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Home My WebLink About224-0737. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 14-32B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 224-073 50-029-20999-02-00 12417 Conductor Surface Intermediate Scab Liner Liner 9038 2463 10061 524 805 806 / 3015 11600 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-3/8" 8829 30 - 2493 27 - 10088 9758 - 10225 9477 - 10225 9476 - 10282 / 9402 - 30 - 2493 27 - 8593 8299 - 8717 8059 - 8717 8059 - 8767 / 7998 - 9038 none 2670 4760 7020 7500 10540 11600 , 12232 5380 6870 8160 8430 10160 11509 - 12260 5-1/2" 13Cr85 25 - 9487 8854 - 8969 Structural 80 20" 31 - 111 31 - 111 1490 470 5-1/2" HES TNT , 9288 , 7905 No SSSV 9288 7905 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907) 564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 028312 25 - 8068 85 1727 2693 7435 3317 2384 0 0 260 267 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:45 pm, Dec 10, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.12.10 13:12:40 - 09'00' Bo York (1248) RBDMS JSB 122624 DSR-12/16/24WCB 2-6-2025 ACTIVITYDATE SUMMARY 11/7/2024 LRS CTU #1 - 1.50" DuraCoil - Job Objective: Plug & Perf MIRU. Test BOPs 300/4000 psi. MU NS 1.69" MHA, 1.75" drift, and HAL GR/CCL. OAL 13.24'. POH from 3500' due to generator issues. Severe oil leak at rear main seal. Call for auxillary generator. Replacement has low voltage. Replacement portable generator found and working. break off logging tools to swap batteries and reprogram. RBIH w/ logging tools. ***Job Continued on 8-Nov-2024*** 11/8/2024 LRS CTU #1 - 1.50" DuraCoil - Job Objective: Plug & Perf Continue RIH w/ logging tools. Tag at LTP. Unable to work passed. POOH to reconfigure tools. Add knuckle joint to tool string. RBIH. No issues getting through LTP w/ reconfigured tool string. Log GR/CCL from 12300' to 10000' Flag pipe @ 12148.9' CTM. POH download data and send logs to OE/GEO. Corrected EOP Flag @ 12133.8'. MU and RIH w/ NS 1.69" MHA w/ knuckle joint, 1.75" Setting tool, and 1.71" OD CIBP (10K pressure rating). OAL 9.3'. Tie-in to EOP flag . Set CIBP @ 12232'. MU and RIH w/ 1.69" NS MHA, HAL 1.56" x 25' gun. OAL 37.4' Tag plug and correct depth to bottom shot. Perforate 12205' - 12230'. Tag plug after shooting guns and confirm still on depth. POOH. Confirm shots fired. Ball recovered. RDMO ***Job Complete*** 11/18/2024 CTU #1 Job Scope Plug and Perf MIRU MU NS MHA and HES logging tools. Stab onto well "Function Test BOPs all good." Freeze Protect flowline. Open well RIH w/HES logging tools for coil flag. **** Continued **** 11/19/2024 CTU #1 Job Scope Plug and Perf ** Continued ** RIH with logging tools load well. Log up from 12200 to 9900'. Paint EOP flag @ 11434'. POH. MU and RIH w/ 1.69" NS CTC, MHA, knuckle, and 1.75" setting tool, 1.71" CIBP OAL 9.2'. Tie in to EOP flag and set plug @ 11600' MD. Stack down 3k and PT to 500 psi. POH. OOH ball recovered. PT MHA 3500 psi. MU and RIH w/ 1.69" MHA, 30' x 1.56 Perf gun. OAL 37.7' Tie in to flag, Tag CIBP @ 11600.3' CTM, Corr to bttm shot 11599.33' PU, position guns, circ 1/2" ball .7 bpm @ 3400 psi CTP, 500 psi WHP and perf 11509' - 11539' MD 1.56" Millenium 60* Phsg, 6 SPF. Guns fired POOH freeze protect well with 62 bbls diesel. Confirm shots fired 1/2" ball recovered. Laydown spent gun breakoff NS tools. RDMO ***** Job Complete ****** Daily Report of Well Operations PBU 14-32B Tie in to EOP flag and set plug @ 11600' MD. perf 11509' - 11539' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241217 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 8/17/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 9/26/2024 YELLOWJACKET PERF-GPT BCU 24 50133206390000 214112 8/19/2024 YELLOWJACKET PERF BCU 25 50133206440000 214132 9/27/2024 YELLOWJACKET PLUG-PERF BLOSSOM 1 50133206480000 215015 9/30/2024 YELLOWJACKET GPT-PLUG-PERF HV B-17 50231200490000 215189 9/23/2024 YELLOWJACKET GPT KU 24-7 50133203520100 205099 10/3/2024 YELLOWJACKET PERF KU 13-06A 50133207160000 223112 12/5/2024 AK E-LINE Plug Setting KU 22-6X 50133205800000 208135 12/8/2024 AK E-LINE Perf KU 23-07A 50133207300000 224126 12/7/2024 AK E-LINE CBL MPU L-17 50029225390000 194169 10/5/2024 YELLOWJACKET PERF MPU R-103 50029237990000 224114 10/14/2024 YELLOWJACKET CBL MPU C-23 50029226430000 196016 11/29/2024 AK E-LINE Plug/cement MPU D-01 50029206640000 181144 11/26/2024 AK E-LINE Perf PBU 13-24B 50029207390200 224087 9/26/2024 YELLOWJACKET CBL PBU 06-07A 50029202990100 224043 9/29/2024 BAKER MRPM PBU 06-18B 50029207670200 223071 10/1/2024 BAKER MRPM PBU 07-32B 50029225250200 204128 10/28/2024 BAKER SPN PBU 14-32B 50029209990200 224073 10/12/2024 BAKER MRPM PBU H-13A 50029205590100 209044 10/23/2024 BAKER SPN PBU L2-20 50029213760000 185134 10/7/2024 BAKER SPN PBU L3-22A 50029216630100 219051 10/9/2024 BAKER PEARL 10 50133207110000 223028 9/25/2024 YELLOWJACKET GPT-PERF PEARL 11 50133207120000 223032 8/29/2024 YELLOWJACKET GPT-PLUG-PERF SRU 241-33 50133206630000 217047 8/23/2024 YELLOWJACKET PERF Please include current contact information if different from above. T39863 T39864 T39865 T39868 T39869 T39870 T39871 T39872 T39873 T39875 T39874 T39867 T39866 T39876 T39877 T39880 T39878 T39879 T39881 T39882 T39883 T39884 T39885 T39886 T39887 PBU 14-32B 50029209990200 224073 10/12/2024 BAKER MRPM Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.18 08:35:44 -09'00' David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 11/13/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL WELL: PBU 14-32B PTD: 224-073 API: 50-029-20999-02-00 FINAL LWD FORMATION EVALUATION LOGS (09/29/2024 to 10/05/2024) Multiple Propagation Resistivity & Gamma Ray (2” & 5” MD/TVD Color Logs) Pressure While Drilling (PWD) Final Definitive Directional Surveys SFTP Transfer - Data Main Folders: Please include current contact information if different from above. 224-073 T39769 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.13 09:28:27 -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: Date: 10/30/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241030 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 221-26 50283202010000 224098 10/20/2024 AK E-LINE Perf BRU 233-23T 50283202000000 224088 10/14/2024 AK E-LINE Perf BRU 241-23 50283201910000 223061 10/12/2024 AK E-LINE Perf GP-ST-18742-33 50733203060000 177032 10/9/2024 AK E-LINE LeakDetect/Packer IRU 11-06 50283201300000 208184 10/4/2024 AK E-LINE Plug/Perf MPU B-28 50029235660000 216027 10/4/2024 READ CaliperSurvey MPU F-13 50029225490000 195027 10/15/2024 READ CaliperSurvey MPU L-36 50029227940000 197148 10/17/2024 READ CaliperSurvey MRU G-01RD 50733200370100 191139 10/10/2024 AK E-LINE Hoist NCIU A-21 50883201990000 224086 10/8/2024 AK E-LINE CBL NCIU B-01B 50883200930200 224097 10/1/2024 AK E-LINE CBL NCIU B-01B 50883200930200 224097 10/11/2024 AK E-LINE Perf PBU 06-18B 50029207670200 223071 10/2/2024 HALLIBURTON RBT PBU 14-32B 50029209990200 224073 10/13/2024 HALLIBURTON RBT PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON RBT PBU C-18B 50029207850200 209071 10/2/2024 HALLIBURTON WSTT PBU NK-26A 50029224400100 218009 10/14/2024 HALLIBURTON PPROF PCU 02A 50283200220100 224110 9/30/2024 AK E-LINE CBL PCU 02A 50283200220100 224110 10/4/2024 AK E-LINE Perf SDI 3-25B 50029221250200 203021 10/17/2024 AK E-LINE Patch Please include current contact information if different from above. T39726 T39727 T39728 T39732 T39733 T39734 T39735 T39736 T39737 T39738 T39739 T39739 T39740 T39741 T39742 T39742 T39743 T39744 T39744 T39745 PBU 14-32B 50029209990200 224073 10/13/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.01 13:27:33 -08'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Monty M. Myers Drilling Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK, 99503 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 14-32B Hilcorp Alaska, LLC Permit to Drill Number: 224-073 Surface Location: 40' FSL, 1292' FEL, Sec. 04, T10N, R14E, UM, AK Bottomhole Location: 240' FSL, 2388' FEL, Sec. 03, T10N, R14E, UM, AK Dear Mr. Myers: Enclosed is the approved application for the permit to drill the above referenced well. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for all well logs run must be submitted to the AOGCC within 90 days after completion, suspension, or abandonment of this well, or within 90 days of acquisition of the data, whichever occurs first. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Jessie L. Chmielowski Commissioner DATED this 10th day of September 2024. Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.10 18:03:04 -05'00' 10165, 10350, 10355, 12205 Drilling Manager 05/29/24 Monty M Myers October 1, 2024 By Grace Christianson at 3:27 pm, May 29, 2024 *BOPE test to 3500 psi. Annular to 2500 psi. 50-029-20999-02-00 WCB 8-6-2024 DSR-5/29/24 224-073 A.Dewhurst 09SEP24 *Variance to 20 AAC25.112(I) approved for alternate plug placement with fully cemented production liner. mgr05AUG2024 *Injector 14-13 to be shut-in 1 week prior to and during all drilling, including window milling, on 14-32A/14-32B. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.09.10 18:03:23 -05'00'09/10/24 09/10/24 RBDMS JSB 091124 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: May 29, 2024 Re:14-32B Permit to Drill Approval is requested for drilling a CTD sidetrack lateral from well 14-32A with the Nabors CDR3 Coiled Tubing Drilling. Proposed plan for 14-32B Producer: See 14-32A Sundry request for complete pre-rig details - Prior to drilling activities, Slickline will drift for a whipstock and dummy the GLVs, service coil will mill up the 3-1/4" CIBP at 10165', E-line will set the 3-1/4" packer whipstock, and then service coil will mill the 2.74" window if a service unit is available. A coil tubing drilling sidetrack will be drilled with the Nabors CDR3 rig. The rig will move in, test BOPE and kill the well. If not done pre-rig, CDR will mill a single string 2.74" window + 10' of formation will be milled. The well will kick off drilling in Ivishak Zone 4 and drill an S-shaped well through Zones 2, 3, and 4 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig. This completion will target isolating and abandoning the parent Ivishak perfs. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: Reference 14-32A Sundry submitted in concert with this request for full details. 1. Slickline : Dummy GLVs and Drift for Whipstock 2. Coil : Mill 3-1/4" CIBP at 10165' MD 3. E-Line : Set 3-1/4” Packer Whipstock – 10,285’ @ 45° ROHS 4. Coil : Mill 2.74" Window (if window not possible, mill with rig) 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in July 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,387psi). 2. Mill 2.74” Window (only if not done pre-rig) 3. Drill build section: 3.25" OH, ~170' (35 deg DLS planned). 4. Drill production lateral: 3.25" OH, ~2051' (12 deg DLS planned). 5. Run 2-3/8” 13Cr liner to TD. RIH with ORCA Cementing tool. 6. Pump primary cement job: 22 bbls, 15.3 ppg Class G, TOC at TOL*. 7. Freeze protect well to a min 2,200' TVD. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set LTP* (if necessary). Set live GLVs. 3. Service Coil : Post rig perforate (~30’), CBL and RPM. PTD 224-073 24 hour notice for AOGCC to witness BOPE test. Sundry 324-316 Managed Pressure Drilling: Managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using minimum 8.4 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A MPD choke for regulating surface pressure and is independent of the WC choke. Deployment of the BHA under trapped wellhead pressure will be necessary. Pressure deployment of the BHA will be accomplished utilizing 3” (big hole) & 2-3/8” (slim hole) pipe/slip rams (see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected: MPD Pressure at the Planned Window (10285' MD -8,769' TVD) Pumps On Pumps O A Target BHP at Window (ppg)4,469 psi 4,469 psi 9.8 B - ECD 617 psi 0 psi 0.09 C 3,921 psi 3,921 psi 8.6 B+C Mud + ECD Combined 4,539 psi 3,921 psi (no choke pressure) A-(B+C)Choke Pressure Required to Maintain 0 psi 547 psi Target BHP at window and deeper Operation Details: Reservoir Pressure: The estimated reservoir pressure is expected to be 3,267 psi at 8,800 TVD. (7.1 ppg equivalent). Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,387psi (from estimated reservoir pressure). Mud Program: Drilling: Minimum MW of 8.4 ppg KCL with viscosifier for drilling. Managed pressure used to maintain constant BHP. Disposal: All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4. Fluids >1% hydrocarbons or flammables must go to GNI. Fluids >15% solids by volume must go to GNI. Fluids with solids that will not pass through 1/4” screen must go to GNI. Fluids with PH >11 must go to GNI. Hole Size: 3.25” hole for the entirety of the production hole section. Liner Program: 2-3/8", 4.6#, 13Cr/Solid: 9,450' MD – 12,506' MD (3,056' liner) The primary barrier for this operation: Kill Weight Fluid to provide overbalance as necessary. A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: BOP diagram is attached. MPD and pressure deployment is planned. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. The annular preventer will be tested to 250 psi and 2,500 psi. 1.5 wellbore volumes of KWF will be on location at all times during drilling operations. A X-over shall be made up to a 2" safety joint including a TIW valve for all tubulars ran in hole. 2" safety joint will be utilized while running solid or slotted liner. The desire is to keep the same standing orders for the entire liner run and not change shut in techniques from well to well (run safety joint with pre- installed TIW valve). When closing on a 2" safety joint, 2 sets of pipe/slip rams will be available, above and below the flow cross providing better well control option. Directional: Directional plan attached. Maximum planned hole angle is 105°. Inclination at kick off point is 37°. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Distance to nearest property line – ~18,000' Distance to nearest well within pool – 405 ft Logging: MWD directional, Gamma Ray and Resistivity will be run through the entire open hole section. Real time bore pressure to aid in MPD and ECD management. Perforating: ~30' perforated post rig – See attached extended perforating procedure. 1.56" Perf Guns at 6 spf 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. The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. Formations: Top of Ivishak at 10,220’ MD in the parent wellbore Anti-Collision Failures: 14-13 fails anti-collision with the 14-32A wellplan. 14-13 is an injector that will be shut-in while drilling 14- 32A. Hazards: DS 14 is a H2S pad. The last H2S reading on 14-32A: 18 ppm on 08/24/2021. Max H2S recorded on DS: 140 ppm. No fault crossings expected. 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: Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. Note: The well will be killed and monitored before making up the initial perfs guns. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. MU nozzle drift BHA (include SCMT and/or RPM log as needed). 3. RIH to PBTD. a. Displace well with weighted brine while RIH (minimum 8.4 ppg to be overbalanced). 4. POOH (and RPM log if needed) and lay down BHA. 5. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 6. There will be no perforations to bullhead kill the well. Well will already be loaded w/ weighted brine or KCl per previous steps. Re-load well at WSS discretion. 7. At surface, prepare for deployment of TCP guns. 8.Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, weighted brine as needed (minimum 8.4 ppg). Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.Pickup safety joint and TIW valve and space out before MU guns.Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 10. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below.Max BHA length per PTD is 500ft. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. a. Perforation details i.Perf Interval:The well will be perforated between the CTD whipstock and TD of the newly drilled CTD well, completely in the Ivishak pool. ii.Perf Length:500’ iii.Gun Length:500’ iv.Weight of Guns (lbs):2300lbs (4.6ppf) 11. MU lubricator and RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate perforation intervals (TBD). POOH. a. Note any tubing pressure change in WSR. 12. After perforating, PUH to top of liner or into tubing tail to ensure debris doesn’t fall in on the guns and stick the BHA.Confirm well is dead and re-kill if necessary before pulling to surface. 13. Pump pipe displacement while POOH.Stop at surface to reconfirm well dead and hole full. 14. Review well control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. Standing orders flow chart included with this sundry request. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 15. Freeze protect well to 2,000’ TVD. 16. RDMO CTU. Coiled Tubing BOPs Standing Orders for Open Hole Well Control during Perf Gun Deployment Equipment Layout Diagram Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B3 B4 B1 B2 Choke Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" 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 9450' - 4.375" BKR C2 SLV, ID=4.00" 9460' - 3.7" DPY SLV, ID=3.00" 9470' - 3-1/2" x 2-3/8" XO 10,285' - 3-1/4" PKR WS 12,506' - 2-3/8 LNR 4.7# HDY511 ID=1.995 B 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. 224-073 PBU 13-32A PRUDHOE BAY PRUDHOE OIL WELL PERMIT CHECKLISTCompanyHilcorp North Slope, LLCWell Name:PRUDHOE BAY UNIT 14-32BInitial Class/TypeDEV / PENDGeoArea890Unit11650On/Off ShoreOnProgramDEVField & PoolWell bore segAnnular DisposalPTD#:2240730PRUDHOE BAY, PRUDHOE OIL - 640150NA1Permit fee attachedYesADL0283122Lease 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) (ForNA15All 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)NAThis well is an in-zone CTD sidetrack from an existing wellbore with pressure integrity.18Conductor string providedNAAll drilling of this sidetrack will be below the existing SC shoe.19Surface casing protects all known USDWsNAThis well is an in-zone CTD sidetrack from an existing wellbore with pressure integrity.20CMT vol adequate to circulate on conductor & surf csgNAThis well is an in-zone CTD sidetrack from an existing wellbore with pressure integrity.21CMT vol adequate to tie-in long string to surf csgYesFully cemented production liner. Parent well isolates the reservoir.22CMT will cover all known productive horizonsYes23Casing designs adequate for C, T, B & permafrostYesCDR3 has adequate tankage and good trucking support.24Adequate tankage or reserve pitYesSundry 324-31625If a re-drill, has a 10-403 for abandonment been approvedNoInjector 14-13 SF <1. Injector will be shut-in 1 week prior to window milling and/or drilling commencing.26Adequate wellbore separation proposedNAAll drilling will be below the SC shoe.27If diverter required, does it meet regulationsYesMPD but reservoir pressure of 7.1 ppg equiv is below water gradient of 8.33 ppg.28Drilling fluid program schematic & equip list adequateYesCT packoff, flow cross, annular, blind/shear, CT pipe slips, flow cross, BHA pipe slips, CT pipe slips29BOPEs, do they meet regulationYes7-1/16" 5000 psi stack pressure tested to 3500 psi.30BOPE press rating appropriate; test to (put psig in comments)YesFlanged choke and kill lines between dual combis w/remote chokc.31Choke manifold complies w/API RP-53 (May 84)Yes32Work will occur without operation shutdownYesPrudhoe's DS-14 is an "H2S pad," with a max recorded value of 140 ppm. Routine monitoring will be conducted.33Is presence of H2S gas probableNAThis is a development well.34Mechanical condition of wells within AOR verified (For service well only)NoMax H2S recorded: 140 ppm35Permit can be issued w/o hydrogen sulfide measuresYesAnticipating reservoir pore pressure of 7.1 ppg EMW36Data presented on potential overpressure zonesNA37Seismic analysis of shallow gas zonesNA38Seabed condition survey (if off-shore)NA39Contact name/phone for weekly progress reports [exploratory only]ApprADDDate9/9/2024ApprWCBDate9/9/2024ApprADDDate9/9/2024AdministrationEngineeringGeologyGeologic Commissioner:Date:Engineering Commissioner:DatePublic CommissionerDate*&:JLC 9/10/2024