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219-149
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-129A Acid Wash Liner Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 219-149 50-029-23433-01-00 13211 Conductor Surface Intermediate Production Liner 6823 80 3062 9842 3477 13095 20" 9-5/8" 7" 4-1/2" 6820 48 - 128 48 - 3110 46 - 9888 9708 - 13185 48 - 128 48 - 3045 46 - 6800 6709 - 6823 None 1500 3090 5410 7500 None 3550 5750 7240 8430 10024 - 12837 4-1/2" 12.6# 13Cr85 44 - 9705 6842 - 6812 Structural 4-1/2" HES TNT Perm Packer 9587 6647 Torin Roschinger Operations Manager Tyson Shriver tyson.shriver@hilcorp.com 907-564-4542 PRUDHOE BAY, AURORA OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028257, 0028258, 0028261 43 - 6707 9550' - 12900'MD Pump 94-bbls 12% HCL. Final Injection pressure = 480-psi. 798 997 2482 2869 192 198 813 751 244 259 N/A 13b. Pools active after work:AURORA OIL No SSSV Installed 9587, 6647 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:03 am, Jul 24, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.07.23 13:15:48 - 08'00' Torin Roschinger (4662) DSR-7/29/24WCB 9-30-2024 CDW 07/24/2024 RBDMS JSB 072425 ACTIVITY DATE SUMMARY 7/10/2024 ***WELL FLOWING ON ARRIVAL*** (acid) PULLED 4-1/2" DREAM CATCHER FROM X-NIP @ 9,559' MD DRIFTED WITH 3.50" CENT, 2-1/2" SAMPLE BAILER TO DEVIATION @ 9,942' SLM ****WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** 7/14/2024 TFS U4 (Assist Coil) Standby for coil *Job continues to 7-15-24* 7/14/2024 LRS #1 1.75" Coil Tubing. Job Scope = Liner Acid Wash MIRU. ***Job Continued 7/15/24 7/15/2024 *Job continues from 7-14-24* TFS U4 (Assist coil) loaded TBG with 3 bbls 60/40 & 300 bbls KCL followed by 94 bbls HCI 12% for acid wash on perfs then flushed with 287 bbls KCL. Well left in control of coil upon departure 7/15/2024 LRS #1 1.75" Coil Tubing. Job Scope = Liner Acid Wash ***Job Continued from 7/14/24*** Continue to rig up. Stand by for SL to finish on S-24 to spot return tanks. RU OTT. MU LRS 2" JSN BHA. RIH. Tag PBTD @ 13,079' CTM. PUH 12,900'. Perform 12% HCL Acid Perf Wash per Schedule from 12,900' to 9,550'. Pre-Injectivity Test 1230 psi @ 1 bpm. Final-Injectivity Test 480 psi @ 1 bpm. POOH. RDMO CTU #1. ***Job Complete*** 7/16/2024 Well Test Unit 6, Begin WSR on 7/16/24. IL Well S-129 / OL Well S-26 Post Acid Wash,Rig up, PT, POP Well, Flow, Stablilize. Continue WSR on 7/17/24 7/17/2024 Well Test Unit 6, Continue WSR from 7/16/24. IL Well S-129 / OL Well S-26 Post Acid Wash, Flow, Stablilize, Flow to tanks. Continue WSR on 7/18/24 7/18/2024 Well Test Unit 6, Continue WSR from 7/17/24. IL Well S-129 / OL Well S-26 Post Acid Wash, Flow to tanks. Continue WSR on 7/19/24 7/19/2024 Well Test Unit 6, Continue WSR from 7/18/24. IL Well S-129 / OL Well S-26 Post Acid Wash, Flow to tanks, BD, RD End WSR on 7/19/24 Daily Report of Well Operations PBU S-129A Performg@ 12% HCL Acid Perf Wash per Schedule from 12,900' to 9,550'. Pre-Injectivity Testjy 1230 psi @ 1 bpm. Final-Injectivity Test 480 psi @ 1 bpm. POOH. RDMO CTU #1. David Douglas Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or fax to 907 777-8510. Received By: Date: Date: 12/31/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU S-129A (PTD 219-149) FRAC FOCUS REPORT STAGE 1-6 TREATMENT REPORTS Folder Contents: Received by the AOGCC 12/31/2020 PTD: 2191490 E-Set: 34499 Abby Bell 12/31/2020 2SHUDWRU1DPH 'HYHORSPHQW ([SORUDWRU\ 6HUYLFH 5 3HUPLWWR'ULOO1XPEHU 358'+2(%$<$8525$2,/ +LOFRUS1RUWK6ORSH//& :HOO1DPHDQG1XPEHU )LHOG3RROV :HOO&ODVV%HIRUH:RUN 3UHVHQW:HOO&RQGLWLRQ6XPPDU\ 7RWDO'HSWK PHDVXUHG IHHW IHHW 3OXJV PHDVXUHG IHHW IHHW (IIHFWLYH'HSWK PHDVXUHG IHHW IHHW 3DFNHU PHDVXUHG IHHW IHHWWUXHYHUWLFDO WUXHYHUWLFDO &DVLQJ /HQJWK 6L]H 0' 79' %XUVW &ROODSVH 6WUXFWXUDO &RQGXFWRU 6XUIDFH ,QWHUPHGLDWH 3URGXFWLRQ 3HUIRUDWLRQ'HSWK 0HDVXUHGGHSWK IHHW 7UXHYHUWLFDOGHSWK IHHW 7XELQJ VL]HJUDGHPHDVXUHGDQGWUXHYHUWLFDOGHSWK &U 3DFNHUVDQG6669 W\SHPHDVXUHGDQG WUXHYHUWLFDOGHSWK +(67173HUP3DFNHU /LQHU 6WLPXODWLRQRUFHPHQWVTXHH]HVXPPDU\ ,QWHUYDOVWUHDWHG PHDVXUHG 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o. 50-029-23433-01-00Well Name/No. PRUDHOE BAY UN AURO S-129ACompletion Status1-OILCompletion Date1/21/2020Permit to Drill2191490Operator BP Exploration (Alaska) Inc.MD13211TVD6823Current Status1-OIL5/26/2020UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:MWD / GR / RES, MWD / GR / RES / DEN / NEUNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleC2/7/20209691 176 Electronic Data Set, Filename: BPXA_S-129A_CBL_IBC_9DEC19_1100-SURFACE.las32023EDDigital DataC2/7/20201108 15 Electronic Data Set, Filename: BPXA_S-129A_CBL_IBC_9DEC19_MAIN.las32023EDDigital DataC2/7/20203501 2946 Electronic Data Set, Filename: BPXA_S-129A_CBL_IBC_9DEC19_REPEAT.las32023EDDigital DataC2/7/2020 Electronic File: BPXA_S-129A_CBL_IBC_9DEC19_1100-SURFACE_CU.dlis32023EDDigital DataC2/7/2020 Electronic File: BPXA_S-129A_CBL_IBC_9DEC19_MAIN_CU.dlis32023EDDigital DataC2/7/2020 Electronic File: BPXA_S-129A_CBL_IBC_9DEC19_REPEAT_CU.dlis32023EDDigital DataC2/7/2020 Electronic File: BPXA_S-129A_CBL_IBC_9DEC19_FIELDPRINT.Pdf32023EDDigital Data0 0 2191490 PRUDHOE BAY UN AURO S-129A LOG HEADERS32023LogLog Header ScansC2/11/20203062 13211 Electronic Data Set, Filename: S-129A_BH_LTK_MEM_Composite_Drilling Depth Data.las32033EDDigital DataC2/11/2020 Electronic File: S-129A_BH_LTK_2TVDSS_Memory Drilling Log.cgm32033EDDigital DataC2/11/2020 Electronic File: S-129A_BH_LTK_5MD_Memory Drilling Log.cgm32033EDDigital DataTuesday, May 26, 2020AOGCCPage 1 of 3S-,129A_BH_LTK_MEM_Composite_Drilling Depth _Data.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23433-01-00Well Name/No. PRUDHOE BAY UN AURO S-129ACompletion Status1-OILCompletion Date1/21/2020Permit to Drill2191490Operator BP Exploration (Alaska) Inc.MD13211TVD6823Current Status1-OIL5/26/2020UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsSentSample SetNumberNameIntervalINFORMATION RECEIVEDC2/11/2020 Electronic File: S-129A_BH_LTK_5TVDSS_Memory Drilling Log.cgm32033EDDigital DataC2/11/2020 Electronic File: S-129A_BH_OTK-VSS_RLT-MEM_Composite Drilling Dynamics.cgm32033EDDigital DataC2/11/2020 Electronic File: S-129A_BH_LTK_MEM_Composite_Drilling Depth Data.dls32033EDDigital DataC2/11/2020 Electronic File: S-129A_BH_LTK_2MD_Memory Drilling Log.pdf32033EDDigital DataC2/11/2020 Electronic File: S-129A_BH_LTK_2TVDSS_Memory Drilling Log.pdf32033EDDigital DataC2/11/2020 Electronic File: S-129A_BH_LTK_5MD_Memory Drilling Log.pdf32033EDDigital DataC2/11/2020 Electronic File: S-129A_BH_LTK_5TVDSS_Memory Drilling Log.pdf32033EDDigital DataC2/11/2020 Electronic File: S-129A_BH_Final Surveys Report.csv32033EDDigital DataC2/11/2020 Electronic File: S-129A_BH_Final Surveys Report.pdf32033EDDigital DataC2/11/2020 Electronic File: S-129A_BH_Final Surveys Report.txt32033EDDigital Data0 0 2191490 PRUDHOE BAY UN AURO S-129A LOG HEADERS32033LogLog Header ScansTuesday, May 26, 2020AOGCCPage 2 of 3 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-23433-01-00Well Name/No. PRUDHOE BAY UN AURO S-129ACompletion Status1-OILCompletion Date1/21/2020Permit to Drill2191490Operator BP Exploration (Alaska) Inc.MD13211TVD6823Current Status1-OIL5/26/2020UICNoCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYComments:Compliance Reviewed By:Date:Mud Logs, Image Files, Digital DataComposite Logs, Image, Data Files Cuttings SamplesY / NAYY / NADirectional / Inclination DataMechanical Integrity Test InformationDaily Operations SummaryYY / NAYCore ChipsCore PhotographsLaboratory AnalysesY / NAY / NAY / NACOMPLIANCE HISTORYDate CommentsDescriptionCompletion Date: 1/21/2020Release Date:11/1/2019Tuesday, May 26, 2020AOGCCPage 3 of 3M. Guhl5/26/2020 1a. Well Status: GINJ Oil 55 1b. Well Class: 5 Exploratory Service BP Exploration (Alaska), Inc 14. Permit to Drill Number/Sundry 219-149 11/24/2019 12/7/20 GL PRUDHOE BAY, AURORA OIL 4a. Surface: Top of Productive Interval: Total Depth: 3645' FSL, 4103' FEL, Sec. 35, T12N, R12E, UM 925' FSL, 3072' FEL, Sec. 34, T12N, R12E, UM 2318' FNL, 2695' FEL, Sec. 03, T11N, R12E, UM Surface: x- y- Zone -619339 5979855 ASP 4 11. Gas SPLUG Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 1/21/2020 15. 50-029-23433-01-00 16. PBU S-129A Well Name and Number: 13095' / 6821' 33.65 17. TPI:y- Zone -615138 ASP 4x-5977069 Total Depth: x-y-Zone -615571 ASP 45973832 13211' / 6823' None DNR Approval Number:19. 83-47 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: MWD / GR / RES, MWD / GR / RES / DEN / NEU CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 7" 4-1/2" 129.45# 40# 26# 12.6# L-80 L-80 13Cr85 48' 46' 9708' 9888' 13185' 48' 46' 6709'6823' 6800' 6-1/8" 8-1/2"x9-7/ ~260 sx Arctic Set 829 sx LiteCrete, 255 sx Class 'G' 404 sx Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. 4-1/2" 12.6# 13Cr85 9705' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: Not on Production N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: 350' Open to production or injection?Yes 5 No 24. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 12805' - 12837' 6811' - 6812' X-65 128'42"20" 9-5/8"48'3110'12-1/4"1220 sx Arctic Set Lite, 447 sx Class 'G'48'3045' 9587' / 6648' Freeze Protect w/ 12 Bbls Diesel Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 128' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028257, 028258 & 028261 Other 12. SSSV Depth (MD/TVD): 2-7/8" Gun Diameter, 6 spf 1/21/2020 Ref Elevations BF 35.77 (attached)5 KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 81.47 Water Depth, if Offshore:13. N/A One API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: 3110' / 3045' 1900' (Approx.) Submit within 30 days of Completion, Suspension, or Abandonment By Samantha Carlisle at 8:42 am, May 18, 2020 Completion Date 1/21/2020 HEW RBDMS HEW 5/21/2020 GMGR22MAY20DSR-5/21/2020SFD 5/22/2020 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Minge, David Contact Email: David.Minge@bp.com Authorized Name:Lastufka, Joseph N Authorized Title:SIM Specialist Authorized Signature with Date:Contact Phone:+1 9075645279 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. 3745' 6871' 6900' 7079' 7156' 7211' 7285' 7358' 7403' 7470' 7570' 8856' 9473' 9834' 9886' 13188' 3585' 5030' 5047' 5158' 5207' 5243' 5292' 5341' 5372' 5417' 5485' 6278' 6590' 6773' 6799' 6823' Ugnu Schrader Bluff Na Schrader Bluff Nb Schrader Bluff OA Schrader Bluff OBa Schrader Bluff OBb Schrader Bluff OBc Schrader Bluff OBd Schrader Bluff OBe Schrader Bluff OBf Base Schrader Bluff Colville Mudstone HRZ Kalubik Kuparuk C HRZ (Fault) HRZ 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes 13188'6823' Top of Productive Interval 9886'6799' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top No 5 31. Summary of Daily Drilling Reports, LOT / FIT Summary, Summary of Post-Rig Work, Survey, Cement Report, Wellbore Schematic Di List of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.05.17 12:49:55 -08'00' YYH¼ YwwcYMUH¼]zR¼ MRMH¼ tOH¼9+39¼ ( #( O]¼YwYH¼06;;¼,¼ tH¼+0!!¼ z¹¼M®¨«£H¼C3 K$$@6@¼jV¼ U¶·¼zUH¼C@6$¼ U¶·UH¼9;!!¼ %D7A¼dkSu¼ &&-1&D ¼ l¼D7A¼S`¼4"¼xA"¼PS¼kW¼I¼AA17¼'<¼' (,)(#)(E¼ 5(,¼Qa¼(,:¼ !0N{¼ #(8,¼ ±¥¼mVJ¼2E8B¼ l¼_¼4&-¼x}¼ =¼Ta¼,:¼yB#¼N{¼ ¼fT¼ #2B2¼ ±¥¼mV¼J¼:,=:¼ \^No¼||N¼ ( \^¼yaF¼Qfo¼T| ¼Qyv¼X\p q¼¼(((E¼ Nay\¼N¼ ¼ \^F¼BEL(.B#8¼ ¯µ£F¼¤¦£²¼µ¯¼ ²¯¢·¡µª¯®¼XQ¼§²¼©ª´µ¯²ª¡¬¼±£³¼¢µ¼ r\¼ ^¼o\Ny¼°® º¼f¼¼ .=B¼:¼(.B#8¼(.B2=¼#(/(.#¼ QV¼ 5( ,¼y~¼(,:¼ !0N{¼ #(8,¼ ±¥¼mV¼J¼2E8B VN[¼[¼Q¼ 0 #0 0 0 (,(:(E¼s|V¼ (,,#(E¼V|s|V¼ #(,2 #¼|s|V¼ #,#2,#¼|vs|V¼ T||[¼VN[¼ ! 0 $ 0 #$!0# 0 Vya¼f¼T[To¼ ^oNy¼V[¼N Ny¼ NV [^¼ #(,( ,#¼ T[T[V¼N o¼|Q[¼ ¼ 5¼ 2¼ ,¼ (¼ [¼Q¼T||[¼ !"&( "!($ ( (( ( ( %( !((( ("(( ( (e4&-¼dZ¼¼}j¼jVI¼1A&1¼ {mxxm~V¼" 0 1&&"¼ 1&,4¼ aN¼yo^¼|NV[y¼ |V¼ V¼V[¼ [¼y¼yNTf¼ 2BB5¼2:E2¼ 2E¼vQa,¼ V|¼Qv¼ =8E:¼88#,¼5=¼vQa,¼V|¼Qv¼ B=E,¼:,5:¼:#¼vQa,¼V|¼Qv¼ E5#B¼:88=¼:#¼vQa,¼V|¼ Qv¼ ¼ VN[¼ #¼(,(((E¼ #¼(,(((E¼ #¼(,(((E¼ #¼(,(((E¼ >5(,¼yQ¼N fm[¼aNa[¼mVJ¼2B:¼ n ?5(,¼fZ¼¼}j ¼jVJ¼2B(2¼ g*»¼¼5(,¼fZ¼}¼ v¼jVJ¼2B8:¼ h5(,¼fZ¼¼}j ¼jVJ¼2B(2¼ i5(,¼fZ¼}¼}j ¼jVJ¼2=,8¼ ?5(,¼yZb¼jVJ¼2E8B¼ =¼¼8¼^V¼y ¼¼fb¸jZQNTv¼y¼ jV¼J522#¼ h8¼5(,¼jVJ¼2E,#»¼ NN¼o¼ [yyG¼(,EN¼ [|o¼¯G¼ ,(E(5E¼ N o¼¯G¼8##,E,2522#(¼ [T¼28¼(,¼(,[¼(:28 ¼^y¼¼((== ¼^y¼ 0/+(*,%.&*)0 (%-'%0 @$3; TOC from CBL 09-DEC-19 Test Date Test Type Test Depth (TMD-Ft) Test Depth (TVD-Ft) AMW (ppg) Surface Pressure (psi) Leak Off Pressure (BHP) (psi) EMW (ppg) 11/24/19 FIT 3,110.00 3,044.94 9.35 467.00 1,946.00 12.30 Well Name: S-129A BP AMERICA LOT / FIT Summary Page 1 of 1 !"! # !$ % &&' (% &)&' 1 2 3 &/ 4 5(% & '&-&''''''6 3 7 &)&' 3 % 889!/2!82'''''-+ ( 5 24:)/*457;# < 6 $ 3 ;+' 0 % #57;$ ( 7= % 7 ;! 7"7 #$ % 7 &&' 6! 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" #$ % & '(') *& '') 2 3 # 4 '0##5 6*& ' )'.'))))))! # 4# 7 '(') # 4 ##͹ 0 3 83)))))., * 6 35:(0+567;$ < ! % 4 +;+ 1 & $67;% * 7= & 7 ; 7"7 $% & 7 "3# ,/0)) 83&#F" # #!8 8 8# #3# & #? 8& +.)) 81 #.!8$ # ?&F3% #3# # +.))81 #. !8$?83 89" % 3#" 3 8! 9##89& # 8 LLL#89#&1# ! :)))LLL +0.)))))+,) #3! * .5!.'+')) ACTIVITYDATE SUMMARY 12/14/2019 T/I/O=TWC/0/0. Post Parker 272, RD temp #40 and two 2" valves from IA and OA. Installed 4 1/8" CIW upper tree with ME-60 SSV. Torqued to API specs. 573 FT/LBS. PT'd tree 300 psi low and 5000 psi high.(PASSED). ***JOB IN PROGRESS*** turned over to night shift. See log for details Final WHP's TWC/0/0. 12/14/2019 T/I/O= TWC/0/0 CONTINUED JOB FROM DAY SHIFT. Continued on with cooking ice in tree. Pulled TWC #440 @125" mid window. R/D CIW lubricator, & installed tree cap. PT'd tree cap to 500psi. RDMO ***Job Complete*** FWHP=0/0/0 12/24/2019 T/I/O = -13/-2/54 Temp - LRS Unit 46 (SIDE TRACK) assist SL. Weather hold. *********Job continued to 12/25/2019*********** 12/24/2019 ***WELL S/I ON ARRIVAL***(post sidetrack) R/U SWCP UNIT#4522. ***MOVE TO WEATHER TICKET*** 12/27/2019 ***CONT'D FROM 12/26/19 WSR***(post sidetrack) LRS CIRC'D OUT WELL W/ 250 BBLS OF 2% KCL, 250 BBLS OF INHIBITED 2% KCL & 90 BBLS OF DIESEL FOR FREEZE PROTECT.(see lrs log) DEPLOYED HES BALL & ROD TO RHC @ 9689' MD. LRS SET 7" x 4-1/2" HES TNT PKR @ 9587' MD. LRS PERFORMED PASSING MIT-T.(see lrs log) LRS PERFORMED PASSING MIT-IA.(see lrs log) *** MOVE TO WEATHER TICKET*** 12/27/2019 ***Job Cont from 12-27-2019 WSR*** Assist Slickline set HES packer (SIDETRACK) MIT-T to 3624 psi ***PASS*** MIT-IA to 3696 psi ****PASS*** Target= 3500 psi Max Applied= 3750 psi Pumped 17 bbls crude down FL of S-26 to verify flow path for Circ returns. Pumped 2 bbls 60/40 meth to open top tank to verify flow path to tank. Pumped 5 bbls 60/40 meth, 242 bbls 115* 2% KCL, 235 bbls 120* 2% KCL inhibited and 90 bbls 100* DSL down IA, up Tbg and to S-26 FL for circ out. Pumped 3 bbls 60/40 meth and 17 bbls crude down FL S-26 for FP. Pressured up FL to 1500 psi. U-tube DSL FP from IA to Tbg for 30 mins. Pumped 2.2 bbls DSL down Tbg to set packer and do 2 MIT-T tests. 2nd MIT-T took Tbg to 3647 psi. Tbg lost 23 psi in 1st 15 mins and 16 psi in 2nd 15 mins for a total loss of 39 psi in 30 min test. PASS. Pumped 3.1 bbls DSL down IA to take IA to 3736 psi MIT-IA. IA lost 27 psi in 1st 15 mins and lost 13 psi in 2nd 15 mins for a total loss of 40 psi in 30 min test. Bled T/IA to 80/80 psi and got back ~4.5 bbls. SSL in control of well Upon LRS departure. Tags hung AFE sign Hung on MV CV's= OTGFWHP's=80/80/42 12/29/2019 ***CONT'D FROM 12/28/19 WSR***(post sidetrack) PULLED BALL & ROD FROM RHC BODY @ 9689' MD. PULLED 4-1/2" RHC BODY FROM XN-NIPPLE @ 9689' MD.(intact) DRIFTED WITH 20' OF 3 3/8" DMY GUNS TO DEV AT 9927' SLM (9954' MD). ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** 1/14/2020 T/I/O = 100/0/0. Set 4" H TWC #440 @125" w/ Lubricator 840. RDMO. ***Job Complete***. MV=O, SSV/SV/WV=C, IA/OA=OTG. 1/15/2020 T/I/O=TWC/0/0. Pre Frac job. RD CIW 4 1/8" tree and RU 4 1/8" Frac tree. Torqued to API specs.553 FT/LBS. Install tree cap.PT'd tree cap to 500 psi (PASSED) ***JOB IN PROGRESS***. See log for details. Final WHP's TWC/0/0. MV open, SSV,WV, SV, CV, second MV closed. IA and OA open to gage. Daily Report of Well Operations PBU S-129A Daily Report of Well Operations PBU S-129A 1/16/2020 T/I/O = TWC/0/0. PT'd against TWC 350/5000 PSI (Pass) Charted and Retained. Pulled 4" H TWC @145" w/ Lubricator 840. RDMO. ***Job Complete***. 1/20/2020 CTU #8 1.75" coil 0.156WT Objective: Pre Frac - Log GR/CCL, Add perf MIRU. MU & RIH w/ HES GR/CCL. ***In Progress*** 1/21/2020 CTU #8 1.75" coil 0.156WT Objective: Pre Frac - Log GR/CCL, Add perf MIRU. MU & RIH w/ HES GR/CCL. Log from 13084ft to 9300ft POH. Good data on log; +10 correction. Perforate 12805' - 12837' w/ SLB 2.88" PJ guns, 6 spf, 60' phasing. ***Complete*** 1/22/2020 T/I/O= 740/77/83. Injectivity test (FRACTURING) Rig up attempt to PT. Rig Down. ***Job continued on 01/23/2020*** 1/23/2020 ***Job continued from 01/22/2020*** Injectivity test (FRACTURING) Pumped a total of 3 bbls dsl followed by 62 bbls crude. Established an Injection rate of 5bpm @ 3200 psi. See Log for details. Valve positions= SV, SV, SSV, WV= Closed. OAC, IAC, MV= Open. FWHP= 1467/96/86 1/24/2020 CTU#9 1.75" CT. Job Scope: Frac Support MIRU CTU. ***Continue Job on 1/25/20 WSR*** 1/25/2020 CTU#9 1.75" CT. Job Scope: Frac Support Rig up CTU. Wait on Frac to rig up. ***Continue job on 1/26/20 WSR*** 1/26/2020 CTU#9 1.75" CT. Job Scope: Frac Support Wait for Frac to rig up. ***Continue Job on 1/27/20 WSR*** 1/27/2020 CTU#9 1.75" CT. Job Scope: Frac Support Wait for Frac to rig up. ***Go to weather ticket.*** 1/27/2020 Job Scope: Fracture Treatment - Mobe and Stby for Weather 1/24/2020 Move to location form SLB Yard 1/25/2020 Complete moving to location and hauling sand and water. Stby for weather - below wind chill minimums. 1/26/2020 Stby for weather - below wind chill minimums. 1/27/2020 Stby for weather - below wind chill minimums. 1/28/2020 Job Scope: Fracture Treatment - Stby for Weather - below wind chill minimums. 1/29/2020 Job Scope: Fracture Treatment - Stby for Weather - below wind chill minimums. 1/30/2020 CTU#9 1.75" CT. Job Scope: Frac Support Wait for Frac to rig up. Rig up CTU and start BOP test. ***Continue job on 1/31/20 WSR*** 1/30/2020 Job Scope: Fracture Treament - Rig Up 1/30/2020 Heat Frac Tanks (FRACTURING) Heat Frac Tanks for 100* *** WSR continued on 01/31/20 *** 1/31/2020 Job Scope: Fracture Treatment - Attempt to resume rig up. Shut down due to windchill below minimums Daily Report of Well Operations PBU S-129A 1/31/2020 *** WSR continued from 01/30/20 ***Assist with Frac (FRACTURING) Heat Frac Tanks to 100*/Heat SLB transport of diesel to 90* 1/31/2020 CTU#9 1.75" CT. Job Scope: Frac Support Finish BOP test. Wait on Frac ***Continue job on 2/1/20 WSR*** 2/1/2020 Job Scope: Fracture Treatment - Attempt to resume rig up. Shut down due for weather - temp below minimums 2/2/2020 Job Scope: Fracture Treatment - Attempt to resume rig up. Shut down due for weather - temp below minimums 2/3/2020 Job Scope: Fracture Treatment - Attempt to resume rig up. 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LSND mud Casing Rotated? Cement In Place At : Method Used To Determine TOC : Estimated TOC : N/A 12/1/2019 3,580 GL / SurfaceFC @ : 6 Date : 1.16 81% Vol to Sur :Spacer returns? Reciprocated? Bump press :1335 10 bbl 365.2/365.4 Density (ppg) : 10.9 2.00 15.8 52.6 6 6 Sacks : Volume (BBLs) : Volume (BBLs) :Mixing / Pumping Rate (bpm) : WELL NAME Date : Shoe @ : FC @ :Top Liner @ : Type: Type : Type : Type : Type : Yes No Yes X No Yes X No X Yes No X Yes No Date : Volume lost during displacement (bbls) : Density (ppg) : Mixing / Pumping Rate (bpm) : Volume : 3 bbl Reciprocated? % Returns during job : 98% Cement returns to surface? Spacer returns? Vol to Sur : Density (ppg) : Rate (bpm) : Volume (bbls) : Method Used To Determine TOC : Cement returns to surfaceFIRST STAGE13185' MD 13095' MD Preflush (Spacer) Density (ppg) : Casing Rotated? 9708' MD 84.1GasBlock D500 N/A Volume (bbls): Yield : Cement In Place At : 0.63 12/9/2019 Estimated TOC : 9708' MD 18 bbl Volume (actual / calculated) : 147.6 bbl / 150.22 bbl FCP (psi) : 1231 Pump used for disp : Rig Plug Bumped? Bump press : 1950 5 Sacks : 403.5721795 5 Post Flush (Spacer) N/A Yield : 1.17 Displacement : Baradril-N Density (ppg) : 10.9 Rate (bpm) : 15.8 30 bbl Lead Slurry Mud Push II Density (ppg) : 13 Volume pumped (bbls) : Sacks : #DIV/0! Mixing / Pumping Rate (bpm) : Tail Slurry Remarks: S-129 CEMENT REPORT 12/9/2019 Hole Size :6-1/8"Casing Size :4-1/2" Baker Hughes S PRINT DISTRIBUTION LIST COMPANY BP Exploration Alaska Inc. WELL NAME S -129A FIELD Prudhoe Bay Unit COUNTY PRUDHOE BAY BHI DISTRICT Alaska AUTHORIZED BY Paul Cani7ares EMAIL Paul.Canizares(ta�bakerhughes.com 219149 32033 Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 or GANCPDC@bp365.onmicrosoft.com Ito acknowledge receipt of this data. LOG TYPE GR-RES-DEN-NEU LOG DATE December 9, 2019 TODAYS DATE February 7, 2020 Revision STATUS Final Replacement: No Details: COMPANY ADDRESS (FEDEX WILL NOT DELVER TO P.O. BOX) PERSON ATTENTION Rev. Requested by: --- FIELD / FINALFCD/DVD FINAL PRELIM LOGS dlis. PDF. META, SURVEY REPORT LOGS O M, Final Surveys) (Compass) # OF PRINTS # OF COPIES J# OF COPIES # OF COPIES .... ------------------------------------------------ ........---------..._...------------ ---- 0 BP North Slope. 0 0 O 0 O EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aides :Attn: Benda Glassmaker & Peggy O'Neil :900 E. Benson Blvd. :Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 0 0 Attn: Ricky Elgarico ATO 3-344 1700 G Street :Anchorage, AK 99510 ........ --........... - ....... ------------ ........ --------- ----------- - ---- 3 ExxonVlobil Upstream Od & Gas, US Conventional 0 O 1 Q 0 :c/o ExxonVlobil Upstream Integrated Solutions Company Attn: Technical Data Center (TDC) 22777 Springwoods Village Parkway JV-2019-USONSHOR-288 N2.2A.332 :Spring, Texas 77389 ............................................ -- ------ - ----------------- - -- ---- --------- ------ -..-......-..---- 4::State of Alaska - AOGCC 0 0 1 0 0 :Attn: Natural Resources Technitian :333 W. 7th Ave, Suite 100 :Anchorage, Alaska 99501 5DNR - Division of Oil & Gas *** 0 0 1 0 0 Aun: Rersource Evaluation Section ;550 NVest 7th Avenue, Suite 1100 p :.Anchorage, Alaska 99501 '*** Stamp "confidential" on all material deliver to DNR i -----------------------------------------------------------------------............ ---_...... 6 B Exploration (Alaska) Inc. Q Q Q 0 0 Petrotechnical Data Center, LR2-1 1900 E. Benson Blvd. :Anchorage, Alaska 99508 ;Attu: Nanev Landi TOTALS FOR THIS PAGE: 0 0 4 0 0 k/k F- g \ \or § J = 2 cr 2 f 3 < as-- � P, k k m j CL 3 § \ 2 � � � k/k > = ■ / $ 0 a cr 2 f $ % st t < as-- � P, k k m j 0 r 3 § 92��§ n - CL a k � I n o _ CEL - § CL $ » & 2 2 G { k r E _ k CLo7 $�0Eg k x 7 k/k � 2 a m j C a 3 § z d cc $ ) k / ¥ � ¥,rn § : � k 5 r ~ c k \ 2 - r � 2 � � \ , . � k � . . § -- . � 9 � k/k � 2 a m j C a 3 § z d cc $ ) k / a Ito THE STATE "'ALASKA GOVERNOR MIKE DUNLEAVY David Wages Well Interventions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S -129A Permit to Drill Number: 219-149 Sundry Number: 319-568 Dear Mr. Wages: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, cx Jessie L. Chmielowski Commissioner DATED this 20 day of December, 2019. BDM&��JAN 0 2 2020 STATE OF ALASKA \SKA OIL AND GAS CONSERVATION COMMISSI .PPLICATION FOR SUNDRY APPROVAL - 20 AAC 25.280 �ccvD Wma 6' DEC 16 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate Q = Repair Well ❑ ti d wn Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing ❑ A A �+jo�Efi gram ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development Q 5. Permit to Drill Number: 219-149 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-23433-01-00 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 Q PBU S -129A 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028257, 028258 & 028261 PRUDHOE BAY, AURORA OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): -13211 -6823 -13111 -6821 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 48-128 48-128 Surface 3062 3-5/8" 48-3110 48-3045 5750 3090 Intermediate -9842 7" -46--9888 -45--6800 7240 5410 Production Liner -3477 4-1/2" -9708 - 13185 -6709 - -6823 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None 4-1/2" 12.6# 13Cr85 -44--9705 Packers and SSSV Type: 4-1/2" HES TNT Perm Packer Packers and SSSV MD (ft) and TVD (ft): -9587 / -6648 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary Q Wellbore Schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q. Service ❑ 14. Estimated Date for Commencing Operations: December 24, 2019 15. Well Status after proposed work: Oil Q WIND ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Wages, David be deviated from without prior written approval. Contact Email: David.Wages(cb_bp.com Authorized Name: Wages, David Contact Phone: 907.564.5669 Authorized Title: Vell Int rven ons Engineer Authorized Signature: Date: (� COMMISSION USE bNLY Conditions of approval: Notify Commission 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 ElNo ❑ MMS I AN 0 2 2020 Spacing Exception Required? Yes ❑ No Subsequent Form Required:/0_ 5/dy APPROVED BYTHE Approved by: i 0'� COMMISSIONER COMMISSION Date: ;X LL t T Form 10-403 Revised 04/2017 M.G.R�tB%EC�g ,, ;2,1141 Approved application�is valid fir 17m6nN.AtLe of approval. Submit Form and Attachments in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF NOTICE OF OPERATIONS j� Before me, the undersigned authority, on this day personally appeared RAL111 JCt4e , who being duly sworn states: 1. My name is David Wages. I am 18 years of age or older and I have personal knowledge of the facts stated in this affidavit. 2. I am employed as an Engineer by BP Exploration (Alaska) Inc. ("BPXA") and I am familiar with the Application for Sundry Approvals to stimulate the S -129A Well (the "Well") by hydraulic fracturing as defined in 20 AAC 25.283(m). 3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations"). 4. On November 1 Ith, 2019, the Notice of Operations was sent to all owners, landowners, surface owners and operators within a one-half mile radius of the current or proposed wellbore trajectory of the Well. The Notice of Operations included: a. A statement that upon request a complete copy of the Application for Sundry Approvals is available from BPXA; b. BPXA's contact information. Signed this 16th day of December, 2019. (Signature) STATE OF ALASKA THIRD JUDICIAL DISTRICT Subscribed and sworn to or affirmed before me at on the day of TllP rcr ti bf✓ 520/4. ignature of Office [Notary te of Alaska /vQ — f�,c, t Public Title of Of icer rne L. Jordheim Commission Expires: 3-20-20 December 16, 2019 S -129A Fracture Stimulation Intervention Engineer David Wages (907) 564-5669 Objective Perform a plug and perf three stage fracture stimulation on the coil sidetrack to increase well's PI and off -take. Procedural Steps Slickline with Fullbore Assist 1. Set a retrievable bridge plug in the tubing 2. Pull DGLV from Station #1 and set a circulation valve 3. Circulate well with inhibited seawater and leave a 2500' freeze protect in the tubing and inner annulus 4. Pull circulation valve and set a DGLV S. MIT -T to 3500 psi with 0 psi on IA 6. MIT -IA to 3500 psi with 2500 psi on tubing 7. Pull retrievable bridge plug from tubing and drift to deviation Special Projects with Fullbore Assist 8. Rig up tree -saver for fracturing operations 9. Execute( Z5stage racture stimulation with the following pressure limits: Maximum Anticipated Treating Pressure: 4000 psi Maximum Allowable Treating Pressure: 4500 psi Stagger Pump Kickouts Between: 4000 psi and 4250 psi (90% to 950/a of MATP) Global Kickout: 4250 psi (95% of MATP) IA Pop-off Set Pressure: 2625 psi (75% of 3500 psi MIT -IA) IA Minimum Hold Pressure: 2400 psi Treating Line Test Pressure: 5500 psi Maximum Anticipated Rate: 40 bpm OA Pressure: Monitor and maintain open to atmosphere 10. Between frac stages, coil will FCO and perforate per proposed perforations below: Page 1 of 2 Top Perf (ftMD) Base Perf (ftMD) Perf Length (ftMD) Interval Top Perf (ftiVDSS) Base Perf (ftTVDSS) 10020 10052 32 PERF 6760.3 6761.5 10477 10509 32 PERF 6756.6 6757.6 11017 11049 32 PERF 6763.1 6763.1 11864 11896 32 PERF 6748.4 6746.4 12292 12324 32 PERF 6729.4 6728.8 12805 12837 32 PERF 6729.8 6730.3 192 . Coiled Tubing 11. Perform a fill cleanout to TD of the well post stimulation Slickline 12. Install a generic GLV design Well Testers 13. Flow well back post stimulation to ensure solids are at a manageable level for facilities to handle and conduct a post frac well test Page 2 of 2 Date: December 16. 2019 Subject: S -129A Fracture Stimulation From: David Wages O: 564.5669 C: 713.380.9836 To: AOGCC Attached is BP's proposal and supporting documents to fracture stimulate Kuparuk interval of well S - 129a. In May of 2015, a heel frac was performed on well S-129 which resulted in an excellent production increase. With that success we elected to frac the toe and the middle section of the well in 2018, however we ended up parting the liner which killed the lateral entirely. This frac request is for the sidetrack to re -access existing reserves and access new reserves across a fault. We are requesting a variance to sections 20 AAC 25.283, a, 3-4 which requires identification of fresh water aquifers and a plan for baseline sampling. Please direct questions or comments to David Wages. Affidavit of Notification (20 AAC 25.283, a, 1) Partners notified 11/13/2019: ConocoPhillips ExxonMobil Chevron Department of Natural Resources Plat Identifying Wells (20 AAC 25.283, a, 2, A -B) x C • 129A Frar-s Data ate - F r tis ,vet Ca.�n- armmd� rPxa S — -129A Ceriiogs. i-? Vders witNn i�'mile of 129A j S -129A 3-129A Produolion Interval 1f2 Mile E,.==-; PU 1:.a'Www—s 3-1 9A LT Mile Buffer MAP 1 BP l_eJ]F5 Per the plat above, there are no water wells within '/z mile of the subject well. Producers within '/z mile of well trajectory (20 AAC 25.283, a, 2, C) S-01 Development Abandoned 5-116AP81 Service Plugged Back For Redrill Wan rates 5-213AL3-01 wall Development Oil Producer Flowing S -01A Development Abandoned 5-11GAPB2 Service Plugged Back For Redrill 5-213AL2 Development Oil Well S -01B Development Abandoned 5-117 Development Oil Producer Shut -In 5-213AL3 Development Oil Well 5-01C Development Oil Producer Shut -In 5-118 Development Oil Producer Shut -In 5-215 Service Water Injector Injecting 5-02 Development Abandoned 5-119 Development Oil Producer Gas Lift 5-216 Service Water Injector Shut -In 5-02A Development Oil ProducerGas Lift S -11A Service Abandoned 5-217 Service Water Injector Shut -In 5-02AL1 Development Oil Well S -11B Service Miscible Injector Shut -In 5-218 Service Miscible Injector Shut -In 5-02AL1PB1 Development IPlugged Back For Redrill 5-12 Development Abandoned 5-22 Development Abandoned S-02AP61 Service Plugged Back For Redrill 5420 Service Water Injector Injecting 5-22A Development Abandoned 5-03 Development Oil ProducerGas Lift 5-121 Development Oil Producer Gas Lift 5-228 Service Water Injector lnjectin 5-04 Service Miscible Injector Shut -In 5-121PB1 Development Plugged Back For Redrill 5-23 Develo ment Oil Producer Shut -In 5-05 Development Abandoned 5-122 Development Oil Producer Gas Lift 5-24 Development Abandoned S -OSA Service Water Injector Injecting 5-122PB1 Development Plugged Back For Redrill 5-24A Service Abandoned S-OSAPBl Service Plugged Back For Redrill 5-122PB2 Development Plugged Back For Redrill S-24APB1 Service Plugged Back For Redrill 5-06 Service Water Injector Shut -In 5-122P133 Development Plugged Back For Redrill 5-24B Service Water Injector Shut -In 5-07 Development Abandoned 5-123 Service Water Injector Shut -In 5-25 Development Abandoned 5-07A Development Oil Producer Shut -In 5-124 Service Miscible Injector Shut -In S -25A Service Water Injector Injecting Smog Development Abandoned 5-125 Development Oil Producer Gas Lift S-25AP01 Service Plugged Back For Redrill 5-O&A Development Abandoned 5-125PB1 Development Plugged Back For Redrill 5-26 Development Oil Producer Shut -In 5-086 Development Oil Producer5hut-In 5-126 Service Water InjectorShut-In 5-27 Development Abandoned 5-09 Service Abandoned 5-128 Service Water In-ector I rject i ng S -27A Development Abandoned S -09A Service Miscible lnjector5hut-In 5-128PB3 Service Plugged Back For Redrill S-27APB1 Development Plugged Back For Redrill S-09APB1 Service Plugged Back For Redrill 5-128P82 Service Plugged Back For Redrill 5-270 IDevelopment Oil ProducerShut-In 5-09AP62 Service Plugged Back For Redrill 5-129 Development Oil Producer Gas Lift 5-28 IDevelopment Abandoned S-09AP133 Service Plugged Back For Redrill 5-129PB1 Development Plugged Back For Redrill S -28A Development Abandoned 5-10 Development Abandoned 5-129PB2 Development Plugged Back For Redrill 5-288 Development Oil Producer5hut-In 5-100 Development Oil Producer Shut -In 5-12A Development Abandoned 5-28BPB1 Development Plugged Back For Redrill 5-101 Service Water Injector Injecting 5-128 Development Oil Producer Gas Lift 5-29 Development Abandoned 5-101PB1 Development Plugged Back For Redrill 5-13 Develo ment Abandoned S -29A Service Water Injector Shut -In 5-102 Development Oil ProducerGas Lift 5-134 Service Miscible lnjector5hut-In 5-29AL1 Service Water Injector Shut -In 5-10211 Development Abandoned 5-135 10evelopment Oil Producer Gas Lift 5-30 Development Oil Producer Shut -In 5-102L1PB1 Development Plugged Back For Redrill 5-135PB1 IDevelopment Plugged Back For Redrill 5-31 Development Abandoned 5-102PB1 Development IPlugged Back For Redrill 5-135P82 IDevelopment Plugged Back For Redrill S -31A IService Water Injector Injecting 5-103 Development Oil Producer Gas Lift 5-13A Development Oil Producer Shut -In 5-32 IDevelopment Abandoned 5-104 Service Water Injector Injecting S43AP131 Development Plugged Back For Redrill 5-32A Development OilProducer Shut -In 5-105 Development Oil Producer Gas Lift 5-14 Service Abandoned 5-33 Development Oil Producer Gas Lift 5-106 Development Oil Producer5hut-In 5-14A Service Suspended 5-34 Service Water Injector Injecting S-lOSPB1 Development Plugged Back For Redrill 5-15 Service Water Injector Shut -In 5-35 Development Oil Producer Shut -In 5-107 Service Water Injector Shut -In 5-151`81 Service Plugged Back For Redrill 5-36 Development oil Producer5hut-In 5-108 Development Suspended 5-16 Development Oil Producer5hut-In 5-37 Development Abandoned S -1D9 Development Oil Producer5hut-In 5-16PB1 Development Plugged Back For Redrill S -37A Development Oil Producer Gas Lift 5-109PB1 Development Plugged Back For Redrill 5-17 Development Abandoned 5-37APB1 Development Plugged Back For Redrill S -10A Development Suspended 5-17A Development Abandoned 5-38 Development Oil Producer5hut-In S-l0APB1 Development Plugged Back For Redrill 5-17AL3 Developmant Abandoned 5-40 Development Abandoned 5-10AP82 Development Plugged Back For Redrill 5-17ALSPB3 Development Plumed Back For Redrill 5-400 Service Abandoned 5-11 Service Abandoned S-17APB1 Development Plugged Back For Redrill 5-400A Service Water Injector Shut -In 5-110 Service Suspended 5-178 Development Abandoned 5-401 Service Water Injector Shut -In 5-110A Service Abandoned 5-17C Development 011 Producer5hut-In 5-401PB1 Service Plugged Back For Redrill 5-1100 Service Water Injector Injecting 5-17CPB1 Development Plugged Back For Redri 11 5-40A Development Oil Producer5hut-In 5-111 Service Water Injector Injecting S-17CP82 Development Plugged Back For Redrill 5-41 Development Abandoned 5-111P81 Service Plugged Back For Redrill 5-18 Development Abandoned -43A Service Water Injector Injectin5-111PB2 Service PIu ed Back For Redrill 5-18A Develo ment Abandoned Develo ment Oil ProducerGas Lift 5-112 Service Water Injector Injectin 5-188 Develo ment Oil ProducerShut-In Develo ment Abandoned 5-112L1 Service WaterAnd Gas Injector 5-19 Development Oil Producer5hut-In VS Service Plu ed Back For Redrill 5-112111`81 Service Plu ed Back For Redrill 5-20 Service Abandoned Develo ment Abandoned 5-11211138 2 Service Plu ed Back For Redrill 5-210 Develo ment Oil Producer5hut-In Develo ment Oil Producer Gas Lift 5-113 Develo ment Abandoned 5-200A Develo ment Oil Producer5hut-In Service Plu ed Back For Redrill 5-113A Develo ment Abandoned 5-200PB1 Develo ment Plu ed Back For Redrill Development Oil Producer5hut-In 5-1138 Development Oil Producer Shut -In 5-201 Development Oil Producer Shut -In S -43L1 Development Oil Producer Gas Lift 5-1130L1 Development Oil Producer5hut-In 5-201PB1 Development Plugged Back For Redrill 5-44 Development Abandoned 5-114 Development Abandoned 5-20A Iservice Water Injector Injecting 5-44A Development Oil Producer Gas Lift 5-114A Service Water Injector Shut -In 5-21 Development Oil Producer Gas Lift 5-44L1 IDevelo ment Abandoned 5-115 Development Oil ProducerGas Lift 5-213 ]Development lAbandoned 5-44L1PB1 Development Plugged Back For Redrill 5-116 Service Abandoned 5-213A IDevelopment 1011 Producer Gas Lift 5-504 IService Water Injector Shut -In 5-1161 Service Miscible Injector Shut -In 5-213AL1 IDevelopment JOH Producer Flowin TW -C Develo ment Abandoned Exemption for Freshwater Aquifers (20 AAC 25.283, a, 3-4) Well S -129A is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II Injection activities. Findings 1-4 state: 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are situated at a depth and location the makes recovery of water for drinking water purposes economically impracticable. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are reported to have a total dissolved solids content of 7000 mg/I or more. By letter of July 1, 1986, EPA -Region 10 advises that the aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non -substantial program revision not requiring notice in the Federal Registrar. Per the above findings, "Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC 25.440." thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. Detailed Casing and Cement Information (20 AAC 25.283, a, 5-6) Well S-129 was spudded on 12/25/2010. Additional information for S-1 29A will be supplied upon completion of drilling Pressure Test Information (20 AAC 25.283, a, 7) Max treating pressure will be 4500 psi. Pressure tests after the tubing is landed and the packer is set will allow for this MATP. Planned Tubing MIT: 3500 psi Planned IA MIT: 3500 psi while holding 2500 psi on tubing TREE = WELLHEAD = FMC ACTUATOR= VLV OKB = REF ELEV = 62.46' BF. ELEV = 35.77' KOP = 2300' Max Angle = 94° Q 11858' Datum MD = 9851' Datum TVD = 6700' SS JMD DR T 20" COND,108' D= " 9-5/8- WHPSTOCK (11/23/19) 9-5/8" CSG, 40#, L-80 BTC, Minimum ID = 3.725" a@ 9689' 4-1/2" HES XN NIPPLE S-729 2006' H4-12' HES X NP, D = 3.813" Mll.-LOUT WINDOW (S -129A) 3110' -3124- GAS 3124'GAS I IFT MANDRFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3884 3693 39 KBG-2 DMY BK 0 12/11/19 3 7596 5502 47 KBG-2 DMY BK 0 12/11/19 2 8792 6246 60 KBG-2 DMY BK 0 12/11/19 1 9408 6557 60 KBG-2 DMY BK F 0 12/11/19 TOC (12110/19) 3580' 9485' 4-1/2" SLB SAPPHIRE GUAGE, D = 3.86" 9559' 4--112" HES 9587' 7" X 4-12" HES TNT PKR, D = 3.856" 9620' 412" HES 4-12' TBG, 12.6#,13CR-85 VAM TOP, 9705' .0152 bpf, D = 3.958" TOP OF 4-12" LNR 9708' 7' CSG, 26#, L-80 VAM TOP HC, 9888' .0383 bpf, D = 6276" PERFORATION SUMMARY REF LOG: ON ANGLE AT TOP PERF: @ ' Note: Refer to Production DB for historical Derf data PBTD —L_13095- 4-1/2' LNR, 12.6#,13CR-85 VAM TOP, 13185' .0152 bpf, D = 3.958' n 13211' 1 9689' 1 9705' 9708' 14-12" HES XN NP, D = 3.725" 4-12" WLEG, D = 3.958" 7"X 5' WFD LTP & HGRw/TEBACK SLV, D = 4.330" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/20MO WES ORIGINAL COMPLETION 12M2M9 P-272 SIDETRACK(S-129A) 12/16/19 JMD DRLG HO CORRECTIONS AURORA UNIT WELL: S -129A PERMIT No: 219-149 API No: 50-029-22846-01 SEC 35, T1 2N, R1 2E, 1635' FNL & 1177' FWL BP Exploration (Alaska) Accurate Pressure Ratings of Tubulars and Schematic (20 AAC 25.283, a, 8) Tvu�1:.i *AD• " `F -ant; PROPOSED ACTUATOR- REV 3 OKB • 62 48' j VLV :LAfCHy PORT REF ELEV = 8 _' BF ELEV = 35]T 11896 20 108' KOP = 2300' 12837 -GOND _ 10,'OB_ 9 Mas Angie I _ 19 0ii371 DAUJMD BULTPROPOSEDREV3 Datum MD 10a4m 4' TVh 6700', SS `B -BM' WHPSTOCK (_f_F )�_ 3168', _.. B-Sf8' CSG, 4091, L-00 B iC, D = B 835' — 3168' -�-_-_ _._..,.__.._____-__ ;Minimum ID = I _-__ " � ' ;TOC (_I L 3668' TOP OF 4-12' LAIR 4.17 TBG, 12 W, 13CR-08 VAM TOP, 1--t9773' D 5&'152 bpf.1)= 3.0 _. j 7- CSG, 26#, L -W VAM TCP HC, 9973' 0383 W. D = 6.276' f PERFORATION SLRAMARY REG LOG, ON A _.1_n ANGLE AT TOFF PERF ,y` Q ' NoIG Roo to Piudu:6on DS W hifi eal pe,idaU SIZE SPF i NTERVAL O 1YS . SHOT SOZ I PBTD 1.'4-1 W LNR, 12.6f, 13CR45 VAM TOP. H 14320' 0152 bP1, D = 3.956' - S-1 2 9A SAFETY NOTES: WELL ANGLE > 70' @ _% MAX DLS: _" a CHROME TBG & LNR. -2000' 4-1+2' RES X NP, D = 3.813' MLLOUT WMDOW (5-129A) —' - fW; i FT' UANnRFI S SII MD TVD DEV TWE j VLV :LAfCHy PORT DATE 8 11864 11896 12232 12324 12805 12837 j5 _ 10,'OB_ 9 DA4JM0 D BULTPROPOS REV 2 I _ 19 0ii371 DAUJMD BULTPROPOSEDREV3 4' 31 zl__-- —�4-1j2` HES X N3'. D = 3 813' 1/2' SLB SAPPHRE GUAG£- D - 9633' --{7' X 4-17 HES TNT PKR, D = 3.856' �--44-17kFS XNP.C=3.813' NES XN W,10 = 3.725' —{7' % S WFD LTP & HGR w/IEBACK SLV, D=4-310' 4Vi E G, D = 39W X 4-17 XO, D - i-910' Top Perf ;f:MD) Base Perf (ftMD) 10020 10052 10477 10x03 11017 1103 11864 11896 12232 12324 12805 12837 _ 10,'OB_ 9 DATT RI'V BX COMMtNfS DA7h REV BYE - COM MEiNTS 11!20!10 N7E3 ORIGBJAL COYPLETfON ._ I I SIDETRACK (5-129A) JMi3__ BUt.TPRQKk5 CL-- 49119 !19 JL40 DU" PROPOSE 0RFV 1 _ 10,'OB_ 9 DA4JM0 D BULTPROPOS REV 2 I _ 19 0ii371 DAUJMD BULTPROPOSEDREV3 AURORA UNIT WELL: S -129A PERMIT N0: API No 50 029 22846 01 T12N.R72E.1636 FNE.& 117' SP Expkxation(Alaska) Name/Size Wei ht Grade ID Burst, psi Collapse, psi 9-5/8" Surface 40# L-80 8.835" 5750 3090 7" Production 26# L-80 6.276" 7240 5410 4-1/2" Tubing/Liner 12.6 13Cr80 3.958" 8430 7500 Wellhead: FMC manufactured wellhead, rated to 5000 psi. Tree: 4-1/16" 5,000psi Tubing head adaptor: 11" 5,000psi x 4-1/16" 5,000psi Tubing Spool: 11" 5,000psi w/ 2-1/16" side outlets Casing Spool: 11" 5,000psi w/ 2-1/16" side outlets Tree saver: The top connection is 3" 1502 hammer union which will be crossed over to 4" 1002 in order to connect to the frac treating iron. The bottom connection is 7-1/16". The tree saver is rated to 10,000 psi. Geological Frac Information (20 AAC 25.283, a, 9) Lithologic Description Geological Name MD Top, ft TVD Top, ft MD Thickness, ft TVD Thickness, ft Est. Frac Pressure Shale Kulubik 9834 6773 87 41 0.70 Sandstone KC3C 9921 6814 6 3 0.55 Sandstone KC26 9927 6817 66 21 0.56 Sandstone KC2A 9993 6838 54 5 0.57 Invert 10047 6843 53 Sandstone KC2A (invert) 10100 6842 241 1 .57 Sandstone KC26 (invert) 10341 6835 79 7 .56 Sandstone KC3C (invert) 10420 6836 900 1 .55 Fault #7/13 Silts 11320 6854 840 Silt B Silts 12160 6815 1028 N/A .59 Unmapped Fault/HRZ 13188 6823 23 TD 13211 6823 Location, Orientation and a Report on Mechanical Condition of Each Well that may Transect Confining Zone (20 AAC 25.283, a, 10) r� c-11?3-17-0 t`.Lt 17A I -t^ aPal _ _ 2Ea=9t mr- jyr 3-t 4F3t 0-116 z�=_ C-IISAPet . 7%% X17 °.�.- I EA 3 _ 4 50C E"EEC ❑ata Saum"- :*.u1'f ci.+ '.`:!n. �J•i5� Ea!s9mc rca'^^;,.•C is 2P+r. bp F— Plat Q .t2.: ?altAvtrsS �•:..z:-us.zr:iw.,:v.a�.e_e, ,1 v o 0 0 N N N U � 7 A a x U x U x q N R N R N A o a m a E LL W Y0 y a c E v u u v v c 0 c 0 c c 0 0 0 V E E E a A a E E E E J Go J m J m E o J° m o S o 0 U 0 0 0 h s V J CL a 01 O. J 0 0 0 0 0 C C C N r J J y J U N U U U U U U U o a v E E E E 01 0, W o0 a0 M W p eon 0 0 0 0 0 Q 4 IQJ r .a .Q .6 .6 .6 .0 ai5 It�t Il`1 1!1 I! m` a i a ~ �. N n N Cl N C N 0. N 8 ✓1 pQ Yl O N 0111 O� M Q1 01 ,Mb M O� OW M M a ooa $$C2L pppgpppgn pa pp6. g8O. p r rte- r-7 r- �- H- a- r v v u v o a u a a a a a a u a a a a V N Y Y Y T Tppp Y T Y Y Y Y Ypp �1Ypp �1Tpp �1Ypp ppTpp p y}}pp q Ti 3 �1DD ��}pp ��Ypp � C W •� m v v v ul sy N N 0 m m N N 71 O ��} aa� 'J f- -:1 O h N P N P N 4 tp N W N O] W of W n 111 n t19. h h V1 Vi N N N N iJ :4 V' M 119 111m M V1 Ul P n h O W C GO W W tG 10 1D l0 r• p V V V U V u V V v u V a a u a a a a a a a a a � E E E Ea E E E E Ea E E E E E E E E E > >° >0 > >° a >° >0 >0 ° > z` > >0 >0 >0 >0 > > ~ 1p c'a IA c u1 fpV Ift �}rnp LO p mq W o VNt O t/1 a go I1N1 V lyppy �0(pJ } w M N 1l1 N Vl N itl Ul U1 111 U1 1(1 ut 111 vt V1 ut 111 N� dJ W W CO W M W W M W N M N N N N N N N � C x a it e•1 .y n m m m� w w 10 W u a � h P n h h h n P P U1 Y1 Y9 Ifl U1 N N M rV !n Ilt N N N h N to N N l0 10 10 l0 10 Iv N R V �y G d, N O� fT h+ th Q1 09 41 C C C C c C C C c c C.N �. C C C C E C C C E .N N .S ..N C C C C C C C C CC C c C C C C C C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .� 0 0 C$ G .� G G G G .z .t 'G G G G .g 0 0 0 0 0 0 0 O O O O O O O 0 a` n. n` a` a` i n` a a` n o a a n` v. ad i a y u. [lam ^- H W- ly H 01 H N r- N Q ti Q m n V V n N N Q W m m N N 3 N N N N H an H N an N Vl -- N rl N 111 N an-1 rl i}I Vf H Ih V1 1%1 N N N N Location of, Orientation of, and Geological data for each known or suspected fault. (20 AAC 25.283, a, 11) BP's technical analysis based on seismic, well and other subsurface information available indicates that there are 8 mapped faults that transect the Kuparuk interval and enter the confining zone within the '/2 radius of the production and confining zone trajectory for S -129A. The seismic mapping was done on a newly acquired seismic survey, and therefore the faults included in this evaluation vary slightly compared to the parent fault analysis. Fracture gradients within the confining zone (Kalubik and HRZ) will not be exceeded during fracture stimulation and would therefore confine injected fluids to the pool. The HRZ and Kalubik in this area are predominately shale with some silts with an estimated fracture pressure of —0.7 psi/ft. Thickness and fracture pressure for the confining layer is discussed in Section 9. There are 2 mapped fault crossings observed during the drilling of the production section of S -129A, faults 4, and 5, in the attached map. No significant losses were observed in the production section of the lateral S -129A. Faults 1-8 intersect the production interval and confining zone within the '/z mile radius of the planned fracs. Their displacements, sense of throw, and zone in which they terminate upwards are given below. Faults THROW Upward Fault Termination Zone Fault #1 DTS 130' Colville Fault #2 DTN 15' HRZ/Colville Fault #3 DTW 130' Colville Fault #4 DTS 35' HRZ/Colville Fault #5 DTNE 50' HRZ Fault #6 DTS 60' Colville HRZ Fault #7 DTW 100' Colville Fault #8 DTS 50' Colville/HRZ The wellbore trajectory is essentially N/S. Because the maximum horizontal stress in the area is also at this orientation, the fracs will result in longitudinal fractures. The midpoints of each of these fracs are approximately 500 ft apart along the wellbore, except for spacing between fracs 2 and 3 being 400 ft. The fracs closest to the faults have been placed with over 250ft of standoff. Fault 1 and 8: The closest point that the trajectory of S -129A could be to Fault 1 is 609ft, and to Fault 8 is 1640ft. The half length of the frac is anticipated to be 250ft, leaving ample standoff room from the deepest fracture midpoint for both faults. Fault 2: The closest point that the trajectory of S -129A is to Fault 2 is 727 feet. Fault 4 is much closer to the planned fractures. Fault 3 and 7: The closest point that the trajectory of S -129A could be to Fault 3 is 845ft, and the closes point to Fault 7 is 784ft. The maximum horizontal stress orientation is —N/S. The fault is directly to the west of the wellbore and runs parallel to its trajectory. It is unlikely that the fracture will develop towards Faults 3 and 7. However, the half-length of the frac is anticipated to be 250ft, leaving ample standoff room from the deepest fracture midpoint. Faults 4 and 5: During drilling, these faults were observed in well logs. The frac placement has been adjusted accordingly to give as much standoff as possible from those fault crossings. Fault 6: The closest point that the trajectory of S -129A could be to Fault 6 is 500ft. The half length of the frac is anticipated to be 250ft, leaving ample standoff room from the planned heel fracture. Summary Hydraulic Fracture Program (20 AAC 25.283, a, 12) Please see attached summa edure Pump Schedule (Same for to es 1-7): "e1�`A\ Volume to Top Perf 206.4 ._ _5555__ 5555._ ..... .. ......... . 5555 5555.. 5555.._. ... _5555....... ... ............._ W 2 PAD YF118FIexD 40 125 1,281 525Q 52,979 0 7Q,216 .._............._.... _ 5555... _ ... ._.. _.._ ._ . 5_555 .. _5.555.. _ .. .........._....._..._. 5555 __5.655 5555. ro 2 05 FLAT YF728FIex0 40 50 1 11 'e 100 55.079 1 027 71 244 16(100 Lde - 2p 2 Perf Length (ftMDi PAD _ YF128FIexD 6655... 40 Stage TVD Frac Too (ft) .._..._._._...... _..55_55 125 1,436 5?50 60,329 " . 6655_.._ ''. 0 71,244 ..__..._.._._.._.._.... 27 ........._.._. 2 1 FLAT 6556..-6565 .._._....... YF128FIexD 40 .: _. . .. _.. ... ..._.......__ 38 1,474 6665.. 1_56 61.925 ...__.._ 1,_.26 72.772 6556__. 5655. 16120 C-LKe ..........__. 22 5555 2 ._ 2 RAMP ._ YF728FIexD 5555. 40 .. ..-. .. -- - __._._..__ _........ _ ._...._.... 38 1512 .__........_ ._ 1596 E:s.521 _.. 5556 2,53_ 75,765W20 .. 6556 6566___ C -Lite . 2�...............2 32 _..__.__ J ._____._ RAMPYF72BFItxD 5555 40-38 6756 ... 6555_ _..._.... 1550 5655.. 1.556 65.177 4.227 79.931 6655_. 161200 Lite 242 6728.8 _ 4 RAMP _ YF128FIexD 90 32 5555.._ 5655 6555 38 1,588 5565,.. ... .. 5555. 1596 6E,713 5565 .. 6555.. 5421 B`_.,3_`6 1620 C-L'Ke 25 556 5 2 6655.. 5 RAMP � ._ 5555. YF 128FIexD 10 5556 - .__ .,8 1626 � 1 t96 68309 555 5_. � �6 34 91.890 6.,20 16200 Lite 26„ 5665.. 2 6 RAMP _ _. 40 _,,. - 38 1664-,,55,55 1 f5E 69.9Qx 7 �7 5566_.— _ 55,55, 27 . 2 7 RAMP _. ..._.,YF128FIexD YF128FIexb 40 38 1,702 1. %• 71501 -8530 - 107987 .. ..___... _._..._. 1fi+'20 C -Liffe ................ 26 ... ...._.__..._.._ 2 - 6665 6 5655-- RAMP 5555... ... ........ YF528FIexD 40 _- _ _' -_._.____. ... .. 6565 _ . 38 1740 5555.. _ _.. .. _ _. 1 _� 73.057 ����� ..._ . .-' - 9,4',0 ....117417 _.__._.___...____' /6120 C -Lite 5565. 6666 6555... 1778_ ....1556 74693 ... ... . 6655 9a}0 126897_ _ 6566 .1620CLite 10 2 9 FIAT .. YF12HFbx0 40 - _ . 75 1,853 .. ._ _ 5556 _ _ _ _ _ _. 3,150_, 77.843 .. _ _. ._. _ _ 20,276 147,723 120 C -L _ 16120 C-Lttt .6655_.5565. _.__.. A 5555 .. ......_..._.. ... 65. ... 55.65... ........ 168961 162p CBL 32 z 11 FLA7 YF728FIexD 40 .. ..._..._. .___....... 5555._ 5665 75 2,0033,1_0 .. 55 5555.. 5565 84,143 5555.._ 5555 ......_.. 23307 192,268 .. __._._.._..._.._... 1620 CBL 33 z --------- 6665_ 12 _ Rw7 ... . 5555... 6555. YF128FIexD 40 .. ...... ___._.._— _....._.. 5655 75 2.078 5655_.. _. ... a,LO 67,293 ...._._._ �-24851 216.959 15'20 CBL A ._._.._...._ 2 ....._.._. ....._._.. FLUSH WF128 40 163 2,242 _._.._._ .. _. 8711 94.154 - - 0 216.959 35 z 665U FLASH ....... FreezeProt � 40 663 _. 5655_ ...____ >s 2 -.., ..5565. 1.596 4'+.7.2 5555.._ 0 216.959 ................. .......... Proposed Perforations: 1144 bb\ q�oz.� l4C 742 I b l`ppf i�0�, bbl Top Perf ,,ftMD) Base Perf (ftMD) Perf Length (ftMDi interval Top Perf (ftTVDSS) Base Perf (ftTVDSS) Stage TVD Frac Too (ft) Stage TVD Frac Btm (ft) 10020 10052 32 PERF 6760.3 6761.5 6730 6795 10477 10509 32 PERF 6756.6 6757.6 6752 6790 11017 11049 32 PERF 6763.1 6763.1 6767 6805 11864 11896 32 PERF 6748.4 6746.4 6725 6756 12292 12324 32 PERF 6729.4 6728.8 6724 6755 12805 12837 32 PERF 6729.8 6730.3 6730 6761 192 Anticipated Pressures and frac dimensions: Maximum Anticipated Treating Pressure: 4500 psi Anticipated half length: —250' Stage 1-7 TVD Frac top: 6730' Stage 1-7 VD Frac bottom: 6790' Due to the horizontal nature of the well we are unable to provide MD top and bottom for the planned fracs. The above values were calculated using modeling software. Surface pressure is calculated based on a closure pressure of —0.55 psi/ft or 3700 psi, this combined with the anticipated net pressure to be built and the friction gives a surface pressure of 5500 psi at the time of flush. The frac height is primarily based on closure pressure differences between the harder Kuparuk formation and the softer confining layers. Average confining layer stress is —0.7 psi/ft. Half length is based on confining layer stress as well as leak -off and formation modulus. Given the values we used, a half length of 250' is expected. Cross -Section a ON MM"m Pressure Test Information (20 AAC 25.283, a, 7) Per the frac program, the both the tubing and the IA will be pressure tested. The IA will be tested to 3500 psi and the tubing will be tested to 3500 psi (110% of max differential of 3000 psi). PRV setting procedures and annulus monitoring: Maximum Allowable Treating Pressure: 4500 psi Stagger Pump Kickouts between: 4000 psi and 4250 psi (90% to 95% of MATP) Global Kickout: 4250 psi (95% of MATP) IA pop-off set pressure: Treating line test pressure: Sand Requirement Minimum Water Requirement IA Hold Pressure OA 2625 psi (75% of MIT -IA) 5500 psi —1.000.000# 16/20 Carbol-ite/Bond 7500 bbls (pump schedule: 7245 bbis) 2400 psi Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and the wellbore from overpressure. Each individual frac pump has an electronic kickout that will kick the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps, these set pressures are set between 90% and 95% of the maximum allowable treating pressure. There is the primary pressure transducer in the treating line that will trigger a global kickout which will kick all the pumps into neutral. Finally, there is a manual kickout that is controlled from the frac van. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally, the treating pressure, IA pressure and OA pressure will be monitored in the frac van. r- °1�'�° Tzt-sayer mauaved � 0.'CU Boam Tnxic Mrs S -129A Rig Up Inner 4nnulu; Line End sonnol pntroi 3Ap assse _ I Chemical Disclosure (20 AAC 25.283, a, 12) C',S Number - Chemical Name Water (Including Mix Water Supplied by Client)` Mass Fraction 6640268-4 Ceramic materials and wares, chemicals -20 % 14808-60-7 Quartz, Crystalline silica < 1 % _9000-30-0 _ _ _ Guar gum < 1 % 67-48-1 2-hydroxy-N,N,N-trimethylethanaminium chloride < 1 % 1319-33-1 4 Ulexite <0.1 % 107-21-1 Ethylene Glycol <0.1 7727-54-0 Diammonium peroxidisulphale <0.1 % 67-63-0 Propan-2-ol <0.1 111 76 2 2 butoxyethanol < 0.1 % 68131-40-8 Alcohols, c11-15-5econdary; ethoxylated <0.1 % 34398-01-1 Elhoxylated C71 Alcohol <0.1 % _ 129898-01-7 2-Propenoic acid, polymer With sodium phosphinate <0.1 % 131073-2 Sodium hydroxide (impurity) <0.1 % _25038-72-6 +_ _ Vinylidene chloride/methylacrvlate copolymer <0.1 % 68131-39-5 Ethoxylated Alcohol <0.1% 1303-964 Sodium Tetraborate Decahydrate <0.1 % 7647-14-5 _ _ Sodium chloride <0.01 % 110-17-8 -enedioic acid ---but-2 10043-52.4 Calcium Chloride <0,01 % 112-42-5 Undecanol <0.01 % 91053-39-3 Diatomaceous earth, calcined <0.01 % 7631-86-9 _ Non -crystalline silica (impurity) < 0.001 % 14807-96-6 Magnesium silicate hydrate (talc) <0.001 1037760-3 Magnesium nitrate <0.001 % 111-46-6 2.2"-oxydiethanol (impurity) '0.001 % 26172-55-4 5 chloro -2 methyl -2h -i thiazolol-3-one <0.001 n 900284-0 poty(tetraFluoroethylene) '0.001 ;6 7786-30-3 Magnesium chloride '0.001 q> 595585-15-2 Diutan <D.001 % 1250105-87-C Owtan gum ' 0.001 % 127-08-2 Acetic acid, potassium salt ' 0.0001 % 7447-40-7 _ Potassium chloride (impurity) < 0.0001 % 2682-20-4 2 -methyl 21-isoth tazol-3-one <0,0001 S 14464.46-1 - Cristobalite <0.0001 % _ 64-19-7 Acetic acid(impurity) ' 0.0001 % ENNNRMNNEErr� Davies, Stephen F (CED) From: Davies, Stephen F (CED) Sent: Wednesday, December 18, 2019 2:16 PM To: Wages, David Cc: Rixse, Melvin G (CED); Lastufka, Joseph N Subject: RE: S -129A (PTD #219-149 Frac Stim Sundry David, Thank you for updating the Mechanical Condition Table. Did you all have any luck finding digital well log data for S - 129A? Once I receive that, I can finish my portion of the review. Regards, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 orstev_�.daviesrDalaska. mv. From: Wages, David <David.Wages@bp.com> Sent: Tuesday, December 17, 2019 3:38 PM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Lastufka, Joseph N <Joseph.Lastufka@bp.com> Subject: RE: S -129A (PTD #219-149 Frac Stim Sundry Updated Mechanical condition Table: L U F6 a-+ F6 tlA O N CL E O 00 Lr) M T LA nl Y to 11R Q 0 J CS J Vl Ln N Z) Z) m T3 - - U L 2 Z u «! ',� c a C m 0 m 0 m 0 O Ew C C C c c E a OL OL UJ fu E E E E E E O E E m m m m ��-+ O O 4 tsA 44 GP W _� >> i� c 0 0 0 0 u T7 J C1 C1 CL CL 7Ql w41 VI c w w1 w 0 w fU 41 W kA E m m m m s s s 0 ti Ili EEEE *1J'� ,� ,4 w w LL U- U- Z m LLJ w Cil Fit Cjl [lid IX} F><;7 IX) OQ ri a^h t-1 r'1 N r T1 m e--1 H Cj rl s--1 s-1 N e -I N s -i N e -f rd H s-1 N C7 '1 �A Q N G N N m m C m C m N "'*., N '^-.. N `•-.. rV N r•1 `.-,. ® , N _, '61 _- _, _, _, N N N N to 1n Fr'1 ,.-. Ff1 -. Cfil Fil VI IA VI wl 1 rel e~-1 N cl CL O , CL CL CL d CL ,� +� yin BVI U1 C,51 W C�1 Fh U'1 LC} 'In CL a C1 Q CL Cl Ln Ln Ln CL U'J m m m m m CL CL Ci 0. r 1 � c)1} m rn N N W � � � Q Q [ 4 =-?. J rel N N N N N x x x r l sc x x x m m m m N 2 2 c b C V1 VI Vi I.I 1A N O VI N Vl L'1 V1 111 VI VI VI VI N L7 i"- ll'J 4D 4I5 Y I"`- oQ C t�l 101 RWM � � � y�+� +y L-A V1 L11 n t2 Ln Ln Ln Fx% r+l � i 1'�- I`- f`� t'^- I"-- f`� t`- R to V Lrti Lb W un)w 4L1 tGp� R] 4 lG 5CJ lC7 47 10 tl7 li7 lC! tCi l(J Lb lU l2Y LC."1 kb lii li7 4C} LO lJ`F U7 1.0 lfi lC7 GA LL sa. w cu al C C�y cct C?n 0 cn cil 0) ch 0 rel 0 0 N m Vj m 0 m Lfa eta cf cp d' ozf ° ' ua Cl) o0 00 m u3 m � m m rn V L+- r(A) q` u"I Ln Ln In N N rd N 4#' Et V" 111 CS � F t� r- t R N N . N .IN N � � � " 0 Ln w w w " Lr) Ln L U F6 a-+ F6 tlA O N CL E O 00 Lr) M T Well Name Casing Type Casing Size Casing Depth Hole Size Vol cmt TQC est. via TQC TQC Top of upper confining layer Zonal Isolatio Inches Feet Inches Cu Ft M'DFeet TVDssFeet TVDssFeet S-116 pc Production rasing 7 7,990 8.75 699 Volumetric 4410 3900 6707 Yes 5-11&A pc Production Casing 7 7050 8.75 520 Volumetric 5327 4360 6706 Yes 5-116APB1 Production Casing 7 7990 9.751 520 Volumetric 53271 4360 6706 Yes S-116APB2 Production Casing 7 7990 8.75 520 Volumetric 5327 4360 6706 Yes 5-128 pc Production Casing 7 3156 8.75 889 Volumetric 4562 4866 6747 Yes S-128PB2 Production Casing 7 9116 8.75 889 Volumetric 4562 4866 6747 Yes 5-129 pc Production Casing 7 9445 8.75 520 Volumetric 6782 5480 6748 Yes S-129PB1 pc Production Casing 7 9445 8.75 520 Volumetric 6782 5480 6708 Yes S-129PB2 pc Production Casing 7 9445 8.75 520 Volumetric 6782 5480 6708 Yes 5.-134 pc Production Casing 7 7762 8.75 784 Log 4018 3864 6519 Yes 5-17A pc Production Casing 9.625 8340 12.25 2214 Volumetric 2857 2789 6684 Yes S-17ALlPB1 Production Liner 2.875 10196 3.75 0 N/A Fill in 0 66-84 Yes S -17B pc Production Casing 9.625 8340 12.25 2214 Volumetric 2857 2789 6654 Yes S-17CPB1 pc Production Casing 9.625 8300 12.25 2214 Volumetric 2857 2789 6684 Yes 5-17CPB2 pc Production Casing 9.625 8300 12.25 2214 Volumetric 2857 2789 6684 Yes 5-28 pc Production Casing 9.625 9696 1225 2068 Volumetric 4612 4439 6654 Yes S -28A pc Production Casing 9.625 9696 12.25 20ES Volumetric 4612 4439 6654 Yes S -28B pc Production Casing 9.625 9696 12.25 2068 Volumetric 4612 4439 6654 Yes 5-28BPB1 pc Production Casing 9.625 9696 12.25 2068 Volumetric 4612 4439 6654 Yes -C pc Production Casing 9.625 8880 12.25 1330 Volumetric 5610 5429 6828 Yes CBL for 7" casing attached, myself and our logging guru would pick TOC for the 7" at 3580' and per log attached David Wages Interventions c. 713.380.9836 o. 907.564.5657 From: Davies, Stephen F (CED) <steve.davies@alaska. av> Sent: Tuesday, December 17, 2019 1:54 PM To: Wages, David <David.Wages @bp.Com> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.ov>; Lastufka, Joseph N <Jaseph.Lastufka@bp.com> Subject: RE: S -129A (PTD #219-149 Frac Stim Sundry David, Please amend my last request to include cement reports for all casing strings in S -129A, and copies of any cement evaluation logs recorded in the well. Thank you, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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.daviestaalaska.gov. Davies, Stephen F (CED) From: Wages, David <David.Wages@bp.com> Sent: Wednesday, December 18, 2019 10:36 AM To: Rixse, Melvin G (CED) Cc: Davies, Stephen F (CED); Lastufka, Joseph N Subject: RE: S -129A (PTD #219-149 Frac Stim Sundry Yessir, getting it finalized today, will have it to you shortly David Wages Interventions c. 713.380.9836 o. 907.564.5657 From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Wednesday, December 18, 2019 10:24 AM To: Wages, David <David.Wages@bp.com> Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Lastufka, Joseph N <Joseph.Lastufka@bp.com> Subject: RE: S -129A (PTD #219-149 Frac Stim Sundry David, Final well information should include an 'as -built' schematic. Please provide. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse(Walaska.gov). From: Wages, David <David.WaRes@bp.com> Sent: Tuesday, December 17, 2019 9:04 AM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Lastufka, Joseph N <Joseph.Lastufka@bp.com> Cc: Davies, Stephen F (CED) <Steve.davies@alaska.Rov> Subject: RE: S -129A (PTD #219-149 Frac Stim Sundry We were waiting for final well information to be received from the drilling team for the frac. David Wages Interventions c. 713.380.9836 o. 907.564.5657 From: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Sent: Tuesday, December 17, 2019 8:58 AM To: Lastufka, Joseph N <Joseph.Lastufka @ bp.com> Cc: Wages, David <David.Wages@bp.com>; Davies, Stephen F (CED) <steve.davies-alaska.gav> Subject: RE: S -129A (PTD #219-149 Frac Stim Sundry Joe, This well has been on your schedule for quite a while(PTD approved November 1"). 1 am surprised there is suddenly a rush. Fracture jobs are work intensive on our part addressing in our work queue. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell We will make it a priority with the other priority work that we are CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin_ Rixse(�aIaska.f ov). From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Monday, December 16, 2019 3:59 PM To: Rixse, Melvin G (CED) <melvin.rixse&alaska.gov>; Davies, Stephen F (CED) <steve.davies alaska.gov> Cc: Wages, David <David.Wages a bp.com> Subject: S -129A (PTD #219-149 Frac Stim Sundry Mel / Steve, We sent a sundry request today for S -129A Fracture Stimulate this afternoon. If possible, we'd like to start the work as soon as possible. If you have any questions or need additional information, please don't hesitate to let me or David know. Thanks! Thank you, Joe Lastufka SIM Specialist Cell: (907) 227 -8496 ---------------------------- Office: (907) 564-4091 Subsurface &Wells BP Exploration Alaska 1900 E. Benson Blvd. I Room: 717B I Anchorage, AK From: Davies, Stephen F (CED) Sent: Tuesday, December 17, 2019 1:31 PM To: Wages, David <David.WaEes�bp.com> Cc: Rixse, Melvin G (CED) <melvin.rixsealaska.gov>; Lastufka, Joseph N <Joseph.Lastufka bp.com> Subject: RE: S-129A (PTD #219-149 Frac Stim Sundry David, In addition to the information requested below, could you please also send cement reports for the surface and intermediate casing strings, estimated cement top(s), and copies of any CBL or other cement evaluation logs so that we can verify the estimated cement tops? Image files in .pdf format will be fine. Thank you, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 stevP.d m(_,sCa alaska.fiov. From: Davies, Stephen F (CED) Sent: Tuesday, December 17, 2019 12:47 PM To: Lastufka, Joseph N <Joseph.Last ufka2bp. com>; Wages, David <David.Wages bp.com> Cc: Rixse, Melvin G (CED) <melvin.rixse alaska.gov> Subject: RE: S -129A (PTD #219-149 Frac Stim Sundry Thank you Joe. Now, a question for David: I'm reviewing the mechanical condition table provided with the application. Do any of the following wells transect the confining layer within % mile of the fracturing interval? If yes, please let me know via email and please update and submit a revised mechanical condition table. If no, please let me know via email. API Well Name Number 50029203560000 PBU TW -C 50029207170000 PBU S-01 50029207170100 PBU S -01A 50029207170200 PBU S -01B 50029229680000 PBU AURORA S-101 50029231300000 PBU AURORA S-115 50029231370000 PBU AURORA S-117 50029231860000 PBU AURORA S-120 Thank you, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 , daska_-P,(_v. From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Tuesday, December 17, 2019 11:27 AM To: Davies, Stephen F (CED) <steve davies@alaska.gov> Cc: Wages, David <David.Wages bp.com>; Rixse, Melvin G (CED) <melvin.rixse@alaska.ov> Subject: RE: S -129A (PTD #219-149 Frac Stim Sundry Steve, Please see attached for the final survey, I'm trying to run down some logs and will get them to you as soon as possible. Thanks! Thank you, Joe Lastufka SIM Specialist Cell: (907) 227-8496 1 Office ------------------------------------- BP Exploration Alaska 1900 E (907) 564-4091 Benson Blvd. I Room: 717B I Anchorage, AK From: Davies, Stephen F (CED) <steve.davieS@alaska.Zov> Sent: Tuesday, December 17, 2019 11:21 AM To: Lastufka, Joseph N <loseph.Lastufka@bbp�com> Cc: Wages, David <David.Wa es bp.com>; Rixse, Melvin G (CED) <rnelvin.rixse _alaska.&ov> Subject: RE: S -129A (PTD #219-149 Frac Stim Sundry Joe, Could you please provide digital well log and directional survey data for S -129A? Field copies are fine in .las or spreadsheet format. Thanks, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 Stevee da vicsaalaska.�ov. From: Davies, Stephen F (CED) Sent: Tuesday, December 17, 2019 8:58 AM To: Lastufka, Joseph N <loseph Lastufka {cDbp.com> Cc: Wages, David <David Wa9es9bp.com>; Rixse, Melvin G (CED) <rrielvin.rixse o)alaska.€ Ov> Subject: RE: S -129A (PTD #219-149 Frac Stim Sundry Hi Joe, The application is in the queue and we will get to it as soon as we can. November and December are AOGCC's busy season in preparation for winter exploratory drilling operations. Cheers and Happy Holidays, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) 907-793-1224 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 steye.dadies@alaSka.F;ov_. From: Lastufka, Joseph N <Joseph.Lastufl<a @ bp.cam> Sent: Monday, December 16, 2019 3:59 PM To: Rixse, Melvin G (CED) <melvin.rixse a alaska.gov>; Davies, Stephen F (CED) <steve.davie2a!aska.gov> Cc: Wages, David <David.Wages Pbp.com> Subject: S -129A (PTD #219-149 Frac Stim Sundry Mel / Steve, We sent a sundry request today for S -129A Fracture Stimulate this afternoon. If possible, we'd like to start the work as soon as possible. If you have any questions or need additional information, please don't hesitate to let me or David know. Thanks! Thank you, Joe Lastufka SIM Specialist Cell: (907) 227-8496 1 Office: (907) 564-4091 ------------------------------------------------------- NM,. BP Exploration Alaska 1900 E. Benson Blvd. I Room: 717B I Anchorage, AK North America -ALASKA - BP Page 4 ot 22 Operation Summary Report sE, a Common Well Name: S-129 AFE No Event Type: DRL- ONSHORE (DON)Start Date: 10/24/2010 End Date: X3-OOVNH-C (5,693,419.00) Project: Prudhoe Bay Site: PB S Pad Rig Name/No.: NABORS 7ES Spud Date/Time: 10/25/2010 12:00:OOAM Rig Release: 11/20/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: S-129 Actual @62.46ft (above Mean Sea Level) Date From - To Hrs Task Code NPT j NPT Depth Phase Description of Operations (hr) (ft) 107:00 - 10:30 - 3.50 -.-.. — CEMT - P — SURF PJSM, WITH SLB CEMENTERS. RU SLB CEMENT LINES. PUMP 5BBLS OF 10.0 PPG MUD PUSH. SHUT DOWN AND PRESSURE TEST TO 3500 PSI. PUMP 95 BBLS OF MUD PUSH AHEAD AT 5 BPM AND 225 PSI. SHUT DOWN AND DROP BOTTOM PLUG. PUMP 500 iRRI 4/ 192x1 SKS (2,13 jjEjSACKIDF 10.7 -EpGAgQTrqFTIITTF_ FAD AT 6 BPM AND 220 PSI. RECIPROCATE PIPE IN 1OFT STOKES - 6 BPM, 210 PSI, 156 BBLS LEAD AWAY, MUD PUSH AT SHOE 6 BPM, 225 PSI, 244 BBLS LEAD AWAY, BOTTOM PLUG LATCHED AT 900 PSI STOP RECIPROCATING PIPE AND LAND ON LANDING RING 6 BPM, 400 PSI, 338 BBLS LEAD AWAY, SPACER AT SHAKERS 6 BPM, 424 PSI, 419 BBLS LEAD AWAY, CEMENT SPACER INTERFACE TO SURFACE SLOW TO 2.8 BPM, 288 PSI, 500 BBLS LEAD AWAY PUMP 87 BBI S/447 SWAP ON THE FLY AND CUFT/SACK) AT 6 BPM AND 440 PSI 3 BPM, 320 PSI, 74 BBLS TAIL AWAY, GOOD CEMENT BACK TO SURFACE i DROP TOP PLUG AND BEGIN DISPLACEMENT AT 7 BPM AND 295 PSI 5 BPM, 1140 PSI, 209 BBLS DISPLACED SLOW TO 3 BPM FOR BUMP, 1028 PSI, 223 BBLS DISPLACED BUMP PLUG AT 234 BBLS DISPLACED AND 11830 PSI. BLEED OFF PRESSURE AND CHECK FLOATS. TOTAL OF 365 BBLS CEMENT BACK TO SURFACE. PRESSURE UP TO 3500 PSI FOR 5 MIN TO TEST CASING. 10:30 - 12:00 1.50 CEMT P SURF RD CASING AND CEMENT EQUIPMENT. FLUSH FLOW LINE AND RISER, FUNCTION AND CLEAN HYDRIL. CLEAN CELLAR BOX. ND DIVERTER AND LD CASING EQUIPMENT 12:00 - 15:00 3.00 BOPSUR P SURF - ------.._................_-.._ 15:00 - 17:30 ._.... 2.50 WHSUR P SURF NU GEN 5 CASING AND TUBING HEAD. TEST SEALS TO 1100 PSI FOR 30 MIN. 117:30 --00.00 6.50 BOPSUR P SURF NU BOPE, CHANGE OUT MANUAL VALVE, LOAD AND STRAP 198 JTS OF 4" DP IN SHED, CHANGE FROM 5.5" LINERS TO 5" LINERS. j CHANGE BALES. CHANGE OUT TOP RAM _ !SLIDE KOOMY HOSE 10/29/2010 00:00 - 01:30 1.50 BOPSUR P SURF I CONTINUE TO NU BOPE. REPLACE AIR BOOT, INSTALL RISER, TAKE RKB MEASUREMENTS, INSTALL DOUBLE jANNULUS VALVE 01 30 02'30 1.00 BOPSUR P I SURF GREASE HCR'S AND MANUAL VALVES. RU ! TO TEST BOPE Printed 12/20/2010 5:03:04PM WELL NAME 5-129 CEMENT REPORT Date : 12/1/2019 Hole Size : 8.5 x 9 7/8 Casing Size : 7" Shoe A 9888 FC (& : 9804 Top Csg Cad : GL / Surface Preflush (Spacer) Tvna Mud Push II Density (ppg) : 11 Volume pumped (BBLs) : 61.7 Remarks: Lead Slurry Type : Litecrete HP D500 Sacks : 829 Yield : 1.7 Density (ppg) : 11.5 Volume (BBLs) : 251 Mixing / Pumping Rate (bpm) : 6 Tail Slurry Type : GasBlock D500 Sacks : 255 Yield : 1.16 Lu a Density (ppg) : 15.8 Volume (BBLs) : 52.6 Mixing / Pumping Rate (bpm) N N Post Flush (Spacer) M Type : Fresh Water Density (ppg) : 8.5 Rate (bpm) : 6 Volume: 10 bbl Displacement : Type : LSND mud Density (ppg) : 10.9 Rate (bpm) : 2.00 Volume (actual / calculated) : 365.2/365.4 FCP (psi) : 800 Pump used for disp : Rig Plug Bumped? x Yes No Bump press : 1335 Casing Rotated? Yes X No Reciprocated? X Yes No % Returns during job : 92% Cement returns to surface? Yes X No Spacer returns? Yes X No Vol to Sur: N/A Cement In Place At: 15:41 Date : 12/1/2019 Estimated TOC: 3,450 Method Used To Determine TOC: lift pressure- gauge hole Remarks: WELL NAME S-129 A CEMENT REPORT Date : 12/9/2019 Hole Size: 6-1/8" Casing Size : 4-1/2" Shoe A 13185' MD FC : 13095' MD Top Liner (ED : 9708' MD Preflush (Spacer) Type: Mud Push II Density (ppg) : 13 Volume pumped (bbls) : 30 bbl Lead Slurry Type : N/A Volume (bbls): Density (ppg) Yield : Sacks : #DIV/0! Mixing / Pumping Rate (bpm) Tail Slurry Type : GasBlock D500 Volume (bbls) : 84.1 Density (ppg) : 15.8 Yield : 1.17 Sacks : 403.5721795 Mixing / Pumping Rate (bpm) : 5 Post Flush (Spacer) Type : N/A Density (ppg) : Rate (bpm) : Volume: Displacement: Type : Baradril-N Density (ppg) : 10.9 Rate (bpm) : 5 Volume (actual / calculated) : 147.6 bbl / 150.22 bbl FCP (psi) : 1231 Pump used for disp : Rig Plug Bumped? Yes No Bump press : 1950 Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job : 98% Cement returns to surface? X Yes No Spacer returns? X Yes No Vol to Sur : 18 bbl Cement In Place At : 0.63 Date : 12/9/2019 Estimated TOC : 9708' MD Method Used To Determine TOC: Cement returns to surface Volume lost during displacement (bbls) : 3 bbl Remarks: .N W V00 LA I � � M m Z CL C Q to to • •� M LOct }r v M L LL. 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LA co V) .6 co N E C) uj vv, 10 f0 a Y m L LA 0 N CL m m T 0 co co 0- E C) 20 AM ,.283 Hydraulic Fracturing Applic, an — Checklist PBU AURO 5-129 (PTD No. 210-132; Sundry No. 318-044) Paragraph Sub -Paragraph Section Complete? (a) Application for (a)(1) Affidavit Provided with app4c,:uc,;i Notification to ConuccPr iii p, SFU Sundry Approval ExxonMobil, Chevron, DNR 2/2/201,8 (a)(1) Plat Provided with application SPD 2/2/2018 (a)(2)(A) Well location Provided with application. SFD 2/2/2018 Provided with application: No wells are used for drinking water purposes are known to lie within %, mile of the surface location of PBU S-129. According to the Water Estate map available through DNR's Alaska Mapper application (accessed online Feb. 2, 2018), the nearest water source well (Milne Point K-34) is located 8.4 miles northwest of the fracturing interval. (See DNR LAS Case (o)(2)(8) Each water well within i4 mile Files 20693 and 30050.) MPU K-34 is open to the Ugnu SPD Formation between -4,327 and 4,516 true vertical feet 2/2/2018 subsea ("TVDSS"), which is about 2,170 true vertical feet shallower than the proposed fracturing interval within the Kuparuk Formation of PBU S-129. The nearest temporary surface water right is for BP to withdraw water from a lake west of S Pad, which is located 1.3 miles to the northeast, (See DNR LAS Case File 28154.) Within G mile there are 145 wells and lateral wellbores (a)(2)(C) Identify all well types within r4 and 50 plugged back wellbores that were lost during SFU mile drilling operations. Within %, mile of the fracturing interval, 2/16/2018 there are 16 wells and lateral wellbores. Tertiary -aged Sagavanirktok Formation, which lies beneath permafrost In this area, perrnafrost appears to be about (a)(3) Freshwater aquifers: geological 1,550' thick. (Only one older exploratory well located in SFD name, measured and true vertical depth this area --N Kuparuk State 26-12-12—was logged with a 2/2/2018 sonic tool from ground level to surface casing point.) However, in AEO 1 the AOGCC concluded that those AOGCC Page 1 February 22, 2018 20 AM .283 Hydraulic Fracturing Applic. )n — Checklist PBU AURO S-129 (PTD No. 210-132; Sundry No. 318-044) Paragraph Sub -Paragraph Section portions of freshwater aquifers occurring beneath the Western Operating Area of Prudhoe Bay Unit 1) do not currently serve as a source of drinking water, 2) are situated at a depth and location that makes recovery of water for drinking water purposes economically impracticable, and 3) have TDS content of 7,000 rng/I or more By letter dated July 1, 1986, EPA exempted aquifers in this area for Class_II injection activities (source: AOGC('s ALO 1 order file, Sections #5 and 06) For an outline of the Western Operating Area, see the EPA's "Alaska Oil & Gas Aquifer Exemptions Interactive Map" available online under the "Permits" section of EPA Region 10's web page at https://www.epa.goy/uic/underground-inlection- control-region-10-ak-id-or-and-wa. Complete? SFD 2/2/2018 (o)(4) Baseline water sampling plan No drinking water sources. Sampling not required. sFF,?12!201 } (a)(5) Casing and cementing information Provided with application. CDW2/12/2018 Intermediate casing cement spotty but provides isolation and containment of the reservoir to upper formations. as1es) Casing and cementing operation As a precaution, the closest open sliding sleeve to the VTL assessment heel will be 1076' ft away so this is nearest point that frac 2/222/2/ 18 will initiate. (The i4 length of each frac stage is predicted to be 250 ft so this will keep the Iasi frac stage wing from intersecting the casing shoe. J (o)(6)(A) Casing cemented below lowermost freshwater aquifer and Provided with application. CDW conforms to 20 AA 25.030 2/12/2018 isolate BJ Each hydrocarbon zone is Yes. In PBU S 129, 8-3/4" intermediate hole was drilled to SFD isolated 9,445' MD (6,820' 7VD, -6,757' TVDSS), and 7" casing was 2/6/201F run to 9,436' MD (also 6,820' TVD, -6,757' 1VDSS because AOGCC Page 2 February 22, 2018 Paragraph 20 AA 5.283 Hydraulic Fracturing AppliL..,on — Checklist PBU AURO S-129 (PTD No. 210-132; Sundry No. 318-044) Sub -Paragraph Section Complete? this section of PBU S-129 is nearly horizontal), and cemented with 144 barrels (808 ft'; 454 sacks, yield = 1.78) Si D of LiteCrete and 39 barrels (219 ft', 223 sacks, yield = 0 98) 2/20/2018 of Class G Cement (pertinent cementing reports are appended to the base of this checklist, below) Volumetrically, the top of cement for the 7" casing string is estimated to be about 4.178 MD, 3,822' TVD, 3,760' TVDSS (assuming 309E hole washout), so cement covers the Kuparuk Formation at the heal of the well and the confining shales, likely reaching upward to cover the stratigraphic equivalent of all but the shallowest oil shows in nearby well PBU TW -C ("Term Well C"; see oversized AOGCC cross section, attached separately) (a)(7) Pressure test: information and pressure -test plans for casing and tubing Provided with application. 3500 psi rig casing test, 4000 psi CDW installed in well MITIA planned, 4500 PSI MITT plan. 2 12 2018 / / Pressure ratings and schematics: Provided with application. 5K psi wellhead 10K psi tree CDW w wellbore, wellbore, wellhead, ROPE, treating head saver, max. frac. Pressure 6700 psi. Pump knock out 6050 2/12/2018 psi and 6350 psi, Global kickout 6350 psi. (a)(9)(A) Fracturing and confining zones: Upper confining zones: from PBU TW C mud log - several lithologic description for each zone intervals of shale and silty shale within the Hue, HRZ, and Kalubik Shale intervals between about 8,054' and 8,872' (aJ(9J(BJ Geological name of each zone measured depth (MD; equivalent to 6,242' to -6,706' true vertical depth subsea, or TVDSS) have an aggregate 818' (a)(9)(C) and (a)(9)(D) Measured and true measured thickness (MT) and 464' true vertical thickness SFD vertical depths (TVT). (See attached figures, below.) Estimated fracture 2/6/2011~ r'radient provided by operator is 0 70 psi/ft. (o)(9)(E) Fracture pressure for each zone i racturing Zone: from Operator — Kuparuk Formation, about 8,872' and 9,030' MD (-6,706' to -6,767' TVDSS) having an aggregate 158' M -f and 61' TVI. The mud log AOGCC Page 3 February 22, 2018 20 A& :.283 Hydraulic Fracturing Applic. .an — Checklist PBU AURO S-129 (PTD No. 210-132; Sundry No. 318-044) Paragraph Sub -Paragraph Section Complete? Cementing Information for PBU S-129 Surface Casing Intermediate Casing— 7" Description or Operations Description of Operations PJSIJ WITH SLB CEMENTERS RU SLB CEMENT LINES PUMP 5B8LS OF to o PPG CIRCULATE AND CONDITION HOLE IN MUD PUSH. SHUT DOWN AND PRESSURE PREPARATION FOR CEMENT JOB TEST TO 3500 PSI PUMP 95 BBLS OF MUD • STAGE UP IN 112 -BBL INCREMENTS TO 6 PUSH AHEAD AT 5 BPM AND 225 PSI SHUT BPM DOWN AND DROP BOTTOM PLUG PUMP 500 RRl v 122n. K¢Q 11 ruFrSACKI OF 10 2 - ICP 905 PSI, FCP 780 PSI PP,AR .TI S T IT PADAT6BPMAND RECIPROCATE PIPE IN 10 -FT STROKES. 220 PSI RECIPROCATE PIPE IN LOFT STOKES - PU WT 240K SO WT 135K - 6 SPId.210 PSI 156 BBLS LEAD AWAY MUD 7" CASING CEMENT JOB PUSH AT SHOE 6 BPM225 PSI 244 BBLS LEAD AWAY, . - PUMPED 30 BBLS 1C 8 PPG MUD PUSH II AT BOTTOM PLUG LATCHED AT 900 PSI STOP 6 BPM RECIPROCATING PIPE AND LAND ON - PRESSURE TESTED SURFACE LINES TO LANDING RING 3 500 PSI TEST GOOD - 6 BPM. apo PSI 338 BBLS LEAD AWAY . DROP BOTTOM PLUG SPACER 42 SHAKERS - 6 BPM, PSI, LEAD PUMPED 144 BBLS 11 0 PPG LITE CRETE SP IN ERFBEIL CEMENT SPACER INTERFACE TO SURFACE SUR CEMENT AT 6 BPM - SLOW TO a BPM 269 PSI, 500 BBLS LEAD • 454 SKS 1 R3 CI I FT'SK YIELD AWAY PUMPED 39 BBLS 15 8 PPG CLASS G SWAP CEMENT AT 6 BPM ON THE FLY AND PUMP 87 8131 0447 OF Is A CLASS n CEMENT 111A • 223 SKS, 1.16 CU FT,SK YIELD, CUFTISACK) AT 6 BPM AND 440 PSI - DROP TOP PLUG - 3 BPM. 320 PSI. 74 BBLS TAIL AWAY GOOD - DISPLACED WITH 5 BBLS OF 8.3 PPG CEMENT BACK TO SURFACE CLEAN UP WATER FROM SLB TRUCK AND 350 BBLS OF 10 3 PPG BRINE FROM RIG DROP TOP PLUG AND BEGIN DISPLACEMENT - BUMPED PLUGS. PRESSURED UP TO 500 AT 7 BPM AND 295 PSI - 5 BPM 1140 PSI, 2D9 68L5 DISPLACED 'PSI OVER FCP TO 1 900 PSI SLOW TO 3 BPM FOR BUMP 1028 PSI 223 - BLED OFF AND CHECKED FLOATS FLOATS BBLS DISPLACED HELD. BUMP PLUG AT 234 BBLS DISPLACED AND _ CEMENT IN PLACE Al 1039 HRS BLEED OFF PRESSURE AND CHEHECKKFLOATS TQTAL OF 365 BBI RD CASING AND CEMENTING EQUIPMENT CEMENT BACK TO SURFACE PRESSURE UP TO 3500 PSI FOR 5 MIN TO TLST CASING AOGCC Page 9 February 22, 2018 20 AA( ;.283 Hydraulic Fracturing Applic in — Checklist PBU AURO S-129 (PTD No. 210-132; Sundry No. 318-044) Paragraph sub -Paragraph section Complete? i s4 j s'' ` QISu2 • A , <,E A' -44L K'Ty l2' iF' UL e e As w r' `a `�lit' r • 4 A7 A04 rs, a,x"K',23,, a n.; _. 28A 0 fz 29 K . _0A fJ 3q 2�� As -116 s a 17 A Ns S 27 _1 `- 271 � KEY -213 G2rr A`3 L Well Paths;J Term 2 s 2-e r One -Half Mil! Radius OWell C I FraC Interval - Proposed % Ifuparuk Fm Intercepts 0 1 mi • AOGCC Page 10 February 22, 2018 20 AA( ;.283 Hydraulic Fracturing Applic 3n — Checklist PBU AURO S-129 (PTD No. 210-132; Sundry No. 318-044) Paragraph Sub -Paragraph Section Complete? -8500 Upper Confining Layers --no Fracturing Interval -9000 Lower Confining Layers r 500292343300 2101320 PBU AURORA S-129 Hue Shale'. it . HRZ.v..�--_ KLBK w� y= ....PWK1 _ ww Si KPRK8 f uw KARKn _- o_w Vertical scale for reference log is in units of feet of measured depth -8500 1 -9000 { AOGCC Page 11 February 22, 2018 20 AAC .283 Hydraulic Fracturing Applic. )n — Checklist PBU AURO S-129 (PTD No. 210-132; Sundry No. 318-044) Paragraph I Sub -Paragraph Section Complete? 600292336300 500292343300 ----- 500282318300 2070970 10 mdw 2101320 0 1 miles 2031810 PSUAURORAS-126 _- PBUAURORAS-128 PSUAURORAS-116 _. -..Henn ..Aft win -K Colville Colville s� Hue Shale cw HRZ Shale N� Kalubik Shale Kuparuk 'T f • Miluveach ,- Shake— Upper Confining Layers Nue 6^am Fracturing Interval Hue Shale' HRZ Shale o Kalubik Shale Kalubik Shale Kuparuk Kuparuk Vertical scale tor cross -sec tror is m units of True Vertical Feat Subsea Lower Confining Layers Miluveach _ Shale— wo THE STATE "ALASKA GOVERNOR MIKE DUNLEAVY Kenneth Allen Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S -129A BP Exploration (Alaska), Inc. Permit to Drill Number: 219-149 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 Surface Location: 3645' FSL, 4103' FEL, Sec. 35, T12N, R12E, UM Bottomhole Location: 3383' FNL, 2360' FEL, Sec. 03, TI IN, R12E, UM Dear Mr. Allen: Enclosed is the approved application for the permit to redrill the above referenced development well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerelyy, Y Je m Price Chair, Commissioner DATED this L day of November, 2019. II 11MIV■ir11 W 14mill STATE OF ALASKA 'ASKA OIL AND GAS CONSERVATION COW OCT 2 4 2019 PERMIT TO DRILL 20 AAC 25.005 la. Type of Work:1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1c. S, d for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil P1 ' Service - Winj ❑ Single Zone 0 . Coalbed Gas ❑ Gas Hydrates ❑ Redrill p ` Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2_ Operator Name: 5. Bond Blanket Q 1 Single Well ❑ 11 Well Name and Number: BP Exploration (Alaska), Inc Bond No. 29S105380 PBU S -129A Address: 3, 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612 Anchorace. AK 99519-6612 MD: 14320' TVD: 6819'' PRUDHOE BAY, AURORA OIL 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): ADL 028257, 028258 & 028261 Surface: 3645' FSL, 4103' FEL, Sec. 35, T12N, R12E, UM 8. DNR Approval Number: 13. Approximate spud date: Top of Productive Horizon: 890' FSL, 3073' FEL, Sec. 34, T12N, R12E, UM 83-47 December 1, 2019 , 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 3383' FNL, 2360' FEL, Sec. 03, T11 N, R12E, UM 13785 Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 80.94 feet • 15. Distance to Nearest Well Open 4b. to Same Pool: Surface: x- 619339 ' y- 5979855 Zone - ASP 4 GL Elevation above MSL: 33.79 feet• 1227 16. Deviated wells: Kickoff Depth: 3168 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 3712 Surface: 3039 18 Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Couplinq Length MD TVD MD TVD i cluding stage data 8-1/2"x9-7/8" 7" 26# L-80 VamTop HC 9923' Surface Surface 9923' 6817' 963 sx LiteCrete. 122 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 VamTo 4547' 9773' 6742' 14320' 6819' 505 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 12964 6791 None 9030 6829 11891 Casing Length Size Cement Volume MD TVD Conductor/Structural 80 20" -260 sx Arctic Set (Aoorox.) 29-109 29-109 Surface 3266 9-5/8" 1220 sx Arctic Set Lite. 447 sx Class'G' 29-3295 29-3193 Intermediate 8849 7" 454 sx LiteCrete, 223 sx Class'G' 26-8875 26-6770 Production Liner 4171 3-1/2" Uncemented Slotted Liner 8699-12870 6674-6791 Perforation Depth MD (ft): 8909-12838 Perforation Depth TVD (ft): 6787-6846 Hydraulic Fracture planned? Yes flik-' No 1%;.1 20. Attachments Property Plat ❑ BOP Sketch Q Drilling Program 4 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 2 21 Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Minae. David from without prior written approval. Authorized Name Allen, Kenneth W Contact Email David.Mingeobp.com Authorized Title Engineering Team Lead Contact Phone +1 9075645279 Authorized Signature DateCJ " y Commission Use OnIv Permit to Drill API: 50-029-23433-01-00 Permit Approval } See cover letter for other Number. Date: �! r ( ��1 requirements: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Q" Other: QP�C' 1 � �" "r O 3 S Z Samples req'd: Yes 0No 0 Mud log req'd: Yes ❑ No 171"' H2S Yes LN No ❑ W ❑ measures Directional svy req'd: Yes No `� 2�� 0�(1 7) V 4LN- lm,, Gt � �/��J''`/'�h r— Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No Ls t o p e 1iWT 0� ""`� a Ct'e V /� �] -] �� '� N,•.G,IE,�^ �w os initial injection MIT req'd: Yes ❑ No ❑ CSL. ,_d ,4�c..�c. ��-�e��v,�t,-�{ J��• T,�•� S'vA)y P %'t?i%Gb v i'a����! APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: I 1� , C 3 - t.- ly, U H I U I N �"' 1— ', 3<::�IX m,G-k Form 10-401 Revised 5/2017 / Submit Form and This permit is valid for 24 months rom the date of approval (20 AAC 25.005(g)) I Attachments in Duplicate �� i M To: Alaska Oil & Gas Conservation Commission From: David Minge, ODE Date: October 24, 2019 RE: S-1 29A Permit to Drill The S-1 29A well is scheduled to be drilled by Parker 272 in December 2019. The proposed S-1 29A sidetrack will be a horizontal producer targeting the Kuparuk C Sands. The planned well is a two - string, ultra-slimhole design using T' intermediate casing, and 4-1/2" production liner. The intermediate casing will be set at the top of the Kuparuk, and the production interval will be completed with a cemented liner. -----____— - The maximum anticipated surface pressure from the Kuparuk with a full column of gas from TD to surface is 3064 psi (assumes 10.6 ppg EMW most likely pore pressure and a 0.1 psi/ft gas gradient). The well will be drilled by Parker 272 using their 5000 psi four preventer BOP stack (3 rams and an annular). The BOP rams and annular will be tested to 3500 psi. A detailed operations summary is included with the permit application. If there are any questions concerning information on S -129A, please do not hesitate to use the contact information below. David Minge Office: (907) 564-5279 Cell: (907) 250-2917 Email: david.minge(cD_bp corn Attachments: Current Well Bore Schematic Proposed Pre -Rig Schematic Proposed Completion Directional Package BOPE Schematic Wellhead Schematic Tree Schematic As -Built Survey S -129A PTD 1 10/24/2019 Planned Well Summary Well S -129A Well Producer Ob Target Kuparuk ` tive Current Status Producer (Shut -In) Estimated Start Date: 12/01/19 Time to Complete: 24.0—Days--- Surface 4.0Da s Surface Northing Easting Offsets TRS Location 5,979,854.990 ' 619,339.050 3645' FSL / 4103' FEL ' 12N 12E Sec 35 Northing Eastinq TVDss Offsets TRS TKUP 5,977,034.610 615,137.282 6736' 890' FSL / 3073' FEL 12N 12E Sec 34 BHL 5,972,772.763 615,923.956 6738' 3383' FNL / 2360' FEL 11 N 12E Sec 3 Planned KOP: 3168' MD Planned TD: 14,320' MD / 6738' TVDss Rig: Parker 272 GL -RT: 1 47.1 RTE ref MSL): 1 80.94 Directional – BHGE WPI 1 Maximum Hole Angle: 690 in the intermediate section 92° in the production section Close Approach Wells: All offset wells pass BP anti -collision scan criteria. Survey Program: Reference attached directional program Nearest Property Line: 13,785' Nearest Well within Pool: 1227' Hydraulic Fracture Planned? Yes S -129A PTD 2 10/24/2019 Formation Tops and Pore Pressure Estimate Formation Estimated Formation Top TVDss) Most Likely Pore Pressure (EMW SV2 2867 8.7 SV1 3187 8.7 UG4 3518 8.85 UG4A 3556 8.85 UG3 3846 8.85 UG1 4373 8.7 UG Ma 4723 8.7 UG_Mb1 4771 8.7 UG_Mb2 4820 8.7 UG Mc 4886 8.7 SB–Na 4965 8.7 SB–Nb 4983 8.7 SB–OA 5085 8.7 SB_OBa 5124 8.7 SB_OBb 5159 8.7 SB_OBc 5200 8.7 SB_OBd 5246 8.7 SB_OBe 5301 8.6 SB_OBf 5340 8.6 SB_OBf_Base 5350 8.6 CM2 5583 9.2 CM-1/TLBK 5982 10 HRZ 6520 10 TKC 6735 10.6 TKB 6790 10.6 S -129A PTD 3 10/24/2019 Casing/Tubing Program Hole Size Casing / WtIFt Grade Conn Length Top Bottom CM1 10.1-10.9 Tbg O.D. KUP 10.8 - 11.0 MD / TVDss MD 1 TVDss 42" 20" 129# A-53 - 80' Surface 108'/ 80' 12-1/4" 9-5/8" 40# L-80 BTC 3168' Surface 3168'/ 3013' 8-1/2" x 9-7/8" 7" 26# L-80 VamTop HC 9923' Surface 9923'/ 6736' 6-1/8" 4-1/2" 12.6# 13Cr-85 Vam Top 4547' 9773'/ 6661' 14320'/ 6738' (150' lap) Tubing 4-1/2" 12.6# 13Cr-85 Vam Top 9773' Surface 9773'/ 6661' (-5' into liner PBR) Mud Program Intermediate Mud Properties: LSND Depth Interval Density PV (cp) YP Ib/100ft2 9-5/8" Window -SB OBf 9.1 -9.5 10-20 20-30 CM2 9.3-9.6 CM1 10.1-10.9 HRZ 10.6-11.0 KUP 10.8 - 11.0 Production Mud Properties: Water Based Pol mer Fluid Depth Interval Density PV (cp) YP tbMQOftZ 7" Shoe - TD 1 10.8 - 11.0 .1 <12 1 12-20 Logging Program Intermediate Sample Catchers - as required by Geology Drilling: Dir/GR/RES Oen Hole: None Cased Hole: Cement Bond Lo Production I Sam to Catchers - as required by Geology Drilling: Dir/GR/RES/NEU/DEN Oen Hole: None Cased Hole: None S -129A PTD 4 10/24/2019 Cement Program Intermediate Lead Oen hole volume + 10% excess Basis Lead TOC 500 ft MD from surface casing shoe Basis Tail Oen hole volume + 10% excess + 80 ft shoe track Tail TOC 500 ft MD above casing shoe Spacer 50 bbls 12.0 ppg Mud Push II Total Cement Lead 298.4 bbls, 1675 cuft, 963 sks of 11.5 ppg LiteCRETE — 1.74 cuft/sk Volume Tail 25.2 bbls, 142 cuft, 122 sks 15.8 ppg Class G — 1.16 cuft/sk Temp BHST 148' F Production Lead N/A Lead TOC N/A Basis Tail Open hole volume + 30% excess + 80 ft shoe track + liner lap + 200'4" DP x 7" LNR annulus Tail TOC Top of liner Spacer 40 bbls 12.0 ppq Mud Push II Total Cement Lead N/A Volume Tail 104.4 bbls, 586 cuft, 505 sks of 15.8 ppg Class G— 1.16 cuft/sk Temp BHST 148° F Surface and Anti -Collision Issues Surface Close Proximity: No wells will be affected by the Parker 272 rig shadow. Sub -Surface Pressure Management: The following wells will be shut-in for reservoir pressure purposes while drilling: • S-128 • S-1 16A • S-134 Anti -Collision: All offset wells pass BP anti -collision scan criteria. Offset Well Ownership Information All offset wells identified within 200 ft of the proposed wellbore are operated by BP. Hydrogen Sulfide Reference "Drilling Critical Issues" section. Faults Reference "Drilling Critical Issues" section. Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and ' inject at DS -04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS -04 for injection. Haul Class I waste to DS -04 and/or Pad 3 for disposal. Contact the GPB Environmental Advisors (659-5893) for guidance. S -129A PTD 5 10/24/2019 Well Control The 8-1/2" x 9-7/8" hole and 6-1/8" hole sections will be drilled with well control equipment consisting of 5,000 psi working pressure rams (2), blind/shear rams, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be - tested to 3,500 psi. BOP test frequency for S -129A will be 14 days with function test every 7 days. Except in the event of a significant operational issue that may affect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. 8-1/2" x 9-7/8" Intermediate Interval Maximum anticipated BHP 3712 psi at the TKUP at 6736' TVDss 10.6 ppg EMW Maximum surface pressure 3039 psi at the TKUP 0.10psi/ft gas gradient to surface 25 bbls with 13.5 ppg frac gradient. Kick tolerance Assumes 10.6 ppg pore pressure in the KUP + 0.5 ppg kick intensity and 10.9 ppg MW. Planned BOP test pressure Rams test to 3500 psi / 250 psi. Annular test to 3500 psi / 250 psi Integrity Test — 8-1/2" x 9- LOT after drilling 20'-50' of new hole 7/8" hole 7" Casing Test 3500 psi surface pressure 6-1/8" Production Interval The base plan is to not conduct the production hole FIT's. See variance request 1. Variance Requests 1. A variance to 20 AAC 25.030(f) is requested to forgo the FIT after drilling out the 7" casing shoe. The planned depth of the intermediate casing shoe is in the target reservoir (Kuparuk), and the production section does not depart the Kuparuk formation. This request is contingent upon a successful intermediate cement job. S -129A PTD 6 10/24/2019 Drill and Complete Operations Summary Rig Operations 2. MIRU Parker 272. 3. Test BPV from below to 3500 psi. 4. Nipple down dry hole tree. Install test dart in HP BPV. Nipple up BOPE (annular, 4-1/2" x 7" VBR, blind -shear, 2-7/8" x 5" VBR) and test to 5000 psi (annular to 3500 psi). Subsequent BOPE tests to 3500 psi rams, 3500 psi annular. - �5/ o -v �J e-�, G -e 14. �CrC, 5. Pull BPV. Circulate out freeze protect with 9.3 ppg brine. 6. Pull 4-1/2" tubing from the pre -rig cut at 3400' MD. 7. Cut 7" casing at 3150' MD (-150' above 9-5/8" shoe). 8. Circulate out OA freeze protect 9.3 ppg brine. 9. Pull 7" casing from cut depth. 10. Run GR/CCL log on E -Line. Set EZSV at 3150' MD and pressure test to 3500 psi. 11. Set 9-5/8" whipstock on EZSV. Displace the well to LSND milling fluid- ---------------------------------------- End luid.----------------------------------------End of Sundry: Start of Permit to Drill ----------------------------------- 12. Mill window in the 9-5/8" casing plus 20' of new formation. 13. Perform LOT. 14. Drill 8-1/2" x 9-7/8" intermediate hole section to TD at 9923' MD (TKUP). 15. Run and cement 7", 26#, L-80 Vam Top HC casing. 16. Install 7" packoff. Pressure test to 3500 psi. 17. Pressure test the 7" casing to 3500 psi. 18. Freeze protect the 9-5/8" x 7" annulus with diesel. 19. Change upper 4-1/2" x 7" VBRs to 2-7/8" x 5" VERs and pressure test 3500 psi. 20. Drill out the 7" casing shoe. 21. Drill 6-1/8" production hole section to TD at 14320' MD. Aa 22. Run and cement 4-1/2", 12.6#, 13CR, Vam Top liner. Set liner hanger and liner top packer.23. Run 4-1/2", 12.6#, 13CR, VamTop tubing. 5 Oen 24. Set the production packer. Pressure test the tubing and 4-1/2" x 7" annulus to 3500 psi. &_5_5 6 25. Freeze protect the well. 26. Install TWC. 27. ND BOPE, NU adapter flange and tree. 28. RDMO Parker 272. Post -Rig Operations: 1 V Tree work as necessary. Install & test tree saver. 2 F Circulate completion fluid. 3 S Drop B&R. 4 F Set packer. MIT -T. MIT -IA. 5 S Pull B&R. 6 C Assist frac unit erf, frac, FCO, plug, repeat) 7 F Multi -stage frac. S -129A PTD 7 10/24/2019 S -129A Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures A. Intermediate Hole: The SV sands are expected to be 8.7 ppg EMW. The Ugnu is expected to be 8.7 — 8.9 ppg EMW. The Schrader Bluff is expected to be 8.7 ppg EMW. The Coleville is expected to be 9.2 — 10.0 ppg EMW. The Kuparuk is expected to be 10.6 ppg EMW. Formation pressures will be controlled with a 9.3 — 11.0 ppg mud. B. Production Hole: The Kuparuk is expected to be 10.6 ppg EMW. Formation pressure will be controlled by using 10.8 — 11.0 ppg water-based mud. II. Lost Circulation/Breathing A. Intermediate Hole: There are five expected fault crossings in the intermediate hole. Past wells have experienced lost circulation and wellbore breathing as a result of similar fault crossings. B. Production Hole: There are four expected fault crossings in the production hole. Lost circulation risk for this hole section is low. v III. Fault Locations Formation Where Fault Encountered MD Intersect TVDss Intersect Throw Direction and Magnitude Uncertainty Lost Circ Potential Fault 1 — UG4 3816' 3556' NE/15' +/- 200' Low Fault 3 — UG1 6015' 4559' W/75' +/- 200' Low Fault 4 — SB OBe 7440' 5316' NE/35' +/- 200' Med - Fault 5 — CM2 8203' 5832' N/10' +/- 200' Low Fault 3a — CM2 8221' 5843' WAS +/- 250' Low Fault 6 — KUP 10,605' 6758' S/15' +/-100' Low Fault 7 — KUP 11,473' 6753' N/10' +/-100' Low Fault 8 — KUP 12,681' 6731' SW/10' +/-100' Low Fault 9 — KUP 13,877 6738' N/20' +/- 200' Low V. Hydrogen Sulfide S -Pad is considered an H2S site. Recent H2S data from the pad is as follows: VI. Anti -Collision Issues All offset wells pass BP anti -collision scan criteria. CONSULT THE S -PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. S -129A PTD 8 10/24/2019 Well Name H2S Levet Date of Reading #1 Closest SHL Well H2S Level S-26 46 ppm 01/26/2017 #2 Closest SHL Well H2S Level S -05A 125 ppm Injector (assumed) #1 Closest BHL Well H2S Level S-135 20 ppm 02/16/2019 #2 Closest BHL Well H2S Level S-125 18 ppm 01/19/2019 Max Recorded H2S on Pad/Facility S-201 180 ppm 03/09/2012 VI. Anti -Collision Issues All offset wells pass BP anti -collision scan criteria. CONSULT THE S -PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. S -129A PTD 8 10/24/2019 TREE= 4-1/16" CNV VVi3.LHEAD= FMC ACTUATOR= LEO OKB. ELEV = 62.46' BF. BEV = 35.7T KOP= 2300' Max Angle = 95" @ 12170_' 20" CONDUCTOR, 108' Datum MD = 8861' _#, , Dat. TVD = 67W SSI ®= " 9-5/8• CSG, 40#, L-80 BTC, O = 8.835" 3295' 4-1/2• TBG, 12.6#, 13CR-80 VAM TOP, 4083' 0152 bpf, D = 3.958" 7" CSG. 26#, L-80 VT -HC XO L-80 BTC -M 5334' Minimum ID = 2.813" @ 8530' 3-1/2" HES X NIPPLE 3-1/2" TBG, 9.2#, 13CR-85 VAM TOP, 8710' .0087 bpf, D = 2.992" ***LNR DAMAGE STARTING @ -8724'*** ***UNABLE TO DRIFT PAST 8739'*** ***SEE WELL PICTURES*** 7" BKR WwSTOCK 14 -887s- SR NOTES:W ELLANGLE> 70' @ 8971' *** CHk%,#dE TBG MAX DOGLEG: 25.8' @ 9065' S-129 * *** LNR DAMAGE - SEE WELL PICTURES*** MN m 4 ST MD 4083' 41/2' X 3-112' XO, D = 2.992' TYPE GAS LET MANDRELS 7- CSG, 26#, L-80, BTC -M, 8435' .0383 bpf, m = 6.276" 20' OIL SWELL PACKERS NO SIZE TOP DEPTH MN m 4 ST MD TVD IDEV TYPE VLV LATCH PORT DATE 5 4163 3811 46 MMG DOME RK 16 08/09/18 C 05/07/18 2.812" 2 11097 C 4 4263 3881 46 MMG DMY RK 0 11/17/10 3 6872 5597 52 MMG DOME RK 16 08/09/18 2 8358 6483 54 MMG DMY RK 0 11/17/10 1 8460 6542 56 MMG SO RK 22 08/09/18 7- CSG, 26#, L-80, BTC -M, 8435' .0383 bpf, m = 6.276" 20' OIL SWELL PACKERS NO SIZE TOP DEPTH MN m 4 3-1/2" 8930 2.992" 3 3-1/2• 9714 2.992" 2 3-1/2" 10659 2.992" 1 3-1/2" 12266 2.992" PERFORATION SUMMARY REF LOG: LWD ON XX/XX/10 ANGLE AT TOP PERF: 56" @ 8722' Note: Refcr to Production DB for historical perf data SIZE I SPF INTERVAL I Opn/Sgz I SHOT I SQZ 1-9/16" 6 8722 - 8737 O 06/07/19 1 1 1 4-1/2" SLTD 112297 - 12838 O 11/15/10 8530' j--�3-1/2" HES X NP, ff) = 2.813" 8595' -I3-1/2" NDPG SINGLE SENSOR SUB, ID = 2.992" 8631' 7" X 3-1/2" HES TNT PKR, O = 2.949" 8667' 3-1/2" HES X Nom, ®= 2.813" 8698' 3-1/2' HES X Nom, m = 2.813" 8699' 8710' 7" X 5" BKR HRD ZXP LTP w /FLEXLCK HGR, ® = 4.400" 8730' S' X 3-1 /2" XO, D = 2.99• 8909 C MILL® OUT WINDOW (7") 8875' - 8910' FISH: MILLED WFD CBP 1-1__1189V (06/03/15) 3-1/2• LNR, 92#, L-80 BT -M, .0087 bpf, D = 2.992• I 12870' BKR CMD SLD SLV (BX PROFILEI NO# TOP DEPTH Opn/Sgz DATE MIN ID 7 8909 C 05/07/18 2.812" 6 9198 C 05/07/18 2.812" 5 9446 C 05/07/18 2.812" 4 9951 C 05/07/18 2.812" 3 10446 C 05/07/18 2.812" 2 11097 C 05/07/18 2.812" 1 11890 O 03/24/11 2.812" 11546' I 4-1/2" X 3• LITE- SLIP ON SWELL PKR, ID = 3.958" 12869' PBTD AURORA LWT WELL' S-129 PERMIT No: 2101320 API No: 50-029-23433-00 SEC 35, T12, R1 2E, 1635' FNL & 1177' FVVL DATE REV BY COMMENTSDATE REI/ BY COMMENTS 11/20/10 WES ORIGINAL COMPLETION 08/15/18 DG/JMD GLV GO (08/09/18) 07/22/15 MJCIJ GLV CJO (06/12/15) 06/25/19 EP1YJMD ADPERFS (06/07/19) 05/08/18 JTC/JMD CLOSED SLEEVES (05/07/18) 05/15/18 CJNIJMD GLV CJO (05/11/18) 06/27/18 JNLJJMDI CORRECTT3D BF ELEV DOTH BP Exploration (Alaska) 07/26/18 JTCJJMDI ADDED SAFETY NOTES RE LNR DAMAGE TREE= 4-1116" CIW PRE -RIS WELLHEAD FMC PROPOSED ACTUATOR = —� LEO OKB. ELEV = 62.46' RF R PA/ = 4r. 77' Max Angle = 95^ 12170' 20" CONDUCTOR, 108' ' Datum MD= 8861' #' Datum ND = 6700' SS ®_ " 9-5/8" CSG, 40#, L-80 BTC, D = 8.835" 3295' 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 4083' 0152 bpf, ID = 3.958" 7" CSG. 26#, L-80 VT -HC XO L-80 BTGM6334' l T X IA TOP 8 BOT CMT 7160' - 8460' - Minimum ID = 2.813" @ 8530' 3-1/2" HES X NIPPLE S-129 S1 [NOTES: W ELL ANGLE > 70° @ 8971' *" CHRUME TBG *** MAX DOGLEG: 25.8^ @ 9065' '**LNR DAMAGE - SEE WELL PICTURES*** lIiii 2006' 4-1/2" HES X NP, ID= 3.813" 10. 3-1/2" TBG, 9.2#, 13CR-85 VAM TOP, J8710' .0087 bpf, ID = 2.992" TBG PUNCH (0607/19) $722' - 873T ***LNR DAMAGE STARTING @ -8724'** ***UNABLE TO DRIFT PAST -8739'*** ***SEE WELL PICTURES*** 7" BKR WHIPSTOCK 1-1 8876' 7" CSG, 26#, L-80, BTC -M, 1-� 9435' 0383 bpf, ID = 6276" 20' OIL SWELL PACKERS NO SIZE TOP DEPTH MN D 4 3-1/2" 8930 2.992" 3 3-1/2" 9714 2.992" 2 3-112" 10659 2.992" 1 3-1/2" 12266 2.992" PERFORATION SUMMARY REF LOG: LWD ON XX/XX/10 ANGLE AT TOP PERF: "@' Note: Refer to Production DB for trstorical perf data FISH MILLED WFD CBP SIZE SPF NTERVAL OprdSgz I SHOT SQZ (06/03/15) 4-1/2" SLTD 12297 - 12838 O 11/15/10 NOTE: LINER IS UNCEMENTED —3400' -- TBG CUT 4083' 4-1/2" X 3-112" XO, D = 2.992" GAS LET MANDRELS ST MD "� DEV TYPEJ VLV LATCH PORT DATE 5 4163 3811 46 MMIG DOME RK 16 08/09/18 4 4263 3881 46 MMG DMY RK 0 11/17/10 3 6872 5597 52 MNG DONE RK 16 08/09/18 2 8358 6483 54 MM1G DMY RK 0 11/17/10 1 18460 6542 56 MWIG SO RK 1 22 08/09/18 8630' j 3-1/2" HES X NP, ID = 2.813" 8696' 3-1/2" NDPG SINGLE SENSOR SUB, D = 2.992" 8631' 7" X 3-1/2" HES TNT PKR, D = 2.949" 8667' 3-1 /2" HES X NIP, —K)—= 2.813" 8698' -13-1 /2" HES X NP, D = 2.813" $69$' 3-112" WRP 8699'7" X 5" BKR HRD ZXP LTP 07/22/15 MJC/JMD GLV C/O 06/12/15 w /FLEXLCK HGR, D = 4.400" 8710' 873W 5" X 3-1/2- XO, ID = 2.99" MILLED OUT WINDOW (7") 8875' - 8910' 1 11891' 1 3-1/2" LNR, 92#, L-80 ET -M, .0087 bpf, D = 2.992" 1—j 12870' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/20/10 N7ES ORIGINAL COMPLETION 08/15/18 DG/JMD GLV C/O 08/09/18 07/22/15 MJC/JMD GLV C/O 06/12/15 0625/19 EPD/JMD ADPERFS 06/07/19 05/08/18 JTC/JMD CLOSED SLEEVES 05/07/18 0924119 DM/JMD PRE -RIG PROPOSED 05/15/18 CJN/JMD GLV C/O 05/11/18 0927119 DD/JMD FO(ED PERF TO PUNCH 0627/18 JNUJMD CORRECTED BF ELEV DEPTH 05/07/18 2.812" 4 07/26/18 JTC/JMD ADDED SAFETY NOTES RE: LNR DAMAGE C BKR CMD SLD SLV (BX PROFILE) NOf# TOP DEPTH Opn/Sqz DATE MN ID 7 8909 C 05/07/18 2.812" 6 9198 C 05/07/18 2.812" 5 9446 C 05/07/18 2.812" 4 9951 C 05/07/18 2.812" 3 10446 C 05/07/18 2.812" 2 11097 C 05/07/18 2.812" 1 11890 O 0324/11 2.812" 11546' 14-112"X 3" LTTE SLIP ON SWELL PKR, D = 3.958- 12869' PBTD AURORA UNIT WELL: S-129 PERMIT No: 2101320 API No: 50-029-23433-00 T12, R12E, 1635' FNL 8 11 77'FWL BP Exploration (Alaska) TREE = = -- - -_ FMC _WELLHEAD ACTUATOR= DEV OKB = 62.46' REF ELEV = ' BF. ELEV = 35.77' KOP = 2300' Max Angle = _ _ JMD Datum MD = Datum TVD = 6700' SS PROP( ED REV 3 20" COND, 108' 9-5/8" WHIPSTOCK (1/_) 316$' 9-518" CSG, 40#, L-80 BTC, ID = 8.835" 3168' Minimum ID = "@ ' TOC 3668' ITOP OF 4-1/2" LNR — 9773' 4-1/2" TBG, 12.6#, 13CR-85 VAM TOP, 9]]3' .0152 bpf, ID = 3.958" 7" CSG, 26#, L-80 VAM TOP HC, 9923' — .0383 bpf, D = 6.276" PERFORATION SUMMARY REF LOG: ON ANGLE AT TOP PERF: _° @ ' Note: Refer to Production DB for historical perfdata SIZE I SPF I INTERVAL I Opn/Sgz I SHOT I SQZ S-1 29A PBTD — — 4-1/2" LNR, 12.6#,13CR-85 VAM TOP, 14320' '— .0152 bpf, ID = 3.958" I :TY NOTES: WELL ANGLE > 700 @ MAX DLS: _'@ '. CHROME TBG & LNR. ^2000' -4-1/2" HES X NIP, ID = 3 813" MILLOUT WINDOW (S -129A) f]AA 1 IFT rAA Nr1RF1 S ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 SIDETRACK (S -129A) 09/19/19 JMD BUILTPROPOSED 09/24/19 JMD 5 10/08/19 DM/JMD BUILT PROPOSED REV 2 10/23/19 1 DM/JMD BUILT PROPOSED REV 3 4 3 2 1 4-1/2" HES X NIP. ID = 3.813" 14-1/2" SI -B SAPPHIRE GUAGF-, ID = " 9633' 1--�7" X 4-1/2" HES TNT PKR, ID = 3 856" 14-1/2" HES X NIP. ID = 3.813" 14-1/2" HES XN NIP. ID = 3.725" 1 9773' �7" X 5" WFD LTP & HGRw/1-EBACK SLV, ID = 4.310" 9773' 4-112" WLEG, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/20/10 N7ES ORIGINAL COMPLETION SIDETRACK (S -129A) 09/19/19 JMD BUILTPROPOSED 09/24/19 JMD BUILT PROPOSED REV 1 10/08/19 DM/JMD BUILT PROPOSED REV 2 10/23/19 1 DM/JMD BUILT PROPOSED REV 3 15" X 4-112"X0. ID = 3.910" AURORA UNIT WELL: S -129A PERMIT No: AP I No: 50-029-22846-01 SEC 35. T12N. 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U o i d Ys LS) a3 00 S a U Z N w m v g o O � p (O m m rn rn 0 rn O o o O /00�0� 00/�0� d G G N C14 C\l N O o a) P, o O N N j Q rn a a U o O v Y Y v O n z z E d � O co L, O O fn0 O O l0O O v a0 O) N N O m OMj In �aaF=` w N ci U O d L u7 N v (D oD O O O r r m m d � � C O r DI r d O C d U i0 C U d C f0 O O d w N U R dL a 0 l0 0 l0 f0 ami vm f0 0 >Ir J I- Z V)o �0 LL F r LL F LL LL LL LL ULL F O F F F O 'O O O O "O F U O Q (D '00 O O O O O O L O O L L O O O O O o O o O L O O O L O O O L O L CL O O L O L o O ZD m U) L O M 0') O (6 O O O O O N M O O O O M Cl) M M N N O O O O M O �-- O M O � o N O O O N C O O O O a O O J O J J J J J O o J O Qm Y O J% O O O O J �Q g E ELL N 0 Q ❑ m ❑ � 0 0 N 0 ❑ N ❑ N 0 O` CO - ❑ v O W LL E � > E U) > r r v L O Z r� �g� v r r r r r °a z(n(nav) r v Q n. c 0 o �o R T m m m m m ` C t6 .. C C 2 � U O (;Ln a m �- Q) M (O m (D O n (O V (O N O M M M (O N N M v v v (D DI N n n D) M (0 Q7 n� n v ao O fD M V (D m (0 M O 00 M DD N M CD M fO (D f0 O n . M O M (0 O OD M M v n (O v n n DI n M o O o O N v n n n N O N W O (O M m l0 N N K1 n v IT N N n m O O Of 01 M oN o N a0 � O �- N N N N N N M M M N N N O O) a0 u) u) N I?v a V v v a V V t V v M M M W C_ O 07 m O N N 0 OD O O n (O O O U On OD LO 01 m � 00 Cl) N N M N Off N M M O O O N O) V M N n (D o QI v m r (O 00 �_ t0 O N O O O N M N M n n n ao O d) N O O v u) v Lo o M o0 n 0) r- N o N n W O N CC C' N N J U) N N Nm v (D N n n n CA M NN ao Of O Z i N N N N (h C? (h C7 C7 V v (A to n + v (O n Cp O o O n f0 D) v O O Cl N � m n n N N N (fat CR f0O M CO n d' OD ao N 4'1 10 N M O Q7 (0 CD V Cl) n O N N O (0 v O 0) n m O �+ W O N N 0 v (0 n o (0 Cl) N cO (0 M a M N O G. y O O N M V (O OD N n O OD N OD Oct OD OD OD OD Cc00 00 OD OD OD OD OD OD OD OD go V Cl) M M M M M M M M v V (O (O (0 O o o N w w (0 (O (D (0 O O N w O (0 o M OO O o O O O O f0 N O N V O o O O O n n (O (O N N N 00 M M v O 9 � O O O O O O o o v v v v M o (O (C) N (O r m m n n n n o o m 0 t v oo v v v v v v v 6 m m w w 0 0 of of of 6 M M 6 o N w m O N n n o (O N N N N o N v m (0 (O n m w w O Nm N v N d (gyp N M (O OD N N W n 0I (A O M n D7 O N v m (r7 v ID M p07 M O') CO M M M M v IT (D (O 00 N m m O O O O O O N N N M 0 rn a R Cl) O LO0 0 a O U w O a 04 0 ❑ m v g o 7 (O m m M rn 00 O o o O v, o o M u� O O O 00 6 o O O f0 O o a) P, o O n L5 o O v v O n O O co L, O O fn0 O O l0O O v a0 O) N N O m OMj In N V co u7 N v (D oD O O O r r coO - O r DI r M❑ f0 O 0 0 0 0 O O c0 0 l0 0 l0 f0 0 (0 f0 0 �0 LL F O LL F LL LL LL LL ULL F O F F F O 'O O O LL F F "O F U O O F '00 O O O O O O L O O L L O O O O O o O o O L O O O L O O O L O L O O l0 O L O O L O L o O L O M 0') O O M O O O O O N M O O O O M Cl) M M N N O O O O M O �-- O M O � o N O O O N C O O O O O O J O J J J J J O o J O O O O O O J% O O O O J E ELL N 0 m ❑ m ❑ � 0 0 N 0 ❑ N ❑ N 0 O` CO - ❑ v O V ❑ E v r r r v r r v r r r r r r r v v r r r r r r v v r v v m n. O �a �a m �a A �o R m m m m m m m m m❑ U H Y to (A (q !A in iq tD (� to to V) (A to in (� cA L7 lA (q to to (A to tq to cq in iq F Q) M (O m (D O n (O V (O N O M M M (O N N M v v v (D DI N n n D) M (0 Q7 n� n v ao O fD M V (D m (0 M O 00 M DD N M CD M fO (D f0 O n . M O M (0 O OD M M v n (O v n n DI n M o O o O N v n n n N O N W O (O M m l0 N N K1 n v IT N N n m O O Of 01 M oN o N a0 � O �- N N N N N N M M M N N N O O) a0 u) u) N I?v a V v v a V V t V v M M M W C_ O 07 m O N N 0 OD O O n (O O O U On OD LO 01 m � 00 Cl) N N M N Off N M M O O O N O) V M N n (D o QI v m r (O 00 �_ t0 O N O O O N M N M n n n ao O d) N O O v u) v Lo o M o0 n 0) r- N o N n W O N CC C' N N J U) N N Nm v (D N n n n CA M NN ao Of O Z i N N N N (h C? (h C7 C7 V v (A to n + v (O n Cp O o O n f0 D) v O O Cl N � m n n N N N (fat CR f0O M CO n d' OD ao N 4'1 10 N M O Q7 (0 CD V Cl) n O N N O (0 v O 0) n m O �+ W O N N 0 v (0 n o (0 Cl) N cO (0 M a M N O G. y O O N M V (O OD N n O OD N OD Oct OD OD OD OD Cc00 00 OD OD OD OD OD OD OD OD go V Cl) M M M M M M M M v V (O (O (0 O o o N w w (0 (O (D (0 O O N w O (0 o M OO O o O O O O f0 N O N V O o O O O n n (O (O N N N 00 M M v O 9 � O O O O O O o o v v v v M o (O (C) N (O r m m n n n n o o m 0 t v oo v v v v v v v 6 m m w w 0 0 of of of 6 M M 6 o N w m O N n n o (O N N N N o N v m (0 (O n m w w O Nm N v N d (gyp N M (O OD N N W n 0I (A O M n D7 O N v m (r7 v ID M p07 M O') CO M M M M v IT (D (O 00 N m m O O O O O O N N N M 0 rn a R Cl) O LO0 0 a O U w O a 04 0 O Q a CL z m Cn n IF a z z x x a N N 3 � o M rn 0 0 a m am\ d u 04 CqN C14 a v E Z z z E m a a f Lw CL m a J a 0 aj E a U) a t Z i N g O til z a <n Cl) a U) rn a V T C CL = a d rn c pQ N N 4, ad+ y rn a V 01M North America - ALASKA - BP PBU S-129 PLAN S -129A S-1 29A WP11 Anticollision Summary Report 21 October, 2019 " Baker Hughes It J b BP p Anticollision Report Baker Hughes Company: North America - ALASKA - BP Project: PBU Reference Site: S Site Error: 0.00usft Reference Well: S-129 Well Error: 0.00usft Reference Wellbore PLAN S -129A Reference Design: S -129A WP11 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well S-129 PLAN KB P272 @ 80.94usft PLAN KB P272 @ 80.94usft True Minimum Curvature 1.00 sigma EDM R5K-Alaska PROD -ANCP1 Offset Datum Reference S -129A WP11 Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 3,124.73 to 9,922.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum centre distance of 1627 Error Surface: Pedal Curve Survey Tool Program From (usft) 166.76 1,151.85 3,124.73 3,168.00 3,570.00 3,570.00 9,922.00 9,922.00 Date 10/21/2019 To (usft) Survey (Wellbore) Tool Name 1,091.17 S-129PB1 Srvy 1 Gyro -WD -SS (S-129PB1 GYRO -WD -SS 3,124.73 5-129PB1 Srvy 2 MWD+IFR+MS (S -129P MWD+IFR+MS-WOCA 3,168.00 S -129A WPll (PLAN S -129A) MWD+IFR+MS-WOCA 3,570.00 S -129A WP11 (PLAN S -129A) BLIND 9,922.00 S -129A WPl l (PLAN S -129A) MWD 9,922.00 S -129A WP11 (PLAN S -129A) MWD+IFR+MS-WOCA 14,320.00 S -129A WPll (PLAN S -129A) MWD 14,320.00 S -129A WPll (PLAN S -129A) MWD+IFR+MS-WOCA Description Gyro while drilling single shots MWD + IFR + Multi Station W/O Crustal MWD + IFR + Multi Station W/O Crustal Blind drilling MWD - Standard MWD + IFR + Multi Station W/O Crustal MWD - Standard MWD + IFR + Multi Station W/O Crustal 10/21/2019 10:29.49PM Page 2 of 5 COMPASS 5000.15 Build 90 �,�,• BP 10 I" Anticollision Re ort Baker 4+ P Hughes Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-129 Project: PBU TVD Reference: PLAN KB P272 @ 80.94usft Reference Site: S MD Reference: PLAN KB P272 @ 80.94usft Site Error: 0.00usft North Reference: True Reference Well: S-129 Survey Calculation Method: Minimum Curvature Well Error: 0.0ousft Output errors are at 1.00 sigma Reference Wellbore PLAN S -129A Database: EDM R5K-Alaska PROD -ANCP1 Reference Design: S -129A WP11 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) BEECH BEECHST-01 - BEECHST-01 - Beechey Pt ST 1 Out of range EX NKUPST NKUPST -NKUPST - NKUPST Out of range EX TW -C TW -C - TW -C - TW -C Out of range S S-01 - S-01 - S-01 3,169.85 3,075.00 164.91 52.63 112.42 Pass - Major Risk S-01 - S -01A - S -01A 3,169.85 3,075.00 164.91 52.63 112.42 Pass - Major Risk S-01 - S-01 B - S-01 B 3,166.10 3,075.00 164.80 52.53 112.41 Pass - Major Risk S-01 - S-01 C - S-01 C 3,166.10 3,075.00 164.80 52.53 112.41 Pass - Major Risk S-02 - IGNORE ME - Plan 3 3,124.73 3,125.00 181.34 44.01 139.81 Pass - Major Risk S-02 - S-02 - S-02 3,124.73 3,125.00 181.08 44.01 139.54 Pass - Major Risk S-02 - S -02A- S -02A 3,124.73 3,125.00 181.49 44.01 139.95 Pass - Major Risk S-02 - S-02ALl - S-02ALl 3,124.73 3,125.00 181.49 44.01 139.95 Pass - Major Risk S-02 - S-02ALl PB1 - S-02ALl PB1 3,124.73 3,125.00 181.49 44.01 139.95 Pass - Major Risk S-02 - S-02APB1 - S-02AP61 3,124.73 3,125.00 181.49 44.01 139.95 Pass - Major Risk S-03 - S-03 - S-03 3,138.49 3,150.00 486.21 45.51 441.08 Pass - Major Risk S-04 - S-04 - S-04 3,130.77 3,250.00 385.23 44.61 344.09 Pass - Major Risk S-05 - S-05 - S-05 3,139.30 3,325.00 497.01 50.64 451.01 Pass - Major Risk S-05 - S -05A- S -05A 3,124.73 3,300.00 487.35 50.52 441.43 Pass - Major Risk S-05 - S-05APB1 - S-05APB1 3,124.73 3,300.00 487.35 50.52 441.43 Pass - Major Risk S-06 - S-06 - S-06 3,138.72 3,375.00 604.23 47.10 561.21 Pass - Major Risk S-07 - Plan S -07B RST - Plan #2 S -07B RST 3,130.65 3,875.00 1,439.20 139.39 1,344.46 Pass - Major Risk S-07 - S-07 - S-07 3,124.73 3,850.00 1,432.78 138.99 1,338.47 Pass - Major Risk S-07 - S -07A- S -07A 3,124.73 3,850.00 1,432.78 138.99 1,338.47 Pass - Major Risk S-117 - S-117 - S-117 6,299.73 5,725.00 824.79 210.80 625.68 Pass - Major Risk S-118 - S-118 - S-118 4,322.10 4,250.00 107.97 84.46 25.07 Pass - Major Risk S-123 - S-123 - S-123 Out of range S-124 - S-124 - S-124 Out of range S-128 - S-128 - S-128 7,118.11 6,150.00 398.16 272.22 294.84 Pass - Major Risk S-128 - S-128PB2 - S-128PB2 7,117.98 6,150.00 398.05 272.21 294.55 Pass - Major Risk S-129 - S-129 - S-129 3,441.08 3,425.00 40.50 0.10 40.50 Pass - NOERRORS S-129 - S-129PB1 - S-129PB1 3,441.08 3,425.00 40.50 0.10 40.50 Pass - NOERRORS S-129 - S-129PB2 - S-129PB2 3,441.08 3,425.00 40.50 0.10 40.50 Pass - NOERRORS S-134 - S-134 - S-134 3,590.23 3,475.00 286.24 61.19 225.09 Pass - Major Risk S-15 - S-15 - S-15 3,388.33 3,300.00 81.65 47.69 34.06 Pass - Major Risk S-15 - S-15PB1 - S-15PB1 3,388.33 3,300.00 81.65 47.69 34.06 Pass - Major Risk S-16 - S-16 - S-16 3,532.77 3,450.00 201.44 64.69 136.81 Pass - Major Risk S-17 - S-17 - S-17 3,834.60 3,675.00 406.18 77.91 328.42 Pass - Major Risk S-17 - S-1 7A - S -17A 3,834.60 3,675.00 406.18 77.91 328.42 Pass - Major Risk S-17 - S-17AL1 - S-17AL1 3,834.60 3,675.00 406.18 77.91 328.42 Pass - Major Risk S-17 - S-17ALl PB1 - S-17ALl PB1 3,834.60 3,675.00 406.18 77.91 328.42 Pass - Major Risk S-17 - S-17AP61 - S-17APB1 3,834.60 3,675.00 406.18 77.91 328.42 Pass - Major Risk S-17 - S-1 7B - S-1 7B 3,834.60 3,675.00 406.18 77.91 328.42 Pass - Major Risk S-17 - S -17C - S -17C 3,834.60 3,675.00 406.18 77.91 328.42 Pass - Major Risk S-17 - S-17CPB1 - S-17CPB1 3,834.60 3,675.00 406.18 77.91 328.42 Pass - Major Risk S-17 - S-17CPB2 - S-17CPB2 3,834.60 3,675.00 406.18 77.91 328.42 Pass - Major Risk S-19 - S-19 - S-19 3,128.12 3,100.00 200.49 47.04 154.47 Pass - Major Risk S-20 - S-20 - S-20 3,141.99 3,175.00 222.67 54.45 172.52 Pass - Major Risk S-20 - S -20A - S -20A 3,141.99 3,175.00 222.67 54.45 172.52 Pass - Major Risk S-21 - S-21 - S-21 3,133.52 3,200.00 317.48 49.17 272.14 Pass - Major Risk 10/21/2019 10.29:49PM Page 3 of 5 COMPASS 5000.15 Build 90 f BP p Anticollision Report Baker; Hughes Company: North America - ALASKA - BP Local Co-ordinate Reference: Well S-129 Project: PBU TVD Reference: PLAN KB P272 @ 80.94usft Reference Site: S MD Reference: PLAN KB P272 @ 80.94usft Site Error: 0.00usft North Reference: True Reference Well: 5-129 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore PLAN 5-129A Database: EDM R5K - Alaska PROD - ANCP1 Reference Design: S -129A WP11 Offset ND Reference: Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) S S-213 - 5-213 - S-213 5,372.10 5,225.00 231.89 160.48 91.66 Pass - Major Risk S-213 - S -213A - S -213A 5,063.27 4,950.00 249.61 200.51 73.37 Pass - Major Risk S-213 - S-213AL1 - S-213ALl 5,063.27 4,950.00 249.61 200.51 73.37 Pass - Major Risk 5-213 - 5-213AL1-01 - 5-213AL1-01 5,063.27 4,950.00 249.61 200.51 73.37 Pass - Major Risk S-213 - S-213AL2 - 5-213AL2 5,063.27 4,950.00 249.61 200.52 73.36 Pass - Major Risk S-213 - 5-213AL3 - 5-213AL3 5,063.27 4,950.00 249.61 200.51 73.37 Pass - Major Risk S-216 - 5-216 - 5-216 3,124.73 3,375.00 571.22 68.58 518.93 Pass - Major Risk 5-22 - S-22 - S-22 3,136.55 3,075.00 177.73 43.45 134.58 Pass - Major Risk 5-22 - S -22A - S -22A 3,136.55 3,075.00 177.73 43.45 134.58 Pass - Major Risk S-22 - S -22B - S-226 3,136.55 3,075.00 177.73 43.45 134.58 Pass - Major Risk S-23 - S-23 - S-23 3,132.19 3,150.10 247.03 44.00 205.33 Pass - Major Risk S-24 - 5-24 - 5-24 3,133.00 3,250.00 402.80 47.92 358.98 Pass - Major Risk S-24 - S -24A - S -24A 3,140.23 3,250.00 409.05 43.94 365.72 Pass - Major Risk S-24 - S-24AP1311 - S-24APB1 3,140.23 3,250.00 409.05 44.20 365.45 Pass - Major Risk S-24 - S -24B - S -24B 3,140.23 3,250.00 409.05 43.94 365.71 Pass - Major Risk 5-25 - S-25 - S-25 3,138.29 3,275.00 428.63 44.61 387.73 Pass - Major Risk 5-25 - S -25A - S -25A 3,138.29 3,275.00 428.63 44.61 387.73 Pass - Major Risk S-25 - S-25APB1 - S-25APB1 3,138.29 3,275.00 428.63 44.61 387.73 Pass - Major Risk 5-26 - S-26 - S-26 3,134.66 3,300.00 479.97 41.89 441.34 Pass - Major Risk S-27 - 5-27 - S-27 3,129.25 3,300.00 481.95 43.69 441.61 Pass - Major Risk S-27 - S -27A - S -27A 3,129.25 3,300.00 481.95 43.69 441.61 Pass - Major Risk S-27 - S-27APB1 - S-27AP61 3,129.25 3,300.00 481.95 43.69 441.61 Pass - Major Risk S-27 - S -27B - S -27B 3,128.70 3,300.00 481.62 43.68 441.30 Pass - Major Risk S-28 - 5-28 - S-28 3,130.99 3,300.00 464.71 47.98 420.45 Pass - Major Risk S-28 - S -28A - S -28A 3,130.99 3,300.00 464.71 47.98 420.45 Pass - Major Risk S-28 - S -28B - S -28B 3,131.84 3,300.00 465.03 48.00 420.75 Pass - Major Risk S-28 - S-28BPB1 - S-2813PB1 3,131.84 3,300.00 465.03 48.00 420.75 Pass - Major Risk 5-30 - S-30 - S-30 3,131.58 3,425.00 716.04 43.85 675.02 Pass - Major Risk 5-31 - S-31 - S-31 3,128.99 3,425.00 657.26 59.84 601.11 Pass - Major Risk S-31 - S -31A- S -31A 3,128.99 3,425.00 657.26 59.84 601.11 Pass - Major Risk S-400 - S-400 - S-400 5,491.95 4,748.00 678.93 158.28 569.05 Pass - Major Risk S-400 - 5-400A - S -400A 5,554.79 4,705.00 578.24 247.98 497.10 Pass - Major Risk 10/21/2019 10.29:49PM Page 4 of 5 COMPASS 5000.15 Build 90 ��• BP Baker pAnticollision Report Hughes Company: North America - ALASKA - BP Project PBU Reference Site: S Site Error: O.00usft Reference Well: S-129 Well Error: 0.00usft Reference Wellbore PLAN S -129A Reference Design: 5-129A WP11 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well S-129 PLAN KB P272 @ 80.94usft PLAN KB P272 @ 80.94usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference Depths are relative to PLAN KB P272 @ 80.94usft Coordinates are relative to: S-129 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27 * OGP-Usa AK Central Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 0.91 ° Ladder Plot 1600 _I I I I I I I l I I I ------- - - - --'- - -- , I - ------- - - - -'- ' 1200- 200 I I I C) 0 C) I O I- - - - - - - - - -'- ai % 800 - - - I I I I N I I I I ".. I I I a 400 - L N Q - C) I _ I -� B1 S- 1 1 -S 16,S-16P$1,S-16PB1 V2 --' --$ 6'` --='-------- I r I - - - - - - - - I - - S-1 6, S-1 6,8-16 V2 I P 2V1 $ S, 7 AV3 $ S-05,S-05APB1,S-05APB1 V1 $ S- 27S -27V1 $ S -05,S -05,S -05V3 'A 1PB1 V1 0 3 05,S-0 - 1 PE 1 V1 0 2000 5-27 S -04,9-2713 V7 6000 8000 -+J W,S-30,S-30 V112000 1 -4• S-31,S-31A,S-3M%%sufed Depth (2000 uSftlin) b S-02, S-02AL1, S-02ALl V0 P ll V2 S-31 S-31 S-31 V1 S-02 S-02APB1 S-02APB1 V1 $ S-01,S-01A,S-01AV3 - - S-02,IGNORE ME, Plan 3V0 $ S-01, S-01 C, S-01 C VOA S-02, S -02A, S -02A V 1 �f S-01, S-01, S-01 V9 $ S-02, S-02, S-02 V4 S-01, S-01 B, S-01 B V4 $ S-02, S-02ALl P131, S-02AL1 P131 V0 A1.3 V7 S-134, S-134, S-134 VO - S-19, S-19, S-19 V1 AL 1 V9 $ S300, S-400, S-400 V4 $ KUPST-01, KUPST-01, KUPST-01 1 AL 2 V5 $ S-400, S300A, S -400A V6 $ S-07, S-07, S-07 V2 $ S-124, S-124, S-124 V8- S-07, Plan S -07B RST, Plan #2 S-0 21 AL1 -01 V7 S-1 23, S-1 23, S-1 23 V1 0 $ S-07,S-07A,S-07AV1 ✓2 S-28,S-28A,S-28AV1 $ BEECHST-01, BEECHST-01, Beece S-25, ea orse, ea orse ea orse 1 ( 10/21/2019 10 29.49PM Page 5 of 5 COMPASS 5000.15 Build 90 North America - ALASKA - BP PBU S S-129 PLAN S -129A S-1 29A WP11 Anticollision Summary Report 21 October, 2019 Baker S Hughes bBP p Anticollision Report Baker Hughes Company: North America - ALASKA - BP Project: PBU Reference Site: S Site Error: 0.00usft Reference Well: S-129 Well Error: 0.00usft Reference Wellbore PLAN S -129A Reference Design: S -129A WP11 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well S-129 PLAN KB P272 @ 80.94usft PLAN KB P272 @ 80.94usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference S -129A WPll Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,922.00 to 14,320.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum centre distance of 1627 Error Surface: Pedal Curve 10/21/2019 10:33:16PM Page 2 of 4 COMPASS 5000.15 Build 90 Survey Tool Program Date 10/21/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 166.76 1,091.17 S-129PB1 Srvy 1 Gyro -WD -SS (S-129PB1 GYRO -WD -SS Gyro while drilling single shots 1,151.85 3,124.73 S-129PB1 Srvy 2 MWD+IFR+MS (S -129P MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 3,124.73 3,168.00 S -129A WPll (PLAN S -129A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 3,168.00 3,570.00 S -129A WP11 (PLAN S -129A) BLIND Blind drilling 3,570.00 9,922.00 S -129A WP11 (PLAN S -129A) MWD MWD - Standard 3,570.00 9,922.00 S -129A WP11 (PLAN S -129A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 9,922.00 14,320.00 S -129A WP11 (PLAN S -129A) MWD MWD - Standard 9,922.00 14,320.00 S -129A WPl l (PLAN S -129A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 10/21/2019 10:33:16PM Page 2 of 4 COMPASS 5000.15 Build 90 bBP p Anticollision Report Baker Hughes Company: North America - ALASKA - BP Project: PBU Reference Site: S Site Error: 0.00usft Reference Well: S-129 Well Error: 0.00usft Reference Wellbore PLAN S -129A Reference Design: S-1 29A WP11 Summary Site Name Offset Well - Wellbore - Design S 5-02 - IGNORE ME - Plan 3 5-02 - 5-02 - S-02 5-02 - S -02A - S -02A S-02 - S-02ALl - S-02ALl S-02 - S-02ALl PB1 - S-02ALl PB1 S-02 - S-02APB1 - S-02APB1 S-06 - S-06 - S-06 5-07 - Plan S-076 RST - Plan #2 S -07B RST 5-07 - 5-07 - S-07 5-07 - S -07A - S -07A S-128 - S-128 - 5-128 S-128 - S-128PI32 - S-128PI32 S-129 - S-129 - S-129 S-129 - S-129PB2 - S-129PB2 S-19 - S-19 - S-19 S-20 - S-20 - 5-20 S-20 - S -20A - S -20A S-213 - 5-213A - S -213A S-213 - 5-213ALl - S-213ALl S-213 - S-213ALl-01 - S-213ALl-01 S-213 - S-213AL2 - S-213AL2 S-213 - S-213AL3 - S-213AL3 S-216 - S-216 - S-216 5-27 - 5-27 - S-27 S-27 - S -27A - S -27A S-27 - S-27APB1 - S-27AP131 S-27 - S -27B - S -27B 5-28 - S-28 - S-28 5-28 - S -28A - S -28A S-28 - S -28B - S -28B S-28 - S-28BPB1 - S-28BPB1 S-30 - S-30 - S-30 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well S-129 PLAN KB P272 @ 80.94usft PLAN KB P272 @ 80.94usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) 10/21/2019 10.33.16PM Page 3 of 4 COMPASS 5000.15 Build 90 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 9,939.83 9,725.00 1,338.02 188.87 1,168.31 Pass - Major Risk 9,938.47 9,725.00 1,374.53 192.40 1,202.87 Pass - Major Risk 10,947.00 10,675.00 92.76 1.02 91.74 Pass - Minor 1/10 10,375.13 10,080.00 200.30 1.48 199.90 Pass - Minor 1/10 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 10/21/2019 10.33.16PM Page 3 of 4 COMPASS 5000.15 Build 90 J"11�VbBP p Anticollision Report Baker Hughes Company: North America - ALASKA - BP Project: PBU Reference Site: S Site Error: 0.00usft Reference Well: S-129 Well Error: 0.00usft Reference Wellbore PLAN S -129A Reference Design: S -129A WP11 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well S-129 PLAN KB P272 @ 80.94usft PLAN KB P272 @ 80.94usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference Depths are relative to PLAN KB P272 @ 80.94usft Coordinates are relative to: S-129 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27 ` OGP-Usa AK Central Meridian is 150° 0'0.000 W ° Grid Convergence at Surface is: 0.91 ° E 1200 0 0 0 CLC � soo C N U 0 a� m 400 U 01 � 2V1 A 1PB1 V1 1 V1 0 i\1.3V7 V 1 V9 %L 2V5 !1 AL1 -01 V7 Ladder Plot - LEGEND $ S-25,S-25APB1,S-25APB1 V1 - k- S-16,S-16PB1,S-16PB1 V2 $ S-26, S-26, S-26 V1 -', -16,S-16V2 $ S-27 S 27,A,S-27AV305,S-05APB1,S-05APB1 V1 $ S-27, S-27', S-27 V1 $ S-05, S-05, S-05 V3 2 -2 -27 1 -05 - 2500 -A- S-27, S-�, -27B V7 7500 10000 -*J 4W, S-30, S-30 V1 15000 -t-- S-31,S-31A,S-3Measured Depth (2500 usftfin) S-02,S-02AL1,S-02AL1 V0 43- S-31 S-31 S-31 V1 S-02 S-02APB1 S-02APB1 V1 $ S-01,S-01A,S-01AV3 $ S-02,IGNOREME,Plan3V0 $ S-01, S-01 C, S-01 C VO „N S-02, S -02A, S -02A V 1 -X- S -01,S -01,S-01 V9 $ S-02, S-02, S-02 V4 -A- S-01, S-01 B, S-01 B V4 $ S-02, S-02AL1 P61, S-02AL1 PB 1 V0 S-134, S-134, S-134 V0 S-19, S-19, S-19 V 1 $ S-400,S-400,S-4o0V4 $ KUPST-01,KUPST-01,KUPST-01 1 $ S-400, S -400A, S -400A V6 $ S-07, S-07, S-07 V2 $ S-124, S-124, S-124 V8 $ S-07, Plan S -07B RST, Plan #2 S-07 B -iF S-123, S-123, S-123 V10 $ S-07, S -07A, S -07A V 1 S-28,S-28A,S-28AV1 $ BEECHST-01, BEECHST-01, Beece ea orse. seanorse wi. tieanorse Irl ( 10121/2019 10: 33 16P Page 4 of 4 COMPASS 5000.15 Build 90 c � t. m to 0 Z 0��1 CN c�tV V Z O aid 3+ U �Y � j m mz z E Oa _ � W U N N U O U U U U p z W m d m d Of d d d d LL of ae a: fr O LU w U> v cl U y c U m � a � r m n 1. d 4 � a10i U � ZC a„ 0 `?z .tQ EE_ H m N N m z a^ N N a c� N U) O � a >d o > d W F 0 m N J d W Z N 0 O m r m N r V7 0 O N VJl �� W Nrn Z m h N n W N m 0 U N W p o 3 cZW-9o O_ J 1' CL CL 7 N Q N m J av2waJr U d -, W C N - 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O N O J (D tho .. `D C O O N N .CN`I. - --_ - _ ---<- __- m O O O C X � l m L') u)a m 07 00rp cn ON �+q� O m _� - .- -_ - - -- -_- - - - -_ N - -car - O coeYv - - - a O � O m a W O o N N (L? 7 pQj cn -v7 D m (7 N I c6 rn OD�i INn w N J O w rn C o U) I Q S tD N r W M J W JL J N m U ^ f ~ O C Z W J O 32 O -- _._ ----___.. .---_�---- (n ch W r m I m ch m Lb "S rn a m o m o Io o cn ! m h (n N (!J CL -- N Q cD Z cn � I d N N d to .w a. a a a - wo W (N' p CL O O SII _ u) _—_ _ o m cn IO o 0 oo 0 0 0 0 0 0 o 0 0 0 0 m m rn m LD N 0 0 0 0 o0 0 0 m n rn m m rn In N N L(] 0 0 m Lfl 0 0 rnm N 0 0 N 0 0 m N 0 0 m lfl (ui/4sn 0006 5uiylJoN aR s Z�N,t (T co V N t-- 04 N a m Y Z Q a e*Aq 4%� by North America - ALASKA - BP PBU S S-129 PLAN S -129A S -129A WP11 Plus 500ft MD AOGCC Offset Well Report 21 October, 2019 Baker Hughes bBP p Anticollision Report Baker Hughes Company: North America - ALASKA - BP Project: PBU Reference Site: S Site Error: 0.00usft Reference Well: S-129 Well Error: 0.00usft Reference Wellbore PLAN S -129A Reference Design: S-1 29A WP11 Plus 500ft MD Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well S-129 PLAN KB P272 @ 80.94usft PLAN KB P272 @ 80.94usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference S -129A WPl l Plus 500ftMD Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum centre distance of 200 Error Surface: Pedal Curve Survey Tool Program Date 10/21/2019 From To (usft) (usft) Survey (Wellbore) Tool Name 166.76 1,091.17 S-129PB1 Srvy 1 Gyro -WD -SS (S-129PB1 GYRO -WD -SS 1,151.85 3,124.73 S-129PB1 Srvy 2 MWD+IFR+MS (S -129P MWD+IFR+MS-WOCA 3,124.73 3,168.00 S -129A WPll Plus 500ft MD (PLAN S-129 MWD+IFR+MS-WOCA 3,168.00 3,570.00 S -129A WP11 Plus 500ft MD (PLAN S-129 BLIND 3,570.00 9,922.00 S -129A WPll Plus 500ft MD (PLAN S-129 MWD 3,570.00 9,922.00 S -129A WP11 Plus 500ft MD (PLAN 5-129 MWD+IFR+MS-WOCA 9,922.00 14,820.00 S -129A WP11 Plus 500ft MD (PLAN 5-129 MWD 9,922.00 14,820.00 S -129A WPll Plus 500ft MD (PLAN S-129 MWD+IFR+MS-WOCA Description Gyro while drilling single shots MWD + IFR + Multi Station W/O Crustal MWD + IFR + Multi Station W/O Crustal Blind drilling MWD - Standard MWD + IFR + Multi Station W/O Crustal MWD - Standard MWD + IFR + Multi Station W/O Crustal 10/21/2019 11:22.01PM Page 2 of 4 COMPASS 5000.15 Build 90 +• BP �- •0 p Anticollision Report Baker Hughes Company: North America - ALASKA- BP Local Co-ordinate Reference: Well 5-129 Project: PBU TVD Reference: PLAN KB P272 @ 80.94usft Reference Site: S MD Reference: PLAN KB P272 @ 80.94usft Site Error: 0.00usft North Reference: True Reference Well: S-129 Survey Calculation Method: Minimum Curvature Well Error: 0.00usft Output errors are at 1.00 sigma Reference Wellbore PLAN 5-129A Database: EDM R5K - Alaska PROD - ANCP1 Reference Design: S -129A WP11 Plus 500ft MD Offset TVD Reference: Offset Datum Summary Reference Offset Centre to Measured Measured Centre Site Name Depth Depth Distance Offset Well - Wellbore - Design (usft) (usft) (usft) BEECH EX NKUPST Plans: Gwydyr Development (SHL) S S-01 - S-01 - S-01 3,169.86 3,075.00 164.91 S-01 - S-01 A- S-01 A 3,169.86 3,075.00 164.91 S-01 - S-01 B- S-01 B 3,166.11 3,075.00 164.80 S-01 - S-01 C- 5-01 C 3,166.11 3.075.00 164.80 S-02 - IGNORE ME - Plan 3 2,964.52 2,925.00 148.30 5-02 - 5-02 - 5-02 2,963.85 2,925.00 148.30 S-02 - S -02A- S -02A 2,964.88 2,925.00 148.31 S-02 - S-02AL1 - S-02ALl 2,964.88 2,925.00 148.31 S-02 - S-02AL1 PB1 - S-02AL1 PB1 2,964.88 2,925.00 148.31 S-02 - S-02APB1 - S-02APB1 2,964.88 2,925.00 148.31 S-03 - S-03 - S-03 1,495.40 1,475.00 159.46 S-04 - S-04- 5-04 2,083.84 2,075.00 83.98 S-05 - 5-05 - 5-05 481.08 475.00 17.49 S-05 - S -05A - S -05A 462.54 450.00 17.14 S-05 - S-05APB1 - S-05APB1 462.54 450.00 17.14 5-06 - S-06 - S-06 485.19 475.00 125.45 S-118 - S-118 - S-118 4,322.10 4,250.00 107.97 5-123 - S-123 - S-123 320.85 300.00 165.79 S-124 - S-124 - S-124 367.56 350.00 184.31 S-129 - S-129 - 5-129 10,900.00 10,625.00 93.81 S-129 - S-129PB1 - 5-129PB1 3,441.08 3,425.00 40.50 S-129 - S-129PB2 - 5-129PB2 3,441.08 3,425.00 40.50 S-15 - S-15 - 5-15 3,388.33 3,300.00 81.65 S-15 - S-15PB1 - S-15PB1 3,388.33 3,300.00 81.65 S-16 - S-16- S-16 3,493.40 3,400.00 199.89 S-19- S-19- 5-19 3,007.28 2,950.00 179.23 S-20 - 5-20 - S-20 2,805.75 2,775.00 83.33 S-20 - S -20A- S -20A 2,805.75 2,775.00 83.33 5-21 - S-21 - S-21 2,549.69 2,525.00 104.04 5-22 - S-22 - S-22 3,074.05 3,000.00 171.59 5-22 - S -22A - S -22A 3,074.05 3,000.00 171.59 S-22 - S -22B - S -22B 3,074.05 3,000.00 171.59 S-23 - S-23 - 5-23 2,764.30 2,725.00 133.08 S-24 - S-24 - 5-24 2,193.84 2,175.00 83.22 S-24 - S -24A - S -24A 2,196.30 2,175.00 83.24 S-24 - S-24APB1 - S-24APB1 2,196.30 2,175.00 83.24 S-24 - S -24B - S -24B 2,196.30 2,175.00 83.24 S-25 - 5-25 - S-25 1,116.98 1,099.95 48.33 S-25 - S -25A - S -25A 1,116.98 1,099.95 48.33 S-25 - S-25APB1 - S-25APB1 1,116.98 1,099.95 48.33 S-26 - S-26 - 5-26 616.16 600.00 14.82 S-27 - S-27 - S-27 465.54 450.00 53.78 S-27 - S -27A - S -27A 465.54 450.00 53.78 S-27 - S-27APB1 - S-27APB1 465.54 450.00 53.78 S-27 - S -27B - S -27B 464.72 450.00 53.76 5-28 - S-28 - 5-28 464.50 450.00 92.37 5-28 - S -28A - S -28A 464.50 450.00 92.37 S-28 - S -28B - S -28B 465.67 450.00 92.40 10/21/2019 11.22:01PM Page 3 of 4 COMPASS 5000.15 Build 90 BP Baker c ,��;► p Anticollision Report Hughes Company: North America - ALASKA- BP Project: PBU Reference Site: S Site Error: 0.00usft Reference Well: 5-129 Well Error: 0.00usft Reference Wellbore PLAN S -129A Reference Design: S -129A WPll Plus 500ft MD Summary Site Name Offset Well - Wellbore - Design S 5-28 - S-28BP61 - S-28BPB1 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well S-129 PLAN KB P272 @ 80.94usft PLAN KB P272 @ 80.94usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 465.67 450.00 92.40 10/21/2019 11:22.01 PM Page 4 of 4 COMPASS 5000.15 Build 90 o N = v o W aa�� goY oKv 2 3 1 NaK o U pp OFp 1 b Q m �a �wJ=S��ainr � 4nv�i vii a��a• �v�i �e�i� vii v�iss au�i�v�i of �NNN\ �• NN �. kk S% 5 p¢V nW 2• N• y]y� ` NNNn ZNNv 27777 NN t2:2 -3:I Nn n nn Y _ - I I 3 3 l it 8 we a6O � eK OWy� O sa ma tWt V V V �.. _ .._— 77= ' = � I J fJ W C pK O < O D 3 0 D g Wz = av ` V \r m - 2 i� - ann Nnn .B/L 9-.t; pn� yy VV�� U U UU W�n W 3r O1Z- K W W g Wz = av ` V \r n U U 8. 15 207.01 26.25 666.75 57.78 1467.61 13.12 1 333.25 22.75 577.85 9.15 232.41 4 1/16-5000 (R-39) SCSSV EXIT TEST PORT E 9 .47 94 , TEST PORT 10 LOCKDOWN SCREWS I1-5000 (R-54) 0 �2 1/16-5000 MOD 120 GV SCSSv EXIT C J6 I 4.06 tr 7 II , 'NEST PORT 1 10 LOCKDOWN SCREWS --- - II -5000 (R -54) n r-2 1/16-5000 MOD 120 GV ITEM PART NUMBER DESCRIPTION 13-300-030 DIVERTER LANDING RING 2 P138322-0005 9 5/8 CASING HANGER 3 P172070 SLIP -IN LANDING RING 4 P164819 CASING HEAD ASSEMBLY 5 13-300-718 GEN 5 TUBING HEAD ASSEMBLY 8 P123277-0002 7 CASING HANGER 7 !2-150-016 7 PACKOFF ASSEMBLY 8 P156963 TUBING HANGER ASSEMBLY 9 02-047-619 TUBING HEAD ADAPTER ASSEMBLY 10 12-093-174 9 5/8 C-21 CASING HANGER II PI 18334-0005 BELL NIPPLE 12 12-093-112 7 C-21 CASING HANGER o p ALQ2KA ANCHORAGE, AK 20 X 9 5/8 X 7 X 4 1/2 PRIVATE ANDCONF10 ENT IAL UNLESS OTHERIUSE SPEC CED REVISIONS 0 m -El --.ma 1. aas 1. •pints IN xL1EF PFpuECi Ox56e gNOLE 30' xuST $TRIUIL NISI— 25✓ 20 OD CASING 9 5/8' OD CASING 7 O CASING 4 I/2' OD CASING ESERIPTUEN GENERATION 5 WELLHEAD 20 X 9 5/8 X 7 X 4 I/2 Ii -5000 COMPLETION REF: OM100042348 0012DM1080698 DTVI 106 711 UI 6T 28.31 77 4 1/16-5000 ® ® 4 1/16-5000 MOD 120 GV Q -- --- — — — ---- T--- ---------- --- — ------------ - --I--- ----- ----- -- -- - 92.25 4 1/16-5000 MOD 120 GV O 4 1/16-5000 MOD 120 GV ACTD OO 50.12 -- -O ---- W --- o- -- O O O O 4 1/16-5000 MOD 120 GV O PRIVATE AND CONFIDENTIAL REVISIONS DESCRIPTION MaR0UE2 OB -01-06 4/16 5000 TREE tilaROUEp2v a OB -01-06 W/ 4 1/16-5000 WING _ AM iON� 08-01-06 u ,LT ON O8 -C,_ aDMI00023007 -N- 1 129 S PAD %y ;I VICINITY MAP F r. NTS ELEVATION MONITORING POINT � i�i'I.�rr � . � � •,9 y+ {( k YL ........ e.neee•es ae .•. YEAR ELEVATION COMMENTS '; •Te•shy E Bam art �s 10200. 2016 35.77 MARKED WITH YELLOW PAINT°e.,°°° °, `*ESSIONP& L SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS -BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE NOTES CORRECT AS OF JUNE 05, 2016. 1. VERTICAL DATUM IS BP MSL 2. BASIS OF VERTICAL ELEVATION: MON S-4; ELEV. = 38.64' 3. BASE FLANGE ELEVATIONS ARE OBTAINED DURING A COMPREHENSIVE WELL -BORE SUBSIDENCE PROGRAM BASED ON LOCAL CONTROL CONFIRMED THROUGH STATIC SATELLITE OBSERVATIONS. 70ATU CHE b„ AAH KMD ` , �" 16 e 28 E"ll : 815 BFE S—PAD WOA — S PAD SHEET WELL 129 00 2 2E ISSUED FOR INFORMATION AAH NMD 'OT TO SCALE BASE FLANGE ELEVATIONS 1 OF 1 NO. DATE RE`ASION BY CNK ■ M M ■ E 29 E......... . C. ...... ... ...... 3 ■ 124i ■ 123 S PAD 28 !29 26 a ?5 VICINITY MAP M 4 7 5 • 24 2� • 23 20 *,-49-TH 0 2 ...... ................. ....... S-PAD ............................ 221 Va'. Leoncrd J. OHanley 11386 - A M SOMME nomm 0 0 M Ess I ONP& SURVEYOR'S CERTIFICATE : HEREBY CER11Fv THAT ' XV 'Rt, RERY REGISTERED AN LfCLNSED -AND SuRvEl:NG 100 200 400 HE STATE OFAASKA ANT THAT 7 --HULL REPR St' HIS AS REPR� XTS A Slikli-I ,VAD.- BY ME OR tNCFrvY DIRECT E 1 SUPERVISION ANG THAT A' - D, 200-iVENSIONS AND OTHER 0 AL-S ARE CORRFC' AS OF S'�PTEYOFR' 10, 20,14 NQTES, J 1 ALASKA STATE PLANE COCRDINA'ES ARE ZONE 4 NAD27. AS-6,[L.T CONDUCTOR CEODETIC , COORDINATES ARE NAD27 2. HCRIZONTAi -AND VERTICAL CONTROL 15 BASED ON S PAD OPERATOR ■ EXISTINGCONCIjc VONUMEN7 S-4, 3 FLEVATTONS ARE 9P EXPLORATION MEAN SEA LEVEL DATUM. 4 MEAN PAO SCALE FACTOR IS 09999165. 5 DATE OF SURVEY: SEPTEMBER !0, 2010, 6. REFERENCE FIELD BOOK: NS10-53, PGS. 1-4 L-OCATED WITHIN PROTRACTED SEC. 35, T. 12--N,.,- R. 12 E., UMI A T— A.S.P. MERIDIAN, ALAS-KA PLAN�: -FOPETIC GECPETIC T-�LLAIR SECT[ON NO- CGI INATES RDINATFS POSITION"DNAS) POSI-ION(D.DD) BOX ELEV. C F F —O RC"-- 701'21 12.9 51 " 70.3535975'3,645' FS-11 29 619.,�39,05 1000,18 4 9'0 '51.i25" 149,0309236* 33.79'. 4,103' F E L Rul' b p WOA S—PAD assoc.AS —BLJILT CONDUCTOR LOCATION WELL S-129 TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: /Development — Service _ Exploratory — Stratigraphic Test — Non -Conventional FIELD: POOL:u �rri-cam Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -) from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements / Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, i/ composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, AURORA OIL - 640120 Well Name: PRUDHOE BAY UN AURO S 129A___ Program DEV Well bore seg L1- - - - PTD#: 2191490 Company BP Exoloration_(Alaska)_I_nc_ _ _ Initial Class/Type DEV/PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA Appr Date SFD 10/30/201 9 Engineering 2 Lease number appropriate_ Yes Surface Location lies_ withinDL- p 028257, To Productive_ Interval lies in ADL0028258;_ 3 Unique well name and number Yes TD lies in ADL0028261. 4 Well located in_a_ defined _pool Yes PRUDHOE BAY, AURORA -OIL - 64.0120, governed by CO 4576 - Corrected_ - - - - - - - - 5 Well located proper distance_ from drilling unit -boundary, - - - - Yes . Rule 1: -"Spacing units within the pool shall -be a minimum of 40_ acres. 20 AAC 2510.55(a)(1)_ 6 Well -located proper distance_ from other wells_ - - - - _ Yes and -(2) -shall- not apply to property lines within the external_boundaries of the Aurora_ - - - - - - 7 Sufficient acreage-ayail_able in drilling unit_ - - - - . Yes Participating_Area."_As_planned, this -well % ill conform_ to spacing requirements. 8 -If-deviated, is wellbore plat_included - - - - - Yes 9 Operator only affected party Yes 10 Operator has -appropriate_ bond in force - - - - - - - Yes 11 Permit_can be issued without conservation order_ - - - - - Yes- 12 es-12 Permit_can be issued without administrative_approval Yes 13 -Can permit be approved before 15 -day wait_ Yes - 14 Well located within area and strata authorized by Injection Order# (put 10# in comments)- (For- NA. - 15 _A_11 wells _wit hin 1/4_mil_e area of review identified (For service well only) N_A_ 16 Pre -produced injector; duration -of pre production Less than 3 months_ (For_service well only) NA_ - - _ _ - - - - _ _ - - 17 _N_onconven. gas conforms to AS31.05.0300.1_.A),(j 2.A -D) NA - ApprDate MGR 10/31/2019 Geology Appr Date SFD 10/30/2019 18 Conductor string -provided - - - - - - . - - - - - - - NA - Sidetrack out of exist_ing_intermediate cas_ing_bel_ow surface casing shoe_ 19 Surface casing -protects all -known_ USDWs - . - - - - - - _NA_ Sidetrack out of-existing_intermediate casing_below surface casing shoe_ - - - - - - - 20 CMT_v_ol_ adequate to circulate -on conductor & surf_csg NA_ Sidetrack out of existing_ intermediate casing -below surface casing shoe_ - 21 _CMTvoladequate to tie-in long string to -surf csg_ - - - - - NA_ Sidetrack out of existing_ intermediate casing -below surface casing shoe_ - ---- 22 CMT -will cover all -known -productive horizons- - - - - - - - Yes Fully cemented production casing,- T' TOC at 3668'.MD, 3437 s_sTVD -80' tvd above UG4 _ 23 _Casing designs adequate for C, T, B &_ permafrost_ - - - - - - Yes 24 Adequate tankageor reserve pit - _ _ - - - - - - - Yes Parker 272 in ongoing operations with good truck support 25 If.a_re-drill_, has_a 10-403 for abandonment been approved _ _ _ _ _ Yes - _ _ Sundry -319-443 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 Adequate wellbore separation -proposed - - _ - - - - Yes All offset wells pass BP separation criteria - - - - 27 If.diverter required, does it meet regulations_ - - - - _ NA_ - - - Sidetrack out of existing -intermediate cas_ing_bel_ow surface casing shoe_ 28 Drilling fluid program schematic-& equip list adequate_ - - - - - - - Yes - - -All fluids overbalanced -to pore pressure 29 BOPEs,.do they meet regulation - . - - - - - - - - Yes 13-5/8"_3_ram stack with _annular- - --- ----- 30 BOPE_press rating appropriate; test to -(put psig in comments)_ Yes 5M tested to_3500 psi - ---- 31 Choke_manifold complies w/API_RP-53 (May 84)_ Yes - - - - - - - 32 Work will occur without operation shutdown_ - Yes - - - - - - Parker 272 will have ongoing operations 33 Is presence of H2S gas probable - - - - - Yes - - - - - - - S pad is an H2S pad and will -have- standard BP_H_2S monitoring in place 34 Mechanical -condition of wells within AOR verified (For service well only) - - - - - - - - - - - NA_ . - - - - - Separate_ sundry for post rig hydraulic -fracturing - _ - - - - - - 35 Permit_ can be issued w/o hydrogen_ sulfide measures - - - - No - - - H2S measures re_quired:_ S -Pad is an H2S site; nearby Aurora Pool wells measure 1.8 -to 125 ppm_ H2S. 36 -Data- presented on potential overpressure zones- - - - - - - . - - - Yes - . Expected pressures range from 8.7 to 1.0,6.ppg EMW. Planned_ drilling mud program appears_ - - - - - - 37 Seismic analysis of shallow gas zones - - - - NA_ - - adequate to control- operator's forecast pore pressure gradient. Should higher pore pressures 38 Seabed condition survey -(if off_ -shore) - - - - - - - - - - - - - - - - - - - - - - - - NA - - - - - - be encountered, BP has- immediate access to fluid mixing facilities within the_PBU. 39 Contact name/phone for weekly progress reports_ [exploratory only] - - NA- - - Nine fault crossings expected; lost_ circulation and -wellbore breathing risk is moderate to low_. Geologic Engineering Public Commissioner: Date: Commissioner: Date Com ssio Date L aG ApprDate MGR 10/31/2019 Geology Appr Date SFD 10/30/2019 18 Conductor string -provided - - - - - - . - - - - - - - NA - Sidetrack out of exist_ing_intermediate cas_ing_bel_ow surface casing shoe_ 19 Surface casing -protects all -known_ USDWs - . - - - - - - _NA_ Sidetrack out of-existing_intermediate casing_below surface casing shoe_ - - - - - - - 20 CMT_v_ol_ adequate to circulate -on conductor & surf_csg NA_ Sidetrack out of existing_ intermediate casing -below surface casing shoe_ - 21 _CMTvoladequate to tie-in long string to -surf csg_ - - - - - NA_ Sidetrack out of existing_ intermediate casing -below surface casing shoe_ - ---- 22 CMT -will cover all -known -productive horizons- - - - - - - - Yes Fully cemented production casing,- T' TOC at 3668'.MD, 3437 s_sTVD -80' tvd above UG4 _ 23 _Casing designs adequate for C, T, B &_ permafrost_ - - - - - - Yes 24 Adequate tankageor reserve pit - _ _ - - - - - - - Yes Parker 272 in ongoing operations with good truck support 25 If.a_re-drill_, has_a 10-403 for abandonment been approved _ _ _ _ _ Yes - _ _ Sundry -319-443 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 Adequate wellbore separation -proposed - - _ - - - - Yes All offset wells pass BP separation criteria - - - - 27 If.diverter required, does it meet regulations_ - - - - _ NA_ - - - Sidetrack out of existing -intermediate cas_ing_bel_ow surface casing shoe_ 28 Drilling fluid program schematic-& equip list adequate_ - - - - - - - Yes - - -All fluids overbalanced -to pore pressure 29 BOPEs,.do they meet regulation - . - - - - - - - - Yes 13-5/8"_3_ram stack with _annular- - --- ----- 30 BOPE_press rating appropriate; test to -(put psig in comments)_ Yes 5M tested to_3500 psi - ---- 31 Choke_manifold complies w/API_RP-53 (May 84)_ Yes - - - - - - - 32 Work will occur without operation shutdown_ - Yes - - - - - - Parker 272 will have ongoing operations 33 Is presence of H2S gas probable - - - - - Yes - - - - - - - S pad is an H2S pad and will -have- standard BP_H_2S monitoring in place 34 Mechanical -condition of wells within AOR verified (For service well only) - - - - - - - - - - - NA_ . - - - - - Separate_ sundry for post rig hydraulic -fracturing - _ - - - - - - 35 Permit_ can be issued w/o hydrogen_ sulfide measures - - - - No - - - H2S measures re_quired:_ S -Pad is an H2S site; nearby Aurora Pool wells measure 1.8 -to 125 ppm_ H2S. 36 -Data- presented on potential overpressure zones- - - - - - - . - - - Yes - . Expected pressures range from 8.7 to 1.0,6.ppg EMW. Planned_ drilling mud program appears_ - - - - - - 37 Seismic analysis of shallow gas zones - - - - NA_ - - adequate to control- operator's forecast pore pressure gradient. Should higher pore pressures 38 Seabed condition survey -(if off_ -shore) - - - - - - - - - - - - - - - - - - - - - - - - NA - - - - - - be encountered, BP has- immediate access to fluid mixing facilities within the_PBU. 39 Contact name/phone for weekly progress reports_ [exploratory only] - - NA- - - Nine fault crossings expected; lost_ circulation and -wellbore breathing risk is moderate to low_. Geologic Engineering Public Commissioner: Date: Commissioner: Date Com ssio Date L aG Geologic Engineering Public Commissioner: Date: Commissioner: Date Com ssio Date L aG
