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Home My WebLink About221-0041. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,323'N/A Casing Collapse Conductor N/A Surface 2,670psi Production 7,020psi Liner 8,100psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Operations Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 13-3/8" 7" 2,653' 9,022' Perforation Depth MD (ft): 2-3/8"2,454' MD N/A 7,700psi 5,380psi 8,160psi 2,653' 7,228' 7,329' 2,653' 9,022' 11,295' Length Size Proposed Pools: 115' 115' TVD Burst PRESENT WELL CONDITION SUMMARY 7,331' 11,283' 7,328' 1,634 N/A 115' 20" MILNE POINT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047433 & ADL0047434 221-004 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-20801-01-00 Hilcorp Alaska LLC KUPARUK RIVER OIL N/A C.O. 432E MILNE PT UNIT C-04A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 9.2# / L-80 / Buttress 8,911' 4/7/2023 7" BOT FHL Retrievable and 3-1/2" Camco TRSV 8,841 MD/ 7,069 TVD and 1,972 MD/ 1,849 TVD See Schematic See Schematic 3-1/2" 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior writt en approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY scott.pessetto@hilcorp.com 907-564-4373 Scott Pessetto Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.03.20 14:36:07 -08'00' David Haakinson (3533) 10-404 DSR-3/20/23MGR21MAR23SFD 3/30/2023JLC 5/5/2023 5/5/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.05 09:51:09 -08'00' RBDMS JSB 050823 EL Add Perf Well: MPU C-04A Date: 3/20/2022 Well Name:MPU C-04A API Number:50-029-20801-01-00 Current Status:Producer - Online Pad:C-Pad Estimated Start Date:4/07/2023 Rig:SL & EL Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Darci Horner Permit to Drill Number:221-004 First Call Engineer:Scott Pessetto (907) 564-4373 (O) (801) 822-2203 (M) Second Call Engineer:Brian Glasheen (907) 564-5277 (O) (907) 545-1144 AFE Number:Job Type:Perforate Current Bottom Hole Pressure: 2,357 psi @ 7,234’ TVD FL on 7/7/2021 | 6.3 PPGE MPSP:1,634 psi (0.1psi/ft gas gradient) Max Deviation:33° deg @ 9,025’ MD Min ID:1.995” 2-3/8” liner Brief Well Summary: Well C-04A is a Kuparuk producer that was sidetracked into a Northern fault black in 2021. The parent perforations were cemented during the pre-rig CTD work. Hilcorp would like to access the parent perforations to increase the oil rate from well MPC-04A. Objective: Perforate cemented MPC-04 parent perfs from 9,005’ – 9,025’ Notes Regarding the Well & Design Perforating inside 2-3/8” 4.7” L-80 Top of whipstock is 9,016’ ELMD. Perforations will penetrate whipstock partially. Procedure Slickline Procedure (No Sundry Required) 1. MIRU Slickline Unit. PT PCE to 250 psi Low / 2,500 psi High. 2. MU 20’ of 1.56’ Dummy Drift Gun and attempt to drift to perf depth @ 9,025’ MD. 3. RDMO Slickline. E-line Perforating Procedure (SUNDRY REQUIRED) 4. MIRU EL unit and PT PCE to 250psi Low / 2,500 psi High. 5. PU Perf Gun BHA and perforate the interval listed below with 20’ of 1.56” guns. a. Document changes in wellhead pressure and condition of guns as they return. 6. Perform log correlation pass. Contact OE or Geo to correlate to open hole log. 7. Contact Geologist and/or Ops Engineer to review depth and planned perforation depths prior to firing guns. a. Ops Engineer: Scott Pessetto scott.pessetto@hilcorp.com; (801) 822-2203 b. Geologist: Graham Emerson graham.emerson@hilcorp.com; (907) 793-0315 Formation Length (ft) Top (MD) Bottom (MD) Top (TVD) Bottom (TVD) Kuparuk C ±20’ ±9,005’ ±9,025’ ±7,213’ ±7,230’ Perforate cemented MPC-04 parent perfs from 9,005’ – 9,025’ EL Add Perf Well: MPU C-04A Date: 3/20/2022 8. RDMO EL unit. Attachments: 1. Schematic 2. Proposed schematic _____________________________________________________________________________________ Revised By: NLW 06/15/2021 SCHEMATIC Milne Point Unit Well: MPU C-04A Last Completed: 4/8/2021 PTD: 221-004 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk B / C 9,690’ 10,090’ 7,305’ 7,303’ 400’ 4/7/2021 Open Kuparuk C 10,320’ 10,640’ 7,286’ 7,278’ 320’ 4/7/2021 Open Kuparuk C 10,642’ 11,280’ 7,278’ 7,327’ 638’ 4/6/2021 Open TD =11,323’(MD) / TD =7,331’(TVD) 20” Orig.RKB Elev: 52’ (Nabors 27E) / GL Elev: 17’ 7” 11 13-3/8” 2 Min ID=1.995” @ 8,846’ PBTD =11,281’(MD) / PBTD =7,328’(TVD) 14Top of 2-3/8” 8840’ 1 3 4 5 6 7 8 9 10 13 15 Est. TOC 1,800’ Arctic Pack Est Primary TOC 8,070’ 12 2-3/8” Stage collar 2,076’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94# / B / N/A N/A Surface 115’ 13-3/8" Surface 72# / L-80 / Buttress 12.347” Surface 2,653’ 7" Production 29# / L-80 / Buttress 6.184” Surface 9,022’ 2-3/8” Liner 4.7# / L-80 / Hyd511 1.995” 8,840’ 11,294’ TUBING DETAIL 3-1/2” Tubing 9.2# / L-80 / Buttress 2.992” Surface 8,911’ JEWELRY DETAIL No Depth Item 1 1,872’ 3-1/2” Camco TRSV (2.813” ID)(Locked out 10/28/1999) GLM Detail: 1” x 3-1/2” KBUG w/ BK latches 2 2,294’STA#10:Dummy Valve 3 3,176’STA#9:Dummy Valve 4 4,028’STA#8:Dummy Valve 5 4,905’STA#7:Dummy Valve 6 5,660’STA#6:Dummy Valve 7 6,351’STA#5:Dummy Valve 8 6,952’STA#4:Dummy Valve 9 7,602’STA#3:Dummy Valve 10 8,197’STA#2: Port 24/64”, OGLV, set 4/2/22 11 8,767’STA#1:Dummy Valve 12 8,808’ BOT SBR w/ X profile (33.3’ length, 2.813” ID) 13 8,841’ 7” BOT FHL Retrievable Packer 14 8,878’ 3-1/2” Camco D Nipple (2.75” ID) 15 8,910’ BOT Hydrotip sub w/ WLEG (Btm @ 8,911’) OPEN HOLE / CEMENT DETAIL 30" Cemented to Surface with 500 sx Arctic Set II 17-1/2" 3200 sx Arctic Set II plus 750 sx Arctic Set I 8-1/2” 800 sx Class “G”, 200 bbls Arctic Pack & 300 sx of Arctic Set I 3-1/4” Uncemented Liner WELL DETAIL KOP @ 600’ Max Hole Angle = 98 deg. @ 10,211’ A Sidetrack @ 9022’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” x 7” 5M FMC NSCT w/3-1/2” FMC Tbg Hgr. CIW 3-1/2” H BPV Profile GENERAL WELL INFO API: 50-029-20801-01-00 Parent Drilled by Nabors 27E– 10/12/1982 Re-perfed and re-completed by Roll’n 4 - 7/12/1985 A Sidetrack Completed: 4/8/2021 _____________________________________________________________________________________ Revised By: TDF 3/20/2023 PROPOSED Milne Point Unit Well: MPU C-04A Last Completed: 4/8/2021 PTD: 221-004 TD =11,323’(MD) / TD =7,331’(TVD) 20” Orig.RKB Elev: 52’ (Nabors 27E) / GL Elev: 17’ 7” 11 13-3/8” 2 Min ID=1.995” @ 8,846’ PBTD =11,281’(MD) / PBTD =7,328’(TVD) 14Top of 2-3/8” 8840’ 1 3 4 5 6 7 8 9 10 13 15 Est. TOC 1,800’ Arctic Pack Est Primary TOC 8,070’ 12 2-3/8” Stage collar 2,076’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94# / B / N/A N/A Surface 115’ 13-3/8" Surface 72# / L-80 / Buttress 12.347” Surface 2,653’ 7" Production 29# / L-80 / Buttress 6.184” Surface 9,022’ 2-3/8” Liner 4.7# / L-80 / Hyd511 1.995” 8,840’ 11,294’ TUBING DETAIL 3-1/2” Tubing 9.2# / L-80 / Buttress 2.992” Surface 8,911’ JEWELRY DETAIL No Depth Item 1 1,872’ 3-1/2” Camco TRSV (2.813” ID)(Locked out 10/28/1999) GLM Detail: 1” x 3-1/2” KBUG w/ BK latches 2 2,294’STA#10:Dummy Valve 3 3,176’STA#9:Dummy Valve 4 4,028’STA#8:Dummy Valve 5 4,905’STA#7:Dummy Valve 6 5,660’STA#6:Dummy Valve 7 6,351’STA#5:Dummy Valve 8 6,952’STA#4:Dummy Valve 9 7,602’STA#3:Dummy Valve 10 8,197’STA#2: Port 24/64”, OGLV, set 4/2/22 11 8,767’STA#1:Dummy Valve 12 8,808’ BOT SBR w/ X profile (33.3’ length, 2.813” ID) 13 8,841’ 7” BOT FHL Retrievable Packer 14 8,878’ 3-1/2” Camco D Nipple (2.75” ID) 15 8,910’ BOT Hydrotip sub w/ WLEG (Btm @ 8,911’) OPEN HOLE / CEMENT DETAIL 30" Cemented to Surface with 500 sx Arctic Set II 17-1/2" 3200 sx Arctic Set II plus 750 sx Arctic Set I 8-1/2” 800 sx Class “G”, 200 bbls Arctic Pack & 300 sx of Arctic Set I 3-1/4” Uncemented Liner WELL DETAIL KOP @ 600’ Max Hole Angle = 98 deg. @ 10,211’ A Sidetrack @ 9022’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” x 7” 5M FMC NSCT w/3-1/2” FMC Tbg Hgr. CIW 3-1/2” H BPV Profile GENERAL WELL INFO API: 50-029-20801-01-00 Parent Drilled by Nabors 27E– 10/12/1982 Re-perfed and re-completed by Roll’n 4 - 7/12/1985 A Sidetrack Completed: 4/8/2021 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk C ±9,005’ ±9,025’ ±7,213’ ±7,230’ 20 Future Future Kuparuk B / C 9,690’ 10,090’ 7,305’ 7,303’ 400’ 4/7/2021 Open Kuparuk C 10,320’ 10,640’ 7,286’ 7,278’ 320’ 4/7/2021 Open Kuparuk C 10,642’ 11,280’ 7,278’ 7,327’ 638’ 4/6/2021 Open 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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer MPU C-04 (PTD# 221-004) Date:Friday, April 8, 2022 3:03:57 PM Attachments:image001.png image002.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Friday, April 8, 2022 12:14 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Producer MPU C-04 (PTD# 221-004) Mr. Regg, Producer MPU C-04 (PTD# 221-004) began to show signs of outer annulus repressurization and was initially manageable by bleeds. On 29 March, the well exceeded outer annulus MOASP (1080 psi). Subsequent wellhead repairs have been completed and competent barriers have been confirmed by a passing MIT-T and CMIT-TxIA to 2500psi. The well is now classified as OPERABLE. Please respond with any questions or concerns. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 From: Jerimiah Galloway Sent: Wednesday, March 30, 2022 7:44 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Producer MPU C-04 (PTD# 221-004) Mr. Regg, Producer MPU C-04 (PTD# 221-004) began to show signs of outer annulus repressurization and was initially manageable by bleeds. On 29 March, the well exceeded outer annulus MOASP (1080 psi). The well is now classified as UNDER EVALUATION and will be placed on a 28 day clock for evaluation and repair. Plan Forward 1. Load and set plug 2. Bleed WHPs to 0 psi 3. PPPOT-T/IC 4. C/O OGLV 5. ENG to evaluate further diagnostics as required. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received thismessage in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender'sphone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect 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:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Producer MPU C-04 (PTD# 221-004) Date:Wednesday, March 30, 2022 9:30:18 AM Attachments:image001.png image002.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Wednesday, March 30, 2022 7:44 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Producer MPU C-04 (PTD# 221-004) Mr. Regg, Producer MPU C-04 (PTD# 221-004) began to show signs of outer annulus repressurization and was initially manageable by bleeds. On 29 March, the well exceeded outer annulus MOASP (1080 psi). The well is now classified as UNDER EVALUATION and will be placed on a 28 day clock for evaluation and repair. Plan Forward 1. Load and set plug 2. Bleed WHPs to 0 psi 3. PPPOT-T/IC 4. C/O OGLV 5. ENG to evaluate further diagnostics as required. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received thismessage in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender'sphone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20801-01-00Well Name/No. MILNE PT UNIT C-04ACompletion Status1-OILCompletion Date4/8/2021Permit to Drill2210040Operator Hilcorp Alaska, LLCMD11323TVD7331Current Status1-OIL6/25/2021UICNoWell Log Information:DigitalMed/FrmtReceivedStart StopOH /CHCommentsLogMediaRunNoElectr DatasetNumberNameIntervalList of Logs Obtained:MWD / GR / RESNoNoYesMud Log Samples Directional SurveyREQUIRED INFORMATION(from Master Well Data/Logs)DATA INFORMATIONLog/DataTypeLogScaleDF4/26/20218650 11323 Electronic Data Set, Filename: MPU_C04A_GAMMA RES.las35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 2MD.cgm35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 2TVD.cgm35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 5MD.cgm35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 5TVD.cgm35044EDDigital DataDF4/26/2021 Electronic File: MPU-C04A_GAMMA RES.ASC35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 2MD.pdf35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 2TVD.pdf35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 5MD.pdf35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 5TVD.pdf35044EDDigital DataDF4/26/2021 Electronic File: MPC-04A_Definitive Surveys.pdf35044EDDigital DataDF4/26/2021 Electronic File: MPC-04A_Definitive Surveys.xlsx35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A_Survey Listing.txt35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A_Surveys.txt35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 2MD.tif35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 2TVD.tif35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 5MD.tif35044EDDigital DataDF4/26/2021 Electronic File: MPU_C-04A 5TVD.tif35044EDDigital Data0 0 2210040 MILNE PT UNIT C-04A LOG HEADERS35044LogLog Header ScansFriday, June 25, 2021AOGCCPage 1 of 4,MPU_C04A_GAMMA RES.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20801-01-00Well Name/No. MILNE PT UNIT C-04ACompletion Status1-OILCompletion Date4/8/2021Permit to Drill2210040Operator Hilcorp Alaska, LLCMD11323TVD7331Current Status1-OIL6/25/2021UICNo0 0 2210040 MILNE PT UNIT C-04A LOG HEADERS PB135045LogLog Header ScansDF4/26/20218649 9923 Electronic Data Set, Filename: MPU-C04APB1_ GAMMA RES_18Mar2021.las35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 2MD.cgm35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 2TVD.cgm35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 5MD.cgm35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 5TVD.cgm35045EDDigital DataDF4/26/2021 Electronic File: MPU-C04APB1_ GAMMA RES_18Mar2021.ASC35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 2MD.pdf35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 2TVD.pdf35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 5MD.pdf35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 5TVD.pdf35045EDDigital DataDF4/26/2021 Electronic File: MPC-04APB1_Definitive Surveys.pdf35045EDDigital DataDF4/26/2021 Electronic File: MPC-04APB1_Definitive Surveys.xlsx35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1_Survey Listing.txt35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1_Surveys.txt35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 2MD.tif35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 2TVD.tif35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 5MD.tif35045EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB1 5TVD.tif35045EDDigital DataDF4/26/20218649 11302 Electronic Data Set, Filename: MPU_C04APB2_ GAMMA RES_24Mar2021.las35046EDDigital DataDF4/26/2021 Electronic File: MPU C-04APB2 2MD.cgm35046EDDigital DataDF4/26/2021 Electronic File: MPU C-04APB2 2TVD.cgm35046EDDigital DataDF4/26/2021 Electronic File: MPU C-04APB2 5MD.cgm35046EDDigital DataDF4/26/2021 Electronic File: MPU C-04APB2 5TVD.cgm35046EDDigital DataFriday, June 25, 2021AOGCCPage 2 of 4MPU-C04APB1_ ,GAMMA RES_18Mar2021.lasMPU_C04APB2_ ,GAMMA RES_24Mar2021.las DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20801-01-00Well Name/No. MILNE PT UNIT C-04ACompletion Status1-OILCompletion Date4/8/2021Permit to Drill2210040Operator Hilcorp Alaska, LLCMD11323TVD7331Current Status1-OIL6/25/2021UICNoWell Cores/Samples Information:ReceivedStart Stop CommentsTotalBoxesSample SetNumberNameIntervalINFORMATION RECEIVEDCompletion ReportProduction Test InformationGeologic Markers/TopsY Y / NAYMud 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 HISTORYCompletion Date:4/8/2021DF4/26/2021 Electronic File: MPU-C04APB2_ GAMMA RES_24Mar2021.ASC35046EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB2 2MD.pdf35046EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB2 2TVD.pdf35046EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB2 5MD.pdf35046EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB2 5TVD.pdf35046EDDigital DataDF4/26/2021 Electronic File: MPC-04APB2_Definitive Surveys.pdf35046EDDigital DataDF4/26/2021 Electronic File: MPC-04APB2_Definitive Surveys.xlsx35046EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB2_Survey Listing.txt35046EDDigital DataDF4/26/2021 Electronic File: MPU_C-04APB2_Surveys.txt35046EDDigital DataDF4/26/2021 Electronic File: MPU C-04APB2 2MD.tif35046EDDigital DataDF4/26/2021 Electronic File: MPU C-04APB2 2TVD.tif35046EDDigital DataDF4/26/2021 Electronic File: MPU C-04APB2 5MD.tif35046EDDigital DataDF4/26/2021 Electronic File: MPU C-04APB2 5TVD.tif35046EDDigital Data0 0 2210040 MILNE PT UNIT C-04A LOG HEADERS PB235046LogLog Header ScansFriday, June 25, 2021AOGCCPage 3 of 4 DATA SUBMITTAL COMPLIANCE REPORTAPI No. 50-029-20801-01-00Well Name/No. MILNE PT UNIT C-04ACompletion Status1-OILCompletion Date4/8/2021Permit to Drill2210040Operator Hilcorp Alaska, LLCMD11323TVD7331Current Status1-OIL6/25/2021UICNoComments:Compliance Reviewed By:Date:Date CommentsDescriptionRelease Date:1/15/2021Friday, June 25, 2021AOGCCPage 4 of 4M. 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03&$3%3RVLWLRQDO8QFHUWDLQW\0RGHO /RJ1DPH&RPPHQW:HOOERUHLQ2SHQ+ROH03&$3%%+&RLO7UDN6WDQGDUG 03&$3%&RLO7UDN0:'! 03&$3%6WULQJ'LDPHWHU:HOOERUH3DJHRI 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 7LH2Q3RLQW 1 : 7RSRI:6 1 : ,QW$] 1 : ,QW$] 1 : )LUVW&OHDQ6XUYH\ 1 : 1 : 1 : 7LH2Q3RLQW 1 : .232SHQ+ROH6LGH7UDFN 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 :3DJHRI 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 : 1 :1$3URMHFWHGWR7'3DJHRI 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: 04/26/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU C-04A, MPU C-04APB1, MPU C-04APB2 (PTD 221-0004) FINAL LWD FORMATION EVALUATION LOGS (03/28/2021 to 04/01/2021) •Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) •Final Definitive Directional Survey SFTP Transfer - Data Folders: Please include current contact information if different from above. PTD: 2210040 E-Set: 35044 Received by the AOGCC 04/26/2021 04/27/2021 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: 04/26/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU C-04A, MPU C-04APB1, MPU C-04APB2 (PTD 221-0004) FINAL LWD FORMATION EVALUATION LOGS (03/28/2021 to 04/01/2021) •Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) •Final Definitive Directional Survey SFTP Transfer - Data Folders: Please include current contact information if different from above. PTD: 2210040 E-Set: 35045 Received by the AOGCC 04/26/2021 04/27/2021 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: 04/26/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU C-04A, MPU C-04APB1, MPU C-04APB2 (PTD 221-0004) FINAL LWD FORMATION EVALUATION LOGS (03/28/2021 to 04/01/2021) •Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) •Final Definitive Directional Survey SFTP Transfer - Data Folders: Please include current contact information if different from above. PTD: 2210040 E-Set: 35046 Received by the AOGCC 04/26/2021 04/27/2021 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11323'None Casing Collapse Conductor N/A Surface 2,670psi Intermediate 7,020psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Monty Myers Contact Name:Trevor Hyatt Drilling Manager Contact Email: Contact Phone: 777-8396 Date: 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 No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 2,454'2-3/8"8,840' - 11,294'7,067' - 7,330' 3-1/2" Perforation Depth MD (ft): trevor.hyatt@hilcorp.com BOT FHL Ret. Packer 8,808 MD/ 7,039 TVD Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: 4/5/2021 80' 20" 13-3/8" 7" 2,653' 9,022' Tubing Grade: 5,380psi 8,160psi 2,383' 7,228' 2,653' 9,022' Tubing MD (ft): None MPU C-04A 80' 80' 9.2# / L-80 TVD Burst 8,911' MD N/A Length Size 7331' 11281' 7329' C.O. 432D PRESENT WELL CONDITION SUMMARY 3,100 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 047434 & 047433 221-004 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 Milne Point Field / Kuparuk Oil Pool 50-029-20801-00-00 Hilcorp Alaska LLC None Perforation Depth TVD (ft): COMMISSION USE ONLY Authorized Name: Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. 4.6.2021 By Samantha Carlisle at 10:41 am, Apr 06, 2021 321-164 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.04.06 10:31:21 -08'00' Monty M Myers MGR06APR21 X DLB 04/06/2021 DSR-4/6/21 all changes included in the 10-407 Comm. 4/8/21 dts 4/7/2021 JLC 4/7/2021 RBDMS HEW 4/8/2021 _____________________________________________________________________________________ Revised By: JNL 4/5/2021 PROPOSED SCHEMATIC Milne Point Unit Well: MPU C-04A Last Completed: TBD PTD: 221-004 PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status TD = 11,323’(MD) / TD =7,331’(TVD) 20” Orig.RKB Elev: 52’ (Nabors 27E) / GL Elev: 17’ 7” 11 13-3/8” 2 Min ID= 2.75” @ 8,878’ PBTD =11,281’(MD) / PBTD =7,329’(TVD) 14Top of 2-3/8” 8840’ 1 3 4 5 6 7 8 9 10 13 15 Est. TOC 1,800’ Arctic Pack Est Primary TOC 8,070’ 12 2-3/8” Stage collar 2,076’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94# / Grade B PELP / N/A N/A Surface 80’ 13-3/8" Surface 72# / L-80 / Buttress 12.347” Surface 2,653’ 7" Production 29# / L-80 / Buttress 6.184” Surface 9,022’ 2-3/8” Liner 4.7# / L-80 / Hyd511 8,840’ 11,294’ TUBING DETAIL 3-1/2” Tubing 9.2# / L-80 / Buttress 2.992” Surface 8,911’ JEWELRY DETAIL No Depth Item 1 1,872’ 3-1/2” Camco TRSV (2.813” ID) GLM Detail: 1” x 3-1/2” KBUG w/ BK latches 22,294’STA#10:Dummy Valve 33,176’STA#9:Dummy Valve 44,028’STA#8:Dummy Valve 54,905’STA#7:Dummy Valve 65,660’STA#6:Dummy Valve 76,351’STA#5:Dummy Valve 86,952’STA#4:Dummy Valve 97,602’STA#3:Dummy Valve 10 8,197’STA#2:Dummy Valve 11 8,767’STA#1:Dummy Valve 12 8,808’ BOT SBR w/ X profile (33.3’ length, 2.813” ID) 13 8,841’ 7” BOT FHL Retrievable Packer 14 8,878’ 3-1/2” Camco D Nipple (2.75” ID) 15 8,910’ BOT Hydrotip sub w/ WLEG (Btm @ 8,911’) OPEN HOLE / CEMENT DETAIL 30" Cemented to Surface with 500 sx Arctic Set II 17-1/2" 3200 sx Arctic Set II plus 750 sx Arctic Set I 8-1/2” 800 sx Class “G”, 200 bbls Arctic Pack & 300 sx of Arctic Set I 3-1/4” Uncemented Liner WELL DETAIL KOP @ 600’ Max Hole Angle = 50 deg. @ 5,200’ A Sidetrack @ ~9020’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” x 7” 5M FMC NSCT w/3-1/2” FMC Tbg Hgr. CIW 3-1/2” H BPV Profile GENERAL WELL INFO API: 50-029-20801-01-00 Parent Drilled by Nabors 27E– 10/12/1982 Re-perfed and re-completed by Roll’n 4 - 7/12/1985 A Sidetrack Completed: TBD To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: April 5, 2021 Re: MPU C-04A Operation Update All previous work that has been completed on MPU C-04A with CDR2 is covered under the approved PTD (221-004). Updated Completion Plan for MPU C-04A (Producer): The planned slotted liner completion was made up and ran but did not make it to TD. The slotted liner completion would not pass ~9,140’ MD, because of wellbore stability issues in the build section. The stability issues in the build section have been seen throughout the well. The liner was pulled and laid down. A new plan was developed and is in the process of being executed. The following describes the new plan. A wellbore schematic of the current well and updated sidetrack is attached for reference. Rig Work: (Completed Work) 1. Run 2-3/8” L-80 solid liner with motor and mill on bottom a. Solid liner, motor and mill allowed liner to reach to within ~29’ of drilled TD. b. Liner was swapped to 2% KCl c. After releasing from liner, the well was swapped over to 10.1 ppg KWF. d. Liner running BHA was pulled out of hole and laid down. 2. Perform weekly test BOPE 250 psi low and 3,500 psi high a. Test against swab and master valves b. Open well and ensure zero pressure (Planned Work) 3. Make up 1.56” perforation string #1 and perforate lowest section of liner a. Run 640’ of perf guns with 1” CS Hydril work string and coil b. Perforate lowest section of liner that was planned to be slotted liner c. Lay down guns. 4. Make up 1.56” perforation string #2 and perforate upper section of liner a. Run 720’ of perf guns, with 1” CS Hydril work string and coil b. Perforate upper section of liner that was planned to be slotted liner c. Lay down guns. d. Freeze protect well from ~2500’ TVD e. RDMO Liner Program: x 2-3/8”, 4.4#, L-80 solid liner: ~8,840’ MD – 11,294’ MD x No Cement x The primary barrier for this operation: a minimum EMW of 11.8 ppg (overbalanced) x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Perforating: x Perforating plan is the same as the slotted liner plan. Perforating all footage that was originally planned to be slotted liner in the Kuparuk C sand. x 1.56”, 6 SPF, 60 deg phasing, spiral orientation x Total perf footage: 1,360’ MD x Perforation Zones: o 9,690’ to 10,090’ MD (400’) o 10,320’ to 11,280’ MD (960’) x The primary barrier for this operation: a minimum EMW of 10.1 ppg (overbalanced) x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 STATE OF ALASKA �- OIL AND GAS CONSERVATION COMMISSION Reviewed By: P. 1. Supry BOPE Test Report for: MILNE PT UNIT C -04A - Comm Contractor/Rig No.: Nabors CDR2AC - PTD#: 2210040 ' DATE: 3/27/2021 - Inspector Brian Bixby - Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: John Perl / Sloan Sunderlan Rig Rep: Chris Erdman / Cleve C Inspector Type Operation: DRILL Sundry No: Test Pressures: Inspection No: bopBDB210329073038 Rams: Annular: Valves: MASP: Type Test: WKLY 250/3500 - 250/3500. 250/3500, 2390 _ Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Upper Kelly — 0 P/F Lower Kelly Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank P_ — P System Pressure 3100 P Housekeeping: P__ Pit Level Indicators P —___ P - Pressure After Closure 2360 P PTD On Location P Flow Indicator P P 200 PSI Attained 17 P Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 43 - P Well Sign P H2S Gas Detector P P Blind Switch Covers: YES P Drl. Rig P MS Misc 0 NA Nitgn. Bottles (avg): 10(&,1950 P Hazard Sec. P ACC Misc _ __-0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly — 0 NA Lower Kelly _ 0 NA Ball Type 2 P_ Inside BOP 0 NA FSV Misc 0 NA BOP STACK: Quantity P/F Size P/F Stripper 1 - 2" P Annular Preventer 1 7 1/16" P #1 Rams 1 Blind/Shear - P #2 Rams 1 2" Pipe Slips P #3 Rams 1_ _ 2 3/8" Pipe Sli -P #4 Rams 1 2" Pipe Slip__ 'P #5 Rams 0 NA #6 Rams 0_ - _N_A Choke Ln. Valves 1 -2 1/6" _P - HCR Valves 2 2 1/6" P ' Kill Line Valves 4 " 2 1/6" P " Check Valve 0 NA BOP Misc 0 NA CHOKE MANIFOLD: Quantity P/F No. Valves 16 P - Manual Chokes 1 P - Hydraulic Chokes 1 P CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves I— - P Number of Failures: 0 ' Test Results Test Time 6 Remarks: Tested all the gas alarms and PVT's. Tested with Multi sized test joint, 2" and 2 3/8". GOOD TEST STATE OF ALASKA Reviewed By: -IEP— OIL AND GAS CONSERVATION COMMISSION P.I. Supry 111 '1 BOPE Test Report for: MILNE PT UNIT C-04 Comm Contractor/Rig No.: Nabors CDR2AC - PTD#: - DATE: -3/13/2021 Inspector Adam Earl Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: M. Igtanloc/ R. Burnett Rig Rep: J. Medina/ K. Cozby Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopAGE210317103919 Rams: Annular: Valves: MASP: Type Test: INIT - 321-014- 250/3500. 250/3500 - 250/3500- 1276 ' Related Insp No: FLOOR SAFTY VALVES: BOP STACK: TEST DATA CHOKE MANIFOLD: Quantity MISC. INSPECTIONS: Quantity Size MUD SYSTEM: Quantity ACCUMULATOR SYSTEM: Upper Kelly -0 _-NA' P/F Stripper Visual Alarm P_ Time/Pressure P/F Location Gen.: P Trip Tank _P = P System Pressure 3275 P - Housekeeping: P Pit Level Indicators P P • Pressure After Closure 2600 P PTD On Location P Flow Indicator P - P - 200 PSI Attained 12 P Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 37 P Well Sign P _ 112S Gas Detector P P Blind Switch Covers: All Stations P _ Drl. Rig P MS Mise 0 NA Nitgn. Bottles (avg): 10 (& 2125 ' P Hazard Sec. P _ #5 Rams 0 NA ACC Misc 0 NA Misc NA #6 Rams 0 NA (Valid for Coil Rigs Only) FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly -0 _-NA' Stripper _ 1 • 2" P_ No. Valves 16- FP Lower Kelly 0 NA • Annular Preventer 1 - 7 1/16" FP Manual Chokes 1 P . Ball Type 2 - P- #1 Rams 1 - Blind/shear P Hydraulic Chokes 1 P ' Inside BOP 0 - NA - #2 Rams 1 - 2" PS FP CH Misc 0 NA FSV Misc 0 NA #3 Rams 1 2 3/8" PS P #4 Rams 1 2" PS P #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves I - 2 1/16" P - Quantity P/F HCR Valves 2 _ 2 1/16" P Inside Reel Valves 1 P Kill Line Valves 4- 2 1/16" FP �- Check Valve 0 NA BOP Misc 0 NA Number of Failures: 4 Test Results Test Time 62.5 Remarks: Annular and upper 2" rams failed to hold on Initial test, R2 failed and was replaced, C9 failed and was replaced, long test with lots of troubleshooting. Several factors in play here, cold weather, Koomy oil, and hyd. Seals. — --�' e < ccs est MEMORANDUM M FROM Jim Regg P. I. Supervisor Adam Earl Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: 3/14/2021 SUBJECT: Initial BOPE Test MPU C -04A Hilcorp Alaska LLC PTD 2210040 Attachment to Inspection Report # bopAGE210317103919 3/11/2021: Showed up for the initial BOPE test on Nabors CDR2AC. The rig has been stacked for the past 11 months. First two tests went along fine. The third test was the Annular and both inside Kill and Choke Line Valves with a 2 -inch test joint. They installed the test joint in the BOP stack and pressured up. The bag was leaking by as we could see test fluid (water) clearly coming up through the element. The crew tried everything, decided to move on to test 4 and change out bag later. Bag looked brand new and it was. Test 4 was the Upper 2 -inch pipe rams. Same result as the bag — it leaked by the rams and up the stack like they weren't even closed. They pulled on the test joint to see if the rams were fully closed — it would not budge, but apparently not sealed enough to prevent test water from leaking past the rams. Troubleshooting went on for hours, including: - Pulled the test joint, look for damage, and found none so reran and checked the space -out again. - Open doors and pulled all rams to check proper placement and seals; all looked brand new and were the correct size. Reinstalled, tested and same result — leaking by. 3/12/2021: The crew decided to focus on the Accumulator unit. They checked the filter screens and for air entrained in the hydraulic oil. The fluid was ok but the level was low so they added a drum of hydraulic oil. They took the control line hoses off at the connections to the BOP stack components, starting at the top and worked down (Annular, Top Rams, etc.) and reconnected them together to circulate oil back to the accumulator tank to remove any air that might be entrained. Attempted to test again— same n—same failing result as before. Next, they decided to pull and replace all rams which had to be broug tin rom Deadhorse. I left location and returned to camp to catch a nap with instructions to call when they were ready to test. I returned later that evening and observed the same failing test results after the rams were replaced on the BOP stack. Nabors and Hilcorp reps consulted with Texas Oil Tools who recommended changing out the equalizer pins. The BOP stack was still cold to the core so heat was put on it and they said it would be a few hours before pins were ready to change. I again left the 2021-0313 BOP Nabors_CDR2AC MPU —C -04A ae.docx Page 1 of 2 — rig and told them to call me when they were ready to try testing again. There was some serious discussion about bringing in a replacement BOP stack. 3/1312021: 1 received a call at 5:00am letting me know that they were ready to test the BOP stack. I got to the rig and they were on Test # 5 — I checked the chart for tests 12 through 5 and the results appeared to be acceptable. After talking with the Hilcorp reps, they restarted so I could witness the entire test. Got going about 7:45am, worked through lots of leaks but the bag and rams held pressure. Mostly bleeder valves and Managed Pressure Drilling system valves were leaking today. I'm convinced the testing problems encountered were due to the stack being cold but am not 100 percent sure. I left the rig at 9:00pm. A very long, stressful test for the rig crews but they stuck with it. Lots of great personnel out there with a ton of experience. 2021-0313—BOP—Nabors - CDR2AC — MPU — C-04A—ae.docx Page 2 of 2 1 Guhl, Meredith D (CED) From:Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent:Friday, March 12, 2021 3:49 PM To:Rixse, Melvin G (CED) Cc:Sean Mclaughlin; Monty Myers Subject:Re: [EXTERNAL] New rig startup - BOPE 7 day test cycle Mel, We are working on a few more things to get the current BOP to test. If those do not work, we will look at changing out the BOP. Trevor Hyatt 907‐223‐3087 On Mar 12, 2021, at 3:11 PM, Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> wrote: Sean, I was told the inspectors were tag teaming this inspection because of delays. Are you currently changing out the stack? 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@alaska.gov). cc. Monty, Trevor From: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Monday, March 8, 2021 4:33 PM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Monty Myers <mmyers@hilcorp.com> Subject: RE: [EXTERNAL] New rig startup ‐ BOPE 7 day test cycle Hi Mel, Hilcorp understands and will comply. However, please consider the following. ‐ CDR2 is not a new rig, it has been operating very steady since 2008 ‐ The rig has took a pause this last year, no equipment modifications have been made ‐ The work scope being done is typical for this rig 2 ‐ The crews that are coming back are 100% experienced with CDR2 and CDR3 operations ‐ Nabors test procedures are robust and they are not starting from scratch ‐ Nabors stump tested the BOPE to ensure it was ready for operations. ‐ A coil drilling unit already has many more advantages than a Rotary rig ‐ closed circulation system, two annular devices, two pipe/slip rams, a tree with valves, and kicking off in zone means infinite kick tolerance (bullhead capability for well control). ‐ There is already a requirement for a 7 day function test, the incremental pressure function test doesn’t improve safety ‐ Time would be better spent on more productive activities like kick drills (which we already do) ‐ Historically the 7 day test cycle was reserved for rigs with performance issues or lack of performance data. This is not the case for CDR2. The decision also has some potentially serious operational impacts. It usually works out that the end of the drilling phase occurs in about 7 days. We may be testing BOPE with 2500’ of openhole that wants to come apart. Rather than calling TD and getting liner in the ground we could be testing BOPE. Operational issues that may have been avoided can significantly increase risk. Nobody wins when a well fails, the loss of production hurts us all. In the future, rig pauses may be more and more common. I think it would be good to have a conversation about the situation prior to making a judgement decision. Regards, sean From: Rixse, Melvin G (CED) [mailto:melvin.rixse@alaska.gov] Sent: Friday, March 5, 2021 3:43 PM To: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Monty Myers <mmyers@hilcorp.com>; Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com>; Monty Myers <mmyers@hilcorp.com> Subject: [EXTERNAL] New rig startup ‐ BOPE 7 day test cycle Monty, Trevor, Sean, As with all new rig startups in Alaska, AOGCC will require a 7 day test cycle for BOPE while CDR2 is drilling their first well. 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@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the 3 onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1 Guhl, Meredith D (CED) From:Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com> Sent:Monday, March 8, 2021 4:51 PM To:Rixse, Melvin G (CED); Trevor Hyatt Cc:Monty Myers; Regg, James B (CED) Subject:RE: [EXTERNAL] RE: New rig startup - BOPE 7 day test cycle Hi Mel, Can you define ongoing operations? I believe shut down and startups will be more and more common. Is any pause acceptable? CDR2 is coming back with same equipment, procedures, crew, and scope of work. CDR2 also has an extensive performance history. Would you be able to share AOGCC data that a drilling rig in this situation (a familiar rig with extensive north slope experience) is susceptible to BOPE failures? I’m particularly interested in what type of failures the AOGCC has observed. Perhaps that can be an area of focus and would be great to learn from the AOGCC’s experience. As stated in my previous email, Hilcorp understands the judgement and will comply. Regards, sean From: Rixse, Melvin G (CED) [mailto:melvin.rixse@alaska.gov] Sent: Monday, March 8, 2021 4:11 PM To: Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Cc: Sean Mclaughlin <Sean.Mclaughlin@hilcorp.com>; Monty Myers <mmyers@hilcorp.com>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: [EXTERNAL] RE: New rig startup ‐ BOPE 7 day test cycle Trevor, AOGCC has historically required new rigs, i.e. rigs that are not in previous ongoing operations, to perform a weekly witnessed BOPE test on the first well after initiating operations. This is based upon AOGCC observations that new drilling ops are susceptible to BOPE failures. In protection of the resource and the industry, please observe this requirement on MPU C‐04A. 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@alaska.gov). cc. Monty Myers, Sean McLaughlin, Jim Regg 2 Subject: New rig startup ‐ BOPE 7 day test cycle Monty, Trevor, Sean, As with all new rig startups in Alaska, AOGCC will require a 7 day test cycle for BOPE while CDR2 is drilling their first well. 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@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 Monty M Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk Oil Pool, MPU C-04A Hilcorp Alaska, LLC Permit to Drill Number: 221-004 Surface Location: 1344' FSL, 2494' FEL, Sec. 10, T13N, R10E, UM, AK Bottomhole Location: 1856' FNL, 359' FWL, Sec. 02, T13N, R10E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jeremy M. Price Chair DATED this ___ day of January, 2021. Jeremy M. Pric 15 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: 12148' TVD: 7420' 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): 52' 15. Distance to Nearest Well Open Surface: x-557963 y- 6029624 Zone-4 17' to Same Pool: 2833' 16. Deviated wells: Kickoff depth: 9020 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 100 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 3-1/4" 2-3/8" 4.4# L-80 TH511 3327' 8820' 7050' 12147' 7420' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): None TVD 115' 2383' 7541' 9005' - 9236' 7213' - 7416' 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: Sr Pet Eng Sr Pet Geo Sr Res Eng GL / BF Elevation above MSL (ft): Uncemented Solid / Slotted Liner 50-029-20801-01-00 See cover letter for other requirements. Perforation Depth MD (ft): 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Commission Use Only Perforation Depth TVD (ft): 7244' 3200 sx Arctic Set II, 750 sx AS 500 sx Arctic Set II 115' 2653' 9378' Authorized Signature: 800 sx 'G', 200 Bbls Arctic Pack, 300 sx Arctic Set I Production Liner Intermediate 9378'7" 13-3/8"Surface Conductor/Structural 20"80' 2653' 9400'7561' LengthCasing 9040', 9155', 9175' Total Depth MD (ft): Total Depth TVD (ft): Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) Effect. Depth TVD (ft): 9040' Effect. Depth MD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 2390 728' FSL, 825' FEL, Sec. 03, T13N, R10E, UM, AK 1856' FNL, 359' FWL, Sec. 02, T13N, R10E, UM, AK 84-123 5120 5140' MPU C-04A Milne Point Unit Kuparuk Oil Pool 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 Hilcorp Alaska, LLC 1344' FSL, 2494' FEL, Sec. 10, T13N, R10E, UM, AK ADL 047434 & 047433 022224484 3/1/2020 Authorized Name: Monty Myers Authorized Title: Drilling Manager Trevor Hyatt trevor.hyatt@hilcorp.com 18. Casing Program: Top - Setting Depth - BottomSpecifications 3100 Form 10-401 Revised 3/2020 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 1.11.2021 By Samantha Carlisle at 3:12 pm, Jan 11, 2021 2021 Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2021.01.11 12:34:44 -09'00' Monty M Myers BOPE test to 3500 psi. MGR 12 Alternate plug placement approved per 20 AAC 25.112(i) SFD 1/12/2021 221-004 DSR-1/12/21JAN202112JAN2021 1/15/21 1/15/2021 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: January 8, 2021 Re: MPU C-04A Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack lateral from well MPU C-04 with the Nabors CDR2 Coiled Tubing Drilling rig on or around March 2021. Proposed plan for MPU C-04A Producer: Prior to drilling activities, a High Expansion Wedge will be set pre-rig with E-line in the 7" casing. Service Coil will then squeeze cement into the perforations and around the HEW. This will isolate and abandon the parent Kuparuk C perforations (see C-04 Sundry request). A ~3,126’ MD coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. A single string window exit + 10’ of rathole will be milled. The well will kick off in the Kuparuk C, build through Kuparuk B and back up to Kuparuk C to continue to TD. This lateral will access a separate fault block to the north of the parent. The proposed sidetrack will be completed with a 2-3/8” L-80 solid/slotted liner to TD. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Rig Work (scheduled to begin March 2021): 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP of 2,390 psi) a. Test against swab and master valves (No TWC) b. Load pits with drilling fluid c. Open well and ensure zero pressure 2. Mill 2.74” single string window (out of 7”) plus 10’ of rathole. a. Top of planned window 9,020’ MD. b. Mill window with a 1.0° fixed bend motor c. MPD or pressure deployment is not required for the window milling runs d. Parent well pressure to be confirmed with pre-rig SBHPS 3. Drill CTD Sidetrack – single lateral a. 2-3/8” BHA with GR/RES b. Drill with bicenter bit (3-1/4”) c. 30° DLS build section – 267’ MD d. 12° DLS lateral section – 2,872’ MD e. Planned TD 12,147’ MD f. Drill with a constant bottom hole pressure for entire sidetrack g. Pressure deployment will be required h. After TD and on the last trip out of hole lay in completion/kill weight fluid in preparation for liner run i. No flow test prior to laying down drilling BHA 4. Run 2-3/8” L-80 solid and slotted liner a. Have safety joint with TIW valve ready to be picked up while running slotted liner b. Solid liner to 300’ past fault and then slotted to TD c. Liner may be run in two sections if weight transfer or hole conditions is poor d. After releasing from the liner swap the well over to 2% KCl e. Freeze protect well from ~2200’ f. RDMO 24 hour notice to AOGCC to witness. Post-Rig Work: 1. V: Valve & tree work 2. S: SBHPS, set LTP, Set live GLVs. 3. T: Portable test separator flowback. Managed Pressure Drilling: The history of CTD at KRU in the Kuparuk reservoir, has demonstrated the benefits of a managed pressure drilling technique. Due to uncertainties about the bottom hole pressures and to aid in wellbore stability, managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using drilling fluid weight in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure is located between the well control choke manifold and the mud pits and will be independent of the well control choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing the dual set of BOP pipe/slips, pipe/slip rams (see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected for this well: MPD Pressure at the MPU C-04A Planned Window (9,020’ MD - 7,225’ TVD) Pumps On Pumps Off A Target BHP at Window (ppg)4,433 psi 4,433 psi 11.8 B Annular friction - ECD (psi/ft)812 psi 0 psi 0.09 C Mud Hydrostatic (ppg)3,231 psi 3,231 psi 8.6 B+C Mud + ECD Combined 4,043 psi 3,231 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 390 psi 1,202 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The reservoir pressure is expected to be 3,100 psi at 7100’ TVDSS (8.4 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,390 psi. Mud Program: x Drilling: Minimum mud weight of 8.6 ppg KCL with Geovis for drilling. This weight is overbalanced to expected pore pressure. Managed pressure can also be used to maintain overbalance if necessary. x Completion: 11.8-11.9 ppg NaBr to be used for liner deployment (if losses are encountered a lower mud weight above pore pressure will be utilized) x Heavy completion/kill weight fluid will be stored on location. The tankage will contain 1.5 wellbore volumes of this fluid for wellbore stability while running liner and to exceed the maximum possible BHP that could be encountered while drilling and running liner. Disposal: x All cuttings & mud generated during drilling operations will be hauled to the Milne Point “B” pad G&I facility. Hole Size: x 3-1/4” hole for entirety of the drilled lateral. Liner Program: x 2-3/8”, 4.4#, L-80 solid liner: 8,820’ MD – 10,125’ MD x 2-3/8”, 4.4#, L-80 slotted liner: 10,125’ MD – 12,147’ MD x No Cement: A liner top packer will be run post rig to facilitate injection into the new fault block. x The primary barrier for this operation: a minimum EMW of 8.6 ppg (overbalanced) x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: x BOP diagram is attached. MPD and pressure deployment is planned. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. x The annular preventer will be tested to 250 psi and 3,500 psi. Directional: x See attached directional plan. Maximum planned hole angle is 100°, inclination at kick off point is 30°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 5,140’ & Distance to nearest well within pool – 2833’ Logging: x MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. x Real time bore pressure to aid in MPD and ECD management. Perforating: x No perforating, slotted liner. Anti-Collision Failures: x No failures to existing wells. C-47 wp24 fails, but is only a plan and if drilled will not be before C-04A. Hazards: x MPU C-pad is not considered a high H2S pad. The highest recorded H2S well on the pad was from MPU C-14 (19.8ppm) in 2009. The H2S hazard while drilling MPU C-04A is considered low. x Overall Lost circulation risk is considered medium. x Fault crossing planned at 9,825’ from Kup B/C to Kup B sand. There has been no recent injection in the area so pressure is not expected to be elevated above what is predicted for the Kup B and C formations. x Wellbore stability in the Kup B. This risk will be managed with managed pressure drilling and holding constant bottom hole pressure. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka 907-223-3087 _____________________________________________________________________________________ Revised By: TDF 12/2/2020 SCHEMATIC Milne Point Unit Well: MPU C-04 Last Completed: 7/12/1985 PTD: 182-126 TD =9,400’ (MD) / TD =7,561’ (TVD) 20” Orig.RKB Elev: 52’ (Nabors 27E) / GL Elev: 17’ 7” 11 13-3/8” 2 Min ID= 2.75” @ 8,878’ PBTD = 9,290’ (MD) / PBTD =7,464’(TVD) 14 1 KUP C-1 3 4 5 6 7 8 9 10 13 15 Est. TOC 1,800’ 9,040’ EZSV Retainer Arctic Pack Fill Tagged @ 9,013’ 9/13/16 Est Primary TOC 8,070’ 12 9,155’ EZSV Retainer 9,175’ EZSV Retainer Stage collar 2,076’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94# / Grade B PELP / N/A N/A Surface 80’ 13-3/8" Surface 72# / L-80 / Buttress 12.347” Surface 2,653’ 7" Production 29# / L-80 / Buttress 6.184” Surface 9,378’ TUBING DETAIL 3-1/2” Tubing 9.2# / L-80 / Buttress 2.992” Surface 8,911’ JEWELRY DETAIL No Depth Item 1 1,872’ 3-1/2” Camco TRSV (2.813” ID) GLM Detail: 1” x 3-1/2” KBUG w/ BK latches 22,294’STA#10: Port= 12, Dev= 38, Vlv= Dome, TVD= 2,102’, 1336 TRO, 10/15/2013 33,176’STA#9: Port= 12, Dev= 41, Vlv= Dome, TVD= 2,784’, 1303 TRO, 10/15/2013 44,028’STA#8: Port= 12, Dev= 46, Vlv= Dome, TVD= 3,398’, 1272 TRO, 10/15/2013 54,905’STA#7: Port= 12, Dev= 48, Vlv= Dome, TVD= 4,001’, 1242 TRO, 10/15/2013 65,660’STA#6: Port= 12, Dev= 45, Vlv= Dome, TVD= 4,509’, 1213 TRO, 10/15/2013 76,351’STA#5: Port= 16, Dev= 39, Vlv= S/O, TVD= 5,013’, 10/15/2013 86,952’STA#4: Port= 0, Dev= 37, Vlv= Dmy, TVD= 5,491’, 10/15/2013 97,602’STA#3: Port= 0, Dev= 35 Vlv= Dmy, TVD= 6,018’, 5/21/2006 10 8,197’STA#2: Port= 0, Dev= 32, Vlv= Dmy, TVD= 6,513’, 8/21/2004 11 8,767’STA#1: Port= 0, Dev= 29, Vlv= Dmy, TVD= 7,004’, 8/21/2004 12 8,808’ BOT SBR w/ X profile (33.3’ length, 2.813” ID) 13 8,841’ 7” BOT FHL Retrievable Packer 14 8,878’ 3-1/2” Camco D Nipple (2.75” ID) 15 8,910’ BOT Hydrotip sub w/ WLEG (Btm @ 8,911’) PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD)Btm (TVD)FT SPF Date Status KUP 9,005’ 9,024’ 7,213’ 7,229’ 19 12 10/11/82 Open KUP 9,052’ 9,058’ 7,254’ 7,259’ 6 12 10/5/82 Squeezed KUP 9,080’ 9,110’ 7,279’ 7,305’ 30 12 10/5/82 Squeezed KUP 9,125’ 9,146’ 7,318’ 7,337’ 21 12 10/5/82 Squeezed KUP 9,182’ 9,236’ 7,369’ 7,416’ 54 12 10/2/82 Squeezed OPEN HOLE / CEMENT DETAIL 20" Cemented to Surface with 500 sx Arctic Set II in 30” Hole 13-3/8" 3200 sx Arctic Set II plus 750 sx Arctic Set I in 17-1/2” Hole 7” 800 sx Class “G”, 200 bbls Arctic Pack & 300 sx of Arctic Set I in a 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 50 deg. @ 5,200’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” x 7” 5M FMC NSCT w/3-1/2” FMC Tbg Hgr. CIW 3-1/2” H BPV Profile GENERAL WELL INFO API: 50-029-20801-00-00 Drilled and completed by Nabors 27E– 10/12/1982 Attempted Recompletion by Roll’n 4 – 6/24/85 Re-perfed and re-completed by Roll’n 4 - 7/12/1985 _____________________________________________________________________________________ Revised By: TDF 1/7/2021 PROPOSED Milne Point Unit Well: MPU C-04 Last Completed: TBD PTD: 182-126 TD =9,400’ (MD) / TD =7,561’ (TVD) 20” Orig.RKB Elev: 52’ (Nabors 27E) / GL Elev: 17’ 7” 11 13-3/8” 2 16 Min ID= 2.75” @ 8,878’ PBTD =9020’ (MD) / PBTD =7,226’(TVD) 14 1 KUP C-1 3 4 5 6 7 8 9 10 13 15 Est. TOC 1,800’ 9,040’ EZSV Retainer Arctic Pack Fill Tagged @ 9,013’ 9/13/16 Est Primary TOC 8,070’ 12 9,155’ EZSV Retainer 9,175’ EZSV Retainer Stage collar 2,076’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94# / Grade B PELP / N/A N/A Surface 80’ 13-3/8" Surface 72# / L-80 / Buttress 12.347” Surface 2,653’ 7" Production 29# / L-80 / Buttress 6.184” Surface 9,378’ TUBING DETAIL 3-1/2” Tubing 9.2# / L-80 / Buttress 2.992” Surface 8,911’ JEWELRY DETAIL No Depth Item 1 1,872’ 3-1/2” Camco TRSV (2.813” ID) GLM Detail: 1” x 3-1/2” KBUG w/ BK latches 22,294’STA#10: Dummy Valve 33,176’STA#9:Dummy Valve 44,028’STA#8:Dummy Valve 54,905’STA#7:Dummy Valve 65,660’STA#6:Dummy Valve 76,351’STA#5:Dummy Valve 86,952’STA#4:Dummy Valve 97,602’STA#3:Dummy Valve 10 8,197’STA#2:Dummy Valve 11 8,767’STA#1:Dummy Valve 12 8,808’ BOT SBR w/ X profile (33.3’ length, 2.813” ID) 13 8,841’ 7” BOT FHL Retrievable Packer 14 8,878’ 3-1/2” Camco D Nipple (2.75” ID) 15 8,910’ BOT Hydrotip sub w/ WLEG (Btm @ 8,911’) 16 ±9,020’Whipstock PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD)Btm (TVD)FT SPF Date Status KUP 9,005’ 9,024’ 7,213’ 7,229’ 19 12 10/11/82 Squeezed KUP 9,005’ 9,024’ 7,213’ 7,229’ 19 12 Future Re-squeeze KUP 9,052’ 9,058’ 7,254’ 7,259’ 6 12 10/5/82 Squeezed KUP 9,080’ 9,110’ 7,279’ 7,305’ 30 12 10/5/82 Squeezed KUP 9,125’ 9,146’ 7,318’ 7,337’ 21 12 10/5/82 Squeezed KUP 9,182’ 9,236’ 7,369’ 7,416’ 54 12 10/2/82 Squeezed OPEN HOLE / CEMENT DETAIL 20" Cemented to Surface with 500 sx Arctic Set II in 30” Hole 13-3/8" 3200 sx Arctic Set II plus 750 sx Arctic Set I in 17-1/2” Hole 7” 800 sx Class “G”, 200 bbls Arctic Pack & 300 sx of Arctic Set I in a 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ Max Hole Angle = 50 deg. @ 5,200’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” x 7” 5M FMC NSCT w/3-1/2” FMC Tbg Hgr. CIW 3-1/2” H BPV Profile GENERAL WELL INFO API: 50-029-20801-00-00 Drilled and completed by Nabors 27E– 10/12/1982 Attempted Recompletion by Roll’n 4 – 6/24/85 Re-perfed and re-completed by Roll’n 4 - 7/12/1985 _____________________________________________________________________________________ Revised By: JNL 1/8/2021 PROPOSED SCHEMATIC Milne Point Unit Well: MPU C-04A Last Completed: TBD PTD: TBD 2-3/8” SOLID Liner 2-3/8” SLOTTED Liner Jts Top (MD) Btm (MD) Top (TVD Btm (Tvd) Jts Top (MD) Btm (MD) Top (TVD) Btm (TVD) TD = 12,148’(MD) / TD =7,420’(TVD) 20” Orig.RKB Elev: 52’ (Nabors 27E) / GL Elev: 17’ 7” 11 13-3/8” 2 Min ID= 2.75” @ 8,878’ PBTD =12,148’(MD) / PBTD =7,420’(TVD) 14Top of 2-3/8” ~8820’ 1 3 4 5 6 7 8 9 10 13 15 Est. TOC 1,800’ Arctic Pack Est Primary TOC 8,070’ 12 XO solid to slotted ~10125’ 2-3/8” Stage collar 2,076’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 94# / Grade B PELP / N/A N/A Surface 80’ 13-3/8" Surface 72# / L-80 / Buttress 12.347” Surface 2,653’ 7" Production 29# / L-80 / Buttress 6.184” Surface ~9,020’ 2-3/8” Liner 4.7# / L-80 / Hyd625 8,820’ 12,147’ TUBING DETAIL 3-1/2” Tubing 9.2# / L-80 / Buttress 2.992” Surface 8,911’ JEWELRY DETAIL No Depth Item 1 1,872’ 3-1/2” Camco TRSV (2.813” ID) GLM Detail: 1” x 3-1/2” KBUG w/ BK latches 22,294’STA#10:Dummy Valve 33,176’STA#9:Dummy Valve 44,028’STA#8:Dummy Valve 54,905’STA#7:Dummy Valve 65,660’STA#6:Dummy Valve 76,351’STA#5:Dummy Valve 86,952’STA#4:Dummy Valve 97,602’STA#3:Dummy Valve 10 8,197’STA#2:Dummy Valve 11 8,767’STA#1:Dummy Valve 12 8,808’ BOT SBR w/ X profile (33.3’ length, 2.813” ID) 13 8,841’ 7” BOT FHL Retrievable Packer 14 8,878’ 3-1/2” Camco D Nipple (2.75” ID) 15 8,910’ BOT Hydrotip sub w/ WLEG (Btm @ 8,911’) OPEN HOLE / CEMENT DETAIL 20" Cemented to Surface with 500 sx Arctic Set II in 30” Hole 13-3/8" 3200 sx Arctic Set II plus 750 sx Arctic Set I in 17-1/2” Hole 7” 800 sx Class “G”, 200 bbls Arctic Pack & 300 sx of Arctic Set I in a 8-1/2” Hole 3-1/4” Uncemented Solid / Slotted Liner WELL DETAIL KOP @ 600’ Max Hole Angle = 50 deg. @ 5,200’ A Sidetrack @ ~9020’ TREE & WELLHEAD Tree 3-1/8” 5M FMC Wellhead 11” x 7” 5M FMC NSCT w/3-1/2” FMC Tbg Hgr. CIW 3-1/2” H BPV Profile GENERAL WELL INFO API: 50-029-20801-01-00 Parent Drilled by Nabors 27E– 10/12/1982 Re-perfed and re-completed by Roll’n 4 - 7/12/1985 A Sidetrack Completed: TBD TOWS 9020 7" shoe 9378' !" #$$ " " 5200540056005800600062006400660068007000720074007600780080008200True Vertical Depth (400 usft/in)4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 8200 8400 8600Vertical Section at 21.10° (400 usft/in)MPC-04L1 wp03 tgt01MPC-04L1 wp03 tgt02MPC-04L1 wp03 tgt03MPC-04L1 wp03 tgt04MPC-04L1 wp03 tgt05MPC-04L1 wp03 tgt06MPC-04L1 wp03 tgt07MPC-04L1 wp03 tgt0890009400MPC-042 3/8" x 3 1/4"90009 5 00 100001050011000115001200012148 MPU C-04A wp06KOP : Start Dir 9º/100' : 9022' MD, 7227.70'TVD : 15° LT TFStart Dir 30º/100' : 9042' MD, 7245.23'TVDStart Dir 12º/100' : 9271.90' MD, 7343.26'TVDTotal Depth : 12147.70' MD, 7420.42' TVDHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: MPC-04Ground Level:0.00+N/-S+E/-WNorthingEastingLatittudeLongitude0.000.00 6029624.270 557963.420 70° 29' 29.598 N149° 31' 34.083 WSURVEY PROGRAMDate: 2020-12-07T00:00:00 Validated: Yes Version: Depth FromDepth ToSurvey/PlanTool100.00 9022.00 1 : Sperry-Sun BOSS gyro multi (MPC-04) 3_Gyro-SR-GMS9022.00 9150.00 MPU C-04A wp06 (Plan: MPU C-04A) 3_MWD_Interp Azi+Sag9150.00 12147.70 MPU C-04A wp06 (Plan: MPU C-04A) 3_MWD+IFR2+MS+SagREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well MPC-04, True NorthVertical (TVD) Reference:9 : 04 9/7/1982 00:00 @ 52.00usft (generic drilling rigMeasured Depth Reference:9 : 04 9/7/1982 00:00 @ 52.00usft (generic drilling rigCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt C PadWell:MPC-04Wellbore:Plan: MPU C-04ADesign:MPU C-04A wp06Milne PointM Pt C PadMPC-04Plan: MPU C-04AMPU C-04A wp066.828CASING DETAILSTVD TVDSS MD Size Name7420.42 7368.42 12147.70 2-3/8 2 3/8" x 3 1/4"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 9022.00 27.90 31.65 7227.70 4669.56 1664.52 0.00 0.00 4955.70 KOP : Start Dir 9º/100' : 9022' MD, 7227.70'TVD : 15° LT TF2 9042.00 29.64 30.71 7245.23 4677.79 1669.50 9.00 -15.00 4965.17 Start Dir 30º/100' : 9042' MD, 7245.23'TVD3 9271.90 97.00 11.95 7343.26 4860.96 1729.60 30.00 -20.00 5157.69 Start Dir 12º/100' : 9271.90' MD, 7343.26'TVD4 9471.90 99.64 347.84 7313.89 5057.32 1729.38 12.00 -82.00 5340.805 9971.90 90.54 47.47 7265.14 5509.33 1875.24 12.00 95.00 5815.026 10321.90 86.39 5.65 7274.97 5815.26 2028.28 12.00 -96.00 6155.547 10796.90 83.84 62.82 7319.11 6190.47 2283.02 12.00 95.00 6597.308 11346.90 84.77 356.46 7380.63 6639.47 2538.18 12.00 -93.00 7108.059 11746.90 90.20 44.22 7399.26 7003.12 2673.35 12.00 85.00 7495.9810 12021.90 85.82 11.48 7409.07 7242.72 2800.05 12.00 -98.00 7765.1311 12147.70 83.89 26.51 7420.42 7360.85 2840.69 12.00 98.00 7889.97 Total Depth : 12147.70' MD, 7420.42' TVD 4533 4800 5067 5333 5600 5867 6133 6400 6667 6933 7200 7467 7733 8000 South(-)/North(+) (400 usft/in)800 1067 1333 1600 1867 2133 2400 2667 2933 3200 3467 West(-)/East(+) (400 usft/in) MPC-04L1 wp03 tgt08 MPC-04L1 wp03 tgt07 MPC-04L1 wp03 tgt06 MPC-04L1 wp03 tgt05 MPC-04L1 wp03 tgt04 MPC-04L1 wp03 tgt03 MPC-04L1 wp03 tgt02 MPC-04L1 wp03 tgt01 MPC-04 2 3/8" x 3 1/4" 6500 6750 700 0 7250 7420 MPU C-04A wp06 KOP : Start Dir 9º/100' : 9022' MD, 7227.70'TVD : 15° LT TF Start Dir 30º/100' : 9042' MD, 7245.23'TVD Start Dir 12º/100' : 9271.90' MD, 7343.26'TVD Total Depth : 12147.70' MD, 7420.42' TVD Project: Milne Point Site: M Pt C Pad Well: MPC-04 Wellbore: Plan: MPU C-04A Plan: MPU C-04A wp06 WELL DETAILS: MPC-04 Ground Level: 0.00 +N/-S +E/-W Northing Easting Latittude Longitude 0.00 0.00 6029624.270 557963.420 70° 29' 29.598 N 149° 31' 34.083 W REFERENCE INFORMATION Co-ordinate (N/E) Reference:Well MPC-04, True North Vertical (TVD) Reference:9 : 04 9/7/1982 00:00 @ 52.00usft (generic drilling rig) Measured Depth Reference:9 : 04 9/7/1982 00:00 @ 52.00usft (generic drilling rig) Calculation Method:Minimum Curvature CASING DETAILS TVD TVDSS MD Size Name 7420.42 7368.42 12147.70 2-3/8 2 3/8" x 3 1/4" Project: Milne Point Site: M Pt C Pad Well: MPC-04 Wellbore: Plan: MPU C-04A Design: MPU C-04A wp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".-0.+&0 &.""-/& )'()%) '()%)'()% "-**&/ "-/+& /0&0+ ".-0.+&0 &""-/+&( )'1()*+)'1()*+)'1()*+*&23,3&2,!%&2"",%2,2"&,3&2,= ?!'1()*+)'1()*+)'1()*+*",2(3"2!,(2""%,2(,2","2== ?! =/ )0>/ )0 .9 .>"& ,-&.23 ) )' ,-& ,-"%& '1()*/ .2'42 5! 6,-"%& "-"*+&+ '1()*/ .2'4!!' ! 6 7 8 93)& 8 :&( 8 8 $ &( ; $#< $) =& 6 :: & 8 86'787(8 9 8 7& 0.001.503.004.50Separation Factor9000 9200 9400 9600 9800 10000 10200 10400 10600 10800 11000 11200 11400 11600 11800 12000 12200 12400 12600Measured DepthMPC-25B wp02MPC-04MPU C-47 wp24MPC-04No-Go Zone - Stop DrillingCollision Avoidance Req.Collision Risk Procedures Req.NOERRORSWELL DETAILS:MPC-04 NAD 1927 (NADCON CONUS)Alaska Zone 04Ground Level: 0.00+N/-S +E/-W Northing Easting Latittude Longitude0.000.006029624.270 557963.420 70° 29' 29.598 N 149° 31' 34.083 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well MPC-04, True NorthVertical (TVD) Reference:9 : 04 9/7/1982 00:00 @ 52.00usft (generic drilling rig)Measured Depth Reference:9 : 04 9/7/1982 00:00 @ 52.00usft (generic drilling rig)Calculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2020-12-07T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool100.00 9022.00 1 : Sperry-Sun BOSS gyro multi (MPC-04) 3_Gyro-SR-GMS9022.00 9150.00 MPU C-04A wp06 (Plan: MPU C-04A) 3_MWD_Interp Azi+Sag9150.00 12147.70 MPU C-04A wp06 (Plan: MPU C-04A) 3_MWD+IFR2+MS+Sag0.0035.0070.00105.00140.00175.00Centre to Centre Separation (60.00 usft/in)9000 9200 9400 9600 9800 10000 10200 10400 10600 10800 11000 11200 11400 11600 11800 12000 12200 12400 12600Measured DepthGLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference9022.00 To 12147.70Project: Milne PointSite: M Pt C PadWell: MPC-04Wellbore: Plan: MPU C-04APlan: MPU C-04A wp06Milne PointLadder / S.F. PlotsCASING DETAILSTVD TVDSS MD Size Name7420.42 7368.42 12147.70 2-3/8 2 3/8" x 3 1/4" Well Slimhole Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 6.0 ft Top of Annular Element 6.7 ft Bottom Annular 8.0 ft CL Blind/Shears 9.3 ft CL 2" Pipe/Slips 10.1 ft B1 B2 B3 B4 Choke Line Kill Line CL 2-3/8" Pipe/Slips 12.6 ft CL 2" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft Swab Test Pump Hose T1 T2 Swab 1 CL of Flow Cross 17.4 ft Master CL of Master 18.8 ft LDS IA OA LDS Ground Level CDR2-AC 4 Ram BOP Schematic 21-Nov-17 CDR2 Rig's Drip Pan 7-1/16" 5k Flange X 7" Otis Box Hydril 7 1/16" Annular 2" Pipe/Slips 7-1/16" 5k Mud Cross 2" Pipe/Slips Blind/Shear 7-1/16" 5 Mud Cross 2-3/8" Pipe/Slips Revised 2/2015 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: ____________________________ POOL: ______________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit No. _____________, API No. 50-_______________________. Production should continue to be reported as a function of the original API number stated above. Pilot Hole In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (_______________________PH) and API number (50-_____________________) from records, data and logs acquired for well (name on permit). Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (_____________________________) as Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for well ( ) until after ( ) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (________________________) must contact the AOGCC to obtain advance approval of such water well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (_______________________________) in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. 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