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213-191
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 C-16C Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 213-191 50-029-20438-03-00 12574 Surface Intermediate Scab Liner / Liner Liner Liner 9013 2659 8548 6367 367 3467 12535 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 9012 29 - 2688 27 - 8575 2673 - 9040 8894 - 9261 9104 - 12571 29 - 2687 27 - 8274 2673 - 8740 8594 - 8935 8803 - 9013 12535 2670 4760 7020 7500 10530 None 5380 6870 8160 8430 10160 10568 - 12525 4-1/2" 12.6# L-80 25 - 8905 9009 - 9012 Conductor 80 20" x 30" 30 - 110 30 - 110 4-1/2" Baker S3 Packer 8848 8548 Torin Roschinger Operations Manager Leif Knatterud Leif.knatterud@hilcorp.com 907-564-4667 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 0028305 25 - 8605 N/A N/A 446 876 43910 36081 3 97 1450 1450 1042 1047 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed 8848, 8548 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 12:54 pm, Jun 10, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.06.10 12:27:05 - 08'00' Torin Roschinger (4662) DSR-6/18/25JJL 6/13/25 ACTIVITY DATE SUMMARY 5/27/2025 CTU#2 1.75" CT 0.156" WT HT-110 Job Scope: Mill CIBP MIRU CTU. NU BOP's & Function Test. Pressure Test PCE 300psi Low / 4200psi High. Test DHCV's - Good surface tests. Open well to 2455psi. Bullhead 162 bbls 1% KCL. RIH w/ Baker Milling BHA w/ 2.30" Junk Mill. Tag LTP at 9129' ctm. Roll pump & pass through. Dry Tag CIBP at 11080' ctm. Establish free-spin. Begin milling CIBP w/ 1:1 returns, mill through seal and lose returns, attempt to push plug dry, but unable, continue pumping and push CIBP to 12535'ctm. POOH ***Continue on 5-28-25 WSR*** 5/28/2025 LRS CTU #2 1.75" CT 0.156"WT HT-110 Job Objective: Mill CIBP POOH w/ Baker milling bha and 2.30" junk mill. FP tubing w/ 3bbls 50/50, 35bbls diesel, FP CT w/ diesel. RDMO to E-09C. ***Job Complete*** Daily Report of Well Operations PBU C-16C 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 C-16C Ext Add Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 213-191 50-029-20438-03-00 12574 Surface Intermediate Scab Liner / Liner Liner Liner 9013 2659 8548 6367 367 3467 11045 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 9004 29 - 2688 27 - 8575 2673 - 9040 8894 - 9261 9104 - 12571 29 - 2687 27 - 8274 2673 - 8740 8594 - 8935 8803 - 9013 12500 2670 4760 7020 7500 10530 11045 5380 6870 8160 8430 10160 10568 - 12525 4-1/2" 12.6# L-80 25 - 8905 9009 - 9012 Conductor 80 20" x 30" 30 - 110 30 - 110 4-1/2" Baker S3 Packer 8848 8548 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028305 25 - 8605 N/A N/A 448 2488 41716 24265 48 552 1450 1300 1130 1000 324-376 13b. Pools active after work:Prudhoe Oil No SSSV Installed 8848, 8548 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 9:14 am, Aug 01, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.01 08:25:12 - 08'00' Torin Roschinger (4662) RBDMS JSB 080624 DSR-8/12/24 ACTIVITY DATE SUMMARY 7/24/2024 LRS #1 1.75" Coil Tubing .156" WT. Job Scope - Drift/Jewelry log, Set CIBP, Contingent Ext AdPerf Travel to C pad, MIRU CTU, M/U NS MHA ***Continued to WSR on 7/25/24*** 7/25/2024 LRS #1 1.75" Coil Tubing .156" WT. Job Scope - Drift/Jewelry log, Set CIBP, Contingent Ext AdPerf Finish M/U NS MHA and HES GR/CCL. RIH, log from 11,300, EOP flag at 10,988.2', top of log 9000. POOH. Download data. -3' depth shift. EOP flag @ 10985.2'. RIH w/ NS 2.20" CTC, 2.13" MHA, 1.75" Setting tool, and 2.10" CIBP (OAL 9.64'). Well Control Drills - Pack off leak and leak below master with pipe in hole. Tie-in to EOP flag and set CIBP @ 11045'. Bleed 800 psi off Tbg and perform drawdown test (Gained 14 psi final 30 mins) Circulate well to 1% KCL whlle POH. Flow check well - Good. Start circ across top on trip sheet. PJSM. Deploy 367' of 2" Maxforce guns, 6SPF, 60 degree phase. RIH, correcr off flag and perforate intervals(10,568'-10,623') (10,640'-10,785') (10,820'-10,935') POOH keeping hole full ***Continued to WSR on 7/26/24*** 7/26/2024 LRS #1 1.75" Coil Tubing .156" WT. Job Scope - Drift/Jewelry log, Set CIBP, Contingent Ext AdPerf Continue POOH keeping hole full. At surface, Flow check good. Un-deploy guns. Ball recovered from firing head and all shots fired. RD. ***Job Complete*** Daily Report of Well Operations PBU C-16C 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 C-16C Ext Add Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 213-191 50-029-20438-03-00 341J ADL 0028305 12574 Surface Intermediate Scab Liner / Liner Liner Liner 9013 2659 8548 6367 367 3467 12535 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 9012 29 - 2688 27 - 8575 2673 - 9040 8894 - 9261 9104 - 12571 2425 29 - 2687 27 - 8274 2673 - 8740 8594 - 8935 8803 - 9013 12500 2670 4760 7020 7500 10530 None 5380 6870 8160 8430 10160 11130 - 12525 4-1/2" 12.6# L-80 25 - 89059003 - 9012 Conductor 80 20" x 30" 30 - 110 30 - 110 4-1/2" Baker S3 Packer No SSSV Installed 8848, 8548 Date: Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY 7/15/2024 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 9:02 am, Jul 01, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.07.01 06:26:08 - 08'00' Torin Roschinger (4662) 324-376 DSR-7/8/24MGR01JUL24 10-404 2425 SFD 7/11/2024 Perforate *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.12 09:43:56 -08'00' 07/12/24 RBDMS JSB 071624 CT Plug and Perf Well: C-16C Well Name:C-16C API Number:50-029-20438-03 Current Status:Operable producer – HGOR Pad:C-Pad Estimated Start Date:8/1/2024 Rig:CT Reg. Approval Req’d?10-403/10-404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:213191 First Call Engineer:Michael Hibbert Contact:907-903-5990 Current Bottom Hole Pressure:3250 psi Estimated KWF:7.2 ppg Use seawater or 1% KCL MPSP:2425 psi (BHP - .1psi/ft gas gradient + safety factor) Max Dev:94 deg At 10,658’ MD Min ID:2.377” 10,388’ @ LTP Brief Well Summary: C-16C is a poor cycling HGOR well. 4 Stages of perforations have been added since the well was sidetracked in 2014. In April 2024, all perforations were opened and the LTP was pressure tested. LTP pressure test passed to 2500 psi. Well POP’d with 306 IOR but declined to HGOR within ~1 week. Objective: CT will isolate all current perforations and perform a drawdown test to confirm plug set/liner top packer isolation. Deploy extended perforation guns and shoot 315’ of net charges over a 367’ interval in Zone 2A. Procedure: Coiled Tubing Drift and Flag 1. MU GR/CCL in a carrier with ~2.25” JSN drift. RIH beyond plug setting depth. Flag pipe for plug and perf depths and pull correlation log. a. CT was last in the well in April 2024 and did have issues getting into the liner. Typically, they had to roll the pumps to get the milling BHAs into the liner. Liner lap is @ 15-20 degrees. 2. Correlate with attached log information. a. Correct flag and send to Jeff Nelson and OE for confirmation. Coiled Tubing Plug Set 1. MU 2-7/8” CIBP 2. RIH and set at 11,045’ 3. Tag plug to verify a good set 4. Perform drawdown test – reduce tubing pressure down to HP flowline pressure, ~800 psi, shut in and see if it builds back up. If drawdown test fails, then POP well to HP and put in test through pad separator for ~2-4 hour test. 5. Discuss results with OE to determine path forward. a. If drawdown test passes or well flows minimally then proceed with perforating. b. If well flows significantly with the plug set in the liner then we may consider other options – potentially pulling and resetting LTP or running a caliper in the liner. 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. CT Plug and Perf Well: C-16C 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. 6. 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. 7. Bullhead 1.2x wellbore volume ~185 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 = 154 bbls b. 4-1/2” Tubing – 9,096’ X .0152 bpf = 139 bbls c. 3-1/4” Liner – 1,292’ X .0079 bpf = 10 bbls d. 2-7/8” Liner – 742’ X .0058 bpf = 5 bbls 8. At surface, prepare for deployment of TCP guns. 9. 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. 10.*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. e.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. 11.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 guns or similar Perf Interval (tie-in depths) Lengths Total Gun Length Weight of Gun (lbs) Run #1 10,568’ – 10,623’ – gun 10,623’ – 10,640’ –blank 10,640’ – 10,785’ – gun 10,785’ – 10,820’ –blank 10,820’ – 10,935’ – gun 55’ - loaded 17’ - blank 145’ - loaded 35’ - blank 115’ - loaded 367’~2055 lbs (5.6 ppf) 12. 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. 13. 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. 14. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 15. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. Make up and test PCE at QTS sub. - MGR CT Plug and Perf Well: C-16C 16. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator to LD gun BHA. 17. RDMO CTU. 18. Turn well over to Operations POP. Attachments: x Wellbore Schematic x Proposed Schematic x Tie-In Log x BOPE Schematic x Standing Orders x Equipment Layoutdiagram x Sundry Change Form CT Plug and Perf Well: C-16C Current Schematic: CT Plug and Perf Well: C-16C Proposed Wellbore Schematic Proposed Perforations S S S S S S S S S Plug Set Depth ~11,045’ CT Plug and Perf Well: C-16C Tie-in Log CT Plug and Perf Well: C-16C Perf – 10,568’-10,623’ Blank – 10,623’-10,640’ Perf – 10,640’-10,785’ Blank – 10,785’-10,820’ Perf – 10,820’-10,935’ CT Plug and Perf Well: C-16C Plug Set – 11,045’ CT Plug and Perf Well: C-16C BOP Schematic CT Plug and Perf Well: C-16C CT Plug and Perf Well: C-16C CT Plug and Perf Well: C-16C Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/9/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240509 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 3-07A 50029219110100 198147 4/17/2024 HALLIBURTON MFC END 3-25B 50029221250200 203021 3/31/2024 HALLIBURTON PPROF MPU J-16 50029226150000 195169 3/28/2024 HALLIBURTON WFL-TMD3D NCIU A-18 50883201890000 223033 5/1/2024 READ Multiple Array PProf PBU B-05D 50029202760400 213069 4/24/2024 HALLIBURTON RBT PBU C-16C 50029204380300 213191 4/26/2024 HALLIBURTON RBT PBU D-18B 50029206940200 215001 4/21/2024 HALLIBURTON RBT TBF A-07 50733200360000 167046 4/17/2024 HALLIBURTON RBT TBF A-18 50733201430000 168076 4/16/2024 HALLIBURTON RBT Please include current contact information if different from above. T38771 T38772 T38773 T38774 T38775 T38776 T38777 T38778 T38779 PBU C-16C 50029204380300 213191 4/26/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.13 12:46:46 -08'00' 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 C-16C Mill CIBPs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 213-191 50-029-20438-03-00 12574 Surface Intermediate Scab Liner / Liner Liner Liner 9013 2659 8548 6367 367 3467 12535 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 9012 29 - 2688 27 - 8575 2673 - 9040 8894 - 9261 9104 - 12571 29 - 2687 27 - 8274 2673 - 8740 8594 - 8935 8803 - 9013 12500 2670 4760 7020 7500 10530 None 5380 6870 8160 8430 10160 11130 - 12525 4-1/2" 12.6# L-80 25 - 8905 9003 - 9012 Conductor 80 20" x 30" 30 - 110 30 - 110 4-1/2" Baker S3 Packer 8848 8548 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-930-5990 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028305 25 - 8605 N/A N/A 206 697 20662 35016 28 162 0 0 816 1096 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 8848, 8548 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 8:02 am, May 02, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.05.02 04:51:37 -08'00' Torin Roschinger (4662) RBDMS JSB 051324 DSR-5/2/24WCB 7-29-2024 ACTIVITY DATE SUMMARY 4/23/2024 LRS CTU 1, 1.5" Blue Coil. Job Objective: Mill CIBPs and Log-CBL MIRU. Perform weekly BOP test 250/4000. Function test BOPs on the well. Make up and RIH with Baker 2.300" venturi burnshoe BHA. ***Job Continued on 4/24/2024*** 4/24/2024 LRS CTU #1 - 1.50" CT ***Continued from WSR 4-23-24*** Job Objective: Mill 2 CIBPs, CBL Continue in hole w/ 1.69" Motor and 2.30" Burn Shoe. Set down on LTP and roll pumps 0.5bpm to get through. Dry drift down to plug #1 tag @ 11364' CTM. Mill plug and push to top of plug #2 @ 11871' CTM. POOH to inspect tools. No core recovered. Swap out 2.30" Burnsoe and RBIH. Tag at @ 11878' CTM. Mill for ~3hrs until stacking weight w/ no motor work or stalls. POOH. Core recovered as well as perf charges from previous split perf gun. Determine perf gun lower sub and bullnose left in hole above CIBP. Continue with 1.69" motor and 2.30" Venturi burnshoe and attempt to recover bullnose. Tag at 11878' CTMD and attempt to mill with occasional MW, though mostly stacking weight. ***Continued on WSR 4-25-24*** 4/25/2024 LRS CTU #1 - 1.50" CT ***Continued from WSR 4-24-24*** Job Objective: Mill 2 CIBPs, CBL Mill on perf gun lower sub and bullnose. POOH and recover steel aluminum chunk stuck in bottom of the burn shoe as there is likely more charge debris left in hole. Make up venturi BHA with 2.36" mule shoe and RIH. Work venturi over ~70' interval 11870' - 11800' 8 passes and pooh pumping to surface. Check tools at surface, recover gun bottom nose. Make up milling BHA w/ 2.30" reverse clutch junk mill. RIH tag @ 11879' CTM and begin milling plug. Mill top of plug and loose returns before stopping progress and stacking weight. POOH and inspect tools with no sign of tool failure, believe to be additional debris on top of the plug. Complete Well Control, Man Down, Fire, and H2S Drills. Make up Venturi Burnshoe milling BHA with 2.30" shoe and RIH. ...Continued on WSR 4-26-24.... 4/26/2024 LRS CTU #1 - 1.50" CT ***Cont. from WSR 5-25-24*** Job Objective: Mill CIBP x 2, CBL RIH with 2.30" venturi burnshoe milling BHA. Push CIBP at 11900 MD down to 12501 CTMD. Dry drift liner to ensure free of debris. POOH. At surface break down tools. Recovered slips/rubber, no core. Install CT DOG and make up CBL run. RIH w/ HES CBL logging tools, pump down backside to keep fluid packed. Log from 12490' - 8700' @ 50fpm. RBIH to top of liner and circ well out diesel while POOH. At surface, well swapped to diesel. Stack riser on back deck and night cap well to secure and stand by for Phase weather to pass. Crew off location. Well Control and Man Down Drill ...Job Continued after Weather Standby... 4/27/2024 LRS CTU #1 - 1.50" CT ***Cont. from WSR 4-26-24*** Job Objective: Mill CIBP x 2, CBL Return to work after phase conditions. Break down CBL toolstring and confirm good data. Dig out equipment and RDMO ***Job Complete**** Daily Report of Well Operations PBU C-16C j RIH with 2.30" venturi burnshoe milling BHA. Push CIBP at 11900 MD down to 12501 CTMD. Set down on LTP and roll pumps 0.5bpm to get through. Dry drift down to plug #1 tag @ 11364' CTM. Mill plugggy and push to top of plug #2 @ 11871' CTM Swap out 2.30" Burnsoe and RBIH. Tag at @ 11878' CTM. Mill for g@ g@ ~3hrs until stacking weight w/ no motor work or stalls. POOH. Core recovered as well gg as perf charges from previous split perf gun. Determine perf gun lower sub and fg gg bullnose left in hole above CIBP. Continue with 1.69" motor and 2.30" Venturi burnshoe and attempt to recover bullnose. Tag at 11878' CTMD and attempt to mill with occasional MW, STATE OF ALASKA OASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIO 1. Operations Performed Abandon ❑ Plug Perforations ® Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend ❑ Perforate ® Other Stimulate ❑ Alter Casing 0 Change Approved Program �❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: j'f C./,.0/) Ly 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 213-191 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20438-03-00 7. Property Designation(Lease Number): ADL 0028305 8. Well Name and Number: PBU C-16C 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: � EIVEDTotal Depth: measured 12574 feet Plugs measured 11395/11900 fe C true vertical 9013 feet Junk measured feet SEP 18 2017 Effective Depth: measured 11395 feet Packer measured 8848 feet true vertical 9002 feet Packer true vertical 8547.44 feet 80 AOG Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"x 30" 30-110 30-110 Surface 2659 13-3/8"72#L-80 29-2688 29-2687 4930 2670 Intermediate 8547 9-5/8"47#L-80 27-8575 27-8274 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11130-11250 feet 11480-11510 feet 11510-11530 feet 11540-11570 feet 11570-11600 feet 12050-12080 feet 12080-12110 feet 12130-12160 feet 12160-12190 feet 12275-12525 feet True vertical depth: 9003-9002 feet feet 9004-9005 feet 9005-9005 feet 9005-9005 feet 9005-9006 feet 9008-9009 feet 9009-9011 feet 9012-9012 feet 9012-9013 feet 9013-9012 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 25-8905 25-8604 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): NOVNOV �j q Treatment descriptions including volumes used and final pressure: SCANNED 0 8 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 363 29479 50 490 700 Subsequent to operation: Shut-In 700 300 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Il 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 0 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: Glasheen,Brian P Contact Name: Glasheen,Brian P Authorized Title: Production En•in:// / Contact Email: Brian.Glasheen@bp.com Authorized Signature: i • Date: 1 d 17 Contact Phone: +1 907 564 5905 i Form 10-404 Revised 04/2017 VP— I O 1 RBDMS [ L.SEP 2 5 2017 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue �+ Anchorage, AK 99501-3572 RECEIVED SEP 18 2017 RE: BP Exploration (Alaska), Inc. A OGCC Report of Sundry Well Operations Summary September 7, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug and Addition of Perforations for Well C-16C, PTD # 213-191. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • (0ca 1 I'- ) NU � ( I- ti C U 44 M O� CO M ,_ N up 0CD 53 CD 01 CCD OD Ns 00 000 0 000 000 m I` 0 CO O U) M C3) M O OD N- ti 0 M U) O 4- O 0 N N- ti O) co O co CO N co ti 00 CO O CA CD 00 1 I 1 I I 1 N U) 0 d' M CA O CA Ns I` r- C7) 0 0 0 tf) M N CV 0 Ns U) O OD O N N Ns 00 O 00 O) i+ O aO0 Ill CO d' 0 _� M up O CO 000 coCD ON) 0) O N 00 � r Q Co CO CDCDtsNsNsrnoUMU) MNNCID O00 , 0N N 00 O CA 0) M CO 0 p 53 0 0 0 53 CO 00 00 .J C) - _1opOO = N r - M N *k J J CSO M 00 4t trj V) 'N X ,r *k *k (Ni O• 0 •(O N RJ it) Eo 0C1CJ - - U _ NCVv oN CM U) f� r- VI CA d' 0/V / CV 0' t 4.CAO � Ns O 0 N M CON_ O000 O N 000 U O M 0 T- N 000 W cc Q C O W W 15 U oau_ WCLCCMCCCIS c � Z Z W W W W W W W m oD _I'- ZZZZZZD UCnZJJJJJJI— • • 0 Packers and SSV's Attachment PBU C-16C SW Name Type MD TVD Depscription C-16C PACKER 2680.47 2679.98 7" Baker ZXP Top Packer C-16C TBG PACKER 8847.69 8547.44 4-1/2" Baker S-3 Hydro Set Packer C-16C PACKER 8901.74 8601.48 4-1/2" Baker ZXP Packer • • • o O O O 'a -a d. x cc c c • O = N N N N CD • •3 - = Q= di Di m C co = O gm a N N N _, d L . .c L Cn - • a) .O o. C]. O- o- CV C6 N �, O 0 O OcD Oj CAE) ' CO CO CO CO v M.§ 0 U- w w w aa)) 11- a n = Cl) vim) a) a) m• � a)cu a) 1v co m co co U 0)"-...., U CQ C C C CO- - NCD a) 0 7 7 7 L .Q = 0) 0) CT 0) •CwQm � ) E E E E w NI- CU Uen v = m g a m U' Ca La EQ CV N N N E i o d O Lc) . ti c ,- c ,- c ,- c ems- ti E U) 0. O N- EL0 0)M ma) T- If � Ify- 0 ,- 0 ,- _ F- a o' a) N- Y � = -Z 0 7 \ = \ = N- my- 3 Cin >, o 20 cu — aN g � � � � � � r� 0 o v U m CO cn � E cO � Q co CU CU CU CU M o rn G) CC w c ma. U X = N = a) = a) = N 'C LL o m = Q° c v a. as m 3 f° 3 c0 3 f° 3 c° (X co m ci G E QL.2-t5„.. a) U a� E L ma moo moo o-) '+ m Si- O = O •cs. N O � J � J •-- Jc�- 'J O E O a 3 C) a)a) I- Cl) X- a) — a) — a) 4- ,• O a .� cT* m O o_ o a) •� E E E E O a) U O L LL 7 a N a) p p p p u) '�•p) C p Y E "O N Nal ,- a) a) a) OD C a) A Q a) ° O —§ 017,: o = 0 < ' c' N- Q' S Me- W M N O 06n. _0 7Z 0 3 - a) O" C U co 1- Y 1- .. T... _,c •- Y L vi U , .� a -OOD : = O NfA Cn * * 0_ �- C[1 •N NM as a) 00 a) c — m c c *CU 0 (t o) v, 0, * * �* F- *kF- *kF- - = a. c * m w. U U o N U Cl) C c aD c N U V U U U U m a) U N 9 m - = - v rn@codN 'in co rn- a) u) CD w CD co 0 co i a0 >>o a) c r co CCS y to Q c d m m O o- c O cn .c O c O c O c o Y Er) Q N `- c `- a) mOV aN0a) a) ma) 0ON OaO • fl. vi — Qma) O 0 N 05 Uc _0 Cli V '' a) y SD4 V = = = � = U Q C5. W cam OQQ.p 0 EL F- O .* F- o O 15 C7)— C.) Cn N * F- O a) N a) N a) N a) CO L a) * F- o * L c) 0 - < U -, U o 2Ce .E o.M « U -namn. mamamwm * UU : ci o w F- r-- r-- r- ti r r r >- o O O O rnco N F- N O N 0CCiN 5 a) o F- Co ao aD aD 0 Q TREE= 6-3/8"CNV ACTUATOR= BAKER C _ MGL G 36'@ 9380'&WV NOTES:WELL NGLE>70° 9458'*"* OKB.ELEV= 59.2' I I BF.ELEV= 37.01' KOP= 2900' , ' 2197' -I4-1/2"FES X NP,D=3.813" Max Angle= 94°@ 10658' Datum MD= 9165 = 2597' H9-5/8"HOWCO DV PKR Datum TVD= 8800'SS TOP OF r SCAB LNR - 2673' 2673' -I 9-5/8"X 7"BKR ZXP LIP,D=6.290" 2687' H9-5/8"X 7"BKR FLEX-LOC HY D HGR,D=6.310" 13-318"CSG,72#,L-80,D=12.347" - 2691' J 1 'e GAS LFT MAMIRES I. 40 ST MD IVO DEV TYPE VLV LATCH FORT DATE 7"SCAB LNR,26#,L-80 BTC-M, -I 8073' 401 n 4 3887 3847 25 KBG2 DOME BK 16 06/10/16 .0383 bpf,D=6.276' L 4 3 6393 6096 9 KBG2 SO BK 20 07/02/16 9-5/8"X 7 BOT LNR HGR,D=? H 8073' 2 7925 7625 0 KBG2 DRAY BK 0 06/06/03 1 8761 8461 2 KBG2 DMY BK 0 06/06/03 L9-5/8"CSG,47#,L-80 BUTT,D=8.681" H 8578' • ' I 8827' H4-1/2"HES X NP,D=3.813" Minimum ID = 2.37" @ 9096' Z X 8848' H7"X 4-1/2"BKR S-3PERM PKR,D=3.875" 45 FLO-GARD LNR TOP PKR 1 I- I 8871' H4-1/2"HES x NP,D=3.813" 1 ' 8892' -14-1/2"HES XN ice,ID=3.80"(mum 05/13/06) 8894' -j 7'BKR LNR TACK SLV,CI=5.250' TOP OF 4-1/2"LNR H 8894' 8902' H7"X 5"BKR ZXP LTP,D=4.440" I 14-1/2"TBG,12.6#,L-80,_0152 bpi,D=3.958" H 890W I $905' H4-1/2"MEG,ID=3.958" 8908' H7"X 5"BKR HMC LNR HGR,D=4.420" 7"LNR,29#,L-80 NSCC,.0371 bpf,D=6.184' -I -9040 j 8915' 1H5"X 4-1/2"X0,113=4.00 7'MLLOUT WINDOW(C-16A)9040'-9062' TOP OF 3-1/2"X 3-1/4"X 2-7/8"LNR -1 9104' L3=1/2"LNR 9.3#,L-80 SIL,.0087 bpf,D=2.992" H 9166' -145 FLOGARD LTP,ID=2.37"(07/22/14) 9104' -13.70"BOT DEPLOY SLV,D=3.00" 4-1/2'PKR WHIPSTOCK(07/12/14) -( 9261' W/RA TAG @ 9270' 9126' --I 3-1/2"OTIS X NP,ID=2.813" 4-1/2"LNR,12.6#,L-80 BT-M.0152 bpf,D=3.958" -I -9261 13-1/4"LNR,6.6#,L-80 TC11,.0079 bpf,ID=2.85-j- 10388' , 1 9156' H3-1/2-X 3-3/16"XO,D=2.786" li PgRFORATION SUMMARY ?l ► 4-1/2"MLLOUT WNDOW(C-16C)9261'-9270" REEF LOG:BKR RPM ON 05/11/14 1 1, ANGLE AT TOP PERF:91°@ 11130' Note:Refer to Production DB for historical perf data 10388' -13-3/16"X 2-7/8"XO,ID=2.377" SIZE SPF NYTBVAL Opn/Sgz DATE SCZ P /: 11250' H 2-7/8 PUP JONI w/RA TAG 2" 6 11130-11250 0 08/11/17 _ 11396' --{2-7/8 WFD CBP(08/10/17) 2" 6 11480-11510 C 04/23/16 .� 2" 6 11510-11530 C 04/17/16 `I ail 2" 6 11540-11570 C 04/17/16 2" 6 11570-11600 C 04/17/16 -_ 11842' -12-7/8 PUP JOINT w/RA TAG 2" 6 12050-12110 C 02/03/15 i, 11900" j--1-7/8 WFD CUP(04/16/16) I 2" 6 12130-12160 C 02/01/15 P 2" 6 12160-12190 C 01/30/15 illl owor 0pil PBTD_I--L12636' I 2" 6 12275- 12525 C 07/21/14 .1 6. TD --L___12674' I R, 2-7/8"LN6.5#,L-80 STL,.0058 bpf,D=2.441" H 12671' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/12/80 N18E ORIGINAL COMPLETION 04/25/16 JD/JMD SET CBP/ADERFS WELL C-16C 01125190 NIES RWO 04/26/16 JD/JMD ADPERF CORRECTION PERMIT No:"2131910 06/07/03 N2ES SIDETRACK(C-16A) 06/13/16 JGUJMD GLV C/O(06/10/16) API No: 50-029-20438-03 05/21/06 NORDIC 1 CTD(C-16B) 07/06/16 JMWJMD GLV C/O(07/02/16) SEC 19,T11N,R14E, 116'SNL&1218'WEL 07/23/14 NORDIC 1 CTD SIDETRACK(C-16C) 08/14/17 JDWJN D SET CIBFMADEFFS 02/04/15 PJC WELLHEAD CORRECTION(SQUID) BP Exploration(Alaska) • # Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday,July 03, 2016 5:58 AM To: AK, OPS GC3&PCC OSM;AK, OPS GC3 Facility OTL;AK, OPS GC3 Field OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM;Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS Well Pad CX;Glasheen, Brian P;Wallace, Chris D(DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; Sternicki, Oliver R;AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; Regg,James B (DOA) Subject: OPERABLE: Producer C-16C (PTD#2131910)Tubing Integrity Restored All, Producer C-16C(PTD#2131910) passed a TIFL post gas lift valve change out confirming two well barrier envelopes.The well is now reclassified as Operable. Please call with questions or concerns. Ryan Holt (Altonnote: Lee ui BP Alaska-Well Integrity Wells ScANtEO DEC 0 9 2016 Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, GWO SUPT Well Integrity t: Monday, June 27, 2016 7:14 PM To: OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad L-- AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Special Projects; AK, GWO SUPT Slickline; AK, R PB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Glasheen, Brl. P; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well In - , ity; AK, GWO Projects Well Integrity; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; AK, GWO S = Well Integrity; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: UNDER EVALUATION: Pro. . er C-16C(PTD #2131910) Sustained Inner Annulus Casing Pressure Over MOASP All, Producer C-16C(PTD#2131910)was reported to have hi:' IA pressure over MOASP on June 26th 2016.Sustained IA casing pressure was confirmed to be 2360 psi.A subsequent failed indicating a lack of two competent well barrier envelopes.The well is now classified as Under Evaluation and will •- epaired or secured within 28 days. Plan Forward: 1. Downhole Diagnostics:Warm TIFL 2. Well Integrity: Further diagnostics/intervention as needed Please call with any questions or concerns, 1 • S Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, June 27, 2016 7:14 PM To: AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL;AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Special Projects; AK, GWO SUPT Slickline; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Glasheen, Brian P; Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; AK, GWO SUPT Well Integrity; Regg, James B (DOA) Subject: UNDER EVALUATION: Producer C-16C (PTD #2131910) Sustained Inner Annulus Casing Pressure Over MOASP All, Producer C-16C (PTD#2131910)was reported to have high IA pressure over MOASP on June 26th 2016. Sustained IA casing pressure was confirmed to be 2360 psi. A subsequent TIFL failed indicating a lack of two competent well barrier envelopes.The well is now classified as Under Evaluation and will be repaired or secured within 28 days. Plan Forward: 1. Downhole Diagnostics: Warm TIFL 2. Well Integrity: Further diagnostics/ intervention as needed Please call with any questions or concerns, Ryan Holt (Alternate: Lee Grey) BP Well Integrity � JuN 2 8 20 lu girogbatztictirs, DEQ Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity oordinator Sent: Monday, August 24, 2015 12:29 PM To: AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility ; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A`;'Daniel Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK,RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Haffener, Jordan Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer Subject: OPERABLE: Producer C-16C (PTD #2131910) MIT-IA Passed All, 1 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMJN REPORT OF SUNDRY WELL OPERATIONS ` 1. Operations Performed Abandon ❑ Plug Perforations Q Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: 5(t- C I II f' ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 213-191 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20438-03-00 7. Property Designation(Lease Number): ADL 0028305 8. Well Name and Number: PBU C-16C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: GR/CCL PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: per Total Depth: measured 12574 feet Plugs measured 11900 feet R E C 'I V E IE true vertical 9013 feet Junk measured feet Effective Depth: measured 11900 feet Packer measured 8902 feet MAY 16 2016 true vertical 9009 feet Packer true vertical 8601.48 feet r AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 30-110 30-1 10 0 0 Surface 2660 13-3/8"72#L-80 28-2688 28-2687 4930 2670 Intermediate 8548 9-5/8"47#L-80 27-8575 27-8274 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11480-11510 feet 11510-11530 feet 11540-11570 feet 11570-11600 feet 12050-12080 feet 12080-12110 feet 12130-12160 feet 12160-12190 feet 12275-12525 feet True vertical depth: 9004-9005 feet feet 9005-9005 feet 9005-9005 feet 9005-9006 feet 9008-9009 feet 9009-901 1 feet 9012-9012 feet 9012-9013 feet 9013-9012 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 24-8905 24-8604 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED JUN 0 1 2016 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 316 25262 43 560 668 Subsequent to operation: Shut-In 0 160 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas El WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 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 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature )/ & Phone +1 907 564 4424 Date 5/12/16 Form 10-404 Revised 5/2015 1/71-- 5/2 3 1 1 RBDMS �,UMAY 1 7 2016 Submit Original Only • • aO O O O O o 0 O 0 0 M - ti CO N O m N .- O C CO m r O O .g N V L[) N r- U i (DocDocDoSo , o m rncwNoov m vor— o000 o0 00 O Nrm O m M O M O N ti r- O M O O O - N CO r� CO CO CO O) 6) CO Will 1 1 1 1 1 1 H N V q- M O) O CO N- N- O) O L O t M N N (O LO M W O N N N- CO M M O C O CO10 M O r- (O CO Mr- c QvO �) (NO CO m O o N - O N O N CD CO O O m O ✓• 0 Nr e0 Q — N-N- LU = U N Co ao a) a) M d Oo 2OoOs J J 00 OD J J J • y M N *k J J 0 c 3 44- Cfl U N N v o N O M M N L_ M O O O N M 00 W C CO CO t() O — In N = CO W N CO LC) O M N M J CC W — C 0 U W W U O W D O Z zcwwwwwwwm O DE— ZZZZZZD U (!) Z J J J J J J • • Packers and SSV's Attachment PBU C-16C SW Name Type MD TVD Depscription C-16C PACKER 2680.47 2679.98 7" Baker ZXP Top Packer C-16C TBG PACKER 8901.74 8601.48 4-1/2" Baker ZXP Packer • • a) � o •S `mea) 0. 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[Y o % c)� t_ x co 0 3 Q.S 0 c2Lo L - = - ( 0 DY ° o° - * D cpr4h -C NQ _ * D •`-'jti o2 xYN O 71 00 0 -000 u UH = 2 � oLL * UU - a.2 * OLL * U � 2 "3 a) �n .- * co CD co co O o 0 0 N N N N•-• O a) N O N • I • 1-3 . e E o .= g 2 0 — \ - -.6---_ / .kk / 7 � 2 / \ \ 2 0 % _ / % f / co -a % 0_22 eo z ± - 0 .E�% % o P $ m g R * $ b - U •c 5 P. 0 $ \ § 3� 12 E_ ® c � ° / \ ?/ / \\ d / � 0- $ d / / u) k ° / N $ f\ \ 0 ° \ •CO \ \ k c _ O o \ 7k % ƒ : / \\ $k o = 2 j m E c f E \ I E 03 O -\ $ D D O -0\ E ° \ \ o R o E O. \ .2 § \ : ± 2 \ t / .g / \ I- O U % E a k ƒ E / % /\ \ / \ S = / _f 2 2 / / / _Cl- z / % / k \ ƒ 3 > U = ® %2 a / » O = a b + @ a = ± ± c & - .@ ' L ® "- 0 n E 2 6 m m => cox ¥ ± - / i / r E o 1 co 6 7 2 2 R b + a176 I— ® T R ® o.§ > cr) \ o J 0 \ \ E i 5 \ \ \ CD / § -.(7; ms / R22 � $ \ � $ a /Ce 0 - \ . \ ƒ / ƒ : • f 2 0 03 c \ E / k / er \ / \ _r• / \ f / \ / \ / / } < \ w / ƒ \ E � � �� � / \ 2 0 2 - & 4 403 \ ® \ I " 0)b c o g O I � > « k = b c e » ƒ / \ � co (2 0)/ \ � / k Y ƒ y \ // E \ / / / / • § • z O / o \ o ? \ k ° ± -c / / / \ ? / Rizi t f 2 \ ? $ / a H R - e - m - G I O c D / o r : CD2 a t a (N o O m P » ± o : : < : OX0- E co I w t o 2 2 O & z 0 CO CO \ \ \ W oe » or m ± craw » & = / d \ Ir � n # � t # # VVIILFEAD= �K� • C -16C MAX DO NOTES: °ELL 9 8NGLE>70°a 9458'""" _.__.__ACTUA___.__ ._ , __59P._. OK&.eEV .7 BF.aEV= 37.01' KOP= 2900' , , 219T 4-1/2-FES X NP,D=3,813" Max Angle= 94° 10658' Llitum MD= 9166' — 2597' —9-5/8"HOV1CO DV PKR 1 Datum ND= 8800'SS '.. TOP OF 7"SCAB LNR 267$' 2673' H 9-5/8'X 7-BKR ZXP LTP,D=6.290' H ' 2687' —19-5/8'X 7"BKR FLEX-LOC HY D HGR,D=6.310'1 13-3/8'CSG,72#,L-80,D=12.347' —{ 2691' FA aGAS LET MANDRELS ST MD ND DEV TYPE VLV LATCH FORT [ATE 7'SCAB LNR,26#,L-80 BTC-M, — 8073' • 4 3887 3847 25 KBG2 DMV BK 0 08/23/15 0383 bpi,D=6.276" I 3 639:.1 6096 9 KFI(7 OW BK 0 08/23/15 I9-5/8'X 7'BOT LNR HGR,D=7 I— 8073' L 2 7925 7625 0 KBG2 DMY BK 0 06/06/03 1 8761 8461 2 KBG2 DMY BK 0 06/06/03 {9-5/8'CSG,47#,L-80 BUTT,D=8.681" — 8578' I .. ,----i 8827' -4-12"HES X NP,D=3.813' Minimum ID = 2.37" @ 9096' g X 8848' —7"X 4-12"BKR S-3 F M PKR,D=3.875' 45 FL©-CARD LNR TOP PKR 1 r-1 8871' I--4-1/2'FAX NP,D=3.813' I- 8892' —4-1/2'HES XN NP,D=3.80'(MLLE)05/13/06) /TOP OF 4-1l2'LNR 8894• } EBD 8894' J—7'BKR LNR TACK SLV, =5.250' 8902' H7'X 5"BKR ZXP LTP,D=4,440' 4-12'TBG,12.6#,L-80,.0152 bpf,D=3.958' H 8905' 1 8905' 4-1/2'WLEG,D=3.958' 8908' I—7'X 5'BKR MD C LNR HGR, =4.420" 7'LNR,29#,L-80 NSCC,.0371 bpf,I)=6.184' I—I —9040 I— f H8915' —5'X 4-1/2"XO,D=4.00 7'MLLOUT WIDOW(C-16A)9040'-9082' TOP OF 3-12"X 3-1/4"X 2-7/8"LNR — 9104' - 9096' —45 FLOGARD LTP,D=2.37'(07/22/14) 3-12'LNR 9.3#,L-80 STL,.0087 bpf,D=2.992" — 9156' 9104' —3.70'BOT DEPLOY SLV,D=3.00' 4-1/2'PKR WFIPSTOCK(07/12/14) — 9261' to to R 9126' —3-1/2'0715 X NP,D=2.813" W/RA TAG @ 9270' 4. • I4-12'LNR, 12.6#,L-80 BT-M,.0152 bpf,D=3.958' — —9261 �" 9166' —3-12'X3-3/16"XO,D=2,786' [3-1/4'LNR,8.6#,L-80 TCI 1,.0079 bpi,D=2.85" —I 10388' 1 4' 4-1/2'FALLOUT WINDOW(C-16C)9261'-9270` PERFORATION SUNWIRY REQ LOG:BFCR REM ON 05/11/14 tot VI i ANGLE AT TOP PERE:89°@ 11480' 10388' H3 3/16'X 2-7/8'XO,D=2.37r Note:Refer to Roduction DB for historical perf data P SIZE SPF INT /AL Opn/Sgz DATE SQZ - 11250' —�2-7/8 RJPJOMw/RA TAG I 7 ? 2" 6 .11480- 11510 0 '0423/16 0 6 11510- 11530 0 04/17/16 r 2" 2' 6 11540- 11570 0 04/17/16 P 1 I 11842' —I 2-7/8 RP JONT w/RA TAG 2' 6 11570- 11600 0 04/17/16 ( = F� 2' 6 12050-12110 C 02/03/15 11900' 2-78 VVFD CEP(04/16/16) 2' 6 12130- 12160 C 02/01/15 m 2' 6 12160- 12190 C 01/30/15 2' _ 6 12275- 12525 C 07/21/14 rA.4 F 'BTD 12535' 2-7/8'LNR,6.5#,L-80 STL,.0058 bpf,D=2.441' 12571' TO 12574' DATE REV BY COAUITS ATE REV BY COMMENTS PRUDHOEBAY WI- 06/12/80 NT06/12/80 N18E ORIGINAL COMPLETION 04/06/15 JMl~GLV GO(04/02/15) WELL: C-16C 01/25/90 N1ES RiNO 09/01/15 JMC,GLV GO(08/23/15) PERMIT No:`2131910 06/07/03 N2E3 SIDETRACK(C-16A) 0425/16 JCYJMD SET CtBPADEFFS AR No: 50-029-20438-03 05/21/06 NDRGC 1 CTD(C-16B) 0426/16 JD/JMD ADPERF CORRECTION SEC 19,T11N,R14E 116'SNL&1218'WEI 07/23/14NDR IC 1CTDSIDETRACK(C-16C) 02/04/15 PJC WELLHEAD CORRECTION(SQUID) _ BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, April 05, 2015 6:52 AM To: AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS Well Pad CX; Wallace, Chris D (DOA); Haffener,Jordan Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA) Subject: OPERABLE: Producer C-16C (PTD#2131910) Passing MIT-T and CMIT T x IA Attachments: image001jpg; image002.png; C-16C Wellbore Schematic.pdf All, Producer C-16C(PTD#2131910) passed a MIT-T and a CMIT T x IA on 04/04/2014 following gas lift valve work. The passing test confirms two competent barriers in the well. The well is reclassified as Operable. • Well status is Operable • Annuli are fluid packed • A SSSV is not needed Please use caution while placing well on production due to fluid packed annuli and the potential for annular fluid expansion. Thank you, Kevin Parks IAlte,nate Lau,in (lune, BP Alaska-Well Integrity Coordinator G'i/V Global WellsOrganization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Tuesday, March 24, 2015 3:25 PM To: AK, OPS GC3 Facility OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Haffener, Jordan; 'chris.wallace@alaska.gov'; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Producer C-16C (PTD #2131910) IAP exceeded MOASP All, 1 Producer C-16C (PTD#2131910) inner annulus exceeded MOASP on March 22, 2015 with T/I/O= 2380/2320/400 psi.A subsequently performed TIFL failed, indicating a potential lack of competent barriers downhole.At this time,the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Slickline: Set Tubing Tail Plug 2. Fullbore: Perform MIT-T and CMIT-TxIA 3. WIE: Additional diagnostics as needed A copy of the wellbore schematic and TIO plot have been included for reference. Please call with any questions. Thank you, Laurie Climer (alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator GWGtow I Wells Organization WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 2 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, March 24, 2015 3:25 PM To: AK, OPS GC3 Facility OIL; AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers; AK, OPS Well Pad CX; Haffener, Jordan;Wallace, Chris D (DOA); Regg,James B (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep Subject: UNDER EVALUATION: Producer C-16C (PTD#2131910)IAP exceeded MOASP Attachments: image001 jpg; Producer C-16C TIO Plot 03-24-15.docx; C-16C Wellbore Schematic.pdf All, Producer C-16C(PTD#2131910) inner annulus exceeded MOASP on March 22, 2015 with T/I/0= 2380/2320/400 psi.A subsequently performed TIFL failed, indicating a potential lack of competent barriers downhole.At this time,the well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Slickline: Set Tubing Tail Plug 2. Fullbore: Perform MIT-T and CMIT-TxIA SCANNED MAR 2 5 2015 3. WIE: Additional diagnostics as needed A copy of the wellbore schematic and TIO plot have been included for reference. Please call with any questions. Thank you, Laurie Climer (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GWG. as 4'de Or{ariimt onsn WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 Producer C-16C(PTD#2131910) TIO Plot 24 Mar 2015 Well:C-16 4.000 — — 3000 t Tbg —U—IA 2.000- --A—OA OOA --•—•000A 1.000 On rbi 1224/14 12/31/14 01/07/15 01/1415 01/21/15 01/28115 02/0415 :2 1115 02/1815 02/25/15 03/04/15 03/1115 03/18715 TREE= , ' 6-3/a"CNV WELLHEAD= FMC C-16 C SA_ .'NOTES:WELL ANGLE>70°@ 9458'"' ACTUATOR= BAKER C MAX DOGLEG:36°@ 9380"" OKB.ELEV= 59.2 I I ' BF. ELEV= - 37.01' KOP= 2900' I 219T H4-1/2'HES X NP,ID=3.813" Max Angle= 94'@ 10658' Datum MD= 9166' - r 2597' -19-5/8"HOWCO DV PKR Datum TVD= 8800'SS 2673' H9-5/8"X 7"BKR ZXP LTP,D=6.290" TOP OF 7"SCAB LNR -{ 2673' 4 2687' -19-5/8'X 7"BKR FLEX-LOC HY D HGR,D=6.310'1 13-3/8"CSG,72#,L-80,D=12.347" -{ 2691' v . , GAS UFT MANDRELS 7.. ST MD I V I: DEV TYPE VLV LATCH FORT DATE 7'SCAB LNR,26#,L-80 BTG-M, - 8073' 4 3887 3847 25 KBG2 DOME BK 16 08/05/14 .0383 bpf,D=6.276" 3 6393 6096 9 KBG2 SO BK 20 11124/14 9-5/8"X 7"BOT LNR HGR,D=? H 8073' 2 7925 7625 0 KBG2 DMY BK 0 06/06/03 . 1 8761 8461 2 KBG2 DMY BK 0 06/06/03 9-5/8"CSG,47#,L-80 BUTT,D=8.681" -I 8578' ' 8827' H4-1,2"HES X NP,D=3.813" Minimum ID = 2.37" @ 9096' S N,. 8848'_1-17"X 4-1/2"BKR S-3 PERM PKR,D=3.875' 45 FLO-GARD LNR TOP PKR 8871' 1a-1/2'HES XNIP,D=3.813" ' 8892' H4-1/2"HES XN NP,D=3.80'(MILLED 05/13/06) 8894' 7'BKR LNR TIEBACK SLV,ID=5.250" TOP OF4-1/2"LNR -1 8894' 8902' -17"X 5"BKR ZXP LIP,D=4.440" 4-112"TBG,12.6#,L-80,.0152 bpf,ID=3.958' H 8905' 4\ I\ 8905' �4-1/2"WLEG,D=3.958" 8908. 7-f'X 5"BKR HMC LNR HGR,D=4.420" 7"LNR,29#,L-80 NSCC,.0371 bpf,D=6.184' -1 -9040 8915' -5"X 4-112"XO,D=4.00 7'MI.LOUT WINDOW(C-16A)9040'-9062' :. :. 9096' -I45 FLOGARD LTP,ID=2.37"(07/22/14) TOP OF 3-1/2"X 3-1/4"X 2-7/8"LNR -{ 9104' 9104' ---13.70"BOT DEPLOY SLV,D=3.00" 3-1/2'LNR,9.3#,L-80 STL, .0087 bpf,D=2.992" -1 9156' I! 4-1/2"PKR WHIPSTOCK(07/12/14) - 9261' 9126' -13-1J2"OTIS X NP,D=2.813" WI RA TAG @ 9270' 9156' -13-1/2"X 3-3/16"XO,ID=2.786" 4-1/2"LNR, 12.6#,L-80 BT-M,.0152 bpf,D=3.958" -f -9261 PERFORATION SUMMARY 4-1/2'MILLOUT WINDOW(C-16C)9261'-9270" FIEF LOG:BKR RPM ON 05/11/14 ANGLE AT TOP PUT::89'@ 12050' 10388' H3-3116"X 2-7/8'XO,D=2.377' Note:Refer to Production DB for historical pert data 1i SIZE SPF INTERVAL Opn/Sgz DATE SOZ 2" 6 12050- 12110 0 02/03/15 11250' 12-7/8 PUP JOINT w/RA TAG 2" 6 12130- 12160 0 02/01/15 2" 6 12160- 12190 0 01/30/15 2" 6 12275- 12525 0 07/21/14 11842' -12-7/8 PUP JOINT w/RA TAG I �1 I" HI 3-114"LNR,6.6#, L-80 TC11,.0079 bpi,ID=2.85" H 10388' ( ,i PBTD -I 12535' 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,ID=2.441" - 12571' TD H 12574' DATE REV BY COMNE NETS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/12/80 N18E ORIGINAL COMPLETION 08/10/14 CJN/PJC GLV CJO(08/05/14) WELL: C-16C 01/25/90 N1ES RWO 08/12/14 TR/PJC TD(7/22/14 DRECTIONAL SURVEY) PERMIT No:'2131910 06/07/03 N2ES SIDETRACK(C-16A) 12/12/14 WRP/JMD GLV C/O(11/24/14) AR No: 50-029-20438-03 05121/06 NORDIC 1 CTD(C-16B) 02/04/15 ATO/PJC ADPB2FS(02/01-02/03/15) SEC 19,T11 N,R14E, 116'SM..&1218'WEL 07/23/14 NORDIC 1 CTD SIDETRACK(C-16C) 02/04/15 PJC WELLHEAD CORRECTION(SOUR) 08/01/14 PJC ADD LTP&MC LNR UPDATES BP Exploration(Alaska) STATE OF ALASKA RECEIVED • AL...iKA OIL AND GAS CONSERVATION COM, JON MAR 0 2 2015 • REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon CIRepair Well ❑ Plug Perforations El Perforate El Other CIIC)GCC Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waived] Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work 5.Permit to Drill Number BP Exploration(Alaska),Inc Name Development 0 Exploratory 213-191-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service 6.API Number Anchorage,AK 99519-6612 50-029-20438-03-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028305 PBU C-16C 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12574 feet Plugs measured None feet true vertical 9013 08 feet Junk measured None feet Effective Depth measured 12535 feet Packer measured See Attachment feet true vertical 9012 4 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 28 87-108 87 28 87-108 87 0 0 Surface 2659 78 13-3/8"72#L-80 28 37-2688 15 28 37-2687 65 4930 2670 Intermediate 8547 97 9-5/8"47#L-80 26 59-8574 56 26.59-8274 42 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12050-12080 feet 12080-12110 feet 12130-12160 feet 12160-12190 feet 12275-12525 feet True Vertical depth 9008 14-9009.47 feet 9009 47-9011 2 feet 9011 91 -9012 42 feet 9012 42-9012 67 feet 9013 16-9012 22 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#L-80 24.48-8904 57 24 48-8604 31 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary t , ,, Intervals treated(measured) Sri ONE° \!' !' ) b Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure - Prior to well operation 291 9970 29 510 273 Subsequent to operation Well Shut-In 1100 20 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development l] Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil E] Gas ❑ WDSPL ❑ GSTOR El WINJ ❑ WAG ❑ GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garrv.Catrona,BP.Com Printed Name Garry Catron Title PDC PE Signature A6441 Phone 564-4424 Date 3/2/2015 vr- 3/" /[5 RBDMS1k MAR - 5 2015 #"/s Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028305 SW Name Type MD TVD Depscription C-16C PACKER 2680.47 2679.98 7" Baker ZXP Top Packer C-16C PACKER 8847.69 8547.44 4-1/2" Baker S-3 Hydro Set Packer C-16C PACKER 8901.74 8601.48 4-1/2" Baker ZXP Packer (u a. OO_ oOM ° Soo S. in :\131 CD toI- NI- V ▪ O� CD (h � N• CO N CO � MCO m CO 'Ct CO N N (D N CO M to co O I- co o CD (h • ch O) t7 M (3) Cr) N- O Ch M O r- 00 N f. f- (3) CO O O CD CO CO CO CO CO C3) O) N CO co co N.. O) M 01.1- O 00 O N O C7 O) M NI- cd r O 00 to O 00 Ni (NINCON- tncoCOONN N N- CO CO O) C CO r co LO O 000 000 0) (3) N kl N CO t C.) 11) 2 .i•+ O M ch (h co °O rnrl� l- rnotnaoc N N CD o 00 Q N N N N000OO (3) � C O . . 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Y NOTES:WELL ANGLE>70'@ 9458'*** ACTUATOR= BAKER C I ' MAX DOGLEG:36'@ 9380'*** EL OKB. EV= 59.7 BF.ELEV= 37.01' KOP= 2900' ' ' - 2197' -j4-1/2"FES X NP,ID=3.813" 1 Max Angle= 94°@ 10658' Datum MD= 9166' 2597' -1 9-5/8"HOVVCO DV PKR Datum TVD 8800'SS TOP OF 7"SCA BLNR - 2673' _ 2673' H9-5/8"X 7"BKR ZXP LW,D=6.290' is 2687' -19-5/8"X 7"BKR FLEX-LOC HY D HGR,D=6.310' 13-3/8"CSG,72#,L-80,D=12.347' H 2691' FA GAS UFT MANDRELS Ir. ST M) TVD DEV TYPE VLV LATCH FORT DATE r SCAB LNR,26#,L-80 BTC-M, H 8073' I. 4 3887 3847 25 KBG2 DOME BK 16 08/05/14 .11 .0383 bpf,D=6.276" , 3 6393 6096 9 KBG2 SO BK 20 11/24/14 9-5/8"X 7"BOT LNR HGR,D=? H 8073' L 2 7925 7625 0 KBG2 DMY BK 0 06/06/03 . I, 1 8761 8461 2 KBG2 DMY BK 0 06/06/03 9-5/8"CSG,47#,L-80 BUTT,D=8.681" -I 8578' ' , 8827' H4-12"FSS X NP.D=3.813' Minimum ID = 2.37" @ 9096' g X 8848' -j 7"x 4-12"BKR S-3 PERM PKR D=3.875" 45 FLO-GARD LNR TOP PKR 1 rI 8871' -j4-12"FES XNP,D=3.813" ij8892' H4-1/2"HES XN NP.D=3.80"(MLLE)05/13/06) 8894' 7'BKR LNR TIEBACK SLV,D=5.250" LOP OF 4-1/2"LNR -i_ 8894' j 8902' 1-{r X 5"BKR ZXP LTP,D=4.440" 4-12"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 8905' 8905' -I4-1/7 WLEG,D=3.958" \ 8908' -17"X 5"BKR FMC LNR HGR,D=4.420'1 7'LNR 29#,L-80 NSCC,.0371 bpf,D=6.184" -{ -9040 891i]-15"X 4-1/2"XO,D=4.00 7'MLLOIJT WINDOW(C-16A)9040'-9062' 9096' .-145 FLOGARD LIP,D=2.37"(07/22/14) TOP OF 3-12"X 3-1/4"X 2-7/8"LNR H 9104' 3-12'LNR 9.3#,L-80 STL,.0087 bpf,0=2.992" 9156' 9104' -13.70"BOT DEPLOY SLV,ID=3.00" b. 4-1/2'PKR WHPSTOCK(07/12/14) - 9261' 9126' -I3-12'OTIS X NP,ID=2.813' W/RA TAG @ 9270' 9156' H3-1/2"X 3-3/16"XO,13=2.786" 4-1/2"LNR,12.6#,L-80 BT-M,.0152 bpf,D=3.958" -1 -9261 ►5 PERFORATION SUMMARY R 4 1/2"MLLOUT YVPDOW(C-16C)9261'-9270 REF LOG:BKR RPM ON 05/11/14bq ANGLE AT TOP PERF:89'@ 12050' I 10388' h 3-3/16'X 2-7/8"XO,D=2.377' Note:Refer to Production DB for historical pert data !� SIZE SW INTERVAL Opn/Sqz DATE SQZ r 2" 6 12050-12110 0 02/03/15 4 11250' H 2-7/8 RJP JONT w/RA TAG 2" 6 12130- 12160 0 02/01/15 r 2" 6 12160- 12190 0 01/30/15 r 2" 6 12275- 12525 O 0721/14 r 11842' -2-7/8 PUP JOINT w/RA TAG r r 13-1/4"LNR,6.6#,L-80 TC11,.0079 bpf,ID=2.85" -1 10388' 1�'tl FWD --I 12535' 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,ID=2.441" - 12571' A4 TD 12574' F.V. DTE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/12/80 NI8E ORIGINAL COMPLETION 08/10/14 CJNI PJC GLV GO(08/05/14) Wa.L: C-16C 01/25/90 N1ES RWO 08/12/14 TR/PJC ID(7/22/14 DIRECTIONAL SURVEY) F]RMTTNo:"2131910 06/07/03 N2E5 SIDETRACK(C-16A) 12/12/14 WRP/JMD GLV GO(1124/14) API No: 50-029-20438-03 0521/06NORI]C 1 CTD(C-16B) 02/04/15 ATO/PJC ADPERFS(02/01-02/03/15) SEC 19,T11N,R14E, 116'SNL&1218'VVL 0723/14pIOREIC 1 CTD SIDETRACK(C-16C) '02/04/15 PJC WELLIEAD CORRECTION(SOLID) 08/01/14 PJC ADD LIP 8 MISC LNR U'DATES BP Exploration(Alaska)
