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Home My WebLink About224-076Nolan 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: 2/8/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type BCU 09A 50133204450100 224113 11/13/2024 YELLOWJACKET GPT-PERF BCU 09A 50133204450100 224113 10/30/2024 YELLOWJACKET GPT BCU 11A 50133205210100 224123 11/9/2024 YELLOWJACKET SCBL BCU 25 50133206440000 214132 11/2/2024 YELLOWJACKET SCBL END 2-74 REVISED 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 HVA 10 50231200280000 204186 11/13/2024 YELLOWJACKET GPT-PERF KU 23-07A 50133207300000 224126 11/23/2024 YELLOWJACKET SCBL NCIU A-21 50883201990000 224086 11/29/2024 AK E-LINE CaliperSurvey PAXTON 6 50133207070000 222054 11/7/2024 YELLOWJACKET PERF PBU 01-37 50029236330000 219073 11/23/2024 BAKER MRPM PBU 06-15A 50029204590200 224108 12/26/2024 BAKER MRPM PBU 06-19B 50029207910200 224095 12/10/2024 BAKER MRPM PBU 07-29E 50029217820500 213001 11/26/2024 BAKER SPN PBU 14-31A 50029209890100 224090 11/10/2024 BAKER MRPM PBU 14-41A 50029222900100 224076 11/9/2024 BAKER MRPM SRU 241-33B 50133206960000 221053 11/5/2024 YELLOWJACKET GPT-PERF Revision Explanation: Annotations added to processed log. Please include current contact information if different from above. T40053 T40053 T40054 T40055 T40056 T40057 T40058 T40059 T40060 T40061 T40062 T40063 T40064 T40065 T40066 T40067 PBU 14-41A 50029222900100 224076 11/9/2024 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.07 13:25:23 -09'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 14-41A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 224-076 50-029-22290-01-00 11688 Conductor Surface Intermediate Liner Liner 8962 80 3217 9078 305 2844 11672 20" 10-3/4" 7-5/8" 5-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8958 34 - 114 34 - 3251 32 - 9110 8911 - 9216 8844 - 11688 34 - 114 34 - 3251 32 - 8653 8469 - 8751 8408 - 8962 none 520 2480 5120 6820 10530 none 1530 5210 8180 7740 10160 11499 - 11581 4-1/2" 12.6# 13Cr80 30 - 8929 8912 - 8935 Structural 4-1/2" Baker SABL-3 , 8866 , 8428 No SSSV 8866 8428 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 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 0028312 30 - 8486 423 509 9506 1440 4003 5860 1361 1666 264 277 N/A 13b. Pools active after work:PRUDHOE OIL 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 1:45 pm, Jan 24, 2025 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Date: 2025.01.24 13:00:00 - 09'00' David Bjork (3888) WCB 2-11-2025 A.Dewhurst 13FEB25 DSR-1/31/25 RBDMS JSB 013025 ACTIVITYDATE SUMMARY 12/30/2024 CTU#1 1.75" CT. Job Scope: Depth Log / Adperf MIRU CTU. Well Flowing on Arrival w/ Gaslift. Function Test BOP's. Shut in well. Freeze Protect Flowline to 14-41/31 Intersection w/ 10 bbls 60/40 Meth. RIH w/ 2.20" Logging Carrier & 2.25" Nozzle. Tag @ 11,646.75' E / 11,661' M / 11,646.33 HES Box. Log up from compression 50 fpm. Flag (yellow & pink stripes) 11,449.61' E / 11,463' M / 11,449.16' HES Box. Log up 50 fpm to 8798.91' E / 8821' M / 8798.17' HES Box. POOH. Pump 93 bbls slick 1% kcl w/ SL then FP well 4 bbls 60/40 + 34 bbls diesel. BD HES Logging Tools / +23' Corr and verified from OE Jerry Lau. PT MHA. MU HES FH & 2" MaxForce Perf Guns 30'. ***Continue on WSR 12/31/24*** 12/31/2024 CTU#1 1.75" CT. Job Scope: Depth Log / Adperf RIH w/ 30' of HES 2" MaxForce Perf Guns. Corr Depth @ Flag. Perf 11,499' - 11,529'. POOH. LD HES 2" spent guns. RDMO ***Job Complete*** Daily Report of Well Operations PBU 14-41A Perf 11,499' - 11,529'. POOH. 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: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241205 Well API #PTD #Log Date Log Company Log Type AOGCC ESet AN 15(GRANITE PT ST 18742 15) 50733200700000 167082 11/18/2024 AK E-LINE Perf BRU 221-26 50283202010000 224098 10/24/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/21/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/30/2024 AK E-LINE Perf BRU 241-23 50283201910000 223061 11/8/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 11/12/2024 AK E-LINE Plug/Perf END 2-72 50029237810000 224016 10/16/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 10/18/2024 HALLIBURTON COILFLAG MGS-ST 17595-05 50733100710000 165038 10/6/2024 AK E-LINE CBL MPU F-109 50029235960000 218014 10/28/2024 READ CaliperSurvey MPU J-02 50029220710000 190096 11/16/2024 READ CaliperSurvey MPU J-47 50029238010000 224120 11/9/2024 READ LeakPointSurvey MPU D-01 50029206640000 181144 10/23/2024 AK E-LINE TubingPunch MPU F-02 50029226730000 196070 11/18/2024 READ CaliperSurvey MPU I-08 50029228210000 197192 10/22/2024 AK E-LINE TubingPunch MPU I-08 50029228210000 197192 10/26/2024 HALLIBURTON JETCUT MPU L-60 50029236780000 220048 10/26/2024 HALLIBURTON MFC24 MRU M-25 50733203910000 187086 11/15/2024 AK E-LINE Plug NCIU A-21 50883201990000 224086 11/9/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/19/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/30/2024 AK E-LINE Perf NCIU A-21 50883201990000 224086 10/30/2024 AK E-LINE Plug/Perf PBU 06-07A 50029202990100 224043 9/30/2024 HALLIBURTON RBT PBU 14-41A 50029222900100 224076 11/8/2024 HALLIBURTON RBT PBU H-36A 50029226050100 200025 10/26/2024 HALLIBURTON RBT PCU 02A 50283200220100 224110 11/24/2024 AK E-LINE Perf Please include current contact information if different from above. T39808 T39809 T39810 T39810 T39811 T39812 T39813 T39813 T39814 T39815 T39816 T39817 T39818 T39819 T39820 T39820 T39821 T39822 T39823 T39823 T39823 T39823 T39824 T39825 T39826 T39827 PBU 14-41A 50029222900100 224076 11/8/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.05 14:52:46 -09'00' 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: 11/13/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU 14-41A PTD: 224-076 API: 50-029-22290-01-00 FINAL LWD FORMATION EVALUATION LOGS (10/11/2024 to 10/17/2024) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Main Folders: Please include current contact information if different from above. 224-076 T39770 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.14 08:06:06 -09'00' 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 Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 14-41A Hilcorp Alaska, LLC Permit to Drill Number: 224-076 Surface Location: 216' FSL, 1329 FEL, Sec. 04, T10N, R14E, UM, AK Bottomhole Location: 1717' FNL, 1836' FWL, Sec. 04, T10N, R14E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this th day of August 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.28 13:45:11 -08'00' 3-1/2"x3-1/4" Drilling Manager 06/03/24 Monty M Myers By Grace Christianson at 11:24 am, Jun 03, 2024 A.Dewhurst 26AUG24 224-076 MGR12JUN2024 * BOPE test to 3500 psi. * Variance to 20 AAC 25.112 (i) Alternate plug placement approved with fully cemented production liner. * Approved for post rig service coil perforating. Gun length to be no longer than 500' in length during open hole deployment. 50-029-22290-01-00 DSR-6/4/24*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.08.28 13:45:22 -08'00' 08/28/24 08/28/24 RBDMS JSB 083024 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: June 3, 2024 Re:14-41A Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well 14-41 with the Nabors CDR2 Coiled Tubing Drilling. Proposed plan for 14-41A Producer: See 14-41 Sundry request for complete pre-rig details - Prior to drilling activities, Slickline will drift for a whipstock and dummy the GLVs, service coil will perform scale removal treatment if necessary, E-line will set the 4-1/2" x 5-1/2" whipstock, and then service coil will mill the XN nipple and 3.80" window if a service unit is available. A coil tubing drilling sidetrack will be drilled with the Nabors CDR3 rig. The rig will move in, test BOPE and kill the well. If not done pre-rig, CDR will mill a single string 3.80" window + 10' of formation will be milled. The well will kick off drilling in Ivishak and drill an S-shaped well through Zones 2 and 3 to TD. The proposed sidetrack will be completed with a 3-1/2" x 3-1/4" x 2-7/8"” 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will target isolating and abandoning the parent Ivishak perfs. 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 14-41 Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift and DMY GLVs 2. Fullbore : MIT-IA 3. E-Line : Set Whipstock – 9218’ (9220’ Pinch Point ) @ 0° ROHS 4. Coil : Scale Treatment, Mill XN nipple and 3.80" Window (if window not possible, mill with rig) 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in October 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2387 psi). 2. Mill 3.80” Window (only if not done pre-rig) 3. Drill build section: 4.25" OH, ~180' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2418' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 37 bbls, 15.3 ppg Class G, TOC at TOL*. 7. Freeze protect well to a min 2,200' TVD. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig RPM, CBL, and perforate. PTD 224-076 Sundry 324-326 24 hour notice for AOGCC witness. 24 hour notice for AOGCC to witness BOPE test to 3500 psi. 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: MPD Pressure at the Planned Window (9218' MD -8,653' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,410 psi 4,410 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 553 psi 0 psi 0.09 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,870 psi 3,870 psi 8.6 B+C Mud + ECD Combined 4,423 psi 3,870 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 540 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,267 psi at 8,800 TVD. (7.1 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2387 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” hole for the entirety of the production hole section. Liner Program: x 3-1/2", 9.3#, 13Cr/Solid: 8,840' MD – 9,210' MD (370' liner) x 3-1/4", 6.6#, 13Cr/Solid: 9,210' MD – 9,500' MD (290' liner) x 2-7/8", 6.5#, 13Cr/Solid: 9,500' MD – 11,818' MD (2,316' 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. 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 Solid 2-7/8” Liner Running Ram Change: Change out 3” pipe/slip rams (for drilling) to 2-3/8” x 3-1/2” VBR rams for liner run. Test VBR rams to 250 psi and 3,500 psi. x A X-over shall be made up to a 2 3/8" safety joint including a TIW valve for all tubulars ran in hole. x 2 3/8" 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 3/8" safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: x Directional plan attached. Maximum planned hole angle is 105°. Inclination at kick off point is 20°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – ~18,000' x Distance to nearest well within pool – 550 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 ~30' perforated post rig – See attached extended perforating procedure. x 2" 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 Ivishak at 9204’ MD in the parent Anti-Collision Failures: x No anti-collision failures with the 14-41A wellplan. Hazards: x DS 14 is an H2S pad. The last H2S reading on 14-41: 22 ppm on 07/26/2024. x Max H2S recorded on DS/Pad: 140 ppm. x 1 fault crossings expected. x Moderate lost circulation risk. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka (907-244-4357) DS 14 is an H2S pad 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 Distances from top of riser Excluding quick-test sub Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B3 B4 B1 B2 Kill Line Choke 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 3" LP hose open ended to Flowline CDR3-AC BOP Schematic CDR3 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 neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee $)$) $) $) $) $) $) $) $) ! !! !! !!!! ! ! ! ! D $) PLAN: 14-41A_BHL PLAN: 14-41A_TPH PLAN: 14-41A_SHL Oil Rim PAGas Cap PAADL028312 DS14 ALASCOM U010N014E Sec. 4 Sec. 9 PRUDHOE BAY UNIT X-04A 14-43 14-41 14-24 14-23 14-20 14-0214-01 14-02A Map Date: 2/19/2024 Prudhoe Bay Unit 14-41A Well wp01 E0 300 600 Feet Legend T14_41A_wp01 $)PLAN: 14-41A_BHL !PLAN: 14-41A_SHL D PLAN: 14-41A_TPH $)Other Bottom Holes (BHL) Other Well Paths Pad Footprint PA Boundary CO_341J AIO_4G Document Path: O:\AWS\GIS\Products\Alaska\NS\Wells\TRS_Distance\mxds\2024\NorthSlope_14-41A wp01.mxd 1600200024002800320036004000South(-)/North(+) (800 usft/in)-2400 -2000 -1600 -1200 -800 -400 0 400 West(-)/East(+) (800 usft/in)8642X-04A939276008000840088009200922914-2364006800720076008000840088009200940214-0176008000840088009200937514-4114-01A84008800916314-02A80008400880014-02B6800720076008000840088009200934414-028800898814-41A wp01Top of Window - 9220'MDEnd 35dls - 9400'MDTD - 11818'MD875088008850890089509000True Vertical Depth (100 usft/in)1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 Vertical Section at 310.00° (400 usft/in)14-41End 35dls - 9609'MD14-41A wp01Top of Window - 9220'MDEnd 35dls - 9400'MDTD - 11818'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 9220.00 20.60 348.07 8754.71 1932.68 -284.52 0.00 0.00 1460.262 9240.00 22.40 348.07 8773.32 1939.85 -286.04 9.00 0.00 1466.033 9310.00 46.90 348.07 8830.46 1978.50 -294.20 35.00 0.00 1497.134 9399.84 77.00 337.52 8872.31 2052.91 -318.33 35.00 -20.00 1563.435 9551.00 77.00 318.90 8906.31 2177.54 -395.58 12.00 -90.00 1702.736 9731.00 77.00 341.07 8946.81 2328.46 -482.77 12.00 90.00 1866.537 9847.00 77.00 326.78 8972.90 2429.73 -532.32 12.00 -90.00 1969.588 9962.02 90.00 331.46 8985.90 2527.61 -590.78 12.00 20.00 2077.289 10095.25 105.00 325.87 8968.55 2640.12 -659.15 12.00 -20.00 2201.9810 10255.00 105.00 306.02 8927.20 2750.46 -765.91 12.00 -90.00 2354.6911 10395.00 105.00 323.41 8890.97 2845.25 -861.64 12.00 90.00 2488.9412 10680.00 105.00 288.02 8817.20 3003.40 -1081.62 12.00 -90.00 2759.1213 10780.00 105.00 300.44 8791.32 3042.96 -1169.53 12.00 90.00 2851.8914 10912.63 90.00 295.05 8774.05 3103.88 -1285.58 12.00 -160.00 2979.9515 11043.63 75.25 289.56 8790.83 3153.13 -1405.36 12.00 -160.00 3103.3616 11164.00 75.25 274.62 8821.47 3177.43 -1518.86 12.00 -90.00 3205.9317 11374.00 75.25 300.68 8874.94 3238.47 -1710.72 12.00 90.00 3392.1318 11614.00 75.25 270.89 8936.05 3300.90 -1931.55 12.00 -90.00 3601.4319 11818.00 75.25 296.21 8987.98 3346.75 -2121.78 12.00 90.00 3776.63Project: Prudhoe BaySite: 14Well: 14-41Wellbore: PLAN: 14-41APlan: 14-41A wp01WELLBORE DETAILSParent Wellbore:14-41Top of Window: 9220.0014-41A wp01Depth From Depth To Survey/Plan Tool35.10 9220.00 1 : Schlumberger GCT multishot (14-41)3_Gyro-CT_pre-1998_Csg19220.00 11818.00 14-41A wp01 (PLAN: 14-41A) 3_MWDWELL DETAILSNorthing: 5940553.42Easting: 675105.88Lattitude: 70° 14' 35.7250 NLongitude: 148° 35' 8.3001 W14-41A wp01SECTION DETAILSHilcorp Alaska, LLCSURVEY PROGRAMNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04PROJECT DETAILSREFERENCE INFORMATIONCoordinate(N/E) Reference: Well 14-41, True NorthVertical (TVD) Reference: KB @ 74.00usft (64 : 41 10/3/1992 00:00)Measured Depth Reference: KB @ 74.00usft (64 : 41 10/3/1992 00:00)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureREFERENCE INFORMATION ! 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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. PRUDHOE OIL 224-076 PRUDHOE BAY PBU 14-41A WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT 14-41AInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2240760PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes ADL283122 Lease number appropriateYes3 Unique well name and numberYes PRUDHOE BAY, PRUDHOE OIL - 640150 - governed by CO 341J4 Well located in a defined poolYes5 Well located proper distance from drilling unit boundaryNA6 Well located proper distance from other wellsYes7 Sufficient acreage available in drilling unitYes8 If deviated, is wellbore plat includedYes9 Operator only affected partyYes10 Operator has appropriate bond in forceYes11 Permit can be issued without conservation orderYes12 Permit can be issued without administrative approvalYes13 Can permit be approved before 15-day waitNA14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForNA15 All wells within 1/4 mile area of review identified (For service well only)NA16 Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.18 Conductor string providedYes All drilling on this sidetrack will below existing surface casing shoe.19 Surface casing protects all known USDWsYes This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.20 CMT vol adequate to circulate on conductor & surf csgYes This well is a in zone CTD sidetrack from an existing wellbore with pressure integrity.21 CMT vol adequate to tie-in long string to surf csgYes Fully cemented production liner. Parent well isolates the reservoir.22 CMT will cover all known productive horizonsYes This well is a in zone CTD sidetrack from an existing well. Full integrity above sidetrack.23 Casing designs adequate for C, T, B & permafrostYes CDR3 has adequate tankage and good trucking support.24 Adequate tankage or reserve pitYes Sundry 324-32625 If a re-drill, has a 10-403 for abandonment been approvedYes Halliburton collision scan shows manageable collision risk.26 Adequate wellbore separation proposedNA All drilling below the surface casing shoe. No diverter required.27 If diverter required, does it meet regulationsYes MPD but reservoir pressure below water gradient.28 Drilling fluid program schematic & equip list adequateYes CT Packoff, flow cross, annular, blind shear, CT pipe slips, flow cross, BHA pipe slips, CT pipe slips29 BOPEs, do they meet regulationYes 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 combi's w remote choke31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes PBU DS 14-pad is an H2S pad >100 ppm. Monitoring will be required.33 Is presence of H2S gas probableNA This is a development well.34 Mechanical condition of wells within AOR verified (For service well only)No DS 14 wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes Pore pressure anticipated to be 7.1 ppg EMW; will be drilled using 8.4 ppg mud and coiled tubing with MPD.36 Data presented on potential overpressure zonesNA37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate8/26/2024ApprMGRDate6/12/2024ApprADDDate8/26/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 8/28/2024