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Home My WebLink About221-078 TTT RR AA NN SS MM II TT TT AA LL FROM:: Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 3S-24B DATE: 04/24/2024 Transmitted: North Slope, Kuparuk River Unit Via SFTP data drop Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: 3S-24B e-transmittal well folder Receipt: Date: Alaska/IT-GGRE/ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 221-078 T38738 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.24 14:46:39 -08'00' TTT RR AA NN SS MM II TT TT AA LL FROM:: Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 3S-24B DATE: 04/09/2024 Transmitted: North Slope, Kuparuk River Unit Via sftp data drop ___ 3S-24B Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: 3S-24B e-transmittal well folder Receipt: Date: Alaska/IT-GGRE/ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 221-078 T38688 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.09 15:21:50 -08'00' TTT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 3S-24B DATE: 04/02/2024 Transmitted: North Slope, Kuparuk River Unit Via email data drop ___ 3S-24B Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: 3S-24B e-transmittal well folder Receipt: Date: Alaska/IT-GGRE/ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 221-078 T38675 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.03 11:57:36 -08'00' PTD: 221-078 T38494 Kayla Junke 2/8/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.08 13:42:51 -09'00' From:Heusser, Heather A (DNR) To:Guhl, Meredith D (OGC) Cc:Morgan, Kirk A (DNR) Subject:RE: ConocoPhillips KRU 3S-24B, PTD 221-078, Extended Confidentiality? Date:Tuesday, January 9, 2024 9:06:33 AM Hi Meredith, I heard back from DOG’s Director’s Office. We have not received a request for extended well confidentiality on KRU 3S-24B. Happy data release! Heather Ann Heusser Natural Resource Specialist IV State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage AK 99501-3560 heather.heusser@alaska.gov From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Tuesday, January 2, 2024 2:17 PM To: Heusser, Heather A (DNR) <heather.heusser@alaska.gov> Subject: ConocoPhillips KRU 3S-24B, PTD 221-078, Extended Confidentiality? Hello Heather, Happy New Year! ConocoPhillips Alaska’s exploratory well KRU 3S-24B, PTD 221-078, API 50-103- 20456-02-00, is due for release after January 7, 2024. Has ConocoPhillips requested extended confidentiality for this well? Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20456-02-00Well Name/No.KUPARUK RIV UNIT 3S-24B Completion Status 1-OILCompletion Date 12/7/2021 Permit to Drill 2210780 Operator ConocoPhillips Alaska, Inc. MD 8724 TVD 4937 Current Status P&A 11/16/2023 UIC No Well Log Information: Digital Med/Frmt ReceivedStart Stop OH / CH Comments Log Media Run No Electr Dataset Number Name Interval List of Logs Obtained:GR/Res/Neu/ USIT/ CCL Log/ CBL NoNo YesMud Log Samples Directional Survey REQUIRED INFORMATION (from Master Well Data/Logs) DATA INFORMATION Log/ Data Type Log Scale DF 1/18/2022 Electronic File: ConocoPhillips_3S- 24B_ASCII_Stage1.txt 36243ED Digital Data DF 1/18/2022 Electronic File: CPAI_3S-24B_RST- IC_16DEC21_Print.Pdf 36243ED Digital Data DF 1/18/2022 Electronic File: CPAI_3S- 24B_RSTPostFrac_11JAN2022_Print.Pdf 36243ED Digital Data DF 2/23/2022 Electronic File: 3S-24B_AOGCC 10- 404_FRAC_transmittal_23FEB22.pdf 36364ED Digital Data DF 2/23/2022 Electronic File: KRU_3S-24B_10-404_FTS.pdf36364EDDigital Data DF 2/23/2022 Electronic File: ConocoPhillips_3S- 24B_ASCII_Stage1.txt 36364ED Digital Data DF 2/23/2022 Electronic File: CPAI_3S-24B_RST- IC_16DEC21_Print.Pdf 36364ED Digital Data DF 2/23/2022 Electronic File: CPAI_3S- 24B_RSTPostFrac_11JAN2022_Print.Pdf 36364ED Digital Data DF 3/1/202244513 44532 Electronic Data Set, Filename: CAPI_3S- 24B_Drilling_Mechanics_Time_BHA03.las 36381ED Digital Data DF 3/1/20227270 8724 Electronic Data Set, Filename: CPAI_3S- 24B_Drilling_Mechanics_Depth_RM_7270- 8724ftMD__02Dec21_160858.las 36381ED Digital Data DF 3/1/20227270 8724 Electronic Data Set, Filename: CPAI_3S- 24B_VISION_Serviec_RM_7270-8724ftMD.las 36381ED Digital Data DF 3/1/20227273 8626 Electronic Data Set, Filename: SonicScope475_QP_7273ft_8626ft_LAS.las 36381ED Digital Data DF 3/1/2022 Electronic File: 3S-24B_AOGCC logging data_final_transmittal_28FEB22.pdf 36381ED Digital Data Thursday, November 16, 2023AOGCC Page 1 of 3 CPAI 3S-,_ 24B_VISION_Serviec_RM_7270-8724ftMD.las DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20456-02-00Well Name/No.KUPARUK RIV UNIT 3S-24B Completion Status 1-OILCompletion Date 12/7/2021 Permit to Drill 2210780 Operator ConocoPhillips Alaska, Inc. MD 8724 TVD 4937 Current Status P&A 11/16/2023 UIC No Well Cores/Samples Information: ReceivedStart Stop Comments Total Boxes Sample Set NumberName Interval INFORMATION RECEIVED DF 3/1/2022 Electronic File: Triple Combo Dlis_Well Composite_RM.dlis 36381ED Digital Data DF 3/1/2022 Electronic File: CPAI_3S- 24B_Drilling_Mechanics_Depth_BHA03.Pdf 36381ED Digital Data DF 3/1/2022 Electronic File: CPAI_3S- 24B_Drilling_Mechanics_Time_BHA03.Pdf 36381ED Digital Data DF 3/1/2022 Electronic File: CPAI_3S- 24B_VISION_Service_RM_2MD.Pdf 36381ED Digital Data DF 3/1/2022 Electronic File: CPAI_3S- 24B_VISION_Service_RM_2TVD.Pdf 36381ED Digital Data DF 3/1/2022 Electronic File: CPAI_3S- 24B_VISION_Service_RM_5MD.Pdf 36381ED Digital Data DF 3/1/2022 Electronic File: CPAI_3S- 24B_VISION_Service_RM_5TVD.Pdf 36381ED Digital Data DF 3/1/2022 Electronic File: CPAI_3S- 24B_VISION_Service_RM_corrected 5TVD.pdf 36381ED Digital Data DF 3/1/2022 Electronic File: O.1018070.05_CPAI_Kuparuk_River_Unit_2_3S _24B_R1_6.125in_SonicScope475_QP_7273ft_8 626ft_PDF.pdf 36381ED Digital Data DF 3/1/2022 Electronic File: 3S-24B Final directional survey report_NAD27.pdf 36381ED Digital Data DF 3/1/2022 Electronic File: 3S-24B_Surveys.csv36381EDDigital Data DF 5/31/2022 Electronic File: 3S-24B AOGCC_SCMT_transmittal_31MAY22.pdf 36671ED Digital Data DF 5/31/2022 Electronic File: CPAI_3S- 24_SCMT_11DEC_21_Main.pdf 36671ED Digital Data Thursday, November 16, 2023AOGCC Page 2 of 3 DATA SUBMITTAL COMPLIANCE REPORT API No.50-103-20456-02-00Well Name/No.KUPARUK RIV UNIT 3S-24B Completion Status 1-OILCompletion Date 12/7/2021 Permit to Drill 2210780 Operator ConocoPhillips Alaska, Inc. MD 8724 TVD 4937 Current Status P&A 11/16/2023 UIC No Completion Report Production Test Information Geologic Markers/Tops Y Y / NA Y Comments: Compliance Reviewed By:Date: Mud Logs, Image Files, Digital Data Composite Logs, Image, Data Files Cuttings Samples Y / NA Y Y / NA Directional / Inclination Data Mechanical Integrity Test Information Daily Operations Summary Y Y / NA Y Core Chips Core Photographs Laboratory Analyses Y / NA Y / NA Y / NA COMPLIANCE HISTORY Date CommentsDescription Completion Date:12/7/2021 Release Date:1/7/2024 Thursday, November 16, 2023AOGCC Page 3 of 3 M. Guhl 1/2/2024 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Callahan, Mike S To:Guhl, Meredith D (OGC); Lemke, Sandra D Cc:Hobbs, Greg S; Roby, David S (OGC) Subject:RE: [EXTERNAL]Well Testing Report KRU 3S-24B, PTD 221-078 Date:Wednesday, November 29, 2023 1:54:21 PM Good afternoon Meredith, Sorry for the delay getting back to you on this. I’ve followed up with our production group, and we did not do any standalone production test on this well, just the standard production which has been reported. Apologies for the confusion with the wording in the 10-407, that should not have referenced a future well test. Please let me know if you need anything else on this well. Thanks, Mike Callahan Drilling Engineer – ConocoPhillips Alaska (907) 231-2176 From: Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Sent: Monday, November 20, 2023 12:01 PM To: Lemke, Sandra D <Sandra.D.Lemke@conocophillips.com>; Callahan, Mike S <Mike.Callahan@conocophillips.com> Cc: Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]Well Testing Report KRU 3S-24B, PTD 221-078 CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hi Sandra and Mike, I’m reviewing the data submitted for KRU 3S-24B, PTD 221-078, completed 12/7/2021. On that 10- 407, it was noted that “well not online/to be tested at a later date”. I have not found a well testing report in the data submitted. The AOGCC did receive production reporting for this well, but I am wondering if there was a standalone test report that has not been provided. Thank you, Meredith Meredith Guhl (she/her) Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: ___________________ Service Stratigraphic Test 2. Operator Name:6. Date Comp., Susp., or 14.Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval:17. Field / Pool(s): GL: 27.7 ft BF: Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 16" H-40 108' 9-5/8" L-80 2613' 4-1/2" L-80 4927' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 37.8 bbls 15.8 ppg G Blend, 5 bbls Cement to surface6.125" 8714'4-1/2" CASING STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ConocoPhillips Alaska, Inc. WAG Gas 10/1/2023 221-078/323-349 2565' FNL, 1266' FEL, Sec. 24, T12N, R7E, UM 1987' FNL, 402' FEL, Sec. 24, T12N, R7E, UM P.O. Box 100360, Anchorage, AK 99510-0360 475994 5993852 2007' FNL, 379' FEL, Sec. 24, T12N, R7E, UM SURFACE 8724' MD/ 4937' TVD ADL0380107, ADL0025544, ADL025551 932060000, 931869000 50-103-20456-02-00 KRU 3S-24B November 28, 2021 November 30, 2021 9. Ref Elevations: KB: 55.7 Kuparuk River Field/ Kuparuk River Oil Pool WT. PER FT.GRADE CEMENTING RECORD 5989143 SETTING DEPTH TVD 5989163 TOP HOLE SIZE AMOUNT PULLED 472058 472034 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. BOTTOM N/A 1740' MD/ 1524' TVD 7301' MD/ 3663' TVD 7140'MD/ 3601' TVD PACKER SET (MD/TVD) 42" 12.25" pre-installed 29'525 sx ArcticSet, 415 sx LiteCrete 28' 4527'29' 28' If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): 12.6# 6923'-8063' 37.6 BBL 15.8 PPG Class G Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Surface-6818' (TxIA) Surface-4527' (OA) PLUGGED AND ABANDONED Perforations (Cemented): 7943-7948', 7948-7953', 7958-7963' MD 4154-4159', 4159-4164', 4169-4174' TVD Gas-Oil Ratio:Choke Size: 148 bbls 15.8 ppg Cement Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: 28 bbl 15.8 ppg Cement 8714' SIZE DEPTH SET (MD) 3600' 62.5# 40# 108' 7136' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 4:08 pm, Oct 26, 2023 Abandoned 10/1/2023 JSB RBDMS JSB 110323 xG -A.Dewhurst A.Dewhurst 26DEC23VTL 12/29/2023 Coyote Undefined Oil DSR-11/16/23 SFDR8E18 Conventional Core(s): Yes No Sidewall Cores: N/A 30. MD TVD Surface Surface 1740' 1524' Top of Productive Interval N/A 31. List of Attachments: Schematics, Summary of Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Jill Simek Digital Signature with Date:Contact Email: jill.simek@conocophillips.com Contact Phone:(907) 263-4131 Staff Well Integrity Engineer General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS N/A - Plugged and Abandoned Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. N/A - Plugged and Abandoned Authorized Name and Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Jill Simek Digitally signed by Jill Simek Date: 2023.10.26 15:55:19 -08'00' Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 8,074.0 3S-24B 2/7/2023 zembaej Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Cement job 3S-24B 9/9/2023 CBURKET Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 39.1 108.0 62.50 H-40 WELDED SURFACE 9 5/8 8.83 39.1 4,527.3 40.00 L-80 BTC INTERMEDIATE 7 6.28 39.1 11,255.0 26.00 L-80 BTCM WINDOW 7 6.00 7,301.0 7,314.0 3,670.7 26.40 L-80 LINER 4 1/2 3.96 7,133.6 8,714.0 4,924.7 12.60 L80 4.5 Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 58.2 Set Depth … 7,143.6 Set Depth … String Max No… 4 1/2 Tubing Description Tubing – Completion Upper Wt (lb/ft) 12.60 Grade L80 Top Connection H563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 2,706.4 GAS LIFT 6.010 4-1/2" x 1" KBG-4-5 GLM, 12.6#, L80, H563 Camco KBG-4- 5 3.953 6,967.9 GAS LIFT 6.010 4-1/2" x 1" KBG-4-5 GLM w/ DV, 12.6#, L80, H563 Camco KBG-4- 5 3.948 6,993.7 Nipple - X 4.500 Nipple, Landing, 4-1/2", "X", 3.813", H563 HES X 3.813 7,091.7 Nipple - X 4.500 Nipple, Landing, 4-1/2", "X", 3.813", H563 HES X 3.813 7,108.5 Sensor - Discharge Gauge 4.500 SLB Metris Evolve 10K DHG Mandrel w/ DHG S/N 42835-7 Metris Evolve 3.942 7,128.2 No-Go Locator 4.500 Locator Baker No-Go 3.950 7,129.2 Seal Assembly 4.500 Bullet Seal Assy Baker Bullet 3.950 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 38.8 MARKER PLATE 30" MARKER PLATE 5' BELOW OG 9/30/2023 0.000 7,680.0 3,901.2 33.52 CEMENT RETAINER 3.59" FH CEMENT RETAINER 7/31/2023 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 2,706.4 1 GAS LIFT DMY BTM 1 0.0 12/29/2021 Schlumb erger KBG-4-5 0.000 6,967.9 2 GAS LIFT DV BK 1 0.0 2/4/2023 Schlumb erger KBG-4- 5 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 7,133.6 Packer 7.000 Baker Liner Top Packer, HRDE ZXP, 16.11' SBE Baker HRDE-ZXP 3.875 7,169.8 Nipple - XN 4.500 Nipple, Landing, 4-1/2", XN, 3.813", H563 HES XN 3.725 8,628.1 4,838.8 0.89 Landing Collar 4.500 Landing Collar, 4-1/2", 12.6#, L80, Hyd 563 Baker Type 1 2.480 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,812.0 6,818.0 8/15/2023 4.0 APERF YELLOW JACKET 6' TUBING PUNCHER, 4 SPF, & 0° PHASE 6,850.0 6,854.0 8/15/2023 4.0 APERF YELLOW JACKET 4' TUBING PUNCHER, 4 SPF, & 0° PHASE 7,793.0 7,798.0 4,005.3 4,010.2 7/13/2023 6.0 APERF SLB 2-7/8" HSD, POWERJET OMEGA 2906 SYSTEM, 60 DEGREE PHASE, 6 SPF 7,943.0 7,948.0 4,154.3 4,159.3 12/18/2021 6.0 IPERF 3-3/8" HSD POWERJET NOVA 3406 HMX, 60 DEG PHASING, 6 SPF, OAL 5' 7,948.0 7,953.0 4,159.3 4,164.3 12/18/2021 6.0 IPERF 3-3/8" HSD POWERJET NOVA 3406 HMX, 60 DEG PHASING, 6 SPF, OAL 5' 7,958.0 7,963.0 4,169.3 4,174.3 12/17/2021 6.0 IPERF 3-3/8" HSD POWERJET NOVA 3406 HMX, 60 DEG PHASING, 6 SPF, OAL 5' Stimulation Intervals Top (ftKB) Btm (ftKB) Inter val Num ber Type Subtype Start Date Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 7,943.0 7,963.0 1 Mini frac 12/19/2021 0.0 0.0 325.00 325.00 7,943.0 7,963.0 2 Stage 12/19/2021 350,000.0 340,994.0 2,012.00 2,493.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,923.0 8,063.0 4,274.2 Cement Plug 7/31/2023 3S-24B, 10/26/2023 11:04:43 AM Vertical schematic (actual) XN INTERMEDIATE; 39.1-11,255.0 LINER; 7,133.6-8,714.0 Production String 2 Cement; 7,550.0 ftKB IPERF; 7,958.0-7,963.0 Mini frac; 7,943.0 Stage; 7,943.0 IPERF; 7,948.0-7,953.0 IPERF; 7,943.0-7,948.0 APERF; 7,793.0-7,798.0 CEMENT RETAINER; 7,680.0 WINDOW; 7,301.0-7,314.0 Nipple - X; 7,091.7 Nipple - X; 6,993.7 GAS LIFT; 6,967.9 Cement Plug; 6,923.0 ftKB Cement Plug; 6,923.0 ftKB APERF; 6,850.0-6,854.0 APERF; 6,812.0-6,818.0 SURFACE; 39.1-4,527.3 GAS LIFT; 2,706.4 CONDUCTOR; 39.1-108.0 Cement Plug; 39.1 ftKB Squeeze – Behind Casing Squeeze; 39.1 ftKB Cement Plug; 39.1 ftKB MARKER PLATE; 38.8 KUP PROD KB-Grd (ft) 33.67 RR Date 6/12/2003 Other Elev… 3S-24B ... TD Act Btm (ftKB) Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032045602 Wellbore Status PROD Max Angle & MD Incl (°) 69.84 MD (ftKB) 3,853.08 WELLNAME WELLBORE3S-24B Annotation End DateH2S (ppm) 1 Date 1/27/2022 Comment Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,923.0 8,063.0 4,274.2 Cement Plug 7/31/2023 39.1 4,527.0 Squeeze – Behind Casing Squeeze 9/9/2023 39.1 6,882.0 Cement Plug 9/9/2023 39.1 6,882.0 Cement Plug 9/9/2023 39.1 6,818.0 Cement Plug 28 bbls 15.8 ppg Cement 10/16/2023 3S-24B, 10/26/2023 11:04:43 AM Vertical schematic (actual) XN INTERMEDIATE; 39.1-11,255.0 LINER; 7,133.6-8,714.0 Production String 2 Cement; 7,550.0 ftKB IPERF; 7,958.0-7,963.0 Mini frac; 7,943.0 Stage; 7,943.0 IPERF; 7,948.0-7,953.0 IPERF; 7,943.0-7,948.0 APERF; 7,793.0-7,798.0 CEMENT RETAINER; 7,680.0 WINDOW; 7,301.0-7,314.0 Nipple - X; 7,091.7 Nipple - X; 6,993.7 GAS LIFT; 6,967.9 Cement Plug; 6,923.0 ftKB Cement Plug; 6,923.0 ftKB APERF; 6,850.0-6,854.0 APERF; 6,812.0-6,818.0 SURFACE; 39.1-4,527.3 GAS LIFT; 2,706.4 CONDUCTOR; 39.1-108.0 Cement Plug; 39.1 ftKB Squeeze – Behind Casing Squeeze; 39.1 ftKB Cement Plug; 39.1 ftKB MARKER PLATE; 38.8 KUP PROD 3S-24B ... WELLNAME WELLBORE3S-24B DTTMSTART JOBTYP SUMMARYOPS 7/11/2023 ACQUIRE DATA EQUALIZE AND PULL XX-PLUG W/ DUAL SPARTEK GUAGES FROM X-NIPPLE @ 7091 RKB. DFIT UP NEXT. 7/12/2023 ACQUIRE DATA SLB E-LINE: SET PLUG 3.66" PIIP RBP W/ PRESSURE GAUGES HUNG BELOW, MOE = 7933' RKB, CCL STOP = 7923' RKB, CORRELATED TO GR/CCL/CBL LOG DATED 12/11/2021, GOOD INDICATION OF SET. JOB IN PROGRESS. 7/13/2023 ACQUIRE DATA SLB E-LINE: RIH WITH GEODYNAMICS 2-7/8" 2818 CONNEX XDP GUN SYSTEM, PERFORATE 7793' TO 7798', CCL STOP = 7784.75, CORRELATE TO GR/CCL/CBL LOG DATED 12/11/2021. GOOD INDICATION OF GUNS FIRING. JOB IS READY FOR DFIT. 7/13/2023 ACQUIRE DATA PERFORM DFIT PER PROGRAM PUMPED 25 BBLS DSL TO ESTABLISH RATE PUMPED 20 BBLS DSL DFIT JOB COMPLETE 7/18/2023 ACQUIRE DATA PERFORM DFIT PER PROGRAM PUMPED 26 BBLS DSL AT 2.5 BPM FOR DFIT 7/23/2023 ACQUIRE DATA PULLED 3.66" P2P RBP W/ GAUGES @ 7930' RKB, DRIFT W/ 10' x 3.625" DUMMY CEMENT RETAINER (UNABLE TO GET PAST 7348' RKB @ MULTIPLE SPEEDS & W/ PUMP ASSIST). READY FOR CTU. 7/23/2023 ACQUIRE DATA ESTABLISHED OA LLR OF 1 BPM @ 1000 PSI PUMPED 20 BBLS OF DIESEL DOWN TBG TO ESTABLISH AN INJECTIVITY RATE OF 3 BPM @ 1100 PSI 7/31/2023 CHANGE WELL TYPE DRIFT FOR CEMENT RETAINER DOWN TO 7,700'. RUN 3.79" CENTRALIZER AND TAG NIPPLE AT 7,170' FLAG PIPE. SET CEMENT RETAINER AT 7,680' IN MIDDLE OF TUBING JOINT.PUMPED 37.6 BBLS OF15.8 PPG CEMENT 25.6 BELOW AND 12 BBLS ON TOP OF RETAINER DRESS OFF TOP OF CEMENT TO 6912' FREEZE PROTECT WELL POOH **** CEMENT PLUG #1 COMPLETE **** 8/11/2023 CHANGE WELL TYPE TAG TOC W/ SAMPLE BAILER @ 6918' SLM (CEMENT IN BAILER) PERFORM MITT TO 2200 PSI (PASSED) PERFORM DDT (PASSED) PERFORM MIT-IA TO 1500 PSI (PASSED) *JOB IN PROGRESS* 8/13/2023 CHANGE WELL TYPE STATE WITNESS TAG TOC @ 6923' RKB, CEMENT IN BAILER, STATE WITNESS MITT TO 2000 PSI (PASSED), JOB COMPLETE. READY FOR ELINE 8/15/2023 CHANGE WELL TYPE RAN 1.56" TBG PUNCH (0-PHASE 4' W/ 4 SPF=16 H0LES) TAG TOC @ 6905' RKB & PUNCH HOLE INTERVAL MID JOINT FROM 6850-6854' RKB (CCL-TOP SHOT = 14'1' W/ CCL STOP @ 6839.5') ESTABLISH CIRC RATE W/ LRS @ 1.18 BPM @ 1900-2000 PSI DOWN TBG TAKING RETURNS UP IA TO FLOW LINE. CONTACT TOWN ENGR. & MAKE UP SECOND TBG PUNCH. MAKE 2ND 1.56" TBG PUNCH (0-PHASE 6' W/ 4 SPF=24 HOLES) TAG TOC @ 6905' RKB & PUH @ PUNCH HOLES MID JOINT FROM 6812'-6818' RKB (CCL STOP @ 6799.9' & CCL-TOP SHOT=12.1'. LRS ESTABLISHED CIRC RATE OF 1.3 BPM @ 2000 PSI. RIG DOWN AND HAVE LRS TROUBLE SHOOT SURFACE LINE TO SEE IF THERE IS A RESTRICTION (OBTAIN SAME CIRC RATE TIED INTO TEE ON IA PUMPING DIRECTLY THRU HOSE TO FLOWLINE) WILL RETURN WITH OTHER EQUIPMENT TO ESTABLISH CIRC RATE. 8/25/2023 CHANGE WELL TYPE PUMPED 28 BBLS DIESEL DWN TBG UP IA TO FL OF 3S-24 TO ESTABLISH PUMPING RATE, PUMPING RATE ESTABLISHED FROM 18 BBLS TO 28 BBLS @ 1.9 BPM 1950 psi TBG AT THE PUMP, 1300 psi IA, WITH A MAX PRESSURE OF 2000 psi, PUMPED 3 BBLS DWN FL F/P U-TUBE TBGxIA FOR FREEZE PROTECT. JOB COMPLETE 3S-24B Plug and Abandon Summary of Operations 9/9/2023 CHANGE WELL TYPE PUMP AN OA DOWN SQUEEZE FROM SURFACE TO THE CASING SHOE @ 4,527KB. PUMPED 5 BBL OF FRESH WATER SPACER AND ESTABLISHED AN INJECTION RATE OF 1.2 BPM/1400 PSI. HALLIBURTON THEN BATCHED UP 148 BBL'S OF 15.8 PPG PERMAFROST CEMENT (SAMPLES TAKEN) AND BULLHEAD DOWN THE OA @ 3.0 BPM/1000 PSI. ALL PRODUCT WAS PUMPED. DOWN OA. (FULL BORE) PUMP FRESH WATER DOWN THE 4 1/2" TUBING TO THE TUBING PUNCH @ 6,882'. THEN UP THE 4 1/2" BY 7" ANNULUS. PUMP A 10 BBL SPACER AND ESTABLISH AN INJECTION RATE OF 4 BPM/600 PSI.HALLIBURTON THEN BATCHED UP 253 BBL'S OF 15.8 PPG CLASS G CEMENT (SAMPLES TAKEN). PUMPED CEMENT AT A RATE OF 4 BPM/200-500 PSI. CEMENT TO SURFACE @ 233 BBL'S AWAY, CONTINUE TO PUMP 20 BBL'S OVER. JOB COMPLETE HALLIBURTON RDMO. 9/11/2023 CHANGE WELL TYPE (P & A) T, IA AND OA DDT TO 0 PSI. (PASSED), T TOC = 4', IA TOC = 4', OA TOC = ~72'. 9/18/2023 CHANGE WELL TYPE (P&A) IN PROGREES. REMOVED TREE, IA/OA VALVES, INSTALLED BLINDS. TUBING TOC 34'-8" LOW O2, HIGH CO , LELs 2.4%. RETURN IN THE AM TO REVERIFY TOC OF IA AND OA . 9/19/2023 CHANGE WELL TYPE (P&A) IN-PROGRESS, VERIFY T,IA & OA TOPS OF CEMENT AND GAS READINGS 9/20/2023 CHANGE WELL TYPE (P&A) IN-PROGRESS CHECK GAS READING'S AND PRUGE IA 9/22/2023 CHANGE WELL TYPE (P&A) AOGCC (GUY COOK) WITNESSED T, IA, & OA CEMENT LEVELS 9/23/2023 CHANGE WELL TYPE (P&A) TOP OFF THE T AND OA WITH CEMENT (COMPLETE) 9/25/2023 CHANGE WELL TYPE (P&A) CUT & REMOVE THE WELLHEAD (COMPLETE) DRIVE SHORING "CAN" (COMPLETE) 9/26/2023 CHANGE WELL TYPE (P&A) REMOVED THE CELLAR BOX (COMPLETE) EXCAVATE TO 14' (IN PROGRESS ~10') 9/27/2023 CHANGE WELL TYPE (P&A) EXCAVATE TO 14' (IN PROGRESS 12' 8"') 9/28/2023 CHANGE WELL TYPE (P&A) EXCAVATE TO 14' (COMPLETE) CUT AND REMOVED AN ADDITIONAL 92" OF THE WELL (COMPLETE) 9/29/2023 CHANGE WELL TYPE (P&A) PREPPED THE WELL FOR THE MARKER PLATE (COMPLETE) AOGCC, ADAM EARL, WITNESSED THE TOC AND OA VOID (APPROVED TO TOP OFF VOID) TOPPED OFF THE OA WITH ~10 GAL OF CEMENT (COMPLETE) 9/30/2023 CHANGE WELL TYPE (P&A) AOGCC, ADAM EARL, WITNESSED THE TOP OF CEMENT AND MARKER PLATE (COMPLETE) BACKFILLED EXCAVATION AND REMOVED SHORING "CAN" (COMPLETE) 10/1/2023 CHANGE WELL TYPE (P&A) LEVELED EXCAVATION BACKFILL (COMPLETE) CLEAN WORK SITE (COMPLETE) AOGCC, AUSTIN MCLEOD, WAIVED WITNESS OF THE FINAL SITE CLEARANCE SUNDRY NOTICE 10-407 ConocoPhillips Well 3S-24B Plug and Abandonment October 10, 2023 ConocoPhillips Alaska, Inc. performed Plug and Abandonment operations on 3S-24B, commencing operations on July 23, 2023 and completing the Plug and Abandonment on October 1, 2023. A cement retainer was set at 7,680ft KB, and 25.6 bbls of Class “G” cement was pumped through the retainer across the perforations and into the tubing, then approximately 12 bbl of cement laid in on top of the retainer. Top of Cement was tagged at 6,923ft KB, and tubing holes punched at 6,850-6,854ft KB and 6,812-6,818ft KB. The production casing by surface casing annulus (OA) was cemented with 148 bbls of permafrost cement pumped from surface to the surface casing shoe at 4,527ft KB, then 253 bbls of Class “G” cement was pumped down the tubing and up the tubing by production casing annulus (IA) to surface. The well was excavated to 4 ft below original ground level, tree and wellhead removed, cement top-off job performed (~10gal in tubing and OA), well capped, and excavation backfilled. Pictures below show cement to surface, marker plate installed, and final site condition after backfill. The field Well Service Report Summary is attached. 2023-0930_Surface_Abandon_Final_KRU_3S-24B_ae Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10-2-2023 P. I. Supervisor FROM: Adam Earl SUBJECT: Surface Abandonment (Final) Petroleum Inspector KRU 3S-24B ConocoPhillips Alaska Inc PTD 2210780; Sundry 323-349 9-30-2023: I traveled out to KRU 3S-24B to inspect the cut-off depth, cement to surface, and marker plate information. Brennen Green was the CPAI representative on the job. The well was cut-off at approximately 5 feet below tundra grade. It had good cement in all strings. The marker plate had the correct information welded on it. Attachments: Photos (2)    2023-0930_Surface_Abandon_Final_KRU_3S-24B_ae Page 2 of 2 Surface Abandonment (Final) – KRU 3S-24B (PTD 2210780) Photos by AOGCC Inspector A. Earl 9/30/2023 [file name] Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 9/22/2023 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector KRU 3S-24B ConocoPhillips Alaska Inc PTD 2210780; Sundry 323-349 9/22/2023: Traveled out to location with AOGCC Petroleum Inspector Josh Hunt to locate the cement level in the well before the well is cemented to surface and the wellhead is removed. Tubing. A measuring tape was used with a small shackle for weight to locate the top of cement in the tubing. Cement was found at 34 feet 8 inches from surface. Inner and Outer Annuli. A weighted string/small cord was used to locate the top of cement in the IA and the OA. The cement was found to be at 4 feet below surface in the IA and at 70 feet below surface in the OA. Once the cement is brought to surface and the wellhead is cut off, CPAI will notify AOGCC to do final surface abandonment inspection before installation of the well identification plate. Attachments: none       MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:18 Township:12N Range:8E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:8724 ft MD Lease No.:ADL380107 Operator Rep:Suspend:P&A:X Conductor:16"O.D. Shoe@ 108 Feet Csg Cut@ Feet Surface:9 5/8"O.D. Shoe@ 4527 Feet Csg Cut@ Feet Intermediate:7"O.D. Shoe@ 8714 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner:3 1/2"O.D. Shoe@ 7136 Feet Csg Cut@ Feet Tubing:O.D. Tail@ Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Perforation Retainer 7680 ft 6923 ft 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2010 1900 1860 IA 545 545 545 OA 305 305 305 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: First tag on cement was at 6923 ft MD. The second tag on cement after the passing MITT was completed was at 6923 ft. The cement sample from the drive-down bailer contained some good cured cement and some contaminated cement. Pollard slickline ran a 1 3/4" x 18" drive-down bailer that had a muleshoe with a flapper valve. Their tool string was approxiamately 175 pounds. MITT to 1500 psi required. 0.94 bbls in and 0.8 returned. August 13, 2023 Guy Cook Well Bore Plug & Abandonment KRU 3S-24 ConocoPhillips Alaska Inc PTD 2210780; Sundry 323-349 none Test Data: P Casing Removal: Mike Scoles Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2023-0813_Plug_Verification_KRU_3S-24_gc             1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 8724'None Casing Collapse Structural Conductor Surface Liner Production Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Jill Simek jill.simek@conocophillips.com (907) 263-4131 Staff Well Intervention Engineer Tubing Grade: Tubing MD (ft): 7140' MD and 3601' TVD N/A Perforation Depth TVD (ft): Tubing Size: L-80 7136' 7/1/2023 Packer: Liner Top Packer SSSV: None STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL380107, ADL025544 221-078 P.O. Box 100360, Anchorage, AK 99510 50-103-20456-02-00 ConocoPhillips Alaska, Inc. KRU 3S-24B N/A Plugged/AbandonedUndefined Oil Pool Kuparuk River Field N/A Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 4937' 8714' 4925' 7091' MD 108' 2613' 4927' 108' 4527' 8714' 16" 9-5/8" 80' 4498' Perforation Depth MD (ft): 4-1/2"1590' 7944-7963' 4157-4176' 4-1/2" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov CONFIDENTIAL By Grace Christianson at 10:02 am, Jun 19, 2023 Jill Simek Digitally signed by Jill Simek Date: 2023.06.14 16:13:07 -08'00' 323-349 DSR-6/21/23 10-407X MDG 6/21/2023 AOGCC inspection required after cutoff and before remedial cementing Well abandonment marker to meet requirements of 20 AAC 25.120 Photo document all steps of surface abandonment X Coyote VTL 06/26/2023BWH 6/26/23 06/26/23 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.06.26 13:51:23 -08'00' RBDMS JSB 062723 JS Date: June 6, 2023 Subject: 3S-24B DFIT and P&A Procedure Procedure Justification: Producer 3S-24B (PTD: 221-078-0) was sidetracked and recompleted in late 2021 to test the Coyote reservoir for future development. After the test is complete, the well will be P&A’d for slot recovery (grassroots Torok producer 3S-624). The well is completed with 4 ½” tubing, liner top packer at 7,124ft KB, and 4 ½” liner run to 8,714ft KB. Surface casing is 9-5/8”, and intermediate casing is 7” with a sidetrack window at 7,301ft KB. Perforations are located from 7,943-7953ft KB and 7,958-7,963ft KB. Per this procedure, P&A operations will be performed with coil tubing to pump cement through a cement retainer, across the perforations, and into the tubing, to an approximate depth of 6,912ft KB. A cement downsqueeze will follow to place approximately 4,527ft of cement in in the surface casing x production casing annulus (OA). Holes will then be punched in the tubing, above Plug #1 Top of Cement (TOC) and cement placed in the tubing and tubing x production casing annulus (IA) to surface. The well will then be excavated 4 feet below original ground level, wellhead and cellar removed, and site backfilled with gravel/fill to ground level. Please call Jill Simek @ 1-907-980-7503 with questions or concerns. Job Objective: Perform Diagnostic Fracture Initiation Test (DFIT), then plug and abandon well with cement to surface. Cut casing and tubing strings below grade and remove wellhead. Well Status: The well is currently shut-in with a plug set at 7,091ft KB, and is being used for 3S-701 interference test monitoring (via downhole gauge at 7,108.5ft KB). Last BHP (PBU on 2/7/2023): 1,935psi at 4,150ft SS Fluid in tubing: 10.6ppg potassium formate brine to perfs Maximum deviation: 70 degrees at 3,853ft KB Max dogleg: 22deg/100ft at 7,757ft KB Min ID: 3.725” XN-nipple at 7,170ft KB CONFIDENTIAL JS Procedure: Slickline: Objective: Pull plug and gauges 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU Slickline and PT Equipment as required. 3. RIH and pull plug and gauges at 7,091ft KB. 4. RDMO. Eline: Objective: Set plug/gauges and perforate for Diagnostic Fracture Initiation Test (DFIT) 1. Ensure an approved sundry has been received from AOGCC. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU E-Line and PT Equipment as required. 4. Reference 5/11/2023 schematic and tubing details for depth correlation. 5. RIH with plug and gauges hung below. Set plug above Coyote top perf, ~7,933ft KB. a. Ensure gauges are set to record at 1 sec intervals. 6. RIH with Geodynamics 2-7/8” 2818 Connex XDP gun system. Perforate 7,793ft – 7,798ft KB. 7. RDMO. Little Red: Objective: Perform DFIT 1. Contact SCADA Analyst (x7216) to ensure SLB downhole gauge pressure data is being recorded at 1 sec intervals. 2. Contact Little Red Services to schedule the pumping unit/crew for the DFIT. Ensure pump unit DAS is recording accurate pump rates and SLB DHG data can be monitored in unit while pumping. 3. RU pump unit to pump down tubing and perform the DFIT below: a. Ensure SLB gauge is recording bottom hole gauge pressure prior to starting pumps. b. Max Tubing Pressure = 4,000 psi. c. Start pumps, establish injection rate @ 2 BPM diesel, for approx. 30 seconds to ensure formation is taking fluid. d. Increase pump rate from 2 BPM to 5 BPM (or max rate under 4,000 psi max tubing pressure) e. Hold 5 BPM/max rate CONSTANT until full 20 bbls is pumped. f. After 20 bbls injection, perform a hard shut-in. CONFIDENTIAL JS g. Ensure pump report (Press/Rates/Density/DHG Data) is gathered prior to leaving location. Email pump report to Completion Engineer: madeline.e.woodard@conocophillips.com 4. RDMO. After 72 hours (confirm with Completion Engineer), well is ready for P&A. Slickline/Little Red Services: Objective: Pull plug/gauges, drift for cement retainer, perform injectivity test to confirm adequate rates for cementing operations 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU Slickline and PT Equipment as required. 3. RIH and pull plug and gauges at 7,933ft KB. 4. RIH with dummy cement retainer tool string to 7,700ft KB, or as far as possible. 5. Rig up LRS. With ~20 bbls diesel pumping down tubing, perform step rate injectivity test from 0.5 – 3 bpm, in ½ bpm increments, up to a maximum pressure of 3,000 psi, to ensure adequate rates for cementing operations. Record Results. DISCUSS RESULTS WITH WELL INTERVENTIONS ENGINEER 6. Establish/confirm OA LLR for cement downsqueeze (last LLR = 1 bpm at 1,250psi). 7. RDMO. Coiled Tubing / Cementing: Objective: Place a cement plug across the perforations and squeeze some cement into perforations. Cement Volume Calculations (TOC approximately 6,912ft KB in tubing): 4 ½ liner & tubing,100ft below bottom perfs to cement retainer: (0.01522 bbl/ft) * (8,063ft – 7,700ft) = 5.5 bbls 4 ½ tubing, cement retainer to TOC: (0.01522 bbl/ft) * (7,700ft – 6,912ft) = 12.0 bbls Squeeze volume = 20.5 bbls Total volume = 5.5 + 12.0 + 20.5 = 38 bbls 1. Contact Cementers a week before the scheduled Suspend date, to allow adequate time for pilot testing of the P&A cement design. The job is designed for 38 bbls of 15.8# Class “G” cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Coil Tubing Unit and PT Surface Equipment as required. 4. Reference 5/11/2023 schematic and tubing details for depth correlation. Use XN-nipple at 7,170ft KB for correlation. CONFIDENTIAL JS 5. RIH and perform tie in pass (tag/flag nipple at 7,170ft KB). 6. RIH with cement retainer, taking returns up the CT x Tubing annulus. Do not pump while RIH. 7. Set cement retainer at approximately 7,700ft KB, or as deep as the retainer will safely drift. (Do not set retainer shallower than 7,443ft KB) 8. Close in the CT x tubing annulus, and line up to pump down the coil tubing. 9. Pump 20 bbls of diesel through the retainer to verify proper set and injectivity required for cementing operations (+/- 2 bpm at 2,000psi). 10. Pump 10 bbls freshwater spacer 11. Pump 26 bbls of 15.8 ppg Class “G” Cement through the cement retainer. If squeeze pressure is seen before pumping total cement volume, stop pumping and begin next step. 12. Shut down, un-sting from retainer 13. Lay in remaining 12 bbls cement above retainer (equates to ~ 788’ of cement above the retainer, leaving TOC ~6,912ft KB) 14. POOH above TOC. Circulate CTU clean. 15. Wash up surface equipment. RDMO. Slickline / Little Red Objective: State witnessed tag of TOC, MIT-T, MIT-IA, DDT 1. WOC per UCA data (minimum 24 hours). Notify the AOGCC Inspector of the timing of the cement plug tag and test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Slickline and PT Equipment as required. 4. RIH and tag TOC @ approximately 6,912ft KB. Record Results. TAG MUST BE AOGCC WITNESSED 5. RU LRS and PT Surface Equipment as required. 6. Perform MIT-T to 1,500 psi. Record results. PRESSURE TEST MUST BE AOGCC WITNESSED 7. Perform MIT-IA to 1,500psi. Record results. 8. Perform DDT-T. Record results. 9. Report issues and results to Well Interventions Engineer. 10. RDMO Eline / Little Red: Objective: Punch tubing, injectivity test 1. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU E-Line and PT Equipment as required. 3. RIH with 1.56” x 4’ tubing punch (medium charge); reference 5/11/2023 schematic and tubing details for depth correlation. CONFIDENTIAL JS 4. Punch 30’-50’ above TOC or as close to mid joint as possible. 5. Rig up LRS and pump 20 bbls diesel through tubing holes to ensure adequate rate for cementing (+/- 2 bpm <= 2,000psi). 6. If 2 bpm circ. rate is not achievable, RIH with a second tubing punch and punch holes 32’ above the previous holes. 7. RDMO. Cementing: Objective: Plug #2 – OA Downsqueeze 9 5/8” x 7” annulus (OA) from surface to surface casing shoe (4,527ft KB). Cement Volume Calculations: Volume in 7” x 9 5/8” annulus: (4,527 ft) x (0.02823 bbl/ft) = 127.8 bbl Excess: 20.2 bbl Total volume: 127.8 + 20.2 = 148 bbl 1. Contact Cementers a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. The job is designed for 148 bbls of Permafrost Cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. RU Cement Equipment and PT surface lines as required. 4. Line up down OA. 5. Pump 5 bbl of fresh water spacer. 6. Pump 148 bbl of Permafrost Cement. If well locks up while pumping cement, go to step 7. 7. Close OA, open the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 8. RDMO DHD: Objective: OA TOC, DDT 1. WOC for 24 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on OA. 4. Confirm OA TOC at surface. DISCUSS RESULTS WITH WELL INTERVENTIONS ENGINEER 5. RDMO. CONFIDENTIAL JS Cementing: Objective: Plug #3 - Fill the tubing and IA with cement from tubing punch (~6,882’ KB) to surface. We will be circulating cement down the 4 ½” tubing and up the 4 ½” x 7” annulus. Cement Volume Calculations: Volume in 4 ½” x 7” annulus: (6,882 ft – 0 ft) x (0.01859 bbl/ft) = 128 bbl Volume inside 4 ½” tubing: (6,882 ft – 0 ft) x (0.01522 bbl/ft) = 104.7 bbl Excess: 20.3 bbl Total volume: 128 + 104.7 + 20.3 = 253.0 bbl 1. Contact Cementers a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. The job is designed for 253 bbls of 15.8# Class “G” cement. 2. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3. MIRU cementers. 4. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 4 ½” x 7“ (IA) annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. 5. PT surface equipment as required. 6. Establish circulation with diesel. 7. Pump 5 bbls fresh water spacer 8. Pump 253 bbls of 15.8 ppg Class “G” cement. Assumes tubing punch at 6,882’ KB and includes 20.3 bbl excess. Recalculate based on actual tubing punch depth. 9. After approximately 233 bbls of cement is pumped away, expect to see IA cement returns. Confirm good cement to surface coming from the IA. Pump contingency cement if needed. 10. Shut down pumps and close in the IA. 11. Close in the master valve, open the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 12. RDMO DHD: Objective: DDT, determine TOC 1. WOC for 24 hr or until field blend UCA chart shows cement developed 1,500 psi compressive strength. 2. RU DHD and PT equipment. 3. Perform drawdown test on tubing, IA, and OA. 4. Determine top of cement in tubing and annuli. DO NOT perform cement top up job until AOGCC has been notified and approval has been given to continue. CONFIDENTIAL JS Wellhead Excavation / Final P&A: 1. Notify the AOGCC Inspector of timing for surface plug witness and marker plate installation (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 2. Remove the well house, if still installed. 3. Bleed off tubing, IA, and OA to ensure all pressure is bled off the system. 4. Remove the production tree, in preparation for the excavation and casing cut. 5. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 6. Cut off the wellhead and all casing strings at 4 feet below original ground level. 7. Verify that cement is at surface in all strings. AOGCC witness and photo document required. 8. Send the casing head w/ stub to materials shop. Photo document. 9. Weld ¼” thick cover plate (16” O.D.) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips 3S-24B PTD #: 221-078-0 API #: 50-103-20456-02 10. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 11. Obtain site clearance approval from AOGCC. RDMO. CONFIDENTIAL JS Schematic: CONFIDENTIAL JS P&A Diagram: CONFIDENTIAL Component Description MD (ft)TVD (ft)Length (ft) 1 4-1/2" x 1" KBG-4-5 - SV 2,696' 1,939' 10' 2 4-1/2" x 1" KBG-4-5 - DV 6,968' 3,536' 10' 3 4-1/2" 3.813" X Profil e 6,994' 3,546' 5' 4 4-1/2" 3.813" X Profil e 7,092' 3,583' 5' 5 SLB Metris Evolve 10k Gauge 7,109' 3,589' 5' 6 5" OD Bullet Seal Assembly 7,128' 3,597' 15' 3-½” 9.2# L-80 SLHT Liner @ 12,513' MD / 6,050' TVD 16" 62.5 ppf H-40 Insulated Conductor @ 108' MD/TVD 7" 26# L-80 BTCM Intermediate casing @ 11,255' MD / 5,203' TVD Top Coyote 7,880' MD / 4,093' TVD 3S-24B Sidetrack Schematic X GLGL GLGL Liner Top Packer @ 10,327'' MD 9-5/8" 40# L-80 BTC Surface Casing set @ 4,527' MD / 2,613' TVD 4-1/2" 12.6# L-80 H563 Liner set @ 8,714' MD / 4,927' TVD ktocCIBP / Whips @ D /7,301' M D3,663' TV e-ubing cut prT MDg @ ~7500'ri Perfs @ 7,944' MD / 4,157' TVD to 7,953' MD / 4,166' TVD 7,957' MD / 4,170' TVD to 7,963' MD / 4,176' TVD Length (ft)TVD (ft)MD (ft)Component Description 7 5" x 15' Sealbore Extension 7,124' 3,595'15' 8 4-1/2" x 7" Liner Top Packer / Hanger 7,140' 3,601'10' 9 4-1/2" 3.813" XN Profil e 7,170' 3,613'4' 10 4-1/2" Float Collar + Landing Collar 8,829' 4,697'4' 11 4-1/2" Float Sho e 8,712' 4,737'3' Lower Completion Component Details 1 4 10-11 5 2 3 67 X N 8 4-1/2" 12.6# L-80 H563 Tubing seals @ 7,136' MD / 3,600' TVD Cement plug @ 9,292' MD (10/2/21) Upper Completion Component Details Lower Completion Component Details 9 X Confining Layer Top 6,500' MD / ,358' TVD3 CONFIDENTIAL 1 Guhl, Meredith D (OGC) From:Roby, David S (OGC) Sent:Tuesday, July 5, 2022 10:53 AM To:Perfetta, Patrick J; Hampton, Kyle Cc:AOGCC Reporting (CED sponsored); Loepp, Victoria T (OGC); Davies, Stephen F (OGC); Boyer, David L (OGC) Subject:RE: [EXTERNAL]KRU 3S-24B (PTD 221-078) test production reporting Will do. Thank you. Dave Roby (907)793‐1232 From: Perfetta, Patrick J <Patrick.J.Perfetta@conocophillips.com> Sent: Tuesday, July 5, 2022 10:48 AM To: Roby, David S (OGC) <dave.roby@alaska.gov>; Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S‐24B (PTD 221‐078) test production reporting Hi Dave, Let’s keep the data confidential that was part of the approved 30 day flow testing program. Thanks, Pat Perfetta Principal Geologist | ConocoPhillips Alaska | O: 907‐263‐4531 | C: 713‐446‐5359 From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Tuesday, July 5, 2022 10:38 AM To: Perfetta, Patrick J <Patrick.J.Perfetta@conocophillips.com>; Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S‐24B (PTD 221‐078) test production reporting Hi Pat, For clarification purposes, are you okay with all of the production data going public at this time, or just what has occurred after the 30‐days of testing that was approved with the fracking permit? There were 15‐days of reported production in each of January and February 2021, so these are the two months that are issue. Since this was part of an approved flow testing program it can be held confidential until the well’s confidential 2 period expires in, I think, January 2023. Production from March and on will become public regardless of what your answer to the above question is. Regards, Dave Roby (907)793‐1232 From: Perfetta, Patrick J <Patrick.J.Perfetta@conocophillips.com> Sent: Tuesday, July 5, 2022 6:59 AM To: Roby, David S (OGC) <dave.roby@alaska.gov>; Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S‐24B (PTD 221‐078) test production reporting Hi Dave, Thanks for the detailed clarification. We will not be submitting an additional sundry request to keep these data confidential. We appreciate the notification, so that we could consider submitting one for your review. Best Regards, Pat Perfetta Principal Geologist | ConocoPhillips Alaska | O: 907‐263‐4531 | C: 713‐446‐5359 From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Thursday, June 30, 2022 1:31 PM To: Perfetta, Patrick J <Patrick.J.Perfetta@conocophillips.com>; Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S‐24B (PTD 221‐078) test production reporting HI Pat, For determining whether or not production can be held confidential what the well is permitted as is less important than what the disposition of the production is. While the regulations and statutes do provide for a 25 month period (24 months after the 30‐day filing period after a well is completed/suspended/abandoned) of confidentiality for exploratory and strat test wells they clearly also state that the confidentiality does not apply to regular production. Regular production is defined as production into a processing facility that’s transported to sale, which I believe is the case for the 3S‐24B well, unless the AOGCC approves a testing/pilot program. For long term production from an exploratory well to get automatic confidentiality the well would have to be produced in such a way that the production wouldn’t be considered regular production. Such as if the production were going through a portable well testing unit and then Some people who received this message don't often get email from patrick.j.perfetta@conocophillips.com. Learn why this is important 3 stored in tanks, which could then be hauled by truck to a facility and sold, but this would require an authorization to flare the associated gas and thus would more than likely only be approved for a duration of a few weeks tops. Unless I’m missing something the only testing that we’ve approved so far was the testing that was described as part of the frack sundry and this well has gone beyond the duration indicated in that sundry, so if you want the production to continue to be held confidential we’ll need an application justifying why we should approve a testing/pilot production process for the well. Regards, Dave Roby (907)793‐1232 From: Perfetta, Patrick J <Patrick.J.Perfetta@conocophillips.com> Sent: Thursday, June 30, 2022 1:08 PM To: Roby, David S (OGC) <dave.roby@alaska.gov>; Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S‐24B (PTD 221‐078) test production reporting Dave, Sorry for taking so long to get back to you on this. I had one clarifying question. The well was permitted as an exploration well. I was under the impression, perhaps wrongfully so, that this production could be considered intermittent test production, and that it would fall under the AOGCC confidentiality provision for the automatic two year period, regardless of submitting a sundry. Is this not the case? The general plan for the well is to do a series of production tests, followed by pressure build‐up periods for reservoir characterization purposes. Ultimately, the well will be plugged and abandoned. As it pertains to the production/injection information with respect to the ERIO application, we will not be seeking to maintain those data as confidential. Thanks a lot, Pat Perfetta Principal Geologist | ConocoPhillips Alaska | O: 907‐263‐4531 | C: 713‐446‐5359 From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Monday, June 27, 2022 4:35 PM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov>; Perfetta, Patrick J <Patrick.J.Perfetta@conocophillips.com> Subject: RE: [EXTERNAL]KRU 3S‐24B (PTD 221‐078) test production reporting Pat and Kyle, 4 Speaking of the Coyote project in general, if you’re going to want to try and hold production/injection information from the upcoming Coyote pilot EOR project confidential you should address that in the ERIO application. Regards, Dave Roby (907)793‐1232 From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Monday, June 27, 2022 4:26 PM To: Roby, David S (OGC) <dave.roby@alaska.gov> Cc: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov>; Perfetta, Patrick J <Patrick.J.Perfetta@conocophillips.com> Subject: RE: [EXTERNAL]KRU 3S‐24B (PTD 221‐078) test production reporting Dave Thanks for the note on 3S‐24B. We really appreciate you bringing up those points on the production duration and discrepancy with the sundry. I’ve let Pat Perfetta (CC’d) know as he’s the lead on this project, and we’re working with our land and asset groups to put together a response. We are targeting a response and action for you tomorrow. Thanks again for making us aware. Kyle Hampton AK WNS Planning | Office: 907‐263‐4627 | Cell: 832‐491‐7869 | kyle.hampton@cop.com From: Roby, David S (OGC) <dave.roby@alaska.gov> Sent: Monday, June 27, 2022 12:14 PM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: AOGCC Reporting (CED sponsored) <aogcc.reporting@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov> Subject: [EXTERNAL]KRU 3S‐24B (PTD 221‐078) test production reporting CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Kyle, ConocoPhillips has been reporting production from the subject well Since January 2022 and claiming it is test production. AS 31.05.035(c) states: …Well Surface and bottom hole locations, well dept, well status, production data, and production reports required by the commission to be filled subsequent to the 30‐day filing period shall be considered public information and may not be classified as confidential…. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 5 And AS 31.05.170(14) defines regular production as: “regular production” means continuing production of oil or gas from a well into production facilities and transportation to market, but does not include short term testing, evaluation, or experimental pilot production activities that have been approved by permit or order of the commission; I believe this well is tied into the pad production facilities and its production is processed, transported, and sold so it would meet the requirements of being considered regular production, and thus should be public information unless the second part of the definition would apply and thus allow the production data to remain confidential. In order to consider this test/evaluation/pilot production requires approval by the AOGCC. The only testing period that I can find that was approved by the AOGCC was a 30‐day flowback test that was tacitly approved as part of the sundry application to frack the well. So far the well has flowed for 15 days in January, another 15 days in February, 16 days in March, was shut in in April, and produced another 15 days in May for a total of 61 days of production. So production has gone well beyond what was tacitly approved. If CP wishes for us to continue to keep the production data for this well confidential you’ll need to submit a sundry application requesting approval of a testing program for the well for us to consider and the application will have to demonstrate why the testing is necessary, what the testing goals are, and how long the testing program will need to run in order to reach those goals. Let me know if you have any questions. Regards, Dave Roby Senior Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793‐1232 3URGXFWLRQ0RQWK0D\&212&23+,//,36$/$6.$,1&$ODVND2LO$QG*DV&RQVHUYDWLRQ&RPPLVVLRQ0RQWKO\3URGXFWLRQ5HSRUW)RUP2SHUDWRU&RQRFR3KLOOLSV$ODVND,QF)LHOG1DPH.XSDUXN5LYHU8QGHILQHG)LHOG1DPH.XSDUXN5LYHU8QGHILQHG:HOO1XPEHU$SL1XPEHU&PS7\SH)LHOG&RGH3URG0HWKRG3URG'D\V7EJ3UHVV$YHUDJH'DLO\2LO'DLO\:DWHU'DLO\*DV7RWDO2LO7RWDO:DWHU7RWDO*DV6%6XP 3URGXFWLRQ0RQWK$SU&212&23+,//,36$/$6.$,1&$ODVND2LO$QG*DV&RQVHUYDWLRQ&RPPLVVLRQ0RQWKO\3URGXFWLRQ5HSRUW)RUP2SHUDWRU&RQRFR3KLOOLSV$ODVND,QF)LHOG1DPH.XSDUXN5LYHU8QGHILQHG)LHOG1DPH.XSDUXN5LYHU8QGHILQHG:HOO1XPEHU$SL1XPEHU&PS7\SH)LHOG&RGH3URG0HWKRG3URG'D\V7EJ3UHVV$YHUDJH'DLO\2LO'DLO\:DWHU'DLO\*DV7RWDO2LO7RWDO:DWHU7RWDO*DV6%6XP TT RR AA NN SS MM II TT TT AA LL CONFIDENTIAL DATA FROM: Sandra D. Lemke TO: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 3S-24B Permit: DATE: 05/31/2022 Transmitted: Kuparuk River Unit, North Slope, Alaska 3S-24B Via SFTP ___ SCMT log – 6935.84-8505.33’ MD Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: 3S-24B - e-transmittal well folder Receipt: Date: Alaska/IT-Data Services|ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 PTD:221-078 T36671 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.31 09:52:53 -08'00' 3URGXFWLRQ0RQWK0DU&212&23+,//,36$/$6.$,1&$ODVND2LO$QG*DV&RQVHUYDWLRQ&RPPLVVLRQ0RQWKO\3URGXFWLRQ5HSRUW)RUP2SHUDWRU&RQRFR3KLOOLSV$ODVND,QF)LHOG1DPH.XSDUXN5LYHU8QGHILQHG)LHOG1DPH.XSDUXN5LYHU8QGHILQHG:HOO1XPEHU$SL1XPEHU&PS7\SH)LHOG&RGH3URG0HWKRG3URG'D\V7EJ3UHVV$YHUDJH'DLO\2LO'DLO\:DWHU'DLO\*DV7RWDO2LO7RWDO:DWHU7RWDO*DV6%6XPThis report is confidential and proprietary to ConocoPhillips Alaska, Inc. and not subject to disclosure because it contains information or data thatis (1) trade secret information as defined in AS 45.50.940(3) and State v. Arctic Slope Regional Corp., 834 P.2d 123 (Alaska 1991); (2) datarequired to be held confidential under AS 38.05.035(a)(8), AS 31.05.035(c), AS 43.05.230, and AS 40.25.100(a) 3URGXFWLRQ0RQWK)HE&212&23+,//,36$/$6.$,1&$ODVND2LO$QG*DV&RQVHUYDWLRQ&RPPLVVLRQ0RQWKO\3URGXFWLRQ5HSRUW)RUP2SHUDWRU&RQRFR3KLOOLSV$ODVND,QF)LHOG1DPH.XSDUXN5LYHU8QGHILQHG)LHOG1DPH.XSDUXN5LYHU8QGHILQHG:HOO1XPEHU$SL1XPEHU&PS7\SH)LHOG&RGH3URG0HWKRG3URG'D\V7EJ3UHVV$YHUDJH'DLO\2LO'DLO\:DWHU'DLO\*DV7RWDO2LO7RWDO:DWHU7RWDO*DV6%6XPThis report is confidential and proprietary to ConocoPhillips Alaska, Inc. and not subject to disclosure because it contains information or data thatis (1) trade secret information as defined in AS 45.50.940(3) and State v. Arctic Slope Regional Corp., 834 P.2d 123 (Alaska 1991); (2) datarequired to be held confidential under AS 38.05.035(a)(8), AS 31.05.035(c), AS 43.05.230, and AS 40.25.100(a) 221-078 T36381 Transmittal instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: 3S-24B - e-transmittal well folder Receipt: Date: Alaska/IT-Data Services |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 TT RR AA NN SS MM II TT TT AA LL CONFIDENTIALL DATA FROM:Sandra D. Lemke TO: Victoria Loepp ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE:: 3S-24B Permit: 221-078 DATE: 02/23/2022 Transmitted: KUPARUK River Unit, North Slope, Alaska 3S-24B Via SFTP Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com CC: 3S-24B - e-transmittal well folder Receipt: Date: Alaska/IT-Data Services |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 By Meredith Guhl at 9:38 am, Feb 23, 2022 221-078 T36364 Meredith Guhl Digitally signed by Meredith Guhl Date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y Meredith Guhl at 3:00 pm, Feb 23, 2022 RBDMS SJC 022522 DSR-2/23/22 CDW 11/20/2023 VTL 12/29/2023 A.Dewhurst 26DEC23 !"!#$% &!#$'!$('#$% #)$* !#$ &+!'#!,% !"#$% & '($ ) %$$ * ' + , - - $%.%(.$ * / % %$$0 + ', ) ', ( 0 ) * ! CONFIDENTIAL Component Description MD (ft) TVD (ft) Length (ft) 1 4-1/2" x 1" KBG-4-5 - SV 2,696' 1,939' 10' 2 4-1/2" x 1" KBG-4-5 - DV 6,968' 3,536' 10' 3 4-1/2" 3.813" X Profile 6,994' 3,546' 5' 4 4-1/2" 3.813" X Profile 7,092' 3,583' 5' 5 SLB Metris Evolve 10k Gauge 7,109' 3,589' 5' 6 5" OD Bullet Seal Assembly 7,128' 3,597' 15' 3-½” 9.2# L-80 SLHT Liner @ 12,513' MD / 6,050' TVD 16" 62.5 ppf H-40 Insulated Conductor @ 108' MD/TVD 7" 26# L-80 BTCM Intermediate casing @ 11,255' MD / 5,203' TVD Top Coyote 7,880' MD / 4,093' TVD 3S-24B Sidetrack Schematic X GLGL GLGL Liner Top Packer @ 10,327'' MD 9-5/8" 40# L-80 BTC Surface Casing set @ 4,527' MD / 2,613' TVD 4-1/2" 12.6# L-80 H563 Liner set @ 8,714' MD / 4,927' TVD CIBP / Whipstock @ 7,301' MD / 3,663' TVD Tubing cut pre- rig @ ~7500' MD Perfs @ 7,944' MD / 4,157' TVD to 7,953' MD / 4,166' TVD 7,957' MD / 4,170' TVD to 7,963' MD / 4,176' TVD Component Description MD (ft) TVD (ft) Length (ft) 7 5" x 15' Sealbore Extension 7,124' 3,595' 15' 8 4-1/2" x 7" Liner Top Packer / Hanger 7,140' 3,601' 10' 9 4-1/2" 3.813" XN Profile 7,170' 3,613' 4' 10 4-1/2" Float Collar + Landing Collar 8,829' 4,697' 4' 11 4-1/2" Float Shoe 8,712' 4,737' 3' Lower Completion Component Details 1 4 10-11 5 2 3 67 X N 8 4-1/2" 12.6# L-80 H563 Tubing seals @ 7,136' MD / 3,600' TVD Cement plug @ 9,292' MD (10/2/21) Upper Completion Component Details Lower Completion Component Details 9 X Confining Layer Top 6,500' MD / 3,358' TVD CONFIDENTIAL Report Start Date Report End Date Job Type Last 24hr Summary 12/7/2021 18:00 12/8/2021 17:00 SLICK- LINE SET CATCHER ON 3.81" NIPPLE @ 6994' RKB, PULLED SOV & REPLACED WITH DUMMY VALVE @ 2706' RKB, REPLACED DUMMY VALVE @ 6968' RKB ( BOTH W/ INCONEL RN ) OBTAINED PASSING MIT-T & MIT-IA , PULLED CATCHER @ 6994' RKB, TAGGED OBSTRUCTION @ 7141' RKB WITH 3" & 2.50" BAILERS ( ROCKS & MUD ) , READY FOR PLAN FORWARD. 12/10/2021 6:00 12/11/2021 0:00 SERVICE COIL TRAVEL TO 3S FROM DEADHORSE, MIRU, DIRFT COIL WITH 1.374" BALL. PERFORM WEEKLY BOP TEST, CLEANOUT WELL TO A HARD TAG @ 8600' CTMD. MADE SEVERAL ATTEMPTS TO GET DEEPER AND HAD HARD TAG @ SAME SPOT. JOB IN PROGRESS 12/11/2021 0:00 12/11/2021 8:00 SERVICE COIL RIH WITH 3.62" WHIPSTOCK DRIFT DOWN TO 8513' CTMD. CONFIRMED DEPTH WAS GOOD WITH TOWN ENG. READY FOR E-LINE. 12/11/2021 8:00 12/12/2021 23:45 E-LINE CEMENT EVALUATION OF 4.5" LINER FROM 8500-7120' MD REPEAT PASS THROUGH TOP OF CEMENT CEMENT FOUND UP TO 7124' MD READY FOR RST LOGGING *JOB IN PROGRESS* 12/12/2021 11:00 12/12/2021 23:30 E-LINE LOG RST SIGMA ON LOWER FORMATION FROM 8500-7665' MD TWO PASSES AT 900 FT/HR LAS FILES DELIVERED FOR CARBONRT READY FOR RST IC LOGGING *JOB IN PROGRESS* 12/16/2021 5:30 12/16/2021 18:15 E-LINE LOG RST IC ON LOWER FORMATION FROM 8500-7750' MD ONE PASS AT 200 FT/HR ***JOB IN PROGRESS*** 12/17/2021 5:30 12/17/2021 21:00 E-LINE ***JOB CONTINUED FROM 12/16/2021*** PERFORATE 7958'-7963' ON THIRD ATTEMPT. UNABLE TO REACH TARGET DEPTH ON FIRST TWO ATTEMPTS DUE TO DOGLEG SEVERITY AND TOOLSTRING CONBINATION. CCL TO TOP SHOT = 9.7', CCL STOP DEPTH = 7948.3'. ***JOB IN PROGRESS 12/18/2021 5:30 12/18/2021 15:30 E-LINE ***JOB CONTINUED FROM 12/17/2021*** GUN 2: PERFORATED INTERVAL = 7948' - 7953'. CCL TO TOP SHOT = 9.7', CCL STOP DEPTH = 7938.3'. GUN 3: PERFORATED INTERVAL = 7943' - 7948'. CCL TO TOP SHOT = 9.7', CCL STOP DEPTH = 7933.3'. NO CHANGE IN PRESSURE AFTER FIRING. ***JOB COMPLETE*** 12/18/2021 16:00 12/18/2021 20:00 E-LINE PRESSURE TEST IA & TBG INJECTIVITY TEST SEE LOG FOR PRESSURE TEST DATA PUMPED 20 BBLS DIESEL DOWN TBG FOR INJECTIVITY TEST JOB COMPLETE 12/19/2021 6:00 12/20/2021 1:30 STIMULA TION PERFORM DATA FRAC w/ X-LINKED FLUIDS. PERFORM 1 STAGE FRAC STIMULATION PER PLAN. PUMPED 290K lbs 16/20 CarboNRT UP TO 10 PPA & 50K lbs 12/18 CarboNRT UP TO 10 PPA. IN PROGRESS. 12/20/2021 5:30 12/21/2021 0:00 DHD STANDBY UNTIL 1900 WAITING FOR FRAC CREW TO RIG DOWN ENOUGH EQUIPMENT TO START RIGGING UP; BRUSH n' FLUSH TBG DOWN TO 7000' RKB; ATTEMPT TO SET 3.81 XX PLUG @ 6993' RKB (LOCK & PACKING HEAVILY SCARED FROM FRAC SAND). IN PROGRESS. 12/21/2021 5:30 12/21/2021 17:30 SLICK- LINE B&F X NIP @ 6993' RKB W/ SLICK DIESEL, ATTEMPT TO SET 3.81" XX PLUG @ 6993' RKB, PACKING SCARED FROM FRAC SAND. IN PROGRESS 12/24/2021 8:00 12/24/2021 21:00 SLICK- LINE SET 3.68" RBP MIDDLE ELEMENT @ 2768' RKB, PERFORM PASSING MIT-T TO 3000 PSI ON RBP, PERFORM DRAWDOWN TEST TO 0 PSI, SET 4.5" NG C-SUB @ 2762' RKB, PULL GLM # 1 BK-DGLV @ 2706' RKB, READY FOR DHD 12/25/2021 6:00 12/25/2021 18:00 DHD (SEC) DDT T X IA TO 0 PSI (PASSED). TEST BPV TO 1500 PSI (PASSED). T-POT (PASSED). T-PPPOT (PASSED). 12/26/2021 6:00 12/26/2021 19:00 DHD (SEC) DDT T X IA TO 0 PSI (PASSED). TREE & THA SWAP FROM 10K TO 5K (COMPLETE). REMOVED BPV. INSTALLED TWC. TREE SHELL TEST TO 5000 PSI (PASSED). T-POT (PASSED). T-PPPOT (PASSED). REMOVED TWC. READY FOR SLICKLINE. 12/29/2021 5:30 12/29/2021 17:00 SLICK- LINE SET DUMMY VALVE @ 2706' RKB, PULLED CATCHER @ 2768' RKB, (( SHUT DOWN -40 BELOW ON LOCATION )), IN PROGRESS. 12/30/2021 5:30 12/30/2021 20:00 SLICK- LINE PULLED 3.68" RBP @ 2768' RKB, SET 3.79" CATCHER ON XN NIPPLE @ 7170' RKB, MADE 1 ATTEMPT TO PULL DMY VLV @ 6968' RKB , SHUT DOWN DUE TO COLD WEATHER BELOW -40 , IN PROGRESS. 1/4/2022 5:30 1/4/2022 22:00 SLICK- LINE PULLED DV & SET OV @ 6967' RKB; ATTEMPT TO PULL CATCHER & ENCOUNTER SAND; BAIL FRAC SAND FROM 7164'-7170' RKB; PULLED CATCHER @ 7170' RKB; DRIFT W/ 2.5" BAILER & TAG @ 8251' RKB (UNABLE TO MAKE HOLE / BAILER FULL OF FRAC SAND). IN PROGRESS. 1/5/2022 5:30 1/5/2022 12:00 SLICK- LINE TAGGED FILL @ 8252' RKB W/ 3" BAILER (FRAC SAND) & UNABLE TO MAKE HOLE. DISCUSS WITH ENGINEER. READY FOR E-LINE. 3S-24B STIMULATION SUMMARY OF OPERATIONS CONFIDENTIAL !" ### ### $!"%& ' () ! " * + " " " " # # , " "! " " % % - " % . * .+ , * # #* "! / ! ! / / ! . ! "! " " / " !" ! " /" / " % "" ! * * . "" ! * * CONFIDENTIAL "" ! * * " ! " /"* ! " * $%,! " + + "! * *" -% " %% * - !0" " " ! " " % . , "" ! * * "" ! * * "" ! * * "" ! * * 1 $+,!/' (+ / " " *!" % " 2 +-'/ ( " /" / ! / *. " ! % . " " " " " * 31 2 $ % * "!/ CONFIDENTIAL . " ! "" /" " " " " 3" - *. ' 2 (31 2 $ " % % " "" " " 2 " ! // "* + * CONFIDENTIAL ! ! Schlumberger-Private FracCAT Treatment Report Well : 3S-24B Field : Kuparuk Formation : Coyote Well Location : Kuparuk County : North Slope Borough State : Alaska Prepared for Client : ConocoPhillips Client Rep : Kyle Hampton : ZJ Date Prepared : 12-20-2021 Prepared by Name : Zaid Al-Saadawi Phone : 832 805 8365 Pressures Initial Wellhead Pressure (psi)381 Maximum Treating Pressure (psi)2861 Final Surface ISIP (psi)950 Surface Shut in Pressure(psi)871 Calibration ISIP 965 Treatment Totals Total Slurry Pumped (bbl) 2814.8 Total Proppant Pumped (lbs.); From Load Tickets 340,431 Total YF125ST (bbl)2519.3 Total Carbo 16/20 (lbs)290,371 Total WF125 (bbl)209.7 Total Carbo 12/18 (lbs)50,060 Total Freeze Prote (bbl)85.8 Total Proppant in Formation (lbs.)338,336 Total Chemical Additives Invoiced Past WH Invoiced Past WH F103 (gal)91 91 J580 (lb)2520 2520 L065 (gal)189 189 J532 (gal)529 529 J511 (gal)317 317 J318 (gal)43 43 J218 (lb)220 192.5 Freeze Protect(bbl)120 - M275 (lb)42 42 Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The inform ation presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is a ware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. CONFIDENTIAL Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Executive Summary: On December 19 th Schlumberger performed a propped frac treatment on ConocoPhillips Alaska’s 3S-24B well. This was a new sidetrack drilled between Nov/Dec 2021 and the first well within Conoco’s Coyote field. Pumps were primed and the crew had a successful pressure test by 16:30. After the safety meeting, the crew started mixing 25ppt gel and the well was opened at 18:25 to begin injection and DataFrac. During the DataFrac, fluids looked good and crosslink gel was displaced to the perforations as the surface lines were freeze protected before shutting down the pumps. Pressures were monitored for approximately 60 minutes. DataFrac analysis resulted in the decision to increase main treatment pad size from 440 bbls to 715 bbls. The main frac went smooth on surface, and the fluids continued to look good for each sample taken. Proppant was stepped up from 1 to 10 PPA. Surface treating pressure trended downward (below 2000 psi) until the change from 9 PPA to 10 PPA. Once 10 PPA hit perforations, pressure trended upwards, and decision was made to reduce rate slightly to accommodate the trend change. The ~600 psi pressure spike during 10 PPA sand step may be attributed to proppant bridging briefly before breaking over again. Once all proppant was pumped from blender, rate was increased back to 25 bpm to complete flush. Proppant was under-flushed with a freeze protect cap to prevent freezing of surface lines and upper 2500 ft of well. CONFIDENTIALntnt:: ConocoPhillipsConocoPhillip Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Section 1: Designed Pump Schedule Designed Pump Schedule Ramp Step #Step Name Slurry Volume (bbl) Pump Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Prop Name Prop Conc (PPA) Prop Mass (lb) 1 XL Check 20.0 15.0 1.3 YF125ST - J532 (6), J218(2)840 0.0 0 2 MiniFrac 150.0 25.0 6.0 YF125ST - J532 (6), J218(2)6300 0.0 0 3 Flush 95.0 25.0 3.8 WF125 - J218(2)3990 0.0 0 4 Freeze Prote 25.0 25.0 1.0 Freeze protect 1050 0.0 0 5 60 min/Shut-0.0 0.0 0.0 WF125 - J218(2)0 0.0 0 6 XL Check 20.0 22.0 0.9 YF125ST - J532 (6), J218(2)840 0.0 0 7 PAD 715.0 25.0 28.6 YF125ST - J532 (6), J218(2)30030 0.0 0 8 1.0 PPA 100.0 25.0 4.0 YF125ST - J532 (6), J218(2)4022 16/20 C-Lite 1.0 4022 9 2.0 PPA 99.9 25.0 4.0 YF125ST - J532 (6), J218(2)3858 16/20 C-Lite 2.0 7716 10 4.0 PPA 179.8 25.0 7.2 YF125ST - J532 (6), J218(2)6422 16/20 C-Lite 4.0 25688 11 6.0 PPA 184.6 25.0 7.4 YF125ST - J532 (6), J218(2)6138 16/20 C-Lite 6.0 36828 12 7.0 PPA 299.4 25.0 12.0 YF125ST - J532 (6), J218(2)9618 16/20 C-Lite 7.0 67326 13 8.0 PPA 279.3 25.0 11.2 YF125ST - J532 (6), J218(2)8683 16/20 C-Lite 8.0 69464 14 9.0 PPA 199.5 25.0 8.0 YF125ST - J532 (6), J218(2)6006 16/20 C-Lite 9.0 54054 15 10.0 PPA 119.7 25.0 4.8 YF125ST - J532 (6), J218(2)3493 16/20 C-Lite 10.0 25273 16 10.0 PPA 171.5 25.0 6.9 YF125ST - J532 (6), J218(2)5006 12/18 C-Lite 10.0 50060 17 Flush 58.0 25.0 2.3 WF125 - J218(2)2436 0.0 0 18 Freeze Prote 60.0 25.0 2.4 Freeze protect 2520 0.0 0 Designed Ramp Totals Slurry (bbl) Pump Time (min) Clean Fluid (gal) Proppant (lb) 2776.6 111.7 101252 350088 CONFIDENTIALntnt:: ConocoPhillipsConocoPhillip Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Section 2: As Measured Pump Schedule As Measured Pump Schedule Step # Step Name Slurry Volume (bbl) Slurry Rate (bbl/min) Pump Time (min) Fluid Name Fluid Volume (gal) Proppant Name Max Prop Conc (PPA) Prop Conc (PPA) Prop Mass (lb) 1 LG 30.5 7.2 4.2 WF125 - J218(2)1281 0.0 0.0 0.0 2 XL Check 22.5 7.2 3.1 YF125ST - J532 (6), J218(2)945 0.0 0.0 0 3 MiniFrac 155 16.8 9.2 YF125ST - J532 (6), J218(2)6510 0.0 0.0 0 4 Flush 96 24.8 3.9 WF125 - J218(2)4032 0.0 0.0 0 5 Freeze Prote 25.9 24.3 1.1 Freeze protect 1087.8 0.0 0.0 0 6 LG 25.2 8.0 3.2 WF125 - J218(2)1058.4 0.0 0.0 0.0 7 XL Check 12.8 8.0 1.6 YF125ST - J532 (6), J218(2)537.6 0.0 0.0 0 8 PAD 715.0 25.0 28.6 YF125ST - J532 (6), J218(2)30030 0.0 0.0 0 9 1.0 PPA 100.0 24.8 4.0 YF125ST - J532 (6), J218(2)4200 16/20 C-Lite 1.0 1.0 3916 10 2.0 PPA 99.9 24.9 4.0 YF125ST - J532 (6), J218(2)4195.8 16/20 C-Lite 2.1 1.9 7529 11 4.0 PPA 179.8 24.8 7.3 YF125ST - J532 (6), J218(2)7551.6 16/20 C-Lite 4.2 4.0 25415 12 6.0 PPA 184.6 24.7 7.5 YF125ST - J532 (6), J218(2)7753.2 16/20 C-Lite 6.2 5.9 36549 13 7.0 PPA 299.4 24.7 12.1 YF125ST - J532 (6), J218(2)12574.8 16/20 C-Lite 7.2 7.0 67152 14 8.0 PPA 279.3 24.7 11.3 YF125ST - J532 (6), J218(2)11730.6 16/20 C-Lite 8.2 8.0 69401 15 9.0 PPA 199.5 24.6 8.1 YF125ST - J532 (6), J218(2)8379 16/20 C-Lite 9.3 9.0 53970 16 10.0 PPA 85.4 24.5 3.5 YF125ST - J532 (6), J218(2)3586.8 16/20 C-Lite 10.2 9.9 24702 17 10.0 PPA 186.1 23.3 8.0 YF125ST - J532 (6), J218(2)7816.2 12/18 C-Lite 10.3 9.4 51797 18 Flush 58.0 25.3 2.3 WF125 - J218(2)2436 0.0 0.0 0 19 Freeze Prote 59.9 22.7 2.6 Freeze protect 2515.8 0.0 0.0 0 Stage Pressures & Rates Step #Step Name Average Slurry Rate (bbl/min) Maximum Slurry Rate (bbl/min) Average Treating Pressure (psi) Maximum Treating Pressure (psi) Minimum Treating Pressure (psi) 1 LG 7.2 14.8 1226 1455 98 2 XL Check 7.2 14.8 1226 1455 98 3 MiniFrac 16.8 24.9 1623 1980 1414 4 Flush 24.8 25.0 1766 1905 1038 5 Freeze Prote 24.3 24.8 1330 1725 332 6 LG 8.0 20.2 1182 1570 365 7 XL Check 8.0 20.2 1182 1570 365 8 PAD 25.0 25.3 1842 1970 1505 9 1.0 PPA 24.8 25.1 1825 1847 1803 10 2.0 PPA 24.9 25.1 1819 1846 1796 11 4.0 PPA 24.8 25.1 1811 1847 1792 12 6.0 PPA 24.7 25.0 1767 1805 1744 13 7.0 PPA 24.7 24.9 1732 1762 1706 14 8.0 PPA 24.7 24.8 1676 1716 1649 15 9.0 PPA 24.6 24.8 1661 1684 1634 16 10.0 PPA 24.5 24.7 1628 1666 1594 17 10.0 PPA 23.3 24.4 1847 2861 1564 18 Flush 25.3 25.5 2219 2286 2059 19 Freeze Prote 22.7 25.3 1790 2056 7 CONFIDENTIALntnt:: ConocoPhillipsConocoPhillip Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private As Measured Totals Slurry (bbl) Pump Time (min) Clean Fluid (bbl) Proppant (lb) 2814.8 129.0 2459.1 340431 Average Treating Pressure:1753 psi Maximum Treating Pressure:2861 psi Minimum Treating Pressure:7psi Average Injection Rate:23.7 bbl/min Maximum Injection Rate:25.5 bbl/min Average Horsepower:1028.7 hhp Maximum Horsepower:1628.5 hhp Maximum Prop Concentration:10.3 PPA Section 3: Fluid Description Fluid Name: YF125ST - J532 (6), J218(2) Additive Name Additive Type Solid Conc (lb/mgal) Liquid Conc (gal/mgal) J580, Gelling Agent GELLINGAGT 25.0 M275, Microbiocide BIOCIDE 0.3 F103, EZEFLO Surfactant SURFACTANT 1.0 L065, Scale Inhibitor INHIBITORAID 2.0 J318, Liquid Breaker Aid BREAKERAID 0.5 J511, Stabilizer STABILIZER 3.4 J218, Breaker BREAKER 2.0 J532, Borate Crosslinker CROSSLINKER 6.0 Fluid Name: WF125 - J218(2) Additive Name Additive Type Solid Conc (lb/mgal) Liquid Conc (gal/mgal) J580, Gelling Agent GELLINGAGT 25.0 M275, Microbiocide BIOCIDE 0.3 F103, EZEFLO Surfactant SURFACTANT 1.0 L065, Scale Inhibitor INHIBITORAID 2.0 J318, Liquid Breaker Aid BREAKERAID 0.5 J511, Stabilizer STABILIZER 3.4 J218, Breaker BREAKER 2.0 Section 4: Proppant Description Proppant Proppant Name Mesh Size Spec Gravity Prop Fric Coeff. Laminar Prop Fric Coeff. Turbulent 16/20 C-Lite 16/20 2.73 1.00 0.85 12/18 C-Lite 12/18 2.73 1.00 0.90 CONFIDENTIALntnt:: ConocoPhillipsConocoPhillip Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Section 5: Perforations Perforations Top MD (ft) Top TVD (ft) Bottom MD (ft) Bottom TVD (ft) Shot Density (shot/ft)Number Diameter (in) 7944.0 4157.3 7953.0 4166.3 6.00 54 0.38 7957.0 4170.3 7963.0 4176.3 6.00 36 0.38 Section 6: Frac 3S-24B, Propped Frac: Job Messages Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 1 Reset Executed Steps 0 0 0.0 0.0 0.0 2 Reset Executed Steps 0 0 0.0 0.0 0.0 3 14:08:41 Start Priming up pumps 47 293 0.0 0.0 0.0 4 14:54:50 Test Pop Off 1301 2 0.0 0.0 0.0 5 14:58:35 POP Off went 6041 1 0.0 0.0 0.0 6 15:54:25 Test pop Off 2 4238 226 0.0 0.0 0.0 7 16:42:56 Good PT 37 226 0.0 0.0 0.0 8 18:28:25 Start XL Check Automatically 97 211 0.0 0.0 0.0 9 18:28:25 Start Propped Frac Automatically 97 211 0.0 0.0 0.0 10 18:28:25 Start Frac 3S-24B Automatically 97 211 0.0 0.0 0.0 11 18:28:49 Started Pumping 98 211 0.0 0.0 0.0 12 18:29:13 Activated Extend Stage 98 211 0.0 0.0 0.0 13 18:33:46 Opening Well 498 1465 0.0 0.0 0.0 14 18:58:48 Deactivated Extend Stage 1454 2105 52.1 14.9 0.0 15 18:58:48 Start MiniFrac Manually 1454 2105 52.1 14.9 0.0 16 19:04:29 Stage at Perfs: XL Check 1585 2274 133.2 15.2 0.0 17 19:07:25 Stage at Perfs: MiniFrac 1953 2283 185.2 24.9 0.0 18 19:08:06 Start Flush Automatically 1897 2268 202.2 24.9 0.0 19 19:11:00 Activated Extend Stage 1706 2238 274.4 24.7 0.0 20 19:12:08 Deactivated Extend Stage 1755 2219 302.4 25.0 0.0 21 19:12:08 Start Flush Manually 1755 2219 302.4 25.0 0.0 22 21:04:35 Started Pumping 331 1975 331.0 0.0 0.0 23 21:05:57 Start XL Check Manually 364 1974 331.1 0.0 0.0 24 21:06:53 Stage at Perfs: Flush 1088 2044 335.1 6.1 0.0 25 21:06:56 Activated Extend Stage 1090 2042 335.4 6.1 0.0 26 21:19:20 Deactivated Extend Stage 1505 2065 370.1 20.0 0.0 27 21:19:20 Start PAD Manually 1505 2065 370.1 20.0 0.0 28 21:22:07 Stage at Perfs: Flush 1826 2143 435.7 25.1 0.0 29 21:23:15 Stage at Perfs: PAD 1701 2023 464.2 25.2 0.0 30 21:24:48 Stage at Perfs: Flush 1726 2160 503.3 25.2 0.0 31 21:47:58 Start 1.0 PPA Automatically 1848 2175 1085.3 25.2 0.0 32 21:47:58 Started Pumping Prop 1848 2175 1085.3 25.2 0.0 33 21:52:00 Start 2.0 PPA Automatically 1822 2185 1185.3 24.8 1.1 34 21:53:21 Stage at Perfs: 2.0 PPA 1805 2193 1218.6 24.8 1.9 35 21:56:01 Start 4.0 PPA Automatically 1840 2117 1285.2 24.9 2.0 36 21:57:21 Stage at Perfs: 4.0 PPA 1798 2134 1318.4 24.9 4.0 37 22:01:23 Stage at Perfs: XL Check 1812 2130 1418.4 24.8 4.1 38 22:03:16 Start 6.0 PPA Automatically 1794 2128 1465.0 24.8 4.2 39 22:08:39 Stage at Perfs: PAD 1745 2229 1598.3 24.6 6.0 ntnt:: ConocoPhillipsConocoPhillip Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Message Log #Time Message Treating Pressure (psi) Annulus Pressure (psi) Total Slurry (bbl) Slurry Rate (bbl/min) Prop. Conc. (PPA) 40 22:10:44 Start 7.0 PPA Automatically 1746 2244 1649.8 25.0 6.1 41 22:16:06 Stage at Perfs: 1.0 PPA 1742 2229 1782.7 24.6 7.0 42 22:22:51 Start 8.0 PPA Automatically 1710 2205 1949.1 24.9 7.0 43 22:28:15 Stage at Perfs: 2.0 PPA 1662 2203 2082.4 24.7 7.9 44 22:34:11 Start 9.0 PPA Automatically 1647 2207 2228.5 24.6 7.9 45 22:39:36 Stage at Perfs: 4.0 PPA 1690 2252 2361.4 24.6 9.1 46 22:42:18 Start 10.0 PPA Automatically 1659 2238 2427.8 24.6 9.1 47 22:43:19 Activated Extend Stage 1647 2229 2452.8 24.2 10.1 48 22:45:47 Deactivated Extend Stage 1608 2189 2513.0 24.4 10.0 49 22:45:47 Start 10.0 PPA Manually 1608 2189 2513.0 24.4 10.0 50 22:47:49 Stage at Perfs: 10.0 PPA 1603 2217 2560.8 23.2 10.2 51 22:48:36 Activated Extend Stage 1658 2202 2579.0 23.5 10.2 52 22:51:30 Stage at Perfs: 7.0 PPA 1797 2207 2646.2 23.3 10.1 53 22:53:46 Deactivated Extend Stage 2242 2189 2699.1 24.8 -0.0 54 22:53:46 Start Flush Manually 2242 2189 2699.1 24.8 -0.0 55 22:55:47 Stopped Pumping Prop 2097 2231 2750.1 25.2 -0.1 56 22:56:04 Start Freeze Prote Automatically 2046 2242 2757.3 25.2 0.0 57 22:56:52 Activated Extend Stage 1803 2257 2777.3 23.4 0.0 CONFIDENTIALntnt:: ConocoPhillipsConocoPhillip Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Section 7: Frac 3S-24B, Propped Frac: Post Job GORV test 14:52:00 15:25:20 15:58:40 16:32:00 17:05:20 Time - hh:mm:ss 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 TR _ P R E S S 2 - p s i 0 5 10 15 20 25 Sl u r r y R a t e - b b l / m i n TR_PRESS AN_PRESS BH_PRESS POP_OFF SLUR_RATE FracCAT* © Schlumberger 1994-2016 ConocoPhillips 3S-24B 12-19-2021 Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Section 8: Frac 3S-24B, Propped Frac: Post Job Pressure test 16:24:04 16:29:04 16:34:04 16:39:04 16:44:04 Time - hh:mm:ss 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 TR _ P R E S S 2 - p s i 0 5 10 15 20 25 Sl u r r y R a t e - b b l / m i n TR_PRESS AN_PRESS BH_PRESS POP_OFF SLUR_RATE FracCAT* © Schlumberger 1994-2016 ConocoPhillips 3S-24B 12-19-2021 Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Section 9: Frac 3S-24B, Propped Frac: Post Job Data FRAC 18:43:13 19:16:33 19:49:53 20:23:13 20:56:33 Time - hh:mm:ss 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 TR _ P R E S S 2 - p s i 0 5 10 15 20 25 30 Sl u r r y R a t e - b b l / m i n 0 2 4 6 8 10 12 Y- A x i s TR_PRESS AN_PRESS BH_PRESS POP_OFF SLUR_RATE FracCAT* © Schlumberger 1994-2016 ConocoPhillips 3S-24B 12-19-2021 Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Section 10: Frac 3S-24B, Propped Frac: Post Job PRC 21:10:57 21:40:07 22:09:17 22:38:27 23:07:37 Time - hh:mm:ss 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 TR _ P R E S S 2 - p s i 0 5 10 15 20 25 30 Sl u r r y R a t e - b b l / m i n 0 2 4 6 8 10 12 Pr o p C o n - P P A TR_PRESS AN_PRESS BH_PRESS POP_OFF SLUR_RATE PROP_CON BH_PROP_CON FracCAT* © Schlumberger 1994-2016 ConocoPhillips 3S-24B 12-19-2021 Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Section 11: Frac 3S-24B, Propped Frac: Additives Plot 21:10:57 21:40:07 22:09:17 22:38:27 23:07:37 Time - hh:mm:ss 0 5 10 15 20 25 J5 8 0 _ C O N - l b / m g a l 0 1 2 3 4 5 6 7 J2 1 8 _ C O N C - l b / m g a l 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 J3 1 8 _ C O N C - g a l / m g a l 0 1 2 3 4 5 6 7 J5 3 2 _ C O N C - g a l / m g a l J580_CON J218_CONC J511_CONC F103_CONC L065_CONC J318_CONC J532_CONC FracCAT* © Schlumberger 1994-2016 ConocoPhillips 3S-24B 12-19-2021 Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Section 12: Frac 3S-24B, Propped Frac: Post Job Nolte Smith Plot 1101001000 Nolte Smith Time - min 1 10 100 1000 10000 Ne t P r e s s u r e - p s i Net Pressure Closure Pressure = 2447 psi Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Section 13: Frac 3S-24B, Propped Frac: Post Job Prop Monitoring Panel 0 500 1000 1500 2000 2500 3000 Cumulative Slurry Volume - bbl 0 2 4 6 8 10 12 Pr o p p a n t C o n c e n t r a t i o n - P P A Ramp Proppant Conc. FracCAT* © Schlumberger 1994-2016 Post Job Proppant Monitoring Plot ConocoPhillips3S-24B12-19-2021 Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private Section 14: Job Timeline December 8th – December 18 th Date Description 8-Dec Mobilize frac tanks to location 9-Dec Mobilize sand chiefs to location; Lynden begin loading proppant 10-Dec Frac Test Corva/BHP gauge connectivity 11-Dec CTU14 on 3S-24B for FCO 12-Dec SLB WL arrive from Alpine for RST logging run Frac COP Safety Orientation (all day) 13-Dec WL down on weather, unable to perform 2nd logging run FWOP in afternoon 14-Dec WL pending weather for 2nd logging run Frac down on weather 15-Dec WL pending weather for 2nd logging run Frac down on weather 16-Dec WL rigging up for 2nd logging run Frac given clear to mobilize remaining equipment begin tripping equipment from Deadhorse (FracCAT + 5 pumps) 17-Dec WL RIH perforating guns (2 of 3 runs) Frac mobilize all remaining equipment Herculite laid out for frac pumps 18-Dec WL RIH for final perforating run Frac rig up as much as possible backside and most of front side - (WL preventing them from rigging to WH and spotting pop off tank) Herculite CONFIDENTIALnocoPhillipsnocoPhillip Client: ConocoPhillips Well: 3S-24B District: Kuparuk Country: United States Schlumberger-Private December 19th – Pumping Day Timeline Date Time Description 19-Dec 5:30 arrive to location, pending crane for rig up to WH (Pumping Day)8:30 rig up stand pipe to WH Start warming equipment onsite lab analysis (water, linear gel, xlink) Spot/rig up flush transport, LAS, heaters Rig up FracCAT cables/transducers to nearby wells and acquisiton testing 14:00 begin priming pumps L065 spill cleanup occurred during this period into secondary contaiment 16:15 Start PT set @7600 psi 16:30 Good PT 7350 psi 16:35 Safety meeting, Set POP off 5890 psi 17:15 Start mixing gel, troubleshooting PCM, test Gel Good 25 ppt 19 cp, 79F, 18:15 Set IA 1500 psi, OA 14 psi 18:25 Equalize the WH 500 psi, Opened WH dropped to 381 psi 18:27 Open well 18:27 Pumped 25 LG of 30.5 bbl 18:33 Shutdown for 15 min 18:49 Performed Data Frac, ISIP 2725 psi, Pc 2697 psi, Tc 2.3 min, E 30%, P net xx psi, P res 1831 psi pumped 156 bbl XL, 117.5 bbl LG, 25 bbl D, 330.9 bbl total 19:13 Shutdown for 60 min 20:46 Prime pumps 21:00 displace fluid 21:05 shutdown 10 min 21:15 Start Frac Stage 1 open well 364 psi 22:52 Finish Frac Stage 1, 2814.8 bbl Slurry Vol, 2459.2 bbl CFLD Vol, bbl XL Vol, K ib Prop 16/20 Carbo 23:35 ISIP 15 min, Secured the well 23:50 Bleed the lines and freeze protect the equipments 20-Dec 2:30 Leave location via COP bus pick up to KCC CONFIDENTIALnocoPhillipsnocoPhillip Hydraulic Fracturing Fluid Product Component Information Disclosure Hydraulic Fracturing Fluid Composition: Job Start Date:12/19/2021 Job End Date:12/19/2021 State:Alaska County:Harrison Bay API Number:50-103-20456-02-00 Operator Name:ConocoPhillips Company/Burlington Resources Well Name and Number:3S-24B Latitude:70.39433000 Longitude:-150.19532300 Datum:NAD27 Federal Well:NO Indian Well:NO True Vertical Depth:4,936 Total Base Water Volume (gal):113,942 Total Base Non Water Volume:0 Trade Name Supplier Purpose Ingredients Chemical Abstract Service Number (CAS #) Maximum Ingredient Concentration in Additive (% by mass)** Maximum Ingredient Concentration in HF Fluid (% by mass)** Comments Fluid Schlumberger N/A Water (Including Mix Water Supplied by Client)* 7732-18-5 73.27597 S522-1620 Schlumberger Propping Agent Listed Below J318 Schlumberger Breaker Aid Listed Below F103 Schlumberger Surfactant Listed Below S522-1218 Schlumberger Propping Agent Listed Below J532 Schlumberger Crosslinker Listed Below M275 Schlumberger Bactericide Listed Below L065 Schlumberger Scale Inhibitor Listed Below J218 Schlumberger Breaker J218 Listed Below J580 Schlumberger Gel J580 Listed Below Ceramic materials and wares, chemicals 66402-68-4 98.16497 26.23364 Items above are Trade Names with the exception of Base Water . Items below are the individual ingredients. Guar gum 9000-30-0 0.72484 0.19371 1, 2, 3 - Propanetriol 56-81-5 0.30919 0.08263 Sodium tetraborate decahydrate 1303-96-4 0.25248 0.06747 Ethylene glycol 107-21-1 0.10806 0.02888 2-Propenoic acid, polymer with sodium phosphinate 129898-01-7 0.10108 0.02701 2,2`,2"-nitrilotriethanol 102-71-6 0.09675 0.02586 Diammonium peroxidisulphate 7727-54-0 0.05565 0.01487 Propan-2-ol 67-63-0 0.04104 0.01097 2-butoxyethanol 111-76-2 0.04104 0.01097 Ethoxylated C11 Alcohol 34398-01-1 0.03769 0.01007 Ethoxylated Alcohol 68131-39-5 0.02046 0.00547 Sodium chloride 7647-14-5 0.02041 0.00545 Calcium Chloride 10043-52-4 0.01032 0.00276 Diatomaceous earth, calcined 91053-39-3 0.00606 0.00162 Undecanol 112-42-5 0.00328 0.00088 Non-crystalline silica (impurity) 7631-86-9 0.00182 0.00049 Magnesium nitrate 10377-60-3 0.00121 0.00032 2,2''-oxydiethanol (impurity) 111-46-6 0.00109 0.00029 5-chloro-2-methyl-4- isothiazolin-3-one and 2- methyl-4-isothiazolin-3- one 55965-84-9 0.00073 0.00019 Magnesium chloride 7786-30-3 0.00061 0.00016 Sodium hydroxide (impurity) 1310-73-2 0.00055 0.00015 Potassium chloride (impurity) 7447-40-7 0.00033 0.00009 Acetic acid, potassium salt 127-08-2 0.00012 0.00003 Cristobalite 14464-46-1 0.00012 0.00003 * Total Water Volume sources may include various types of water including fresh water, produced water, and recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100% *** If you are calculating a percentage of total ingredients do not add the water volume below the green line to the water volume above the green line Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided. Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS) Quartz, Crystalline silica 14808-60-7 0.00012 0.00003 Acetic acid (impurity)64-19-7 0.00002 0.00001 Production Month: Jan - 2022 CONOCOPHILLIPS ALASKA INC Alaska Oil And Gas Conservation Commission Monthly Production Report Form : 10-405 Operator: ConocoPhillips Alaska Inc. Field Name Kuparuk River/UndefinedField Name Kuparuk River/Undefined Well Number Api Number Cmp Type Field Code Prod Method Prod Days Tbg Press Average Daily Oil Daily Water Daily Gas Total Oil Total Water Total Gas 3S-24B 501032045602 1 490180 2 15 95 358 156 748 5,363 2,347 11,217 Sum:5,363 2,347 11,217 This report is confidential and proprietary to ConocoPhillips Alaska, Inc. and not subject to disclosure because it contains information or data that is (1) trade secret information as defined in AS 45.50.940(3) and State v. Arctic Slope Regional Corp., 834 P.2d 123 (Alaska 1991); (2) data required to be held confidential under AS 38.05.035(a)(8), AS 31.05.035(c), AS 43.05.230, and AS 40.25.100(a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y Samantha Carlisle at 8:52 am, Jan 18, 2022 5%'06 +(: &': '65 AOGCC ŽŵƉŽŶĞŶƚĞƐĐƌŝƉƚŝŽŶ D;ĨƚͿ ds;ĨƚͿ >ĞŶŐƚŚ;ĨƚͿ ϭ ϰͲϭͬϮΗǆϭΗ<'ͲϰͲϱͲ^s Ϯ͕ϲϵϲΖ ϭ͕ϵϯϵΖ ϭϬΖ Ϯ ϰͲϭͬϮΗǆϭΗ<'ͲϰͲϱͲs ϲ͕ϵϲϴΖ ϯ͕ϱϯϲΖ ϭϬΖ ϯ ϰͲϭͬϮΗϯ͘ϴϭϯΗyWƌŽĨŝůĞ ϲ͕ϵϵϰΖ ϯ͕ϱϰϲΖ ϱΖ ϰ ϰͲϭͬϮΗϯ͘ϴϭϯΗyWƌŽĨŝůĞ ϳ͕ϬϵϮΖ ϯ͕ϱϴϯΖ ϱΖ ϱ ^>DĞƚƌŝƐǀŽůǀĞϭϬŬ'ĂƵŐĞ ϳ͕ϭϬϵΖ ϯ͕ϱϴϵΖ ϱΖ ϲ ϱΗKƵůůĞƚ^ĞĂůƐƐĞŵďůǇ ϳ͕ϭϮϴΖ ϯ͕ϱϵϳΖ ϭϱΖ ò´/6/+7/LQHU# 0' 79' SSI+ ,QVXODWHG&RQGXFWRU # 0'79' /%7&0,QWHUPHGLDWH FDVLQJ# 0' 79' 7RS&R\RWH 0' 79' 6%6LGHWUDFN6FKHPDWLF y */*/ */*/ /LQHU7RS3DFNHU# 0' /%7& 6XUIDFH&DVLQJVHW# 0' 79' /+ /LQHUVHW# 0' 79' &,%3:KLSVWRFN # 0' 79' 7XELQJFXWSUH ULJ#a 0' 3HUIV# 0' 79'WR 0' 79' 0' 79'WR 0' 79' ŽŵƉŽŶĞŶƚĞƐĐƌŝƉƚŝŽŶ D;ĨƚͿ ds;ĨƚͿ >ĞŶŐƚŚ;ĨƚͿ ϳ ϱΗǆϭϱΖ^ĞĂůďŽƌĞǆƚĞŶƐŝŽŶ ϳ͕ϭϮϰΖ ϯ͕ϱϵϱΖ ϭϱΖ ϴ ϰͲϭͬϮΗǆϳΗ>ŝŶĞƌdŽƉWĂĐŬĞƌͬ,ĂŶŐĞƌ ϳ͕ϭϰϬΖ ϯ͕ϲϬϭΖ ϭϬΖ ϵ ϰͲϭͬϮΗϯ͘ϴϭϯΗyEWƌŽĨŝůĞ ϳ͕ϭϳϬΖ ϯ͕ϲϭϯΖ ϰΖ ϭϬ ϰͲϭͬϮΗ&ůŽĂƚŽůůĂƌн>ĂŶĚŝŶŐŽůůĂƌ ϴ͕ϴϮϵΖ ϰ͕ϲϵϳΖ ϰΖ ϭϭ ϰͲϭͬϮΗ&ůŽĂƚ^ŚŽĞ ϴ͕ϳϭϮΖ ϰ͕ϳϯϳΖ ϯΖ >ŽǁĞƌŽŵƉůĞƚŝŽŶŽŵƉŽŶĞŶƚĞƚĂŝůƐ ϭ ϰ ϭϬͲϭϭ ϱ Ϯ ϯ ϲϳ y E ϴ /+ 7XELQJVHDOV# 0' 79' &HPHQWSOXJ# 0' hƉƉĞƌŽŵƉůĞƚŝŽŶŽŵƉŽŶĞŶƚĞƚĂŝůƐ >ŽǁĞƌŽŵƉůĞƚŝŽŶŽŵƉŽŶĞŶƚĞƚĂŝůƐ ϵ y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ƉƌŽƚĞĐƚĞĚďĞĨŽƌĞƐŚƵƚƚŝŶŐĚŽǁŶƚŚĞƉƵŵƉƐ͘WƌĞƐƐƵƌĞƐǁĞƌĞŵŽŶŝƚŽƌĞĚĨŽƌĂƉƉƌŽǆŝŵĂƚĞůǇϲϬŵŝŶƵƚĞƐ͘ĂƚĂ&ƌĂĐĂŶĂůǇƐŝƐƌĞƐƵůƚĞĚ ŝŶƚŚĞĚĞĐŝƐŝŽŶƚŽŝŶĐƌĞĂƐĞŵĂŝŶƚƌĞĂƚŵĞŶƚƉĂĚƐŝǌĞĨƌŽŵϰϰϬďďůƐƚŽϳϭϱďďůƐ͘ dŚĞŵĂŝŶĨƌĂĐǁĞŶƚƐŵŽŽƚŚŽŶƐƵƌĨĂĐĞ͕ĂŶĚƚŚĞĨůƵŝĚƐĐŽŶƚŝŶƵĞĚƚŽůŽŽŬŐŽŽĚĨŽƌĞĂĐŚƐĂŵƉůĞƚĂŬĞŶ͘WƌŽƉƉĂŶƚǁĂƐƐƚĞƉƉĞĚƵƉ ĨƌŽŵϭƚŽϭϬWW͘^ƵƌĨĂĐĞƚƌĞĂƚŝŶŐƉƌĞƐƐƵƌĞƚƌĞŶĚĞĚĚŽǁŶǁĂƌĚ;ďĞůŽǁϮϬϬϬƉƐŝͿƵŶƚŝůƚŚĞĐŚĂŶŐĞĨƌŽŵϵWWƚŽϭϬWW͘KŶĐĞϭϬ WWŚŝƚƉĞƌĨŽƌĂƚŝŽŶƐ͕ƉƌĞƐƐƵƌĞƚƌĞŶĚĞĚƵƉǁĂƌĚƐ͕ĂŶĚĚĞĐŝƐŝŽŶǁĂƐŵĂĚĞƚŽƌĞĚƵĐĞƌĂƚĞƐůŝŐŚƚůǇƚŽĂĐĐŽŵŵŽĚĂƚĞƚŚĞƚƌĞŶĚ ĐŚĂŶŐĞ͘dŚĞΕϲϬϬƉƐŝƉƌĞƐƐƵƌĞƐƉŝŬĞĚƵƌŝŶŐϭϬWWƐĂŶĚƐƚĞƉŵĂǇďĞĂƚƚƌŝďƵƚĞĚƚŽƉƌŽƉƉĂŶƚďƌŝĚŐŝŶŐďƌŝĞĨůǇďĞĨŽƌĞďƌĞĂŬŝŶŐ ŽǀĞƌĂŐĂŝŶ͘KŶĐĞĂůůƉƌŽƉƉĂŶƚǁĂƐƉƵŵƉĞĚĨƌŽŵďůĞŶĚĞƌ͕ƌĂƚĞǁĂƐŝŶĐƌĞĂƐĞĚďĂĐŬƚŽϮϱďƉŵƚŽĐŽŵƉůĞƚĞĨůƵƐŚ͘WƌŽƉƉĂŶƚǁĂƐ ƵŶĚĞƌͲĨůƵƐŚĞĚǁŝƚŚĂĨƌĞĞǌĞƉƌŽƚĞĐƚĐĂƉƚŽƉƌĞǀĞŶƚĨƌĞĞǌŝŶŐŽĨƐƵƌĨĂĐĞůŝŶĞƐĂŶĚƵƉƉĞƌϮϱϬϬĨƚŽĨǁĞůů͘ ůŝĞŶƚ͗ŽŶŽĐŽWŚŝůůŝƉƐ tĞůů͗ϯ^ͲϮϰ ŝƐƚƌŝĐƚ͗<ƵƉĂƌƵŬ ŽƵŶƚƌǇ͗hŶŝƚĞĚ^ƚĂƚĞƐ ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ^ĞĐƚŝŽŶϭ͗ĞƐŝŐŶĞĚWƵŵƉ^ĐŚĞĚƵůĞ ĞƐŝŐŶĞĚWƵŵƉ^ĐŚĞĚƵůĞZĂŵƉ ^ƚĞƉ η^ƚĞƉEĂŵĞ ^ůƵƌƌǇ sŽůƵŵĞ ;ďďůͿ WƵŵƉZĂƚĞ ;ďďůͬŵŝŶͿ WƵŵƉ dŝŵĞ ;ŵŝŶͿ &ůƵŝĚEĂŵĞ &ůƵŝĚ sŽůƵŵĞ ;ŐĂůͿ WƌŽƉEĂŵĞWƌŽƉŽŶĐ ;WWͿ WƌŽƉDĂƐƐ ;ůďͿ ϭy>ŚĞĐŬϮϬ͘Ϭϭϱ͘Ϭ ϭ͘ϯz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϴϰϬϬ͘ϬϬ ϮDŝŶŝ&ƌĂĐϭϱϬ͘ϬϮϱ͘Ϭ ϲ͘Ϭz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϲϯϬϬϬ͘ϬϬ ϯ&ůƵƐŚϵϱ͘ϬϮϱ͘Ϭ ϯ͘ϴt&ϭϮϱͲ:Ϯϭϴ;ϮͿϯϵϵϬϬ͘ϬϬ ϰ&ƌĞĞǌĞ WƌŽƚĞϮϱ͘ϬϮϱ͘Ϭ ϭ͘Ϭ&ƌĞĞǌĞƉƌŽƚĞĐƚϭϬϱϬϬ͘ϬϬ ϱϲϬ ŵŝŶͬ^ŚƵƚͲϬ͘ϬϬ͘Ϭ Ϭ͘Ϭt&ϭϮϱͲ:Ϯϭϴ;ϮͿϬϬ͘ϬϬ ϲy>ŚĞĐŬϮϬ͘ϬϮϮ͘Ϭ Ϭ͘ϵz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϴϰϬϬ͘ϬϬ ϳWϳϭϱ͘ϬϮϱ͘Ϭ Ϯϴ͘ϲz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϯϬϬϯϬϬ͘ϬϬ ϴϭ͘ϬWWϭϬϬ͘ϬϮϱ͘Ϭ ϰ͘Ϭz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϰϬϮϮϭϲͬϮϬͲ>ŝƚĞϭ͘ϬϰϬϮϮ ϵϮ͘ϬWWϵϵ͘ϵϮϱ͘Ϭ ϰ͘Ϭz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϯϴϱϴϭϲͬϮϬͲ>ŝƚĞϮ͘Ϭϳϳϭϲ ϭϬϰ͘ϬWWϭϳϵ͘ϴϮϱ͘Ϭ ϳ͘Ϯz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϲϰϮϮϭϲͬϮϬͲ>ŝƚĞϰ͘ϬϮϱϲϴϴ ϭϭϲ͘ϬWWϭϴϰ͘ϲϮϱ͘Ϭ ϳ͘ϰz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϲϭϯϴϭϲͬϮϬͲ>ŝƚĞϲ͘ϬϯϲϴϮϴ ϭϮϳ͘ϬWWϮϵϵ͘ϰϮϱ͘Ϭ ϭϮ͘Ϭz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϵϲϭϴϭϲͬϮϬͲ>ŝƚĞϳ͘ϬϲϳϯϮϲ ϭϯϴ͘ϬWWϮϳϵ͘ϯϮϱ͘Ϭ ϭϭ͘Ϯz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϴϲϴϯϭϲͬϮϬͲ>ŝƚĞϴ͘Ϭϲϵϰϲϰ ϭϰϵ͘ϬWWϭϵϵ͘ϱϮϱ͘Ϭ ϴ͘Ϭz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϲϬϬϲϭϲͬϮϬͲ>ŝƚĞϵ͘ϬϱϰϬϱϰ ϭϱϭϬ͘ϬWWϭϭϵ͘ϳϮϱ͘Ϭ ϰ͘ϴz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϯϰϵϯϭϲͬϮϬͲ>ŝƚĞϭϬ͘ϬϮϱϮϳϯ ϭϲϭϬ͘ϬWWϭϳϭ͘ϱϮϱ͘Ϭ ϲ͘ϵz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϱϬϬϲϭϮͬϭϴͲ>ŝƚĞϭϬ͘ϬϱϬϬϲϬ ϭϳ&ůƵƐŚϱϴ͘ϬϮϱ͘Ϭ Ϯ͘ϯt&ϭϮϱͲ:Ϯϭϴ;ϮͿϮϰϯϲϬ͘ϬϬ ϭϴ&ƌĞĞǌĞ WƌŽƚĞϲϬ͘ϬϮϱ͘Ϭ Ϯ͘ϰ&ƌĞĞǌĞƉƌŽƚĞĐƚϮϱϮϬϬ͘ϬϬ ĞƐŝŐŶĞĚZĂŵƉdŽƚĂůƐ ^ůƵƌƌǇ ;ďďůͿ WƵŵƉdŝŵĞ ;ŵŝŶͿ ůĞĂŶ&ůƵŝĚ ;ŐĂůͿ WƌŽƉƉĂŶƚ ;ůďͿ Ϯϳϳϲ͘ϲϭϭϭ͘ϳϭϬϭϮϱϮϯϱϬϬϴϴ ůŝĞŶƚ͗ŽŶŽĐŽWŚŝůůŝƉƐ tĞůů͗ϯ^ͲϮϰ ŝƐƚƌŝĐƚ͗<ƵƉĂƌƵŬ ŽƵŶƚƌǇ͗hŶŝƚĞĚ^ƚĂƚĞƐ ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ^ĞĐƚŝŽŶϮ͗ƐDĞĂƐƵƌĞĚWƵŵƉ^ĐŚĞĚƵůĞ ƐDĞĂƐƵƌĞĚWƵŵƉ^ĐŚĞĚƵůĞ ^ƚĞƉ η ^ƚĞƉ EĂŵĞ ^ůƵƌƌǇ sŽůƵŵĞ ;ďďůͿ ^ůƵƌƌǇ ZĂƚĞ ;ďďůͬŵŝŶͿ WƵŵƉ dŝŵĞ ;ŵŝŶͿ &ůƵŝĚEĂŵĞ &ůƵŝĚ sŽůƵŵĞ ;ŐĂůͿ WƌŽƉƉĂŶƚEĂŵĞ DĂǆ WƌŽƉ ŽŶĐ ;WWͿ WƌŽƉ ŽŶĐ ;WWͿ WƌŽƉ DĂƐƐ ;ůďͿ ϭ>'ϯϬ͘ϱϳ͘Ϯϰ͘Ϯt&ϭϮϱͲ:Ϯϭϴ;ϮͿϭϮϴϭϬ͘ϬϬ͘ϬϬ͘Ϭ Ϯy>ŚĞĐŬϮϮ͘ϱϳ͘Ϯϯ͘ϭz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϵϰϱϬ͘ϬϬ͘ϬϬ ϯDŝŶŝ&ƌĂĐϭϱϱϭϲ͘ϴϵ͘Ϯz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϲϱϭϬϬ͘ϬϬ͘ϬϬ ϰ&ůƵƐŚϵϲϮϰ͘ϴϯ͘ϵt&ϭϮϱͲ:Ϯϭϴ;ϮͿϰϬϯϮϬ͘ϬϬ͘ϬϬ ϱ&ƌĞĞǌĞ WƌŽƚĞϮϱ͘ϵϮϰ͘ϯϭ͘ϭ&ƌĞĞǌĞƉƌŽƚĞĐƚϭϬϴϳ͘ϴϬ͘ϬϬ͘ϬϬ ϲ>'Ϯϱ͘Ϯϴ͘Ϭϯ͘Ϯt&ϭϮϱͲ:Ϯϭϴ;ϮͿϭϬϱϴ͘ϰϬ͘ϬϬ͘ϬϬ͘Ϭ ϳy>ŚĞĐŬϭϮ͘ϴϴ͘Ϭϭ͘ϲz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϱϯϳ͘ϲϬ͘ϬϬ͘ϬϬ ϴWϳϭϱ͘ϬϮϱ͘ϬϮϴ͘ϲz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϯϬϬϯϬϬ͘ϬϬ͘ϬϬ ϵϭ͘ϬWWϭϬϬ͘ϬϮϰ͘ϴϰ͘Ϭz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϰϮϬϬϭϲͬϮϬͲ>ŝƚĞϭ͘Ϭϭ͘Ϭϯϵϭϲ ϭϬϮ͘ϬWWϵϵ͘ϵϮϰ͘ϵϰ͘Ϭz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϰϭϵϱ͘ϴϭϲͬϮϬͲ>ŝƚĞϮ͘ϭϭ͘ϵϳϱϮϵ ϭϭϰ͘ϬWWϭϳϵ͘ϴϮϰ͘ϴϳ͘ϯz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϳϱϱϭ͘ϲϭϲͬϮϬͲ>ŝƚĞϰ͘Ϯϰ͘ϬϮϱϰϭϱ ϭϮϲ͘ϬWWϭϴϰ͘ϲϮϰ͘ϳϳ͘ϱz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϳϳϱϯ͘ϮϭϲͬϮϬͲ>ŝƚĞϲ͘Ϯϱ͘ϵϯϲϱϰϵ ϭϯϳ͘ϬWWϮϵϵ͘ϰϮϰ͘ϳϭϮ͘ϭz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϭϮϱϳϰ͘ϴϭϲͬϮϬͲ>ŝƚĞϳ͘Ϯϳ͘ϬϲϳϭϱϮ ϭϰϴ͘ϬWWϮϳϵ͘ϯϮϰ͘ϳϭϭ͘ϯz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϭϭϳϯϬ͘ϲϭϲͬϮϬͲ>ŝƚĞϴ͘Ϯϴ͘ϬϲϵϰϬϭ ϭϱϵ͘ϬWWϭϵϵ͘ϱϮϰ͘ϲϴ͘ϭz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϴϯϳϵϭϲͬϮϬͲ>ŝƚĞϵ͘ϯϵ͘ϬϱϯϵϳϬ ϭϲϭϬ͘ϬWWϴϱ͘ϰϮϰ͘ϱϯ͘ϱz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϯϱϴϲ͘ϴϭϲͬϮϬͲ>ŝƚĞϭϬ͘Ϯϵ͘ϵϮϰϳϬϮ ϭϳϭϬ͘ϬWWϭϴϲ͘ϭϮϯ͘ϯϴ͘Ϭz&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿϳϴϭϲ͘ϮϭϮͬϭϴͲ>ŝƚĞϭϬ͘ϯϵ͘ϰϱϭϳϵϳ ϭϴ&ůƵƐŚϱϴ͘ϬϮϱ͘ϯϮ͘ϯt&ϭϮϱͲ:Ϯϭϴ;ϮͿϮϰϯϲϬ͘ϬϬ͘ϬϬ ϭϵ&ƌĞĞǌĞ WƌŽƚĞϱϵ͘ϵϮϮ͘ϳϮ͘ϲ&ƌĞĞǌĞƉƌŽƚĞĐƚϮϱϭϱ͘ϴϬ͘ϬϬ͘ϬϬ ^ƚĂŐĞWƌĞƐƐƵƌĞƐΘZĂƚĞƐ ^ƚĞƉη^ƚĞƉEĂŵĞǀĞƌĂŐĞ^ůƵƌƌǇZĂƚĞ ;ďďůͬŵŝŶͿ DĂǆŝŵƵŵ^ůƵƌƌǇ ZĂƚĞ ;ďďůͬŵŝŶͿ ǀĞƌĂŐĞdƌĞĂƚŝŶŐ WƌĞƐƐƵƌĞ ;ƉƐŝͿ DĂǆŝŵƵŵdƌĞĂƚŝŶŐ WƌĞƐƐƵƌĞ ;ƉƐŝͿ DŝŶŝŵƵŵdƌĞĂƚŝŶŐ WƌĞƐƐƵƌĞ ;ƉƐŝͿ ϭ>'ϳ͘Ϯϭϰ͘ϴϭϮϮϲϭϰϱϱϵϴ Ϯy>ŚĞĐŬϳ͘Ϯϭϰ͘ϴϭϮϮϲϭϰϱϱϵϴ ϯDŝŶŝ&ƌĂĐϭϲ͘ϴϮϰ͘ϵϭϲϮϯϭϵϴϬϭϰϭϰ ϰ&ůƵƐŚϮϰ͘ϴϮϱ͘ϬϭϳϲϲϭϵϬϱϭϬϯϴ ϱ&ƌĞĞǌĞWƌŽƚĞϮϰ͘ϯϮϰ͘ϴϭϯϯϬϭϳϮϱϯϯϮ ϲ>'ϴ͘ϬϮϬ͘ϮϭϭϴϮϭϱϳϬϯϲϱ ϳy>ŚĞĐŬϴ͘ϬϮϬ͘ϮϭϭϴϮϭϱϳϬϯϲϱ ϴWϮϱ͘ϬϮϱ͘ϯϭϴϰϮϭϵϳϬϭϱϬϱ ϵϭ͘ϬWWϮϰ͘ϴϮϱ͘ϭϭϴϮϱϭϴϰϳϭϴϬϯ ϭϬϮ͘ϬWWϮϰ͘ϵϮϱ͘ϭϭϴϭϵϭϴϰϲϭϳϵϲ ϭϭϰ͘ϬWWϮϰ͘ϴϮϱ͘ϭϭϴϭϭϭϴϰϳϭϳϵϮ ϭϮϲ͘ϬWWϮϰ͘ϳϮϱ͘ϬϭϳϲϳϭϴϬϱϭϳϰϰ ϭϯϳ͘ϬWWϮϰ͘ϳϮϰ͘ϵϭϳϯϮϭϳϲϮϭϳϬϲ ϭϰϴ͘ϬWWϮϰ͘ϳϮϰ͘ϴϭϲϳϲϭϳϭϲϭϲϰϵ ϭϱϵ͘ϬWWϮϰ͘ϲϮϰ͘ϴϭϲϲϭϭϲϴϰϭϲϯϰ ϭϲϭϬ͘ϬWWϮϰ͘ϱϮϰ͘ϳϭϲϮϴϭϲϲϲϭϱϵϰ ϭϳϭϬ͘ϬWWϮϯ͘ϯϮϰ͘ϰϭϴϰϳϮϴϲϭϭϱϲϰ ϭϴ&ůƵƐŚϮϱ͘ϯϮϱ͘ϱϮϮϭϵϮϮϴϲϮϬϱϵ ϭϵ&ƌĞĞǌĞWƌŽƚĞϮϮ͘ϳϮϱ͘ϯϭϳϵϬϮϬϱϲϳ ůŝĞŶƚ͗ŽŶŽĐŽWŚŝůůŝƉƐ tĞůů͗ϯ^ͲϮϰ ŝƐƚƌŝĐƚ͗<ƵƉĂƌƵŬ ŽƵŶƚƌǇ͗hŶŝƚĞĚ^ƚĂƚĞƐ ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ƐDĞĂƐƵƌĞĚdŽƚĂůƐ ^ůƵƌƌǇ ;ďďůͿ WƵŵƉdŝŵĞ ;ŵŝŶͿ ůĞĂŶ&ůƵŝĚ ;ďďůͿ WƌŽƉƉĂŶƚ ;ůďͿ Ϯϴϭϰ͘ϴϭϮϵ͘ϬϮϰϱϵ͘ϭϯϰϬϰϯϭ ǀĞƌĂŐĞdƌĞĂƚŝŶŐWƌĞƐƐƵƌĞ͗ϭϳϱϯƉƐŝ DĂǆŝŵƵŵdƌĞĂƚŝŶŐWƌĞƐƐƵƌĞ͗ϮϴϲϭƉƐŝ DŝŶŝŵƵŵdƌĞĂƚŝŶŐWƌĞƐƐƵƌĞ͗ϳƉƐŝ ǀĞƌĂŐĞ/ŶũĞĐƚŝŽŶZĂƚĞ͗Ϯϯ͘ϳďďůͬŵŝŶ DĂǆŝŵƵŵ/ŶũĞĐƚŝŽŶZĂƚĞ͗Ϯϱ͘ϱďďůͬŵŝŶ ǀĞƌĂŐĞ,ŽƌƐĞƉŽǁĞƌ͗ϭϬϮϴ͘ϳŚŚƉ DĂǆŝŵƵŵ,ŽƌƐĞƉŽǁĞƌ͗ϭϲϮϴ͘ϱŚŚƉ DĂǆŝŵƵŵWƌŽƉŽŶĐĞŶƚƌĂƚŝŽŶ͗ϭϬ͘ϯWW ^ĞĐƚŝŽŶϯ͗&ůƵŝĚĞƐĐƌŝƉƚŝŽŶ &ůƵŝĚEĂŵĞ͗z&ϭϮϱ^dͲ:ϱϯϮ;ϲͿ͕:Ϯϭϴ;ϮͿ ĚĚŝƚŝǀĞEĂŵĞĚĚŝƚŝǀĞdǇƉĞ^ŽůŝĚŽŶĐ ;ůďͬŵŐĂůͿ >ŝƋƵŝĚŽŶĐ ;ŐĂůͬŵŐĂůͿ :ϱϴϬ͕'ĞůůŝŶŐŐĞŶƚ'>>/E''dϮϱ͘Ϭ DϮϳϱ͕DŝĐƌŽďŝŽĐŝĚĞ/K/Ϭ͘ϯ &ϭϬϯ͕&>K^ƵƌĨĂĐƚĂŶƚ^hZ&dEdϭ͘Ϭ >Ϭϲϱ͕^ĐĂůĞ/ŶŚŝďŝƚŽƌ/E,//dKZ/Ϯ͘Ϭ :ϯϭϴ͕>ŝƋƵŝĚƌĞĂŬĞƌŝĚZ<Z/Ϭ͘ϱ :ϱϭϭ͕^ƚĂďŝůŝǌĞƌ^d/>/Zϯ͘ϰ :Ϯϭϴ͕ƌĞĂŬĞƌZ<ZϮ͘Ϭ :ϱϯϮ͕ŽƌĂƚĞƌŽƐƐůŝŶŬĞƌZK^^>/E<Zϲ͘Ϭ &ůƵŝĚEĂŵĞ͗t&ϭϮϱͲ:Ϯϭϴ;ϮͿ ĚĚŝƚŝǀĞEĂŵĞĚĚŝƚŝǀĞdǇƉĞ^ŽůŝĚŽŶĐ ;ůďͬŵŐĂůͿ >ŝƋƵŝĚŽŶĐ ;ŐĂůͬŵŐĂůͿ :ϱϴϬ͕'ĞůůŝŶŐŐĞŶƚ'>>/E''dϮϱ͘Ϭ DϮϳϱ͕DŝĐƌŽďŝŽĐŝĚĞ/K/Ϭ͘ϯ &ϭϬϯ͕&>K^ƵƌĨĂĐƚĂŶƚ^hZ&dEdϭ͘Ϭ >Ϭϲϱ͕^ĐĂůĞ/ŶŚŝďŝƚŽƌ/E,//dKZ/Ϯ͘Ϭ :ϯϭϴ͕>ŝƋƵŝĚƌĞĂŬĞƌŝĚZ<Z/Ϭ͘ϱ :ϱϭϭ͕^ƚĂďŝůŝǌĞƌ^d/>/Zϯ͘ϰ :Ϯϭϴ͕ƌĞĂŬĞƌZ<ZϮ͘Ϭ ^ĞĐƚŝŽŶϰ͗WƌŽƉƉĂŶƚĞƐĐƌŝƉƚŝŽŶ WƌŽƉƉĂŶƚ WƌŽƉƉĂŶƚEĂŵĞDĞƐŚ^ŝǌĞ^ƉĞĐ'ƌĂǀŝƚǇWƌŽƉ&ƌŝĐŽĞĨĨ͘>ĂŵŝŶĂƌWƌŽƉ&ƌŝĐŽĞĨĨ͘dƵƌďƵůĞŶƚ ϭϲͬϮϬͲ>ŝƚĞϭϲͬϮϬϮ͘ϳϯϭ͘ϬϬ Ϭ͘ϴϱ ϭϮͬϭϴͲ>ŝƚĞϭϮͬϭϴϮ͘ϳϯϭ͘ϬϬ Ϭ͘ϵϬ ůŝĞŶƚ͗ŽŶŽĐŽWŚŝůůŝƉƐ tĞůů͗ϯ^ͲϮϰ ŝƐƚƌŝĐƚ͗<ƵƉĂƌƵŬ ŽƵŶƚƌǇ͗hŶŝƚĞĚ^ƚĂƚĞƐ ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ^ĞĐƚŝŽŶϱ͗WĞƌĨŽƌĂƚŝŽŶƐ WĞƌĨŽƌĂƚŝŽŶƐ dŽƉD ;ĨƚͿ dŽƉds ;ĨƚͿ ŽƚƚŽŵD ;ĨƚͿ ŽƚƚŽŵds ;ĨƚͿ ^ŚŽƚĞŶƐŝƚǇ ;ƐŚŽƚͬĨƚͿEƵŵďĞƌŝĂŵĞƚĞƌ ;ŝŶͿ ϳϵϰϰ͘Ϭ ϰϭϱϳ͘ϯ ϳϵϱϯ͘Ϭ ϰϭϲϲ͘ϯϲ͘ϬϬϱϰϬ͘ϯϴ ϳϵϱϳ͘Ϭ ϰϭϳϬ͘ϯ ϳϵϲϯ͘Ϭ ϰϭϳϲ͘ϯϲ͘ϬϬϯϲϬ͘ϯϴ ^ĞĐƚŝŽŶϲ͗&ƌĂĐϯ^ͲϮϰ͕WƌŽƉƉĞĚ&ƌĂĐ͗:ŽďDĞƐƐĂŐĞƐ DĞƐƐĂŐĞ>ŽŐ ηdŝŵĞDĞƐƐĂŐĞ dƌĞĂƚŝŶŐ WƌĞƐƐƵƌĞ ;ƉƐŝͿ ŶŶƵůƵƐ WƌĞƐƐƵƌĞ ;ƉƐŝͿ dŽƚĂů^ůƵƌƌǇ ;ďďůͿ ^ůƵƌƌǇZĂƚĞ ;ďďůͬŵŝŶͿ WƌŽƉ͘ŽŶĐ͘ ;WWͿ ϭZĞƐĞƚǆĞĐƵƚĞĚ^ƚĞƉƐϬϬϬ͘ϬϬ͘ϬϬ͘Ϭ ϮZĞƐĞƚǆĞĐƵƚĞĚ^ƚĞƉƐϬϬϬ͘ϬϬ͘ϬϬ͘Ϭ ϯϭϰ͗Ϭϴ͗ϰϭ^ƚĂƌƚWƌŝŵŝŶŐƵƉƉƵŵƉƐϰϳϮϵϯϬ͘ϬϬ͘ϬϬ͘Ϭ ϰϭϰ͗ϱϰ͗ϱϬdĞƐƚWŽƉKĨĨϭϯϬϭϮϬ͘ϬϬ͘ϬϬ͘Ϭ ϱϭϰ͗ϱϴ͗ϯϱWKWKĨĨǁĞŶƚϲϬϰϭϭϬ͘ϬϬ͘ϬϬ͘Ϭ ϲϭϱ͗ϱϰ͗ϮϱdĞƐƚƉŽƉKĨĨϮϰϮϯϴϮϮϲϬ͘ϬϬ͘ϬϬ͘Ϭ ϳϭϲ͗ϰϮ͗ϱϲ'ŽŽĚWdϯϳϮϮϲϬ͘ϬϬ͘ϬϬ͘Ϭ ϴϭϴ͗Ϯϴ͗Ϯϱ^ƚĂƌƚy>ŚĞĐŬƵƚŽŵĂƚŝĐĂůůǇϵϳϮϭϭϬ͘ϬϬ͘ϬϬ͘Ϭ ϵϭϴ͗Ϯϴ͗Ϯϱ^ƚĂƌƚWƌŽƉƉĞĚ&ƌĂĐƵƚŽŵĂƚŝĐĂůůǇϵϳϮϭϭϬ͘ϬϬ͘ϬϬ͘Ϭ ϭϬϭϴ͗Ϯϴ͗Ϯϱ^ƚĂƌƚ&ƌĂĐϯ^ͲϮϰƵƚŽŵĂƚŝĐĂůůǇϵϳϮϭϭϬ͘ϬϬ͘ϬϬ͘Ϭ ϭϭϭϴ͗Ϯϴ͗ϰϵ^ƚĂƌƚĞĚWƵŵƉŝŶŐϵϴϮϭϭϬ͘ϬϬ͘ϬϬ͘Ϭ ϭϮϭϴ͗Ϯϵ͗ϭϯĐƚŝǀĂƚĞĚǆƚĞŶĚ^ƚĂŐĞϵϴϮϭϭϬ͘ϬϬ͘ϬϬ͘Ϭ ϭϯϭϴ͗ϯϯ͗ϰϲKƉĞŶŝŶŐtĞůůϰϵϴϭϰϲϱϬ͘ϬϬ͘ϬϬ͘Ϭ ϭϰϭϴ͗ϱϴ͗ϰϴĞĂĐƚŝǀĂƚĞĚǆƚĞŶĚ^ƚĂŐĞϭϰϱϰϮϭϬϱϱϮ͘ϭϭϰ͘ϵϬ͘Ϭ ϭϱϭϴ͗ϱϴ͗ϰϴ^ƚĂƌƚDŝŶŝ&ƌĂĐDĂŶƵĂůůǇϭϰϱϰϮϭϬϱϱϮ͘ϭϭϰ͘ϵϬ͘Ϭ ϭϲϭϵ͗Ϭϰ͗Ϯϵ^ƚĂŐĞĂƚWĞƌĨƐ͗y>ŚĞĐŬϭϱϴϱϮϮϳϰϭϯϯ͘Ϯϭϱ͘ϮϬ͘Ϭ ϭϳϭϵ͗Ϭϳ͗Ϯϱ^ƚĂŐĞĂƚWĞƌĨƐ͗DŝŶŝ&ƌĂĐϭϵϱϯϮϮϴϯϭϴϱ͘ϮϮϰ͘ϵϬ͘Ϭ ϭϴϭϵ͗Ϭϴ͗Ϭϲ^ƚĂƌƚ&ůƵƐŚƵƚŽŵĂƚŝĐĂůůǇϭϴϵϳϮϮϲϴϮϬϮ͘ϮϮϰ͘ϵϬ͘Ϭ ϭϵϭϵ͗ϭϭ͗ϬϬĐƚŝǀĂƚĞĚǆƚĞŶĚ^ƚĂŐĞϭϳϬϲϮϮϯϴϮϳϰ͘ϰϮϰ͘ϳϬ͘Ϭ ϮϬϭϵ͗ϭϮ͗ϬϴĞĂĐƚŝǀĂƚĞĚǆƚĞŶĚ^ƚĂŐĞϭϳϱϱϮϮϭϵϯϬϮ͘ϰϮϱ͘ϬϬ͘Ϭ Ϯϭϭϵ͗ϭϮ͗Ϭϴ^ƚĂƌƚ&ůƵƐŚDĂŶƵĂůůǇϭϳϱϱϮϮϭϵϯϬϮ͘ϰϮϱ͘ϬϬ͘Ϭ ϮϮϮϭ͗Ϭϰ͗ϯϱ^ƚĂƌƚĞĚWƵŵƉŝŶŐϯϯϭϭϵϳϱϯϯϭ͘ϬϬ͘ϬϬ͘Ϭ ϮϯϮϭ͗Ϭϱ͗ϱϳ^ƚĂƌƚy>ŚĞĐŬDĂŶƵĂůůǇϯϲϰϭϵϳϰϯϯϭ͘ϭϬ͘ϬϬ͘Ϭ ϮϰϮϭ͗Ϭϲ͗ϱϯ^ƚĂŐĞĂƚWĞƌĨƐ͗&ůƵƐŚϭϬϴϴϮϬϰϰϯϯϱ͘ϭϲ͘ϭϬ͘Ϭ ϮϱϮϭ͗Ϭϲ͗ϱϲĐƚŝǀĂƚĞĚǆƚĞŶĚ^ƚĂŐĞϭϬϵϬϮϬϰϮϯϯϱ͘ϰϲ͘ϭϬ͘Ϭ ϮϲϮϭ͗ϭϵ͗ϮϬĞĂĐƚŝǀĂƚĞĚǆƚĞŶĚ^ƚĂŐĞϭϱϬϱϮϬϲϱϯϳϬ͘ϭϮϬ͘ϬϬ͘Ϭ ϮϳϮϭ͗ϭϵ͗ϮϬ^ƚĂƌƚWDĂŶƵĂůůǇϭϱϬϱϮϬϲϱϯϳϬ͘ϭϮϬ͘ϬϬ͘Ϭ ϮϴϮϭ͗ϮϮ͗Ϭϳ^ƚĂŐĞĂƚWĞƌĨƐ͗&ůƵƐŚϭϴϮϲϮϭϰϯϰϯϱ͘ϳϮϱ͘ϭϬ͘Ϭ ϮϵϮϭ͗Ϯϯ͗ϭϱ^ƚĂŐĞĂƚWĞƌĨƐ͗WϭϳϬϭϮϬϮϯϰϲϰ͘ϮϮϱ͘ϮϬ͘Ϭ ϯϬϮϭ͗Ϯϰ͗ϰϴ^ƚĂŐĞĂƚWĞƌĨƐ͗&ůƵƐŚϭϳϮϲϮϭϲϬϱϬϯ͘ϯϮϱ͘ϮϬ͘Ϭ ϯϭϮϭ͗ϰϳ͗ϱϴ^ƚĂƌƚϭ͘ϬWWƵƚŽŵĂƚŝĐĂůůǇϭϴϰϴϮϭϳϱϭϬϴϱ͘ϯ Ϯϱ͘ϮϬ͘Ϭ ϯϮϮϭ͗ϰϳ͗ϱϴ^ƚĂƌƚĞĚWƵŵƉŝŶŐWƌŽƉϭϴϰϴϮϭϳϱϭϬϴϱ͘ϯ Ϯϱ͘ϮϬ͘Ϭ ϯϯϮϭ͗ϱϮ͗ϬϬ^ƚĂƌƚϮ͘ϬWWƵƚŽŵĂƚŝĐĂůůǇϭϴϮϮϮϭϴϱϭϭϴϱ͘ϯ Ϯϰ͘ϴϭ͘ϭ ϯϰϮϭ͗ϱϯ͗Ϯϭ^ƚĂŐĞĂƚWĞƌĨƐ͗Ϯ͘ϬWWϭϴϬϱϮϭϵϯϭϮϭϴ͘ϲ Ϯϰ͘ϴϭ͘ϵ ϯϱϮϭ͗ϱϲ͗Ϭϭ^ƚĂƌƚϰ͘ϬWWƵƚŽŵĂƚŝĐĂůůǇϭϴϰϬϮϭϭϳϭϮϴϱ͘Ϯ Ϯϰ͘ϵϮ͘Ϭ ϯϲϮϭ͗ϱϳ͗Ϯϭ^ƚĂŐĞĂƚWĞƌĨƐ͗ϰ͘ϬWWϭϳϵϴϮϭϯϰϭϯϭϴ͘ϰ Ϯϰ͘ϵϰ͘Ϭ ϯϳϮϮ͗Ϭϭ͗Ϯϯ^ƚĂŐĞĂƚWĞƌĨƐ͗y>ŚĞĐŬϭϴϭϮϮϭϯϬϭϰϭϴ͘ϰ Ϯϰ͘ϴϰ͘ϭ ϯϴϮϮ͗Ϭϯ͗ϭϲ^ƚĂƌƚϲ͘ϬWWƵƚŽŵĂƚŝĐĂůůǇϭϳϵϰϮϭϮϴϭϰϲϱ͘Ϭ Ϯϰ͘ϴϰ͘Ϯ ϯϵϮϮ͗Ϭϴ͗ϯϵ^ƚĂŐĞĂƚWĞƌĨƐ͗WϭϳϰϱϮϮϮϵϭϱϵϴ͘ϯ Ϯϰ͘ϲϲ͘Ϭ ůŝĞŶƚ͗ŽŶŽĐŽWŚŝůůŝƉƐ tĞůů͗ϯ^ͲϮϰ ŝƐƚƌŝĐƚ͗<ƵƉĂƌƵŬ ŽƵŶƚƌǇ͗hŶŝƚĞĚ^ƚĂƚĞƐ ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ DĞƐƐĂŐĞ>ŽŐ ηdŝŵĞDĞƐƐĂŐĞ dƌĞĂƚŝŶŐ WƌĞƐƐƵƌĞ ;ƉƐŝͿ ŶŶƵůƵƐ WƌĞƐƐƵƌĞ ;ƉƐŝͿ dŽƚĂů^ůƵƌƌǇ ;ďďůͿ ^ůƵƌƌǇZĂƚĞ ;ďďůͬŵŝŶͿ WƌŽƉ͘ŽŶĐ͘ ;WWͿ ϰϬϮϮ͗ϭϬ͗ϰϰ^ƚĂƌƚϳ͘ϬWWƵƚŽŵĂƚŝĐĂůůǇϭϳϰϲϮϮϰϰϭϲϰϵ͘ϴ Ϯϱ͘Ϭϲ͘ϭ ϰϭϮϮ͗ϭϲ͗Ϭϲ^ƚĂŐĞĂƚWĞƌĨƐ͗ϭ͘ϬWWϭϳϰϮϮϮϮϵϭϳϴϮ͘ϳ Ϯϰ͘ϲϳ͘Ϭ ϰϮϮϮ͗ϮϮ͗ϱϭ^ƚĂƌƚϴ͘ϬWWƵƚŽŵĂƚŝĐĂůůǇϭϳϭϬϮϮϬϱϭϵϰϵ͘ϭ Ϯϰ͘ϵϳ͘Ϭ ϰϯϮϮ͗Ϯϴ͗ϭϱ^ƚĂŐĞĂƚWĞƌĨƐ͗Ϯ͘ϬWWϭϲϲϮϮϮϬϯϮϬϴϮ͘ϰ Ϯϰ͘ϳϳ͘ϵ ϰϰϮϮ͗ϯϰ͗ϭϭ^ƚĂƌƚϵ͘ϬWWƵƚŽŵĂƚŝĐĂůůǇϭϲϰϳϮϮϬϳϮϮϮϴ͘ϱ Ϯϰ͘ϲϳ͘ϵ ϰϱϮϮ͗ϯϵ͗ϯϲ^ƚĂŐĞĂƚWĞƌĨƐ͗ϰ͘ϬWWϭϲϵϬϮϮϱϮϮϯϲϭ͘ϰ Ϯϰ͘ϲϵ͘ϭ ϰϲϮϮ͗ϰϮ͗ϭϴ^ƚĂƌƚϭϬ͘ϬWWƵƚŽŵĂƚŝĐĂůůǇϭϲϱϵϮϮϯϴϮϰϮϳ͘ϴ Ϯϰ͘ϲϵ͘ϭ ϰϳϮϮ͗ϰϯ͗ϭϵĐƚŝǀĂƚĞĚǆƚĞŶĚ^ƚĂŐĞϭϲϰϳϮϮϮϵϮϰϱϮ͘ϴ Ϯϰ͘ϮϭϬ͘ϭ ϰϴϮϮ͗ϰϱ͗ϰϳĞĂĐƚŝǀĂƚĞĚǆƚĞŶĚ^ƚĂŐĞϭϲϬϴϮϭϴϵϮϱϭϯ͘Ϭ Ϯϰ͘ϰϭϬ͘Ϭ ϰϵϮϮ͗ϰϱ͗ϰϳ^ƚĂƌƚϭϬ͘ϬWWDĂŶƵĂůůǇϭϲϬϴϮϭϴϵϮϱϭϯ͘Ϭ Ϯϰ͘ϰϭϬ͘Ϭ ϱϬϮϮ͗ϰϳ͗ϰϵ^ƚĂŐĞĂƚWĞƌĨƐ͗ϭϬ͘ϬWWϭϲϬϯϮϮϭϳϮϱϲϬ͘ϴ Ϯϯ͘ϮϭϬ͘Ϯ ϱϭϮϮ͗ϰϴ͗ϯϲĐƚŝǀĂƚĞĚǆƚĞŶĚ^ƚĂŐĞϭϲϱϴϮϮϬϮϮϱϳϵ͘Ϭ Ϯϯ͘ϱϭϬ͘Ϯ ϱϮϮϮ͗ϱϭ͗ϯϬ^ƚĂŐĞĂƚWĞƌĨƐ͗ϳ͘ϬWWϭϳϵϳϮϮϬϳϮϲϰϲ͘Ϯ Ϯϯ͘ϯϭϬ͘ϭ ϱϯϮϮ͗ϱϯ͗ϰϲĞĂĐƚŝǀĂƚĞĚǆƚĞŶĚ^ƚĂŐĞϮϮϰϮϮϭϴϵϮϲϵϵ͘ϭ Ϯϰ͘ϴͲϬ͘Ϭ ϱϰϮϮ͗ϱϯ͗ϰϲ^ƚĂƌƚ&ůƵƐŚDĂŶƵĂůůǇϮϮϰϮϮϭϴϵϮϲϵϵ͘ϭ Ϯϰ͘ϴͲϬ͘Ϭ ϱϱϮϮ͗ϱϱ͗ϰϳ^ƚŽƉƉĞĚWƵŵƉŝŶŐWƌŽƉϮϬϵϳϮϮϯϭϮϳϱϬ͘ϭ Ϯϱ͘ϮͲϬ͘ϭ ϱϲϮϮ͗ϱϲ͗Ϭϰ^ƚĂƌƚ&ƌĞĞǌĞWƌŽƚĞƵƚŽŵĂƚŝĐĂůůǇϮϬϰϲϮϮϰϮϮϳϱϳ͘ϯ Ϯϱ͘ϮϬ͘Ϭ ϱϳϮϮ͗ϱϲ͗ϱϮĐƚŝǀĂƚĞĚǆƚĞŶĚ^ƚĂŐĞϭϴϬϯϮϮϱϳϮϳϳϳ͘ϯ Ϯϯ͘ϰϬ͘Ϭ ůŝĞŶƚ͗ŽŶŽĐŽWŚŝůůŝƉƐ tĞůů͗ϯ^ͲϮϰ ŝƐƚƌŝĐƚ͗<ƵƉĂƌƵŬ ŽƵŶƚƌǇ͗hŶŝƚĞĚ^ƚĂƚĞƐ ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ^ĞĐƚŝŽŶϳ͗&ƌĂĐϯ^ͲϮϰ͕WƌŽƉƉĞĚ&ƌĂĐ͗WŽƐƚ:Žď'KZsƚĞƐƚ 7LPHKKPPVV 75 B 3 5 ( 6 6 S V L 6O X U U \ 5 D W H E E O P L Q 75B35(66 $1B35(66 %+B35(66 323B2)) 6/85B5$7( )UDF&$7 6FKOXPEHUJHU &RQRFR3KLOOLSV 6% ůŝĞŶƚ͗ŽŶŽĐŽWŚŝůůŝƉƐ tĞůů͗ϯ^ͲϮϰ ŝƐƚƌŝĐƚ͗<ƵƉĂƌƵŬ ŽƵŶƚƌǇ͗hŶŝƚĞĚ^ƚĂƚĞƐ ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ^ĞĐƚŝŽŶϴ͗&ƌĂĐϯ^ͲϮϰ͕WƌŽƉƉĞĚ&ƌĂĐ͗WŽƐƚ:ŽďWƌĞƐƐƵƌĞƚĞƐƚ 7LPHKKPPVV 75 B 3 5 ( 6 6 S V L 6O X U U \ 5 D W H E E O P L Q 75B35(66 $1B35(66 %+B35(66 323B2)) 6/85B5$7( )UDF&$7 6FKOXPEHUJHU &RQRFR3KLOOLSV 6% ůŝĞŶƚ͗ŽŶŽĐŽWŚŝůůŝƉƐ tĞůů͗ϯ^ͲϮϰ ŝƐƚƌŝĐƚ͗<ƵƉĂƌƵŬ ŽƵŶƚƌǇ͗hŶŝƚĞĚ^ƚĂƚĞƐ ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ ^ĞĐƚŝŽŶϵ͗&ƌĂĐϯ^ͲϮϰ͕WƌŽƉƉĞĚ&ƌĂĐ͗WŽƐƚ:ŽďĂƚĂ&Z 7LPHKKPPVV 75 B 3 5 ( 6 6 S V L 6O X U U \ 5 D W H E E O P L Q < $ [ L V 75B35(66 $1B35(66 %+B35(66 323B2)) 6/85B5$7( )UDF&$7 6FKOXPEHUJHU &RQRFR3KLOOLSV 6% ůŝĞŶƚ͗ŽŶŽĐŽWŚŝůůŝƉƐ tĞůů͗ϯ^ͲϮϰ ŝƐƚƌŝĐƚ͗<ƵƉĂƌƵŬ ŽƵŶƚƌǇ͗hŶŝƚĞĚ^ƚĂƚĞƐ ^ĐŚůƵŵďĞƌŐĞƌͲWƌŝǀĂƚĞ 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&ŝŶŝƐŚ&ƌĂĐ^ƚĂŐĞϭ͕Ϯϴϭϰ͘ϴďďů^ůƵƌƌǇsŽů͕Ϯϰϱϵ͘Ϯďďů&>sŽů͕ďďůy>sŽů͕<ŝďWƌŽƉ ϭϲͬϮϬĂƌďŽ Ϯϯ͗ϯϱ/^/WϭϱŵŝŶ͕^ĞĐƵƌĞĚƚŚĞǁĞůů Ϯϯ͗ϱϬůĞĞĚƚŚĞůŝŶĞƐĂŶĚĨƌĞĞǌĞƉƌŽƚĞĐƚƚŚĞĞƋƵŝƉŵĞŶƚƐ ϮϬͲĞĐϮ͗ϯϬ>ĞĂǀĞůŽĐĂƚŝŽŶǀŝĂKWďƵƐƉŝĐŬƵƉƚŽ< Production Month: Jan - 2022 CONOCOPHILLIPS ALASKA INC Alaska Oil And Gas Conservation Commission Monthly Production Report Form : 10-405 Operator: ConocoPhillips Alaska Inc. Field Name Kuparuk River/UndefinedField Name Kuparuk River/Undefined Well Number Api Number Cmp Type Field Code Prod Method Prod Days Tbg Press Average Daily Oil Daily Water Daily Gas Total Oil Total Water Total Gas 3S-24B 501032045602 1 490180 2 15 95 358 156 748 5,363 2,347 11,217 Sum:5,363 2,347 11,217 This report is confidential and proprietary to ConocoPhillips Alaska, Inc. and not subject to disclosure because it contains information or data that is (1) trade secret information as defined in AS 45.50.940(3) and State v. Arctic Slope Regional Corp., 834 P.2d 123 (Alaska 1991); (2) data required to be held confidential under AS 38.05.035(a)(8), AS 31.05.035(c), AS 43.05.230, and AS 40.25.100(a) ! "# $ %&' %&' &(! ))))))))))))))))))) * +*, &! - !. . /! & !0 $ 12 %& ! /* (3 ! * 4 5 ,6*-&!& ! (* ,( * % 76(" 89 2:034 22( 9: , +9*; <0,= 5 $+ /* (3 9 .&24 , <0,= 7&6 & ! 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" 6" 71J /25 /21/ , ",,%&",C< 5D 12D &0 513434 ** *(! -J 1D -D /25/D -J /J 5D -D D &0 &0 >9 6 ,% &,", (, >9 > 6 ;H :A, + 6"+ ( 27/1>27/5D.27/5>271D.275>27-1D< //>/7D./7>/-/D./-7>/2/D,= "+ >9 >9 >1>/->> 8 ;6 :0( 9#1-.*+.877>1- >2501>5 152.//. & !1.-D:&.--D:".*/.,&.62".< 2D:&.127D:".*/.,&.62".< 2 :!>/26 10 ! A 1$(! . .! CONFIDENTIAL" :8 :8 By Meredith Guhl at 10:06 am, Jan 05, 2022 RBDMS HEW 1/6/2022 Completion Date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omponent Description MD (ft) TVD (ft) Length (ft) 1 4-1/2" x 1" KBG-4-5 - SV 2,696' 1,939' 10' 2 4-1/2" x 1" KBG-4-5 - DV 6,968' 3,536' 10' 3 4-1/2" 3.813" X Profile 6,994' 3,546' 5' 4 4-1/2" 3.813" X Profile 7,092' 3,583' 5' 5 SLB Metris Evolve 10k Gauge 7,109' 3,589' 5' 6 5" OD Bullet Seal Assembly 7,128' 3,597' 15' 3-½” 9.2# L-80 SLHT Liner @ 12,513' MD / 6,050' TVD 16" 62.5 ppf H-40 Insulated Conductor @ 108' MD/TVD 7" 26# L-80 BTCM Intermediate casing @ 11,255' MD / 5,203' TVD Top Coyote 7,880' MD / 4,093' TVD 3S-24B Sidetrack Schematic X GLGL GLGL Liner Top Packer @ 10,327'' MD 9-5/8" 40# L-80 BTC Surface Casing set @ 4,527' MD / 2,613' TVD 4-1/2" 12.6# L-80 H563 Liner set @ 8,714' MD / 4,927' TVD CIBP / Whipstock @ 7,301' MD / 3,663' TVD Tubing cut pre- rig @ ~7500' MD Perfs @ 7,944' MD / 4,157' TVD to 7,953' MD / 4,166' TVD 7,957' MD / 4,170' TVD to 7,963' MD / 4,176' TVD Component Description MD (ft) TVD (ft) Length (ft) 7 5" x 15' Sealbore Extension 7,124' 3,595' 15' 8 4-1/2" x 7" Liner Top Packer / Hanger 7,140' 3,601' 10' 9 4-1/2" 3.813" XN Profile 7,170' 3,613' 4' 10 4-1/2" Float Collar + Landing Collar 8,829' 4,697' 4' 11 4-1/2" Float Shoe 8,712' 4,737' 3' Lower Completion Component Details 1 4 10-11 5 2 3 67 X N 8 4-1/2" 12.6# L-80 H563 Tubing seals @ 7,136' MD / 3,600' TVD Cement plug @ 9,292' MD (10/2/21) Upper Completion Component Details Lower Completion Component Details 9 X Confining Layer Top 6,500' MD / 3,358' TVD CONFIDENTIAL Page 1/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/21/2021 02:00 11/21/2021 14:00 12.00 MIRU, MOVE MOB P Move pits away from sub, move sub off 3S-611, remove tree from sub and hang 3S-24 tree in sub. Stage wellhead equipment behind well. Spot sub. Back pits into position. Identified damaged flow line. 0.0 0.0 11/21/2021 14:00 11/21/2021 18:00 4.00 MIRU, MOVE DMOB T Pull pits ahead. Remove damaged flexible flow line hose. Remove nipples from hose. Shorten and reinstall nipples, back pits in and install flowline 0.0 0.0 11/21/2021 18:00 11/21/2021 21:30 3.50 MIRU, MOVE MOB P Spot pits, berm, hook up service interconnects, steam, air, water, mud lines, etc. Work on post move checklist "RIG ACCEPTED AT 2130 Hrs" 0.0 0.0 11/21/2021 21:30 11/22/2021 00:00 2.50 MIRU, MOVE RURD P Take on 10.0 ppg NaCl/NaBr brine, RU circ equipment to tree, manifold and tiger tank. Load, strap and tally 4" 15.7# XT-39 DP in shed 0.0 0.0 11/22/2021 00:00 11/22/2021 00:30 0.50 MIRU, MOVE RURD P Take on 10.0 ppg NaCl/NaBr brine, RU circ equipment to tree, manifold and tiger tank. Load, strap and tally 4" 15.7# XT-39 DP in shed 0.0 0.0 11/22/2021 00:30 11/22/2021 02:30 2.00 MIRU, WELCTL MPSP P Pull H-BPV T= 0 psi, IA= 0 psi, OA= 0 psi 0.0 0.0 11/22/2021 02:30 11/22/2021 09:30 7.00 MIRU, WELCTL KLWL P Continue dilute brine, test lines to 3500 psi, circulate and displace out diesel and seawater with 10.1 ppg NaCl/NaBr brine @ 5 BPM, 1200 PSI down tubing out IA through choke house to tiger tank. Stopped to empty tiger tank twice. Take on additional load10.1 PPG NaCl/NaBr into pits. Pumped total of 584 Bbls before clean 10.1 PPG KWF was seen at surface. 0.0 0.0 11/22/2021 09:30 11/22/2021 10:00 0.50 MIRU, WELCTL OWFF P Observed well for flow - no flow 30 Min. 0.0 0.0 11/22/2021 10:00 11/22/2021 10:30 0.50 MIRU, WELCTL MPSP P Dry rod in BPV. 0.0 0.0 11/22/2021 10:30 11/22/2021 11:00 0.50 MIRU, WELCTL PRTS P Pressure test BPV from below T/ 1000 PSI for 10 Min - good test. 0.0 0.0 11/22/2021 11:00 11/22/2021 11:30 0.50 MIRU, WHDBOP RURD P R/D B/D circulating equipment. 0.0 0.0 11/22/2021 11:30 11/22/2021 15:30 4.00 MIRU, WHDBOP NUND P N/D tree, adapter. Function LDS. Dress hanger @ install blanking plug, screwed in 10 3/4 turns. 9 LH turns T/ M/U Acme. Top of blanking plug 1.15' 0.0 0.0 11/22/2021 15:30 11/22/2021 22:30 7.00 MIRU, WHDBOP NUND P N/U DSA, Stack. Change out flow block on kill side to block with rotating flange. Get RKB measurements. Change-out TD saver sub to 4" XT-39, Install riser. 0.0 0.0 11/22/2021 22:30 11/23/2021 00:00 1.50 MIRU, WHDBOP RURD P RU to test BOPE, MU 3.5" Test Joint 0.0 0.0 11/23/2021 00:00 11/23/2021 02:30 2.50 MIRU, WHDBOP BOPE P Initial BOPE test at 250/3500 PSI for 5 Min each, Tested annular, Upper 2-7/8 x 5 VBR w/ 3 1/2" test joint. Choke manifold valves 1-11, 16, 2” Demco, HCR Kill, Man Kill, Super choke and manual choke. "AOGCC Rep. Jeff Jones waived witness Test. 11/21/21 7:15 AM 0.0 0.0 11/23/2021 02:30 11/23/2021 04:30 2.00 MIRU, WHDBOP BOPE P Lock down screw dripping, Continue testing choke manifold, valves 12 and 13 and dart valve while FMC service LDS 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 CONFIDENTIALCONFIDENTIALCONFIDENTIAL( ith Ti l D th ) Page 2/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/23/2021 04:30 11/23/2021 09:00 4.50 MIRU, WHDBOP BOPE P Continue Test BOPE with 3.5" test Jt. Lower 3.5" x 5.5" VBR, Koomy drawdown test, test blind rams, Manifold valves 14 and 15 , Upper and lower IBOPs, With 4.5" test joint, test upper and lower VBR's, Man and HCR choke, TIW, gas alarms, PVT and flow show. 0.0 0.0 11/23/2021 09:00 11/23/2021 10:00 1.00 SLOT, WELLPR RURD P Retrieve blanking plug, RD test JT, blow down lines 0.0 0.0 11/23/2021 10:00 11/23/2021 10:45 0.75 SLOT, WELLPR MPSP P Pull BPV with dry rod, OWFF 0.0 0.0 11/23/2021 10:45 11/23/2021 12:30 1.75 SLOT, WELLPR RURD P Rig up equipment to L/D 3 1/2 tubing. 7,478.0 7,445.0 11/23/2021 12:30 11/23/2021 13:00 0.50 SLOT, WELLPR THGR P MU landing Jt, BOLDS, Pull Hgr to floor with 120K initial, dropped to 70K, LD Hgr and Lndg Jt 7,478.0 7,445.0 11/23/2021 13:00 11/23/2021 14:00 1.00 SLOT, WELLPR CIRC P Circ. B/U @ 256gpm. 750 psi. 7,445.0 7,445.0 11/23/2021 14:00 11/23/2021 15:00 1.00 SLOT, WELLPR RURD P Back ups on the tongs were frozen and not dressed out with the correct size. 7,445.0 7,445.0 11/23/2021 15:00 11/24/2021 00:00 9.00 SLOT, WELLPR PULD P LD 3-1/2" Tubing 7,445.0 2,800.0 11/24/2021 00:00 11/24/2021 02:30 2.50 SLOT, WELLPR PULD P LD 3-1/2" Tubing. Complete recovery. 237 Jts, 16.17' cut-off ,2 GLM's, 2 pups and hanger w/ pup. Began seeing pitting on collars last 800' LD, 3rd jt below lower GLM had some pitting on tube 2,800.0 0.0 11/24/2021 02:30 11/24/2021 03:30 1.00 SLOT, WELLPR RURD P RD Tbg equip 0.0 0.0 11/24/2021 03:30 11/24/2021 04:30 1.00 SLOT, WELLPR OTHR P Install wear bushing 0.0 0.0 11/24/2021 04:30 11/24/2021 10:00 5.50 SLOT, WELLPR BHAH P PU and MU Baker scraper assy 0.0 751.0 11/24/2021 10:00 11/24/2021 18:00 8.00 SLOT, WELLPR PULD P Single in the hole with scraper assy. on 4" DP, tag 3.5" tubing stump at 7475' drill pipe measure. 751.0 7,475.0 11/24/2021 18:00 11/24/2021 20:00 2.00 SLOT, WELLPR CIRC P Std back one std to 7376' , circulate at 7 bpm, 1780 psi, rotate 60 rpm at 5K tq and reciprocate scraper from 7364' to 7268' 7,475.0 7,280.0 11/24/2021 20:00 11/24/2021 23:30 3.50 SLOT, WELLPR TRIP P POOH on trip tank to 751'. 10 min flow check 7,280.0 751.0 11/24/2021 23:30 11/25/2021 00:00 0.50 SLOT, WELLPR BHAH P LD BHA 751.0 78.0 11/25/2021 00:00 11/25/2021 01:30 1.50 SLOT, WELLPR BHAH P LD BHA, clear/clean floor 78.0 0.0 11/25/2021 01:30 11/25/2021 02:00 0.50 SLOT, WELLPR SVRG P Service rig 0.0 0.0 11/25/2021 02:00 11/25/2021 06:00 4.00 SLOT, WELLPR RURD P Spot Eline unit, RU Eline 0.0 0.0 11/25/2021 06:00 11/25/2021 13:00 7.00 SLOT, WELLPR ELOG P Perform USIT/CCL log run in casing evaluation mode 0.0 0.0 11/25/2021 13:00 11/25/2021 15:00 2.00 SLOT, WELLPR ELOG P Evaluate logs with town. CIBP set depth @ ˜7320’ 0.0 0.0 11/25/2021 15:00 11/25/2021 16:30 1.50 SLOT, WELLPR ELOG P M/U CIBP on E-line 0.0 0.0 11/25/2021 16:30 11/25/2021 20:00 3.50 SLOT, WELLPR ELOG P RIH and set CIBP @ 7,320' Center of element (Run speed 80' min), POOH w/ Eline/setting tool to surface 0.0 0.0 11/25/2021 20:00 11/25/2021 20:30 0.50 SLOT, WELLPR PRTS P RU and pressure test casing to 2030 psi for 10 min, RD 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 CONFIDENTIALCONFIDENTIALCONFIDENTIAL( ith Ti l D th ) Page 3/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/25/2021 20:30 11/25/2021 21:30 1.00 SLOT, WELLPR ELOG P RD E-Line 0.0 0.0 11/25/2021 21:30 11/26/2021 00:00 2.50 PROD1, WHPST BHAH P MU whipstock BHA, orient MWD to WS face 0.0 113.0 11/26/2021 00:00 11/26/2021 01:30 1.50 PROD1, WHPST BHAH P MU whipstock BHA. 113.0 853.0 11/26/2021 01:30 11/26/2021 02:30 1.00 PROD1, WHPST DHEQ P RIH, Shallow hole test MWD (Good Test) 853.0 2,230.0 11/26/2021 02:30 11/26/2021 11:00 8.50 PROD1, WHPST WPST P Continue RIH w/ whipstock on 4" DP to 7,229 2,230.0 7,229.0 11/26/2021 11:00 11/26/2021 11:30 0.50 PROD1, WHPST CIRC P Break circulation @ 278 gpm 1280 psi. P/U= 105k S/O= 73k. Orient tool Face to 125. 7,229.0 7,229.0 11/26/2021 11:30 11/26/2021 12:00 0.50 PROD1, WHPST OTHR P Slack off to 7,319, recheck orientain. S/O and set the K anchor with 18K down wt. and shear out with 40k. Top of the wipstock 7,301' 7,229.0 7,319.0 11/26/2021 12:00 11/26/2021 14:00 2.00 PROD1, WHPST DISP P Displace well over from 10.1 ppg. NaCl to 10.0 ppg. LSND @ 280 gpm 1209 psi. 7,319.0 7,319.0 11/26/2021 14:00 11/26/2021 15:30 1.50 PROD1, WHPST WPST P Milling window f/ 7301' to 7303': @ 191 gpm, 975 psi. 80 rpm. 4.2k Tq. P/U= 105k S/O= 73 ROT= 83k O/A PSI= 0 7,301.0 7,303.0 11/26/2021 15:30 11/26/2021 20:00 4.50 PROD1, WHPST WPST P Milling window f/ 7303' to 7337': @ 191 gpm, 975 psi. 100 rpm. 4.7k Tq. P/U= 105k S/O= 73 ROT= 83k. Pumped high vis super sweep at 7314' Window 7301'-7314' O/A PSI= 0 7,303.0 7,314.0 11/26/2021 20:00 11/26/2021 21:00 1.00 PROD1, WHPST WPST P Milled 23' of rathole to 7337', Gives 3' gauge hole below BOW. 220 gpm, 1290 psi, 100 rpm, 4.6k tq, P/U= 110k S/O= 75 ROT= 80k 7,314.0 7,337.0 11/26/2021 21:00 11/26/2021 22:00 1.00 PROD1, WHPST CIRC P Circulated high vis super sweep around while dress window 4x. 220 gpm, 1290 psi, 100 rpm, 4.6k tq, P/U= 110k S/O= 75 ROT= 80k. Drift window no pump, no rotary, good. 7,337.0 7,268.0 11/26/2021 22:00 11/27/2021 00:00 2.00 PROD1, WHPST TRIP P Flow check, POOH on trip tank 7,268.0 4,153.0 11/27/2021 00:00 11/27/2021 03:00 3.00 PROD1, WHPST TRIP P POOH on trip tank, flow check 4,153.0 853.0 11/27/2021 03:00 11/27/2021 06:00 3.00 PROD1, WHPST BHAH P LD window milling assy, 853.0 0.0 11/27/2021 06:00 11/27/2021 07:30 1.50 PROD1, WHPST RURD P Clear and clean floor, stage BHA on floor, Jet BOPE stack, Flush Kill and Choke lines. 0.0 0.0 11/27/2021 07:30 11/27/2021 08:00 0.50 PROD1, WHPST SVRG P Service Top Drive, Reposition Rotary hose. 0.0 0.0 11/27/2021 08:00 11/27/2021 13:00 5.00 PROD1, WHPST BHAH P BHA: Make up motor to bit, make up and mwd, load source, run in HWDP 0.0 913.0 11/27/2021 13:00 11/27/2021 15:00 2.00 PROD1, WHPST PULD P RIH, Pick up 18 jnt of DP 913.0 1,489.0 11/27/2021 15:00 11/27/2021 16:30 1.50 PROD1, WHPST DHEQ T Shallow hole test directional tools. 1,489.0 1,489.0 11/27/2021 16:30 11/27/2021 18:00 1.50 PROD1, WHPST TRIP T MWD Failed POOH, rack HWDP/Jars 1,489.0 186.0 11/27/2021 18:00 11/27/2021 20:00 2.00 PROD1, WHPST BHAH T Pull source, Change out Digiscope, orient to motor 186.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 CONFIDENTIALCONFIDENTIALCONFIDENTIAL( ith Ti l D th ) Page 4/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/27/2021 20:00 11/27/2021 21:30 1.50 PROD1, WHPST BHAH T MU LWD, load source 0.0 141.0 11/27/2021 21:30 11/27/2021 22:30 1.00 PROD1, WHPST TRIP T RIH HWDP/Jars and DP stds from derrick to 1489' 141.0 1,489.0 11/27/2021 22:30 11/27/2021 22:45 0.25 PROD1, WHPST DHEQ P Shallow hole test MWD ok 1,489.0 1,489.0 11/27/2021 22:45 11/28/2021 00:00 1.25 PROD1, WHPST PULD P RIH picking up 24 more Jts DP to 1943' 1,489.0 1,943.0 11/28/2021 00:00 11/28/2021 02:30 2.50 PROD1, WHPST TRIP P RIH with drilling assy 7251' 1,943.0 7,251.0 11/28/2021 02:30 11/28/2021 03:30 1.00 PROD1, WHPST TRIP P Orient TF, RIH through window to 7320', smooth, wash to bottom at 7337' 7,251.0 7,337.0 11/28/2021 03:30 11/28/2021 03:45 0.25 PROD1 , DRILL DDRL P Drill from 7337' MD to 7341' MD, 213 gpm, 1640 psi. AST=.17, ART= 0, ADFT=.17 hrs 7,337.0 7,341.0 11/28/2021 03:45 11/28/2021 04:45 1.00 PROD1 , DRILL RGRP T Pull std, rack back, repair TD brake, RIH to btm 7,341.0 7,341.0 11/28/2021 04:45 11/28/2021 12:00 7.25 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,341'- 7400' MD, 3713' TVD, 200 gpm, 1630 psi, FO 32%, WOB K, off bottom 1800 psi, PU 95, SO 65K, AST=8.03 , ADT 8.03, BIT=8.03, JARS=8.03 7,341.0 7,400.0 11/28/2021 12:00 11/28/2021 16:00 4.00 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,400'- 7416' MD, 3723' TVD, 200 gpm, 2100 psi, FO 32%, WOB 16K, off bottom 1900 psi, PU 95, SO 65K, AST=3.05 , ADT 11.08, BIT=11.08, JARS=11.08 7,400.0 7,416.0 11/28/2021 16:00 11/28/2021 19:30 3.50 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,416'- 7442' MD, 3739' TVD, 200 gpm, 2170 psi on/ 2010 psi off, FO 32%, 30RPM, 5.5K tq on, 5.0K tq off, WOB 16K, PU 95, SO 65K, ROT 80K, AST=0, ART= 3.62 , ADT 18.32, BIT=18.32, JARS=18.32 7,416.0 7,442.0 11/28/2021 19:30 11/29/2021 00:00 4.50 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,442'- 7608' MD, 3739' TVD, 200 gpm, 2170 psi on/ 2010 psi off, FO 32%, 13.73 ECD, 40RPM, 5.5K tq on, 5.0K tq off, WOB 18K, PU 95, SO 65K, ROT 80K, AST=2.92, ART= 1.17 , ADT= 4.09TADT 18.32, BIT=18.7, JARS=18.7 7,442.0 7,608.0 11/29/2021 00:00 11/29/2021 06:00 6.00 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,608'- 7695' MD, 3,852' TVD, 240 gpm, 2580 psi on/ 2450 psi off, FO 32%, 12.91 ECD, 40RPM, 5.5K tq on, 5.0K tq off, WOB 18K, PU 105, SO 80K, ROT 85K, 7,608.0 7,695.0 11/29/2021 06:00 11/29/2021 12:00 6.00 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,695'- 7,754' MD, 3,968' TVD, 240 gpm, 2820 psi on/ 2450 psi off, FO 32%, 12.91 ECD, 40RPM, 5.5K tq on, 5.0K tq off, WOB 20K, PU 100, SO 80K, ROT 85K, 7,695.0 7,754.0 11/29/2021 12:00 11/29/2021 14:30 2.50 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,754'- 7,784' MD, 3,993 TVD, 240 gpm, 2750 psi on/ 2520 psi off, FO 32%, 12.91 ECD, WOB 18-23K, PU 100, SO 65K 7,754.0 7,784.0 11/29/2021 14:30 11/29/2021 19:30 5.00 PROD1 , DRILL SIPB T Flow observed with pumps off, shut in well. SIDPP 260 psi, SICP 340 psi, CBU through choke adjusting choke to maintain min losses, no light fluid or hydrocarbons observed. 7,784.0 7,784.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 CONFIDENTIALCONFIDENTIALCONFIDENTIAL( ith Ti l D th ) Page 5/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 11/29/2021 19:30 11/29/2021 23:00 3.50 PROD1 , DRILL SIPB T Bleed off ~2 bbls twice minimal pressure decrease, circ and warm up lines, bleed off 10 bbls twice, decreasing shut in pressures observed, CBU, no light fluids or hydrocarbons observed, bleed off 20 bbls, then attempt another 20 bbls, observing decreasing flow back trend, stop at 12 bbl gain due to time/cold, Decreasing trends observed indiicative of wellbore breathing. 7,784.0 7,784.0 11/29/2021 23:00 11/30/2021 00:00 1.00 PROD1 , DRILL SIPB T Circ and warm up lines, take on fluid, once fluid on and volumes stabilized, open choke 100% while circ at 2 bpm, gained 3 bbls then stabilized 7,784.0 7,784.0 11/30/2021 00:00 11/30/2021 00:30 0.50 PROD1 , DRILL SIPB T Pump off with choke open 100%, observed decreasing flow back trend. 2 bpm initial to .25 bpm final, open annular, slight flow observed 7,784.0 7,784.0 11/30/2021 00:30 11/30/2021 01:00 0.50 PROD1 , DRILL SIPB T Circulate at 2bpm to warrm lines, take on remainder of mud, blow down choke line, 7,784.0 7,784.0 11/30/2021 01:00 11/30/2021 02:15 1.25 PROD1 , DRILL SIPB T Stage up pump rate to drilling rate,240 gpm, 12.45 ECD minimal losses, shakers running wet, simulate connection 2X to obtain flow back signature 7,784.0 7,784.0 11/30/2021 02:15 11/30/2021 06:00 3.75 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 7,784'- t/7,842' MD, 4000 TVD, 240 gpm, 2300psi. 2200 psi. off 7,784.0 7,842.0 11/30/2021 06:00 11/30/2021 12:00 6.00 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/' 7,784’ – 8,119' MD, 4320' TVD, 240 gpm, 2820 psi on/ 2450 psi off, FO 32%, 12.67 ECD, 40RPM, 5.5K tq on, 5.0K tq off, WOB 20K, PU 100, SO 80K, ROT 85K, 7,842.0 8,119.0 11/30/2021 12:00 11/30/2021 18:00 6.00 PROD1 , DRILL DDRL P Directional drill 6 1/8" production section f/ 8,119'-8425' MD, 4645' TVD, 240 gpm, 2150 psi on/ 2050 psi off, FO 32%, 12.64 ECD, 40RPM, 7.3K tq on, 6.5K tq off, WOB 2-4K, PU 130, SO 75K, ROT 98K, 8,119.0 8,425.0 11/30/2021 18:00 12/1/2021 00:00 6.00 PROD1 , DRILL DDRL P TD 6 1/8" production section f/ 8425' - 8724' MD, 4944'TVD, 220 gpm, 2050 psi on/ 1930 psi off, FO 32%, 12.58 ECD, 40RPM, 7.3K tq on, 6.5K tq off, WOB 4-7K, PU 146 SO 88K, ROT 105K, 8,425.0 8,724.0 12/1/2021 00:00 12/1/2021 01:30 1.50 PROD1 , DRILL CIRC P Circulate and condition well, work DP, Survey, SPR #1 30 SPM=610 PSI 40 SPM=725 SPR #2 30 SPM=590 40 SPM=690. Empty cuttings tank. Load pits with fresh 10 PPG LSND Rack back stand 82, Pu single 31.14' 8,724.0 8,627.0 12/1/2021 01:30 12/1/2021 03:00 1.50 PROD1 , DRILL CIRC P Displace well over to clean 10ppg mud. 8,627.0 8,627.0 12/1/2021 03:00 12/1/2021 04:00 1.00 PROD1 , DRILL OWFF P Flow check for 30 minutes no flow. Load pits with 290 BBL's 10 PPG LSND for TOOH. 8,627.0 8,627.0 12/1/2021 04:00 12/1/2021 06:00 2.00 PROD1 , DRILL TRIP P TOOH from 8627' T/ 7382' Survey PUW= 105K 8,627.0 7,347.0 12/1/2021 06:00 12/1/2021 06:30 0.50 PROD1 , DRILL DLOG P Two Missed survey @ 7,347 & 7,382' 7,347.0 7,382.0 12/1/2021 06:30 12/1/2021 07:30 1.00 PROD1 , DRILL TRIP P TIH F/ 7,382' - T/7,740' 7,382.0 7,740.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 CONFIDENTIALCONFIDENTIALCONFIDENTIAL( ith Ti l D th ) Page 6/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/1/2021 07:30 12/1/2021 11:00 3.50 PROD1 , DRILL DLOG P MAD pass log from 7,740' - T/ 7,459' 30 rpm 240 gpm 3.3 fpm pulling speed. 7,740.0 7,459.0 12/1/2021 11:00 12/1/2021 14:00 3.00 PROD1 , DRILL SLPC P Pull up throug the window to 7,243' . Slip and cut off drilling line 7,459.0 7,243.0 12/1/2021 14:00 12/1/2021 18:00 4.00 PROD1 , DRILL TRIP P TOOH F/7,243' - T/911.95' 7,243.0 913.1 12/1/2021 18:00 12/1/2021 18:15 0.25 PROD1 , DRILL OWFF P Observe well for flow. 913.1 913.1 12/1/2021 18:15 12/1/2021 18:45 0.50 PROD1 , DRILL BHAH P LD 2 singles and jars. 913.0 823.9 12/1/2021 18:45 12/1/2021 20:00 1.25 PROD1 , DRILL BHAH P Stand back HWDP. 823.9 186.3 12/1/2021 20:00 12/1/2021 23:00 3.00 PROD1 , DRILL BHAH P LD BHA Filter sub, collar, stabilizer, stage equipment and remove source. Bit gauged 6.125" 186.3 0.0 12/1/2021 23:00 12/1/2021 23:30 0.50 PROD1 , DRILL CLEN P Clean and clear rig floor 0.0 0.0 12/1/2021 23:30 12/2/2021 00:00 0.50 PROD1 , DRILL BOPE P Drain stack, pull bowl protector. 0.0 0.0 12/2/2021 00:00 12/2/2021 04:00 4.00 PROD1 , DRILL BOPE P Set test plug and 4" test joint, Tested annular preventer, HCR choke, HCR kill, and choke valve 7 to 250/3500 PSI for 5 minutes per AOGCC regulation. State witness waived by Lou Laubenstein. Re- set bowl protector. 0.0 0.0 12/2/2021 04:00 12/2/2021 05:00 1.00 PROD1 , DRILL RURD P Rig up to run 4.5 Liner. 0.0 0.0 12/2/2021 05:00 12/2/2021 10:30 5.50 COMPZ1, CASING PUTB P Pick up shoe track and test floats (good test) TIH with 4 ½ 12.6# L-80 Hyd. 563 Liner 0.0 1,191.0 12/2/2021 10:30 12/2/2021 13:30 3.00 COMPZ1, CASING OTHR P Pick up Packer3 1,191.0 1,191.0 12/2/2021 13:30 12/2/2021 16:00 2.50 COMPZ1, CASING OTHR P Drift HWDP out ofthe derrick (Drift froze in third stand off HWDP) 1,191.0 1,515.0 12/2/2021 16:00 12/3/2021 00:00 8.00 COMPZ1, CASING RUNL P TIH with 4 ½ 12.6# L-80 Hyd. 563 Liner on 4" DP. F/1515 T/8700' filling every 20 stands. PU 1 single and 4 5' pups. Spot in cementers and support trucks. Clean pill pit. 1,515.0 8,700.0 12/3/2021 00:00 12/3/2021 01:00 1.00 COMPZ1, CASING RUNL P RIH with liner from 8700 to 8714' MU Cement head to DP. PUW-=125K SOW=80K 8,700.0 8,714.0 12/3/2021 01:00 12/3/2021 04:30 3.50 COMPZ1, CASING CIRC P Condition well PR=37 SPM DP=640 PSI. Circulate SxS 0.0 0.0 12/3/2021 04:30 12/3/2021 08:00 3.50 COMPZ1, CASING CMNT P 15 bbl. of H2O, test surface lines to 2000 psi. (good test) pump 25bbl. Tuned Spacer with red die @ 4BPM, 900 PSI, 32% F/, Start batching . Pump 37.8 bbls of 15.8 ppg G blend. cement at 4 bpm, psi, F/O 32%. Drop top plug swap over & kick out with 25 bbls 10.1 duo-vis pill. displace w/ 10.1 ppg LSND @ 3 bpm, 635 psi, F/O 32%. Reduced rate to 2 bpm 435 psi. Bump plug with 1.3 over calculated . final circ. psi. 1848 Pressure up to 2000 hold for 5 minutes. Bleed off pressure, Check floats good. CIP 05:52 hrs 12/03/21. No losses, 0.0 0.0 12/3/2021 08:00 12/3/2021 09:00 1.00 COMPZ1, CASING HOSO P Set ZXP Top Liner packer, 0.0 0.0 12/3/2021 09:00 12/3/2021 10:00 1.00 COMPZ1, CASING CIRC P Circ. B/U. 5bbl. of cement was observed at surface 0.0 0.0 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 CONFIDENTIALCONFIDENTIALCONFIDENTIAL( ith Ti l D th ) Page 7/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/3/2021 10:00 12/3/2021 11:00 1.00 COMPZ1, CASING RURD P Rig down cement head 0.0 0.0 12/3/2021 11:00 12/3/2021 11:30 0.50 COMPZ1, CASING PRTS P Rig up and test packer to 2000 psi. hold for 10 min. 0.0 0.0 12/3/2021 11:30 12/3/2021 16:00 4.50 COMPZ1, CEMENT TRIP P POOH racking back D/P & HWDP and L/D Runnning Tool 0.0 0.0 12/3/2021 16:00 12/3/2021 17:00 1.00 COMPZ1, CEMENT BHAH P P/U M/U Polishing Mill BHA. 0.0 0.0 12/3/2021 17:00 12/3/2021 21:00 4.00 COMPZ1, CEMENT MILL P TIH to the Top of the PBR @ 7,125' 0.0 7,125.0 12/3/2021 21:00 12/3/2021 21:45 0.75 COMPZ1, CEMENT MILL P Tag No-Go at liner top at 7126' PU=125 top of liner at 7130' Establish milling parameters. PUW= 120 SOW=60 Rot Tq=6.3 at 40 RPM Rot Tq = 6.7K at 60 RPM 200 GPM=1400 PSI 300 GPM=1400 PSI Dressed PBR 3 times at 40 RPM 300 GPM Rot Tq=5K SOW=74K, 1200 PSI 7,125.0 12/3/2021 21:45 12/3/2021 22:30 0.75 COMPZ1, CEMENT CIRC P Stopped rotating, picked mill up off top of PBR. Reciprocate DP roll well over to 9.4PPG corrosion inhibited NaCl brine. 12/3/2021 22:30 12/4/2021 00:00 1.50 COMPZ1, CEMENT SVRG T Replace service loop on Top-drive. 12/4/2021 00:00 12/4/2021 13:00 13.00 COMPZ1, CEMENT SVRG T Replace service loop on Top-drive. steam out trip tank and clean pits. Clean and clear rig floor for L/D DP. 7,105.0 7,105.0 12/4/2021 13:00 12/4/2021 21:30 8.50 COMPZ1, CEMENT PULD P L/D 4" DP & HWDP 7,105.0 25.0 12/4/2021 21:30 12/4/2021 22:00 0.50 COMPZ1, CEMENT BHAH P L/D BHA 25.0 0.0 12/4/2021 22:00 12/4/2021 22:30 0.50 COMPZ1, CEMENT CLEN P Clean and clear floor, Pull bowl protector, Jet BOP stack 0.0 0.0 12/4/2021 22:30 12/4/2021 23:00 0.50 COMPZ1, CEMENT SVRG P Service top drive 0.0 0.0 12/4/2021 23:00 12/5/2021 00:00 1.00 COMPZ1, CEMENT RURD P Move 3rd party equip. to floor, SLB spooler unit, I wire clamps, ETC. 0.0 0.0 12/5/2021 00:00 12/5/2021 02:00 2.00 COMPZ1, CEMENT RURD P Continue to set up floor to run completion. Clean Pits. 0.0 0.0 12/5/2021 02:00 12/5/2021 19:00 17.00 COMPZ1, RPCOMP RCST P RIH W/4-1/2" 12.6# L-80 Hyd 563 completion. F surface T/7127' Tagged on No-Go, Bottom of seals at 7143' PUW=95K SOW=50K 0.0 7,143.0 12/5/2021 19:00 12/6/2021 00:00 5.00 COMPZ1, RPCOMP HOSO P Spaced out completion .83' off tag, bottom of seals at 7143.61'. MU Pup joints 7.87', 7.87', 7.88', 5.79'. OAL= 29.41' Space out pups. PU Hanger and landing joint terminate I-wire. Test termination at hanger to 5000 psi for 10 minutes. Verify continuity on gauge. 7,143.0 7,143.6 12/6/2021 00:00 12/6/2021 01:00 1.00 COMPZ1, RPCOMP HOSO P Land tubing hanger RILDS torque to 450 Ft/Lbs. 7,143.6 7,143.6 12/6/2021 01:00 12/6/2021 03:30 2.50 COMPZ1, RPCOMP PRTS P Pressure test tubing to 3500 PSI for 30 Minutes. Bled pressure back to 1500 PSI on tubing pressured 7" casing up to 2150 PSI tested for 30 minutes. 7,143.6 7,143.6 12/6/2021 03:30 12/6/2021 04:30 1.00 COMPZ1, RPCOMP RURD P Rig down test equipment set BPV test from below to 1000 psi for 10 minutes good. 7,143.6 7,143.6 12/6/2021 04:30 12/6/2021 12:00 7.50 COMPZ1, RPCOMP OTHR P Perform between well maintenance on BOPE 7,143.6 7,143.6 Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 CONFIDENTIALCONFIDENTIALCONFIDENTIAL( ith Ti l D th ) Page 8/8 3S-24 Report Printed: 1/3/2022 Operations Summary (with Timelog Depths) Job: DRILLING SIDETRACK Time Log Start Time End Time Dur (hr) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 12/6/2021 12:00 12/6/2021 15:00 3.00 COMPZ1, WHDBOP NUND P N/D BOPE 7,143.6 7,143.6 12/6/2021 15:00 12/7/2021 00:00 9.00 COMPZ1, WHDBOP NUND P NU adpater and tree test, adapter to 5000 PSI. Terminate and test I-wire. 7,143.6 7,143.6 12/7/2021 00:00 12/7/2021 01:00 1.00 COMPZ1, WHDBOP NUND P NU tree and tested to 5000 PSI for 10 minutes. 7,143.6 7,143.6 12/7/2021 01:00 12/7/2021 02:00 1.00 COMPZ1, WHDBOP NUND P Pulled HP-BPV. 12/7/2021 02:00 12/7/2021 03:30 1.50 COMPZ1, WHDBOP FRZP P Pumped 68 BBLS freeze protect down annulus. U-Tube well till 0 psi on tubing and IA. Blow down and disconnect hardline from tree and wellhead. 12/7/2021 03:30 12/7/2021 04:30 1.00 COMPZ1, WHDBOP MPSP P Set 4" H-BPV in tubing hanger. Rig released Rig: NABORS 7ES RIG RELEASE DATE 12/8/2021 CONFIDENTIALCONFIDENTIALCONFIDENTIAL( ith Ti l D th ) CONFIDENTIAL CONFIDENTIALCCCCCOOOOOCCCCCCOOOOOOO CONFIDENTIALCCCCCOOOOOCCCCCCOOOOOOO Not a Survey(Interpolated) CCCCCOOOOOCCCCCCOOOOOOO Not a Survey(Interpolated) CONFIDENTIALCCCCCOOOOOCCCCCCOOOOOOO Page 1/1 3S-24 Report Printed: 1/4/2022 Cement Detail Report Cement Details Description Production String 2 Cement Cementing Start Date 12/3/2021 03:30 Cementing End Date 12/3/2021 06:00 Wellbore Name 3S-24B Comment 15 bbl. of H2O, test surface lines to 2000 psi. (good test) pump 25bbl. Tuned Spacer with red die @ 4BPM, 900 PSI, 32% F/, Start batching . Pump 37.8 bbls of 15.8 ppg G blend. cement at 4 bpm, psi, F/O 32%. Drop top plug swap over & kick out with 25 bbls 10.1 duo-vis pill. displace w/ 10.1 ppg LSND @ 3 bpm, 635 psi, F/O 32%. Reduced rate to 2 bpm 435 psi. Bump plug with 1.3 over calculated . final circ. psi. 1848 Pressure up to 2000 hold for 5 minutes. Bleed off pressure, Check floats good. CIP 05:52 hrs 12/03/21. No losses, 5bbl. of cement to surface. Cement Stages Stage # 1 Description Production String 2 Cement Objective Top Depth (ftKB) 7,550.0 Bottom Depth (ftKB) 8,724.0 Full Return? Yes Vol Cement … 5.0 Top Plug? Yes Btm Plug? No Q Pump Init (bbl/m… 4 Q Pump Final (bbl/… 1 Q Pump Avg (bbl/… 4 P Pump Final (psi) 1,548.0 P Plug Bump (psi) 1,884.0 Recip? Yes Stroke (ft) 30.00 Rotated? No Pipe RPM (rpm) Tagged Depth (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 5 bbl. of H2O, test surface lines to 2000 psi. (good test) pump 25bbl. Tuned Spacer with red die @ 4BPM, 900 PSI, 32% F/, Start batching . Pump 37.8 bbls of 15.8 ppg G blend. cement at 4 bpm, psi, F/O 32%. Drop top plug swap over & kick out with 25 bbls 10.1 duo-vis pill. displace w/ 10.1 ppg LSND @ 3 bpm, 635 psi, F/O 32%. Reduced rate to 2 bpm 435 psi. Bump plug with 1.3 over calculated . final circ. psi. 1848 Pressure up to 2000 hold for 5 minutes. Bleed off pressure, Check floats good. CIP 05:52 hrs 12/03/21. No losses, 5bbl. of cement to surface. Cement Fluids & Additives Fluid Fluid Type Tail Cement Fluid Description Estimated Top (ftKB) 7,126.0 Est Btm (ftKB) 8,724.0 Amount (sacks) 165 Class G Volume Pumped (bbl) 37.8 Yield (ft³/sack) 1.16 Mix H20 Ratio (gal/sa… 5.09 Free Water (%) Density (lb/gal) 15.80 Plastic Viscosity (cP) 123.0 Thickening Time (hr) 6.32 CmprStr 1 (psi) Additives Additive Type Concentration Conc Unit label String: Production String 2 Cement Job: DRILLING SIDETRACK, 11/21/2021 02:00 CONFIDENTIALCONFIDENTIALCONFIDENTIALtD t ilR t CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Hampton, Kyle To:Davies, Stephen F (OGC) Cc:Boyer, David L (OGC); Loepp, Victoria T (OGC) Subject:RE: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Date:Wednesday, December 15, 2021 8:30:26 PM Victoria Thanks for the call earlier. I’ll add a little more detail to my responses below. While pumping, if we were to see any rapid, significant pressure increase or decrease that is uncharacteristic of the reservoir behavior that suggested by our modeling, we will stop adding proppant to our fluids, go to flush (if the pressures and wellbore allow), and shut in the well after clearing proppant from the wellbore. Based on our extensive modeling of the reservoir and stimulation, we believe that we have a defined expectation for the stimulation and interaction with the reservoir; if anything is significantly out of those bounds, we will stop and evaluate before proceeding. Thanks, Kyle Hampton AKBU Completions | kyle.hampton@cop.com | cell. 832-491-7869 | office. 907-263-4627 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Hampton, Kyle To:Loepp, Victoria T (OGC) Subject:Fwd: [EXTERNAL]3S-24 SCMT log Date:Tuesday, December 14, 2021 11:03:49 AM Apologies. I intended to attach this to my earlier email. Kyle Completions Engineer AK 832-491-7869 From: Doherty, Dale R <Dale.R.Doherty@conocophillips.com> Sent: Monday, December 13, 2021 11:40:53 AM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Subject: RE: [EXTERNAL]3S-24 SCMT log Kyle 7,025 – 7,080’ Nearly Free Pipe 7,080 – 7,140’ Solids evident but Poor to No bond 7,140 – Top of Cement 7,140 – 7,180’ Areas of good to moderate bond – Provides Isolation 7,180 – 7,265’ Areas of very good bond with values approaching 4mV amplitude = Provides Isolation 7,265 – 7,300’ Area of Moderate bond – Provides Isolation 7,300 – 7,530’ Good bond averaging <6mV – Provides Isolation 7,530 – 7,552’ Very good bond with areas <2mV 7,552 – 7,775’ Good to Moderate bond Provides Isolation 7,775 – 7,870’ Poor bonding, possible formation response (See Gama) Isolation unknown 7,870 – 8,250’ Good to Moderate bonding – Provides Isolation 8,250 – 8,325’ Moderate to Poor bonding – Isolation unknown 8,325 – 8,480’ Poor to no bonding – Loss of isolation likely From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Sunday, December 12, 2021 8:22 PM To: Doherty, Dale R <Dale.R.Doherty@conocophillips.com> Subject: FW: [EXTERNAL]3S-24 SCMT log Dale These are the field prints from our CBL that we just ran on our 4.5” liner. Do you have any concerns with this? I’m a little surprised to see the drop off around 7850’ MD and then toward the bottom of the liner below 8400’ MD. Our perfs are at 7960’ MD, so I think we have plenty of coverage. It’s just not the results I was expecting. Thanks, Kyle Hampton AKBU Completions | kyle.hampton@cop.com | cell. 832-491-7869 | office. 907-263-4627 From: Ajay Pradhan <APradhan6@slb.com> Sent: Sunday, December 12, 2021 12:41 AM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com>; NSK E-line and DSL Field Supv <n2540@conocophillips.com> Cc: Blake Pentland <BPentland@slb.com> Subject: [EXTERNAL]3S-24 SCMT log CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Hello Kyle and Bryce, Please see attachment for the FIELD RUSH prints for the SCMT/CBL log preformed on 3S-24. Crew will have a late start tomorrow but we will try to get the finalized version in between our RST runs. 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7KH³6KRUW7HUP3UHVVXUH%XLOG8S´ZLOOIROORZWHQWDWLYHO\HTXDOLQGXUDWLRQWRWKH³+LJK5DWH &OHDQXS)ORZ3HULRG´ :LWKWKHZHOOWLHGLQWRWKH6SDGVHSDUDWRUDQGSURYHQWRWKHSRUWDEOHWHVWVHSDUDWRUWKH³([WHQGHG )ORZEDFN7HVW´ZLOOEHJLQ7KLVIORZSHULRGZLOOEHDWDORZHUGUDZGRZQWRKHOSOLPLWJDVEUHDNRXWWR DLGLQSUHVVXUHWUDQVLHQWDQDO\VLV'XULQJWKH³([WHQGHG)ORZEDFN7HVW´ZHZLOOFROOHFWSUHVVXUL]HG JDVDQGRLOVDPSOHVVWRFNWDQNRLODQGIRUPDWLRQZDWHULISUHVHQW7KLVSHULRGLVH[SHFWHGWRODVW GD\V $IWHUWKH³([WHQGHG)ORZEDFN7HVW´WKH'+6,7ZLOOEHFORVHGDQGWKH³/RQJ7HUP%XLOG8S3HULRG´ ZLOOEHJLQWRJDWKHUSUHVVXUHEXLOGXSGDWDIRUSUHVVXUHWUDQVLHQWDQDO\VLV6XUIDFHUHDGRXWGRZQKROH JDXJHVZLOOEHXVHGWRPRQLWRUWKHEXLOGXSUHVSRQVHLQQHDUUHDOWLPHWRGHWHUPLQHLIWKH³/RQJ7HUP %XLOG8S3HULRG´KDVODVWHGORQJHQRXJKWRUHDFKWKHLQILQLWHDFWLQJUDGLDOIORZSHULRGRIWKHSUHVVXUH EXLOGXS7KHUHDUHQRWLPHFRQVWUDLQWVWRWKHOHQJWKRIWKLVVKXWLQSHULRGEXWLWLVH[SHFWHGWRODVWD PLQLPXPRIGD\V 6DPSOH:HOO7HVWLQJ/D\RXW CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Loepp, Victoria T (OGC) To:Hampton, Kyle Subject:KRU 3S-24B Perforation Plan APPROVAL Date:Thursday, December 16, 2021 8:18:00 AM Kyle, Approval is granted to perforate as outlined below. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Wednesday, December 15, 2021 1:21 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: 3S-24B Perforation Plan Victoria, On 12/16,2021, we would like to perforate the interval 7,944’ MD – 7,953’ MD & 7,957’ MD – 7,963’ MD in 3S-24B. In order to confirm connection to the reservoir, we typically inject 20 bbls of diesel into the wellbore; we are also requesting to inject 20 bbls of diesel into 3S-24B. Aside from the information provided in the submitted sundry, please let me know if you need any additional information. Thanks, Kyle Hampton CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Hampton, Kyle To:Loepp, Victoria T (OGC) Subject:3S-24B Perforation Plan Date:Wednesday, December 15, 2021 1:21:30 PM Victoria, On 12/16,2021, we would like to perforate the interval 7,944’ MD – 7,953’ MD & 7,957’ MD – 7,963’ MD in 3S-24B. In order to confirm connection to the reservoir, we typically inject 20 bbls of diesel into the wellbore; we are also requesting to inject 20 bbls of diesel into 3S-24B. Aside from the information provided in the submitted sundry, please let me know if you need any additional information. Thanks, Kyle Hampton AKBU Completions | kyle.hampton@cop.com | cell. 832-491-7869 | office. 907-263-4627 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Davies, Stephen F (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Date:Wednesday, December 15, 2021 8:52:29 AM Please file. From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Tuesday, December 14, 2021 5:01 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Thanks Steve. I’m looking forward to any additional questions or discussions. Kyle Hampton AKBU Completions | kyle.hampton@cop.com | cell. 832-491-7869 | office. 907-263-4627 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Tuesday, December 14, 2021 4:16 PM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Kyle, Never mind about obtaining permission for me to download the 3S-24B LWD files, we were able to download them. Thanks again and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (OGC) Sent: Tuesday, December 14, 2021 3:42 PM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Kyle, Thanks for your replies. I’ll read through them and let you know if I have additional questions. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. We’ve tried, but failed, to download the LWD files on your share site. I apparently don’t have permission to set up an account there. I tried, but after adding my name and AOGCC affiliation, I was asked to establish a password for Dave Boyer’s email address. Can you help me find a way to obtain these digital well log data files? Thanks and stay safe, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Tuesday, December 14, 2021 2:18 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Steve Thanks for those additional questions. I should’ve checked my inbox before I hit send on those other responses. Again, response in red. Thanks, Kyle Hampton AKBU Completions | kyle.hampton@cop.com | cell. 832-491-7869 | office. 907-263-4627 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Tuesday, December 14, 2021 10:52 AM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Thank you Kyle. I had two additional questions for you: Because CPAI’s calculations indicate that the Coyote interval is not covered by cement in 3S-21 and 3S-24A, CPAI proposed to monitor the annulus between 7” and 9-5/8” casing during and immediately after the frac job for pressure communication. What measures will CPAI take if any change in annulus pressure be detected during fracturing operations? What actions will be taken if a change in annulus pressure is detected after the frac operations cease? CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. During frac: If a rapid annular pressure increase is seen in either 3S-21 or 3S-24A, we will stop pumping the job, flush the well, and shut-in to observe. There is some anticipated pressure increase due to temperatures and ballooning effect of the casing. Post frac: If there isn’t pressure observed during the frac but after the frac, we will monitor the pressures and bleed pressures down as necessary. If the pressures do not subside within a day on the well, we will have discussions at that point with the interventions team about a path forward. What mitigation measures will CPAI take if there are indications that an induced fracture has intersected a fault or natural-fracture interval during frac operations? Based on our seismic evaluation and formation evaluation, we do not see any major natural fractures near our well; the only mapped fracture is ~900’ away in a direction orthogonal to Shmax. Indications are that this fault does not translate out of our confining zone. In the event of a net pressure loss during the frac, we will have a difficult time distinguishing between the leak-off within zone versus pumping away into a fault that has the potential to communicate out of zone. Therefore, the prudent response to a net pressure loss would be to continue pumping, assume the leak-off is within zone, and complete the frac as premised. Thanks and stay safe, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Tuesday, December 14, 2021 9:49 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Steve, I uploaded the LWD logs to the ftp that was shared with Victoria and Dave. You should have access to that ftp site as well. I’ve answered the questions in red below in the body of the email. Thanks, Kyle Hampton AKBU Completions | kyle.hampton@cop.com | cell. 832-491-7869 | office. 907-263-4627 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Tuesday, December 14, 2021 8:35 AM CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Thank you Kyle. In addition to my request for digital well log data, I have a few more questions and requests. Perhaps I overlooked this information in the Sundry Application. How were CPAI’s expected fracture gradients for the confining and fracturing zones determined? We utilized offset wells that have drilled through the Coyote around the 3S pad and the data analysis that they performed (logs, LOT, FIT, and core) to calibrate a geomechanical model for the overburden and coyote formation. From these, we derived fracture gradients for these formations in this area. We then used the 3S-24B logs to further calibrate and inform the model. What are the height, length, MD and TVD to the top and base of the anticipated induced fractures? The modeled frac details: frac height=170’, frac half-length=380’; frac top = 7,880’ MD / 4,093’ TVD, frac base = 8,050’ MD / 4,260’ TVD. Please briefly describe the fracturing model used to determine these lengths and heights. We modeled this fracture in both StimPlan and GOHFER. We have a full log suite from our drilling of Palm 1, and we used these logs to perform a frac model sensitivity on the frac design. Our priorities for the model were providing an efficient, high conductivity fracture that stayed within the prime pay interval of the Coyote formation. This drove our volumes, fluid type, and proppant type to be pumped. Once we completed the open hole logs the 3S-24B sidetrack, we recalibrated the previous model, based on Palm 1, with the new logs from 3S-24B. We saw very little difference in the modeled frac behavior, but we were able to slightly adjust the perforation depths to those included in this sundry. Based on these studies, we believe that we have designed an optimized single stage fracture for the Coyote formation. What is the currently expected date of commencement for the fracturing operations? Anticipated frac date is now 12/17 based on the recent weather delays. Thanks and stay safe, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Monday, December 13, 2021 9:56 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Steve Thanks for the quick note back. It looks like there was a mistake on the locations; I have attached the corrected letter. The table below is the corrected locations. Location FNL FEL Township Range Section Meridian Surface 2565' 1266' 12N 8E 18 Umiat Top Open Interval 2007' 383' 12N 7E 24 Umiat Bottomhole 1987' 402' 12N 7E 24 Umiat I have also attached the final survey for the well. I was anticipating the final log .las files this evening, but we’re still waiting on some of the processing from SLB. As soon as I receive them in the morning, I’ll forward them along. Thanks, Kyle Hampton AKBU Completions | kyle.hampton@cop.com | cell. 832-491-7869 | office. 907-263-4627 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, December 13, 2021 12:01 PM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Kyle, I’m beginning the land administration and geology portions of AOGCC’s review of CPAI’s Sundry Application to frac 3S-24B. Since CPAI’s application was submitted this morning and the estimated date for commencing operations is Dec. 15th or 16th I’ll need your quick help. I notice in CPAI’s Affidavit that the location coordinates for the well are given as: But in CPAI’s Permit to Drill application the well location coordinates were given as: CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Some people who received this message don't often get email from kyle.hampton@conocophillips.com. Learn why this is important Please confirm which coordinates are correct. For the geologic portion of this review, could CPAI please provide a copy of the directional survey data recorded in KRU 3S-24B? Specifically, MD, azimuth, and inclination data in spreadsheet or ASCII comma- or tab-delimited table form would be most helpful to load into AOGCC’s geoscience workstation. Please also provide a copy of all open-hole or LWD logs recorded in KRU 3S-24B in .las, spreadsheet, or ASCII comma- or tab-delimited table form. Thanks and stay safe, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Monday, December 13, 2021 9:52 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov>; Buck, Brian R <Brian.R.Buck@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: 3S-24B Frac Sundry I have attached the final sundry for 3S-24B. We completed the CBL on the 4-1/2” liner this weekend, and we saw successful cement coverage to our liner top. The CBL has been uploaded to the file share (https://copsftp.sharefile.com/home/myfiles/fofd123f-348f-4c2b-bc1d-6bf1abff5a7e). We are looking to frac on Wednesday 12/15; please let me know if you have any questions or concerns. Thanks, Kyle Hampton AKBU Completions | kyle.hampton@cop.com | cell. 832-491-7869 | office. 907-263-4627 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Davies, Stephen F (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Date:Wednesday, December 15, 2021 9:01:34 AM Attachments:3S-24B Standard Survey Report 11 29 2021_12-1-2021_23-14-36.xlsx KRU 32-34B_FracNoticeLetter_121321.pdf Also for filing From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Monday, December 13, 2021 9:56 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests Steve Thanks for the quick note back. It looks like there was a mistake on the locations; I have attached the corrected letter. The table below is the corrected locations. Location FNL FEL Township Range Section Meridian Surface 2565' 1266' 12N 8E 18 Umiat Top Open Interval 2007' 383' 12N 7E 24 Umiat Bottomhole 1987' 402' 12N 7E 24 Umiat I have also attached the final survey for the well. I was anticipating the final log .las files this evening, but we’re still waiting on some of the processing from SLB. As soon as I receive them in the morning, I’ll forward them along. Thanks, Kyle Hampton AKBU Completions | kyle.hampton@cop.com | cell. 832-491-7869 | office. 907-263-4627 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Monday, December 13, 2021 12:01 PM To: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Cc: Boyer, David L (OGC) <david.boyer2@alaska.gov>; Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Subject: [EXTERNAL]KRU 3S-24B Frac Sundry (PTD 221-078) - Questions and Requests CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Some people who received this message don't often get email from kyle.hampton@conocophillips.com. Learn why this is important Kyle, I’m beginning the land administration and geology portions of AOGCC’s review of CPAI’s Sundry Application to frac 3S-24B. Since CPAI’s application was submitted this morning and the estimated date for commencing operations is Dec. 15th or 16th I’ll need your quick help. I notice in CPAI’s Affidavit that the location coordinates for the well are given as: But in CPAI’s Permit to Drill application the well location coordinates were given as: Please confirm which coordinates are correct. For the geologic portion of this review, could CPAI please provide a copy of the directional survey data recorded in KRU 3S-24B? Specifically, MD, azimuth, and inclination data in spreadsheet or ASCII comma- or tab-delimited table form would be most helpful to load into AOGCC’s geoscience workstation. Please also provide a copy of all open-hole or LWD logs recorded in KRU 3S-24B in .las, spreadsheet, or ASCII comma- or tab-delimited table form. Thanks and stay safe, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Monday, December 13, 2021 9:52 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov>; Buck, Brian R <Brian.R.Buck@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com> Subject: 3S-24B Frac Sundry CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. I have attached the final sundry for 3S-24B. We completed the CBL on the 4-1/2” liner this weekend, and we saw successful cement coverage to our liner top. The CBL has been uploaded to the file share (https://copsftp.sharefile.com/home/myfiles/fofd123f-348f-4c2b-bc1d-6bf1abff5a7e). We are looking to frac on Wednesday 12/15; please let me know if you have any questions or concerns. Thanks, Kyle Hampton AKBU Completions | kyle.hampton@cop.com | cell. 832-491-7869 | office. 907-263-4627 Exhibit 1 Exhibit 2 List of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Operator & Owner: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1226 P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Vincent Lelarge North Slope Development Manager Owner (Non-Operator): Non-Operators: Chevron U.S.A. Inc. 1400 Smith Street Room 40116 Houston, TX 77002 Attention: Gary Selisker, NOJV Advisor ExxonMobil Alaska Production Inc. 3700 CenterPoint, Suite 600 Anchorage, AK 99503 Attention: Lisa Cross Surface Owner: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director [3S-24B] Actual Survey Survey Report(Non-Def Survey)2.10.826.8CommentsMD(ft)Incl(°)Azim True(°)TVD(ft)TVDSS(ft)DLS(°/100ft)TF(°)VSEC(ft)NS(ft)EW(ft)Trav Cyl Dist Ct-Ct(ft)Trav Cyl Azim-North(°)Closure(ft)AD Survey Tool0.00 0.00 0.00 0.00 -55.70 0.00 0M 0.00 0.00 0.00 0.00 N/A 0.00PHOTO-GSS-Depth OnlyMarker MudLine28.00 0.00 0.00 28.00 -27.70 0.00 324M 0.00 0.00 0.00 0.00 N/A 0.00PHOTO-GSS-Depth Only88.62 0.45 324.00 88.62 32.92 0.74 303.36M -0.06 0.19 -0.14 0.00 N/A 0.24SLB_PHOTO-GSS16" Cond107.620.50 303.36 107.6251.920.94 267M -0.070.30 -0.25N/A N/A 0.39SLB_PHOTO-GSS178.62 1.00 267.00 178.61 122.91 0.94 221M 0.37 0.44 -1.13 0.00 N/A 1.21SLB_PHOTO-GSS269.62 3.10 221.00 269.55 213.85 2.76 204M 3.36 -1.46 -3.54 0.00 N/A 3.83SLB_PHOTO-GSS361.62 5.50 204.00 361.29 305.59 2.93 209.99M 10.11 -7.37 -6.97 0.00 N/A 10.14SLB_PHOTO-GSS477.39 9.25 209.99 476.08 420.38 3.30 11.67R 24.66 -20.50 -13.88 0.00 N/A 24.75SLB_MWD+GMAG566.64 12.27 212.91 563.76 508.06 3.44 9.72L 41.18 -34.68 -22.62 0.00 N/A 41.40SLB_MWD+GMAG656.92 17.34 210.01 651.01 595.31 5.67 2.41L 64.02 -54.39 -34.56 0.00 N/A 64.45SLB_MWD+GMAG749.58 22.30 209.46 738.16 682.46 5.36 8.67R 95.02 -81.68 -50.13 0.00 N/A 95.83SLB_MWD+GMAG838.95 24.96 210.42 820.03 764.33 3.01 2.83R 130.39 -112.71 -68.02 0.00 N/A131.64SLB_MWD+GMAG935.95 27.90 210.73 906.88 851.18 3.03 2.7R 173.10 -149.87 -89.98 0.00 N/A174.81SLB_MWD+GMAG1028.44 28.82 210.82 988.27 932.57 1.00 23.68R 216.58 -187.62 -112.46 0.00 N/A 218.74SLB_MWD+GMAG1119.05 30.63 212.37 1066.95 1011.25 2.17 0.94R 261.13 -225.87 -136.01 0.00 N/A 263.66SLB_MWD+GMAG1212.88 33.66 212.46 1146.39 1090.69 3.23 50.64R 310.72 -268.01 -162.77 0.00 N/A 313.57SLB_MWD+GMAG1309.97 35.73 216.63 1226.22 1170.52 3.24 37.64R 365.79 -313.48 -194.13 0.00 N/A 368.72SLB_MWD+GMAG1402.16 40.05 221.67 1298.98 1243.28 5.76 3.7L 422.35 -357.26 -229.94 0.00 N/A 424.86SLB_MWD+GMAG1494.65 45.82 221.15 1366.66 1310.96 6.25 7.1L 485.27 -404.50 -271.58 0.00 N/A 487.22SLB_MWD+GMAG1587.81 49.42 220.56 1429.45 1373.75 3.89 16.42L 554.04 -456.55 -316.58 0.00 N/A 555.58SLB_MWD+GMAG1684.36 52.44 219.44 1490.29 1434.59 3.25 6.06L 628.98 -513.98 -364.75 0.00 N/A 630.25SLB_MWD+GMAG1778.40 54.67 219.15 1546.16 1490.46 2.38 15.11R 704.62 -572.52 -412.65 0.00 N/A 705.73SLB_MWD+GMAG1872.56 58.80 220.45 1597.79 1542.09 4.54 3.15L 783.32 -632.98 -463.05 0.00 N/A 784.27SLB_MWD+GMAG1967.97 65.07 220.07 1642.66 1586.96 6.58 74.83R 867.45 -697.20 -517.43 0.00 N/A 868.23SLB_MWD+GMAG2062.13 65.64 222.31 1681.93 1626.23 2.25 165.05L 952.96 -761.59 -573.780.00 N/A 953.55SLB_MWD+GMAG2156.83 63.07 221.54 1722.91 1667.21 2.81 47.32R 1038.22 -825.10 -630.830.00 N/A 1038.62SLB_MWD+GMAGTotal Gravity Field Strength:1002.0052mgn (9.80665 Based)Total Corr Mag North->True North:Gravity Model:57294.747 nTDOXTotal Magnetic Field Strength:Magnetic Dip Angle:North Reference:80.714 °October 25, 2021BGGM 2021True North0.0000 °15.3933 °Grid Convergence Used:55.700 ft above Mean Sea LevelTVD Reference Elevation:Seabed / Ground Elevation:27.700 ft above Mean Sea LevelField:Report Date:Kuparuk River Unit - 2Client:ConocoPhillipsDecember 01, 2021 - 11:14 PMMinimum Curvature / Lubinski219.000 ° (True North)0.000 ft, 0.000 ftRotary TableSurvey / DLS Computation:TVD Reference Datum:Vertical Section Azimuth:Vertical Section Origin:UWI / API#:3S-24BStructure / Slot:Well:Borehole:501032045602 / 5010320456023S-24Kuparuk 3S Pad / 3S-24Location Grid N/E Y/X:NAD83 Alaska State Plane, Zone 04, US Feet218.880 ° / 6182.459 ft / 6.379 / 1.252Coordinate Reference System:Survey Name:[3S-24B] Actual SurveySurvey Date:Grid Scale Factor:Version / Patch:Well HeadLocal Coord Referenced To:15.393 °Magnetic Declination:Declination Date:0.99990068Magnetic Declination Model:N 70° 23' 38.49801", W 150° 11' 54.44958"Tort / AHD / DDI / ERD Ratio:CRS Grid Convergence Angle:October 25, 2021Location Lat / Long:-0.1870 °N 5993602.110 ftUS, E 1616025.580 ftUSDrilling Office 2.10.826.812/15/2021 9:03 AM Page 1 of 3 Kuparuk River Unit - 2\Kuparuk 3S Pad\3S-24\3S-24B\[3S-24B] Actual Survey #SchlumbergerͲPrivate CommentsMD(ft)Incl(°)Azim True(°)TVD(ft)TVDSS(ft)DLS(°/100ft)TF(°)VSEC(ft)NS(ft)EW(ft)Trav Cyl Dist Ct-Ct(ft)Trav Cyl Azim-North(°)Closure(ft)AD Survey Tool2250.70 65.49 224.39 1763.65 1707.95 3.76 23.78L 1122.56 -886.96 -688.470.00 N/A 1122.80SLB_MWD+GMAG2344.76 66.28 224.01 1802.08 1746.38 0.92 118.16R 1208.06 -948.51 -748.32 0.00 N/A 1208.16SLB_MWD+GMAG2438.66 65.68 225.25 1840.30 1784.60 1.36 47.88L 1293.41 -1009.54 -808.57 0.00 N/A 1293.43SLB_MWD+GMAG2534.26 67.56 223.02 1878.24 1822.54 2.91 58.08L 1380.80 -1072.52 -869.66 0.00 N/A 1380.80SLB_MWD+GMAG2628.63 68.30 221.75 1913.70 1858.00 1.47 105.29R 1468.10 -1137.12 -928.61 0.00 N/A 1468.11SLB_MWD+GMAG2722.02 68.01 222.91 1948.45 1892.75 1.19 95.01L 1554.64 -1201.20 -986.98 0.00 N/A 1554.68SLB_MWD+GMAG2814.75 67.89 221.34 1983.27 1927.57 1.57 51.54L 1640.45 -1264.95 -1044.63 0.00 N/A 1640.53SLB_MWD+GMAG2908.92 68.23 220.88 2018.45 1962.75 0.58 84.75L 1727.74 -1330.76 -1102.06 0.00 N/A 1727.85SLB_MWD+GMAG3004.65 68.38 219.22 2053.84 1998.14 1.62 168.87R 1816.67 -1398.85 -1159.29 0.00 N/A 1816.79SLB_MWD+GMAG3099.14 68.05 219.29 2088.91 2033.21 0.36 97.71R 1904.41 -1466.79 -1214.81 0.00 N/A 1904.53SLB_MWD+GMAG3194.06 68.03 219.45 2124.41 2068.71 0.16 95.86R 1992.45 -1534.84 -1270.65 0.00 N/A 1992.56SLB_MWD+GMAG3287.84 67.89 221.00 2159.60 2103.90 1.54 169.9R 2079.35 -1601.21 -1326.79 0.00 N/A 2079.48SLB_MWD+GMAG3382.52 67.32 221.11 2195.67 2139.97 0.61 65.36L 2166.83 -1667.22 -1384.28 0.00 N/A 2166.99SLB_MWD+GMAG3476.03 69.17 216.92 2230.34 2174.64 4.61 102.57L 2253.65 -1734.69 -1438.92 0.00 N/A 2253.81SLB_MWD+GMAG3569.62 69.04 216.29 2263.72 2208.02 0.64 74.89R 2341.01 -1804.88 -1491.06 0.00 N/A 2341.12SLB_MWD+GMAG3663.99 69.35 217.50 2297.24 2241.54 1.24 75.88L 2429.17 -1875.43 -1544.02 0.00 N/A 2429.25SLB_MWD+GMAG3757.94 69.49 216.91 2330.27 2274.57 0.61 68.92L 2517.08 -1945.48 -1597.20 0.00 N/A 2517.13SLB_MWD+GMAG3852.70 69.84 215.95 2363.20 2307.50 1.02 111.01R 2605.84 -2016.97 -1649.96 0.00 N/A 2605.87SLB_MWD+GMAG3943.35 68.90 218.63 2395.14 2339.44 2.95 21.34L 2690.63 -2084.46 -1701.35 0.00 N/A 2690.65SLB_MWD+GMAG4036.82 69.62 218.33 2428.24 2372.54 0.83 158.29L 2778.04 -2152.89 -1755.74 0.00 N/A 2778.05SLB_MWD+GMAG4128.41 68.06 217.66 2461.30 2405.60 1.83 133.63R 2863.44 -2220.20 -1808.32 0.00 N/A 2863.45SLB_MWD+GMAG4223.43 67.02 218.85 2497.60 2441.90 1.59 93.49L 2951.24 -2289.16 -1862.69 0.00 N/A 2951.25SLB_MWD+GMAG4317.49 66.94 217.29 2534.39 2478.69 1.53 52.12R 3037.79 -2357.31 -1916.07 0.00 N/A 3037.80SLB_MWD+GMAG4412.38 68.31 219.17 2570.51 2514.81 2.33 99.65L 3125.52 -2426.22 -1970.37 0.00 N/A 3125.53SLB_MWD+GMAG4469.09 68.14 218.07 2591.55 2535.85 1.83 46.33R 3178.18 -2467.37 -2003.24 0.00 N/A 3178.19SLB_MWD+GMAG9-5/8"4526.6268.74 218.74 2612.69 2556.99 1.50 46.09R 3231.68 -2509.30 -2036.48 N/A N/A 3231.69SLB_MWD+GMAG4568.41 69.17 219.22 2627.70 2572.00 1.50 111.11L 3270.69 -2539.61 -2061.01 0.00 N/A 3270.69SLB_MWD+GMAG4663.66 68.55 217.47 2662.06 2606.36 1.83 74.32L 3359.52 -2609.29 -2116.12 0.00 N/A 3359.52SLB_MWD+GMAG4760.09 68.70 216.90 2697.20 2641.50 0.57 126.74L 3449.27 -2680.83 -2170.40 0.00 N/A 3449.27SLB_MWD+GMAG4853.62 68.23 216.22 2731.53 2675.83 0.84 94.25R 3536.19 -2750.71 -2222.22 0.00 N/A 3536.19SLB_MWD+GMAG4949.57 68.04 219.43 2767.28 2711.58 3.11 90R 3625.20 -2821.03 -2276.82 0.00 N/A 3625.21SLB_MWD+GMAG5044.32 68.04 220.85 2802.71 2747.01 1.39 102.49L 3713.06 -2888.21 -2333.47 0.00 N/A 3713.06SLB_MWD+GMAG5140.44 67.71 219.20 2838.91 2783.21 1.63 98.67R 3802.08 -2956.39 -2390.73 0.00 N/A 3802.08SLB_MWD+GMAG5233.76 67.56 220.29 2874.42 2818.72 1.09 110.08L 3888.37 -3022.75 -2445.91 0.00 N/A 3888.37SLB_MWD+GMAG5328.20 67.17 219.12 2910.77 2855.07 1.22 154.9R 3975.53 -3089.80 -2501.59 0.00 N/A 3975.53SLB_MWD+GMAG5420.60 66.68 219.37 2946.99 2891.29 0.59 75.3R 4060.54 -3155.64 -2555.37 0.00 N/A 4060.54SLB_MWD+GMAG5515.21 67.48 222.54 2983.84 2928.14 3.20 98.82L 4147.61 -3221.43 -2612.48 0.00 N/A 4147.61SLB_MWD+GMAG5614.18 67.46 222.40 3021.76 2966.06 0.13 111.32L 4238.86 -3288.86 -2674.21 0.00 N/A 4238.87SLB_MWD+GMAG5709.39 66.89 220.79 3058.70 3003.00 1.67 22.99L 4326.52 -3354.49 -2732.46 0.00 N/A 4326.54SLB_MWD+GMAG5804.68 68.16 220.21 3095.12 3039.42 1.45 72.91R 4414.54 -3421.44 -2789.64 0.00 N/A 4414.56SLB_MWD+GMAG5899.14 68.18 220.28 3130.25 3074.55 0.07 94.42L 4502.21 -3488.37 -2846.29 0.00 N/A 4502.24SLB_MWD+GMAG5992.99 68.11 219.26 3165.19 3109.49 1.01 120.6L 4589.30 -3555.32 -2902.02 0.00 N/A 4589.34SLB_MWD+GMAG6086.85 67.75 218.60 3200.45 3144.75 0.76 89.61R 4676.28 -3622.98 -2956.67 0.00 N/A 4676.32SLB_MWD+GMAG6182.86 67.76 219.65 3236.80 3181.10 1.01 97.74L 4765.14 -3691.92 -3012.75 0.00 N/A 4765.18SLB_MWD+GMAG6277.10 67.59 218.25 3272.60 3216.90 1.39 109.81R 4852.32 -3759.72 -3067.55 0.00 N/A 4852.35SLB_MWD+GMAG6372.28 67.30 219.13 3309.11 3253.41 0.91 106.94L 4940.22 -3828.32 -3122.49 0.00 N/A 4940.25SLB_MWD+GMAG6466.91 67.23 218.88 3345.68 3289.98 0.25 42.71L 5027.49 -3896.15 -3177.42 0.00 N/A 5027.52SLB_MWD+GMAG6561.83 67.35 218.76 3382.33 3326.63 0.17 40.3L 5115.05 -3964.37 -3232.31 0.00 N/A 5115.08SLB_MWD+GMAG6656.45 67.59 218.54 3418.58 3362.88 0.33 40.66L 5202.45 -4032.62 -3286.90 0.00 N/A 5202.48SLB_MWD+GMAG6750.43 68.24 217.94 3453.92 3398.22 0.91 99.78R 5289.53 -4101.02 -3340.80 0.00 N/A 5289.55SLB_MWD+GMAG6846.24 67.69 221.65 3489.87 3434.17 3.63 103.85R 5378.31 -4169.25 -3397.63 0.00 N/A 5378.33SLB_MWD+GMAG6940.82 67.64 221.87 3525.81 3470.11 0.22 62.68L 5465.69 -4234.51 -3455.89 0.00 N/A 5465.73SLB_MWD+GMAG7034.40 67.88 221.37 3561.23 3505.53 0.56 115.44L 5552.22 -4299.26 -3513.42 0.00 N/A 5552.27SLB_MWD+GMAG7131.11 67.50 220.50 3597.95 3542.25 0.92 53.26R 5641.64 -4366.85 -3572.04 0.00 N/A 5641.71SLB_MWD+GMAGTie-In Survey7226.04 67.77 220.89 3634.07 3578.37 0.47 173.11R 5729.39 -4433.41 -3629.28 0.00 N/A 5729.47SLB_MWD+GMAGTOW - Interpolated AZ7301.08 66.33 221.08 3663.33 3607.63 1.93 125.1R 5798.44 -4485.57 -3674.60 1.01 41.31 5798.54MWD-INC_ONLY_FILLERDrilling Office 2.10.826.812/15/2021 9:03 AM Page 2 of 3 Kuparuk River Unit - 2\Kuparuk 3S Pad\3S-24\3S-24B\[3S-24B] Actual Survey #SchlumbergerͲPrivate CommentsMD(ft)Incl(°)Azim True(°)TVD(ft)TVDSS(ft)DLS(°/100ft)TF(°)VSEC(ft)NS(ft)EW(ft)Trav Cyl Dist Ct-Ct(ft)Trav Cyl Azim-North(°)Closure(ft)AD Survey ToolBOW - Interpolated AZ7314.05 65.46 222.45 3668.62 3612.92 11.75 168.61R 5810.27 -4494.40 -3682.49 1.31 45.92 5810.37MWD-INC_ONLY_FILLERInterpolated AZ7410.72 52.92 225.60 3718.05 3662.35 13.27 146.6L 5892.81 -4554.07 -3739.96 8.86 43.95 5892.95MWD-INC_ONLY_FILLER7497.25 47.77 220.94 3773.27 3717.57 7.25 50.62R 5959.18 -4602.47 -3785.65 15.63 51.52 5959.36SLB_MWD+GMAG7562.04 49.56 223.75 3816.06 3760.36 4.27 166.52R 6007.73 -4638.41 -3818.43 14.27 61.41 6007.93SLB_MWD+GMAG7661.12 37.50 228.50 3887.78 3832.08 12.60 170.52R 6075.32 -4685.81 -3867.28 6.10 74.77 6075.58SLB_MWD+GMAG7757.23 17.26 239.88 3972.74 3917.04 21.66 172.11R 6117.97 -4712.65 -3901.91 8.53 28.24 6118.33SLB_MWD+GMAG7853.15 5.04 259.87 4066.69 4010.99 13.18 272.34M 6134.52 -4720.56 -3918.43 24.22 24.37 6134.97SLB_MWD+GMAG7950.44 2.91 272.34 4163.74 4108.04 2.35 297.19M 6139.22 -4721.21 -3925.11 35.46 23.86 6139.73SLB_MWD+GMAG8044.52 3.14 297.19 4257.70 4202.00 1.40 318.37M 6141.18 -4719.94 -3929.78 36.27 17.05 6141.75SLB_MWD+GMAG8138.59 2.91 318.37 4351.64 4295.94 1.21 319.97M 6141.31 -4716.98 -3933.66 38.24 10.18 6141.95SLB_MWD+GMAG8233.93 2.96 319.97 4446.85 4391.15 0.10 326.17M 6140.45 -4713.28 -3936.85 41.48 4.93 6141.16SLB_MWD+GMAG8330.11 2.48 326.17 4542.93 4487.23 0.58 329.44M 6139.36 -4709.65 -3939.61 44.97 1.03 6140.14SLB_MWD+GMAG8425.04 1.86 329.44 4637.79 4582.09 0.67 337.09M 6138.22 -4706.62 -3941.54 48.00 358.67 6139.05SLB_MWD+GMAG8521.12 1.33 337.09 4733.83 4678.13 0.59 333.28M 6137.15 -4704.25 -3942.76 50.42 357.34 6138.03SLB_MWD+GMAG8619.27 0.91 333.28 4831.96 4776.26 0.43 319.45M 6136.29 -4702.51 -3943.56 52.20 356.55 6137.20SLB_MWD+GMAG8655.36 0.83 319.45 4868.05 4812.35 0.62 319.45M 6136.13 -4702.05 -3943.85 52.67 356.26 6137.04SLB_MWD+GMAGProj to bit8724.00 0.83 319.45 4936.68 4880.98 0.00 6135.95 -4701.30 -3944.50 53.47355.62 6136.88 SLB_MWD-STDPartMD From (ft)MD To (ft)EOU Freq (ft)Hole Size(in)Casing Diameter(in)1 0.000 28.000 1/98.425 12.250 9.6251 28.000 28.000 Act Stns 12.250 9.6251 28.000 361.620 Act Stns 12.250 9.6251 361.620 4469.090 Act Stns 12.250 9.6251 4469.090 7226.040 Act Stns 8.500 7.0001 7226.040 7410.720 Act Stns 30.000 30.0001 7410.720 8655.360 Act Stns 30.000 30.0001 8655.360 8724.000 Act Stns 30.000 30.000SLB_MWD-STD 3S-24B / [3S-24B] Actual SurveySLB_MWD-INC_ONLY_FILLER 3S-24B / [3S-24B] Actual SurveySLB_MWD+GMAG 3S-24B / [3S-24B] Actual SurveySLB_MWD+GMAG 3S-24 / 3S-24SLB_MWD+GMAG 3S-24 / 3S-24SLB_PHOTO-GSS-Depth Only 3S-24 / 3S-24SLB_PHOTO-GSS 3S-24 / 3S-24DescriptionSurvey Tool Type Borehole / SurveySLB_PHOTO-GSS-Depth Only 3S-24 / 3S-24Survey Type:Non-Def SurveySurvey Error Model:ISCWSA Rev 0 *** 3-D 95.000% Confidence 2.7955 sigmaSurvey Program:Drilling Office 2.10.826.812/15/2021 9:03 AM Page 3 of 3 Kuparuk River Unit - 2\Kuparuk 3S Pad\3S-24\3S-24B\[3S-24B] Actual Survey #SchlumbergerͲPrivate From:Callahan, Mike S To:Loepp, Victoria T (OGC) Subject:KRU 3S-24B(PTD 221-078) Notice of BOP Use Date:Tuesday, November 30, 2021 9:23:31 AM Good morning Victoria, As I mentioned on the phone, we shut in the annular preventer on Nabors 7ES yesterday afternoon in response to the well flowing on the 3S-24B well. We were at a depth of 7786’ MD. While drilling prior to shutting in we had lost ~190 bbls of mud to the formation. While shut down to take a survey, flow was observed and the well shut in. The initial shut in pressures were 305 psi on the drill pipe and 370 psi on the casing. We circulated two bottoms up through the choke and confirmed no gas or light fluid was in the well. We then did a series of bleed off tests and observed the pressure dropping each time. We opened the well for 30 minutes and observed the flow steadily decreasing, down to 0.25 bbls/min after 30 minutes, confirming that the issue was wellbore breathing and not an influx from the reservoir. We proceeded drilling at ~02:30 this morning. We are continuing to monitor the breathing signature on connections to ensure no change. We continue to lose a little bit of fluid while drilling and get a little bit back on connections, with the flow steadily decreasing at the same rate each time, confirming continued wellbore breathing. We have not seen any notable change in gas or mud weight out. Our plan forward is to continue drilling to planned TD at ~8,755’ MD. Prior to tripping out of hole we will do another breathing test to confirm the well is not flowing on its own. After tripping out of hole, we will function test the annular preventer prior to running liner. Please let me know if you have any questions or need any more information. Thanks, Mike Callahan Drilling Engineer – ConocoPhillips Alaska ATO-1544 Mike.Callahan@cop.com Office: (907) 263-4542 Cell: (907) 231-2176 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 Chris Brillon Wells Engineering Manager ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Coyote Undefined Oil Pool, KRU 3S-24B ConocoPhillips Alaska, Inc. Permit to Drill Number: 221-078 Surface Location: 2565' FNL, 1266' FEL, S18, T12N, R8E Bottomhole Location: 2048' FNL, 374' FEL, S24, T12N, R7E Dear Mr. Brillon: Enclosed is the approved application for the permit to drill the above referenced well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of October, 2021. Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.06 11:40:39 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5.Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address:6. Proposed Depth: 12. Field/Pool(s): MD: 8749 TVD:4956 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8.DNR Approval Number: 13. Approximate Spud Date: 10/8/2021 Total Depth:9. Acres in Property:14. Distance to Nearest Property: 3232' to ADL025551 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL (ft): 28 15. Distance to Nearest Well Open Surface: x-475994 y- 5993852 Zone- 4 27.7 to Same Pool: N/A 16. Deviated wells: Kickoff depth: 180 feet 17.Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 67.9 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 6-1/8" 4-1/2" 12.6 L-80 HYD563 1399' 7,150' 3,605' 8,549' 4,756' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): N/A TVD 108' 2,613' 5,203' 6,050' Hydraulic Fracture planned? Yes No 20.Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name:Mike Callahan Chris Brillon Contact Email:mike.callahan@cop.com Wells Engineering Manager Contact Phone:907-231-2176 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 3S-24B Kuparuk Field Coyote Cement Quantity, c.f. or sacks Commission Use Only See cover letter for other requirements. 5,897' - 5,913' 184 sx class G7" Total Depth MD (ft): Total Depth TVD (ft): 59-52-180 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1674 Hi 2048' FNL, 374' FEL, S24 T12N R7E 932060000, 931869000 P.O. Box 100360 Anchorage, Alaska, 99510-0360 ConocoPhillips 2565' FNL, 1266' FEL, S18 T12N R8E ADL380107, ADL025544 2447, 2559 18. Casing Program: Top - Setting Depth - BottomSpecifications 2150 Cement Volume MDSize Plugs (measured): (including stage data) 136 sx 15.8 ppg class G 12,513' 6,050' Conductor/Structural 16"80' 12,518 6,052' LengthCasing N/A Authorized Title: Authorized Signature: 3-1/2" 11,255' 422 sx class G Production Liner 11,229' 2,186' Intermediate Authorized Name: 12,295' - 12,318' 12,513' 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 4,498' Pre-Installed 108' 4,527'9-5/8" 525 sx Arctic set, 415 sx LiteCrete Effect. Depth MD (ft): Effect. Depth TVD (ft): Stratigraphic Test Nooo Mud log req'd: Yes No o No Directional svy req'd: Yes Noooo Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements BOP SketchDrillingProgram Time v. DepthPlotShallow HazardAnalysis Single Well Gas Hydrates Nooo Inclination-only svy req'd: Yes No oo Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Nooo sNo Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Digitally signed by Chris Brillon DN: C=US, OU=Wells Engineering, O=ConocoPhillips Alaska, CN=Chris Brillon, E=chris.l.brillon@conocophillips.com Reason: I am approving this document Location: your signing location here Date: 2021.09.21 10:23:30-08'00' Foxit PDF Editor Version: 11.0.0 Chris Brillon By Meredith Guhl at 11:17 am, Sep 21, 2021AOGCC YessHydraulic Fracture planned? SFD 9/28/2021 SFD 9/28/2021 50-103-20456-02-00 SFD 9/28/2021 7,313 SFD 9/28/2021 DSR-9/21/21 Exploratory OilExploratory - Oil 55.7 Undefined Oil Pool KRU 3S-24B 2041' FNL 368 FEL, S24 T12N R07E 221-078 SFD 9/28/2021 X BOP test to 3500 psig Annular preventer test to 2500 psig VTL 10/5/21 dts 10/6/2021 JLC 10/6/2021 10/6/21 Jeremy Price Digitally signed by Jeremy Price Date: 2021.10.06 11:41:47 -08'00' ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 17, 2021 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill 3S-24B Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore, exploratory producer well into the Coyote formation, sidetracking out of the existing 3S-24A well, from the existing 3S pad in Kuparuk. The intended spud date for this well is 10/8/2021. It is intended that Nabors 7ES be used to drill the well. 3S-24B will sidetrack out of the existing 7” intermediate casing in the 3S-24A wellbore. A 6-1/8” hole will be drilled to the planned TD, and a 4-1/2” liner will be run and cemented back into the 7” casing, with the top planned 740’MD or 490’TVD above the top of the Coyote interval. The well will be completed as a fracture stimulated Producer with a single stage frac job planned in the Coyote formation. This well is an exploratory test well to test the production capability of the Coyote formation. It is requested that all data related to this well be kept confidential. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4.A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Mike Callahan at 231-2176 (mike.callahan@conocophillips.com) or Chris Brillon at 265-6120. Sincerely, Mike Callahan Drilling Engineer well will be completed as a fracture stimulated Producer with a single stage frac job p n exploratory test well to test the production capability of the Coyote pggSFD 9/28/2021interval Application for Permit to Drill 3S-24B Saved: 17-Sep-21 3S-24B APD Page 1 of 7 Printed: 17-Sep-21 3S-24B Application for Permit to Drill Document Table of Contents 1.Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................... 2 2.Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................... 2 3.Proposed Drilling Program ...................................................................................... 3 4.Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) ................................................................................................................................... 4 5.MASP Calculations ................................................................................................... 4 6.Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ............................................................................................................... 5 7.Casing and Cementing Program ............................................................................. 5 8.Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................... 5 9.Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 5 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .......................................... 6 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ......................... 6 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................... 6 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 (Requirements of 20 AAC 25.005 (c)(14)) ............................................................................. 6 14. Drilling Hazards Summary ....................................................................................... 6 15. Proposed Completion Schematic ........................................................................... 7 Application for Permit to Drill 3S-24B Saved: 17-Sep-21 3S-24B APD Page 2 of 7 Printed: 17-Sep-21 1.Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as 3S-24B 2.Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 2565' FNL, 1266' FEL, S18 T12N R8E, UM NAD 1927 Northings: 5993852 Eastings: 475994 RKB Elevation 55.7’ AMSL Pad Elevation 27.7’ AMSL Location at Sidetrack KOP 1776' FNL, 132' FEL , S24 T12N R7E, UM NAD 1927 Northings: 5989373 Eastings: 472305 Measured Depth, RKB: 7300’ Total Vertical Depth, RKB: 3662’ Total Vertical Depth, SS: 3606’ Top of Productive Horizon 2041' FNL, 368' FEL , S24 T12N R7E, UM NAD 1927 Northings: 5989109 Eastings: 472068 Measured Depth, RKB: 7891’ Total Vertical Depth, RKB: 4099’ Total Vertical Depth, SS: 4043’ Total Depth 2048' FNL, 374' FEL, S24 T12N R7E, UM NAD 1927 Northings: 5989102 Eastings: 472062 Measured Depth, RKB: 8749’ Total Vertical Depth, RKB: 4956’ Total Vertical Depth, SS: 4900’ Application for Permit to Drill 3S-24B Saved: 17-Sep-21 3S-24B APD Page 3 of 7 Printed: 17-Sep-21 3.Proposed Drilling Program The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. Pre Rig: 1. Slickline: tag; drift for retainer; injectivity test 2. Coil tubing: set retainer ~12,000ft KB; pump 15 bbls across/into perfs; un-sting and lay in 18 bbls to ~10,000ft KB; through open sleeve or GLM, circulate 10 bbls cement to IA 3. Slickline: pressure test; tag TOC, pull GLV 4. Circ in 320 bbls 10ppg NaCl 5. Eline: Cut tubing ~7,500ft KB Nabors 7ES: 1. MIRU Nabors 7ES on 3S-24B. 2. Install and test BOPE to 250 psi low / 3500 psi high (2500 psi annular) 3. Pull and lay down existing tubing (pre-rig cut at 7500’). 4. Run casing scraper down to 7400’. 5. Set CIBP and whipstock at 7300’, oriented 180° for low-side exit. 6. Perform pressure test on 7” casing to 2000 psi. 7. Mill window in 7” casing. 8. Drill 6-1/8” hole to TD, 200’ TVD below base of Coyote formation. 9. Circulate hole clean and pull out of hole with drilling BHA. 10. Run 4.5” liner TD. 11. Cement liner, bringing cement above liner top. Set liner top hanger/packer and circulate cement out of hole from above top of liner. 12. Perform pressure test on 7” casing / 4-1/2” liner to 2000 psi (to ensure no casing integrity issues were caused during drilling/liner running). a. If pressure test does not pass, log with caliper and MVT. Run casing patch across leak and re-test. If unable to repair with casing patch, run 5-1/2” tie-back string. 13. Run 4.5” upper completion (if casing patch or tie-back must be run due to failed pressure test in prior step, upper completion will be 3.5”). 14. Pressure test hanger seals to 5,000 psi. 15. Test tubing to 3700 psi, chart test. 16. Test IA to 2000 psi, chart test. 17. Install BPV and test to 2500 psi. 18. Nipple down BOP. 19. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes. 20. Freeze protect down tubing and annulus. 21. Secure well. Rig down and move out. Application for Permit to Drill 3S-24B Saved: 17-Sep-21 3S-24B APD Page 4 of 7 Printed: 17-Sep-21 4.Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP schematics on file for Nabors 7ES. As this well is a sidetrack below the surface casing, no diverter will be used. 5.MASP Calculations The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Casing/Window Depth MD/TVD(ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) 7 7300 / 3662 12.5 1,675 2014 4.5 8549 / 4756 12.5 2,150 1674 PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS Drilling 6-1/8” hole out of 7” intermediate casing ASP = [(FG x 0.052) – 0.1] D = [(12.5 x 0.052) – 0.1] x 3662= 2014 psi OR ASP = FPP – (0.1 x D) = 2150– (0.1 x 4756) = 1674 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 12.5 12.5 Application for Permit to Drill 3S-24B Saved: 17-Sep-21 3S-24B APD Page 5 of 7 Printed: 17-Sep-21 6.Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) LOT to 13.5 ppg was performed on surface shoe during initial drilling of 3S-24. No FIT/LOT is planned as part of this sidetrack. 7.Casing and Cementing Program Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 4.5 6.125 12.6 L-80 Hyd563 Cemented liner Cementing Calculations 4-1/2” production liner run to 8549’ MD / 4756’ TVD Top of slurry is designed to be at 7150’ MD, the top of the 4-1/2” liner, which is 760’MD / 501’ TVD above the top of the Coyote interval. Assume 20% excess annular volume. Tail slurry from 8549’ MD to 7150’ MD with 15.8 ppg Class G + Add's Total Volume = 158ft3 => 136 sx of 15.8 ppg Class G + Add's@ 1.16 ft3/sk 8.Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Production Hole Size in. 6.125 Casing Size in. 4.5 Density PPG 9.5-10.0 PV cP 10 YP lb./100 ft2 10 - 15 Funnel Viscosity s/qt. 40 - 50 Initial Gels lb./100 ft2 6 10 Minute Gels lb./100 ft2 8 API Fluid Loss cc/30 min. 4.0 HPHT Fluid Loss cc/30 min. 10.0 pH 9.0 – 9.5 The interval will be drilled with a water-based mud (LSND) weighted to 9.5-10.0 ppg. Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9.Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A – No abnormally pressured formations expected Density PPG 9.5-10.0 No FIT/LOT is planned a water-based mud (LSND) weighted to 9.5-10.0 ppg. Application for Permit to Drill 3S-24B Saved: 17-Sep-21 3S-24B APD Page 6 of 7 Printed: 17-Sep-21 10.Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A – No seismic to be performed, drilling in well developed area. 11.Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12.Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well 3S-24B will be injected into a permitted annulus on 1B pad. 14.Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 6.125” Hole / 4.5” Liner - Horizontal Production Hole Event Risk Level Mitigation Strategy Lost circulation Low Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Low Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Low Keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: No collision risks exist in the planned 3S-24B wellbore. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Lost returns are possible if weaker than expected formations or stringers are encountered. LCM material will be available to seal in losses if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. LCM material will bep available to seal in losses if needed. Application for Plug to Redrill 3S-24A Saved: 5-Oct-21 3S—24A 10-403 Page 2 of 2 Printed: 5-Oct-21 Proposed Completion Schematic Application for Permit to Drill 3S-24B Saved: 17-Sep-21 3S-24B APD Page 7 of 7 Printed: 17-Sep-21 15.Proposed Completion Schematic superceded SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 7300.00 67.87 221.08 3661.99-4485.11 -3674.20 0.00 0.005797.92 KOP: 16°/100' DLS, 180° TF, for 13' 2 7313.00 65.79 221.08 3667.10 -4494.12 -3682.06 16.00 180.005809.86 Hold for 20' 3 7333.00 65.79 221.08 3675.30 -4507.87 -3694.04 0.00 0.005828.10 Start 10°/100' DLS, 180° TF, for 400' 47733.00 25.79 221.08 3948.58 -4719.64 -3878.65 10.00 180.006108.92 Adjust TF to 180°, for 158.25' 5 7891.25 9.97 221.08 4098.70 -4756.15 -3910.47 10.00 180.006157.33 Adjust TF to 180°, for 99.68' 6 7990.93 0.00 0.00 4197.88 -4762.67 -3916.16 10.00 180.006165.98 Hold for 557.82' 7 8548.75 0.00 0.00 4755.70 -4762.67 -3916.16 0.00 0.006165.98 Adjust TF to 0°, for 200' 8 8748.75 0.00 0.00 4955.70 -4762.67 -3916.16 0.00 0.006165.98 TD: 8748.75' MD, 4955.7' TVD 07300 7300 7490 7490 7670 7670 7860 7860 8040 8040 8230 8230 8500 8500 8600 8600 8600 8600 8600 8600 8500 8500 8600 8600 8600 8600 8400 8400 8500 8500 8600 8600 8620 8620 8640 8640 8580 8580 8680 8680 8700 8700 8550 8550 8650 8650 8749 3S-24B wp06 Plan Summary 0 3 Dogleg Severity7400 7600 7800 8000 8200 8400 8600 8800 Measured Depth 7" x 8-1/2" 45 45 90 90 0 90 180 270 30 210 60 240 120 300 150 330 Azimuth from North [°] vs Travelling Cylinder Separation [90 usft/in] 73007325735073747399742374477471749375167538 7559 7579 7600 7617 7636 3S-24 73007325735073747399742374477471749375167538 7559 7579 7600 7617 7636 3S-24A 0 3000 True Vertical Depth0 1000 2000 3000 4000 5000 6000 Vertical Section at 219.43° 9 5/8" 7" x 8-1/2" 0 30 60 Centre to Centre Separation7400 7600 7800 8000 8200 8400 8600 8800 Measured DepthEquivalent Magnetic Distance DDI 6.367 SURVEY PROGRAM Date: 2021-05-04T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 88.62 361.62 3S-24 CB-GYRO-MS (3S-24) CB-GYRO-SS 477.39 7300.00 3S-24 IIFR (3S-24) MWD+IFR-AK-SCC 7300.00 7650.00 3S-24B wp06 (3S-24B) MWD-INC_ONLY 7650.00 8748.75 3S-24B wp06 (3S-24B) MWD OWSG 7650.00 8748.75 3S-24B wp06 (3S-24B) MWD+IFR2+SAG+MS Surface Location North / 5993602.11 East / 1616025.58 Elevation / 27.70 CASING DETAILS TVD MD Name 3661.99 7300.00 7" x 8-1/2" 4955.70 8748.75 4-1/2" x 6-1/8" Mag Model & Date: BGGM2021 30-Oct-21 Magnetic North is 15.39° East of True North (Magnetic Declinati Mag Dip & Field Strength: 80.71° 57294.15nT FORMATION TOP DETAILS TVDPathFormation 4098.70Top Coyote 4755.70Base Coyote By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. Prepared by Checked by SLB DE Accepted by SLB PSD Approved by CoP DE 3S-24B: 28+27.7 @ 55.70usft (N7ES) -9000-7500-6000-4500-3000-15000South(-)/North(+)-10500 -9000 -7500 -6000 -4500 -3000 -1500 0 1500 3000West(-)/East(+)3S-243S-24A9 5/8"7" x 8-1/2"4-1/2" x 6-1/8"3S-24B wp063S-24B wp06Plan View11:05, August 26 2021 01500300045006000True Vertical Depth0 1500 3000 4500 6000 7500 9000 10500Vertical Section at 219.43°3S-243S-24A9 5/8"7" x 8-1/2"4-1/2" x 6-1/8"1000200030004000500060007000800087490°30°60°30°0°3S-24B wp06Top CoyoteBase Coyote3S-24B wp0611:07, August 26 2021Section View 3S-24B wp06Spider12:47, August 26 20217300.00 To 8748.75Northing (5500 usft/in)Easting (5500 usft/in)3S-033S-063S-06A3S-073S-083S-08A3S-08B3S-08C3S-08C.3S-08CL13S-08CL1PB13S-093S-103S-143S-153S-163S-173S-17A3S-183S-193S-213S-223S-233S-23A3S-243S-24A3S-26PALM 13S-6113S-611PB13S-611A wp013S-6123S-6133S-6203S-601 wp013S-602 [Northland] wp023S-605 [Blackstone] wp023S-606 [Concordia] wp013S-610 [Terminal] wp023S-617 [Harriman] wp013S-624 [Chenega] wp023G-023G-033G-043G-04A3G-04AL13G-053G-063G-073G-07A3G-083G-093G-103G-113G-123G-133G-143G-14A3G-153G-163G-173G-183G-193G-19A3G-203G-213G-21A3G-21AL13G-21AL1-013G-223G-22A3G-22AL13G-22AL23G-22AL2-013G-22AL2PB13G-233G-243G-253G-25X3G-263G-273G-283G-29_wp053G-30_wp063H-013H-01A3H-01AL13H-01AL1PB13H-023H-033H-043H-053H-063H-073H-083H-093H-103H-10B3H-10C3H-10CL13H-10CL23H-10CL2-013H-10CL2-023H-10CPB13H-113H-11A3H-11AL13H-11AL1-013H-123H-12A3H-12AL13H-12AL23H-12AL33H-12APB13H-133H-13A3H-13AL13H-13AL1-01PB13H-13AL1-023H-13AL1-033H-13AL1PB13H-13AL1PB23H-13AL1PB33H-143H-14A3H-14APB13H-14B3H-14BL13H-14BL23H-14BL33H-14BL43H-153H-163H-16A3H-16APB13H-173H-183H-193H-203H-20L13H-20L1-013H-20L1-01PB13H-20L1-023H-20L1-033H-20L1-03PB13H-20L1-043H-20L1-04PB13H-20L1-053H-20L1-063H-213H-21A_wp03 (DraftA3H-21AL1_wp02 (Dra3H-223H-22L13H-22L1-023H-22L1-033H-22L1-03PB13H-22L1-03PB23H-233H-23A3H-23AL13H-243H-253H-25A3H-25APB13H-25APB23H-263H-26L13H-26L1-013H-26L1-023H-283H-28A3H-28APB13H-313H-31A3H-31AL13H-323H-32PB13H-32A wp013H-333H-33A3H-33AL13H-33AL1PB13H-33AL23H-33AL2-013H-343H-34L13H-34L1-013H-34L1-01PB13H-34L1-023H-34L1PB13H-353H-373H-36wp053M-083M-193M-213M-23A3M-23AL13M-23AL23M-23APB13M-23APB23M-243M-24L13M-24L1-013M-24L1-01PB13M-24L1-023M-24L1-033M-24L1PB13M-24L1PB23M-24L1PB33M-283M-293M-29A3M-29APB13S-626 [Pulju] wp013T-01 wp01 v43T-02 wp01 v43T-03 wp01 v43T-04 wp01 v43T-05 wp01 v43T-06 wp01 v43T-07 wp01 v43T-08 wp01 v43T-09 wp01 v43T-10 wp01 v43T-11 wp01 v43T-12 wp01 v43T-13 wp01 v43T-14 wp01 v43T-15 wp01 v43T-16 wp01 v43T-17 wp01 v43T-18 wp01 v43T-19 wp01 v43T-20 wp01 v43T-21 wp01 v43T-22 wp01 v43T-23 wp01 v43T-24 wp01 v43T-25 wp01 v43T-26 wp01 v43T-27 wp01 v43T-28 wp01 v43T-29 wp01 v43W-07W SAK 113S-24B wp06 !"#$ ! $ ! %& # $ ! 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'."&./(0( *--&') -,'&12!(3( //-,'& -,.%& ' (*. 12(4/540-,.%& +,-*+&-% ' (*. 122 -,.%& +,-*+&-% ' (*. 12!! !1 6 7 89(& 7 :&/ 7 7 $ &/ ; $#< $( =& > :: & 7 7>1676/7 8 7 6& 0 30 60 Centre to Centre Separation7350 7420 7490 7560 7630 7700 Partial Measured Depth 3S-243S-24AEquivalent Magnetic Distance 3S-24B wp06 Ladder View 0 150 300 Centre to Centre Separation7400 7600 7800 8000 8200 8400 8600 Measured Depth3S-243S-24AEquivalent Magnetic Distance SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 88.62 361.62 3S-24 CB-GYRO-MS (3S-24) CB-GYRO-SS 477.397300.00 3S-24 IIFR (3S-24) MWD+IFR-AK-SCC 7300.007650.00 3S-24B wp06 (3S-24B) MWD-INC_ONLY 7650.008748.75 3S-24B wp06 (3S-24B) MWD OWSG 7650.008748.75 3S-24B wp06 (3S-24B) MWD+IFR2+SAG+MS 10:48, August 26 2021 CASING DETAILS TVD MD Name 3661.99 7300.00 7" x 8-1/2" 4955.70 8748.75 4-1/2" x 6-1/8" 07300 7300 7490 7490 7670 7670 7860 7860 8040 8040 8230 8230 8500 8500 8600 8600 8600 8600 8600 8600 8500 8500 8600 8600 8600 8600 8400 8400 8500 8500 8600 8600 8620 8620 8640 8640 8580 8580 8680 8680 8700 8700 8550 8550 8650 8650 8749 3S-24B wp06 TC View 60 60 120 120 180 180 240 240 300 300 0 90 180 270 30 210 60 240 120 300 150 330 Azimuth from North [°] vs Travelling Cylinder Separation [120 usft/in] 730073257350737473997423744774717493751675387559757976007617763676507670 7686 7700 7716 7733 7743 7750 7769 7780 7792 7800 7812 7822 3S-24 730073257350737473997423744774717493751675387559757976007617763676507670 7686 7700 7716 7733 7743 7750 7769 7780 7792 7800 7812 7822 3S-24A SURVEY PROGRAM Date: 2021-05-04T00:00:00 Validated: Yes Version: From To Tool 88.62 361.62 CB-GYRO-SS 477.39 7300.00 MWD+IFR-AK-SCC 7300.00 7650.00 MWD-INC_ONLY 7650.00 8748.75 MWD OWSG 7650.00 8748.75 MWD+IFR2+SAG+MS CASING DETAILS TVD MD Name 3661.997300.00 7" x 8-1/2" 4955.708748.75 4-1/2" x 6-1/8" SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation 1 7300.00 67.87 221.08 3661.99-4485.11 -3674.20 0.00 0.005797.92 KOP: 16°/100' DLS, 180° TF, for 13' 2 7313.00 65.79 221.08 3667.10 -4494.12 -3682.06 16.00 180.005809.86 Hold for 20' 3 7333.00 65.79 221.08 3675.30 -4507.87 -3694.04 0.00 0.005828.10 Start 10°/100' DLS, 180° TF, for 400' 47733.00 25.79 221.08 3948.58 -4719.64 -3878.65 10.00 180.006108.92 Adjust TF to 180°, for 158.25' 5 7891.25 9.97 221.08 4098.70 -4756.15 -3910.47 10.00 180.006157.33 Adjust TF to 180°, for 99.68' 67990.93 0.00 0.00 4197.88 -4762.67 -3916.16 10.00 180.006165.98 Hold for 557.82' 7 8548.75 0.00 0.00 4755.70 -4762.67 -3916.16 0.00 0.006165.98 Adjust TF to 0°, for 200' 8 8748.75 0.00 0.00 4955.70 -4762.67 -3916.16 0.00 0.006165.98 TD: 8748.75' MD, 4955.7' TVD 3S-24B wp06AC FlipbookSURVEY PROGRAMDepth From Depth To Tool88.62 361.62 CB-GYRO-SS477.39 7300.00 MWD+IFR-AK-SCC7300.00 7650.00 MWD-INC_ONLY7650.00 8748.75 MWD OWSG7650.00 8748.75 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName3661.99 7300.00 7" x 8-1/2"4955.70 8748.75 4-1/2" x 6-1/8"66121218180901802703021060240120300150330Azimuth from North [°] vs Travelling Cylinder Separation [6 usft/in]73007325735073747399742374473S-2473007325735073747399742374473S-24A073007300 74907490 76707670 78607860 80408040 82308230 85008500 86008600 86008600 86008600 85008500 86008600 86008600 84008400 85008500 86008600 86208620 86408640 85808580 86808680 87008700 85508550 86508650 8749From Colour To MD7300.00 To 7500.00MD Azi TFace7300.00 221.08 0.007313.00 221.08 180.007333.00 221.08 0.007733.00 221.08 180.007891.25 221.08 180.007990.93 0.00 180.008548.75 0.00 0.008748.75 0.00 0.00 3S-24B wp06AC FlipbookSURVEY PROGRAMDepth From Depth To Tool88.62 361.62 CB-GYRO-SS477.39 7300.00 MWD+IFR-AK-SCC7300.00 7650.00 MWD-INC_ONLY7650.00 8748.75 MWD OWSG7650.00 8748.75 MWD+IFR2+SAG+MSCASING DETAILSTVDMDName3661.99 7300.00 7" x 8-1/2"4955.70 8748.75 4-1/2" x 6-1/8"2020404060600901802703021060240120300150330Azimuth from North [°] vs Travelling Cylinder Separation [20 usft/in]742374477471749375167538755975793S-24742374477471749375167538755975793S-24A073007300 74907490 76707670 78607860 80408040 82308230 85008500 86008600 86008600 86008600 85008500 86008600 86008600 84008400 85008500 86008600 86208620 86408640 85808580 86808680 87008700 85508550 86508650 8749From Colour To MD7400.00 To 8748.75MD Azi TFace7300.00 221.08 0.007313.00 221.08 180.007333.00 221.08 0.007733.00 221.08 180.007891.25 221.08 180.007990.93 0.00 180.008548.75 0.00 0.008748.75 0.00 0.00 3S-24B wp06AC Wells Only10:52, August 26 20217300.00 To 8748.75Northing (5500 usft/in)Easting (5500 usft/in)3S-143S-153S-163S-173S-17A3S-183S-193S-213S-223S-233S-23A3S-243S-24A3S-26PALM 13S-6133S-6203S-617 [Harriman] wp013S-624 [Chenega] wp023S-626 [Pulju] wp013S-24B wp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outh(-)/North(+) (1500 usft/in)-9000 -7500 -6000 -4500 -3000 -1500 0 1500 3000West(-)/East(+) (1500 usft/in)3S-143S-15603S-163S-173S -17A 3S-183S-19603S-216 03S -2 2 60 3 S -23 3S-23A3S-24603S-24A3S-2 6 60PALM 13S-6133S-6203S-24B wp063S-24B wp06Quarter Mile View11:03, August 26 2021WELLBORE TARGET DETAILS (MAP CO-ORDINATES)Name TVD Shape3S-24B Base Coyote 082621_MC_QM4755.70 Circle (Radius: 1320.00)3S-24B Top Coyote 082621_MC_QM4098.70 Circle (Radius: 1320.00) 1 Guhl, Meredith D (CED) From:Callahan, Mike S <Mike.Callahan@conocophillips.com> Sent:Tuesday, September 28, 2021 1:41 PM To:Davies, Stephen F (CED) Cc:McLellan, Bryan J (CED) Subject:RE: [EXTERNAL]KRU 3S-24B (PTD 221-078) - Additional Questions Steve,I’veansweredthequestionsbelowinred,pleaseletmeknowifthiscoverswhatyou’relookingfororifyouhave anyotherquestions. Thanks, Mike From:Davies,StephenF(CED)<steve.davies@alaska.gov> Sent:Tuesday,September28,202112:44PM To:Callahan,MikeS<Mike.Callahan@conocophillips.com> Cc:McLellan,BryanJ(CED)<bryan.mclellan@alaska.gov> Subject:[EXTERNAL]KRU3SͲ24B(PTD221Ͳ078)ͲAdditionalQuestions Mike, Onemoresetofquestions: TheoriginalwellKRU3SͲ24wasnotmudlogged,andIhaven’tbeenabletofindanymudweightrecordsfromdrilling thatwellinAOGCC’sfiles.TheonlymentionisinPTDapplication203Ͳ079,wherethedrillingprogramspecifiesuseof 10.2ppgmudtodrilltheCͲ40interval,whichIbelieveisroughlyequivalenttotheCoyoteinterval.TheOperations SummaryReportforKRU3SͲ24on5/25/2003notesthatmaximumgasencounteredwhiledrillingCͲ40was2594units. x WhatmudweightwasusedtodrilltheCoyoteintervalintheoriginal3SͲ24well?Theoriginalwellwasdrilled with10.5ppgLSNDthroughtheCoyote,butmudweightwasdroppeddownto10.1ppgpriortotrippingthat BHAout(trippedforunrelatedwashoutindrillpipe).Diggingthroughtheolderreportsit’stoughtofindwhy theyloweredthemudweight,butmyguessisthattheywereencounteringsomedegreeoflosses.Thereisno mentionofincreasedgasoranyissueassociatedwiththedropto10.1ppgmudweightinthereports.They raisedthemudweightbackupto11.5ppgdeeperinsection,butthatwasinrelationtoenteringtheKuparuk, whichwewillbestayingwellaboveinthissidetrack. TheDrillingFluidProgramforplannedwellKRU3SͲ24BindicatestheCoyoteintervalwillbedrilledwith9.5to10.0ppg mud. x Willthisrangeofmudweightsbesufficient?Howwasitchosen?Weintendtodrilloutwitha10.0ppgLSND mudandmaintainthattoTDofthesidetrackifnoissuesarise.Iincludedalowerrangedownto9.5ppginthe eventweseelossesandneedtodropthemudweightdowntocombatthem.10.0ppgwaschosenbasedon the10.1ppgtheyreducedtointheoriginalwell,inadditiontothetypicalmudweightsweusedrillingthrough thisintervalinourKuparukwellsinthearea. x Sincemudloggerswillnotbeutilizedon3SͲ24B,howwillpressurebemonitoredwhiledrillingtheCoyote interval?Gaswillbemonitoredthroughtherig’sgasmonitoringsystem.Wewillusenormaldrillingpractices andkickdetectionindicators(flowin/flowoutmonitoring,pitvolumemonitoring,watchingfordrillingbreaks, etc.)forsignsofpressureencountered. x IsthereanychanceforencounteringoverͲpressurein3SͲ24B?Expectedpressureisnormal,8.7ppg,inthe3SͲ 24B.ThereisnoindicationofanyoverͲpressureandtherehasbeennoinjectionintotheintervalthatwould createanoverͲpressurecondition. 2 x Willadditionalsuppliesbeavailableonsitetoraisethemudweight1ppgabovemaximumanticipatedmud weightincaseofemergency?Wewillhavesufficientbariteandmudadditivesonlocationtoraisethemud weightatleast1ppgabovetheplanned10.0ppg,inadditiontotheabilitytobringpreͲmixed,higherweight spikefluidfromthemudplantatKuparuk. Thanksforyourhelp, SteveDavies AOGCC CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. From:Callahan,MikeS<Mike.Callahan@conocophillips.com> Sent:Tuesday,September28,202111:51AM To:Davies,StephenF(CED)<steve.davies@alaska.gov> Subject:RE:[EXTERNAL]KRU3SͲ24B(PTD221Ͳ078)ͲQuestions Steve,sorryaboutthelackofdetailontheloggingprogram.Wedonotplantorunanywirelinelogs.LWDlogswill consistofatriplecombo(gamma/resistivity/neutrondensity)andasoniclog.Therewillbenocorestaken,asweare planningtodrillapilotholewithfullcorethroughtheCoyoteonagrassrootswellin2022).Thereisnomud logging/samplingplanned. Themainpurposeofthis“exploratory”wellistotesttheproductivityoftheCoyoteintervalandgatherdataonthefrac (toincludetiltmeterdataandsomeotherdatagatheringduring/afterfrac).Thecoreandmoredetailedlogging programisbeingplannedforthegrassrootswellnextyear,asthatwillsetupbettertogatherthefullsuiteofdatawe arelookingfor. Thanks, MikeCallahan DrillingEngineer–ConocoPhillipsAlaska ATOͲ1544 Mike.Callahan@cop.com Office:(907)263Ͳ4542 Cell:(907)231Ͳ2176 From:Davies,StephenF(CED)<steve.davies@alaska.gov> Sent:Tuesday,September28,202111:42AM To:Callahan,MikeS<Mike.Callahan@conocophillips.com> Subject:[EXTERNAL]KRU3SͲ24B(PTD221Ͳ078)ͲQuestions Mike, ReadingthroughthePTDapplicationforKRU3SͲ24B,Ididnotseeanymentionofawellloggingprogram.Whatlogs doesCPAIintendtorecordacrosstheCoyoteinterval?LWDorwireline?DoesCPAIplantoacquireconventionalor sidewallcores?Othertypesofsamples?Ifso,pleasedescribe. Thanksandstaysafe, SteveDavies AlaskaOilandGasConservationCommission(AOGCC) 3 CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. From:Callahan,MikeS<Mike.Callahan@conocophillips.com> Sent:Tuesday,September28,20219:50AM To:Davies,StephenF(CED)<steve.davies@alaska.gov> Cc:Loepp,VictoriaT(CED)<victoria.loepp@alaska.gov>;Carlisle,SamanthaJ(CED)<samantha.carlisle@alaska.gov> Subject:RE:[EXTERNAL]KRU3SͲ24B(PTD221Ͳ078)ͲRequest Steve,sorryaboutthat,notsurewhathappenedwiththereport.PleasefindtheattachedErrorEllipseSurveyReport, hopefullynoissuesonthisone. Pleaseletmeknowifyouneedanythingelse. Thanks, Mike From:Davies,StephenF(CED)<steve.davies@alaska.gov> Sent:Tuesday,September28,20219:44AM To:Callahan,MikeS<Mike.Callahan@conocophillips.com> Cc:Loepp,VictoriaT(CED)<victoria.loepp@alaska.gov>;Carlisle,SamanthaJ(CED)<samantha.carlisle@alaska.gov> Subject:[EXTERNAL]KRU3SͲ24B(PTD221Ͳ078)ͲRequest CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Mike, I’mreviewingCPAI’sPermittoDrillapplicationforKRU3SͲ24B.ThetextwithintheErrorEllipseSurveyReportiscorrupt (seescreencapturebelow).Couldyoupleaseprovideareplacement? Thanksandstaysafe, SteveDavies SeniorPetroleumGeologist AlaskaOilandGasConservationCommission(AOGCC) CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. 4 Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 221-078 KRU 3S-24B Kuparuk River Kuparuk River, Coyote Undefined Oil WELL PERMIT CHECKLISTCompanyConocoPhillips Alaska, Inc.Well Name:KUPARUK RIV UNIT 3S-24BInitial Class/TypeEXP / PENDGeoArea890Unit11160On/Off ShoreOnProgramEXPField & PoolWell bore segAnnular DisposalPTD#:2210780KUPARUK RIVER, UNDEFINED OIL - 490180NA1Permit fee attachedYesSurface location in ADL 380107; top prod interval and TD in ADL 0025544.2Lease number appropriateYes3Unique well name and numberNoKUPARUK RIVER, UNDEFINED OIL - 4901804Well located in a defined poolYes5Well located proper distance from drilling unit boundaryYes6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYesWell plat included8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)NA18Conductor string providedNAsurface casing fully cemented19Surface casing protects all known USDWsNA20CMT vol adequate to circulate on conductor & surf csgNA21CMT vol adequate to tie-in long string to surf csgYesProductive interval will be completed with a cemented liner22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesRig has steel tanks24Adequate tankage or reserve pitYes25If a re-drill, has a 10-403 for abandonment been approvedYesAnti-collision analysis complete; no major risk failures26Adequate wellbore separation proposedNA27If diverter required, does it meet regulationsYesMax form pressure is 2150 psi(8.6 ppg EMW); will drill w/ 9.5-10.0 ppg EMW28Drilling fluid program schematic & equip list adequateYes29BOPEs, do they meet regulationYesMPSP is 1674 psig; will test BOPE to 3500 psig30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownNo33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)YesNone known from nearby offset wells. Rig will have sensors and alarms.35Permit can be issued w/o hydrogen sulfide measuresYesExpected pressure gradient is normal (8.7 ppg). Supplies will be onsite to raise mud weight36Data presented on potential overpressure zonesNAto 1 ppg higher than highest anticipated mud weight.37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)YesMike Callahan 907-231-217639Contact name/phone for weekly progress reports [exploratory only]ApprSFDDate9/28/2021ApprVTLDate10/5/2021ApprSFDDate9/28/2021AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDateDelineation (exploratory) redrill designed to frac and then test produce the untested Coyote sand, which lies within the Nanushuk Formation. A new grass-roots well targeting this sand is planned for next year to obtain more detailed logging and core informattion. SFD-03dts 10/6/2021JLC 10/6/2021