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Home My WebLink About197-049CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brooks, Phoebe L (OGC) To:Alaska NS - ASR - Well Site Managers Cc:Regg, James B (OGC) Subject:RE: ASR-1 | MPF-65 Initial Test Report Date:Friday, June 7, 2024 2:55:36 PM Attachments:Hilcorp ASR 1 05-08-24 Revised.xlsx Attached is a revised report changing the report date to reflect 5/8/24 and adding 4 to the # of Nitgn. Bottles. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com> Sent: Thursday, May 9, 2024 7:54 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov> Cc: Alaska NS - ASR - Well Site Managers <AlaskaNS-ASRWellSiteManagers@hilcorp.com>; Scott Heim - (C) <Scott.Heim@hilcorp.com> Subject: ASR-1 | MPF-65 Initial Test Report Please find attached. Regards, ASR DSM’s Hilcorp DSM: 907-685-1266 Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please Attached is a revised report changing the report date to reflect 5/8/24 and adding 4 to the # ofAttached is a revised report changing the report date to reflect 5/8/24 and adding 4 to the # of 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Jet Pump Temp Production Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 16,853 feet N/A feet true vertical 7,819 feet N/A feet Effective Depth measured 16,755 feet 16,106 feet true vertical 7,729 feet 7,152 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / L-80 / TXP BTC 16,213’ 7,245' Packers and SSSV (type, measured and true vertical depth)Tripoint Perm 7" x 4-1/2" N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: 5,750psi 7,240psi16,840' 7,807' Burst N/A Collapse N/A 3,090psi 5,410psi Casing Conductor 16,812' 8,604'Surface Production 20" 9-5/8" 7" 110' 8,573' measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-049 50-029-22752-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025509, ADL0355017 & ADL0355018 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT F-65 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 1737 Gas-Mcf MD 110' 0 Size 110' 4,633' 382 2872123 0 50 360 324-187 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:57 pm, Jun 07, 2024 e and corree and correDigitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.06.07 13:47:19 - 08'00' Taylor Wellman (2143) RBDMS JSB 061124 DSR-6/7/24WCB 8-30-2024 _____________________________________________________________________________________ Revised By: TDF 5/2/2024 SCHEMATIC Milne Point Unit Well: MP F-65 Last Completed: 12/31/2023 PTD: 197-049 TD =16,853(MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13’ DF to Tbg.Spool =28.5’ (Nabors 22E) 7” 5 7 9-5/8” 3 4 KUP A Sands PBTD =16,755’(MD) / PBTD =7,729’(TVD) 6X 1 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP BTC 3.958 Surface 16,213’ JEWELRY DETAIL No Depth Item 1 271’ X-Nipple – ID=3.813 2 3,247’ GLM 4-1/2" x 1" with BK-DCK Valve – 3,000' TVD 3 16,048’ Viking XD Sliding Sleeve – ID=3.813” 4 16,106’ Tri-Point 7” x 4-1/2” Perm Packer 5 16,165’ 4-1/2” XN-Nipple (3.813” No-go ID) 6 16,175’ WLEG – Btm @ 16,213’ 7 16,430’ CIBP PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Open Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Open Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,767 sx PF “E”, 800 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle = 77 deg. Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 ESP RWO w/ ASR#1 – 11/29/2021 4-1/2” Sliding Sleeve Completion by ASR – 12-31-2023 STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 Slickline 50-029-22752-00-00 197-049 4/4/2024 5/2/2024 4/5/2024 - Friday WELL S/I ON ARRIVAL. BEGIN R/U .125 CARBON, 1-7/8'' RS, QC, 8' X 1-7/8'' RS (2.60'' wheels), QC, KJ, 5' X 1-7/8'' RS (2.60'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. MADE 2 RUNS /w 3'' JET PUMP (ratio12A, sidoti seal, sec. loc.,screen, oal= 88''), TOOLS KEPT FALLING THROUGH SLEEVE @ 16,110' SLM / 16,048' MD. POSSIBLY RUN BRUSH, KNUCKLE ABOVE X-LINE. WELL S/I ON DEPARTURE. 4/3/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 4/4/2024 - Thursday BEGIN R/U .125 CARBON, 1-7/8'' RS, QC, 8' X 1-7/8'' RS (2.60'' wheels), QC, KJ, 5' X 1-7/8'' RS (2.60'' wheels), QC, 5' X 1-7/8'' (2.60'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT=250L / 3500H. OPEN SLEEVE @ 16022' SLM / 16048' MD. WELL S/I ON DEPARTURE. No operations to report. No operations to report. 4/6/2024 - Saturday No operations to report. 4/9/2024 - Tuesday 4/7/2024 - Sunday WELL S/I ON ARRIVAL. REPLACE ROLL PINS, CHECK CONNECTIONS, MAKEUP TOOLS, STAB ON & PRESSURE TEST TO 3,000 PSI (pass). RAN KJ, BLB, 3.25" GAUGE RING, BRUSH XD @16,025' SLM (16,048' MD). SET 3" JETPUMP (12A ratio w/ sidoti seal), SCREEN (=88" oal) IN XD @16,048' MD. WELL S/I ON DEPARTURE. 4/8/2024 - Monday SET 3" JETPUMP (12A ratio w/ sidoti seal), SCREEN (=88" oal) IN XD @16,048' MD Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 Slickline 50-029-22752-00-00 197-049 4/4/2024 5/2/2024 No operations to report. No operations to report. 4/13/2024 - Saturday No operations to report. 4/16/2024 - Tuesday 4/14/2024 - Sunday No operations to report. 4/15/2024 - Monday 4/12/2024 - Friday No operations to report. 4/10/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL. BEGIN R/U .125 CARBON, 1-7/8'' RS , QC, 5' X 2-5/8'' RS (3'' wheels), QC, 5' X 2-5/8'' RS (3'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. PULLED 3'' JET PUMP @ 16110' SLM / 16048' MD (ratio:12A). CLOSE SLEEVE @ 16110' SLM / 16048' MD. LRS MIT-IA PASSED to 3486 psi. Pressured up IA to 3523 psi with 4.5 bbls 60/40. 1st 15 min IA lost 31 psi. 2nd 15 min IA lost 6 psi for a total loss of 37 psi in 30 min. Bled back 4 bbls. Final Whps= 100/300/0. OPEN SLEEVE @ 16110' SLM / 16048' MD. WELL S/I ON DEPARTURE. 4/11/2024 - Thursday WELL S/I ON ARRIVAL. 3'' JET PUMP (ratio12A, sidoti seal, sec. loc.,screen, soft set, BHP's 78058, 77868 batt. in @ 06:23, oal= Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 Slickline 50-029-22752-00-00 197-049 4/4/2024 5/2/2024 No operations to report. No operations to report. 5/4/2024 - Saturday No operations to report. 5/7/2024 - Tuesday 5/5/2024 - Sunday No operations to report. 5/6/2024 - Monday 5/3/2024 - Friday No operations to report. 5/1/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 5' x 2-5/8" STEM, OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. HOTSHOT TO A-PAD TO FIND SPECIAL POWER FLUID CONNECTION. CHASE THREADS ON WHIPSTOCK. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good).RAN 10' x 3.70" DUMMY WHIPSTOCK, 3.70" CENT BARBELL SETUP TO 16,200' SLM (target depth). NEED POWER FLUID 4,200' SLM. ATTEMPT TO SET 4-1/2" JETPUMP, DUAL SPARTEK GAUGES (ratio: 12A, sidoti seal) IN VIKING-SS AT 16,048' MD. 5/2/2024 - Thursday RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 10' x 2-5/8" ROLLER STEM (3.50" whls), OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. RIG-UP POWER FLUID, PT PCE 350L / 3500H. (Good).ATTEMPT TO SET 4-1/2" JETPUMP, DUAL SPARTEK GAUGES (ratio: 12A, sidoti seal) IN VIKING-SS AT 16,048' MD (See log). WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. _____________________________________________________________________________________ Revised By: TDF 5/2/2024 SCHEMATIC Milne Point Unit Well: MP F-65 Last Completed: 12/31/2023 PTD: 197-049 TD =16,853(MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13’ DF to Tbg.Spool =28.5’ (Nabors 22E) 7” 5 7 9-5/8” 3 4 KUP A Sands PBTD =16,755’(MD) / PBTD =7,729’(TVD) 6X 1 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP BTC 3.958 Surface 16,213’ JEWELRY DETAIL No Depth Item 1 271’ X-Nipple – ID=3.813 2 3,247’ GLM 4-1/2" x 1" with BK-DCK Valve – 3,000' TVD 3 16,048’ Viking XD Sliding Sleeve – ID=3.813” 4 16,106’ Tri-Point 7” x 4-1/2” Perm Packer 5 16,165’ 4-1/2” XN-Nipple (3.813” No-go ID) 6 16,175’ WLEG – Btm @ 16,213’ 7 16,430’ CIBP PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Open Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Open Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,767 sx PF “E”, 800 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle = 77 deg. Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 ESP RWO w/ ASR#1 – 11/29/2021 4-1/2” Sliding Sleeve Completion by ASR – 12-31-2023 STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 Slickline 50-029-22752-00-00 197-049 4/4/2024 5/2/2024 4/5/2024 - Friday WELL S/I ON ARRIVAL. BEGIN R/U .125 CARBON, 1-7/8'' RS, QC, 8' X 1-7/8'' RS (2.60'' wheels), QC, KJ, 5' X 1-7/8'' RS (2.60'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. MADE 2 RUNS /w 3'' JET PUMP (ratio12A, sidoti seal, sec. loc.,screen, oal= 88''), TOOLS KEPT FALLING THROUGH SLEEVE @ 16,110' SLM / 16,048' MD. POSSIBLY RUN BRUSH, KNUCKLE ABOVE X-LINE. WELL S/I ON DEPARTURE. 4/3/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 4/4/2024 - Thursday BEGIN R/U .125 CARBON, 1-7/8'' RS, QC, 8' X 1-7/8'' RS (2.60'' wheels), QC, KJ, 5' X 1-7/8'' RS (2.60'' wheels), QC, 5' X 1-7/8'' (2.60'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT=250L / 3500H. OPEN SLEEVE @ 16022' SLM / 16048' MD. WELL S/I ON DEPARTURE. No operations to report. No operations to report. 4/6/2024 - Saturday No operations to report. 4/9/2024 - Tuesday 4/7/2024 - Sunday WELL S/I ON ARRIVAL. REPLACE ROLL PINS, CHECK CONNECTIONS, MAKEUP TOOLS, STAB ON & PRESSURE TEST TO 3,000 PSI (pass). RAN KJ, BLB, 3.25" GAUGE RING, BRUSH XD @16,025' SLM (16,048' MD). SET 3" JETPUMP (12A ratio w/ sidoti seal), SCREEN (=88" oal) IN XD @16,048' MD. WELL S/I ON DEPARTURE. 4/8/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 Slickline 50-029-22752-00-00 197-049 4/4/2024 5/2/2024 No operations to report. No operations to report. 4/13/2024 - Saturday No operations to report. 4/16/2024 - Tuesday 4/14/2024 - Sunday No operations to report. 4/15/2024 - Monday 4/12/2024 - Friday No operations to report. 4/10/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL. BEGIN R/U .125 CARBON, 1-7/8'' RS , QC, 5' X 2-5/8'' RS (3'' wheels), QC, 5' X 2-5/8'' RS (3'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. PULLED 3'' JET PUMP @ 16110' SLM / 16048' MD (ratio:12A). CLOSE SLEEVE @ 16110' SLM / 16048' MD. LRS MIT-IA PASSED to 3486 psi. Pressured up IA to 3523 psi with 4.5 bbls 60/40. 1st 15 min IA lost 31 psi. 2nd 15 min IA lost 6 psi for a total loss of 37 psi in 30 min. Bled back 4 bbls. Final Whps= 100/300/0. OPEN SLEEVE @ 16110' SLM / 16048' MD. WELL S/I ON DEPARTURE. 4/11/2024 - Thursday WELL S/I ON ARRIVAL. 3'' JET PUMP (ratio12A, sidoti seal, sec. loc.,screen, soft set, BHP's 78058, 77868 batt. in @ 06:23, oal= Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 Slickline 50-029-22752-00-00 197-049 4/4/2024 5/2/2024 No operations to report. No operations to report. 5/4/2024 - Saturday No operations to report. 5/7/2024 - Tuesday 5/5/2024 - Sunday No operations to report. 5/6/2024 - Monday 5/3/2024 - Friday No operations to report. 5/1/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 5' x 2-5/8" STEM, OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. HOTSHOT TO A-PAD TO FIND SPECIAL POWER FLUID CONNECTION. CHASE THREADS ON WHIPSTOCK. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good).RAN 10' x 3.70" DUMMY WHIPSTOCK, 3.70" CENT BARBELL SETUP TO 16,200' SLM (target depth). NEED POWER FLUID 4,200' SLM. ATTEMPT TO SET 4-1/2" JETPUMP, DUAL SPARTEK GAUGES (ratio: 12A, sidoti seal) IN VIKING-SS AT 16,048' MD. 5/2/2024 - Thursday RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 10' x 2-5/8" ROLLER STEM (3.50" whls), OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. RIG-UP POWER FLUID, PT PCE 350L / 3500H. (Good).ATTEMPT TO SET 4-1/2" JETPUMP, DUAL SPARTEK GAUGES (ratio: 12A, sidoti seal) IN VIKING-SS AT 16,048' MD (See log). WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. UNABLE TO SET JETPUMP. PREP WELL FOR RWO. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Subm it to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 5/8/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name: PTD #1970490 Sundry #324-153 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/2500 Annular:250/2500 Valves:250/2500 MASP:1829 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 0 NA Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators P P #1 Rams 1 2-7/8" x 5" VBR P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 2 1/16"FP Time/Pressure Test Result HCR Valves 1 2 1/16"P System Pressure (psi)3000 P Kill Line Valves 3 2 1/16"FP Pressure After Closure (psi)1900 P Check Valve 0 NA 200 psi Attained (sec)16 P BOP Misc 0 NA Full Pressure Attained (sec)63 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4@2450 PSI P No. Valves 16 FP ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec) Test Result CH Misc 0 NA Annular Preventer 14 P #1 Rams 6 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 0 NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:3 Test Time:14.5 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 5/6/24 10:16 Waived By Test Start Date/Time:5/8/2024 4:00 (date) (time)Witness Test Finish Date/Time:5/8/2024 18:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Guy Cook Hilcorp Tested with 4-1/2" and 2-7/8" test joints Test #3 - K2 leaking. R/R Valve, Retest good #9 on chart Test #4 - C9 leaking. R/R Valve, Retest good #4 on chart Test #8 - C1 leaking. R/R Valve, Retest good #8 on chart Precharge avg bottle psi = 1,008 psi C. Greub / M. Boord Hilcorp Alaska LLC S. Heim / M.Heinz-Brown MPU F-65 Test Pressure (psi): skans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2025-0508_BOP_Hilcorp_ASR1_MPU_F-65 FP FP FP 3 K2 leaking. C9 leaking. C1 leaking. C9 leaking. 4-1/2" and 2-7/8" test joints K2 leaking. K2 leaking. 16106 / 7152 Drilling Manager 03/26/24 Monty M Myers By Grace Christianson at 11:22 am, Apr 01, 2024 RBDMS JSB 040424 DSR-4/12/24WCB 2024-07-11 ACTIVITYDATE SUMMARY 1/15/2024 ***WELL SHUT IN UPON ARRIVAL*** RAN 20' X 3.70" DUMMY WHIPSTOCK, TOOLS FALLING SLOW, SD @8581' SLM RAN KJ, BLB, 3.69" GAUGE RING, NO ISSUES @8,581' SLM, TAG CIBP @16,403' SLM (16,430' MD) ***WELL S/I ON DEPARTURE*** 1/18/2024 ***WELL S/I ON ARRIVAL*** RAN X-WING MAGNETS DOWN TO EOT @ 16174' MD (lost 1 wheel 1'' X .4 & roll pin) RAN 3.70'' GAUGE TAG @ 16,487' SLM RAN 20' X 4-1/2 DUMMY WHIPSTOCK, TOOLS STOP FALLING @ 8591' SLM WAS ABLE TO GET MOVING & STOPPED FALLING @ 8630' SLM, COULDN'T GET ANY DEEPER WELL S/I ON DEPARTURE ***CONTINUE WSR ON 1-19-24*** 1/19/2024 ***CONTINUE WSR FROM 1-18-24*** WELL S/I ON ARRIVAL RAN HES 40 ARM CALIPER, LOG FROM 16487' SLM TO 15800' SLM (good data) ***WELL S/I ON ARRIVAL*** 1/30/2024 LRS CTU #1 - 1.5" Coil Tubing .134 wt. Job Scope = Drift MIRU. ***Job continued 1/31/24*** 1/31/2024 LRS CTU #1 - 1.5" Coil Tubing .134 wt. Job Scope = Drift ***Job Continued from 1/30/24*** Perform weekly BOP test. Pass. RU NS MHA and BOT 3.70" dummy whip stock drift. Tag 16,444' CTM, POOH, FP well with diesel on way OOH. RDMO ***Job complete*** Daily Report of Well Operations PBU MPF-65 , @ RAN 20' X 4-1/2 DUMMY WHIPSTOCK, TOOLS STOP FALLING @ 8591' SLM@ WAS ABLE TO GET MOVING & STOPPED FALLING @ 8630' SLM, COULDN'T GET ANY DEEPER RU NS MHA and BOT 3.70" dummy whip stock drift.y Tag 16,444' CTM, POOH _____________________________________________________________________________________ Revised By: JNL 3/13/2024 SCHEMATIC Milne Point Unit Well: MP F-65 Last Completed: 12/31/2023 PTD: 197-049 TD = 16,853’ (MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13.0’ 7” 3 7 9-5/8” 1 2 PBTD =16,410’(MD) / PBTD = 7,418’(TVD) 4 6X 4-1/2x7 Whipstock set @ 16,410’ 5 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / EUE 8rd 3.958 Surface 16,213’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Closed Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Closed Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Closed Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 24" 260 sx of Arcticset I (Approx.) 12-1/4" 1767 sx PF “E”, 800 sx Class “G” 8-1/2” 300 sks Class “G” WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 ESP RWO w/ ASR#1 – 11/29/2021 4-1/2” Sliding Sleeve Completion by ASR – 12/31/23 L1 & L1-01 Sidetrack by CDR2 - TBD STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned. JEWELRY DETAIL No Depth Item 1 271’ X-Nipple ID = 3.813” 2 3,247’ GLM: 4-1/2” x 1” BK-DCK Valve (2992’ TVD) 3 16,048’ Viking XD Sliding Sleeve ID: 3.813” 4 16,106’ Tri Point Perm Packer 5 16,165’ X-Nipple ID=3.813” 6 16,175’ WLEG – Bottom @ 16,213’ 7 16,430’ CIBP 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Jet Pump Temp Production 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 16,853'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KUPARUK RIVER OIL N/A 7,819' 16,755' 7,729' 1,829 N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT F-65 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 4/1/2024 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509, ADL0355017 & ADL0355018 197-049 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22752-00-00 Hilcorp Alaska LLC C.O. 432E Length Size Proposed Pools: 110' 110' 12.6 / L-80 / TXP BTC TVD Burst 16,213’ MILNE POINT MD N/A 5,750psi 7,240psi 4,633' 7,807' 8,604' 16,840' 110' 20" 9-5/8" 7" 8,573' 16,812' Tripoint Perm 7" x 4-1/2" and N/A 16,106 MD/ 7,152 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic See Schematic 4-1/2" No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:08 am, Apr 01, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.04.01 08:01:14 - 08'00' Taylor Wellman (2143) 324-187 MGR03APR24 SFD 4/1/2024 10-404 DSR-4/12/24 * Approved for 90 days of production with 24/7 man watch with jet pump utilizing the Sidoti check. * Kill line piping and 1.5 wellbore volumes of KWF to be stored on MPU F PAD. JLC 4/12/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.12 14:15:27 -08'00'04/12/24 RBDMS JSB 041624 Well: MPF-65 PTD: 197-049 API: 50-029-22752-00-00 Well Name:MPF-65 API Number:50-029-22752-00-00 Current Status:Producer Rig: Estimated Start Date:4/5/2024 Estimated Duration:1 days Regulatory Contact:Tom Fouts Permit to Drill Number:197-049 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: TBD, currently drilling the sidetrack. Max Potential Surface Pressure: TBD Gas Column Gradient (0.1 psi/ft) Max Angle:77° @ 10,950’ MD Brief Well Summary: MPU F-65 was drilled in January 1996 and completed in March 1996 as a Kuparuk producer. The well has been an ESP production well with ESP change outs as follows: March 1996 (initial), October 2001, February 2006, December 2012 and February 2017. Injection support was resumed in May 2021 to offset voidage. The ESP failed during a power bump that shut down Milne Point October 2021. November 2021 the ESP was replaced. February 2024 F-65 was sidetracked with CTD to drill the multilaterals F-65L1 and F-65L1-01. We currently drilling the F-65L1-01. When kicking off the billet from the F-65L1 lateral it appeared we milled up a large amount of the aluminum billet because we got back a significant amount of aluminum cuttings. Throughout the F-65L1-01 drilling process we had to make frequent trips to keep the hole clean. As a result, we believe a period of jet pump production will allow us to clean up the new laterals before installing the ESP completion. Hilcorp is requesting permission to produce this well as a jet pump completion for up to 90 days. Hilcorp is also requesting a variance from 20 AAC 20.265 for the SSSV in the tubing. Hilcorp will manwatch the well 24/7 during Jet pump operations. The IA will be isolated with the use of a Sidoti check valve in the jet pump. Objectives: Produce the well on JP for 90 days to clean up the well prior to installing the ESP completion. Notes Regarding Wellbore Condition: x 7” IA tested to 2,178 psi @ 16,106’ on 1/10/24 Procedure Full bore 1. Rig up kill line and have 1.5x wellbore volume of kill weight fluid available at the MI plant in Prudhoe for emergency bullhead operations. 2. 24/7 manwatch during Jet pump operations Full bore 1. RU pump truck pressure test lines to 3,500 psi. 2. MIT-IA to max PF pressure of 3,200 psi for 30 min, charted. 3. Bleed off pressure. RDMO. Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer to the x-nipple at 16,165’MD. 3. RIH shift sliding sleeve open @ 16,048’ MD. KWF store on MPU F-pad. - mgr Well: MPF-65 PTD: 197-049 API: 50-029-22752-00-00 4. RIH with 3” JP with a Sidoti Seal check valve and set in sliding sleeve. 5. RDMO. Attachments: Current Wellbore Schematic _____________________________________________________________________________________ Revised By: TDF 1/24/2024 SCHEMATIC Milne Point Unit Well: MP F-65 Last Completed: 12/31/2023 PTD: 197-049 TD =16,853(MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13’ DF to Tbg.Spool =28.5’ (Nabors 22E) 7” 5 7 9-5/8” 3 4 KUP A Sands PBTD =16,755’(MD) / PBTD =7,729’(TVD) 6X 1 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP BTC 3.958 Surface 16,213’ JEWELRY DETAIL No Depth Item 1 271’ X-Nipple – ID=3.813 2 3,247’ GLM 4-1/2" x 1" with BK-DCK Valve – 3,000' TVD 3 16,048’ Viking XD Sliding Sleeve – ID=3.813” 4 16,106’ Tri-Point 7” x 4-1/2” Perm Packer 5 16,165’ 4-1/2” XN-Nipple (3.813” No-go ID) 6 16,175’ WLEG – Btm @ 16,213’ 7 16,430’ CIBP PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Open Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Open Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,767 sx PF “E”, 800 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle = 77 deg. Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 ESP RWO w/ ASR#1 – 11/29/2021 4-1/2” Sliding Sleeve Completion by ASR – 12-31-2023 STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Jet Pump Temp Production 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 16,853' N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KUPARUK RIVER OIL N/A 7,819' 16,755' 7,729' 1,829 N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT F-65 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 4/1/2024 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509, ADL0355017 & ADL0355018 197-049 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22752-00-00 Hilcorp Alaska LLC C.O. 432E Length Size Proposed Pools: 110' 110' 12.6 / L-80 / TXP BTC TVD Burst 16,213 MILNE POINT MD N/A 5,750psi 7,240psi 4,633' 7,807' 8,604' 16,840' 110' 20" 9-5/8" 7" 8,573' 16,812' Tripoint Perm 7" x 4-1/2" and N/A 16,106 MD/ 7,152 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic See Schematic 4-1/2" No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 8:08 am, Apr 01, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.04.01 08:01:14 - 08'00' Taylor Wellman (2143) MGR03APR24 SFD 4/1/2024 10-404 * Approved for 90 days of production with 24/7 man watch with jet pump utilizing the Sidoti check. * Kill line piping and 1.5 wellbore volumes of KWF to be stored on MPU F PAD. JLC 4/5/2024 Well: MPF-65 PTD: 197-049 API: 50-029-22752-00-00 Well Name:MPF-65 API Number:50-029-22752-00-00 Current Status:Producer Rig: Estimated Start Date:4/5/2024 Estimated Duration:1 days Regulatory Contact:Tom Fouts Permit to Drill Number:197-049 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: TBD, currently drilling the sidetrack. Max Potential Surface Pressure: TBD Gas Column Gradient (0.1 psi/ft) Max Angle:77° @ 10,950 MD Brief Well Summary: MPU F-65 was drilled in January 1996 and completed in March 1996 as a Kuparuk producer. The well has been an ESP production well with ESP change outs as follows: March 1996 (initial), October 2001, February 2006, December 2012 and February 2017. Injection support was resumed in May 2021 to offset voidage. The ESP failed during a power bump that shut down Milne Point October 2021. November 2021 the ESP was replaced. February 2024 F-65 was sidetracked with CTD to drill the multilaterals F-65L1 and F-65L1-01. We currently drilling the F-65L1-01. When kicking off the billet from the F-65L1 lateral it appeared we milled up a large amount of the aluminum billet because we got back a significant amount of aluminum cuttings. Throughout the F-65L1-01 drilling process we had to make frequent trips to keep the hole clean. As a result, we believe a period of jet pump production will allow us to clean up the new laterals before installing the ESP completion. Hilcorp is requesting permission to produce this well as a jet pump completion for up to 90 days. Hilcorp is also requesting a variance from 20 AAC 20.265 for the SSSV in the tubing. Hilcorp will manwatch the well 24/7 during Jet pump operations. The IA will be isolated with the use of a Sidoti check valve in the jet pump. Objectives: Produce the well on JP for 90 days to clean up the well prior to installing the ESP completion. Notes Regarding Wellbore Condition: 7 IA tested to 2,178 psi @ 16,106 on 1/10/24 Procedure Full bore 1. Rig up kill line and have 1.5x wellbore volume of kill weight fluid available at the MI plant in Prudhoe for emergency bullhead operations. 2. 24/7 manwatch during Jet pump operations Full bore 1. RU pump truck pressure test lines to 3,500 psi. 2. MIT-IA to max PF pressure of 3,200 psi for 30 min, charted. 3. Bleed off pressure. RDMO. Slickline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer to the x-nipple at 16,165MD. 3. RIH shift sliding sleeve open @ 16,048 MD. KWF store on MPU F-pad. - mgr Well: MPF-65 PTD: 197-049 API: 50-029-22752-00-00 4. RIH with 3 JP with a Sidoti Seal check valve and set in sliding sleeve. 5. RDMO. Attachments: Current Wellbore Schematic _____________________________________________________________________________________ Revised By: TDF 1/24/2024 SCHEMATIC Milne Point Unit Well: MP F-65 Last Completed: 12/31/2023 PTD: 197-049 TD =16,853(MD) / TD =7,819(TVD) 20 7x 42.21Marker Joint from 16,218 to 16,260 Orig. KB Elev.: 42.3/ Orig. GL Elev.: 13 DF toTbg.Spool=28.5 (Nabors 22E) 7 5 7 9-5/8 3 4 KUP A Sands PBTD =16,755(MD) / PBTD =7,729(TVD) 6X 1 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP BTC 3.958 Surface 16,213 JEWELRY DETAIL No Depth Item 1 271 X-Nipple ID=3.813 2 3,247 GLM 4-1/2" x 1" with BK-DCK Valve 3,000' TVD 3 16,048 Viking XD Sliding Sleeve ID=3.813 4 16,106 Tri-Point 7 x 4-1/2 Perm Packer 5 16,165 4-1/2 XN-Nipple (3.813 No-go ID) 6 16,175 WLEG Btm @ 16,213 7 16,430 CIBP PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454 16,460 7,458 7,463 6 3/1/2005 Open Kup. A Sands 16,471 16,491 7,473 7,491 20 4/1997 Open Kup. A Sands 16,498 16,526 7,497 7,522 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56, TTP= 12.89) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24 Hole 9-5/8" Cmt w/ 1,767 sx PF E, 800 sx Class G in 12-1/4 Hole 7 Cmt w/ 300 sks Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 300 to 4,000 77 deg. f/ 4,000 to 14,500 Max Hole Angle = 77 deg. Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16 Wellhead 11 x 7-1/16 5M FMC Gen 5A, w/ 2-7/8 FMC Tbg. Hngr. Tbg Hngr 3 LH ACME Lift Thread, 2-1/2 BPV CIW H Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations 4/1997 ESPR WO w/ Nabors 4ES 7/2/2001 ESP RWO w/ Nabors 4ES 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES 3/2/2005 ESP RWO w/ Nabors 4ES 9/18/2009 ESP RWO w/ Nabors 4ES 10/11/2010 ESP RWO w/ ASR#1 11/29/2021 4-1/2 Sliding Sleeve Completion by ASR 12-31-2023 STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Cut Tubing Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Completion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 16,853' N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi L1 N/A L1-01 N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Tri-Point 7" x 4-1/2" and N/A 16,106' MD / 7,152 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 2-7/8" 6.5# / L-80 / EUE 8rd ±16,081' ±18,574' Perforation Depth MD (ft): ±18,719' See Schematic ±1,959' See Schematic 4-1/2" ±TBD2-7/8" 110' 20" 9-5/8" 7" 8,573' 3-1/2 / 3-1/4 / 2-7/8±2,544' 16,812' MD N/A N/A 5,750psi 7,240psi 4,633' 7,807' ±TBD 8,604' 16,840' Length Size Proposed Pools: 110' 110' 12.6# / L-80 / TXP BTC TVD Burst 16,213' N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509, ADL0355017 & ADL0355018 223-121 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22752-60-00 Hilcorp Alaska LLC C.O. 432E AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 4/1/2024 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT F-65L1 MILNE POINT KUPARUK RIVER OIL N/A 7,819' 16,755' 7,729' 1,829 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Coldiron at 1:59 pm, Mar 08, 2024 324-153 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.03.08 13:52:48 - 09'00' Taylor Wellman (2143) SFD 197-049 * * See attached email from R. Lewis dated 3/20/2024 SFD 10-404 MGR21MAR24 1,829 SFD 50-029-22752-00-00 * SFD 3/20/2024 DSR-3/11/24 * BOPE test to 2500 psi. MPU F-65 * SFD SFD JLC 3/21/2024 Well: MPF-65 PTD: 223-121 API: 50-029-22752-60-00 Well Name:MPF-65L1 API Number:50-029-22752-60-00 Current Status:Producer Rig:ASR Estimated Start Date:4/1/2024 Estimated Duration:5 days Regulatory Contact:Tom Fouts Permit to Drill Number:197-049 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 2,438 psi @ 6,086 TVD SBHP 11/10/21 | 7.9 PPGE Max Potential Surface Pressure: 1,829 psi Gas Column Gradient (0.1 psi/ft) Max Angle:77° @ 10,950 MD Brief Well Summary: MPU F-65 was drilled in January 1996 and completed in March 1996 as a Kuparuk producer. The well has been an ESP production well with ESP change outs as follows: March 1996 (initial), October 2001, February 2006, December 2012 and February 2017. Injection support was resumed in May 2021 to offset voidage. The ESP failed during a power bump that shut down Milne Point October 2021. November 2021 the ESP was replaced. February 2024 the well was sidetracked with CTD North for a pilot hole across a fault into and untapped fault. Afterwards it will be openhole sidetracked to an unswept fault block to the West. Both laterals were completed with slotted liner. Objectives: 1. Pull 4-1/2 completion. 2. Run 2-7/8 ESP completion Notes Regarding Wellbore Condition: 7 IA tested to 2,178 psi @ 16,106 on 1/10/24 Pre-Rig Procedure (Non Sundried Work) Wireline 1. RU slickline, pressure test PCE to 250psi low / 2,500psi high. 2. Drift and tag with sample bailer. 3. RIH with Well Tec mechanical cutter and tie in on depth with the liner tally and cut in the full joint between the packer and sliding sleeve, +-16,081. 4. RDMO. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 barrel returns tank. 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 197-049 SFD Well: MPF-65 PTD: 223-121 API: 50-029-22752-60-00 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 2,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8 and 4-1/2 test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Install casing jacks on top of BOP stack and function test. 5. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 6. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an FMC 11 x 4-1/2, with 4-1/2 EUE thread. b. Tubing PU weight on ASR #1 estimated to be 177kip. Slack off weight recorded as 42 kip. c. 4-1/2 12.6#,L-80, TXP-BTC yield is 288 kip. 7. Confirm hanger free, lay down tubing hanger. 8. Utilize casing jacks to unseat and pull 4-1/2 tubing. a. Use casing jacks until comfortably under the pulling limitations of the ASR and swap over to using the ASR elevators. 9. POOH and lay down the 4-1/2 tubing. a. Save all the tubing for re-use in the future. 10. RIH with new 2-7/8 6.5# L-80 ESP completion to +/- 16,000 and obtain string weights. a. Check electrical continuity every 1000. b. Note PU and SO weights on tally. c. Install ESP clamps per Baker, and cross coupling clamps every other joint. Nom. Size Length Item Lb/ft Material Notes 5.85 2 Centralizer 4 4.5 2 Intake Sensor 30 5.62 34 Motor - 350HP 80 5.2 7 Lower Tandem Seal 38 5.2 7 Upper Tandem Seal 38 197-049 SFD Well: MPF-65 PTD: 223-121 API: 50-029-22752-60-00 5.2 8 Gas Separator 52 5.38 14 GINPSHH 20 stage 45 5.38 57 Pumps Flex-47, 93 stages 45 1 Ported Discharge Head 13 L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 XN-nipple 2.313" / 2.505" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 15,500 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, 1/4" OV 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 11. Land tubing hanger. Use extra caution to not damage cable. 12. Lay down landing joint. 13. Set BPV. 14. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic 197-049 SFD _____________________________________________________________________________________ Revised By: TDF 1/24/2024 SCHEMATIC Milne Point Unit Well: MP F-65 Last Completed: 12/31/2023 PTD: 197-049 TD =16,853(MD) / TD =7,819(TVD) 20 7x 42.21Marker Joint from 16,218 to 16,260 Orig. KB Elev.: 42.3/ Orig. GL Elev.: 13 DF toTbg.Spool=28.5 (Nabors 22E) 7 5 7 9-5/8 3 4 KUP A Sands PBTD =16,755(MD) / PBTD =7,729(TVD) 6X 1 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP BTC 3.958 Surface 16,213 JEWELRY DETAIL No Depth Item 1 271 X-Nipple ID=3.813 2 3,247 GLM 4-1/2" x 1" with BK-DCK Valve 3,000' TVD 3 16,048 Viking XD Sliding Sleeve ID=3.813 4 16,106 Tri-Point 7 x 4-1/2 Perm Packer 5 16,1165 4-1/2 XN-Nipple (3.813 No-go ID) 6 16,175 WLEG Btm @ 16,213 7 16,430 CIBP PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454 16,460 7,458 7,463 6 3/1/2005 Open Kup. A Sands 16,471 16,491 7,473 7,491 20 4/1997 Open Kup. A Sands 16,498 16,526 7,497 7,522 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56, TTP= 12.89) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24 Hole 9-5/8" Cmt w/ 1,767 sx PF E, 800 sx Class G in 12-1/4 Hole 7 Cmt w/ 300 sks Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 300 to 4,000 77 deg. f/ 4,000 to 14,500 Max Hole Angle = 77 deg. Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16 Wellhead 11 x 7-1/16 5M FMC Gen 5A, w/ 2-7/8 FMC Tbg. Hngr. Tbg Hngr 3 LH ACME Lift Thread, 2-1/2 BPV CIW H Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations 4/1997 ESPR WO w/ Nabors 4ES 7/2/2001 ESP RWO w/ Nabors 4ES 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES 3/2/2005 ESP RWO w/ Nabors 4ES 9/18/2009 ESP RWO w/ Nabors 4ES 10/11/2010 ESP RWO w/ ASR#1 11/29/2021 4-1/2 Sliding Sleeve Completion by ASR 12-31-2023 STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned _____________________________________________________________________________________ Revised By: TDF 3/5/2024 PROPOSED Milne Point Unit Well:MP F-65L1 Last Completed: TBD PTD:223-121 L1-01 Slotted 2-7/8 18,574 6 20 7 x 42.21 Marker Joint from 16,218 to 16,260 Orig. KB Elev.: 42.3/ Orig. GL Elev.: 13 DF to Tbg. Spool = 28.5 (Nabors 22E ) 7 5 4 9-5/8 3 3.70 DPY SLV @ 16175 X 4-1/2x7 Whipstock set @ 16415 3.5 X 3.25 XO @ 16,400 3.25 X 2.875 XO @ 16,615 L1 - Slotted 2-7/8 18719 Aluminum Billet 16615 7 1 2 4 5 & 6 11 7 & 8 9 & 10 12 44 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840 L1: 3-1/2x 3-1/4x2-7/8Liner 9.3/6.6/6.5 / L-80 / STL/TCII/H511 2.992 ±16,175 ±18,719 L1-01: 2-7/8 Liner 6.25 / L-80 / H511 2.441 ±16,615 ±18,574 TUBING DETAIL 2-7/8 Tubing 6.5# / L-80 / EUE 8rd 2.441 Surface ±16,081 4-1/2" Tubing 12.6 / L-80 / TXP BTC 3.958 ±16,08116,213 JEWELRY DETAIL No Depth Item 1 ±XXX Sta #2: 2-7/8" x 1" GLM, 1/4" OV 2 ±XX,XXX Sta #1: 2-7/8" x 1" GLM, DV installed 3 ±XX,XXX XN-nipple 2.313" / 2.505" No-Go 4 ±XX,XXX Ported Discharge Head 5 ±XX,XXX Pump #2: Flex 47 6 ±XX,XXX Pump #1: Flex 93 7 ±XX,XXX GINPSHH 20 stage 8 ±XX,XXX Gas Separator 9 ±XX,XXX Upper Tandem Seal 10 ±XX,XXX Lower Tandem Seal 11 ±XX,XXX Motor - 350HP 12 ±XX,XXX Intake Sensor & Centralizer: Btm @ ±16,000 13 16,106 Tri-Point 7 x 4-1/2 Perm Packer 14 16,165 4-1/2 X-Nipple (3.813 No-go ID) 15 16,175 WLEG Btm @ ±16,200 16 16,430 CIBP OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24 Hole 9-5/8" Cmt w/ 1,767 sx PF E, 800 sx Class G in 12-1/4 Hole 7 Cmt w/ 300 sks Class G in 8-1/2 Hole WELL INCLINATION DETAIL KOP @ 300 Max Hole Angle = 77 deg. L1 KOP @ 16,415' L1-01 KOP @ 16,615 TREE & WELLHEAD Tree 5M CIW 2-9/16 Wellhead 11 x 7-1/16 5M FMC Gen 5A, w/ 2-7/8 FMC Tbg. Hngr. Tbg Hngr 3 LH ACME Lift Thread, 2-1/2 BPV CIW H Profile GENERAL WELL INFO API: 50-029-22752-60-00 / -60-00 / -61-00 L1 & L1-01 CDR2: TBD PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status F-65: A Sands 16,454 16,460 7,458 7,463 6 3/1/2005 Open F-65: A Sands 16,471 16,491 7,473 7,491 20 4/1997 Open F-65: A Sands 16,498 16,526 7,497 7,522 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56, TTP= 12.89) F-65L1: F-65L1-01: 197-049 SFD Milne Point ASR Rig 1 BOPE 2023 11 BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8 x 5 VBR 1 Davies, Stephen F (OGC) From:Ryan Lewis <ryan.lewis@hilcorp.com> Sent:Wednesday, March 20, 2024 8:06 AM To:Davies, Stephen F (OGC) Cc:Dewhurst, Andrew D (OGC); Rixse, Melvin G (OGC); Tom Fouts Subject:RE: [EXTERNAL] MPU F-65L1 (PDT 223-121, Sundry 324-153) - Question You are completely jus ed; this is a poorly wri en Well Summary. To clarify: Is F 65L1 the pilot hole men oned in the summary above? (Note that the term pilot hole typically refers to an expendable sec on drilled to gain stra graphic or uid informa on and then immediately plugged back.) F 65L1 I refer to as a pilot hole b/c had it been all water when we crossed the fault, our plan would have been to plug it back and kicked o to drill F 65L1 01. Once we crossed the fault it contained oil, we ran a slo ed liner. Has F 65L1 been drilled? Yes, TDed on 3/7/24. Has F 65L1 01 been drilled? Currently drilling Has either wellbore been completed with slo ed liner? If so, which one(s)? Yes F 65L1 has an open hole slo ed liner deployed. We stacked a billet on top and kicked o to drill F 65L1 01. Will the original F 65 well s ll contribute to produc on or have the perfora ons or slo ed liner within F 65 been plugged and abandoned or otherwise isolated? F 65 perfora ons have been isolated with a CIBP but we plan to run slo ed liner back up to the F 65 parent bore to drain that same area. If the original F 65 well will con nue to contribute to produc on, shouldnt this Sundry Applica on for an ESP comple on be for well F 65 rather than the lateral branch F 65L1? You are correct, this sundry should have been submi ed under the F 65 PTD 197 049. Would you prefer to redline this one otherwise I am happy to withdraw this one, correct the grammar, well name PTD and resubmit. Thanks, RL From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Tuesday, March 19, 2024 2:25 PM To: Ryan Lewis <ryan.lewis@hilcorp.com> Cc: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] MPU F 65L1 (PDT 223 121, Sundry 324 153) Question Ryan, Im reviewing Hilcorps Sundry Applica on and I admit Im confused. The well summary within the applica on begins by discussing the history of the F 65 original well up to November 2021 when the ESP was replaced. The next part of the summary con nues: CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Im confused by the changing past and future tenses of the verbs. I gather that in February the F 65L1 lateral was drilled as a branch from the F 65 well, and that the F 65L1 01 wellbore is being (or will be) drilled as a branch from F 65L1. (Note that the last sentence of the summary reads Both laterals were completed with slo ed liner.) Or am I not understanding this correctly? To clarify: Is F 65L1 the pilot hole men oned in the summary above? (Note that the term pilot hole typically refers to an expendable sec on drilled to gain stra graphic or uid informa on and then immediately plugged back.) Has F 65L1 been drilled? Has F 65L1 01 been drilled? Has either wellbore been completed with slo ed liner? If so, which one(s)? Will the original F 65 well s ll contribute to produc on or have the perfora ons or slo ed liner within F 65 been plugged and abandoned or otherwise isolated? If the original F 65 well will con nue to contribute to produc on, shouldnt this Sundry Applica on for an ESP comple on be for well F 65 rather than the lateral branch F 65L1? Thanks and Be Well, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e mail message, including any a achments, contains informa on from the Alaska Oil and Gas Conserva on Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain con den al and/or privileged informa on. The unauthorized review, use or disclosure of such informa on may violate state or federal law. If you are an unintended recipient of this e mail, please delete it, without rst saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907 793 1224 or steve.davies@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Install Completion Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 16,853 feet 16,430 feet true vertical 7,819 feet N/A feet Effective Depth measured 16,755 feet 16,106 feet true vertical 7,729 feet 7,152 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / L-80 / TXP BTC 16,213' 7,245' Packers and SSSV (type, measured and true vertical depth)7'' x 4 1/2'' Tri-Point Perm N/A See Above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Wells Manager Contact Phone: N/A Ryan Lewis 323-646 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ryan.lewis@hilcorp.com 303-906-5178 400 Size 110' 4,633' 113 35982410 Water-BblOil-Bbl Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0000 MILNE PT UNIT F-65 Plugs Junk measured Length measured true vertical Packer MD measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 197-049 50-029-22752-00-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025509, ADL0355017 & ADL0355018 MILNE POINT / KUPARUK RIVER OIL Collapse N/A 3,090psi 5,410psi Casing Conductor 16,812' 8,604'Surface Production 20" 9-5/8" 7" 110' 8,573' 110' 5,750psi 7,240psi16,840' 7,807' Burst N/A Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:32 pm, Mar 05, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.03.04 16:17:45 - 09'00' Taylor Wellman (2143) DSR-3/5/24WCB 2024-07-08 RBDMS JSB 031324 _____________________________________________________________________________________ Revised By: TDF 1/24/2024 SCHEMATIC Milne Point Unit Well: MP F-65 Last Completed: 12/31/2023 PTD: 197-049 TD =16,853(MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13’ DF to Tbg.Spool =28.5’ (Nabors 22E) 7” 5 7 9-5/8” 3 4 KUP A Sands PBTD =16,755’(MD) / PBTD =7,729’(TVD) 6X 1 2 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP BTC 3.958 Surface 16,213’ JEWELRY DETAIL No Depth Item 1 271’ X-Nipple – ID=3.813 2 3,247’ GLM 4-1/2" x 1" with BK-DCK Valve – 3,000' TVD 3 16,048’ Viking XD Sliding Sleeve – ID=3.813” 4 16,106’ Tri-Point 7” x 4-1/2” Perm Packer 5 16,1165’ 4-1/2” XN-Nipple (3.813” No-go ID) 6 16,175’ WLEG – Btm @ 16,213’ 7 16,430’ CIBP PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Open Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Open Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,767 sx PF “E”, 800 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle = 77 deg. Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 ESP RWO w/ ASR#1 – 11/29/2021 4-1/2” Sliding Sleeve Completion by ASR – 12-31-2023 STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 ASR#1 50-029-22752-00-00 197-049 12/19/2023 1/31/2024 Rig Accepted at 0800 HRS. Continue prep equipment to test BOP's. BOPE testing to 5,000 psi for new stack. Extended testing time due to proof testing BOPE. Install test joint. Test BOP's 250 /5000 PSI - New BOP stack. Test pump isolation valves found to be leaking by. Disassembly manifold & change out valves. Finished assembling manifold. Begin filling for BOPE test. No operations to report. 12/16/2023 - Saturday No operations to report. 12/19/2023 - Tuesday 12/17/2023 - Sunday No operations to report. 12/18/2023 - Monday 12/15/2023 - Friday No operations to report. 12/13/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 12/14/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 ASR #1 50-029-22752-00-00 197-049 12/19/2023 1/31/2024 Perform successful CSG test 3,000psi/30min charted. POOH w/ BOT "J" Hydraulic Setting Tool from 16,290' to 8,000' while maintaining 1x displacement. Set BOT 7" Storm Valve @ 15' from CSG Head & test to 3,000psi/30min. Replace 11" x 7-1/16" TBG Spool w/ 11" x 11". NU BOPE. E-Line: Continue RIH w/ BOT 6.00" Round Nose Bit & 7" Scraper BHA while maintaining 2x displacement. Reciprocate BHA in WS/CIBP setting interval 16,400 - 16,430'. FWD circulate 122 bbls up to 3.5 bpm @ 800 psi. Unable to achieve desired 4-5 bpm rate due to pump problems. Reverse circ. 86 bbls - 4 bpm @ 500psi before pump failed. POOH w/ BHA while maintaining 2x displacement from 16,430' to 3,437'. 12/23/2023 - Saturday Cont. RIH w/ BOT "J" Hydraulic Setting Tool & "K-1" CIBP while maintaining 2x displacement from 11,027' to 16,430' MD. Spot in 492 bbls 1% KCL w/ CI & NSX lube. Drop ball & set CIBP @ 16,429.90' MD. Begin pressuring up for MIT-IA. Fullbore: Assist ASR, Pumped 70 bbls Source Water down Tubing to set ball, Pumped 3 bbls Source Water down Tubing to set Plug, Pumped 4.5 bbls Source Water down Tubing to Pressure up to 3000 psi for test. 12/26/2023 - Tuesday 12/24/2023 - Sunday POOH/LD BOT 6.00" Round Nose Bit & 7" Scraper BHA while maintaining 2x displacement from 3,437'. MU/RIH w/ BOT "J" Hydraulic Setting Tool & "K-1" CIBP while maintaining 2x displacement to 11,027' PUW = 48K | SOW = 31K. 12/25/2023 - Monday 12/22/2023 - Friday Continue RIH w/ BOT 6.00" Round Nose Bit & 7" Scraper BHA while maintaining 2x displacement from 1,272' to 14,310'. 12/20/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary ASR #1: Cont. to BOPE testing to 5,000 psi for new stack. Extended testing time due to proof testing BOPE. Change out choke manifold valve. Pull tubing hanger to rig floor. Initial up weight - 130K. Slack off and work string to observed up weight fall to 110K, pumping lubricated fluid down the IA. Breakout & lay down hanger, well on a vac. Pumped 30 BBLS down the IA, did not top off the well. 10 BBLS down the tbg. Prep ESP cable to pull over sheave and spool on the spolling unit. POOH with 2 7/8 ESP completion from 16320' to 10,560' spooling ESP cable, removing clamps. Pumping double displacement. WELLHEAD: Set BPV after well kill N/D tree/adapter set CTS plug and tested 500 low 5000 high 5/10 min test good S/B for MIRU. After BOP test P/U Tbar pulled CTS plug and BPV well on a vac, M/U landing joint to hanger BOLDS offseat hanger at 60k and pulled to floor then B/O of string and layed down. 12/21/2023 - Thursday CONT POOH w/ 2-7/8" ESP Completion from 10,740' spooling ESP cable, removing clamps. Pumping double displacement. LD ESP - All motors spinning freely, fluid appears good, no scale or sand. Transition equipment for running. RIH w/ BOT 6.00" Round Nose Bit & 7" Scraper BHA while maintaining 2x displacement to 1,272'. Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 ASR #1 50-029-22752-00-00 197-049 12/19/2023 1/31/2024 12/29/2023 - Friday Redress Kill side Blind Ram. Function and test BOPE 250/2500psi - Good. Retrieve Test Plug & Storm Packer. POOH w/ 2-7/8" Workstring, BOT "J" Hydraulic Setting Too from 8,273' to 3,873' while pumping 1x displacement. 12/27/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Test BOPE w/ 2-7/8" Test Joint - Good. Troubleshoot leaking 2-7/8" x 5" VBR Rams w/ 4-1/2" Test Joint. Replaced seals with new, same result. Discovered 4-1/2" Test Joint interface area to be egged, scarred, and undersized. 12/28/2023 - Thursday Continue troubleshooting BOP issues. RD all equipment necessary to remove and replace BOP. NU BOP, RU all equipment. Function test BOPE. Blind Ram cylinder leaking, apply heat and cycle valve w/out success. Mobilize Yellow Jacket Techs. No operations to report. POOH & LD 2-7/8" Workstring, BOT "J" Hydraulic Setting Tool from 3,873' while pumping 1x displacement. RIH w/ 4-1/2" completion "XX" plug installed in the lowest X-Nipple (Floating completion in) to 8,271' MD. PUW = 30K | SOW = 20K - Dry weight ~104,214# 12/30/2023 - Saturday LRS Assist ASR: Freeze Protect IA and TBG. Pumped 110 bbls diesel down the IA (10 bbls to reach max pressure 2550 psi to sheer the sheer valve) up the TBG. Pump 8.4ppg Source Water to fill TBG and allow air to migrate to surface. TBG full w/ 88 BBLS short of volume, monitor well 1hr, IAP rises to 65psi. Bleed IAP through Gas Buster & TBG fluid level dropped immediatley. Confer w/ OE. LRS Sheared GLV & FP IA & TBG w/out setting Packer. Install BPV. RELEASE RIG @ 06:00. WELLHEAD: BOP removed, clean hgr void, install RX54 gasket and SBMS metal seal. Land tree/adapter, torque to spec and test void 500/5000 (PASS). Pull Bpv with dry rod. QAll valves closed. 1/2/2024 - Tuesday 12/31/2023 - Sunday Continue RIH w/ 4-1/2" completion "XX" plug installed in the lowest X-Nipple (Floating completion in) from 8,271' to 16,213.17' (EOT) Pump 8.4ppg Source Water to fill TBG and allow air to migrate to surface. Monitor well. LRD: Assist ASR (Freeze Protect) Spot unit, heat diesel, SB for Rig. WELLHEAD: MU LJwith 4 1/2 563 to Tbg Hgr and MU to comp. string. Five ft into profile 16.20' RILDS and pull LJ. RIG pumping and Packer test, set BPV. 1/1/2024 - Monday WELLHEAD: MU LJwith 4 1/2 563 to Tbg Hgr and MU to comp. string. Five ft into profile 16.20' RILDS and pull LJ. RIG pumping and Packer test, set BPV. Continue RIH w/ 4-1/2" completion "XX" plug installed in the lowest X-Nipple (Floating completion in Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 Slickline 50-029-22752-00-00 197-049 12/19/2023 1/31/2024 RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 8' x 1-7/8" ROLLER STEM (2.60" whls), KJT 5' x 1-7/8" ROLLER STEM (2.60" whls), OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good). BLEED PRESSURE BACK TO ZERO.RAN 4-1/2" BRUSH, 3.50" GAUGE RING OUT TUBING TAIL AT 16,250' SLM (No issues). MAKE 2 ATTEMPTS TO SET 4-1/2" PX PLUG IN X-NIPPLE AT 16,165' MD (See log). RAN 4-1/2" BRUSH, 3.80" GAUGE RING OUT TUBING TAIL AT 16,250' SLM (No issues). No operations to report. 1/6/2024 - Saturday RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 8' x 1-7/8" ROLLER STEM (2.60" whls), KJT 5' x 1-7/8" ROLLER STEM (2.60" whls), OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (good). BLEED BACK PRESSURE BEFORE STABBING ON. PULL DCK-SHEAR VALVE FROM ST#1 (3,247' md). SET BK-DGLV AT ST#1 (3,247' md). 1ST ATTEMPT PRESSURE TEST IA TO 500psi (failed, see log). RAN 4-1/2" 42BO TO VIKING-SD AT 16,048' SLM (Appears closed). 2ND ATTEMPT PRESSURE TEST IA TO 500psi (failed, see log). EQUALISE AND PULL 4-1/2" XX PLUG BODY FROM X- NIPPLE AT 16,165' MD (see log for plug details). 1/9/2024 - Tuesday 1/7/2024 - Sunday No operations to report. 1/8/2024 - Monday 1/5/2024 - Friday No operations to report. 1/3/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/4/2024 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 FB & SL 50-029-22752-00-00 197-049 12/19/2023 1/31/2024 1/12/2024 - Friday No operations to report. 1/10/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary RIG-UP .125 CARBON WIRE. TS = 1.75" RS, 10' x 2-5/8" ROLLER STEM (3.50" whls), OJ, KJT LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good). SET 4-1/2" RHC IN X-NIPPLE AT 16,165' MD. DEPLOY BALL&ROD FROM SURFACE TO RHC IN X-NIPPLE AT 16,165' MD. PERFORM PASSING PRESSURE TEST ON TUBING TO 600psi (See log). LRS SET PACKER WITH 4000psi FOR 5 MINUTES (See log). LRS PERFORMED PASSING MIT-T TO 3900psi (see log). LRS PERFORMED PASSING MIT-IA TO 2000psi (See log). PULL BALL&ROD FROM RHC IN X-NIPPLE AT 16,165' MD. 1/11/2024 - Thursday WELL S/I ON ARRIVAL. BEGIN R/U .125 CARBON, 1-7/8'' RS, QC, 5' X 2-5/8'' RS (3.50'' wheels), QC, 5' X 2-5/8'' RS (3.50'' wheels), QC, OJ, QC, KJ, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. PULL RHC @ 16222' SLM / 16165' MD. WELL S/I ON DEPARTURE. No operations to report. No operations to report. 1/13/2024 - Saturday WELL SHUT IN UPON ARRIVAL. PT 250/2500. RAN 20' X 3.70" DUMMY WHIPSTOCK, TOOLS FALLING SLOW, SD @8581' SLM. RAN KJ, BLB, 3.69" GAUGE RING, NO ISSUES @8,581' SLM, TAG CIBP @16,403' SLM (16,430' MD). WELL S/I ON DEPARTURE. 1/16/2024 - Tuesday 1/14/2024 - Sunday No operations to report. 1/15/2024 - Monday SET 4-1/2" RHC IN X-NIPPLE AT 16,165' MD. DEPLOY BALL&ROD FROM SURFACE TO RHC IN X-NIPPLE AT 16,165' MD. PERFORM PASSING PRESSURE TEST ON TUBING TO 600psi (See log). LRS SET PACKER WITH 4000psi FOR 5 MINUTES (See log). LRS PERFORMED PASSING MIT-T TO 3900psi (see log). LRS PERFORMED PASSING MIT-IA TO 2000psi (See log). PULL BALL&ROD FROM RHC IN X-NIPPLE AT 16,165' MD. Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 FB & SL 50-029-22752-00-00 197-049 12/19/2023 1/31/2024 1/19/2024 - Friday WELL S/I ON ARRIVAL. BEGIN R/U .125 CARBON, 1-7/8'' RS, 3' X 2-1/8'' RS (3.5'' wheels), QC, 8' X 2-5/8'' STEM, QC, LSS, CHECK ALL ROLL PINS, TIGHTEN ALL CONN. w/ WRENCHES, PT= 250L / 3500H. RAN HES 40 ARM CALIPER, LOG FROM 16487' SLM TO 15800' SLM (good data). WELL S/I ON ARRIVAL. 1/17/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/18/2024 - Thursday WELL S/I ON ARRIVAL. SPOT IN CRANE & BEGING RIGGING BACK UP, PT= 250L / 3500H. RAN X-WING MAGNETS DOWN TO EOT @ 16174' MD (lost 1 wheel 1'' X .4 & roll pin). RAN 3.70'' GAUGE TAG @ 16,487' SLM. RAN 20' X 4-1/2 DUMMY WHIPSTOCK, TOOLS STOP FALLING @ 8591' SLM WAS ABLE TO GET MOVING & STOPPED FALLING @ 8630' SLM, COULDN'T GET ANY DEEPER. WELL S/I ON DEPARTURE. No operations to report. No operations to report. 1/20/2024 - Saturday No operations to report. 1/23/2024 - Tuesday 1/21/2024 - Sunday No operations to report. 1/22/2024 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 ASR #1 50-029-22752-00-00 197-049 12/19/2023 1/31/2024 MIRU CTU #1. No operations to report. 1/27/2024 - Saturday No operations to report. 1/30/2024 - Tuesday 1/28/2024 - Sunday No operations to report. 1/29/2024 - Monday 1/26/2024 - Friday No operations to report. 1/24/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/25/2024 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP F-65 CTU #1 50-029-22752-00-00 197-049 12/19/2023 1/31/2024 No operations to report. No operations to report. 2/3/2024 - Saturday No operations to report. 2/6/2024 - Tuesday 2/4/2024 - Sunday No operations to report. 2/5/2024 - Monday 2/2/2024 - Friday No operations to report. 1/31/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Perform weekly BOP test. Pass. RU NS MHA and BOT 3.70" dummy whip stock drift. Tag 16,444' CTM, POOH, FP well with diesel on way OOH. RDMO. Job complete. 2/1/2024 - Thursday No operations to report. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Alaska NS - CTD DSM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Robert Coyne; Nathan Wheeler; Thomas Henson; Coyne, Cleve; White, Bradley; Alaska NS - CTD DSM Subject:Nabors CDR2-AC Initial BOPE test MPU F-65 Date:Tuesday, February 27, 2024 3:54:21 PM Attachments:Nabors CDR2-AC 02-27-2024.xlsx Initial Test MPU F-65 John Perl Sr. Drilling Foreman – Nabors CDR2 Rig (907) 670-3097 Personal Cell (907) 355-5815 H# 4169 Positional Email AlaskaNS-CTD-DSM@hilcorp.com Alternate: Mark Igtanloc Hilcorp Alaska, LLC The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 0LOQH3RLQW8QLW) 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m itt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:CDR2AC DATE: 2/27/24 Rig Rep.: Coyne / Henson Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #11970490 Sundry #323-667 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:2758 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2P Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 2-3/8"P Trip Tank PP Annular Preventer 1 7 1/16" 5K P Pit Level Indicators PP #1 Rams 1 Blind/Shear P Flow Indicator PP #2 Rams 1 2-3/8" Pipe/Slips P Meth Gas Detector PP #3 Rams 1 3" Pipe/Slips P H2S Gas Detector PP #4 Rams 1 2-3/8" Pipe/Slips P MS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result HCR Valves 2 2-1/16"FP System Pressure (psi)3000 P Kill Line Valves 2 2-1/16"P Pressure After Closure (psi)2250 P Check Valve 0NA200 psi Attained (sec)19 P BOP Misc 2 2.0" Piper P Full Pressure Attained (sec)55 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge: 1006 P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 10 @ 1980 P No. Valves 12 P ACC Misc 0NA Manual Chokes 1FP Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 4 P #1 Rams 4 P Coiled Tubing Only:#2 Rams 3 P Inside Reel valves 1P #3 Rams 3 P #4 Rams 3 P Test Results #5 Rams NA #6 Rams NA Number of Failures:2 Test Time:7.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/25/24 02:28 Waived By Test Start Date/Time:2/26/2024 20:00 (date) (time)Witness Test Finish Date/Time:2/27/2024 3:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nabors F/P on Choke line HCR B4, greased then passed. Manual Choke C fail, was rebuilt then pass. Perl / Kavanagh Hilcorp Alaska, LLC MPU F-65 Test Pressure (psi): robert.coyne@nabors.com alaskans-ctd-dsm@hilcorp.com Form 10-424 (Revised 08/2022) 2024-0227_BOP_Nabors_CDR2AC_MPU_F-65 9 9 9 999 9 99 9 9 9 9 9 -5HJJ FP FP F/P on Choke line HCR B4,Manual Choke C fail Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/8/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240208 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 13-08 50133203040000 177029 10/11/2023 AK E-LINE TUBING CUT KBU 14-6Y 50133205720000 207149 10/24/2023 AK E-Line PLUG/PERF MPU B-28 50029235660000 216027 1/10/2024 HALLIBURTON MFC40 MPU F-65 50029227520000 197049 1/19/2024 HALLIBURTON MFC40 MPU I-12 50029230380000 201163 1/30/2024 HALLIBURTON Coilflag MPU J-08A 50029224970100 199117 1/21/2024 HALLIBURTON Coilflag Please include current contact information if different from above. T38488 T38489 T38490 T38491 T38492 T38493 2/8/2024 MPU F-65 50029227520000 197049 1/19/2024 HALLIBURTON MFC40 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.08 10:05:37 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/3/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240103 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-28 50029235660000 216027 12/27/2023 READ Leak Detection Survey MPU F-65 50029227520000 197049 12/15/2023 READ Caliper Survey PBU W-202 50029234340000 210133 12/5/2023 READ Production Profile Please include current contact information if different from above. T38251 T38252 T38253 1/3/2024 MPU F-65 50029227520000 197049 12/15/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2024.01.03 13:52:25 -09'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT F-65 JBR 01/26/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Test Results TEST DATA Rig Rep:GreubOperator:Hilcorp Alaska, LLC Operator Rep:Haberthur Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:1970490 DATE:12/29/2023 Type Operation:WRKOV Annular: 250/2500Type Test:WKLY Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopRCN231231134719 Inspector Bob Noble Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 2391 Sundry No: 323-646 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 none NA Annular Preventer 1 11"P #1 Rams 1 2 7/8" x 5"P #2 Rams 1 Blinds P #3 Rams 0 none NA #4 Rams 0 none NA #5 Rams 0 none NA #6 Rams 0 none NA Choke Ln. Valves 1 2 1/16"P HCR Valves 1 2 1/16"P Kill Line Valves 3 2 1/16"P Check Valve 0 none NA BOP Misc 0 none NA System Pressure P3000 Pressure After Closure P1500 200 PSI Attained P15 Full Pressure Attained P57 Blind Switch Covers:YAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2250 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P15 #1 Rams P7 #2 Rams P6 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0     CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Alaska NS - ASR - Well Site Managers To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Cc:Scott Heim - (C) Subject:MPF-65 Initial BOPE Test Date:Thursday, December 21, 2023 10:50:12 PM Attachments:MPF-65 Initial BOPE Test.xlsx Please find attached. Thank you, Mike Heinz-Brown | Milne Point | DSM | Hilcorp Alaska Rig Office: 907-685-1266 | Cell: 480-296-5214 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 0LOQH3RLQW8QLW) 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSu bmitt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:ASR 1 DATE: 12/19/23 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1970490 Sundry #323-646 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Other: Rams:250/5000 Annular:250/3500 Valves:250/5000 MASP:2391 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1P Permit On Location P Hazard Sec.P Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 2FP Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank NA NA Annular Preventer 1 11"P Pit Level Indicators PP #1 Rams 1 2-7/8" x 5"P Flow Indicator PP #2 Rams 1 Blind P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result HCR Valves 1 2-1/16"P System Pressure (psi)3000 P Kill Line Valves 3 2-1/16"FP Pressure After Closure (psi)1950 P Check Valve 0NA200 psi Attained (sec)14 P BOP Misc 0NAFull Pressure Attained (sec)53 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 4 / 2275 psi P No. Valves 16 FP ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1P Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 16 P #1 Rams 6 p Coiled Tubing Only:#2 Rams 7 P Inside Reel valves 0NA #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:3 Test Time:13.0 HCR Choke 2 P Repair or replacement of equipment will be made within days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 12/17/23 08:33 Waived By Test Start Date/Time:12/19/2023 8:00 (date) (time)Witness Test Finish Date/Time:12/20/2023 9:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Josh Hunt Hilcorp Tested w/ 2-7/8" & 4-1/2" test joints Bottle average pre-charge = 1000 psi FP #1: TIW Valve #2 - replace Valve FP #2: Choke Manifold Valve #4 - replace Valve FP #3: Kill Line Valve #2 - Grease and service Valve C.Pace | M.Boord Hilcorp Alaska, LLC S.Heim | R.Gallen MPU F-65 Test Pressure (psi): askans-asr-toolpushers@hilcorp.c ans-asrwellsitemanagers@hilcorp Form 10-424 (Revised 08/2022) 2023-1220_BOP_Hilcorp_ASR1_MPU_F-65 MEU 9 99 99 9 99 9 9 9 9 9 9 9 9 9 -5HJJ FP FP FP g TIW Valve #2 Choke Manifold Valve #4 Kill Line Valve #2 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Ryan Lewis Cc:AOGCC Records (CED sponsored) Subject:20231215 1235 Approval PTD: 197049 Sundry 323-646 MPF-65 Prep for CTD sidetrack Date:Friday, December 15, 2023 12:37:44 PM Ryan, Approved to run a CIBP rather than a RBP. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Ryan Lewis <Ryan.Lewis@hilcorp.com> Sent: Friday, December 15, 2023 8:49 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PTD: 197049 Sundry 323-646 MPF-65 Prep for CTD sidetrack Mel- In this procedure I would like to run a CIBP to set at 16,430’ in place of the RBP called out in the sundry. All the testing would be the same. I would leave the CIBP in the well to give us a closed wellbore while we float in the tubing. The changes would only effect line 14 and 24 of the procedure. Sundried steps: 14: MU/RIH with 7” RBP on 2-7/8” 6.5# L-80 tubing and set @ 16,150’. 24: The procedure line 24: RIH and engage RBP. Proposed changes to sundries steps: 14: MU/RIH with 7” CIBP on 2-7/8” 6.5# L-80 tubing and set @ 16,430’ 24: POOH with 2-7/8” 6.5# L-80 tubing, while filling hole with 2x pipe displacement. Read through it and I can answer any questions you may have. Thanks, Ryan Lewis Hilcorp Alaska – Operations Engineer (303) 906-5178 Ryan.lewis@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Drilling Manager 12/13/23 Monty M Myers 323-667 By Grace Christianson at 9:33 am, Dec 13, 2023 10-404 MGR16JAN24 DSR-12/14/23SFD 12/15/2023JLC 1/16/2024 Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.01.16 13:06:28 -09'00'01/16/24 RBDMS JSB 011724 To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz Drilling Engineer Date: December 12, 2023 Re: MPU F-65 Sundry Request Sundry approval is requested to set whipstock and mill window in well MPF-65 as part of the drilling and completion of the proposed MPF-65L1 CTD lateral. Proposed plan for F-65L1 Producer: Prior to drilling activities, a rig workover will pull the ESP completion and run 4-1/2" tubing. Screening will be conducted to MIT and drift for whipstock. E-line will then attempt to set a 4-1/2"x7" flow through whipstock (if not possible, will set with rig). Service Coil will mill the window if a unit is available. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unable to set or mill pre-rig, the rig will set a 4-1/2"x7" flow through whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling and land in the Kuparuk A sands. The lateral will continue in the Kuparuk A to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” L-80 Slotted liner. A RWO will be conducted post rig to cut and pull the 4-1/2" tubing and run a new ESP completion. The following describes the work planned. A wellbore schematic of the current well and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in December 15th) x Reference MPU F-65 Sundry submitted in concert with this request for full details. 1. RWO : Pull ESP completion, Run packer and 4-1/2" tubing, MIT-IA to 3500 psi (Separate Sundry) 2. Slickline : Retrieve XN plug, drift & caliper for whipstock 3. Wireline : Set 4-1/2" x 7" Delta Expandable Whipstock 4. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in February 29, 2024) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,758 psi). 2. Mill 3.80” Window. 3. Drill build section: 4.25" OH, ~194' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~1965' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” L80 Slotted liner. 6. Freeze protect well to a min 2,200' TVDss. 7. Close in tree, RDMO. Post Rig Work: 1. Wireline : Cut tubing above packer. 2. RWO : Pull 4-1/2" tubing 3. RWO : Run ESP completion Sundry 323-667 gg flow through whipstock Future PTD Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Set live GLVs, set LTP* (if necessary). 3. CT : Post rig perforate ~ 1000’ (if not done with CDR2) The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Ryan Ciolkosz CC: Well File Drilling Engineer (907-244-4357) Joseph Lastufka _____________________________________________________________________________________ Revised By: TDF 8/18/2022 SCHEMATIC Milne Point Unit Well: MP F-65 Last Completed: 11/29/2021 PTD: 197-049 TD =16,853(MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13’ DF to Tbg.Spool =28.5’ (Nabors 22E) 7” 3 5 & 6 7 8 9 9 10 9-5/8” 1 2 KUP A Sands PBTD =16,755’(MD) / PBTD =7,729’(TVD) 4 X CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 16,325’ JEWELRY DETAIL No Depth Item 1 186’ Sta #2: 2-7/8” x 1” KBMG GLM w/ DSOV 2 16,080’ Sta #1: 2-7/8” x 1” KBMG GLM w/ Dummy 3 16,199’ 2-7/8” HES XN-Nipple (2.205 No-go ID) 4 16,252’ Discharge Head B/O PMP 513 w/ Zenith Ported Sub: PRESS PORT 513/538P PMP 5 16,253’ Pump #2: 538PMSXD 119 P23 FER NO PNT 6 16,270’ Pump #1: 538PMSXD 54 G31 7 16,283’ Gas Separator Gas Master Extreme 538GS w bolt on intake GPXARCINT FER H6 8 16,289’ Tandem Seal Section – GSB3DBUT SB/SB PFSA & GSB3DBLT SB/SB PFSA CL5 9 16,303’ Motor: KMH 228hp, 2,305 volts and 60 amps 10 16,320’ Sensor: Zenith E7 Motor Gauge w/ Centralizer – Btm @ 16,325’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Open Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Open Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,767 sx PF “E”, 800 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle = 77 deg. Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 ESP RWO w/ ASR#1 – 11/29/2021 STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned _____________________________________________________________________________________ Revised By: JNL 12/11/2023 PROPOSED Milne Point Unit Well: MP F-65 Last Completed: TBD PTD: TBD TD = 16,853’ (MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13.0’ 7” 3 9-5/8” 1 2 PBTD =16,755’(MD) / PBTD = 7,729’(TVD) 4X 4-1/2x7 Whipstock set @ ±16,415’ 5 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ 3-1/2”x 3-1/4”x 2-7/8” Slotted Liner 9.3 / L-80 / STL 6.6 / L-80 / TCII 6.5 / L-80 / H511 2.992 2.805 2.441 16,175’ 18,574’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / EUE 8rd 3.958 Surface ±16,215’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Open Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Open Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 24" 260 sx of Arcticset I (Approx.) 12-1/4" 1,767 sx PF “E”, 800 sx Class “G” 8-1/2” 300 sks Class “G” WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 & 50-029-22752-60-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 ESP RWO w/ ASR#1 – 11/29/2021 L1 Sidetrack by CDR2 - TBD STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned. JEWELRY DETAIL No Depth Item 1 ±16,045’ 3.813” X Sliding Sleeve 2 ±16,130’ 4-1/2” X 7” Pro. Packer 3 ±16,141’ X- Nipple 4 ±16,213’ 4-1/2” Mule Shoe – BTM @ ±16,215’ 5 ±16,415’ 4-1/2”x7” Whipstock _____________________________________________________________________________________ Revised By: JNL 12/11/2023 PROPOSED Milne Point Unit Well: MP F-65L1 Last Completed: TBD PTD: TBD TD = 16,853’ (MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13.0’ 7” 6 3 3-1/2” xo 3-1/4” 9-5/8” 1 2 3-1/4”xo 2-7/8” PBTD =16,755’(MD) / PBTD = 7,729’(TVD) 4X 4-1/2x7 Whipstock set @ ±16,415’ 5 L1 TD = 18,574’ (MD) / TD = 7,492’ (TVD) L1 PBTD = 18,574’ (MD) / PBTD = 7,492’ (TVD) CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ 3-1/2”x 3-1/4”x 2-7/8” Slotted Liner 9.3 / L-80 / STL 6.6 / L-80 / TCII 6.5 / L-80 / H511 2.992 2.805 2.441 16,175’ 18,574’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / EUE 8rd 3.958 Surface ±16,215’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Open Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Open Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 24" 260 sx of Arcticset I (Approx.) 12-1/4" 1,767 sx PF “E”, 800 sx Class “G” 8-1/2” 300 sks Class “G” 4-1/4” Uncemented Slotted Liner WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle L1 KOP @ 16,415’ Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 & 50-029-22752-60-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 ESP RWO w/ ASR#1 – 11/29/2021 L1 Sidetrack by CDR2 - TBD STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned. JEWELRY DETAIL No Depth Item 1 ±16,045’ 3.813” X Sliding Sleeve 2 ±16,130’ 4-1/2” X 7” Pro. Packer 3 ±16,141’ X- Nipple 4 ±16,213’ 4-1/2” Mule Shoe – BTM @ ±16,215’ 5 ±16,415’ 4-1/2”x7” Whipstock Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2.0" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 2-3/8" Pipe / Slip 9.54 ft CL 2.0" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3.0" Pipe / Slip HF nneceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Install Completion 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 16,853'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KUPARUK RIVER OIL N/A 7,819' 16,755' 7,729' 2,391 N/A Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT F-65 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 12/18/2023 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509, ADL0355017 & ADL0355018 197-049 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22752-00-00 Hilcorp Alaska LLC C.O. 432E Length Size Proposed Pools: 110' 110' 6.5# / L-80 / EUE 8rd TVD Burst 16,325' MILNE POINT MD N/A 5,750psi 7,240psi 4,633' 7,807' 8,604' 16,840' 110' 20" 9-5/8" 7" 8,573' 16,812' N/A and N/A N/A and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 Perforation Depth MD (ft): See Schematic See Schematic 2-7/8" No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.11.21 07:33:24 - 09'00' Taylor Wellman (2143) 323-646 By Grace Christianson at 1:55 pm, Nov 29, 2023 10-404 MGR01DEC23 DSR-11/29/23 2,391 SFD 12/11/2023 BOPE test to 2500 psi. *&:JLC 12/11/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.12.11 10:00:03 -09'00'12/11/23 RBDMS JSB 121223 Well: MPF-65 PTD: 197-049 API: 50-029-22752-00-00 Well Name:MPF-65 API Number:50-029-22752-00-00 Current Status:Producer Rig:ASR Estimated Start Date:12/18/2023 Estimated Duration:5 days Regulatory Contact:Tom Fouts Permit to Drill Number:197-049 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 2,438 psi @ 6,086’ TVD SBHP 11/10/21 | 7.9 PPGE Maximum Expected BHP: 3,000 psi Max Potential Surface Pressure: 2,391 psi Gas Column Gradient (0.1 psi/ft) Max Angle:77° @ 10,950’ MD Brief Well Summary: MPU F-65 was drilled in January 1996 and completed in March 1996 as a Kuparuk producer. The well has been an ESP production well with ESP change outs as follows: March 1996 (initial), October 2001, February 2006, December 2012 and February 2017. Injection support was resumed in May 2021 to offset voidage. The ESP failed during a power bump that shut down Milne Point October 2021. November 2021 the ESP was replaced and continues to run today. Objectives: 1. Pull ESP completion. 2. Set 7” CIBP above perforations. 3. Run tubing and a production packer setting up the well for a CTD sidetrack. Notes Regarding Wellbore Condition: x 7” IA tested to 1,500 psi @ 8,007’ on 11/27/21 Pre-Rig Procedure (Non-Sundried Work) Pumping & Well Support 1. Bleed OA to 0 psi prior to ASR moving onto well. 2. Clear and level pad area in front of well. Spot rig mats and containment. 3. RD well house and flowlines. Clear and level area around well. 4. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 5. Pressure test lines to 3,000 psi. 6. Circulate at least one wellbore volume with produced water with lube down tubing, taking returns up casing to 500 barrel returns tank. 7. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 8. RD Little Red Services and reverse out skid. 9. Set BPV. ND tree. NU BOPE. Brief RWO Procedure (Approved Sundry Required) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 bbl returns tank. Well: MPF-65 PTD: 197-049 API: 50-029-22752-00-00 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 2,500 psi high. Test annular to 250 psi low/ 2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” and 4-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with produced water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out Centrilift for ESP pull. 6. RU spooler(s) to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger a. The hanger should come free at 106K. The previous pull in 2021 they had to pull 125K to get the tubing moving off bottom. Start by pulling up to 115K and we can raise it in 5K increments. b. String weight not recorded on install. SO recorded as 25K lbf. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing. Number all joints. a. Pre-rig caliper to inform on whether to keep 2-7/8” tubing. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Continue to monitor hole fill while pulling ESP. e. Clamp placement. i. Cross collar clamps: 301 ii. Pump Clamps: 6 iii. Flat Guards: 2 10. Lay Down ESP. 11. MU 7” casing scraper and 2-7/8” workstring. RIH and wash to 16,430’ and circulate x2 bottoms up or until clean returns are observed. a. Whipstock setting depth is +/-16,415’ MD. b. Packer setting depth is +/- 16,130’ MD. 12. Line up to reverse circulate and reverse circulate 490bbls of completion fluid into well at 4-5 bpm. a. Completion fluid to be seawater w/ 0.5% corrosion inhibitor. 13. POOH w/ 2-7/8” workstring and lay down. a. Monitor fluid level in well and fill as needed (~3.5gal/joint). 14. MU/RIH with 7” RBP on 2-7/8” 6.5# L-80 tubing and set @ 16,150’. 15. Test casing to 3,000 psi. 30 minute charted test to 3000 psi. - mgr Well: MPF-65 PTD: 197-049 API: 50-029-22752-00-00 16. POOH 3 joints and pick up RTTS storm packer. 17. RIH one joint and set RTTS storm packer. 18. Test storm packer to 3,000 psi. 19. Confirm casing packoffs have been tested and OA pressure bled off. 20. Split the BOP stack and remove 7 x 11 spool and install 11 x 11 spool. 21. Test packoff (this will test casing spool by new tubing spool break) 22. Test BOPE shell test to 250 psi low/ 2,500 psi high for 5-min. 23. Release RTTS storm packer and pull storm packer out of hole. 24. RIH and engage RBP. 25. POOH with RBP, while filling hole with 2x pipe displacement. 26. MU and run 4-1/2”, 12.6# L-80 TXP BTC completion. a. Ensure XN plug is set in the XN nipple in the tubing tail prior to running. b. Displacement from the well will be ~0.80 bbl/joint. 27. Run 4-1/2”, L-80 tubing tail and completion with packer to setting depth. a. Packer setting depth is +/- 16,130’ md and the WLEG depth is +/- 16,200’ MD. b. Note the Baker permanent packer is a hydraulically set and will only set with a hydrostatic overbalance of pressure from the inside of the tubing string. Risk of setting due to RIH speed is negligible. c. Enclosed table are the projected weights of the completion during running with a plug in tubing string and 8.5ppg seawater in the wellbore. Table 1 – Projected hook loads w/ plug in tubing tail while running completion from WellPlan. Run Measured Depth using: Expected friction factor: 0.25 Tripping In using: Hook load wt (usft) (kip) 010 2,000.00 21.4 4,000.00 31.7 6,000.00 37.8 8,000.00 44.9 10,000.00 53.2 12,000.00 61.6 14,000.00 70.6 16,000.00 85 16,450.00 90.2 28. Space out and land the hanger. RILDS. Lay down landing joint. a. Space out to the nearest joint and shift depths accordingly. b. Note PU (Pick Up) and SO (Slack Off) weights on tally. 29. Load tubing salt water with lube and hydraulically set the packer as per Baker’s setting procedure. 30. Conduct MIT-T to 3000psi and MIT-IA to 2000psi. 31. Set BPV. Well: MPF-65 PTD: 197-049 API: 50-029-22752-00-00 32. RU SL and pull XN plug from +/-16,180’ md. RD SL. a. If we cannot pull with SL PU 2-7/8” tubing and TIH to retrieve. 33. RD Hilcorp ASR #1 WO Rig, ancillary equipment and lines to 500bbl returns tank. Colors indicate assemblies to be bucked up prior to RWO. Nom. Size ~Length Item Lb/f t Material Notes 4-1/2” WLEG L-80 Place at ±16,200’ MD 4.5'' 62’2 Joints 12.6 L-80 TXP BTC 4.5''10'Pup Joint 12.6 L-80 4.5''XN Nipple 12.6 L-80 XN Plug installed 4.5''10'Pup Joint 12.6 L-80 4.5'' 31’ 1 joint 12.6 L-80 TXP BTC 4.5''10'Pup Joint 12.6 L-80 7'' 7” x 4-1/2” Packer 12.6 L-80 Packer set ±16,130' MD 4.5''10'Pup Joint 12.6 L-80 4.5'' 31’ 1 joint 12.6 L-80 TXP BTC 4.5''10'Pup Joint 12.6 L-80 4.5''3.813” X Sliding Sleeve 12.6 L-80 4.5''10'Pup Joint 12.6 L-80 4.5'' 16,035’Joints 12.6 L-80 TXP BTC 4.5''Space out PUPS 12.6 L-80 TXP BTC 4.5'' 1 joint 12.6 L-80 TXP BTC 4.5''Tubing Hanger 12.6 L-80 Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Slickline & Pumping 1. MIRU EL, PT PCE to 250 psi low / 2,500 psi high 2. RIH to 16,440’ and drift and caliper for whipstock 3. Shift the sliding sleeve open. 4. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 5. Pressure test lines to 3,000 psi. 6. Freeze protect IA and tubing. Well: MPF-65 PTD: 197-049 API: 50-029-22752-00-00 7. Shift the sliding sleeve closed. 8. RDMO Wireline 1. MIRU EL, PT PCE to 250 psi low / 2,500 psi high 2. MU RIH Baker 7” x 4-1/2” Delta expandable whipstock, DPU, gyro, GR and CCL. 3. Correlate on depth, confirm depth correction with Geology, Graham Emerson, 907-793-0315. 4. Set whipstock using a Halliburton DPU at 16,415’ @ 0 o. 5. POOH, RDMO. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic 4. Hookload wt with flotation _____________________________________________________________________________________ Revised By: TDF 8/18/2022 SCHEMATIC Milne Point Unit Well: MP F-65 Last Completed: 11/29/2021 PTD: 197-049 TD =16,853(MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13’ DF to Tbg.Spool =28.5’ (Nabors 22E) 7” 3 5 & 6 7 8 9 9 10 9-5/8” 1 2 KUP A Sands PBTD =16,755’(MD) / PBTD =7,729’(TVD) 4 X CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 16,325’ JEWELRY DETAIL No Depth Item 1 186’ Sta #2: 2-7/8” x 1” KBMG GLM w/ DSOV 2 16,080’ Sta #1: 2-7/8” x 1” KBMG GLM w/ Dummy 3 16,199’ 2-7/8” HES XN-Nipple (2.205 No-go ID) 4 16,252’ Discharge Head B/O PMP 513 w/ Zenith Ported Sub: PRESS PORT 513/538P PMP 5 16,253’ Pump #2: 538PMSXD 119 P23 FER NO PNT 6 16,270’ Pump #1: 538PMSXD 54 G31 7 16,283’ Gas Separator Gas Master Extreme 538GS w bolt on intake GPXARCINT FER H6 8 16,289’ Tandem Seal Section – GSB3DBUT SB/SB PFSA & GSB3DBLT SB/SB PFSA CL5 9 16,303’ Motor: KMH 228hp, 2,305 volts and 60 amps 10 16,320’ Sensor: Zenith E7 Motor Gauge w/ Centralizer – Btm @ 16,325’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Open Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Open Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,767 sx PF “E”, 800 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle = 77 deg. Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 ESP RWO w/ ASR#1 – 11/29/2021 STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned _____________________________________________________________________________________ Revised By: TDF 11/17/2023 PROPOSED Milne Point Unit Well: MP F-65 Last Completed: 11/29/2021 PTD: 197-049 TD =16,853(MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13’ DF to Tbg.Spool =28.5’ (Nabors 22E) 7” 3 5 & 6 9-5/8” 1 2 KUP A Sands PBTD =16,755’(MD) / PBTD =7,729’(TVD) 4X CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP BTC 3.958 Surface ±16,200’ JEWELRY DETAIL No Depth Item 1 ±16,045’ Sliding Sleeve – ID=3.813” 2 ±16,130’ 7” x 4-1/2” Packer 3 ±16,181’ 4-1/2” XN-Nipple (3.725” No-go ID) 4 ±16,198’ WLEG – Btm @ ±16,200’ 5 ±16,415’ 4-1/2”x7” Whipstock 6 ±16,440’ CIBP PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Open Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Open Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,767 sx PF “E”, 800 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle = 77 deg. Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 ESP RWO w/ ASR#1 – 11/29/2021 STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR Well: MPF-65 PTD: 197-049 API: 50-029-22752-00-00 Hookload Weight with Flotation STATE OF ALASKA �- Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Supry I Z �E' Ztril BOPE Test Report for: MILNE PT UNIT F-65 Comm Contractor/Rig No.: Hilcorp ASR 1 PTD#: 1970490 - DATE: 11/24/2021 Inspector Austin McLeod - Insp Source Operator: Hilcorp Alaska, LLC Operator Rep: Anderson/Vanderpool Rig Rep: Beshea/Haberthur Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopSAM211127132343 Rams: Annular: Valves. MASP: 321-566TYPe Test: [NIT ----- - - — 250/2500 • 250/2500 250/2500 2227 1 Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P _ Trip Tank NA - NA System Pressure 3150 P Housekeeping: P Pit Level Indicators P P Pressure After Closure 1850 P " PTD On Location P Flow Indicator P P 200 PSI Attained 14 P ' Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 65 P ' Well Sign P 112S Gas Detector P P Blind Switch Covers: All stations P ' Drl. Rig P_ - MS Misc -NA NA_ Nitgn. Bottles (avg): 4 a 2187 __ P ' Hazard Sec. NA ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly --- 0_ - NA" Stripper __ 0 NA No. Valves 15 FP ✓ Lower Kelly 0 NA Annular Preventer 1 - 11" P Manual Chokes - 1_ P Ball Type 1 P_ #1 Rams 1 2-7/8"x5" P Hydraulic Chokes 1 P Inside BOP I P #2 Rams 1 Blinds - P CH Misc 0 NA FSV Misc 0 NA #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 -_ NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 2-1/16" P Quantity P/F HCR Valves 1 2-1/16" P Inside Reel Valves 0 NA__ Kill Line Valves 3 2-1/16" FP Check Valve 0 - _NA - BOP Misc 0 NA Number of Failures: 3 ✓ Test Results Test Time 5.5 Remarks: 2-7/8 & 3-1/2" joints. CMV 15 replaced for a pass. Outermost kill valve greased/cycled for a pass. Valve on kill manifold used for testing greased/cycled for a pass. Annular-24secs; Rams-5secs; HCR -1 sec. By Samantha Carlisle at 10:36 am, Aug 19, 2022 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Change-out 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 16,853'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 7,819'16,755'7,729'2,227 N/A 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Taylor Wellman twellman@hilcorp.com 907-777-8449 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: N/A and N/A N/A and N/A See Schematic See Schematic 11/21/2021 2-7/8" Perforation Depth MD (ft): PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355017 197-049 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22752-00-00 Hilcorp Alaska LLC MILNE PT UNIT F-65 MILNE POINT / KUPARUK RIVER OIL C.O. 432D 110' 6.5# / L-80 / EUE 8rd TVD Burst 16,353' N/A 5,750psi 7,240psi 4,633' 7,807' 8,604' 16,840' Length Size 110' MD 16,812' 110' 20" 9-5/8" 7" 8,573' ry Statu Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. Taylor Wellman for David Haakinson Operations Manager By Samantha Carlisle at 8:51 am, Nov 04, 2021 321-566 WellmanWellmanDigitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.11.03 15:52:16 -08'00' Taylor Wellman (2143) ADL0355018 DSR-11/4/21MGR08NOV21 ADL0025509 X DLB 10-404 DLB 11/04/2021 BOPE test to 2500 psi. JLC 11/10/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.11.10 09:57:44 -09'00' RBDMS HEW 11/12/2021 ESP Change Out Well: MPU F-65 Well Name:MPU F-65 API Number:50-029-22752-00-00 Current Status:Oil Well [Failed ESP]Pad:F-Pad Estimated Start Date:November 21, 2021 Rig:ASR 1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Darci Horner Permit to Drill Number:197-049 First Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) Current Bottom Hole Pressure: 2,969 psi @ 7,416’ TVD (FL Shot 10/31/2021 / 7.70 ppg EMW) Maximum Expected BHP:2,969 psi @ 7,416’ TVD (FL shot taken on 10/31/21) MPSP:2,227 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU F-14 was drilled in January 1996 and completed in March 1996 as a Kuparuk producer. The well has been an ESP production well with ESP change outs as follows: March 1996 (initial), October 2001, February 2006, December 2012 and February 2017. Injection support was resumed in May 2021 to offset voidage. The ESP failed during a recent power bump that shut down Milne Point on October 10, 2021. Notes Regarding Wellbore Condition x CO 390A: A packer is not required on this ESP completion as the reservoir pressure of 7.7 ppg EMW is less than 8.55 ppg EMW. A BHP survey is scheduled to be performed to confirm prior to the return of the ASR crews. x Last CSG Test Prior to 2010. A casing test will be performed. Objective: Pull failed ESP, pressure test casing and run a new ESP. Pre-Rig Procedure: 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 4. Pressure test lines to 3,000 psi. 5. Circulate at least one wellbore volume with produced water down tubing, taking returns up casing to 500 bbl returns tank. a. Partial returns will probably be seen. After attempting circulation down the tubing, load the IA. 6. Confirm well is dead. Contact the operations engineer if freeze protection is needed depending on ASR arrival. 7. RD Little Red Services and reverse out skid. 8. RU crane. Set BPV. ND Tree. NU BOPE. RD Crane. 9. NU BOPE house. Spot mud boat. ESP Change Out Well: MPU F-65 Brief RWO Procedure: 10. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines. 11. Check for pressure and if 0 psi pull BPV. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ produced water prior to pulling BPV. Set TWC. 12. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8” and 3-1/2” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 13. Contingency: (If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 14. Bleed any pressure off casing to the returns tank. Pull TWC. Kill well with produced water as needed. 15. MU landing joint or spear and PU on the tubing hanger. a. The PU weight during the 2010 ESP swap was 114 K lbs to free pipe, 105K up wt. after free. The current completion was landed with an up wt of 108k. b. If needed, circulate (long or reverse) pill with lubricant prior to laying down the tubing hanger. ESP Change Out Well: MPU F-65 16. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 17. POOH and lay down the 2-7/8” tubing. Number all joints. Tubing will be saved for inspection and potential reuse. Lay down failed ESP. a. Pull out all visually bad joints for disposal. b. Look for over-torqued connections from previous tubing runs and junk them. c. 322 Cannon Cross Collar Clamps were installed. 18. PU test packer and run on 3-1/2” workstring to 8,000’ md. a. Base of the Schrader is at 7,716’ md / 4,350’ TVDSS. 19. Test casing to 1,500psi for 30 minutes (charted). 20. PU new ESP and RIH on 2-7/8” 6.5# L-80 tubing. Check electrical connections every 2,000’ a. Base of ESP at ± 16,330’ MD b. 1 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing c. 2-7/8” XN (2.205” No-Go) Nipple d. 3 joints of 2-7/8”, 6.5#, L-80, EUE 8rd tubing e. Lower 2-7/8”x 1” Side-pocket GLM with Dummy GLV f. Mulitple joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing g. Upper 2-7/8”x 1” Side-pocket GLM @ ± 200’ MD with 0.25” OV h. ± 5 joints 2-7/8”, 6.5#, L-80, EUE 8rd tubing 21. Land tubing hanger (Caution not to Damage Cable while landing the hanger). Lay down landing joint. Note PU (Pick Up) and SO (Slack Off) weights on tally. 22. Set BPV. Post-Rig Procedure: 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE. 3. NU existing 2-9/16” 5,000# tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. Replace gauge(s) if removed. 6. Turn well over to production. RU well house and flowlines. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic s (charted). _____________________________________________________________________________________ Revised By: TDF 10/14/2021 SCHEMATIC Milne Point Unit Well: MP F-65 Last Completed: 10/11/2010 PTD: 197-049 TD =16,853(MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13’ DF to Tbg.Spool = 28.5’ (Nabors 22E) 7” 3 5& 6 7 8 9 9 10 9-5/8 ” 1 2 KUP A Sands PBTD =16,755’ (MD) / PBTD =7,729’(TVD) 4 X CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface 16,353’ JEWELRY DETAIL No Depth Item 1 142’ Sta #2: 2-7/8” x 1” KBMG GLM w/ DSOV 2 16,121’ Sta #1: 2-7/8” x 1” KBMG GLM w/ Dummy 3 16,233’ 2-7/8” HES XN-Nipple (2.205 No-go ID) 4 16,275.8’ Discharge Head: 2-7/8” GPDIS EUE 8rd 5 16,276’ Upper Pump: SXD 137-P17 6 16,295’ Lower pump: SXD 68 G31 MVP 7 16,311’ Gas Separator GRSFTX AR H6 8 16,316’ Tandem Seal Section – GSB3DBUT SB/SB PFSA & GSB3DBLT SB/SB PFSA CL5 9 16,330’ Motor: KMH 228hp, 2,305 volts and 60 amps 10 16,350’ Sensor: Pumpmate XTO w/ Centralizer – Btm @ 16,353’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Open Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Open Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,767 sx PF “E”, 800 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle = 77 deg. Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned _____________________________________________________________________________________ Revised By: TDF 11/3/2021 PROPOSED Milne Point Unit Well: MP F-65 Last Completed: 10/11/2010 PTD: 197-049 TD =16,853(MD) / TD =7,819(TVD) 20” 7” x 42.21’ Marker Joint from 16,218’ to 16,260’ Orig. KB Elev.: 42.3’/ Orig. GL Elev.: 13’ DF to Tbg.Spool = 28.5’ (Nabors 22E) 7” 3 5& 6 7 8 9 9 10 9-5/8 ” 1 2 KUP A Sands PBTD =16,755’ (MD) / PBTD =7,729’(TVD) 4 X CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / N/A N/A Surface 110' 9-5/8" Surface 40 / L-80 / Btrc. 8.835 Surface 8,604’ 7" Production 26 / L-80 / Mod Btc 6.276 Surface 16,840’ TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±16,353’ JEWELRY DETAIL No Depth Item 1 ±142’ Sta #2: 2-7/8” x 1” GLM 2 ±16,121’ Sta #1: 2-7/8” x 1” GLM 3 ±16,233’ 2-7/8” HES XN-Nipple (2.205 No-go ID) 4 ±16,275’ Discharge Head: 5 ±16,276’ Upper Pump: 6 ±16,295’ Lower pump: 7 ±16,311’ Gas Separator: 8 ±16,316’ Tandem Seal Section: 9 ±16,330’ Motor: 10 ±16,350’ Sensor w/ Centralizer: Btm @ ±16,353’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kup. A Sands 16,454’ 16,460’ 7,458’ 7,463’ 6 3/1/2005 Open Kup. A Sands 16,471’ 16,491’ 7,473’ 7,491’ 20 4/1997 Open Kup. A Sands 16,498’ 16,526’ 7,497’ 7,522’ 28 3/1/2005 Open Ref Log: SWS GR/CCL 5/10/1997. 24gm RDX Big Hole @ 60 Deg. Phasing (EHD=0.56”, TTP= 12.89”) OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I (Approx.) in 24” Hole 9-5/8" Cmt w/ 1,767 sx PF “E”, 800 sx Class “G” in 12-1/4” Hole 7” Cmt w/ 300 sks Class “G” in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 300’ to 4,000’ 77 deg. f/ 4,000’ to 14,500’ Max Hole Angle = 77 deg. Hole Angle through perforations = 27 deg. TREE & WELLHEAD Tree 5M CIW 2-9/16” Wellhead 11” x 7-1/16” 5M FMC Gen 5A, w/ 2-7/8” FMC Tbg. Hngr. Tbg Hngr 3” LH ACME Lift Thread, 2-1/2” BPV CIW ‘H’ Profile GENERAL WELL INFO API: 50-029-22752-00-00 Drilled and Cased by Nabors 22E - 4/11/1997 Initial Perforations – 4/1997 ESPR WO w/ Nabors 4ES – 7/2/2001 ESP RWO w/ Nabors 4ES – 9/17/2002 ESP RWO & Perf Add w/ Nabors 4ES – 3/2/2005 ESP RWO w/ Nabors 4ES – 9/18/2009 ESP RWO w/ Nabors 4ES – 10/11/2010 STIMULATION SUMMARY 6/12/1997: 31,000 lbs of 16/20 Carbolite behind pipe, screened out early. 6/13/1997: Re-Frac w/ 130,000 lbs of 16/20 Carbolite behind pipe, screened out as planned Milne Point ASR Rig 1 BOPE BOPE ~4.48' ~4.54' 2.00' 5000# 2-7/8" x 5" VBR 5000#Blind DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head ×HVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning Project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] GraYScale, halftones, pictures, graphs, charts - Pages: [] Poor Quality Odginal- Pages: n Other- Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type 'OVERSIZED .Logs of vadous kinds Other Complete COMMENTS: Scanned bY: ~.,r~j M~r.d-D~r~.',. N~Low~ TO RE-SCAN Date: Notes: Re-Scanned bv: ~ver~/Mildred Daretha Nathan Lowell Date: /si bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder 1(317 D Alaska Oil and Gas Conservation Commission �^ 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name P11) # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/22011 MPF -09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 822011 MPF -13 1950270 50029225490000 0.2 N/A 02 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971980 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 822011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/12011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/92011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF-33 2010820 50029226890000 23 Need top job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF-37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF -42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A WA MPF -49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NN 2.0 N/A 13.6 9/1/2011 "" MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/312011 MPF -69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF -81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 17 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 1.2 N/A 12 N/A 13.6 8/3/2011 MPF - 848 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 1.2 N/A 12 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/132011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/132011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/132011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/12011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/112011 STATE OF ALASKA • ALASOIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory 197 -049 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 " 50 -029- 22752 -00 -00 7. Property Designation: N N 8. Well Name and Number: ADL 025509 & 355017 " MPF 9. Field / Pool(s): m Milne Point Unit / Kuparuk River ILI 10. Present well condition summary Total depth: measured 16853 feet Plugs (measured) None true vertical 7819 feet Junk (measured) None Effective depth: measured 16755 feet Packer: measured None feet true vertical 7729 feet true vertical None feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 8573' 9 -5/8" 8604' 4633' 5750 3090 Intermediate Production 16809' 7" 16840' 7807' 7240 5410 Liner Perforation Depth: Measured Depth: 16471'- 16526' N N 1 0 MO O True Vertical Depth: 7473'- 7522' Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6/5# L -80 16353' 7368' Packers and SSSV (type, measured and true vertical depth): None 11. Stimulation or cement squeeze summary: ` Intervals treated (measured): Treatment description including volumes used and final pressure: w Oil & Gas Can& Anchoraoill 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 283 98 82 350 291 Subsequent to operation: 665 240 156 260 291 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: ® Daily Report of Well Operations " ® Development ❑ Service ❑ Exploratory ❑ Stratigraphic ® Well Schematic Diagram 15. Well Status M oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Suspended after work: ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 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: Contact David Bjork, 564 -5683 1 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Phone 564 -4750 Date l f ' - 1 - C- - ) Sondra Stewman, 564 -4750 Form 10-404 Revised 07/2009 Submit Original Only fDAAS NOV 05 2010" l �• G • /o Tree: 2 9/16" 5M, CIW M P U F -65 Tbg. Spool :11" x 7 1/16" �a Orig. KB El 42.30' (N 22E) 5M FMC, Orig. GL Ele 13.0' Tbg. Hgr: 7" x 2 7/8 8rd bottom x 3 LH RT To Tbg. Spool = 28.5' (N 22E) Acme lift thread, 2.5" BPV CIW 'H' profile. 20" 91.1 ppf, H -40 Camco 2 -7/8" x 1 KOP @ 300 to 4000' =' sidepocket KBMG GLM 77 deg. 4,000'- 14,500' Max. hole angle = 77 deg. Hole angle thru' perfs = 27 deg. 9 5/8 ", 40 ppf, L -80 BTC. 8,604' m 2 7/8" 6.5 ppf, L -80, 8rd EUE Tbg ( drift ID = 2.347 ", cap. = 0.00592 bpf ) 7" 26 ppf, L -80, NSCC production casing _. ( drift ID = 6.151 ", cap. = 0.0383 bpf) a i' Camco 2 -7/8" x 1" sidepocket KBMG GLM 16 ,121 ` Marker Jts 16,227' to 16,267' RKB. 2 -7/8" HES XN- Nipple (2.205" id) 16 ,233 ` Centrilift Tandem ESP Up Pump- SXD - 137 -P17 16,276 Low Pump- SXD- 68 -G31 MVP Gas Separator GRSFTx -AR -H6 16,311 ` Stimulation Summary Tandem Seal Section 16,316` 6/12/97 - 31 M# of 16/20 Carbolite GSB3DB UT /LT SB /SB PFSA/FSA CL5 behind pipe, screened out early. 6/13/97 - 132 M# of 16/20 Carbolite Motor, 228 HP KMH 2305v 60a 16,329 behind pipe, screened out at design. PumpMate XTO w/6 fin 16,350 Centralizer Perforation Summary Ref Log: SWS GR/CCL 05/10/97 Size SPF Interval (TVD) 3 3/8" 6 16,471'- 16,491 (7,449'- 7,467') 6 16454'- 16460' 7458' -7463' 6 16498'- 16526' 7497' -7522' 7586' TVD 7" float collar (PBTD) 16,755 ' m 7" float shoe 16,840 ' m DATE REV.BY COMMENTS MILNE POINT UNIT 06/16/97 JBF Initial ESP Completion by Nabors 4ES 07/03/01 B. Hasebe ESP RWO Nabors 4ES Well No: F -65 09/17/02 MDO ESP RWO Nabors 4ES API : 50- 029 -22752 03/03/05 JRC ESP RWO and Add Perf Nabors 4ES 09/18/09 LH ESP RWO Nabors 4ES 10/11/10 REH ESP RWO- Nabors 4ES I BP EXPLORATION (AK) MPF -65, Well History Date Summary 07/20/10 ** *WELL FLOWING ON ARRIVAL ** *(flowing scrape, caliper tbg) RAN KJ, 1.72" CENT, FULL BORE SCRATCHER TO 3,000' SLM. (0 -900' slm 100 fpm, 900' -2450' sim 120 fpm, 2450' - 3,000' slm 90 fpm). LIGHT RESTRICTION. PULLED 1" BEK - DPSOV FROM ST #2 @ 142' MD. SET 1" BEK - DPSOV IN ST #2 @ 142' MD. CURRENTLY IN HOLE W/ KJ, 2.23" CENT, 5'x 1 -1/2" STEM, 2.12" CENT, QC, 5'x 1 -1/2" STEM, 3'x 1- 1/2" STEM, 2.25" GAUGE RING. VERY SLOW IN HOLE @ 4000' SLM. STOP @ 10232' SLM. TOOK 2 HOURS TO WORK DOWN TO 10510' SLM 07/21/10 T /I /0= 520/520/0. Assist Slickline. Pump 61 bbls criesel down Tbg FWHP= 500/500/0. S -Line has control of well @ LRS departure. 07/21/10 * * *CONT'D FROM 07- 20 -10 ** *(flowing scrape, caliper) TAGGED XN @ 16,251' SLM (16241' MD, +10' CORRECTION). VERY SLOW IN HOLE. LRS PUMPED 60 BBLS OF CRIESEL DOWN TUBING TO ASSIST W/ TOOLS FALLING. RAN 2.23" CENT, AND PDS CALIPER PER PROCEDURE FROM XN @ 16,241' MD TO SURFACE @ 50 FPM. RECIEVED GOOD DATA. WELL S/I ON DEPARTURE 08/19/10 T /1 /0= 400/400/0. Solvent Treatment. Pumped 3 bbls neat methanol, 30 bbls diesel /xylene, 86 bbls crude down Tbg. FWHP= 300/400/0. 09/10/10 T /1 /0= 500/500/0 Pre RWO Freeze Protect Pumped 15 bbls diesel down Tbg. Pumped 2 bbis 60/40, 3 bbls diesel, & 2 bbls 60/40 down FL & Test line. DSO notified swab wing ssv shut, master is oa open. FW HP's= 500/500/0 09/12/10 T /I /0= 200/320/0 Temp= warm PPPOT -T (PASS) PPPOT -IC (PASS) (Pre RWO) PPPOT -T : RU 1 HP BT onto THA 50 psi to 0 psi. Pressured to 5000 psi for 30 minute test, 4700/ 15 minutes, bled void to 0 psi. Cycle and torque LDS "ET style" all moved with no problems. 2nd test 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment, re installed Alemite cap. PPPOT -IC : RU 2 HP BT onto IC test void 200 psi to 0 psi. Flushed void until clean returns achieved, pressured to 3500 psi for 30 minute test, 3000/ 15 minutes, 3000/ 30 minutes. Bleed IC void to 0 psi, RD test equipment re installed Alemite caps. Cycle and torque LDS "ET style" all functioned no problems. 09/27/10 T /l /O = 500/400/0. Freeze protected tubing w/ 15bbls diesel. Flushed both lateral lines with 2bbls 60/40, 3bbls diesel, 2bbls 60/40. FWHP's = 500/400/0. Swab, SSV, Wing = shut. Master, IA, OA = open. 09/28/10 T /1 /0= 500/640/0 Displace Tbg w/85 bbls diesel. DSO notified swab wing ssv shut, master is oa open. FW HP's= 550/580/0 09/30/10 * ** WELL S/I ON ARRIVAL * ** (rig prep) ATTEMPTED TO RUN SBHPS.UNABLE TO GET PASS 13700' SLM. 10/01/10 MADE 30 MINUTE STOP @ 13525' SLM & 6 HOUR STOP @ 14025' SLM. PULLED 1" DGLV FROM ST #1 @ 16128' MD (pocket empty). PULLED 1" DPSOV & SET 1" DGLV IN ST #2 @ 142' MD. ASSISTED SUPPORT TECHS IN STALL BPV. » »> BPV SET « «< �- *** WELL S/I ON DEPARTURE * ** 10/01/10 T /l /O = 900/880/0 Assist S -Line Pumped 50 bbls diesel down Tbg. DSO notified SLB S -Line on well upon LRS departure. FWHP's= 900/840/0 10/03/10 MPU Well Support Tech's « « < » » »» Demobed well house, flowlines and foundation and the 2nd IA work valve was installed. 10/10/10 SURFACE WORK FOR 4 -ES INSTALL DPSOV IN OPEN TOP SPM AND DUMMY IN BOTTOM SPM 10/12/10 T /1 /0= bpv /0/0 Post RWO Freeze Protect Pumped 15 bbls crude down Tbg & 65 bbls crude down IA. DSO notified Nabors 4ES on well upon LRS departure. FWHP's= bpv /0/0 t \t Page 1 of 2 MPF -65, Well History Date Summary 10/13/10 The Well Support Techs rigged up and set the foundation, removed the 2nd IA valve, installed the flowlines, installed the wellhouse, pulled the BPV and set a TWC to pressure test tree which had to be turned to hook the flowlines up. They remove the TWC. Tree was tested to 5000 psi and the flowlines to 1150 psi NOTE: » » »» »All tests were GOOD and the BPV/TWC were left OUT « « ««« Page 2 of 2 Norffi America -ALASKA - BP Page�f , mm ort Re Qperatior� Su ary., R Common Well Name: MPF -65 AFE No Event Type: WORKOVER (WO) Start Date: 10/7/2010 End Date: X4- OORFF -E (415,000-00) Project: Milne Point Site: M Pt F Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 3/25/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292275200 Active Datum: 67 : 65 3/24/1997 10:58 @42.50ft (ab Mea Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/7/2010 06:00 08:00 2.00 MOB P PRE DERRICK DOWN AND PREP FOR RIG MOVE i INSPECT DERRICK LANDING AND HANDRAILS 108:00 - 10:30 2.50 MOB P PRE PJSM WITH PEAK DRIVERS AND RIG CREW PULL OFF OF F -77 WITNESSED BY WSL AND TP BOB NOBLE OF AOGCC CALLED @ 08:58 TO WAIVE BOPE TEST WITNESS 1 10:30 - 13:30 3.00 MOB P PRE CLEAN UP AROUND F -77 PREP WITH RIG MATS (2 HIGH) AROUND F -65 BERM UP AND SPOT IN KILL WEIGHT FLUIDS TANKS 13:30 16:00 2.50 MOB P PRE SPOT RIG OVER F -65 WITNESSED BY WSL AND TP SPOT IN PIPE SHED AND PITS MODULES 16:00 - 18:00 2.00 MOB P PRE CONTINUE TO RU RIG EQUIPMENT RIG UP LINES TO TIGER TANK & PITS RIG UP O/A BLEED OFF LINE TO TIGER TANK. 118:00 - 18:30 0.50 MOB P PRE PRE TOUR/ PRE JOB MEETING. i - DISCUSS REPAIR AND WELDER ASSIST WITH REGARD TO LANDING ON DERRICK. - DISCUSS ASSOCIATED HAZARDS, WIND DIRECTION, DROPPED OBJECT POTENTIAL. - ASSIGN TASKS, REMIND HANDS OF LAST DAY OF HITCH AND MAINTAINING FOCUS. 18:30 - 22:00 3.50 MOB P PRE ATTEMPT TO REPAIR LANDING. -WELD IN HAND RAILS - DECISION MADE TO REMOVE LANDING & REPAIR IN SHOP. - SECURE NECESSARY PERMITS, DISCUSS PLAN FORWARD WITH SUPERINTENDANT. - REMOVE LANDING WITH CRANE. 22:00 - 00:00 2.00 MOB P PRE PJSM. RAISE AND SCOPE DERRICK. - INSTALL ROOF PANELS. 10/8/2010 00:00 - 01:00 1.00 MOB P PRE CONTINUE TO INSTALL ROOF PANELS - RIG ACCEPTED@ 0100 HRS, 10/08/2010. 01:00 02:30 1.50 KILLW P DECOMP PJSM. P/U LUBRICATOR, TEST TO 25011500 PSI, CHARTED, OK. - PULL BPV, SITP 950 PSI, SICP 1350 PSI, O/A = 0 PSI. 02:30 - 04:30 2.00 KILLW P DECOMP PJSM. TEST MUD LINES TO 3500 PSI, OK - TAKE ON SEAWATER TO PITS Printed 11/4/2010 12:16:09PM orth America - ALASKA - BR, Page 2`of 6 operation Summary Report Common Well Name: MPF -65 AFE No Event Type: WORKOVER (WO) Start Date: 10/7/2010 End Date: X4- OORFF -E (415,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 3/25/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292275200 Active Datum: 67 : 65 3/24/1997 10:58 @42. (ab Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 12:00 7.50 KILLW P DECOMP PJSM. MILNE PT ALERTED TO GAS VENTING OPS - BLEED GAS ON TUBING THRU CHOKE TO TIGER TANK F/ 950 PSI TO 80 PSI. - BLEED GAS ON VA THRU CHOKE TO TIGER TANK TO 700 PSI - PUMP HEATED SEAWATER DOWN TUBING @ 4 BPM, 80 PSI, TAKING (GAS) RETURNS UP I/A TO TIGER TANK. PUMP 115 BBLS SEAWATER, SHUT IN AND RIJI-LHFAD 29 SEAWAT AWAT lad 5 BPM. - INITIAL BULLHEAD PRESS = 80 PSI, CAUGHT FLUID AFTER 18 BBLS - FINAL AND MAX BULLHEAD PRESSURE _ 800 PSI @ 5 BPM. - RESUME PUMPING DOWN TUBING @ 4 BPM, 110 - 150 PSI TAKING (GAS) RETURNS UP VA THRU CHOKE TO TIGER TANK. (400 PSI ON VA) - PUMPED 1 -18 BBLS SEAWATER AFTER BULLHEADING. STOP PUMPS SI TBG = (0) SI IA = 330. DUE TO WIND DIRECTION AND GAS VENTING TO THE TIGER TANK, TRUCKS WITH KWF WERE NOT ALLOWED TO UNLOAD DURING THE OPS. LOAD THE PITS WITH KWF. - SI TBG = (0), SI IA PRESSURE INCREASED TO 500 PSI OVER 45 MINUTES DURING LOAD PITS WITH SEAWATER. - RESUME PUMPING DOWN THE TBG (THROUGH THE CHOKE) WITH SEAWATER @4 BPM / 400, CAUGHT FLUID WITH 35 BBLS AWAY. FREEZE PROTECT (DIESEL) TO SURFACE AFTER PUMPING A TOTAL OF 500 BBLS SEAWATER. 4 BPM / 1150 PSI. - SEAWATER TO SURFACE STARTED WITH A TOTAL OF 588 BBLS PUMPED. 4 BPM / 1240 PSI. - REDUCE PUMP RATE TO 3 BPM / 1270 AND PUMPED THE LAST 90 BBLS. FCP = TBG = 730 PSI, IA = 100 - PUMPS OFF 10:15 HRS. MONITOR WELL, RECOVER RETURN FLUID FROM TIGER TANK. TOTAL 8.45# SEAWATER = 944 BBLS TOTAL BULLHEAD = 29 BBLS FLUID RECOVERED FROM TIGER TANK = 265 BBLS (50 % DIESEUCRUDE) (50 % SEAWATER) 82 TOTAL BBLS SEAWATER LOST TO FORMATION (29 BULLHEAD) (53 BBLS LOST PUMPING) TBG AND IA ON A VACUUM. Printed 11/4/2010 12:16:09PM pith Amenca Ak ASKf� - BP Page 3 of 6 Operation Summary Report Common Well Name: MPF -65 AFE No Event Type: WORKOVER (WO) Start Date: 10/7/2010 End Date: X4- OORFF -E (415,000.00) i Project: Milne Point Site: M Pt F Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 3/25/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292275200 Active Datum: 67 : 65 3/24/19 10:58 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 13:30 1.50 WHSUB P DECOMP SET 2 WAY CHECK AND ATTEMPTED TO TEST FROM BELOW. PUMPED 43 BBLS IN WITH 2O -30 PSI ONLY TESTED FROM ABOVE TO 3500 PSI FOR 10 MIN CHARTED. RD TEST EQUIPMENT 13:30 - 15:00 1.50 WHSUR P DECOMP TOOK FLUID SHOT -3 SECONDS FOR FLUID AT 1800 FT / 54 BBLS LOW PJSM AND ND TREE 171 XINTAIN HOLE FILL WITH 8.45 PPG SEA WATER AT 20 BPH 15:00 - 18:00 3.00 KILLW P DECOMP PJSM, AND NU BOP'S WHILE MAINTAING HOLE FILL WITH 8.45 PPG SEA WATER AT 20 BPH 18:00 - 18:30 0.50 KILLW P DECOMP CONDUCT PRE TOUR CHECKS, SERVICE RIG. 18:30 - 19:00 0.50 BOPSUR P DECOMP RIG UP TEST EQUIPMENT. 19:00 - 00:00 5.00 BOPSUR P DECOMP CONDUCT FULL BOPE TEST - TEST ALL ALL—OP C MP NENTS @ 250 / 3500 PSI. -USE 2 718" TEST JT TO TEST VBRS AND ANNULAR PREVENTOR - CONDUCT DRAWDOWN TEST ON ACCUMULATOR - 200 PSI INCREASE AFTER DRAWDOWN = 39 SEC - FULL PRESSURE ACHIEVED 2 MIN 53 SEC - NO FAILURES DURING TEST, WITNESSED BY WELL SITE LEADER & TOOL PUSHER - STATE REP BOB NOBLE WAIVED WITNESSING TEST, 24 HOUR NOTICE GIVEN. 10/9/2010 00:00 00:30 0.50 BOPSUR P DECOMP PJSM. LAY DOWN TEST TOOLS, N/U DUTCH RISER. 00:30 - 02:30 2.00 WHSUR P DECOMP PJSM. RIG UP LUBRICATOR, PT @ 250 / 1500 PSI, CHARTED. PULL TWO WAY CHECK VALVE, LID VALVE & LUBRICATOR. 02:30 - 03:30 1.00 PULL P DECOMP PJSM- MU LANDING JOINT WITH TIW VALVE AND XO - FM F BOLDS, CONFIRM NO PRESSURE ON IA - PULL TBG HANGER FREE AT114 K PUW AND 105 K FREE WT - LD TBG HANGER 03:30 - 04:30 1.00 PULL P DECOMP PUMP A TBG VOLUMM AT 4 BPM / 980 PSI (95 BBLS) PUMP 20 BBLS DOWN IA MONITOR WELL 05:00 - 06:00 1.00 PULL P DECOMP PJSM- PULL 2 7/8" EUE 6.5, TBG ESP COMPLETION STAND TBG IN DERRICK LD GLM - 3 STANDS OUT AT 0600 HRS - MAINTAIN CONTINUOUS HOLE FEED AT 20 - 30 BHA W/ NO RETURNS. 06:00 - 07:00 1.00 PULL P DECOMP SERVICE RIG AND CREW CHANGE SPILL CHAMP INSPECTED TANKS ON LOCATION PJSM FOR PULLING COMPLETION Printed 11/4/2010 12:16:09PM orth America - ALASKA - BP Page 4 of��` Operation Summ ary Report a Common Well Name: MPF -65 AFE No Event Type: WORKOVER (WO) Start Date: 10/7/2010 End Date: X4- OORFF -E (415,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 3/25/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292275200 Active Datum: 67: 65 3/24 /1997 10:58 @42.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 13:00 6.00 PULL P DECOMP CONTINUE TO PULL COMPLETION FROM STAND #3 - MAINTAIN A CONTINUOUS HOLE FILL AT 30 BPH WITH 8.5 SEAWATER 13:00 - 14:00 1.00 PULL P DECOMP PJSM, REMOVE FULL REEL FROM SPOOLING UNIT AND LOAD EMPTY REEL 16:45 - 18:00 1.25 PULL P DECOMP CONTINUE TO TOH FROM STAND 89 WITH CONTINOUS HOLE FEED AT 20 BPH WITH 8.45 SEAWATER - FIRE DRILL IN PITS. 15:15 HRS 18:00 - 19:00 1.00 PULL P DECOMP CREW CHANGE, WALK AROUNDS, AND PJSM FOR PULLING COMPLETION - PRE TOUR CHECKS, TAKE ON SEAWATER. 19:00 - 21:00 2.00 PULL P DECOMP CONTINUE TO TOH FROM STAND #145 - MAINTAIN CONTINOUS HOLE FILL AT 30 BPH WITH 8.5 SEE WATER - 514 JTS PULLED, 322 CANNON CLAMPS. 21:00 - 23:00 2.00 PULL P DECOMP REMOVE (6) PROTECTROLIZERS, & (3) FLAT GUARDS. PULL ESP CABLE OVER SHEAVE, DRAIN AND L/D CENTRILIFT PUMP. 23:00 - 00:00 1.00 PULL P DECOMP - PJSM. CHANGE OUT SPOOLS. 10/10/2010 00:00 - 01:30 1.50 RUNCOM P RUNCMP PJSM. STRING ROPE, PREP FLOOR TO RUN COMPLETION. 01:30 05:00 3.50 RUNCOM P RUNCMP P/U & S ERVICE NEW ESP PUMP. 05:00 - 06:00 1.00 RUNCOM P RUNCMP RIH W/ 2 7/8" EUE 8 RD ESP COMPLETION. - MAINTAINING CONSTANT HOLE FILL @ 30 BPH TORQUING CONNECTIONS TO 2300 FT /LBS 06:00 - 07:00 1.00 RUNCOM P RUNCMP RIG SERVICE - PERFORM PRE -TOUR CHECKS - PERFORM DERRICK AND FLUID TANK INSPECTIONS. 30 MIN. 07:00 - 08:00 1.00 RUNCOM P RUNCMP CONTINUE N ESP COMPLETION ON 2 7/8 TBG FR DER RICK. - CHANGE OUT JOINT #168 (RIH) DEFORMED FROM PAST'WORK -OVER' IN TONG AREA. - MAINTAINING CONSTANT HOLE FEED @ 20 BPH SEAWATER -FLUSH PUMP AND CHECK CONDUCTIVITY OF ESP CABLE EVERY 2000 FT AT 1 BPM /1130 PSI -AT —4,000 FT AT 1 BPM 1430 PSI 08:00 - 13:00 5.00 RUNCOM P RUNCMP CONTINUE RUN ESP COMPLETION ON 2 7/8" TBG FROM DERRICK. F/ JT #168 T/ # 180 - HELD RIG EVACUATION DRILL @ 11:14 HRS, HEAD COUNT AT 11:16 HRS. - DISCUSSED ENERGY SOURCES ON LOCATION. -FLUSH PUMP AND CHECK CONDUCTIVITY OF ESP CABLE AT —6,000 FT, 1 BPM /1160 PSI -AT —7,677 FT (AT SPLICE) 1 BPM 1160 PSI AT JOINT # 342 Printed 11/4/2010 12:16:09PM orfh America fiLASKR - BP se t mf 6 Operation Summary Report Common Well Name: MPF -65 AFE No Event Type: WORKOVER (WO) Start Date: 10/7/2010 End Date: X4- OORFF -E (415,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 3/25/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292275200 Active Datum: 67 : 65 3/24/1997 1 0:58 @42.50ft (above Mea Se Le Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 113:00 - 14:00 1.00 RUNCOM P RUNCMP AT SPLICE IN ESP CABLE MOTOR TEMPERATURE LEAD FAILED TO TEST - CONSULT WITH MPU AND ENGINEER AND DECIDE TO CONTINUE IN HOLE WITHOUT MOTOR TEMP GAUGE IN OPERATION. -HELD WEEKLY SAFETY MEETING DURING SPLICE REVIEWED SPCC PLAN AND RECENT IADC & ADW INCiDENT REPORTS COVERED FLUID TEMERATURES, BURN RATES, AND HAZARDS AROUND THE RIG. 14:00 - 17.30 3.50 RUNCOM P RUNCMP WITH GO AHEAD FROM ASSET CENTRALIFT PERFORMED ESP REEL TO REEL CABLE SPLICE 17:30 - 18:00 0.50 RUNCOM P RUNCMP CONTINUE TO RIH W/ ESP COMPLETION STRING. 18:00 - 18:30 0.50 RUNCOM P RUNCMP PERFORM PRE TOUR CHECKS, SERVICE RIG. 18:30 22:30 4.00 RUNCOM P RUNCMP CONTINUE TO RIH W/ 2 7/8" EUE 8RND ESP COMPLETION STRING. - TORQUING EACH CONNECTION TO 2300 FT /LBS CHECKING CONTINUITY AND PUMPING TO CLEAR MOTOR EVERY 2000' PUMPING @ 1 BPM / 1200 PSI. S CONSTANT HOLE FILL 30 BPH. 22:30 - 00:00 1.50 RUNCOM P RUNCMP PERFORM REEL TO REEL SPLICE. 10/11/2010 100:00 - 02:00 2.00 RUNCOM P RUNCMP CONTINUE WITH REEL TO REEL SPLICE. - CHECK CONTINUITY, OK. - FLUSH MOTOR / PUMP BY PUMPING SEAWATER @ 1 BPM / 1200 PSI - PUMP (8) BBLS TO CATCH FLUID IN TUBING, PUMP ADDITIONAL (5) BBLS TO FLUSH. - WEEKLY SAFETY MEETING WHILE PERFORMING SPLICE - REVIEWED SPCC PLAN AND ASSOCIATED TOPICS DISCUSSED RECENT INCIDENTS DISCUSSION REGARDING HAND/ FINGER AWARENESS REVIEWED PROPER CLOSURE OF BLIND SHEAR RAMS AND PIPE RAMS AND ASSOCIATED VERBAL COMMUNICATIONS. - KUDOS TO THE GUYS FOR MAINTAINING EXCELLENT WORK ATTITUDE. 02:00 - 03:30 1.50 RUNCOM P RUNCMP CONTINUE IN HOLE W/ ESP COMPLETION - C/O JT & COLLAR ON BOTTOM OF STAND # 169. - 322 CANNON CROSS COLLAR CLAMPS RUN. 03:30 - 04:00 0.50 RUNCOM P RUNCMP PJSM. M/U LANDING JT & HANGER. 04:00 - 06:00 2.00 RUNCOM P RUNCMP INSTALL PENETRATOR, MAKE FIELD 1 CONNECTION. - LAND TBG SOW = 40 K, PUW = 108 K. - FMC REP RILDS. - LD LANDING JT. 06:00 07:00 1.00 RUNCOM P RUNCMP RIG SERVICE AND PERFORM PRE -TOUR CHECKS - DERRICK AND TANK INSPECTIONS. Printed 11/4/2010 12:16:09PM Operatior> Summary Report Common Well Name: MPF -65 AFE No Event Type: WORKOVER (WO) Start Date: 10/7/2010 End Date: X4- OORFF -E (415,000.00) Project: Milne Point Site: M Pt F Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 3/25/1997 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. UWI: 500292275200 Active Datum: 67: 65 3/2 4/1997 10:58 @42.50ft (above Mean Sea Lev - - - - -_- - - - - -- __ __ _ - - - - -- -_ - -- -- - - -- - - -- _- ----_._---..--- Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 08:30 1.00 WHSUB P RUNCMP FMC REP INSTALLED TWC - PRESSURE-TEST TWC FROM BELOW, 4 BPM / 90 PSI FOR 10 CHARTED MINUTES. GOOD - TESTED FROM ABOVE TO 2000 PSI FOR 10 CHARTED MINUTES. GOOD 08:30 - 09:30 1.00 BOPSUR P RUNCMP ND BOPE 09:30 - 11:00 1.50 WHSUR P RUNCMP NU 2 1/16" PRODUCTION TREE 11:00 - 12:00 1.00 WHSUR P RUNCMP FMC REP TESTED HANGER VOID TO 5000 PSI FOR 30 CHARTED MINUTES. GOOD. 12:00 - 13:30 1.50 WHSUR P RUNCMP PJSM- PU AND TEST LUBRICATOR TO 250 / 2000 PSI. - PULL TWC AND INSTALL BPV. 13:30 14:30 1.00 WHSUR P RUNCMP ATTEMPT TO TEST BPV FROM BELOW AT 4 BPM / 80 PSI, CHARTED FOR 10 MIN. 14:30 - 17:00 2.50 RIGID P RUNCMP PJSM & SCOPE DOWN DERRICK 17:00 - 18:00 1.00 RIGD P RUNCMP PJSM & LID DERRICK 18:00 00:00 6.00 RIGID P RUNCMP WAIT ON TRUCKS FOR RIG MOVE AS WELL AS TRUCKS TO EMPTY MUD PITS OF SEAWATER. - THE REPAIRED UPPER DERRICK LANDING WAS INSTALLED. RIG RELEASED AT 00:00 HRS, 10/11/2010. Printed 11/4/2010 12:16:09PM STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPO OF SUNDRY WELL OPE~IONS ~~~EIVE[~ OCT U 2 2~10~ 1. Operations Performed: A„-~Or~~~ ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspend~el ^ Alter Casing ~ Pull Tubing ^ PerForate New Pool ^ Waiver ~ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension Replace ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory ` 197-049 3. Address: ^ Service ^ Stratigraphic 6. API Number. P.O. Box 1~612, Anchorage, Alaska 99519-6612 '`* 50-029-22752-00-00 7. Property Designation: 8. Well Name and Number: ' ADL 025509 & 355017 '~ MPF-65 9. Field / Pool(s): '~ Milne Point Unit / Kuparuk River Sand s 10. Present well condition summary Total depth: measured ~ 16853' feet true vertical `~ 78~ g feet Plugs (measured) None Effective depth: measured 16755' feet Junk {measured) None true vertical 772g feet Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 8573' 9-5/8" 8604' ._.~.,,.......A~33'~-~ 5750 3090 Intermediate Production 16809' 7" 16840' 7807' 7240 5410 Liner ~f1,~~ ~ ~ ~UU~ ., "~'~` '`'~~~~~ Perforation Depth: Measured Depth: 1647 1' - 16526' " True Vertical Depth: 7473' - 7522' Tubing (size, grade, measured and true vertical depth): 2-7/8", 6.5# L-80 16347' 7363' Padcers and SSSV (type, measured and true vertical depth): None 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 359 181 39 80 299 Subsequent to operation: 658 230 66 340 301 13. Attachments: ~ Copies of Logs and Surveys run 14. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations ~ Well Schematic Diagram 15. Well Status after work: ~ Oil ~ Gas ^ WDSPL ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Mehrdad Nadem, 564-5941 N/A Printed Name Terrie Hubble Title Drillin Technologist Si D '~ Pfe~~ By ~N~ ~ ~ gnature ate Phone 564-462 ~ Terrie Hubble, 564-4628 Form 10-404 Revised 07/2009 ` ~~~~° ~~ fg/~ ~-~ Submit Original Only a~Y~ ~ ~ t ~ • • BP EXPLORATION Page 1 of 3' Operations Summary Report Legal Well Name: MPF-65 , Common Well Name: MPF-65 Spud Date: 3/25/1997 ' Event Name: WORKOVER Start: 9/10/2009 End: 9/18/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/18/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 9/14/2009 06:00 - 07:30 1.50 MOB P PRE Scope Derrick down. Lay Derrick over. -Prepare Modlues to move to MPF-65. -Move off MPF-87a. 07:30 - 11:30 4.00 RIGU P PRE Move Rig & components of MPF-87a. -Spot & berm Rig over MPF-65. 11:30 - 13:00 1.50 RIGU P PRE Rig up. Raise & scope Derrick up. Accept Rip @ 13:00 hrs on 9/14/09 13:00 - 16:00 3.00 RIGU P PRE Rig up to Tree & Tiger Tank. Prepare to circulate. -Take on 8.5 ppg Seawater. 16:00 - 17:00 1.00 RIGU P PRE RU Lubricator. Test Lubricator to 500 psi - Pass. -Pull BPV. LD same. 17:00 - 18:00 1.00 RIGU P PRE Test surface lines to 3500 psi - Pass. -O en Well - T/I/O = 270 / 270 / 0 si. -Bull head 94 bbls of Seawater down Tb . -Pump rate: 5 bpm / 1,500-1,950 psi. -Obtain SPR 30 spm / 250 psi. 18:00 - 18:30 0.50 RIGU P PRE Service Rig. Check alarms. Inspect Derrick. 18:30 - 21:30 3.00 RIGU P PRE Pump down Tbg 4 bpm / 500 psi. -Returns @ 44 bbis away. Shut down. -Bull head down annulus: -ICP 2 bpm / 150 psi. FCP 5 bpm / 1700 psi. -Bull head 530 bbls down annulus. -Monitor well - Static. -Bull head 50 bbls of Seawater down Tbg. -4 bpm / 2200 psi. -Total fluid Bull headed = 10 260 stks / 604 bbis. , 21:30 - 23:00 1.50 RIGU P PRE Set TWC. Test from below. -Pum 2 b m/ 300 si for 10 minutes. -T t from above 3500 si / 10 minutes - Pass. -RD & blow down lines. 23:00 - 00:00 1.00 RIGU P PRE PJSM. ND Tree. 9/15/2009 00:00 - 00:30 0.50 BOPSU P DECOMP Continue to ND Tree. 00:30 - 03:00 2.50 BOPSU P DECOMP NU BOP stack. -RU to test BOP's. 03:00 - 08:00 5.00 BOPSU P DECOMP Test BOP's and related equipment. -Test to BP & AOGCC procedures & regulations. -BOP configuration: -13 5/8" Hydril GK 5000. -Blind Shear Rams. -Spacer spool. n~iou v n~ ~i,..-:..~..i.. o,..., o,....... ~ Test Choke Manifold, Blinds, 2-7/8" X 5" VBR's, -Manual Choke, HCR Choke, Manual Kill, HCR Kill, -Floor Valves. -Test to 250 psi low and 3,500 psi high. -Test Hydril Annular to 250 psi low and 3,500 psi high. -Used 2-7/8" Test Joint on Rams and Annular. -Each test was held for 5 charted minutes. -Jeff Jones AOGCC witnessed test Printed: 9/29/2009 11:36:38 AM o ~ • BP EXPL Qperations Si Legal Well Name: MPF-65 Common Well Name: MPF-65 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date From - To Hours Task Code NPT PI .ORATION ' Page 2 af 3 ammary Report Spud Date: 3/25/1997 Start: 9/10/2009 End: 9/18/2009 Rig Release: 9/18/2009 Rig Number: 4ES iase Description of Operations 9/15/2009 03:00 - 08:00 5.00 BOPSU P DECOMP -Test was also witnessed by WSL & TP. 08:00 - 10:00 2.00 PULL P 10:00 - 11:30 ~ 1.50 ~ PULL ~ P 11:30 - 12:30 I 1.001 PULL I P 12:30 - 18:00 5.50 PULL P 18:00 - 18:30 0.50 PULL P 18:30 - 21:30 3.00 PULL P 21:30 - 22:30 1.00 PULL P 22:30 - 00:00 1.50 PULL P 9/16/2009 00:00 - 08:30 8.50 PULL P 08:30 - 11:30 3.00 PULL P 11:30 - 13:00 1.50 PULL P 13:00 - 14:00 1.00 PULL P 14:00 - 15:30 1.50 RUNCO P 15:30 - 19:30 4.00 19:30 - 20:00 0.50 20:00 - 00:00 4.00 9/17/2009 ~ 00:00 - 06:00 ~ 6.00 06:00 - 08:00 I 2.00 08:00 - 11:00 3.00 11:00 - 17:00 6.00 17:00 - 21:00 4.00 21:00 - 22:00 1.00 DECOMP SHOOT FLUID LEVELS @ 2,200' MD._~ L TEST TO 500 PSI. -PULL TWC. LD SAME. DECOMP MU LANDING JT. BOLDS. PULL HANGER @ 80K. -PULL HANGER TO FLOOR @ 110K. -LD HANGER. ADD 20 BBLS SEAWATER TO WELL. DECOMP PU CLAMP BOX. -PULL ESP ESP CABLE OVER SHEAVE & ATTACH TO SPOOLER. DECOMP L TION ASSEMBLY. -POH STAND BACK IN DERRICK 76 STDS. DECOMP SERVICE RIG. CHECK ALARMS. INSPECT DERRICK. DECOMP CONTINUE TO POH W/ ESP COMPLETION ASSEMBLY. -POH STAND BACK IN DERRICK ATOTAL OF 90 STDS. DECOMP CHANGE OUT ESP CABLE SPOOL REELS. DECOMP CONTINUE TO POH W/ ESP COMPLETION ASSEMBLY. -POH STAND BACK IN DERRICK ATOTAL OF 103 STDS. DECOMP CONTINUE TO POH W/ ESP COMPLETION ASSEMBLY. -POH STAND BACK IN DERRICK A TOTAL OF 171 STDS. OF 2-7/8" EUE 8RD. TUBING. DECOMP BREAK OUT, INSPECT AND LAY DOWN ESP BHA. DECOMP CLEAR AND CLEAN RIG FLOOR. RIG UP PIPE HANDLING TOOLS TO RUN 2-7/8" TUBIN . DECOMP SAFETY STANDDOWN CONVERSATION WITH WILLINGHAM/GRAFF AND RIG CREW. RUNCMP RIG UP ESP CABLE SPOO~ER AND PREPARE ESP BHA IN PIPE SHED. -PU PUMP TOOLS & CANNON CLAMPS. RUNCMP MU CENTRILIFT PUMP. PULL ESP CABLE OVER SHEAVE. -SECURE CABLE TO PUMP. SERVICE PUMP. RUNCMP SERVICE RIG. CHECK ALARMS. INSPECT DERRICK. -CLEAR & CLEAN RIG FLOOR. RUNCMP RIH W/ ESP ASSEMBLY ON 2 7/8" TBG. -INSTALL CANNON CLAMPS ON EVERY COLLAR FOR 41 STDS. -TEST ESP & PUMP EVERY 2,000'. -21 STDS RUN IN HOLE. RUNCMP CONTINUE TO RIH W/ ESP ASSEMBLY ON 2 7/8" TBG. -INSTALL CANNON CLAMPS ON EVERY COLLAR FOR 41 STDS. -TEST ESP & PUMP EVERY 2,000'. -64 STDS RUN IN HOLE. RUNCMP CONTINUE TO RIH W/ ESP ASSEMBLY ON 2 7/8" TBG. -TEST ESP & PUMP EVERY 2,000'. -81 STDS RUN IN HOLE. RUNCMP MAKE REEL TO REEL ESP CABLE SPLICE. RUNCMP CONTINUE TO RIH W/ ESP ASSEMBLY ON 2 7/8" TBG. -TEST ESP & PUMP EVERY 2,000'. -162 STDS RUN IN HOLE. RUNCMP MAKE SECOND REEL TO REEL CABLE SPLICE. -165 STDS IN Qa 16,000' MD. CLEAN RIG. RUNCMP CONTINUE TO RIH W/ ESP ASSEMBLY ON 2 7/8" TBG. Printed: 9/29/2009 17:36:38 AM . • • BP' EXPLORATION Page 3 of 3 Operations Summary Report Legal Well Name: MPF-65 Common Well Name: MPF-65 Spud Date: 3/25/1997 Event Name: WORKOVER Start: 9/10/2009 End: 9/18/2009 Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 9/18/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 9/17/2009 21:00 - 22:00 1.00 RUNCO P RUNCMP -RIH TO TD. 22:00 - 00:00 2.00 RUNCO P RUNCMP PU LANDING JT. MU TBG HANGER. -INSTALL TWC & PENETRATOR. 9/18/2009 00:00 - 01:00 1.00 RUNCO P RUNCMP ATTACH FIELD CONNECTOR. PLUG INTO PENETRATOR. -TEST CONDUCTIVITY. 01:00 - 01:30 0.50 RUNCO P RUNCMP LAND TBG HANGER W/ TWC INSTALLED.. RILDS. LD LANDING JT. -PUW = 105K -SOW = 40K -RAN 319 CANNON CABLE CLAMPS, 5 PROTECTORLIZERS AND 3 FLAT CABLE GUARDS. 01:30 - 02:30 1.00 RUNCO P RUNCMP TEST TWC FROM BELOW. PUMP 2 BPM / 170 PSI. -CHART TEST FOR 10 MINUTES. 02:30 - 04:30 2.00 RUNCO P RUNCMP ND BOP'S, 04:30 - 06:00 1.50 WHSUR P WHDTRE NU TREE. TEST VOID TO 5000 PSI. -TEST FOR 30 CHARTED MINUTES - PASS. -SECURE RIG & CELLAR. RELEASE RIG 06:00 HRS 9/18/09 Printed: 9/29/2009 11:36:38 AM Tbg..Spoo11611'nx 7 1 16" 5M FM~.5a M P U F-65 Tbg. Hgr: 7" x 2 7/8" 8rd bottom x 3" LH Acme lift thread, 2.5" BPV CIW 'H' profile. 20" 91.1 ppf, H-40 110' KOP @ 300 to 4000' 77 deg. 4,000' - 14,500' Max. hole angle = 77 deg. Hole angle thru' perfs = 27 deg. 9 5/8", 40 ppf, L-80 BTC. 8,604' m' 2 7/8" 6.5 ppf, L-80, 8rd EUE Tbg ( drift ID = 2.347", cap. = 0.00592 bpf ) 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) Marker Jts 16,227' to 16,267' RKB. Stimulation Summary 6/12/97 - 31 M# of 16/20 Carbolite behind pipe, screened out early. 6/13/97 - 132 M# of 16/20 Carbolite behind pipe, screened out at design. PerForation Summary Ref Log: SWS GR/CCL 05/10/97 Orig. KB ~= 42.30' (N 22E) Orig. GL Elev. = 13.0' RT To Tbg. Spool = 28.5' (N 22E) Camco 2-7/8" x 1" ~ I sidepocket KBMM GLM 142` Camco 2-7/8" x T' sidepocket KBMM GLM 16,128` 2-7/8" HES XN-Nipple (2.205" id) 16,241 ` I Pump, 161 Stg 161-P11 TC 16,275` and 18 Stg 18-P75 TC Gas Separator ~RSFTx-aR-HS 16,303` Intake = 7,324' TVD Tandem Seal Section 16 308` GS63DB UT/LT SB/SB PFSA/FSA CL5 , Motor, 228 HP KMH 2305v 60a 16,322` PumpMate XTO w/6 fin 16,345` Centralizer PumpMate = 7,358' TVD Size SPF Interval (ND) 3 3/8" 6 6,471'-16,491 (7,449'-7,467') 6 16454'-16460' 7458`-7463' 6 16498`-16526' 7497`-7522' DATE EV.BY COMMENTS 06/16/97 07/03I01 JBF B. Hasebe Initial ESP Completion by Nabors 4ES ESP RWO Nabors 4ES 09/17/02 MDO ESP RWO Nabors 4ES 03/03/05 JRC ESP RWO and Add Perf Nabors 4ES 09/18/09 LH ESP RWO Nabors 4ES MILNE POINT UNIT Well No : F-65 API : 50-029-22752 BP EXPLORATION (AK) I 7586' ND 7" float collar (PBTD) 16,755' m 7" float shoe 16,840' m ) STATE OF ALASKA ) ALASKA vIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~ECF'\/ED charM!\5tt~sJ 2005 _ Alaska Ml81tmfs Cons. Comrüssion o TiAWcfi~on ') 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 181 Repair Well 0 Plug Perforations 0 Stimulate 181 Pull Tubing 0 Perforate New Pool 0 Waiver o Operation Shutdown 181 Perforate 0 Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 42.30" 8. Property Designation: ADL 355017 4. Current Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 197-049-00 6. API Number: 50-029-22752-00-00 9. Well Name and Number: MPF-65 10. Field / Pool(s): Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 16853 feet true vertical 7819 feet Plugs (measured) None Effective depth: measured 16755 feet Junk (measured) None true vertical 7729 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 8573' 9-5/8" 8604' 4633' 5750 3090 I nterm ediate Production 16809' 7" 16840' 7807' 7240 5410 Liner SC.ANNED MAR 2 4 20 Œ~ Perforation Depth MD (ft): Perforation Depth TVD (ft): 16471' - 16526' 7473' - 7522' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2-7/8",6.5# 16354' L-80 None Treatment description including volumes used and final pressure: RBOM!--" BFhf ", - " . . ,,) 1'"",'I~1í 2 .2 20D5 13. Oil-Bbl Prior to well operation: 557 Subsequent to operation: 673 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure 319 16 330 339 59 350 TubinQ Pressure 338 345 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman ~- /' Si~ure~~~~_._____ Form 10-404 Revised 04/2004 Title Technical Assistant Phone Prepared By Name/Number: Date 03' 7v1 -os Sondra Stewman, 564-4750 Submit Original Only 564-4750 j '~ 't' ¡'/.\ '.J ¡- '\ -". Tree: 29/16" 5M, CIW Tbg. Spool : 11" x 71/16" 51 '}, Gen. Sa. Tbg. Hng: 7" x 2 7/8" 8 rd bottom x 3" LH Acme lift thread, 2.5" BPV CIW 'H' profile. 20" 91.1 ppf, H-40 i I 110' I KOP @ 300 to 4000' 77deg. 4,000' - 14,500' Max, hole angle = 77 deg. Hole angle thru' perfs = 27 deg. 95/8",40 ppf, L-80 Blre. 18,604' mq ~ 27/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift 10 = 2.347", cap. = 0.00592 bpf) 7" 26 ppf, L-80, NSCC production casing (drift 10 = 6.151", cap. = 0.0383 bpf) ~ ^ Marker Jts 16,227' to 16,267' RKB. X Stimulation Summary 6/12/97 - 31 M# of 16/20 Carbolite behind pipe, sceened out early. 6/13/97 - 132 M# of 16/20 Carbolite behind pipe, screened out at design. Perforation Summary Ref Log: SWS GR/CCL 05/10/97 Size SPF Interval (TVD) 33/8" 6 16,471'-16,491' (7,449'-7,467') 6 16454'-16460' 7458'-7463' 6 16498'-16526' 7497'-7522' MPU F-65 L Orig. )=Iev. = 42.30' (N 22E) Orig. GL Elev. = 13.0' RT To Tbg. Spool = 28.5' (N 22E) Camco 2-7/8" X 1" sidepocket KBMM GLM 1139' I , Camco 2-7/8" x 1" sidepocket KBMM GLM 116,130' 1 2-7/8" HES XN-Nipple (2.205" id)116,241' 1 Pump, 151 Stg GC1700 116,285' 1 and 19 stg. GC8200 Tandem Gas Separator 1 1 513 Internals 16,309' Intake 16,314' MD = 7,334' TVC Tandem Seal Section 116 314' 1 GSB3 DB UT/L T IL H6 PFS Aflas/HSN ' Motor, 228 HP KMH 2305 v 60a 116,328' I Phoenix MS1 w/6 fin Centralizer 116,348'1 7586' tvd 7" float collar (PBTO) 116,755' m1 ~ 7" float shoe 116,840 ' m~ DATE REV. BY COMMENTS MILNE POINT UNIT 06/16/97 JBF Initial ESP Completion by Nabors 4ES Well No : F-65 07/03/01 B. Hasebe ESP RWO Nabors 4ES API: 50-029-22752 09/17/02 MOO ESP RWO Nabors 4ES 03/03/05 JRC ESP RWO and Add Perf Nabors 4ES BP EXPLORATION (AK) ) ) BP .EXPLORATION ()ipèrati()n~lSumniarY Repqrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-65 MPF-65 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/26/2005 Rig Release: 3/2/2005 Rig Number: 4ES Spud Date: 3/25/1997 End: Date From.. To Hours' . Task Code NPT Description.öf Opera.tions 2/26/2005 14:00 - 15:30 1.50 MOB P PRE Scope down and lower Derrick. 15:30 - 16:30 1.00 MOB P PRE Move off of MPF-94 Well Slot. 16:30 - 18:00 1.50 RIGU P PRE Spot Rig Mats. Wait on Pad Operator -1 hr. (Pad Operator change-out). 18:00 - 21 :00 3,00 RIGU P PRE MIRU on MPF-65 Well Slot. Raise and Scope Derrick. Spot Pipe Shed and Pits. Spot Camp. Take on Hot Sea Water in Rig Pits. Spot Tiger Tank and lay return line. Accepted Rig at 20:00 hrs, 21 :00 - 22:00 1.00 KILL P DECOMP Rig up Lines to Production Tree. Continue to take on Hot Sea Water in Rig Pits. Pick-up Lubricator and pull BPV. Lay down same, TP = 820 psi. lAP = 830 psi. OAP = 0 psi. Pressure test Lines at 3,500 psi. Good, 22:00 - 22:30 0.50 KILL P DECOMP PJSM with all. 22:30 - 00:00 1.50 KILL P DECOMP Begin pumping 120 deg F down Tubing at 4.5 bpm/1075 psi. 2/27/2005 00:00 - 03:00 3.00 KILL P DECOMP Finish killing and cleaning up Well at 4.5 bpm/1300 psi. Total Sea Water pumped = 715 bbls. Sent recovered Diesel, Oil, and Produced Water to MPU ORT. 03:00 - 03:30 0.50 KILL P DECOMP Monitor Well dead. 03:30 - 05:00 1.50 WHSUR P DECOMP Set TWC and test. Nipple down Production Tree. 05:00 - 08:00 3.00 BOPSUR P DECOMP Nipple up BOPE. Change out 2 7/8" Pipe Rams. Install re-built 2 7/8" x 5" VB Pipe Rams. 08:00 - 12:00 4.00 BOPSUF P DECOMP Rig up test equipment. Test BOPE per BP/AOGCC requirements at 250/3,500 psi. Good test. State's right to witness test waived by C. Sheeve. Co Man and Tool Pusher were present for Test. Blow down Lines, Rig down test equipment. 12:00 - 13:00 1.00 BOPSUP P DECOMP Pick-up Lubricator and pull TWC. Lay down same. Monitor Well. Well on vacuum. 13:00 - 13:30 0.50 PULL P DECOMP Pick-up Landing Joint. BOLDS. Attempt to pull Hanger to Floor at 125K. Stopped at 80% rule plus weight of Blocks. 13:30 - 15:30 2.00 PULL P DECOMP Mix a 40 bbl hot Sea Water Pill containing 2 Drums of EP Mud Lube. Reverse 40 bbl Pill down Annulus at 4.0 bpm/700 psi. Loosing 2 bpm returns. Stop with lead Pill at -8,800'. 15:30 - 16:30 1.00 PULL P DECOMP Shut down Pumps. Pull on Tubing. Completion broke free at 120K. Pull Tubing Hanger to floor at 105K. Test ESP. Cut ESP Cable. Lay down Landing Joint and Tubing Hanger. 16:30 - 17:00 0.50 PULL P DECOMP Pulled ESP Cable over Sheave and attached tp Reel in Spooling Unit. 17:00 - 00:00 7.00 PULL P DECOMP Begin POOH with 27/8" Tubing and ESP Completion. 2/28/2005 00:00 - 02:30 2.50 PULL P DECOMP Finished POOH with 514 Jts 2 7/8" Tbg, 2 GLMs, XN-Nipple and ESP Assy, 02:30 - 04:30 2.00 PULL P DECOMP Lay down ESP Assembly. 04:30 - 05:30 1.00 PULL P DECOMP Rig down ESP handling equipment. Clear and Clean Floor. 05:30 - 06:00 0.50 CLEAN P DECOMP Pick-up 2 7/8" Mule Shoe. Start TIH with 27/8" Tubing. 06:00 - 06:30 0.50 CLEAN P DECOMP Service Rig. 06:30 - 12:00 5,50 CLEAN P DECOMP Finish TIH with Tubing standing in Derrick (171 stds). 12:00 - 13:00 1.00 CLEAN P DECOMP Single in with Tubing from Pipe Shed. Found no Fill. Tagged hard bottom at 16,730' (Driller's depth) on Joint #532, 13:00 - 14:30 1.50 CLEAN P DECOMP Start POOH. Lay down extra singles. Continue POOH standing Tubing back in Derrick. 14:30 - 15:30 1.00 CLEAN P DECOMP Stop to Cut and Slip Drilling Line. 15:30 - 21 :00 5.50 CLEAN P DECOMP Continue POOH standing Tubing in Derrick. Pulled 171 stands. Printed: 3f712005 9:45:56 AM ) ) BPEXPLORATION ()pèré1ti()l1s...·Sumrnê:lryR~pºrt . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ··Date MPF-65 MPF-65 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 2/28/2005 From -To Hours Task 'Code NPT Phase 21 :00 - 22:00 1.00 PERF P DECOMP 22:00 - 00:00 2.00 PERF P DECOMP 00:00 - 03:30 3.50 PERFOB N SFAL OTHCMP 3/1/2005 03:30 - 08:00 4.50 PERFOB P OTHCMP 08:00 - 09:00 1.00 PERFOB P OTHCMP 09:00 - 12:00 3.00 PERFOB P OTHCMP 12:00 - 14:00 2.00 PERFOB P OTHCMP 14:00 - 15:00 1.00 RUNCOMP RUNCMP 15:00 - 20:00 5.00 RUNCOMP RUNCMP 20:00 - 00:00 4.00 RUNCOMP RUNCMP 3/2/2005 00:00 - 01 :00 1.00 RUNCOIVP RUNCMP 01 :00 - 04:30 3.50 RUNCOMP RUNCMP 04:30 - 06:00 1.50 RUNCOMP RUNCMP 06:00 - 06:30 0,50 RUNCOMP RUNCMP 06:30 - 10:00 3.50 RUNCOMP RUNCMP 10:00 - 13:00 3.00 RUNCOMP RUNCMP 13:00 - 13:30 0.50 RUNCOMP RUNCMP 13:30 - 15:30 2.00 RUNCOrvP RUNCMP 15:30 - 16:00 0.50 RUNCOMP RUNCMP 16:00 - 17:00 1.00 BOPSUR P RUNCMP 17:00 - 18:30 1.50 WHSUR P RUNCMP 18:30 - 19:00 0.50 WHSUR P RUNCMP 19:00 - 20:00 1.00 WHSUR P POST Start: 2/26/2005 Rig Release: 3/2/2005 Rig Number: 4ES Spud Date: 3/25/1997 End: Description of Qperations Clear & clean rig floor. Pullflow nipple. N/U shooting flange on annular. Hold PJSM & review R/U procedure to perf well. R/U E-line equip & lubricator. Finish M/U lubricator. Attempt to pressure test. leaking no good. Bleed off Lubricator. Bleed-off Line frozen. LId lubricator & thaw line. Fix leak. P/U Ibricator & test same to 1000 psi, Tested good. Bleed off lines, M/U & arm perf guns. RIH wi same. Tie-in & Corellate depth. Perforate A-1 sands 16498 to 16526'. POOH wi perf guns. LID spent guns. P/U & arm guns for next interval. RIH. Tie-in & corellate depth. Perforate the Ä-3 sand from 16454 to 16460'. POOH wi perf guns. LID spent guns, lubricator & E-line equip. N/U flow nipple to annular. Clear & clean rig floor. R/U to run completion. Unload. M/U & service ESP. Plug in cable. Check same. RIH wi ESP on stands of 2 7/8" tubing. Pump thru pump & test cable every 2000' , Con't to RIH wi ESP completion, Pump thru pump & test cable every 2000'. Ran 81 stands in hole. (7875') Change out spools & make reel to reel splice. Check & test same. Con't to RIH wi ESP completion. Pump thru pump & test cable every 2000'. Lubricate rig. PJSM. Continue in hole wi 2 7/8" ESP completion. Check cable & circulate down tubing, 5 bbls @ 1 bpm I 1000 psi every 2000', OK. PJSM. Make reel to reel splice. 166 stds in hole, @ 15,759'. Con't to RIH wi 27/8" ESP completion. Pump thru pump & check cable every 2000'. Ran 171 stands. P/U landing Jt. M/U hanger. Install penetrator. Land completion. RILDS. Set & test TWC to 3500 psi, Ok. N/D BOPE. N/U X-mas tree. Test tree & void to 5000 psi, Ok. Perform final check & test of ESP cable. P/U lubricator & pull TWC. Install BPV & LID lubricator. Secure well. Clean cellar. RELEASE RIG @ 2000 Hrs. Printed: 3m2005 9:45:56 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 42.30' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2101' NSL, 2520' WEL, SEC. 06, T13N, R10E, UM MPF-65 At top of productive interval 9. Permit Number / Approval No. 197-049 3252' NSL, 1930' WEL, SEC. 29, T14N, R10E, UM 10. APl Number At effective depth 50-029-22752-00 3370' NSL, 1879' WEL, SEC. 29, T14N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 3407' NSL, 3407' WEL, SEC. 29, T14N, R10E, UM Sands 12. Present well condition summary Total depth: measured 16853 feet Plugs (measured) true vertical 7819' feet Effective depth: measured 16755 feet Junk (measured) true vertical 7729' feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" 260 sx Arctic Set (Approx.) 110' 110' Surface Intermediate Production 8573' 9-5/8" 1767 sx PF 'E', 800 sx 'G' 8604' 4633' Liner 16089' 7" 300 sx Class 'G' 16840' 7807' Perforation depth: measured 16471'- 16491' true vertical 7473' - 7491'RECEIVED Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 16347' o~'r 0 i~) ~00~ Packers and SSSV (type and measured depth) None ,~ja8~]l 0ii & GaS Cons. C0mrfli~lO~ Anehora~e 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~_.~___ _Title TechnicalAssistant Date Prepared By Name/Number: Sondra Stewman, 564-4750 Forum .1 c~,,~r~4_ ~ev.r-~611~188 Submit In Duplicate i ii i OP ra i fi s0 ma RePort Legal Well Name: MPF-65 Common Well Name: MPF-65 Spud Date: 3/25/1997 Event Name: WORKOVER Start: 9/13/2002 End: 9/17/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/17/2002 Rig Name: NABORS 4ES Rig Number: 4ES Fro~: ~: ~8~rs i: ~ ]~ : i : Description of Operations 9/15/2002 00:00 - 06:00 6.00 RIGU 'P PRE MI/RU & ACCEPT RIG @ 0600 HRS. 9/15/2002 06:00 - 09:30 3.501 KILLP DECOMP SPOT & BERM KILL TANK/RIG LINES TO TREE & TEST TO .00 3500 PSI. ;09:30 - 10:30 1 KILL P DECOMP RIG LUBRICATOR & PULL BPV. 10:30 - 15:30 5.00 KILL P DECOMP ClRC WELL BORE WITH HOT SEAWATER. ;15:30-16:00 050 WHSURiP DECOMP SETTWC&TEST 16:00 - 17:00 1.00 WHSUR P DECOMP NIPPLE DOWN TREE. 17:00 - 18:30 I 50 BOPSUR[P DECOMP NIPPLE UP BOP i 18:30 - 21:30 3.00i BOPSURP DECOMP TEST BOP TO 250 LOW & 3500 HIGH TEST WAIVED BY ! I LOU GRIMALDI WITH AOGC 21:30 -22:00 0.50 BOPSUF:P DECOMP RIG LUBRICATOR & PULLTWC. 22:00 - 23:00 1.00 PULL P DECOMP PULL & LAY DN HANGER. 23:00 - 00:00 1.00 PULL P DECOMP POOH WITH ESP COMPLETION 9/16/2002 00:00 - 10:00 10.00 PULL P DECOMP PULL ESP COMPLETION & LAY DN PUMP & MTR & ALL EQUIPMENT RECOVERED. 10:00 - 14:00 4.00 RUNCOI~ COMP MAKE UP ESP ASSY. 14:00 - 00:00 10.00 RUNCOIVP COMP RIH WITH ESP ASSY. 9/17/2002 00:00 02:30 2.50 RUNCOr~ COMP RIH WITH ESP COMPLETION TO SETTING DEPTH @ I j 16347' 02:30 - 05:30 3.00 RUNCO COMP MU HANGER & MAKE EFT CONNECTOR & ATTACH TO ' SAME & LAND & RILDS & TEST. [05:30-07:00 1.50 BOPSURP COMP SETTWC &TEST& NIPPLE DN BOP 07:00 - 08:30 1.50 WHSUR P COMP NIPPLE UP & TEST TREE & TEST SAME. TO 5000 PSI. 08:30 - 09:00 0.50 WHSUR P COMP PULL TWC & SET BPV &SECURE TREE AREA. & RELEASE i RIG I 1 I SCANNE._ NOV O 5 200z Printed: 9/25/2002 4:08:49 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Water Block Treatment Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 42 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 196612 Stratigraphic._ Anchorage, AK 99519-6612 Service__ Milne Point Unit 4. Location of well at surface 8. Well number 3179' FNL, 2520' FEL, Sec. 06, T13N, R10E, UM (asp's542042, 6035554) MPF-65 At top of productive interval 9. Permit number / approval number 2141' FNL, 2280' FEL, Sec. 29, T14N, R10E, UM (asp's547451, 6047183) 197-049 At effective depth 10. APl number 1908' FNL, 1878' FEL, Sec. 29, T14N, R10E, UM (asp's547850, 6047418) 50-029-22752-00 At total depth 11. Field / Pool 1873' FNL, 1864' FEL, Sec. 29, T14N, R10E, UM (asp's 547864, 6O47454) Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 16853 feet Plugs (measured) true vertical 7818 feet Effective depth: measured 16755 feet Junk (measured) true vertical 7728 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" 260 sx Arcticset I (Approx 139' 139' Surface 8573' 9-5/8" 1767 sx PF 'E', 800 sx 8604' 4633' Class 'G' Production 16811' 7" 300 sx Class 'G' 16840' 7807' Perforation depth: measured Open Perfs 16471'- 16491' i~:'~ ~... ~,,.,,., ~.i, !~ !:~ i!.., ;,-, true vertical Open Perfs 7473' - 7491' , IUi~. 'i ,.'-'~,,,. ,._,,,-'rH,'~),,,.. Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 16347' A~aSk8 IJit .& d~.5 (;0i' S. -Oty~'itl'r~iSs~0~' Anchorage Packers & SSSV (type & measured depth) No Packer (ESP pump in well). Sidepocket KBMM GLM Camco 2-7/8" x 1" @ 139' 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 07/12/2002 875 197 1 367 Subsequent to operation 07/17/2002 848 196 0 371 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true, and correct to the best of my knowledge. ,~~_~-4~,.~~ Title: Technical Assistant Date July 18, 2002 DeWayne R. Schnorr Prepared b)/DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · MPF-6$ DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/16/2002 WATER BLOCK TREATMENT EVENT SUMMARY 07/16/O2 HB&R RIGGED UP TO THE IA AND PUMPED 295 BBLS DEAD CRUDE TO FILL IT, PUMPED AT 2 BPM FROM 450 TO 1100 PSI. SWITCHED TO THE TUBING AND 5 BBLS EC9610A, PUMPED AT 1.5 BPM AT 600 TO 1000 PSI. SWITCHED TO DIESEL FOR SPACER, PUMPED 50 BBLS AT 1.5 BPM AT 1100 PSI. SWITCHED TO ACID, PUMPED 5 BBLS OF 7.5% DAD ACID, PUMPED AT 1.5 BPM AT 1100 PSI. SWITCHED TO DEAD CRUDE FOR DISPLACEMENT, PUMPED 95 BBLS AT 1.5 BPM FROM 1100 TO 2150 PSI. CONCLUSION: JOB WAS COMPLETED WITH NO PROBLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT BACK ON LINE. FLUIDS PUMPED BBLS 5O DIESEL 39O CRUDE 5 EC9610A 5 7.5% DAD ACID 450 TOTAL Page 1 .SCANNED JUL 3 Tb9 Spoo~ : Ii" x 7 1/16" 5M FMC, Gen ~ Orig. KB Elev. = 42.30' (N 22E) Tbg Hng: 7~ x 27/8' 8 rd b(~0m x 3" LH i RT TO Tbg. Spoo~ = 28 5' (N 22E) Acs~e ~ift thre~l, 25 B PV CIW H Camco 2'7/8" x 1' ~ KOP ~ 300 to 4000' sidepocket KBMM GLM 77de9. 4,000' - 14,500' M~ hole angle: 77 deg. i Ho~e angle thru' perfs = 27 deg. 9 5/8", 40 ppf, L-80 Btrc j ~ ~ i 7" 26 ppf. L-80, NSCC production casing :~ ~ ) Marker Jts 16,227' to 16,267' RKB. ~¢~/_ 7586' tvd BP EXPLORATION (AK) STATE OF ALASKA ALASKA' L~L AND GAS CONSERVATION COMMI;:,c~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 42.30' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2101' NSL, 2520' WEL, SEC. 06, T13N, R10E, UM MPF-65 At top of productive interval 9. Permit Number / Approval No. 197-049 3138' NSL, 3000' EWL, SEC. 29, T14N, R10E, UM 10. APl Number At effective depth 50-029-22752-00 3370' NSL, 3400' EWL, SEC. 29, T14N, R10E, UM 11. Field and Pool At total depth ~ Milne Point Unit / Kuparuk River 3406' NSL, 3415' EWL, SEC. 29, T14N~ .R10E, UM Sands 12. Present well condition summary :. Total depth: measured 16853 feet Plugs (measured) true vertical 7818' feet Effective depth: measured 16755 feet Junk (measured) true vertical 7728' feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 260 sx Arctic Set (Approx.) 110' 110' Surface Intermediate Production 8573' 9-5/8" 1767 sx PF 'E', 800 sx 'G' 8604' 4633' Liner 16089' 7" 300 sx Class 'G' 16840' 7807' , Perforation depth: measured 16741'- 16491' VED true vertical 7473'- 7491' '~/G 0 ~ ,200 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 16347' A/aska 0//~ Gas A°Choroo~ C°mmiss/on Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil. Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Technical Assistant Date (~)~ Signed~..._s Ti_.tle Prepared By Name/Number: Sondra Stewrnan, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate ION: : Page lofl Report Legal Well Name: MPF-65 Common Well Name: MPF-65 Spud Date: 3/25/1997 Event Name: WORKOVER Start: 6/27/2001 End: Contractor Name: NABORS Rig Release: 7/2/2001 Rig Name: NABORS 4ES Rig Number: Date '~ HoursActivitycOde NP'F l~: i:i ~: Description of Operations 6/28/2001 12:00 - 00:00 12.00 MOB P PRE MI/RD & FIX 3-FLATS DURING RIG MOVE. 6/29/2001 00:00 - 06:00 6.00 MOB P PRE MI/RD & BERM & SAFE OUT EQUIPMENT. 06:00 - 08:00 2.00 KILL P DECOMP RIG TIGER TANK & LINES TO TREE & TEST SAME TO 3500 PSI. & PULL BPV. 08:00 - 13:00 5.00 KILL P DECOMP KILL WELL BY ATTEMPT TO CIRC DN TBG. FRICTION PSI. HIGH & REVERT TO BULL HEADING DN ANNULUS & BULL HEADING TBG. VOLUME. AT I -BPM 3200 PSI,. 13:00 - 15:00 2.00 WHSUR P DECOMP SET TWC & TEST & NIPPLE DN TREE. 15:00 - 17:00 2.00 BOPSUR P : DECOMP NIPPLE UP BOP 17:00 - 20:00 3.00 BOPSUF P DECOMP TEST BOP TO 3500 PSI. & 350 LOW (TEST WAIVED BY LEW GRIMMALDI WITH AOGC. ) 20:00 - 21:30 1.50 BOPSUF:P DECOMP PULL TWC & HAD OIL & GAS INFLUX IN TBG. THAT HAD MIGRATED BACK UP TBG. DUE TO NOT BEING ABLE TO FLUSH CLN AT LOW PUMP RATE CIRC. 21:30 - 00:00 2.50 BOPSUF,P DECOMP MU LANDING JT. & BOLDS & ATTEMPT TO PULL HANGER TO FLOOR AT 80 % OF TENSILE. PARTED PULLING TOOL AT STL PIN & DROPPED HANGER APP 8-10' 6/30/2001 00:00 - 03:30 3.50 PULL N DECOMP WAIT ON SPEAR & CONTINUE TO MIX & PUMP EP-LUBE. 03:30 - 04:30 1.00 PULL N DECOMP PU/LANDING JT. & MU SPEAR & SPEAR PARTED XO & BACK OUT & PULL TO FLOOR & LAY DN & RE-RUN SPEAR & SPEAR HANGER & WORK TO TENSILE ALLOWED OF TBG NO GOOD & RELEASE SPEAR & LAY DN SAME. 04:30 - 07:30 3.00 PULL N DECOMP CIRC & PUMP EP-LUBE 07:30 - 09:00 1.50 PULL N DECOMP MU 3" LH ACME PULLING TOOL & MU INTO HANGER & WORK TBG TO 90% OF TENSILE 135 K LH ACME PULL BOTTOM TWO THRDS. & LAY DN SAME 09:00 - 13:00 4.00 PULL N DECOMP CIRC & MIX & PUMP EP-LUBE NTO SEAWATER WITH 30 VIS TO MAKE IRON WET. 13:00 - 14:00 1.00 PULL N DECOMP MU SPEAR & SPEAR 2-7/8" BELOW HANGER & PULL SAME TO FLOOR AT 80 % OF TENSILE (NOTE:IT REPRESENTS THAT EP-LUBE GREATLY REDUCES FRICTION PRESSURE WHEN APPLIED IN RIGH AREA OF METAL TO METAL CONTACT. 14:00 - 00:00 10.00 PULL P DECOMP POOH WITH ESP COMPLETION 7/1/2001 00:00 - 04:00 4.00 RUNCOI~P COMP RIH WITH 10-DC & PUT RTTS ON TOP & SET @ 30' 04:00 - 08:30 4.50 WHSUR ~ COMP MU & RIH HANGER & TEST FROM BELOW & ABOVE 3500 PSI. & LAY DN HANGER & PULL RTTS & LAY DN & LAY DN HANGER. 08:30 - 00:00 15.50 RUNCOI~ COMP PREP & MU ESP ASSY & TEST & RIH WITH ESP COMP. 7/2/2001 00:00 - 06:30 6.50 RUNCOI~ COMP LAND HANGER & TEST TO 3500 PSI. & SET TWC 06:30 - 08:00 1.50 RUNCOI~ COMP NIPPLE DN BOP 08:00 - 09:00 1.00 RUNCOI~ COMP NIPPLE UP TREE & TEST TO 5000 PSI. 09:00 - 10:00 1.00 RUNCOI~ COMP P/U LUB & PULL TWC & SET BPV & RELEASED RIG @ 1000 HRS. 7/2/2001 Printed: 7/9/2001 3:49:45 PM ON OR BEFORE ANUARY 03 2001 c:LO~]Lt~.DOC PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS 97-049 GR/CCL /.~ 8350-16550 97-049 CDR-TVD ~100-7750 97-049 ADN-MD ~'~500-16750 97-049 CDR-MD ~'8625-16800 97-049 ADN-TVD ~4600-7700 97-049 PERF ~/~.6471-16491 97-049 MMS SRVY '~SPERRY 8550.3-16853 97-049 MMS SRVY ~SPERRY 0-3885.3 97-049 DIR SRVY ~SCHLUM 0-16853 97-049 GYRO MULTI SHOT ~YRODATA 0-16601 Page: 1 Date: 05/24/99 RUN RECVD FINAL 06/19/97 FINAL 06/19/97 FINAL 06/19/97 FINAL 06/19/97 FINAL 06/19/97 FIANL 07/03/97 08/29/97 08/29/97 08/29/97 08/29/97 10-407 ~...._~O_~B~ETION DATE @ ~/l~ I ~ ~ DAILY WELL OPS R © ] ~'~/q? / TO ~ /!~/~,~/ Are dry ditch samples required? yes ~___And received? Was the well cored? yes ~_Analysis & description received? Are well tests required? yes ~~ceived? -~~ Well is in compliance Initial COMMENTS T D BOX -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-49 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ,¢ ........ 50-029-22752 4. Location of well at surface ~ ~'~';"~!~- i~?''~ 9. Unit or Lease Name 2101' NSL, 2520' WEL, SEC. 06, T13N, R10E, UM ~ .... '.;~- ~ ~, _F._F._F._F._F._F._~ ~...~__, Milne Point Unit At top of productive interval ~ "~'.~ ~..-.~¢~>,~,~ il 0. Well Number 3246' NSL, 3301' EWL, SEC. 29, T14N, R10E, UM i ~L-;¢;; ~i ~-~~ MPF-65 At total depth :~"~ .... i: !'~ 11. Field and Pool 3328' NSL, 3553' EWL, SEC. 29, T14N, R10E, UM .............. *;Z/-'~ l:¢t ~ ~ Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No~"~ Sands KBE = 55'I ADL 355017 12. Date Spudded 113. Date I.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 3/25/97 4/6/97 6/16/97 MSLJ One 17. Total Depth (MD+TVD)16853 7818' FTII18' Plug Back Depth (MD+TVD)I19' Directi°nal Survey 120' Depth where SSSV set 121' Thickness °f Permafr°st16755 7728' FTI [~] Yes [~No MD 1800' (Approx.) 22. Type Electric or Other Logs Run GR/CDR/CDN 23. CASING, LINER AND CEMENTING RECORD CASING SE'FFING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 Surface 110' 24" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 31' 8604' 12-1/4" 1767 sx PF 'E', 800 sx 'G' ..... 7" 26# L-80 31' 16840' 8-1/2" 300 sx Class 'G' 24. Perforations oPen to Production (MD+TVD Of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3 3/8" at 6 spf 2 7/8" 6.5 L-80 16272' MD TVD MD TVD ,, 16471 '-16491' 7472'-7490' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ...... ORIGINAL DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED .... 16471 '-16491' 94,654 lbs 16/20 Pr°ppant Refrac with 131,708 lbs 16/20 Proppant .... 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/29/97 t Electric Submersible Pump Date of Test Hours Tested iPRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (~ORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None REEE V. ,D AUG 29 1997 Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TKUP 16196' 7229' TKA3 16440' 7444' TKA2 16458' 7460' TKA1 16485' 7484' 31 i"'l'"i'st of Attachments Summary of Daily Drilling Reports, Surveys ,,, 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ChipAIvord .,~/'~.~_ ~ ~)'/~., Title Senior Drilling Engineer Date MPF-65 97-49 Prepared By Name/Number: Jeanne Haas, 564-5225 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator BP Exploration Date 01:00, 28 Aug 97 Page 1 The analysis is from - 14:00, 01 Apr 97 - to - 14:00, 01 Apr 97 Programs in Result Table: MPF-65 DRILL AND COMPLETE Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) MPF-65 Event 14:00, 01 Apr 97 14:00, 01 Apr 97 0 hr 0 min Obtained leak off 15.000 Hole Size MDR 8-1/2 Facility M Pt F Pad Progress Report Well MPF-65 Page 1 Rig Nabors 22E Date 27 August 97 Date/Time 24 Mar 97 25 Mar 97 26 Mar 97 27 Mar 97 28 Mar 97 29 Mar 97 30 Mar 97 31 Mar 97 15:01-16:00 16:00-05:00 05:00-06:00 06:00-08:30 08:30-14:30 14:30-15:00 15:00-16:30 16:30-17:00 17:00-06:00 06:00-09:30 09:30-10:30 10:30-11:30 11:30-12:00 12:00-12:30 12:30-05:00 05:00-06:00 06:00-06:30 06:30-09:30 09:30-10:00 10:00-11:30 11:30-06:00 06:00-10:30 10:30-11:00 11:00-13:30 13:30-14:00 14:00-17:00 17:00-19:30 19:30-23:30 23:30-00:00 00:00-01:00 01:00-03:30 03:30-06:00 06:00-18:00 18:00-19:30 19:30-20:30 20:30-21:00 21:00-23:30 23:30-05:30 05:30-06:00 06:00-07:00 07:00-07:30 07:30-19:30 19:30-22:30 22:30-00:30 00:30-01:15 01:15-01:30 01:30-05:00 05:00-06:00 06:00-06:30 06:30-06:45 06:45-08:00 08:00-09:00 09:00-11:00 11:00-13:00 Duration 3/4 hr 13hr lhr 2-1/2 hr 6hr 1/2 hr 1-1/2 hr 1/2 hr 13hr 3-1/2 hr lhr lhr 1/2 hr 1/2 hr 16-1/2 hr lhr 1/2 hr 3hr 1/2 hr 1-1/2 hr 18-1/2 hr 4-1/2 hr 1/2 hr 2-1/2 hr 1/2hr 3hr 2-1/2 hr 4hr 1/2hr lhr 2-1/2 hr 2-1/2 hr 12hr 1-1/2 hr lhr 1/2 hr 2-1/2 hr 6hr 1/2hr lhr 1/2 hr 12hr 3hr 2hr 3/4 hr 1/4 hr 3-1/2 hr lhr 1/2 hr 1/4 hr 1-1/4 hr lhr 2hr 2hr Activity Rigged down Drillfloor / Derrick Rig moved 100.00 % Rigged up Bell nipple Rigged up Bell nipple Made up BHA no. 1 Held safety meeting Drilled to 255.00 ft Made up BHA no. 1 Drilled to 1559.00 ft Drilled to 2213.00 ft (cont...) Circulated at 2213.00 ft Pulled out of hole to 188.00 ft Serviced Drillfloor / Derrick R.I.H. to 2213.00 ft Drilled to 4455.00 ft Circulated at 4455.00 ft Circulated at 4455.00 ft (cont...) Pulled out of hole to 0.00 ft Serviced Top drive R.I.H. to 4452.00 ft Drilled to 6743.00 ft Drilled to 7024.00 ft (cont...) Serviced Mud pumps Drilled to 7148.00 ft Repaired Mud pump fluid end Drilled to 7401.00 ft Circulated at 7401.00 ft Pulled BHA Serviced Top drive Made up BHA no. 2 R.I.H. to 7401.00 ft Drilled to 7604.00 ft Drilled to 8625.00 ft (cont...) Circulated at 8625.00 ft Pulled out of hole to 6720.00 ft R.I.H. to 8625.00 ft Circulated at 8625.00 ft Pulled BHA Rigged up Casing handling equipment Rigged up Casing handling equipment (cont...) Held safety meeting Ran Casing to 8604.00 ft (9-5/8in OD) Circulated at 8604.00 ft Mixed and pumped slurry - 560.000 bbl Displaced slurry - 646.000 bbl Functioned DV collar Circulated at 1306.00 ft .?~ Mixed and pumped slurry - 200.000 bbl Mixed and pumped slurry - 287.000 bbl (cont...) Displaced slurry - 99.000 bbl Cleared Mud shakers ~$~ down Cement head .... ~'~ ~~-gi~~ Rigged Rigged down Bell nipple .......... Installed Wellhead primary components Facility Date/Time 01 Apr 97 02 Apr 97 03 Apr 97 04 Apr 97 05 Apr 97 06 Apr 97 07 Apr 97 M Pt F Pad Progress Report Well MPF-65 Rig Nabors 22E Page Date Duration Activity 13:00-15:30 15:30-16:00 16:00-18:30 18:30-19:00 19:00-19:30 19:30-22:00 22:00-22:30 22:30-23:30 23:30-00:00 00:00-01:00 01:00-06:00 06:00-06:45 06:45-09:00 09:00-10:00 10:00-11:00 11:00-11:45 11:45-12:00 12:00-13:00 13:00-14:00 14:00-06:00 06:00-11:45 11:45-13:30 13:30-14:30 14:30-15:30 15:30-16:30 16:30-06:00 2-1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr lhr 1/2 hr lhr 5hr 3/4 hr 2-1/4 hr lhr lhr 3/4 hr 1/4 hr lhr lhr 16hr 5-3/4 hr 1-3/4 hr lhr lhr lhr 13-1/2 hr Rigged up BOP stack Made up BHA no. 3 Tested BOP stack Retrieved BOP test plug assembly Installed B ore protector Made up BHA no. 3 Tested MWD - Via string Serviced Block line R.I.H. to 1306.00 ft Drilled installed equipment - DV collar Singled in drill pipe to 8307.00 ft Singled in drill pipe to 8307.00 ft (cont...) Circulated at 8517.00 ft Tested Casing Serviced Top drive Drilled installed equipment - Landing collar Drilled to 8645.00 ft Circulated at 8645.00 ft Performed formation integrity test Drilled to 10561.00 ft Drilled to 11028.00 ft (cont...) Circulated at 11028.00 ft Pulled out of hole to 8604.00 ft Serviced Top drive R.I.H. to 11028.00 ft Drilled to 12518.00 ft 06:00-05:00 05:00-06:00 06:00-07:30 07:30-09:00 09:00-10:00 10:00-12:00 12:00-13:30 13:30-14:00 14:00-02:30 02:30-04:30 04:30-06:00 06:00-10:00 10:00-11:00 11:00-12:00 12:00-13:00 13:00-14:00 14:00-15:00 15:00-21:00 21:00-06:00 06:00-00:30 00:30-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-07:30 07:30-08:30 08:30-16:00 16:00-17:00 23 hr lhr 1-1/2 hr 1-1/2 hr lhr 2hr 1-1/2 hr 1/2 hr 12-1/2 hr 2hr 1-1/2 hr 4hr lhr lhr lhr lhr lhr 6hr 9hr 18-1/2 hr 2-1/2 hr lhr lhr lhr 1-1/2 hr lhr 7-1/2 hr lhr Drilled to 14519.00 ft (cont...) Circulated at 14519.00 ft Circulated at 14519.00 ft (cont...) Pulled out of hole to 11028.00 ft Serviced Top drive R.I.H. to 14519.00 ft Drilled to 14614.00 ft Circulated at 14614.00 ft Drilled to 15304.00 ft Circulated at 15304.00 ft Pulled out of hole to 10000.00 ft Pulled out of hole to 500.00 ft (cont...) Pulled BHA Made up BHA no. 4 R.I.H. to 1600.00 ft Serviced Top drive Serviced Block line R.I.H. to 15304.00 ft Drilled to 15670.00 ft Drilled to 16853.00 ft (cont...) Circulated at 16853.00 ft Pulled out of hole to 14000.00 ft R.I.H. to 16853.00 ft Circulated at 16853.00 ft Circulated at 16853.00 ft (cont...) Dropped EMMS survey barrel Pulled out of hole to 500.00 fl Pulled BHA 2 27 August 97 Facility Date/Time 08 Apr 97 09 Apr 97 10 Apr 97 11 Apr 97 M Pt F Pad Progress Report Well MPF-65 Page 3 Rig Nabors 22E Date 27 August 97 Duration Activity 17:00-18:00 18:00-19:30 19:30-20:30 20:30-21:00 21:00-05:30 05:30-06:00 06:00-17:00 17:00-17:30 17:30-20:30 20:30-20:45 20:45-21:15 21:15-23:00 23:00-00:00 00:00-01:00 01:00-03:00 03:00-06:00 06:00-09:00 09:00-12:00 12:00-20:00 20:00-22:00 22:00-23:00 23:00-06:00 06:00-06:00 06:00-01:00 lhr 2hr 3hr 3hr 3hr 8hr 2hr lhr 7hr 24 hr 19hr Serviced Top drive Tested Top ram Rigged up Casing handling equipment Held safety meeting Ran Casing to 8516.00 ft (7in OD) Circulated at 8516.00 ft Ran Casing to 16840.00 ft (7in OD) Rigged up Cement head Circulated at 16840.00 ft Pumped Fresh water spacers - volume 90.000 bbl Mixed and pumped slurry - 61.000 bbl Displaced slurry - 641.500 bbl Rigged down Casing handling equipment Installed Seal assembly Rigged down BOP stack Installed Tubing head spool Installed Xmas tree integral components Freeze protect well - 70.000 bbl of Diesel Laid out 5in drill pipe from derrick Racked back drill pipe Serviced Block line Serviced Mud shakers Serviced Mud shakers (cont...) Serviced Mud shakers -~: 5RN ~%'01 16:52 No.O08 P.O1 AFL No: 347097 Repo~No; I Jute: 0/1 O/g7 ~n~plo~on D~ .{: 0 J.NEW Well: MPU F-65 ~D: 1G,a40 PBD: t 8,755 Jl°p of Fill: Contr~on NABORS 4ES* "~hono: 4154~¢~,~.1Dai~y S~6,16.1 . ~wolm~cos~s:c°MP ~.~_T,,_~__ ~lcummw., co.,, ..... -' Ilnterm~late (PrecluSion) Csg: 7"260 BTC LB0 ~ 16,840 Operafloh at 0600: RIH W/2 7/8 WK STRING TO RET/RBP ~ize~e~thPr~uctlon Mner: IPeNoratod Int~: 16,471-16,491 Su~a~ Csg. p=i: I~i~n/D~nfh~La~ Gag qig A~pt (hr/date): 0700-G~9.97 ' Rig Rol~ae (hrldato): - ' Pump No. I Liner Size: 6 X 12 9PM: " GPM: ' . psh Biow ~ump Rate: SI~ Pump Da~ No. 2 ~ner ~ize: 6 X 12 SPM~ ' GpM; ' psi: - · Slow Pump Rate: Slow Pump psh ' - · . FIu~ ' ' 'BRINE ' ~Over' Daily ' - -... T~al Dail~ ~FIu~-- ~pe: balance: Loss:J ' ' B ' ~ss: ~st: ICoat: ~.,...o,.. ., i.v~.=_ ;hlorides:- . 'iF!uid L~.: [:mp (pit),- IE.S. (OBM), p_~Wt~. Data - / ' ' ' .. BHADe~riPtlon: RBP R~ TOOL 2 7/8 TBG . . - . . , ~ · , =, , .. . . .. . . . .. . . .- " ' '! i .o.,. . . Bit& Bit Num:~" Size: Make:'- ' Ou~: ,, · ,. .._~? .· .. .Mi!! ~epth- . " Ftg: ''. Hrs: '- IROP~ . . '- I RPM' '- ' IW~ 'lCondition' O~t; , ... : ,- , ~oume: " .VolUme: ' Type Fluid: .. -~ injeoUo~!. Rate: '~E~. · .... '-, Well;- . '. " . : ' . . '"-- .Daily. V~um:.: ~ ,., , .~ummulative".. , .. .. . , B~Li vo,ume¢. ,, . ' .: . .~ Erea~ Prote~ Fluid: : . . ,,, ~, _ ~, · . . ...: - : - ~.:. - . . . .. · , - :* . , -- . ".~f ' ~ -~uel&WaterData : ' ' ' ~ "' ' Fuel '" 875 ' ~- ':l~d~l' . bpX ' - [Fuel ~ ' - - - IDfl. Water ' 740 ' tDH. Water .... Used: ~al ~8oume: ' ' IRe~d: ' gallUsOd:' ' ' D~Iv; .... pUmulative: /Storage ' '~' 8pe~: BBdOOuroo: ; ' lW~nd IOhill Fa~r: '. CFI ..... --.~].at' . .... -. ,, _ . . . . mphl ,. , _ ..... ' ~st BOP~ Tern: '~9/97 ' Last BOp Dflll: ~/97 ']~ H2S.Drllh Data · -. . S/~97 ~stFIr°DHIl: 6~/97 ~'~af~Mtg: ~t Spill '6rill: 6~/97' Spill ~m)? N ; /~olu~ (Gals.):. Type S~i¢l~ ' Repo~ Filed? .... ~ident? (YIN) -N ' INam.: ' IEmployen " .IRpt ~iled? (Y/N) , ¢ , , , ~mo. '~peration Prob ~e H'r~. Operatlo~ From 06~ to ~ . .**NO Spl~0,-N0 ACCidEnTS"073 DSLT~'"lO3 DSLS "' . . 0600-07001- MIRU~ ' ... I ' ' MIRU ON MPU F~5'~**A~P~ RIG 07~ HRS 6-0-e7 - - 0~-~0~ I-' -NUrND " 3 ' NDTREE,NU BOp ,PULL 7".B~,INSTALL'TEST P~'UG ' ' ' - 10~-1.300 TEST - ~ TEST BOP 2508 5000~,~ULL TEsT'PLUG INSTALL WEAR RI~G~ -' - ..-. " ~ ' '- TE~T WITNESS BY BOBBY FOSTE~AOGGG", -. . . 1~00-1700 RN TBO ' ' 4 Lo~D"PIPE SHED W/27/8 WRK SRNO,PL PROTEC,bRI~,SL~ ' ' . . . ,,*,, ,- 1700--1730 RN-TBO .5 MU RBP RET TOOL, RIH WI2 7/8 WRK STRNG '1730-19~ CIRG ' I -1 .5 CIR~"'YHRU.ICE PLUG F/140--300' ' ' ' '" : . '1900~2030 . RN.~G ~ . - 1.5 RI~ 1125'/HANGING UPON WEAR:BSHNG.POH INSPECT WE~h BSHNG ' . . Z030-22~ RN TBO . 1.5 RIH TO200~'-; . ' --. '.'* -'-" . ~-~23o "ClRC ' .5 OIhC OUT FREEzE-PROTCT ' . 2230-06~ RN ThO' - 7.5 -'~0NT RIH W/2.7/8 T8G W/'RBP RET' TOOL ,, = ~ ,=, . . i , i== , . . , , ~ , ~ , . .; , ,i ,,~ ,, , ~ , ,~_ ,, · . , . __ · ~' JFIN -'01 16:S4 No.O05 P.O1 -~rl ~lh~. I~? 'AI~I~. I No:~ 2= ~' ate: - 6/11/~17 Completion Da' ~,c 5 Sul3v Init'. ' J.NEW . Contractor: NABoRS 4ES rhone: 41~leo.l,,lDaily $~,734 IwoICU~c~t,;C°mp $118,895 J Wall . J lntermdiato ~r~ffilon) OeO; " ' Operation at 0600: RIH W/4.6 WRK STRNo 18~~h . 7'26~BTC/L00~ 1~,840 ~iTn/DnnthPr~u~ion Liner; J Pe~omted I~1: 16,471~--16,~9 Suds~ C~. p~: l~l~n~eothJLaat C~g -Te8~ · ~lg ~opt (hr/date): 0700~:~-9~ Rig Relea~ (hCdate); ..... Pump No. 1 Liner Size:. 6-X 12 SPM: ...... OPM: ~i: ~Ow Pu~ ~t~': ' slew pump psh "' ~ pei: " Da~ No. 2 Liner Size: 6 X 12 ~PM; GPM; Slow Pump RaI~ Slew Pump psi:'. · _ Fluid BRINE I°ver o~,y j' T~al J Daily JCum ...... Fluid Type:. _ I bala~: ' Leas: BB ~ss: .... I ~6t; IOost; , Data Weight: 8.8 [Vis: ' JPv~P: / :hlogdes: .... JFluld~ss: [omp(pit): JE.S.(OBM): r/. wtr: .. BHA De~riptlon: . . - - - MULE SHO~16 JT~ NSCT 3.6.Xo,4:BTBG ' ~"' - =" ' ' - . . , , , ~t': , , . ,~ ...... Inie~n D~ ta ' · ~urae: - . Volume:- - - rypa Flu~: ' ' Injection . IRate: ' - ' JProaeure: ' - W~II; " ~pml -' P~ -- ~BLI Volume: _BBL " - ' : Freeze p~o'~ Fluid: ' ' - [Volume:. -. gal .... ...... _ - Fg~! ~ W~t~f P~g " " -- JDrl.'Water- Fuel 746 . J F~I - . JFuel ' - JDd.' Water 521 Used: . gal J Source: JReov'd: " ' flal lUsod: ' . Cu~lnas -Dat~ . . - - ' ~peed: D~,~ C~umulmlve:' ' -'"' C..,.~JSt°rage' .. · -.,Iw'"'. . - mphlOhlllFi Ir: -~"' ~,'"","': -'. N ...... ffo~ume (Gals.):' ppe Sp,~ ' ' _-.Re~" Filed? . ~md0nt? ~/N) "-N' JNa~; .: __'"'_ --, ". ~ J~m~Oy*~ .' JRpt Filed? (Y/N) ' 'l'-..'.. - , .... -. . , Time OPeration Pmb ~e Hr~ ' * operaflo~ From 06~ to 0600 - ' ...... :' . - :;NO SPILLS*'NO ACCIDENTS*' 674 DSLTA-- I'~'D~LS;" -~00-~30 - ' RIGSER ' ;5.. LUBRIG: ; -- . -~:-.' - ' - - ........ '- ~30~730~ -. RN TBG "* ': '- - - 1 ..~ PU 2 718 TBG-RIH,TO 16250' ' 07~0-!030 RN TBG- -- .. -- -- 3-. ',DISP~CE-~E~--W/8'7 BRINE,GAS/~ODE:-IN R~URNS - · . ........ -1030;1100 ' CIRC .'- " ,5 CIRC DWN OVER'RBP,~I~,280,OPEN.EQuL VALVE,MON WELL,STATIC. "" " " ' ' . PULL?~00OVER. REL~SE RBP;RIHTO 16,313. ' · ' - " " . 110~1430: OlRO ' . -.: '-' '~:-5 """OlRC'B~M~ up~ILAND GAS, B~MS'UP,MON ~E.LL STATIC .. . -143~2~0 PL .TBO " 6 TOH W/g 7/8 T~ W/RBP& RUN TOOL ' .. . 2030-2230 .TEST . -. ' 2. - P-ULL' WEAR BOHNG CHNo R~M~ TO 4,S,TEST ~AME .' .~30-2330- BNTaG .- -'" -' ' .-1 . RIG-TO RUN4.5, 8TR'~h'BHA .... ' · - ........... 2330-06~ -RNTBG' ' . , ' . 0.5; RIH W/4.SWRK sTRNG " -' ": ............ .- . . . . [...~ ,~ _ _ · . -- 11... · . -. . . . . ,,, , . _:q , ___ .... ~-~= 5RN '0~ ~6:22 No.O0~ P.0~ BrlJdhq~. Rsv Drillinn ~- ,,, r .... Daily (;c~mnl~tlnn/wnrKdv~.l AF~ NO: 3470~7 J Repo~No; ' 3.'ate; 6/12/97 Completion D~y, , t:,5 ' ]Su6v. Init: myers MPM F-65 FD: 16.840 ~BD; 16,756 IT°P O~ C'°ntrnctor: NABORS4E~' r~ne:' 4154 i~"ily $22,734' 'lou~o°m~ $141,629 iC~mm ~l~t [WO Cq~ts: Wall .... I In(ermediate (Pr~umion) Ceg: 7"26ffBTC/LS0"~ 6,840 O~ration m 0600: WASH FRAC; SD. O~ OF 7" CSG. ~rod~lon Uner: IPe~orat~ I~1:' 16.471--16.49 Sudece tag. psi: I~st Csg Te~= Ri?n~nnthI' 1 ' .. J RiTn~nnth Rig A~ept (hr/date): ~ 0700~-9-97 Rig Releaee (hr/date): .~u~p No, I Liner Size: 6.X 12 SPM: ; GPM: psi: Slow'Pump Ra~: Slow Pump psiS" Da~ No. 2 Liner size: 6 X 12 SPM: - ' GPM:' I psi: Slow pump Rate; Slow P~mp psh ' ' ' Coat; . ICost: . aHA De~ripfion: . . ' ' ¢nie~ion Data :' ' '" .... ' Dali? Volume~ . IOummulatlve BBL! y~luma: BBL: ..... - - :"" . Freeze Prote~ Fluid: ' Volume: Fue! ~nler Data - . · Fuel 954 ' I Fuel ..... ~ 1Fuel- . - IDH~Water . IDH. Water · - Cuffinas Da[~ - Wenthnr Date 8af~tv~P ~ntn _ [e~t BOPE Te~ 6_g.gT- ~ BOP OH~: ' 6/12/97 L~ H2~ Drill: 6/11~7 ~st Fire Dfllh 6~/97 Last Safety Mtg: 6/12/g7 ~st Spill DHII; 6/3/97 Spill ~)? . N . Ho~ume-(~S.)~ Ty~-Spill: ' Repo~ Filed? ' ' ~c~dent?'~]N) :'N !N"me: ' ' J~mp,oyen . -. ' .' JRp, Filed? (Y~). -Time Oporation Prob Oode Hrs,. ' ' Operatio~ Pmm-0e00 to 0600 ' .- . _. AOOIBE~8'" DSLTA 67~'t DSL8 135~' oeoo-~ao' FBAO -'.- .6.5 ~N.~. T8 ~¢HWlTH 4,5"'1'B6. FOR FRAG; . . .. ......... 1230-14~' OTHER 1.6 SLIP 1450' DRL6. LINE . 14~-1680 "FRAO · -.'- '- ' 2.~ RIQ. DOWELL & HOLD 8AF~Y MERINO &:~B~T:LINBB'Tb.7000 Pgh & P~RF. . . . F AO.-& S NO NFO. TO TOWN DESIGN. 2000-2100 ' '"~O " -- '1 PUMP FRAO-AS'DESlGN PUMPBD e~B4 ~ OF 1~20 & . ' 31000 ~ BBHI'Nb-~IP~. & LEFT eae54e IN TBG, 80RBBND OUT TO 6000 PSh ' ~oo-~8oo ~Ao ' .7~ = ~ - ~- R~V,.EXOBs8 SD. OUT OF 2~'o~o F'RAO ' "- .1 MONITOR WELL & RIG DN DOWELL EQUIP. & BLEED OF 310 PSI. 8LOWLY o~0-oaa° OLN-OUY " ' 3.s REV. OIRO. & Vis.- BRINE TO 8~ .- '- ...... ~--' ' 0330~430 CLN-OUT .... : ! RIH-WITH 4.5" TBG. TO 16280' ~ TA~ FILL. 0430-0600 CLN-OUT 1,5 - OLN FRAC. SD. OUT OF 7" CSG. 16280' TO 16295~ " A~ER CLN-OUT TO 25' BELOW PERF. & CHG. OVER Tb-~LN FEUt¢'WiL~ ATTEMPT TO RE-FRAO. , .. ...... AFE No: '3470~7 ! Repoff'No: Well: MPU 1=-65. Contrau-'lor:. NABORS 4ES Operation at 0600: ,'D: r hone: 4154 WAIT ON FRAO TO BREAK Produc~10n Liner: :lig AOcePl (hr/dat~): ' - F~id I~J?~e: BRINE . lover Fluid I balance: ... ~ght: 8 8 IWs: IPV~P~ DatR / ' I ! BHA De~Hption: I Perforated Intrvl: 16,471--16,49 0700-6-9-97 .pPM: Dail~ Loss: / f~hlortdes: 6/13/97 JOompletion D~y,-~ . 5 MYERS 46.840 . ITop o, ally' '$152.308 IOumm Comp I Cumm Ilntermdiete (P[~u~lon) ISi~e~enth ~ 7"26~ BTC/LS0 ~ 16,840 _ I sudaco Osg, psi: IL~I Csg Tes~ I Ri~e~e mt h l RIg Relo~e (hr/date): ' ~1: ' Rate; · - Pump pal:. psi:' Pump Ra~; psh BHA No: IBHA., Length; Bit &IBIt Num: JSize: Make: l Ets: lout: - ~ut: ~ource: :ue~ ! ~bol Jsed: ~al I Source: -- Cuttinoa' Data- )ally: cr~UmUlativ°: Last BOFE Test: Last Spill Drill: ~.~=ident? (Y/N) Date Last Inspe~led: [ Type: j-ROP: RO~rypa: ' Inioction Fluid: ISerial INn' IRPM: . ' ISarlel ' IN0:_ RPM: " 1 wt: wt: ta I~oction Woll: Dally Volume: Freeze Protect Fluid: JHours On Jars: 6-g-97 [Last BOP Drill: 6/3/97 - ISpill (Y/N)? N !Name: Volumo: ~,ets/TFA: IDepth In: ,[ . J Oondition: iets/l'FA: ~th In: IOondition: BBL °F IRate: ~pm{Pr0ssure: lCummulative BBLI Volume: .IL'est H2~ Drill: 6/1 s/9~ I~st Fire Drill: 6/1~97 N/A lEtuPI°y°r: rial Fuel & Water Data I FUel -- lDrl. Water I~rl, Water Racy'd: gaI l[,J~; ggLiSource: /Storage rap.: Wind Speed: mphJOhill FaCtor: Cl~ite- ~F - . 6/7/97 N/A Report Flied? Last Safety Mtg: 6/13/97 N/A Filed? (Y/N) Time Operation 0600-1030 CLN-OUT 1030-1~i00 CLN-OUT 1600-2130 CLN-OUT 2130-2200 FRAC 2200-2300 FRAC 2300-0200 FRAC ' Pmb Code D200-0230 FRAC FRAC :)$30-0600 FRAC Operations From 0800 to O6D0 "NO SPILLS"NO'ACCIDENTS** DSLTA 676-- DSLS 136'* REV. SAND F/'15295'---16546' REV. CIRC.. & COND. HOLE. REV. CIRC. & RAISE BRINE WT. TO 8.g PPG. POOH TO 16,000' RIG DOWELL& TEST LINES TO 7000 PSI. PERFORM INJ. TEST & DATA FRAC & FRAC WITH 131708 # 16/20 BEHIND PIPE LEFT 27698# IN TBG. AT SCREEN OUT. & REVERSE OUT SAME RIG DOWN DOWELL ON FRAc CARRIER TO BREAK RIG UFa TO REV, CIRG FRAC SD. OUT OF 7" ... ~: 5RN ~'01 17:23 No.O02 P.O1 AFL NO: 3470~7 ~RepoKNo: ' 5 .ate; 6/14J97 Completi~ Day. _ .. 5 · _[Sudv Ir,it: MYERS Well: MPU F-65 D: 16~840 - PBD: 16,755 . , . . CUmm Con=raster: NABORS 4ES hon~: 4154 [Da~Y - ' $53,584 -I~ ~mp $347,521 Iwaft ~o~ · IWO Costs: I Intermedieto (P~uotl~n).~: ~peratlon at 0600; FILTERING BRINE & RAISE ~ TO g.0 - ISl-~-~h ' ' 7"26~BTC/L80 ~ 16,840 Ri~n~enthPr~l°n Uner:. IPedoratod Int~ ' 16,4711--16,49 Su~a~ ~. psi: . ~LaetR~/Daath~g Test: ' ~ig A~6pt (hr/date): 0700~.~97 -. Rig Releae° (hr/date)t Pump N°. 1 Liner Size,. 6 X 12 SPM: GPM: psi; Slow Pure, Rate: Slow Pump psi= D~ No. 2 Uner Size: 6 X 12 SPM: GPM: : psi: ' Si~ Pump Rate:' ~1o~ Pump pal= = Fluid Type: bal~n~: -Loss: Data . . / , ,.. ...... BHA .De~iption: m Il .. i J . - -. _ .l i ~ ..- O~: ' ,, -, ' , · INs' . .,, Mill Depl~ Fig=. - "' lnloetion ~t~ - - , ' ' ' . ' ' ' DalIV V~ume: - ~u~mul~tive ' . ' ' BBLWOIumO:' BaC .... Froezo Pr~ Fluid: ... vOp~,: · ill _ i _ ~,_ n t ~fi'~i ' 730 ] Fuel ' BpX IFuel ' ' IDd. W,tor - 1900 ' . [Dd. ~d: gal1 ~ource: . . iReoVd;. .5~0., __ gal ]Used: . cuttinfle Pal~ =all~ C~umulaUve:" l~rage- - emp= . : 'lWrnd ~ad: . mphlChill Fa~or: ~st BOPE Te~ 0.9297 I~at,.BOP_ Drill: G/12/97 ~ H2S.DdlI: 6/11/97 ~t'l;iro-Drill: 6/13/97 ~at Safety Mtg: :6/14/97 ' ~t Spill DH!I: ' 6/13/97 I spI,i N ' Volu~ (Gals.):. Typo Spill: .. .Repo~ Flied? ~,dent? (YIN)" N paine= --.... __. :_ ' ., i.,.~ · Time Operation ~r~ C~e' 'Hr~, .Operat~na From 0600 to 0800 - .... "NO ~P. ILL8"NO ACCIDENTS" DOLTA 677"'":DSLO ~8~*' '. ' ' .~-. 06~-16~ cLNTouT - '- /!0.5. REV. CIRc;-FRAC'SD: OUI' OF 7" COG.F/!6002--1~' -. . .= 10~-2000~ O~-OUT ' 4 :~ ~..GIRG~-HI-VI0 SWEEP 5-BPM 800 P01. & MON.IIOR WE~ &.FLOWINO. . 20~2300 C~-OUT 3. REV."CIRC & C~-PITO &' TAKE ON FILTERED BRINE. . 2300.0230 :CLN'-OUT ' - · . 3.5' PUMP CSG.. WASH & FOLLOW WITH a.9.PPG. BRINE (DID NOT PUMP CAUSY!C) -0230~~ -C~UT "-'- - 3.5 RAISE-~. TO 9,0 &.FILTER WITH-BAR01D ' ~ELL FLOWING )~ --'- -'- ~'. . ... ~ ~ · .. . . . . . . . .... . . . : .: - . .' . . - . ,. . . . . . . ~ .' . ... ' . .... .. _ . ... ; .. - . . . _ ~ ' - ' . %2~.' g~.. ~: · . . . .. - . . . . . . : . , · , ,., ,, , ', · . . . . ,. . . _. , L ~ O1 16:16 No.O0:3 P O1 ~-. : BAh' ~-' ' . ..'--'rlJr'Ji~NA l~t~u g~rllllrlC] I )r~llV t ;nmnli~.l'lt~n/V~/nrkc]v'~ ,^r=E .o= a4706'7 .JR.p°~'No: ,6. Da,o: 6/15/97 COmp[etlon Days~Esl: 5" ISurJv. Ihlt: . MYERS Well: MPU F-65 TD: 16.840 PBD: 16,755 JToP of Fill: - ContractOr: NABORS 4Es ~hone: 4154 iDaily $57.53~ ~Cumm Comp $405,056 I Cumm " · Wall k'~. ~,SI~, IW0 I lntermediBte (Production) 0S{l: ' - 3per&ti0n at 0600: RIH W/ESP COMPLETION IR~,~"~pth 7"26#BTC/LB00 16,840 Produolion Liner:. IPerforated !nt'r~4: 16,471--16,41) ~'urface Csg. psi: I~st Cag Test: ~lg ^coopt (hr/date): 0700-~..0-97 Rig Releaae '('hr/date): " ! , Pump No. I Liner Size: 6 X 1 ~ SPM; GPM: ps~;' ~Slow Pump Rate: Slow pUmP psi: _ Data NO. 2 Liner Size: 6 X 12 SPM: GPM: psi: Slew Puml~ Rate: Slow Pump psi: . '°'"' ! ' Fluid Type:. ! b{~lanoe; ' L~s: Loss; Coat: ' ' Data iNelght:- t~.0 IVis: - IPV/YP:_.. / , ~hlorides:' IFluid Loss:.. ~ernp (pR): . IE.E~. (?.B.M): ~/~ Wtr: '" BI-IA Deacriptlon: -. - . . . ' I ' '! "1 . ~it &' ~lt mm:. -. sloe: - -~: "'lrv~i.~ ."- .l~e.al[u~r~^: .... · ~o~ m: . .-"'~ ' ~ / ,. , ~ , ~ ' MI~ Depth' - Ftg; ' H~ . - . .. ~di .. .;? -' ' 'l~l~ ~$~g.'- ' · . . · , .. ' , ' ~o~:. ' ' *~l- j '- --' ' " . . ". Freeze P~e~ FI~: BBLJVolumo: .'. . ,, . .. - _ - , , ,, , :... Volume: . . .. ~ gal .' .. .... - Fuel ~'W~r Dote '- F~ 7~ "IFil ' BPX IFUol . ' IDd, Water O~ GAL - ~d; Water ~KE' U~: 9a~ 18our~: l~d: aallUa~: ' B~Ll~ume: 'L' O~ - ; e~$[~fl: . gat~/~,D~a' ' " _" .... -~ BOPE-To~" G-~97 '- ~t BOP DflU: ~1~07 ~ H~.DHII:' ~11m7' ~ Fire d~tl: ~13m7 ~st 0afety M(g~ . ~1~07 ~st ~pifl D,~I: W13/97 SHIl'~m)?. -N- ' lVolume (G~.>~ N/A "~o Spill; h/A- ' Roi*, ~l~? "' ~~anI?.CY/N) ' . N iN~me; '' ' '~A '- IEmb~yen : N/A ": I~t R~? ~IN~ ~A , , , -',. - ' "NO' SPILLS--NO AOOIDE~O*~ DB~TA 078" DGLO 108'! . . " '.. . . ' ; , -~~9~I.O~'-OUT -': ' : 3 - REV~ OlRO, & ~iLTER BAIZE & MONITOR; WE~ FLOW ON BOTH SIDES '. 0~1630 O~-0~ "' 1.s' ~"TO MO~. WELL. FLOW OTOPPED ~Y DE DP T0 PERFO, &'MON~OR .. :1~2300 .C~~ - :.. ' -12.5-~_~Y-DN ~G. ' ' ..'- '~ --'- "' , - , ' · .. , ~, -. . -. ' · ~24~ -ND~U : ~ .~ CHG~ R~S&TESTTO.~'PSI .... ~ ' - ' ..... :. . .- . . . i '_ . . iL " 2~3~ --RUN~O ""' -~ ' 3:: RIG FL~R~.Mu ESP-ASSY. & CHEC~ ': ' : - ..... -'- '; ..' .. "- . · . .- . . ...... 0a~~ -'.R~~ '3' alH W~H ESP ~MP. ON 2-f/8~" TBS.' · " .' ' -' "' ~ - · A~ ,, - ,, , -. . . . . -' . ' ' ' - .. ;':' HOLD ~MIN SAF~-& E~IRO ME~ING B'E~0RE ~CH TOUR ..... ., ..; . , . ,~, ~ ,- , , .. ...... . . . ' ..- . -~ : · . . . . .. . - . - . '.. . _ . . . . . · .. . -. . -_ -_.- . ..... . . . . . .1 . . 1~ - iii ~ 1~ , . .. . . _ . .... - . - . ... .. .... - . ,-. ..[ . ~.- . ..' . I I .. I . . ~ IJ ' . I I I -- . · . . . . -- .- '1 '~_ .- . . -- i l_ . . = i . ,. .~ . . . . . --. ., .., ,. ... , · . .. FEB O~ '01 5:11 No.002 P.01 t-"l'-iJl:]l']f}l~_l-~,~;l~/ I lrilllnrl ~ ./~-z~,,_, · AFE No: 3470~7 [RepoffNo; _7'r ~t~; 6/1§/97 CQmpletlon Da''~" .5 ° lOuSY init; myers Well; MPU F-6I~ D: 16,840 PBD: 16,755 Top of Fill: Dontractor: NABORS4ES Fh°ne: 41,54 [~ils~YI $38,094 iCumrnc°mp $443.149 I Ou~ [we Co~8: Wall Cosl~ Operation at-0600: FREEZE PROTECT WELL WITH DIESEL {Intermediate (ProduU'tion) C~,g: I.~l.A/l').nth 7"26#B.T _C/_L .80.@ ! 6;_8_ .40 Pr~luctlon Liner; HN^ IPerforated Intrvl: ' .'16,~'-1--16,49 Surfaco Csg. psi: NA ILast Csg Te~t: NA ~i:~e/D~nfh ,,, 1, ,, IRiTAIr')~nth F~ig Accep! (hr/date): 0700-~o9-97 Rig Release (hr/date): ...... Pump No. I Liner E~izo; 6 X 12 SPM: ~PM: psi: Slow Pump Rata: Slow. Pump Date -No~ 2 Liner Size: 6 X 12 .SPM: APM:' I~$i:' Slow Pump Rate: Slow Pump pal: Fluid Type: balance; Loss: - toss; C~: · lCost: I,v.?.,.: , F . . . Wtc, !BHA Description: . ~H^-o: N^ ,I""^Len"'~: NA.-,P"~e~'~"'"°~"d:" . N^'" JHou..On~r.: . - NA'-~ Bit& Bit~Jum: HA Size: HA lvJ~[[~e: NA -iZv--::-, - N'~ ' ~So.~,,.o: NA 'l~a~r~'; ....... .' _-I°°P"~'n: NA Mill Depth..'' Fig: Pits: NA ' NA NA NA . _ -; _ . _ tnlectlon D~ .to S0umo: NA Volume: -NA Type Fluid: -HA . Inier. fion NA_' 1Rat~'.-" NA .' - IPre~eure: 'HA ' ' WglI: ..I , : gpmI ' '' Dally Volume: ~"IX~ : -ICummuletive HA , BBLI Volume: . ' , _ .... DB_L_ Freeze Protect Fluid: HA ... · ....... Volume: NA . gal ,, ,.,, FV~ ~, W~l[~ pa~ Fuel 732 i Fuel- ' BPX - - 600GAL · ' /Fuel ' IDrl. Water - LDrl. Water . . Used: gal Source: lReev'd: gal lI, J~ed: ' BBLI,~OUree: Cuttinos Data I ! WR~fh~r 13 L~tBOP~Te~: ~-I~-~' m~tBOPDrtll: ~/'1~/~7 LMtH~$DrlII; e/11/97 LaSt FIre Dr, l: 6/~97 L~tSafety'MtU: 6/'le/~? 'Last Splll-C~rill: 6/lS/97 ' Spil| (Y/N)? . N Volume (Gale.): NA ' Type 6piti: NA Report Flied? NA ~,ocldent? (YIN) ' N .^ lem"'wer: N^- . . .~. ' zi'ime Operation Prob Oode Hfs, Operation~ From 0600 to 0600 · "NO SPILLS--NO ACCIDENTS" ' DSLTA 679" DSLS 139' ' - ~ , . . 0600-0900 RUN-CO .' 3 : RIH WITH ESP COMP ' ' ' ' .. '~l~ . 0900-1200 . RUN-CO 3 MAKE'MID LINE 'SPLICE IN ESP (;ABLE -. .. . ~1200-1630 'RUN-CO . ' 4.5'- DENT. TO RIHWITH-ESP oOMp. 1630-1930 RUN-CO _ _-.3 -: ~POOL TO ~POOL SPLICE ' " '"' ". IkAl~. · 1930-2.100 'RUN-CO · ' -'- : 1,5- CONT, TO RIH WITH E,~P COMP. Ikap_ ....... 21'00-2400 RUN-CO 3 - INSTALL PENETRATOR & SPLICE HANGER PIGTAIL &. TEST PENETRATOR !~!1~ ,, - ' ' ~400-0030, RUN-CO .$ LAND HANGER & RILDS & S~I~:I' TWC. . 0030-0300 RUN-CO 2.5 . NIPPLE DOWN BOP'8 & NU COMP. TREE . !~/I I:P - _ , . 0300-0400 RUN-CO I FINAL TEST ON. PENETRATOR 7 TEST ADAPTER & TREE TO 5000 ' SUI::4FACE LINES TO 3000 PSI. & PULL TVVC & INSTALL [3PV.- -. o40o-o~0o RUN-CO . ' ..... .~, =AEEZE pROTeCT WELL..WITH ?---S BBL. DIESEL ' hdf~ ., . . · . HOLD O-MmN ~AF~TY ~ ~NVi~O M~eTmN~ ~EFORe FAOH TOUR. ~G R~LEASED ~ 0~00 HR'$ '6'~:~" (LGM) .. . · . ,. .m.. --.. *~: 3~N - '01 16:14 No.O0~ P.01 AFE No; 3470~7 [Rep°~N°: 7 4re: 6/1 ~97 - Completion Day:' Well: MPU F~S 16.840 PBD: 16,755 Top of Fill: ~mra~n , NABoRo 4E0 rhone: 4154 IDaily ~8,094 C~mm oomp ~za~ tA ~mm - . ~oat~. i lnte~edlaie (Pr~uctlon).GBg: 7"26~BTO/L80 ~ 16,840 Op~r~t~n et 06~: FREEZE PRoTEcT WELL WITH DIESEL . ,lB~--~th · Pr~u~ion Liner: HNA - [Perforated Int~: 16,471--16,49 Suda~.Csg. psi: NA ILe~t O~g Test: NA ~ig A~6pt (hr/dato): 0700-6-9;07 Rig Rolease (hr/dalo): Pump No. 1 Uner Size: ~ X 12 S~M: . GP~: p~: Siow Pump Rs~: Slow Pump psh Data No. 2 Mner Size::6 X 12 SPM:. GPM: i psl; Slow Pu~ Rate:' Slo~ Pump , ' d Tota, 69 I Da"Y Icum $52,000 ~lu~ BRINE lever Dally aa ' ~9s: Cost; ICoaI: . BHA-No: NA- BHA Length: '- NA ITy~: "IserlaI ~e~FA: " NA nit'&l Bit Nam: ~A Size: HA Make: .NA NA. ' NA * ibapth In: : . - Daily .Volume: HA BBL! VolH~e~ HA - , ' Freeze Proto~ ~luid; HA - Fuel & Water Data . ".oO~ - I Fuel 'BpX IFbel ' IDrl. Water 600~AL - i~"' Water ~nf.~,.o. ~.,. l~.t Fire Drill: Last Oaf~y Mtg: ~aB~PETe~ '6-9-97 !~"tn°PDri": 6z~07 ~stH~Ddli: 6/11m7 - 6t13/07 . 8/1 . -~ Spill Drill: 6/15/97 Ispill (Y~)? ' N golumo'(~s.): NA ~Ype Spll{: NA RepoA Filed? ' NA ~me Operation Prob O~e Hm. O~reflon~-From 0600 ' ' "NO SPIL~'*NO AOCIDE~S'~ DSLTA 679'" DSLS ~'~e'' 060~9~ RUN-CO . --- " 3 RIH WITH E0P COMP- 09~-1200 RUN-~ 3 ~KE MID LINE SPLICE IN ESP CABLE lZ00-10~0 RUN-OO ~.5 OONT, TO RIH WI~ E~P COMP. 1830-!930 RUN-CO - ' 3 s~OoLTo'sPOOLSPLICE - . 19~-2100 RUN-OO' --1.S CONI. TO RIH WI~ E0P COMP.' 2~00-2~0 RUN-CO -:" 3 INSTALL PENdT~ToR & ePLICE HANGER 'P!GYX.IC&. TEST PENE~TOR 2400~30 RUN-CO ~ .5 ~ND HANGER & RILDS &'S~ET TWO, - 00~0-0300 RUN-CO - 2.5 NIPPLE DoWN~Op'S & NO GOMP~.TREE 0300.0~0 RUN-CO- - - 1 FINA~T~ST ON PEN~I ~TOR -7. TE~T ADAPTER & TREE TO ~0'~0 PSI. ' 0400-0600 RUN-CO 2 FREEZE pRoTECT~WELL WITH 75' BBL, DIEGO- ~ {~'~ ~_["~ ~ ........ I I B.P. EXPLORATION F PAD, WELL NO. MPF-65 7/,~''- MILNE POINT FIELD, ALASKA Gyro Multishot Survey Inside 7"CASING Survey date · 10 - MAY, 1997 Job number :A0597GCE398 ORIGINAL CONTENTS JOB NUMBER :A0597GCE398 t. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER' A0597GCE398 Tool 772 was run in WELL# MPF-65 on SCHLUMBERGER 3/8" wireline inside casing. The survey was run without problems. SURVEY CERTIFICATION SHEET JOB NUMBER · A0597GCE398 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: A0597GCE398 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER LOCATION: F PAD, ALASKA WELL: MPF-65 LATITUDE: 70.505 N LONGITUDE: 149.5 W SURVEY DATE: SURVEY TYPE : 10, MAY, 1997 GYRO MULTISHOT IN 7" CASING DEPTH REFERENCE: 42.3' MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 16601' SURVEY TIED ONTO: NA SURVEY INTERVAL: 0-16601' APl NUMBER: 050-029-22752 TARGET DIRECTION: 26.58 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING A Gyroda t a D i r e c t i ona i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 Run Date: 10-May-97 16:15:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 42.3 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 26.580 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 PaHe MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deH. deH. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deH./ feet deH. 100 ft. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.0 100.0 .48 336.03' 100.0 200 . 0 . 54 3 . 23 200 . 0 301.0 .88 35.56 301.0 401 . 0 1 . 71 54 . 07 401 . 0 0.0 0.00 0.0 0.0 .3 .48 .4 336.0 1.0 .25 1.3 345.8 2.2 .51 2.3 4.1 4.3 .92 4.3 25.4 0.00 N 0.00 E .38 N .17 W 1.23 N .31 W 2.34 N .17 E 3.84 N 1.82 E 499.0 2.32 59.44 498.9 601.0 2.66 63.51 600.8 701.0 3.52 70.14 700.7 801.0 4.63 76.04 800.4 901.0 6.26 77.70 899.9 7.2 .64 7.4 39.6 10.8 .38 11.6 47.8 14.9 .93 16.8 53.9 19.8 1.18 23.6 59.7 25.8 1.64 32.8 64.6 5.70 N 4.71 E 7.81 N 8.61 E 9.89 N 13.58 E 11.91 N 20.38 E 14.04 N 29.63 E 1001.0 9.28 74.32 999.0 1101.0 11.34 75.88 1097.4 1201.0 12.63 76.14 1195.2 1301.0 13.66 72.26 1292.6 1401.0 15.69 66.05 1389.3 1501 . 0 16 . 26 58 . 58 1485 . 5 1602.0 15.36 55.43 1582.7 1701.0 15.78 49.34 1678.0 1801 . 0 17.40 43 . 53 1773 . 9 1901 . 0 18 . 21 38 . 54 1869 . 1 34.7 3.05 46.1 67.9 46.5 2.09 63.9 69.9 60.0 1.28 84.6 71.4 75.3 1.36 107.3 72.0 94.0 2.57 132.6 71.4 116.3 2.13 159.7 69.8 140.1 1.23 186.7 68.0 164.0 1.71 212.3 66.0 190.8 2.32 239.4 63.7 220.4 1.72 267.8 61.2 17.38 N 42.72 E 21.96 N 60.02 E 26.98 N 80.17 E 33.20 N 102.03 E 42.29 N 125.64 E 55.08 N 149.94 E 70.04 N 173.02 E 86.25 N 194.03 E 105.96 N 214.65 E 129.02 N 234.69 E 2000.0 19.48 30.61 1962.8 2050.0 20.62 27.56 2009.8 2100.0 21.20 27.19 2056.5 2150.0 22.96 27.62 2102.8 2200.0 24.20 27.17 2148.6 252.0 2.89 296.6 58.4 269.1 3.09 311.7 56.9 287.0 1.19 327.3 55.3 305.7 3.54 344.1 53.9 325.7 2.50 362.1 52.5 155.33 N 252.73 E 170.31 N 261.05 E 186.15 N 269.25 E 202.83 N 277.90 E 220.59 N 287.10 E A Gyr oda t a Di r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2250 . 0 25.50 25 . 97 2194 . 0 2300.0 26.43 25.90' 2239.0 2350 . 0 27.71 26 . 13 2283 . 5 2400.0 28.58 26.77 2327.6 2450 . 0 29 . 71 27 . 45 2371 . 2 346.7 2.79 381.1 51.1 368.6 1.88 401.0 49.8 391.4 2.56 421.9 48.5 415 . 0 1 . 83 443 . 9 47 . 4 439.3 2.37 466.8 46.3 239.38 N 296.49 E 259.07 N 306.07 E 279.52 N 316.05 E 300.63 N 326.55 E 322.30 N 337.65 E 2500.0 31.12 27.83 2414.4 2550.0 32.18 27.81 2456.9 2600.0 33.50 27.68 2498.9 2650.0 34.32 27.75 2540.4 2700.0 35.22 28.09 2581.5 464.6 2.85 490.8 45.4 490.9 2.].2 515.9 44.5 518.0 2.64 541.9 43.7 545.9 1.64 568.8 42.9 574.4 1.84 596.4 42.2 344.73 N 349.40 E 367.93 N 361.64 E 391.93 N 374.26 E 416.62 N 387.23 E 441.82 N 400.59 E 2750.0 35.97 28.34 2622.2 2800.0 37.28 28.50 2662.3 2850.0 37.70 28.59 2702.0 2900.0 38.73 28.70 2741.2 2950.0 39.79 28.91 2780.0 3000.0 42.01 29.69 2817.7 3050 . 0 43 . 21 29 . 86 2854 . 5 3100 . 0 45 . 05 29 . 63 2890 . 4 3150 . 0 45 . 75 29 . 52 2925 . 5 3200.0 46.62 29.36 2960.2 603.5 1.54 624.7 41.6 633.3 2.61 653.7 41.0 663.7 .86 683.5 40.4 694.6 2.07 713.8 39.9 726.2 2.12 744.9 39.4 758.9 4.56 777.1 39.0 792.7 2.41 810.6 38.6 827.5 3.69 845.0 38.3 863.0 1.41 880.2 37.9 899.0 1.76 915.9 37.6 467.46 N 414.35 E 493.69 N 428.55 E 520.42 N 443.09 E 547.57 N 457.92 E 575.30 N 473.16 E 603.84 N 489.18 E 633.22 N 506.00 E 663.44 N 523.27 E 694.40 N 540.84 E 725.82 N 558.57 E 3250 . 0 47 . 89 29 . 03 2994 . 1 3300.0 48.81 28.68 3027.3 3350.0 49.91 27.98 3059.9 3400.0 51.42 27.13 3091.6 3450.0 53.18 26.89 3122.2 935.7 2.58 952.2 37.3 973.0 1.91 989.2 36.9 1011.0 2.46 1026.7 36.6 1049.6 3.29 1064.9 36.3 1089.2 3.55 1104.0 36.0 757.87 N 576.48 E 790.59 N 594.51 E 823.99 N 612.52 E 858.28 N 630.40 E 893.52 N 648.37 E A Gyroda t a Di r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 3500.0 3550.0 3600.0 3650.0 3700.0 53.87 26.50 3151.9 1129 55.61 25.57' 3180.7 1170 56.36 25.58 3208.7 1211 58.01 25.54 3235.8 1253 59.22 25.46 3261.8 1296 .4 .2 .7 .7 .4 1 . 51 1143 . 7 35 · 6 3.79 1183 .9 35.3 1 . 51 1224 . 8 35 · 0 3.30 1266.3 34.7 2.42 1308.4 34.4 929.44 N 966.13 N 1003.51 N 1041.42 N 1079.94 N 666.43 E 684.35 E 702.24 E 720.37 E 738.75 E 3750.0 3800.0 3850.0 3900.0 3950.0 60.99 25.34 3286.8 1339 62.45 25.50 3310.5 1383 64.16 25.69 3332.9 1428 65.70 25.77 3354.1 1473 67.19 25.46 3374.1 1519 .7 .7 .4 .7 .5 3 . 54 1351.3 34 . 1 2 . 94 1394 . 8 33 . 8 3 . 45 1439 . 0 33 . 6 3 . 0'7 1483 . 9 33 . 3 3 . 04 1529 . 4 33 . I 1119.10 N 1158.87 N 1199.15 N 1239.95 N 1281.28 N 757.34 E 776.24 E 795.53 E 815.19 E 835.00 E 4000.0 4050.0 4100.0 4150.0 4200.0 4250.0 4300.0 4350.0 4400.0 4450.0 68.54 24.91 3392.9 1565 69.51 24.62 3410.8 1612 71.05 24.07 3427.7 1659 71.58 23.64 3443.7 1706 73.74 23.02 3458.6 1754 73.80 22.74 3472.6 1802 73.40 22.63 3486.7 1850 73.62 22.82 3500.9 1898 74.86 22.96 3514.5 1946 74.69 22.80 3527.6 1994 .8 .4 .5 .8 .4 .3 .2 .0 .0 .2 2.88 1575.2 32.9 2.01 1621.5 32.6 3.24 1668.1 32.4 1.35 1714.9 32.2 4.46 1762.1 31.9 .56 1809.5 31.7 .81 1856.9 31.5 .55 1904.3 31.2 2.50 1951.9 31.0 .45 1999.7 30.8 1323.19 N 1365.59 N 1408.47 N 1451.79 N 1495.61 N 1539.84 N 1584.09 N 1628.32 N 1672.65 N 1717.09 N 854.71 E 874.27 E 893.66 E 912.82 E 931.72 E 950.38 E 968.88 E 987.40 E 1006.11 E 1024.87 E 4500.0 4550.0 4600.0 4650.0 4700.0 73.96 22.84 3541.1 2042 74.18 23.01 3554.9 2090 74.83 22.97 3568.2 2138 74.71 22.95 3581.3 2186 74.80 22.89 3594.5 2234 .2 .2 .3 .4 .6 .46 2047.4 30.6 .55 2095.0 30.5 .30 2142.8 30.3 .23 2190.7 30.1 .21 2238.5 30.0 1761.47 N 1805.75 N 1850.10 N 1894.52 N 1938.96 N 1043.54 E 1062.27 E 1081.09 E 1099.91 E 1118.69 E A Gyr oda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet Page 4750.0 74.63 22.79 3607.7 4800.0 74.26 22.93' 3621.1 4850.0 74.95 23.77 3634.4 4900.0 75.34 24.07 3647.2 4950.0 75.02 24.02 3660.0 2282.7 .39 2286.4 29.8 2330.8 .77 2334.2 29.7 2378.9 2.13 2382.1 29.6 2427.2 .96 2430.2 29.4 2475.5 .65 2478.4 29.3 1983.41 N 1137.41 E 2027.79 N 1156.13 E 2072.05 N 1175.24 E 2116.22 N 1194.84 E 2160.37 N 1214.53 E 5000.0 75.18 24.12 3672.8 5050.0 75.80 24.76 3685.4 5100.0 75.85 24.86 3697.6 5150.0 75.30 24.72 3710.1 5200.0 75.37 25.12 3722.7 2523.7 .38 2526.5 29.2 25"72.1 ]..76 2574.7 29.2 2620.~ .22 2623.1 29.1 2669.0 1.12 2671.3 29.0 2717.3 .79 2719.6 28.9 2204.48 N 2248.55 N 2292.55 N 2336.51 N 2380.38 N 1234.23 E 1254.26 E 1274.60 E 1294.91 E 1315.29 E 5250 . 0 75 . 56 25 . 99 3735 . 3 5300.0 75.40 25.98 3747.8 5350 . 0 75 . 69 25 . 94 3760 . 3 5400 . 0 75.49 26 . 03 3772 . 7 5450 . 0 73 . 91 26 . 37 3785 . 9 5500.0 72.57 27.46 3800.3 5550.0 72.62 28.27 3815.3 5600.0 72.43 28.49 3830.3 5650.0 72.10 28.60 3845.5 5700.0 72.29 28.88 3860.8 2765.7 1.72 2767.9 28.9 2814.1 .32 2816.3 28.8 2862.5 .59 2864.6 28.8 2911.0 .45 2913.0 28.7 2959.2 3.22 2961.2 28.7 3007.1 3.41 3009.0 28.7 3054.7 1.54 3056.7 28.6 3102.4 .57 3104.4 28.6 3150.0 .70 3152.0 28.6 3197.6 .67 3199.6 28.6 2424.05 N 2467.56 N 2511.09 N 2554.62 N 2597.89 N 2640.58 N 2682.76 N 2724.72 N 2766.56 N 2808.30 N 1336.16 E 1357.37 E 1378.56 E 1399.78 E 1421.07 E 1442.74 E 1465.04 E 1487.71 E 1510.46 E 1533.35 E 5750.0 71.62 28.81 3876.3 5800.0 72.32 28.71 3891.8 5850.0 72.65 28.58 3906.8 5900.0 73.58 27.88 3921.4 5950.0 73.99 27.35 3935.3 3245.1 1.35 3247.2 28.6 3292.6 1.40 3294.7 28.6 3340.3 .72 3342.4 28.6 3388.1 2.28 3390.3 28.6 3436.1 1.31 3438.3 28.6 2849.94 N 2891.62 N 2933.46 N 2975.62 N 3018.16 N 1556.29 E 1579.17 E 1602.03 E 1624.66 E 1646.91 E A Gyroda t a Di r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet Page 6000.0 73.56 27.34 3949.3 6050.0 73.05 27.20' 3963.7 6100.0 74.02 27.11 3977.8 6150.0 73.87 27.06 3991.6 6200.0 73.85 27.06 4005.5 3484.1 .86 3486.3 28.6 3532.0 1.06 3534.1 28.6 3579.9 1.95 3582.1 28.6 3628.0 .32 3630.1 28.5 3676.0 .05 3678.1 28.5 3060.80 N 3103.37 N 3146.04 N 3188.82 N 3231.59 N 1668.97 E 1690.91 E 1712.79 E 1734.67 E 1756.52 E 6250.0 74.18 26.63 4019.3 6300.0 '75.57 25.48 4032.4 6350.0 75.66 25.10 4044.8 6400.0 75.56 24.96 4057.2 6450.0 75.67 24.69 4069.6 3724.1 1.06 3726.2 28.5 3772.3 3.56 3774.4 28.5 3820.7 .75 3822.'7 28.4 3869.2 .33 3871.1 28.4 3917.6 .57 3919.4 28.3 3274.48 N 3317.84 N 3361.63 N 3405.51 N 3449.47 N 1778.23 E 1799.42 E 1820.11 E 1840.61 E 1860.94 E 6500 . 0 75 . 33 24 . 74 4082 . 1 6550 . 0 75 . 12 24 . 69 4094 . 9 6600 . 0 74 . 93 24 . 56 4107 . 8 6650 . 0 74 . 46 24 . 19 4121 . 0 6700 . 0 74 . 12 24 . 11 4134 . 6 3965.9 .70 3967.7 28.3 4014.3 .42 4016.0 28.3 4062.5 .45 4064.2 28.2 4110.7 1.18 4112.3 28.2 4158.8 .71 4160.3 28.1 3493.44 N 3537.36 N 3581.27 N 3625.20 N 3669.12 N 1881.18 E 1901.39 E 1921.52 E 1941.42 E 1961.12 E 6750.0 74.05 24.14 4148.3 6800.0 74.88 24.66 4161.7 6850.0 75.17 24.76 4174.6 6900.0 74.74 24.61 4187.6 6950.0 75.67 25.27 4200.3 4206.9 .15 4208.3 28.1 4255.0 1.93 4256.4 28.0 4303.3 .62 4304.6 28.0 4351.5 .90 4352.8 28.0 4399.9 2.25 4401.1 27.9 3713.00 N 3756.87 N 3800.75 N 3844.62 N 3888.46 N 1980.77 E 2000.67 E 2020.86 E 2041.02 E 2061.41 E 7000.0 76.04 25.61 4212.5 7050.0 75.92 25.45 4224.7 7100.0 75.89 25.39 4236.8 7150.0 75.80 25.23 4249.1 7200.0 75.70 25.15 4261.4 4448.3 1.00 4449.5 27.9 4496.8 .40 4498.0 27.9 4545.3 .12 4546.4 27.9 4593.8 .36 4594.9 27.8 4642.2 .25 4643.3 27.8 3932.24 N 3976.01 N 4019.81 N 4063.64 N 4107.49 N 2082.24 E 2103.14 E 2123.96 E 2144.69 E 2165.32 E A Gyrodat B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 7250 . 0 75.60 24 . 85 4273 . 8 7300 . 0 75 . 77 24 . 85' 4286 . 1 7350 . 0 75 . 98 24 . 98 4298 . 3 7400 . 0 76 . 50 25 . 01 4310 . 2 7450 . 0 75 . 65 24 . 82 4322 . 2 7500.0 75.29 24.94 4334.8 7550.0 75.00 25.41 4347.6 7600.0 74.55 25.87 4360.7 7650.0 74.18 26.24 4374.2 7700.0 74.02 26.09 4387.9 7750.0 73.62 25.99 4401.9 7800.0 74.00 26.40 4415.8 7850.0 74.36 26.85 4429.4 7900.0 74.58 27.17 4442.8 7950.0 74.64 27.42 4456.1 8000.0 74.13 27.23 4469.5 8050.0 73.66 26.96 4483.4 8100.0 74.27 26.65 4497.2 8150.0 74.12 26.32 4510.8 8200.0 73.72 26.13 4524.7 8250 . 0 73 . 53 25 . 99 4538 . 8 8300 . 0 74 . 04 25 . 99 4552 . 7 8350 . 0 74 . 21 26 . 08 4566 . 4 8400 . 0 74 . 69 26 . 59 4579 . 8 8450 . 0 74 . 83 26 . 66 4593 . 0 4690.7 4739.1 4787.6 4836.1 4884.6 4933.0 4981.3 5029.5 5077.7 5125.8 5173.8 5221.8 5269.9 5318.1 5366.3 5414.4 5462.5 5510.5 5558.6 5606.7 5654.7 5702.7 5750.8 5798.9 5847.2 a Di r e c t i ona i Survey DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. .63 4691.7 27.8 · 34 4740 . 1 27 . 7 .49 4788.5 27.7 1.04 4837.0 27.7 1.75 4885.5 27.7 · 75 4933 . 8 27 . 6 1.07 4982.1 27.6 1 . 27 5030 . 3 2'7 . 6 1 . 03 50'78 . 4 2'7 . 6 .44 5126.5 27.6 .81 5174.5 27.5 1.09 5222.5 27.5 1.13 5270.6 27.5 .76 5318.8 27.5 .48 5367.0 27.5 1.08 5415.2 27.5 1.06 5463.2 27.5 1.35 5511.2 27.5 .69 5559.3 27.5 .88 5607.4 27.5 .47 5655.3 27.5 1.03 5703.3 27.5 .38 5751.4 27.4 1.36 5799.6 27.4 .32 5847.8 27.4 Page HORIZONTAL COORDINATES feet 4151.39 N 2185.79 E 4195.35 N 2206.15 E 4239.33 N 2226.58 E 4283.35 N 2247.10 E 4327.36 N 2267.54 E 4371.27 N 4415.01 N 4458.50 N 4501.76 N 4544.92 N 4588.06 N 4631.15 N 4674.15 N 4717.07 N 4759.91 N 4802.70 N 4845.46 N 4888.35 N 4931.41 N 4974.51 N 5017.61 N 5060.77 N 5103.98 N 5147.15 N 5190.28 N 2287.90 E 2308.46 E 2329.33 E 2350.48 E 2371.69 E 2392.77 E 2413.97 E 2435.52 E 2457.40 E 2479.51 E 2501.61 E 2523.49 E 2545.16 E 2566.61 E 2587.84 E 2608.92 E 2629.95 E 2651.06 E 2672.43 E 2694.05 E A Gyroda t a Di re c t i ona I B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 8500.0 75.03 26.70 4606.0 8550.0 74.64 26.56 4619.0 8600.0 74.44 26.36 4632.4 8650.0 73.07· 26.01 4646.4 8700.0 73.24 25.87 4660.8 5895.4 .42 5896.1 27.4 5943.7 .83 5944.3 27.4 5991.9 .56 5992.5 27.4 6039.9 2.82 6040.5 27.4 6087.7 .44 6088.4 27.4 8750.0 72.56 25.54 4675.5 8800.0 73.17 25.11 4690.3 8850.0 73.15 24.61 4704.8 8900.0 73.78 24.37 4719.0 8950.0 73.88 24.12 4732.9 6135.5 1.49 6136.1 27.4 6183.3 1.48 6183.9 27.4 623]..1 .95 ~231.7 27.3 6279.0 1.34 6279.6 27.3 6327.0 .52 6327.5 27.3 9000 . 0 74 . 93 24 . 94 4746 . 4 9050 . 0 74 . 65 24 . 98 4759 . 5 9100 . 0 74 . 11 25 . 34 4772 . 9 9150 . 0 74 . 04 25 . 00 4786 . 7 9200 . 0 73 . 73 24 . 57 4800 . 5 6375.1 2.64 6375.6 27.3 6423.4 .57 6423.8 27.3 6471.5 1.27 6471.9 27.2 6519.6 .66 6520.0 27.2 6567.6 1.05 6568.0 27.2 9250 . 0 74 . 12 24 . 74 4814 . 4 9300.0 74.26 25.40 4828.0 9350 . 0 74 . 04 25 . 13 4841 . 7 9400 . 0 73 . 77 24 . 71 4855 . 5 9450 . 0 74 . 16 24 . 99 4869.3 6615.6 .86 6616.0 27.2 6663.7 1.31 6664.1 27.2 6711.8 .69 6712.1 27.2 6759.8 .98 6760.1 27.1 6807.8 .96 6808.2 27.1 9500.0 74.22 25.03 4882.9 9550.0 74.98 24.99 4896.2 9600.0 75.09 24.71 4909.1 9650.0 75.26 25.31 4921.9 9700.0 75.31 25.30 4934.6 6855.9 .13 6856.2 27.1 6904.1 1.52 6904.4 27.1 6952.4 .59 6952.7 27.1 7000.7 1.21 7001.0 27.1 7049.1 .11 7049.3 27.1 Survey Page HORIZONTAL COORDINATES feet 5233.42 N 5276.56 N 5319.70 N 5362.78 N 5405.81 N 5448.87 N 5492.06 N 5535.48 N 5579.10 N 5622.89 N 5666.70 N 5710.44 N 5754.03 N 5797.54 N 5841.15 N 5884.82 N 5928.39 N 5971.89 N 6015.45 N 6059.06 N 6102.66 N 6146.34 N 6190.17 N 6233.98 N 6277.70 N 2715.72 E 2737.35 E 2758.82 E 2780.01 E 2800.94 E 2821.67 E 2842.11 E 2862.23 E 2882.10 E 2901.81 E 2921.81 E 2942.17 E 2962.64 E 2983.09 E 3003.23 E 3023.27 E 3043.66 E 3064.19 E 3084.44 E 3104.63 E 3124.97 E 3145.35 E 3165.65 E 3186.08 E 3206.75 E A Gyroda t a D i r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATE feet 9750.0 75.23 25.03 4947.3 9800.0 75.13 25.07' 4960.1 9850.0 75.26 25.52 4972.9 9900.0 75.28 25.80 4985.6 9950.0 75.30 26.28 4998.3 7097 . 4 . 54 7097 . 6 27 . 0 7145 . 7 . 21 7145 . 9 27 . 0 7194 . 0 . 92 7194 . 3 27 . 0 7242 . 4 . 53 7242 . 6 27 . 0 7290.8 .93 7291.0 27.0 6321.46 N 6365.25 N 6408.96 N 6452.55 N 6496.00 N 3227.31 E 3247.78 E 3268.43 E 3289.37 E 3310.60 E 10000.0 75.20 25.94 5011.1 10050.0 75.10 25.62 5023.9 10100.0 74.77 26.00 5036.9 10150.0 75.21 26.29 5049.8 10200.0 75.65 26.50 5062.4 7339 . 1 . 69 7339 . 3 27 . 0 7387.4 .64 7387.6 27.0 7435 . 7 1.00 7435.9 27.0 7484.0 1.05 7484.2 27.0 7532 . 4 . 97 7532 . 6 27 . 0 6539.42 N 6582.94 N 6626.40 N 6669.76 N 6713.11 N 3331.88 E 3352.89 E 3373.91 E 3395.19 E 3416.70 E 10250.0 75.85 26.53 5074.7 10300.0 75.84 26.26 5086.9 10350.0 75.70 26.11 5099.2 10400.0 75.91 26.73 5111.5 10450.0 75.71 26.77 5123.8 10500.0 75.44 26.42 5136.2 10550.0 75.39 26.13 5148.8 10600.0 76.37 26.40 5161.0 10650.0 76.19 26.28 5172.9 10700.0 76.02 26.01 5184.9 7580.9 .40 7581.0 27.0 7629.'3 .52 7629.5 27.0 7677.8 .41 7678.0 27.0 7726.3 1.28 7726.4 27.0 7774.7 .40 7774.9 27.0 7823.2 .87 7823.3 27.0 7871.6 .57 7871.7 27.0 7920.0 2.03 7920.2 26.9 7968.6 .44 7968.8 26.9 8017.2 .62 8017.3 26.9 6756.47 N 6799.90 N 6843.39 N 6886.80 N 6930.08 N 6973.38 N 7016.77 N 7060.25 N 7103.78 N 7147.35 N 3438.34 E 3459.89 E 3481.28 E 3502.85 E 3524.67 E 3546.35 E 3567.77 E 3589.23 E 3610.78 E 3632.16 E 10750.0 76.01 26.12 5196.9 10800.0 76.85 26.61 5208.7 10850.0 76.86 26.97 5220.1 10900.0 77.28 27.24 5231.2 10950.0 76.92 27.09 5242.4 8065.7 .21 8065.8 26.9 8114.3 1.93 8114.4 26.9 8163.0 .69 8163.1 26.9 8211.7 .99 8211.8 26.9 8260.4 .79 8260.6 26.9 7190.94 N 7234.48 N 7277.95 N 7321.33 N 7364.69 N 3653.48 E 3675.07 E 3697.01 E 3719.22 E 3741.46 E A Gyrodata B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 11000.0 76.52 26.86 5253.9 11050.0 76.48 26.58 5265.6 11100.0 76.21 26.34 5277.4 11150.0 75.94 26.14 5289.4 11200.0 75.60 25.75 5301.7 11250.0 75.28 25.49 5314.3 11300.0 74.93 25.23 5327.1 11350.0 74.76 25.00 5340.2 11400.0 74.60 25.08 5353.4 11450.0 74.58 25.70 5366.7 11500.0 74.23 25.62 5380.1 11550.0 73.98 25.34 5393.8 11600.0 73.99 25.69 5407.6 11650.0 73.99 25.82 5421.4 11700.0 74.87 25.73 5434.8 11750 . 0 75 . 04 25 . 67 5447 . 8 11800.0 74.62 25.47 5460.9 11850 . 0 74 . 31 25 . 48 5474 . 3 11900 . 0 74 . 33 26 . 22 5487 . 8 11950 . 0 74 . 10 26 . 18 5501 . 4 12000.0 73.91 26.09 5515.2 12050.0 73.71 26.13 5529.1 12100.0 74.17 26.68 5543.0 12150.0 73.78 26.54 5556.8 12200.0 73.72 26.29 5570.7 8309.1 8357.7 8406.3 8454.8 8503.3 8551 8600 8648 8696 8744 8792 884O 8888 8937 8985 9033 9081 9129 9178 9226 9274 9322 9370 9418 9466 .7 .0 .2 .4 .6 .8 .9 .9 .0 .1 .4 .7 .8 .0 .1 .1 .1 .2 .2 .3 Directional DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. .90 8309.2 26.9 .55 8357.9 26.9 .71 8406.4 26.9 .68 8455.0 26.9 .00 8503.4 26.9 .82 8551.8 26.9 .86 8600.1 26.9 .58 8648.4 26.9 .35 8696.6 26.9 .18 8744.7 26.9 .73 8792.9 26.9 .72 8841.0 26.9 .66 8889.0 26.9 .26 8937.1 26.8 .78 8985.2 26.8 .35 9033.5 26.8 .91 9081.7 26.8 .62 9129.9 26.8 .42 9178.0 26.8 .48 9226.1 26.8 .42 9274.2 26.8 .41 9322.2 26.8 .41 9370.3 26.8 .83 9418.3 26.8 .49 9466.3 26.8 Survey HORIZONTAL COORDINATES feet 7408.06 N 7451.49 N 7494.98 N 7538.51 N 7582.09 N 7625.73 N 7669.39 N 7713.09 N 7756.78 N 7800.32 N 7843.73 N 7887.15 N 7930.52 N 7973.80 N 8017.17 N 8060.68 N 8104.21 N 8147.70 N 8191.02 N 8234.19 N 8277.34 N 8320.46 N 8363.49 N 8406.46 N 8449.45 N 3763.54 E 3785.40 E 3807.05 E 3828.50 E 3849.71 E 3870.64 E 3891.34 E 3911.82 E 3932.23 E 3952.90 E 3973.75 E 3994.44 E 4015.14 E 4036.02 E 4056.97 E 4077.91 E 4098.74 E 4119.47 E 4140.46 E 4161.70 E 4182.87 E 4204.01 E 4225.37 E 4246.90 E 4268.25 E Page A Gyrodat a Di r e c t ional Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 Page 10 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 12250 . 0 74 . 29 26 . 55 5584 . 5 12300 . 0 74 . 61 26 . 94' 5597 . 9 12350.0 74.22 26.94 5611.4 12400 . 0 73 . 87 26 . 82 5625 . 1 12450 . 0 74 . 33 27 . 22 5638 . 8 9514.3 1.25 9514.4 26.8 9562.5 .98 9562.6 26.8 9610.6 .78 9610.7 26.8 9658.7 .74 9658.8 26.8 9706.8 1.19 9706.9 26.8 8492.50 N 4289.64 E 8535.51 N 4311.32 E 8578.44 N 4333.15 E 8621.32 N 4354.88 E 8664.16 N 4376.73 E 12500.0 74.18 27.22 5652.4 12550.0 74.21 27.04 5666.0 12600.0 74.28 27.00 5679.6 12650.0 75.39 27.16 5692.6 12700.0 75.21 26.98 5705.3 9754.9 .30 9755.0 26.8 9803.0 .34 9803.1 26.8 9851.2 .16 9851.2 26.8 9899.4 2.24 9899.5 26.8 9947.8 .50 9947.9 26.8 8706.96 N 4398.74 E 8749.77 N 4420.68 E 8792.64 N 4442.54 E 8835.61 N 4464.51 E 8878.67 N 4486.52 E 12750.0 74.96 26.85 5718.2 12800.0 74.62 26.72 5731.3 12850.0 74.24 26.52 5744.7 12900.0 74.13 26.37 5758.4 12950.0 74.86 26.56 5771.7 9996.1 .56 9996.2 26.8 10044.3 .74 10044.4 26.8 10092.5 .85 10092.6 26.8 10140.6 .37 10140.7 26.8 10188.8 1.51 10188.9 26.8 8921.76 N 4508.39 E 8964.83 N 4530.14 E 9007.89 N 4551.72 E 9050.96 N 4573.14 E 9094.09 N 4594.61 E 13000.0 74.47 26.24 5784.9 13050 . 0 74 . 03 26 . 09 5798 . 5 13100 . 0 73 . 79 25 . 75 5812.4 13150 . 0 73 . 57 25 . 59 5826 . 4 13200 . 0 73 . 84 25 . 50 5840 . 5 10237.0 1.00 10237.1 26.8 10285.1 .92 10285.2 26.8 10333.2 .82 10333.2 26.8 10381.1 .53 10381.2 26.8 10429.1 .57 10429.2 26.8 9137.28 N 9180.47 N 9223.68 N 9266.93 N 9310.23 N 4616.05 E 4637.28 E 4658.28 E 4679.06 E 4699.76 E 13250 . 0 74 . 04 25 . 46 5854 . 3 13300 . 0 74 . 55 25 . 35 5867 . 8 13350 . 0 74 . 32 25 . 25 5881 . 2 13400 . 0 73 . 95 25 . 14 5894 . 9 13450 . 0 73 . 57 25 . 05 5908 . 9 10477.2 .39 10477.2 26.8 10525.3 1.05 10525.3 26.8 10573.4 .50 10573.5 26.8 10621.5 .77 10621.6 26.8 10669.5 .78 10669.6 26.8 9353.60 N 9397.08 N 9440.63 N 9484.15 N 9527.62 N 4720.43 E 4741.08 E 4761.66 E 4782.14 E 4802.50 E A Gyroda t a Di r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 PaHe 11 MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deH. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deH./ feet deH. 100 ft. HORIZONTAL COORDINATES feet 13500.0 13550.0 13600.0 13650.0 13700.0 74.74 25.16 5922.5 74.59 24.96' 5935.8 74.22 24.74 5949.2 74.13 24.64 5962.8 74.98 25.07 5976.2 10717.6 2.35 10717.6 26.7 10765.8 .48 10765.8 26.7 10813.9 .85 10814.0 26.7 10862.0 .26 10862.0 26.7 10910.2 1.90 10910.2 26.7 9571.18 N 9614.86 N 9658.56 N 9702.27 N 9745.99 N 4822.91 E 4843.33 E 4863.56 E 4883.66 E 4903.92 E 13750.0 13800.0 13850.0 13900.0 13950.0 74 . 67 24 . 84 5989 . 2 74 . 49 24 . 65 6002 . 5 74 . 41 24 . 49 6015 . 9 75.41 24 . 85 6029.0 74 . 91 24 . 67 6041 . 8 10958.4 .77 10958.5 26.7 11006.6 .51 1].006.6 26.7 11054.7 .34 11054.8 26.7 11103.0 2.11 11103.0 26.7 11151.3 1.06 11151.3 26.7 9789.75 N 9833.52 N 9877.33 N 9921.20 N 9965.08 N 4924.28 E 4944.46 E 4964.49 E 4984.64 E 5004.88 E 14000.0 14050.0 14100.0 14150.0 14200.0 74.61 24.44 6054.9 74.91 24.30 6068.1 75.68 25.01 6080.7 75.28 24.86 6093.3 74.87 24.70 6106.1 11199.5 .74 11199.5 26.7 11247.7 .66 11247.7 26.6 11296.1 2.06 11296.1 26.6 11344.4 .85 11344.4 26.6 11392.7 .88 11392.7 26.6 10008.96 N 10052.91 N 10096.86 N 10140.75 N 10184.62 N 5024.93 E 5044.84 E 5065.01 E 5085.42 E 5105.67 E 14250.0 14300.0 14350.0 14400.0 14450.0 75.07 25.24 6119.1 75.18 25.71 6131.9 74 . 68 25 . 64 6144 . 9 74 . 29 25 . 56 6158 . 3 73.89 25.45 6172.0 11441.0 1.12 11441.0 26.6 11489.3 .93 11489.3 26.6 11537.6 1.00 11537.6 26.6 11585.8 .81 11585.8 26.6 11633.8 .83 11633.8 26.6 10228.39 N 10272.02 N 10315.54 N 10358.98 N 10402.38 N 5126.05 E 5146.83 E 5167.75 E 5188.57 E 5209.27 E 14500.0 14550.0 14600.0 14650.0 14700.0 73.52 25.37 6186.1 71.93 25.44 6200.9 70.88 25.29 6216.9 69.18 25.24 6233.9 68.32 25.07 6252.1 11681.8 .76 11681.8 26.6 11729.5 3.18 11729.5 26.6 11776.9 2.12 11776.9 26.6 11823.9 3.41 11823.9 26.6 11870.5 1.74 11870.5 26.6 10445.73 N 10488.85 N 10531.67 N 10574.17 N 10616.35 N 5229.86 E 5250.35 E 5270.65 E 5290.70 E 5310.51 E A Gyro da t a Di r ec t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: A0597GCE398 Page 12 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 14750.0 66.37 24.85 6271.3 14800.0 65.52 24.59' 6291.7 14850.0 63.87 24.83 6313.1 14900.0 63.15 24.63 6335.4 14950.0 61.64 25.47 6358.5 11916.6 3.94 11916.6 26.6 11962.2 1.77 11962.2 26.6 12007.4 3.31 12007.4 26.6 12052.1 1.49 12052.1 26.5 12096.4 3.37 12096.4 26.5 10658.18 N 5329.99 E 10699.65 N 5349.08 E ].0740.72 N 5367.97 E 10781.36 N 5386.70 E 10821.50 N 5405.45 E 15000.0 60.67 25.30 6382.7 15050.0 59.08 25.13 6407.8 ].5100.0 58.17 25.46 6433.8 15150.0 56.75 25.61 6460.7 15200.0 55.83 25.69 6488.4 12140.2 1.95 12140.2 26.5 12183.5 3.20 12183.5 26.5 12226.1 1.89 12226.1 26.5 12268.3 2.85 12268.3 26.5 12309.9 1.85 12309.9 26.5 10861.07 N 10900.19 N 10938.79 N 10976.82 N 11014.32 N 5424.23 E 5442.66 E 5460.89 E 5479.06 E 5497.07 E 15250.0 54.31 26.21 6517.0 15300.0 53.53 25.80 6546.5 15350.0 52.54 25.45 6576.6 15400.0 50.95 26.00 6607.5 15450.0 50.06 25.61 6639.3 12350.9 3.16 12350.9 26.5 12391.3 1.70 12391.3 26.5 12431.2 2.06 12431.2 26.5 12470.5 3.28 12470.5 26.5 12509.0 1.89 12509.1 26.5 11051.18 N 11087.50 N 11123.52 N 11158.89 N 11193.62 N 5515.00 E 5532.72 E 5550.00 E 5567.04 E 5583.83 E 15500.0 47.69 26.33 6672.2 15550.0 46.13 26.82 6706.3 15600.0 43.18 26.40 6741.9 15650.0 41.74 26.67 6778.8 15700.0 39.36 26.24 6816.8 12546.7 4.86 12546.7 26.5 12583.2 3.20 12583.2 26.5 12618.4 5.93 12618.4 26.5 12652.1 2.91 12652.1 26.5 12684.6 4.79 12684.6 26.5 11227.48 N 11260.14 N 11291.56 N 11321.75 N 11350.85 N 5600.32 E 5616.66 E 5632.40 E 5647.48 E 5661.96 E 15750.0 38.61 25.92 6855.7 15800.0 36.31 26.20 6895.3 15850.0 35.24 25.84 6935.9 15900.0 33.01 24.28 6977.3 15950.0 32.03 23.99 7019.5 12716.1 1.55 12716.1 26.5 12746.5 4.61 12746.5 26.5 12775.7 2.18 12775.7 26.5 12803.7 4.81 12803.7 26.5 12830.6 1.97 12830.6 26.5 11379.10 N 11406.42 N 11432.69 N 11458.09 N 11482.62 N 5675.79 E 5689.15 E 5701.97 E 5713.86 E 5724.86 E A Gyroda t a Di r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA JOb Number: A0597GCE398 Page 13 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATE feet 16000.0 31.93 23.91 7061.9 16050.0 31.34 23.38' 7104.4 16100.0 30.60 23.21 7147.3 16150.0 30.01 23.29 7190.5 16200.0 29.32 23.42 7233.9 12857.1 .22 12857.1 26.5 12883.2 1.30 12883.3 26.5 12908.9 1.50 12909.0 26.5 12934.1 1.18 12934.1 26.5 12958.8 1.39 12958.9 26.5 11506.82 N 11530.85 N 11554.48 N 11577.66 N 11600.38 N 5735.61 E 5746.12 E 5756.30 E 5766.26 E 5776.07 E 16250 . 0 28 . 96 23 . 32 7277 . 6 16300 . 0 28 . 52 23 . 15 7321 . 4 16350 . 0 28 . 06 23 . 24 7365 . 5 16400 . 0 27 . 71 23 . 28 7409 . 7 16450 . 0 27 . 05 23 . 18 7454 . 1 12983.1 .72 12983.2 26.5 1.3007.1 .89 13007.2 26.5 13030.8 .93 13030.8 26.5 13054.1 .70 13054.2 26.4 13077.1 1.32 13077.1 26.4 11622.73 N 11644.82 N 11666.60 N 11688.08 N 11709.21 N 5785.72 E 5795.21 E 5804.54 E 5813.78 E 5822.84 E 16500.0 26.77 23.06 7498.6 16550.0 26.44 22.75 7543.3 16600.0 25.71 22.95 7588.3 16601.0 25.68 22.94 7589.2 13099.7 .58 13099.7 26.4 13122.0 .70 13122.1 26.4 13143.9 1.47 13144.0 26.4 13144.4 3.62 13144.4 26.4 11730.02 N 11750.65 N 11770.90 N 11771.30 N 5831.73 E 5840.44 E 5848.98 E 5849.14 E Final Station Closure: Distance: 13144.43 ft Az: 26.42 deg. A Gyroda t a Di re c t i ona i Survey for B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: SUB398 Run Date: 10-May-97 16:15:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 42.3 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 26.580 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a Di r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: SUB398 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAl] DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet -42 100 200 300 400 .3 .0 .0 .0 .0 0.00 0.00 0.0 .50 347.54 142.3 .68 16.77 242.3 1.22 43.21 342.3 1.97 56.34 442.3 0.0 0.00 0.0 0.0 .6 .38 1.3 340.2 1.5 .36 2.3 353.5 3.0 .68 4.3 12.9 5.5 .80 7.4 31.4 0.0 N 0.0 E .7 N .2 W 1.7 N .3 E 3.0 N .9 E 4.6 N 3.0 E 5OO 600 700 8OO 900 .0 .0 .0 .0 .0 2.46 61.18 542.3 3.02 66.27 642.3 3.98 72.61 742.3 5.32 76.74 842.3 7.55 76.25 942.3 8.8 .53 11.6 43.1 12.5 .61 16.8 50.3 16.9 1.03 23.6 56.3 22.3 1.37 32.8 61.8 29.6 2.24 46.1 66.0 6.6 N 6.4 E 8.7 N 10.7 E 10.7 N 16.4 E 12.8 N 24.3 E 15.5 N 35.2 E 1000 1100 1200 1300 1400 .0 .0 .0 .0 .0 10.19 75.00 1042.3 11.93 76.00 1142.3 13.13 74.26 1242.3 14.70 69.07 1342.3 16.00 61.93 1442.3 39.9 2.62 63.9 68.8 52.7 1.72 84.6 70.6 67.4 1.32 107.3 71.7 84.9 1.98 132.6 71.7 106.3 2.33 159.7 70.5 19.4 N 50.3 E 24.3 N 69.3 E 30.0 N 90.7 E 37.9 N 114.2 E 49.3 N 139.0 E 1500 1600 1700 1800 1900 .0 .0 .0 .0 .0 15.73 56.74 1542.3 15.62 51.62 1642.3 16 . 87 45 . 44 1742 . 3 17 . 98 39 . 95 1842 . 3 19.20 32.34 1942.3 130.2 1.60 186.7 68.7 155.0 1.53 212.3 66.8 182.0 2.12 239.4 64.5 212.1 1.89 267.8 61.9 245.1 2.63 296.6 59.0 63.8 N 163.4 E 80.2 N 186.2 E 99.5 N 207.9 E 122.5 N 229.0 E 149.6 N 248.8 E 2000.0 2100.0 2200.0 2300.0 2400.0 21.02 27.30 2042.3 24.03 27.23 2142.3 26.53 25.92 2242.3 28.96 27.00 2342.3 31.82 27.82 2442.3 281.5 1.77 327.3 55.8 323.0 2.65 362.1 52.7 370.3 1.93 421.9 49.7 423.2 2.01 466.8 47.0 481.8 2.37 515.9 44.8 181.3 N 266.8 E 218.1 N 285.8 E 260.6 N 306.8 E 307.9 N 330.3 E 360.0 N 357.4 E A Gyroda t a Di r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Nuttier: SUB398 Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2500 2600 2700 2800 2900 .0 .0 .0 .0 .0 34.36 27.77 2542.3 36.63 28.42' 2642.3 38 . 76 28 . 70 2742 . 3 42.81 29.81 2842.3 46.17 29.44 2942.3 547 618 695 781 880 .2 .4 .5 .5 .5 1.65 596.4 42.9 2.08 653.7 41.3 2.07 744.9 39.9 3.13 810.6 38.8 1.58 915.9 37.8 417.8 N 387.8 E 480.6 N 421.5 E 548.3 N 458.3 E 623.4 N 500.4 E 709.6 N 549.4 E 3000 3100 3200 3300 3400 .0 .0 .0 .0 .0 49.32 28.36 3042.3 53.65 26.63 3142.3 58.32 25.52 3242.3 64.84 25.72 3342.3 71.54 23.67 3442.3 990 1116 1264 1448 1702 .5 .4 .3 .4 .6 2.16 1026.7 36.8 2.17 1143.7 35.7 3.08 1308.4 34.6 3.28 1483.9 33.5 1.52 1714.9 32.2 805.9 N 602.8 E 917.9 N 660.6 E 1051.0 N 724.9 E 1217.2 N 804.2 E 1448.0 N 911.1 E 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 73 . 98 22 . 85 3542 . 3 75.19 23.96 3642.3 75.47 25.98 3742.3 72 . 17 28 . 57 3842 . 3 73.78 27.35 3942.3 75.64 25.18 4042.3 74.08 24.13 4142.3 75.85 25.32 4242.3 75.12 25.21 4342.3 74.58 27.16 4442.3 2046 2408 2792 3139 3460 3811 4186 4567 4961 5316 .3 .8 .9 .9 .1 .1 .0 .0 .3 .3 1.38 2095.0 30.6 1.41 2430.2 29.5 · 93 2816.3 28.8 .67 3152.0 28.6 1.08 3486.3 28.6 1.31 3822.7 28.4 .39 4208.3 28.1 · 23 4594.9 27.8 .94 4982.1 27.6 · 78 5318.8 27.5 1765.3 N 1045.1 E 2099.4 N 1187.4 E 2448.5 N 1348.1 E 2757.7 N 1505.6 E 3039.5 N 1657.9 E 3352.9 N 1816.0 E 3693.9 N 1972.2 E 4039.4 N 2133.2 E 4396.9 N 2299.9 E 4715.5 N 2456.6 E 4500.0 4600.0 4700.0 4800.0 4900.0 73.66 25.99 4542.3 73.47 26.11 4642.3 74.61 24.70 4742.3 74.02 25.11 4842.3 75 . 26 25 . 14 4942 . 3 5666.8 6026.0 6360.6 6714.0 7078.2 .61 5703.3 27.5 2.17 6040.5 27.4 2.00 6375.6 27.3 .70 6760.1 27.2 .37 7097.6 27.1 5028.5 N 2614.2 E 5350.3 N 2773.9 E 5653.5 N 2915.8 E 5973.9 N 3065.1 E 6304.1 N 3219.1 E A Gyroda t a Di r e c t i ona I Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: SUB398 Page SUBSEA DEPTH feet I N C L AZIMUT}{ VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5000.0 5100.0 5200.0 5300.0 5400.0 74.95 26.12 5042.3 75.41 26.28 5142.3 76.92 27.09 5242.3 74.73 25.01 5342.3 74.97 25.70 5442.3 7456.0 1.02 7484.2 27.0 7846.6 .73 7871.7 27.0 8260.0 .79 8260.6 26.9 8655.9 .54 8696.6 26.9 9012.9 .96 9033.5 26.8 6644.6 N 3382.8 E 6994.4 N 3556.7 E 7364.3 N 3741.3 E 7720.1 N 3915.1 E 8042.2 N 4069.0 E 5500.0 5600.0 5700.0 5800.0 5900.0 74 . 15 26 . 65 5542 . 3 74 . 29 27 . 22 5642 . 3 74 . 30 26 . 56 5742 . 3 73.87 25.49 5842.3 74.41 24.85 5942.3 9367.9 1.36 9370.3 26.8 9719.2 .96 9755.0 26.8 10083.8 .83 10092.6 26.8 10435.5 .55 10477.2 26.8 10789.2 .66 10814.0 26.7 8361.5 N 4224.4 E 8675.2 N 4382.4 E 9000.1 N 4547.8 E 9316.0 N 4702.5 E 9636.1 N 4853.2 E 6000.0 6100.0 6200.0 6300.0 6400.0 6500.0 6600.0 6700.0 6800.0 6900.0 74.90 24.66 6042.3 74.78 25.65 6142.3 68.78 25.16 6242.3 62.70 24.88 6342.3 57.72 25.51 6442.3 53 . 64 25 . 86 6542 . 3 49.84 25.67 6642.3 43.17 26.41 6742.3 38.87 26.03 6842.3 34.90 25.60 6942.3 11153.3 1.05 11199.5 26.7 11527.8 .99 11537.6 26.6 11845.4 2.64 11870.5 26.6 12065.4 2.06 12096.4 26.5 12239.5 2.20 12268.3 26.5 12385.5 1.91 12391.3 26.5 12512.5 2.16 12546.7 26.5 12618.7 5.90 12652.1 26.5 12705.3 2.66 12716.1 26.5 12780.0 2.58 12803.7 26.5 9966.9 N 5005.7 E 10306.7 N 5163.5 E 10593.7 N 5299.9 E 10793.4 N 5392.3 E 10950.8 N 5466.6 E 11082.3 N 5530.2 E 11196.7 N 5585.3 E 11291.9 N 5632.6 E 11369.4 N 5671.0 E 11436.6 N 5703.8 E 7000.0 7100.0 7200.0 7300.0 7400.0 31.98 23.95 7042.3 30.69 23.23 7142.3 29.25 23.40 7242.3 28.30 23.19 7342.3 27.22 23.20 7442.3 12844.8 1.03 12857.1 26.5 12905.9 1.47 12909.0 26.5 12963.5 1.26 12983.2 26.5 13018.3 .91 13030.8 26.5 13071.0 1.15 13077.1 26.4 11495.7 N 11551.7 N 11604.7 N 11655.1 N 11703.6 N 5730.6 E 5755.1 E 5777.9 E 5799.6 E 5820.4 E A Gyroda t a Di r e c t i ona i Survey B.P. EXPLORATION F PAD, WELL NO. MPF-65 MILNE POINT FIELD, ALASKA Job Number: SUB398 Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 7546.9 25.68 22.94 Final Station Closure: 7589.2 13144.4 3.62 Distance: 13144.43 ft 13144.4 26.4 Az: 26.42 deg. 11771.3 N 5849.1 E 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: A0597GCE398 TOOL NUMBER: 772 MAXIMUM GYRO TEMPERATURE: 80.0 C MAXIMUM AMBIENT TEMPERATURE: 82.0 C MAXIMUM INCLINATION: 76.04 AVERAGE AZIMUTH: 26.58 WIRELINE REZERO VALUE: N/A REZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: 1926 CALIBRATION USED FOR FINAL SURVEY: 1926 PRE JOB MASS BALANCE OFFSET CHECK: .25 POST JOB MASS BALANCE OFFSET CHECK~: USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES .5 UPON ARRIVAL AT RIG: OFF UPON COMPLETION OF SURVEY: OFF UPON RETURN TO ATLAS OFF BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD 16619 25.33 23.6 7592 11698 6036 FINAL SURVEY 16601 25.68 22.94 7589.2 11771 5849 FUNCTION TEST JOB NUMBER: A0597GCE398 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 2000 19.48 19.48 19.48 19.48 19.48 AZIMUTH M.D. ft I 2 3 4 5 2000 30.74 30.79 30.70 30.65 30.64 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: A0597GCE398 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 772 GYRO SECTION DATA SECTION POWER SECTION A0147 C0100 C0040 COMPUTER A0222 POWER SUPPLY PRINTER A0079 INTERFACE A0143 A0085 BACKUP TOOL No. 768 GYRO SECTION DATA SECTION POWER SECTION A0159 C0089 C0086 COMPUTER A0222 POWER SUPPLY PRINTER A0029 INTERFACE A0055 A0107 WlRELINE COMPANY: SCHLUMBERGER CABLE SIZE: 3/8" RUNNING GEAR SCHLUMBERGER 3 3/8" HOUSING W/ROLLERS TOP AND BOTTOM TOTAL LENGTH OF TOOL :25' MAXIMUM O.D.: 5.5 INCHES TOTAL WEIGHT OF TOOL: 500 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: A0597GCE398 SATURDAY,05/10/97 09:00 10:00 14:00 16:00 15:30 16:00 19:30 23:30 TO I,OCATION ARRIVE LOCATION MU TOOL, STANDBY LD GR/CCL. WARM UP GYRO PU GYRO. START INRUN SURVEY SURVEY CONTINUOUS TO 16601' OUTRUN CONTINUOUS SUNDAY,05/11/97 00:15 01:30 07:00 10:00 14:00 RIG DOWN RTN TO ATLAS PROCESS SURVEY/CHECK TOOL RETURN TO MILNE POINT FIELD WITH RESULTS. RETURN TO ATLAS. STAND BY FOR MPF-57 Schlumberger ANADRILL Survey Report Client: BP Exploration Field: Milne Point Well Name: MPF-65 Permanent datum GROUND LEVEL Depth measured from Elevation of kelly bushing Elevation of drill floor Elevation of ground level Magnetic Declination 28.07 DEG Grid Convergence 0.00 DEG Total Correction 28.07 DEG TIE IN POINT Measured depth True vertical depth N/S disp (-ye for S) E/W disp (-ye for W) 0.00 FT 0.00 FT 0.00 FT 0.00 FT Survey_01.ASCII_FILE 7-APR-97 06:41:02 42.30 FT 42.30 FT 13.00 FT Inclination 0.00 DEG Azimuth 0.00 DEG Azimuth from rotary table to the target 26.58 DEG Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET DEPTH DEPTH SECTION FT FT FT FT 0.0 0.00 0.00 0.00 112.0 112.00 112.00 0.00 203.6 91.60 203.60 0.37 291.4 87.80 291.39 1.34 381.7 90.30 381.67 3.02 468.9 87.20 468.82 5.47 561.7 92.80 561.54 8.68 651.8 90.10 651.53 12.15 746.1 94.30 745.63 16.47 837.1 91.00 836.33 21.07 927.5 90.40 926.19 27.36 1018.7 91.20 1016.34 36.93 1111.0 92.30 1106.94 48.74 1203.9 92.90 1197.70 61.55 1297.3 93.40 1288.64 75.90 1390.3 93.00 1378.65 92.98 1481.2 90.90 1466.01 113.16 1576.4 95.20 1557.56 135.61 1669.1 92.70 1646.92 157.67 1764.3 95.20 1738.23 182.77 Page 001 1857.5 93.20 1827.14 209.57 1950.4 92.90 1915.30 238.32 2042.9 92.50 2002.32 269.60 2136.2 93.30 2088.97 304.15 2231.2 95.00 2175.69 342.93 2322.6 91.40 2257.59 383.48 2416.8 94.20 2340.49 428.19 2511.8 95.00 2422.33 476.40 2606.1 94.30 2501.58 527.48 2698.4 92.30 2577.40 580.06 2791.4 93.00 2652.16 635.29 STATION INCLN. DEG 0.00 0.00 O.55 0.83 1.52 AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS N/-S E/-W CEMENT DEG FT FT FT DEG D/HF 0.0 0.00 0.00 0.00 0.00 0.00 0.0 0.00 0.00 0.00 0.00 0.00 353.6 0.44 -0.05 0.44 353.60 0.60 38.8 1.35 0.30 1.38 12.62 0.67 56.8 2.52 1.71 3.05 34.26 0.86 2.32 2.55 3.22 4.16 5.21 61.2 4.00 4.23 5.82 46.59 0.93 63.0 5.84 7.71 9.68 52.86 0.26 69.1 7.66 11.86 14.12 57.17 0.82 72.8 9.61 17.61 20.06 61.37 1.03 82.6 11.12 24.86 27.23 65.90 1.45 7.22 10.13 11.90 12.72 13.63 71.9 13.41 34.33 36.86 68.66 2.56 72.9 17.55 47.44 50.59 69.70 3.19 75.9 22.26 64.43 68.17 70.94 2.02 76.6 26.96 83.67 87.91 72.14 0.90 71.9 32.76 104.14 109.17 72.53 1.50 15.50 16.65 15.19 15.68 17.20 67.6 40.91 126.04 132.51 72.02 2.32 58.8 52.28 148.42 157.36 70.59 2.96 55.6 66.39 170.37 182.85 68.71 1.79 50.6 81.21 190.08 206.70 66.87 1.53 45.1 99.31 209.99 232.29 64.69 2.28 17.73 19.05 20.62 22.87 25.33 41.3 119.70 229.12 258.50 62.42 1.35 33.0 143.05 246.71 285.19 59.89 3.15 28.7 170.00 262.76 312.96 57.10 2.32 28.2 200.39 279.22 343.68 54.33 2.42 27.0 234.77 297.17 378.72 51.69 2.64 27.35 29.35 31.67 33.97 35.57 26.2 271.03 315.32 415.80 49.32 2.24 28.6 310.72 335.93 457.60 47.23 2.44 28.1 353.17 358.82 503.47 45.45 2.46 28.6 398.14 383.10 552.52 43.90 2.46 29.8 444.08 408.78 603.58 42.63 1.89 37.42 29.4 492.18 Page 1 436.10 657.59 41.54 2.01 Survey_01.ASCII_FILE Schlumberger ANADRILL Survey Report 7-APR-97 06:41:02 Page 002 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 2884.6 93.20 2725.57 692.64 38.63 28.9 542.32 464.06 713.77 40.55 1.34 2976.2 91.60 2795.84 751.31 41.17 30.2 593.42 493.05 771.52 39.72 2.92 3070.3 94.10 2864.81 815.18 44.55 30.2 648.73 525.24 834.70 39.00 3.59 3161.9 91.60 2929.10 880.30 46.28 29.8 705.23 557.86 899.19 38.35 1.91 3255.4 93.50 2992.51 948.90 48.32 30.0 764.79 592.11 967.21 37.75 2.19 3348.4 93.00 3053.23 1019.28 50.16 27.5 826.55 625.97 1036.83 37.14 2.84 3442.8 94.40 3111.76 1093.31 53.19 28.2 892.02 660.57 1109.97 36.52 3.26 3535.1 92.30 3165.61 1168.26 55.44 25.6 958.87 694.46 1183.94 35.91 3.34 3628.4 93.30 3217.13 1246.03 57.52 26.3 1028.80 728.50 1260.61 35.30 2.32 3721.6 93.20 3265.15 1325.90 60.45 25.6 1100.62 763.44 1339.48 34.75 3.21 3814.4 92.80 3308.90 1407.72 63.28 3906.8 92.40 3348.32 1491.28 66.22 4000.9 94.10 3384.16 1578.27 69.00 4094.0 93.10 3415.80 1665.81 71.25 4187.6 93.60 3444.03 1754.99 73.65 27.0 1173.97 799.71 1420.47 34.26 3.33 26.1 1248.72 837.05 1503.31 33.83 3.30 26.1 1326.85 875.32 1589.56 33.41 2.95 25.1 1405.80 913.15 1676.34 33.01 2.62 24.0 1486.97 950.22 1764.65 32.58 2.80 4281.9 94.30 3470.79 1845.31 73.38 23.7 1569.68 986.78 1854.08 32.16 0.42 4379.3 97.40 3497.49 1938.86 74.79 23.8 1655.41 1024.50 1946.79 31.75 1.45 4472.5 93.20 3522.34 2028.57 74.29 23.5 1737.69 1060.54 2035.76 31.40 0.62 4568.8 96.30 3548.11 2121.25 74.67 24.1 1822.59 1097.98 2127.77 31.07 0.72 4663.7 94.90 3573.16 2212.70 74.72 24.1 1906.14 1135.36 2218.65 30.78 0.05 4759.4 95.70 3598.56 2304.86 74.49 23.6 1990.53 1172.66 2310.27 30.50 0.56 4854.3 94.90 3623.33 2396.41 75.25 25.6 2073.82 1210.80 2401.41 30.28 2.19 4949.5 95.20 3647.80 2488.38 74.97 24.9 2157.03 1250.05 2493.07 30.09 0.77 5044.3 94.80 3671.72 2580.10 75.80 26.0 2239.86 1289.47 2584.51 29.93 1.42 5140.1 95.80 3695.61 2672.86 75.31 25.8 2323.31 1329.99 2677.06 29.79 0.55 5235.1 95.00 3719.43 2764.82 75.66 27.6 2405.47 1371.31 2768.89 29.69 1.87 5330.4 95.30 3743.10 2857.13 75.57 27.3 2487.39 1413.86 2861.14 29.61 0.32 5425.7 95.30 3767.52 2949.24 74.74 26.6 2569.50 1455.61 2953.16 29.53 1.12 5519.0 93.30 3793.64 3038.76 72.75 29.9 2648.39 1497.99 3042.69 29.49 4.01 5614.6 95.60 3822.23 3129.83 72.45 29.9 2727.48 1543.46 3133.91 29.51 0.31 5710.2 95.60 3851.09 3220.82 72.41 29.7 2806.56 1588.76 3225.05 29.51 0.20 5804.9 94.70 3879.41 3311.05 72.78 29.8 2885.02 1633.60 3315.41 29.52 0.40 5901.6 96.70 3907.04 3403.61 74.02 28.8 2965.83 1678.95 3408.08 29.51 1.62 5996.8 95.20 3933.47 3495.00 73.74 28.7 3046.01 1722.93 3499.53 29.49 0.31 6093.0 96.20 3959.92 3587.45 74.35 28.1 3127.37 1766.93 3592.00 29.47 0.87 6188.2 95.20 3985.93 3679.00 73.93 28.0 3208.19 1809.99 3683.55 29.43 0.45 6282.7 94.50 4010.82 3770.15 75.53 25.9 3289.45 1851.30 3774.62 29.37 2.73 6377.7 95.00 4034.48 3862.15 75.63 25.9 3372.22 1891.48 3866.47 29.29 0.11 6474.4 96.70 4058.75 3955.75 75.30 26.0 3456,38 1932.44 3959.92 29.21 0.36 6570.1 95.70 4083.31 4048.24 74.96 25.8 3539.59 1972.85 4052.26 29.13 0.41 6666.2 96.10 4108.71 4140.89 74.39 24.7 3623.41 2012.38 4144.73 29.05 1.25 6760.3 94.10 4134.29 4231.41 74.06 25.4 3705.45 2050.72 4235.07 28.96 0.80 6854.3 94.00 4159.39 4321.97 74,97 24.6 3787.55 2089.01 4325.45 28.88 1.27 6947.0 92.70 4182.70 4411.66 75.90 25.8 3868.73 2127.21 4414.98 28.80 1.61 7040.4 93.40 4205.41 4502.25 75.96 26.3 3950.12 2166.99 4505.48 28.75 0.52 Page 2 Survey_01.ASCII_FILE Schlumberger ANADRILL Survey Report 7-APR-97 06:41:02 Page 003 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 7135.0 94.60 4228.33 4594.02 75.99 25.5 4032.68 2207.08 4597.15 28.69 0.82 7229.8 94.80 4251.84 4685.85 75.30 25.9 4115.44 2246.91 4688.86 28.63 0.83 7323.5 93.70 4274.90 4776.66 76.20 25.6 4197.24 2286.36 4779.57 28.58 1.01 7423.4 99.90 4299.07 4873.58 75.80 26.2 4284.43 2328.70 4876.39 28.53 0.71 7523.6 100.20 4324.21 4970.58 75.14 26.3 4371.42 2371.60 4973.31 28.48 0.67 7621.2 97.60 4349.85 5064.75 74.40 27.3 4455.48 2414.06 5067.44 28.45 1.25 7716.9 95.70 4376.05 5156.79 73.82 26.8 4537.45 2455.92 5159.46 28.42 0.79 7812.6 95.70 4402.22 5248.84 74.44 27.3 4619.44 2497.78 5251.49 28.40 0.82 7907.5 94.90 4427.26 5340.36 74.96 27.9 4700.56 2540.19 5343.01 28.39 0.82 8003.0 95.50 4452.79 5432.35 74.03 28.1 4781.81 2583.39 5435.03 28.38 0.99 8095.5 92.50 4477.83 5521.37 74.56 27.7 4860.50 2625.06 5524.08 28.37 0.71 8190,6 95.10 4503.78 5612.85 73.76 27.1 4941.73 2667.16 5615.55 28.36 1.04 8283.8 93.20 4529.44 5702.45 74.29 27.3 5021.42 2708.12 5705.13 28.34 0.60 8378.4 94.60 4554.64 5793.62 74.81 27.8 5102.26 2750.29 5796.31 28.33 0.75 8472.9 94.50 4579.00 5884.91 75.31 27.3 5183.21 2792.52 5887.60 28.31 0.74 8550.3 77.40 4598.95 5959.69 74.81 27.0 5249.75 2826.65 5962.37 28.30 0.75 8698.6 148.30 4639.92 6102.18 73.12 28.5 5375,89 2893.00 6104.89 28.29 1.50 8783.9 85.30 4664.78 6183.76 72.99 26.1 5448.39 2930.42 6186.46 28.27 2.70 8878.2 94.30 4691.96 6274.00 73.51 23.2 5530.45 2968.08 6276.57 28.22 3.00 8971.6 93.40 4717.91 6363.63 74.23 24.9 5612.38 3004.64 6366.06 28.16 1.91 9064.9 93.30 4743.10 6453.45 74.45 9160.3 95.40 4769.04 6545.26 74.00 9255.4 95.10 4795.18 6636.69 74.10 9350.2 94.80 4821.29 6727.81 73.92 9442.2 92.00 4846.76 6816.21 73.94 27.3 5693.05 3044.16 6455.83 28.13 2.49 25.4 5775.31 3084.91 6547.59 28.11 1.97 27.2 5857.28 3125.42 6638.98 28.08 1.82 27.4 5938.26 3167.22 6730.10 28.07 0.28 25.1 6017.54 3206.32 6818.45 28.05 2.40 9535.5 93.30 4871.89 6906.04 74.81 25.3 6098.84 3244.58 6908.20 28.01 0.96 9628.3 92.80 4895.96 6995.65 75.13 27.6 6179.08 3284.49 6997.78 27.99 2.42 9718.1 89.80 4918.87 7082.47 75.31 25.0 6256.91 3322.96 7084.56 27.97 2.81 9811.9 93.80 4942.78 7173.17 75.16 26.7 6338.54 3362.51 7175.20 27.95 1.76 9906.6 94.70 4967.08 7264.67 75.10 28.7 6419.57 3405.05 7266.72 27.94 2.04 10000.9 94.30 4991.31 7355.77 75.13 27.6 6499.93 3448.05 7357.86 27.94 1.13 10094.0 93.10 5015.35 7445.69 74.93 27.9 6579.52 3489.92 7447.80 27.94 0.38 10186.9 92.90 5039.09 7535.47 75.46 28.4 6658.71 3532.30 7537.61 27.94 0.77 10279.5 92.60 5061.95 7625.19 75.96 27.0 6738.16 3574.01 7627.34 27.94 1.56 10373.5 94.00 5084.95 7716.33 75.72 26.9 6819.41 3615.31 7718.47 27.93 0.28 10467.9 94.40 5108.37 7807.77 75.55 27.7 6900.67 3657.26 7809.92 27.92 0.84 10560.1 92.20 5131.23 7897.07 75.73 27.5 6979.83 3698.64 7899.23 27.92 0.29 10654.7 94.60 5154.20 7988.84 76.17 27.1 7061.37 3740.73 7991.00 27.91 0.62 10747.4 92.70 5176.29 8078.87 76.26 26.0 7141.91 3780.97 8081.00 27.90 1.16 10839.9 92.50 5197.76 8168.83 76.90 28.4 7221.93 3822.09 8170.96 27.89 2.62 10933.8 93.90 5218.95 8260.28 77.02 27.4 7302.77 3864.90 8262.44 27.89 1.05 11024.9 91.10 5239.80 8348.95 76.51 27.3 7381.54 3905.64 8351.12 27.88 0.57 11118.8 93.90 5262.08 8440.16 76.04 27.5 7462.52 3947.62 8442.33 27.88 0.54 11212.3 93.50 5285.06 8530.79 75.51 27.1 7543.06 3989.19 8532.96 27.87 0.70 11306.2 93.90 5309.05 8621.57 74.89 25.9 7624.30 4029.70 8623.71 27.86 1.40 Page 3 Survey_01,ASCII_FILE Schlumberger ANADRILL Survey Report 7-APR-97 06:41:02 Page 004 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN, N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 11398.8 92,60 5333,39 8710,91 74,63 27,0 7704,29 4069,49 8713,03 27,84 1,18 11492,3 93,50 5358,45 8800,99 74,27 27,2 7784,48 4110,52 8803,10 27,84 0,44 11584,7 92,40 5383,85 8889,82 73,82 26,4 7863,78 4150,58 8891,92 27,83 0,96 11677,7 93,00 5409,21 8979,30 74,54 27,1 7943,68 4190,85 8981,39 27,81 1,06 11769,3 91,60 5433,44 9067,63 74,78 26,1 8022,66 4230,41 9069,70 27,80 1,08 11862,0 92,70 5458,15 9156,98 74,30 11957,7 95,70 5484,25 9249,05 74,04 12049,2 91,50 5509,69 9336,94 73,68 12141,1 91,90 5535,40 9425,16 73,83 12235,0 93,90 5561,24 9515,44 74,22 26,6 8102,73 4270,06 9159,02 27,79 0.73 27,2 8184,83 4311,72 9251,08 27,78 0,66 27,2 8263,01 4351,89 9338,97 27,77 0.39 26,2 8341,83 4391,54 9427,18 27,76 1,06 26,9 8422,58 4431,89 9517,43 27,75 0,83 12328,4 93,40 5586,57 9605,34 74,31 12421,7 93,30 5612,11 9695,07 73,92 12515,9 94,20 5637,91 9785,66 74,29 12611,4 95,50 5663,33 9877,69 74,84 12706,8 95,40 5688,01 9969,81 75,17 26,9 8502,75 4472,56 9607,32 27,74 0.10 27,6 8582,53 4513,65 9697,06 27,74 0,83 26,9 8663,08 4555,13 9787,65 27,74 0,82 28,4 8744,61 4597,85 9879,70 27,74 1,62 27,9 8825,87 4641,33 9971,85 27,74 0,61 12802,7 95,90 5713,04 10062,38 74,57 12895,3 92,60 5737,89 10151,58 74,30 12992.3 97,00 5764,01 10245,00 74,46 13087.1 94.80 5789,92 10336,18 73,81 13181,7 94.60 5816,31 10427,03 73,80 26,4 8908,24 4683,57 10064,42 27,73 1,63 27,1 8987,89 4723,72 10153,61 27,72 0,78 26,2 9071,39 4765,62 10247,01 27,72 0.91 27,1 9152,89 4806,52 10338,18 27,71 1,14 26,0 9234,15 4847,13 10429,01 27,70 1,12 13277,3 95.60 5842,50 10518,97 74,40 13371,7 94,40 5868,20 10609,80 74,01 13469,3 97,60 5894,86 10703,68 74,28 13564,2 94.90 5920,38 10795,08 74,52 13660.1 95,90 5945,91 10887,50 74,60 26,5 9316,61 4887,79 10520,92 27,68 0,80 25,7 9398,18 4927,75 10611,72 27,67 0.91 26,2 9482,60 4968,84 10705,56 27.65 0.57 25,5 9564,86 5008,69 10796,92 27,64 0,75 25,8 9648,19 5048,71 10889,30 27,62 0.31 13755,7 95,60 5971,23 10979,68 74,69 13851,4 95,70 5996,28 11072,04 74,96 13946,4 95,00 6020,96 11163,76 74,92 14042,0 95,60 6045,61 11256,10 75,20 14137,6. 95,60 6069,94 11348,53 75,31 25,5 9731,29 5088,61 10981,44 27,61 0,32 26,3 9814,38 5128,96 11073,76 27,59 0,85 25,1 9897,04 5168,74 11165,45 27,58 1,22 25,3 9980,61 5208,07 11257,74 27.56 0,36 25,5 10064,13 5247,72 11350,12 27,54 0,23 14231,7 94,10 6094,02 11439,49 75,04 14328,0 96,30 6119,11 11532,45 74,75 14423,3 95,30 6144.73 11624,25 74,07 14518,7 95,40 6171,96 11715,68 72,76 14613,9 95,20 6202,24 11805,92 70,14 25,7 10146,17 5287,03 11441,04 27,52 0,35 26,3 10229,73 5327,78 11533,98 27,51 0,67 26,4 10311,99 5368,53 11625,75 27,50 0,72 26,7 10393,77 5409,39 11717,17 27,49 1,41 26,0 10474,64 5449,45 11807,40 27,49 2,84 14709,9 96,00 6236,81 11895,46 67,64 14805,2 95,30 6275,18 11982,66 64,88 14899.0 93,80 6316,53 12066,81 62,80 14995,2 96,20 6362,25 12151,42 60,44 15089,5 94,30 6410,37 12232,51 58,20 25,1 10555,43 5488,08 11896,90 27,47 2,75 25,3 10634,36 5525,22 11984,05 27,45 2,90 24,7 10710,65 5560,80 12068,16 27,44 2,29 26,0 10787,14 5597,02 12152,74 27,42 2,73 26,1 10860,00 5632,64 12233,81 27,41 2.38 15186,0 96.50 6462,88 12313,47 55,86 15282,0 96,00 6518,36 12391,80 53,52 15377,5 95,50 6576,57 12467,50 51,37 15473,5 96,00 6638,21 12541,07 48,72 15568,1 94,60 6703,02 12609,95 44,78 26,4 10932,60 5668,44 12314,75 27,41 2.44 26,0 11002,89 5703,03 12393.06 27.40 2.46 27,5 11070,49 5737,09 12468,76 27,39 2,57 27,8 11135,67 5771,23 12542,34 27,40 2,77 26,6 11196,93 5802,74 12611,23 27,40 4,27 Page 4 Survey_O1.ASCII_FILE Schlumberger ANADRILL Survey Report 7-APR-97 06:41:02 Page 005 Minimum Curvature Method MEASURED INTERVAL VERTICAL TARGET STATION AZIMUTH LATITUDE DEPARTURE DISPLA- at AZIMUTH DLS DEPTH DEPTH SECTION INCLN. N/-S E/-W CEMENT FT FT FT FT DEG DEG FT FT FT DEG D/HF 15662.5 94.40 6772.49 12673.83 40.42 26.3 11254.12 5831.20 12675.10 27.39 4.62 15758.8 96.30 6847.25 12734.52 37.71 26.7 11308.43 5858.27 12735.78 27.39 2.83 15854.8 96.00 6924.95 12790.88 34.21 26.9 11358.75 5883.68 12792.14 27.38 3.65 15950.4 95.60 7005.03 12843.08 32.00 25.0 11405.68 5906.55 12844.33 27.38 2.55 16045.3 94.90 7085.92 12892.65 31.05 23.2 11450.96 5926.82 12893.86 27.37 1.41 16140.5 95.20 7168.04 12940.74 29.73 23.6 11495.16 5945.94 12941.91 27.35 1.40 16236.7 96.20 7251.92 12987.77 28.89 23.7 11538.30 5964.83 12988.90 27.34 0.87 16332.4 95.70 7336.05 13033.33 28.04 24.0 11580.02 5983.27 13034.43 27.32 0.90 16428.5 96.10 7421.26 13077.73 27.05 24.4 11620.55 6001.49 13078.80 27.31 1.05 16523.1 94.60 7505.72 13120.30 26.49 24.1 11659.40 6018.99 13121.35 27.30 0.61 16619.7 96.60 7592.61 13162.46 25.33 23.6 11698.00 6036.06 13163.48 27.29 1.22 16714.2 94.50 7678.31 13202.21 24.50 23.1 11734.55 6051.84 13203.20 27.28 0.91 16764.4 50.20 7724.11 13222.73 23.86 22.4 11753.51 6059.79 13223.70 27.27 1.40 Survey Projected to TD: 16853.0 88.60 7805.14 13258.47 23.86 22.4 11786.65 6073.45 13259.41 27.26 0.00 Page 5 SPERRY-SUN DRILLING SERVICES .... ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE POINT / MPF-65 500292275200 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 040897 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70094 KELLY BUSHING ELEV. = 42.50 OPERATOR: BP EXPLORATION PAGE FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8550.30 4598.95 4556.45 8734.47 4650.06 4607.56 8828.07 4677.24 4634.74 8921.67 4703.65 4661.15 9015.77 4728.80 4686.30 74 48 N 27.00 E .00 5249.76N 2826.95E 72 57 N 26.63 E 1.02 5407.65N 2906.75E 73 16 N 27.40 E .86 5487.44N 2947.43E 73 56 N 26.97 E .84 5567.32N 2988.45E 75 2 N 28.08 E 1.62 5647.73N 3030.35E 5959.83 6136.73 6226.30 6316.09 6406 74 9110.37 4753.81 4711.31 9204.67 4779.62 4737.12 9257.07 4793.99 4751.49 9298.17 4805.11 4762.61 9390.17 4830.14 4787.64 74 18 N 28.03 E .78 5728.24N 3073.26E 73 55 N 27.01 E 1.11 5808.67N 3115.17E 74 14 N 27.20 E .69 5853.53N 3138.13E 74 20 N 27.13 E .32 5888.73N 3156.20E 74 4 N 27.55 E .53 5967.37N 3196.85E 6497 94 6588.63 6639 02 6678.58 6767 10 9483.87 4855.82 4813.32 9576.67 4880.30 4837.80 9668.07 4903.52 4861.02 9761.47 4927.24 4884.74 9854.87 4950.70 4908.20 74 6 N 27.18 E .38 6047.40N 3238.28E 75 17 N 27.30 E 1.28 6126.98N 3279.24E 75 16 N 28.43 E 1.20 6205.13N 3320.56E 75 18 N 28.34 E .09 6284.60N 3363.50E 75 35 N 28.06 E .44 6364.28N 3406.22E 6857 21 6946.71 7035 08 7125.37 7215.74 9949.17 4974.29 4931.79 10042.17 4998.00 4955.50 10135.47 5021.98 4979.48 10228.57 5045.17 5002.67 10321.67 5067.60 5025.10 75 25 N 28.24 E .26 6444.78N 3449.29E 75 1 N 27.48 E .90 6524.28N 3491.32E 75 10 N 27.73 E .31 6604.18N 3533.10E 75 58 N 28.09 E .93 6683.85N 3575.31E 76 10 N 22.31 E 6.03 6765.58N 3613.76E 7307.01 7396.91 7487.06 7577.20 7667.49 10416.57 5090.51 5048.01 10467.97 5103.12 5060.62 10509.26 5113.29 5070.79 10603.47 5136.72 5094.22 10696.07 5159.67 5117.17 75 53 N 24.00 E 1.75 6850.24N 3649.97E 75 42 N 22.14 E 3.52 6896.08N 3669.50E 75 46 N 22.08 E .21 6933.15N 3684.56E 75 25 N 21.98 E .37 7017.74N 3718.79E 75 52 N 24.45 E 2.63 7100.17N 3754.15E 7759.41 7809.14 7849.04 7940.00 8029.54 10790.27 5181.97 5139.47 10883.77 5202.96 5160.46 10976.37 5223.80 5181.30 11069.77 5245.55 5203.05 11162.97 5267.93 5225.43 76 44 N 26.74 E 2.53 7182.69N 3793.68E 77 18 N 25.03 E 1.89 7264.65N 3833.45E 76 40 N 26.07 E 1.29 7346.05N 3872.36E 76 23 N 25.32 E .83 7427.90N 3911.74E 75 49 N 24.60 E .97 7509.92N 3949.92E 8121.02 8212.12 8302.32 8393.14 8483.58 11256.37 5291.32 5248.82 11348.87 5315.42 5272.92 11442.77 5340.35 5297.85 11535.67 5365.38 5322.88 11628.77 5390.97 5348.47 75 10 N 24.56 E .69 ' 7592.15N 3987.53E 74 36 N 26.50 E 2.12 7672.72N 4026.01E 74 35 N 25.33 E 1.21 7754.15N 4065.57E 74 8 N 25.15 E .53 7835.07N 4103.71E 73 56 N 25.01 E .25 7916.15N 4141.65E 8573.95 8663.22 8753.74 8843.18 8-932.66 ORIGINAL ~'ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-65 500292275200 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 040897 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70094 KELLY BUSHING ELEV. = 42.50 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11721.07 5415.52 5373.02 75 11 11814.27 5439.83 5397.33 74 33 11908.27 5465.04 5422.54 74 19 12000.57 5490.28 5447.78 73 55 12092.87 5515.76 5473.26 74 1 N 24.97 E 1.35 7996.79N 4179.24E N 25.07 E .69 8078.31N 4217.29E N 26.65 E 1.64 8159.80N 4256.78E N 28.63 E 2.11 8238.44N 4297.97E N 26.49 E 2.24 8317.07N 4339.00E 9021.60 9111.54 9202.08 9290.83 9379.52 12136.47 5527.88 5485.38 73 40 12280.37 5566.89 5524.39 74 51 12366.60 5589.94 5547.44 74 7 12460.70 5615.60 5573.10 74 13 12556.50 5641.62 5599.12 74 15 N 26.44 E .79 8354.56N 4357.67E N 26.83 E .86 8478.36N 4419.76E N 28.19 E 1.73 8552.05N 4458.13E N 27.12 E 1.10 8632.25N 4500.15E N 27.14 E .03 8714.30N 4542.20E 9421.39 9559.90 9642.97 9733.49 9825.68 12651.90 5666.35 5623.85 75 41 12747.50 5690.56 5648.06 74 56 12841.60 5715.67 5673.17 74 5 12937.10 5741.22 5698.72 74 52 13031.80 5766.53 5724.03 74 7 N 28.21 E 1.87 8795.88N N 26.70 E 1.72 8877.94N N 26.91 E .93 8958.88N N 25.95 E 1.26 9041.28N N 25.81 E .80 9123.38N 4584.99E 9917.79 4627.63E 10010.25 4668.52E 10100.94 4709.48E 10192.95 4749.31E 10284.20 13127.30 5793.22 5750.72 73 25 13222.80 5819.98 5777.48 74 2 13317.40 5845.68 5803.18 74 25 13412.90 5872.01 5829.51 73 33 13508.40 5898.03 5855.53 74 49 N 26.44 E .97 9205.70N N 25.28 E 1.33 9288.19N N 24.68 E .74 9370.72N N 23.61 E 1.41 9454.48N N 25.61 E 2.41 9538.00N 4789.68E 10375.88 4829.66E 10467.55 4868.11E 10558.55 4905.65E 10650.26 4943.91E 10742.07 13604.10 5924.04 5881.54 73 38 13699.50 5949.81 5907.31 75 0 13795.10 5975.03 5932.53 74 23 13890.70 5999.93 5957.43 75 25 13985.80 6024.61 5982.11 74 30 N 25.49 E 1.24 9621.09N N 24.81 E 1.59 9704.23N N 24.94 E .66 9787.88N N 26.83 E 2.19 9870.90N N 27.99 E 1.52 9952.43N 4983.62E 10834.15 5022.65E 10925.97 5061.45E 11018.13 5101.75E 11110.41 5144.02E 11202.24 14081.30 6049.12 6006.62 75 45 14176.90 6073.28 6030.78 74 58 14272.30 6097.73 6055.23 75 18 14367.80 6122.66 6080.16 74 25 14463.30 6148.83 6106.33 73 45 N 29.08 E 1.71 10033.51N N 28.39 E 1.07 10114.61N N 29.78 E 1.45 10195.19N N 28.89 E 1.28 10275.56N N 28.02 E 1.12 10356.30N 5188.11E 11294.47 5232.57E 11386.91 5277.39E 11479.02 5322.55E 11571.10 5366.32E 11662.89 14558.90 6177.66 6135.16 71 7 14654.30 6210.42 6167.92 68 41 14749.90 6247.26 6204.76 65 57 14845.50 6288.10 6245.60 63 27 14940.30 6332.00 6289.50 61 21 N 27.70 E 2.77 10436.88N N 28.38 E 2.63 10515.94N N 26.74 E 3.27 10594.13N N 25.71 E 2.79 10671.65N N 24.64 E 2.43 10747.67N 5408.91E 11754.01 5451.01E 11843.55 5491.83E 11931.74 5530.04E 12018.17 5565.77E 12102.15 PAGE 3 ~'ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE POINT / MPF-65 500292275200 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 040897 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70094 KELLY BUSHING ELEV. = 42.50 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 15035.80 6379.62 6337.12 58 49 N 23.61 E 2.82 10823.21N 15131.40 6430.68 6388.18 56 35 N 22.89 E 2.41 10897.45N 15226.80 6484.54 6442.04 54 37 N 22.58 E 2.08 10970.05N 15322.30 6541.79 6499.29 51 42 N 23.65 E 3.19 11040.34N 15417.80 6602.03 6559.53 50 4 N 23.24 E 1.73 11108.32N 5599.61E 12184.84 5631.51E 12265.51 5661.94E 12344.05 5691.93E 12420.33 5721.41E 12494.31 15512.90 6665.49 6622.99 46 11 N 24.45 E 4.20 11173.09N 15608.20 6734.03 6691.53 41 47 N 25.38 E 4.67 11233.11N 15703.60 6806.91 6764.41 38 34 N 27.14 E 3.57 11288.32N 15799.30 6883.25 6840.75 35 35 N 28.05 E 3.18 11339.46N 15894.90 6962.56 6920.06 32 17 N 23.84 E 4.24 11387.39N 5750.01E 12565.04 5777.87E 12631.18 5805.07E 12692.72 5831.79E 12750.42 5855.20E 12803.75 15990.70 7043.85 7001.35 31 35 N 25.53 E 1.19 11433.44N 16086.40 7125.88 7083.38 30 23 N 25.01 E 1.27 11478.00N 16182.10 7208.96 7166.46 29 7 N 25.28 E 1.35 11521.00N 16277.60 7292.72 7250.22 28 16 N 23.41 E 1.30 11562.76N 16373.40 7377.43 7334.93 27 24 N 24.43 E 1.03 11603.66N 5876.35E 12854.40 5897.39E 12903.67 5917.57E 12951.15 5936.48E 12996.96 5954.61E 13041.65 16468.90 7462.56 7420.06 26 30 N 22.05 E 1.48 11643.42N 16564.50 7548.41 7505.91 25 41 N 24.41 E 1.38 11682.06N 16619.70 7598.28 7555.78 25 5 N 24.67 E 1.11 11703.59N 16660.10 7634.88 7592.38 24 58 N 25.38 E .81 11719.08N 16705.10 7675.71 7633.21 24 45 N 24.71 E .78 11736.22N 5971.70E 13084.85 5988.27E 13126.82 5998.10E 13150.48 6005.33E 13167.56 6013.34E 13186.48 16853.00 7810.01 7767.51 24 45 N 24.71 E .00 11792.49N 6039.23E 13248.39 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 13248.97 FEET AT NORTH 27 DEG. 7 MIN. EAST AT MD = 16853 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 26.58 DEG. TIE-IN SURVEY AT 8,550.30' MD PROJECTED SURVEY AT 16,853.00' MD ~--ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING MILNE POINT / MPF-65 500292275200 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/22/97 DATE OF SURVEY: 040897 JOB NUMBER: AK-EI-70094 KELLY BUSHING ELEV. = 42.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 8550.30 4598.95 4556.45 5249.76 N 2826.95 E 3951.3 9550.30 4873.61 4831.11 6104.31 N 3267.55 E 4676.6 10550.30 5123.38 5080.88 6970.02 N 3699.51 E 5426.9 11550.30 5369.38 5326.88 7847.81 N 4109.69 E 6180.9 12550.30 5639.93 5597.43 8708.99 N 4539.47 E 6910.3 725.34 750.23 754.00 729.44 13550.30 5909.00 5866.50 9574.47 N 4961.39 E 7641.3 14550.30 6174.90 6132.40 10429.67 N 5405.12 E 8375.4 15550.30 6691.78 6649.28 11197.27 N 5761.09 E 8858.5 16550.30 7535.61 7493.11 11676.46 N 5985.73 E 9014.6 16853.00 7810.01 7767.51 11792.49 N 6039.23 E 9042.9 730.93 734.10 483.12 156.17 28.30 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SJ-~'RRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 5 SHARED SERVICES DRILLING MILNE POINT / MPF-65 500292275200 NORTH SLOPE BOROUGH COMPUTATION DATE- 4/22/97 DATE OF SURVEY: 040897 JOB NUMBER: AK-EI-70094 KELLY BUSHING ELEV. = 42.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8550.30 4598.95 4556.45 5249.76 N 2826.95 E 3951.35 8708.66 4642.50 4600.00 5385.59 N 2895.69 E 4066.16 114.81 9068.53 4742.50 4700.00 5692.68 N 3054.33 E 4326.03 259.86 9435.24 4842.50 4800.00 6005.80 N 3216.88 E 4592.74 266.71 9821.89 4942.50 4900.00 6336.09 N 3391.20 E 4879.39 286.65 10217.55 5042.50 5000.00 6674.42 N 3570.27 E 5175.05 295.66 10626.44 5142.50 5100.00 7038.36 N 3727.11 E 5483.94 308.89 11056.80 5242.50 5200.00 7416.51 N 3906.35 E 5814.30 330.36 11450.87 5342.50 5300.00 7761.20 N 4068.91 E 6108.37 294.06 11824.30 5442.50 5400.00 8087.08 N 4221.39 E 6381.80 273.44 12188.49 5542.50 5500.00 8399.26 N 4379.89 E 6645.99 264.18 12559.75 5642.50 5600.00 8717.08 N 4543.62 E 6917.25 271.27 12942.02 5742.50 5700.00 9045.55 N 4711.55 E 7199.52 282.26 13305.55 5842.50 5800.00 9360.34 N 4863.34 E 7463.05 263.53 13671.24 5942.50 5900.00 9679.45 N 5011.20 E 7728.74 265.69 14054.40 6042.50 6000.00 10010.72 N 5175.43 E 8011.90 283.16 14440.67 6142.50 6100.00 10337.12 N 5356.11 E 8298.17 286.27 14738.08 6242.50 6200.00 10584.48 N 5486.94 E 8495.58 197.41 14961.97 6342.50 6300.00 10764.93 N 5573.63 E 8619.47 123.89 15152.88 6442.50 6400.00 10913.97 N 5638.48 E 8710.38 90.91 15323.42 6542.50 6500.00 11041.15 N 5692.28 E 8780.92 70.54 15479.23 6642.50 6600.00 11150.66 N 5739.93 E 8836.73 55.81 15619.50 6742.50 6700.00 11239.86 N 5781.09 E 8877.00 40.26 15748.68 6842.50 6800.00 11312.90 N 5817.78 E 8906.18 29.19 15871.06 6942.50 6900.00 11375.67 N 5849.87 E 8928.56 22.38 15989.11 7042.50 7000.00 11432.69 N 5875.99 E 8946.61 18.05 16105.67 7142.50 7100.00 11486.83 N 5901.51 E 8963.17 16.55 16220.50 7242.50 7200.00 11537.90 N 5925.55 E 8978.00 14.83 16334.05 7342.50 7300.00 11587.17 N 5947.12 E 8991.55 13.55 16446.49 7442.50 7400.00 11634.15 N 5967.95 E 9003.99 12.44 16557.94 7542.50 7500.00 11679.47 N 5987.10 E 9015.44 11.45 16668.50 7642.50 7600.00 11722.28 N 6006.85 E 9026.00 10.56 16778.65 7742.50 7700.00 11764.21 N 6026.22 E 9036.15 10.15 16853.00 7810.02 7767.52 11792.49 N 6039.23 E 9042.98 6.83 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) PO S RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-65 500292275200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 033097 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70085 KELLY BUSHING ELEV. = 42.50 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -42.50 0 0 331.20 331.18 288.68 0 53 421.10 421.05 378.55 1 41 510.90 510.80 468.30 2 13 600.80 600.61 558.11 2 48 N .00 E .00 .00N .00E .00 N 75.97 E .27 .63N 2.51E 1.69 N 74.99 E .89 1.14N 4.48E 3.03 N 73.08 E .60 1.99N 7.43E 5.11 N 70.97 E .66 3.22N ll.t9E 7.89 693.50 693.17 650.67 3 36 784.30 783.73 741.23 4 34 875.20 874.26 831.76 5 45 966.00 964.39 921.89 8 11 1089.70 1086.31 1043.81 11 10 N 75.39 E .89 4.70N 16.16E 11.43 N 78.39 E 1.10 6.15N 22.47E 15.55 N 87.61 E 1.58 7.07N 30.57E 20.00 N 74.45 E 3.19 8.99N 41.35E 26.54 N 75.18 E 2.42 14.42N 61.42E 40.37 1181.80 1176.44 1133.94 12 30 1275.40 1267.66 1225.16 13 28 1368.20 1357.70 1315.20 14 32 1459.60 1445.73 1403.23 16 41 1553.10 1535.49 1492.99 15 50 N 85.62 E 2.74 17.46N 79.99E 51.41 N 74.29 E 2.90 21.19N 100.60E 63.96 N 70.70 E 1.49 27.96N 121.99E 79.59 N 63.71 E 3.12 37.57N 144.59E 98.29 N 57.78 E 1.99 50.31N 167.42E 119.91 1646.50 1625.40 1582.90 15 33 1740.80 1716.14 1673.64 16 2 1833.80 1805.22 1762.72 17 25 1927.00 1893.88 1851.38 18 26 2020.20 1982.01 1939.51 19 30 N 54.56 E .98 64.37N 188.41E 141.87 N 53.63 E .58 79.43N 209.20E 164.65 N 44.51 E 3.19 96.99N 229.32E 189.35 N 39.09 E 2.10 118.38N 248.40E 217.02 N 32.46 E 2.58 142.96N 266.05E 246.89 2113.20 2069.21 2026.71 21 8 2208.10 2156.87 2114.37 23 54 2301.00 2241.02 2198.52 26 10 2395.10 2324.73 2282.23 28 9 2487.60 2405.52 2363.02 30 5 N 29.05 E 2.17 170.72N 282.52E 279.09 N 29.03 E 2.91 202.50N 300.16E 315.40 N 28.26 E 2.47 237.00N 319.00E 354.69 N 29.58 E 2.20 274.60N 339.78E 397.61 N 30.72 E 2.17 313.51N 362.40E 442.53 2581.80 2485.95 2443.45 32 36 2675.40 2564.03 2521.53 34 18 2768.00 2639.69 2597.19 36 4 2881.40 2730.50 2688.00 37 29 2954.60 2787.72 2745.22 39 39 N 30.81 E 2.68 355.61N 387.46E 491.39 N 30.58 E 1.82 399.99N 413.79E 542.86 N 32.14 E 2.14 445.55N 441.57E 596.04 N 32.57 E 1.27 502.91N 477.92E 663.60 N 30.95 E 3.26 541.72N 501.93E 709.05 3048.00 2857.91 2815.41 3140.60 2924.48 2881.98 3234.40 2989.47 2946.97 3327.40 3051.74 3009.24 3420.40 3111.20 3068.70 42 45 47 48 51 52 11 4 51 38 N 32.33 E 3.57 594.14N 534.25E 770.40 N 31.68 E 2.55 648.71N 568.35E 834.45 N 32.00 E 2.02 706.15N 604.02E 901.78 N 30.63 E 2.21 765.15N 639.90E 970.61 N 28.84 E 3.34 827.24N 675.34E 1041.99 ORIGINAL i997 S' 2RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EXPLORATION MILNE POINT / MPF-65 500292275200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 033097 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-70085 KELLY BUSHING ELEV. = 42.50 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 3513.70 3167.60 3125.10 53 56 N 28.62 E 2.47 3606.90 3221.03 3178.53 56 4 N 27.53 E 2.49 3700.80 3270.16 3227.66 60 48 N 29.45 E 5.33 3792.90 3314.48 3271.98 61 38 N 27.38 E 2.17 3885.30 3356.34 3313.84 64 28 N 27.81 E 3.10 892.39N 959.76N 1030.05N l101.04N 1174.04N 711.06E 1116.24 746.98E 1192.55 785.16E 1272.50 823.56E 1353.17 861.72E 1435.53 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 1456.34 FEET AT NORTH 36 DEG. 16 MIN. EAST AT MD = 3885 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 26.58 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD LAST SURVEY STATION AT 3,885.30' MD RRY-SUN DRILLING SERVICES ANCHOR_AGE A_LAS KA PAGE BP EXPLORATION MILNE POINT / MPF-65 500292275200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 033097 JOB NUMBER: AK-EI-70085 KELLY BUSHING ELEV. = 42.50 FT. OPERATOR: BP EXPLOP~ATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -42.50 .00 N .00 E 1000.00 998.00 955.50 10.34 N 46.25 E 2000.00 1962.97 1920.47 137.27 N 262.43 E 3000.00 2822.27 2779.77 566.88 N 517.22 E 3885.30 3356.34 3313.84 1174.04 N 861.72 E .00 2.00 2.00 37.03 35.03 177.73 140.70 528.96 351.23 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE POINT / MPF-65 500292275200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 033097 JOB NUMBER: AK-EI-70085 KELLY BUSHING ELEV. = 42.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .0 42.50 42.5 142.50 142.5 242.51 242.5 342.52 342.5 -42.5 .0 100.0 200.0 300.0 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .29 N 1.17 E .01 .01 .67 N 2.68 E .02 .01 442.56 442.5 542.62 542.5 642.74 642.5 742.94 742.5 843.28 842.5 400.0 500.0 600.0 700.0 800.0 1.31 N 5.09 E 2.36 N 8.62 E 3.89 N 13.16 E 5.48 N 19.23 E 6.93 N 27.38 E .06 .03 .12 .07 .24 .12 .44 .20 .78 .35 943.91 942.5 1045.13 1042.5 1147.03 1142.5 1249.54 1242.5 1352.50 1342.5 900.0 1000.0 1100.0 1200.0 1300.0 8.25 N 38.43 E 12.30 N 53.49 E 16.89 N 72.48 E 19.75 N 94.83 E 26.66 N 118.27 E 1.41 .63 2.63 1.22 4.53 1.90 7.04 2.51 10.00 2.95 1456.23 1442.5 1560.39 1542.5 1664.25 1642.5 1768.26 1742.5 1872.88 1842.5 1400.0 1500.0 1600.0 1700.0 1800.0 37.16 N 143.73 E 51.37 N 169.10 E 67.13 N 192.29 E 84.16 N 215.26 E 105.33 N 237.52 E 13.73 3.74 17.89 4.16 21.75 3.86 25.76 4.01 30.38 4.62 1978.29 1942.5 2084.56 2042.5 2192.42 2142.5 2302.65 2242.5 2415.26 2342.5 1900.0 2000.0 2100.0 2200.0 2300.0 131.19 N 258.51 E 161.69 N 277.51 E 197.01 N 297.12 E 237.64 N 319.34 E 282.87 N 344.48 E 35.79 5.41 42.06 6.27 49.92 7.86 60.15 10.23 72.76 12.61 2530.41 2442.5 2649.34 2542.5 2771.47 2642.5 2896.52 2742.5 3027.12 2842.5 2400.0 2500.0 2600.0 2700.0 2800.0 332.05 N 373.41 E 387.34 N 406.32 E 447.28 N 442.66 E 510.67 N 482.87 E 582.21 N 526.75 E 87.91 15.15 106.84 18.93 128.97 22.14 154.02 25.05 184.62 30.59 3166.17 2942.5 3313.36 3042.5 3471.22 3142.5 3646.46 3242.5 3853.78 3342.5 2900.0 3000.0 3100.0 3200.0 3300.0 664.15 N 577.88 E 756.06 N 634.52 E 862.32 N 694.63 E 989.10 N 762.56 E 1148.97 N 848.54 E 223.67 39.06 270.86 47.19 328.72 57.86 403.96 75.24 511.28 107.32 S=~--%RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 BP EXPLORATION MILNE POINT / MPF-65 500292275200 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 033097 JOB NUMBER: AK-EI-70085 KELLY BUSHING ELEV. = 42.50 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3880.00 3354.05 3311.55 1169.81 N 859.49 E 525.95 14.67 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 6/30/97 GeoQuest 500 Wo International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11118 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) Well Job # Log Description Date BL RF Sepia ' LIS Tape MPU B-14 L~- ~ C ...... INJECTION PROFILE 970607 I I : i MPU E-07 bx. t C.. INJECTION PROFILE 9 70 60 6 1 1 MPU E-16 ~-" INJECTION PROFILE 970605 1 1 MP U F-05 ~,,--' ~ PERFORATION RECORD 9 70 51 7 1 1 M PU F-05 ~- TEMP & PRESSURE SURVEY 9 70 51 7 1 1 MPU F-05 ~-' GR/CCL LOG 970517 I I , MPU F-26 ~-" GPJCCL LOG 970525 I 1 'MPU F-26 ~.-' STATIC PRESS &TEMP 970527 I 1 MPU F-26 v" PERFORATION RECORD 970527 I 1 MPU F-50 '" PERFORATION RECORD 97050 8 I 1 MPU F-50 .."' STATIC PRESSURE SURVEY 970509 I 1 MPU F-57 ','"' PERFORATION RECORD 970512 I 1 MPU F-62 ~," i.-(-t C INJECTION PROFILE 970608 I 1 MPU F-65 .,/ PERFORATION RECORD 970511 I 1 MPH -07 '~ GPJCCL RECORD 970424 I 1 MPH -07 '-- GPJCCL RECORD 970427 I 1 , PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received ~~,_~~ Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) June 18, 1997 TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the MWD Depth Corrected CDR/ADN, CDR/ADN TVD'S & GR/CCL for well MPF-65, Job # 97230 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each I Depth Shift Display State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 ... _. I OH tls Tape 1 Blueline each 1 RF Sepia each OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710 I OH LIS Tape I Blueline each 1 RF Sepia each Sent Certified Mail' P 067 695 338 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99~.6¢1~ Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~, .~ ~-~~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial Workover: X Nabors Rig No. BPX MPU F-65 Set ~ 16,840' X Weekly Other 4ES PTD # Rep.: Rig Rep.: Location: Sec. DATE: 6/9/97 96-0049 Rig Ph.# 659-4154 JESSIE NEW GENE S WEA 'IT 6 T. f3N R. fOE Meddian Umiat MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P ,',OP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign Dd. Rig Hazard Sec. P P P Quan. Test Press. I 250/3000 I 250/5,000 250/5,000 1 250/5,000 I 250/5,000 1 250/5,000 2 250/5,000 N/A 250/5,000 Pti= P P P P P P N/A MUD SYSTEM: Visual Alarm Tdp Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure * 250/5,000 P/F * 250/5,000 2 250/5,000 P 250/5,000 CHOKE MANIFOLD: No. Valves 12 I I No. Flanges 28 Manual Chokes 1 Hydraulic Chokes f Test Pressure P/F 250/5,000 P P 250/5,000 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: Four Bottles 2150 Avg. 3,000 I P 1,850 P minutes 32 sec. minutes 18 sec. P Remote: P Psig. Number of Failures: 1 ,Test Time: 2.0 Hours. Number of valves tested 17 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 6,59-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Failure: The furl opening floor safety valve leaked - replaced and replacement tested OK. NO TE:** The upper and lower kelly vavles will be tested when kelly is picked up. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: W'~T~essed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) AWOIFIEE.XLS MEMORANDUM TO: David John~ Chairmarf~ THRU: Blair Wondzell, P. I. Supervisor FROM: Bobby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 9, 1997 FILE NO: AWOIFIEE.doc SUBJECT: BOPE Test - Nabors 4ES BPX - MPU - F-65 PTD # 97-0049 Monday, June 9, 1997: i traveled this date to BPX's MPU well F-65 being worked over by Nabors rig 4ES and witnessed the initial BOPE test. As the attached AOGCC BOPE test report shows there was 1 failure. The full opening floor safety valve leaked. It was replaced and that valve tested OK. Summary: ! witnessed the initial BOPE test on Nabors rig 4ES working over BPX's MPU well F-65. Nabors 4ES - 6/9/97 - test time 2 hours - 1 failure. Attachment: AWOIFIEE.×LS X Unclassified Confidential (Unclassified if doc. removed ) TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 21. 1997 Tim Schoficld. Senior Drilling Enginccr BP Exploration (Alaska). Inc. POBox 196612 Anchorage, AK 99519-6612 Well No. Company Pcmut No. Surf Loc Btmholc Loc Milnc Point Unit MPF-65 BP Exploration (Alaska). Inc. 97-49 2101'NSL. 2520'WEL. Sec 06. TI3N. RIOE. UM 33_2NSL. 1634'WEL. Scc 29. T14N. R10E. UM Dear Mr Schoficld: Enclosed is thc approved application for pcnnit to drill thc abovc rcfcrcnccd xx-cll. Thc pcrmit to drill docs not cxcmpt you from obtaining additional pcmfits rcquircd by law from othcr governmental agcncics, and docs not authorize conducting drilling operations until all other required pcmfitling dctcnninations arc made. Your rcqucst for divcrtcr variancc is approved. Blowout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordance with 20 AAC 25.035. Sufficicnt noticc (approximatcly 24 hours) of thc BOPE test pcrformcd bcforc drilling bcloxv thc surface casing shoe must bc givcn so that a rcprcscntativc of thc Commission mav v,'itncss thc tcst. Noticc may bc inspcctor on thc North Slope pagcr at 659-3607. Chainnan~ BY ORDER OF THE COMMISSION dlffcncl c: ])opt of' l"ish & Game. I labil, at Section - w/o cncl l)cpt ol' l';nvironmcntal Conservation - xv/o cncl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb' Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepent [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 42.5' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355017 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2101' NSL, 2520' WEL, SEC. 06, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3171' NSL, 1725' WEL, SEC. 29, T14N, R10E, UM MPF-65 At total depth 9. Approximate spud date Amount $200,000.00 3352' NSL, 1634' WEL, SEC. 29, T14N, R10E, UM 03/21/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 3355016, 1928'I No Close Approach 4480 16855' MD / 7762' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 300' Maximum Hole Angle 74.68 o Maximum surface 3311 "psig, At total depth (TVD) 7370' / 3679 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H~40 Weld 80' 32' 32' 112' 112' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 8097' 31' 31' 8127' 4482' 977 sx PF 'E', 834 sx 'G', 563 sx PF 'E' 8-1/2" 7" 26# L-80 BTC-Mod 16825' 30' 30' 16855' 7762' 225 sx Class 'G' I i19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate ~% ~,~ ~ ~ V ~ L~'~ Production Liner MkR 1 4 1997 Perforation depth: measured ....... true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Robertson, 564~5159 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the fore~q~ing is trLje and c~r~ect to the best of my knowledge Signed ~ ~'~"-~' / ,4.,' ~J~ _/ / Tim Schofield '- / ~'~1 ~ ~~.:,~x,~t) Title Senior Drilling Engineer Date / Commission Use Only Permit Number . I APl Number ~ _ Approval Date I See cover letter ~-- ~ ~;~ I 50- 0 ~.-~' -, ~ ~-- ~ ~.2..I for other requirements Yes es~ No Conditions of Approval: Samples Required [] Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures .~Y [] No Directional Survey Required ~ Yes [] No Required Working Pressure for BOPE [] 2M; []3M; ~ 5M; [] 10M; [] lSM Other: by order of Approved By Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate Shared Services Drilling Contact: I Well Name: James E. Robertson IMP F-65 I Well Plan Summary 564-5159 IType of Well (producer or injector): IKUPARUK PRODUCER Surface Location: 2100 NSL 2520 WEL Sec 06 T13N R10E UM., AK Target Location: 3171 NSL 1725 WEL Sec 29 T14N R10E UM., AK Bottom Hole Location: 3352 NSL 1634 WEL Sec 29 T14N R10E UM., AK I AFE Number: 1337067 Estimated Start Date: 121MAR97 I I Rig: I Nabors 22-E Operating days to complete: IMD: 116,855, I I TVD: 17,762' bkb I IKBE: I® Well Design: IMilne Point Ultra Slimhole Longstring 9-5/8", 40# Surface X 7", 26# Longstring Formation Markers: Formation Tops MD TVD (bkb) base permafrost 1,818 1,792 NA 6236 3982 Top of Schrader Bluff Sands (8.3 ppg) Seabee Shale 7977 4442 Base of Schrader Bluff Sands (8.3 ppg) HRZ 16057 7071 High Resistivity Zone MK-19 16103 7111 Top Kuparuk 16231 7221 Kuparuk Cap Rock Target Sand -Target 16451 7412 Target Sand (9.6 ppg) I,~/~,~ Total Depth 16855 7762 *'"'~'k-- '" ;~" ~' Casing/Tub ing Program: Hole Size Csg~ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1 # H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btm 8097 31/31 8127/4482 8-1/2" 7" 26# L-80 btm- 16825 30/30 16855/7762 mod Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at _+7370 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3679 psi (9.6 ppg EMW) is 3311 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface MWD Directional surface to TD. LWD Gamma Ray surface to TD Intermediate N/A Final MWD Directional and LWD Triple Combo(GR/RES, Density, Neutron). Cased Hole Logs: N/A Mudloggers are NOT required for this well. Mud Program: Special design considerations I None-SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 50 15 8 10 9 8 to to to to to to to 9.4 150 35 15 30 10 15 Intermediate Mud Properties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 35 6 3 7 8.5 6-12 to to to to to to to 11.2 50 20 10 20 9.5 4-6 Well Control: Shared Services Drilling requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (7)(b) "Secondary Well Control: Blowout Prevention Equipment (BOPE) Requirements" based upon historical drilling experience on 'F' Pad in the Milne Point Unit. To date, there have been 32 wells drilled on Milne Point 'F' Pad. None of these wells experienced any difficulty with shallow gas in the interval prior to placement of surface casing to depths not exceeding 5000' TVD Sub Sea. In light of the historical evidence indicating virtually no risk due to shallow gas at Milne Pt. 'F' Pad within the above mentioned interval, it is requested that forthcoming wells on the pad - for as long as the drilling on 'F' Pad remains continuous - can be drilled without the installation of the diverter system. A 20" riser will be installed to act as a conduit to facilitate drilling mud flow. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed after setting surface casing and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 1300' IMaximum Hole Angle: Close Approach Well: 74.68° NONE Disposal: Cuttings Handling: Cuttings and drilling waste fluids should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. , 2. 3. 4. 5. , . 11. 12. 13. 14. 15. MP F-65 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU 20" riser. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD and LWD GR from surface to TD. Run and cement 9-5/8" casing. ND riser. NU and test 13-5/8" BOP. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 20' of new formation. Perform LEAKOFF TEST. If LOT EMW is less than 12.5 ppg contact appropriate superintendent. Drill 8.5" hole to TD as per directional plan. Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with completion fluid and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig for 30 min. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. MIRU completion rig. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing. Install Surface Lines and Wellhouse and turn well over to production. DRILLING HAZARDS AND RISKS: Seethe updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on F Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Close Approach: There are no close approaches associated with the drilling of MP F-65. Lost Circulation: There has not been any appreciable amount of lost circulation on any of the F Pad wellls to date. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. If significant gravels are encountered stop and raise funnel viscosity to 150 cp viscosity immediately. Formation Pressure: The maximum expected pore pressure for this well is 9~6 pp.q~EMW. (3,679 psi @ 7,370' TVDss). There has been no injection in this region, therefore the reservoir pressure should not exceed this estimate and it is likely the area is somewhat depleted. MP F-65 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 60 deg F at 2840' TVDSS. SPACER: 75 bbls spacer weighted to mudweight in the hole. STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder + CELLO-FLAKES (1/4 lb/sack) 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk 977 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANUULAR VOLUME FROM 100 FEET TVD ABOVE SCHRADER BLUFF TO BASE OF PERMAFROST AT 1800' MD +30% EXCESS +ANNULAR VOLUME FROM 1800' MD TO STAGE COLLAR AT 1300' MD +200% EXCESS. STAGE1 TAIL CEMENT TYPE: ADDITIVES: WEIGHT: APPROX #SACKS: FLUID LOSS: PREMIUM 'G' 0.2% CFR-3 + 0.20% HALAD-344 + CELLO-FLAKES 15.8 ppg YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk 834 THICKENING TIME: Greater than 4 hrs at 50° F. 100-150 cc FREE WATER: 0 TAIL CEMENT FROM TD TO 100 FEET TVD ABOVE TOP of Schrader Bluff + 30% EXCESS + 80'md 9-5/8", 40# capacity for float joints. STAGE2 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg 563 SACKS YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. ANUULAR VOLUME FROM STAGE COLLAR AT 1300' MD TO SURFACE+ 200% EXCESS. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX NO SACKS: 150 RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. I Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. MP F-65 Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL: CIRC. TEMP: SPACER: 140° F BHST 170° F at 7040' TVDSS. 20 bbls fresh water 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: WEIGHT: 15.8ppg APPROX # SACKS: FLUID LOSS: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk 225 SACKS THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F < 50cc/30 min @ 140° FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: . 7"x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 20 joints of 7" casing (40). This will cover __.300' above the KUPARUK Sand. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: . Single stage cement job is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand with 30% excess. SHARED · ii ii iiii SERV T CES BR'TI'L T' 6 i i ii i i iii 4nadrJ ]] Schlumberger - ' , ..... :,..Z . J_ MPF-65 (P7) VERTICAL SECTION VIEW __ Section at: 26.58 TVD Scale.: I inch = 1600 feet Dep Scale.: I inch = 1600 feet Drawn ..... : 05 Mar .1997 - A ......... Harker Identification MD BKB SECTN INCI B -- I . A) KB 0 0 0 '0. C '- ; i ~ I B) KOP/BUILO ]/]OO 300 300 0 0.( , . C) BUILD i.5/lO0 500 500 -~D'-F }. ............ ; -.[ i, I . O) BUILD 2/']00 B00 799 ,§ 6.! I ' i ' ' E) CURVE 2/100 1200 1t92 6! E ., I , ........... ] ........... ; ..... ~_~ ................. '~-~- ~22 ............... ~ ......... i ........ 'i ~ : ~~ ...... ~ : I ; · i . ..............:. .... ............ , 222~ .............................. 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 t0400 tt200 ~.2000 12800 ~3600 Sect ion Departure (Anadrill (c)97 HPF65P7 3.0C 10:49 AH P) 'l ~dius 20( 0 Mar-O6-g7 og:35A Anadrill DPC 907 344 2160 P .04 i ii Dii m m mi m · [ SHARE SERVICES DRILLING i i i i ~, ~,~ ~/,oo o~o~ ,~o~, ~o~,. ,~_~o~ ~o.oo ~) ~,~, ,~,~ ~,,~ ,~,o, ~o.oo VERTICAL SECTION VIEW D) TD 16855 776~ ~3303 30.00 SeCtion at: 26.58 TVD Scale · 1 inch : 100 feet 7ODD -- Dep Scale.' 1 inch : 100 feet m Drawn ..... : 05 Mar ~997 : :': ' 7050' ~2-~: .._ _- ,~-~ ~adri ]1 Schlumberger 7 ~50 ........... ~. .... : ........ ~ [_'. -2'2-" ~ 5 . .. ~oo -,._'. T Al~i:'.."~.-~)V~!.~"~ FO~ ' q I f T 7~50 .... - .......................... , .................... ~ I : " I D 7300- ., , i , 7~50 .......................... ~ ....................................... , 7400 ~ , T~n~T (Radius 200 feet ) ~) - 748 ..................... ) ..... _ . i 7500 '~- i ................. i ~¢o ..................... : . ....,~ ,~.,?~. _: ........... - . . I ' I~ ' i 7650 ........ ~ ..................................... 77~0- -' ............... ~ .................... 7BOO m ' I Section DepaPture ' ~ Mar-06-g7 09:35A Anadrill DPC 907 344 2160 P.05 SHARED Marker Identification MD N/S A) KB 0 0 N B) KOP/BUILD 1/100 300 0 N C) BUILD 1.5/100 500 1 N D) BUILD 2/100 BOO 5 N E) CURVE 2/100 1200 20 N F) END 2/100 CURVE 1773 97 N G) BUILD 2.5/100 1847 113 N H) CURVE 8.5/~00 2300 247 N I) END 2.5/100 CURVE 4258 t536 N J) 9-5/8" CASING POINT 8127 4874 N- K) DROP 3/t00 14569 10429 N L) END 3/100 DRoP 16058 11457 N M) TARGET 16452 11633 N N) 7' CASING POINT 16855 1J814 N O) TD 16855- tt8~4 N SERVICES E/W 96 E 204 E 213 E 294 E g7B E 2648 E 5427 E 5941E 6029 E 6120 E 6t20 E DRILLTNG i i MPF-65 (P7) PLAN VIEW I CLOSURE ' · 13305 feet at Azimuth 27.38 DECLINATION' +28.063 (E) SCALE ' 1 inch: 2000 feet DRAWN · 05 Mar 1997 Jnadrj ]] $chYumberger ~000' 0 ]000 2000 3000 '4000 5000 6000 7000 8000 9000 10000 I~000 12000 13000 <- NEST · EAST -> (Anadri]l (c]g7 ~F65P7 3.0C J0:53 AM P) 07071 VENDOR I I o3~1 o',97 CKO~IOg?A ~[SC I I ~ m S/H TERR[ HUBSI.[ X 4628 i i [ i i i i i i i ] i I I I I I I I I I I I I I I I I I I I I I I THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ..... WELL PERMIT CHECKLISTco IELD. POOL ~ WELL NAME INIT CLASS ~ ~.a., /'~/1 GEOL AREA ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. 10. Operator has appropriate bond in force ........ ll. Permit can be issued without conservation order... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait.' ...... PROGRAM: expo dev~redrl[] servO wellbore segD ann disp para reqO ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ Y~ N CMT vol adequate to circulate on conductor & surf csg..~ 16. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or rese~e pit ............ N 21. If a re-drill, has a 10-403 for abndn~t been approved.~¢~-~--~Fr' 22. Adequatewellboreseparationproposed .......... --YI~N ~~ 23. If diverter required, is it adequate ........... N ~ 24. Drilling fluid progr~ schematic & equip list adequate .~Y~ N 25. BOPEs adequate .................... ( ~_~ N 26. BOPE press rating adequate; test to ~~ psig.~ N~~ 27. Choke manifold complies w/~I ~-53 (May 84) ...... ~ N ~,- 28. Work will occur without operation shutdo~ ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y / &'l ~ 32. Seismic analysis of shallow gas zones .......... y N /.L/~,F ~4 33. Seabed condition survey (if off-shore) ........ /Y N ~ ~ 34. Contact name/phone for weekly progress reports . . ./ . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: JDH ~ mcm Comments/Instructions: t HOWldlf - A:\FORMS\chekiist rev 01/97 Well 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'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER . ****************************** . ............................ * ....... SCHLUMBERGER ....... . ............................ ****************************** COMPANY NAME : BP EXPLORATION WELL NAME : MPF-65 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUAIBER : 500292275200 REFERENCE NO : 97230 Oate. 01 - 0'5 -0~ RECEIVED JUN 1 9 1991 Alaska Oil & Gas Co.s. ~ Anchorage LIS Tape Verificatio~ ~isting Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/06/10 ORIGIN : FLIC REEL NAME : 97230 CONTINUATION # : PREVIOUS REEL : C03~!ENT : B.P. EXPLORATION, MILNE POINT MPF-65, API #50-029-22752-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/06/10 ORIGIN : FLIC TAPE NAME : 97230 CONTINUATION # : 1 PREVIOUS TAPE : COI4FiENT : B.P. EXPLORATION, MILNE POINT MPF-65, API #50-029-22752-00 TAPE HEADER MILNE POINT MWD/MAD LOGS WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB ~ER: LOGGING ENGINEER: OPERATOR WITNESS: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING MPF-65 500292275200 BP EXPLORATION SCHLUMBERGER WELL SERVICES 6-JUN-97 BIT RUN1 BIT RUN2 BIT RUN3 97230 97230 97230 BOSSE BOSSE BOSSE 6 13N 10E 2101 2520 42.30 42.30 13. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9. 625 8613.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 2ND STRING 3RD STRING PRODUCTION STRING Well drilled 25-MAR through 7-APR-97 with MWD GR, CDR, and ADN. Data was collected in three bit $ $ PAGE: **** FILE HEADER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/06/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUAg~ARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (FiEASURED DEPTH) START DEPTH STOP DEPTH 48.0 16860.5 BASELINE DEPTH 88888.0 16599.0 16555.0 16537.0 16530. 0 16525.5 16510. 0 16507. 0 16487.5 16479.5 16463. 0 16457. 0 16444.5 16426. 0 16418.5 16410. 0 16383.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD 88896.0 16607.0 16564.5 16548.5 16542.0 16537.5 16521.5 16518.5 16499.0 16490.5 16474.5 16468.0 16455.5 16437.0 16429.5 16421.0 16394.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 16374.0 16359.5 16316.0 16304.0 16285.0 16261.5 16237.0 16202.0 16195.0 16179.0 16157.0 16137.5 16109.5 16101.5 16072.5 16055.5 16036.5 16010.0 16006.0 15995.5 15957.0 15954.0 15909.5 15892.0 15864.5 15830.5 15814.5 15768.5 1563 O. 5 15592.0 15586.0 15571.0 15549.0 15536.5 15472.5 15370.5 15348.5 15226.0 15140.0 15110.0 14973.5 14864.0 14614.5 14485.5 14286.5 14191.5 14044.0 13980.0 13528.5 13516.0 13469.5 13378.0 13233.0 13161.5 13135.5 16385.5 16370.5 16327.0 16310.5 16296.0 16272.5 16249.0 16213.0 16206.0 16190.5 16168.5 16148.5 16120.0 16112.0 16083.0 16067.0 16047.0 16020.0 16014.5 16004.0 15967.5 15966.0 15918.5 15901.0 15874.0 15842.5 15826.0 15779.0 15640.0 15602.0 15597.0 15581.0 15559.0 15547.5 15482.0 15382.5 15361.0 15238.5 15152.0 15122.5 14985.0 14877.0 14627.5 14496.0 14298.5 14202 5 14059 5 13994 5 13543 5 13530 0 13484, 0 13385.0 13242.5 13174.5 13148.5 lO-JUN-1997 08:55 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 13064.5 13025.0 12970.0 12900.5 12751.5 12493 o 5 12452.5 12274.5 12197.5 12127.0 12107.5 11990.5 11796.0 11721.0 11718.5 11656.5 11635.0 11506.5 11498.0 11445.0 11410.5 11289.0 11250.0 11126.5 11066.5 10990.0 10967.5 10811.5 10790.5 10705.5 10673.0 10488.5 10437.5 10415.0 10410.0 10350.5 10277.0 10196.0 10167.5 10153.5 10135.5 10074.5 10031.0 9894.0 9805.5 9721.0 9708.5 9590.0 9533.0 9422.5 9421.0 9381.0 9252.0 9215.0 9167.0 13076.5 13037.5 12985.5 12911 5 12761 0 12503 0 12461 0 12284 5 12207 0 12138 5 12119, 5 12001.5 11805.5 11731.0 11730.0 11666.0 11646.0 11512.5 11504.5 11455.5 11420.0 11294.5 11256.5 11134.0 11076.0 10996.5 10974.5 10819.5 10798.0 10713.5 10681.0 10499.0 10444.5 10423.5 10419.0 10358.0 10285.5 10205.5 10176.0 10163.0 10145.0 10082.5 10038.5 9902.0 9813.5 9728.5 9716.0 9594.0 9539.0 9431.5 9429.0 9387.5 9257.5 9222.0 9173.5 lO-JUN-1997 08:55 PAGE: LIS Tape Verificatioz~ Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: 9093.0 9047.0 8956.5 8914.5 8879.0 8866.0 8775.5 8761.5 8679.0 8667.0 8650.5 8646.0 8605.0 8602.5 8587.0 8585.0 8540.0 8534. o 8499.0 8479.0 8435.5 8428 5 8367 0 8358 5 8332 5 8303 5 8295 5 100 0 $ MERGED DATA SOURCE LDWG TOOL CODE LWD LWD $ 9100.5 9055.5 8965.5 8923.5 8887.5 8876.5 8782.5 8768 0 8684 0 8671 0 8658 0 8654 5 8612 5 8608 5 8592 5 8589 5 8545.0 8538.5 8502.0 8481.0 8438.5 843 O. 0 8367.5 83 60.5 8332.5 8304.5 8297.5 102.0 BIT RUN NO. MERGE TOP f~ERGE BASE 1 112.0 8625.0 1 8625.0 15304.0 2 15304.0 16853.0 The depth adjustments shown above reflect the MWD GR to the PDC GRCH logged by SWS. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that was reprocessed at GeoQuest. The ADN quadrant outputs are as follows: ROBB/ROBU/ROBL/ROBR are bottom, upper, left, and right quadrant density; and are also listed as RHO1, RH02, RH03, RH04 in the LDWG listing. The other outputs (Delta Rho, PEF, Max. Density) are listed with their quadrants as DRHB/DRHU/DRHL/DRHR, PEB/PEU/ PEL/PER, and ROM~/ROMU/ROf4L/ROFiR. The LDWG outputs of CALA and CALS are HDIA and VDIA respectively. THIS IS THE MERGED AND EDITED DATA FILE. $ LIS FORMAT DATA LIS Tape Verificatioz~ Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD OPi~ O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OH~M O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OH~M O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OH~ O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~ O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI O0 000 O0 0 1 1 1 4 68 0000000000 RHOB MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RHO1 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH02 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH03 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 RH04 MWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E O0 000 O0 0 1 1 1 4 68 0000000000 DCALMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 CALSMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 CALAMWD IN O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: ** DATA ** DEPT. 16860.000 FET.f99~D VRA.MWD -999.250 VRP.MWD GR.MWD -999.250 RHOB.MWD RHO3.MWD -999.250 P~HO4.MWD DCAL.MWD -999.250 CALS.MWD DEPT. 48. 000 FET.MWD VRA.MWD -999. 250 VRP.MWD GR .MWD 15. 580 RHOB.MWD RH03 .MWD -999.250 RHO4.~fw]9 DCAL.M~rD -999.250 CALS.MWD -999.250 RA.MWD -999.250 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALA.MWD -999.250 RA.MWD -999.250 DER.MWD -999.250 RHO1.MWD -999.250 DRHO.MWD -999.250 CALA.MWD -999.250 RP.MWD -999.250 ROP.MWD -999.250 RHO2.MWD -999.250 PEF.MWD -999.250 NPHI.MWD -999.250 RP.MW1) -999.250 ROP.MWD -999.250 RHO2.MWD -999.250 PEF.MWD -999.250 NPHI.MWD -999.250 92.310 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE · 97/06/10 M3LYREC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/06/10 M3L~REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AUJ?/iBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCILEMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD GR 112.0 8625.0 $ LOG HEADER DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION.. DATA TYPE (MEMORY or REAL-TIME) TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 7-APR-97 FAST-4.0 011 _ 4.0C REAL-TIME 16853.0 45.0 16853.0 75 O. O0 76.20 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAk4FiA RAY $ TOOL NUMBER ........... MWD GR BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): 8.500 8613.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OH~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): 300 2. 830 1. 950 85.0 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 0.0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 0.3 20000 MWD GR run 001 Drilled interval:il2'-7399' MWD GR run 002 Drilled interval:7399'-8625' Ail data for MWD GR is real-time downhole transmitted data. Units for MWD GR are AAPI, apparent API. LWD ru~ O01:CDR751V4.1 ADNO45V4.0 (GSRJa2066, NSRMaO033) bit to RES:59.61' GR:70.61' DEN:il4.05' NEU:ll8.18' USCal:l12.76' Drilled interval:8625'-15304'. LWD run O02:CDR751V4.1 ADNO45V4.0 (GSRJa2066, NSRMaO033) bit to RES:56.96' GR:67.96' LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: DEN:ill.20' NEU:llS.33' USCal:109.91' Drilled interval: 15304 ' -16853 '. THIS IS THE RAW MWD GR & ROPE DATA FOR BIT RUN #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 12 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 85 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LWi F/HR O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8624. 000 GR.LW1 -999.250 ROPE.LW1 136. 000 DEPT. 46. 000 GR.LW1 15.580 ROPE.LW1 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: 10 **** FILE TRAILER **** FILE NA~E .. EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/06/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE .. **** FILE HEADER **** FILE NA~E : EDIT .003 SERVICE · FLIC VERSION : O01CO1 DATE : 97/06/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NDY4~ER: 2 DEPTH INCRt~IENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH CDR 8500.5 15303.0 ADN 8500.5 15192.5 $ LOG HEADER DATA DATE LOGGED: 7 -APR- 97 SOFTWARE: SURFACE SOFTWARE VERSION: FAST-4.0 011 _ DOWNHOLE SOFTWARE VERSION: 4. OC DATA TYPE (M~4ORY or REAL-TIME): 14~40RY TD DRILLER (FT) : 16853.0 TOP LOG INTERVAL (FT) : 45.0 BOTTOM LOG INTERVAL (FT) : 16853.0 BIT ROTATING SPEED (RPM) : 75 HOLE INCLINATION (DEG) MINIMUM ANGLE: 55.86 MAXIMU~ ANGLE.. 77.02 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY/GR ADN DENSITY/NEUTRON TOOL NUMBER CDR751 ADN045 LIS Tape Verificatioz, Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: 11 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 8613.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHP94) AT TEMPERATURE (DEGF) : MUD AT S~EASURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): 300 2.830 1.950 NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): O. 0 TOOL STANDOFF (IN): O. 3 EWR FREQUENCY (HZ): 20000 REMARKS: MWD GR run 001 Drilled interval:il2'-7399' MWD GR run 002 Drilled interval:7399'-8625' Ail data for MWD GR is real-time downhole transmitted data. Units for MWD GR are AAPI, apparent API. LWD run O01:CDR751V4.1 ADNO45V4.0 (GSRJa2066, NSRMaO033) bit to RES:59.61' GR:70.61' DEN:Il4.05' NEU:ll8.18' USCal:l12.76' Drilled interval: 8625 ' -15304 '. LWD run 002: CDR751V4.1 ADNO45V4.0 (GSRJa2066, NSRMaO033) bit to RES:56.96' GR:67.96' DEN:Ill.20' NEU:llS.33' USCal:109.91' Drilled interval :15304' -16853 '. THIS IS THE RAW LWD DATA FOR BIT RUN #2. $ LIS FORMAT DATA 85.0 68.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: 12 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE ~ CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUPI~ SAMP ELEM CODE (HEX) DEPT FT O0 000 O0 0 3 1 1 4 68 0000000000 ATR LW2 OHlVl~ O0 000 O0 0 3 1 1 4 68 0000000000 PSR LW2 O~ O0 000 O0 0 3 1 1 4 68 0000000000 ATVR LW2 OHI4~ O0 000 O0 0 3 1 1 4 68 0000000000 PSVR LW2 OPi~I~ O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 OHlVi~ O0 000 O0 0 3 1 1 4 68 0000000000 ROPE LW2 F/HR O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI O0 000 O0 0 3 1 1 4 68 0000000000 TABR LW2 HR O0 000 O0 0 3 1 1 4 68 0000000000 ROI~B LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBU LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBL LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 ROBR LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHB LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHULW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHL LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 DRHR LW2 G/C3 O0 000 O0 0 3 1 1 4 68 0000000000 PEB LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PEU LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PEL LW2 O0 000 O0 0 3 1 1 4 68 0000000000 PER LW2 O0 000 O0 0 3 1 1 4 68 0000000000 CALNLW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 TNPH LW2 PU O0 000 O0 0 3 1 1 4 68 0000000000 DCALLW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 HDIA LW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: 13 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) VDIA LW2 IN O0 000 O0 0 3 1 1 4 68 0000000000 RPM LW2 RPM O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. PSVR . LW2 TABR . LW2 ROBL . LW2 DRHL. LW2 PEL . LW2 DCAL . LW2 16743 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999,250 DEPT. 45. 000 PSVR. LW2 -999. 250 TABR. LW2 - 999.250 ROBL. LW2 - 999. 250 DRHL. LW2 -999. 250 PEL. LW2 -999. 250 DCAL. LW2 - 999. 250 ATR.LW2 -999.250 PSR.LW2 -999.250 ATVR.LW2 DER. LW2 -999. 250 ROPE. LW2 -999. 250 GR. LW2 ROMB.LW2 -999.250 ROBB.LW2 -999.250 ROBU. LW2 ROBR.LW2 -999.250 DRHB.LW2 -999.250 DRHU. LW2 DRHR.LW2 -999.250 PEB.LW2 -999.250 PEU. LW2 PER. LW2 -999. 250 CALN. LW2 - 999. 250 TNPH. LW2 HDIA.LW2 -999.250 VDIA.LW2 -999.250 RPM. LW2 ATR.LW2 -999.250 PSR.LW2 -999.250 ATVR.LW2 DER. LW2 -999. 250 ROPE. LW2 -999. 500 GR. LW2 ROM~. LW2 - 999. 250 ROBB. LW2 - 999. 250 ROBU. LW2 ROBR. LW2 -999. 250 DRHB. LW2 - 999. 250 DRHU. LW2 DRHR. LW2 -999. 250 PEB. LW2 -999. 250 PEU. LW2 PER. LW2 -999. 250 CALN. LW2 -999. 250 TNPH. LW2 H~IA.LW2 -999.250 VDIA.LW2 -999.250 RPM. LW2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAi~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/06/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/06/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: 14 FILE NUFiBER 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUM~ER: 3 DEPTH INCREMF2~f: 0.5000 FILE SU~VLARY VENDOR TOOL CODE START DEPTH CDR 15214.5 ADN 15165.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: ~IMUM ANGLE: STOP DEPTH 16852.5 16852.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESISTIVITY/GR AND DENSITY/NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHN~) AT TEMPERATURE (DEGF): MUD AT ~SURED TEMPERATURE (MT): MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): MUD CAKE AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 7 -APR - 97 FAST-4.0 011 _ 4.0C MEMORY 16853.0 45.0 16853.0 75 23.86 53.52 TOOL NUMBER ........... CDR751 ADN045 8.500 8613.0 300 2.830 85.0 1. 950 68.0 SAArDSTONE 2.65 0.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: 15 TOOL STANDOFF (IN): O. 3 EWR FREQUENCY (HZ): 20000 REMARKS: MWD GR run 001 Drilled interval:il2'-7399' MWD GR run 002 Drilled interval:7399'-8625' Ail data for MWD GR is real-time downhole transmitted data. Units for MWD GR are AAPI, apparent API. LWD run O01:CDR751V4.1 ADNO45V4.0 (GSRJa2066, NSRMaO033) bit to RES:59.61' GR:70.61' DEN:ll4.05' NEU:ll8.18' USCa1:112.76' Drilled interval: 8625 ' -15304 '. LWD run O02:CDR751V4.1 ADNO45V4.0 (GSRJa2066, NSRMaO033) bit to RES:56.96' GR:67.96' DEN: 111.20 ' NEU: 115.33 ' USCal: 109.91 ' Drilled interval :15304 ' -16853 '. THIS IS THE RAW LWD DATA FOR BIT RUN #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 108 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-JUN-1997 08:55 PAGE: 16 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 4 1 1 4 68 0000000000 DEPT FT ATR LW3 OHM~ O0 000 O0 0 4 1 1 4 68 0000000000 PSR LW3 OHlZi~ O0 000 O0 0 4 1 1 4 68 0000000000 ATVRLW3 OHFiM O0 000 O0 0 4 1 1 4 68 0000000000 PSVR LW3 OI-IFi~ O0 000 O0 0 4 1 1 4 68 0000000000 DER LW3 OHF~4 O0 000 O0 0 4 1 1 4 68 0000000000 ROPE LW3 F/HR O0 000 O0 0 4 1 1 4 68 0000000000 GR LW3 GAPI O0 000 O0 0 4 1 1 4 68 0000000000 TABR LW3 HR O0 000 O0 0 4 1 1 4 68 0000000000 ROMB LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBB LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBU LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBL LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 ROBR LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHB LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHULW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHL LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 DRHR LW3 G/C3 O0 000 O0 0 4 1 1 4 68 0000000000 PEB LW3 O0 000 O0 0 4 1 1 4 68 0000000000 PEU LW3 O0 000 O0 0 4 1 1 4 68 0000000000 PEL LW3 O0 000 O0 0 4 1 1 4 68 0000000000 PER LW3 O0 000 O0 0 4 1 1 4 68 0000000000 CALNLW3 PU O0 000 O0 0 4 1 1 4 68 0000000000 TNPH LW3 IN O0 000 O0 0 4 1 1 4 68 0000000000 DCD~ LW3 IN O0 000 O0 0 4 1 1 4 68 0000000000 HI)IA LW3 IN O0 000 O0 0 4 1 1 4 68 0000000000 VDIA LW3 RPM O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 16852.500 ATR . LW3 PSVR. LW3 -999. 250 DER. LW3 TABR. LW3 - 999. 250 ROf4~. LW3 ROBL. LW3 -999. 250 ROBR. LW3 DRHL. LW3 ~ 999. 250 DRHR. LW3 PEL . LW3 -999. 250 PER. LW3 DCAL. LW3 - 999. 250 HDIA. LW3 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 DEPT. 15165. 000 ATR . LW3 -999. 250 PSVR. LW3 - 999.250 DER. LW3 - 999. 250 TABR. LW3 -999. 250 ROMB. LW3 -999. 250 ROBL.LW3 -999.250 ROBR.LW3 -999.250 DRHL. LW3 - 999. 250 DRHR. LW3 -999. 250 PEL. LW3 -999. 250 PER. LW3 -999. 250 DCAL.LW3 -999.250 HDIA.LW3 -999.250 PSR.LW3 -999.250 ATVR.LW3 ROPE. LW3 92. 786 GR. LW3 ROBB.LW3 -999.250 ROBU. LW3 DRHB. LW3 -999. 250 DRHU. LW3 PEB. LW3 -999. 250 PEU. LW3 CALN. LW3 -999. 250 TNPH. LW3 VDIA. LW3 -999. 250 PSR.LW3 -999.250 ATVR.LW3 ROPE. LW3 -999. 250 GR. LW3 ROBB. LW3 -999. 250 ROBU. LW3 DRHB . LW3 - 999. 250 DRHU. L W3 PEB. LW3 - 999. 250 PEU. LW3 CALN. LW3 -999. 250 TNPH. LW3 VDIA. LW3 -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center lO-JUN-1997 08:55 PAGE: 17 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 97/06/10 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NABIE : EDIT DATE : 97/06/10 ORIGIN : FLIC TAPE NA~E : 97230 CONTINUATION # : 1 PREVIOUS TAPE : COF~ENT : B.P. EXPLORATION, MILNE POINT MPF-65, API #50-029-22752-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/06/10 ORIGIN . FLIC REEL NAME : 97230 CONTINUATION # : PREVIOUS REEL : COFk~mNT : B.P. EXPLORATION, MILNE POINT MPF-65, API #50-029-22752-00