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Home My WebLink About225-0087. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU D-03B Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 225-008 50-029-20057-03-00 13094 Intermediate Intermediate Liner Liner 8856 4412 9903 731 3908 12802 13-3/8" 10-3/4" x 9-5/8" 3-1/4" 2-3/8" 8962 18 - 4430 16 - 9919 9286 - 10017 9022 - 12930 18 - 4204 16 - 8389 7832 - 8481 7600 - 8916 None 1540 2480 11780 12802 3090 5210 11200 11974 - 12869 4-1/2" 12.6# x 5-1/2" 17# 13cr80, L80 14 - 9919 9014 - 8938 Surface 2269 20" 20 - 2289 20 - 2289 1530 520 4-1/2" Baker S-3 Perm Packer 9213 7767 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907-564-5026 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028285 14 - 8389 N/A N/A 225 304 19758 6837 225 304 600 350 720 200 325-387 13b. Pools active after work:Prudhoe Oil No SSSV Installed 9213, 7767 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 10:50 am, Aug 18, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.18 09:48:00 - 08'00' Torin Roschinger (4662) DSR-9/11/25 RBDMS JSB 082125 J.Lau 11/4/25 ACTIVITY DATE SUMMARY 8/1/2025 LRS CT #1 1.50" CT 0.134" WT HT-110 Job Scope = Drift, log, Set CIBP Ext perf MIRU Function test BOP. MU NS CTC/MHA and LRS MBT w/ 1.76" DJN. Load the well with KCL. Test H2S/LEL alarms. Drift to 12919 CTM. POOH. RIH w/ HES 1.69" gamma/ccl logging tools, begin logging from 12910'. Paint depth correlation flag at 12741.55. Continue logging. ***Job in Progress*** ***Test H2S/LEL monitors and place in wellhouse, Bump test CTC against stripper brass 10k, PT 1.5" safety joint/TIW 290/4152psi*** 8/2/2025 LRS CTU #1 1.50"CT 0.134"WT HT-110 Job Objective. Drift, Log, Set CIBP, Ext Ad Perf Continue HES gamma/ccl log up to 8950'. Top fill CTBS w/ 1%KCL w/ safelube while POOH. Confirm no-flow at surface, close laterals on flowline, de-pressurize S-riser, laterals leaking. Grease S-riser and wing, bleed S-riser again. RIH w/ NS 2-3/8" CIBP, correct depth to COE at the flag. Set CIBP 12802' COE. Flagged coil red at 11975 MD (11959.36' EOP) Performed no flow checks at surface, ~2 bbl/hr losses. MU swivel and pressure tested to 3500 psi. Performed safety deployment drill. MU 5 - 6 SPF Millinnium guns. MU coil to gun. RIH. At the flag correlated to top shot depth of 11965.21'. RIH past shot depth, PUH to 11974' top shot depth.Pumped 1/2" ball. Shoot 11974-12080'. POOH Stop at 180' and wait for HES TCP. Perform no flow check, ~ 2 bb/hr loss rate. Circulate across the tree, keep the hole full and monitor the trip tankl. HES arrived on location, perform 10 min no-flow check. Hold well control drill w/ night crew, confirm shots fired and begin retrieving perf guns. ***In Progress*** ***Verify fit of XO from safety joint to perf guns, Conduct well control drill w/ day and night shift for taking a kick while deploying / retrieving perf guns, review open hole ops standing orders*** 8/3/2025 LRS CTU #1 0.175"CT 0.134"WT HT-110 Job Objective: Drift, Log, Set CIBP, Ext Ad Perf Finish retrieving all spent perf guns, all guns in scallops. RDMO. ***Job Complete*** Daily Report of Well Operations PBU D-03B 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU D-03B Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 225-008 50-029-20057-03-00 341J ADL 0028285 13094 Intermediate Intermediate Liner Liner 8856 4412 9902 731 3908 12914 13-3/8" 10-3/4" x 9-5/8" 3-1/4" 2-3/8" 8922 18 - 4430 16 - 9918 9286 - 10017 9022 - 12930 2420 18 - 4204 16 - 8388 7832 - 8481 7600 - 8916 None 1540 2480 11780 None 3090 5210 11200 12180 - 12869 4-1/2" 12.6# x 5-1/2" 17# 13cr80, L80 14 - 99199015 - 8938 Surface 2269 20" 20 - 2289 20 - 2289 1530 520 4-1/2" Baker S-3 Perm Packer No SSSV Installed 9213, 7767 Date: Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY 7/10/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-387 By Gavin Gluyas at 3:22 pm, Jun 26, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.06.26 15:07:19 - 08'00' Torin Roschinger (4662) JJL 6/27/25 Perforating gun BHA not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead before breaking containment 10-404 A.Dewhurst 07JUL25 DSR-6/30/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.08 08:56:50 -08'00'07/08/25 RBDMS JSB 070925 CCT Extended Perforating Well:D-03B Page 11 of 111 Well Name: D-03B AAPI Number: 50-029-20057-03 Current Status: Operable producer, offline PPad: D-Pad Estimated Start Date: 07/10/2025 RRig: Coil Reg. Approval Req’d? 10-403/10-404 DDate Reg. Approval Rec’vd: TBD Regulatory Contact: Abbie Barker PPermit to Drill Number: 225-008 First Call Engineer Finn Oestgaard CContact: 907-350-8420 (C) Second Call Engineer Leif Knatterud CContact: 432-227-4342 (C) Current Bottom Hole Pressure: 3300 psi @ 8,800’ TVDss Estimated based on average Ivishak Pressure KWF: 7.3 ppg Use seawater or 1% KCL MPSP: 2420 psi (BHP - 0.1psi/ft gas gradient) Max Dev: 112 deg 13,094’ MD Min ID: 1.920” 9,047’ MD Tie In Log Baker Hughes RPM – 5/1/2025 Last SIWHP 2300 psi - Estimated Brief Well Summary: D-03B is a U-shaped coil sidetrack with 2-3/8” liner drilled in May 2025. The well was initially perf’d in zone 2B with 11’ of perfs. Initial rates came on at 233 bopd. After 5 days of production the oil rate had decreased to 108 bopd prompting an adperf to increase productivity. The original perfs were reperfed and additional footage was added, initial rates were 408 bopd, however it has since flattened out at 216 bopd and is approaching field marginal GORs with a gas rate of 18 million scfd. It has been decided by the subsurface team to set a plug over the toe up where the gas is suspected to be coming from and pursue the next stage of perfs. Objective: Set CIBP & Perforate 106’ Z2A. Procedure: Coiled Tubing –Drift/Tie-In & Plugset 1. MU Tie-In/Drift BHA (configuration per WSL discretion), RIH and flag for plug set (target set depth 12,802’) and perforations. Contact Finn Oestgaard & Jeff Nelson for tie-in correlation. 2. Set CIBP mid element @ 12,802’ Setting in 2-3/8” liner 4.6#, ID = 1.995” (will need to pass through XO w/ ID=1.920”) Coil –Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. CCT Extended Perforating Well:D-03B Page 22 of 111 2. Bullhead 1.2x wellbore volume ~182 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a.Wellbore volume to top perf (12,180’)=151 bbls b. 4-1/2” Tubing – 9,022’ X .0152 bpf = 137 bbl c. 3-1/2” Liner – 25’ X 0.0087bpf = 1 bbls d. 2-3/8” Liner – 3,133’ X 0.0039 bpf = 13 bbls 3. At surface, prepare for deployment of TCP guns. 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KKWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 5. *Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 6.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 1.56”Millenium charges 6 SPF Perf Interval (tie-in depths)Total Gun Length Weight of Gun (lbs) 11,974’ – 12,080’ – gun 106’~384 lbs (3.62 ppf) 7. RIH with perf gun past perf interval, pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 8. After perforating, PUH to top of liner or into tubing to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary, before pulling to surface. 9. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 10. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 11. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 12. RDMO CTU. 13. Turn well over to Operations POP. Attachments: Wellbore Schematic, Proposed Schematic,Tie-In Log,BOPE schematic,Standing Orders, Equipment Layout diagram, Sundry Change Form CCT Extended Perforating Well:D-03B Page 33 of 111 Current Schematic 03 CCT Extended Perforating Well:D-03B Page 44 of 111 Proposed Wellbore Schematic Proposed Perforations 11,974’ – 12,080’ (106’) CIBP @ 12,802’ C 03 CCT Extended Perforating Well:D-03B Page 55 of 111 Tie-In Log CCT Extended Perforating Well:D-03B Page 66 of 111 Perforate 11,974’ – 12,080’ (106 feet) CCT Extended Perforating Well:D-03B Page 77 of 111 Set plug ME @ 12,802’ CCT Extended Perforating Well:D-03B Page 88 of 111 BOP Schematic CCT Extended Perforating Well:D-03B Page 99 of 111 CCT Extended Perforating Well:D-03B Page 110 of 111 CCT Extended Perforating Well:D-03B Page 111 of 111 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared BBy (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/13/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250613 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-17A 50733203110100 213049 4/14/2025 AK E-LINE GPT T40549 AN-17A 50733203110100 213049 4/16/2025 AK E-LINE Perf T40549 BRU 244-27 50283201850000 222038 5/15/2025 AK E-LINE Perf T40550 IRU 241-01 50283201840000 221076 5/16/2025 AK E-LINE Perf T40551 KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP T40552 KU 13-06A 50133207160000 223112 5/9/2025 AK E-LINE Perf T40552 KU 33-08 50133207180000 224008 5/30/2025 AK E-LINE Perf T40553 MPU K-33 50029227290000 196202 5/2/2025 AK E-LINE Caliper T40554 Aurora S-100A 50029229620100 224083 5/8/2025 BAKER MRPM Borax #2 T40555 PBU 06-12C 50029204560300 225022 5/15/2025 BAKER MRPM T40556 PBU B-30B 50029215420200 225009 4/9/2025 BAKER MRPM T40557 PBU D-03B 50029200570300 225008 5/2/2025 BAKER MRPM T40558 PBU H-29B 50029218130200 225005 5/7/2025 BAKER MRPM T40559 END 1-25A 50029217220100 197075 5/4/2025 HALLIBURTON MFC40 T40560 END 3-03 50029223060000 192121 5/18/2025 HALLIBURTON PPROF T40561 NS-33A 50029233250100 208189 5/13/2025 HALLIBURTON MFC24 T40562 PBU D-03B 50029200570300 225008 5/2/2025 HALLIBURTON RBT T40558 PBU H-29B 50029218130200 225005 5/7/2025 HALLIBURTON RBT T40559 PBU L-108 50029230900000 202109 5/16/2025 HALLIBURTON IPROF T40563 Please include current contact information if different from above. PBU D-03B 50029200570300 225008 5/2/2025 HALLIBURTON RBT PBU D-03B 50029200570300 225008 5/2/2025 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.17 11:38:14 -08'00' From:Lau, Jack J (OGC) To:Finn Oestgaard - (C) Cc:Joseph Lastufka; Abhijeet Tambe - (C); Max Shayer Subject:RE: [EXTERNAL] Re: D-03B PTD 225-008 extended perforation inquiry/confirmation Date:Wednesday, May 21, 2025 12:41:50 PM Good afternoon Finn, You are approved for the extended perfs on the existing approved PTD. Please report on the same 10-407. Please follow the standard conditions of approval for extended perforating outlined below. Conditions of Approval for Extended Perforating Perforating gun not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using Hilcorp’s extended perforating standing orders. Ensure well is dead before breaking containment. Thanks Jack From: Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com> Sent: Wednesday, May 21, 2025 12:01 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Abhijeet Tambe - (C) <Abhijeet.Tambe@hilcorp.com>; Max Shayer <mshayer@hilcorp.com> Subject: RE: [EXTERNAL] Re: D-03B PTD 225-008 extended perforation inquiry/confirmation Hi Jack, just wanted to follow up from our phone convo that we are clear to extended perforate under the PTD 225-008 & report under the same 407 and do not need to submit a separate 10-403 for this extended perforation job. Thanks for the help on this, Finn From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Tuesday, May 20, 2025 12:12 PM To: Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Abhijeet Tambe - (C) CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. <Abhijeet.Tambe@hilcorp.com>; Max Shayer <mshayer@hilcorp.com> Subject: [EXTERNAL] Re: D-03B PTD 225-008 extended perforation inquiry/confirmation Finn - You are approved to shoot the additional ~20’ on the existing approved 401 and report on the same 407. Jack From: Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com> Sent: Wednesday, May 14, 2025 5:22 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Abhijeet Tambe - (C) <Abhijeet.Tambe@hilcorp.com>; Max Shayer <mshayer@hilcorp.com> Subject: D-03B PTD 225-008 extended perforation inquiry/confirmation Hi Jack, Question regarding D-03B, a recent CTD well. We shot a 9’ of perfs in the toe on 5/3. The well productivity is not as prolific as expected. We are going to go back to reperf that 9’ and add an additional 12’ in a single 21’ gun run. We are considering while coil is on the well shooting an extended adperf run in the belly of the well. I wanted to confirm that we have the approval under the PTD 225-008. We have the extended perforating procedure and service coil BOP diagram in the PTD submission. Typically under the COA’s we have the statement that BHA’s will be < 500’ which this approved PTD does not, along with the line description under the post rig work we submitted stating post rig perforate (~20’). Those discrepancies were enough I wanted to confirm that we are indeed approved for extended perforating and do not need to submit a separate 403. This particular well/PTD had quite a bit of discussion on it prior to approval regarding the protection string I want to make sure that we are staying in compliance on this one. Thanks! Finn Finn Oestgaard GBP GC1 & GC3 Operations Engineer A,B,C,D,E,F,G,K,P,X,Y pads 907-564-5026 office 907-350-8420 mobile The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis 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 theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. David Douglas Hilcorp North Slope, LLC Sr. 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. Received By: Date: Hilcorp North Slope, LLC Date: 05/14/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU D-03B PTD: 225-008 API: 50-029-20057-03-00 FINAL LWD FORMATION EVALUATION LOGS (04/11/2025 to 04/24/2025) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Main Folders: SFTP Transfer - Data Sub-Folders: Please include current contact information if different from above. 225-008 T40408 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.15 08:02:49 -08'00' 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 Sean McLaughlin Drilling Manager Hilcorp North Slope LLC 3800 Centerpoint Dr, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay, Prudhoe Oil, PBU D-03B Hilcorp North Slope LLC Permit to Drill Number: 225-008 Surface Location: 1910’ FNL, 1067’ FEL, Sec. 23, T11N, R13E, UM, AK Bottomhole Location: 684’ FSL, 87’ FWL, Sec. 14, T11N, R13E, UM, AK Dear Mr. McLaughlin 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 AOGCCwithin 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 AOGCCreserves 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 AOGCCspecifically 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 AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this day of )HEUXDU\, 2025. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.07 14:15:59 -09'00' February 25, 2025 By Grace Christianson at 12:53 pm, Jan 29, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.01.28 16:05:58 - 09'00' Sean McLaughlin (4311) A.Dewhurst 04FEB25 50-029-20057-03-00 WCB 2-7-2025 225-008 *AOGCC witnessed BOPE test to 3500 psi. Annular to 2500 psi minimum. *Variance to 20 AAC 25.036(c)(2)(A)(iv) approved for work performed before 3-31-2025 with documented well control drills performed by all crews deploying tubulars <2.375" OD without properly sized pipe rams. DSR-1/31/25*&: 2/7/2025 2/7/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.07 14:16:17 -09'00' RBDMS JSB 021025 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: January 27, 2025 Re:D-03B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well D-03 with the Nabors CDR2/CDR3 Coiled Tubing Drilling rig. Proposed plan for D-03B Producer: See D-03A Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift for whipstock MIT-T/IA and Caliper. E-line will set a 4-1/2"x5-1/2" whipstock. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2/CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2"x5-1/2" whipstock. A dual string (5-1/2"x9- 5/8") 3.80" window + 10' of formation will be milled. The well will kick off drilling in the Kingak and top set in the Shublik. A 3-1/4" slotted liner will be run to the base of the Kingak. The rig will swap from 2-3/8" to 2" coil and mill out the aluminum shoe with a 2.74" mill. The lateral will land in Ivishak Zone 2 and continue in Zone 2 to TD. The proposed sidetrack will be completed with a 2-3/8" L80 solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: x Reference D-03A Sundry submitted in concert with this request for full details. 1. Slickline : Run CBL from deviation to TOL @ 9997’ 2. Eline Set 2-7/8” 1 trip cement retainer @ 10,142’ – Confirm with OE TOC behind 2- 7/8” is shallower than set depth. Punch 2-7/8” liner from 10,137’ – 10132’ 3. Coil Stab into retainer & pump 8.0 bbls of Class G cement or equivalent cement and unstab from retainer. Lay in 3.3 bbls of cement while pulling up hole letting cement U-tube in the 2-7/8” & 5-1/2”. Target TOC at 9997’ MD 4 Fullbore WOC and MIT to 1000 psi 5. Slickline Drift for whipstock and Caliper whipstock setting interval 6. E-line : Set 4-1/2" x 5-1/2" Whipstock. Top at 9965' Oriented at 0 deg RHOS 7. Valve Shop : Pre-CTD tree work (install sarber spool, PT swab, leak-tight master) 8. Valve Shop : Bleed wellhead pressures down to zero. 9. Valve Shop : Bleed production, flow and GL lines down to zero and blind flange. 10. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start February 25, 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,447 psi). 2. Mill 3.80” Window. Perform FIT to 4100 psi equivalent BHP minimum. 3. Drill build section: 4.25" OH, ~50' (18 deg DLS planned) to top of reservoir 4. Run 3-1/4" L80 slotted liner with aluminium bullnose shoe 5. Secure well and swap from 2-3/8" to 2" Coil and BOPE rams. Test BOPE 250 psi low and 3,500 psi high. RIH and mill out aluminium shoe 6. Drill build section: 3.25" OH, ~830' (18 deg DLS planned) 7. Drill production lateral: 3.25" OH, ~2225' (12 deg DLS planned). 8. Run 2-3/8” L-80 liner 9. Pump primary cement job: 34 bbls, 14.8 ppg Class G, yield 1.33 ft3/sk, TOC at TOL. Volume to completely fill 2-3/8” and 3-1/4” outside annuli. Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : SBHPS, Pressure test liner lap to 1000 psi minimum, set LTP (if necessary). Set live GLVs. 3. Service Coil : Post rig perforate (~20’) and RPM. Managed Pressure Drilling: Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.4 ppg drilling fluid 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 and is independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3” (big hole) & 2-3/8” (slim hole) 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: 4.25” Hole MPD Pressure at the Planned Window (9967' MD -8,432' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)5,174 psi 5,174 psi 11.8 B Annular ĨƌŝĐƟŽŶ-;ƉƐŝͬŌͿ 598 psi 0 psi 0.06 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 4165 psi 4165 psi 9.5 B+C Mud + ECD Combined 4,763 psi 4165 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 411 psi 1,008 psi Target BHP at window and deeper 3.25” Hole MPD Pressure at the Planned Shoe (10,017' MD -8472' TVD) Pumps On Pumps Oī A Target BHP at Shoe (ppg)4317 psi 4317 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ-;ƉƐŝͬŌͿ 598 psi 0 psi 0.06 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3789 psi 3789 psi 8.6 B+C Mud + ECD Combined 4,763 psi 3789 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain -69 psi 529 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,327 psi at 8,800 TVD. (7.3 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,447 psi (from estimated reservoir pressure). Mud Program: x Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. x Fluids with solids that will not pass through 1/4” screen must go to GNI. x Fluids with PH >11 must go to GNI. Hole Size: x 4.25" for shale drilling and 3.25" hole for the entirety of the production hole section. Liner/Cement Program: x 3-1/4", 6.6#, L80 slotted: 9300' MD – 10,019' MD (719' liner) x 2-3/8", 4.6#, L80 solid: 9,190' MD – 13,072' MD (3,882' liner) x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary. x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. x 34 bbls, 14.8 ppg Class G, yield 1.33 ft3/sk, TOC at TOL. Volume to completely fill the 2-3/8” liner annulus from the shoe to the top of liner and 3-1/4” annulus from the shoe to top of liner. 20 AAC 25.030 (d)(5) intermediate and production casing must be cemented with sufficient cement to fill the annular space from the casing shoe to a minimum of 500 feet measured depth or 250 feet true vertical depth, whichever is greater, above all significant hydrocarbon zones and abnormally geo-pressured strata or, if zonal coverage is not required under (a) of this section, from the casing shoe to a minimum of 500 feet measured depth or 250 feet true vertical depth, whichever is greater, above the casing shoe; if indications of improper cementing exist, such as lost returns, or if the formation integrity test shows an inadequate cement job, 20 AAC 25.030 (c)(5) production casing must be set and cemented through, into, or just above the production interval; 20 AAC 25.030 (c)(6) slotted liners, pre-perforated liners, and screens installed below a production packer are considered production equipment and not casing. The window will be milled and D-03B kicked off in the Kingak shale at 9965’ MD (8432’ TVD). Records indicate that 2050 sacks of cement were pumped during the first cement stage behind the 9-5/8” casing in the original D- 03 wellbore. Based on volumetric calculations, the expected TOC for the first cement stage behind the 9-5/8” casing is at 5420’ MD (Based on 40% washout). Losses were noted before and during the cement job, however, cement returns from first stage were noted while circulating through the 9-5/8” DV collar at 7097’ MD in preparation for the 2nd cement stage. A second and third cement stage was also pumped to bring the logged TOC up to 4444’ MD behind the 9-5/8” casing. An SCMT Log run on 06/02/06 found TOC between the 5-1/2” tubing and 9-5/8” casing at 9416’ MD. 549’ MD above the proposed whipstock depth. This provides 549’ of lateral cement isolation across all annuli just above the top of reservoir for future well abandonment. Based on the 9-5/8” casing cementing records and the CBL log, a minimum of 500’ MD and 250’ TVD of cement exists above the planned KOP(new casing shoe) just above the production interval which meets and exceeds the minimum requirements for 20 AAC 25.030. 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 2,500 psi. x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. x A X-over shall be made up to a 2” safety joint including a TIW valve for all tubulars ran in hole. x 2” safety joint will be utilized while running solid or slotted liner. The desire is to keep the same standing orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre- installed TIW valve). When closing on a 2” safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. x Request variance to 20 AC 25.036(c)(2)(A)(iv) to deploy tubulars < 2.375” OD without properly sized pipe rams. x 2” safety joint will be utilized while running 1” / 1-1/4” CS hydril. x Blind/Shear rams will be utilized in place of pipe rams sized for CTD jointed pipe operations as a worst-case shut-in scenario (in place 1” / 1-1/4” CS hydril pipe rams). x The well will be full of KWF prior to running liner or jointed pipe operations. x The BHA will be circulated out of hole prior to laying down BHA for jointed pipe operations. x The well will be flow checked after laying in KWF, before laying down BHA and before making jointed pipe. Directional: x Directional plan attached. Maximum planned hole angle is 110°. Inclination at kick off point is 28°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 23,700 ft x Distance to nearest well within pool – 970 ft 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 20' perforated post rig – See attached extended perforating procedure. x 1.56 Perf Guns at 6 spf x If post rig extended perforating with service coil is not an option, the well will be perforated with the rig or post rig under this PTD. x The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. x Formations: Top of Prudhoe Pool at 10,017’ MD in the parent Anti-Collision Failures: x D-07B Fails anticollision with the D-03B wp03 wellpath. D-07B was abandoned as part of the D-07C CTD sidetrack. Hazards: x D Pad is not an H2S pad. The last H2S reading on D-03A: 21 ppm on 01/02/2023. x Max H2S recently recorded on DS/Pad: 34 ppm. x 3 fault crossings expected. x Medium lost circulation risk. Post-Rig Service Coil Perforating Procedure: Coiled Tubing Notes: x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. x Note: The well will be killed and monitored before making up the initial perfs guns. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. MU nozzle drift BHA (include SCMT and/or RPM log as needed). 3. RIH to PBTD. a. Displace well with weighted brine while RIH (minimum 8.4 ppg to be overbalanced). 4. POOH (and RPM log if needed) and lay down BHA. 5. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 6. There will be no perforations to bullhead kill the well. Well will already be loaded w/ weighted brine or KCl per previous steps. Re-load well at WSS discretion. 7. At surface, prepare for deployment of TCP guns. 8.Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, weighted brine as needed (minimum 8.4 ppg). Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 10. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.Max BHA length per PTD is 500ft. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. a. Perforation details i.Perf Interval:The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. ii.Perf Length:500’ iii.Gun Length:500’ iv.Weight of Guns (lbs):2300lbs (4.6ppf) 11. MU lubricator and RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate perforation intervals (TBD). POOH. a. Note any tubing pressure change in WSR. 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA.Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH.Stop at surface to reconfirm well dead and hole full. 14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. Standing orders flow chart included with this sundry request. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. Freeze protect well to 2,000’ TVD. 16. RDMO CTU. Coiled Tubing BOPs Standing Orders for Open Hole Well Control during Perf Gun Deployment Equipment Layout Diagram Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well 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 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well 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 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee $) $) $) $) $) $) $) $) $) $) $)$) $ $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) $) !! ! !! !!! ! !!! !!!!!! !! !! ! !!! ! !! !!! !! !!!! !!! !!! !!!! !!! ! !!!!! !! !! !!!!! !! !!!!! !! !!!!! !!!! !!!! ! ! D $) D-01 D-03 D-03A D-06 D-07B D-11 D-11B D-12 D-14B D-15 D-17A D-17B D-19 D-19A D-19B D-19C D-22 D-22C D-25 D-26 D-27 D-27A D-28 D-28A D-28B D-31A D-31B D-33 D-35 G-18B H-28 H-28A H-36 Q-07 Q-07B Prudhoe Bay Unit Sec. 14 Sec. 15 Sec. 22 Sec. 23 U011N013E SANTA FE PAD D PAD COLD STORAGE PAD ADL28285 ADL28284 D-03B_SHL D-03B_TPH D-03B_BHL Map Date: 6/22/2023 Prudhoe Bay Unit D-03B Well wp03 E0 490 980 Feet Legend $)D-03B_BHL !D-03B_SHL D D-03B_TPH $)Other Bottom Holes (BHL) Other Well Paths Oil and Gas Unit Boundary Pad Footprint IPA CO_341J AIO_3C Document Path: O:\AWS\GIS\Products\Alaska\NS\Wells\TRS_Distance\mxds\2023\NorthSlope_PBU_D-03B_wp03.mxd 2000 2500 3000 3500 4000 4500 5000 South(-)/North(+) (1000 usft/in)-5000-4500-4000-3500-3000-2500-2000-1500-1000West(-)/East(+) (1000 usft/in)9009G-18B92378800H-36A880090 1 5H- 3 6 5 6 0 0 6 0 0 0 6 4 0 0 6 8 0 0 72 00 76 00 8000 8 4 00 8 80 0 9176 D-03 9 0 0 3 D - 0 3 A 84 0088 00 91 97D -279000 D-27A D - 2 8 B P B 1 D-28BD-28A D-26A8800D-26B840088009156D-26D -2 8 A 90 2 5 D-07 B 8800D -07A 7 2 0 0 7 6 00 8 0 0 0 84 008800D-07 A P B 16400 6 80 0 7 2 00 7600 8000 D-0 7 90 13 Q-0 7B 9133Q-0788008866D-03B wp03 Top of Window (9,967'MD) End 18dls (10,847'MD) TD (13,072'MD) 8600 8800 9000 9200 True Vertical Depth (400 usft/in)0200400600800100012001400160018002000220024002600280030003200340036003800Vertical Section at 250.00° (400 usft/in) D-03D-03AD-03B wp03Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect 1 9967.00 26.85 350.01 8432.00 3706.12 -2144.53 0.00 0.00 747.63 2 9987.00 28.65 350.01 8449.69 3715.29 -2146.14 9.00 0.00 746.01 3 10067.00 43.05 350.01 8514.37 3761.31 -2154.25 18.00 0.00 737.89 4 10179.00 43.08 320.49 8596.19 3830.00 -2185.92 18.00 -90.00 744.15 5 10359.00 12.65 293.89 8753.46 3885.06 -2247.45 18.00 -160.00 783.14 6 10474.00 32.65 308.74 8859.05 3909.27 -2284.14 18.00 15.00 809.34 7 10847.43 92.00 270.31 9024.78 3993.97 -2583.44 18.00 -28.00 1061.63 8 10948.58 92.00 258.16 9021.25 3983.83 -2683.83 12.00 -90.00 1159.43 9 11107.99 90.00 239.13 9018.47 3926.07 -2831.59 12.00 -96.00 1318.03 10 11208.00 90.00 251.14 9018.47 3884.09 -2922.16 12.00 90.00 1417.50 11 11488.00 90.00 217.54 9018.47 3723.17 -3146.40 12.00 -90.00 1683.25 12 11628.00 90.00 234.34 9018.47 3626.15 -3246.64 12.00 90.00 1810.63 13 11888.00 90.00 203.14 9018.47 3425.84 -3407.32 12.00 -90.00 2030.13 14 12008.00 91.00 217.50 9017.42 3322.53 -3467.74 12.00 86.00 2122.24 15 12128.00 91.00 203.10 9015.32 3219.21 -3528.11 12.00 -90.00 2214.31 16 12248.00 91.51 188.70 9012.69 3104.13 -3560.90 12.00 -88.00 2284.47 17 12408.00 91.51 207.91 9008.48 2952.99 -3610.91 12.00 90.00 2383.16 18 12528.00 95.47 221.78 9001.18 2854.94 -3679.15 12.00 74.00 2480.82 19 12638.00 96.62 235.01 8989.59 2782.46 -3760.75 12.00 85.00 2582.29 20 12758.00 106.80 245.42 8965.26 2724.13 -3862.39 12.00 45.00 2697.75 21 12858.00 107.85 232.90 8935.48 2675.31 -3944.20 12.00 -85.00 2791.32 22 13072.00 110.07 259.95 8865.95 2594.92 -4127.88 12.00 85.00 2991.42 Project: Prudhoe Bay Site: D Well: D-03 Wellbore: Plan: D-03B Plan: D-03B wp03 WELLBORE DETAILS Parent Wellbore:D-03Top of Window: 9967.00 D-03B wp03 Depth From Depth To Survey/Plan Tool 100.00 9967.00 1 : Camera based gyro multisho (D-03) 3_CB-Film-GMS2 9967.00 13072.00 D-03B wp03 (Plan: D-03B) 3_MWD WELL DETAILS Northing: 5959090.98Easting: 654092.01Lattitude: 70° 17' 42.5301 NLongitude: 148° 45' 8.0958 W D-03B wp03 SECTION DETAILS Hilcorp Alaska, LLC SURVEY PROGRAM NAD 1927 (NADCON CONUS) US State Plane 1927 (Exact solution) Alaska Zone 04 PROJECT DETAILS REFERENCE INFORMATION Coordinate(N/E) Reference: Well D-03, True North Vertical (TVD) Reference: D-03 @ 58.22usft Measured Depth Reference: D-03 @ 58.22usft Section (VS) Reference: Slot - (0.00N, 0.00E) Calculation Method: Minimum Curvature REFERENCE INFORMATION ! 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( $ )* 2 " , 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 no greater 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. 225-008 PRUDHOE OIL PBU D-03B PRUDHOE BAY 1 Gluyas, Gavin R (OGC) From:Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Sent:Wednesday, October 16, 2024 11:21 AM To:Rixse, Melvin G (OGC) Cc:Boman, Wade C (OGC) Subject:RE: [EXTERNAL] CDR2 3" Pipe/Slips on planned well D-03A Categories:CDR2-3 Mel, These rams are used for pressure deploying our “Bighole” (3”) BHAs for drilling. Ryan Ciolkosz | Drilling Engineer C: 907.244.4357 | O: 907.564.4413 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, October 16, 2024 2:58 AM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Cc: Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: [EXTERNAL] CDR2 3" Pipe/Slips on planned well D-03A Ryan, Is your BOPE schematic correct for this PTD? You have 3” pipe slips. Why? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 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). You don't often get email from ryan.ciolkosz@hilcorp.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. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 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 Gluyas, Gavin R (OGC) From:Trevor Hyatt <Trevor.Hyatt@hilcorp.com> Sent:Monday, November 25, 2024 2:20 PM To:Boman, Wade C (OGC) Subject:RE: [EXTERNAL] CTD Discussion: D-03B variances, CTD BOPE rams, etc Confirmed everyone from my side is good meeting on the 9th. Trevor Hyatt Hilcorp Alaska, LLC Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 From: Trevor Hyatt <trevor.hyatt@hilcorp.com> Sent: Monday, November 25, 2024 12:54 PM To: Boman, Wade C (OGC) <wade.boman@alaska.gov> Cc: John Perl <John.Perl@hilcorp.com>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: [EXTERNAL] CTD Discussion: D-03B variances, CTD BOPE rams, etc Wade, Any chance we can push this meeting to December 9th so John Perl can attend? Trevor Hyatt Hilcorp Alaska, LLC Drilling Engineer Trevor.Hyatt@hilcorp.com Cell: 907-223-3087 -----Original Appointment----- From: CAL-DOA-AOGCC (CED sponsored) <akoilgas.forwarder@alaska.gov > Sent: Wednesday, November 20, 2024 4:30 PM To: CAL-DOA-AOGCC (CED sponsored); Torin Roschinger; Sean McLaughlin; Rixse, Melvin G (OGC); McLellan, Bryan J (OGC); Dewhurst, Andrew D (OGC); Lau, Jack J (OGC); Boman, Wade C (OGC); Aras Worthington Cc: Ryan Ciolkosz; Trevor Hyatt Subject: [EXTERNAL] CTD Discussion: D-03B variances, CTD BOPE rams, etc When: Monday, December 2, 2024 2:00 PM-3:30 PM (UTC-09:00) Alaska. Where: Microsoft Teams Meeting; AOGCC Public Conference Room (CED sponsored) Everyone, let’s please meet in person to discuss a few CTD drilling issues: CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 x PBU D-03B variances (plugging requirements and casing cementing) x CTD BOPE ram requirements x Service coil window milling requirements x Any additional CTD items requiring discussion There has been much back and forth in phone calls and emails on a couple of these subjects, and an in-person discussion would be beneficial. Thanks. -Wade ________________________________________________________________________________ Microsoft Teams Need help? Join the meeting now Meeting ID: 253 273 308 83 Passcode: Jp9iK9Sn Join on a video conferencing device Tenant key: 260748889@t.plcm.vc Video ID: 116 205 349 7 More info For organizers: Meeting options ________________________________________________________________________________ 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 Gluyas, Gavin R (OGC) From:Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Sent:Wednesday, November 6, 2024 3:46 PM To:Rixse, Melvin G (OGC); Ryan Ciolkosz Cc:Trevor Hyatt; Joseph Lastufka; Dewhurst, Andrew D (OGC); Aras Worthington; Boman, Wade C (OGC); McLellan, Bryan J (OGC); Lau, Jack J (OGC) Subject:RE: [EXTERNAL] PTD 229-129 PBU D-03B Compliance Clarifications Categories:CDR2-3 Mel, Thank you. Ryan will take it into consideration. sean From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, November 6, 2024 3:20 PM To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Boman, Wade C (OGC) <wade.boman@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: [EXTERNAL] PTD 229-129 PBU D-03B Compliance Clarifications Sean, Seems like a plan. AOGCC would be happy to consider a draft. AOGCC will request a full procedure, not just a one liner as the CTD PTD submissions currently are submitted. You can look at the detailed service coil post rig perforating procedure if you need a guide. Always helps to expedite if AOGCC has clear, labeled, and accurate schematic with cement locations. I think it best to provide a Ʊnal reservoir abandonment plug schematic as well. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 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). CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Wednesday, November 6, 2024 2:59 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Boman, Wade C (OGC) <wade.boman@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Mel, For both cases, the cement will be placed via the displacement method. Perforate the interval and place the cement across the zone. I believe this has been acceptable in the past for perforated intervals. 20 AAC 25.112 (c) Plugging of cased portions of a wellbore must be performed in a manner that ensures that all hydrocarbons and freshwater are conƱned to their respective indigenous strata and are prevented from migrating into other strata or to the surface. The minimum requirements for plugging cased portions of a wellbore are as follows: (1) perforated intervals must be plugged by one of the following methods: (A) by the displacement method, a cement plug placed from 100 feet below the base to 50 feet above the base of the perforated interval and from 50 feet below the top to 100 feet above the top of the perforated interval; Regards, sean From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, November 6, 2024 11:57 AM To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Boman, Wade C (OGC) <wade.boman@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Sean, How will Hilcorp demonstrate 100’ of cement isolation behind the 3-1/4” slotted liner for the Ʊnal abandonment? How will Hilcorp demonstrate cement isolation from D-03A with a Ʋow through whipstock and only a (proposed?) liner top packer? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 3 907-297-8474 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). From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Monday, November 4, 2024 4:21 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Boman, Wade C (OGC) <wade.boman@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Mel, Would it be acceptable to run a 3-1/4” slotted liner? I would think so since the well is already constructed and with an existing pressure envelope. This is further evidenced by the fact that this is a through tubing operation. It should be impossible to insert an intermediate casing sting through the tubing. If a slotted pipe would be okay to run in this situation, then it is not an intermediate casing string. Please consider it an advanced coiled tubing completion. Regulation 20 AAC 25.030(d)(5) should not apply to this application. Regards, sean From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, November 4, 2024 2:50 PM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Boman, Wade C (OGC) <wade.boman@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, Several points/questions for Hilcorp regarding D-03B PTD: First a regulation: 20 AAC 25.030. Casing and cementing d) Speci Ʊc well casing cementing provisions are as follows: CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 4 (5) intermediate and production casing must be cemented with suƯicient cement to Ʊll the annular space from the casing shoe to a minimum of 500 feet measured depth or (d)(5) true vertical depth, whichever is greater, It appears the 3-1/4” liner is not cemented. I have not seen jusƟĮcaƟon from Hilcorp determining the HRZ to be equal to or a greater barrier than cement. AOGCC will require empirical jusƟĮcaƟon that the HRZ is equal to or beƩer for a variance. If Hilcorp is requesƟng a waiver, then clear jusƟĮcaƟon of the risk and beneĮt why this PTD should be approved. Second The schemaƟc shows a 4-1/2” x 5-1/2” Ňow thru whipstock at 9965’ MD. The Ňow through whipstock is placed adjacent to an uncemented 3-1/4” liner that communicates to the reservoir via an uncemented OH x 3-1/4” in the upcoming ’B’ lateral. This provides a Ňow path from the parent well to the new sidetrack and is only isolated from the produc Ɵon tubing with a liner top packer and an unapproved HRZ barrier. This appears to be an ‘L1’. Also, AOGCC will want jusƟĮcaƟon or evidence that the proposed cement squeeze in the Įnal reservoir plug is competent cement plug of minimum of ~100’ MD within the conĮning zones. Per regula Ɵon: 20 AAC 25.112. Well plugging requirements c) Plugging of cased por Ɵons of a wellbore must be performed in a manner that ensures that all hydrocarbons and freshwater are conĮned to their respecƟve indigenous strata and are prevented from migraƟng into other strata or to the surface. The minimum requirements for plugging cased por Ɵons of a wellbore are as follows: ………….. The process of bullheading cement through perforaƟons does not demonstrate isolaƟon. How will Hilcorp demonstrate isolaƟon through cemented 2-2/8” x 3-1/4” to the 3-1/4” x 5-1/2” annulus of the exisƟng producƟon liner? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 Cell 5 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). From: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > Sent: Monday, November 4, 2024 12:04 PM To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Boman, Wade C (OGC) <wade.boman@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Wade, Just following up on Sean’s email from last week. Typically, as part of the Sundry request on most CTD sidetrack we request a variance for alternate plug placement per 20 AAC 25.112. See below the screenshot from the D-03 Sundry. Cement is planned to the top of the 2-3/8” which extends beyond the top of the D-03 parent perfs and the 3-1/2” liner which should isolate any production from the parent’s perforations. If we believe we are getting production from the parent perforations, we will likely set a liner top packer above the 2-3/8” liner in the tubing to isolate the parent production. The intent is to abandon the parent production. Let me know if you want to discuss further. 6 Ryan Ciolkosz | Drilling Engineer C: 907.244.4357 | O: 907.564.4413 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Wednesday, October 30, 2024 5:05 PM To: Boman, Wade C (OGC) <wade.boman@alaska.gov>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Hi Wade, I think I see what you are getting at, but it is unconventional and not in line with our accounting. There maybe a hang up between plugging and abandonment. I believe the parent well will be e Ưectively plugged with the whipstock set in the HRZ shale. I don’t believe Ʋow is possible from the parent and neither is access or reentry. Adding a lateral usually means keeping parent production, reserves, or utility. None of that exists in this case. Setting the whipstock eƯectively plugs the parent well and that would prompt a new wellbore. I agree abandonment will occur when the annulus is Ʊlled with cement. 7 Would you reconsider the lateral designation for this project? Thank you, sean From: Boman, Wade C (OGC) <wade.boman@alaska.gov> Sent: Wednesday, October 30, 2024 3:47 PM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com >; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, I think that looks good to include in the PTD. Something that has come up is that with this design the parent wellbore would not be abandoned until the proposed cement is placed in the 3-1/2 x 5-1/2 annulus at time of P&A, as described below (there would only be a whipstock between D-03A’s liner top and the new liner top packer). So, this would make the new sidetrack a lateral of the parent (D-03AL1) rather than its own standalone wellbore (D-03B). Hence, the verbiage in the PTD “This completion will isolate and abandon the parent Ivishak perfs” would have to be removed, and the name would need to be changed. Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907-793-1238 cell: 907-687-4468 From: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > Sent: Wednesday, October 30, 2024 1:02 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Mel/Wade, Thanks for the clariƱcation, would the following verbiage and illustration in the PTD be acceptable? Hilcorp requests the AOGCC approval for alternate plug placement at abandonment per 20 AAC 25.112 using the following methods: 1. At abandonment, the well would be perforated across the 2-3/8”x3-1/2” pipe over the cased hole section from 9965’ to 9416’ MD. The 3-1/2” x 5-1/2” annulus would be cemented with a cement plug placed and squeezed into the perforations from 9965’ to 9416’ MD. This would provide 549’ of concentric lateral CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 8 cement isolation from the reservoir up all annuli. See schematic below for illustration of Ʊnal plug placement and lateral barriers. Ryan Ciolkosz | Drilling Engineer C: 907.244.4357 | O: 907.564.4413 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, October 29, 2024 10:08 AM 9 To: Boman, Wade C (OGC) <wade.boman@alaska.gov>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, The expectation is that Hilcorp identify the regulations (in this case 20 AAC 25.030 (d)(5)) where they are requesting a variance or waiver in the PTD or sundry then provide a justiƱcation why AOGCC should approve. For most cases presented by Hilcorp, they have good physical justiƱcation why it should be approved, but the record needs to be documented. AOGCC identiƱes this well design as possibly requiring a waiver for the Ʊnal reservoir abandonment plug in the future at the end of the economic life. To approve this design AOGCC would want to see Hilcorp’s proposal for abandonment. I think a schematic describing the placement of cement plugs would be suƯicient. This is not unique to the regulations. CO736 requires a Ʊnal abandonment schematic. When CTD exits the wellbore in the overburden, I think they should consider including the Ʊnal abandonment schematic (at least for the reservoir plug). For Hilcorp’s understanding regarding the Ʊnal abandonment, most CTD wells exit the parent within the PB oil pool and AOGCC regulates this as a single indigenous oil zone with high vertical permeability. As long as the Ʊnal abandonment has cement across all annuli of su Ưicient length within the conƱning zones, preferably at the base of the conƱning zones, AOGCC has not required cement across the perforations within the reservoir. I hope this helps. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 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). From: Boman, Wade C (OGC) <wade.boman@alaska.gov> Sent: Monday, October 28, 2024 12:44 PM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com >; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, thanks for the supplied details. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 10 Our main concern is that there will be newly placed pipe (the 3-1/2 and 3-1/4) that will be an intermediate string, uncemented. This does not meet the requirements of 20 AAC 25.030 (d)(5). Additionally, this uncemented section reaches above the cement in both the 5-1/2 x 9-5/8 annulus and in the 9-5/8 x OH, thereby creating a potential pathway from the 3-1/4 x OH section, up into the 4-1/2 x 9-5/8 annulus. We would need to see 20 AAC 25.030 (d)(5) satisƱed by cement being placed around the 3-1/4 and the 3-1/4 string. Also, please submit a new 10-401 application with the new WBS included (but thank you for sending the proposed WBS screenshot in the below email). Also, unless I’m missing something, the cement top at 9342’ behind the 9-5/8 isn’t being shown on the new schematic section. Thanks. -Wade Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907-793-1238 cell: 907-687-4468 From: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > Sent: Monday, October 28, 2024 10:10 AM To: Boman, Wade C (OGC) <wade.boman@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com > Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Wade, As discussed over the phone, please see my response to your questions/concerns below: Intermediate and Production casing (20 AAC 25.030(d)(5)) The top of the of the conƱning HRZ/Kingak shale is at 8511’ MD/7153’ TVD which is 1454’ MD/1277’ TVD above the D-03B Kick oƯ point. See the diagram below for reference. The KOP is ~70’ TVD above the top of the Prudhoe Pool. This leaves ~1207’ TVD of conƱning shale above the KOP. The original well was cemented throughout this section of the wellbore up to the top of the DV collar at 7097’ MD. A cement log was run and conƱrmed cement up to and above the conƱning shale at 8511’ MD behind the 9-5/8” casing. The 9-5/8” casing would still be considered the production casing in reference to 20 AAC 25.030(d)(5) as it still satisƱes all the conditions outline in the statute. The “casing shoe” as referenced in the statute would now be at the D-03A KOP (9965’ MD). Future Abandonment (20 AAC 25.112) 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. 11 In addition to the wellbore conditions noted above, a SCMT run on 06/02/06 logged cement up to 9416’ MD between the 5-1/2” and 9-5/8” casing. To provide concentric cement isolation across the wellbore adjacent to the conƱning shale, the standard procedure would be to perforate the 2-3/8”x3-1/2” pipe across the cased hole section and cement that annulus with a cement plug at abandonment. Alternatively, a cement plug could be placed directly above the production packer inside the 4-1/2” tubing and in the 4-1/2” x 9-5/8” annulus. Formation Integrity test after milling the window I don’t think it makes sense to perform an FIT after milling out the window as cement isolation above the window has been veriƱed via CBL behind the 9-5/8” casing. Also, performing an FIT in the Kingak will likely lead to wellbore instability and any leak oƯ would likely be going into the perforations in the 2-7/8” liner below the whipstock. 12 Also, see the attached updated full wellbore schematic. Let me know if you have any more follow up questions or concerns or would like to discuss over the phone/in person. Ryan Ciolkosz | Drilling Engineer C: 907.244.4357 | O: 907.564.4413 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From: Boman, Wade C (OGC) <wade.boman@alaska.gov> Sent: Tuesday, October 22, 2024 3:22 PM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com >; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, upon closer inspection of the schematic, it’s now clearer that the bottom of the 3-1/2” x 3-1/4” liner is located at 10019’ MD, well below the whipstock depth. However, we still have concerns, chief of which is Mel’s Ʊrst question below. The 3-1/2” and 3-1/4” liner are, in this case, production casing. If no cement is placed behind it, this would clearly not satisfy 20 AAC 25.030(d)(5). Other concerns are of the WBS itself. x The whipstock should be in red, as it is part of the proposed new well. x The TOC behind the 9-5/8 casing is shown at 9342’ MD, which is Ʊne, and the WBS shows it as “tagged,” yet Page 3 of the program mentions the TOC at 9342’ MD is known from a CBL ran in 1976. The WBS should match the program. x The existing cement between the 5” tubing and the and 9-5/8 casing is clearly shown on D-03A’s WBS (with TOC logged at 9416’ MD via SCMT in 2006), but this same cement is not shown at all in the proposed WBS for D-03B. Instead, this annulus is shown blank in the proposed WBS. This should be included so that it’s visually clear, especially since reservoir isolation concerns are an issue. x The straight red lines below the end of the 3-1/4” protection liner make it look as though there are concentric liner strings from 10019’ MD on. Please remove those red lines, as they make it seem that the 3- 1/4” liner extends to TD. Thanks. -Wade Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907-793-1238 cell: 907-687-4468 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, October 22, 2024 3:16 PM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 13 Cc: Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, Wade pointed out there is a little tiny liner shoe on your schematic below the whipstock at 10,019’ MD which looks like it is a shoe on the 2-3/8” so it is now clear to me the depth you are running the 3-1/4” to. We still need all the other information though. Clear schematics are always appreciated. Proposed whipstocks and new jewelry in red. Shoes clearly visible. Tapered strings actually tapered on the schematic. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 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. Wade From: Rixse, Melvin G (OGC) Sent: Tuesday, October 22, 2024 9:34 AM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > Cc: Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, What is Hilcorp’s plan to provide compliance to 20 AAC 25.030(d)(5)? It appears there is no plan to cement the 3-1/4” x OH annulus, correct? intermediate and production casing must be cemented with suƯicient cement to Ʊll the annular space from the casing shoe to a minimum of 500 feet measured depth or (d)(5) true vertical depth, whichever is greater, above all signiƱcant hydrocarbon zones and abnormally geo-pressured strata or, if zonal coverage is not required under (a) of this section, from the casing shoe to a minimum of 500 feet measured depth or true vertical depth, whichever is greater, above the casing shoe; if indications of improper cementing exist, such as lost returns, or if the formation integrity test shows an inadequate cement job, If Hilcorp is requesting a variance to 20 AAC 25.030(d)(5), please note the regulation and the method to assure an equal to or greater method for compliance to the regulation in the PTD. Also, regarding this regulation, it usually assures that the Ʊnal abandonment will require only on additional plug in the tubing or liner to assure a proper Ʊnal reservoir abandonment. It is not clear to me how Hilcorp will place a Ʊnal 14 reservoir abandonment plug across all annuli at the top of the reservoir when this wel l ends its economic life. Please describe. The schematic shows that the 3-1/2” x 3-1/4” liner will be run to 9950’ MD. Eline is setting a whipstock at 9965’ MD. It is not clear to me why you would be setting the 3-1/2” x 3-1/4” as a protection string across the Kingak to TShublik? What MD is TShublik? Why is the 3-1/2” x 3-1/4” shoe above the whipstock? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 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. Wade Boman 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 d issemination, 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. 15 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. 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. 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 d issemination, 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. 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 d issemination, 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. 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 d issemination, 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 Gluyas, Gavin R (OGC) From:Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Sent:Wednesday, November 6, 2024 2:59 PM To:Rixse, Melvin G (OGC); Ryan Ciolkosz Cc:Trevor Hyatt; Joseph Lastufka; Dewhurst, Andrew D (OGC); Aras Worthington; Boman, Wade C (OGC); McLellan, Bryan J (OGC); Lau, Jack J (OGC) Subject:RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Categories:CDR2-3 Mel, For both cases, the cement will be placed via the displacement method. Perforate the interval and place the cement across the zone. I believe this has been acceptable in the past for perforated intervals. 20 AAC 25.112 (c) Plugging of cased portions of a wellbore must be performed in a manner that ensures that all hydrocarbons and freshwater are conƱned to their respective indigenous strata and are prevented from migrating into other strata or to the surface. The minimum requirements for plugging cased portions of a wellbore are as follows: (1) perforated intervals must be plugged by one of the following methods: (A) by the displacement method, a cement plug placed from 100 feet below the base to 50 feet above the base of the perforated interval and from 50 feet below the top to 100 feet above the top of the perforated interval; Regards, sean From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, November 6, 2024 11:57 AM To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Boman, Wade C (OGC) <wade.boman@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Sean, How will Hilcorp demonstrate 100’ of cement isolation behind the 3-1/4” slotted liner for the Ʊnal abandonment? How will Hilcorp demonstrate cement isolation from D-03A with a Ʋow through whipstock and only a (proposed?) liner top packer? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 907-297-8474 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). From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Monday, November 4, 2024 4:21 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Boman, Wade C (OGC) <wade.boman@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Mel, Would it be acceptable to run a 3-1/4” slotted liner? I would think so since the well is already constructed and with an existing pressure envelope. This is further evidenced by the fact that this is a through tubing operation. It should be impossible to insert an intermediate casing sting through the tubing. If a slotted pipe would be okay to run in this situation, then it is not an intermediate casing string. Please consider it an advanced coiled tubing completion. Regulation 20 AAC 25.030(d)(5) should not apply to this application. Regards, sean From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, November 4, 2024 2:50 PM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Boman, Wade C (OGC) <wade.boman@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, Several points/questions for Hilcorp regarding D-03B PTD: First a regulation: 20 AAC 25.030. Casing and cementing d) Speci Ʊc well casing cementing provisions are as follows: CAUTION: External sender. DO NOT open links or attachments from UNKNOWN sender s. 3 (5) intermediate and production casing must be cemented with suƯicient cement to Ʊll the annular space from the casing shoe to a minimum of 500 feet measured depth or (d)(5) true vertical depth, whichever is greater, It appears the 3-1/4” liner is not cemented. I have not seen jusƟĮcaƟon from Hilcorp determining the HRZ to be equal to or a greater barrier than cement. AOGCC will require empirical jusƟĮcaƟon that the HRZ is equal to or beƩer for a variance. If Hilcorp is requesƟng a waiver, then clear jusƟĮcaƟon of the risk and beneĮt why this PTD should be approved. Second The schemaƟc shows a 4-1/2” x 5-1/2” Ňow thru whipstock at 9965’ MD. The Ňow through whipstock is placed adjacent to an uncemented 3-1/4” liner that communicates to the reservoir via an uncemented OH x 3-1/4” in the upcoming ’B’ lateral. This provides a Ňow path from the parent well to the new sidetrack and is only isolated from the produc Ɵon tubing with a liner top packer and an unapproved HRZ barrier. This appears to be an ‘L1’. Also, AOGCC will want jusƟĮcaƟon or evidence that the proposed cement squeeze in the Įnal reservoir plug is competent cement plug of minimum of ~100’ MD within the conĮning zones. Per regula Ɵon: 20 AAC 25.112. Well plugging requirements c) Plugging of cased por Ɵons of a wellbore must be performed in a manner that ensures that all hydrocarbons and freshwater are conĮned to their respecƟve indigenous strata and are prevented from migraƟng into other strata or to the surface. The minimum requirements for plugging cased por Ɵons of a wellbore are as follows: ………….. The process of bullheading cement through perforaƟons does not demonstrate isolaƟon. How will Hilcorp demonstrate isolaƟon through cemented 2-2/8” x 3-1/4” to the 3-1/4” x 5-1/2” annulus of the exisƟng producƟon liner? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 Cell 4 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). From: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > Sent: Monday, November 4, 2024 12:04 PM To: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Boman, Wade C (OGC) <wade.boman@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Wade, Just following up on Sean’s email from last week. Typically, as part of the Sundry request on most CTD sidetrack we request a variance for alternate plug placement per 20 AAC 25.112. See below the screenshot from the D-03 Sundry. Cement is planned to the top of the 2-3/8” which extends beyond the top of the D-03 parent perfs and the 3-1/2” liner which should isolate any production from the parent’s perforations. If we believe we are getting production from the parent perforations, we will likely set a liner top packer above the 2-3/8” liner in the tubing to isolate the parent production. The intent is to abandon the parent production. Let me know if you want to discuss further. 5 Ryan Ciolkosz | Drilling Engineer C: 907.244.4357 | O: 907.564.4413 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From: Sean McLaughlin <Sean.Mclaughlin@hilcorp.com> Sent: Wednesday, October 30, 2024 5:05 PM To: Boman, Wade C (OGC) <wade.boman@alaska.gov>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Hi Wade, I think I see what you are getting at, but it is unconventional and not in line with our accounting. There maybe a hang up between plugging and abandonment. I believe the parent well will be e Ưectively plugged with the whipstock set in the HRZ shale. I don’t believe Ʋow is possible from the parent and neither is access or reentry. Adding a lateral usually means keeping parent production, reserves, or utility. None of that exists in this case. Setting the whipstock eƯectively plugs the parent well and that would prompt a new wellbore. I agree abandonment will occur when the annulus is Ʊlled with cement. 6 Would you reconsider the lateral designation for this project? Thank you, sean From: Boman, Wade C (OGC) <wade.boman@alaska.gov> Sent: Wednesday, October 30, 2024 3:47 PM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com >; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, I think that looks good to include in the PTD. Something that has come up is that with this design the parent wellbore would not be abandoned until the proposed cement is placed in the 3-1/2 x 5-1/2 annulus at time of P&A, as described below (there would only be a whipstock between D-03A’s liner top and the new liner top packer). So, this would make the new sidetrack a lateral of the parent (D-03AL1) rather than its own standalone wellbore (D-03B). Hence, the verbiage in the PTD “This completion will isolate and abandon the parent Ivishak perfs” would have to be removed, and the name would need to be changed. Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907-793-1238 cell: 907-687-4468 From: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > Sent: Wednesday, October 30, 2024 1:02 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Mel/Wade, Thanks for the clariƱcation, would the following verbiage and illustration in the PTD be acceptable? Hilcorp requests the AOGCC approval for alternate plug placement at abandonment per 20 AAC 25.112 using the following methods: 1. At abandonment, the well would be perforated across the 2-3/8”x3-1/2” pipe over the cased hole section from 9965’ to 9416’ MD. The 3-1/2” x 5-1/2” annulus would be cemented with a cement plug placed and squeezed into the perforations from 9965’ to 9416’ MD. This would provide 549’ of concentric lateral CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 7 cement isolation from the reservoir up all annuli. See schematic below for illustration of Ʊnal plug placement and lateral barriers. Ryan Ciolkosz | Drilling Engineer C: 907.244.4357 | O: 907.564.4413 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, October 29, 2024 10:08 AM 8 To: Boman, Wade C (OGC) <wade.boman@alaska.gov>; Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, The expectation is that Hilcorp identify the regulations (in this case 20 AAC 25.030 (d)(5)) where they are requesting a variance or waiver in the PTD or sundry then provide a justiƱcation why AOGCC should approve. For most cases presented by Hilcorp, they have good physical justiƱcation why it should be approved, but the record needs to be documented. AOGCC identiƱes this well design as possibly requiring a waiver for the Ʊnal reservoir abandonment plug in the future at the end of the economic life. To approve this design AOGCC would want to see Hilcorp’s proposal for abandonment. I think a schematic describing the placement of cement plugs would be suƯicient. This is not unique to the regulations. CO736 requires a Ʊnal abandonment schematic. When CTD exits the wellbore in the overburden, I think they should consider including the Ʊnal abandonment schematic (at least for the reservoir plug). For Hilcorp’s understanding regarding the Ʊnal abandonment, most CTD wells exit the parent within the PB oil pool and AOGCC regulates this as a single indigenous oil zone with high vertical permeability. As long as the Ʊnal abandonment has cement across all annuli of su Ưicient length within the conƱning zones, preferably at the base of the conƱning zones, AOGCC has not required cement across the perforations within the reservoir. I hope this helps. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 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). From: Boman, Wade C (OGC) <wade.boman@alaska.gov> Sent: Monday, October 28, 2024 12:44 PM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com >; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com >; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, thanks for the supplied details. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 9 Our main concern is that there will be newly placed pipe (the 3-1/2 and 3-1/4) that will be an intermediate string, uncemented. This does not meet the requirements of 20 AAC 25.030 (d)(5). Additionally, this uncemented section reaches above the cement in both the 5-1/2 x 9-5/8 annulus and in the 9-5/8 x OH, thereby creating a potential pathway from the 3-1/4 x OH section, up into the 4-1/2 x 9-5/8 annulus. We would need to see 20 AAC 25.030 (d)(5) satisƱed by cement being placed around the 3-1/4 and the 3-1/4 string. Also, please submit a new 10-401 application with the new WBS included (but thank you for sending the proposed WBS screenshot in the below email). Also, unless I’m missing something, the cement top at 9342’ behind the 9-5/8 isn’t being shown on the new schematic section. Thanks. -Wade Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907-793-1238 cell: 907-687-4468 From: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > Sent: Monday, October 28, 2024 10:10 AM To: Boman, Wade C (OGC) <wade.boman@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com >; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com > Subject: RE: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Wade, As discussed over the phone, please see my response to your questions/concerns below: Intermediate and Production casing (20 AAC 25.030(d)(5)) The top of the of the conƱning HRZ/Kingak shale is at 8511’ MD/7153’ TVD which is 1454’ MD/1277’ TVD above the D-03B Kick oƯ point. See the diagram below for reference. The KOP is ~70’ TVD above the top of the Prudhoe Pool. This leaves ~1207’ TVD of conƱning shale above the KOP. The original well was cemented throughout this section of the wellbore up to the top of the DV collar at 7097’ MD. A cement log was run and conƱrmed cement up to and above the conƱning shale at 8511’ MD behind the 9-5/8” casing. The 9-5/8” casing would still be considered the production casing in reference to 20 AAC 25.030(d)(5) as it still satisƱes all the conditions outline in the statute. The “casing shoe” as referenced in the statute would now be at the D-03A KOP (9965’ MD). Future Abandonment (20 AAC 25.112) 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. 10 In addition to the wellbore conditions noted above, a SCMT run on 06/02/06 logged cement up to 9416’ MD between the 5-1/2” and 9-5/8” casing. To provide concentric cement isolation across the wellbore adjacent to the conƱning shale, the standard procedure would be to perforate the 2-3/8”x3-1/2” pipe across the cased hole section and cement that annulus with a cement plug at abandonment. Alternatively, a cement plug could be placed directly above the production packer inside the 4-1/2” tubing and in the 4-1/2” x 9-5/8” annulus. Formation Integrity test after milling the window I don’t think it makes sense to perform an FIT after milling out the window as cement isolation above the window has been veriƱed via CBL behind the 9-5/8” casing. Also, performing an FIT in the Kingak will likely lead to wellbore instability and any leak oƯ would likely be going into the perforations in the 2-7/8” liner below the whipstock. 11 Also, see the attached updated full wellbore schematic. Let me know if you have any more follow up questions or concerns or would like to discuss over the phone/in person. Ryan Ciolkosz | Drilling Engineer C: 907.244.4357 | O: 907.564.4413 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From: Boman, Wade C (OGC) <wade.boman@alaska.gov> Sent: Tuesday, October 22, 2024 3:22 PM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com >; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, upon closer inspection of the schematic, it’s now clearer that the bottom of the 3-1/2” x 3-1/4” liner is located at 10019’ MD, well below the whipstock depth. However, we still have concerns, chief of which is Mel’s Ʊrst question below. The 3-1/2” and 3-1/4” liner are, in this case, production casing. If no cement is placed behind it, this would clearly not satisfy 20 AAC 25.030(d)(5). Other concerns are of the WBS itself. x The whipstock should be in red, as it is part of the proposed new well. x The TOC behind the 9-5/8 casing is shown at 9342’ MD, which is Ʊne, and the WBS shows it as “tagged,” yet Page 3 of the program mentions the TOC at 9342’ MD is known from a CBL ran in 1976. The WBS should match the program. x The existing cement between the 5” tubing and the and 9-5/8 casing is clearly shown on D-03A’s WBS (with TOC logged at 9416’ MD via SCMT in 2006), but this same cement is not shown at all in the proposed WBS for D-03B. Instead, this annulus is shown blank in the proposed WBS. This should be included so that it’s visually clear, especially since reservoir isolation concerns are an issue. x The straight red lines below the end of the 3-1/4” protection liner make it look as though there are concentric liner strings from 10019’ MD on. Please remove those red lines, as they make it seem that the 3- 1/4” liner extends to TD. Thanks. -Wade Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907-793-1238 cell: 907-687-4468 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Tuesday, October 22, 2024 3:16 PM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 12 Cc: Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: RE: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, Wade pointed out there is a little tiny liner shoe on your schematic below the whipstock at 10,019’ MD which looks like it is a shoe on the 2-3/8” so it is now clear to me the depth you are running the 3-1/4” to. We still need all the other information though. Clear schematics are always appreciated. Proposed whipstocks and new jewelry in red. Shoes clearly visible. Tapered strings actually tapered on the schematic. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 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. Wade From: Rixse, Melvin G (OGC) Sent: Tuesday, October 22, 2024 9:34 AM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com > Cc: Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: PTD 229-129 PBU D-03B Compliance Clarifications Ryan, What is Hilcorp’s plan to provide compliance to 20 AAC 25.030(d)(5)? It appears there is no plan to cement the 3-1/4” x OH annulus, correct? intermediate and production casing must be cemented with suƯicient cement to Ʊll the annular space from the casing shoe to a minimum of 500 feet measured depth or (d)(5) true vertical depth, whichever is greater, above all signiƱcant hydrocarbon zones and abnormally geo-pressured strata or, if zonal coverage is not required under (a) of this section, from the casing shoe to a minimum of 500 feet measured depth or true vertical depth, whichever is greater, above the casing shoe; if indications of improper cementing exist, such as lost returns, or if the formation integrity test shows an inadequate cement job, If Hilcorp is requesting a variance to 20 AAC 25.030(d)(5), please note the regulation and the method to assure an equal to or greater method for compliance to the regulation in the PTD. Also, regarding this regulation, it usually assures that the Ʊnal abandonment will require only on additional plug in the tubing or liner to assure a proper Ʊnal reservoir abandonment. It is not clear to me how Hilcorp will place a Ʊnal 13 reservoir abandonment plug across all annuli at the top of the reservoir when this wel l ends its economic life. Please describe. The schematic shows that the 3-1/2” x 3-1/4” liner will be run to 9950’ MD. Eline is setting a whipstock at 9965’ MD. It is not clear to me why you would be setting the 3-1/2” x 3-1/4” as a protection string across the Kingak to TShublik? What MD is TShublik? Why is the 3-1/2” x 3-1/4” shoe above the whipstock? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 OƯice 907-297-8474 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. Wade Boman 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 d issemination, 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. 14 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. 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. 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 d issemination, 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. 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 Gluyas, Gavin R (OGC) From:Boman, Wade C (OGC) Sent:Friday, January 17, 2025 3:44 PM To:Ryan Ciolkosz Cc:Trevor Hyatt; Sean McLaughlin; Joseph Lastufka; Lau, Jack J (OGC) Subject:RE: PBU D-03B (PTD 224-129) Ryan, I separated responses below, for ease of reading. D-03A lateral abandonment The proposed abandonment plans for the D-03A lateral would satisfy 20 AAC 25.112. I’m assuming you meant to include something akin to the red text below: SL: Run CBL from deviation to packer at 9213’ EL: Set 2-7/8” cement retainer at 10,142’. Punch 2-7/8” Liner from 10137’ to 10132’ MD Coil: Stab into retainer and pump 8.0 bbls of Class G and un-stab from retainer. Coil then lays in cement above the cement retainer in the 2-7/8” and circ into the 2-7/8” x 5-1/2” annulus. FB: WOC and MIT-T to 2500 psi D-03B request for variance to 20 AAC 25.030(d)(5) A granted variance to 25.030(d)(5). would mean the methods applied would meet or exceed the eƯects of the protection string being cemented. There are some mitigative measures that would help justify such a variance, such as: x FIT – An FIT performed after the window is milled and 10-20 feet of formation is cut would give conƱdence that integrity exists outside the 9-5/8 that would support forgoing cement around the protection string. Is an FIT planned? x A LTP would provide additional barrier to formation, further supporting forgoing a cemented protection string. Is a LTP planned to be installed? x A longer liner lap would provide still more barrier to formation. The current plan has only 25’ of cement from the top of the 3-1/2” to the top of the 2-3/8” liner. If the liner was brought up to the packer depth, roughly 75’ of cement would be possible (see diagram below). Has a longer liner lap been considered? x The former point also brings into consideration 20 AAC 25.030(d)(6), which requires a minimum of 100’ overlap between inner and outer strings: “if the intermediate or production string is a liner, a minimum of 100 measured feet overlap between the outer and inner strings is required…”. An increased cemented liner lap length (between the 2-3/8” (liner) and 4-1/2” (outer string) would get nearer the requirements of (d)(6) and also further support forgoing a cemented protection string. A request for a variance to 20 AAC 25.030(d)(6) would also be needed. x Finally, a full, complete, detailed procedure for the entire CTD drilling package will help the AOGCC decide on granting the variance. This would be the full drilling plan, as is supplied for rotary PTDs, included in the 10-401. The AOGCC wants to see going forward for all CTD PTD applications. 2 Wade Boman Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave, Anchorage, AK 99501 wade.boman@alaska.gov office: 907-793-1238 cell: 907-687-4468 From: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Sent: Thursday, January 16, 2025 10:36 AM To: Boman, Wade C (OGC) <wade.boman@alaska.gov> Cc: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>; Sean McLaughlin <Sean.Mclaughlin@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU D-03B (PTD 224-129) Wade, Looking to move forward with D-03 as we continue to push this on back on the schedule waiting on Permit/Sundry approval. Following up on your last email below regarding the variance to 25.112 and 25.030 not being granted due to only 30’ of cement and a liner top packer isolating the A lateral. Would the AOGCC consider approval of the D-03A/B permit and sundry with the addition of the following procedure for abandonment of the A lateral in addition to the request for variances outlined below? 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. 3 A Lateral Abandonment Procedure to be outlined in the Sundry: SL: Run CBL from deviation to packer at 9213’ EL: Set 2-7/8” cement retainer at 10,142’. Punch 2-7/8” Liner from 10137’ to 10132’ MD Coil: Stab into retainer and pump 8.0 bbls of Class G and un-stab from retainer FB: WOC and MIT-T to 2500 psi Hilcorp requests the AOGCC grant a variance from 20 AAC 25.030(d)(5) for wellbore kick oƯ in the Kingak shale and running an uncemented 3-1/2” x 3-1/2” liner to the top of the Prudhoe Pool based upon the following information: The window will be milled and D-03B kicked oƯ in the Kingak shale at 9965’ MD (8432’ TVD) (Just above the production interval as per 20 AAC 25.030(c)(5)) and a 3-1/2” x 3-1/4” protection string set at the Top of Shublik around 10,017’ MD. (Sag formation is faulted out in this area). This protection string will not comply with the requirements for an “intermediate or production casing” outlined in 20 AAC 25.030. Records indicate that 2050 sacks of cement were pumped during the Ʊrst cement stage behind the 9-5/8” casing in the original D-03 wellbore. Based on volumetric calculations, the expected TOC for the Ʊrst cement stage behind the 9-5/8” casing is at 5420’ MD (Based on 40% washout). Losses were noted before and during the cement job, however, cement returns from Ʊrst stage were noted while circulating through the 9-5/8” DV collar at 7097’ MD in preparation for the 2nd cement stage. The CBL ran in 7-7-1970 indicates TOC at 4444’ MD behind the 9-5/8” casing. (See schematic below) A minimum of 500’ MD and 250’ TVD of cement exists behind the 9-5/8” production casing above the planned KOP and the 9-5/8” production casing KOP is just above the productive interval which meets the minimum requirements for 20 AAC 25.030 and will meet the intent of conƱning reservoir Ʋuids to their respective pools. 4 5 Hilcorp requests the AOGCC grant a variance approval for future alternate plug placement at abandonment per 20 AAC 25.112 using the following methods: At the time of well abandonment, the following procedure is proposed to satisfy 20 AAC 25.112. Lateral and wellbore will be abandoned to the top of the reservoir by the following displacement method: • Coil: Perforate across the 3-1/2” x 3-1/4” pipe from 10,017’ to 9416’ MD. Lay in cement plug to Ʊll the wellbore from PBTD to 9416’ MD (549’ lateral cement coverage across the top of reservoir • FB: WOC. Pressure test cement plug to 2000 psi. Ryan Ciolkosz Drilling Engineer | C: 907.244.4357 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H 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 d issemination, 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. 6 1 Gluyas, Gavin R (OGC) From:AOGCC Permitting (CED sponsored) Sent:Friday, November 15, 2024 3:00 PM To:Joseph Lastufka Cc:Ryan Ciolkosz; Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC); Guhl, Meredith D (OGC); Rixse, Melvin G (OGC); Boman, Wade C (OGC) Subject:RE: PBU D-03B 10-401 Permit to Drill (Replacement) Categories:CDR2-3 Hello Joe, This application has been received for processing. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 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 conƱdential 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 Ʊrst saving or forwarding it, and so that the AOGCC is aware of the mistake in sending it to you, contact Grace Christianson at (907 -793-1230) or (grace.christianson@alaska.gov). From: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Sent: Friday, November 15, 2024 2:48 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Boman, Wade C (OGC) <wade.boman@alaska.gov> Subject: PBU D-03B 10-401 Permit to Drill (Replacement) All, Please see attached electronic distribution Replacement PTD for PBU D-03B. Please let me know if you have any questions. Thanks! Thanks, Joe Lastufka Sr. Drilling Technologist 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 Hilcorp North Slope, LLC Office: (907)777-8400, Cell:(907)227-8496 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 d issemination, 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. WELL PERMIT CHECKLIST Company Hilcorp North Slope, LLC Well Name:PRUDHOE BAY UNIT D-03B Initial Class/Type DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Program DEVField & Pool Well bore seg Annular DisposalPTD#:2250080 PRUDHOE BAY, PRUDHOE OIL - 640150 NA1Permit fee attached Yes ADL0282852Lease number appropriate Yes3Unique well name and number Yes PRUDHOE BAY, PRUDHOE OIL - 640150 - governed by CO 341J4Well located in a defined pool Yes5Well located proper distance from drilling unit boundary NA6Well located proper distance from other wells Yes7Sufficient acreage available in drilling unit Yes8If deviated, is wellbore plat included Yes9Operator only affected party Yes10Operator has appropriate bond in force Yes11Permit can be issued without conservation order Yes12Permit can be issued without administrative approval Yes13Can permit be approved before 15-day wait NA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA15All wells within 1/4 mile area of review identified (For service well only) NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only) NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA This well is a CTD sidetrack from an existing wellbore with pressure integrity.18 Conductor string provided NA All drilling on this sidetrack will be below the existing SC shoe.19 Surface casing protects all known USDWs NA This well is a CTD sidetrack from an existing wellbore with pressure integrity.20 CMT vol adequate to circulate on conductor & surf csg NA This well is a CTD sidetrack from an existing wellbore with pressure integrity.21 CMT vol adequate to tie-in long string to surf csg Yes Fully cemented production liner. The parent well is being cemented across all zones.22 CMT will cover all known productive horizons Yes23Casing designs adequate for C, T, B & permafrost Yes CDR2/CDR3 both have adequate tankage and good trucking support.24 Adequate tankage or reserve pit Yes Sundry 325-04125If a re-drill, has a 10-403 for abandonment been approved No D-07B fails anticollision. D-07B was abandonded during CTD sidetrack D-07C.26 Adequate wellbore separation proposed NA All drilling will be below the SC shoe.27 If diverter required, does it meet regulations Yes MPD w/8.4 ppg mud, and res press of 7.3 ppg equivalent. 1.5x wellbore vol of KWF on location.28 Drilling fluid program schematic & equip list adequate Yes CT packoff, flow cross, annular, blind/shear, CT pipe slips, flow cross, BHA pipe slips, CT pipe slips29BOPEs, do they meet regulation Yes 7-1/16" 5000 psi stack, pressure tested to 3500 psi.30 BOPE press rating appropriate; test to (put psig in comments) Yes Flanged choke and kill lines between dual combis w/remote choke.31 Choke manifold complies w/API RP-53 (May 84) Yes32Work will occur without operation shutdown No D-Pad is not an H2S pad. Max H-pad reading was 34 ppm.33 Is presence of H2S gas probable NA This is a development well.34 Mechanical condition of wells within AOR verified (For service well only) NA D-Pad wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measures Yes Expected reservoir pressure is 7.3 ppg EMW. MPD to be employed.36 Data presented on potential overpressure zones NA37Seismic analysis of shallow gas zones NA38Seabed condition survey (if off-shore) NA39Contact name/phone for weekly progress reports [exploratory only] Appr ADD Date 2/4/2025 Appr WCB Date 2/7/2025 Appr ADD Date 2/4/2025 Administration Engineering Geology Geologic Commissioner:Date:Engineering Commissioner:Date Public Commissioner Date *&:JLC 2/7/2025