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Home My WebLink About214-0027. 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 D-30C Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-002 50-029-22646-03-00 12947 Conductor Surface Intermediate Production Liner 9046 80 3418 9823 3358 10660 20" 10-3/4" 7-5/8" 3-1/2" x 3-1/4" x 2-7/8" 9039 38 - 118 38 - 3456 36 - 9859 9589 - 12947 38 - 118 38 - 3276 36 - 8945 8769 - 9046 None 470 2480 7150 10530 10660, 11080, 11440, 12150, 12600 1490 5210 8180 10160 10130 - 12910 4-1/2" 12.6# L-80 34 - 9859 9038 - 9045 Structural No Packer No Packer Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907-564-5026 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 0028285 34 - 8945 N/A N/A 642 2538 38904 22455 141 304 1300 1150 940 806 325-315 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 3:00 pm, Jun 24, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.06.24 14:35:42 - 08'00' Torin Roschinger (4662) RBDMS JSB 062725 JJL 6/30/25 ACTIVITY DATE SUMMARY 6/14/2025 CTU#1 1.5" CT. Job Scope: Drift/Log, Set CIBP, Ext Adperf MIRU CTU. NU BOP's on well & Function Test. Make up Drift/Logging BHA. Tag Brass with Coil Connector. ***In Progress*** 6/15/2025 CTU#1 1.5" CT. Job Scope: Drift/Log, Set CIBP, Ext Adperf Pressure Test PCE 275psi Low, 4275psi High. Test DHCV's. Good Surface Tests. Open well to 2528psi. Bullhead Meth Spear & 192 bbls 1% KCL. RIH w/ HES 2.20" Logging Carrier & 2.25" Down Jet Nozzle. Injector pump issues at 8585' for 8 hours. RIH and tag CIBP at 11049' and log up to 9500', painting tie-in flag at 10650'. Attempt no-flow test while on bottom but there was gas entrained from leaking wing valve. Isolate and bleed S-riser and continue to pump pipe displacement to minimize additional influx. Confirm good data and +11' correction. Make up 2-7/8" NS CIBP setting BHA and RIH. Correct depth at Flag. Set Top of CIBP at 10660'. Stack 4k down on plug. Plug set looks good. Launch 7/16" ball & open circ-sub. Chase ooh w/ 1% Slick KCL. At surface, pressure test CIBP to 1080psi. Lost 35psi in 5 mins. Good Plug PT. Bleed off pressure & perform good no flow test. Break down setting tool. Recover both 3/8" & 7/16" steel balls. Make up Swivel & PT MHA 3500psi. Raise up Injector and lubricator. Perform Kick Drill w/ Night Crew. Review Standing Orders in Sundry. Deploy HES 2" x 120' Perf Guns while circulating 1% KCL across the top. ***In Progress*** 6/16/2025 CTU#1 1.5" CT. Job Scope: Drift/Log, Set CIBP, Ext Adperf Continue RIH w/ 2" x 120' HES MaxForce Perf Guns. Take displacement returns while Rih. Reference depths at Flag. Tag CIBP & correct to Btm shot depth. Puh & Perforate Interval: 10130' - 10250'. Good indication of firing. Pooh keeping the hole full with 1% KCL. Perform good no flow test. Circulate 1% KCL across the top. Unstab lubricator & undeploy perf guns. All shots fired. Recover 1/2" ball. RIH with nozzle and lay in FP. Rig down CTU. ***Job Complete*** Daily Report of Well Operations PBU D-30C 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 D-30C Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-002 50-029-22646-03-00 341J ADL 0028285 12947 Conductor Surface Intermediate Production Liner 9046 80 3418 9823 3358 11080 20" 10-3/4" 7-5/8" 3-1/2" x 3-1/4" x 2-7/8" 9047 38 - 118 38 - 3456 36 - 9859 9589 - 12947 2420 38 - 118 38 - 3276 36 - 8945 8769 - 9046 None 470 2480 7150 10530 11080, 11440, 12150, 12600 1490 5210 8180 10160 10730 - 12910 4-1/2" 12.6# L-80 34 - 98599044 - 9045 Structural No Packer No SSSV Installed Date: Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907-564-5026 PRUDHOE BAY 6/15/25 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 10:37 am, May 21, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.05.21 10:08:06 - 08'00' Torin Roschinger (4662) 325-315 JJL 6/2/25 10-404 *Perforating gun not to exceed 500'. *Reestablish pressure containment prior to perforating. *Perform and document well control drill on each shift using attached standing orders and verify correct XO for safety joint. Ensure well is dead before breaking containment *Ensure well is dead before breaking containment DSR-6/3/25A.Dewhurst 10JUN25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.06.10 11:56:22 -08'00' 06/10/25 RBDMS JSB 061025 CCT Extended Perforating Well:D-30C Well Name:D-30C API Number::50-029-22646-03 Current Status::Operable producer, offline Pad::D-Pad Estimated Start Date::06/15/2025 Rig::Coil Reg.. Approval Req’d?10-403/10-404 Date RReg. Approval Rec’vd::TBD Regulatory Contact:Abbie Barker Permit to Drill Number:2140020 First Call Engineer Finn Oestgaard Contact:907-350-8420 (C) Second Call Engineer Leif Knatterud Contact:432-227-4342 Current Bottom Hole Pressure:3300 psi @ 8,800’ TVDss Estimated based on average Ivishak Pressure KWF:7.3 ppg Use seawater or 1% KCL MPSP:2420 psi (BHP - 0.1psi/ft gas gradient) Max Dev:96 deg @ 12,296’ MD Min ID:2.2” (liner obstruction) 11,681’ CTM Tie In Log Baker Hughes RPM - 8/28/2014 Last SIWHP 2300 psi - 5/14/2025 (From daily manual reads) Brief Well Summary: D-30C is an Ivishak Z2 producer that was coil sidetracked in 2014. It has been produced via the typical plug and perf approach taken in horizontal GD wells. The most recent stage was shot in February 2025 with very strong initial performance, coming on @ 2,400 bopd. Throughout it’s life, the well has had very strong initial pop rates after perforating with 4 of 5 stages having rates above 2,000 BOPD. The well was a fulltime producer for 2 months until hitting field marginal GOR’s and was SI following the last stage. This is the final perf stage in the lateral. Objective: Set CIBP & Perforate 120’ Z2A. Procedure: Coiled Tubing –Drift/Tie-In & Plugset 1. MU Tie-In/Drift BHA (configuration per WSL discretion), RIH and flag for plug set (target set depth 10,715’) Contact Finn Oestgaard & Jeff Nelson for tie-in correlation. 2. Set CIBPmid element @ 10,715’ Setting in 2-7/8” liner 6.5#, ID = 2.441” (will need to pass through LTP @ 9,578’ w/ ID=2.31”) 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. CCT Extended Perforating Well:D-30C 2. Bullhead 1.2x wellbore volume ~187 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 (10,730’)=156 bbls b. 4-1/2” Tubing – 9,578’ X .0152 bpf = 146 bbl c. 3-1/2” Liner – 65’ X 0.0087 bpf = 1 bbls d. 3-1/4” Liner – 936’ X 0.0079 bpf = 8 bbls e. 2-7/8” Liner – 151’ X 0.0058 bpf = 1 bbls 3. At surface, prepare for deployment of TCP guns. 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KKWF, 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. 5. *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. 6.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 2”Maxforce 070 charges 6 SPF Perf Interval (tie-in depths)Total Gun Length Weight of Gun (lbs) 10,130’ – 10,250’ – gun 120’~670 lbs (5.58 ppf) 7. RIH with perf gun and lightly tag CIBP for depth control. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 8. 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. 9. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 10. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 11. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 12. RDMO CTU. 13. Turn well over to Operations POP. Attachments: Wellbore Schematic, Proposed Schematic,Tie-In Log,BOPE diagram,Standing Orders, Rig-up diagram, Sundry Change Form CCT Extended Perforating Well:D-30C Current Schematic CCT Extended Perforating Well:D-30C Proposed Wellbore Schematic Proposed Perforations 10,130’ – 10,250’ (120’) CIBP @ 10,715’ c CCT Extended Perforating Well:D-30C Tie-In Log CCT Extended Perforating Well:D-30C Perforate 10,130’ – 10,250’ (120 feet) CCT Extended Perforating Well:D-30C Set plug ME @ 10,715’ CCT Extended Perforating Well:D-30C BOP Schematic CCT Extended Perforating Well:D-30C CCT Extended Perforating Well:D-30C CCT Extended Perforating Well:D-30C 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) HNNS Approved By (Initials) AOGCC Written Approval Received (Person aand Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 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 D-30C Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-002 50-029-22646-03-00 12947 Conductor Surface Intermediate Production Liner 9046 80 3418 9823 3358 11080 20" 10-3/4" 7-5/8" 3-1/2" x 3-1/4" x 2-7/8" 9047 38 - 118 38 - 3456 36 - 9859 9589 - 12947 38 - 118 38 - 3276 36 - 8945 8769 - 9046 None 470 2480 7150 10530 11080, 11440, 12150, 12600 1490 5210 8180 10160 10730 - 12910 4-1/2" 12.6# L-80 34 - 9859 9044 - 9045 Structural No Packer No Packer N/A Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 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 0028285 34 - 8945 N/A N/A 455 2149 48132 19021 69 282 300 1200 1240 800 325-029 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 Gavin Gluyas at 2:36 pm, Mar 04, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.03.04 14:06:01 - 09'00' Torin Roschinger (4662) DSR-3/10/25JJL 3/4/25 RBDMS JSB 031325 ACTIVITY DATE SUMMARY 2/18/2025 LRS CTU #1, 1.5" CT, 0.134" WT. Job Objective: CIBP & Ext Adperfs Mobilize CTU #1. MIRU and make up 1-11/16" NS MHA with HES GR/CCL logging toolstring in 2.20" carrier with 2.25" DJN. L&K the well with 230 BBL's of 1% KCL. RIH and tag at 11177' CTM. Log up to 9400' at 50 FPM. Paint a tie-in flag at ~ 11050'. POOH. BD HES GR/CCL BHA. ***Continue on WSR 2/19/25*** 2/19/2025 LRS CTU #1, 1.5" CT, 0.134" WT. Job Objective: CIBP & Ext Adperfs MU NS 2-7/8" CIBP BHA. (+2' Corr on HES Log). L&K well slick 1% kcl 225 bbls. RIH w/ NS CIBP & Corr Depth at Flag. Set Top CIBP @ 11,080'. PT CIBP 1000 psi. POOH. BD NS CIBP BHA. PT MHA. Deploy 190' HES 2", 60deg, 6 spf MaxForce perf guns & RIH. Tag Wgt back / Corr Depth to Btm Shot 11,079.33' / PUH to Btm Shot depth. Perf interval (10,730' - 10,920'). Launch 1/2" firing ball. Ball on seat / guns fired @ 2876 psi 27.6 bbls. Pump 60/40 down backside / well on Vac. Swap to KCL. POOH maintain cont hole fill. Guns at surface. Loss rate slowed, caught WHP. Swap to 60/40 establish loss rate at .2 to .3 bpm. PJSM gun undeplyment Line up Trip tank & circulate over the top. Loss rate ~3-4 bph. SD for Flow check, Well on a Vac. Pop off & verify shots fired. Break firing head. Ball Recovered. LD 10 guns. Verify all shots fired. Talked with operator he is happy with 28 bbls of FP. Close Swab. ***Continue on WSR 2/20/25*** 2/20/2025 LRS CTU #1, 1.5" CT, 0.134" WT. Job Objective: CIBP & Ext Adperfs RDMO CTU #1 ***Job Complete*** Daily Report of Well Operations PBU D-30C 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 this 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 D-30C Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-002 50-029-22646-03-00 341J ADL 0028285 12947 Conductor Surface Intermediate Production Liner 9046 80 3418 9823 3358 11440 20" 10-3/4" 7-5/8" 3-1/2" x 3-1/4" x 2-7/8" 9051 38 - 118 38 - 3456 36 - 9859 9589 - 12947 2420 38 - 118 38 - 3276 36 - 8945 8769 - 9046 None 470 2480 7150 10530 11440, 12150, 12600 1490 5210 8180 10160 11120 - 12910 4-1/2" 12.6# L-80 34 - 98599046 - 9045 Structural No Packer No SSSV Installed Date: Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY 2/6/2025 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 12:27 pm, Jan 23, 2025 325-029 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.01.23 11:24:31 - 09'00' Torin Roschinger (4662) SFD 1/24/2025JJL 1/23/25 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 DSR-1/31/25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.03 08:48:48 -09'00'02/03/25 RBDMS JSB 020425 CCT Extended Adperf Well:D-30C Well Name:D-30C API Number::50-029-22646-03 Current Status::Operable producer, offline Pad::D-Pad Estimated Start Date::02/06/2025 Rig::Coil Reg.. Approval Req’d?10-403/10-404 Date RReg. Approval Rec’vd:: Regulatory Contact:Abbie Barker Permit to Drill Number:2140020 First Call Engineer Finn Oestgaard Contact:907-350-8420 (C) Current Bottom Hole Pressure:3300 psi @ 8,800’ TVDss Estimated based on average Ivishak Pressure KWF:7.3 ppg Use seawater or 1% KCL MPSP:2420 psi (BHP - 0.1psi/ft gas gradient) Max Dev:96 deg @ 12,296’ MD Min ID:2.2” (liner obstruction) 11,681’ CTM Tie In Log Baker Hughes RPM - 8/28/2014 Last SIWHP 2000 psi - 7/27/2024 (From daily manual reads) Brief Well Summary: D-30C is an Ivishak Z2 producer that was coil sidetracked in 2014. It has been produced via the typical plug and perf approach taken in horizontal GD wells. The most recent stage was shot in March 2024 with very strong initial performance, coming on @ 2,400 bopd. The well was a fulltime producer for 4 months until hitting field marginal GOR’s. 2 separate cycle attempts have been done with no recharge characteristics and it has been decided to proceed with the 5th stage of perforations. Objective: Set CIBP & Perforate 190’ Z2A. Procedure: Coiled Tubing –Drift/Tie-In & Plugset 1. MU Tie-In/Drift BHA (configuration per WSL discretion), RIH and flag for plug set (target set depth 11,080’) Contact Finn Oestgaard & Jeff Nelson for tie-in correlation. 2. Set CIBP mid element @ 11,080’ Setting in 2-7/8” liner 6.5#, ID = 2.441” (will need to pass through LTP @ 9,578’ w/ ID=2.31”) 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 1.2x wellbore volume ~191 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 (11,120’)=159 bbls b. 4-1/2” Tubing – 9,578’ X .0152 bpf = 146 bbl CCT Extended Adperf Well:D-30C c. 3-1/2” Liner – 65’ X 0.0087bpf = 1 bbls d. 3-1/4” Liner – 936’ X 0.0079 bpf = 8 bbls e. 2-7/8” Liner – 541’ X 0.0058 bpf = 4 bbls 3. At surface, prepare for deployment of TCP guns. 4. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/ KKWF, 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. 5. *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. 6.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 2”Maxforce 070 charges 6 SPF Perf Interval (tie-in depths)Total Gun Length Weight of Gun (lbs) 10,730’ – 10,920’ – gun 190’~1060 lbs (5.58 ppf) 7. RIH with perf gun and lightly tag CIBP for depth control. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 8. 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. 9. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 10. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 11. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 12. RDMO CTU. 13. Turn well over to Operations POP. Attachments: x Wellbore Schematic x Proposed Schematic x Tie-In Log x BOPE diagram x Standing Orders x Rig-up diagram x Sundry Change Form CCT Extended Adperf Well:D-30C Current Schematic CCT Extended Adperf Well:D-30C Proposed Wellbore Schematic Proposed Perforations 10,730’ – 10,920’ (190’) CIBP @ 11,080’ CCT Extended Adperf Well:D-30C Tie-In Log CCT Extended Adperf Well:D-30C Perforate 10,730’ – 10,920’ (190 feet) CCT Extended Adperf Well:D-30C Set plug ME @ 11,080’ CCT Extended Adperf Well:D-30C BOP Schematic CCT Extended Adperf Well:D-30C CCT Extended Adperf Well:D-30C CCT Extended Adperf Well:D-30C 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 BBy (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date 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 D-30C Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-002 50-029-22646-03-00 12947 Conductor Surface Intermediate Production Liner 9046 80 3418 9823 3358 11440 20" 10-3/4" 7-5/8" 3-1/2" x 3-1/4" x 2-7/8" 9051 38 - 118 38 - 3456 36 - 9859 9589 - 12947 38 - 118 38 - 3276 36 - 8945 8769 - 9046 None 470 2480 7150 10530 11440, 12150, 12600 1490 5210 8180 10160 11120 - 12910 4-1/2" 12.6# L-80 L-80 34 - 9859 9046 - 9045 Structural No Packer None None Torin Roschinger Operations Manager Kirsty Glasheen kirsty.glasheen@hilcorp.com 907-564-5258 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 0028285 34 - 8945 N/A N/A 448 2305 37173 17881 74 798 1250 1150 1113 1122 323-629 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 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.04.05 16:57:15 -08'00' Torin Roschinger (4662) By Grace Christianson at 1:13 pm, Apr 08, 2024 DSR-4/12/24 RBDMS JSB 041024 WCB 2024-07-09 ACTIVITYDATE SUMMARY 12/30/2023 SLB CTU 9 1.75" CT, .156" WT Job Scope = BOP Test, Mill 2 CIBPs Travel to D-30C @ 0300. MIRU, BOP Test. L&K well with slick 1%KCL + 20bbl meth cap. MU/RIH with 2-1/16" burn shoe + 2.29" mule shoe, RIH. POOH due to finding frozen surface iron. ***Job in Progress*** 12/31/2023 SLB CTU 9 1.75" CT, .156" WT Job Scope = BOP Test, Mill 2 CIBPs Continue thawing reel. RIH @ 0700. Reel is Thawed. Displace reel to hot KCL for Milling. RIH w/ YJ 2.290" Venturi Burn Shoe BHA. Tag restriction in Perfs @ 11681' CTM, ~470' above upper CIBP. Attempt to mill past obstruction for 2 hours. No Go. 8 Stalls. POOH to change BHA. RIH w/ YJ 2.250" 6-blade Junk Mill BHA. Unable to mill passed 11684' w/junk mill. POOH, RIH w/YJ 2.22" crayola mill. *Perform well control drill with crew (D/N).* ***In progress*** 1/1/2024 SLB CTU 9 1.75" CT, .156" WT Job Scope = Mill 2 CIBPs RIH w/2.22" crayola mill. Tag 11697.7. See log for details. Unable to make any progress, POOH and inspect mill. Outer perimieter of mill is damaged from milling on metal. Apparent liner damage. ***Incomplete*** 1/6/2024 LRS-46 Heat Slick KCL URs to 140* 3/25/2024 Coil Unit #9 1.75" Coil .156" WT Job Scope = Drift/Log, Set CIBP, Ext Perf MIRU. MU NS MHA and HES memory gamma CCL w/ 2.25" DJN. ***Job continued on 3/26/24*** 3/26/2024 Coil Unit #9 1.75" Coil .156" WT Job Scope = Drift/Log, Set CIBP, Ext Perf ***Job Continued from 3/25/24*** MIRU. MU NS MHA and HES memory gamma CCL w/ 2.25" DJN. RIH to 11,600' ctmd. Perform tie in log. Flag coil 11,200'. Good data, +44.5' correction. PT Safety Joint to BOP criteria. Re-align (Zero Sensors) remote gas monitoring system with Hilcorp fire and gas. Perform kick while tripping & h2s drill. MU NS MHA, NS Fury5 setting tool, 2-7/8" CIBP, Set 2-7/8" CIBP TOP @ 11,440', Circulate in KWF from just above plug. RIH with 2" HES MaxF Perf Guns, 60* phasing, 6 SPF. Shoot Guns on depth @ 11120 - 11300. Keep hole full on trip OOH. ***Job Continued to 3/27/24*** Daily Report of Well Operations PBU D-30C g Set 2-7/8" CIBP TOP @ 11,440', j Shoot Guns ong depth @ 11120 - 11300. Daily Report of Well Operations PBU D-30C 3/27/2024 Coil Unit #9 1.75" Coil .156" WT Job Scope = Drift/Log, Set CIBP, Ext Perf ***Job Continued from 3/26/24*** Continue OOH after shooting gun keeping the hole full. Stop at 200' and wait for wind. ***Continue on WSR 3/28/24*** 3/28/2024 Coil Unit #9 1.75" Coil .156" WT Job Scope = Drift/Log, Set CIBP, Ext Perf ***Job Continued from 3/27/24*** PJSM. Wind 26 MPH. PJSM. Good NO-FLOW. BD HES FH & 1/2" ball recovered. Un-deploy 9 spent 2" perf guns. Blow down CT w/ N2. RDMO CTU 9. ***Job Complete*** CIBP and adperfs are correctly shown on the new WBS, below. -WCB 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 D-30C Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-002 50-029-22646-03-00 341J ADL 0028285 12947 Conductor Surface Intermediate Production Liner 9046 80 3418 9823 3358 12150 20" 10-3/4" 7-5/8" 3-1/2" x 3-1/4" x 2-7/8" 9052 38 - 118 38 - 3456 36 - 9859 9589 - 12947 2420 38 - 118 38 - 3276 36 - 8945 8769 - 9046 None 470 2480 7150 10530 12150, 12600 1490 5210 8180 10160 11510 - 12910 4-1/2" 12.6# L-80 L-80 34 - 98599049 - 9045 Structural No Packer No SSSV Installed No Packer No SSSV Installed Date: Torin Roschinger Operations Manager Kirsty Glasheen kirsty.glasheen@hilcorp.com 907-564-5258 PRUDHOE BAY 12/15/23 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 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.11.20 13:49:27 -09'00' Torin Roschinger (4662) 323-629 2420 MGR24NOV23 10-404 DSR-11/20/23SFD 11/24/2023*&: By Grace Christianson at 4:29 pm, Nov 24, 2023 JLC 11/27/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.11.27 11:39:06 -09'00' RBDMS JSB 112823 Set CBP & Ext AdPerf Well: D-30C Well Name:D-30C API Number:50-029-22646-03 Current Status:Operable – Cycle Well Pad:D-Pad Estimated Start Date:12/15/2023 Rig:Coil Reg. Approval Req’d?10-404 Date Reg. Approval Rec’vd:N/A Regulatory Contact:Abbie Barker Permit to Drill Number:2140020 First Call Engineer:Kirsty Glasheen Contact:907-350-4310 Current Bottom Hole Pressure:3300 psi @ 8,800’ TVDss Area Average MPSP:2420 psi (BHP- .1psi/ft gas gradient) Recent SITP:2400 psi 9/29/2021 Max Dev:96 deg At 12,296’ MD Min ID:2.313” @ 9,591’ MD (2-7/8” x nipple) Brief Well Summary: D-30C is an Ivishak Z2 producer that was CTD sidetracked in 2014. The well has been produced via a typical plug and perf strategy moving up hole throughout the years. Most recently, coil milled two CIBPs reaccessing Ivishak production that were SI since 2021. This production will be produced until the well is no longer cycling competitively, and then coil will be scheduled to set a CIBP to shut off all current perforations and add new uphole perforations. Objective: Isolate current perforations with a CIBP and complete extended add perf. Procedure: Slickline: 1.Pull dreamcatcher (if set). Coil 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. x 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. MIRU 1.75” CTU 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. RIH with GR/CCL & ~2.3” nozzle to ~11,500’. PUH and paint flag for plug/perfs depths. 4. POOH. 5. Bullhead ~239 bbls 1% KCL/SW down tubing. Max tubing pressure 2500 psi. (This step can be performed any time before setting the CIBP and 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 = 159 bbls b. 4-1/2” Tubing – 9578’ X 0.0152 bpf = 146 bbls c. 3-1/4” liner – 1001’ X 0.0079 bpf = 8 bbls d. 2-7/8” Liner – 2337’ X 0.0058 bpf = 14 bbls Set CBP & Ext AdPerf Well: D-30C 6. MU 2-7/8” CIBP. RIH and set at ~11,450’ avoiding collars. a. Tag CIBP to confirm good set and complete PT to 1500 psi. 7. POOH. 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 x 2” guns were used to estimate gun weight for this job (~6 ppf). x 2” Maxforce recommended due to smaller swell (2.171”), but 2” Millenium ok to use at WSL discretion. x Tie-In Log: Baker RPM log from 28-Aug-2014. Tie-in log is on depth with reference log. No depth shift required. x Recommend using the RA tags at 10569’ MD or 12305’ MD for tie-in. Perf Interval Perf Length Gun Length Weight of Gun in air (lbs) 11,120’-11,300’ MD 180’ 180’1080 lbs 11. RIH with perf gun and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. 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. 16. FP well and RDMO. Attachments: x Current Schematic x Proposed Schematic x CT BOP Schematic x Standing Orders x Equipment Layout x Tie In log x Sundry Change Form Make up PCE. -mgr Set CBP & Ext AdPerf Well: D-30C Figure 1: Current Schematic Set CBP & Ext AdPerf Well: D-30C Figure 2: Proposed Schematic PROPOSED C C C Add Perf:11,120’ – 11,300’ CIBP ~11,450’ MD Set CBP & Ext AdPerf Well: D-30C Figure 3: BOP Schematic Set CBP & Ext AdPerf Well: D-30C Figure 4: Extended Perforating Standing Orders Set CBP & Ext AdPerf Well: D-30C Figure 5: Extended Perforating Equipment Layout Set CBP & Ext AdPerf Well: D-30C Figure 6: Tie-In Log Header Set CBP & Ext AdPerf Well: D-30C Perf 11,120- 11,300’ MD Set CBP & Ext AdPerf Well: D-30C Figure 7: Perf Tie-In Figure 8: CIBP Tie-In CIBP ~11,450’ MD Hi l c o r p N o r t h S l o p e , L L C Hi l c o r p N o r t h S l o p e , L L C Ch a n g e s t o A p p r o v e d W o r k o v e r S u n d r y P r o c e d u r e Da t e : N o v e m b e r 2 0 , 2 0 2 3 Su b j e c t : C h a n g e s t o A p p r o v e d S u n d r y P r o c e d u r e f o r W e l l D - 3 0 C Su n d r y # : An y m o d i f i c a t i o n s t o a n a p p r o v e d s u n d r y w i l l b e d o c u m e n t e d a n d a p p r o v e d b e l o w . C h a n g e s t o a n a p p r o v e d s u n d r y w i l l b e c o m m u n i c a t e d t o t h e AO G C C b y t h e w o r k o v e r ( W O ) “ f i r s t c a l l ” e n g i n e e r . A O G C C w r i t t e n a p p r o v a l o f t h e c h a n g e i s r e q u i r e d b e f o r e i m p l e m e n t i n g t h e c h a n g e . St e p Pa g e Da t e P r o c e d u r e C h a n g e HNS Pr e p a r e d By ( I n i t i a ls ) HN S Ap p r o v e d By ( I n i t i a l s ) AO G C C W r i t t e n Ap p r o v a l R e c e i v e d (P e r s o n a n d D a t e ) Ap p r o v a l : As s e t T e a m O p e r a t i o n s M a n a g e r D a t e Pr e p a r e d : Fi r s t C a l l O p e r a t i o n s E n g i n e e r D a t e 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): 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 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 D-30C Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-002 50-029-22646-03-00 12947 Conductor Surface Intermediate Production Liner 9046 80 3418 9823 3358 12150 20" 10-3/4" 7-5/8" 3-1/2" x 3-3/16" x 2-7/8" 9052 38 - 118 38 - 3456 36 - 9859 9589 - 12947 38 - 118 38 - 3276 36 - 8945 8769 - 9046 None 470 2480 7150 10530 12150 1490 5210 8180 10160 11510 - 11760 4-1/2" 12.6# L-80 34 - 9859 9049 - 9047 Structural No Packer No Packer No Packer No Packer Stan Golis Sr. Area Operations Manager Noel Nocas Noel.Nocas@hilcorp.com 907.564.5278 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 13.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 0028285 No SSSV Installed 34 - 8945 No SSSV Installed 367 2501 41215 19014 56 368 250 1150 1074 788 321-450 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: By Samantha Carlisle at 8:26 am, Oct 11, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.08 18:02:42 -08'00' Stan Golis (880) RBDMS HEW 10/11/2021 MGR15OCT2021 SFD 10/11/2021 DSR-10/11/21 ACTIVITYDATE SUMMARY 9/29/2021 CTU #6 w/1.75" CT Job Objective: CIBP and Extended adperf. MIRU CTU, MU HES Logging BHA and RIH. Tag up high at 12,400' CTMD, attempt to jet through with no luck. Made it through on 3rd attempt without pumping. Continued in hole and tagged CIBP at 12,560' CTMD. Logged from 12,561' ctm - 9,450' ctm @ 50 FPM. Painted flags 12,100' & 11,510'. Pooh w/BHA. Good data + 36' correction confirmed by OE. RIH w/Tbird CIBP BHA. ***Job in Progress*** 9/30/2021 CTU #6 w/1.75" CT Job Objective: CIBP and Extended adperf. Continue RIH w/Tbird CIBP BHA. At flag, corrected EOP = 12,128.07'. Corrected counter to COE of CIBP. Set Tbird CIBP COE @ 12,150' MD. Pooh w/BHA. Flow check well at surface. Deploy 250' of SLB 2" PJO guns. RIH and tag CIBP, correct depth to bottom shot, PUH and perforated interval 11,510-11,760'. POOH and lay down 250' of SLB PJO guns. Freeze protect tubing w/38 bbls of MEOH. RDMO CTU6. ***Job Completed*** Daily Report of Well Operations PBU D-30C 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/Pool(s): 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 planned perforations require a spacing exception?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 ServiceDevelopmentStrastigraphicExploratory Authorized Name: Authorized Title: Authorized Signature: Date: Contact Name: Contact Email: Contact Phone: COMMISSION USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE COMMISSIONCOMMISSIONER PBU D-30C Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 214-002 50-029-22646-03-00 341H ADL 0028285 12947 Conductor Surface Intermediate Production Liner 9046 80 3418 9823 3358 12600 20" 10-3/4" 7-5/8" 9043 38 - 118 38 - 3456 36 - 9859 9589 - 12947 2470 38 - 118 38 - 3276 36 - 8945 8769 - 9046 None 470 2480 7150 10530 12600 1490 5210 8180 10160 12200 - 12910 4-1/2" 12.6#L-80 34 - 98599051 - 9045 Structural No Packer No SSSV Installed No Packer No SSSV Installed Date: Stan Golis Sr. Area Operations Manager Noel Nocas Noel.Nocas@hilcorp.com 907.564.5278 PRUDHOE BAY, PRUDHOE OIL 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 3/2020 Approved application is valid for 12 months from the date of approval. 3-1/2" x 3-3/16" x 2-7/8" By Samantha Carlisle at 10:15 am, Sep 07, 2021 321-450 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.09.04 16:32:07 -08'00' Stan Golis (880) MGR15SEP2021 10-404 DSR-9/7/21 Estimated Date f SFD 9/7/2021 dts 9/15/2021 JLC 9/15/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.16 10:39:16 -08'00' RBDMS HEW 9/16/2021 9/2/2021 – Version 1 Extended Addperfs D-30C PTD:214-002 Well Name:D-30C API Number:50-029-22646-03 Current Status:Operable – Cycling Rig:Slickline / Coil Estimated Start Date:Q3 2021 Estimated Duration:5days Regulatory Contact:Abbie Barker Permit to Drill Number:2140020 First Call Engineer:Noel Nocas (907) 229-9532 (c)(907) 564-5278 (o) Second Call Engineer:Wyatt Rivard (509) 670-8001 (c) AFE Number:212-00936 IOR 386 Estimated Bottom Hole Pressure:3220 psi @ 8,800’ TVD 7.1 PPGE Maximum Expected BHP:3350 psi @ 8,800’ TVD 7.4 PPGE | Average Ivishak BHP) Max. Anticipated Surface Pressure:2470psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1000 psi (Taken on 8/30/2021) Min ID:2.313” @ 9591’MD – 2-7/8” X Nip in PTSA Max Angle:96 Deg @ 12,296’MD Tie-In Log: D-30C PDCL Log – 10 Sept 2014 Brief Well Summary: D-30C is a Zone 2A coil tubing sidetrack drilled in 2014. Stage 2 perforations were added in January 2021 however there was high gas from the onset, and these perforations reached marginal GORs quickly. Pressure testing of the CIBP during the previous job indicated that the LTP is competent, so the next step for this well is to move on to the next stage of perforations. Objective: The objective of the program is to make the well more competitive by isolating the existing perforations and shooting additional addperfs uphole in Zone 2A. Slickline (This step is at the WSL’s discretion.) 1. MIRU Slickline Unit and spot ancillary equipment. 2. RIH with ~2” centralizer and sample bailer to deviation and collect sample if possible. If sample is collected please note in AWGRS and notify OE. Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored before making up the initial perfs 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. Coil Tubing 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. Bullhead 1.5x wellbore volume (250 bbls)of KWF, 8.4 ppg 1% KCl or seawater down the tubing to the formation. (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 WSL.) a. Wellbore volume to bottom perf = 165 bbls b. 4-1/2” Tubing – 9578’ X .0152bpf = 146 bbls c. 3-1/4” Liner – 1001’ X .0079bpf = 8 bbls d. 2-7/8” Liner – 1871’ x .0058bpf = 11bbls * 9/2/2021 – Version 1 Extended Addperfs D-30C PTD:214-002 3. MU and RIH with logging tools and drift nozzle to resemble 2-7/8” CIBP. Drift to 12,600’, log OOH and flag pipe as necessary. This drift to previous CIBP may be important for future wellwork if the new CIBP is milled up and needed to be pushed to bottom. If TD cannot be tagged, note in AWGRS. It’s critical that the drift makes it to at least ~12,150’+ md for the CIBP to be set. 4. POOH and confirm good data. Notify OE to verify tie-in before setting CIBP. 5. Freeze protect tubing as needed. 6. MU and RIH with 2-7/8” CIBP (WSL to choose vendor). 7. Tie-in to flag and set CIBP at 12,150’md. POOH. 8. Freeze protect tubing as needed. 9. At surface, prepare for deployment of TCP guns. 10. Confirm well is dead. Bleed any pressure off to return tank. Kill well w/KWF, 8.4 ppg 1% KCl or seawater as needed. Maintain continuous hole fill taking returns to tank until lubricator connection is reestablished. 11.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. 12. Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. D-30C Perf Schedule *2” guns were used to estimate for this job and calculate gun weights. Perf Interval Perf Length Gun Length Weight of Gun (lbs) 11,510-11,760’250 250 1500lbs (~6ppf) 13. RIH with perf gun and tie-in to coil flag correlation and/or CIBP at 12,150’md. Pickup and perforate interval per Perf Schedule above. POOH. a. Note any tubing pressure change in WSR. 14. POOH. Stop at surface to reconfirm well is dead and hole full. 15. Reviewwell control steps with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 16. RDMO CTU. 17. RTP or FP well. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Tie In Log Standing orders flow chart included with this sundry request. MU lubricator. 9/2/2021 – Version 1 Extended Addperfs D-30C PTD:214-002 Current Wellbore Schematic 9/2/2021 – Version 1 Extended Addperfs D-30C PTD:214-002 Proposed Schematic 9/2/2021 – Version 1 Extended Addperfs D-30C PTD:214-002 Coiled Tubing BOPs 9/2/2021 – Version 1 Extended Addperfs D-30C PTD:214-002 Equipment Layout Diagram 9/2/2021 – Version 1 Extended Addperfs D-30C PTD:214-002 Standing Orders for Open Hole Well Control during Perf Gun Deployment Standing Orders for Service Coiled Tubing Operations While Deploying Extended Length Perforating BHA WELL BEGINS FLOWING DURING OPEN HOLE DEPLOYMENT Pull BHA above blind/shear rams, and close blind/shears. Space out BHA with safety joint above slip bowl, set hand slips Install safety joint with open TIW Can BHA be pulled above blind/shear rams in a single pick? Pull hand slips YES NO Begin Notifications Close Upper Pipe/Slip Ram Close TIW Close choke valves, monitor and record SIWHP Close choke line. Monitor and record SIWHP Lower safety joint and space out over BOP, set hand slips Begin Notifications 9/2/2021 – Version 1 Extended Addperfs D-30C PTD:214-002 Tie-In Log 9/2/2021 – Version 1 Extended Addperfs D-30C PTD:214-002 9/2/2021 – Version 1 Extended Addperfs D-30C PTD:214-002 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Workover Sundry ProcedureDate: September 3, 2021Subject: Changes to Approved Sundry Procedure for Well D-30CSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “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 Date Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:214-002 6.50-029-22646-03-00 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 12947 12600 9043 No Packer 12600 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 38 - 118 38 - 118 1490 470 Surface 3418 10-3/4" 38 - 3456 38 - 3276 5210 2480 Intermediate 9823 7-5/8" 36 - 9859 36 - 8945 8180 7150 Production Perforation Depth: Measured depth: 12200 - 12910 feet True vertical depth:9051 - 9045 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 34 - 9859 33 - 8945 Packers and SSSV (type, measured and true vertical depth) No Packer Liner 3358 3-1/2" x 3-3/16" x 2 9589 - 12947 8769 - 9046 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 150014162559 20031463 1348 49539 1180 1176 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:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-5278 Treatment descriptions including volumes used and final pressure: 13. 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 measured9046 Sundry Number or N/A if C.O. Exempt: 320-476 No SSSV Junk Packer Printed and Electronic Fracture Stimulation Data 5 Extended Perf with CTU Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate 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 028285 PBU D-30C 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 Samantha Carlisle at 9:44 am, Jan 27, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.01.26 18:14:02 -09'00' Bo York MGR18FEB2021 DSR-2/1/21 RBDMS HEW 1/29/2021 SFD 1/27/2021 ACTIVITY DATE SUMMARY 1/14/2021 CTU-6 1.75" .156" Objective: Set CIBP / AdPerf Road unit to location. Rig Up. Pump Coil Drift ball (1.188") Complete BOP test. 1/15/2021 CTU-6 1.75" X .156" Coil Objective: Plug and Extended perforating Make up Baker MHA along with SLB 2.20" Gamma/CCl logging tools. Log from 12,700 up to 12000' (paint flag), continue log OOH to liner top. Good data +39.2' correction. MU/RIH with 2.875" BOT CIBP. Set plug at 12600'. Re paint blue flag on way out. Deploy 250' X 2.00" HES perf guns, RIH 1/16/2021 CTU-6 1.75" X .156" Coil Objective: Plug and Extended perforating Continue RIH with HES 2.00 X 250' Perf guns. Tag plug at 12,600' Pull up hole and shoot 12,200' - 12,450' POOH. Undeploy spent guns. Well FP'd/handed over to OPS. ***Complete*** 1/18/2021 T/I/O = 280/0/0. Temp = SI. TBG /IA FLs (SL request). No AL. TBG FL @ 1700' (26 bbls). IA FL @ 100' (3 bbls). SV, WV = C. SSV, MV = O. IA, OA = OTG. 23:30 1/21/2021 ***WELL S/I ON ARRIVAL*** (profile modification) SET 4-1/2" CATCHER ON LTP @ 9,578' MD. PULLED BK-DGLV FROM ST# 3 @ 3,779' MD. MAKE SEVERAL ATTEMPTS TO PULL ST# 2 @ 7,144' MD. ***WSR CONTINUED ON 1/22/21*** 1/21/2021 T/I/O= 250/0/0 Temp=S/I TFS Unit 1 Assist Slickline with TBG Load Pumped a total of 51 bbls of 90*F Crude down TBG to Assist slickline with pulling GLV. Pollard in control of well upon TFS Departure. Final whps=0/0/0 1/22/2021 ***WSR CONTINUED FROM 1/21/21*** (profile modification) PULLED BK-DGLV FROM ST# 2 @ 7,144' MD. SET BK-GLV IN ST# 3 @ 3,779' MD. SET BK-OGLV IN ST# 2 @ 7,144' MD. PULLED EMPTY 4-1/2" CATCHER FROM 9,578' MD. ***JOB COMPLETE, WELL LEFT S/I*** Daily Report of Well Operations PBU D-30C 12,200' - 12,450' P Set plug at 12600'. Re Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:214-002 6.API Number:50-029-22646-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028285 Property Designation (Lease Number):10. 341H 8. PBU D-30C 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 Extended Perforations Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12947 Effective Depth MD: L-80 11. 11/16/2020 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): 9046 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill 5Perforate Perforate New Pool No Packer No SSSV Installed Date: Liner 3358 3-1/2" x 3-3/16" x 2-7/8"9589 - 12947 8769 - 9046 10160 10530 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 38 - 3456 38 - 3276 14. Estimated Date for Commencing Operations: BOP Sketch 38 - 118 Structural 8180 Proposal Summary 13. Well Class after proposed work: No Packer 12650 - 12910 9046 - 9045 4-1/2" 12.6#34 - 9859 Production 12916 9045 38 - 118 470 10-3/4" 7-5/8" Contact Phone:(907)564-5278 Date: 7150 80 149020"Conductor 2480 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 Surface 3418 5210 Intermediate 9823 36 - 9859 36 - 8945 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 2340 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. with CTU By Samantha Carlisle at 8:33 am, Nov 10, 2020 320-476 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.11.09 16:31:49 - 09'00' Stan Golis 10-404 DSR-11/10/2020DLB 11/10/2020MGR10NOV20 XYesn Required? Comm 11/12/2020 dts 11/12/2020 JLC 11/12/2020 RBDMS HEW 11/12/2020 Extended Perforating Procedure To:Well Services Foreman Date:11/6/20 AFE:2024050 From:Noel Nocas IOR:285 Est. Cost:$115,000 Subject:D-30C Extended Perforating with Coiled Tubing Revision: Job Sequence WBL Steps 1 Coil MU/RIH and drift with GR/CCL and nozzle. 2 Coil Set CIBP @ ~ 12,600’MD 3 Coil Shoot Adperfs from: x 12,200-12,450’ MD (250’ total) 4 Slickline Set GLV design to kick off well. (if needed, may skip step if well can pop without GL) Current Bottom Hole Pressure:3,220 psi @ 8800’ TVD ( 7.04ppg EMW) MASP MASP 2340psi (assumes 0.1psi/ft gas gradient to surface) Fracture Pressure:5785psi at 8900' TVD or .65psi/ft (12.5ppg EMW) Last SI WHP:1230 psi on 5/13/19 Min ID:2.313” ID X-Nip @ 9,591’ MD Max Angle:96 Deg @ 12,296’ Reference Log:D-30C PDCL Log H2S:20 ppm 8/10/20 CT Size:1.75"The safety joint shall be the same OD as CT size referenced here. Program Contacts: Contact Work Phone Mobile Phone Operations Engineer Noel Nocas 907-564-5278 907-229-9532 1 Scope of Work and Well Summary D-30C is a 2014 Rotary sidetrack completed in Z2A with 260' of perforations. Despite not having a liner lap test, a LTP was set post rig. The well POP'd at 2000 bopd and 6.0 mmscfpd gas at 20% water cut before quickly degrading to 700 bopd, 30 mmscfpd and 0% water cut. The well flowed consistently at these rates until the test separator metering upgrade in mid-2015, when D-30C Coiled Tubing Extended Perforating Program Well: D-30C 2 water cut increased from 3% to 25% and forced the well's GOR from 62K to 78K. The well has cycled ever since with decent, but extremely short-lived flush production from cycling. Current on-time percentage in the last 12 months is 23%. Recent forecasting indicates the well to have minimal value with current perforations that are open. 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. 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. Monitor WHP to confirm well is dead before MU perf guns. If necessary, re-kill well. 5. Pickup 1.75” 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. 6. 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: D-30C Proposed Extended Length Gun Runs Gun Run # Perf Top Perf Bottom Perf Length Overall Gun Length Weight of Perf Gun (lbs) 1 12,200 12,450 250 250 tbd Total 250 7. RIH with perf gun(s), tie-in and perforate. POOH. a. Note any tubing pressure changes in WSR. 8. Once at surface, stop to confirm well is dead. 9. Review Standing Orders (Appendix E) prior to breaking lubricator connection and rigging down guns. 10. Repeat steps 4 through 9 for each subsequent gun run (if applicable). 11. Either return the well to production or FP well. 12. RDMO. 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 G. Sundry Revision Change Form Set CIBP ~ 12,600' MD. See note above in red regarding kill methods if pressur observed on surface after perforating. * Well: D-30C 3 Appendix A - Current Wellbore Configuration Well: D-30C 4 Appendix B: Proposed Schematic Well: D-30C 5 Appendix C: Coiled Tubing BOP Schematic / Tree Diagram Well: D-30C 6 Appendix D: Extended Perforating Equipment Layout Well: D-30C 7 Appendix E: Standing Orders for Open Hole Well Control during Perf Gun Deployment Well: D-30C 8 Appendix F: Tie-In Log / Perf Sheet Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: November 6, 2020Subject: Changes to Approved Sundry Procedure for Well D-30CSundry #: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 Date STATE OF ALASKA RECEIVE ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed MD: TVD: I'lM I U / Z`Jy Collapse: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown Plugs Suspend ❑ Perforate 11 Other Stimulate ❑ Alter Casing 0 �1❑w Change Ap 9046 Plug for Retlnll [I Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: OA Cement Squeezze 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work feet 15. Permit to Drill Number 214-002 3. Address: P.O. Box 196612 Anchorage, Development ® Exploratory ❑ 8770 feet Packer AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-22646-03-00 7. Property Designation (Lease Number). ADL 028285 8. Well Name and Number: PBU D30C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: True vertical depth: 9046-9045 feet PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Size: MD: TVD: Buret: Collapse: Structural Total Depth: measured 12947 feet Plugs measured 9591 feet true vertical 9046 feet Junk measured None feel Effective Depth: measured 9591 feet Packer measured None feet true vertical 8770 feet Packer true vertical None feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Prior to well operation: 397 33530 40 0 Conductor 80 20" 38-118 38-118 1490 470 Surface 3418 10-3/4" 38-3456 38-3276 5210 2480 Intermediate 9836 7-5/8" 36-9859 36-8945 8180 5120 Production Liner 3369 3-1/2" x 3-1/4" x 2-7/8" 9578-12947 8759-9046 Perforation Depth: Measured depth: 12650 -12910 feet True vertical depth: 9046-9045 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 34-9859 348945 Packers and SSSV (type, measured and No Packer true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: OA DownSgz from surface to shoe. Pump 5 bbl FW spacer, 10 bbls neat Class G 15.8 ppg cement, 50 bbls w/ 15 ppb agregate, and 106 bbls neat. Did not achieve squeeze pressure even after 3 hesitations ranging from 15 to 30 mins. Cement squeeze OA w/ squeezecrete: Used 7.5 gallons to squeeze OA to 1200 psi. Monitor for 30 min. During monitor OAP decreased to 1120 psi. Let cement set for 72 hours. Intervals treated (measured): Surface - 3456' Treatment descriptions including volumes used and final pressure: 5bbls FW Spacer, 10 bble neat Class G 15.8 ppg Cement, 50 bbls w/ 15 ppb agregate and 106 bbls neat. 7.5 gals Squeezecrete. Final Pressures: OA = 0 psi, IA = 0 psi, Tbg = 260psi 13, Representative Daily Average Production or Injection Data Authorized Name: Worthington, Area J Contact Name: Worthington, Area J Authorized Title: Interventigpis & Integrity Engineer Contact Email: Aras.Worthington0bp.com Authorized Signature: Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 397 33530 40 0 1041 Subsequent to operation: Shut In 0 260 14. Attachments:(mqui a pm 20 MC 25.07025.071, 62511) Daily Report of Well Operations Z Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ 15. Well Class after work: Exploratory ❑ Development EI Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil IWI Gas ❑ WDSPL ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318326 Authorized Name: Worthington, Area J Contact Name: Worthington, Area J Authorized Title: Interventigpis & Integrity Engineer Contact Email: Aras.Worthington0bp.com Authorized Signature: Date: S/-?0'Zp/Contact Phone: +1907 564 4102 Form 10404 Revised 04/2077 "�/(, /� �G M iq RBDMS14 " PlAY 0 81019 Submit Original Only Daily Report of Well Operations PBU D -30C ACTIVITYr)ATF RI IMMARV T/1/0 = SSV/0+/30. Temp = SI. WHPs (Pre injectivity test). No AL. OA FL @ near surface. Circ ports in conductor are visible (Plumbers style plugs). RG -2401 starts —12" from top lip of conductor. There is 52" from the top lip of the conductor to a hard bottom (6 o'clock position). Heater installed in cellar (Bled TC to 0 psi, door left open). 11/19/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 1320 hrs. T/1/0=71tvac/30 Pump as directed (CEMENT SQUEEZE (OA/IA DWNSQZ). Pumped 49 bbls 9.8 ppg brine down OA to establish injectivity, (4bpm @—1000psi) and attempt to locate depth of SC leak. No returns observed in D-03 cellar. Pumped 102 bbls DSL down OA for further SC leak depth diagnostics, no returns observerd in D-30 cellar. Ground water migration observed from D-03 cellar (online), ground water movement observed in D-24 cellar (online), ice migrating from conductor on D-25 (shut in). Valve positions upon departure: SV, WV, SSV=closed; MV, IA, OA=open, operator notified. Tag hung on OA. FWHP's=76/ 11/20/2018 2/7 T/I/O = SSVNac/10. Temp = SI. WHPs (Post injectivity test). No change in the WHPs overnight. No fluid in the cellar. Distance from the top of the cellar box to the top of fluid (12 o'clock position): D-05: 12" freeboard. D-25: Icicles extruded from conductor. No liquid in cellar. D-24: 10" freeboard. D-03: 32" freeboard. 11/21/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 1430 TWO = SSVNac/20. Temp = SI. WHPs (Post injectivity test). No AL. OAP increased 10 psi in 13.5 hrs. No fluid in the cellar. SV, WV, SSV = C. MV = 0. IA, OA = OTG. 04:30 Distance from the top of the cellar box to the top of fluid (12 o'clock position): D-05: 12" freeboard. D-25: Icicles extruded from conductor. No fluid in cellar. D-24: 10" freeboard. 11/22/2018 D-03: 32" freeboard. TWO = SSVNac/30. Temp = SI. WHPs (Post injectivity, test). No fluid in the cellar. No change in IAP. OAP increased 10 psi overnight. Distance from the top of the cellar box to the top of fluid (12 o'clock position): D-05: 12" freeboard. D-25: Icicles extruded from conductor. No liquid in cellar. D-24: 9" freeboard. D-03: 20" freeboard. Liquids in cellars are starting to freeze. No other changes. 11/23/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 16:00 TWO = SSVNac/30. Temp = SI. WHPs (Post injectivity test). No fluid in the cellar. No change in IAP, OAP increased 10 psi in 12 hrs. Distance from the top of the cellar box to the top of fluid (12 o'clock position): D-05: 9" freeboard. rose 3" overnight, Heater in WH working property, cellar thawed. D-25: Icicles extruded from conductor. No liquid in cellar. D-24: 3" freeboard. rose 3" overnight. Called for heater and cellar fluids removed (after shift change). D-03: 9" freeboard. rose 2" overnight. Called for heater and cellar fluids removed (after shift change). 11/24/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 15:30 T/I/O = SSVNac/30. Temp = SI. WHPs (Past injectivity test). No fluid in the cellar. No change in IAP& OAP overnight. Distance from the top of the cellar box to the top of fluid (12 o'clock position): Reserve pit ice level appears to be — 3' below pad grade. D-05: 65" freeboard/ -3" of fluid in cellar. Was vac'd on night shift, heater in WH working properly, cellar thawed. D-25: Icicles extruded from all flutes/conductor. No liquid in cellar. D-24: 24" freeboard/4" of fluids in cellar. Was vac'd on night shift, heater in WH working properly, cellar thawed. D-03: 48" freeboard/16" of fluids in cellar. Was vac'd on night shift, heater in WH working properly, cellar thawed. 11/25/2018 1 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:45 Daily Report of Well Operations PBU D -30C T/I/O = SSVNac/30. Temp = SI. WHPs (Post injectivity test). No fluid in the cellar. No change in IAP & OAP overnight. Distance from the top of the cellar box to the top of fluid (12 o'clock position): 0-05: 54" freeboard, 11" gain/ -19" of fluid in cellar. Cellar is thawed. D-25: Icicles extruded from all flutes/conductor. No liquid in cellar. D-24: 21" freeboard, 3" gain/4" of fluids in cellar. Was vac'd on night shift, heater in WH working properly, cellar thawed. D-03: 43" freeboard, /21" of fluids in cellar. Was vac'd on night shift, heater in WH working properly, cellar thawed. 11/26/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 15:00 T/I/0 = SSVNac/30. Temp = SI. WHPs (Post injectivity test). No fluid in the cellar. No change in IAP & OAP from 11/26/18. Distance from the top of the cellar box to the top of fluid (12 o'clock position): D-05: 48.5" freeboard, 5.5" gain. Heater working properly. D-25: Icicles extruded from all flutes/conductor. No liquid in cellar. D-24: 20.5" freeboard, —0.5" gain. Heater working properly. D-03: 31" freeboard, 12" gain. Heater working properly. 11/28/2018 JSV, WV, SSV = C. MV = 0. IA, OA = OTG. 01:30 T/I/O = SSV/Vac/30. Temp = SI. WHPs (Post injectivity test). No fluid in the cellar. No change in IAP & OAP overnight. Distance from the top of the cellar box to the top of fluid (12 o'clock position): D-05: 43" freeboard, 11" gain/ -30" of fluid in cellar. Heater in WH working properly, cellar is thawed. D-25: Icicles extruded from all flutes/conductor. No liquid in cellar. D-24: 21 " freeboard, 3". 10" of fluids in cellar, heater in WH working properly, cellar thawed. D-03: 24" freeboard, 37" of fluids in cellar. Heater in WH working properly, cellar thawed. 11/29/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 16:20 TWO = SSVNAC/30. Temp = SI. LDD on OA w/N2. OA FL @ 70'. Used 1 rack of N2 to increase OAP from 30 psi to 40 psi in 30 min. Noticed increased activity in D-03 & D-05 after —20 min. Pushed OA FL on D-30 to 90', —20' of movement. Monitored cellars for 2 hrs, during monitor D-05 continued to gradually decrease in bubbling, D-03 continued to inflow in the cellar —2" per hour. Vac'd out D-03 cellar prior to leaving location. D-05: 38" freeboard, 5" gain since 11-2-18. Unchanged during job. D-25: Icicles extruded from all flutes, no fluid in cellar. Unchanged during job. D-24: 18" freeboard, 3" gain since 11-29-18. Unchanged during job. D-03: 12" freeboard, 12" gain since 11-29-18. Vac out cellar prior to introducing N2 to well D-30. New measurement = 32" freeboard. Removed 72 bbls of fluid from cellar, currently sitting @ 39" of freeboard. 12/2/2018 ISV, WV, SSV = C. MV = O. IA, OA = OTG. 16:55 T/I/O = SSVNAC/30. Temp = SI. WHPs (post LDD). No AL. Heater installed & working properly. No fluid in the cellar. No change in IAP & OAP overnight. Distance from the top of the cellar box to the top of fluid (12 o'clock position): D-05: 34" freeboard, 4" gain. Heater installed & working properly. D-25: Icicles extruded from all flutes/conductor. No liquid in cellar. D-24: 17" freeboard, 1". Heater installed & working properly. D-03: 31" freeboard, 8" of gain. Heater installed & working properly. 12/3/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 05:30 Daily Report of Well Operations PBU D -30C TWO = SSVNAC/30. Temp = SI. WHPs (post OA LDD). No AL. Heater installed & working properly. 2"- 4" of fluid in the cellar from 9-4 o'clock position fluid. 19" free board @ 12 o'clock position. No active bubbling in cellar @ present time. No change in IAP & OAP overnight. Distance from the top of the cellar box to the top of fluid (12 o'clock position): D-05: 32" freeboard, 2" gain. Heater installed & working properly. D-25: Icicles extruded from all flutes/conductor w/ —1 cup blu goo down conductor. No liquid in cellar. D-24: 16" freeboard, 1" gain. Heater installed & working properly. D-03: 26" freeboard, 5" of gain. Heater installed & working properly. 12/4/2018 1 SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:00 T/1/0 = SSVNAC/30. Temp = SI. WHPs (post OA LDD). No AL. Heater installed & working properly. 2% 4" of fluid in the cellar from 9-4 o'clock position fluid. 19" free board @ 12 o'clock position. Active bubbling in cellar @ the 9 o'clock postion, 0 LELs present. No change in IAP & OAP overnight. Distance from the top of the cellar box to the top of fluid (12 o'clock position): D-05: 30" freeboard, 1" gain. Heater installed & working properly. D-25: Icicles extruded from all flutes/conductor w/ —1 cup blu goo down conductor. No liquid in cellar. D-24: 15" freeboard, 1" gain. Heater installed & working properly. D-03: 25" freeboard, 1" of gain. Heater installed & working properly. 12/5/2018 1 SV, WV, SSV = C. MV = O. IA, OA = OTG 16:00 T/1/0 = SSVNAC/30. Temp = SI. WHPs (post OA LDD). No AL. Heater installed & working properly. 3.5" of fluid (crude/ diesel mix) in the cellar from 9-4 o'clock position fluid. 17" free board @ 12 o'clock position. Active bubbling in cellar @ the 3,6, & 9 o'clock postion, 0 LELs present. No change in IAP & OAP overnight. XX plug in TBG. Distance from the top of the cellar box to the top of fluid (12 o'clock position): D-05: 30" freeboard, unchanged overnight. Heater installed & working properly. D-25: Icicles extruded from all flutes/conductor w/ —1 cup blu goo down conductor. No liquid in cellar. Unchanged overnight. D-24: 15" freeboard, unchanged. Heater installed & working properly. D-03: 25" freeboard, unchanged. Heater installed & working properly. 12/6/2018 ISV, WV, SSV = C. MV = O. IA, OA = OTG 12:00. T/I/O = 20NAC/30. Temp = SI. WHPs (post OA LDD). No AL. Heater installed & working properly. 3.5" of fluid (crude/ diesel mix) in the cellar from 9-4 o'clock position fluid. 17" free board @ 12 o'clock position. No active bubbling in cellar at this time, 0% LELs present. No change in IAP & OAP overnight. XX plug in TBG. Distance from the top of the cellar box to the top of fluid (12 o'clock position. SV, WV, SSV = C. MV = O. IA, OA = OTG 00:15 D-05: 5'5" of freeboard. D-25: Icicles extruded from all flutestconductor w/ —1 cup blu goo down conductor. No liquid in cellar. D-24: 26" freeboard. D-03: 33" freeboard. Heaters gone from well houses. 12/10/2018 TWO = 20NAC/30. Temp = SI. WHPs (post OA LDD). No AL. Heater installed & working properly. 3.5" of fluid (crude/ diesel mix) in the cellar from 9-4 o'clock position fluid. 17" free board @ 12 o'clock position. No active bubbling in cellar at this time, 0% LELs present. No change in distance from the top of the cellar box to the top of fluid (12 o'clock position) since 12/10/18. SV, WV, SSV = C. MV = O. IA, OA = OTG 16:00 D-05: 65" of freeboard. (unchanged) D-25: Icicles extruded from all flutes/conductor w/ —1 cup blu goo down conductor. No liquid in cellar. (unchanged). D-24: 26" freeboard. (unchanged). 12/12/2018 D-03: 33" freeboard (unchanged). Daily Report of Well Operations PBU D -30C TWO = 20NAC/30. Temp = SI. WHPs (post OA LDD). No AL. 4.5" of fluid (crude/ diesel mix) in the cellar. OA FL @ 72' (2 bbls). 16" free board @ 12 o'clock position. Active bubbling in cellar at the 8 o'clock, & 11 o'clock positions. 0% LELs detected @ 1" above bubbling, or anywhere in wellhouse at present time. 1" change in distance from the top of the cellar box to the top of fluid (12 o'clock position) since 12/12/18. No heater present in wellhouse. Fluid contacting conductor in all locations. SV, WV, SSV = C. MV = O. IA, OA= OTG. 05:30 D-05: 5' 5" of freeboard. (unchanged, cellar frozen). D-25: Icicles extruded from all flutes/conductor w/ -1 cup blu goo down conductor. No liquid in cellar. (unchanged). D-24: 26" of freeboard. (unchanged, cellar frozen). 12/15/2018 1 D-03: 17" of freeboard 16" inflow since 12/12/2018, top of cellar frozen wl water under ice). TWO = 20NAC/30. Temp = SI. WHPs (post OA LDD). No AL. No change in WHP's overnight. 4" of fluid (crude/ diesel mix) in the cellar. 16.5" free board @ 12 o'clock position. Active bubbling in cellar at the 8 o'clock, & 11 o'clock positions. 0% LELs detected @ 1" above bubbling, or anywhere in wellhouse at present time. S' change in distance from the top of the cellar box to the top of fluid (12 o'clock position) overnight. No heater in wellhouse. SV, WV, SSV = C. MV = O. IA, OA= OTG. 03:00 D-05: 5' 5" of freeboard. (no change overnight, cellar frozen). D-25: Icicles extruded from all flutes/conductor w/ -1 cup blu goo down conductor. No liquid in cellar. (no change overnight). D-24: 26" of freeboard. (No change overnight, cellar frozen). 12/16/2018 1 D-03: 15" of freeboard 2" inflow overnight, cellar seems frozen solid). TWO = 20NAC/30. Temp = SI. WHPs (post OA LDD). No AL. No change in WHP's overnight. 6.75" of fluid (crude/ diesel mix) in the cellar. 13.75" free board @ 12 o'clock position. Active bubbling in cellar at the 9 o'clock position. 0% LELs detected @ 1" above bubbling, or anywhere in wellhouse at present time. No heater in wellhouse. 2.75" of inflow in 36 hours. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:40- D-05: 65" of freeboard. (no change overnight, cellar frozen). D-25: Icicles extruded from all flutes/conductor w/ -1 cup blu goo down conductor. No liquid in cellar. (no change overnight). D-24: 26" of freeboard. (no change since 12-16-18, cellar frozen). 12/17/2018 1 D-03: 7" of freeboard 8" inflow in 36 hours, cellar seems frozen solid). TWO = 20Nac/30 Temp = SI. WHPs (post OA LDD). No AL. WHPs unchanged since 12/17/18. Active bubbling next to conductor from 6 - 9 and 11 o'clock (4% LELs measured 1" above fluid @ 09:00). Active bubbling @ 7 o'clock against cellar box (25% LELs measured @ 1" above fluid. No LELs measured elsewhere in the well house. 5.75" of fluid in cellar @ 12 o'clock position, 16" freeboard. No heater in well house. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:30 D-05: 65" freeboard (cellar frozen, unchanged since 12/17/18). D-25: Icicles extruded from conductor flutes, -1 cup blue goo down conductor, no fluid in cellar (unchanged since 12/17/18). D-24: 26" freeboard (unchanged since 12/17/18). 12/19/2018 D-03: 2" freeboard Y inflow since 12/17/18, fluid thawed around well head. Vac truck ordered). TWO = 20Nact3O. Temp = SI. WHPs (post OA LDD). No AL. WHPs unchanged since 12/19/18. Active bubbling next to conductor from 6 - 9 and 3 o'clock. No LEL 1' & 1" above conductor also measured elsewhere in the well house. 5.75" of fluid in cellar @ 12 o'clock position, 16" freeboard. SV, WV, SSV = C. MV = O. IA, OA= OTG. 15:00 D-05: 65" freeboard (cellar frozen, unchanged since 12/19/18). D-25: Icicles extruded from conductor flutes, -1 cup blue goo down conductor, no fluid in cellar (unchanged since 12/19/18). D-24: 26" freeboard (unchanged since 12/19/18). 12/23/2018 1 D-03: 32" freeboard since 12/19/18, fluid thawed around well head). Daily Report of Well Operations PBU D -30C TMO = 20/Vac/30. Temp = SI. WHPs (post OA LDD). No AL. WHPs unchanged since 12/19/18. Active bubbling next to conductor from 6 - 9 and 3 o'clock. No LEL V& 1" above conductor also measured elsewhere in the well house. 5.75" of fluid in cellar @ 12 o'clock position, 16" freeboard. 12/28/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 16:00 T/1/0 = SSVNac/30. Temp = SI. Inspect cellars pre cement job. No AL. 17" of freeboard with 5" of fluid in cellar. SV, WV, SSV = C. MV = 0. IA, OA = OTG. 11:00 D-05: 65" freeboard (cellar frozen, —5' radius of ice around well head, cellar mostly free of ice), well is SI. D-25: 19" of free board, cellar is free of ice or fluid, well is SI. D-04: 24" of freeboard, 6" of fluid. Well is online with heater installed in well house. D-24: 26" freeboard, cellar has ice in the bottom, well is SI. 3/8/2019 1 D-03: 20" of freeboard with 45.25" of fluid, well is SI. Job Scope: OA DownSgz from surface to shoe Pump 5 bbl FW spacer, 10 bbls neat Class G 15.8 ppg cement, 50 bbls w/ 15 ppb agregate, and 106 bbls neat. Did not achieve squeeze pressure even after 3 hesitations ranging rom 15 to 30 mins. Did not over disp-casing valve closed on cement. Noted slight increase in rate of water entry into the cellar of well 3 alacen some in ermi en bubbling. Empuej well cellars on wells 3 and 4. 3/9/2019 ***Job Complete*** Job Scope: Cement squeeze OA w/ squeezecrete. Used 7.5 gallons to squeeze OA to 1200 psi. Monitor Tor 30 min. During monitor OAP decreased to 1120 psi. Let cement set for 72 hours. Heater in well house, tree cap @ 0 psi, door left ajar. 3/13/2019IT/I/O = SSV/0/0. Temp = SI. SV, WV, SSV = C. MV = 0. IA, OA = OTG. 14:00 T/1/0 = SSV/0/0+. Temp = SI. Bleed OAP & 1 hr NFT (pre NU OA gate valve). No AL. Bubbling @ the 7 o'clock position, LELs = 0%, 02 = 20.9%, CO = 0 PPM, H2S = 0 PPM. Bled OAP from 0+ to 0 psi in <5 seconds, monitored for 1 hr for NFT w/ no visible flow. Valve shop removed integrals & installed 2 1/16 gate valve on OA torqued to API specs (192 ft/lbs), tapped blind flange with alemite fitting installed on the companion side torqued to API specs (192 ft/lbs) with no VR plug, VR profile full of cement. Final WHPs = SSV/0/0. 3/19/2019 SV, W V, SSV = C. MV=O. IA, OA = OTG. 10:30 ***WELL S/I ON ARRIVAL***(cement squeeze) DRIFTED TO 2-7/8" XX PLUG W/ 2.30" CENT AND X -EQ PRONG. PULLED 2-7/8" XX -PLUG FROM 9591' MD. 3/28/2019 ***'WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED**** T/l/O = SSV/0/05. Temp = SI. WHPs (Post SC repair). No AL. There is a small puddle of hydrocarbons (12"x12"x0.5") at the 3 o'clock position, no active bubbling in cellar or flutes. No %LELs 1' above cellar and flutes and through out wellhouse. 4/8/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:15 T/I/O = SSV/0/04. Temp = SI. WHPs (Post SC repair). No AL. There is a small puddle of hydrocarbons (12"x12"x0.5") at the 3 o'clock position, no active bubbling in cellar or flutes. No %LELs 1' above cellar and flutes and through out wellhouse. OAP decreased 1 psi overnight. 4/10/2019 SV, WV, SSV = C. MV = 0. IA, OW71077 00:40 TWO = SSV/0/04. Temp = SI. WHPs (Post SC repair). No AL. There is a small puddle of hydrocarbons (12"x 20"x0.5") at the 3 o'clock position, no active bubbling in cellar or flutes. Fluid in conductor is —8" below flutes, No LEL's 1" above fluid, No LELs V above cellar and flutes and throughout wellhouse. IAP,OAP unchanged overnight. 4/13/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 12:25 T/1/0 = 3001Vac/4. Temp = SI. TBG & IA FL (Superintendent request). No AL. TBG FL @ 780' (12 bbls). IA FL @ —50' (1.3 bbls). No change in the WHPs overnight. Hydrocarbons at the 3 o'clock position stretch from the conductor to the cellar box. LRS on location to assist Ops at time of job. 4/14/2019 LRS in control of all valves upon departure. 11:40 T/1/0 = 1190/470/10. Temp = 92". WHPs (post SC repair). No AL. There is a small puddle of hydrocarbons @ the 3 o'clock position, and a newer larger puddle of hydrocarbons against the culvert from the 10 o'clock to 12 o'clock position. No active bubbling in cellar or flutes. Fluid in conductor is —8" below flutes, No LEL's 1" above fluid, No LELs V above cellar and flutes and through out wellhouse. Well POP from last monitor. 4/16/2019 ISV, WV, SSV = C. MV = 0. IA, OA = OTG. 18:00 Daily Report of Well Operations PBU D -30C T/I/O = 850/190/160. Temp = 90°. WHPs (Post SC repair). No AL. 4/17/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 16:00 T/I/O = 850/540/160. Temp = 90°. WHPs (Post SC repair). No AL. IA FL @ surface, OA FL @ cemented (installed signage). Small pool of hydrocarbons @ 10 - 12 o'clock position. No LELs taken from V above in flutes or cellar box. TP unchanged, IAP increased 350 psi and OAP unchanged overnight. 4/18/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 22:00 TWO = 860/540/130. Temp = 90°. WHPs (Post SC repair). No AL. IA FL @ surface, OA FL @ cemented (installed signage). No pool of hydrocarbons. No % LELs, taken from 1' above in flutes or cellar box. TP increased 10 psi, IAP unchanged and OAP decreased 30 psi since last monitor on 04/18/19. 4/21/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 00:30 T/I/O = 1230/560/130. Temp = 97°. WHPs (Post SC repair). No AL. IA FL @ surface, OA cemented to surface. There is a trace of dark fluid in the conductor on top of the RG2401 from the 12:00-2:00 position. No fluid visible throughout cellar box (culvert). 0% LELs in flutes, in cellar box, or throughout wellhouse. TP increased 370 psi, IAP increased 20 psi and OAP unchanged overnight. SV = C. WV, SSV, MV = 0. IA, OA= OTG. 1415 hrs 4/22/2019 T/1/0 = 1230/580/70. Temp = 95°. WHPs (Post SC repair). No AL. IA FL @ surface, OA cemented to surface. OA jewelry was frozen, thaw and clear with externally applied hot water. No change in conductor or cellar condition. 0% LELs in flutes, in cellar box, and in remainder of wellhouse. IAP increased 20 psi, OAP decreased 60 psi overnight. 4/23/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 23:00. TWO = 1280/580/120. Temp = 94°. WHPs (Post SC repair). No AL. IA FL @ surface, OA cemented to surface. No change in conductor or cellar condition. 0% LELs in flutes, cellar box, and remainder of wellhouse. TP increased 20 psi, IAP unchanged, OAP increased 50 psi overnight. 4/24/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 23:30 TWO = 1240/590/130. Temp = 98°. WHPs (Post SC Repair). No AL. 0% LELs in flutes, cellar or wellhouse. TP decreased 40 psi, IAP increased 10 psi, OAP increased 10 psi, and temp increased 4° overnight. 4/25/2019 SV = C. WV, SSV, MV = O, IA, OA = OTG. 16:00 TWO = 1270/600/130. Temp = 101 °. WHPs (Post SC Repair). No AL. LELs = 0% in flutes, cellar and wellhouse. TP increased 30 psi, IAP increased 10 psi, OAP unchanged, and temp increased W since 4/25/19. 4/28/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 15:30 TWO = 1280/610/150. Temp = 112°. WHPs (post SC repair). No AL. LELs = 0% in flutes, cellar and wellhouse. TP increased 10 psi, IAP increased 10 psi, OAP increased 20 psi, & temp increased 9° overnight. 4/29/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 10:00 T/I/O = 1280/580/150. Temp = 112°. WHPs (Post SC repair). No AL. IA FL @ surface. OA cemented to surface. IAP decreased 30 psi since 4/29/19. 5/1/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 01:15 T/I/O = 1300/620/140. Temp = 112°. WHPs (Post SC repair). No AL. IA FL @ surface. OA cemented to surface. TP increased 20 psi, IAP increased 40 psi, OAP decreased 10 psi since 5/01/19. SV = C. WV, SSV, MV = 0. IA, OA = OTG. 03:50 5/3/2019 T/I/O = 1240/560/140. Temp = 112°. WHPs (Post SC repair). No AL. TP decreased 60 psi, IAP decreased 60 psi, & OAP unchanged overnight. 5/4/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 14:00 TWO = 1280/570/140. Temp = 113'. WHPs (Post SC leak). No AL. OA cemented to surface. The TP increased 40 psi, IAP increased 10 psi and the OAP remained unchanged overnight. There is a small amount of standing liquid on top of the RG -2401 in the conductor. No standing liquids in cellar. 5/5/2019 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 1430 hrs. TREE = 4-1/16" CW WELLHEAD= FMC ACTUATOR= BAKER OKB. ELEV = 78.25' BF. ELEV = 40.6' KOP= 1215' Max Angle = 96° @ 122W Datum MD = 9738' Datum TVD= 880V SS 10-3/4' CSG, 45.5#, L-80 BTC, D = 9.950" 3456' Minimum ID = 2.313" @ 9591' 2-7/8" X NIP IN NS PTSA ITOP OF 3-1/2" x 3-1/4" z 2-7/8' LNR/ C M T I I3-1/2"LNR, 9.3#, L-80 STL, .0087 bpf, D = 2.992" 9643' 4-1/2" BKR WHIPSTOCK (05/02/14) 9860' 7-5/8" X 4-1/2' BKR S3 PKR 9933' 4-1/2" TBG, 12.6#, L-80 BTC -M, 9991' \ .0152 bpf, D = 3.958" 7-5/8' CSG, 297#, 10405' USSS-95, D = 6.875" 3-1/4' LNR 6.6#, L-80 TC11, .0079 bpf, D = 2.85" 10579' PERFORATION SUTAMARY REF LOG: _ ON 08/28114 ANGLEAT TOP PERF: 89°@ 12650' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE SCZ 2" 6 12650-12910 O 08127/14 3 D-30CSAFETY NTES: MAX DOGLOEG:42.2W 03G ELL ANLE�70°@10013' 2215' 4-1/2" HES HXO SSSV NP. D = 3.813' GAS LIFT MANDRELS ISTI MD 11VDIDEVI PRUDiOE BAY UNIT WELL: D30C PERMIT No: 2140020 API No: 50-029-22646-03 SEC 23, T11 N, R1 3F- 1655' FN- 8 1066 FEL TYPE I VLV LATCHI PORT DATE 3 3779 3567 25 KBMG-M DMY BK 0 09/05/18 2 7144 6573 26 KBW h DMY BK 0 09/05/18 1 9812 89211 58 1 KBMG h "OMY BK 0 03/20/96 " STA # 1 = DMY BEIOMD 2014 CT LMR 9591' 1-12-7/8" XX 13-1/2" X 3-3/16' XO. D= 2.786" 1 MILLOUT WINDOWI-30C) 9859'-9872' 10569' I-13-1/4" RA PUPJ014T 10579' 3-3/16" X 2-7/8" XO, D -72 377- PRUDiOE BAY UNIT WELL: D30C PERMIT No: 2140020 API No: 50-029-22646-03 SEC 23, T11 N, R1 3F- 1655' FN- 8 1066 FEL DATE REV BY COMMENTS DATE REV BY COMMENTS 03/22196 D-09 ORlG. HORZ. COMPLETION 12/28/15 JPK/TLH GLV CIO (10/02/15) 01111/03 40MC I CTD SIDETRACK(D30A) 11/13/17 JH/JMD ADD TOC FOR4-1/2"X7-5/8"ANNUL 05112107 QORDIC I CTD SIDETRACK(D30B) 01/23/18 DG/JM) RESETLTP(01/22/18) 08/30/14 4ORDIC 1 CTD SIDETRACK (D -30C) 09/12118 GJB(JMD GLV CIO (09/05/18) 09/10/14 DJ/PJC FINALODEAPPROVAL 09/12118 ZVIJMD SETXXPI.UG(09/07/18) BP Exploration (Alaska) 12/28/15 D RITLH 4-1/2" TBG CORRECTIONS (9123115) 03/18119 AB/JMD OA CMF FROM SURFACETO SHOE THE STATE °fALASKA GOVERNOR BILL WALKER Aras J. Worthington Interventions & Integrity Engineer BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU D -30C Permit to Drill Number: 214-002 Sundry Number: 318-426 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, s Hollis S. French Chair k� DATED this lZ day of October, 2018. R13DMS` CT 16116 F� �L Y V V -U STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CSP 2 20 AAC 25.280 nom. 1 61 / 2 /le" 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well El Alter Casing H / ^ther OA Cement Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development E7. 5. Permit to Drill Number. 214-002 ' - 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ a API Number: 50-029-22646-03-00 - 7, If perforating: S. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? -d Will planned perforations require a spacing exception? Yes ❑ No 0 PBU D -30C 8. Property Designation (Lease Number): 10. Fieltl/Pools: ADL 0282i5' - - PRUDHOE BAY. PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft)'. Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12947 9046 9591 8770 9591 None Casing Length Size MD TVD Buret Collapse Structural Conductor 80 20" 38-118 38-118 1490 470 Surface 3418 10-3W' 38-3456 38-3276 5210 2480 Intermediate 9836 7-5/8" 36-9859 36-8945 8180 5120 Production Liner 3369 3-1/2" x 3-1/4" x 2-7/8" 9578- 12947 8759-9046 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12650- 12910 904fi - 9045 4-1/2" 12.6# L-80 32-9859 Packers and SSSV Type: No Packer Packers and SSSV MD (ft) and TVD (ft): No Packer No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary RI Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: October 15, 2018 15. Well Status after proposed work. Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date. GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington, Area J be deviated from without prior written approval. Contact Email: Ann Worthington(Mbp.com Authorized Name: Worthington, Aras J Contact Phone: +1 907 564 4102 Authorized Title: Interventions & Integrity Engineer Authorized Signature: i�� Date: 9/wll1 mfg >• COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L/`!// Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑✓h Other: Reel Cw C CV" -Cn t' 51uce5 ci9b rr.5 v 1+15 hr/`t-h 4-06 C CG /n Clud/ip P1-<55��5��'�S fo Cc6lar clti�f; �f Post Initial Injection MIT Req'; Yes ❑ No ff9/a-� d wh k C Uh d C r C ✓c,1L�i Va C vyl Spacing Exception Required? Yes ❑ No L7 Subsequent Form Required: o- g'OT APPROVED BYTHE COMMISSION Approved by: COMMISSIONER Date: vn- 10117-11g ORIGINAL RBD MSCOCT 16 141 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval- �✓Attachments in Duplicate of�sb y24.19- by D-30 OA Cement Squeeze Well Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Chris Stone (907) 564-5518 Estimated Start Date: 10/15/2018 History D -30C is a 2014 big hole CST completed in Z2A with 260' of perforations. Bubbling was observed in the cellar b Operations on 8/15/18. An OA Integrity test was performed on /18/18 with a Surface Casing (SC) leak to the cellar during the test. Current Status The well is currently classified as "Not Operable' due to the SC Leak. Objective Perform an OA down -squeeze to fully cement the OA and seal off the SC leak. Procedural steps Fullbore 1. Establish injectivity rate and pressure with diesel or crude oil down the OA and into formation. Max OA pressure 2500 psi. 2. If SC leak is too prolific to establish injectivity down to OA shoe, pump LCM to temporarily seal -off leak in order to get cement pumped into the OA. 3. Pump —160 bbls of 15.8 ppg Class G cement down the OA to fully cement the OA from surface to the Surface Casing Shoe. Pump the following schedule at maximum rate below 2500 psi treating pressure: ➢ 10-bbls of 60/40 or 10 bbls neat MEOH ➢ 50 bbls hot (180 deg) freshwater + surfactant; 2 gal/bbl F103 and 2 gal/bbl UO67 ➢ 10 bbls of 13.5 ppg MUDPUSH II Spacer ➢ 20 bbls of neat cement ➢ 50 bbls of cement with 15 -ppb aggregate ➢ 90 bbls of neat cement Volumes: top bot volume MD MD Size ID bbls/ft. Ft. bbls Ppg: 15.8 ppg Class G Unislurry — Mix on the fly Slurry Temperature: 10-3/4" 45.5# 9.95" x 40 - 200 cc (20-100cc/30min) Thickening Time: Minimum 4 hours 10-3/4" x 7-5/8" annulus 0 3456' x 7-5/8" 29.7# 7.625" 1 0.0397 1 3456' 137 Ppg: 15.8 ppg Class G Unislurry — Mix on the fly Slurry Temperature: between 80° and 110°F API fluid loss: 40 - 200 cc (20-100cc/30min) Thickening Time: Minimum 4 hours Compressive Strength: 2000 psi in 24 — 48 hours Cement thickening time: Mix on the fl Activit Time hours) Shearing time 'quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 Minimum required thickening time: 4 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 65 0 2:00 65 0 5:30 52 0 10:00 46 0 16:30 42 0 24:00 39 0 Special Projects 1. Strap the TOC in the OA. 2. Fill and squeeze the remaining void in the OA with well lock, squeezecrete, or similar product (if needed). Squeeze to 2500 psi. DHD/Operations 1. POP well Under-Evalution to determine operability status. 2. If SC leak is fixed, re-classify well as Operable. OKB. E_2✓ =78.25• BF. � _ 4a:v KOP= - 1215' Man Angle = 96' @ 12296' lAtunbD= 9738' Dslom ND= .. _-_ 8800' SS Minimum ID = 2.313" @ 9591' 2-7/8" X NIP IN NS PTSA x DI 52 bpf, D = 3.95W 7-5/8' CSG, 29.7#, 11SSS95. D=6.875' X 7-5/8' SAFETY NOTES :"'WELL ANGLE> 7O° @ 10015 D-30 Current MAX DOGLEG: 422"@11405"' '411 1 2216' 4-12'FESHXOSSSVNP,D=3.813' 3-1/4' LNR 6.6#, L-80 TCI I, .0079 bpf, D = 2.85' 10679• PHxFORATION SLLOMRY FJTLOG: ON 0828/14 ANGLE AT TOP PEW 89'@ 12650' Note Refer to Ptocimbon DB for hmto al pert data SIZE SPFJ INTERVAL Opn/Sgz 0.47E SOZ 2 6 12650 - 12910 O 0827/14 0&30111 40FIDIC CTD SIDETRACK(D30C) 12-7/8' LNZ 8.5#, L-80 STL..0058 bpf. D = 2 441' H 12947' 1 GAS LFT MAN FUS 1 1981217 98 21857 05118 9211 26 BK 0 58 IKBhGMI'OMYI BK I 0 1031211196 STA #1= OMY B&#N) 2014 CT LNi X NP, D= FES X NP, D=2.8121 X 3-3/16' XO, D = 2.786' MLLOUT WINDOW(0.30C) 9859' 9872' 10699' I—(3-1/4' RA nrJOINT 10679' 3-3/16' X 2-7/8' XO, D = 2.377' FRJDHOE BAY 1#4T WELL 0300 PEFWT No 2140020 AR No. 50-02922646-03 SEC 23, T11K R13E 1656 FTL 8 1066' FE DATE REV BY COM.HNTS DATE REV BY ODKNA94TS 0322196 609 OIG- HOR7_ COMPLETION 12/28/15 JFKM-H GLV GO (10102/15) 1 01111103 4OMC CTDSIOETRIICK(D30A) 11/13117 JWJMD ADDTOCFOR4-112'X7-5/8'ANNLJLL 05/12/07 40FUC CTDSIDETRACK(D-30B) 01/23/18 DGIJMD RESL7LTP(Ot/22118) 0&30111 40FIDIC CTD SIDETRACK(D30C) 09/12/18 GJBIJMD GLV GO (09105/18) 09/10/14 DJ/ PJC FINAL OOEAP ROVAL 09112118 ZVIJMD SET XX PLUG (09107/18) BP Uploratlon (Alaska) 1228/15 DGINTU 4-12' TBG ODRwfO (9/23115) Fully Cemented OA Minimum [D=2.313"@9591' 2-718" X NIP IN NS PTSA D = 2.992" 4.1/2' TBG, 12.84, L-80 911C -M,.0152 W. D=3.958" D = 6.875' SAFETY NOTES: -WELL ANGLE> 70.0 10013' — D-30 Proposed MAXDOMM:42.2"@11403'- fIk451 3-114' LNR 6.60, L-80 T61_0079 W, D=2.85' 10579' PERFORATION SUWANRY FEE LOG: —ON 0828114 ANGLEATTOPPERF: 89'@ 12650' Nola: Refer b Roduc6Dn DB for historical pod deb SIZE SPP WERVAL OPrVSgz DATE SOZ 7 8 12650 -12919 O 0827/14 103IAC M �:n• Gi6cSI'1� SSi;jj,"a GAS LFT MN303S JSTJ AD ITVDIMVI TYPE I VLV ILATMI DATE REV BY CDI.KSJfS RMT DATE 3 3779 3567 25 103IAC M DAN BK 0 09/05118 2 7144 6573 26 KBAGM OA1Y BK 0 WD5118 1 9812 8921 58 KBMG-M "pAY BK 0 032096 " STA S 1 = DMY BEHND 2014 CT LAR MLLOUT WINDOW (0,30C) 9859'-9872' PRUDHOE BAY (1MT VAIL D -30C PEFW NW, 2140020 ARNo: 50-029-2284603 SFS 23, Tl 1 K R13E 1655 FTt 8 1066' FT DATE REV BY COk68dFS DATE REV BY CDI.KSJfS 03rMN 0,09 ORM MRZ. COMPLETION 12(28/15 JFKMJH GLV GO (10AM15) 01111103 WMC CTDSIDETRIICK(DM) 11113117 Jt*JMDAMTOCFOR4.irZX7-5ilrANNULt 06112107 IDROIC CTOSIDETMCK(030B) OWNIS DGI AD RESEILTP(01=18) MI3M14 WF0C CTD SDETMCK (D -W) 09/12/18 GJS/AAD GLV CIO (0995118) 09/10114 ON PJC FINALODEAPPROVAL 09112118 ZV/JMD SEI XXR.IG(09107118) SP Exploration (Alaska) 12/28115 DGBITLF 4117 TBG OORRIBMIOW (923/15) Loepp, Victoria T (DOA) From: Worthington, Aras 1 <Aras.Worthington@bp.com> Sent: Tuesday, October 09, 2018 1:56 PM To: Loepp, Victoria T (DOA) Subject: RE: PBU D-30C(PTD 214-002, Sundry 318-426) OA Cement Squeeze for SC leak Victoria, The SC leak depth is unknown at this time but we believe it to be relatively shallow since the returns to the cellar during the OA Integrity test were fairly rapid. The OA has no cement in it at this time, thus we believe this makes for a good candidate to fully cement it and seal off the SC leak in the process. Thanks, Aras Worthington Well Interventions & Integrity Engineer BP Alaska Inc. Office: (907) 564-4102 Cell: (907) 440-7692 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, October 9, 2018 9:03 AM To: Worthington, Aras J <Aras.Worthington@bp.com> Subject: PBU D-30C(PTD 214-002, Sundry 318-426) OA Cement Squeeze for SC leak Aras, 1. What depth is the SC leak? 2. Is there any OA cement now? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeppl?a alaska.goy CONFIDENTIALIrY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(si. If may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907(793-1247 or Victoria.Loeoip@alaska.gov STATE OF ALASKA , SLASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS r 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Pull&ReSet LTP 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 214-002 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22646-03-00 7. Property Designation(Lease Number): ADL 0028285 8. Well Name and Number: PBU D-30C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12947 feet Plugs measured feet true vertical 9046 feet Junk measured feet Effective Depth: measured 12916 feet Packer measured feet true vertical 9045 feet Packer true vertical feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 37-115 37-115 1490 470 Surface 3421 10-3/4" 35-3456 35-3276 5210 2480 Intermediate 9836 7-5/8" 36-9872 36-8951 8180 5120 Production Liner 3358 3-1/2"x3-1/4"x2-7/ 9589-12947 8769-9046 10160/8620/10570 10530/7820/11160 Perforation Depth: Measured depth: 12650-12910 feet True vertical depth: 9046-9045 feet feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 32-9872 32-8951 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: SCANNED i;;Ar J ../±,, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 433 34045 48 660 1200 Subsequent to operation: 422 34390 44 380 243 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Haffener,Jordan Contact Name: Haffener,Jordan Authorized Title: Production Engineer Contact Email: Jordan.Haffener@bp.com Authorized Signature: `4 : Date: Z//2/2C/g Contact Phone: +1 9075645383 Form 10-404 Revised 04/2017 6/ y V7-1- 3////g p E3 I I fl� 1,k, Err i 3 !.18 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary February 6, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Pulling and Re-Setting of the Liner Top Packer for Well D-30C, PTD # 214-002. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. 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Fkt • @NOTES:"'WELL ANGLE>70' 10013""' ACTtIATOR D"3 V% MAX DOGLEG:42.7 011403'— a 0KB. /= BAKER C 7825 I # BF.ELEV= 40.6' KOP= 1215' et J L 2216' H4-1/2"tiES HXO SSS/NP,I3=3.813" Mix Ante= 96'@2296' Dtun Nf.)= 9738' Daum TVD= 8800'SS GAS LFT MANDRH S 110-3/4'CSG,45.51,1-80 BTC,D=9.950' H 3466' ST M3 TVD DEV TYFE VLV LATCH PCRT DATE '1 la 3 3779 3567 25 Ka -M DONE BK 16 09/07/14 Minimum I® =2.37" 958V �i 2 7144 6573 26 KBkG-M DOLE BK 16 12115 45 KB LINER TOP PACKER 1 9812 8921 58 KBI3-M TUT BK 0 03120/96 `STA 11=DM BEHMD 2014 CT L.FR 14-1/2'X 7-5/8'TOC(04/30/14) H 8980' , �-y ,_ . . 9578' —145 KB LIP sr NS PISA,D=2.3r(01122/18) (TOP OF 3-1/7 x 3-1/4'x 2-718'LTR/CUT 9689' `"Q" 9689' —13.70'CEEPLLOY SLY,D=3.00 I A'' 'o 9610' —(3-1/2'FES X N12.D=2.812' ( S4 :"' (3-1/2'LTR 9,31,1-80 STL,.0087 bpf,D=2.992' H 9643' F, :tilt 9643' J-1112-X 3-3/16'XO,D=2.786" ( (4.1'2-SKR WHIPSTOCK(05/02/14) H 9860' " w I 2 (7-5/8'X 4-1 'BKR s3 PKR H9933' ( 4-1/7 1BG,1261,L-80 BTC-M, H 9991' :44: '( MI.LOUT VVNDOW(D-30C) 9859'-9872' • .0152 bpf,D=3.958' 7-5/8'CSC,29.71, -1 10405 ,Ft1SSS-95,D=6.875' x` F 10669' --13-1/4'RA RPJOPT( 13-114'LTR,6,64,1-80 TC11,.0079 bpf,D=2.85' H 10679' (-- --1 10679' H3-3116-X 2-7/8"XO,ID=2.377 1 PI37FORATION SUMMARY REF LOG: ON 08/28/14 ---( 12306' H2-7/8'RA PUPJONNI ANGLE AT TCW PEW 89'@ 12650' Note:Refer to Reduction DB for historical perf data SEE SPF INTERVAL Opn/Sqz DATE SCS 2" 6 12650-12910 0 08/27/14 PBTD 12916' 12-7/8'LTR 6.5#,1-80 SIL,.0058 bpf.D=2.441' H 12947' .4 DATE REV BY COMMENTS DATE REV BY OOkMEN S PRUDHOE BAY INT 03/22/96 0-09 ORIG.HOW.COMPLETION 09110/14 SWOPJC SET 45 KB LTP(09/08/14) WELL D-30C 01/11/0311OR IC 1 CTD SIDETRACK(D-30A) 09110/14 WI PJC FNAL ODE APPROVAL PHUT No:"2140020 05/12/07rIOI =1tGTD SIDETRACK(D-30B) 12/28/15 DGBV-11.144-1/2'TBG CORRECTIONS(9/23/15) API No: 50-029-22646-03 08/30/14 NORDIC 1 CTD SIDETRACK(0-30C) 12/28/15 JPK1TLH GLV 010(10/02/15) SEG 23,T11 N,R13E,1655 RE&1066'FEL 09/02/14 ROIPJC EOW /LNR CORRECTIONS 11/13/17 JWJMD ADD TOC FOR 4-1/2'X 7-5/8'AMELUS 09107/14 SWCIPJC GLV CJO 01/23/18 DG/AD RESET LIP(01/22/18) I BP Exploration(Alaska)