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Home My WebLink About196-0161. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Isolate Sag River Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Set plug and Cement 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 10,850 feet 9,000 feet true vertical 9,362 feet N/A feet Effective Depth measured 9,000 feet feet true vertical 7,769 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6 / 13Cr / VAM 7,938' 6,923' 4-1/2" 12.6 / 13Cr / JBEAR 10,052' 8,646' Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / 13Cr / VAM 10,142' 8,726' 7" x 4-1/2" (2) Packers and SSSV (type, measured and true vertical depth)7" x 4-1/2" Premier 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: 8,098, 9,015 & 10,090 7,049. 7,781 & 8,679 324-609 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 Erik Nelson Erik.Nelson@hilcorp.com 907-564-5277 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) 166 Gas-Mcf MD 112' 1,200 Size 112' 4,620' 389 3,435347 0 00 191 measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-016 50-029-22643-00-00 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: ADL0047434 MILNE POINT / KUPARUK RIVER OIL MILNE PT UNIT C-23 Plugs Junk measured LengthCasing Conductor 9,216' 4,941'Surface Production 20" 9-5/8" 7" 80' 4,910'5,750psi 7,240psi10,777' 9,296' Burst N/A Collapse N/A 3,090psi 5,410psi 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 1:30 pm, Jan 06, 2025 Digitally signed by Scott Pessetto (9864) DN: cn=Scott Pessetto (9864) Date: 2025.01.06 12:56:43 - 09'00' Scott Pessetto (9864) JJL 2/7/25 SFD 3/25/2025 DSR-1/8/25 RBDMS JSB 011525 _____________________________________________________________________________________ Revised by: TDF 1/3/2025 SCHEMATIC Milne Point Unit Well: MPU C-23 Last Completed: 9/18/2023 PTD: 196-016 TD =10,850 (MD) / TD =9,362’(TVD) 20” Orig. KB Elev.: 45.4’/ GL Elev.:16.8’(Nabors22E) RKB-THF: 21.30’ (Nabors 4ES) 9-5/8” RA Tag in top collar of joint at 10,060’ PBTD =10,689’ (MD) / PBTD = 9,216’(TVD) 7” 1 2 4 3 Min ID = 3.725” Sag RiverLast Tag: 10,622’SLM 1/16/2020 3” DD bailer TOC calculated at 6,398’ MD Kuparuk River 7 8 10 11 9 6 Tubing Cut @ 10,085 WLM 9/13/2023 TOC @ 9,000’ 5 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1/ H-40 / NA 19.124” Surface 112’ 9-5/8" Surface 40 / L-80 / BTC 8.835” Surface 4,941’ 7" Production 26 / L-80 / BTC 6.276” Surface 10,777’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13Cr / VAM 3.958” Surface 7,938’ 4-1/2” Tubing 12.6 / 13Cr / JBEAR 3.958” 7,938’ 10,052’ 4-1/2” Tubing 12.6 / 13Cr / VAM 3.958” 10,085’ 10,142’ WELL INCLINATION DETAIL KOP @ 300’ MD Max Hole Angle = 42° @ 7,007’ MD TREE & WELLHEAD Tree 4-1/16” 5M Cameron Wellhead 11” 5M FMC Gen. 5 w/4-1/2” tbg hanger, 4- 1/2” TCII top/btm threads, 4” “H” BPV profile OPEN HOLE / CEMENT DETAIL 20” 250 sx (approx.) Arctic Set I in 24” Hole 9-5/8” 963 sx Class “E”, 250 Class “G”, plus 114 sx Class “E” top job in 12-1/4” Hole 7” 600 sx Class “G” in 8-1/2” Hole PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk River 8,245’ 8,275’ 7,165’ 7,189’ 30’ 9/21/2023 Open Sag River 10,190’ 10,247’ 8,768’ 8,819’ 57 3/5/1996 Open Ref Log: 3/5/96 AWS gr/ccl 3-3/8” Western Atlas Jumbo Jet 22 gr/6spf/60deg (0.76” EH/6.4” Pen) JEWELRY DETAIL No Depth Item ID 1 7,926’ HAL Sliding Sleeve 3.813” 2 7,990’ Downhole gauge - Suction 3.865” 3 8,098’ 7” x 4-1/2” Halliburton Packer 3.958” 4 8,126’ 4-1/2” “X” Nipple Min ID = 3.813”3.813” 5 9,010’ 10K 4-1/2” CIBP 6 9,015’ 7” x 4-1/2” Packer 3.958” 7 9,045’ 4-1/2” “X” Nipple w/ PX Plug and P-Prong Min ID = 3.813”3.813” 8 10,052’ Baker Non-Sealing Tubing Overshot 4.398” 9 10,090’ 7” x 4-1/2” Premier Packer 3.875” 10 10,129’ 4-1/2” HES “XN”Nipple Min ID = 3.725”3.725” 11 10,140’4-1/2” WLEG –Btm @ 10,142’4.000” GENERAL WELL INFO API: 50-029-22643-00-00 Drilled & Cased by Nabors 22E - 2/17/1996 ESP Completion by Nabors 4ES - 6/2/1996 RWO by Nabors 4ES - 11/9/1996 CTU Jet Pump Completion - 8/13/2000 RWO – Jet Pump Conversion by Nabors 4ES - 10/6/2009 Jet Pump Completion & Perf Add by ASR – 9-18-2023 Well Name Rig API Number Well Permit Number Start Date End Date MP C-23 EL & SL 50-029-22643-00-00 196-016 11/27/2024 12/2/2024 No operations to report. No operations to report. 11/30/2024 - Saturday WELL S/I ON ARRIVAL (profile mod). TAGGED TOC @ 8,991' SLM/ 9,000' MD W/ 3.60" CENT & 2.25" BAILER.(sample of cement). CONFIRMED 'XD' SSD OPEN W/ SHIFTING TOOL.(open). SET 3" JET PUMP ASSY W/ SCREEN(Ratio:12B) IN 'XD' SSD @ 7,926' MD. WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS. 12/3/2024 - Tuesday 12/1/2024 - Sunday No operations to report. 12/2/2024 - Monday 11/29/2024 - Friday WELL SHUT IN ON ARRIVAL. T/IA/OA=1400/1200/150. RIG UP AKE PCE. PT 250L 3000H. RIH WITH 3.71" CIBP. TAGGED @ 9038'. SET PLUG @ 9010'. CCL STOP DEPTH=9002.1 (CCL-ME=7.9'). DUMP BAIL 5 GALS OF CEMENT ON PLUG . EST TOC=9002'. JOB COMPLETE. T/IA/OA=1400/1200/150. WELL SHUT IN ON DEPARTURE. 11/27/2024 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL SHUT-IN ON ARRIVAL. TAG FISH AT 9,028' SLM W/ 10' x 3.70" DUMMY WHIPSTOCK, 3.75" CENT (No issues). WELL SHUT- 11/28/2024 - Thursday No operations to report. 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: 12/05/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241217 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 12A 50133205300100 214070 8/17/2024 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 9/26/2024 YELLOWJACKET PERF-GPT BCU 24 50133206390000 214112 8/19/2024 YELLOWJACKET PERF BCU 25 50133206440000 214132 9/27/2024 YELLOWJACKET PLUG-PERF BLOSSOM 1 50133206480000 215015 9/30/2024 YELLOWJACKET GPT-PLUG-PERF HV B-17 50231200490000 215189 9/23/2024 YELLOWJACKET GPT KU 24-7 50133203520100 205099 10/3/2024 YELLOWJACKET PERF KU 13-06A 50133207160000 223112 12/5/2024 AK E-LINE Plug Setting KU 22-6X 50133205800000 208135 12/8/2024 AK E-LINE Perf KU 23-07A 50133207300000 224126 12/7/2024 AK E-LINE CBL MPU L-17 50029225390000 194169 10/5/2024 YELLOWJACKET PERF MPU R-103 50029237990000 224114 10/14/2024 YELLOWJACKET CBL MPU C-23 50029226430000 196016 11/29/2024 AK E-LINE Plug/cement MPU D-01 50029206640000 181144 11/26/2024 AK E-LINE Perf PBU 13-24B 50029207390200 224087 9/26/2024 YELLOWJACKET CBL PBU 06-07A 50029202990100 224043 9/29/2024 BAKER MRPM PBU 06-18B 50029207670200 223071 10/1/2024 BAKER MRPM PBU 07-32B 50029225250200 204128 10/28/2024 BAKER SPN PBU 14-32B 50029209990200 224073 10/12/2024 BAKER MRPM PBU H-13A 50029205590100 209044 10/23/2024 BAKER SPN PBU L2-20 50029213760000 185134 10/7/2024 BAKER SPN PBU L3-22A 50029216630100 219051 10/9/2024 BAKER PEARL 10 50133207110000 223028 9/25/2024 YELLOWJACKET GPT-PERF PEARL 11 50133207120000 223032 8/29/2024 YELLOWJACKET GPT-PLUG-PERF SRU 241-33 50133206630000 217047 8/23/2024 YELLOWJACKET PERF Please include current contact information if different from above. T39863 T39864 T39865 T39868 T39869 T39870 T39871 T39872 T39873 T39875 T39874 T39867 T39866 T39876 T39877 T39880 T39878 T39879 T39881 T39882 T39883 T39884 T39885 T39886 T39887 MPU C-23 50029226430000 196016 11/29/2024 AK E-LINE Plug/cement Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.18 08:35:44 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Isolate Sag River Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Set plug and Cement 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): 10,850'10,622 SLM 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 & SAG RIVER OIL KUPARUK RIVER OIL 9,362' 10,689' 9,216' 3,484 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 C-23 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/28/2024 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047434 196-016 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22643-00-00 Hilcorp Alaska LLC C.O. 816 Length Size Proposed Pools: 112' 112' 12.6 / 13Cr / VAM TVD Burst 10,142' MILNE POINT MD N/A 5,750psi 7,240psi 4,620' 9,296' 4,941' 10,777' 112' 20" 9-5/8" 7" 4,941' 10,777' 7" x 4-1/2" (2) & 7" x 4-1/2" Premier and N/A 8,098 MD/ 7,049 TVD, 9,015 MD/ 7,781 TVD and 10,090 MD/ 8,679 TVD Erik Nelson Erik.Nelson@hilcorp.com 907-564-5277 Perforation Depth MD (ft): See Schematic See Schematic 4-1/2" 4-1/2" 4-1/2" 12.6 / 13Cr / JBEAR 12.6 / 13Cr / VAM 10,052' 7,938' 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 10:34 am, Oct 22, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.10.22 10:26:35 - 08'00' Taylor Wellman (2143) 324-609 MGR25NOV24 10-404 DSR-10/29/24SFD 10/23/2024 * Temporary isolation of the Sag River perforations for upcoming hydraulic fracturing. * Future co-mingling to remain an option. This is NOT and Sag River P&A. *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.11.26 08:16:29 -09'00'11/26/24 RBDMS JSB 112624 Isolate Sag River Perfs Well: MPU C-23 Date: 22 Oct 2024 Well Name:MPU C-23 API Number:50-029-22643 Current Status:Not Operable Pad:MPU C-Pad Reg. Approval Req’d?10-404 AFE Number:TBD Regulatory Contact:Tom Fouts Job Type:Isolate Perforations First Call Engineer:Erik Nelson Phone:(907) 564-5277 Cost Estimate:$20,000 IOR:200 Second Call Engineer:Todd Sidoti Phone:(907) 777-8443 Current Bottom Hole Pressure: 4181 psi @ 6964’ TVD Live DH gauge data (11.5 PPGE) MPSP:3484 psi (0.1psi/ft gas gradient) Max Deviation:42° 6911-ft MD Min ID:3.813” @ 7926 and 8126-ft MD TOF ±9009-ft MD Background: MPC-23 is a jet pump producer well which is operating under AOGCC approval (Docket Number CO-23- 005 / Conservation Order 809) for comingling of production from both the Kuparuk River and Sag River Oil Pools pursuant to AS 31.05.030 and 20 AAC 25.215(b). Slickline intervention left a portion of their BHA in the well during wellwork operations this past year. Parts of the fish were recovered during subsequent fishing operations but the decision has been made to cease further attempts and proceed to isolate the Sag River perforations in order to allow for production from the Kuparuk River perforations. Well History: x 04 Oct 2024 - MU CT fishing assembly w/ 4" GS & RIH. Tag Bait Sub @ 9013' & latched. PUH 4 straight pulls. Start jar hits, on the 6th jar hit came free. POOH. SL tool parted at 1st knuckle joint. Redress bait sub. MU onto CT fishing assembly w/ 4" GS & RIH. Bait fish @ 9029' CTM & latched. PUH start jar hits. On thirteen jar hit came free. POOH . Recovered bottom of knuckle, stem, QC and top of jar 6.625'. Redress bait sub w/ 1.75" grapple. x 05 Oct 2024 - RIH w/ CT fishing assembly and bait sub dressed with 1.75" grapple.Tag fish 9035 CTMD. Start jarring. 32 jar licks and 10 down came free. POOH. Parted SL Tools @ 2nd knuckle joint. Recovered 3.33' oil jar, quick connects, & 1.2 knuckle joint. Procedure: NOTE:Below steps are a field decision on whether or not to utilize E-Line or Slickline w/ DPU 1. MIRU Slickline/E-Line a. Drift for 10K CIBP (4-½”, 12.6# tbg – Min Restriction is 3.813-in) and tag TOF b. Set CIBP ±50-ft above TOF. Ensure set depth is not across a tbg collar. NOTE: If planned set depth is shallower than 8900-ft MD consult with Ops Engr Isolate Sag River Perfs Well: MPU C-23 Date: 22 Oct 2024 c. Dump bail ±5 gals Class G neat on top of CIBP 2. Tag TOC 3. Run 12B jet pump and set in HES Sliding Sleeve at 7926-ft MD 4. RDMO 5. POP Attachments: 1. As-built Schematic 2. Proposed Schematic _____________________________________________________________________________________ Revised by: TDF 10/17/2023 SCHEMATIC Milne Point Unit Well: MPU C-23 Last Completed: 9/18/2023 PTD: 196-016 TD =10,850 (MD) /TD =9,362’(TVD) 20” Orig. KB Elev.: 45.4’/ GL Elev.:16.8’(Nabors22E) RKB-THF: 21.30’ (Nabors 4ES) 9-5/8” RA Tag in top collar of joint at 10,060’ PBTD =10,689’ (MD) /PBTD = 9,216’(TVD) 7” 1 2 4 3 Min ID = 3.725” Sag RiverLast Tag: 10,622’SLM 1/16/2020 3” DD bailer TOC calculated at 6,398’ MD Kuparuk River 6 7 9 10 8 5 Tubing Cut @ 10,085 WLM 9/13/2023 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1/ H-40 / NA 19.124” Surface 112’ 9-5/8" Surface 40 / L-80 / BTC 8.835” Surface 4,941’ 7" Production 26 / L-80 / BTC 6.276” Surface 10,777’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13Cr / VAM 3.958” Surface 7,938’ 4-1/2” Tubing 12.6 / 13Cr / JBEAR 3.958” 7,938’ 10,052’ 4-1/2” Tubing 12.6 / 13Cr / VAM 3.958” 10,085’ 10,142’ WELL INCLINATION DETAIL KOP @ 300’ MD Max Hole Angle = 42° @ 7,007’ MD TREE & WELLHEAD Tree 4-1/16” 5M Cameron Wellhead 11” 5M FMC Gen. 5 w/4-1/2” tbg hanger, 4- 1/2” TCII top/btm threads, 4” “H” BPV profile OPEN HOLE / CEMENT DETAIL 20” 250 sx (approx.) Arctic Set I in 24” Hole 9-5/8” 963 sx Class “E”, 250 Class “G”, plus 114 sx Class “E” top job in 12-1/4” Hole 7” 600 sx Class “G” in 8-1/2” Hole PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk River 8,245’ 8,275’ 7,165’ 7,189’ 30’ 9/21/2023 Open Sag River 10,190’ 10,247’ 8,768’ 8,819’ 57 3/5/1996 Open Ref Log: 3/5/96 AWS gr/ccl 3-3/8” Western Atlas Jumbo Jet 22 gr/6spf/60deg (0.76” EH/6.4” Pen) JEWELRY DETAIL No Depth Item ID 1 7,926’ HAL Sliding Sleeve 3.813” 2 7,990’ Downhole gauge - Suction 3.865” 3 8,098’ 7” x 4-1/2” Halliburton Packer 3.958” 4 8,126’ 4-1/2” “X” Nipple Min ID = 3.813”3.813” 5 9,015’ 7” x 4-1/2” Packer 3.958” 6 9,045’ 4-1/2” “X” Nipple w/ PX Plug and P-Prong Min ID = 3.813”3.813” 7 10,052’ Baker Non-Sealing Tubing Overshot 4.398” 8 10,090’ 7” x 4-1/2” Premier Packer 3.875” 9 10,129’ 4-1/2” HES “XN”Nipple Min ID = 3.725”3.725” 10 10,140’4-1/2” WLEG –Btm @ 10-142’4.000” GENERAL WELL INFO API: 50-029-22643-00-00 Drilled & Cased by Nabors 22E - 2/17/1996 ESP Completion by Nabors 4ES - 6/2/1996 RWO by Nabors 4ES - 11/9/1996 CTU Jet Pump Completion - 8/13/2000 RWO –Jet Pump Conversion by Nabors 4ES- 10/6/2009 Jet Pump Completion & Perf Add by ASR – 9-18-2023 _____________________________________________________________________________________ Revised by: TDF 10/21/2024 PROPOSED Milne Point Unit Well: MPU C-23 Last Completed: 9/18/2023 PTD: 196-016 TD =10,850 (MD) / TD =9,362’(TVD) 20” Orig. KB Elev.: 45.4’/ GL Elev.:16.8’(Nabors22E) RKB-THF: 21.30’ (Nabors 4ES) 9-5/8” RA Tag in top collar of joint at 10,060’ PBTD =10,689’ (MD) / PBTD = 9,216’(TVD) 7” 1 2 4 3 Min ID = 3.725” Sag RiverLast Tag: 10,622’SLM 1/16/2020 3” DD bailer TOC calculated at 6,398’ MD Kuparuk River 7 8 10 11 9 6 Tubing Cut @ 10,085 WLM 9/13/2023 TOC @ ±8,895’ 5 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1/ H-40 / NA 19.124” Surface 112’ 9-5/8" Surface 40 / L-80 / BTC 8.835” Surface 4,941’ 7" Production 26 / L-80 / BTC 6.276” Surface 10,777’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13Cr / VAM 3.958” Surface 7,938’ 4-1/2” Tubing 12.6 / 13Cr / JBEAR 3.958” 7,938’ 10,052’ 4-1/2” Tubing 12.6 / 13Cr / VAM 3.958” 10,085’ 10,142’ WELL INCLINATION DETAIL KOP @ 300’ MD Max Hole Angle = 42° @ 7,007’ MD TREE & WELLHEAD Tree 4-1/16” 5M Cameron Wellhead 11” 5M FMC Gen. 5 w/4-1/2” tbg hanger, 4- 1/2” TCII top/btm threads, 4” “H” BPV profile OPEN HOLE / CEMENT DETAIL 20” 250 sx (approx.) Arctic Set I in 24” Hole 9-5/8” 963 sx Class “E”, 250 Class “G”, plus 114 sx Class “E” top job in 12-1/4” Hole 7” 600 sx Class “G” in 8-1/2” Hole PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk River 8,245’ 8,275’ 7,165’ 7,189’ 30’ 9/21/2023 Open Sag River 10,190’ 10,247’ 8,768’ 8,819’ 57 3/5/1996 Open Ref Log: 3/5/96 AWS gr/ccl 3-3/8” Western Atlas Jumbo Jet 22 gr/6spf/60deg (0.76” EH/6.4” Pen) JEWELRY DETAIL No Depth Item ID 1 7,926’ HAL Sliding Sleeve 3.813” 2 7,990’ Downhole gauge - Suction 3.865” 3 8,098’ 7” x 4-1/2” Halliburton Packer 3.958” 4 8,126’ 4-1/2” “X” Nipple Min ID = 3.813”3.813” 5 ±8,900’ 10K 4-1/2” CIBP 6 9,015’ 7” x 4-1/2” Packer 3.958” 7 9,045’ 4-1/2” “X” Nipple w/ PX Plug and P-Prong Min ID = 3.813”3.813” 8 10,052’ Baker Non-Sealing Tubing Overshot 4.398” 9 10,090’ 7” x 4-1/2” Premier Packer 3.875” 10 10,129’ 4-1/2” HES “XN”Nipple Min ID = 3.725”3.725” 11 10,140’4-1/2” WLEG –Btm @ 10,142’4.000” GENERAL WELL INFO API: 50-029-22643-00-00 Drilled & Cased by Nabors 22E - 2/17/1996 ESP Completion by Nabors 4ES - 6/2/1996 RWO by Nabors 4ES - 11/9/1996 CTU Jet Pump Completion - 8/13/2000 RWO – Jet Pump Conversion by Nabors 4ES - 10/6/2009 Jet Pump Completion & Perf Add by ASR – 9-18-2023 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/17/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231017 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 212-26 50283201820000 220058 9/2/2023 AK E-LINE Perf KBU 14-6Y 50133205720000 207149 9/18/2023 AK E-LINE GPT/Plug KBU 23-05 50133206300000 214061 9/9/2023 AK E-LINE GPT/Perf MP S-21 50029230650000 202009 10/7/2023 READ CaliperSurvey MPU C-23 50029226430000 196016 9/21/2023 AK E-LINE Perf MPU M-22 50029236450000 219111 9/20/2023 AK E-LINE Mechanical Cutter Paxton 7 50133206430000 214130 9/8/2023 AK E-LINE Tubing Punch/RCT PBU 06-16B 50029204600200 223072 10/7/2023 HALLIBURTON RBT PBU D-18B 50029206940200 215001 9/14/2023 BAKER RPM PBU J-19 50029216290000 186135 9/26/2023 AK E-LINE TTBP/Cement PBU J-23A 50029217120100 204193 10/4/2023 BAKER SPN PBU N-18A 50029209060100 208175 9/4/2023 BAKER SPN PBU P1-02A 50029217790100 202065 9/11/2023 BAKER SPN PBU P1-13 50029223720000 193074 9/15/2023 HALLIBURTON IPROF PBU R-12A 50029209210100 211055 9/7/2023 BAKER SPN Please include current contact information if different from above. T38062 T38063 T38065 T38064 T38066 T38067 T38068 T38069 T38070 T38071 T38072 T38073 T38074 T38075 T38076 10/20/2023 MPU C-23 50029226430000 196016 9/21/2023 AK E-LINE Perf Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.20 08:34:04 -08'00' 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: 10/06/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231006 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KBU 11-17x 50133205850000 209016 9/23/2023 HALLIBURTON RMT3D MPU C-23 50029226430000 196016 9/15/2023 HALLIBURTON RBT MPU F-89A 50029232680100 223026 9/12/2023 HALLIBURTON COILFLAG MPU F-89A 50029232680100 223026 9/12/2023 HALLIBURTON RBT PCU-04 50283201000000 201193 9/14/2023 HALLIBURTON EPX PCU-04 50283201000000 201193 9/14/2023 HALLIBURTON MFC24 Please include current contact information if different from above. T38041 T38042 T38043 T38043 T38044 T38044 10/6/2023 MPU C-23 50029226430000 196016 9/15/2023 HALLIBURTON RBT Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.06 15:41:18 -08'00' 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:McLellan, Bryan J (OGC) To:Todd Sidoti Cc:Rixse, Melvin G (OGC) Subject:RE: MPU C-23 (PTD: 196-016) Date:Friday, September 22, 2023 1:02:00 PM Todd, Hilcorp has approval to produce this well for 30 days with the reverse-circulating jet-pump to see if the reservoir pressure will quickly fall off. After 30 days of production, the well must be shut-in to obtain a static bottom-hole pressure survey after a minimum 48 hr shut-in period. If the reservoir pressure is still above 8.55 ppg, then Hilcorp can isolate the tubing from the IA and confirm with a passing Pressure test to MPSP before putting the well on naturally flowing production. Or bring the well into conformance with CO 808. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Todd Sidoti <Todd.Sidoti@hilcorp.com> Sent: Friday, September 22, 2023 12:05 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: MPU C-23 (PTD: 196-016) Hello, We just perforated the Kuparuk (the Sag is isolated with a retrievable plug) and the BHP is at 10.1ppg equivalent. The sundry (323-168) was submitted back before we had any line of sight on our jet-pump approvals and states: “Approved for reverse circulating jet pump completion with BHP gradient less than 8.55 ppg (aligned to CO392A).” I am requesting permission to flow this well as a reverse-circulating jet pump in alignment with CO 808 and our proposed revisions. Rule 2 Completions (from CO 808): Wells completed with jet pumps may be produced with an open sliding sleeve that compromises the production packer if the well has either: 1. Two barriers to the formation with a tieback string from surface to the depth of the lower tieback seals; or 2. One barrier to the formation and a monitorable OA with open SC shoe that is in communication with the formation below the surface casing shoe; or 3. A forward-circulating jet pump, at least one barrier to the formation, a SC shoe that may be unmonitorable, and an equivalent BHP gradient less than 8.55 ppg. Hilcorp’s proposal (Sent 08SEP2023): Currently existing wells with one barrier and a closed SC shoe will be ‘grandfathered’ and allowed to continue to be operated. Many of the existing jet pump completions have been in operation back ~20 years without confirmation of a closed or open shoe (no record of an MIT-OA performed post completion). See attached file “Rule 2 – One Barrier and Closed Shoe Schematic” of MPU S-34 (PTD 203130) as an example. Request that this be amended to read “ One barrier to the formation and a monitorable OA”. Justification being that any wells of this construction that have a monitorable OA and a “Closed” shoe will have the casing pressure tested at 2 year intervals to ensure integrity and that powerfluid is not exiting and fracturing the shallower zones below the SC shoe. I realize that Hilcorp’s proposal has not been approved yet by the AOGCC and approval may not be possible yet to operate this well as a reverse JP completion. If that is the case and since the BHP is high, may we install the JP and naturally produce the well through the JP? Meaning we would not be pumping power fluid and the check valve that we will install in the jet pump will prevent TBG to IA communication. Additionally, this well has never had an MIT-OA performed but would probably require us to break the shoe down if we were to attempt to achieve an “open shoe”. Thanks for your consideration. Todd Todd Sidoti | Operations Engineer | Hilcorp Alaska | 907-632-4113 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, 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 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. 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: Complete 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 10,850 feet N/A feet true vertical 9,362 feet 10,622 SLM feet Effective Depth measured 10,689 feet feet true vertical 9,216 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2" 12.6 / 13Cr / VAM 7,938' 6,923' 4-1/2" 12.6 / 13Cr / JBEAR 10,052' 8,646' Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / 13Cr / VAM 10,142' 8,726' 7" x 4-1/2" (2) Packers and SSSV (type, measured and true vertical depth)7" x 4-1/2" Premier 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: Casing Conductor 9,216' 4,941'Surface Production 20" 9-5/8" 7" 80' 4,910' 10,777' MILNE PT UNIT C-23 Plugs Junk measured Length Burst Collapse measured TVD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-016 50-029-22643-00-00 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: ADL047434 MILNE POINT / KUPARUK RIVER OIL 354 97 19856 237 Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 246 Gas-Mcf MD 112' 3,433 Size 112' 4,620' 0 Todd Sidoti todd.sidoti@hilcorp.com 907-777-8443 measured true vertical 3,380 5,750psi 7,240psi9,296' N/A N/A 3,090psi 5,410psi 8,098, 9,015 & 10,090 7,049, 7,781 & 8,679 323-168 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 375 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 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 8:37 am, Nov 27, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.11.17 16:03:51 - 09'00' Taylor Wellman (2143) WCB 5-10-2024 RBDMS JSB 112823 DSR-11/30/23 _____________________________________________________________________________________ Revised by: TDF 10/17/2023 SCHEMATIC Milne Point Unit Well: MPU C-23 Last Completed: 9/18/2023 PTD: 196-016 TD =10,850 (MD) /TD =9,362’(TVD) 20” Orig. KB Elev.: 45.4’/ GL Elev.:16.8’(Nabors22E) RKB-THF: 21.30’ (Nabors 4ES) 9-5/8” RA Tag in top collar of joint at 10,060’ PBTD =10,689’ (MD) /PBTD = 9,216’(TVD) 7” 1 2 4 3 Min ID = 3.725” Sag RiverLast Tag: 10,622’SLM 1/16/2020 3” DD bailer TOC calculated at 6,398’ MD Kuparuk River 6 7 9 10 8 5 Tubing Cut @ 10,085 WLM 9/13/2023 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1/ H-40 / NA 19.124” Surface 112’ 9-5/8" Surface 40 / L-80 / BTC 8.835” Surface 4,941’ 7" Production 26 / L-80 / BTC 6.276” Surface 10,777’ TUBING DETAIL 4-1/2” Tubing 12.6 / 13Cr / VAM 3.958” Surface 7,938’ 4-1/2” Tubing 12.6 / 13Cr / JBEAR 3.958” 7,938’ 10,052’ 4-1/2” Tubing 12.6 / 13Cr / VAM 3.958” 10,085’ 10,142’ WELL INCLINATION DETAIL KOP @ 300’ MD Max Hole Angle = 42° @ 7,007’ MD TREE & WELLHEAD Tree 4-1/16” 5M Cameron Wellhead 11” 5M FMC Gen. 5 w/4-1/2” tbg hanger, 4- 1/2” TCII top/btm threads, 4” “H” BPV profile OPEN HOLE / CEMENT DETAIL 20” 250 sx (approx.) Arctic Set I in 24” Hole 9-5/8” 963 sx Class “E”, 250 Class “G”, plus 114 sx Class “E” top job in 12-1/4” Hole 7” 600 sx Class “G” in 8-1/2” Hole PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Kuparuk River 8,245’ 8,275’ 7,165’ 7,189’ 30’ 9/21/2023 Open Sag River 10,190’ 10,247’ 8,768’ 8,819’ 57 3/5/1996 Open Ref Log: 3/5/96 AWS gr/ccl 3-3/8” Western Atlas Jumbo Jet 22 gr/6spf/60deg (0.76” EH/6.4” Pen) JEWELRY DETAIL No Depth Item ID 1 7,926’ HAL Sliding Sleeve 3.813” 2 7,990’ Downhole gauge - Suction 3.865” 3 8,098’ 7” x 4-1/2” Halliburton Packer 3.958” 4 8,126’ 4-1/2” “X” Nipple Min ID = 3.813”3.813” 5 9,015’ 7” x 4-1/2” Packer 3.958” 6 9,045’ 4-1/2” “X” Nipple w/ PX Plug and P-Prong Min ID = 3.813”3.813” 7 10,052’ Baker Non-Sealing Tubing Overshot 4.398” 8 10,090’ 7” x 4-1/2” Premier Packer 3.875” 9 10,129’ 4-1/2” HES “XN”Nipple Min ID = 3.725”3.725” 10 10,140’4-1/2” WLEG –Btm @ 10-142’4.000” GENERAL WELL INFO API: 50-029-22643-00-00 Drilled & Cased by Nabors 22E - 2/17/1996 ESP Completion by Nabors 4ES - 6/2/1996 RWO by Nabors 4ES - 11/9/1996 CTU Jet Pump Completion - 8/13/2000 RWO –Jet Pump Conversion by Nabors 4ES- 10/6/2009 Jet Pump Completion & Perf Add by ASR – 9-18-2023 Well Name Rig API Number Well Permit Number Start Date End Date MP C-23 SL 50-029-22643-00-00 196-016 4/17/2023 9/22/2023 4/14/2022 - Friday No operations to report. 4/12/2022 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 4/13/2022 - Thursday No operations to report. RIG-UP BRAIDED LINE TS HARDLINED: RS - 1.75", 10' x 2-5/8" ROLLER STEM (3.50" whls), 2-1/2" OJ, 2-1/2" LSS. STACK PCE AND TAKE CONTROL OF WIRE. PULL TREE CAP AND STAB ONTO WELLHEAD. PT PCE 350L / 3500H (Good). PULL 3: JETPUMP W/ GAUGES (no data)(ratio: 10X) FROM CMD-SS @ 10,025' MD (See log). RIG-DOWN BRAIDED LINE, RIG-UP SLICKLINE. RAN 4- 1/2" 42BO TO CMD-SS AT 10,025' MD. APPEARS OPEN. WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. No operations to report. 4/15/2022 - Saturday WELL SHUT-IN ON ARRIVAL. RIG-DOWN SLICKLINE AND RIG-UP BRAIDED LINE. GROVE CRANE ON LOCATION. PICKUP LUBRICATOR AND STACK PCE. TAKE CONTROL OF WIRE AND PULL TREE CAP. STAB ONTO WELLHEAD, PT PCE 350L / 3500H (Good). ATTEMPT TO PULL JETPUMP IN CMD-SS AT 9,965' BLM. BLOWN DOWNHOLE TO 10,003' BLM (well went on huge vac, gs sheared). 4/18/2023 - Tuesday 4/16/2023 - Sunday No operations to report. 4/17/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP C-23 SL 50-029-22643-00-00 196-016 4/17/2023 9/22/2023 4/28/2023 - Friday No operations to report. 4/26/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL. 3'' JET PUMP (ser# HC-00029, sec. loc., screen, soft set, BHP's ser#''s 77270 & 77277, 360 day's & 10 min, OAL= 149'') SET IN CMD-SS @ 10044' SLM / 10025' MD. WELL S/I ON DEPARTURE. 4/27/2023 - Thursday No operations to report. No operations to report. No operations to report. 4/29/2023 - Saturday No operations to report. 5/2/2023 - Tuesday 4/30/2023 - Sunday No operations to report. 5/1/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP C-23 Slick & E Line 50-029-22643-00-00 196-016 8/25/2023 9/22/2023 8/25/2023 - Friday WELL FLOWING 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. PULL 3'' JET PUMP @ 10049' SLM / 10025' MD (10X), FLUID @ 6400' SLM, (recover all nubbins, only 3 pieces of packing). RAN 3.77' CENT., 10' 1-7/8'' STEM, 3.80'' CENT., 4-1/2 BLM, TAG @ SCRATCH XN-NIPPLE @ 10148' SLM / 10129' MD. WELL S/I ON DEPARTURE. 8/23/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 8/24/2023 - Thursday No operations to report. No operations to report. 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. SET 4-1/2 CAT, SET IN XN-NIPPLE @ 10155' SLM / 10129' MD (fluid @ 7200' SLM). LRS MIT-COMBO TEST (pass). PULL 4-1/2 CAT @ 10155' SLM / 10129' MD, (fluid @ 2000' SLM). T/I/O = 5/0/90 CMIT TxIA 3000 psi, *Passed* , Pumped 248 bbls Produced Water down IA up TBG, First 15 min Tubing lost 109 psi, IA lost 110 psi, Second 15 min Tubing lost 51 psi, IA lost 53 psi, FWP = 170/160/150. 8/26/2023 - Saturday WELL S/I ON ARRIVAL. PT PCE 300L/3000H. RIH W/CH/ 2 3/8 '' WELLTEC MECHANICAL CUTTER. CUT TUBING @ IN MIDDLE OF 19.82' JOINT, CCL TO CUTTER =18.3' CCL STOP DEPTH=10059.7'MD. . AT SURFACE TATTLE TAIL SHOWED INDICATING WENT OUT TO 4.55''.JOB COMPLETE . 8/29/2023 - Tuesday 8/27/2023 - Sunday No operations to report. 8/28/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP C-23 Wellhead 50-029-22643-00-00 196-016 4/17/2023 9/22/2023 Accept Rig.. R&R. Begin testing 11" BOPE - 250psi | 3500psi - w/ 4-1/2" test joint.;Continue testing 11" BOPE - 250psi | 3500psi - w/ 4-1/2" test joint.;Blow down lines, blow down stack, line up to reverse circulate. No operations to report. 9/9/2023 - Saturday WELLHEAD: BLeed off Tbg Hgr void, tree cap lift device in and hooked to crane. ND tree/adapter, pull and cut tech line. Lay down tree/adapter behind well for reuse. Install CTS plug, new R54 gasket and check lift threads 4 1/2 TC11 8 1/2 turns. NU BOP stack.. 9/12/2023 - Tuesday 9/10/2023 - Sunday Set 4" CTS BPV in tubing hanger, Secure tree. 9/11/2023 - Monday 9/8/2023 - Friday No operations to report. 9/6/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/7/2023 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP C-23 ASR & WH 50-029-22643-00-00 196-016 4/17/2023 9/22/2023 9/15/2023 - Friday POOH W/ 4-1/2" 12. 6" 13cr Vam Top and tech wire F/1,225' T/ surface. Pump double displacement. 240 jts discharge gauge, sliding sleeve, and intake gauge. All clamps and half clamps recovered. Spot in crane. Rig down casing jacks. Rig up flow spool and spacer spools. Spot in and Rig up E-line for CBL run. RIH W/ CBL and log from 9,006' to 7,130'. POOH with E-line. Rig down E-line. R/U slick line, Tool String = 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. 6. 05" GAUGE RING. TAG TUBING STUB @ 10,121' SLM. No tight spot RIH. POOH. R/D slickline. Perform derrick inspection. No issues. R/D rig tongs & tong rack. W/ crane fly off rig floor. Fly third party casing equip. to rig floor. R/U tongs & perform dump test. Rack & tally completion. Rig service, Check equip. fluid levels. RIH w/ 4-1/2" 13CR 80 JFEBear jet pump completion T/ 995'. CSG tong motor seal failed. Moblize crane. Swap & fly spare set to rig floor & R/U. Perform dump test on torque turn. Cont. RIH w/ 4-1/2" 13CR 80 JFE Bear jet pump completion F/ 995' T/1,700'. 9/13/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Pull CTS plug and BPV. TBG and IA on vac. Line up and pump 73 BBLs 8. 4 ppg SW reverse @ 3 BPM 80 psi. no returns. swap to conventional. Pumped 160 BBLs down tubing @ 3 BPM 80 PSI. Started taking returns after 123 BBLs pumped down tubing. Blow down lines. P/U M/U landing joint, TIW and kelly hose. BOLDS. P/U on hanger. Hanger offseat @ 100K. Work pipe up to 145K. Line up and pump down tubing @ 3. 5 BPM 120 psi while working pipe up to 145K. Mobilize E-line unit to perform second cut. SimOps Clean and organize location, and prep to rig up E-line. PJSM w/ crew & E-line. R/U E-line equip. & P/U RCT BHA. To perform tubing cut. RIH E/ RCT correlate to previous cut log. Cut at 10,084. 6' WLM. POOH. R/D RCT BHA & inspect. RCT fired. Anchor damaged, all BHA components accounted for,. Install bails & elevators for 4-1/2", Prep to POOH. Work tubing up to max pull with rig of 144k Performing x8. Land hanger 1x ensuring marks consistent. All P/U weight marks indicate no change. Decision made w/ OE to rig up casing jacks. Release E-line crew. Land tubing hanger. B/O landing JT. & L/D. Begin R/D of spools. for casing jacks. Utilize crane support, Remove spools from rig floor, Fly casing jacks, E type air slips, false bowl & hand slips to rig floor. Install casing jacks on annular bag, connect Hyds. & function test jacks. Prep to jack tubing. P/U & M/U landing joint. Set slips. P/U w/ jacks t/ 180K. Work pipe F/ 120K T/ 180K w/ casing jacks. 9/14/2023 - Thursday Continue to work pipe F/80K T/ 140K with rig and F/ 80K T/ 180K with casing jacks. Mobilize Eline crew for free point and caliper run. Mix up 40BBL pill with 1% BaraLube. Pump down IA. Continue to work pipe F/80K T/ 140K with rig and F/ 80K T/ 180K with casing jacks. Continue working pipe F/ 80K T/ 140K with rig, slight movement was made. Continue to work pipe waiting on E-line. Pipe started pulling free @ 135K up. pulled hanger to floor. Circulate a TBG volume. 160 BBLs @ 3 BPM 120 psi. Lay down Hanger. Tie Tech wire to spool. POOH W/ 4-1/2" 12. 6# Vam Top and tech wire from cut @ 10,084' to 4,914' Pump double displacement. Service Rig. Check equip. fluid levels. POOH W/ 4-1/2" 12. 6" 13cr Vam Top and tech wire from cut @ 4,914' to 2,807' Pump double displacement. Overpull observed while P/U out of slip at 2928' Jt # 178 out. 15K over. Remove tec wire full spool & replace w/ empty. Cont T/ POOH. POOH W/ 4-1/2" 12. 6" 13cr Vam Top and tech wire from cut @ 10,084' to 1,225'. Pump double displacement. Well Name Rig API Number Well Permit Number Start Date End Date MP C-23 ASR & WH 50-029-22643-00-00 196-016 4/17/2023 9/22/2023 Hilcorp Alaska, LLC Weekly Operations Summary WELL SHUT-IN ON ARRIVAL. 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" ROLEER 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). PULL 4-1/2" RHC FROM X-NIPPLE @ 9,040' MD. DRIFT TO 9,200' SLM (target depth) W/ 3. 0" CENT, 5' x 1-7/8" STEM. 3. 0" CENT, 10' x 3. 0" DRIVE DOWN BAILER (no issues). SET 4-1/2" PX PLUG AND P- PRONG IN X-NIPPLE AT 9,040' MD. SHIFT XD-SS FULLY OPEN @ 7,925' MD W/ 4-1/2" 42BO. WELL SHUT-IN ON DEPARTURE, PAD OP NOTIFIED. Cont. RIH w/ 4-1/2" 13CR 80 JFE Bear jet pump completion F/ 1,700' T/ 1,900'. P/U M/U X nipple, Packer, BHPG, and sliding sleeve. Baker tie in tech line and test. Install XO 4. 5" JFE Bear X 4. 5" VAM TOP. Continue RIH W/ 4-1/2 " VAM TOP and jet pump completion F/2,130' T/ 3,921'. Testing tech line every 1,000'. Found tech wire spool had crossed loop, preventing spooling. Baker perform splice on tech line. Continue RIH W/ 4-1/2 " 13CR VAM TOP and jet pump completion F/ 3,921' T/ 6,454'. Pump double displacement. Cont. RIH W/ 4-1/2" 13CR VAM TOP and jet pump completion F/ 6,454' T/ 9,653'. Pump double displacement. Service rig, Check equipment fluid levels. Cont. RIH W/ 4-1/2" 13CR VAM TOP and jet pump completion F/ 9,653' T/ 10,051'. P/U Jt # 241 attempt to locate on cut TBG. S/O dw to 10,093' No tag. Decision made to stay off possible 4-1/2" 6. 6' TBG fish & land w/ bottom of overshot at 10,051'. Pump double displacement. 78K S/O wt, 135K P/U wt. P/U hanger. Terminate TEC line through hanger, test gauge. (good test). M/U landing Jt. Land out W/ 78K set in hanger bowl. Last P/U Wt = 135K. RILDS. Remove landing JT. R/U to pump down IA. Open tubing to gas buster. Pump 160 bbls of CI brine dw IA. R/D pump lines & B/D. 9/16/2023 - Saturday Land 11" TC-II FMC tubing hanger (P156963), rig set packer, set 4" BPV, ASR crew moved rig, Nipple up tree and adapter, terminate tech line, tested to 500 / 5000 psi for 10 mins each, attempted to remove BPV with dry rod, Pressure on tubing, BPV still in well. Wellhead: Removed 4" BPV post-RWO with S-10 lubricator. No Issues. WELL SHUT-IN ON ARRIVAL. SHIFT XD-SS PARTIALLY OPEN AT 7,925' MD W/ 4-1/2" 42BO. PULL BALL & ROD FROM RHC AT 9,044' MD. 9/19/2023 - Tuesday 9/17/2023 - Sunday P/U M/U landing joint. Drop 1. 875" ball and rod. Line up to pump down tubing and set packers. Pressure up to 600 psi and found leak in hard line. bleed off. tighten hammer union. test hard line to 3600 psi. Pressure up up on tubing to 3200psi hold for 30 min. Good test. Bleed tubing to 1500psi. Fill IA with 50 BBLs of 8. 5 ppg SW. Pressure up on IA for MIT IA to 3600psi while holing pressure on tubing. Found Kelly hose leaking. bleed of pressure. Blow line down and replace. Pressure up on IA for MIT-IA to 3700 psi. Good Test. Blow down stack and fluid lines. SET BPV. Rig released at 12:00 pm 9-17-23. 9/18/2023 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP C-23 ASR & WH 50-029-22643-00-00 196-016 4/17/2023 9/22/2023 No operations to report. No operations to report. 9/23/2023 - Saturday No operations to report. 9/26/2023 - Tuesday 9/24/2023 - Sunday No operations to report. 9/25/2023 - Monday 9/22/2023 - Friday WELL SHUT IN UPON ARRIAL. PT 300 LOW/ 3000 HIGH. CONFIRM XD SSD IS OPEN @ 7972' SLM. SET JET PUMP @ 7970' SLM (RATIO - 12B/ SIDOTI SEAL INSTALLED, OAL = 87"). WELL SHUT IN UPON DEPARTURE. NOTIFY DSO. 9/20/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/21/2023 - Thursday WELL S/I ON ARRIVAL. PT PCE 250LP-3500HP. PERFORATE FROM 8245' - 8275' MD WITH 2.875" X 30' RAZOR XDP CHARGES, 6 SPF, 60 DEG PHASED. CCL STOP DEPTH=8237.1', CCL TO TS=7.9', TOOLS JUMPED AFTER SHOOTING INDICATING UNDERBALANCED. NO PRESSURE CHANGE ON TUBING, FLUID LEVEL WAS AT 4320' MD WHILE RUNNING IN HOLE. DID NOT SEE WHILE PULLING OUT TO HOLE.. LOG CORRELATED TO MPC-23_OH_GR_TIE_IN_1_240. END TICKET. PERFORATE FROM 8245' - 8275' MD Well Name Rig API Number Well Permit Number Start Date End Date MP C-23 ASR & WH 50-029-22643-00-00 196-016 4/17/2023 11/15/2023 11/17/2023 - Friday No operations to report. 11/15/2023 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Decision was made not to comingle C-23 and maintain current production. 11/16/2023 - Thursday No operations to report. No operations to report. No operations to report. 11/18/2023 - Saturday No operations to report. 11/21/2023 - Tuesday 11/19/2023 - Sunday No operations to report. 11/20/2023 - Monday JLC 3/30/2023 RBDMS JSB 033123 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS SEP i 2 'r7 1. Operations Abandon Plug Perforations Fracture Stimulate[ -j Pull Tubing Ll Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate❑✓ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well❑ Re-enter Susp Well ❑ Other: CT Fill Clean-out w/ N2 ❑� 2. Operator Name: Hilcorp Alaska LLC 4. Well Class Before Work: Development 0 Stratigraphic❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 196-016 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-029-22643-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL047434 MILNE PT UNIT C-23 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT / SAG RIVER OIL 11. Present Well Condition Summary: Total Depth measured 10,850 feet Plugs measured N/A feet true vertical 9,362 feet Junk measured 10,378 CTMD feet Effective Depth measured 10,689 feet Packer measured 10,090 feet true vertical 9,216 feet true vertical 8,679 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' NIA NIA Surface 4,941' 9-5/8" 4,941' 4,620' 5,750psi 3,090psi Production 10,777' 7" 10,177' 9,296' 7,240psi 5,410psi 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 / 13Cr85 / Vam Top 10,142 MD 8,726 TVD Packers and SSSV (type, measured and true vertical depth) 7"x4-1/2" Packer N/A See above N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): 10,190'to 10,247' MD Treatment descriptions including volumes used and final pressure: DuraKleen Asphaltene Inhibitor - 40bbls @ 1,317psi. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 0 0 1 1,300 0 Subsequent to operation: 1142 144 142 3,451 194 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory[] Development 121 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-291 Np Authorized Name: Chad Helgeson Contact Name: Stan Pothole Authorized Title: Operations Manager Contact Email: Sporhola@hllcorp.cOm Authorized Signature: �l�L Date: 9/10/2019 Contact Phone: 777-8412 -ABDMS I- SEP 16 2019 Form 10-404 Revised 412017 Submit Original Only ' K Milne Point Unit SCHEMATIC Well: MPU C-23 Last Completed: 10/6/2009 Ililcara Alaeka, J,I.D PTD: 196-016 Ong, KB Elev.: 45.4' / GL Elev.: 16.8' (Nabors 22E) TREE & WELLHEAD TD =10,850 (MD) / TD = 9,362'(TVD) PBTD=10,689' (MD) / PBTD= 9,216'(TVD) Tree 4-1/16" 5M Cameron Wellhead 11" 5M FMC Gen. 5 w/4-1/2" tog hanger,. 4- Top 1/2" TCII top/btm threads, 4" "H" BPV profile OPEN HOLE/ CEMENT DETAIL CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm 20" Conductor 91.1/ H-40 / NA 19.124" Surface 112' 9-5/8" Surface 40 / L-80 / BTC 8.835" Surface 4,941' 7" Production 26 / L-80 / BTC 6.276" Surface 10777' TUBING DETAIL 4-1/2 1 Tubing 1 12.6 / 13Cr/ Vam Top 1 3.958" 1 Surface 10,142' WELL INCLINATION DETAIL KOP @ 300' MD Max Hole Angle = 42° @ 7,007' MD JEWELRY DETAIL No Depth Item ID 1 10,008' 4-1/2" SGM-NDPG-CA Sapphire Discharge Gauge 3.958" 2 10,025' 4-1/2" Baker CMD Sliding Sleeve w/"X" Profile Min ID = 3.812" Sleeve Open; 10X Jet Pump Set 6/27/19; 8,621' TVD; 27' 3.812" 3 10,049' 4-1/2" SGM-NDPG-CA Sapphire Intake Gauge 3.958" 4 10,090' 7" x 4-1/2" Premier Packer 3.875" 510,129' 4-1/2" HES "XN"Nipple Min ID = 3.725" 3.725" 6 10,140' 4-1/2" WLEG 4.000" PERFORATION DETAIL Sand Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Sag River 10,190' 10,247' 8,768' 8,819' 57 3/5/1996 Open Ref Log: 3/5/96 AWS gr/ccl 3-3/8" Western Atlas Jumbo Jet 22 gr/6spf/60deg (0.76" EH/6.4" Pen) GENERAL WELL INFO API: 50-029-22643-00-00 Drilled & Cased by Nabors 22E - 2/17/1996 ESP Completion by Nabors 4ES- 6/2/1996 RWO by Nabors 4ES - 11/9/1996 CTU Jet Pump Completion - 8/13/2000 RWO—Jet Pump Conversion by Nabors 4ES - 10/6/2009 Revised by: TDF 9/10/2019 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-23 ASR 50-029-22643-00-00 196-016 6/22/2019 6/27/2019 Daily Operations. 6/19/2019- Wednesday No operations to report. 6/20/2019 - Thursday No operations to report. 6/21/2019 - Friday No operations to report. 6/22/2019 -Saturday MIRU SLB CTU #6 with 16,050' of 2" CT. CV = 44.3 bbls. PU injector and 20' of lubricator. Run coil down and MU BHA #1- 3.05" OD CTC, 3.13" OD DBPV, Spacer bar, Disconnect (7/8" ball), Rupture sub, Tempress Screen Sub, Tempress Hydropull, Tempress nozzle. DAL = 15.71' Pull Test connector to 28k. Wait for water to arrive for PT of coil tools. Function test BOPE. 3% KCL water on site. Fluid pack coil and PT BHA to 3,500psi. Stab on well. PT to 300/4200psi. Perform DBPV check -good. Open Well to 135psi SITP. RIH to 2,500' with BHA #1 circulating hot 3% KCL water down coil / returns up the IA to tanks. Circulate from 2,500' for 2+ hrs / checking IA - still plugged. RIH to SS depth of 10,025' circulating hot SW heated to 160 degrees by LRS. Pump and lay in 20 bbls of Xylene from 10040' ctmd. Displace out of coil with hot 3% KCL. Attempt to squeeze xylene into the IA via the sliding sleeve taking tubing pressure up to 2,OOOpsi. No go. Resume POOH. Pressure IA with power fluid to 2,500psi. IA beginning to slowly bleed down. Continue to bump pressure up to 2,500psi. OOH with coil. Secure well. Stand injector back. Leave 2,400psi on IA. SDFN. 6/23/2019 -Sunday Arrive on site. PJSM. Check equip. IA pressure has bleed off from 2,500psi to Opsi over night. Attempt to pump power fluid down the IA with no luck. Appear to have slight communication to the tubing. Attempt to pump down the tubing and up the IA with no luck. Stab on well with injector and BHA #2- 3.05" OD CTC, 3.13" OD DBPV, Spacer bar, Disconnect (7/8" ball), XO, ported XO to 3/4" SR, 4.5" 8042 SS shifting tool. Wells support change out 2" chicksan and grease all valves on return line from well to the tanks. PT low - leaking 2" block valve. Changeout. Re -PT to 425psi / 4,200psi - good. RIH with SS shifting tool to 2,640' ctmd. Able to divert power fluid down coil. Circulate hot 132 degree power fluid down coil up the tubing to tanks in attempt to free the IA. Circulate 132 degree power fluid down coil taking returns from the tubing to tanks with end of coil at 2,640' and 4,896' ctmd for 500 bbls. RIH to 10,160' ctmd. Pump 5 bbls Xylene, 2 bbls diesel flush and displace to end of coil with 3% KCL. With 1 bbls Xylene out, shut in tubing at surface and take returns from the IA trying to squeeze Xylene into IA. Took tubing pressure up to 2,500psi. Shut in IA at surface and IA pressured up to 200psi only. Start taking returns from tubing and lay in remaining 4 bbls Xylene while PUH. Closed the SS at 10,042' ctmd. Make 2nd pass up across SS and see no weight change that was seen on the 1st pass. Continue to POOH and resume circulating power fluid down coil with returns from the tubing. Stop at 2,600'. Circulate from 2,600' for another hour (100+ bbls of 135 degree power fluid). POOH. Secure well. Change BO42 to shift down. Stand injector back. SDFN. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-23 ASR 50-029-22643-00-00 196-016 6/22/2019 6/27/2019 Daily Operations. 6/24/2019 - Monday Arrive on site. PJSM. Check equipment. Stab on well with injector and BHA #2 - BO42 shifting tool to open SS. PT to 300/ 3,500psi. Open well to 50/293/10psi T/I/0. RIH with 4.5" 8042 . Circulate hot power fluid down coil with returns from tubing while RIH. Set down and open SS at 10,042' ctmd (10,025' MD). Make 2nd pass to confirm. POOH. Attempt Inject 60/40 down IA with field triplex. Able to pump 15 bbls 60/40 into IA. OOH with coil. Close swab. Pop off and bring injector to back deck of CTU. LRS crew on site. PJSM. Line up LRS and pump 20 bbls 60/40 / 20 bbis Xylene/ 2 bbis diesel down the IA. No problem - IA is clear. Able to get up to 3 bpm. Displace fluids down to the SS with power fluid. Stop PF with leading edge of Xylene at the SS. Let soak for 30 min. Send 10 more bbis PF down to push 10 bbls Xylene through the SS. Let soak. Simops: Coil crew - L/D BHA - L/D lubricator - Cut 100' of coil off string - Change packoffs - PU lubricator - Rehead with new CTC and MU BHA #2 - 3.05" OD CTC, 3.13" OD DBPV, Spacer bar, Disconnect (7/8" ball), Rupture sub, XO, XO to 3/4" SR, 4.5" 8042 shifting tool set to shift SS up to close. PT tools to 4,OOOpsi. Back on well with injector. PT to 300psi / 3,046psi. Open well to 108/3/11psi T/I/0. RIH with 4.5" BO42 to close SS. LRS pump 46 bbis 60/40 down the IA for freeze protect. Make 3 up passes from 10,060'- 10,035' ctmd. See overpulls at 10,040' ctmd on 1st 2 passes, no overpull on 3rd pass. PT IA against closed SS to 1,750psi for 10 min. Lost 25psi. SS is closed. Bleed off IA to Opsi. POOH from 10,030'. Tag up at surface. Close swab valve. Remove fusible cap. BD and PO well. Bring injector back, run coil down, L/D BO42 and XO's, MU Tempress Screen, hydropull, and Nozzle. BHA #1 back on coil. Set injector down, secure well and SDFN. 6/25/2019-Tuesday Arrive on site. PJSM. PU injector and stab on well. PT to 300/2,807psi via backside. Open Well to 17/0/9psi T/I/0. RIH with BHA #1- 3.05" OD CTC, 3.13" OD DBPV, Spacer bar, Disconnect (7/8" ball), Rupture sub, Tempress Screen Sub, Tempress Hydropull, Tempress nozzle. DAL = 15.71'. Cleanout well from TT (10,140' md) to 10,378' ctmd pumping Xylene at 2.7 bpm / 3,900psi CTP/ 160psi WHP. Recovering 100% returns. Chase xylene with 3% KCL to TT and pump bottoms up. RIH to top of perfs. 143 bbls Xylene used. 165 bbis 3% KCL. MIRU HAL cementers. PT hardline to 4,600psi. Pump 16 bbis 3% KCL for injection test but unable to build WHIP. Swap to DuraKleen and circulate 40 bbls down coil followed by 5 bbis 3% KCL. Close choke and squeeze away DuraKleen, pumping Xylene behind at average rate and pressure of 2 bpm / 850psi WHP. Max pressure was 1,317psi WHP, then broke over and stabilized. SD pumping with X ylene at the nozzle. Let soak for 4 hours. Circulate Xylene out of coil with 3% KCL with nozzle at bottom of perfs. With xylene out of the coil POOH to 9,000'. Pump 2x BU volume of 3% KCL. POOH freeze protecting well to 2,500' with 60/40m. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number StartDate End Date MP C-23 Slick Line 50-029-22643-00-00 196-016 6/22/2019 6/27/2019 Daily Operations. 6/26/2019 - Wednesday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H. RUN 42 -BO (keys down) AND DUAL RAIL MAGNETS AND SHIFT CMD -SS AT 10,031' SLM OPEN (magnets return 100% full of SWORF). RUN DUAL RAIL MAGNETS TO 10,100' SLM (bottom magnet 95% full, top magnet 60% full). PAD -OP BRING WELL ON LINE AT 1,500bwpd FOR 20min (no pressure gain, sleeve open). L/D FOR THE NIGHT, NOTIFY 6/27/2019 - Thursday WELL S/I ON ARRIVAL, NOTIFY PAD -OP, PT PCE 250L/2,500H. RUN DUAL RAIL MAGNETS TO 10,100' SLM (bottom magnet 20% full, top magnet 20% full). SET 3" JET PUMP (serial# BP -1036, ratio: 10X, OAL=70", secondary lock) IN CMD -SS AT 10,030' SLM/10,025' MD. WELL ONLINE AND PRESSURED UP, TAG WELL. RDMO, NOTIFY PAD -OP. 6/28/2019 - Friday No operations to report. 6/29/2019 -Saturday No operations to report. 6/30/2019 -Sunday No operations to report. 7/1/2019 - Monday No operations to report. 7/2/2019 -Tuesday No operations to report. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Sag River Oil Pool, MPU C-23 Permit to Drill Number: 196-016 Sundry Number: 319-291 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.claska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, jVV4-L / V _ Jessie L. Chmielowski Commissioner DATED this I q day of June, 2019. ABDMS L` JUN 18 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 ear 25 onn JUN 11 2619 AOGc%-X 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate D • Other Stimulate Q Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT Fill Clean-out w/ N2 ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development 121. Stratigraphic ❑ Service ❑ 196-016 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-029-22643-00.00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 423 Will planned perforations require a spacing exception? Yes ❑ No Q MILNE PT UNIT C-23 " 9. Property Designation (Lease Number): 10. Field/Pool(s): —'—� ADL047434 MILNE POINT /AG RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (R): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 10,850 9,362 10,689 9,216 1,873 NIA N/A Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 112' 112' N/A N/A Surface 4,941' 9-5/8" 4,941' 4,620' 5,750psi 3,090psi Production 10,777 7" 10,177' 9,296' 7,240psi 5,410psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (R): See Schematic See Schematic 4-1/2" 12.6 / 13Cr85 / Vam Top 10,142 Packers and SSSV Type: Packers and SSSV MD (R) and TVD (ft): 7"x4-1/2" Packer and N/A 10,090 MD / 8,679 TVD and N/A 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/18/2019 OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Stan Porhola 57P Authorized Title: Operations Manager Contact Email: S Orh018 hIIC0r .COM Contact Phone: 777-8412 Authorized Signature: Date: 611 012 01 9 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. I G Z 611 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No❑r�(/ 9BDMS� JUN 18 2019 Spacing Exception Required? Yes El No L:J Subsequent Form Required: 16 e L/ M APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: W 61rry ORIG I NAL Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and Attachments Duplicate 7W &-rZIry K Hilwra Alaska. M Well Prognosis Well: MPC -23 Date; 6/11/19 Well Name: MPU C-23 API Number: 50-029-22643-00-00 Current Status: Oil Well [Jet Pump] Pad: Milne Point C -Pad Estimated Start Date: June 18`^, 2019 Rig: Coil Tubing Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 196-016 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) AFE Numbers 1953295 Job Type: Asphaltene/N2 CO Current Bottom Hole Pressure: 2,750 psi @ 8,768' TVD (Last BHP measured 4/08/2018) Maximum Expected BHP: 2,750 psi @ 8,768' TVD (No new perfs being added) MPSP: 1,873 psi (Based on 0.10 psi/ft gas gradient) Brief Well Summary MPU C-23 was drilled in 1996 using Nabors 22E and completed with Nabors 4ES with an ESP. The completion was pulled and changed out in 2009 using Nabors 4ES to replace the 4.5" L-80 tubing with 4.5" 13 Chrome and ran a Jet Pump completion. The well has a history of asphaltenes in the tubing. Notes Regarding Wellbore Condition • Deviation at pump is 27°. Jet pump pulled 5/05/2019. • Casing last tested to 3,500 psi for 30 min down to 10,090' on 12/10/2015. • 4-1/2" Tubing is 13 Chrome. Possible metal shavings (swarf) in well. • ***Unable to circulate through the sliding sleeve*** • ***Perfs plugged off and partially covered; Asphaltenes in the tubing/casing*** • ***Note hazards in PJSMs when using Xylene and DuraKleen (Asphaltene Solvent)*** Objective: The purpose of this work/sundry is to treat asphaltene deposits that have plugged off the sliding sleeve and parts of the perforations. A contingency re-perf job is also planned in case there continues to be limited inflow performance from the perforations. Coiled Tubing Procedure: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/ Xylene (for treatment) and 60/40 McOH (for freeze protect) and Produced Water (for displacement). 2. Pressure test BOPE to 250 Low/ 3,500psi Hi, 5 min Hi. 5 min Low each test a. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. b. Each subsequent test of the lubricator will be to 250 Low/ 3.500psi Hi to confirm no leaks. c. No AOGCC notification required. d. Record BOPE test results on 10-424 form. 3. MU Baker Tempress Hydropull SC Nozzle tool (3.13" OD) and coil BHA on 2.0" coil. 4. RIH to sliding sleeve at 10,025' MD and spot +/- 5 bbl Xylene pill using nozzle. n errmm Alaska. Lb Well Prognosis Well: MPC -23 Date: 6/11/19 a. Coil capacity is +/-45 bbl for 2.0" of 16,000' of coil. CAP= 0.00276 bbl/ft 5. Soak pill for a minimum of 15 mins. 6. Repeat spotting 5.0 bbl Xylene pills as needed if circulation has not been established through the slidirrg' sleeve. 7. After circulation has been confirmed through the sliding sleeve, pump 10 bbl DuraKleen (Asphaltene Solvent) and displace w/ 8.5 ppg produced water w/ 3% KCI down the coil through the sliding sleeve up the 7" x 4.5" annulus. Wireline Procedure (Contingency if formation damage persists) 29. RU E -line. Test lubricator to 250/2,000 psi. 30. MU 20' of 3-3/8" perfguns. 31. RIH and perforate the Sag River from +/-10,227'-10,247' MD. POOH. a. Reference Log is AWS GR/CCL dated 3/05/1996. 32. MU 20' of 3-3/8" perf guns. a. Annular volume from sleeve to surface is 186 bbl. CAP= 0.0186 bbl/ft 8. Freeze protect 7" x 4.5" annulus (+/- 45 bbl). 9. Contingency: (if unable to establish circulation through sliding sleeve) repeat steps 3-6 changing up BHA type and/or fluid volume. 10. POOH w/ coil. LD Tempress Hydropull (prep for another run). 11. MIRU Slickline and PCE. 12. RIH and shift sliding sleeve @ 10,025' MD closed. POOH. 13. RD Slickline. 14. Contingency: (if unable to shift the sleeve using slickline) a. PU 4.5" BO shifting tool on 2.0" coil. b. RIH and shift Baker CMD closed (shift up to close) at 10,025' MD. Confirm sleeve is closed. c. POOH w/ coil. LD shifting tool. 15. MU Baker Tempress Hydropull SC Nozzle tool (3.13" OD) and coil BHA on 2.0" coil. 16. RIH to tubing tail at 10,140' MD and wash down using Xylene to cleanout fill across perfs. 17. Cleanout fill to below bottom perfs at 10,247' MD. Cleanout to 10,300' MD washing down w/ Xylene. 18. PU to above perfs at 10,185' MD. 19. Spot +/- 25 bbl DuraKleen (Asphaltene Solvent) pill and squeeze into the perforations. Displace the coil w/ Xylene (+/-45 bbl). �- 20. Soak pill for a minimum of 4 hours. Wait on bottom. a. If running up at the end of a shift, then POOH and allow pill to soak overnight. 21. RIH to below bottom perfs at 10,250' MD. 22. Circulate down coil. Begin POOH when +/- 45 bbl of Xylene has exited the coil. Displace Xylene w/ 8.5 ppg produced water w/ 3% KCI. 23. Stop coil at 9,000' MD and CBU x 2 w/ 8.5 ppg produced water w/ 3% KCI. 24. POOH w/ coil. 25. PU to 2,500' and freeze protect tubing. POOH w/ coil. 26. Contingency: (if unable to establish circulation to surface; losses are too great) a. RIH w/ 2.00" coil w/ 2.5" to 3.5" max OD mill and motor cleanout BHA and cleanout to +/-10,300' i/ MD. POOH. Nb. Circulate out fill using 8.5 ppg produced water w/ 3% KCI w/liquid foamer and mix with Nitrogen (see Nitrogen procedure and diagram). Utilize defoamer for returns in Kill Tank. / 27. RD Coiled Tubing and ancillary equipment. 28. Turn well over to production. Wireline Procedure (Contingency if formation damage persists) 29. RU E -line. Test lubricator to 250/2,000 psi. 30. MU 20' of 3-3/8" perfguns. 31. RIH and perforate the Sag River from +/-10,227'-10,247' MD. POOH. a. Reference Log is AWS GR/CCL dated 3/05/1996. 32. MU 20' of 3-3/8" perf guns. H llik,,m Alaska. LL 33. RIH and perforate the Sag River from +/- 10,207'-10,227' MD. POOH. 34. MU 17' of 3-3/8" perf guns. 35. RIH and perforate the Sag River from +/- 10,190'-10,207' MD. POOH. 36. RD E -line. Turn well over to production. Attachments: 1. As -built Schematic 2. Coil BOPE Schematic 3. Nitrogen Operations Procedure 4. Nitrogen & Foam Flow Diagram Well Prognosis Well: MP C-23 Date: 6/11/19 Milne Point Unit SCHEMATIC Well: MPU C-23 Last Completed: 10/6/2009 eorP.• AMA., LU PTD: 196-016 Ong. KB Elev.: 45.4' / GL Elev.:16.8' (Nabors 22E) TD =10,850 (MD) /TD= 9,362'(TVD) PBTD =10,689' (MD) / PBTD= 9,216(TVD) TREE & WELLHEAD Tree 4-1/16" 5M Cameron Wt/ Grade/ Conn 11" 5M FMC Gen. 5 w/4-1/2" Wellhead tbg hanger, 4-1/2"TCII 9-5/8" top/btm threads, 4" "H" BPV 91.1/H-40/NA profile OPEN HOLE/ CEMENT DETAIL CASING DETAIL Size 250 sx (approx.) Arctic Set I in 24" Wt/ Grade/ Conn Hole E20" 963 sx Class "E", 250 Class "G", plus 9-5/8" 114 sx Class "E" top job in 12-1/4" 91.1/H-40/NA Hole 7" 600 sx Class "G" in 8-1/2" Hole CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1/H-40/NA 19.124" Surface 112' 9-5/8" Surface 40 / L-80 / BTC 8.835" Surface 4,941' 7" Production 26/L-80/BTC 6.276" Surface 10,777' TUBING DETAIL 4-1/2" I Tubing12.6/13Cr/Vam Top 3.958" Surface 10,142' WELL INCLINATION DETAIL KOP @ 300' MD Max Hole Angle = 42' @ 7,007' MD JEWELRY DETAIL Depth Item ID 10,008' 4-1/2" SGM-NDPG-CA Sapphire Discharge Gauge 3.958" 10,025' 4-1/2" Baker CMD Sliding Sleeve w/"X" Profile Min ID = 3.812" Sleeve Open; No Jet Pump, 8,621' TVD; 27° 3.812" 10,049' 4-1/2" SGM-NDPG-CA Sapphire Intake Gauge 3.958" 10,090' 7" x 4-1/2" Premier Packer 3.875" 10,129' 4-1/2" HES "XN"Nipple Min ID=3.725" 3.725 10,140' 4-1/2" WLEG 4.000" PERFORATION DETAIL and Top (MD) Btm (MD) Top (TVD) 8tm (TVD) FT Date Status ag 10,190' 10,247' 1 8,768' 8,819' 57 3/5/1996 1 Open Log: 3/5/96 AWS gr/ccl 3-3/8" Western Atlas Jumbo Jet 22 gr/6spf/60deg (0.76" EH/6.4" Pen) GENERAL WELL INFO API: 50-029-22643-00-00 Drilled & Cased by Nabors 22E - 2/17/1996 ESP Completion by Nabors 4ES- 6/2/1996 RWO by Nabors 4ES - 11/9/1996 CTU Jet Pump Completion - 8/13/2000 RWO—Jet Pump Conversion by Nabors 4ES- 10/6/2009 Revised by: STP 6/10/2019 Lubricator to injection head 2.00" Single Stripper 1/16 - • - SE! Pipe 3_ - F__� Pipe Crossover spool 4 1/1610M X 4 1/16 SM Pump -In Sub 4 1/16 5M Manual Gate Manual Gate Valve, Swab, WKM-M, 21/85M 21/85M 4 1/16 5M FE �/� Ja�eR'1Iy6 Valve, Upper Master, Baker, // 4 1/16 5M FE, w/ Hydraulic II\\0 Valve, Lower Master, WKM-M, 4 1/16 SM FE Tubing Adapter, 41/16 5M 1502 Union COIL BOMILNE POINT UNIT MPU C-23 Hikorp Alaelc., LLC 6/10/2019 MPU C-23 20 X9%X 7X 4% Coil Tubing BOP Lubricator to injection head 2.00" Single Stripper 1/16 - • - SE! Pipe 3_ - F__� Pipe Crossover spool 4 1/1610M X 4 1/16 SM Pump -In Sub 4 1/16 5M Manual Gate Manual Gate Valve, Swab, WKM-M, 21/85M 21/85M 4 1/16 5M FE �/� Ja�eR'1Iy6 Valve, Upper Master, Baker, // 4 1/16 5M FE, w/ Hydraulic II\\0 Valve, Lower Master, WKM-M, 4 1/16 SM FE Tubing Adapter, 41/16 5M 1502 Union STANDARD WELL PROCEDURE IileorpAlaska, IAX NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 ff III", AM.V. I.u: 400 BBL UPRIGHT I SEAWATER W/ DEFOAMER 500 8BL KILL TANK Open Open Op— Open Open Open I� Open Y^i' To Flowllne No Open l'0i an.ea o��j"' TRIPLEX 'f ---y 50 88L FREEZE PROTECTTANK Updated 922/16 Coil Tubing Unit Fluid Flow Diagram Clcanout w/ Nitrogen & Foam SW or KCL W/ 400 BBL UPRIGHT FOAMER OR FRICTION 400 BBL UPRIGHT SWor KCL W/ FOAMER OR FRICTION COILUNIT WITH I.S"So 2.d'COIL Rrnl 1rrR Choke Manifold COIL PUMP PUMP & TANK LEGEND: Fluids Pumped . Fluids Remmed Q Valve op. Valve Closed Gate Valve DG Ball Valve D00 Butterfly Valve X Lo Tcrq Valve D00 Check Valve Manual Choke Fy Pressure Gauge Qr • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 l F c---- Mr. Tom Maunder ` Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 4'00 Subject: Corrosion Inhibitor Treatments of MPC -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -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) MPC -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA MPC -05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA MPC-08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011 MPC -09 1850360 50029212990000 Tanko conductor NA NA NA NA NA MPC-10 1850150 50029212780000 Tanko conductor NA NA NA NA NA MPC -11 1850590 50029213210000 Tanko conductor NA NA NA NA NA MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA MPC-13 1850670 50029213280000 Tanko conductor NA NA NA NA NA MPC-14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011 MPC-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA MPC -21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011 MPC -22A 1951980 50029224890100 38 NA Need top job "" MPC-23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011 MPC-24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011 MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011 MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011 MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011 MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011 MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011 MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011 MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011 MPC -42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011 MPC -43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPO T OF SUNDRY WELL OPERA IONS . ~~l„~~~~~~ ~1(~~ ~ "~ 2~1Q~ 1. Operations Performed: ~ ;~~B~It~ ~1~ ~t ~8~ 1,OCl~. ~Ot11ff11SSl ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter uspend W~ I ~ , ^ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ~ Other n~"~~~~~ ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: Permit To Drill Number. BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 196-016 3. Address: ^ Service ^ Stratigraphic . API Number. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22643-00-00 : Property Designation: WeH Name and Number. ADL047434 MPC-23 ~Field / Pool(s): Milne Point Unit / Sag River Oi! Pool 10. Present well condition summary Total depth: measured 10850' feet true vertical 9362~ feet Plugs (measured) None Effective depth: measured ~ pggg' feet Junk (measured) None true vertical 92~g~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 4910' 9-5/8" 4941' 4620' S750 3090 Intermediate Production 10748' 7" 10777' 9296' 7240 5410 Liner ~~~6~~` ~ ~' ~r ~ ~ ~~~~ Perforation Depth: Measured Depth: 10190' - 1024T True Vertical Depth: 8768' - 8819' Tubing {size, grade, measured and true vertical depth): 4-1/2", 12.6# 13Cr 10142' 8726' Packers and SSSV (type, measured and true vertical depth): 7" x 4-1/2" Baker Premier Packer 10090' 8679' 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: 111 17 369 Not Available Not Available Subsequent to operation: 1,027 781 25 3,363 224 13. Attachments: ^ Copies of Logs and Surveys run • We41 Class after work: ^ Explvratory ~ Developmerrt ^ Service ~ Daily Report of Well Operations ~ Well Schematic Diagram • Well Status after work: ~ pil ~ Gas ^ WDSPL ^~STOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledg~. Sundry Number or WR rf C.O. Ex~npt: Contact Mehrdad Nadem, 5645941 308-416 Printed Name Terrie Hubble Title Drillin Technolo ist ~ B Signature Phone 564-4628 Date ~'~/ Te Hu bb~ 564-4628 :1 Form 10-404 Revised 07/2009 ~. ~ (~ ~ n ~ ~ ~ ~ ~ ,~~~ ~~Original Ony ~ /~, ~ ~ ~.~' J, ~ ~ MPC-23, Well History (Pre Rig Workover) Date Summary 10/8/2008 Freeze Protect (Pre-RWO) Pump production & test laterals w/2 bbls 60/40, 3 bbls diesel & 2 bbls 60/40 each. Close lateral valves & bleed each to 0 psi. IA/OA open. Swab, master, ssv & wing closed. Notify operator & tag well, turn well over to support tech's. 10/10/2008 (Fuilbore Diagnostics) T/I/0= 575/975/200 - Bullhead down Tbg x CT annulus w/2 bbls 60/40 methanol & 47 bbls diesel through packer/check. Injectivity=0.9 bpm C~ 2000 psi. Bullhead down CT through packer/check w/19 bbls diesel. Injectivity =-0.5 bpm C~ 1925 psi. Load & kill IA w/9 bbls 60/40 methanol, 20 bbls diesel, 596 bbls 1% kcl, 4 bbls 60/40 methanol, shutdown & monitor PFO (See Log). Freeze protect IA w/65 bbls diesel. IA/OA, master, swab & ssv open to ROS/gauges to monitor PFO. Wing closed. ROS SI to flow back tank. Well Tech's on location to monitor pressures following LRS departure. Notify operator & tag well. Final WHP's=1000/500/0 10/13/2008 CT/T/IA = 850/850/360. Monitor WHP's post bullhead project. 10/17/2008 Wellhead pressures (Post Bullhead Project) 10/13/08 2000 hrs CT = 850 psi, 2 7/8 T= 850 psi, IA = 340 psi. 10/14/08 1600 hrs CT = 850 psi, 2 7/8 T- 850 psi, IA = 340 psi. 10/15/08 0200 hrs CT = 850 psi, 2 7/8 T= 850 psi, IA = 340 psi. 10/15/08 1715 hrs CT = 850 psi, 2 7/8 T= 850 psi, IA = 340 psi. 10/16/08 0230 hrs CT = 850 psi, 2 7/8 T= 850 psi, IA = 340 psi. 10/26/2008 CT/T/I/0=1000/850/340/160 Load and Kill ( Prep for 1.5" CT removal) Pumped 3 bbls 60/40 methanol, 20 bbls 9.6 ppg NaCI brine, and 3.5 bbls Diesel down 1.5" CT string. Pumped 3 bbls 60/40 methanol, 50 bbls 9.6 ppg NaCI brine, and 8 bbls Diesel down tubing. Pumped 5 bbls 60/40 methanol, 149 bbls 9.6 ppg NaCI brine down IA. 10/27/2008 Load and Kill ( Prep for 1.5" CT removal ) Pumped remaining 210 bbls of 360 total bbls of 9.6 ppg NaCI brine down IA. Followed by 66 bbls Diesel. FWHP= 400/400/320/240 Swab, Wing, SSV, closed. IA, and OA open to gauges. 10/27/2008 T/I/O CT=O/ TBG=125/ IA=O OA=O. MPU Well support Techs come out and did fluid level shot down IA, Tubing, and coil tubing string all fluid packed. IA psi O, Tubing O psi,1.5 CT PSI bleed from 125 psi to 55 psi at 8:00 am. will come back in tonight and check Pressures. At 17:10 pm checked on pressure and was at O PSI. T/I/O CT=0 psi / TBG=O / IA=O psi 10/27/2008 MPU Well Support Techs removed well house, flow-lines and foundation. Installed blinds and TQ to spec. Note this well does not have a BPV profile do to the Coil Tubinq. 10/28/2008 CTU #9 Pipe Swap from 2.375" to 1.5". Complete. 10/28/2008 T/I/0= TBG on Vac /CT on Vac / IA on Vac/OA 120. Bleed OA to 0 psi in 5 mins. Fluid packed, waited 30 mins and shut in Valve. OA PSI at 0. TBG/CT/I/O=TBG on Vac /CT on Vac/IA on Vac/OA 0 PSI. 10/29/2008 T/I/O=TBG on vac /CT on Vac/IA on Vac/OA Ipressure but not enough to read on gauge. Bleed OA to 0 psi in 3 min. T/I/0= TBG on Vac/CT on Vac/IA on Vac/OA 0 psi. TBG FL was 70', CT FL 71', IA FL 110'. 10/30/2008 T/I/O=TBGon vac /CT on Vac/IA onVac/OA Ipressure but not enough to read on gauge. T/I/0= TBG on Vac/CT on Vac/IA on Vac/OA 0 psi. TBG FL was 70', CT FL 71', IA FL 110'. 10/31/2008 T/I/O=TBG on vac /CT on Vac/IA onVac/OA 35 psi. T/I/0= TBG on Vac/CT on Vac/IA on Vac/OA 35 psi. TBG FL was 70', CT FL 70', IA FL 110'. 11/1/2008 T/I/O=TBG on vac /CT on Vac/IA on Vac/OA 50 psi. T/I/0= TBG on Vac/CT on Vac/IA on Vac/OA 50 psi. TBG FL was 70', CT FL 70', IA FL 110'. 11/2/2008 ~ Continue riq up of CT to VVWP. Perform BOP test - passed. RIH with Baker fishing tools w/ Itco spear. ~ Spear coiled tubing. Back out the Pedcor hanger screws. PUH and release coil from downhole packer. ,~~o~`'lL ~,,,CT pull released with 18.5k pull. Set pipe in BOP slips. Load CT x tubing annulus with 4 bbls of 9.6 ppg u~ ~C NaCI brine. Perform no-flow test on CT, CT x tubing and IA. Double cold-roll CT and POOH, keeping ~ hole loaded with brine. ~~~ ~ Page 1 of 2 ~ . MPC-23, Well History (Pre Rig Workover) Date Summary 11/3/2008 Continue POOH with 1.5" CT. At 5000', noted that CT started showing siightly more wear. Continue loading well to handle pipe displacement. At 5150', holes were seen in the tubing. A major fracture occured coming over the guide arch at 5185'. After observation, work on securing CT. Cut CT above BOPs and secure by instaliing a lubricator and cap over remaining stub. Evaluate options. Elect to pull and cut coil in 20' segments utilizing the WWP crane. Establish procedure. Procede with coil recovery pull 15 to 20' of CT at a time. Continued pulling ratty coiled tubing. At midnight, 777' had been pulled with 3852' remaining. 11/3/2008 T/I/0=0/0/0, Temp=Sl. Assist Coii with Pedco head. Attempt to back out slips on Pedco safeset hanger. Slip screws backed out approx 2" and got extremely tight (2 slightly bent). Suspect solids behind slips not allowing them to retract fully. Will need at least 3.75" to clear I.D. of head. Will re-attempt after coil pulls and cuts 5000' of pipe. 11/4/2008 Continue pulling pipe in 20' sections. After pulling 923' of CT broke below the wellhead and a final 13' piece was extracted. CT extracted was extremely ratty with major breaks seen in the tubing. Total CT recovered from the well was 6118'. Remaininq CT in the well is 3707' estimated, Freeze protect well to 2200' in tubing pumping through CT hanger with 13 bbls of 60/40 meth. Spool off and cut junk coil from reel. MU 1.5" SLB Side Jet Nozzle. Open well and tag top of master for depth control. Standby on LRS. 11/5/2008 Wash CT hangar with 130° diesel with LRS, then work Pedcor hangar screws open. Pumped 15 bbls then work screws open. When all Pedcor screws were open 3-3/4", drifted 5' past hangar to into the top of 2-7/8" tubing successfully. POOH. Begin de-mobing equipment. Road unit to shop to re-spool 1 1/2" pipe. Note: Pedcor hanger slips are backed out to 3-3/4" per manufacturers specs. Hanger has only been drifted to 1-1/2" with CT. 11/6/2008 Continue pipe spooling to install 1-1/2" CT string. Completed spooling pipe, total of 18480' of 1 1/2" coil is currently available. Job Complete. 11/13/2008 WELL S/I ON ARRIVAL. (OBSTRUCTION IN TREE ~ TBG HANGER) MADE SEVERAL ATTEMPTS TO GET PAST TBG HANGER W/ LIB's. LIB's INDICATE CONE OBSTRUCTION. 1.50" WILL NOT PASS BPV PROFILE. WELL LEFT S/I, OPER NOTIFIED. 12/3/2008 Run video camera to view obstruction in tree. Ran video camera to top of Pedcor Hanger approx 4' from the top of the tree. Unable to determine exactly what obstruction is but it has an inside diameter of less than 1.7". 5/16/2009 T/I/0=100/0/0. (Well kill/ Tree removal) Spear into tbg w/ 5 bbls 60/40 meth followed by 398 bbls 9.0 KCL brine down tbg taking returns up IA to kill well for tree removal. Freeze protect tree w/ 1 bbl 60/40 meth & 2 bbls diesel. FWHP=0/0/600. Swab, wing, & SSV closed. Master, IA, & OA open. 5/18/2009 T/1/O=SSV/0/80, Temp=Sl. PPPOT-T (PASS), pre RWO. PPPOT-T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (1 "). Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 5/20/2009 T/I/O = Vac/Vac/110. Pull Tree with Pedcor hanqer and replace with dN hole tree. Performed NFT on tubing and IA. Initially IA and tubing were on a Vac. Both IA and tubing went to 0 psi in approx 15 min. Left bleed open for three hours. No change in pressures and no flow to surface. Rigged up crane to pull tree, RU loader with stinger and dry hole tree. Rigged up 2" line from IA to flowback tank. Verified pressures were still at 0 psi. Hot bolted tree, verified pressures and unbolted tree. Pulled tree, checked BPV profile and set TWC. Stabbed on dry hole tree and pressure tested to 5000 psi. Removed TWC and set BPV. Rigged down all equipment. Pulled Pedcor hanqer from tree and found that the obstuction in the hanger was a second coil tubinq quide with an 1 1/2" ID. -END- Page 2 of 2 ~ . BP EXPLORATION Page ~ of 5' Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ' Date , I From - To MPG23 MPG23 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES I I Start: 9/21 /2009 Rig Release: y 0/6/2009 Rig Number: 4ES w.. ~ ~, Spud Date: 2/3/1996 End: 10/6/2009 9/29/2009 ~ 00:00 - 01:00 01:00 - 04:00 04:00 - 07:00 urs Task Code NPT 1.00 MOB P 3.00 MOB P 3.00 MOB P 07:00 - 09:30 2.50 MOB P 09:30 - 13:00 3.50 MOB P 13:00 - 15:00 2.00 MOB P 15:00 - 18:00 3.00 KILL P 18:00 - 19:00 1.00 KILL P 19:00 - 19:30 0.50 KILI P 19:30 - 22:30 3.00 KILL P 22:30 - 23:00 0.50 KILL P 23:00 - 00:00 1.00 WHSUR P 9/30/2009 I 00:00 - 01:30 01:30 - 02:30 02:30 - 06:00 06:00 - 06:30 06:30 - 16:30 1.50 WHSUR P 1.00 WHSUR P 3.50 BOPSU P ~ ~r.. , Qp6f~tlOnS PRE HOLD WEEKLY SAFETY MEETING WITH CREW. DISCUSS ADW AND IADC INCIDENTS. DISCUSS PERSONAL SAFETY. REVIEW ~AST WELL. PRE SCOPE IN DERRICK AND LOWER ONTO SUB. BLOWDOWN AND UNHOOK LINES. PREP UNITS FOR MOVE TO MPC-23. PREP SHOP AND GENERATOR FOR MOVE. PRE MOVE PIPE SHED AND PITS OFF OF MPF-96, MOVE SUB OFF OF MPF-96. LINE UNITS ON PAD AND READY TO MOVE TO MILNE POINT C-PAD. PRE MOVE RIG COMPONENTS TO MPC-23. PRE SPOT SUB OVER MPC-23 AND LEVEL SUB. SPOT PlTS AND PIPE SHED. SPOT TIGER TANK, SPOT FUEL TANK AND GENERATOR #3. HOOK UP COMPLEXS AND PLUG IN LI N ES. PRE RAISE DERRICK OFF OF SUB AND SCOPE UP INTO POSITION, R/U FLOOR AND DERRICK. LINE UP PITS. " RIG ACCEPTED AT 15:00 HOURS ON 9/29/2009'*, *' WHILE MOVING CAMP AROUND CORNER ON MPC-PAD, CAMP STRUCK END WELLHOUSE. MILNE POINT OPERATIONS, ADW HSE ADVISOR AND SECURITY WERE NOTIFIED. SEE IR 2009- 3245198'" DECOMP TAKE ON 120 DEGREE 9.0 PPG BRINE INTO PITS. R/U FLANGE TO TOP OF TREE. HOOK UP LINE TO TIGER TANK AND TEST TO 120 PSI WITH AIR. DECOMP R/U WELL SUPPORT LUBRICATOR AND TEST TO 500 PSI WITH DIESEL. PULL 2-1/2" CAMERON TYPE "H" BPV. 160 PSI ON TUBING, 0 PSI ON IA, 200 PSI ON OA. DECOMP HOOK UP CIRCULATING LINES AND TEST TO 3,500 PSI. DECOMP BLEED TUBING PRESSURE OFF. PUMP DOWN TUBING TAKING RETURNS OUT THE IA THROUGH THE CHOKE MANIFOLD TO THE TIGER TANK. PUMP 3 BPM AT 1,760 PSI. PUMP 420 BBLS, CLEAN 9.0 PPG BRINE RETURNS BACK TO SURFACE. LOST A TOTAL OF 16 BBLS DURING CIRCULATION. DECOMP MONITOR WELL, 0 PSI ON THE TUBING, 0 PSI ON THE IA. VISUALLY INSPECT, THE TUBING AND IA ARE ON A SLIGHT VAC. DECOMP DRY ROD IN 2-1/2" CAMERON TYPE "H" TWC WITH FMC DECOMP TEST CAMERON TYPE "H" TWC FROM ABOVE TO 3,500 PSI FOR 10 MINUTES ON THE CHART, TEST FROM BELOW TO 1,000 PSI BY INJECTING AT 1 BPM FOR 10 MINUTES ON THE CHART. DECOMP N/D TREE AND REMOVE FROM CE LAR. INSPECT HANGER THREADS AND LOCK DOWN SCREWS. LANDING JOINT TOOK 8-1/2 TURNS TO MAKE UP. DECOMP N/U 13-5/8" 5M HYDRIL BOP STACK. P/U HYDRIL DOUBLE 0.50 BOPSU P DECOMP CREW CHANGE, RIG SERVICE, DERRICK INSPECTION, SET AND TEST PVT'S. 10.00 BOPSU P DECOMP N/U 13-5/8" 5M HYDRIL BOP STACK. P/U HYDRtL DOUBLE GATE DUE TO WELL PRESSURE. REMOVE SINGLE GATE Printetl: 10/19/2009 ~77:04:05 AM ~ ~ ~ BP EXPLQRATI~N :.. Page 2 ofi 5 Operations Suummary Report Legal Weil Name: MPC-23 Common Well Name: MPC-23 Spud Date: 2/3/1996 Event Name: WORKOVER Start: 9/21/2009 End: 10/6/2009 Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 10/6/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 9/30/2009 06:30 - 16:30 10.00 BOPSU P DECOMP FROM CELLAR 16:30 - 19:00 2.50 BOPSU P DECOMP INSTALL 3-1/2" X 6" VBR'S IN TOP RAM BODY ON THE DOUBLE GATE, REMOVE BLIND / SHEAR RAMS FROM SINGLE SET OF RAMS. 19:00 - 19:30 0.50 BOPSU P DECOMP HOLD SAFETY MEETING WITH CREW ON STAIR SAFETY, ANTI-SLIP FOOTWEAR AND HANDRAILL POLICY. 19:30 - 23:00 3.50 BOPSU P DECOMP INSTALL BLIND/SHEAR RAMS IN BOTTOM SET ON THE DOUBLE GATES. RAM CONFIGURATION IS ANNULAR PREVENTER, 3-1/2" X 6" VBR'S, BLIND SHEARS, MUD CROSS, AND 2-7/8" X 5" VBR'S 23:00 - 23:30 0.50 BOPSU P DECOMP FUNCTION TEST BOPE, FILL WITH WATER AND PURGE A!R FROM SYSTEM 23:30 - 00:00 I 0.50I BOPSUp P 10/1/2009 I00:00 - 04:30 I 4.50I BOPSUF~ P 04:30 - 05:00 0.50 BOPSU~ P 05:00 - 07:00 2.00 WHSUR P 07:00 • 09:00 I 2.00 I WHSUR ~ P 09:00 - 11:30 I 2.50 I PULL I P 11:30 - 20:00 I 8.501 PULL I P DECOMP TEST BOPE TO 250 PSI LOW AND 3 500 P I I PRESSURE. HOLD EACH TEST FOR 5 MINUTES ON THE CHART. TEST ANNULAR, VBR'S, BLINDS, CHOKE MANIFOLD VALVES, CHOKE LINE VALVES, KILL LINE VALVES, AND FLOOR VALVES. AOGCC WITNESS OF TEST WAS WAIVED BY BOB NOBLE, TEST WAS WITNESSED BY THE NABORS TOOLPUSHERS AND THE BP WSL. DECOMP TEST BOPE TO 250 PSI LOW AND 3,500 PSI HIGH PRESSURE. HOLD EACH TEST FOR 5 MINUTES ON THE CHART. TEST ANNULAR, VBR'S, BLINDS, CHOKE MANIFOLD VALVES, CHOKE LINE VALVES, KILL LINE VALVES, AND FLOOR VALVES. PERFORM KOOMEY DRAWDOWN TEST. AOGCC WITNESS OF TEST WAS WAIVED BY BOB NOBLE, TEST WAS WITNESSED BY THE NABORS TOOLPUSHERS AND THE BP WSL. DECOMP R/D BOP TEST ASSEMBLIES. BLOW DOWN LINES AND DRAIN BOP STACK DECOMP R/U WELL SUPPORT LUBRICATOR AND TEST TO 500 PSI WITH DIESEL. PULI. CAMERON 2-1/2" TYPE "H" TWC. DECOMP M/U TIW VALVE ON 2-7/8" LANDING JOINT, FMC REP BOLDS, WSL VERIFY TBG AND IA ON A SLIGHT VACUUM. PULL HANGER OFF SEAT AT 78K. PUW = 85K. L/D TBG HANGER. DECOMP CIRCULATE 40 BBLS SAF-SURF-O SURFACE TO SURFACE AT 3 BPM / 1500 PSi. PUMPED A TOTAL OF 416 BBLS AND LOSSED 33 BBLS. TBG AND IA ON A S~IGHT VACUUM. DECOMP POH WITH ESP AND UD 2-7/8" TBG 1 BY 1 TO PIPE SHED. 20:00 - 20:30 0.50 PULL P DECOMP R/U FOR LAYING DOWN 2-7/8" TUBING WITH 1-1/2" COIL TUBING ON THE INSIDE. HOLD D-1 DRILL ON HOW TO SECURE WELL. DISCUSS HAZARDS AND MITAGATION WITH CREW ON LAYING DOWN TUBING WITH COIL TUBING IN THE INSIDE. 20:30 - 23:00 2.50 PULL P DECOMP POOH LAYING DOWN 2-7/8" TUBING WITH 1-1/2" COIL TUBING_BREAK THE 2-7/8" TUBING CONNECTION AND P/U JOINT. CUT COIL WITH HYDRAULIC CUTTER AND LAY DOWN JOINT OF TUBING WITH COIL ON THE INSIDE DOWN THE PIPE SKATE. ESP CABLE SPOOL FULL AT JOINT#254. 23:00 - 00:00 1.00 PULL P DECOMP CHANGE OUT ESP SPOOL IN SPOOLING UNIT. P ~ Printed: 10/19/2009 11:04:05 AM ~ • BP EXPLORATION Page 3 of 5' Operations Summary Report Legal Well Name: MPC-23 Common Weli Name: MPC-23 Spud Date: 2/3/1996 Event Name: WORKOVER Start: 9/21/2009 End: 10/6/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/6/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 10/2/2009 00:00 - 03:30 3.50 PULL P DECOMP POOH LAYING DOWN 2-7/8" TUBING WITH 1-1/2" COIL TUBING. BREAK THE 2-7/8" TUBING CONNECTION AND P/U JOINT. CUT COIL WITH HYDRAULIC CUTTER AND LAY DOWN JOINT OF TUBING WITH COIL ON THE INSIDE DOWN THE PIPE SKATE. LAST JOINT WITH COIL INSIDE WAS JOINT #311. LAST JOINT OF 2-7/8" TUBING WAS JOINT #314. JOINT #314 WAS PERFED TOWARD PIN END. ESP CABLE WAS NOT CONNECTED. THE PINS WERE PULLED OUT OF THE POT HEAD. 03:30 - 06:00 2.50 PULL P DECOMP BREAK DOWN AND L/D ESP INTO PIPE SHED. CLEAR RIG FLOOR. 06:00 - 06:30 0.50 PULL P DECOMP SERVICE RIG AND PERFORM PRE-TOUR CHECKS. 06:30 - 07:30 1.00 PULL P DECOMP B/O TIW VALVE AND OVERSHOT, R/D ESP CABLE TRUNK. 07:30 - 08:30 1.00 PU~L P DECOMP CLEAN AND CLEAR RIG FLOOR. 08:30 - 09:30 1.00 CLEAN P DECOMP PU/MU 6-1/8" BIT, BIT SUB, 5 JTS 3-1/2" DP, XO, 7" SCRAPER, 2 EA BOOT BASKETS, XO = 204.40' 09:30 - 15:30 6.00 CLEAN P DECOMP P/U 3-1/2" DP 1X1 FROM PIPE SHED AND RIH TO 6246' WITH 7" SCRAPER ASSEMBLY. 15:30 - 17:30 2.00 CLEAN P DECOMP CUT AND SLIP DRILLING LINE. 17:30 - 18:00 0.50 CLEAN P DECOMP P/U 3-1/2" DP 1X1 FROM PIPE SHED AND RIH TO 6556' WITH 7" SCRAPER ASSEMBLY. 18:00 - 19:00 1.00 CI.EAN P DECOMP CREW CHANGE, INSPECT DERRICK, SERVICE RIG, SET AND TEST PVT'S ' 19:00 - 23:30 4.50 CLEAN P DECOMP P/U 3-1/2" DP 1X1 FROM PIPE SHED AND RIH TO 10,307' BIT DEPTH WITH 7" SCRAPER ASSEMBLY. WORK SCRAPER 4 TIMES ACROSS RTTS SETTING DEPTH OF 2' A D SLEEVE DEPTH OF 10,030'. P/U WEIGHT 138K, S/O WEIGHT 103K 23:30 - 00:00 0.50 CLEAN P DECOMP LINE UP AND CIRCULATE A 40 BBL HIGH VIS SWEEP AROUND AT 5 BPM WITH 1,200 PSI. 10/3/2009 00:00 - 01:30 1.50 CLEAN P DECOMP LINE UP AND CIRCULATE A 40 BBL HIGH VIS SWEEP AROUND AT 5 BPM WITH 1,200 PSI. LOST 12 BBLS DURING CIRCULATION. 01:30 - 06:00 4.50 CLEAN P DECOMP POOH WITH SCRAPER ASSEMBLY STANDING 3-1/2" DRILL PIPE IN DERRICK. MAINTAIN CONTINIOUS HOLEFILL WITH 9.0 PPG BRINE. HOLE IS TAKING -5 BPH. 90 STANDS OUT. 06:00 - 06:30 0.50 CLEAN P DECOMP CREW CHANGE, INSPECT DERRICK, SERVICE RIG, SET AND TEST PVT'S 06:30 - 07:30 1.00 CLEAN P DECOMP CONTINUE TO POH FROM 90 STANDS TO SURFACE (110 STANDS). 07:30 - 08:00 0.50 CLEAN P DECOMP SERVICE BOOTBASKETS AND UD 7' SCRAPER ASSEMBLY. BOOTBASKETS WERE EMPTY. 08:00 - 08:30 0.50 CLEAN P DECOMP INSTALL SHORT BOWL PROTECTOR. 08:30 - 09:30 1.00 CLEAN P DECOMP PJSM WITH HALlBURTON REP. M/U 7' CHAMP #4 PACKER WITH 3-1/2" MULE SHOE BELOW. 09:30 - 13:00 3.50 CLEAN P DECOMP RIH WITH 7" CHAMP PACKER ON 3-1/2" DRILL PIPE FROM DERRICK TO 10,150' 13:00 - 15:00 2.00 CLEAN P DECOMP BREAK CIRCULATION AT 3 BPM / 550 PSI, SET 7" CHAMP PACKER AT 10,140' , BLEED OFF AND MONITOR O.A. DURING CSG TEST. PRESSURE UP WITH 63 STK TO TEST ~~ CSG 3,500 PSI FOR 30 CHARTED MI UTES. UNSET, RELAX ELEMENTS AND BREAK CIRCULATION AT 3 BPM / Printed: 10/19/2009 11:04:05 AM ~ . BP EXPLORATION Page 4 of 5 Operation~ Summary Report Legal Well Name: MPC-23 Common Well Name: MPC-23 Spud Date: 2/3/1996 Event Name: WORKOVER Start: 9/21/2009 End: 10/6/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/6/2009 Rig Name: NABORS 4ES Rig Number: 4ES Date Fram - To Hours Task Code NPT Phase Description af Operations 10/3/2009 13:00 - 15:00 2.00 CLEAN P DECOMP 550 PSI. 15:00 - 00:00 9.00 CLEAN P DECOMP POH FROM 10,140' AND UD 3-1/2" DP 1X1. MAINTAIN CONTINIOUS HOLE FILL. HOLE IS TAKING -7 BPH 10/4/2009 00:00 - Oi:30 1.50 CLEAN P DECOMP POH FROM 10,140' AND UD 3-1/2" DP 1X1. BREAK AND UD 7" HES CHAMP PACKER. MAINTAIN CONTINIOUS HOIE FILL. HOLE IS TAKING -7 BPH 01:30 - 02:00 0.50 WHSUR P DECOMP PUI.I. WEAR BUSHING 02:00 - 03:00 1.00 WHSUR P DECOMP CLEAR ANO CLEAN RIG FLOOR. R/D DRILL PIPE HANDLING EQUIPMENT. 03:00 - 06:00 3.00 RUNCO P RUNCMP R/U HANDLING EQUIPMENT FOR RUNNING 4-1/2" 13CR80 COMPLETION. HAVING TO BRING ALL EQUIPMENT IN THROUGH THE PIPE SHED. R/U TONGS AND COMPENSATOR. 06:00 - 09:00 3.00 RUNCO P RUNCMP P/U 1-WIRE SPOOL FROM PIPE SHED AND HANGE I-WIRE SHEAVE IN DERRICK. LOAD, STRAP AND DRIFT LAST ROW OF 4.5" CHROME TBG INTO PIPE SHED. 09:00 - 09:30 0.50 RUNCO P RUNCMP PJSM ON RUNING CHROME TBG WITH I-WIRE. 09:30 - 12:00 2.50 RUNCO P RUNCMP PU/MU 4.5" 13CR,12.6# WLEG,XN, 7" PKR, SINGLE GAUGE, 12:00 - 18:00 I 6.00 18:00 - 18:30 I 0.501 RUN 18:30 - 00:00 I 5.501 RUN 10/5/2009 100:00 - 06:00 I 6.001 RU 06:00 - 06:30 I 0.501 RUN 06:30 - 07:00 I 0.501 RU 07:00 - 07:30 0.50 RUN 07:30 - 09:00 1.50 RUN 09:00 - 10:30 ~ 1.50 ~ RU E MU AND TEST I-WIRE CONNECTIONS. RUNCMP RUN 4.5" 12.6#, 13CR80, VA T P M LETI ASSEMBLY WITH I-WIRE, USE JET LUBE SEAL GUARD PIPE DOPE, TORQUE TURN ALL CONNECTIONS, AVERAGE M/U TORQUE OF 4,440 FT/LBS. USE COMPENSATOR ON ALL JOINTS. JOINT # 1 TO JOINT #90. CHECK I-WIRE EVERY 20 JOINTS RUNCMP CREW CHANGE, RIG SERVICE, DERRICK INSPECTION, SET AND TEST PVT'S. RUNCMP RUN 4.5" 12.6#, 13CR80, VAM TOP COMPLETION ASSEMBLY WITH I-WIRE, USE JET LUBE SEAL GUARD PIPE DOPE, TORQUE TURN ALL CONNECTIONS, AVERAGE M/U TORQUE OF 4,440 FT/LBS. USE COMPENSATOR ON ALL JOINTS. JOINT # 91 TO JOINT #148. CHECK I-WIRE EVERY 20 JOINTS. RUNCMP RUN 4.5" 12.6#, 13CR80, VAM TOP COMPLETION ASSEMBLY WITH I-WIRE, USE JET LUBE SEAL GUARD PIPE DOPE, TORQUE TURN ALL CONNECTIONS, AVERAGE M/U TORQUE OF 4,440 FT/LBS. USE COMPENSATOR ON ALL JOINTS. CHECK I-WIRE EVERY 20 JOINTS. RUNCMP CREW CHANGE, RIG SERVICE, DERRICK INSPECTION, SET AND TEST PVT'S. RUNCMP RUN JTS# 132 TO # 140. RAN TOTAL OF 240 JTS, 4.5" 13CR,12.6# TBG. 125 LASALLE CLAMPS AND 4 HALF CLAMPS. RUNCMP M/U TIW VALVE AND LANDING JOINT AND XO. RUNCMP M/U TUBING HANGER AND ORIENT WITH FMC REP. INSTALL I-WIRE AND LAND HANGER, DROP 1-7/8" BALL / ROD, RILDS. RUNCMP PUMP 39 STK TO SET AND PRESSURE TEST PACKER TO 4,000 PSI FOR 30 CHARTED MINUTES. BLEED TUBING TO , UMP 68 STK TO PRESSURE TEST I.A. TO 3,500 FOR 30 CHARTED MINUTES. GOOD TEST. Printed: 10/19/2009 11:04:OS AM ~ . BP EXPLORATION Page 5 af 5 Qperations ~ummary Report Legal Well Name: MPC-23 Common Well Name: MPC-23 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date From - To I Hours Task Cod~ NPT 10/5/2009 10:30 - 11:00 0.50 11:00 - 13:00 I 2.00 13:00 - 22:30 I 9.50 I BOPSUF~ P 22:30 - 23:30 I 1.00 I BOPSUR P 23:30 - 00:00 I 0.50 I BOPSUF~ P 10/6/2009 I 00:00 - 04:30 I 4.50 I BOPSUFi P 04:30 - 06:00 I 1.50I BOPSUp P 06:00 - 06:30 0.50 BOPSU P 06:30 - 07:30 1.00 BOPSU P 07:30 - 09:30 2.00 BOPSU P 09:30 - 12:00 2.50 WHSUR P Spud Date: 2/3/1996 Start: 9/21 /2009 End: 10/6/2009 I Rig Release: 10/6/2009 Rig Number; 4ES Phase ' Description of Operatit~ns RUNCMP FMC REP SET TWC. PRESSURE TEST FROM ABOVE TO 3,500 PSI FOR 10 CHARTED MINUTES. RUNCMP R/D CHROME HANDLING EQUIPMENT THROUGH THE PIPE SHED. RUNCMP N/D BOPE. REMOVE RAMS FROM DOUBLE GATES, N/D DUTCH SYSTEM AND REMOVE, N/D ANNULAR PREVENTER AND REMOVE FROM BOP STACK, N/D DOUBLE GATES AND REMOVE STUDS, REMOVE DOUBLE GATES FROM CELLAR. RUNCMP HOLD WEEKLY SAFETY MEETING WITH CREW. DISCUSS HSE STATS FORM ADW AND NABORS, REVIEW IADC SAFETY ALERTS. REVIEW PRE-JOB FORMS. RUNCMP N/U HYDRIL 13-5/8" 5M SINGLE GATES AND ANNULAR PREVENTER. RUNCMP N/U HYDRIL 13-5/8" 5M SINGLE GATES AND ANNULAR PREVENTER. INSTALL DUTCH SYSTEM AND KOOMEY LINES. RUNCMP INSTALL BLIND SHEAR RAMS IN TOP SET AND BUTTON UP STACK. N/0 BOLTS FROM LOWER RAMS. RUNCMP PERFORM PRE-TOUR CHECKS. RUNCMP COMPLETE N/U AND SET SECURE BOP TO RIG. PICK-UP TOOLS. RUNCMP N/U 4-1/8" 5M ADAPTOR FLANG AND TREE. INSTALL I-WIRE SURFACE TIE-IN ASSEMBLY AND TAKE FINAL READING. TEST ADAPTER HANGER VOID AND TREE TQ 5,000 PSI RUNCMP /U M/U AND TEST LUBRICATOR WITH DIESEL TO 500 PSI. PULL TWC AND INSTALL 4" TYPE'H" BPV. RIG RELEASED FOR MOVE TO MPC-01 ~ 12:00 10/06/2009. Printed: 10/19/2009 11:04:05 AM Tree: 4-1/16" 5M Cameron ~ M P U C~23 Orig. DF L'T~v. = 45.4' (N 22E) Wellhead: 11" 5M FMC Gen. 5 Orig. GL Elev. = 16.8' w/ 4-1/2" FMC Tbg. Hanger DF To Tbg. Spool = 28.6' (N 22E) 4-1/2" TCII top/btm threads 4" "H" BPV Profile 20" 91.1 ppf, H-40 115' KOP @ 2550' Max. hole angle = 39 to 42 deg. f/ 4400' to 7400' Hole angle thru' perFs = 27 deg 9 5/8", 40 ppf, L-80 BTC. 4,941' I Sag River Completion: 7", 26 ppf, L-80, Btrc. production casing (drift ID = 6.151", cap. = 0.0383 bpf) 4.5", 12.6#, 13Cr, Vam Top Tbg. Tubing Drift ID - 3.833" Capacity = .0152 ft/bbl Reverse Circulation' Je1 PumO Confguretbn ~ ~ ~i ~~~,d.wd si ~i 1' ~i i i ~. _ ~ i~' , ~' , J Stimulation Summary 03/07/96 - 146 M# of 20/40 prop. was placed behind casing. Job went to flush Perforation Summary Ref log: 3/5/96 AWS ar/ccl Size SPF Interval D) Sag 3 3/8" 6 10,190'-10247' (8759'-8810') 4.5" SLB Sapphire Discharge 10,008' Gauge 4.5" Baker CMD Sliding 10,025' Sleeve w/ "X" profile 4.5" SLB Sapphire Gauge 10,029' I Sensor. 7"x 4.5" Premier Pkr. 10,090' I 4.5" HES "XN" Nipple 10,129' 4-1/2" WLEG 10,140' Two 20' 7" short joints from 10,060' to 10,101' md w/ RA tag in top collar 22 gm Jumbo Jet charges (EHD = 0.76", TTP = 6.4")@ 60 deg. phasing DATE REV.BY COMMENTS 02 / 17 / 96 6/ 05/ 96 JBF MDO Drill and Cased by Nabors 22E ESP COMPLETION 4ES 11/9/96 M. Linder RWO Nabors 4-ES 08/13/00 M. Linder CTU jet pump completion. 09/16/01 B. Hasebe Addition of Jet Pump flow schematic 10/05/09 REH RWO - Jet Pump Conversion - Nabors 4ES MILNE POINT UNIT WELL C-23 (Saq) API NO: 50-029-22643 BP EXPLORATION (AK) FCO to 70,307' by Nabors 4ES 10/6/09 PBTD 11/6/96 10697' 7" float 10689' 7" float 10777' shoe • AI,ASSA OIL A1QD GRAS COIYSERQATIOI~T COM!-IIS5IOI~T David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 C SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA X9501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Anchorage, AK 99519-6612 `~~ ~~'~~ ~ ~ ~~~ ~. (~ D~` Re: Milne Point Unit, Sag River Oil Pool, MPC-23 "1 Sundry Number: 308-416 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Cornrnission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~$l~~ Cathy P. Foerster Commissioner f~- DATED this ~ day of November, 2008 Encl. _ _ STATE OF ALASKA /-/l0~ ~ • (~ ~ _,~W~ ~~ ALF~ OIL AND GAS CONSERVATION COM ION ~~ "'ppp"'111 ~- APPLICATION FOR SUNDRY APPROVAL ~'~ 20 AAC 25.280 ~ 1. Type Of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ®Repair Well. ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing . ^ Perforate New Pool ^ Waiver ®Other Tubin Swa 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ,® Development ^ Exploratory 196-016 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22643-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: MPC-23 Spacing Exception Required? ^ Yes ^ No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ~v'tY ~ mo ADL047434 45' Milne Point Unit / Ku t2. PRESENT WELL CONDITION SUM MARY ~~/9'~ Total Depth M (ft): r Total Depth D (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 1 /~ ~2 10689 9216 None 10060' - 10101' in ~' ~ L n h iz M r ~~ 1 ' 4 1 / " 4 1' 7 In r i in " r Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10190' - 10247' 8768' - 8819' 2-7/8", 6.5# L-80 9990' Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: November 24, 2008 ®Oil - ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Howard West, 564-5x71 Printed Nam avid Reem Title Engineering Team Leader Prepared By NameMumber: Signature Phone 56 y - 7 3 Date /~ ~~ ~g Sondra Stewman, 564-4750 Commission Use Onl Sundry Number:- Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity .BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other. Q ~dd® psi `~~ ~S~' ~ ~~~.~ ~.~~ ~c~0~ ~c,~j~C~c~ d ~~\~`~GG~`~'c~ ~ \c~t~ ~- ~` i ~V 5~~~ c~~5 ~ ~°t ~~~~ ~ alc~~.v~'fc c~,cs~@~h~ ~ ~'~ ~~~ ~'S `~~~ `~1 Subsequent Form Required: ~~~~ - APPROVED BY / A roved B : COMMISSIONER THE COMMISSION Date / "~' fl Form 10-403 Revised 6/2006 (~ ('` (~( -~.~;~ 5~~,. tv(1V ~ `' 2000 ubmit In Duplicate /l /'Q oe • by Milne Point C-23 Rig Workover • Scope of Work: Pull existing 2 7/8" tubing ESP completion and remaining 1 1/2" coil tubing jet pump completion. Run new jet pump completion on 3 1/2", 9.2 #, 13Cr-80, tubing. A service coil tubing unit successfully pulled out 6000' of the coil. The check valve in the jet pump has failed, The mechanical integrity of the 2 7/8" tubing is unknown due to the jet pump's failed check valve. The attached pictures show that the coil is pitted, corroded, full of holes and is progressively degrading with depth. Therefore, 1 1/2" BOP's for coil in this condition would not provide additional well control. The 1 1/2" coil will be cut into pieces for disposal. A 2 7/8" full opening safety valve will be on the rig floor during all phases of this operation. MASP: 3100 psi Well Type: Sag River Producer Estimated Start Date: Nov 24, 2008 Intervention Engineer: Howard West Pad Engineer: Laurie Cornell Pre-riq prep work: F 1 Circulate well with kill wei ht fluid and diesel thru the cut. W 2 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. W 3 Set a BPV in the tubin han er. O 4 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Nabors 3S. 2. Circulate out freeze protection fluid and circulate well with warm seawater. Measure SITP. 3. Kill well with clean kill weight fluid. 4. ND tree. NU and test BOPE to 4000 psi, test annular to 3500 psi. Stack will consist of annular, pipe rams, blind shears. flow cross, and 2 7/8" x 5" vbr's. 5. POOH with existing 2 7/8" completion down to the top of the remaining 1 '/z" CT jet pump completion (6000' MD). 6. Pull single joints of 2 7/8" completion, cutting 1 '/z" coil as each joint of 2 7/8" is pulled out of hole. 7. Run jet pump completion on 3 1/2", 9.2 #, 13Cr-80, tubing w/ Baker premier packer set at 10,080' MD w/ wire line entry guide set at 10,150' MD. 8. Test the IA to 4000 psi. 9. Freeze protect to 2200' MD w/diesel. 10. ND BOPE. Set & test BPV. 11. Install tree, test to 5000 psi. 12. RDMO. Tree: 2-9/16"x 11" - 5M FMC Orig. DF Elev. = 45.~22E) Wellhead: 11" 5M FMC Gen. 5 ~ Orig. GL Elev. = 16.8' ESP DF To Tbg. Spool = 28.6' (N 22E) w/ 2-718" FMC Tbg. Hng , EUE lift threads, 2-7/8" CIW H BPV Profile 40 115' 20" 91 1 f H . pp , - Camco 2 7/8" x 1" KOP @ 2550' sidepocket KBMM GLM 138' Max. hole angle = 39 to 42 w/ dummy valve. deg. f/ 4400' to 7400' Hole angle thru' perfs = 27 deg 9 5/8", 40 ppf, L-80 Btrc. 4,941' ~ ~ ~ 1-1/2"CTU completion: Sag River Completion: " ,_,.2 Coil tubing data: 7", 26 ppf, L-80, Btrc. production ~'iall= .109, 1.623#/ft HS-70. ID=1 .232" casing (drift ID = 6.151", cap. = 0.0383 bpf) Capadty= t6 bbls; ,ooo 'Pump In /Pump Oul' Cdletl Tubing Jel Pump Configuratlon Tricojet pump receptical 9825' _ - F - ~ re j ~ Baker seal assembly 9829' I i s ~ Baker 028FA-18 perm 9830' `~' - packer (1.25" sealbore I ~ ~ • Tubing punched 9890'-9894' ~ w/ 10 shots, 0 degree phasing. ~ I Centrilift GC 1700 ESP, series 513, GPMTAR 1-1, 9928 . 123 Stg. a • Centrilift GSTDBHLBAFLAS 9946' Re~rv ,F~uitl seal section Centrilift KME1 562 series, 9959, Stimulation Summary 165 hp motor, 2230/ 43 amps. 03/07/96 - 146 M# of 20140 prop. was placed behind casing. Job went to flush Centrilift 9977 Perforation Summary Ref log: 3/5/96 AWS gr/ccl Two 20' 7" short joints from 10,060' to 10,101' and w/ RA tag in top collar Size SPF Interval (TVD) Sag 3 3/8" 6 10,190'-10247' (8759'-8810') 22 gm Jumbo Jet charges (EHD = 0.76", TTP = 6.4")@ 60 deg. phasing 10697' PBTD 11/6/96 7" float 10689' 7" float 10777' shoe DATE REV. BY COMMENTS MILNE POINT UNIT 02 / 17 / 96 JBF Drill and Cased by Nabors 22E WELL C-23 (Sag) 6 / 05/ 96 MDO ESP COMPLETION 4ES API NO: 50-029-22643 11/9/96 M. Linder RWO Nabors 4-ES 08/13/00 M. Linder CTU jet pump completion. BP EXPLORATION (AK) 09/16/01 B. Hasebe Addition of Jet Pump flow schematic 4-1/16"x 11" - 5M FMC read: 11" 5M FMC Gen. 5 R w/ 2-7/8" FMC Tbg. Hng , EUE lift threads, 2-7/8" CIW H BPV Profile 20" 91.1 ppf, H-40 115' KOP @ 2550' Max. hole angle = 39 to 42 deg. f/ 4400' to 7400' Hole angle thru' perfs = 27 deg 9 5/8", 40 ppf, L-80 Btrc. 4,941' 7", 26 ppf, L-80, Btrc. production casing (drift ID = 6.151", cap. = 0.0383 bpf) Sag River Completion: Orig. DF Elev. = 45. 22E) Orig. GL Elev. = 16.8' DF To Tbg. Spool = 28.6' (N 22E) 3.5" HES X-Nipple 2000' Camco 3 1/2" x 1" KBMG GLM 2200' 3.5" HES "XD" Duro sliding sleeve 2.813" ID (opens down) 10030' Baker 7" x 3.5" 10080' Premier Pkr. 2.87" ID 3.5" 9.3# 13Cr-80 Vam Top Tbg. 3.5" HES XN-Nipple 10135' Stimulation Summary 03/07/96 - 146 M# of 20/40 prop. was placed behind casing. Job went to flush Perforation Summary Ref log: 3/5196 AWS gr/ccl Size SPF Interval (ND) Sag 3 3/8" 6 10,190'-10247' (8759'-8810') 22 gm Jumbo Jet charges (EHD = 0.76", TTP = 6.4")@ 60 deg. phasing 3.5" WLEG 10150' Two 20' 7" short joints from 10,060' to 10,101' and w/ RA tag in top collar PBTD 11/6/96 7" float 7" float shoe 10697' 10689' DATE REV. BY COMMENTS 02 / 17 / 96 JBF Drill and Cased by Nabors 22E 6 / 05/ 96 MDO ESP COMPLETION 4ES 11/9/96 M. Linder RWO Nabors 4-ES 08/13/00 M. Linder CTU jet pump completion. 09/16/01 B. Hasebe Addition of Jet Pump flow schematic MILNE POINT UNIT WELL C-23 (Sag) API NO: 50-029-22643 BP EXPLORATION (AK) • Page 1 of 1 Maunder, Thomas E (DOA) From: Reem, David C [ReemDC@BP.com] Sent: Friday, November 21, 2008 1:58 PM To: Maunder, Thomas E (DOA) Cc: West, Howard J Subject: RE: MPC-23 (196-016) Tom, see replies to your questions below in RED... DCR From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sen#: Friday, Navernber 21, 2008 12:37 PM To: West, Howard J Cc: Reem, David C Subject: MPC-23 (196-016) I am reviewing the sundry application for the continued work on this well and have a couple of questions ... 1. t# is mentioned to circulate the well "out through the cut" however 1 don't find any information regarding any tubing cut. Correct, there will be no tubing cuts... we will circulate thru the tubing punch holes just below the CT jet pump. 2-7/8" tubing will be left intact. 2. Is there any plan far a cleanout run? Since you plan to run the new completion deeper than the existing one, a cleanout may be needed. There will be cleanout and casing scraper run in the workover after the ESP is laid down. 3. What is the condition of the 7" casing? is there any plan to log or pressure test the casing? The 7" casing will be MIT'd to 4000 psi prior to running the new jet-pump completion. We do not plan on running any logs. 4. What will the flow directions be on the well? Power fluid down the tubing or down the casing? Power fluid flow-path will be down the annulus and up the tubing. Thanks in advance. Tom Maunder, PE AOGCC 11/21/2008 Mp C_23 ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, November 12, 2008 9:02 AM To: 'West, Howard J' Cc: Reem, David C Subject: RE: MP C-23 Howard, When you submit the sundry, make your case in it for not employing the 1-1/2" rams. I acknowledge that you, Dave and I have discussed this situation however I cannot give you AOGCC concurrence. I will review what you propose in the sundry and provide my endorsement (if appropriate) for the Commissioners to approve. Making application by sundry signifies to me that your management supports what you propose. I look forward to the application. Call or message with any questions. Tom Maunder, PE AOGCC from: West, Howard 3 [mailto:Howard.West@bp.com] Sent: Tuesday, November 11, 2008 4:20 PM To: Maunder, Thomas E (DOA) Subject: MP C-23 Tom- I would like to touch base with you on Milne Point well C-23. As you are aware , MP C-23 had 9000' of 1 1/2" jet pump coil tubing completion set inside 27/8" tubing, ESP completion. A service coil tubing uni# successfully pulled out 6000' of the coil. Attached is a few pictures of the 1 1/2" coil that made it to surface. As you can see from the picture, the coil is pitted, corroded, full of holes and was progressively degrading wi#h depth. The check valve in the jet pump has also been noted to have failed, sa there is no way to know what kind of condition the 2 7/8" tubing is in. We feel that 1 1/2" BOP's for coil in this condition would not be of any benefit to the operation. Qur plan is to rig up Nabors 3s and pull this completion. The 1 1/2" coil wilt be cut into pieces for disposal. A 2 7/8" full opening safety valve will be on the rig floor during all phases of this decomplete. We are seeking AOGCC concurrence with this plan. Thanks for your time and please call with any questions or concerns, Howard «P1000669 (Large).JPG» «P1000671 (Large).JPG» 1 v2v2oas u~, , ___._~ ~~ ~, ~, ,. ,~:~_. _ . ., .. - ,~ ., sec ,. . , ~ ~, . _ ..v.... .. - ~' .-. r #.. .. r ~1 r. .N, .. -mow NY ~ s, , ~_- ~. ~ "v F _{` ~ a.v.-' .. .,.. '~ '~'f xY s ~ t~,~ -.. _. , y.~,;, .:.. ~~ ..s° - ~> T%P ens itii d,. .- ~~'a~ "M~a & /~9~0 s1~ ~.,w t . ,Ee. '. R• Paz A ~ _ 4 c .<.nkP X~ ~+ :'tea .r -. . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount 0.77 DATE: July 12, 2000 Commissioner' O/Io/bc:.;:) THRU: Blair Wondzell, @~ P. I. Supervisor .9f1(c(J FROM: ~t!¡ Jeff Jones ..-,.. SUBJECT: Safety Valve Tests Petroleum'l sp c /'r Milne Point Unit B & C Pads July 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU 8-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap a-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. . SUMMARY: I witnessed SVS tests on BP'S MPU B & C pads. MPU 8 Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. '3 J1-'Q~ r~h.-~i- 21 well houses were inspected, no failures. -'þ" Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc . . Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: Field/Unit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/00 .'ra" rm ,/ ~~~«:{i;~:ì\' ~ji j)~ I a . .. . ""--' , 'r.: .~ ...>~ ;~~!'~;I:';\',:'--'. -"." .......' . . ..... . .... "}Yell-rýþe~,', . " " Pilots' .~~:~.V:~'~. ',S~.IV:'\ I;~:}'{ .:~¡ ~:ft~'.\ ~~~, ';\. . . ~ I. I Well Permit Sepal' Set L/P Test Test Test Number Number PSI PSI Trip Code Code Code Oil, WAG, GIN.', GAS or CYCLE ~: ~~Q 11~-~? ~<~ '/ 1811430 140 100 95 P P OIL C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 1972480 C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG 12 Components: 23 Failures: 6 Failure Rate: 26.0%090 Day We lIs: Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap a-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these iteITIS corrected. 8/7 lOa Page 1 of 1 VI v7irqm.xls STATE OF ALASKA ALASKA ~,~L AND GAS CONSERVATION CO~wMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown []Stimulate [] Plugging [] Perforate [~]Pull Tubing []Alter Casing [] Repair Well [~Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. AddreSs P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1038' NSL, 2404' WEL, Sec. 10, T13N, R10E, UM At top of productive interval 2758' NSL, 1167' WEL, Sec. 9, T13N, R10E, UM At effective depth 2841' NSL, 1395' WEL, Sec. 9, T13N, R10E, UM At total depth 2854' NSL, 1430' WEL, Sec. 9, T13N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 48' 7. Unit or Property Name Milne Point Unit 8. Well Number MPC-23 9. Permit Number / Approval No. 96-016 10. APl Number 50- 029-22643 11. Field and Pool Milne Point/Sag River 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10777' feet 9296' feet 10689' feet 9216' feet Length 81' 4910' 10748' Size 20" 9 5/8" 7" Plugs (measured) Junk (measured) Cemented MD TVD 250 sx Arctic Set I (approx) 112' 112' 963 sx PF 'E', 250 sx 'G' 4941' 4620' 114 sx PF 'E' 600 sx Class 'G' 10777' 9296' Perforation depth: measured 10190'-10247' true vertical 8768'-8818' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 9990' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 0 i 6 i N A L 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord ~ ~' ~ Title Engineering Supervisor Date ,~'//-~,./,,~ ' Prepared By Name/Number: Mary Youngers 564-5242 Submit In Duplicate Form 10-404 Rev. 06/15/88 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPC-23 Rig Name: N-4ES AFE# 339029 Accept Date: 11/04/96 Spud Date: . Release Date: 11/09/97 NOVEMBER 05, 1996 RIG ACCEPTED @ 1900 HRS. MOVE RIG FROM MPUF-66 TO MPU C-23 & RIG UP BERM & LEVEL DERRICK, SAFE OUT EQUIPMENT. TAKE ON 2% KCL WATER, SET, BERM TT, RIG HARD LINES TO TREE & TEST TO 2200 PSI. RIG LUB, PULL BPV. ANNULUS = 440PSI TBG = 280PSI CIRC. WELL BORE W/KCL, TAKE GAS & CRUDE RETURNS TO TT PUMPED A TOTAL OF 463 BBL & TOOK A TOTAL OF 197 BBL CRUDE TO 'IT. MIX XANVIS OM PILL W/KCL WATER. NOVEMBER 06, 1996 SPOT SPILL & MONITOR WELL (NO CIRC). SET TWC, ND TREE & MU BOP'S. TEST BOP'S TO 250 LOW & 5000 HIGH (ANNULAR WOULD NOT TEST). CHANGE OUT ANNULAR ELEMENT & TEST OK. PULL TWC & INSTALL LANDING JT. BOLDS & PULL HANGER CIRC. BU & MONITOR WELL BORE. PULL HANGER TO FLOOR & LD SAME. POOH W/ESP COMP (REC ALL CLAMPS & BANDS) LD & INSPECT PUMP (POT HEAD IS SUSPECTED PROBLEM) RIG HES WIRE LINE UNIT FOR GR/JB RUN. NOVEMBER 07, 1996 RIH W/6.0" GR/JB ON SLICKLINE SET DN @ 10232' - 457' FILL POOH R/D SLICKLINE. MU 5.90" MILL ON 2 7/8" TUBING TIH TAG FILL @ 10229'. REVERSE CIRCULATE & ATTEMPT TO WASH OUT FILL, WASH 10229 TO 10242 FILL WOULD NOT WASH OUT. POOH STAND BACK 2 7/8" TUBING. PULL WEAR BUSHING, SET TEST PLUG, CHANGE RAMS TO 3 W' & TEST TO 5000 PSI, SET W/B MU BHA, TIH PICKING UP 3 ½' DRILL PIPE FOR FILL CLEAN OUT, 5500' @ 0600 HRS. NOVEMBER 08, 1996 REPAIR HYDRAULIC LINE ON PIPE HANDLING MACHINE RIG DOWN TIME. CONTINUE TIH PICKING UP 3 Y:~" DRILL PIPE TAG TOP OF FILL @ 10242' CLEAN OUT FILL LONG WAY 10242' TO PBTD @ 10697' DPM - PUMP SWEEPS TO CLEAN HOLE CIRCULATE @ 6 Y2 BPM WHILE ROTATING & RECIPROCATING & PUMP SWEEP AROUND, CIRCULATE UNTIL HOLE CLEAN. CARBOLITE FRAC SAND, FORMATION SAND & LCM IN RETURNS. PUMP 40 BBLS XANVIS SPACER FOLLOWED BY CLEAN 2% KCL WATER LONG WAY @ 6 1/2 BPM ROTATING & RECIPROCATING - 63 NTU ON RETURN FLUID @ SHAKER - MONITOR WELL OK NO LOSS POOH LD DRILL PIPE @ 1000' 0600 HRS. NOVEMBER 09, 1996 FINISH POOH LD DRILL PIPE & BHA. PULL WR BUSHING, SET TEST PLUG, CHANGE RAMS TO 2 7/8" TEST DOOR TO 2000 PSI. LD EXCESS TUBING FROM DERRICK 12 JTS. MU & SERVICE ESP. RIH W/ESP ON 2 7/8 TUBING FROM Page 1 of 2 SUMMARY OF DALLY OPERATIONS DERRICK- RAN TOTAL 314 JT 2 7/8" 6.5# L-80 EUE 8RD TUBING MU TWO CABLE SPLICES. LAND TUBING @ 9977' IN STALL TWC VALVE & TEST TO 1500 PSI. ND BOP, NU 1 lx2 9/16 ADAPTER FLANGE, NU CIW 2 9/16 TREE. TEST TREE & PACK OFF TO 5000 PSI - OK. FREEZE PROTECT WELL BY BULLHEADING 59 BBLS DOWN ANNULUS & 10 BBLS DOWN TUBING @ ~ BPM 1500 PSI. BLOW DOWN LINES, SET BPV W/LUBRICATOR, SECURE WELL CLEAN PITS. RIG RELEASED @ 0600 HRS. Page ~ {Ja 1~ared . ervices rilling Alaska (If .{ ~. 900 East Benson Boulevard, MB 8-1 . Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request DEC 141998 Dear Ms. Mahan: Alaska Oil & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through present time. We compared your list with our records and are able to provide you with the following data: . Individual Annular Disposal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. TheSSD records are provided to you in the same order as listed on your log. . There were some wells on your list which were not injected into. These wells are identified as follows: . Endicott wells 1-03/P-16, 1-65/N-25, 1-59/0-24 . Exploration well Pete's Wicked #1 . Milne Point wells E-22, E-23, F-Ol, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & #2, K-05, K-02, H-07, K-25, K-37, E-17, F-21,K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F -49i, K-18 . PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11..38 . The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: . The wells listed above in italics were permitted but not used for annular disposal. . The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. . We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular disposal: SCANNED NOV 1 3 2002 .. ,Annular Disposal Letter 12/14/98 ( '" (-#Þ t ~ 0, ~ . ) :L8 I <14- I -+ z.,. ) ~-4 .ISZ- I . Endicott wells 1-23/0-15, 1-61/Q-20, 2-40/S-22 . Exploration well sourdo?lh #?, ;r~4;,.;. 00 ßo4- 1 Z-.b 9 f.,- 0 2. r q 8 ,~. II..) /'-' . Milne point wells F-06, -05, ÍI-06, J-13, L-24 - 'IS' 010 Ch . qt C!tS-<oq .... ( ~S:'I~'3 ' qs. I-t. '3 . PBU wells-18-30, 18-31, 14M,.s..-43, E-34, E-36, G-04A, and S-33- Q2-/°2- . . . 9~ . oS '2.. '~"3 . '2.c+- . g ç. 0'9 3 . IndIVIdual logs are provIded to yOU fof these logs as well. . Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, ~{L- ~p, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEtV'ED DEC ~141998 Alasí<â Oil ,& Gas Cons. Commission Anchorage , Shartd Se~ice Drilling Anndfar .njectionVolumes July 25, 1995 until December 1998 Cumulative Report Rig Endicott Doyon 15 Doyon 15 Doyon 15 - ---- -----_._----. . Joyon 15 InjWell 1-19/1~18 Surface Casing Depth 5000 Legal Desc Sec. 36, T12N,R16E Cum Mud Cum Total & Ctgs 1-23/0-15 4246 2020'FNL, 2081'FEW, SEC.36,T12N,R16E 1-33/M-23 5013 3211'NSL, 2114'WEL, Sec36,T12N, R16E --------------------- -----.-------------------- 1-61/0-20 4236 3075'NSL, 2201'WEL, Sec 13,T12N, R16E 8,960 32,084 9,879 Joyon 15 2-40/S-22 4531 :OA Joyon 14 15-47 3515 -_._-----~-------------------~--- -- . 14 )oyon 14 OS 15-45 OS 15-48 - )oyon 14 OS 15-49 )_oyon 9 18-30 )oyon 9 18-31 ---~-------- >oyon 9 18-32 )oyon 9 18-33 ..---------- labors18E labors 18E 12-35 12-36 labors 18E 'abors 18E 13-36 14-44 xploration 0014 :ilne 3543 3452 3431 3288 Sourdough #3 4236 27E MPK-17 MPC-23 ------< abors 22E -- abors 22E MPC-25 MPC-26 abors 22E 3bors 22E MPC-28 3508 4941 8595 4704 5405 2020'FNL, 2289'FEL, Sec 36,T12N, R16E -- --- ---- 348'NSL, 705'WEL, Sec 18,T10N, R14E 63'FSL, 899'FEL, Sec 18,T10N, R15E 1585'NSL, 5187WEL, See 13,T10N, R14E 2829'NSL. 1611'WEL, See 9,T10N, R14E 2245'FSL, 5061' FEL, Sec. 29, T9N, R24E 3648'NSL,2100'WEL, Sec.03,T12NR11 E 1038 NSL, 2404 WEL, See 10,T13N, 1143'FNL, 2436'FWL, See 10,T13N, R10E 1086 NSL, 2419 WEL, See 10,T13N, Sec 10,T13N, R10E SCANNED NOV 1- 3 2002 25,228 31,195 3,723 4,002 4,137 3,974 5,786 19,608 2,060 1,905 5,228 425 Page 1 7,848 30,604 9,729 21,379 29,952 903 1,697 216 1,559 936 2,250 1,861 2,050 3,436 1,961 3,523 2,319 4,630 18,538 1,800 1,465 4,483 350 Cum Rig Wash 992 1,160 150 2,613 -- ------... - 1,063 2,009 134 820 1,141 380 1,100 200 3.035 137 50 464 1,156 285 130 300 555 Cum Compl Cum Form Cum Interm Cum Final Disposal Period Fluids Fluids Freeze Freeze Start End 1,176 2,283 1,904 800 2,565 1,100 1,871 1,535 200 120 10 685 r~h=Gt:i\lED DEe 1 4 1998 120 1215/95 120 9/30/95 8/31/95 12/5/96 12/31/95 12/31/95 Annulus Status Open Open Broached 60 12/5/95 12/5/96 Open 60 7/25/95 12/31/95 Open -"--- -- ---- ------" --------..- 51 4/4/96 12/31/95 Open _0_------ ..- 90 11/7/95 66 12/21/95 --- 65 2/21/96 150 7/25/95 171 7/26/95 150 8/24/95 120 9/28/95 150 9/1/95 120 10/13/95 150 10/26/95 120 8/17/95 1/26/96 100 4/18/96 130 1/25/96 140 1/5/96 190 12/19/95 75 2115/96 ::\!gSK~ un & l:ýas Cons. Commis::Jr. Anchorage 4/4/97 12/21/96 2/21/97 12/31/95 12/31/95 12/31/95 12131/95 12/31/95 12/31/95 12131/95 12/31/95 1/26/97 4/18/97 1/25/97 1/5/97 12/19/96 2/15/97 Broached Open _._~"-----_.._. Open . 3648'NSL, 4956'WEL, See 22,T11N, R14E 3,002 --------------- 3829 4749' NSL. 5180' WEL, Sec. 22, T11 N, 1,882 ~4~__~__S_~.22~~~~~~ - ---- ----------- - 3,385 3667 4676' NSL, 5165' WEL, Sec. 22, T11 N, 4,669 3930 1499'SNL, 26'WEL, See 24,T11N, R14E 2,266 3680 3719'NSL, 64'WEL, See 24,T11N, R14E 6,086 3830 3632'NSL, 41'WEL, See 24,T11N, R14E 3,311 4140 3690'NSL, 56'WEL, See 24,T11N, R14E 5,215 Open Open Open Open ------- Open Open Open Open Closed -~ Open Open Open Open , Sha~d S~ice Drilling Annufar Injection Volumes July 25, 1995 until December 1998 . Cumulative Report Rig IniWell Nabors 22E MPF-06 Nabors 22E MPF-14 Nabors 22E MPF-70 Nabors 22E MPH-05 _._----------- Nabors 22E MPH-06 Nabors 22E MPI-07 Nabors 22E MPJ-13 Nabors 22Ë MPJ-16 Nabors 27E 8-24 Nabors 27E MPF-22 ----.---- --------- Nabors 27E MPF-25 _4_~ Nabors 27E MPF-37 ------ Nabors 27E MPF-38 --------~----- Nabors 27E MPF-45 Nabors 27E MPF-53 --~~- Nabors 27E MPF-61 Nabors 27E MPF-62 Nabors 27E MPF-69 _._- Nabors 27E MPF-78 Nabors 27E MPL-24 _._-~--- WOA 18E F-33 18E F-36 -- - --'----'--- Joyon 9 0-30 Joyon 9 0-31 )oyon 9 0-33 -Jabors 18E S-43 Surface Casing Depth 8766 6690 7919 5335 7304 2680 2835 3112 4080 8841 3405 6621 8561 6678 6750 6585 6059 5772 7085 6515 Legal Desc See 06,n3N, R10E ~-- . . Sec06,T13N, R10E UM - . -. - -. - 2189'NSL, 2591'WEL, See 6,T13N, R10E n_" -' 2882'NSL, 4028'WEL, See 34,T13N, R10E 2824'NSL, 4044'WEL, See 34,T13N, R10E . -.-_0-,---- -. . ---- ._.-_4- -.. - - - -- . - - 2339'NSL, 3906'WEL, See 33,T13N, R10E . . - . - - . -. - - - uo 2319'NSL, 3179'WEL, See 28,T13N, R10E --------""------ 2317'NSL, 3336'WEL, See 28,T13N, R10E --~---_. .____--0-- ----... - See 18,T13N, R11E UM See 06,T13N, R10E UM 1857'NSL, 2696'WEL, Sec6,T13N, R10E 1931'NSL, 2643'WEL, See 6,T13N, R10E 1994'NSL, 2731'WEL, See 6,T13N, R10E ----~ 1979'NSL, 2608'WEL, Sec 6,T13N,R10E 2028'NSL, 2572'WEL, Sec 6,T13N, R10E 2077'NSL, 526'WEL, See 31,T14N, RWE 2141'NSL, 2627'WEL, Sec 6,T13N, R10E 2125'NSL, 2502'WEL, Sec 6,T13N, R10E 2237'NSL, 2555'WEL, See 6,T13N, R10E 3654'NSL, 5180'WEL, Sec 8,T13N, R10E Cum Mud Cum Total & Ctgs 1,927 1,731 18,717 19,775 8,283 8,515 - --.- -- 1,680 --"---- --- 14,127 985 1.468 9,897 7,032 9,232 17 ,562 6,051 5,732 386 9,740 8,476 6,790 17,107 18,794 7,711 8,335 1,280 13,292 915 1,396 6.466 9,357 6,887 9,157 17,381 5,671 5,657 316 9,665 7,456 4,900 3570 3691 3456' 3215 3222 3121' 3332'NSL, 2174'WEL, Sec 2,T11N, R13E 2642'NSL, 2878'WEL, Sec 2,T11N, R13E 3625' NSL, 1066' WEL, SEC. 23, T11N, SEC.26,T11N,R13E 2965' NSL, 1067' WEL, SEC. 23, T11 N, 4211'NSL,4503'WEL,SEC35, T12N, R12E 1.468 6,963 5,261 150 4,661 5,943 183 1,998 2,811 2.425 2,636 Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Wash Fluids Fluids Freeze Freeze Start End 196 1/25/96 1/25/97 . ~- ----"- 1,270 735 382 40 1,320 660 1,359 1,275 2,106 1,716 250 190 340 6/3/96 56 6/17/96 190 8/19/95 ---- 180 8/5/95 80 70 9/21/95 225 65 335 - -----. ----.--- - -- -- ---- - - 60 130 10/17/95 ----- - -.- - - 70 11/12/95 6/3/97 6/17/97 12/31/95 12/31/95 12/31/95 12/31/95 12/31/95 1/25/97 12/12/96 12/31/95 2/21/97 1/31/97 Annulus Status Open Open Open Open Open Open ---- .~ Open 75 8/31/95 12/31/95 Open ------------- 140 9/12/95 12/31/95 Open 70 11/27/95 12/31/95 Open --------------- -------- Open --- ---------- Open Open Open . .--.----- - 65 12/26/95 12/26/96 Open 75 7/25/95 12/31/95 Open ----~----- 75 12/6/95 12/31/95 Open -~~------ ----- --------- - ----.-- 181 7/31/95 12/31/95 Open 80 8/19/95 12/31/95 Open ---------- ------.--- ------ 75 8/31/95 12/31/95 Open 130 2/21/96 80 5/7/97 Open --. 160 2/21/96 135 12/18/95 12/18/96 Open - -----_.~-------~---- Open ~ AlatIl3011 & Gas Con.. COffi¡j'~S~;~n AnchCta~o 645 72 250 70 165 75 775 165 465 3.471 1,035 1,511 1/25/96 70 12/12/95 60 70 10/13/95 140 1/31/96 150 4/20/96 ~0.~ Open- Open OPEN 2/21/97 5/7/98 Page 2 f,~t.;t,vEO DEt 1 4 199a Shar.ed ~êi\rice Ddllin9 Annutã"r Injection Volumes July 25, 199!¡ until December 1998 Cumulative Report Rig Nabors 28E Nabors 28E Nabors 28E Nabors 28E InjWell B-33 E-34 E-36 E-37 Surface Casing Depth 3504' 3664 3648 3810 Nabors 28E Nabors 28E --------- ----_._----~--~---------- 3638 3509 Nabors 28E Nabors 28E Nabors 28E ---~-- Nabors 28E Nabors 28E ------- Nabors 2ES Nabors 2E8 E-39 G-04A G-21 8-24 S-33 S-41 S-42 H-35 H-36 3509 2750 2958 3331 3077 3157 --'-'-~-----_.- 3550 Cum Mud Legal Desc Cum Tot~! & Ctgs 969'SNL, 1898'EWL, Sec 31, TUN, R14E 3,974 2,842 - - - - - - .--_u--- .--" 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 ------ --- --~ --- - - - . - - ------_.~~- ---- 1706'SNL, 822'WEL, See 6, T11 N, R 14E 9,271 -- -'- -- .~---- 3391'NSL, 881'WEL, Sec6,T11N, R14E 4,695 3358'NSL, 501 'WEl, See 6,T11 N. R 14E 2,250 -.. .-- - ---. - --- -- - --- - - - ----------~---- 2917'NSL, 1974'WEL, See 12,T11N, R13E 5,937 ----------. ---- --- .-- -,.-- ----.'----- -- --------------------- 2911'NSl, 2368'WEl, See 12,T11N, R14E 11,430 - .--------------- 1633'SNL, 4228'WEL, See 35,T12N. R12E 20,261 - --------~~----~-----------~ 1639'SNL, 1487'WEL, See 35,T12N, R12E 18,014 4152' NSl, 4504' WEl, See 35,T12N, 8,062 -- ----------------~- Sec 35, T12N, R12E 168 4535'NSl, 1266'WEL, See 21, T11 N, R 13E 4,860 4478'NSl, 1265'WEl, See 21,T11N, R13E 1.452 7,228 4,417 4,241 928 1,798 3,956 11,773 6,613 4,159 100 Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Wash Auids Fluids Freeze Freeze Start End 857 195 80 5/1/96 12131/96 Annulus Status Broached 1 ,420 1,293 374 220 ------ 1,022 2,315 -----~-_._-- 4,270 5,751 - ---- - ~- --~- 858 3,096 40 110 8/23/95 12131/95 Open 365 100 7/25/95 12/31/95 Open u__._-----~.~----~~~~~_5 ----~.~--- Ope!:!.--- 80 8/28/95 12/31/95 Open 10/20/95 12/31/95 Open .. _____n~-~ . 9/8/95 12/3Y9~_._____~pe~._~.. 555 100 1,824 3,072 2,177 -. -------- 2,431 8,392 2,034 1,754 ------------- 275 270 285 12/9/95 308 12/1195 12/9/~~...n ~e':'H 12/1196 Open Open 3,725 857 ------ 2/8/97 3/13/97 Open Open 115 2/8/96 68 3/13/96 -------- ----"- 480 410 20 80 10/26/95 12/31/95 ---~--_.--- 85 10/26/95 12131/95 Open --~--~----~---- Page 3 t..:.~ \;.~ ...~~\rì~D.' l u \>." - 1to...J- J V i....- DEt 1 it 199a ,,,,,I.' .J" ~ ",a>; 1,;00s. comm\~r'_:r- '\nchOrSfJ° ~ ~ ,,--.. ..- . . '- ~ 'hi d = ~..:- ¡ ~Y-ì r. ".. S.. . . . !" ......... I I ~ ; t-' ¡ ,~ . ,..i .! a.; -..- . Q, rv- Ice- s- " . ~.- '. : ". .. .' . -: ::..": . - -:.. .. ..... .. - ..-- - - >-- riJlling TO: FROM: DATE: SUBJECT: Blair Wondzell Chris West October 27, 1995 MPB-24 Well Suspension API # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. ' We would . like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. ' Thank you for your help in this matter. Please call me if I may be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 ,._~ . . .~. -t¡ ,", b' \i.'t. t~;-.;; I', .~ ~:~E\..ßt~ V i-~ DEt 1 1\ '\998 .. .,.._~ '~.- ,~ . :~~-:'., ~:,,-;; ;¡:~,.., ::. "\I \~: t.J -. .. .'t<I~I\!")~~ ~'...r; 0, H. {:~"'~ COf¡~. (jC\1i~'~.';;';"'''''' Nô$"'?' \\ 0 ~~.., r". ",~chcra2" SCANNED NOV 1 3 2002 , ' . \. ~. ",'., I~" '.. \ \ ~ ... '.., \., . PERMIT 96-016 96-016 96-016 96-016 96-016 96-016 96-016 96-016 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS 7062 GR/CCL PLS - STATIC RES/GR MD GR/CND/SLD MD ~/GR ~EPIA ~Oi~0 - ! ~ ~. ~'~ ..... q~'112-10850 ~'~'112-10850 GR/CNP/SLD TVD L'/i12-9362 7529 &~SPERRY GR/RES/CNP/SLD Page: 1 Date: 06/09/98 RUN RECVD 04/09/96 1 03/20/96 1 03/20/96 FINAL 11/04/96 FINAL 11/04/96 FINAL 11/04/96 FINAL 11/04/96 1-3 11/20/96 10-407 ~R-~COMPLETION DATE ~ /k /.~.~ / DAILY WELL OPS R ~/k/q~/ TO ,~/5 /~/ Are dry ditch samples required? yes ~~d received? Was the well cored? yes ~.~Analysis & description received? Are well tests required? yes ~..-Received? qz~s-__~kQ~.- Well is in compliance ~ Initial COMMENTS WEI,L LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Dr. C(~ ©\ I'D Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs - MPC-23 AK-MM-960206 November 15, 1996 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted LIS tape with verification listing. API#: 50-029-22643-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9¢7) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company r'l I::t I I_1_ I IM G S I::: I::1 ~./I 1-- I::: S WELL LOG TRANSMITTAL To: State of Alaska October 28, 1996 Alaska Oil and Gas Conservation Comm. Attn.' Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPC-23, AK-MM-960206 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" MD Resistivity and Gamma Ray Logs: 2"x 5" TVD Resistivity and Gamma Ray Logs: 2"x 5" MD Neutron Porosity and Density Logs: 2" x 5" TVD Neutron Porosity and Density Logs: 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALASr, J-~ OIL AND GAS CONSERVATION CL)MMISSION 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. 96-016 8. APl Number 3. Address . P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22643 4. Location of well at surface ! - Ciii'd~::i".?:'i:'!i~i'i~- i 9. Unit or Lease Name 1038' NSL, 2404' WEL, SEC. 10, T13N, R10i:~. ;,,,,~.< ~ r,':. ;i:; i .!~ !,'_;'~.:¥~";'.~i':~:~.:~:;'.~'~' Milne Point Unit Attop of productive interval i ~__/'.~./'~__~.,~ 10. Well Number MPC-23 At total depth R10E ............. ~ 11 2863' NSL, 1459' WEL, SEC. 9, T13N, Milne Point 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Seriak'No: KBE = 47.5'I ADL 047434 12. Date Spudded02/03/96 113' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'115' Water depth' if °fish°re I16' N°' °f C°mpleti°ns02/12/96 06/02/96 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 20. Depth where SSSV set~l. Thickness of Permafrost 10850 9362 FT~ 10689 9216 F'~ [] Yes [] No N/A MD ! 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD, EMSS, CDL/CNL/DLL/MLL/GR 123. CASING, LINER AND CEMENTING RECORD CASING SE'FrING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arctic Set I (Approx.) 9-5/8" 40# L-80 31' 4941' 12-1/4" 963 sx PF 'E', 250 sx 'G', 114 sx PF 'E' 7" 26# L-80 29' 10777' 8-1/2" 600 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. " TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 2-7/8", L-80 9990' N/A M D TVD M D TVD 10190'-10247' 8768'-8818' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect w/63 bbls diesel 10190'-10247' Frac'd w/146000# 20/40 Carbolite behind pipe 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) June 10, 1996 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD · I Flow Tubing Casing PressureCALCULATED . OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (COBB) iPress. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .R c IV[DoRiGINAL 0CT Z 4 1996 Alaska 0il & 6as Cons. Oommission Anchorc. g0 Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Mark,,.,s 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) Top Sag River 10142' 8681' Top Shublik 10238' 8766' Top Eileen 10452' 8957' Top Ivishak 10503' 9003' · 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that ?~_/'~ the fore. going is trufl and col'r~ctto the best of my knowledge Signed Tim Schofield Title Senior Drilling Engineer Date Prepared By Name/Number: Kathy Campoamor, 564-5122 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 · SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M P C- 2 3 Rig Name: N - 2 2 E AFE: 3 3 7 01 6 Accept Date: 02/02/96 Spud Date: 02/03/96 Release Date: 02/1 6/96 Feb 2 1996 (1) RD service lines. Held safety meeting. Rig moved 50 %. Held safety meeting. Rig moved 55 %. RU divertor. Rig moved 60 %. Rig moved 85 %. Rig moved 100 %. Feb 3 1996 (2) Held safety meeting. RU lines/cables. RD additional services. RU divertor. Held safety meeting. RU drillfloor / derrick. RU divertor. Held safety meeting. Test divertor. MU BHA #1. Held safety meeting. MU BHA #1. Cleared Standpipe manifold. Functioned downhole tools at 112 ft. Drilled to 297 ft.' MU BHA #1. Feb 4 1996 (3) MU BHA #1. Held safety meeting. Drilled to 2511 ft. Flow check. POOH to 266 ft. RIH to 2511 ft. Drilled to 3350 ft. Held drill (Kick while drilling). Drilled to 3470 ft. Feb 5 1996 (4) Held safety meeting. Serviced mud pumps. Drilled to 3751 ft. Took MWD survey at 3751 ft. POOH to 2419 ft. Held drill (Kick while tripping). RIH to 2750 ft. Reamed to 3185 ft. RIH to 3751 ft. Serviced mud pumps. Drilled to 4039 ft. Held safety meeting. Drilled to 4960 ft. Held drill (Fire). Circulated at 4960 ft. Flow check. POOH to 266 ft. Serviced top drive. Feb 6 1996 (5) Held safety meeting. RIH to 4960 ft. Circulated at 4960 ft. Flow check. POOH to 2500 ft. Held drill (H2S). POOH to 266 ft. Pulled BHA. RU casing handling equipment. Held safety meeting. Ran casing to 4941 ft (9.625 in OD). RD handling equipment. Circulated at 4941 ft. Mixed and pumped slurry - 426 bbl. Mixed and pumped slurry - 44 bbl. Serviced casing handling equipment. RD down Divertor. Page Feb 7 1996 (6) RD Divertor. Installed wellhead primary components. RU BOP stack. Tested BOP stack. Repaired choke manifold. Held safety meeting. Repaired choke manifold. Tested choke manifold. Installed wellhead integral components. MU BHA #2. Repaired MWD tool. MU BHA #2. Serviced block line. RIH to 2500 ft. Feb 8 1996 (7) .. RIH to 4855 ft. Held drill (Kick while drilling). Serviced top drive. Circulated at 4855 ft. Tested casing. Drilled installed equipment - Float collar. Circulated at 4870 ft. Performed formation integrity test, 12.5 ppg EMW. Drilled to 6830 ft. Circulated at 6830 ft. Pumped out of hole to 4900 ft. RIH to 6830 ft. Held drill (Fire). Drilled to 7307 ft. Feb 9 1996 (8) Drilled to 7622 ft. Circulated at 7622 ft. POOH to 6700 ft. RIH to 7622 ft. Drilled to 8923 ft. Circulated at 8623 ft. POOH to 7594 ft. RIH to 8923 ft. Drilled to 9020 ft. Feb 10 1996 (9) Held safety meeting. Drilled to 10053 ft. Circulated at 10053 ft. RIH to 10053 ft. Drilled to 10338 ft. POOH to 8735 ft. Feb 11 1996 (10) Held safety meeting. Held drill (Spill). Drilled to 10552 ft. Circulated at 10522 ft. Repaired top drive. POOH to 9700 ft. RIH to 10522 ft. Circulated at 10522 ft. POOH to 256 ft. Downloaded MWD tool. MU BHA #3. R.I.H. to 1100 ft. Feb 12 1996 (11) Held safety meeting.' Held drill (Fire). Serviced Block line. RIH to 10490 ft. Reamed to 10552 ft. Drilled to 10850 ft. Circulated at 10850 ft. Pumped out of hole to 8100 ft. Page 2 RECEIVED OCT ~ 4 199G Alaska 0il & (~:.~s Cor~s. Commission Anohorago Feb 13 1996 (12) Held safety meeting. Held drill (Kick while tripping). POOH to 8100 ft. RIH to 10790 ft. Reamed to 10850 ft. Circulated at 10850 ft. Dropped EMSS survey barrel. POOH to 233 ft. Pulled BHA. Ran electric logs. MU BHA #4. RIH to 4900 ft. Circulated at 4900 ft. RIH to 8000 ft. Feb 14 1996 (13) Held safety meeting. Held drill (H2S). RIH to 10850 ft. Circulated at 10850 ft. Flow check. POOH to 4960 ft. Flow check. RIH to 10850 ft. Circulated at 10850 ft. Pumped out of hole to 9440 ft. POOH to 4940 ft. Flow check. POOH to 4000 ft. Feb 15 1996 (14) Held safety meeting. Held drill (H2S). POOH to 1016 ft. Pulled BHA. RU top ram. RU casing handling equipment. Held safety meeting. Ran casing to 10777 ft (7 in OD). Circulated at 10776 ft. Mixed and pumped slurry-123 bbl. Feb 16 1996 (15) Held safety meeting. Held drill (Spill). Tested casing. RD casing handling equipment. Installed wellhead integral components. RD BOP stack. Installed all tree valves. Serviced block line. Laid down drillpipe of 0 ft. Freeze protect well - 70 bbl of diesel. Page SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M PC-23 Rig Name: N-4ES AFE: 33701 6 Accept Date: 05/29/96 Spud Date: Release Date: 06/02/96 May 30 1996 Scope & lower derrick. MIRU. Lay herculite & spot rig. Raise & scope derrick. Rig accepted 05/29/96 @ 1500 hrs. Rig lines to tree. Test casing. ND tree & NU BOPE. Test BOPE. Test witnessed by Lou Grimaldi. Install WB. MU RBP retrieving tool & RIH with 3-1/2" drillpipe. SLM & drift drillpipe. Slip drill line. Cont RIH with 3-1/2" drillpipe. · May 31 1996 Lube rig. RIH with 3-1/2" drillpipe & retrieving toll t/9882'. Condition brine in pits, viscosify fluid & adjust MW. Displace fluid in hole with conditioned fluid. Washed down hole & tagged RBP @ 9965'. Opened equalizer & release RBP. RIH with RBP t/9977'. Circ out gas & crude through choke. POOH with RBP. Plugged off, POOH wet. LD RBP. MU mill & space out scrapper. RIH with BHA #1 for cleanout. Jun 1 1996 Lube rig. Tagged fill @ 10031'. Rotate & wash sand f/10031' t/10277'. Hard packed sand. PU kelly, rotate 30' & reverse out sand. Reverse & wash f/10277' t/10689'. Reverse circ hole clean at 10689'. LD 13 jts of drillpipe t/10287'. Spot LCM pill across perfs. LD 11 jts drillpipe t/9948'. Mix new brine in pits. Reverse circ casing wash & displaced with clean brine. RU MI filtration unit. Filter brine in hole. Jun 2 1996 Cont reverse circ& filtering brine. NTU reading out of hole 78. Reverse circ 2 hole volumes. POOH laying down pipe & BHA. Pull WR. Set test plug. Change pipe rams to 2-7/8". Test rams, OK. Flushed BOPE & flowline. RU Centrilift equip. MU & service ESP. PU & run in hole with 2-7/8" ESP completion. Jun 3 1996 Cont picking up 2-7/8" ESP completion t/8000'. Make midline ESP cable splice. Finished picking up 2-7/8" completion. PU hanger & made ESP hanger splice. Landed hanger run in lock down screws & set TWC. ND BOP's & NU tree. Test tree & adapter. Test surface lines. Pull TWC & install BPV. Freeze protect well with 63 bbls diesel down annulus & 12 bbls diesel bullheaded down tubing. Secure well blow down lines & RD cellar equipment. Rig released 06/02/96 @ 2330 hrs. Page ! ANNULAR INJECTION DATA ENTRY SCREEN Asset .Mil~ ........................................ Legal Desc..1.Q3.8..~SL,..2.4.0.&..WE, L..Se.c...1.0,~.:I.2~,,..B.1.13.E ...................... Rig Name .blab.Q/.S..22.E ........................... · ...................................................................................................................... Inj Well Name .M..P..O.:.2`3 .................................. Permit Start ..... .1._/.2.,5.,/.9..6 ..... Permit End ..... .1._/.2..5.,/.9..7. ..... Sur Csg Dep ..4.9..4..1 ............... · ............................................................. Cumulative Data Rig Completion Formation Intermittant Final Well Total Mud/Ctcj Wash Fluids Fluids Freeze Freeze ..,....2.,~.6.0 ..... : .......... .1.~..8.0.0 ................... .1,2t~ ........................................................................................................... ,,..1.3.0....,..,. Daily Data ,.M,...P....c...-..~..,3. ............... .~.,.2_./..._!..._.6../..9_....~ ............................................................... ..1..,~..o_. .................................................................................................................................................................. .7,_..0,.. ................................ .2_,o._.o. .............o~p_ ............................................................................................................. ._M.._P_.C_.:.2_..8_ .......... _0_.2__ ./.._.2.... _0../_..9_..._6 ................ .!_..8....0,.....0.., ............................................................................................................................................................................................................................................ 6o 1,86o 0 ~_.n.. ...................................................................................................... ............... , · ANNULAR INJECTION DATA ENTRY SCREEN A s s e t .M. ilne. ........................................ Legal Desc ..1..1.~3:.E~L,...2..426.'.EWL,...Se.c....1..Q,.T.12rg.,...B..1,.QE ...................... Rig Name .[gab.or.s.22.E ........................... · ...................................................................................................................... Inj Well Name .M.P..C.=.2..5 .................................. Permit Start ....... .1.Z.5.Z.9.6 ...... Permit End ....... 1.Z.5.Z.9.Z ...... Sur Csg Dep .8.5.9.5 .............. · ............................................................. Cumulative Data Rig Completion Formation Intermittant Final Well Total Mud/Ctg Wash Fluids Fluids Freeze Freeze ...... ...1.,~9.Q5 ................ .1.~.4.6.5..., ..... ,.., ..... 3.0.Q .......................................................................................................... ,....1,4.Q.,...~ .... Daily Data ANNULAR INJECTION DATA ENTRY SCREEN Asset .M[IQe ........................................ Legal Desc..I.Q~6..~tSL,..2.4.~.~..~/F_L..Se.c...1.0.~'.:t3bL..IK1.13.E ...................... Rig Name .biab.Qr.s.22.E .......................... · ...................................................................................................................... Inj Well Name .ME.C.:2_6 .................................. Permit Start .... .~.2J...L9Lg.5... Permit End .... .l.2J...~.9.J..@.~... Sur Csg Dep ..4.7.Q~ .............. ' ............................................................. Cumulative Data Rig Completion Formation Intermittant Final Well Total Mud/Ctg Wash Fluids Fluids Freeze Freeze · ....... ~22,8,,, .... ,,,,,,.~.~.8.3.,~,... ........... 5.5.5, ......... . . ............................. .......... ,.1.9.~....,,:..,. Daily Data .H.?.~.:.~.~ ................... ~...!...(..~..6_.(.~..~ ............................................................................. !...~..~ ................................................................................................................................................................................................................................... ~_.~.~ ....................................................................................................................................................................................... MPC-26 01/07/96 230 230 ....... MPC-26 01/08/96 105 105 ,,, MPC-26 01/09/96 133 133 MPC-26 01/10/96 600 600 MPC-26 01/1 1/96 530 530 MPC-26 01/12/96 635 100 60 795 ...IPC-26 01/19/96 680 60 740 MPC-23 02/1 6/96 1,500 100 70 1,670 O~n ........ .S-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLOITATION MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/21/96 DATE OF SURVEY: 021296 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60022 KELLY BUSHING ELEV. = 45.00 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. 4866.30 4563.13 4518.13 4968.39 4640.71 4595.71 5063.12 4712.59 4667.~59 5158.36 4784.96 4739.96 5253.91 4857.75 4812.75 40 29 40 35 40 41 40 23 40 20 N 64.06 W .00 469.20N 1075.51W N 64.49 W .30 498.00N 1135.29W N 65.98 W 1.02 523.84N 1191.32W N 66.48 W .46 548.80N 1247.98W N 66.52 W .07 573.48N 1304.74W 1173.39 1239.69 1301.37 1363.27 1425.17 5349.45 4930.81 4885.81 5445.08 5004.60 4959.60 5540.82 5079.14 5034.14 5636.24 5153.20 5108.20 5731.45 5226.80 5181.80 39 53 39 7 38 36 39 33 39 10 N 66.94 W .56 597.80N 13~1.29W N 67.55 W .88 621.33N 1417.39W N 67.18 W .60 644.45N 1472.84W N 65.17 W 1.66 668.76N 1527.86W N 65.25 W .40 694.08N 1582.69W 1486.73 1547.56 1607.63 1667.78 1728.15 5827.09 5301.07 5256.07 5922.29 5375.03 5330.03 6017.73 5449.04 5404.04 6113.28 5523.09 5478.09 6209.04 5597.12 5552.12 38 55 39 7 39 9 39 14 39 30 N 66.08 W .61 718.91N 1637.59W N 65.85 W .27 743.33N 1692.34W N 66.02 W .12 767.90N 1747.36W N 65.85 W .13 792.53N 1802.50W N 65.55 W .35 817.52N 1857.86W 1788.40 1848.34 1908.59 1968.97 2029.71 6304.40 5670.56 5625.56 6400.06 5743.81 5698.81 6495.54 5816.30 5771.30 6591.00 5888.16 5843.16 6686.77 5959.76 5914.76 39 45 40 17 40 54 41 25 41 47 N 65.46 W .27 842.74N 1913.21W N 65.07 W .62 868.49N 1969.09W N 64.53 W .73 894.95N 2025.31W N 64.37 W .56 922.05N 2082.00W N 64.63 W .42 949.43N 2139.41W 2090.52 2152.02 2214.12 2276.91 2340.46 6781.98 6030.85 5985.85 6877.68 6102.16 6057.16 6973.35 6173.09 6128.09 7068.78 6244.14 6199.14 7163.98 6315.62 6270.62 41 36 42 1 42 16 41 29 41 10 N 66.25 W 1.15 975.75N 2197.01W N 65.98 W .47 1001.59N 2255.36W N 66.20 W .29 1027.60N 2314.06W N 65.23 W 1.06 1053.80N 2372.13W N 68.10 W 2.02 1078.70N 2429.84W 2403.78 2467.59 2531.79 2595.49 2658.34 7259.63 6388.24 6343.24 7355.65 6461.82 6416.82 7451.12 6535.85 6490.85 7544.42 6609.10 6564.10 7640.06 6684.22 6639.22 4O 1 39 56 38 21 38 10 38 18 N 69.74 W 1.63 1101.09N 2487.91W N 69.63 W .12 1122.51N 2545.77W N 71.06 W 1.91 1142.79N 2602.52W N 70.97 W .20 1161.59N 2657.16W N 71.02 W .14 1180.87N 2713.13W 2720.53 2782.15 2842.29 2899.91 2958.95 7735.91 6759.57 6714.57 7831.50 6835.02 6790.02 7926.24 6910.03 6865.03 8021.88 6985.73 6940.73 8117.20 7060.90 7015.90 38 1 37 44 37 34 37 47 38 5 N 71.23 W .33 1200.03N 2769.18W N 70.28 W .68 1219.37N 2824.59W N 69.92 W .29 1239.06N 2879.01W N 69.92 W .24 1259.14N 2933.91W N 69.99 W .31 1279.22N 2988.97W 3018.01 3076.55 3134.32 3192.69 3251.20 SI .... f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/21/96 DATE OF SURVEY: 021296 ELECTRONIC MULTI-SHOT SURVEY JOB N-UMBER: AK-EI-60022 KELLY BUSHING ELEV. = 45.00 FT. OPERATOR: BP EXPLORATION JTRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 8212.73 7136.25 7091.25 37 46 N 68.17 W 1.22 1300.18N 3043.81W 3309.86 8307.97 7211.65 7166.65 37 33 N 67.51 W .48 1322.13N 3097.70W 3368.04 8402.83 7287.21 7242.21 36 50 N 64.65 W 1.97 1345.36N 3150.11W 3425.37 8497.83 7363.32 7318.32 36 40 N 63.79 W .57 1370.09N 3201.31W 3482.16 8591.78 7438.81 7393.81 36 23 N 63.58 W .34 1394.88N 3251.44W 3538.01 8686.98 7515.01 7470.01 37 16 N 62.87 W 1.04 1420.58N 33~2.39W 3594.97 8782.08 7590.93 7545.93 36 47 N 63.13 W .54 1446.58N 3353.42W 3652.12 8876.95 7666.53 7621.53 37 34 N 67.19 W 2.72 1470.63N 3405.43W 3709.40 8972.49 7742.38 7697.38 37 19 N 67.41 W .29 1493.05N 3459.02W 3767.49 9065.26 7815.65 7770.65 38 19 N 65.68 W 1.57 1515.70N 3511.20W 3824.38 9160.46 7890.22 7845.22 38 31 N 66.08 W .34 1539.88N 3565.21W 3883.54 9255.69 7964.73 7919.73 38 30 N 66.47 W .26 1563.74N 3619.50W 3942.85 9349.12 8037.91 7992.91 38 21 N 66.89 W .32 1586.73N 3672.84W 4000.93 9443.07 8112.87 8067.87 35 46 N 66.62 W 2.75 1609.08N 3724.88W 4057.56 9537.45 8190.46 8145.46 33 34 N 68.27 W 2.53 1629.69N 3774.45W 4111.25 9632.37 8270.56 8225.56 31 20 N 72.08 W 3.20 1647.00N 3822.34W 4162.07 9727.28 8352.67 8307.67 28 51 N 70.32 W 2.77 1662.31N 3867.39W 4209.51 9819.95 8434.73 8389.73 26 27 N 72.26 W 2.76 1676.14N 3908.11W 4252.38 9912.75 8517.79 8472.79 26 30 N 69.82 W 1.17 1689.58N 3947.24W 4293.63 10007.32 8602.39 8557.39 26 36 N 70.55 W .36 1703.91N 3987.01W 4335.83 10043.37 8634.58 8589.58 26 54 N 69.05 W 2.06 1709.52N 4002.24W 4352.04 10102.36 8687.07 8642.07 27 21 N 68.33 W .95 1719.29N 4027.30W 4378.93 10197.54 8771.51 8726.51 27 36 N 67.94 W .31 1735.65N 4068.07W 4422.84 10290.44 8854.00 8809.00 27 9 N 69.91 W 1.09 1751.02N 4107.93W 4465.52 10386.30 8939.67 8894.67 26 10 N 72.07 W 1.44 1765.04N 4148.58W 4508.41 10478.31 9022.33 8977.33 25 56 N 69.50 W 1.25 1778.33N 4186.74W 4548.72 10515.63 9055.89 9010.89 25 54 N 69.65 W .20 1784.03N 4202.03W 4565.01 10573.45 9107.91 9062.91 25 52 N 69.71 W .09 1792.79N 4225.71W 4590.22 10668.00 9193.14 9148.14 25 25 N 69.68 W .47 1806.99N 4264.08W 4631.09 10728.00 9247.46 9202.46 24 51 N 69.63 W .95 1815.86N 4287.98W 4656.54 10850.00 9358.16 9313.16 24 51 N 69.63 W .00 1833.70N 4336.04W 4707.75 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4707.84 FEET AT NORTH 67 DEG. 4 MIN. WEST AT MD = 10850 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 293.28 DEG. TIE IN POINT 4866.3' INTERPOLATED DEPTH 10850' °f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/21/96 DATE OF SURVEY: 021296 JOB NUMBER: AK-EI-60022 KELLY BUSHING ELEV. = 45.00 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 4866.30 4563.13 4518.13 5866.30 5331.58 5286.58 6866.30 6093.71 6048.71 7866.30 6862.54 6817.54 8866.30 7658.08 7613.08 469.20 N 1075.51 W 303.17 728.90 N 1660.11 W 534.72 231.55 998.49 N 2248.40 W 772.59 237.87 1226.55 N 2844.64 W 1003.75 231.17 -- 1468.10 N 3399.46 W 1208.22 204.47 9866.30 8476.22 8431.22 10850.00 9358.16 9313.16 1682.43 N 3927.78 W 1390.08 181.86 1833.70 N 4336.04 W 1491.84 101.76 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~ .... ~-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/21/96 DATE OF SURVEY: 021296 JOB NUMBER: AK-EI-60022 KELLY BUSHING ELEV. = 45.00 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 4866.30 4563.13 4518.13 4974.04 4645.00 4600.00 5105.87 4745.00 4700.00 5237.18 4845.00 4800.00 469.20 N 1075.51 W 499.58 N 1138.61 W 535.19 N 1216.78 W 569.17 N 1294.80 W 303.17 329.04 25.87 360.87 31.83 392.18 31.31 5367.94 4945.00 4900.00 5497.11 5045.00 5000.00 5625.60 5145.00 5100.00 5754.92 5245.00 5200.00 5883.58 5345.00 5300.00 602.44 N 1372.20 W 633.88 N 1447.68 W 665.91 N 1521.71 W 700.29 N 1596.16 W 733.34 N 1670.05 W 422.94 30.76 452.11 29.18 480.60 28.49 509.92 29.32 538.58 28.66 6012.51 5445.00 5400.00 6141.57 5545.00 5500.00 6271.15 5645.00 5600.00 6401.62 5745.00 5700.00 6533.52 5845.00 5800.00 766.56 N 1744.35 W 799.85 N 1818.83 W 833.91 N 1893.87 W 868.91 N 1970.01 W 905.65 N 2047.77 W 567.51 28.93 596.57 29.05 626.15 29.59 656.62 30.47 688.52 31.90 6666.97 5945.00 5900.00 6800.91 6045.00 6000.00 6935.39 6145.00 6100.00 7069.93 6245.00 6200.00 7203.01 6345.00 6300.00 943.77 N 2127.48 W 980.82 N 2208.52 W 1017.30 N 2290.69 W 1054.12 N 2372.82 W 1088.28 N 2453.68 W 721.97 33.45 755.91 33.95 790.39 34.47 824.93 34.54 858.01 33.08 7333.72 6445.00 6400.00 7462.79 6545.00 6500.00 7590.09 6645.00 6600.00 7717.41 6745.00 6700.00 7844.11 6845.00 6800.00 1117.61 N 2532.57 W 1145.14 N 2609.37 W 1170.79 N 2683.85 W 1196.36 N 2758.39 W 1221.97 N 2831.86 W 888.72 30.71 917.79 29.07 945.09 27.30 972.41 27.32 999.11 26.71 7970.36 6945.00 6900.00 8097.00 7045.00 7000.00 8223.79 7145.00 7100.00 8350.02 7245.00 7200.00 8474.99 7345.00 7300.00 1248.30 N 2904.28 W 1274.96 N 2977.26 W 1302.70 N 3050.10 W 1331.98 N 3121.34 W 1364.06 N 3189.07 W 1025.36 26.25 1052.00 26.64 1078.79 26.80 1105.02 26.22 1129.99 24.97 8599.47 7445.00 7400.00 8724.67 7545.00 7500.00 8849.84 7645.00 7600.00 8975.79 7745.00 7700.00 9102.68 7845.00 7800.00 1396.91 N 3255.52 W 1430.99 N 3322.70 W 1464.08 N 3390.30 W 1493.82 N 3460.87 W 1525.26 N 3532.35 W 1154.47 24.48 1179.67 25.20 1204.84 25.17 1230.79 25.95 1257.68 26.88 9230.48 7945.00 7900.00 1557.48 N 3605.11 W 1285.48 27.80 S~ .... Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/21/96 DATE OF SURVEY: 021296 JOB NUMBER: AK-EI-60022 KELLY BUSHING ELEV. = 45.00 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 9358.13 8045.00 8000.00 1588.92 N 3677.95 W 1313.13 27.65 9482.68 8145.00 8100.00 1618.27 N 3746.14 W 1337.68 24.55 9602.33 8245.00 8200.00 1641.97 N 3807.37 W 1357.33 19.65 9718.50 8345.00 8300.00 1660.89 N 3863.36 W 1373.50 16.17 -- 9831.42 8445.00 8400.00 1677.69 N 3912.98 W 1386.42 12.92 9943.15 8545.00 8500.00 1694.26 N 3959.97 W 1398.15 11.73 10055.06 8645.00 8600.00 1711.41 N 4007.18 W 1410.06 11.91 10167.62 8745.00 8700.00 1730.44 N 4055.22 W 1422.62 12.56 . 10280.32 8845.00 8800.00 1749.43 N 4103.59 W 1435.32 12.70 10392.24 8945.00 8900.00 1765.84 N 4151.08 W 1447.24 11.92 10503.52 9045.00 9000.00 1782.19 N 4197.07 W 1458.52 11.28 10614.66 9145.00 9100.00 1799.03 N 4242.56 W 1469.66 11.14 10725.29 9245.00 9200.00 1815.46 N 4286.91 W 1480.29 10.63 10835.49 9345.00 9300.00 1831.58 N 4330.33 W 1490.49 10.20 10850.00 9358.16 9313.16 1833.70 N 4336.04 W 1491.84 1.34 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS S,- ,~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA BP EXPLORATION (ALASKA) INC. MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/20/96 DATE OF SURVEY: 021296 MWD SURVEY JOB NUMBER: AK-MM-960206 KELLY BUSHING ELEV. = 45.00 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 -45.00 175.66 175.66 130.66 260.85 260.85 215.85 350.32 350.29 305.29 441.59 441.47 396.47 0 0 N .00 E .00 .00N 0 9 S 25.22 W .09 .21S 0 38 S 52.59 W .60 .60S 1 43 S 83.48 W 1.36 1.05S 3 13 N 85.83 W 1.71 1.02S · 00E · i0W · 52W · 25W · 17W .00 .01 .24 1.65 5.26 532.54 532.24 487.24 624.99 624.45 579.45 716.04 715.17 670.17 807.23 805.87 760.87 897.90 895.91 850.91 3 54 N 77.05 W .96 .14S 4 22 N 75.76 W .52 1.43N 5 24 N 71.56 W 1.21 3.64N 6 24 N 64.03 W 1.38 7.22N 7 4 N 62.41 W .78 12.02N 1~_ 18 25 34 43 .73W · 21W · 65W .29W .79W 10.72 17.29 25.00 34.36 44.98 988.21 985.43 940.43 1083.47 1079.51 1034.51 1178.32 1172.91 1127.91 1273.44 1266.74 1221.74 1368.95 1361.37 1316.37 8 6 N 62.08 W 1.13 17.58N 9 49 N 58.67 W 1.90 24.95N 10 15 N 51.94 W 1.32 34.37N 8 31 N 51.02 W 1.84 44.02N 7 1 N 48.80 W 1.60 52.32N 54 67 8O 92 102 .34W · 22W · 79W .93W · 82W 56.87 71.61 87.79 102.77 115.13 1464.38 1456.20 1411.20 1559.85 1551.29 1506.29 1655.52 1646.78 1601.78 1751.03 1742.22 1697.22 1846.05 1837.22 1792.22 5 46 N 52.89 W 1.39 59.05N 4 15 N 58.13 W 1.65 63.82N 2 42 N 56.08 W 1.64 66.96N 1 23 N 64.88 W 1.41 68.70N 1 8 N 74.25 W .34 69.45N 111 117 122 125 127 · 04W .88W .76W .68W .63W 125.34 133.50 139.23 142.60 144.69 1941.71 1932.86 1887.86 2036.84 2027.97 1982.97 2132.29 2123.41 2078.41 2227.69 2218.81 2173.81 2323.30 2314.42 2269.42 1 2 N 74.84 W .09 69.94N 1 16 N 75.88 W .24 70.42N 0 18 N 82.33 W 1.02 70.72N 0 15 S 64.39 E .58 70.66N 0 9 S 78.36 E .12 70.55N 129 131 132 132 132 .39W ·27W .56W · 62W .31W 146.50 148.41 149.71 149.75 149.42 2418.73 2409.85 2364.85 2513.76 2504.87 2459.87 2609.83 2600.86 2555.86 2705.50 2696.17 2651.17 2801.83 2791.63 2746.63 0 13 S 83.72 E .08 70.50N 0 44 N 87.06 W 1.02 70.51N 3 34 N 84.01 W 2.95 70.85N 6 18 N 79.79 W 2.88 72.10N 9 3 N 76.30 W 2.90 74.83N 132 132 136 144 156 .00W · 42W · 02W · 15W · 72W 149.12 149.51 152.95 160.91 173.54 2896.87 2885.12 2840.12 2992.52 2978.46 2933.46 3088.05 3070.83 3025.83 3183.64 3162.30 3117.30 3278.42 3251.87 3206.87 11 30 N 73.09 W 2.64 79.36N 13 40 N 68.72 W 2.48 86.23N 15 47 N 68.26 W 2.22 95.14N 17 53 N 71.56 W 2.42 104.61N 20 13 N 70.92 W 2.47 114.57N 173.06W 192.71W 215.30W 241.32W 270.62W 190.33 211.10 235.38 263.02 293.87 RECEIVED OCT 2_. 4 1996 Alaska Oil & e,~s Con~, Commission Anchora?, ~IY-SUN DRILLING SERVICES ANCFIORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC. MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/20/96 DATE OF SURVEY: 021296 MWD SURVEY JOB NUMBER: AK-MM-960206 KELLY BUSHING ELEV. = 45.00 OPERATOR: BP EXPLORATION 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. 3374.05 3340.97 3295.97 3470.65 3429.59 3384.59 3566.23 3515.81 3470.81 3658.51 3597.69 3552.69 3754.90 3681.45 3636.45 22 17 N 69.74 W 2.21 126.26N 303.27W 24 32 N 69.04 W 2.35 139.78N 339.20W 26 32 N 67.46 W 2.21 155.08N 377.48W 28 21 N 69.24 W 2.15 170.75N 417.02W 30 54 N 68.76 W 2.66 187.83N 461.50W 328.48 366.83 408.03 450.55 498.16 3851.18 3762.83 3717.83 3946.75 3841.23 3796.23 4041.49 3917.44 3872.44 4137.10 3994.04 3949.04 4232.63 4070.53 4025.53 33 40 N 67.21 W 3.00 207.14N 509.17W 36 2 N 65.59 W 2.66 229.02N 559.21W 36 49 N 65.60 W .82 252.27N 610.45W 36 41 N 65.71 W .16 275.86N 662.59W 36 54 N 66.10 W .34 299.22N 714.82W 549.58 604.20 660.46 717.67 774.89 4327.99 4146.27 4101.27 4423.29 4220.80 4175.80 4518.18 4294.54 4249.54 4613.21 4368.76 4323.76 4707.32 4441.82 4396.82 37 55 N 65.27 W 1.19 323.09N 767.62W 39 9 N 64.83 W 1.32 348.14N 821.46W 38 50 N 63.45 W .98 374.18N 875.19W 38 27 N 64.08 W .58 400.41N 928.43W 39 42 N 65.91 W 1.81 425.47N 982.18W 832.82 892.17 951.83 1011.09 1070.37 4802.54 4514.52 4469.52 4866.30 4562.91 4517.91 5003.49 4667.12 4622.12 5098.14 4739.11 4694.11 5193.33 4811.73 4766.73 40 45 N 64.79 W 1.34 451.12N 1038.06W 40 29 N 64.06 W .85 469.04N 1075.50W 40 39 N 65.72 W .80 506.90N 1156.29W 40 19 N 66.97 W .92 531.56N 1212.58W 40 13 N 66.67 W .23 555.78N 1269.15W 1131.84 1173.32 1262.49 1323.94 1385.48 5288.94 4884.90 4839.90 5384.31 4958.36 4913.36 5479.93 5032.60 4987.60 5575.62 5107.61 5062.61 5671.00 5182.11 5137.11 39 53 N 67.22 W .51 579.88N 1325.77W 39 21 N 66.37 W .80 603.84N 1381.67W 38 46 N 67.10 W .78 627.65N 1437.03W 37 59 N 67.63 W .88 650.51N 1491.86W 39 16 N 65.43 W 1.98 674.24N 1546.47W 1447.02 1507.84 1568.09 1627.50 1687.04 5766.19 5255.86 5210.86 5861.67 5330.02 5285.02 5956.60 5403.85 5358.85 6051.90 5477.88 5432.88 6147.46 5551.97 5506.97 39 9 N 65.69 W .22 699.14N 1601.26W 38 56 N 66.51 W .58 723.51N 1656.24W 38 57 N 66.35 W .11 747.37N 1710.94W 39 7 N 66.31 W .18 771.46N 1765.91W 39 12 N 65.08 W .82 796.30N 1820.90W 1747.21 1807.35 1867.02 1927.03 1987.37 6243.25 5626.01 5581.01 6338.61 5699.39 5654.39 6434.16 5772.44 5727.44 6528.54 5844.01 5799.01 6625.24 5916.77 5871.77 39 32 N 65.77 W .57 821.57N 1876.17W 39 50 N 65.21 W .50 846.84N 1931.58W 40 25 N 64.97 W .62 872.78N 1987.44W 40 57 N 64.87 W .57 898.86N 2043.17W 41 26 N 64.42 W .59 926.14N 2100.72W 2048.12 2109.02 2170.58 2232.08 2295.72 .{Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC. MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/20/96 DATE OF SURVEY: 021296 MWD SURVEY JOB NUMBER: AK-MM-960206 KELLY BUSHING ELEV. = 45.00 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. 6720.47 5987.92 5942.92 6815.18 6058.56 6013.56 6911.86 6130.62 6085.62 7007.32 6201.44 6156.44 7102.32 6272.45 6227.45 41 52 41 38 41 59 42 13 41 0 N 64.35 W .46 953.50N 2157.80W N 66.29 W 1.39 979.84N 2215.11W N 66.42 W .37 1005.69N 2274.15W N 65.91 W .44 1031.56N 2332.71W N 67.59 W 1.74 1056.47N 2390.66W 2358.97 2422.02 2486.48 2550.48 2613.57 7199.03 6345.27 6300.27 7294.46 6417.82 6372.82 7390.33 6491.50 6446.50 7485.55 6565.45 6520.45 7578.88 6638.89 6593.89 41 17 39 43 39 49 38 14 37 58 N 68.16 W .48 1080.44N 2449.62W N 70.00 W 2.06 1102.58N 2507.50W N 70.56 W .39 1123.28N 2565.24W N 71.38 W 1.76 1142.84N 2621.93W N 71.27 W .29 1161.28N 2676.50W 2677.20 2739.12 2800.34 2860.14 2917.55 7674.56 6714.26 6669.26 7770.15 6789.59 6744.59 7865.87 6865.34 6820.34 7960.62 6940.54 6895.54 8055.71 7015.70 6970.70 38 3 37 56 37 26 37 30 38 2 N 70.80 W .31 1180.43N 2732.23W N 70.90 W .14 1199.74N 2787.82W N 70.27 W .66 1219.19N 2843.02W N 70.79 W .34 1238.40N 2897.36W N 70.89 W .57 1257.52N 2952.38W 2976.32 3035.02 3093.41 3150.92 3209.01 8151.86 7091.32 7046.32 8247.47 7166.81 7121.81 8342.88 7242.57 7197.57 8438.34 7318.73 7273.73 8533.01 7394.72 7349.72 38 15 37 27 37 24 36 44 36 28 N 70.58 W .30 1277.11N 3008.44W N 68.88 W 1.37 1297.43N 3063.47W N 68.16 W .46 1318.67N 3117.44W N 64.82 W 2.22 1341.60N 3170.19W N 64.69 W .29 1365.68N 3221.26W 3268.25 3326.83 3384.80 3442.32 3498.75 8627.09 7470.52 7425.52 8721.80 7546.62 7501.62 8816.68 7622.59 7577.59 8909.70 7696.90 7651.90 9007.82 7775.04 7730.04 36 9 36 54 36 41 37 16 37 10 N 64.20 W .46 1389.71N 3271.53W N 63.03 W 1.08 1414.77N 3322.03W N 63.86 W .57 1440.18N 3372.87W N 65.40 W 1.18 1464.15N 3423.43W N 65.31 W .12 1488.90N 3477.37W 3554.43 3610.72 3667.46 3723.37 3782.71 9100.37 7848.17 7803.17 9195.78 7922.95 7877.95 9290.46 7997.16 7952.16 9384.50 8070.99 8025.99 9478.58 8146.29 8101.29 38 25 38 20 38 25 38 7 35 31 N 65.92 W 1.41 1512.31N 3529.03W N 66.09 W .13 1536.40N 3583.15W N 65.18 W .60 1560.66N 3636.71W N 65.45 W .37 1584.99N 3689.64W N 66.76 W 2.88 1607.84N 3741.18W 3839.41 3898.65 3957.44 4015.67 4072.05 9573.12 8224.42 8179.42 9668.15 8304.98 8259.98 9762.66 8387.05 8342.05 9855.91 8469.80 8424.80 9947.80 8552.13 8507.13 33 31 28 26 26 0 2 23 27 17 N 69.67 W 3.19 1627.63N 3790.57W N 70.12 W 2.07 1644.96N 3837.89W N 69.92 W 2.81 1660.96N 3881.92W N 70.43 W 2.10 1675.54N 3922.33W N 70.04 W .26 1689.34N 3960.74W 4125.24 4175.55 4222.33 4265.20 4305.95 RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/20 INC. /96 DATE OF SURVEY: 021296 MWD SURVEY JOB NUMBER: AK-MM-960206 KELLY BUSHING ELEV. = 45.00 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/10 TOTAL RECTANGULAR COORDINATES 0 NORTH/SOUTH EAST/WEST VERT. SECT. 10042.07 8636.40 8591.40 26 57 N 69.67 W .73 1703.89N 4000.40W 10135.40 8719.39 8674.39 27 28 N 69.06 W .62 1718.93N 4040.35W 10232.76 8805.75 8760.75 27 32 N 70.16 W .53 1734.60N 4082.49W 10325.90 8888.68 8843.68 26 36 N 70.32 W 1.01 1748.93N 4122.38W 10421.59 8974.53 8929.53 25 50 N 70.00 W .81 1763.28N 4162.15W 4348.13 4390.77 4435.67 4477.97 4520.17 10514.22 9057.90 9012.90 25 49 N 70.29 W .14 1776.98N 4200.11W 10607.71 914'2.09 9097.09 25 43 N 69.85 W .23 1790.84N 4238.33W 10702.58 9227.84 9182.84 24 54 N 69.63 W .87 1804.89N 4276.39W 10766.66 9286.01 9241.01 24 43 N 70.84 W .85 1813.98N 4301.70W 10850.00 9361.71 9316.71 24 43 N 70.84 W .00 1825.42N 4334.62W 4560.46 4601.04 4641.56 4668.40 4703.16 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 4703.30 FEET AT NORTH 67 DEG. 9 MIN. WEST AT MD = 10850 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 293.28 DEG. ~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC. MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/20/96 DATE OF SURVEY: 021296 JOB NUMBER: AK-MM-960206 KELLY BUSHING ELEV. = 45.00 FT. OPERATOR: BP EXPLORATION 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 -45.00 .00 N .00 E 1000.00 997.10 952.10 18.36 N 55.81 W 2000.00 1991.14 1946.14 70.22 N 130.47 W 3000.00 2985.72 2940.72 86.87 N 194.36 W 4000.00 3884.23 3839.23 242.00 N 587.80 W .00 2.90 2.90 8.86 5.96 14.28 5.42 115.77 - 101.49 5000.00 4664.48 4619.48 505.96 N 1154.22 W 6000.00 5437.60 5392.60 758.31 N 1735.93 W 7000.00 6196.02 6151.02 1029.55 N 2328.21 W 8000.00 6971.78 6926.78 1246.29 N 2920.00 W 9000.00 7768.80 7723.80 1486.93 N 3473.08 W 335.52 219.76 562.40 226.87 803.98 241.59 1028.22 224.24 1231.20 202.97 10000.00 8598.90 8553.90 1697.26 N 3982.52 W 10850.00 9361.71 9316.71 1825.42 N 4334.62 W 1401.10 169.91 1488.29 87.19 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. AY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC. MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/20/96 DATE OF SURVEY: 021296 JOB NUMBER: AK-MM-960206 KELLY BUSHING ELEV. = 45.00 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 .00 -45.00 45.00 45.00 .00 145.00 145.00 100.00 245.00 245.00 200.00 345.02 345.00 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .14 S .06 W .00 .00 .49 S .38 W .00 .00 1.04 S 2.10 W .02 '- .02 445.12 445.00 400.00 545.33 545.00 500.00 645.60 645.00 600.00 746.01 745.00 700.00 846.61 845.00 800.00 1.01 S 6.37 .05 N 12.58 1.81 N 19.73 4.53 N 28.33 9.17 N 38.26 W .12 .10 W .33 .20 W .60 .27 W 1.01 .41 W 1.61 .60 947.38 945.00 900.00 1048 . 44 1045 . 00 1000 . 00 1149 . 96 1145 . 00 1100 . 00 1251 . 45 1245 . 00 1200 . 00 1352 . 46 1345 . 00 1300 . 00 14.90 N 49.29 21.84 N 62.11 31.25 N 76.81 -41.97 N 90.40 50.99 N 101.31 W 2.38 .77 W 3.44 1.06 W 4.96 1.52 W 6.45 1.50 W 7.46 1.00 1453.12 1445.00 1400.00 1553.54 1545.00 1500.00 1653.74 1645.00 1600.00 1753.81 1745.00 1700.00 1853.83 1845.00 1800.00 58.37 N 110.14 63.57 N 117.48 66.91 N 122.69 68.73 N 125.74 69.49 N 127.78 W 8.12 .67 W 8.54 .41 W 8.74 .20 W 8.81 .07 W 8.83 .02 1953.85 1945.00 1900.00 2053.87 2045.00 2000.00 2153.88 2145.00 2100.00 2253.88 2245.00 2200.00 2353.88 2345.00 2300.00 69.99 N 129.61 70.52 N 131.64 70.73 N 132.67 70.61 N 132.52 70.53 N 132.24 W 8.85 .02 W 8.87 .02 W 8.88 .01 W 8.88 .00 W 8.88 .00 2453.88 2445.00 2400.00 2553.90 2545.00 2500.00 2654.09 2645.00 2600.00 2754.70 2745.00 2700.00 2855.94 2845.00 2800.00 70.48 N 131.86 70.59 N 133.38 71.28 N 139.25 73.29 N 150.05 77.02 N 165.32 W 8.88 .00 W 8.90 .02 W 9.09 .19 W 9.70 .61 W 10.94 1.24 2958.09 2945.00 2900.00 3061.21 3045.00 3000.00 3165.46 3145.00 3100.00 3271.10 3245.00 3200.00 3378.40 3345.00 3300.00 83.29 N 185.14 92.44 N 208.52 102.84 N 236.02 113.75 N 268.23 126.83 N 304.82 W 13.09 2.15 W 16.21 3.11 W 20.46 4.25 W 26.10 5.65 W 33.40 7.30 ~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC. MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/20/96 DATE OF SURVEY: 021296 JOB NUMBER: AK-MM-960206 KELLY BUSHING ELEV. = 45.00 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 3487.59 3445.00 3400.00 3598.86 3545.00 3500.00 3712.48 3645.00 3600.00 3829.85 3745.00 3700.00 3951.42 3845.00 3800.00 142.30 N 345.78 W 160.67 N 390.95 W 179.98 N 441.28 W 202.64 N 498.36 W 230.16 N 561.71 W 42.59 9.18 53.86 11.27 67.48 13.62 84.85 17.37 106.42 '- 21.57 4075.92 3945.00 3900.00 4200.70 4045.00 4000.00 4326.38 4145.00 4100.00 4454.50 4245.00 4200.00 4582.87 4345.00 4300.00 260.80 N 629.25 W 291.45 N 697.29 W 322.67 N 766.73 W 356.52 N 839.30 W 392.17 N 911.46 W 130.92 24.50 155.70 24.78 181.38 25.69 209.50 28.12 237.87 28.37 4711.46 4445.00 4400.00 4842.75 4545.00 4500.00 4974.33 4645.00 4600.00 5105.87 4745.00 4700.00 5236.91 4845.00 4800.00 426.55 N 984.59 W 462.35 N 1061.75 W 499.09 N 1138.97 W 533.51 N 1217.18 W 566.93 N 1295.00 W 266.46 28.59 297.75 31.29 329.33 31.58 360.87 31.54 391.91 31.04 5367.03 4945.00 4900.00 5495.83 5045.00 5000.00 5623.11 5145.00 5100.00 5752.18 5245.00 5200.00 5880.93 5345.00 5300.00 599.45 N. 1371.63 W 631.52 N 1446.20 W 661.71 N 1518.91 W 695.50 N 1593.20 W 728.33 N 1667.35 W 422.03 30.12 450.83 28.80 478.11 27.27 507.18 29.08 535.93 28.75 6009.53 5445.00 5400.00 6138.47 5545.00 5500.00 6267.87 5645.00 5600.00 6398.13 5745.00 5700.00 6529.86 5845.00 5800.00 760.72 N 1741.43 W 793.91 N 1815.75 W 828.00 N 1890.46 W 862.90 N 1966.28 W 899.23 N 2043.95 W 564.53 28.60 593.47 28.94 622.87 29.40 653.13 30.25 684.86 31.73 6662.91 5945.00 5900.00 6797.03 6045.00 6000.00 6931.21 6145.00 6100.00 7065.94 6245.00 6200.00 7198.67 6345.00 6300.00 936.90 N 2123.21 W 974.99 N 2204.07 W 1010.87 N 2286.02 W 1047.37 N 2368.60 W 1080.35 N 2449.40 W 717.91 33.05 752.03 34.13 786.21 34.18 820.94 34.73 853.67 32.73 7329.80 6445.00 6400.00 7459.51 6545.00 6500.00 7586.63 6645.00 6600.00 7713.60 6745.00 6700.00 7840.26 6845.00 6800.00 1110.31 N 2528.73 W 1137.69 N 2606.65 W 1162.81 N 2681.01 W 1188.35 N 2754.96 W 1213.93 N 2828.36 W 884.80 31.13 914.51 29.71 941.63 27.13 968.60 26.96 995.26 26.66 .RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC. MILNE PT/MPC-23 500292264300 NORTH SLOPE BOROUGH COMPUTATION DATE: 2/20/96 DATE OF SURVEY: 021296 JOB NUMBER: AK-MM-960206 KELLY BUSHING ELEV. = 45.00 OPERATOR: BP EXPLORATION FT. 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 7966.25 6945.00 6900.00 1239.53 N 2900.59 W 1021.25 25.99 8092.91 7045.00 7000.00 1265.02 N 2974.04 W 1047.91 26.66 8220.00 7145.00 7100.00 1291.41 N 3047.88 W 1075.00 27.09 8345.94 7245.00 7200.00 1319.36 N 3119.17 W 1100.94 25.95 8471.12 7345.00 7300.00 1349.94 N 3187.94 W 1126.12 '- 25.18 8595.48 7445.00 7400.00 1381.60 N 3254.74 W 1150.48 24.35 8719.77 7545.00 7500.00 1414.22 N 3320.95 W 1174.77 24.30 8844.62 7645.00 7600.00 1447.54 N 3387.86 W 1199.62 24.85 8970.13 7745.00 7700.00 1479.39 N 3456.68 W 1225.13 25.50 9096.33 7845.00 7800.00 1511.29 N 3526.73 W 1251.33 26.20 9223.89 7945.00 7900.00 1543.47 N 3599.10 W 1278.89 27.56 9351.47 8045.00 8000.00 1576.51 N 3671.09 W 1306.47 27.57 9476.98 8145.00 8100.00 1607.47 N 3740.32 W 1331.98 25.52 9597.66 8245.00 8200.00 1632.27 N 3803.10 W 1352.66 20.67 9714.54 8345.00 8300.00 1652.95 N 3859.94 W 1369.54 16.88 9828.21 8445.00 8400.00 1671.40 N 3910.70 W 1383.21 13.67 9939.85 8545.00 8500.00 1688.14 N 3957.43 W 1394.85 11.64 10051.72 8645.00 8600.00 1705.41 N 4004.51 W 1406.72 11.87 10164.26 8745.00 8700.00 1723.69 N 4052.78 W 1419.26 12.54 10277.02 8845.00 8800.00 1741.54 N 4101.73 W 1432.02 12.76 10388.79 8945.00 8900.00 1758.38 N 4148.71 W 1443.79 11.76 10499.89 9045.00 9000.00 1774.88 N 4194.23 W 1454.89 11.10 10610.94 9145.00 9100.00 1791.32 N 4239.64 W 1465.94 11.05 10721.50 9245.00 9200.00 1807.66 N 4283.86 W 1476.50 10.55 10831.61 9345.00 9300.00 1822.90 N 4327.35 W 1486.61 10.11 10850.00 9361.71 9316.71 1825.42 N 4334.62 W 1488.29 1.69 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS MEMORANDUM State of Alaska Aiaska Oil and Gas Conservation Commission TO: David Johnst4;~~ Chairman DATE' May 29, 1996 THRU' Blair Wondzeil ~ FILE NO: P. !. Supervisor FROM' Lou Grimaldi, SUBJECT' Petroleum Inspector AW9JE3DD.DOC BOFE Test Nabors rig 4ES BPX well #MPC-23 Mi!ne Point Field PTD #96-016 Wednesday, May 29, 1996' I witnessed the initial BOPE test on Nabors rig 4ES which was drilling BPX well #MPC-23 in the Milne Point Field. Due to the Kuparuk river bridge being washed out l had to take the Otter to Kuparuk and truck transport to C pad in the Milne Point Field. The rig was almost ready to test when I arrived. I toured the area surrounding the rig and found it to be kept clean and orderly. The test once started went well. The inside Blooey valve had a small amount of leakage and the gas detectors were inoperative and both items will be repaired before the rig drills out. The Kelly valves were not tested as the Kelly was laid down and should not be needed for this wells work. Danny Hebed (Nabors toolpusher) assured me that if the Kelly was needed it would be tested first and he would call the North Slope Inspector for a witness of this test. The rest of the BOPE tested out OK and I found the upkeep of this rig to be good. ~; ~,~,~^ Rv' i witne~*ed the initial BOPE test on Nabors rig 4ES. There were three failures, the inside Blooey valve and gas detectors. Test time 3 !/2 hours. Attachments'my" ' ^"~' ~'~ D D.XLSvu,~ ,..,~ CC: Scott Sigurdsen/Tom Horten (Prudhoe Bay drlg.) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: Nabors Rig No. 4ES PTD # BPX Rep.: MPC-23 Rig Rep.: Set @ Location: Sec. Weekly Other DATE: 5/29/96 96-0f6 Rig Ph.# 659-4154 Eddie Vaughn Danny Hebert 10 T. 13N R. fOE Meridian Urn/at TEST DATA MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Quan. Annular Preventer f Pipe Rams Lower Pipe Rams Blind Rams 1 Choke Ln. Valves f HCR Valves Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Test Press. P/F 250/2500 P 250/5,000 P 25O/5,0OO P 250/5,000 250/5,000 1 250/5,000 P 2 250/5,000 P N/A 250/5, 000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector F F H2S Gas Detector F F FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F * 250/5,000 * 250/5,000 2 250/5,000 P 1 250/5,000 P CHOKE MANIFOLD: No. Valves 18 No. Flanges 38 Manual Chokes 1 Hydraulic Chokes f Test Pressure P/F 250/5,00O F 250/5, 000 P Functioned P Functioned P 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 1900 Average 2,950 1,850 minutes 32 sec. minutes 8 sec. P Remote: P Psig. TEST RESULTS Number of Failures: 3 ,Test Time: 3.5 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within N/A 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. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Inside Blooey valve failed, Gas detection system inop. Repair and retest before proceeding. Notify North Slope inspector when rep/rs are complete. Test Kelly if picked up and notify N.S. of results. 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: Witnessed By: Louis R Grimaldi FI-021L (Rev. 12/94) AW9JE3DD.XLS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 21 March 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 LDWG TAPE+LIS 1 LDWG TAPE+LIS 1 LDWG TAPE+LIS ECC No. Run # 1 6603.00 Run # 1 6609.00 Run # 1 6616.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Naska ~i & Gas Cons. Commi~io~ Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MILNE POINT NORTH SLOPE, AK Enclosed, please find the data as described below: Date: RE: Prints/Films: 1 PFC/PERF FINAL BL+RF Run # 1 1 PLS FINAL BL+RF Run # 1 11 March 1996 Transmittal of Data ECC #: 6616.00 Sent by: HAND CARRY Data: PLS Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 ~~o (907) 563-7803 Date: MAR 20 99S Anchorage ALASKA OIL AND GAS CONSERVATION CO HSSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Januaw 25,1996 J. D. Polya BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Miine Point Unit MPC-23 BP Exploration (Alaska), Inc. ' - Permit No 96-016 Surf Loc 1038'NSL, 2404'WEL, Sec. 10, T13N, R10E, UM Btmhole Loc 2953'NSL, 1576'WEL, Sec. 09, T13N, R10E,UM Dear Mr. Polya: Enclosed is the approved application for permit to drill the above referenced well. The permit to ddil does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Suffident notice (approximately 24 hours) of the BOPE test performed before drilling belowthe surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl Joan Miller - AOGCC · STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill F"Jllb. Type of well. Exploratory l--I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-Ii 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 RTE = 46.3' feet Milne Point/Sag River 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047434 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 1038' NSL, 2404' WEL, SEC. 10, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 2799' NSL, 1219' WEL, SEC. 9, T13N, RIOE MPC-23 2S100302630-277 At total depth 9. Approximate spud date Amount 2953' NSL, 1576' WEL, SEC. 9, T13N, RIOE 01/27/96 $200,000.00 12. Distance to nearest !13. Distance to nearest well !4. Number of acres in property15. Proposed depth(M~)and'rVD) property line ADL 315848 2953 feet No CloseApproach feet 2560 11006'MD/9450' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o ^AC 25.035 (e)(2)) Kickoff depth 300 feet Maximum hole angle39.~ o Maximum surface 3301 psig At total depth ('rVD) 7000'/3998 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 4912' 31' 31' 4943' 4619' 963 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 8-1/2" 7" 26# L-80 Btrc 10976' 30' 30' 11006' 9450' 615 sx Class 'G' 19. 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 Measured depth True Vertical depth Structural Conductor Surface -~; ~:.... %_~, Intermediate Production JAN 2 Liner Perforation depth: measured ,",~.~,.,¥'. ,.~i'.~(" ,;",,-,:.: true vertical ,'-,: 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling' 'program [] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed reportl-I 20 AAC 25.050 requirementsi--I 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~j.~O,, ¢~ Title Senior Drilling Eng*eer /~/Z2/~ ~,~ Date ~ Commission Use Only ~ermit Number IAPI number Approval date ISee cover letter C( (o ~ (~ [(o 150- Ce.d-¢. ,~~ /-,¢,~,'~'~ ~'~. Jfor other requirements Conditions of approval Samples required I~ Yes [] No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes ~ No Directional survey required I~ Yes [] No Required working pressure for DOPE [] 2M; I-]3M; ,J~.5M; I--I10M; I--115M; by order of Other: Original Signed By Commissioner [ne commission Date Approved by h,~virt IM Form 10-401 Rev. 12-1-85 n oi'i Submit ir triplicate -~ -- Well Plan Summary SHARED SERVICES DRILLING CONTACT: JAMES ROBERTSON 564-5159 I Well Name: I MP C-23 (SAG) I (producer or Sag River Producer Surface Location: 1037 NSL 2404 WEL Sec 10 T13N R10E UM., AK TarQet Location: 2799 NSL 1219 WEL Sec 09 T13N R10E UM., AK Bottom Hole 2953 NSL 1576 WEL Sec 09 T13N R10E UM., AK Location: IAFE Number: 1337016 I I ~:~~~ated Start 127JAN96 I MD: 111.006' I I Rig: I Nabors 22-E I I Operating days to 11 5 I complete: TVD: l:k~50' I I KBE: 146.0' I (conventional, slimhole, I Milne Point Ultra Slimhole:9-5/8" SURFACE CASING X 7" LONGSTRING MD 1,793 4,4741 4,7931 7,2861 7,6891 8,169 8,513 10,228 10,590 +11,006 4,5021 6,436 6,749 7,121 7,388 8,776 TOD of Schrader Bluff Sands (8.3 9,090 +9,450 Sadlerochit Sand (8.6 3001 below last oil bearina zone "'aSlna/l UDlna t'ro :¡ram: Hole Csgl Wt/Ft Grade Conn Length Top Btm Size Tba O.D. MD/TVD MD/TVD 24" 2011 91 .1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/811 40# L-80 btrc 4,912 31/31 4,943/4,619 8 1/2" 7" 26# L-80 btrc 10,976 30/30 11006/9450 Internal yield pressure of the T1 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3998 psi is 3301 psi, well b"elow the internal yield pressure rating of the T1 casing. ,.. ~ Open Hole Loos: Surface MWD Directional and LWD GR/RES Intermediate N/A Final MWD Directional and LWD (GR/CDR/CDN). E-Line GR/CDR/CDN (triple combo) across Sag River and RFT log (pressure only) across KUPARUK. Cased Hole LOQs: Mudloggers are NOT required for this well. ~...;.. . . .... ¡;' ".."", ~ .~ ii ~.-. D.'~ - It '% ¡j.,,<= %J !!.-. it \7 í.- JAN 22 1996 Alae~~t;\ on & Ür:w Cün:~. C\~JìfÍi\?,s¡m¡ ¡~ll(;t't(?f~~Jf~ .~ Mud Program: Special design considerations None-SPUD MUD Surface Mud Properties: I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity. Point ael Qel Loss 8.6 100 1 5 8 1 0 9 8 to to to to to to to 9.0 50 35 1 5 30 1 0 1 5 Intermediate Mud Prol>erties: N/A I Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point Qel Qel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Poi nt Qel ael Loss 9.0 40 1 0 3 7 8.5 6-8 to to to to to to to 11.0 50 1 5 1 0 20 9.5 4-5 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: Disposal: Cuttings Handling: Cuttings 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. Request to AOGCC for Annular Pumping Approval for MP C-23 (SAG): 1. Approval is requested for Annular Pumping into the MP C-23 (SAG), 9-5/811 x T' casing annulus and any well on the pad/drillsite previously permitted for disposal activities by AOGCC. 2. The base of the Permafrost for all wells located in the Milne Point Unit is :t1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/811 casing shoe will be set at 4,9431 md (4,6191 tvd) which is a minimum of 500' tvd below the Permafrost and into the Seabee/Colville formation which has an established history of annular pumping at Milne Point. 4. There are i:23 wells on Milne Pt. IC' Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 5. The wastes to be disposed of during drilling operations can be defined as "DRILLlNG WASTES". 6. The burst rating (800k) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the SEABEE (COLVILLE) formation is 12.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping regardless of fluid density is 2000 psi as per Shared Services Drilling "Recommended Cuttings Injection Procedurell. 7. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 8. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. ~ ANNULAR INJECTION: THE FOLLOWING MILNE PT. 'C' PAD WELLS HAVE BEEN PERMITTED FOR ANNULAR INJECTION FOR 1995 AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (BBLS) (B B LS) Milne Point C-26 0 35,000 1 JAN96-31 DEC96 Milne Point C-25 0 35,000 1JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 Milne Point 1 JAN96-31 DEC96 DO NOT EXCEED 35,000 BBLS. IN ANY ANNULUS. MAXIMUM EXPECTED FLUID DENSITY IS 17.0 PPG BURTST PRESSURE 9-5/811 40# L-80 CASING: COLLAPSE T', 26#, L-80 CASING: 9-5/8" SURFACE CASING SHOE DEPTH: 5750 PSI 5410 PSI 4,9431 MD/4,6191 TVD HYDROSTATIC PRESSURE @ 4.619' TVD WITH VARIOUS DENSITY FLUIDS: (0.052) X (4619) X (FLUID DENSITY) = HYDROSTATIC PRESSURE 80% OF 7" COLLAPSE PRESSURE = (5410 PSI) X (0.8) = 4328 PSI MAXIMUM ALLOWABLE INJECTION PRESSURE 2000 PSI AT ANY PPG SURFACE CASING SHOE DEPTH (TVO): 4,619 HYDROSTATIC MAXIMUM ALLOWABLE PRESSURE AT SURFACE 7" COLLAPSE ANNULAR INJECTION FLUID DENSITY CASING SHOE DEPTH PRESSURE (80%) SURFACE PRESSURE (PPG) (PSI) (PSI) (PSI) 8 1921.50 4328 2000 9 2161.69 4328 2000 1 0 2401.88 4328 1926 1 1 2642.07 4328 1686 1 2 2882.26 4328 1446 1 3 3122.44 4328 1206 1 4 3362.63 4328 965 1 5 3602.82 4328 725 1 6 3843.01 4328 485 1 7 4083.20 4328 245 MAX ALLOWABLE INJECTION PRESSURE = 4328 PSI- HYDROSTATIC PRESSURE or 2000 psi (whichever is less). ~-, MP C-23 (SAG) Proposed Summary of Operations 1 . Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. 2. Prepare location for rig move. 3. MIRU Nabors 22E drilling rig. 4. NU and test 2011 Diverter system. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional/Gamma Ray/Resistivity MWD/LWD across Schrader Bluff sands. Run and cement 9-5/8" casing. 6. ND 20" Diverter, NU and Test 13-5/8" BOPE. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 101 of new formation. Perform FIT to 12.5 ppg. 7. 8. Drill 8.5" hole to TD as per directional plan. Run E-Line logs. Run and Cement T' Casing. Displace cement with seawater and enough diesel to cover from the base of permafrost to surface. 9. Test casing to 3500 psig. 10. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. 11 . Perforate and Stimulate in absence of rig. Displace well with appropriately weighted completion fluid and set a wireline retrievable bridge plug. 12. MIRU Nabors 4ES or Polar 1 Rig. NU & Test BOPE to 5000 psig. 13. Complete well with 2-7/8" tubing and packer hookup. 14. Install Surface Lines and Wellhouse and put the well on production. Drillina Hazards and Risks: 1. The Kuparuk, Sag River, and Sadlerochit reservoir sands are expected to be normally pressured (8.6 PPG). The closest injection well is Milne Pt. Well# C-08i which appears to be isolated by a fault. 2. See the Milne Point C-Pad Data Sheet prepared by Pete Van Dusen for a general recap of wells drilled by Conoco on C-Pad plus wells recently drilled by BPX. 3. There will be no close approach wells associated with the drilling of Milne Pt. Welt# C-23 (SAG). 4. A GYRO or IN-HOLE REFERENCE GYRO MA Y be required to be run in this wellbore. LOST CIRCULATION: There were no reports of lost circulation while DRILLINGin the production intervals. However, Milne Pt. "c' Pad was developed in the early to mid 1980's with virgin reservoir pressures. Several wells at Milne Pt. 'c' Pad have experienced partial to full lost returns while running, circulating and cementing 7" casing. Have the LCM materials outlined in the Drilling Fluid Program on location and recommended pills ready to address the Lost Circulation Problem when drilling into the Kuparuk Sand. Stuck Pioe Potential: Stuck pipe has occurred on 2 wells on this pad in the Schrader Bluff Sands. These wells and the corresponding depths at which they were stuck were: C- 09 @ 4,427' 55 with a mudweight of '9.4 ppg. Milne Pt.. W~IIII;. ç,()2 f?f 3,911' ss with 9.2 ppg mudweight. ~"'-~C~.jr.:~ \'J i!.,....~ JAN 2 2 1~9b . . . -'.... h\\ )::. Ga$ CQ.n~. CQí(\iT\i3~¡on i----' Gas hvdrates: Although hydrates were encountered at Milne Point on 'E' and 'H' Pads, no hydrates are expected on Milne Pt. 'c' pad. No hydrates were encountered while drilling MP C-21 or MP C-22 nor the more recent MP C-26 or MP C- 25 wells. 4. No other drilling hazzards or risks have been identified for this well. ,.-. CASING SIZE: 9-5/8" SPACER: MP C-23 (SAG) 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CIRC. TEMP 50 deg F at 2500' TVDSS. 75 bbls fresh water. LEAD CEMENT TYPE: ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX #SACKS: 963 TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 Type E Permafrost YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. Premium G YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FLUID LOSS: 100-150 cc FREE WATER: 0 TOP JOB CEMENT TYPE: Permafrost E ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/811 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. CEMENT VOLUME: 1 . The Tail Slurry volume is calculated to cover 6181 md above the 9-5/8" Casing Shoe with 30% excess. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 15001 md with 300k excess and from 15001 md to surface with 100% excess. 80lmd 9-5/8", 40# capacity for float joints. Top Job Cement Volume is 150 sacks. 2. 3. 4. ,-~. MP C-23 (SAG) Well 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB FROM TD UP 10001 ABOVE THE KUPARUK INTERVAL: CIRC. TEMP: 1400 F BHST 1700 F at 70401 TVDSS. SPACER: 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: 0.20/0 CFR-3, 0.1 % HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg APPROX # SACKS: 615 VI ELD: 1 .15 cu ft/sk MIX WATER: 5.0 gal/sk THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 1400 F FLUID LOSS: < 50cc/30 min @ 1400 F FREE WATER: Occ @ 45 degree angle. CENTRALIZER PLACEMENT: 1 . 7" X 8-1/4" Straight Blade Rigid Centralizers. Two per joint from 1001 below to 1001 above any potential producing hydrocarbon zone. Run two (2) 711 x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. 2. 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 8-10 bpm. Batch mixing is not necessary. CEMENT VOLUME: 1 . Stage 1 cement volume is calculated to cover 1000' md above the Kuparuk Sand with 300/0 excess. SHARED SERVICES DRILLING Anadrjll Schlumberger MPC-23 (P9) . CLOSURE.....: ~~~~ee~I:~ Azimuth 293.28 DECLINATION.: +28.132 (E) SCALE.......: 1 jnch = 600 feet DRAWN.......: 01/22/96 3300 ---'1 3000 2700 I --l- I 2400 (, 2100 1800 1500 - 1200 900 ( 600 I ^ 300 .-L.. I :I: i .-. a: CJ I z 0 I :r .-. =:J 0 I en I 300 v 5100 01800 01500 42':0 (AnadriU (cl96 C23P9 2.5b.03 10: 1.4 AIo( PI ---. .~_. I I"~ I \ ._,\ I I t--' \ \ Marker Identification ",MO A) KB -1\p~ B) BUILD 1/100 300 CI BUILD 1.5/100 500 0) END 1.5/100 BUILD 1100 EI DROP 1.5/100 1100 F) END 1.5/100 DROP 1833 G) BUILD 2.5/100 2500 HI END 2.5/100 BUILD ~064 I) 9-5/88 CASING POINT 4943 JI DROP 2/100 9372 K) END 2/100 DROP 9828 l) TARGET 10228 MI 7. CASING POINT 11006 H) TO 11006 ~ ! .. ì I -+-. I I ..-l i I I ! I --r' I ~-- I .-L I i AN 3900 3300 3000 900 600 300 0 300 (- WEST: EAST -> 2700 2400 2100 1500 1200 1BOO 3600 N/S 0 0 1 28 . 28 56 56 259 478 1582 1664 1763 1917 1917 I , I I ! I I r-- ; E/W 0 0 3 66 66 130 130 602 1211 3678 3915 40ge 4456 4456 I I -1 ! ~. -- Jan-22-9S 10:14 Anadrill OPC 907 344 21S0 P.06 , SHAREp SERV~ES DRILL¡NG I . Marker Identi fieat ion MO BKB SECTN INCLN M P C - 23 ( P 9 ) A) END 2.5/100 BUILD 4064 3937 655 39.11 B) 9-5/S8 CASING POINT 4943 4619 1210 39.11 VERTICAL SECTION VIEW C) DROP 2/100 9372 S055 4003 39.11 0) END 2/100 DROP 9828 8430. 4262 30.00 EJ TARGET. . 10228 8776 4462 30.00 F) 78 CASING POINT 11006 ..9450 4851 30.00 3Scm.yp . '\. I I 11 ~06 945~. 485 f 30 .00 Section at: 293.28 TVD Scale.: 1 inch::: 800 feet Dep Scale.: 1 inch :a BOO feet . -Drawn. . . . .:, 01/22/96 9000 ----- Anadrill SChlumóerger . - - --...-.... ....-- 5400 8 5800 K B 6200 ---1_- . ; . I --..- I .---. ...- '- I I 9400 9aoo 10200 400 SOD 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 Section Departure 6000 lAnaol'ill (c) 96 C23P9 2. 5b. 03 ~O: 13 AN PI ~f N p~ - ;¿ J (Sq() \: Xf [6 v l,"t{ t~ I r) l"jeu '---C1~( WELL PERMIT CHECKLIST 5~ ~ sz..Ç(5Þo PROGRAM: exp 0 dev Ja:.. redrll 0 aerv 0 wellbore seg D WELL NAME COMPANY /1 J:lCY ON/OFF SHORE l)/I\. UNIT//: INIT CLASS GEOL AREA REMARKS Permit fee attached. . . . . . . . . . . . . . . . . .~ N Lease number appropriate.. .............. . N Unique well name and number. . . . . . . . . . . . . .. N Well located in a defined pool. . . . . . . . . . . . . ~ N Well located proper distance from drlg unit boundary. . ~ N Well located proper distance from other wells. . . . ..CV N Sufficient acreage available in drilling unit. . . . . .CÌ) N If deviated, is wellbore plat included. . . . . . . . ~ N Operator only affected party. . . . . . . . . . . . . . GÞ N Operator has appropriate bond in force. . . . . . . . .~N Permit can be issued without conservation order. . . ..~ N Permit can be issued without administrative approval. . G]) N Can permit be approved before 15-day wait. . . . . . . ~ N 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. ll. 12. 13. c 0 Z ) 0 -I ~ ::0 - -I m - z -I :I: - CIJ :CIJ -C I> (") m AAPR DATE ~ ~~~<tb ENGINEERING Conductor string provided. . . . . . . . . . . . . . . ~ N Surface casing protects all known USDWs . . . . . . . . ~ N CMT vol adequate to circulate on conductor & surf esg. .~ N CMT vol adequate to tie-in long string to surf csg . . . Y (][) CMT will cover all known productive horizons. . . . . . ~ N Casing designs adequate for C, T, B & permafrost. . . .~ N Adequate tankage or reserve pit. . . . . . . . . . . . .ét) N If a re-drill, has a 10-403 for abndnmnt been approved. ~ Adequate wellbore separation proposed. . . . . . . . . .(jr N If diverter required, is it adequate. . . . . . . . . ..Y N Drilling fluid program schematic & equip list adequate .C3[) N HOPEs adequate. . . . . . . . . . . . . . . . . . . . ~ N HOPE press rating adequate; test to ~~ psig~ N Choke manifold complies w/API RP-53 (May 84). . . . . .~I\Jt4- Work will occur without operation shutdown. . . . . . . ~ N Is presence of H2S gas probable. . . . . . . . . . . .~ N 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. APPR DAlE J.. - Jq-~ GEOLOGY ------ 30. Permit can be issued w/o hydrogen sulfide SU;es....Y 31. Data presented on potential overpr re . . . . Y 32. Seismic analysis of s~ s zones. . . . . . . . . . Y 33. Seabed eondit~ey (if off-shore) . . . . . . . . . Y 34. Cont~phone for weekly progress reports. . . . . Y ------ [exploratory only] N N N N N APPR DATE ~~q~ COMMISSION: GEOLOGY: RPC ,;zl) (IN> c¡¡;, ENGINEERING: Comments/Instructions: BEW ~ & (~~(FG DWJ f?I::r7J JDa~ JD~L- ~: TAB HOWlljb - A:\FORMS\cheklist rev 11195 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. ~£ile 2 is type: , .~£E HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN Ii 1 AK-MM-9~. 206 D. MOUN~JOY 9226~'3 - - BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 07 -NOV- 96 MWD RUN 2 B. ZIEMKE J. PYRON 10 13N 10E MWD RUN 3 B. ZIEMKE J. PYRON 1037 2404 45.40 16.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 12.250 PRODUCTION STRING 8.500 REMARKS: 20.000 112.0 9.625 4941.0 10850.O MWD - GR/EWR4/CNP/SLD. ALL DEPTHS ARE MEASURED BIT DEPTHS. WELL MPC-23 IS REPRESENTED BY RUNS 1-3. RUN 1 IS DIRECTIONAL WITH GAMMA RAY (SGRC), AND ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4) . RUNS 2 AND 3 ARE DIRECTIONAL WITH GAMMA RAY (SGRC), ELECTROMAGNETIC WAVE 4-PHASE RESISTIVITY (EWR4), COMPENSATED NEUTRON POROSITY (CNP/SPSF), AND STABILIZED LITHO-DENSITY (SLD/SBDC). ALL GAMMA RAY DATA ACQUIRED WITH DUAL GAMMA RAY, GEIGER MUELLER TYPE DETECTORS, AND IS DENOTED AS DGR/SGRC. A GAP IN GAMMA RAY DATA EXISTS FROM 4894' TO 4908' DUE TO LOGGING TOOL CONFIGURATION CHANGE BETWEEN RUNS 1 AND 2. WELL MPC-23 HAS BEEN DEPTH SHIFTED. WELL MPC-23 IS DRILLED TO TD AT 10850'. ~ HEADER ' ~ _~LE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMM~%RY PBU TOOL CODE GR RP NPHI RHOB $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 108.0 108.0 4895.0 4906.0 BASELINE DEPTH 43.0 9936.5 9943.5 9949.0 9984.0 10006.5 10098.0 10189.0 10242.0 10247.0 10250.0 10282.5 10362.5 10364.5 10375.0 10380.5 10386.0 10408.5 10429.0 10433.5 10442.0 10445.5 10451.5 10470.5 10473.5 10482.0 10496.0 10507.5 10520.0 10547.5 10558.5 10564.5 10574.0 1058O.5 10605.5 10618.5 10629.5 10648.0 10855.0 $ GR 36.0 9929.5 9937.5 9941.0 9976.5 9996.0 10088.5 10179.5 10232.5 10237.0 10240.0 10270.5 10352.5 10354.5 10365.5 10370.5 10376.0 10398.5 10418.0 10423.0 10431.0 10434.0 10440.0 10460.0 10462.5 10470.0 10485.0 10499.0 10511.0 10543.0 10553.5 10559.0 10568.5 10574.5 10600.5 10613.0 10625.0 10643.5 10850.5 all bit runs merged. STOP DEPTH 10816.0 10790.0 10797.0 10806.0 (WALS, Cased Hole, 05-Mar-96.) EQUIVALENT UNSHIFTED DEPTH DATA SOURCE _s'U TOOL CODE MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 112.0 4960.0 2 4960.0 10551.0 3 10551.0 10850.0 MERGED MAIN PASS. CN WN FN COUN STAT /? ?SHIFT. OUT $ : BP EXPLORATION (ALASKA) : MPC-23 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 FET MWD 68 1 HR 4 11 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 t 4 90 120 46 1 4 90 120 46 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 180 01 1 4 90 810 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1025 Tape File Start Depth = 10855.000000 Tape File End Depth = 100.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 258133 datums . Subfile: 2 Minimum record length: Maximum record length: 1158 records... 62 bytes 1014 bytes ~ Subfile 3 is 'type~ LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RL~ NO: 1 DEPTH iNCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 101.0 EWR4 101.0 $ 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: MAXIMUM ANGLE: STOP DEPTH 4894.0 4886.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 05-FEB-96 ISC 2.11 / MPDS 1.22 3.94 MEMORY 4960.0 112.0 4960.0 0 .1 40.7 TOOL NUMBER P0459CRG8 P0459CRG8 12.250 112.0 SPUD 9.40 70.0 9.0 600 7.6 3.000 .000 3.000 4.400 68.0 .0 68.0 68.0 .00 .000 .0 0 .~mKARKS: CN WN FN STAT : BP EXPLORATION (ALASKA) : MPC-23 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API AP1 AP1 AP1 Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ,FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 315 Tape File Start Depth = 4970.000000 Tape File End Depth = 100.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 77929 datums Tape Subfile: 3 380 records... Minimum record length: 62 bytes Maximum record length: 998 bytes S9'I ~O~$~N-~ 0'09 O' PSI 0'0/. 009'E 000'E 099' 0S9'I p'~ 00g 0'6 0'L~ 00'II 0'I~6~ 00S'8 9©GqSN%ID08P0d 9©G%SN~D08~0d 9DGqSNIID08~0d 8'S~ 0 0'IfiSOI 0'096P 0'ISfi0I ~6'£ 96-~ZZ-II : (MI) ZZIS LIS ZqOH NZdO $ XLISNZG-OHLIq GqS ~ 'SISZ~ 'D~FNO~LDZ~Z ZEAL ~OOi ZGOD qOOi ~OQMZA (NOLiO~ Oi dOi) ©HI,iS qOOi 0'6£~0I 0'668~ ~qs 0'0£P0I 0'888~ AND 0'£9~0I 0'~£8~ ~HMZ 0'06P0I 0'806~ ~O GMH M~F~ £ :~Z~HF_M ZqI~ ~2C~ZH ZqI~ SIq .:eclKn. s~ p eTlSqr_s ~ _iOLE CORRECTION TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 2. $ CN WN FN COUN STAT :BP EXPLORATION (ALASKA) : MPC-23 : MILNE POINT : NORTH SLOPE : ALASKA .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 NCNT MWD 68 1 CPS 4 11 FCNT MWD 68 1 CPS 4 12 FET MWD 68 1 HR 4 13 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 334 30 1 4 90 334 31 1 4 90 180 01 1 4 90 810 01 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 634 Tape File Start Depth = 10560.000000 Tape File End Depth = 4860.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 417748 datums Tape Subfile: 4 703 records... s~qAq ~IOI ssqAq E9 . :q~Bu~I pxoo~x :q~Bu~I pxoo~x ZNO£S~NtfS 0'09 0'SS 0'66I 0'0L 009'E 000'E 000 ' 0S9'I 9'£ 008 0'6 0 '~ 00'II {INSq 0 ' I I76 I7 00~'8 9©GqSNItD0890d 9DGqSNItD08~06 9DGqSNItD08~0d 9D~qSN%{D08~0~ HZ~I, qnN ~00~ 0 0'0S80I 0'ISSOI 0'0S80I ~6'£ EE'I SGdH / II'E OSI :ALISNZ~ XI~tzlq :XI~£VH : (MI) ZZIS iI~ Z~OH NZdO XLISNZ~-OHLI~ ZEAL ~OOi Z~OD ~OOL ~OGMZA (HOLLO~ Oi 60£) ©~I~LS 0'I080I 0'E6LOI 0'~8t0I 0'EI80I HLdZ~ dOiS 'SeIT~ @~des ul unx ~Tq qo~e ~o~ ~p x@pweq 5oi pu~ senxno CMH M¥~ HZG~f~H ZqI~ SIq :edA~. s~ ~ eI!~qns ~ ~oLE CORRECTION (l : 30 TOCL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 3. $ CN WN FN CO~JN STAT : BP EXPLORATION (ALASKA) : MPC-23 : MILNE POINT : NORTH SLOPE : ALASKA .0 * FORRAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 NCNT MWD 68 1 CPS 4 11 FCNT MWD 68 1 CPS 4 12 FET MWD 68 1 HR 4 13 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 334 30 1 4 90 334 31 1 4 90 180 01 1 4 90 810 01 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 47 Tape File Start Depth = 10851.000000 Tape File End Depth = 10430.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TP~AILER **** LIS representation code decoding summary: Rep Code: 68 89732 datums Tape Subfile: 5 116 records... s~qXq ~IOI s~qXq ~9 - :q~6u~I p~oos~ mum~- :qqBu~I p~oo~ ~e Subfile 6 is tYPe~ LIS 96/10/31 . **** REEL TRAILER **** 6 O1 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 6 NOV 96 10:04a Elapsed execution time = 6.70 seconds. SYSTEM RETURN CODE = 0 .5 ..., ,,, .,/ ..-.,- :::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::: mm{ ,mm,,,{ '%%~M SIHI ~O~ Hid~ ~HA SI I SS~d ~DNIS fi~i~IHS Hid~ iON STfM I SSTfd 'HNI~ G~Mk~4 Oi ~HIi SHIdH~ HNI~H~IM ~ SHI~H~ ~T~ HidH~ ~HI~IHSNll J~IHqSfAIfl0H SMDIAMMS ONIOOO~ 96-kncq4-S0 I I HDM~ ' .~H.~d/O.gd : SX~,g%{ HDM~ H~Ld.g~ ~IIq.gS~f~t :XN~dMOD ~NIf)O0~ :GZDD07 :HGOD ~{A~qD :~GOD ~00~ S.L,~IHS %{0.~ ~tA~flO ~I~I,gS~f~t (Za/~t~I) ~LHQI.gM (£.4) H,LdMG (NI) .gZIS (blI) ,gZIS ONIS~fD S%{.~'I~IIMG ONIS~D ,~IOH N,~aO 08'9I 0~,'59 L£0I .g0I 0I SI~ 'sd. Kq s! ~ aI!~qns FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH $ .5000 START DEPTH 9700.0 STOP DEPTH 10650.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: MAIN PASS. NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPC - 23 FN : MILNE POINT COLTN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB 4 4 30 995 99 1 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 23 Tape File Start Depth = 9695.000000 Tape File End Depth = 10650.000000 Tape File Level Spacing = 0.500000 Tape File Depth U,._cs = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 5734 datums Tape Subfile: 2 116 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; ~raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9697.0 $ LOG HEADER DATA STOP DEPTH 10660.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL CASING COLLAR LOC. PFC PFC GAMMA P~AY $ 05-MAR-96 FSYS REV. J001 VER. 1.1 1036 05-MAR-96 10689.0 10687.0 9700.0 10653.0 1800.0 YES TOOL NUMBER 2315NA 0722XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : 0.000 10777.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT R~ ~ SCALES SET BY FIELD ENGI. ~'R FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN) : 0.0 REMARKS: PASS 1. $ CN : BP EXPLORATION WN : MPC - 23 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GR GR 68 1 GAPI 4 CCL GR 68 1 4 SPD GR 68 1 F/MN 4 TTEN GR 68 1 LB 4 TEN GR 68 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 4 30 635 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 92 Tape File Start Depth = 9697.000000 Tape File End Depth = 10660.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 23119 datums Tape Subfile: 3 164 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes · spuoD~s 6S'E = ~mT~ uoT~n~x~ P~Sd~I~ d~:9 96 Hlf]4 0E P~M :uo~nD~x~ ~o pu~ s~Aq ~£I :q~Bu~I p~oo~ mnm~x~ s~Xq EEI :q~6u~I p~oo~ mnmTuT~ I0 0z/[ /gs I0 0E/[ /96