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Home My WebLink About225-093Nolan 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: 11/20/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251120 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 10/14/2025 AK E-LINE PPROF T41129 BR 09-86 50733204480000 193062 10/28/2025 AK E-LINE Perf T41130 BRU 213-26T 50283202040000 225038 10/30/2025 AK E-LINE Perf T41131 END 1-57 50029218730000 188114 11/16/2025 READ PressTempSurvey T41132 END 2-28B 50029218470200 203006 11/15/2025 READ PressTempSurvey T41133 END 2-30B 50029222280200 208187 11/18/2025 READ PressTempSurvey T41134 END 2-52 50029217500000 187092 10/28/2025 HALLIBURTON LDL T41135 KALOTSA 10 50133207320000 224147 11/7/2025 AK E-LINE Perf T41136 MPF-92 50029229240000 198193 11/8/2025 READ CaliperSurvey T41137 MPH-01 50029220610000 190086 11/7/2025 READ CaliperSurvey T41138 MPI-14 50029232140000 204119 11/8/2025 READ CaliperSurvey T41139 MPU H-01 50029220610000 190086 11/4/2025 AK E-LINE Drift/CBL/Caliper/Packer T41138 MPU I-14 50029232140000 204119 11/8/2025 AK E-LINE RigAssist T41139 MPU J-02 50029220710000 190096 11/6/2025 AK E-LINE Caliper/Gyro T41140 NCIU A-07A 50883200270100 225094 11/1/2025 AK E-LINE CBL T41141 NCIU A-07A 50883200270100 225094 11/4/2025 AK E-LINE Perf T41141 ODSN-01A 50703206480100 216008 10/24/2025 HALLIBURTON PACKER T41142 ODSN-25 50703206560000 212030 10/23/2025 HALLIBURTON PACKER T41143 ODSN-26 50703206420000 211121 11/4/2025 HALLIBURTON PERF T41144 PBU 02-10B 50029201630200 200064 10/27/2025 HALLIBURTON RBT T41145 PBU A-24B 50029207430200 225067 10/20/2025 BAKER MRPM T41146 PBU B-05E 50029202760500 225093 10/23/2025 HALLIBURTON RBT T41147 PBU B-05E 50029202760500 225093 10/23/2025 BAKER MRPM T41147 PBU B-20A 50029208420100 212026 10/16/2025 BAKER SPN T41148 PBU F-18B 50029206360200 225099 11/5/2025 HALLIBURTON RBT-COILFLAG T41149 PCU D-10 50283202080000 225082 10/31/2025 AK E-LINE Patch T41150 PCU D-10 50283202080000 225082 10/17/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/22/2025 AK E-LINE Perf T41150 PCU D-10 50283202080000 225082 10/29/2025 AK E-LINE Perf T41150 T41147PBU B-05E 50029202760500 225093 10/23/2025 HALLIBURTON RBT PBU B-05E 50029202760500 225093 10/23/2025 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:19 -09'00' 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: PCU D-11 50283202090000 225088 10/16/2025 AK E-LINE CBL T41151 PCU D-11 50283202090000 225088 10/24/2025 AK E-LINE Perf T41151 Please include current contact information if different from above. Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.20 13:27:31 -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: 11/05/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU B-05E PTD: 225-093 API: 50-029-20276-05-00 FINAL LWD FORMATION EVALUATION LOGS (10/03/2025 to 10/15/2025) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Main Folders: SFTP Transfer - Data Sub-Folders: Please include current contact information if different from above. 225-093 T41050 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.05 10:41:28 -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 Sean McLaughlin Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Unit Field, Prudhoe Oil, PBU B-05E Hilcorp Alaska, LLC Permit to Drill Number: 225-093 Surface Location: 855' FNL, 1600' FEL, Sec. 31, T11N, R14E, UM, AK Bottomhole Location: 562' FNL, 138' FEL, Sec. 31, 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 13:55:28 -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: 12957' TVD: 9061' 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): 71.5' 15. Distance to Nearest Well Open Surface: x-664036 y- 5949795 Zone- 4 40.0' to Same Pool: 750' 16. Deviated wells: Kickoff depth: 10175 feet 17. Maximum Potential Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 103 degrees Downhole: Surface: Hole Casing Weight Grade Coupling Length MD TVD MD TVD 3-1/4" 2-3/8" 4.6# 13Cr80 H511 2957' 10000' 8381' 12957' 9061' 19.PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Junk (measured): TVD 34 - 114 34 - 2663 31 - 6011 1784 - 6011 5910 - 8983 8318 - 8735 8583 - 9041 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 1963 cu ft Cement 1125 cu ft Class G 31 - 7274 1784 - 7274 Liner Scab Liner 7243 5490 9-5/8" 7" PBU B-05E PRUDHOE BAY, PRUDHOE OIL 10/13/2025 20190' Total Depth MD (ft): Total Depth TVD (ft): 107205344 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 2420 1030' FSL, 1542' FWL, Sec. 29, T11N, R14E, UM, AK 562' FNL, 138' FEL, Sec. 31, T11N, R14E, UM, AK 89-034 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 Hilcorp North Slope, LLC 855' FNL, 1600' FEL, Sec. 31, T11N, R14E, UM, AK ADL 028310 2491 18. Casing Program: Top - Setting Depth - BottomSpecifications 3278 Cement Quantity, c.f. or sacks Cement Volume MDSize Plugs (measured): (including stage data) 86 sx Class G Conductor 20" x 30"80 LengthCasing Authorized Title: Authorized Signature: 2-3/8" 7110 - 10899 174 cu ft Class G 96 sx Class G Liner Liner 3789 491 3496 Intermediate Authorized Name: Commission Use Only See cover letter for other requirements. 10115 - 13678 8484 - 9041 424 cu ft Class G 9930 - 104213-1/2" 5-1/2" 10227 - 13723 21. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Surface Perforation Depth TVD (ft): GL / BF Elevation above MSL (ft): Perforation Depth MD (ft): 2630 300 sx Cement 34 - 114 34 - 266413-3/8" 5200 cu ft Cement Effect. Depth MD (ft): Effect. Depth TVD (ft): 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 4:26 pm, Aug 21, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.08.21 14:25:38 - 08'00' Sean McLaughlin (4311) *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. TS 9/10/25 TS 9/9/25 JJL 9/9/25 DSR-9/10/25 9/28/25 225-093 *Variance to 20 AAC 25.036 (c)(2)(A)(iv) with compliance to rules in CO 823. *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 50-029-20276-05-00 JLC 9/10/2025 Gregory C Wilson Digitally signed by Gregory C Wilson Date: 2025.09.10 13:54:59 -08'00' 09/10/25 09/10/25 RBDMS JSB 091225 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: August 21, 2025 Re:B-05E Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well B-05B with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for B-05E Producer: See B-05D Sundry request for complete pre-rig details - Prior to drilling activities, screening was conducted to drift for whipstock and MIT. A coil tubing drilling sidetrack will be drilled with the Nabors CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will set the 3-1/2" Packer whipstock and mill a single string 2.74" window + 10' of formation. The well will kick off drilling in the Shublik and lands in Ivishak Zone 2. The lateral will continue cross cutting through the Ivishak to find OGC/OWCs. 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. 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-05B Sundry submitted in concert with this request for full details. 1. Slickline : Dummy GLMs, SL Whipstock Drift (Fail), CT drift (good) and Caliper 2. Fullbore : MIT-IA and/or MIT-T 3. Valve Shop : Pre-CTD Tree Work 4. 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. Set 3-1/2” Whipstock at 10,175’ MD @ 180 Degrees ROHS. 3. Mill 2.74” Window 4. Drill build section: 4.25" OH, ~326' (28 deg DLS planned). 5. Drill production lateral: 4.25" OH, ~2567' (12 deg DLS planned). Swap to KWF for liner. 6. Run 2-3/8” 13Cr solid liner with cementing valve. POOH and LD running tool. Run 1” CSH inside of liner and sting into cementing valve. 7. Pump primary cement job*: 19 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP*. 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). 8. Only if not able to do with service coil extended perf post rig – Perforate Liner 9. Freeze protect well to a min 2,200' TVD. * 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 and perforate (~30’) *3.25" OH - JJL *3.25" OH Prod Lateral 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 (10175' MD -8,537' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)4,350 psi 4,350 psi 9.8 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 916 psi 0 psi 0.09 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,818 psi 3,818 psi 8.6 B+C Mud + ECD Combined 4,733 psi 3,818 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain -383 psi 533 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,278 psi at 8,583 TVD. (7.4 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: 10,000' MD – 12,957' MD (2,957' 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. x Request variance to 20 AC 25.036(c)(2)(A)(iv) to deploy tubulars < 2.375” OD without properly sized pipe rams. x 2” safety joint will be utilized while running 1” / 1-1/4” CS hydril. x Blind/Shear rams will be utilized in place of pipe rams sized for CTD jointed pipe operations as a worst- case shut-in scenario (in place 1” / 1-1/4” CS hydril pipe rams). x The well will be full of KWF prior to running liner or jointed pipe operations. x The BHA will be circulated out of hole prior to laying down BHA for jointed pipe operations. x The well will be flow checked after laying in KWF, before laying down BHA and before making 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 103°. Inclination at kick off point is 28°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 20,190 ft x Distance to nearest well within pool – 750 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 Prudhoe Pool. x Formations: Top of Prudhoe Pool: 10,104’ MD in the parent Anti-Collision: x The B-20A (Producer) wellbore comes within 42’ center to center distance of the B-05E wellplan at 10,843’ MD (B-04B depth) and 10,400’ 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. *Waiver under CO 823 - JJL Top of Prudhoe Pool: 10,104’ MD Hazards: x B Pad is an H2S pad. The last H2S reading on B-05B: 18 ppm on 3/3/2025. 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) 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 12957' % Prudhoe Bay Unit ADL028310 Sec. 32 Sec. 29 Sec. 31 (607) Sec. 30 (604) U011N014E B PAD CPS Oil Rim PA B-05E_SHL B-05E_TPH B-05E_BHL Legend B-05E_BHL B-05E_SHL %B-05E_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: 8/21/2025 0 260 520 Feet Document Path: O:\AWS\GIS\Dropbox\Julieanna Potter\Project_Handoff\Project_Handoff.aprxPrudhoe Bay Unit B-05E wp05 u 1:8,000 B-05E 825084008550870088509000True Vertical Depth (300 usft/in)-4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 Vertical Section at 225.00° (400 usft/in)B-05BB-05CB-05DPB1B-05DB-05E wp05Top of Window - 10175'MDEnd 28dls - 10501'MDTD - 12957'MDB-05E wp0505001000150020002500South(-)/North(+) (1000 usft/in)1000 1500 2000 2500 3000 3500 4000 4500 West(-)/East(+) (1000 usft/in)60 0 06400680072007600800084008800 9008B-05B4 4 0 0 4 8 00 5 200 56 0 0 60 0 0 64 0 0 68 0 072007600B-05B-05C8800B-05DPB14400480052005600600064006800B-226400B-22A400044004800B-02400044004800B-02A520056006000640068007200760080008400880092009315B-06B-0887 51B-16APB188009007B-16A4 8 0 0 5 2 0 0 56 0 0 600 0 6 4 0 0 68 0 0 7 20 0 7600 8 0 0 0 8400 8800 92009252B-164 4 0 0 4800 5200 5 600 6000 64 0 0 68 00 7200 7 6 0 0B-364000 4400 4800 5200560060006400680072007600B-378800B-27B8800B-27A8800B-27C44 0 0 4 8 0 0 5 2 0 0 56 00 6 0 0 0 6 4 0 0 6 8 0 0 7 2 0 0 7 6 0 0 80008400880092009222B-278800B-27CPB15 60 0 6 0 0 0 6 4 0 0 6 8 0 0 7 2 0 0 7 6 0 0 8 0 0 0 8 4 0 0 88 0 0 9 2 009244B-209033B-20A4000440048005200560060006400B-07A40 0 0 4 4 00 4 8 0 0 5 2 00 56 0 0 6 0 0 0 6 4 0 0 6 8 0 0 72 0 0B-078 992B-04B wp12520056006000640068007200B-0490 6 1 B-05E wp05Top of Window - 10175'MDEnd 28dls - 10501'MDTD - 12957'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 10175.00 28.92 353.37 8537.61 1917.52 3132.87 0.00 0.00 -3571.162 10195.00 27.12 353.37 8555.26 1926.85 3131.79 9.00 180.00 -3576.993 10265.00 7.52 353.37 8621.76 1947.45 3129.39 28.00 180.00 -3589.874 10500.86 59.00 194.75 8822.10 1854.52 3098.35 28.00 -160.00 -3502.205 10661.00 59.00 217.17 8904.58 1731.89 3038.64 12.00 90.00 -3373.276 10801.00 59.00 197.57 8976.69 1625.84 2983.74 12.00 -90.00 -3259.467 11072.63 90.00 208.19 9048.59 1388.71 2881.67 12.00 20.00 -3019.628 11188.05 103.00 213.01 9035.54 1290.21 2823.49 12.00 20.00 -2908.839 11409.00 103.00 240.23 8985.84 1143.73 2668.49 12.00 90.00 -2695.6510 11609.00 103.00 215.59 8940.85 1014.11 2524.98 12.00 -90.00 -2502.5211 11824.00 103.00 242.08 8892.48 877.44 2368.68 12.00 90.00 -2295.3612 12006.00 103.00 219.66 8851.54 766.24 2232.00 12.00 -90.00 -2120.0713 12121.03 90.00 224.34 8838.54 681.54 2155.67 12.00 160.00 -2006.2214 12272.09 73.00 230.73 8860.81 580.95 2046.05 12.00 160.00 -1857.5715 12463.00 73.00 254.68 8916.63 497.84 1884.99 12.00 90.00 -1684.9216 12643.00 73.00 232.09 8969.26 421.24 1732.09 12.00 -90.00 -1522.6317 12823.00 73.00 254.68 9021.88 344.63 1579.18 12.00 90.00 -1360.3418 12957.00 73.00 237.87 9061.06 293.26 1462.29 12.00 -90.00 -1241.36Depth From Depth To Survey/Plan Tool102.76 7202.76 1: Camara based gyro multishot (B-05) 3_CB-Film-GMS27274.00 10175.00 Survey #2 (B-05B) 3_MWD (BP MWD+IFR+MS-WOCA)10175.00 12957.00 B-05E wp05 (B-05E) 3_MWDSECTION DETAILSSURVEY PROGRAMProject: Prudhoe BaySite: BWell: B-05Wellbore: B-05EPlan: B-05E wp05REFERENCE INFORMATIONCoordinate(N/E) Reference: Well B-05, True NorthVertical (TVD) Reference: KB @ 71.50usft (B-05B)Measured Depth Reference: KB @ 71.50usft (B-05B)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureParent Wellbore: B-05BTop of Window: 10175.00Northing: 5949795.00Easting: 664036.00Lattitude: 70.269180580Longitude: -148.673394705NAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04REFERENCE INFORMATIONWELLBORE DETAILSWELL DETAILSHilcorp Alaska, LLCPROJECT DETAILSB-05E wp05 ! 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"#$%&'() (* (*+, - ,( %"#$%&'() - ! % . - , ( ! 4%6 8 456 9$! 456 23) 4%6 , - ! 4%6 , 4%6 2-3 4%6 +" ' ( ! 4%6 &'( % ( ?>;<? ' $ $=<&<1 :&11 < 7%<&$< =1<&0% : $&:%&1<<<$ 01&$ 0 <==&<=< :7&1<%%&:= 1 $0&7 $ =%$&:< :&<1 < 77:&1$ =71&:1 : $$&<$&0 <<$ 07&:$ 0 $7&%:< :$%&$$$&= 1 $$%&= $ =7&$7 :&07 < 7<$&< =<&$0 : $=&07&=<<$ 0&1= 0 $%=&<1< :0<&%1&0 1 $=1&0 $ 0:0&7% :%&<< < 7$&<0 0&:7 : =1&%:&<<<$ 0$&7= 0 $<$&1:< 7$<&%0 &=% 1 =%0&0 = ::&%1 :&1< < <1=&< 0:&1= : =<&0=$&0=<<$ %%&1< 0 =%&1<< <&<1&=: 1 =<&=0 = %1<&1 10&7 < $=&$0 00=&$= : 0:&77=&%=<<$ %<&$1 0 =<&=0< <:$&10 %&:1 1 =0:&<: = 1%0&00 1=&:$ < $0%&1% % 7:&:0 : %&10&1%<<$ %%1&< 0 0&<:< $%0&$%&=0 1 0:& = :%%&:7 1$&1 < =$1&% % =&%7 : %$&07%%&$%<<$ %%0&:7 0 07$&:< =&<%&0 1 0<7&0 = 7<&0= 1$&% < 0$&:% % %1$&=7 : %%&0%0&7<<$ %1<&:= 0 00&:0< ==&=%%&$ : &$= = 700&%< 1<&<1 $ :0&$ % %<=&0: : %11&1==&%7 <<$ %:%&=7 0% :%&<%< 0<=&$&$$ : :7&:7 = 0&0$ 1<&< $ %1%&<7 % 10&<$ : %1=&%1=&1<<$ %:<&= 0% $1&7<$ &%7 &7 : <$&1= = <=& 1<&= $ 1&$% % 1%&:7 : %:7&:%=&<=<<$ %71&= 0% %%7&1<$ %:7&1%&17 : %%&%1 = $$=& 1&=1 $ 1=0&% % 10%&00 : %7&<$&71 <<$ %7<&07 0% %&1$ 1%$&<%&% : %::&0: = 0<:&$ 1$&% $ 7&%< % :$7&0 : %7$&<1:&%%<<$ %1&<0 0% 1:=&%1$ :=:&<<%&:= : %0$&07 0 =&0: 1&=7 $ 7&1 % 7%$&<% : %70&0<:&%=<<$ %7&% 0% 1=&=1$ 7<=&$%&$ : 110&$< 0 %%&<$ 1$&1= $ <1:&%< % 70& : %&0%:0&:<<$ %7&%7 0% :11&1$$ %&<<1&: : 10&$: 0 17<&$ 1=&< $ $$&:$ % :&1 : %&11:=&$<<$ %1& 0% :<<&:0$ <:&=$&01 : 10&7< 0 :7&11 1$&$% $ $=0&0= % 7<&0 : %70&%<:=&:<<$ %&70 0% 7%&$ $%=&7=&:= : :1&<1 0 7::&70 1$&%7 $ =$1&$$ % =0&= : %7=&::0&%<<<$ %7=&<= 0% 71&0$$ =%&1$&<0 : :&:= 0 1<&:: 1<&07 $ 0&7< % <:1& : %7$&0<:0&01 <<$ %7$&71 0% 70&%$ ==:&0<&7: : :$0&0= 0 <%0&% 1<&%% = :=&=: % <$:&<$ : %7$&=1:0&$%<<$ %7<&:= 0% :<&$$ 0<$&::&0 : 70&:% 0 $%1&= 1&<% = %11&= % $%7&1 : %7$&%::=&::<<$ %77&=% 0% $$&:%= %&=&=7 : 7:$&1 0 =&7: 1<&=< = 1&=$ % $&1= : %7&=7:=&$<<$ %71&<1 0% <%=&10= %:7&:$%&: : 7<&<% 0 =00&: 1<&1 = 1=0&<= % $0<&=0 : %7:&$1:<&$<<$ %:0&< 0% <0&== 1%=&%=%&:% : 70:&7 0 00&10 1&7 = :$<&7% % =:=&: : %7&::&%7 <<$ %:& 0% $%&7= :7&0%&$$ : 1&$1 % 1<&$= 17&=7 = 77&01 % =%&=< : %:0&70:&07 <<$ %:7&%$ 0% $%7&$= :::&71 1&= : 10&7% % %&: 1$&% = 1&% % 0=&%7 : %::&00::&7 <<$ %1$&77 0% $$&== 77=&%1&:% : <&:1 % %$& 1=&01 = :$&<% % 0%$&1 : %:1&=$::&:$<<$ %1<&%1 0% $=&1= 7<<&%%$&%: : $%&%< & %) ::@A,( % %0& 1$&%1 = &1< % 01<&= : %:%&$0::&:$<<$ %17&=: 0% $=0&%= 7=:&$<0& : $<&00 % 1& 1&$1 = 0&$7 % 010&< : %:%&:::&:$<<$ %17&: 0% $0%&$%= 7==&17 1=& : $=&:= % 11& 1&%1 = $=&% % 0:<&$0 : %:&<:::&:$<<$ %1:&7< 0% $00&71= <&<1=& : =:&1% % 17& %7&1 = 0$&17 % 071&$% : %10&07::&:$<<$ %11&< 0% =&:1= 1&$7 1=& : =<&0 % 1<& =&01 = <%<&=% % 07<&$7 : %10&7$::&:$<<$ %11&0 0% =0&:7= 7&:%1=& : =0&7: % 1<& $&1 = <1%&$< % 07$&7 : %10&:0::&:$<<$ %1%&00 0% =%&= &1<1=& : =0&=$ % 1=& :&= = <:<&<0 % 07=&=$ : %10&:::%&70 <<$ %1%&< 0% =%%&7<= <&%0 1=& : 0&<1 % :& :&$7 = <<&<< % 070&% : %1=&%$1:<&7=<<$ %1&$: 0% =%%&<$= =&%<1=& : 0&%$ % :1& =&$% = <$<&7 % 07$&7: : %1<&=<1%&1:<<$ %%0&7< 0% =0&0== <&7 1=& : ==&$ % :7& %7&% = <0<&%7 % 07:&== : %1&%11:&7<<$ %%$&=% 0% =<&:0= <17&<7 1=& : =7&:: % :<& %0&<0 = $%&1< % 0:=&7$ : %11&0=1&7%<<$ %%&$$ 0% =&0:= <7:&$<1=& : $=&00 % :=& 1&1 = $::&$7 % 0:%&1$ : %1&7:%0=&<<<<$ %%:&:0 0% $0:&<== <<1&17 1=& : $1&0 % 7& :&=1 = $%&:= % 011&:7 : %%$&1%0$&1 <<$ %%&<= 0% $=7&<== <$0&==1=& : <:&$1 % 71& :<&7 = $<=&: % 0%%&$< : %%7&1=%0<&<0 <<$ %$&<< 0% $$7&7= <0<&:1=& : :&07 % 77& 7%&00 = $=:&: % =00&<7 : %%&$1%0<&<<<$ %7&:$ 0% $<%&=7= $%1&:1=& : 71&= % 7<& 7$&= = $0$&$1 % ==<&= : %<&==%0&<<<$ %&=: 0% $7=&1%= $1<&11 1=& : :&< # $ " % &'( % ) )* +" ,! ! "#$%&'() (* (*+, - ,( %"#$%&'() - ! % . - , ( ! 4%6 8 456 9$! 456 23) 4%6 , - ! 4%6 , 4%6 2-3 4%6 +" ' ( ! 4%6 &'( % ( B@>B<=@ ' % 7=& :&%$ = =%&7$ % =$%&17 : %1&=%%0&%:<<$ 0$&= 0% $::&1== $:=&0$1=& : %$&%= % &=< 0& = =11&% % =7&1 : 0=&:%07&$<<$ 01&00 0% $%<&7$= $&<1=& : 1&1% B::A,( % 1& 0& = =:7&7 % =:7&<$ : 01&70%0=&%:<<$ =$&< 0% <0<&= $<:&7 %1& : 7=7&: % & 0& = =7$&7% % =%7&1 : =&1%1%&<:<<$ =&$1 0% <$<&1= $$&0%%1& : 7<7&<: % $& 0& = =<&10 % $07&=< : $<&$%1&%:<<$ $1&< 0% <<&:= $==&$0 %1& : 777&$1 % <& 0& = =$:&%< % $$&$ : <$&11=&<:<<$ <:&:= 0% <:$&7= =%&<<%1& : 717&: % <1& 0& = ==<&7 % $$&1< : <&%=1%1&%:<<$ 1&0 0% <%=&:1= =%7&7 %1& : 7:&<1 % <& 0& = =0=&01 % $:0&7= : 77&171%&<:<<$ 7%&7 0% <&1== =1$&71 %1& : :=1&< % <<%& 0& = 07&= % $:%&=0 : :=&<71%$&%$<<$ :&0$ 0% 01&$= =::&=%1& : :$:&1$ % <$& 0& = 0%%&$0 % $11&1 : :%&<1%&1%<<$ 10&% 0% =1&$7= =7&10 %1& : :<%&71 % $& 0& = 017&<$ % $7&:: : %0&$71%%&$%<<$ %$&<= 0% <7&<%= =:&%$%1& : :7&71 % $1& 0& = 0:$&7 % <=&$$ : 0&71=&1%<<$ $&:= 0% 7&=1= =<<&7 %1& : :%0&$: % $& 0& = 0&71 % <<<&= 1 000&17&$%<<< 00=&1< 0% 1<&77= =$=&01 %1& : 100&71 % $$& 0& = 0<:&: % <7<&=< 1 00%&%71%&1%<<< 00&:: 0% <&:= =0%&=%1& : 1$0&< % =%& 0& = 0$<&<0 % <1&=7 1 0=:&$7%0$&$<<< 0=:&:0 0% 7=&:<= 0&%0 %1& : 10&7< % =1& <%&$% = 0==&< % <<&1 1 0$$&1%0=&<0 <<< 0$$&:: 0% 7<&7= 0%$&<%1& : 17&=< % =& <7&7 = 000&=< % =7&0$ 1 0<0&=0%00&=<<< 0$&77 0% 777&1= 01=&:<%1& : 11&$$ % =$& <$&:0 0 %&7 % <:&< 1 0<%&0<1&=<<< 0<1&0= 0% 711&<:= 0:=&7 %1& : 1&: % 0& $&1: 0 %0&$ % 7%&= 1 0:&7$1%&=<<<< 07&0$ 0% 7&$7= 07$&$%1& : %$=&<= % 01& $:&0 0 1<&07 % %0&0% 1 077&711&=7 <<< 07<&71 0% :$=&<%= 0&77 %1& : %<&$= % 0& $&07 0 ::&<% % 70$&$0 1 0:7&011:&$0 <<< 0:$&:= 0% :<&1== 0<1&%%%1& : %:7&:0 % 0$& $=&=% 0 :0&= % 7$& 1 017&017&$%<<< 01$&=7 0% :::&=:= 0<$&=%1& : %%%&= %% & =%&<$ 0 7:&:1 % 7:&1 1 0%7&711&<1 <<< 0%$&=< 0% :%%&:%= 0$%&=1 %1& : ==&7% %% 1& =7&7 0 7<&:1 % 7:&0< 1 0:&11<&%<<< 0$&77 0% 1==&$0= 0$7&=1 %1& : <7&07 %% & =$&7 0 7=&= % 7=&$: 1 =01&111$&:0 <<< =0<&<: 0% 1<<&:1= 0$<&=%1& : 7%&1: %% $1&<: 0& 0 7=&0 % :==&$% 1 ==%&<$1=&%0 <<< ==<&1 0% 17<&== 0$$&0 %1& : %0&<1 %% $& 0&1$ 0 7=&= % :=<&<: 1 ==&1=&10 <<< ==&7 0% 17:&0== 0$$&=%1& : %$&: %% %& 0:&0 0 7$&= % :<7&$: 1 =<=&%10&:%<<< =$:&=0 0% 11%&=1= 0$<&:%1& 1 00:&:< %% %1& 0&0 0 7&=0 % :7:&%% 1 =<&%11%&:<<< =<%&0$ 0% %00&07= 0$7&:0 %1& 1 0<0&: %% %& 0=&$1 0 71&$% % :1%&=: 1 =7:&71%%&:0 <<< =70&$1 0% %$=&:0= 0$%&1%%1& 1 07&1< %% %$& %%&: 0 :=&:1 % :&07 1 =:&:01%1&7<<< =:$&%$ 0% %$&11= 0<<&=1 %1& 1 01%&10 %% %==& %:& 0 :&7 % 10&1% 1 =1:&701%:&%<<< =:&% 0% %7<&:= 0<7&7 %1& 1 0=&=: %% 1& %:& 0 :1&= % 1=&: 1 =%$&11%7&7=<<< =17&1 0% %:<&:= 0<%&:%1& 1 =0$&7% %% 11& %:& 0 1$&1: % 1<&=7 1 =1&$1%$&<<<< =%&:$ 0% %%<&1= 0&$:%1& 1 =$:&: %% 1& %:& 0 1%&<% % 17%&0: 1 $=$&:711&<7 <<< $0&71 0% 0$&10= 0&%%%1& 1 =70&%: %% 1$& %:& 0 %&0= % 11:&=0 1 $$&0011:&$1 <<< $$0&7< 0% $=&=0= 077&7=%1& 1 =17&= %% :& %:& 0 %&:< % 1<&$7 1 $:&<=11<&=<<< $<1&7 0% <%&:== 0:=&=<%1& 1 =&77 %% :1& %:& 0 7&$7 % %0& 1 $:&70110&==<<< $77&$ 0% 77&== 0::&17 %1& 1 $$<&%: %% :& %:& = 000&%% % %$&:< 1 $%<&71:1&0<<<< $1<& 0% 10&1= 01$&<%%1& 1 $%&0: %% :$& %:& = 00:&70 % %<%&11 1 <0<&<11:<&7 <<< $<&70 0% %7&<:= 01%&00 %1& 1 $1$&0 %% 7& %:& = 0=$&=< % %7=&%< 1 <$<&<1:0&%1 <<< <=<&11 0% %&%:= 0%<&:<%1& 1 $7&%: %% 70& %:& = 0=&=7 % %7:&$: 1 <<=&7017&1:<<< <$=&$7 0 00<&:= 0%7&:7 %1& 1 <0&< %% 71& %:& = 0=1&17 % %:&$< 1 <&01:=&1<<<< <<&: 0 0==&1$= 0%&$7 %1& 1 <=&7 %% 7& %:& = 0$<&<1 % %11&7 1 <:7&$:1:&%=<<< <7&7< 0 0$7&7$= 0&%1 %1& 1 <<&<0 # $ " % &'( % ) )* +" ,! ! "#$%&'() (* (*+, - ,( %"#$%&'() - ! % . - , ( ! 4%6 8 456 9$! 456 23) 4%6 , - ! 4%6 , 4%6 2-3 4%6 +" ' ( ! 4%6 &'( % ( BB==<;= ' %% 7$& %:& = 0$&00 % %$&0< 1 <%&%11:1&%<<< <1<&%$ 0 00&<%= =00&70 %1& 1 <:1&<% %% & %:& = 0<&:$ % 01&7= 1 0<&:%110&1 <<< <$&$ 0 07:&$:= =0:&=$%1& 1 <=&:$ %% 1& %:& = 00&$ % $<&1 1 $=&:11&07 <<< 0&%1 0 01<&=== ===&1%1& 1 =7&: %% & %:& = 07&%1 % =&<1 1 <%&:%111&=<<<< $:&7< 0 00&%%= ==1&<1 %1& 1 0&<= %% $& %:& = 07=& % 7&:: 1 7&1:1%0&$=<<< $&$= 0 =0&7$= =$$&%1& 1 :&:$ %% <& %:& = 071&=$ % 1%&1 1 :&%<1%<&$<<< 7:&%: 0 =$%&1= =$%&:$%1& 1 %%&%0 %% <0& %:& = 07&= % %7&%% 1 17&0=1%&0 <<< :=&%% 0 =<:&=:= =<0&:%1& 1 1&1 %% <1& %:& = 0:$&1 % %&< 1 %&$1%$&<<<< 10&% 0 =%&%%= =<&$%1& 1 7=$&% %% <& %:& = 0:%&<: 0=1&$ 1 &::11&<7 <<< %7&% 0 =:%&=== =<&%:%1& 1 7<1&=$ %% <$& %:& = 01<& 0<7&< 1 7=:&0=11:&$1 <<< 70=&1 0 =%:&7== =7&%1& 1 7:=& %% $& %:& = 01&:= 07$& 1 7<<&<=11<&=<<< 7=%&1$ 0 $0&0$= =7=&==%1& 1 7%7&%0 %% $1& %:& = 0%7&$< 0:%&:% 1 77=&7=110&==<<< 7<:&77 0 $$0&:== =7:&1<%1& 1 :=0&== %% $& %:& = 00&%: 0%<&%1 1 710&771:1&0<<<< 777&$: 0 $<:&$0= =:$&<:%1& 1 :<&<$ %% $$& %:& = 0:&% 0%&0= 1 70&<%1:<&7 <<< 71&11 0 $70&1%= =:1&%%1& 1 :7%&< %% =& %:& = =0$&== ===&01 1 :=0&1:0&%1 <<< 77&0 0 $:&$%= =1<&:=%1& 1 :%$&== %% =17& %:& = =01&7= =$$&77 1 :<=&<=171&=<<< :=7&=: 0 $1:&$0= =1&0=%1& 1 10&:< %% =& %:& = ==<&<7 =<7&0< 1 :7<&<71:=&==<<< :<:&$ 0 $%&=:= =%&%7 %1& 1 1$&0 %% =$& %:& = ==%&% =%&=1 1 :1<&%71:&=<<< :71&=< 0 <0$&1= =0&%%1& 1 17$&% %% 0& %:& = =$&:0 =:$&0 1 :<&:$1:1&$1 <<< :1:&7% 0 <=1&0= =:&=0 %1& 1 11:&%% %% 01& %:& = =<0&$$ =11&:1 1 1=$&:0110&<7 <<< :7&$$ 0 <<<&0%= $0=&1$%1& 1 %0=&0 %% 0& %:& = =<7&%7 =<& 1 1<0&1$11<&<<<< 1=$& 0 <&1= $01&<7 %1& 1 %$7&= %% 0$& %:& = ==&1 $==&=: 1 11&711:&7=<<< 1$&%< 0 <:1&<$= $=$&1 %1& 1 %&11 %1 & %:& = =1&=0 $$&$% 1 1:&$<11&7<<< 17&1= 0 <%7&1= $=%&:0 %1& 1 %1&0 %1 <& %:& = =%&7 $<<&17 1 1:1&1%0&<<<<< 1&<1 0 <0&<7= $=&7 %1& 1 %1&$ %1 1& %&=< = =7$&<1 $1&% 1 11&711&7<<< 1:=&0$ 0 0&%<= $$<&%1 %1& 1 %%&< %1 & 0=&: = =7:&1 $::&:0 1 1:&=$11%&7=<<< 11:&11 0 $<&%0= $$1&1 %1& 1 $<&0< %1 $& 0&1% = =7&<: $%7&0: 1 %=$&1<111&70 <<< 1$&% 0 $&:== $<0&%:%1& 1 1&%< %1 %& 01&:= = =:=&0= <0<&<0 1 %$&1<11:&70 <<< %0&7% 0 :=&$$= $<$&7=%1& 1 1$&17 %1 %1%&: 0& = =:=&7 <=%&7 1 %&<$117&:7 <<< %$<&%< 0 1:&:%= $<$&7 %1& 1 <&11 %1 %1& =0& = =:=&< <$=&$% 1 %1&=0117&<<< %$:&77 0 1&71= $<$&<%1& 1 1&1 %1 %& =<&$: = =:0&:$ <<%& 1 %:&1111&:<<< %<&%< 0 1&:$= $<$&=$%1& % 0$$&1< %1 %$& =:&01 = =7%&7% <7:&$ 1 %%$&1011<&<<<< %:=&<% 0 7=7&<0= $<0&0%%1& % 01&: %1 1& =%&% = =77&<$ <1<&== 1 00&%711$&<<<< %1&=7 0 7<$&7:= $$:&%$%1& % 01$&= %1 11& $=&10 = =70&%7 <%&7< 1 =&=:11=&<<<<< %1&== 0 7&<1= $$$&<7 %1& % 0:&: %1 1& $&7= = =7&=% 07& 1 <1&7110&$<<< =7&=% 0 7:7&:%= $=:&:%%1& % =$=&$ %1 1$1&0 $:& = =<&=% =&0 1 7<&1:&$:<<< <=&$$ 0 71&:<= $=0&:%%1& % =$&$ %1 1$& $:& = =<%&<< $0&1 1 7:&01:%&0 <<< <<&< 0 7%=&<= $0&%<%1& % =7&=% %1 :& $:& = =<=&0$ <7&$ 1 17&=01:7&1:<<< 7$&0$ 0 7:&<= $0$&7$%1& % =:%&%1 %1 :1& $:& = =$<&1= %&1< 1 &%11:$&:<<<< 1=&70 0 :=0&$0= =7&$=%1& % =$&<7 %1 :& $:& = ==:&0 :=&0: % 0=7&<17&<<< =&10 0 :$$&%= =%1&0 %1& % $=7&77 %1 :$& $:& = =0&0 1$&$: % 0<:&:17:&<7 << 0=$&71 0 :<&:<= =%0&7%1& % $<%&0 %1 7& $:& = =0=&1% %$&$% % 07%&=117<&$=<< 0<&0 0 :7&=$= =1<&$%%1& % $:0&% %1 71& $:& = 0&1 =&=0 % 0%0&<%170&0%<< 07:&0: 0 :7&<= =:7&1 %1& % $%$&1 %1 7& $:& = 0%1&=: %&: % =0<&071:&<< 01%&7: 0 ::$&7== =7%&::%1& % <0&=% %1 7<:& $:& = 0%<&<: 70$&=7 % ==7&0017&<=<< 00&$ 0 :::&$$= =7&%:%1& % <=7&01 # $ " % &'( % ) )* +" ,! ! "#$%&'() (* (*+, - ,( %"#$%&'() - ! % . - , ( ! 4%6 8 456 9$! 456 23) 4%6 , - ! 4%6 , 4%6 2-3 4%6 +" ' ( ! 4%6 &'( % ( BB;B<?; ' %1 7$& $:& = 01&%7 707&<$ % =$:&0$1:&%=<< =0=&<1 0 ::&:= =7=&<7 %1& % <$7&== %1 & $:& = 01$&7 7=$&%1 % =%&101&7 << =$<&% 0 :11&:1= =&0%1& % <:&% %1 1& $:& = 0:7&$ 7$=&: % =10&17<&0<< =7&< 0 :%:&<= =<:&1%1& % <:%&= %1 & $:& = 071&< 7<=&:= % =$&::17:&$$<< =:1&< 0 :1&<1= =$&<%1& % <0&%< %1 $& $:& = 070&:$ 7$&1: % $=<&%=17&<:<< =%%&<$ 0 10%&%= =$$&=$%1& % =<&:: %1 <& $:& = 0<&<= 777&07 % $<&<=1:$&70 << $0%&77 0 1$=&1== ==&%=%1& % <:&%7 %1 <1& $:& = 0<:&00 7:%&7 % $7&==1:7&:<< $$%&07 0 1<7&7<= =01&70 %1& % :0&<$ %1 <7:& $:& = 0<0&1< 71%&17 % $:1&01:1&0 << $=&:= 0 1:&== =0$&$<%1& % 11&<: %1 <& $:& = 0$%&: 7%$&%$ % $1<&$=1:1&0$<< $:&%< 0 170&<$= =00&=%1& % %<& %1 <$& $:& = 0$=&<% 7:&: % $$&:%1:<&%%<< $::&00 0 1:&:== 0$&%%%1& % 701&71 %1 $& $:& = 0=&01 :0&1 % <=$&%%1:0&1<< $%7&= 0 111&%<= 0%7&71 %1& % 7<0&% %1 $1& $:& = 00:&1: :$=&=< % <<<&17171&:=<< <0:&7$ 0 1%&<= 01%&$:%1& % 77<&% %1 $& $:& 0 &7 :<=&:< % <77&$<17&1 << <$1&1: 0 %00&0= 010&7 %1& % 71:&70 %1 $$& $:& 0 $&= :0&< % <11&$717=&<<<< <&71 0 %=0&:%= 0:<&:%1& % 7%&:7 %1 =& $:& 0 %&%< :&0$ % <&171%&=<< <1=&% 0 %=&$7= 07:&<<%1& % :$0&$1 %1 =1:& $:& 0 1%&== :77&<: % $0&%=17&<=<< <$&%0 0 %$:&07= 0&:=%1& % :<&:7 %1 =1& $:& 0 11&7$ :77&%1 % $$&:717&7:<< <&:< 0 %$:&:0= 0&0$%1& % :=&<= %1 =& $:& 0 10&$= ::$&= % 7&1%&:<< =1&<= 0 %<&== 0=&1=%1& % ::$& %1 =$& $:& 0 :$&0 :1=&= % :1&$17=&%<<< <&77 0 %$&== 0<&0 %1& % :%&=7 %1 0& $:& 0 77&:0 :%0&: % %&%717&1 << :=&$1 0 %7$&%%= 0$1&=0 %1& % 10:&<% %1 01& $:& 0 %&$ :=&<1 % 7==&$17%&==<< %$&$ 0 %:&0<= 0=&1%1& % 1$&0: %1 0& $:& 0 0&% 10<&$= % 7<$&001:=&$<< 70$&$ 0 %1:&<== 0=$&%%1& % 17$&== %1 0$& $:& 0 <%&< 10:&1< % 7<1&101:$&=$<< 70%&7 0 %1&7= 0=0&<%1& % 17%&:< &(:=@A,( # $ " % &'( % ) )* +" ,! ! 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" .' * !" #$ ) & *, 6 " - 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 neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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. PRUDHOE BAY PBU B-05E 225-093 PRUDHOE OIL WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT B-05EInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVWell bore segAnnular DisposalPTD#:2250930Field & Pool:PRUDHOE BAY, PRUDHOE OIL - 640150NA1Permit fee attachedYesEntire Well lies within ADL28310.2Lease number appropriateYes3Unique well name and numberYesPRUDHOE BAY, PRUDHOE OIL - 640150 - governed by CO 341J4Well located in a defined poolYes5Well located proper distance from drilling unit boundaryNA6Well located proper distance from other wellsYes7Sufficient acreage available in drilling unitYes8If deviated, is wellbore plat includedYes9Operator only affected partyYes10Operator has appropriate bond in forceYes11Permit can be issued without conservation orderYes12Permit can be issued without administrative approvalYes13Can permit be approved before 15-day waitNA14Well located within area and strata authorized by Injection Order # (put IO# in comments) (For NA15All wells within 1/4 mile area of review identified (For service well only)NA16Pre-produced injector: duration of pre-production less than 3 months (For service well only)NA17Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)Yes18Conductor string providedYes19Surface casing protects all known USDWsYes20CMT vol adequate to circulate on conductor & surf csgYes21CMT vol adequate to tie-in long string to surf csgYes22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYes24Adequate tankage or reserve pitYes*Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement w/ fully cemented liner.25If a re-drill, has a 10-403 for abandonment been approvedYes26Adequate wellbore separation proposedNA27If diverter required, does it meet regulationsYes28Drilling fluid program schematic & equip list adequateYes*Variance to 20 AAC 25.036 (c)(2)(A)(iv) with compliance to rules 29BOPEs, do they meet regulationYes5000 psi.30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesThe last H2S reading on B-05B: 18 ppm on 3/3/2025.33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)NoB-Pad wells are H2S-bearing. H2S measures are required.35Permit can be issued w/o hydrogen sulfide measuresYesExpected reservoir presure is 3,278 psi (7.4 ppg EMW), MPD will be utilized to maintain ECD of 9.8 EMW.36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprTCSDate9/10/2025ApprJJLDate9/9/2025ApprTCSDate9/10/2025AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 9/10/2025