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Home My WebLink About225-086MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 16, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-110C PRUDHOE BAY UN AURO S-110C Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/16/2026 S-110C 50-029-23030-03-00 225-086-0 G SPT 6691 2250860 1673 2946 2947 2955 2948 192 300 300 300 INITAL P Austin McLeod 12/29/2025 Initial after coil tubing sidetrack 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN AURO S- 110C Inspection Date: Tubing OA Packer Depth 3 2452 2396 2381IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM251231092911 BBL Pumped:2.2 BBL Returned:2.2 Friday, January 16, 2026 Page 1 of 1             Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251222 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 1-35 50029216720000 186184 12/3/2025 READ PressTempSurvey T41215 END 2-36 50029220140000 190024 10/20/2025 YELLOWJACKET PLUG-PERF T41216 END 2-38 50029220900000 190129 11/14/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/15/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/22/2025 HALLIBURTON WFL-TMD3D T41217 END 2-48 50029226120000 195166 12/4/2025 READ PressTempSurvey T41218 END 2-60 50029223750000 193083 12/2/2025 READ PressTempSurvey T41219 MPU C-22A 50029224890100 195198 10/13/2025 YELLOWJACKET PERF T41220 MPU I-14 50029232140000 204119 10/15/2025 YELLOWJACKET CUT T41221 MPU R-111 50029238270000 225097 12/3/2025 YELLOWJACKET SCBL T41222 PBU 15-43 50029226760000 196083 11/25/2025 HALLIBURTON TMD3D-SiAct T41223 PBU 15-43 50029226760000 196083 11/23/2025 YELLOWJACKET CBL T41223 PBU C-32E 50029215590500 225102 11/20/2025 HALLIBURTON RBT T41224 PBU F-42A 50029221080100 207093 10/27/2025 YELLOWJACKET CBL T41225 PBU L-202 50029232290000 204196 10/23/2025 YELLOWJACKET RCBL T41226 PBU L-202 50029232290000 204196 10/30/2025 YELLOWJACKET RCBL T41226 PBU S-110C 50029230300300 225086 12/1/2025 HALLIBURTON RBT T41227 PBU S-24B 50029220440200 203163 11/19/2025 HALLIBURTON WFL-TMD3D T41228 Please include current contact information if different from above. PBU S-110C 50029230300300 225086 12/1/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.23 08:27:35 -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: 12/19/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL: WELL: PBU S-110C + PB1 + PB2 PTD: 225-086 API: 50-029-23030-03-00 (PBU S-110C) API: 50-029-23030-70-00 (PBU S-110CPB1) API: 50-029-23030-71-00 (PBU S-110CPB2) FINAL LWD FORMATION EVALUATION LOGS (11/21/2025 to 11/29/2025) x Multiple Propagation and Azimuthal Resistivity (2” & 5” MD/TVD Color Logs) x Final Definitive Directional Surveys x Pressure While Drilling SFTP Transfer – Main Folders: SFTP Transfer – Sub-Folders: Please include current contact information if different from above. T41212 T41213 T41214 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.19 10:26:34 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UN AURO S-110C JBR 01/21/2026 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 TJ Multi Joint 2-3/8 X 3-1/8 Accumulator bottles 16 @ 1106 psi precharge Test Results TEST DATA Rig Rep:J, Perl/E. GregoryOperator:Hilcorp North Slope, LLC Operator Rep:N. Wheeler/M. Nunley Rig Owner/Rig No.:Nabors CDR2AC PTD#:2250860 DATE:11/21/2025 Type Operation:DRILL Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopKPS251121103408 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4 MASP: 2988 Sundry No: Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2-3/8 P Annular Preventer 1 7-1/16"P #1 Rams 1 Blind / Shears P #2 Rams 1 2-3/8" Pipe sli P #3 Rams 1 3-1/8" Pipe sli P #4 Rams 1 2-3/8" Pipe sli P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16"P HCR Valves 2 2-1/16"P Kill Line Valves 2 2-1/16"P Check Valve 0 NA BOP Misc 2 2" piper P System Pressure P3100 Pressure After Closure P2300 200 PSI Attained P20 Full Pressure Attained P49 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P10 @ 2035 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 P Annular Preventer P4 #1 Rams P3 #2 Rams P3 #3 Rams P3 #4 Rams P3 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1        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, Aurora Oil, PBU S-110C Hilcorp Alaska, LLC Permit to Drill Number: 225-086 Surface Location: 4481' FSL, 4498' FEL, Sec 35, T12N, R12E, UM, AK Bottomhole Location: 1863' FSL, 2402' FEL, Sec 25, T12N, R12E, 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 AOGCCreserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCCspecifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCCorder, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, *UHJRU\ &. :LOVRQ Commissioner DATED this 27th day of August 2025. Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.27 09:42:14 -08'00' 3-1/2"x3-1/4" By Grace Christianson at 12:36 pm, Aug 07, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.08.07 10:41:36 - 08'00' Sean McLaughlin (4311) 225-086 DSR-8/14/25 *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 to 20 AAC 25.036 (c)(2)(A)(iv) approved f with documented well control drills performed by all crews deploying tubulars <2.375" OD without properly sized pipe rams. Provide AOGCC opportunity to witness. *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. 50-029-23030-03-00 JJL 8/26/25 A.Dewhurst 26AUG25JLC 8/27/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.08.27 09:30:29 -08'00' RBDMS JSB 082825 ®ôīīώbÍıô " I "ĖŜťÍĲèôώϯώťÍťŪŜĺŕώĺċώiĖīώĺĺīϼXŪŕÍŘŪħϠώa"ϽĺŕώĺċώiĖīώĺĺīϼXŪŕÍŘŪħϠώ«"ŜŜϽĺŕώĺċώıťϼa"Ͻĺŕώĺċώıťϼ«"ŜŜϽ¾ĺĲÍīIŜĺīÍťĖĺĲĺııôĲťŜϱ͐͐͏ ͑͏͐ϱ͐͑͘ ͔͏ϱ͏͑͘ϱ͑͒͏͒͏ϱ͏͏ϱ͏͏ ͐Ϡ͏͗͏ДώϯώЭДî ͗Ϡ͓͗͏Д ͕Ϡ͖͔͒Д ͒Ϡ͓͔͏Д ͑Ϡ͖͗͑Д ´ôŜŪıŕôîώ͕͔͐ϟ͒ώææīŜώĺċώ͐͑ϟ͏ώŕŕČώ[ĖťôŘôťôώĖĲώŜĖĲČīôώŜťÍČôώĤĺæώĺĲώ͖ГώŕŘĺîŪèťĖĺĲèÍŜĖĲČϟώbĺώīĺŜŜôŜώſôŘôώŘôŕĺŘťôîϟώIĲĖťĖÍīώIώīĺČώſÍŜώĖĲèĺĲèīŪŜĖŽôϟώώIώīĺČŘÍĲώĖĲώ͐ϯ͖ϯ͑͏͐͑ώŜēĺſŜώŜĺīĖîώiώÍťώ͒Ϡ͓͔͏Дώa"ϟώēôώ͖ГώŕŘĺîŪèťĖĺĲώèÍŜĖĲČώſÍŜèŪťώÍĲîώŕŪīīôîώċĺŘώťēôώϱ͐͐͏ώŜĖîôťŘÍèħώæŪťώťēôƅώēÍîώťĺώèŪťώŜôŽôŘÍīώťĖıôŜώťĺŕŪīīώċŘôôϠώĖĲîĖèÍťĖĲČώťēôŘôώſÍŜώīĖħôīƅώŘÍťťƅώèôıôĲťώôŽôĲώēĖČēôŘϟϱ͐͐͏ ͑͐͐ϱ͐͑͘ ͔͏ϱ͏͑͘ϱ͑͒͏͒͏ϱ͏͏ϱ͏͐ ͐Ϡ͕͔͑ДώϯώЭДî ͖Ϡ͖͘͘Д ͕Ϡ͕͖͘Д ͓Ϡ͓͐͏Д͒Ϡ͒͗͘Д ´ôŜϱ͐͐͏ώſÍŜώŜĖîôťŘÍèħôîώĺŪťώĺċώťēôώ͘ϱ͔ϯ͗ГώèÍŜĖĲČώĺċώťēôώϱ͐͐͏ώŕÍŘôĲťώæĺŘôϟŪıŕôîώ͐͘ϟ͕ώææīŜώĺċώ͐͐ϟ͏ώŕŕČώ[ĖťôŘôťôώÍŜώīôÍîώċĺīīĺſôîώæƅώ͓͒ϟ͑ώææīŜώĺċώ͔͐ϟ͗ŕŕČώīÍŜŜώД@ДώťÍĖīώŜīŪŘŘƅϟώbĺώīĺŜŜôŜώſôŘôώŘôŕĺŘťôîώÍĲîώÍώIώīĺČώŘÍĲώĺĲ͑ϯ͐͒ϯ͑͏͐͑ώŜēĺſŜώiώÍťώ͓Ϡ͓͐͏Дώa"ώſēĖèēώèĺŘŘôīÍťôŜώťĺώ͓͑҇ώſÍŜēĺŪťϟϱ͐͐͏ ͑͐͒ϱ͐͗͘ ͔͏ϱ͏͑͘ϱ͑͒͏͒͏ϱ͏͏ϱ͏͑͏ДώϯώiŕôŘÍæīôώ®@IĲĤôèťĺŘ͗Ϡ͖͔͐Д ͕Ϡ͖͔͕Д ͔Ϡ͏͔͏Д ͓Ϡ͏͐͗Д ´ôŜϱ͐͐͏ώſÍŜώŜĖîôťŘÍèħôîώĺŪťώĺċώťēôώ͘ϱ͔ϯ͗ГώèÍŜĖĲČώĺċώťēôώϱ͐͐͏ώŕÍŘôĲťώæĺŘôώÍŜſôīīϟώŪıŕôîώ͓͗ϟ͒ώææīŜώĺċώ͐͐ϟ͔ώŕŕČώ[ĖťôŘôťôώÍŜώīôÍîώċĺīīĺſôîώæƅώ͓͒ϟ͘ώææīŜώĺċ͔͐ϟ͗ώŕŕČώīÍŜŜώД@ДώťÍĖīώŜīŪŘŘƅϟώbĺώīĺŜŜôŜώſôŘôώŘôŕĺŘťôîώÍĲîώÍώIώīĺČώŘÍĲώĺĲ͑ϯ͗ϯ͑͏͓͐ώŜēĺſŜώiώÍťώ͔Ϡ͏͔͏Дώa"ώſēĖèēώèĺŘŘôīÍťôŜώťĺώ͓͑҇ώſÍŜēĺŪťϟaIϱIώŕÍŜŜôîώĺĲώ͒ϯ͔ϯ͑͏͑͒ώťĺώ͕͔͑͒ώŕŜĖϟŘôÍώĺċώôŽĖôſώώϱ͐͐͏ To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: August 7, 2025 Re:S-110C Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well S-110B with the Nabors CDR2/CDR3 Coiled Tubing Drilling. Proposed plan for S-110C Injector: See S-110B Sundry request for complete pre-rig details - Prior to drilling activities, screening will be conducted to drift/caliper and MIT. E-line or coil will mill the XN-nipple. Coil will mill out of slotted liner shoe pre-rig. If unable to set mill out slotted liner shoe pre-rig, 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 pre-rig, the rig will mill out of the slotted liner shoe with a 3.80" mill + 10' of formation. The well will kick off drilling and lands in the Kuparuk C. The lateral will continue in Kuparuk C, B and A to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” L-80 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 Aurora Pool slotted liner. 1. Slickline : Dummy WS drift and Caliper 2. Fullbore : MIT-IA and/or MIT-T to 3,100 psi (min) 3. Coil : Mill XN nipple (at 8,578' MD) and mill out slotted liner shoe with 3.80" mill plus 10' rat hole. 4. Valve Shop : Pre-CTD Tree Work 5. 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 2,988 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” out of slotted liner shoe (if not already done pre-rig) 3. Drill build section: 4.25" OH, ~117' (38 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,781' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” L-80 solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 38 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). 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. Post Rig Work: 1. Valve Shop : Valve & tree work 2.Slickline : Contingent set LTP. ParentwellborePBUS-110BonlyhasKuparukCsandsexposed.Thus,theproposeddesignwill confinehydrocarbonstotheirinGigenousstrata.-A.Dewhurst26AUG25 The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: x ReferenceS-110B Sundry submitted in concert with this request for full details. 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 (8,774' MD -6,878' TVD) Pumps On Pumps Oī A Target BHP at Window (ppg)3,934 psi 3,934 psi 11.0 B ŶŶƵůĂƌĨƌŝĐƟŽŶ- ECD ;ƉƐŝͬŌͿ 526 psi 0 psi 0.06 C DƵĚ,ǇĚƌŽƐƚĂƟĐ;ƉƉŐͿ 3,076 psi 3,076 psi 8.6 B+C Mud + ECD Combined 3,602 psi 3,076 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 332 psi 858 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: x The estimated reservoir pressure is expected to be 3,658 psi at 6,700 TVD. (10.5 ppg equivalent). x Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,988 psi (from estimated reservoir pressure). Mud Program: x Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: x All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. x Fluids >1% hydrocarbons or flammables must go to GNI. x Fluids >15% solids by volume must go to GNI. x Fluids with solids that will not pass through 1/4” screen must go to GNI. x Fluids with PH >11 must go to GNI. Hole Size: x 4.25" hole for the entirety of the production hole section. Liner Program: x 3-1/2", 9.3#, L80 /Solid: 8,600' MD – 8,630' MD (30' liner) x 3-1/4", 6.6#, L80 /Solid: 8,630' MD – 9,200' MD (570' liner) x 2-7/8", 6.5#, L80 /Solid: 9,200' MD – 11,670' MD (2,470' liner) x The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary. x A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: x BOP diagram is attached. MPD and pressure deployment is planned. x Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. x The annular preventer will be tested to 250 psi and 2,500 psi. x 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. x Solid 2-7/8” Liner Running Ram Change: Change out 3”/3-1/8” pipe/slip rams (for drilling) to 2-3/8” x 3- 1/2” VBR rams for liner run. Test VBR rams to 250 psi and 3,500 psi. x A X-over shall be made up to a 2 3/8" safety joint including a TIW valve for all tubulars ran in hole. x 2 3/8" safety joint will be utilized while running solid or slotted liner. The desire is to keep the same standing orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre-installed TIW valve). When closing on a 2 3/8" safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: x Directional plan attached. Maximum planned hole angle is 103°. Inclination at kick off point is 45°. x Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. x Distance to nearest property line – 8700 ft x Distance to nearest well within pool – 1070 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 1500' perforated post rig – See attached extended perforating procedure. 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 Aurora Pool. x Formations: Top of Aurora Pool is 8,715’ MD in the parent Anti-Collision Failures: x All Wells Pass AC scan Hazards: x DS/Pad is an H2S pad. The last H2S reading on S-110B: NA - injector. x Max H2S recorded on DS/Pad: 136 ppm. x 1 fault crossings expected. x Low lost circulation risk. Trevor Hyatt CC: Well File Drilling Engineer Joseph Lastufka (907-223-3087) Pre-Rig – Service Coil – Liner Shoe Millout The approved sundry and permit to drill will be posted in the Operations Cabin of the unit during the entire milling operation. Notes for milling: x 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 milling assembly – mill followed by string reamer. NOTE: Confirm milling BHA configuration prior to job execution due to variations in different service provider’s milling BHAs. 3. RIH & TAG shoe PBTD, calculate distance till string reamer is out of the shoe, paint coil flag and note in WSR. 4. Mill our of liner shoe per vendor procedure. – Make note of any WHP changes while milling 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 clean. Maximum approved distance to reciprocate beyond the shoe is 15 ft to ensure confidence the mill out is prepared for the sidetrack.DO NOT RECIPROCATE DEEPER than 15 ft. 6. Confirm exited liner & string reamer dressed entire shoe exit with coil flag and note bottom of shoe 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 – Liner Shoe 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 10.6 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 10.6 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 Aurora 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 670067506800685069006950True Vertical Depth (100 usft/in)4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 8200 8400 Vertical Section at 70.12° (400 usft/in)S-110BS-110C wp01KOP - End of Slotted Liner - 8772'MDEnd 38 dls - 8889'MDTD - 11670'MDS-110C wp01100015002000250030003500South(-)/North(+) (1000 usft/in)4500 5000 5500 6000 6500 7000 7500 8000 West(-)/East(+) (1000 usft/in)6400S-13APB18931S-41AL17200760080008400S-418961S-41A720076008000S-41PB16812S-1098860S-43L19033S-436 00 0 640 0 6 8 0 06880 S-110BM-2056921 S-110C wp01KOP - End of Slotted Liner - 8772'MDEnd 38 dls - 8889'MDTD - 11670'MDSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect1 8772.00 45.40 64.36 6878.84 1891.99 4686.42 0.00 0.00 5050.522 8889.37 90.00 64.36 6922.26 1937.80 4781.86 38.00 0.00 5155.853 8995.62 102.75 64.36 6910.48 1983.40 4876.86 12.00 0.00 5260.694 9085.62 102.52 53.29 6890.74 2028.78 4951.87 12.00 -90.00 5346.675 9196.42 90.00 48.78 6878.67 2097.92 5037.29 12.00 -160.00 5450.516 9297.00 89.16 36.74 6879.41 2171.63 5105.45 12.00 -94.00 5539.677 9747.00 87.89 90.75 6891.91 2363.39 5494.06 12.00 92.00 5970.338 9875.00 102.31 85.43 6880.55 2367.57 5621.10 12.00 -20.00 6091.229 9995.00 88.75 80.55 6869.00 2382.18 5739.33 12.00 -160.00 6207.3710 10110.00 88.79 66.74 6871.48 2414.48 5849.38 12.00 -90.00 6321.8511 10350.00 88.94 95.55 6876.34 2451.03 6083.98 12.00 90.00 6554.9012 10590.00 89.07 66.74 6880.60 2487.57 6318.60 12.00 -90.00 6787.9613 10830.00 89.18 95.55 6884.34 2524.13 6553.22 12.00 90.00 7021.0314 11070.00 86.88 66.82 6892.76 2560.46 6787.75 12.00 -95.00 7253.9415 11310.00 87.27 95.66 6905.28 2596.58 7022.14 12.00 90.00 7486.6416 11550.00 87.60 66.83 6916.26 2632.70 7256.60 12.00 -90.00 7719.4117 11670.00 87.68 81.24 6921.22 2665.60 7371.57 12.00 90.00 7838.71Depth From Depth To Survey/Plan Tool93.60 452.70 S-110 Srvy 1 CB GYRO SS (S-110) 3_CB-Film-GSS2477.86 2664.75 S-110 Srvy 2 MWD+IFR+MS (S-110) 3_MWD+HRGM+MS12710.00 2844.40 S-110B Srvy 1 INC+TREND (S-110B) 3_MWD_Interp Azi (BP INC+Trend)2939.30 6353.97 S-110B Srvy 2 MWD+IFR+MS (S-110B)3_MWD+HRGM+MS+Sag6448.29 8603.73 S-110B Srvy 3 MWD+IFR+MS (S-110B)3_MWD+HRGM+MS+Sag8730.14 8772.00 S-110B Srvy 4 MWD (S-110B) 3_MWD8772.00 11670.00 S-110C wp01 (S-110C) 3_MWDSECTION DETAILSSURVEY PROGRAMProject: Prudhoe BaySite: SWell: S-110Wellbore: S-110CPlan: S-110C wp01REFERENCE INFORMATIONCoordinate(N/E) Reference: Well S-110, True NorthVertical (TVD) Reference: KB @ 83.15usft (S-110B ACTUAL)Measured Depth Reference: KB @ 83.15usft (S-110B ACTUAL)Section (VS) Reference: Slot - (0.00N, 0.00E)Calculation Method: Minimum CurvatureParent Wellbore: S-110BTop of Window: 8772.00Northing: 5980684.85Easting: 618929.96Lattitude: 70° 21' 21.1766 NLongitude: 149° 2' 2.8967 WNAD 1927 (NADCON CONUS)US State Plane 1927 (Exact solution)Alaska Zone 04REFERENCE INFORMATIONWELLBORE DETAILSWELL DETAILSHilcorp Alaska, LLCPROJECT DETAILSS-110C wp01 !! 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& '() & * *+ , -" !"#$%&'( )* + )., )+-./ )- -) &!"#$%&'( )* + / " & 0 ) - ) " 7&9 ; 789 <%" 789 546* 7&9 - / ". 7&9 - 4. 7&9 5/6 7&9 , ( ) " 7&9 '() & )! >@@?A ( 3 1==%3= $1%21 = 23%29 ==3%1& 9 21%$=&%==2$ %=$& 1#2 91%2== ##%1 %3 9 &2&%$1 # =%&$ $1%22 = $99%=$ =1$%21 9 2=$%$#=9%1&=2$ =&%&3& 1#2 99&%9== 2=%9#% 9 &#&%2 # &=%&3 $1%$3 = 9#%# 3#%3& 9 $3%12=9%11 =2$ 21%=1& 1#2 93%31= $$&%$%= 9 =9&%3 # 2&%&# $1%$9 = 91%=9 399%$= 9 $32%9==9%3=2$ 23$%#& 1#2 91#%2&= 9#%91 %1 9 3&%= # $9&%19 $1%2& = &=9%=3 3=1%== 9 92=%==&%1 =2$ $23%&$& 1#2 &29%9= 9#%&2 %$9 9 3=9%&# # 99%#2 $1%2& = =$#%9 319%&3 9 9#%2=&%33 =2$ $#%39& 1#2 &&%#= &&9%11 %$1 9 #29%9 # &$=%9 9%== = 3%&1 #2%2& 9 &$3%9=&%2 =2$ 9$3%&& 1#2 &3=%3&= =23%99 2%&3 9 ##&%1# # =$%3$ 99%&9 = 3=% #9%& 9 &31%&=$%1&=2$ 93#%1$& 1#2 &13%$= =3=%#=9%92 9 1$2% # 3$%9 9&%9 = #91%9& #31%1 9 =&1%&&=9%$==2$ &&#%3& 1#2 =$3%&2= 3==%$%32 & 2%#= # 332% 9&%9 = #3#%#9 #1%11 9 =#=%92=9%$==2$ &#&%$=& 1#2 =&%#9= 31&%=1 % & &%&2 C:4 & !@BBD-) # 3#% 9#%99 = ##9%$ #19%&2 9 =1%=1=9%$==2$ &1%&1& 1#2 =&$%9&= #%&$#% & &=%$$ # 31% &2%29 = #1%=# #13%#& 9 =1#%=$=9%$==2$ &13%93& 1#2 =&=%#1= #3%&$$#% & =$%11 # #% &=%9 = #1=%&9 1%$& 9 3&%1$=9%$==2$ =9%32& 1#2 ==%&= #$%$1 $#% & 32%& # #% &1%#9 = 1%#& 1&%2 9 3$%&3=9%$==2$ =2%$& 1#2 ==9%$= ##%3$#% & #%9# # #2% =$%=9 = 1=%&# 1#%#$ 9 32%&=9%$==2$ =2%#& 1#2 ==#%2$= #2$%9$$#% & #1%29 # #$% =3%99 = 1%32 12%33 9 321%3=9%$==2$ =2#%$2& 1#2 =32%$= #23%&3 $#% & 1#%$ # #9% 3%29 = 19%2& 1=%#2 9 3$#%&=9%$==2$ =$=%=#& 1#2 =3=%9#= #$%$#% & 3%= # #&% 3&%9 = 13%& 12%1= 9 39=%33=9%$==2$ =9&%29& 1#2 =#%3== #$9%$#% & 3%2 # #=% 3#%#9 = 11%9 12&%3 9 3&&%&==9%$==2$ =&$%1=& 1#2 =#&%= #$=%2=$#% & 2=%#2 # #3% #2%=9 = 12%2 121%99 9 3=9%9&=9%$==2$ ==2%3#& 1#2 =#1%&2= #$3%#3 $#% & $=%=$ # ##% #=%99 = 12%13 1$$%3& 9 33$%92=9%$==2$ =3%=#& 1#2 =1$%13= #$#%#2 $#% & 9=%&9 # ##1%$3 1% = 122%2= 1$3%# 9 3#%#3=9%$==2$ =#%=& 1#2 =1#%== #$1%$3%11 & &&%#& 4=@@@@AD-) # 1% 1%2# = 122%9 192%9 9 31%9&=9%$==2$ =#1%&3& 1#2 32%1= #$#%11 2% & ==%9$ # 12&% 19%2# = 12%1$ 1&$%2 9 #$%1==9%$==2$ 3%1& 1#2 39%== #$3%3#2% & 1%23 # 1&% 13%2# = 1#%9 1=$%13 9 #$=%$#=9%$==2$ 3$9%&& 1#2 32&%#= #$&%2=2% & 2=% # 13&% %2# = 19%= 139%== 9 #&#%=&=9%$==2$ 3&=%29& 1#2 3$=%22= #$%9&2% & 29%&1 # 11&%=2 2%3& = 1%9# 1#$%9 9 #3=%#==9%$==2$ 339%$& 1#2 39&%2&= #23%$$2% & 2=%=1 1 % 2%3& = 11%&2 1#&%23 9 ##%3=$%#2 =2$ 33#%$& 1#2 393%#= #2=%$3 2% & 2=9%19 1 2&% 2%3$ = 19% 11=%= 9 12%21=%3&=2$ 311%&$& 1#2 3&#%#== #2%#&2% & 2#1% 1 &% 2%=3 = #1#%& 2 1%1 9 12$%29&3%=3 =2$ #2%23& 1#2 33%=3= #&%$=2% & $$%9 1 3&% 2%&3 = #1$%& 2 22%=# 9 19$%91&9%==2$ #9%$& 1#2 3#&%&#= #1%12% & $$=%3 1 #&%=2 2%&2 = #1%39 2 2#%3# 9 1&%#3&$%21 =2$ #9#%&1& 1#2 31%#2= #3%&1 2% & $9=%=3 1 % %1 = ##3%#2 2 $3%2= 9 1=$%2&2%=1 =2$ #&1%3& 1#2 #%93= #9%=3 2% & $=%2 1 2&% 1#%# = ##$%3 2 &2%$# 9 1#2%&1&%===2$ #3#%1$& 1#2 #&%#1= #%&&2% & $#$%&# 1 &% 1&%2& = ##%# 2 =3%1& & %1$&%=&=2$ #1#%& 1#2 #$%33= 313%=&2% & 93%= 1 3&% 12%92 = #31%$ 2 #$%19 & 2%#91%=9 =2$ 1=%1& 1#2 #9#%== 31&%1#2% & 9$%& 1 1=%92 1% = #3#%=3 2 13%12 & $3%219#%3#=2$ 1$2%#1& 1#2 #=2%$= 31&%&2 2% & 9&%& 1 2% #1%13 = #3#%=# 2 %21 & $1%139#%$&=2$ 1$&%&$& 1#2 #=9%3= 31&%&$2% & 9&$%#$ 1 22&% #1%3= = #3#%3$ 2 3%$1 & &#%29&%$==2$ 1&$%&& 1#2 ##2%1= 31&%&#2% & 93=%# 1 2&% #1%&& = #3#%## 2 $&%9 & 3&%&$92%$3 =2$ 13%&$& 1#2 1%$#= 31&%3$2% & 911%22 1 23&% #1%$& = #31%2 2 &9%$ & 1%#1$1%$#=2$ 1#=%&#& 1#2 11%&9= 31&%13 2% & &2%$ 1 213% #1%= = #31%9 2 3%=$ & &%9&$=%39 =2$ 111%#=& 1#2 1$3%3= 31=%2=2% & &$1%=3 1 $% #1%& = #31%9= 2 39%$ & 3%2&$3%=29 %=$& 1#2 1$1%&= 31=%$2% & &92%# $ % ! & '() & * *+ , -" !"#$%&'( )* + )., )+-./ )- -) &!"#$%&'( )* + / " & 0 ) - ) " 7&9 ; 789 <%" 789 546* 7&9 - / ". 7&9 - 4. 7&9 5/6 7&9 , ( ) " 7&9 '() & )! >BA>?B ( 1 $2&% #1%& = #31%#& 2 1$%&= & 22%#&9%=29 =%1& 1#2 1&1%23= 31=%32% & &=$%9# 1 $&% ##%1& = ##%21 2 22%2& & $1%999$%=29 $$%2& 1#2 13#%22= 313%9 2% & &#&%99 1 $3&% ##%#& = ##%33 2 2$%& & &=%119=%=29 &%9=& 1#2 11=%21= 313%=2 2% & =#% 1 9% ##%3= = ##%21 2 29=%1 & 3&%9991%=29 =#%=&& 1#$ $%99= 31#%9 2% & =$%# 1 92&% ##%== = ##%#& 2 2=2%3= & 19%3&&2%=29 #3%3& 1#$ 21%== 31#%32% & =&9%=9 1 9&% ##%&# = ##2%9& 2 233%= & 29%#=&&%=29 3%&3& 1#$ 99%3&= 311%$2% & =3#%&1 1 93&% ##%91 = ##$%1 2 21%$& & 2$&%32&#%=29 2#%2& 1#$ &#%#9= 311%19 2% & 32%#1 1 &% ##%9 = ##$%33 2 $9% & 2&3%2#=%=29 91%&=& 1#$ 3%#2= #%=2 2% & 323%9= 1 &2&% ##%$9 = ##9%9# 2 $&%& & 231%9==9%=29 3%&&& 1#$ #$%=3= #%$$2% & 3&2%2$ 1 &&% ##%23 = ##&%22 2 $2&%#2 & $2%2=3%=29 19%9& 1#$ 19%$== #2%3 2% & 333%9 1 &3&% ##%2 = ##&%11 2 $$9%19 & $2&%9#3%=29 23%2&& 1#$ $%#9= #2%#9 2% & #2%2 1 =% ##%9 = ##=%3# 2 $92%#$ & $91%#3$%=29 29%#$& 1#$ 2%= #$%=$2% & #23%1 1 =2&% ##%1 = ##3%= 2 $91%93 & $3$%233=%=29 2=9%#& 1#$ 1%2= #9%9=2% & #&2% 1 =&% ##%$ = ###%9& 2 $&9%#$ & $13%=331%=29 2#1%& 1#$ 29%#3= #&%$2% & #3=%33 1 =3&% #3%11 = ##1%$2 2 $&#%1 & 922%$#2%=29 $$%=1& 1#$ 21%$9= #=%3 2% & 1%$$ 1 3% #3%1& = #1%2 2 $=%=1 & 993%9#&%=29 $$#%93& 1#$ $2%&2= #3%=2% & 12&%=$ 1 32&% #3%12 = #1% 2 $=$%3 & 932%###%=29 $=$%$3& 1#$ $9%9= #3%1=2% & 191%&# 1 393%#3%#1 = #1%1 2 $=$%$1 & 919%=1%3&=29 $#&%$&& 1#$ $9%13= ##%3=2% & 13%$$ 1 3&% ##%2$ = #12% 2 $=$%$= & 913%=1%=2 =29 $##%$&& 1#$ $9%1#= ##%#=2% & 13$%9 1 33&% 1%& = #12%3 2 $=$%$ & &22%&#1%==29 9$%$9& 1#$ $&%$$= #1%2 2% & 11=%=$ 1 #% 1$%#3 = #1% 2 $=$%3 & &93%$##%&3 =29 9$#%$& 1#$ $=%2= #3%1&2% = 2%29 1 #2&% 1=%=# = ###%# 2 $=9%&& & &3%1#3%&9 =29 9=$%=& 1#$ $3%$== #&%=&2% = 9$%1$ 1 #&% 11%& = ##&%2# 2 $=&%#9 & &1=%=2#=%91 =29 9#3%#9& 1#$ $1%9= #2%$2% = =3%= 1 #3&% 2%$ = ##%&& 2 $=3%&3 & =2%#&%9$=29 &2%$& 1#$ 9%== 313%92% = 1%22 1 1% 11%91 = #3&%#2 2 $=1%3& & =9&%&&#9%$1 =29 &$=%3& 1#$ 9$%3$= 312%=3 2% = 9%1& 1 12&% 1=%=3 = #32%$ 2 $32%$1 & =3%=#$%$==29 &=%23& 1#$ 9=%3== 3#1%=2% = $#%11 1 1&% 1$%#9 = #3%2 2 $3&%91 & =19%#=#2%$&=29 &#&%1& 1#$ &%2&= 3#=%#3 2% = =$%23 1 13&% 1% = #=#%1= 2 $31%$ & 31%&##%$&=29 =%&3& 1#$ &9%#= 3#&%#2% = #3%3$ 1 11&% ##%3& = #=1% 2 $#2%# & 3$1%$$#%&&=29 =$%23& 1#$ &3%=9= 3#&%#&2% = 23%$3 % ##%3& = #=1% 2 $#$%$ & 399%2=31%1&=29 =$&%#& 1#$ &#%&== 3#&%1=2% = 22%21 2&% ##%3= = #=1%== 2 $##%$ & 3=#%393=%19 =29 =&1%&#& 1#$ =$%1== 3#=%&2% = 2$3%2 &% ##%3= = #3%2 2 $19%$ & 312%1$3$%19 =29 =#$%==& 1#$ 3%=2= 3#3%&2% = 2=%1 3&% ##%33 = #3%39 2 9%#& & #=%3=3%19 =29 33%$3& 1#$ 3#%&9= 3#3%&1 2% = 2#=%#3 % ##%3# = #3%23 2 9%=$ & #9%==3%19 =29 3$%=2& 1#$ #3%=#= 3##%2 2%= $%#= % ##%31 = #3%9# 2 99%9# & #91%$#==%39 =29 3$1%31& 1#$ 1%=#= 3##%$$2% = $2%#& 2&% ##%31 = #3%# 2 92%# & #=$%2&=#%&9 =29 3&$%&=& 1#$ 13%== 3##%=&2% = $$=%#$ &% ##%31 = #32%$$ 2 92#%3 & ##=%393%&9 =29 33=%1& 1#$ 2=%&= 3#1%#2% = $=%#2 3&% ##%# = #32%#& 2 9$=% & 1%=&39%&9 =29 #%=1& 1#$ 29%3= 3#1%32% = $#=%3# 2% ##%# = #3$%$3 2 992%$ & 1$9%133%&9 =29 #29%#&& 1#$ 22%&#= 31%22 2% = 9%=9 22&% ##%#2 = #3$%#1 2 99=%3# & 1&1%99#%&&=29 #91%$& 1#$ 22&%32= 31%39 2% = 9$=%$$ 2&% ##%#9 = #39%9 2 9&%29 & 1#9%1#$%&&=29 #39%& 1#$ 221%&3= 31%2&2% = 9=%3# 23&% ##%#= = #39%1 2 9&2%$1 = 1%1#=%&&=29 #1#%#&& 1#$ 2$2%2= 31%3&2% = 9#9%1$ $% ##%## = #3&%$1 2 9&$%2& = $9%3#1%&&=29 12$%#& 1#$ 2$$%$3= 312%29 2% = &#%3 $2&% ##%1 = #3&%#3 2 9&2%31 = &1%&12%&&=29 19#%#& 1#$ 2$$%$= 312%32 2% = &$2%& $&% ##%19 = #3=%$9 2 9&%$ = #$%1#1&%&&=29 13$%3=& 1#$ 2$%19= 31$%1 2% = &&9%1 $ % ! & '() & * *+ , -" !"#$%&'( )* + )., )+-./ )- -) &!"#$%&'( )* + / " & 0 ) - ) " 7&9 ; 789 <%" 789 546* 7&9 - / ". 7&9 - 4. 7&9 5/6 7&9 , ( ) " 7&9 '() & )! >BA=?>> ( $3&% ##%19 = #3=%# 2 991%2= = #%112%&&=29 11#%3& 1#$ 2$%&3= 31$%==2% = &33%39 9% ##%19 = #33%23 2 99#%# = $$%1#1%&&=2& 2$%3& 1#$ 2$%&= 319%2 2% = =%1 92&% ##%1& = #33%3$ 2 991%== = &#%###=%&&=2& 9#%==& 1#$ 2$%3== 319%&#2% = =29%#= 9&% ##%1= = #3#%# 2 9&%# = #$%3##$%&&=2& 3$%&2& 1#$ 2$9%$2= 31&%$2% = =91% 93&% ##%13 = #3#%=$ 2 9&&%23 = 2#%&$#%&&=2& 1#%2& 1#$ 2$#%3= 31&%9#2% = =3$%93 &% ##%11 = #31%# 2 9=%2 = 2$$%333%&9 =2& 22%=3& 1#$ 29$%$= 31&%1$2% = =1#%= &2&% #1% = #31%& 2 9==%& = 2&3%$$39%&9 =2& 9=%#$& 1#$ 291%32= 31=%$=2% = 32$%2 &&% #1%$ = #31%19 2 93$%$9 = 2#%2$3%&9 =2& 3%=& 1#$ 2&3%$#= 31=%31 2% = 393%1# &3&% #1%& = ##%$= 2 9#%#3 = $9%3$=#%&9 =2& 1$%1=& 1#$ 2==%2#= 313%22% = 332%13 &1% #1%3 = ##%= 2 9#3%&3 = $#%===%39 =2& 23%39& 1#$ 232%2= 313%9&2% = 3#3%1= =% #1%3 = ##%33 2 91%9$ = $23%#2=3%19 =2& 2=%1& 1#$ 23=%2= 313%=2 2% = 313%19 =2&% #1%3 = ##%3 2 &%2 = $&%2$3%19 =2& 29%=& 1#$ 2#&%$&= 31#%2 2% = #22%19 =&% #1%# = ##%&# 2 &3%39 = $3&%=3$%19 =2& 2=$%#3& 1#$ 21$%23= 31#%9$2% = #93%1 =3&% #1%# = ##%1# 2 &9%2 = $11%2&3=%19 =2& 2#3%1=& 1#$ 211%1$= 31#%#$2% = #32%31 3% #1%1 = ##2%$3 2 &1%$ = 92$%3931%1&=2& $2%$=& 1#$ $&%$$= 311%22 2% = #13%&$ 32&% #1% = ##2%33 2 &22%3& = 99#%9&#2%1&=2& $$3%& 1#$ $1%9$= 311%=2 2% = 122%$ 3&% #1%2 = ##$%& 2 &2&%3 = 93$%$$#&%1&=2& $=%#9& 1#$ $2%2&= #%2% = 19=%2& 33&% #1%9 = ##$%&$ 2 &2=%2# = 91#%$##%1&=2& $#=%31& 1#$ $$%3== #%$#2% = 13% #% #1%= = ##$%1 2 &2=%1 = &2$%211%1&=2& 9%3#& 1#$ $$%1== #%3&2% = 11$%&& #2&% #1%# = ##9%23 2 &29%&# = &9#%2919%1&=2& 9$=%3&& 1#$ $2%#&= #%2 2% 3 =%& #$% #1%# = ##9%$9 2 &29%$ = &&$%221&%&&=2& 99%3$& 1#$ $2%9#= #%1 2% 3 2%$ #&% ##%1# = ##9%== 2 &22%= = &3$%=1$%==2& 9=%=1& 1#$ $%2#= #%&2% 3 $1%2= #3&% ##%32 = ##&%= 2 &2%## = &1#%91%3 =2& 9#=%=#& 1#$ $%1&= #2%2% 3 =2%& 1% ##%9= = ##&%3# 2 &22%9= = =2$%2#3%#=2& &%=&& 1#$ $%12= #2%=$2% 3 #=%2 12&% ##%2 = ##=%& 2 &29%$& = =9#%9#9%1 =2& &$=%&$& 1#$ $9%2= #$%$&2% 3 %23 1&% #3%13 = ##3%$$ 2 &23%&2 = =32%#2#%1 =2& &=%2&& 1#$ $3%33= #9%#2% 3 $9%=& 13&% #3%3$ = ###%23 2 &$%11 = =13%$13#%2=2& &#&%3&& 1#$ $22%=$= #&%2 2% 3 &1%2# % #3%91 = ##1%$2 2 &$3%39 = 32%33&%2=2& =1%1=& 1#$ $2#%3== #=%3 2% 3 #9%1 2&% #3%23 = #1%9= 2 &99%39 = 39&%=332%2=2& =$$%#2& 1#$ $$=%9= #3%$2% 3 21%2 &% #3%& = #1%3 2 &&2%11 = 3=1%2$=1%22 =2& =&3%2&& 1#$ $99%3== ##%&&2% 3 2$$%1# 3% #=%## = #12%3= 2 &=%9= = 3#3%3&==%#2 =2& =3&%=9& 1#$ $&2%&$= #1%=2% 3 2&$%19 3&% #=%## = #1$%$ 2 &=2%9 = 312%$&=3%92 =2& =#%2& 1#$ $&9%&9= #1%##2% 3 2&#%12 % #=%## = #19%$1 2 &3%$# = #&%=93%9$=2& 3$%$&& 1#$ $=$%##= #%29 2% 3 2#$%## 2&% #=%1 = #1&%3& 2 &31%2 = #$1%$33$%9$=2& 32=%1&& 1#$ $32%= #2%=2% 3 $#%#$ &% #=%12 = #13%1 2 &#&%= = #=$%933=%9$=2& 3&%1&& 1#$ $3#%#3= #$%19 2% 3 $$$%3 3&% #=%1& = #1#%9$ 2 &1%#$ = ##3%#131%99 =2& 33&%23& 1#$ $#9%9#= #&%2#2% 3 $&#%9$ 2% #=%11 = #11%3& 2 &19%3= = 12%&9#2%99 =2& 311%#&& 1#$ $##%#= #=%=2% 3 $#2%1& 22&% #3%9 = 1%& 2 &13%$1 = 1$3%$=#&%9&=2& #29%=$& 1#$ $1%#$= #3%12% 3 93%1 2&% #3% = 12%$$ 2 &1#%32 = 1=2%21##%9&=2& #91%&$& 1#$ $1$%&&= #1%#2% 3 9$%# 23&% #3%= = 1$%&# 2 &1#%39 = 1#3%2&1%9&=2& #39%91& 1#$ $1$%13= #2%9$2% 3 9&9%&3 $% #3%2$ = 19%# 2 &13%9= 3 2%119%9&=2& #11%99& 1#$ $1$%#= #2%=&2% 3 933%&# $% #3%23 = 1&%2# 2 &1=%&# 3 22%91&%===2& 11%9& 1#$ $12%$== #22%$2% 3 9#=%=9 $2&% #3%23 = 1=% 2 &1&%$$ 3 $3%31$%#&=2& 129%$&& 1#$ $1%$&= #22%#&2% 3 &%2= $&% #3%23 = 13%1 2 &19%$ 3 =2%21%#&=2& 191%$& 1#$ $1%32= #29%9 2% 3 &2$%$3 $3&% #3%21 = 1#%$3 2 &19%&1 3 #=%1##3%#&=2& 139%23& 1#$ $1%9= #2&%22 2% 3 &9=%19 $ % ! & '() & * *+ , -" !"#$%&'( )* + )., )+-./ )- -) &!"#$%&'( )* + / " & 0 ) - ) " 7&9 ; 789 <%" 789 546* 7&9 - / ". 7&9 - 4. 7&9 5/6 7&9 , ( ) " 7&9 '() & )! >@>? ( 9% #3%$ = 11%&& 2 &1=%1 3 %1#9%#9 =2& 111%=& 1#$ $1$%$1= #2=%92% 3 &3%12 92&% #3%$9 = 1%32 2 &11%# 3 $=%3#%#9 =2= 2$%1& 1#$ $1=%=#= #23%&3 2% 3 &1&%2$ 9&% #3%$# = 1%#3 2 =$%23 3 =%$23#%#9 =2= 9#%9&& 1#$ 9%2== #2#%32 2% 3 =1%# 93&% #3%9$ = 1$% 2 =#%3& 3 #&%=#3&%#9 =2= 32%32& 1#$ 93%2= #21%#&2% 3 =99%&3 &% #3%9# = 19% 2 =&%91 3 21%3$32%#$=2= 1=%==& 1#$ 99%29= #$%1=2% 3 ==1%9# &2&% #3%&9 = 1&%2 2 =2$%9# 3 2$$%$1=1%#$=2= 2%#& 1#$ 922%== #$2%&2% 3 =19%9& &&% #3%= = 1=%2= 2 =$2%3 3 2&=%===%#$=2= 9$%29& 1#$ 9$2%2= #$$%2% 3 31%9 &3&% #3%= = 13%$ 2 =9%1$ 3 231%#=1%#$=2= ==%$& 1#$ 99%31= #$9%&2% 3 399%$3 =% #3%=2 = 1#%$9 2 =91%12 3 $$%9332%#$=2= #1%#$& 1#$ 9&%== #$&%1 2% 3 3=1%$9 =2&% #3%=$ = 11%$# 2 =&=%=3 3 $23%&23&%#9 =2= 2$%33& 1#$ 9&3%2#= #$=%2$2% 3 319%2& =&% #3%== = 12%9 2 ==2%9 3 $&%#13#%#9 =2= 2$#%9& 1#$ 9=$%9= #$3%2=2% 3 #1%$ =3% #3%=# = 12%22 2 ==&%= 3 $3%&3#%29 =2= 2&3%==& 1#$ 9==%1= #$#%3 2% 3 #$#%3 ')>BD-) ( ) " 7&9 - ) " 7&9 . )% 7E9 )% 7E9/% . 6.*)76575-= #3#%#9# 332%9A2 =A# 23A#<= 12%22 =3%23A# 9A9 - ) " 7&9 ( ) " 7&9 546* 7&9 5/6 7&9 ! %% # 332% = #3#%#9 #1%11 9 =#=%92 !6-'#332>. # ##1%$3 = 122%2= 1$3%# 9 3#%#3 -$####1>. =3% = 12%22 2 ==&%= 3 $3%&3 ).=3>. !"" #$ $ !"" !"" % " ! &' ' !"# $ %&'()*&'()* + ' !"# $ %&',*&' & ' %- &'! # .' + , / , ' &0' 1 -! . 0.'! # &02 * 2'/0+1+ %/ # 0 &*3' 21&& ()*&' 4 , ' * 3' & .,' , ' .&' 5 ' 3 * 0 /) 45 65 73%/8 &. )#) 9 #. +0 3, -"!# ::-! ;:!# + < ) # ;-! # 2 2' 303/./ ' -! ))) / = 3, ' 5 6& 7 /(3 * (-/6027 ( 6& 7 * :>-?>--" 176 -- 6 8 7 . . *@ !; ?"-!: , 6A5 $ ' 1+0B6+B+ -+ 8 6+ ) 9 ?::!; -;;?!:" , - +0B37B+ $ ' 1+013 C $( 34B%)'-+D8 3 ) C*-:! -??!? , 34B%/40 $ ' 1+0B6+B+ B ."+D8 6+ ) 9 -@ @! ; " !@: , - +0B37B+ $ ' 1+0B6+B+ B ."+D8 6+ ) 9 ;??!-@ ; !: , +0B37B+ $ ' 1+0 +D>3 ?8 66+ ) : !? ::-! , ? +0 $ ' 1+0 +D>3 ?8 66+ ) ::-! ;:! 2 $ ' 1&& 0!02!*3 & , * 6& 7 1&& , * 6& 7 % 6& 7 % . 6& 7 5 03 - * + +- +- +-5 # . +-" +-" +-"5 # . +-: +-: +-:5 # . +-: +-: +-: 25 # . 5 # . 5 # . 2 ( "# +0 5 # . ( 2:5 # . ( (5 # . 5 # . ( (5 # . - - -5 # . - - -5 # . - - -5 # . - -( -(5 # . - -( -(5 # . ( 8 2?5 # . 5 # . ? ? ?5 # . " " "5 # . " " "5 # . ; ; ;5 # . ; ; ;5 # . ; ; ;5 # . + ) ,. 7 # / ! &' ' !"# $ %&'()*&'()* + ' !"# $ %&',*&' & ' %- &'! # .' + , / , ' &0' 1 -! . 0.'! # &02 * 2'/0+1+ %/ # 0 &*3' 21&& ()*&' 1&& 0!02!*3 & , * 6& 7 1&& , * 6& 7 % 6& 7 % . 6& 7 5 03 - * ; ;( ;(5 # . ; ;( ;(5 # . : : :5 # . : : : 2"5 # . 5 # . @ @ @ 5 # . @ @( @(5 # . / 7 ::-! ":-! :!- @"@!:@ !" / 7 ::-! :?! -?!:: ;!-@ -@!- - 46 E 0. / 7 ::?!:; ::?! !:; !? ! ? 5 # . ( (5 # . (- (-5 # . - - -5 # . - - -5 # . - -( -(5 # . - -(- -(-5 # . 5 # . 5 # . 5 # . 5 # . ? ? ?5 # . ? ? ?5 # . " " "5 # . ; ; ;5 # . ; ; ;5 # . ; ;( ;(5 # . ; ;(- ;(-5 # . : : :5 # . 5 # . @ @ @ 5 # . @ @ @5 # . - - -5 # . - - -5 # . - -( -(5 # . -- -- --5 # . -- --( --(5 # . -- --(- --(-5 # . -- --( --( 5 # . -? -? -?5 # . -" -" -"5 # . -" -"( -"(5 # . 5 # . ( (5 # . - - -5 # . + ) ,. 7 # / ! &' ' !"# $ %&'()*&'()* + ' !"# $ %&',*&' & ' %- &'! # .' + , / , ' &0' 1 -! . 0.'! # &02 * 2'/0+1+ %/ # 0 &*3' 21&& ()*&' 1&& 0!02!*3 & , * 6& 7 1&& , * 6& 7 % 6& 7 % . 6& 7 5 03 - * - - -5 # . - -( -(5 # . - - -5 # . - - -5 # . - -( -(5 # . - - - 5 # . - - - 5 # . - - - 5 # . - - - 5 # . - - - - -5 # . - - - 5 # . -; -; -;5 # . ? ? ?5 # . ? ? ?5 # . ? ? ?5 # . ? ? ?5 # . ? ?( ?(5 # . ? ? ? 5 # . ? ? ? 5 # . ?? ?? ??5 # . ?? ?? ??5 # . ?? ?? ??5 # . ?? ??( ??(5 # . + ) ,. 7 # / ! &' ' !"# $ %&'()*&'()* + ' !"# $ %&',*&' & ' %- &'! # .' + , / , ' &0' 1 -! . 0.'! # &02 * 2'/0+1+ %/ # 0 &*3' 21&& ()*&' " : " ? - ? ; - + ) 0* )) ( = = = / 6 / 4 0 ) , 8 ) & ( @-: $/< ' E ? 6) ,. # 8 !@F +) "F G ! 5## 0* , 5## 0 # 0* , !"# $ %&' + ) ,. 7 # / ! &' ' !"# $ %&'()*&'()* + ' !"# $ %&',*&' & ' %- &'! # .' + , / , ' &0' 1 -! . 0.'! # &02 * 2'/0+1+ %/ # 0 &*3' 21&& ()*&' ! ! ;! @! 7 - ? ; + ) 0* 46 E 0. ,) H) () H! 45/5 7 ( = = = / 6 / 4 0 ) , 8 ) & ( @-: $/< ' E ? 6) ,. # 8 !@F +) "F G ! 5## 0* , 5## 0 # 0* , !"# $ %&' + ) ,. 7 # / Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3"or 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Revised 7/2022 TRANSMITTAL LETTER CHECKLIST WELL NAME: ______________________________________ PTD: _____________________________________________ ___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional FIELD: __________________________ POOL: ____________________________________ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL (If last two digits in API number are between 60-69) The permit is for a new wellbore segment of existing well Permit Number _____________, API Number 50-______________________. Production from or injection into this wellbore must be reported under the original API Number stated above. Spacing Exception The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce or inject is contingent upon issuance of a conservation order approving a spacing exception. The Operator assumes the liability of any protest to the spacing exception that may occur. Dry Ditch Sample All dry ditch sample sets submitted to the AOGCC must be in no greater than 30-foot sample intervals from below the permafrost or from where samples are first caught and 10-foot sample intervals through target zones. Non- Conventional Well Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for this well until after the Operator has designed and implemented a water-well testing program to provide baseline data on water quality and quantity. The Operator must contact the AOGCC to obtain advance approval of such a water-well testing program. Well Logging Requirements Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by the Operator in the attached application, the following well logs are also required for this well: Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. 225-086 PRUDHOE BAY AURORA OIL PBU S-110C WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UN AURO S-110CInitial Class/TypeSER / PENDGeoArea890Unit11650On/Off ShoreOnProgramSERWell bore segAnnular DisposalPTD#:2250860Field & Pool:PRUDHOE BAY, AURORA OIL - 640120NA1Permit fee attachedYesADL0282572Lease number appropriateYes3Unique well name and numberYesPRUDHOE BAY, AURORA OIL - 640120 - governed by CO 457B4Well 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 waitYesAIO 22E14Well located within area and strata authorized by Injection Order # (put IO# in comments) (ForYes15All wells within 1/4 mile area of review identified (For service well only)No16Pre-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 pitYesVariance as per 20 AAC 25.112(i): Approved for alternate plug placement with 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 adequateYesVariance to 20 AAC 25.036 (c)(2)(A)(iv) approved with documented WC drills for tubulars < 2.375"OD.29BOPEs, do they meet regulationYes5K30BOPE press rating appropriate; test to (put psig in comments)Yes31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesMax H2S recorded on DS/Pad: 136 ppm.33Is presence of H2S gas probableNA34Mechanical condition of wells within AOR verified (For service well only)NoH2S measures required. Max H2S recorded of 136 ppm.35Permit can be issued w/o hydrogen sulfide measuresYesExpected pressure gradient is 10.5 ppg 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]ApprADDDate26-Aug-25ApprJJLDate21-Aug-25ApprADDDate25-Aug-25AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 8/27/2025