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Home My WebLink About218-122By Grace Christianson at 2:28 pm, Mar 25, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.03.25 13:56:48 - 08'00' Sean McLaughlin (4311) 325-170 JJL 3/26/25 10-407 DSR-4/1/28SFD 4/4/2025*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.07 10:06:21 -08'00'04/07/25 RBDMS JSB 040825 To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: March 25, 2025 Re:J-07B Sundry Request Sundry approval is requested to set a whipstock and mill a window in the J-07B wellbore as part of the drilling and completion of the proposed J-07C CTD lateral. Proposed plan: Prior to drilling activities, screening will be conducted to drift for whipstock, caliper (if needed) and MIT. See J-07C permit request for complete details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. The rig will set a 3-1/4" NS packer whipstock. A single string 2.74" window + 10' of formation will be milled. The well will kick off drilling in Ivishak Zone 2. The lateral will continue in Zones 3 and 2 to TD. The proposed sidetrack will be completed with a 2-3/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in April 15, 2025) x Reference J-07B permit submitted in concert with this request for full details. 1. Slickline : Dummy WS drift, Set plug, MIT-IA, MIT-T, Pull Plug 2. Other : CTD Tree Prep and Pad Work Rig Work: (Estimated to start in May 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2335 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Set 3-1/4" NS Packer Wedge @ 11,240' MD @ 70° RHOS. Mill 2.74” Window. 3. Drill build section: 3.25" OH, ~321' (22 deg DLS planned). 4. Drill production lateral: 3.25" OH, ~2059' (12 deg DLS planned). Swap to KWF for liner. 5. Run 2-3/8” 13Cr solid liner. 6. Pump primary cement job: 20 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Coil : Liner lap test, CBL, RPM, 30' ADP 3. Slickline : LGLVs, LTP Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 This,p yppg(p completion will completely isolate and abandon the parent Prudhoe Pool perfs Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2.0" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 2-3/8" Pipe / Slip CL 2.0" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2.0" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2.0" Pipe/Slips 2-3/8" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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 J-07B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 218-122 50-029-20241-02-00 12321 Surface Intermediate Intermediate Liner Liner 8918 2642 8705 11031 211 1633 11600 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8996 41 - 2683 40 - 8745 38 - 11069 10937 - 11148 10688 - 12321 41 - 2683 40 - 7261 38 - 8964 8936 - 8964 8839 - 8918 12282 2670 4760 5410 7500 10530 11600 4930 6870 7240 8430 10160 11040 - 12272 4-1/2" 12.6# 13cr / L80 36 - 10947 8962 - 8927 Conductor 80 20" x 30" 41 - 121 41 - 121 4-12" Baker S3 Packer 10889, 8917 10663, 10889 8829, 8917 Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 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 0028281 36 - 8940 N/A N/A 23 24 1987 6924 3232 3374 1083 1150 175 280 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S3 Packer 10663, 8829 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 No SSSV Installed By Grace Christianson at 11:22 am, Nov 21, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.11.21 04:48:07 - 09'00' Torin Roschinger (4662) DSR-11/21/24 RBDMS JSB 112724 WCB 2-7-2025 ACTIVITY DATE SUMMARY 10/31/2024 T/I/O= 1975/1975/450 Assist S-Line with Pump Down *****Jobe Postponed for wind**** SL in control of well upon departure 10/31/2024 ***WELL S/I UPON ARRIVAL*** (perforating) DRIFTED W/ 2.53" CENT, 1.75" SAMPLE BAILER TO DEVIATION @ 10,969' SLM (unable to pumpdown due to fluids unavailable) ***CONT WSR ON 11/1/24*** 11/1/2024 ***LAYDOWN HES 759 SLICKLINE UNIT DUE TO WINDS*** 11/11/2024 ***WELL S/I UPON ARRIVAL*** (perforating) DRIFTED LINER W/ 2.65" CENT TO DEVIATION @ 10,959' SLM, PUMP TOOLS DOWN TO 11,600' SLM.(drifted @ 5bpm) ATTEMPT TO DRIFT LINER W/ 11' x 2" DUMMY GUNS(2.16"rings), 33' x 2" DUMMY GUNS(2.29"rings) TOOLS DEVIATED OUT @ 11,026' SLM, UNABLE TO PUMP DOWN TBG.(tbg locked up) THUNDERBIRD PUMPED 180 BBLS OF CRUDE DOWN TBG TO ASSIST. ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** 11/11/2024 T/I/O 1950/1850/650 Temp=S/I (TFS unit 1 assist S-Line with Pump down) Pumped 180 BBLS of crude to assist SL in reaching target depth. SL in control of well upon departure. Final WHPS=1000/1700/710 11/14/2024 ***WELL S/I ON ARRIVAL*** (HOIST TRACTOR/SET PLUG / ADPERF) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH SET 2.875" NS CIBP AT 11600', CCL TO MID ELEMENT=14.9' CCL STOP DEPTH= 11585.1'. TAG AFTER SET PERFORATE INTERVAL 11080'-11100' WITH 2'' HUNTING TITAN RTG 6spf 60 DEG PHASE CCL TO TOP SHOT=7.6' CCL STOP DEPTH= 11072.4'. CONFIRM SHOTS FIRED. PLUG AND GUN CORRELATE TO HES COIL FLAG LOG DATED 07-APR-2019 LAID DOWN LUBRICATOR FOR THE NIGHT ***WSR CONTINUE ON 11/15/2024*** 11/15/2024 ***WSR CONTINUE FROM11/14/2024***(HOIST TRACTOR/ADPERF) PT PCE 300 PSI LOW /3000 PSI HIGH PERFORATE INTERVAL 11060'-11080' WITH 2'' HUNTING TITAN RTG 6spf 60 DEG PHASE CCL TO TOP SHOT=7.6' CCL STOP DEPTH= 11052.4'. CONFIRM SHOTS FIRED. PERFORATE INTERVAL 11040'-11060' WITH 2'' HUNTING TITAN RTG 6spf 60 DEG PHASE CCL TO TOP SHOT=7.6' CCL STOP DEPTH= 11032.4'. CONFIRM SHOTS FIRED. ALL GUN RUNS CORRELATE TO HES COIL FLAG LOG DATED 07-APR-2019 JOB COMPLETE ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU J-07B PERFORATE INTERVAL 11060'-11080' SET 2.875" NS CIBP AT 11600', PERFORATE INTERVAL 11040'-11060' PERFORATE INTERVAL 11080'-11100' 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 J-07B Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 218-122 50-029-20241-02-00 12321 Surface Intermediate Intermediate Liner Liner 8918 2642 8705 11031 211 1633 12282 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8926 41 - 2683 40 - 8745 38 - 11069 10937 - 11148 10688 - 12321 41 - 2683 40 - 7261 38 - 8964 8936 - 8964 8839 - 8918 12282 2670 4760 5410 7500 10530 None 4930 6870 7240 8430 10160 12210 - 12272 4-1/2" 12.6# 13cr / L80 36 - 10947 8941 - 8927 Conductor 80 20" x 30" 41 - 121 41 - 121 4-12" Baker S3 Packer 10889, 8917 10663, 10889 8829, 8917 Aras Worthington for Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 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 0028281 36 - 8940 N/A N/A 23 Well Test not Available 1987 3232 1083 1150 175 200 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S3 Packer 10663, 8829 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:59 pm, Jun 06, 2024 Digitally signed by Aras Worthington (4643) DN: cn=Aras Worthington (4643) Date: 2024.06.06 14:19:17 - 08'00' Aras Worthington (4643) WCB 8-29-2024 DSR-6/7/24 RBDMS JSB 061124 ACTIVITYDATE SUMMARY 5/31/2024 LRS CTU #1, 1.50" Blue Coil. Job Objective: Mill CIBP, 62' Adperf MIRU and make up 2-1/8" Yellowjacket milling BHA with 2.63" venturi & 2.75" burn shoe. RIH while bullheading the well w/ 167 bbls (Well Vol 175 bbls) of 1% KCL w/ Safelube. Initial pressure @ 4 bpm 1510. Final pressure 1500 psi @ 1 bpm (formation tight). SD pump and continue RIH. Dry tag CIBP at 12232' and paint coil flag at 12226.8' CTM. Mill plug and push to the 3-1/4 x 2-7/8" XO at 12282'. POOH. Freeze protect the well to 2500' w/ 38 bbls of diesel. Recovered CIBP slips, body lock ring, and lots of metal. Pics in the well pictures folder. RD and travel to MPI-06. 6/1/2024 LRS CTU #1, 1.50" Blue Coil. Job Objective: Mill CIBP, 62' Adperf MIRU and make up 1-11/16" Yellowjacket MHA. RIH with 2.00" x 31' HES Millennium, 6 SPF, 60 degree phase gun. Perforate 12241' - 12272'. Start POOH. ***Cont on 6/2/24*** 6/2/2024 LRS CTU #1, 1.50" Blue Coil. Job Objective: Mill CIBP, 62' Adperf Continue POOH with 2.00" x 32' HES perf gun (all shots fired in scallop, 1/2" ball recovered). PT MHA ~ 3500 psi. RBIH with second 2.00" x 31' HES Millennium, 6 SPF, 60 degree phase gun. Perforate 12,210'-12241' and POOH. At surface all shots fired in scallop and 1/2'' ball recovered. RDMO travel to L2-29A. ***Job Complete*** Daily Report of Well Operations PBU J-07B yg Mill plug and push to the 3-1/4 x 2-7/8" XO at 12282'. POOH Perforate 12,210'-12241' j Perforate 12241' - 12272' Milled CIBP fish and adperfs are correctly shown on new WBS, below. -WCB Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:218-122 6.50-029-20241-02-00 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 12321 12230 8936 10663, 10889 None 12230 8829, 8917 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" x 30" 41 - 121 41 - 121 Surface 2642 13-3/8" 41 - 2683 41 - 2683 4930 2670 Intermediate 8705 9-5/8" 40 - 8745 40 - 7261 6870 4760 Intermediate 11031 7" 38 - 11069 38 - 8964 7240 5410 Production 211 4-1/2" 10937 - 11148 8936 - 8964 8430 7500 Perforation Depth: Measured depth: 12210 - 12250 feet True vertical depth:8941 - 8932 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6#13cr / L80 36 -10947 36 - 8940 10663 8829Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Packer Liner 1633 10688 - 12321 8839 - 8918 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1811186400034 32861996 1052 1857 17 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: Brian Glasheen brian.glasheen@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-5277 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 measured8918 Sundry Number or N/A if C.O. Exempt: N/A 4-1/2" Baker S-3 Packer 10889 8917 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Set CIBP 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 Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028281 PBU J-07B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3-1/2" x 3-3/16" x 2-7/8" 169 By Samantha Carlisle at 11:52 am, Oct 22, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.10.22 11:43:37 - 08'00' Stan Golis SFD 10/22/2020RBDMS HEW 11/10/2020 DSR-10/22/2020MGR22OCT2020 ACTIVITY DATE SUMMARY 10/16/2020 CTU #9 - 1.75" Coil x 0.156" wt. Job Objective: Set CIBP MIRU CTU. RIH w/ Memory gamma/CCL 2.65" drift nozzle. Tag bottom at 12252 ctm. Perform tie in log, flag coil at 12200 ctm. At surface noted the tree had subsided. MU NS 3-1/4" CIBP. Pumped 100 bbls of 1%KCL down the tubing followed by 20 bbls of 60/40 methanol. RIH and tie in to flag and set CIBP at 12230'. POOH and FP well as per Pad Op. Begin Rig Down ...Job in Progress....**CP 10/17/2020 CTU #9 - 1.75" Coil x 0.156" wt. Job Objective: Set CIBP Complete Rig Down of CTU. ***Job Complete*** Daily Report of Well Operations PBU J-07B Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:218-122 6.50-029-20241-02-00 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 12321 12283 8925 10663, 10889 none none 8829, 8917 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" x 30" 41 - 121 41 - 121 Surface 2642 13-3/8" 41 - 2683 41 - 2683 4930 2670 Intermediate 8705 9-5/8" 40 - 8745 40 - 7261 6870 4760 Intermediate 11031 7" 38 - 11069 38 - 8964 7240 5410 Production 211 4-1/2" 10937 - 11148 8936 - 8964 8430 7500 Perforation Depth: Measured depth: 12210 - 12250 feet True vertical depth:8941 - 8932 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13cr / L80 36 - 10947 36 - 8940 10663 8829Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S3 Packer Liner 1633 10688 - 12321 8839 - 8918 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2.5 gallons of 14# SqueezeCrete to fill 9-5/8" x 13-3/8" void to surface. Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 18911353839139 20411628 1353 1657 41 176 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: Aras Worthington aras.worthington@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-4763 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations 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 measured8918 Sundry Number or N/A if C.O. Exempt: 4-1/2" Baker S3 Packer 10889 8917 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Conductor Top Job Operations shutdown Change Approved Program 5 9-5/8" x 13-3/8" annulus at Surface Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028281 PBU J-07B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 3-1/2" x 3-3/16" x 2-7/8" 320-294 No SSSV Installed By Samantha Carlisle at 2:32 pm, Aug 26, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.26 14:01:40 - 08'00' Stan Golis MGR02SEP2020 DSR-8/27/2020 SFD 9/1/2020RBDMS HEW 8/27/2020 ACTIVITY DATE SUMMARY 7/18/2020 T/I/O = SSV/490/20. Temp = SI. Concuctor top job. ALP = 1990 psi, SI @ CV. OA cemented to surface. Bubbling in 9-5/8"x13-3/8" from 5 - 12 o'clock position - 20% LELs @ 1" above, 0% LELs @ 1' above. Bled OAP from 20 psi to 0 psi in 1 minute (all gas), held open bleed. Vacced out water from cellar and conductor. Used 2.5 gallons of 14# Squeez Crete to fill 9-5/8"x13-3/8" void to surface. Heater installed in well house, tree cap bled to 0 psi. Bubbling unchanged post cement top job. Rear door left ajar. Final WHPs = SSV/490/0+. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:15 7/22/2020 T/I/O = SSV/500/10. Temp = SI. LEL's (post top job). ALP = 1990 psi, SI @ CV. No bubbling detected. Cement set up in conductor. LEL = 0% inside flute & throughout cellar and wellhouse. OAP increased 10 psi from 7/18/20. SV = C. WV, SSV, MV = O. IA, OA, OOA = OTG. 01:30 7/24/2020 T/I/O = SSV/500/10. Temp = SI. Monitor bubbling/LELs (post conductor top job). ALP = 1980 psi, SI @ CV. No fluid or bubbling in cellar or conductor. 0% LELs 1" or 1' above conductor and throughout cellar. IAP and OAP unchanged since 7/22/20. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:45 7/24/2020 T/I/O = SSV/500/10. Temp = SI. WHPs (Eval conductor cement top). AL SI @ casing valve (2000 psi). No change in the WHPs overnight. Sporatic bubbling @ the 0430 position (Over Limit LELs 1" above cement top, 13.6% LELs 1' above cement top, 1" out from conductor.). No other bubbling or LELs in the wellhouse. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:45. 7/25/2020 T/I/O = SSV/500/10. Temp = SI. WHPs (Eval conductor top job). AL SI @ casing valve = 1990 psi. No abnormal readings 1" above conductor top or anywhere else in the wellhouse. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 7/26/2020 T/I/O = SSV/500/10. Temp = SI. WHPs (Eval conductor cement). AL SI @ casing valve (1980 psi). No abnormal readings 1" above the new cement top or anywhere else in the cellar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:10 7/27/2020 T/I/O = SSV/500/10. Temp = SI. WHPs (Eval conductor cement). ALP = 1980 psi, AL SI @ casing valve. No abnormal readings 1" above the new cement top or anywhere else in the cellar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:15 7/28/2020 T/I/O = SSV/500/10. Temp = SI. WHPs (Eval conductor cement). ALP = 1980 psi, AL SI @ casing valve. No abnormal readings 1" above the new cement top or anywhere else in the cellar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:30 7/29/2020 T/I/O = SSV/500/10. Temp = SI. WHPs (Eval conductor cement). ALP = 1980 psi, AL SI @ casing valve. No abnormal readings 1" above the new cement top or anywhere else in the cellar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:30 7/30/2020 T/I/O = 560/900/10. Temp = 34°. Assist OPS w/POP (under eval). ALP = 900 psi, AL online. Pad OP POP'd well @ 07:30. Monitor cellar for bubbling & LEL readings. See log for details. Released by Pad Op. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:10 Daily Report of Well Operations PBU J-07B Daily Report of Well Operations PBU J-07B 7/31/2020 T/I/O = 220/1170/150. Temp = 138°. Monitor cellar for bubbling (under eval). ALP = 1170 psi, AL online. Well appears to have grown 4" since well POP'd. LELs = 0% 1" above and throughout cellar. Pad Ops & WIE notified about tree growth. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:00 7/31/2020 T/I/O = 160/1320/60. Temp = 120°. Monitor cellar for bubbling (Under eval). ALP = 1320 psi, online. OA cemented to surface. No bubbling in cellar. 0% LELs 1" and 1' above the conductor and around the cellar. SV = C. WV, SSV, MV = O. IA, OA = OTG. 02:30 8/1/2020 T/I/O = 180/1170/160. Temp = 144°. Monitor cellar for bubbling (Under eval). ALP = 1170 psi, online. OA cemented to surface. No bubbling in cellar. 0% LELs 1" and 1' above the conductor and around the cellar. Pad operator thought the well appeared to rise up. Took measurements around tree. From the top of cement to the top of the casing hanger at the 12 o'clock position measured 48". From the top of the grating to the top of the OA flange above the grating at the 12 o'clock position measured 14 7/8". From the top of the tree cap collar to the roof at the 3 o'clock position measured 77 1/4". From the top of the flowline to the bottom of the plywood where marked with black sharpie measured 1 3/8 " SV = C. WV, SSV, MV = O. IA, OA = OTG. 05:00 8/1/2020 T/I/O = 220/1180/150. Temp = 140°. Monitor cellar for bubbling (under eval). ALP = 1180 psi, AL online. LELs = 0% 1" above and throughout cellar. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:15 8/2/2020 T/I/O = 220/1170/160. Temp = 144°. Monitor cellar for bubbling (under eval). ALP = 1170 psi, AL online. OA cemented to surface. No bubbling in the cellar at this time. LELs = 0% 1" above and throughout cellar. Top of flowline is 3/4" from making contact with plywood backing of well house. SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:00 8/2/2020 T/I/O = 180/1170/160. Temp = 144°. Monitor cellar for bubbling (Under eval). ALP = 1170 psi, online. OA cemented to surface. No bubbling in cellar. 0% LELs 1" and 1' above the conductor and around the cellar. All measurements indicate tree has risen 1/2" since yesterday. New measurements are as follows: top of cement to top of casing hanger at 12 o'clock = 48 1/2", top of grating to top of OA flange at 12 o'clock = 15 3/8", top of tree cap collar to roof at 3 o'clock = 76 3/4", and top of flowline to bottom of plywood = 7/8" SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:00 8/3/2020 T/I/O = 220/1170/160. Temp = 144°. Monitor cellar for bubbling (under eval). ALP = 1170 psi, online. OA cemented to surface. No bubbling in cellar. 0% LELs 1" above & throughout cellar. SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:00 8/4/2020 T/I/O = 180/1150/150. Temp = 146°. Monitor cellar for bubbling (Under eval). ALP = 1170 psi, online. OA cemented to surface. No bubbling in cellar. 0% LELs 1" and 1' above the conductor and around the cellar. All measurements indicate tree has risen another 1/2" since 8/02/20. New measurements are as follows: top of cement to top of casing hanger at 12 o'clock = 49", top of grating to top of OA flange at 12 o'clock = 15 7/8", top of tree cap collar to roof at 3 o'clock = 76 1/4", and top of flowline to bottom of plywood = 3/8" SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:30 8/7/2020 T/I/O = 180/1150/110. Temp = 146°. Monitor cellar for bubbling (Under Eval). AL online. OAP decreased 40 psi since 8/4/20. No bubbling in cellar or conductor. 0% LEL's 1" and 1' above conductor and around cellar. SV = C. WV, SSV, MV = O. IA, OA = OTG. 17:15 Daily Report of Well Operations PBU J-07B 8/8/2020 T/I/O = 180/1150/100. Temp = 147°. Monitor cellar for bubbling (Under Eval). AL online @ 1150 psi. OA cemented to surface. TP & IAP unchanged, OAP decreased 10 psi overnight. Infrequent bubbling outside conductor @ 9 o'clock ~4" out - 0% LELs @ 1" & 1' above. Minute bubbling around SC and just outside conductor @ 11 - 12 o'clock - 0% LELs @ 1" & 1' above. SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:15 8/9/2020 T/I/O = 180/1150/100. Temp = 148°. Monitor cellar for bubbling (Under Eval). AL online. There is ~4" of water in the cellar at the 2 to 6 o'clock position, and ~1/2" of water at the 9 o'clock. No bubbling or LEL's anywhere in the cellar or conductor. SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:00 8/10/2020 T/I/O = 180/1160/80. Temp = 114°. Monitor cellar for bubbling (Under Eval). AL online @ 1160 psi. OA cemented to surface. TP unchanged, IAP increased 10 psi, OAP decreased 20 psi overnight. There is ~4" of water in the cellar at the 2 - 6 o'clock position, and ~1/2" of water at the 9 o'clock postition. No bubbling or LELs detected in the cellar or conductor. SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:00 8/12/2020 T/I/O = 180/1160/80. Temp = 107°. Monitor cellar for bubbling (Under Eval). AL online @ 1160 psi. OA cemented to surface. WHPs unchanged overnight. No bubbling or LELs detected in cellar. Fluid level in cellar unchanged. SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:00 8/12/2020 T/I/O = 180/1160/80. Temp = 150°. Monitor cellar for bubbling (Under Eval). AL online. OA cemented to surface. Intermittent bubbling in cellar at the 9 o'clock position. 0% LEL's 1" or 1' above. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:40 8/13/2020 T/I/O = 180/1160/80. Temp = 110°. Monitor cellar for bubbling (Under Eval). AL online @ 1160 psi. OA cemented to surface. WHPs unchanged overnight. No bubbling or LELs detected in cellar. SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:30 8/14/2020 T/I/O = 210/1160/80. Temp = 149*. Monitor cellar for bubbling (Under Eval). AL open @ casing valve. No bubbling or LEL's detected in cellar. The TP increased 30 psi, IA & OAP remained unchagned overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 12:00 8/14/2020 T/I/O = 180/1170/70. Temp = 112°. Monitor cellar for bubbling (Under Eval). AL online @ 1170 psi. OA cemented to surface. TP unchanged, IAP increased 10 psi, OAP decreased 10 psi overnight. Infrequent bubbling in cellar ~2' outside conductor @ 7 o'clock position - 0% LELs @ 1" & 1' above, no LELs detected in cellar. SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:00 8/17/2020 T/I/O = 180/1170/80. Temp = 105°. Monitor cellar for bubbling (Under Eval). AL online @ 1170 psi. OA cemented to surface. TP & IAP unchanged, OAP increased 10 psi since 08/14/2020. No bubbling or LELs detected in cellar. Minor bubbling inside conductor @ 4 o'clock position - 0% LELs @ 1" & 1' above. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:00 8/18/2020 T/I/O = 220/1170/50. Temp = 109*. Monitor cellar for bubbling (Under Eval). AL open @ casing valve. The TP increased 40 psi, IA & OAP remained unchanged overnight. No bubbling or abnormal gas readings around the conductor or cellar. SV = C. WV, SSV, MV = O. IA, OA = OTG. 12:00 Daily Report of Well Operations PBU J-07B 8/19/2020 T/I/O = 220/1170/90. Temp = 107°. Monitor cellar for bubbling (UE). AL online. No bubbling detected in the cellar floor or conductor. LEL = 0% throughout cellar and wellhouse. TP & IAP unchanged, OAP increased 40 psi, temp decreased 2° overnight. SV = C. WV, SSV, MV = O. IA, OA = OTG. 09:00 8/20/2020 T/I/O = 300/1150/50 Temp = 104*. Monitor Cellar for bubbling (Under Eval). The TP increased 80 psi, IAP decreased 20 psi and the OAP remained unchanged since 8-18- 20. No bubbling or abnormal gas readings in the cellar. Cement top is broken is several places, wellhead appears to have lifted 9.5" (rust line on casing is visible). GLT line has lifted off of the supports in wellhouse. S-riser is slightly impacting backing board. Flowline has lifted off of 1st VSM behind wellhouse 5.5", flowline is resting on all other VSMs. SV = C. WV, SSV, MV = O. IA, OA = OTG. 09:20 8/21/2020 T/I/O = 180/1170/100. Temp = 150*. Monitor cellar for bubbling (Under Eval). AL Online on @ 1170 psi. OA cemented to surface. WHPs unchanged. No bubbling of LELs detected in cellar. 0% LELs 1" 1' above conductor and around cellar. No change in well measurments since 08-20-20. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:40 8/21/2020 T/I/O = 180/1170/90. Temp = 152°. Monitor cellar for bubbling (Under Eval). AL online @ 1170 psi. OA cemented to surface. WHPs unchanged since 08/19/2020. No bubbling or LELs detected in cellar. 0% LELs 1" & 1' above conductor and around cellar. SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:00 By Jody Colombie at 1:41 pm, Jul 13, 2020 320-294 DLB 07/13/20 10-404 DSR-7/13/2020MGR13JUL20 X 7/14/2020 JLC 7/14/2020 RBDMS HEW 7/16/2020 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed 2020 Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other. Conductor Top Ad 0 2. Operator Name: BP Exploration (Alaska), Inc 4, Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 218-122 3. Address: P.O. Box 196612 Anchori AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20241-02-00 7 Property Designation (Lease Number): ADL 028281 8. Well Name and Number: PBU J -07B 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 12321 feel Plugs measured None feet true vertical 8918 feet Junk measured None feet Effective Depth: measured 12283 feet Packer measured 10663, 10889 feet true vertical 8925 feet Packer true vertical 8829, 8917 feet Casing: Length: Size. MD: TVD: Burst: Collapse: Conductor 80 20" x 30" 41-121 41-121 Surface 2642 13-3/8" 41 -2683 41-2683 4930 2670 Intermediate 8705 9-5/8" 40-8745 40-7261 6870 4760 Intermediate 11031 7" 38-11069 38-8964 7240 5410 Liner 211 4-1/2" 10937 -11148 8936-8964 8430 7500 Liner 1633 3-1/2" x 3-1/4" x 2-7/8" 10688 - 12321 8839-8918 10160 / 10570 10530 / 11160 Perforation Depth: Measured depth: 12210 - 12250 feet True vertical depth: 8941 -8932 feet Tubing (size, grade, measured and true vertical depth) 4-1/2° 12.68, 13Cr80 / L-80 36-10947 36-8940 4-1/2" Baker S-3 Perm Packer 10663 8829 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 10889 8917 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Cement Conductor to Surface Treatment descriptions including volumes used and final pressure: Conductor clean down to 64" HES on location mix 15 gallons of LocCem and place -14 gallons in void. UCA compressive strength will be @ 1800 psi at 69 his. Secure area and leave heal at base of wellhead for three days. OA cemented to surface. Cement sample is set up. Final Pressures: OA = 50 psi, IA = 250 psi, TBG = 60 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 139 1657 3839 1135 189 Subsequent to operation: Shut -In 250 60 14. Attachments: tre4mre4 per 20 MC 25070.25.071, a 252637 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ 16. Printed and Electronic Fracture Stimulation Data ❑ 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: 319-275 Authorized Name: Obrigewitch, Beau Contact Name: Obrigewitch, Beau nt rity EEngineer Contact Email: BEAU.OBRIGEWITCHLt1bp.com Authorized Title: Well Integrity Authorized SignaturcW• y Jl Date: `L' 'GOG(% Contact Phone: +1 907 564 4854 Form 10-404 Revised 01/2017 / ,,,,�wzmbzcRBDMS��FEB 12 2020 '/�J' Submit Original Only Daily Report of Well Operations PBU J -07B ACTIVITYDATE SUMMARY T/I/O = SSV/270/70. Temp = SI. Check cellar thaw (Pre conductor cement). AL SI @ casing valve (270 psi). Well has a sliplock tree installed. Cellar water has been removed (47" from top of grating to gravel bottom, 7 o'clock). Cut off 20" and 13 3/8" are visible). The conductor void is visible from the 4 o'clock to 11 o'clock positions, 1" of gravel will need to be removed to expose the circumference. There appears to be ^2" of room between the 13 3/8" x 9 5/8" conductor on the 9 o'clock side (filled with water). 11/23/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:40 TWO = SSV/270/70. Temp = SI. WHPs (eval cellar thaw). ALP = 270 psi, SI @ CV & LVs. WHPs unchanged since 11/23/19. No fluid present in cellar, fluid in conductor is 4" from the top. Conductor has -36" of fluid to hard bottom, fully thawed. 11/25/2019 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 01:45 T11/0 = SSV/250/75. Temp = SI. ALP = 270 psi, SI @ CV & LVs. No fluid present in cellar. Conductor has -36" of fluid to hard bottom, fully thawed. 1/17/2020 SV, WV, SSV = C. Job Scope: Clean conductor with steam. Conductor clean down to 64" HES on location mix 15 gallons of LocCem and place -14 gallons in void. @ 10:30 AM LICA compressive strength will be @ 1800 psi at 69 hrs. Secure area and leave 1/18/2020 heat at base of wellhead for three days. POP well after 72 hrs ***Job Complete*** TWO = SSV/270/80. Temp = SI. WHPs (Post conductor cement job). ALP = 270 psi, SI @ CV. OA cemented to surface. Cement sample is set up. Installed heater in wellhouse. Bled tree cap to 0 psi. Wellhouse door left partially open. 1/20/2020 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:50 T/I/O = SSV/270/80. Temp = SI. WHPs (Post conductor cement job). ALP = 270 psi, SI @ CV. OA cemented to surface. Heater is working properly, re -adjusted heat hose and installed tempeture gauge at 3 o'clock position. OA Hanger Temp = 70*. Bled tree cap to 0 psi. Wellhouse door left partially open. 1/22/2020 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:45 TREE= WELLHEAD= FMG GENV ACTUATOR= _ OKB_ ELEV = 6819' FIEF ELBf = 75M BF. ELEV = 38.46' KOP= 2800' Max Angle = 104* @ 11991' Datum M7= 10787 Datum TVD= Bow SSI J -07B 20' X 30' COND, J 121' D= ' 12.347' D = 6250' D = 6.312" 9-5/8'X 7' BKR FMC LNR HGR D = 6.167" -J_ 35/8' CSG, 47#, 14-80, D = 8.681' Minimum ID = 2.786" @ 10721' 3-1125'X 3-3116" XO LNR, 9.3#, 13CR-85 STL, bpf, D=2.992' CR, -0152 bpf, D = 3.958• 12" TBG STUB (XX/XX/XX) 2118' 2670' 862W I 10688' I {ACK SLV, D=5.250" I- 10937' .0152 bpf, D = 3.958" 10946' LNR HGR. D = 4.375' 10949" .0383 bpf, D=6.276" 11069' 'LATCH WHPSTOq( 11148' .0152bpf,D=3.958' H -11148' PERFORATION SUMMA RY REF LOG: BKR MWD ON 01120/19 ANGLE AT TOP PERF: 102* @ 12210' Note: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL Opn/Sqz SHOTSOZ 2" 1 6 112210-122201 O 01/29/19 2" 6 12240 - 12250 O 04/08/19 LNR 6.6#, 13CR-85 TCI, .0079 bpf, D LNR, 6.5#. L-80 STL, .0058 bpf, D = 2.441' SAFETY NOTES: WELL > -70* @ 10963'*** MAX DOGLEG: 23" @ 11593'*** 13-318" CSG CRACKED BELOW BRADENHEAD WELD -30" L *** 4-112" CHROME TBG'*' WELLHEAD STARTS AT 9-518" CSG - NO ODA ••• CHROME TBG & LNR •"• 2�HES XNP, D=3.813' GAS LFT MANDRELS ST MD I WD I DEVI VLV TYPE LATCH PORT DATE 6 3638 3619 20 KGB -2 DOW BK 16 01/31/19 5 6092 5474 45 KBG-2 SO BK 20 01/31/19 4 8091 6826 48 KBG-2 0AT' BK 0 07/05104 3 9462 7863 29 KBG-2 DW BK 0 07/05/04 2 10158 8466 30 KBG-2 13W BK 0 07/05/04 1 10563 8780 56 KBG-2 OW BK 0 07/05104 9-5/8' MILLOUT WINDOW (J -07A) 8745' - 8795' D631' 4-12' HES X NP, D = 3.813' D662" 7' X 4-1/2" BKR S-3 PKR, D = 3.875" D688' 3.70" DEPLOY SLV, D= 3.00' 10740' -{ 4-12" MLAESHOE WLEG, D = 3.958• 10878' 4-12' HIS X NP, D = 3.813" 10869' 7' X 4-12" BKR S-3 WJ;t D = 3.875" 10912' a-12• HEs x NP, to = 3.813• BEHIND CT LNR 10946' -j4-1/2' WLEG, D=3.958" 10945' 7'X4-12'BKRZXPPKR0=4.375' MILLOl1T WINDOW (1078) 11148-- 11156- x DATE REV BY ODMyBffS DATE REV BY COMu84TS 1IN04177 ORIGINAL COMPLETION 01131/19 BGIJND PERFS (0129119) 06111196 SBR SIOETRACK(J-07A) 02107/19 CJWJMJ GLV C/O (01/31/19) 12/02/02 ODWIKK RWO SUSPENDED 02/25/19 JNL/JMD ADDED MB, REF, BF & COAD PFO 07/06104 DCFVKAI4 RWO 04/17/19 JCF/JMD4 PENS (04/08119) & SAFEIY NOTE (CHROME) 01124119 N-CDFa CTD ST (J -07B) 04/30/19 DD/JM) CORRECTED TOP PERF DEPIHS 01130/19 ZBIJMD FNALODEAPPROVAL PRUDHOE BAY UNT WELL: 1078 PERMIT No: 218-122 AR No: 50-029-20241-02 SFJ; 9, T11K R13E, 84V FHL & 804' FEL BP Exploration (Alaska) THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU J -07B Permit to Drill Number: 218-122 Sundry Number: 319-275 Dear Mr. Obrigewitch: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.oloslko.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, 4IZ5—� Daniel T. Seamount, Jr. Commissioner DATED this��dayofune, 2019. RRD04,"-�- JUN 0 5 2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.260 MAY 3 0 2019 1, Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 61 ' Ac&eejeno Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Conductor Top Job 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0. 5. Permit to Drill Number: 218-122 - 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigrephic ❑ Service ❑ 6. API Number: 50-029-20241-02-00 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No El PBU J -07B ' 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028281 • 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): 12321 • 8918 12283 8925 None None Casing Length Size MD TVD Buret Collapse Conductor 80 20" x 30" 41-121 41-121 Surface 2642 13-3/8" 41-2683 41-2683 4930 2670 Intermediate 8705 9-5/81• 40-8745 40-7261 6870 4760 Intermediate 1 11031 1 7" 38-11069 38 - 8964 7240 5410 Liner 211 4-1/2" 10937-11148 8936 - 8964 8430 7500 Liner 1633 3-1/2" x 3-1/4" x 2-7/8" 10688 - 12321 8839-8918 1 10160 / 10570 1 10530 / 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12210- 12250 8941 -8932 4-1/2'• 12.68 13Cr80 / L-80 36-10947 Packers and SSSV Type: 4-1/2" Baker S-3 Penn Packer Packers and SSSV MD (ft) and TVD (ft): 10663 / 8829 4-1/2" Baker S-3 Perm Packer 10889/8917 No SSSV Installed 12. Attachments: Proposal Summary IZ Wellbore Schematic 0 13. Well Class after proposed work. Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ® Service ❑ 14. Estimated Date for Commencing Operations. 6/15/2019 15. Well Status after proposed work: Oil H 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: Obrigewitch, Beau be deviated from without prior written approval. Contact Email. BEAU.OBRIGEWITCH0bp.com Authorized Name: Obrigewitch, Beau Contact Phone: +1 907 564 4854 Authorized Title: Well Integ Engineer Authorized Signature: OAA Dater Zq/-ZO 14 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representa8ve may witness Sundry Number _ S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMSlg&✓jUN 0 5 2019 Post Initial Injection MIT Req'tl? Yes ❑ No ❑—/ '` Spacing Exception Required? Yes 11 No CN Subsequent Form Required: p, _Vff / Ir APPROVED BYTHE Approved by:A0/__Z* COMMISSIONER COMMISSION Date: �1 Klt� Form 10-403 Revised 04/2017 ORIGINAL itt6Q31MAM q � S•S� v � jj�✓ Submit Fonn and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate J -07B Conductor Top Job Well Interventions Engineer: Beau Obrigewitch (907) 564-4854 Pad Engineer: Julie Wellman (907) 564-4657 Estimated Start Date: June 15, 2019 History During a rig workover in 2004, the original 9-5/8" x 13-3/8" OA was abandoned with cement to surface, cutting the 13-3/8" at surface, welding a new wellhead onto the 9-5/8", and running a 7" scab liner from 8,642' to surface (7" x 9-5/8" cement to —1,500'). Since that time, the cellar has experienced intermittent bubbling. Following a Coiled Tubing Sidetrack in early 2019, the well began exhibiting cellar bubbling again, also including a fluid that laboratory testing indicated the presence of hydrocarbons. Current Status The well is currently classified as Not Operable by BP due to the confirmed intermittent bubbling and hydrocarbons in the cellar. Objective Mitigate the recurrent bubbling and hydrocarbons returned to surface, and return the well to Operable status. Job Steos 1 O POP Under Eval 2 J Clean and Prep Conductor for Cement Top Job 2 J Cement Conductor to Surface 3 O POP Under Eval 4 D Monitor Cellar Procedural steps Well Integrity / Operations 1. Well Integrity to make well Under Eva[ and Ops to POP. The intent of this step is to thermally energize the system, which will minimize the influence of trapped annular spaces after the cement is in place. Special Projects 2. Steam clean the 9-5/8" x 13-3/8" Annulus to top of good cement, or as deep as can be achieved. 3. Attempt to centralize the 9-5/8" in the 13-3/8" using shims. Circulate cement into the annulus from the cleanout depth until clean cement returns are observed. Note: Choose cement that is most operationally feasible. The desire is to use a free-flowing, well sealing cement product, increasing the probality the cement will flow into small annular spaces where the 9-5/8" is leaning against the 13-3/8". Operations / DHD 4 WOC at least 3 days. Ops to POP well. DHD to monitor for cellar bubbling and hydrocarbons. TREE= WELLHEAD= FMC GE4V ACTUATOR= _ OKB. ELEV = 68.19' Rff ELE/ = 75N BF. E LEV = 38.46' KOP= 2800' Max Angle = 104' @ 11991' Datum MD= 10782' Datum WD= 88W SS 20' X 30' COND, 121' SCAB LNR 17' TIEBACK SLV, D = 6.250" H 8629' 9-518'X7"BKR ZXP R(R D=6.312' H 8637' B' X 7' BKR HMC LNR HGR D = 6.187' H 8842' 9-5/8' CSG, 47#, N-80, D = 8.681" 874F Minimum ID = 2.786" @ 10721' 3-1/2" X 3-3H 6" XO LNR, 9.3#, 13CR-85 STL, I 10721' bpf, D = 2.992' 14-1/2' TBG, 12.6#, 13 -CR .0152 bpf, D- 3.958" I TBG,12.6#, L-80-0152 bpf, D = L-80, .0383 bpf, D = 6276' SNAP LATCH WHIPSTOCK .-80, .0152 bpf, D = 3.958' PERFORATION SUMMARY REF LOG: BKR MWD ON 01/20/19 A NGLE AT TOP PERF: 102.0 12210' Note: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I Opn/Sqz I SHOTSQZ 2' 6 12210 - 12220 O 01/29/19 2- 6 12240 - 12250 O 04/08/19 3-1/4' LNR 6.69, 13CR-85 TCI, .0079 bpf, D = 2.55' F —PBTD LNR 6.5#, L-80 STL, J -07B 1 12283' 1 SAFETY NOTES: WELL > -70' @ 10963'*** MAX DOGLEG: 23° @ 11593'*** 13-3/8" CSG CRACKED BELOW BRADENHEAD WELD -30" L ••' 4-1/2" CHROME TBG "• WELLHEAD STARTS AT 9-5/8" CSG - NO ODA "• CHROME TBG & LNR '•' HBS X NP, D = 3.813' GAS LFT MANDRELS ST MD I WDI DEV I VLV TYPE LATCH PORT DATE 6 3638 3619 20 KGB -2 DONE 81( 16 01/31/19 5 6092 5474 45 KBG-2 SO BK 20 01/31/19 4 8091 6826 48 KBG-2 DW BK 0 07/05/04 3 9462 7863 29 KBG-2 OMY BK 0 07/05/04 2 10158 8466 30 KBG-2 DMY BK 0 07/05/04 1 10563 8780 56 KBG-2 OMY BK 0 07/05104 9-5/8' MILLOUT WINDOW (J -07A) 8745' - 8795' 10662' H7" X 4-112" BKR S-3 PKR D = 3.875" 10688' 3.70" DEPLOY SLV, D=3.00" 10710' xNP,0=2.812^ CT 107�-t 3-12' X 3-3/16" XO, D = 2.786' 1074W 4-12' MULESHOE WLEG, ID = 3.958' 10878' 4-12" HES X NP, D = 3.813' 10889' 7'X4-12' BKR S-3 PKR D = 3.875' 10912' 4-12' HES X NP, D = 3.813' BEHIND 10932' CT LNR 4-12' HES XN NP, D = 3.725' 10946' 4-1/2- VVLEG,D=3.958' 10946' 7" X 4-12" BKR ZXP R75 01130119 ZB/JMD FTNALODEAFPfROVAL MILLOUT WINDOW (J -07B) 11148'- 11156' 1 11968' 1 I PUP ITw/RA TAG I DATE REV BY COMMENTS DATE REV BY COMMENTS 10104/77 ORIGINAL COMPLETION 01/31/19 BGIJID PERFS (07129/19) 06111196 SBR SIOETRACK(J-07A) 02/07/19 CJNJMD GLV GO (01/31119) 12/02/02 013NIM RWO SUSPENDED 02125/19 JNIJJMD ADDS OKB, REF, BF 8 COND PFO 07/0604 DCV4KAH R.WO 04/17/19 CF/J R3RFS (04/08119) 8 SAFETY NOTE (CHROME) 01124119 N-CDR2 CTD ST (J-078) 04/30/19 DDJMD CORRECT®TOP PEW DEPTHS 01130119 ZB/JMD FTNALODEAFPfROVAL PRUDHOE BAY INT WELL: J -07B PERMIT No: 218-122 AR No: 50.029-20241-02 SEC 9, T11 N, R13E, 848' FNL & 804' FEL SP Expioration (Alaska) STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMIS? REPORT OF SUNDRY WELL OPERATIOha APR 3 0 201 1. Operations Performed p it G° i` Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations seutdown CJ `-❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4, Well Class Before Work Development 0 1 Stratigraphic ❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number. 218-122 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 1 6. API Number. 60-029-20241-02-00 7. Property Designation (Lease Number): ADL 028281 S. Well Name and Number: PBU J -07B 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: Length: Size: MD: TVD: Burst: Collapse: Total Depth: measured 12321 feet Plugs measured None feet true vertical 8918 feet Junk measured None feet Effective Depth. measured 12283 feet Packer measured 10663, 10889 feet true vertical 8925 feet Packer true vertical 8829, 8917 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" x 30" 41-121 41-121 1115 185 Surface 2642 13-3/8" 41-2683 41-2883 4930 2570 Intermediate 8705 9-5/8" 40-8745 40-7261 6870 4760 Intermediate 11031 7" 38-11069 38-8964 7240 5410 Liner 211 4-1/2" 10937 -11148 8936-8964 8430 7500 Liner 1633 3-1/2" x 3-1/4" x 2-7/8" 10688 -12321 6839-8918 10160 / 10570 10530 / 11160 Perforation Depth: Measured depth: 12210 -12250 feet True vertical depth: 8941-8932 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.671 13Cr80, 13Cr80 / L-80 36-10947 Oil -Bbl 4-1/2" Baker S-3 Perm Packer 10663 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 10889 true vertical depth) No SSSV Installed 1846 12. Stimulation or cement squeeze summary: Intervals treated (measured). including volumes used and final pressure: 36-8940 8829 8917 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 287 1429 1846 1115 185 Subsequent to operation: 164 1480 4050 1143 190 14.Attachments: (mgwmd per 20 Mc 25.07025071, a 2S 283) Daily Report of Well Operations 0 15. Weil Class after work: Exploratory ❑ Development 0 Service ❑ Stratigrephic ❑ Copies of Logs and Surveys Run ❑ 18. Well Status after work: Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ 7. 1 hereby certify, that the foregoing is true and correct to the best of my knowledge. Oil 0 Gas ❑ WDSPL ❑ INJ ❑ SUSP ❑ SPLUG ❑ Sundry Number of N/A if C.O. Exempt: NIA Authorized Name: Wellman, Julie Contact Name: Wellman, Julie Authorized Title: Production Engine Contact Email: Julie.Wellmanftbp.com Authorized Signature: P2�'�_ Date: y t 3011 1 Contact Phone: +1 9075644657 Form 10.404 Revised 04120 MAY 06 2019Sy7 RBDMS MAY 0 11019 Submit Original Only Daily Report of Well Operations PBU J -07B Ar:Ti%/ITYhATF CI IMMARV 4/6/2019 CTU #9 - 1.75" Coil, 0.156" wt Job Objective: AddPerf MIRU CTU. Make up 2.2" GR/CCL carrier with 2.25 JSN and RIH. ...Continued on WSR 4-7-19... CTU #9 - 1.75" Coil, 0.156" wt ***Cont. from WSR 4-6-19*** Job Objective: AddPerf RIH with 2.2" GR/CCL carrier with 2.25 JSN. POOH due to immanent failure of priority hydraulic pump, decision made to rig down and move to SLB yard for repairs. RDMO CTU to SLB yard for repairs. MIRU CTU. Make up same 2.2" GR/CCL carrier with 2.25" JSN and RIH. Load well with 1% KCL w/ SL. RIH to TD of 12274 CTMD. Log up to 10,500 painting a blue/green tie-in flag at 12,200'. POOH. 4/7/2019 ...Continued on WSR 4-8-19... CTU #9 - 1.75" Coil, 0.156" wt ***Cont. from WSR 4-71-9*** Job Objective: AddPerf POOH with GR/CCL carrier. Determine +7' correction and corr. PBTD of 12281'. Make up 10' x 2" MaxForce Perf gun, 6 spf and RIH. Tie in at flag and perforate 12240-12250 (ref. depths to Baker MWD 1-20-19). POOH and FP well. 4/8/2019 ...Job Complete I fd_E= !M LFEAD= FMC GEJV �!ACRJATOR= I DEVI OKB. ELEV = 6.8.19' RE' E -E/ _ -- 75.8' BF. ELEV = 38.46, 20' X 30' GOND, KOP= 280(Y #, � Max Angle = 104` @ 11991' ' D = Dawn MD = 10782 . Dalen TVD= 8800'SS, 5 TOP OF 7'SCA B LNR I- LNR, 26#, L-80,.0383 bpf, D = 6276' 13-3/8' CSG, 72#, N-80, D = 12.347' :Z�74CA'7613:3.T_T1CI:7C 17- TACK SLV, D = 6.250' 9-5/8' X 7- BKR ZXP PKR, 3' X 7' BKR HMC LNR HGR, D = 6.187- 19-5/8- CSG, 47#, N-80, D = 8.681' Minimum ID =2.786" @ 10721' 3-112" X 3-3116" XO 3-1/2' LNR, 9.3#, 13CR-85 STL, .0087 bpf, D = 2.992' W. 13 -CR -0152 bpf, D = 3.958' 4-1/2' TBG STUB (XX/XX/XX I4-1/2' TIEBACK SLV, D =5250' TBG,12.6#, L-80, .0152 bpf, D = 1.958- X 4-1/2' BKR HMC LNR HGR, D = 4.375' 7. 1 NO IRA 1 An MA1 6nf n -A 979 - J-07 ✓ SAFE OTES: WELL> -70° @ 10963' •'• MAX Lu A , DOGLEG: 23' @ 11593' ••• 13-3/8" CSG CRACKED [AgBELOW BRADENHEAD WELD -30" L ••• 4-1/2" CHROME TBG •'• WELLHEAD STARTS AT 9SAT" 121' CSG - NO ODA •" CHROME TBG & LNR ••• 2118' 2670' 8628' HES X NP, D = GAS LFT MANDRELS ST ND I ND I DEVI VLV TYPE LATCH PORT DATE 6 3638 3619 20 KGB -2 DONE BK 16 01/31/19 5 6092 5474 45 KBG-2 SO BK 20 01/31/19 4 8091 6826 48 KBG-2 DMY BK 0 07/05/04 3 9462 7863 29 KBG-2 DMY BK 0 07/05/04 2 10158 8466 30 KBG-2 DMY BK 0 07/05/04 1 10563 8780 56 KBG-2 DMY BK 0 07/05/04 9-5/8' MLLOLJT W14DOW (J -07A) 8745' - 8795- 382V --44-1/2- HES X NP. D = 3.813- 10662- —j7' X 4-12' BKR S3 PKR, D = 3.875- 10686' 3.70' DEPLOY SLV, D=3.00' 10710' X NP, D = 2.812' 10718' 4 -1/2 -HES X NP, D=3.813 -(BEHIND CTL 10721' 3-1/2'X3-3/16' XO, D = 2.786' 10740' 4-1/2' MULESHOE WLEG, D = 3.958' 10878' 4-1/2' HES X NP, D = 3.813' IMUM 7-X4-1/2'RKR S3 PKR_D=3875' PERFORATION SUMMARY REF LOG: BKR MWD ON 01/20/19 ANGLE AT TOP PERF: 102" @ 12210' Note: Refer to Production DB for historical perf data SIZE SPFI INTERVAL Opn/Sqz SHOT SOZ 2' 6 12210 - 12220 O 1011291191 2' 6 12240 - 12250 O 04/08/19 13-1/4' LNR 6.6#, 13CR-85 TCR .0079 bpf, D = 2.85' I 6.5#, L-80 STL, .0058 bpf, ID = 1 11414' 1 1 11968' 1 TAG TAG 3-3/16' X 2-7/8' XO, D= 2.377' 1 DATE REI BY COM MINTS DATE REV BY COMMENTS 10/04177 ORIGINAL COMPLE ION 10912' 4 -1/2 -HES X NP, o=3.813' BEHIND 1pg37• _ 02/07/19 CJWJM7 GLV aO(01/31/19) 12/02102 DOWIM RWO SUSPENDED CT LNR 10932' 4-1/2' HES XN NP, D= 3.725' 10946' 04/17/19 Ja=/JM34 PERFS (04/08/19) & SAFETY NOTE (CHROME) 01124/19 N-CDR2 CTD ST (J -07B) 10946' 4-12'WLEG,D=3.958' 10949' 10946' 7' X 4-1/2' BKR ZXP PKR, 11069' 1114W MILLOUT WINDOW (J -07B) 11148' - 11156' PERFORATION SUMMARY REF LOG: BKR MWD ON 01/20/19 ANGLE AT TOP PERF: 102" @ 12210' Note: Refer to Production DB for historical perf data SIZE SPFI INTERVAL Opn/Sqz SHOT SOZ 2' 6 12210 - 12220 O 1011291191 2' 6 12240 - 12250 O 04/08/19 13-1/4' LNR 6.6#, 13CR-85 TCR .0079 bpf, D = 2.85' I 6.5#, L-80 STL, .0058 bpf, ID = 1 11414' 1 1 11968' 1 TAG TAG 3-3/16' X 2-7/8' XO, D= 2.377' 1 DATE REI BY COM MINTS DATE REV BY COMMENTS 10/04177 ORIGINAL COMPLE ION 01/31/19 BG1JMD PERFS (01/29/19) 06/11/96 SBR SIOETRACK(J-07A) _ 02/07/19 CJWJM7 GLV aO(01/31/19) 12/02102 DOWIM RWO SUSPENDED 02/25/19 JNL/JMT ADDED OKB, REP, BF & COND WO 07/06/04 DCRIKAP RWO 04/17/19 Ja=/JM34 PERFS (04/08/19) & SAFETY NOTE (CHROME) 01124/19 N-CDR2 CTD ST (J -07B) 04/30/19 DD'JMD CORRECTED TOP PERF DEPTHS 01/30/19 ZB/JMD FINALODEAPPROVAL PRUDHOE BAY UNIT WELL: J -07B PE MlTNo: 218-122 AR No: 50-029-20241-02 SEC 9, T11 R R1 3E, 848' FPL & 804' FEL SP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 4/29/2019 Permit to Drill 2181220 Well Name/No. PRUDHOE BAY UNIT J -07B Operator BP EXPLORATION (ALASKA) INC. API No. 50-029-20241-02-00 MD 12321 TVD 8918 Completion Date 1/29/2019 Completion Status 1-0I1 Current Status 1-0I1- UIC No REQUIRED INFORMATION / Ye Mud Log No ✓ Samples No 'z Directional Survey s / DATA INFORMATION List of Logs Obtained: MWD/GR/RES, GR/CCL/RPM (from Master Well Data/Logs) Well Log Information: Logl Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED C 30420 Digital Data 10178 12284 3/1/2019 Electronic Data Set, Filename: J- 07B_MRPM PNC3D_RAW_PASS0IUP_28JAN2 019 BHGE.Ias ED C 30420 Digital Data 10180 12284 3/1/2019 Electronic Data Set, Filename: J- 07B_MRPM_ PNC3D_RAW_PASS02UP_28JAN2 019_BHGE.Ias ED C 30420 Digital Data 3/1/2019 Electronic File: J- 07B_MRPM_PNC3D_RAW _PASS0I UP_28JAN2 019 BHGE.dlis ED C 30420 Digital Data 3/1/2019 Electronic File: J- 07B_MRPM PNC3D_RAW _PASS02UP_28JAN2 019 3HGE.dlis ED C 30420 Digital Data 3/1/2019 Electronic File: J- 07B_MRPM_PNC3D_RAW_28JAN2019_BHGE. meta ED C 30420 Digital Data 3/1/2019 Electronic File: J- 07B_MRPM_ PNC3D_RAW_28JAN2019_BHGE. meta.PDF Log C 30420 Log Header Scans 0 0 2181220 PRUDHOE BAY UNIT J -07B LOG HEADERS ED C 30436 Digital Data 10353 12321 3/12/2019 Electronic Data Set, Filename: J- 07B_LW D_FINAL — INAL_ FIELD_COMPOSITE_20JAN2 019_BHI_CTK.Ias ED C 30436 Digital Data 3/12/2019 Electronic File: J- 07B_GR_Res _ 20JAN2019_MD_FINAL_FIELD_B HI_CTK.cgm AOGCC Page] of 3 Monday. April 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4129/2019 Permit to Drill 2181220 Well Name/No. PRUDHOE BAY UNIT J -07B Operator BP EXPLORATION (ALASKA) INC. API No. 50-029-20241-02-00 MD 12321 TVD 8918 Completion Date 1/29/2019 Completion Status 1 -OIL Current Status 1 -OIL UIC No ED C 30436 Digital Data 3/12/2019 Electronic File: J- 07B_GR_Res _ 20JAN2019_TVDSS_FINAL_FIEL D_BHI_CTK.cgm ED C 30436 Digital Data 3/12/2019 Electronic File: J- 07B_GR_Res _ 20JAN2019_MD_FINAL_FIELD_B HI_CTK.pdf ED C 30436 Digital Data 3/12/2019 Electronic File: J- 07B_GR_Res _ 20JAN2019_TVDSS_FINAL_FIEL D_BHI_CTK.pdf ED C 30436 Digital Data 3/12/2019 Electronic File: J -07B Final Surveys TO 12321.csv ED C 30436 Digital Data 3/12/2019 Electronic File: J -07B Final Surveys TO 12321.xlsx ED C 30436 Digital Data 3/12/2019 Electronic File: J -07B Final Survey Report _.pdf ED C 30436 Digital Data 3/12/2019 Electronic File: J -07B Final Surveys.txt ED C 30436 Digital Data 3/12/2019 Electronic File: J-07B_25_tapescan_BHI _CTK.txt ED C 30436 Digital Data 3/12/2019 Electronic File: J-07B_5_tapescan_BHI_CTK.txt ED C 30436 Digital Data 3/12/2019 Electronic File: J-076_output.tap ED C 30436 Digital Data 3/12/2019 Electronic File: J- 07B_GR_Res _ 20JAN2019_MD_FINAL_FIELD_B HI_CTK.tif ED C 30436 Digital Data 3/12/2019 Electronic File: J- 07B_GR_Res _ 20JAN2019_TVDSS_FINAL_FIEL D_BHI_CTK.tif Log C 30436 Log Header Scans 0 0 2181220 PRUDHOE BAY UNIT J -07B LOG HEADERS Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments INFORMATION RECEIVED AOGCC Page 2 M 3 Monday, April 29, 2019 DATA SUBMITTAL COMPLIANCE REPORT 4/2912019 Permit to Drill 2181220 Well Name/No. PRUDHOE BAY UNIT J -07B Operator BP EXPLORATION (ALASKA) INC. MD 12321 TVD 8918 Completion Report Production Test Informatio ;NA Geologic Markersfrops0 COMPLIANCE HISTORY Completion Date: 1/29/2019 Release Date: 10/24/2018 Description Comments: Completion Date 1/29/2019 ��Completion Status 1 -OIL Current Status 1 -OIL Y I Directional / Inclination Data / Mud Logs, Image Files, Digital Data Y / t Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data Files V Daily Operations Summary U Cuttings Samples Y //NA / Date Comments API No. 50-029.20241-02-00 UIC No Core Chips Y A Core Photographs Y Laboratory Analyses Y NA t Compliance Reviewed By: Date: AOGCC Page 3 of 3 Monday, April 29, 2019 BA_ KER PRINT DISTRIBUTION LIST UGHES a GE company COMPANY BP Exploration Alaska Inc. WELL NAME J -07B FIELD Prudhoe Bav Unit COUNTY PRUDHOE BAY BHI DISTRICT Alaska AUTHORIZED BY Patrick Rider EMAIL Patrick.Rioer@bhge.corn STATUS Final Replacement COMPANY ADDRESS (FEDEXMLL NDTOELIVER TO P.O. BOX) PERSON ATTENTION V t RP North Slope. EOA. PBOC. PRB-20 (Office 109) D&C Wells Project Aides Attn: Benda Glassmaker & Peggy O'Neil 900 E. Benson Blvd, Aachoroge. Alaska 99508 2 ConocoPhillips Alaska Inc. AM: Ricky Elgarico 'ATO 708 700 G Street Anchorage, AK 99501 3 Esxonklobil,Alaslm Attn: Lynda M. Vaskell a"(For Leonardo Elias 3201 C Street, Suite 505 Anchorage, AK 99503 2181 22 30 43 6 Ise sign and return one copy of this transmittal form to: Exploration (Alaska) Inc. rotechnical Data Center, 1-112-1 ) E. Benson Blvd. :horage, Alaska 99508 or AKGDMINTERNAL@bp.com LOG TYPE GR - RES LOG DATE January 20, 2019 TODAYS DATE March 11, 2019 Revision Details: Rev. Requested by: --- FIELDI FINAL CD/DVDFINAL PRELIM I (las, dlis, PDF, META, I I SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES IlF OF COPIES # OF COPIES 4 4 1; 4 u u RECEIVE® MAR 12 2019 4 State of Alaska -AOGCC 0 D 0 Attn: Natural Resources Technician 11 1333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas ... 0 0 0 0 Attn: Resource Evaluation 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 Liiia.Wt '** Stamp "confidential" on all material deliver to DNR 6 BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: David liter TOTALS FOR THIS PAGE: 0 BA ER 0PRINT DISTRIBUTION LIST HaUGHES GE company COMPANY BP Exploration Alaska Inc. WELL NAME J -07B FIELD Prudhoe Bay Unit 218122 30 42 0 ise sign and return one copy of this transmittal form to: Exploration (Alaska)Inc. rotechnical Data Center, 1-112-1 E. Benson Blvd. :hora¢e, Alaska 99508 or AKGDMINTERNAL@bp.com COUNTY PRUDHOE BAY LOG TYPE BHI DISTRICT Alaska AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(a)bhge.com STATUS Final Replacement: COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V t IRP North Slope. EOA, PBOC, PRB-20 (Off -ice 109) D&C Wells Project Aides Attn: Benda Glassmaker & Peggy O'Neil 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Ann: Ricky Elgarico ATO 3-344 700 G Street Anchorage, AK 99501 3 ExxonMohil, Alaska Atm: Lynda M. Vaskell and/or Lisa Boggs 3201 C Street, Suite 505 Anchorage, AK 99503 4 State of Alaska - AOGCC Ann: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5'DNR -Division ofOil&Gas *** Ann: Garret Brown 550 West 7th Avenue, Suite 1100 .Anchorage, Alaska 99501 *** Shrimp "confidential" on all material deliver to DNR 6iBP Exploration (Alaslo) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd (Anchorage, Alaska 99508 Attn: Gerardo Cedillo TOTALS FOR THIS PAGE: V - RPM:PNC3D LOG DATE January 28, 2019 TODAYS DATE February 28, 2019 Revision Details: Rev. Requested by: -- FIELD I FINAL CD/DVD FINAL PRELIM (las, cilis, PDF, META, SURVEY REPORT LOGS LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES lu 4 4 jj 4 4 R E C E I V MAR 0 1 2019 0 1 4 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI^N WELL MPLETION OR RECOMPLETION REPO( AND LOG la. Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended❑ 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development m Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: One Service ❑ Stratigrephic Test ❑ 2. Operator Name: 6, Date Comp., Susp., or Aband.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 1/29/2019 218422 ' 3. Address. 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-0612 1/14/2019 50-029-20241-02-00 ' 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16, Well Name and Number. 1/19/2019 PBU J -07B 9 Ref Elevations KB 75 80 - 17. Field/Pool(s): Surface: 848 FNL, 804' FEL, Sec. 09, TNN, R13E, UM Top of Productive Interval: 4022FSL. 1110' FEL, Sec. 04, T1 1N, R13E, UM GL 40.07 • BF 38.46 • PRUDHOE BAY, PRUDHOE OIL " 10. Plug Back Depth(MD/TVD): 18, Property Designation: TOUT Depth: 5004' FSL, 1927' FEL, Sec. 04, T1 1N. R13E, UM 12283'/ 8925' ADL 028281 ' 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 643550 • y- 5970505 - Zone - ASP 4 12321'18918' ' 85-24 12. SSSV Depth(MD/TVD): 20Thickness of Permafrost MDRVD: TPI: x- 643140 y- 5975369 Zone- ASP Total Depth: x- 642302 y- 5976336 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No ❑ 13. Water Depth, if Offshore: 21. Re-ddll/Lateral Top Window MDrVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 11148'18964' 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential gamma ray; caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD/GR/RES, GR/CCL/RPM 26 LOiJ FEBG L 23. CASING, LINER AND CEMENTING RECORD i CASING WT, PER FT. GRADE SETTING DEPTH MD TOP BOTTOM SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM 20" x 30" 41' 121' 41' 121' 36" 213 cu 8 PF 13-3/8" 72# N -as 41' 2683' 41' 2683' 17-1/2" 3861 cu It PF 11, 279 ou It PF 11 9-5/8" 47# N-60 40' 8745' 40' 7261' 12-1/4" 1525 ou It HowcoUte, 250 ou ft Class'G, 135 cu ft PF'C', 629 cu ft AS 1 7" 26# L -m 38' 11069, 38' 8964' 8-1/7' 506 ou ft Clasil 186 able Class'G' 4-1/2" 12.6# l 1 10937' 11148' 8936' 8964' 6" 196 tuft Class'G' 3-1/2"x3-1/4" x2-7/8" 9.3#/6.6# /6.5# 13Cr85IL-8o 10688' 12321' 8839' 8918' 4-1/4" 96 as Class'G' 24. Open to production or injection? Yes 0 No ❑ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation GRADE DEPTH SET (MD) PACKER SET (MD/N Size and Number; Date Pertd): 4-1/2" 12.6# 13Cr80 10751' 10663'18828' 2" Gun Diameter. 5 sof 1/29/2019 4-1/Z' 12.6# L-80 10852' - 10945' 10889' / 8917' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12210'- 12220' 8941'- 8938' COMPLETION D -I E tl Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information 2919 VE:2IR° D DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2500' Freeze Protect w/ 38 Bible Diesel 27, PRODUCTION TEST Date First Production: February 9, 2019 Method of Operation (Flowing, gas lift, etc.): Gas Lift Date of Test: 2/11/19 Hours Tested Production for Di4Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: 1 6 Test Period -111. 66 912 404 G 13875 Flow Tubing 220 Casina Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Grevitv-API Icon): Press 1100 24 Hour Rale -11. 283 3649 1616 N/A Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMS�(l FEB 2 7 2019 .� 28. CORE DATA Conventional Consist Yes ❑ No 0 I Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize nmology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071, 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 0 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 10826' 8893' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071, Base Of CGL - Zone 2C 10826' 8893' Kicked off from Parent (J -07A) 11148' 8964' Zone 2B 11268' 8974' Zone 2C (Invert) 12047' 8975' Formation at total depth: Zone 2C (From Base) 1 12047' 1 8975' 31. List of Attachments: Summary of Daily Drilling Reports, Summary of Post -Rig Work, Survey, Cement Report, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Browning, Zachary H Authorized Title: 'alist Contact Email: Zachary. Browning@bp.com Authorized Signature: Date: 1�1-rt/� Contact Phone: +1907 564 5220 INSTRUCTIONS General: This forth is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a. Multiple completion is defined as a well protlucing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Sah Water Disp, Water Supply for Injection, Observation or Other. Item 41b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals coretl and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Forth 10-407 Revised 5/2017 Submit ORIGINAL Only WELLHEAD= FMC GEN V ACTUATOR= DEV OKB. ELEV = 68.19' iaF ELli/ = 76.8' BF. E EV = 38.46 KOP= 2800' Max Angle = 104'@ 11991' DatumND= 10787 Datum TVD = 8800' SS 20' X 30' COED, I)- 17- LNR, 26#, L-80, .0383 bpf, D = 6276' 13-3/8' GSG, 729, N-80, D = 12.347' BOTTOM OF SCAB LNR 7- TIEBACK SLV, D = 6.250' 9-5/8' X 7- BKR ZXP PKR, D = 6.312' 9-5/8' X 7' BKR HMC LNR HGR. D = 6.187' 6629' Minimum ID =2.786"@ 10721'3-1/2"X 33116" XO TOP OF 3 -1/2'X3 -1/4'X2-7/8' LNR/CMT 3-1/2' LNR, 9.3#, 13CR-85 STL, --� .0087 bpf, D = 2.992' 14-1/2' TIEBACK SLV, D = 5.250- 14-1/2" TBG,12.6#, L-80_0152 bpf, D = 3.958' 7' X 4-1/2' BKR HMC LNR HGP D = 4375- 7' LNR 26#, L-80, .0383 bpf, D = 6276' 4-1/2' SNAP LATCH WHIPSTOCK 4-12' LNR, 12.6#, L-80,.0152 bpf, D = 3.958' J-07 B SAFETY NOTES: WELL> -70• LID 10963' ••• MAX DOC :23- 9 11593' ••• 13-318" CSG CRACKED BELOW BRADENHEAD WELD -30- L... 4-12" P3 I CHROME TBG ••• WELLHEAD STARTS AT 9-519" CSG- NO OOA •** CHROME LNR ••• GAS LFT MANDRELS ST MD TVD DEV VLV TYPE LATCH PORT DATE 6 3638 3619 20 KGB -2 DONE BK 16 01/31/19 5 6092 5474 45 KBG2 SO BK 20 01/31/19 4 8091 6826 48 KBG2 DMY BK 0 07/05/04 3 9462 7863 29 KBG2 DMY BK 0 07/05/04 2 10158 8466 30 KBG-2 DMY BK 0 07/05/04 1 10563 8780 56 KBG2 DMY BK 0 07/05/04 9-5/8' MLLOLIT WINDOW (J -07A) 8745' - 8795- 163-V 4-12' HES X NP, D = 3.813- PEF FORATION SL MMW RY REL LOG. BKR RPM ON 01-28-19 ANGLE AT TOP P9;ff=: 102-912207- Note- 02'@12207'Note: Refer to Production DB for historical cert data = 2.tlb- PBTD ^w PUP JT w/RA TAG 13-3/16' X 2-7/8' XO, D = 2.377' 1 DATE REV BY OOMMBNTS DATE FfV BY COMMENTS 10104f77 ORIGINAL COMPLEFION 01/30/19 ZB/JMD FINAL ODEAPPROVAL 10667 7- X 4-12' BKR S-3 PKR, D = 3.875' 01/31/19 BG/JND PHiFS(0129/19) 12102/02 ODWIKK RWO SUSPENDED 02/07/19 CJWJMD GLV C/O (01/31/19) 07106104 DCRfKAI1 RWO 10688' 3.70' DEPLOY SLV, D 01124/19 N-CDR2 CTD ST (J -07B) 0128/19 JMD DR -G HO CORRECTIONS 10710' 10721' 10718' 4-12' HES X NP, D = 3.813' (BBUND CT LNR) 10721' 3-1/2- X 3-3/16' XO, D = 2.786' 10740' 10740' 4-1/2' MULESHOE WLEG, 10841' 4-12'HES X NIP, D=3.813' 10$$9' 7' X 4-12' BKR S3 PKR, D = 3.875' 10912' 4-12' HES X NP, D = 3.813' BEHIND 10937' CT LNR = 10932' 4-12' HES XN NP, D 3.726 10946' 10946' 4-12' WLEG, D = 3.958' 10949' 10946' 7- X 4-12' BKR ZXP PKR, D = 4.375' 11069' 11148' MILLOUT WINDOW (J -07B) 11148'-11156- PEF FORATION SL MMW RY REL LOG. BKR RPM ON 01-28-19 ANGLE AT TOP P9;ff=: 102-912207- Note- 02'@12207'Note: Refer to Production DB for historical cert data = 2.tlb- PBTD ^w PUP JT w/RA TAG 13-3/16' X 2-7/8' XO, D = 2.377' 1 DATE REV BY OOMMBNTS DATE FfV BY COMMENTS 10104f77 ORIGINAL COMPLEFION 01/30/19 ZB/JMD FINAL ODEAPPROVAL 06111196 SBR SIDETRACK(J-07A) 01/31/19 BG/JND PHiFS(0129/19) 12102/02 ODWIKK RWO SUSPENDED 02/07/19 CJWJMD GLV C/O (01/31/19) 07106104 DCRfKAI1 RWO 0225/19 JNJJM) ADDED OKB, REF, BF & COPD PFO 01124/19 N-CDR2 CTD ST (J -07B) 0128/19 JMD DR -G HO CORRECTIONS PRUDHOE BAY LINT WELL: J -07B PERMIT No: 218-122 AR No: 54029-20241-02 SEC 9, T11 N, R13F-849 FN- & 804' FB- BP ELBP Exploration (Alaska) North America - ALASKA - BP Operation Summary Report Page 1 of 12 Common Well Name: J-07 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 1/10/2019 End Date: 1/20/2019 X3 -0197K -C: (1,534,876.00 ) ___- Project: PBU Site: _ J Rig Name/No.: CDR -2 Spud DatetTime: 7/25/1977 12:00:OOAM Rig Release: 1/24/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPU01: USA00000372 Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Him Task Cade NPT Total Depth Phase Description of Operations (hr) _ lush) 1/10/2019 10:00 - 14:30 4.50 RIGID P PRE RELEASED RIG FROM P -04A FINISH RIG DOWN. PULL OFF WELL _ INSTALLJEEPS 14:30 - 1830 4.00 RIGID P �, PRE MOVE RIG FROM P -PAD TO J -PAD 18:30 - 22:00 3.50 RIGU P III PRE ARRIVE ON PAD VERIFY PRESSURE ON IA / OA. SHUTALL VALVES. LAY DOWN HERCULITE AND 12 X 12 CHOCK BLOCK. PJSM FOR PULLING OVER WELL PULLSUB OVER WELL, SPOTMUDMODULE 22:00 - 00:00 2.00 RIGU P PRE ACCEPTRIGAT22:00 BEGIN RIG U_P_CHECKLISTS 1/11/2019 0000 - 06.00 6.00 RIGU P PRE CONTINUE WITH RIG UP CHECKLIST PERFORM LTT BETWEEN MASTER AND SWAB ,TO 3500# GOOD TEST RIG UP ANCILLARY EQUIPMENT AROUND RIG. WELL SUPPORT RIGGING UP FLOW BACK TANK INSTALL MPD LINE. 06:00 - 08.30 2.50 RIGU P PRE RIG DOWN SLINGS ON BOP STACK PREP RIG FLOOR FOR BOP TEST. CHECK VALVE LINEUP THEN CIRCULATE WARM WATERAROUND. - GREASE RIG VALVES THAT WILL BE TESTED. OPEN BLEEDERS WHILE CIRCULATING TO PURGE AIR OUT OF SYSTEM. 08:30 - 10:00 1.50 BOPSUR P PRE PJSM WITH CH2 GREASE CREW. GREASE TREE VALVES. PJSM WITH NABORS CREW FOR TESTING BOPS. DRILLER AND WSL REVIEW PRESSURE XCHECK VERIFICATION CHECKLIST. LINE UP VALVES FOR SHELL TEST AGAINST MASTER VALVE. SHELL TEST TO 250 / 4500 PSI, GOOD. CALL AOGCC REP MATT HERRERA TO COME OUT AND WITNESS. _ 1000 - 1400 4.00 BOPSUR P PRE TEST BOPS AS PER AOGCC AND BP GUIDELINES TO 25013,500 PSI: TEST 1: BLIND / SHEARS, R1, BL1A, B1, B4 - PASS TEST 2: ANNULAR (2-3/8"), TIW2, B3, B2, BL1 - PASS TEST 3: UPPER 2-3/8"PIPE /SLIPS, TIW1, BL2, R2, T2, C15 - PASS TEST 4: C16, T1, C11 -PASS TEST 5: VBR (2-3/8"), C7, C9, C10, TV2 C10 LEAKING, CYCLE AND GREASE. RE -TEST IS GOOD. C10-FAIL/PASS C9, C7, TV2-PASS TEST 6: LOWER 2-3/8" PIPE / SLIPS, C5, C6, C8, TV1-PASS TESTI: CHOKEA, CHOKE C- PASS Printed 2120/2019 9:00:41AM **All depths reported in Drillers Depths'" North America - ALASKA - BP Operation Summary Report Common Well Name: J-07 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 1/102019 End Date. 1/20/2019 X3 -0197K -C: (1,534,876.00 ) Protect: PBU Site: J Page 2 of 12 Rig Contractor NABORSALASKA DRILLING INC. Active datum: KB @75.80us8 (above Mean Sea Level) BPUOI: USA00000372 Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations _ (hr) .. (usft) :00 14 - 1645 2.75 BOPSUR P PRE CREW CHANGEAND PJSM WITH ONCOMING CREW. REVIEW DRAWDOWN TEST PROCEDURE. FLUIDAERATED. PUMP VOLUME FORWARD CONDUCT DRAWDOWN TEST, RECORD CLOSING TIMES. TEST GAS ALARMS. RECONFIGURE TEST JOINT FOR REMAINING 'BOP TESTS. TEST 6: ANNULAR (3-12"), C1, C4 ANNULAR HAS SLOW DRIP. LINE UP _VALVES FOR TEST 10 CYCLE ANNULAR AND RETEST, GOOD. - 22:30 ANNULAR - FAIL / PASS, C1, C4 - PASS BOPSUR _TEST 9: VBRS (3-1/2"), C2, C4 - PASS 1645 - 21:00 4.25 BOPSUR P PRE PREP FOR TEST 10. 'REMOVE TEST JOINT. INSTALL DRILLING RISERS / OTS EQUIPMENT. BLEEDING AIR PRESSURE OFF COIL. TAKING BACKWARDS AWHILE LOAD COIL WITH FRESHWATER TO HELP EVACUATE AIR. PUMP AT 1.5 BPM. REMOVE FLOATS FROM LOC. MAKE UP UPPER QUICK 21:00 - 2200 1.00 BOPSUR P PRE STAB INJECTOR FLUIDAERATED. PUMP VOLUME FORWARD .� TO FLUID PACK. LINE UP _VALVES FOR TEST 10 22:00 - 22:30 0.50 BOPSUR P PRE TEST#101RV/PACKOFF/C9&C10 BACKWARDS ATTEMPT TO GET LOW PT. LEAKINGAT C16BL. TROUBLESHOOT. C9 LEAKING. GREASE / CYCLE. PERFORM 250 PSI LOW/ 3500# HIGH IRV/PACKOFF/C10 BACKWARDS PASS C9 FAIL/ PASS _ 2230 - 00:00 1.50 BOPSUR P PRE PJSM WITH CREW. VALVE CREWTORQUED TREE WHILE INJECTOR STACKED ON IT. 1/122019 22:30 - 00:00 1.50 KILLW P PRE BULLHEAD KILL - PRESSURE UPAGAINST MASTER TO 1500# WITH METHANOL -10 BELS SPEAR OF METHANOL 1500# 0 1.5 BPM - 290 BBLS OF 1% KCI -4.7 BPM @ 2600# 0000 - 0400 4.00 KILLW P PRE FINISH WITH TORQUEING TREE BOLTS. INSTALL FLOATS. PRESSURE TEST TO 3500# PASSED PRESSURE TEST UQC. _ DISPLACE COIL OVER TO DRILLING MUD. 04:00 - 06:00 2.00 KILLW P PRE PJSM, REVIEW PROCEDURE FOR PULLING TWC PRIOR TO BULLHEAD. FLUID PACK BPV LUBRICATOR WITH MEOH AND PT TO 250 / 3500 PSI, GOOD. 0600 - 0645 0.75 KILLW P PRE BLEED DOWN BPV LUBRICATOR, NOT BLEEDING OFF. TROUBLESHOOT. LINE TO TIGER TANK IS FROZEN. 06:45 - 08:30 1.75 KILLW N PRE PJSM WITH NABORS CREW FOR CLEARING LINE TO TIGER TANK. HARDLINE CREW COMING TO HELP THAW OUT THE LINE. WARM UP RIG SIDE OF HARDLINE AND DISCONNECT BLEED HOSE, WARM IT UPAND Printed 2/202019 9:00:41AM **Ali depths reported in Drillers Depths" North America - ALASKA - BP Page 3 or 12 Operation Summary Report Common Well Name: J-07 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 1/102019 End Date. 1/20/2019 X3 -0197K -C: (1,534,876.00 ) Project: PBU _ - -- Site: J Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB @75.80usft (above Mean Sea Level) BPUOI: USA00000372 Date From - To Him Task Code NPT Total Depth Phase Descripbon of Operations (hr) _(usft) 0830 - 1030 2.00 KILLW N PRE PJSM WITH HARDLINE CREWAND NABORS FOR THAWING REST OF LINE. WRAP LINE WITH VISDUEEN AND HEAT FROM BOTH ENDS. TWO MORE HEATERS ARRIVE, HEAT LINE FOR ABOUT HOUR. 10.30 - 11.00 0.50 KILLW N PRE TRYTO PURGE THE LINE WITHAIR FROM THE RIG SIDE. FLUID IS SEEN LEAKING OUT THE HARDLINE FROM A SPLIT IN THE LINE, ABOUT 2 FEET FROM A UNION AND MIDWAY BETWEEN THE 11.00 - 13'.30 2.50 KILLW N 1330 - 1600 2.50 KILLW N RIG AND THE TIGER TANK ABOUT I GAL OF FRESH WATER HAS LEAKED OUT, CAUGHT IN CONTAINMENT. CLEAR AREA, DISCUSS PLAN FORWARD WITH HARDLINE CREWAND RIG CREW. NOTIFY SR WSLAND CTD SUPT. PRE HOOK UPAVAC TRUCK TO THE RIG SIDE OF THE HARDLINE, EVACUATE FLUID FROM THE SPLIT TO THE RIG. CONTINUE HEATING THE TANK SIDE OF THE HARDLINE, CHECK OCCASIONALLY TO SEE IF ITS THAWED. _ PRE ABLE TO PUSH AIR FROM THE TIGER TANK BACK TOWARDS THE RIG. EVACUATE ALL REMAINING FLUID FROM HARDLINE WITH VAC TRUCK. KNOCKAPART HARDLINE, TWO MORE JOINTS ARE FOUND WITH SPLITS. REMOVE ALL HARDLINE AND MAKE UP NEW LINE FROM RIG TO TIGER TANK. PRESSURE TEST LINE TO TIGER TANK TO 250 / 3500 PSI, GOOD. 16:00 - 20:30 4.50 KILLW P —i. PRE PJSM WITH VALVE CREWAND RIG CREW FOR PULLING TWC. PUMP 10 BBLS MEOH INTO STACKAND OUT 2030 - 2100 0.50 KILLW P 21.00 - 22.30 150 KILLW P STAINLESS STEEL LINE TO TIGER TANK VERIFY RETURNS. PRESSURE TEST BPV LUBRICATOR TO 3500 PSI, GOOD. PULLTWC. 1500rf ON WELLBORE. PURGE LUBRICATOR WITH AIR. OFFLOAD LUBRICATOR. VALVE RECOVERED WITH SEAL INTACT PRE PERFORM PRESPUD WITH ROY CREW AAR FOR BULLHEAD / PULL TWC WITH ROY CREW PRE PJSM, MAKEUP STINGER AND NOZZLE STAB INJECTOR. FLUID PACK FOR LUBRICATOR BREAK TEST. 250 PSI Printed 2202019 9:00:41AM **All depths reported in Drillers Depths-- North America - ALASKA - BP Operation Summary Report Page 4 of 12 Common Well Name: J-07 AFE No Event Type. RE-ENTER- ONSHORE (RON) Start Dale: 1/10/2019 End Date: 1/2012019 X3 -0197K -C: (1,534,876.00 ) Project: PBU -- - Site: J Rig Name/No.: COR -2 Spud Daterrime: 7/25/1977 12:00 OOAM Rig Release: 1/24/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000372 Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr)_ — (usft) 1/13/2019 00:00 - 01:25 1.42 KILLW P PRE BULLHEAD KILL CONT'D -COMPLETE PUMPING A TOTAL OF 280 BBLS OF 1% KCL. - PUMP 20 BBLS OF 8.6PPG OD -N PILL (HI VIS) - PUMP 152 BBLS OF 8.6 PPG QD-N - DRILLING MUD PUMPED AT 1980 PSI @ 4.5 BPM. - PRESSURE INCREASE WHEN HIVIS HIT OPEN PERFS. -SWAPPED TO COIL. PUMPED AT HIGH RATE OUT TO TIGER TANK TO FLUSH WATER OUT END OF COIL. OPEN SWAB WHEN PRESSURE HIT ZERO. PUMP ACROSS TOP. WHEN CLEAN _F_LU_ID_ BRING INSIDE. 01:25 - 0200 0.58 KILLW P PRE PERFORM 30 MIN FLOW CHECK WHILE BUILDING BHA#1 WELLSTATIC. FILL HOLE AFTER 30 MIN. 1.1 _ BBL HOLE FILL. (2.2 BPH LOSS RATE) 02:00 - 03:00 1.00 STWHIP P WEXIT PJSM, DISCUSS BHA#1 MAKE UP. DISCUSS WELL CONTROL. MAKE UP WINDOW MILLING BHA INJECTOR ON: 03:00 03.00 - 04:00 1.00 STWHIP P WEXIT RIH WITH 3.80" WINDOW MILLING BHA#1 - RATE: 0.46 BPM IN, 0.99 BPM OUT. CIRC PRESSURE: 610 PSI MUD WEIGHT: 8.52 PPG IN, 8.45 PPG OUT 04:00 - 05:00 1.00 KILLW P WEXIT DURING WALK THROUGH. TEFLON SPACER ON GRIPPER BLOCKS WAS SEEN WORKING ITS WAY OUT, STOP MOVEMENT. LOCKOUT INJECTOR. (2) CARRIER BLOCKS TABS BROKEN. TOOLPUSHER DISCUSSED WITH TOWN. 05:00 - 06:15 1.25 KILLW N WEXIT DECISION TO PULLOUT OF HOLE TO REPAIR. 0615 - 0700 0.75 KILLW N WEXIT NEAR SURFACE, 10 MIN FLOWCHECK IS GOOD. PJSM WITH NABORS AND BHI CREW FOR UD BHA. UD COILTRAK AND HANG 2 JTS PH6 • MOTOR FROM PDL WINCH. 0700 - 11:30 4.50 STWHIP N WEXIT PJSM WITH TOOLPUSHER AND MECHANIC FOR REPLACING RETAINING TABS ON GRIPPER BLOCKS. PERFORM LO/TO ON INJECTORAND REEL WHEN NECESSARY. 11:30 - 12:30 1.00 STWHIP N WEXIT INJECTOR REPAIRS FINISHED. PJSM WITH NABORSAND BHI FOR RUNNING BHA, MAKE UP BHA#2, SAMEAS BHA#1. MILLAND REAMER 3.80" GO, 3.79" NO-GO. TEST QTS TO 3,500 PSI, GOOD. 12.30 - 14.45 2.25 STWHIP P WEXIT RIH BHA #2. 1445 - 15'.00 0.25 STWHIP P WEXIT LOG GR TIE-IN FROM 10460'. CORRECT -29' Printed 2/20/2019 9:00:41AM **All depths reported in Drillers Depths"' North America - ALASKA - BP Operation Summary Report Common Well Name: J-07 Event Type: RE-ENTER- ONSHORE(RON) StartDate: 1/10/2019 End Date: 112012019 Project: PBU Site: J AFE No K3-0197 (1,534,876.00 ) Page 5 of 12 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000372 Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ _ (usft) 15:00 - 16:00 1.00 STWHIP P 11,148.00 WEXIT CONTINUE RIH. AT 10730' GETTING LIGHT RETURNS, AROUND PPG. SHUT OFF PUMP FOR FLOWCHECK 10 MIN FLOW CHECK IS GOOD NO FLOW. TAKE RETURNS TO TIGER TANK FOR AWHILE UNTIL THEY CLEAR UP. NOTIFY CTD SUPT AGREE ON PLAN FORWARD. PASS TUBING STUBAT 35 FT/MIN, NOTHING SEEN. RUN TO 11,100' AND CLOSE EDC. UP WT HERE IS 46K. RIH CAREFULLY, LIGHT TAG AT 11,148' AT 0.5 BPM. 16:00 - 17:30 1.50 STWHIP P 11,148.00 WEXIT PICK UPAND GO TO FULL RATE. EASE DOWN AND START WINDOW AS PER BTT REP. OUT DENSITY STILL FLUCTUATING 7.8-8.4 PPG STILL GOING OUT TO TIGER TANK WITH 'RETURNS. 17:30 - 1� 0.50 STWHIP P 11,148.00 WEXIT 'AFTER i B/U RETURNS HAVE CLEANED UP. PURGE RISER OUT TO BLEED TRAILER THEN BRING RETURNS BACK INSIDE. PUMP DIESEL OUT TO TIGER TANK THEN PURGE THE LINE WITH AIR. CONTINUE MILLING WINDOW. 1800 - 21:15 3.25 STWHIP P 11,150.00 WEXIT MILL 3.80" WINDOW IN 4-1/2" LINER PER BAKER REP FROM 11148' MD TO 11150' MD TRATE: Z.ov or t9Ti56 ormi UU I - MUD WEIGHT: 8.57 PPG IN, 8.53 PPG OUT - DWOB: 1.83 — 3.7 KLBS - CIRC PRESSURE: 2050 PSI -NOT DRILLING OFF. PICKUP TO INCREASE RATE AT ZERO WOB 2115 - 00:00 2.75 STWHIP P 11,151.80 WEXIT MILL 3.80"WINDOW IN 4-1/2' LINER PER BAKER REP FROM 11148' MD TO 11151.8' MD - RATE: 2.70 BPM IN, 2.70 BPM OUT - MUD WEIGHT: 8.57 PPG IN, 8.51 PPG OUT -DWOB: 1.83-3.7 KLBS - FREE SPIN CIRC PRESSURE: 2481 PSI _ 1/14/2019 00:00 - 06:00 6.00 STWHIP P 11,151.80 WEXIT MILL 3.80" WINDOW IN 4-1/2" LINER PER BAKER REP FROM 11151.8' MD TO 11156' MD - RATE: 2.70 BPM IN, 2.69 BPM OUT - MUD WEIGHT: 8.56 PPG IN, 8.51 PPG OUT -DWOB: 1.9-2.6 KLBS - FREE SPIN CIRC PRESSURE: 2600 PSI ESTIMATED CASING EXITAT 11,156' 9:00:41AM **All depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name: J-07 Phase Description of Operations Event Type: RE-ENTER- ONSHORE(RON) Proiect: PBU - - Start Date. 1/10/2019 - Site: J - Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Ars Task (hr) 06:00 - 11:00 5.00 STWHIP Page 6 of 12 ALE No End Date. 1/20/2019 X3 -0197K -C.(1, 534, 876.00) BPUOI: USA00000372 Code NPT Total Depth (usft) Phase Description of Operations P 11,151.80 WEXIT MILL RATHOLE TO 11,167' -16:00 CONDUCT REAMING PASS, NO APPRECIABLE 4.00 MOTOR WORK SEEN. PUMP 10 BBLS LO / Al VIS SWEEPS AROUND. DRY DRIFT IS CLEAN. PICK UP FOR DYNAMIC FLOW CHECK GOOD, OPEN EDC, POOH. PUMP 3.9 BPM PULLING PAST 7" TUBING _ SECTION. 11,151.80 PROD1 AT 5,300' 2 BBL DISCREPANCY ON PITWATCH TRIP SHEET FOR LAST 1000. DRILLER'S IS OK. _ FLOW CHECK FOR 10 MIN IS GOOD, NO 11,350.00 PROW FLOW. CONTINUE POOH. SIMOPS: BUILD BHA#3 OFFLINE WHILE POOH, HANG FROM PDL WINCH. 11:00 - 12:30 1.50 STWHIP P 12:30 - 16:00 3.50 DRILL P -16:00 - 2000 4.00 DRILL P 20:00 - 21:30 1.50 DRILL P 11,151.80 WEXIT 10 MIN FLOWCHECK IS GOOD. PJSM FOR UD BHA. OPEN RISERAND INSPECT LAST 50' OF CT, NO FLAT SPOTS SEEN. UD BHA#2, HANG PH6 FOR UD LATER, OFFLINE. MILL IS 3.80" GO, 3.79" NO-GO. RUN BHA#3 INTO WELL, MAKE UP UQC AND INJECTOR. _ PRESSURE TEST QTS TO 3500 PSI, GOOD, 11,151.80 PROD1 RIH BHA#3. TIE-IN DEPTH FROM 10,450' CORRECT -27'. JUSTABOVE WINDOW, SHUT DOWN PUMP _ AND CLOSE EDC. 11,350.00 PROW DRILL 4.25' LATERAL FROM 11168' MD TO 11350' MD - FREE SPIN: 2940 PSI, 2.82 BPM - RATE: 2.82 BPM IN, 2.84 BPM OUT. CIRC PRESSURE: 2940-3040 PSI - MUD WEIGHT: 8.59 PPG IN, 8.52 PPG OUT, ECD: 9.94 PPG - ROP: 40 - 50 FT/HR, WOB: 1 - 2 KLBS - PERFORM WIPER UP TO 7" SECTION 11,350.00 PROW PERFORM LONG WIPER TRIP TO WINDOW FROM 11350' MD TO 10700' MD - RATE: 4.1 BPM IN, 4.1 BPM OUT. CIRC PRESSURE: 3310 PSI - PUMPED 10 BBLS OF LOVIS 110 BBLS OF HIVIS - JET 7" SECTION WITH SWEEPS. CONTINUE PUMPING - 50% CUTTINGS INCREASE WITH HIVIS SWEEP - LOG DOWN FOR TIE-IN FROM 10420' TO 10460' MD (FORMATION) WITH +2' CORRECTION - RIH ABOVE WINDOW. COME OFFLINE WHEN CUTTINGS STARTED TO SUBSIDE. TIE RA TAG INTO PDC RUN BACK TO BOTTOM. Printed 2/202019 9:00:41AM **All depths reported in Drillers Depths" North America - ALASKA- BP Operation Summary Report Page 7 of 12 Common Well Name. J-07 ARE No Event Type. RE-ENTER- ONSHORE (RON) Start Date: 1/10/2019 End Date: 1/20/2019 X3 -0197K -C: (1,534,876.00 ) Project: PBU Site: J Rig Name/No.: CDR -2 Spud Daternme: 7/25/1977 12:00:OOAM Rig Release: 1/24/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000372 Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Hire Task Code NET Total Depth Phase Description of Operations (hr) (usft) 21:30 - 0000 2.50 DRILL P 11,501.00 PROD1 DRILL 4-1/4" LITERAL FROM 10,700'MD TO 1/15/2019 00:00 - 02:00 2.00 0200 - 0300 1.00 0300 - 04:00 1.00 04:00 - 19:30 15.50 1930 - 0000 4.50 1/16/2019 00.00 - 0015 0.25 00:15 - 00:30 0.25 DRILL P 11,501.00 PRODt I DRILL P 11,547.00 PROD1 DRILL P 11,547.00 PROD1 DRILL - N- �- 11,547.00 PROD1 DRILL N 11,547.00 PROD1 DRILL N 11,547.00 PROD1 DRILL N 11,547.00 PROD1 Printed 2720/2019 9:00:41AM **All depths reported in Drillers Depths- 11501' MD - FREE SPIN: 3000 PSI, 2.82 BPM - RATE: 2.62 BPM IN, 2.83 BPM OUT. CIRC PRESSURE: 3000-3288 PSI - MUD WEIGHT: 8.61 PPG IN, 8.58 PPG OUT, ECD: 10.2 PPG - ROP: 85 FT/HR, WOB: 2.0 - 2.6 KLBS BLED IA FROM 1000# TO 170# WIPER TRIP TO WINDOW PUMP HIVIS SWEEP. OPEN EDC PUMP BOTTOMS UP WHILE JETTING 7". CALIBRATE AT WINDOW FOR ANNULAR FRICTION. 59 PSI / 1000' LOG •1 TO RA, RUN BACK TO BOTTOM DRILL 4-1/4" LATERAL FROM 11501' MD TO 11547' MD - FREE SPIN: 3032 PSI, 2.84 BPM RATE: 2.84 BPM IN, 2.84 BPM OUT. CIRC PRESSURE: 3032 - 3260 PSI - MUD WEIGHT: 8.63 PPG IN, 8.59 PPG OUT, ECD: 10.2 PPG - ROP: 40 FT/HR, WOB: 2.6-3.7 KLBS COUPLE STALLS. - WELL WENT ON 60 BPH LOSS RATE. SLOWLY RECOVERING TO 15 BPH - ATTEMPT TO DRILL AHEAD TO HEAL LOSSES. VERY QUICK TO TORQUE UP. -TIME DRILL, START GETTING MOTOR WORK. - PUMP #1 LEAKING AT SUCTION MANIFOLD. - PULL TO WINDOW. OPEN EDC. CIRCULATE AT WINDOW - RATE IN: 2.08 BPM RATE OUT: 1.84 BPM OUT - MUD WEIGHT IN: 8.61 PPG / MUD WEIGHT OUT: 8.58 - REPAIR MUD PUMP #1 - LOSSES 8-10 BBLS/HR WHILE CIRCULATING TEST PUMP #1 -ATTEMPT TO TEST PUMP #1, UNABLE TO KEEP PRIME. CONTINUE TO TROUBLE SHOOT -CIRCULATE AT WINDOW - RATE IN: 2.13 BPM RATE 01 BPM OUT - MUD WEIGHT IN: 8.59 PPG / MUD WEIGHT OUT: 8.58 - LOSSES 5-6 BBLS/HR WHILE CIRCULATING. TEST MUD PUMP 1 TO 4000 PSI FOR FIVE MINUTES -GOOD TEST RUN IN HOLE -CLOSED EDC -RIH -TIE IN TO RA MARKER AT 11157' -NO CORRECTION North America -ALASKA - BP Page 8 of 12 Operation Summary Report Common Well Name: J-07 APE No Event Type. RE-ENTER- ONSHORE (RON) Start Date: 1/10/2019 End Date 1/20/2019 X3 -0197K -C: (1,534,876.00) Prosect: PBU Site: J Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth _(hr) (usft). 00:30 - 04:00 3.50 DRILL P 11,671.00 04:00 - 04:40 1 0.67 DRILL P 11,671.00 aPUOI: USA00000372 Phase Description of Operations PROD1 DRILL 4-1/4" LATERAL FROM 11 54TMD TO 11671' MD - FREE SPIN: 2890 PSI, 2.84 BPM - RATE: 2.84 BPM IN, 2.69 BPM OUT. CIRC I PRESSURE: 3032 - 3260 PSI - MUD WEIGHT: 8.63 PPG IN, 8.59 PPG OUT, ECD: 10.1 PPG - ROP: 60 FT/HR, WOB: 2.6 - 3.5 KLBS NOTE: LOSSES DECREASED TO 4-6 BPH - PULL BACK THROUGH 11,547' TWO TIMES, SLIGHT OVERPULL SEEN. PRODt ' SWAB ON PUMP #2 IS LEAKING. ,PULLBACK TO WINDOW. CLOSETOA SCHEDULED WIPER TRIP HERE ANYWAY. 'KEEP AS DRILLED TF PULLING BACK THROUGH 11,547 FAULT AND SHALE ZONES. DISCUSS WITH ODE, DECIDE TO POOH FOR BIT SWAP DUE TO LOW ROP AND FORECAST TO DRILL THROUGH HIGHER CHERT ZONES LATER IN THE WELL. PULL THROUGH WINDOWAT 160L, 0.5 BPM, NOTHING SEEN. 0440 - 0500 0.33 DRILL P 11,671.00 PROD1 REPAIR SWAB ON PUMP #2. 0500 - 0800 3.00 T DRILL P 11,671.00 PROD1 POOH, PUMP 3.8/ 3.16 BPM PAST 7" CASING SECTION. PUMP 10 BBLS LO / HI VIS SWEEPS. MUD WEIGHT IN/OUT IS 8.63/8.58 PPG. HOLD 10.1 PPG ECDAT THE WINDOW WHILE POOH. 10 MIN FLOW CHECK NEAR SURFACE IS GOOD, NO FLOW. 08.00 - 0900 1.00 DRILL P 11,671.00 PROD1 PJSM WITH RIG CREW FOR CHANGING BHA. OPEN RISER AND INSPECT LAST 50' OF CT, NO FLAT SPOTS SEEN. INJECTOR OFF AT 08:30. UO BHA, BIT IS 3-3 WITH ONE TO BUTTON _ _ MISSING. _ 09:00 - 09:30 0.50 BOPSUR P 11,671.00 PROD1 CLOSE SWAB AND VAC OUT STACK FUNCTION TEST BOPS. 09:30 - 10:20 0.83 DRILL P 11,671.00 1 PROD1 MAKE UP 3" DRILLING BHA #4 - PICK UP 2-7/8' ULS MOTOR (1.56 DEG AKO) AND 3' COILTRAK TOOLS - MAKE UP 175"X 4.25" HYC BICENTER BIT WITH 13MM CUTTERS 1 - SURFACE TESTED COILTRAK TOOL. GOOD TEST. - PRESSURE TEST OTS TO 3500 PSI HIGH FOR X MINUTES - INJECTOR ON: 09:50 1020 - 1220 2.00 DRILL P 11,671.00 PROD? RIH WITH 3.0' DRILLING BHA #4 i- RATE: 0.57 BPM IN, 0.95 BPM OUT. CIRC PRESSURE: 1540 PSI - MUD WEIGHT: 8.58 PPG IN, 8.61 PPG OUT - LOG DOWN FOR TIE-IN FROM 10,450' WITH -29' CORRECTION 12:20 - 13:10 0.83 DRILL P 11,671.00 PROD1 LOG CCL DOWN ACROSS LINER TOPAREA. CLOSE EDC. PASS WINDOW WITH NO ISSUES. Printed 2/20/2019 9:00:41AM **All depths reported in Drillers Depths*` Common Well Name: J-07 Event Type: RE-ENTER- ONSHORE(RON) Project: PBU North America - ALASKA - BP Page 9 of 12 Operation Summary Report Start Date. 1/10/2019 End Date: 1/20/2019 Site: J APE No K3 -0197K -C:(1,534.876.00) Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB @75.80usft (above Mean Sea Level) BPUOI: USA00000372 Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) _ 13:10 --18:00 4.83 DRILL P 11,867.00 PROD? DRILL 4-114" LATERAL FROM 11671' MO TO 11867' MD - FREE SPIN: 3050 PSI, 2.79 BPM - RATE: 2.81 BPM IN, 2.76 BPM OUT. CIRC PRESSURE: 3032 - 3330 PSI - MUD WEIGHT: 8.65 PPG IN, 8.61 PPG OUT, ECD: 10.2 PPG - ROP: 60 - 90 FT/HR, WOB: 2 - 3 KLBS - AT 11180' PUMP 10 BELS LO / HI VIS SWEEPS -AT 11800' PULL200' WIPER TRIP. CLEAN _ PASS UP AND DOWN_ 18:00 - 00:00 6.00 DRILL P 12,011.00 PROD1 DRILL 4-1/4" LATERAL FROM 11867' MO TO 12011' MD - FREE SPIN: 3050 PSI, 2.79 BPM - RATE: 2.81 BPM IN, 2.76 BPM OUT. CIRC PRESSURE: 3032-3330 PSI - MUD WEIGHT: 8.65 PPG IN, 8.61 PPG OUT, ECD: 10.2 PPG - ROP:20-40 FT/HR, WOB: 2 - 3 KLBS - AT 11 929'PUMP 10 BBLS LO / HI VIS SWEEPS -AT 11948' PULL200' WIPER TRIP. CLEAN PASS UPAND DOWN NOTE:12000' SAMPLE SHOWED 40% CHERT 1/17/2019 0000 - 0300 3.00 DRILL P T 12,110.00 PROD1 DRILL 4-1/4" LATERAL FROM 12011' MD TO 12110'MD - FREE SPIN: 3226 PSI, 2.88 BPM - RATE: 2.88 BPM IN, 2.86 BPM OUT. CIRC PRESSURE: 3300-3400 PSI - MUD WEIGHT: 8.68 PPG IN, 8.62 PPG OUT, ECD: 10.2 PPG _ - ROP:20.40 FT/HR, WOB: 2 - 3.5 KLBS 0300 - 0530 2.50 DRILL P 12,110.00 PROD1 WIPER TRIP TO 10740' -PUMP 5X5 LOW/ HI VIS SWEEP. -PULL TO WINDOW OPEN EDC -PUMP 10X10 LOW/HI VIS SWEEP -PULL TO 7" 10841-10740 -PUMP BOTTOMS UP WHILE JETTING 7". -TIE IN +3.5 TO RA, RUN BACK TO BOTTOM 0530 - 0800 2.50 DRILL P 12,120.00 PROD1 DRILL 4-1/4" LATERAL FROM 12110'MD TO 12132' MD - FREE SPIN: 3226 PSI, 2.88 BPM - RATE: 2.88 BPM IN, 2.86 BPM OUT. CIRC PRESSURE: 3300 - 3400 PSI - MUD WEIGHT: 8.68 PPG IN, 8.62 PPG OUT, ECD: 10.2 PPG - ROP:20-40 FT/HR, WOB: 2 - 3.5 KLBS 08:00 - 11:00 3.00 DRILL P 12,132.00 PROD1 AT 12132' ENCOUNTER SUSTAINED, LOW ROP. POOH FOR BIT. MONITOR WELL FOR 10 MINUTES: STATIC - MUD WEIGHT: 8.68 PPG IN, 8.64 PPG OUT - RATE: 3.75 BPM IN, 3.69 BPM OUT OPEN EDC, POH AND JET 7' SECTION SLOWLY. - RATE: 3.74 BPM. CIRC PRESSURE: 3300 PSI - PU 49 KLBS Printed 2/2012019 9:00:41AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page W of 12 Operation Summary Report Common Well Name. J-07 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date'. 1/10/2019 End Date. 1/20/2019 X3 -0197K -C: (1,534,876.00 ) Project: PBU Site: J Rig Nsme/No.: CDR -2 Spud Date/Time: 7/25/1977 12.00:OOAM Rig Release: 1/24/2019 Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI: USA00000372 Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ _ (usft) 11:00 - 22:00 11.00 DRILL N 12,132.00 i PROD1 WHILE POOH ATA DEPTH OF 1654' A PROBLEM IS SEEN ON THE ODS REEL HUB. STOP HERE AND TROUBLESHOOT, DEVELOP PLAN FORWARD. THE HUB MECHANISM APPEARS TO HAVE SEPARATED SLIGHTLY FROM THE BLOCK. FLAG OFF PIPE SHED AND REEL AREAAS EXCLUSION ZONE. HOOK UP SLINGS TO REELAS PRECAUTIONARY RETENTION. DISCUSS PLAN FORWARD WITH ANC TEAM, DECISION IS MADE TO WELD ATEMPORARY REPAIR TO THE HUB TO ALLOW US TO POOH. MAINTAIN 10.1 PPG WHILE PARKED. LOSSESABOUT 2 BBL/HR. HOLD PJSM WITH CREW AND WELDER FOR TEMPORARY REPAIR OF HUB WELD HUB RECONNECT COLLECTOR SECURE WORKAREA RIG DOWN TEMPORARY RIGGING SUPPORTING REEL. - 22:00 - 00:00 2.00 DRILL N 12,13200 PROD1 POOH —HOLD PJSM WITH CREW -POOH AT 10' PER MINUTE, INSPECTING HUB AT 100' AND EVERY 500' AFTER. T -MAINTAIN 10.1 PPG WHILE POOH. 1/18/2019 0000 - 00:15 0.25 DRILL N 12,132.00 PROD1 POOH -HOLD PJSM WITH CREW -POOH AT 10' PER MINUTE -MAINTAIN 10.1 PPG WHILE POOH. 0015 - 0115 1.00 DRILL P 12,132.00 PROD1 STAND BACK BHA -FLOWCHECK WELL FOR 10 MINUTES -NO FLOW -BREAK INJECTOR FROM LUBRICATOR -STAND BACK LATERAL BHA -BIT RUNG OUT 5-1 RUNG OUT/CHIPPED TEETH_ _ 01:15 - 03:30 2.25 DRILL N 12,132.00 PROD1 BLOW DOWN REEL -ATTEMPT TO BLOW DOWN REEL WITH AIR, UNABLE TO MOVE DRILLING FLUID WITH AIR -RIG UP TO CIRCULATE COIL TO WATER -DISPACE COIL TO WATER -BLOW DOWN COIL WITH RIG AIR COMPRESSOR _ 0330 - 06:00 2.50 DRILL N 12,132.00 PROD1 CLOSE SWABAND PUT 10.1 PPG ON THE WELL. REMOVE AND REPLACE REEL HUB AND SPINDLE -HOLD PJSM WITH CREW -LOTO REEL -FOLLOW NABORS PROCEDURE FOR CHANGE OUT OF PILLOW BLOCKAND SPINDLE. PERFORM LO / TO ON REEL, INJECTOR, LEVELWIND CIRCUITAND VALVES LEADING TO REEL (SRB, SR9, IRV) Printed 2/20/2019 9:00:41AM ••All depths reported in Drillers Depths" Printed 2120/2019 9:00:41AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 11 of 12 Operation Summary Report Common Well Name. J-07 AFE No Event Type: RE-ENTER- ONSHORE (RON) Stan Date. 1/10/2019 End Date. 1/20/2019 X3 -0197K -C: (1,534,876.00 ) Project: PBU Site: J Rig Name/No.: CDR -2 Spud Date/Time. 7/25/1977 12:00:00AM Rig Release: 1/24/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000372 Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Hire Task Code NPT Total Depth Phase Description of Operations __ (hr) _ _ (usft)_ _ 06:00 - 13:00 7.00 DRILL N 12,132.00 PROD1 REMOVE INNER REEL IRON AND WASH PIPE. REMOVE COUNTER AND LEVELWIND ASSEMBLY, HANG OFF. REMOVE REEL CHAIN GAURD AND DRIVE GEAR. UNBOLT PILLOW BILOCK FROM REEL STAND. OPEN BACK DOORS AND USE LOADER WITH STINGER TO REMOVE OLD PILLOW BLOCK AND SPINDLE. 13-.00 - 0000 11.00 DRILL N 12,132.00 PROD1 -PILOT BUSHING HAS COME OFF WITH THE HUB. -CALL GBR WELDER OUT TO WELD THE PILOT BUSHING BACK ONTO THE REEL. -WELD PILOT BUSHING ONTO THE REEL. -REINSTALL HUBS AND TORQUE BOLTS. -REINSTALL PILLOW BLOCKS -REINSTALL WASH PIPE -REINSTALL LEVELWIND AND DRIVE GEAR -REINSTALL GUARDS AND COUNTERS. -INSPECTAREA TO BE SURE ALL TOOLS ARE REMOVED _ -REMOVE LOCKOUTS _ 1/19/2019 00.00 - 0200. 2.00 _ DRILL N 12,132.00 PROD? .REEL REPAIR -CHECK ELINE-GOOD -INSTALL NOZZLE -STAB INJECTOR -DISPLACE COIL TO QUICK DRILL N -TEST LINE BEHIND INNER REEL VALVE TO _250/4000 PSI FOR 5 MINUTES EACH -PASS _ 0200 - 03.00 1.00 DRILL P 12,132.00 PROD? MAKE UP 3" DRILLING BHA#5 - PICK UP 2-7/8° ULS MOTOR (1.56 DEG AKO) AND 3" COILTRAK TOOLS - MAKE UP 3.75'X 4.25" HYC BICENTER BIT WITH 13MM CUTTERS - SURFACE TESTED COILTRAK TOOL. GOOD TEST. - PRESSURE TEST QTS TO 3500 PSI HIGH FOR X MINUTES - INJECTOR ON: 0300 03:00 - 06:00 3.00 DRILL P 12,132.00 PROD1 RIH WITH 3.0" DRILLING BHA#5 - RATE: 0.40 BPM IN, 0.54 BPM OUT. CIRC PRESSURE: 1500 PSI - MUD WEIGHT: 8.66 PPG IN, 8.67 PPG OUT - LOG GR FROM 10,450' CORRECT -31'. 0600 - 0645 0.75 DRILL P 12,132.00 PROD1 CONTINUE RIH. PASS TUBING STUB HIGH SIDE, NOTHING SEEN. CLOSE EDC. PASS WINDOWAT 160L, 0 PUMP, 20 FT/MIN NOTHING SEEN. RIH, KEEP AS DRILLED TF AND REDUCE PUMP THROUGH SHALES. Printed 2120/2019 9:00:41AM **All depths reported in Drillers Depths" Common Well Name: J-07 Event Type: RE-ENTER- ONSHORE (RON) PBU North America - ALASKA - BP Operation Summary Report AFE No Start Date: 1/10/2019 End Date. 1/20/2019 X3 -0197K -C: (1,534,876.00 ) Site'. J Page 12 of 12 Rig Name/No.: CDR -2 Spud Datefrime: 7/25/1977 12:00:00AM Rig Release: 1/24/2019 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000372 Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 01545-1406 1400 7.25 DRILL P 12,260.00 PROD1 DRILL 4-1/4" LATERAL FROM 12132' MD TO 12260' MD - FREE SPIN: 3220 PSI, 2.90 BPM - RATE: 2.91 BPM IN, 2.91 BPM OUT. CIRC PRESSURE: 3300 - 3600 PSI - MUD WEIGHT: 6.73 PPG IN, 8.66 PPG OUT, ECD: 10.39 PPG AT BIT ROP: 10-30 FT/HR, WOB: 2-3.5 KLBS - SLOW ROP DRILLING HIGH CHERT ZONE AT 12,172' TAKE SLIGHT LOSSES, PICKUP IS CLEAN. - CONTINUE DRILLING, LOST ABOUT 3 BBLS THEN HEALED UP. - AT 12,197' START TAKING LOSSES ABOUT 10-15 BBUHR 14.00 - 1730 3.50 DRILL P 12,320.00 PROW DRILL 4-1/4" LATERAL FROM 12260' MD TO 12320' MD '- FREE SPIN: 3250 PSI, 2.86 BPM - RATE: 2.86 BPM IN, 2.86 BPM OUT. CIRC PRESSURE: 3300-3660 PSI ' - MUD WEIGHT: 8.73 PPG IN, 8.66 PPG OUT, ECD: 10.38 PPG AT BIT -ROP: 10-50 FT/HR, WOB: 2-3.5 KLBS - NEAR TD PUMP 10 BBLS EACH LO VIS 19.8# SWEEPS. _ 1730 - 2030 3.00 DRILL _ P T 12,321.00 PROD1 WIPERTRIPS -WIPER TO WINDOWAT 2.8 BPM AT 3000 PSI -OPEN EDC -PUH TO T' AT 10841' TO 10740' AND JET T' AT 3.65 BPM AT 3400 -ONCE CUTTINGS HAVE CLEARED UP PUH TO 10375' FOR TIE IN -TIE IN FROM 10420' TO 10454' +3' CORRECTION -R01H TO WINDOW AT 3.63 BPM AT 3433 PSI CLOSE EDC -PASS THROUGH WINDOW WITH PUMPS OFF -RIH FROM BELOW WINDWOAT 2.77 BPM AT 3394PSI. -SOFT TAG TO AT 12321.3 MD 2030 - 00.00 3.50 DRILL P 12,321.00 PRODt POOH -DYNAMIC FLOW CHECK FOR 10 MINUTES -POOH TO WINDOW PUMPING AT 2.72 BPM AT 3139 -OPEN EDC -SWAP TO 9.8 PPG -POOH PUMPING AT 2.35 BPM AT 2112 PSI.. - PAINT YELLOW FLAG AT 10479.48' BIT DEPTH (10400' EDP) - PAINT WHITE FLAG AT 9279.48' BIT DEPTH (9200' E_OP) 1/20/2019 0000 - 01:30 1.50 DRILL P 12,321.00 PROD1 POOH -MUD WEIGHT IN/OUT 9.83 PPG PUMPING AT 2.3 BPM 1999 PSI LOSING 7-10 BPH 01:30 - 02:00 D.50 DRILL P 12,321.00 PROD1 LAY DOWN BHA -BREAK OFF INJECTOR it -LAYDOWN BHA BIT WAS GRADED AS 1-1. Printed 2/202019 9:00:41AM **All depths reported in Drillers Depths** Common Well Name: J-07 Event Type: COM- ONSHORE (CON) Project: PBU — --- North America - ALASKA - BP Operation Summary Report Start Date: 1/20/2019 End Date. Site: J Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB @75.80usft (above Mean Sea Level) Date From - To 12012019 02:00 - 05:00 Him Task (hr) 3.00 CASING 05',00 - 07:00 1 2.00 07'.00 - 08:00 1.00 08:00 - 09:15 1.25 09:15 - 09:45 0.50 0945 - 1700 7.25 17:00 - 19:15 2.25 me: 7/25/1977 12:00:OOAM Code NPT Total Depth Phase (usft) P 12,321.00 RUNPRD Page 1 of 9 AFE No %3 -0197K -C: (844,491.00 ) Rig Release: 1/24/2019 BPUOI: USA00000372 Description of Operations PJSM, REVIEW STEPS FOR PREPARING LINER. - LO E -LINE. MWD REMOVE UQC. INSTALL BOOT ON E -LINE. - MAKE UP TWO JOINTS OF 2-3/8" BTS-6. -STABONWELL. PUMPAT4.5 BPM TO PUMP SLACK OUT. - PERFORM 3 CYCLES. E -LINE NO LONGER MOVING - PUMP 214' OF POSSIBLE 280' OUT. - BOOT E -LINE. MAKEUP STINGER AND CASING P 12,321.00 RUNPRD PJSM FOR LAUNCHING DRIFT BALL. -LOAD AND LAUNCH 7/8" DRIFT BALL. - PRESSURE UP TO 35001 DUMP. COME ONUNEAT3.5BPM. BALLROLLING - SHUT DOWN AND BREAK DOWN. _RECOVERED 7/8" STEEL BALL. CASING P 12,321.00. RUNPRD PREP RIG FLOOR FOR RINNING LINER. VERIFY PIPE COUNT WITH WSL, DRILLER AND BTT REP. CHECK SLIPS, ELEVATORS AND RUNNING EQUIPMENT. INSPECT TONGS AND DIES. LATCH UP SAFETY JT WITH 3-1/4" ELEVATORS THEN LAY IT BACK DOWN. PJSM WITH NABORS CREW AND BTT FOR WU LINER. WELL IS ON 6-B BBUHR LOSSES. FILL AT LEAST EVERY 30 MIN. _ CASING P 12,321.00 RUNPRD MIN LINER AS PER APPROVED SUMMARY AND NABORS PROCEDURE. CASING P 12,321.00 RUNPRD AFTER JT #8 CONDUCT Di DRILL WITH MICA'SCREW. CREWS RUN THE JOINT ON THE SKATE BACK DOWN TO THE PIPE SHED AND RUN SAFETY JOINT TO RIG FLOOR. LATCH UP SAFETY JOINTAND TORQUE UP. DRILLER SIMULATES SHUTTING IN WELL, ALL CREW REPORTS TO ASSIGNED STATIONS. WELL SECURED IN 6 MIN. HAD TROUBLE LATCHING THE LIFT SUB ON THE SAFETY JOINT, TRY LATCHING THE SAFETY JOINT SEVERAL MORE TIMES TO FIND THE BEST POSITION THEN MARK THE JOINTS POSITION FOR FUTURE REFERENCE. CONDUCTAAR. CASING P 12,321.00 RUNPRD CONTINUE M/U LINER. FILL LINER AND WELL EVERY 30 MIN. M/U LINER RUNNING TOOLAND 6 JTS BTS -6. INJECTOR ON: 16:45, PRESSURE TEST OTS TO 3,500 PSI. PUMP 15 BBLS 8.6#MUD AROUND. CASING P 12,321.00 RUNPRD RIH WITH LINER BHA. -RIH TO WINDOW FLAG -29.51' CORRECTION. Printed 211 9:01.14AM **AAI depths reported in Drillers Depths" North America - ALASKA - BP Operation Summary Report Common Well Name'. J-07 Event Type: COM- ONSHORE (CON) Start Date: 1/20/2019 Eno Date: Project: PBU Site: J Rig Name/No.: CDR -2 Spud DatefTime: 7/25/1977 12:00:OOAM AFE No X3 -0197K -C. (844A91 00 ) Page 2 of 9 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI. USA00000372 Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ (us() - 19:15 - 2200 275 CASING P 12,321.00 RUNPRD SWAP WELL BORE TO QUICK DRILL IN -PUMP AT .88 BPM AT 1850 PSI -LOSSES AT INTITIAL CIRCULATION 10-14 BPH -LOSSES AT FINAL CIRCULATION -4-8 BPH -END OF CIRC PICK UP WT 53K, DOWN WT _ 23K fFIR 22:00 - 23:30 1.50 CASING P 12,321.00 RUNPRD WITH LINER BHA -RUN THROUGH WINDOW AT 40 FPM AT .33 BPM AT 1440 PSI WITH NO ISSUES -RUN LINER IN OPEN HOLE AT 50 FPM AT .33 BPM AT 1480 PSI HOLDING 400 PSI ON WELL HEAD. -AT 11721,11795', 11880' COIL STARTS TAKING WT 8K. WORK COIL START LOSING HOLE DISCUSS PUMPING LVT WITH ENGINEER. HOLDING 400 PSI ON WELLHEAD. LOSS RATE 10-15 BBL PER HOUR 23:30 - 00:00 0.50 CASING N 12,321.00 RUNPRD PACK OFF LEAKING, DISCUSS WITH TOWN TEAM. SHUT ANNULAR AND UPPER PIPE SLIP RAMS AND CIRCULATE AT .3 BPM HOLDING 400 PSI ON WELL HEAD. LOSS RATE 15-25 BBL PER HOUR 1/21/2019 0000 - 01'00 1.00 CASING IN 12,321.00 RUNPRD PACK OFF LEAKING, DISCUSS WITH TOWN TEAM. SHUT ANNULAR AND UPPER PIPE SLIP RAMS AND CIRCULATEAT.3 BPM HOLDING 400 PSI ON WELLHEAD. -RECEIVE LEVEL 2 ODN FOR CHANGING OUT PACK OFFS. -BLEED OFF PRESSURE -CLOSE ANNULAR AND UPPER PIPE RAMS -FILL HOLE ACROSS THE TOP -HOLD PJSM WITH RIG CREW FOR CHANGING OUT PACK OFF -CHANGE OUT PACK OFF PER NABORS PROCEDURE. -OPEN ANNULAR AND UPPER PIPE RAMS Printed 2120/2019 9:01:14AM ••AII depths reported in Drillers Depths" North America - ALASKA - BP Page 3 of 9 Operation Summary Report Common Well Name: J-07 Event Type: COM- ONSHORE (CON) Stan Date. 1/20/2019 Project: PBU Site: J Rig Name/No.: CDR -2 Spud Date/Time: 72: Rig Contractor. NABORS ALASKA DRILLING INC. PUMPING AT.61 BPM AT 1750 PSI HOLDING Active datum: KB @75.80usft (above Mean Sea Level) Date From - To Him Task Code ___ (hr). .. _ 01:00 - 04:45 3.75 CASING N 04.45 - 05.15 0.50 0515 - 06:00 0.75 06:00 - 08:40 � 2.67 08:40 - 11:50 3.17 CASING CASING P CASING N CASING P End Date. AFE No X3 -0197K -C:(844,491.001 Rig Release: 1/24/2019 NPT Total Depth Phase Description of Operations (usft) 12,321.00 RUNPRD WORKCOIL PUMPING AT.61 BPM AT 1750 PSI HOLDING 400 PSI WELLHEAD PRESSURE LOSING 15-20 BPH ATTEMPT TO WORK COIL TO 30K OVER, NOT ABLE TO MOVE - 10 BBLS 1% KCL, 20 BBLS LVT, 10 BBLS 1% KCL -INCREASE RATE TO 1 BBL PER MINUTE AFTER GETTING LVT IN PIPE -LOSE RETURNS DECREASE RATE BACK TO ; el WITH NO INCREASE IN RETURNS -DISCUSS WITH ODE AND DROP WELL PRESSURE BACK TO ZERO, LOSSES AT 15-18 BPH AT 1 BPM AT 1620 PSI. -WORK PIPE 10K DOWN 37K OVERPULLAND AS LVT COMING OUT PIPE, AT 10 BBLS OUTSIDE PIPE SHUT DOWN PUMPS AND CIRCULATEACROSS THE TOP TO KEEP HOLE FULL. FOR 20 MINUTES -LOSS RATE 6 BPH -WORK PIPE 10K DOWN 37K OVERPULL -PUMPADDITIONAL 10 BBLS OUTSIDE PIPE WORK PIPE 10K DOWN 37K OVERPULLAND AS LVT COMING OUT PIPE, AT 10 BBLS OUTSIDE PIPE SHUT DOWN PUMPS AND CIRCULATE ACROSS THE TOP TO KEEP HOLE FULL. FOR 20 MINUTES -LOSS RATE 6 BPH -WORK PIPE 10K DOWN 30K OVERPULL PIPE CAME FREE. NOTEAECEIVED PERMISSION FROM NABORS SUPERINTENDENT TO PULL UP TO _ 90K (37K OVER) 12,321.00 RUNPRD -PULL UP HOLE TO 11650'AND WORK FROM 11600' TO 11650' -CIRCULATE AT .5 BPM AT 1159PSI LOSING 15 BPH -UP WT 57K DOWN AT 20K -DISCUSS OPERATION WITH ODE ANDAGREE ON PLAN FORWARD -INCREASE WELLHEAD PRESSURE TO 175 _ PSI LOSS RATE STABLE AT 15 BPH. 12,321.00 RUNPRD RIH WITH LINER BHA. FROM 11600' TO 11852 RIH PUMPING AT .5 BPM AT 1369 PSI, LOSING AT 6-10 BPH 12,321.00 RUNPRD CONTINUE WORKING LINER TO TD. TRY RIH WITH PUMPS OFF, NO PROGRESS. HOLD TENSION 51 KAND CIRCULATE 10 MIN, TRY WORKING PIPE AFTER SITTING AND CIRCULATING, LOSING GROUND. _ PUMP 20 BBLS 1.5 PPB BEAD PILL DOWN. 12,321.00 RUNPRD WITH 5 BBLS BEAD OUT START WORKING PIPE. ABLE TO WORK FROM 11 852'TO 11917'. PJSM WITH CREW FOR PUMPING 40 BBLS MINERAL OIL. PUMP 15 BBLS KCL, 38 BBLS LVT, 15 BBLS KCL. Printed 2202019 9:01:14AM '"AII depths reported in Drillers Depths" Common Well Name: J-07 Event Type: COM- ONSHORE (CON) North America - ALASKA - BP Page 4 of 9 Operation Summary Report Start Dale. 1/20/2019 End Date. AFE No (844,491.00 ) Project: PBU Site: J Rig Name/No.: CDR -2 Spud Date/Time: 7/25/1977 12:00:OOAM Rig Release: 1/24/2019 Rig Contractor: NABORSALASKA DRILLING INC. - 1900 2.00 BPUOI: USA00000372 Active datum. KB @75.80usft (above Mean Sea Level) - 21:00 2.00 CASING N Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ (usft) _ _ _ _ 11:50 - 14:40 2.83 CASING P 12,321.00 RUNPRD WITH 5 BBLS OUT THE NOZZLE SHUT IN WELL. WORK PIPE DOWN PAST 12000' PUMP 3 MORE BBLS OUTAND SOAK KEEP 340 PSI WHP. WORK PIPE DOWN TO 12220'. CONTINUE PUMPING SMALL VOLUMES OF MINERAL OIL OUTAND ALLOW IT TO SOAK, WORK PIPE DOWN TO 12229'. CONTINUE WORKING PIPE, LOSE GROUND BACK TO 12173' ADD LUBES TO MUD SYSTEM TO BRING TOTAL LUBES UP TO 3.25%. 14:40 - 17:00 1 2.33 CASING N 12,321.00 RUNPRD CIRCULATE MINERAL OIL OUT. SEND 30 BBLS BEAD PILL IN NEW MUD I DOWN WHILE CIRCULATING. HOLD 340 PSI WHIR WHILE CIRCULATING 1700 - 1900 2.00 CASING N — 19:00 - 21:00 2.00 CASING N MINERALOILOUT. AFTER BEAD PILL IS AT NOZZLE REDUCE RATE TO 0.5 BPM, WORK PIPE. NO PROGRESS LOSE GROUND BACK TO 12124'. DISCUSS PLAN FORWARD WITH ODE. DECISION IS MADE TOPUMPANOTHER 12,321.00 RUNPRD PUMP 10 BBLS KCL, 20 BBLS LVT, 10 BBLS KCL. 12,32 1.00 RUNPRD WORK LINER -WHEN LVT REACHES BIT START TO ATTEMPT TO WORK PIPE DOWN -WHEN 5 BBLS OUTSIDE PIPE SLOW PUMP TO .2 BPM AND CONTINUE TO WORK PIPE FROM 12124' TO 12226', CONTINUE TO WORK PIPE LOSE GROUND TO 12174' WITH 10 BBLS LVT OUTSIDE PIPE. -SHUT DOWN PUMP AND ALLOW TO SOAK FOR 10 MINUTES. -CONTINUE TO WORK PIPE AT VARIABLE PUMP RATES LOOSING FOOTAGE. -PULL UP HOLE IN INCREMENTS OF 100' ATTEMPTING TO WORK PIPE WITH NO SUCCESS. -HOLD 180 PSI WELL HEAD PRESSURE WHILE CIRCULATING OUT LVT PILL 12100 - 00:00 l 3.00 CASING P 12,242.00 RUNPRD WORK LINER -BRING PUMP RATE UP TO 1.6 BPM AT 1764 PSI PRESSURE FOR TEN MINUTES WITH COIL IN COMPRESSION. -DROPRATE 10 MINUTES AND ATTEMPT TO WORK PIPE -REPEAT PROCESS WHILE 10 BBL LVT PILL BEING PUMPED -WITH 5 BBLS OF LVT OUT OF PIPE REDUCE RATE TO -2 BPM AND WORK PIPE. RUN IN HOLE TO 12255', WORK PIPEAND LOSE FOOTAGE TO 12242' STOP WORKING PIPE AND PUMP ANOTHER 10 BBLS OF LVTAT 1.60 BPM AT 1800 PSI. Printed 2@0/2019 9:01:14AM "All depths reported in Drillers Depths" Common Well Name: J-07 Event Type: COM- ONSHORE (CON) North America - ALASKA - BP Page 5 of 9 Operation Summary Report Start Date'. 1/20/2019 Entl Date AFE No X3 -0197K -O. (844,491 00 ) Project: PBU Site: J Rig Name/No.: CDR -2 Spud Date/Time: 7/25/1977 12:00 OOAM Rig Release: 1/24/2019 Active datum: KB @75,80usft (above Mean Sea Level) Date From - To Him Task { (hr) _.. 1/22/2019 100:00 - 00:45 0.75 CASING Code I NPT N 0045 - 0245 2.00 CASING N 02:45 - 04:30 1.75 04.30 - 0830 4.00 CASING N I Total Depth Phase Descnpfion of Operations (usft) 12,321.00 RUNPRD WORKLINER -PUMP 10 BBLS OF LVTAT 1.60 BPMAT 1800 PSI. UNTIL 3 BBLS OUT OF PIPE. -REDUCE RATE TO.2 BPM -ATTEMPT TO WORK LINER FROM 12242' TO 12219' -STOP WORKING PIPE DUE TO FOOTAGE LOSS AND SWAP TO 1% KCL 12,321.00 '', RUNPRD SWAP WELL TO 1% KCL 8APPG -PUMP AT 1.75 TO 2.5 BPM AT 1700 PSI -WITH SBBLS OF KCL OUTSIDE PIPE ATTEMPT TO WORK PIPE. FROM 12219' TO 12200' -WITH KCLAT SURFACE SHUT DOWN PUMPS AND RELAX HOLE FOR 20 MINUTES ATTEMPT TO WORK PIPE FROM 12200' TO 12180' NOTE: HOLDING 100 PSI WELLHEAD PRESSURE WITH KCL IN HOLE. 12,321.00 RUNPRD WORK LINER - WORK PIPE FROM 12200' TO 12155' WITH � PUMPS OFF '-HOLD PJSM TO PUMP 10 BBL LVT PILL -PUMP 10 BBL LVT PILL -SHUT DOWN PUMPING SEVERAL TIMES AND ATTEMPT TO WORK PIPE -WITH 3 BBLS OF LVT OUT OF PIPE REDUCE PUMP RATE TO .2 BPM AND WORK PIPE FROM 12155' TO 12160' -WITH OPEN HOLE COVERED WITH LVT TURN OFF PUMPS AND CONTINUE TO WORK PIPE FROM 12,160' TO 12135' -RESUME PUMPING FROM .2 BPM TO .6 BPM BPM AND WORK PIPE FROM 12135' TO 12115' NOTE: DISCUSS RESULTS WITH ODE CASING N 12,321.00 RUNPRD -CIRCULATE LVT PILL OUT OF HOLE AT 2.5 08:30 - 11:15 275 CASING N 11:15 - 1500 3.75 CASING N BPM AT 1800 PSI HOLDING 277 PSI WELLHEAD PRESSURE. -WITH LVT PILL OUT OF THE HOLE START NEW 10 BBL LVT PILLAT 2.1 BPM AT 1500 PSI. - PUMP LVT TO NOZZLE, 3 BBLS OUT START WORKING PIPE FROM 12110'. - 5 BBLS OUT SHUT OFF PUMP, WORK DOWN TO 12175'. - CONTINUE PUMPING SMALL VOLUMES OF MINERAL OIL OUT AND WORK PIPE, LOSE GROUND BACK TO 12151'. - AFTER LAST OIL OUT SOAK FOR 15 MIN THEN CYCLE, NO PROGRESS. PARKAT 12129'. - CIRCULATE MINERAL OIL OUT, HOLD 230 PSI WHIP. 123,321.00 RUNPRD DISPLACE WELLTO QUICK DRILL N 8.6 PPG AT VARIOUS RATES HOLDING PRESSUREAT 1700-1800 PSI WORK PIPE EVERY 20 MIN TO KEEP IT FREE. -CONTINUE TO CIRCULATE UNTIL4% LUBE OBTAINED IN SURFACE AND HOLE MUD SYSTEM. 12,321.00 RUNPRD WORK PIPE LOSING GROUND FROM 12129' TO 12125' Printed 2/20/2019 9:01:14AM *`All depths reported in Drillers Depths** North America - ALASKA - BP Page 6 of 9 Operation Summary Report Common Well Name: J-07 AFE No Event Type: COM- ONSHORE (CON) Start Date 1;20/2019 End Date X3 -0197K -C'. (844,491,00) Project: PBU Site: J Rig Name/No.: CDR -2 Spud Date/Time: 7/25/1977 12.00.00AM Rig Release: 1/24/2019 Rig Contractor: NABORSALASKA DRILLING INC. Active datum: KB @75.80usft (above Mean Sea Level) BPUOI: USA00000372 Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) _ _ _(_usft) WORK PIPE WHILE CIRCULATING. PIPE 15:00 - 16:15 1.25 CASING N 12,321.00 RUNPRD PULL OUT OF HOLE TO 11 700'AND PUMP 30 12272' WITH OUT PULLING PAST 12265' CALL BBL 5% EP LUBE PILL 16:15 - 18:45 2.50 CASING N 12,321.00 RUNPRD WORK PIPE TO GET BACK TO 12135' PUMP 10 WORK LINER DOWN. _BBL LVT PILL _ 18:45 - 20:00 1.25 CASING N 12,321.00 RUNPRD WORKPIPE 12,3210 RUNPRD WORKPIPE -WITH 3 BBLS OF LVT ON OUTSIDE OF PIPE WORKING PIPE, PIPE FREE UP AT 12,263 AT 72K. WORK PIPE DOWN TO 12311' IN COMPRESSION 10 K (ESTIMATED 12309' REDUCE PUMP RATE TO.2 BPM BOTTOM OF LINER AT NEUTRAL WT.) 03:30 - 05'.00 1.50 CASING P 12,321.00 RUNPRD -WORK PIPE TO 12250' (IN COMPRESSION) -CIRCULATE OUT LVT PILL HOLDING 1700 TO AROUND 12238' NEUTRAL WEIGHT. 1800 PSI -CAN NOT WORK PAST 12250' LET 8 BBLS LVT SOAK OUTSIDE OF PIPE FOR 20 MINUTES -WORK PIPE WITH NO PROGRESS -PRESSURE UP TO 500 PSI AND ATTEMPT TO PASS 12250 DUMPING PRESSURE AT SET DOWN TWO TIMES WITH NO PROGRESS.. 20:00 - 22:45 2.75 CASING N 12,321.00 ! RUNPRD CIRCULATE OUT LVT PILL HOLDING 1800 PSI PUMP PRESSUREAT 180 PSI WELLHEAD PRESSURE. WITH PILL OUT OF HOLE START NEW LVT PILLDOWN COIL HOLDING 1800 PSI PUMP PRESSURE. NOTE: CORRECT TO TO FLAG +10 22:45 - 23:30 0.75 CASING P 12,321.00 RUNPRD WORKPIPE -WITH 3 BBLS OF LVT ON OUTSIDE OF PIPE REDUCE PUMP RATE TO.2 BPM -WORK PIPE TO 12289" (IN COMPRESSION) AROUND 12272' NEUTRAL WEIGHT. -CAN NOT WORK PAST 12272' LET 10 BBLS LVT SOAK OUTSIDE OF PIPE FOR 20 MINUTES - NO PROGRESS MADE 23:30 - 00:00 0.50 CASING P 12,321.00 RUNPRD CIRCULATE OUT LVT PILL HOLDING 1800 PSI PUMP PRESSURE. Printed 2/20/2019 9:01:14AM "All depths reported in Drillers Depths" -WORK PIPE EVERY 20 MINUTES 1/23/2019 0000 - 0315 3.25 CASING N 12,321.00 RUNPRD CIRCULATE -CIRCULATE OUT LVT PILL HOLDING 1800 PSI. WORK PIPE WHILE CIRCULATING. PIPE MOVED UP HOLE NOT ABLE TO GET BACK TO 12272' WITH OUT PULLING PAST 12265' CALL ODEAND DISCUSS DECIDE TO PUMP ANOTHER 10 BBL LVT PILL AND ATTEMPT TO WORK LINER DOWN. CIRCULATE LVT PILL LINER SHOE HOLDING 1700-1800 PSI 03:15 - 03:30 0.25 CASING P 12,3210 RUNPRD WORKPIPE -WITH LVT 3 BBLS OUT OF PIPE START WORKING PIPE, PIPE FREE UP AT 12,263 AT 72K. WORK PIPE DOWN TO 12311' IN COMPRESSION 10 K (ESTIMATED 12309' BOTTOM OF LINER AT NEUTRAL WT.) 03:30 - 05'.00 1.50 CASING P 12,321.00 RUNPRD CIRCULATE -CIRCULATE OUT LVT PILL HOLDING 1700 TO 1800 PSI Printed 2/20/2019 9:01:14AM "All depths reported in Drillers Depths" Common Well Name. J-07 Event Type: COM- ONSHORE (CON) Project: PBU Rig Name/No.: CDR -2 Active datum: KB @75.80usft (abo Date From - To 05:00 - 0600 North America - ALASKA - BP Operation Summary Report Start Date: 1/20/2019 End Date: Site: J Spud Date/Time: 7/25/1977 12:00 OOAM Mean Sea Level) AFE No {3 -0197K -C_ (844,491.00 ) Rig Release: 1/24/2019 Page 7 of 9 His Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 1.00 CASING P 12,321.00 RUNPRD - RELEASE FROM LINER PJSM, DISCUSS BALL DROP PROCEDURE. I - BOT / WSL VERIFIED BALL SIZE. I - CLOSE SRS AND LOAD BALL Panted 2/2012019 9:O1:14AM **All depths reported in Drillers Depths" - PRESSURE UP TO 3000 PSI - LAUNCH 5/8" STEEL BALL - 2.5 BPM IN 12.5 BPM OUT CIRC PRESSURE: 2500 PSI - BALL HEARD GOING OVER GOOSE NECK. - DROP RATE AT 40 BBLS AWAY TO .75 BPM WITH 1315 PSI - BALL LANDED AT 47.5 BBLS AWAY. PRESSURE UP AND SHEAR AT 3525 PSI - PICKUP FROM 12312.7 WITH IOK DOWN TO BREAKOVER AT 12303' MD. 52K BREAKOVER. - CONFIRM BREAKOVER TWICE TOTAL _ '- SET DOW_N10K AT 12313' 0600 - 0830 2.50 CEMT P 12,321.00 RUNPRD SWAP WELL TO KCL - 2.47 BPM IN AT 1986 PSI WITH 2.38 BPM OUT '- 1.63 BPM IN AND 1.54 BPM OUTAT 930 PSI WITH 8.43 PPG IN AND 8.46 PPG OUT - CIRCULATE AT 10 MINUTES FOR A BASELINE LOSS RATE OF4.5 BPH_ _ 08.30 - 09:00 0.50 CEMT P 12,321.00 RUNPRD SAFETY MEETING FOR CEMENT JOB -ALL THIRD PARTY CONTRACTORS GATHERED AND DISCUSSED HAZARDS AND ROLES AND RESPONSIBILITIES -CONFIRMED SPILL CHAMPS FOR SLB AND NABORS - REVIEW CEMENT JOB STEPS - PERFORM RADIO CONFIRMATIONS WITH SINGLE POINT OF CONTACT FOR SLB AND NABORS 09.00 - 09:20 0.33 CEMT P 12.321.00 RUNPRD PTCMT LINETO4700 PSI - REVIEW PRESSURE CROSSCHECK LIST - LEAK TIGHT TEST TO 4700 PSI - PUMP TRIPS TRIPPED AT LOW SETTING OF 300 PSI -GOOD LOW PT AT 300 - GOOD LEAK TIGHT TEST AT 4700 PSI - CONFIRM TRIP SETS AT 3800 PSI 0920 - 09.26 0.10 CEMT P 12,321.00 RUNPRD CMTWETAT09:26 09.26 - 0935 015 CEMT P 12,321.00 RUNPRD CMT TO WEIGHT, PUMP 3 BBLS OF EXHAUST PILL TO THE REEL Panted 2/2012019 9:O1:14AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 8 of 9 Operation Summary Report Common Well Name: J-07 AFE No Event Type: COM- ONSHORE (CON) Start Date: 1/20/2019 End Date. X3 -0197K -C: (844,491 00 ) Project: PBU Site: J Rig Name/No.: CDR -2 Spud DatelTlme: 7/25/1977 12:00:00AM Rig Release: 1/24/2019 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00000372 Active datum: Ke @75.80usft (above Mean Sea Level) Dale From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) ____ — — _..___ - 0935 - 11:10 1.58 CEMT P 12,321.00 RUNPRD START CMT JOB 1.5 BPM = 652 PSI -SHUT DOWN RIG PUMPAND LINE UP CMT PUMP DOWN THE COIL - ON LINE WITH CMT, ZERO IN MM AT 13.5 PPG DENSITY SHUT DOWN PUMP 22.5 BBLS AWAYAND CLOSE THE CHOKE -ONLINE WITH RIG PUMP TO DISPLACE CMT WITH EXHAUST PILL CAUGHT CMTAT 1.5 BBLS AWAY - 70.3 BBLS AWAY CMT AT THE SHOE, ZERO OUT MM AND TAKE RETURNS TO PIT# 1 -74.5 BBLS AWAY, SHUT DOWN THE PUMP - PU TO 12304' BREAK OVER AT 55K PU TO 12292' - STACK 10K AT 12302' - SET DOWN 10' HIGHER, LAUNCH PEE WEE DART - PEE WEE DART LANDED, PU TO EXPOSE CIRC PORTS - ONLINE TO PUMP 5 BBLS OF CMT AND 3 BBLS OF EXHAUST PILL - 1.5 BPM AT 650 PSI - 5 BBLS PUMPED SHUT DOWN PUMP, OPEN BAKER CHOKE AND STACK Wr BACK DOWN - SET 1 O DOWN STILL 10' HIGHER - PRESSURE UP TO 2000 PSI, ZERO IN MM AND SHEAR UWP - LWP SHEARED AT 3800 PSI, DISPLACE UWP �% AT 2.9 BPM WITH 2450 PSI - BUMP PLUG AT 12.7 BBLS AFTER CEMENT ti HAD TURNED THE CORNER -.25 BBLS CEMENT LOSS FROM TURNING D 1 WIPER PLUG 11.10 - 14'.00 283 CEMT P 12,321.00 14.00 - 14'15 025 RIGD P 12,321.00 14:15 - 15'.50 1.58 RICO P 12,321.00 15:50 - 17:30 1.67 CEMT P 12,32100 Printed 2/20/2019 9:01:14AM **All depths reported in Drillers Depths** - CEMENT IN PLACE AT 10:50 AM '- PRESSURE UP TO 3700 PSI AND HOLD FOR 2 MINUTES - BLEED OFF PRESSURE AND CONFIRM FLOATS ARE HOLDING AT OUTLET IN PITS, GOOD NO FLOW CONFIRMED, FLOATS AND DART ARE HOLDING - CLOSE CHOKE AND PRESSURE UP TO 1500 PSI AND UNSTING FROM LINER RUNPRD POOH WITH LINER RUNNING TOOL - ONCE PRESSURE DROP FROM UNSTINGING FROM LINER PUMP 40 BBLSAT HIGH RATE TO MOVE EXHAUST PILLAND AXCESS CEMENT AWAY FROM DEPLOYMENT SLEEVE POST STOP AT 2500' WHILE LRS RU AND TESTS THEIR LINE TO FP THE WELL INSPECT CHAINS WHILE WAITING_ POST LRS RU AND LINE IS TESTED - OPEN UP LRS TO REELAND PUMP 45 BBLS OF DIESEL IN THE REEL - 2 BBLS OF DIESEL OUT, POOH LAYING IN DIESEL FP RUNPRD STOPAT 100', FLOW CHECK WELL -GOOD NO FLOW CHECK -TAG UPAND LD THE LINER RUNNING BHA Printed 2/20/2019 9:01:14AM **All depths reported in Drillers Depths** North America - ALASKA- BP Page 9 of 9 Operation Summary Report Common Well Name. J-07 AFE No Event Type: COM -ONSHORE (CON) Start Date: 1/20/2019 End Date: X3 -0197K -C (844,491.00 ) Project: PBU Site: J Rig Name/No.: CDR -2 Spud Daterrime: 7/25/1977 12:00:00AM Rig Release: 1/24/2019 Rig Contractor: NABORS ALASKA DRILLING INC. -PUMP SLACK BACK -CUT 345' COIL BPUOI: USA00000372 Active datum: KB @75.80usft (above Mean Sea Level) CONNECTOR. -PULL TEST COIL CONNECTOR TO 50K -DID Date From- To Hm Task Code NPT Total Depth Phase Description of Operations (hr) -INSTALL BOOT ON E -LINE _ (us_ft) -MAKE UP 4' STINGER AND VALVE. TEST COIL 17:30 - 18:00 0.50 RIGD P 12,321.00 POST SERVICE TREE AND SET TWC WITH DRY FRESHWATER -BLOW DOWN SAME. -BLOW DOWN COIL WITH BIG AIR COMPRESSOR. ROD. 18:00 - 00:00 6.00 RIGID P 12 321.00 POST -INSTALL SIDE JET NOZZLE 1/24/2019 00:00 - 0700 7.00 RIGID 07'.00 - 10'.00 3.00 RIGID 1000 - 11:30 1.50 RIGID "AII depths reported in Drillers Depths** -DISPLACE COIL TO FRESH WATER -JET STACK -PUMP SLACK BACK -CUT 345' COIL -DRESS COILAND INSTALL COIL CONNECTOR. -PULL TEST COIL CONNECTOR TO 50K -DID NOT PASS P 12,321.00 POST -RE INSTALL COIL CONNECTOR -PULL TEST COIL CONNECTOR TO 50K -GOOD TEST -INSTALL BOOT ON E -LINE -MAKE UP 4' STINGER AND VALVE. TEST COIL CONNECTOR TO 250/3500 PSI FOR 5 MIN EACH -GOOD. -FLUSH SURFACE LINES WITH FRESHWATER -BLOW DOWN SAME. -BLOW DOWN COIL WITH BIG AIR COMPRESSOR. -FILL TREE WITH METHANOL FOR LEAK TIGHT TEST -UNABLE TO TEST WITH BP TRIPLEX -RIG UP NABORS TEST PUMP WITH DIESEL. -LEAK TIGHT TEST TREE BELOW SWAB _VALVE TO 3500 PSI. P 12,321.00 POST GOOD LTT - RD MPD LINE AND HEAD UP BHI UOC WO/CHECKS - ND BOPE - NU TREE CAPAND TEST P 12,321.00 POST TREE CAP TESTED TO 3500 PSI WITH METHANOL - GOOD TEST, NO LEAKS - RIG RLEASED "AII depths reported in Drillers Depths** Daily Report of Well Operations J -07B ArTI\/ITVr)ATF CI IMMARV T/I/O=TWC/0/0 Removed CDR kill line #3. Installed tapped blind with chem. inj. jewelry. Removed blind on Swab, installed tree cap bonnet. R/U lubricator, shell tested tree 1/25/2019 see"Field Charted Tests" Pulled 4" CIW "H" TWC #294. FWP's 0/0/0 see log for details. CTU #8 - 1.75" Coil: Job Objective: RPM/Adperf MIRU. Test liner lap to 2285psi - pass. MU & RIH w/ 2.49" nozzle BHA. 1/27/2019 ***In ro ress CTU #8 - 1.75" Coil: Job Objective: RPM/Adperf MIRU. Test liner lap to 2285psi - pass. MU & RIH w/ 2.49" nozzle BHA. 1/27/2019 ***In Progress*** CTU #8 - 1.75" Coil: Job Objective: RPM/Adperf MIRU. Test liner lap to 2285psi - pass. MU & RIH w/ 2.49" nozzle BHA. Tag bottom at 12277ft. Paint flag at 12267ft. POH. FP coil & well. MU BOT MHA. MU BOT RPM logging tool. RIH. 1/28/2019 ***In Progress*** CTU #8 - 1.75" Coil: Job Objective: RPM/Adperf MIRU. Test liner lap to 2285psi - pass. MU & RIH w/ 2.49" nozzle BHA. Tag bottom at 12277ft. Paint flag at 12267ft. POH. FP coil & well. MU BOT MHA. MU BOT RPM logging tool. RIH. Log RPM from PBTD 12263' CTM to 10,185'CTM. Log repeat from PBTD to 10,185. Paint white coil flag for perfs at 12050. Pump 10bbl 60/40 meth cap while pooh. Lay down RPM tools/verify data. 1/28/2019 ***In Progress*** CTU #8 - 1.75" Coil: Job Objective: RPM/Adperf MIRU. Test liner lap to 2285psi - pass. MU & RIH w/ 2.49" nozzle BHA. Tag bottom at 12277ft. Paint flag at 12267ft. POH. FP coil & well. MU BOT MHA. MU BOT RPM logging tool. RIH. Log RPM from PBTD 12263' CTM to 10,185'CTM. Log repeat from PBTD to 10,185. Paint white coil flag for perfs at 12050. Pump 10bbl 60/40 meth cap while pooh. Lay down RPM tools/verify data. Standby for weather - Winds higher than manlift rating. 1/28/2019 1 ***Not Complete*** CTU #8 - 1.75" Coil: Job Objective: RPM/Adperf MU perf gun BHA. RIH w/ 1 Oft 2" maxforce perf gun. Correct to PBTD. Perforate from 12,207ft - 12,217ft, 2" maxforce. POH. FP well. Recover ball, all shots fired. RDMO. 1/29/2019 ***Com lete*** CTU #8 - 1.75" Coil: Job Objective: RPM/Adperf MU pert gun BHA. RIH w/ 1 Oft 2" maxforce perf gun. Correct to PBTD. Perforate from 12,207ft - 12,217ft, 2" maxforce. POH. FP well. Recover ball, all shots fired. RDMO. 1/29/2019 ***Complete*** by North America - ALASKA - BP PBU J-07 J -07B 500292024102 Design: J -07B Final Survey Report 24 January, 2019 N PBU, PBU, PRUDHOE ger by Alaska NAD27 State Plane Zones Geo Datum: NAD27`OGP-Usa AK[4267*15864] Company: North America - ALASKA - BP Project: PBU Site: J Well: J-07 Wellbore: J -07B Design: J -07B Project PBU, PBU, PRUDHOE Map System: Alaska NAD27 State Plane Zones Geo Datum: NAD27`OGP-Usa AK[4267*15864] Map Zone: NAD27' OGP-Usa AK / Alaska zone 4 Site J, TR -11-13 TVD Reference: Site Position: MD Reference: KB @ 75.80usft (J -07B) From: Map Survey Calculation Method: Position Uncertainty: 0.00 usft EDM FSK - Alaska PROD - ANCP1 Well J-07, J-07 System Datum: Well Position -NI-S 0.00 usft Using Well Reference Point Grid Convergence: -E/.W 0.00 usft E Position Uncertainty 0.00 usft Latitude: Wellbore J -07B Magnetics Model Name Sample Date Dec Elevation: BGGM2018 1/1/2019 Ground Level: Design J -07B Audit Notes: Strength Version: Phase: ACTUAL Vertical Section: Depth From (TVD) +N/ -S (usft) (usft) 203 0.00 BP Final Survey Report Local Coordinate Reference: Well J-07 TVD Reference: KB @ 75.80usft (J -07B) MD Reference: KB @ 75.80usft (J -07B) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM FSK - Alaska PROD - ANCP1 641,155.790 usft Longitude: System Datum: Mean Sea Level Using Well Reference Point Grid Convergence: Using geodetic scale factor Northing: Wellhead lination Northing: 5,968,224.220 usft Latitude: 70° 19' 14.845 N Easting: 641,155.790 usft Longitude: 148'51'20.092W Slot Radius: 0.000 in Grid Convergence: 1.08 ° 5,970,505.360 usft Latitude: 70° 19'36A31 N asting: 643,549.680 usft Longitude: 148° 50'8.966 W Elevation: 38.46 usft Ground Level: 40.07 usft Dip Angle Field Strength (nT) 17.02 60.94 57,440 Tie On Depth: 11,139.98 +E/ -W Direction (usft) (°) 0.00 349.02 1/24/2019 10:27:24AM Page 2 COMPASS 5000.1 Build 81D BP Final Survey Report Company: North America -ALASKA - SP Local Coordinate Reference: Well J-07 Project: PBU TVD Reference: KB @ 75.80usft (J -07B) Site: J MD Reference: KB @ 75.80us8 (J -07B) Well: J-07 North Reference: True Wellbore: J -07B Survey Calculation Method: Minimum Curvature Design: J -07B Database: EDM RSK- Alaska PROD -ANCP1 Survey Program Date 1/24/2019 From To (usft) (usft) Survey (Wellbore) Tool Name Description 107.61 8,707.61 1 : Camera based gyro multishc (J-07) CB -GYRO -MS Camera based gyro multishot 8,750.00 11,139.982: MWD - Standard (J -07A) MWD MWD -Standard 11,148.00 12,321.00 Survey#1 (J -07B) MWD MWD -Standard Survey MD Inc Azi (azimuth) TVD TVDSS NIS ENV Northing Easting DLeg V. Sec (usR) (1) V) (usft) (usft) (usft) (usft) (usft) (usft) (°1100us@) (usft) 37.34 0.00 0.00 37.34 -38.46 0.00 0.00 5,970,505.360 643,549,680 0.00 0.00 107.61 0.17 289.90 107.61 31.81 0.04 -0.10 5,970,505.394 643,549.581 0.24 0.05 207.61 0.92 171.72 207.81 131.81 -0.71 -0.12 5,970,504.649 643,549.572 1.01 -0.67 307.61 0.17 42.35 307.60 231.80 -1.39 0.09 5,970,503.969 643,549.800 1.04 -1.39 407.61 0.08 222.86 407.60 331.80 -1.33 0.15 5,970,504.028 643,549.852 0.25 -1.34 507.61 0.35 179.92 507.60 431.80 -1.69 0.10 5,970,503.671 643,549.811 0.30 -1.68 607.61 0.57 126.05 607.60 531.80 -2.29 0.50 5,970,503.081 643,550.225 0.46 -2.34 707.61 0.18 51.10 707.60 631.60 -2.48 1.03 5,970,502.897 643,550.753 0.55 -2.63 807.61 0.08 284.29 807.60 731.80 -2.37 1.08 5,970,503.013 643,550.806 0.24 -2.53 907.61 0.50 154.97 907.59 831.79 -2.75 1.20 5,970,502.638 643,550.930 0.55 -2.9: 1,007.61 0.27 17.02 1,007.59 931.79 -2.92 1.45 5,970,502.473 643,551.187 0.72 -3,14 1,107.61 0.35 213.22 1,107.59 1,031.79 -2.95 1.35 5,970,502.440 643,551.089 0.61 -3,15 1,207.61 0.13 76.05 1,207.59 1,131.79 -3.17 1.30 5,970,502.211 643,551.036 0.45 -3.36 1,307.61 0.33 30428 1,307.59 1,231.79 -2.98 1.17 5,970,502.398 643,550.905 0.43 -3.15 1,407.61 0.57 22022 1,407.59 1,331.79 -3.20 0.61 5,970,502.170 643,550.350 0.63 -3.26 1,507.61 0.52 151.08 1,507.59 143179 -3.98 0.51 5,970,501.391 643,550.263 0.62 4.00 1,607.61 0.42 100.93 1,607,58 1,53178 -4.45 1.09 5,970,500.936 643,550.851 0.41 -4.57 1,707.61 0.08 33.46 1,707.58 1,63178 -4.46 1.48 5,970,500.932 643,551.249 0.40 -4.66 1,807.61 0.40 202.22 1,807.58 1,731.78 -4.72 1.39 5,970,500.666 643,551.161 0.48 -4.90 1,907.61 0.42 126.26 1,907.58 1,831.78 -5.26 1.55 5,970,500.129 643,551.335 0.50 -5.46 1242019 10.77:24AM Page 3 COMPASS 5000.1 Build 81D BP Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well J-07 Project: Pau TVD Reference: KB @ 75.80usft (J-078) Site: J MD Reference: KB @ 75.80usft (J-078) Well: J-07 North Reference: True Wellbore: J-078 Survey Calculation Method: Minimum Curvature Design: J -07B Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS NIS E/W Northing Essdng DLeg (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°1100usft) 2,007.61 0.25 53.30 2,007.58 1,931.78 -5.35 2.02 5,970,500.052 643,551.807 0.42 2,107.61 0.33 202.02 2,107.58 2,031.78 -5.49 2.09 5,970,499.916 643,551.876 0.56 2,207.61 0.30 137.01 2,207.58 2,131.78 -5.94 2.16 5,970,499.459 643,551.956 0.34 2,307.61 0.33 120.65 2,307.58 2,231.78 -6.28 2.59 5,970,499.129 643,552.386 0.09 2,407.61 0.32 89.69 2,407.57 2,331.77 -6.43 3.12 5,970,498.994 643,552.918 0.17 2,507.61 0.42 84.09 2,507.57 2,431.77 -6.39 3.76 5,970,499.046 643,553.561 0.11 2,607.61 0.43 70.89 2,607.57 2,531.77 -6.23 4.48 5,970,499.220 643,554.277 0.10 2,707.61 0.23 60.78 2,707.57 2,631.77 -6.01 5.01 5,970,499.451 643,554.802 0.21 2,807.61 0.58 327.17 2,807.57 2,731.77 -5.48 4.91 5,970,499.972 643,554.693 0.64 2,907.61 4.42 322.06 2,907.45 2,831.65 -2.02 2.26 5,970,503.386 643,551.983 3.84 3,007.61 7.27 348.24 3,006.94 2,931.14 7.22 -1.40 5,970,512.551 643,548.147 3.83 3,107.61 9.17 352.46 3,105.91 3,030.11 21.31 -3.73 5,970,526.597 643,545.542 1.99 3,207.61 11.42 355.17 3,204.29 3,128.49 39.08 -5.61 5,970,544.323 643,543.323 2.30 3,307.61 12.87 354.80 3,302.05 3,226.25 60.04 -745 5,970,565:240 643,541.080 1.45 3,407.61 14.70 354.55 3,399.17 3,323.37 83.76 -9.67 5,970,588.915 643,538.412 1.83 3,507.61 17.17 355.09 3,495.32 3,419.52 111.10 -12.14 5,970,616.202 643,535.421 2.47 3,607.61 19.27 353.67 3,590.30 3,514.50 142.21 -15.22 5,970,847.245 643,531.744 2.15 3,707.61 21.60 354.22 3,684.00 3,608.20 176.93 -18.89 5,970,681.883 643,527.407 2.34 3,807.61 24.50 354.66 3,776.00 3,700.20 215.90 -22.68 5,970,720.767 643,522.878 2.91 3,907.81 27.33 354.95 3,865.94 3,790.14 259.42 -26.63 5,970,764.200 643,518.095 2.83 4,007.61 30.17 354.15 3,953.60 3,877.80 307.29 -31.21 5,970,811.974 643,512.598 2.87 4,107.61 33.08 353.90 4,038.74 3,962.94 359.44 -36.67 5,970,864.001 643,506.139 2.91 4,207.61 36.82 353.74 4,120.70 4,044.90 416.38 -42.84 5,970,920.810 643,498.882 3.74 4,307.61 39.87 354.39 4,199.12 4,123.32 478.08 -49.25 5,970,982.372 643,491.301 3.08 4,407.61 43.83 356.43 4,273.59 4,197.79 544.57 -54.54 5,971,048.741 643,484.739 4.19 4,507.61 46.83 357.87 4,343.89 4,268.09 615.58 -58.05 5,971,119.673 643,479.869 3.17 4,607.61 46.23 357.90 4,412.69 4,336.89 688,11 -60.73 5,971,19Z 127 643,475.804 0.60 V. Sec (usfq -5.61 -578 -6.25 -6.66 -6.90 -6.99 -6.97 -6.85 -6.32 -2.41 7 35 2163 3943 60.36 84.07 111.31' 142.51 177.29 216.26 259.74 307.61 359.84 416.92 478.71 544.98 615.37 687.08 1242019 10:27:24AM Page 4 COMPASS 5000.1 Build 81D BP by Final Survey Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well J-07 Project: PBU TVD Reference: KB @ 75.80usft (J -07B) Site: J MD Reference: KB @j 75.80usft (J -07B) Well: J-07 North Reference: True Wellbore: J -07B Survey Calculation Method: Minimum Curvature Design: J -07B Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc Azi (azimuth) TVD TVDSS NIS E/W Northing Easting DLeg V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) ('1100ueft) (usft) 4,707 61 46.25 357 80 4,481.85 4,406.05 760.28 -63.44 5,971,264.230 643,471.714 0.07 758.41 4,807.61 45.73 357.64 4,551.33 4,475.53 832.15 -66.30 5,971,336.021 643,467.479 0.53 829.54 4,907.61 45.23 357.67 4,621.44 4,545.64 903.39 -69.22 5,971,407.187 643,463.199 0.50 900.03 5,007.61 44.58 357.77 4,692.27 4,616.47 973.92 -72.02 5,971,477.652 643,459.042 0.65 969.81 5,107.61 44.17 357.83 4,763.75 4,687.95 1,043.81 -74.71 5,971,547.466 843,455.021 0.41 1,038.93 5,207.61 44.25 358.35 4,835.43 4,759.63 1,113.50 -77.03 5,971,617.094 643,451.365 0.37 1,107.78 5,307.61 43.83 358.44 4,907.31 4,831.51 1,182.99 -78.98 5,971,686.527 643,448.088 0.42 1,176.37 5,407.61 44.57 358.27 4,979.00 4,903.20 1,252.67 -80.98 5,971,756.158 643,444.754 0.75 1,245.16 5,507.61 43.75 358.49 5,050.74 4,974.94 1,322.31 -62.95 5,971,825.740 643,441.452 0.83 1,313.90 5,607.61 43.13 358.64 5,123.35 5,047.55 1,391.05 -84.68 5,971,894.427 643,438.415 0.63 1,381.71 5,707.61 42.95 358.90 5,196.44 5,120.64 1,459.28 -86.14 5,971,962.616 643,435.644 0.25 1,448.97 5,807.61 43.12 358.88 5,269.53 5,193.73 1,527.51 -8746 5,972,030.805 643,433.017 0.17 1,516.21 5,907.61 43.37 359.23 5,342.38 5,268.58 1,596.02 -88.59 5,972,099,267 643,430.578 0.35 1,583.67 6,007.61 44.33 359.40 5,414.49 5,338.89 1,66529 -89.42 5,972,168.505 643,428.425 0.97 1,651.83 6,107.61 45.27 359.96 5,485.45 5,409.65 1,735.75 -89.81 5,972,238.940 643,426.687 1.02 1,721.07 6,207.61 46.58 359.82 5,555.01 5,479.21 1,807.59 -89.95 5,972,310.760 643,425.174 1.31 1,791.6? 6,30761 47.55 359.76 5,623.12 5,547.32 1,880.80 -90.22 5,972,383.947 643,423.504 0.97 1,863.55 6,407.61 48.57 359.97 5,689.98 5,614.16 1,955.18 -90.39 5,972,458.308 643,421.907 1.03 1,936.60 6,507.61 49.25 359.79 5,755.68 5,679.88 2,030.55 -90.55 5,972,533.653 643,420.307 0.69 2,01062 6,607.61 49.07 359.68 5,821.08 5,745.28 2,106.21 -90.90 5,972,609.279 643,418.510 0.20 2,084.95 6,707.61 48.58 359.30 5,888.91 5,811.11 2,181.47 -91.57 5,972,684.514 643,416.401 0.57 2,156.97 6,807.61 48.32 359.20 5,953.24 5,877.44 2,256.30 -92.55 5,972,759.307 643,413.990 0.27 2,232.62 6,907.61 48.15 358.70 6,019.85 5,944.05 2,330.88 -93.92 5,972,833.837 643,411.198 0.41 2,306.09 7,007.61 47.68 358.81 6,086.87 6,011.07 2,405.08 -95.53 5,972,907.984 643,408.166 0.48 2,379.23 7,107.61 47.25 358.91 6,154.47 6,078.67 2,478.75 -96.99 5,972,981.608 643,405.291 0.44 2,451.84 7,207.61 47.13 358.20 6,222.43 6,146.63 2,552.08 -98.84 5,973,054.891 643,402.039 0.53 2,524.18 7,307.61 46.67 358.05 6,290.76 6,214.96 2,625.06 -101.23 5,973,127.803 643,398.255 0.47 2,596.28 1242019 10:27.24AM Page 5 COMPASS 5000 1 Build BID BP Final Survey Report Company: North America -ALASKA - BP Local Co-ordinate Reference: Well J-07 Project: PBU TVD Reference: KB @ 75.80usft (J -07B) Site: J MD Reference: KB Q 75.80usft (J -07B) Well: J-07 North Reference: Two Wellbore: J -07B Survey Calculation Method; Minimum Curvature Design: J -07B Database: EDM R5K-Alaska PROD -ANCP1 Survey MD Inc Azi (azimuth) ND TVDSS NIS E/W Northing Easgng OLag V. Sec (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°I100usft) (usft) 7,407.61 46.25 35814 6,359.64 6,283.84 2,697.51 -103.64 5,973,200.187 643,394.459 0.43 2,667. BF 7,507.61 46.00 358.18 6,428.95 6,353.15 2,769.56 -105.96 5,973,272.172 643,390.767 0.25 2,739.03 7,607.61 46.33 358.09 6,498.21 6,422.41 2,841.65 -108.30 5,973,344.204 643,387.041 0.34 2,810.25 7,707.61 47.00 357.92 6,566.84 6,491.04 2,914.34 -110.84 5,973,416.828 643,383.118 0.68 2,882.09 7,807.61 47.45 358.35 6,634.75 6,558.95 2,987.71 -113.23 5,973,490.126 643,379.327 0.55 2,954.57 7,907.61 47.42 358.73 6,702.39 6,626.59 3,061.33 -115.10 5,973,563.698 643,376.043 0.28 3,027.20 8,007.61 47.30 359.49 6,770.13 6,694.33 3,134.89 -116.24 5,973,637.210 643,373.493 0.57 3,099.63 8,107.61 48.08 359.68 6,837.45 6,761.65 3,208.84 -116.78 5,973,711.129 643,371.543 0.79 3,172.32 8,207.61 48.92 0.19 6,903.71 6,827.91 3,283.73 -116.86 5,973,786.002 643,370.028 0.92 3,245.86 8,307.61 48.33 0.79 6,969.81 6,894.01 3,358.77 -116.22 5,973,861.031 643,369.232 0.74 3,31940 8,407.61 48.48 2.11 7,036.19 6,960.39 3,433.53 -114.33 5,973,935.807 643,369.695 1.00 3,392.43 8,507.61 48.22 2.45 7,102.65 7,026.85 3,508.19 -111.36 5,974,010.507 643,371.238 0.36 3,465.16 8,607.61 48.00 3.95 7,169.42 7,093.82 3,582.51 -107.20 5,974,084.890 643,373.968 1.14 3,537.33 8,707.61 48.30 4.54 7,236.14 7,160.34 3,656.79 -101.69 5,974,159.260 643,378.061 0.53 3,609.21 8,750.00 49.02 5.00 7,264.14 7,188.34 3,688,51 -99.04 5,974,191.018 643,380.100 1.88 3,639.84 8,778.13 45.60 4.33 7,283.21 7,207.41 3,709.12 -97.36 5,974,211.650 643,381.390 12.28 3,659.71 8,808.26 43.20 3.54 7,304.74 7,228.94 3,730.14 -95.91 5,974,232.701 643,382.437 8.17 3,680.11 8,840.29 40.60 2.61 7,328.58 7,252.78 3,751.50 -94.76 5,974,254.075 643,383.180 8.35 3,700.86 8,871.85 37.70 1.59 7,353.05 7,277.25 3,771.41 -94.02 5,974,273.993 643,383.535 9.41 3,720.26 8,903.97 34.90 0.40 7,378.93 7,303.13 3,790.42 -93.68 5,974,293.004 643,383.508 8.99 3,738.86 8,937.15 32.30 359.60 7,406.57 7,330.77 3,808.78 -93.68 5,974,311.359 643,383.161 7.95 3,756.88 8,968.90 31.30 0.50 7,433.55 7,357.75 3,825.51 -93.67 5,974,328.085 603,382.854 3.49 3,773.30 9,000.87 31.10 1.00 7,460.90 7,385.10 3,842.07 -93.45 5,974,344.645 643,382.753 1.02 3,789.52 9,096.67 28.60 355.80 7,543.99 7,468.19 3,889.69 -94.70 5,974,392.230 643,380.595 3.75 3,836.51 9,190.41 28.80 353.80 7,626.22 7,550.42 3,934.52 -98.78 5,974,436.965 643,375.656 1.05 3,881.29 9,284.92 29.30 349.60 7,708.85 7,633.05 3,979.90 -105.41 5,974,482.210 643,368.156 2.22 3,927.10 9,380.73 29.60 344.90 7,792.29 7,716.49 4,025.81 -115.81 5,974,527.909 643,356.882 2.43 3,974.15 1242019 10:27:24AM Page 6 COMPASS 5000.1 Build BID BP bp Final Survey Report Company: North America - ALASKA - BP Local Coordinate Reference: Well J-07 Project: PBU TVD Reference: KB C 75.80usft (J -07B) Site: J MD Reference: KB @ 75.80usft (J-078) Well: J-07 North Reference: True Wellbore: J -07B Survey Calculation Method: Minimum Curvature Design: J -07B Database: EDM RSK- Alaska PROD -ANCP1 Survey MD Inc An (azimuth) TVD TVDSS NIS EIW Northing Easting DLeg V. Sae (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) (usft) (°Moousft) (usft) 9,476.22 29.20 345.00 7,875.48 7,799.68 4,071.08 -127.88 5,974,572.933 643,343.847 0.42 4,020.9' 9,572.22 28.20 34570 7,959.69 7,883.89 4,115.68 -139.65 5,974,617.298 643,331.334 1.10 4,066.92 9,668.06 28.40 343.80 8,044.07 7,968.27 4,159.51 -151.60 5,974,660.889 643,316.546 0.96 4,112.22 9,763.77 29.60 342.20 8,127.78 8,051.98 4,203.87 -165.18 5,974,704.984 643,304.124 1.49 4,158.36 9,859.91 30.50 340.30 8,211.00 8,135.20 4,249.45 -180.66 5,974,750.254 643,287.773 1.36 4,208.06 9,955.77 32.10 341.50 8,292.91 8,217.11 4,296.51 -196.94 5,974,796.990 643,270.593 1.79 4,255.36 10,053.01 31.50 342.40 8,375.55 8,299.75 4,345.23 -212.82 5,974,845.391 643,253.786 0.79 4,306.21 10,154.94 30.20 341.20 8,463.06 8,387.26 4,394.88 -229.14 5,974,894.720 643,236.526 1.41 4,358,05 10,249.50 29.30 340.20 8,545.16 8,469.36 4,439.17 -244.64 5,974,938.697 643,220.180 1.09 4,404.49 10,278.71 29.60 340.60 8,570.59 8,494.79 4,452.70 -249.46 5,974,952.130 643,215.105 1.23 4,418.68 10,310.89 31.20 341.30 8,598.35 8,522.55 4,468.09 -254.77 5,974,967417 643,209.500 5.09 4,434.81 10,342.87 34.00 342.50 8,625.29 8,549.49 4,484.47 -260.11 5,974,983.688 643,203.842 8.99 4,451.90 10,375.01 37.00 343.90 8,651.45 8,575.65 4,502.33 -265.50 5,975,001.447 643,198.116 9.67 4,470.47 10,406.94 40.00 345.40 8,676.44 8,600.84 4,521,50 -270.75 5,975,020.508 643,192.498 9.64 4,490.28 10,438.86 43.00 347.30 8,700.34 8,624.54 4,542.05 -275.73 5,975,040.959 643,187.126 10.19 4,511.41 10,470.98 46.10 349.20 8,723.23 8,647.43 4,564.11 -280.31 5,975,062.924 643,182.128 10.50 4,533.9' 10,503.33 49.60 349.20 8,744.93 8,669.13 4,587.67 -284.80 5,975,086.387 643,177.185 10.82 4,557.91 10,535.39 53.40 349.90 8,764.89 8,689.09 4,612.34 -289.35 5,975,110.964 643,172.168 11.98 4,583.00 10,567.30 56.80 349.70 8,783.14 8,707.34 4,638.09 -293.98 5,975,136.622 643,167.042 10.87 4,608.16 10,599.26 60.30 351.40 8,799.82 8,724.02 4,664.98 -298.45 5,975,163.420 643,162.060 11.85 4,636.41 10,611.20 61.60 352.10 8,805.61 8,729.81 4,675.31 -299.95 5,975,173.719 643,160.366 12.03 4,646.84 10,665.90 66.13 355.38 8,829.71 8,753.91 4,724.11 -305.28 5,975,222.400 643,154.108 8.88 4,695.76 10,697.64 66.58 355.47 8,842.44 8,766.64 4,753.09 -307.59 5,975,251.330 643,151.236 1.44 4,724.65 10,729.73 66.81 354.37 8,855.13 8,779.33 4,782.44 -310.20 5,975,280.628 643,148.065 3.23 4,753.96 10,762.01 66.98 355.59 8,867.80 8,792.00 4,812.02 -312.80 5,975,310.147 643,144.902 3.52 4,783.49 10,793.87 67.03 356.39 8,880.25 8,804.45 4,841.28 -314.85 5,975,339.356 543,142.292 2.32 4,812.60 10,825.71 67.01 355.48 8,892.68 8,816.88 4,870.52 -316.93 5,975,368.548 643,139.655 2.63 4,841.70 1242019 10:27:24AM Page 7 COMPASS 5000.1 Build 81D Company: North America - ALASKA - BP Project: Pau Site: J Well: J-07 Wellbore: J -07B Design: J -07B Survey MD (usft) 10,858 00 10,889.32 10,910.01 10,946.43 10,978.90 11,010.93 11,037.64 11,044.31 11,076.16 11,108.01 11,139.98 Tie -In -Point 11,148.00 TOWSIKOP 11,167.01 Interpolated Azl 11,200.84 Interpolated Azi 11,230.50 Interpolated Azi 11,260.25 1st Clean Survey 11,290.50 11,320.21 11,350.34 11,380.55 11,409.66 11,440.58 BP Final Survey Report Local Co-ordinate Reference: Well J-07 TVD Reference: KB @ 75.80usft (J -07B) MD Reference: KB @ 75.80usft (J -07B) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCP1 Inc 359.80 An (azimuth) 8,963.95 TVD TVDSS -326.11 NIS 643,124.197 E/W Northing 84.48 Easting 337.41 DLeg V. Sec 5,232.64 -327.17 5,975,730.385 643,122.493 (usft) (usft) 81.02 (usft) 82.30 (usft) (usft) 5,261.95 (usft) 5,975,759.640 (°1100usft) (usft) 67.04 83.66 354.61 5,375.83 8,90528 8,829.48 5,291.16 4,900.13 5,975,788.769 -319.50 5,975,398.108 5,257.83 643,136.522 344.73 2.48 4,871,2- 67.10 5,320.54 355.36 5,975,818018 8,917.49 8,841.69 5,287.88 4,928.87 -322.02 5,975,426.787 5,432.40 643,133451 2.21 4,899.96 67.10 358.04 8,925.54 8,849.74 4,947.87 -323.45 5,975,445.780 643,131.659 3.03 4,918.89 68.29 357.72 8,939.36 8,863.56 4,981.52 -325.28 5,975,479.360 643,129.184 5.37 4,952.26 73.26 358.37 8,950.05 8,874.25 5,012.15 -326.32 5,975,509.963 643,127.555 15.42 4,982.53 78.98 359.24 8,957.73 8,881.93 5,043.22 -326.97 5,975,541.018 643,126.316 18.05 5,013.16 83.74 359.24 8,961.74 8,885.94 5,069.62 -327.32 5,975,567.401 643,125.461 17.82 5,039.14 84.88 359.39 8,96240 8,886.60 5,076.26 -327.40 5,975,574.034 643,125.254 17.24 5,045.67 89.14 0.12 8,964.06 8,888.26 5,108.05 -327.53 5,975,605.822 643,124.510 13.57 5,076.91 89.94 0.84 8,964.32 8,888.52 5,139.90 -327.27 5,975,637.667 643,124.168 3.38 5,108.13 90.65 1.56 8,964.15 8,888.35 5,171.86 -326.60 5,975,669.633 643,124.226 3.16 5,139.38 90.74 1.75 8,964.06 8,888.26 5,179.88 -326.37 5,975,677.652 643,124.304 2.62 5,147.20 89.88 359.80 8,979.88 8,963.95 8,888.15 5,198.89 -326.11 5,975,698.659 643,124.197 11.21 5,165.81 84.48 356.60 337.41 8,965.62 8,889.82 5,232.64 -327.17 5,975,730.385 643,122.493 18.55 5,199.1. 81.02 353.70 82.30 8,969.36 8,893.56 5,261.95 -329.65 5,975,759.640 643,119.449 15.17 5,228.40 83.66 350.88 5,375.83 8,973.33 8,897.53 5,291.16 -333.61 5,975,788.769 643,114.934 12.92 5,257.83 83.87 344.73 16.75 8,976.62 8,900.82 5,320.54 -339.96 5,975,818018 643,108.024 20.22 5,287.88 83.50 341.50 8,979.88 8,904.08 5,348.80 -348.53 5,975,846.099 643,098.911 10.88 5,317.25 82.34 337.41 8,983.60 8,907.80 5,376.79 -359.02 5,975,873.884 643,087.888 14.01 5,346.72 82.30 333.61 8,987.64 8,911.84 5,404.03 -371.43 5,975,900.880 643,074,962 12.47 5,375.83 86.10 330.54 8,990.58 8,914.78 5,429.61 -384.99 5,975,926.193 643,060.915 16.75 5,403.52 89.94 325.87 8,991.65 8,915.85 5,455.86 -401.27 5,975,952.127 643,044.142 19.54 5,432.40 1/242019 10:27.24AM Page 8 COMPASS 5000.1 Build 61D BP by Final Survey Report Company: North America - ALASKA- BP Local Coordinate Reference: Well J-07 Project: PBU TVD Reference: KB @ 75.80usft (J -07B) Site: J MD Reference: KB @ 75.80usft (J-078) Well: J-07 North Reference: True Wellbore: J -07B Survey Calculation Method: Minimum Curvature Design: J -07B Database: EDM RSK- Alaska PROD -ANCPt Survey MD Inc Azi (azimuth) ND NDSS N/S EIW Northing Easting DLeg V. Sec (usft) (1) V) (usft) (usft) (usft) (tai (usft) (usft) (°/100usft) (usft) 11,470.76 89.26 322.39 8,991.86 8,916.06 5,480,31 -418.95 5,975,976.234 643,025.998 11.75 5,459.7- 11,500.30 88.83 318.06 8,992.35 8,916.55 5,503.01 -437.84 5,975,998.561 643,006.677 14.73 5,465.65 11,530.76 90.74 313.16 8,992.47 8,916.67 5,524.76 -459.14 5,976,019.907 642,984.966 17.26 5,511.06 11,565.64 87.14 311.06 8,993.11 8,917.31 5,548.14 -485.01 5,976,042.786 642,958.660 11.95 5,538.94 11,592.60 82.98 306.53 8,995.43 8,919.133 5,564.97 -505.93 5,976,059.205 642,937.421 22.76 5,559.44 11,620.05 83.48 301.40 8,998.67 8,922.87 5,580.19 -528.53 5,976,073.991 642,914.536 18.65 5,578.69 11,654.57 86.44 297.26 9,001.71 8,925.91 5,597.03 -558.50 5,976,090.249 642,884.251 14.70 5,600.93 11,691.10 85.23 292.36 9,004.36 8,928.56 5,612.31 -591.56 5,976,104.897 642,850.908 13.78 5,622.23 11,720.58 84.03 289.62 9,007.12 8,931.32 5,622.82 -618.96 5,976,114.883 642,823.314 10.11 5,637.77 11,750.54 83.72 293.30 9,010.32 8,934.52 5,633.72 -646.68 5,976,125.246 642,795.394 12.26 5,653.75 11,780.36 84.52 298.45 9,013.37 8,937.57 5,646.66 -673.36 5,976,137.674 642,768.474 17.39 5,671.53 11,810.53 88.34 301.69 9,015.25 8,939.45 5,661.75 -699.41 5,976,152.256 642,742.143 16.59 5,691.30 11,840.19 92.64 304.78 9,015.00 8,939.20 5,678.00 -724.20 5,978,168.027 642,717.039 17.85 5,711.98 11,670.33 96.79 308.85 9,012.52 8,936.72 5,695.98 -748.24 5,976,185:552 642,692.662 19.25 5,734.22 11,901.88 101.14 313.42 9,007.80 8,931.80 5,716.47 -77171 5,978;208:582 642,668.812 19.87 5,758.80 11,930.45 102.20 318.58 9,001.82 8,926.02 5,736.59 -791.14 5,976,225.323 642,649.001 18.07 5,782.21 11,960.77 102.33 313.03 8,995.38 8,919.56 5,757.82 -811.78 5,976,246.156 642,627.956 17.89 5,807.03 11,990.69 104.15 308.93 8,988.52 8,912.72 5,776.92 -833.76 5,976,264.828 642,605.617 14.66 5,829.96 12,022.43 104.14 304.34 8,980.76 8,904.96 5,795.28 -858.45 5,976,282.711 642,580.582 14.02 5,852.69 12,050.91 103.44 300.86 8,973.97 8,898.17 5,810.18 -881.75 5,976,297.159 642,557.005 12.12 5,871.75 12,081.08 103.65 298.03 8,966.90 8,891.10 5,824.59 -907.29 5,976,311.084 642,531.197 9.15 5,890.77 12,111.62 100.82 291.92 8,960.48 8,884.68 5,837.18 -934.34 5,976,323.154 642,503.911 21.93 5,908.28 12,135.14 100.37 287.92 8,956.19 8,880.39 5,845.06 -956.08 5,976,330.613 642,482.028 16.76 5,920.16 12,162.39 103.16 283.36 8,950.63 8,874.83 5,852.26 -981.76 5,976,337.315 642,458.218 19.32 5,932.11 12,195.20 101.75 277.15 8,943.55 8,867.75 5,857.95 -1,013.27 5,976,342.406 642,424.608 18.97 5,943.71 12,230.21 102.51 271.56 8,936.19 8,860.39 5,860.55 -1,047.38 5,976,344.353 642,390.453 15.76 5,952.76 12,258.17 101.89 268.00 8,930.28 8,854.48 5,860.45 -1,074.71 5,976,343.725 642,363.139 12.64 5,957.86 1242019 10:27.24AM Page 9 COMPASS 5000,1 Build 81D by Company: North America -ALASKA - BP Project: Pau Site: J Well: J-07 Wellbore: J -07B Design: J -07B Survey MD Just) 12,287.69 12,321.00 Preojection to TD BP Final Survey Report Local Coordinate Reference: TVD Reference: MD Reference'. North Reference: Survey Calculation Method: Database: Well J-07 KB @ 75.80usft (J -07B) KB @ 75.80usft (J -07B) True Minimum Curvature EDM RSK - Alaska PROD - ANCP1 Inc Azi (azimuth) TVD TVDSS N/S E/W Northing Easting DLeg V. See J°) (1) (usft) (usft) (usft) Just) Will (usft) (°/10ousft) (usft) 10145 26222 8,924.30 8,848.50 5,857.98 -1,103.50 5,976,340.710 642,334402 1923. 5,960.9; 101.45 262.22 8,917.69 8,841.89 5,853.56 -1,135.84 5,976,335.873 642,302.148 0.00 5,962.75 1242019 10:27:24AM Page 10 COMPASS 5000.1 Build 811) EG Pmjm PBu Ste: J TQ Well: JO1 yffi// Wellbore: J713 PNn: J -0]B am.nsu T^.xnl^ J WELLBORE DETAILS: J 07B J -07B J -07A Tegn MQ 11139.98 �4FF WEII MMTloN Loaalnal WIW&om VAIJ07 Tme NON Easling (300 usNin) NA OWWFO O 0 CD s n A D to O CD CD pSh 0. CDT_ N O �T W W4 rd ■ k \ � \�( � ( \k6 ; {\} \ E ] 7 : � \�( � ( \k6 ; ( \ � /§)fes/\� \k6 ; £ � \s N m O LO N N N N N N+++++- + i i i i i L +++ 0 0 0 O O O O O O O O O O O O O O O O O O O O O O O O A W W N N m m m m J J J J V V W W N+ + 0 0 0 m m m m m m m V V V m m m m N m N m W N N N j. [. [. . . W W r_ —8—.00000006666666666666666666 A W W N N m m m m J J V V V J W W N O O m m m m m m m V V V W W W m m N N N W N N N LDLD"m`D`On�mD`D".DVD m➢mmD��D�mD�m�(�nmDD`mmD'ammD` 0 m` o L m ++ o m D tOm m L O WO +OrmmLOm6VJ`` NV OO . 66 66w 0Um Nm NLD L+mo j L0m t0D O m0nm--OnmD mD o 0 m D a m m D a m 3p O1 N m m m m J Y m Ip W W O O O O fD V V� m m Oi N 10 10 m O OI A m O V+ N O O m m A A+ + m m m O O+ m m m W W W m W V m W m W O O m m m N W N J m+ m m m K N+ m W W A A A A A A N W w w W W W W W O A O O V V m m w m m m m A A A A A A m m m m m m m m m m m m m m m m W W+ w W m m m m N m A 0 0 0 V V V V V N y N' 0 0 0 0 0 0 0 o .... 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o a a o 0 0 00000000 G q 0 0 0 o O O o o O O o 0 o O o 0 0 o O o 0 0 o O o 0 0 0 0 0 0 o m o 0 0 0 0 0 0 o O o 0 0 0 0 0 o O 0 O S 0 o a o ... 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o m o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o O o 0 0 0 0 0 0 0 0 0 0 0 0 0 o w o 0 0 0 o O 0 0 0 0 0 0 0 0 0 0 0 0 0 JN N m m W fNj N V V m m b O (J W (J W m O O O O O O O Om m+0V 0V 0V m m m OC goommmmO ...O 00000 V N> Ot m N 4f 4f O O N N A A A> V m O N N N W m m m m m m . 0 W O W N m m N N N W O O m + A W O w m m m �' x' x' m N N+ N ON +++ A 0 2 O d 00 O; G O z O 9 N a O S } Md .0 A 2 0 O N O ' � N o. n N � 0 N, m m O a N N N N m C m O O O O N m A A 3 q R- 3 N m n A m m m N N N w Z W N N m� w a m O 0, XXX m A A m_ry •Z m N N m `f D N N N D � E N Q 3 9 A m i N N m 1p P •• X mD xo4-DL L v m m N N N X p rz o mma�++in iu o +mmmm nm wN NON o D > D D b N N N m f0 N N ////^1111 C b fD m m A A O O w y C �i 0 poppoo0 =�,3 » 0 0 5 c m m 0 0000000 n X30 - w 3 p N V V O � m p n m x 3 3 3 m n A O O Cr m D m m m 66 N U p O m m m O U m m m c c N m n A m m m m m n m p w N W A O � 3 m N N N N m m++ rz o mma�++in iu o +mmmm nm b N N N m f0 N N ////^1111 C b fD m m A A O O w y C �i 0 poppoo0 =�,3 » 0 0 5 c m m 0 0000000 n X30 - w 3 p N V V O + p n m x 3 3 3 m n O O Cr m w 2 m m m 66 U p O m m O D Z A v Printed 2252019 9:59'.56AM North America -ALASKA - BP Psga i of Cementing Report Common Well Name: J-07 / 02 -Report no.: 1 Report date: 123/2019 Project: PSU Site: J — - - - - - Sputl Date/Time: 725/1977 - Event Type: COM- ONSHORE (CON) Start Date: 1202019 End Data AEE No.: Contractor. NABORS ALASKA DRILLING INC.Rip NemelNo.: CDR -2 Rig Reuse: 1242019 X3 -0197K -C: (844,491.00) BPUOI: USA00000372 Alive datum: KB 075.BOost (above Mean Sea Level) eananl information Job type: Primary Cement job start date/time: 1/23/2019 9 35A Job end dateRime: 1/23/2019 11.10AM Cement Company: SCHLUMBERGER Cementer: DANIEL SETTLE Cemented String: PRODUCTION LINER 1 String Size: 3.250 (in) String Set TMD: 12,321.00 (usft) Hole Size: 4.250 (in) Pipe Movement Pipe Movement: NO MOVEMENT Rotating Time (Start -End): RPM: Rotating Torque (initlavg/max): (ft -161) Reciprocating Time (Start -End): Recip Drag Up/Dom. - (kip) SPM: Stroke Length: Fluid Nene: CEMENT FItr10a (1 of 1) Sluny Type. CEMENT Purpose: PRIMARY Class: G -CLASS Description: LEAD SLURRY Density: 15.30 (ppg) Yield: 1.3100 (113/sk) Mix Water Ratio: Excess: 20.00(%) Mb(Mathad: BATCH Sacks Used: 96.50 (9411b sacks) Water Volume: 0.0 (bbl) Excess Slurry Volume: 2.5 (bbl) Density Measured by: DENSOMETER Other Volume: Total Vol in Well: Slurry Volume: 22.5 (bbl) Excess Measurod From: EST. GAUGE HOLE Mud Type: Density: PV: YP: Viscosity: Gels 10 Sec: Gels 10 Min: Additives Name Type Amount Units Concentration Unit D163 CEMENT 5.000 %BWOC D047 ANTIFOAMAGENT 0.100 GAL/SX D206 ANTIFOAMAGENT 0.100 GAUSX 0600 G GAS -BLOCK 1.500 GAUSX D065 1.000 %BWOC D167 0.100 %BWOC Printed 2252019 9:59'.56AM Printed 2/252019 9:59:56AM North America - ALASKA - BP Page 2 of 2 Cementing Report Cammon Well Name: J-07 / 02 TRepart no.: 1 Report date: 1/23/2019 Pro/ectPBU -Project J bite: J Spud Date/Time, 7/25/1977 Event Type: COM- ONSHORE CON YP (CON) Start Date: 1/202018 End Date AFE No.: Contractor: NABORS ALASKA DRILLING INC. I RigName/No.'. CDR -2 Rig Release: 1/242019 X3 -0197K -C: (844 491.00 ) BPUOI: USA00000372 i Active datum. KB tg75.80usR (above Mean Sea Leve0 stag" Stage Stage Type Est. Top Est. Bottom Mud Circ. Mud Circ. Top Bottom Plug Pressure Float Pressure Retums Circulate Cmt Vol to Total Annular no. (usft) (usft) Rate Press. Plug Plug Bumped Bumped nam nem Prior Surface Mud Lost Flow (gpm) (psi) (hr) (bbl) (bbl) After Inas) Im'�l 1 RIMARY CEMENT 10,688.00 12,321.00 Y Y Pumping Scha Jule Fluid pumped Volume Avg. Max Disp. Slurry Top Slurry Base Start Mix Cmt Start Slurry Pumping end Start Disp Foam Gas Type Gas Vol BH circ. Bh static Pumped Disp. Rete TMD TMD Pmp date/time job Used temp. temp. (bbl) Rate (bbVmin) (usft) (usft) (scf) bbVmin Talus Cuing Test Shoe Test Liner Top Test Test Pressure: (psi) FIT/LOT: (ppg) Liner Overlap: (usft) Time: (min) Tool: N Positive Test: (ppg) Positive Test Tool: N Cement Found between Shoe and Collar. N Open Hole Length: (usft) Negative Test: (ppg) Negative Test Tool: N Hours Before Start: (hr) Time before test: (hr) Cmt Found on Tool: N Log/Survey Evaluation Interpretation Summary CBL Run: N Cement Top: (usft) Under Pressure: (Psi) How Determined: Bond Quality: TOC Sufficient: N CET Run: N Job Rating: Bond Quality: If Unsuccessful, Detection Indicator: Temp Survey: N Remedial Cement Required: N Hrs Prior to Log: (hr) How Determined: Printed 2/252019 9:59:56AM THE STATE °fALASKA GOVERNOR BILL WALKER Garret Staudinger Engineering Team Leader — CTD & RWO BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU J -07B BP Exploration (Alaska), Inc. Permit to Drill Number: 218-122 Surface Location: 848' FNL, 804' FEL, SEC. 09, TI 1N, RI 3E, UM Bottomhole Location: 4998' FSL, 1838' FEL, SEC. 04, Tl IN, RI 3E, UM Dear Mr. Staudinger: 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Enclosed is the approved application for the permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Hollis S. French Chair 4 DATED this 24 day of October, 2018. STATE OF ALASKA JLASKA OIL AND GAS CONSERVATION COMMIS. PERMIT TO DRILL 20 AAC 25.005 la. Type of Work: 1b. Proposed Well Class: Exploratory - Gas ❑ Service -WAG ❑ Service - Disp❑ 1c. Specify if well is proposed for. Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Oil 0" Service -Wnj ❑ Single Zone 0 Coalbed Gas. ❑ Gas Hydrates❑ Redrill 0 ' Reentry ❑ Exploratory - Oil ❑ Development- Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket 0 Single Well ❑ 11, Well Name and Number: BP Exploration (Alaska), Inc Bond No. 295705380 PBU J -07B 3 Address: 6. Proposed Depth: 12, Field/Pool(s). P.O. Box 196612 Anchorage, AK 99519-6612 MD: 12220' TVD: 8855'ss- PRUDHOE BAY, PRUDHOE OIL 4a. Location of Well Governmental Section). ( ) 7. Property Designation (Lease Number): ADL 028281 Surface: 848' FNL, 804' FEL, Sec.09, TllN, R73E, UM ' g DNR Approval Number: 13. Approximate spud date: 3679FSL, 1086' FEL, Sec. 04. T11N ,R13E, UM 85-24 December 1, 2018 Top of Productive Horizon: 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth. 4998' FSL, 1838' FEL, Sec, 04, T11N ,R13E, UM 16133 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 75.80- feet 15. Distance to Nearest Well Open t0 Same Pool: Surface: x- 643550 " y- 5970505' Zone - ASP 4 GL Elevation above MSL: 34.87 • feet 0 16. Deviated wells: Kickoff Depth: 11146 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 100 degrees Downhole: 3203 ' Surface: 2323 ' 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casino Weight Grace Couollno Len th MD TVD MD TVD(including stage data) 4-1/4" 3-1/4" 6,60 13Cr85 TCII 1520' 10700' 8768'55 12220' 8855'ss 87 sx Class'G' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 12235 8944 11560''1 11560 8958 None Casing Length Size Cement Volume MD TVD Conductor/Structural 80 20" 213 cu ft PF 41-121 41-121 Surface 2642 13-3/8" 3861 cu ft PF 11, 279 cu ft PF II 41-2683 41 -2683 Intermediate 8705 9-5/8" 1525 cu ft HowcoLite, 250 cu It Class'G', 135 cu H PF'C' 40-8745 40-7261 Intermediate 11031 7- 3069 cu ft Class'G' 38-11069 38-8964 Liner 1298 4-1/2" 196 cu ft Class'G' 10937 - 12235 8936-8944 Perforation Depth MD (ft): 11040 - 12180 Perforation Depth TVD (ft): 8962-8943 Hydraulic Fracture planned? Yes ❑ No 0 20. Attachments Property Plat ❑ BOP Sketch 0 Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval. Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Name Browning. Zachary H from without prior written approval. Authorized Name Staudinger, Garret Contact Email Zachary.Browning@bp.com Authorized Title nearing Team eader- CTD 8 RWO Contact Phone +1 907 564 5220 rEn + Authorized Signature / Dale 0 1 1/1% Commission Use Only Permit to Drill l2 API: 50- 029-20241-02-00 Permit App rov See cover letter for other Number: 'Z Date: fequirements: Conditions of approval: If box is checked, well may not be used to explore for, test, or produce coalbedm—etthh?ne, gas hydrates, or gas contained in shales: / �ESTTID Other Be),M 35t5o�S5 Samples req'd: Yes ❑ No 8d Mud log req'd: Yes ❑/ No EI � 4 flay ld•-Pr. r�0 Zs s t H2S measures Yes No ❑ Directional svy req'd: Yes Ef No 11 Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No Lrl Post initial injection MIT req'd: Yes ❑ No ❑ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1 e (Z4 I jG r� Revised 5/2017 This permit is valid for 24 mont JrdTF tL tlaR 6f apjrpval (20 AAC 25.005(9)) ueme and Attachments ents is Duplicate 4 To: Alaska Oil & Gas Conservation Commission From: Zach Browning CTD Engineer Date: October 8, 2018 Re: J -07B Permit to Drill Request Y 40, bP 1%4lr Approval is requested for a permit to drill a CTD sidetrack lateral from well J -07A with the Nabors CDR2 Coiled Tubing Drilling rig on or around December 1', 2018. Proposed plan for J -07B:, The sidetrack 1-07B will be a "1074' horizontal CST that will kick -out from the 1-07A parent in Zone 2. The CST will establish competitive offtake west of previous 1-07A and east of 1-22A and J-06 by providing opportunities to perforate below OWC and cone down oil while maintaining standoff from gas. The sidetrack will be drilled on or around December 1`t, 2018. During pre -rig work a 4-1/2" whipstock will be set at "'11,146' MD. Then the rig will move in, test BOPE and kill the well. A 3.80" window+ 10' of rathole will be milled kicking off in zone 2. The well will be drilled in zone 2 for the r duration. The proposed sidetrack will be completed with a 3-1/4" 13Cr solid liner, cemented in place and selectively perforated (post rig). Rig Work (scheduled to begin December 1", 2018) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2324 psi). 2. Mill 3.80" Window and rathole. 3. Drill production section: 4.25" OH, 1074' (18 deg DLS planned). 4. Run 3-1/4" 13Cr liner to TD. 5. Pump primary cement job: bls, 15.3 ppg Class G, TOC at TOL ('10,700 MD)*. 6. Freeze protect well to a min 2,200' TVDss. 7. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. V: Valve & tree work 2. C: Test liner lap, RPM (rush), perf —20' 3. 5: Set live valves, contingent set LTP if lap fails 4. F: Test LTP if necessary Mud Program: - • Drilling/Completion: a min EMW of 8.4 ppg KCL with Geovis for drilling (640 psi over -balance) - Disposal: • All Class 1& II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3 at DS 6. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. • Fluids with solids that will not pass through 1/4" screen must go to GNI. • Fluids with PH >11 must go to GNI. Hole Size: • 4.25" for entirety of the production hole section. Liner Program: • 3-1/4", 6.6ft!lsiJid liner: 10,700' MD -12,220' MD • A planned 66sof 15.3 ppg cement will be used for liner cementing (TOC = TOL at 10,700' MD). • The primary barrier for this operation: a minimum EMW of 8.4 ppg (640 psi over -balance). • A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional: • See attached directional plan. Maximum planned hole angle is 100", inclination at kickoff point is 91'. • Magnetic and inclination surveys will betaken every 30 ft. No gyro will be run. • Distance to nearest property— 16,133' • Distance to nearest well within pool — 606' (J-07) Logging: • MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. v • A Neutron/density log is planned post rig. Perforating: • Perforating (post rig):—10-20' of perforations, 2", 60 deg random phasing, 6 spf, perf guns. • The primary barrier for this operation: a minimum EMW of 8.4 ppg (640 psi over -balance). - • A X -over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti -Collision Failures: • None. All offset wells pass BP anti -collision scan criteria. Hazards: • 1 -pad is not considered an 1125 pad. Max recorded H2S reading on 1-07: 18 ppm on 1/24/18. • No fault crossings. • Lost circulation risk is considered Low. Reservoir Pressure: • The reservoir pressure on 1-078 is expected to be 3203 psi at 8800' NDSS (7.00 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2323 psi. ' • A min EMW of 8.4 ppg for this well will provide 640 psi over -balance to the reservoir. Zach Browning CTD Engineer 564-5220 CC: Well File Joseph Lastufka North America - ALASKA - BP PBU J J-07 PLAN J -07B J -07B WP03 Plus 500ft MD AOGCC Offset Well Report 20 September, 2018 BA1��JKUGHES �' 1 a GE company Company: North America - ALASKA - BP Project: PBU Reference Site: J Site Error: 0.00usft Reference Well: J-07 Well Error: 0.00usft Reference Wellbore PLAN J -07B Reference Design: J -07B WP03 Plus 50Dft MD BP BA. ICER Anticollision Report UGHES GE co p ny Local Co-ordinate Reference: Well J-07 TVD Reference: Mean Sea Level MD Reference: Kelly Bushing / Rotary Table Q 75.80usft North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM R5K - Alaska PROD - ANCP1 Offset TVD Reference: Offset Datum Reference J -07B WP03 Plus 500ft MD Filter type: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria To Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 11,108.01 to 12,719.83usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 200.00usft Error Surface: Elliptical Conic Survey Tool Program Date 9/20/2018 From To (usft) (usft) Sumey(Wellbore) Tool Name Description 107.61 8,707.61 1 Camera based gyro multisho (J-07) CB -GYRO -MS Camera based gyro multishot 8,750.00 11,108.01 2 ' MWD -Standard (J -07A) MWD MWD - Standard 11,108.01 12,719.83J -07B WP03 Plus 50011 MID (PLAN J-0713) MWD MWD - Standard Summary She Name Offset Well - Wellbore - Design F J J-07 - J -07A- J -07A J-07 - PLAN J -07B - J-070 WP03 R Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft( (usft( 11,414.05 11,450.00 92.12 12,150.00 12,150.00 0.00 9120/2018 3,14 33PM Page 2 of 2 COMPASS 5000.1 Build BID North America - ALASKA - BP PBU J-07 PLAN J -07B Plan: J -07B WP03 BP Coil Tubing Report 20 September, 2018 BAIGIHES T 1 aGEcompany BP BP Coil Tubing Report BAF�UGHES GF company Company: North America - ALASKA - BP Local Coordinate Reference: Well J-07 Project: PBU TVD Reference: Mean Sea Level Site: J MD Reference: Kelly Bushing / Rotary Table @ 75.80usft - Well: J-07 North Reference: True Wellborn: PLAN J -07B Survey Calculation Method: Minimum Curvature Design: J -07B WP03 Database: EDM RSK- Alaska PROD -ANCP1 Project PBU, PBU, PRUDHOE Map System: Alaska NAD27 State Plane Zones System Datum: Mean Sea Level Geo Datum: NAD27' OGP-Usa AK [4267'158641 Using Well Reference Point Map Zone: NAD27' OGP-Usa AK / Alaska zone 4 [26734`1586, Using geodetic scale factor Site J. TR -11-13 Site Position: From: Map Position Uncertainty: 0.00 usft Well J-07, J-07 Well Position .N/ -S 0.00 usft -EI-W 0.00 usft Position Uncertainty 0.00 usft Wellbore PLAN J -07B Magnetics Model Name BGGM2018 Design J -07B WP03 Audit Notes: Version: Vertical Section: Northing: Easting: Slot Radius: Northing: Easting: Wellhead Elevation: 5,9hd,224.22U usft Latitude: 641,155.790 usft Longitude: 0.000 in Grld Convergence: 5,970,505.360 usft Latitude: 643,549.680 usft Longitude: 38.46 usft Ground Level: Sample Date Declination Dip Angle Field Strength (°) (°) InT) 1/1/2019 17.02 80.94 57.440 Phase: PLAN Depth From (TVD) +N/ -S (usft) (usft) -3846 000 Tie On Depth: 11,108-01 +EI -W Direction (usft) (°) 000 34985 70° 19' 14.845 N 148° 51'20.092 W 1.08 ° 70° 19'36,831 N 148° 50' 8.966 W 38.40 usft 9/20/2018 2: 56:47PM Page 2 COMPASS 5".1 Build 81D BP BP Coil Tubing Report BA ER BAT GE company Company: North America -ALASKA - BP Local Co-ordinate Reference: Well J-07 Project: PBU TVD Reference: Mean Sea Level Site: J MD Reference: Kelly Bushing / Rotary Table @ 75.80usft Well: J-07 North Reference: True Wellbore: PLAN J -07B Survey Calculation Method: Minimum Curvature Design: J-078 WP03 Database: EDM RSK- Alaska PROD -ANCP1 Survey Tool Program Date 9/20/2018 From To (usft) (usft) Survey (Wellbore) Tool Name Description 107.61 8,707.61 1 Camera based gyro multisho (J-07) CB -GYRO -MS Camera based gyro multishol 8,750.00 11,108.01 2: MWD- Standard (J -07A) MWD MWD -Standard 11,108.01 12,219.83 J -07B WP03(PLAN J-078) MWD MWD -Standard Planned Survey MD Inc Azi TVDSS NIS FJW Northing Easting DLeg V. Sac TFace (usft) r) (°) (usft) (usft) (usft) (usft) (usft) (°I100usft) (usft) (°I 11,108.01 89.94 0.84 8,888.52 5,139.90 -327.27 5,975,637.667 643,124.168 0.00 5,117.15 0.00 JWA Actual Survey 11,139.98 90.65 1.56 8,888.35 5,171.86 -326.60 5,975,669.633 643,124.226 3.16 5,148.49 45.40 J -07A Actual Survey - TIP 11,146.00 90.71 1.70 8,888.28 5,177.88 -326.43 5,975,675.652 643,124.282 2.53 5,154.39 66.80 HOP 11,166.00 89.02 1.08 8,88(1.33 5,197.87 -325.94 5,975,695.649 643,124.385 9.00 5,173.98 -160.00 Start DLS 18.00 TFO -160.00 11,200.00 83.27 358.99 8,890.82 5,231.78 -325.92 5,975,729.548 643,123.759 18.00 5,207.35 -160.05 11,206.00 82.25 358.61 8,891.37 5,237.73 -326.04 5,975,735.495 643,123.520 18.00 5,213.23 -160.02 Start Turn .18.17 11,300.00 82.25 341.53 8,904.04 5,329.14 -342.04 5,975,826.573 643,105.778 18.00 5,306.03 -91.16 11,321.93 82.26 337.55 8,907.00 5,349.50 -349.64 5,975,846.781 643,097.795 18.00 5,327.41 -90,19 26P 11,388.00 82.25 329.54 8,912.94 5,388.56 -369.07 5,975,885.459 643,077.616 18.00 5,36928 -90.58 Start DLS 18.00 TFO -50.00 11,400.00 86.21 324.85 8,916.36 5,416.97 -387.40 5,975,913.517 643,058.754 18.00 5,400.48 -50.00 11,432.39 90.00 32041 8,917.43 5,442.69 40704 5,975,938.849 643,038.626 18.00 5,429.26 -49.53 Start DLS 18.00 TFO -90.00 11,500.00 90.00 308.24 8,917.43 5,489.85 -455.31 5,975,985.070 642,989.463 18.00 5,484.18 -90.00 11,600.00 90.00 290.24 8,917.43 5,538.50 .542.21 5,976,032.048 642,901.659 18.00 5,547.38 -90.00 9120/2018 2:56:47PM Page 3 COMPASS 5000 1 Build 81D Company: North America - ALASKA - BP Project: PBU Site: J Well: J-07 Wellbore: PLAN J -07B ICER Design: J -07B WP03 Planned Survey Tubing Report MD Inc lusftj 1°j 11,612.39 90.00 Start DLS 18.00 TFO 90.00 11,700.00 90.00 11,800.00 90.00 11,827.39 90,00 Start DLS 18.00 TFO 30.00 11,891.65 100.00 Start Turn -18.28 11,896.25 100.00 26P 11,900.00 100.00 12,000.00 100.00 12,012.00 100.01 POWC 12,028.90 99.99 KOP-POWC 12,092.24 100.00 PGOC Kelly Bushing I Rotary Table @ 75.80usft 12,100.00 100.00 12,132.40 100.01 PGOC 12,149.83 100.00 Start Turn 18.28 12,155.40 100.01 26P Survey Calculation 12,200.00 100.00 12,219.83 100.00 TD at 12219.83 9/20/2018 2:56:47PM Page 4 COMPASS 5000.1 Build BID BP BA, ICER BP Coil Tubing Report IGHES aGFcompany Local Co-ordinate Reference: Well J-07 TVD Reference: Mean Sea Level MD Reference: Kelly Bushing I Rotary Table @ 75.80usft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM R5K - Alaska PROD - ANCPI AN TVDSS NIS EIW Northing Seating OL99 V. Sec TFace 1°I lusftj lusftj lusftj lusftj (ust) 1°1100usft1 (usft) 288.01 8,917.43 5,542.56 -553.91 5,976,035.882 642,889.880 18.00 5,553.44 -90.00 303.78 8,91743 5,580.71 -632.47 5,976,072.517 642,810.608 18.00 5,604.83 90.00 321.78 8,917.43 5,648.35 -705.56 5,976,138.746 642,736.242 18.00 5,684.30 90.00 326.71 8,917.43 5,670.57 -721.56 5,976,160.655 642,719.824 18.00 5,708.99 90.00 320.87 8,911.83 5,722.15 -759.29 5,976,211.500 642,681.117 18.00 5,766.41 -30.00 320.03 8,911.03 5,725.64 -762.18 5,976,214.937 642,678.166 18.00 5,770.36 -89.87 319.34 8,910.38 5,728.46 -764.57 5,976,217.707 642,675.724 18.00 5,773.55 -90.01 301.06 8,893.02 5,791.76 -839.46 5,976,279.559 642,599.637 18.00 5,849.06 -88.40 298.87 8,890.93 5,797.66 -849.70 5,976,285.264 642,589.289 18.00 5,856.67 -89.60 295.78 8,888.00 5,805.30 -864.48 5,976,292.618 642,574.364 18.00 5,866.80 -90.00 264.20 8,877.00 5,826.59 -923.00 5,976,312.783 642,515.449 18.00 5,898.07 -88.98 282.78 6,875.65 5,828.38 -930.43 5,976,314.423 642,507.988 18.00 5,901.13 -89.72 276.86 8,870.03 5,833.82 -961.86 5,976,319.261 642,476.466 18.00 5,912.02 -89.42 27367 8,867.00 5,835.39 -978.95 5,976,320.509 642,459.349 18.00 5,916.58 -89.84 274.69 8,866.03 5,835.79 -98442 5,976,320.804 642,453.872 18.00 5,917.94 89.60 282.84 8,858.29 5,842.48 -1,027.79 5,976,326.662 842,410.383 18.00 5,932.17 89.33 286.47 8,854.84 5,847.42 -1,046.68 5,976,331.240 642,391.403 18.00 5,940.36 89.69 9/20/2018 2:56:47PM Page 4 COMPASS 5000.1 Build BID BP BP Coil Tubing Report BA ER' BAT It ,ES Company: North Amedca- ALASKA -BP Local Co-ordinate Reference: Well J-07 Project: PBU TVD Reference: Mean Sea Level Site: J MD Reference: Kelly Bushing / Rotary Table @ 75.80usR Well: J-07 North Reference: True Wellbore: PLAN J -07B Survey Calculation Method: Minimum Curvature Design: J -07B WP03 Database: EDM RSK- Alaska PROD -ANCP1 Plan Annotations Measured Vertical Local Coordinates Depth Depth .N/ -S +EI -W (usft) (usft) (usft) (usft) Comment 11,108.01 8,888.52 5,139.90 -327.27 J -07A Actual Survey 11,139.98 8,888.35 5,171.86 -326.60 J-07AActual Survey - TIP 11,146.00 8,888.28 5,177.88 -326.43 KOP 11,166.00 8,888.33 5,197.87 -325.94 Start DLS 18.00 TFO -160.00 11,206.00 8,891.37 5,237.73 -326.04 Start Tum -18.17 11,366.00 8,912.94 5,388.56 -369.07 Start DLS 18.00 TFO-50.00 11,432.39 8,917.43 5,442.89 -407.04 Start DLS 18.00 TFO -90.00 11,612.39 8,917.43 5,542.56 -553.91 Start DLS 18.00 TFO 90.00 11,827.39 8,917.43 5,670.57 -721.56 Start DLS 18.00 TFO-30.00 11,891.65 8,911.83 5,722.15 -759.29 Start Turn -18.28 12,149.83 8,867.00 5,835.39 -978.95 Start Turn 18.28 12,219.83 8,854.84 5,847.42 -1,046.68 TO at 12219.83 9/20/2018 2'56-47PM Page 5 COMPASS 5000 1 Build BID North America - ALASKA - BP PBU J J-07 PLAN J -07B J -07B WP03 Anticollision Summary Report 20 September, 2018 BAT IGI0 1 a GE company Company: North America - ALASKA - BP Project: PBU Reference Site: J Site Error: 000usft Reference Well: J-07 Well Error: 0 o0usft Reference Wellbore PLAN J -07B Reference Design: J -07B WP03 BP Anticollision Report Local Coordinate Reference: Well J-07 TVD Reference: Mean Sea Level MD Reference: Kelly Bushing / Rotary Table @ 75.80usft North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM R5K - Alaska PROD - ANCP1 Offset TVD Reference: Offset Datum UGHES GE[.w, Reference J -07B WP03 Filter type: NO GLOBAL FILTER: Using user defined selection 8 filtering criteria To Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 11,108.01 to 12,219.83usft Sun Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1.418 25usft Error Surface: Elliptical Conic Survey Tool Program Date 9/20/2018 Distance From To (usft) from Plan (usft) (usft) Survey (Wellbore) Tool Name Description 107.61 8,707.61 1 : Camera based gyro multisho (J-07) CB -GYRO -MS Camera based gyro multishot 8,750.00 11,108.01 2: MWD- Standard (J -07A) MWD MWD -Standard 11,108.01 12,219.83 J -07B WP03(PLAN J-0713) MWD MWD- Standard Summary Site Name Offset Well - Wellbore - Design J J-07 - J-07 - J-07 J-07 - J -07A - J -07A J-08 - J -08A- J -08A J-24 - J-24 - J-24 J-24 - J -24A - J -24A J-24 - J-24APBI - J-24APSI J-24 - J-24APB2 - J-24APB2 R R-10 - R-1 OA - R-1 OA Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 11208.01 10,950.00 707.22 11,414.05 11,450.00 92.12 12,108.01 13, 875.00 1,413.50 No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) 385.46 365.78 Pass - Major Risk 6.96 85.32 Pass - Major Risk Out of range Out of range Out of range Out of range Out of range 389.69 1,029.89 Pass- Major Risk 9/20/2018 3:27:45PM Page 2 of 3 COMPASS 5000.1 Build BID Company: Project: Reference Site: Site Error: Reference Well: Well Error: Reference Wellbore Reference Design: North America - ALASKA - BP PBU J 0.00usft J-07 O.00usft PLAN J-078 J -07B WP03 f EIP BER Anticollision Repoli UGHES a GE<.u, Local Coordinate Reference: Well J-07 TVD Reference: Mean Sea Level MD Reference: Kelly Bushing / Rotary Table @ 75 80usft North Reference: True Surrey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM RSK - Alaska PROD - ANCP1 Offset TVD Reference: Offset Datum Reference Depths are relative to Kelly Bushing / Rotary Table @ Coordinates are relative to: J-07 Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27' OGP-Usa AK Central Meridian is 150° 0'0,000 W ° Grid Convergence at Surfaceis: 1.10° Ladder Plot I -- - - -- - - - - - - - - - - I I I � I I I I I I I II i I i I l I i I --- ------------------------ LEGEND 0 -6- J-24,J1,J-F $ J -24„424,J -24V3 -17,J-17BPB1,J-17BPBl V4 $- J-17,J-17B,J-17BV15 $ J-17,J-17A,J-17AV5 $ J-17,J-17C,J-17CV11 $ J-17„117D,J-170VO -f ,117,J -17,J -17V5 ->� J -22„122,J -22V3 -� J-22,J-22A,J-22AV1 $ J-01,J-01B,J-01BV7 $ J-01,J-01B,Plan*7V4 %- J05,J.05CLC10995C/�Ll V2-W0.1-19„119PB1,,A9P@QV0 12000 �IIOlgft(2000 USIRjD-- J -21,J -21,J-21 VI $ J-05,J-05B,J-05BV14 $ J -06,.1 -06,J -06V1 -Xf J-06,J-0BPB1,J-06PB1 VO -A- ,107„107A,J-07AV1 -8- J -07,J -07,J -07V1 $ .108,.108,]-O8V4 $ ,108, J -08A, J -08A V8 $ J-08,J-08PB1,J-08PB1 V3 - J-1o,J-10,J-10vl �- ,110„L10A,J-10A V3 -dr J-23,J-23A,J-23AV4 -t- .128,J-28APB7,J-28APB1 VO $ J28,J-28A,J-28AVO $ JX-02,JX-02,JX-02 V1 $ JX-02,A-02PB1,JX-02PB1 VO -W J0(-02, JX-02A,JX-02A V1 -Id- J -03,J -03,J -03V1 J -09,J -09,J-09 vl $ J-09,J-09B,J-09BVO $ J-09,J09BPB1,J-09BPB1 VO 9/202018 3:2745PM Page 3 of 3 COMPASS 5000.1 Build 81D Project: PSU Site: J by Well: J-07 Wellbore: PLANJiOnS Plan: J -07B WPW IJ471PI.AN J07B) V.ELL DETAILS: J-07 Ground Lttrel'. 3840 SECTBJNDETAILS Sec MD Inc Azi WTVD .WS .EPW Dhg TFace VSen Target 1 11108.01 89.94 0.84 8888.52 513920 327.27 0.00 0.00 5117.15 2 11139.98 90.65 1.56 8888.35 5171.86 326.60 3.16 45.10 5148.49 3 11146.00 90.71 1.70 6888.28 5177,88 326.43 253 66.80 5154.39 4 11166.00 69.02 1.08 8808.33 5197,87 325.94 9.00 .160.00 5173.96 5 11206.00 82.25 358.61 8891.37 5237.73 -326.04 18.00 -160.10 5213.23 6 11366.00 82.25 32954 891294 538856 359.07 18.00 -9020 536928 7 1143239 90.00 320.41 8917.17 5442.69 407.04 18.00 5020 542926 8 1161239 90.00 280.01 8917.43 554256 -553.91 18.00 -9020 5553.44 9 11827.39 90.00 326.71 8917.43 567057 -721.56 18.00 90.00 5708.99 10 11891.65 100.00 320.87 8911.83 5722.15 -759.29 18.00 -30.00 5766.41 11 12149.83 100.00 273.67 8867.00 5835.39 .978.95 16.00 -9020 591658 12 12219.83 100.00 286.47 8854.84 5847.42 -1046.68 18.00 90.00 5940.36 O c 261'x, g Xmu `231x°' 'zn` X43. W 4WU L F `IUiU Axmw.mm.Nmn Mprcw XaM.t]R nyle&Rb S6eryX.57M]au' c°m nr�ml IANeI&iCJ.NI WELLBORE DETAILS. PLAN J -07B fEFEfdIJC£IKCRAki81N J-078 coonrre.(w Fiefeenm Waal T.NW, V.reei FMeevn Nee SeeteM Parent Wellbore: J -WA wean Nsl Releenw sbbleem'ccoE) Tle on MO: 111D8.01 A�1ee8 oepm ReM<rce Xery 8w11g/Rolmyinla®tSwuX CtloIN4m AkXrd kh'.pweWe ANNOTATIONS TVD MD Amtalm 88885211108.01 J-07AAchealSunecy 8888.3511139.98 J-07AAc8Jal Survey-T8J 8888-2811146.00 KOP 8888.3311166.00 Sba0LS18.00TFO-160.00 8891.3711206.00 StertTu n-18.17 89129411366.00 Sill 18.00TFO50.00 8917.4311432.39 StOWLS18.00TFO-90.00 8917.4311612.39 SldDLS lull rF090.00 8917.4311827.39 Stal18.00TFO-30,00 8911,8311891.65 Ste ln-18.28 8867.00 12149.83 Sta0 Tum 18.28 8854.8412219.83 TDatl2219.83 7WO'' 68110 J -07B WP03 00 c66 6400: J47B FaYl¢ J -07B Fel J417n 116200; 1-078n �Wo Z. I/4" J-07BT2 =5800 1-07BTI ^600; 07 L - 5400 O 1416 J 14,A 5200. 14 In' OWS J-2J,AP I 1-07B Faul24 J-14 k I R I 000- 1-07B Feul13 48W 46W 44C0' -2200 -2000 -IWO -IWO -1400 -1300 -IWO -800 fi 400 -200 0 200 400 600 800 IWO IWO 1400 West( -)/East(+) (200 us Win) J -07B WP03 JI/!'-I'lemxd l'IrU'Y KtIP 10711 n J 07AnnwlSunn .51211 Tem -Ib 2b 1.l ium-1e 17 ` 11711,1-11..,,V- III ' SIVAn1VIXW no .0 w � ti4NDLY Itl YY IIY).3UW SlaNnl.5 I800 JFO-5000 slw11l1.x 18 a l' 1114000 1YAnItiIb.W 1411-1! W IA7n 13 3 I/J' - _ Ii1TI WN!1 .wn rwn lnza 1,13, Mean Se9NWvel4w Jsuu 4550 4auo aai0 4700 4750 4800 Jbs. 4900 Jvsu suwl iuiU iIW 5150 ixul 5x50 vul, msu sam 54s0 5500 sssa si wsu 5i.0 5750 A. yes. sv.. 54so aoa. anw aIW 615u 6200 6250 elm Vertical Section at 349.85° (50 ustl/in) Project: PBU BBa: J Wall: J-07 Wetlbore: PUNJ478 Plan:J47B WPU3(J-011PLAN J -07B) ANThCOLLISIDN SETONGS 11350 COMPANY DETAILS: NoMArdaica-AL MS BP Interpolation Method: 28D.Weand:25A0 11550 Celcula4on Meflod: Minimum CurvaWe Depth Rage From: MOM To 12218.83 • J42 J BPBI, JMWB1 W +J J458, J-056 V14 Eoor Syafem.' ISCWSA Resider Limited By: Centre Distance: 10825 • IX -02 JX@, JX42 V1 Scan Method: Tray. Cylinder Noah Reference: Plan: J-078 Ilt(J-07NtAN J-0)5) J@, JL F02AV12 Eno, Sudere: EllipOcalComc •J-10, J10&J10AW .J19, J-19, J-19 Vt Waning Method: Rules Based Ladder Plot J J J J 41 W A ➢ N G O O O O O O O O J-078 WP03 ible Magnetic Interference from: KOP to 11,350'MD N N do N re 0] Ip fp OO . N fJ N O N O N O N O O N O N O O O O O O O O O O O O O O O O Measured Depth (50 usftlin) BAKER JUGHES From Colour To MD 11108 11350 11350 11550 11550 12220 - }NJ34AP02 }24PPB2 V3 - J -P, J M. J-170 W • J 01. lOt F01 W + JL5, J-06APat. }OSAPBI Va - JdB, J-0SPB1, J48PB1 W - J-18, J 18, J-18 V1 • J46. J -28A, J28A Vo • J-09. JL9A lt9AW J24, J-24AP01, J-2 A B1 N - J-17, J-17, J-17 VS • J42 J BPBI, JMWB1 W +J J458, J-056 V14 • J-10, J10. J-10 V1 - }18. J -18A J-18AW • IX -02 JX@, JX42 V1 • R-10. R -10A, R-10AW . J24. J24,}24 V3 •J@, J -22J V3 J@, JL F02AV12 -J{6, J{6, JJM V1 •J-10, J10&J10AW .J19, J-19, J-19 Vt •JX -02, JX42PB1, JX-02PB1 W-JA3J-13,J-13W - 124. 124A. 124A -- J-2; J- J -22A V1 ^ 102, 1028, J BV5 - JL6, J-06PB1, J2ePB1 V,c -• J-10, J -IDB, J-108 vc - N9, Y19PB1, J-19PB1 W - JX@, Jpt 2 JX -02A V1 • J-13, J -13A, J -1M W -117.1178PB1, J-178PB1 V4 = J 31, J -01B. J -01B W - J05, J -05A, l AW - J-07, J -07A JWA VI •• J-11. J41AP81, J IWB1 VI - J 21, J-01, J-21 Vt - J-03, J03, J03 V1 • J 07B WP03 -• F17. J-178. J 170 V15 - J-01, JL1B, Plan V V4 - J 05, JOSC, J-050 W - JL7, J-07. J97 V1 • J-11. J-11, J -it Vt - J43, J-23, J4t3 V1 -J-09. J09, J09 V1 -•117. J -17A 117AV5 -MI, MIA J01AV1 -J05, J-05CL1, J-05CL1W -JM, J-0B,J-08W - JA1,}11A J -11A V1 Nd3, J -23A J-23AW J-09. J-098 JL9BW • 117, 117C, J -17C V11 -Ml J41PB1J-01PB1 V0 - J-05, }05J05 V16 - JL8, ARIA J -08A W - J-12, J-12, J-12 V1 - JQa, JQ8APBIJ-26APB1 W • J49, J498PB1, J-09BPB1 VO "T' Project: PBU Site: J by 4J Well: J-07 Wellbore: PLANJ-07B Plan: J -07B WP03 (J-07/PLAN J -07B) ANTI -COLLISION SETTINGS COMPANY DETAILS: North America- ALASKA - BP Interpolation Method: MD, interval: 25.00 Depth Range From: 11108.01 To 12219.83 Results Limited By: CentreDislance: 1418.25 Reference: Plan: J -07B WP03 (J-07/PLAN J-076) Depth Range- 11108.01 To 12219.83 11108 Colour 711350 Possible Magnetic Interference: OD From KOP to 11,350' MD 3 1 �0 11350 11550 \ 11550--12220 20 System: ISCWSA Method: Tray. Cylinder North Surface: Elliptical Conic BAKER UGHES c,eum I : uu �W8 nF/n NorMl1 .., .... L ,ft. 6.W A. smes.M0 6.a. M 1 W31 IM-0&MW 2 11139.08 goes 1.56 8808.35 5171.86 -=.so 3.1645.4D 5148.49 3 11146.00 90.71 1.70 8888.28 5177.98 -326.43 2.53 65 as 5154.38 4 11166.00 39.02 1.08 8888.33 5197.87 -325.94 9.00 .160.00 5173.98 5 11206.00 82.25 358.61 8891.37 5237.73 -326.04 10.00 -160.00 5213.23 6 11366.00 02.25 329.54 8912.94 5388.56 -359.07 10.00 -90.00 5359.20 7 11432.39 90.Do 320.41 8917.43 5442.69 -007.04 10.00 -50.00 5429.26 8 11fi12.39 90.00 260.01 8917.43 554256 -553.91 10.00 -90.00 5553.4 9 11821.39 90.00 326.71 8917.43 5670.57 -721.16 18.00 90.0 5708.99 10 11891.65 100.00 320.87 8911.83 572.15 -759.29 10.00 -30.00 5766.41 11 12149.83 110.0 273.67 8867.00 5835.39 -978.95 18.00 .90.00 5918.58 12 12219.83 100.00 286 A7 8854.84 5047.42 -0046.08 18.00 90.0 5940.36 SIIRYEYPwoG DWM From Dem T. aw Mw iod 107, 1 970761 1: CMME WWMM4 Mu LaGYRO-MS .11. 1110801 2'... -.(J -07A) MM 1110601 IM19M JVSB 31P1 NM791 MM DD LEGEND 1 BD a lM, 111A 1-.11 .- R-10 R -ILLY R -1.1V Azimuth from North [°]vsCentre toCentre Separation (10usft/in] J4 7J"J�V1 Azimuth from North ri vs Centre to Centre Separation [40 ustVin[ Project: Paueaau. 7++� WELLBORE DETAILS: PIAN J -07B nEFEa s(ZffOBwnOs sire: J F n J -07B �,aro.wmrohled : MAV T.w ER b .are.. ICHEs Wall: J47 surae. _aw 1101TVDIPe+erenm: Ne --UM eGE.m+WM Wetlbore: PIAN J-076 uasrvrsura secron Nslaexie— Sol-Ioasx.MQ PIan:J-07B WP03llbs.: 011MD J-O7IPLAN J -07B mev+rzo+ Parent Wellbore: J -07A ya:um o.einanc.m. KeRV& m11RAw T.eta7se0M+ 0 1 I rrami scctan Te on MD: 11108.01 cemubtian emawa. w<+mmcuveeva Eastinc (100 usNin) EasliN (100 usNin) Mean Sea Level TREE= CAMERON WELLHEAD= FMCGENV ACIUATOR= OTIS !DIAL KB. ELE 68.4' BF. ELEV = 40.16' KOP= 2800' Max Angle = 96' 11652' Datum MD= 107ST Datum TVD = 8804 SS 13-31W L-80, CONDUCTOR D= ' P OF 7" SCAB LNF B3 bpf, D = 6276' N-80. D = 12.347 SAFL NOTES: WELL > 70" @ 10963' — MAX J —O 7 ,� DOGLEG: 12.3- @ 8778'*** 13-318- CSG CRACKED BELOW BRADENHEAD WELD -30' L'•' 4-12' CHROMETBG"' WELLHEAD STARTS AT9-518- 1 7 CSG - NO OOA "' BOTTOM OF SCAB LNR H 862W 17- TEBACK SLV. D = 6.250- H 8829' -5/8' X 7" BKR ZXP R0K D = 6.312' 8637' K 7' BKR FMC LNR Fi R. D = 6.187' 8842' 9-518' CSG, 47#. 4 80, D = 8.681' 8748' Minimum ID = 3.725" @ 10932' 4-1@" HES XN NIPPLE 1/2" TBG, 12.6#, 13 -CK .0152 bpf, D = 3.958' 10739' 4-12' TBG STUB (XX/XX/XX) 10841' 4-1/2" TFRACK SLV. D = 5.250' GAS LFT MANDFELS ST MD TVD DEV VLV TYPE LATCH PORT DATE 6 3638 3619 20 KGB -2 DOME BK 16 07115104 5 6092 5474 45 KBG-2 SO BK 20 07115104 4 8091 6826 48 KBG-2 DW BK 0 07/05104 3 9462 7863 29 KBGG2 OMY 8K 0 07/05/04 2 10158 8466 30 KBG-2 DMY SK 0 07/05104 1 10563 8780 56 KBG-2 DMY BK 0 07/05/04 9-518' MLLOUT WrDOW (J -07A) 8745' - 8795' 10�—i7' x 4-12' BKR S-3 PKK D= 3.875' 10718' 4-12' FES X NP. D = 3.813" KK D= 3.813" 17" X 4-12" BKR HMC LNR HGK D - 4.375' H 10949' 1 PERFORATION SUMMARY REF LOG: DPC PERF ANGLEAT TOP PEW.- 84-@11040' Note: Refer b Production DB for historical perf data SIZE SPF NTBNAL Opn/Sgz SHOT SOZ 2-3/4' 6 11040- 11070 O 05116116 2-3/4' 6 11070-11100 O 05116116 2-7/8' 6 11240- 11270 O 04/27115 2-314' 4 11630 - 11750 C 06/10/96 2-3/4' 4 11810-11950 C 06110196 2-314' 4 12140- 12180 C 06110196 4-12' WFD ISO RBPw / JLN( CATCHER SUB (04122/15) 7" LNR 26#, L-80 .0383 bpt, D = 6276' PBTO 12184' � 4-1/2- LW 12.6#, L-80, .0152 bpf, D = 3.95W 12235' DATE REV BY COM`BQTS DATE REV BY COM am 10104/77 OfMYNAL COMPLETION 04/22115 CJS/ PJC SET WFR ISO RBP 0611V96 SBR SIDETRACK(J-07A) 0427/15 CfSI PJC ADR3W 1210002 MNIK K RWO SUSP943ED 05116116 JLS/JMD ADPEWS (05/16116) 07106104 DCFVKAP RWO 0623/17 RBIJMD SET PX RUG (06114117) 08/14111 JLJ/ RIC GLV OOFWC'IION 0822117 JWJP.0 PILL® PX RUG (0820117) 05/0B/13 JF PYJM) SET 4-12 CEP (0429/13) PRUDHOE BAY UNT WELL J -07A PEHMT No: '1960870 API ND: 50-029-20241-01 SEC 9, T11N, R13E, 848' RL 8 804' FEL 13P E'Xploraaon (Alaska) WELLHEAD= FMC GEN V ACl/ ATOR= _ INTINL KB. ELE 68.4' BF. E -E/ = 40.16' KOP= 2800' Ml: Angle = - -_° Datura KID @ _ Oaten TVD= 8800'SS PROPOaED Nt 269, L-80, .0383 bpl. D = 6.276' 13-3/8' CSG, 724, N-80, D= 12.347' BOTTOM OF SCAB LNR X 7' BKR H G LNR HGR D = 6.187' ri 6642• 9-58' CSG, 474, wao. D = 8.681' 8746' Minimum ID = _" @ ' TOP0F3-1/4-LNRlCMT 10760' 4-12' TEBACK SLV. D- 5.250• X 4-12' BKR HMC LNR HGP, D - 4.375' 7- LNR 26#, L-60..0383 bp1. D = 6276- 14-1/2" VN-IPSTOCK 'LNR 12.6#- L-80..0152 WE D = 3.958' PERFORATION SLR~Y REF LOG. ON XX -XX -XX ANGLE AT TOP PERF: data J -07B SAFL- - NOTES: WELL > 70' @ _' "' MAX DOGLEG: . @ "' 13-318" CSG CRACKED BELOW BRADENHEAD WELD -30" L "' 4-112" CHROME TBG "' WELLHEAD HEAD STARTS AT 9-518" CSG - NO OOA"' CHROME LNR "' 94113• M1/2'HPSXNPn=3.613• GAS LFT MANORE-S ST M) TVD DEV VLV TYPE LATCH PORT DATE 6 3638 3619 20 KGB -2 DO BK 16 07/15/04 5 6092 5474 45 KBGa2 SO BK 20 07/15/04 4 8091 6826 48 KBG-2 DMY BK 0 07/05104 3 9462 7863 29 KBG-2 DMY BK 0 07/05(04 2 10158 8466 30 KBG-2 DMY BK 0 07105/04 1 10563 8780 56 KBG-2 I)MY BK 0 07105104 9-58' MLLOL7T VACM (J -07A) 8745'-8795- 11' 745'-8795'N' 4-12' FES X NP, D = 3.813' z 4-12' BKR S-3 PKP, D = a UY SLV, u= s.OU- HEX D3 Ml1LESHOE V61.EG, D = BKR S•3 R(K D = 3.875' X NP. D= 3.813' BEHIND CT LNR 12' W -EG, D= 3.958' X 4-12' BKR ZXP PKK D - 4.375' MLLOUT WPDOW (1078) 11146 - 11156' DATE REV BY OOMIB4TS DATE REV BY OOkTBJTS 1084177 ORIGNAL COMPLEDON 06111/96 SBR SIDETRACK (J -07A) 12102102 OOVVIKK MIND SUSPENDED 0786104 DCFVKAP RWO _I_I_ CTD ST(J-076) 05/29118 JMD BLRT PROPOSED PRLUHOE BAY LENT WELL: J -07B PEFW W: AN W: 50-029-20241-02 SEC 9, T11 N, R13E� 848' FPL 8 804' FEL BP Exploration (Alaska) Well Bighole CDR2-AC 4 Ram BOP Schematic Date 8 -Oct -18 Quick Test Sub to Otis -1.1 ft Top of 7" Otis 1 0.0 ft jo, — — — — — -- --=-------- F—CDR2 Rig's Drip Pan Distances from top of riser Excluding quick -test sub 4 h1116" 6k Flange X T' Otis Bae Top of Annular 6.0 ft Hydril 7 1/16 Top of Annular Element 6.7 ft Annular - Bottom Annular Cc Blind/Shears BlindiShear 9,3 ft 0. 2-3/8" Pipe/Slips 2.318" Plpellu 10.1 ft 81 ez e0 Ba Kill Line CL 2-3/8" x 3-1/2" VBRS 12.6 k CL 2-3/8" Pipe/Slips 13.4 ft CL of Top Swab 16.0 ft4111 �— Swab Test Pump Hose Me T1 1 T2 CL of Flow Cross 17.4 ft f� Master CL of Master 18.8 tt LDS O IA OA LDS O Ground Level 0 Rixse, Melvin G (DOA) From: Rixse, Melvin G (DOA) Sent: Wednesday, October 17, 2018 11:16 AM To: 'Browning, Zachary H'; Lastufka, Joseph N Subject: RE: Cement volumes and yield for PBU J -07B PTD(218-122) Zach, Thank you. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY 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(s). It 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 Mel Rixse at (907-793-1231) or (Melvin. RixsePalaska.gov). From: Browning, Zachary H <Zachary. Browirl bp.com> Sent: Wednesday, October 17, 2018 8:43 AM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>; Lastufka, Joseph N <Joseph.Lastufka@bp.com> Subject: RE: Cement volumes and yield for PBU J -07B PTD(218-122) Mel, In addition to your calculations: • We're using 20% open hole excess (+1.5 bbls) • There is 100' of 7"exposed from 10,739'-10841' MD which adds (+2.3 bbls) • We are planning 200' of cement that will be washed off the TOL to ensure a good lap (+1.9 bbls) • Plus our side exhaust volume (+2 bbls) • But only 40' of shoe track (-0.3 bis) • Total difference = +7,4 bbls Thanks, Zach From: Rixse, Melvin G (DOA) <nnelvin.rixse@alaska.eov> Sent: Wednesday, October 17, 2018 7:55 AM To: Browning, Zachary H <Zachary.Browning@bp.com>; Lastufka, Joseph N <Joseph.Lastufka@bp.com> Subject: RE: Cement volumes and yield for PBU J -07B PTD(218-122) Zach, I calculate cement volume as follows: 10.6 bbls=((((3.958A2)-(3.25A2)) /1029.4 )*(11146-10700)) + ((((4.25A2)-(3.25A2))/1029.4)*(12220- 11146)) + ((2.8A2)/1029.4*80) Are you planning 92% excess in the open hole (or significant amount over TOL)? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY 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(s). It 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 Mel Rixse at (907-793-1231) or (Melvin.RixsePalaska.eov). From: Browning, Zachary H <Zachary.Browning@bp.com> Sent: Wednesday, October 17, 2018 6:31 AM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>; Lastufka, Joseph N <Joseph.Lastufka@bp.com> Subject: RE: Cement volumes and yield for PBU 1-07B PTD(218-122) Mel, The 17.9 bbls of 15.3 ppg cement is actually correct. I believe the 13.9 bbls was a typo on the sundry that got carried forward onto the summary section of the PTD. My apologies for the error. Thanks, Zach From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Tuesday, October 16, 2018 4:34 PM To: Browning, Zachary H <Zachary.Browning@bp.com>; Lastufka, Joseph N <Joseph.Lastufka@bp.com> Subject: Cement volumes and yield for PBU J -07B PTD(218-122) Zach,Joe, I see two different cement volumes to be pumped for the 3-1/4" liner cement job on the PTD request. The 10-401 cover form shows 87 sx (I assume —1.2 yield), the cover letter shows 13.9 bbls of 15.3 ppg cement (I assume to be correct) and the liner program on the following page shows 17.9 bbls of 15.3 ppg cement. I am guessing you want to pump ` 13.9 bbls of 15.3 ppg which is somewhere around 65 sx. Please confirm what you expect to pump. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY 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(s). It 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 Mel Rixse at (907-793-1231 ) or (Melvin.RixsePalaska.eov). TRANSMITTAL LETTER CHECKLIST WELL NAME: (� -T- �% % /:5L / PTD: Zro l2 2 Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: �y� POOL:�is e� Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50 - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69 In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - -� from records, data and logs acquired for well name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT J 078 Program DEV _ _ Well bore seg ❑ PTD#:2181220 CnmDanv BP EXPLORATION (ALAS -KA) INC. _. _ Initial Class/Type _ DEV / PEND GeoArea 890 - _ _ Unit 11650 _- _ On/Off Shore On Annular Disposal ❑ J Administration 17 Nonconven. gas conforms to AS31.05,0300.1.A),(t2.A-D) - - - - - - - NA. _ _ _ __ NA .. 1 Permit fee attached ----------- --- -----. .. No OMT.vol adequate to circulate -on conductor & surf csg . . . . .. . ............ 2 Lease number appropriate. _ _ _ _ _ _ _ _ Yes _ Entire Well lies within ADL0028281.... '3 NA _ Unique well name and number ....... . ........... . . Yes 22 CMT will cover -all known productive horizons _ _ _ _ _ ____ _ _ _ _ _ _ _ _ 4 Well located in defined pool _ _ _ _ _ _ _ _ _ _ _ _ _ Yes PRUDHOE BAY, PRUDHOE OIL POOL - 64015, governed by 00.341 F Casing designs adequate for C, T, B & permafrost . . . . . . . .. . . ......... 5 Well located proper distance from drilling unit. boundary... _ _ Yes _ CO 341. F, Rule 2:. There shall be no restrictions. as to well. spacing. except that. no pay shall be Adequate tankage or reserve pit ___ _ _ _ _ 16 Well located proper distance, from other wells _ _ _ _ ..... _ _ Yes opened in a well closer than 500 feet to the boundary of the affected. area. Planned well conforms to ..... - - If.a re -drill, has. a 10-403 for abandonment been approved . . . . . . . . . . . . 7 Sufficient acreage. available in. drilling unit... _ _ Yes CO 341 F. Rule 2.- - - - - ..... _ _ Adequate wellbore separation proposed _ -- - - - - - - - - - - - - - - - - - - 8 If deviated, is wellbore plat. included _ . .......... . ............ . Yes _ _ _ _ _ ............. If.djverter required, does it meet regulations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _________ 9 Operator only affected party _ _ _ _ _ _ _ _ _ _ _ - - - - - _ Yes 28 Drilling fluid program schematic & equip list.adequate_ _ _ _ _ _ _ 10 Operator has. appropriate bond in force _ _ _ ...... _ Yes 29 Appr Date .11 _ Permit can be issued without conservation order .. ........... . . . . . . . Yes 30 12 Permit can be issued without administrative approval - - - - - - - . - _ _ _ _ _ - Yes SFD 10/12/2018 ' 13 Can permit be approved before 15 -day wait. _ _ _ _ Yes _ 32 14 Well located within area and. strata authorized by, Injection Order # (put 10# in. comments) (For- NA 33 15 All wellswithin 1/4 -mile area.of review identified (For service well only). .... _ _ _ NA 34 16 Pre -produced injector: duration of pre -production less than 3 months (For service well on)y) .. .A 35 18 Conductor stringprovided. . . . . . ................. . . . . . . . . . . . . NA... - - - . - Coiled Tubing. Sidetrack_ .......... _ Engineering 19 Surface casingprotectsall. known USDWs _ _ _ _ _ _ _ _ _ ____ _ _ __ _ _ _ _ _ _ _ _ _ _ __ NA .. .. Coiled Tubing Sidetrack.... 20 OMT.vol adequate to circulate -on conductor & surf csg . . . . .. . ............ . . . . INA _ _ _ _ - Coiled Tubing Sidetrack_ . 21 CMT vol adequate to tie-in long string to surf csg. ...... . . . . . . . . . . . . ........ NA _ Coiled Tubing Sidetrack_ 22 CMT will cover -all known productive horizons _ _ _ _ _ ____ _ _ _ _ _ _ _ _ _ _ ___ Yes 23 Casing designs adequate for C, T, B & permafrost . . . . . . . .. . . ......... . . . . . . . Yes 24 Adequate tankage or reserve pit ___ _ _ _ _ _ _ _ __ Yes _ CDR 2 has been utilized many times 25 If.a re -drill, has. a 10-403 for abandonment been approved . . . . . . . . . . . . ...... Yes _ _ _ Sundry.318-368 approved 126 Adequate wellbore separation proposed _ -- - - - - - - - - - - - - - - - - - - - - - - - - Yes . _ _ _ No major collision risk well identified with clearance_ scan 27 If.djverter required, does it meet regulations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _________ _ _ NA _ _ Coiled Tubing Sidetrack- Appr Date 28 Drilling fluid program schematic & equip list.adequate_ _ _ _ _ _ _ _ _ _ Yes _ - - - - - - - - - -- MGR 10/23/2018 29 BOPEs,_do they meet regulation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _____ _ Yes _ _ 30 BOPS. press rating appropriate; test to (put psig in comments) ......... . .... . _ Yes 31 Choke manifold complies w/API. RP -53 (May 84). _ _ _ _ _ ...... - Yes - - - - - - - - - - - - ------- 32 Work will occur without operation shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ . _ . _ . _ - - - - - - - - - 33 Is presence of H2S gas probable . . . . . . . . . .. . . .................. . . No _ _ _ ... PBU J peck is not considered an H25 Dad.... 34 Mechanical condition of wells within AOR verified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ NA - - .... PBU producer _ 35 Permit can be issued w/o hydrogen. sulfide measures .. . . . . . . . . . ......... _ No. .. _ J -Pad. wells are H2S,bearin H2$ measures are. required.,_ _ _ _ ..... - _ _ _ _ g - _ _ - Geology 36 Datapresentedon potential overpressure zones . . . . ........: . . . . . . . . . . . . . . Yes _ _ Horizontal,. redr[I] development well; will kick off inJvishak Zone.2 and remain within that zone, Appr Date 37 Seismic analysis of shallow gas zones- - - - - - - - - - - ---- - - - - - - _ NA.. .. _ Expected reservoirpressure is 7,0-ppg EMW; will be drilled using 8.4 ppg mud & coiled tubing.. _ SFD 10/12/2018 38 Seabed condition survey.(if off -shore) _ _ .. - - - - - ----- - - - - - - - - _ _ _ _ NA.... _ Should higher.pore.pressures be encountered, BP has immediate access to nearby fluid.mixing facilities.. 39 Contact name/phone for weekly.. progress reports_ [exploratory only] __ _ _ _ _ _ _ _ _ _ _ _ _ _ NA.. Geologic Engineering C Date: ate Date Commissioner: Dommissio er: � i0 on Di 10J24o,r f -b (z4 Ile