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208-038
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 07-01B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-038 50-029-20272-02-00 11025 Conductor Surface Intermediate Liner Liner 9019 80 2684 8643 864 3044 9250 20" 13-3/8" 9-5/8" 7" 3-1/2" x 2-3/8" 8702 38 - 118 36 - 2720 33 - 8676 8337 - 9201 7981 - 11025 38 - 118 36 - 2720 33 - 8232 7963 - 8659 7664 - 9019 10487 520 2670 4760 7020 11780 9250 , 9266 , 9314 , 10500 1530 4930 6870 8160 11200 8982 - 10960 5-1/2" 17# x 4-1/2"12.6# 13Cr85 31 - 8258 8476 - 9015 Structural 4-1/2" Baker S-3 Perm , 7917 , 7617 No SSSV 7917 , 8135 7617 , 7797 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 0028312 31 - 7899 268 245 29550 18997 11 2 0 0 965 961 N/A 13b. Pools active after work:PRUDHOE OIL 5-1/2" Baker SAB , 8135 , 7797 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Gavin Gluyas at 10:05 am, Feb 05, 2025 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Date: 2025.02.05 09:00:01 - 09'00' David Bjork (3888) A.Dewhurst 04MAR25 RBDMS JSB 021825 DSR-2/18/25JJL 02/27/25 ACTIVITYDATE SUMMARY 1/4/2025 ***WELL S/I ON ARRIVAL*** DRIFTED WITH 1-3/4" SAMPLE BAILER TO 9,272' SLM DRIFTED WITH 2.73" x 11' 6" DUMMY GUN, 1-3/4" SAMPLE BAILER TO 9,272' SLM ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 1/6/2025 T/I/O = 2370/301/95 Assist E-Line ( PERFORATING ) Pumped 170 bbls of crude down TBG to kill well. Sim Ops complete. DSO notified upon departure. FWHP = 488/300/98 1/6/2025 T/I/O=2200/600/75 Temp=S/I (Assist E-Line with flush) Pumped 30 BBLS of crude down TBG to assist E-Line in reaching target depth. Pumped an additional 40 BBLS of crude down TBG for flush. E-Line in control of well upon departure. DSO notified of departure. Final WHPS=22/300/75 1/6/2025 *** WELL FLOWING ON ARRIVAL*** OBJECTIVE: PERFORATE INTERVAL W/1.56" GEO RAZOR GUN 6 spf 60 DEG PHASE MIRU YELLOW JACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH RIH W/CH/1.69'' GUN GAMMA/12' OF 1.56'' GEO RAZOR GUN 6 spf 60 DEG PHASE TO PERFORATE INTERVAL 9235'-9247' CCL TO TOP SHOT=16.7' CCL STOP DEPTH=9218.3' GAMMA RAY LOG CORRELATED TO SLB MEMORY COMPENSATED NEUTRON DATED 24-APR-2008 ON SURFACE LAID DOWN FOR THE NIGHT JOB CONTINUE 1/07/2025 ***WELL S/I ON DEPARTURE*** 1/7/2025 *** JOB CONTINUED FROM 01/06/2025*** WELL SI ON ARRIVAL*** WELL FLOWING ON ARRIVAL*** OBJECTIVE: SET PLUG IN ZONE @ 9250' MIRU YELLOW JACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH RIH W/CH/1.69'' GUN GAMMA/MSST SETTING TOOL AND, 1.71" OD PLUG CCL TO MID ELEMENT=14.3' CCL STOP DEPTH=9235.7'' SET PLUG @ 9250' GAMMA RAY LOG CORRELATED TO SLB MEMORY COMPENSATED NEUTRON DATED 24-APR-2008 JOB COMPLETE ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU 07-01B 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 07-01B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-038 50-029-20272-02-00 11025 Conductor Surface Intermediate Liner Liner 9019 80 2684 8643 864 3044 9266 20" 13-3/8" 9-5/8" 7" 3-1/2" x 2-3/8" 8717 38 - 118 36 - 2720 33 - 8676 8337 - 9201 7981 - 11025 38 - 118 36 - 2720 33 - 8232 7963 - 8659 7664 - 9019 10487 520 2670 4760 7020 11780 9266 , 9314 , 10500 1530 4930 6870 8160 11200 8982 - 10960 5-1/2" 17# x 4-1/2"12.6# 13Cr85 31 - 8258 8476 - 9015 Structural 4-1/2" Baker S-3 Perm , 7917 , 7617 No SSSV 7917 , 8135 7617 , 7797 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 0028312 31 - 7899 325 339 27557 29189 7 0 0 0 1123 966 N/A 13b. Pools active after work:PRUDHOE OIL 5-1/2" Baker SAB , 8135 , 7797 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:40 am, Jun 07, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.06.06 22:13:05 - 08'00' Bo York (1248) WCB 8-29-2024 A.Dewhurst 04MAR25 RBDMS JSB 061124 DSR-6/7/24 ACTIVITYDATE SUMMARY 5/7/2024 ***WELL FLOWING ON ARRIVAL*** RAN 3.80" G-RING DOWN TO ROCKSCREEN @ 7887' MD (no issues) PULLED 4-1/2" X-LOCK w/ ROCKSCREEN FROM X-NIP @ 7887' MD RAN 11' x 1.56" DUMMY GUNS (1.72" swell rings), 1.75" SAMPLE BAILER(msfb), DRIFTED DOWN TO 2-3/8" CIBP @ 9314' MD ***JOB COMPLETE, WELL LEFT S/I ON DEPARTURE, NOTIFY DSO OF WELL STATUS*** 5/11/2024 ***WELL SHUT IN ON ARRIVAL*** (PLUG SET/ADPERF) MIRU AKEL PT PCE 250LP 3000HP PERFORATE FROM 9253'-9261 WITH 1.56" 6SPF 60PHASE HSC W/ GEO RAZOR CHARGES CCL STOP DEPTH=9242.4, CCL-TS=10.6 SET NORTHERN SOLUTIONS CIBP AT 9266' CCL STOP DEPTH=9252.3, CCL-ME=13.7' RDMO AKEL *** WELL SHUT IN ON DEPARTURE, JOB COMPLETE*** Daily Report of Well Operations PBU 07-01B CIBP and adperfs are correctly shown on the new WBS, below. -WCB SET NORTHERN SOLUTIONS CIBP AT 9266' PERFORATE FROM 9253'-9261 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 07-01B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-038 50-029-20272-02-00 11025 Conductor Surface Intermediate Liner Liner 9019 80 2684 8643 864 3044 9314 20" 13-3/8" 9-5/8" 7" 3-1/2" x 2-3/8" 8764 38 - 118 36 - 2720 33 - 8676 8337 - 9201 7981 - 11025 38 - 118 36 - 2720 33 - 8232 7963 - 8659 7664 - 9019 10487 520 2670 4760 7020 11780 9314 , 10500 1530 4930 6870 8160 11200 8982 - 10960 5-1/2" 17# x 4-1/2"12.6# 13Cr85 31 - 8258 8476 - 9015 Structural 4-1/2" Baker S-3 Perm , 7917 , 7617 No SSSV 7917 , 8135 7617 , 7797 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 0028312 31 - 7899 124 278 13044 27814 213 67 0 0 252 335 N/A 13b. Pools active after work:PRUDHOE OIL 5-1/2" Baker SAB , 8135 , 7797 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 9:13 am, Dec 11, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.12.08 10:33:04 - 09'00' Bo York (1248) RBDMS JSB 121423 DSR-12/14/23A.Dewhurst 04MAR25WCB 3-14-2024 ACTIVITYDATE SUMMARY 11/13/2023 ***WELL SHUT IN ON ARRIVAL*** Pressure test PCE from 200lp - 3000hp RIH with 1 7/16" Cable Head, (4X) 1 11/16" Weight Bar, 1 11/16" Gamma/CCL, 1.68 Owens long Stroke Setting Tool, 1.71" NS CIBP Plug Set Depth = 9,314' , CCL Offset = 13.5' , CCL Stop Depth = 9,300.5' RIH with 1 7/16" Cable Head, (4X) 1 11/16" Weight Bar, 1 11/16" Gamma/CCL, 1.56" Perf gun Perf Shooting Depth = 9,269' - 9,282' , CCL Offset = 9.5' , CCL Stop Depth = 9,259.5' Both runs correlated to SLB CNL dated 24apr08 Rig Down/Move off ***WELL SHUT IN ON DEPARTURE*** 11/13/2023 ***CONTINUED FROM 11/12/23 WSR*** (Perforating) DRIFT W/ 4-1/2" BRUSH & 3.80" G. RING TO 3.81" WIRE SCREEN AT 7,887' MD PULLED 3.81" WIRE SCREEN @ 7887' MD (damaged at btm) DRIFT TBG TO 9400' SLM w/ 11' x 1.71" DMY GUN & 1.75" SAMPLE BAILER (13' oal) ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** 11/14/2023 ***WELL S/I ON ARRIVAL*** (perforating) SET 3.81" WIRE ROCK SCREEN IN X NIP @ 7887' MD (10.9' OAL, verified w/ checkset) ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** Daily Report of Well Operations PBU 07-01B g Perf Shooting Depth = 9,269' - 9,282' NS CIBPg Plug Set Depth = 9,314' Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:208-038 6.50-029-20272-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11026 10500 9032 10487 10500 7617 , 7797 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 38 - 118 38 - 118 1530 520 Surface 2684 13-3/8" 36 - 2720 36 - 2720 4930 2670 Intermediate 8643 9-5/8" 33 - 8676 33 - 8232 8150 / 6870 5080 / 4760 Liner 864 7" 8337 - 9201 7963 - 8659 8160 7020 Perforation Depth: Measured depth: 8982 - 10960 feet True vertical depth:8476 - 9015 feet Tubing (size, grade, measured and true vertical depth)5-1/2" 17# x 4-1/2" 12.6# 13Cr 31 - 8258 31 -7899 7927 7617Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Liner 3044 3-1/2" x 2-3/8" 7981 - 11025 7664 - 9019 11200 11780 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 272-750306118 71019 -750 4774 275 281 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9019 Sundry Number or N/A if C.O. Exempt: n/a 5-1/2" Baker SAB 8135 7797 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028312 PBU 07-01B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 7927 , 8135 / L-80 By Samantha Carlisle at 10:43 am, Feb 23, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.02.23 10:30:35 -09'00' Bo York SFD 2/24/2021MGR23FEB2021DSR-2/23/21 RBDMS HEW 2/23/2021 ACTIVITYDATE SUMMARY 5/5/2020 ***WELL S/I ON ARRIVAL*** (mill/ underream) SWCP 4522 RIG UP ***CONT ON 5/6/20 WSR*** 5/6/2020 ***CONT FROM 5/5/20 WSR*** (mill/ underream) RAN 3.805" G. RING TO SLOTTED LINER AT 7,887' SLM (no issues) PULLED 4-1/2" SLOTTED LINER FROM 7,887' MD (intact) ***WELL S/I ON DEPARTURE*** 8/31/2020 ***Cost place holder for FP trucking cost*** 12/29/2020 CTU #9 1.5" coil 0.109 WT Objective mill CIBP MIRU / MU and RIH W/ 1.80" 3 bladed junk mill BHA. 12/30/2020 CTU#9 1.5" CT. Job Scope: Mill CIBP. MU & RIH w/ 1.80" 3-Bladed Junk Mill. Tag at 9687'. Work thru tight spot. Stalled at 10178'. Work mill & became detained at 10186'. Able to work free, Pooh. MU & RIH w/ 1.80" Venturi. Dry Tag at 10157'. Work Venturi down to 10189' and stop making progress. Pooh. Recover what appears to be perf gun debris? MU & RIH w/ Venturi/Burnshoe 1.75" Max OD. Roll Coil to KCL. Dry Tag at 10191'. Work Venturi down to 10300'. Attempted to dry drift but tagged at 10300'. Continue working venturi down to 10439' where progress stopped. Likely venturi full and not able to get rid of debris. Pooh heavy initially then weights cleared up at 10250'. Pooh. ***Continue Job on 12/31/2020*** 12/31/2020 T/I/O=0/410/400 SI Assist CTU as directed (MILL / UNDERREAM) Pumped 138 bbls 50* crude down TBG to assist Coil stuck in hole. ***Job continued on 1-1-21 WSR*** 12/31/2020 CTU#9 1.5" CT. Job Scope: Mill CIBP. Pooh with Venturi/Burnshoe. Venturi recovery barrel packed full of what appears to be asphaltines & perf gun debris. Trim 100' of pipe. MU & Re-run Venturi/Burnshoe BHA. Stall at 10449', Coil detained for a bit. Able to get free. Chase up to 8000'. Venturi back down to CIBP at 10511' ctm. Mill on plug ~ 1hr then motor stalled and became bit stuck. Try various attempts to get free with no success. LRS pumped 132 bbls crude down backside. Continue to work pipe with no luck. ***Continue Job on 1/01/2021*** 1/1/2021 ***Job continued from 12-31-20 WSR*** Pumped 22.6 bbls 50* crude down TBG to assist Coil stuck in hole. CTU in control of wellhead upon departure. FWHP=250/380/400 1/1/2021 CTU#9 1.5" CT. Job Scope: Mill CIBP Unable to get unstuck. Drop 1/2" ball & successfully disconnect. Pooh. Recover tools from disconnect up. Perform Weekly BOP Test. Trim 150' of pipe. MU & RIH w/ G-spear Fishing BHA. Latch fish at 10502' ctm. Hit 16 up jar licks. Jar doesn't appear to be hitting very good. Swap to working Hipp Tripper. ***LIH = 1.69" x 1.03" TJ Disco, 1.69" x .93' Circ Valve, 1.69" x 7.64' Mud Motor, 1.75" x 3.68" Venturi/Burnshoe. OAL= 13.28'. ***Job Continued on 1/2/2021*** Daily Report of Well Operations PBU 07-01B Daily Report of Well Operations PBU 07-01B 1/2/2021 CTU#9 1.5" CT. Job Scope: Mill CIBP Continue working Hipp Tripper with no movement. Circulate well to 1% KCL w/ safelube and diesel in Coil. Attempt to jar free with no success. Not much overpull with 1.5" CT. Pump off fish & Pooh. Freeze protect Tbg w/ Diesel. Break down tools. OE says to rig down. Rig Down CTU. ***Job Incomplete*** 1/31/2021 ***WELL S/I ON ARRIVAL, DSO NOTIFIED, PERMIT FILLED OUT***(adperf) PERFORATE 9570'-9580' USING 1.56", 60 DEGREE PHASING, 6 SPF HSC LOADED W/ 3 GR GEO RAZER CHARGES. CCL TO TOP SHOT OFFSET: 7.6', CCL STOP DEPTH: 9562.4'. LOG CORRELATED TO SLB CNL DATED 24-APR-2008. PRE PERF T/IA/OA: 200/100/225, TENSION: 1160#, POST PERF T/IA/OA: 200/100/225, TENSION: 1145#. ***WELL LEFT S/I ON DEPARTURE, TURNED OVER TO DSO*** 1/31/2021 T/I/O=0/75/200 Temp=SI. Assist E-line with loading well. Pumped 3 bbls of 60/40 followed by 150 bbls of crude down the tbg to load the well. FW HP=100/50/200 E-line still on well upon departure. 2/2/2021 T/I/O = SSV/120/250. Temp = SI. IA FL (Slickline request). AL disconnected. IA FL @ near surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 20:30 2/2/2021 ***WELL S/I ON ARRIVAL*** SPOT EQUIPMENT AND PREP FOR AM ***JOB CONTINUED ON 2/3/21*** 2/6/2021 ***JOB CONTINUED FROM 2/2/21*** SET 4 1/2 X-LOCK 3.70" CENTRALIZED ROCK SCREEN (21.5' OAL, 3.70" OD). @ 7887' MD SET 4 1/2 WHIDDON @ 7882' MD PULLED 1.5" RK-DGLV STATION 3 @ 5507' MD. PULLED 1.5" RK-DGLV STATION 4 @ 3243' MD SET 1.5" RK-LGLV (16/64" 1500PSI) IN STATION 4 @ 3243' MD SET 1.5" RK-OGLV(20/64") IN STATION 3 @ 5507' MD. PULL WHIDDON FROM 7882' MD ***WELL LEFT S/I UPON DEPARTURE*** Dt= e`7 5 STATE OF ALASKA ALASKA OIL AND GAS. CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Length: - pU e-. a;, Abandon ❑ Plug Perforations Suspend ❑ Perforate ❑ Fracture Stimulate ❑ 0 Other Stimulate ❑ Pull Tubing ❑ Oper on hgldow ❑ ❑ Total Depth: measured 11026 Alter Casing Chamt ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Junk 5. Permit to Drill Number: 208-038 3. Address: P.O. Box 196612 Anchorage, Development 0 Exploratory ❑ feet Packer AK 99519-6612 1 Stratigraphic ❑ Service 6. API Number: 50-029-20272-02-00 7. Property Designation (Lease Number): ADL 028312 8. Well Name and Number: PBU 07-01B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Length: Size: MD: TVD: Burst: Collapse: Total Depth: measured 11026 feet Plugs measured 10500 feet true vertical 9019 feet Junk measured None feet Effective Depth: measured 10500 feet Packer 36-2720 4930 2670 Intermediate 8643 9-5/8" 33-8676 measured 7927, 8135 feet true vertical 9032 feet Packer true vertical 7617, 7797 feet Liner Casing. Length: Size: MD: TVD: Burst: Collapse: Structural Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ Conductor 80 20" 38 - 118 38-118 1530 520 Surface 2684 13-3/8" 36-2720 36-2720 4930 2670 Intermediate 8643 9-5/8" 33-8676 33-8232 8150/6870 5080/4760 Liner 864 7" 8337-9201 7963-8659 8160 7020 Liner 3044 3-1/2" x 2-3/8" 7981 -11025 7664-9019 11200 11780 Perforation Depth: Measured depth: 8982-10960 feet True vertical depth: 8476-9015 feet Tubing (size, grade, measured and true vertical depth) 5-1/2" 17# x 4-1/2" 12.6#, 13Cr85 / L-80 31-8258 31 -7899 4-1/2" Baker 5-3 Perm Packer 7927 7817 Packers and SSSV (type, measured and 5-1/2" Baker SAB Packer 8135 7797 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary Intervals treated (measured): 13. descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Prior to well operation: 228 4485 168 0 Subsequent to operation: No Test Available 10 Tubing Pressure 430 0 14. Attachments: fre9uired Per 20 nac 25,670.25.071, s 25.2831 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigrephic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Thompson, Ryan Contact Name: Thompson Ryan Authorized Title: Petroleum Engineer Contact Email: RYAN.THOMPSON( bloom Authorized Signature: "Ut' 1 wy-t 4e, Date: 'I b *I//,? Contact Phone: +1 907 564 4535 Form 10-404 Revised 04/2017 .01t t�ltlj ml-kd'40m? IMS 1�"SEP 19 2019 Submit Original Only Daily Report of Well Operations PBU 07-01 B ArTP/ITVnATF ......... _.. ***WELL $/I ON ARRIVAL***(add perfs) DRIFTED TO 4-1/2" SLOTTED ROCK SCREEN @ 7887' MD W/ 3.80" GAUGE RING. PULLED 4-1/2" SLOTTED ROCK SCREEN FROM X -NIPPLE @ 7887' MD (— 4 cups of fine gravel / Screen in great shape) DRIFTED W/ 10'x 1.72" DUMMY GUN & S.BAILER, TOOLS AT DOWN AT 9078' SLM (1 qt sample of dry schmoo in bailer) 8/2/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** ***CONT FROM 8/22/19 WSR***(adpert) PERFORATE 8,993'-9,003' WITH 1.69" DEEP STAR STRIP GUN, 6 SPF, PENTAPHASE ORIENTATION. CCL TO TOP SHOT OFFSET: 9.7', CCL STOP DEPTH: 8983.3'. CORRELATED TO SLB MEMORY CNL DATED 24 -APR -2008. 8/23/2019 ***JOB COMPLETE, DSO NOTIFIED*** ****WELL S/I UPON ARRIVAL**** (Perforating) RAN 4-1/2" OM -1 W/ 1.70" LIB TO STA 44,9 3,236' SLM / 3,243' MD (Impression of latch in pocket) RAN 4-1/2" OM -1 W/ 1.70" LIB TO STA #3 @ 5,502' SLIM / 5,507' MD (Impression of latch in packet) RAN 4-1/2" OM -1 W/ 1.70" LIB TO STA #2 @ 6,681' SLIM / 6,678' MD (Impression of latch in pocket) RAN 4-1/2" OM -1 W/ 1.70" LIB TO STA #1 @ 7,809' SLM / 7,808' MD (Impression of latch in pocket) SET 4-1/2" X -LOCK W/ SLOTTED LINER ROCK SCREEN ASSY. @ 7,889' SLIM / 7,887' MD (21.41' oal) 8/25/2019 ****CONT JOB ON 8/26/19**** CONT. JOB FROM 8/25/19**** (Perforating) RAN 4-1/2" CHECK SET TO ROCK SCREEN @ 7,889' SLM (Sheared) 8/26/2019 ****WELL LEFT S/I & DSO NOTIFIED OF STATUS UPON DEPARTURE**** 'TREE= FMCS -1/8"x7-1/11 WELLHEAD= GRAY ACTUATOR= BAKER KB. E.EV = 64' BF. ELEV = ? KOP= 4900' Max Angle = 101'@ 10543' Datum MD = 8463' Datum TVD = 8800'SS FOC 13-3/8" CSG, 72#, N-80 BUTT, ID = 12.347" 1 Minimum ID =1.920" @ 7987' XO 4-1/2" TBG, 11.6#, 13 -CR VAM TOP, J— 8041' .0152 bpf, ID = 3.958" TUBING STUB8048' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID=4.892" I LNR 4-1/2" TBG, 12.6#, N-80, .0152 bpf, D = 3.958" 8256' 3-1/2" TBG, 9.2#, L-80, .0087 bpf, D = 2.992" 828T 9-5/8" CSG, 47#, N-80/ S-95 BTC, D = 8.681" 8672' TOC 8775' 3-3/16" LNR 6.2#, L -8Q .0076 bpf, D = 2.8" 9206' BKR WHIPSTOCK W /PERM. PKR (04/01/08) 9206' RA TAG9206' 7" LNR, 29#, N-80 BUTT, .0371 bpf, D = 6.184" 9—I75 8' L-3/8" LNR, 4.7#, 13 -CR STL XO TO L-80 STL X 2-3/8" XO, D = HES XN NP, D = X5-1/2' XO, D = CAMCO DB -6 Nf 8127' I—i5-1/2"BKRSBRASSY,D= 19-5/8` X 5-1/2" BKR SAB PKR ID = ? 814b' 1-y 19-5/8" 6-5le" X 4-12" XO, D= 3-958" PERFORATION SUMMARY 07-01 B ANGLE> 70° @ 9665'—" ORIGINAL WBS & 07-01A REF LOG: MCNL/GR/CCL on 0424/08 4-1/2" TUBING TAIL, D = 3.958" ANGLE AT TOP PERF: 35" @ 8982' Note: Refer to Pmdmton OB for Nstorical oerfdata 3-1/2" X —3-3/16-X0 D = 5,7q- 79" SIZE SPF INTERVAL O NS z DATE 1.56" 6L8993'- 8982-8992 O 03/04/18 1.69" 6 9003' 0 08123/19 1.56" 69660-9690O 0725/17 1.56" 69870 -10000 O 0425/08 156" 60050 -104300 0425/08 1.56' 60640 -10960 C 0425/08 L-3/8" LNR, 4.7#, 13 -CR STL XO TO L-80 STL X 2-3/8" XO, D = HES XN NP, D = X5-1/2' XO, D = CAMCO DB -6 Nf 8127' I—i5-1/2"BKRSBRASSY,D= 19-5/8` X 5-1/2" BKR SAB PKR ID = ? 814b' 1-y 19-5/8" 6-5le" X 4-12" XO, D= 3-958" JAhtIY NL)'k: """CHKVMt IBGS LINK"WCLL 07-01 B ANGLE> 70° @ 9665'—" ORIGINAL WBS & 07-01A 4-1 /2" CAMCO DB -6 NP, D = 3: NOTSHOWNBELOW WHIPSTOCK. 4-1/2" TUBING TAIL, D = 3.958" 8228' ELMD TT LOGGED 0729/89 8287' 3-1/2" X —3-3/16-X0 D = 5,7q- 79" 22' 5-1/2" X 4-1/2" XO, D=3.958" 08/06/19 CJWJMD PULLED ROCK SCREEN (08N2l19) N02107106 DOVON 16 RWO 2205' 4-7/2"HESX NP,D=3.813" EPD/JMD ADPERFS (0823/19) NORDIC 1 CTD SIDETRACK (07-018) 0828/19 GAS LIFT MANDRELS BTN/JMD ADPERFS 03/04/16 ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3243 3243 1 MNG DMY RK 0 04/08/18, —L 3 5507 5481 22 MdG DMY RK 0 04/08/181 1 — 2 6678 6493 30 M G DMY RK 0 02/02/061 1 7808 7510 25 MMG DMY RK 0 02/02/06 7887' 4-1 /2" HES X NP, D = 3.813" 7887' -4-12` SLTD LNR/SCREEN ON X -LOCK (826/19) 7917' 9-5/8" X 4-1 /2" 8KR S-3 PKR ID = 3.670" 7950' 4-1/2" HES X NP, D = 3.813" 7981' 3.70"BTT DEPLOYMENT SLV,D=3.00" L-3/8" LNR, 4.7#, 13 -CR STL XO TO L-80 STL X 2-3/8" XO, D = HES XN NP, D = X5-1/2' XO, D = CAMCO DB -6 Nf 8127' I—i5-1/2"BKRSBRASSY,D= 19-5/8` X 5-1/2" BKR SAB PKR ID = ? 814b' 1-y 19-5/8" 6-5le" X 4-12" XO, D= 3-958" 8188' 3-1/2"BKR DEPLOY SLV,D=; 8200' 4-1 /2" CAMCO DB -6 NP, D = 3: 8256' 4-1/2" TUBING TAIL, D = 3.958" 8228' ELMD TT LOGGED 0729/89 8287' 3-1/2" X —3-3/16-X0 D = 5,7q- 79" 19-5/8" X 7" BOT TIFBK SLV W/ LNR HGR ID = ? I I y\�MILILLOUT WINDOW (07-01B) 9201'- 9207' 10500 2-3/8" GBP (07 PBTD { 10987' 2-3/8" LNR, 4.7#, L-80 STL, .0039 bpf, D = 1.995" 11025' PRUDHOE BAY UNIT WELL: 07-01B PERMIT No: 2080380 API NO: 50-029-20272-02-00 t, T11N, R14E, 2037' FNL & 7' FW BP Explora5on (Alaska) REV BY COMMENTS DATE REV BY COMMENTS ROWAN 35 ORIGINAL COMPLETION 04/16/18 MTWJMO SETX LOCK SLOTTED ROCK SCRN N4/3S SIDETRACK 07-01A 08/06/19 CJWJMD PULLED ROCK SCREEN (08N2l19) N02107106 DOVON 16 RWO 0828/19 EPD/JMD ADPERFS (0823/19) NORDIC 1 CTD SIDETRACK (07-018) 0828/19 LLG/JMD SET SLTD SCREEN ONX-LOCK(08l BTN/JMD ADPERFS 03/04/16 MTWJMD GLV C/O 04108/18) PRUDHOE BAY UNIT WELL: 07-01B PERMIT No: 2080380 API NO: 50-029-20272-02-00 t, T11N, R14E, 2037' FNL & 7' FW BP Explora5on (Alaska) ivioff%..„4, V ` • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO ION REPORT OF SUNDRY WELL OPE NS MAR 2 3 2018 1. Operations Performed , 7 Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown? ❑ Suspend ❑ Perforate Q Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other:Add 10'perfs ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 208-038 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20272-02-00 7. Property Designation(Lease Number): ADL 028312 8. Well Name and Number: PBU 07-01B 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 11026 feet Plugs measured 10500 feet true vertical 9019 feet Junk measured none feet Effective Depth: measured 10500 feet Packer measured 7927,8135 feet true vertical 9032 feet Packer true vertical 7617,7797 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 38-118 38-118 1530 520 Surface 2684 13-3/8" 36-2720 36-2720 4930 2670 Intermediate 8643 9-5/8" 33-8676 33-8232 8150/6870 5080/4760 Liner 858 7" 8343-9201 7968-8659 8160 7020 Liner 3044 3-1/2"x 2-3/8" 7981-11025 7664-9019 11200 11780 Perforation Depth: Measured depth: 8982-10960 feet True vertical depth: 8476-9015 feet Tubing(size,grade,measured and true vertical depth) 5-1/2',17#,13Cr85/L-80 x 4-1/2",12.6#,13Cr85/L-80 31-8258 31 -7899 Packers and SSSV(type,measured and 4-1/2"BKR S-3 Packer 7927 7617 true vertical depth) 5-1/2"BKR SAB Packer 8135 7797 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED ,',,`t,, 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: 20 1 702 600 234 Subsequent to operation: 102 5847 2116 1250 529 14.Attachments:(required per 20 AAC 25 070.25 071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory El Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG ❑ GINJ ❑ SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: . N/A Authorized Name: Vohra,Prachi Contact Name: Vohra,Prachi Authorized Title: Production Engineer Contact Email: Prachi.Vohra@bp.com // Authorized Signature: l /f?C✓�5--— Date: /224_24: Contact Phone: +1 907-564-4677 Form 10-404 Revised 04/2017 tr-7, '1_%'2"6/1,iBDM p PR 0 4 414 Submit Original Only • • ,.. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary March 22, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for the addition of perforations in well 07-01B, PTD# 208-038. 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 • • r` rn CO I H 11 w 0 0 0 � o J (' a O U Q N O >- O rn v co N E a) oZ ii O Q m L0Df- Lu'-' O co C� O0 0 — - OwCI) O Tu O ~ w O O O w O U Q J d U d Q cA ct rn O o z < w o * < 0 °- (3) 0N W O Z 0 c _ II a x Q O 0 a. 2 0 U c U 00 � wI- < 0 TU ry w = w w Z a) w H co >- o u) 0 m M 0 'TRH:= FMC 5-1/8"x 7-1/11 O 1 It I Y NV IIS: """CHKOMt ICiti&LNK"""WILL '"W€LLHEAD= GRAY0 0 7 GLE>70"@ 9665'""ORIGINAL WBS&07-01A ACTUATOR= BAKER C NOT SHOWN BELOW WHIPSTOCK. 22' H5-1/2"X 4-1/2"XO,D=3.958" I KOP 4900' Max Angle= 101"@ 10543' 9-5/8'FOC 2335' 1----_,„-> 2206' --I4-1/2'HES X NP,D-3.813" Detum MD= 8463' 9-5/8'FOC - 2451' Datum TV D= 8800'SS / l GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3243 3243 1 MMG DOME RK 16 05/12/08 13-3/8"CSG,724,N-80 BUTT,ID=12.347" 2714' 3 5507 5481 22 MMG SO RK 20 05/12/08 2 6678 6493 30 MMG DMY RK 0 02/02/06 1 7808 7510 25 MMS DMY RK 0 02/02/06 Minimum ID = 1.920" @ 79$7' ( 7887' J-14-1/2"HES X NP,D=3.813" I 2-3/8" XO Xi �� 7917' ,-1_9-5/8"X 4-1/2'BKR S-3 PKR D=3.870" 7960' -4-112"HES X MP,13=3.813" •ej "e4 7981' H3.70'BTT DEPLOYMENT SLV,D=3.00" �, �0�� '+0• i,+ 7987' H3-1/2"X 2-3/8"XO,D=1-920" 4-1/2'TBG, 11.6#,13-CR VAM TOP, - 8041' --. ______./.4 .• 40 8020' --14-112'HES XN NP,D=3.725' .0152 bpf,D=3.958' 011114 ► N1 '�,� ►�i1�' 8041' -14-1/2"X 5-1/2"X0,10=3.958" [. TUBING STUB I 8048' •41 '11-- , i, ►+�+1 8049' -15-1/2-CAMCO DB-6 NIP,13=4.562" , ?N1 /111 4 X4.•.4 8052' -{9-5/8"X 5-1/2"UNIQUE OVERSHOT ����4 1..11�j , ts. ♦�. ►11144 8127' -I 5-1/2"BKR SBR ASSY,D=? �11�$� 41111.1c _ No 8138' -19-5/8-X 5-1/2"BKR SAB PKR D=? I 5-1/2'TBG, 17#,L-80,.0232 bpf,D=4.892' - 8144' �NO ►V$'1 "- 8144' 7"FALLOUT EXTENSION,to.? I . 41 � 1N �a11 �1,) 8146' 6-5/8"X 4-112"XO,0=3.958'TOPOF3 112"LNi2,- 8138'elm ►1• ►; : [ 8188' -I3-1/2"BKR DEFL.OY SLV,D=3.000' ►y' E 111 I. l 8200' 1-14-1/2"CAMCO DB-6 NP,D=3.813" I 4-1/2"TBG, 12.64,N-80,.0152 bpf,D=3.958" 8256' • .4 44 .44 44 .44 8266' H4-1/2"TU31NG TAL,D=3.958" ►o1, ►`i+ 8228' H aMO TT LOGGED 07/29/89 3-1/2'TBG,9.2#,L-80,.0087 bpf,ID=2.992" H 8287' 1 ►+ 14 14 �.1 `---' 8287' H 3-1/2"X 3-3/16"XO,0=2.79" ill 11 ,19-518"CSG,47#,Nl 801 S 95 BTC,D=8.581" -I $672' ►11 14 11 8337' -I)9-5/8"X 7"BOT TRK SLV w/LNR HGR,D=? ►1i 111 TOC-I 8776' 1 3-3/16"LNR,6.24,L-80,.0076 bpf,D=2.8" ►11111►11 1-1._ 9206' 11104 .:r 4-T BKR WHIPSTOCK w/PERM.PKR(04101!08) - 9206' 'i�4'�1'14��4., 4a14 MLLOUT WINDOW(07-018)9201'-9207' ♦Aa�. RA TAG 9206' W1'1�1�1��i1:l.' a��ic►"• II 7"LNR 29#,N-80 BATT,.0371 bpf, =6.184' 9876' , H 23!8"CDP(07/25/17) D � •- .1.1.1: 10600' FERFORATION SUMMARY REF LOGMCNJGR/CCL on 04/24/08 / 'i sist ANGLE AT TOP PERF: 35°@ 8982' 2-3/8"LNR,4 7#,13-CR STL -I 10034' Note:Refer to Fkoduction DB for historical perf data XO TO L-80 STL '4 . SIZE SEE NTBNAL Opn/Sqz DATE 4v 1.56" 6 8982-8992 0 03/04/18 FETID H 10987' 4k• ••• 1-56" 6 9660-9690 0 07/25/17 1-56" 6 9870- 10000 O 04/25108 2-3/8"LNR,4.74,L-80 STL, .0039 bpf,D=1.995" -I. 11026' J 1.56" 6 10050- 10430 O 04/25/08 1.56" 6 10640- 10960 C 04/25/08 DATE REV BY COP?vU+fTS DATE REV BY CX)M1143JTS PRUDHOE BAY MIT 07/78 ROWAN 35 ORIGINAL COMPLETION +01/11/10 IVR/J143 DRLG DRAFT CORRECTIONS WELL: 07-01B 01/15198 N4/3S SIDETRACK(07-01A) 07/26/17 JDMJMD SET CIBP&ADF- FS(07/25/17) PRAT No '2080380 02/07/06 DOYON 16 RWO 03/05/18 BTNUMD ADPERFS(03/04/18) AR No: 50-029-20272-02-00 04/26/08 NORDIC 1 CTD SIDETRACK(07-01 B) SEC 34,T11 N,R14E 2037'FM_&7'FWL 05/05/08 JO/TLH 1 F0±GO 05726/08 JLJ/SV GLV 00(05/12/08) BP Exploration(Alaska) • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations H Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program,5 0,/ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other f c/13/7 7 u 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 208-038 3. Address: P.O.Box 196612 Anchorage, Development ET Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20272-02-00 7. Property Designation(Lease Number): ADL 0028312 8. Well Name and Number. PBU 07-01B 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 11026 feet Plugs measured 10500 feet RECEIVED I V true vertical 9019 feet Junk measured feet AUGffective Depth: measured 10500 feet Packer measured See Attachment feet U t7 017 true vertical 9032 feet Packer true vertical See Attachment feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 38-118 38-118 1530 520 Surface 2684 13-3/8"72#N-80 36-2720 36-2720 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9660-9690 feet feet 9870-10000 feet 10050-10430 feet 10640-10960 feet True vertical depth: 9034-9044 feet feet 9047-9044 feet 9043-9041 feet 9009-9015 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): SCANNED NOV 0 B 2017. 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: 230 19520 326 339 Subsequent to operation: 20 1 702 234 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas ❑ WDSPL ❑ 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: ( ) L _. ! & 1 7 Date:���///5;42_4 I t 4,.. Contactt Phone:8q/+1 9075644677 Form 10-404 Revised 04!2017 1/r/, J 0 / /�0�/i / RBDMS t'.I 1 L `017 Submit Original Only • • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue RECEIVED Anchorage, AK 99501-3572 AUG 2 5 2017 AOGCCRE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary August 24, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug and Adding of Perforations for Well PBU 07-01 B, PTD # 208-038. 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 07-01B SW Name Type MD TVD Depscription 07-01B TBG PACKER 7927.44 7616.85 4-1/2" Baker S-3 Perm Packer 07-01B TBG PACKER 8135.47 7796.83 5-1/2" Baker SAB Packer • • d N O !Q N O- 00 O O 090 g N 00 0 000 O CNILOCNILO N L) d' ON- CO CO (O I- U 4iMM= Lom _LO0- L0 0oacpcD (0 rNd' CO�) m e- N' M CO CO ' ' CO N- N ti 0 r r O O (O N 0) 0) O) O) LON- 0) -- N I- M N- CO toM M O m f- M O N O CO O O M r` CO CO NN000OOti0) co N- N- llllllll H co 'cr mco COCOM 000W %- MCN.) O MMMMOCOCOCOMMMN- cc N CO I- ti ti N- N N- it 0 L° L° ONCO (NO (NONOONOOM (OtLOA O) _ N N CO CO I, . 0) CO 03 00 4.0 m QP O CO M 0 O CO CO M r- Is CO CO CO • M CO Nr M M M N CO N N- M M 03 _ CO O • CO • M_ WLo l[) 0 LC) O to 0 0 CO 0 p 0 0 00 0) CO 0) CO 00 CD � 0 co a i O M J J •� •N C N d' N- N- V CO V Z * 0 O ti *k • m O a0 - - - - co - N , N - U N (`? n n nM ic- NNN- Q 0) 0) 0) N n j N t +- Cp co O m0cocop 00 O CCCOCDN - 00 (000LnN0O - N NCO N M mw co W W W =0 Q Q Q ' U Wwww riDp u. w w w c a t w z z z z o Z w W W W W W W W m m m m 10D1- 1- 1--' ZZZZDDDD U (nZZZJJJJHHHH 0 S = 2 ¢ Ek _ _ _a) 5 2 -1 b o $ 2 0 ' 2 2 / ° @ � , $ x _ 00 02 . , $ 2 - E a30- o13 ° 2 2 E 2 % ■ S k $ O- E 2 � o § > g G § a _Rw ® f � 2 = 6 o-o � • � / kkk . EE / S S 5 & ' _ c a U ■ f 000 = Q 0 y \�= CD/ = § %E E Et a © a 2 k t \ E o CO q / k ƒ,- 22o.k / >, 0. 2 2 » o : 7 R O .� b c R O � 2 a•2 � \ ) (U Z. co X \ _7 o 3 c M ® � 2w _ _ L Ar 'P0_ / I's' R -r22 % 0 t � Qb _ .cb » # w = on a Lo 4 3 � � �£ .t Do 2 � N. ® C•1 0 2 < a_ 0 o c c 0 3 « 2ER � E E2 �I — a ■ e a q ; 2 g i » § - 7 re \ � — \ Lt 2 2E % $ � � e -50 / ƒ / k k 2 o k $ u) ® ¥ -CI e 6 @ ® © R q / cn 7 \ / q a % 0 0 2 1 00 c _ . 9 00010 2 / ° ° - k k / \ k \ ' t \ I co k f / J 7_1 c e £ , # o % R O E E. Y - � � d / � 0) .oo ^I- a .0 2 � O 0 -, 01-245 . � ® a / o e / - (ao * _c) — 0 2 4,-- 0 2 t / o - 2 E o ; O -7 O M I E o ; n A- LL' E ¥ ¥ / \ C@4 5 / / M � ^ U r- ~ « • •"� 'TIS •= FMC 5-1/8'x 7-1/11 O 7 NU itS: ""'(:HKUMt iti(9li LNK'""WtLL VVELHEAD= GRAY - ANGLE>70'Q 9665""'ORIGINAL WBS&07-01A ACTUATOR= BAKER C NOT SHOWN BELOW WHIPSTOCK. KB.ELEV= 64* BFELEV= ? KOP= 4500 , 22' -5-1/2"X 4-1/2"XO,D=3.958' Max Angle= 101'(c 10543' 9-5/8-FOC H 2335' 1.-......_ 2205' -GAS4 1/2"LHFf MAES X NP Ds=3.813" Datum MD= 8463' 9-5/8'FOC --1 2451' �— Datum ND= 8800 SS ST MD WDI DEV TYFE VLV LATCH PORT DATE , 3243 32431 1 MMD DOME RK 16 05/12/08 13-3/8"CSG,72#,N-80 BUTT,D=12.347' H 2714' 3 5507 5481 22 MNG SO RK 20 05/12/08 2 6678 6493 30 MAG DIN RK 0 02102/06 1 7808 7510 25 MNG DMY RK 0 02/02/06 Minimum ID = 1.920" @ 7987' L7887' -14-1n"I-ES X 2"P,D=3.813" 3-1/2 X 2-3/8" XO T� iirli 7917' -.9-5/8"X 4-1/7 BKR S-3 FKR,D=3.870" IIIII III 7950' -14-1/2"HES X NP,D=3.813' ���� ;s. 7981' H310"BTT DEPLOYMENT SIN,D=3.00- I t1 i1�II ►`#1 Mf. 7987' -13.1/7 X 2-3/8"XO,D=1.920" 4-1/7 TBG,11.6#.13-CR VAM TOP, 8041' #1 41 8020' -4-1/7 HES XN NIP,D=3.725" 41 ►14 .0152 bpf,D=3.958' /1111 mini, 1111 ►11#� 8041' --14-1/2"X 5-12'XO,D=3.958' TUBIJG STUB H 8048' 0111 ►1111 8049' 5-12'CAMDO DB-6 NP,D=4.562' ,1►j1j1 ►111-� 4111 111 II $052' H9-518"X 5-1/2'1R IQUE OVERSHOT X111 111►#11 11 111111 ►1/111 /- D 4 8127'_1--15-1/2" 111 ►1N =?11111 ►1111141�,4 8138' H9-518"X5-12"BKR SAB PKR,D=? 15-1/2"TBG, 17#,L-80,.0232 bpf,D=4,892' 8144' •�1�1� ►�1�1�4i 8144'---f 7"MLLOUT E IH3SION,D=? ‘1# ►1♦fii TOP OF 3-42"LNR 8138'elm ` 111 ♦►t- 1,4 8145' 6-518"X 4-12"X©,D=3.958" 'y ►..#;1 8188' -13-112"BKR DEPLOY SLV,D=3.000' I 14' Pr y4'�`� 8200' -4-1/7'CAIVCO DB-6 NP,D=3.813" 4-1/2'TBG, 12.6#,N-80,.0152 bpf,13=3.958" -I 8256' 1/ 11 I# ►1 8256' -14-1/7 TUBING TAL,D=3.958" 14 1.1 /i48228' --1 aND TT LOGGED 07/29/89 3-12"TBG,9.2#,L-80,.0087 bpf,D=2.997 -I 8287' 1 1•"1i 1 8287' D 3 112 "X 33116"XO. =2.79" 9-5/8"CSG,47#,N-80/8-95 BTC,D=8.681" H 8672' '#1 /11 # 8337' --I9-5/8"X 7"BOT TRK SLV w/LNR HGR,D=? 111 01 TOC -I 8776' # *0.44%I • ►1�14 3-3/16"LNR,6.2#,L-80,,0076 bpf,D=28" H 9206' 111##114 /111 BKR M STOCK w/PERM PIER(04/01/08) -I 9206' .,, +4 ,14`14 MLLOUT WINDOW(07-01B)9201'-9207' s 1111 RA TAG H 9206' �1+1{F#,1:1,�O :i+i�1�1�111�1 7"LNR,29#,N-80 BUTT,.0371 bpf,D=6.184" H 9875' , ',v'4 1 ,",: 10500' H 2-3/8'CEP(0725/1 7) ,�-�j���,�� (yam, �,�/ ��� T♦1 FERFORATDN SUMMARY SII REF LOG:MCNUGR/CCL on 04/24/08 / 'r Ltilit ANGLE AT TOP PERF: 67"@ 9660' 2-3/8"LNR,4.7#,13-CR STL -f 10034' Note:Refer to Ftoduction DB for historical perf data XO TO L-80 STL 1'h SEE SPF NTIVAL Opn/Sqz DATE •14`1i�1*#1. 1.56" 6 9660-9690 0 0725/17 PBTD H 10987' 1.56" 6 9870-10000 0 04/25/08 1.56" 6 10050-10430 0 0425/08 1.56" 6 10640-10960 C 0425!08 2-3/8"LNR,4.7#,L-80 STL,.0039 bpf,D=1.995" -I 11025' DATE REV BY COMMIS DATE REV BY COMMENTS FRUDHOE BAY UMT " 07/78 ROWAN 35 ORIGINAL COMPLETION 01/11/10 MyJMO DRLG DRAFTCORREfCTIONS WaL: 07-01B 01/15/98 N4/35 SIDETRACK(07-01A) 07/26/17 JDMJM? SET C1BP 8 ADPERFS(07/25/17) PEWIT No:'t080380 02/07/06 DOYON 16 RNID API No: 50-029-20272-02-00 04/26/08 NORDIC 1 CTD SIDETRACK(07-01B) SEC 34,T11N,R14E,2037'FNL&7'FIM_ 05/05/08 JO/TLH TREE C/O - 05/26/08 JLJ/SV GLV GO(05/12/08) BP Exploration(Alaska) Ima a Pro~ct Well History File Cov~age 9 J 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. aQ ~ _ ~.~ ~ Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: gY: Maria ~- .- Project Proofing gY; Maria Scanning Preparation eY: Maria Production Scanning Liuumuiiiiim P 3Q + ~ ~ _ .TOTAL PAGES c~ ~- (Count does not include cover sheet) ~~ /s/ Stage 7 Page Count from Scanned File: ~_ (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: 3 ~ /0 /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO gY: Maria Date: ~s~ s rescannin is re wired. II I II ~) II I II II I I III Scanning is complete at this point unles 9 q ed IIIIIIIIIIIIIIIIIII ReScann gY; Maria Date: Comments about this file: ~,wo.,~~ iiummuiiiuii DIGI L DATA Diskettes, N~ ^ Other, No/Type: Date: ~I pF Date: ,~ _x30= Date: ~ o ae,~a~xw~n oiuoiuiuum OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other.: o~a ~r~.,~ked iui~iuimuiim 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/22/2010 Permit to Drill 2080380 Well Name/No. PRUDHOE BAY UNIT 07-01 B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20272-02-00 MD 11026 TVD 9019 Completion Date 4/26/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATIDN Types Electric or Other Logs Run: MWD DIR, GR, RES, GR /CCL /CNL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ry mearrrmi ~~umuer game a~a~e mews rvo atar~ atop ~.n rcecervea ~.u~mnenw ED C Lis 16390 Neutron 8688 10971 ,Ofleff 6/6/2008 LIS Veri, GR, CNT ~ og Neutron 5 Blu 8690 10967 serf' 6/6/2008 MCNL, Lee, GR, CCL, ~a,1~,L CNL 24-Apr-2008 U~t~ D Asc Directional Survey 9200 11026 Open 5/23/2008 Rpt Directional Survey 9200 11026 Open 5/23!2008 pt LIS Verification 9050 11026 Open 7/17/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS D C Lis 16605~nduction/Resistivity 9050 11026 Open 7/17/2008 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS og Gamma Ray 25 Col 9225 11026 Open 7/14/2008 MD GR i / ~ r~Log Induction/Resistivity 25 Col 9225 11026 Open 7/14/2008 MD MPR, GR og Induction/Resistivity 25 Col 9225 11026 Open 7/14/2008 TVD MPR, GR og See Notes 5 CoI 9040 11010 Open 7!14/2008 Depth Shift Monitor Plot ', Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments •I •I DATA SUBMITTAL COMPLIANCE REPORT 2/22/2010 Permit to Drill 2080380 Well Name/No. PRUDHOE BAY UNIT 07-01 B Operator BP EXPLORATION (ALASKA INC API No. 50-029-20272-02-00 MD 11026 TVD 9019 Completion Date 4/26/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y N~ Daily History Received? ' '' N Chips Received? ~#- Formation Tops ~~ N Analysis 47'I~ Received? • Comments: Compliance Reviewed By: Date: '1 u ®/~ BAKER F~V~iE/ES Saber Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKA'11UN (ALASKA) lNC CUUN'IY NUKIH SLUYIr BUKUUGH WELL NAME 07-O1B STATE ALASKA FIELD PRUDHOE BAY UNIT THIS DISTRIBUTION LIST AUTHORIZED BY DATE 7/16/2008 CATRINA GUIDRY SO #: 1927618 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE_ AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv' BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: ~~~~ ~~ Page 1 of I ! • NTE L®~ ata 'I"ranS ittal F®r To: State of Alaska -A®GCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 07-O1B Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPRlDirectiona.l Measured Depth Log (to follow) LAC Job#: 1927618 Sent by: Catrina Guidry Date: 07/16/08 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 BAKER sate~~ .. , .., .r Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~o~ ~~ ~ ~~~as' r~~~ BAKER HU6NES ~~ 7260 Homer Drive Anchorage, AK 99518 L_J To Whom It May Concern: May 23, 2008 Please find enclosed directional survey data for the following wells: P2-08APB 1 P2-08A G-11B 15-25B 07-O1B Enclosed for each well is: tea copies of directional survey reports lea 3.5" floppy diskette 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: Q ,State of Alaska AOGCC DATE: ,a 3 .. ,a,,p~ Cc: State of Alaska, AOGCC ~.u8- C~38 STATE OF ALASKA ~SJi~~~B ALASKA~L AND GAS CONSERVATION COMNRSSION ~lA~ 2 2 2008 WELL COMPLETION OR RECOMPLETION REPORT AND L~aGska Oii & Gas Cons. Commission ®n~hnr~n~ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1 b. Well Class: zoAAC zs.~os zoAAC zs.»o ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aba , ~ ~ 12. Permit to Drill Number - BP Exploration (Alaska) Inc. 4/26/2008 208-038 3. Address: 6. Date Spudded ~ 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 4/18/2008- 50-029-20272-02-00 ' 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 4/22/2008 ~ PBU 07-01 B - FWL, SEC. 34, T11 N, R14E, UM FNL, 7 2036 8. KB (ft above MSL): 64'- 15. Field /Pool(s): Top of Productive Horizon: 3831' FNL, 960' FWL, SEC. 34, T11 N, R14E, UM Ground (ft MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 5158' FNL, 1062' FWL, SEC. 34, T11 N, R14E, UM 10987' 9017' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 676230 y- 5948888 Zone- ASP4 11026' 9019' ADL 028312 " TPI: x- 677229 y- 5947117 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: - 5945793 Zone- ASP4 th: x- 677364 Total De None y p 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ' Submit electroni and rinted information er 20 AAC 2 .0 0 N/A ft MSL (Approx.) 1900 21. Logs Obtained (List all logs here and submit electronic and printed information r 20 AAC 25.071): MWD DIR, GR, RES, GR / CCL / CNL ~/%NDoi/~ 9i~OIT~/~a ~6~'TYQ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH.MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 2 94# H-40 Surface 11 S rface 11 3 " 300 sx Ar icset 13-318" 72# N-80 Surface 2714' Surface 2714' 17-1/2" 5300sxArcticset 9-5/8" 47# N-80 / RS / S00.9s Surface 8670' Surf ce 8228' 12-1 /4" 1000 sx Class 'G' 7" 29# N-80 337' 7 3' 8-1/2" 525 sx lass 'G' 3-1/2" x 2-7/8" 9.2# / 6.4# L-80 8188' 2 7841' 8659' 4-1/4" 102 sx Class'G' 2-3/8" 4.7# L-80 / 13Cr 7981' 1102 ' 7 664' 9019' 3" 63 sx lass 'G' 23. Open to production or injec tion? ®Yes ^ No 24. TuswG RECORD If Yes, list each i MD+TVD m P f T & B tt nterval open ration Size and Number): rf SIZE DEPTH SET MD PACKER SET MD ; ( o op o o e o 6 spf 1 56" Gun Diameter 4-1/2", 11.6#! 12.6#, 13Cr 8052' 7917' , . MD TVD MD TVD s-tlz°, nn X a-vz^, 12.6#, L-80 / N-80 8047 - 8255' 8132' 9870' - 10000' ~ 904T - 9044' ~ 10430' ~ 9043' 9041' 10050' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - - 10640' - 10960' i 9009' - 9015' ~ DEPTH INTERVAL MD AMOUNT & KIND Of MATERIAL USED 2500' Freeze Protect w/ 40 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date Of Test: HOUrS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing Casing PreSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): PreSS. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall Cores Ac uired? ^Yes ®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 2Q,~C 25LL071. ~ i0td f ~fr?~L+m3 ~ None ' S BFI ~iU-~ ~ 0 2DD8 ° , Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS ' NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top CGL 9329' 8778' None Base CGL 9400' 8844' 23S6 /Zone 2B 9468' 8903' 22TS 9534' 8956' 21 TS /Zone 2A 9631' 9021' Formation at Total Depth (Name): 21 TS /Zone 2A 9631' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. / / OS ~ ( ~`~~ Signed Terrie Hubble Title Drilling Technologist Date PBU 07-01 B 208-038 Prepared eyName/Number. Te~rie Hubble, 564-4628 Well Number Permit No. / A rOVal No. Drilling Engineer: Mel Rixse, 564-5620 INSTRUCTIONS GeNeRAI.: 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 1a: Class cation 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: 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 29: 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 02/2007 Submit Original Only • BP EXPLORATION Page 1 of 9 Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Spud Date: 6/5/1978 Event Name: REENTER+COMPLETE Start: 3/26/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 4/26/2008 Rig Name: NORDIC 1 Rig Number: Date Hours Task Code NPT Phase Description of Operations From - To 4/15/2008 12:00 - 14:00 2.00 MOB N RREP PRE Remove drive motor and blind off same. 14:00 - 00:00 10.00 MOB N WAIT PRE Still on DS 15-25B. Wait on wind to diminish, 30+ mph wind directly toward cellar doors. 4/16/2008 00:00 - 07:30 7.50 MOB N WAIT PRE Wait on wind to open cellar doors 07:30 - 08:00 0.50 MOB P PRE PJSM for moving rig off well & to DS7. 08:00 - 11:00 3.00 MOB P PRE Move rig to DS 7. 11:00 - 13:15 2.25 MOB P PRE Spot matting boards, PJSM & Remove tree cap (due to tree height) .PJSM & Spot rig over well. Accept rig at 11:00 hours- 13:15 - 15:30 2.25 BOPSU P PRE NU BOP. 15:30 - 22:50 7.33 BOPSU P PRE Test BOP. AOGCC rep John Crisp waived witnessing BOP test. 22:50 - 23:40 0.83 BOPSU P PRE Blind rams not holding pressure. Conduct PJSM for BOP maintenance. Open doors on top set of BOPs to access blind ram bodies. 23:40 - 00:00 0.33 BOPSU P PRE Re-test blind rams, holding good test. Rig up to PT both TIW valves. Test low and high level H2S and LEL alarms, good test. 4/17/2008 00:00 - 02:00 2.00 BOPSU P PRE Lift BPV lubricator to rig floor. Pull BPV. No pressure under it. Close master valve. 02:00 - 02:30 0.50 BOPSU P PRE Break down BPV equipment and send it down beaver slide. Bring BTT motor and window mill onto rig floor. 02:30 - 03:10 0.67 BOPSU P PRE Line up valves to pressure test inner valve. Test 400 / 3,800 psi, good. 03:10 - 03:25 0.25 STWHIP P WEXIT SAFETY MEETING. Discuss procedures, hazards and mitigations for picking up window milling BHA. 03:25 - 03:50 0.42 STWHIP P WEXIT PU BHA #1 - 2.74" Diamond Speed Mill, 2.73" Diamond Reamer, 2.13" Extreme "X" Mud Motor, Circ Sub with 1/2" Ball Seat, Disconnect with 5/8" Ball Seat, 2 jts. of 2-1/16" CSH, Check Valve and Weld on Connector. 03:50 - 05:40 1.83 STWHIP P WEXIT RIH with BHA #1, take crude returns outside to flowback tank. Weight check at 9,000 ft is 29 Klbs. Dry tag whipstock at 9,205 ft, tag a second time at the same spot. Pick up 10 ft and swap well over to 2# biozan. 05:40 - 07:20 1.67 STWHIP P WEXIT Park at 9,195 ft and circulate well to biozan. Getting gas returns, hold 300 psi choke pressure until biozan at surface. Ci s 07:20 - 11:30 4.17 STWHIP P WEXIT Tag and flag pipe at 9208.1'. Time Milling window 1fUhr. ~i~ 1.76/1.78 bpm C~3 2880 psi. 2380 FS. Mill to 9212'. 07'D~~ 11:30 - 14:00 2.50 STWHIP P WEXIT Continue to time mill 1ft/hr. Stall at 9214.1 Gas in returns. 1.75/1.74 ~ 2500 psi FS. PU. 14:00 - 15:00 1.00 STWHIP P WEXIT Ream to 9214.1 seen motor work at 9213. 15:00 - 15:30 0.50 STWHIP P WEXIT Mill 9214.1. Milling with little MW 1.61/1.61 BPM C~? 2350 psi making 5 ft/hr min weight on bit .3-.4K. 15:30 - 17:30 2.00 STWHIP P WEXIT Mill rat hole to 9225.1. 1.61/1.61 bpm 02450 psi , 8 fpm..5K WOB. 17:30 - 18:30 1.00 STWHIP P WEXIT Ream window and dry tag same. Clean pass up and down through window with pumps off. 18:30 - 20:00 1.50 STWHIP P WEXIT POOH. Pump 1.7 bpm while POOH. 20:00 - 20:15 0.25 STWHIP P WEXIT Tag stripper. SAFETY MEETING. Discuss procedures, hazards and Nnntea: oiioiluuts a:~cee r+m BP EXPLORATION Page 2 of 9 Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Spud Date: 6/5/1978 Event Name: REENTER+COMPLETE Start: 3/26/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 4/26/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code i NPT ~ Phase Description of Operations 4/17/2008 20:00 - 20:15 0.25 STWHIP P WEXIT mitigations for laying down BHA. Leave well open and flow check. 20:15 - 20:50 0.58 STWHIP P WEXIT Lay down BHA #1. Window mill came out in gauge, no-go with 2.73" ring. 20:50 - 21:05 0.25 DRILL P PROD1 SAFETY MEETING. Discuss procedures, hazards and mitigations for pumping N2 to purge reel. 21:05 - 21:40 0.58 DRILL P PROD1 Pump 40 bbls fresh water, then 15 bbls inhibited water, then 5 bbls McOH ahead of N2. 21:40 - 22:00 0.33 DRILL P PROD1 Pressure test N2 line. Shut in rig and open up reel to N2 unit. Pump 1,500 scfm N2 for 15 min. 22:00 - 22:40 0.67 DRILL P PROD1 Shut down pumping and allow N2 to bleed off. 22:40 - 23:00 0.33 DRILL P PROD1 Break off well, cut off CT connector. Install internal grapple connector + cable, and pull test. 23:00 - 23:10 0.17 DRILL P PROD1 SAFETY MEETING. Discuss procedures, hazards and mitigations for pulling CT across and winding it onto reel. 23:10 - 00:00 0.83 DRILL P PROD1 Pull CT across pipe shed and secure it to reel. 4/18/2008 00:00 - 00:30 0.50 DRILL P PROD1 Unhook 1502 line from reel swivel. Hook up slings to work reel. 00:30 - 00:50 0.33 DRILL P PROD1 SAFETY MEETING. PJSM with CH2MHILL driers for lowering work string and picking up a-coil. discuss hazards and mitigations, and crew placement. 00:50 - 03:30 2.67 DRILL P PROD1 Lower work strip onto trailer and secure it. Lift e-coil into reel house, secure with driveshaft pins and hook up 1502 line. Attach internal grapple and pull test, prepare to pull CT across to injector. Check fluid level in well, still visible. 03:30 - 04:10 0.67 DRILL P PROD1 Pull CT across pipe shed roof and into injector. Cut off internal grapple and install CT connector. Pull test to 36 Klbs. 04:10 - 05:55 1.75 DRILL P PROD1 Install cable head and test, good. Line up valves to fill reel forward, and fill reel. 05:55 - 06:00 0.08 DRILL P PROD1 Pick up injector, MU pressure test plate to cable head. Pressure test to 4,000 psi, good. 06:00 - 07:00 1.00 DRILL P PROD1 MU BHA #1 with 1.8 motor. 07:00 - 07:10 0.17 DRILL P PROD1 Test MWD tools. 07:10 - 09:05 1.92 DRILL P PRODi RIH .Swapping to FLO Pro.RIH to 9100' 09:05 - 10:00 0.92 DRILL P PRODi Log tie-in. +2.5 ft correction. 10:00 - 10:10 0.17 DRILL P PROD1 RIH seen bottom of widow. 10:10 - 14:30 4.33 DRILL P PROD1 Directionally drill 3350psi FS at 1.62 bpm. Drill a 1.61/1.62 bpm ~ 3750 psi. 141 ROP,.87 WOB,INC 17.3, 9.41 ECD.Drill to 9303. ROP fell off to 30. Continue to drill 1.6/1.59 bpm C~? 3490 psi. 35 ROP, .37 W0B,15.5 INC, ECD 9.42. Drill to 9350'. 14:30 - 14:55 0.42 DRILL P PROD1 Wiper to window. 14:55 - 18:30 3.58 DRILL P PROD1 Directionally drill 1.6/1.58 bpm at 3470 psi,3300 psi FS. 16 ROP 2K WOB, 23 INC, ECD 9.44. 18:30 - 20:50 2.33 DRILL P PROD1 Slightly better ROP past 9,400 ft. Base of Zone 3 icked at 9 402 ft b Geo. Build angle with 60L toolface, drilling at 1.58 / 1.58 bpm, 200 - 900 psi motor work, ROP 40 - 80 ft/hr, and DWOB 1 - 3 Klbs. 18:50 -Stall at 9,550 ft, up weight is 28 Klbs clean pickup. 19:20 -Stall at 9,480 ft, up weight is 27 Klbs clean pickup. 20:50 - 21:20 0.50 DRILL P PROD1 Stall at 9,531 ft, up weight is 26 Klbs clean. h'flf1t20: 5/1~/[VUtf `J:LC:LL HM BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Spud Date: 6/5/1978 Event Name: REENTER+COMPLETE Start: 3/26/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 4/26/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ', Code NPT Phase Description of Operations 4/18/2008 20:50 - 21:20 0.50 DRILL P PROD1 Drill to 9,550 ft at 1.57 / 1.54 bpm, ROP 40 - 70 ft/hr. Motor work 300 - 700 psi. 21:20 - 21:50 0.50 DRILL P PROD1 Wiper trip from 9,550 ft to 9,220 ft. Clean trip up and down. 21:50 - 00:00 2.17 DRILL P PROD1 Drill from 9,550 ft. Loss of motor work and weight loss at 9,580 ft, clean pickup. Entry into 22N shale after 9,580 ft, ROP 10 - 20 ft/hr with 400 - 500 psi motor work and 5 Klbs DWOB. ECD = 9.49 ppg, 1.57 / 1.57 bpm. Stacking weight with around 400 psi motor work at 9,600 ft, stop and drill off slowly. Pick up to get weight back, up weight is 27 Klbs clean pickup. 4/19/2008 00:00 - 00:30 0.50 DRILL P PROD1 Continue drilling from 9,608 ft to 9,613 ft. Slow drilling, stacking weight. 00:30 - 01:00 0.50 DRILL P PROD1 Surveys showing decreasing DLS after 9,550 ft. Confirm with BHI and Geo that the landing point will be too low if current build rates are maintained. POOH for AKO change. 2.6 deg requested by BHI. Pull above window and open circ sub. 01:00 - 03:00 2.00 DRILL P PROD1 POOH pumping 2 bpm through open circ sub. 03:00 - 03:15 0.25 DRILL P PRODi Tag stripper, flow check well. SAFETY MEETING. Discuss procedures, hazards and mitigations for laying down BHA. 03:15 - 03:45 0.50 DRILL P PROD1 LD BHA #2. Bit is missing some gauge on nose, which accounts for part of the low build rates. Send WFT motor back to shop to adjust it down to 2.4 deg, no equipment on rig to do this. 03:45 - 04:45 1.00 DRILL N DPRB PROD1 Wait for motor from WFT shop. Install CT Inspect on reel. 04:45 - 05:20 0.58 DRILL P PROD1 2.4 deg motor arrives, bring to rig floor and MU BHA #3. 05:20 - 07:55 2.58 DRILL P PROD1 RIH with BHA #3 -New SRX340 bicenter bit, 2.4 deg AKO WFT motor + RES tool. RIH to 9230' 07:55 - 08:30 0.58 DRILL P PROD1 Log tie - in. -7'. 08:30 - 09:15 0.75 DRILL P PRODi IH to at 9613 09:15 - 15:45 6.50 DRILL P PROD1 Directionally drill. 1.49/1.45 bpm at 3380 psi, 3000 psi FS. 12.0 ROP, INC 12.9,5K WOB, 9.53 ECD. Slow drilling to 9625. Drilling break drill 1.44/1.41 bpm ~ 3450psi ,3250 psi FS, ROP 60-120, .5-4 K wob. ECD 9.62. Unable to hold angle 9610-9650. Will dip into HOT .Drill to 9840. POH for lateral assembl . 15:45 - 18:40 2.92 DRILL P PROD1 POH. 18:40 - 18:55 0.25 DRILL P PRODi Tag stripper. SAFETY MEETING. Discuss procedure, hazards, and mitigations for LD BHA. 18:55 - 19:45 0.83 DRILL P PROD1 Break off CT riser, stand back injector and circulate. LD BHA #3. Bit has some chipped cutters on nose and side, decide to run a new bit. AKO housing on motor is partially unscrewed, making it a straight motor. 19:45 - 20:10 0.42 DRILL P PROD1 Confirm with WFT that correct MU torque and Baker-locked set screws for AKO housing on next BHA, also double check AKO Printetl: 5/152008 9:2L:L"L Ewi BP EXPLORATION Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: 0 ell Name: 0 e: Name: From - To 7-01 7-01 REENTE NORDIC NORDIC Hours II R+COM CALIST 1 Task PLET A Code ~, E NPT __ 4/19/2008 19:45 - 20:10 0.42 DRILL P 20:10 - 22:00 1.83 DRILL P 22:00 - 22:55 0.92 DRILL P 22:55 - 23:20 0.42 DRILL P 23:20 - 00:00 0.67 DRILL P 4/20/2008 00:00 - 00:50 0.83 DRILL P 00:50 - 02:00 1.17 DRILL P 02:00 - 03:45 1.75 DRILL P 03:45 - 04:40 0.92 DRILL P 04:40 - 06:20 1.67 DRILL P 06:20 - 06:45 0.42 DRILL P 06:45 - 07:00 0.25 DRILL P 07:00 - 07:35 0.58 DRILL P 07:35 - 10:30 2.92 DRILL P 10:30 - 11:30 1.00 DRILL P 11:30 - 19:30 8.00 DRILL P 19:30 - 20:25 0.92 DRILL P 20:25 - 21:20 0.92 DRILL P Page 4 of 9 ~ Spud Date: 6/5/1978 Start: 3/26/2008 End: Rig Release: 4/26/2008 Rig Number: Phase Description of Operations PROD1 angle, reads 0.9 on BHI gauge. MU BHA #4 -New SRX3408 bicenter bit, W FT 0.9 deg AKO lateral assembly + RES tool. Test tool at surface, good test. PROD1 RIH BHA #4. Shut off pump, orient to lowside, pass through window on 1st attempt. PROD1 Log GR down from 9,220 ft at 120 ft/hr. Log to 9,270 ft, RA tag is not seen. Pull back to 9,220 ft and re-log section at 100 ft/hr. RA tag is seen, correct -8 ft. PROD1 RIH. Tag at 9,530 ft with motor work, pick up and orient to 60L. Pass through a second time with no weight loss. Stacking weight at 9,590 ft - 9,630 ft. Back ream through this area at full pump rate, slight overpulls seen, 1 - 3 Klbs. RIH to bottom. PROD1 Ta bottom at 9,832 ft and drill at 30R. 1.45 / 1.40 bpm, 3,300 psi FS. Initial ROP is 70 - 100 ft/hr with 1.7 Klbs DWOB. Drill to 9,890 ft, stacking weight occasionally. PROD1 Continue drilling past 9,890 ft. Level off at 90 deg after target TVD of 8,977 ft is reached. PROD1 Wiper trip from 9,955 ft to 9,220 ft. Clean pickup off bottom. Slight weight changes going through 22N shale at 9,600 - 9,640 ft. PROD1 Drill from 9,955 ft at 1.46 / 1.41 bpm. ROP is 70 - 90 ft/hr with 1-2 Klbs DWOB. Past 10,000' gain 3 more TVD feet after 9,950' sample had traces of HOT. Drill to 10,105 ft PROD1 Wiper trip from 10,155 ft to 9,220 ft. Clean pass up and down. PROD1 Drill from 10,105 ft at 1.44 / 1.39 bpm.. ROP is 70 - 100 ft/hr. Stacking weight at 10,214 ft, up weight is 34 Klbs. Drill to 10,250 ft. PRODi Wiper trip from 10,250 ft to 9,220 ft. Up weight is 27 Klbs off bottom, clean pickup. PROD1 Log Tie-in. Correction -.5'. PROD1 Wiper to TD. Clean trip. PROD1 Tag at 10254. Drill 1.42/1.36 bpm C~ 3550 psi, FS 3200psi, 90 ROP, .5 WOB, ECS 9.83 ppg. Drill to 10400. PROD1 Wiper to window clean trip. PROD1 Drill 1.43/1.38 bpm 3500 psi,fs 3200 psi, swap TF to straight up. 70 rop, .9K wob, ECD 9.89. Drill to 10450 ROP fell off to 26 rop. Drill 1.5/1.49 ~ 3960 psi, 3550 psi FS, 50-60 ROP, .25K WOB, ECD 9.83ppg, Swap to new mud at 10500'. drill 1.44/1.42 bpm C~ 3387 psi , 3050 FS, 3-30 ROP, 3K WOB, ECD 9.66. Drill to 1 PROD1 Wiper trip from 10,547 ft to 9,220 ft. 1-4 Klbs overpulls and motor work pulling through 22N shale from 10,547 ft back to 10,460 ft. Clean pass up through rest of hole. PROD1 Pull into casing and circulate minimum rate to change oil on rig Generator #1. Printetl: 5/15/2008 9:22:22 AM BP EXPLORATION Page 5 of 9 Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Spud Date: 6/5/1978 Event Name: REENTER+COMPLETE Start: 3/26/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 4/26/2008 Rig Name: NORDIC 1 Rig Number: Date ~', From - To Hours ' Task Code ~ NPT Phase' Description of Operations 4/20/2008 21:20 - 22:20 1.00 DRILL P PRODi RIH to complete wiper trip. , 21/2008 :20 - 00:00 0:00 - 01:35 67 .58 ILL RILL P P OD1 ROD1 New mud is an odd pink color after 1st circulation, call MI engineer to run a mud check -mud check shows all mud properties within normal range. Set down weight on shales at 9,530 ft and 9,650 ft. Set down at 10,450 ft. Difficult to get back to bottom, swelling shales. Run to 10,540 at minimum rate, then pull back through at full pump. Work up and down through the area 10,450 - 10,540 ft several times. Drill from 10,545 ft at 1.61 / 1.57 bpm. ROP is 20 - 50 ft/hr with 1 - 3 Klbs DWOB. Maintain 100 deg inclination, still going up strat through 22N shales. Drill to 10,600 ft. Continue drillin from 10 600 ft to 10 700 ft with ood ROP Came through top of 22N shale at 10,596 ft. 01:35 - 02:30 0.92 DRILL P PROD1 Wiper trip from 10,700 ft to 9,220 ft. 3-5 Klbs overpulls and motor work seen pulling back from 10,500 ft to 10,460 ft. 02:30 - 02:40 0.17 DRILL P PROD1 Tie-in depth from 9,230 ft. Correct +0.5 ft. 02:40 - 03:10 0.50 DRILL P PROD1 Finish wiper trip back to bottom. Difficult assin shales at 10 500 - 10 6 0 ft 02:50 - 15 gal freshwater release from rig water tank, when automatic shutoff for fill line malfunctioned. Total of 5 gal on pad, 10 gal in spill containment. Reported to x5700, was told 5 gal fresh water on pad is not a recordable spill. Traction #2008-I R-2616372. 03:10 - 04:45 1.58 DRILL P PROD1 Drill from 10,700 ft at 1.55 / 1.50 bpm. ROP is 80 - 100 fUhr. Maintain 88 - 90 deg inc to follow Zone 26 sand along dip. Drill to 10,850 ft. 04:45 - 06:15 1.50 DRILL P PROD1 Wiper trip from 10,850 ft. Clean pickup from bottom, 27 Klbs. Weight fluctuations going up through shale zone 10,550 - 10,500 ft. 06:15 - 07:05 0.83 DRILL P PROD1 Drill 1.29/1.24 bpm @ 3230 PSI, 2780 psi FS, 1.66K WOB, Drill to 10925. No motor work. Three attempts at tagging bottom without MW. 07:05 - 09:40 2.58 DRILL N DFAL PRODi POH. No over pulls. thru shale.10600-10450. POH to 9190 . Open EDC. Continue to POH. 09:40 - 13:20 3.67 DRILL N DFAL PROD1 BHA swap. Bit 4-2. PU Hughes bicenter, Extreme Motor drop RES. 13:20 - 13:35 0.25 DRILL N DFAL PROD1 Log tie-in -4' correction. 13:35 - 14:40 1.08 DRILL N DFAL PROD1 RIH 1.48 bpm ~ 3050 psi. Set down at 10465,10515,10536,10555,10585,10650, 10684 10702. 14:40 - 15:45 1.08 DRILL P PROD1 Drill 1.45 / 1.42 bpm ~ 3400 psi, 3140 psi FS, 150 ROP, .7K WOB, 10.18 ECD. Swap to 9.1 mud. Drill to 10994 run into a shale./ 15:45 - 18:50 3.08 DRILL P PRODi No ro ress drillin ,have made 1 ft in 3.08 hrs. RIH to bottom at good speed and set full weight on bit, no motor work. 18:50 - 21:45 2.92 DRILL P PROD1 POOH for bit change. 3-5 Klbs weight fluctuations and motor work from 10,650 ft rnncea: ai uicwa a:cccc r.m • BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Spud Date: 6/5/1978 Event Name: REENTER+COMPLETE Start: 3/26/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 4/26/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task '~ Code NPT Phase Description of Operations 4/21/2008 18:50 - 21:45 2.92 DRILL P PROD1 back to 10,450 ft. Pull through window and open EDC, pump 1.7 bpm out of hole. 21:45 - 22:00 0.25 DRILL P PROD1 Tag stripper and flowcheck well. SAFETY MEETING. Discuss crew responsibilities and positions, hazards and mitigations for BHA change. 22:00 - 22:30 0.50 DRILL P PROD1 Break off injector and stand back, circulate. Bit swap. Bit is junk, nose has been flattened. Re-run SRX3408 from build section, re-run same BHA. 22:30 - 00:00 1.50 DRILL P PROD1 Test BHA at surface, then RIH. 4/22/2008 00:00 - 00:30 0.50 DRILL P PROD1 Continue RIH with BHA #6. 00:30 - 00:35 0.08 DRILL P PROD1 Log GR down from 9,230 ft at 100 fUhr to tie-in depth. Correct -1 ft. 00:35 - 01:20 0.75 DRILL P PROD1 RIH to bottom. Set down weight at 9,625 ft - 9,650 ft. Set down 10,450 - 10,460 ft multiple times. Go to minimum pump rate. Run through 10,450 - 10,600 with pumps off. 01:20 - 02:10 0.83 DRILL P PROD1 Ta bottom at 10,990 ft and drill at 1.54 / 1.46 bpm, Initial ROP is 70 - 80 fUhr, dropping to 20 - 30 ft/hr after 11,015 ft. Try to build angle up to 89-90 deg to climb up stratigraphy. Stacking weight at 11,015 ft, pick up is 30 Klbs. 02:10 - 02:30 0.33 DRILL P PROD1 Tool is not building angle with highside toolface. Pull wiper trip to troubleshoot orienter. 02:30 - 02:40 0.17 DRILL P PROD1 Tag bottom and drill highside TF at 1.53 / 1.46 bpm. Very little motor work with 2.2 Klbs DWOB. 02:40 - 03:45 1.08 DRILL N DFAL PROD1 Continuous drop in inclination, despite HS toolface. On bottom troubleshooting not able to resolve problem. POOH to check BHA and bit. 3-7 Klbs overpulls through 10,600 - 10,500, with motor work. 03:45 - 05:30 1.75 DRILL N DFAL PROD1 Pull through window and open EDC. Pump 1.7 bpm out of hole. 05:30 - 05:45 0.25 DRILL N DFAL PROD1 Tag stripper and flow check well. SAFETY MEETING. Discuss hazards and mitigations for LD BHA. 05:45 - 06:10 0.42 DRILL N DFAL PROD1 LD BHA #6. Bit has some chipped cutters and starting to form grooves on the nose. 06:10 - 07:00 0.83 DRILL P PROD1 Ri u to cut CT for chrome mana ement. Cut 103' of CT. 07:00 - 10:00 3.00 DRILL P PROD1 MU CTC and test same. MU BHA. 10:00 - 11:45 1.75 DRILL N DFAL PROD1 RIH to 9220. 11:45 - 12:00 0.25 DRILL N DFAL PROD1 Log tie-in. Correction = -4' 12:00 - 13:30 1.50 DRILL N DFAL PROD1 RIH set down ~ 10478,10490,10509,10532 numerous times,10576,10590, 10605,10623, 10652,10,675, & 10692. RIH tag TD at 11026 13:30 - 14:28 0.97 DRILL P PROD1 Backream ~ 5 fpm 1.5 bhm at 3250 psi , FT 30L, FS, MW from 10650 to 10450 motor work the entire interval 14:28 - 14:45 0.28 DRILL P PROD1 RIH .5 bpm .set down 10500, 10538. RIH to 10720. 14:45 - 15:40 0.92 DRILL P PROD1 Backream from 10720', TF90L ~ 1.5 bpm 3400psi. 10571 200 psi MW, Irradic MW to 10420'. 15:40 - 16:00 0.33 DRILL P PROD1 RIH .5 bpm. Set down 10515 ,10524. RIH tag TD at 11025'. 16:00 - 17:00 1.00 DRILL P PROD1 Back ream TF 120R. 1.4 bpm ~ 2950 psi. MW at 10521 & 10476 17:00 - 17:50 0.83 DRILL P PROD1 RIH while c irculating liner pill to bit. Tag TD at 11027'. YIIM@tl: 5/15/'LUUtf `J:LL:CL HM BP EXPLORATION Page 7 of 9 Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Spud Date: 6/5/1978 Event Name: REENTER+COMPLETE Start: 3/26/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 4/26/2008 Rig Name: NORDIC 1 Rig Number: Date From - To I Hours Task Code NPT ~ .Phase Description of Operations 4/22/2008 17:50 - 21:20 3.50 DRILL P PROD1 POH. 21:20 - 21:45 0.42 DRILL P PROD1 La down drilling BHA. Install nozzle for reel blow down. 21:45 - 22:25 0.67 CASE P RUNPRD Flush coil and pickle. RU and cooling down N2 22:25 - 22:45 0.33 CASE P RUNPRD PJSM for N2 reel blow down 22:45 - 00:00 1.25 CASE P RUNPRD Blow down reel and bleed off reel to tiger tank 4/23/2008 00:00 - 00:30 0.50 CASE P RUNPRD PJSM for reel swap 00:30 - 04:00 3.50 CASE P RUNPRD Reel swa .Cut off CTC, install grapple and tail coil back to reel and secure. Lower reel to trailer, move trailers and PU e free coil. Install grapple and pull coil across to injector. 04:00 - 06:30 2.50 CASE P RUNPRD Install Baker CTC, pull test to 35K, pump 5 Bbls. McOH, 5 Bbls. fresh water, 2 Bbls. Flow-pro. PT inner reel valve to 4000 psi. Launch dart, 41.7 Bbls.coil volume. PT CTC to 3500 psi. 06:30 - 06:45 0.25 CASE P RUNPRD SAFETY MEETING covering procedure, hazards, and mitigations to PU liner. 06:45 - 11:00 4.25 CASE P RUNPRD PU liner as er ro ram: 2-3/8" rotating guide shoe, 2-3/8" STL float collar, 1 jt 2-3/8" STL 4.7 ppf L-80 solid liner, 2-3/8" STL float collar, 2-3/8" STL 4.7 ppg L-80 solid liner pup, 2-3/8" STL Baker Latch Collar, 30 jts 2-3/8" STL 4.7 ppf L-80 solid liner without cementralizers, 67 jts 2-3/8" STL 4.7 ppf 13CR solid liner w/ cementralizers, 2-3/8" STL 4.7 ppg L-80 pup, 2-3/8" X 3-1/2" Chrome XO, BTT Deployment Sleeve. Total Liner BHA Len the 3043.67' Torque each connection between 800-1100 psi 11:00 - 13:10 2.17 CASE P RUNPRD RIH with liner to 9000. Up Wt 28K. Circulate at min rate .4 bpm .Continue to RIH. Set down at 10539. Pop thru .Set down at 10763.PU to 10748. Set down at 10776. 10804, PU 38K to 10790. RIH to 10835- twice, 10850, 10839, 10878, pu 10838, PU to 10780, RIH ste do at 10867,Pump .PU 4 bpm , Rlh min rate tag at 10857, 10860, 10871, 10878, 10874 . Circulate .45 bpm ~ 1530` psi. 10941, Circulate at .5 bpm ~ 1549 psi, Ta~~ TD 1 13:10 - 14:00 0.83 CASE P RUNPRD Load 5/8 al ball and launch. Circualte ball to seat. On seat at 32.2 bbls. Shear at 4100 psi.. PU off liner. 14:00 - 15:30 1.50 CASE P RUNPRD Wait on KCL trucks. 15:30 - 18:00 2.50 CASE P RUNPRD Swap well to KCL.Attempt 2 /1.5 bpm. Slow rate to 1.26./ 1.02 bpm. Slow to .96/.8 20% loss. IA 34,OA 146. 18:00 - 19:30 1.50 CASE P RUNPRD Continue to circulate, 1.36/1.12 BPM. 19:30 - 20:00 0.50 CEMT P RUNPRD PJSM for liner cement job 20:00 - 21:00 1.00 CEMT P RUNPRD Batch u cement 20:42 , Ian to um 13.5 Bbls. PT hard line to inner reel valve to 6000 psi 21:00 - 22:10 1.17 CEMT P RUNPRD Pump cement, Zero MM at 14.5 ppg, 15.8 at .4 bbls away In MM Out MM CT Pres. Rate in/out 3 2.6 2300 1.51/1.25 6 5.0 2600 1.42/1.22 9 7.7 2760 1.35/1.15 12 10.2 2710 1.14/1.06 13.1 11.4 out of cement, launch dart, chase with bio 15 12.6 3150 1.27/1.10 20 17.0 3220 1.27/1.10 25 21.4 2550 1.20/1.04 30 25.6 1740 1.20/1.04 F'flflt0tl: 5/15/LUUG `J:L'C:CL HM • • BP EXPLORATION Page 8 of 9 Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Spud Date: 6/5/1978 Event Name: REENTER+COMPLETE Start: 3/26/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 4/26/2008 Rig Name: NORDIC 1 Rig Number: Date From - To ,Hours Task Code NPT Phase Description of Operations 4/23/2008 21:00 - 22:10 1.17 CEMT P RUNPRD 35 29.8 1530 1.36/1.18 40 34.2 1575 1.36/1.18 45 38.7 1680 1.36/1.18 50 42.9 1660 1.37/1.18 53.4 45.8 2500 1.38/1.18 Cement at shoe 55.3 47.4 2560 1.38/1.18 PU liner wiper, calc 54.9 sheared at 3800 si 60 51.4 3051 1.20/1.11 67.0 57.0 3750 0.70/0.47 Plug landed, calc 2.4 Bbls cement lost to formation 22:10 - 00:00 1.83 CEMT P RUNPRD Check floats, no flow. POOH filling displacement. 4/24/2008 00:00 - 00:30 0.50 CEMT P RUNPRD Lay down CTLRT 00:30 - 01:00 0.50 EVAL P LOWERI MU 3.74" parabollic mill on 2 7/8" motor for 4 1/2" tubing clean out run 01:00 - 03:00 2.00 EVAL P LOWERI RIH, at 7000' increase pump rate to 2.25 BPM, tag deployment sleeve at 7988 CTMD Clean run with no tags or motor work 03:00 - 04:30 1.50 EVAL P LOWERI POOH pumping at 2.25 BPM, light cement in returns at bottoms up. 04:30 - 04:50 0.33 EVAL P LOWERI Lay down clean out BHA. 04:50 - 07:30 2.67 EVAL P LOWERI MU 1.875" mill, 1- 11/16" motor and MHA. 52 Stands 1"CSH. 07:30 - 07:50 0.33 EVAL P LOWERI PU & stab injector. 07:50 - 10:17 2.45 EVAL P LOWERI RIH to 10986 clean trip.. 10:17 - 12:30 2.22 EVAL P LOWERI POH to CSH. 12:30 - 15:00 2.50 EVAL P LOWERI Drop .5" ball. Open circulation sub. Stand back 1" CSH. 15:00 - 15:50 0.83 BOPSU P LOWERI Function test BOPE. 15:50 - 16:00 0.17 EVAL P LOWERi SAFETY MEETING covering hazards, procedures, and mitigations for picking up radioactive source and logging BHA 16:00 - 18:00 2.00 EVAL P LOWERI Pick up MCNL and 52 stands of CSH. 18:00 - 19:50 1.83 EVAL P LOWERI PU injector and RIH Start pert pill down coil. 20 Bbls flow pro. 19:50 - 21:00 1.17 EVAL P LOW ER1 Start logging down from 8700' at 30 FPM Ta PBTD at 1 21:00 - 21:40 0.67 EVAL P LOWERI Log up from 10984' at 60 fpm, laying in pert pill 21:40 - 23:00 1.33 EVAL P LOW ER1 8700', POOH 23:00 - 00:00 1.00 EVAL P LOWERI Stand back 52 Stds. 1"CSH 4/25/2008 00:00 - 02:00 2.00 EVAL P LOWERI Stand back CSH, Lay down logging string. PBTD per log 10979. 02:00 - 03:00 1.00 EVAL P LOWERI Test liner la assed 02:15 - 1970 psi 02:30 - 1920 psi 02:45 - 1904psi PJSM for PU perf guns 03:00 - 05:15 2.25 PERFO P LOWERI PU 52 pert guns 05:15 - 06:30 1.25 PERFO P LOWERI Run 32 stands 1"CSH 06:30 - 07:00 0.50 PERFO P LOW ER1 MU injector 07:00 - 08:40 1.67 PERFO P LOWERI T to and correct to' 10979 08:40 - 10:00 1.33 PERFO P LOWERI Circulate In 10 bbl pill launch ball and displace with 10 bbl and KCL. Back on depth with bottom shot 10960.7'. Circulate a 1.3 bpm ~ 4100 psi. After 37of 41 bbls reduce rate to .7 bpm. 38.8 bls on seat. Fired at 4700 psi. No indication of shot fired on surface monitor. Pflntetl: 5/75/Z008 9:'LG'"l"L AM • BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Well Name: 07-01 Common Well Name: 07-01 Spud Date: 6/5/1978 Event Name: REENTER+COMPLETE Start: 3/26/2008 End: Contractor Name: NORDIC CALISTA Rig Release: 4/26/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/25/2008 08:40 - 10:00 1.33 PERFO P LOWERI Per intervals 1-11/16 guns 6SPF. 9,870' - 10,000' 10,050 - 10,430' 10,640' - 10,690' 10:00 - 10:15 0.25 PERFO P LOWERI PU to 9800..Pump down back side to confirm perfs open . Pressure to 1300 si. bleed off to 800 i in 1 mi 10:15 - 11:45 1.50 PERFO P LOWERi POH..57 / .22 at 80 ft/min loss rate .1 bpm. 11:45 - 12:00 0.25 PERFO P LOWERI PJSM for standing back CSH. 12:00 - 13:45 1.75 PERFO P LOWERI Stand back 32 stands of CSH. 13:45 - 14:00 0.25 PERFO P LOWERI PJSM LD perforating guns. 14:00 - 16:30 2.50 PERFO P LOWERI LD spent and blanc guns. 16:30 - 17:00 0.50 PERFO P LOWERI LD perf tools and clean floor. 17:00 - 17:15 0.25 WHSUR P POST MU nozzel and RIH to 2500'. 17:15 - 17:45 0.50 WHSUR P POST RIH to 2500'. 17:45 - 19:00 1.25 WHSUR P POST Wait on LRS to pump diesel FP 19:00 - 20:00 1.00 WHSUR P POST Pump 40 bbls. diesel and lay in while POOH 20:00 - 22:00 2.00 WHSUR P POST Install BPV in tree 22:00 - 00:00 2.00 WHSUR P POST Pump fresh water and corrosion inhibitor. RU nitrogen and blow down reel. 4/26/2008 00:00 - 06:00 6.00 RIGD P POST Drop stuffing box and convert to 2 3/8", tail coil back to reel, change out BOP rams. Swap reels. Change out gripper blocks in injector. Clean pits. 06:00 - 10:00 4.00 RIGD P POST Pull CT across .had to rethread CT thru pipe straightener. Simultaneously repairing drive motor. 10:00 - 12:00 2.00 RIGD P POST ND BOP. NU tree cap and test same to 4100 psi. Release Rig _ at 12:00 hrs 4-26-2009. Tree greased with Clare 501 prior to release. 12:00 - 16:00 4.00 RIGD P POST Investigate drivemotor leak. Determined lacking parts will proceed on three drive motors. Pflrlt2tl: 5/15/2UU8 y:L"L:"LZ AM i -, by BP Alaska s Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 4!23/2008. Time: 11:19:51 Pare: 1 Field!: Prudhoe 88y Co-®rdhtate(NE) Reference: Well: 07-01, True North Site: PB DS 07 Vet11ea1(TVD) Pteter'eaca 1:01 6!5/1978 00:00 64.0 Weli: 07-01 ` Section (VS) Reference: Wetl (O.OON,O.OOE,161.23Azi) Welipathd 07-018 Survey Calculation Metbod: Minimum Curyalure Db: OraGe Field: Prudhoe Bay - North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well CenVe Sys Datum: Mean Sea Level Geomagoetk Model: bggm2007 Site: PB DS 07 TR-11-14 UNITED STATES :North Slope Site Positron: Northing: 5948144.78 ft Latitude: 70 15 49.847 N From: Map Easting: 677382.28 ft LoagNude: 148 33 56.934 W Positioe Uncertainty: 0.00 ft North Refereece: True Grouml Level: 0.00 ft Grid Convergence: 1.35 deg Well: 07-01 Slot Name: 01 07-01 Well Position: +N/-S 770.21 ft Northing: 5948887.99 ft Latitude: 70 15 57.421 N +E/-W -1134.84 ft Easting : 676229.68 ft Longitude: 148 34 29.3 W Position Uneertainty: 0.00 ft Wetipath: 07-01 B Drilled From: 07-01 500292027202 T~-on Depth: 9200.00 ft Current Datum: 1:01 6/5/1978 00:00 Height 64.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/8/2008 DecHnatioo: 23.43 deg Field Strength: 57669 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Directioa ft ft ft deg 37.00 0.00 0.00 161.23 Survey Program Por Definitive Wellpath Date: 2/8/2008 Validated: Yes Version: 4 Actual From To Survey Tooleode Tool Name ft ft 100.00 9200.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 9201.00 11026.00 MWD (9201.00-11026.00) MWD MWD -Standard Annotation MD TVD ft ft 9200.00 8657.77 TIP 9201.00 8658.61 KOP 11026.00 9018.72 TD Survey: MWD Start Date: 4/21/2008 Company: Baker Hughes INTEQ Engiocer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Iael Azim TVD Sys TVD N/S E/W MapN MapE VS I)LS Taal ft ~ deg tt ft ft ft ft ft ft dttg/1OOft 9200.00 32.50 184.00 8657.77 8593.77 -1611.20 1035.18 5947301.57 677302.23 1858.59 0.00 MWD 9201.00 32.28 184.12 8658.61 8594.61 -1611.73 1035.15 5947301.04 677302.20 1859.09 22.92 MWD 9237.17 24.53 189.87 8690.41 8626.41 -1628.79 1033.16 5947283.94 677300.62 1874.60 22.70 MWD 9273.23 16.51 200.68 8724.17 8660.17 -1640.98 1030.06 5947271.67 677297.81 1885.15 24.51 MWD 9304.99 13.97 217.58 8754.82 8690.82 -1648.25 1028.13 5947264.32 677294.04 1890.76 16.03 MWD 9332.35 17.22 228.00 8781.18 8717.18 -1653.58 1021.10 5947258.87 677289.14 1894.19 15.64 MWD 9362.53 22.63 258.66 8809.62 8745.62 -1657.72 1012.06 5947254.52 677280.20 1895.20 38.39 MWD 9391.39 25.04 247.16 8836.03 8772.03 -1661.19 1000.98 5947250.80 677289.20 1894.92 18.10 MWD 9420.51 28.11 233.67 8862.09 8798.09 -1687.65 989.76 5947244.07 677258.14 1897.43 23.19 MWD 9451.07 31.02 219.86 8888.70 8824.70 -1677.97 978.90 5947233.50 677247.52 1903.71 24.18 MWD 9482.03 34.29 206.04 8914.80 8850.80 -1691.96 969.94 5947219.31 677238.90 1914.07 26.24 MWD by BP Alaska ~ Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Ffeld: Prudhoe Bay Date: 4/23/2008 Time: 11:19:51 Co-ard~ate(NE}Refereece: Well: 07-01, True North Page: Z SNe: PB DS 07 Vertleai (TVD) Retereoce: 1:01 6/5/197 8 00:00 64.0 .:.Well: 07-01 Sectier(YS}Retereace: Well (O.OON,O .OOE,161.23Azi) Wellpatb: 07-01 B Sarvey CakaMtieo Method: Minimum Curvature Db: OraGe Snrvey MD' Iacl Azim TVD Sys TVD N/S EIVi' MapN MapE VS DLS Tool ft deg -deg ft ft ft ft ft ft ft deg1100ft 9511.79 37.25 193.81 8938.97 8874.97 -1708.26 964.10 5947202.87 677233.44 1927.63 25.85 MWD 9541.85 40.20 183.32 8962.45 8898.45 -1726.80 961.37 5947184.27 677231.14 1944.30 23.91 MWD 9572.53 45.79 183.26 8984.88 8920.88 -1747.68 960.17 5947163.37 677230.43 1963.69 18.22 MWD 9604.04 52.73 183.17 9005.43 8941.43 -1771.51 958.83 5947139.53 677229.65 1985.81 22.03 MWD 9634.80 59.25 188.12 9022.63 8958.63 -1796.85 956.28 5947114.13 677227.70 2008.99 25.03 MWD 9665.18 68.43 185.21 9036.02 8972.02 -1823.90 953.15 5947087.01 677225.20 2033.59 31.41 MWD 9695.66 77.29 181.29 9044.99 8980.99 -1852.95 951.52 5947057.94 677224.25 2060.57 31.55 MWD 9728.60 81.28 166.54 9051.15 8987.15 -1885.03 954.97 5947025.95 677228.45 2092.05 45.62 MWD 9761.54 86.53 167.43 9054.65 8990.65 -1916.93 962.34 5946994.24 677236.57 2124.63 16.16 MWD 9795.80 93.71 169.21 9054.57 8990.57 -1950.46 969.27 5946960.88 677244.28 2158.61 21.59 MWD 9825.35 97.66 159.67 9051.64 8987.64 -1978.75 977.14 5946932.79 677252.81 2187.92 34.79 MWD 9857.00 95.80 158.35 9047.93 8983.93 -2008.09 988.40 5946903.72 677264.75 2219.33 7.19 MWD 9888.52 93.26 160.07 9045.44 8981.44 -2037.46 999.55 5946874.61 677276.58 2250.73 9.72 MWD 9915.98 91.81 163.53 9044.23 8980.23 -2063.52 1008.12 5946848.77 677285.76 2278.15 13.65 MWD 9947.34 89.94 166.52 9043.75 8979.75 -2093.81 1016.22 5946818.68 677294.57 2309.44 11.24 MWD 9976.02 90.18 169.99 9043.72 8979.72 -2121.88 1022.06 5946790.75 677301.06 2337.90 12.13 MWD 10012.62 90.15 173.99 9043.61 8979.61 -2158.12 1027.15 5946754.65 677307.00 2373.85 10.93 MWD 10042.34 91.44 173.89 9043.20 8979.20 -2187.67 1030.29 5946725.18 677310.83 2402.84 4.35 MWD 10072.88 92.03 175.35 9042.28 8978.28 -2218.06 1033.15 5946694.87 677314.40 2432.53 5.15 MWD 10102.78 93.01 178.76 9040.96 8976.96 -2247.88 1034.69 5946665.09 677316.64 2461.26 11.86 MWD 10132.78 93.02 181.56 9039.38 8975.38 -2277.84 1034.61 5946635.14 677317.25 2489.60 9.32 MWD 10162.48 91.38 183.75 9038.24 8974.24 -2307.48 1033.23 5946605.47 677316.57 2517.23 9.21 MWD 10195.74 89.29 184.44 9038.05 8974.05 -2340.66 1030.86 5946572.26 677314.98 2547.87 6.62 MWD 10226.66 87.72 186.31 9038.85 8974.85 -2371.43 1027.96 5946541.43 677312.80 2576.07 7.90 MWD 10255.34 88.65 188.09 9039.76 8975.76 -2399.87 1024.37 5946512.92 677309.88 2601.84 7.00 MWD 10289.28 89.51 192.27 9040.31 8976.31 -2433.26 1018.37 5946479.39 677304.66 2631.53 12.57 MWD 10320.76 88.71 194.64 9040.80 8976.80 -2463.87 1011.05 5946448.62 677298.06 2658.16 7.95 MWD 10351.91 89.20 198.55 9041.37 8977.37 -2493.71 1002.15 5946418.58 677289.87 2683.55 12.65 MWD 10383.61 89.54 202.24 9041.71 8977.71 -2523.42 991.11 5946388.63 677279.52 2708.12 11.69 MWD 10413.94 90.68 202.14 9041.66 8977.66 -2551.50 979.65 5946360.29 677268.73 2731.03 3.77 MWD 10450.75 96.43 199.17 9039.37 8975.37 -2585.86 986.70 5946325.64 677256.58 2759.39 17.57 MWD 10484.61 98.75 196.27 9034.90 8970.90 -2617.82 956.48 5946293.44 677247.12 2786.37 10.91 MWD 10514.11 100.30 192.93 9030.02 8966.02 -2645.97 949.15 5946265.13 677240.44 2810.66 12.34 MWD 10543.17 101.20 190.18 9024.60 8960.60 -2673.94 943.43 5946237.04 677235.38 2835.30 9.80 MWD 10576.27 100.55 185.75 9018.35 8954.35 -2706.12 938.93 5946204.76 677231.63 2864.32 13.29 MWD 10608.78 99.02 183.88 9012.82 8948.82 -2738.04 936.24 5946172.79 677229.70 2893.68 7.37 MWD 10634.29 95.22 182.75 9009.66 8945.66 -2763.31 934.78 5946147.50 677228.82 2917.13 15.53 MWD 10672.54 93.01 179.26 9006.92 8942.92 -2801.45 934.11 5946109.36 677229.05 2953.03 10.78 MWD 10702.16 91.66 176.23 9005.71 8941.71 -2831.01 935.28 5946079.83 677230.91 2981.40 11.19 MWD 10737.16 89.48 172.60 9005.36 8941.36 -2865.84 938.68 5946045.09 677235.13 3015.47 12.10 " MWD 10770.60 87.73 168.03 9006.18 8942.18 -2898.78 944.30 5946012.29 677241.52 3048.47 14.63 MWD 10806.68 86.72 164.82 9007.92 8943.92 -2933.81 952.76 5845977.48 677250.79 3084.35 9.32 MWD 10838.08 88.90 160.71 9009.67 8945.67 -2963.75 982.05 5945947.77 677260.78 3115.69 13.08 MWD 10879.14 88.56 158.03 9011.30 8947.30 -3002.14 976.50 5945909.73 677276.12 3158.69 7.67 MWD 10919.43 86.20 151.44 9013.14 8949.14 -3038.51 993.67 5945873.76 677294.14 3196.65 17.36 MWD 10951.13 87.73 143.73 9014.82 8950.82 -3065.22 1010.62 5945847.47 677311.71 3227.39 24.76 MWD 10979.52 86.56 139.77 9016.24 8952.24 -3087.48 1028.17 5945825.62 677329.78 3254.12 14.53 MWD 10995.75 87.02 134.98 9017.15 8953.15 -3099.40 1039.14 5845813.97 677341.02 3268.93 29.60 MWD 11026.00 87.02 134.98 9018.72 8954.72 -3120.75 1060.51 5945793.12 677382.88 3296.02 0.00 MWD TREJ=~e FMC5-1/8x7-1/16 WELLHEAD = GRAY ACTUATOR = BAKER "C" KB. ELEV = 64' BF. ELEV = ? KOP = 4900' Max Angle = 101° @ 10543' Datum MD = 9423' Datum ND = 8800' SS DRLG DRAFT 9-5/8" Foc 2335' 9-5/8" Foc 2451' 13-3/8" CSG, 72#, N-80 BUTT, ID = 12.347" Minimum ID = 2.375" @ 10005' TOP 2-7/8" TBG TOP OF 2-3; 8" LNR 7981' TOP OF CEMENT 79$1' 4-1/2" TBG, 11.6#, 13-CR VAM TOP, .0152 bpf, ID = 3.958" TUBING STUB 5-112" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~~ $'144' TOP OF3-1/2" LNR 8138' elm 4-1/2" TBG, 12.6#, N-80, .0152 bpf, ID = 3.958" 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" TOP OF 7" LNR 9-5/8" CSG, 47#, N-80/ S-95 BTC, ID = 8.681" TOP OF CEMEM PERFORATION SUMMARY REF LOG: BHCS ON 07/04/78 ANGLE AT TOP PERF: 95° @ 9870' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" 6 9870 - 10000 O 04/25/08 1-11116" 6 10050 - 10430 O 04/25/08 1-11(16" 6 10640 - 10960 O 04/25/08 07-01 B 7" LNR, 29#, N-80 BUTT, .0371 bpf, ID = 6.184" I 9875' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.8" 2-7/8" LNR, 6.4#, L-80, .0058 bpf, ID = 2.441" NOTES: ***CHROMETBG**" 5-1/2" X 4-1/2" XO,ID = 3.958" 4-112" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3243 3243 1 MMG DMY RK 0 07/10!07 3 5507 5481 22 MMG DMY RK 0 07/10/07 2 6678 6493 30 MMG DMY RK 0 02/02/06 1 7808 7510 25 MMG DMY RK 0 OZ/02/06 7$$7' 4-1/2" HES X NIP, ID= 3.813" 7917' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.870" 7950' 4-1/2" HES X NIP, ID = 3.813" 8020' 4-1/2" XN NIP, ID = 3.725" 8041' 4-112" X 5-1 /2" XO, ID = 3.958" 8047' S-1 /2" CAMCO DB-6 NIP, ID = 4.562" 8052' 9-5/8" X 5-1/2" UNIQUEOVERSHOT 8083' 5-1/2" BKR SBR ASSY, ID = ? 8132' 9-5/8" X 5-1/2" BKR SAB PKR, ID = ? 8138' 7" MILLOUT EXTENSION, ID = ? 8144' 6-5/8" X 4-1/2" XO, ID = 3.958" 8188' 3-1/2" BKR DEPLOY SLV, ID = 3.000" 8199' 4-1/2" CAMCO DB-6 NIP, ID= 3.813" ${ 256' I--~4-1/2" TUBING TAIL, ID = 3.958" 8228' ELMD TT LOGGED 07/29/89 8287' 3-1/2" X 3-3/16" XO, ID = 2.79" 8337' 9-5/8" X 7" BOT TIEBK SLV w /LNR HGR, ID = ? 2-318" Chrome crtt'ed and perfed I-j 11025' IMech Packer WSw R/A tags/ 7" MILLOUT WINDOW (07-01A) 9423' - 9429' 9942' ~ DAMAGED LNR (REF: MILLING OPER 08/04/07) 9943' FISH- 2-1 /2" CIBP DEBRIS (08/04/07) 10005' 3-3/16" X 2-7/8" XO, ID = 2.375" 11816' PBTD, MILLED OUT 08/19/98 DATE REV BY COMMENTS DATE REV BY COMMENTS 07178 ROWAN 35 ORIGINAL COMPLETION 01115/98 N4/3S SIDETRACK (07-01A) 02/07/06 DOYON 16 RWO 04/26!08 NORDICI CTD SIDETRACK 05/05/08 JO/TLH TREE GO PRUDHOE BAY UNfr WELL: 07-01 B PERMff No: 2080380 API No: 50-029-20272-02 SEC 34, T11 N, R14E, 7' FWL & 2037' FNL BP F~cploration (Alaska) 06/04/08 ~~ ~~ill~~~~~i~~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh 3k N0.4736 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ .... no s:.. L-220 11975963 CH EDIT PDC GR (USIT) 04/22/08 1 L-221 11962592 CH EDIT PDC GR (USIT) 04/07/08 1 V-223 40016679 OH MWD/LWD EDIT ~ 03/20/08 2 1 W-30 12034892 RST ~y -( (f 04/11/08 1 1 G-11B 11963085 MCNL Dip-0 / 04/01/08 1 1 05-28B 11649987 MCNL (o- 08/17/07 1 1 P2-36A 11209594 MCNL - 03/26/06 1 1 07-016 12021155 MCNL `)j~ 04/28/08 1 1 OS-34 11966251 CH EDIT PDC GR (USIT) 04/13/08 1 17-12 12057613 PRODUCTION PROFILE - (~ 05/23/08 1 1 W-31 11999015 LDL - 05/25/08 1 1 GNI-02A 12057618 PRESS/TEMP SURVEY (o - 3 ~ 05/24/08 1 1 13-12 11982434 USIT _ [. ~~- 05/29/08 1 1 --..__ .......... .. __....~ ..~.. ~.. . .... v.w.n... '.nv ~~~ ~ vnwnvaa vrvc wr ~ cfiVn ~ v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 i; ;~ { Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503- 83 ATTN: Beth Received by: ALA-SFiA OIL A11TD GA5 COrITSERVATIOI~T COrII~II55IO1~T Mel Rixse CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PALW, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-O1B BP Exploration Alaska, Inc. Permit No: 208-038 Surface Location: 2036' FNL, 7' FWL, SEC. 34, T11N, R14E, UM Bottomhole Location: 180' FNL, 1204' FWL, SEC. 03, T10N, R14E, UM Dear Mr. Rixse: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely Daniel T. Seamount, Jr. Chair DATED this2~ day of March, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ,~/.~ ~' - -- ALAS~IL AND GAS CONSERVATION COMM N MAR 0 5 2008 PERMIT TO DRILL ~/~ 4~ 20 AAC 25.005 ~ Qj) $ G1S COns. Canmission 1 a. Type of work ^ Drill ~ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well ~ for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 07-01 B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD _ 11350 TVD 8975ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' ' 7. Property Designation: ~ ADL 028312 Pool FWL, SEC. 34, T11N, R14E, UM FNL; 7 2036 Top of Productive Horizon: T11 N, R14E, UM 1012' FWL SEC. 34 3804' FNL 8. Land Use Permit: 13. Approximate Spud Date: - May 1, 2008 , , , Total Depth: 180' FNL, 1204' FWL, SEC. 03, T10N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 38,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-676230 y- 5948888 Zone-ASP4 10. KB Elevation (Height above GL): ` 64' feet 15. Distance to Nearest Well Within Pool: 1292' 16. Deviated Wells: Kickoff Depth: ~ 9200 feet Maximum Hole An le: - 99 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole:3261 Surface: ~ 2381 18. Casin Pro ram: eCificatio ns To -` ettin -Bo ttom uanti of ment c.f. or ack Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.7# 13Cr STL 3375' 7975' 7595'ss 11350' 8975'ss 67 sx Class 'G' j g. PRESE NT WELLCONDITiON SUMMARY (To be completed for Redrili and Re-entry Operations) Total Depth MD (ft): 11823 Total Depth TVD (ft): 8992 Plugs (measured): None Effective Depth MD (ft): 11816 Effective Depth TVD (ft): 8994 Junk (measured): 9943 :Casin Length ize -Cement Volume MD TVD Conductor /Structural 110' 20" 300 sx Arcticset 110' 110' Surface 2714' 13-3/8" 5300 sx Arcticset II 2714' 2714' Intermediate 8670' 9-518" 100 sx Class'G' 8670' 8228' Production Liner 1085' 7" 525 sx Class'G' 8337' - 9422' 7963' - 8846' Liner 3635' 3-1 /2" x 2-7/8" 102 sx Class 'G' 8188' - 11823' 7841' - 8992' Perforation Depth MD (ft): 9610' - 11798' Perforation Depth TVD (ft): 8979' - 9000' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mel Rixse, 564-5620 Printed Name Mel Rixs Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 564-5620 Date®Y- -~ Terrie Hubble, 564-4628 Commission Use.Onl Permit To Drill Number: O D,~~ API Number: 50-029-20272-02-00 Permit r YY~~I See cover letter for Date: d~~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed meth ne, gas hydrates, or gas contained shales: ~_,/~ Samples Req'd: Yes ~No Mud Log Req'd: ^ es Ld No ~y ~ \ HZS Measures: Yes ^ No Directional Survey Req'd: LrJ Yes ^ No Other: ~S ~l1 PS\ `.~~ ~~5~ 3 / 7 / ~ APPROVED BY THE COMMISSION ~b Dat ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ ~ I n~ A ~f~~~_ _ / Submit In Duplicate • DS 07-01 B -Coiled Tubing ling To: Tom Maunder Petroleum Engineer ~p Alaska Oil & Gas Conservation Commission 1~,J From: Mel Rixse CTD Engineer Date: March 3, 2008 Re: 07-01 B Application for Permit to Drill Request CTD Drill and Complete 07-01B program: Spud in Mav 1, 2008 Pre-Rig Work: 1. O Functions test LDS 2. O PT Master & Swab valve to 4000 psi. Drawdown test MV, SV, & SSSV to 0 psi 3. S Drift to 9360'MD for Baker cement retainer & Baker WS set in 3-3/16" liner @ 9206'MD. 4. E Set Baker Cement Retainer at ~ 9332'MD 5. C Stab into retainer, shut in well, test for injectivity, if injectivity is high, squeeze flo-pro to provide reduced injectivity. 6. C Down squeeze generous amount -- 20 bbls of 15.8#/gal cement through retainer until lock up 7. C Unsting from cement retainer, lay in 1 bbl cement above retainer, cleanout to 9280' MD w/ 2 ppb Biozan. 8. O Wait for 2500 psi UCA on cement, MIT - T 9. E Drift for whipstock. 10.E Set Whipstock (TOWS 9206' MD). 11. S With slickline pump bailer, lay in ~1 bbl 15.8#/gal cement above whipstock, TOC no greater than 9186' MD. 12. O Set BPV. 13. O Bleed production flow lines and GL lines down to zero and blind flange. 14. O Remove wellhouse, level pad. Rig Sidetrack Operations: (Scheduled to begin on May 1, 2008) 1. NU 7-1/16" CT Drilling ROPE and test to 250 psi low and 3500 psi high 2. Pull BPV. 3. Mill 2.74" window at 9,206'. Swap well to Flo-Pro. 4. Drill build/turn section with 3" bicenter bit, and land well. 5. Drill lateral section to 11,350' MD. 6. Run 2-3/8" to TD. Place liner top at 7975' MD 7. Pump 1-2-3/8" liner annular volume of 15.8 ppg cement. 8. cleanout liner. 9. Run MCNUGR/CCL log 10. Test liner lap to 2000 psi 11. Perforate per geologist. 12. FP well to 2000' with diesel. 13. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 14. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design RU test separator, flow test well. Page 1 of 2 March 4, 2008 • DS 07-01 B -Coiled Tubing D~'llling Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. 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: 3" Casing Program: • 2 3/8", 4.7# , 13Cr, STL connection Solid liner - 7975'MD - 11,350' MD. • A minimum of 12 bbls 15.8 ppg cement will be used for liner cementing. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 99.3 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 38,500' (North) • 07-22 - 1292' ctr-ctr Anticollision Summary • 07-22 - 1292' ctr-ctr, Status: Producing Zone 1 A • 07-20A 1400' ft ctr-ctr, Status: Cycle producer Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCUCNL log will be run. Hazards • The maximum recorded H2S level on DS 7 is 150 ppm on 07-13A (7-21-1993). DS 7 is not an H2S pad; levels are generally < 30 ppm • Lost circulation risk is low. No fault crossings are expected. Reservoir Pressure • Res. press. is estimated to be 3,261 psi at 8,800'ss (7.1 ppg EMW). Max' um surface pressure with gas (0.10 psi/ft) to surface is 2381 psi. Mel Rixse CTD Drilling Engineer Page 2 of 2 .March 4, 2008 LHEAD = ~ GRAY CTLWTOR= AXELSON . ELEV = 64' F. ELEV = ? OP = 4900' Angle = J9 ~ 11763' tum Alq = 9445' tum TV D = 8800' SS • 07-01A 9-5/8" FOC 2335' 9-5/8" FOC 2461' 113-3/8" CSG, 72#, N-80 BUTT, ID = 12.347" I Minimum ID = 2.375" ~ 10005' TOP 2-718" TBG 41/2" TBG, 11.6#, 13-CR VAM TOP, .0152 bpi, ID = 3.958" TUBING STUB 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" TOP OF 3-112" LNR I 8144' i SAFETY NOTES: "*"CHROME TBG" 22' S-112" X 41/2" XO, ID = 3.958" 2205' 4-1 /2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DATE 4 3243 3243 1 MMG DMY RK 0 07/10/07 3 5507 5481 22 MMG DMY RK 0 07/10/07 2 6678 6493 30 MMG DMY RK 0 02/02/06 1 7808 7510 25 AIMC DMY RK 0 02/02/06 7887' 41/2" HES X NIP, ID = 3.813" 7917' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.870" 7950' 41/2" HES X NIP, ID = 3.813" 8020' 4-1 /2" XN NIP, ID = 3.725" 8041' 4-1/2" X 5-112" XO, ID = 3.958" $047' 5-1/2" CAMCO DB-6 NIP, ID = 4.562" 8052' 9-5/8" X 5-1 /2" UNgUE OVERSHOT 8083' 5-1 /2" BKR S BR ASSY, ID = ? 8132' 9-5/8" X5-1/2" BKR SAB PKR, ID = ? 8138' T' MILLOUT EXTENSION, ID = ? 8144' 6-5/8" X 41/2" XO, ID = 3.958" 8188' 3-1/2" BKR DEPLOY SLV, ID = 3.000" 8199' 4-112" CAMCO DB-6 NIP, ID = 3.813" 41 /2" TBG, 12.6#, N-80, .0152 bpf, ID = 3.958" 8756' J 8256' 4-1/2" TUBING TAIL, ID = 3.958" 992" 8287' / " T # L 8 0087 b f ID = 2 ' ELMD TT LOGGED 07/29/89 , - p , . 3-1 2 BG, 9.2 0, . 8228 TOP OF T' LNR 8337' $2$7' 3-112" X 3-3/18" XO, ID = 2.79" 8337' 9-5/8" X T' BOT TIEBK SLV w /LNR HGR, ID = ? ~ 9-5/8" CSG, 47#, N-80/ S-95 BTC, ID = 8.681" ~ PERFORATION SUMMARY REF LOG: BRCS ON 07/04/78 ANGLEATTOP PERF: 55 ~ 9810' Note: Refer to Productron DB for h~torical pert data SQE SPF INTERVAL OpNSgz DATE 2" 6 9610 -9630 O 07/04/08 1-11/15' 4 10270-10500 O 01/10/98 7' 4 10550 -10800 O 12/12/00 2" 4 11000 - 11200 O 12/12/00 1-11/15' 4 11280 - 11651 O 01/10!98 2-1/8' 4 11760-11798 O 08/24/98 = 6.184" T' MILLOUT WINDOW (07-01A) 9423' -9429' 8942' DAMAGED LNR (REF: MILLING OPER 08/041 9843' FISH- 2-112" CIBP DEBRIS (08/04/07) 10005' 3-3/16" X 2-7/8" XO, ID = 2.375" 3-3118" LNR, 8.2#, L-80, .0078 bpf, ID = 2.8" 10005 11816' PBTD, MILLED OUT OS/19/98 2-718" LNR, 6.4#, L-80, .00.58 bpf, ID = 2.441" 11823' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/78 FaO1NAN 35 ORIgNAL COMPLETION 05/17/08 JGNYPJC RETRIEVE FISH ~ 811 T 01/15198 N4/3S SIDETRACK(07-01A) 07/04!06 RRDVPAG WEATHERFORDIBP, PERF 02/07/06 DOYON 18 RWO 02/28/07 OOB/TLH PBTD MILLED 8/1998 02/09/06 RWUPJC DRLG DRAFT CORRECTIONS 07/20/07 TEUPJC GLV GO (07110/07) 02/13/08 DTR/PAG GLV CJO (02/0810 08/04/07 DMSJPJC NtLL CIBP/ FISW DAMAGED LN 03/30/06 JLMrTLH VERBAL GLV CORRECTION PRUDHOE BAY UNff WELL: 07-01 A PERNAT No: 1971530 API No: 50-029-20272-01 SEC 34, T11 N, R14E, T FWL 8 203T FNL BP Exploration (Alaska) LHEAD = JATOR = 1EV = 1.EV = Ang~ _ mIVO= mTVn= GEN 2 GRAY ~ ~ SAFETY NOTES: """CHROME TBG"" 1sO~N P mposed C TD S iletrack 1763' 9-5/8" FOC 2335' 9445 9-5/8" FOC 2451' la ss 113-3/8" CSG, 72#, N-80 BUTT, ID = 12.347" 1 Minimum ID = 2.375" ~ 10005' TOP 2-7/8" TBG ITOP OF CEMENT 4-1/Z" TBG, 11.6#, 13-CR VAM TOP, .0152 bpf, ID = 3.958" 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~--~ 8144. TOP OF3-1/2" LNR 8138' elm ~ 4-1 /2" TBG, 12.6#, N-80, .0152 bpf, ID = 3.958" ~ ID = 2.992" ~-{ 828T ITOPOFT'LNR I-~ 9-5/A" GSr~ d7S N-AO/ S-95 RTC If] = A 6A1" I 8775' I PERFORATION SLINMARY R~ LOG: BHCS ON 07/0488 ANGLE AT TOP PFRF: 55 ~ 961 a Note: Refer to PFoduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 2" 6 9610 -9630 isolated proposed 1-11/15' 4 10270 - 10500 isolated proposed 2" 4 10550 - 10800 isolated proposed 2" 4 11000 - 11200 isolated proposed 1-11/15' 4 11280- 11651 isoaated proposed 2-1/8' 4 11760- 11798 isolated proposed T' LNR, 29#, N-80 BUTT, .0371 bpf, ID = 6.184" 9875' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.8" 2-7/8" LNR, 6.4#, L-80, .0058 bpf, ID = 2.441" 22' S-1/2" X 4-1/2" XO, ID = 3.958" 2205' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST AIO TVD DEV TYPE VLV LATCH PORT DATE 4 3243 3243 1 MMG DMY RK 0 07!10/07 3 5507 5481 22 MMG DMY RK 0 07/10/07 _ 2 6678 6493 30 NMG DNIY RK 0 02/02/06 1 7808 7510 25 NMG DNIY RK 0 02/02/06 7887' 4-1/2" HES X NIP, ID = 3.813" 7917' 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.87x' 7950' 4-1/2" HES X NIP, ID = 3.813" 8020' 4-1 /2" XN NIP, ID = 3.725" 8041' 4-1/2" X 5-1/2" XO, ID = 3.958" 8047' 5-1/2" CAMCO DB-6 NIP, ID = 4.562" 8052' 9-5/8" X 5-1/2" UNIQUE OVERSHOT 8083' 5-1/2" BKR SBR ASSY, ID = ? 8132' 9-5/8" X 5-1/2" BKR SA B PKR, ID = ? 8138' 7" MILLOUT EXTENSION, ID = ? 8144' 6-5/8" X 4-1 /2" XO, ID = 3.958" $188' 3-1/2" BKR DEPLOY SLV, ID=3.OOa' 8199' 4-1/2" CAMCO DB-6 NIP, ID = 3.813" 8256' 4-1/2" TUBING TAIL, ID = 3.958" 8228' ELMD TT LOGGED 07/29/89 8287' 3-1/2" X 3-3/15' XO, ID = 2.79" 8337' 9-5/8" X T' BOT TIEBK SLV w/LNR HGR, ID =? 2-3/8" Chrome cmt'ed and perfed 11350' 9206' Top of Whipstock _1 9332' Baker TT Cement Retainer T' MILLOUT WINDOW (07-01A) 9423' - 9429' 9942' ~ DAMAGED LNR (REF: MILLING OPER 08/04/07) 9943' FISH- 2-1/2" CIBP DEBRIS (08/04/07) 10005' 3-3/16" X 2-7/8" XO, ID = 2.375" 11816' PBTD, MILLED OUT 08/19/98 DATE REV BY COMMENTS DATE REV BY C,oMMENTS 07178 RDWAN 35 ORIGINAL COMPLETION 05/17/06 JGANPJC RETRIEVE FISH ~ 811T 01/15/98 N4/3S SIDETRACK (07-01A) 07/04/06 RRD/PAG WEATHERFORD IBP, PERF 02/07/08 DOYON 18 RWO 02/28/07 OOB/TLH PBTD MILLED 8/1998 02/09/06 RWL/PJC DRLG DRAFT CORRECTIONS 07/20/07 TEL/PJC GLV GO (07/10/07) 02/13/06 DTR/PAG GLV GO (02/08/06) 08/04/07 DMS/PJC MILL CIBP/ FISH/ DAMAGED LN i 03!30106, JLM/TLH !V~RBA~ GLV CORRECT ON l i PRUDHOE BAY UNIT WELL: 07-01 A PERNNT No: 1971530 API No: 50-029-20272-01 SEC 34, T11 N, R14E, T FWL & 203T FNL BP Exploration (Alaska) by ~ BP Alaska Baker Hughes INTEQ Planning Report ~~~ ~.. _ ~,,~ Company: BP Amoco Date: 2/8/2008 Time: 13:39:32 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 07-01, True North ~~ Site: PB DS 07 Vertical (TVD) Reference: 1:01 6/5/1978 00:00 64.0 Well: 07-01 Section(VS)Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: Plan ?; 07-016 Survey Calculation Method: Minimum Curvature Db: Sybase Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 07 TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5948144.78 ft Latitude: 70 15 49.847 N From: Map Easting: 677382.28 ft Longitude: 148 33 56.934 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.35 deg Well: 07-01 Slot Name: 01 07-01 Well Position: +N/-S 770.21 ft Northing: 5948887.99 ft Latitude: 70 15 57.421 N +E/-W -1134.84 ft Easting : 676229.68 ft Longitude: 148 34 29.963 W Position Uncertainty: 0.00 ft Wellpath: Plan 7, 07-01 B Drilled From: 07-01 500292027202 Tie-on Depth: 9200.00 ft Current Datum: 1:01 6/5/1978 00:00 Height 64.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/8/2008 Declination: 23.43 deg Field Strength: 57669 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.00 0.00 0.00 180.00 Plan: Plan #7 Date Composed: 2/8/2008 copy Lamar's plan 7 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets Name Description TVD +N!-S +E/-W Map Northing Map Easting.. <---- Latitude ----> Deg Min Sec <--- Longitude ---~ Deg Min Sec 07-01 B Polygon 64.00 -1816.58 768.06 5947090.00 677040.00 70 15 39.554 N 148 34 7.614 W -Polygon 1 64.00 -1816.58 .768.06 5947090.00 677040.00 70 15 39.554 N 148 34 7.614 W -Polygon 2 64.00 -3043.43 829.36 5945865.00 677130.00 70 15 27.488 N 148 34 5.834 W -Polygon 3 64.00 -3611.71 961.11 5945300.00 677275.00 70 15 21.899 N 148 34 2.004 W -Polygon 4 64.00 -3532.03 1403.12 5945390.00 677715.00 70 15 22.682 N 148 33 49.145 W -Polygon 5 64.00 -1987.17 1004.15 5946925.00 677280.00 70 15 37.876 N 148 34 0.745 W -Polygon 6 64.00 -1766.86 994.30 5947145.00 677265.00 70 15 40.043 N 148 34 1.031 W 07-01 B Fault 1 64.00 -1638.64 1072.33 5947275.00 677340.00 70 15 41.304 N 148 33 58.760 W -Polygon 1 64.00 -1638.64 1072.33 5947275.00 677340.00 70 15 41.304 N 148 33 58.760 W -Polygon 2 64.00 -1863.83 1077.06 5947050.00 677350.00 70 15 39.089 N 148 33 58.623 W 07-01 B Fault 2 64.00 -1889.76 1116.46 5947025.00 677390.00 70 15 38.834 N 148 33 57.477 W -Polygon 1 64.00 -1889.76 1116.46 5947025.00 677390.00 70 15 38.834 N 148 33 57.477 W -Polygon 2 64.00 -2387.94 1244.85 5946530.00 677530.00 70 15 33.934 N 148 33 53.743 W -Polygon 3 64.00 -3293.83 1483.72 5945630.00 677790.00 70 15 25.025 N 148 33 46.798 W 07-01 B Fault 3 64.00 -2264.26 662.55 5946640.00 676945.00 70 15 35.151 N 148 34 10.685 W -Polygon 1 64.00 -2264.26 662.55 5946640.00 676945.00 70 15 35.151 N 148 34 10.685 W -Polygon 2 64.00 -2998.88 635.34 5945905.00 676935.00 70 15 27.927 N 148 34 11.479 W 07-01 B Fault 4 64.00 -2658.31 1043.45 5946255.00 677335.00 70 15 31.276 N 148 33 59.604 W -Polygon 1 64.00 -2658.31 1043.45 5946255.00 677335.00 70 15 31.276 N 148 33 59.604 W -Polygon 2 64.00 -3090.91 1148.36 5945825.00 677450.00 70 15 27.021 N 148 33 56.554 W 07-01 B Fault 5 64.00 -3336.73 752.47 5945570.00 677060.00 70 15 24.604 N 148 34 8.072 W -Polygon 1 64.00 -3336.73 752.47 5945570.00 677060.00 70 15 24.604 N 148 34 8.072 W -Polygon 2 64.00 -3763.28 812.51 5945145.00 677130.00 70 15 20.409 N 148 34 6.327 W ~ BP Alaska by Baker Hughes INTEQ Planning Report iNTEQ Company: BP Amoco ~-- Date: 2/812008 Time: 13:39:32 Page: 2 Field: Prudhoe Bay Co-ordiaate(NE) Reference: W ell: 07-01, True North ~ Site: PB DS 07 VerticaY(TVD) Reference: 1 :01 6/5/1978 00:00 64.0 Well: 07-01 Section (VS) Reference: W ell (O.OON,O.OOE,180.OOAzi) Wellpath: Plan 7, 07-01 B Survey Calculation Method: M inimum Curvature Db: Sybase Targets Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip.. Dir. f1 ft ft ft ft 07-01 B Target 3 9024.00 -2441.13 953.50 5946470.00 677240.00 70 15 33.412 N 148 34 2.220 W 07-01 B Target 1 9039.00 -1890.66 941.38 5947020.00 677215.00 70 15 38.826 N 148 34 2.571 W 07-01 B Target 2 9039.00 -2261.17 957.72 5946650.00 677240.00 70 15 35.182 N 148 34 2.097 W 07-01 B Target 4 9039.00 -2951.85 976.56 5945960.00 677275.00 70 15 28.389 N 148 34 1.552 W 07-01 B Target 5 9039.00 -3421.39 1206.64 5945496.00 677516.00 70 15 23.770 N 148 33 54.860 W Annotation MD TVD - -__ I ft ft 9200.00 8657.77 TIP / KOP 9220.00 8674.80 End of 9 Deg/100' DLS 9280.00 8729.79 3 9380.00 8824.64 4 9506.00 8936.87 5 9731.37 9039.04 End of 25 Deg/100' DLS 9936.37 9039.04 7 10101.37 9039.04 8 10191.37 9031.71 9 10281.37 9024.35 10 10406.37 9026.78 11 10706.37 9037.89 12 10806.37 9039.50 13 11256.37 9039.46 14 11350.00 9039.46 TD Plan Section Information _ _ _ _. r-- MD Incl' Aiim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg. deg ft ft "ft deg/t00ft deg/100ft deg/100ft deg -- --- 9200.00 32.50 184.00 8657.77 -1611.20 1035.18 - 0.00 0.00 0.00 0.00 9220.00 30.70 184.00 8674.80 -1621.65 1034.45 9.00 -9.00 0.00 180.00 9280.00 15.70 184.00 8729.79 -1645.16 1032.81 25.00 -25.00 0.00 180.00 9380.00 25.31 255.86 8824.64 -1664.18 1010.79 25.00 9.61 71.86 106.00 9506.00 33.66 190.87 8936.87 -1706.11 977.24 25.00 6.63 -51.58 254.00 9731.37 90.00 190.87 9039.04 -1893.46 941.27 25.00 25.00 0.00 0.00 9936.37 90.00 166.27 9039.04 -2096.82 946.35 12.00 0.00 -12.00 270.00 10101.37 90.00 186.07 9039.04 -2260.64 957.33 12.00 0.00 12.00 90.00 10191.37 99.34 180.62 9031.71 -2350.05 952.07 12.00 10.38 -6.05 330.00 10281.37 90.05 175.08 9024.35 -2439.55 955.46 12.00 -10.32 -6.15 211.00 10406.37 87.73 160.26 9026.78 -2561.30 982.07 12.00 -1.86 -11.86 261.00 10706.37 88.16 196.28 9037.89 -2856.04 990.96 12.00 0.14 12.01 90.00 10806.37 90.01 184.42 9039.50 -2954.22 973.03 12.00 1.84 -11.86 278.70 11256.37 90.00 130.42 9039.46 -3354.52 1139.49 12.00 0.00 -12.00 270.00 11350.00 90.00 141.66 9039.46 -3421.81 1204.39 12.00 0.00 12.00 90.00 BP Alaska ~ ~- by Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco I Field: Prudhoe Bay ~~ Site: PB D& 07 Well: 07-01 Wellpath: Plan 7, 07-01.6 Survey -- MD Inch Azim ft deg deg. TVD ft S ft - Date: 2/8/2008 Co-ordiuate(NE) Reference: Vertical (TVD) Reference: Section (VS}Reference: Survey Calculation Method E/W MapN ft ft - --~ Time: 13:39:32 Fage: 3 Well: 07-01, True North 1:01 6/5/1978 00:00 64.0 Well (O.OON,O.OOE,1$O.OOAzi) _ Minimum Curvature Db: Sybase - - ---- MapE DLS VS TFO Too ft deg/100ft ft deg 9200.00 32.50 184.00 8593.77 -1611.20 1035.18 5947301.57 677302.23 0.00 1611.20 0.00 MWD 9220.00 30.70 184.00 8610.80 -1621.65 1034.45 5947291.10 677301.74 9.00 1621.65 180.00 MWD 9225.00 29.45 184.00 8615.13 -1624.15 1034.28 5947288.60 677301.63 25.00 1624.15 180.00 MWD 9250.00 23.20 184.00 8637.53 -1635.20 1033.51 5947277.53 677301.11 25.00 1635.20 180.00 MWD 9275.00 16.95 184.00 8660.99 -1643.76 1032.91 5947268.97 677300.71 25.00 1643.76 180.00 MWD 9280.00 15.70 184.00 8665.79 -1645.16 1032.81 5947267.56 677300.65 25.00 1645.16 180.00 MWD 9300.00 15.09 202.78 8685.09 -1650.26 1031.61 5947262.43 677299.57 25.00 1650.26 106.00 MWD 9325.00 16.52 225.28 8709.16 -1655.77 1027.82 5947256.84 677295.91 25.00 1655.77 87.89 MWD 9350.00 19.85 242.33 8732.93 -1660.25 1021.53 5947252.22 677289.73 25.00 1660.25 66.21 MWD 9375.00 24.33 254.01 8756.10 -1663.64 1012.81 5947248.62 677281.09 25.00 1663.64 49.99 MWD 9380.00 25.31 255.86 8760.64 -1664.18 1010.79 5947248.03 677279.08 25.00 1664.18 39.15 MWD 9400.00 24.38 244.15 8778.80 -1667.03 1002.92 5947245.00 677271.28 25.00 1667.03 254.00 MWD 9425.00 24.55 229.02 8801.58 -1672.69 994.35 5947239.14 677262.85 25.00 1672.69 264.63 MWD 9450.00 26.15 214.88 8824.19 -1680.62 987.27 5947231.05 677255.96 25.00 1680.62 278.42 MWD 9475.00 28.97 202.78 8846.37 -1690.73 981.77 5947220.81 677250.70 25.00 1690.73 291.21 MWD 9500.00 32.67 192.93 8867.85 -1702.90 977.91 5947208.55 677247.12 25.00 1702.90 301.95 MWD 9506.00 33.66 190.87 8872.87 -1706.11 977.24 5947205.33 677246.52 25.00 1706.11 310.42 MWD 9525.00 38.41 190.87 8888.23 -1717.09 975.13 5947194.31 677244.67 25.00 1717.09 360.00 MWD 9550.00 44.66 190.87 8906.94 -1733.36 972.01 5947177.97 677241.93 25.00 1733.36 0.00 MWD 9575.00 50.91 190.87 8923.73 -1751.53 968.52 5947159.72 677238.87 25.00 1751.53 0.00 MWD 9600.00 57.16 190.87 8938.40 -1771.39 964.71 5947139.78 677235.52 25.00 1771.39 360.00 MWD 9625.00 63.41 190.87 8950.79 -1792.70 960.61 5947118.38 677231.93 25.00 1792.70 360.00 MWD 9647.89 69.13 190.87 8960.00 -1813.28 956.66 5947097.72 677228.47 25.00 1813.28 0.00 07-01 9650.00 69.66 190.87 8960.74 -1815.21 956.29 5947095.78 677228.14 25.00 1815.21 360.00 MWD 9675.00 75.91 190.87 8968.14 -1838.65 951.79 5947072.24 677224.19 25.00 1838.65 0.00 MWD 9700.00 82.16 190.87 8972.89 -1862.74 947.17 5947048.05 677220.13 25.00 1862.74 360.00 MWD 9725.00 88.41 190.87 8974.95 -1887.20 942.47 5947023.49 677216.01 25.00 1887.20 360.00 MWD 9731.37 90.00 190.87 8975.04 -1893.46 941.27 5947017.21 677214.95 25.00 1893.46 0.00 MWD 9750.00 90.00 188.63 8975.04 -1911.82 938.12 5946998.78 677212.23 12.00 1911.82 270.00 MWD 9775.00 90.00 185.63 8975.04 -1936.62 935.01 5946973.91 677209.71 12.00 1936.62 270.00 MWD 9800.00 90.00 182.63 8975.04 -1961.55 933.21 5946948.95 677208.49 12.00 1961.55 270.00 MWD 9825.00 90.00 179.63 8975.04 -1986.54 932.72 5946923.95 677208.58 12.00 1986.54 270.00 MWD 9850.00 90.00 176.63 8975.04 -2011.53 933.53 5946899.00 677209.98 12.00 2011.53 270.00 MWD 9875.00 90.00 173.63 8975.04 -2036.43 935.65 5946874.15 677212.68 12.00 2036.43 270.00 MWD 9900.00 90.00 170.63 8975.04 -2061.20 939.07 5946849.47 677216.68 12.00 2061.20 270.00 MWD 9925.00 90.00 167.63 8975.04 -2085.75 943.79 5946825.04 677221.97 12.00 2085.75 270.00 MWD 9936.37 90.00 166.27 8975.04 -2096.82 946.35 5946814.03 677224.80 12.00 2096.82 270.00 MWD 9950.00 90.00 167.90 8975.04 -2110.11 949.40 5946800.82 677228.15 12.00 2110.11 90.00 MWD 9975.00 90.00 170.90 8975.04 -2134.68 954.00 5946776.37 677233.32 12.00 2134.68 90.00 MWD 10000.00 90.00 173.90 8975.04 -2159.45 957.30 5946751.67 677237.20 12.00 2159.45 90.00 MWD 10025.00 90.00 176.90 8975.04 -2184.37 959.30 5946726.81 677239.79 12.00 2184.37 90.00 MWD 10050.00 90.00 179.90 8975.04 -2209.36 960.00 5946701.85 677241.07 12.00 2209.36 90.00 MWD 10075.00 90.00 182.90 8975.04 -2234.35 959.39 5946676.85 677241.04 12.00 2234.35 90.00 MWD 10100.00 90.00 185.90 8975.04 -2259.27 957.47 5946651.89 677239.71 12.00 2259.27 90.00 MWD 10101.37 90.00 186.07 8975.04 -2260.64 957.33 5946650.53 677239.60 12.00 2260.64 90.00 MWD 10125.00 92.46 184.65 8974.53 -2284.15 955.12 5946626.97 677237.94 12.00 2284.15 330.00 MWD 10150.00 95.05 183.14 8972.89 -2309.04 953.42 5946602.05 677236.83 12.00 2309.04 329.97 MWD 10175.00 97.64 181.62 8970.13 -2333.86 952.39 5946577.21 677236.38 12.00 2333.86 329.87 MWD 10191.37 99.34 180.62 8967.71 -2350.05 952.07 5946561.02 677236.44 12.00 2350.05 329.70 MWD 10200.00 98.45 180.08 8966.38 -2358.57 952.02 5946552.50 677236.59 12.00 2358.57 211.00 MWD 10225.00 95.87 178.53 8963.26 -2383.37 952.32 5946527.71 677237.47 12.00 2383.37 210.92 MWD 10250.00 93.29 177.00 8961.26 -2408.27 953.30 5946502.85 677239.02 12.00 2408.27 210.72 MWD 10275.00 90.71 175.47 8960.39 -2433.20 954.94 5946477.97 677241.25 12.00 2433.20 210.60 MWD bP ~ BP Alaska Baker Hughes INTEQ Planning Report ~it~ s u. a L~ Company: BP Amoco Field: Prudhoe Bay Site: PB DS 07 Well: 07-01 `Wellpath: Plan 7, 07-01 B '" Survey Date: 2/$/2008 Time: 13:39:32 Page: 4 Co-ordinate(NE)Reference: Well: 07-01, True North Vertical (TVD)'Reference: 1:01 6/5!1978 00:00 64.0 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Survey,Calculation Method: Minimum Curvature Db: Sybase MD ft Iuci .deg Azim :deg SS TVD' ft N/S ft E/W ft MapN ft MapE ft __ DLS deg/100ft __ VS ft TFO deg Too 10281. 37 90. 05 175.08 8960. 35 -2439. 55 955.46 5946471.63 677241. 92 12.00 2439.55 210.55 MWD 10300. 00 89. 70 172.87 8960. 39 -2458. 07 957.42 5946453.16 677244. 31 12.00 2458.07 261.00 MWD 10325. 00 89. 23 169.91 8960. 62 -2482. 79 961.16 5946428.54 677248. 63 12.00 2482.79 261.00 MWD 10350. 00 88. 77 166.95 8961. 05 -2507. 27 966.17 5946404.18 677254. 21 12.00 2507.27 261.03 MWD 10375. 00 88. 30 163.98 8961. 69 -2531. 46 972.44 5946380.15 677261. 05 12.00 2531.46 261.08 MWD 10400. 00 87. 85 161.01 8962. 53 -2555. 29 979.96 5946356.50 677269. 12 12.00 2555.29 261.16 MWD 10406. 37 87. 73 160.26 8962. 78 -2561. 30 982.07 5946350.55 677271. 37 12.00 2561.30 261.26 MWD 10425. 00 87. 73 162.50 8963. 52 -2578. 93 988.01 5946333.06 677277. 72 12.00 2578.93 90.00 MWD 10450. 00 87. 74 165.50 8964. 50 -2602. 94 994.90 5946309.22 677285. 17 12.00 2602.94 89.91 MWD 10475. 00 87. 75 168.50 8965. 49 -2627. 28 1000.52 5946285.02 677291. 36 12.00 2627.28 89.79 MWD 10500. 00 87. 77 171.50 8966. 46 -2651. 88 1004.85 5946260.53 677296. 27 12.00 2651.88 89.67 MWD 10525. 00 87. 80 174.50 8967. 43 -2676. 67 1007.89 5946235.82 677299. 89 12.00 2676.67 89.56 MWD 10550. 00 87. 83 177.51 8968. 38 -2701. 59 1009.63 5946210.95 677302. 21 12.00 2701.59 89.44 MWD 10575. 00 87. 87 180.51 8969. 32 -2726. 57 1010.07 5946185.99 677303. 23 12.00 2726.57 89.33 MWD 10600. 00 87. 91 183.51 8970. 24 -2751. 53 1009.19 5946161.01 677302. 94 12.00 2751.53 89.21 MWD 10625. 00 87. 96 186.51 8971. 14 -2776. 42 1007.01 5946136.08 677301. 34 12.00 2776.42 89.10 MWD 10650. 00 88. 02 189.51 8972. 01 -2801. 16 1003.53 5946111.27 677298. 44 12.00 2801.16 89.00 MWD 10675. 00 88. 08 192.51 8972. 87 -2825. 68 998.75 5946086.65 677294. 24 12.00 2825.68 88.89 MWD 10700. 00 88. 15 195.52 8973. 69 -2849. 92 992.70 5946062.27 677288. 76 12.00 2849.92 88.79 MWD 10706. 37 88. 16 196.28 8973. 89 -2856. 04 990.96 5946056.11 677287. 16 12.00 2856.04 88.69 MWD 10725 .00 88. 50 194.07 8974. 44 -2874. 01 986.09 5946038.03 677282. 71 12.00 2874.01 278.70 MWD 10750 .00 88. 96 191.10 8974. 99 -2898. 40 980.64 5946013.52 677277. 83 12.00 2898.40 278.76 MWD 10775 .00 89. 42 188.14 8975. 34 -2923. 05 976.46 5945988.79 677274. 23 12.00 2923.05 278.83 MWD 10800 .00 89. 89 185.18 8975. 49 -2947. 87 973.56 5945963.90 677271. 92 12.00 2947.87 278.87 MWD 10806 .37 90. 01 184.42 8975. 50 -2954. 22 973.03 5945957.54 677271. 53 12.00 2954.22 278.89 MWD 10825 .00 90. 01 182.18 8975. 50 -2972. 82 971.96 5945938.93 677270. 90 12.00 2972.82 270.00 MWD 10850 .00 90. 01 179.18 8975. 49 -2997. 82 971.66 5945913.93 677271. 18 12.00 2997.82 270.00 MWD 10875 .00 90. 01 176.18 8975. 49 -3022. 79 972.67 5945888.99 677272 .78 12.00 3022.79 270.00 MWD 10900 .00 90. 01 173.18 8975. 49 -3047. 68 974.99 5945864.16 677275 .67 12.00 3047.68 270.00 MWD 10925 .00 90. 01 170.18 8975. 49 -3072. 42 978.60 5945839.52 677279 .87 12.00 3072.42 270.00 MWD 10950 .00 90. 01 167.18 8975. 48 -3096. 93 983.51 5945815.13 677285 .34 12.00 3096.93 270.00 MWD 10975 .00 90. 00 164.18 8975. 48 -3121. 15 989.69 5945791.06 677292 .09 12.00 3121.15 270.00 MWD 11000 .00 90. 00 161.18 8975. 48 -3145. 01 997.13 5945767.38 677300 .09 12.00 3145.01 270.00 MWD 11025 .00 90. 00 158.18 8975. 48 -3168. 45 1005.80 5945744.15 677309 .31 12.00 3168.45 270.00 MWD 11050 .00 90. 00 155.18 8975. 48 -3191. 41 1015.70 5945721.44 677319 .74 12.00 3191.41 270.00 MWD 11075 .00 90. 00 152.18 8975. 47 -3213. 82 1026.78 5945699.30 677331 .34 12.00 3213.82 270.00 MWD 11100 .00 90. 00 149.18 8975. 47 -3235. 61 1039.02 5945677.79 677344 .08 12.00 3235.61 270.00 MWD 11125 .00 90 .00 146.18 8975. 47 -3256. 74 1052.38 5945656.99 677357 .94 12.00 3256.74 270.00 MWD 11150 .00 90 .00 143.18 8975. 47 -3277. 14 1066.83 5945636.94 677372 .86 12.00 3277.14 270.00 MWD 11175 .00 90 .00 140.18 8975. 47 -3296. 75 1082.33 5945617.69 677388 .81 12.00 3296.75 270.00 MWD 11200 .00 90 .00 137.18 8975. 47 -3315. 52 1098.83 5945599.31 677405 .75 12.00 3315.52 270.00 MWD 11225 .00 90 .00 134.18 8975. 46 -3333. 41 1116.30 5945581.84 677423 .63 12.00 3333.41 270.00 MWD 11250 .00 90 .00 131.18 8975. 46 -3350. 36 1134.67 5945565.33 677442 .39 12.00 3350.36 270.00 MWD 11256 .37 90 .00 130.42 8975 .46 -3354. 52 1139.49 5945561.28 677447 .31 12.00 3354.52 270.00 MWD 11275 .00 90 .00 132.66 8975 .46 -3366. 87 1153.44 5945549.26 677461 .54 12.00 3366.87 90.00 MWD 11300 .00 90 .00 135.66 8975 .46 -3384 .29 1171.37 5945532.27 677479 .87 12.00 3384.29 90.00 MWD 11325 .00 90 .00 138.66 8975 .46 -3402 .61 1188.37 5945514.35 677497 .29 12.00 3402.61 90.00 MWD 11350 .00 90 .00 141.66 8975 .46 -3421 .81 1204.39 5945495.53 677513 .75 12.00 3421.81 90.00 2 3/8" BP Alaska WELLPATX DET~IIJ . o~d fDrzoa P~~tl~ nYD: Bt00.0O Newlcaf~ R~1. D~1um: 1. 191E W.W 69.OOn LEGEND w~~ n.,n~ma~mwio ai .~ ~ - -_. 07-01 107-01) ci..a.a er »me ~~/j 07-01107-01 A) B I~KlGFIE ~ 07-01 07-01APB1) Xw a x~ as - P Plan707-018 i. eiaoa ~~ Plan #1 re~p~ s~i Cw~un imwmano~: Vii,. ~~~~ &II MKl~aelwn EQ Em`.,1~~ma~,~,a awm .~®,~e i Vertical Saetlon at 700.00' [SO1Nn] BP Alaska WELLNITN DETAIri PlW39~DOS,m ... WN~p.,n D,-0, n to m MD: 9w0.00 of joio apno - oo,ts,azc B1l OiOllo~~aipAi d,l°-B~APe~~ - -oal wlooraanl os to' mi ~ia,~e - 0~ (off-0~I i `_ I~` SAKER f1~VAG EQ y T M Azhnugrs to Tnre NOdit Magnetic NOM. 2343° Magn tic FieM S4englh: 5]669nT Dip nglo. ae.91• Dale'21B/100a MoOei'. itggm2007 Plan: Plan N7 (07-01/Plan 7, 07-018) Creased By: BP Dala: 2/8/1008 Checked: Dese: conUtt Inlumulwn. Bit MiNaeleon Ee~aaa~'~'~:~~~nN9~ m aNlc y E.I.ONU~iPe~ ,.0, 19TD w:00 Ba.wD ]A GAL _~I~BI o O 1, O n 'inN: ."di .dEfw s..m~T"MiD °B flf g-OBAO °ael aioitlo~i ' i° ,w.w• o.w o.w n.w - I on wr-iwl it tm-m u tm-i ml REFERENCE INFORMATION i~~i ~~. ~~; Ctrordinate (N/E) Reference: Well CenUe: 07-01, True North -1s log i~el _r31 - 1 Vertical (ND) Reference: 1:01 6/5/1978 00:00 fi0.o0 _j~'IO~_~~pl Section (VS Reference: Slat - 01 (O.OON,O.OOE) u lob-~ a ~ ' Measured Depth Reference. 1 01 6/5/197800:00 Sa.00 Calculation Mothotl: Minimum Curvature - ~ al ~~sq IO~i1u~ ° -. _-_- _--_ - - ~o f~ ~ o _. -ts 1oiisn~ ..~ Np in< i rvD .wa .u F.r. v w. is ~oi- it f°r 2i i - nl°t tai ]~po~-xsl 7 (°>23A~ ° is j°~ ~sj 4510-PSa1 t 1aw.w ,o tx .M ,] Il~non]-~j 201a] xBA '1 ]9 Oi ~AI n lob-rinaBl l Z3 ~°i 2°B~ell 29 (ol Dnl w (a~ wl _ ]o {(l{(a~~wal ~ (0~ 38111 32APa11 ~IOI-JZa) { X900 I 07.0, 07-O,A ;~~ 7300 N-- .-. ! 510 0 _ ~\gppp II ' . 8~0 ~ ~0 .. I .. ! ~_- I{{ l I t ' F T ~ - I °" - I' I 7300 -1200 ~ 5700 -', i ~./ 8700 f -a I 1 a~nn i 8900 7200 - { t t 1 J r~ L f L i -..- _~ C _ y~j -24 N_-zsoo- t -zsoo_4. 07 -3000 ~ 07 t i -3200 I a+ 7 f% -,,rn~. ---.. iT • rsoo lriao lzoo laoo lcoo West(-)/East(+) [200ft/in] s rements are from top of Riser i ~_ of bag Dowel I of slips Blind/Shears of pipes 2" combi pipe/slips BAG TOTs Mud Cross I I Mud Cross cross 2 3/8" combi pipe/slip of pipe/slips 2" combi pipe/slips ab Va Flow Tee TOTS Alaska Department of Natural Resources Land Administration System Page 1 of~ j ;;~~ ;;r~i :r:~~:;r= ~ -:i .!-'tats Reccreier's Sa~;rch State Cabins [~1~tu~~ 5~~!°~es „ „e_,.__~._. Alaska DNR Case Surnmar~ File T e ADS File Number 28312 ~o~+ Printable Case File_Summary 3'P ..~....._.... • .........~~.._~__.~._._..... ~_. See Township, Range, Section and Acreage? New Search ~`' Yes ~'"' No __ _ _ ___...~... _.~__ i.AS Menlo I Case Abstract I Gase Detail I Land Abstract Fi1c: :4DL 28312 ~'~~'~' Search for Stat~3s Plat Updates ~ cif (13 l3 X005 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: X84 OIL & GAS LF,ASE COMP DNR Urzit.~ 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 3.5 ISSUED Statr~ts Dute: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: ] 2/04/2006 Case Subtype: NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED 1-Iei~rdiafr: 1, Townslai~~ U I ON R~ur,~r: (11 ~I: ,tie~c~rion: 03 .S'ectivn ~1c~r~~s t~~(> Search Plats ll~~j~i~li~rn: l' 7~u~rri~e6rrJ~: (_)]ON l~ura~;~~.~ 014E S'cc~liun: 0-1 .ti"~c~liun.~lc~f~e~~: 64U ;ll~~ri~lr~at.~ l~ To~r~~i.~hi~~: OION Ica~rge: 0141: .~'c't•li(>n.~ Uy ,ti~~~~~lionfler°es: (i~4Q ;l~/c>>~rc/iuPi: [, Toh~~t.~~f7r~~: OION R~rirge: OI-~E .~~~>~7ro~i: I0 .5~c~c~Iin~~ 4cres: 640 Lr~al 1)cscription 0~-28-196 *'~ * SALE NOTICE LEGAL DESCRIPTION ~ * ~` C1=t-133 TI DN, R14E, UM 3, ~t, 9, 10 2~ 60.00 ~i" C! ~~:~ sL9im'111"'' Last updated on 03/1312008. http://www. dnr.state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28312&... 3/ 13/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~/.~L/ D,~- O/~ PTD# ~Od~0,~~0 /_ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~.~'G1D~D6' ~sJy POOL: ~,e,~,D,c/1~~" ~aY t \ T Circle 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 perforate and 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 throu h tar et 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 ro ram. Rev: 1 / 1 I /2008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL •640150 Well Name: PRUGHOE BAY UNIT 07-01 B Program DEV Well bore seg ^ PTD#:2080380 Company BP fXPLORATION~ALAS ) INC Instal Classll'ype DEV! PEND GeoArea 890 UMt 11650 OnlOff Shore Qn Annular Disposal ^ Administration 1 Petmitfee attached- - - - - - - - - ----------------- - - _ - - - - NA_ _ - _ - _ - - - - - - - - - - 2 Lease numberepprppriete - - - - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - 3 Unique wall-nam®_andnumbet - -- --- - - -- -- -- Yes -- --- - - -- -- --- -- -- --- - -- - --- 4 Well loc;Med in a-definedpool- - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - 5 Welllccatedp[operdistancefromdrillingunit_bound~ry-____________ __- _--Yes- ------------------------------ - - -- -- - -- - - - -- 6 Wall located ptoperdistanpe.fromptherwells--------------------- -------Yes- ----------------------------- ----- -- - --- -- -- - --- 7 Sufficientacreageayeilableindnllinguns___-__-________-__--- ---- --Yes- ------------------- ---- -- --- --- ---------------------------------- 8 If deviated, is wellbQra plat_iocluded - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - 9 Opsratoronlyaffectedpar4r -- ---- --- -- --- -- - -- ----Yes- ------- - - -~ ---- - -- ----- - - -- - -- - -- -- 10 Operatorhas-apptopria2ebondinforts------------------------- ------Yes- ------BlaglcetBpnd#6194193-.------------------------------ - ----- --- - 11 PetmkcanbeissUedwithoutcpnservatioR4rder_---------------- -__----Yes- --------------------------------- -------- ------ ----- - - - --- Appr Date 12 Petmitcanbeissuedwithouiadministtative_approval------------------ -------Yes- -------------------------------- -- -- - -- - ---- --- - -- --- 13 Can permit be eAprpved befprs l5•daY+vaii ~ - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 311312008 14 Well-klcatedwithin areaartdstrataeuthprizedbylnjection9rdet#(put1O#in_comments)_(Fpr- NA__ __________________________._____-.-------------------------------- -- 15 All wells_within 114-roils area of review ident~ed (Fp[ service well pol - ~ Y)-- -- ~- - -- -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 16 Pre•prpduced inleu~or. duration ofpro-produptipn less than 3 months_ (Forservice well Qnly) - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 Nonconven, gas confpnns to AS31,05.034(1.1.A)~U.2.R-D) - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - Englneering 18 Conductorstring_prpvided________--_------------------ ------ NA-- -----CpnductprsetinpS07.01(177.061).------------------------------------------ --- 19 Surfar~_casingprptectsall_knownU$DWs------------------------ ------- NA-- ------Npaquifers,A1O4B,_conGlusion5,----------------------------------------- -- 20 CMT-voladequatefpcirculate-oncpnducipr$surf_csg-____-__-__---_ _-____NA__ _____Surfasecasing set in 07-01,--___________------------------------------- --- 21 CM'~voladequatetotie-inlQngstringtosurfcsg____________________ _____-NA-- --_-_Productipn-casingseiin 07-01,----____-________-___-_------------------------ i22 CMT-will coyer all knoxn_ptoductivehcrizprts___-____-------------- -------Yes- ------------------- --- - - - - --- 23 Casing designs adequatfl for C, T B &_ petmaf[ost - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequate tankage-pr reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ . -Rig equipped with steel pits. Noleserve pit pinned.- All waste_tp apprpved disposal well(s). - . _ - _ - - _ _ 25 re-drill,hasa10.403fprebandpnment keen apprpved--------------- If a -------Yes- ------308,065-------------------------------- - ------ - ---- -- 26 - - Adequate wellkore separation-proppsed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ -Proximity analysis perf_orroed_ iJearest segment is ebandpned pprtipn-of 07-01A and-paths diverge. - - _ _ _ _ _ - _ 27 If_diverter.ra0.uir@d, does it meet regulations_____-__------------- --- ---NA-_ ___-.BOPStapkwillalreadY-be in place,----------------------------------------- Appr Oate 28 Drilling fluid program scfiematic $ equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - _ - _ Maximum expected formatipn pressure 7,1 EMW._ NIW planned 8.6 ppg. - - _ _ _ - _ - - _ - - _ - - _ _ - - _ - _ TEM 3!26!2008 29 BOPEs, d9 theymeetregulation - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30 BOPE.press rating appropriate; test to-(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ - _ MASP calculated at 2381 psi, 3500-psi-BOP test-planned. - _ _ - _ _ _ . _ _ - _ _ - - _ - - - _ - _ _ _ - _ - _ _ ~i/ 31 Choke-manifptdcpmpl~s w/API-RP-53GMay$4)--__________________ _______Yes- -----.---- -- - 32 Work will occur without operation shutdpwn - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - 33 Is presence of H2S gas prpbable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - _ _ - _ _ _ - - _ - _ _ _ -Yes _ _ - _ _ - H2S is present pn DS 7.- Mud should preclude H2S on_ rig, Rig has sensors and alarms.- - _ _ - _ _ _ _ _ - _ _ 34 -Mechanical condsion of wells within AQf2 verified GFpr service yell poly) _ _ - - _ _ - _ _ _ _KA_ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - ~ - - - - - - Geology 35 Permit can i~ issued wla hydrogen_suifiide measures - _ - _ _ _ - _ _ _ - _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ Max teeel H2S on Pad pS 7 is_150ppm, well 07.13A_(7-21-93)__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 36 Data_presented pn Roiential 9verpressurezones- - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 37 Seismic anaysis pf shallow gas zones- - - - - ~ - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ACS 311312008 ~ SeakedcondkionsurYe-y-(if4ff-shore)--------------------------- ------- NA- --- 39 Contact namelphpne_fcrweekY-P-ro9ressrepprfs_Iexploratcryonly]---------- -------Yes- ------MelRi~se464-5620------------------------------ --- --- ---- Geologic Commissioner: Engineering Date Public Date: Commissioner: iss r Date Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efi(ort has been made to chronologically organize this category of information. ~ ~ **** REEL HEADER **** MWD 08/07/14 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/04/22 19127618 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 9050.0000: Starting Depth STOP.FT 10098.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 07-O1B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 15' 57.421"N 148 deg 34' 29.963"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 22 Apr 2008 API API NUMBER: 500292027202 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 34 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 64 DMF DF EKB .F 0 EDF .F 64 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. ~011-0~~ ¢ /(ola1~5 • (2) All depths are Bit Depths unless (3) All True Vertical Depths (TVDSS) (4) All Formation Evaluation data is (5) Baker Hughes INTEQ utilized Coil' Advantage otherwise noted. are Subsea corrected. realtime data. Prak downhole tools and the surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 22 Apr 2008 per Doug Stoner with BP Exploration (Alaska), Inc. (8) Tied to 07-01 at 9200 feet MD (8593.8 feet TVDSS). (9) The sidetrack was drilled from 07-01 through a milled window in a 3 1/2 and 7 inch li ner. Top of window 9201 ft.MD (8594.6 ft.TVDSS) Bott om of window 9207 ft.MD (8599.7 ft.TVDSS) (13) The interval from 11001 feet to 11026 feet MD (8593.4 feet to 8954.7 feet TVDSS ) was not logged due to sensor to b it offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP AVG -> Rate of Penetration, feet/hour _ RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TVD -> True Vertical Depth (Subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 9057.83, 9058.66, ! 0.829102 9059.08, 9060.11, ! 1.03613 9061.57, 9061.77, ! 0.207031 9066.33, 9067.58, ! 1.24414 9070.48, 9070.89, ! 0.414062 9084.16, 9083.12, ! -1.03711 9086.03, 9086.44, ! 0.415039 9093.9, 9095.35, ! 1.45117 9098.46, 9098.67, ! 0.208008 9100.33, 9101.16, ! 0.829102 9104.48, 9104.89, ! 0.415039 9108.62, 9109.04, ! 0.414062 9112.35, 9112.77, ! 0.414062 9114.84, 9115.05, ! 0.207031 9117.12, 9117.95, ! 0.829102 9181.77, 9185.5, ! 3.73145 9194.42, 9198.77, ! 4.35352 9205.2, 9207.89, ! 2.69531 9206.23, 9210.17, ! 3.93848 9207.48, 9211.42, ! 3.93848 9213.49, 9217.43, ! 3.93848 9217.43, 9221.57, ! 4.14551 9225.1, 9225.72, ! 0.62207 9227.38, 9231.11, ! 3.73145 9228.62, 9232.35, ! 3.73145 9230.9, 9234.84, ! 3.93848 9238.2, 9242.14, ! 3.93848 9242.14, 9245.66, ! 3.52441 9247.32, 9251.67, ! 4.35254 9251.05, 9254.99, 9259.6, 9263.95, 9261.88, 9265.82, 9264.16, 9269.14, 9274.21, 9278.15, 9281.47, 9286.03, 9284.58, 9289.55, 9290.38, 9294.94, 9299.65, 9302.97, 9305.04, 9312.71, 9309.19, 9316.65, 9310.84, 9318.72, 9314.16, 9322.04, 9317.89, 9326.39, 9368.46, 9375.93, 9432.44, 9440.74, 9449.65, 9456.91, 9467.27, 9475.35, 9475.45, 9484.16, 9477.94, 9486.65, 9482.29, 9490.59, 9486.86, 9494.53, 9494.53, 9502.4, 9513.64, 9521.52, 9514.88, 9523.38, 9516.13, 9524.62, 9518.61, 9526.28, 9525.04, 9532.71, 9528.56, 9535.82, 9530.22, 9538.72, 9532.71, 9541.21, 9534.16, 9543.07, 9543.49, 9551.99, 9560.06, 9564.21, 9563.8, 9568.56, 9566.7, 9570.64, 9575.61, 9580.59, 9580.79, 9585.35, 9583.9, 9588.05, 9594.68, 9596.55, 9603.6, 9607.54, 9611.31, 9616.08, 9615.66, 9620.22, 9620.43, 9624.16, 9629.14, 9633.9, 9644.06, 9649.24, 9656.96, 9662.97, 9667.88, 9673.9, 9675.4, 9680.59, 9679.96, 9687.43, 9691.72, 9697.32, 9693.8,9701.47, 9697.53, 9704.99, 9727.11, 9733.95, 9730.22, 9737.48, 9792.5, 9799.55, 9797.89, 9805.98, 9822.76, 9824.21, 9832.92, 9835.2, 9839.55, 9841, ! 9852.39, 9853.22, 9866.28, 9867.32, 9997.42, 9999.7, 10015, 10018.6, 10021.3, 10023.7, 10031.8, 10032.9, 10040.7, 10043.2, 3.93848 4.35254 3.93848 4.97461 3.93848 4.56055 4.97559 4.56055 3.31641 7.66992 7.46289 7.87793 7.87695 8.49902 7.46289 8.29199 7.25488 8.08398 8.70703 8.70703 8.29199 7.66992 7.87695 7.87695 8.5 8.49902 7.66992 7.66992 7.25586 8.5 8.49902 8.91309 8.49902 4.14648 4.76758 3.93848 4.97461 4.56055 4.14648 1.86621 3.93848 4.76758 4.55957 3.73145 4.76758 5.18164 6.01172 6.01172 5.18262 7.46289 5.59766 7.66992 7.46289 6.84082 7.25586 7.04883 8.08398 1.45117 2.28027 1.45117 0.829102 1.03711 2.28027 3.52344 2.4873 1.03613 2.48828 10078.8, 10079.7, 10098.9, 10100.4, 10103.3, 10104.7, 10107, 10108, ! 10108.9, 10109.5, 10175.7, 10176.7, 10184.4, 10183.8, 10187.5, 10189, 10201, 10206.2, 10211.4, 10211.6, 10217.4, 10218.8, 10224.8, 10227.3, 10304.7, 10307.8, 10352.1, 10354.8, 10433.2, 10429.9, 10445.2, 10447.3, 10454.5, 10454.5, 10462.4, 10464.9, 10471.9, 10475, 10478.8, 10481.3, 10485.4, 10485.6, 10490.6, 10490.2, 10512.6, 10516.5, 10519, 10521.7, 10524, 10526.1, 10527.7, 10528.6, 10529.4, 10530.4, 10533.5, 10533.3, 10538.3, 10537.9, 10549.7, 10549.7, 10560.3, 10564.6, 10568.1, 10570.4, 10577, 10578.5, 10581.6, 10584.1, 10590.7, 10593.6, 10600.9, 10601.9, 10605.7, 10607.9, 10614.2, 10616.2, 10631.3, 10633.6, 10638.4, 10641.1, 10642.5, 10644.6, 10958.9, 10956.9, 10962.9, 10961.6, 10964.5, 10962.9, 10968.7, 10966.8, 10972.8, 10970.5, EOZ END ! 0.829102 ! 1.45117 ! 1.4502 1.03711 ! 0.62207 ! 1.03711 ! -0.62207 1.45117 5.18164 ! 0.207031 ! 1.45117 ! 2.48828 ! 3.10938 ! 2.69531 ! -3.31641 ! 2.07324 ! p ! 2.48828 3.10938 ! 2.4873 ! 0.207031 ! -0.415039 ! 3.93848 2.69531 2.07227 ! 0.829102 ! 1.03711 ! -0.207031 ! -0.414062 ~ 0 ! 4.35254 ! 2.28027 1.45117 ! 2.48828 ! 2.90234 ! 1.03613 ! 2.2793 ! 2.07227 ! 2.28027 ! 2.69531 ! 2.07324 ! -2.07324 ! -1.24414 ! -1.6582 ! -1.86621 ! -2.28027 ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 216 records... 10 bytes 132 bytes • *** INFORMATION TABLE: CONS MNEM VALU WDFN 07-OlB_5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN 07-OlB APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 Data presented here is final and has been depth adjusted to a PDC (Primary Depth log provided by Schlumberger GR CNL dated 22 Apr 2008 per Doug Stoner with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT ------------------ CNAM - - ODEP GR GR --- - ------ GRAX ----------------- 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F J Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 110 Tape File Start Depth = 9050.000000 Tape File End Depth = 11026.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 123 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 07-01B.xtf LCC 150 CN BP Exploration (Alaska) WN 07-O1B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE _ ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD ).250 * F Code Samples Units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 220 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 9051.000000 Tape File End Depth = 11026.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 233 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/04/22 19127618 01 **** REEL TRAILER **** MWD 08/07/14 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9050.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9050.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 57.1941 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9200.0000 26.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 31.1148 138.0079 30.9114 42.2246 58.9866 71.1233 9400.0000 26.4509 15.2112 43.4158 102.6904 62.3785 78.0070 9500.0000 29.1728 46.7382 22.7620 29.4157 40.1555 54.4230 9600.0000 145.4083 31.2556 7.8633 6.7145 6.4677 5.9430 9700.0000 86.6324 87.8622 9.4585 8.3632 8.8678 8.5641 9800.0000 30.7259 80.3081 8.4516 6.8835 7.7060 7.3371 9900.0000 21.5000 88.3077 13.5491 18.2283 27.7444 31.1097 10000.0000 25.1964 88.5795 8.9326 9.1015 9.9838 10.5510 10100.0000 72.6255 87.6278 8.7454 9.1174 10.2575 11.5688 10200.0000 26.2138 95.6655 8.6204 7.5556 7.3446 6.6740 10300.0000 29.0506 45.6419 7.8316 6.6397 6.4682 5.7740 10400.0000 21.8837 62.6751 8.2711 7.5578 8.8735 9.5324 10500.0000 173.7950 13.6511 6.7133 5.7765 6.1508 6.1135 10600.0000 66.3267 31.3261 8.1663 8.1020 9.3670 10.5728 10700.0000 34.3148 84.4702 14.7101 20.0400 25.0290 32.0224 10800.0000 22.4523 108.1312 13.5464 20.2389 27.7995 38.4806 10900.0000 23.0531 145.9343 -999.2500 -999.2500 -999.2500 -999.2500 11000.0000 -999.2500 77.4797 -999.2500 -999.2500 -999.2500 11026.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9050.000000 Tape File End Depth = 11026.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet -999.2500 -999.2500 • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9051.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9051.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 31.3000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9200.0000 19.9000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 33.6000 141.3000 32.0820 44.3540 53.7200 65.6480 9400.0000 23.3000 23.8000 38.0690 43.6680 41.0040 44.2620 9500.0000 24.0000 63.0000 22.3750 25.4320 28.1430 31.7360 9600.0000 160.9000 43.2000 7.4210 6.8420 6.6440 6.3430 9700.0000 27.4000 78.9000 9.0650 8.7230 10.1590 10.7580 9800.0000 35.2000 57.1000 8.7470 6.9980 7.8330 7.6270 9900.0000 26.7000 87.8000 13.7630 19.2530 25.5980 31.7360 10000.0000 35.5000 89.8000 9.1420 9.2120 9.9750 10.5450 10100.0000 68.4000 89.1000 8.4050 8.9420 11.0540 11.9390 10200.0000 29.7000 93.2000 8.5890 7.2330 6.9410 6.1230 10300.0000 27.7000 45.8000 7.8360 6.7560 6.6480 6.0320 10400.0000 18.9000 66.6000 8.2110 7.6910 8.7350 9.2750 10500.0000 171.6000 12.6000 6.6620 5.7030 6.0710 6.0300 10600.0000 50.3000 31.5000 8.1900 8.1190 9.3670 10.6530 10700.0000 37.7000 82.8000 14.2940 20.0710 24.9940 31.9710 10800.0000 22.5000 108.0000 13.5000 20.2690 27.6900 38.5400 10900.0000 21.8000 121.7000 -999.2500 -999.2500 • • -999.2500 -999.2500 11000.0000 57.6000 78.3000 -999.2500 -999.2500 -999.2500 11026.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9051.000000 Tape File End Depth = 11026.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet -999.2500 -999.2500 • Tape Subfile 4 is type: LIS
