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Home My WebLink About217-043PBU E-07B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 217-043 50-029-20451-03-00 12055 9061 2644 8881 715 713 3726 10182 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 9066 34 - 2678 33 - 8914 8435 - 9150 8437 - 9150 8329 - 12055 34 - 2678 33 - 8621 8157 - 8850 8160 - 8850 8055 - 9061 11732, 11875 10182 5380 6870 8160 10160 11200 9515 - 11900 7" 26# L-80 31 - 8405 9062 - 9061 76 20" x 30" 35 - 112 35 - 112 4-1/2" Baker SAB Packer 8405 8128 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907-564-5026 PRUDHOE BAY, Prudhoe Oil ADL 0028299, 0028304 31 - 8128 N/A N/A 413 1376 38210 14195 24 271 0 0 840 307 Prudhoe Oil No SSSV Installed 8405, 8128 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.02 15:20:51 - 08'00' Torin Roschinger (4662) 325-344 By Grace Christianson at 8:45 am, Sep 03, 2025 J.Lau 11/4/25 RBDMS JSB 091625 DSR-9/11/25 PBU E-07B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 217-043 50-029-20451-03-00 341J ADL 0028299, 0028304 12055 9061 2644 8881 715 713 3726 11903 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 9061 34 - 2678 33 - 8914 8435 - 9150 8437 - 9150 8329 - 12055 2500 34 - 2678 33 - 8621 8157 - 8850 8160 - 8850 8055 - 9061 11732, 11875None 5380 6870 8160 10160 11200 10230 - 11900 7" 26# L-80 31 - 84059066 - 9061 76 20" x 30" 35 - 112 35 - 112 4-1/2" Baker SAB Packer No SSSV Installed 8405, 8128 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY 6/20/2025 Prudhoe Oil Prudhoe Oil STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.06.05 10:53:22 - 08'00' Torin Roschinger (4662) 325-344 By Grace Christianson at 2:14 pm, Jun 05, 2025 JJL 6/9/25 Perforating gun BHA not to exceed 500'. Reestablish pressure containment prior to perforating. Perform and document well control drill on each shift using attached standing orders. Ensure well is dead before breaking containment 10-404 A.Dewhurst 16JUN25 DSR-6/18/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.20 13:14:31 -08'00' RBDMS JSB 091625 1 Well: E-07B Extended Adperf & Plugset PTD: 217-043 Well Name: E-07B API Number: 50-029-20451-02 Current Status: Offline Operable Pad: E PAD Reg. Approval Req’d? 10-403, 10-404 Regulatory Contact: Abbie Barker Job Type: Extended Perforating First Call Engineer: Finn Oestgaard Phone: (907) 350-8420 Second Call Engineer: Leif Knatterud Phone: (432) 227-4342 Current Bottom Hole Pressure: 3,300 psi (Estimated based on average Ivishak BHP) MPSP: 2,500 psi (Estimated from BHP- .1psi/ft gas gradient+ safety factor) Max Dev: 95 deg @ 9,891’ MD Min ID: 1.920” @ 8,356’ Tie In Log: PDCL Log – May 17, 2018 Background: E-07B is a horizontal coil sidetrack drilled in April 2018 targeting Z1A sands. The well was originally completed with 300’ of perforations, however since then multiple configurations of adperfs, plugs and DH chokes have been executed on the well. It has been decided it is now time to move uphole and isolate all current offtake points behind a plug due to the diminished returns of cycling the well. The LTP was confirmed to be holding August 2024 after setting a plug below the LTP in the 2-7/8” and attempting to flow the well to LP to see if there was any measurable gas leaking by the LTP, however none was measured. The well has no GLV’s & 7” tubing. The well will be swapped over to diesel to help the well kick off. Top adperf is @ 9,061 TVD. A full column of diesel result in 100 psi underbalance (assuming Pres = 3,300 psi). A contingent N2 lift with 1.75” coil is included in the event operations cannot get the well kicked off. Objective: Extended Perforate 285’ & set CIBP. Procedure: Coiled Tubing –Drift/Tie-In &Extended Perforate 1. MU Tie-In/Drift BHA (configuration per WSL discretion), RIH and flag for plug set & perforating. Contact Finn Oestgaard & Jeff Nelson for tie-in correlation. NOTE: Tie-In log is 7’deeper than reference log. Need to shift -7’ to tie-in depths to report reference depths for wellbore schematics etc. - Set CIBP mid element @ 10,182’ (Tie-In Depth) - Setting in 2-3/8” liner 4.7#, ID = 1.995” (will need to pass through 2-7/8”x 2-3/8” XO @ 8,356’ w/ ID=1.92”) Coil –Extended Perforating Notes: Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. 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 03 2 Well: E-07B Extended Adperf & Plugset PTD: 217 -043 be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 2. 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. 3. Bullhead 1.2x wellbore volume ~395 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a.Wellbore volume to top perf (10,230’)=329 bbls b. 7” Tubing – 8,330’ X .0383 bpf = 319 bbl c. 3-1/2” Liner – 15’ X 0.0087 bpf =1 bbls d. 2-7/8” Liner – 11’ X 0.0058 bpf =1 bbls e. 2-3/8” Liner – 1,874’ X 0.0039 bpf = 8 bbls 4. At surface, prepare for deployment of TCP guns. 5. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KWF, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re- established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 6. *Perform drill by picking up safety joint with TIW valve and space out before MU guns. Review standing orders 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. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 7.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 1.56”Millenniums 6 SPF or similar Perf Interval (tie-in depths)Total Gun Length Weight of Gun (lbs) 9,522’ – 9,807’ – gun 285’ ~1031 lbs (3.62 ppf) 8. RIH with perf gun, pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 9. After perforating, PUH to top of liner or into tubing 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. 10. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 11. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 3 Well: E-07B Extended Adperf & Plugset PTD: 217 -043 12. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 13. MU nozzle & RIH to 9,522’ MD (top of adperf interval) & swap well over from KCL to diesel. 14. Turn well over to Operations to POPto tanks. Operations to POP well to tanks, then swap to LP. Coiled Tubing (Contingent on well not flowing to tanks)–Nitrogen Lift (2nd rig up) 15. MIRU 1.75” Coil, blow down coil reel to ensure no unwanted fluids get pumped into the well, RIH to TOL and pump N2 to lift well. Reference RP: Coil Tubing Operations – N2 Lifting Procedures. - Initially have well lined up to tanks and ensure production flow path is rigged up to seamlessly transition flow from tanks to LP production (we do not want to shut the well in to transition and lose any momentum) If this rig up configuration is not available, contact OE to discuss, alternative mab be to just lift to LP production. - Anticipate to swap to tanks after a bottoms up, however this may be adjusted depending on how the well is reacting. - Coordinate with Ops to be able to have well lined up to the test separator for monitoring 16. Once well is believed to be naturally flowing shut off N2 & monitor rates from WPS for 2 hours, if well is sustaining productionRDMO CTU. Attachments: Wellbore Schematic Proposed Schematic Tie-In Log BOPE diagram Standing Orders Equipment Layout Diagram Sundry Change Form 4 Well: E-07B Extended Adperf & Plugset PTD: 217 -043 Current Schematic 03 5 Well: E-07B Extended Adperf & Plugset PTD: 217 -043 Proposed Wellbore Schematic c Proposed Perforations 9,515’ – 9,800’ (285’) Reference depths CIBP @ 10,175’ Reference depths 03 6 Well: E-07B Extended Adperf & Plugset PTD: 217 -043 Tie-In Log 03 7 Well: E-07B Extended Adperf & Plugset PTD: 217 -043 Perforate from 9,522’-9,807’ (Tie-In Depth) 8 Well: E-07B Extended Adperf & Plugset PTD: 217 -043 Set CIBP @ 10,182’ (Tie-In Depth) 9 Well: E-07B Extended Adperf & Plugset PTD: 217 -043 BOP Schematic 10 Well: E-07B Extended Adperf & Plugset PTD: 217 -043 11 Well: E-07B Extended Adperf & Plugset PTD: 217 -043 12 Well: E-07B Extended Adperf & Plugset PTD: 217 -043 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Christianson, Grace K (OGC) To:Brooks, James S (OGC) Cc:Coldiron, Samantha J (OGC) Subject:FW: Cancellation: Sundry 323-439 - PBU E-07B (PTD #217-043) Date:Tuesday, July 23, 2024 1:07:19 PM Attachments:Sundry_323-439_081423.pdf James, FYI, I have logged it in 2023 10-403 log in comments. Thank you, Grace Christianson Executive Assistant AOGCC (907) 793-1230 From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Tuesday, July 23, 2024 1:00 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Michael Hibbert <Michael.Hibbert@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Christianson, Grace K (OGC) <grace.christianson@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; PB Wells Tech Aides <PBWellsTechAides@hilcorp.com> Subject: Cancellation: Sundry 323-439 - PBU E-07B (PTD #217-043) Good Afternoon, The team has elected not to pursue the Extended Add Perforations with CTU that is covered by Sundry #323-439. As such, please cancel this 10-403 and any future work will be the subject of a new 10-403 request. I have attached the approved file for reference purposes only. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564-4915 Cell: (907)351-2459 From: Christianson, Grace K (OGC) <grace.christianson@alaska.gov> 7. 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 E-07B Mill CIBP, Polar Choke Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 217-043 50-029-20451-03-00 12055 Surface Intermediate Liner Liner Liner 9061 2644 8881 715 713 3726 11903 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 9061 34 - 2678 33 - 8914 8435 - 9150 8437 - 9150 8329 - 12055 34 - 2678 33 - 8621 8157 - 8850 8160 - 8850 8055 - 9061 11732, 11875 2670 4760 7020 10530 11780 None 5380 6870 8160 10160 11200 10230 - 11900 7" 26# L-80 31 - 8405 9066 - 9061 Conductor 76 20" x 30" 35 - 112 35 - 112 4-1/2" Baker SAB Perm Packer 8405, 8128 8405 8128 Aras Worthington for Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 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 0028299, 0028304 31 - 8128 N/A N/A 387 1073 37859 12705 32 496 0 0 874 660 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed 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 7:50 am, Dec 20, 2023 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2023.12.19 16:46:24 - 09'00' Aras Worthington (4643) RBDMS JSB 122623 DSR-1/26/24WCB 5-10-2024 ACTIVITY DATE SUMMARY 9/8/2023 ***WELL FLOWING ON ARRIVAL*** DRIFT w/ 1.80" DUMMY WRP TO S/D @ 9332' SLM ***CONTINUED ON 9/9/23 WSR*** 9/8/2023 Assist SL ***Job Continued 9-9-23*** 9/9/2023 ***Job Continued from 9-8-23*** T/I/O=2491/29/2 (PERFORATING) Assist Slickline. MIT-T to 2,371 psi ***PASSED*** Target Pressure= 2,250 psi - Max Applied= 2,500 psi - Loaded TBG with 340 bbls of Diesel. Pumped 6.1 bbls of Diesel to reach 2,496 psi. 1st 15-minute loss of 93 psi, 2nd 15-minute loss of 32 psi, for a total loss of 125 psi in 30 minutes. Bled back ~4.6 bbls. SL in control of well upon departure. FWHPs= 500/10/0 9/9/2023 ***CONTINUED FROM 9/8/23 WSR*** SET 2-7/8" WRP @ 8370' SLM LRS PERFORMED MIT-T TO 2500 PSI MAX APPLIED **PASS* PULLED 2-7/8" WRP @ 8370' SLM ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** 12/7/2023 LRS CTU #1, 1.5" Blue Coil. Job Objective: Mill CIBP, Extended Perforate MIRU and MU 1-11/16" Yellowjacket milling BHA with 1.80" venturi burnshoe (1.12" ID). Load the well with 320 BBL's of KCL. RIH and mill 2-3/8" CIBP at 11284' CTM / 11270' MD, push down to 11328' CTM. POOH and recover plug pieces. RIH with 1.80" 5-blade junk mill (unable to get motor work). POOH and see impression of plug core on bottom of mill. MU 1.80" venturi burnshoe (1.1" ID) and RIH. Have to start taking returns to surface. ***Job in Progress*** 12/8/2023 LRS CTU #1, 1.5" Blue Coil. Job Objective: Mill CIBP, Extended Perforate Mill 2-3/8" NS Polar choke at 11320' CTM / 11330' MD. Push plug remnants down to 11732' CTM (multiple stalls, unable to work deeper). POOH to check tools. More plug pieces retreived, no core. Discuss plan forward w/ OE. Rig down motor mill, RIH w/ nozzle and lay in FP from 2500'. RDMO ***Job Complete*** 12/9/2023 T/I/O = 2490/0/0. Temp = SI. T FL (Ops req). No AL. Hardline RU on Well. Could not shoot FL, flange on gate valve/ flowcross above swab leaking gas on inlet side (WS notified). Gas bled off, leaking flange flagged. SV, WV = C. SSV, MV = O. IA, OA = OTG. 21:00 12/10/2023 T/I/O = 160/0+/0+. Temp = SI. T FL (CTU request). No AL. T FL @ 560' (21 bbls). SV = C. WV, SSV, MV = O. IA & OA = OTG. 09:00 12/12/2023 LRS CTU #1, 1.5" Blue Coil. Job Objective: N2 Lift Rig up CTU. Perform Weekly BOP Test. Rig up HES N2. Displace Coil Volume down flowline. PCC roll well into Test Separator. RIH w/ 1.75" Nozzle pumping 500 scf/min. Increase to 750 scf/min at 1500'. Park at 2500'. Well started to slug and making formation gas. Continue pumping N2 as rates continue to climb. Up to ~ 6300 bpd, 22mm gas. Shut off N2 & monitor well. PCC rolled well into HP. Well is flowing. Pooh. Well is flowing strong into HP. Displace Coil to diesel. Rig down CTU. ***Job Complete*** Daily Report of Well Operations PBU E-07B j Mill 2-3/8" NS Polar choke at 11320' CTM / 11330' MD Push plug remnants down to 11732' CTM (multiple stalls, unable to work deeper). POOH CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Sent: Monday, August 14, 2023 3:23 PM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Darci Horner - (C) <dhorner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Jerimiah Galloway <jerimiah.Galloway@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Josh Allely - (C) <josh.allely@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] Completed Sundry 323-439 Hello, Attached is the completed Sundry for PBU E-07B. Thank you, Grace Christianson Executive Assistant AOGCC (907) 793-1230 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU E-07B Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 217-043 50-029-20451-03-00 341J ADL 0028299, 0028304 12055 Surface Intermediate Liner Liner Liner 9061 2644 8881 715 713 3726 11270 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" 2-3/8" 9061 34 - 2678 33 - 8914 8435 - 9150 8437 - 9150 8329 - 12055 2425 34 - 2678 33 - 8621 8157 - 8850 8160 - 8850 8055 - 9061 11875 2670 4760 7020 10530 11780 11270 5380 6870 8160 10160 11200 10230 - 11900 7" 26# L-80 31 - 84059066 - 9061 Conductor 76 20" x 30" 35 - 112 35 - 112 4-1/2" Baker SAB Perm Packer No SSSV Installed 8405, 8128 Date: Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY 8/18/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:18 am, Aug 04, 2023 323-439 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.08.03 11:09:13 -08'00' Torin Roschinger (4662) 10-404 SFD 8/14/21023MGR04AUG23 DSR-8/7/23JLC 8/14/2023GCW 08/14/2023 08/14/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.14 15:09:05 -08'00' RBDMS JSB 081523 Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B Well Name:E-07B API Number:50-029-20451-02 Current Status:Cycle Well – High GOR Pad:E-Pad Estimated Start Date:8/18/2023 Rig:C, S Reg. Approval Req’d?10-403 & 10-404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker PTD Number:217-043 First Call Engineer:Michael Hibbert Contact:907-903-5990 Current Bottom Hole Pressure:3250 psi Estimated MPSP:2425 psi (BHP - .1psi/ft gas gradient + safety factor) Max Dev:95 deg At 9,891’ MD Min ID:1.920” ID of 2-7/8” x 2-3/8” XO at 8,356’ MD Tie In Log:E-07B PDCL (see annotated Log attached) Brief Well Summary: E-07B was a CTD sidetrack that was drilled in April 2018. A series of plugs/chokes have been installed/milled to optimize GOR. Currently a CIBP is set at 11,270’ and a Polar choke is set at 11,320’. Objective: Diagnose potential liner lap and install LTP if needed. If the liner lap is not leaking then proceed with the following work: Mill CIBP and choke in liner and push to bottom, set CIBP at 10,175’ and then deploy extended length perforating guns and adperf from 9,515’ – 9,800’. NOTES: x Well does not have any GLMs so it likely will need a N2 lift to kick off. Procedure: Slickline & Fullbore 1. Drift to deviation for 2-3/8” WRP (~1.80”) 2. MU DPU and 2-3/8” WRP. RIH to above liner (~8200’) and load well with 330 bbls of diesel/dead crude (pump at max rate to sweep as much gas out of the tubing as possible). After loading, RIH and set WRP in 2-3/8” liner at ~8400. If the liner lap is leaking, then a LTP will be set. If this is the case, then the diesel kill will allow the well to be more likely to flow on its own without needing an N2 lift. 3. POOH. 4. Fullbore to MIT-T to 2500 psi max applied pressure. 5. Pull WRP and call OE with results. 6. RDMO. 1.5” CTU – Mill CIBP and Polar choke: 1. MU 1-11/16” motor with ~1.75” venturi/burn shoe or mill. 2. RIH and burn over/mill NS CIBP at 11,270’. Push downhole and attempt to recover core. Also mill out Polar choke at 11,320’. a. Continue running venturi/burn shoe BHAs until progress stalls. b. Swap between burnshoe/mill at WSL discretion. c. Attempt to recover or push all debris down to 11,875’ or as deep as possible. 3. POOH. Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B Coil – Extended Perforating Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. 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. 1. 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. 2. Bullhead ~327 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to top perf = 327 bbls b. 7” Tubing/Liner – 8,329’ X .0383 bpf = 319 bbls c. 2-3/8” Liner – 1901’ X 0.0039 bpf = 7.4 bbl 3. MU and RIH with GR/CCL with ” JSN. 4. Flag pipe as appropriate per WSS for adperf 5. POOH and freeze protect tubing as needed. 6. Confirm good log data. 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, 8.4 ppg 1% KCl or 8.5 ppg as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 9.*Perform drill by picking up safety joint with 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. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 10.Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule Use 1.56” Millenium guns or similar Perf Interval Perf Length Gun Length Weight of Gun (lbs) Run #1 9,515’ – 9,800’285’285’1140 lbs (4 ppf) 11. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. Make up PCE. - mgr Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B 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 is dead. Kill well if necessary. 14. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 15. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. Coil – Nitrogen Lift: 16. MU JSN nozzle and lift well with N2 until well is flowing on its own or until most fluids lost to the well are recovered. Take returns down the flowline. 17. RDMO CTU. 18. Turn well over to Operations to continue flowing. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Tie in Log 4. CT BOP Schematic 5. Standing Orders 6. Equipment Layout 7. Sundry Change form Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B Current Schematic: Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B Proposed Schematic: Milled CIBP and Polar Choke Set CIBP @ 10,175’ C C C Perforate 9515’-9800’ Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B Tie-in Log \\hilcorp.com\share\Alaska\Hilcorp North Slope\S-Drive-Benson\RES\Wells\PBU\E\E-07B\Logs\Pequin\E-07B- 2018_05_17-BP-IN_HOUSE_EDITED_DATA_CREATED_17MAY2018_FOR_E07B-1020499240.pdf Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B Set CIBP @ 10,175’ Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B Perforate from 9,515’-9,800’ Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B BOP Schematic Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B Mill Plug/Choke & Set CIBP & Ext AdPerf Well: E-07B Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:217-043 6.50-029-20451-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12055 11270 9061 8405 11875 11270 8128 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 76 20" x 30" 35 - 112 35 - 112 Surface 2644 13-3/8" 34 - 2678 34 - 2678 5380 2670 Intermediate 8881 9-5/8" 33 - 8914 33 - 8621 6870 4760 Liner 715 7" 8435 - 9150 8157 - 8850 8160 7020 Liner 713 3-1/2" x 3-3/16" 8437 - 9150 8160 - 8850 10160 10530 Perforation Depth: Measured depth: 10230 - 11900 feet True vertical depth:9066 - 9061 feet Tubing (size, grade, measured and true vertical depth)7" 26# L-80 31 - 8405 30 - 8128 8405 8128Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker SAB Perm Packer Liner 3726 2-3/8" 8329 - 12055 8055 - 9061 11200 11780 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1014039519 4233667 0 32022 567 915 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Noel Nocas Noel.Nocas@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5278 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9061 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028304 & 0028299 PBU E-07B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Meredith Guhl at 2:34 pm, Jul 19, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.07.19 14:30:10 -08'00' Stan Golis (880) MGR28JUL2021 DSR-7/19/21 SFD 7/20/2021RBDMS HEW 7/20/2021 ACTIVITY DATE SUMMARY 7/9/2021 CTU6 1.5" CT Job Objective: Drift, Wash Perfs, set CIBP. MIRU CTU6. MU SLB 1.75" Nozzle BHA. RIH and bring well online while displacing coil to diesel/xylene, tag polar choke and corrected depth to 11,320'. PUH 60' and flagged pipe at plug set depth. SI well and jetted perfs with 20bbls of diesel/xylene. POOH and brought well back online after 3 hour soak. MU NS 2-3/8" CIBP BHA and RIH. At flag, corrected EOP = 11,247.3' + 16.15' (EOP to COE) = 11,263.45' MD. Correct counter and set NS 2-3/8" CIBP at 11,270' MD. Pooh w/BHA. ***Job in Progress*** 7/10/2021 CTU6 1.5" CT Job Objective: Drift, Wash Perfs, set CIBP. On surface w/BHA, recovered 3/8" ball. Contact PCC, pop well and verify flow. 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6WDQ*ROLV Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:217-043 6.API Number:50-029-20451-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028304 & 028299 Property Designation (Lease Number):10. 341 8. PBU E-07B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations 5 Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12055 Effective Depth MD: L80 11. 12/17/2020 Commission Representative: 15. Suspended Contact Name: Noel Nocas Contact Email: noel.nocas@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9061 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool 8405, 8128 No SSSV Installed Date: Liner 3726 2-3/8"8329 - 12055 8055 - 9061 11200 11780 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 35 - 112 33 - 8617 14. Estimated Date for Commencing Operations: BOP Sketch Conductor 8160 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker SAB Perm Packer 11420 - 11900 9061 - 9061 7" 26# 31 - 8405 Liner 11903 9061 34 - 2676 2670 9-5/8" 7" Contact Phone:(907)564-5278 Date: 7020 2644 538013-3/8"Surface 4760 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 76 20" x 30"35 - 112 Intermediate 8881 6870 Liner 715 8435 - 9150 8157 - 8850 713 3-1/2" x 3-3/16" 8437 - 9150 8160 - 8850 10160 10530 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2424 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. Extended Perf w CTU 34 - 2678 33 - 8914 By Samantha Carlisle at 11:16 am, Dec 08, 2020 320-514 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.12.08 11:01:18 - 09'00' Stan Golis 10-404 MGR10DEC2020 DSR-12/9/2020 10-404 SFD 12/8/2020 Yeon Required? Comm 12/10/2020 dts 12/10/2020 JLC 12/10/2020 RBDMS HEW 12/14/2020 Extended Perforating Procedure To:Well Services Foreman Date: AFE:2023827 From:Noel Nocas IOR:194 Est. Cost:$185,000 Subject:E-07B Extended Perforating with Coiled Tubing Revision:1 Job Sequence WBL Steps 1 Coil MU/RIH and drift with GR/CCL and nozzle.Set Plug at appx 11,350’MD avoiding collars. (preferred set away from collars and deeper than 11,300 but needs to isolate old perfs) 2 Coil Shoot Addperfs from: x 10,955’ -11,205’MD 3 Coil If well will not flow on its own, kick off with N2 4 Well Test (Pending) Flowback to portable test separator, two piggyback hour tests.This is only if GC1 plant foreman requests flowback Current Bottom Hole Pressure:3304 psi @ 8800’ TVD 7.22ppg EMW Fracture Pressure:5857psi at 8800' TVD (12.8ppg EMW) Last SI WHP:2360 psi on 8/11/2020 Min ID:1.92” ID @ 8356’ MD Max Angle:93 Deg @ 10,960’MD Reference Log:E-07B PDCL Log 17-May-20108 H2S:10 ppm 05/11/2019 CT Size:1.5” - 1.75”The safety joint shall be the same OD as CT size Program Contacts: Contact Work Phone Mobile Phone Operations Engineer Noel Nocas 907-564-5278 907-229-9532 E-07B Coiled Tubing Extended Perforating Program 12/8/20 Well: E-07B Revision: 1 2 1 Scope of Work and Well Summary E-07B is a May 2018 tiny coil sidetrack which targeted Z1B sands in the E/K Graben. The well was initially completed with 300' of perforations in the toe - leaving future stage perf opportunities once the prior perfs become uncompetitive. A total of at least 4 more stages remain. Performance of the well was strong initially - coming online at 1500 bopd and 1200 GOR, however the well approached marginal in less than one year of ontime and is currently uncompetitive at 90000 GOR. The remaining value of the well in its current state is low as it is not expected to see much remaining ontime. The objective of this intervention is to add the second stage perforations to the well to restore the well to fulltime status. 2 Sundry Procedure (Approval Required to Proceed): Coiled Tubing (Reference Coiled Tubing Extended Perforating Recommended Practice) 1. MIRU Coiled Tubing Unit 2. MU and RIH with logging and drift assembly. a. Kill well with 1.5x WBV to top perf. Note: The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run and/or plug set 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. 3. Paint flag, POOH and confirm good data. 4. Set Plug at appx 11,350’MD 5. Monitor WHP to confirm well is dead before MU perf guns. If necessary, re-kill well. 6. Pickup safety joint (safety joint and CT size MUST be the same OD)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. 7. Break lubricator connection at QTS and begin MU perf guns per the following table (If at any time pressure is seen or there is flow at surface follow the steps in the Standing Orders Appendix E to secure the well): Table 1: E-07B Proposed Extended Length Gun Runs Gun Run # Perf Top Perf Bottom Perf Length Overall Gun Length Weight of Perf Gun (lbs/ft) 1 10,955 11,205 250 250 4 Total 250 8. RIH with perf gun(s), tie-in and perforate. POOH. a. Note any tubing pressure changes in WSR. 9. Once at surface, stop to confirm well is dead. 10. Review Standing Orders (Appendix E) prior to breaking lubricator connection and rigging down guns. 11. Either return the well to production or FP well. 12. RDMO. * *See note above in red regarding kill methods if pressure observed at surface after perforating. Well: E-07B Revision: 1 3 Attachments: A. Current Schematic B. Proposed Schematic C. Coiled Tubing BOP Schematic / Tree Diagram D. Equipment Layout Diagram E. Standing Orders for Open Hole Well Control during Perf Gun Deployment F. Tie In Log/Perf Sheet Well: E-07B Revision: 1 4 Appendix A - Current Wellbore Configuration Well: E-07B Revision: 1 5 Appendix B: Proposed Schematic Well: E-07B Revision: 1 6 Appendix C: Coiled Tubing BOP Schematic / Tree Diagram Well: E-07B Revision: 1 7 Appendix D: Extended Perforating Equipment Layout Well: E-07B Revision: 1 8 Appendix E: Standing Orders for Open Hole Well Control during Perf Gun Deployment Well: E-07B Revision: 1 9 Appendix F: Tie-In Log / Perf Sheet Well: E-07B Revision: 1 10 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate:Subject: Changes to Approved Sundry Procedure for Well E-078BSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer DateDecember 8, 2020