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201-153
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251016 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 2-36 50029220140000 190024 9/17/2025 BAKER SPN T40994 END 2-74 50029237850000 224024 9/22/2025 HALLIBURTON PATCH T40995 KU 12-17 50133205770000 208089 9/23/2025 YELLOWJACKET TEMP-CALIPER T40996 KU 24-7RD 50133203520100 205099 9/24/2025 YELLOWJACKET TEMP-CALIPER T40997 M-25 50733203910000 187086 8/31/2025 YELLOWJACKET CALIPER T40998 MPC-22A 50029224890100 195198 10/4/2025 READ CaliperSurvey T40999 MPF-61 50029225820000 195117 9/27/2025 READ CaliperSurvey T41000 MPU H-16 50029232270000 204190 10/6/2025 HALLIBURTON COILFLAG T41001 NIK SI17-SE2 50629235120000 214041 9/23/2025 HALLIBURTON IPROF T41002 NS-19 50029231220000 202207 9/8/2025 HALLIBURTON COILFLAG T41003 NS-19 50029231220000 202207 9/15/2025 HALLIBURTON COILFLAG T41003 ODSN-26 50703206420000 211121 10/7/2025 HALLIBURTON MFC24 T41004 PBU 01-25A 50029208740100 225056 9/13/2025 BAKER MRPM T41005 PBU 01-25A 50029208740100 225056 9/13/2025 HALLIBURTON RBT-COILFLAG T41005 PBU 01-31A 50029216260100 225070 9/22/2025 BAKER MRPM T41006 PBU 01-31A 50029216260100 225070 9/23/2025 HALLIBURTON RBT-COILFLAG T41006 PBU 05-09A 50029202540100 199014 9/18/2025 READ ArcherVIVID T41007 PBU 07-16A 50029208560100 201153 9/20/2025 HALLIBURTON RBT T41008 PBU 07-23C 50029216350300 225043 7/4/2025 BAKER MRPM T41009 PBU 13-24B 50029207390200 224087 9/18/2025 HALLIBURTON RBT T41010 PBU 15-11C 50029206530300 210163 9/6/2025 HALLIBURTON RBT T41011 PBU 15-49C 50029226510300 215129 9/10/2025 HALLIBURTON RBT T41012 PBU H-07B 50029202420200 225064 9/30/2025 HALLIBURTON RBT-COILFLAG T41013 PBU P19 L1 50029220946000 212056 10/3/2025 HALLIBURTON RBT T41014 PBU S-14A 50029208040100 204071 9/25/2025 HALLIBURTON RBT T41015 PBU V-105 50029230970000 202131 9/30/2025 HALLIBURTON RMT3D T41016 Please include current contact information if different from above. PBU 07-16A 50029208560100 201153 9/20/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.20 13:17:06 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 07-16A Pulled Tbg Patches Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-153 50-029-20856-01-00 12368 Conductor Surface Intermediate Liner Liner 8913 79 2457 9819 971 2846 10539 20" 13-3/8" 9-5/8" 7" 3- 1/ 2" x 3- 3/16" x 2-7/8" 8885 31 - 110 30 - 2487 28 - 9847 9533- 10504 9518- 12364 31 - 110 30 - 2485 28 - 8315 8065- 8858 8053- 8913 10515 , 12317 470 2670 4760 7020 13890 10539 , 11595 1490 5380 6870 8160 13450 9898 - 12280 4-1/2" 12.6# / 5-1/2" 17# 13Cr85 / L-80 26 - 9403/9497 - 9582 8356 - 8917 Structural 4-1/2" HES AHC HydroSet, 9283 , 7866 No SSSV 9283 , 9497 7866 , 8037 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907)564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028309 26 - 7962/8037 - 8104 249 0 46023 0 19 0 0 0 1507 0 n/a 13b. Pools active after work:PRUDHOE OIL 5-1/2" Bake SAB, 9497 , 8037 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:26 am, Oct 15, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.10.14 15:41:39 - 08'00' Bo York (1248) RBDMS JSB 101625 J.Lau 11/10/25 ACTIVITYDATE SUMMARY 9/13/2025 *** WELL S/I ON ARRIVAL *** RAN 20' x 1.56" DUMMY GUNS (1.72" SWELL RINGS) TO 9497' SLM (UNABLE TO SKIP BY SPOT, CHANGE UP BHA) SET X CATCHER IN NIP @ 9257' MD PULLED RK-OGLV FROM STA #2 @ 7938' MD *** WSR CONT ON 9/14 *** 9/13/2025 Assist SL with CBL/L&T ***job continued to 09-14-25*** 9/14/2025 Continue standing by for SL 9/14/2025 *** WSR CONT FROM 9/13 *** PULLED RK-LGLV's FROM STA #3 (6517' MD), STA #4 (4950' MD), STA #5 (3264' MD) SET RK-DGLV IN STA #5 @ 3264' MD RAN 4-1/2" BRUSH, KJ, KJ, 2.13" G-RING & RATTLED MANDRELS TO CATCHER @ 9257' MD PULLED 4-1/2" X-CATCHER FROM 9257' MD (recovered st# 4) SET 4-1/2" X-CATCHER IN X-NIP @ 9257' MD SET RK-DGLV'S IN STA # 4, AND STA # 3 *** WSR CONT ON 9/14 *** 9/15/2025 T/I/O=2355/2350 Assist SL with L&T Loaded IA with 510 bbls 110* crude Pumped 188 bbls crude down tbg to load. Pump 2.4 bbls crude to MIT T 2754 psi. TP lost 173 psi 1st 15 min & 85 psi 2nd 15 min. Re-pressured with .2 bbl crude to 2766 psi. TP lost 83 psi 1st 15 min, 59 psi 2nd 15 min & 53 psi 3rd 15 min. IAP slowly increased during both tests from 345 psi to 427 psi. Pump 6.7 bbls crude down TBG & IA to 2756/2743 psi. CMIT TxIA lost 20/56 psi 1st 15 min & 12/25 psi 2nd 15 min. Pressured tbg to 2750 TBG lost 317 psi in 22 min. Pumped xx bbls crude down tbg while SL ran a D&D ***job continued to 09-16-25*** 9/15/2025 *** WSR CONT FROM 9/14 *** PULL X CATCHER FROM NIPPLE @ 9257' MD LOAD IA w/ 510 bbls OF CRUDE SET X CATCHER IN NIPPLE @ 9257' MD SET RK-DGLV IN STA #2 @ 7938' MD PULLED 4-1/2" X-CATCHER FROM X-NIP @ 9257' MD LRS LOADED TUBING w/ 188 BBLS CRUDE SET 4-1/2" PX PLUG BODY IN X-NIP @ 9320' MD SET P-PRONG IN PX PLUG BODY @ 9320' MD CONDUCTED FAILING MIT-T PASSED A CMIT-TxIA CONDUCTED FAILING MIT-T RAN 4-1/2" D&D (see log for details) *** WSR CONT ON 9/16 *** 9/16/2025 ***Job Continue from 9-15-25*** SL to continue to tun D&D hole finder. Pump 2.1 bbls crude to attempt MIT T. TP lost 221 psi in 15 min & IAP gained 51 psi in 15 min Re-pressured with 0.2 bbl after 20 mins. ( ~ 0.42 GPM LLR ) Pumped 2 bbls crude down tbg to attempt MIT T to 2758 psi. TP lost 134 psi 1st 15 min & 43 psi 2nd 15 min ( IAP gained 10 psi in 30 mins ) Passing Test. Bled back 2 bbls FWHPs=442/465 Daily Report of Well Operations PBU 07-16A Daily Report of Well Operations PBU 07-16A 9/16/2025 *** WSR CONT FROM 9/15 *** MADE D & D HOLEFINDER RUN, POSSIBLE LEAK @ STA #4 (see log for details) ATTEMPTED MIT-T's (FAILED, see LRS log for details) SET 4-1/2" KEYLESS X-CATCHER ON PRONG @ 9320' MD PULLED RK-DGLV FROM STA #4 @ 4950' MD (Upper pieces of packing torn on each set) SET RK-DGLV IN STA #4 @ 4950' MD LRS PERFORMED PASSING MIT-T (See Lrs log for details) PULLED PRONG FROM PX PLUG BODY @ 9320' MD PULLED PX FROM NIPPLE @ 9320' MD, GET HUNG UP IN STA #4, STRIP PLUG BODY OFF OF GS *** WSR CONT ON 9/17 *** 9/17/2025 *** WSR CONT FROM 9/16 *** PULLED PLUG BODY FROM STA # 4 @ 4950' MD TAGGED TOP OF STRADDLE PATCH @ 9509' MD/9607' SLM PULLED 45 FLOGARD PACKER/SNAP LATCH SEAL ASSY FROM 9509' MD RAN KJ, 1-1/2" BOWSPRING CENT, 4-1/2" BRUSH, 3.75" WIRE GRAB (No Recovery) RAN KJ, 1-1/2" BOWSPRING CENT, STIFF 3-1/2" BRUSH, 2.62" WIRE GRAB (Recovered 3/4 of 2 separate elements) RAN 1.50" BOWSPRING CENT, 1.50" BOWSPRING CENT, 2.69" MAGNET TO 9519' SLM, NO RECOVERY PULLED SNAP LATCH RECEPTACLE/35 FLOGARD ASSY FROM 9509' MD, REMAINDER OF 45 FLOGARD ELEMENTS RECOVERED *** WSR CONT ON 9/18 *** 9/18/2025 T/I/O = 2500/160/0+. Temp = SI. Tbg FL (SL request). ALP = 930 psi, AL SI @ CV. OA cemented to surface. T FL @ 9410' (143 bbls). SL in control of well upon departure. 9/18/2025 *** WSR CONT FROM 9/17 *** ** CONDUCTED WELL CONTROL DRILL ** RAN 1.50 BOWSPRING, 1.50 BOWSPRING, 2.69" MAGNET TO TOP OF 3-1/2" NS PATCH @ 9891' MD *1/2 OF MISSING SLIP RECOVERED* RAN 1.50 BOWSPRING, 1.50 BOWSPRING, 2.69" MAGNET TO TOP OF NS PATCH *SMALL PIECE OF METAL RECOVERED* PULLED NS UPPER STRADDLE PACKER ASSY FROM 9891' MD (Fully Intact) PULLED NS SNAP LATCH RECEPTACLE/SPACER PIPE/SNAP LATCH ASSY @ 9903' SLM PULLED NS LOWER STRADDLE PACKER ASSY FROM 9938' SLM (Fully Intact) RAN 1.50" BOWSPRING, 1.50" BOWSPRING, 2.69" MAGNET. S/D @ 10545' SLM (RECOVERED COIL SHAVINGS) RAN 10' x 2.25" PUMP BAILER TO 10543' SLM, RECOVERED HANDFUL OF SMALL CIBP BITS, AND 3 BRASS NUBBINS *** WSR CONT ON 9/19 *** 9/19/2025 T/I/O = 2500/200 (TFS Unit 1 Assist S-Line w/ Load) Pumped 171 bbls Crude down TBG for Load Pollard SL in control of well upon TFS departure FWHPS = 400/50 Daily Report of Well Operations PBU 07-16A 9/19/2025 *** WSR CONT FROM 9/18 *** RAN KJ, 1.50" BOWSPRING, 1.50" BOWSPRING, 2.49 TAPERED LIB, INCONCLUSIVE IMPRESSION RAN KJ, 1.50" BOWSPRING, 1.50" BOWSPRING, 2.50 LIB, INCONCLUSIVE IMPRESSION RAN 2.18" CENT, 22' x 1.56" DUMMY GUNS (1.72" SWELL RINGS), 1.50" BOWSPRING CENT, BULLNOSE TO 10545' SLM (No Issues) T-BIRD LOADED TUBING w/ 170 BBLS CRUDE RAN HALLIBURTON MCBL FROM 10525' SLM TO 9000' SLM **BAD DATA** *** WSR CONT ON 9/20 *** 9/20/2025 (TFS U4 Assist S-line) Pumped 2 bbls 60/40 followed by 188 bbls Crude to Load TBG. Further Pumped 16 bbls Crude minimum Rate down TBG for S-Line Log. S- Line in Control of well upon departure. FWHP=350/200/0 9/20/2025 *** WSR CONT FROM 9/19 *** T-BIRD LOADED TUBING w/ 190 BBLS CRUDE RAN HES CBL FROM 10525' TO 9000' SLM w/ T-BIRD MAINTAINING MINIMUM RATE DURING LOGGING (Good Data) ***WELL LEFT S/I ON DEPARTURE, NOTIFY DSO OF WELL STATUS*** Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 01/12/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 4Q 2022. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through the end of 4Q 2022. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Engineer Hilcorp North Slope, LLC By Samantha Carlisle at 3:53 pm, Jan 12, 2023 Digitally signed by Oliver Sternicki (4525) DN: cn=Oliver Sternicki (4525), ou=Users Date: 2023.01.12 14:52:49 -09'00' Oliver Sternicki (4525) 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 07-16A Patch Deployment Sleeve Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-153 50-029-20856-01-00 12368 Conductor Surface Intermediate Liner Liner 8913 79 2457 9819 971 2846 10539 20" 13-3/8" 9-5/8" 7" 3- 1/ 2" x 3- 3/16" x 2-7/8" 8885 31 - 110 30 - 2487 28 - 9847 9533- 10504 9518- 12364 31 - 110 30 - 2485 28 - 8315 8065- 8858 8053- 8913 10515 , 12317 470 2670 4760 7020 13890 10539 , 11595 1490 5380 6870 8160 13450 9898 - 12280 4-1/2" 12.6# / 5-1/2" 17# 13Cr85 / L-80 26 - 9403 / 9497 - 9582 8356 - 8917 Structural 4-1/2" HES AHC HydroSet, 9283 , 7866 No SSSV 9283 , 9497 7866 , 8037 Bo York Operations Manager Jerry Lau Jerry.Lau@hilcorp.com (907)564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028309 26 - 7962 / 8037 - 295 243 33438 38747 25 6 0 0 1013 1478 n/a 13b. Pools active after work:PRUDHOE OIL 5-1/2" Baker SAB, 9497 , 8037 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 8104 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2022.12.11 16:07:45 -09'00' RBDMS JSB 121322 WCB 11-26-2024 DSR-12/13/22 ACTIVITYDATE SUMMARY 11/25/2022 ***WELL S/I ON ARRIVAL*** (profile modification) RAN 2.75" CENT, 3-1/2" BRUSH & 2.83" G. RING TO PATCH AT 9,891' MD RAN 3.80" G. RING, 4-1/2" BRUSH & 3.25" LIB TO DEPLOYMENT SLEEVE AT 9,518' MD (impression of deployment sleeve) ***CONT ON 11/26/22 WSR*** 11/26/2022 ***CONT FROM 11/25/22 WSR*** (profile modification) SET BAKER 35 KB FLOGARD PKR IN DEPLOYMENT SLEEVE AT 9,518' MD SET BAKER 45 KB FLOGARD PKR W/ SNAP LATCH ON 35 KB PKR AT 9,509' MD ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU 07-16A () SET BAKER 35 KB FLOGARD PKR IN DEPLOYMENT SLEEVE AT 9,518' MD SET BAKER 45 KB FLOGARD PKR W / SNAP LATCH ON 35 KB PKR AT 9,509' MD By Anne Prysunka at 4:14 pm, Aug 10, 2022 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 07-16A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-153 50-029-20856-01-00 12368 Conductor Surface Intermediate Liner Liner 8913 79 2457 9819 971 2846 10355 20" 13-3/8" 9-5/8" 7" 3- 1/ 2" x 3- 3/16" x 2-7/8" 31 - 110 30 - 2487 28 - 9847 9533- 10504 9518- 12364 31 - 110 30 - 2485 28 - 8315 8065- 8858 8053- 8913 12317 470 2670 4760 7020 13890 10355 , 10539 , 11595 1490 5380 6870 8160 13450 9898 - 12280 4-1/2" 12.6# / 5-1/2" 17# 13Cr85 / L-80 26 - 9403 / 9497 - 9582 8356 - 8917 Structural 9281 , 9497 9281 , 9497 7866 , 8037 Bo York Operations Manager Ryan Thompson Ryan.Thompson@hilcorp.com (907)564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final 13.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028309 No SSSV 7866 , 8037 273 186 46860 32110 21 4 0 0 1358 1084 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 4-1/2" HES AHC HydroSet & 5-1/2" Baker SAB 26 - 7962 / 8037 - 8104 8733 n/a By Samantha Carlisle at 10:08 am, Oct 12, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.10.11 20:01:03 -08'00' Bo York SFD 10/12/2021MGR15OCT2021 RBDMS HEW 10/12/2021 DSR-10/12/21 ACTIVITYDATE SUMMARY 9/19/2021 ***WELL SHUTIN UPON ARRIVAL*** RUN:1 RIH W/ 2.80" CENTRALIZER DRIFT. UNABLE TO GET PAST 9501' (BAKER PACKER) RUN:2 RIH W/ 2.6" ROLLER STANDOFFS AND 2.80" CENTRALIZER PLUG DRIFT. UNABLE TO GET PAST 9501' (BAKER PACKER) RUN:3 RIH W/ 2.6" ROLLER STANDOFFS AND 2.80" CENTRALIZER PLUG DRIFT W / 1.5" BOWSPRING CENTRALIZER HANGING BELOW. SUCCESSFUL DRIFT TO 10400'. ***LAY DOWN FOR THE NIGHT*** 9/20/2021 ***JOB CONTINUED FROM 19-SEP-2021*** SET 3-1/2" ALPHA CIBP AT 10,355' MD. LOG CORRELATED TO TO SLB MCBL DATED 20-APR-2009. ***JOB COMPLETE ON 20-SEP-2021*** Daily Report of Well Operations PBU 07-16A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS � uV LD 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Op ra s t ry ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing 11C ( am ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number 201-153 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6API Number: 50-029-20856-01-00 7 Property Designation (Lease Number): ADL 028309 8. Well Name and Number: PBU 07.16A 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 12368 feet Plugs measured 10539, 11595 feet true vertical 8913 feet Junk measured 9874,12317 feet Effective Depth: measured 10539 feet Packer measured 9281, 9497 feet true vertical 8885 feet Packer true vertical 7866, 8037 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 31 -110 31 -110 1490 470 Surface 2457 13-3/8" 30-2487 30-2485 5380 2670 Intermediate 9819 9-5/8" 28-9847 28-8315 6870 4760 Liner 971 7" 9533-10504 8065-8858 8160 7020 Liner 2846 3-1/2" x 3-3/16" x 2-7/8" 9518-12364 8053-8913 13450 13890 Perforation Depth: Measured depth: 9898-12280 feet True vertical depth: 8356-8917 feet Tubing (size, grade, measured and true vertical depth) 4-1/21T12.6# 13Cr85 26-9403 26-7962 5-1/2" 17# x 4-1/2" 12.6# L-80 9497-9582 8037-8104 4-1/2" HES AHC HydroSet Packer 9281 7866 Packers and SSSV (type, measured and 5-1/2" Baker SAB Packer 9497 8037 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 56 6400 0 1419 987 Subsequent to operation: Shut -In 1378 0 14. Attachments: (required per 20 MC 25.070.25.071. a 25,283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Of 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Thompson, Ryan Contact Name: Thompson, Ryan Authonzed Title: Petroleum Engineer Contact Email: RYAN.THOMPSON@bp.com Authorized Signature: fi�- Date: 17– i! Z/ / (� Contact Phone: +1 907 564 4535 Form 10-404 Revised 04/2017 /t'3 j11 „ yQ RBDMS 1L�*-'DEC 13 2019 Submit Original Only ****WELL S/I UPON ARRIVAL**** (Perforating) DRIFTED W/ 2.85" CENT, 3' x 1-7/8", 2.99" CENT, S/D IN DEP SLV @ 9,529' SLM (Unable to work past, see log) DRIFTED W/ 2.85" CENT, 33' x 2-1/2" DMY GUNS, 2.85" CENT, S/D ON PKR @ 9,492' SLM / 9,497' MD (Unable to work past) 11/15/2019 ****CONT JOB ON 11/16/19**** ****CONT. JOB FROM 11/15/19**** (Perforating) DRIFTED W/ 2.85" CENT, 33'x 2-1/2" DMY GUNS, 2.85" CENT, B.NOSE, TAG XO @ 10,437' SLM / 10,435' MD (No issues) 11/16/2019 ****WELL LEFT S/I & PAD -OP NOTIFIED OF STATUS UPON DEPARTURE**** ***WELL SHUT IN ON ARRIVAL*** SPOT IN EQUIPMENT, LOAD WELL, PREP FOR PERF RUN 11/20/2019 ***JOB CONTINUES ON 21NOV19 WSR*** ***CONTINUED FROM 20NOV19 WSR*** PERFORATE 9,898-9,930' ELMD WITH 2.75" GEODYNAMICS PERF GUNS, 6 SPF, 60 DEG PHASE. PERF GUNS AND TOOLSTRING LEFT IN HOLE. TOP OF FISH @ 9874'. ***JOB COMPLETE*** NOTIFY DSO 11/21/2019 ***FISH LEFT IN HOLE 1-3/8" FN, DAL = 57.3', WT = 629#*** TREE= 4-1/16" CNV 7 I9-S/B-(SG,47#,L-80VAMTOP,11)=8.681" 2126' 9-5/8" BOWEN CSG PATCH, D=9.060' 2126' - 2130' 13-3/8" CSG, 72#, L-80 BT&C, D = 12.347" 248T Minimum ID = 2.372" @ 10564' 3-3116" X 2-718" LNR XO TBG, 12.6#, 13CR-86 VAMTOP, 9406' bpf, D = 3.958" 17#, L-80, .0232 bpf, D = 4.892" 961W TOP OF 3-12" LNR PERFORATION SUMMARY 4-1/2" TBGPC, 12.6#, L-80 BTRS, — 9581' �- Note: Refer to Production DB for historical pe data .0152 bpf, D = 3.958" SPF 95/8" CSG, 47#, L W BTRS,ID = 8.681" OprVSqz FISH: FIRED PERF GUNS & TOOLSTRING (1121/19) 9674' 3-12" LNR, 8.81#, L-80..008 f, ID = 2.992" 10435- 17- WHIPSTOCK w / RA TAG @ 10506' (XX/XX/01) 10486' 7" LNR, 29#, L-80 BTRS, .0371 bpf, D = 6.184" 1107 PERFORATION SUMMARY REF LOG: MCNUGR/CCL ON 09/12/01 ANGLE AT TOP PERF: 36'@ 9898' Note: Refer to Production DB for historical pe data Sf SPF I INTERVAL OprVSqz SHOT SOZ 2-3/4" 6 9898-9930 O 1121/19 RK 2-12' 6 10460 -10470 0 0822/19 40 2" 6 10700 -10750 C 05/02/09 3 2" 6 10950-11250 C 01/17/03 RK 2" 4 11360-11560 C 09/12/01 44 2" 4 11610 -11960 C 09/12/01 1 2' 4 12030-12280 C 09/12/01 RK 07-16A CHFErY ROME TBG — MAX DDGLEGL435-@110523'i""'SEE PG'S 2 & 3 FOR PREVIOUS WELLBORES------------ 2062' 9-5/8" HES ES CEMENTER 2105' 9-5/8' BOT IXTERPIAL CSG PKR 2212' 4-12" OTIS X NIP, D = 3.813" GAS LFTMANDM S ST M) ND DEV TYPE VLV LATCH PORT DATE 5 3265 3251 17 RVG DONE RK 16 04/18/14 4 4950 4640 40 MNC DONE RC 16 04/18/14 3 6517 5840 40 MNG DONE RK 16 04/18/14 2 7938 6913 44 MNG SO RK 24 04/18/14 1 9137 7754 39 MNG DNIY RK 0 04/08/14 9257"—J4-12" OTIS X NIP, D = 3.813- 9283' 9-5/8" X 4-1/2" HES AHC HY D WK D = 3 9320' 4-12" OTIS X NIP, D = 3.813" 9388' 4-12" OTIS X NIP, D = 3.813' � 4-1/2" VYLEG, D = 3.958" 9497'9-5B" X 5-12" BKR SAB PKR, ID = 3.875" 9509' S-1/2"X4-1/2"XO,D=3.958" 9618' 3.70' BKR DEPLOY SLV. D = 3.00" —� 9S17O- �y4-12" CAM DB -6 NP, D= 3.812' 9562' 412" WLEG, D=3.958" 9572'ELMD TT LOG (XX/XX/XX) 10436'3-12" x 3.1/16" LNR XO, D = 2.80' FLOUT WIDOW (07-16A) 10504' - 10513' 10539' ELM 3-3/16" BKR CBP (0822119) 10564' 3-3116' X 2 -7M -XO, D =2.372" F-11696--l—F2 I" WFO CBP(07/08/17) i" LNR, 6.2#, L-80 TC2, bpf, D = 2.80" PBTD L 2-7/8" LINT, 6=16# .16#, L-80 STL, 10563' .0058 bpf, D = 2.37" DATE REV BY I COMMENTS DATE REV BY COMMENTS 12M5R2 PKR 176 INITIAL COMPLETION 0421/14 CJW PJC GLV ClO (041108114) 09/13101 ? CTD SDETRACK 05A7/14 1 RCT/PJC I PULL EVO TREVE PLUG 04/09M4 D-14 RWO 11 05/13/141 PJC SFTYNOTE-MAX DOGLEG 04/10/14 PJC DRLGHO CORRECTIONS 07/10/17 1 JTM/JMD SETCBP(07/08/17) 04/17/14 JB/PJC FNAL ODE APPROVAL 1 0827/19 EPD/JMD ADPERFS&CBP 0822/19 04112/14 CJN/ PJC GLV C/O 1125/19 BTN/JMD ADPERFS &FISH (1121/19) FRM FISH - MILLED CBP (05/02/09) PRUDHOE BAY UNIT WELL: 07-16A PERMIT No: 2011530 API No: 50-029-20856-01 T7IN. R14E, 1127' SNL & 534 BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPFRATinNIS SEP 19 gnm 1. Operations Performed Summary: Size: MD: Abandon ❑ Plug Perforations M Fracture Stimulate ❑ Pull Tubing ❑ Operations st'"1E�r'LJ Suspend ❑ Perforate 4 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set CIBP p 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 201-153 3. Address: P.O. Box 196512 Anchorage, 12317 feet AK 99519-6612 Stratigraphic ❑ Service 11 1 6, API Number: 50-029-20856-01-00 7. Property Designation (Lease Number): ADL 028309 8. Well Name and Number: PBU 07-16A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 4760 Liner 971 measured 9281 10. Field/Pools: true vertical 8885 feet Packer PRUDHOE BAY, PRUDHOE OIL 7866 11. Present Well Condition Summary: Size: MD: TVD: Burst: Collapse: Structural Total Depth: measured 12368 feet Plugs measured 10539, 11595 Leet 20" true vertical 8913 feet Junk measured 12317 feet Effective Depth: measured 10539 feet Packer 9819 9-5/8" 28-9847 28-8315 6870 4760 Liner 971 measured 9281 feet 8160 true vertical 8885 feet Packer true vertical 7866 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural 20516 4-1/2' HES AHC HydroSet Packer 9281 7866 Packers and SSSV (type, measured and 5-1/2" Baker SAB Packer Conductor 79 20" 31 -110 31-110 1490 470 Surface 2457 13-3/8" 30-2487 30-2485 5380 2670 Intermediate 9819 9-5/8" 28-9847 28-8315 6870 4760 Liner 971 7' 9533-10504 8065 - 8858 8160 7020 Liner 2846 3-1/2" x 3-3/16" x 2-7/8" 9518-12364 8053-8913 13450 13890 Perforation Depth: Measured depth: 10460 - 12280 feet True vertical depth: 8821 -8917 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr85 26-9403 26-7962 Casing Pressure 5-1/2" 17# x 4-1/2" 12.6# L-80 9497-9582 8037-8104 20516 4-1/2' HES AHC HydroSet Packer 9281 7866 Packers and SSSV (type, measured and 5-1/2" Baker SAB Packer 9497 0 true vertical depth) 915 14.Attachments. f.1.i®dper2a Mc25.07,.zsml,s2s.zea) 8037 Daily Report of Well Operations p No SSSV Installed Copies of Logs and Surveys Run. ❑ 16. Well Status after work: Oil Rl Gas ❑ WDSPL ❑ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Authorized Name: Thompson, Ryan Contact Name: Thompson, Ryan Authorized Title: Petroleum Engineer Contact Email: RYAN.THOMPSON(4bp.com LAuthorized Signature /1y/ Dale 1 /' 1 /' 1 Contact Phone 1 907 564 4535 Forth 10-404 Revised 04/2077 3BMAPSEP 19 2019 Submit Original Only Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 236 20516 50 0 938 Subsequent to operation: 1 0 0 0 915 14.Attachments. f.1.i®dper2a Mc25.07,.zsml,s2s.zea) 15. Well Class a8erwork: Daily Report of Well Operations p Exploratory ❑ Development ® Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run. ❑ 16. Well Status after work: Oil Rl Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge, Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Thompson, Ryan Contact Name: Thompson, Ryan Authorized Title: Petroleum Engineer Contact Email: RYAN.THOMPSON(4bp.com LAuthorized Signature /1y/ Dale 1 /' 1 /' 1 Contact Phone 1 907 564 4535 Forth 10-404 Revised 04/2077 3BMAPSEP 19 2019 Submit Original Only Daily Report of Well Operations PBU 07-16A 4r TIVITVnATF ***WELL FLOWING ON ARRIVAL*** (pre a -line) DRIFTED TO DEVIATION AT 10,648' SLM W/2.25" CENT & S.BAILER (Difficulty passing PKR at 9497'& dep sleeve at 9518') DRIFTED TO DEVIATION AT 10,502' SLM W/ 11' x 2-1/2" DUMMY GUN W/ 2.78" SWELL RINGS AND BULLNOSE (passed PKR easily) 8/5/2019 ***WELL LEFT SHUT IN AND DSO NOTIFIED UPON DEPARTURE*** ***WELL SHUT IN ON ARRIVAL***(plug and ad pert) COULD NOT PASS 9497' WITH 2-7/8" CIBP. SET 3-3/16" BAKER HUGHES CAST IRON BRIDGE PLUG MID -ELEMENT AT 10540'. TOP OF CIBP 10,539'. CORRELATED TO MEMORY CORRELATION LOG 1 -MAY -2009- 8/21/2019 ***JOB IN PROGRESS, CONT ON 8/22/2019 WSR*** ***CONT FROM 8/22/2019 WSR*** PERFORATE 10,460'-10,470' WITH 2.5", 6 SPF, 60 DEGREE PHASE MILLENIUM HMX CHARGES. CORRELATED TO MEMORY CORRELATION LOG 1 -MAY -2009 8/22/2019 ***JOB COMPLETE, WELL TURNED OVER TO DSO*** TRIP= 4-1/16" CNV -5/6-GSG, 411P,L-BOVAM TOP,D=8.681" 2126' /B" BOWEN CSG PATCH, 0-:_9 060- 2126" - 2130' 13318" CSG, 72#, L-80 BT&C, D =12.347T -{ 2487' Minimum ID = 2.372" @ 10564' 3-3H6" X 2-7/8" LNR XO 4-1/2" TBG, 12.6#, 13CR-85 \ .0152 bpf, D = 3.958" :PC, 17#. L-80..0232 bof. D LNR 11/2' TBG-7'1 BC PC, 12-7 L-80 BTRS, - 9581' i 52 bpf, D=3.958" 9-5/8" CSG, 47#, L-80 BTRS, D = 8.681" 9847' 3-12' LNR, 8.81#, L-80, .0087 f, ID = 2.992'10435' - WHIPSTOCK w / RA TAG @ 10506' (XX/XX I01) 10496' 7" LNR, 29#, L-80 BTRS, .0371 bpf, D = 6.184" F 10700' PERFORATION SUMMARY REF LOG: MCNL/GR/CCL ON 09/12/01 ANGLE AT TOP PERF: 32' @ 10460' Nope: Refer to Production DB for historical Derfdata SIZE SPF INTERVAL OprVSqz SHOT SOZ 2-12' 6 10460 -10470 O 0822/19 RK 2' 6 10700 -10750 C 05402/09 40 2" 6 10950 -11250 C 01/17/03 04/18/14 2" 4 11360-11560 C 09/12/01 DONE 2" 4 11610-11960 C 09/12/01 7938 6913 2" 4 12030-12280 C 09/12/01 24 07-16A ND ND DEV TYPE VLV LATCH PORT DATE FSAFEIFY HMETBG—MAXDOGLEGL435'@110523'isSEE 3265 3251 17 RAI US 2 A 3 FOR PREVIOUS WELLBORES 210�� 9-5/8' BOT IXIERNP.L CSG PKR 2212' 4-12" OTIS X NIP, D = 3.613" GAS KT MAWC ST ND ND DEV TYPE VLV LATCH PORT DATE 5 3265 3251 17 RAI DONE RK 16 04/18/14 4 4950 4640 40 NMC.' DOME RK 16 04/18/14 3 6517 5840 40 NMG DONE RK 16 04/18/14 2 7938 6913 44 M G SO RK 24 04/18/14 1 9137 7754 39 MNG DIW RK 0 04/08/14 3.813" 9283' --I9-5/8' X 4-1/2' FFS AHC HYC 9320' 4-12' OTB XNIP, D = 3.813" 938W4-112. OTIS X NIP. D = 3.813" 1 V40 -(9-5/8-X5-1/2'BKR SAB PKR, ID=3.E 9509' S-1/2" X 4-12" X0,10= 3.958" 9618' 3.70' BKR DEELOV SLV, D = 3.00' 9633' 9-5/8" X 7" LTP, HGR w / TEBACK SLS 9570' 4-12' CAM DB -8 NP, D = 3.812" 9582' 4-12" WLEG, D = 3.958" 9572'ELMD TT LOG (XX/XX/XX) 1043fi' 3-12' z 3-3/16' LNR XO, D = 2.80' MLLOUT WINDOW (07-16A) 10504' - 10513' 0539' ELM 3-0/16' BKR CBP (0822/19) 10564' 33/16' X 2-7/8'X0. D = 2.372' —AMFSTO 2-7/8" LNR, 6.11 6#, L-80 STL, 33/16" LNR 6.2#, L-80 TC2, 10563' .0058 bpf, D = 2.37" .0076 bpf, D= 2.80' DATE I REV BY COMMENTS DATE REV BY COMMENTS 12105/82 PKR 176 1 INITIAL COMPLETION 0421/14 CJ W PJC GLV C/O (04/108/14) 09/13101 ? CTD SIDETRACK 05107/14 RCT/PJC PULL EVO TREVE PLUG 04109114 0-14 RWO 05/13/14 PJC SFTYNOTE-MAX DOGLEG 04/10/14 PJC DRLG HO CORRECTIONS 07/10/17 J7M/JMD SETCBP(07/08/17) 04/17/14 JB/PJC FINAL ODE APPROVAL 0827119 EPD/JMD ADPERFS&CBP 0822/19 04/12/14 CJW PJC GLV C/O PRUDHOE BAYUNIT WELL: 07-16A PERMIT No: 2011530 API No: 50-029-20856-01 T11 N, RUE. 1127' SNL & 534 BP Exploration (Alaska) STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations RI Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:5j CI OF au 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 201-153 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20856-01-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-16A 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: R EC E I V E Total Depth: measured 12368 feet Plugs measured 11595 feet true vertical 8913 feet Junk measured 12317 feet AUG 17 2.017 Effective Depth: measured 11595 feet Packer measured See Attachment feet true vertical 8951 feet Packer true vertical See Attachment feet AOGGC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"91.5#H-40 30-109 30-109 1490 470 Surface 1 13-3/8"72#L-80 29-29 29-29 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10700-10725 feet 10725-10750 feet 10950-11250 feet 11360-11560 feet 11610-11961 feet 12030-12280 feet True vertical depth: 8942-8944 feet feet 8944-8945 feet 8948-8950 feet 8949-8952 feet 8950-8929 feet 8926-8917 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED NOV 0 72017, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 305 27024 88 879 901 Subsequent to operation: 125 34 95 940 941 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Ed Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil III Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Vohra,Prachi Contact Name: Vohra,Prachi Authorized Title: Production Engr Contact Email: Prachi.Vohra©bp.com Authorized Signature: ae)14 Date: gJ. t1. Contact Phone: +19075644677 Form 10-404 Revised 04/2017 Kn.- 10/,&,/1 RBDMS t� AUG 2 3 2017 OriginalOnly Ai4 ' Submit • • RECEIVED AUG 172017 AOGCC Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary August 17, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug for Well 07-16A, PTD # 201-153. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 1.96612 Anchorage,AK 99519-6612 • • Packers and SSV's Attachment PBU 07-16A SW Name Type MD TVD Depscription 07-16A PACKER 2103.05 2102.93 9-5/8" BOT External CSG PKR 07-16A TBG PACKER 9280.35 7865.71 4-1/2" HES AHC HydroSet Packer 07-16A TBG PACKER 9497.48 8037.02 5-1/2" Baker SAB Packer • S d R• O. � MCO N Mco �tMO 75- CO 0 _ 1.0 CCOO r- C) • 0 M0 0 0 O M 0 0 M0 m• , � 000 co - Mr- co CO LO CO CO OO M N CO nt CA O N P O tO O) P CO O � NPMN 000OO) 0) OP N CO 00 00 CO CO r— CO CO Q1 1 1 1 1 1 1 1 1 1 I I� d CO 00 N- CO OOOONCOCOCACACOM � M N N P O O N. CON O O N CO OO OO W cow P CO t} N N M O O O L.° M M O) P P P P 0 m4 ) 2 1 1 1 1 1 1 1 1 1 1 1 a co P I� O N M N- 0) M N N N V CO = O N O CA CA O) • M_ m lO I— 0. O O OO CO O 0 W M M CO O CO CO M M CO Q� I J J u OO 4# 4 P J % N N Lo s. h- CO u CO N- CO ' N • Cl) • P - _ CO O CO N _ V b M O ti N M t 5 01 M O N O CON- MCD N M C I� P P N. P t' N CO M P d N I� OOP PCA WW ce Q QOWW= UHUww 000 Z ZUa wcoo Z w W W W W W W m m m Q n t izZ Z Z Z m p o O (/) .. M =1 =1 =11- 1- 1- • • c L: N 0) O .0 o 0 = 7 ea `ert L N a Q J O O 0 p U ° U N m O 0. U N (moo ioU c 73 T O �. _ N 0! c O 7 �. co in • N - OL a) 3 O m � U N O 07:510 CO Oo 0m E c °o �`-`v CD U V ) J � - a) = C � = mf/) in 0 ON0a3c0 a0 O Ee N N C 0- c d o ° p • ° U • np mint° ° mob S2 Z CV USN dV CL0 d0 O N J � N Eg m �' CA 1- lo U D U m O >- Q Co M a) in p m a) - co m I1+ cc 5 a) C� - Q Q N L co NE Q= ;:, c.i 0 r= <RI a. 0 Na) m5cooa) c0C = a E CD g N .V �C Q +. O F- O O �O Ll N C N Q. a) 0 Q C m -O .a CO � 20 * N N ~ O mQ a) 06 U a) C L ~ •� 0- w M al N N 0 0 O O O a) U a 0 O O N J 0 L `O a) L _• L_ O = - 1= in �[ c c in C a _- Q-O t' m *, Q'•p N N N U = N C '� i s c Q. -..< -I * aN a) p E p _ * 0_ p0- � Q p 0) O= ;."-_ -6-1 ,4t cp > Q O m O • _U O m Qo_ cc 2 co Fn N Ti.73 r- J O > U L N `-Ce a _N p O V a) N-Ce = p °03 ..... 7 Co E p O m * m m ZN = UMUmmYcy - N - a)N t E - UO) c OL = N E 0 = 0 .4? 3 = inw - 0_ 2 a) O mCnco@ Ln - � -Iv c C c v 3 No -°• v m m e = � '° � aco o m o wI- wtte _0 # = c Oa N a .Q C * 3 c, Q w0Ci- p � oE NO u) . CF- i UF- 00C = = rnUF- O = m . U o * 0 * Ua. � � rn� c * * U 0 0. 0. * 0 in u) w F- O O O 0 (4 CV 0) I- N N N N m N- O N 5 CO up r- �. M N. N. N. 0 Q TREE= 4-1/16'CNV • D= 0 7-1 6A , S NOTeS: '''' WELL ANGLE>70°@ 10616' C ME TBG***MAX DOGLEG:43.5*@ 10523'""-*SEE 11/VELLFM CNV 'ACTUA TOR= BAKER C i OKJ3 Ely= 47 .. 1 i PG'S 2&3 FOR PREVIOUS WELLBORES 58.'. * BF. ELEV= NA; • i. tO . 2082' H 9-5/8'1-ES ES CEMBV1-ER KOP= 30,30,,1-"CONDUCTOR ---.i ? i i„; - 1 Max A ng$e---- 97'@ 11786 .--i. .----- 2105' I-I 9-5/8"BOT EXTERNAL CSG PKR Datum NO= 10504' 2212' H-14 1/2"0118 X NP,ID=3.813" i Datum ND= 8800'SS GAS LFT MANDRELS 19-5/8'CSG.47#,L-80 VAM TORID=8681" 1---i 2126' - —, ST'. AID ND, DEV I TYPE VLV .'LATCH]PORT DATE 1 1 I i i 9-5/8"soineq CSG PATO-4.13=9 060' H 2126' -2130' i ..1,I 5 3265'32511 17 ii/IMG i IDOME i RK I 16 04/18114i 4 ;4950'4640; 40 1144G'I DOW.I RK 1 16 i 04/18/141 13-3/8"CSG,724, L-80 BT&C,ID= 12.347' !--1 2487' 1 il , 3 6517;5840' 40 WAG I DOMERK 16 04/18/141 i 2 !7938 6913: 44 I MIMG SO i RK 1 24 104/18/14 i 1 i 9137 7754; 39 !MMG! MY I RK i 0 04/08/1411 II Minimum 10 = 2.372" @ 10564' 9257' --i 4-lir OTIS X NIP,ID=3 813" 13-3/16" X 2-718" LNR XO I i r 9283' iH9-5/8 X 4-1/2"HES AHC HYD PKR,ID=3.903" I 9320' H4-1/2"0-11S X NIP,ID=3.813" I 9388' i H4-1/2"OTIS X NP,D=3.813" 14-1/2"TBG, 12 64,13CR-8S VAM TOP, 17-9406' f 9406"--H 4-1/2"VVLEG,ID=3.958" 0152 bpf,ID=3 958" 14 , 9497' j--19-5/8-X 5-1/2"BKR SAB PKR 0=3 875' J 15-1/2"TBG-FC, 174 L-80, .0232 bpf,ID=4.892' I- 9510' , , i 9509' H5-112"X 4-1/2"XO,ID=3 958" 1 ! 9618' 1-4,3.70BKR DEPLOY SLV,ID=3.00' 1 I TOP OF 3-1/2'LNR1--i 9630' ,1 ,.:; :, : 9633' IH9-5/8"X 7LTP,HGR w/TEBACK SLV,10=7" . ' 9670' ---i4-1/2"CAM DB-6 11P,ID=3.812' I 4-1/2"113G-PC, 1264,L-80 BTRS, H 9581' i ! 0152 bpf,ID=3958" 9682' 1-H4-1/2" INLEG,ID=3 9581i I 9572' I-1 WOO TT LOG(XX/XX/XX) 1 9-5/8"CSG,474 L-80 BT .ID=8 681" 1-1- 984. 1i --1 13-1/2'LNR,8.814,L-80..0087 bpf,ID=2.992' H 10435' . / 113436' ---13-1/2"x 3-3/16"LP XO, D=2.80' 7"W-iPSTOOK w/RA TAG fg 10506' (X XTXX/01) -4 10496' 1 1 MELOUT WINDOW(07-16A) 10504'-10513" 1 7"LNR,294,L-80 SIRS, 0371 bpi,ID=6 184" {- 10700' 1 10564'J---13-3116"X 2-7/8"X0,ID=2 372" ] r PERFORATION SUMMARY REF LOG IkACNL/GPJCCL ON 09/12/01 ANGLE Al'TOP PERE 84"@ 10700' . a ! 11595' 1-2 1"VVFD CEP(07/08/17) -----"i 12317'CTM 1-FISH-MLLE° !CCP(05/02/09)I Note Pzfer to Production Cf3 for historical perf data i 44.04'fff NM — — WWI 1••••••• ff. SIZE SFF INTERVAL OpniSqz SI-OT SQZ •••••••• i 4.. 0....... 41a.a. 2" 1 6 ,10700 10750 0 05/02/09 •••••••• 1••••••• 2' ' 6 . 10950- 11250 0 01/17/03 4.1.4.11 I P6TD HI 12322' ; 2" i 4 111360- 11560 0 09/12/01 I •••••••1 Vit.•*••••••••. 1 2-7/8"L f tR,6.164,L-80 s-rL 1---i 12364' 2" 1 4 ! 11610- 11960 C 09/12/01 ' 2" ! 4 12030- 12280 C 09/12/01 13-3/16"LNR,6 24, L-80 TC2 !.-- 10563' 1 .,0058 bpf,ID=2.37" i i [ 1 0076 bpf,ID=2,80" 1 DATEIRe..i BY CONMENTS DATE ' REV BY i COIM/ENTS PRUDHOE BAY [NT 12105/82 I PKR 176 INITIAL COMPLETION 04/21/14 CJNY PJC1GLV C/O(04/108/14) WELL. 07-16A ; 1 09/131011 ? CID SIDETRACK 05/07/14 RCT/PJC RLL EVO TRIEVE R_UG FERMI No "2011530 i 04109/14 I 0-14 i 10 05/13/14 PJC ,SFTY NOTE-MAX DOGLEG AA1b 50-029-20856-01 1 04/10/14 I PJC IDRI_G 1-10 CORRECTIONS 07/10/17 JTIVIJMD,SET CP(07/08/i7) SEC 34, T11N,R14E, 1127'SIC&534'ENIVI_ '04/17/14. 13/PJC ;FINAL ODE APPROVAL 04/12/14 I CAW 13..1C i GLV 00 BP Exploration (Alaska) • THE STATE 1vn �"„'�--8'."A Of / 4I A J, /l s � I 333 West Seventh Avenue COVF,RI\`C)R SEAN hA1tN Ell,L Anchorage fie, Alaska 99501 3572 '� Main: 907 279.1433 �-4LA s,� :.,i,x: 907.7-7, /5,2 SCANNED AUG 9 0 2 4 Dave Bjork Engineering Team Leader ),,01r' 5 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-16A Sundry Number: 314-062 Dear Mr. Bork: J Enclosed is the approved application for 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, r 1 p)x_e_44,,___ Cathy P. oerster Chair DATED this 13t of February, 2014. II End. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL JAN 2 9 2014 20 AAC 25.280 cylc �21^^) 1. Type of Request: • AO CC ❑Abandon 0 Plug for Redrill 0 Perforate New Pool ®Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate ®Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate ®Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 201-153 • 3. Address: 6. API Number: e,Alaska 99519-6612 ®Development ❑Service P.O. Box 196612,Anchorage, 50.029-20856-01-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 07-16A ' Will planned perforations require a Spacing Exception? 0 Yes No 9. Property Designatior 10.Field/Pool(s): ADL 028309 ' Prudhoe Bay/Prudhoe Bay • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD (ft): Plugs(measured): Junk(measured): 12368' . 8913' • 12322' 8915' 9522' 12317' Casing Length Size MD ND Burst Collapse Structural _ Conductor 79' 20" 79' 79' 1490 470 • Surface 2487' 13-3/8" 2487' 2485' 4930 2670 • Intermediate 9847' 9-5/8" 9847' 8315' 6870 4760 Production Liner 971' 7" 9533'- 10504' _ 8065'-8858' 8160 7020 Liner 2846' 3-1/2"x 3-3/16"x 2-7/8" 9518'- 12364' 8053'-8913' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10700'- 12280' 8942'-8917' 5-1/2", 17#x 4-1/2", 12.6# L-80 9582' Packers and SSSV Type: 9-5/8"x 5-1/2" Baker SAB Packer Packers and SSSV 9497/8037' MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: ® Description Summary of Proposal ®BOP Sketch ❑ Detailed Operations Program 0 Exploratory 0 Stratigraphic IN Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: March 1,2014 • ®Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sean McLaughlin,564-4387 Printed Name: Dave Bjork Title: Engineering Team Leader Email: Sean.McLaughlin@bp.com Signature: �J__ /�/ `/ Phone: 564-5683 Date: /��r� 'fes ��/`� Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 k`k- p(02 z ❑Plug Integrity E BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: B o f7 e.5 f C 35-CC /7 5 I BOP RBDMS 4.MAY 1 0 2014 Spacing Exception Required? 0 Yes £ No Subsequent Form Required: /Q — Ll-.04 APPROVED BY Approved By: F -ji( ---� COMMISSIONER THE COMMISSION Date: Z—13—/ Form 10-403 Revised 1x-/2012 A roRlitaGn1sNidArtmonths from the date of approval / Submit In Duplibate y� Vi- 2 //3/ {4p pp +/�j,7 14- IY by Sundry Request for casing repair Well: 07-16A Date: 01/21/2014 Engineer: Sean McLaughlin MASP: 2370 psi Well Type: Producer Estimated Start date: March 2014 History: Well 07-16A was drilled in 2001 as a horizontal Z1A producer with a Z1 B toe-up. The well began to cycle in mid-2003 with —50%on-time. After numerous OA Repressurization tests and detaching and reattaching the GL spool, it was determined that the IAxOA communication was a direct response to the well being on gas lift. The well when loaded with fluid would pass an MITIA. However once put on GL the OA would again respond with tracking pressure. In May, 2009, the CIBP set in 2006 was milled and 50'of Z1 B perfs were added towards the heel. However, a surface casing leak was discovered during the adperf operation and the well could not be POP'd and tested. The well was secured with a WRP and remains shut-in. A surface casing leak excavation was one route to fix the Surface casing leak problem but the well would . still require a workover to fix the IAxOA communication. It was decided that the best way to proceed was to complete a workover that will abandon both OA and the SC x Conductor annulus. This work is completed by a cut and pull of the 9-5/8" production casing, running new 9-5/8"casing and cementing it with the 13-3/8"casing to surface removing the OA annulus from service and running a sliplock wellhead system abandoning the SC x conductor annulus. Scope of Work: The primary objective of this RWO is to restore well integrity and return the well to 1 operable status. Pre Rig Prep Work: W 1 LDS; PPPOT-T, IC S 2 Pull leaking WRP from 9522'. Set 4-1/2" Special clearance WRP (3.69" OD) at 9516'. F 3 MIT-T to 1500 psi. MIT-IA to 3500 psi. MIT-OA to 500 psi. S 4 Dump—10' of sluggits above the WRP. E 5 Use radial cutting torch to cut the 5-1/2" tubing 3' from top of first full joint above the packer at—9441'(leave a 36' stub). (Reference tubing summary 12/04/82) F 6 Post jet cut CMIT-TxIA to 1000 psi. Circulate well with seawater and Diesel F/P. V 7 Ensure dual barriers on annulus valves, Set a TWC. O 8 Remove the well house&flow line. Level the pad as needed for the rig. W 9 Excavate the cellar as needed to get top of spray-in liner below the 13-3/8" starting head. Line the cellar around the wellhead with impermeable, Rhino lined Herculite. Proposed RWO Procedure: • MIRU Doyon 14. Test TWC. • ND tree. NU and test BOPE with four preventers configured top down (annular, 9-5/8" fixed, blind shears, mud cross and 3-1/2"x 6"VBR's). Test the VBR's to 3,500 psi and the annular to 3,500- psi. Pull TWC. • Pull 5-%" L-80 IPC tubing from jet cut—9,441' MD. • RU E-line, Run USIT in the 9-5/8"casing to determine TOC in the 95/8"x 13-3/8" annulus. • Set 9-5/8"RBP and 50' of sand —100' below logged TOC. PT RBP to 3,500 psi. • Mechanically cut 9-5/8" casing in 1st full joint above the TOC. • Pull 9-5/8"casing to surface. • Scrape 13-3/8"and dress-off 9-5/8"casing stub • Split the BOP stack and cut off 13-3/8" starting head 1—-- ; • Run 9-5/8"tie-back fully cemented to surface with 120 bbls of 15.8 ppg class G cement • Install 9-5/8" x 13-3/8" hanger and 9-5/8" sliplock wellhead. Nipple up and test BOP equipment. • Drill out the 9-5/8" shoetract and test casing to 3,500 psi. • Recover the RBP. • Run new 4-1/2" 13Cr completion with 9-5/8"x 4-1/2" HES TNT packer. MIT-T& MIT-IA to 3500 psi. • Set a BPV and RDMO. Post rigWork ✓ 1 Pull BPV S 2 Pull ball and Rod, Pull RHC seat, Install dummy GLV's, Pull WRP TREE= GRAY VVELLHFAD GRAY SAFEI TES: WELL ANGLE>70° 10615'. ACTUATOR= AXEISON 0 7-1 6A OKB.ELEV= 58' BF.ELEV= NA KOP= 3000' Max Angle= 97°@ 11785' [Datum M1- 10504' Q 2202' H5-1/2"CAM BAL-O SSSV NP,ID-4.562" Datum TVD= 8800'SS /j\ r pv I L GAS UFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-318"CSG,72#,L-80 BTRS,D=12.347" -1 2487' 4 1 28942889 6 MNG RK 16 02/21/09 .1N, ! 2 5013 4688 40 MNG CO' RK 0 06/23/06 ----� _ �ffi� 3 6619 5918 40 MAG SO RK 20 02/21/09 4 7755 6780 43 MNG DMY RK 0 09/17/01 Minimum ID = 2.372" @ 10564' I 5 8444 7266 47 IVIG DMY RK 0 09/17/01 I 3-3/16" X 2-718" LRN XO y 6 8515 7314 48 MNG DMY RK 0 09/17/01 7 8979 7634 42 MIG DMY RK 0 09/17/01 8 9046 7684 42 MvIG DMY RK 0 09/17/01 4, 9 9314 7892 39 MNG MY RK 0 09/17/01 ,M -/V- 10 9381 7945 38 MNG DMY RKP 0 09/17/01 5-1/2'TBG-PC,174,L-80,.0232 bpf,D=4.892' - 9478' 9482' H5-1/2"BAKER PER ASSY ! 9497' -I9-5/8"X 5-1/2"BKR SAB PKR,D=3.875" 9509' -15.1/2'X 4-1/2'X0,ID=3.958' I TOP OF 3-1l2"LNR 8.814;L-80,FL4S,©=2.992" H 9530' �„9512'ELMD H4-1/2”SPECIAL CLEARANCE WRP'(09/21/11) Alaill ...... 9-518"X 7'LNR TOP PKR/HGR W/ i I BACK SLV - 9533' ' I 9518' J--13.70'BKR LNR DEPLOYMENT SLV,ID=3.00 1 "- 9570' --4-1/2"CAM DB-6 LANDING NP,ID=3.812' 4-1/2'TBG PC, 12,64,L-80,.01 52 bpi,D=3.958' - 9581' \ { 9582' -14-1/2"TtBNG TAL(BOT SOS) 9572' -IELMDTTLOG NOT AVALABLE 9-5/8'CSG,474,L-80 BTRS,D=8.681" --I 984T A , 3-1/2'LNR,8.814,L-80,.0087 bpf,ID=2.992" - 10435' _ ` x { 10436' 1-3-1/2"x 3-3/16'LNR XO,ID=2.80" 7"MLLOUT WIDOW 10504-10513 WHIPSTOCK @ 10496' PERFORATION SLAMMARY RA TAG @ 10506' REE LOG:Ml.JGR/CCL ON 09/12/01 ANGLE AT TOP PERF:84°@ 10700' bilihhh. 10564' H3-3/16'x 2-7/8'LNR XO,D=2.372" I Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 111111111111111 MINIM =Ell MIIIIII IIIIIIIIIIIIIIIIIIIII AN 2" 6 10700-10750 0 05102/09 11111111 14J 2' 6 10950-11250 0 01/17/03 11111111 111111111111111 3-3/16"LNR,6.24,L-80 TC2,.0076 bpf,D=2.80" H 10563' 2" 4 11360 11560 0 09/12/01 1111111 11111111 FISH:MLLED CSP(05/02/09) 12317'CTM© 2" 4 11610-11960 0 09/12/01 11111111 2" 4 12030- 12280 0 09/12/01 1111111 11111111 11111 N PaT6 -• 12322' 111111111111 _ ..__.. 11111111 1111111 L2-718"LNR 6.16#,L-80 STL,.0058 bpf,D=2.37"-{ 12364' 1111111111111 _ - 1111111111111 11111111111 1111111111111 111111111111111 7'LNR,2 #,L 9 -80 BTRS,•0371 bpi,D - =6.184" L 10700` 11111111+ DATE REV BY CO MUTTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/05/82 ORIGINAL COMPLETION 08/14/11 OW/PJC PULL WRP(08/10/11) WELL: 07-16A 09/13/01 CWKAK CTO SIDETRACK 09/22/11 SWC/PJC SET Vv P(09/21/11) PEWIT No:''011530 06/23/06 TEL/PJC GLV CJ0 01/28/14 JNUJMD LNR,FISH,WRP DEPTH CORRECTIO AR No: 50-029-20856-01 03/03/09 JC1v'SV GLV CJO(02/21/09) SEC 34,Ti iN,R14E,1127'SNL&534'E& 05/31/09 DBANTLH CUP MILUADFS2FS(05/02/09) _ 06/13/09 CIN/TLH WRP SET(05/31/09) BP Exploration(Alaska) TREE= ` Cameron -WELLHEAD= Cameron ACTUATOR= AXH SON 0 7 16A SAFEI TES: WELL ANGLE>70°@ 10615'AND>90° @ 10750'. KB. ELEV= 58' RW 0 P mposed BE ELEV= N0. KOP= 3000' Max Angle= 97@11785' Datum MD= 10504' " Datum TVD= 8800'SS , I 2200' H4-1/2"HES X NP,D=3.812" 9-5/8"HES ES Cern enter — -2,244-'- 9-5/8" BKR ECP —{-'2,265 9-5/8" Bowen Casing Patch — -"2,286'/ 9-5/8" 47#, L-80, Hydn1563, ID=8.681" — -2,290' L 13-3/8"CSG,72#,L-80 BTRS,D=12.347' 2487' / 1 1 - 9,258 -1412'FESXI'P X3812' R 9,289' —19-518'x 4-1/2'HES TNT Fkr,D=3 88" I I R323 -{4V2'FIEXNP,CP3812' 4-1/" 12 .6#, 13Cr-85,Vam Top ' I 9381' H4-1/2-HES XNNP,D=3725'1 9,396' 9-5/8"X 5-1/2'UNIQUE OVERSHOT 5-1/2"TBG-PC, 17#,L-80,.0232 bpf,D=4-892" --{ 9478' I I- — 9487 H5-1/2"BAKER FBR ASSY Minimum ID = 2.372" @ 10564' 2 ,=, 9497' H9-5/8"X 5-1/2"BKR SAB PKR,D=3.875" 3-3/16" X 2-7/8" LRN XO 9509' H5-1/2"X 4-1/2"XO,ID=3.958" TOP OF 3-1/2"LNR,8.81#,L-80,FL4S,D=2.99T —I 9530' , 9512' ELMD —14-1/2"SPECIAL CLEARANCE Vv1 (09/21/11) 9518' —13.70"BKR LNR DER.OY MSYT SLV,ID= =3.00" 9-5/8"X 7"LNR TOP PKR/HGR W/TEBACK SLV — 9533' /: 1 ' L 9570' H4-1/2"CAM DB-6 LANDING NP,D=3.812" 4-1/2'TBG-FC, 12.6#,L-80, 0152 bpf,13=3.958' H 9581' \ 9582' H4-1/2"TUBING TAL(BOT SOS) 9572' HELMD TT LOG NOT AVA LA BLE 9-5/8"CSG,47#,L-80 BTRS,D=8.681" —{ 9847' A k 3-1/2"LNR,8.81#,L-80, .0087 bpf,ID=2.992" H 10435' \ 7 ( 10436' —13-1/2"x 3-3/16"LNR XO,D=2.80" 7"MLLOUT WNDOW 10504-10513 WHPSTOCK @ 10496' RA TAG @ 10506' tilli10564' H3-3/16"x 2-7/8"LNR XO,D=2.372" PERFORATION SUMMARY 1111111111111111IMM .0,��� FEF LOG:MCNJGR/CCL ON 09/12/01 1111111111111111 A. ANGLE AT TOP PERF @ 84 10700' 1111111111111111 � 11111111 3-3116"LNR,6.2#,L-80 TC2, .0076 bpf,D=2.80" 10563' Note:Refer to Production DB for historical rf data 11111111 _ 11111111 SEE SFF NTB VAL Oprt/Sgz DATE 1111111111111111 (FISH: MLLt3JCBP(05/02/09) —�1231T CTMD 2" 6 10700- 10750 0 05/02/09 1111111111111111 11111111 PBTD -r_12322' 2" 6 10950- 11250 0 01/17/03 1111111111111111 2' 4 11360- 11560 0 09/12/01 11111111 1111111111111111 [2-7/8"LNR,6.16#,L-80 STL. 0058 bpf,ID=2.37"— 12364' 1 2" 4 11610- 11960 0 09/12/01 11111111 2" 4 12030- 12280 0 09/12/01 1111111111111111 1111111111111111 1111111111111111 1111111111111111 7'LNR,29#,L-80 BTRS, .0371 bpf,D=6.184" —1 10700' ^ M.1.1.1.1.1.t DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY tJNT 12/05/82 ORIGINAL COMPLETION 08/14/11 DW/PJC PULL WRP(08/10/11) WELL: 07-16A 09/13/01 CWKAK CTD SIDETRACK 09/22/11 SWC/PJC SET WRP(09/21/11) FERMT No: 2011530 06/23/06 TEUPJC GLV C/O 01/28/14 JNUJMD LNR FISH 8 WRP DEPTH CORRECTI AR No: 50-029-20856-01 03/03/09 JCMSV GLV C/O(02/21/09) SEC 34,T11 N,R14E, 1127'SNL&534'EWL 05/31/09 DBM/TLH CBP MLUADPERFS(05/02/09) 06/13/09 CJN/TLH WRP SET(05/31/09) BP Exploration(Alaska) ..?., , 11 ... em,„fin *Aril ' . , 11 .i. ,:I ; ..,, ..,..... N # , *'• :,...,;Pok, ""- :#, toi: *4—i . _ _ ,.. ',#..i.,' ' mi. . 4.,exlig, I i sillik 400... , . . fti ,• ‘ P ri - t..,., .,. .......f.; ...--- ,, . ....- .7747,,,,,Airep,..„7„... u V WV.. 4670,114;e1;*„ . 44# 4 ird IF"Or#4, XX zie 40r jr;r-- , Zdezjor isfir4•rag, ArIA - of V 1111111' I . .., Ili 7/Zzil; 'hi • . r 6 k 4' Jr/ A rj r, defily7A ...- • .00°.°' ,00000004 Pdpoor;.;,.."... ' '''-'.,..•.1":". - 1,'''' ''-'' • '//v ill I r drildri rried - , 00 i .4i- ..,41,44,000000-0# 4,:000:000„ IP AO /Ai AO 404.1"-4, elis".ilr' w EcC 0 C a C0 coop i Su ;) SECT ION ASSY, 1 1 1 OWI 18 LN I`D SHV b y I3 SPCA IO,380 POWL., 3 I yy i 9 5/8 SI 1 'Yh/ X H MIS i1M I , \ ,,....._,1` i �. r F 11 L11 i,➢ N , C,_ q. a:', , i , ...._, i . , , u , , , , , „00 t i 1 _____________ 1 , ,2_,,,, -3, - __ 4. , , [,._ SLIP BCW[ 1 ASSY _ ,'1: 1 3,130 X 9 5/8, 3,075 VAX 0.) )8:1433 _A^,3 NO i3 3 '8 SiVJ, 13„I 3 C BRO'81I 12.505 M :D 13 3/8' 0D PSC 9 'sib° 0D CS!O 23 � J A_ASAA sT,P73RT R57:0,3_NV,." 3'3 �. PRIVATE AND CONFIDENTIAL REV'S C7S oESCNI / ON 5T 1 i BF'REPRODUCED,USLD LL,SC 05,CP MA.'TPA C,N ANT MANNER RRIDP"0 SJR AGS` ,A LAD L,YC T, �BABA BA Mnar a E os 17 s RC.CIL„ o DI.IoNM." LAIN IIN�' RI`( x SLIP -GR NH„ „,a ,r, fMCTQchnologios AlACCEPTED BY PEB PIE.PUP.ANT 10 A . 9 5/8 CAU PROGRAM, BASION E�u�z o5-1z-1� 3 5/8 X 0 / S RCMS HD, MARC - MUST BE PET..UPON DEMAND f X SL ASKA SUP' 05 os-1�-13 ,N , r EAS ERW0 DRAIN NG Mate FOR AT USE CIP SAT'I.W...,ORI 4 OR A.°I.,PT PSCIN p � (0 � fa . I-0 Tit oN x.,MR N ax,+ ox ,AA, F[NOL06i6 -305. TCN CS-I'-13 Jl, '/U (UL�H.�i V • • = N N a)i i . 3 o m i t ,.., w - x O ST 0 1 ill . z 8 aM so z �� �qt{& t 0.o O G i Q qq p - In N S �gg • x Z K 0 Q • P el L., 0 :.§ i. 0 d R OW. n w a a a ,5-11 _,y 0 3 n a z Q CD Y U OJ N Or G 111 J Q i ,i i O g rim 1, D7) -110.7- ..-----1 E'_ 0= w _ Masillini .;O \ V Q ,' O Pd ... • i,li O iiiYNM O tMi+ abai U -p �- V6 z 41 r K E n3 zaz 0 b4m b y. m 5 n > > e ¢¢ a w =o os o v�� w w 8y- i� w N -z m = - t', m ad m E �i II 1 §a m 8Jifa . 0 Es m J z m o o m e f I 0 Po Qp M to M M n e, '4 WW I Z gN j m J • £ •;: l O Il II i ..„ li , Z £ o J - uIU'll' 'ifsiiiiii I 0 et. co 0111E1111 u 111 it A—, O E o 45 cn 1 &M o ; LJ M Page 1 of 1 n U Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 28, 2009 9:38 AM To: Gary Preble (SAIC) Subject: DS 07-16A (201-153) Gary, I am reviewing the 404 recently submitted for milling the BP and perforating. Do you have the operations summary when the BP was set? The most recent information I found in the file appears to be the original completion in 2001. Thanks in advance. Tom Maunder, PE AOGCC ~~~~ 5/28/2009 STATE OF ALASKA ~AY 1 2 2009 ALAS OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OP~~ art~r Cammi~saor _~z~ S/~S=Qy~ 1. Operations Abandon ~ RepairWell ~ PlugPerforations ~ Stimulated - `•~ ~Pu~ Other MILL (~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ~~ 201-1530 3. Address: P.O. Box 196612 Stratigraphic Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20856-01-00 7. KB Elevation (ft): 9. Well Name and Number: 58 KB PBU 07-16A 8. Property Designation: 10. Field/Pool(s): ADLO-028309 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12368 feet Plugs (measured) None true vertical 8912.62 feet .Junk (measured) 12358' 4-30-09 Effective Depth measured 12322 feet true vertical 8915 feet Casing Length Size MD TVD Burst Collapse Conductor 79 20" 91.5# H-40 Surface - 79 Surface - 79 1490 470 Surface 2487 13-3/8" 72# I-80 Surface - 2487 Surface - 2485 4930 2670 Production 9847 9-5/8" 47# L-80 Surface - 9847 Surface - 8315 6870 4760 Liner 971 7" 29# L-80 9533 - 10504 8065 - 8858 8160 7020 Liner 2846 3-1/2X3-3/16X2-7/8 9518 - 12364 8053 - 8913 8.8# 6,2# 6.16# Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 SURFACE -9478' 4-1 /2" 12.6# L-80 9509' - 9581' Packers and SSSV (type and measured depth) 9-5/8"X5-1/2" BKR SAB PKR 9497' 9-5/8"X7" LNR TOP PKR/HGR 9533' 0 0 0 0 12. Stimulation or cement squeeze summary: ~~~~~ Intervals treated (measured): ~~L.C_~ ~~~ ~ v.9 ~.~~ ~ „~ S.`C ~-~~ ~~ 3' ~ ~o Treatment descriptions including volumes used and final pressure: ~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory [~ Development Service ~~` Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary ,e Title Data Management Engineer Signature r` Phone 564-4944 Date 5/11/2009 Form 10-404 Revised 04/2006 ~, 4~`~ X09 r~~~~Submit Original Only 07-16A 201-153 PERF ATTACHMENT I~ Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 07-16A 9/12/01 PER 11,360. 11,560. 8,948.55 8,951.63 07-16A 9/12/01 PER 11,610. 11,960.68 8,950.06 8,928.81 07-16A 9/12/01 PER 12,030. 12,280. 8,925.56 8,916.74 07-16A 1/17/03 APF 10,950. 11,250. 8,948.12 8,949.78 07-16A 4/6/06 BPS 11,984. 11,985. 8,927.54 8,927.49 07-16A 4/30/09 BPP ~ 11,984. / 11,985. 8,927.54 8,927.49 07-16A 5/1/09 APF 10,725. 10,750. 8,944.25 8,944.91 07-16A 5/2/09 APF 10,700. 10,725. 8,942.24 8,944.25 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • u L J 07-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY I 4/29/2009~CTU #9 w/1.75" CT. Drift/Mem SCMT. <InterACT publishing> MIRU CTU. Pump ~ 1-1/4" drift ball. Perform weekly BOP test. RIH with 2.25" Drift BHA. Tagged at 10,676' ctmd and BH jetted down to 11,878' ctmd, paint flag at 10500' ctmd and I EPOOH for SCMT logging tools: OOH LD Drift BHA and MU SCMT Logging tools. .Log SCMT from 10564' @ 30 fpm. Logging pass in progress. Continued on 04/30/09 WSR. I -- -- 4/30/2009 Continued from 04/29/09 WSR. Complete SCMT pass interval 10564'-9524' @ 30 .fpm. Make repeat pass, same interval. POOH. MU WOT 1 11/16" motor/2.29" five blade junk mill. RIH and tagged at 11,589 ctmd. Milled down to 12,036' ctmd ..with many stalls & over pulls. PUH to 10350' with stalls and over pulls mainly in .the heel of the well. RIH and tagged where we left off, 18:36 Lost all WHP, bit to 12358' w/ 50 stalls. Looks close to TD. Back ream up. Continued on 05/01/09 WSR. 5/1/2009 T/I/O = 0/600/250. Temp = SI. Monitor WHPs ,bubbling in cellar (Operator call in). No AL line. Water rising out of conductor flutes w/light oil sheen and cresting into cellar @ 7 o'clock position. Random u b mg every o y secon s m u es rom o c oc to o c oc posi ion. No LEL reading on gds meter. Fluid level in ~ I~cellar is -6" deep and 5" from top of grating. Fluid sample taken from conductor. 5/1/2009 Continued from 04/30/09 WSR. Pull up into 3 1/2" liner @ 10500'. Flush liner w 100 bbl KCL. R_IH dry, tag @ 12275'. Make repeat trips from bottom @ 12359 to .11950'. Continue to see motor work/stalls/tags. POOH. MU/RIH w/ 2.25" iventuri/jars. Tagged ~ 12,161' ctmd and pushed debris down to 12,206' ctmd. ':Had some over pulls and discussed situation with CT scheduler and decided not to go any deeper. POOH to MU SWS Logging tools. Fluid leaking up around !casing hanger, called DSO and he called the WIE. We are ok to proceed. OOH LD 'Venturi BHA and MU SWS Logging tools. RIH and tagged at 12,212' ctmd, PU to 12,200' and logged up to 10,100' painting a flag at 10,800' ctmd. OOH checking ..tools for da a. oo ata, RIH w/ Gun #1, 25' of 2" guns. Correct to flag. Shoot interval from 10725'-10750'. POOH. Continued on 05/02/09 WSR. 5/2/2009 Continued from 05/01/09 WSR. Interact publishing=yes. POOH from Gun #1. MU/RIH w/ Gun #2: 25' of 2". Tie into flag @ 10675'. Shoot interval 10700' to 1 5'. OOH with spent perf gun, all shots fired. Prep or o remove n ge @ 12,212'. RIH w/ DJN BHA and tagged 12161' ctmd. Washed down to CIBP @ 12,317' ctmd and POOH. 7740' found Gouge/Dent in CT, damage is below minimums and reel will need to be blown down, continue POOH. OOH. Blowdown reel & freeze protect well to 2000' with 50/50 meth. RDMO, job complete, well ready to POP. • • FLUIDS PUMPED BBLS 156 METHM/ATER 46 1 %KCL 417 1 %KCL W/XS 162 GALS OF N2/15093 SCF 619 Total WeIlSezviceReport WELL SERVICE REPORT Page 1 of 2 WELL J08 SCOPE UNIT 07.'~ ~;~, PACKERS/BRIDGE PLUGS (NRWO} CTU #8 DATE DAILY WORK DAY SUPV 4/6/2006 JEWELRY LOG--DEPTH CONTROL; SET MECHANICAL gUNDY PLUG COST CODE PLUS KEY PERSON NIGHT SUPV PBD07WL16-N DS-TRASK ROCHIN MIN ID DEPTH TTL SIZE 2.372 " 10564 FT 0 " CTU ~, Memory (UKtCCL, Set CIBP; Continue from WSR 4-5-06 ... RIH with PDS memory GRlCCL. Log interval 12100' up to 11500' ctmd. Flagged pipe at 11950` cfmd. Log correction was +7'. Did not see any indications on coAar log of the perforated in#ervals. RIH with Baker 2 7i8" CIBP. Correct depth at flag to top of CIBP. Continue RIH and position CIBP at 119$4' corrected depth. Set CIBP with 3400 psi CTP. Confirm set at 11984'. POOH. FP well to 2500' with 60140 methanol. LOG ENTRIES Ini# T , IA, OA 7249 1200 0 TIME DEPTH TBG CTP BPM BBL5 COMMENTS 00:01 0 Continue from WSR 4-5-06. Wait on Veco hardline crew to PT surface lines and P-sub. 01:51 0 Veco on location. 09:55 0 Make u PDS to in tools. 02:29 0 Veco hardline ressure tested to 4k. 02:39 0 4 Circulate meth to flowback tank. PT lubricator 500 1 1600 1 4000 02:54 0 Flan a leak from wellhead to um -in~ub. Ti h#en s#uds. 03:08 0 Pad o eratar shut win va{ve, o en SSV. 03:13 0 JIC fitting at IA transducer failed releasing gas into weghouse. Shut down a ui ment and re air. 03:29 0 2m Re- ressure test to 4000 si. 03:40 0 2249 O en swab 35 turns 03;49 0 2238 2369 3.1 0 Be in um in meths ar down backside. 03:51 0 2212 2362 3.9 10m Swa to 2 % KCL down backside to kill well 04:00 0 1909 2074 5 16 Well kill. 04:17 0 936 930 4.4 102 Continue well kill. 04:30 0 407 559 0 150k S#o um in KCL, switch to me#h down backside 04;35 0 317 472 0 10m Down on um . 04:43 0 286 442 RIH wth PDS memo GRlCCL to in tools. 05:49 5000 436 334 Wt ck 10k 06:46 10050 838 151 Wt ck 23k 07:11 12100 974 150 Make memo to in sto at bottom to interval. 07:21 12100 1021 149 Be in to in u hole at 50 f m. U wei ht 25k. 07:33 11500 1076 128 Sto at to of b in interval. 07:38 11500 1095 128 RIH to 12100 #or re eat to i ass. 07:45 12100 1126 151 Make memo to in sto at bottom to interval. 07:58 12100 1170 150 PUN in at 50 t m. Stalled. RBIH. 08:04 12100 1190 150 PUH fo in at 50 f m. 08:15 11600 1210 130 Sto . 08:20 11600 1215 130 RBIH 08:22 12100 1220 155 At bottom of to in interval Pause. 08:26 12100 1225 140 PUH to in at 50 m. 08:28 11950 1225 130 Pause. Paint fla ellow . 08:35 11950 1220 130 PUH io in . 08:44 11500 1220 130 Pause at to of to in interval. 08:48 11500 1220 130 POOH. Wei ht 23 k#. 10:11 0 1155 125 At surface. Bleed down. 10:35 0 La down tools. Check for data. 11:10 0 Data ood. +7 foot correction 11:20 0 Baker on location. Hold PJSM. 11:33 0 0 Fill coil with meth. 11:45 0 19m PT MHA to 3500 si . 11:48 0 MU Baker CIBP ass . 12:11 0 3m Stab onto well. PT lubricator via backside to 250!2500 si . http:/lapps2-alasl~a.bpweb.bp,com/awgrs-weliservicerepart/default,aspx?id=17948796EAC444A9.., S/2812009 WellServiceReport Page2of2 12:32 0 1185 140 O en swab. SIWHP = 1185 i 12:33 0 1185 140 2.0 0 S ear meth down backside. 12:39 0 1100 140 4.5 10m10 Swa to KCL down backside. 12:50 0 900 140 4.5 50 RIH with BHA #2 (2.13" ctc, 2.13" checks, 2.13" hyd. disc, 2.13" xo, 2.13" inflate valve, 2.13" xo, 1.69" hyd. sefting tool, 2.20" CIBP). TOL = 12.29' 13:28 3215 200 190 0 210k Down an um . 13:35 3850 75 190 1.9 0 Ca well with meth. 13:41 43$0 40 190 0 12m Down on um . 13:54 5500 40 170 Wei ht check 11 k#. 14:58 10500 145 145 Wei ht check 22 k# 15:05 11188 375 145 Havin roblems with the level-wind. Park and re air. 15:58 11188 545 145 Continue RIH. 16:15 11962 590 145 At fia . 16:19 11957 595 150 Chan a de th to corrected to of CIBP fla = 11957' 16:21 12010 590 140 RIH to below set de th. Pre to launch baN. 16:40 12010 5$0 150 1.1 0 Launch 112" Bali. Pum to seat. 16:43 12010 585 770 1.0 3 PUW to set de th. Wei ht 23.5 k# 16:45 11984 585 955 1 A 4 Park at CIBP set de th of 11984'. 16:49 11984 590 150 0 7 Down an pump. Appears burst disc in pump has blown, Troubleshoot um . 17:28 11984 570 140 0 7 Found chunk of debris cau ht in suction valve. Re-assemble um . 17:42 11984 570 145 2.0 7 Flush um down backside. PT um head to 4000 si . 17:50 11984 570 145 0.9 11 Continue um in down coil to seat Bali. 18:01 119$4 590 2800 0 22.9 Ball on seat. Down on um 19 bbls to seat . 18:03 11984 590 2800 0 22.9 Bum CTP u to shear. 18:04 11984 590 3400 0 23.1m Sheared a#3400 si CTP. PUH. 18:07 11965 590 145 RBIH to to and confirm set. 18:13 11986 590 145 Sat down 1 k# at 11986'. A ears to be a ood set. 18:15 11986 585 145 POOH 18:34 10900 575 125 0.5 0 Begin pumping meth down backside to flN pipe voidage and FP Weil. 20:10 0 516 126 43m At surface. Post ' b safe meetin ,Shut in well. Be in RD 23:59 0 End Ticket. Move to DS 07-29 Final Tb IA OA 516 1000 350 FE.UIp SUMMARY 113 obis - 60140 methanol 360 bbis - 2°I° KCL http://apps2-alaska.bpweb. bp. c©m/awgrs-wellservicereportldefault. aspx?id=1 ?948796EAC4Q~4A9... 5128/2009 05/14/09 Woll .Inh !t S~hlu~b~r~~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth I nn nasrrinfinn N0.5235 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 .,~f~, 2-06 AP30-00035 STATIC PRESS/TEMP SURVEY 04/25/09 1 E-07A AYOO-00022 SCMT 04/24/09 1 1 V-04 AWJB-00031 MEM GLS -( 03/24/09 1 1 Y-16 AZ4D-00015 USIT /'dr --() QQ 05/06/09 1 1 07-16A 62WY-00002 MEM CBL ~ 04/29/09 1 1 J-06 ANHY-00009 PRODUCTION PROFILE t3U 05/08/09 1 1 R-21 AVYS-00038 LDL / -I / / C~ 05/02/09 1 1 18-01A B2WY-00003 MEM CBL f ~}~ -(~ 05/01/09 1 1 13-03 AYKP-00018 SCMT Q'-~ ~-~ ®(o~ ~ ~ (~ 05/01/09 1 1 4-04A/T-30 BOCV-00014 SCMT ~ 04/27/09 1 1 03-09 AXOY-00007 MCNL / ~ , ~ 61~j' 12/13/08 1 1 K-i6AL2 AXIA-00009 MCNL 01/10/09 1 1 02-13B AWL9-00028 RST 03/26/09 1 1 C-03B AVY5-00040 RST 05/05/09 1 1 ^AIP RI Cninr Cn PLEASE ACKNOWLEDGE RECEIPT BY SIGNING ANU HEI URNING ONE DOPY EACH TO: BP Exploration (Alaska) Inc. ~ - , "~' ~~' ~ ti Petrotechnical Data Center LR2-1 ~,~ 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ ~ ~QG9 Date Delivered: ~~ ggtt5't1S51 ~i0 CFa~r ~ 1~ Alaska Data & Consulting Services 2525 Gambell Street, to 400 Anchorage, AK~950 - 838 ATTN: Beth Received by i 11/21/07 Schlumber~er ~,9 h'(~~/ NO. 4509 Alaska Data 8 Consultin Services ~t:L~i'g~ ~U Y ~ ~ ~~~~ 9 Company: State of Alaska 2525 Gambell Street, Suite 400 / Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ 4..~ Attn: Christine Mahnken ATTN: Beth c, ~ \ ~' eJr 333 West 7th Ave, Suite 100 ~r ~i Anchorage, AK 99501 - Field: P.Bay, Milne Pt., Endicott Z-10 1167697d GLS "~~'~~~, -- l 11/11/07 1 06-16 11686797 PPROF & RS7 ~ ~" ('~.~ P °~*°:~ 17/15/07 1 MPL-33 11661179 MEM INJECTION PROFILE f 1 t' '~, ~ f; : ~ ...~ ~ry ~~ '"~ 11/13/07 1 MPF-25 11846827 USIT / 'p 'j ~~;^~ ! k~ ~~ 11/10107 1 GNI-04 11846828 USIT ~._~~~';l-.._ ~'`~t- 11/11/07 1 OWDW-SW 11626128 RST y r° ~^. , ~ P' _. - - '~ '. ~°~._~ •'-~- 10/10/07 1 1 3-35/L-36 11630502 RST ~ ~i`~~;- r^; _~°} ~ '~.~~- ~ r~~_ 09/09/07 1 1 15-26B 11661165 MCNL i' ~~~ ~ ~ ~ ~~ i ~;!.: ;ea 1- l r.~ 08/24/07 1 1 05-36A 10928638 MCNL %p ~~- - ~) ~-f) 't ~;; `" I) ~'~~ ~ ~ 06/11/05 1 1 07-16A 11216211 MCNL ~ - .,~„~ t~ B'~-~'- ~''~•( 08/27/06 1 1 2-286/0-19 11638650 RST ):~~ ,~~j - ~~, ~, ~~., a°= ~ - -,~- °~j 07/05/07 1 1 07-02A 11649983 MCNL l~ /~. --- {~~ a "~~ "~¢ ~ d~~~ ~;~. I P 08/07/07 1 1 N-27 40015763 OH MWDILWD EDtT ,..t-°~.._,rij~~p' `° i:~-°~~-pj 09111107 2 1 r~~r+ac llvn~wvvLCIJVC RCV Or'1 or JIl71VInlb NIVU KCIUKIVIIVb VNt.GU Y~IG-+KAI. FI IU: BP Exploration (Alaska) Inc. a ~ t, ~ ~ ~~ ~~~' Petrotechnical Data Cenler LR2-1 _ J 900 E. Benson Blvd. Anchorage, Alaska 99508 ~. F` Date Delivered: °: j alu<<,,: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2,83; ATTN: Beth ~, ~ ~ i I j Received by I I ,~ ~ /~,_ . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2011530 MD 12368 TVD DATA SUBMITTAL COMPLIANCE REPORT '10~3~2003 Well Name/No. PRUDHOE BAY UNIT 07-16A Operator BP EXPLORATION (ALASKA) INC 8913 ~-~ Completion Date 9/13/2001 x Completion Status 1-OIL Current Status 1-OIL APl No. 50-029-20856-01-00 UIC N REQUIRED INFORMATION Mud Log N._~o Samples N_~o Directional Survey N_go DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments Rpt ED -'~ fid ........................................................................ Directional Survey ~"1~0570 10428 :::::::::::::?:::::::::::::?::::::::::::::::::::::::::::::::::::::::::::::::::?::¥:::::::::::::::?::::::::::?::::::::::::: Directional Survey FINAL Open 10/4/2001 Driectional Survey Paper Copy 1 10510 12368 Open 1/15/2002 1 9383 12305 Case 11/2/2001 FINAL Open 10/4/2001 Directional Survey Digital Data Well Cores/Samples Information: Name Start Interval Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis ~ Received? Daily History Received? ~ N Formation Tops ~ N Compliance Reviewed By: Date: 01/14/02 Scklumberger Alaska Data & Consulting Services 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. 1716 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD G-19A iqcl--IO~ 21505 MCNL 11/07/01 ! 1 1 W-21A 21507 PP,IMP,ARC & D/N 11/10/01 1 W-21A ~O I- J J ) 21507 MD VISION RESISTIVITY 11/10/01 1 1 W-21A 21507 TVD VISION RESISTIVITY 11/10/01 1 1 W-21A 21507 MD VISION D/N 11/10/01 1 1 W-21A 21507 TVD VISION D/N 11110101 1 1 D.S. 7-16A C:~O~-1.5.~ 21520 PP,ARC 09/09/01 1 D.S. 7-16A 21520 MD VISION RESISTIVITY 09/09/01 I 1 D.S. 7-16A 21520 TVD VISION RESISTIVITY 09/09/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED JAN 1 $ 2002 Alad~ Oil & Gas Cons. Conunission Ancl~age Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 Al-tN: Sherrie Received 10/31/01 Schlumbe er Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATFN: Sherrie NO. 1582 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 7-16A ~O/-I 5.~ 21433 MCNL 09/12/01 1 1 1 F-0S 1 --/I- OOC~ 21411 RST 09/11/01 1 1 1 F-21 /_~o_~ ,-~ 5 (~ 21412 EST 09/08/01 1 1 1 K-10A c::~/" ~i~ 21341 MCNL/BORAX 09/11/01 1 1 1 D.S. 1-04A c:~Oi--! 5~ 21436 MCNL 08/31/01 1 1 1 J-13 / ~~ ~ 21410 EST 09/06/01 I 1 1 D.S. 1-04A ~O)-/~c,~ 21435 MCNL 08/30/01 I 1 1 F-40 I ~ l- I/"1 21415 RST-SIGMA 09/09/01 1 1 1 N-20A IC~_ I~! 21441 USIT 09/21/01 2 L-01 (REDO) ~=,~O)-~:~'~,-~ 21320 DSI/AIT/PEX 06/19/01 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Bivd. Anchorage, Alaska 99508 Date Delivered: RECEIVED NOV 0 2. 2001 0il & Gas C(ms. C0mmi~n Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A~N: Sherrie Receivec~~' .~0 X~) ~.,,-~ I STATE OF ALASKA (~" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-153 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20856-01 4. Location of well at surface~' '--~; '~'~'~ ~ ~ I ~''~'~1~I ~'~TM i~~ 9. Unit or Lease Name 1127' SNL, 534' EWL, SEC. 34, T11 N, R14E, UM .i ._.~._,. Z~:/:~_ ~ At top of productive interval " ~': :,'r~!. ~, YEa1 Prudhoe Bay Unit 3050'At totalNSL'depth2370' EWL, SEC. 27, T11N, R14E, UM i .~,~.~'E;-,.! ::~'~:~ i~ i ~.~ ~ 10. Well Number 07-16A 4662' NSL, 1812' EWL, SEC. 27, T11N, R14E, UM '~, ................ ~...--~¥:'.. ---.-,,- ............ '5'. El'evation in feet (indicate KB, DF, etc.) 6. 'Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool RKB - 58' ADL 028309 12. Date Spudded9/4/2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'9/9/2001 9/13/2001 115' Water depth' if °ffsh°reN/A M S L 116' N°' °f C°mpleti°nsO n e 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV setl 21. Thickness of Permafrost 12368 8913 FTI 12322 8915 FT []Yes [] No (Nipple) 2202' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, Memory CNL, CCL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 79' 30" 1900# Poleset 13-3/8" 72# L-80 Surface 2487' 17-1/2" 1650 sx Fondu~ 400 sx PF 'C' 9-5/8" 47# L-80 Surface 9847' 12-1/4" 500 sx Class 'G'r 300 sx PF 'C' 7" 29# L-80 9533' 10504' 8-1/2" 350 sx Class 'G' 3-1/2,,x3-3/16,, 8.8#xS.2#x6.16# L-80 9518' 12364' 3-3/4" 125 sx Class 'G' x 2-7/8" 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) ........ SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 5.1/2,,, 1'7~,' L.80 9509' 9497' ' MD TVD MD TVD '4-1/2", 1216#, L-SO ' 9581' ' ' ' ' 11360' - 11560' 8949' - 8952' . . . . 11610' - 11961' 8897' - 8929' 26. '"ACID,' FRAc-rU'RE, CEMENT 'SQuEEzE, 'ETC. 12030' - 12280' 8926' - 8917' . .......... .D.E.P'I'H, INTERVAL/MD) .... AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 43 Bbls of Dead Crude ,, 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) September 14, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Row Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER'BBL OIL GRAVITY-APl (CORR) ~ress. 24-HouR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED OCT Alaska 0il & Gas Cons. Commission ......... Anchor~. .... Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Zone 1 B 10552' 8894' RECEIVED OCT I ? 2001 Alaska Oil & Gas Cons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys , , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble "~/1~ ~ Title TechnicalAssistant Date /~"'/7'~/ 07-16A 201-153 Prepared By Name/Number: Terrie Hubble, 564-4628 ...... Well Number Permit No. / Approval No. , , INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL BP EXPLORATION Page 1 of 7 Operations Summa Report Legal Well Name: 7-16 Common Well Name: 7-16A Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/13/2001 Contractor Name: NABORS Rig Release: 9/13/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/2/2001 14:00 - 22:00 8.00 STWHIP P WEXlT NU BOP 22:00 - 23:59 1.98 STWHIP P WEXlT Test BOP 9/3/2001 00:00 - 07:00 7.00 STWHIP P WEXlT Test BOP. CTU arrived 0300 ;07:00 - 07:30 0.50 STWHIP P WEXlT Clear floor and hold PJSM '07:30 - 08:30 1.00 STWHIP P WEXlT Stab coil 08:30 - 09:30 1.00 STWHIP P WEXlT align gooseneck 09:30 - 10:00 0.50 STWHIP P WEXlT Change paokoff and brass 10:00 - 10:30 0.50 STWHIP P 'WEXlT Install coil connector and displace coil 10:30 - 11:15 0.75 STWHIP P WEXlT PT hard lines 11:15 - 11:45 0.50 STWHIP P WEXlT Install second gate valve on outer annulus 11:45 - 12:00 0.25 STWHIP P WEXlT PT coil connector and MHA 12:00 - 12:40 0.67 STWHIP P 'WEXlT PU floor and general house keeping 12:40- 15:20 2.67 STWHIP P WEXlT RIH 15:20 - 15:50 0.50 STWHIP P WEXlT Change over to slick water for milling operation 15:50 - 21:10 5.33 STWHIP P WEXlT Mill window. Top of window 10,503.6' mill to 10,506.0 mill quit. 21:10 - 23:45 2.58 STWHIP P WEXlT POH to change mill 23:45 - 23:59 0.23' STWHIP P WEXlT Change out mill. Mill out of gauge = 3.77", string mill in gauge 9/4/2001 00:00 - 02:45 2.75 STWHIP P WEXIT RIH, Pull test. 02:45 - 03:45 1.00 STWHIP: P WEXlT Corrolate depth. 03:45 - 10:00 6.25 STWHIP P WEXIT Mill window 10,506.2 to 10,512.5 drilled 10' new hole to 10522'. 10:00 - 11:00 1.00 S TWHIPi P WEXIT Pump sweep. 11:00 - 11:20 0.33 STWHIP P WEXlT Dry trip thru window,. OK 11:20 - 14:00 2.67 STWHIP P WEXlT POH for drill build assembly. 14:00 - 14:30 0.50 STWHIP P WEXlT L/D window milling BHA. 14:30 - 16:30 2.00 DRILL P PROD1 Function test orienter. M/U BHA #3 (90.28') 16:30 - 18:30 2.00 DRILL P PROD1 TIH to 10325'. 18:30 - 20:00 1.50 DRILLP PROD1 Log GR tie-in (-12' correction). Meanwhile swap well to 8.7 ppg SF FIo-Pro Mud. 20:00 - 20:15 0.25 DRILL P PROD1 RIH & tag bottom. 20:15 - 00:00 3.75 DRILL P PROD1 Orient as needed & drill build section to 10620'. 9/5/2001 00:00 - 01:10 1.17 DRILL P PROD1 Continue drilling build section from 10620' to 10652' with 2.4/2.4bpm, 3100psi freespin / 200psi dp / 60L TF / 2k WOB / 48fph ROP. 01:10 - 04:15 3.08 DRILL , P PROD1 POOH BHA#3 for lateral drilling assembly. 04:15 - 04:30 0.25 DRILL ;P PROD1 OOH. PJSM on LID BHA#3 & P/U BHA#4 04:30 - 05:00 0.50 DRILL P PROD1 L/D BHA#3. 05:00 - 07:00 2.00 DRILL P PROD1 Function test orienter, getting 3 for 3. Download memory resistivity data. P/U BHA ~ (90.14') w/1.04 ABH motor setting. Resistivity tool in memory position. Bit to sensor offsets: D&1=26.80', GR= 29.80', Res- 57.28' 07:00 - 08:00 1.00: DRILL P ' PROD1 RIH to 400' and shallow test tools - ok continue RIH to 5000'. Question as to whether a service break was torqued. 08:00 - 09:00 1.00 DRILL N HMAN PROD1 TOH and check make-up torque at suspected break. It was torqued. 09:00 - 11:00 2.00 DRILL P PROD1 TIH 11:00 - 11:45 0.75 DRILL P PROD1 Log tie-in -7' correction. 11:45 - 12:00 0.25 DRILL P PROD1 RIH to bottom. 12:00 - 13:20 1.33 DRILL P PROD1 Orienting TF to highside. 13:20 - 15:00 1.67 DRILL P PROD1 Directionally drilling build section f/10652' - 10781'. 2.4/2.4 3330 psi on bottom. No mud losses. Landed out at 10749' md 89.9' deg 8887' tvd. GR APl 35-55 15:00 - 15:35 0.58 DRILL P PROD1 Survey and orienting. 15:35 - 16:35 1.00 DRILL P PROD1 Directionally drilling lateral f/10781'- 10850' 2.5~2.5 3400 psi Printed: 9/17/2001 4:26:39 PM BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: 7-16 Common Well Name: 7-16A Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/13/2001 Contractor Name: NABORS Rig Release: 9/13/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/5/2001 15:35 - 16:35 1.00 DRILL P PROD1 (max) on bottom 3100 psi off bottom. 90-100 fph 16:35 - 17:00 0.42 DRILL P PROD1 Wiper trip to window. 17:00- 17:30 0.50 DRILL P PROD1 Orient 17:30 - 18:35 1.08 DRILL P PROD1 Directionally drill from 10850' to 10915' with 2.4/2.4bpm, 3320psi freespin / 3500psi on btm / 95L-120L TF / 2k WOB / 86fph ROP. Ocassional wt stacking. 18:35 - 18:45 0.17 DRILL P PROD1 Orient 2 clicks & acquire surveys. 18:45 - 19:00 0.25 DRILL P PROD1 Drill from 10915' to 10930' with 2.5/2.5bpm, 3250psi freespin / 3400psi on btm / 80L TF / 2k WOB / 85fph ROP. 19:00 - 19:10 0.17 DRILL P PROD1 Orient 1 for 1. Up Wt = 50k & Down Wt = 14.5k. 19:10 - 19:45 0.58 DRILL P PROD1 Drill from 10930' to 10960' with 2.5/2.5bpm, 3250psi freespin / 3400psi on btm / 50L TF / 2k WOB / 72fph ROP. 19:45 - 20:05 0.33 DRILL P PROD1 Survey and orient 1 for 1. 20:05 - 20:45 0.67 DRILL P PROD1 Drill from 10960' to 11000' with 2.5/2.5bpm, 3250psi freespin / 3400psi on btm / 5L TF / 2k WOB ! 66fph ROP. Observe Iow angle build in loose sands. 20:45 - 21:30 0.75 DRILL P PROD1 Wiper trip to window. 21:30 - 22:00 0.50 DRILL P PROD1 Orient 4 for 4. 22:00 - 23:15 1.25 DRILL P PROD1 Drill from 11000' to 11080' with 2.5/2.5bpm, 3175psi freespin / 3375psi on btm / 85-95R TF / 2k WOB / 60fph ROP. No downhole losses. 23:15 - 23:35 0.33 DRILL P PROD1 Orient 6 for 6 & 2 for 2 to LHS 23:35 - 00:00 0.42 DRILL P PROD1 Drill from 11080' to 11101' with 2.5/2.5bpm, 3250psi freespin / 3400psi on btm / 95L TF / 2k WOB / 35fph ROP. Formation sticky. 9/6/2001 00:00 - 05:30 5.50 DRILL N RREP PROD1 Observe 2 missing & 1 cracked teeth on one of injector's topdrive timing gear. POOH to replace injector. POOH slowly to avoid mialignment of timing gears. 05:30 - 05:45 0.25 DRILL N RREP PROD1 OOH. PJSM on L/D BHA#4. 05:45- 06:30 0.75 DRILL N RREP PROD1 L/D BHA#4. 06:30 - 16:00 9.50 DRILL N RREP PROD1 R/D CTU #4. Will take to Deadhorse yard and replace entire injector unit with one on stand-by in yard. Estimate downtime 12 hrs. 1145 hrs: hole has taken 4 bbls in the last 3 hrs. 1600 hrs: CTU ~ on location 16:00 - 18:30 2.50 DRILL N RREP PROD1 PJU coil unit. R/U injector & stab packoff. M/U CTC. 18:30- 18:45 0.25 DRILL N RREP PROD1 PJSM on R/U BHA#5. 18:45 - 19:45 1.00 DRILL N RREP PROD1 Function test orienter, getting 3 for 3 & total of 60 degs. M/U BHA #5 (90.14') with memory resistivity tool & 1.04 ABH motor setting. Bit to sensor offsets: D&1=26.66', GR=29.66', Resistivity=57.14'. 19:45 - 22:15 2.50 DRILL N RREP PROD1 RIH & SHT tools - OK. Continue RIH to 10352'. 22:15 - 22:35 0.33 DRILL N RREP PROD1 Fix throttle for NAD pump. 22:35 ~ 23:15 0.67 DRILL N RREP PROD1 Log GR tie-in (-8' correction). 23:15 - 00:00 0.75 DRILL N RREP PROD1 Continue RIH. Work thru various tight spots @ 10545', 10597' & 11045'. 9/7/2001 00:00 - 00:15 0.25 DRILL N RREP PROD1 Continue RIH BHA#5 to btm. Bring on pumps and obtain toolface. 00:15 - 01:30 1.25 DRILL P PROD1 Drill from 11101' to 11170' with 2.5/2.5bpm, 3250psi freespin / 3500psi on btm / 65-120L TF / <2k WOB / 90fph ave ROP. Motor stall @ 4000psi. 01:30 - 01:50 0.33 DRILL P PROD1 P/U and shoot survey. Up Wt = 45k & Down Wt = 15k. 01:50 - 02:35 0.75 DRILL P PROD1 Drill from 11170' to 11185' with 2.5/2.5bpm, 3250psi freespin / Printed: 9/17/2001 4:26::39 PM BP EXPLORATION Page 3 of 7 Operations Summa Report Legal Well Name: 7-16 Common Well Name: 7-16A Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/13/2001 Contractor Name: NABORS Rig Release: 9/13/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/7/2001 01:50 - 02:35 0.75 DRILL P PROD1 3500psi on btm / 50L TF / <2k WeB / 40fph ReP. Wt stacking. 02:35 - 03:40 1.08 DRILL P PROD1 Drill ahead to 11240' with 2.5/2.5bpm, 3250psi freespin / 3500psi on btm / 40L TF / <2k WeB / 67fph ReP. 03:40 - 04:10 0.50 DRILL P PROD1 Shoot survey. 04:10 - 05:00 0.83 DRILL P PROD1 Wiper trip to window. 05:00 - 05:45 0.75 DRILL P PROD1 Attempt to orient. Getting MWD noise interference. Orient 15 clicks to LHS. 05:45 - 07:30 1.75 DRILL P PROD1 Drill from 11240' to 11372'. 2.5 / 2.5 3200 psi 125 fph. (Planning mud swap around 1200 hrs) 07:30 - 08:15 0.75 DRILL P PROD1 Wiper trip 08:15 - 10:00 1.75 DRILL P PROD1 Drill ahead f/11372' to 11470'. 10:00 - 11:00 1.00 DRILL P PROD1 Wiper trip to window. Swap to Dowell pump. Replace 1 valve and seat in Nabors pump. 11:00 - 11:30 0.50 DRILL P PROD1 Orienting 11:30 - 14:00 2.50 DRILL P PROD1 Drill ahead f/11470' TO 11549'. 2.8 / 2.8 2650 psi free spin, 3200 psi on bottom. (Despite valve replacement in Nabors pump we've slowly lost off-bottom pressure this morning. Down 350 psi. Have checked all surface systems. MWD pulses good indicating no washout above MWD tool. Motor appears to be getting weaker also as stall pressures are lower by 300 psi. Swapping to new mud then plan to POH and replace motor and bleed sub.) 14:00 - 17:00 3.00 DRILL N DFAL PROD1 TOH looking for washout. 17:00 - 18:00 1.00 DRILL N DF^L PROD1 L/D BHA #5. Found washout in monel above motor. Check motor and bleed sub - ok, bit in gauge. Download resistivity. 18:00- 18:15 0.25 DRILL N DFAL PROD1 PJSM on PJU BH^#6. 18:15 - 20:45 2.50 DRILL N DFAL PROD1 Function test orienter, getting 3 for 3 & total of 60 degs. While M/U BHA #6 observed wash on MWD battery barrel (adjacent to washout point on monel). L/D and swap MWD battery barrel. Finish M/U BH^#6 (90.57') with memory resistivity tool & 1.04 ^BH motor setting. Bit to sensor offsets: D&1=27.11', GR=30.11 ', Resistivity=57.60'. 20:45 - 21:00 0.25 DRILL N DF^L PROD1 Fix pit valves. 21:00 - 23:15 2.25 DRILL N DFAL PROD1 RIH & SHT tools - OK. Continue RIH to 10360'. 23:15 - 00:00 0.75 DRILL N DF^L PROD1 Log GR tie-in. 9/8/2001 00:00 - 00:10 0.17 DRILL N DF^L PROD1 Continue logging GR tie-in (-7' correction). 00:10 - 00:45 0.58 DRILL N DFAL PROD1 RIH BHA#6. Tag top of window. Check TF, orient 11 clicks and pass thru window. 00:45 - 01:15 0.50 DRILL N DF^L PROD1 Continue RIH to btm. Bring on pumps. 01:15 - 01:30 0.25 DRILL N DFAL PROD1 Check TF & orient. 01:30 - 03:00 1.50 DRILL P PROD1 Drill from 11549' to 11615' with 2.5/2.5bpm, 3175psi freespin / 3450psi on btm / 50R TF / 2.5k WeB / 67fph ReP. 03:00 - 03:20 0.33 DRILL P PROD1 Shoot survey. 03:20 - 03:30 0.17 DRILL P PROD1 Orient 3 clicks. 03:30 - 04:15 0.75 DRILL P PROD1 Drill from 11615' to 11630' with 2.5/2.5bpm, 3150psi freespin / 3350psi on btm / 110R TF / 3.5k WeB / 40fph ReP. Occasional wt stacking. 04:15 - 05:00 0.75 DRILL P PROD1 Drill ahead to 11674' with 2.5/2.5bpm, 3175psi freespin / 3400psi on btm / 110R TF / 3k WeB / 35fph ReP. Formation sticky. 05:00 - 06:45 1.75 DRILL P PROD1 Wiper trip 06:45 - 10:45 4.00 DRILL P PROD1 Drill and orienting as needed f/11674' to 11786'. 3400 free-spin 3800 on bottom 2.7/2.7Trying to maintain +/- 45 Rtf Printed: 9/17/2001 4:26:39PM BP EXPLORATION Page 4 of 7 Operations Summa Report Legal Well Name: 7-16 Common Well Name: 7-16A Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/13/2001 Contractor Name: NABORS Rig Release: 9/13/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/8/2001 10:45 - 11:40 0.92 DRILL P PROD1 Wiper trip to window. 11:40 - 12:40 1.00 DRILL P PROD1 Orienting. Getting 1:1 clicks but very hard to hold 45R TF 12:40 - 13:45 1.08 DRILL P PROD1 Drill f/11786' to 11887'. 13:45- 15:00 1.25 DRILL P PROD1 Wipertrip 15:00 - 17:50 2.83 DRILL P PROD1 Drill f/11887' to 12015'. Holding +/- 90R TF 2.8/2.8 3775 free-spin 3900 on-bottom 17:50- 19:20 1.50 DRILL P PROD1 Wipertrip. 19:20 - 19:30 0.17 DRILL P PROD1 Shoot survey. 19:30 - 20:15 0.75 DRILL P PROD1 Drill from 12015' to 12057' with 2.5/2.5bpm, 3500psi freespin / 3650psi on btm / 130R TF / 80fph ROP. 20:15 - 20:25 0.17 DRILL P PROD1 Orient. 20:25 - 20:35 0.17 DRILL P PROD1 Drill from 12057' to 12064' with 2.5/2.5bpm, 3500psi freespin / 3650psi on btm / 40R TF / 64fph ROP. 20:35 - 20:40 0.08 DRILL P PROD1 Orient. 20:40 - 22:00 1.33 DRILL P PROD1 Drill from 12064' to 12150' with 2.5/2.5bpm, 3500psi freespin / 3650psi on btm / 70-90R TF / 63fph ave ROP. Wt stacking. 22:00 - 23:40 1.67 DRILL P PROD1 Wiper trip to window. 23:40 - 00:00 0.33 DRILL P PROD1 Drill from 12150' to 12188' with 2.5/2.5bpm, 3500psi freespin / 3650psi on btm / 90R TF / 63fph ave ROP. 9/9/2001 00:00 - 00:10 0.17 DRILL N MISC PROD1 Check Nabors pump. Motor overheated & tripped off. 00:10 - 00:22 0.20 DRILL P PROD1 Drill from 12188' to 12217' with 2.6/2.6bpm, 3550psi freespin / 3650psi on btm / 100R TF / 88fph ave ROP. 00:22 - 00:45 0.38 DRILL P PROD1 Short trip to allow pump motor cool down. 00:45 - 01:30 0.75 DRILL P PROD1 Drill from 12217' to 12240' with 2.6/2.6bpm, 3500psi freespin / 3650psi on btm / 100R TF / 130fph ave ROP. 01:30 - 01:35 0.08 DRILL P PROD1 Orient 1 click. 01:35 - 02:40 1.08 DRILL P PROD1 Drill from 12240' to 12286' with 2.5/2.5bpm, 3500psi freespin / 3700psi on btm / 105R TF / 50fph ave ROP. Aiming for 8856ftvd @ +/-12400' (proposed TD). 02:40 - 04:15 1.58 DRILL P PROD1 Wiper trip to window. 04:15 - 05:15 1.00 DRILL P PROD1 Drill from 12286' to 12320' with 2.5/2.5bpm, 3500psi freespin / 3650psi on btm / 105R TF / 35fph ave ROP. Wt stacking & hole getting tight. P/U with 20k O/P. 05:15 - 06:00 0.75 DRILL P PROD1 Shoot survey & short trip. Project 92.17 deg & 8856.92ftvd @ 12320'. Geologist decide to drill on & attempt to steer hole down. 06:00 - 06:15 0.25 DRILL P PROD1 Drill f/12320' to 12345'. TD 06:15 - 06:45 0.50 DRILL P PROD1 Survey at 12309' 06:45 - 07:20 0.58 DRILL P PROD1 Wiper trip to window. 07:20 - 10:20 3.00 DRILL P PROD1 Log tie-in. First pass was started too Iow. +22' correction. Revised TD = 12368'. 10:20 - 12:45 2.42 DRILL P PROD1 Wiper trip back to bottom and round trip again. 12:45 - 16:00 3.25 DRILL P :PROD1 TOH laying in 1:1 new FIo-Pro in the openhole 16:00 - 17:30 1.50 DRILL P :PROD1 L/D BHA #6. Set injector on deck. 17:30 - 18:00 0.50 CASE P COMP Rig up floor to run liner. 18:00 - 18:20 0.33 CASE P COMP Crew change. PJSM concerning procedures and plans for running liner. 18:20 - 19:00 0.67 CASE P COMP Continue rigging tools for liner. 19:00 - 23:00 4.00 CASE P COMP M/U & RIH 55 jts +2 pup jts of 2-7/8", 6.16#, L-80 STL liner X/over to 4 jts of 3-3/16", 6.2# L-80 TCII liner X/over to 29 jts of 3-1/2", 8.81#, L-80 FL4S liner and jewelry as per program. 23:00 - 23:15 0.25 CASE P COMP MU CTLRT with disconnect/swivel & deployment sleeve. 23:15 - 00:00 0.75 CASE P COMP R/U & pig / pump dart through coil. Printed: 9/17/2001 4:26:39 PM BP EXPLORATION Page 5 of 7 Operations Summa Report Legal Well Name: 7-16 Common Well Name: 7-16A Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/13/2001 Contractor Name: NABORS Rig Release: 9/13/2001 Rig Name: NABORS 3S Rig Number: Date From -To Hours Activity:Code NPT Phase Description of Operations 9/10/2001 00:00 - 00:30 0.50 CASE P COMP Continue pumping dart through coil. Recovered worn dart after 55.1 bbls pumped. 00:30 - 01:15 0.75 CASE P COMP Cut off CTC and install Baker slip type connector. Pull test same to 40000 lbs and pressure test to 3500 psi - OK. M/U coil to CTLRT. 01:15 - 01:45 0.50 CASE P COMP Circulate and fill liner. 01:45 - 04:45 3.00 CASE P COMP RIH liner assy BHA#7 @ 100 fpm pumping @ 0.40bpm/1250psi. RIH thru window @ 50 fpm - no bobbles. Continue RIH & tag TD @ 12363'. Up wt - 55k & down wt = 14k. 04:45 - 05:30 0.75 CASE P COMP Drop 5/8" ball and pump down @ 2.6bpm/2700psi. Slow down to 0.3bpm/1000psi @ 40 bbls. Ball on seat @ 41.9bbls. Pressure up to 3700psi & shear out ball. P/U @ 39k confiming release & wt loss of 16k. TOL @ 9524'. PBTD @ 12334'. Will correct w/memory log. 05:30 - 08:50 3.33 CASE P COMP Displace well to 2% KCI at 2.6bpm & 2550psi. Final rates after displacment to KCL were 2.7 in 2.5 out. Same time R/U Dowell cementers. 08:50 - 09:10 0.33 CASE P COMP PJSM with all crews concerning cementing operations. 09:10 - 10:45 1.58 CASE P COMP Batch mix 27 bbls 15.8ppg cmt with additives. PT lines to 5k. Start cement, pumped 24.5 bbls (pumped 1.5 bbls more than calculated vol due to hole losses). Close inner reel valve and clean lines. Load and launch CTWP, confirm launch. Pumped 25 bbls KCL w/2# bio then 30 bbl KCL CTWP engaged LWP at 54.8 bbl away, continue displ, LWP bumped at 73.8 bbl away (74.2 calculated) - floats held. Pressure up to 1000 psi and sting out of liner. Wash-up on top of liner with 5 bbl bio then TOH. CIP at 1038 hrs. 10:45 - 13:15 2.50 CASE P COMP TOH f/CNL 13:15 - 13:30 0.25 CASE P COMP LID LRT BHA#7 13:30 - 13:45 0.25 EVAL P COMP PJSM on p/u 1 1/4" CHS tbg and CNL tools. 13:45 - 18:10 4.42 EVAL P COMP P/U BHA #8 (2910.02') w/90 jts. 1 1/4" CSH tbg. P/U injector. (Called AOGCC. Talked to Jeff Jones and received 1 day extension for BOP testing) 18:10 - 21:45 3.58 EVAL P COMP TIH w/BHA #8. 21:45 - 23:45 2.00 EVAL P COMP Start logging down MCNL/GR/CCL @ 30fpm from 9400' to PBTD (tagged @ 12322'). Lay-in new 100k LSRV FIo-Pro while logging up to 9400'. 23:45 - 00:00 0.25 EVAL P COMP POOH logging BHA #8. 9/11/2001 00:00 ~ 01:30 1.50 EVAL P COMP Continue POOH logging BHA#8. 01:30 - 05:00 3.50 EVAL P COMP Rack back 90 jts of 1-1/4" CS Hydril & L/D logging tool. Attempt to download MCNL/GR/CCL data. Observe that logging tool quit data acquisition from 10150' & recorded flat lines while logging down. Tool battery found OK. Suspect tool failure. Discuss with town Geologist & decide to proceed with BOP testing & decide whether or not to relog. 05:00 - 06:00 1.00 EVAL P COMP Line up to & test liner lap. Compressive strength of cement @ 05:00 was 3000 psi. I/A 150 psi, & O/A 0 psi @ onset of test. Staged up in 500 psi intervals, monitoring I/A & O/A. PT @ 2000 psi, leaked 80 psi in 30 rain, no change in inner or outer annulus pressures thoughout test. 06:00 - 16:30 10.50 EV^L P COMP Install test valve in wellhead. Testing BOPE. Shutdown operations briefly to observe current national events. Review Printed: 9/17/2001 4:26:39PM BP EXPLORATION Page 6 of 7 Operations Summa Report Legal Well Name: 7-16 Common Well Name: 7-16A Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/13/2001 Contractor Name: NABORS Rig Release: 9/13/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/11/2001 06:00 - 16:30 10.50 EVAL P 'COMP safety concerns for continuation of testing operations. Resume and finish testing BOPE. 16:30 - 17:00 0.50 EVAL P COMP Pull test plug. 17:00 - 18:00 1.00 EVAL N DFAL COMP P/U BHA #9 w/MCNL/GPJCCL. ;18:00 - 20:45 2.75 EVAL N DFAL COMP M/U & RIH logging tools on 90 jts of 1-1/4" CSH tbg. M/U injector. ~20:45 - 21:30 0.75 EVAL P COMP Pressure test HP hard lines and inner reel valve. 21:30 - 23:45 2.25 EVAL N DFAL COMP RIH w/logging BHA #9. 23:45 - 00:00 0.25 EVAL N DFAL COMP Start logging down MCNL/GR/CCL @ 30fpm from 9400'. 9/12/2001 00:00 - 02:00 2.00 EVAL N DFAL COMP CONTINUE LOGGING DOWN MCNL/GR/CCL @ 30FPM TO PBTD. LOG UP TO 9500'. 02:00 - 03:35 1.58 EVAL N DFAL COMP POH W/BHA #9 03:35 - 06:00 2.42 EVAL N DFAL COMP RACK BACK 90 JTS OF 1 1/4" CS HYDRIL AND L/D LOGGING TOOLS. 06:00 - 07:30 1.50 EVAL P COMP DOWNLOAD MCNL/GR/CCL LOG DATA - GOOD DATA OBTAINED. TOL CONFIRMED @ 9517' & PBTD @ 12322'. FAXED LOG DATA TO TOWN. WAITING ON REPLY. RECEIVED REVISED PERF PROGRAM. SCHLUMBERGER LOADING PARTIALS. 07:30 - 11:30 4.00 PERF P COMP WO PERF GUNS F/SCHL 11:30 - 12:00 0.50 PERF P COMP UNLOAD PERF GUNS. 12:00 - 12:30 0.50 PERF P COMP PJSM ON PICKING UP PERF GUNS. 12:30- 16:40 4.17 PERF P COMP M/U BHA # 10 16:40 - 17:15 0.58 PERF P COMP P/U INJECTOR AND STAB-ON WELL. 17:15 - 19:15 2.00 PERF P COMP RIH W/PERF GUNS. TAG PBTD @ 12323'. 19:15 - 21:30 2.25 PERF P COMP LOAD 5/8" BALL & ClRC DOWN WHILE POSITIONING GUNS FOR BOTTOM SHOT AT 12280'. PUMP BALL TO SEAT @ 2.TBPM/3700PSl. SLOW DOWN TO 0.8BPM/650PSl @ 48BBLS. BALL ON SEAT @ 59 BBLS AWAY. 21:30 - 21:40 0.17 PERF P COMP PRESSURE UP TO 3490PSI & OBSERVE FIRING HEAD FIRE GUNS. PERF INTERVALS: 11360'-11560', 11610'-11960.68' AND 12030'-12280'. 21:40 - 22:05 0.42 PERF P COMP POOH WITH PERF BHA #10 TO 3821' FILLING & MONITORING WELL. WELL RELATIVELY STABLE. 22:05 - 00:00 1.92 PERF P COMP LID 1-1/4" CS HYDRIL TUBING WORK STRING. 9/13/2001 00:00 - 02:00 2.00 PERF P COMP CONTINUE LID 1-1/4" CS HYDRIL TUBING WORK STRING. 02:00 - 02:15 0.25 PERF P COMP PJSM ON L/D PERF GUNS. EMPHASIS ON COMMUNICATION & REVIEW WELL CONTROL PROCEDURE. 02:15 - 02:30 0.25 PERF P COMP FILL WELL WITH 4 BBLS KCL WATER. 02:30 - 06:00 3.50 PERF P COMP L/D 44 GUN JTS. ASF. 06:00 - 07:00 1.00 PERF P COMP CREW CHANGE AND TOUR SAFETY MEETING. PREP TO FP WELL. 07:00 - 08:15 1.25 DEMOB P COMP P/U INJECTOR. M/U BHA TO FP. PRESSURE TEST LINES AT HP FILTERS THAT WERE WORKED ON LASTNIGHT. 08:15 - 09:30 1.25 DEMOB P COMP RIH TO 2000' FP WELL WITH 43 BBL CRUDE F/2000' TO SURFACE. CLEAN OUT STACK WITH DIESEL FOLLOWED BY KCL TO TT. 09:30 - 17:00 7.50 DEMOB P COMP RID DOWELL CTU#4. WILL GO TO DEADHORSE FOR ROUTINE MAINTENENCE AND REPLACE INJECTOR WITH THE REPAIRED INJECTOR TAKEN OFF EARILIER LAST WEEK. N/D BOP'S AND INSTALL TREE CAP TEST TO 4500 PSI Printed: 9/17/2001 4:26:39PM BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: 7-16 Common Well Name: 7-16A Spud Date: Event Name: REENTER+COMPLETE Start: 9/2/2001 End: 9/13/2001 Contractor Name: NABORS Rig Release: 9/13/2001 ,Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/13/2001 17:00 - 0.00 DEMOB P COMP RIG RELEASEDAT 1700 HRS 9-13-2001 MOVEINGTO DS 15 #36A Printed: 9/17/2001 4:26:39 PM ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration Field .................... : Prudhoe Bay Well ..................... : 07-16a API number ............... : 50-029-20856-01 Engineer ................. : M. Brown COUNTY: .................. : Nabors 3S / Dowell # 4 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference -- Permanent datum .......... : Mean Sea Level Depth reference .......... : GR Tie-in @ 10352 ft GL above permanent ....... : -50000.00 ft KB above permanent ....... : -50000.00 ft DF above permanent ....... : -50000.00 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 343.50 degrees 10-Sep-2001 10:06:10 Page 1 of 3 Spud date ................ : 05-Sep-01 Last survey date ......... : 09-Sep-01 Total accepted surveys...: 49 MD of first survey ....... : 10400.00 ft MD of last survey ........ : 12368.00 ft Geomagnetic data -- Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 03-Sep-2001 Magnetic field strength..: 1149.70 HCNT Magnetic dec (+E/W-) ..... : 26.62 degrees Magnetic dip ............. : 80.78 degrees MWD survey Reference Criteria · Reference G ............... 1002.68 mGal Reference H ............... 1149.70 HCNT Reference Dip ............. 80.78 degrees Tolerance of G ............ (+/-) 2.50 mGal Tolerance of H ............ (+/-) 6.00 HCNT Tolerance of Dip .......... (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 26.62 degrees Grid convergence (+E/W-) .: 0.00 degrees Total az corr (+E/W-) .... : 26.62 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_IC_10] ANADRILL SCHLUMBERGER Survey Report 10-Sep-2001 10:06:10 Page 2 of 3 ~ Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) Course TVD Vertical Displ Displ Total length depth section +N/S- +E/W- displ (ft) (ft) (ft) (ft) (ft) (ft) At DLS Srvy Tool Azim (deg/ tool qual (deg) I00f) type type 1 10400.00 32.90 24.50 2 10500.00 32.10 22.30 3 10523.20 40.29 19.71 4 10555.18 50.49 16.15 5 10574.93 57.66 13.95 0.00 100.00 23.20 31.98 19.75 8712.25 8796.59 8815.30 8837.73 8849.31 3418.48 4097.10 1795.30 4473.18 3459.69 4146.40 1816.65 4526.90 3470.57 4159.19 1821.52 4540.57 3489.35 4180.83 1828.46 4563.18 3502.97 4196.27 1832.60 4578.98 23.66 0.00 TIP 23.66 1.43 MWD 23.65 35.90 MWD 23.62 32.86 MWD 23.59 37.40 MWD 6 7 8 9 10 10606.20 68.32 10.47 31.27 8863.50 10625.05 73.15 8.37 18.85 8869.72 10655.37 78.38 359.05 30.32 8877.19 10685.19 81.65 356.52 29.82 8882.36 10719.47 86.35 354.67 34.28 8885.94 3527.39 4223.46 1838.44 4606.24 3543.39 4241.01 1841.35 4623.50 3570.93 4270.29 1843.22 4651.11 3599.39 4299.63 1842.08 4677.61 3632.71 4333.61 1839.46 4707.84 23.52 35.50 23.47 27.70 23.35 34.40 23.19 13.81 23.00 14.72 MWD MWD SP SP SP 11 12 13 14 15 10749.34 89.90 353.75 29.87 8886.92 10780.77 93.28 352.70 31.43 8886.05 10808.48 91.25 349.45 27.71 8884.95 10838.36 88.95 346.77 29.88 8884.90 10888.56 87.55 341.25 50.20 8886.43 3662.04 4363.31 1836.45 4734.02 3693.00 4394.50 1832.74 4761.36 3720.45 4421.85 1828.44 4784.97 3750.22 4451.08 1822.29 4809.66 3800.38 4499.30 1808.47 4849.15 22.83 12.29 22.64 11.25 22.47 13.82 22.26 11.82 21.90 11.36 SP SP SP SP SP 16 17 18 19 20 21 22 23 24 25 10929.00 85.68 339.37 40.44 8888.82 10971.82 88.80 337.57 42.82 8890.88 10990.58 90.68 338.30 18.76 8890.97 11014.80 91.48 339.88 24.22 8890.51 11055.49 91.28 344.32 40.69 8889.53 11098.37 89.53 342.02 42.88 11138.60 87.35 340.15 40.23 11178.00 88.00 337.40 39.40 11203.68 89.85 335.25 25.68 11249.06 91.63 331.95 45.38 8889.23 8890.33 8891.92 8892.41 8891.82 3840.68 4537.30 1794.86 4879.41 3883.28 4577.08 1779.17 4910.71 3901.95 4594.46 1772.12 4924.38 3926.09 4617.08 1763.48 4942.40 3966.75 4655.78 1750.98 4974.16 4009.62 4696.82 1738.57 5008.27 4049.80 4734.86 1725.53 5039.48 4089.03 4771.55 1711.28 5069.14 4114.50 4795.07 1700.97 5087.83 4159.19 4835.70 1680.80 5119.48 21.58 6.53 SP 21.24 8.41 SP 21.09 10.75 MWD 20.90 7.31 SP 20.61 10.92 SP 20.31 6.74 SP 20.02 7.14 SP 19.73 7.17 MWD 19.53 11.04 SP 19.17 8.26 SP 6 -axis -- 26 27 28 29 3O 11285.00 90.45 329.45 35.94 11323.53 90.85 327.80 38.53 11385.62 88.85 322.07 62.09 11421.00 88.30 319.00 35.38 11453.88 89.70 315.52 32.88 8891.17 8890.73 8890.89 8891.77 8892.35 4194.23 4867.04 1663.22 5143.38 4231.46 4899.93 1643.16 5168.10 4290.30 4950.73 1607.50 5205.17 4322.86 4978.03 1585.03 5224.28 4352.34 5002.17 1562.72 5240.59 18.87 7.69 18.54 4.41 17.99 9.77 17.66 8.81 17.35 11.41 MWD SP SP MWD SP ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 31 11483.31 89.55 312.47 32 11515.00 89.04 310.00 33 11553.74 89.05 307.92 34 11587.20 92.73 309.85 35 11642.77 91.45 314.45 36 11701.08 89.83 318.67 37 11751.18 92.65 320.57 38 11785.50 97.18 324.65 39 11853.70 94.60 332.39 40 11923.70 94.90 339.30 41 11974.03 93.03 343.90 42 12000.00 92.60 345.70 43 12063.00 91.40 353.90 44 12116.23 92.01 357.99 45 12161.00 91.80 2.70 46 12229.47 91.88 8.26 47 12265.00 93.50 11.40 48 12333.47 92.43 18.00 49 12368.00 92.43 18.00 29.43 31.69 38.74 33.46 55.57 58.31 50.10 34.32 68.20 70.00 10-Sep-2001 10:06:10 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 8892.54 8892.93 8893.57 8893.06 8891.04 4377.95 5022.61 1541.55 5253.85 4404.74 5043.49 1517.72 5266.91 4436.65 5067.85 1487.60 5281.67 4464.18 5088.85 1461.57 5294.58 4511.59 5126.10 1420.41 5319.26 4563.55 5168.43 1380.33 5349.57 4609.35 5206.58 1347.88 5378.22 4641.28 5233.73 1327.13 5399.37 4706.76 5291.54 1291.74 5446.93 4775.85 5355.15 1263.21 5502.12 8890.38 8889.30 8886.36 8879.35 8873.55 17.06 16.75 16.36 16.02 15.49 14 . 95 14.51 14.23 13.72 13.27 50.33 8870.06 4826.02 5402.78 1247.37 5544.91 13.00 25.97 8868.79 4851.95 5427.81 1240.57 5567.78 12.87 63.00 8866.59 4914.48 5489.72 1229.43 5625.71 12.62 53.23 8865.00 4966.42 5542.79 1225.67 5676.68 12.47 44.77 8863.51 5009.23 5587.52 1225.94 5720.43 12.37 68.47 8861.31 5072.67 5655.61 1232.47 5788.34 12.29 35.53 8859.65 5104.47 5690.58 1238.53 5823.80 12.28 68.47 8856.10 5162.93 5756.68 1255.87 5892.08 12.31 34.53 8854.64 5191.36 5789.49 1266.53 5926.41 12.34 3 of 3 DLS (deg/ 100f) 10.38 7.96 5.37 12.39 8.58 7.75 6.79 17.73 11.91 9.85 9.85 7.12 13 . 15 7.77 10.53 8.12 9.94 9.75 0.00 Srvy tool type SP MWD MWD SP SP SP SP SP MWD SP SP MWD MWD SP MWD SP MWD MWD MWD Tool qual type 6-axis -- -- -- -- 6 -axis -- 6-axis -- -- -- [(c)2001 Anadrill IDEAL ID6 lC 10] bp Date: 10-01-2001 Transmittal Number:92263 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-40'~ 1. Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type DS01-04A 08-29-2001 ANADRILL I 9100 10640 SURVEY REPORT/HARDCOPY (2EA) SURVEY REPORT/DISKETTE (1EA) 07-16A 09-10-2001 ANADRILL 1 10400 12368 SURVEY REPORT/HARDCOPY (2EA) SURVEY REPORT/DISKETTE (1EA) S-17B 08-17-2001 ANADRILL 1 9462 10445 SURVEY REPORT/HARDCOPY (2EA) 'SURVEY REPORT/DISKETTE (lEA) Please Sign and Retu~r~ one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Lisa Weepie (AOGCC) Attn: Sandy Lemke (Phillips Alaska) Attn: Susan Nisbet (Exxon Mobil Production) RECEIVED OCT 0 4 ?.001 Alaska Oil & Gas Cons, Commiesion Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 ALASKA OIL AN~D GAS CO~SERYATIO~ COMMISSIO~ TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re; Prudhoe Bay Unit 07-16A BP Exploration (Alaska) Inc. Permit No: 201-153 Sur Loc: 1127' SNL, 534' EWL, SEC. 34, T1 IN, R14E, UM Btmhole Loc. 4735' NSL, 1817' EWL, SEC. 27, T1 IN, R14E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 07-16A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Julie M. Heusser Commissioner · BY ORDER OF THE COMMISSION DATED this ~0~--~' day of August, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. K~( STATE OF ALASKA IVI~'. ALAS OILAND GAS CONSERVATION CO ...~SION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work [] Drill [] RedriU 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI I-I Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator' 5. Datum Elevation (DF or KB) 10. Fiel(J and Pool BP Exploration (Alaska) Inc. RKB - 58' Prudhoe Bay Field / Prudhoe ,,, 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028309 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1127' SNL, 534' EWL, SEC. 34, T11 N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 2768' NSL, 2240' EWL, SEC. 27, T11N, R14E, UM 07-16A Number 2S100302630-277 At total depth 9. Approximate spud date 4735' NSL, 1817' EWL, SEC. 27, T11 N, R14E, UM 09/15/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028306, 543' MDI No Close Approach 2560 12400' MD / 8870' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} o Kick Off Depth 10500' MD Maximum Hole Angle 92 Maximum surface 2194 psig, At total depth (TVD) 8800' / 3250 psig 18. Casing Program Specifications Setting Depth Size Top Bolt0m Quantity of Cement Hole Casinq Weiqht Grade Couplin,q Lenqth MD TVD MD TVD (include staqe data) 3-3/4" 3-1/2"x 2-7/8" 9.3 / 6.16# L-80 ST-L 2840' 9560' 8029' 12400' 8870' 98 sx Class 'G' , iii ~'~ __ i ,i .i ,i i i i .....,,,~ , i .................. i i , i,i ,i i i ,il i i i . i i ,i ,i ................................................... 19. TO be completed for Redrill, Re-entr~/, and Deepen Operations. UJ Present well condition summary Total depth: measured 10700 feet Plugs (measured) Top of Cement Plug at 10507' (05/98)~,,) true vertical 9025 feet LL~ '-~ Effective depth: measured 10507 feet Junk (measured) true vertical 8861 feet Casing Length Size Cemented MD TVD Structural Conductor 79' 20" 1900# Poleset 79' 79' Surface 2429' 13-3/8" 1650 sx Fondu, 400 sx Permafrost 'C' 2487' 2485' Intermediate Production 9789' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' 9847' 8315' Liner 1167' 7" 350 sx Class 'G' 9533' - 10700' 8065' - 9025' Perforation depth: measured Open: 10462' - 10472' Open but isolated below Cement / Sand Plug: 10506' - 10646' true vertical Open: 8822'- 8831' Open but isolated below Cement / Sand Plug: 8860' - 8979' 20. Attachments' [] Filing'Fee ' " [] Pr(~perty Plat ' '[] BOP'~ketch ...... I-I D'ivert~r Sketch' []' D~illing 15ro'g~am [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Co~taci Engineer Nam~/Nurn'ber: ' 'Th~rn~ 'Mcb~rty, 564'5697 ....................... Pre'pare~ BYN'ame/Numb'er:" Terrie Hubble1564:4628 '21 ."'i' 'h'er~by'certify that t_.he'foregoing' is tru~ '~n'd c0r~'ect' to'the best '~f rny kn'~led'ge ........................ Signed ThomasUcCarty//' ,~'~-,¢'~',~'~--"~"~ Title CT Drilling Engineer Date Permit Number I APl Number ] Approval Date I See cover letter ~__o? -- ,/'.~'~ 50-029-20856-01 , , ~'~ .~'J'~ i for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log'Rec~uired [] Yes [] No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required ~ Yes [] No Required Working Pressure forBOPE []2K []3K []4K []5K []10K []15K J~.5KpsiforCTU Other: by order of ,,~/~.~/ Approved By EiRI~INA~ ~l~i=li~ R¥ Commissioner the commission Date Form 10-401 Rev. 12-01-85 J, M; Heu~)~,....,,~ t~.~\ ! G I N A L = plicate BPX 07-16A Sidetrack Summary of Operations: A CTD sidetrack of well 07-16 will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Isolate & integrity test inner annulus, (IA). Drift/caliper liner and set whipstock. Mill window if service coil is available. Planned for August 10, 2001 · Well Drifted with dummy whipstock to 10477' SLM 6/23/01 and liner callipered from10453' SLM 6/24/01. · Integrity test IA performed 6/15/01after displacing to seawater & installing dummy gas lift valves. · Underream cement to 10522'. · Set through tubing whipstock using e-line at approx. 10,497' (top of whipstock). · Mill window with service coil if available. Phase 2: Drill and Complete CTD sidetrack: Planned for September 15, 2001 2-3/8" coil will be used to drill a -1900 foot, 3-3/~'' open hole sidetrack, (as per attached plan) and run a solid, cemented & perforated 3-1/2" x 2-7/8" liner completion. Mud Program: · Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 3-1/2", L-80, solid liner will be run from 9560'md (TOL, 8029 TVDss) to approx. 10560'md and then crossed over to 2- 7/8",L-80, solid liner to TD at approx 12,400'md. Liner will be cemented in place with approximately 20bbls (annular volume plus 25% excess in OH) of 15.8 ppg class G cement. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2200 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray + Resistivity log will be run over the open hole section. · Memory CNL will be run in the cased hole after reaching TD. Hazards H2S was measured at 0 ppm on February 11, 1998. Assume H2S less than 10 ppm. The well-path will cross 0 mapped faults. The risk of lost circulation events has been judged as Iow, however trajectory is fairly constrained between faulting both to the East and West. Reservoir Pressure Res. press, is estimated to be 3250 psi at 8800ss. Max. surface pressure with gas (0.12 psi/fi) to surface is 2194 psi. TREE= GRAY WR LHEAD= GRAY ACTUATOR= AXFI SON KB. ELEV = 58' BF. ELEV = KOP = 3000' M~ Angle = 49 @ 8600" Datum MD = 10504' DatUm TVD= 8800' SS 13-3/8" CSG, 72#, L-80 BTRS, ID: 12.347" H 2487' IMinimum D = 3.812" @ 9570' 4-1/2" CAM DB-6 LANDHG NIP 5-11Z' TBG-PC, 17#, L-80 8RD, .0232 bpf, ID=4.892" H 9478' ITOPOF 4-1/2" TBG H 9510' 19-5/8"X 7"LNRTOPPKR/HGRW/TIEBACKSLV H 9533' 4-1/2" TBG-PC, 12.6#, L-80 BTRS, .0152 bpf, ID = 3.958" I"~ 9581' 19-5/8"CSG, 47#,L-80BTRS, ID=8.681" I"'~ 9847' FERFORATION SUMMARY RI~' LOG: BHCS on 12/1/1982 ANGLE AT TOP PERF: 32 @ 10462' Note: Refer tD Production DB for historical )erf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10462- 10472 O 05/07/98 3-1/2" 4 10462 - 10472 O 05/30/98 3-1/2" 4 10462 - 10472 O 05/30/98 1-11/16" 4 10506- 10546 S 10/08/83 1-11/16" 4 10556 - 10583 S 10/08/83 3-3/8" 1 10572 - 10578 S 05/01/89 3-3/8" 1 10578 - 10583 S 05/01/89 3-3/8" 6 10598 - 10606 S 05/01/89 1-11/16" 4 10606 - 10624 S 10/08/83 I FBTD H 10681' 7" LNR, 29#, L-80BTRS,.0371 bpf, ID =6.184" H 10700' 07-16 SAFETY NOTES 2202' H5-1/Z' CAM BAL-OSSSV I~P, ID =4.56Z' J GAS LIFT MANDRELS ST IVD TVD DEV TYPE VLV LATCH SIZE DATE I 2894 2889 6 IVlVlIG RK 1-1/2.' 2 5013 :4688 40 IVlt, IlG RK 1-1/2.' 3 6619 5918 40 IVlVlIG RK 1-1/2.' 4 7755 6780 43 rVlVIIG RK 1-1/2.' 5 8444 7266 47 IVlVIIG RK 1-1/2.' 6 8515 7314 48 MVlIG RK 1-1/2'' 7 8979 7634 42 rvfvllG RK 1-1/2'' 8 9046 7684 42 rVlVIIG RK 1-1/2'' 9 9314 7892 39 rvlVIIG RK 1-1/2'' 10 9381 7945 38 FvlVIIG RKP 1-1/2'' 9482' J--~5-1/2" BAKER PBR ASSY J 9497' J--~9-5/8" X5-1/2" BKR'SAB'PKR, ID= 3.875" J 9soe' J-15-1/z' x 4-1/2" xo, ID = 3.958" J 9570' I--~ 4-1/2.' CAM DB-6 LANDING NIP, ID= 3.812" 9582' 19572. I-~4-1/2.' TUBING TAIL (BOT SOS) DATE ~ BY COMIVENTS DATE REV BY COMMENTS 12/05/82 ORIGINAL COMFLEDION 01/10/01 SIS-SLT CONVERTEDTOCANVAS 02/09/01 SIS-LG REVISION 05/29/01 CH/tlh CORRECTIONS PRUDHOE BAY UNIT WELL: 07-16 PERMIT No: 82-182 APl No: 50-029-20856-00 Sec. 34, T11N, R14E, 1127' FNL, 534'FWL BP Exploration (Alaska) WELLHEAD: GRAY ACTUATOR= AXELSON "KBi"~'~ 58' ~'~ngi~'= 49 ~ ................................................. ~tum MD = 10504' ~tum ~D= 8800' SS 07-16A ( I ~^..~NO~S PROPOSED CTD SIDETRACK 13-3/8" CSG, 72#, L-80 BTRS, ID: 12.347" I--J 2487' IMinimum ID = 3.812" @ 9570' 4-1/2" CAM DB-6 LANDING NIP 5-1/2" TBG-PC, 17#, L-80 8RD, .0232 bpf, ID = 4.892" Id 9478' ITOPOF 4-1/2" TBG Id 9510' 19-5/8"X 7" LNR TOP PKP,/HGR W/ TIEBACK SLV ]--J 9533' 2202' Id5-1/2"CAMBAL-OSSSV NIP, ID=4.562" I 4-1/2" TBG-PC, 12.6#, L-80 BTRS, .0152 bpf, ID= 3.958" Id 9581' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 1 2894 2889 6 MMIG RK 1-1/2" 2 5013 4688 40 MMIG RK 1-1/2" 3 6619. 5918 40 MMIG RK 1-1/2" 4 7755 6780 43 MMIG RK 1-1/2" 5 8444 7266 47 MMIG RK 1-1/2" 6 8515 7314 48 MMIG RK 1-1/2" 7 8979 7634 42 MMIG RK 1-1/2" 8 9046 7684 42 MMIG RK 1-1/2" 9 9314 7892 39 MMIG RK '1-1/2" 10 9381 7945 38 MMIG RKP 1-1/2" 9482' 9497' 9509' I--{5-1/2" BAKER PBRASSY I I--~9-5/8" X 5-1/2" BKR'SAB' FKR, ID= 3.875" Id 5-1/2" X 4-1/2" XO, ID= 3.958" 9560' 9570' 9582' IdTop of Proposed 3-1/2" Liner I Id4-1/2" CAM DB-6 LANDING NIP, ID= 3.812" I Id 4-1/2" TUBING TAIL (BOT SOS) I 9572' I-'J ~'MD I I 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" Id 9847' (Peff's to be P&A'd pdor to Sidetrack) [ 10300' J--J Top of Cement J PERFORATION SUMMARY REF LOG: BHCS on 12/1/1982 ANGLE AT TOP PERF: 32 @ 10462' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10462 - 10472 O 05/07/98 3-1/2" 4 10462- 10472 O 05/30/98 3-1/2" 4 10462- 10472 O 05/30/98 1-11/16"I 4 10506- 10546 S 10/08/83 1-11/16": 4 10556- 10583 S 10/08/83 3-3/8" 1 10572- 10578 S 05/01/89 3-3/8" 1 10578- 10583 S 05/01/89 3-3/8" 6 10598- 10606 S 05/01/89 1-11/16" 4 10606 - 10624 S 10/08/83 ..~ ~osoo' I---I Mill Window off Mechanical Whipstock 3_~/~,, × ~.~/8,, ×0I 13-3/4'' HoleJ 'J 10520' I--I u~ c~,,.~,~, I J2-7,'8" Liner. Cemented & Perr'd J~ 12400' J 7" LNR, 29#, L-80 BTRS, .0371 bpf, ID=6.184" J--J 10700' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/05/82 ORIGINAL COMPLETION 01/10/01 SlS-SLT CONVERTEDTO CANVAS 02/09/01 SIS-LG REVISION 05/29/01 CH/tlh CORRECTIONS 06/08/01 pcr 07-16A proposed ST PRUDHOE BAY UNIT WELL: 07-16A Proposas PERMIT No: 182-182 APl No: 50-029-20856-01 Sec. 34, T11N, R14E, 1127' FNL, 534' FWL BP Exploration (Alaska) ObP BP Amoco Baker Hughes INTEQ Planning Report Company: BP Amoco Date: 6/15/2001 Time: 14:56:15 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07-16, True North Site: PB DS 07 Vertical (TVD) Reference: System: Mean Sea Level Well: 07-16 Section CVS) Reference: Well (0.00N,0.OOE,345.00Azi) Wellpath: Plan#307-16A Snr~ey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2001 Site: PB DS 07 TR-11-14 UNITED STATES * North Slope Site Position: Northing: 5948144.78 ft Latitude: 70 15 49.847 N From: Map Easting: 677382.28 ft Longitude: 148 33 56.934 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: ~;.00 ff Gri_d_.Co_nve.rg_e_nce: 1.35.. deg Well Position:Well': ....... {~:07-161'6+E/-w+N/-S 1680.35_609.81 ftft Northing:Easting: 5949810.19676733.09 ftft~i;~-~;~;':Longitude:Latitude: .............................. 14870 34i"~1614.6846'373 wN P°sitio" _vncerta!nty! ................. OLO0_ ff Wellpath: Plan#3 07-16A Drilled From: 07-16 500292085601 Tie-on Depth: 10500.00 ft Current Datum: 26 · 1611/16/198200:00 Height 58.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/15/2001 Declination: 26.70 deg Field Strength: 57497 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ff ft deg 0.00 0.00 0.00 345.00 Plan: Plan #3 Date Composed: 6/15/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets 07-16AT3.1 8895.00 4500.61 1723.89 5954349.74 678350.72 70 1650.634 N 148 3324.475 W 07-16AT3.2 8875.00 5208.73 1390.51 5955049.80 678000.84 70 1657.599 N 148 3334.181 W 07-16AT3.3@TD 8870.00 5959.75 1358.26 5955799.80 677950.96 70 17 4.985 N 148 33 35.116 W Annotation ff =' 10400.00 8712,25 TIP 10500.00 8796.59 FOP 10515.00 8809.20 1 10681.86 8892,65 2 10735.05 8894.97 3 10835.05 8894.21 4 11335.05 8880.42 5 11683.86 8873.86 6 11958.86 8872.73 7 12400.00 8869.52 TD Obp BP Amoco Baker Hughes INTEQ Planning Report I~TEQ Company: BP Amoco Date: 611512001 Time: 14:56:15 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07-16, True North Site: PB DS 07 Vertical (TVD) Reference: System: Mean Sea Level Well: 07-16 Section (VS) Reference: Well (0.00N,0.00E,345.00Azi) Wellpath: Plan~L3 07-16A Surwey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 10400.00 32.90 24.50 8712.25 4097.06 1795.29 0.00 0.00 0.00 0.00 10500.00 32.10 22.30 8796.59 4146.36 1816.64 1.43 -0.80 -2.20 234.99 10515.00 33.41 20.94 8809.20 4153.90 1819.63 10.00 8.71 -9.08 330.00 10681.86 85.00 356.64 8892.65 4290.45 1832.15 33.00 30.92 -14.56 330.00 10735.05 90.00 354.82 8894.97 4343.42 1828.20 10.00 9.40 -3.42 340.00 10835.05 90.87 4.79 8894.21 4443.29 1827.86 10.00 0.87 9.96 85.00 11335.05 92.09 314.78 8880.42 4897.58 1660.64 10.00 0.24 -10.00 272.00 11683.86 90.00 349.61 8873.86 5201.34 1500.50 10.00 -0.60 9.98 93.00 11958.86 90.46 322.11 8872.73 5449.89 1389.12 10.00 0.17 -10.00 271.00 12400.00 90.33 6.23 8869.52 5863.88 1271.74 10.00 -0.03 10.00 90.00 Survey ............ 7 .................................... : ........................................... :-'-'~ ......... , ..................................................... ~ ............ -~ 'MD Inei Azim SSTVD N/S E/W MapN , MapE DLS VS TFO Tool ft deg deg ft ft ~ ft · ft deg/100ft ft deg 10400.00 32.90 24.50 8712.25 4097.06 1795.29 5953948.01 678431.58 0.00 3492.80 0.00 TI P 10425.00 32.70 23.96 8733.26 4109.41 1800.85 5953960.48 678436.84 1.43 3503.29 234.99 MWD 10450.00 32.50 23.41 8754.33 4121.74 1806.26 5953972.94 678441.96 1.43 3513.80 235.44 MWD 10475.00 32.30 22.86 8775.44 4134.06 1811.52 5953985.37 678446.94 1.43 3524.34 235.90 MWD 10500.00 32.10 22.30 8796.59 4146.36 1816.64 5953997.79 678451.76 1.43 3534.90 236.37 KOP 10515.00 33.41 20.94 8809.20 4153.90 1819.63 5954005.40 678454.58 10.02 3541.40 330.10 1 10525.00 36.30 18.15 8817.41 4159.29 1821.54 5954010.83 678456.36 33.00 3546.11 330.00 MWD 10550.00 43.75 12.62 8836.54 4174.78 1825.74 5954026.41 678460.19 33.00 3559.99 332.29 MWD 10575.00 51.40 8.42 8853.40 4192.91 1829.06 5954044.62 678463.09 33.00 3576.64 336.54 MWD 10600.00 59.17 5.05 8867.63 4213.30 1831.44 5954065.06 678464.99 33.00 3595.72 339.37 MWD 10604.73 60.65 4.47 8870.00 4217.38 1831.78 5954069.14 678465.23 33.00 3599.58 341.30 07-16A 10615.50 64.03 3.23 8875.00 4226.90 1832.42 5954078.67 678465.65 33.00 3608.60 341.59 07-16A 10625.00 67.02 2.18 8878.93 4235.53 1832.83 5954087.31 678465.85 33.00 3616.84 342.17 MWD 10650.00 74.91 359.64 8887.08 4259.14 1833.19 5954110.92 678465.66 33.00 3639.55 342.60 MWD 10675.00 82.83 357.27 8891.91 4283.64 1832.52 5954135.40 678464.42 33.00 3663.39 343.43 MWD 10681.86 85.00 356.64 8892.65 4290.45 1832.15 5954142.20 678463.89 32.98 3670.06 343.79 2 10700.00 86.70 356.02 8893.96 4308.50 1830.99 5954160.22 678462.30 10.00 3687.80 340.00 MWD 10725.00 89.06 355.16 8894.89 4333.41 1829.07 5954185.07 678459.80 10.00 3712.36 340.00 MWD 10735.05 90.00 354.82 8894.97 4343.42 1828.20 5954195.05 678458.69 10.00 3722.25 340.03 3 10750.00 90.13 356.31 8894.95 4358.32 1827.04 5954209.93 678457.19 10.00 3736.94 85.00 MWD 10775.00 90.35 358.80 8894.85 4383.30 1825.98 5954234.87 678455.54 10.00 3761.34 85.00 MWD 10800.00 90.56 1.29 8894.65 4408.30 1826.00 5954259.86 678454.97 10.00 3785.49 85.01 MWD 10825.00 90.78 3.79 8894.36 4433.27 1827.10 5954284.85 678455.49 10.02 3809.32 85.00 MWD 10835.05 90.87 4.79 8894.21 4443.29 1827.86 5954294.88 678456.01 10.02 3818.80 85.03 4 10850.00 90.92 3.30 8893.98 4458.20 1828.91 5954309.81 678456.71 10.00 3832.93 272.00 MWD 10875.00 91.01 0.80 8893.56 4483.18 1829.81 5954334.80 678457.02 10.00 3856.83 271.98 MWD 10900.00 91.09 358.30 8893.10 4508.17 1829.61 5954359.78 678456.23 10.00 3881.02 271.93 MWD 10925.00 91.17 355.80 8892.60 4533.13 1828.32 5954384.70 678454.36 10.00 3905.46 271.89 MWD 10950.00 91.25 353.30 8892.08 4558.01 1825.95 5954409.52 678451.40 10.00 3930.11 271.84 MWD 10975.00 91.33 350.80 8891.51 4582.76 1822.49 5954434.18 678447.37 10.00 3954.91 271.79 MWD 11000.00 91.40 348.30 8890.92 4607.34 1817.96 5954458.64 678442.26 10.00 3979.83 271.73 MWD 11025.00 91.47 345.80 8890.29 4631.69 1812.36 5954482.86 678436.09 10.00 4004.80 271.67 MWD 11050.00 91.54 343.30 8889.63 4655.78 1805.70 5954506.78 678428.87 10.00 4029.79 271.61 MWD 11075.00 91.61 340.80 8888.94 4679.55 1798.00 5954530.36 678420.61 10.00 4054.74 271.54 MWD 11100.00 91.67 338.30 8888.23 4702.97 1789.27 5954553.56 678411.34 10.00 4079.62 271.47 MWD 11125.00 91.73 335.80 8887.49 4725.97 1779.53 5954576.34 678401.06 10.00 4104.37 271.40 MWD 11150.00 91.79 333.30 8886.72 4748.54 1768.79 5954598.64 678389.79 10.00 4128.94 271.33 MWD 11175.00 91.84 330.80 8885.93 4770.61 1757.08 5954620.43 678377.57 10.00 4153.29 271.25 MWD 11200.00 91.89 328.30 8885.12 4792.15 1744.42 5954641.66 678364.40 10.00 4177.37 271.17 MWD 11225.00 91.93 325.80 8884.28 4813.11 1730.83 5954662.30 678350.32 10.00 4201.14 271.09 MWD Obp BP Amoco Baker Hughes INTEQ Planning Report Company: BP Amoco Date: 6/1512001 Time: 14:56:15 Page: 3 ..... Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07-16, True North Site: PB DS 07 Vertical (TVD) Reference: System: Mean Sea Level Well: 07-16 Section (V$) Reference: Well (0.00N,0.00E,345.00Azi) ~ W e. !!_p_a~t.h !__ ?!a?_ _g3_ _O_7_-? 6__A ................................................................... _s. u._r~.e_y__C_a.!?.!.n._fl__°.n_. _M-e~0-d_"- ...... ~i_n_ !._m_u__m_ C_ .u_~ _at_u~e ............ _D.b :_. _?(ac/e ........ Sur~ey MD incl Azim SSTVD NIS E/W MapN MapE DLS VS TFO Tool " ft deg deg ft ft ff ft ff deg/100ff ff deg i 11250.00 91.98 323.30 8883.43 4833.46 1716.33 5954682.30 678335.36 10.00 4224.55 271.01 MWD 11275.00 92.02 320.79 8882.56 4853.16 1700.97 5954701.63 678319.54 10.00 4247.55 270.92 MWD 11300.00 92.05 318.29 8881.67 4872.17 1684.76 5954720.26 678302.89 10.00 4270.11 270.83 MWD 11325.00 92.08 315.79 8880.77 4890.45 1667.73 5954738.13 678285.44 10.02 4292.17 270.72 MWD 11335.05 92.09 314.78 8880.42 4897.58 1660.64 5954745.09 678278.18 10.02 4300.89 270.63 5 11350.00 92.01 316.27 8879.89 4908.24 1650.17 5954755.50 678267.47 10.00 4313.90 93.00 MWD 11375.00 91.88 318.77 8879.04 4926.67 1633.30 5954773.53 678250.17 10.00 4336.07 93.05 MWD 11400.00 91.74 321.27 8878.25 4945.81 1617.25 5954792.29 678233.67 10.00 4358.71 93.14 MWD 11425.00 91.60 323.77 8877.52 4965.64 1602.04 5954811.75 678218.00 10.00 4381.80 93.22 MWD 11450.00 91.45 326.26 8876.86 4986.12 1587.72 5954831.88 678203.20 10.00 4405.29 93.29 MWD 11475.00 91.30 328.76 8876.26 5007.19 1574.29 5954852.64 678189.29 10.00 4429.12 93.36 MWD 11500.00 91.15 331.26 8875.72 5028.84 1561.80 5954873.99 678176.29 10.00 4453.26 93.42 MWD 11525.00 91.00 333.75 8875.25 5051.01 1550.26 5954895.88 678164.23 10.00 4477.67 93.47 MWD 11550.00 90.85 336.25 8874.85 5073.66 1539.69 5954918.28 678153.14 10.00 4502.28 93.52 MWD 11575.00 90.69 338.74 8874.51 5096.76 1530.13 5954941.14 678143.04 10.00 4527.06 93.56 MWD 11600.00 90.53 341.24 8874.25 5120.24 1521.57 5954964.41 678133.93 10.00 4551.96 93.59 MWD 11625.00 90.38 343.73 8874.05 5144.08 1514.05 5954988.07 678125,85 10.00 4576.94 93.62 MWD 11650.00 90.22 346.23 8873.92 5168.22 1507,57 5955012.05 678118,81 10.00 4601.93 93.64 MWD 11675.00 90.06 348.72 8873.86 5192,63 1502.15 5955036.32 678112.82 10.01 4626.91 93.65 MWD 11683.86 90.00 349.61 8873.86 5201.34 1500.50 5955044.99 678110.96 10.01 4635.75 93.66 6 11700.00 90.03 348.00 8873.86 5217.17 1497.37 5955060.74 678107.46 10.00 4651.85 271.00 MWD 11725.00 90.07 345.50 8873,83 5241.50 1491.63 5955084.93 678101.16 10.00 4676.84 271.00 MWD 11750.00 90.12 343.00 8873.79 5265.56 1484.85 5955108.82 678093.81 10.00 4701.84 271.00 MWD 11775.00 90.16 340.50 8873.73 5289.30 1477.02 5955132.37 678085.42 10.00 4726.79 270.99 MWD 11800.00 90.20 338.00 8873.66 5312.68 1468.16 5955155.53 678076.02 10.00 4751.67 270.99 MWD 11825.00 90.24 335.50 8873.56 5335.65 1458.29 5955178,26 678065.62 10.00 4776.41 270.98 MWD 11850.00 90.29 333,00 8873.44 5358.16 1447.43 5955200.51 678054.23 10.00 4800.96 270.97 MWD 11875.00 90.33 330.50 8873.31 5380.18 1435.60 5955222.25 678041.89 10.00 4825.30 270.96 MWD 11900.00 90.37 328.00 8873.16 5401.66 1422.82 5955243.42 678028.60 10.00 4849.36 270.94 MWD 11925.00 90.41 325.50 8872.99 5422.57 1409.11 5955264.00 678014.41 10.00 4873.10 270.93 MWD 11950.00 90.45 323.00 8872.80 5442.86 1394.51 5955283.93 677999.33 10.00 4896.47 270.91 MWD 11958.86 90.46 322.11 8872.73 5449.89 1389.12 5955290.84 677993.79 10.04 4904.66 270.78 7 11975.00 90.46 323.72 8872.60 5462.77 1379.39 5955303.48 677983.75 10.00 4919.61 90,00 MWD 12000.00 90.46 326.22 8872.40 5483.24 1365.04 5955323.61 677968,93 10.00 4943.10 90.01 MWD 12025.00 90.46 328.72 8872.20 5504.31 1351.60 5955344.36 677955.00 10.00 4966.94 90.03 MWD 12050.00 90.45 331.22 8872.00 5525.95 1339.09 5955365.70 677941.99 10.00 4991.08 90.05 MWD 12075.00 90.45 333.72 8871.80 5548.12 1327.54 5955387.59 677929.92 10,00 5015.48 90.07 MWD 12100.00 90.45 336.22 8871.61 5570.77 1316.97 5955409.99 677918.82 10.00 5040.10 90.09 MWD 12125.00 90.44 338.72 8871.41 5593.86 1307.39 5955432.84 677908.70 10.00 5064.88 90.11 MWD 12150.00 90.43 341.22 8871.22 5617.35 1298.83 5955456.12 677899.59 10.00 5089.78 90.13 MWD 12175.00 90.43 343.72 8871.04 5641.19 1291.30 5955479.77 677891.51 10.00 5114.75 90.15 MWD 12200.00 90.42 346,22 8870.85 5665.33 1284.82 5955503.76 677884.46 10.00 5139.75 90.17 MWD 12225.00 90.41 348.72 8870.67 5689.73 1279.40 5955528.02 677878.47 10.00 5164.72 90.19 MWD 12250.00 90.40 351.22 8870.49 5714.35 1275.05 5955552.53 677873.54 10.00 5189.63 90.21 MWD 12275.00 90.39 353.72 8870.32 5739.13 1271.78 5955577.22 677869.69 10.00 5214.41 90.22 MWD 12300.00 90.38 356.22 8870.15 5764.03 1269.59 5955602.07 677866.92 10.00 5239.03 90.24 MWD 12325.00 90.37 358.72 8869.99 5789.00 1268.48 5955627.00 677865.23 10.00 5263.44 90.26 MWD 12350.00 90.36 1.22 8869.83 5814.00 1268.47 5955651.99 677864.63 10.00 5287.59 90.27 MWD 12375.00 90.34 3.73 8869.68 5838.97 1269.55 5955676.98 677865.12 10.01 5311.43 90.29 MWD 12400.00 90.33 6.23 8869.52 5863.88 1271.74 5955701.93 677866.73 10.01 5334.92 90.31 TD Amoco 7700 7800 7900 8OOO 8100 O8200 8300 ~8400 '~8500 ~r~86oo ~87oo ~88oo 89oo 900( 91oo Plan¢~3 07 10/ ..~¢ Magnetic North 26 ~ Crna~d By Bt, Potms da'e 6/15/Z0( r~ ~ . Streo9tgh: 57497nl Dip Angle: 80~8 Model BGGM2001 680C 660C 6400 6200 8000 ~5800 ~5600 ~,~5400 "~5200 *~5000 ~4800 4600 f~4400 4200 400( 38OO 36OO ~400 07.16A T3 3~]D TD 07-16A T3 ~ *~ . 2 07-t6,07 16 -1000 -800 ~UUU ~aUU ~¢~ C 200 400 600 800 1000 1200 I400 1600 1800 200( 2200 240L Xt~U£ 280C 300C 3200 3400 3600 3800 4000 4200 West(-)/East(+) [20Oft/in] KOP 2 3 ~ 07-16A IS2 -r 07.16~, T3 i - · 2800 2900 3000 ...... 32O0 3300 3400 ~50( f60 379( 380C 3900 400C 110C 120C 430C 440t' 4500 4600 4700 4800 4000 5000 5100 5200 5300 5400 55O( 560( 57O( 580( 5fK)( (JO00 610C 620C O30C 6400 6500 6000 Vertical Section at 345,00° [IOOft/i~] 6/15/2001 3:I2 PM 3S CTD BOP Detail ~ CT Injector Head Methanol Injection tis7" WLA Quick onnect ~ I Stuffing Box (Pack-Off), 10,000 psi Working Pressure 7" Riser 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold HCR 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPFTOT I Manual over Hydraulic 2" Side outlets Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure Blind/Shear I I 2 3/8" °r 31/2" Combi IPipe/Slip Kill line check valve Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 7/8" Combi Pipe/Slip 2 3/8" Combi Pipe/Slip MOJ 5/21/01 XO Spool as necessary Single Manual Master Valve (optional depending on RU) I Tubing r' Spool 2 flanged gate valves 7" Annulus 9 5/8" Annulus H 19 3 3 2 2 o7~ o6 ~o ~ oo ~ ~ss== VENDOR ........ AI_,~,~51,~AU l L.A DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 070201 CKo/o>'oii i00. O0 100. O0 PYMT (;OMMENTS: Pert it to Dril 1 F'ee HANDL NO INST: S/H - Terrie Hubt le X4&28 or Sondra SteuJman X4750 ..... rilE AIl'ACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE, ~ ~$] ~'-~ ~ ] BP EXPLORATION, (ALASKA)INC. RO. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY To Th e ORDER 0~ FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO ";' O~E~i'HuN~RED & 00/1.********************* · :,:' .. . . ,, 2 :. · ;::ALASKA AND ~'AS 3~':'.:,::rNES*':. 7'''~'' 'nvENUE '; SU I TE 1:~.0 " , ::,:,:~ ::..: ..... No,'.H 1933,22 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 001c~3322 ~**~*********** US D6LLA,R ':~Mo0~T TRANSMITAL LETTER CHECK LIS~ CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULA~AL A i A OiS,OSA ( ) YEs ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ( ) YES+ SPACING EXCEPT'ION "CLUE" The permit is for a new wellbore segment of existing well , Permit No, ~ APl No. . Production should continue to be reported as a function of the original AP1 number stated above. In accordance with 20 AAC 25.005(0, ali records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PI-I) and API number (50 -70/80) from records, data and logs acquired for wel! (name on permit). Annular disposal has not been requested... Annular Disposal of drilling wastes will not be approved... : Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conserVation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive~jody\templates WELL PERMIT CHECKLIST FIELD & POOL ~',~o/.ccd .. cO~PXNY 12~/e ADMINISTRATION ENGINEERING INIT CLASS ~/~z.~ /--'~ '/ ~ re~l ' WELL NAME 7-/'~'~ PROGRAM: exp dev ._ di ,~ serv GEOL AREA __,~2_r~ UNIT# 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available-in drilling unit ............ 8. If deviated, is wellbore plat included ............. ·.. 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... [Y Y Y Y Y 14. Conductor string provided ......... . .......... 15. Surface casing protects all known USDWs... ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg .... ' .... , , ,, wellbore seg ann. disposal para req O ,2/~.~",,~ ON/OFF SHORE d'~ ~/ N N N N N N N N N .- N N N N Y _ Y N~ .3 18. CMT will cover all known productive horizons. ' 'Y N 19. Casing' designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit ............ ..... 21. If a re-drill, has a 10-403 for abandonment been approved... _~y i ,~~,,\c~%'~>~ ~,~,~ · 22. Adequate wellbore separation proposed ....... : ...... 23. If diverter required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate press ..... psig. 25. BOPEs, do they meet regulation ................ ~, 26. BOPE rating appropriate; test to "~{~('~ 27. Choke manifold complies w/APl RP-53 (May 84) ......... 28. Work will occur without operation shutdown ........... ~.)~ 29. Is presence of H2S gas probable ................. GEOLOGY 30. permit can be issued wlo hydrogen sulfide measures ...... Y N. ,,,/ . ' 31.' Data presented on potential overpressure zones ...... . Y~ 32. Seismic analysis of shallow gas zones... ..... ~ · . i · · Y/'N ~'/~ ,, AI~P~ __,D~AT~/' 33. Seabed conditionsurvey(ifoff-shore) ............. 34. Contact name/phone for weekly progress reports [exploratoryon,!/~.. Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ..... . . Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity .of the Well used for diSposal; (D) will not damage producing formation or impair recovery from a pool; .and .. (E.) wi!l n~ot circumven! 20 AAC 25:2.52 or 20 AAC 25.412. ~: ENGINEERING:. ' UICIA~nular ~~C~. BE.W WM .."~.. ....... ,'~,.~.--"t,.- ~.-- , ,,,, ...... Y N Y N Y N .C. OMMISSION: .C~ ,.,,, ~ 7, -! , , CommentsllnstructionS: O Z O c:~nsoffice\wordian~diana~J~ecklist (rev. 111011100)
