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219-166
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1R-23A KUPARUK RIV UNIT 1R-23A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 1R-23A 50-029-22200-01-00 219-166-0 W SPT 6713 2191660 1678 2570 2562 2555 2571 160 200 200 200 4YRTST P Austin McLeod 5/5/2023 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:KUPARUK RIV UNIT 1R-23A Inspection Date: Tubing OA Packer Depth 1310 1800 1765 1750IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230506183750 BBL Pumped:1.3 BBL Returned:1.2 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 999 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.02 11:08:25 -08'00' Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVED APR 2 3 2020 AOGCC 219166 32812 13 -Mar -20 WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD # 1 1E-20 2 1E-12 3 1E-12 4 1F-05 5 1R -23A 6 WSW 11 7 3G-05 8 3M-17 9 3N -02A 10 30-01 50-029-20895-00906260886 50-029-20736-00 50-029-20736-00 50-029-20807-00 50-029-22200-01 50-029-20882-00 50-029-20132-00 50-029-21729-00 SO -029-21527-01 50-029-21836-00 906207895 906190298 906223186 906228630 906310488 906174377 906210841 906192001 1906193765 Kuparuk Kuparuk Kuparuk Kuparuk Kuparuk Shallow Sand Kuparuk Kuparuk Kuparuk Kuparuk Multi Finger Caliper Leak Detect with ACX Plug Setting Record Injection Profile Log Multi Finger Caliper Plug Setting Record Packer Setting Record Leak Detect Log Leak Detect Log Plug Setting Record Field&Proc Processed Final -Field Field&Proc Field&Proc Final -Field Final -Field Final -Field Final -Field Final -Field 23 -Jan -20 30 -Dec -19 19 -Dec -19 8 -Jan -20 7 -Jan -20 12 -Feb -20 26 -Dec -19 29 -Dec -19 23 -Dec -19 20 -Dec -19 0 1 0 1 0 1 0 1 0 1 0 1 0 1 0 1 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date: Signed: CDW 04/14/2020 SFD 4/10/2020VTL 4/20/20 DSR-4/9/2020 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22200-01-00Well Name/No. KUPARUK RIV UNIT 1R-23ACompletion Status1-OILCompletion Date1/20/2020Permit to Drill2191660Operator ConocoPhillips Alaska, Inc.MD14723TVD7017Current Status1WINJ4/20/2020UICYesWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:GR/RESNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScale0 0 2191660 KUPARUK RIV UNIT 1R-23A LOG HEADERS32027LogLog Header ScansC2/10/2020 Electronic File: 1R-23A EOW - NAD27.pdf32027EDDigital DataC2/10/2020 Electronic File: 1R-23A EOW - NAD27.txt32027EDDigital DataC2/10/2020 Electronic File: 1R-23A EOW - NAD83.pdf32027EDDigital DataC2/10/2020 Electronic File: 1R-23A EOW - NAD83.txt32027EDDigital DataC2/10/2020 Electronic File: 1R-23APB1 EOW - NAD27.pdf32028EDDigital DataC2/10/2020 Electronic File: 1R-23APB1 EOW - NAD27.txt32028EDDigital DataC2/10/2020 Electronic File: 1R-23APB1 EOW - NAD83.pdf32028EDDigital DataC2/10/2020 Electronic File: 1R-23APB1 EOW - NAD83.txt32028EDDigital Data0 0 2191660 KUPARUK RIV UNIT 1R-23A PB1 LOG HEADERS32028LogLog Header ScansC2/13/202011086 14723 Electronic Data Set, Filename: 1R-23A GAMMA RES.las32034EDDigital DataC2/13/2020 Electronic File: 1R-23A 2MD Final.cgm32034EDDigital DataC2/13/2020 Electronic File: 1R-23A 5MD Final.cgm32034EDDigital DataC2/13/2020 Electronic File: 1R-23A 5TVDSS Final.cgm32034EDDigital DataC2/13/2020 Electronic File: 1R-23A 2MD Final.pdf32034EDDigital DataC2/13/2020 Electronic File: 1R-23A 5MD Final.pdf32034EDDigital DataC2/13/2020 Electronic File: 1R-23A 5TVDSS Final.pdf32034EDDigital DataC2/13/2020 Electronic File: 1R-23A EOW - NAD27.pdf32034EDDigital DataC2/13/2020 Electronic File: 1R-23A EOW - NAD27.txt32034EDDigital DataMonday, April 20, 2020AOGCCPage 1 of 5PB1~1R-23A GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22200-01-00Well Name/No. KUPARUK RIV UNIT 1R-23ACompletion Status1-OILCompletion Date1/20/2020Permit to Drill2191660Operator ConocoPhillips Alaska, Inc.MD14723TVD7017Current Status1WINJ4/20/2020UICYesC2/13/2020 Electronic File: 1R-23A EOW - NAD83.pdf32034EDDigital DataC2/13/2020 Electronic File: 1R-23A EOW - NAD83.txt32034EDDigital DataC2/13/2020 Electronic File: 1R-23A Final Surveys 14723 TD.csv32034EDDigital DataC2/13/2020 Electronic File: 1R-23A Final Surveys 14723 TD.xlsx32034EDDigital DataC2/13/2020 Electronic File: 1R-23A Survey Listing.txt32034EDDigital DataC2/13/2020 Electronic File: 1R-23A Surveys.txt32034EDDigital DataC2/13/2020 Electronic File: 1R-23A_25_tapescan_BHI_CTK.txt32034EDDigital DataC2/13/2020 Electronic File: 1R-23A_5_tapescan_BHI_CTK.txt32034EDDigital DataC2/13/2020 Electronic File: 1R-23A_output.tap32034EDDigital DataC2/13/2020 Electronic File: 1R-23A 2MD Final.tif32034EDDigital DataC2/13/2020 Electronic File: 1R-23A 5MD Final.tif32034EDDigital DataC2/13/2020 Electronic File: 1R-23A 5TVDSS Final.tif32034EDDigital Data0 0 2191660 KUPARUK RIV UNIT 1R-23A LOG HEADERS32034LogLog Header ScansC2/13/202011086 13876 Electronic Data Set, Filename: 1R-23APB1 GAMMA RES.las32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 2MD Final.cgm32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 5MD Final.cgm32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 5TVDSS Final.cgm32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 2MD Final.pdf32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 5MD Final.pdf32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 5TVDSS Final.pdf32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 EOW - NAD27.pdf32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 EOW - NAD27.txt32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 EOW - NAD83.pdf32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 EOW - NAD83.txt32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 Final Surveys.csv32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 Final Surveys.xlsx32035EDDigital DataMonday, April 20, 2020AOGCCPage 2 of 51R-23APB1GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22200-01-00Well Name/No. KUPARUK RIV UNIT 1R-23ACompletion Status1-OILCompletion Date1/20/2020Permit to Drill2191660Operator ConocoPhillips Alaska, Inc.MD14723TVD7017Current Status1WINJ4/20/2020UICYesC2/13/2020 Electronic File: 1R-23APB1 Survey Listing.txt32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 Surveys.txt32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1_25_tapescan_BHI_CTK.txt32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1_5_tapescan_BHI_CTK.txt32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1_output.tap32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 2MD Final.tif32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 5MD Final.tif32035EDDigital DataC2/13/2020 Electronic File: 1R-23APB1 5TVDSS Final.tif32035EDDigital Data0 0 2191660 KUPARUK RIV UNIT 1R-23A PB1 LOG HEADERS32035LogLog Header ScansC2/26/202011086 13876 Electronic Data Set, Filename: 1R-23APB1 GAMMA RES.las32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 2MD Final.cgm32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 5MD Final.cgm32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 5TVDSS Final.cgm32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 2MD Final.pdf32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 5MD Final.pdf32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 5TVDSS Final.pdf32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 EOW - NAD27.pdf32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 EOW - NAD27.txt32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 EOW - NAD83.pdf32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 EOW - NAD83.txt32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 Final Surveys.csv32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 Final Surveys.xlsx32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 Survey Listing.txt32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 Surveys.txt32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1_25_tapescan_BHI_CTK.txt32061EDDigital DataMonday, April 20, 2020AOGCCPage 3 of 51R-23APB1GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22200-01-00Well Name/No. KUPARUK RIV UNIT 1R-23ACompletion Status1-OILCompletion Date1/20/2020Permit to Drill2191660Operator ConocoPhillips Alaska, Inc.MD14723TVD7017Current Status1WINJ4/20/2020UICYesWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION 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:1/20/2020Release Date:12/4/2019C2/26/2020 Electronic File: 1R-23APB1_5_tapescan_BHI_CTK.txt32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1_output.tap32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 2MD Final.tif32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 5MD Final.tif32061EDDigital DataC2/26/2020 Electronic File: 1R-23APB1 5TVDSS Final.tif32061EDDigital Data0 0 2191660 KUPARUK RIV UNIT 1R-23A PB1 LOG HEADERS32061LogLog Header ScansMonday, April 20, 2020AOGCCPage 4 of 5M. Guhl4/20/2020 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-22200-01-00Well Name/No. KUPARUK RIV UNIT 1R-23ACompletion Status1-OILCompletion Date1/20/2020Permit to Drill2191660Operator ConocoPhillips Alaska, Inc.MD14723TVD7017Current Status1WINJ4/20/2020UICYesMonday, April 20, 2020AOGCCPage 5 of 5 Baker 5�1 PRINT Hughes COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1R-23APB1 FIELD Greater Kuparuk Area COUNTY North Slope Borough BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(a)bakerhughes.com 21 91 6, 6 32 06 1 DISTRIBUTION I,TST Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE January 11, 2020 TODAYS DATE February 24, 2020 Revision Added corrected gamma to .las file on disc. STATUS Rev 1 Replacement CD Details: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 Rev. Requested by: --- FIELD / FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEYLRREPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES OPIES 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 F 700 G Street EB 2 6 2020 (Anchorage, AK 99510 A V G C C 3 ' Exxon Mobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias '3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6' BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 0 2 0 0 i MEMORANDUM TO: Jim Regg �j P.I. Supervisor �� �(�w FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, February 24, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IR -23A KUPARUK RIV UNIT IR -23A Sre: Inspector Reviewed By: P.I. Supry - ,,L Comm Well Name KUPARUK RIV UNIT 1R -23A API Well Number 50-029-22200-01-00 Inspector Name: Brian Bixby Permit Number: 219-166-0 Inspection Date: 2/23/2020 Insp Num: initBDB200223104446 Rel Insp Num: Monday, February 24, 2020 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WCII IR -23A 'Type Inj w - TVD 1 6713 - 'Tubing 2437 2437 2437 2432 PTD 2191660 Type Test SPT Test psi 1678 ' IA 320 1905 - ! 1820 - 1810 BBL Pumped: 2.s BBL Returned: 2.s - OA zoo 200 _ 200 - 200• Interval INITAL P/F P Notes' This is the Initial Testper SUNDRY #320-065 l nn j C(tu&k 4-ri Monday, February 24, 2020 Page I of I VTL 4/17/20 DSR-4/9/2020SFD 4/10/2020 Baker 5�1 PRINT DISTRIBUTION LIST Hughes FINAL COMPANY ConocoPhillips Alaska, Inc. WELL NAME 1R-23APB1 las, dlis, PDF, META, (las, FIELD Greater Kuparuk Area LOGS COUNTY North Slope Borough (Compass) BHI DISTRICT Alaska 9 UF PKIN 16 AUTHORIZED BY Patrick Rider EMAIL Patrick. Rider(d-)bakerhughes.com 2.19166 32035 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE January 11, 2020 TODAYS DATE February 11, 2020 Revision STATUS Final Replacement: No Details: Rev. Requested by: FIELD / FINAL CD/DVD FINAL PRELIM LOGS 1 las, dlis, PDF, META, (las, SURVEY REPORT LOGS ConocoPhillips Alaska Inc. Now V LP: Final Surveys) (Compass) # OF PRINTS 9 UF PKIN 16 1 # OF COPIES # OF COPIES 1# OF COPIES COMPANY BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill ADDRESS (FEDEX WILL NOT DELIVER TO P.O. 80X) 900 E. Benson Blvd. PERSON ATTENTION 2 ConocoPhillips Alaska Inc. Now V LP: lu 4 4 4 4 4 4 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. .Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Now V LP: Attn: Ricky Elgarico FEB 13 2020 ATO 708 700 G Street qO G C C Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC 1 1 Attn: Natural Resources Technician II 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 *** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 TOTALS FOR THIS PAGE: 0 1 2 0 0 Baker 5�1 PRINT DISTRIBUTION LIST Hughes FINAL COMPANY ConocoPhillips Alaska, Inc. V WELL NAME 1R -23A (las, dlis, PDF, META, FIELD Greater Kuparuk Area LOGS COUNTY North Slope Borough (Compass) BHI DISTRICT Alaska It UF FRIN 16 AUTHORIZED BY Patrick Rider EMAIL Patrick. RiderCcDbakerhughes.com STATUS Final Replacement: No 2 19 166 32 034 Please sign and return one copy of this transmittal form to: ConocoPhillips Alaska, Inc. Tom Osterkamp (WNS Petroleum Technician) 700 G Street. Anchorage, Alaska 99510 Ito acknowledge receipt of this data. LOG TYPE GR - RES LOG DATE January 17, 2020 TODAYS DATE February 11, 2020 Revision Details: Rev. Requested by: --- FIELD / FINAL CD/DVD FINAL V PRELIM EOA, PBOC, PRB-20 (Office 109) (las, dlis, PDF, META, SURVEY REPORT LOGS LOGS I CGM, Final Surveys) (Compass) # OF PRINTS It UF FRIN 16 1 # OF COPIES 1# OF COPIES 1# OF COPIES COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 BP North Slope. EOA, PBOC, PRB-20 (Office 109) D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Attn: Ricky Elgarico ATO 708 700 G Street Anchorage, AK 99510 3 ExxonMobil, Alaska Attn: Lynda M. Yaskell and/or Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas *** Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 j*** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 4 4 4 4 FEB 13 2020 AOGCC TOTALS FOR THIS PAGE: 0 1 2 0 0 THE STATE V 0 1 16111 GOVERNOR MIKE DUNLEAVY Jennifer McLeod Petroleum Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, KRU 1R -23A Permit to Drill Number: 219-166 Sundry Number: 320-065 Dear Ms. McLeod: 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 Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, re . rice C it DATED this 1 V day of February, 2020. BDMS FEB 1 12020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED FEB 0 5 2020 D'TS Z-1 6 v / z a AOGCC 1. Type of Request: Abandon LJ Plug Perforations ❑ Fracture Stimulate Li Repair Well Ll Operations shutdown Ll Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ PROD to WINJ Other: El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑• Stratigraphic ❑ Service ❑ 219-166-0 3. Address: 6. API Number: • P. 0. Box 100360, Anchorage, Alaska 99510 50-029-22200-01—&) 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ {� A KRU 1 R -23A 9. Property Designation (Leas Number): 10. Field/Pool(s): V ADL 25635`, ADL 25636, ADL 25627 Kuparuk River Field /Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,723' 7,017' 11,871' 6,805' 2841 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 123' 123' Surface 6,289' 9-5/8" 6,331 4,072' Intermediate Production 12,149' 7" 12,178' 7,003' Slotted Liner 275' 2-3/8" 11,871' 6,805' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3.500" J-55 11,610' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): BAKER HB RETRIEVABLE PACKER / Camco TDRP-1A Safety Valve Packer: MD= 11581 TVD= 6713 / SSSV: MD = 1816 TVD = 1719 12. Attachments: Proposal Summary -/ Wellbore schematic L11 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/4/2020 OIL ❑ WINJ 0 WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jennifer McLeod Contact Name: Jennifer McLeod Authorized Title: Petroleum Engineer Contact Email: jennifer.mcleod@conocophillips.com Contact Phone: 907-265-1050 '(�' Authorized Signature:j ,� �--�--:; i Date: Ly c COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: i Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: /FEB Post Initial Injection MIT Req'd? Yes Y�' No ❑ qSDMS ( 1 12020 Spacing Exception Required? Yes No V Subsequent Form Required: 16-404 ❑ APPROVED BY ^ Q Approved by: a , ' COMMISSIONER THE COMMISSION Date: o)< `/ j , Forr�7-403Revise 4]2DD I r�r��;�� Submit Form and Approved applica n I d 1 �o t s1� he date of approval. Attachments in Duplicate ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 February 4, 2020 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 111-23A from Oil Production to Water Injection service. Enclosed you will find the 10-403 application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 111-23A (PTD# 219-166). If you have any questions regarding this matter, please contact me at 907-265-1050. Sincerely, Jennifer McLeod Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Application Proposal Summary Area Map Well Schematic 1 1 R -23A PROPOSAL SUMMARY :ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit Well 1 R -23A (PTD # 219-166) :from Oil Production service to Water Injection service. Area of Review: Kuparuk River Unit Well 1 R -23A was completed as a CTD lateral well on 1/20/2020. This well will be converted :to provide water injection into the reservoir to increase the ultimate recovery of oil. Well 1 R -23A will provide :support to existing producer 1 R-25. Area map with 1/4 mile radius around target injection zone (see attached): :The map attached shows that there are no wells located within a 1/4 mile radius of the 1 R -23A penetration of :the Kuparuk interval. Mechanical Condition of Well to be Converted: :The mechanical condition of Kuparuk well 1 R -23A is good. The CTD well was completed with 275' of slotted ;liner. The injection tubing/casing annulus is isolated via a Baker HB Retrievable Packer at 11,581' and (6,713' :tvd). The well passed a pre-injection MIT on 1/26/2020. :A state witnessed MIT -IA will be performed once well 1 R -23A is placed on water injection, online and stabilized.: Interpretation of Cement Quality: Parent well cementing details: ;The 16" Conductor was cemented with 331 SX AS I. :The 9-5/8" Surface casing was cemented with 1300 SX PF E, 630 SX CLASS G. :The 7" Production casing was cemented with 380 SX CLASS G. --------------------------------------------------------------------------------------------------------------------------------- A D L025628 1R-16 1R-25 r�� R�9�rR'f 6 ' 1 4 if? -27 1R-01 ConocoPhillips N Alaska 1 R -23A 10-403 Sundry 0 0.2 2/3/2020 Miles AD n. NOTE: There are no active wells within the Open Interval quarter mile buffers. IS 1R -EAST —m Well Path 1R -23A, Open Interval 1R-23AL2, Open Interval 1R-23APB1, Open Interval 1R -23A 01 Quartermile Buffer 1R-23AL2 01 Quartermile Buffer ® 1R-23APB1 01 Quartermile Buffer a, Well Pad Active Well Suspended Well P+A Well CPAI Lease L) �5 0 I c \ |||||| ; \w § § _ - 04 cr co ) § b ;9e \CRcli k\ - -_ ; ! \/ -9 }/ _\ �9 \C, \�\ } /{ \ \ } $e6 w 2 § )\) \/ fR § 7 &23 cm a. ;! =« \ \ - co \ § — g e c m C: E ca -Lo m } \ E Q £ — / f 2 _ w Co - k - Ef { 0 CO \\ \\ j x x 04 Q) \ \ ~Cl) \ ka \ \ 0co 0 I c |||||| ; \w § § _ - cr co ) § b ;9e © k\ - -_ ; ! \/ -9 }/ _\ �9 \C, \�\ } /{ $e6 §e ($ )\) \/ fR § &23 a. ;! Fe3. 0 I c |||||| \§ § _ - cr ) § k\ \ \/ }/ CL } /{ ($ \/ /7 Roby, David S (CED) From: McLeod, Jennifer <Jennifer.McLeod@conocophillips.com> Sent: Wednesday, February 5, 2020 12:48 PM To: Roby, David S (CED" Cc: Loepp, Victoria T (CED); Davies, Stephen F (CED); Boyer, David L (CED); Wallace, Chris D (CED) Subject: RE: [EXTERNAL]RE: Sundry application to convert KEU 1 R -23a (PTD 219-166) from a producer to an injector David, The timing of the decision was based on drilling results. The CTD laterals were intended to test an area at the edge of the field as a pre -produced injector, however the scope of this project changed due to hole instability issues and encountering water saturated rock due to a higher than expected oil -water -contact in the area we were targeting. The well was completed with ^275' of slotted liner to retain communication with the C -sand in the parent fault block and no pre -production period was needed. Hope this helps. Please let me know if you have additional questions. Jennifer McLeod CPF1 Staff Drillsite Petroleum Eneineer 265-1050 From: Roby, David S (CED) <dave.roby@alaska.gov> Sent: Wednesdav, February 5, 2020 12:15 PM To: McLeod. Jennifer <Jennifer.McLeod @conocophillips.com> Cc: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Davies, Stephen F (CED) <steve.davies@alaska.gov>; Boyer, David L (CED) <david.boyer2@alaska.gov>; Wallace, Chris D (CED) <chris.wallace@alaska.gov> Subject: [EXTERNAL]RE: Sundry application to convert KEU 1R -23a (PTD 219-166) from a producer to an injector Jennifer, I was curious why the decision was made to convert the subject well from a producer to an injector. Did plans for the well change based on drilling results, or was it always the intent to have this well as an injector and if so then why was it permitted as a producer in the first place? Thanks, David Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission 907-793-1232 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 Dave Roby at 907- 793-1232 or dave.robv@alaska.gov. R f_ 2 19 166 32028 Letter of Transmittal Baker Hughes � Date: February 7, 2020 Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 rom: Harvey Finch Baker Hughes 795 East 94th Avenue Anchorage, Alaska 99515 ;Please find enclosed the directional survey data for the following well(s): 1R -23A 1R-23APB1 1R -23 -AL2 FEB10 2020 AOGCC 1 (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Harvey Finch Baker Hughes Wellplanner Harvey.Finch@bakerhughes.com O V -n CD cr 91)c N O N O �� ou 77, CD 2 m� `V cn Z m 0 CL W 0 0 00 V r 5 0 _ L m 0 V � CA N N LO N co Ol m fA G G D O 3 c S* * m m 9 T v�* to 'v e No j z CL H. m ° `° v o v �. m m 3 n N OJ , O C T W Cf C f0 3 CD Q O O •p N v N O `G (O O A d O O O N O `G d 7 Z O d .�. ID 3 cn cc y 3 f1 rn F 0 a 3 o S V vCi p m Z D Z C D co C D D w C C y CO N 10 01 O yC of x O O C .77 N .Zl1 N F W Cn V1 00 w O D fn N w d d = W W O O fD z N N (p <. 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N m p L7 G7 G1 L1 L7 L7 G7 L7 L7 O O G) G7 G7 G7 L7 L7 L7 L7 (7 G1 G7 G7 L7 G7 G1 L7 G7 L7 G7 G� O w w w w w w w w w w w w W v V w w w w w w w w w w w w w w w w Z m 3 m w w w w w w w w w U w w w w w c 3 m m J J J J m m m U U A A y Q m 0) U U U A m m m m m 00 t0 m m N W N m m w o) (mil V (Wn m m m m m m m m m m m m m m n 0 0 M V U U U V V m m OAO � tV0 W mm � O (AJC A A v A � J N N N N N V V V m O (WO O N m A U U V U m m m m m m m m m m m m m m c mm m m w U O m N O m m W W O U t0 t0 -i m m m m m m m m m m m m m m c< �I J J 0Vp r V V V V J v v V V y v m W m A t0 m V U O m N O m m W W O U W (0 W m w W 10 U W w N U m W m + V V V V J V V v V V J m m m y Z N V A N m U N O m A OOD 001 W N U U U m U V m O O N A m O N Umi (.J1 m A O A Omo O m m N A N 6Ni + m m m m m m OD m m m m m m m y m A W W W N NO 0 m OJ 001 N A x G N Ut J 0 0 0 m m W J W J N J N A O O U O m U U U U U U U Ot U fn U U U U z co co co io co is i0 m ro co m co O m m m o 0 0 c0 0 m o m m m A m m m m m m m m m m D m m m x .O t0 t0 (0 m m m m V J j 01 m m m M A m U W O V A m U W O m m m m m O N W j j t0 N A [WO m (AD A V N W m U N N W O A A A A A -D. A A A A A A A A N V V V V V V V J J J V V V V x w co ti w m w �i m o o w cn o w o o J U � m cn t0 5o co w o � r O V m O A m m U m N A O U! G V V V J J J J V J V V m m m ,.., ID m N V A m U N O OV A 00D W L' f1 U U (n m U V m O O N.m m O N 3 d m V V O U f0 m O m m m m N U W m A O A m O m J t0 A m m 0 0 0 0 0 0 0 0 0 0 0 0 0 1:� :�> * * :�E g 1 R) m W W m (!i In m V) m m m m 0 O G7 G1 Gln L1 G7 Gl G7 G7 Cil O_ � 3 0 m cn v g g 0 v 0 3 7 O y n O m O O S m O c Zl m m w w y 3 nP (P7 N O (� m m W N c m m z Cl O O O a _ C C3 ZJ .Z] O N N C O v O d Z v fD — 0 v •% 17 X n m 0� fD m 0 7. A 0 O O O D G C ID N Q d C 0 CD N N m � 0 A 70 O -I. m O c Zl m m w w y 3 nP (P7 N O (� m m W N c m m z Cl O O O a _ C C3 ZJ .Z] O N N Baker Hughes C I Date: Abby Bell AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 February 7, 2020 From: 21 91 66 32027 Letter of Transmittal Harvey Finch Baker Hughes 795 East 94th Avenue Anchorage, Alaska 99515 3lease find enclosed the directional survey data for the following well(s): 1R -23A 1R-23APB1 1R -23 -AL2 RECEIVE® FEB 10 2020 AOGCC (3) Total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Harvey Finch Baker Hughes Wellplanner Harvey. Finch@ bakerhughes.com v CD mh C• D Cf) �3 CD l< X CD 00 0 Mi co CD �T y �T J CD U) Z m roI su CL W, 0 X r. 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U Vl Vl U y A A A V J A A A O o cn o co 0 0 0 0 o m � r O m U W J A W A O W m to < m m m m (b V V V V J J J J ,.•„ _ O O O O t0 (D (0 t0 m (b (b m .� O W (0 W W A cp W U CO O N W 7 d A t0 W W m A W W (D c0 N N 3 3 3 3 3 3 cn 0 0 0 0 0 0 0 0 0 0 0 0 z M 0 0 0 0 0 0 0 0 0 0 O O M, W (n W (n W f/1 (n co W CO W cn-01 p L) G) O O O G) L) G) 1) G7 G) 0 G7 O O A A D A A A A A A A A A Z � !v O N Un v g Un v n 2 y m m� o, ID 3 K cc cy 7 O n y (D � v a a y o m CD m h A n N W O m m m m 7 W 3 ID 0 O � a � N Vfi THE STATE 'ALAS GOVERNOR MIKE Dt NLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1R -23A ConocoPhillips Alaska, Inc. Permit to Drill Number: 219-166 Surface Location: 4854' FNL, 144' FWL, SEC. 17, T12N, R10E, UM Bottomhole Location: 870' FNL, 2972' FWL, SEC. 9, T12N, RIOE, UM Dear Mr. Ohlinger: Enclosed is the approved application for the permit to redrill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, VJere2. Price Chair DATED this t day of December, 2019. r ■any■. I V 1.LJ STATE OF ALASKA / NOV 2 1 2019 AL :A OIL AND GAS CONSERVATION COMM'. ,ON PERMIT TO DRILL 20 AAC 25 005 1a. Type of W r CCC��� ed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill 9 Lateral Stratigrephic Test ❑ Development - Oil ❑� ' Service - Winj ❑ Single Zone Q • Coalbed Gas ❑ Gas Hydrates ❑ Redrill - Reentry Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. OperatoLName:(q 1 5. Bond: Blanket Q . Single Well ❑ 11. Well Name and Number: /may 1( ConocoPhillips Alaska, Inc. Bond No. 5952180 KRU 1 R -23A 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 15,846' TVD: 6960' Kuparuk River Field / Kuparuk River Oil Pool - 4a. Location of Well (Governmental Section): 7. Property Designation: qD 1_ ZS�,'7,zj� Surface: ' 4854' FNL, 144' FWL, Sec 17, T12N, R10E, UM M(. 46DL 25627 ALK 2560 Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: 4594' FNL, 1783' FWL, Sec 9, T12N, R10E, UM LOINS 83-134 if -21 /� 12/5/2019 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 870' FNL, 2972' FWL, Sec 9, T12N, R10E, UM 2560 4790' 4b. Location of Well (Slate Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 88' 15. Distance to Nearest Well Open Surface: x- 539830 ' y- 5991630 * Zone- 4 GL / BF Elevation above MSL (ft): 45' to Same Pool: 2935', 113-35 ` 16. Deviated wells: Kickoff depth: 11,650 - feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 101 degrees Downhole: 3515 Surface: 2841 - 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade I Coupling Length MD TVD MD I TVD (including stage data) 3" N/A - - - - - - - - Unlined delineation lateral w/anchored billet at 14,100' MD 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 12180' 7004' N/A 12178' 7003' N/A Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 331 sx AS 1 123' 123' Surface 6289' 9-5/8" 1300 sx PF E, 630 sx Class 'G' 6331' 4072' Production 12149' T' 380 sx Class 'G' 12178' 7003' Perforation Depth MD (ft): Perforation Depth TVD (ft): 11710'-11770' 6774'-6803' Hydraulic Fracture planned? Yes❑ No ❑- 20. Attachments: Property Plat ❑ BOP Sketch Dive t r Sketch B Drilling Program Seabed Report Time v. Depth Plot DrillingFluid Program ❑ 20 AAC ShallowHazard Analysis menisg ❑ 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Name: Ryan McLaughlin Authorized Name: James Ohlinger Contact Email: an.mclau hlin Co .Com Authorized Title: Staff CTD Engineer Contact Phone: 907-265-6218 5 e_r-Wmp AA Authorized Signature�dytsp )aqe.r Date: ommission Use Only Permit to Drill Number: API Number: zZG--�-�`-�-G�"{LJ Permit Approval See cover letter for other 50- `%Zg� Date: requirements. Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed meth ne, as hydrates, or gas contained in shales: Eir fb .350075/ Samplesles req'd: Yes ❑ o Mud log req'd: Yes❑No � Other: Qf)O Q�No Directional svy reqd: Yes L,/No❑ np n vC/ ariPre- 500pAImeasures: Yes❑ .6Dacind ej(ception req'd: Yes❑ NoFv,/ Inclination -only svy req'd: Yes[] No[;�/ _ - Post initial injection MIT req'd: Yes ❑ No[1' APPROVED BY 1a,1f Approved by: COMMISSIONER THE COMMISSION DateN 1 1 Form 701kN4 . d5/2 Y / L T/h`pTms veli approval per 20 AAC 25.005(8) Attachments Duplicate Suhmit Form and ConocoPs philli Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 20, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill four laterals out of the KRU 1 R-23 (PTD# 191-101) using the coiled tubing drilling rig, Nabors CDR3-AC. CDR3-AC previouy§ attempted to drill the 1 R -23L1 (219-128) lateral in October 2019, but after drilling 3 plugbacks due to hole cleaning and hole stability issues, the decision was made to RDMO. The well is currently being set-up „for a cement pilot hole exit by cement squeezing the original C -sand perforations up to the tubing tail. CDR3-AC plans to return to the well and CTD operations are scheduled to begin on December 5th, 2019. The objective will be to drill three laterals — 1 R -23A and 1 R-23AL1 will be unlined delineation laterals to the north and east, crosscutting through the A3 and C1 sands. 1 R-23AL2 will be drilled to the north targeting the C1 sands and lined with 2-3/8" solid and slotted liner from TD up into the tubing tail. The fourth lateral, 1 R- 23AL3, will be a contingency lateral that will target the C1 sands in an upthrown fault block. This lateral will be drilled only if the oil -water -contact comes in higher than anticipated and the project does not get completed to scope. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to this application are the following documents: - Permit to Drill Application Forms (10-401) for 1 R -23A, 1 R-23AL1, & 1 R-23AL2, & 1 R-23AL3 - Detailed Summary of Operations - Directional Plans for 1 R -23A, 1 R-23AL1, & 1 R-23AL2, & 1 R-23AL3 - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-265-6218. Sincerely, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Kuparuk CTD Lateral 1 R -23A, 1 R-23AL15 & 1 R-23AL2 & 1 R-23AL3 Application for Permit to Drill Document 1. Well Name and Classification........................................................................................................ 2 (Requirements of 20 AAC 25.005(0 and 20 AAC 25.005(b))................................................................................................................... 2 2. Location Summary.......................................................................................................................... 2 (Requirements of 20 AAC 25.005(c)(2)).................................................................................................................................................. 2 3. Blowout Prevention Equipment Information................................................................................. 2 (Requirements of 20 AAC 25.005(c)(3))................................................................................................................................................. 2 4. Drilling Hazards Information and Reservoir Pressure.................................................................. 2 (Requirements of 20 AAC 25.005(c)(4))................................................................................................................................................. 2 5. Procedure for Conducting Formation Integrity tests................................................................... 2 (Requirements of 20 AAC 25.005(c)(5)).................................................................................................................................................. 2 6. Casing and Cementing Program.................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(6)).................................................................................................................................................. 3 7. Diverter System Information.......................................................................................................... 3 (Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3 8. Drilling Fluids Program.................................................................................................................. 3 (Requirements of 20 AAC 25.005(c)(8)).................................................................................................................................................. 3 9. Abnormally Pressured Formation Information............................................................................. 4 (Requirements of 20 AAC 25.005(c)(9)).................................................................................................................................................. 4 10. Seismic Analysis............................................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................ 4 11. Seabed Condition Analysis............................................................................................................ 4 (Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................4 12. Evidence of Bonding...................................................................................................................... 4 (Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4 13. Proposed Drilling Program............................................................................................................. 4 (Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................ 4 Summaryof Operations...................................................................................................................................................4 LinerRunning...................................................................................................................................................................6 14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6 (Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6 15. Directional Plans for Intentionally Deviated Wells....................................................................... 6 (Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 6 16. Attachments.................................................................................................................................... 7 Attachment 1: Directional Plans for 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3........................................................7 Attachment 2: Current Well Schematic for 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3.............................................7 Attachment 3: Proposed Well Schematic for 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3..........................................7 Page 1 of 7 November 11, 2019 PTD Application: 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3 1. Well Name and Classification (Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3. The laterals will be classified as "Development - Oil" wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target the C1 and A3 sand packages in the Kuparuk reservoir. See attached 10-401 form for surface and subsurface coordinates of 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC. BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations. V---- - /— Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. Using the maximum formation pressure in the area of 3517 psi in 1 R-23 (i.e. 0.0 ppg EMW), the maximum potential surface pressure in 1 R-23, assuming a gas gradient of 0.1 psi/ft, would be 2841 psi See the "Drilling Hazards Information and Reservoir Pressure" section for more details. — The annular preventer will be tested to 250 psi and 2,500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The formation pressure in KRU 1 R-23 was measured to be 3517 psi (10.0 ppg EMW) on 12/20/2010. The maximum downhole pressure in the 1 R-23 vicinity is the 1 R-23 at 3517 psi or 10.0 ppg EMW on 12/20/2010. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; gas injection has been performed in this area, so there is a chance of encountering gas while drilling the 1 R -23A laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away from the rig. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c)) , The major expected risk of hole problems in the 1 R -23A laterals will be shale instability across faults. Managed pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity test is not required. Page 2 of 7 September 16, 2019 PTD Application: 1 R -23A, 1 R-24AL1, & 1 R-23AL2 & 1 R-23AL3 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Lateral Name Liner Top Liner Btm Liner Top Liner Btm Liner Details Btm MD MD MD TVDSS TVDSS Conductor 16" 62.5 H-40 Welded Surface Delineation lateral —will be unlined 1 R -23A N/A N/A N/A N/A with an anchored billet set at 14,100' 36.0 J-55 BTC Surface 6331 MD 4072' 3520 2020 Production 7" Delineation lateral —will be unlined 1R-23ALl N/A N/A N/A N/A with an anchored billet set at 12,500' 4980 4320 Tubing 3-1/2" 9.3 MD EUEABMOD I Surface 1 11,610 Surface 6727' 2-3/8", 4.7#, L-80, ST -L slotted/solid 1R-23AL2 11,605' 17,700' 6636' 6615' liner, with oil and water tracer pups, and sealbore deployment sleeve 1R-23AL3 11,605' 14,000' 6636' 6500' 2-3/8", 4.7#, L-80, ST -L slotted liner Existing Casing/Liner Information Category OD Weight (ppf)TVD Grade Connection Top MD Btm MD Top Btm TVD Burs t psi Collapse psi Conductor 16" 62.5 H-40 Welded Surface 123' Surface 123' 1640 670 Surface 9-5/8" 36.0 J-55 BTC Surface 6331 Surface 4072' 3520 2020 Production 7" 26.0 L-80 NSCC Surface 12,178' Surface 7003' 4980 4320 Tubing 3-1/2" 9.3 J-55 EUEABMOD I Surface 1 11,610 Surface 6727' 1 8430 17500 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System A diagram of the Nabors CDR3-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Water based Power -Vis milling fluid (8.6 ppg) — Drilling operations: Water based PowerVis mud (8.6 ppg). This mud weight may not hydrostatically overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices described below. - - — Completion operations: BHA's will be deployed using standard pressure deployments and the well will be loaded with a weighted completion fluid in order to provide formation over -balance and maintain wellbore stability while running completions. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 -psi rated coiled tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3 "Blowout Prevention Equipment Information". Page 3 of 7 September 16, 2019 PTD Application: 1 R -23A, 1 R-2jAL1, & 1 R-23AL2 & 1 R-23AL3 In the 1 R -23A laterals we will target a constant BHP of 11.8 EMW at the window. The constant BHP target will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. Pressure at the 1R -23A Window (11,650' MD, 6745' ND) Using MPD 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background In October 2019, CDR3-AC rigged up and attempted to drill 3 laterals out of KRU 1 R-23. After 3 plugbacks while drilling the 1 R-231_1 lateral due to poor hole conditions and hole cleaning issues, the decision was made to _ RDMO and reattempt at a later date via cement pilot hole exit. This will require E -line to perforate the tubing tail, and service coil to ;cement squeeze the C -sand perforations up to the tubing tail. This wellwork is ongoing. CDR3-AC will return to 1 R-23 in mid-December, mill a pilot hole down to 11,680' MD, set a whipstock and mill a 2.80" window in the production casing at a depth of 11,650' MD. After that, the 1 R -23A delineation lateral will be drilled to the north and crosscut through the C1 and A3 sands to determine rock quality and oil -water contact in both sand packages. An anchored billet will be set and the 1 R-23AL1 lateral will be drilled to the east, crosscutting through the C1 and A3 sands to determine rock quality and OWC in the eastern fault block. Finally, an anchored billet will be set and the 1 R-23AL2 lateral will be drilled to the north, targeting the C1 sands, and lined with 2-3/8" slotted liner to the tubing tail. If the C1 sands are found to be wet due to a higher than anticipated oil -water -contact, the 1 R-23AL2 lateral will not be drilled and instead a contingency lateral, 1 R-23AL3, will be Page 4 of 7 September 16, 2019 Pumps On 1.8 bpm) Pumps Off Formation Pressure 10.0 3507 psi 3507 psi Mud Hydrostatic 8.6 3016 psi 3016 psi Annular friction (i.e. ECD, 0.080psi/ft) 932 psi 0 psi Mud + ECD Combined no chokepressure) 3948 psi Overbalanced —441psi) 3016 psi (Underbalanced —491 psi) Target BHP at Window 11.8 4139 psi 4139 psi Choke Pressure Required to Maintain Target BHP 191 psi 1123 psi 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A - Application is for a land based well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background In October 2019, CDR3-AC rigged up and attempted to drill 3 laterals out of KRU 1 R-23. After 3 plugbacks while drilling the 1 R-231_1 lateral due to poor hole conditions and hole cleaning issues, the decision was made to _ RDMO and reattempt at a later date via cement pilot hole exit. This will require E -line to perforate the tubing tail, and service coil to ;cement squeeze the C -sand perforations up to the tubing tail. This wellwork is ongoing. CDR3-AC will return to 1 R-23 in mid-December, mill a pilot hole down to 11,680' MD, set a whipstock and mill a 2.80" window in the production casing at a depth of 11,650' MD. After that, the 1 R -23A delineation lateral will be drilled to the north and crosscut through the C1 and A3 sands to determine rock quality and oil -water contact in both sand packages. An anchored billet will be set and the 1 R-23AL1 lateral will be drilled to the east, crosscutting through the C1 and A3 sands to determine rock quality and OWC in the eastern fault block. Finally, an anchored billet will be set and the 1 R-23AL2 lateral will be drilled to the north, targeting the C1 sands, and lined with 2-3/8" slotted liner to the tubing tail. If the C1 sands are found to be wet due to a higher than anticipated oil -water -contact, the 1 R-23AL2 lateral will not be drilled and instead a contingency lateral, 1 R-23AL3, will be Page 4 of 7 September 16, 2019 PTD Application: 1 R -23A, 1 R-2sAL1, & 1 R-23AL2 & 1 R-23AL3 drilled targeting the C1 sands in an upthrown block This lateral will be lined with 2-3/8" slotted liner from TD to the tubing tail. Pre -CTD Work 1. RU E -line: Perforate Tubing Tail 2. RU CTU: Injectivity test, cement 1 R-23 up to the tubing tail, mill XN nipple to 2.80", mill cement to 11,609' MD Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. j 2. 1 R -23A Lateral (Delineation Lateral A/C Sands - North) a. Mill cement from tubing tail (11,609' MD) to 11,680' MD - b. Set whipstock at 11,650' MD - c. Mill 2.80" window at 11,650' MD d. Drill 3" bi-center lateral to TD of 15,846' MD e. Set anchored aluminum billet at 14,100' MD 3. 1 R-23AL1 Lateral (Delineation Lateral A/C Sands - East) a. Kickoff of the aluminum billet at 14,100' MD b. Drill 3" bi-center lateral to TD of 16,665' MD c. Set anchored aluminum billet at 12,500' MD 4. 1R-23AL2 Lateral (C1 Sand — North) a. Kick off of the aluminum billet at 12,500' MD b. Drill 3" bi-center lateral to a TD of 17,700' MD c. Run 2-3/8" slotted/blank liner with oil/water tracer pups and sealbore deployment sleeve from TD up to 11,605' MD 5. 1R-23AL3 Lateral (C1 Sand — North) a. Kick off of the aluminum billet at 12,400' MD b. Drill 3" bi-center lateral to a TD of 14,000' MD c. Run 2-3/8" slotted liner and sealbore deployment sleeve from TD up to 11,605' MD 6. Freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. RU E -Line: Set LTP 2. Return well to production. Pressure Deployment of BHA The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the swab valve on the Christmas tree. MPD operations require the BHA to be lubricated under pressure using the swab valve on the Christmas tree, deployment ram on the BOP, check valve and ball valve in the BHA, and a slick -line lubricator. This pressure control equipment listed ensures reservoir pressure is contained during the deployment process. During BHA deployment, the following steps are observed. — Initially the swab valve on the tree is closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valve. The swab valve is opened and the BHA is lowered in place via slick -line. — When the BHA is spaced out properly, the deployment ram is closed on the BHA to isolate reservoir pressure via the annulus. A closed ball valve and check valve isolate reservoir pressure internal to the Page 5 of 7 September 16, 2019 PTD Application: 1 R -23A, 1 R-2jAL1, & 1 R-23AL2 & 1 R-23AL3 BHA. Slips on the deployment ram prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment ram. — The coiled tubing is made up to the BHA with the ball valve in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the ball valve is opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment ram is opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment, the steps listed above are observed, only in reverse. Liner Running . — The 1 R -23A, 1 R-23AL1, & 1 R-23AL2 & 1 R-23AL3 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids" section for more details. — While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide secondary well control while running 2-3/8" liner 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) • No annular injection on this well. - • All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18 or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. • Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200). 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plans f` — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional and gamma ray will be run over the entire open hole section. — Distance to Nearest Property Line (measured to KPA boundary at closest point) Lateral Name Distance 1 R -23A 4790' 1 R-23AL1 3041' 1R-23AL2 2541' 1 R-23AL3 5105' — Distance to Nearest Well within Pool Lateral Name Distance Well 1 R -23A 2935' • 1 R-35 1 R-23AL1 3002' 1 R-35 1 R-23AL2 2872' 1 R-35 1 R-23AL3 2972' 1 R-35 Page 6 of 7 September 16, 2019 PTD Application: 1 R -23A, 1 R-24AL1, & 1 R-23AL2 & 1 R-23AL3 16. Attachments Attachment 1: Directional Plans for the IR -23A, 1 R-23AL 1, & 1 R-23AL2 & 1R-23AL3 laterals Attachment 2: Current Well Schematic for 1R-23 Attachment 3: Proposed CTD Well Schematic for the 1R -23A, 1 R-23AL 1, & 1 R-23AL2 & 1 R-23AL3 laterals Page 7 of 7 September 16, 2019 � S 0 c 0 ConocoPs philli ConocoPhillips Alaska Inc—Kuparuk Kuparuk River Unit Kuparuk 1 R Pad 1 R-23 1 R -23A Plan: 1 R-23A_wp06 (Draft A) Standard Planning Report 18 November, 2019 Baker Hughes 8 ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc—Kuparuk Project: Kuparuk River Unit Site: Kuparuk I Pad Well: 1 R-23 Wellbore: 1 R -23A Design: 1 R-23A_wp06 (Draft A) ConocoPhillips Planning Report Baker Hughes Local Co-ordinate Reference: Well 1 R-23 TVD Reference: Mean Sea Level MD Reference: 1 R-23 @ 88.00usft (1 R-23) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1R Pad Site Position: Northing: 5,991,050.01 usft Latitude: 70° 23' 11.370 N From: Map Easting: 539,829.93 usft Longitude: 149° 40'33.803 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 0.31 ° Well 1 R-23 Well Position +N/ -S 0.00 usft Northing: 5,991,630.19 usft Latitude: 70° 23' 17.076 N +E/ -W 0.00 usft Easting: 539,829.67 usft Longitude: 149° 40'33.721 W - Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 0.00 usft Wellbore 1 R -23A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (I (I (nT) BGG M 2018 12/1/2019 16.33 80.88 57,400 11/18/2019 9.14:52AM Page 2 COMPASS 5000.14 Build 85H Design 1R-23A_wp06(Draft A) Audit Notes: Version: Phase: PLAN Tie On Depth: 11,600.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction (usft) (usft) (usft) (1) 0.00 0.00 0.00 0.00 11/18/2019 9.14:52AM Page 2 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes > Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1R-23 Company: ConocoPhillips Alaska Inc Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1R-23 @ 88.00usft (1R-23) Site: Kuparuk 1R Pad North Reference: True Well: 1 R-23 Survey Calculation Method: Minimum Curvature Wellbore: 1 R -23A Azimuth System Design: 1R-23A_wp06 (Draft A) Rate Rate Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/ -S +E/ -W Rate Rate Rate TFO (usft) (°) (°) (usft) (usft) (usft) (°/100usft) (°/100usft) (°1100usft) (°) Target 11,600.00 61.91 45.26 6,633.88 5,511.92 6,868.29 0.00 0.00 0.00 0.00 11,650.00 61.76 45.08 6,657.48 5,542.99 6,899.55 0.44 -0.30 -0.36 -133.43 11,671.00 65.96 45.08 6,666.73 5,556.30 6,912.89 20.00 20.00 0.00 0.00 11,734.26 90.00 45.08 6,679.81 5,599.67 6,956.39 38.00 38.00 0.00 0.00 11,804.26 91.72 45.38 6,678.75 5,648.96 7,006.08 2.50 2.46 0.43 10.00 11,904.26 91.94 42.89 6,675.56 5,720.69 7,075.67 2.50 0.22 -2.49 275.00 12,204.26 91.94 42.89 6,665.40 5,940.35 7,279.74 0.00 0.00 0.00 0.00 12,454.26 86.07 40.75 6,669.75 6,126.53 7,446.34 2.50 -2.35 -0.86 200.00 12,554.26 87.32 38.59 6,675.52 6,203.37 7,510.07 2.50 1.25 -2.17 300.00 12,704.26 89.20 35.34 6,680.08 6,323.15 7,600.20 2.50 1.25 -2.16 300.00 12,904.26 89.20 30.34 6,682.88 6,491.12 7,708.61 2.50 0.00 -2.50 270.00 13,154.26 87.07 24.46 6,691.02 6,712.85 7,823.54 2.50 -0.85 -2.35 250.00 13,414.26 89.93 18.62 6,697.83 6,954.48 7,918.91 2.50 1.10 -2.25 296.00 13,914.26 89.93 18.62 6,698.44 7,428.32 8,078.54 0.00 0.00 0.00 0.00 14,209.26 101.73 18.62 6,668.52 7,705.94 8,172.07 4.00 4.00 0.00 0.00 14,409.26 96.32 12.65 6,637.13 7,896.02 8,225.18 4.00 -2.70 -2.99 228.00 14,499.26 93.60 10.28 6,629.34 7,983.88 8,242.99 4.00 -3.02 -2.63 221.00 14,629.26 90.99 5.78 6,624.12 8,112.45 8,261.12 4.00 -2.01 -3.46 240.00 14,744.26 86.39 5.78 6,626.74 8,226.81 8,272.70 4.00 -4.00 0.00 180.00 15,427.26 73.03 341.52 6,750.24 8,888.25 8,202.13 4.00 -1.96 -3.55 -121.04 15,846.00 73.03 341.52 6,872.46 9,268.10 8,075.18 0.00 0.00 0.00 0.00 11/18/2019 9:14.52AM Page 3 COMPASS 5000 14 Build 85H ConocoPhillips Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc-Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1 R Pad Well: 1 R-23 Wellbore: 1 R -23A Design: 1 R-23A_wp06 (Draft A) ConocoPhillips Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Baker Hughes Well 1 R-23 Mean Sea Level 1 R-23 @ 88.00usft (1 R-23) True Minimum Curvature Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/ -S +E/ -W Section Rate Azimuth Northing Easting (usft) r) V) (usft) (usft) (usft) (usft) (°1100usft) V) (usft) (usft) 11,600.00 61.91 45.26 6,633.88 5,511.92 6,868.29 5,511.92 0.00 0.00 5,997,178.07 546,667.83 TIP 11,650.00 - 61.76 45.08 6,657.48 5,542.99 6,899.55 5,542.99 0.44 -133.43 5,997,209.31 546,698.92 KOP 11,671.00 65.96 45.08 6,666.73 5,556.30 6,912.89 5,556.30 20.00 0.00 5,997,222.69 546,712.19 Start Build 38.0000 11,700.00 76.98 45.08 6,675.93 5,575.69 6,932.33 5,575.69 38.00 0.00 5,997,242.17 546,731.53 11,734.26 90.00 45.08 6,679.81 5,599.67 6,956.39 5,599.67 38.00 0.00 5,997,266.28 546,755.45 Start DLS 2.5000 TFO 10.0000 11,800.00 91.62 45.37 6,678.88 5,645.97 7,003.04 5,645.97 2.50 10.00 5,997,312.82 546,801.86 11,804.26 91.72 45.38 6,678.75 5,648.96 7,006.08 5,648.96 2.50 10.00 5,997,315.83 546,804.87 Start DLS 2.5000 TFO 275.0000 11,900.00 91.93 43.00 6,675.70 5,717.57 7,072.77 5,717.57 2.50 -85.00 5,997,384.79 546,871.20 11,904.26 91.94 42.89 6,675.56 5,720.69 7,075.67 5,720.69 2.50 -85.08 5,997,387.92 546,874.081 Start 300.0000 hold at 11904.2632 MD 12,000.00 91.94 42.89 6,672.32 5,790.79 7,140.80 5,790.79 0.00 0.00 5,997,458.36 546,938.821 12,100.00 91.94 42.89 6,668.93 5,864.01 7,208.82 5,864.01 0.00 0.00 5,997,531.93 547,006.45 12,200.00 91.94 42.89 6,665.55 5,937.23 7,276.84 5,937.23 0.00 0.00 5,997,605.51 547,074.07 12,204.26 91.94 42.89 6,665.40 5,940.35 7,279.74 5,940.35 0.00 0.00 5,997,608.65 547,076.96 Start DLS 2.5000 TFO 200.0000 12,300.00 89.69 42.07 6,664.04 6,010.95 7,344.39 6,010.95 2.50 -160.00 5,997,679.57 547,141.22 12,400.00 87.34 41.22 6,666.63 6,085.64 7,410.81 6,085.64 2.50 -160.01 5,997,754.62 547,207.24 12,454.26 86.07 40.75 6,669.75 6,126.53 7,446.34 6,126.53 2.50 -159.99 5,997,795.69 547,242.55 Start DLS 2.5000 TFO 300.0000 12,500.00 86.64 39.76 6,672.66 6,161.37 7,475.84 6,161.37 2.50 -60.00 5,997,830.68 547,271.86 12,554.26 87.32 38.59 6,675.52 6,203.37 7,510.07 6,203.37 2.50 -59.94 5,997,872.86 547,305.86 Start DLS 2.5000 TFO 300.0000 12,600.00 87.89 37.59 6,677.43 6,239.34 7,538.26 6,239.34 2.50 -60.00 5,997,908.97 547,333.85 12,700.00 89.14 35.43 6,680.02 6,319.68 7,597.73 6,319.68 2.50 -59.96 5,997,989.62 547,392.89 12,704.26 89.20 35.34 6,680.08 6,323.15 7,600.20 6,323.15 2.50 -59.90 5,997,993.11 547,395.34 Start DLS 2.5000 TFO 270.0000 12,800.00 89.20 32.94 6,681.42 6,402.38 7,653.92 6,402.38 2.50 -90.00 5,998,072.61 547,448.64 12,900.00 89.20 30.44 6,682.82 6,487.45 7,706.45 6,487.45 2.50 -89.97 5,998,157.95 547,500.71 12,904.26 89.20 30.34 6,682.88 6,491.12 7,708.61 6,491.12 2.50 -89.93 5,998,161.64 547,502.84 Start DLS 2.5000 TFO 250.0000 13,000.00 88.38 28.09 6,684.90 6,574.66 7,755.32 6,574.66 2.50 -110.00 5,998,245.41 547,549.11 13,100.00 87.53 25.74 6,688.47 6,663.77 7,800.55 6,663.77 2.50 -109.95 5,998,334.75 547,593.86 13,154.26 87.07 24.46 6,691.02 6,712.85 7,823.54 6,712.85 2.50 -109.87 5,998,383.95 547,616.581 Start DLS 2.5000 TFO 296.0000 13,200.00 87.57 23.43 6,693.16 6,754.60 7,842.08 6,754.60 2.50 -64.00 5,998,425.80 547,634.90 13,300.00 88.67 21.18 6,696.44 6,847.06 7,880.02 6,847.06 2.50 -63.95 5,998,518.45 547,672.34 13,400.00 89.77 18.94 6,697.79 6,940.98 7,914.31 6,940.98 2.50 -63.88 5,998,612.54 547,706.13 13,414.26 89.93 18.62 6,697.83 6,954.48 7,918.91 6,954.48 2.50 -63.85 5,998,626.07 547,710.65 Start 500.0000 hold at 13414.2632 MD 13,500.00 89.93 18.62 6,697.93 7,035.73 7,946.28 7,035.73 0.00 0.00 5,998,707.45 547,737.58 13,600.00 89.93 18.62 6,698.06 7,130.50 7,978.21 7,130.50 0.00 0.00 5,998,802.38 547,769.00 13,700.00 89.93 18.62 6,698.18 7,225.27 8,010.13 7,225.27 0.00 0.00 5,998,897.31 547,800.42 13,800.00 89.93 18.62 6,698.30 7,320.03 8,042.06 7,320.03 0.00 0.00 5,998,992.23 547,831.84 13,900.00 89.93 18.62 6,698.42 7,414.80 8,073.99 7,414.80 0.00 0.00 5,999,087.16 547,863.26 13,914.26 89.93 18.62 6,698.44 7,428.32 8,078.54 7,428.32 0.00 0.00 5,999,100.70 547,867.74 Start Build 4.0000 14,000.00 93.36 18.62 6,695.98 7,509.52 8,105.90 7,509.52 4.00 0.00 5,999,182.04 547,894.66 11/18/2019 9:14:52AM Page 4 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Planning Report Baker Hughes Database: EDT 14 Alaska Production Company: ConocoPhillips Alaska Inc-Kuparuk Toolface Project: Kuparuk River Unit +NIS Site: Kuparuk 1R Pad Rate Well: 1 R-23 Easting Wellbore: 1 R -23A (usft) Design: 1 R-23A_wp06 (Draft A) (usft) Planned Survey 7,603.85 8,137.68 Measured 4.00 TVD Below Depth Inclination Azimuth System (usft) (1 (°) (usft) 14,100.00 97.36 18.62 6,686.64 14,200.00 101.36 18.62 6,670.38 14,209.26 101.73 18.62 6,668.52 Start DLS 4.0000 TFO 228.0000 8,198.52 14,300.00 99.29 15.89 6,651.97 14,400.00 96.58 12.92 6,638.17 14,409.26 96.32 12.65 6,637.13 Start DLS 4.0000 TFO 221.0000 548,009.88 14,499.26 93.60 10.28 6,629.34 Start DLS 4.0000 TFO 240.0000 5,999,569.12 14,500.00 93.59 10.25 6,629.29 14,600.00 91.58 6.79 6,624.78 14,629.26 90.99 5.78 6,624.12 Start DLS 4.0000 TFO 180.0000 0.00 14,700.00 88.16 5.78 6,624.64 14,744.26 86.39 5.78 6,626.74 Start DLS 3.9967 TFO -121.0369 6,000,898.61 14,800.00 85.25 3.86 6,630.81 14,900.00 83.21 0.41 6,640.87 15,000.00 81.19 356.93 6,654.45 15,100.00 79.20 353.41 6,671.49 15,200.00 77.26 349.84 6,691.89 15,300.00 75.36 346.22 6,715.57 15,400.00 73.52 342.54 6,742.40 15,427.26 73.03 341.52 6,750.24 Start 418.7400 hold at 15427.2632 MD 15,500.00 73.03 341.52 6,771.47 15,600.00 73.03 341.52 6,800.66 15,700.00 73.03 341.52 6,829.85 15,800.00 73.03 341.52 6,859.03 15,846.00 73.03 341.52 6,872.46 Planned TD at 15846.0032 Casing Points Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well 1 R-23 Mean Sea Level 1 R-23 @ 88.00usft (1 R-23) True Minimum Curvature 7,983.88 8,242.99 7,983.88 4.00 -139.00 5,999,657.07 548,029.22 7,984.60 8,243.12 Vertical Dogleg Toolface Map Map +NIS +E/ -W Section Rate Azimuth Northing Easting (usft) (usft) (usft) (°/100usft) (°) (usft) (usft) 7,603.85 8,137.68 7,603.85 4.00 0.00 5,999,276.53 547,925.94 7,697.34 8,169.18 7,697.34 4.00 0.00 5,999,370.17 547,956.93 7,705.94 8,172.07 7,705.94 4.00 0.00 5,999,378.79 547,959.78 7,791.13 8,198.52 7,791.13 4.00 -132.00 5,999,464.11 547,985.78 7,887.04 8,223.14 7,887.04 4.00 -132.50 5,999,560.14 548,009.88 7,896.02 8,225.18 7,896.02 4.00 -132.91 5,999,569.12 548,011.87 7,983.88 8,242.99 7,983.88 4.00 -139.00 5,999,657.07 548,029.22 7,984.60 8,243.12 7,984.60 4.00 -120.00 5,999,657.79 548,029.34 8,083.37 8,257.92 8,083.37 4.00 -120.00 5,999,756.64 548,043.61 8,112.45 8,261.12 8,112.45 4.00 -120.16 5,999,785.73 548,046.66 8,182.82 8,268.24 8,182.82 4.00 -180.00 5,999,856.13 548,053.41 8,226.81 8,272.70 8,226.81 4.00 -180.00 5,999,900.13 548,057.62 8,282.20 8,277.37 8,282.20 4.00 -121.04 5,999,955.54 548,062.001 8,381.60 8,281.08 8,381.60 4.00 -120.90 6,000,054.95 548,065.181 8,480.63 8,278.79 8,480.63 4.00 -120.55 6,000;153.96 548,062.361 8,578.80 8,270.49 8,578.80 4.00 -120.08 6,000,252.07 548,053.55 8,675.63 8,256.25 8,675.63 4.00 -119.48 6,000,348.81 548,038.78 8,770.65 8,236.11 8,770.65 4.00 -118.75 6,000,443.72 548,018.151 8,863.41 8,210.19 8,863.41 4.00 -117.89 6,000,536.33 547,991.73 8,888.25 8,202.13 8,888.25 4.00 -116.90 6,000,561.12 547,983.55 8,954.23 8,180.08 8,954.23 0.00 0.00 6,000,626.98 547,961.14 9,044.94 8,149.77 9,044.94 0.00 0.00 6,000,717.52 547,930.35 9,135.66 8,119.45 9,135.66 0.00 0.00 6,000,808.06 547,899.55 9,226.37 8,089.13 9,226.37 0.00 0.00 6,000,898.61 547,868.75 9,268.10 - 8,075.18 9,268.10 0.00 0.00 6,000,940.26 547,854.59 Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 15,846.00 6,872.46 2-3/8' 2.375 3.000 11/18/2019 9.14:52AM Page 5 COMPASS 5000.14 Build 85H Plan Annotations ConocoPhillips ConocoPhillips Planning Report Baker Hughes Database: EDT 14 Alaska Production Local Co-ordinate Reference: Well 1 R-23 Company: ConocoPhillips Alaska Inc_Kuparuk TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1R-23 @ 88.00usft (1R-23) Site: Kuparuk 1R Pad North Reference: True Well: 1R-23 Survey Calculation Method: Minimum Curvature Wellbore: 1 R -23A 6,868.29 TIP Design: 1 R-23A_wp06 (Draft A) 6,657.48 5,542.99 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/ -S +E/ -W (usft) (usft) (usft) (usft) Comment 11,600.00 6,633.88 5,511.92 6,868.29 TIP 11,650.00 6,657.48 5,542.99 6,899.55 KOP 11,671.00 6,666.73 5,556.30 6,912.89 Start Build 38.0000 11,734.26 6,679.81 5,599.67 6,956.39 Start DLS 2.5000 TFC, 10.0000 11,804.26 6,678.75 5,648.96 7,006.08 Start DLS 2.5000 TFO 275.0000 11,904.26 6,675.56 5,720.69 7,075.67 Start 300.0000 hold at 11904.2632 MD 12,204.26 6,665.40 5,940.35 7,279.74 Start DLS 2.5000 TFO 200.0000 12,454.26 6,669.75 6,126.53 7,446.34 Start DLS 2.5000 TFO 300.0000 12,554.26 6,675.52 6,203.37 7,510.07 Start DLS 2.5000 TFO 300.0000 12,704.26 6,680.08 6,323.15 7,600.20 Start DLS 2.5000 TFO 270.0000 12,904.26 6,682.88 6,491.12 7,708.61 Start DLS 2.5000 TFO 250.0000 13,154.26 6,691.02 6,712.85 7,823.54 Start DLS 2.5000 TFO 296.0000 13,414.26 6,697.83 6,954.48 7,918.91 Start 500.0000 hold at 13414.2632 MD 13,914.26 6,698.44 7,428.32 8,078.54 Start Build 4.0000 14,209.26 6,668.52 7,705.94 8,172.07 Start DLS 4.0000 TFO 228.0000 14,409.26 6,637.13 7,896.02 8,225.18 Start DLS 4.0000 TFO 221.0000 14,499.26 6,629.34 7,983.88 8,242.99 Start DLS 4.0000 TFO 240.0000 14,629.26 6,624.12 8,112.45 8,261.12 Start DLS 4.0000 TFO 180.0000 14,744.26 6,626.74 8,226.81 8,272.70 Start DLS 3.9967 TFO -121.0359 15,427.26 6,750.24 8,888.25 8,202.13 Start 418.7400 hold at 15427.2632 MD 15,846.00 6,872.46 9,268.10 8,075.18 Planned TD at 15846.0032 11/18/2019 9:14:52AM Page 6 COMPASS 5000.14 Build 85H ConocoPhillips ConocoPhillips Anticollision Report Baker Hughes Company: ConocoPhillips Alaska Inc_Kuparuk Project: Kuparuk River Unit -2 Reference Site: Kuparuk 1 R Pad Site Error. 0.00 usft Reference Well: 1 R-23 Well Error: 0.00 usft Reference Wellbore 1 R -23A Reference Design: 1 R-23A_wp06 (Draft A) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 1R-23 1 R-23 @ 88.00usft (1 R-23) 1 R-23 @ 88.00usft (1 R-23) True Minimum Curvature 2,00 sigma EDT 14 Alaska Production Offset Datum Reference 1 R-23A_wp06 (Draft A) 1 R-23 - 1 R-23 - 1 R-23 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 11.600.00 to 15,846.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum ellipse separation of 3,000.00 usft Error Surface: Combined Pedal Curve Warning Levels Evaluated at: 2.79 Sigma Casing Method: Added to Error Values Survey Tool Program Date 11115/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description i 100.00 11,600.00 1 R-23 (1 R-23) GCT -MS Schlumberger GCT multishot 11,600.00 15,845.26 1R-23A_wp06(Draft A)(1R-23A) MWD OWSG OWSGMWD- Standard Summary Kuparuk 1 R Pad - 1 R-23 - 1 R-23 - 1 R-23 Between Minimum Survey Program: 100 -GCT -MS Reference Offset Distance Factor (usft) (usft) Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) Offset Wellbore Centre Kuparuk 1R Pad Depth Depth Depth 0.704 STOP Drilling 1.13 1 R-23 - 1 R-23 - 1 R-23 11,650.00 11,650.00 0.00 -314.97 0.000 STOP Drilling, CC, ES, SF 1 R-23 - 1 R-23 - 1 R-23 11,911.83 11,950.00 128.22 122.97 24.456 CC, ES, SF 1 R-23 - 1 R-23AL1 - 1 R-23A1-1_wp04 (Draft A) 14,416.88 14,425.00 46.21 38.48 5.979 CC, ES, SF 1 R-23 - 1 R-23AL2 - 1 R-23A1-2_wp03 (Draft A) 12,800.05 12,800.00 5.17 1.16 1.290 Take Immediate Action, CC, 1 R-23 - 1 R-23AL2 - 1 R-23AL2_wp03 (Draft A) 14,950.36 14,925.00 52.68 5.82 1.124 Take Immediate Action, SF 1 R-23 - 1 R-23AL3 - 1 R-23AL3_wp01 (Draft A) 12,719.18 12,725.00 60.43 59.92 118.422 CC, ES 1 R-23 - 1 R-23AL3 - 1 R-23AL3_wp01 (Draft A) 13,977.54 14,000.00 203.75 196.14 26.755 SF 1 R-23 - 1 R-231-1 PB1 - 1 R-2311 PB1 11,918.83 11,925.00 26.73 24.72 13.330 CC, ES 1 R-23 - 1 R-231-1 PB1 - 1R-231-1 PB1 13,971.02 14,088.00 79.53 51.94 2.883 Normal Operations, SF 1 R-23 - 1 R-231-1 PB2 - 1 R-231-1 PB2 11,918.83 11,925.00 26.73 24.72 13.299 CC, ES, SF 1 R-23 - 1 R-231-1 PB3 - 1 R-231-1 PB3 11,918.83 11,925.00 26.73 24.72 13.330 CC, ES 1 R-23 - 1 R-231-1 PB3 - 1 R-2311 PB3 13,528.40 13,760.00 152.47 128.18 6.276 SF 1 R-35 - 1 R-35 - 1 R-35 5,574.13 6,930.66 11,699.00 6,763.70 Out of range 1 R-35 - 1 R-35 - 1 R-35 160.14 161.39 -134.14 5,574.13 Out of range 1 R-35 - 1 R-35 - 1 R-35 TD Projection 6.767.24 11,725.00 6,781.14 0.85 Out of range Offset Design Kuparuk 1 R Pad - 1 R-23 - 1 R-23 - 1 R-23 Between Minimum Survey Program: 100 -GCT -MS Centres Ellipses Separation Factor (usft) (usft) Reference Offset -0.91 Semi Major Axis 0.02 -278.65 278.68 Measured Vertical Measured Vertical Reference Offset Azimuth Offset Wellbore Centre Depth Depth Depth Depth 0.704 STOP Drilling 1.13 from North -N/-S +EI -W (usft) (usft) (usft) (usft) (usft) lush) (°) (usft) (usft) 11,625.00 6,733.68 11,625.00 6,733.66 0.41 0.43 91.00 5,527.45 6,883.93 11625.00 6,733.68 11625.00 6,733.66 159.90 160.11 91.00 5,527.45 6,883.93 11,650.00 6,745.48 11,650.00 6,745.48 0.82 0.86 -46.64 5,543.00 6,899.55 11,650.00 6,745.48 11,650.00 6,745.48 160.12 160.54 -46.64 5,543.00 6,899.55 11,674.92 6,756.28 11,675.00 6,757.32 0.83 1.29 -133.83 5,558.56 6,915.12 11,674.92 6,756.28 11,675.00 6,757.32 160.13 160.97 -133.83 5,558.56 6,915.12 11,699.00 6.763.70 11,700.00 6,769.19 0.84 1.72 -134.14 5,574.13 6,930.66 11,699.00 6,763.70 11,700.00 6,769.19 160.14 161.39 -134.14 5,574.13 6,930.66 11,721.16 6.767.24 11,725.00 6,781.14 0.85 2.15 -134.26 5,589.70 6,946.15 11,721.16 6,767.24 11,725.00 6,781.14 160.16 161.82 -134.26 5,589.70 6.946.15 11,741.78 6,767.80 11,750.00 6,793.22 0.86 2.58 -134.28 5,605.23 6,961.58 Offset Site Error: 0.00 usft Offset Well Error: 0.00 usft Distance Between Between Minimum Separation Warning Centres Ellipses Separation Factor (usft) (usft) (usft) 0.02 -0.91 0.93 0.025 STOP Drilling 0.02 -278.65 278.68 0.000 STOP Drilling 0.00 -1.82 1.82 0.001 STOP Drilling 0.00 -314.97 314.97 0.000 STOP Drilling, CC, ES, SF 1.13 -0.48 1.61 0.704 STOP Drilling 1.13 -236.48 237.61 0.005 STOP Drilling 5.65 3.69 1.96 2.878 Normal Operations 5.65 -221.59 227.24 0.025 STOP Drilling 13.96 11.69 2.27 6.151 13.96 -198.79 212.75 0.066 STOP Drilling 25.43 22.88 2.55 9.972 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1111512019 1:55:24PM Page 2 COMPASS 5000.14 Build 85H rV N W L 01 7 F ._. _.. _...._,:_._ j_..._... .. 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J p Q FFaad�_ N 22 K ~ m C O 1� N G Q S M O m aM � d N V a �o 8 O I It .:. V �A POP p N O 2 a)LO L D O W ;0 O # d ���`` = CL (O N -O O N r Y d c 50M O m Nr N N L�3 (0 Y> U r co ' V u § w _§ § § �4 m2 - �k Cl) CL Cl) co\\ �\ ¥ a - /e 3 §\ � / \ � \ § \ / -- - E ) co k / \ \ \ Cl) - CL e - m e 2 E cu _ �b } \ E Q£ - j2 e � k co - %LO - & \ \CL \ \ x ~77 == 7 ( / j { \ co co § w _§ § § �4 m2 - �k Cl) CL Cl) co\\ �\ ¥ a - /e 3 §\ � Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Friday, November 1, 2019 10:51 AM To: McLaughlin, Ryan; Boyer, David L (CED) Cc: Ohlinger, James J Subject: KRU 1R-23(PTD 191-101, Sundry 319-493) Set 261B Whipstock Follow Up Flag: Follow up Flag Status: Completed Ryan, This sundry work for setting a whipstock in motherbore KRU 111-23 has changed from setting a 261B whipstock(originally the C Sand was left open) to a plug for redrill since now all the perforations will be cemented. The paperwork has just increased. This is what is needed: 1. A plug for redrill sundry for KRU 1R-23(PTD 191-101); we can change this existing sundry(319-492) to plug for redrill by hand. No need to resubmit the whipstock sundry. 2. However, the naming convention of the sidetrack and laterals must change as follows and new PTDs must be submitted: a. Well KRU 111-231-1 will need to be resubmitted as KRU 111-23A b. Well KRU 111-23L1-01 will need to be resubmitted as KRU 1R -23A-01 c. Well KRU 1R -23L1-02 will need to be resubmitted as KRU 1R -23A-02 d. These will all be assigned new PTD and API numbers. The motherbore will be abandoned and the KRU 111-231-1 closed out. I will route the plug for redrill whipstock for KRU 113-23 for approval today or Monday. However, please submit the required new PTDs. So sorry for the additional paperwork. Let me know if any clarification is needed. 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(cDalaska.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 Vicbria.Loepp:�alaska.gov Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Tuesday, October 29, 2019 10:18 AM To: McLaughlin, Ryan Cc: Ohlinger, James J Subject: KRU 1 R-23L1(PTD 219-128) Operations Shutdown Request Follow Up Flag: Follow up Flag Status: Completed Ryan, Verbal approval is granted for the Operations Shutdown for CRD3-AC for KRU 1R-23L1(PTD 219-128). Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(a)alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.aov From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Tuesday, October 29, 2019 10:13 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Ohlinger, James J <James.J.Ohlinger@conocophillips.com> Subject: 113-23 (PTD 191-101) Operations Shutdown Request Hello Victoria On October 16th CDR3-AC rigged up to drill a tri -lateral project on 1R-23. After 3 unsuccessful attempts at drilling the 1R -23L1 lateral, primarily due to hole cleaning issues in the 7" production casing, the decision was made to rig down CDR3-AC from 111-23 and set the well up for a cement pilot hole exit for the rig to come back at a later date and complete the scope of the project under the approved PTD. In preparation for resuming CTD operations on this well, perforations will be shot in the tubing tail, cement will be pumped to occupy the 7" casing and plug off C -sand perforations, and the XN nipple in the tubing tail will be milled out. CDR3-AC will mill a cement pilot hole, set a 3-1/2" whipstock, and mill a 2.80" window in the production casing at a depth of 11,662' MD and complete the original scope of the project under the existing permits . We are requesting verbal approval for an Operations Shutdown with the Sundry to be submitted today. We will also submit a subsequent sundry request for cement -squeezing the C -sand perforations and setting a new whipstock prior to beginning the service coil work. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 Loepp, Victoria T (CED) From: Loepp, Victoria T (CED) Sent: Thursday, November 7, 2019 9:18 AM To: Melvin Rixse; Schwartz, Guy L (CED) Cc: Chmielowski, Jessie L C (CED); Carlisle, Samantha J (CED); Boyer, David L (CED) Subject: FYI: KRU/CRU PTD(10-401 s) while Victoria on A/L Attachments: Sonic Conditions of Approval.docx; Permit 219-140_101619.pdf; 8.13.19 Conditions of Approval NFT.SSSV.ESP 3R-111.docx; Permit 219-134_102219.pdf Mel, Guy, Sam, FYI Rotary PTDs that will be submitted for AOGCC approval include KRU 3R-107(producer) and CRU CD5-96: Guy will handle these. Guy attached are conditions of approval that I'm attaching to DS -3R producers relating to the no flow test required for elimination of the SSSV requirement. I worked on these conditions with Jim and would like to be consistent with the DS -3R producers. CTD PTDs that will be submitted include KRU 111-23 sidetrack and laterals and 3H-01 sidetrack and laterals: Mel will handle these; Mel, I attached 10-401 "condition" for kickoff point variance so you can see what we have been granting on these CTD laterals. Note, originally the 1R-23 PTDs were approved as laterals because C sand was left open in the motherbore. This has changed. They are now plugging the motherbore and drilling a sidetrack (111-23A) plus laterals. The plug for redrill sundry for the motherbore has been approved however they will be submitting new PTDs(10-401s) for the 1R-23 sidetrack and laterals. Also attached is 10-401 Conditions of Approval for running the sonic for cement evaluation for wells to be fracked or injectors which I have been including as a part of the 10-401 approval. Thank you! 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(o)alaska.go_v 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 V cto ia_Loepp_< algs_kaaoy Davies, Stephen F (CED) From: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Sent: Thursday, November 21, 2019 3:41 PM To: Davies, Stephen F (CED) Cc: Ohlinger, James J Subject: RE: [EXTERNAL]KRU 1 R-23 (PTD 191-101; Sundry 319-421, 319-493) - Questions Hello Steve, The existing perforations will be isolated with cement (Sundry #319-493). The cement portion of that work has not occurred yet, but will hopefully commence sometime next week. ConocoPhillips does not plan to attempt to drill 1R-231_1-01, 1R-231_1-02, and 1R-231_1-03 so those permits can be withdrawn. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-265-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Thursday, November 21, 2019 2:22 PM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1R-23 (PTD 191-101; Sundry 319-421, 319-493) - Questions Hi Ryan, I'm working on the Permit to Drill applications for the laterals that will be drilled from 1R-23, and I need a bit of clarification. 1. Will all existing perforations in KRU 1R-23 be isolated with cement prior to beginning the currently proposed drilling operations? 2. Does ConocoPhillips wish to withdraw the Permit to Drill applications for 1R-231-1-01, 111-231-1-02, and 111-231-1- 03? 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.daviesnalaska.aov. From: Davies, Stephen F (CED) Sent: Monday, September 16, 2019 11:20 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocOghillips.com> Subject: RE: [EXTERNAL]KRU 1R-23 (PTD 191-101; Sundry 319-421) - Question Thank you Ryan. 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: McLaughlin, Ryan <Ryan.McLaughlin@Conocophilh s.com> Sent: Monday, September 16, 2019 11:18 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Subject: RE: [EXTERNAL]KRU 1R-23 (PTD 191-101; Sundry 319-421) - Question Steve, That is correct. The high expansion wedge is non -isolating. Regards, Ryan McLaughlin Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-26S-6218 Cell: 907-444-7886 700 G St, ATO 670, Anchorage, AK 99501 From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Monday, September 16, 2019 11:16 AM To: McLaughlin, Ryan <Ryan.McLaughlin@conocophillips.com> Subject: [EXTERNAL]KRU 1R-23 (PTD 191-101; Sundry 319-421) - Question Ryan, Could you please confirm that the proposed High Expansion Wedge will not isolate the existing C -sand perforations in KRU 1R-23? Thank you, 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.gay. TRANSMITTAL LETTER CHECKLIST WELL NAME: Ka //.C"- z C� PTD: Development — Service — Exploratory _ Stratigraphic Test Non ._ -Conventional FIELD: j 1C�t 1 1 ti� POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PI) and API number (50- - _� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where sam les are first caught and 10' sam le intervals throu tar et zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well until after (Company_Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (C:Omt W Name) must contact the AOGCC to obtain advance approval of such water well testin prow -am. 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 (Compare Namel in the attached application, the following well logs are also required for this well: Well Logging Requirements j 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 da after com letion, su rasion or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 Date: Well Name: KUPARUK RIV UNIT 1R-23A Program DEV Well bore seg ❑ PTD#: 2191660 Company ConocoPhillips Alaska, Inc. Initial Class/Type DEV/PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease number appropriate_ Yes - - - - - - - Surface Location lies_within ADL0025635; Portion-of Well Passes Thru ADL0025636;_ - - 3 Unique well-name and number --- Yes - - - - Top-Prod- Int_& TD he with in_ADL0025627- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 Well located in-a_d_efinedpool- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Kuparuk River Oil Pool, governed by Conservation Order No. 432D - - - - - 5 Well located proper distance from_ drilling unit-boundary --------------------- - - - Yes CO 432D Rule 3: There shall be no restrictions as to well spacing except that no pay shall be opened in- 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes a well closer_than_500 feet to an external property-line where ownership or landownership ----- - - 7- 7 Sufficient acreage available in-drilling unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - - As planned, this redrill conforms with spacing requirements._ - - - - - - - - - - _ _ _ _ - - - - _ _ - - - - - - 8 If deviated, is wellbore plat-included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ - _ _ _ - - - - _ _ - - - - - - - - - - - - - - - - --------------------------------------- 9 Operator only affected party_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - - _ - - _ _ _ - _ _ - - - Yes- - . - - _ ------------------------------------------------------------------- 10 Operator has_appropriate-bond in force--------------------------------- Yes ------------------------------------- 11 Permit can be issued without conservation order- - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ _ - - _ - _ - - _ _ _ _ _ - _ _ _ - _ _ - _ _ - - - _ - - - - - - - - - Appr Date 12 Permit Gan be issuers without admin istrativ_e_approval - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - _ - - _ _ _ - - - _ _ - - _ - _ _ - - - _ _ _ - - 13 Can permit be approved before 15-day wait- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - SFD 11/21/2019 - 14 Well located within area and-strata authorized by_ Injection Order # (put 10# in-comments)_(For_ NA- -- - - - - - - - - - - - - - - - - - - _ _ _ _ _ - _ _ _ _ - _ - - - 15 All wells-within -1/4 mile area of review identified (For service well only) - - - - - - - - - - - - - - - NA_ - - - _ _ _ _ _ - _ - - _ - _ - - _ - _ - _ - - - - _ - - - _ - - - - - 16 Pre-produced injector; duration of pre production less than 3 months _(For service well only) _ _ NA_ - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 Nonconven. gas conforms to AS31.05.030Q.1_.A),(j.2_.A-D) - - - - - - - - - - - - - - - - - - - - - - NA_ - - - - - - - - - - - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ - 18 Conductor string-Provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ Conductor set_for _KRU_ 1 R-23 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Engineering 19 Surface casing_protects all known_ USDWs _ _ _ _ _ - - NA- - - - _ - _ Surface casing set for KRU 1R-23- - - - - - - - - - - - - - - - - - - 20 CMT-vol_ adequate_ to circulate-on conductor & surf_csg - - - - - - - - - - - - - - - - - - - NA- - . - - _ Surface casing set and fully cemented - - - - - - - - - - - - - - - - - - - - - - - - - - - - 21 CMT_voladequate _to tie-in long string to surf csg------------------------ - - NA- - - - - - - - - - - - _ - - _ _ _ - - _ _ _ _ _ - - - _ - - _ . - 22 CMT-will cover all known-productive horizons- - - - - - - - - - - - - - - - - - - - - - - - - - - - No Productive interval will not be_completed;_unlined delineation lateral - . - - - - 23 Casing designs adequate for C,_T, B &_permafrost ------- Yes - - - - - - - - - - - - - - - - - 24 Adequate tankage_ or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes. - - - - - _Rig has steeltanks., all _waste-to approved disposal wells _ _ _ _ 25 -If-a- reArill, has_a 10-403 for abandonment been approved - - _ _ Yes - - - PTD 191-101,_Sundry 319-493_ _ _ _ 26 Adequate wellbore separation proposed - - - - - - - - - - - Yes - - - - - - - Anti-collision analysis complete; no major risk _failures - - - - - - - - -- - - - - - - - - - - - - - - - - - - 27 If diverter required, does it meet regulations- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - - - - - - - - - - - - - - - - - _ - - _ _ _ _ _ _ _ _ _ ---------------------------------------------- Appr Date 28 Drilling fluid-program schematic& equip list adequate- - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Max formation_ pressure is_3515 psig(10 ppg EMW); will drill w/ 8.6-ppg EMW and maintain overbal_w/ MPD_ _ _ _ _ VTL 12/4/2019 29 BOPEs,-do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPE_press rating appropriate; test to _(put prig in comments)_ - - - - - - - - - - - - - - - - Yes - - - - - _ - MPSP is 2841_ psig; will test BQPs_to 3500_psig _ _ _ 31 Choke_manifold complies w/API_ RP-53 (May 84)- - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - - - - - - - _ - - - 33 Is presence-of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - _ - - H2S measures required_ - - - - - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - 34 Mechanical condition of wells within AOR verified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ - - - - _ - _ _ _ - _ - _ _ _ _ _ _ - _ - - - - - - - _ - _ _ _ - - - _ - - - _ _ _ _ _ _ _ _ _ _ - _ _ - - - - - - - - 35 Permit can be issued w/o hydrogen_ sulfide measures No Wells on 1R-Pad are_H2S-bearing, H2$ measures required. - - - - - - - - - - - Geology 36 Data_presented on_ potential overpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Expected r-eservoirpressure is 10.0 ppg, with some potential of_higher pressure due to gas - - Appr Date 37 Seismic analysis_ of shallow gas_zones- - - - - - - - - - - - - - - - - - NA_ are injection within this area. Well will be drilled using 8.6_ ppg mud, a coiled-tubing rig, and- _ - - SFD 11/21/2019 38 Seabed condition survey (if off_ -shore) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - - - - - - - managed pressure technique to control formation pressures and-stabilize shale sections _by_ - - _ 39 Contact name/phone for weekly-progress reports_ [exploratory only] - - - - - - - - - - - - - - - - NA_ - - - - - - - maintaining a constant pressure gradient of about 1.1 A ppg EMW. _ _ _ _ _ _ _ _ Geologic Engineering Public Commissioner: Commissioner: Date Date )� NN g
