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Home My WebLink About225-092Alaska 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 Unit Field, Prudhoe Oil, PBU B-04B Hilcorp Alaska, LLC Permit to Drill Number: 225-092 Surface Location: 741' FNL, 1598' FEL, Sec. 31, T11N, R14E, UM, AK Bottomhole Location: 1106' FSL, 392' FWL, Sec. 29, T11N, R14E, 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, *UHJRU\ &.:LOVRQ Commissioner DATED this 10 th day of September 2025. Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.10 14:04:11 -08'00' 1a. Type of Work: 1b. Proposed Well Class: Exploratory - Gas Service - WAG Service - Disp 1c. Specify if well is proposed for: Drill Lateral Stratigraphic Test Development - Oil Service - Winj Single Zone Coalbed Gas Gas Hydrates Redrill Reentry Exploratory - Oil Development - Gas Service - Supply Multiple Zone Geothermal Shale Gas 2. Operator Name: 5. Bond: Blanket Single Well 11. Well Name and Number: Bond No. 3. Address: 6. Proposed Depth: 12. Field/Pool(s): MD:12344'TVD:8980' 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: Top of Productive Horizon: 8. DNR Approval Number: 13. Approximate Spud Date: Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL (ft): 59.61' 15. Distance to Nearest Well Open Surface: x-664034 y- 5949909 Zone- 4 40.5' to Same Pool:400' 16. Deviated wells: Kickoff depth:10341 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 101 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 3-1/4" 2-3/8" 4.6# 13Cr80 H511 2414' 9930' 8387' 12344' 8980' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): 10362, 10621, 12147 TVD 23 - 103 23 - 2274 22 - 2116 21 - 4224 20 - 8677 18 - 10260 8417 - 9028 Hydraulic Fracture planned? Yes No 20. Attachments: Property Plat BOP Sketch Drilling Program Time v. Depth Plot Shallow Hazard Analysis Diverter Sketch Seabed Report Drilling Fluid Program 20 AAC 25.050 requirements Contact Name: Ryan Ciolkosz Sean McLaughlin Contact Email:ryan.ciolkosz@hilcorp.com Drilling Manager Contact Phone:907-244-4357 Date: Permit to Drill API Number: Permit Approval Number:Date: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes No Mud log req'd: Yes No H2S measures: Yes No Directional svy req'd: Yes No Spacing exception req'd: Yes No Inclination-only svy req'd: Yes No Post initial injection MIT req'd: Yes No APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 23 - 103 20 - 1026010-3/4" x 9-5/8"1400 sx G, 725 sx G, 400 sx G, 500 sx G Effect. Depth MD (ft): Effect. Depth TVD (ft): 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Intermediate Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 10240 ~250 sx Cement Authorized Title: Authorized Signature: 3-1/2" x 3-1/4" x 2-7/8" 18 - 10260 124 sx Class GLiner 10242 2913 Scab Liner Authorized Name: 9980 - 12120 8430 - 9020 476 sx Class G, 480sx G, 738 sx G7" Conductor/Structural 30"80 12158 9028 LengthCasing 10130, 10205, 10362 Cement Volume MDSize Plugs (measured): (including stage data) 68 sx Class G 10130 8562 18. Casing Program: Top - Setting Depth - BottomSpecifications 3300 Cement Quantity, c.f. or sacks Total Depth MD (ft): Total Depth TVD (ft): 17205344 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 2420 2189' FSL, 1373' FWL, Sec. 29, T11N, R14E, UM, AK 1106' FSL, 392' FWL, Sec. 29, T11N, R14E, UM, AK 89-034 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 Hilcorp North Slope, LLC 741' FNL, 1598' FEL, Sec. 31, T11N, R14E, UM, AK ADL 028310 2491 PBU B-04B PRUDHOE BAY, PRUDHOE OIL 23 - 2274 22 - 2116 21 - 4332 September 15, 2025 21720' Commission Use Only See cover letter for other requirements. 9965 - 12158 Surface Intermediate Intermediate 2251 2094 4311 20" 16" 13-3/8" 4000 sx Permafrost Uncemented 1700 sx Class G Form 10-401 Revised 3/2021 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) By Grace Christianson at 7:43 am, Aug 21, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.08.20 16:02:29 - 08'00' Sean McLaughlin (4311) 225-092 *AOGCC Witnessed BOP Test to 3500 psi, Annular 2500 psi minimum. *Post rig service coil perforating approved for max gun length of 500'. *Window milling approved on service coil *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. DSR-9/9/25TS 9/8/25 50-029-20072-02-00 JJL 9/4/25 *Variance to 20 AAC 25.036 (c)(2)(A)(iv) with compliance to rules in CO 823. JLC 9/10/2025 Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.10 14:03:47 -08'00' 09/10/25 09/10/25 107205344 JSB RBDM SJSB 091225 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: August 20, 2025 Re:B-04B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well B-04A with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for B-04B Producer: See B-04A Sundry request for complete pre-rig details - Prior to drilling activities, coil will mill two CBPs and push to bottom, slickline will drift for a whipstock, and E-line will set a 3-1/4" whipstock. Coil will mill window pre- rig. If unable to set the whipstock or mill the window pre-rig, the rig will perform that work. 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 unable to pre-rig, the rig will set the 3-1/4" whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in Ivishak Zone 4. The lateral will land and continue in Zone 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 (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs below the KOP. 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 B-04A Sundry submitted in concert with this request for full details. 1. Coil : Mill CBPs at 10,130' and 10,205' and push to bottom. 2. Slickline : Whipstock Drift/DMY GLVs 3. E-line : Set 3-1/4" Packer Whipstock at 10,341' MD @ 0 deg RHOS 4. Coil : Mill 2.74" Window 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in October 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,420 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 2.74” Window (if not done pre-rig). 3. Drill build section: 3.25" OH, ~483' (31 deg DLS planned). 4. Drill production lateral: 3.25" OH, ~1729' (12 deg DLS planned). Swap to KWF for liner. 5. Run 2-3/8” 13Cr solid liner 6. Pump primary cement job*: 15 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at window. If high losses are encountered during cement job and it is deemed necessary, a cement down squeeze from TOL to loss zone will be performed with the rig or service coil (if performed by service coil see future sundry). 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. 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 and perforate (~30’) *Requested 3. Slickline : set LTP, set live GLVs. 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 (10341' MD -8,745' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,456 psi 4,456 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ-;ƉƐŝͬŌͿ 362 psi 0 psi 0.09 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,911 psi 3,911 psi 8.6 B+C Mud + ECD Combined 4,273 psi 3,911 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 184 psi 546 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,300 psi at 8,800 TVD. (7.2 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,420 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: 9,930' MD – 12,344' MD (2,414' 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 2-3/8” 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. x Request variance to 20 AC 25.036(c)(2)(A)(iv) to deploy tubulars < 2.375” OD without properly sized pipe rams. x 2-3/8” 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 up jointed pipe. x Crew will perform documented well control drills before deploying 1” / 1-1/4” CS hydril pipe. Directional: x Directional plan attached. Maximum planned hole angle is 101°. Inclination at kick off point is 34°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 21,720 ft x Distance to nearest well within pool – 400 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 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: 9968’ MD in the parent Anti-Collision: x The B-05B (Producer) wellbore comes within 110’ center to center distance of the B-04B wellplan at 11,755 MD (B-04B depth) and 11,211’ MD (B-05B depth) o B-05B was abandoned as part of the B-05C sidetrack. Current active wellbore is B-05D(Producer). o Collision risk is within the same Pool as the offset well o Close approach is below the production packer o Offset well is a producer from the same Pool o No significant difference in pressure expected o The potential of intersection and proper response will be discussed with the crew. x The B-05C (Producer) wellbore comes within 110’ center to center distance of the B-04B wellplan at 11,755 MD (B-04B depth) and 11,211’ MD (B-05B depth) o B-05C was abandoned as part of the B-05D sidetrack. Current active wellbore is B-05D(Producer). o Collision risk is within the same Pool as the offset well o Close approach is below the production packer o Offset well is a producer from the same Pool o No significant difference in pressure expected o The potential of intersection and proper response will be discussed with the crew. x The B-05D/B-05DPB1 (Producer) wellbore comes within 69’ center to center distance of the B-04B wellplan at 11,658 MD (B-04B depth) and 11,212 MD (B-05D/B-05DPB1 depth) o 3-1/2” NS CIBP was set in B-05D at 10192’ MD o Collision risk is within the same Pool as the offset well o Close approach is below the production packer o Offset well is a producer from the same Pool o No significant difference in pressure expected o The potential of intersection and proper response will be discussed with the crew. x The B-07A (Producer) wellbore comes within 50’ center to center distance of the B-04B wellplan at 11,046’ MD (B-04B depth) and 13,398’ MD (B-07A depth) o 3-1/2” CIBP was set in B-05D at 10192’ MD o Collision risk is within the same Pool as the offset well o Close approach is below the production packer o Offset well is a producer from the same Pool o No significant difference in pressure expected o The potential of intersection and proper response will be discussed with the crew. x The B-20 (Producer) wellbore comes within 430’ center to center distance of the B-04B wellplan at 12,087’ MD (B-04B depth) and 9731’ MD (B-20 depth) o B-20was abandoned as part of the B-20A sidetrack. Current active wellbore is B-20A(Producer). o Collision risk is within the same Pool as the offset well o Close approach is below the production packer o Offset well is a producer from the same Pool o No significant difference in pressure expected o The potential of intersection and proper response will be discussed with the crew. x The B-20A (Producer) wellbore comes within 432’ center to center distance of the B-04B wellplan at 12,088’ MD (B-04B depth) and 9,700’ MD (B-20A depth) o Collision risk is within the same Pool as the offset well o Close approach is below the production packer o Offset well is a producer from the same Pool o No significant difference in pressure expected o Pad operator will be aware of the failed anticollision scan and is prepared to shut in well B-20A in the event of a collision. o At least 200 bbls of KWF (offset tubing volume) is on location at all times while drilling by well. o The potential of intersection and proper response will be discussed with the crew. x The C-27A(Producer) wellbore comes within 841’ center to center distance of the B-04B wellplan at 10,941’ MD (B-04B depth) and 12,310’ MD (C-27A depth) o C-27A was abandoned as part of the C-27B sidetrack. Current active wellbore is C-27C(Producer). o Collision risk is within the same Pool as the offset well o Close approach is below the production packer o Offset well is a producer from the same Pool o No significant difference in pressure expected o Pad operator will be aware of the failed anticollision scan and is prepared to shut in well B-20A in the event of a collision. o The potential of intersection and proper response will be discussed with the crew. Hazards: x B Pad an H2S pad. The last H2S reading on B-04A: 32 ppm on 9/23/2021. x Max H2S recorded on DS/Pad: 120 ppm. x 0 fault crossings expected. x Low lost circulation risk. Ryan Ciolkosz CC: Well File Drilling Engineer Joseph Lastufka (907-244-4357) Pre-Rig – Service Coil – Window Milling The approved sundry and permit to drill will be posted in the Operations Cabin of the unit during the entire window milling operation. Notes for window milling: x Window milling with service CTU operations will fully comply with 20 AAC 25.286(d)(3), including the use of pressure control equipment, all BHAs fully lubricated and at no point will any BHA be open-hole deployed. Window Milling Procedure: 1. Kill well with 1% KCL if necessary. Well may already be killed from previous operations. 2. MU and RIH with window milling assembly – Window mill followed by string reamer. NOTE: Confirm milling BHA configuration prior to job execution due to variations in different service provider’s window milling BHAs. 3. RIH & TAG whipstock pinch point, calculate distance till string reamer is out of the window, paint coil flag and note in WSR. 4. Mill window per vendor procedure. – Make note of any WHP changes while milling window in the WSR. 5. Make multiple reciprocating passes through the kickoff point to dress liner exit and eliminate all burs. Perform gel sweeps as necessary to keep window clean. Maximum approved distance to reciprocate beyond the window is 15 ft to ensure confidence the window is prepared for the sidetrack.DO NOT RECIPROCATE DEEPER than 15 ft. 6. Confirm exited liner & string reamer dressed entire window with coil flag and note bottom of window and total milled depth in WSR. 7. FP well to 2,500’ TVD with 60/40 MeOH while POOH. 8. Once on surface inspect BHA, measure OD of mill and string reamer & document in WSR. 9. RDMO 10. Communicate to Operations to tag wing valve “Do Not POP”. Pre-Rig – Service Coil – Window Milling – BOP Diagram 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 12344' 10274 % Prudhoe Bay Unit ADL028310 Sec. 32 Sec. 29 Sec. 31 (607) Sec. 30 (604) U011N014E B PAD CPS GC3 Oil Rim PA B-04B_SHL B-04B_TPH B-04B_BHL Legend B-04B_BHL B-04B_SHL %B-04B_TPH Other Surface Holes (SHL) Other Bottom Holes (BHL) Other Well Paths Pad Footprint Oil and Gas Unit Boundary Participating Area Boundary AIO 3C CO 341J Map Date: 8/20/2025 0 260 520 Feet Document Path: O:\AWS\GIS\Dropbox\Julieanna Potter\Project_Handoff\Project_Handoff.aprxPrudhoe Bay Unit B-04B wp12 u 1:8,000 B-04B 8700875088008850890089509000True Vertical Depth (100 usft/in)-5600 -5400 -5200 -5000 -4800 -4600 -4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 Vertical Section at 235.00° (400 usft/in)B-04AB-04B-04APB1B-04B wp12Top of Window - 10341'MDEnd 30dls - 10891'MDTD - 12344'MDB-04B wp12100015002000250030003500South(-)/North(+) (1000 usft/in)1000 1500 2000 2500 3000 3500 4000 4500 West(-)/East(+) (1000 usft/in)720076008000840088008996B-05B8800B-05E wp04B-05C8800B-05DPB1B-05D8400880092009251B-08B-08A9033C-27A9013C-27APB1680072007600800084008800C-29B8800B-27B8800B-27A8800B-27C5 6 00 6 0 0 0 6 4 0 0 6 80 0 7 2 0 0 7 6 0 0 80008400880092009210B-278800B-27CPB168 0 0 7 20 0 7 6 0 08000 8 4 0 0 8 8 0 0 92 0 09232B-208 8 0 09021B-20A44004800520056006000640068 0 0 7 2 0 0 7600 8000 84008800 B-07A44 00 4 80 0 5 2 0 0 56 0 0 60 00 6 4 00 6 80 0 7 2 00 7 6 00B-074000440048005200560060006400680072007 6 00 8 0 00 840 0 88 0 0B-289028B-04A5600600064006800720076008 00 0 8 4 0 0 8 8 00 9 2 0 09262B-0488009043B-04APB188008 98 0B-04B wp12Sec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 10341.00 34.30 106.52 8745.27 2982.62 3134.24 0.00 0.00 -4278.182 10361.00 36.10 106.52 8761.61 2979.34 3145.29 9.00 0.00 -4285.353 10436.00 58.60 106.52 8812.10 2963.76 3197.84 30.00 0.00 -4319.464 10891.22 95.00 249.70 9020.15 2681.72 3142.20 30.00 119.75 -4112.115 11037.96 90.00 232.80 9013.70 2611.44 3014.20 12.00 -106.00 -3966.956 11138.00 90.00 220.79 9013.70 2543.08 2941.41 12.00 -90.00 -3868.117 11222.00 90.00 230.87 9013.70 2484.63 2881.23 12.00 90.00 -3785.298 11319.63 101.00 226.82 9004.35 2420.81 2808.17 12.00 -20.00 -3688.849 11479.00 101.00 246.29 8973.95 2335.00 2678.27 12.00 90.00 -3533.2110 11664.00 101.00 223.68 8938.65 2231.47 2530.49 12.00 -90.00 -3352.7811 11799.00 101.00 240.18 8912.89 2150.04 2426.52 12.00 90.00 -3220.9112 11896.40 90.00 236.21 8903.56 2099.01 2344.30 12.00 -160.00 -3124.2813 11994.03 79.00 232.15 8912.91 2042.26 2265.62 12.00 -160.00 -3027.2814 12094.00 79.00 244.37 8931.98 1990.73 2182.32 12.00 90.00 -2929.4915 12244.00 79.00 226.04 8960.61 1907.06 2061.92 12.00 -90.00 -2782.8716 12344.00 79.00 238.26 8979.69 1846.94 1984.56 12.00 90.00 -2685.02Depth From Depth To Survey/Plan Tool100.00 10200.00 B-04 Srvy 1 CB-GYRO-MS (B-04) 3_CB-Film-GMS210254.00 10341.00 B-04APB1 Srvy 1 MWD (B-04APB1) 3_MWD10341.00 12344.00 B-04B wp12 (B-04B) 3_MWDSECTION DETAILSSURVEY PROGRAMProject: Prudhoe BaySite: BWell: B-04Wellbore: B-04BPlan: B-04B wp12REFERENCE INFORMATIONCoordinate(N/E) Reference: Well B-04, True NorthVertical (TVD) Reference: KB @ 59.61usft (B-04)Measured Depth Reference: KB @ 59.61usft (B-04)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureParent Wellbore: B-04APB1Top of Window: 10341.00Northing: 5949909.00Easting: 664034.00Lattitude: 70.269492088Longitude: -148.673390784NAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04REFERENCE INFORMATIONWELLBORE DETAILSWELL DETAILSHilcorp Alaska, LLCPROJECT DETAILSB-04B wp12 !!" # $ % " & $ ! 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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 B-04B 225-092 PRUDHOE OILPRUDHOE BAY WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT B-04BInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250920Field & Pool:PRUDHOE BAY, PRUDHOE OIL - 640150NA1 Permit fee attachedYes Entire Well lies within ADL28310.2 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) (For NA15 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)Yes18 Conductor string providedYes19 Surface casing protects all known USDWsYes20 CMT vol adequate to circulate on conductor & surf csgYes21 CMT vol adequate to tie-in long string to surf csgYes22 CMT will cover all known productive horizonsYes23 Casing designs adequate for C, T, B & permafrostYes24 Adequate tankage or reserve pitYes Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement with fully cemented liner.25 If a re-drill, has a 10-403 for abandonment been approvedYes26 Adequate wellbore separation proposedNA27 If diverter required, does it meet regulationsYes28 Drilling fluid program schematic & equip list adequateYes Variance to 20 AAC 25.036 (c)(2)(A)(iv) with compliance to rules 29 BOPEs, do they meet regulationYes 5000 psi30 BOPE press rating appropriate; test to (put psig in comments)Yes31 Choke manifold complies w/API RP-53 (May 84)Yes32 Work will occur without operation shutdownYes The last H2S reading on B-04A: 32 ppm on 9/23/2021.33 Is presence of H2S gas probableNA34 Mechanical condition of wells within AOR verified (For service well only)No B-Pad wells are H2S-bearing. H2S measures are required.35 Permit can be issued w/o hydrogen sulfide measuresYes Expected reservoir pressure gradient is 7.2 ppg EMW. MPD to maintain an ECD of 9.8 ppg EMW.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]ApprTCSDate9/8/2025ApprJJLDate9/9/2025ApprTCSDate9/8/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 9/10/2025