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Home My WebLink About223-0051 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Tuesday, October 17, 2023 11:50 AM To:amcvey@asrcenergy.com Cc:McLellan, Bryan J (OGC) Subject:RE: Foggy Island Bay State 1 Wellsite Clearance (PTD 223-005) Subsidence around the well does not meet the intent of AOGCC location clearance requirements found in 20 AAC 25.170. AOGCC should be notified for opportunity to do location inspection next year following site remediation. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Saturday, October 14, 2023 9:33 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Subject: Fwd: Foggy Island Bay State 1 Wellsite Clearance (PTD 223‐005) Jim, Could you respond to Adrienne’s question below about site clearance inspection. She is copied on this email. Thank you Bryan Sent from my iPhone Begin forwarded message: From: "McVey, Adrienne" <amcvey@asrcenergy.com> Date: October 13, 2023 at 1:25:50 PM CDT To: "McLellan, Bryan J (OGC)" <bryan.mclellan@alaska.gov> Subject: Foggy Island Bay State 1 Wellsite Clearance (PTD 223‐005) Bryan, I’m following up on the voicemail I left yesterday afternoon regarding the Foggy Island wellsite clearance inspection required by PTD 223‐005. ERM was at Foggy Island this past summer continuing remediation work per the ADEC Corrective Action Plan. Two pictures of the backfilled well excavation site, taken June 2023, are attached. Per ERM, the edges of the settled area are 6‐12 inches deep. The maximum depth is about 18 inches. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 ERM will return next summer to continue remediation work. The planned scope includes removing remaining geofoam, collecting surface water samples (if required by ADEC), and assessing revegetation efforts. The scope does not currently include filling in the settled area at the well excavation site. If AOGCC wants to conduct a site inspection via helicopter in the near future, we could likely facilitate that. Please let me know how you would like to proceed. Thanks, Adrienne McVey ASRC Energy Services 907‐980‐8623 3 4 March 6, 2023 Kayla Junke Natural Resource Technician 2 Alaska Oil and Gas Conservation Commission 333 W. 7th Ave. Anchorage, AK 99501 Re: Exploratory Field, Exploratory Pool, Foggy Island Bay State 1 BP America Production Company Permit to Drill Number: 223-005 Dear Ms. Junke: Enclosed are the well log files from the cement evaluation log run in the subject well on February 20, 2023. Please acknowledge receipt by e-mailing mcanumc@bp.com. Sincerely, Mike Mc Anulty Liability Manager BP/ Remediation Management 317 Anaconda Road Butte MT 59701 Phone: (907) 355-3914 E-Mail: mcanumc@bp.com Michael C. Mc Anulty LiabilityManager 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address:7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: 16' BF: Total Depth:10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 3 TPI: x- y- Zone- 3 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 3 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 N/A (ft MSL) 22. Logs Obtained: Isolation Scanner (IBC), DSLT (CBL-VDL), and GR-CCL on Feb 20, 2023. 23. BOTTOM 30" B 43' 20" H-40/K-55 159' 13-3/8" K-55 2500' 9-5/8" S-95 9765' 7" P-110 10,855' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 'G' to 8350'. PF 2550' to surf.12-1/4" TUBING RECORD 200 sx (1st job) 175 (remed)10,855' Permafrost cement to surf. N/A 9490' 17-1/2" N/A 8-1/2" N/AN/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG BP America Production Company WAG Gas Mar 2, 2023 223-005 50-029-20146-90-00 Foggy Island Bay State #1 ADL 47506 650' FEL, 700' FSL, Sec 19 T11N R17E UM Same LAS 34343 Feb 3, 1975 11,202' MD/TVD 10,746' MD/TVD 42' 317 Anaconda Rd. Butte, MT 59701 264765 5958522 Same CASING WT. PER FT.GRADE Apr 1, 1975 CEMENTING RECORD 5958522 1730' MD/TVD SETTING DEPTH TVD 5958522 TOP HOLE SIZE AMOUNT PULLED 16' 264765 264765 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) 9490' 36" 26 N/A N/A 26" 84 sx permafrost cement 0' Permafrost cement to surf. N/A 40/43.5/47 0' 0' 159'0' 0' 68 9765' 0' 0' 157.53 94/133 43' 0' 2500' N/A Re-entered a well that was previously classified as Abandoned. Former PTD 174-044. Former API # 50-029-20146-00. See wellbore schematic for depths and lengths of cement plugs and CIBP's set in 9- 5/8" casing. Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Exploratory N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment Received by James Brooks on 3/6/2023 at 11:20 AM Abandoned 3/2/2023 JSB RBDMS JSB 030923 xGDSR-3/14/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD 0' 0' 1730' 1730' Top of Productive Interval 9708' 9708' Kayak 31. List of Attachments: Wellbore schematic, summary of daily operations. Cement bond log will be submitted via secure file transfer. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Adrienne McVey Digital Signature with Date:Contact Email:amcvey@asrcenergy.com Contact Phone: 907-980-8623 Liability Manager General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: INSTRUCTIONS Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Authorized Name and Formation Name at TD: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Michael McAnultyMichael C. Mc Anulty Lisburne 30" 20" ArcticSET 1 15.7 ppg Well Number 1 Field Exploratory 400' CIBP API 50-029-20146-90-00 Borough North Slope Lease No.ADL0047506 State Alaska Spud Date 03-Feb-75 Well Type Exploratory Permit to Drill 174-044 Status P&A 9.8 ppg Brine Coordinates DD Latitude 70.287800 DMS Latitude 70° 17' 16.27" N DD longitude -147.906200 DMS Longitude 147° 54' 15.40" W As Drilled 650' from East line and 700' from South line. Section 19 Township 11-N Range 17-E Elevation 16' 1,715' 1,730' Permafrost 1,908' 9-5/8" FO Collar Class G 15.8 ppg 2,500' Top Bottom Length (ft) 2,566' 13-3/8" Shoe Plug #1 8,283 9,387 1,104 9-5/8" FO Collar Plug #2 2,700 CIBP 2,700' CIBP Plug #3 1,715 2,700 985 Plug #4 400 CIBP Plug #5 0 400 400 Tagged cement plug from original (1975) supension at 9,387'. 4,618' Paleocene 7,058' Cretaceous 7,400' Sea Bee 8,350' TOC 8,283' Class G 15.8 ppg 9,387'9,118' Turonian 7" Liner Top 9,490' 9,462' 9,437' Neocomian 9,765' 9,708'9,708' Lisburne 9.2 ppg Brine 75' Cement Plug 15.8 ppg Class 'G' with GasBLOK Cast Iron Bridge Plug 15.8 ppg Class 'G' Cast Iron Bridge Plug 15.7 ppg ArcticSET 1 Description 13-3/8" 2,500' 68 K-55 9-5/8" 9,765' 40, 43.5 & 47 S-95 7" 9,490' - 10,855' 26 P-110 Well Abandonment Work Completed 30" 43' 157.53 B 20" 159' 94 & 133 H-40 & K-55 Location Details Casing Strings Casing Strings Depth (ft) Weight (ppf) Grade AMOCO Production Company Completed P&A Work Scope Well Foggy Island Bay State Well Details 9-5/8" Shoe 10,200' ELM 10,209' Top of Cement 10,746'10,808' Kayak 10,855' PBTD 7" Shoe 11,202' TD 508 To tal Pe rfor a t i o n s Remediation Management Environmentalliabilitymanagementisourbusiness. 10ͲFebͲ23 Hottapsideoutlet,4"markerpole,and13Ͳ5/8”wellflange.Nopressureobserved.AOGCCInspectorwitnessed. 11ͲFebͲ23 Padprepandmoveinequipment. 12ͲFebͲ23 Continuepadprepandmovinginequipment. 13ͲFebͲ23 Continuepadprepandmovinginequipment. 14ͲFebͲ23 MIRUCTU. 15ͲFebͲ23 CompleteBOPtest.WitnesswaivedbyAOGCCInspector.MUBHA#1Ͳ8.5"mill. 16ͲFebͲ23 Millsurfacecementplugandthermistorcableto170’.Veryslowmilling.POH. 17ͲFebͲ23 Millgaugeisworn.MUBHA#2Ͳnew8.5"mill.Millsurfacecementplugto187'.Brokethrough.RIHpushingthermistor cableto994'.POH.MUBHA#3Ͳspear,8.5"noͲgo,fishingmotor.RIH.Tagthermistorcableat1029'. 18ͲFebͲ23 Fishapproximately2000'ofthermistorcablein2runs.MUBHA#4Ͳ8.5"mill.Tagsecondcementplugandmillfrom2496'Ͳ 2553'(FOcollar).POH.Millgaugeisworn.MUBHA#5Ͳ8.25"mill.TagFOcollaratsamedepth.TimemillthroughFOcollar with8.25"mill. 19ͲFebͲ23 Millcementstringersfrom2557'Ͳ2645'.Tagthirdcementplugandmillfrom5367'Ͳ5470'.RIHandtagbottomcement plugat9387’.Circulatewellto9.2ppgbrine.POH. 20ͲFebͲ23 PTwellboreto1000psi.MIRUEͲlineunit.LogwithIsolationScanner(IBC),DSLT(CBLͲVDL),andGRͲCCLfrom22'Ͳ9352'. RDMOEͲline. 21ͲFebͲ23 MUBHA#6Ͳ3.1"cementingnozzle.LayinCementPlug#1Ͳ78bbl15.8ppgClass'G'withGasBLOK,from9375Ͳ8310'. Circulatewellto9.2ppgbrineaboveplug.PerformweeklyBOPtestwhileWOC. AOGCCSeniorPetroleumEngineerreviewedEͲlinelogandgaveapprovaltoproceed. 22ͲFebͲ23 MUBHA#7Ͳ6"mill.TagCementPlug#1at8283'andsetdown10klbs(AOGCCInspectorwaivedwitness).POH.MUBHA#8 ͲCIBPandsettingtool.SetCIBPat2700'.Setdown10klbsonCIBPforplugverification,per20AAC25.112g(approvedby AOGCCSeniorPetroleumEngineer).LayinCementPlug#2Ͳ71bbl15.8ppgClass'G',from2700'Ͳ1715'.Circulatewellto 9.8ppgbrineaboveplug. 23ͲFebͲ23 MUBHA#8ͲCIBPandsettingtool.SetCIBPat400'.RUnitrogenpump.Blowdowncoiledtubingreelandtop400’ofthe wellaboveCIBP.RDMOcoilunit. 24ͲFebͲ23 PumpCementPlug#3Ͳ30bbl15.7ppgArcticSET1,fromsurface(calculatedwellborevolumetoCIBPat400’is29.3bbl). Topofcementvisiblein9Ͳ5/8"casingatsurface.Nofluidreturnedaheadofcement. 25ͲFebͲ23 Excavatearoundwellheadto5.5’belowtundralevel,inpreparationforwellheadcut. 26ͲFebͲ23 Finishexcavatingaroundwellheadto7’belowtundralevel. 27ͲFebͲ23 Installshoringbox. 28ͲFebͲ23 Cutoffwellhead3.5’belowtundralevel.20"x13Ͳ3/8"annulusneedscementtopͲoff.Plumbtopofcementinannulusat 85'(calculatedfillͲupvolume15bbl). 1ͲMarͲ23 Topoff20”x13Ͳ3/8”annuluswith17bblofArcticSET1cement.Monitorforslumping.Topofffinal12"withcold temperatureQuikrete. 2ͲMarͲ23 AOGCCInspectorwitnessedcutͲoffwellheadandhardcementatsurfacein9Ͳ5/8"casingandallannuli.Weldonmarker plate. SummaryofDailyOperations,FoggyIslandBayState#1P&A(PTD223Ͳ005) ❙CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McVey, Adrienne To:Brooks, James S (OGC) Subject:RE: 10-407 Submittal: Foggy Island Bay State #1 P&A (PTD 223-005) Date:Monday, March 13, 2023 11:47:49 AM Hi James, Productive interval is Lisburne. Thanks, Adrienne McVey Wellsite Leader ASRC Energy Services 907-980-8623 From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Monday, 13 March 2023 09:24 To: McVey, Adrienne <amcvey@asrcenergy.com> Subject: FW: 10-407 Submittal: Foggy Island Bay State #1 P&A (PTD 223-005) Hi, What is the name of the formation for tpi (this is needed for box 29) ? thanx From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Monday, March 6, 2023 12:31 PM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: FW: 10-407 Submittal: Foggy Island Bay State #1 P&A (PTD 223-005) From: McVey, Adrienne <amcvey@asrcenergy.com> Sent: Monday, March 6, 2023 11:20 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Mcanulty, Michael C <mcanumc@bp.com>; Collin Simmons <csimmons31876@cudd.com>; Cismoski, Doug <dcismoski@asrcenergy.com>; Spence, Clinton <cspence@asrcenergy.com> Subject: 10-407 Submittal: Foggy Island Bay State #1 P&A (PTD 223-005) CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from amcvey@asrcenergy.com. Learn why this is important Hello, Please see attached 10-407 for the Foggy Island Bay State #1 P&A (PTD 223-005). Thanks, Adrienne McVey 2023-0302_Surface_Abandon_Foggy_Island_Bay_State-1_am Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 3/2/2023 P. I. Supervisor FROM: Austin McLeod SUBJECT: Surface Abandonment Petroleum Inspector Foggy Island Bay State #1 BP America Production Company PTD 2230050; PTD 1740440 3/2/2023: I traveled to location and met with Adrienne McVey of ASRC Energy Services to witness the surface abandonment of the well. The well had been cutoff three and a half feet below tundra grade. All annuli had cured cement at surface. I used a hammer to verify cement integrity. Marker plate was of proper thickness, had the proper information bead welded onto it and did not extend beyond outermost string. I found no issues with this inspection and informed Adrienne she could weld the marker plate on. Attachments: Photos (4) 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.09 14:18:58 -08'00' 2023-0302_Surface_Abandon_Foggy_Island_Bay_State-1_am Page 2 of 3 Surface Abandonment - Foggy Island Bay State #1 (PTD 2230050) Photos by AOGCC Inspector A. McLeod 3/2/2023 2023-0302_Surface_Abandon_Foggy_Island_Bay_State-1_am Page 3 of 3 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Spence, Clinton Subject:RE: PDF IBC-CBL Foggy Island Date:Tuesday, February 21, 2023 10:00:00 AM Attachments:image001.png Clint, My interpretation of the CBL: Looks like you have good TOC in the 9-5/8” casing around 8380’ MD. Cement from around 1927’ to surface, I’m assuming that’s from the cement job pumped through the DV collar at 1908’ MD. Looks like some degree of cement, but less well bonded or lower compressive strength cement from the deeper DV collar at 2550’ up to around 2075’ or so. BP has approval to proceed with the P&A as planned in the approved PTD. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Spence, Clinton <cspence@asrcenergy.com> Sent: Tuesday, February 21, 2023 7:38 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: FW: PDF IBC-CBL Foggy Island Here is the log. I would like to give you a call later this morning to discuss a few aspects of the job. Thanks From: Juan Luis Lopez <JLopez240@slb.com> Sent: Monday, February 20, 2023 6:46 PM To: Spence, Clinton <cspence@asrcenergy.com> Cc: Arnoldo Perez <APerez96@slb.com> ⚠ CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Subject: PDF IBC-CBL Foggy Island Hello Clint, Please find attached the rush PDF of the IBC-CBL done in Foggy Island. Regards Juan Luis López Senior Field Engineer Reservoir Performance – North Gulf Coast Mob. +1 504 756 0225 SLB-Private 2023-0219_P&A_Hot-Tap_Foggy_Island_Bay_State-1_ae Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 2/19/2023 P. I. Supervisor FROM: Adam Earl SUBJECT: Reentry for P&A Petroleum Inspector Foggy Island Bay State #1 BP America Production Company PTD 2230050; PTD 1740440 2/10/2023: I traveled to Foggy Island Bay State #1 to witness hot tap operations for reentering the well. Clint Spence was the Company representative on location. The well had been deemed suspended and then abandoned in AOGCC records. BP America Production Company plans to re-enter the well and fully plug and abandon starting with hot tap operations to determine pressure on the well. The top marker plate and side flange entry were hot tapped – both were found at 0 psi. Attachments: Photos (2) 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.08 14:17:28 -08'00' 2023-0219_P&A_Hot-Tap_Foggy_Island_Bay_State-1_ae Page 2 of 2 Hot Tap Operations – Foggy Island Bay State #1 PTD 2230050; PTD 1740440 Photos by AOGCC Inspector A. Earl 2/19/2023 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Spence, Clinton Subject:RE: Update on Foggy Island Bay State #1 Date:Sunday, February 19, 2023 6:17:00 PM Attachments:image001.png Clint, BP has approval to proceed with placing the cement Plug #1 in steps 3.4.1 – 3.4.5 while waiting on the CBL results. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Spence, Clinton <cspence@asrcenergy.com> Sent: Sunday, February 19, 2023 10:57 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Cismoski, Doug <dcismoski@asrcenergy.com>; Dial, Amanda <ADial@asrcenergy.com>; Collin Simmons <csimmons31876@cudd.com> Subject: Update on Foggy Island Bay State #1 Bryan Update for work completed Saturday 2/18/23: Milled thru cement plugs. Just broke thru last plug and RIH to tag TD at report time. Plan forward: Tag bottom plug, circ bottoms up, roll hole to 9.2# brine and RU E-line for bond log. Clint Spence Simops Coordinator MHP / Prudhoe Bay ASRC Consulting & Environmental Services, LLC cspence@asrcenergy.com Cell: 907-330-7149 Harmony - 2556 Alternate: Clark Olsen 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Michael McAnulty Liability Manager BP America Production Company 317 Anaconda R. Butte, MT 59701 Re: Exploratory Field, Exploratory Pool, Foggy Island Bay State 1 BP America Production Company Permit to Drill Number: 223-005 Surface Location: 650' FEL, 700' FSL, Sec. 19, T11N, R17E, UM Bottomhole Location: 650' FEL, 700' FSL, Sec. 19, T11N, R17E, UM Dear Mr. McAnulty: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. Re-entry of this plugged and abandoned well necessitates changing the API Number to 50-029- 20146-90-00 (the rightmost four digits changed from 00-00 to 90-00). This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Brett W. Huber, Sr. Chair, Commissioner DATED this ___ day of February, 2023. Brett W. Huber. Sr. Digitally signed by Brett W. Huber. Sr. Date: 2023.02.01 14:24:57 -09'00' 1 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2.Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3.Address: 6.Proposed Depth: 12.Field/Pool(s): MD:TVD: 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8.DNR Approval Number: 13. Approximate Spud Date: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 15. Distance to Nearest Well Open Surface: x- y- Zone- to Same Pool: 16. Deviated wells: Kickoff depth: feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD Hydraulic Fracture planned? Yes No 20.Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Contact Email: Contact Phone: Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Commission Use Only See cover letter for other requirements. Perforation Depth MD (ft): Authorized Title: Authorized Signature: Production Liner Intermediate Effect. Depth MD (ft): Effect. Depth TVD (ft): Conductor/Structural LengthCasing Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) 18. Casing Program: Top - Setting Depth - BottomSpecifications Total Depth MD (ft): Total Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Authorized Name: ions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane,gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No See cover letter for other requirements. Permit Approval Date: API Number:to Drill er: Commission Use Only Contact Name: Contact Email: Contact Phone: Date: hereby certify that the foregoing is true and the procedure approved herein will not be ed from without prior written approval. ized Title: ized Signature: ized Name: tachments: Property Plat BOP SketchDrilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed ReportDrilling Fluid Program 20 AAC 25.050 requirements ulic Fracture planned?Yes No Perforation Depth TVD (ft):ation Depth MD (ft): Liner Production ntermediate Surface ductor/Structural TVDMDCementVolumeSizeLengthCasing Junk (measured):Effect. Depth TVD (ft):Effect. Depth MD (ft):Plugs (measured):Total Depth TVD (ft):l Depth MD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)Y (including stage data)MD TVDLength MD TVDCasing Weight Grade Couplinge Cement Quantity, c.f. or sackssing Program:Top - Setting Depth - BottomSpecifications viated wells:Kickoff depth:feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle:degrees Downhole:Surface: cation of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft):15. Distance to Nearest Well Open e: x- y-Zone-to Same Pool:GL / BF Elevation above MSL (ft): ress:6.Proposed Depth:12.Field/Pool(s): MD:TVD: ocation of Well (Governmental Section):7. Property Designation: e: Productive Horizon:8.DNR Approval Number:13. Approximate Spud Date: Depth:9.Acres in Property:14. Distance to Nearest Property: rator Name:5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. pe of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp1c. Specify if well is proposed for: Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Michael McAnulty January 16, 2023 By Samantha Carlisle at 8:02 am, Jan 17, 2023 BP America Production Company 317 Anaconda R. Butte, MT 59701 650' FEL, 700'FSL, Sec 19 T11N R17E UM Same Same 11,202 11,202 ADL 47506 42 original KB 16 Foggy Island Bay State #1 Wildcat February 01, 2023 N/A N/A 4672 psi 3,695 psi 11,202 11,202 0 0 43' 30" 43' 43' 159' 20" 42 bbl (Surface) 159' 159' 2500' 13-3/8" 309 bbl (Surface) 2500' 2500' 9765' 9-5/8" 88 bbls to 8121'&143 bbl to Surf 9765' 9765' 1365' 7" 31 bbls 9490'-10855' 9490'-10855' 9708'-10209'9708'-10209' MIchael Mc Anulty Liability Manager Clint Spence cspence@asrcenergy.com 907-223-6315 ✔✔ ✔ ✔ ✔✔ Reentry 3 BOP test to 4000 psi. Submit daily operations reports during P&A activity. Set at least 10,000 lbs on cement plugs to verify depth of hard cement, except for surface plug. Surface cement plug must be designed for permafrost per 20 AAC 25.112(e) Submit Cement log to AOGCC for approval before placing cement plugs. See additional requirements noted on procedure. Wellsite site clearance inspection w/ AOGCC in summer 2023 after snow melts, before Sept 30, 2023. 223-005 9407340 BJM 1/23/23 5958522 Re-entry SFD SFD DSR-1/23/23 264765 50-029-20146-90-00 SFD 1/31/2023JLC 2/1/2023 2/1/23 2/1/23Brett W. Huber. Sr.Digitally signed by Brett W. Huber. Sr. Date: 2023.02.01 14:25:49 -09'00' RBDMS JSB 020323 Foggy Island Bay State #1 Plug and Abandon Procedure API #: 50-029-20146-00 PTD: 174-044 October 21, 2022 Prepared for Thru Tubing Solutions and BP America Production Company Prepared by Doug Cismoski, P.E. and Clint Spence 3900 C Street, Suite 700 Anchorage, Alaska 99503 223-005 50-029-20146-90-00 SFD 1/25/2023 Foggy Island Bay State 1 North Slope, Alaska BP America Production Company 1 October 2022 18096-01 22-139 Rev. 1.0 1.0 General Plug & Abandonment Design Foggy Island Bay State #1 was drilled as an exploration test well in 1975 under Permit To Drill number 174-044. The production hole was tested and cored and indicated no economic production. The wellwas suspended in a “temporary abandonment” in April 1975. In 1982, Amoco requested the AOGCCre-classify the well from “suspended” to “abandoned”. A site visit was made in August 2022 by BP America, Thru Tubing Solutions and Cudd Pressure Control representatives to confirm wellhead size, associated flange sizes and height above ground level. The wellhead top flange was confirmed to be 13-5/8” and was stamped as 3000 psi working pressure. 2ULJLQDOPXGZHLJKWZDVSSJDW¶UHFRUGVVKRZSSJ0:%+3aSVL*DV JUDGLHQWWRVXUIDFHSVLIW\LHOGVD0$63RIaSVL 2.0 Objective Complete permanent plug and abandonment of the subject well, excavate and cut casings three feet below original tundra grade and weld permanent marker cap. 3.0 Procedure 3.1 Site Preparation (Expected Start in January 2023) 3.1.1 Building of ice pad and ice road to begin as soon as allowed from Endicott access road to work site. 3.1.2 Initial gravel site remediation to begin along with site leveling for upcoming well work. 3.1.3 Notify AOGCC Inspector hours in advance of plugging operations commencing. 3.1.4 Hot-Tap above the dry hole marker and verify zero pressure. Record and bleed any pressure. Monitor for 1 hour for potential pressure build up. 3.1.5 If possible, at this point, remove 2500’ of thermistor cable. Thermistor cable would appear to be cemented in surface plug but will confirm upon upper flange removal. 3.1.6 Install adapter flange and 11” BOPE with blind rams on well (See Figure 1 and Figure 2). 1RWHWKH %23(ZLOODOORZXVWROXEULFDWHWKHPLOODQG&,%3EHORZWKH%23(DQGDWHVWEDUULHU ZKHQZHEUHDNRIIWRFKDQJHRXW%+$ DTest BOP body and existing wellheadFRQQHFWLRQ against surface cement plug to 1500 psi OR20% over initial pressure found during hot-tap. E 3UHVVXUHWHVWEOLQGUDPVWRSVLDJDLQVWDWHVWSOXJVHWLQWKHVSRROEHORZWKH %23( 3.1.7 Move in and rig up flowback iron and tanks for upcoming coiled tubing work. 3.1.8 Install temporary scaffolding and shelter. Foggy Island Bay State 1 North Slope, Alaska BP America Production Company 2 October 2022 18096-01 22-139 Rev. 1.0 3.2 2-3/8” Coiled Tubing Work 3.2.1 MIRU 2-3/8” Service CTU. Rig up to flowback iron and install. BOPE. Function and pressure test BOPE to 4000 psi. 3.2.2 Drill out 50' surface plug with 8.5” PLOOFish thermistor cable if needed. 3.2.3 Wash and ream to second plug at 2,515'. Drill roughly 5' into the cement plug to capture the top diesel contaminated cement. 3.2.4 Continue to drill out the cement plug at 2,515'. 3.2.5 Wash and ream in hole to the cement plug at 5,357'. 3.2.6 Drill out the cement plug at 5,357'. 3.2.7 Circulate the well clean at as high a rate as possible while pulling out of the hole. Freeze protect from 2500 ft. MIT well to 1000 psi for 30 min. 3.2.8 At surface, stand back injector, raise T-bar. 3.3 Electric Line 3.3.1 Rig up electric line unit. 3.3.2 Log the well with the Schlumberger Isolation Scanner or a Segmented Bond Tool to confirm isolation of the hydrocarbon and aquifers. x NOTE: Details from the bond logs could potentially increase the P&A requirements to include perforating and cement squeeze. 3.3.3 Rig down electric line unit. 3.4 Coiled Tubing Cementing Work 3.4.1 CTU to pick up injector and cementing BHA. PT Lubricator to 4000 psi. 3.4.2 Plug #1 - Pump a 1,000' cement plug (75 bbls of 15.8 ppg Type G cement) from above existing cement plug (~9,327') to 8,327' in the 9.5/8" casing. 3.4.3 Pull out of holeGLVSODFLQJZLWKSSJEULQHDQG freeze protecting from 2500 ft. 3.4.4 Notify AOGCC Inspector hours in advance to witness PT and Tag. 3.4.5 Change out BHA and RIH tag TOC. 3.4.6 Plug #2 - Set a 9.5/8" cast iron bridge plug at 2,700'. PT to 1000 psi. 3.4.7 Plug #2 - Pump a 1,000' cement plug from 2,700' to 1,700' (75 bbls of 15.8 ppg Type G cement) in the 9.5/8" casing. Send logs to AOGCC and obtain approval to proceed with setting cement plugs. -bjm RIH to confirm top of cement plug reported at 9337' MD. -bjm Set at least 10,000 lbs on cement to confirm hard TOC. -bjm Foggy Island Bay State 1 North Slope, Alaska BP America Production Company 3 October 2022 18096-01 22-139 Rev. 1.0 3.4.8 Notify AOGCC Inspector hours in advance to witness PT and Tag of Plug #2. 3.4.9 Change out BHA. RIH and tag Plug #2 TOC. 3.4.10 Plug #3 - RIH and set a 9-5/8" cast iron bridge plug at 400'. 3.4.11 Plug #3 - Pump a 400' cement plug from 400' to surface in the 9.5/8" casing (30 bbls of 15.8 ppg Type G cement). 3.4.12 RDMO CTU and cementing equipment. 3.5 Post Cementing Excavation and Capping 3.5.1 Notify AOGCC Inspector hours in advance for opportunity to witness casing cut-off. 3.5.2 Excavate and cut-off casings and wellhead three feet below original tundra grade. Top job all annuli and casing as needed. 3.5.3 Photo document the well (at a minimum): x Immediately after cutting off the wellhead x Before and after the top job (if necessary) 3.5.4 Bead weld marker cap on outermost casing string (30” Conductor) to read as follows: x BP America Production Company x Foggy Island Bay State #1 x 174-044 x 50-029-20146-00 3.5.5 Take pictures of welded on marker plate with well identification information. 3.5.6 Backfill the excavated hole and mound the excavation with gravel or tundra organics to account for settling and to prevent accumulation of surface water. Photograph mound. 3.6 Variance Request A variance is requested for 20 AAC 25.112(c)(1)(E) and 20 AAC 25.112(c)(2). BP requests to use the existing cement plug placed from 9462’ – 9327’ as the base for the new plug rather than milling through the existing plug and reentering the perforated interval. The existing plug is 246’ above the top perforation, exceeding the requirement of no more than 50 ft stipulated by regulation when isolated from open hole below. A portion of the liner is also uncemented which requires the variance to 20 AAC 25.112(c)(2) to use the existing plug as the base for the new plug. Be prepared to fill up annuli with small diameter pipe to bring cement to surface as needed for surface cement plug. -bjm Set at least 10,000 lbs on plug to verify TOC depth. -bjm Cement plug must be designed to set in permafrost per 20 AAC 25.112(e) Site clearance inspection with AOGCC witness required after snow melts but before Sept 30, 2023. -bjm Do not leave hydrocarbon in the well between plugs. Place brine per 20 AAC 25.112(f). Foggy Island Bay State 1 North Slope, Alaska BP America Production Company 4 October 2022 18096-01 22-139 Rev. 1.0 Figure 1: Actual wellhead from August 2022 Site Visit Foggy Island Bay State 1 North Slope, Alaska BP America Production Company 5 October 2022 18096-01 22-139 Rev. 1.0 Figure 2: 11” DQGBOPE Diagram installed above existing wellhead 30" 50' Cement Plug 20" 50' Well Number 1 Field Exploratory Company API 50-029-20146 Bourgh North Slope Project Mgr Lease No.ADL0047506 State Alaska Address Spud Date 3-Feb-75 Well Type Wildcat Date Permit to Drill 174-044 Status P&A Phone 190 bbls Diesel Coordinates DD Latitude 70.287800 DMS Latitude 70° 17' 16.27" N Displacement DD longitude -147.906200 DMS Longitude 147° 54' 15.40" W As Drilled 650' from East line and 700' from South line. Section 19 Township 11-N Range 17-E Elevation 16' 2,500' of Casing Strings Depth (ft) Weight (ppf) Grade ID (in) Burst (psi) Collapse (psi) Capacity (bpf) Thermistor 1,730' Permafrost 30" 43' 157.53 B 1,908' Cable 20" 159' 94 & 133 H-40 & K-55 18.73" 1,530 520 0.3408 9.5/8" FO Collar Installed 13.3/8" 2,500' 68 K-55 12.42" 3,450 1,950 0.1499 9.5/8" 9,765' 40, 43.5 & 47 S-95 8.68" 6,820 3,320 0.0745 7" 9,490' - 10,855' 26 P-110 6.28" 9,950 6,230 0.0383 2,515' 51' Cement Plug 2,500' Hole Depth (ft) Sacks Ann Cap (bpf)est. Yield ETOC Pressure Test Test Date 2,566' 2,566' 13.3/8" Shoe 36" x 30" 43' 84 Surface 9.5/8" FO Collar 26" x 20" 159' 710 0.2681 1.03 Surface 17.1/2" x 13.3/8" 2,500' 2418 0.1237 1.03 Surface 12.1/4" x 9.5/8" 9,765' #1-500 #2-1035 0.0558 1.03 8,121' & Surface 8.1/2" x 7" 9,490' - 10,855' #1-200 #2-175 0.0226 1.03 10,200' ELM Dilled as an exploration test well. The 8.1/2" hole was tested by; 2 cores (61'), 6 logging runs, 60 sidewall cores and 5 DSTs - no economical production 05-Apr-1975 Mud record 9.2 ppg and 32 vis at 11.202' when running 7" liner. No available records of the logs on the AOGCC website. The well was suspended in a 'temporary abandonment' style in April 1975 for the potential to re-enter.40 #0' - 5,730' Records indicate that API Class G cement was utilized for the plugs.43.5 #5,730' - 8,240' In December 1982 Amoco made a request to AOGCC to re-classify the well from 'suspended' to 'abandoned'.47 #8,240' - 9,765' 4,618' Paleocene 5,357' 5,492' 7,058' Cretaceous 7,400' Sea Bee 8,121' ETOC 9,327'9,118' Turonian 7" Liner Top 9,490' 9,462' 9,437' Neocomian 9.5/8" Shoe at 9,765' 9,708'9,708' Lisburne 135' Cement Plug 135' Cement Plug 9.5/8" Casing Weights: Well & Project Detail Location details Casing Strings Casing Cement Well History AMOCO Production Company Current Well Diagram Well Foggy Island Bay State 11.2 ppg FIT at 9,770' 10,200' ELM 10,209' Top of Cement 10,746'10,808' Kayak 10,855' PBTD 7" Shoe 11,202' TD 50 8 T o t a l Pe r f o r a t i o n s Remediation Management Environmental liability management is our business. 30" 20" Class * 15.8 ppg Well Number 1 Field Exploratory Company 400' CIBP API 50-029-20146 Bourgh North Slope Project Mgr Lease No.ADL0047506 State Alaska Address Spud Date 3-Feb-75 Well Type Wildcat Date Permit to Drill 174-044 Status P&A Phone Coordinates DD Latitude 70.287800 DMS Latitude 70° 17' 16.27" N DD longitude -147.906200 DMS Longitude 147° 54' 15.40" W As Drilled 650' from East line and 700' from South line. Section 19 Township 11-N Range 17-E Elevation 16' Tag Casing Strings Depth (ft) Weight (ppf) Grade ID (in) Burst (psi) Collapse (psi) Capacity (bpf) 1,700' 1,730' Permafrost 30" 43' 157.53 B 1,908' 20" 159' 94 & 133 H-40 & K-55 18.73" 1,530 520 0.3408 9.5/8" FO Collar 13.3/8" 2,500' 68 K-55 12.42" 3,450 1,950 0.1499 Class *9.5/8" 9,765' 40, 43.5 & 47 S-95 8.68" 6,820 3,320 0.0745 15.8 ppg 7" 9,490' - 10,855' 26 P-110 6.28" 9,950 6,230 0.0383 2,500' Depth Gradient BHP PPG Original PPG 2,566' 13.3/8" Shoe 11,202 0.450 5041 8.7 9.5/8" FO Collar 11,202 0.465 5209 8.9 2,700' CIBP 11,202 0.478 5359 9.2 Top Bottom Length (ft) API Class Weight (ppg) Barrels Sacks Plug #1 8,327 9,327 1,000 G 15.8 75 387 ion.Plug #2 2,700 CIBP Mechanical Plug #3 1,700 2,700 1,000 G 15.8 75 387 Plug #4 400 CIBP Mechanical Plug #5 0 400 400 G 15.8 30 155 Plug #6 Plug #7 CEMENT: Class: G Weight: 15.8 ppg Yield: 1.08 w/ gas block 179 930 4,618' Paleocene 7,058' Cretaceous 7,400' Sea Bee 8,121' ETOC Tag 8,327' Class * 15.8 ppg 9,327'9,118' Turonian 7" Liner Top 9,490' 9,462' 9,437' Neocomian 9.5/8" Shoe at 9,765' 9,708'9,708' Lisburne AMOCO Production Company Proposed P&A Work Scope Well Foggy Island Bay State Well & Project Detail Location details Casing Strings Well Control Well Abandonment Work Scope 135' Cement Plug 11.2 ppg FIT at 9,770' 10,200' ELM 10,209' Top of Cement 10,746'10,808' Kayak 10,855' PBTD 7" Shoe 11,202' TD 50 8 T o t a l Pe r f o r a t i o n s Remediation Management Environmental liability management is our business. ❙ CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Davies, Stephen F (OGC) To:Carlisle, Samantha J (OGC) Cc:Guhl, Meredith D (OGC) Subject:FW: Foggy Island Bay State Well 1 Re-entry (223-005) Date:Friday, January 27, 2023 3:51:44 PM Sam, Could you please append the email below to the Permit to Drill application for Foggy Island Bay State 1 Re-entry? Thanks, Steve From: Spence, Clinton <cspence@asrcenergy.com> Sent: Friday, January 27, 2023 3:12 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Collin Simmons <csimmons31876@cudd.com>; Cismoski, Doug <dcismoski@asrcenergy.com> Subject: RE: Foggy Island Bay State Well 1 Re-entry (223-005) Steve, I have reviewed the well file and there is no mention of H2S. The original drilling had DST’s and flowback post acid job with no mention of H2S. Although it is always a potential ASRC sees the presence of H2S to be a very low probability. We will have 4 gas detectors at the well head, on the back deck of the coil unit and personnel will be wearing personal monitors while on location. We also will be keeping the well over balanced. ERM (who is managing the Foggy Island remediation project for bp) has a unified health safety plan that we will be following. The following are additional risks identified. Risk Management Plan Risk Description Consequence Potential Impact of Risk Risk Mitigation Plan Description Who, When Unable to Access Wellbore or Check Pressure Loss of Well Control and Ability to Operate Financial, Environmental, Personnel Hot Tap Cudd Well Control - Prior to Removing Base Flange Circulating out Diesel stored in wellbore Leak of diesel in circulating system Environmental Pressure Testing, Spill Response Plan Cudd, ASRC, SLB - Prior to Circulating Diesel Fishing Thermistor Cable in Wellbore Extend operations Financial Ensure fishing trips are well planned Cudd, TTS, ASRC, SLB Encountering H2S Risk to health Personnel Monitoring, keeping well overbalanced Cudd, TTS, ASRC, SLB Well Pressure Exceeds MAWP of Wellhead Assembly Wellhead Leak Financial, Personnel, Environmental Prep welbore with sufficient fluid prior to drilling plugs Cudd, TTS, ASRC, SLB Extensive Debris in Wellbore Extend Operations Financial Ensure Multiple Options to Clean out Well Cudd, TTS, ASRC, SLB P&A Delay Due to Inclimate Weather Extend Operations Financial Plan Operations Efficiently Around Weather Forcast Cudd, TTS, ASRC, SLB All records will have the new API number 50-029-20146-90-00 and well name will be listed as Foggy Island Bay State 1. This will used on the marker plate when completed. We just confirmed yesterday that we have been delayed ~ 10 days and will be starting on the 10th of February. Do I need to resend our application with the new start date and API number? Thank You Clint From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Thursday, January 26, 2023 9:38 AM To: Spence, Clinton <cspence@asrcenergy.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: RE: Foggy Island Bay State Well 1 Re-entry (223-005) Clint, Embarrassingly I must retract my previous correction. Looking into this further this morning, the well name listed in AOGCC’s database wrong (Foggy Island Bay Unit 1), but on Amoco’s Well Completion Report in AOGCC’s Well History File 174-044, the well name is listed as Foggy Island Bay State 1. Apologies for the confusion. I will correct AOGCC’s database. Cheers and Stay Safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Davies, Stephen F (OGC) Sent: Wednesday, January 25, 2023 4:39 PM To: cspence@asrcenergy.com Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: Foggy Island Bay State 1 (PTD 223-005) - Question Hi Clint, I’m reviewing ASRC’s Permit to Drill application to re-enter the Foggy Island Bay State 1 well, and I didn’t notice a potential hazards discussion within the application. When originally drilled in 1975, the well penetrated the Lisburne limestone and continued downward to TD in argillite basement rock. My questions are: Is there any record of H2S in this well? Is there any chance of encountering H2S while opening the well and conducting ASRC’s proposed plug and abandonment operations? If encountered, what are ASRC’s monitoring, safety, and mitigation plans? Has ASRC identified any other potential health or safety hazards associated with this well? If so, what monitoring, safety, and mitigation measures are planned? As a head-up, the API Number for this re-entered well must change. Since ASRC’s proposed operations involve re-entering a well that was previously classified as abandoned, AOGCC’s regulation 20 AAC 25.005(a) requires a new Permit to Drill application. For tracking purposes, AOGCC assigns each such application a unique Permit to Drill Number, and this particular application has been assigned the Permit to Drill Number of 223-005. AOGCC’s data management systems require a one-to- one relationship of each Permit to Drill Number with the corresponding API Number assigned to each well. Because of this, the existing API Number for this re-entry must be changed slightly from 50-029-20146-00-00 to 50-029-20146-90-00 in accordance with long-standing AOGCC practice. Please apply the Permit to Drill Number 223-005 and the API Number 50-029-20146-90-00 to all records associated with ASRC’s re-entry operations. Thanks and stay safe, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. ❙CAUTION: EXTERNAL SENDER This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Spence, Clinton To:McLellan, Bryan J (OGC) Subject:RE: Foggy Island Bay State #1 (PTD 174-044) annular cement Date:Tuesday, January 24, 2023 10:50:17 AM Attachments:image001.png Bryan, All annuli will be topped off with cement and pictures taken for documentation. I received word that the state has received and approved bp’s bond. Do you want me to resend the 10-401? Our bond number is 9407340. Thanks From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Monday, January 23, 2023 12:43 PM To: Spence, Clinton <cspence@asrcenergy.com> Subject: RE: Foggy Island Bay State #1 (PTD 174-044) annular cement Clint, ASRC should be prepared to fill any annuli with cement in case you don’t see it at surface when you cut off the wellhead. Have some small diameter, flush-joint pipe that you can run down into the annuli and circulate cement as needed. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Spence, Clinton <cspence@asrcenergy.com> Sent: Monday, January 23, 2023 10:26 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: Foggy Island Bay State #1 (PTD 174-044) annular cement Bryan I have this from the state, it was based off the state monthly drilling workover report. Does that answer your question? Not a lot of information Thanks CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Some people who received this message don't often get email from cspence@asrcenergy.com. Learn why this is important From:McLellan, Bryan J (OGC) To:McLellan, Bryan J (OGC) Subject:FW: Foggy Island Bay State Well 1 Re-entry (223-005) Date:Wednesday, February 1, 2023 10:44:50 AM From: Spence, Clinton <cspence@asrcenergy.com> Sent: Friday, January 27, 2023 3:12 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Collin Simmons <csimmons31876@cudd.com>; Cismoski, Doug <dcismoski@asrcenergy.com> Subject: RE: Foggy Island Bay State Well 1 Re-entry (223-005) Steve, I have reviewed the well file and there is no mention of H2S. The original drilling had DST’s and flowback post acid job with no mention of H2S. Although it is always a potential ASRC sees the presence of H2S to be a very low probability. We will have 4 gas detectors at the well head, on the back deck of the coil unit and personnel will be wearing personal monitors while on location. We also will be keeping the well over balanced. ERM (who is managing the Foggy Island remediation project for bp) has a unified health safety plan that we will be following. The following are additional risks identified. Risk Management Plan Risk Description Consequence Potential Impact of Risk Risk Mitigation Plan Description Who, When Unable to Access Wellbore or Check Pressure Loss of Well Control and Ability to Operate Financial, Environmental, Personnel Hot Tap Cudd Well Control - Prior to Removing Base Flange Circulating out Diesel stored in wellbore Leak of diesel in circulating system Environmental Pressure Testing, Spill Response Plan Cudd, ASRC, SLB - Prior to Circulating Diesel Fishing Thermistor Cable in Wellbore Extend operations Financial Ensure fishing trips are well planned Cudd, TTS, ASRC, SLB Encountering H2S Risk to health Personnel Monitoring, keeping well overbalanced Cudd, TTS, ASRC, SLB Well Pressure Exceeds MAWP of Wellhead Assembly Wellhead Leak Financial, Personnel, Environmental Prep welbore with sufficient fluid prior to drilling plugs Cudd, TTS, ASRC, SLB Extensive Debris in Wellbore Extend Operations Financial Ensure Multiple Options to Clean out Well Cudd, TTS, ASRC, SLB P&A Delay Due to Inclimate Weather Extend Operations Financial Plan Operations Efficiently Around Weather Forcast Cudd, TTS, ASRC, SLB All records will have the new API number 50-029-20146-90-00 and well name will be listed as Foggy Island Bay State 1. This will used on the marker plate when completed. We just confirmed yesterday that we have been delayed ~ 10 days and will be starting on the 10th of February. Do I need to resend our application with the new start date and API number? Thank You Clint From: Davies, Stephen F (OGC) Sent: Wednesday, January 25, 2023 4:39 PM To: cspence@asrcenergy.com Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Boyer, David L (OGC) <david.boyer2@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: Foggy Island Bay State 1 (PTD 223-005) - Question Hi Clint, I’m reviewing ASRC’s Permit to Drill application to re-enter the Foggy Island Bay State 1 well, and I didn’t notice a potential hazards discussion within the application. When originally drilled in 1975, the well penetrated the Lisburne limestone and continued downward to TD in argillite basement rock. My questions are: Is there any record of H2S in this well? Is there any chance of encountering H2S while opening the well and conducting ASRC’s proposed plug and abandonment operations? If encountered, what are ASRC’s monitoring, safety, and mitigation plans? Has ASRC identified any other potential health or safety hazards associated with this well? If so, what monitoring, safety, and mitigation measures are planned? Thanks and stay safe, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME:______________________________________ PTD:_____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD:__________________________POOL:____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in nogreater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. FOGGY ISLAND BAY STATE 1 223-005 EXPLORATORY EXPLORATORY Re-entry of this plugged and abandoned well necessitates changing the API Number to 50-029-20146-90-00 (the right- most four digits changed from 00-00 to 90-00). SFD 1/25/2023