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Home My WebLink About224-1557. 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-01B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 224-155 50-029-20054-02-00 11487 Intermediate Intermediate Liner Liner Liner 9014 7300 9277 190 326 2565 11112 10-3/4" x 9-5/8" 9-5/8" x 7" 4-1/2" 3-1/2" x 3-1/4" 2-3/8" 8883 2000 - 9300 23 - 9300 9138 - 9328 9002 - 9328 8922 - 11487 2000 - 8567 23 - 8567 8424 - 8592 8305 - 8592 8235 - 9014 None 2480 4760 7500 10530 11780 11112 5210 6870 8430 10160 11200 10568 - 11168 4-1/2" 12.6# 13Cr, L80 21 - 9142 8920 - 8901 Surface 4005 13-3/8" 25 - 4030 25 - 4030 3450 1950 4-1/2" Baker S3 Packer 9086, 8379 8928, 9086 8240, 8379 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 21 - 8428 N/A N/A 115 951 16416 3239 434 1056 700 1350 240 1020 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker SB3 Packer 8928, 8240 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 No SSSV Installed By Grace Christianson at 10:13 am, Aug 27, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.26 19:17:56 - 08'00' Torin Roschinger (4662) RBDMS JSB 082825 J.Lau 11/4/25 DSR-9/11/25 ACTIVITY DATE SUMMARY 8/3/2025 LRS CTU #1 1.50"CT 0.134"WT HT-110 Job Objective: Drift, Log, Perf MIRU. MU LRS 1.76" DJN drift BHA. Function test BOP. Load the well with safelube. RIH. Tag TD 11476 CTM. POOH. MU HES memory Gamma/CCL tool. RIH. Tag TD 11482 CTM. Log up. Flag coil 11144.93 CTM, Continue to log up to 9900'CTM. Confirm -13' correction. Standby for HES TCP to finish at L1-10. ***Continue on 8-4-25 WSR*** 8/4/2025 LRS CTU #1 1.50"CT 0.134"WT HT-110 Job Objective: Drift, Log, Ad Perf Continue standby on HES TCP, RIH w/ 1.56"x13' Millennium 6spf, 3.4gr, 60 degree phasing, correct depth to top shot, perf interval 11145-11158'. Freeze protect the tubing 38 bbls diesel. RDMO. ***Job Complete*** 8/23/2025 LRS CTU #1 1.5" CT .134" WT HT-110 Job Objective: Mill two extended range CIBPs MIRU CTU #1. MU LRS 1.75" DJN drift BHA. NU BOPs & Fnc Test. Load & kill well. RIH. Tag PBTD @ 11,475' CTM. POOH pumping displacement. BD LRS 1.75" DJN BHA. MU NS ctc / MHA & HES GR/CCL logging BHA. RIH and log from 11,461-8,350'. Flag pipe at 11,062' while logging OOH. POOH and download logging data, confirm -1' correction with Geo/OE. Make up NS 2-3/8" CIBP and RIH. ***Job Continued on WSR 8-23-25*** 8/24/2025 LRS CTU #1 1.5" CT .134" WT HT-110 Job Objective: Mill two extended range CIBPs ***Continued from WSR 8-23-25*** Continue RIH with CIBP BHA. Tie into flag from previous logging run, set top of CIBP at 11,112'. Paint second flag at 10,530' on way out of hole. Lay down CIBP BHA. MU Tirpoint 1.56"x22' gun 6spf 60 degree phasing. Corr Depth to top shot at White Flag. Perf 10,568'-10,590'. POOH - LD Spent perfs guns - recovered 1/2" ball. RDMO ***Job Complete*** Daily Report of Well Operations PBU D-01B 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: 6/18/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250618 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN 07RD2 50733200120200 195113 6/1/2025 AK E-LINE LDL AN 24RD 50733202850100 207170 6/1/2025 AK E-LINE LDL BRU 221-24 50283202020000 225027 5/29/2025 AK E-LINE CBL KALOTSA 10 50133207320000 224147 5/21/2025 AK E-LINE Perf KALOTSA 2 50133206590000 216155 5/25/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/27/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/26/2025 AK E-LINE Perf PBU 06-12C 50029204560300 225022 5/17/2025 HALLIBURTON RBT-COILFLAG PBU 15-32C 50029224620300 217104 5/27/2025 HALLIBURTON RBT PBU D-01B 50029200540200 224155 5/18/2025 BAKER MRPM PBU D-01B 50029200540200 224155 5/18/2025 HALLIBURTON RBT-COILFLAG PBU H-18A 50029208800100 224011 5/14/2025 BAKER MRPM PBU H-18A 50029208800100 224011 5/14/2025 HALLIBURTON RBT-COILFLAG PBU L-109 50029230460000 201201 5/24/2025 HALLIBURTON IPROF PBU L-115 50029230350000 201140 5/19/2025 HALLIBURTON IPROF PBU L-117 50029230390000 201167 5/30/2025 HALLIBURTON IPROF PBU N-07B 50029201370200 223122 6/7/2025 HALLIBURTON RBT PBU S-100A 50029229620100 224083 5/26/2025 HALLIBURTON PPROF-LDL PBU Z-34 50029234690000 212061 5/17/2025 HALLIBURTON IPROF-LDL Please include current contact information if different from above. T40566 T40567 T40568 T40569 T40570 T40571 T40571 T40572 T40573 T40574 T40574 T40575 T40575 T40576 T40577 T40578 T40579 T40580 T40581 PBU D-01B 50029200540200 224155 5/18/2025 BAKER MRPM PBU D-01B 50029200540200 224155 5/18/2025 HALLIBURTON RBT-COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.18 12:03:53 -08'00' 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: 06/05/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU D-01B PTD: 224-155 API: 50-029-20054-02-00 FINAL LWD FORMATION EVALUATION LOGS (05/01/2025 to 05/09/2025) 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. 224-155 T40531 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.06 08:13:03 -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 Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU D-01B Hilcorp Alaska, LLC Permit to Drill Number: 224-155 Surface Location: 2130’ FNL, 1067’ FEL, Sec 23, T11N, R13E, UM, AK Bottomhole Location: 182' FSL, 1177' FWL, Sec 23, 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 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, Gregory C. Wilson Commissioner DATED this 31st day of December 2024. Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.31 09:45:47 -09'00' By Grace Christianson at 9:14 am, Dec 17, 2024 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2024.12.16 17:24:35 - 09'00' Sean McLaughlin (4311) A.Dewhurst 20DEC24 January 15, 2025 DSR-12/18/24 50-029-20054-02-00 * BOPE test to 3500 psi. * Fully cemented liner to satisfy parent well abandonment approved variance per 20 AAC 25.112 (i) * Post rig perforating total BHA gun length not to exceed 500'. 224-155 MGR30DEC2024MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.31 09:43:11 -09'00' 12/31/24 12/31/24 RBDMS JSB 010225 WELL NAME: 19. Setting Depth MD Setting Depth TVD Casing Length Size Top Bottom Top Bottom Cementing Record Intermediate 7300 10-3/4" x 9-5/8" 2000 9300 2000 8567 2700 sx Class G Intermediate 1863 9-5/8" x 7"23 9300 23 8567 200 sx Class G Liner 1530 4-1/2" 9138 10668 8425 9071 180 sx Class G Liner 152 3-1/2" x 3-1/4" 9002 10197 8305 8982 17.5 Bbls Class G Attachment - Present Well Condition Summary (for Redrill Operations) PBU D-01A To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: December 16, 2024 Re:D-01B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well D-01A with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for D-01B Producer: See D-01A Sundry request for complete pre-rig details - Prior to drilling activities, slickline will DMY GLVs, Pull the 3-1/4" R NIP and plug, and drift for whipstock. E-line will set a 3-1/2" whipstock. If unable to set the whipstock, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or 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 3-1/4" whipstock. A single string 2.74" window + 10' of formation will be milled. The well will kick off drilling in the Shublik and land in Ivishak Zone 2. The lateral will continue in Zone 4, 3 and 2 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will completely isolate and abandon the parent Prudhoe Pool 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 D-01A Sundry submitted in concert with this request for full details. 1. Slickline : Pull Monopak packer/plug, drift for whipstock 2. E-Line : Set 3-1/4" whipstock @ 9,360' MD & orient @ 0 ROHS 3. Valve Shop : Pre-CTD Tree Work 4. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in February 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,447 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 2.74” Window (3-1/4" x 4-1/2" dual string exit) 3. Drill build section: 3.25" OH, ~390' (30 deg DLS planned). 4. Drill production lateral: 3.25" OH, ~2092' (12 deg DLS planned). Swap to KWF for liner. 5. Run 2-3/8” 13Cr solid liner 6. Pump primary cement job: 19 bbls, 14.8 ppg Class G, 1.332 (ft3/sk), 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. Service Coil : Post rig RPM, CBL, perforate ~20-30' 1.56" guns 3. Slickline : Set GLV's, contingent LTP Sundry 324-702 PTD 224-155 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”/3-1/8” (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 (9360' MD -8,619' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,392 psi 4,392 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 328 psi 0 psi 0.09 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,854 psi 3,854 psi 8.6 B+C Mud + ECD Combined 4,182 psi 3,854 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 210 psi 538 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 3.25” hole for the entirety of the production hole section. Liner Program: x 2-3/8", 4.6#, 13Cr Solid: 8,920' MD – 11,842' MD (2,922' 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 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. Directional: x Directional plan attached. Maximum planned hole angle is 105°. Inclination at kick off point is 33°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 24,375 ft x Distance to nearest well within pool – 1200 ft (A-44i) 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 10-30'' 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 Prudhoe Pool. x Formations: Top of Prudhoe Pool at 9203' MD in the parent Anti-Collision Failures: x D-19A fails anti-collision with the D-01B wp11 wellpath. D-19A was abandoned as part of the D-19B sidetrack which kicked off at 6231' MD. Current active wellbore is D-19C. Hazards: x DS/Pad is not an H2S pad. The last H2S reading on D-01A: 14 ppm on 4/13/22. x Max H2S recorded on DS/Pad: 34 ppm.. x 1 fault crossings expected. x Medium lost circulation risk. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka (907-244-4357) 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 -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 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 -3200-2800-2400-2000-1600-1200-800South(-)/North(+) (800 usft/in)-4400 -4000 -3600 -3200 -2800 -2400 -2000 -1600 -1200 West(-)/East(+) (800 usft/in)8995D-19A6 0006 4 0 0 6 8 00 7 2 00 7600800084008800D-31AD-31B7 6 0 0 8000840088009130D-17BD-16A760080008400880092009317D-168800D-17A4 800 5 2 0 0 5 60 060006400680 072007 6 0 0 8 000 8 400 8 8 00 92 0 0 93 2 2 D -17 560060006400680072007600D-088800 D-08B wp0564 0 0 6800720076008000840088009163D-08A7200760080008400D-318993D-31BPB168 0 0 7 20 0 7 6 0 0 8 0 0 0 8400 880092009303D-01880 0 9072D-01A88009 0 5 3 D -01 B w p 1 1Top of Window - 9360'MDEnd 30dls - 9750'MDLanding 90inc - 10104'MDCrest 90inc - 10976'MDTD - 11842'MD86008700880089009000True Vertical Depth (200 usft/in)600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 Vertical Section at 200.00° (400 usft/in)D-01D-01AD-01B wp11Top of Window - 9360'MDEnd 30dls - 9750'MDLanding 90inc - 10104'MDCrest 90inc - 10976'MDTD - 11842'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 9360.00 33.04 292.51 8619.21 -1116.92 -2177.61 0.00 0.00 1794.342 9380.00 34.84 292.51 8635.81 -1112.64 -2187.92 9.00 0.00 1793.853 9450.00 55.84 292.51 8684.74 -1093.69 -2233.66 30.00 0.00 1791.694 9750.00 49.31 166.80 8916.52 -1174.17 -2346.58 30.00 -142.00 1905.945 10103.86 90.00 180.15 9037.47 -1496.60 -2314.96 12.00 20.00 2198.116 10237.09 105.00 185.75 9020.11 -1628.09 -2321.63 12.00 20.00 2323.957 10433.00 105.00 210.08 8969.41 -1806.80 -2379.40 12.00 90.00 2511.648 10643.00 105.00 184.00 8915.06 -1999.07 -2438.33 12.00 -90.00 2712.479 10843.00 105.00 208.84 8863.29 -2182.93 -2492.51 12.00 90.00 2903.7710 10975.63 90.00 203.46 8846.02 -2300.63 -2550.17 12.00 -160.00 3034.1011 11108.86 75.00 209.05 8863.37 -2418.76 -2608.32 12.00 160.00 3164.9812 11212.00 75.00 196.24 8890.07 -2510.51 -2646.60 12.00 -90.00 3264.3013 11482.00 75.00 229.78 8959.95 -2726.10 -2786.66 12.00 90.00 3514.7914 11612.00 75.00 213.63 8993.59 -2819.54 -2869.93 12.00 -90.00 3631.0715 11842.00 75.00 242.20 9053.12 -2966.90 -3033.11 12.00 90.00 3825.36Project: Prudhoe BaySite: DWell: D-01Wellbore: D-01BPlan: D-01B wp11WELLBORE DETAILSParent Wellbore:D-01ATop of Window: 9360.00D-01B wp11Depth From Depth To Survey/Plan Tool108.42 9208.45 1 : Camera based gyro multisho (D-01) 3_CB-Film-GMS29322.00 9360.00 3 : MWD - Standard (D-01A) 3_MWD9360.00 11842.00 D-01B wp11 (D-01B) 3_MWDWELL DETAILSNorthing: 5958871.03Easting: 654096.71Lattitude: 70° 17' 40.3663 NLongitude: 148° 45' 8.0903 WD-01B wp11SECTION DETAILSHilcorp Alaska, LLCSURVEY PROGRAMNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04PROJECT DETAILSREFERENCE INFORMATIONCoordinate(N/E) Reference: Well D-01, True NorthVertical (TVD) Reference: KB @ 65.95usft (D-01A OKB)Measured Depth Reference: KB @ 65.95usft (D-01A OKB)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureREFERENCE INFORMATION !!" #$ % & " % ! 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A! , ) * 56 C / -) B) () B" 5&0& 7 ( # # # >. 4 4 4 > 4 4 4 > A A A >4 A A A >4 A A A >4 ; ; ; >A ; ; ; 2! > ; ; ; >.A 4 4 4 > 4 4( 4( > > >4 << << << > 0 6 0 5 ) - 8 ) 9 ( #.A %0= ' C < 6) -/ $ 8 "AD ,) !D E " &$$ * - &$$ $ * - !"#!$ % &' , ) -/ 7 $ 0 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. PBU D-01B 224-155 PRUDHOE BAY PRUDHOE OIL WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT D-01BInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2241550PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes ADL0282852 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 Flanged choke and kill lines between dual combi's w remote choke18 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 CDR rigs have adequate tankage and good trucking support.24 Adequate tankage or reserve pitYes Sundry 324-70225 If a re-drill, has a 10-403 for abandonment been approvedYes Halliburton collision scan shows manageable collision risk with no HSE close approaches26 Adequate wellbore separation proposedYes All drilling on this sidetrack will below existing surface casing shoe.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 shutdownNo Monitoring still required.33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No D-Pad wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected reservoir pressure is 7.24 ppg EMW (0.38 psi/ft). MPD will be utilized along with 8.4 ppg mud36 Data presented on potential overpressure zonesNA to maintain an ECD of 9.8 ppg EMW at the window to manage wellbore stability.37 Seismic analysis of shallow gas zonesNA38 Seabed condition survey (if off-shore)NA39 Contact name/phone for weekly progress reports [exploratory only]ApprADDDate12/20/2024ApprMGRDate12/30/2024ApprADDDate12/20/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate