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212-085
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 5/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250508 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40 MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF Please include current contact information if different from above. T40372 T40373 T40374 T40375 T40376 T40377 T40378 T40379 T40379 T40380 T40381 T40382 T40383 T40384 T40385 T40386 T40387 T40388 T40389 T40390 PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 12:42:44 -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 07-22A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-085 50-029-20925-02-00 11002 Conductor Surface Intermediate Production Liner 9013 80 2513 9472 576 1896 9750 20" 13-3/8" 9-5/8" 7" 3- 1/ 2" x 3-1/ 4" x 2- 7/8" 8731 30 - 110 29 - 2542 28 - 9500 9195- 977 9106- 11002 30 - 110 29 - 2541 28 - 8510 8242- 8749 8165- 9013 10894 470 2670 4760 7020 7820 9750 1490 5380 6870 8160 8620 9705 - 10950 4-1/2" 12.6# x 5-1/2" 17# 13Cr80 / L-80 26 - 9257 8691 - 9014 Structural 4- 1/ 2" Baker S-3 Perm , 9046 , 8112 No SSSV 9046 , 9172 8223 , 8112 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 - 8233 403 685 43737 62397 146 27 0 0 911 1052 N/A 13b. Pools active after work:PRUDHOE OIL 5-1/2" Baker SAB , 9173 , 8223 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:53 am, Apr 30, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.04.29 14:14:16 - 08'00' Bo York (1248) RBDMS JSB 050225 DSR-5/1/25JJL 5/8/25 ACTIVITYDATE SUMMARY 3/31/2025 ***WELL S/I ON ARRIVAL*** RAN 2' x 1-7/8" STEM, 3.80" G-RING, TAGGED 4-1/2" DREAMCATCHER @ 9062' MD PULLED 3.81" X-LOCK w/ DREAMCATCHER (recovered pieces of wfd cbp) RAN 30' x 2.29" DUMMY GUNS, 2.50 CENT, DEVIATE OUT @ 10092' SLM RAN CBL FROM 9875' SLM TO 8700' SLM *** WSR CONT ON 4/1 *** 4/1/2025 T/I/O= 2370/676/18 AssistSlickline ( PERFORATING ) Pumped 180 bbls of crude down TBG @ 5 bpm to load. Sim Ops complete. DSO notified upon departure. FWHP - 112/688/22 4/1/2025 *** WSR CONT FROM 3/31 *** CONDUCTED MAN DOWN DRILL w/ WSS LRS LOADED TBG w/ 180 BBLS CRUDE GO ON WEATHER TICKET @ 12:00 (HIGH WINDS) END WEATHER TICKET @ 20:00 RAN HALLIBURTON CBL FROM 9875' SLM TO 8700' SLM *** WSR CONT ON 4/2 *** 4/2/2025 *** WSR CONT FROM 4/1 *** RAN HALLIBURTON CBL FROM 9875' SLM TO 8700' SLM * QUESTIONABLE DATA * *** WELL LEFT S/I ON DEPARTURE *** 4/3/2025 *** WELL S/I ON ARRIVAL *** POLLAR 63 RIG UP *** WSR CONT ON 4/4 *** 4/3/2025 TFS Unit #4 assist S-Line Spot equipment and standby for S/L 4/4/2025 *** WSR CONT FROM 4/3 *** LOADED TBG w/ 200 BBLS CRUDE RAN HES CBL FROM 9875' SLM TO 8700' SLM (good data) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 4/4/2025 T/I/O= 2500/600/0 TFS Unit4 Assist S-Line Pumped 200 bbls Crude down TBG to Load/Kill FWHP's= 0/600/0 Well left in S-Line control upon departure 4/6/2025 *** WELL SHUT IN ON ARRIVAL *** (SET PLUG IN ZONE/ ADPERF) MIRU YELLOW JACKET E-LINE PT PCE 300 PSI LOW 3000 PSI HIGH, FUNCTION TEST WLVS CORRELATE NTO HES MEMORY COIL FLAG LOG DATED 07 MAY 2024 SET NS 325-250 CIBP AT 9750' CCL TO MID ELEMENT 40.1' CCL STOP DEPTH = 9709.9', TAG AFTER SET PERFORATE INTERVAL 9705' - 9725' WITH 2" 6SPF 60PHASE HSC W/ GEO RAZOR CHARGES CCL TO TOP SHOT 8.5' CCL STOP DEPTH = 9696.5', CONFIRM SHOTS FIRED RDMO YELLOW JACKET ELINE *** WELL SHUT IN ON DEPARTURE *** Daily Report of Well Operations PBU 07-22A 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 07-22A Squeeze Perforations Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 212-085 50-029-20925-02-00 11002 Conductor Surface Intermediate Production Liner 9013 80 2513 9472 576 1896 10288 20" 13-3/8" 9-5/8" 7" 3- 1/ 2" x 3-1/ 4" x 2- 7/8" 9029 30 - 110 29 - 2542 28 - 9500 9195- 977 9106- 11002 30 - 110 29 - 2541 28 - 8510 8242- 8749 8165- 9013 10350 470 2670 4760 7020 7820 none 1490 5380 6870 8160 8620 10020 - 10950 4-1/2" 12.6# x 5-1/2" 17# 13Cr80 / L-80 26 - 9257 8974 - 9014 Structural 4- 1/ 2" Baker S-3 Perm , 9046 , 8112 No SSSV 9046 , 9172 8223 , 8112 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 - 8233 Perforations at 10020 - 10030 and Liner holes Pumped 40 bbls of Polymer Gel displaced with 132 bbls of diesel to shut off gas with final squeeze /treating psressure of 2050 psi. 416 366 55049 12536 74 415 0 0 1022 265 N/A 13b. Pools active after work:PRUDHOE OIL 5-1/2" Baker SAB , 9173 , 8223 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.02 10:55:09 - 08'00' Torin Roschinger (4662) By Grace Christianson at 1:43 pm, Aug 02, 2024 DSR-8/12/24 RBDMS JSB 080624 WCB 10-1-2024 ACTIVITYDATE SUMMARY 4/23/2024 ***WELL S/I ON ARRIVAL*** (profile modification) DRIFT w/ 2 7/8" WRP DRIFT TO 80* DEVIATION AT 10,147' SLM STOOD BY FOR PUMP TRUCK ***CONTINUED ON 4/24/24 WSR*** 4/24/2024 ***CONTINUED FROM 4/23/24 WSR*** (Profile modificaton) STOOD BY FOR PUMP TRUCK ***JOB SUSPENDED FOR PUMP SUPPORT*** 4/25/2024 T/I/O=2475/500/0 Temp=S/I (Assist Slickline/Pump Down Drift) pumped 135 bbls of crude down the TBG to load for a pump down drift. Started pumping at 1.5 BPM increasing rate up to 5 BPM for a total of 34 bbls, could not reach target depth. Tried again on a different run with 5 BPM for 11 bbls slickline confirmed they could not reach target depth with pump down. Well left in control of slickline upon departure FWHPS=250/500/0 4/25/2024 *** WELL S/I ON ARRIVAL*** (profile modification) T-BIRD PUMPED 180 BBLS CRUDE FOR PUMP ASSIST UNABLE TO PASS 10178' SLM w/ 2.25" DMY WRP DRIFT & 1.5" SAMPLE BAILER (bailer empty, hit same depth with pump off or @ 5 bpm) ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** 5/6/2024 LRS CTU #1- 1.50" Coil Job Objective: GR/CCL log, Set CBP, Inj test Travel to location, MIRU, M/U NS MHA ***Continued to WSR on 5/7/24*** 5/7/2024 LRS CTU #1- 1.50" Coil Job Objective: GR/CCL log, Set CBP, Inj test Finish M/U NS MHA. M/U and RIH w/HES GR/CCL. Load well with 1% KCl w/ SafeLube. RIH and tag DH Choke at 10287' CTMD and log up to 9000', painting a flag at 10150'. Confirm good data and a +15' correction. Make up 2-7/8" Mill EZ 10k CBP and RIH. Reload well with Seawater before entering liner. Tie-in to the flag and set CBP with ME at 10288'. Pull into the tubing and perform injectivity test with seawater 1.1 bpm @ 702 psi, 1.5 bpm @ 1085 psi, 2.0 bpm @ 1510 psi, and 4.0 bpm at 1844 psi. Continue to POOH and FP tubing with diesel. Rig Down CTU. ***Job Complete*** 6/17/2024 T/I/O= 1184/548/23. LRS 72 Assist HES (GEL SQUEEZE). Pumped 3 bbls of 60/40 MeOH and 185 bbls of 1% KCl into the TBG at 5 bpm and 2400 psi. HES pumped Ge Pill. We pumped 132 bbls DSL down Tbg to spot Gel. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG Choke Trailer= SI 7/2/2024 CTU#1 1.5" Blue Coil Job Scope: Jet through gel, mill CBP, mill Polar Choke and push to PBTD. MIRU LRS CTU #1. Function BOPs. MU and RIH w/ YJ and RIH - 2.35" Venturi Burn Shoe. Burned over CBP @ 10297 CTM (10288' MD). Chase to Polar Choke @ 10314' CTM (10300' MD) Burned over and pushed to 10894' CTM (56' above bttm perf) Unable to work deeper. Previously milled CIBP (10350') likely @ 10894' CTM. POH. Circ remaining gel OOH and SD pump. Final retruns ~50% @ 1.2 bpm. Freeze protect w/ 38 bbls diesel. Injectivity 1.6 bpm @ 750 psi. Recovered cores from both CBP and Polar Chk. RD. ***Job in Progress*** Daily Report of Well Operations PBU 07-22A The milled CBP fish is correctly shown on the WBS below. -WCB g Pull into the tubing and perform injectivity test with seawater MIRU LRS CTU #1. Function BOPs. MU and RIH w/ YJ and RIH - 2.35" Venturi Burn Shoe. Burned over CBP @ 10297 CTM (10288' MD). Chase to Polar Choke @ @()@ 10314' CTM (10300' MD) Burned over and pushed to 10894' CTM (56' above bttm()( perf) Unable to work deeper. Previously milled CIBP (10350') likely @ 10894' CTM. ) POH We pumped 132 bbls DSL down Tbg to spot Gel set CBP with ME at 10288' (GEL SQUEEZE). Pumped 3 bbls of 60/40 () MeOH and 185 bbls of 1% KCl into the TBG at 5 bpm and 2400 psi. HES pumped Ge Pill. Daily Report of Well Operations PBU 07-22A 7/3/2024 LRS CTU #1 1.5" Blue Coil. Job Scope: Jet through gel, mill CIBP, mill Polar choke & push to PBTD. Blow the reel down with N2 and RDMO. Head to LRS yard for maintenance and pipe swap. ***Job Complete*** 7/4/2024 ***WELL S/I ON ARRIVAL*** RAN 4-1/2'' BRUSH, 3.80'' G. RING TO DEPLOYMENT SLV @ 9106' MD ***WSR CONT. ON 07-05-2024*** 7/5/2024 ***WSR CONT. FROM 07-04-2024*** SET 4-1/2'' DREAM CATCHER IN X NIP @ 9062' MD ***WELL LEFT S/I ON DEPARTURE*** STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVE® CCQ ') 4 nnnn 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operate t�n ❑ S Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing 11Chang CC ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Pull LTP m 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 21 Exploratory ❑ 5. Permit to Drill Number: 212-085 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ $eMCe ❑ 6. API Number: 50-029-20925-02-00 7 Property Designation (Lease Number): ADL 028309 8. Well Name and Number: PBU 07-22A 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 11002 feet Plugs measured 10300 feet true vertical 9013 feet Junk measured 10350 feet Effective Depth: measured 10300 feet Packer measured 9046, 9173 feet true vertical 9028 feet Packer true vertical 8112, 8223 feet Casing. Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" 30-110 30-110 1490 470 Surface 2513 13-3/8" 29-2542 29-2542 5380 2670 Intermediate 9472 9-5/8" 28-9500 28-8510 6870 4760 Liner 576 7" 9195-9771 8242-8749 8160 7020 Liner 1896 3-1/2" x 3-1/4" x 2-7/8" 9106-11002 8165-9013 10160 / 8620 1105 10530 / 7820 / 111 Perforation Depth: Measured depth: 10020 - 10950 feet True vertical depth: 8974-9014 feet Tubing (size, grade, measured and true vertical depth) 4-1/2' 12.6# 15-1/2" 17#, 13C80 / L-80 26-9257 26-8233 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Penn Packer 9046 8112 true vertical depth) 5-1/2" Baker SAB Packer 9173 6223 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-Bbi Gas-Mct Water -Bbl Casing Pressure 7 Tubing Pressure Prior to well operation: 491 50040 27 0 1024 Subsequent to operation: 446 47122 88 0 1424 14. Attachments: (.q..d per20 Mc 25 070 s 25283) 15. Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development EI Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ® Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authodzed Name: Thompson, Ryan Contact Name: Thompson, Ryan Authorized Title: Petroleum Engineer Contact Email: RYAN.THOMPSONabp.00m Authorized Signature: fil Date: Z O / Z Q Contact Phone: +1 907 564 4535 Form 10404 Revised 04/2017 /vim tA1"2,�(, �'�j �Q gBDMS _tJ7 FEB 2 4 2020 Submit Original Only Daily Report of Well Operations PBU 07-22A ACTT V ITYDATF C I IIIAAI A MV 1/24/2020 'WELL S/I ON ARRIVAL***(Patch Tubing/Liner) PULLED 45KB LTP FROM 9096' MD, MISSING ONE ELEMENT. MADE 2 UNSUCCESSFUL ATTEMPTS TO RETRIEVE MISSING ELEMENT. ***CONT ON 1-25-20 WSR*** ***CONT FROM 1-25-20 WSR***(Patch tubing/liner) DRIFTED W/ 20'x 2.70" DUMMY WHIPSTOCK, 2.73" CENT & 1-3/4" SAMPLE BAILER, TOOLS S/D IN RESTRICTION @ 9785' SLM. DRIFTED W/ 10'x 2.70" DUMMY WHIPSTOCK, 2.73" CENT & 1-3/4" SAMPLE BAILER, TOOLS S/D IN RESTRICTION @ 9785' SLM. DRIFTED W/ 2.73" CENT & 1-3/4" SAMPLE BAILER, TOOLS S/D IN RESTRICTION @ 9785' SLM. DRIFTED W/ 2.30" CENT & 6'x 1-3/4" BAILER, TOOLS DEVIATED OUT @ 10,129' SLM. DRIFTED W/ 2.50" CENT & 6'x 1-3/4" BAILER, TOOLS DEVIATED OUT @ 10,132' SLM. DRIFTED W/ 2.71" CENT & 6'x 1-3/4" BAILER, TOOLS S/D IN RESTRICTION @ 9785' SLM. 1/25/2020 '**WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** TREE= 5x7 FMC WELLHEAD= GRAY ACTLWTOR= BAKER KB. ELEV = 58' BF. ELEV = ? KOP= 2900' Max Angle = 96° @ 10254' Datum MJ= 9885' Datum TVD= 8800, SS L80 20" CONDUCTOR, 91.5#, H-00, D = 19.124" RS, ID = 12.347" EST TOP OF CEMENT N IA (7/24/05) 8938' 4 112" CHROME � L ANGLE 70° @ 10105" 0 7 W2 2 A •' 2086' 4-1/2" HES X NP, D = 3.813" GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3106 3099 16 Mao` DOME RK 16 07/29/12 2 5981 5508 37 Ma1G SO RK 20 07/29/12 3 7918 7109 30 Ma1G DW RK 0 04/22/05 '4 8947 8025 28 MAG - - - 04/22t05 'CEM ENTED IN (07/24/05) Minimum ID = 0.25" @ 10300'° wY 9638, 2-7/8" NS POLAR CHOKE w/BEAN r e"c' TBG, 12.0, 13CR80, VAM TOP, bpf, D = 3.958" 5-12" TBG SNB 9134' bpf, ID = 4.892" TOP OF 7- LNR 9195' 4-12" TBG -PC, 12.6#, L-80 BTC, 9257' .0152 bpf, D = 3.958" 9-5/8" CSG, 47#, L-80 BTC, D = 8.681" 9500' 3-1 /2", 9.3#, L-80 STL, .0087 bpf, D = 2.992" 9586' 7" X 4" BKR WHIPSTOCK (07/15/12) 9765' 7" LNR 29#, L -BO BTC, .0371 bpf, D = 6.184" 9771' 14" LNR 6.6#, L-80, .0079 bpf, ID = 2.85" 1—L PERFORATION SUMMARY REF LOG: SLB LEE TNN/TNF/GPJCNL on 0721/12 ANGLE AT TOP PERF: 47° @ 10020' 2" 1 6 1 10600-10950 1 O 1 0722112 4-1/r Nw A NV, U = J.uis- 9-5/8" X 4-12" BKR S-3 PKR, D = 3.875- 14-1/2' /2' HES X NP. ID = 3.813" D = 3.00' 9-5/8" X 5-1/2" BKR SAB PKR ID = 4.00 7" MILLOUT EXTENSION, D =??? 9244' "4-1/2" .813" CAMCO DB -6 NP, D = 3.813- -14-112- BKR 4-1/2-BKR SHEAROUT SUB 9257' 4-12" WLEG, D = 3.958" 9251' EiMD TT LOGGED 05/18/98 �? RNfTP RWO FISH: 3 ELEMENTS (CHUNKS). 1 -SLP 1"X 1' (SQUARE) (10/09/16) 9586' 3-12" X 3-3/16" XO, ID = MLLOUT WINDOW (07.22A) 9771' - 9778' 10262' 3-3/16" X 2-7/8" XO, D = 2.377" 10300' DATE 2-7/8" NORTHERN SOLUTIONS POLAR CHOKE w /0.25" BEAN (08/08/18) 10350' FSH: ED & PUSHED 3-114" WFD CBP- SEE WELL FLE FOR PICTURES (08/07118) 08/09/18 DATE REV BY COMMENTS DATE REV BY COMMENTS 0322/83 RWN 178 1 INITIAL COMPLETION 08/09/18 TFA/JMD MLLED FISH &SET POLAR CHOKE 09/11181 RNfTP RWO 09/05/19 EPD/JMD SET BKR BP (08/31/19) 10/14104 NOES RWO 09/09/19 MS/JMD SET BP STOP (09108/18 0724/12 NORDIC 2 CTD SIDETRACK (07-22A) 09/16/19 EPD/JMD PULLED BPS 08/02/17 MS/JMD SET CEP & ADPERFS 0729/ 1120/19 RT/JMD PULLED BP 09/11/19 04/26/18 LLG/JMD CBP MOVED UH AND E NOVA 012820 LLG/JMD PULLED LTP w/ PTSA 012520 PRUDHOE BAY UNIT WELL: 07-22A PERMIT No: '2120850 API No: 50-029-20925-02 Tl 1N, R14E, 1831' FNL & 682' FWL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations El 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: 5C f e/3,P it 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 212-085 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20925-02-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number PBU 07-22A 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: RECEIVED Total Depth: measured 11002 feet Plugs measured 10099 feet true vertical 9013 feet Junk9107 feet measured AUG 3 12017 Effective Depth: measured 10099 feet Packer measured See Attachment feet true vertical 9016 feet Packer true vertical See Attachment feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 2512 13-3/8"72#L-80 29-2541 29-2541 4930 2670 Intermediate 9472 9-5/8"47#L-80 28-9500 28-.8510 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10020-10030 feet 10600-10950 feet True vertical depth: 8974-8980 feet feet 9023-9014 feet SCON �j i r Al t Y 2017 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: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 523 44061 148 440 1017 Subsequent to operation: 706 44216 166 1200 368 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory 0 Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 171 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: ( jf — Date: ? (1 C kt Contact Phone: +1 9075644677 Form 10-404 Revised 04/2017 V71 10/6,//tI p �S® `+ /VV SEP - 5 2017 c `(oW7 ® Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED AUG 312017 RE: BP Exploration (Alaska), Inc. AOWC Report of Sundry Well Operations Summary August 31, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Adding of Perforations for Well 07-22A, PTD # 212-085. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 . • Packers and SSV's Attachment PBU 07-22A SW Name Type MD TVD Depscription 07-22A TBG PACKER 9045.58 8111.64 4-1/2" Baker S-3 Perm Packer 07-22A PACKER 9103 8162.02 4-1/2" Baker KB LT Packer 07-22A TBG PACKER 9172.68 8222.92 5-1/2" Baker SAB Packer . 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A a » S t i o CC n CC 0_ a < CC 0 : W < ¥ ¥ w ¥ Ia d d d E. e Ni- co co d \ w N- ¥ N. < • w _o a) \ § k 2 of a_ / Cn kk ■ 2 U § 7 7-1 / k k a 0. f n _ < f � 2 • _ \ L • 0 cc o o oca : uj a 0. . • \ $ E >+ 0 D • E n fob ¥ = (I) If @ T c � ? ? 66 f S � § 2 kE $II / -I2 | a ƒ 5 k / r- 7/ c � / 'a' R III L, TREE= 5x7 FMC WE LLFfAD= GRAY 07-22A SAFETY NOTES:WELL ANGLE>70°@ 10105'•" ACTUATOR= BAKER C 4-1/2-CHROME TBG KB.ELEV- 58' BF.t3.EV= ? KOP= 2900 2086' I-14-1/2"IES X PP,D=3.813' 20'CONDUCTOR, — 110' Max Angle= 96"@ 10254' GAS LFT MANDRELS 91.5#,H-40, Oaten MD= 9885' ST MD ND D1Y FD VLV LATCH PORT DOTE D=19.124' Datum NO= 8800'SS 1 3106 3099 16 MAG DOME RK 16 07/29/12 2 5981 5508 37EV PLG SO RFC 20 07/29/12 13-3/8"CSG,72#,L-80 BTRS,D=12.347" —I 2542' 3 7918 7109 30 MMG DMY RK 0 04/22/05 *4 8947 8025 28 MMG - —- 04/22J05 'CBAeIr®IN(07124/05) EST TOP OF CEMBYr N IA(7/24105) 8938' T Y 901T —I 41/2"HES X NP D=3.813" YYY. Yir Minimum ID =2.31" @ 9106' '� �_� PM I-1 9-5/8"X 4-1/2"BKR S-3 PCR,D=3.875" 2-7/8" X NIPPLE IN LTP w/PTSA Y Y. ++}}��� 9062' H 4-1/2'FES X MP D=3.813' Y,Yf,Y, 14} Y Y 11c�'ss��' 9096' _--145K8 BKR LTP w INS PISA(10/15/16) 4-1/2"TBG,12.6#,13CR 80,VAM TOP, 9125' ;if. _. MA a Ty 9 9106' 3.70"BKR DEPLOYMENT NT SLV,D=3.00" I .0152 bpf,ID=3.958" kr. 411N 9106' H2-7/8"X NP,D=2.31" 5-1/2"TBG STUB 9134' 9136' H UNIQUE MACHNE OVERSHOT 5-1/2'TBG-PC,1711,1-80 8RD AB-MOD, H 9157' 9157' —{5-1/2'BKR PBR ASSY,D=4.00' .0232 bpf,ID=4.892' CA ►� 9172' H9-518"X 5-1/2"BKR SAB PKE2 D=a.00 a9178' --I 7"MELLOUT E XT BNISION,D=??? 9179' H 7"X 4-112"XO,D=3.958" TOP OF 7"LAR —I 9195' ;, 9244' H4-1/2"CAMCO DB-6 MP D=3.813" 9256' H41/2"BKR S►EAROUT Sub 4-1/2"TBG PC,12.6#,L-80 BTC —I 9257' I / 9257' H4-1/2"WLE G,D=3.958" .0152 bpf,D=3.958' 9251' H RM)TT LOGGED 05/18/98 9-5/8'CSG,47#,L-80 BTC,13=8.681" -1 9500' .' 7 FISH:3 ELEMENTS(CHUNKS),1-SLP 1"X 1' (SQUARE)(10/09/16) 3-1/2",9.3#,L-80 STL,.0087 bpf,D=2.992" — 9586' - , 9686' _I-13-1/2"X 3-3/16'XO,D=2.786" •�4 W 7"X 4"BKR HPSTOCK(07/15/12) —I 9766' I it:: PA '+�* •• ACLOUT WNDOW(07-22A)9771'-9778' • 7"LM,29#,L-80 BTC,.0371 bpf,D=6.184" -I 9771' • •0• I 10099' —13-1/4"WFDCBP(07/29/17) 3-1/4"LHR,6.6#,L-80,.0079 bpf,13=2.85" H 10262' 10262' H3-3/16"X 2-7/8"XO,D=2.377" 2FORATION SUMMARY REF LOG:SLB LEE TP'I•YTTF/GR/C L on 07/21/12 ANGLE AT TOP PERE 47"I§10020' Note:Refer to Production DB for historical perf data I SIZE SPF NTE3RVAL Opn/Sgz DATE 1.56' 6 10020-10030 0 07/29/17 2" 6 10600-10950 C 07/22/12 PBTD H 10964' ►i 2-7/8'LNR,6.5#,1-80 STL,.0058 bpf,ID=2.441" —I 11002' 1.4 DATE REV BY COMENTS DATE REV BY COMMENTS PRU DHOE BAY LNT 03/22/83 RWN 176 IMTIAL COMPLETION 10/19/16 JGL/JMD PULL BP,13P STOP,LTP,SET FISH WELL: 07-22A 09/11/01 RWTP MO 10/19/16 JGUJMD SET KB LTPw/PTSA 8 X tip(10I15/16) PERMIT No:12120850 10/14/04 N4E35 RWO 08/02/17 MS/JMD SET CBP&ADPERFS(07/29/17) AR No: 50-029-20925-02 07/24/12 NORDIC 2 CTO SIDETRACK(07-22A) SEC 34,T11 N,R14E 1831'FM_&682'FY& 09/19/16 KFS/JM) SET BKR BP(09/17/16) 09/27/16 TBD/JMD SET XLOCK w/BP STOP BP Exploration(Alaska) 2t2=01'5 ` PRINT DISTRIBUTION LIST UGHES , a GE company ��a���� Please sign and return one copy of this transmittal form to: Al COMPANY BP Exploration a (V" BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED WELL NAME 07-22A A116 1</%4/2011 2017 900 E.Benson Blvd. M. K.BENDER (� Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit AOGCC to acknowledge receipt of this data. AOGCC COUNTY NORTH SLOPE LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska --- LOG DATE July 29,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(a bakerhughes.com TODAYS DATE August 9,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #LH-I'RIN I S #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope. 0 1 1 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 1 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 1 State of Alaska -AOGCC 0 1 I 1 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 0 I 1 I 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ntial"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. I I I Petrotechnical Data Center,LR2-1 900 E.Benson Blvd SCANNED SEP 1 5 2017, Anchorage,Alaska 99508 TOTALS FOR THIS PAGE: • 0 2 5 • 0 0 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMIS.' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ 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 Wella Re-enter Susp Well 0 Other:Pull/ReSet LTP l 1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 212-085 3. Address: P.O.Box 196612 Anchorage, Development a Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20925-02-00 7. Property Designation(Lease Number): ADL 0028309 8. Well Name and Number: PBU 07-22A 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: FrErvED Total Depth: measured 11002 feet Plugs measured feet true vertical 9013 feet Junk measured 9107 feet N O V 1 7 2016 Effective Depth: measured 10964 feet Packer measured See Attachment feet true vertical 9013 feet Packer true vertical See Attachment feet h / `1 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 2512 13-3/8"72#L-80 29-2541 29-2541 4930 2670 Intermediate 9472 9-5/8"47#L-80 28-9500 28-8510 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10600-10950 feet MAR 01 8 Z017 True vertical depth: 9023-9014 feet 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: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 544 47863 30 420 820 Subsequent to operation: 671 58764 9 400 865 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations VI Exploratory ❑ Development 11 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil a Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer SignatureC — Phone +1 907 564 4424 Date 11/17/16 Form 10-404 Revised 5/2015 VTC 2//G I/ 4��7 RBDMS v- NOV 2 8 2016 Submit Original Only • • Packers and SSV's Attachment PBU 07-22A SW Name Type MD TVD Depscription 07-22A TBG PACKER 9045.58 8111.64 4-1/2" Baker S-3 Perm Packer 07-22A PACKER 9103 8162.02 4-1/2" Baker KB LT Packer 07-22A TBG PACKER 9172.68 8222.92 5-1/2" Baker SAB Packer • • a) 0.O O O M 0 0 CD 0 0 0 0 N- CO 1.0 N N (0 OO o co O 0 N N Ns O Ns ,_ CCOO Ps CCOO Ns U ' 000 ° 000 ° 00Q E O) M I- CD CO N j M M CO X- Tr CO O op Z(.0D N- co ti co O LC) O) ,— M N- M N 00 d M N- O) M O) U) U) N- 0 O N N N 1- N CO CO CO O) CA CO CO CO LO CO CO O 0) CO CO Cr CO Cr) CO N- 0) M M N N N U) 0 N N T- N CO CO CO O) CO CO 04.0 co N N O N- 03 U) N 0)) O) Off) N O) O) 0) o 2.010 4-1 11111 III i 4-0 aN ornaoornac°oc (DNV- OD MNN CnNNN y) C O CA O) O) O) 0) M� W 0 0.""' o0o0 OOco aoo00Oaoo a C9oC? 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O O O O N N N N U) CO M r •r r r m r- co O O O O r ,- r TREE= 5x7 FMC411 WELLHEAD= GRAY 07-22A SA NOTES:W ELL ANGLE>70°@ 10105'*** •ACTUATOR= BAKERC 4.112°CHROME TBG KB ELB/= 58' I BE ELEV= ? 2 j(pp_ 2086' 1-14-1/2"FES X NP,D=3.813" 20'CONDUCTOR, —I 110' Max Angle= 96"a10254' 91.5#,1-1-40, GAS LFT MADS Datum AD= 9885' / ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum 1VD= 8800'SS 0=19.124• 1 3106 3099 16 MMG DOME RK 16 07/29112 / 2 5981 5508 37 MMG SO RK 20 07/29/12 13-3/8•CSG,72#,L-80 MRS,I)=12.347" H 2542' r 3 7918 7109 30 MMG OMY RK 0 04/22(05 *4 8947 8025 28 MMG - - - 04122/05 'EST TOP OF CEMB�TF N b(7124/05) -1 8938' *CEM BAIT®IN(07/14105) Y Y tionsi901T H 4-1/2 HES X NP D=3.813" Y YYY1 1',Yt,Y,Yf.'I Minimum ID=2.31" d(-,i 9106* Y Y� 9038• —9-5/6-X 4-1/2'BKR S-3 PKR D=3.875' 2-7/8"X NIPPLE IN LTP w/PTSA '= '=' rYYYi 9062' H4-1/2"HES X NP,D=3.813" YY rYYY PI 9096' 45KB BKR LIP /NS SA(10/15/16) 4-12•TBG,12.6#,13CR-80,VAM TOP 9125' Y o'. r4 9106' H 3.70'BKR DE FLOP NB4IT SLV,13=3.00' I .0152 bpf,D=3.958' i'I itie 5 9106' _I-12-7/8"X NP,D=2.31" 5-1/7 7BG site H 9134' 8136' -�UNQUE MACFit+E OV E3iSHOT 5-1/2'TBG-PC,17#,L-80 8RD AB-MOD, H 8157' 8167' H5-112'BKR PBR ASSY,D=4.00' .0232 bpf,D=4.892' 4 ii, 8172' H9-5/8'X 5-1/2"BKR SAB F D=4.00 9178' --17"MELLOUT EXTHVSION,D=??? MR AR H s195' 9179' --17"X 4-1/2"XO,D=3.958" im i 9244' —14-12"CAMCO DB-6 NP,D=3.813" 9256' -14-12"BKR S*-EAFXff SW 4-1/7166-Ft,12.6#,L-80 BTC, —{ 9257' .0152 bpf,D=3.958" 9257 H4-1/7 W M,D=3.958' 9251' H ELAD TT LOGGED 05/18/98 19-5/8'CSG,47#,L-80 BTC,D=8.681" -1 9500' y .' ? I—FISH B.BMENrS(CHUNKS),1-SLP 1'X 1" (SQUARE)(10/09116) 3-12",9.3#,L-80 STL,.0087 bpf,D=2.992" —I 9586' •4 •*1 9586' —312"X33116'XO,D=2.786" 17"X 4'BKR WFPSTOCK(07/15/12) H 8766' E►004 !0041 '" •i4 MfLLOUT WINDOW(07-22A)9771'-9778' 7"LN,29#,L-80 BTC.,.0371 bpf,D=6.184" H 9771' X0.4 131/4"LN2,6.6#,1-80_0079 bpf,13=2.85" H 10262' 10262' --I3-3/16"X 2-7/8"XO,D=2.377" PERFORATION SUMMARY REF LOG:SLB LEE T? MTTF/GWC ..on 07/21/12 ANGLE AT TOP PERF:90"a 10600' Note:Refer to Production OB for historical pert data SUE SPF NTERVAL Opn/Sqz DATE 2" 6 10600-10950 0 07/22/12 PBTD 10864' 2-7/8"LNR,6.5#,1-80 STL,.0058 bpf,D=2.441' —I 11002' I_____� DATE REV BY CONSENTS DATE REV BY CONSENTS PRUDHOE BAY UNI 03/22/83 RWN 176 INITIAL COMPLETION 10/19/16 JGUJMD PALL BP,IBP STOP,LTP,SET FISH WELL: 07-22A 09/11101 RNITP RINO 10/19/16 JGUJMD SET KB LTP w/PISA&X NP(10/15/16) FER IT No:"2120850 10/14/04 NES 16NO API No: 50-029-20925-02 07/24/12 NORDIC 2 CTD SIDETRACK(07-22A) SEC 34,Tt 1 N,R14E,1831'R4_&682'FW.. 09/19/16 KFS/JMD SET BKR BP(09/17/16) 09/27/16 TBD/J14) SET XLOCK w/IBP STOP BP Exploration(Alaska) 2(Z —c Davies, Stephen F (DOA) From: Loepp, Victoria T (DOA) s�`� Sent: Tuesday, August 18, 2015 3:50 PM To: Davies, Stephen F (DOA) ,,e6 4( S Subject: FW: PBU 07-22A Well Name Discrepancy (PTD 212-085) LI(.41 7-)-2,6' Steve, l-f 677�z-Af- -, (g is-- I'm forwarding this to you for handling. It was before my time and you can probably decipher what was done and what needs to be done in RBDMS concerning this Name Change. Thanx, Victoria From: Lastufka, Joseph N [mailto:Joseph.Lastufka@bp.com] Sent: Tuesday, August 18, 2015 2:48 PM To: Loepp, Victoria T(DOA) Subject: FW: PBU 07-22A Well Name Discrepancy (PTD 212-085) Victoria, Just happened to research this well and noticed that the change hasn't been made into effect. Could you please update your records to reflect the naming request? Please let me know if you have any questions. Thanks! SCANNED AUG 2 4 2015 Home Well Info I Production Info NGL Info Injection Info Reference Info Search Section (click to slide search panel up or down) Well Name v Begins with v! search Advance+ Current Search: Well Name Like'%07-22%' Narrow Results: PRUDHOE BAY UNIT 07-22B v Reset Please be patient... the page may take 30 seconds or more to load. Use '%" as a wild card when searching. Well Detailed Info Permit to Drill# 2120850 Well Name PRUDHOE BAY UNIT 07-22B General Location History Production Markers API Well # 50-029-20925-02-00 Confidential No Current Operator BP EXPLORATION(ALASKA)INC Geo Area ARCTIC SLOPE Field PRUDHOE BAY Field(Pool PRUDHOE OIL Leases ADL028309 Pad/Platform PBU_DS7 Current Class Development Current Status Oil well,single completion Status Date 712912012 Release Date 6128;2012 Permitted Class Development Permitted Status Oil well,single completion Comp Date 7/2912012 Spud Date 7r17t2012 TD 11002 TVD 9013 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz©alaska.gov] Sent: Tuesday, October 09, 2012 8:35 AM To: Clifton, Sean C (DNR) Cc: Davies, Stephen F (DOA); Lastufka, Joseph N Subject: RE: PBU 07-22A Well Name Discrepancy (PTD 212-085) Sean, Good catch... we had withdrawn the first PTD 212-084 but had not renamed 7-22B to 7-22A in RBDMS. I changed well name to 7-22A this morning. So well is now officially PBU 7-22A with PTD 212-085 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Clifton, Sean C (DNR) Sent: Tuesday, October 09, 2012 8:11 AM To: Schwartz, Guy L (DOA) Subject: FW: PBU 07-22A Well Name Discrepancy 2 Just resending this, in case it got buried in your inbox. I'm the guy who left a voicemail this morning, but fumbled at my office phone number. I will be out of the office for training from 9:30-4:30 today, but will check my email and voicemail during lunch. Thanks for your help. From: Clifton, Sean C (DNR) Sent: Thursday, October 04, 2012 4:10 PM To: Schwartz, Guy L (DOA) Subject: PBU 07-22A Well Name Discrepancy Good afternoon, The API# in question is 50029209250200.The well appears to be registered as 07-22B, though I just received some well logs from BP that have it named 07-22A. The database I am checking against is titled "AOGCC_DataExtract.mdb," which is the monthly data update we get from AOGCC. I contacted Doug Dortch at BP, and Joseph Lastufka responded to my inquiry by sending me the below correspondence. Since it appears that you touched it last, I thought you may be able to help me clear it up. The last person I spoke with at AOGCC about a problem like this was Steve McMains. If he, or someone else, is more appropriate for this kind of issue, please let me know. If you need more details or wish to speak over the phone about this, I am in my office 8-4:30. Thanks for your help. Sean Clifton Natural Resource Technician Resource Evaluation Division of Oil& Gas Department of Natural Resources, State of Alaska 550 W 7th Ave, Ste 800 Anchorage,AK 99501 907-269-8789 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Department of Natural Resources(DNR), State of Alaska,and is for the sole use of the intended recipient(s) It may contain confidential or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law If you received this e-mail in error, please delete it,without first saving or forwarding it, and, so that future mistakes can be avoided, contact Sean Clifton at sean.clifton@alaska.gov or 907-269-8789 From: Lastufka, Joseph N fmailto:Joseph.Lastufka@abD.coml Sent: Thursday, October 04, 2012 3:24 PM To: Clifton, Sean C (DNR) Subject: FW: 07-22A and 07-22B permit to drill Sean, 3 I understand that you have questions regarding 07-22A and the API number assigned. Hopefully this will help to clear up any questions you have. Please see the chain of events for the naming and API designation for this well. Feel free to contact me if further clarification is required. Thanks, Joe Lastufka From: Johnston, David Sent: Wednesday, July 18, 2012 11:10 AM To: Schwartz, Guy L (DOA) Cc: Lastufka, Joseph N (Northern Solutions) Subject: RE: 07-22A and 07-22B permit to drill Guy, I would like to request to withdraw PTD#212-084 for well 07-22A at this time. I would also like to request the name change on the second permitted target to reflect: PTD 212-085 with an API suffix of-02 to be named 07-22A. Thanks again, David Johnston CTD Engineer 564-5985 From: Schwartz, Guy L (DOA) fmailto:guv.schwartz@alaska.govj Sent: Wednesday, July 18, 2012 9:40 AM To: Johnston, David Cc: Davies, Stephen F (DOA) Subject: RE: 07-22A and 07-22B permit to drill David, Request to withdraw the first permit( 7-22A / PTD 212-084) and then we can rename the second permitted target to 07- 22A and it becomes drilled well. (We cannot change the API number for the PTD so it will remain -02 suffix. ) So the well will be 07-22A and PTD 212-085 with an API suffix of-02 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnston, David fmailto:David.Johnston2@BP.comj Sent: Wednesday, July 18, 2012 9:17 AM To: Schwartz, Guy L (DOA) Subject: 07-22A and 07-22B permit to drill Guy, Thanks for working with me on getting both 07-22A and 07-22B permits to drill issued. We have found the targets of 07- 22A to be undesirable and are going to drill the 07-22B targets. We will not be plugging back what we have drilled 4 already, we are just going to continue to drill ahead from our current depth to the new direction north, instead of continuing the turn to the north west. We would like to maintain the 07-22A wellbore name, and not use the (B) name. Please advise me of what steps you would like me to take to maintain this name, and under which permit. Thanks for your time, David Johnston BP Alaska, CTD Engineer 564-5985 5 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Qj c2 - 02,5 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RE CAN: OVERSIZED: NOTES: Color Items: ❑ M s: Grayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: 9 a 0itt /s/ VII Project Proofing BY: �• Date: d /5/ 1/4 r Scanning Preparation I x 30 = 30 + aD. . TOTAL PAGES 1/45,19-- (Count does not include cover sheet) AiBY: Maria Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: 53 (Count does include covers eet) Page Count Matches Number in Scanning Prerraration: YES Vi/i/f) NO BY: Date: a{Q `if /s/ al. Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: P Digital version appended by: Meredith Michal :- e: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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INTERMEDIATE FINAL Yes (mandatory) �\rj 0 Q�'^5 WELL NAME \—ZZ� RUN NUMBER L— C mandatory) 27-7 G, FIELD Prudhoe Bay BH SALESMAN Okechukwu(Okey)Anyanwu (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: TODAYS DATE: 5/31/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: BP Exploration(Alaska)bac. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY CO FIELD FINAL (digital/ ADDRESS(FEDEXWILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) SNA PERSON ATTENTION #OF PRINTS #Oh THIN I S #OF COPIES Q#OF COPIES �1 D. U U 1 BP Exploration(Alaska)Inc. 1 3 j 1 1 I Petroterhnical Data Center LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 i 2 JConocoPhillips Alaska Inc. 1 1 I 1 'Attn Ricky Elgarico iP0 Box 100360 )Anchorage,Alaska 99510 3 ExxonMobil,Alaska 1 1 1 I Attn Lynda M.Yaskell and/or Leonardo Elias 3700 Centerpointe Dr. Suite 600 Anchorage,Alaska 99503 4 State of Alaska-AOGCC 1 1 1 1 1 I 1 !Christine Shartzer it 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 R-Division of Oil&Gas 1 5iDN Attn:Sean Clifton 1550 W.7th Ave,Suite 800 Anchorage,Alaska 99501 TOTALS FOR THIS PAGE: 0 5 5 0 0 0 TOTALS FOR ALL PAGES: 0 5 5 0 0 0 Letter of Transmittal HIM Date: Ft `�'a D BAKER October 2, 2012 0 C T 12 2012 HUGHES AOGCC. To: From: State of Alaska AOGCC Baker Hughes INTEQ 333 W. 7th Ave., Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Bill Michaelson Please find enclosed the directional survey data for the following well(s): C-09BPB 1 C-09B A ` 0 Le c C-03CPB 1 C-03C — LcD, - 0.6`N C-24BPB 1 C-24B 0 1.423 B-27B 17-22 ' ECYS.5 37APB 1 ) S-32A t nZ ) O S-12B ‘27 ( 2 Enclosed for each well(s): 2 hardcopy prints of directional survey reports 1 compact disk containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: / , State of Alaska AOGCC DATE: ogr bp Date 10-04-2012 0 Transmittal Number:93260 RECEIVED BPXA WELL DATA TRANSMITTAL OCT p 4 2012 Enclosed are the materials listed below. AOGCC (BPXA FIELD LOG DATA) If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data& Electronic Log Prints for the following wells: 17-22A ;1/Z- 07-35A -07-35A --1 13-15A • �G f 13-15APB1 Z//—/Z( vt % /= tip c L`� ,t,, 6,J �'S' l s(e cr 13-15APB2 v 212—o7ZJ B-20A C-01B C-Q1 BPB1 C-27C 21 7--C-)(-112- F-08B -C-)`-11ZF-08B 2/2_,-D VO C��_izodo{ % a 4-2) -6lZ 2/(— /L6 6-/7- /j Please Sign and Return one copy of this transmittal. Thank You, Doug Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Shartzer 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E.Benson Blvd.PO Box 196612 Anchorage,AK 99519-6612 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended lb. Well Class: • 20AAC 25.105 20AAC 25.110 ®Development. 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One 0 Service 0 Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 07/29/2012 212-085 ' 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 7/17/2012 50-029-20925-02-00 ' 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 7/19/2012 • PBU 07-22a l 1831'FNL,682' FWL, Sec.34,T11N, R14E, UM • 8. KB(ft above MSL): - 58 15. Field/Pool(s): Top of Productive Horizon: Prudhoe Bay/Prudhoe Bay FNL, 113' FEL, Sec.33,T11N, R14E, UM GL(ft above MSL): ..• 27.59' • 0Total Depth: 9.Plug Back Depth(MD+TVD): 4441' FNL, 76' F L Sec. 34, T11N, R14E, UM 10964' 9013' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 676899 y- 5949110 Zone- ASP4 • 11002' 9013' ' ADL 028309 • TPI: x- 676192 y- 5945662 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 676360 Y- 5946486 Zone- ASP4 None 18. Directional Surve Y ®Yes ❑ No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD/GR/RES, GR/CCL/MCNL, Caliper 9771' 8749' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM Top BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 79' Surface 79' 30" 1900#Poleset 13-3/8" 72# L-80 Surface 2542' Surface 2542' 17-1/2" 1520 sx Fondu,400 sx PF C 9-5/8" 47# L-80 Surface 9500' Surface 8510' 12-1/4" 500 sx Class'G',300 sx PF C 7" 29# L-80 9195' 9771' 8242' 8749' 8-1/2" 300 sx Class'G' 3-1/2"x3-1/4"x2-7/8" 9.2#/6.6#/6.5# L-80 9098' 11002' 8158' 9013' 4-1/4" 106 sx Class'G' 24. Open to production or injection? ®Yes 0 No25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ) 2"Gun Diameter,6 spf 4-1/2", 12.6#x 5-1/2", 17#, 9257' 9038'/8105' MD TVD MD TVD 13Cr80/L-80 9172'/8222' 10600'-10950' 9023'-9014' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 0.1ii'iI iu.y DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED r RECEIVED 2500' Freeze Protect w/39 Bbls of Diesel rt:t.s i. ,� j/� AUG 2 7 2012 27. AOGCCPRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): August 2,2012 Flowing f Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 8/11/2012 10 Test Period 4 520 3610 199 87 6947 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 227 600 24-Hour Rate 4 1247 8664 478 27.4 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No • Sidewall Core(s)Acquired? 0 Yes IN No • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None R88DMS AUG 2 8 2012_,f /(All,I Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ,diter/i/�Submit(spinal Only t 29. GEOLOGIC MARKERS(List all formations ar ' narkers encountered): 30. FORMATION TESTS NAME D TVD Well Testes. A Yes ®No • Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Top of CGL/Zone 3 9854' 8828' None Base of CGL/Zone 2C 9930' 8901' 23SB/Zone 2B 10002' 8961' 22TS 10129' 9026' Formation at Total Depth (Name): 22TS/Zone 2B • 10129' 9026' 31.List of Attachments: Summary of Daily Drilling Reports, Summary of Post-Rig Work,Well Schematic Diagram,Surveys 32. I hereby certify that thfo oing ue orrect to the best of my knowledge. Signed: Joe Lastufk i * v _ Title: Drilling Technologist Date: S/l"TnZ PBU 07-22A 212-085 Prepared By Name/Number: Joe Lastufka, 564-4091 Well Number Permit No./Approval No. Drilling Engineer: David Johnston, 564-5985 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only 'MP North , `North America -ALASKA- SP Page 1 of 11 Operation Summary Report Common Well Name:07-22 AFE No Event Type: RE-ENTER-ONSHORE(RON) I Start Date.7/13/2012 End Date: 7/20/2012 X3-01284-C. (2,423,935.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No NORDIC 2 Spud Date/Time:3/7/1983 12:00:00AM Rig Release:7/24/2012 Rig Contractor. NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322W Active Datum: Kelly Bushing/Rotary Table©58.00ft(above Mean Sea Level) _ Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/13/2012 20:00 - 21:00 1.00 MOB P DECOMP BEGIN RON EVENT AT 20:00 ON 7/13/12 WITH NORDIC 2 CTD RIG. MOVE RIG OFF WELL 7-35 AND STAGE ON DRILLSITE 7 09:00-NOTIFY AOGCC REPRESENTATIVE CHUCK SCHEVE OF INTENTION TO TEST BOPE AT 09.00 ON 7/14/2012. MR.SCHEVE REQUESTS UPDATE ON 7/14/12 AM. 21:00 - 23:00 2.00 MOB P DECOMP MOVE RIG MATS FROM WELL 7-35 TO WELL 7-22 AND LAYOUT HERCULITE. TUBOSCOPE ON LOCATION TO PERFORM ULTRASOUND INSPECTIONS IN PITS. 23:00 - 00:00 1.00 MOB P DECOMP HOLD PJSM AND MOVE RIG IN FRONT OF WELL 7-22. 7/14/2012 00:00 - 02:00 2.00 MOB P DECOMP RIG STAGED IN FRONT OF WELL 7-22. PREPARE CELLAR FOR MOVING RIG OVER WELL. NEED TO PULL TREE CAP PRIOR TO PULLING OVER WELL DUE TO CLEARANCE TOLERANCE. 02:00 - 06:00 4.00 WHSUR P DECOMP ACCEPT NORDIC 2 CTD RIG AT 02:00 ON 7/14/2012. PERFORM LEAK TIGHT TEST OF SSV FROM ABOVE AND SWAB FROM BELOW THROUGH WING VALVE TO 3500 PSI TO ESTABLISH BARRIERS FOR BOP NU BREAKING CONTAINMENT(PASSING TESTS,SV TURNS AND SSV STEM LENGTH CONFIRMED, CAVITY MONITORED DURING BREAKING CONTAINMENT). PULL TREE CAP. -EXTRA TIME TO ESTABLISH BARRIERS BECAUSE OF DISCUSSIONS ABOUT NEW PROCEDURE. 06:00 - 10:00 4.00 MOB P DECOMP CENTER RIG OVER WELL AND BERM UP CELLAR. SPOT AUXILLARY EQUIPMENT AROUND RIG. ALL PRE-RIG WORK VERIFIED COMPLETE -INITIAL IA/OA PRESSURES=0/30 PSI -RIG UP SSV CONTROL LINE TO PANEL IN OPS CAB. -WELLWORK TRANSFER PERMIT OPEN WITH DRILLSITE OPERATIONS. -HANDOVER OF WELL COMPLETED WITH WELLS GROUP -PRE-SPUD MEETINGS HELD WITH RIG CREWS. -SUNDRY#312-232,DRILL PERMIT#212-084 Printed 8/7/2012 3:05:45PM North America ALASKA- BP • Page 2 of 11 Operation Summary Report Common Well Name:07-22 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 7/13/2012 End Date: 7/20/2012 X3-01284-C: (2,423,935.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:NORDIC 2 Spud Date/Time:3/7/1983 12:00:00AM Rig Release:7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322'W Active Datum:Kelly Bushing/Rotary Table©58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 14:30 4.50 BOPSUR P DECOMP NIPPLE UP 7-1/16"BOP STACK TO 7-1/16" SWAB FLANGE,CONSISTING OF FOLLOWING FROM TOP DOWN: -HYDRIL GK ANNULAR PREVENTER -TOT BLIND-SHEAR RAMS -TOT 2-3/8"COMBI SLIP PIPE RAMS FLOW CROSS WITH 3-1/8"INNER MANUAL GATE VALVES AND 3-1/8"OUTER HCR VALVES ON BOTH KILL AND CHOKE LINES 2-3/8"X 3-1/2"TOT VB RAMS -2-3/8"COMBI SLIP PIPE RAMS WITH TWO VALVES OUTLET NIPPLED UP BELOW. 14:30 - 16:30 2.00 BOPSUR P DECOMP RIG UP TO PRESSURE TEST BOPE. FLOOD AND GREASE MANIFOLDS. 16:30 - 00:00 7.50 BOPSUR P DECOMP ,PRESSURE TEST BOPE PER ADWOP AND AOGCC REGULATIONS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(ALL PASSING TESTS,SEE ATTACHED DOCUMENTATION). STATE'S RIGHT TO WITNESS WITNESS TEST WAIVED BY AOGCC REPRESENTATIVE,CHUCK SCHEVE. - -TEST ANNULAR AND COMBI SLIP RAMS -WITH 2-3/8"TEST JOINT TEST VB RAMS WITH 2-3/8"AND 3-1/2"TEST JOINTS. -RIG GAS ALARMS TESTED -ALL COMPONENTS FUNCTIONED FROM BOTH REMOTE PANELS. -TWO FULL OPENING SAFETY VALVES TESTED -ALL BOP COMPONENTS VISUALLY INSPECTED PER HIGH GOR SOP ON 7/13/2012 7/15/2012 07:00 - 09:00 2.00 KILLW P WEXIT ALLOW PRESSURE TO BLEED OFF. BRING FLUID INTO PITS. MONITOR WELL FOR 15 MINUTES FOLLOWING WELL KILL. NO FLOW BACK. PRESSURE INDICATORS SHOW WELL TAKING FLUID. DID NOT WANT TO LOWER HYDROSTATIC PRESSURE TO FAR SO CIRCULATED OVER THE TOP TO ESTABLISH A LOSS RATE. MICROMOTION, MANUAL AND PVT CORRELATE TO SHOW A 9-12 BPH LOSS RATE. HOLD RIG EVACUATION DRILL AND AAR. NOTIFY DRILL SITE OPERATOR AND SECURITY. 00:00 - 00:30 0.50 WHSUR P DECOMP HOLD PRE-JOB SAFETY MEETING FOR PULLING BPV. 00:30 - 01:00 0.50 WHSUR P DECOMP HOLD RIG EVAC/H2S DRILL AND AAR. Printed 8/7/2012 3:05:45PM • North America ALASKA BP • Page 3 of 11 Operation Summary Report Common Well Name:07-22 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:7/13/2012 End Date:7/20/2012 !X3-01284-C: (2,423,935.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time:3/7/1983 12:00:00AM Rig Release:7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322'W Active Datum: Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 04:00 3.00 WHSUR P DECOMP 1 RIG UP LUBRICATOR AND PRESSURE TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR 'FIVE MIN EACH(PASSING TESTS PER TEMPORARY PIPEWORK SOP). OPEN SWAB, MASTER AND SURFACE SAFETY VALVES. PUMP THROUGH BPV TO DETERMINE 35 PSI BELOW VALVE. ENGAGE AND PULL 5-1/8" GRAY K PLUG. CLOSE MASTER AND SSV AND CONFIRM LEAK TIGHT TO ESTABLISH BARRIERS. RDMO WELLS SUPPORT VALVE SHOP LUBRICATOR. 04:00 - 05:30 1.50 KILLW P DECOMP INSTALL AND PRESSURE TEST NIGHT CAP TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). HOLD PRE-JOB SAFETY MEETING FOR BULLHEAD KILL 05:30 - 07:00 1.50 KILLW r P DECOMP OPEN MASTER AND SSV VALVES. BULL HEAD KILL WELL AS FOLLOWS: -5 BBLS MEOH SPEAR -255 BBLS(1.5X TBG VOL)KCL AT 5 BPM, ICP 300 PSI, FCP=1600 PSI(PRESSURE STABILIZED AT 1600 PSI AT 200 BBLS AWAY) -50 BBL HI-VIS POWERVIS MUD PILL,5 BPM, ICP= 1600 PSI, FCP= 1600 PSI -120 BBLS POWERVIS MUD TO DISPLACE LEADING EDGE OF HI-VIS PILL AT PERFORATIONS,5 BPM, ICP=1520 PSI, FCP =1520 PSI. 09:00 - 10:30 1.50 WHIP P WEXIT PUMP E-LINE SLACK BACK.CUT 275-FT OF 2-3/8"COIL. 10:30 - 12:30 2.00 WHIP P WEXIT MAKE UP COIL CONNECTOR.PULL TEST TO 35K-GOOD TEST.PRESSURE TEST CONNECTION TO 500 PSI LOW,4000 PSI HIGH-GOOD TEST. PUMP SLACK FORWARD. TEST ELINE,LINE OK.CUT E-LINE TO LENGTH(3-FT).MAKE UP E-LINE CONNECTION AND TEST-GOOD TEST. 12:30 - 14:00 1.50 WHIP P WEXIT TEST CHECKS,PACKOFF AND LUBRICATOR TO 250 PSI LOW,3500 PSI HIGH.POP OFF AND CIRCULATE OUT REMAINING KCL AND BIOZAN FROM COIL.PUMP FORWARD ONE COIL VOLUME AT 2.7 BPM. 14:00 - 15:00 1.00 WHIP P WEXIT PJSM.PICK UP AND RUN IN HOLE WITH WHIPSTOCK,SETTING TOOL AND MWD TOOLS.SCRIBE TOOLFACE TO COILTRAK HOT. PICK UP INJECTOR AND MAKE UP COIL. PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). 15:00 - 15:30 0.50 WHIP P WEXIT FILL HOLE AND PREP TO RUN IN HOLE. Printed 8/7/2012 3:05:45PM • North America -ALASKA- BP Page 4 of 11 Operation Summary Report Common Well Name:07-22 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 7/13/2012 I End Date:7/20/2012 X3-01284-C: (2,423,935.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time:3/7/1983 12:00:00AM Rig Release: 7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322"W Active Datum: Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase i Description of Operations (hr) (ft) 15:30 - 20:00 4.50 WHIP P WEXIT i RIH WITH WHIPSTOCK ON COIL AT 60 FPM. PUMP AT 0.44 BPM IN AND 0.51 OUT WITH 785 PSI. NO ISSUES GETTING WHIPSTOCK TO DEPTH. LOSING—5 BPH TO FORMATION. MW IN/OUT=8.7 PPG. !LOG GR SIGNATURE ACROSS TOP SAG RIVER AND TOP SHUBLIK A. TIE-IN TO TOP SHUBLIK A FORMATION AT 9562'MD AND APPLY-15'CORRECTION. LOG CCL ACROSS WHIPSTOCK SETTING DEPTHS TO CONFIRM COLLAR LOCATIONS. 20:00 - 20:30 0.50 WHIP P WEXIT CLOSE EDC AND SET BAKER 4-1/2"X 7" WHIPSTOCK BY PRESSURING UP COIL TO 3600 PSI. TOP OF WHIPSTOCK SETA 5, BOTTOM AT 9783'MD. COLLAR ABOVE= 1976 'MD,BELOW=9800'MD. CONFIRM WHIPSTOCK IN PLACE BY SETTING 5 KLBS BACK DOWN. 20:30 - 23:00 2.50 WHIP P WEXIT .PULL OUT OF HOLE FROM WHIPSTOCK TOP AT 9765'MD TO BHA AT 81'MD. FLOW 'CHECK WELL PRIOR TO TRIP AND PRIOR TO BHA ENTERING BOP STACK. WELL STATIC. TRIP SHEET=-10 BBLS FOR TRIP(-5 BPH LOSSES TO FORMATION). LOG CCL ACROSS 9000'MD TO 9200'MD TO CONFIRM COLLARS DEPTHS FOR PROJECTED LINER TOP. HOLD KICK WHILE TRIPPING DRILL WITH AAR ;AND SIMULATE LINEUP TO MUD-GAS SEPARATOR. -SIMULATE FAILED SUPER CHOKE FOR DRILL COMPLEXITY. 23:00 - 00:00 1.00 WHIP P WEXIT LAYDOWN WHIPSTOCK SETTING TOOLS(ALL APPEAR TO HAVE PROPERLY FUNCTIONED). 7/16/2012 00:00 - 01:00 1.00 STWHIP P WEXIT MAKEUP MILLING ASSEMBLY AS FOLLOWS AND RUN IN HOLE. STAB ON WELL WITH INJECTOR AND PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). -HCC 3.8"DIAMOND MILL -HCC 3.8"GO/3.79"NO-GO DIAMOND STRING MILL -2-7/8'STRAIGHT MOTOR WITH 3-1/2" CENTRALIZER -2 JOINTS 2-3/8"PH-6 TUBING -3"COILTRAK TOOLS WITH NO HOT -BHAOAL= 121' Printed 8/7/2012 3:05:45PM North America -ALASKA- BP - . ��•' 11 Operation Summary Report Common Well Name:07-22 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 7/13/2012 End Date: 7/20/2012 X3-01284-C: (2,423,935.00) Project: Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time:3/7/1983 12:00:OOAM Rig Release:7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°1659.451"1 Long: 0148°34'10.322"W Active Datum:Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 04:30 3.50 STINHIP P WEXIT RUN IN HOLE WITH 3.8"MILLING ASSEMBLY FROM BHA AT 121'TO TOP OF WHIPSTOCK. PICKUP WEIGHT=43 KLBS,SLACKOFF=19 KLBS. DRY TAG WITH PUMPS OFF AT 9772.5. PICKUP AND RUN BACK AT IN HOLE WITH PUMPS AT 2.5 BPM. RE-TAG AT 9771.1'MD. LOG GR SIGNATURE ACROSS TOP OF SHUBLIK A FORMATION AND APPLY-16' CORRECTIONS(COMPARED TO-15' CORRECTION ON LAST RUN). SLOW PUMP RATES AT 9765'MD,8.7 PPG: MP#1: 0.5 BPM= 1230 PSI,1 BPM=1500 PSI MP#2: 0.5 BPM=1210 PSI,1 BPM=1520 PSI 04:30 - 17:00 12.50 STWHIP P WEXIT KICK OFF SIDETRACK AND MILL WINDOW IN 7"LINER. —. -TIME MILL FROM 9771.1'MD AT 1 FPH. -INITIAL PARAMETERS: 2.5 BPM,2625 PSI FREESPIN,25-50 PSI DIFFERENTIAL,0-0.2 -- KLBS WOB,8.7 PPG MW IN/OUT, ECD=10 -PPG,IA/OA=0/45 PSI. AVERAGE PARAMETERS FOR REMAINDER -OF MILLING;2.5 BPM,2805 PSI,MW IN/OUT= 8.7 PPG,-1-2 BPH LOSSES TO FORMATION, 15%FORMATION IN SAMPLES AT 9778'MD. ESTIMATE EXIT FROM CASING AT 9778'MD 17:00 - 22:00 5.00 STWHIR P WEXIT MILL RATHOLE OUTSIDE WINDOW FROM 9778'MD TO 9,787'MD. PUMPING AT 2.5 BPM WITH 2886 PSI AND 300 PSI DIFFERENTIAL. WOB 3K.ECD=10.0 PPG.MUD WEIGHT 8.7 PPG IN AND OUT.LOSSES STILL LESS THAN 2 BPH.OA-105 PSI,IA-5 PSI. SAMPLES AT 9787'MD INDICATE>75% FORMATION. ESTIMATED WINDOW DEPTHS ARE 9771'MD TO 9778'MD(7'LOWSIDE WINDOW EXIT COMPARED TO EXPECTED 9'WINDOW). 22:00 - 23:30 1.50 STWHIP P WEXIT REAM WINDOW THREE TIMES AT 1 FPM IN UP AND DOWN DIRECTIONS. DRY DRIFT WINDOW ONE TIME. NO DRAG OR SETDOWN ISSUES OBSERVED WHEN PASSING THROUGH WINDOW. PULL ABOVE WINDOW AND FLOWCHECK WELL. WELL IS STATIC. IA/OA=5/125 PSI 23:30 - 00:00 0.50 STWHIP P WEXIT PULL OUT OF HOLE FROM WINDOW AT 9771' MD TO 7000'MD AT MIDNIGHT(CONTINUE TO TOH ON 7/17/12);70-100 FPM,3 BPM,2625 PSI THROUGH OPEN EDC. 7/17/2012 00:00 - 01:30 1.50 STWHIP P WEXIT CONTINUE TO PULL OUT OF HOLE FROM 7000'MD AT MIDNIGHT TO BHA AT 121'MD. FLOW CHECK WELL PRIOR TO BHA ENTERING BOP STACK. WELL STATIC. 01:30 - 02:30 1.00 STWHIP P PROD1 LAYDOWN 3.8"WINDOW MILLING ASSEMBLY. MILLS APPEAR TO BE IN GOOD CONDITION. GAUGE MILLS(3.79"GO,3.78"NO-GO). Printed 8/7/2012 3:05:45PM �...,- • North America -ALASKA- BP • Page 6 of 11 Operation Summary Report Common Well Name:07-22 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 7/13/2012 End Date: 7/20/2012 1X3-01284-C: (2,423,935.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time:3/7/1983 12:00:00AM Rig Release:7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322'W Active Datum:Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (ft) 02:30 - 04:00 1.50 DRILL P PROD1 MAKEUP 4-1/4"BUILD ASSEMBLY AND SCRIBE IN HOLE. -3-3/4"X 4-1/4"HYCALOG SRR3211M-C3 BI-CENTER PDC BIT -2-7/8"BAKER ULTRA LOW-SPEED 2.7°AKO MUD MOTOR -3"COILTRAK TOOLS WITH RESISTIVITY -BHA OVERALL LENGTH=80'MD. STAB INJECTOR ON WELL AND PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). 04:00 - 06:00 2.00 DRILL N DFAL 9,787.00 PROD1 TROUBLESHOOT MWD TOOLS. UPON P f A RESOLVING COMPUTER ISSUE, DISCOVER ISSUE WIH WOB SENSOR. UNSTAB INJECTOR,CHANGEOUT TOOLS AND RESTAB INJECTOR ON WELL. PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). _. 06:00 08:30 2.50 DRILL P PROD'I RUN IN HOLE WITH 4-1/4"DRILLING -ASSEMBLY FROM BHA AT 80'TO PREVIOUSLY MILLED TO DEPTH OF 9787'MD. • LOG ACROSS TOP OF SHUBLIK A AND TIE-IN TO GR SIGNATURE. APPLY-15'CORRECTION (COMPARED TO-16'CORRECTION ON LAST Nel,..1 RUN). TAKE SLOW PUMP RATES n-re 08:30 - 10:00 1.50 DRILL P PROD1 DIRECTIONAL DRILL AHEAD TO 9,834-FT MD. PUMP AT 2.67 BPM WITH 3180 PSI, FREE SPIN 2900 PSI.WOB 2-3K.ROP 40-60 FPH. MUD WEIGHT IN AND OUT 8.7 PPG, ECD 10.1 PPG. VOLUME 363 BBLS.OA=90 PSI,IA=0 PSI. 10:00 - 12:00 2.00 DRILL P PROD1 DIRECTIONAL DRILL AHEAD TO 9,872-FT MD IN CONGLOMERATE AT REDUCED ROP OF- 12-18 FPH. PUMPING AT 2.64 BPM WITH 3040 PSI, FREE SPIN 2900 PSI.WOP 1-3K. MUD WEIGHT IN AND OUT 8.7 PPG, ECD 10.1 PPG. VOLUME 359 BBLS.OA=110 PSI,IA=0 PSI. 12:00 - 15:00 3.00 DRILL P PROD1 DIRECTIONAL DRILL AHEAD TO 9950'MD;2.6 BPM,2900 PSI FREESPIN,3000-3200 PSI, WOB=1-3 KLBS,MUD WEIGHT IN AND OUT= 8.7 PPG,ECD=10.2 PPG. 15:00 - 16:30 1.50 DRILL P PROD1 PERFORM WIPER TRIP FROM 9950'MD TO 9200'MD(50' INSIDE 4-1/2"TUBING TAIL)TO CLEAN 7"LINER BETWEEN TUBING TAIL AND WINDOW. NO OPEN HOLE ISSUES OBSERVED. LOG GR ACROSS TOP OFF SHUBLIK A AND APPLY+1'CORRECTION. LOCATE WHIPSTOCK RA TAG AT 9777'MD ON TRIP IN HOLE. Printed 8/7/2012 3:05:45PM • North America -ALASKA- BP Operation Summary Report Common Well Name:07-22 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 7/13/2012 End Date:7/20/2012 X3-01284-C: (2,423,935.00) Project: Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time:3/7/1983 12:00:00AM Rig Release:7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322"W Active Datum: Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth I Phase ' Description of Operations (hr) (ft) 17:00 - 00:00 7.00 DRILL P PROD1 DIRECTIONAL DRILL 4-1/4"BUILD HOLE SECTION FROM 9950'MD TO 10260'MD AT IVUIDNIGHT(310'IN 7 HRS=44 FPH WITH WIPER TRIPS INCLUDED);2.6 BPM,2950 PSI FREESPIN,3100-3250 PSI,1-4 KLBS WOB,MW IN/OUT=8.8 PPG. ECD-10.2 PPG. NO LOSSES TO FORMATION WHILE DRILLING. IA /OA=2/170 PSI. LAND BUILD SECTION IN ZONE 2A AT 10190' MD,9036'TVD. PERFORM ROUND TRIP WIPER TRIPS TO WINDOW AT 9771'MD,30 FPM,AT 10100'MD AND 10260'MD PER CTD RECOMMENDED PRACTICES. PICKUP WEIGHTS=41-43 KLBS, SLACKOFF=22 KLBS. NO HOLE ISSUES ENCOUNTERED DURING WIPERS. SLOW PUMP RATES AT 10100'MD,8.8 PPG: MP#1: 0.5 BPM= 1470 PSI,1 BPM= 1750 PSI MP#2: 0.5 BPM= 1450 PSI,1 BPM= 1780 PSI 7/18/2012 00:00 - 02:15 2.25 DRILL P PROD1 (DIRECTIONAL DRILL 4-1/4"LATERAL HOLE tSECTION FROM 10260'MD AT MIDNIGHT TO 110410'MD(150'IN 2.25 HRS=67 FPH);2.6 BPM,2950 PSI FREESPIN,3000-3500 PSI,2-5 KLBS WOB,NO LOSSES TO FORMATION WHILE DRILLING. MW IN/OUT=8.8 PPG. ECD=10.3 PPG. IA/OA=5/175 PSI. 02:15 - 04:00 1.75 DRILL P PROD1 PERFORM WIPER TRIP FROM 10410'MD TO WINDOW AT 9771'MD;2.6 BPM,2950 PSI OFF BOTTOM PRESSURE,30 FPM. NO HOLE ISSUES. OPEN EDC AND JET 7"LINER FROM WINDOW AT 9771'MD TO 4-1/2"TUBING TAIL AT 9257'MD. CLOSE EDC AND RUN BACK IN HOLE TO PREVIOUSLY DRILLED DEPTH OF 10410'MD. NOTE: BUILD SECTION DETERMINED TO HAVE LANDED IN TAR AND LOW PERCENTAGE OF MOVEABLE OIL IS PRESENT. DECISION WITH GEOLOGISTS TO ABORT PLAN FOR 07-22A AND BEGIN NEW— DIRECTIONAL PLAN UNDER PERMIT TO DRILL #212-085. NEW PLAN IS TO BUILD BACK UP ABOVE 24N SHALE AND TURN DIRECTIONALLY DUE NORTH. WELL NAME WILL REMAIN 07-22A,API NUMBER WILL CHANGE TO 50-029-20925-02-00, PERMIT TO DRILL NUMBER WILL BE 212-085 PER ODE COMMUNICATION WITH STATE OF ALASKA. LOG ACROSS WHIPSTOCK RA TAG AND APPLY+2'CORRECTION. 04:00 - 06:30 2.50 DRILL P PROD1 DIRECTIONAL DRILL 4-1/4"LATERAL HOLE SECTION FROM 10410'MD TO 10560'MD(150' IN 2.5 HRS=60 FPH);2.6 BPM,2950 PSI FREESPIN,3000-3300 PSI,2-4 KLBS WOB,NO LOSSES TO FORMATION WHILE DRILLING. MW IN/OUT=8.8 PPG. ECD=10.3 PPG. IA/ OA=5/175 PSI. Printed 8/7/2012 3:05:45PM North America-ALASKA- BP Page 8 of 11 Operation Summary Report Common Well Name:07-22 AFE No Event Type. RE-ENTER-ONSHORE(RON) Start Date: 7/13/2012 End Date 7/20/2012 X3-01284-C: (2,423,935.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time.3/7/1983 12:00:OOAM Rig Release. 7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322"W Active Datum:Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 07:30 1.00 DRILL P PROD1 POOH FOR AKO AND BIT CHANGE. PULL THROUGH WINDOW AND OPEN EDC. FLOW CHECK WELL. 07:30 - 09:00 1.50 DRILL P PROD1 FLOW CHECK SHOWS NO FLOW. POOH TO SURFACE. PUMP 3.2 BPM WHILE PULLING OUT. 09:00 - 10:30 1.50 DRILL P PROD1 TAG STRIPPER AND FLOW CHECK WELL. TRIP SHEET IS-6 BBLS CUMULATIVE. LAY DOWN BHA. BIT IS 1-3. CHANGE OUT BIT, DGS AND CHANGE AKO SETTING OF MOTOR TO 1.2 DEG 10:30 - 11:00 0.50 DRILL P PROD1 M/U BHA#5-HYC RE-RUN BICENTER WITH 3" COILTRAK,WITH'RES. BHA OAL=80.41 FT. PRESSURE TEST QUICK TEST SUB. 11 00 - 13 00 2.00 DRILL P PROD1 RIH BHA#5. TIE IN DEPTH TO FORMATION,CORRECT-15 FT: PASS THROUGH WINDOW WITH NO ISSUES AT 160L. 13:00 - 15:00 2.00 DRILL P PROD1 MAD PASS INTERVAL 10248 FT BACK TO .10020 FT WITH RES TO TRY AND SPOT MHO INTERFACE. • SLOW PUMP RATES AT 10560'MD,8.8 PPG: MP#1: 0.5 BPM=1523 PSI,1 BPM=1860 PSI MP#2: 0.5 BPM=1450 PSI,1 BPM=1864 PSI 15:00 - 18:00 3.00 DRILL P PROD1 DIRECTIONAL DRILL 4-1/4"LATERAL HOLE SECTION FROM 10560'MD TO 10700'MD. HOLD 95L FOR NOW TO CONTINUE LH TURN AND STAY IN THE NEW POLYGON. ROP IS 40-60 FT/HR WITH 3-4K DWOB. DISPLACE WELL TO NEW 8.9 PPG POWERVIS UPON RETURNING TO DRILL AHEAD. 18:00 - 19:30 1.50 DRILL P PROD1 PERFORM ROUND TRIP FROM 10700'MD TO 7"LINER WINDOW AT 9771'MD TO WIPE HOLE;30 FPM. NO HOLE ISSUES ENCOUNTERED. 19:30 - 22:30 3.00 DRILL P PROD1 DIRECTIONAL DRILL 4-1/4"LATERAL HOLE SECTION FROM 10560'MD TO 10750'MD,2.6 BPM.3100-3300 PSI.3050 PSI FREESPIN.1-4 KLBS WOB, MW IN/OUT=8.9 PPG, ECD= 10.2 PPG. NO LOSSES TO FORMATION WHILE DRILLING. IA/OA=0/150 PSI. ABLE TO SET 1-3 KLBS WEIGHT DOWN AT 10750'MD, BUT UNABLE TO BUILD DIFFERENTIAL PRESSURE OR MAKE NEW FOOTAGE. DECISION TO TRIP FOR NEW BIT. SLOW PUMP RATES AT 10730'MD,8.9 PPG: MP#1. 0.5 BPM=1350 PSI,1 BPM= 1750 PSI _ MP#2: 0.5 BPM=1360 PSI,1 BPM=1765 PSI Printed 8/7/2012 3:05:45PM • North America -ALASKA- BP 111 Page 9 of 11 Operation Summary Report Common Well Name:07-22 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 7/13/2012 End Date: 7/20/2012 X3-01284C: (2,423,935.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:NORDIC 2 Spud Date/Time:3/7/1983 12:00:00AM Rig Release:7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322"W Active Datum:Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 00:00 1.50 DRILL P PROD1 FLOWCHECK WELL.WELL IS STATIC. PULL OUT OF HOLE FROM 10750'MD TO 7"LINER WINDOW AT 9777'MD. OPEN EDC AND FLOWCHECK WELL. WELL STATIC. PULL OUT OF HOLE FROM WINDOW AT 9777'MD TO 8000'MD AT MIDNIGHT. 7/19/2012 00:00 - 01:00 1.00 DRILL P PROD1 TRIP OUT OF HOLE FROM 8000'MD AT MIDNIGHT TO 4300'MD;70-100 FPM,2.9 BPM, 2700 PSI WITH OPEN EDC. 01:00 - 01:30 0.50 DRILL N HMAN 4,300.00 PROD1 WHILE POOH THE SSV FITTING IN THE CELLAR IS CONTACTED WITH A LADDER AND BROKEN. NOTIFICATION MADE TO CTD SUPT. STOP OPERATION AND REPAIR SSV FITTING. RE-OPEN SSV VALVE SPOOL CT BACK AND INSPECT, NO DAMAGE TO COIL FOUND. tCONTINUE POOH. 01:30 - 02:30 1.00 DRILL P PROD1, TRIP OUT OF HOLE FROM 4300'MD TO BHA AT 80'MD. FLOWCHECK WELL PRIOR TO BHA ENTERING STACK. WELL STATIC. 02:30 - 03:00 0.50 DRILL • P PROD1 UNSTAB INJECTOR AND SET BACK. BREAK BIT AND LAYDOWN. GRADE HYCALOG SRX3611 M-B3 3-3/4"X 4-1/4" BI-CENTER 8-3-RU-N-X-I-BU-PR. MAKEUP NEW BIT TO SAME BHA AND RUN IN HOLE TO 80'MD. STAB ON WELL WITH INJECTOR. PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). -3-3/4"X 4-1/4"HYCALOG SRR3211 M-C3-Z BI-CENTER REBUILD PDC BIT -2-7/8"BAKER ULTRA LOW-SPEED 1.2°AKO MUD MOTOR -3"COILTRAK TOOLS WITH RESISTIVITY -BHA OVERALL LENGTH=80'MD. 03:00 - 06:00 3.00 DRILL P PROD1 TRIP IN HOLE FROM BHA AT 80'MD TO PREVIOUSLY DRILLED MD OF 10750'MD. NO HOLE ISSUES ENCOUNTERED. LOG ACROSS WHIPSTOCK RA TAG TO TIE-IN AND APPLY-15'CORRECTION(COMPARED TO-15' LAST RUN). SLOW PUMP RATES AT 10750'MD,8.9 PPG: MP#1: 0.5 BPM= 1428 PSI,1 BPM= 1787 PSI MP#2: 0.5 BPM=1482 PSI,1 BPM=1790 PSI 06:00 - 10:00 4.00 DRILL P PROD1 DIRECTIONAL DRILL 4-1/4"LATERAL HOLE SECTION FROM 10750'MD TO 10900'MD(150' IN 4 HOURS=38 FPH);2.6 BPM,3050 PSI FREESPIN,3100-3400 PSI,1-4 KLBS WOB,MW IN/OUT=8.9 PPG. ECD= 10.3 PPG. NO LOSSES TO FORMATION WHILE DRILLING. IA/OA=5/200 PSI. MAINTAIN 90 DEG INC TO TD. 10:00 - 11:00 1.00 DRILL P PROD1 WIPER TRIP FROM 10900 FT TO WINDOW. CLEAN PASS UP AND DOWN. 11:00 - 13:30 2.50 DRILL P PROD1 DRILL FROM 10900 FT. CALL TD AT 11000 FT, NEARING THE END OF THE POLYGON. Printed 8/7/2012 3:05:45PM North America-ALASKA- BP ' Page 10 of 11 Operation Summary Report Common Well Name:07-22 AFE No • Event Type: RE-ENTER-ONSHORE(RON) Start Date:7/13/2012 End Date:7/20/2012 X3-01284-C: (2,423,935.00) Project: Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 3/7/1983 12:00:00AM Rig Release:7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322"W Active Datum: Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 16:00 2.50 DRILL P PROD1 WIPER TRIP FROM TD TO WINDOW. PULL THROUGH WINDOW AND OPEN EDC. PUMP 1 B/U AT 4 BPM. LOG GR TO TIE-IN DEPTH,CORRECT+3.5 FT. CLOSE EDC AND RUN BACK IN TO BOTTOM. TAG BOTTOM AT 11002'MD,9018'TVD OFFICIAL TD. 16:00 - 17:30 1.50 DRILL P PROD1 PERFORM ROUND WIPER TRIP BETWEEN TD AND 7"LINER WINDOW AT 9771'MD TO 'CONFIRM HOLE IS CLEAN. NO EXTRA DRAG WHILE TRIPPING IN OR OUT OF HOLE. 17:30 - 20:30 3.00 DRILL P PROD1 PULL OUT OF HOLE FROM WELL TOTAL DEPTH AT 11002'MD TO WINDOW AT 9771' MD, LAYING IN CLEAN 8.9 PPG POWERVIS MUD LOGGING PILL. OPEN EDC AT WINDOW AND FLOW CHECK WELL(STATIC). PULL OUT OF HOLE FROM 9771'MD TO BHA AT 80' MD AND FLOWCHECK WELL. WELL STATIC. 20:30 - 21:00 0.50 DRILL P PROD1 UNSTAB INJECTOR FROM WELL AND STAND BACK ON RIG FLOOR. LAYDOWN 4-1/4" DRILLING ASSEMBLY. HYCALOG BIT GRADED 3-1-BT-N-X-I-WT-TD. DAYS PER 10K FROM WINDOW MILLING SPUD TO LD DRLG BHA=29.94 DAYS 21:00 - 21:30 0.50 EVAL P PROD1 CUT OFF CONNECTOR AND CUT 100'2-3/8" ICOIL FOR CHROME MANAGEMENT. NEW COIL LENGTH= 15590',VOLUME=57.8 BBLS. 21:30 - 23:30 2.00 EVAL P PROD1 MAKEUP NEW SLB KENDLE COILED TUBING CONNECTOR. PULL TEST TO 35 KLBS. MAKEUP BHI E-LINE HEAD AND TEST(PASS). 23:30 - 00:00 0.50 EVAL P PROD1 I STAB ON WELL WITH INJECTOR AND LINE UP TO PRESSURE TEST LUBRICATOR AND NEW DUAL FLAPPER CHECK VALVES. 7/20/2012 00:00 - 00:30 0.50 EVAL P PROD1 COMPLETE PRESSURE TEST OF LUBRICATOR AND DFCVS TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH '(PASSING TESTS). UNSTAB INJECTOR AND SETBACK ON RIG FLOOR. 00:30 - 02:00 1.50 EVAL P PROD1 MAKEUP PDS 40 ARM CALIPER LOGGING ASSEMBLY ON 3"COILTRAK TOOLS(NO HYDRAULIC ORIENTING TOOL OR RESISTIVITY). STAB ON WELL WITH INJECTOR. PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). -BHA OVERALL LENGTH=56' -CALIPER ARMS PROGRAMMED TO OPEN IN 4 HRS(05:30) 02:00 - 05:00 3.00 EVAL P PROD1 'TRIP IN HOLE WITH CALIPER LOGGING ASSEMBLY FROM BHA AT 56'MD TO WELL TOTAL DEPTH AT 11002'MD;80 FPM;0.3-0.8 BPM. NO HOLE ISSUES ENCOUNTERED. LOG GR ACROSS TOP OF SAG RIVER FORMATION AND APPLY-14'CORRECTION TO COIL DEPTH(COMPARED TO-15' CORECTION ON LAST RUN). Printed 8/7/2012 3:05:45PM Page 11 of 11 North America -ALASKA- BP � Operation Summary Report Common Well Name.07-22 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date. 7/13/2012 End Date: 7/20/2012 X3-01284-C: (2,423,935 00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.:NORDIC 2 Spud Date/Time:3/7/1983 12:00:00AM Rig Release:7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322'W Active Datum:Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 05:30 0.50 EVAL P PROD1 RECIPROCATE PIPE WHILE WAITING FOR CALIPER ARMS TO OPEN. SLOW PUMP RATES AT 11002'MD,8.9 PPG: MP#1: 0.5 BPM=1400 PSI,1 BPM=1750 PSI MP#2: 0.5 BPM=1350 PSI,1 BPM=1740 PSI 05:30 - 07:00 1.50 EVAL P PROD1 LOG WITH 40 ARM CALIPER FROM WELL TOTAL DEPTH AT 11002'MD TO 7970'MD (1000' INSIDE 4-1/2"PROD TUBING);30 FPM. 0.3 BPM. PAINT EOP FLAGS FOR LINER RUN AT 8800' AND 7500'WHILE LOGGING AND PULL OUT OF HOLE. 07:00 - 09:30 2.50 EVAL P PROD1 PULL OUT OF HOLE FROM 7970'MD TO BHA AT 56'MD. 09:30 - 10:00 0.50 EVAL P PROD1 TAG STRIPPER AND FLOWCHECK WELL (STATIC). TRIP SHEET IS-4 CUMULATIVE. L/D BHA AND DOWNLOAD DATA. DATA IS GOOD, SEND TO PDS IN HOUSTON FOR ANALYSIS. END RON EVENT AT 10:00 on 7/20/2012 Printed 8/7/2012 3.05.45PM North America -ALASKA- BP Page 1 of 7 Operation Summary Report Common Well Name:07-22 1AFE No Event Type: COM-ONSHORE(CON) Start Date:7/20/2012 End Date:7/24/2012 X3-01284-C: (1,105,787.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 3/7/1983 12:00:00AM Rig Release:7/24/2012 Rig Contractor: NORDIC CALISTA UWI:/Lat:070°1659.4511 Long: 0148°34'10.322'W Active Datum:Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/20/2012 10:00 - 10:30 0.50 BOPSUR P RUNPRD BEGIN CON EVENT AT 10:00 HRS ON 7/20/12 WITH NORDIC 2 CTD RIG. FUNCTION TEST ALL BOPS EXCEPT BLIND-SHEAR RAMS FROM RIG FLOOR REMOTE STATION. 10:30 - 11:30 1.00 CASING P RUNPRD PREP RIG FLOOR TO PUMP SLACK OUT OF -CT. PLACE INJECTOR OVER CIRC HOLE AND PUMP 3.5 BPM. PUMP OUT 213 FT OF CABLE SLACK, SPREADSHEET SHOWS 270 FT. 11:30 - 12:00 0.50 CASING P RUNPRD INSTALL CABLE BOOT. REMOVE SLB CONNECTOR. PREP END OF CT FOR BTT CONNECTOR. 12:00 - 13:20 1.33 CASING P RUNPRD INSTALL BTT CONNECTOR. PULL TEST TO 35K,GOOD. PRESSURE TEST TO 3500 PSI,GOOD. 13:20 - 14:30 1.17 CASING P RUNPRD INSTALL STINGER AND BALL CATCHER NOZZLE ON CT. MOVE INJECTOR OVER CIRC HOLE. PUMP 3/4"DRIFT BALL AROUND. LEAVES REEL HOUSE AT 47 BBLS, CALCULATED REEL VOLUME IS 58 BBLS. 14:30 - 15:30 1.Q0 CASING P RUNPRD PREP RIG FLOOR TO M/U LINER. 15:30 - 23:00 7.50 CASING P RUNPRD MAKEUP AND RUN IN HOLE WITH 3-1/2"X 3-1/4"X 2-7/8"PRODUCTION LINER+4 JOINTS PH-6 TUBING FOR E-LINE SAFETY MARGIN. CONFIRM FLOATS ARE HOLDING. DRIFT FIRST FIVE JOINTS OF 2-7/8"LINER AND FIRST FIVE 3-1/4"JOINTS. FILL LINER WITH FRESH WATER THROUGH HOSE EVERY 1000' MD. MAKEUP TORQUES ARE AS FOLLOWS: 2-7/8",6.4#, L-80,ST-L: 800-1000 FT-LBS 3-1/4",6.6#, L-80(3-3/16",6.2#,TC-II): 1200-1400 FT-LBS 3-1/2",9.2#, L-80,ST-L: 1400-1800 FT-LBS TOTAL LINER LENGTH=1896' HOLD KICK WHILE TRIPPING DRILLS WITH EACH CREW. STAB SAFETY JOINTS TO SECURE WELL. 23:00 - 00:00 1.00 CASING P RUNPRD STAB ON WELL WITH INJECTOR. PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). CIRCULATE WATER OUT OF LINER AND HOLE. Printed 8/7/2012 3:05:54PM North America -ALASKA- BP Page 2 of 7 Operation Summary Report Common Well Name:07-22 AFE No Event Type: COM-ONSHORE(CON) Start Date:7/20/2012 End Date:7/24/2012 X3-01284-C:(1,105,787.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time:3/7/1983 12:00:00AM Rig Release:7/24/2012 Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322"W Active Datum: Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/21/2012 00:00 - 02:15 2.25 CASING P RUNPRD RUN IN HOLE WITH PRODUCTION LINER ON 2-3/8"COIL FROM TOTAL BHA LENGTH AT 2036'MD TO FIRST FLAG AT 9536'MD (WINDOW AT 9771'MD);85 FPM,0.2 BPM, 1375 PSI. APPLY-19'CORRECTION TO DEPTH(COMPARED TO-14'CORRECTION ON LAST RUN). PICKUP WEIGHT AT WINDOW= 46 KLBS,SLACK OFF=23 KLBS. CONTINUE TO RUN IN HOLE FROM WINDOW TO HARD BOTTOM AT 10998'MD(DRILLING TD WAS 11002'MD);75 FPM,0.3 BPM,1400 PSI. SECOND FLAG OBSERVED ON DEPTH AT 10836'MD. NO HOLE ISSUES ENCOUNTERED. MW IN/OUT=8.9 PPG, IA/OA =0/50 PSI. RIG CREW DRAINING PITS AND PREPARING 100 BBLS BIOZAN/CITRIC CONTAMINATION FLUID. CONFIRM LINER ON BOTTOM WITH TWO TAGS. FINAL PICKUP WEIGHT NEAR LANDING DEPTH=56 KLBS,SLACKOFF= 19 KLBS. 02:15 - 02:30 0.25 CASING. P RUNPRD STACK 10 KLBS DOWN WEIGHT ON LINER AND ESTABLISH CIRCULATION AT 2 BPM, 2565 PSI, FULL RETURNS. 102:30 - 03:30 1.00 CASING P RUNPRD PUMP 10 BBLS 8.9 PPG KCL AND SHUT DOWN PUMPS. LAUNCH 5/8"STEEL BALL WITH 1500 PSI. CIRCULATE BALL DOWN TO SELRT BALL SEAT WITH 8.9 PPG KCL AT 2 BPM,2000 PSI. DROP RATE TO 0.75 BPM, 1900 PSI AT 70%COIL VOLUME. LAND BALL ON SEAT AT 48.8 BBLS(COIL VOLUME=57.8 BBLS). SHEAR BALL SEAT AT 4300 PSI. PICKUP TO BREAKOVER WEIGHT+2'TO CONFIRM LINER HAS BEEN RELEASED. NEW PICKUP WEIGHT=41 KLBS(15 KLBS LESS THAN WHEN LINER LANDED). SET BACK DOWN WITH 10 KLBS ON LINER. 03:30 - 07:20 3.83 CASING P RUNPRD COMPLETE WELL DISPLACEMENT FROM 8.9 PPG POWERVIS MUD TO 8.9 PPG KCL;2.5 BPM, FINAL CIRCULATING PRESSURE AT 1.5 BPM WITH WELL DISPLACED TO KCL=860 PSI. MIRU SCHLUMBERGER CEMENTING EQUIPMENT. 07:20 - 08:00 0.67 CEMT P RUNPRD PJSM. PRESSURE TEST TEST CEMENT LINE 250/6000 PSI. GOOD PT,PRESSURE LOSS WITHIN ACCEPTABLE CRITERIA.,VISUAL CONFIRMATION OF NO LEAKS. 08:00 - 09:00 1.00 CEMT P RUNPRD PJSM FOR PUMPING CEMENT JOB WITH SLB, CH2, NORDIC RIG CREW. BATCH UP CEMENT. 09:00 - 09:20 0.33 CEMT P RUNPRD SLB PUMP UNIT PUMP 22.1 BBLS OF 15.8 PPG CLASS G CEMENT INTO CT THEN SHUT BOWN. Printed 8/7/2012 3:05:54PM North America ALASKA- BP • Page 3 of 7 O•eration Summary Report Common Well Name 07-22 AFE No Event Type: COM-ONSHORE(CON) Start Date: 7/20/2012 End Date: 7/24/2012 X3-01284-C: (1,105,787.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time: 3/7/1983 12:00:OOAM Rig Release:7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°1559.4511 Long: 0148°34'10.3221W Active Datum:Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:20 - 09:50 0.50 CEMT P RUNPRD CLEAN UP LINE GOING BACK TO CEMENT UNIT LINE UP RIG PUMP TO CT TO START CEMENT DISPLACEMENT. SLOW TO 1.2 BPM WHEN LEADING EDGE OF CEMENT IS PASSING LWP. ZERO OUT MM AT 49.7 BBLS IN,CEMENT IS EXITING THE SHOE. 09:50 - 11:00 1.17 CEMT P RUNPRD AT 56.3 BBLS IN,2 BBLS LEFT ABOVE THE SELRT. PICK UP CT WEIGHT+ 13 FT. SET 10K BACK DOWN.NOW 10 FT HIGHER. PUSH PEE WEE DART INTO LWP, PRESSURE UP TO 700 PSI. PICK UP AND SIDE EXHAUST 5 BBLS. STACK 10K BACK DOWN AND PRESSURE UP TO LAUNCH LWP. SHEARS AT 2900 PSI. PUSH LWP DOWN AT 2-2.5 BPM. BUMP PLUG AT 13.2 BBLS. RIGHT AT CALCULATED VOLUME. OPEN BAKER CHOKE AND CHECK FLOATS (HOLDING) .PULL OUT OF DEPLOYMENT SLEEVE AND CIRC 5 BBLS AT MIN RATE CEMENT IN PLACE AT 10:20. PUMPED 21.5 BBLS CEMENT BEHIND PIPE. ALL JOB PARAMETERS WERE NORMAL AND NO LOSSES WERE OBSERVED. TOP OF CEMENT ESTIMATED AT 9586'MD 0-1/2"X 3-1/4"XO) TOP OF LINER AT 9106 MD(665 LINER LAI' WIDE WINDOW). 11:00 - 12:10 1.17 CASING P RUNPRD POOH FROM LINER TOP TO SURFACE, MAINTAINING OUT RATE AT 0.5 BPM WHILE POOH. 12:10 - 13:50 1.67 CASING P RUNPRD TAG STRIPPER AND FLOWCHECK WELL. TRIP SHEET IS-7 BBLS FOR THE TRIP. FLOWCHECK IS GOOD. UD 4 JTS OF PH6 AND LINER RUNNING TOOLS. TOOLS HAVE FUNCTIONED NORMALLY. RECOVER 5/8"STEEL BALL. 10'EXTRA E-LINE FOUND HANGING INSIDE PH-6 PIPE. OFFLOAD LINER RUNNING EQUIPMENT. 13:50 - 14:10 0.33 EVAL P OTHCMP PJSM FOR RUNNING CSH AND MCNL-GR-CCL TOOL. REVIEW RISK ASSESSMENT FOR RUNNING CSH. 14:10 - 14:30 0.33 EVAL P OTHCMP PREP RIG FLOOR FOR RUNNING CSH AND LOGGING TOOLS. Printed 8/7/2012 3:05:54PM • North America ALASKA- BP • Page 4 of 7 Operation Summary Report Common Well Name:07-22 AFE No Event Type: COM-ONSHORE(CON) Start Date: 7/20/2012 End Date: 7/24/2012 X3-01284-C:(1,105,787.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time:3/7/1983 12:00:OOAM Rig Release:7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322'W Active Datum:Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 20:15 5.75 EVAL P OTHCMP M/U BHA#9-2.3"MILL CLEANOUT AND MEMORY GR/CCL/CNL LOGGING ASSEMBLY, INCLUDING 34 STANDS 1-1/4"CSH PIPE FROM DERRICK. -2.3"HUGHES D331 MILL -2-1/8"XTREME STRAIGHT MUD MOTOR SLB MEMORY LOGGING TOOLS -TWO DISCONNECTS,CIRC SUB,BUAL BPV, 4 JOINTS PH-6 FOR E-LINE -BHA OVERALL LENGTH=2332' STAB ON WELL WITH INJECTOR AND PRESSURE TEST QUICK TEST SUB TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). 20:15 - 21:30 1.25 EVAL P OTHCMP RUN IN HOLE FROM'BHA AT 2332'MD TO LOGGING START DEPTH AT 8900'MD. 21:30 - 00:00 2.50 EVAL ` P 'OTHCMP LOG DOWN FROM 8900'TO HARD TAG DEPTH AF 10978'MD UNCORRECTED(LINER TALLY PBTD= 10964'MD);30 FPM,1.25 BPM,1250 PSL NO ISSUES ENTERING LINER TOP OR CLEANING OUT TO PBTD. LOG UP FROM -10978'MD UNCORRECTED PBTD TO 8900'MD (LINER TOP AT 9106'MD);60 FPM,1.5 BPM. NO CEMENT RETURNS TO SURFACE AND NO MILLING REQUIRED. FLOWCHECK WELL AT 8900'MD(WELL STATIC). LAY IN PERF PILL OF NEW 8.8 PPG KCL AND PAINT 8200'EOP FLAG ON TRIP OUT OF HOLE. 7/22/2012 00:00 - 01:30 1.50 EVAL R OTHCMP PULL OUT OF HOLE FROM 8900'MD TO BHA AT 2332'MD;80-100 FPM. 01:30 - 04:30 3.00 EVAL P OTHCMP RACK BACK 39 STANDS 1-1/4"CSH PIPE. HOLD PJSM AT 300'FROM SURFACE WITH LOGGING REP TO DISCUSS HAZARDS FROM RADIOACTIVE SOURCE IN CNL TOOL. 04:30 - 05:00 0.50 EVAL P OTHCMP LAYDOWN LOGGING TOOLS AND CLEAR RIG FLOOR. SLB REP CONFIRMS GOOD DATA. 05:00 - 06:30 1.50 CASING P RUNPRD INSTALL NIGHT CAP ON WELL. PRESSURE TEST LINER LAP AND NEW PRODUCTION LINER TO 250 PSI LOW FOR 5 MIN AND 2400 I$I HIGH FOR 30 MIN(FAILING HIGH TEST). -NO BREAKOVER OR INJECTION RATE ACHEIVED WHILE PRESSURING UP TO 2400 PSI. -PRESSURE BLEEDS OFF 150 PSVMIN -AUTHORIZATION TO PROCEED RECEIVED FROM WELL OPS MGR(DELEGATED FROM WTL). 06:30 - 07:00 0.50 PERFOB P OTHCMP PJSM FOR M/U PERF GUNS. REVIEW RISK ASSESSMENT FOR RUNNING CSH. 07:00 - 11:30 4.50 PERFOB P OTHCMP M/U PERF GUN BHA+34 STDS OF CSH. CONDUCT KICK WHILE TRIPPING DRILL AFTER 2 GUNS ARE RUN. 11:30 - 12:00 0.50 PERFOB P OTHCMP M/U INJECTOR TO RISER. PRESSURE TEST QTS LOW AND HIGH, GOOD. 12:00 - 14:10 2.17 PERFOB P OTHCMP RIH WITH BHA#10 FOR PERFORATING. Printed 8/7/2012 3:05:54PM • North America -ALASKA- BP Page 7 Operation Summary Report Common Well Name:07-22 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/20/2012 End Date: 7/24/2012 iX3-01284-C. (1,105,787.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.:NORDIC 2 Spud Date/Time. 3/7/1983 12.00.00AM Rig Release. 7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070°1559 451"1 Long 0148°3410.322"W Active Datum:Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:10 - 14:45 0.58 PERFOB P OTHCMP STOP AT FLAG AND CORRECT-17 FT TO 10853 FT.CONSISTENT WITH EARLIER CORRECTIONS WHILE DRILLING AND LOGGING. TAG PBTD LIGHTLY AT 10960.2 FT. REPEAT, SAME DEPTH.GET WEIGHT BACK AND CORRECT DEPTH+7 FT TO 10963 FT. 14:45 - 15:50 1.08 PERFOB P OTHCMP PULL UP TO JUST BELOW SHOT DEPTH AND GET 2 RATES FOR E-FIRE HEAD. GO THROUGH PUMP SEQUENCE TO ACTIVATE SLB E-FIRE HEAD. GET GOOD SHOT INDICATION FROM ACOUSTIC SENSOR AND FLUID LOSS. POOH HOLDING 200-300 PSI WHP WITH HAND CHOKE.KEEP PULLING SPEED AT 40 FT/MIN WHILE INSIDE LINER. PERFORATION SUMMARY: ZONE 2B(22TS FORMATION): 350'NET, 10600'MD TO 10950'MD,6 SPF 15:50 - 16 20 0.50 PERFOB P OTHCMP STOP AT 9050 FT FOR FLOW CHECK OF WELL ABOVE LINER TOP. TRIP SHEET IS -EVEN TO THIS POINT. FLOW CHECK SHOWS NO FLOW. 16:20 - 18:00 1.67 PERFOB P OTHCMP PULL OUT OF HOLE FROM 9050'MD TO CSH AND PER GUN BHA AT 2668'MD. 18:00 - 18:30 0.50 PERFOB P OTHCMP FLOWCHECK WELL FOR 30 MIN AFTER PERFORATING(WELL STATIC). TRIP SHEET IS EVEN. 18:30 - 19:00 0.50 PERFOB P OTHCMP CREW CHANGEOUT DAY. HOLD PJSM FOR LAYING DOWN PIPE 19:00 - 21:30 2.50 PERFOB P OTHCMP LAYDOWN 68 JOINTS 1-1/4"CSH PIPE. HOLD KICK WHILE TRIPPING DRILL-STAB SAFETY JOINT,SHUT TIW AND SIMULATE SHUTTING BOPS TO SECURE WELL. 21:30 - 23:30 2.00 PERFOB P OTHCMP LAYDOWN 17 SPENT PERFORATING GUNS HALL SHOTS CONFIRMED TO HAVE FIRED). 23:30 - 00:00 0.50 PERFOB P OTHCMP CLEAR RIG FLOOR AFTER TRIPPING. 7/23/2012 00:00 - 01:00 1.00 WHSUR P POST MAKE UP NOZZLE ASSEMBLY AND RUN IN HOLE 10 9'MD.STAB ON INJECTOR AND PRESSURE TEST QTS TO 250PSI LOW AND 3500PS1 HIGH FOR FIVE MIN EACH(PASSING TESTS). MIRU LITTLE RED SERVICES TO PUMP DIESEL FOR FREEZE PROTECT PRESSURE TEST LRS LINES TO 250PS1 LOW AND 2500PSI HIGH PER TEMPORARY PIPEWORK SOP(PASSING TESTS). 01:00 - 02:30 1.50 WHSUR P POST RUN IN HOLE TO 2550'MD,2500 TVD. LAY IN 39 BBLS 6.8 PPG,75 DEGF DIESEL TO FREEZE PROTECT WELL. FLOW CHECK WELL WHEN BACK AT SURFACE WELL STATIC UNSTAB INJECTOR AND SET BACK ON RIG FLOOR. NOTE CALCULATED OVERBALANCE TO 7 1 PPG FORMATION AT 8800'TVDSS WITH DIESEL IN PLACE IS 518 PSI. Printed 8/7/2012 3.05:54PM • North America -ALASKA- BP • Page 6 of 7 Operation Summary Report Common Well Name:07-22 AFE No Event Type:COM-ONSHORE(CON) Start Date: 7/20/2012 End Date: 7/24/2012 iX3-01284-C: (1,105,787.00) Project:Prudhoe Bay Site:PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time:3/7/1983 12.00:OOAM Rig Release: 7/24/2012 Rig Contractor:NORDIC CALISTA UWI:/Lat:070015'59.451"1 Long: 0148°34'10.322'W Active Datum:Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 05:00 2.50 WHSUR P POST GREASE TREE VALVES. MIRU VALVE SHOP LUBRICATOR CREW. CLOSE MASTER AND SSV. PRESSURE TEST LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH PER TEMPORARY PIPEWORK SOP(PASSING TESTS).SET 5-1/8" GRAY K BPV. CLOSE MASTER AND SSV WITH CORRECT TURNS AND STROKE LENGTH,BLEED OFF ABOVE VALVES AND CONFIRM LEAKTIGHT. RDMO LUBRICATOR CREW. MIRU SLB N2 PUMP UNIT. PRESSURE TEST LINES TO 250 PSI LOW AND 3000 PSI HIGH FOR FIVE MIN EACH PER TEMPORARY PIPEWORK SOP(PASSING TESTS). 05:00 - 06:30 1.50 RIGD P POST DISPLACE COIL REEL FROM 8.8 PPG KCL TO 8.4 PPG FRESH WATER. 06:30 - 07:30 1.00 RIGU P POST PJSM THEN PURGE REEL WITH N2. ALLOW IT TO BLEED OFF. 07:30 - 12:00 4.50 RIGD P POST LIFT UP INJECTOR AND REMOVE CT CONNECTOR. PULL CT ACROSS PIPE SHED ROOF AND -SECURE IT TO THE REEL REMOVE 1502 IRON FROM INSIDE REEL. DRESS CUT END OF CT SO IT WILL FIT THROUGH THE REEL BAY DOOR. 12:00 - 12:20 0.33 RIGD POST PJSM WITH CH2, NORDIC AND SLB FOR LOWERING REEL ONTO TRUCK. PERFORM HAZARD HUNT FOR POTENTIAL DROPPED OBJECTS ON AND AROUND THE REEL STAND. 12:20 - 14:00 1.67 RIGD P POST OPEN REEL BAY DOOR. LOWER REEL DOWN ONTO TRAILER. SECURE IT ON TRAILER. 14:00 - 20:30 6.50 RIGD P POST REMOVE INJECTOR GOOSENECK AND STRIPPER.REMOVE CT RISER SECTIONS FROM WELL. CONTINUE CLEANING PITS AND CUTTINGS BOX, INSTALL CATTLE CHUTE RAMS. 20:30 - 21:00 0.50 WHSUR P POST PERFORM LEAK TIGHT TEST TO 3500 PSI THROUGH WING VALVE AGAINST BOTTOM OF SWAB AND TOP OF SSV.CONFIRM NO FLOW THROUGH SWAB VALVE AND NO FLOW THROUGH SSV AFTER BLEEDING PRESSURE OFF. BARRIERS ESTABLISHED TO BREAK CONTAINMENT. 21:00 - 00:00 3.00 BOPSUR P POST OPEN BOP DOORS,CLEAN AND INSPECT RAMS. 7/24/2012 00:00 - 01:30 1.50 BOPSUR P POST NIPPLE DOWN BOP STACK AT SWAB VALVE FLANGE. 01:30 - 03:30 2.00 WHSUR P POST INSTALL TREE CAP AND PRESSURE TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS,RIG CREW WORKING ON GENERAL RIG DOWN OPERATIONS. 03:30 - 04:30 1.00 RIGD P POST GENERAL RIG DOWN OPERATIONS. WARM UP MOVING SYSTEM. HOLD PJSM FOR MOVING OFF WELL. Printed 8/7/2012 3:05:54PM ` • North America -ALASKA- BP • Page 7 of 7 Operation Summary Report Common Well Name:07-22 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/20/2012 End Date:7/24/2012 X3-01284-C: (1,105,787.00) Project:Prudhoe Bay Site: PB DS 07 Rig Name/No.: NORDIC 2 Spud Date/Time:3/7/1983 12:00:00AM Rig Release:7/24/2012 Rig Contractor: NORDIC CALISTA UWI:/Lat:070°15'59.451"1 Long: 0148°34'10.322'W Active Datum:Kelly Bushing/Rotary Table @58.00ft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 05:00 0.50 RIGD P POST PULL RIG OFF WELL AND STAGE ON DRILLSITE 7 WHILE PREPARING TO MOVE. 05:00 - 06:00 1.00 RIGD P POST CLEAN UP AROUND TREE/WELLHEAD. PREPARE TO MOVE RIG TO CC2A FOR ANNUAL SUMMER MAINTENANCE. -ALL TREE AND WELLHEAD VALVES LEFT CLOSED TO PRESSURE GAUGES. -FINAL IA/OA=0/25 PSI -TREE/WELLHEAD AND CELLAR CLEAN -WELLWORK TRANSFER PERMIT CLOSED OUT WITH DRILLSITE OPERATOR. WELL HANDOVER COMPLETED WITH WELLS GROUP(NOTE: LINER TOP PACKER MUST BE SET POST RIG) 10.17 DAYS FROM RIG ACCEPT TO RIG RELEASE ORIGINAL PERFORMANCE TARGET 12.35 DAYS ORIGINAL AFE P50 TARGET= 12.67 DAYS RELEASE NORDIC 2 CTD RIG AND END COMPLETION EVENT AT 06:00 ON 7/24/2012. Printed 8/7/2012 3:05:54PM 07-22A, Well History (Post Rig Sidetrack) Date Summary 07/29/12 TAGGED DEPLOYMENT SLEEVE W/ 10'x 3.70" DUMMY WHIPSTOCK, 3.50"LIB(picture of junk) BRUSHED DEPLOYMENT SLEEVE W/3.60"CENT, 4 1/2"BRUSH, 3'x 1 7/8"STEM, 3 1/2"BRUSH SET BAKER 14.5'LINER TOP PACKER @ 9098' MD SET 45 KB LTTP IN PACKER @ 9,076'SLM & MIT- T TO 2400psi"PASS" PULLED STA#2 RK-DGLV FROM 5,978'SLM /5,981' MD PULLED STA#1 RK- DGLV FROM 3,106'SLM/3,101' MD SET STA#1 RK-LGLV @ 3,106'SLM/3,101'MD SET STA#2 RK- OGLV @ 5,978'SLM/5,981'MD PULLED LTTP FROM 9,076'SLM Page 1 of 1 BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 07 07-22 - Slot 22 / Lat: 070°15'59.451"1 Long: 0148°34'10.322"W 07-22A CS Survey: MWD Survey Report - Geographic 23 July, 2012 s;. r2 Eli. bp BAKER AKERHUGHES Survey Report-Geographic INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-22-Slot 22 Project: Prudhoe Bay TVD Reference: Kelly Bushing/Rotary Table @ 58.00ft(NABORS Site: PB DS 07 MD Reference: Kelly Bushing/Rotary Table @ 58.00ft(NABORS Well: 07-22 North Reference: True Wellbore: 07-22Ar:b Survey Calculation Method: Minimum Curvature Design: 07-22K 13, Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 07,TR-11-14 Site Position: Northing: 5,948,144.78ft Latitude: 70°15'49.847 N From: Map Easting: 677,382.28ft Longitude: 148°33'56.934 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.35 ° Well 07-22 API No 500292092500 Well Position +N/-S 0.00 ft Northing: 5,949,110.18 ft Latitude: 70°15'59.451 N +El-W 0.00 ft Easting: 676,899.43 ft Longitude: 148°34'10.322 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 27.00 ft Wellbore 07-22A API No 500292092502 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2011 7/15/2012 20.95 81.02 57,656 Design 07-22A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,700.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (ft) (ft) (ft) (0) 31.00 0.00 0.00 192.96 Survey Program Date: 7/23/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 9,700.00 1 :Camera based gyro multisho(07-22) CB-GYRO-MS Camera based gyro multishot 9,766.50 11,002.00 MWD(07-22A) MWD MWD-Standard 7/23/2012 2:36:31PM Page 2 COMPASS 2003.16 Build 73 BAKERbp HUGHES Survey Report Geographic INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 07-22-Slot 22 Project: Prudhoe Bay TVD Reference: Kelly Bushing/Rotary Table @ 58.00ft(NABORS Site: PB DS 07 MD Reference: Kelly Bushing/Rotary Table @ 58.00ft(NABORS Well: 07-22 North Reference: True Wellbore: 07-22A? 6 Survey Calculation Method: Minimum Curvature Design: 07-22e 8 Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,700.01 27.75 207.13 8,686.25 -3,402.67 -922.61 5,945,686.99 676,057.09 70° 15'25.985 N 148°34'37.163 W TIP 9,766.50 27.71 206.39 8,745.11 -3,430.30 -936.54 5,945,659.04 676,043.81 70°15'25.714 N 148°34'37.568 W KOP 9,800.27 20.78 194.21 8,775.90 -3,443.16 -941.51 5,945,646.07 676,039.14 70°15'25.587 N 148°34'37.713 W 9,830.96 13.72 173.30 8,805.22 -3,452.07 -942.43 5,945,637.14 676,038.44 70°15'25.499 N 148°34'37.739 W 9,860.20 11.60 138.70 8,833.78 -3,457.73 -940.08 5,945,631.53 676,040.92 70°15'25.444 N 148°34'37.671 W 9,890.27 13.62 115.72 8,863.14 -3,461.55 -934.89 5,945,627.85 676,046.20 70°15'25.406 N 148°34'37.520 W 9,920.66 21.15 117.60 8,892.13 -3,465.64 -926.79 5,945,623.94 676,054.39 70°15'25.366 N 148°34'37.285 W 9,950.36 29.57 105.20 8,918.96 -3,470.06 -914.94 5,945,619.80 676,066.33 70°15'25.322 N 148°34'36.940 W 9,980.46 37.23 93.67 8,944.09 -3,472.60 -898.65 5,945,617.65 676,082.68 70°15'25.298 N 148°34'36.466 W 10,010.31 44.05 82.30 8,966.76 -3,471.78 -879.31 5,945,618.92 676,102.00 70°15'25.306 N 148°34'35.903 W 10,040.17 51.41 73.10 8,986.86 -3,466.99 -857.80 5,945,624.22 676,123.39 70°15'25.353 N 148°34'35.277 W 10,070.32 60.15 65.98 9,003.81 -3,458.21 -834.51 5,945,633.54 676,146.46 70°15'25.439 N 148°34'34.600 W 10,101.24 68.96 60.27 9,017.09 -3,445.57 -809.67 5,945,646.76 676,171.00 70°15'25.563 N 148°34'33.877 W 10,131.00 75.71 53.21 9,026.13 -3,430.01 -786.01 5,945,662.87 676,194.28 70°15'25.717 N 148°34'33.189 W 10,162.02 82.23 44.48 9,032.07 -3,409.98 -763.14 5,945,683.43 676,216.68 70°15'25.914 N 148°34'32.524 W 10,192.34 89.02 37.11 9,034.38 -3,387.12 -743.42 5,945,706.75 676,235.85 70°15'26.138 N 148°34'31.950 W 10,219.71 91.23 28.25 9,034.32 -3,364.11 -728.66 5,945,730.10 676,250.07 70°15'26.365 N 148°34'31.521 W 10,254.06 96.32 17.76 9,032.06 -3,332.61 -715.27 5,945,761.89 676,262.71 70°15'26.674 N 148°34'31.131 W 10,281.50 95.35 8.37 9,029.26 -3,306.05 -709.11 5,945,788.59 676,268.24 70°15'26.936 N 148°34'30.952 W 10,309.86 92.33 2.58 9,027.36 -3,277.90 -706.42 5,945,816.80 676,270.28 70°15'27.213 N 148°34'30.874 W 10,341.67 91.51 9.20 9,026.29 -3,246.30 -703.16 5,945,848.47 676,272.79 70°15'27.523 N 148°34'30.779 W 10,370.93 92.15 357.47 9,025.36 -3,217.15 -701.46 5,945,877.64 676,273.81 70°15'27.810 N 148°34'30.730 W 10,400.66 89.17 346.83 9,025.01 -3,187.75 -705.51 5,945,906.94 676,269.06 70°15'28.099 N 148°34'30.848 W 10,430.64 91.54 344.35 9,024.83 -3,158.72 -712.97 5,945,935.79 676,260.92 70°15'28.385 N 148°34'31.065 W 10,463.26 90.64 357.46 9,024.20 -3,126.58 -718.11 5,945,967.79 676,255.03 70°15'28.701 N 148°34'31.215 W 10,499.62 91.32 9.50 9,023.58 -3,090.36 -715.91 5,946,004.05 676,256.38 70°15'29.057 N 148°34'31.151 W 10,530.78 91.81 8.15 9,022.73 -3,059.58 -711.13 5,946,034.93 676,260.43 70°15'29.360 N 148°34'31.012 W 10,561.12 90.31 357.48 9,022.17 -3,029.33 -709.65 5,946,065.21 676,261.21 70°15 29.657 N 148°34'30.968 W 10,590.43 88.74 357.97 9,022.41 -3,000.04 -710.81 5,946,094.46 676,259.35 70°15'29.945 N 148°34'31.002 W 10,621.27 91.23 359.02 9,022.42 -2,969.22 -711.62 5,946,125.25 676,257.82 70°15'30.248 N 148°34'31.026 W 10,653.11 95.44 3.20 9,020.56 -2,937.45 -711.01 5,946,157.02 676,257.69 70° 15'30.561 N 148°34'31.008 W 10,681.44 92.58 5.53 9,018.58 -2,909.28 -708.86 5,946,185.24 676,259.18 70° 15'30.838 N 148°34'30.946 W 10,710.26 94.76 9.26 9,016.74 -2,880.76 -705.16 5,946,213.83 676,262.20 70° 15'31.118 N 148°34'30.838 W 10,742.18 92.15 11.26 9,014.81 -2,849.41 -699.48 5,946,245.30 676,267.14 70°15'31.427 N 148°34'30.673 W 10,771.09 91.11 14.85 9,013.99 -2,821.27 -692.95 5,946,273.59 676,273.00 70° 15'31.704 N 148°34'30.483 W 10,805.42 89.72 17.58 9,013.74 -2,788.31 -683.37 5,946,306.76 676,281.81 70° 15'32.028 N 148°34'30.205 W 10,830.64 89.39 19.96 9,013.94 -2,764.43 -675.26 5,946,330.82 676,289.36 70° 15'32.263 N 148°34'29.969 W 10,860.34 90.06 22.98 9,014.08 -2,736.80 -664.39 5,946,358.70 676,299.58 70° 15'32.534 N 148°34'29.652 W 10,890.93 89.82 26.87 9,014.11 -2,709.06 -651.50 5,946,386.73 676,311.81 70° 15'32.807 N 148°34'29.277 W 10,921.10 90.18 29.47 9,014.11 -2,682.47 -637.26 5,946,413.65 676,325.42 70° 15'33.069 N 148°34'28.863 W 10,950.52 91.35 26.46 9,013.72 -2,656.49 -623.46 5,946,439.95 676,338.60 70° 15'33.324 N 148°34'28.462 W 11,002.00 91.35 26.46 9,012.51 -2,610.41 -600.53 5,946,486.54 676,360.44 70° 15'33.777 N 148°34'27.795 W TD-2 7/8" 7/23/2012 2:36:31PM Page 3 COMPASS 2003.16 Build 73 TREE= 5x7 FMC VYE LLFEAD= GRAY 07_2 2 A ' SAI NOTES:WELL ANGLE n 70°©10105'*** ACTUATOR= BAKER 4-112"CHROME TBG KB.ELEV= 58' BF.TEV= _ 2086' H4-1/2"FES X NP,ID=3.813' KOP —2900' 20"CONDUCTOR, 110' Max Angle= 96"t)10254' 91.5#,11-40, GAS LFT MANDRELS Datum MD= 5' ID=19.124" ST M) TVD DEV TYPE VLV LATCH FORT DATE Datum TVD= 8800'SS 1 3106 3099 16 MMG DOME RK 16 07/29/12 2 5981 5508 37 MMG SO RK 20 07/29/12 13-3/8"CSG,72#,L-80 BTRS,D=12.347" H 2542' 3 7918 7109 30 WIG DMY RK 0 04/22/05 *4 8947 8025 28 MMM - - - 04/22/05 *GENIE T'13.1IN(07124/05) EST TOP OF CEMENT IN IA(7/24/05) H 8938' •: iYYY i YV' 901T —14-1/2"HES X NP,D=3.813" i l "E Y'Y r t.1. , Y� Minimum ID =2.36" 9098' Y ‘i 9038' —I9-5/8-X4-1/2'BKR S-3 PKR,D=3.875" • 4-1/2" KB LINER TOP PKR =A ►= t� !��I. 9062' —14-1/7 FES X NP,D=3.813' 1'1`I ••r.,:0 909$' I4-1/2" KB LW,D=2.36"(07/29/12) 4-1/2"TBG,12.6#,13CR-80,VAM TOP, —I 9125' iY•Y e: 10 gal Y Y 9106' —13.70"BKR DEPLOYMENT SLV,D=3.00" .0152 bpf,D=3.958" YjY9136' UNIQUE MACHINE OVERSHOT Y } 5-1/2"TBG STUB I 9134' 9157' H5-1/2"BKR FSRASSY,13=4.00" 5-1/2"TBG-PC,17#,L-80 8RD AB-MOD, -H 9157' .0232 bpf,ID=4.892" 9172' 19-5/8"X 5-1/2"BKR SAB PKR,D=4.00 \ y 9178' —d 7"MLLOUT EXTENSION,D=??? TOP OF 7"LNR 9195' 9179' --17"X 4-1/T XO,D=3.958" HU C 1 9244' —I4-1/2'CARCO DB-6 MP 13=3.813" 9256' —141/2"BKR SFEAROUTSW 4112"TBG PC,12.6#,L-80 BTC, 9257' , 9257' —I4-1/2"WLEG,D=3.958' .0152 bpf,13=3.958" 9251' —i ELME TT LOGGED 05/18/98 9-5/8"CSG,47#,L-80 BTC,ID=8.681' -I 9500' .,44 - 3'41'3'y1' 3-1/2',9.3#,L-80 STL,.0087 bpf,13=2.992' —I 9586' j 686' H3-1/2"X 3-3/16"XO,D=2.786' 7"X 4"BKR WHPSTOCK(07/15/12) -I 9765' f' ' Pi 0 MLLOUT WINDOW(07-22A)9771'-9778' 7"LMS 29#,L-80 BTC,.0371 bpf,13=6.184" —I 9T71' *} VP �,f� �� 3-1/4"LNR,6.6#,L-80,.0079 bpf,D=2.85" -j 10262' S 10262' H 3-3116"X 2-7/8"XO.D=2.377' PERFORATION SUMMARY �� h REF LOG:SLB LEE TNW9NF/GR/CNL on 07/21/12 g ANGLE AT TOP FERE:90'@a 10600' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10600-10950 0 07/22/12 FBTD H 10964' 1+ 2-7/8"LTV,6.54,L-80 STL,.0058 bpf,D=2.441" —I 11002' 1.4 DATE REV BY COMENTS DATE REV BY COMHENfS PRLEDHOE BAY UNIT 03/22/83 RWN 176 INITIAL COMPLETION 08/03/12 GJFIJM) GLV C/O(07/29/12) WELL: 07-22A 09/11/01 RNITP RWO 08/08/12 PJC DRLG DRAFT CORRECTIONS PERMIT No: 2120850 10/14/04 N4ES RWO 08/10/12 PJC GLV CORRECTIONS AFI No: 50-029-20925-02 07/24/12 NORDIC 2/CTD SIDETRACK(07-22A) SEC 34,T11 N,R14E,1831'FML&682'RM._ 08/03/12 AK/JM) DRG DRAFT CORK(08/21/12) ' 08/03/12 GJF/JM) SET KB LTP(07/29/12) BP Exploration(Alaska) 1 Page 1 of 2 Schwartz, Guy L (DOA) P 21 L --© Y.S From: Johnston, David [David.Johnston2@BP.com] , , Sent: Wednesday, July 18, 2012 11:10 AM To: Schwartz, Guy L(DOA) Cc: Lastufk- Joseph N (Northern Solutions) Subject: - : 07-22A .nd 07-22B permit to drill Guy, I would like to request to withdraw PTD#212-084 for well 07-22A at this time. I would also like to request the name change on the second permitted target to reflect: PTD 212-085 with an API suffix of -02 to be named 0 - 2A. Thanks again, David Johnston CTD Engineer 564-5985 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, July 18, 2012 9:40 AM To: Johnston, David Cc: Davies, Stephen F (DOA) Subject: RE: 07-22A and 07-22B permit to drill David, Request to withdraw the first permit( 7-22A / PTD 212-084) and then we can rename the second permitted target to 07-22A and it becomes drilled well. (We cannot change the API number for the PTD so it will remain -02 suffix. ) So the well will be 07-22A and PTD 212-085 with an API suffix of-02 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnston, David [mailto:David.Johnston2@BP.com] Sent: Wednesday, July 18, 2012 9:17 AM To: Schwartz, Guy L(DOA) Subject: 07-22A and 07-22B permit to drill Guy, Thanks for working with me on getting both 07-22A and 07-22B permits to drill issued. We have found the targets of 07-22A to be undesirable and are going to drill the 07-22B targets. We will not be plugging back what we have drilled already,we are just going to continue to drill ahead from our current depth to the new direction north, instead of continuing the turn to the north west. We would like to maintain the 07-22A wellbore name, and not use the(B) name. Please advise me of what steps you would like me to take to maintain this name,and under which permit. 7/18/2012 Page 2 of 2 Thanks for your time, David Johnston BP Alaska, CTD Engineer 564-5985 7/18/2012 S cum oF SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-22B BP Exploration (Alaska), Inc. Permit No: 212-085 Surface Location: 1831' FNL, 682' FWL, Sec. 34, T11N, R14E, UM Bottomhole Location: 4416' FNL, 76' FEL, Sec. 34, T11N, R 14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy r. Foe ster ,, Chair, Commissioner DATED this 2A-lay of June, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALA�..,-t OIL AND GAS CONSERVATION COMMioSION JUN 2 0 2012 PERMIT TO DRILL 20 AAC 25.005 CONTIN*ri C 0. 6 TO DRILL la.Type of work: , lb.Proposed Well Class: _4 Development Oil 0 Service-Winj ®Single Zone , lc. Specify if well is proposed for: ❑ Drill -4 Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates ❑ Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name: 5.Bond: 0 Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 • PBU 07-22B • 3. Address: 6. Proposed Depth: 12.Field 1 Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 10965' ' TVD 8939'ss Prudhoe Bay/Prudhoe Bay , 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Surface: ADL 028309 1831' FNL,682'FWL, Sec. 34,T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 5208'FNL,234' FEL, Sec. 33,T11N, R14E, UM July 15,2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4416' FNL, 76'FWL, Sec. 34,T11N, R14E, UM 2560 22000' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 58' ` feet 15.Distance to Nearest Well Open Surface: x- 676899 , y-5949110' Zone- ASP4 GL Elevation above MSL: 27.59' •feet to Same Pool: 600' 16.Deviated Wells: Kickoff Depth: 9750' feet - 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 95 degrees Downhole: 3250 Surface: 2370 18. Casing Program: 1 Specifications Top Setting Depth-Bottom Quaty of Cement,cf.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-1/2' 3-112x3-114"x2-718' 92#166#/65# L-80 STL/TC-II 1720' 9100' 8101'ss 10965' 8939'ss 77 sx Class'G' 19: PRESENT WELL CONDITION SUMMARY(To be completed for Redrl and Re-entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured): 10285' 9210' None 10250' 9178' 10024' Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 20" 1900#Poleset 79' 79' Surface 2542' 13-3/8" 1520 sx Fondu,400 sx PF C 2542' 2542' Intermediate 9500' 9-5/8" 500 sx Class'G'. 300 sx PF C 9500' 8510' Production Liner 1090' 7" 300 sx Class'G' 9195'- 10285' 8242'-9210' Perforation Depth MD(ft): 10042'- 10064' Perforation Depth TVD(ft): 8990'-9010' 20.Attachments: 0 Property Plat 0 BOP Sketch 0 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report ®Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is „- and correct. Contact David Johnston,564-5985 Printed Name John // Title Engineering Team Leader Prepared By Name/Number: Signature 1 '/ ,— Phone 564-4711 Date Or.,,.1 17 Joe Lastufka,564-4091 Commission Use Only Permit To D r` API Number: Permit ppr v I D See cover letter for Number: ' I Z-c� .5 50-029-20925-02-00 // . /Z other requirements Conditions of Approval: If box is checked,well maynot be used to explore for,test,or produce cos ted meths ,gas hydrates,or gas contained shales: p Other: 4., 3 s-7)0 nS, ,2Cjp les- F- Samples Req'd: 0 Y.es 13/No Mud Log Req'd: ❑yes "No /_ H2S Measures: Ig/Yes 0 No Directional Survey Req'd: ❑/Yes 0 No /� / APPROVED BY THE COMMISSION Date (p –2 8"I! 'y' A� COMMISSIONER O v f Form 10-401 Revised 07/2009 This permit is validr 24 month r•Rhe Ge • . ',v l(20 AAC 25.005(g)) Submit In Duplicate t>,A t To: Alaska Oil & Gas Conservation Commission From: David E. Johnston At by CTD Engineer Date: June 14, 2012 Re: 07-22B Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well 07-22. CTD Drill and Complete 07-35B program: This is only a contingency plan to be used if the 07-22A directional plan lands wet at 10,200 ft. Pre-Rig Work: (scheduled to begin July 1, 2012) 1. S Dummy GLV's (done 4/13/12) 2. D MIT-OA to 2,000 psi (passed 4/13/12) 3. D MIT-IA to 3,000 psi (passed 4/13/12) 4. S Dummy WS drift to 9,800' - Failed 6/8/2012 5. C Dummy whipstock drift to 9,800 ft 6. W AC-LDS; AC-PPPOT-IC, T 7. W PT MV, SV, WV 8. F Load and kill well with 8.4 ppg 1% KCL 9. V Install TWC 10. 0 Bleed gas lift and production flowlines down to zero and blind flange 11. 0 Remove wellhouse, level pad Rig Work: (scheduled to begin on July 15, 2012) Steps 1 to 5 are from the 07-22A plan 1. MIRU Nordic 2 and test BOPE to 250 psi low and 3500 psi high. 2. Pull TWC and bullhead kill well 3. Set top of 4-1/2" X 7" through tubing whipstock at 9,750 ft and 205 deg TF (25 de LOLSL 4. Mill 3.8" window at 9750' and 10' of rathole. L., 5. Drill Build: 4.25" OH, 450' (28 deg/100 planned) with resistivity `� /.4 7-iz A If we land wet with 07-22A then we want to drill to a new bottom hole location that is 629 ft from the original planed TD location. 6. Drill Lateral: 4.25" OH, 765' (12 deg/100 planned) with resistivity 7. Run 3-1/2" x 2-7/8" solid chrome liner leaving TOL at 9,100' 8. Pump primary cement leaving TOC at 9600', 17 bbls of 15.8 ppg class G liner cement 9. Cleanout liner and MCNL/GR/CCL log 10. Test liner lap to 2400 psi. 11. Perforate liner per asset instructions (-300') 7 i 12. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse, flowline and pull BPV. 2. Set 4-'/2" liner top packer, and test to 2,400 psi (If liner lap test fails) 3. Generic GLV's Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg PowerVis for milling window and drilling (686 psi over-balance). Disposal: • 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. Hole size: 4.25" Liner Program: • 3-1/2", 9.2#, L-80, STL Solid liner 9,100' MD — 9,600' MD • 3-1/4", 6.6#, L-80, TC-II Solid Liner 9,600' MD — 10,250' MD • 2-7/8", 6.5#, L-80, STL Solid Liner 10,250' MD — 10,965' MD • A minimum of 16 bbls of 15.8 ppg cement will be used for liner cementing. (TOC 9,600 MD) • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 95°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property — 22,000'. • Distance to nearest well within pool — 600' (07-01 B). • This is only a contingency plan in the event that 07-22A lands water wet. Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • Cased hole GR/CCL/MCNL logs will be run. • If available an open hole caliper log will be ran through the build section for swell packer evaluation data. • If available an open hole Multi Express tool for high quality density and saturation data will be ran. Perforating: • SWS 2", 6 spf, perf guns, 1-1/4" CSH work string, & 2-3/8" PH6 • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti-Collision Failures • No Failures Hazards • The maximum recorded H2S level on DS 07 was 50 ppm on well 07-24 on 5/15/2005. Reservoir Pressure • The reservoir pressure on 07-22 is expected to be 3,250 psi at 8,800' TVDSS. (7.1 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,370 psi. • An EMW of 8.4 ppg for this well will provide 595 psi over-balance to the reservoir. David E. Johnston CC: Well File CTD Engineer Terrie Hubble/Joe Lastufka TREE= GRAY GEN 2 tFETY NOTES:***4-1/2"CHROME TBG WELLHEAD= GRAY ACTUATOR= AXELSON 0 22 I ***GLM#4(IA)IS COVERED IN CEMENT*** l KB.ELEV= 58 BF. ELEV= ? 2900' 2086' —4-1/2"HES X NIP,ID=3.813" KOP= Max Angle= 37 @ 6200' I I GAS LIFT MANDRELS ___ Datum MD= 9894' ST MD TVD DEV TYPE VLV LATCH PORT QATE Datum TVD= 8800'SS 1 3106 3093 16 MMG DMY RK 0 04/13/12 2 5981 5520 37 MMG DMY RK 0 04/13/12 3 7918 7100 30 MMG DMY RK 0 07/24/05 13-3/8"CSG,72#, L-80,ID=12.347" I— 2542' —A *4 8947 8028 28 MMG - - 07/24/05 *CEM ELATED IN EST TOP OF CEMENT IN IA(7/24/05) — 8938' 14 •�•4 `- 9017' H4-12"HES X NIP,ID=3.813" 0.4 • i TREE= GEN 2 NOTE ME TBG WELLHEAD= GRAY GRAY 07 -2 2 B ***GLM#4(IA)IS COVERED INRCO M ENT"** ACTUATOR= AXELSON KB. ELEV= 58' proposed CTD she(rdck BF. ELEV= ? 1 KOP= 2900' 2086' H4-1/2'HES X NIP,I D=3.813" Max Angle= 37 @ 6200' I GAS LIFT MANDRELS Datum MD= 9894' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum ND= 8800'SS 1 3106 3093 16 MMG DMY RK 0 04/13/12 2 5981 5520 37 MMG DMY RK 0 04/13/12 3 7918 7100 30 MMG DMY RK 0 07/24/05 13-3/8"CSG,72#, L-80, ID=12.347" — 2542' —A *4 8947 8028 28 MMG - - - 07/24/05 EST TOP OF CEMENT IN IA(7/24/05) --I 8938' *CEM ENT ED IN CV •�•� !�!�� 9017' J-14-1/2"HES X NIP,ID=3.813" ♦♦ 41 -•4 44.E 9038' —19-5/8"X 4-1/2"BKR S-3 PKR, ID=3.958" Minimum ID = 2.377" @ 10500' o=' =� .... 704• 3-1/4" x 2-7/8" XO .•••• 91, 9062' H41/2"HES X NIP, ID=3.813" •28 • ••�• MTo of312"liner@ -9,100' •• 144 p 4-1/2"TBG, 12.6#,13CR-80, .0152 bpf, ID=3.958" H 9125' • \ / '4.4 ��. ..•.. 9126' H UNIQUE MACHINE OVERSHOT 5-1/2"TBG STUB H 9134' 915T H5-12"BKR PBR ASSY, ID=4.00" 5-12"TBG-PC,17#, L-80, .0232 bpf, ID=4.892" H 9157' - N OM9172' H9_5/8"X 5-1/2'BKR SAB PKR TSGR = 9,511'MD \ 9183' -T'X4-12"XO, ID=3.958" TOP OF 7"LNR H 9195' ' , 9244' H4-1/2'CAMCO DB-6 NIP, ID=3.813" 9256' —412"BKR SHEAROUT SUB 4-1/2"TBG-PC, 12.6#, L-80, .0152 bpf, ID=3.958" H 9257' I 9257' H4-12"WLEG, ID=3.958" 9-5/8"CSG,47#, L-80, ID=8.681" 9500' 9251' --IELMD TT LOGGED 05/18198 3-1/2"x 3-3/16"X0 PERFORATION SUMMARY Top m 600' entat-9, \ ofceTD 9 10,965' REF LOG: BHCS ON 03/18/83 0 L''''' \ ' ANGLE AT TOP PERF:26 @ 10018' 2 8 Note: Refer to Production DB for historical perf data ) 3-1/4"x 2-7/8"X0 9 10,250' SIZE SPF INTERVAL OpnlSgz DATE /7"TT whipstock @ 9,750' � 3-3/8" 4 10018- 10038 S 12/04/83 3-3/8" 4 10042- 10062 0 12/04/83 • 3-3/8" 6 10054- 10064 0 02/19/98 1 � A I10024' H FISH:IBP RUBBER ELEMENT(05/18/05) PBTD H 10250' I—1'0"4'4'4'4'1 441444444444441 7"LNR,29#, L-80,.0371 bpf, ID=6.184" H 10285' t•4•4•4•4•4•4•44 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/22/83 ORIGINAL COMPLETION 07/29/05 JNA/PJC MILL CMT&FASDRILL @ 9195 WELL: 07-22A 09/11/01 _ RNITP RWO 04/21/12 CDJ/PJC GLV C/O(04/13/12) PERMIT No:'1830390 10/15/04 KBS/TLP RWO 04/30/12 WJH proposed CTD sidetrack AR No: 50-029-20925-00 06/26/05 BMcUPJC PULL IBP/SET FASDRILL @9195 SEC 34,T11 N,R14E,354.89'FEL&190.64'FNL 07/24/05 BMcUPJC CEMENT _ 08/07/05 DAV/PJC GLV C/O BP Exploration(Alaska) rim m G Mr T Y m 'el.._ .4. / Pel. e E a ac� E p a .. m . /-4 1rI = ► -a 7100 . 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These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLISTAz, fie,' WELL NAME — 7—� /3 07- 71/4 ` ' PTD# 2- ' > ' Development Service Exploratory Stratigraphic Test Non-Co ventional Well / FIELD: re c L teA-� 1-?'-4-(-1-4/A-43------POOL: 1 l Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 cn .a co G) D a cn D >I- � ,0 o r � tQ_ 0 0 i 1 ° cn 1 3 1 7 3 G) (0 co M 3 .o 0.) rn 3 rn N c ° �° M co . .c° Ni D Ni v Ni 0 o .)n o ° m .. c o Er~ co CD o m m —7! Ni Ni Ni ')-...._.5 I-T W W OO W W W W W O W Ni Ni Ni Ni Ni Ni Ni Ni Ni N . . . -) CO COJ O 01 A W N _ -s 0 Ni 3 �- CO CO �1 CT CT A W Ni 0 CO CO V 0) CT A (A Ni ., 0 CO CO CT U7 A CA Ni O �I . < 0 0 0 0) 0 K � o0W00 �. D �. 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