reported. -- On the initial Formation Integrity Test (FIT) for the surface casing shoe dated 1/18/2021, the pressure slope rises smoothly with test stopping at 1.5 bbl pumped and 810 psi to yield the desired 16.7 ppg EMW. The pressure declined slightly from 810 to 700 psi (15.75 ppg EMW) during the 10 minute shut in period with the 1.0 bbl being bled back. The initial FIT indicates that the surface casing shoe is well cemented. An open hole injectivity test was completed on 1/29/2021 prior to running and cementing the 7.625” casing with a depth of the casing shoe of 2195 ft MD/ 2188 ft TVD and an open hole to est 4961 ft MD yielding a 13.4 ppg EMW. The test showed pressure rising steadily with the slight tangent change at the 13.4 ppg EMW and a sharp break over point at approximately 13.67 ppg EMW. -- The 7.625” casing was run and successfully cemented with a two stage job and shoe of 14525 ft. First stage cement was pumped and was estimated as 14525 to TOC 11650 ft MD. Cement tool at 6050 ft was opened and the 2nd stage pumped without problems with that TOC estimated at 4536 ft MD. A “SonicScope Top of Cement” evaluation log processed on 2/1/2021 was run from 2475 ft MD to TD and shows a TOC of 11650 ft with improving cement to shoe. The sonic tool ran out of memory passing up at 4600 ft but indicated good cement from 6050 to approx. 4600 ft. --There are multiple wells currently drilled or planned to be drilled within ¼ mile radius of CD5- 93 and the CPAI application contains supporting cementing and LOT well information and mentions that well and cementing information is already on file with AOGCC. The surface shoe of CD5-11 is closest, about 164’ distant. AD is already prolific on CD5 and it is expected to continue with additional CD5 wells. CPAI is therefore constructing the CD5 wells to be compliant with AD regulations. Examination of the cementing information and LOT data did not reveal anything to preclude granting CPAI’s request. Based on examination of the submitted information, I recommend approval of ConocoPhillips’ request for the subject well. Chris Wallace Sr. Petroleum Engineer AOGCC February 16, 2021 Note to File CRU CD5-93 (PTD 221-073) February 16, 2021 Re: ConocoPhillips’ Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD5-93 Request ConocoPhillips requests approval to dispose of 35,000 barrels of drilling waste in well CRU CD5-93. Recommendation Approve ConocoPhillips’ request. Conclusions 1. In CD5-93, the surface casing shoe is set at 2,194’ measured depth (MD; equivalent to -2,115’ true vertical depth subsea1), near the base of a 450-foot thick shale-, claystone-, and siltstone-dominated interval that persists throughout the area. This interval will prevent upward migration of injected fluids. 2. There appears to be a sufficient volume of sandstone and sandy siltstone open to the annulus of this well to accept the proposed injected fluids. 3. Lower confining layers are sufficiently thick and laterally persistent to ensure injected materials remain within the disposal interval. 4. There are no potential USDWs in this area. There are no water wells within one mile of CD5-93. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The volume of sediments most strongly impacted by the proposed annular injection operation will likely lie within about 100’ of the CD5-93 wellbore. 8. Injected fluids will likely reach one or more nearby wells that have open annuli beneath their surface casing shoes. However, if this occurs, surface casing, surface casing cement (to surface), and thick, laterally continuous confining layers of shale, claystone, and siltstone will ensure injected fluids remain within the disposal interval. Discussion ConocoPhillips’ application was reviewed along with records from Colville River Unit CD5-93 (CD5-93), nearby development wells, and exploratory well Nuiqsut 1, which is located 1-1/2 miles to the northeast. The discussion that follows is based on information, well logs, and mud logs from these wells. An index map is provided in Figure 1, below. The proposed annular disposal injection interval in this well lies in the Torok and Seabee Formations within Section 7, T11N, R4E, Umiat Meridian, which is about 2 miles from the current exterior boundary of the Colville River Unit. The surface casing shoe of CD5-93 lies at 2,194’ MD (-2,115’ TVDSS), near the base of a 450-foot thick interval that is dominated by shale, claystone, and siltstone and is continuous throughout 1 Unless otherwise noted, all depths presented herein as positive integers represent measured depth in feet. All depths expressed as negative integers represent true vertical depth (in feet) below mean sea level (mean low, low water; herein termed true vertical feet subsea, which is abbreviated “TVDSS”). All thicknesses are expressed as positive integers, which represent true vertical feet. All horizontal distances are expressed as positive integers, which represent feet. CD5-93 Annular Disposal February 16, 2021 Note to File Page 2 of 5 the area. This interval will provide upper confinement for fluids disposed in the annulus of the well (see Figure 2, below). In CD5-93, the annulus open to disposal extends downward from the surface casing shoe at 2,194’ MD (-2,115’ TVDSS) to the top of second-stage cement for the 7-5/8” casing string, which is estimated to lie at 4,536’MD (-3,849’ TVDSS). The portion of the open annulus that will most likely accept the injected waste is a 185-foot thick interval that contains several 1- to 8-foot thick beds of sandstone and sandy siltstone that lie below the surface casing shoe between about 2,332’ MD (-2,250’ TVDSS) and 2,520’ MD (-2,435’ TVDSS). The aggregate thickness of these thin, potential receptor layers is about 30’. These layers are separated by thin claystone intervals. Beneath the disposal interval are several intervals of claystone that are continuous throughout the area and will provide lower confinement for any injected wastes. Figure 1. CD5-93 Index Map (The magenta-colored line depicts the path of the cross-section displayed in Figure 2.) The index map above displays trajectories for all wells drilled from the Colville River Unit CD5 Drill Site. The locations of the surface casing shoes for all well bores are depicted with green-colored triangles. The calculated top of second-stage cement for the CD5-93 intermediate casing string (4,536’ MD, -3,849’ TVDSS) is indicated by the orange-colored semi-circle. Thirty three wells are currently open to these same strata within the ¼-mile radius area of review: CD5-01, CD5-02, CD5-03, CD5-04, CD5-05, CD5-06, CD5- 07, CD5-08, CD5-09, CD5-10, CD5-11, CD5-12, CD5-17, CD5-18, CD5-19, CD5-20, CD5-21, CD5-22, CD5-23, CD5-24, CD5-25, CD5-26, CD5-28, CD5-90, CD5-92, CD5-96, CD5-98, CD5-99A, CD5-313, CD5-314, CD5-314X, CD5-315, and CD5-316. Figure 2, below, presents a structural cross-section view of CD5-93 and nearby wells CD5-19 and CD5-01, which were logged to the ground surface. Resistivity measurements indicate that the base of permafrost occurs at about -1,250’ in the CD5 Drill Site area, which is about 865’ above the CD5-93 surface casing shoe. 0 500 feet NORTH Surface Casing Shoe Locations Top of Second‐Stage Cement for Intermediate Casing CD5‐93 Open Annulus Surface Casing Shoe for CD5‐93 Most Likely Disposal Interval CD5-93 Annular Disposal February 16, 2021 Note to File Page 3 of 5 Figure 2. CD5-93 Area: Structural Cross-section (Depth scale represents true vertical feet. Horizontal separation footages shown between wells are the approximate distances between the surface casing shoes.) Mud logs were recorded in only two wells drilled at the CD5 Drill Site, CD5-04 and CD5-313, that were drilled through the shallow geologic section using somewhat similar drilling mud weights (typically 9.8 to 9.9 pounds per gallon). These mud logs suggest the shallow geologic section in the area contains predominantly methane gas, with minor amounts of ethane, propane, and butane. The shallowest occurrences of more significant amounts of methane encountered in these wells (arbitrarily placed at 20 units of gas—equivalent to 4,000 ppm—on the mud log) were about -1,850’and -2,000’, respectively. So, the entire proposed annular disposal interval likely contains small, non-commercial amounts of methane gas. Surface Casing Cement Surface Casing Cement Surface Casing Cement Most Likely Disposal Interval Lower Confining Layers Upper Confining Interval Surface Casing Shoe Open Annulus Permafrost Base at ‐1,250’ TVDSS 590’ 660’ SW NE Top of Cement 4,536’ MD, ‐3,849’ TVDSS Upper Confining Interval CD5-93 Annular Disposal February 16, 2021 Note to File Page 4 of 5 Unfortunately, oil shows are not recorded on the mud logs obtained in CD5-04 and CD5-313, likely due to the use of oil-base drilling mud. In ARCO’s Nuiqsut 1 exploratory well, located about 1-1/2 miles to the northeast, the shallowest oil show was encountered at 3,990’ MD (-3,930’ TVDSS), with a second show encountered at 4,115’ MD (-4,055’ TVDSS). The mud logging geologists rated these shows as fair to poor in quality. These oil shows occur in thin sandstones that are encapsulated above and below by claystone and mudstone. These oil shows indicate the presence of only trace to minor quantities of oil in the geologic strata that may be affected by annular disposal in CD5-93. These shows do not represent commercial quantities of oil. Supporting documentation to ConocoPhillips’ annular disposal applications states: “There are no USDW aquifers in the Colville River Unit.” This is correct. Conclusion 3 of Area Injection Order No. 18, which governs the Alpine Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit. The Alaska Department of Natural Resources’ Alaska Mapper web application, accessed February 16, 2021, confirms that there are no publicly recorded water wells within one mile of CD5-93. Figure 3. CD5-93 Area Likely Affected by Annular Injection (Assuming uniform, piston-like, radial displacement of 50% of native formation fluids) The gamma ray well log curve recorded in CD5-93 indicates that an aggregate total of about 30 true vertical feet of sandstone and sandy siltstone are present within the most likely disposal interval. Inspection of density porosity logs from correlative strata in nearby wells suggests porosity averages about 30% at this depth. Based on these values, the volume of rock that will receive 35,000 barrels of injected fluids lies within a radius of about 120’ from the CD5-93 wellbore, assuming uniform, radial, piston-like displacement of half of the native formation fluids (Figure 3, above). The surface casing shoes of the three closest wells— CD5-07, CD5-10, and CD5-11—are located between about 150’ and 250’ from the most likely disposal CD5-93 Annular Disposal February 16, 2021 Note to File Page 5 of 5 interval within CD5-93. However, review of the daily drilling summaries indicates that surface casings in these three wells were cemented to surface with full returns. If fluids injected into CD5-93 reach uncemented annuli beneath the surface casing shoes in any of the three nearby wells, surface casing, surface casing cement, and thick, laterally continuous confining layers will ensure those fluids remain within the intended interval. Summary The limited volume of rock that will be affected by this proposed annular disposal operation is situated beneath 1,250’ of permafrost and is bounded above and below by continuous confining layers of shale, claystone, and siltstone. The disposal interval lies inside the Colville River Unit, far from any external property lines, so correlative rights are not a concern. There are no freshwater aquifers present, and there are no water wells within one mile of CD5-93. The disposal interval does not include any potentially commercial hydrocarbon accumulations. Surface casing, surface-casing cement (to surface), and laterally continuous layers of shale, claystone, and siltstone will prevent injected fluids from migrating out of zone. I recommend approving the proposed annular disposal operations within CRU CD5-93 to the requested limit of 35,000 barrels. Steve Davies Senior Petroleum Geologist 1 Davies, Stephen F (CED) From:Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent:Tuesday, February 16, 2021 12:35 PM To:Davies, Stephen F (CED) Subject:CD5-93 Final Actual Wellpath Attachments:Final_CD5-93__AWP.xlsx Steve, Let me know if this does not work‐ Greg Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263‐4749 I C: (907) 231‐0515 1 Davies, Stephen F (CED) From:Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Sent:Tuesday, February 16, 2021 12:32 PM To:Davies, Stephen F (CED) Subject:RE: CD5-93Surface and Intermediate Section Logs Steve, These logs were for CD5‐93. That is what I get for talking and typing… Greg _____________________________________________ From: Hobbs, Greg S Sent: Tuesday, February 16, 2021 12:30 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: CD5‐96 Surface and Intermediate Section Logs << File: CPAI_CD5‐93_RUN 01_DEPTH_MEM ‐ Copy.las >> << File: CPAI_CD5‐93_RUN 01_DEPTH_MEM.las >> << File: CPAI_CD5‐93_RUN 02_DEPTH_MEM.las >> Greg Hobbs, P.E. Regulatory Engineer I Wells Team I W: (907) 263‐4749 I C: (907) 231‐0515 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By: P.1. Supry BODE Test Report for: COLVILLE RIVER UNIT CD5-93 ✓ Comm Contractor/Rig No.: Doyon 25 PTD#: 2200730 - DATE: 1/18/2021 - Inspector Lou Laubenstein Insp Source Operator: ConocoPhillips Alaska, Inc. Operator Rep: Reinhart / Tucker Rig Rep: Potter/Williams Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopLOL2101 18 1 64847 / Rams: Annular: Valves: MASP: T — ype Test: [NIT 250/3500' 250/25000 _ 250/3500 - 2618 ' Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Upper Kelly I P/F Lower Kelly Visual Alarm Time/Pressure l P/F Location Gen.: P Trip Tank P P System Pressure 2900 P Housekeeping: P Pit Level Indicators P P Pressure After Closure 1500 P PTD On Location P_ Flow Indicator P P 200 PSI Attained 19 P Standing Order Posted -P Meth Gas Detector P P Full Pressure Attained 113 P Well Sign P 112S Gas Detector P P Blind Switch Covers: Quantity P " Drl. Rig P - MS Misc NA NA Nitgn. Bottles (avg): 6_a 1985 " P Hazard Sec. P -' Check Valve 0 NA ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly I _ P - Lower Kelly - - 1 P Ball Type l P Inside BOP _ 1 P FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA No. Valves 15 P, Annular Preventer 1 13-5/8" P _ Manual Chokes _ 1 P #1 Rams 1 2-7/8 x 5-1/2' P Hydraulic Chokes l P #2 Rams - 1 Blind/Shear' P CH Misc 0 NA #3 Rams 1 2-7/8 x 5-1/2- P #4 Rams NA_ __0 #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 P/F 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: 0 ✓` Test Results Test Time 4.5 Remarks: Test was completed using a 5" test joint. Good test no issues and the rig looked good. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Paul McGrath Engineering Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD5-93 ConocoPhillips Alaska, Inc. Permit to Drill Number: 200-073 Surface Location: 263’ FNL, 2335’ FEL, SEC. 18, T11N, R4E, UM Bottomhole Location: 555’ FNL, 2179’ FEL, SEC. 27, T12N, R3E, UM Dear Mr. McGrath: Enclosed is the approved application for the permit to drill the above referenced service 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, Jeremy M. Price Chair DATED this ___ day of December, 2020. Sincerely, 18 220-073 ! 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y Samantha Carlisle at 3:22 pm, Nov 18, 2020 220-073 DSR-11/18/2020SFD 12/2/2020 50-103-20827-00-00 SFD 11/20/2020 BOP test to 3500 psig Annular preventer test to 2500 psig. See attached Conditions of Approval for the intermediate cement job and sonic logging. XDiverter waiver granted per 20 AAC 25.035(h)(2) Provide Surface Casing LOT as soon as available VTL 12/16/20 ce Casing LOT as so 12/11111666/20 12/18/2020 12/18/2020 CRU CD5-93(PTD 220-073) Conditions of Approval: Approval is granted to run the LWD-Sonic on upcoming well CRU CD5-93 with the following provisions: 1. CPAI will provide a written log evaluation/interpretation to the AOGCC along with the log as soon as they become available. The evaluation is to include/highlight the intervals of competent cement (and lengths) that CPAI is using to meet the objective requirements for annular isolation, reservoir isolation, or confining zone isolation etc. Providing the log without an evaluation/interpretation is not acceptable. 2. LWD sonic logs must show free pipe and Top of Cement, just as the e-line log does. CPAI must start the log at a depth to ensure the free pipe above the TOC is captured as well as the TOC. 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' 3 5+! 8 D 8>)887"42( /( -"?( <44 5 % - 47 ? % <4 &7 4 <D4 % - & & 7 4& & & (<7 % -& & % % & 4& & 4 87@7)887"42( /( -"?( <44 % % & &H7 4' & 4& D % 04H 0 7 2 % ? & M D4 ( % D (& 4&& & 7 87.%)&'2( /( -"?( <44 % % & &H7 4' & 4& D % 04H 0 7 2% ? & D4 ( % D (& 4&& & 7 !" 0 6 !%78 @ 7 H4 10 )11 7 ) '%78 7 23 7 )%- ) ?8 7)%-7 ) % ((43DE@B8@-7 47H F )(%- 9 7 ) From:Rawlins, Tom D To:AOGCC Permitting (CED sponsored) Cc:Hobbs, Greg S Subject:CD5-93 PTD app - completion tubing change Date:Tuesday, December 8, 2020 12:07:45 PM Attachments:CD5-93wp06 Completion Schematic 12-04-20 draft.png Greetings, Regarding the 4.5” tubing that is currently planned to be run in the CD5-93 completion, in the PTD application we originally were planning to run Tenaris Blue above the production packer and TXP below in the tubing tail. The current plan now is to run Tenaris Blue in all of the completion, replacing the TXP in the tubing tail in order to use up excess inventory. This change will not affect the function or safety of the well, and the PTD application can be updated to reflect this change if that is desired. I have attached the updated completion schematic. Please let us know if you have any questions, thank you, Thomas D Rawlins Drilling Engineer Wells Engineering Team ConocoPhillips Alaska (907) 230-0325 cell (918) 662-8429 fax !" ' 3 5 +3 !" ' 3 #5 41 250 250 440 440 640 640 830 830 1020 1020 1220 1220 1410 1410 1600 1600 2750 2750 3900 3900 5050 5050 6200 6200 7350 7350 8500 8500 9650 9650 10800 10800 13090 13090 15390 15390 17680 17680 19970 19970 22270 22270 24560 24560 26850 26850 29408 CD5-93 wp06 Plan Summary 0 3 Dogleg Severity0 4500 9000 13500 18000 22500 27000 Measured Depth 10-3/4 x 13-1/2 7-5/8 x 9-7/8 by 11 45 90 0 90 180 270 30 210 60 240 120 300 150 330 Azimuth from North [°] vs Travelling Cylinder Separation [90 usft/in] 1782 1872 1958 CD5-07 4316 4386 CD5-23CD5-23L1-01 41602 901 1000 1097 1194 CD5-90 41 602 901 1099 1198 CD5-92 41402 801 900 1095CD5-96 41 CD5-98 100400 699 798 41 504 703 902 1100CD5-95 wp02 186 785885 0 4000 True Vertical Depth0 3500 7000 10500 14000 17500 21000 24500 Vertical Section at 332.00° 10-3/4 x 13-1/2 7-5/8 x 9-7/8 by 11 0 33 65 Centre to Centre Separation0 4250 8500 12750 17000 21250 25500 29750 Measured Depth Equivalent Magnetic Distance DDI 7.401 SURVEY PROGRAM Date: 2017-05-10T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 41.10 1300.00 CD5-93 wp06 (CD5-93)GYD-GC-SS 1300.00 2190.00 CD5-93 wp06 (CD5-93)MWD OWSG 1300.00 2190.00 CD5-93 wp06 (CD5-93)MWD+IFR2+SAG+MS 2190.00 2290.00 CD5-93 wp06 (CD5-93) MWD-INC_ONLY (INC>10°) 2290.00 3790.00 CD5-93 wp06 (CD5-93) MWD OWSG 2290.00 12430.00 CD5-93 wp06 (CD5-93) MWD+IFR2+SAG+MS 12430.00 12530.00 CD5-93 wp06 (CD5-93) MWD-INC_ONLY (INC>10°) 12530.00 14030.00 CD5-93 wp06 (CD5-93) MWD OWSG 12530.00 30113.01 CD5-93 wp06 (CD5-93) MWD+IFR2+SAG+MS Surface Location North / 5965699.58 East / 1489707.47 Ground / 33.60 CASING DETAILS TVD MD Name 2189.50 2194.39 10-3/4 x 13-1/2 7480.70 14355.21 7-5/8 x 9-7/8 by 11 7342.70 30113.01 4-1/2 x 6-3/4 Mag Model & Date: BGGM2020 31-Dec-20 Magnetic North is 15.29° East of True North (Magnetic Declinatio Mag Dip & Field Strength: 80.64° 57280.75nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 41.10 0.00 0.00 41.10 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 Start Build 1.50 3 500.00 3.00 150.00 499.91 -4.53 2.62 1.50 150.00 -5.23 Start 700.00 hold at 500.00 MD 4 1200.00 3.00 150.00 1198.95 -36.26 20.93 0.00 0.00 -41.84 Start Drop -1.20 5 1450.00 0.00 0.00 1448.84 -41.93 24.21 1.20 180.00 -48.38 Start 55.66 hold at 1450.00 MD 6 1505.66 0.00 0.00 1504.50 -41.93 24.21 0.00 0.00 -48.38 Start Build 1.50 7 1805.66 4.50 300.00 1804.19 -36.04 14.01 1.50 300.00 -38.40 Start Build 1.50 8 2194.39 10.33 300.00 2189.50 -10.97 -29.42 1.50 0.00 4.13 Start 20.00 hold at 2194.39 MD 9 2214.39 10.33 300.00 2209.18 -9.17 -32.53 0.00 0.00 7.17 Start DLS 2.50 TFO 11.22 10 4530.02 68.04 310.24 3930.11 863.90 -1126.76 2.50 11.221291.76 Start 8759.60 hold at 4530.02 MD 11 13289.62 68.04 310.24 7205.51 6112.06 -7328.30 0.00 0.008837.06 Start DLS 3.00 TFO 73.00 12 13955.21 75.00 330.00 7418.24 6594.73 -7728.70 3.00 73.009451.20 Start Build 3.00 13 14355.21 87.00 330.00 7480.70 6936.25 -7925.87 3.00 0.009845.32 CD5-93 T01 H 090120 Start 20.00 hold at 14355.21 MD 14 14375.21 87.00 330.00 7481.75 6953.55 -7935.86 0.00 0.009865.28 Start DLS 1.50 TFO 28.02 15 14642.19 90.54 331.88 7487.49 7186.82 -8065.48 1.50 28.0210132.09 Start 15470.82 hold at 14642.19 MD 16 30113.01 90.54 331.88 7342.7020830.93-15356.81 0.00 0.0025602.20 CD5-93 T02 T 090120 TD at 30113.01 FORMATION TOP DETAILS TVDPathFormation 1399.70Base Perm 2324.70 C-30 2845.70 C-10 3768.70 K-3 3997.70 K-2 4046.70 K-2 Base 5258.70 Alp 96 7139.70 FCS Top 7191.70 Kalubik 7303.70 Kup C 7314.70 LCU 7455.70 Alp C 7466.70 UJU 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 surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by Accepted by Approved by Plan D25 @ 74.70usft (D25) 060001200018000True Vertical Depth (3000 usft/in)06000120001800024000Vertical Section at 332.00° (3000 usft/in)10-3/4 x 13-1/27-5/8 x 9-7/8 by 114-1/2 x 6-3/4100020003000400050006000700080009000100001100012000130001400015 000 16 000 17000 1800 0 1900 0 20000 21000 22000 23000 24000 25000 26000270002800029000 3000030113Plan: CD5-93 (12A)/CD5-93 wp06 Section View Project: Western North SlopeSite: CD5 Alpine West PadWell: Plan: CD5-93 (12A)Wellbore: CD5-93Design: CD5-93 wp06 Plan View Project: Western North SlopeSite: CD5 Alpine West PadWell: Plan: CD5-93 (12A)Wellbore: CD5-93Design: CD5-93 wp06070001400021000South(-)/North(+) (3500 usft/in)-21000 -14000 -7000 0 7000West(-)/East(+) (3500 usft/in)10-3/4 x 13-1/27-5/8 x 9-7/8 by 114-1/2 x 6-3/450010001500200025003000350040004500500055006000650070007343Plan: CD5-93 (12A)/CD5-93 wp06 Standard Proposal Report 02 November, 2020 Plan: CD5-93 wp06 ConocoPhillips Alaska Inc_WNS Western North Slope CD5 Alpine West Pad Plan: CD5-93 (12A) 50103xxxxx00 CD5-93 ConocoPhillips Standard Proposal Report Well Plan: CD5-93 (12A)Local Co-ordinate Reference:Database:EDT 15 Alaska Prod Plan D25 @ 74.70usft (D25)TVD Reference:ConocoPhillips Alaska Inc_WNSCompany: Plan D25 @ 74.70usft (D25)MD Reference:Western North SlopeProject: TrueNorth Reference:CD5 Alpine West PadSite: Minimum CurvatureSurvey Calculation Method:Plan: CD5-93 (12A)Well: CD5-93Wellbore: CD5-93 wp06Design: Map System: Geo Datum: Project Map Zone: System Datum:US State Plane 1983 North American Datum 1983 Western North Slope, North Slope Alaska, United States Alaska Zone 4 Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Position: From: Site Latitude: Longitude: Position Uncertainty: Northing: Easting: Grid Convergence: CD5 Alpine West Pad Map -1.15 °Slot Radius:13.200 in 5,965,528.00 usft 1,489,252.00 usft 0.00 usft 70° 18' 47.778 N 151° 13' 30.647 W Well Well Position Longitude: Latitude: Easting: Northing: +E/-W +N/-S Position Uncertainty Ground Level: Plan: CD5-93 (12A) 5,965,699.58 usft 1,489,707.47 usft 33.60 usftWellhead Elevation:0.00 usft0.00 usft 70° 18' 49.555 N 151° 13' 17.462 W 180.73 usft 451.96 usft Wellbore Declination (°) Field Strength (nT) Sample Date Dip Angle (°) CD5-93 Model NameMagnetics BGGM2020 12/31/2020 15.29 80.64 57,280.75 Phase:Version: Audit Notes: Design CD5-93 wp06 PLAN Started with wp04, adjusted targets. Vertical Section: Depth From (TVD) (usft) +N/-S (usft) Direction (°) +E/-W (usft) Tie On Depth:41.10 332.000.000.0041.10 11/2/2020 4:44:29PM COMPASS 5000.15 Build 91E Page 2 1983 70° 18' 49.555 N 151° 13' 17.462 W ConocoPhillips Standard Proposal Report Well Plan: CD5-93 (12A)Local Co-ordinate Reference:Database:EDT 15 Alaska Prod Plan D25 @ 74.70usft (D25)TVD Reference:ConocoPhillips Alaska Inc_WNSCompany: Plan D25 @ 74.70usft (D25)MD Reference:Western North SlopeProject: TrueNorth Reference:CD5 Alpine West PadSite: Minimum CurvatureSurvey Calculation Method:Plan: CD5-93 (12A)Well: CD5-93Wellbore: CD5-93 wp06Design: Depth From (usft) Plan Survey Tool Program RemarksTool NameSurvey (Wellbore) Depth To (usft) Date 9/15/2020 GYD-GC-SS Gyrodata gyro single shots CD5-93 wp06 (CD5-93)41.10 1,300.001 MWD OWSG OWSG MWD - Standard CD5-93 wp06 (CD5-93)1,300.00 2,190.002 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag CD5-93 wp06 (CD5-93)1,300.00 2,190.003 MWD-INC_ONLY (INC>10° MWD-INC_ONLY_FILLER ( CD5-93 wp06 (CD5-93)2,190.00 2,290.004 MWD OWSG OWSG MWD - Standard CD5-93 wp06 (CD5-93)2,290.00 3,790.005 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag CD5-93 wp06 (CD5-93)2,290.00 12,430.006 MWD-INC_ONLY (INC>10° MWD-INC_ONLY_FILLER ( CD5-93 wp06 (CD5-93)12,430.00 12,530.007 MWD OWSG OWSG MWD - Standard CD5-93 wp06 (CD5-93)12,530.00 14,030.008 MWD+IFR2+SAG+MS OWSG MWD + IFR2 + Sag CD5-93 wp06 (CD5-93)12,530.00 30,113.019 Inclination (°) Azimuth (°) +E/-W (usft) TFO (°) +N/-S (usft) Measured Depth (usft) Vertical Depth (usft) Dogleg Rate (°/100usft) Build Rate (°/100usft) Turn Rate (°/100usft) Plan Sections Target 0.000.000.000.000.000.0041.100.000.0041.10 0.000.000.000.000.000.00300.000.000.00300.00 150.000.001.501.502.62-4.53499.91150.003.00500.00 0.000.000.000.0020.93-36.261,198.95150.003.001,200.00 180.000.00-1.201.2024.21-41.931,448.840.000.001,450.00 0.000.000.000.0024.21-41.931,504.500.000.001,505.66 300.000.001.501.5014.01-36.041,804.19300.004.501,805.66 0.000.001.501.50-29.42-10.972,189.50300.0010.332,194.39 0.000.000.000.00-32.53-9.172,209.18300.0010.332,214.39 11.220.442.492.50-1,126.76863.903,930.11310.2468.044,530.03 0.000.000.000.00-7,328.306,112.067,205.51310.2468.0413,289.62 73.002.971.053.00-7,728.706,594.737,418.24330.0075.0013,955.21 0.000.003.003.00-7,925.876,936.257,480.70330.0087.0014,355.21 CD5-93 T01 H 0901 0.000.000.000.00-7,935.866,953.557,481.75330.0087.0014,375.21 28.020.701.321.50-8,065.487,186.827,487.49331.8890.5414,642.19 0.000.000.000.00-15,356.8120,830.937,342.70331.8890.5430,113.01 CD5-93 T02 T 0901 11/2/2020 4:44:29PM COMPASS 5000.15 Build 91E Page 3 ConocoPhillips Standard Proposal Report Well Plan: CD5-93 (12A)Local Co-ordinate Reference:Database:EDT 15 Alaska Prod Plan D25 @ 74.70usft (D25)TVD Reference:ConocoPhillips Alaska Inc_WNSCompany: Plan D25 @ 74.70usft (D25)MD Reference:Western North SlopeProject: TrueNorth Reference:CD5 Alpine West PadSite: Minimum CurvatureSurvey Calculation Method:Plan: CD5-93 (12A)Well: CD5-93Wellbore: CD5-93 wp06Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Vertical Section (usft) Dogleg Rate (°/100usft) +N/-S (usft) Build Rate (°/100usft) Turn Rate (°/100usft) Planned Survey Vertical Depth (usft) 41.10 0.00 0.00 41.10 0.00 0.000.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.000.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.000.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.000.00 0.00 0.00 0.00 Start Build 1.50 400.00 1.50 150.00 399.99 -1.31 1.50-1.13 0.65 1.50 0.00 500.00 3.00 150.00 499.91 -5.23 1.50-4.53 2.62 1.50 0.00 Start 700.00 hold at 500.00 MD 600.00 3.00 150.00 599.77 -10.46 0.00-9.07 5.23 0.00 0.00 700.00 3.00 150.00 699.63 -15.69 0.00-13.60 7.85 0.00 0.00 800.00 3.00 150.00 799.50 -20.92 0.00-18.13 10.47 0.00 0.00 900.00 3.00 150.00 899.36 -26.15 0.00-22.66 13.08 0.00 0.00 1,000.00 3.00 150.00 999.22 -31.38 0.00-27.20 15.70 0.00 0.00 1,100.00 3.00 150.00 1,099.09 -36.61 0.00-31.73 18.32 0.00 0.00 1,200.00 3.00 150.00 1,198.95 -41.84 0.00-36.26 20.93 0.00 0.00 Start Drop -1.20 1,300.00 1.80 150.00 1,298.86 -46.03 1.20-39.89 23.03 -1.20 0.00 1,400.00 0.60 150.00 1,398.84 -48.12 1.20-41.70 24.08 -1.20 0.00 1,400.86 0.59 150.00 1,399.70 -48.13 1.20-41.71 24.08 -1.20 0.00 Base Perm 1,450.00 0.00 0.00 1,448.84 -48.38 1.20-41.93 24.21 -1.20 0.00 Start 55.66 hold at 1450.00 MD 1,500.00 0.00 0.00 1,498.84 -48.38 0.00-41.93 24.21 0.00 0.00 1,505.66 0.00 0.00 1,504.50 -48.38 0.00-41.93 24.21 0.00 0.00 Start Build 1.50 1,600.00 1.42 300.00 1,598.83 -47.40 1.50-41.34 23.20 1.50 0.00 1,700.00 2.92 300.00 1,698.75 -44.19 1.50-39.46 19.93 1.50 0.00 1,800.00 4.42 300.00 1,798.54 -38.77 1.50-36.26 14.39 1.50 0.00 1,805.66 4.50 300.00 1,804.19 -38.40 1.50-36.04 14.01 1.50 0.00 Start Build 1.50 1,900.00 5.92 300.00 1,898.14 -31.14 1.50-31.76 6.59 1.50 0.00 2,000.00 7.42 300.00 1,997.46 -21.29 1.50-25.96 -3.46 1.50 0.00 2,100.00 8.92 300.00 2,096.44 -9.25 1.50-18.85 -15.76 1.50 0.00 2,194.39 10.33 300.00 2,189.50 4.13 1.50-10.97 -29.42 1.50 0.00 Start 20.00 hold at 2194.39 MD - 10-3/4 x 13-1/2 2,200.00 10.33 300.00 2,195.02 4.98 0.00-10.46 -30.29 0.00 0.00 2,214.39 10.33 300.00 2,209.18 7.17 0.00-9.17 -32.53 0.00 0.00 Start DLS 2.50 TFO 11.22 2,300.00 12.44 301.93 2,293.10 21.66 2.50-0.46 -47.00 2.46 2.26 2,332.41 13.24 302.51 2,324.70 27.91 2.503.38 -53.09 2.47 1.77 C-30 2,400.00 14.91 303.51 2,390.26 42.29 2.5012.34 -66.87 2.47 1.48 2,500.00 17.39 304.64 2,486.30 66.87 2.5027.94 -89.89 2.48 1.13 2,600.00 19.87 305.50 2,581.05 95.36 2.5046.31 -116.03 2.48 0.86 2,700.00 22.36 306.18 2,674.33 127.70 2.5067.42 -145.23 2.49 0.67 2,800.00 24.85 306.72 2,765.95 163.84 2.5091.21 -177.43 2.49 0.55 2,888.70 27.06 307.13 2,845.70 199.00 2.50114.54 -208.46 2.49 0.46 C-10 2,900.00 27.35 307.17 2,855.75 203.69 2.50117.66 -212.58 2.49 0.42 3,000.00 29.84 307.56 2,943.55 247.19 2.50146.71 -250.61 2.49 0.38 3,100.00 32.33 307.88 3,029.18 294.25 2.50178.30 -291.45 2.49 0.33 3,200.00 34.83 308.17 3,112.49 344.79 2.50212.37 -335.01 2.50 0.29 11/2/2020 4:44:29PM COMPASS 5000.15 Build 91E Page 4 ConocoPhillips Standard Proposal Report Well Plan: CD5-93 (12A)Local Co-ordinate Reference:Database:EDT 15 Alaska Prod Plan D25 @ 74.70usft (D25)TVD Reference:ConocoPhillips Alaska Inc_WNSCompany: Plan D25 @ 74.70usft (D25)MD Reference:Western North SlopeProject: TrueNorth Reference:CD5 Alpine West PadSite: Minimum CurvatureSurvey Calculation Method:Plan: CD5-93 (12A)Well: CD5-93Wellbore: CD5-93 wp06Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Vertical Section (usft) Dogleg Rate (°/100usft) +N/-S (usft) Build Rate (°/100usft) Turn Rate (°/100usft) Planned Survey Vertical Depth (usft) 3,300.00 37.32 308.42 3,193.30 398.70 2.50248.86 -381.22 2.50 0.25 3,400.00 39.82 308.65 3,271.48 455.89 2.50287.71 -429.98 2.50 0.22 3,500.00 42.32 308.85 3,346.87 516.25 2.50328.82 -481.21 2.50 0.20 3,600.00 44.81 309.03 3,419.32 579.66 2.50372.14 -534.81 2.50 0.18 3,700.00 47.31 309.20 3,488.70 645.99 2.50417.56 -590.68 2.50 0.17 3,800.00 49.81 309.36 3,554.89 715.13 2.50465.02 -648.70 2.50 0.16 3,900.00 52.30 309.50 3,617.74 786.95 2.50514.41 -708.77 2.50 0.14 4,000.00 54.80 309.64 3,677.14 861.29 2.50565.65 -770.77 2.50 0.13 4,100.00 57.30 309.76 3,732.98 938.04 2.50618.63 -834.59 2.50 0.13 4,167.68 58.99 309.84 3,768.70 991.27 2.50655.44 -878.76 2.50 0.12 K-3 4,200.00 59.80 309.88 3,785.15 1,017.03 2.50673.26 -900.11 2.50 0.12 4,300.00 62.30 310.00 3,833.56 1,098.12 2.50729.43 -967.19 2.50 0.11 4,400.00 64.79 310.10 3,878.10 1,181.15 2.50787.04 -1,035.72 2.50 0.11 4,500.00 67.29 310.21 3,918.71 1,265.97 2.50845.97 -1,105.55 2.50 0.10 4,530.03 68.04 310.24 3,930.11 1,291.76 2.50863.90 -1,126.76 2.50 0.10 Start 8759.60 hold at 4530.02 MD 4,600.00 68.04 310.24 3,956.28 1,352.04 0.00905.83 -1,176.30 0.00 0.00 4,700.00 68.04 310.24 3,993.67 1,438.17 0.00965.74 -1,247.10 0.00 0.00 4,710.77 68.04 310.24 3,997.70 1,447.45 0.00972.19 -1,254.72 0.00 0.00 K-2 4,800.00 68.04 310.24 4,031.06 1,524.31 0.001,025.65 -1,317.89 0.00 0.00 4,841.82 68.04 310.24 4,046.70 1,560.33 0.001,050.71 -1,347.50 0.00 0.00 K-2 Base 4,900.00 68.04 310.24 4,068.46 1,610.45 0.001,085.57 -1,388.69 0.00 0.00 5,000.00 68.04 310.24 4,105.85 1,696.59 0.001,145.48 -1,459.49 0.00 0.00 5,100.00 68.04 310.24 4,143.24 1,782.72 0.001,205.39 -1,530.28 0.00 0.00 5,200.00 68.04 310.24 4,180.63 1,868.86 0.001,265.31 -1,601.08 0.00 0.00 5,300.00 68.04 310.24 4,218.02 1,955.00 0.001,325.22 -1,671.88 0.00 0.00 5,400.00 68.04 310.24 4,255.42 2,041.14 0.001,385.13 -1,742.68 0.00 0.00 5,500.00 68.04 310.24 4,292.81 2,127.27 0.001,445.04 -1,813.47 0.00 0.00 5,600.00 68.04 310.24 4,330.20 2,213.41 0.001,504.96 -1,884.27 0.00 0.00 5,700.00 68.04 310.24 4,367.59 2,299.55 0.001,564.87 -1,955.07 0.00 0.00 5,800.00 68.04 310.24 4,404.98 2,385.69 0.001,624.78 -2,025.86 0.00 0.00 5,900.00 68.04 310.24 4,442.38 2,471.82 0.001,684.70 -2,096.66 0.00 0.00 6,000.00 68.04 310.24 4,479.77 2,557.96 0.001,744.61 -2,167.46 0.00 0.00 6,100.00 68.04 310.24 4,517.16 2,644.10 0.001,804.52 -2,238.26 0.00 0.00 6,200.00 68.04 310.24 4,554.55 2,730.24 0.001,864.44 -2,309.05 0.00 0.00 6,300.00 68.04 310.24 4,591.95 2,816.37 0.001,924.35 -2,379.85 0.00 0.00 6,400.00 68.04 310.24 4,629.34 2,902.51 0.001,984.26 -2,450.65 0.00 0.00 6,500.00 68.04 310.24 4,666.73 2,988.65 0.002,044.18 -2,521.44 0.00 0.00 6,600.00 68.04 310.24 4,704.12 3,074.78 0.002,104.09 -2,592.24 0.00 0.00 6,700.00 68.04 310.24 4,741.51 3,160.92 0.002,164.00 -2,663.04 0.00 0.00 6,800.00 68.04 310.24 4,778.91 3,247.06 0.002,223.92 -2,733.84 0.00 0.00 6,900.00 68.04 310.24 4,816.30 3,333.20 0.002,283.83 -2,804.63 0.00 0.00 7,000.00 68.04 310.24 4,853.69 3,419.33 0.002,343.74 -2,875.43 0.00 0.00 7,100.00 68.04 310.24 4,891.08 3,505.47 0.002,403.66 -2,946.23 0.00 0.00 7,200.00 68.04 310.24 4,928.47 3,591.61 0.002,463.57 -3,017.02 0.00 0.00 7,300.00 68.04 310.24 4,965.87 3,677.75 0.002,523.48 -3,087.82 0.00 0.00 7,400.00 68.04 310.24 5,003.26 3,763.88 0.002,583.40 -3,158.62 0.00 0.00 7,500.00 68.04 310.24 5,040.65 3,850.02 0.002,643.31 -3,229.42 0.00 0.00 7,600.00 68.04 310.24 5,078.04 3,936.16 0.002,703.22 -3,300.21 0.00 0.00 7,700.00 68.04 310.24 5,115.43 4,022.30 0.002,763.14 -3,371.01 0.00 0.00 11/2/2020 4:44:29PM COMPASS 5000.15 Build 91E Page 5 ConocoPhillips Standard Proposal Report Well Plan: CD5-93 (12A)Local Co-ordinate Reference:Database:EDT 15 Alaska Prod Plan D25 @ 74.70usft (D25)TVD Reference:ConocoPhillips Alaska Inc_WNSCompany: Plan D25 @ 74.70usft (D25)MD Reference:Western North SlopeProject: TrueNorth Reference:CD5 Alpine West PadSite: Minimum CurvatureSurvey Calculation Method:Plan: CD5-93 (12A)Well: CD5-93Wellbore: CD5-93 wp06Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Vertical Section (usft) Dogleg Rate (°/100usft) +N/-S (usft) Build Rate (°/100usft) Turn Rate (°/100usft) Planned Survey Vertical Depth (usft) 7,800.00 68.04 310.24 5,152.83 4,108.43 0.002,823.05 -3,441.81 0.00 0.00 7,900.00 68.04 310.24 5,190.22 4,194.57 0.002,882.96 -3,512.60 0.00 0.00 8,000.00 68.04 310.24 5,227.61 4,280.71 0.002,942.88 -3,583.40 0.00 0.00 8,083.14 68.04 310.24 5,258.70 4,352.33 0.002,992.69 -3,642.26 0.00 0.00 Alp 96 8,100.00 68.04 310.24 5,265.00 4,366.85 0.003,002.79 -3,654.20 0.00 0.00 8,200.00 68.04 310.24 5,302.40 4,452.98 0.003,062.70 -3,725.00 0.00 0.00 8,300.00 68.04 310.24 5,339.79 4,539.12 0.003,122.62 -3,795.79 0.00 0.00 8,400.00 68.04 310.24 5,377.18 4,625.26 0.003,182.53 -3,866.59 0.00 0.00 8,500.00 68.04 310.24 5,414.57 4,711.40 0.003,242.44 -3,937.39 0.00 0.00 8,600.00 68.04 310.24 5,451.96 4,797.53 0.003,302.36 -4,008.18 0.00 0.00 8,700.00 68.04 310.24 5,489.36 4,883.67 0.003,362.27 -4,078.98 0.00 0.00 8,800.00 68.04 310.24 5,526.75 4,969.81 0.003,422.18 -4,149.78 0.00 0.00 8,900.00 68.04 310.24 5,564.14 5,055.95 0.003,482.10 -4,220.58 0.00 0.00 9,000.00 68.04 310.24 5,601.53 5,142.08 0.003,542.01 -4,291.37 0.00 0.00 9,100.00 68.04 310.24 5,638.92 5,228.22 0.003,601.92 -4,362.17 0.00 0.00 9,200.00 68.04 310.24 5,676.32 5,314.36 0.003,661.83 -4,432.97 0.00 0.00 9,300.00 68.04 310.24 5,713.71 5,400.50 0.003,721.75 -4,503.76 0.00 0.00 9,400.00 68.04 310.24 5,751.10 5,486.63 0.003,781.66 -4,574.56 0.00 0.00 9,500.00 68.04 310.24 5,788.49 5,572.77 0.003,841.57 -4,645.36 0.00 0.00 9,600.00 68.04 310.24 5,825.88 5,658.91 0.003,901.49 -4,716.16 0.00 0.00 9,700.00 68.04 310.24 5,863.28 5,745.05 0.003,961.40 -4,786.95 0.00 0.00 9,800.00 68.04 310.24 5,900.67 5,831.18 0.004,021.31 -4,857.75 0.00 0.00 9,900.00 68.04 310.24 5,938.06 5,917.32 0.004,081.23 -4,928.55 0.00 0.00 10,000.00 68.04 310.24 5,975.45 6,003.46 0.004,141.14 -4,999.34 0.00 0.00 10,100.00 68.04 310.24 6,012.84 6,089.60 0.004,201.05 -5,070.14 0.00 0.00 10,200.00 68.04 310.24 6,050.24 6,175.73 0.004,260.97 -5,140.94 0.00 0.00 10,300.00 68.04 310.24 6,087.63 6,261.87 0.004,320.88 -5,211.73 0.00 0.00 10,400.00 68.04 310.24 6,125.02 6,348.01 0.004,380.79 -5,282.53 0.00 0.00 10,500.00 68.04 310.24 6,162.41 6,434.15 0.004,440.71 -5,353.33 0.00 0.00 10,600.00 68.04 310.24 6,199.81 6,520.28 0.004,500.62 -5,424.13 0.00 0.00 10,700.00 68.04 310.24 6,237.20 6,606.42 0.004,560.53 -5,494.92 0.00 0.00 10,800.00 68.04 310.24 6,274.59 6,692.56 0.004,620.45 -5,565.72 0.00 0.00 10,900.00 68.04 310.24 6,311.98 6,778.70 0.004,680.36 -5,636.52 0.00 0.00 11,000.00 68.04 310.24 6,349.37 6,864.83 0.004,740.27 -5,707.31 0.00 0.00 11,100.00 68.04 310.24 6,386.77 6,950.97 0.004,800.19 -5,778.11 0.00 0.00 11,200.00 68.04 310.24 6,424.16 7,037.11 0.004,860.10 -5,848.91 0.00 0.00 11,300.00 68.04 310.24 6,461.55 7,123.25 0.004,920.01 -5,919.71 0.00 0.00 11,400.00 68.04 310.24 6,498.94 7,209.38 0.004,979.93 -5,990.50 0.00 0.00 11,500.00 68.04 310.24 6,536.33 7,295.52 0.005,039.84 -6,061.30 0.00 0.00 11,600.00 68.04 310.24 6,573.73 7,381.66 0.005,099.75 -6,132.10 0.00 0.00 11,700.00 68.04 310.24 6,611.12 7,467.80 0.005,159.67 -6,202.89 0.00 0.00 11,800.00 68.04 310.24 6,648.51 7,553.93 0.005,219.58 -6,273.69 0.00 0.00 11,900.00 68.04 310.24 6,685.90 7,640.07 0.005,279.49 -6,344.49 0.00 0.00 12,000.00 68.04 310.24 6,723.29 7,726.21 0.005,339.41 -6,415.29 0.00 0.00 12,100.00 68.04 310.24 6,760.69 7,812.35 0.005,399.32 -6,486.08 0.00 0.00 12,200.00 68.04 310.24 6,798.08 7,898.48 0.005,459.23 -6,556.88 0.00 0.00 12,300.00 68.04 310.24 6,835.47 7,984.62 0.005,519.15 -6,627.68 0.00 0.00 12,400.00 68.04 310.24 6,872.86 8,070.76 0.005,579.06 -6,698.47 0.00 0.00 12,500.00 68.04 310.24 6,910.26 8,156.90 0.005,638.97 -6,769.27 0.00 0.00 12,600.00 68.04 310.24 6,947.65 8,243.03 0.005,698.89 -6,840.07 0.00 0.00 12,700.00 68.04 310.24 6,985.04 8,329.17 0.005,758.80 -6,910.87 0.00 0.00 12,800.00 68.04 310.24 7,022.43 8,415.31 0.005,818.71 -6,981.66 0.00 0.00 12,900.00 68.04 310.24 7,059.82 8,501.45 0.005,878.62 -7,052.46 0.00 0.00 11/2/2020 4:44:29PM COMPASS 5000.15 Build 91E Page 6 ConocoPhillips Standard Proposal Report Well Plan: CD5-93 (12A)Local Co-ordinate Reference:Database:EDT 15 Alaska Prod Plan D25 @ 74.70usft (D25)TVD Reference:ConocoPhillips Alaska Inc_WNSCompany: Plan D25 @ 74.70usft (D25)MD Reference:Western North SlopeProject: TrueNorth Reference:CD5 Alpine West PadSite: Minimum CurvatureSurvey Calculation Method:Plan: CD5-93 (12A)Well: CD5-93Wellbore: CD5-93 wp06Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Vertical Section (usft) Dogleg Rate (°/100usft) +N/-S (usft) Build Rate (°/100usft) Turn Rate (°/100usft) Planned Survey Vertical Depth (usft) 13,000.00 68.04 310.24 7,097.22 8,587.58 0.005,938.54 -7,123.26 0.00 0.00 13,100.00 68.04 310.24 7,134.61 8,673.72 0.005,998.45 -7,194.05 0.00 0.00 13,113.62 68.04 310.24 7,139.70 8,685.45 0.006,006.61 -7,203.70 0.00 0.00 FCS Top 13,200.00 68.04 310.24 7,172.00 8,759.86 0.006,058.36 -7,264.85 0.00 0.00 13,252.69 68.04 310.24 7,191.70 8,805.24 0.006,089.93 -7,302.15 0.00 0.00 Kalubik 13,289.62 68.04 310.24 7,205.51 8,837.06 0.006,112.06 -7,328.30 0.00 0.00 Start DLS 3.00 TFO 73.00 13,300.00 68.13 310.56 7,209.38 8,846.01 3.006,118.30 -7,335.63 0.88 3.09 13,400.00 69.05 313.63 7,245.90 8,933.54 3.006,180.71 -7,404.70 0.91 3.07 13,500.00 70.01 316.66 7,280.88 9,023.19 3.006,247.12 -7,470.76 0.97 3.03 13,567.87 70.70 318.70 7,303.70 9,085.12 3.006,294.38 -7,513.79 1.01 3.00 Kup C 13,600.00 71.03 319.66 7,314.23 9,114.71 3.006,317.35 -7,533.63 1.03 2.98 13,601.44 71.04 319.70 7,314.70 9,116.04 3.006,318.38 -7,534.51 1.04 2.97 LCU 13,700.00 72.09 322.61 7,345.87 9,207.86 3.006,391.21 -7,593.14 1.06 2.96 13,800.00 73.20 325.53 7,375.70 9,302.39 3.006,468.49 -7,649.13 1.11 2.92 13,900.00 74.35 328.42 7,403.65 9,398.02 3.006,548.99 -7,701.44 1.15 2.89 13,955.21 75.00 330.00 7,418.24 9,451.20 3.006,594.73 -7,728.70 1.18 2.86 Start Build 3.00 14,000.00 76.34 330.00 7,429.33 9,494.57 3.006,632.31 -7,750.40 3.00 0.00 14,100.00 79.34 330.00 7,450.38 9,592.26 3.006,716.96 -7,799.27 3.00 0.00 14,130.02 80.24 330.00 7,455.70 9,621.79 3.006,742.55 -7,814.04 3.00 0.00 Alp C 14,200.00 82.34 330.00 7,466.29 9,690.92 3.006,802.45 -7,848.63 3.00 0.00 14,203.09 82.44 330.00 7,466.70 9,693.97 3.006,805.10 -7,850.16 3.00 0.00 UJU 14,300.00 85.34 330.00 7,477.01 9,790.27 3.006,888.55 -7,898.33 3.00 0.00 14,355.21 87.00 330.00 7,480.70 9,845.32 3.006,936.25 -7,925.87 3.00 0.00 Start 20.00 hold at 14355.21 MD - 7-5/8 x 9-7/8 by 11 14,375.21 87.00 330.00 7,481.75 9,865.28 0.006,953.55 -7,935.86 0.00 0.00 Start DLS 1.50 TFO 28.02 14,400.00 87.33 330.17 7,482.97 9,890.03 1.506,975.01 -7,948.21 1.32 0.71 14,500.00 88.65 330.88 7,486.48 9,989.93 1.507,062.01 -7,997.38 1.32 0.70 14,600.00 89.98 331.58 7,487.68 10,089.91 1.507,149.66 -8,045.50 1.32 0.70 14,642.19 90.54 331.88 7,487.49 10,132.09 1.507,186.82 -8,065.48 1.32 0.70 Start 15470.82 hold at 14642.19 MD 14,700.00 90.54 331.88 7,486.95 10,189.90 0.007,237.80 -8,092.73 0.00 0.00 14,800.00 90.54 331.88 7,486.01 10,289.90 0.007,325.99 -8,139.86 0.00 0.00 14,900.00 90.54 331.88 7,485.07 10,389.90 0.007,414.19 -8,186.99 0.00 0.00 15,000.00 90.54 331.88 7,484.14 10,489.89 0.007,502.38 -8,234.11 0.00 0.00 15,100.00 90.54 331.88 7,483.20 10,589.89 0.007,590.57 -8,281.24 0.00 0.00 15,200.00 90.54 331.88 7,482.27 10,689.88 0.007,678.77 -8,328.37 0.00 0.00 15,300.00 90.54 331.88 7,481.33 10,789.88 0.007,766.96 -8,375.50 0.00 0.00 15,400.00 90.54 331.88 7,480.39 10,889.87 0.007,855.15 -8,422.63 0.00 0.00 15,500.00 90.54 331.88 7,479.46 10,989.87 0.007,943.34 -8,469.76 0.00 0.00 15,600.00 90.54 331.88 7,478.52 11,089.86 0.008,031.54 -8,516.89 0.00 0.00 15,700.00 90.54 331.88 7,477.59 11,189.86 0.008,119.73 -8,564.02 0.00 0.00 15,800.00 90.54 331.88 7,476.65 11,289.85 0.008,207.92 -8,611.15 0.00 0.00 15,900.00 90.54 331.88 7,475.71 11,389.85 0.008,296.11 -8,658.28 0.00 0.00 16,000.00 90.54 331.88 7,474.78 11,489.85 0.008,384.31 -8,705.41 0.00 0.00 11/2/2020 4:44:29PM COMPASS 5000.15 Build 91E Page 7 ConocoPhillips Standard Proposal Report Well Plan: CD5-93 (12A)Local Co-ordinate Reference:Database:EDT 15 Alaska Prod Plan D25 @ 74.70usft (D25)TVD Reference:ConocoPhillips Alaska Inc_WNSCompany: Plan D25 @ 74.70usft (D25)MD Reference:Western North SlopeProject: TrueNorth Reference:CD5 Alpine West PadSite: Minimum CurvatureSurvey Calculation Method:Plan: CD5-93 (12A)Well: CD5-93Wellbore: CD5-93 wp06Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Vertical Section (usft) Dogleg Rate (°/100usft) +N/-S (usft) Build Rate (°/100usft) Turn Rate (°/100usft) Planned Survey Vertical Depth (usft) 16,100.00 90.54 331.88 7,473.84 11,589.84 0.008,472.50 -8,752.54 0.00 0.00 16,200.00 90.54 331.88 7,472.91 11,689.84 0.008,560.69 -8,799.67 0.00 0.00 16,300.00 90.54 331.88 7,471.97 11,789.83 0.008,648.88 -8,846.80 0.00 0.00 16,400.00 90.54 331.88 7,471.04 11,889.83 0.008,737.08 -8,893.93 0.00 0.00 16,500.00 90.54 331.88 7,470.10 11,989.82 0.008,825.27 -8,941.06 0.00 0.00 16,600.00 90.54 331.88 7,469.16 12,089.82 0.008,913.46 -8,988.19 0.00 0.00 16,700.00 90.54 331.88 7,468.23 12,189.81 0.009,001.65 -9,035.32 0.00 0.00 16,800.00 90.54 331.88 7,467.29 12,289.81 0.009,089.85 -9,082.45 0.00 0.00 16,900.00 90.54 331.88 7,466.36 12,389.80 0.009,178.04 -9,129.58 0.00 0.00 17,000.00 90.54 331.88 7,465.42 12,489.80 0.009,266.23 -9,176.71 0.00 0.00 17,100.00 90.54 331.88 7,464.48 12,589.79 0.009,354.42 -9,223.84 0.00 0.00 17,200.00 90.54 331.88 7,463.55 12,689.79 0.009,442.62 -9,270.96 0.00 0.00 17,300.00 90.54 331.88 7,462.61 12,789.79 0.009,530.81 -9,318.09 0.00 0.00 17,400.00 90.54 331.88 7,461.68 12,889.78 0.009,619.00 -9,365.22 0.00 0.00 17,500.00 90.54 331.88 7,460.74 12,989.78 0.009,707.19 -9,412.35 0.00 0.00 17,600.00 90.54 331.88 7,459.81 13,089.77 0.009,795.39 -9,459.48 0.00 0.00 17,700.00 90.54 331.88 7,458.87 13,189.77 0.009,883.58 -9,506.61 0.00 0.00 17,800.00 90.54 331.88 7,457.93 13,289.76 0.009,971.77 -9,553.74 0.00 0.00 17,900.00 90.54 331.88 7,457.00 13,389.76 0.0010,059.96 -9,600.87 0.00 0.00 18,000.00 90.54 331.88 7,456.06 13,489.75 0.0010,148.16 -9,648.00 0.00 0.00 18,100.00 90.54 331.88 7,455.13 13,589.75 0.0010,236.35 -9,695.13 0.00 0.00 18,200.00 90.54 331.88 7,454.19 13,689.74 0.0010,324.54 -9,742.26 0.00 0.00 18,300.00 90.54 331.88 7,453.25 13,789.74 0.0010,412.74 -9,789.39 0.00 0.00 18,400.00 90.54 331.88 7,452.32 13,889.73 0.0010,500.93 -9,836.52 0.00 0.00 18,500.00 90.54 331.88 7,451.38 13,989.73 0.0010,589.12 -9,883.65 0.00 0.00 18,600.00 90.54 331.88 7,450.45 14,089.73 0.0010,677.31 -9,930.78 0.00 0.00 18,700.00 90.54 331.88 7,449.51 14,189.72 0.0010,765.51 -9,977.91 0.00 0.00 18,800.00 90.54 331.88 7,448.57 14,289.72 0.0010,853.70 -10,025.04 0.00 0.00 18,900.00 90.54 331.88 7,447.64 14,389.71 0.0010,941.89 -10,072.17 0.00 0.00 19,000.00 90.54 331.88 7,446.70 14,489.71 0.0011,030.08 -10,119.30 0.00 0.00 19,100.00 90.54 331.88 7,445.77 14,589.70 0.0011,118.28 -10,166.43 0.00 0.00 19,200.00 90.54 331.88 7,444.83 14,689.70 0.0011,206.47 -10,213.56 0.00 0.00 19,300.00 90.54 331.88 7,443.90 14,789.69 0.0011,294.66 -10,260.69 0.00 0.00 19,400.00 90.54 331.88 7,442.96 14,889.69 0.0011,382.85 -10,307.81 0.00 0.00 19,500.00 90.54 331.88 7,442.02 14,989.68 0.0011,471.05 -10,354.94 0.00 0.00 19,600.00 90.54 331.88 7,441.09 15,089.68 0.0011,559.24 -10,402.07 0.00 0.00 19,700.00 90.54 331.88 7,440.15 15,189.68 0.0011,647.43 -10,449.20 0.00 0.00 19,800.00 90.54 331.88 7,439.22 15,289.67 0.0011,735.62 -10,496.33 0.00 0.00 19,900.00 90.54 331.88 7,438.28 15,389.67 0.0011,823.82 -10,543.46 0.00 0.00 20,000.00 90.54 331.88 7,437.34 15,489.66 0.0011,912.01 -10,590.59 0.00 0.00 20,100.00 90.54 331.88 7,436.41 15,589.66 0.0012,000.20 -10,637.72 0.00 0.00 20,200.00 90.54 331.88 7,435.47 15,689.65 0.0012,088.39 -10,684.85 0.00 0.00 20,300.00 90.54 331.88 7,434.54 15,789.65 0.0012,176.59 -10,731.98 0.00 0.00 20,400.00 90.54 331.88 7,433.60 15,889.64 0.0012,264.78 -10,779.11 0.00 0.00 20,500.00 90.54 331.88 7,432.66 15,989.64 0.0012,352.97 -10,826.24 0.00 0.00 20,600.00 90.54 331.88 7,431.73 16,089.63 0.0012,441.16 -10,873.37 0.00 0.00 20,700.00 90.54 331.88 7,430.79 16,189.63 0.0012,529.36 -10,920.50 0.00 0.00 20,800.00 90.54 331.88 7,429.86 16,289.62 0.0012,617.55 -10,967.63 0.00 0.00 20,900.00 90.54 331.88 7,428.92 16,389.62 0.0012,705.74 -11,014.76 0.00 0.00 21,000.00 90.54 331.88 7,427.99 16,489.62 0.0012,793.93 -11,061.89 0.00 0.00 21,100.00 90.54 331.88 7,427.05 16,589.61 0.0012,882.13 -11,109.02 0.00 0.00 21,200.00 90.54 331.88 7,426.11 16,689.61 0.0012,970.32 -11,156.15 0.00 0.00 21,300.00 90.54 331.88 7,425.18 16,789.60 0.0013,058.51 -11,203.28 0.00 0.00 21,400.00 90.54 331.88 7,424.24 16,889.60 0.0013,146.70 -11,250.41 0.00 0.00 11/2/2020 4:44:29PM COMPASS 5000.15 Build 91E Page 8 ConocoPhillips Standard Proposal Report Well Plan: CD5-93 (12A)Local Co-ordinate Reference:Database:EDT 15 Alaska Prod Plan D25 @ 74.70usft (D25)TVD Reference:ConocoPhillips Alaska Inc_WNSCompany: Plan D25 @ 74.70usft (D25)MD Reference:Western North SlopeProject: TrueNorth Reference:CD5 Alpine West PadSite: Minimum CurvatureSurvey Calculation Method:Plan: CD5-93 (12A)Well: CD5-93Wellbore: CD5-93 wp06Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Vertical Section (usft) Dogleg Rate (°/100usft) +N/-S (usft) Build Rate (°/100usft) Turn Rate (°/100usft) Planned Survey Vertical Depth (usft) 21,500.00 90.54 331.88 7,423.31 16,989.59 0.0013,234.90 -11,297.54 0.00 0.00 21,600.00 90.54 331.88 7,422.37 17,089.59 0.0013,323.09 -11,344.66 0.00 0.00 21,700.00 90.54 331.88 7,421.43 17,189.58 0.0013,411.28 -11,391.79 0.00 0.00 21,800.00 90.54 331.88 7,420.50 17,289.58 0.0013,499.48 -11,438.92 0.00 0.00 21,900.00 90.54 331.88 7,419.56 17,389.57 0.0013,587.67 -11,486.05 0.00 0.00 22,000.00 90.54 331.88 7,418.63 17,489.57 0.0013,675.86 -11,533.18 0.00 0.00 22,100.00 90.54 331.88 7,417.69 17,589.56 0.0013,764.05 -11,580.31 0.00 0.00 22,200.00 90.54 331.88 7,416.76 17,689.56 0.0013,852.25 -11,627.44 0.00 0.00 22,300.00 90.54 331.88 7,415.82 17,789.56 0.0013,940.44 -11,674.57 0.00 0.00 22,400.00 90.54 331.88 7,414.88 17,889.55 0.0014,028.63 -11,721.70 0.00 0.00 22,500.00 90.54 331.88 7,413.95 17,989.55 0.0014,116.82 -11,768.83 0.00 0.00 22,600.00 90.54 331.88 7,413.01 18,089.54 0.0014,205.02 -11,815.96 0.00 0.00 22,700.00 90.54 331.88 7,412.08 18,189.54 0.0014,293.21 -11,863.09 0.00 0.00 22,800.00 90.54 331.88 7,411.14 18,289.53 0.0014,381.40 -11,910.22 0.00 0.00 22,900.00 90.54 331.88 7,410.20 18,389.53 0.0014,469.59 -11,957.35 0.00 0.00 23,000.00 90.54 331.88 7,409.27 18,489.52 0.0014,557.79 -12,004.48 0.00 0.00 23,100.00 90.54 331.88 7,408.33 18,589.52 0.0014,645.98 -12,051.61 0.00 0.00 23,200.00 90.54 331.88 7,407.40 18,689.51 0.0014,734.17 -12,098.74 0.00 0.00 23,300.00 90.54 331.88 7,406.46 18,789.51 0.0014,822.36 -12,145.87 0.00 0.00 23,400.00 90.54 331.88 7,405.52 18,889.51 0.0014,910.56 -12,193.00 0.00 0.00 23,500.00 90.54 331.88 7,404.59 18,989.50 0.0014,998.75 -12,240.13 0.00 0.00 23,600.00 90.54 331.88 7,403.65 19,089.50 0.0015,086.94 -12,287.26 0.00 0.00 23,700.00 90.54 331.88 7,402.72 19,189.49 0.0015,175.13 -12,334.39 0.00 0.00 23,800.00 90.54 331.88 7,401.78 19,289.49 0.0015,263.33 -12,381.51 0.00 0.00 23,900.00 90.54 331.88 7,400.85 19,389.48 0.0015,351.52 -12,428.64 0.00 0.00 24,000.00 90.54 331.88 7,399.91 19,489.48 0.0015,439.71 -12,475.77 0.00 0.00 24,100.00 90.54 331.88 7,398.97 19,589.47 0.0015,527.90 -12,522.90 0.00 0.00 24,200.00 90.54 331.88 7,398.04 19,689.47 0.0015,616.10 -12,570.03 0.00 0.00 24,300.00 90.54 331.88 7,397.10 19,789.46 0.0015,704.29 -12,617.16 0.00 0.00 24,400.00 90.54 331.88 7,396.17 19,889.46 0.0015,792.48 -12,664.29 0.00 0.00 24,500.00 90.54 331.88 7,395.23 19,989.45 0.0015,880.67 -12,711.42 0.00 0.00 24,600.00 90.54 331.88 7,394.29 20,089.45 0.0015,968.87 -12,758.55 0.00 0.00 24,700.00 90.54 331.88 7,393.36 20,189.45 0.0016,057.06 -12,805.68 0.00 0.00 24,800.00 90.54 331.88 7,392.42 20,289.44 0.0016,145.25 -12,852.81 0.00 0.00 24,900.00 90.54 331.88 7,391.49 20,389.44 0.0016,233.45 -12,899.94 0.00 0.00 25,000.00 90.54 331.88 7,390.55 20,489.43 0.0016,321.64 -12,947.07 0.00 0.00 25,100.00 90.54 331.88 7,389.62 20,589.43 0.0016,409.83 -12,994.20 0.00 0.00 25,200.00 90.54 331.88 7,388.68 20,689.42 0.0016,498.02 -13,041.33 0.00 0.00 25,300.00 90.54 331.88 7,387.74 20,789.42 0.0016,586.22 -13,088.46 0.00 0.00 25,400.00 90.54 331.88 7,386.81 20,889.41 0.0016,674.41 -13,135.59 0.00 0.00 25,500.00 90.54 331.88 7,385.87 20,989.41 0.0016,762.60 -13,182.72 0.00 0.00 25,600.00 90.54 331.88 7,384.94 21,089.40 0.0016,850.79 -13,229.85 0.00 0.00 25,700.00 90.54 331.88 7,384.00 21,189.40 0.0016,938.99 -13,276.98 0.00 0.00 25,800.00 90.54 331.88 7,383.06 21,289.39 0.0017,027.18 -13,324.11 0.00 0.00 25,900.00 90.54 331.88 7,382.13 21,389.39 0.0017,115.37 -13,371.24 0.00 0.00 26,000.00 90.54 331.88 7,381.19 21,489.39 0.0017,203.56 -13,418.36 0.00 0.00 26,100.00 90.54 331.88 7,380.26 21,589.38 0.0017,291.76 -13,465.49 0.00 0.00 26,200.00 90.54 331.88 7,379.32 21,689.38 0.0017,379.95 -13,512.62 0.00 0.00 26,300.00 90.54 331.88 7,378.38 21,789.37 0.0017,468.14 -13,559.75 0.00 0.00 26,400.00 90.54 331.88 7,377.45 21,889.37 0.0017,556.33 -13,606.88 0.00 0.00 26,500.00 90.54 331.88 7,376.51 21,989.36 0.0017,644.53 -13,654.01 0.00 0.00 26,600.00 90.54 331.88 7,375.58 22,089.36 0.0017,732.72 -13,701.14 0.00 0.00 26,700.00 90.54 331.88 7,374.64 22,189.35 0.0017,820.91 -13,748.27 0.00 0.00 26,800.00 90.54 331.88 7,373.71 22,289.35 0.0017,909.10 -13,795.40 0.00 0.00 11/2/2020 4:44:29PM COMPASS 5000.15 Build 91E Page 9 ConocoPhillips Standard Proposal Report Well Plan: CD5-93 (12A)Local Co-ordinate Reference:Database:EDT 15 Alaska Prod Plan D25 @ 74.70usft (D25)TVD Reference:ConocoPhillips Alaska Inc_WNSCompany: Plan D25 @ 74.70usft (D25)MD Reference:Western North SlopeProject: TrueNorth Reference:CD5 Alpine West PadSite: Minimum CurvatureSurvey Calculation Method:Plan: CD5-93 (12A)Well: CD5-93Wellbore: CD5-93 wp06Design: Measured Depth (usft) Inclination (°) Azimuth (°) +E/-W (usft) Vertical Section (usft) Dogleg Rate (°/100usft) +N/-S (usft) Build Rate (°/100usft) Turn Rate (°/100usft) Planned Survey Vertical Depth (usft) 26,900.00 90.54 331.88 7,372.77 22,389.34 0.0017,997.30 -13,842.53 0.00 0.00 27,000.00 90.54 331.88 7,371.83 22,489.34 0.0018,085.49 -13,889.66 0.00 0.00 27,100.00 90.54 331.88 7,370.90 22,589.34 0.0018,173.68 -13,936.79 0.00 0.00 27,200.00 90.54 331.88 7,369.96 22,689.33 0.0018,261.87 -13,983.92 0.00 0.00 27,300.00 90.54 331.88 7,369.03 22,789.33 0.0018,350.07 -14,031.05 0.00 0.00 27,400.00 90.54 331.88 7,368.09 22,889.32 0.0018,438.26 -14,078.18 0.00 0.00 27,500.00 90.54 331.88 7,367.15 22,989.32 0.0018,526.45 -14,125.31 0.00 0.00 27,600.00 90.54 331.88 7,366.22 23,089.31 0.0018,614.64 -14,172.44 0.00 0.00 27,700.00 90.54 331.88 7,365.28 23,189.31 0.0018,702.84 -14,219.57 0.00 0.00 27,800.00 90.54 331.88 7,364.35 23,289.30 0.0018,791.03 -14,266.70 0.00 0.00 27,900.00 90.54 331.88 7,363.41 23,389.30 0.0018,879.22 -14,313.83 0.00 0.00 28,000.00 90.54 331.88 7,362.48 23,489.29 0.0018,967.42 -14,360.96 0.00 0.00 28,100.00 90.54 331.88 7,361.54 23,589.29 0.0019,055.61 -14,408.09 0.00 0.00 28,200.00 90.54 331.88 7,360.60 23,689.28 0.0019,143.80 -14,455.21 0.00 0.00 28,300.00 90.54 331.88 7,359.67 23,789.28 0.0019,231.99 -14,502.34 0.00 0.00 28,400.00 90.54 331.88 7,358.73 23,889.28 0.0019,320.19 -14,549.47 0.00 0.00 28,500.00 90.54 331.88 7,357.80 23,989.27 0.0019,408.38 -14,596.60 0.00 0.00 28,600.00 90.54 331.88 7,356.86 24,089.27 0.0019,496.57 -14,643.73 0.00 0.00 28,700.00 90.54 331.88 7,355.92 24,189.26 0.0019,584.76 -14,690.86 0.00 0.00 28,800.00 90.54 331.88 7,354.99 24,289.26 0.0019,672.96 -14,737.99 0.00 0.00 28,900.00 90.54 331.88 7,354.05 24,389.25 0.0019,761.15 -14,785.12 0.00 0.00 29,000.00 90.54 331.88 7,353.12 24,489.25 0.0019,849.34 -14,832.25 0.00 0.00 29,100.00 90.54 331.88 7,352.18 24,589.24 0.0019,937.53 -14,879.38 0.00 0.00 29,200.00 90.54 331.88 7,351.24 24,689.24 0.0020,025.73 -14,926.51 0.00 0.00 29,300.00 90.54 331.88 7,350.31 24,789.23 0.0020,113.92 -14,973.64 0.00 0.00 29,400.00 90.54 331.88 7,349.37 24,889.23 0.0020,202.11 -15,020.77 0.00 0.00 29,500.00 90.54 331.88 7,348.44 24,989.22 0.0020,290.30 -15,067.90 0.00 0.00 29,600.00 90.54 331.88 7,347.50 25,089.22 0.0020,378.50 -15,115.03 0.00 0.00 29,700.00 90.54 331.88 7,346.57 25,189.22 0.0020,466.69 -15,162.16 0.00 0.00 29,800.00 90.54 331.88 7,345.63 25,289.21 0.0020,554.88 -15,209.29 0.00 0.00 29,900.00 90.54 331.88 7,344.69 25,389.21 0.0020,643.07 -15,256.42 0.00 0.00 30,000.00 90.54 331.88 7,343.76 25,489.20 0.0020,731.27 -15,303.55 0.00 0.00 30,100.00 90.54 331.88 7,342.82 25,589.20 0.0020,819.46 -15,350.68 0.00 0.00 30,113.01 90.54 331.88 7,342.70 25,602.21 0.0020,830.93 -15,356.81 0.00 0.00 TD at 30113.01 11/2/2020 4:44:29PM COMPASS 5000.15 Build 91E Page 10 ConocoPhillips Standard Proposal Report Well Plan: CD5-93 (12A)Local Co-ordinate Reference:Database:EDT 15 Alaska Prod Plan D25 @ 74.70usft (D25)TVD Reference:ConocoPhillips Alaska Inc_WNSCompany: Plan D25 @ 74.70usft (D25)MD Reference:Western North SlopeProject: TrueNorth Reference:CD5 Alpine West PadSite: Minimum CurvatureSurvey Calculation Method:Plan: CD5-93 (12A)Well: CD5-93Wellbore: CD5-93 wp06Design: Target Name - hit/miss target - Shape TVD (usft) Northing (usft) Easting (usft) +N/-S (usft) +E/-W (usft) Design Targets LongitudeLatitude Dip Angle (°) Dip Dir. (°) CD5-93 T02 T 090120 7,342.70 5,986,833.00 1,474,773.0020,830.93 -15,356.810.00 0.00 70° 22' 14.276 N 151° 20' 46.725 W - plan hits target center - Circle (radius 1,320.00) CD5-93 T02 T 032520 7,379.70 5,986,209.00 1,475,107.0020,213.72 -15,010.320.00 0.00 70° 22' 8.213 N 151° 20' 36.553 W - plan misses target center by 33.74usft at 29405.03usft MD (7349.33 TVD, 20206.54 N, -15023.14 E) - Circle (radius 1,320.00) CD5-93 T01 H 090120 7,480.70 5,972,793.00 1,481,923.006,936.25 -7,925.870.00 0.00 70° 19' 57.733 N 151° 17' 8.903 W - plan hits target center - Circle (radius 1,320.00) CD5-93 T01 H 032520 7,489.70 5,972,793.00 1,481,923.006,936.25 -7,925.870.00 0.00 70° 19' 57.733 N 151° 17' 8.903 W - plan misses target center by 8.99usft at 14355.68usft MD (7480.72 TVD, 6936.66 N, -7926.11 E) - Circle (radius 1,320.00) CD5-93 T01 H 072120 7,493.70 5,970,698.00 1,482,986.004,862.86 -6,820.950.00 0.00 70° 19' 37.352 N 151° 16' 36.584 W - plan misses target center by 949.33usft at 12289.76usft MD (6831.64 TVD, 5513.01 N, -6620.42 E) - Circle (radius 1,320.00) Vertical Depth (usft) Measured Depth (usft) Casing Diameter (in) Hole Diameter (in)Name Casing Points 10-3/4 x 13-1/22,189.502,194.39 10.750 13.500 7-5/8 x 9-7/8 by 117,480.7014,355.21 7.625 11.000 4-1/2 x 6-3/47,342.7030,113.01 4.500 6.750 Measured Depth (usft) Vertical Depth (usft) Dip Direction (°)Name Lithology Dip (°) Formations 1,400.86 Base Perm 0.00Empty1,399.70 2,332.41 C-30 0.00Empty2,324.70 2,888.70 C-10 0.00Empty2,845.70 4,167.68 K-3 0.00Empty3,768.70 4,710.77 K-2 0.00Empty3,997.70 4,841.82 K-2 Base 0.00Empty4,046.70 8,083.14 Alp 96 0.00Empty5,258.70 13,113.62 FCS Top 0.00Empty7,139.70 13,252.69 Kalubik 0.00Empty7,191.70 13,567.87 Kup C 0.00Empty7,303.70 13,601.44 LCU 0.00Empty7,314.70 14,130.02 Alp C 0.00Empty7,455.70 14,203.09 UJU 0.00Empty7,466.70 11/2/2020 4:44:29PM COMPASS 5000.15 Build 91E Page 11 ConocoPhillips Standard Proposal Report Well Plan: CD5-93 (12A)Local Co-ordinate Reference:Database:EDT 15 Alaska Prod Plan D25 @ 74.70usft (D25)TVD Reference:ConocoPhillips Alaska Inc_WNSCompany: Plan D25 @ 74.70usft (D25)MD Reference:Western North SlopeProject: TrueNorth Reference:CD5 Alpine West PadSite: Minimum CurvatureSurvey Calculation Method:Plan: CD5-93 (12A)Well: CD5-93Wellbore: CD5-93 wp06Design: Measured Depth (usft) Vertical Depth (usft) +E/-W (usft) +N/-S (usft) Local Coordinates Comment Plan Annotations 300.00 300.00 0.00 0.00 Start Build 1.50 500.00 499.91 -4.53 2.62 Start 700.00 hold at 500.00 MD 1,200.00 1,198.95 -36.26 20.93 Start Drop -1.20 1,450.00 1,448.84 -41.93 24.21 Start 55.66 hold at 1450.00 MD 1,505.66 1,504.50 -41.93 24.21 Start Build 1.50 1,805.66 1,804.19 -36.04 14.01 Start Build 1.50 2,194.39 2,189.50 -10.97 -29.42 Start 20.00 hold at 2194.39 MD 2,214.39 2,209.18 -9.17 -32.53 Start DLS 2.50 TFO 11.22 4,530.03 3,930.11 863.90 -1,126.76 Start 8759.60 hold at 4530.02 MD 13,289.62 7,205.51 6,112.06 -7,328.30 Start DLS 3.00 TFO 73.00 13,955.21 7,418.24 6,594.73 -7,728.70 Start Build 3.00 14,355.21 7,480.70 6,936.25 -7,925.87 Start 20.00 hold at 14355.21 MD 14,375.21 7,481.75 6,953.55 -7,935.86 Start DLS 1.50 TFO 28.02 14,642.19 7,487.49 7,186.82 -8,065.48 Start 15470.82 hold at 14642.19 MD 30,113.01 7,342.70 20,830.93 -15,356.81 TD at 30113.01 11/2/2020 4:44:29PM COMPASS 5000.15 Build 91E Page 12 ! 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(/* 04'''&'' 03&'% '&% %4%$&$$ &$0 '&''$&0 '&''%&0 '&' '&' &''$&0 '&3 ,@A @":@,"4% 04''&'' 03&'% '&% %4$&0 & '&''&0 '&''%&$3 '&' '&' &'%&0$ &'' ,@A @":@,"4% 04''&'' 03&'% '&% %4%& &% '&''0&$' '&''&' '&' '&' &'30&$ &3 ,@A @":@,"4% 04''&'' 03&'% '&% %4& & '&''0&$ '&''&0 '&' '&' &0&$0 &$ ,@A @":@,"4% 04%''&'' 03&'% '&% %40&% %& '&''0&3' '&''0&'% '&' '&' &%0&3 & ,@A @":@,"4% 04''&'' 03&'% '&% %4000&$ %&$ '&''0$&3 '&''0&%$ '&' '&' &$0$&30 &$% ,@A @":@,"4% 040''&'' 03&'% '&% %4$'%& & '&''0& '&''0&3 '&' '&' &'0& & ,@A @":@,"4% 04$''&'' 03&'% '&% %4$%& & '&''$&0 '&''$& '&' '&' &$&$ & ,@A @":@,"4% 043''&'' 03&'% '&% %4$$3& & '&''$%&' '&''$&$ '&' '&' &0$%&' &' ,@A @":@,"4% 04''&'' 03&'% '&% %430&' 0& '&''$0&'3 '&''3&$ '&' '&' &3$0&' &% ,@A @":@,"4% $4'''&'' 03&'% '&% %43&0 0&$ '&''$3& '&''3&0' '&' '&' &'$3&% &0 ,@A @":@,"4% $4''&'' 03&'% '&% %43&'3 $& '&''3'& '&''&' '&' '&' &3'&' &33 ,@A @":@,"4% $4''&'' 03&'% '&% %43&%$ $& '&''3& '&''&%0 '&' '&' &%3&0 &'3 ,@A @":@,"4% $4''&'' 03&'% '&% %40&3$ $& '&''3%& '&''&3 '&' '&' &03%& &$ ,@A @":@,"4% $4%''&'' 03&'% '&% 4''&0 3& '&''30&3 '&'''& '&' '&' &330& &%$ ,@A @":@,"4% $4''&'' 03&'% '&% 4'%'&0 3&$ '&''33&%% '&'''&$ '&' '&' &33&% &0$ ,@A @":@,"4% $40''&'' 03&'% '&% 4'$3&'% &% '&'''&' '&''&3 '&' '&' &%'& &3$ ,@A @":@,"4% $4$''&'' 03&'% '&% 4&% &% '&''&$ '&''&0 '&' '&' &%&3 %&'$ ,@A @":@,"4% $43''&'' 03&'% '&% 4&3 & '&''%&0 '&''&' '&' '&' &%%%&0% %&$ ,@A @":@,"4% $4''&'' 03&'% '&% 4'& '&0 '&''0&$' '&''&%3 '&' '&' &%0&$' %&%$ ,@A @":@,"4% 34'''&'' 03&'% '&% 4$&0 '&$0 '&''3&$0 '&''& '&' '&' &%$3&$$ %&0$ ,@A @":@,"4% 34'3&% 03&'% '&% 43&$' &$ '&''''&3 '&''& '&' '&' &%3''&3 %&33 ,@A @":@,"4% 34''&'' 03&'% '&% 40&'' &$ '&''''&3 '&''& '&' '&' &%3''&3 %&33 ,@A @":@,"4% 34''&'' 03&'% '&% 4'&%' &3 '&'''&3 '&''&$ '&' '&' &%'&' &' ,@A @":@,"4% 34''&'' 03&'% '&% 4&$ & '&'''%&0 '&''%& '&' '&' &''%&$ & ,@A @":@,"4% 34%''&'' 03&'% '&% 4$$&3 &%' '&'''$&' '&''%&00 '&' '&' &'$&' &' ,@A @":@,"4% 34''&'' 03&'% '&% 4%%&$ &3' '&'''&' '&''&' '&' '&' &'&' &$ ,@A @":@,"4% 340''&'' 03&'% '&% 4%&0 & '&''&0 '&''& '&' '&' &&$ & ,@A @":@,"4% 34$''&'' 03&'% '&% 4%3&0 &0 '&''& '&''&0 '&' '&' &%&% 0& ,@A @":@,"4% 343''&'' 03&'% '&% 40&$ %&' '&''&' '&''0&%' '&' '&' && 0&% ,@A @":@,"4% 34''&'' 03&'% '&% 40%&% %&%% '&''$&$ '&''0&3% '&' '&' &0$&$ 0& ,@A @":@,"4% 4'''&'' 03&'% '&% 40'& %&30 '&''&%% '&''$&3 '&' '&' &$&%% 0&$0 ,@A @":@,"4% 4''&'' 03&'% '&% 403& &$ '&''&' '&''$&$ '&' '&' &3& 0&3 ,@A @":@,"4% 4''&'' 03&'% '&% 40$0& &03 '&''&$ '&''3& '&' '&' &&3 $& ,@A @":@,"4% 4''&'' 03&'% '&% 4$&$ 0&' '&''&0% '&''3& '&' '&' &&0 $&% ,@A @":@,"4% 4%''&'' 03&'% '&% 4$&' 0&' '&''$&$ '&''&' '&' '&' &0'$&$ $&0 ,@A @":@,"4% 4''&'' 03&'% '&% 4$33&% 0& '&''&$3 '&''&%0 '&' '&' &0&$ $&3% ,@A @":@,"4% 40''&'' 03&'% '&% 43&33 $& '&''&3 '&''&' '&' '&' &0&30 3&'0 ,@A @":@,"4% 4$''&'' 03&'% '&% 430&3 $&$% '&''& '&'''&% '&' '&' &0& 3&3 ,@A @":@,"4% 43''&'' 03&'% '&% 4''&0$ 3& '&''0&'' '&'''&$3 '&' '&' &00&'' 3&' ,@A @":@,"4% 4''&'' 03&'% '&% 43&'0 3&0 '&''3&'$ '&''& '&' '&' &0%3&'$ 3&$ ,@A @":@,"4% '4'''&'' 03&'% '&% 4$&% 3&3 '&''%'&% '&''&00 '&' '&' &0%%'& 3&% ,@A @":@,"4% '4''&'' 03&'% '&% 04'&3% & '&''%& '&''&' '&' '&' &0%& &0 ,@A @":@,"4% '4''&'' 03&'% '&% 04''&% &3' '&''%%&3 '&''&% '&' '&' &0%%& & ,@A @":@,"4% '4''&'' 03&'% '&% 04'3$&0 '& '&''%0& '&''&3 '&' '&' &00%0&0 &0 ,@A @":@,"4% '4%''&'' 03&'% '&% 04&' '&0 '&''%3&% '&''&% '&' '&' &00%3&% &3 ,@A @":@,"4% '4''&'' 03&'% '&% 040&% &' '&'''&' '&''&30 '&' '&' &0$'&' '&'0 ,@A @":@,"4% '40''&'' 03&'% '&% 04&3 &%0 '&''&$ '&''%&' '&' '&' &0$&3 '&3 ,@A @":@,"4% '4$''&'' 03&'% '&% 04$&' &33 '&''%&0% '&''%&$% '&' '&' &03%&0 '& ,@A @":@,"4% '43''&'' 03&'% '&% 04$%& & '&''0&$ '&''&3 '&' '&' &030&$ '&$% ,@A @":@,"4% '4''&'' 03&'% '&% 04&3 &$ '&''3&$3 '&''&0 '&' '&' &03&$ '&$ ,@A @":@,"4% 4'''&'' 03&'% '&% 04%&$ & '&''0'&30 '&''0&'0 '&' '&' &00'&30 &' ,@A @":@,"4% 4''&'' 03&'% '&% 0430&$$ &% '&''0& '&''0&' '&' '&' &$'0&% &% ,@A @":@,"4% 4''&'' 03&'% '&% 04%%&0 & '&''0&'' '&''0&% '&' '&' &$'0&' &00 ,@A @":@,"4% . % #/ $ !"$ #$%&$'()01!/ $ !" 2$ #$%&$'()3!/ $ *$ +( / $ $ ,-(-(.( 3#$ $ /'0!4$5 &''1- ! $+ * =4#3 # ! (/* (/* > (/* ? (<* (<* . (/* > (/* 1 (/* > (/* 34# /> (/* % %2 (/* (/* ? (<* 0 # 1 ! (/* 4''&'' 03&'% '&% 04%0& %&$ '&''0$&'$ '&''$&3 '&' '&' &$0$&'3 &3 ,@A @":@,"4% 4%''&'' 03&'% '&% 04%3&% %&$3 '&''0& '&''$&3 '&' '&' &$0& & ,@A @":@,"4% 4''&'' 03&'% '&% 040& &' '&''$& '&''3&0 '&' '&' &$$& & ,@A @":@,"4% 40''&'' 03&'% '&% 04$&$ &0 '&''$& '&''3&$' '&' '&' &$$&' & ,@A @":@,"4% 4$''&'' 03&'% '&% 040& 0&' '&''$&$ '&''&% '&' '&' &$$&$ &3 ,@A @":@,"4% 43''&'' 03&'% '&% 040%3& 0&% '&''$$&%% '&''&3 '&' '&' &$$$&% &'0 ,@A @":@,"4% 4''&'' 03&'% '&% 0403&' 0&30 '&''$& '&''%'&' '&' '&' &$$& & ,@A @":@,"4% 4'''&'' 03&'% '&% 04$& $&3 '&''3& '&''%'&%$ '&' '&' &$3& & ,@A @":@,"4% 4''&'' 03&'% '&% 04$0'&0 $&$' '&''3&00 '&''%'& '&' '&' &$%3&0$ &$$ ,@A @":@,"4% 4''&'' 03&'% '&% 04$3&'3 3& '&''3&$ '&''%& '&' '&' &$%3&$% %&'' ,@A @":@,"4% 4''&'' 03&'% '&% 043&%$ 3& '&''3$&3 '&''%&$ '&' '&' &$%3$&3 %&% ,@A @":@,"4% 4%''&'' 03&'% '&% 043$&30 3& '&''3&33 '&''%& '&' '&' &$3&3 %&%3 ,@A @":@,"4% 4''&'' 03&'% '&% 04'&0 3& %&0'&% '&''%&% '&' &$ &$'&% '&3 ! ?!6=!B'74 40''&'' 03&'% '&% 04%$&0 3&30 '&''&% '&''%&%0 '&' '&' &$&% 0&' ,?":40 4$''&'' 03&'% '&% 043&'% 3&3 '&''&' '&''%&%$ '&' '&' &$& 0& ,?":40 43''&'' 03&'% '&% $4'&% 3& '&''&$ '&''%&' '&' '&' &$&3 0&0 ,?":40 4''&'' 03&'% '&% $4'&3 3& '&''& '&''%&% '&' '&' &$&0 0&% ,?":40 4'''&'' 03&'% '&% $4'$& &' '&''&' '&''%& '&' '&' &$0&'% 0&0 ,?":40 4''&'' 03&'% '&% $4%&0 & '&''0& '&''%&0 '&' '&' &$00& 0&$$ ,?":40 4&0 03&'% '&% $4&$' & '&''$&' '&''%&$ '&' '&' &$$$&' 0& ,?":40 4''&'' 03&'% '&% $4$&'' & '&''$&' '&''%&$ '&' '&' &$$$&' 0& ,?":40 4&0 03&'% '&% $4&$' & '&''3&$ '&''%&3 '&' '&' &$$3&$% $&' ,?":40 43&0 03&'% '&% $4'& & '&''3&$ '&''%&3 '&' '&' &$$3&$% $&' ,?":40 4''&'' 03& '&0 $4'&3 & '&''3&3$ '&''%&3% '&' '&' &$$3&33 $&'0 ,?":40 4%''&'' 0&' &0 $4%&' &% '&''& '&''%&3 '&' '&' &$''&0 $& ,?":40 4''&'' $'&' 0&00 $43'&33 &0 '&''''& '&''%&% '&' '&' &3%'& $&3 ,?":40 40$&3$ $'&$' 3&$' $4'&$' &$' '&''''&00 '&''%%&$ '&' '&' &'&% $&0 ,?":40 40''&'' $&' &00 $4%& &$' '&''''&00 '&''%%&$ '&' '&' &'&% $&0 ,?":40 40'&%% $&'% &$' $4%&$' &3 '&''''&$ '&''%&% '&' '&' '&''& $&$$ ,?":40 4$''&'' $&' &0 $4%&3$ &3 '&''''&$ '&''%&% '&' '&' '&''& $&$$ ,?":40 43''&'' $&' & $4$&$' %'&' '&''&0$ '&'%0&' '&' '&' '&'0&% 3&' ,?":40 4''&'' $%& 3&% $4%'&0 %'& '&''3&0 '&'%0&% '&' '&' '&'3&$' 3& ,?":40 4& $&'' '&'' $4%3&% %'& '&''$&$3 '&'%$& '&' '&' '&%'&0$ 3& ,?":40 %4'''&'' $0&% '&'' $4%& %'&3 '&''3&0% '&'%0& '&' '&' '&'&%$ 3&03 ,?":40 %4''&'' $&% '&'' $4%'&3 &0 '&''3&'$ '&'%& '&' '&' '&''0&03 3& ,@A @":@,"%40 %4'&' 3'&% '&'' $4%&$' &$' '&''3&0 '&'%&3 '&' '&' '&'0$&3 3&' ,@A @":@,"%40 %4''&'' 3&% '&'' $4%00& &$' '&''3&0 '&'%&3 '&' '&' '&'0$&3 3&' ,@A @":@,"%40 %4'&' 3&%% '&'' $4%00&$' &$3 '&''30&$ '&'%&3 '&' '&' '&$&0 3&$ ,@A @":@,"%40 %4''&'' 3&% '&'' $4%$$&' &$3 '&''30&$ '&'%&3 '&' '&' '&$&0 3&$ ,@A @":@,"%40 %4& 3$&'' '&'' $4%3'&$' &3 '&''30&% '&'%'&3' '&'' '&' '&0$&3 3&3 ,@A @":@,"%40 %4$& 3$&'' '&'' $4%3&$ &3 '&''30&0 '&'%'&3 '&'' '&' '&33&' 3&33 ,@A @":@,"%40 %4%''&'' 3$& '&$ $4%3&$ &3$ '&''30& '&'%'&$ '&'' '&' '&3& 3&% ,@A @":@,"%40 %4''&'' 33&0 '&33 $4%30&%3 &0 '&''30& '&'%'&$ '&'' '&' '&$3&$$ &$ ,@A @":@,"%40 %40''&'' 3&3 &3 $4%3$&03 %'&'0 '&''30&' '&'%'&'0 '&'' '&' '&%& &% ,@A @":@,"%40 %40%& '&% &33 $4%3$&% %'&' '&''3&3 '&'& '&'' '&' '&3&0 & ,@A @":@,"%40 %4$''&'' '&% &33 $4%30& %'& '&''30& '&'%'&' '&'' '&' '&%&33 &0$ ,@A @":@,"%40 %43''&'' '&% &33 $4%30&' %'&0 '&''3$&'' '&'%'& '&'' '&' '&''&%0 & ,@A @":@,"%40 %4''&'' '&% &33 $4%3&'$ %'&$ '&''3$&00 '&'%'& '&'' '&' '&'&'0 '& ,@A @":@,"%40 4'''&'' '&% &33 $4%3%&% %'&%3 '&''33&% '&'%'& '&'' '&' '&03'&0$ '& ,@A @":@,"%40 4''&'' '&% &33 $4%3&' %'&0' '&''3&'% '&'%'&% '&'' '&' '&$$'& '&3 ,@A @":@,"%40 4''&'' '&% &33 $4%3&$ %'&$ '&''3&$0 '&'%'&$ '&'' '&' '&3$'& & ,@A @":@,"%40 4''&'' '&% &33 $4%3& %'&3 '&'''&' '&'%'&$' '&'' '&' '&0'&3 &%3 ,@A @":@,"%40 4%''&'' '&% &33 $4%3'& %'&3 '&''& '&'%'&3 '&'' '&' &'0'%& &3 ,@A @":@,"%40 4''&'' '&% &33 $4%$&%0 %& '&''&' '&'%'&$ '&'' '&' &0'%& & ,@A @":@,"%40 . % #/ $ !"$ #$%&$'()01!/ $ !" 2$ #$%&$'()3!/ $ *$ +( / $ $ ,-(-(.( 3#$ $ /'0!4$5 &''1- ! $+ * =4#3 # ! (/* (/* > (/* ? (<* (<* . (/* > (/* 1 (/* > (/* 34# /> (/* % %2 (/* (/* ? (<* 0 # 1 ! 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(/* :;% (/* :;% (/* . # ''&'' ''&'' '&'' '&'' "9(*&' ''&'' %& %& &0 "$''&''*''&'', 4''&'' 43& 0&0 '& "&' 4%'&'' 4%%3&3% %& %& "&00*%'&'', 4'&00 4'%&' %& %& "9(*&' 43'&00 43'%& 0&'% %&' "9(*&' 4%& 43&' '&$ &% "'&''*%&, 4%& 4'&3 &$ & "6"&'+A?& %4'&' 4'& 30&' 40&$0 "3$&0'*%'&', 43&0 $4'& 04&'0 $43&' "6"&''+A?$&'' 4& $4%3&% 04%&$ $4$3&$' "9(*&'' %4& $4%3'&$' 040& $4&3$ "'&''*%&, %4$& $4%3&$ 04& $4&30 "6"&'+A?3&' %40%& $4%3$&% $430&3 34'0&%3 "%$'&3*%0%&, '4&' $4%&$' '43'& 40&3 +'&' . *9> *9> From:Rawlins, Tom D To:Loepp, Victoria T (CED) Cc:Hobbs, Greg S Subject:RE: CRU CD5-93 (PTD 220-073) MPSP & 12.2 ppg reservoir pressure potential Date:Wednesday, December 16, 2020 11:23:59 AM Hi Victoria, We do not expect to encounter those high pressures in CD5-93. I believe that Johnson misspoke yesterday and he meant to say 10.2 ppg, not 12.2 ppg, for the CD5-90 C sand potential (I CC’d Greg Hobbs to this e-mail to confirm). The CD5-93 well is north of the UJU and we expect lower pressures in the Alpine A & C sands due to production of CD5-92 to the east, and that producer has been shut-in since September to keep the sands from being drawn down further. Below is the PP & FG prognosis from our asset team, which I confirmed is still current. Also, north of the UJU the A & C sands are on top of each other (no B sands) and are predicted to have the same maximum pressures shown below. The MPSP and mitigation measures referenced in the CD5-93 PTD application are still valid and have not changed. I hope that this clarifies any miscommunication! Best regards, Tom From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, December 16, 2020 9:48 AM To: Rawlins, Tom D <Tom.D.Rawlins@conocophillips.com> Subject: [EXTERNAL]KRU CD5-93(PTD 220-073) MPSP & 12.2 ppg reservoir pressure potential Tom, Concerning maximum potential reservoir pressure. Will there be the same possibility of intersecting a 12.2 ppg sand while drilling the production section as there is in CD5-90. If so, this would affect the maximum potential reservoir pressure and the MPSP. Please explain. What is the maximum potential reservoir pressure, the MPSP and what are CPAI’s plan if higher pressures are encountered? Please reply at your earliest convenience. 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 From: Rawlins, Tom D <Tom.D.Rawlins@conocophillips.com> Sent: Monday, December 14, 2020 1:44 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: KRU CD5-93(PTD 220-073) Kick Tolerance Hi Victoria – just a quick note that CD5-93 should be a “CRU” Alpine well, I’ll double-check to make sure I filled out the PTD app correctly in case I typo’d (shows KRU in the subject)! Thanks, Tom From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, December 11, 2020 12:49 PM To: Rawlins, Tom D <Tom.D.Rawlins@conocophillips.com> Subject: [EXTERNAL]KRU CD5-93(PTD 220-073) Kick Tolerance 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. Tom, Could you please provide kick tolerance calculations for drilling out of the surface casing shoe? You may email those to me. 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 Well: CD5-93 <== Data Input Name: Surface Shoe Kick Tolerance <== Data Input Mud Weight (ppg) 9.60 <== Data Input Weak point or LOT - Measured depth (ft) 2,194'<== Data Input Weak point or LOT True vertical depth (ft) 2,190'<== Data Input Weak point or LOT - Hole angle (deg) 10.3º<== Data Input Weak point or LOT - Hole size (in) 9.875"<== Data Input Weak point pressure or LOT - EMW (ppg) 12.50 <== Data Input Zone of interest - Measured depth (ft) 14,293'<== Data Input Alpine A interval Zone of interest - True vertical depth (ft) 7,477'<== Data Input Zone of interest - Hole angle (deg) 85.1º<== Data Input Zone of interest - Hole size (in) 11.000"<== Data Input Zone of interest - Pore pressure EMW (ppg) 8.60 <== Data Input Gas gradient (psi/ft) 0.10 <== Data Input Bottom hole assembly OD (in) 6.750"<== Data Input Baker proposed Int1 BHA Bottom hole assembly length (ft) 214'<== 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)0.0704 Additional safety margin (psi) 0.00 <== Data Input Weak point pressure (psi):Plo 1,423 psi Weak point pressure - Safety margin:Pmax 1,423 psi Pmax EMW 12.50 ppg Max anticipated formation pressure (psi):Pf 3,344 psi Weak Pt to Zone of Interest distance (TVD ft):OH {TVD}5,288' Weak Pt to Zone of Interest distance (MD ft):OH {MD}12,099' Maximum influx height at the bit (TVD ft):H {TVD}1,801' Maximum influx height at the bit (MD ft):H {MD}21,085' Calc. volume of {H} around BHA:V1bha 15.7 bbl Calc. volume of {H} around drill pipe:V1dp 1946.4 bbl Calc. volume that H equals @ initial shut in:V1 1962.1 bbl Calc. vol. that H equals @ weak point (MD ft):Vwp 129.0 bbl Calc. volume of Vwp @ initial shut in:V2 54.9 bbl Kick Tolerance: V2 54.9 bbl NOTE: Spreadsheet revised by: G. S. Walz 3/9/99 Well: CD5-93 <== Data Input Name: Surface Shoe Kick Tolerance <== Data Input Mud Weight (ppg) 9.60 <== Data Input Weak point or LOT - Measured depth (ft) 2,194'<== Data Input Weak point or LOT True vertical depth (ft) 2,190'<== Data Input Weak point or LOT - Hole angle (deg) 10.3º<== Data Input Weak point or LOT - Hole size (in) 9.875"<== Data Input Weak point pressure or LOT - EMW (ppg) 12.50 <== Data Input Zone of interest - Measured depth (ft) 13,252'<== Data Input Kuparuk interval (use Miluveach for -93) Zone of interest - True vertical depth (ft) 7,192'<== Data Input Reservoir quality NOT anticipated Zone of interest - Hole angle (deg) 68.0º<== Data Input Zone of interest - Hole size (in) 11.000"<== Data Input Zone of interest - Pore pressure EMW (ppg) 8.65 <== Data Input Gas gradient (psi/ft) 0.10 <== Data Input Bottom hole assembly OD (in) 6.750"<== Data Input Baker proposed Int1 BHA Bottom hole assembly length (ft) 214'<== 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)0.0704 Additional safety margin (psi) 0.00 <== Data Input Weak point pressure (psi):Plo 1,423 psi Weak point pressure - Safety margin:Pmax 1,423 psi Pmax EMW 12.50 ppg Max anticipated formation pressure (psi):Pf 3,235 psi Weak Pt to Zone of Interest distance (TVD ft):OH {TVD}5,003' Weak Pt to Zone of Interest distance (MD ft):OH {MD}11,058' Maximum influx height at the bit (TVD ft):H {TVD}1,717' Maximum influx height at the bit (MD ft):H {MD}4,584' Calc. volume of {H} around BHA:V1bha 15.7 bbl Calc. volume of {H} around drill pipe:V1dp 407.5 bbl Calc. volume that H equals @ initial shut in:V1 423.2 bbl Calc. vol. that H equals @ weak point (MD ft):Vwp 123.0 bbl Calc. volume of Vwp @ initial shut in:V2 54.1 bbl Kick Tolerance: V2 54.1 bbl NOTE: Spreadsheet revised by: G. S. Walz 3/9/99 Well: CD5-93 <== Data Input Name: Surface Shoe Kick Tolerance <== Data Input Mud Weight (ppg) 9.60 <== Data Input Weak point or LOT - Measured depth (ft) 2,194'<== Data Input Weak point or LOT True vertical depth (ft) 2,190'<== Data Input Weak point or LOT - Hole angle (deg) 10.3º<== Data Input Weak point or LOT - Hole size (in) 9.875"<== Data Input Weak point pressure or LOT - EMW (ppg) 12.50 <== Data Input Zone of interest - Measured depth (ft) 5,752'<== Data Input Minke interval (Sub-97 for -93) Zone of interest - True vertical depth (ft) 4,387'<== Data Input Reservoir quality anticipated Zone of interest - Hole angle (deg) 68.0º<== Data Input Zone of interest - Hole size (in) 9.875"<== Data Input Zone of interest - Pore pressure EMW (ppg) 8.46 <== Data Input Gas gradient (psi/ft) 0.10 <== Data Input Bottom hole assembly OD (in) 6.750"<== Data Input Baker proposed Int1 BHA Bottom hole assembly length (ft) 214'<== Data Input Drill pipe OD (in) 5.000"<== Data Input BHA annular vol. @ zone of interest (bbl/ft)0.0505 DP annular vol. @ zone of interest (bbl/ft)0.0704 DP annular vol. @ weak point (bbl/ft)0.0704 Additional safety margin (psi) 0.00 <== Data Input Weak point pressure (psi):Plo 1,423 psi Weak point pressure - Safety margin:Pmax 1,423 psi Pmax EMW 12.50 ppg Max anticipated formation pressure (psi):Pf 1,930 psi Weak Pt to Zone of Interest distance (TVD ft):OH {TVD}2,198' Weak Pt to Zone of Interest distance (MD ft):OH {MD}3,558' Maximum influx height at the bit (TVD ft):H {TVD}1,479' Maximum influx height at the bit (MD ft):H {MD}3,947' Calc. volume of {H} around BHA:V1bha 10.8 bbl Calc. volume of {H} around drill pipe:V1dp 263.0 bbl Calc. volume that H equals @ initial shut in:V1 273.8 bbl Calc. vol. that H equals @ weak point (MD ft):Vwp 105.9 bbl Calc. volume of Vwp @ initial shut in:V2 78.1 bbl Kick Tolerance: V2 78.1 bbl NOTE: Spreadsheet revised by: G. S. Walz 3/9/99 From:Rawlins, Tom D To:Loepp, Victoria T (CED) Subject:RE: KRU CD5-93(PTD 220-073) Kick Tolerance Date:Monday, December 14, 2020 1:43:58 PM Hi Victoria – just a quick note that CD5-93 should be a “CRU” Alpine well, I’ll double-check to make sure I filled out the PTD app correctly in case I typo’d (shows KRU in the subject)! Thanks, Tom From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, December 11, 2020 12:49 PM To: Rawlins, Tom D <Tom.D.Rawlins@conocophillips.com> Subject: [EXTERNAL]KRU CD5-93(PTD 220-073) Kick Tolerance 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. Tom, Could you please provide kick tolerance calculations for drilling out of the surface casing shoe? You may email those to me. 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 Spider View Project: Western North SlopeSite: CD5 Alpine West PadWell: Plan: CD5-93 (12A)Wellbore: CD5-93Design: CD5-93 wp06-16000016000South(-)/North(+) (8000 usft/in)-32000 -16000 0 16000 32000West(-)/East(+) (8000 usft/in)CD5-93 T01 H 090120CD5-93 T02 T 0901206 570 756070706070 756070 75756060707575707565 7560706075757560757575 Spider View Project: Western North SlopeSite: CD5 Alpine West PadWell: Plan: CD5-93 (12A)Wellbore: CD5-93Design: CD5-93 wp06070001400021000South(-)/North(+) (3500 usft/in)-14000 -7000 0 7000 14000West(-)/East(+) (3500 usft/in)13188CD5-93 T01 H 090120CD5-93 T02 T 0901206 570 756065706065706 0 6 570 6570 756070 7560706 07070 6070607070756065707075606570757075657075606570 Spider View Project: Western North SlopeSite: CD5 Alpine West PadWell: Plan: CD5-93 (12A)Wellbore: CD5-93Design: CD5-93 wp0606001200South(-)/North(+) (300 usft/in)-2400 -1800 -1200 -600 0 600West(-)/East(+) (300 usft/in)2628303234*37*8790510152 0 1520252510152025515202 52025 515202530352 025 10152 025 152530 52530354045 5102025205 151520253035152025303540455055606510152025303551052025305203035152025303520 2 5 30 3540510152025303540 3-D View Project: Western North SlopeSite: CD5 Alpine West PadWell: Plan: CD5-93 (12A)Wellbore: CD5-93Design: CD5-93 wp06CD5-93 wp06CD5-02CD5-02ACD5-03CD5-04CD5-07CD5-10CD5-12CD5-22CD5-23CD5-23L1CD5-23L1-01CD5-90 (C) wp11CD5-90L1 (A) wp14CD5-92CD5-96CD5-96L1CD5-94 wp06CD5-95 wp02 From:Rawlins, Tom D To:Davies, Stephen F (CED) Cc:Boyer, David L (CED); Loepp, Victoria T (CED); Hobbs, Greg S Subject:RE: CRU CD5-93 (PTD 220-073) - Request Date:Wednesday, November 25, 2020 3:05:56 PM Attachments:CD5-93_WP06_quarter mile spiders.pdf CD5-93_PTD_20201027.pdf Hi Steve, Just following up via e-mail after our phone call from yesterday; regarding your questions: 1. No H2S experienced while drilling the wells on CD5. We do have a robust H2S program that includes H2S detection sensors on our rigs and also crew-worn sniffers for everyone at CD5 as they are processed on location with Site Control. In regards to H2S produced after the wells have been online, a sample of the most recent tests show the following (nothing that requires signage): a. CD5-04: 8/31/20, 45ppm b. CD5-313: 8/31/20, 55 ppm c. CD5-22: 8/31/20, 45 ppm d. CD5-98: 8/31/20, 50 ppm 2. Correct that there are no wells within ¼ mile of the injection zone (Alpine sands) for CD5-93 and, a. It will be pre-produced for a month to help characterize the Alpine A sand reservoir to assist on decision making for future development wells b. Regarding the ¼ mile radius surrounding CD5-93 for Alpine A sand injection, there are no other wells within the AOR and I have included the ¼ mile spider plots to illustrate this. The closest existing well is CD5-92 that comes within 1,442’ in the same pool as described in the 10-401. I hope that this clarifies the questions you asked below. Please do not hesitate to reach out to me if any additional information is needed. Best regards and I hope everyone has a great Thanksgiving, Tom From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Friday, November 20, 2020 2:22 PM To: Rawlins, Tom D <Tom.D.Rawlins@conocophillips.com> Cc: Boyer, David L (CED) <david.boyer2@alaska.gov>; Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]RE: CRU CD5-93 (PTD 220-073) - Request Tom, I have a few questions about CPAI’s Permit to Drill application for the planned CD5-93 well: 1. Has H2S been measured in any wells from the CD5 Drill Site? If so, please provide a list of wells, measured values expressed in units of ppm, and dates samples were taken. 2. According to the cover letter accompanying CPAI’s current application, CD5-93 will be completed as an injector in the Alpine A reservoir. a. Will CD5-93 be pre-produced for an extended period, or will it be simply flowed back for clean up? b. Because this well will be an injector, it is also governed by 20 AAC 25.402, Enhanced Recovery Operations. If there are no wells that lie within the one-quarter-mile radius Area of Review (AOR) surrounding CD5-93, please state so. If other wells lie within the AOR, please review Regulation 20 AAC 25.402 with specific emphasis on subparagraphs 20 AAC 25.402(c)(15) and 20 AAC 25.402(e). Attached are two documents that will aid you as you compile the required AOR information: a guidance document and the AOR attachment to CPAI’s 2019 Permit to Drill application for the KRU 3G-27 injector. Please present information for all wells that lie within the AOR using the spreadsheet format shown in CPAI’s 2019 AOR attachment. Please let me know if I you have questions. Regards, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (CED) Sent: Thursday, November 19, 2020 2:21 PM To: Rawlins, Tom D <Tom.D.Rawlins@conocophillips.com> Subject: RE: CRU CD5-93 (PTD 220-073) - Request Tom, Perfect. Thanks again for your help and stay safe, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Rawlins, Tom D <Tom.D.Rawlins@conocophillips.com> Sent: Thursday, November 19, 2020 2:04 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: RE: CRU CD5-93 (PTD 220-073) - Request Hi Steve, Please let me know if this will work for you. Thanks, Tom From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Thursday, November 19, 2020 1:35 PM To: Rawlins, Tom D <Tom.D.Rawlins@conocophillips.com> Subject: [EXTERNAL]CRU CD5-93 (PTD 220-073) - 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. Tom, Could you please provide the planned digital directional survey data file for CRU CD5-93. It will speed my portion of the review for this Permit to Drill application. Excel spreadsheet or ASCII table format will be fine. All I need is MD, Inclination, and azimuth information. Thanks and stay safe, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Q211186851024717332293334142359426201615123019271123252822133631T11N, R4E, UMT11N, R3E, UMT11N,R4E, UMT12N, R4E, UMT12N, R3E, UMT11N, R3E, UMT12N, R3E, UMT12N, R4E, UMADL387211ADL388466AA094165AA092347ASRC-NPR1ASRC-NPR2ASRC-NPR2ASRC-NPR4ASRC-NPR4ASRC-NPR3AA087888ASRC-NPR8CD2-74 CD5-26 CD5-25L1 CD5-2 5 CD5-314XCD5-313 P B 1 CD5-313CD5-04CD5-05CD5-316CD5-316PB1CD5-99CD5-11CD5-01CD5-19L1CD5-17CD5-17L1CD5-18CD5-23 L 1 - 0 1 CD5-9 6 L1CD5-08CD5 -23 L1 CD5-9 6 CD5-21CD5-06 CD5-06L1CD5-10 CD5-02CD5-0 7 C D5-20 L 1 CD5-2 0CD5-03CD5-02ACD5-9 8 L 1 CD5-98 CD5-09 CD5-2 2 CD5-1 2 CD5-2 3 CD5-92 CD5QPadWell TrajectoryOpen IntervalActiveSuspendedInactivePlugged and AbandonedAlpine PAUnit BoundaryIndustry LeaseCPAI LeaseCD5-93PTD Plat10/27/2020Document Path: S:\ANC\Longterm\Alpine\Development Eng\ArcGIS_EXP130_IND\Geotech_info\CRU_Wells\Pad_CD5\CD5-93\CD5-93_PTD_20201026.mxd¯00.51MilesCD5-9 3Alpine PAColville River Unit Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this 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. X CRU CD5-93 220-073 COLVILLE RIVER, ALPINE OILCOLVILLE RIVER WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:COLVILLE RIVER UNIT CD5-93Initial Class/TypeSER / PENDGeoArea890Unit50360On/Off ShoreOnProgramSERField & PoolWell bore segAnnular DisposalPTD#:2200730COLVILLE RIVER, ALPINE OIL - 120100NA1Permit fee attachedYesWell begins in ASRC lease NPR4 and passes through NPR2, NPR3 and NPR12Lease number appropriateYes3Unique well name and numberYesCOLVILLE RIVER, ALPINE OIL - 120100, governed by CO 443C.4Well located in a defined poolYesAs planned, well will conform to spacing requirements.5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitYesInjection governed by Area Injection Order No. 18D14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For YesNone15All wells within 1/4 mile area of review identified (For service well only)Yes16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes80' conductor driven18Conductor string providedYesSC shoe at 2194' MD19Surface casing protects all known USDWsYes178% excess cement planned20CMT vol adequate to circulate on conductor & surf csgNo21CMT vol adequate to tie-in long string to surf csgYesTOC planned 250' TVD above Kup C; 2nd stg 250' TVD above Minke22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks; all waste to approved disposal wells24Adequate tankage or reserve pitNA25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedYesDiverter waiver granted per 20 AAC 25.035(h)(2)27If diverter required, does it meet regulationsYesMax reservoir pressure is 8.7 ppg ; will drill w/ 8.8.to 9.4 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 2618 psig; will test BOPs to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesH2S measures required33Is presence of H2S gas probableYesNo wells within 1/4 mile radius34Mechanical condition of wells within AOR verified (For service well only)NoRequired per 20 AAC 25.065(b): CD5 wells have reported 45 to 50 ppm H2S. Rig has sensors/alarms.35Permit can be issued w/o hydrogen sulfide measuresYesNormal pressure gradient expected. Managed Pressure Drilling will be used to mitigate shale instability36Data presented on potential overpressure zonesNAand cycling.37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate12/2/2020ApprVTLDate12/16/2020ApprSFDDate12/2/2020AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateJMP 12/18/2020dts 12/17/2020JLC 12/17/2020