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Home My WebLink About223-073Reviewed By: P.I. Suprv Comm ________ :ZϭϭͬϮϳͬϮϬϮϰ /ŶƐƉĞĐƚEŽ͗ƐƵƐϮϰϭϬϬϭϭϯϰϭϱϴ tĞůůWƌĞƐƐƵƌĞƐ;ƉƐŝͿ͗ ĂƚĞ/ŶƐƉĞĐƚĞĚ͗ϵͬϯϬͬϮϬϮϰ /ŶƐƉĞĐƚŽƌ͗ƌŝĂŶŝǆďǇ /ĨsĞƌŝĨŝĞĚ͕,Žǁ͍KƚŚĞƌ;ƐƉĞĐŝĨǇŝŶĐŽŵŵĞŶƚƐͿ ^ƵƐƉĞŶƐŝŽŶĂƚĞ͗ϭͬϮϴͬϮϬϮϰ η ϯϮϰͲϬϬϱ dƵďŝŶŐ͗Ϭ /͗Ϭ K͗Ϭ KƉĞƌĂƚŽƌ͗ŽŶŽĐŽWŚŝůůŝƉƐůĂƐŬĂ͕/ŶĐ͘ KƉĞƌĂƚŽƌZĞƉ͗DĂƚƚDŝůůĞƌ ĂƚĞK'EŽƚŝĨŝĞĚ͗ϵͬϮϳͬϮϬϮϰ dǇƉĞŽĨ/ŶƐƉĞĐƚŝŽŶ͗/ŶŝƚŝĂů tĞůůEĂŵĞ͗<hWZh<Z/shE/dϮDͲϮϰ WĞƌŵŝƚEƵŵďĞƌ͗ϮϮϯϬϳϯϬ tĞůůŚĞĂĚŽŶĚŝƚŝŽŶ 'ŽŽĚ ^ƵƌƌŽƵŶĚŝŶŐ^ƵƌĨĂĐĞŽŶĚŝƚŝŽŶ 'ŽŽĚ ŽŶĚŝƚŝŽŶŽĨĞůůĂƌ 'ŽŽĚ ŽŵŵĞŶƚƐ >ŽĐĂƚŝŽŶǀĞƌŝĨŝĞĚďǇƵƐŝŶŐWĂĚDĂƉ͘ ^ƵƉĞƌǀŝƐŽƌŽŵŵĞŶƚƐ WŚŽƚŽƐĂƚƚĂĐŚĞĚ;ϯͿ ^ƵƐƉĞŶƐŝŽŶƉƉƌŽǀĂů͗^ƵŶĚƌǇ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚ͍ KĨĨƐŚŽƌĞ͍ &ůƵŝĚŝŶĞůůĂƌ͍ tĞůůďŽƌĞŝĂŐƌĂŵǀĂŝů͍ WŚŽƚŽƐdĂŬĞŶ͍ sZWůƵŐ;ƐͿ/ŶƐƚĂůůĞĚ͍ Ws/ŶƐƚĂůůĞĚ͍ tĞĚŶĞƐĚĂǇ͕EŽǀĞŵďĞƌϮϳ͕ϮϬϮϰ 9 9 9 9 9 2024-0930_Suspend_KRU_2M-24A_photos_bb Page 1 of 2 Suspended Well Inspection – KRU 2M-24A PTD 2230730 AOGCC Inspection Rpt # susBDB24100134158 Photos by AOGCC Inspector B. Bixby 9/30/2024 2024-0930_Suspend_KRU_2M-24A_photos_bb Page 2 of 2 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:Brooks, Phoebe L (OGC) To:Cozby, Kelly Cc:Regg, James B (OGC) Subject:RE: 7ES BOP Test 1/21/24 Date:Friday, February 16, 2024 1:52:20 PM Attachments:Nabors 7ES 01-21-24 Revised.xlsx Kelly, Attached is a revised report changing the well name to reflect KRU 2M-24A for PTD #2230730 (removing the sundry #). Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Cozby, Kelly <Kelly.Cozby@nabors.com> Sent: Tuesday, January 23, 2024 7:07 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: NSK RWO CM <nskrwo.cm@conocophillips.com>; White, Bradley <Bradley.White@nabors.com>; Morales, Tony <Tony.Morales@nabors.com>; Turcotte, Matthew <Matthew.Turcotte@nabors.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Medina, Johnny <Johnny.Medina@nabors.com> Subject: Re: 7ES BOP Test 1/21/24 Please disregard first report as test time was incorrect. Changed from 8.5 hrs. to 6.5 hrs. as test time reflected. Thanks, Kelly Cozby KRU 2M-24A PTD 2230730 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907 670-6132 Mobil 907 715 9055 kelly.cozby@nabors.com From: Cozby, Kelly <Kelly.Cozby@nabors.com> Sent: Tuesday, January 23, 2024 6:00 PM To: Regg, James B (CED) <jim.regg@alaska.gov>; AOGCC.Inspectors@alaska.gov <AOGCC.Inspectors@alaska.gov>; Brooks, Phoebe L (CED) <phoebe.brooks@alaska.gov> Cc: NSK RWO CM <nskrwo.cm@conocophillips.com>; White, Bradley <Bradley.White@nabors.com>; Morales, Tony <Tony.Morales@nabors.com>; Turcotte, Matthew <Matthew.Turcotte@nabors.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Medina, Johnny <Johnny.Medina@nabors.com> Subject: 7ES BOP Test 1/21/24 Thanks, Kelly Cozby 7ES Rig Manager NABORS ALASKA DRILLING INC. Office 907 670-6132 Mobil 907 715 9055 kelly.cozby@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:1/21/24 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2230730 Sundry # Operation:Drilling:X Workover:Explor.: Test:Initial:Weekly:Bi-Weekly:X Other: Rams:250/4000 Annular:250/4000 Valves:250/4000 MASP:3535 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)2950 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1550 P Check Valve 0 NA 200 psi Attained (sec)21 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)119 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1000 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5 @ 2050 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 25 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 2 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/19/24 11:53 Waived By Test Start Date/Time:1/21/2024 16:00 (date)(time)Witness Test Finish Date/Time:1/21/2024 22:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Nabors Test BOPE with 3.5'' & 4" test joints 250/4000. Annular tested on 3.5" test jnt. 250/4000. Alarms tested. Kelly Cozby/Matt Turcotte ConocoPhillips Ron Phillips/Chase Erdman KRU 2M-24A Test Pressure (psi): kelly.cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2024-0121_BOP_Nabors7ES_KRU 2M-24A         J. Regg; 4/5/2024 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brooks, Phoebe L (OGC) To:Morales, Tony Cc:Regg, James B (OGC) Subject:RE: 7ES Nabors KUP 2M-24A 1/23/24 Date:Friday, February 16, 2024 2:01:08 PM Attachments:Nabors 7ES 01-25-24 Revised.xlsx Tony, Attached is a revised report changing the well name to reflect KRU 2M-24A for PTD #2230730 (removing the sundry #) and changing the report date to 01/25/24 to match the finish date. Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Morales, Tony <Tony.Morales@nabors.com> Sent: Sunday, January 28, 2024 12:39 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: NSK RWO CM <nskrwo.cm@conocophillips.com>; Hobbs, Greg S <greg.s.hobbs@conocophillips.com>; White, Bradley <Bradley.White@nabors.com> Subject: 7ES Nabors KUP 2M-24A 1/23/24 Tony Morales 7ES Rig Manager NABORS ALASKA DRILLING INC. KRU 2M-24A PTD 2230730 Office 907 670-6132 Mobil 805 797-6720 tony.morales@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:1/25/24 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2230730 Sundry # Operation:Drilling:X Workover:Explor.: Test:Initial:Weekly:Bi-Weekly:X Other: Rams:250/4000 Annular:250/4000 Valves:250/4000 MASP:3535 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 3 1/2" x 5 1/2"FP Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)2950 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1550 P Check Valve 0 NA 200 psi Attained (sec)15 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)117 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:1000 P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5 @ 2050 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 30 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 6 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:1 Test Time:40.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 1/23/24 16:41 Waived By Test Start Date/Time:1/23/2024 22:30 (date)(time)Witness Test Finish Date/Time:1/25/2024 15:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Nabors Test BOPE with 4.5'' & 4" test joints 250/4000. Annular tested on 4" test jnt. 250/3500. Alarms tested. Note: repaired upper rams bonnet door mud wiper seal, re-test good. Total test time 9.5 hrs. Tony Morales/Matt Turcotte ConocoPhillips Mark Adams/Chase Erdman KRU 2M-24A Test Pressure (psi): tony.morales@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2024-0125_BOP_Nabors7ES_KRU_2M-24A           J. Regg; 4/5/2024 T + 1 337.856-7201 1058 Baker Hughes Drive Broussard, LA 70518, USA Feb 02, 2024 AOGCC Attention: Kayla Junke 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Subject:Final Log Distribution for ConocoPhillips Alaska, Inc. KRU 2M-24A Kuparuk River API #: 50-103-20171-01-00 Permit No: 223-073 Rig: Nabors 7ES The final Coil deliverables were uploaded via https://copsftp.sharefile.com/ for the above well. Items delivered: Digital Las Data, Graphic Images CGM/PDF and Survey Files. Thank you. Signature of receiver & date received: Please return transmittal letter to: Jenny Jones Jenny.E.Jones@conocophillips.com Luis G Arismendi Luis.arismendi@bakerhughes.com PTD: 223-073 T38472 2/2/2024 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.02 15:26:08 -09'00' 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? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7450'7130' Casing Collapse Structural Conductor Surface Intermediate Production 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 1/8/2023 3-1/2" Perforation Depth MD (ft): J-55 3104' 7070-7079', 7103-7112', 7122- 7137', 7156-7182' 7397' 6040-6048', 6068-6075', 6084- 6096', 6112-6134' 7" Perforation Depth TVD (ft): 121' 3146' 6348'7436' 16" 9-5/8" 79' 6990' MD 121' 2792' ConocoPhillips Alaska, Inc. Length Size Proposed Pools: PRESENT WELL CONDITION SUMMARY Kuparuk River Oil Pool TVD Burst STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL 0025586 223-073 P.O. Box 100360, Anchorage, AK 99510 50-103-20171-01-00 Kuparuk River Field Kuparuk River Oil Pool AOGCC USE ONLY Victoria Loepp 1/8/2023 Tubing Grade: Tubing MD (ft): Cy Eller Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: cy.eller@conocophillips.com (907) 265-6049 Graduate Engineer KRU 2M-24A 6360' 6570' 5625' 6570' N/A Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Packer: Baker HB Rtrvbl Packer SSSV: None 6961' MD and 5949' TVD N/A By Grace Christianson at 7:53 am, Jan 10, 2024 324-005 Suspended Note: Sundry 324-032 is an updated change of approved program sundry.PTD 10-407X VTL 01/24/2023 SFD 1/12/2024 BOP test to 4000 psig Annular preventer to 2500 psig X DSR-1/26/24*&:JLC 1/26/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.26 15:20:44 -09'00'01/26/24 RBDMS JSB 012924 Application for Permit to Drill, 2M-24A Saved: 8/24/20238-Jan-24 Page 1 of 7 Printed: 8-Jan-24 2M-24A Application for Permit to Drill Document Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................... 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................... 2 3. Proposed Drilling Program ...................................................................................... 3 4. Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) ................................................................................................................................... 4 5. MASP Calculations ................................................................................................... 4 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ............................................................................................................... 5 7. Casing and Cementing Program ............................................................................. 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................... 6 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .......................................... 6 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ......................... 6 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................... 6 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 (Requirements of 20 AAC 25.005 (c)(14)) ............................................................................. 6 14. Drilling Hazards Summary ....................................................................................... 7 15. Proposed Completion Schematic ........................................................................... 8 Application for Permit to Drill, 2M-24A Saved: 8/24/20238-Jan-24 Page 2 of 7 Printed: 8-Jan-24 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as 2M-24A 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 114‘ FSL, 554‘ FWL, SEC 27, T11N, R8E, UM NAD 1927 Northings: 5948986 Eastings: 487859 RKB Elevation 146’ AMSL Pad Elevation 105’ AMSL Location at Sidetrack KOP 1030‘ FNL, 1786‘ FEL, SEC 34, T11N, R8E, UM NAD 1927 Northings: 5947838 Eastings: 491335 Measured Depth, RKB:6550’ Total Vertical Depth, RKB:5754’ Total Vertical Depth, SS:5608’ Location at Sidetrack KOP 564‘ FNL, 1713‘ FEL, SEC 34, T11N, R8E, UM NAD 1927 Northings: 5948303 Eastings: 491407 Measured Depth, RKB:6425’ Total Vertical Depth, RKB:5506’ Total Vertical Depth, SS:5360’ Top of Productive Horizon 1032‘ FNL, 1349‘ FEL, SEC 34, T11N, R8E, UM NAD 1927 Northings: 5947835 Eastings: 491771 Measured Depth, RKB:7164’ Total Vertical Depth, RKB:6172’ Total Vertical Depth, SS:6026’ Total Depth 941‘ FNL, 980‘ FEL, SEC 34, T11N, R8E, UM NAD 1927 Northings: 5947926 Eastings: 492140 Measured Depth, RKB:7645’ Total Vertical Depth, RKB:6465’ Total Vertical Depth, SS:6319’ 488394 SFD Application for Permit to Drill, 2M-24A Saved: 8/24/20238-Jan-24 Page 3 of 7 Printed: 8-Jan-24 3. Proposed Drilling Program The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. Completed Pre-Rig Work 1. Pull 2 ea. Patches straddling tubing leaks (1,789’- 1818’ and 6876’-6904’) – Completed 6/26/23 2. Tubing punch below packer for injectivity test, Injectivity Failed – 6/29/23 3. T-PPPOT (Passed) and T-POT tests (passed). IC-POT failed 7/18/2023 Remaining Pre-Rig Work 4. Suspend well based on separate state approved sundry (323-385) a. Tag top of cement @ ~6600’ MD 5. Dummy off GLMs 1,2,4 and leave station 7 open 6. Perform tubing cut at 6565’ MD Rig Work MIRU 1. MIRU Nabors 7ES on 2M-24. Circulate well over to 8.5ppg seawater. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30- minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing, Grow PC, Set whipstock 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to cut (~6565’ RKB). a. Grow and stretch of 7” production casing: set plug/ storm packer near surface, pressure test plug. ND to casing head and let grow, pull 7” casing and re-land slips and PO, nipple up new tubing spool and BOP’s, test flange break and IC packoffs. b. Continue to lay down tubing 6. Set Whipstock at 6550’ 6425’ TOWS oriented high side. 1. Mill window in 7” casing. 2. Drill 6-1/8” hole to TD, 250’ RKB below base of Kuparuk formation. 3. Circulate hole clean and pull out of hole with drilling BHA. 4. Run 3.5” liner TD. 5. Cement liner, bringing cement above liner top to at least 6500’ MD. Set liner top hanger/packer and circulate cement out of hole from above top of liner. a.We intend to frac this well later and will request a variance from 20 AAC 25.283(c)(1) with the 10-403 for the frac, since the liner top packer will be set at 6375’ MD leaving ~90’ of cement with good bonding, and ~30’ of cement with poorer bonding above the liner top packer. 6. Perform pressure test on 7” casing / 3-1/2” liner to 2000 psi (to ensure no casing integrity issues were caused during drilling/liner running). We intend to frac this well later and will request a variance from 20 AAC 25.283(c)(1) with the 10-403 for the frac, since the liner top packer will be set at 6375’ MD leaving ~90’ of cement with good bonding, and ~30’ of cement with poorer bonding above the liner top packer. Application for Permit to Drill, 2M-24A Saved: 8/24/20238-Jan-24 Page 4 of 7 Printed: 8-Jan-24 a. If pressure test does not pass, run 5-1/2” tie-back string and re-test. 7. Run 3.5” gas lift upper completion 8. Pressure test hanger seals to 5,000 psi. 9. Test tubing to 3050 psi, chart test. 10. Test IA to 3,300 psi, chart test. Drop tubing pressure and shear SOV. 11. Install BPV and test to 1000 psi in the direction of flow. 12. Nipple down BOP. 13. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes. 14. Freeze protect down annulus through SOV, RU TxIA cross, let u-tube. 15. Secure well. Rig down and move out. 4. Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP schematics on file for Nabors 7ES. As this well is a sidetrack below the surface casing, no diverter will be used. 5. MASP Calculations The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Casing/Window Depth MD/TVD(ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) EMW 7 6550 / 5608 6425 / 5506 16.5 2945 1977 11.5 3.5 7645 / 6319 15 4138 2124 13.5 PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD Application for Permit to Drill, 2M-24A Saved: 8/24/20238-Jan-24 Page 5 of 7 Printed: 8-Jan-24 1. ASP CALCULATIONS Drilling 6-1/8” hole out of 7” intermediate casing ASP = [(FG x 0.052) – 0.1] D = [(16.5 x 0.052) – 0.1] x 5608 5506 = 4251 psi 4174 psi OR ASP = FPP – (0.1 x D) = 2538 – (0.1 x 5608) = 1977 psi = 2492 – (0.1 x 5506) = 1941 psi Drilling 6-1/8” hole to top of Reservoir ASP = [(FG x 0.052) – 0.1] D = [(15 x 0.052) – 0.1] x 6026 = 4098 psi OR ASP = FPP – (0.1 x D) = 2727 – (0.1 x 6026) = 2124 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) LOT to 16.0 ppg was performed on the intermediate casing shoe, 5806’ TVD when drilling 2M-40 which is a neighboring well. No FIT/LOT is planned as part of this sidetrack. 7. Casing and Cementing Program Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 3.5 6.125 9.3 L-80 Hyd563 Cemented liner – 5.5” OD Centralizers planned Cementing Calculations 3-1/2” production liner run to 7645’ MD / 6319’ TVD Top of slurry is designed to be at ~6500’ MD, the top of the 3-1/2” liner, which is 664’MD / 459’ TVD above the top of the Kuparuk interval. Assume 20% excess annular volume. Tail slurry from 7645’ MD to 6500’ MD with 15.8 ppg Class G + Add's Total Volume = 158ft3 209ft3 => 136 sx 170 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk (Note: 170 sks x 1.16 cuft/sk = 197.2 cuft = 35.1 barrels SFD) Application for Permit to Drill, 2M-24A Saved: 8/24/20238-Jan-24 Page 6 of 7 Printed: 8-Jan-24 8.Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Production Hole Size in. 6.125 Casing Size in. 3.5 Density PPG 11.5-13.5 PV cP 10 YP lb./100 ft2 10 - 15 Funnel Viscosity s/qt. 40 - 50 Initial Gels lb./100 ft2 6 10 Minute Gels lb./100 ft2 8 API Fluid Loss cc/30 min. 4.0 HPHT Fluid Loss cc/30 min. 10.0 pH 9.0 – 9.5 The interval will be drilled with a water-based mud (LSND) weighted to 11.5-13.5 ppg. Fluid hydraulic modeling has been performed. Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9.Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A – No abnormally pressured formations expected Kuparuk (target) Formation expected to be overpressured. Anticipating 4146 psi at top of Kuparuk at 7188’ MD, 6040’ TVD. Equivalent to 13.2 ppg. -A.Dewhurst 12 SEP 2023 10.Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A – No seismic to be performed, drilling in well developed area. 11.Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12.Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13.Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well 2M-24A will be injected into a permitted annulus on 1B pad. o 13.2 ppg. Kuparuk (target) Formation expected to be overpressured. Application for Permit to Drill, 2M-24A Saved: 8/24/20238-Jan-24 Page 7 of 7 Printed: 8-Jan-24 14. Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 6.125” Hole / 3.5” Liner - Slant Production Hole Event Risk Level Mitigation Strategy Lost circulation high Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Low Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Low Keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: No collision risks exist in the planned 2M-24A wellbore. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Lost returns are possible if weaker than expected formations or stringers are encountered. LCM material will be available to seal in losses if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. HIGH (13.2 ppg EMW) SFD Application for Permit to Drill, 2M-24A Saved: 8/24/20238-Jan-24 Page 8 of 7 Printed: 8-Jan-24 15. Proposed Completion Schematic 1 Conklin, Amy A From:Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent:Monday, January 8, 2024 11:29 AM To:Eller, Cy Subject:[EXTERNAL]RE: 2M-24 KOP Plan Forward APPROVAL CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Cy, Approval is granted to proceed with seng the whipstock and the plan forward outlined below. Please submit a 10-403 Change of Approved program as soon as possible. Victoria Loepp Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Eller, Cy <Cy.Eller@conocophillips.com> Sent: Monday, January 8, 2024 11:25 AM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Subject: RE: 2M-24 KOP Plan Forward Hi Victoria, Per our conversa:on on the phone, we are following the Change of Approved Program Sundry 323-659, a=ached, and intend to set the whipstock on the tubing stub at 6443’ MD. This will put the KOP at 6425’ MD. We do not intend to perform a FIT before drilling ahead, since we are below the 7” TOC at ~6286’ MD based on the CBL that was ran. Correct me if I'm wrong, but we should be able to proceed with seng the whipstock following this change of approved sundry, if not please let me know. The liner top packer seng depth will be changed from the depth listed in the Permit to Drill 223-073, because of the change in KOP. A change from the email below is that we intend to set the liner top packer 50’ above the KOP, at 6375’ MD. To meet regula:ons for hydraulic fracturing, the liner top packer must be set no less than 100’ MD above the produc:on casing TOC. The CBL that was ran shows ~90’ of cement with good bonding, and an addi :onal ~30’ of cement with poorer bonding above the intended liner top packer seng depth. You don't often get email from cy.eller@conocophillips.com. Learn why this is important 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 I will follow up this email with a change of approved program for PTD 223-073, providing the new direc :onal plan, and reques:ng a variance for the liner top packer seng depth. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska OJce: 907-265-6049 Cell: 907-232-4090 From: Eller, Cy Sent: Sunday, January 7, 2024 11:18 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Coberly, Jonathan <Jonathan.Coberly@conocophillips.com >; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com >; Tuttle, Elliott <Elliott.Tuttle@conocophillips.com > Subject: 2M-24 KOP Plan Forward Hi Victoria, We have ran the CBL, CCL and caliper on the 7” casing on 2M-24 which are a=ached in this email. Based on these logs, we are seeking your approval to set the whipstock at 6443’ MD and begin the sidetrack por:on of this project. Con:nuing to mill the tubing and cement down to the original planned KOP will cause unnecessary risk of damaging the 7” casing. We believe that we have good cement bonding up to ~6286’ MD, which gives us ~138’ of good cement bonding above our proposed KOP. The gamma signature from the new CBL corresponds nicely to the gamma signature from the original CBL that was ran in 1992. The caliper log showed some minor damage to the casing at ~6266’ – 6272’ MD. We are s:ll passing pressure tests to 2500 psi on the 7” casing currently, but since we will have to do a 3300 psi pressure test in the future, we intend to set the liner top packer above this damaged zone to have new pipe for the en:re interval that will be subjected to this higher test pressure. The cement top for this 3.5” liner will s:ll be to at least 6500’ RKB, as originally planned, but may not be all the way up to the bo=om of the liner top packer. We are on standby due to weather condi:ons now, so I will follow up this email with a call tomorrow morning. Thank you, Cy Eller RWO/CTD Engineer ConocoPhillips Alaska OJce: 907-265-6049 Cell: 907-232-4090 2M-24 Proposed RWO-ST Completion Schematic COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 121' 121' 16" 15.06" 62.58# H-40 Welded Welded Surface 3146' 2791.9' 9 5/8" 8.681" 47# L-80 BTC ABMOD BTC ABMOD Production 7436' 6348' 7" 6.276" 26# J-55 BTC MOD BTC MOD Tubing 6500' 6375'5567' 5465'3 1/2" 2.992" 9.3# L-80 EUE 8rd EUE 8rd Liner 7542' 6247' 3 1/2" 2.992" 9.3# L-80 HYD563 HYD563 MD +/- 5' TVDSS 7245 5926 7,265 5,937 7,296 5,954 7,331 5,976 A3 Top Perf A3 Btm Perf Planned Perf Details: WP02 Reference Point A4 Top Perf A4 Btm Perf PROPOSED UPPER COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" x 1 1/2" MMG @ - 2872' RKB - 5392' RKB - 6450' RKB 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 80-40 Locator and Seal assembly PROPOSED LOWER COMPLETION 5" x 7" Baker ZXP Packer and FL5 Hanger @ ~6500' RKB 6375' MD (3.875" ID) 4" Sealbore Extension 3-1/2" 9.3# H563 Liner to a TD of ~7532' RKB Landing Collar Float Collar Float Shoe Planned TD of: 7542' RKB (210' past Target) Tubing cut planned Pre-Rig @ 6565' MD Surface Casing @ 3146' RKB Conductor @ 121' RKB KOP: 6550' RKB 6425' MD (6409' RKB) 5462' TVDSS 6415 6700 6700 7000 7000 7200 7200 7400 7400 7542 2M-24A wp03 Plan Summary 2M-24A RWO ST 2M-15 2M-16 2M-17 2M-18 2M-19 2M-20 2M-21L1 2M-22 2M-22L1 2M-22L1PB1 2M-23 2M-24 2M-25 2M-26 2M-31 2M-38 2M-41 0 9 Do g l e g S e v e r i t y 6400 6600 6800 7000 7200 7400 Measured Depth 3-1/2" Production Tubing 50 50 100 100 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] 2M-24 5250 6000 Tr u e V e r t i c a l D e p t h 2850 3000 3150 3300 3450 3600 3750 3900 Vertical Section at 106.46° 2M-24 2M -24 A w p 0 3 0 150 300 Ce n t r e t o C e n t r e S e p a r a t i o n 6625 6750 6875 7000 7125 7250 7375 Measured Depth 2M-24 DDI 5.618 SURVEY PROGRAM Date: 2023-03-06T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 148.00 6415.40 2M-24 Srvy 1 - SLB_GCT-MS (2M-24)GCT-MS6415.40 7542.00 2M-24A wp03 (2M-24A RWO ST)r.5 MWD OWSG Surface Location North / 5948985.76 East / 488394.29Ground / 104.90 CASING DETAILS TVD MD Name 6263.22 7542.00 3-1/2" Production Liner Mag Model & Date: BGGM2023 08-Jan-24 Magnetic North is 14.26° East of True North (Magnetic Declination) Mag Dip & Field Strength: 80.56° 57214.01nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 6415.40 34.96 109.30 5497.96 -1118.34 2869.40 0.00 0.00 3068.67 Start DLS 0.22 TFO -15.99 2 6425.00 34.98 109.29 5505.83 -1120.16 2874.60 0.22 -15.99 3074.16 Start DLS 12.50 TFO -45.00 3 6461.00 38.28 104.15 5534.72 -1126.30 2895.16 12.50 -45.00 3095.62 Start 40.00 hold at 6461.00 MD 4 6501.00 38.28 104.15 5566.12 -1132.35 2919.19 0.00 0.00 3120.38 Start DLS 7.00 TFO -57.86 5 6746.21 49.25 84.89 5743.74 -1142.73 3086.59 7.00 -57.86 3283.87 Start 631.54 hold at 6746.21 MD 6 7377.75 49.25 84.89 6156.00 -1100.13 3563.11 0.00 0.00 3728.80 Start 164.25 hold at 7377.75 MD 7 7542.00 49.25 84.89 6263.22 -1089.05 3687.04 0.00 0.00 3844.52 TD at 7542.00 FORMATION TOP DETAILS TVDPath Formation 5827.81 Top Kalubik 5851.96 Top HRZ 6016.47 Top Reservoir 6069.34 A4 Top Perf 6082.40 A4 Btm Perf 6102.63 A3 Top Perf 6125.48 A3 Btm Perf 6211.00 Btm Reservoir By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. 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"# "$ "$ %&' "$ () *$#+, , !"##$ %&''-.+, ( )/, !"##$ %&'".+, *+, +0+,#"## $1, ( "#,+%, &"## , %1,#"## $ +%2 - +.2,./+ 0 * -$$ / +.3, 1#2 &++'-.+, "#, .3, + 1"#, "#, 1+, 4 , + (" * 3 4* * ( 56-76 86+. 6./9 1 1 ##:; ##< ### $ $ / ( &"##$ )* = * $ >&#"#>$ 1#2 *#2 , 3%3* 1 #, "0> *** . ? 3"#, 4 5+6 '3 .'0 5%26 ' 5+6 . <@<# 5+ 4, 5+ @"## !A &"# ( 675+ %' "& / - 5 - 5 / * * ("&!A &"# 0A&"## 1#2 % - +' &++%$%2$.3 + "# . 5+6 &++ "# . 5+6 7( 5+6 7( 1 5+6 4 %3 0 . * & & & 2"0 2&"## "## >" ! !"2#0 . & & & 2!>" 0 20&"## "2 @"&& 2>"@@ 8 & & & A # "&& A##"## 2!>"> 2& " >"!>0 ! ! ! 2&2"# 2&#"## >0">2 >"!@ 20"0 . ! ! ! 20&"@2 20&"## >@" >"& 2">@ 8 ! ! ! 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"!2 &"2># 82@ 2@ 2@ @0"> 0&"## 2 "## "@# &"##2 22#" 0 2&"## "! #0"& !"@#@ . 20@"# 20&"## "># #0" 2"2># 8 0&"&& 00&"## !"&> &2" 0 0"!2 * (, A 8 $ A . *$#+, , !"##$ %&''-.+, ( )/, !"##$ %&'".+, *+, +0+,#"## $1, ( "#,+%, &"## , %1,#"## $ +%2 - +.2,./+ 0 * -$$ / +.3, 1#2 &++'-.+, # &# &## 0&# ### # &## 2### &## !### 0&## >### * / 6 ** &A &A & ? !A !A ! ? 0A 0A 0 ? @A @A @ ? >A >A > ? #A #A # ? A A ? A 6 A 6 ?# A 6 # A 6 # ?# A 6 7 A 6 7 ?# A A ? A 6 A 6 ?# A 6 7 A 6 7 ?# 2A 2A 2 ?# A A ? &A &A & ? !A !A ! ? 2 A 2 A 2 ?# 22A 22A 22 ?# 2A 2A 2 ? 2&A 2&A 2& ?# 2@A 2@A 2@ ?# A A ?# 6 . 5 . 3 / *$#+, , !"##$ %&''-.+, ( )/, !"##$ %&'".+, *+, +0+,#"## $1, ( "#,+%, &"## , %1,#"## $ +%2 - +.2,./+ 0 * -$$ / +.3, 1#2 &++'-.+, #"## 2"## !"## >"## 8 # &## 2### &## !### 0&## * / +- /, + * 3 - 8 &A &A & ? !A !A ! ? 0A 0A 0 ? @A @A @ ? >A >A > ? #A #A # ? A A ? A 6 A 6 ?# A 6 # A 6 # ?# A 6 7 A 6 7 ?# A A ? A 6 A 6 ?# A 6 7 A 6 7 ?# 2A 2A 2 ?# A A ? &A &A & ? !A !A ! ? 2 A 2 A 2 ?# 22A 22A 22 ?# 2A 2A 2 ? 2&A 2&A 2& ?# 2@A 2@A 2@ ?# A A ?# 6 . 5 . 3 / Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB (TOC corrected by E-Line) 6,570.0 2M-24 11/24/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Added tubing cut at 6180' RKB 2M-24 12/4/2023 jconne Notes: General & Safety Annotation End Date Last Mod By NOTE: ROCK PRODUCER. SIGNIFICANT VOLUME OF ROCKS FCO'd ON 4/28/2020. 4/28/2020 condijw Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.58 H-40 WELDED SURFACE 9 5/8 8.92 41.9 3,146.4 2,791.9 47.00 L-80 BTC ABMOD Tie-Back String 7 6.28 0.0 1,798.0 1,700.3 26.00 L-80 HYD563 PRODUCTION 7 6.28 38.8 7,436.3 6,348.5 26.00 J-55 BTC-MOD Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 38.0 Set Depth … 6,990.3 Set Depth … 5,973.5 String Max No… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection ABM-EUE ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 38.0 38.0 0.09 HANGER 8.000 FMC GEN IV TUBING HANGER 3.500 1,808.0 1,708.2 36.94 SAFETY VLV 5.250 CAMCO TRDP-4A-RO SAFETY VALVE CAMCO TRDP- 4A RO 2.812 3,214.2 2,848.8 32.90 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 4,714.2 4,098.4 34.15 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,244.5 4,535.3 34.62 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 5,652.6 4,870.7 35.06 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,094.8 5,235.2 34.75 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,535.0 5,595.9 35.05 GAS LIFT 5.390 CAMCO KBUG CAMCO KBUG 2.920 6,892.4 5,892.0 33.65 GAS LIFT 5.750 CAMCO MMG-2 CAMCO MMG-2 2.920 6,947.8 5,938.1 33.58 PBR 5.125 BAKER PBR w/ 10' STROKE, 4" SEAL BORE BAKER 10' STROK E 3.000 6,961.5 5,949.5 33.52 PACKER 6.063 BAKER HB RETRIEVABLE PACKER BAKER HB 2.890 6,977.8 5,963.1 33.45 NIPPLE 4.540 CAMCO D NIPPLE CAMCO D 2.750 6,989.4 5,972.8 33.42 SOS 4.500 BAKER SHEAR OUT SUB, TTL ELMD @ 6987' SBHP 5/28/1007 BAKER 3.015 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,565.0 5,620.5 34.93 CUT WellTech Mechanical cutter made tubing cut @ 6565' RKB. Tied into GLM and corrected TOC depth. All indications of good cut. 11/24/2023 2.990 6,893.0 5,892.5 33.65 Tubing Leak Leak at 6893' 6/8/2020 2.992 6,925.0 5,919.1 33.63 CEMENT RETAINER 10/30/2023 0.000 6,970.0 5,956.6 33.49 TUBING PUNCH 2" x 3' TBG PUNCH, 3/8" TITAN KNOCKOUT CHARGES, 7g, 6 SPF, 0 DEG PHASING 6/29/2023 2.992 6,977.0 5,962.4 33.46 SCREEN ROCK SCREEN ON 2.75" C LOCK. (2"OD) 18' OAL 11/21/2022 0.000 6,990.0 5,973.3 33.42 OTHER 2.12" OD DISCONNECT, CIRC SUB, MOTOR & 2.72" MILL OAL= 14.98 10/2/2022 0.520 7,130.0 6,090.4 32.92 FISH ROCK SCREEN 250 MICRON SCREEN, BN BOTTOM (OAL 218") SCREEN BODY STILL IN HOLE MILLED AND PUSHED INTO 7" ON 2/5/22 8/7/2020 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 3,214.2 2,848.8 32.90 1 GAS LIFT DMY BK 1 8/16/2023 4,714.2 4,098.4 34.15 2 GAS LIFT DMY BK 1 0.0 7/27/2023 0.000 5,244.5 4,535.3 34.62 3 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 5,652.6 4,870.7 35.06 4 GAS LIFT DMY BK 1 0.0 7/27/2023 0.000 6,094.8 5,235.2 34.75 5 GAS LIFT DMY BK5 1 0.0 9/4/1992 0.000 6,535.0 5,595.9 35.05 6 GAS LIFT DMY BTM 1 0.0 5/26/2017 0.000 6,892.4 5,892.0 33.65 7 GAS LIFT OPEN 1 1/2 0.0 10/31/2023 0.000 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 0.0 0.0 0.00 Parker 245 ORKB = 39.08'. Nabors 7es RKB = 28.0' 0.000 Parker 245 ORKB = 39.08'. Nabors 7es RKB = 28.0' 0.000 1,783.8 1,688.9 36.86 Cementing Nipple 8.300 7" ES Cementer (SN#: 102463867 -A) Halliburto n HES Cementer 6.171 2M-24, 1/8/2024 5:04:43 PM Vertical schematic (actual) PRODUCTION; 1,795.0-7,436.3 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SCREEN; 6,977.0 TUBING PUNCH; 6,970.0 PACKER; 6,961.5 CEMENT RETAINER; 6,925.0 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 Cement Plug; 6,570.0 ftKB CUT; 6,565.0 GAS LIFT; 6,535.0 SURFACE; 41.9-3,146.4 Tie-Back String; 0.0-1,798.0 Production String 1 Cement; 39.0 ftKB CONDUCTOR; 42.0-121.0 KUP PROD KB-Grd (ft) 46.49 RR Date 6/19/1992 Other Elev… 2M-24 ... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032017100 Wellbore Status PROD Max Angle & MD Incl (°) 38.50 MD (ftKB) 2,114.40 WELLNAME WELLBORE2M-24 Annotation Last WO: End DateH2S (ppm) 70 Date 12/5/2016 Comment SSSV: TRDP Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 7,070.0 7,079.0 6,040.1 6,047.7 C-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,103.0 7,112.0 6,067.8 6,075.3 A-5, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,122.0 7,137.0 6,083.7 6,096.3 A-4, 2M-24 8/28/2010 6.0 APERF 2.5" MILLENIUM II HMX DP, 60 deg phase 7,156.0 7,176.0 6,112.3 6,129.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 77 deg. CCW; SWS 4 1/2" Csg Gun 7,176.0 7,182.0 6,129.1 6,134.1 A-3, 2M-24 9/4/1992 4.0 IPERF 180 deg. phasing; Oriented 81.8 deg CCW; SWS 4 1/2" Csg Gun Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 6,570.0 6,925.0 5,624.6 5,919.1 Cement Plug 10.7 bbls15.8 PPG CLASS G 11/1/2023 2M-24, 1/8/2024 5:04:44 PM Vertical schematic (actual) PRODUCTION; 1,795.0-7,436.3 IPERF; 7,176.0-7,182.0 IPERF; 7,156.0-7,176.0 FISH; 7,130.0 APERF; 7,122.0-7,137.0 APERF; 7,103.0-7,112.0 APERF; 7,070.0-7,079.0 OTHER; 6,990.0 SCREEN; 6,977.0 TUBING PUNCH; 6,970.0 PACKER; 6,961.5 CEMENT RETAINER; 6,925.0 GAS LIFT; 6,892.4 Tubing Leak; 6,893.0 Cement Plug; 6,570.0 ftKB CUT; 6,565.0 GAS LIFT; 6,535.0 SURFACE; 41.9-3,146.4 Tie-Back String; 0.0-1,798.0 Production String 1 Cement; 39.0 ftKB CONDUCTOR; 42.0-121.0 KUP PROD 2M-24 ... WELLNAME WELLBORE2M-24 1 Christianson, Grace K (OGC) From:Loepp, Victoria T (OGC) Sent:Tuesday, January 23, 2024 9:51 PM To:Long, Sydney Subject:CPAI_KRU_2M-24A_(PTD 223-073, Sundry 324-032) Suspend Sydney, ApprovalisgrantedtosettheretainerandpumpcementasoutlinedinthissubmiƩedsundry.Theplugmustbetagged andpressuretestedwithanAOGCCwitness. Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Chris Brillon Wells Engineering Manager Conoco Phillips Alaska, Inc. 700 G Street Anchorage, AK, 99501 Re:.XSDUXN5LYHU)LHOG.XSDUXN5LYHU2LO.580$ Conoco Phillips Alaska, Inc. Permit to Drill Number: 223-073 Surface Location: 114' FSL, 554' FWL, Sec 27, T11N, R8E, UM Bottomhole Location: 941'FNL, 980'FEL, SEC 34, T11N, R8E, UM Dear Mr. Brillon: 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. 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 October 2023. . Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.10.04 09:49:32 -08'00' 4 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: 7645'TVD:6173' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2560 1329' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 146' 15. Distance to Nearest Well Open Surface: x- 487859 y- 5948986 Zone-4 105' to Same Pool:25' @ 425'MD 16. Deviated wells: Kickoff depth: 6550' feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 35.04 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 24" 16" 62.58 H-40 Weld 79' Surface Surface 121' 121' 12.25" 9-5/8" 47 L-80 BTCABMOD 3104' Surface Surface 3146' 2792' 8.5" 7" 26 J-55 BTC MOD 7397' Surface Surface 7436' 6349' 3-1/2" 9.3 L-80 EUE 8rd 6508' Surface Surface 6550' 5482' 6-1/8" 3-1/2" 9.3 L-80 HYD563 7645 7645 6173 7645' 6173' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): 7130' TVD 121' 2792' 6348' 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: Elliott Tuttle Elliott Tuttle Contact Email:elliott.tuttle@conocophillips.com RWO/CTD Drilling Engineer Contact Phone:907-263-4742 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 121' 3146'9-5/8" 613 SX PFE, 483 SX Class G Effect. Depth MD (ft): MD Plugs (measured): Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 3104' 220 SX ASIConductor/Structural 16"79' 7450'6360' LengthCasing None Cement VolumeSize Authorized Title: Authorized Signature: 206 SX Class GProduction 7397' Authorized Name: 7070-7079' 7103-7112' 7122-7137' 7156-7182' (including stage data) 7130' 136 sx of 15.8ppg Class G 18. Casing Program: Top - Setting Depth - BottomSpecifications 4138psi Cement Quantity, c.f. or sacks Total Depth MD (ft): Total Depth TVD (ft): 5952180 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 3535psi 1032' FNL, 1349'FEL, SEC 34, T11N, R8E, UM 941'FNL, 980'FEL, SEC 34, T11N, R8E, UM ALK 2672 P.O. Box 100360 Anchorage, AK 99510 ConocoPhillips Alaska, Inc. 114' FSL, 554' FWL, Sec 27, T11N, R8E, UM ADL 0025586 KRU 2M-24A Kuparuk River Field/ Kuparuk River Oil Pool 6040-6048' 6068-6075' 6084-6096' 6112-6134' Commission Use Only See cover letter for other requirements. 7436'7" 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) 13. Approximate Spud Date: 9/15/2023 Effect. Depth TVD (ft): 6090' /1 By Grace Christianson at 2:52 pm, Aug 07, 2023 6500 6319' 50-103-20171-01-00 5567 A.Dewhurst 29 AUG 2023 BOP test to 4000 psig Annular preventer to 2500 psig X 63195567 DSR-8/7/23 488394 55.6 A.Dewhurst 11SEP2023 6181 VTL 9/21/2023 223-073 258 sx *&:JLC 10/4/2023 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.10.04 09:50:05 -08'00' 10/4/23 10/4/23 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 August 7, 2023 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill 2M-24A Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore, slot recovery to reacquire the Kuparuk formation, sidetracking out of the existing 2M-24 well, from the existing 2M pad in Kuparuk. The intended spud date for this well is 9/15/2023. It is intended that Nabors 7ES be used to drill the well. 2M-24A will sidetrack out of the existing 7” intermediate casing in the 2M-24 wellbore. A 6-1/8” hole will be drilled to the planned TD, and a 3-1/2” liner will be run and cemented back into the 7” casing, with the top planned 700’MD or 460’TVD above the top of the Kuparuk resevoir. The well will be completed as a fracture stimulated Producer with a single stage frac job planned in the A Sand, Kuparuk formation. A frac sundry will follow this PTD. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a) 2. A proposed drilling program 3. A proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035 (d)(2) 6. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Elliott Tuttle at 907-252- 3347(Elliott.tuttle@conocophillips.com) or Jonathan Coberly at 265-1013. Sincerely, Elliott Tuttle Drilling Engineer Application for Permit to Drill, «Well_Name» Saved: 1-Aug-23 3S-24B APD Page 1 of 7 Printed: 1-Aug-23 2M-24A Application for Permit to Drill Document Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (f)) ........................................................... 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) ......................................... 2 3. Proposed Drilling Program ...................................................................................... 3 4. Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) ................................................................................................................................... 4 5. MASP Calculations ................................................................................................... 4 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) ............................................................................................................... 5 7. Casing and Cementing Program ............................................................................. 5 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) .................................... 5 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) ................................................................................................................................... 6 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) .......................................... 6 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) ......................... 6 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) ................................... 6 13. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 (Requirements of 20 AAC 25.005 (c)(14)) ............................................................................. 6 14. Drilling Hazards Summary ....................................................................................... 6 15. Proposed Completion Schematic ........................................................................... 8 Application for Permit to Drill, «Well_Name» Saved: 1-Aug-23 3S-24B APD Page 2 of 7 Printed: 1-Aug-23 1. Well Name (Requirements of 20 AAC 25.005 (f)) The well for which this application is submitted will be designated as 2M-24A 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) Location at Surface 114‘ FSL, 554‘ FWL, SEC 27, T11N, R8E, UM NAD 1927 Northings: 5948986 Eastings: 487859 RKB Elevation 146’ AMSL Pad Elevation 105’ AMSL Location at Sidetrack KOP 1030‘ FNL, 1786‘ FEL, SEC 34, T11N, R8E, UM NAD 1927 Northings: 5947838 Eastings: 491335 Measured Depth, RKB:6550’ Total Vertical Depth, RKB:5608’ Total Vertical Depth, SS:5462’ Top of Productive Horizon 1032‘ FNL, 1349‘ FEL, SEC 34, T11N, R8E, UM NAD 1927 Northings: 5947835 Eastings: 491771 Measured Depth, RKB:7164’ Total Vertical Depth, RKB:6026’ Total Vertical Depth, SS:5880’ Total Depth 941‘ FNL, 980‘ FEL, SEC 34, T11N, R8E, UM NAD 1927 Northings: 5947926 Eastings: 492140 Measured Depth, RKB:7645’ Total Vertical Depth, RKB:6319’ Total Vertical Depth, SS:6173’ 6172 A.Dewhurst 29 AUG 2023 6465 5608 6026 6319 5754 Application for Permit to Drill, «Well_Name» Saved: 1-Aug-23 3S-24B APD Page 3 of 7 Printed: 1-Aug-23 3. Proposed Drilling Program The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. Completed Pre-Rig Work 1. Pull 2 ea. Patches straddling tubing leaks (1,789’- 1818’ and 6876’-6904’) – Completed 6/26/23 2. Tubing punch below packer for injectivity test, Injectivity Failed – 6/29/23 3. T-PPPOT (Passed) and T-POT tests (passed). IC-POT failed 7/18/2023 Remaining Pre-Rig Work 4. Suspend well based on separate state approved sundry (323-385) a. Tag top of cement @ ~6600’ MD 5. Dummy off GLMs 1,2,4 and leave station 7 open 6. Perform tubing cut at 6565’ MD Rig Work MIRU 1. MIRU Nabors 7ES on 2M-24. Circulate well over to 8.5ppg seawater. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30- minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/3,500 psi. Test annular 250/3,500 psi. Retrieve Tubing, Grow PC, Set whipstock 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to cut (~6565’ RKB). a. Grow and stretch of 7” production casing: set plug/ storm packer near surface, pressure test plug. ND to casing head and let grow, pull 7” casing and re-land slips and PO, nipple up new tubing spool and BOP’s, test flange break and IC packoffs. b. Continue to lay down tubing 6. Set Whipstock at 6550’ TOWS oriented high side. 1. Mill window in 7” casing. 2. Drill 6-1/8” hole to TD, 250’ RKB below base of Kuparuk formation. 3. Circulate hole clean and pull out of hole with drilling BHA. 4. Run 3.5” liner TD. 5. Cement liner, bringing cement above liner top. Set liner top hanger/packer and circulate cement out of hole from above top of liner. 6. Perform pressure test on 7” casing / 3-1/2” liner to 2000 psi (to ensure no casing integrity issues were caused during drilling/liner running). a. If pressure test does not pass, run 5-1/2” tie-back string and re-test. 7. Run 3.5” gas lift upper completion 8. Pressure test hanger seals to 5,000 psi. Application for Permit to Drill, «Well_Name» Saved: 1-Aug-23 3S-24B APD Page 4 of 7 Printed: 1-Aug-23 9. Test tubing to 3050 psi, chart test. 10. Test IA to 3,300 psi, chart test. Drop tubing pressure and shear SOV. 11. Install BPV and test to 1000 psi in the direction of flow. 12. Nipple down BOP. 13. Install tubing head adapter assembly. N/U tree and test to 5000 psi/10 minutes. 14. Freeze protect down annulus through SOV, RU TxIA cross, let u-tube. 15. Secure well. Rig down and move out. 4. Diverter and Blowout Prevention Equipment (Requirements of 20 AAC 25.005(c)(7)) Please reference BOP schematics on file for Nabors 7ES. As this well is a sidetrack below the surface casing, no diverter will be used. 5. MASP Calculations The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size (in) Casing/Window Depth MD/TVD(ft) Fracture Gradient (ppg) Pore pressure (psi) ASP Drilling (psi) EMW 7 6550 / 5608 16.5 2945 1977 11.5 3.5 7645 / 6319 15 4138 2124 13.5 PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]*D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP – (0.1 x D) Where: FPP = Formation Pore Pressure at the next casing point FPP = 0.4525 x TVD 1. ASP CALCULATIONS Drilling 6-1/8” hole out of 7” intermediate casing ASP = [(FG x 0.052) – 0.1] D Application for Permit to Drill, «Well_Name» Saved: 1-Aug-23 3S-24B APD Page 5 of 7 Printed: 1-Aug-23 = [(16.5 x 0.052) – 0.1] x 5608 = 4251 psi OR ASP = FPP – (0.1 x D) = 2538 – (0.1 x 5608) = 1977 psi Drilling 6-1/8” hole to top of Reservoir ASP = [(FG x 0.052) – 0.1] D = [(15 x 0.052) – 0.1] x 6026 = 4098 psi OR ASP = FPP – (0.1 x D) = 2727 – (0.1 x 6026) = 2124 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Drilling Hazards Summary 6. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005 ©(5)) LOT to 16.0 ppg was performed on the intermediate casing shoe, 5806’ TVD when drilling 2M-40 which is a neighboring well. No FIT/LOT is planned as part of this sidetrack. 7. Casing and Cementing Program Casing and Cementing Program Csg/Tbg OD (in) Hole Size (in) Weight (lb/ft) Grade Conn. Cement Program 3.5 6.125 9.3 L-80 Hyd563 Cemented liner – 5.5” OD Centralizers planned Cementing Calculations 3-1/2” production liner run to 7645’ MD / 6319’ TVD Top of slurry is designed to be at ~6500’ MD, the top of the 3-1/2” liner, which is 664’MD / 459’ TVD above the top of the Kuparuk interval. Assume 20% excess annular volume. Tail slurry from 7645’ MD to 6500’ MD with 15.8 ppg Class G + Add's Total Volume = 158ft3 => 136 sx of 15.8 ppg Class G + Add's @ 1.16 ft3/sk 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) see attached revised cement calculations VTL 9/20/2023 Application for Permit to Drill, «Well_Name» Saved: 1-Aug-23 3S-24B APD Page 6 of 7 Printed: 1-Aug-23 Production Hole Size in. 6.125 Casing Size in. 3.5 Density PPG 11.5-13.5 PV cP 10 YP lb./100 ft2 10 - 15 Funnel Viscosity s/qt. 40 - 50 Initial Gels lb./100 ft2 6 10 Minute Gels lb./100 ft2 8 API Fluid Loss cc/30 min. 4.0 HPHT Fluid Loss cc/30 min. 10.0 pH 9.0 – 9.5 The interval will be drilled with a water-based mud (LSND) weighted to 11.5-13.5 ppg. Fluid hydraulic modeling has been performed. Diagram of Nabors 7ES Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) N/A – No abnormally pressured formations expected 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) N/A – No seismic to be performed, drilling in well developed area. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A - Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well 2M-24A will be injected into a permitted annulus on 1B pad. 14. Drilling Hazards Summary Kuparuk (target) Formation expected to be overpressured. Anticipating 4146 psi at top of Kuparuk at 7188' MD, 6040' TVD. Equivalent to 13.2 ppg. -A.Dewhurst 12 SEP 2023 Application for Permit to Drill, «Well_Name» Saved: 1-Aug-23 3S-24B APD Page 7 of 7 Printed: 1-Aug-23 (To be posted in Rig Floor Doghouse Prior to Spud) 6.125” Hole / 3.5” Liner - Slant Production Hole Event Risk Level Mitigation Strategy Lost circulation high Reduce pump rates, reduce trip speeds, real time ECD monitoring, mud rheology, add lost circulation material Hole swabbing on trips Low Reduce trip speeds, condition mud properties, proper hole filling, pump out of hole, real time ECD monitoring Abnormal Reservoir Pressure Low Well control drills, check for flow during connections, increased mud weight Differential Sticking Low Keep pipe moving, control mud weight Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Well Proximity Risks: No collision risks exist in the planned 2M-24A wellbore. Directional drilling / collision avoidance information as required by AOGCC 20 ACC 25.050 (b) is provided in the following attachments. Drilling Area Risks: Lost returns are possible if weaker than expected formations or stringers are encountered. LCM material will be available to seal in losses if needed. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Application for Permit to Drill, «Well_Name» Saved: 1-Aug-23 3S-24B APD Page 8 of 7 Printed: 1-Aug-23 15. Proposed Completion Schematic 5608'6181' ! "#$% & '( % ) * '( +, $ & - $ . #/& !"#$ %&'+0# . ()* $1 !"#$ %&'# . +# #* , -, # " . +# # .#.)#* # % $ 2 /0 2 / 1 "# & & 1 #1 , 3 & 1#1,// 2%3 # ' (2%()4()4(,/' +# #* , -5( / 5, / 6 " / 7 * , $ , $ & 41 - - & ) " 5& +# # &"!" #$ #$ #$ 8 &529529&!92 959&2!& " ": ;9!&9( &":&;&<!9 2 2 & - - 5& " 6572 6"7 & ) - % 2 5 % "!" "!" 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"&!"" 5<2&!" 5& ! 5"22!2 <5& !" / 7/&!""C49"!"" 5 &!" 5<2!" 5"&!< <5!2 &!"" 6521 7000 7000 7200 7200 7400 7400 7645 2M-24A wp01 Plan Summary 2M-24A RST Project 2M-15 2M-16 2M-17 2M-18 2M-19 2M-20 2M-21L1 2M-22 2M-22L12M-22L1PB1 2M-23 2M-24 2M-25 2M-26 2M-31 2M-38 2M-41 0 9 Do g l e g S e v e r i t y 6600 6800 7000 7200 7400 7600 Measured Depth 3-1/2" Production Liner 50 50 100 100 0 90 180 270 30 210 60 240 120 300 150 330 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Travelling Cylinder Separation [100 usft/in] 2M-24 5250 6000 Tr u e V e r t i c a l D e p t h 2850 3000 3150 3300 3450 3600 3750 3900 Vertical Section at 90.00° 2M-24 2M-24A wp01 0 150 300 Ce n t r e t o C e n t r e S e p a r a t i o n 6625 6750 6875 7000 7125 7250 7375 Measured Depth 2M-24 Equivalent Magnetic Distance DDI 5.720 SURVEY PROGRAM Date: 2023-03-06T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 148.00 6521.10 2M-24 Srvy 1 - SLB_GCT-MS (2M-24)GCT-MS 6521.10 7645.00 2M-24A wp01 (2M-24A RST Project) GCT-MS Surface Location North / 5948985.76 East / 488394.29Ground / 104.90 CASING DETAILS TVD MD Name 5608.20 6550.00 3-1/2" Production Liner Mag Model & Date: BGGM2023 01-Aug-23 Magnetic North is 14.46° East of True North (Magnetic Declination) Mag Dip & Field Strength: 80.57° 57231.16105662nT SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Annotation 1 6521.10 35.05 109.09 5584.54 -1138.30 2926.66 0.00 0.00 2926.66 Start DLS 0.30 TFO -96.68 2 6550.00 35.04 108.94 5608.20 -1143.71 2942.35 0.30 -96.68 2942.35 Start DLS 13.00 TFO -30.00 3 6586.00 39.15 105.24 5636.91 -1150.05 2963.10 13.00 -30.00 2963.10 Start DLS 2.00 TFO -30.00 4 6725.00 41.58 103.14 5742.81 -1172.08 3050.38 2.00 -30.00 3050.38 Start DLS 7.00 TFO -65.00 5 7075.00 55.64 76.06 5976.04 -1163.55 3307.63 7.00 -65.00 3307.63 Start 320.00 hold at 7075.00 MD 6 7395.00 55.64 76.06 6156.63 -1099.90 3564.02 0.00 0.00 3564.02 Start DLS 5.00 TFO 180.00 7 7645.00 43.14 76.06 6319.03 -1054.27 3747.86 5.00 180.00 3747.86 TD at 7645.00 FORMATION TOP DETAILS TVDPath Formation 5850.54 Top Kalubik 5875.51 Top HRZ 6026.27 Top Reservoir 6071.98 A4 Top Perf 6083.27 A4 Btm Perf 6100.76 A3 Top Perf 6120.52 A3 Btm Perf 6196.04 Btm Reservoir By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured it's completeness, and all surroundingwells are assigned to the proper position, and I approve the scan and collision avoidance plan as set out in the audit pack.I approve it as the basiis for the final well plan and wellsite drawings. I also acknowledge that unless notified otherwise all targets have a 100 feet lateral tolerance. 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B ? @# ??B ??B ?? @# !B !B ! @ &B &B & @ B B @# 6 . 5 . 3 / 1 Dewhurst, Andrew D (OGC) From:Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Sent:Thursday, September 7, 2023 08:05 To:Dewhurst, Andrew D (OGC) Cc:Loepp, Victoria T (OGC); Roby, David S (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Taylor, Jenna Subject:RE: [EXTERNAL]KRU 2M-24A (PTD 223-073) - Questions Andrew, TheEMWvaluesIlistedinthattablewasthemudweightsIplantouseinthegivensecƟonandaŌerreviewshouldn’t belistedinthatsecƟon.TheŇuidgradientwasfromastopcountduringtheSBHPsoitdoescalculateouttobe13.2 downtothereservoir. EverythinglooksgoodforcorrecƟonexceptforthe7”TVD,notsurewhythatonewascorrectedonournewsubmission. ThesoŌwareJennaandIusewasmigraƟngtoanewURLwhilecreaƟngthisPTDwhichcausedissueswithMDtoTVD conversions.Iapologizeforthediscrepancies. Regards, ElliottTuttle|CTD/RWODrillingEngineer|ConocoPhillips O:907.263.4742|C:907.252.3347|Desk:668 From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Sent:Tuesday,September5,202311:29AM To:Tuttle,Elliott<Elliott.Tuttle@conocophillips.com> Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>;Davies,Stephen F(OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Taylor,Jenna <Jenna.L.Taylor@conocophillips.com> Subject:RE:[EXTERNAL]KRU2MͲ24A(PTD223Ͳ073)ͲQuestions EllioƩ, ThanksforthisinformaƟon. x IdidseeoneaddiƟonalTVDcorrecƟon.PleaseconĮrmthattheboƩomdepthofthe7”casingat7,436’MD shouldbe6,181’TVD. x Also,I’msƟllseeingadiscrepancyinSecƟon5regardingtheexpectedporepressure(psi)andEMW: You don't often get email from elliott.tuttle@conocophillips.com. Learn why this is important 2 For5608’TVDand2945psi,I’mcalculaƟnganEMWof10.11PPG;for6319’TVDand4138,I’mcalculaƟngan EMWof12.61PPG. Also,youmenƟonedinyourlastemail3887psiat5567’TVD.I’mcalculaƟngthatasagradientof0.698psi/Ō (13.44PPG). Wouldyoutakealookatthesenumbersanddoublecheckmyvalues? x ThefastestandeasiestwayisformetoedittheoriginalPTDdocumentwiththecorrectvalues.Wouldyou pleaseconĮrmthatIhavedonesobyreviewingthescreenshotsbelow? From:Tuttle,Elliott<Elliott.Tuttle@conocophillips.com> Sent:Friday,August25,202313:58 To:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>;Davies,Stephen F(OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov>;Taylor,Jenna <Jenna.L.Taylor@conocophillips.com> Subject:RE:[EXTERNAL]KRU2MͲ24A(PTD223Ͳ073)ͲQuestions 3 Andrew, FortheKOP,weareplanninga11.5ppgLSNDtoaidinholdingtheHRZback,butitispredictedtobenormally pressured.ThatweightshouldbeadequateinholdingtheHRZbackfromcollapseandallowustogetdepartureand steeradequatelyfortarget.Wewillthenweightuptoa13.5ppgLSNDpriortoenteringtheKuparukAsandduetoa recentSBHPtakenfromtheparentbore,2MͲ24: Pressure3887psi@6500'RKB(5567'TVD) FluidGradienttoreservoirattime:.548 6040'TVDTopofReservoir=4146psi =13.2ppgEMW PleaseseeaƩachednew10Ͳ401withsignatureandboxeschangedasrequested,thankyouforyourthoroughreview.A correcƟonneededtobemadeonplansummary,page4oftheaƩached;theTVDandTVDSSwasmiscalculatedbuthas beencorrectedonthissubmission. Thankyou, ElliottTuttle|CTD/RWODrillingEngineer|ConocoPhillips O:907.263.4742|C:907.252.3347|Desk:668 From:Dewhurst,AndrewD(OGC)<andrew.dewhurst@alaska.gov> Sent:Monday,August21,20232:10PM To:Tuttle,Elliott<Elliott.Tuttle@conocophillips.com> Cc:Loepp,VictoriaT(OGC)<victoria.loepp@alaska.gov>;Roby,DavidS(OGC)<dave.roby@alaska.gov>;Davies,Stephen F(OGC)<steve.davies@alaska.gov>;Guhl,MeredithD(OGC)<meredith.guhl@alaska.gov> Subject:[EXTERNAL]KRU2MͲ24A(PTD223Ͳ073)ͲQuestions CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. EllioƩ, IamcompleƟngthereviewoftheKRU2MͲ24APTDandhaveacouplequesƟons: x WouldyouconĮrm(orprovideupdatedvaluesfor)thebelowcorrecƟonsinboldonthe401form: o Box1a:TypeofWork=Redrill o Box4b:x=488394(the401formshows487859;direcƟonalplanshows488394) o Box6:TVD=6319’ o Box16:MaximumHoleAngle=55.6degrees You don't often get email from elliott.tuttle@conocophillips.com. Learn why this is important 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. 4 o Box18:TopSeƫngDepthfor3.5”tubing(HYD563)=6500’MD x WouldyoupleaseconĮrmthepredictedporepressuresandEMWcalculaƟonsattheKOPandTDinSecƟon5? Thanks, Andy AndrewDewhurst SeniorPetroleumGeologist AlaskaOilandGasConservaƟonCommission 333W.7thAve,Anchorage,AK99501 andrew.dewhurst@alaska.gov Direct:(907)793Ͳ1245 CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyaƩachments,containsinformaƟonfromtheAlaskaOilandGasConservaƟon Commission(AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).ItmaycontainconĮdenƟaland/orprivilegedinformaƟon. Theunauthorizedreview,useordisclosureofsuchinformaƟonmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail, pleasedeleteit,withoutĮrstsavingorforwardingit,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactAndrewDewhurst at907Ͳ793Ͳ1245orandrew.dewhurst@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. From:Tuttle, Elliott To:Loepp, Victoria T (OGC) Cc:Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL]KRU 2M-24A(PTD 223-073) BOP test pressure Date:Monday, September 18, 2023 3:05:46 PM Victoria, This was an oversight, I was waiting for the updated SBHP expecting it to be lower with 3 total injectors in this fault block shut in but it came in at or slightly higher than previous. The program I am currently writing states 4000psi BOP test pressure with 3500psi annular. Regards, Elliott Tuttle | CTD/ RWO Drilling Engineer | ConocoPhillips O: 907.263.4742| C: 907.252.3347 | Desk: 668 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, September 18, 2023 11:16 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]KRU 2M-24A(PTD 223-073) BOP test pressure CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Elliot, Why are you proposing testing the BOPs to 3500 psig with a 3535 psig MPSP? Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 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:Tuttle, Elliott To:Loepp, Victoria T (OGC) Cc:Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL]RE: KRU 2M-24A(PTD 223-073) Outside 7" Cement Date:Monday, September 18, 2023 2:42:16 PM Victoria, Working with Halliburton cementing on plan, they are recommending a 15.3ppg blend now with a 30% excess, numbers look like this: Top Btm ID OD Volume (ID^2-OD^2)/1029.4 LT to TOWS 6500 6550 6.276 3.5 1.32 TOWS to TD 6550 7645 6.125 3.5 34.94 *30% excess Shoetrack (90')7555 7645 2.992 1.02 37.27 Bbls 209.28 Bbls to Ft^3 169.28 Yield 1.2362 sacks / ft^3 Thank you, Elliott Tuttle | CTD/ RWO Drilling Engineer | ConocoPhillips O: 907.263.4742| C: 907.252.3347 | Desk: 668 From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov> Sent: Monday, September 18, 2023 10:55 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL]RE: KRU 2M-24A(PTD 223-073) Outside 7" Cement CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Elliot, Please look at the cement calculation for production liner. Your calculation states an assumption of 20% excess however my calculations indicate 0% excess. Please provide calculation. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 From: Loepp, Victoria T (OGC) Sent: Monday, September 18, 2023 9:14 AM To: Tuttle, Elliott <Elliott.Tuttle@conocophillips.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: KRU 2M-24A(PTD 223-073) Outside 7" Cement Elliot, Please provide cementing information for outside the 7”. Was a cement evaluation log run? What was TOC from log or calculated? Specifically at location of window. What is current timing for commencement of operations. Thank you, Victoria Victoria Loepp Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Work: (907)793-1247 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. KRU 2M-24A 223-073 KUPARUK RIVER KUPARUK RIV OIL X W E L L P E R M I T C H E C K L I S T Co m p a n y Co n o c o P h i l l i p s A l a s k a , I n c . We l l N a m e : KU P A R U K R I V U N I T 2 M - 2 4 A In i t i a l C l a s s / T y p e DE V / P E N D Ge o A r e a 89 0 Un i t On / O f f S h o r e On Pr o g r a m DE V Fi e l d & P o o l We l l b o r e s e g An n u l a r D i s p o s a l PT D # : 22 3 0 7 3 0 KU P A R U K R I V E R , K U P A R U K R I V O I L - 4 9 0 1 0 0 NA 1 Pe r m i t f e e a t t a c h e d Ye s En t i r e l y i n A D L 0 0 2 5 5 8 6 2 Le a s e n u m b e r a p p r o p r i a t e Ye s 3 Un i q u e w e l l n a m e a n d n u m b e r Ye s KU P A R U K R I V E R , K U P A R U K R I V O I L – 4 9 0 1 0 0 , g o v e r n e d b y C O 4 3 2 E . 4 We l l l o c a t e d i n a d e f i n e d p o o l Ye s 5 We l l l o c a t e d p r o p e r d i s t a n c e f r o m d r i l l i n g u n i t b o u n d a r y NA 6 We l l l o c a t e d p r o p e r d i s t a n c e f r o m o t h e r w e l l s Ye s 7 Su f f i c i e n t a c r e a g e a v a i l a b l e i n d r i l l i n g u n i t Ye s 8 If d e v i a t e d , i s w e l l b o r e p l a t i n c l u d e d Ye s 9 Op e r a t o r o n l y a f f e c t e d p a r t y Ye s 10 Op e r a t o r h a s a p p r o p r i a t e b o n d i n f o r c e Ye s 11 Pe r m i t c a n b e i s s u e d w i t h o u t c o n s e r v a t i o n o r d e r Ye s 12 Pe r m i t c a n b e i s s u e d w i t h o u t a d m i n i s t r a t i v e a p p r o v a l Ye s 13 Ca n p e r m i t b e a p p r o v e d b e f o r e 1 5 - d a y w a i t NA 14 We l l l o c a t e d w i t h i n a r e a a n d s t r a t a a u t h o r i z e d b y I n j e c t i o n O r d e r # ( p u t I O # i n c o m m e n t s ) ( F o r NA 15 Al l w e l l s w i t h i n 1 / 4 m i l e a r e a o f r e v i e w i d e n t i f i e d ( F o r s e r v i c e w e l l o n l y ) NA 16 Pr e - p r o d u c e d i n j e c t o r : d u r a t i o n o f p r e - p r o d u c t i o n l e s s t h a n 3 m o n t h s ( F o r s e r v i c e w e l l o n l y ) NA 17 No n c o n v e n . g a s c o n f o r m s t o A S 3 1 . 0 5 . 0 3 0 ( j . 1 . A ) , ( j . 2 . A - D ) NA 18 Co n d u c t o r s t r i n g p r o v i d e d NA 19 Su r f a c e c a s i n g p r o t e c t s a l l k n o w n U S D W s NA 20 CM T v o l a d e q u a t e t o c i r c u l a t e o n c o n d u c t o r & s u r f c s g NA 21 CM T v o l a d e q u a t e t o t i e - i n l o n g s t r i n g t o s u r f c s g Ye s We l l c o m p l e t e d w i t h c e m e n t e d p r o d u c t i o n l i n e r 22 CM T w i l l c o v e r a l l k n o w n p r o d u c t i v e h o r i z o n s Ye s 23 Ca s i n g d e s i g n s a d e q u a t e f o r C , T , B & p e r m a f r o s t Ye s 24 Ad e q u a t e t a n k a g e o r r e s e r v e p i t Ye s KR U 2 M - 2 4 ( P T D 1 9 2 - 0 5 0 , S u n d r y 3 2 3 - 4 4 7 ) 25 If a r e - d r i l l , h a s a 1 0 - 4 0 3 f o r a b a n d o n m e n t b e e n a p p r o v e d Ye s An t i - c o l l i s i o n a n a l y s i s c o m p l e t e ; n o m a j o r r i s k f a i l u r e s 26 Ad e q u a t e w e l l b o r e s e p a r a t i o n p r o p o s e d NA 27 If d i v e r t e r r e q u i r e d , d o e s i t m e e t r e g u l a t i o n s Ye s Ma x r e s e r v o i r p r e s s u r e i s 4 1 3 8 p s i g ( 1 2 . 5 p p g E M W ) ; w i l l d r i l l w / 1 1 . 5 - 1 3 . 5 p p g E M W 28 Dr i l l i n g f l u i d p r o g r a m s c h e m a t i c & e q u i p l i s t a d e q u a t e Ye s 29 BO P E s , d o t h e y m e e t r e g u l a t i o n Ye s MP S P i s 3 5 3 5 p s i g ; w i l l t e s t B O P s t o 4 0 0 0 p s i g 30 BO P E p r e s s r a t i n g a p p r o p r i a t e ; t e s t t o ( p u t p s i g i n c o m m e n t s ) Ye s 31 Ch o k e m a n i f o l d c o m p l i e s w / A P I R P - 5 3 ( M a y 8 4 ) Ye s 32 Wo r k w i l l o c c u r w i t h o u t o p e r a t i o n s h u t d o w n Ye s H2 S m e a s u r e s r e q u i r e d 33 Is p r e s e n c e o f H 2 S g a s p r o b a b l e NA 34 Me c h a n i c a l c o n d i t i o n o f w e l l s w i t h i n A O R v e r i f i e d ( F o r s e r v i c e w e l l o n l y ) No We l l s o n 2 M - P a d a r e H 2 S - b e a r i n g . H 2 S m e a s u r e s r e q u i r e d . 35 Pe r m i t c a n b e i s s u e d w / o h y d r o g e n s u l f i d e m e a s u r e s Ye s An t i c i p a t i n g 1 3 . 2 p p g E M W a t t a r g e t K u p a r u k F o r m a t i o n . 36 Da t a p r e s e n t e d o n p o t e n t i a l o v e r p r e s s u r e z o n e s NA 37 Se i s m i c a n a l y s i s o f s h a l l o w g a s z o n e s NA 38 Se a b e d c o n d i t i o n s u r v e y ( i f o f f - s h o r e ) NA 39 Co n t a c t n a m e / p h o n e f o r w e e k l y p r o g r e s s r e p o r t s [ e x p l o r a t o r y o n l y ] Ap p r AD D Da t e 8/ 2 1 / 2 0 2 3 Ap p r VT L Da t e 9/ 2 1 / 2 0 2 3 Ap p r AD D Da t e 9/ 1 2 / 2 0 2 3 Ad m i n i s t r a t i o n En g i n e e r i n g Ge o l o g y Ge o l o g i c Co m m i s s i o n e r : Da t e : En g i n e e r i n g Co m m i s s i o n e r : Da t e Pu b l i c Co m m i s s i o n e r Da t e *& : JL C 1 0 / 4 / 2 0 2 3