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198-217
2025-0316_Surface_Abandon_MPU_F-80_ksj Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 03/16/2025 P. I. Supervisor FROM: Kam StJohn SUBJECT: Surface Abandonment Petroleum Inspector MPU F-80 Hilcorp Alaska LLC PTD 1982170; Sundry 323-656 03/16/2025: I witnessed the marker plate installation MPU F-80 after surface cement job was completed. Bill Kruskie was the Hilcorp representative for today’s inspection. I verified the PTD and API # numbers, Operator, and well name are correct on the marker plate. The cement was hard in the tubing and annular spaces of the well – this was verified by hitting with a hammer. The cutoff was clean and flush with a depth below tundra at 3 feet 6 inches. The conductor split when the cutoff was done; 18 inches was visible starting at 1-inch wide at top and tapering off. The split was patched by welding angle iron to the conductor. The marker plate installation was good. No follow up needed. Attachments: Photos (6) 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.04.16 16:44:46 -08'00' 2025-0316_Surface_Abandon_MPU_F-80_ksj Page 2 of 4 Surface Abandonment – MPU F-80 (PTD 1982170) Photos by AOGCC Inspector K. StJohn 3/16/2025 2025-0316_Surface_Abandon_MPU_F-80_ksj Page 3 of 4 2025-0316_Surface_Abandon_MPU_F-80_ksj Page 4 of 4 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 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): 13,408'12,805' Casing Collapse Conductor N/A Surface 3,090psi Production 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng KUPARUK RIVER OIL N/A 7,179' 13,295' 7,077' 0 11,676 & Surface Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT F-80 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 1/15/2023 Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 & ADL0388235 198-217 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22928-00-00 Hilcorp Alaska LLC C.O. 432E Length Size Proposed Pools: 112' 112' N/A TVD Burst N/A MILNE POINT MD N/A 5,750psi 8,160psi 3,860' 7,152' 5,612' 13,379' 80' 20" 9-5/8" 7" 5,518' 13,349' N/A and N/A N/A and N/A Ryan Thompson ryan.thompson@hilcorp.com 907-301-1240 Perforation Depth MD (ft): See Schematic See Schematic N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:55 pm, Dec 08, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.12.08 09:31:28 - 09'00' Taylor Wellman (2143) 323-656 DSR-12/14/23 10-407 AOGCC to witness cement in all annuli before welding plate. Photo document as described. MGR30JAN24 SFD 12/20/2023 Abandon *&:JLC 1/31/2024 1/31/24 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.01.31 15:21:31 -09'00' RBDMS JSB 020124 Plug and Abandon Well: MPF-80 PTD: 198-217 API: 50-029-22928-00-00 Well Name:MPF-80 API Number:50-029-22928-00-00 Current Status:Suspended Rig:Surface Ops Estimated Start Date:1/15/2024 Estimated Duration:2 days Reg.Approval Req’d? Yes Date Reg. Approval Rec’vd:TBD Regulatory Contact:Tom Fouts Permit to Drill Number:198-217 First Call Engineer:Ryan Thompson 907-564-5005 907-301-1240 (M) Second Call Engineer:Ryan Lewis 303-906-5178 (M) AFE Number:TBD MASP: 0 psi, cement 60’ below surface. Brief Well Summary MPF-80 was drilled in November 1998 as a Kuparuk ESP producer. ESP changeouts were performed in 2000, 2003, 2005 & 2009 via RWO. During the 2009 RWO the tubing parted at ~350’. The well was P&A’d with Doyon 16 in 2011. The tubing & ESP cable were pulled and a tubing stub with ESP were left at ~12,805’. The P&A is summarized in the below table from the 2011 10-407 submittal. The OA is cemented to surface w/ 57 bbls of returns during the cement job. The inside of the 7” casing is cemented to ~60’. Notes Regarding Wellbore Condition x Cement to surface in the OA. TOC at ~60’ inside the 7” casing. x Last suspended well inspection completed 9/20/20. Plug and Abandon Well: MPF-80 PTD: 198-217 API: 50-029-22928-00-00 Objective: x To perform a complete P&A of the well. Procedure SL 1. RIH, tag cement @ 60’ to verify cement top/volume. Fullbore 1. Evacuate diesel from inside the 7” casing down to 60’ 2. Perform cement top job w/ ~2.2 bbls of 12-15.8# class G cement. Operations 1. Photo document all steps. 2. Cut off all casings and wellhead 3’ below tundra. 3. Top off tubing and annuli with cement if needed. 4. AOGCC witness welding marker cap on the outermost casing string. The marker plate should have the following information bead welded onto it: a. Hilcorp Alaska, LLC. b. Permit to Drill Number – 198-217 c. Well Name – MPU F-80 d. API Number - 50-029-22928-00-00 *** Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) Attachments: 1. As-built Schematic 2. Red line schmematic Plug and Abandon Well: MPF-80 PTD: 198-217 API: 50-029-22928-00-00 Plug and Abandon Well: MPF-80 PTD: 198-217 API: 50-029-22928-00-00 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Renew Suspension 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,408'13,278' / 12,805' Casing Collapse Conductor 520psi Surface 3,090psi Production 7,020psi Liner 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 Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Abhijeet Tambe Operations Manager Contact Email: Contact Phone: 777-8485 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE COMMISSION Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 13,379'13,379' 7 inch NA See Schematic Authorized Signature: NA NA Perforation Depth MD (ft): See Schematic 7,152' 1,530psi 5,750psi 112' 3,861' 112' 5,612' 20 inch 9-5/8" 112' 5,612' NA TVD Burst NA 8,160psi Tubing Grade: Tubing MD (ft): MD 50-029-22928-00-00 Length Size 7,179' Surface Surface PRESENT WELL CONDITION SUMMARY 11,676' / 5,837' / surface STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0388235 / ADL0025906 198-217Hilcorp Alaska LLC MILNE PT UNIT F-80 MILNE POINT / KUPARUK OIL Abhijeet.Tambe@hilcorp.com COMMISSION USE ONLY Authorized Name: Perforation Depth TVD (ft): Tubing Size: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:41 am, Feb 10, 2021 321-078 Chad Helgeson (1517) 2021.02.09 17:05:41 - 09'00' X ADL0025509 DLB DLB DSR-2/10/21 NA DLB 02/10/2021 MGR16FEB2021Comm. 2/18/21 dts 2/16/2021 JLC 2/16/2021 RBDMS HEW 2/25/2021 February 9, 2021 Jesse Chmielowski, Chair Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Milne Point F-80 (PTD # 198-217) Application for Renewal of Existing Suspension (10-403) Dear Commissioner Chmielowski, Hilcorp Alaska, LLC (“Hilcorp”) as operator of the Milne Point Unit completed an AOGCC witnessed suspended well inspection of Milne Point Unit well MP F-80 on 9/20/2020. A report of Sundry Well Operations (10-404) with attachments documenting the inspection and the current condition of the well (reference 20 AC 25.110 (e) and (f)) were submitted on 10/09/2020. F-80 was suspended on 06/12/2011. The well has been cemented to surface and is essentially P&A’d. It is located on a pad with active wells. Hilcorp believes the well is mechanically sound and secure and will meet requirements for renewal of suspended status, as the wellhead and cellar will be removed at the end of the life of the other wells on the pad. Based on this information, Hilcorp Alaska requests approval for renewal of the existing suspension status for this well. Please do not hesitate to contact me at 907-777-8405 or Abhijeet Tambe at 907-777-8485 should you have any questions. Sincerely, Chad Helgeson, ANS Operations Manager HILCORP ALASKA, LLC Attachments: Technical Justification for Application for Renewal of Suspended Status 2020 Suspended Well Inspection Report Wellbore Schematic Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: 907/777-8300 Fax: 907/777-8301 Chad Helgeson (1517) 2021.02.09 17:04:55 - 09'00' Page |2 Milne Point Unit well MP F-80 Technical Justification for Application for Renewal of Suspension Status February 8, 2021 Well Status: Milne Point Unit well MP F-80 (PTD# 198-217) was suspended on 07/23/2010 after parted tubing discovery during a workover operation to install failed ESP. After several unsuccessful attempts to retrieve stuck ESP at the bottom, a cement retainer was set at 12,795’ MD (100’ above TOF) and Kuparuk A-3 perfs were squeezed off. A 1,000’ of cement plug was placed on top of the retainer. A CIBP was set at 5,837’ and cement plug was set across the surface casing shoe and the 7” intermediate casing was cemented to surface. The well is mechanically sound as evident by the successful pressure tests performed during plugging operations. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair recovery of oil or gas, and is secure, safe, and not a threat to public health. The strata through which the well was drilled is neither abnormally geo-pressured nor depleted. Condition of the Wellhead and Surface Location: Milne Point Unit well MP F-80 is located on an active, well maintained pad with clean gravel and in good condition. The surrounding area are in good condition. There is no discoloration and sheens on the pad, pits, or in nearby water. The well pressure readings are T/IA/ OA = 0 psi/ 0 psi / 0 psi Request: Hilcorp Alaska LLC requests approval for renewal of the existing suspension status for MP F-80. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email: If Verified, How? Onshore / Offshore: Date AOGCC Notified: Suspension Date: Type of Inspection: Sundry No.: Wellbore Diagram Avail.? Photos Taken? Well Pressures (psi): Tubing 0 IA 0 OA 0 Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm None Location verified by Pad map WBS Pictures Area map Yes Yes Onshore 09/18/20 Subsequent Good, Clean, No leaks Good, Clean STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Brian Bixby 09/20/20 Yes Jon ArendMPF-80 (907)240-4383 Follow Up Actions Needed: Hilcorp 198-217 Condition of Surrounding Surface Location: 06/12/11 310-410 REVIEWED BY: Other (specify in comments) PLB 12/2014 MPF-80 Suspended Well Inspection 9-20-20 Tree: CIW 2-9/16" 5M 'FLS' Wellhead: 11" x 11" 5M FMC Gen 5a 11" x 2-7/8” NSCT. 2.5” CIW-H BPV profile. DATE REV. BY COMMENTS Orig. DF Elev. = 43.25 (N 27E) Orig. GL Elev. = 10.80' DF To Csg. spool= (N 27E) MILNE POINT UNIT WELL F-80 API NO: 50-029-22928 9 5/8", 40 ppf, L-80 Btrc. Perforation Summary Ref log: SWS PDC 12-07-98 Size SPF Interval (TVD) BP EXPLORATION (AK) 7" float collar (PBTD) KOP @ 400' Max. hole angle = 70 to 76 deg. f/ 5,950' to 10,700' Hole angle thru' perfs = 27 deg. 7" float shoe 20" 91.1 ppf, H-40 MPU F-80 112' Stimulation Summary 7" 29 ppf, L-80, Hydrill.563 casing, ( drift ID = 6.184", cap. = 0.0371 bpf ) 5612' HES 9 5/8" ES" Cementer0 Two 7" x 20' marker joints 12,962’ - 13002‘ 2098‘ X 11/22/98 MDO Drill and Cased Nabors 27E 13379’ 13295’ Kup. A-3 Sand 2.5 3 13,164’-13,184’ 6941’ - 6959’ 2.5 6 13,164’-13,184’ 6941’ - 6959’ 3 3/8 6 13184‘ - 13200’ 6977‘ - 6992’ 12/08/98 - 2.5” SWS RDX UP bighole charges 12/25/98 - 2.5” SWS RDX 35B UP bighole charges 12/29/98 ‘A’ Sand refrac - 7200 # of AEA ChemFlow SI impregnated proppant and 85.8 M# of 16/20 Carbolite behind casing. Tight spot in 7” casing at 2063’ 4-es had trouble getting desander past this point. 2-7/8”, 6.5 ppf, L-80 EUE 8 rd ( drift ID =2.347”, Cap. =.0058 bpf) 1/13/99 M. Linder Initial completion w/ desander 4-ES 3/99 4/00 MDO / Linder ESP RWO 4-ES 00 due to corrosion Baker 7" WLSRBP with overshot & 4.5” fn. Top of tbg cut on fish - 12805‘ Mid-perf TD = 6967 Mid-perf MD = 13182’ PBTD MD = 13295’ PBTD TVD = 7017’ 1/21/03 MDO ESP RWO 4-ES 6/28/05 L Hulme Replace ESP / Add Perfs 4-ES 6/27/05 - 3 3/8“ SWS HSD PJ 3406 5/28/09 Worthington Update WBS - parted tbg during RWO o oo 6/9/11 Hulme P&A - Doyon 16 7" EZ-SVB Cement Retainer 12795’ 3450’ 7" CIBP 5837’ Tbg shot interval 5250‘ - 5260‘ (unable to circulate) Tbg shot interval 3500‘ - 3510‘ Top of Cement - 11676‘ Squeez e d 7" EZ-SVB Cement Retainer Hilcorp Alaska 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect Well Hilcorp Alaska 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 13,408 feet 11,676' / 5,837' / surface feet true vertical 7,179 feet 13,278' / 12,805'feet Effective Depth measured Surface feet feet true vertical Surface feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)None N/A N/A N/A Packers and SSSV (type, measured and true vertical depth)N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 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:Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: N/A N/A 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse 520psi 3,090psi 7,020psi Burst 1,530psi 5,750psi 8,160psi 80' 5,581' 13,349' Surface Production 20" 9-5/8" 7" measured N/A Liner Casing Conductor Size Junk Length MILNE PT UNIT F-80 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: David Gorm dgorm@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 196-217 50-029-22928-00-00 Plugs ADL0388235 / ADL0025906 5. Permit to Drill Number: MILNE POINT / KUPARUK OIL 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data WINJ WAG Water-Bbl MD 112' measured 3,861' 7,152' 5,612' TVD 112' Oil-Bbl measured true vertical Packer 13,379' PPP Form 10-404 Revised 3/2020 Submit Within 30 days of Operations 198-217 Chad A Helgeson 2020.10.09 13:06:34 -08'00' By Samantha Carlisle at 2:03 pm, Oct 09, 2020 ADL0025509 SFD 10/12/2020 DSR-10/12/2020 SFD 10/12/2020 MGR13OCT2020 RBDMS HEW 11/25/2020 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email: If Verified, How? Onshore / Offshore: Date AOGCC Notified: Suspension Date: Type of Inspection: Sundry No.: Wellbore Diagram Avail.? Photos Taken? Well Pressures (psi): Tubing 0 IA 0 OA 0 Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm None Location verified by Pad map WBS Pictures Area map Yes Yes Onshore 09/18/20 Subsequent Good, Clean, No leaks Good, Clean STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Brian Bixby 09/20/20 Yes Jon ArendMPF-80 (907)240-4383 Follow Up Actions Needed: Hilcorp 198-217 Condition of Surrounding Surface Location: 06/12/11 310-410 REVIEWED BY: Other (specify in comments) PLB 12/2014 MPF-80 Suspended Well Inspection 9-20-20 DATE REV. BY COMMENTS MILNE POINT UNIT 9 5/8", 40 ppf, L-80 Btrc. Perforation Summary Ref log: SWS PDC 12-07-98 Size SPF Interval (TVD) 7" float collar (PBTD) KOP @ 400' Max. hole angle = 70 to 76 deg. f/ 5,950' to 10,700' Hole angle thru' perfs = 27 deg. 7" float shoe 20" 91.1 ppf, H-40 112' Stimulation Summary 7" 29 ppf, L-80, Hydrill.563 casing, ( drift ID = 6.184", cap. = 0.0371 bpf ) 5612' HES 9 5/8" ES" Cementer0 Two 7" x 20' marker joints 12,962’ - 13002‘ 2098‘ X 13379’ 13295’ Kup. A-3 Sand 2.5 3 13,164’-13,184’ 6941’ - 6959’ 2.5 6 13,164’-13,184’ 6941’ - 6959’ 3 3/8 6 13184‘ - 13200’ 6977‘ - 6992’ 12/08/98 - 2.5” SWS RDX UP bighole charges 12/25/98 - 2.5” SWS RDX 35B UP bighole charges 12/29/98 ‘A’ Sand refrac - 7200 # of AEA ChemFlow SI impregnated proppant and 85.8 M# of 16/20 Carbolite behind casing. Tight spot in 7” casing at 2063’ 4-es had trouble getting desander past this point. 2-7/8”, 6.5 ppf, L-80 EUE 8 rd ( drift ID =2.347”, Cap. =.0058 bpf) Baker 7" WLSRBP with overshot & 4.5” fn. Top of tbg cut on fish - 12805‘ Mid-perf TD = 6967 Mid-perf MD = 13182’ PBTD MD = 13295’ PBTD TVD = 7017’ 6/27/05 - 3 3/8“ SWS HSD PJ 3406 o oo 7" EZ-SVB Cement Retainer 12795’ 3450’ 7" CIBP 5837’ Tbg shot interval 5250‘ - 5260‘ (unable to circulate) Tbg shot interval 3500‘ - 3510‘ Top of Cement - 11676‘ Squeez e d 7" EZ-SVB Cement Retainer Suspended Well Inspection Review Report |nupectNo: susBDB200921I40754 Date Inspected: 9/20/2020 ' Inspector: Brian Bixby - Type ofInspection: Subsequent Well Name: K4|LNE PTUNIT F-80 Date A0G{INotified: 9/18/2020 ' � � Permit Number: 1982170 Operator: Hiko/pAlaska' LL[ Suspension Approval: Sundry # 310~410 ^ Operator Rep: Jon Arend Suspension Date: 6/12/2011 _ Wellbore Diagram Avail? Location Verified? Photos Taken? |fVerified, How? Other (specify incomments) offshore? El Well Pressures (psi): Tubing: Jl Fluid in Cellar? [] |A: O' 8PV|nstaUed? OA: 0 VRP|u8(s)Installed? Wellhead Condition All ofthe valves unthe appeared ingood working order with working gauges onthe Tubing, |Aand OA. There are noVR Plugs mr8PVinstalled. Condition ofCellar Good Condition. | did not observe and excessive water incellar, trash nrany sheen. ~' Surrounding Surface Condition Everything looked good. I did not see debris or sheen around the pad. Comments I verified the location using the pad map. Supervisor Comments Photos(2) ~r� �i u6�9/td'50W Monday, September 2D'2OZO STATE OF ALASKA ALLKA OIL AND GAS CONSERVATION COMPSION SEP 1 7 2015 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing A Operations shutdown A Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well LI Other: Inspect Well 0 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ 198-217 3.Address: Stratigraphic Li Service ❑ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-22928-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0388235 MILNE PT UNIT KR F-80 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: 11,676,5,837& Total Depth measured 13,408 feet Plugs measured Surface feet true vertical 7,179 feet Junk measured N/A feet Effective Depth measured 0 feet Packer measured N/A feet ' true vertical 0 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20" 120' 120' Surface 5,612' 9-5/8" 5,612' 3,861' 5,750psi 3,090psi Production 13,379' 7" 13,379' 7,152' 8,160psi 7,020psi Liner SCANNED N U r j15 Perforation depth Measured depth See Attached Schematic feet True Vertical depth See Attached Schematic feet tt Tubing(size,grade,measured and true vertical depth) N/A N/A N/A N/A Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments(required per 20 AAC 25 070 25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development LiService LI Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Gas ❑ WDSPL 7 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ Li WAG ❑ GINJ ❑ SUSP❑✓ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Stan Porhola Email sporholahilcorp.com Printed Name _St/an Porhola Title Operations Engineer Signature �„ f -v///',— Phone 777-8412 Date 9/14/2015 i e`l•1.5 RBDMS SEP 2 2 2015 Form 10-404 Revised 5/2015 Submit Original Only • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/23/15 Inspector: Chuck Scheve Operator: Hilcorp.LLC Well Name: MPF-80 Oper.Rep: Bill Kruskie PTD No.: 198-217 Oper.Phone: 1-907-670-3387 Location Verified? Yes Oper.Email: wkruskieOhilcorp.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Date AOGCC Notified: 08/21/15 Suspension Date: 06/12/11 Type of Inspection: Subsequent Sundry No.: 314-410 Wellbore Diagram Avail.? Yes Photos Taken? Yes Well Pressures(psi): Tubing 0 IA 0 OA 0 Condition of Wellhead: Good,No visable leaks and all gauges are installed , Well house on,Well Head sign installed, work tree two valves. Condition of Surrounding Surface Location: Good Follow Up Actions Needed: None. Comments: Map on location. Attachments: Pictures REVIEWED BY: Area map Insp.Supry WBS Comm PLB 12/2014 MPF-80 2015 Suspended Well Inspection Form • • Tree CIW 2-9/16" 5M 'FLS' MPU F-80 Orig. DF Elev. = 43.25 (N 27E) Wellhead:11" x 11" 5M FMC Gen Orig. GL Elev. = 10.80' 5a 11" x 2-7/8" NSCT. 2.5" CIW-H DF To Csg. spool= (N 27E) BPV profile. 20" 91.1 ppf, H-40 112' 0 HES 9 5/8" ES" 2098' Cementer Tight spot in 7" casing at 2063' 4-es had trouble getting desander past th s 7" EZ-SVB Cement Retainer 3450' point. KOP @ 400' 1. Tbg shot interval 3500' - 3510' Max. hole angle = 70 to 76 deg. * — 5,950' to 10,700' t Tbg shot interval 5250' - 5260' Hole angle thru' perfs = 27 deg. I (unable to circulate) 9 5/8", 40 ppf, L-80 Bt-c. 5612' ''''''7"1”,10' 7" CIBP 5837' 2-7/8", 6.5 ppf, L-80 EUE 8 rd ( drift ID =2.347", Cap. =.0058 bpf) 7" 29 ppf, L-80, Hydrill.563 casing, ( drift ID = 6.184", cap. = 0.0371 bpf ) Mid-pert TD = 6967 Mid-pert MD = 13182' PBTD MD = 13295' Top of Cement - 11676' PBTD TVD = 7017' X Two 7" x 20' marker joints 12,962' - 13002' Stimulation Summary 12/29/98 'A' Sand refrac - 7200 # of A:A ChemFlow SI impregnated proppant an., Perforation Summary Ref log: SWS PDC 12-07-98 7" EZ-SVB Cement Retainer 12795' 85.8 M# of 16/20 Carbolite behind casi g. Kup. A-3 Sand Size SPF Interval (TVD) mm Top of tbg cut on fish - 12805' 2.5 3 13,1 4 ' 6941' - 69 '9' 2.5 6 -13,184' 6941' - 69 '9' 3 3/8 6 84' - 13200' 6977' - 69:, ' ;tet – 12/08/98 - 2.5" SWS RDX UP bighole charges _ 12/25/98 - 2.5" SWS RDX 35B UP 1111 bighole charges 6/27/05 - 3 3/8" SWS HSD PJ 3406 IBaker 7" WLSRBP with overshot & 4.5"fn. I .11E..-__,___ 7" float collar (PBTD) I 93295' 7" float shoe 13379' DATE REV. BY COMMENTS MILNE POINT UNIT 11/22/98 MDO Drill and Cased Nabors 27E 1/13/99 - M. Linder Initial completion w/desander 4-ES WELL F-80 321/03MDO ESP RWO 4 00 /Linder RWO 4-ES 00 due to corrosion 1/ API NO: 50-029-22928 6/28/05 L Hulme Replace ESP/Add Perfs 4-ES 5/28/09 Worthington Update WBS- parted tbg during RWO 6/9/11 Hulme P&A- Doyon 16 • • 10 III -4.011111111791111P -"";41% 4110110- 41 ■ � 3 CAM MPE"80 lontaiepere•54•7 „�♦� � I'. • • • . • • 6 ' • 111111,). IMF71 l ..—_ I-') =7. r a Sraw—lit let ,nMr • 1s, ►-rL r.- r■ - `• *- WELL NAME MPF-80 OWNER Mee Point Unit (.� OPERATOR 9P CRAG..Sec6, .. SUR LOCATION SW 1-4 Sec 6,T17%R1OF 0R 1. ' UNG PERMIT 96-211 } 41 I 10 • I I 111 '41 I 41 I op- „dimp:20,1,. 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" r _ ) , 1 *cf r � +/ r` 1i r+ Jr a i� I cb • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/23/15 Inspector: Chuck Scheve Operator: Hillcorp Well Name: MPU F-80 Oper.Rep: Bill Kruskie PTD No.: 1982170 Oper. Phone: 907-670-3387 ' Location Verified? Yes Oper.Email: Milne-WellsiteSupervisors(fhi If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore ' Suspension Date: 06/12/11 Date AOGCC Notified: 08/20/15 - Sundry No,: 310-410 . Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA 0 - Condition of Wellhead: Double gate valves. Condition of Surrounding Surface Location: Good Follow Up Actions Needed: None Comments: Location verified by site map. Photos taken by operator available upon request. Attachments: none SCANNED SEP 1 5 2016 REVIEWED BY: Insp.Supry q(36115 Comm PLB 06/2014 2015-0823_Suspend_MPU_F-80_cs.xlsx • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 v December 30, 2011 9.4 7 Mr. Tom Maunder - 1 0 Alaska Oil and Gas Conservation Commission vik? 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 WA 1.2 N/A 15.3 822011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/62011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 WA 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 WA 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF -34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF-37 1950250 50029225480000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF-38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 7&2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/112011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/312011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/312011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NA/ 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/112011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/312011 MPF-69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 0.2 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 WA 6.8 8/3/2011 > MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 1.2 N/A 1.2 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/122011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/13/2011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF-89 2050900 50029232680000 1.2 WA 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/13/2011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 WA 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 WA 1.8 N/A 13.6 8/132011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9112011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 07/30/11 Inspector: Bob Noble Operator: BPX Well Name: MPU F -80 Oper. Rep: John Arend PTD No.: 1982170 Oper. Phone: Location Verified? Yes Oper. Email: If Verified, How? LAT / LONG Onshore / Offshore: Onshore Suspension Date: 06/12/11 Date AOGCC Notified: 07/28/11 Sundry No.: 310 -410 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 0 Photos Taken? Yes IA 0 OA 0 4, Condition of Wellhead: Wellhead was in good condition. All lines were flanged with gauges. No flowline. Well had 2 master valves. Temp scafolding around well head. Condition of Surrounding Surface Good clean gravel. Dry cellar with no sign of oil staining. Location: Follow Up Actions none Needed: Attachments: Photos (2) REVIEWED BY: 'l � z � /rr Insp. Supry Comm PLB 08/2010 2011- 0730_Suspend_MPU_F- 80_bn.xls Suspended Well Inspection - MPU F -80 PTD 1982170 Photos by AOGCC Inspector B. Noble .IIIIIIIIIIIHIIIIIIIII 71-Mt. ' '.=.01k._. -: 1111 ■ :- hill b 1 1 11" :1 I -.."."' I 011111111111111111111111 ‘ilii .._ i _ .... ... ,.. - 4 ,..„,„,,, 1 ......, ...., mow i - - pull . , . 1 _ . ... I p ir --:-... IIIMM I i` igr apIllai el I il r zm I 11110411 * ' 1 WELL NAME MPH(' -� ,. C.% OM RPM am 4 4 k 7 V ' .';' . ' ..4 ' . , .... .. ,, ._ , .- 41111 " 11600 41.11111immon aminwit .. r y • r4 t e Topmak 1 MPU F -80 Suspended Well Inspection 7 -30 -11 bn STATE OF ALASKA • • ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other 0 REPORT OF Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ INSPECTION Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development E Exploratory ❑ - 198 -2170 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 22928 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 388235, 025509 . MPF -80 10. Field /Pool(s): MILNE POINT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured 13408 feet Plugs (measured) 11676, 5837, surface (TOC) feet true vertical 7178.53 feet Junk (measured) 13278, 12805 feet Effective Depth measured 13295 feet Packer (measured) feet true vertical 7076.79 feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.1# H -40 32 - 112 32 - 112 Surface 5581' 9 -5/8" 40# L -80 31 - 5612 31 - 3860 5750 3090 Production 13349' 7" 29# L -80 30 - 13379 30 - 7152 8160 7020 Production Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ - True Vertical depth: _ U — Tubing: (size, grade, measured and true vertical depth) NONE - _ Packers and SSSV (type, measured u and true vertical depth) NONE ( 14 : V �^'1 1 _ 5 c_c_me d 'i 1 ce 3k, e- c" ' `1,c- c. " 14/e1( re_.. ` .!r6 - RECEIV . 12. Stimulation or cement squeeze summary: AUli 1 b 2011 Intervals treated (measured): Aiwa Oil & Goa Caw Cerseission Treatment descriptions including volumes used and final pressure: Anchorage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El r Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ + SUSPQ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Name Joe Lastufka Title Petrotechnical Data Technologist Signature Phone 564 -4091 Date 8/12/2011 Form 10 -404 Revised 10/2010 RBDMS AUG 16 ef" 4 1 Submit Original Only MPF -80 198 -217 _ PERF ATTACHMENT Sw Name Operation Date Peri Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPF -80 12/8/98 PER 13,164. 13,184. 6,959.61 6,977.43 MPF-80 12/26/98 APF 13,164. 13,184. 6,959.61 6,977.43 MPF -80 6/29/05 APF 13,184. 13,200. 6,977.43 6,991.7 MPF-80 7/7/11 SQZ 11,676. 13,295. 5,753.03 7,076.79 MPF-80 7/9/11 BPS 5,837. 11,676. 3,941.79 5,753.03 MPF -80 7/9/11 SQZ 5,348. 5,837. 3,771.08 3,941.79 MPF -80 7/12/11 SQZ 32. 5,348. 32. 3,771.08 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET Ill FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: MPF -80 Field /Pool: MPU /KUPARUK Permit # (PTD): 1982170 API Number: 500292292800 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 7/23/2011 Surface Location: Section: 6 Twsp: 13N Range: 10E Nearest active pad or road: MPU F -Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good, Clean level gravel Pad or location surface: Good Location cleanup needed: None Pits condition: N/A (none) Surrounding area condition: Good Water /fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: N/A Access road condition: Good Photographs taken (# and description): #1- Front, #2- Back Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: FMC Welhead - Good condition, FMC Tree - Good condition, FMC Annular and Tree valves - Good condition, No SSV Cellar description, condition, fluids: None Rat Hole: None Wellhouse or protective barriers: No Wellhouse, Drig scaffolding /Barrier in place Well identification sign: Yes - Good condition Tubing Pressure (or casing if no tubing): 0 psi Annulus pressures: IA - 0 psi, OA - 0 psi Wellhead Photos taken (# and description): Wellhead -Tree, Annular valves & cellar Work Required: None Operator Rep (name and signature): Gerald Murphy AOGCC Inspector: Bob Noble Other Observers: Jon Ar d Inspection Date: 7/30/2011 AOGCC Notice Date: 7/26/2011 Time of arrival: 10:55 AM Time of Departure: 11:10 AM Site access method: Truck • • Milne Point Well F -80 PTD 198 -2170 Suspended Well Inspection Report BP Exploration Alaska (BPXA) completed a suspended well inspection of MPF -80 on 7/30/11. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC Inspector Bob Noble witnessed the inspection. • Wellbore Diagram illustrating the current configuration of the well. • Pad map showing the well location and other wells within 1 /4 mile radius of \the surface location. • Photographs showing the condition of the wellhead and surrounding location. Supplemental Information: • MPF -80 was suspended on 7/23/2010 due to a tubing part. • MPF -80 is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The well is secured with a cement retainer and cement to surface. • The well is mechanically sound as proven by a cement retainer test to 1500 #. AWO 8/1/2011 • • Tree: CIW 2- 9/16" 5M 'FLS' M P U F -80 Orig. DF Elev. = 43.25 (N 27E) Wellhead: 11" x 11 5M FMC Gen Orig. GL Elev. = 10.80' 5a 11" x 2 -7/8" NSCT. 2.5" CIW -H DF To Csg. spool= (N 27E) BPV profile. 20" 91.1 ppf, H -40 112' 0 HES 9 5/8" ES" 1 2098' Cementer Tight spot in 7" casing at 2063' 4 -es had trouble getting desander past this 7" EZ -SVB Cement Retainer 3450' I point. KOP @ 400' Tbg shot interval 3500' - 3510' Max. hole angle = 70 to 76 deg. f 5,950' to 10,700' C Tbg shot interval 5250' - 5260' (unable to circulate) Hole angle thru' perfs = 27 deg. , 9 5/8 ", 40 ppf, L -80 Btrcl 5612 7" CIBP 5837' 2 -7/8 ", 6.5 ppf, L -80 EUE 8 rd ( drift ID = 2.347 ", Cap. =.0058 bpf) 7" 29 ppf, L -80, Hydri11.563 casing, ( drift ID = 6.184 ", cap. = 0.0371 bpf ) Mid -pert TD = 6967 Mid -pert MD = 13182' PBTD MD = 13295' Top of Cement - 11676' PBTD TVD = 7017' X Two 7" x 20' marker joints 12,962' - 13002' Stimulation Summary 12/29/98 'A' Sand refrac - 7200 # of AEA ChemFlow SI impregnated proppant and Perforation Summary Ref log: SWS PDC 12 -07 -98 7" EZ -SVB Cement Retainer 1 12795' 85.8 M# of 16/20 Carbolite behind casing. Kup. A -3 Sand Size SPF Interval (TVD) Top of tbg cut on fish - 12805' 2.5 3 13,164' -' 6941' - 6959' 2.5 6 13,184' 6941' - 6959' 3 3/8 6 4' - 13200' 6977' - 6992' mg 12/08/98 - 2.5" SWS RDX UP bighole charges 12/25/98 - 2.5" SWS RDX 35B UP bighole charges 6/27/05 - 3 3/8" SWS HSD PJ 3406 Baker 7" WLSRBP with overshot & 4.5" fn. E 7" float collar (PBTD) 13295' 7" float shoe 13379' DATE REV. BY COMMENTS MILNE POINT UNIT 11/22/98 MDO Drill and Cased Nabors 27E 1/13/99 M. Linder Initial completion w/ desander 4 -ES WELL F-80 3/99 4/00 MDO / Linder ESP RWO 4 -ES 00 due to corrosion API NO: 50-029 -22928 1/21/03 MDO ESP RWO 4 -ES 6/28/05 L Hulme Replace ESP / Add Perfs 4 -ES 5/28/09 Worthington Update WBS - parted tbg during RWO 6/9/11 Hulme P&A - Doyon 16 BP EXPLORATION (AK) •U F Pad July 25, 2010 Approximate Scale: 1"=200' 2010- 19c -4 -48 AzRo -mErRIC • ,/ , • �• 1 . r t t , 4 iill ' s■, ,*,.. • 1 a q � L t M °*: t t t 3 .r iii . #4 f • ' ' •.•',V #:' ••:•-•, r i it r s / 4 - ‘ ,. ...ti.- ti . . 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Well Class: 20AAC 25.105 20AAC 25.110 IN Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 6/12/2011 198 - 217 310 - 410 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 10/28/1998 50 029 - 22928 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/08/1998 MPF-80 1943' FSL, 3046' FEL, SEC. 06, T13N, R10E, UM 8. KB (ft above MSL): 43.25' 15. Field / Pool(s): Top of Productive Horizon: N/A GL (ft above MSL): 10.8' Milne Point Unit / Kuparuk River Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 678' FNL, 2018' FEL, SEC. 11, T13N, RO9E, UM Surface Surface 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 541517 y - 6035393 Zone ASP4 13408' 7179' ADL 025509 & 388235 TPI: x- y- Zone- 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 532121 y- 6032725 Zone- ASP4 None 18. Directional Survey: ❑ Yes ®No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: MWD, D &I, GR, DWOB, DTQE, Gyro, CDR, ADN, PWD, USIT N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.1# H-40 Surface 120' Surface 120' 24" 250 sx Arcticset 1 (ADOrox.) 9-5/8" 40# L -80 35' 5612' 35' 3860' 12 -1/4" 550 sx PF E, 140 sx G', 1268 sx PF 'E', 175 sx PF'C' 7" 29# L -80 33' 13379' 33' 7152' 8-1/2" 340 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open .SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): None MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. l' PICOLe='f'[(`" DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED r AUG 1 6 2,011 See Attachment F 4' 1 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A - Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: Gas -McF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ■D No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None INI CMS l i 9 all JUL U �i' Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Al � {° �Ij t!� vftfl+� 7ffIf111�S µit Original Only cie tch ..0e4aIrr 6 29. GEOLOGIC MARKERS (List all formations and marlancountered): 30. *NATION TESTS NAME MD TVD Well Tested? ❑ Yes IS No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. SBF2 NA 5441' 3803' None TSBB - OB 6229' 4066' SBA5 6484' 4139' Base of HRZ 12574' 6443' Kalubik 12727' 6575' Kuparuk D 12924' 6747' LCU 13102' 6905' Kuparuk A 13135' 6934' Kuparuk A3 13142' 6940' Kuparuk A2 13160' 6956' Kuparuk Al 13187' 6980' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. O.7 �/ Signed: Terrie Hubble , Title: Drilling Technologist Date: l/ MPF-80 198 -217 310 -410 Prepared By Name/Number Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: David Bjork, 564 -5683 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.07E Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 26.071. • Form 10-407 Revised 12/2009 Submit Original Only • • WELL NAME: MPF -80 (Suspend Well) (10 -407) Attachment Permit to Drill #198 -217 / Sundry Approval #310 -410 Depth Interval Description 12800' Top of 2 -7/8 ". 6.5 #, L -80 Fish 12795' Set Cast Iron Cement Retainer ✓ —12250' Pump Abandonment Plug w/ 20 Bbls Class 'G' ✓ 11655' Pump Abandonment Plug w/ 20 Bbls Class 'G' 5837' Set Cast Iron Bridge Plug ✓ 5250' - 5260' Tubing Punch 3500' - 3510' Tubing Punch Pump Abandonment Plug w/ 20 Bbls Class 'G' Pump Abandonment Plug w/ 51 Bbls Class 'G' Pump Abandonment Plug w/ 20 Bbls Class 'G' 11655' Pump Abandonment Plug w/ 20 Bbls Class 'G' 3450' Set Cast Iron Cement Retainer Surface Pump Abandonment Plug w/ 285 Bbls Class 'G' Surface - 60' Freeze Protect w/ .5 Bbls Diesel 10 -407 Signed: July 19, 2011 • -p..� F-80 /� 10/A Orig. DF Elev. = 43.25 (N IYIP� F-80 As -Bu�' Orig. GL Elev. = 10.80' • • DF To Csg. spool= (N 27E) • . , a Top of Cement 3' below tundra line 20" 91.1 ppf, H -40 112' * ., .. p 0 HES 9 5/8" ES" Cementer 2098' .. 7" Cast Iron Cement Retainer (3,450') - • • * Circulation perfs 3,500- 3,510' Cement Stringer at —3,700' • Top of Cement 4,218' Circulation perfs 5,250 - 5,260' USIT logged TOC 5,348` 9 5/8 ", 40 ppf, L -80 Btrc. 5612' �Cl 7" Cast Iron Bridge Plug (5,837') • „ Top of Cement 11,655' .4) ' • X11 i KOP @ 400' , °" ' Max. hole angle = 70 to 76 deg. f/ 1 64• .• a' 5,950' to 10,700' s. g Hole angle thru' perfs = deg. _ 7 Cast Iron Cement Retainer (12,795') Kup. A -3 Sand _ Top of 2 -18" fish (12,800') Size SPF Interval (TVD) 2.5 3 13,164'- 13,184' 6941' - 6959' - ■ Two 7" x 20' marker joints 12,962' - 13002' 2.5 6 13,164'- 13,184' 6941' - 6959' 3 3/8 6 13184' - 13200' 6977' - 6992' - Mid -perf TD = 6967 *, a u igia Mid -perf MD = 13182' s �e _ PBTD MD = 13295' .. PBTD TVD = 7017' Last TD tag 13278' MD 6/28/05 with 4ES Baker 7" WLSRBP with overshot & 4.5" fn. 7" 29 ppf, L -80, Hydri11.583 casing, 7" float collar (PBTD) 13295' ( drift ID = 6.184 ", cap. = 0.0371 bpf) 7" float shoe 13379' DATE REV BY COMMENTS MILNE POINT UNIT 11/22/98 MDO Drill and Cased Nabors 27E 1/13/99 M. Linder Initial completion w/ desander 4 -ES WELL F -80 3/99 4/00 MDO / Linder ESP RWO 4 -ES 00 due to corrosion API NO: 50- 029 -22928 1/21/03 MDO ESP RWO 4 -ES 6/28/05 L Hulme Replace ESP / Add Perfs 4 - ES 5/28/09 Worthington Update WBS - parted tbg during RWO BP EXPLORATION (AK) • • . Nor 't ;America �:AL: SKcA -` BP; Pagel 001 ' Operation Summary Report Common Well Name: MPF -80 1AFE No Event Type: PLUG AND ABANDON (PXA) I Start Date: 5/21/2011 End Date: 6/12/2011 IZ3 -001 LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 ' Spud Date/Time: 10/28/1998 12:00:00AM : Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT NPT Depth Phase Description of Operations ! (hr) (ft) 5/21 /2011 00:00 - 03:00 3.00 MOB P PRE -PJSM/ PREP RIG FOR RIG MOVE 1 -CLEAN OUT PITS -PJSM/ DERRICK DOWN 03:00 - 05:00 2.00 MOB P PRE PJSM/ PULL RIG OFF OF MPL -07 - NOTIFY PAD OPERATOR I . -WSL, TP, AND PAD OPERATOR OBSERVED _ , MOVING OFF OF WELL 05:00 - 05:30 0.50 MOB P ' PRE MOVE RIG AROUND TO FRONT SIDE OF PAD - INSTALL BOOSTER WHEELS. 05:30 - 08:00 2.50 MOB P 1 PRE REMOVE BOP'S FROM CELLAR AND INSTALL TRANSPORT SKID NOTIFY F PAD OPERATOR AND ALLOW HIM j I ' TO GET ON F PAD SIDE OF RIG MOVE NOTIFY WELLS GROUP WHEN E LINE UNIT TO MOVE OFF F PAD CALLED AOGCC FOR 24 HR NOTIFICATION OF INITIAL BOPE TESTING FOR MPF -80 - CHUCK SHEAVE CALLED BACK AND ASKED FOR AN UPDATE IN THE MORNING. 08:00 - 18:00 I 10.00 MOB P PRE MOBILIZE RIG OFF OF MPU L PAD AND ONTO F PAD ACCESS ROAD 1 F PAD ACCESS RAOD HAS RIG MATS A LITTLE LESS THAN HALF WAY - WILL BE LEAP FROGGING THE RIG MATTS IN ORDER TO GET THE RIG OVER TO F -PAD 18:00 - 00:00 6.00 ! MOB • P PRE : CONTINUE TO MOBILIZE DOWN F PAD ROAD -BACK UP OVER DOUBLE MATS 1 I 1 1 -LAY OUT MATS ON F PAD ROAD TO F PAD - CREW CHANGE & PJSM WITH LAST OF RIG ' 1 MATS LAID OUT TO F PAD '- CONTINUE TO MOBILIZE DOWN F PAD ' i ROAD 5/22/2011 00:00 - 00:30 0.50 MOB P PRE CONTINUE TO MOVE RIG DOWN F PAD ROAD AND ONTO F PAD 00:30 - 01:30 1.00 MOB P PRE MOVE RIG AROUND BACK SIDE OF PAD AND 1 ' STAGE TO PREP RIG FOR SPOTTING OVER MPF -80 01:30 - 05:30 4.00 MOB P PRE PJSM/ REMOVE BOOSTER WHEELS IN CELLAR -INSTALL BOPS IN CELLAR - DERRICK UP -BRIDAL UP -SPOT MAT BOARDS AROUND MPF -80 & SPOT IN NEW DRY HOLE TREE 05:30 - 06:00 0.50 MOB P PRE SPOT RIG OVER MPF -80 - NOTIFIED PAD OPERATOR - WITNESSED BY WSL'S AND TP 06:00 - 08:00 2.00 RIGU P PRE JACK AND SHIM UP RIG TO 3 MAT BOARDS ' HIGH -BUILD STAIRS FOR ENTERING RIG DOORS ' - BRING ON ON 100 BBLS OF 11.7 PPG BRINE FROM MPL -07. RIG ACCEPTED @ 07:30 ON 5/22/2011 Printed 7/5/2011 9:31:13AM Ortii America ALASKA - BP ; Page 2 of 31; peration Summary Common Well Name: MPF -80 �� AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 i End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point I Site: M Pt F Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. I UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To I Hrs Task Code NPT NPT Depth Phase Description of Operations 08:00 12:00 4.00 r RIGU P (ft) PRE I RIGGING UP SURFACE LINES ! WAIT ON KWF FROM PRUDHOE, TRUCKS I NOT AVAILABLE I - LOADERS MOVING MATTS OFF THE ROAD I BACK TO MPL -PAD - OFFLOADED 2 TRUCKS WITH 400 BBLS OF I 1 12.1 PPG NABR KWF, STILL WAITING ON ONE — — TRUCK. 12:00 - 16:30 4.50 RIGU P 1 PRE RIG UP FOR TESTING SURFACE LINES - WEIGHTING UP THE 11.7 PPG BRINE FROM MPL -07 TO 12.1 PPG - TESTED SURFACE LINES TO 4,000 PSI UPSTEAM OF THE CHOKE AND 500 PSI I 1 1 DOWN STREAM OF THE CHOKE, 5 CHARTED ! MIN EA - RIGGING UP 2" OA LINE FROM THE OA TO --------- - - - - -- r RIGU THE SLOP TANK. 16:30 - 17:00 0.50 P PRE RIG EVACUATION DRILL WITH AAR: - DRILL WENT WELL ALL CREW WAS ACCOUNTED FOR - QUESTION WAS RAISED ABOUT A SLB UNIT THAT WAS NEAR BY, AND WEITHER OR NOT I WE NEEDED TO GO INFORM THEM DURING A REAL EVAC? IT WAS DECIDED THAT WE WERE COVERED BY THE SIMOPS CARD THEY HAD FILLED OUT WITH THE SPOC, AND THAT IN A REAL EVENT WE WOULD CALL THEM ON THE HARMONY AND LET THEM 1 KNOW. 17:00 - 19:00 ! 2.00 RIGU P PRE PU & MU DSM LUBRICATOR - CONT TO WAIT ON LAST TRUCK OF KWF - MPU DSM ON LOCATION AND WAITING -PJSM FOR RU & PULLING BPV 19:00 - 22:00 3.00 WHSUR P 1 , DECOMP RU DSM LUBRICATOR I 1 -PT LUBRICATOR AGAINST TREE VALVES TO 250 LOW AND 4000 PSI I - SERVICE TREE VALVES WITH GREASE AS WE CAN'T GET A GOOD HIGH TEST AGAINST TREE -PT TO 4000 PSI AGAIN AND TEST GOOD - ATTEMPT TO PULL BPV BUT UNABLE TO RETRIEVE -UNSTAB LUBRICATOR AND FOUND PULLING TOOL TO BE INOP - REBUILT PULLING TOOL AND RE MU LUBRICATOR TO TREE -PT LUBRICATOR TO 250 LOW AND 4000 PSI HIGH -PULL BPV &WHP =1710 PSI -SECURE TREE AND RD LUBRICATOR 22:00 22:30 0.50 KILLW P DECOMP _ START TO BREAK DOWN FLOW BACK TANK HARD LINES UNTIL WIND CHANGED DIRECTION. - HARMER UP BROKEN CONNECTIONS -PT DOWN STREAM OF CHOKE TO 500 PSI -WIND HAD BEEN BLOWING STRAIGHT AT RIG BUT FINALLY CHANGED AS WE WERE STARTING TO BREAK IT ALL DOWN. Printed 7/5/2011 9:31:13AM I I . orth America- lC A SIA - BP Page of 3t' Ae rat i on , Summary; Report . Common Well Name: MPF -80 _____— - -- – —� AFE No Event Type: PLUG AND ABANDON (PXA) I Start Date: 5/21/2011 End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad I Rig Name /No.: DOYON 16 1 Spud Date/Time: 10/28/1998 12:00:00AM I Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date ! From - To Hrs ! Task Code NPT I NPT Depth Phase ■ Description of Operations (hr) KILLW P (ft) 22:30 - 00:00 ! 1.50 DECOMP PJSM FOR BLEED DOWN OF WHP -WALK DOWN LINES AND POSITION PERSONAL - NOTIFY MPU RADIO AND PAD OPERATOR OF GAS VENTING , -BLEED DOWN WHP FROM 1720 PSI TO 1100 PSI AT 00:00 -MAINLY GAS RETURNS WITH SOME FLUID I RETURNS T 5/23/2011 I 00:00 02:30 2.50 KILLW 1 DECOMP ' CONTINIIF TO RI ER') DOWN WHP FROM I 1100 PSI TO 67n PSI -KEEPING DOWN STREAM PRESSURE I . 1 BELOW 120 PSI -AFTER SHUT IN PRESSURE CLIMBED TO 710 I 1 AND SLOWLY CLIMBING (-BROUGHT BACK 100 BBLS OF RETURNS TO , , TIGER TANK . -PJSM FOR WELL KILL OPPS 4 1 1 02:30 - 04:00 1 1.50 KILLW DECOMP LINE UP AND BULL HEAD DOWN TUBING AND IA AT 7 BPM FOR 515 BBLS - STARTING WHP = 960 PSI , - INITIAL CIR PRESSURE AT 7 BPM 1450 PSI I -MAX CIRC PRESSURE WAS 3100 PSI ' j -FINAL CIR PRESSURE = 2500 PSI KILLW -INITIAL SHUT IN PRESSURE WAS 960 PSI 04:00 - 06:00 2.00 DECOMP MONITOR & BLEED OFF OF WHP PRESSURE ,/ ' FROM 960 PSI - PRESSURE SLOWLY BLED DOWN TO 360 PSI • IN 30 MIN i -BLED OFF 340 PSI TO 20 PSI AND SHUT IN - 3 BBLS RETURNS - PRESSURE SLOWLY CAME BACK TO 150 PSI I . AND STABILIZED ' -BLED OF TO 50 PSI AND SHUT IN - 1.5 BBLS , RETURNS ' I - PRESSURE SLOWLY BUILT TO 180 PSI 06:00 - 09:30 3.50 KILLW DECOMP I CONTINUE TO MONITOR PRESSURE BUILDUP ' IN WELL -TOTAL PRESSURE GAIN IN 3.5 HOURS = 350 PSI (100 PSI PER HOUR). -FINAL PRESSURE = 400 PSI 09:30 - 11:00 ' 1.50 KILLW DECOMP MANUALLY STRAP PITS, LINE UP CHOKE MANIFOLD THROUGH GAS BUSTER. BLED ' OFF 400 PSI (1.5 BBLS 12.1 PPG BRINE ' RETURNED) TO ZERO. GAS IN RETURNS AT END OF BLEED CYCLE. WELL SHUT BACK IN. - PRESSURE BUILT BACK UP FROM 0 PSI TO 130 PSI IN 50 MIN (2.5 PSI PER MIN). 11:00 - 11:30 0.50 KILLW DECOMP CIRCULATE THROUGH HYDRAULIC CHOKE AND GAS BUSTER. NO LOSSES OR GAINS MEASURED IN PITS. PUMPING AT 50 SPM, 178 GPM, 200 PSI. SHUTDOWN PUMPS. 11:30 - 12:30 1.00 KILLW DECOMP FLOW CHECK WELL. NO FLOW. 12:30 - 13:00 0.50 KILLW ' DECOMP WELL BEGAN FLOWING AT LOW RATE. SHUT IN WELL AND MONITORED. WHP INCREASED TO 10 PSI OVER 15 MINUTES. Printed 7/5/2011 9:31:13AM orth A merica - ALA BP Page 4 of 3,1:., peration. Summary Report . , Common Well Name: MPF-80 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 i End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point ' Site: M Pt F Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 10/28/1998 12:00:00AM 1Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To I Hrs Task ' Code NPT NPT Depth I Phase Description of Operations (hr) (ft) HI 13:00 - 17:00 4.00 KILLW DECOMP RE -OPEN WELL AND CONTINUE TO 1 1 1 I FLOWCHECK. LINED UP THROUGH I HYDRAULIC CHOKE AND GAS BUSTER TO MUD PITS. I - INITIAL FLOW RATE FROM WELL 1 I ; APPROXIMATELY 1 BBL PER 10 MIN FOR • I FIRST HOUR 1 -FLOW RATE DROPPED DURING SECOND 1 HOUR TO APPROXIMATELY 1 BBL PER 20 MIN -FLOW RATE DROPPED OFF TO TRICKEL Ii I 'AND DROPS DURING 3RD AND FOURTH , i HOURS OF FLOW CHECK. I ' -TOTAL FLUID RETURNED TO PITS OVER I r FOUR HOUR PERIOD = APPROXIMATELY 10 BBL_ 1 17:00 - 20:00 I 3.00 1 KILLW DECOMP l WELL SHUT -IN AT HYDRAULIC CHOKE AND MONITORED. 1 - PRESSURE BUILT UP TO 50 PSI IN FIRST 30 ' I 1 MIN - PRESSURE BUILT UP TO 60 PSI AFTER 1 ' HOUR. ' - PRESSURE BUILT TO 70 PSI AFTER 1.5 `HOURS. -PRESSURE BUILT TO FINAL 90 PSI AFTER 3 HRS 120:00 - 22:00 2.00 KILLW DECOMP OPEN CHOKE AND MONITOR FLOW AND VOLUME EVERY 10 MIN - INITIAL SHUT IN PRESSURE 90 PSI -BLEED TO 0 PSI IMMEDIATELY WITH VERY I SMALL AMOUNT OF FLOW -FLOW SLOWLY DIMINISHED TO A VERY I SMALL DRIBBLE 22:00 - 23:35 1.58 KILLW 1 F 7 DECOMP 1 SHUT IN TO MONITOR AND PRESSURE j SLOWLY RISING I -10 PSI IN 10 MIN THEN NO CHANGE j -OPEN BLEEDER ON CHOKE MANIFOLD AND W 1 GOT GAS RETURNS -OPEN BLEEDER ON IA AND GAS ONLY -SHUT IN AND WAIT ON DSM TO DO A FLUID SHOOT - PRESSURE BUILT TO 30 PSI IN 30 MIN -TOOK FLUID SHOT SHOWING FLUID AT • SURFACE I -BLEED OFF ALL PRESSURE THROUGH CHOKE -FILL HOLE WITH CHARGE PUMP TOOK 3 BBLS TO GET RETURNS -HAS ONLY BLED BACK 1/3 OF A BBL SINCE 20:00 23:35 - 00:00 0.42 KILLW DECOMP CONSULT WITH TOWN AND PLAN TO LEAVE OPEN AND ALLOW TO BLEED OFF -OPEN CHOKE AND GETTING SMALL AMOUNT RETURNS 5/24/2011 00:00 - 03:40 3.67 KILLW P DECOMP CONTINUE TO MONITOR WELL WITH VERY ' SMALL RETURNS -00:10 GAINED — 1/2 BBL THEN NO FLUID FLOW, BUT STILL VENTING GAS I Printed 7/5/2011 9:31:13AM orth America - ALASKA - BP Page 5 of 31 . , peration Summary Report Common Well Name: MPF -80 1AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 I End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point -I Site: M Pt F Pad L Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM 1 Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date I From - To ' Hrs Task Code 1 NPT I NPT Depth 1 Phase I Description of Operations (hr) (ft) 0340 04:00 0.33 KILLW P DECOMP FILL HOLE W WITH 3 BBLS FROM CHARGE PUMP TAKING RETURNS THROUGH GAS BUSTER. I -3 BBLS TO FILL HOLE '- CONTINUE TO CIRCULATE FOR 5 MIN AND OBTAIN A 20 BPH LOSS RATE i 04:00 - 05:45 1.75 KILLW P DECOMP NO FLOW WITH NO GAS RETURNS I -04:45 HAD A 3 BBL GAIN THEN NO FLUID FLOW -BLED OFF GAS TO STATIC, NO FLOW 1 05:45 - 06:00 0.25 KILLW P 1 I DECOMP CONTINUE TO MONITOR WELL 1 WELL BEGAN TO FLOW AGAIN : -1/2 BBL BROUGHT. BACK GAS CONTINUING TO BREAK OUT 06:00 - 11:00 5.00 KILLW 1 P DECOMP j CONTINUE TO MONITOR WELL. 1 - TUBING AND IA IS OPEN & LINED UP T THE GAS BUSTER. I - SMALL AMOUNT OF GAS IS VENTING, 5 -10 PSI , WITH NO FLOW. - PLAN FORWARD IS TO CONTINUE TO MONITOR THE WELL, LOOKING FOR AT ' , LEAST AN HOUR OF STATIC CONDITION. IN .ORDER TO HAVE A STABLE KWF BARRIER BEFORE ND OF TREE. CALLED AOGCC WITH UPDATE OF OUR STATUS @ 11:15 1- CHUCK SHEAVE CALLED BACK AND ASKED I I TO BE UPDATED AT 19:00 TONIGHT. 11:00 16:30 I 5.50 KILLW P DECOMP CONTINUE TO MONITOR RETURNS 16:30 18:00 1.50 KILLW P DECOMP THROUGH CHOKE AND GAS BUSTER I ' HO FLUID SHOT WELL -FLUID NEAR SURFACE -FILL HOLE WITH 6 BBLS AT 17:00 HRS AND / I SHUT DOWN TO MONITOR V -VENT SMALL RETURNS THROUGH GAS BUSTER AND OPEN CHOKE 18:00 - 23:00 5.00 KILLW P DECOMP SHUT IN WELL AND MONITOR -0 TO 10 PSI IN 1 HOUR -OPEN UP AND CONTINUE TO VENT ,THROUGH GAS BUSTER -21:30 FIRS FILL HOLE AGAIN WITH 6 BBLS - MONITOR SMALL RETURNS THROUGH GAS BUSTER -23:00 FLOW STOPPED 23:00 - 00:00 1.00 KILLW P DECOMP WELL IS ON A SLIGHT VAC AT THE CHOKE AND IA -FILL HOLE WITH 3 BBLS - CIRCULATE DOWN TUBING OUT IA FOR 17 MIN -LOST 4 BBLS -SHUT DOWN CHARGE PUMP AND WELL IS ON SLIGHT VAC AT CHOKE MANIFOLD -PIT WATCHERS STRAP IS - 6 BBLS FOR 21 BPH LOSS RATE - CONTINUE TO MONITOR VAC -AT 23:45 CONTINUE TO CIRC WITH C PUMP WITH LOSSES TO KEEP FULL DURING CREW CHANGE TIME. LOSSES FOR THE DAY = 28 BBLS 1 Printed 7/5/2011 9:31:13AM I orth America - ALASKA BP Page f peratian Summary Report _, ------ . ___ Common Well Name: MPF -80 ; AFE No Event Type: PLUG AND ABANDON (PXA) I Start Date: 5/21/2011 End Date: 6/12/2011 1Z3 -001 LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 I Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. I UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs Task 1 Code I NPT I NPT Depth ' Phase 1 Description of Operations 1 (ft) 5/25/2011 00:00 00:30 0.50 KILLW P r DECOMP CONTINUE TO CIRCULATE DOWN TUBING, OUT THE IA, THROUGH THE CHOKE, AND GAS BUSTER BACK TO THE PITS WITH 15 TO ' 20 BPH LOSS RATE 00:30 - 01:15 0.75 KILLW P ! F DECOMP SD CHARGE PUMP AND MONITOR I -SMALL AMOUNT OF DIMINISHING RETURNS -WELL IS ON A VAC AT 00:35 HRS I -LOST 7 BBLS CIRCULATING FOR A 15 BPH I LOSS RATE -CALL OUT DSM FOR TWC _ C -RU TO CIRCULATE IN IA FOR ND OPPS 1 01:15 - 02:00 0.75 KILLW P DECOMP ' -CHECK IA BEFORE RU AND HAVE 5 PSI OF I GAS THAT DOES NOT BLEED OFF FAST -RE RIG UP TO SAME AS BEFORE: I- CHARGE PUMP TO TUBING, RETURNS OUT IA , TO THE CHOKE, TO GAS BUSTER, TO PITS r — - — 02:00 - 03:30 1.50 KILLW P ' DECOMP -STILL VENTING LOW PRESSURE GAS 1 THROUGH OPEN CHOKE TO GAS BUSTER. 03:30 - 04:00 0.50 KILLW ' P DECOMP -STILL SMALL AMOUNT OF GAS RETURNS AT CHOKE. FILL HOLE WITH 10 BBLS AND CONTINUE TO CIRCULATE -FOR 30 MIN WITH INITIAL LOSS RATE OF 20 1 BPH SLOWING TO 15 BPH 1 04:00 - 05:00 1.00 KILLW I P DECOMP SD CHARGE PUMP AND MONITOR -WELL IS ON A VAC LEFT OPEN TO GAS . BUSTER -04:45 WELL IS STILL ON VAC. SHUT #5 VALVE ON CHOKE MANIFOLD TO ISOLATE GAS BUSTER AND MONITOR THROUGH BLEEDER -05:00 WELL IS STATIC 05:00 - 05:30 0.50 KILLW P 1 DECOMP FILL HOLE WITH CHARGE PUMP AND WELL I TOOK 6 BBLS TO FILL 1 1 - CONTINUE TO CIRCULATE WHILE WAITING FOR DSM. 05:30 - 08:00 2.50 WHSUR P DECOMP RU AND TEST LUBRICATOR TO 250 / 4,000 PSI FOR 5 CHARTED MINUTES. -SET TWC -TEST FROM BELOW AT 1 -1.33 BPM TO INJECT AT 500 PSI -BULL HEAD 23 BBLS KWF DOWN THE IA AND BLEED BACK 2 BBLS. - PRESSURE TEST FROM ABOVE TO 4,000 PSI FOR 10 CHARTED MINUTES. -R /D LUBRICATOR. 08:00 - 10:00 2.00 WHSUR P DECOMP FMC WELL HEAD REP BLEED OFF ADAPTER VOID. -PJSM -N /D 2 9/16" PRODUCTION TREE. - 8 RD. EUE HANGAR THREAD, M/U 10 TURNS. 10:00 - 11:30 1.50 ' BOPSUR P DECOMP PJSM -N /U 13 -3/8" BOP STACK - ANNULAR, 2 -7/8" X 5" VBR, BLIND SHEAR RAMS, MUD X- CROSS, 2 -7/8" PIPE RAMS. - AOGCC STATE INSPECTOR LOU GRIMALDI CALLED AT 10:30 FOR UP DATE ON TEST TIME. Printed 7/5/2011 9:31:13AM . ortft America - A LASKA - BP Page 7 o pe " ration - Summary Report . Common Well Name -- C : MPF-80 AFE No Event Type: PLUG AND ABANDON (PXA) I Start Date: 5/21/2011 I End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) — — I 1 Project: Milne Point , Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs ' Task Code NPT NPT Depth Phase I Description of Operations - (hr) I P l (ft) 1 1 :3 12:30 1.00 BOPSUR I DECOMP R/U TEST EQUIPMENT - FUNCTION TEST ' * *BILL HOPKINS, ALLEN GRAFF ADW HSE, ' : BEN BEARDEN DOYON SAFETY. 12:30 - 21:00 '� 8.50 BOPSUR P DECOMP ; PJSM AND GREASE CHOKE AND BOP 1 VALVES. TEST BOPE PER WELL PLAN, PERMIT TO cVP ' [DRILL, AND AOGCC REGS. TEST WITNESS WAIVED BY LOU GRIMALDI p ' -RAMS TESTED TO 250 PSI LOW AND 4,000 PSI HIGH. I -HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH -TEST USING 2- 7 /8'AND 4" TEST JOINTS. i PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL / DDI TP. ' I -ALL TEST FOLLOW TESTING CRITERIA ' I DOCUMENTED IN CRT - AK -10 -45 - MAINTAINING -8 BPH CONTINUOUS HOLE FILL IN THE IA DURING TESTING. AOGCC STATE INSPECTOR LOU GRIMALDI ;WAIVED STATES RIGHT TO WITNESS BOPE _ TEST @ 12:20 HRS 5 -25 -2011 21:00 - 22:00 1.00 1 BOPSUR P DECOMP KOOMEY DRAW DOWN TEST: -2800 PSI DRAWN DOWN TO 1500 PSI. I -200 PSI INCREASE IN 20 SECONDS. -FULL PRESSURE IN 95 SECONDS. ! -5 N2 BOTTLES @ 1850 PSI. ' I TIMED PREVENTER CLOSING LOWER RAMS = 8 SEC. UPPER RAMS = 8 SEC. ANNULAR PREVENTER = 34 SEC @ 750 PSI BLIND RAMS = 17 SEC @ 800 PSI ' 22:00 - 00:00 2.00 BOPSUR P DECOMP RD TEST EQUIPMENT DERRICK INSPECTION CLEAN OUT STACK AND CLEAN OFF TOP OF TWC CLEAN AND CLEAR RIG FLOOR CREW CHANGE LOSSES FOR THE DAY = 149 BBLS 5/26/2011 00:00 - 02:30 2.50 ' BOPSUR P DECOMP RU OPSO -LOPSO AND TOO SHORT, ADD 4 FT PUP JOINT !RU PUMP IN SUB AND DSM LUBRICATOR ' PT TO 250 LOW / 4000 PSI HIGH ' , ' - 5 TO 10 PSI PRESSURE ON IA PLAN TO BLEED OFF & CIRCULATE -PULL TWC 02:30 - 04:00 1.50 I BOPSUR P DECOMP CIRCULATE DOWN TUBING THROUGH PUMP, IN SUB AND OPSO- LOPSO, OUT THE IA -DUMP -25 BBLS DIRTY RETURNS OUTSIDE 1 COMMING BACK AT 11.5 TO 11.9 PPG -SHUT DOWN PUMP SHUT IN AND MONITOR ' ' FOR PRESSURE Printed 7/5/2011 9:31:13AM orth America = ALASKA - BP Page 8 of 31 Aeration Summary Report �___ J Common Well Name: MPF -80 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 End Date: 6/12/2011 1Z3 -001 LV (3,000,000.00 ) Project: Milne Point j Site: M Pt F Pad Rig Name /No.: DOYON 16 � Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. [UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT . Depth I Phase Description of Operations 04:00 04:45 075 BOPSUR DECOMP (hr) (ft) - I ` P I � ! 20 PSI IA AND 10 PSI WHP - CIRCULATE DOWN IA RETURNING THROUGH THE TUBING OUT DSM PUMP IN SUB I ! THROUGH CHOKE MANIFOLD TO GAS 1 BUSTER DUMPING DIRTY RETURNS OVER BOARD I ! i 12.2 IN AND 11.9 OUT @ 15 BBLS AWAY !12.2 IN AND 12.15 OUT @ 23 BBLS AWAY - BRING RETURNS BACK INSIDE - ESTABLISH LOSS RATE -8' BPH LOSS RATE ' 12.2 IN AND 12.09 OUT SHUT DOWN TO MONITOR WITH 12.1 _ RETURNS 04:45 - 10:30 5.75 BOPSUR P I! , DECOMP I SHUT DOWN PUMPS AND CLOSE IN AT I !CHOKE MANIFOLD . -04:50 CHOKE MANIFOLD IS STATIC AND IA IS I FLOWING -SHUT IN AND ALLOW PRESSURE TO BUILD / FLUIDS TO MIGRATE -05:10 NO PRESSURE READING BUT VENTING SMALL AMOUNT OF GAS VENTING AT CHOKE ! MANIFOLD. -LINE UP AND VENT THROUGH GAS BUSTER - - CIRCULATE DYNAMIC, 6 -BBLS TO FILL WELL LOSS RATE 12 -BPH - CIRCULATE FROM 07:00 TO 10:00 WITH 6 BPH LOSS RATE. 10:30 - 12:00 1.50 BOPSUR P DECOMP PJSM -R/D LUBRICATOR & OPSO -LOPSO I -M /U LANDING JNT WITH TIW VALVE. & I CONTINUE TO CIRCULATE DYNAMIC WITH CHARGE PUMP, LOSS RATE 6 -BPH -RID DSM 12:00 - 14:00 2.00 WHSUR 1 P DECOMP I- CONTINUE TO CIRCULATE DOWN THE TBG. & UP THE IA, THROUGH CHOKE TO GAS BUSTER -6 -BPH LOSS, 12.2 PPG BRINE. -FMC REP BOLDS, UD TBG HANGER AND 1 JT 2 7/8" TBG AND 1 ADDITIONAL PUP 14:00 - 20:00 6.00 FISH P DECOMP P/U M/U BAKER SPEAR BHA #1, RIH WITH BHA ON 2 -7/8" HT PAC DP FROM PIPE SHED 1X1. -TAG OBSTRUCTION AT 230' MD - CIRCULATE AND WORK OBSTRUCTION, AT 1 -2 BPH / 490 -1130 PSI, WITH NO JOY. -POH / MU HEAD PIN TO CIRCULATE OUT BHA W AND DIRTY RETURNS -LD BHA , -KUPARUK RIVER WENT OUT —16:00 HRS. RWO SUPERINTENDENT TRAPPED AT MPU. Printed 7/5/2011 9:31:13AM ' orth America - ALASKA - BP . Page 9 of 31 peratiqh Summary Report Common Well Name: MPF -80 1 AFE No Event Type: PLUG AND ABANDON (PXA) 1 Start Date: 5/21/2011 End Date: 6/12/2011 11,Z3-001LV (3,000,000.00 ) Project: Milne Point I Site: M Pt F Pad ' Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM 1Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 ©43.25ft (above Mean Sea Level) Date 1 From - To Hrs Task 1 Code NPT I NPT Depth 1 Phase 1 Description of Operations 1 (hr) 1 1 f 1 (ft) 20:00 21:30 1.50 FISH P DECOMP PU & MU CUT LIP SHOE ASSEMBLY - BHA #2 5 -3/4" TSS CUT LIP SHOE ' 1 5-3/4" TSS POOR BOY ROPE GRAB 1 JOINT 5 -3/4 WASH PIPE 5 -3/4" WASH OVER BOOT BASKET • 4 -3/4" BOWEN BUMPER SUB I XO 3 -1/2 IF x XT 39 -RIH WITH 1 JOINT 4" DP - INSTALL HEAD PIN AND CIRCULATE TO I CLEAN UP RETURNS 21:30 - 23:00 1.50 FISH I P ' DECOMP I- CONTINUE IN HOLE ON 4" DP CIRCULATING 1 1IN 1-ROTATE DOWN AT 10 RPM FROM 121 FT TO 1176 FT - STARTED TAKING WEIGHT 1000# '- CONTINUE ROTATING DOWN TO 181 FT 1 WITH A LITTLE MORE WEIGHT -PU NO ROTATION WITH SOME DRAG 23:00 - 00:00 1.00 FISH P DECOMP 1POH / LD BHA #2 ONE CHUNK OF RUBBER IN CUT LIP GUIDE CLEAN AND CLEAR RIG FLOOR LOSSES FOR THE DAY ARE 163 BBLS AND . DUMPED 87 BBLS ' MAINTAIN CONTINUOUS HOLE FILL WITH 12.2 • TO 12.1 KILL WEIGHT FLUID FOR THE DAY STILL GETTING DIRTY EMULSIFIED OIUBRINE _ .RETURNS FROM TUBING 5/27/2011 00:00 00:30 0.50 FISH P DECOMP BRING IN, MU AND PU ROPE SPEAR BHA - BI-1A# 3 3 -1/2" CRANK SHAFT ROPE SPEAR 3 -1/2" DRAIN SUB ' - 4 -3/4 BOWEN BUMPER SUB 1 _ _ _ XO 3-1/2" IF BY 4" XT 39 00:30 0 - 01:30 ' 1.00 FISH P - DECOMP I - . ' ' RIH ON 5 JOINTS OF 4" DP - TAG AT 145 FT AND WORK DOWN TO 155 FT - STACKING 2 TO 5 K #'S AND ROTATING 1 TURN AFTER STAKING DOWN 3 TIMES -PU WITH OVER PULL OF 5 TO 6 K THEN ' BROKE OVER (PARTED CABLE) -POOH AND RECOVERD ABOUT 20 FT OF ESP CABLE Printed 7/5/2011 9:31:13AM arth Ame rica - ALASKA BP Page 10 of 31 perati Summa Rep Common Well Name: MPF -80 �. vv 1 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 I End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) - -- - - -- I Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM I Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs Task Code I NPT 11 NPT Depth, Phase Description of Operations ' 01:30 06:30 5.00 FISH 1 P (ft) DECOMP -CONTINUE TO RIH WITH BHA #3 MULTIPLE I TIMES I -RUN 2 RECOVERED 15 TO 20 FT OF ESP I CABLE , I -RUN 3 RECOVERED 25 FT OF ESP CABLE THAT STRANDED THE SHIELDING TO SURFACE -RUN 4 RECOVERED ESP ARMOR/SHIELDING 1 I WAD -RUN 5 RECOVERED 10 FT OF UN- ARMORED 'ESP CABLE -RUN 6 RECOVERED 12 FT OF ESP CABLE I -RUN 7 RECOVERED 9 FT OF ESP CABLE AVERAGE LOSSES HAVE BEEN - 8 BPH ' MAINTAIN CONTINUOUS HOLE FILL WITH 12.2 TO 12.1 KILL WEIGHT FLUID FOR THE DAY STILL GETTING DIRTY EMULSIFIED OIUBRINE RETURNS FROM TUBING 06:30 - 21:00 14.50 FISH P DECOMP ' -RUN 8 RECOVERED 12 FT OF ESP CABLE.e,5‘ -RUN 9 RECOVERED 10 FT OF ESP CABLE. -RUN 10 RECOVERED 5 FT OF ESP CABLE. -23 6 c ' -RUN 11 RECOVERED 18 FT OF ESP CABLE. -RUN 12 RECOVERED 25 FT OF ESP CABLE. -RUN 13 RECOVERED 60 FT OF ESP CABLE. LOSS RATE INCREASING TO 13 BPH WITH ' CONTINUOUS HOLE FILL. -CBU AT 6 BPM/450 PSI AND RECOVERED 10 I GAL RUBBER FROM ESP INSULATION. -RUN 14 RECOVERED 102 FT OF ESP CABLE. I @17:00 HRS. -WASH EACH JOINT DOWN PRIOR TO ENGAGING FISH. -WORK DOWN 2 FT PAST TAG WITH 2 K @ ' 520 FT -START TO PULL BHA AND HAD TO STAB BACK IN AND CBU TO CLEAR -RUN 15 RECOVERED A SMALL AMOUNT OF ' ESP CABLE ARMOR -LOSS RATE INCREASING TO 14 BPH. ** *ONE INCIDENT SEE REMARKS. * ** 21:00 - 21:30 0.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR SAFETY MOMENT WITH RIG CREW ABOUT UNKNOWN / UN -SEAN HAZARDS 21:30 - 23:30 2.00 FISH P DECOMP RIH WITH ROPE SPEAR FOR RUN # 16 -TAG WITH 3 K WORK SAME SPOT @ 520 FT (FISH SHOULD BE AT -544 FT) -TRY TO PULL SPEAR & CBU TO CLEAR OUT BHA -PULL IT WITH NO MORE FISH -LD ROPE SPEAR BHA * * ** ROPE SPEAR RECOVERED A TOTAL OF 368 FT OF ESP CABLE Printed 7/5/2011 9:31:13AM orth America - ALASKA - BP Page 41 of 31 40 peratIon Summary Report Common Well Name: MPF -80 _.- _.__ - ___-___- - -- ° _ No �� -� Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 1 End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) I Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 ©43.25ft (above Mean Sea Level) Date From - To Hrs 1 Task i Code . NPT NPT Depth Phase Description of Operations 1 (hr) (ft) 23:30 00:00 0.50 FISH P , DECOMP I CLEAN AND CLEAR RIG FLOOR CREW CHANGE MAINTAIN CONTINUOUS HOLE FILL WITH 12.1 KILL WEIGHT FLUID FOR THE DAY STILL GETTING DIRTY EMULSIFIED OIUBRINE RETURNS FROM TUBING l i LOSSES FOR THE DAY = 246 BBLS 5/28/2011 00:00 - 02:30 2.50 FISH P DECOMP PU AND MU BHA #4 WITH 6 4-3/4 DC, JARS, `BUMPER SUB, REVERSE CIRC JUNK BASKET !RIH AND TAG AT 520 FT ATTEMPT TO MILL ' DOWN HAD TO CIRCULATE OUT BHA 2 TIMES TO , CLEAR OUT MAINTAIN CONTINUOUS HOLE FILL WITH 12.1 'KILL WEIGHT FLUID FOR THE DAY STILL GETTING DIRTY EMULSIFIED OIUBRINE RETURNS FROM TUBING 1 _ LOSS RATE —12 BPH 1 02:30 - 03:15 0.75 I FISH P DECOMP PARAMETERS: 55 K DOWN WT, 52 K UP WT, 1.5 TQ CIR PRESS NO BALL 540 PSI - 630 PSI WITH BALL ON SEAT TAG AT 520 FT MILL DOWN WITH 2 K TO 10 K WT ON BIT , MILL TO 522 WITH 10 K AND NO MORE HOLE 03:15 - 04:30 1.25 ' FISH P DECOMP POH BREAK DOWN RCJB RECOVERED — 2 FT OF ESP ARMOR STRAND IN BASKET AND NOTHING ELSE PIT WATCHER RECOVERED —2" x 4" CHUNK 1 OF ROTTED TUBING LOSSES —11 BPH SINCE 00:00 04:30 - 07:30 1 3.00 FISH P DECOMP MU AND RUN MILLING JUNK BASKET BHA AGAIN -TAG UP @ 05:00 DRY MILL WITH 1 TO 3K WOB - CIRCULATE THROUGH HOLE FILL ONLY TO KEEP HOLE FULL BUT NOT DOWN DRILL PIPE - OBSERVED 30K OV ER PULL @ 526' MD. 07:30 - 08:00 0.50 FISH P DECOMP LID BHA #4 -1/3 OF RCJB FINGERS MISSING. -NO RECOVERY 08:00 - 09:00 1.00 FISH P DECOMP i M/U BHA #5 ROPE SPEAR -RIH TAG @ 522' - ATTEMPT TO ENGAGE ESP CABLE, NO TORQUE NOTED. ' 09:00 - 10:00 1.00 FISH P DECOMP ' POH WITH BHA #5, NO ESP CABLE RECOVERED. 10:00 - 11:00 1.00 FISH P DECOMP M/U 2.44" ITCO SPEAR BHA -RIH TO510'MD 11:00 - 11:30 0.50 FISH P DECOMP CIRCULATE SPR =20 /SPM 1600 PSI, 30 SPM / 2940 PSI -PJSM FOR JARRING FISH. - ENGAGE SPEAR AT 522' MD. -@ 11:30 PULL 130K, AND PARTED THE PIPE. -FLOW CHECK, NO INCREASE NOTED. 11:30 - 12 :00 0.50 FISH P DECOMP POH FROM 522' MD WITH FISH. Printed 7/5/2011 9:31:13AM orth America LA - BP Page 12 of 31 p eretianl Summary' Report Common Well Name: MPF -80 AFE No ��� — Event Type: PLUG AND ABANDON (PXA) I Start Date: 5/21/2011 I End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point I Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. I UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) ' — 12:00 12:30 ; 0.50 FISH P DECOMP CREW CHANGE AND PJSM @ 12:00 1 12:30 - 14:00 1.50 1 FISH 1 P I r rDECOMP I B/O UD FISH. ! - RECOVERED 2.44' SECTION, 2 JNTS., 11.76' ! t SbC I ION OF 2 -7/8" TBG I I -(2) LA SALLE CLAMPS. h- 60' OF ESP CABLE. , 14:00 - 15:30 1.50 FISH P DECOMP CLEAN RIG FLOOR REMOVE FISH FROM SPEAR @ DOYON SHOP. 15:30 - 17:45 2.25 , FISH P I DECOMP ' M/U 2.44" ITCO SPEAR AND RIH I -CBU 1.5 BPM / 800 PSI I - ENGAGE SPEAR @ 598' MD -PULL 130K, AT 17:45 HRS. PARTED PIPE. 17:45 - 18:30 T 0.75 FISH 1 P I DECOMP 1 , PERFORM DERRICK INSPECTION AFTER I FISHING ATTEMPT -. 18:30 - 20:00 I 1.50 FISH P DECOMP I POH, B/O UD FISH. RECOVERED 19.53' SECTION, 1 JNT, 12.88' SECTION OF 2 -7/8" TBG I -(1) LA SALLE CLAMPS. 60' OF ESP CABLE 20:00 - 00:00 4.00 FISH P I DECOMP M/U 2.44" ITCO SPEAR BHA , -CBU X2 1.5 BPM / 1170 PSI PU-54K SO-52K - ENGAGE SPEAR @ 665' MD ! -PULL 145K AND HOLD 2 MINUTES - AT 2 MINUTES, PIPE PARTED. NEW PU - 52K -WORK PIPE FREE: 150K UP WT FOR 4 HRS AND MADE -30 FT. -LOSS RATE SLOWS TO -10 BPH. ! -WORK PIPE : 155K UP WT FOR 3HRS AND I_ I MADE -30 FT. 5/29/2011 00:00 - 00:30 0.50 FISH P DECOMP [CREW CHANGE AND PJSM @ 00:00 00:30 01:30 1.00 FISH P _ - - -- DECOMP POH, B/O LID FISH. - RECOVERED 12.45' SECTION OF 2 -7/8" TBG -NO CLAMPS OR CABLES 01:30 03:00 1.50 FISH P ' DECOMP M/U & RIH 2.44" ITCO SPEAR BHA 7 -CBU 2 BPM / 1680 PSI f -PU-54K SO -52K - ENGAGE SPEAR @ 678' MD All -PULL 150K AND PIPE PARTED. NEW PU - 1 52K. 03:00 04:00 1.00 FISH P DECOMP POH, B/O UD FISH. - RECOVERED 4.55 SECTION OF 2 -7/8" TRC; ' -NO CLAMPS OR CABLES - TUBING WON'T RELEASE FROM SPEAR. 04:00 - 05:30 1.50 FISH P DECOMP CUT TUBING OFF OF SPEAR. 05:30 06:00 0.50 FISH P DECOMP WELL CONTROL DRILL / AAR. WITH BP GLOBAL WELL CONTROL WSL ASSESSOR. -CREW RESPONSE WAS SCORED 100 % 06:00 - 07:30 1.50 FISH P DECOMP M/U & RIH WITH ROPE SPEAR -CBU X2 AT 6 BPM / 130 PSI. -PU-54K SO-52 - ROTATE ROPE SPEAR AND TAG FISH AT 683' MD. -PULL 5K OVER AND FLOW CHECK. 07:30 - 08:30 1.00 FISH P DECOMP POH, 13/0 LID FISH. -RECOVERED 27 FT ESP CABLE. I -B /O LID ROPE SPEAR, 10 FT PUP Printed 7/5/2011 9:31:13AM me A 3 f [C ALASKA - BP orth Q Page 13 , a peration Summary Report ; Common Well Name: MPF -80 I AFE No Event Type: PLUG AND ABANDON (PXA) I Start Date: 5/21/2011 End Date: 6/12/2011 IZ3 -001LV (3,000,000.00 ) Project: Milne Point I Site: M Pt F Pad I Rig Name /No.: DOYON 16 , Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. IUWI.500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs Task Code NPT ' NPT Depth I Phase I Description of Operations (ft) L 1 08:30 10:00 1.50 I FISH I P DECOMP rM /U 4 1/8" CLOSE CATCH OVERSHOT, EXTENSION, XO, XO, PUMP OUT SUB, BUMPER SUB, JARS, 6 EC 4 3/4" SDC, XO = 217.01 FT -RIH TO 680' MD I -CBU AT 6 BPM / 145 PSI. - PU-56K SO -52K ,TAG OUT 2 FT HIGH (CABLE ?)671" MD. 10:00 - 11:00 1.00 I FISH P DECO MP ! POH FROM 681' MD -BO UD OVERSHOT -NO 11:00 - 11:30 0.50 FISH P DECOMP RECOVERY M/U 6 "X4.75" ROUGH ID MILL SHOE - PU-56K SO-53K I - 54K -RT WT, 40 RPM AT 1.3K FREE TQ, 5 BPM , I I/ 180PSI. ! I -MILL 3 FT WITH NO PUMP, 40 RPM, 1 -3K I I TORQUE, 3.5 BPM/ 180 PSI, 3K -WOB. -TO 683' MD. 11:30 13:00 1.50 FISH P DECOMP T N - . RIH TAG JUNK (ESP CABLE) AT 681' MD I I - PU-56K SO-53K -MILL 3 FT WITH NO PUMP, 40 RPM, 1 -3K I TORQUE, 3.5 BPM / 180 PSI, 3K -WOB. -TO 683' MD. ■ 13:00 14:30 1.50 FISH I P DECOMP POH FROM 683' MD - RECOVERED 4 FT CABLE. 1 14:30 - 16:00 1.50 FISH P DECOMP KICK WHILE TRIPPING DRILL WITH DAY CREW. I I I -11 BBLS PIT GAIN -WELL SECURED LESS THE 1 MINUTE. ' -WHILE RECORDING WELL HEAD SHUT -IN !PRESSURE THE H2S ALARM WAS SET OFF I BY THE RIG ELECTRICIAN AND A RIG EVACUATION DRILL HELD. - DURING THE SWEEP OF THE RIG A MAN DOWN DRILL WAS INCLUDED. I -AAR HELD WITH 22 WORKERS. LL: EMERGENCY SHUT DOWN SYSTEM FAILED AT THE DRILLER CONSOLE. LL: CHECK WIND DIRECTION. LL: WHILE THE H2S MESSAGE AND ALARM IS BEING TRANSMITTED, -THE GI- TRONIC CAN NOT BE USED. 16:00 22:30 6.50 FISH 1 N RREP DECOMP RIG ELECTRICIAN SERVICE AND OR MAKE REPAIRS TO EMERGENCY SHUT DOWN I SYSTEM THAT FAILED AT THE DRILLER CONSOLE. Printed 7/5/2011 9:31:13AM artht America = ALASKA BP Page 14 of peration Summary Retort' Common Well Name: MPF -80 AFE No Event Type: PLUG AND ABANDON (PXA) I Start Date: 5/21/2011 End Date: 6/12/2011 I Z3 -001 LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 1 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date ' From - To I Hrs Task Code ', NPT NPT Depth ! Phase Description of Operations h (ft) ( ) 22:30 DECOMP CONTINUE TO REPAIR RIG r 00:00 1.50 FISH T N RREP i I I - WEEKLY CREW SAFETY MEETING !- REVIEW OF OUTSTANDING ACTION ITEMS -REVIEW OF STOP CARDS - REVIEW OF RECENT INCIDENT / SAFETY ' 'REPORTS UNSEEN / UN KNOWN HAZARDS f- INTRODUCTION TO WELL CONTROL (PETEX VIDEO) I PRE TOWER MEETING_ LOSSES FOR THE DAY = 281 BBLS LOSSES FOR THE WELL =1656 BBLS CONTINUE WITH CONTINUOUS HOLE FILL AT I 12 TO 14 BPH - - - - - - -- 1_ - - - -- -- - -- 5/30/2011 00:00 - 04:00 4.00 N FISH ' RREP ? D ECOMP ' CONTINUE TO REPAIR RIG EMERGENCY ' SHUT DOWN SYSTEM I CONTINUE TO CONTINUOUSLY FEED HOLE j AT 12 TO 14 BPH WITH 12.1 PPG BRINE REPAIRS ARE DONE - FUNCTION TEST ESD SYSTEM -ESD SWITCH AT DRILLERS CONSOLE ' PROPERLY WORKS TO BLACK OUT RIG 04:00 04:45 0.75 FISH P I DECOMP IMU OVER SHOT BHA WITH : 4 -1/8" CLOSE CATCH OVERSHOT WITH 2 -7/8" I GRAPPLE 4 -1/8" OVERSHOT EXTENSION 4 -1/8" OVERSHOT DRIVE SUB XO'S PUMP OUT SUB JARS — i ^ 6 4-3/4" DRILL COLLARS I Printed 7/5/2011 9:31:13AM (Nth America. - ALASKA - BP Rage 15 of 31 Aeration Summary Re Common Well Name: MPF -80 AFE No Event Type: PLUG AND ABANDON (PXA) I Start Date: 5/21/2011 End Date: 6/12/2011 `Z3 -001 LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM i Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs I Task 1 Code ' NPT NPT Depth 1 Phase I Description of Operations ' (ft) 04:45 - 19:30 14.75 FISH P , DECOMP CBU PRIOR TO ENGAGING FISH GET PARAMETERS OF 53 UP AND 56 DOWN SET DOWN TO 682 FT WITH 1 TO 2 K SET DOWN TO 683 FT WITH 2 K AGAIN PU AND WE HAVE FISH SET DOWN TO 10 K I 1 PU AND SLOWLY WORK TO UP WT OF 150 K AND HOLD BO TO 145 K PU TO 150 K AND HOLD BO AND SLOWLY PU HOLE ***08:00 HRS GAVE 24HRS NOTICE. TALKED TO AOGCC INSPECTOR JOHN CRISP, AGREED TO UP DATE HIM WHEN FISH IS I FREE " "" -WORK PIPE FREE: 150 K UP WT FOR 4 HRS AND MADE —30 FT. I -LOSS RATE SLOWS TO —10 BPH. I , -WORK PIPE: 155KUPWTFOR3HRSAND • MADE —30 FT. -LOSS RATE SLOWS TO 8 -4 BPH. -2 BBLS PIT GAIN, PUMPS OFF FLOW CHECK, OBSERVED FLUID DROPPING IN STACK. I -11:30 HRS: STAND BACK 1 STAND 4" DP AND I CONTINUE TO WORK FISH UP HOLE WITH 155KUPWT. -13:30 HRS LOSS RATE SLOWS TO —1 BPH AND MADE 1 FT. PU SINGLE FROM PIPE SHED FOR MORE I I DOWN STROKE. -15:30 HRS LOSS RATE SLOWS TO LESS ' THEN A BPH AND MADE 1 FT. -CIRCULATE TO CLEAR DP OF CRUDE AT I I THE OVER SHOT. '- PERFORM POST JARRING INSPECTION (DERRICK & TOP DRIVE) ' 16:30 HRS: JAR UP 80 K TO 90 K START AT 582' MD 19:30 21:45 2.25 FISH P DECOMP ATTEMPT TO CIRCULATE A BU TO HELP CLEAN OUT TUBING - DUMPED 336 BBLS TO OUTSIDE THAT CAME BACK 11.4 PPG TO 11.9 PPG - CIRCULATE 4182 STKS (5415 FOR BU) AT 2.5 ' BPM AT 460 PSI ' -SHUT DOWN WITH 11.8 PPG TO 11.9 PPG FLUID IN RETURNS BUT NEED TO WAIT ON FLUIDS FROM W PAD -SHUT IN WELL WITH BAG TO HOLD BACK PRESSURE ON BACKSIDE WHILE WAITING SHUT IN PRESSURES ARE SICP= 0 PSI AND SIDPP =O PSI 21:45 - 00:00 2.25 FISH N WAIT DECOMP WAITING ON FLUIDS. WE HAVE 2 TRUCKS IN USE BUT ONLY ONE DRIVER ' I - CH2MHILL HAS PLENTY OF TRUCKS BUT NO DRIVERS Printed 7/5/2011 9:31:13AM - orth America - ALASKA BP' - , - ' Page 10 of 31 A erati on Su Report - - Common Well Name: MPF -80 AFE No Event Type: PLUG AND ABANDON (PXA) ! Start Date: 5/21/2011 End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. i UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To 1 Hrs Task Code NPT NPT Depth i Phase Description of Operations hr (ft) - - – ( ( 5/31/2011 00:00 01:00 1.00 FISH 1 N WAIT DECOMP ' CONTINUE TO WAIT ON FLUIDS/TRUCK NO PRESSURE UNDER BAG AND NO LOSSES I -OPENED BAG TO VERIFY FLUID LEVEL - FLUID IN THE STACK 01:00 - 02:45 1.75 FISH N FLUD , DECOMP ! OFF LOAD 200 BBLS OF 12.1 PPG BRINE TO ! PITS EMULSIFIED RETURNS HAVE SETTLED TO I `TOP OF PIT THREE -HAVE DIRTY VAC SUCK OFF THE TOP OF PIT -.' THREE - -- SUCKED OUT 26 BBLS OF HEAVILY EMULSIFIED RETURNS FROM PIT 3 -MADE PITS 3 & 4 OUR ACTIVE SYSTEM FOR PIT THREE TO BE OUR SETTLING PIT 02:45 - 04:30 ' 1.75 FISH , P ' DECOMP CHECK PRESSURES STILL 0 AND 0 PSI I , 'OPEN BAG - FLUID IS AT THE STACK AND STATIC CIRCULATE THROUGH BHA AGAIN TO CLEAN UP RETURNS CLEANED UP AFTER 10 BBLS START TO WORK PIPE TO 155 K (53 K UP WT PRIOR TO FISH ON) -PULL TO 100 K FOR JARRING -MULTIPLE PULLS AND 10 JAR LICKS ' -MADE 3 INCHES OF TRAVEL AT BEST -TOP OF FISH IS AT 594 FT 04:30 04:45 0.25 FISH P DECOMP TOP DRIVE INSPECTION FOLLOWING JARRING OPERATIONS WITH CURRENT TOP OF FISH AT 594 FT WELL IS STATIC WITH NO LOSSES ' DECOMP — / 04:45 05:45 ! 1.00 FISH P CONTINUE TO WORK PIPE WITHOUT MUCH V , SUCCESS PULL UP 155 K UP WEIGHT JAR AT 100 K CONSULT TOWN AND RWO SUPERINTENDENT ' 05:45 - 07:30 1.75 ' FISH P DECOMP ' ATTEMPT TO RELEASE OVERSHOT FORM TUBING, OVERSHOT WILL NOT RELEASE JARRING AT 140K LBS PULLING UP TO 160K ' ' LBS -DERRICK AND TOP DRIVE INSPECTION. ** *06:00 HRS TALKED TO AOGCC INSPECTOR JOHN CRISP, AGREED TO UPDATE HIM ! WHEN FISH IS FREE * ** 07:30 - 09:00 1.50 FISH P DECOMP SERVICE RIG - FORMULATE EXTRACTION PLAN 09:00 - 12:00 3.00 FISH P DECOMP JARRING AT MAX 150K LBS PULLING UP TO 175K LBS WITH PERIODIC DERRICK AND TOP DRIVE INSPECTIONS -PIPE FREE AT 178K LBS. - MONITOR WELL, NO GAINS NO LOSSES. ' ** *09:20 HRS TALKED TO AOGCC INSPECTOR JOHN CRISP, AGREED TO UP DATE HIM WHEN FISH IS FREE * ** 12:00 - 13:30 1.50 FISH P DECOMP STAND BACK ONE STAND - PERFORM DERRICK AND TOP DRIVE INSPECTION. - PERFORM DRAW WORKS INSPECTION. Printed 7/5/2011 9:31:13AM arth America ALASKA - BP Page 17 of 3 wink Operation Summary Report Common Well Name: MPF -80 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point I Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. , UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs I Task 1 Code NPT ! NPT Depth I Phase Description of Operations (hr) } (ft) 13:30 - 14:30 1.00 FISH P DECOMP POOH WITH FISH 57K LBS UP WT. TO BHA ** *13:45 HRS TALKED TO AOGCC INSPECTOR JOHN CRISP, AGREED TO A ONE HRS CALL OUT PRIOR TO TEST TIME. * ** 14:30 - 20:30 6.00 ' FISH P DECOMP FL/D FISHING OVER SHOT WITH FISH. - RECOVERED: -14 LASALLE CABLE CLAMPS. -28 FULL JTS 2 7/8" EUE 6.5# TBG. -25.35 FT PIECE. - =902 FT , -RECOVERED ALL BUT 50 FT OF ESP CABLE. LOST 1 LASALLE CLAMP TO HOLE -TOP OF FISH IS 1,482' MD WITH 50 FT OF I I I ,I ESP CABLE ABOVE FISH. -NO FLUID LOSS TODAY WITH 12.1# NABR BRINE. 20:30 - 22:00 1.50 P ' DECOMP FLUSH BOPSTACK -CLEAN AND CLEAR RIG FLOOR ' -SET AND TEST TUBING HANGER/TWC - ROLLING TEST FROM BELOW TO 500 PSI FOR 10 MIN -TEST FROM ABOVE 10 MIN 4000 PSI 22:00 00:00 2.00 I P DECOMP PJSM: CHANGE OUT LOWER BOP RAMS - CHANGE OUT LOWER PIPE RAMS FROM _ _! 2 -7/8" SOLID BODY TO 2 -7/8" X 5" VBR T 6/1/2011 00:00 02:00 2.00 BOPSUR P I DECOMP I RIG UP TO TEST BOPE I i -CROWN AND DERRICK INSPECTION ' 1 HOUR CALL TO AOGCC INSPECTOR JOHN CRISP FOR BOPE TEST WITNESS 02:00 - 08:00 6.00 ! BOPSUR P DECOMP PJSM BOPE TEST TEST BOPE PER WELL PLAN, PERMIT TO ' DRILL, AND AOGCC REGS. TEST WITNESSED BY AOGCC INSPECTOR Qo\ JOHN CRISP /(1 -RAMS TESTED TO 250 PSI LOW AND 4,000 PSI HIGH. ' - HYDRIL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH -TEST USING 2 -7/8" AND 4" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT - AK -10 -45 08:00 - 09:00 1.00 BOPSUR P DECOMP R/D TEST EQUIPMENT 09:00 - 18:00 9.00 FISH N RREP DECOMP WELDING SAFETY RESTRAINT LUG MOUNTS IN THE DERRRICK, (3) SAFTY LUGS. - WELDING'i' BEAM WEB STIFFENERS IN DERRICK, INSPECT BY N.O.V. INSPECTOR. - PASSED TUBOSCOPE MPI. - FILLED WELL DOWN IA BELOW TESTED TUBING HANGER, 4 BBLS TO FILL AFTER 12 HOURS Printed 7/5/2011 9:31:13AM . America , ALASKA - BP Page 18 of 31 . . Operation. Summary Report . . . . . . . .. Common Well Name: MPF-80 AFE No Event Type: PLUG AND ABANDON (PXA) I Start Date: 5/21/2011 I End Date: 6/12/2011 1 Z3-001LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name/No.: DOYON 16 I Spud Date/Time: 10/28/1998 12:00:00AM I Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. uwl: 500292292800 1 Active Datum: MPF-80 @43.25ft (above Mean Sea Level) Date From - To Hrs Task I Code NPT NPT Depth ' Phase i Description of Operations (hr) 1 (ft) —H- 18:00 - 21:00 1 3.00 FISH N 1 DECOMP PJSM: SLIP/CUT DRILLING LINE I 1 I -CUT 371 OF DRILLING LINE FROM FISHING II „ I 1 I I I OPERATIONS. -INSPECT DRAWWORKS I 1 I I !-CLEAN/CLEAR RIG FLOOR 21:00 - 00:00 : 3.00 WHSUR 1 N i : DECOMP , RIG UP OPSO LOPSO AND DSM LUBRICATOR I 1 TO PULL TWC 1 1 „ -TEST DSM LUBRICATOR TO 250 PSI LOW , 1 , I AND 4000 PSI HIGH FOR 5 CHARTED MIN -PULL TINC 6/2/2011 00:00 - 01:00 I 1.00 I WHSUR P 1— I DECOMP I LAYDOWN DSM LUBRICATOR 1 I -PU LANDING JOINT 1 , , 1 , : : -BOLDS -PULL HANGER ' , 1 '-LAYDOWN LANDING JOINT , I ! , 01:00 - 03:00 ,' 2.00 ' FISH ' P 1 , DECOMP i MU FISHING BHA--ROPE SPEAR, DRAIN SUB, BUMPER SUB , 1 I -RIH TO TOP OF CABLE FISH AT 1454' I I -CIRC BOTTOMS UP 46 BBLS @ 5 BPM & 150 I I 1 I 1 1 , , 1 I PSI 03:00 - 04:30 I 1.50 I FISH 1 . P I . 1 DECOMP ROTATE 3 TIMES INTO CABLE -PULL UP 19' WHEN CABLE BROKE WITH 5K OVERPULL : , . „ . -POH -40' OF CABLE RECOVERED AND LAYED , I : I DOWN / : _ --- 7 1 04:30 - 06:00 1.50 1 FISH I P I I DECOMP IRIH WITH ROPE SPEAR BHA_ I : 1 1 I -PUMP 2 N O BBLS OF ACASING F E UR SURF -O 0 S W E E P T 0 CLEAN -CBU 06:00 - 07:00 I 1.00 , FISH ! P I DECOMP I POH FROM 1454' MD WITH 10' OF , I RECOVERED ESP CABLE. ' 07:00 - 08:00 1.00 I FISH I P 1 : 1 DECOMP RIH WITH ROPE SPEAR BHA TO 1476' MD -PUW = 65-K, SOW = 62-K. -ROTATE DOWN 3 TURNS TO ENTANGLE I ; CALBE. 08:00 - 09:00 1.00 FISH ' P ' ! DECOMP I POH FROM 1476' MD AND RECOVERED 12 FT OF CABLE. 09:00 - 10:00 1.00 FISH P DECOMP RIH WITH ROPE SPEAR BHA TO 1476' MD -PUW 65-K, SOW 62-K. -ROTATE DOWN 4 TO 1492' NO PUMP. 10:00 - 10:30 0.50 FISH P DECOMP RIG SERVICE (TOP DRIVE) -TOTCO TECH CALIBRATED NEW FLOW PADDLE. -AT 7 BPM FLOW HIGH SIDE. 10:30 - 12:00 1.50 I FISH P DECOMP , POH FROM 1492' MD - RECOVERED 25' OF ESP LINE 12:00 - 13:00 1 1.00 FISH P DECOMP RIH WITH ROPE SPEAR FROM TO 1496' TAG UP 64K, DN 60K UWT -ROTATE 1 RPM TO ENGAGE ESP CABLE. , 13:00 - 14:30 1.50 FISH P I DECOMP POH FROM 1496' TO ROPE SPEAR BHA NO FISH. 14:30 - 15:30 1.00 FISH P DECOMP UD ROPE SPEAR BHA -PJSM: P/U OVERSHOT BHA AS PER BAKER ' I REP. Printed 7/5/2011 9:31:13AM orth America - ALASKA BP Page 19 of3 Operation Summary Report Common Well Name: MPF -80 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point I Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations ( ' — (f )! 15:30 - 18:00 2.50 FISH r P DECOMP M/U BHA -P /U 5.75" OVER SHOT WITH EXTENSION, 5.75" DRIVE SUB, 3.50" PUMP OUT SUB, 4.75 "BOWEN JARS, OIL JARS, 15 4 3/4" DC, 4.75" INTENSIFIER, XO + 505.10' i -SERVICE TOP DRIVE, REPLACE LEAKING HOSE 18:00 - 21:00 3.00 FISH P DECOMP RIH TO TOP OF FISH -TAG FISH AT 1491', SWALLOW TO 1494' ' -75K SOW 71K PUW ESTABLISH SLOW PUMP RATES I 1 BPM @ 370 PSI 2 BPM @ 790 PSI 1 3 BPM @ 2050 PSI ' -CIRC BOTTOMS UP AT 4 BPM -PUMP 40 BBL SAFE- SURF -O PILL AT 2 BPM 12110 PSI DOWN DP -ONCE PILL ON THE BACKSIDE, SLOW PUMP ' TO 1/2 BPM TO WASH TUBING 21:00 - 22:30 1.50 FISH P DECOMP I START JARRING AT 125K UP WORKING TO , 150K UP -AFTER EACH JAR HIT, STRAIGHT PULL TO 175K '- CONTINUE PUMPING SOAP PULL UP BACKSIDE AT 1/2 BPM . -AFTER 15 JARS COMPLETED DERRICK INSPECTION 22:30 - 00:00 '', 1.50 FISH P DECOMP CONTINUE JARRING -MADE 4" UPHOLE WITH COMPLETION - AFTER 15 JAR HITS, INSPECTED DERRICK 6/3/2011 00:00 - 09:00 9.00 FISH P DECOMP CONTINUE JARRING FISH AT 1491' i -JARS FIRING AT 165K. STRAIGHT PULL TO 185K -EVERY 15 JAR HITS INSPECT DERRICK �, -INSPECT DRILLING LINE -MIX AND PUMP 20 BBLS SAFE -CUBE SWEEP. -2 BPM / 770 PSI -SPR 1 BPM / 50 PSI. -NO FLUID LOSSES WITH 12.1 PPG NABR - CONFER WITH ANCHORAGE RWO ENGINEERS ON PLAN FORWARD STARTING AT 07:30 HRS. 09:00 - 10:30 1.50 FISH P DECOMP FISHING CALLED OFF. - RELEASE FROM FISH. -TO OF FISH 1,490' MD. -POH FROM 1491' MD. - UD943/4 "DC. 10:30 - 11:00 0.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR. 11:00 16:00 5.00 FISH X WAIT 1,491.00 DECOMP CHANGE OF SCOPE. -MILL HAD TO BE DRESSED FOR 2 7/8" TBG DRESS -OFF AT THE BAKER SHOP. -THEN TRANSPORTED TO RIG LOCATION. 16:00 - 17:30 1.50 FISH P DECOMP MU DRESS OFF MILL ' -RIH TO 145 17:30 - 19:00 1.50 FISH P DECOMP PJSM: CUT DRILLING LINE -CUT 371' DRILLING LINE Printed 7/5/2011 9:31:13AM orth America ALASKA - BP Page:20 of 31 pe Summary Report . Common Well Name: MPF -80 - - - - -_- -,--- -e.-- AFE No _ Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 End Date: 6/12/2011 IZ3 -001LV (3,000,000.00 ) Project: Milne Point ! Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. I UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase Description of Operations - ( P (ft) DECOMP PU 1 STAND 4" DP hr) X19:00 20:30 1.50 FISH ; - ESTABLISH MILLING PARAMETERS: PUW 65K, SOW 67K, 67K ROTATING WEIGHT, 1.5K FREE TQ, 40 RPM I -TAG 2 -7/8" TUBING STUB @ 1489' -PU AND ROTATE DOWN AT 40 RPM, PUMPING 4 BPM AT 600 PSI I - INCREASE ROTATION TO 60 RPM AT 1.5 -2K I I TQ -NO DEPTH GAINED WHILE MILLING, MILL SEEMS TO BE SPINNING NOT BITING 20:30 - 21:30 1.00 , FISH P DECOMP DRY MILL @ 60 RPM WITH 2 -5K WOB , -MILL STARTED TO BITE, MADE 6" OF HOLE - TURNED PUMP ON AT 2 BPM AND 50 PSI SLACKED OFF TO TAG 1489.5', PUMP PRESSURE INCREASED TO 190 PSI -PU OFF TUBING, INCREASED RATE TO 4 BPM -WASHED DOWN OVER TUBING TO 1489.5 ! AND PRESSURE INCREASED TO 1050 PSI ' 21:30 - 23:00 1.50 FISH P DECOMP ! POH WITH DRESS OF BHA TO SURFACE i, - MONITOR WELL PRIOR TO PULLING DC TTHROUGH THE STACK, WELL STATIC 23:00 23:30 0.50 FISH P DECOMP I INSPECT SHOE AND INNER MILL -MILL SHOWS INDICATIONS OF CUTTING ON I BLADES -ALSO RING MARK AROUND NOSE SECTION INDICATING DRESS -OFF OF TUBING 23:30 00:00 0.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR 6/4/2011 00:00 - 03:00 3.00 FISH P DECOMP ! RIH WITH OVERSHOT BHA TO TOP OF , � ' TUBING STUB AT 1489.5' WITH 15 STANDS OF 4" DP + 5' AND 15' PUPS + SINGLE JOINT ' 1 -PU, TURN PUMP ON AT 2 BPM, 60 PSI -WASH DOWN OVER TUBING STUB AND J PRESSURE INCREASED TO 380 PSI AT 2BPM tl/ -SHUT DOWN PUMP -TOP OF DP AT RIG FLOOR FOR E -LINE RIG UP 03:00 - 03:30 0.50 FISH P ' DECOMP PJSM WITH E -LINE CREW FOR RIG UP AND ' JET CUT 03:30 - 05:00 1.50 FISH P DECOMP RIG UP E -LINE FOR JET CUT -SPOT UNIT, BRING FULL PRESSURE CONTROL EQUIPMENT TO RIG FLOOR -RU XO, 4" TIW VALVE, XO TO OTIS, QUICK TEST SUB, WIRE LINE BOP & LUBRICATOR. -HELD H2S / RIG EVACUAION DRILL AND AAR. 05:00 - 05:30 0.50 FISH P DECOMP HELD H2S / RIG EVACUATION DRILL AND AAR. -SLS EXPLAINED EXPLOSIVE LOCK OUT. - - -- - - --------------- -- 05:30 - 06:30 1.00 FISH P DECOMP CONTINUE TO RU WIRE LINE BOPE AND LUBRICATOR. 06:30 - 07:30 1.00 FISH P , DECOMP ' TEST LUBRICATOR AGAINST TIW VALE TO 250 LOW / 4000 PSI FOR 5 CHARTED MINUTES. -LOAD JET CUTTER AND RETEST WITH QUICK TEST SUB. 07:30 - 08:30 1.00 FISH P DECOMP RUN #1 WITH 2 1/8" JET CUTTER,. -CAN NOT GO PAST 1495' MD . . -MADE IT -3 FT IN TO 2 7/8" TBG STUB. ' -POH AND REMOVE CENTRLIZER. Printed 7/5/2011 9:31:13AM orth`America - ALASKA - BP 0 Page 21 of 31: Operation Summary Report Common Well Name: MPF -80 ____ — -- AFE No —�— � Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 I End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. I UWI: 500292292800 Active Datum: MPF -80 ©43.25ft (above Mean Sea Level) Date From - To Hrs I Task Code I NPT NPT Depth Phase Description of Operations , (ft) 08:30 - 13:30 I 5.00 1 FISH P DECOMP 'I RUN #2 LOCATE DEPTH WITH OUT PUMP I - CUTTER COMFIRMED FIRE AT 12 R05' MD, -POH TO SURFACE. k 13:30 - 16:00 2.50 FISH P I DECOMP PJSM -R/D E -LINE TOOLS, E -LINE BOPE AND LUBRICATOR. 16:00 - 17:00 1.00 FISH I P DECOMP 1 CBU + AT 5 BPM / 2500 PSI, 4783 STROKES. I - OBSERVED NO LOSSES l -12.1 PPG IN AND OUT. I I17:00 - 18:30 1.50 FISH I P DECOMP POH . -BO /LD XO'S, TIW VALVE AND SPACE OUT PUPS. _ _ -POH WITH 4" DP FROM 1489' 18:30 19:30 1.00 FISH 1 P I DECOMP IAT SURFACE WITH BHA -BO CUT LIP GUIDE AND INSTALL GRAPPLE IN-5-3/4" OVERSHOT -MU AND INSTALL PUMP OUT SUB, BUMPER SUB, JARS AND 6 4 -3/4" DC 19:30 - 21:00 1.50 FISH P DECOMP I RIH TO ABOVE TOP OF TUBING FISH -KELLY UP AND ESTABLISH PARAMETERS BEFORE LATCHING TUBING STUB 68K SOW, 65K PUW ' 21:00 - 00:00 3.00 I FISH P F DECO ^ "e AT( FH E«N ar �aaa PI( 11P A N COME UP I HOLE WITH 120K PUW -PULL UP 40' AND WEIGHT DROPPED FROM ' 122K TO 115K, CABLE BREAKING AT JET CUT -POH STANDING BACK 4" DP - MONITOR WELL PRIOR TO PULLING NON- SHEARABLES THROUGH STACK, WELL I STATIC -LAY DOWN BHA 6/5/2011 00:00 01:00 1.00 FISH P DECOMP I LAY DOWN 3 JOINTS OF 2 -7/8" TUBING -CUT CABLE IN SECTIONS SINCE JARRING ON FISH CAUSE STRETCH AND DAMAGE TO THE CABLE - EVALUATE CABLE STRENGTH TO SEND OVER SHEAVE TO SPOOLING UNIT 01:00 02:00 1.00 FISH P DECOMP RIG UP SHEAVE, ELEPHANT TRUNK, HERCULITE TO SPOOL ESP CABLE. 02:00 - 06:00 4.00 FISH P DECOMP POH AND LAY DOWN 2 -7/8" TUBING FISH FROM 12,800' TO -9,000'. Printed 7/5/2011 9:31:13AM I . . . . , orth Arnirica" ALASKA - BP , i Page-22 0'31 • . . . , . , . , ., , . . ' Operation Summary Report . . . . ■ . . . . . . J... ■■■.a■.■...■■■■■■■■ r . ■.a...■.■■■ -■-.■--■ , .* ' Common Well Name: MPF-80 AFE No Event Type: PLUG AND ABANDON (PXA) , Start Date: 5/21/2011 End Date: 6/12/2011 Z3-001LV (3,000,000.00 ) Project: Milne Point 1 Site: M Pt F Pad Rig Name/No.: DOYON 16 1 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 1 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF-80 @43.25ft (above Mean Sea Level) Date 1 From - To „ Hrs Task Code 1 NPT 1 NPT Depth 1 Phase 1 1 1 : Description of Operations I 1 (hr) 1 , 1 , (ft) 1_ 1 06:00 - 16:00 10.00 1 FISH ' P 1 1 DECOMP CONTINUE TO POH WITH 2 7/8" TBG AND ESP 1 1 1 1 CABLE -FROM –9,000' TO SURFACE. : 1 1 : I 1-LAST –400 FT OF TBG HAD HEAVY SCALE , , 1 ON THE CLAMPS. -RECOVERED A TOTAL OF 406 JOINTS PLUS , 3.50' OF JET CUT JOINT. (THAT INCLUDES THE JOINTS THAT WERE PULLED IN 2009 RWO). 1-RECOVERED ADDITIONAL 232' OF ESP • CABLE BELOW THE JET CUT. 1 : : . LEFT IN HOLE: -8 LASALLE CLAMPS LOST TO THE HOLE. 1 : , -68.01 FT OF (ESP ASSEMBLY). 1 , -11.84 FT OF( X0 AND TBG PUP). -59.10 FT (1-FULL JOINT AND CUT JOINT : 1 1 127.80') 1 ! 1-NO FLUID LOSSES WITH CONTINUOUS HOLE ' I FILL. 16:00 - 17:30 1.50 ' PXA 1 P ' DECOMP RIG DOWN CABLE SHEAVE, ELEPHANT . TRUNK, HERCULITE TO ESP SPOOLER. : -CLEAN AND CLEAR RIG FLOOR 17:30 - 19:00 1 1.50 , PXA P DECOMP MU MILL AND SCRAPER BHA: 6" BLADED 1 : , 1 JUNK MILL, 7" CASING SCRAPER, BIT SUB, , 1 , PUMPOUT SUB, 4-3/4" BUMPER SUB, 4-3/4" 1OIL JARS, 6 4-3/4" DC, X-OVER TO DP -RIH WITH 15 STANDS 4" DP 1 , 1 19:00 - 22:30 3.50 PXA P , DECOMP RIH 4" DP SINGLES FROM 1650'- 4229' -NO INDICATIONS OF TIGHT SPOT @ 2063' FROM WHEN MOTOR ASSEMBLY WAS RUN , , 1IN 2005 , . A_ • 22:30 - 00:00 1.50 ; PXA ; P • ; ' DECOMP ESTABLISH CIRCULATION AT 4 BPM, 450 PSI . @ 4229' -CONTINUE IN HOLE TO 5725' 6/6/2011 00:00 - 09:00 , 9.00 , PXA P i DECOMP RIH MILUSCRAPER ON 4" DP FROM 5725' TO 12,732' MD" / 09:00 - 09:30 0.50 PXA P DECOMP OBTAIN PARAMETERS -PUW 175K -SOW 116K, 3BPM / 480 PSI -WASH FROM 12,795' TO 12,805' TAG WITH 5K. -WORK SETTING DEPTH SEVERAL TIMES FROM 12,732' TO 12,804'. 09:30 - 10:30 1.00 ; PXA P DECOMP PUMP 2OBBL HIGH VIS SWEEP. -5 BPM @ 1120 PSI. -MONITOR WELL STATIC. 10:30 - 17:30 7.00 PXA P DECOMP ! POH FROM 12,805' SURFACE -JUST A LITTLE ESP ARMOR IN SCRAPER. -NO LOSSES 17:30 - 18:30 1.00 ' PXA P , DECOMP , CLEAR RIG FLOOR OF BAKER FISHING TOOLS — 18:15 HRS. CALLED AOGCC, JEFF JONES SAID GIVE HIM A UP DATE AT 0600 HRS ON P&A CEMENT TEST*** 18:30 - 19:30 ' 1.00 BOPSUR , C , DECOMP FLUSH BOP STACK -SMALL AMOUNT OF PLASTIC AND METAL IN RETURNS OVER SHAKERS ; ; Printed 7/5/2011 9:31:13AM orth America - ALASKA - BP Page 23 of 31 ` Operation Summary Report ' Common Well Name: MPF -80 AFE No Event Type: PLUG AND ABANDON (PXA) ' Start Date: 5/21/2011 End Date: 6/12/2011 I Z3 -001 LV (3,000,000.00 ) Project: Milne Point ! Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date I From - To 1 Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 21:30 I 2.00 BOPSUR I C I DECOMP PU LANDING JOINT I I -MU CROSS -OVERS TO 2 -7/8" TUBING I I I HANGER -LAND TUBING HANGER WITH TWC INSTALLED 1 -RILDS -TEST HANGER/TWC FROM ABOVE 200 PSI , LOW, 4000 PSI HIGH FOR 5 CHARTED MINUTES -TEST HANGER/TWC FROM BELOW 500 PSI, 5 CHARTED MIN 21:30 23:30 I 2.00 BOPSUR C DECOMP OPEN BOP RAM DOORS AND INSPECT FOR I j ESP CABLE DEBRIS -1 PIECE OF 3" X 1/4" ARMOR FOUND BEHIND B/S RAM _ -CLOSE DOORS — — 23:30 00: 0.50 BOPSUR C — — - - - L _ DECOMP ; FILL L STACK AND D R/ TO TO TEST BOPE BREAKS I 6/7/2011 ! 00:00 01:00 I 1.00 I BOPSUR C I ABAN :TEST BOP BREAKS I - BODY TEST ON UPPER PIPE, LOWER PIPE I I AND BLIND /SHEAR RAMS TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED = MINUTES. 01:00 03:30 2.50 BOPSUR I C ABAN TWC ! RIG UP WELL SUPPORT TO PULL i - PRESSURE TEST LUBRICATOR TO 250 PSI LOW, 4000 PSI HIGH FOR 5 CHARTED MIN 1 I -PULL TWC -BOLDS _ I -PU LANDING JOINT AND PULL HANGER 03:30 - 04:00 I 0.50 ZONISO P ' ABAN I LAY DOWN 2 STANDS OF 4 3/4" DC. 04:00 - 06:00 2.00 ZONISO P ABAN PJSM, M/U 7' EZ -SVB SQUEEZE PACKER WITH HES REP ON 4" DP. -RIH AT REDUCED SPEED ON DP FROM I 1DERRICK. I -15 STANDS IN AT 0530 HRS. 06:00 HRS.***24 HRS NOTICE OF WEEKLY BOPE TEST TO AOGCC, JEFF JONES SAID GIVE HIM A UP DATE AT 1800 HRS ON P &A CEMENT TEST.*** 06:00 - 12:00 6.00 ZONISO P ABAN RIH TO CEMENT RETAINER SET DEPTH„ 12,795' - 164K PUW, 115K SOW - RECIPROCATE AND PUMP 3 BPM TO CLEAN AROUND RETAINER -39 TURNS IN DRILL PIPE TO SET RETAINER AT 12795', OVER PULL 55K TO SHEAR OFF 12:00 - 13:00 1.00 ZONISO P ABAN TEST CEMENT RETAINER FROM ABOVE 1500 PSI FOR 10 CHARTED MIN Printed 7/5/2011 9:31:13AM , Oth America - ALASKA - BP Pa 24 of 31 Operation Summary Report Common Well Name: MPF -80 _ AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 End Date: 6/12/2011 IZ3 -001 LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad I, Rig Name /No.: DOYON 16 Spud Date /Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 - - - -- — - -- - -- ----- - - - - -- - -- -- Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs 1 Task Code 1 NPT NPT Depth 1 Phase Description of Operations 13:00 - 15:00 2 0 ZONISO 1 Il i` — P — (ft) ABAN SPR WITH STINGER @ 12770' ' 1 1 BPM @ 80 PSI 2 BPM © 200 PSI ! 3 BPM @ 380 PSI STING INTO RETAINER FOR INJECTIVITY I (BELOW. -PUMPED 1.3 BBLS AT 1 BPM AND PRESSURED UP TO 3000 PSI -SI AND HELD FOR 15 MIN, TOTAL OF 350 PSI I 'BLEED OFF IN 15 MIN -PULL OUT OF RETAINER, ROTATE DP TO ENSURE STINGER FULLY EXTENDED I 1-STING BACK INTO. RETAINER, PUMP AT 1/4 ' BPM AND PRESSURE BUILT TO 3000 ' CALL TOWN RWO ENGINEER AND DIRECTED r TO SKIP CEMENTING BELOW RETAINER AND TO PROCEED WITH CEMENT PLUGS ABOVE RETAINER. 15:00 - 17:00 2.00 ZONISO P I ABAN I WELL OUT OF BALANCE FROM INJECTIVITY ATTEMPT - CIRCULATED A SURFACE TO SURFACE VOLUME, 420 BBLS ' -MUD WEIGHT IN = MUD WEIGHT OUT (12.1 ! HEAVY) -WELL BALANCED 17:00 - 18:30 1.50 ZONISO 1 P i ABAN PJSM: PUMP CEMENT BALANCED PLUG , - DISCUSS PLAN, PUMP SCHEDULE COMMUNICATION, LAYING DOWN DP -PUMP 9 BBLS OF WATER AHEAD 1-RIG UP AND PRESSURE TEST SLB CEMENT ' I LINES TO 4000 PSI. 1 18:30 - 19:30 1.00 1 ZONISO P ABAN START PUMPING CEMENT @ 18:30 HRS. -PUMP 20 BBLS OF 15.8 PPG CLASS "G" CEMENT. - BALANCED PLUG EST LENGTH AFTER WORK STRING PULLED OUT = 540' -TAKE OVER WITH RIG PUMPS AT 5 BPM AND ii 1100 PSI. PUMP 120 BBLS TO SPOT CEMENT. lc 1 CIP AT 19:10 HRS. -R /D CEMENT EQUIPMENT. CEMENT SPECS OF: -1.16 FT3 / /SK -15.8 PPG. -FLUID LOSS OF 60 mL -70 Bc IN 3:55 HR:MN -1000 PSI COMPRESSIVE STRENGTH IN 9:42 HR:MN I 19:30 - 20:00 0.50 ZONISO P ABAN ' POOH WITH DP TO 12172' -POH LAYING DOWN 19 JOINTS OF DRILL PIPE. -TOP OF CEMENT ESTIMATED TO BE AT 12250' 20:00 - 22:00 2.00 ZONISO P ABAN R/U CIRCULATION EQUIPMENT. - REVERSE CIRCULATE SURFACE TO SURFACE VOLUME AT 6 BPM WITH 1200 PSI I ICP AND 1350 PSI FCP. Printed 7/5/2011 9:31:13AM arth America ALASKA. - BP ' Page 25 of 31, ' ' Oper ation Summary Report . _ _ - - - — Common Well Name: MPF -80 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 End Date: 6/12/2011 Z3 -001LV (3,000,000.00 ) Project: Milne Point 1 M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Firs Task Code NPT I NPT Depth Phase 1 Description of Operations (ft) 22:00 - 23:00 � 1.00 ZONISO P r (hr) ABAN P/U 15' PUP AND 2 JOINTS OF DP. 1 ! -RIH ANT TAG TOP OF CEMENT AT 12216' 'WITH 10K. -P /U AND LID 1 JOINT OF DP. -SCREW IN TOP DRIVE TO CLEAR DP AND CIRCULATE DP VOLUME. 23:00 - 00:00 1.00 ZONISO ' P ABAN BACK OUT 15' PUP AND UD. -P /U 10' PUP AND RIH TO 12213'. ' -PUMP 20 BBLS OF 15.8 PPG CLASS "G" CEMENT. -TAKE OVER WITH RIG PUMPS AT 5 BPM AND 1100 PSI. PUMP 114 BBLS TO SPOT CEMENT. -R/D CEMENT EQUIPMENT. CEMENT SPECS OF: ! -1.16 FT3 / /SK . ! I -15.8 PPG. ' I -FLUID LOSS OF 60 mL -70 Bc IN 3:55 HR:MN -1000 PSI COMPRESSIVE STRENGTH IN 9:42 HR:MN CEMENT IN PLACE AT 0000 HRS. 6/8/2011 00:00 - 00:30 0.50 PXA P ABAN POH RACKING BACK DP IN DERRICK. -POH TO 11471' ' 00:30 - 02:30 2.00 PXA P ABAN R/U AND REVERSE CIRCULATE SURFACE TO I SURFACE. ' - CIRCULATE AT 6 BPM AND 1360 PSI. -LINE UP TO PUMP DOWN DP. -DROP WIPER BALL AND CIRCULATE AT 6 — - ABAN BPM w/ 1390 PSI. — -- - 0 2:30 06 00 3.50 PXA P RACKING N -- I POH B BACK CK DP IN DERRICK. / 06:00 07:00 1.00 P P 02:30 ABAN MU MILL AND 7" SCRAPER 07:00 - 11:00 4.00 PXA P I ABAN RIH TO TAG CEMENT TOP j - PUW -160K , SOW -100K - PUMP ON AT 4 BPM WITH 350 PSI ' - TAGGED TOP OF CEMENT AT 11,655' 7:45 CALL AOGCC WITH UPDATE FOR TAG TIME OF 11AM. 11:00 - 11:30 0.50 PXA P ABAN RIH TO 11,565 TO ESTABLIS PARAMETERS - PUW -160K , SOW -100K - PUMP ON AT 4 BPM WITH 350 PSI - RIH TO TAG TOP OF CEMENT AT 11,655' - SET 15 K DOWN, PICK UP AND SET BACK ' ' DOWN 15 K AGAIN. - AOGCC REP MATT HERRERA WITNESSED CEMENT TAG 11:30 - 12:30 1.00 PXA P ABAN RU TEST EQUPMENT TO TEST CEMENT ' - LD ONE JOINT OF DP - TESTED CEMENT @ 11,625' - PRESSURE TESTED CEMENT TO 1500 PSI FOR 30 MIN CHARTED, NOTIFIED RWO SUPT FILLING IN FOR WTL OF TEST RESULTS - LOST 50 PSI OVER THE ENTIRE 30 MIN TEST. 12:30 - 14:00 1.50 PXA P ' ABAN PJSM FOR DISPLACING THE WELL WITH INHIBITED 12.1 PPG BRINE - PUMPED 240 BBLS @ 6 BPM Printed 7/5/2011 9:31:13AM .. , . orth America - ALASKA - BP Page 26 of 31 Operation Summary. Report Common Well Name: MPF -80 v AFE No �___ Event Type: PLUG AND ABANDON (PXA) I Start Date: 5/21/2011 End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point I, Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date /Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. 1 UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs I Task ' Code ' NPT NPT Depth'. Phase I Description of Operations - 0 50 PXA P (ft) 14:00 14:30 I ABAN BREAK OUT AND BREAK DOWN CEMENT I I LINE ' - MONITOR WELL, WELL IS STATIC 14:30 - 23:00 !� 8.50 PXA P I ABAN I POOH FROM 11,625' LAYING DOWN 199 ' SINGLES TO THE PIPE SHED - LAYING DOWN ' 4400' , RACKING BACK THE REST LEAVING - 7200' IN THE DERRICK . -20:00 HRS - STOP L/D PIPE AND BEGIN RACKING IT BACK IN DERRICK TO ENSURE THE BOPE TEST WAS STARTED PRIOR TO 1 — MIDNIGHT. - . 23:00 - 23:30 I 0.50 BOPSUR P ABAN R/U BOPE TEST EQUIPMENT. -SET TEST PLUG. -FILL BOPE WITH FRESH WATER FOR 'TESTING. 23:30 - 00:00 0.50 BOPSUR P I ABAN BEGIN TESTING ROPE FOR WEEKLY TEST. I -TEST BOPE PER WELL PLAN, PERMIT TO I DRILL, AND AOGCC REGS. I -TEST WITNESS WAIVED BY MATT HERRERA -HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH. TEST WITH 4" TEST JOINT. 6/9/2011 00:00 - 04:30 4.50 BOPSUR ! P ABAN- .TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. -RAMS TESTED TO 250 PSI LOW AND 4,000 Floe PSI HIGH. V -TEST USING 4" TEST JOINTS. 'r - PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL / DDI TP. ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT - AK -10 -45 -NO BOPE TEST FAILURES ACCUMULATOR TEST: - ACCUMULATOR PRESSURE: 2850 PSI, MANIFOLD PRESSURE: 1525 PSI, ANNULAR ' PRESSURE: 950 PSI -DRAW DOWN = 1700 PSI -200 PSI INCREASE IN 19 SEC -FULL INCREASE TO 2850 PSI IN 90 SEC ' -5 BOTTLES OF N2 AT 1900 PSI 04:30 - 05:00 0.50 BOPSUR P ABAN RIG DOWN BOPE TEST EQUIPMENT 05:00 - 07:00 2.00 PXA P ABAN LAY DOWN 4" DP FROM DERRICK. 07:00 10:00 3.00 PXA P ABAN PJSM FOR R/U E -LINE -SPOT AND R/U E -LINE TOOLS AND EQUIPMENT. 10:00 - 18:00 8.00 PXA P ABAN LOG WITH USIT. -RIH TO 5700' AND LOG UP IN CEMENT MODE. TOC AT 5348' WITH A CLEAR TOP AT 3700'. ' DISCUSSED WITH TOWN ENGINEER. DECISION TO ATTEMPT TO TBG PUNCH AND ACHIEVE CIRCULATION AT 5250' AND IF FAILED MOVE UP AND REPUNCH AT 3700'. - REMOVE FRONT BOOSTER CAGE, BLOW DOWN HARD LINE TO FLOW BACK TANK, HOUSEKEEPING. 18:00 - 20:00 ' 2.00 PXA P ABAN WAIT ON CIBP AND USIT READING FROM TOWN. Printed 7/5/2011 9:31:13AM Otth America - ALASKA BP Page, 27 of 31 Operation Summary Report Common Well Name: MPF -80 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad ~ i Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase ,' Description of Operations 20:00 00:00 4 0 PXA P — ABAN ; PJSM FOR R/U CIBP. (ft) 1 -R/U TOOLS AND ARM CIBP ARM SETTING TOOL. 1 -RIH TO 5400' AND SEEN AN INCREASE IN ' DRAG. ' -RUN DOWN TO 5818' AND ATTEMPT TO TIE ' IN ON THE UP STROKE. TOOLS BECAME STUCK AT - 5800'. PULLED 4000K OVER TO ATTEMPT TO FREE. • NOTIFIED TOWN AND DECIDED TO LEAVE AT ri 1 ' THE 5800' AREA. - I S CIBP AND CLEAR TOOL. P/U AND TIE IN. 6% � : ET . RIH ANp TA(; TOP OF CIBP AT 5837'. POOH. 6/10/2011 00:00 - 00:30 0.50 PXA P ABAN i POH WITH ELINE. R/U TO TEST CIBP AT 5837' 00:30 - 01:00 0.50 PXA P I , ABAN TEST CIBP TO 1500 PSI FOR 10 CHARTED 1 , MIN. GOOD TEST. I ' ' -PUMP 14 STROKES TO ACHIEVE THIS TEST 1_ .OUT OF A CALCULATED 14 STROKES. 01:00 02:00 1.00 PXA P ABAN R/U SWS ELINE FULL WELL CONTROL EQUIPMENT FOR PERFING T' PIPE. 02:00 - 04:00 2.00 PXA N ' WAIT ABAN CLEANOUT E -LINE FLOWTUBES DUE TO ' : BLOCKAGE OF CABLE MOVEMENT 04:00 - 06:00 2.00 PXA P ABAN E -LINE SURFACE TOOL CHECK 4 PRESSURE TEST LUBRICATOR 06:00 - 10:30 4.50 PXA I P ABAN ' RIH ON WIRELINE TO 5250' FOR CASING PUNCH - TIE -IN AND SHOOT PUNCHES FROM. 750' 1 TO 5,260' -POH FROM 5250' TO SURFACE -GUNS RECOVERED AT SURFACE, ALL 40 SHOTS FIRED ' 1 - SHUT IN BLIND SHEAR RAMS 10:30 - 12:00 1.50 PXA P ABAN RIG UP TO PUMP DOWN T CASING ' - OPEN THE OA TO A GUAGE , GUAGE SHOWING ZERO PRESSURE '- ATTEMPT TO ESTABLISH CIRCULATION THROUGH PERFORATIONS. ! - PRESSURED UP TO 1000 PSI WITH 7 ' : . STROKES ` - BROUGHT PRESSURE UP TO 2000 PSI WITH ' 15 STROKES - 1.5 BBLS CONTACT RWO ENGINEER TO DISCUSS SHOOTING PUNCHES HIGHER NEAR 3700' 12:00 - 15:30 3.50 PXA P ABAN MU 10' OF CASING PUNCHES ON E -LINE - PRESSURE TEST LUBRICATOR VIA THE QUICK TEST SUB -RIH TO - 3,600' - TIE -IN AND PUNCH CASING FROM 3 500' -3 510' - OPENED OA TO GUAGE. - 650 PSI ON OA Printed 7/5/2011 9:31:13AM O Kth America - ALASKA - BP ';. Page 28. of 31 Operation Summary Report Common Well Name: MPF -80 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21 /2011 End Date: 6/12/2011 . Z3-001LV (3,000,000.00 ) 1 I 1 1 Project: Milne Point , Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. I UWl: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date I From - To Hrs Task Code , NPT NPT Depth Phase I Description of Operations ( hr ) - (ft) — 15:30 - 17:00 1.50 PXA P ABAN CIRCULATE OUT THE OA 1 - OPENED THE OA AND ALLOWED 20 BBLS ' TO U -TUBE OUT & PRESSURE TO BLEED TO NEAR ZERO - STAGED PUMP UP TO 5 BPM @ 100 PSI , PUMPED 22 BBLS BEFORE CATCHING FLUIDS - BROUGHT PUMP UP TO 7 BPM @ 550 PSI, PUMPED UNTIL WE HAD 12.1 PPG IN AND 1 OUT PUMPED TOTAL OF 130 BBLS 17:00 19:00 I 2.00 PXA P ABAN RIGGING DOWN SLB WIRELINE PCE EQPT - PREP FOR RIH WITH DRILL PIPE AND I 1 I CEMENTING. - P RD DUTCH RISER 19:00 2.50 21:30 2. 0 – PXA ABAN P/U MULE SHOE AND XO. -RIH WITH 4" DP FROM DERRICK TO 5738'._ 21:30 - 23:00 1.50 PXA I P ABAN PJSM FOR SLIP AND CUT DRILLING LINE. -SLIP AND CUT 105' OF DRILLING LINE. - INSPECT TOP DRIVE AND DRAW WORKS. 23:00 - 00:00 1.00 ! PXA P ABAN CONTINUE TO RIH FROM 5738'. -TAG CIBP AT 5,839'. SET 4 K ON CIBP. -P /U TO 5,831'. 6/11/2011 1 00:00 - 01:30 1.50 PXA P ABAN :SPOT DP AND R/U CEMENT LINES. -HOLD PJSM WITH SLB, CREW, TRUCK DRIVERS WSL ON CEMENT JOB. - DISCUSS R/U OF CEMENT LINES AND CHANGE. REMOVE TON TOP OF TIW AND GO THRU PLUMBING FOR CLEAN OUT ON MUD LINE, THIS ENABLE PIPE MOVEMENT FOR CEMENT JOB. ' 01:30 02:30 1.00 PXA A BAN P SLB PRIME CEMENT UNIT. 1 j I -TEST CEMENT LINES TO 4500 PSI - GOOD _ ' TEST. 02:30 - 03:00 0.50 PXA P ABAN PUMP 9 BBLS H2O. -PUMP 20 BBLS CLASS G CEMENT AT 5 BPM AND 850 PSI. -CHASE WITH 3 BBLS H2O. -RIG THEN PUMPS 51 BBLS TO SPOT CEMENT AT 6 BPM AND 650 PSI, CATCH CEMENT AT 3 BBLS AWAY. RECIPROCATE PIPE WHILE CHASING CEMENT. CEMENT IN PLACE AT 0300 HRS. 03:00 - 03:30 0.50 PXA P ABAN L/D CEMENT LINE AND TIW. -POH L/D 18 JOINTS OF DP TO CLEAR TOP OF CEMENT AT –5299' -R /U TO REVERSE CIRCULATE AND CLEAR STRINGERS. 03:30 - 04:00 0.50 PXA P ABAN REVERSE CIRCULATE SURFACE TO SURFACE TO CLEAR OUT CEMENT STRINGERS. -PUMP AT 6 BPM AND 550 PSI. Printed 7/5/2011 9:31:13AM ,Oth. America - ALASKA BP Page 29 of 31 Operation Summary Report Common Well Name: MPF -80 � �� �- - �— �.� .. - ' , AFE No __— _ Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth', Phase Description of Operations ft 04:00 - 05:00 1.00 PXA P ABAN HOLD UNANNOUNCED WELL CONTROL DRILL. HOLD UNANNOUNCED FIRE DRILL WITH 3RD PARTY VEHICLE AT SAME TIME. -HOLD AAR WITH CEMENTERS, WSL, TOOL PUSHER, CREW. THE DRILLS OCCURRED WITH A NEW DRILLER, NEW FLOOR HAND AND NEW PIT WATCHER ON TOUR. I DISCUSSED WHAT THIRD PARTY PERSONNEL SHOULD DO WHEN ANY DRILL OCCURS AND IT WAS DETERMINED THAT THEY WOULD REPORT TO MUSTER AREA , WHILE RIG TEAM SECURES THE WELL. THE RIG HANDS WOULD SECURE THE WELL AND ' EVAC TO MUSTER AREA IF A FIRE WAS TO ' BREAK OUT ON THIRD PARTY VEHICLES NEAR THE RIG. NOT ALL TRUCK DRIVERS WHERE NOTIFIED AS NEW HAND IN PITS DID ' NOT REALIZE DRIVERS WHERE MONITORING HUB. THESE ITEMS WHERE CAPTURED AND DISCUSSED DURING THE AAR. 05:00 - 06:15 1.25 PXA P ABAN PUMP 9 BBLS H2O. -PUMP 20 BBLS CLASS G CEMENT AT 5 BPM , AND 850 PSI. -CHASE WITH 3 BBLS H2O. , •-PUMP 45 BBLS TO SPOT CEMENT AT 6 BPM AND 650 PSI, CATCH CEMENT AT 3 BBLS i AWAY. RECIPROCATE PIPE WHILE CHASING ' CEMENT. CEMENT IN PLACE AT 06:15 HRS. 1 06:15 08:00 1.75 PXA P ABAN IUD CEMENT HEAD AND TIW. -POH FROM 5289' TO 4719' -R/U TO REVERSE CIRCULATE - REVERSE PUMPING 6.5 BPM AT 60 PSI ' 08:00 08:30 1 0.50 PXA P ABAN RIH TO 4748' , , -PUW = 94K, SOW = 88K -RU TO PUMP CEMENT 08:30 - 09:00 0.50 PXA P ' ABAN PJSM: CEMENTING -SCHLUMBERGER, TRUCK DRIVERS, RIG CREW, WSL PRESENT 09:00 - 10:00 1.00 PXA P ABAN PUMP 9 BBLS H2O. -PUMP 20 BBLS CLASS G CEMENT -CHASE WITH 3 BBLS H2O. -PUMP BBLS TO SPOT CEMENT AT 6 BPM AND 650 PSI, CATCH CEMENT AT 3 BBLS AWAY. RECIPROCATE PIPE WHILE CHASING ' CEMENT. - CEMENT IN PLACE AT 0930 HRS. -RD CIRCULATING HEAD AND TIW 10:00 - 10:30 0.50 PXA P ABAN POH FROM 4748' TO 4143' 10:30 11:30 ' 1.00 PXA P ABAN R/U TO REVERSE CIRCULATE - REVERSE PUMPING 6 BPM AT 700 PSI 11:30 - 14:30 3.00 PXA P ABAN POH FROM 4143' - MONITOR WELL - STATIC. -POH AND UD MULE SHOE. 14:30 - 15:30 1.00 1 PXA P ABAN M/U HALIBURTON RUNNING TOOL AND EZSV ' POPPET FOR 7" CASING. -RIH WITH TOOL HANGING UP AT 27' IN. PUSH THROUGH WELL. 15:30 - 17:30 2.00 PXA P I ABAN RIH TO 3450'. - ESTABLISH PARAMETERS OF PUW 91K, SOW 82K. Printed 7/5/2011 9:31:13AM orth America ALASKA - BP Page 30 of 31 Operation Summary Report Common Well Name: MPF -80 ' AFE No Event Type: PLUG AND ABANDON (PXA) ' Start Date: 5/21/2011 End Date: 6/12/2011 Z3 -001 LV (3,000,000.00 ) Project: Milne Point I Site: M Pt F Pad �I Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM ; Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To Hrs Task 1 Code NPT ' NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 19:00 ' 1.50 PXA P ABAN BREAK CIRCULATION AT 3 BPM WITH 150 PSI. -SET EZSV POPPET PLUG WITH 35 TURNS TO THE RIGHT. -PULL 10 OVER 3 TIMES. - SHEARED OUT AT 127K. - ROTATE 25 MORE TURNS TO THE RIGHT. ` -SET DOWN 20K OVER. -CLOSE ANNULAR. -PRESSURE TEST PLUG TO 1500 PSI FOR 10 CHARTED MIN. GOOD TEST. -OPEN ANNULAR. — T -PLUG SET AT 3450'. I 19:00 - 19:30 0.50 PXA P ABAN P/U 10' OFF OF EZSV PLUG. 1 -CLOSE LOWER PIPE RAMS. -BRING UP PUMPS TO 7 BPM WITH 700 PSI CIRCULATING DOWN THROUGH PERF AND 1 UP THE OA. J OPEN LOWER PIPE RAMS. 19:30 23:00 3.50 PXA P 1 ABAN B/O AND B/D TOP DRIVE. -POOH FROM 3444' TO SURFACE L/D DP IN - — PIPE SHED. 23:00 - 00:00 1.00 PXA P ABAN M/U MULE SHOE TO 1 JOINT OF DP. . -RIH WITH 2 JOINTS OF DP TO A DEPTH OF 60'. 6/12/2011 00:00 - 01:00 1.00 PXA P ABAN PJSM WITH CEMENTERS, TRUCK DRIVERS, RIG CREW, WSL AND TOOL PUSHER ON UP COMING CEMENT JOB. DISCUSS HAZARDS, TRUCK PLACEMENT, 1 VOLUMES. R/U CEMENT EQUIPMENT AND HOSES. 01:00 - 03:00 2.00 PXA P ; ABAN PRESSURE TEST LINES TO 4500 PSI - GOOD , TEST. -PUMP 5 BBLS H2O. -PUMP 285 BBLS 15.8 PPG CLASS G CEMENT AT 4.8 BPM WITH ICP OF 315 PSI AND FCP OF 1005 PSI. 15.5 PPG SEEN AT SURFACE. A / TOTAL OF 57 BBLS OF CEMENT SEEN AT i/ SURFACE. -FLUSH LINES CEMENTER'S LINES 2:45: 2 QUART NABR BRINE LEAK INTO SECONDARY CONTAINMENT AT RIG LINE WHEN VAC TRUCK DRIVER OPENED THE CAP. NOTIFICATIONS MADE TO MPU ENVIRONMENTAL, BP SUPT, DOYON SAFETY. VAC TRUCK DRIVER GOT BRINE ON HIM AND WENT TO MEDIC AFTER HIS SHIFT DUE TO SKIN IRRITATION. 03:00 06:00 3.00 PXA P ABAN FLUSH BOP STACK -VAC OUT BOP STACK -BLOW DOWN CHOKE, KILL, HOLE FILL LINES 06:00 - 08:00 2.00 PXA P ABAN RIH 2 JOINTS OF DP -RIG UP LITTLE RED TO PUMP DIESEL FREEZE PROTECT FROM 60' TO SURFACE 08:00 - 10:30 2.50 PXA P ABAN CLEAN CUTTINGS BOX WITH SUPER SUCKER PRIOR TO TAKING DIESEL RETURNS 10:30 - 11:00 0.50 PXA P ABAN PUMP 1/2 BBL DIESEL WITH LRS -SI WHEN DIESEL RETURNS TO CUTTINGS BOX ' -RIG DOWN LRS Printed 7/5/2011 9:31:13AM 4 •orth America - ALASKA - BP Page 31 of 31 Operation Summary. Report' Common Well Name: MPF -80 AFE No Event Type: PLUG AND ABANDON (PXA) Start Date: 5/21/2011 End Date: 6/12/2011' Z3 -001 LV (3,000,000.00 ) Project: Milne Point Site: M Pt F Pad Rig Name /No.: DOYON 16 Spud Date/Time: 10/28/1998 12:00:00AM 1Rig Release: 6/13/2011 Rig Contractor: DOYON DRILLING INC. UWI: 500292292800 Active Datum: MPF -80 @43.25ft (above Mean Sea Level) Date From - To I Hrs Task Code NPT NPT Depth 1 1 Phase Description of Operations (ft) ' - - -- 11:00 12:00 1.00 PXA P T ABAN SET TUBING HANGER/TWC ON LANDING JOINT 1 - FMC REP TO LAND HANGER WITH TWC 1 INSTALLED. 12:00 - 00:00 1 12.00 BOPSUR i P ABAN I CONTINUE TO BREAK DOORS ON BOP - REMOVE LOWER 2 -7/8" X 5" VBR'S , CLEAN UP AND SEND BACK TO NABORS. - REMOVE THE UPPER 2 -7/8" X 5" VBR'S , INSPECT AND MOVE TO THE LOWER RAM CAVITY I INSTALL 3 -1/2" X 6" VBR'S IN THE UPPER `CAVITY. - OPEN &INSPECT BLIND SHEAR RAMS. - BREAK OFF ANNULAR CAP AND INSPECT - CHANGE ANNULAR ELEMENT. - REPLACE BOTH MANUALS ON THE CHOKE ,AND KILL LINES. - RELEASE RIG AT MIDNIGHT AS THE ABOVE WORK IS FOR THE NEXT WELL. Printed 7/5/2011 9:31:13AM • ill i . N P nom' 7:-, 0 . O cr/ E E 0 O 0 U d cV'5om U.c "t • ti m m � x U� c Y W oo w Q en v CO 0 N CS g e C d W Q O L N A N N Li' « Y . L V 0 -a50 r N r+M C O N C:270 CO (A Q Q M Q5 (15. OS Q C\A 7506 N C 0 E N x N., el 4,co E O O U N N U Z 0 Q N Q tX d j.j.T T 7 7 C C ;. ' NR co co co c c > > co 0 2222 '2,7742 01 1n N O 7 C0 0 O 0 N t0 N N N CI s^ a C�1 H 444.1 C = O Q o, W n a 0 co co O 0i LL 0 0) f- -, 0 3 w -I w C) = 3 0 w 0 w,_ 0 w c91,01 J JW z J Z S. wcc K cc Q u. e111-16 0 a a a WW 3 a 1- z az-I O0z w 30 >-o� '' ,71() a op -^- K W rL 2 W 21-i 0 W Q w-,W Z 100 1uo N 0.... 0.4,--,o p1 u O O M O O 0 0 n 00'3;00.0,000 }O 99 ° 0990099 m ca v VmN0Uv a ul= 0_(9 mui v m9?Om-I�00-0 w mmmmmmmmmm coo Q -1 0)`t w 0E . ` a r r M a0 0 G ' y1,= JYU N eta C V 0 N r 01 N"O mu 0 2 m d M 9 N"O N W N-"N Z a 0 m CID 4f0) Y • m a m c c W C p O O 0 Q-12=c1+5 (.1()I-1-22U W O E d.a 1", p p N W 0 0] ..� Y D C 15 u) n d N N V Z W W O O VS 10 N 1- Q N Q Q a m a in • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: June 8, 2011 P.I. Supervisor e ((- b i �'lt l SUBJECT: Well Bore Plug & Abandonment THRU: MPU F -80 BPXA Milne Point FROM: Matt Herrera PTD 1982170 Petroleum Inspector Sundry 310 -410 Section: 6 Township: 13N Range: 10E Meridian: Umiat Drilling Rig: Doyon 16 Rig Elevation: Total Depth: 13,408 ft MD Lease No.: ADL 0388235 Operator Rep.: Anthony Knowles Casing /Tubing Data: Casing Removal: Conductor: 20" O.D. Shoe@ 120 ft MD Casing Cut@ Feet Surface: 9 -5/8" O.D. Shoe@ 5612 ft MD Casing Cut@ Feet Intermediate: O.D. Shoe@ Casing Cut@ Feet Production: 7" O.D. Shoe@ 13,379 ft MD Casing Cut@ 12,800 Feet Liner: O.D. Shoe@ Casing Cut@ Feet Tubing: 2 -7/8" O.D. Tail@ 13,054 ft MD Casing Cut@ Feet Plugging Data: Type Plug Bottom of T.O.C. Mud Weight Pressure (bottom up) Founded on Cement T.O.C. Depth Verified? above plug Test Annulus Retainer 12,795 ft MD 11,655 ft MD DP Tag 1500 psi Type Plug Founded on: Verified? Open Hole Bottom Drillpipe tag Perforation Bridge plug Wireline tag Annulus Balanced C.T. Tag -"0"i 4461NU) JUN Casing Stub Retainer No : Surface Perforations at 13,164 - 13,200 ft MD; PBTD @ 13,295 ft MD. Approximately 1140 ft of cement left on top of retainer set at 12,795 ft MD; estimated 40 bbls cement pumped. Approximately 478 ft of tubing left in hole above ESP @ 13,278 ft. Cut off at 12,800 ft MD. Tag with drillpipe and set down with approximately 15,000Ibs. Followed with pressure test - pump rate at 3BPM; held 1500psi for 30 minutes (good) Distribution: -Well File (original) -Read File -DNR /DOG Rev.:01/26/09 by L.R.G. 2011- 0608_P &A_MPU_F- 80_mh.xls 6/14/2011 Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, June 06, 2011 3 :16 PM To: 'Bjork, David' Cc: Reem, David C; Stewman, Sondra D; Hubble, Terrie L; Barker, Elizabeth R (SAIC) Subject: RE: MPF -80 P&A (PTD 198 -217) Dave, As per our phone conversation today you have approval to set a cement retainer at 12800' and and attempt to squeeze cement past the stuck ESP pump to isolate the Kuparuk perforations. If injection past pump is not possible place 1000' of cement on top of the retainer as per plan. This will provide adequate isolation keeping hydrocarbons in their original strata and is approved per 20 AAC 25.112(i). No other oil pools are open besides the Kuparuk in this well ( 13164- 13200' md) The rest of the cement plugs and retainers planned for the suspension should go as per the sundry. Guy Schwartz Senior Petroleum Engineer AOGCC JUN 0 8 2.011 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Friday, June 03, 2011 2:02 PM To: Schwartz, Guy L (DOA) Cc: Reem, David C; Stewman, Sondra D; Hubble, Terrie L; Barker, Elizabeth R (SAIC) Subject: MPF -80 P&A (PTD 198 -217) Guy, The MPF -80 P/A is turning out to be a real bear of a fishing job. After 20ish fishing runs and 13 days we have the tubing stuck. We are estimating that the pump is stuck on bottom. We are planning on cutting the tubing with a -line and recovering what we can. I estimate that the minimum lower cement retainer will be set around 12,800ft instead of the proposed 13,100ft. We will attempt to squeeze the Kuparuk A -3 before dumping 1,000ft of cement on top of the plug. Right now the wellbore is plugged off, but we will get an injection test after setting the retainer. We will then proceed with the original plan of tagging and testing the plug. Is this acceptable? Thanks, Dave Bjork 564 -5683w 440 -0331 c 6/6/2011 • • STATE DEF ALM En SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM1IHSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 l Re: Milne Point Field, Kuparuk River Oil Pool, MPF -80 Sundry Number: 310 -410 Dear Mr. Reem: s NED JAN 1 2011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, 0/ Daniel T. Seamount, Jr. Chair DATED this day of January, 2011. Encl. STATE OF ALASKA r 3 l( RECEIVE -el1 ALAS ICAT AND GAS CONSERVATION COMMISwi t APPLION FOR SUNDRY APPROV : t, .�,t DEC 1 0 2010 20 AAC 25.280 %� n 1. Type of Request: Alaska OH & Gas Llms Lti nntnsaIOR Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved ProtAii 1 .gs Suspend /i 2 /3, /.d ® Plug Perforations ❑ Perforate ii Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. S Development ❑ Exploratory 198-217 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 22928 -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: MPF$0 Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 025509 & 388235' Milne Point Unit / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13408 7179 13295 7077 N/A 13278' Casing Length Size MD TVD Burst Collapse Structural _ Conductor 120' 20" 120' 120' 1490 470 Surface 5577' 9-5/8" 5612' 3860' 5750 3090 Intermediate Production 13346' 7" 13379' 7152' 8160 7020 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13164' - 13200' 6960' - 6992' 2 - 7/8 ", 6.5# L - 80 350' - 13054' Packers and SSSV Type: N/A Packers and SSSV N/A MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory -® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 5, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR Abandoned Commission Representative: ❑WAG ❑ SPLUG Suspended .17 A 17. I hereby certify th he foregoing is true and correct to the best of my knowledge. Contact David Bjork, 564-5683 Printed Name Da rid Ree Title Engineering Team Leader 1 / Prepared By Name/Number: Signature ^ Phone 564 Date /2 /�U/zeilo Elizabeth Barker, 564 -5674 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ✓ ?' (3 C-41 j 1 Sundry Number: - 0 Plug Integrity i BQEJest ❑ Mechanical Integrity Test ❑ Location Clearance Other: -k ` l ' C ) ' OS 6 aP — re; f 2.5 P 5 Z.. 401,1 4.4. 14--P" - ells t - I.AIti...,+ ...- 1,0er -- 4 w .4-i,t e.s,r pr £ T-- -Z L -- .P's-- . Subsequent Form R- • uired: / p a 7 APPROVED BY / 13 / / / Approved By 1 COMMISSIONER THE COMMISSION Date / ( ` / / Form 10-403 R- is 01/2010' Submit In Duplicate RBDMS jAN 0 1 201 R 1 G 1 N A L , L .,3. ,d N200 4 0 bp GP MPF -80 Rig (Plug and Abandon) Scope of Work: Pull parted ESP completion. Plug and abandon Kuparuk A sand. Set a cement plug across the surface casing shoe and cement to surface. Engineer: David Bjork MASP: 3,593 psi Well Type: Plug and Abandon Kuparuk Producer Estimated Start Date: January 5th, 2011 Pre -Riq Work Request: W 1 Check all lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT -T & IC. W 2 Set a BPV in the tubing hanger. Proposed Procedure 1. MIRU. ND tree. NU and test BOPE with four preventer stack (consisting of annular, 2 -7/8" x 5" VBRs, blind /shear, mudcross and 2 -7/8" x 5" VBR's) to 250 psi low /4� 000 psi high. Bullhead kill the well with brine. . 2. Fish / Pull and LD ESP completion assembly. 30 Seta 7" cast iron cement retainer at 13,100'. Squeeze 10 -bbls cement below the retainer and spot o / 40 -bbls cement on top of the retainer (-12,000'). Test the casing tpa-06e=psi for 10 charted minutes. 4. t$et a 7" cast iron bridge plug at 5,700'. /. . — LA);- E h- 2 p 5. Perforate the 7" casing at 5,550'; above the 9 -5/8" casing shoe at 5,612'. 6C6et a 7" cast iron cement retainer at 5,500' and pump 180 -bblg of cement below the retainer. of 220 -bbls of cement on top of the retainer. Test the casing to 1,000 -psi for 10 charted minutes , , t3 7. ND BOPE. Install dry hole tree. RDMO -.--f: ,,., 8. Final P/A work will be completed post rig. �: "" /Coo 604- 7 " x ° l v .o2yL g v�,Y Z 04 361 - - ' . 0 37( � 80f.; K Tree: CIW 2- 9/16" 5M 'FI " • M P U F -80 Orig. [ 11111= 43.25 (N 27E) Wellhead: 11" x 11" 5M FN en Orig. Gt.. _.ev. = 10.80' 5a 11" x 2 -7/8" NSCT. 2.5" CIW -H DF To Csg. spool= (N 27E) BPV profile. Tbg hanger +1 joint tbg II 20" 91.1 ppf, H-40 112' _ Broken -off tbg stub w/ Tight spot in 7" casing at 2063' 4 -es , 350' of ESP cable on top 1 350' had trouble getting desander past this point. ( There is no LaSage clamp on the first joint ' i of tbg left in the well. KOP @ 400' Max. hole angle = 70 to 76 deg. f/ OHES 9 5/8" ES" I I 5,950' to 10,700' 2098' Cementer Hole angle thru' perfs = deg. _, > , 9 5/8 ", 40 ppf, L -80 Btrcl 5612 i a Note: Had some trouble orienting in the top SPM. Possible need for replacement 2 -7/8 ", 6.5 ppf, L -80 EUE 8 rd on the next RWO ( drift ID = 2.347 ", Cap. =.0058 bpf) 7" 29 ppf, L -80, Hydri11.563 casing, t ;> ( drift ID = 6.184 ", cap. = 0.0371 bpf ) ' AVA Ported nipple w/ 12,839' I (isolation sleeve 1.87 ID) Mid -pert TD = 6967 Mid -pert MD = 13182' MS -1 Pressure Head I 12,989' I PBTD MD = 13295' PBTD TVD = 7017' Centrilift Tandem ESP I 12,991' I 27GC2200 &122GC2200 GPMTAR 1:1 ■-i. Centrilift gas separator I 13,017' I Stimulation Summary GRSFTXBARH6 12/29/98 'A' Sand refrac - 7200 # of AEA Centrilift seal section GS83DBUTAB/HSN PFSA ( 13,022' I AIIIMIL ChemFlow SI impregnated proppant and GS83DBLTA6/HSN FSA CL5 C KMH Motor Perforation Summary �°�' I 13,035' Ref log: SWS PDC 12 -07 -98 562 series, 209 hp, 2385 v, 53 a 85.8 M# of 16/20 Carbolite behind casing. Phoenix MS -1 Sensor w/ I 13,054' Kup. A -3 Sand 6 fin centralizer Sensor TVD - 6862' Size SPF Interval (TVD) 2.5 3 -- 13,164' -1 3,184' - -6941' - 6959' XTwo 7" x 20' marker joints 12,962' - 13002' 2.5 6 13,164' - 13,184' 6941' - 6959' — — e.«a 3 3/8 6 13184' - 13200' 6977' - 6992' 12/08/98 - 2.5" SWS RDX UP bighole charges 12/25/98 - 2.5" SWS RDX 35B UP .) bighole charges 6/27/05 - 3 3/8" SWS HSD PJ 3406 111 Last TD tag 13278' MD 6/28/05 with 4ES 11 Baker 7" WLSRBP with overshot & 4.5" fn. _______________�_ 7" float collar (PBTD) 1 13295' 7" float shoe I 13379' DATE REV. BY COMMENTS MILNE POINT UNIT 11/22/98 MDO Drill and Cased Nabors 27E 1/13/99 M. Linder Initial completion w/ desander 4 -ES WELL F-80 3/99 4/00 MDO / Linder ESP RWO 4-ES 00 due to corrosion 1/21/03 MDO ESP RWO4 -ES API NO: 50 -029 -22928 6/28/05 L Hulme Replace ESP / Add Perfs 4-ES 5/28/09 Worthington Update WBS - parted tbg during RWO BP EXPLORATION (AK) --MP F - 80 Propo P/ /`1 Orig. DF Elev. = 43.25 �Y� �J Orig. GL Elev. = 10.80 DF To Csg. spool= (N 27E) • Top of Cement 3' below tundra line 4 fi 20" 91.1 ppf, H -40 112' Tight spot in 7" casing at 2063' 4 -es ) HES 9 5/8" ES "Cementer 2098' had trouble getting desander past this 4 . point. " a KOP @ 400' Max. hole angle = 70 to 76 deg. f/ 7" Cast Iron Cement Retainer (5,500') 5,950' to 10,700' Hole angle thru' perfs = deg. a 9 5/8 ", 40 ppf, L -80 Btrc. 5612' , � 7" Cast Iron Bridge Plug (5,700') 7" 29 ppf, L -80, Hydri11.563 casing, ( drift ID = 6.184 ", cap. = 0.0371 bpf ) Mid -perf TD = 6967 Mid -perf MD = 13182' PBTD MD = 13295' PBTD TVD = 7017' Top of Cement 12,000' 8 u � Kup. A -3 Sand 7" Cast Iron Cement Retainer (13,100') t/ Size SPF Interval (TVD) 2.5 3 13,164'- 13,184' 6941' - 6959' ' 9 x : Two 7" x 20' marker joints 12,962' - 13002' 2.5 6 13,164'- 13,184' 6941' - 6959' v " 4 3 3/8 6 13184' - 13200' 6977' - 6992' - ,' 8 — 4 " Last TD tag 13278' MD 6/28/05 with 4ES xi Baker 7" WLSRBP with overshot & 4.5" fn. , s 7" float collar (PBTD) 13295' 7" float shoe 13379' DATE REV BY COMMENTS MILNE POINT UNIT 11/22/98 MDO Drill and Cased Nabors 27E 1/13/99 M. Linder Initial completion w/ desander 4 -ES WELL F -80 3/99 4/00 MDO / Linder ESP RWO 4 -ES 00 due to corrosion API NO: 50- 029 -22928 1/21/03 MDO ESP RWO 4 -ES 6/28/05 L Hulme Replace ESP /Add Perfs 4 -ES 5/28/09 Worthington Update WBS - parted tbg during RWO BP EXPLORATION (AK) • • MPF -80 P/A Doyon 16 12/6/2010 JJ �NJJJJJJJ % J�J��%�J�J�� i JJJJJJJJ JJJ �% ����% i �a��a :��� :������. _ ..�v�,�.y \:am \s \s \�. \sss.� I • I eTh d8 eh Mb Rh NA dh dh lh HYDRIL 13 5/8" 5M 'Annular: IHydril UK I Awe ohm "o II - 'M' , . ` � ' �`j Rams: 2 -7/8" x 5" variable HYDRIL ' , HYDRIL its. hatg 04 OISE 13 5/8" 5M 0 r Rams: [blind /shears 1 ,1111 WIL,F. n A k on, thffhordh , T a -. ((_ A. II= i adCros ®® l i a � :-4. 1 .-&-"- 1M ii: -,-,'=',.., glittiima: mi i Wit NW 1 i Rams: 2-7/8" x 5" variable 135/8 "5M - I I (4' - =f I lf, z • • Page 1 of 2 Schwartz, Guy L (DOA) From: Roby, David S (DOA) Sent: Wednesday, December 29, 2010 10:15 AM To: Schwartz, Guy L (DOA) Subject: RE: MPF -80 RWO (PTD 198 -217) Looking at the production data in OFM I concur that the well is near its economic limit, and in fact I assign lower remaining reserves to it than BP does. In late 2003 the water cut rose to approximately the same level as it was at when the well last produced in May 2009. Prior to the end of 2004 the well was producing consistently in the 600 to 700 BOPD range, which was likely the pump capacity, after that time the production began to decline and had dropped to approximately 400 BOP in June of 2005 when the ESP was replaced. For approximately 1 year after pump replacement the well produced in the 300 to 400 BOPD range before production was increased back to the approximately 600 BOPD that the well produced at previously. This time however production began declining immediately at a relatively constant rate for the next three years before the ESP failed again in May 2009. During the period of decline the water cut remained relatively constant and there is no information to indicate that the ESP was gradually failing, so the decline appears to be related to declining oil reserves and not some other factor. At that time the ESP failed the oil production was down to approximately 150 BOPD. BPXA initially attempted to pull the tubing and replace the failed ESP, but the tubing parted and made the workover much more difficult. Doing a decline curve analysis over the period August 2006 to May 2009, the period of constant decline, indicates that remaining reserves, assuming 100 BOPD economic limit, to be approximately 50 MBO. Therefore, I believe it is appropriate to allow BPXA to abandon the existing wellbore. Dave Roby (907)793 -1232 From: Schwartz, Guy L (DOA) Sent: Wednesday, December 29, 2010 9:38 AM To: Roby, David S (DOA) Subject: FW: MPF -80 RWO (PTD 198 -217) Here is the justification from BP. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bjork, David [mailto:David.Bjork @bp.com] Sent: Tuesday, December 21, 2010 9:23 AM To: Schwartz, Guy L (DOA) Cc: Engel, Harry R; Reem, David C; Stewman, Sondra D; Barker, Elizabeth R (SAIC) Subject: RE: MPF -80 RWO (PTD 198 -217) Guy, Below is the abandonment verbiage. Please let me know if you need any more information. 12/29/2010 • • Page 2 of 2 Regards, Dave MPF -80 has severely corroded and parted 2 -7/8" tubing with approximately 350 feet of ESP cable on top of the tubing stub. The rig work over will facilitate plug and abandonment operations. The rig workover is a risky operation due to the condition of the tubing and is complicated by the remaining ESP cable. MPF -80 is a low rate well with a remaining estimated reserve of 300 mbo based upon decline curve analysis. Considering the potential high intervention cost and need for new chrome tubulars, the economics do not support re- completion. Regardless of the cost to remove the parted tubing, the well is uneconomic. In addition there are no shallow, up -hole reserves in this well, therefore the well has no economic utility. From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, December 13, 2010 4 :39 PM To: Bjork, David Cc: Roby, David S (DOA) Subject: MPF -80 RWO (PTD 198 -217) Dave, We need more justification from your reservoir engineer to abandon this well. The sundry will not get approved until we feel this is the best alternative. There appears to be some reserves at risk if the well is abandoned, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 12/29/2010 NOT OPERABLE: ESP Producer MPF-80 (PTD #1982170) Secured with kill weight fluid Page 1 of 1 • Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Sunday, May 16, 2010 2:11 PM To: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, RES MPU Production Optimization Engineer; AK, OPS MPU Wells Ops Coord 2; AK, OPS MPU OSM; Engel, Harry R; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Welt Services Operations Team Lead Cc: Chebul, Josh M; Quy, Tiffany; Holt, Ryan P (ASRC); Winslow, Jack L (ASRC) Subject: NOT OPERABLE: ESP Producer MPF-80 (PTD #1982170) Secured with kill weight fluid All, Milne Point ESP Producer MPF-80 (PTD #1982170) has been secured with kill weight fluid on 5/15/2010. The well has been reclassified as Not Operable. The current plan forward is to review rig workover options. Please let us know if there are questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator 4"' ' ~ t` Office (907) 659-5102 ~_ . ~ ;, ~ ;~ „ ~~ ~ ~ t ti Cell (907) 752-0755 ~~°'~:. '~ ' ~ °~`-° Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer SeM: Monday, April 19, 2010 9:28 PM To: 'Regg, lames B (DOA)'; 'Maunder, Thomas E (DOA)'; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven; 'Schwartz, Guy (DOA)' Cc: Chebul, Josh M; Quy, T"ifrany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: ESP Producer MPF-80 (PTD #1982170) Sustained Casing Pressure on the IA All, Milne Point ESP Producer MPF-80 (PTD #1982170) has sustained casing pressure on the IA. The tubing parted at approximately 350' during a RWO, leaving the tubing, cable, and ESP in the hole as a fish. The wellhead pressures exceeded MOASP on 4/16!10 when the IA pressure was 2020 psi. The well has been reclassified as Under Evaluation. The plan forward is to video log the top of the fish to help evaluate future work. After the log is complete, the well'will be secured with a load and kill. A TIO Plot and Wellbore Schematic have been included for reference. « File: MPF-80 TIO plot.doc » Please let us know if there are any questions. Thank you, ,~nnu ~u6e, ~ ~. (alt Torin Roschinger) WeU Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 5/17/2010 UNDER EVALUATION: ESP Produ~MPF-80 (PTD #1982170) Sustained ~ing Pressure on... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] 1-~C~~, 4~~1/~ Sent: Monday, April 19, 2010 9:28 PM I~ To: Regg, James 6 (DOA); Maunder, Thomas E (DOA); MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven; Schwartz, Guy L (DOA) Cc: Chebul, Josh M; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: ESP Producer MPF-80 (PTD #1982170) Sustained Casing Pressure on the IA Attachments: MPF-80 TIO plot.doc; MPF-80.ZIP All, Milne Point ESP Producer MPF-80 (PTD #1982170) has sustained casing pressure on the IA. The tubing parted at approximately 350' during a RWO, leaving the tubing, cable, and ESP in the hole as a fish. The wellhead pressures exceeded MOASP on 4/16/10 when the IA pressure was 2020 psi. The well has been reclassified as Under Evaluation. The plan forward is to video log the top of the fish to e p evaluate future work. After the log is complete, the well will be secured with a load and kill. A TIO Plot and Wellbore Schematic have been included for reference. «MPF-80 TIO plot.doc» «MPF-80.ZIP» Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. (altTorin Roschinger) `~~ ~~~ ~ ~' ~~~~ Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 4/20/2010 MPU F-80 PTD 1982170 4/ 19/2010 TIO Pressures Plot Well: MPF-80 4,000 ',000 2.000 1,OD0 -~- T6g --~-- IA -~- OA OOA -~ OOOA On u 01/23110 01/30110 02/06110 02f13/1D 02/20/10 02127110 03/06!10 03113/1D 03/20110 03f27'1D 04103110 D4f10/10 0411?f1D • Tree: CIW 2-9/16" 5M 'FLS' ~ Wellhead: 11" x 11" 5M FMC Gen 5a 11" x 2-7/8" NSCT. 2.5" CIW-H BPV profile. 20" 91.1 ppf, H-40 ~ 112' ~ Tight spot in 7" casing at 2063' 4-es had trouble getting desander past this point. KOP @ 400' Max. hole angle = 70 to 76 deg. f/ 5,950' to 10,700' Hole angle thru' perfs = deg. 9 5/8", 40 ppf, L-80 Btrc 5617 ~ MPU F-80 2-7/8", 6.5 ppf, L-80 EUE 8 rd ( drift ID =2.347", Cap. =.0058 bpf) 7" 29 ppf, L-80, Hydrill.563 casing, ( drift ID = 6.184", cap. = 0.0371 bpf ) Mid-pert TD = 6967 Mid-pert MD = 13182' PBTD MD = 13295' PBTD TVD = 7017' Stimulation Summary 12/29/98 `A' Sand refrac - 7200 # of AEA ChemFlow SI impregnated proppant and Pertoration Summary Ref log: SWS PDC 12-07-98 85.8 M# of 16/20 Carbolite behind casing. Kup. A-3 Sand Size SPF Interval (TVD) 2.5 3 13,164'-13,184' 6941' - 6959' 2.5 6 13,164'-13,184' 6941' - 6959' 3 318 6 13184' - 13200' 6977` - 6992' 12/08/98 - 2.5" SWS RDX UP bighole charges 12/25/98 - 2.5" SWS RDX 356 UP bighole charges 6/27/05 - 3 3/8" SWS HSD PJ 3406 DATE REV. BY COMMENTS 11/22/98 MDO Drill and Cased Nabors 27E 1/13/99 M. Lind r Initial completion w/ desander 4-ES ./99 4/00 MDO / Linder ESP RWO 4-ES 00 due to corrosion 1/21/03 MDO ESP RW04-ES 6/28/05 L Hulme Replace ESP /Add Perts 4-ES 5/28/09 Worthington Update WBS -parted tbg during RWO Orig. DF E'1~G. = 43.25 (N 27E) Orig. GL Elev. = 10.80' DF To Csg. spool= (N 27E) Tbg hanger +1 joint tbg Broken-off tbg stub w/ 350` of ESP cable on top 350' There is no LaSalle clamp on the first joint of tbg left in the well. HES 9 5/8" ES" 2pgg Cementer Note: Had some trouble orienting in the top SPM. Possible need for replacement on the next RWO AVA Ported nipple w/ 12,839' (isolation sleeve 1.87 ID) MS-1 Pressure Head 12,989` Centrilift Tandem ESP 12,991' 27GC2200 &122GC2200 GPMTAR 1:1 Centrilift gas separator 13,017' GRSFTXBARH6 Centrilift seal section 13,022' GS83DBUT AB/HSN PFSA GSB3DBLT AB/HSN FSA CLS Centrilift KMH Motor 13,035' 562 series, 209 hp, 2385 v, 53 a Phoenix MS-1 Sensor w/ 13,054' 6 fin centralizer Sensor TVD - 6862' Two 7" x 20' marker joints 12,962' - 13002` Lasi TD tag 13278` MD 6/28105 with 4ES Baker 7" WLSRBP with overshot & 4.5" fn. 7" float collar (PBTD) 13295' 7" float shoe 13379' MILNE POINT UNIT WELL F-80 API NO: 50-029-22928 BP EXPLORATION STATE OF ALASKA AL~4 OIL AND GAS CONSERVATION CON~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ^ Pull Tubing ^ Perforate IVew Pool ^ Waiver ^ Other ^ Change Approved Program "~ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development ^ Exploratory 198-217 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22928-00-00 . 7. KB Elevation (ft): 43 25 . 9• ~Nell Name and Number: 4 . MPF-80 8. Property Designation: 10. Field / Pool(s): ADL 388235 ' Milne Point Unit / Kuparuk River Oil Pool . 11. Present well condition summary Total depth: measured 13408• feet true vertical 7179 ~ feet Plugs (measured) N/A Effective depth: measured 13295 feet Junk (measured) 13278' true vertical 7077 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20" 120' 120' 1490 470 Surface 5577' 9-5/8" 5612' 3860' 5750 3090 Intermediate Production 13346' 7" 13379' 7152' 8160 7020 Liner ~~ , ,~Ul ~. ~ ~Q~~ ~~~.~+~~~~~ .~~~ ~ ~ ~~as Perforation Depth MD {ft): 13164' - 13200' r~~~~~~ Q~t ~~~~ ~ ' ' p~~e ~~~~~SS'~~ - 6992 Perforation Depth TVD (ft): 6960 ~~h L ~r~ ~~ 350' - 13074' 'SO" 2-7/8", 6.5# Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): _ y~,`\ ~ ~ ~`~~ ~ Treatment description including volumes used and final pressure: ~3rY '~ l 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ~ Oil '^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 309-183 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Sig ature Phone 564-5743 Dat~~ Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 ~ Sub d Original On///ly~~~ / / ~ ~ .. l~s rl ~~4_ QF ~J L~VJ ~~/ ~..~~, ~-*] ~~...~/~" Gs' ~/ ~~ ( Tree: CIW 2-9/16" 5M 'FL~ Wellhead: 11" x 11" 5M FMC Gen 5a 11" x 2-7/8" NSCT. 2.5" CIW-H BPV profile. MPU F-80 Orig. Dl~lev. = 43.25 (N 27E) Orig. GL Elev. = 10.80' DF To Csg. spool= (N 27E) 20" 91.1 ppf, H-40 112' - Tight spot in 7" casing at 2063' 4-es had trouble getting desander past this point. KOP C~3 400' Max. hole angle = 70 to 76 deg. f/ 5,950' to 10,700' Hole angle thru' perfs = deg. 9 5/8", 40 ppf, L-80 Btrc 5612' I 2-7/8", 6.5 ppf, L-80 EUE 8 rd ( drift ID =2.347", Cap. =.0058 bpf) 7" 29 ppf, L-80, Hydrill.563 casing, ( drift ID = 6.184", cap. = 0.0371 bpf ) Mid-perf TD = 6967 Mid-perf MD = 13182' PBTD MD = 13295' PBTD TVD = 7017' Stimulation Summarv 12/29/98 'A' Sand refrac - 7200 # of AEA ChemFlow SI impregnated proppant and Perforation Summary Ref log: SWS PDC 12-07-98 85.8 M# of 16/20 Carbolite behind casing. Kup. A-3 Sand Size SPF Interval (TVD) 2.5 3 13,164'-13,184' 6941' - 6959' 2.5 6 13,164'-13,184' 6941' - 6959' 3 3/8 6 13184` - 13200' 6977` - 6992' 12/08/98 - 2.5" SWS RDX UP bighole charges 12/25/98 - 2.5" SWS RDX 356 UP bighole charges 6/27/05 - 3 3/8" SWS HSD PJ 3406 DATE REV. BY COMMENTS 11/22/98 MDO Drill and Cased Nabors 27E 1/13/99 M. Linder Initial completion w/ desander 4-ES 3/99 4/00 MDO / Linder ESP RWO 4-ES 00 due to corrosion 1121/03 MDO ESP RWO 4-ES 6/28/05 L Hulme Replace ESP / Add Perfs 4-ES 5/28/09 Worthington Update WBS - parted tbg during RWO Tbg hanger +1 joint tbg ~ Broken-off tbg stub w/ 350' of ESP cable on top 350' HES 9 5/8" ES" 209g Cementer AVA Ported nipple w/ 12,839' (isolation sleeve 1.87 ID) MS-1 Pressure Head 12,989` Centrilift Tandem ESP 12,991` 27GC2200 &122GC2200 GPMTAR 1:1 Centrilift gas separator 13 017` GRSFTXBARH6 , Centrilift seal section ' GS63DBUTAB/HSN PFSA 13,022 GS83DBLT AB/HSN FSA CL5 Centrilift KMH Motor 13,035' 562 series, 209 hp, 2385 v, 53 a Phoenix MS-1 Sensor w/ 13,054' I 6 fin centralizer Sensor TVD - 6862' Two 7" x 20' marker joints 12,962' - 13002`~ Last TD tag 13278` MD 6128/05 with 4ES Baker 7" WLSRBP with avershot & 4.5" #n. 7" float collar (PBTD) 13295' 7" float shoe 13379' MILNE POINT UNIT WELL F-80 API NO: 50-029-22928 BP EXPLORATION • • BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPF-80 Common Well Name: MPF-80 Spud Date: 10/28/1998 Event Name: WORKOVER Start: 5/14/2009 End: 5/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/24/2009 Rig Name: NABORS 3S Rig Number: ' Date' From - To Hc~urs Task Code NPT Phase Qescriptior~ of Operatians 5/19/2009 08:00 - 15:00 7.00 WHSUR C WHDTRE Wait on Slickline for static reading on Mid-perf extrapolation. 15:00 - 16:30 1.50 WHSUR C WHDTRE Confer with ADW RWO Engineers in Anchorage on 11.2 ppg kill fluid. BPV set by well support techs, slick line unit off MPF-80. 1,200 psi on tubing. 16:30 - 20:30 4.00 CONS C PRE ait on a prep rom roa s and Pads on MPF-80. Remove Rig mats and Well work platform from MPF-79 20:30 - 22:00 1.50 CONS P PRE Clean and clear the snow / ice from behind MPF-80 and level out any gravel around the well. 22:00 - 00:00 2.00 MOB P PRE Position the rig mats with herculite around the wellhead. Spot the rig over MPF-80 with WSL and Pad Op witnessing, position rig mats under the sub and jack up the rig. 5/20/2009 00:00 - 01:30 1.50 MOB P PRE Spot the pipe shed and pits onto the sub. Build containment around the cellar. 01:30 - 02:30 1.00 MOB P PRE Rig up the service and electrical lines, test and run the pipe skate. 02:30 - 04:00 1.50 RIGU P PRE Prep, raise, and scope up the derrick, tighten the load lines, raise the wind walls. Rlg up the derrick climber and angel decent. Accept the rig @ 0400 hrs. 04:00 - 06:00 2.00 RIGD P PRE Rlg up an test t e surface lines 3500 psi and downstream to the tiger tank to 500 psi. Rig up and test LRS surface lines to 3500 psi. 06:00 - 10:00 4.00 WHSUR P WHDTRE PU/MU and test lubricator to 500 psi with diesel. Well support techs puli BPV, LD lubricator and service IA valve. Load Pits wit 20 eg 8.45 ppg seawater. 10:00 - 11:00 1.00 WHSUR P WHDTRE Held safety meeting with ADW superintendent during visit to Rig. 11:00 - 12:00 1.00 WHSUR P WHDTRE Complete pressure test on surtace lines to 3,500 psi. 12:00 - 18:00 6.00 WHSUR P WHDTRE Held pre-well kill meeting. Open well to closed Choke. WHP's: Tubing = 1070 psi, IA = 1100 psi. Bleed IA and tubing to 480 psi on the ubing and 520 psi on the IA. Pump 75 bbls of 8.43 ppg, 120 degF seawater at 4 bpm / 730 psi down the tubing up the IA through the choke to the Tiger tank and recovered 40 bbls crude. Close the Choke and bullhead down the tubing 14 bbls at 4 bpm / 1950 psi. Open the Choke and finish circulating 194 bbls 8.45 ppg seawater followed by 75 bbis 11.2 ppg brine at 4 bpm /-500 psi the long way. Close the Choke and bullhead down the tubing 21 bbls at 3 bpm / 1650 psi. Open the Choke and finish circulating 375 bbls at 4 bpm / 500 psi down the tubing up the IA through the choke to the Tiger Tank during final circulation. Returns fluid weight 8.6 ppg stop pumping. Order 11.2 ppg brine. Shut in and observe WHP~ for 30 minutes. TBG = 360 , IA = 390 psi. 18:00 - 23:00 5.00 WHSUR P WHDTRE Blown down line and valves. ai on . ppg brine from MI-mud plant. Talked with the Anchorage RWO engineer to confirm wait of 11.2 ppg. 23:00 - 00:00 1.00 WHSUR P WHDTRE Spot and off load the 11.2 ppg brine from the MI-mud plant to our pits and upright tank. Then we spotted / rigged up the dirty truck to the tiger tank and hauled away 290 bbls of well fluids. 5/21/2009 00:00 - 03:30 3.50 WHSUR P WHDTRE Open the Choke and circulate 100 bbls at 4 bpm / 520 psi down the tubing up the IA through the choke to the Tiger Tank with 11.2 ppg brine. Shut down and monitor well for 30 minutes. Had a Tubing pressure of 250 psi and a IA pressure of 290 psi. Transfer 75 bbls of 11.2 ppg and begin circulating Printed: 6/8/2009 11:35:47 AM ~ • Q ~E:1' Legal Well Name: MPF-80 Page 2' ~ort Common Well Name: MPF-80 Spud Date: 10/28/1998 Event Name: WORKOVER Start: 5/14/2009 End: 5/24/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/24/2009 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/21/2009 00:00 - 03:30 3.50 WHSUR P WHDTRE at 4 bpm / 510 psi through the choke to the Tiger Tank. Returns fluid weight 11.0+ ppg when pumping was complete. Shut in and observe wRP s for 30 minutes. TBG = 220 psi , IA = 240 psi. 03:30 - 04:00 0.50 WHSUR P WHDTR pen e hoke and circulate 100 bbls at 4 bpm / 520 psi down the tubing up the IA through the choke to the Tiger Tank with 11.2 ppg brine. Shut down and monitor well for 30 minutes. Had a Tubing pressure of 250 psi and a IA pressure of 290 psi. Transfer 75 bbls of 11.2 ppg and begin circulating at 4 bpm / 510 psi through the choke to the Tiger Tank. Returns fluid weight 11.0+ ppg when pumping was complete. Shut in and observe WHP's for 30 minutes. TBG = 220 psi , IA = 240 psi. 04:00 - 11:30 7.50 WHSUR P WHDTRE Wait on 11.5 ppg Spike fluid from the Mi-Mud plant. 11:30 - 13:30 2.00 WHSUR P WHDTRE oa lui s, mix an en i ui o . ppg rine. Held circulation Well Kill meeting. 13:30 - 18:00 4.50 WHSUR P WHDTRE SITP = 220, SICP = 280 psi. Open choke and pump down the tubing 75 bbls 11.2 ppg brine at 4 bpm / 200-390 psi through the gasbuster to the Pits. Bull head 14 bbls into formation at 2 bpm / 650 - 830 psi. Shut-in and monitor WHP's for 30 minutes SITP = 190 psi. Confer with ADW RWO Engineer, Anchorage to order 12 ppg brine. Resume pumping down the tubing up the IA through the gasbuster to the Pits, mixing Spike fluid (11.5 ppg) to maintain 11.2 ppg brine. Pumped a total of 543 bbls till returns at surface were 112 ppg. Monitor WHP's for 30 minutes, Tbg = 110, IA = 140, OA = 10 psi. 18:00 - 00:00 6.00 WHSUR P WHDTRE Remove 580 bbls of 11.2 ppg brine from location to Pad 3. Wait on 600 bbls of 12.0 ppg brine from Mi-Plant. 5/22/2009 00:00 - 02:00 2.00 WHSUR P WHDTRE Receive 600 bbls of 12.Oppg brine from the Mi-Plant and offload into the upright tank and the pits. 02:00 - 06:00 4.00 WHSUR P WHDTRE Wait on an additional 400 bbls of 12.Oppg brine from Mi-Plant before starting circulation in case there are issues with the Kuparuk river bridge. 06:00 - 12:30 6.50 WHSUR P WHDTRE Held fluid displacement meeting with crew. Displace Well with 75 bbis of 12.0 ppg brine at 4 bpm / 400 psi down the tubing up the IA through choke to the Tiger tank. Bullhead 14 bbls at 2 bpm / 600-750 psi into formation. Resume displacing 12.0 ppg Brine in at 4 bpm / 400 psi tiil returns at surface are 12.0 ppg Brine. Return fluid weight at bottoms up cut to 10.4 ppg. Pumped a total of 575 bbls. 12:30 - 13:00 0.50 WHSUB P WHDTRE Monitor WHP's for 30 minutes, Blow down lines and valves. Tubing and IA on a slight vacuum. 13:00 - 13:30 0.50 WHSUR P WHDTRE own own ines, i manifold and valves. 13:30 - 15:00 1.50 WHSUR P WHDTRE D rod TWC with FMC wellhead tech. Pressur from above to 3,500 si for 10 charted minut t from below to 500 psi for 10 charted minutes bv iniectinq into formation at 1.4 bpm / 500 psi. Pumped 30 bbls and recovered 3 bbls. TBG and IA on a slight vacuum. 15:00 - 15:30 0.50 WHSUR P WHDTRE R/D surface lines, kill manifold and lines. 15:30 - 17:00 1.50 WHSUR P WHDTRE ND production tree and adaptor, then set back. Remove SSSV for service. 17:00 - 18:00 1.00 WHSUR P WHDTRE Nipple up the DSA and single gate rams, then drag the BOP's into the cellar. Pfinted: 6/8/2009 11:35:47 AM ~ ~ BP EXPLQRATION Page 3 of 3' Operatians Summary Report Legal Well Name: MPF-80 Common Well Name: MPF-80 Spud Date: 10/28/1998 Event Name: WORKOVER Start: 5/14/2009 End: 5/24/2009 Contractor Name: .' NABORS ALASKA DRILLING I Rig Release: 5/24/2009 Rig Name: NABORS 3S Rig Number: Date ' From - To Hours Task Code NPT Phase Deseriptian of Operations 5/22/2009 18:00 - 00:00 6.00 WHSUR P WHDTRE Nipple up the BOP stack. on iguration: -Annular -2 7/8" x 5" VBR -Blind Rams -2 7/8" Rams -DSA Fluid level shot C~ 19:00 and was 180' below the wellh` e~ad: 5/23/2009 00:00 - 05:30 5.50 BOPSU P W HDTRE Pressure test BOPE t 50 psi low and 3,500 psi high per BP / AOGCC Regulations. Each test held for 5 minutes. The top VBRs (2-7/8" X 5"), Blind rams, lower pipe rams (2-7/8") and Annular were tested with a 2-7/8" Test Joint against TWC. The test was witnessed by AOGCC rep Bob Noble,NAD Toolpusher Rick Bjorhus, and BP WSL Chris Kobuck. 05:30 - 06:00 0.50 WHSUR P WHDTRE Clean and clear the floor after BOP Test and prepare to pull the TWC. 06:00 - 07:00 1.00 WHSUR P WHDTRE PU/MU Opso Lopso and lubricator, test to 500 psi with diesel. Well support techs pulled TWC. Tbg and IA on a vacuum. 07:00 - 08:30 1.50 PULL P DECOMP MU 2-7/8" landing joint with TIW valve. FMC wellhead tech, BOLDS. Pull tubing hanqer free at 70K, and strina oarted at_ 75K. 08:30 - 11:00 2.50 WHSUR C WHDTRE Circulate 5 bbls to clear tubing. LD landing joint and TIW valve. POH and LD tubing hanger with hanger pup, 10' 2-7/8" tbg pup, 9 joints 2-7/8"tbg, 28.91' of parted joint, GLM. Total feet recovered = 350', and 12' ESP cable 7- Lasalle clamps. on er wi RWO Engineer on plan forward. -Left in hole• 12704' of 2 875" comnletion with FSP nn tha _ bottom. Looking up is 2 7/8" 6.5 ppf L-80 EUE 8 rd, drift ID= so, 5 o ESP cable on to of fish. 11:00 - 14:00 3.00 WHSUR C WHDTRE tubing hanger with landing joint and TIW valve. Land tubing hanger with hanger pup, 10' 2-7/8" pup, and 1 joint 2-7/8" tubing. FMC rep RILDS. Pressure test TWC to 3 500 psi from above or charted minutes and below b in'ectin i a ion a. pm 500 psi. Pumped 24 bbls and recovere s. 14:00 - 16:00 2.00 WHSUR WHDTRE Laydown Centralift tools then blow down lines and valves. 16:00 - 00:00 8.00 WHSUR WHDTRE Pull the riser, disconnect the Koomy, choke, and kill lines. Nipple down the BOPE. Remove the rams from the double gate and change out the rams in the single gate to 2 7/8" x 5" VBR's 5/24/2009 00:00 - 03:00 3.00 WHSUR WHDTRE Nipple up the tree and replace the actuator valve. Test the void to 3500 psi for 30 minutes. Good Test. Test the tree to 5000 psi. Good Test 03:00 - 04:00 1.00 WHSUR WHDTRE Rig up the lubricator and test to 500 psi. Good Test. Pull the TWC and set the BPV.. -Rig release C~ 0400 to go to MPL-43 Printed: 6/8/2009 11:35:47 AM .» . • • ka g F~` ~~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ I ~\ P=~. ~ SARAH PAUN, GOVERNOR ~ ask ~ ~~ ~~ ~, ~`. s~ ~ ~~ ~~ ~~ ~~rr~~ O AisD ~7 333 W. 7th AVENUE, SUITE 100 tlirt~-7 II! ~ CO1~T5ERQA7`IOAT CO1rII1IISSIOI~T / ANCHORAGE, ALASKA 99501-3539 !,C PHONE (907) 279-1433 FAX (907) 276-7542 ~:. David Reem Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 ~~ Anchorage, Alaska 99519-6612 .... .~.. :~ti Re: Milne Point Field, Kuparuk River Oil Pool, MPF-~0 Well Sundry Number: 309-183 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 Commission'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, Cathy P. Foerster Commissioner DATED this Z day of June, 2009 Encl. ~b ,o`~ ~,ti STATE OF ALASKA ~~~'~" ALA~OIL AND GAS CONSERVATION COMM~O APPLICATION FOR SUNDRY APPROV ~ l ~~~' 7~g~ 20 AAC 25.280 .. 1. Type of Request: ^ Abandon ^ Suspend • ®Operation Shutdown ^ Perforate ^ Time E en ion "~ ' - ISSfOA) '~ ~ rl~ ~rra ~ ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspen ed Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ' ®Development ^ Exploratory 198-217 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22928-00-00 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: MPF$0 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ~~'/ ~~ ADL 388235.. 43.25 Milne Point Unit / Kuparuk River s ~ ~ ' 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13408 7179. 13295 7077 N/A 13278' in n h i MD N r oll trutrl n 1 1 12 ' Surfa 5577' 9-5/8" 5612' 6 ' S7 In erme is e 1 4' 7" 1 71 2' 1 7 2 finer Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13164' - 13200' 6960' - 6992' 2-7/8", 6.5# L-80 350' - 13074' Packers and SSSV Type: N/A Packers and SSSV MD (ft): 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: May 24, 2009 ®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 Aras Worthington, 564-4102 Printed Name vid Reem Title Engineering Team Leader Prepared By NamelNumber: Signature ~ Phone 564-5743 Dates~zpf,~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: 3act,- ~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~ ~ ~ 'CAS v ME '~~;~C.~0.~~`O'l\S lam- 1 ,~ Subsequent Form Required: (,..~ d ~ ~- ~Ot~S "~~`NS~~ ~- ~ ~ - lVQS~ r~oQe~ C.E ~ APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date (O '^ c>`~ Form 10-403 Revised/b6/2006 Submit In Duplicate 6 ~ I ~ A L~ ~ ~ ~i~ ~ ~ 2~~9 -~~~~~f • MPF-80 Operations Shutdown • Nabors 3S shutdown operations on MPF-80 on May 24, 2009. This was done because as the tubing was being pulled from the wellbore it parted at 350'. This would require an extended fishing operation. Unfortunately, delivery of additional brine was not available due to the fact that the Kuparuk River bridge was in danger of being closed / soon. The decision was made to run the tubing hanger back in the well, install and test the BPV and leave the well until 12 ppg brine was readily available from MI and a thorough fishing plan was developed. Operations Thus Far: • Rigged up on well and circulated to 11.2 ppg brine. The well was not dead and showed 200 psi on casing and tubing. • 12.0 ppg brine was called out and circulated. This killed the well and tubing and casing were on a slight vacuum. • ND Tree, NU BOPS and tested. • Pulled tubing hanger free at ~70K and at --75K the tubing parted shallow. • LD 9 joints of tubing and one parted joint 0350' of tubing). ESP cable pulled out of tubing hanger and LIH. Tubing was severely corroded. • Checked availability of 12 ppg brine for extended fishing operations. Decision was made to safe out the well and leave location (temporarily). Plan Forward (within approximately the next three months): • MIRU NOES • Kill well with brine • Fish corroded tubing and ESP • Run new ESP completion • RDMO N4ES r~,g: CI'1N 2-9/16" SM 'FLS' }~Ihead: 11" x 11" SM FMC Gen 5a 11" x 2-7/8" NSCT. 2.5" CIVIHH BPV profile. ZO" 91.1 ppf, H-40 112' Tight spot in 7" casing at 2063' 4-es had trouble getting desander past this point. KOP @400' Max. hole angle = 70 to 76 deg. f/ 5,950' to 10,700' Hole angle thru' perfs = deg. 9 5/8", 40 ppf, L-80 Btrc. 5612' 2-7/8", 6.5 ppf, L-80 EUE 8 rd ( drift ID =2.347°, Cap. =.0058 bpf) 7" 29 ppf, L-80, Hydrill.563 casing, ( drift ID = 6.184", cap. = 0.0371 bpf ) F-80 Orig. DF Elev = 43.25 -; Orig. GL Elev. = 10.80' DF To Csg. spool= (N 27E) Tbg hanger +1 joint tbg Broken-off tbg stub w/ 350` of ESP cable on top 350' ~IiES 9 5/8" ES" ~I Cementer Note: Had some trouble orienting in the top SPM. Possible need for replacement on the next RWO AVA Ported nipple w/ 12 839' (isolation sleeve 1.87 ID) Mid-perf TD = 6967 Mid-pert MD = 13182' PBTD MD = 13295' PBTD TVD = 7017' MS-1 Pressure Head 12,989` Centrilift Tandem ESP 12,991` 27GC2200 &122GC2200 GPMTAR 1:1 Stimulation Summary 12/29/98 'A'Sand refrac - 7200 # of AEA ChemFk>+tnr SI impregnated proppant and Perforation Summary Ref log: SWS PDC 12-07-98 85.8 M# of 16/20 Carbolite behind casing. Kup. A-3 Sand Size SPF Internal (f VD) 2.5 3 13,164'-13,184' 6941' - 6959' 2.5 6 13,164'-13,184' 6941' - 6959' 3 3/8 6 13184' - 13200' 6977' - 6992' 12/08/98 - 2.5" SWS RDX UP bighde charges 12/25/98 - 2.5" SWS RDX 356 UP bighole charges 6/27/05 - 33/8° SWS HSD PJ 3406 Centrilift gas separator 13,017` GRSFTXBARH6 Centrilift seal section ' GS63DBUTAB/HSN PFSA 13,022 GSB3DBLT AB/HSN FSA CL5 Centrilift KMH Motor 13 035' 562 series, 209 hp, 2385 v, 53 a , Phoenix MS-1 Sensor w/ 6 fin centralizer 13,054` Sensor TVD - 6862' Two 7" x 20' marker joints 12,962' - 13002' Last TD tag 13278' MD 6/28/05 with 4ES Baker 7" WLSRBP with overshot 8r 4.5° fn. 7" float collar (PBTD) 13295' I 7° float shoe 13379• DATE 3/99 4/00 1 /21 /03 6/28/05 6Y 1 COMMENTS 1 Linder I ESP RWO 4-ES 00 due to corrosion MDO ESP RWO 4-ES L Hulme Replace ESP /Add Perfs 4-ES MILNE POINT UNIT WELL F~0 API NO: 50-029-22928 BP EXPLORATION Page 1 of 1 Maunder, Thomas E (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Tuesday, May 26, 2009 4:21 PM To: Maunder, Thomas E (DOA) ` 1 Subject: RE: Workover Rpt to AOGCC C~ ~ ~`~ Hi Tom, Looks like you are right... I'll be getting that over to you tomorrow. Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 26, 2009 2:47 PM To: Hubble, Terrie L Subject: RE: Workover Rpt to AOGCC Thanks Terrie. Regarding MPF-80, I understand the tubing was parted and there was a desire to move on to another well. Is this correct? If so, I think operations SD applies here. If you can, please provide some additional information. Tom From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Tuesday, May 26, 2009 2:18 PM To: Maunder, Thomas E (DOA); McMains, Stephen E (DOA) Subject: Workover Rpt to AOGCC 6/1/2009 Page 1 of 1 • Maunder, Thomas E (DOA) From: Noble, Robert C (DOA) Sent: Sunday, May 24, 2009 4:21 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA) Subject: Nabors 3S MPF-80 ~ ~~- '~ ~ Jim I witnessed a BOP test yesterday morning on this rig. This morning I got a call fora 24 hr notice for another BOP test. I questioned the Co. man. He told me that they parted tubing while trying to pull it on MPF-80. He said with the Kuparuk River about ready to go out they didnt want to try to finish this well. He also said the well had kill weight fluid in it and they had reinstalled the tree and tested it. They were going to move to another well. Bob Bob Noble Petroleum Inspector Alaska Oil & Gas Conservation Commission (907) 659-3607 ~~ 1L.U6.u' 5/25!2009 L • r~ STATE OF ALASKA sn2ros OIL AND GAS CONSERVATION GOMMISSiON BOPS Test Report Submit to: Contractor: Nabors Rig No,: 3S DATE: 5/25/09 Rig Rep.: G.Sweatt/R.Bjorhus Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: BP Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: D.Rhodes / C_Kobuck E-Mai! adwdr3snsu~bp.com Well Name: MPF~O PTD # 1982170 Operation: Drlg: Workover. x Explor.: Test: Initial: X Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular. 250/3500 Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NT Housekeeping: P Drl. Rig P Lower Kelly 0 NT PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc P Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity SizelType Test Result MUD SYSTEM: Visual Alarm Stripper 0 NT Trip Tank P P Annular Preventer 1 3 5/8 5000p: P Pit Level Indicators P P #1 Rams 1 2 7/8 x 5" P Flow Indicator P P #2 Rams 1 blind P Meth Gas Detector P P #3 Rams 1 Z 7/8" P H2S Gas Detector P P #4 Rams 0 NA MS Misc P P #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1!8" P Inside Reel valves 0 NA HCR Valves 2 2 1/16" 3 1/8" P Kill Line Valves 1 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 1400 P Quantity Test Result 200 psi Attained 30 sec P No. Valves 13 P Full Pressure Attained 219 sec P Manual Chokes 1 NT Blind Switch Covers: All stations Yes Hydraulic Chokes 1 NT Nitgn. Bottles (avg}: 4 1900 i CH Misc 0 NA ACC Misc NA Test Results Number of Failures: 0 Test Time: 5.0 Hours Repair or replacement of equipment will be made within days. Notify the North Slope Ins ector 659-3607, follow with written confirmation to Su rvisor at: Remarks: Tested with 2 7/8" test joint against TWC, Chris Kobuck WSL and Rick Bjorhus T.P. Witnessed with Bob Noble State Rep. 24 HOUR NOTICE GIVEN YES x NO Waived 8y Date 5120/09 Time 06:20 Witness Bob Noble Test start 00:00 Finish 05:00 BOP 05/12/09 Nabors 3S BOP Test MPU F-80 5-25-2009.x1s 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program J STATE OF ALASKA) RECE/\ ,If':".'" ALASKA IL AND GAS CONSERVATION COlv(MISSION V c[) REPORT OF SUNDRY WELL OPERATIONS AUG 042005 Alaska Oil & Gr~¢>\ C.. R J (Ins C· . JI,... ~ ,omr-'!r.~.;,. .¡r,'1 ChangØ'11Øí~ge . :¡;""')I~'¡I, o Suspend 0 Operation Shutdown a Perforate a Other o Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well a Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: a Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 198-217 6. API Number: 50-029-22928-00-00 99519-6612 43.25 9. Well Name and Number: MPF-80 8. Property Designation: ADL 388235 10. Field 1 Pool(s): Milne Point Unit 1 Kuparuk River Sands 11. Present well condition summary Total depth: measured 13408 feet true vertical 7179 feet Plugs (measured) N/A Effective depth: measured 13295 feet Junk (measured) 13295' true vertical 7077 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 120' 20" 120' 120' 1490 470 Surface 5577' 9-5/8" 5612' 3860' 5750 3090 Intermediate Production 13346' 7" 13379' 7152' 8160 7020 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 13164' - 13200' 6960' - 6992' ~"r-h",H\U:::::C" ru'i(, n G 200¡¡: t) \w.M"'U\'J a 1.1 ~';,~'.) ~."\¡ V ILl t' ~j .,.jI ;J Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8", 6.5# L-80 13074' N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8FL AUG 08 2005 Oil-Bbl Prior to well operation: 484 Subsequent to operation: 602 14. Attachments: 0 Copies of Logs and Surveys run a Daily Report of Well Operations a Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure 120 1301 400 130 1331 370 Tubinq Pressure 335 300 13. 15. Well Class after proposed work: o Exploratory a Development 0 Service 16. Well Status after proposed work: a Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Signat~Ør.~ Form 10-404 Revised 04/2004 Title Technical Assistant Phone . 0 1/ ...... Prepared By Name/Number: Date 0 õ --l:J..1't)ßondra Stewman, 564-4750 Submit Original Only 564-4750 O F' 'I ,r"'·, '\ I , ., I ¡" : \) ¡ ~ ".'j. . l\ L._ \ , ~ "'.-' i. j \...., ) ') BP EXPLORATION OperationS$UmJ11aryReport Page 1 of 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-80 MPF-80 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/25/2005 Rig Release: 6/30/2005 Rig Number: Spud Date: 10/28/1998 End: 6/30/2005 Date From - To HOLl rs Task Code NPT Phase Description of Operations 6/25/2005 21 :00 - 23:00 2.00 RIGD P PRE RID Rig. Scope down & lower derrick. 23:00 - 00:00 1.00 MOB P PRE Move rig & pipe shed from MPL-25 to MPF-80. 6/26/2005 00:00 - 02:30 2.50 MOB P PRE Con't to Move from MPL-25 to MPF-80. Layout herculite & matting boards. Spot rig over well. Spot in pipe shed, pits & camp. 02:30 - 04:00 1.50 MOB P PRE Raise & scope up derrick. Con't to R/U equip. Rig Accepted @ 04:00 hrs. 04:00 - 05:00 1.00 RIGU P DECOMP R/U lines to tiger tank. Valve on annulus leaking. Cannot hook up lines to tree. Valve pressured up. Start taking on 120 degree seawater. 05:00 - 06:00 1.00 WHSUR P DECOMP P/U lubricator. Pull BPV. UD lubricator. Con't to take on seawater. IIA valves leaking, (2), call valve crew, apply valve grease, OK. 06:00 - 07:00 1.00 WHSUR P DECOMP Add secondary HCR valve on I/A. Test lines @ 250 I 3500 psi, OK. 07:00 - 07:30 0.50 KILL P DECOMP Conduct pre kill safety meeting. Notify Milne Pt of impending gas venting ops. Bleed gas off tbg to tiger tank. 07:30 - 08:30 1.00 KILL P DECOMP Commence pumpiong seawater down tubing @ 3 bpm 11400 psi, taking returns up I/A, thru choke & to tiger tank. Pump 75 bbls, shut in & bullhead 10 bbls @ 2 bpm I 1700 psi. Resume pumping down tubing @ 3 bpm 11400 psi & taking returns to tiger tank. Pump (50) bbls & bleed IIA & shut in well. 08:30 - 09:00 0.50 KILL P DECOMP Monitor well, SITP = 830 psi after (30) minutes. Order 11.1 ppg kill weight fluid. 09:00 - 11 :30 2.50 KILL P DECOMP Resume circulating heated seawater around. Pumped 500 bbls, clean seawater returns coming back. 11 :30 - 12:30 1.00 KILL P DECOMP Monitor well. Confirm SITP = 830 psi. 12:30 - 16:30 4.00 KILL P DECOMP Resume circulating rest of heated seawater around @ 4 bpm I 1500 psi wI waiting on kill wt fluid. Pumped total of 900 bbls heated seawater. 16:30 - 20:30 4.00 KILL P DECOMP Take on 11.1 ppg kill wt brine & commence circulating to kill well @ 4 bpm I 1370 psi, taking seawater returns thru choke to tiger tank. WI tubing volume pumped, bullhead 10 bbls @ 3 bpm I 830 psi. Continue pumping kill wt fluid around @ 4 bpm I 1700 psi. Final rate 4 BPM @ 1800 psi. Pumped total of 590 bbls, Monitor well. Circulate well thru pits, had light spot in returns.S/D Well dead. 20:30 - 21 :00 0.50 WHSUR P DECOMP Set & test TWC. Blow down & RID kill lines. 21 :00 - 23:00 2.00 WHSUR P DECOMP NID HCR valve & bled off tubing void. NID adapter flange & tree. 23:00 - 00:00 1.00 BOPSUR P DECOMP N/U BOPE. 6/27/2005 00:00 - 00:30 0.50 BOPSUP P DECOMP Con't to N/U BOPE. 00:30 - 04:00 3.50 BOPSU8 P DECOMP Pressure test BOPE as per AOGCC/BP requirements. LP 250 psi, HP 3500 psi. No Failures. BOP test witnessing waived by Jeff Jones wI AOGCC. Blow down & RID test equip. 04:00 - 04:30 0.50 WHSUR P DECOMP P/U lubricator, pull TWC. UD lubricator. 04:30 - 05:00 0.50 PULL P DECOMP M/U landing jt into hanger. BOLDS. Pull hanger to floor wI 90K. Break out, UD hanger & landing jt. 05:00 - 05:30 0.50 PULL P DECOMP POOH & standback 2 7/8" ESP completion. UD pup jt. below hanger due to damage. 05:30 - 06:30 1.00 PULL P DECOMP PJSM. Circulate hole to clean up oil that has migrated up. 06:30 - 14:00 7.50 PULL P DECOMP PJSM. POOH w/2 7/8" ESP completion string. Stand back tubing. Double displacing hole, fluid level continuously Printed: 7/1/2005 9:50:45 AM ) ) BP EXPLORATION Ope.ratiöns Summary Report Page 20f 3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-80 MPF-80 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 6/25/2005 Rig Release: 6/30/2005 Rig Number: Spud Date: 10/28/1998 End: 6/30/2005 Date From- To Hours Task Code NPT Phase Description of Operations 6/27/2005 06:30 - 14:00 7.50 PULL P DECOMP dropping. 14:00 - 16:30 2.50 PULL P DECOMP Break out & LID ESP. 16:30 - 17:30 1.00 PULL P DECOMP Clear & clean rig floor. 17:30 - 18:30 1.00 PRFADD P DECOMP NID flow nipple. N/U shooting nipple for perforating operations. 18:30 - 19:30 1.00 PRFADD P DECOMP Wait on perforators. Move spooling unit. 19:30 - 22:00 2.50 PRFADD P DECOMP R/U perforating equip. Hold PJSM. Pressure test lubricator to 500 psi, Ok. 22:00 - 00:00 2.00 PRFADD P DECOMP Arm & P/U perforating guns. RIH Attempt to get to bottom, unable to get deeper than 7620'. 6/28/2005 00:00 - 00:30 0.50 PRFADD P DECOMP POOHwl perf guns. 00:30 - 01 :30 1.00 PRFADD N DPRB DECOMP Mix & pump 15 bbls EP lube pill in well. 1 BPM @ 300 psi. Reposition wireline sheave. 01 :30 - 04:00 2.50 PRFADD N DPRB DECOMP RIH wi perf guns to 8260' Made several attempts to get deeper by bull heading @ 1 1/2 BPM , 410 psi. Could not get deeper than 8450'. 04:00 - 07:00 3.00 PRFADD N DPRB DECOMP POOH & LID perf guns. RID perf equip. 07:00 - 12:00 5.00 CLEAN N DPRB DECOMP PJSM. RIH w/2 7/8" EUE 8 rnd tubing, 424 jts total, tag @ 13,278' DPM. 57K up wt, 30K down wt. 12:00 - 14:30 2.50 CLEAN N DPRB DECOMP PJSM. Line up & reverse circulate @ 4 bpm 1750 psi. Pump 30 bbls leftover pill, chase wI 50 bbls brine, followed by another (30) bbls brine wI (1) bbl EP Mud Lube & chase wI 225 bbls brine. Slow rate down to 3 bpm 1450 psi to minimize losses. 93 bbls lost wI pumping. 14:30 - 17:30 3.00 CLEAN N DPRB DECOMP PJSM. Pump dry job & POOH w/2 7/8" tbg. 30 stands out, hole fill off, well giving fluid back. 17:30 - 19:00 1.50 CLEAN N DPRB DECOMP TIH with 2-7/8" EUE 8rd Tbg to top of perfs at 13,164' 19:00 - 00:00 5.00 CLEAN N DPRB DECOMP Wieght up pits to 11.1 ppg brine I Ciculate and wieght up hole to 11.1 ppg brine I Mix and spot 30 bbl EP mud lube at 9000' + 6/29/2005 00:00 - 00:30 0.50 CLEAN N DPRB DECOMP Circulating 11.1 ppg brine around from 13,164' and spotting 30 bbl EP mud lube at 9000' + Hole check, well is dead. 00:30 - 03:30 3.00 CLEAN N DPRB DECOMP POOH with 2-7/8" EUE 8rd Tbg racked back by stds. 03:30 - 04:30 1.00 PRFADD P DECOMP N/D Flow Nipple, N/U perf Flange 04:30 - 06:00 1.50 PRFADD P DECOMP PJSM I R/U Schlumberger wireline equipment 06:00 - 06:30 0.50 PRFADD P DECOMP Pre job safety meeting on running guns. Emphasis on unnecessary people staying clear of rig floor and pipe shed during arming & picking up I laying down of gun assembly. Well bore to be filled & shut in just prior to firing gun, so as to able to observe well for flow thereafter. 06:30 - 10:30 4.00 PRFADD N DFAL DECOMP Run in hole wI (20') 3 3/8",6 spf, powerjet gun assembl;y, including CCL I gamma, 41/4" rollers on top & bottom. Tie in & adjust depth. Fill hole, (7) bbls. With gun postioned to perforate fl 13,184' - 13,200', go thru fi ring sequence. No indication at surface that gun fired. Monitor well, well stable. POOH wI gun assembly, gun did not fire. Lay down & inspect..., dead short in compensating sub, remove same from tool string. P/U new gun assembly. 10:30 - 13:30 3.00 PRFADD P DECOMP RIH. Tie in wI correlation log. Fill hole, (8) bbls. Perforate fl 13,184' - 13,200'. Monitor well, well stable. POOH & LID gun assembly, ASF. 13:30 - 15:00 1.50 PRFADD P DECOMP PJSM. Rig down Schlumberger Eline. 15:00 - 16:00 1.00 RUNCOrvP RUNCMP PJSM. R/U ESP spooling unit & prep rig floor to run ESP completion. 16:00 - 18:00 2.00 RUNCOí RUNCMP PJSM. Pick up ESP assembly. Printed: 7/1/2005 9:50:45 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPF-80 MPF-80 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 6/29/2005 6/30/2005 From - To Hours . Task Code NPT Phase 18:00 - 23:30 5.50 RUNCOMP RUNCMP 23:30 - 00:00 0.50 RUNCOMP RUNCMP 00:00 - 02:30 2.50 RUNCOMP RUNCMP 02:30 - 06:00 3.50 RUNCOMP RUNCMP 06:00 - 08:00 2.00 RUNCOMP RUNCMP 08:00 - 09:00 1.00 RUNCOMP RUNCMP 09:00 - 10:00 1.00 BOPSUP P RUNCMP 10:00 - 11 :00 1.00 WHSUR P RUNCMP 11 :00 - 12:00 1.00 WHSUR P RUNCMP 12:00 - 16:00 4.00 WHSUR P RUNCMP Page 3 of3 Start: 6/25/2005 Rig Release: 6/30/2005 Rig Number: Spud Date: 10/28/1998 End: 6/30/2005 Description of Operations RIH ESP Completion checking conductivity each 2000' Change out spools to make cable splice Make cable splice Test connections TIH 2-7/8" EUE 8rd ESP completion check conductivity every 2000' PJSM. Pick up landing joint, M/U tubing hanger. Install penetrator & test, OK. 66K up wt, 40K down wt. Total of (3) flat guards, (6) protralizers, & (213) LaSalle clamps used. PJSM. Land hanger & run in lock down screws. Set two way check valve & test @ 3500 psi, OK. PJSM. NID 13 5/8" x 5M BOPE. PJSM. N/U & test tree & void @ 5000 psi, OK. Make final check on ESP, OK. PJSM. P/U lubricator & pull two way check vavle, set BPV. Secure well. PJSM. Remove manual valves on mud cross in preparation for rig move. Off load 11.1 ppg brine & transport to tank on MP D pad. Flush pits & tiger tank wI heated seawater. Rig released @ 16:00 hrs, 06/30/2005. Printed: 7/1/2005 9:50:45 AM Tree: CIW 2-9/16" 5M ). Wellhead: 11" x 11" 5M FMC Gen 5a 11" x 2-7/8" NSCT. 2.5" CIW-H BPV profile. 20" 91.1 ppf, H-40 112' I" Tight spot in 7" casing at 2063' 4-es had trouble getting desander past this point. KOP @ 400' Max. hole angle = 70 to 76 deg. f/ 5,950' to 10,700' Hole angle thru' perfs = deg. 95/8", 40 ppf, L-80 Btrc~ 5612' IJI 2-7/8", 6.5 ppf, L-80 EUE 8 rd ( drift ID =2.347", Cap. =.0058 bpf) 7" 29 ppf, L-80, Hydril1.563 casing, ( drift ID = 6.184", cap. = 0.0371 bpf ) Mid-perf TD = 6967 Mid-perf MD = 13182' PBTD MD = 13295' PBTD TVD = 7017' Stimulation Summary 12/29/98 'A' Sand refrac - 7200 # of AEA ChemFlow SI impregnated proppant and Perforation Summary Ref log: SWS POC 12-07-98 85.8 M# of 16/20 Carbolite behind casing. Kup. A-3 Sand Size SPF Interval (TVD) 2.5 3 13,164'-13,184' 6941' - 6959' 2.5 6 13,164'-13,184' 6941' - 6959' 3 3/8 6 13184' - 13200' 6977' - 6992' 12/08/98 - 2.5" SWS RDX UP big hole charges 12/25/98 - 2.5" SWS ROX 35B UP bighole charges 6/27/05 - 3 3/8" SWS HSD PJ 3406 MPU F-80 o Orig. IF Elev. = 43.25 (N 27E) Orig. GL Elev. = 10.80' OF To Csg. spool= (N 27E) , Camco 2~7/8" x1" KBMM Gas lift mandrel )HES 95/8" ES" Cementer i @J I 2098' Note: Had some trouble orienting in the top SPM. Possible need for replacement on the next RWO AVA Ported nipple w/ (isolation sleeve 1.87 10) MS~1 Pressure Head ·1 Centrilift Tandem ESP I 27GC2200 &122GC2200 GPMTAR 1:1 Centrilift gas separator I GRSFTXBARH6 Centrilift seal section I GSB3DBUT AB/HSN PFSA GSB3DBL T AB/HSN FSA CL5 Centrilift KMH Motor I 562 series, 209 hp, 2385 v, 53 a Phoenix MS-1 Sensor w/ 6 fin centralizer Sensor TVD - 6862' I 12,839' I 12,989' I 12,991' I 13,017' I 13,022' I 13,035' I 13,054' X Two 7" X 20' marker joints 12,962' - 13002' Last TO tag 13278' MO 6/28/05 with 4ES Baker 7" WLSRBP with overshot & 4.5" fn. 7" float collar (PBTO) 7" float shoe 13295' 13379' DATE REV. BY COMMENTS MILNE POINT UNIT 11/22/98 MDO Drill and Cased Nabors 27E 1/13/99 M. Linder Initial completion wi desander 4-ES WELL F-80 3/99 4/00 MDO / Linder ESP RWO 4-ES 00 due to corrosion API NO: 50-029-22928 1/21/03 MOO ESP RWO 4-ES 6/28/05 L Hulme Replace ESP / Add Perfs 4-ES BP EXPLORATION (AK) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 43.25' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 14. Location of well at surface 8. Well Number 1943' NSL, 3046' WEL, SEC. 06, T13N, R10E, UM X = 541517, Y = 6035393 MPF-80 At top of productive interval 9. Permit Number / Approval No. 198-217 620' SNL, 1926' WEL, SEC. 11, T13N, R09E, UM X = 532213, Y = 6032784 10. APl Number At effective depth 50-029-22928-00 652' SNL, 1975' WEL, SEC. 11, T13N, R09E, UM X = 532163, Y = 6032751 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 678' SNL, 2017' WEL, SEC. 11, T13N, R09E, UM X = 532121, Y = 6032725 Sands 12. Present well condition summary Total depth: measured 13408 feet Plugs (measured) true vertical 7179 feet Effective depth: measured 13295 feet Junk (measured) Baker 7" WLSRBP with overshot & 4-1/2" retrieving tool true vertical 7077 feet at 13257' (WLM 3/99) Casing Length Size Cemented MD TVD Structural Conductor 120' 20" 250 sx Arcticset I (Approx.) 120' 120' Surface 5577' 9-5/8" 550 sx PF E, 140 sx G, 1268 sx PF E, 175 5612' 3861' Intermediate Production 13346' 7" 340 sx Class 'G' 13379' 7152' Liner Perforation depth: measured 13164' - 13184' true vertical 6960' - 6977' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 13058' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 664 152 876 Subsequent to operation: 747 166 1290 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the fo~l:egoing is true and correct to the best of my ..l~n. owledge Si~ned s~ ~ Title Technical Assistant Date Prepare~l By Name/Number:. Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 FEB 2 z~ ~ ~ Submit In Duplicate BP EXPLO~TtON Page 1 of 2 Operations Summary =Report Legal Well Name: MPF-80 Common Well Name: MPF-80 Spud Date: 10/28/1998 Event Name: WORKOVER Start: 1/17/2003 End: 1/21/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/21/2003 Rig Name: NABORS 4ES Rig Number: :Date From - To Hours Task Code NPT phase ~eScr pt[On of Operations 1/17/2003 09:00 - 18:00 9.00 RIGU P PRE RD, SCOPE AND LD DERRICK. MOVE SHOP, PIPE SHED, SUB BASE, MUD PITS, CAMP AND SPOT SAME ON MPF-80. 18:00 - 21:30 3.50 RIGU P PRE ACCEPT RIG AT 1800 JM. RECEIVE 625 BBLS 10 4 BRINE. RAISE AND SCOPE DERRICK. RU TO TREE TO KILL WELL. 21.30 - 22:00 0.50 RIGU P PRE PU LUB AND PULL BPV 22:00 - 23:00 1.00 RIGU P PRE RU TO TIGER TANK, TEST KILL LINES 23:00 - 23:30 0.50 RIGU P PRE PRE SPUD MEETING WITH BAROID, NAD AND BP. 23:30 - 00:00 0.50 KILL P DECOMP START WELL KILL DOWN TBG WITH RETURNS TO TIGER TANK. PUMP TBG VOL 80 BBLS 10.4 BRINE AT 4 BPM-1450 PSI. 1/18/2003 00:00 - 03:00 3.00 KILL P DECOMP CeNT W / WELL KILL. CLOSE CHOKE, BH 15 BBLS INTO FORM. OPEN CHOKE CeNT CIRC 10.4 BRINE AT 4 BPM/1450 PSI UNTIL 10.3 BRINE AT SURFACE AND CLEANED UP. 03:00 - 03:30 0.50 KILL P DECOMP MONITOR WELL, WELL FLOWED 8 BBLS OUT IA, TBG ON VAC. 03:30 - 04:30 1.00 KILL P DECOMP ClRC 80 BBLS DOWN TBG AT 4 BPM/1500 PSI 04:30 - 05:00 0.50 KILL P DECOMP MONITOR WELL, WELL FLOWING OUT TBG. BH 10 BBLS INTO FORM 4 BPM/1450 PSI. 05:00 - 06.00 1.00 KILL P DECOMP SI WELL, MONITOR, SlTP 210 = 11 PPG FOR BALANCE(~4000 BHP). PREP TO INC BRINE FROM 10.4 PPG TO 11.0 PPG 06:00 - 12:30 6 50 KILL P DECOMP CeNT ClRC / WT UP BRINE UNTIL 10.7 PPG RETURNS. 12:30 - 13:00 0.50 KILL P DECOMP MONITOR WELL - TBG & IA 80 PSI 13:00-16:00 3.00 KILL P DECOMP ClRC/WTUPUNTILL11.0PPGRETURNS 16:00 - 16:30 0.50 i KILL P DECOMP MONITOR WELL, SLIGHT VAC ON TBG 16:30-17:00 0.50~WHSUR P DECOMP SET AND TEST TWC 17:00-18:00 1.00IWHSUR P DECOMP NDTREE 18:00-20:30 2.50 WHSUR P DECOMP NU BOPE 20:30 - 22:00 1.50 BOPSUF P DECOMP TEST BOPE TO BP / AOGCC PROCEDURES 250 / 3500 PSI GOOD TEST. AOGCC INSP, Leu GRtMALDI WAIVED WITNESS OF TEST. 22:00 - 22:30 0 50 BOPSUFP DECOMP PULL TWC 22:30 - 23:30 1.00 PULL P DECOMP PRE SPUD MEETING, NAD, BAKER, BP. MU 2 7/8" SPEAR, STING INTO HGR, BOLDS. 23:30 - 00:00 0.50 PULL P DECOMP PULL HGR - HGR FREE AT 95 K UP WT. - STRING PU WT 75 K, LD STINGER. 1/19/2003 00:00 - 06.00 6.00 PULL P DECOMP POH WITH TBG AND ESP ASSY 06:00 - 07:30 1.50 PULL P DECOMP CREW CHANGE - PJSM - CeNT TOH W / 2 7/8'TBG / ESP ASSY. 07:30 - 09:30 2.00 PULL P DECOMP TEST ESP CABLE-BAD-CHANGE REELS. 09:30 - 13:30 4.00 PULL P DECOMP CeNT TOH, LD CORRODED TBG TO ESP ASSY. 13:30 - 15:00 1 50 PULL P DECOMP INSP AND LD ESP ASSY. - LOST 1 FLAT GUARD IN HOLE. 15:00 - 16:00 1.00 PULL P DECOMP CLEAR AND CLEAN RIG FLOOR. 16:00 - 17:00 1.00 PULL N DECOMP RU TO RUN TBG. MU 6" BIT FOR DRIFT RUN TO LOCATE FLAT GUARD IN HOLE. 17:00-18'00 1.00 PULL N DECOMP RIHW/6"BITAND27/8"TBG 18:00-2300 5.00 PULL IN iDECOMP CREWCHANGE-PJSM-CONTRIHW/ BITANDTBG. PUW AT 13100' 63 K - SOW 35 K.- SOLID TAG AT 13288' DPM NO OBSTRUCTIONS ENCOUNTERED ON TIH. 2300-00'00 1.00 PULL N DECOMP POH/LDEXTRAJTS(12) USED FOR TAG, STAND27/8" TBG BACK. SCANNED VIARQ 2003 Pnnted 1/27/2003 9 54 26 AM BP EXPLORATION Page 2 of 2 0peratlon Su:mma Repo Legal Well Name: MPF-80 Common Well Name: MPF-80 Spud Date: 10/28/1998 Event Name: WORKOVER Start: 1/17/2003 End: 1/21/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/21/2003 Rig Name: NABORS 4ES Rig Number: Date From - To Hours, Task Code NPT Phase Description of Operations 1/20/2003 00:00 - 01:30 1.50 PULL N DECOMP POH WITH BIT, STAND BACK TBG. 01:30-02:30 1.00 PULL P DECOMP SLIP / CUT102' DRLG LINE 02:30 - 06:00 3.50 PULL P DECOMP POH WITH BIT, STAND BACK TBG 06:00 - 07:00 1.00 PULL P DECOMP CREW CHANGE, CONT POH W / BIT. 07:00 - 07:30 0.50 PULL P DECOMP CLEAR / CLEAN FLOOR, RU TO RUN ESP ASSY. 07:30 - 08:00 0.50 PULL P DECOMP PJSM - W / NAD, BAKER, BP. OBSERVED WELL FLOWING. 08:00 - 16'30 8 50 KILL N COMP BH 37 BBLS 11.0 NaBr-1.5 BPM/700 PSI. MONITOR, OBSERVED 7 BPH FLOW BACK. BH 20 BBLS 11.0 NaBr-2 BPM/900 PSI. MONITOR, OBSERVED 3 BPH FLOW BACK. MONITOR AND ORDER 11.6 NaBr. 16:30 - 18:00 1 50 KILL N COMP BH 50 BBLS 11.6 NaBr 1.5 BPM/900 PSI SI WELL, MONITOR 18'00 - 19'00 1.00 KILL N COMP SICP 140. - 15 MIN 110 PSI - 30 MIN 50 PSI - 45 MIN 10 PSI - 60 MIN 0PSI. 19:00 - 21:00 2.00 KILL N COMP OPEN WELL, FLUID AT SURFACE - FLUID LEVELS 15 MIN ~1' DOWN - 30 MIN ~1.5' DOWN - 45 MIN ~2' DOWN - 60 MIN ~ 2.5' DOWN MU CABLE TO PUMP AND SECURE FLUID LEVEL 120 MIN 15' DOWN. 21:00-22:30 1.50 RUNCOI~P COMP RIH W/ESPASSY+ I JT 2 7/8"TBG, INSTALLAVA SLEAVE (IN OPEN POSITION) LD 2 JTS BAD TBG, PU 2 JTS NEW 'FBG, 22.30 - 00:00 1.50 RUNCOI~ P COMP RIH WITH ESP/TBG ASSY 1/21/2003 00'00 - 03:30 3.50 RUNCOI~ P COMP CONT RIH WITH 2 7/8" TBG / ESP COMPLETION 03:30 - 06:00 2.50 RUNCOI~ P COMP MAKE REEL TO REEL SPLICE PUMP 15 BBLS OF 11.6 BRINE DOWN TBG. 06:00 - 10:00 4.00 RUNCOI~F' COMP CREW CHANGE. PJSM. CONTINUE TIH WITH ESP ASSY AND 2 7~8" TBG. 10:00 - 11:00 1.00 WHSUR P COMP PU LANDING JT AND MU TBG HANGER. INST PENETRATORS. 11:00 - 12:30 1.50 RUNCOI~ ~ COMP MAKE EFT SPLICE. SECURE TO PENETRATOR. TEST. GOOD. 12:30-13:00 0.50 RUNCOI~P COMP LAND TBG HANGER. PUW=76K. SOW=37K. RILDS. 13:00- 13:30 0.50 RUNCOI~ COMP SETTWC. DRAIN BOP. 13:30 - 15:00 1.50 BOPSUF P COMP ND BOPE 15:00 - 16:00 1.00 WHSUR P COMP NU PRODUCTION TREE 16:00 - 17:00 1.00 WHSUR P COMP TEST ADAPTOR FLANGE AND TREE TO 5,000 PSI...GOOD. FINAL ESP CABLE TEST...GOOD....CLEAN PITS. 17:00 - 17:30 0.50 WHSUR P COMP PU LUBRICATOR AND PULLTWC. SET BPV. LD LUBRICATOR. 17:30 - 18:00 0.50 RIGD P COMP BLOW DOWN LINES. RD LINES. SECURE CELLAR. RELEASED RIG AT 1800 HRS..LMH. Printed 1/27/2003 9 54 26 AM i'98,2i7_0 MILNE pT UNIT KR F~80 502 029_22928~00 'BP'~i~6RAT~0N Roll #1: Start: Stop Roll #2: Start Stop (ALASKA) INC MD 13408 TVD 07179 Completion Date: 1/13/99 Completed Status: 1-OIL Current: T Name Interval '/L ADN-MD FINAL 9300-13400 ~,~ .//L ADN-TVD FINAL 4900-7100 ~L CDR-TVD FINAL 140-7100 / .//L CDR-T~'F) FINAL 140-13400 ~,~ jL DEPTH FINAL 5000-13303 d, · /'L STATTEM/PRES FINAL 13164-13303 v/ R CALIPERSRVY PDS 0-12842 ~,/ R GYRO MULTISHOT GYRODATA TBNG 0-12300 SRVY RPT 8966 SCHLUM 112-13408.22 SCHLUM CDR/ADN Sent Received T/C/D OH OH OH OH CH CH CH OH OH OH 1/28/99 2/4/99 1/28/99 2/4/99 1/28/99 2/4/99 1/28/99 2/4/99 12/17/98 1/5/99 12/17/98 1/5/99 4/25/00 4/25/00 2/7/99 2/8/99 3/2/99 3/2/99 1/28/99 2/4/99 Thursday, January 25, 2001 Page 1 of 1 ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution- Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returnincj a signed cop'~, of thi~ ,. _'- ...... ;~tal letter to the attention of · Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration(Alaska), Inc. Petro-Technical Data Center MB 3-2. 900 East Benson Blvd. Anchorage, Alaska 99508 LoG DIGITAL MYLAR / BLUE LINE i REPORT WELL OATE TYPE OR SEPIA PRIN,loII OR CD-ROM F~LM ~ BLUEL~NE , · , (,~aliper i~ ¢ RECEIVED Print Name: Alaska Oil & Gas Co,~s. ~ ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99"34 Phone:(907)659-2307 Fax:(907)63~-2314 E-maih pdsprudhoc~NAS00.net Wcbsitc: www.mcmoD'log.com Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No.: Run No.: Pipe Desc.: Pipe Use: BP Exploration (Alaska) Inc. April 7, 2000 4047 1 2 7/8" 6.5~ L-80 EUE 8rd Tubing Well: F-80 Field: Milne Pt. Unit State: Alaska APl No.: 50-029-22928-00 Top Log Intvl: Surface Bot. Log Intvl: 12,842 Ft. (MD) Inspection Type' Corrosive Damage Inspection COMMENTS · This survey was run to assess the condition of the tubing with respect to corrosive damages. The caliper recordings indicate that the tubing ranges from good to poor condition with respect to corrosive damage. Most of the tubing appears in good condition, with maximum joint penetrations falling between 10% and 20% wall thickness. However, a deep line of corrosion is recorded between Joints 21 and 55, with 30 joints recording penetrations in excess of 50% wall thickness. The deepest penetration recorded in this interval is a possible hole located in Joint 52 @ 1,637', and measures 91% wall thickness. No areas of substantial cross-sectional wall loss are recorded, with the most severe measuring 15% in Joint 74. Light deposits are recorded scattered throughout the logging interval, with the most significant accumulations reducing the minimum measured ID to 2.24". MAXIMUM RECORDED WALL PENETRATIONS · Possible Hole (91%) Jt. 52 @ 1,637' MD Line Corrosion (86%) Jt. 32 @ 1,029' MD Line Corrosion (86%) Jt. 47 @ 1,487' MD Line Corrosion (84%) Jt. 50 @ 1,575' MD Line Corrosion (83%) Jt. 38 @ 1,190' MD MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' No areas of substantial cross-sectional wall loss (>15%) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS ' No significant restrictions are recorded throughout the interval logged. RECEIVED APR 25 000 Alaska 0il & Gas Cons. Commission Anchorage Field Engineer' R. Richey Analyst: S. Adcock Witness: M. O'Malley ProActive ~.)ld.(.Jlq, ObtfC .... qarn. .,ta~,_,rL,, i;,t 77497 Pl'~one: (281) or ~_~o2 .~o5-9085 Fax: (28~) 565-~369 Em-~ai!:Pu~m~mor~~ -- ~ ,~lug,com Prudhoe 8ay Field Office_,, _~ Phone: {907) o~-z..,~,~ '~r'~ F~.., .... (907) 659-23~ Well: FGO Field: MILNE PT. UNIT Company: BP EXPLORATION ALASKA Country: USA PDS Caliper Overview Body Region Analysis Survey Date: April 07, 2000 Tool Type: MFC24 No.99628 Tool Size: 1 11/16" ins No. of Fingers: 24 Analysed: Steve Adcock Tubing: Size Weight Grade & Thread Nora. OD Nom3D Nora. Upset 2.875 ins 6.5 ppf EUE 8RD 2.875 ins 2.441 ins 3.063 ins Penetration and Metal Loss (% wall) ~%~ penetration body ~>:~4 metal loss body 200 ~ 100~ ~ 0to 1 to 10to 20~o ~to above 1% 10% 20% ~% 85% 85% Namber of joinu a~ah,sed (total = 414} Pene 9 28 297 47 30 3 Loss 56 330 28 0 0 0 Dan~ge Configu~fion ( body ) N umber of joints damased ttotaJ = 247) 103 17 126 0 1 Damage Profile (% wall) penetration body ~!~ metal toss body 0 50 GLM 1 97 197 297 397 Bottom of Survey = 411 100 RECEIVED Analysis Overview page 2 APR 25 2000 Abska Oi~ & ~}as Cons, Csmmissior~ Anchorage We[k F~80 Fie[d: M[LNE PT, UNIT Company: BP EXPLORATION ALASKA Country: USA PDS Caliper Overview Upset Region Analysis Survey Date: April 07, 2000 Tool Type: MFC24 No.99628 Tool Size: 1 11/16" ins No. of Fingers: 24 Analysed: Steve Adcock Tubing: Size Weight Grade & Thread Nom. OD NomJD Nora. Upset 2~875 ins &5 ppf EUE 8RD 2.875 ins 2~44~ ins 3.063 ins Penetration and Metal Loss (% wall) ~ penetration upset 5O0 300 ~ 200 ~ 100 ~ 0 0to 1to 10to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 414) Pene 396 3 2 9 4 0 Damage Configuration ( upset 10 N umber of joints damaged {total = 1 7 8 0 0 Damage Profile (% wall) penetration upset 0 50 100 97 197 297 397 GLM 1 Bottom of Survey = 411 Analysis Overview page 3 RECEIVED PDS JOINT TABULATION SH[ Pipe:2.875 ins 6.5 ppf EUE 8RD Wall thickness. Body: 0.217ins Upset: 0.311 ins Nominal iD: 2.441 ins Penetration Well: Field: Company: Count~,: Date: F-80 MILNE PT. UNIT BP EXPLORATION ALASKA USA April 07, 2000 Minimum ID inches 2.38 PUP 2.38 Line corrosion. 2.37 Line corrosion. 2.36 Line shallow corrosion, 2.36 2.37 2.37 2.35 2.37 2.37 PUP Shallow pitting GLM #1 {No High Side) PUP Shallow pitting. Line shallow corrosion. 2.37 2.37 Line shallow corrosion, 2.37 2.37 2.37 2.36 2.36 2.37 2.36 2.37 Shallow pitting, Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Lt. Deposits. Line shallow corrosion. Shallow pitting, Isolated pitting. Lt. Deposits. Isolated pitting. Line shallow corrosion. Lt. Deposits. Line corrosion. 2.37 Line shallow corrosion. 2.35 Line corrosion. 2.36 2.36 2.35 2.36 Line shallow corrosion. Lt. Deposits. Liue shallow corrosion. Lt Deposits. 2.37 2.37 Line corrosion. 2.36 Shallow pitting. Line corrosion. Lt. Deposits. Line corrosion. 2.36 2.36 Line corrosion, 2.37 2.37 Corrosion. LL Deposits. Line corrosion. Line corrosion. LL Deposits. Line corrosion. 2.37 Line corrosion. 2.37 Line corrosion. 2.37 Possible HOLE. 2.36 2.37 2.37 Line corrosion. 2.37 2.36 2.36 2,37 2.37 2.37 2.36 2.36 Line corrosion. Lt. Deposits. Corrosion. Line corrosion. Lt. Deposits. Line corrosion, Line corrosion. Lt. Deposits. Line corrosion. Line corrosion. Lt. Deposits. Line corrosion. 2.38 2.37 Line corrosion. 2.38 Line corrosion, Line corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Corrosion. penetration body metal toss body Damage profile %wal) 50 100 Pipe Tabulations page I RLL , 25 2000 PDS JOINT TABULATION SHI Pipe: 2.875 ins 6.5 ppf EUE 8RD Well: 7430 Wallthickness. Body: 0.217ins Upset= 0.311ios Field: MILNE PT. UNIT Nominal ID: 2.441 ins Company: BP EXPLORATION ALASKA Country: USA Date: April 07, 2000 ~tt/penetration body ~:i:: metal loss body Joint Penetration Metal Projection Minimum Damage profile NO. Upset Bcd' Loss Upset Body lO Comments /%wall) inches inches % % inches inches inches 0 50 10 47 0 .19 86 12 0 .04 2.37 Possible HOLE~ ts 48 .06 .t7 78 9 .02 ,04 2.37 Line corrosion. 49 ] 0 .16 75 14 0 .04 2.37 Line corrosion. 50[ 0 .t8 84 14 0 .04 2.38 Line corrosion. Lt. Deposits, 51 0 .14 65 12 0 .04 2.36 Line corrosion, ts 52 0 .20 91 13 0 .04--2.37 PROBABLE HOLE. ~ tsts ts~ 53 0 .16 72 8 0 .05 2.37 Line corrosion, ts ts / 54 0 .14 65 7 0 .05 2.37 Line corrosion. Lt. Deposits. 55 0 .09 44 9 0 .05 2.35 Corrosion, ~ ts 56 0 .06 29 8 0 .04 2.37 Line corrosion, ts 57 0 .08 36 11 0 ,04 2.38 Line corrosion. 58 0 .06 28 11 0 .04 2.36 Line corrosion. Lt.D~. ts 59 0 .05 22 8_ 0 .04 2.36 Line corrosion, ts 60 .05 .05 23 7 0 .04 2.37 Line corrosion. 6~1 0 .05 24 6 0 .05 2.37 Line corrosion. Lt. Deposits. __ 62 0 ,06 26 8 0 .04 2.38 Line corrosion= ts 63 0 .05 24 6 0 .04 2.37 Line c~orrosion, ts 64 0 .05 25 9 0 .04 2.38 Line corrosion. 65 0 ,06 27 8 0 .04 2.37 Line corrosion, ts ~66 0 .06 26 9 0 .0q 2.37 Line corrosion. ~,~ 67 0 .06 29 11 0 .04 2.37 Corrosion. 68 ,08 _07 33 11 0 .05 2.36 Line corrosioo. Lt. Deposits. 69 0 .06 28 12 0 .04 2.37 Line corrosion. 70 0 .06 28 12 0 .04 2.37 Line corrosion. 71 0 .06 27 8 0 .05 2.37~ Line corrosion. Lt. Deposits, 72 O~ .07 34 13 0 .04.04 2'38 Corrosion. .04 2.37 Line corrosion. 73 0 __ .06 29 13 0 .04 2.37 Line corrosion. 7~4 0 .07 34 15 0 75 0 .06 26 9 0 2.37 Line corrosion. LL Deposits. 76 0 .06 27 7 0 ,04 2~3~ Line corrosion, ts 77 0 .04 20 7 0 .04 2.38 Line corrosion. 78 0 .04 20 7 0 .05 2.36 Line corrosion. LL Depos~ls. ts 79 0 .05 22 4 0 .05 2.36 Line corrosion, ts 80 0 .03 15 4 0 .04 2.36 Shallow pitting. 81 0 .03 16 4 0 .05 2.35 Line shallow corrosion. 82 0 .04 20 7 0 .05; 2.36 Isolated pitting. Lt. Deposits, ts 83 0 .04 18 6 0 .05 2.36 Line shallow corrosion, ts 84 _ 0 .03 16 6 0 .05 2.36 Line shallow corrosion. 85 0 ~03 13 2 0 ,05 2.36 86 0 .04 18 5 0 .05 2.35 Shallow pitting. Lt. Deposits. 87 0 .04 19 7 0~ .04 2.36 Line shallow corrosion, ts 88 0 .03 14 5 0 .04 2.36 Lt. Deposits. 89 O~ .04 19 7 0 .05 2.36 Line shallow corrosion. 90 0 .02 1 3 0 .04 2,36 91 0 .03 13 4 0 .05 2.35 9~2 0 .03 15 3 0 .05 2,35 Line shallow corrosion. LL Deposits. 93 0 .03 15 4 0 ~05 2.36 Shallow pitting. 94 0 .03 13 3 0 .04 2.37 95 0 .03 13 3 0 .0~5 2.36 96 j 0 .03 12 4 0 ,05 2.35 Lt. Deposits. __ Pipe Tabulations page 2 RECEIVED PDS JOINT TABULATION SH Pipe: 2.875 ins 6.5 ppf EUE 8RD Well: F4~0 Wallthickness. Body:0.217ins Upset=0.311ins Field: MILNEPT. UNIT Nominal ID: 2.441 ins Company: BP EXPLORATION ALASKA Country: USA Date: April 07, 2000 penetration body metal loss body Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset 3ody ID Comments (% wall) inches inches % % inches inches inches 50 1C 97 0 .03 13 3 0 .05 2.35 98 0 .03 15 3 0 .05 2.36 Shallow pitting. LL Deposits. 99 0 .03 15 5 0 .05 2.35 Line shallow corrosion. 100 0 ~03 13 2 0 .05 2,36 Lt. Deposits. 1 O1 0 _04 17 4 0 .0~5 2.3~5 Shallow pitting. t02 0 .03 13 3 0 .05 2.36 103 0 .04 18 4 0 .05 2.35 Line shallow corrosion. Lt, Deposits. 104 0 .04 18 6 0 .04 2.36 Shallow pitting. 105 0 .03 t 3 3 0 .05 2.35 106 0 ,03 14 5 0 .05 236 107 0 .03 14 3 0 .06 2.34 Shallow pitting. Lt. Deposits. 108 0 .02 1 2 0 .06 2.34 109~ 0 .03 15 4 0 .05 2.35 Shallow pitting. Lt. Deposits. 110 0 .03 13 4 0 .05 2.34 111 0 .01 3 2 0 .05 2.34 Lt, Deposits. __ 112 0 .03 13 3 0 ~05 2.34 113 0 .03 1t5 5 0 .06 2.35 Shallow pitting. 114 0 .02 1 ~ 1 .05 .06 2.34 115 0 .03 13 2 0 .04 2.36 LL De~its. 116 0 .02 1C 3 0 .05 2.35 117 0 .02 1 3 .05 .06 2.34 118 0 .03 12 3 0 .05 2.35 Lt_ Depos_its. 119 0 .03 13 3 0 .05 2.34 ~ 20 0 .03 12 3 ~ .06 2.34 121 0 .03 14 4 0 .05 2.35 LL Deposits. t 22 0 .03 12 5 0 .05 2.35 LL Deposits 123 0 ,03 12 2 0 .05 2.35 -~ 124 0 ,03 12 2 0 .05 2.34 Lt. Deposits 125 0 .03 12 3 0 .05 2.35 126 0 .03 12 2 0 .05 2.35 Lt. De~29_sits. 127 0 .03 12 3 0 ~05 2.34 128 0 .02 11 1 0 .05 2.35 Lt. Deposits, 129 0 .03 ~5 5 ~- .06 2.33 Shallow pitting. 130 0 0 1 0 .05 2.35 Lt. De~2~ts. 131 0 .02 1C 1 0 .05 2.35 132 0 .02 11 I 0 ,06 2.34 133 0 .01 1 0 .06 2.34 Lt. Deposits. 134 0 0 1 .05 ,06 2.33 135 0 0 1 .06 .06 2.32 136 0 .02 11 3 .05 .07 2.31 Lt. Deposits. 137 0 .02 1£ 3 .06 .06 2.33 ~'~ 138 0 0 1 .05 .08 2.30 t39 0 ,0~3 1_~ 1 .06 .07 2.32 [ Shallow pitting. LL Deposiis. 140 0 .04 1 [ 3 .07 .07 2.31 Line shallow corrosion. 141 0 .02 11 1 .06 .07 2.31 Lt. Deposits. ~:~ 142 0 .03 1 z 2 .05 .06 2,32 143 0 .03 12 2 .06 .07 2.32 144 0 .03 lZ 2 .05 .06 2.34 145 000 1 0 .06 2.33 Lt. Deposits. 146 0 104 1[ 3 .05 .06 2.33 L ne shallow corros on. Pipe Tabulations page 3 RECEIVED A~aska Oil & Gas Cons, Oommissio~ PDS CAi OINT TABULATION SHI Pipe: 2.875 ins 6.5 ppf EUE8RD Wall thickness. Body: 0.217ins Upset = 0311 ins Nominal ID: Z441 ins Penetration Well: Field: Company: Countw: Date: Minimum ID Commen~s inches 2.31 2.30 2.31 2.31 2.29 2.31 2.30 2.32 2.32 2.32 2.31 2.29 2.31 2.31 2.30 2.31 2.30 2.32 2.31 2.29 2.30 2.28 2.29 2.31 2.31 2_34 2.32 2.34 233 2.31 2.31 2.29 2.29 2.32 2.32 2.32 2.31 2.32 2.31 2.16 2.33 2.34 2.32 2.33 2.29 2.29 2.30 2.28 2.32 2.31 F~80 MILNE PT. UNIT BP EXPLORATION ALASKA USA April 07, 2000 penetration body metal loss body Damage profile (% wall) 50 1 O0 Pipe Tabu[ations page 4 RECEIVED Alask~ Oil & Gas Cons~ A~ra~a PDS CAi JOINT TABULATION Pipe: 2.875 ins 6.5 ppf EUE8RD Wailthickness. Body:0.217ins Upset: 0.311ins Nominal ID: 2.441 ins Well: Field: Company: Country: Date: F-80 MILNE PT. UNIT BP EXPLORATION ALASKA USA April 07, 2000 penetration body metal loss body Minimum tD Comments inches 2.33 2.31 Lt. Deposits. 2.31 2,30 2.29 2.30 2.29 2.33 2.29 2.26 2.27 2.31 2.28 2.27 2.32 2.28 2.28 2.30 2.27 2.30 2.29 2.29 2.29 2.31 2.30 2.30 2.29 Shallow corrosion. Lt. Deposits. Line shallow corrosion. Lt Deposits. Shallow pitting. Shallow pitting. Lt. Deposits. Shallow pitting. Shallow pitting. Lt. Deposits. LL Deposits Shallow ittin . Line shallow corrosion. Lt. Deposits. Shallow pitting. Lt. Deposits. Lt Deposits. Shallow pitting. Lt Deposits. Line shallow corrosion. 2.29 2.29 2.32 2.32 2.29 2.32 2.32 2.31 2.32 2.29 2.29 2.29 Shallow pitting. Lt. Deposits. Shallow pitting. Lt. Deposits. Shallow pitting. Shallow pitting. Lt, Deposits. Shallow pitting. Shallow pitting. Lt. Deposits. Corrosion, 2.31 Line shallow corrosion. 2.31 Corrosion. Lt. Deposits. Line corrosion, 2.29 2.30 Line corrosion. 2.29 Line shallow corrosion. Lt. Deposits. 2.28 2~34 2.33 Line shallow corrosion. Lt. Deposits. 2.34 Shallow pitting. 2.32 2.31 Lt. Deposits. Pipe Tabulations page 5 Damage profile (% wall) 50 RECEIVED Jk?R 2000 Alaska Oi~ & C, as Co~s. tamm~ior, 100 PDS JOINT TABULATION SH[ Pipe: 2.875 ins 6.5 ppf EUE8RD Wall thickness. Body: 0.217ins Upset = 0.311 ins Nominal ID: 2.441 ins Well: F-80 Field: MILNE PT. UNIT Company: BP EXPLORATION ALASKA ~&~ penetration body Counti'y: USA ~Z;~ metal loss body Date: April 07, 2000 toint Penetration Metal Projection Minimum l Damage profile No. Upset Body Loss Upset Body ID Comments inches inches % % inches inches inches [0 50 247 0 .04 20 5 .06 .07 2.32 Line corrosion. i 248 0 .03 15 3 .07 .1 t 2.29 Shallow pitting. ! 249 0 .03 13 3 .06 .07 2.30 Lt. Deposits. 250 0 .01 $ 1 .08 .08 2.28 25t 0 .02 10 2 .05 .07 2.3t 252 0 .03 16 3 .07 .07 2.30 Shallow pitting. Lt. Deposits. 253 0 .03 16 2 .05 .06 2.33 Shallow pitting. 254 0 .02 11 3 0 .06 2.33 255 0 .03 12 3 0 .07 2.31 Lt. Deposits. 256 0 .02 11 3 .06 .07 2.31 257 0 .00 1 .05 .07 2.30 258 0~ .04 20 4 .07 .08 2.29 Shallow corrosion. Lt. Deposits. 259 0 .00 (3 1 .08 .08 2.29 260 0 0 C I 0 .06 2.33 261 0 .03 14 4 .05 .06 2.33 Lt. Deposits, 262 0 .04 17 6 .20 .06 2.33 Shallow pitting 263 0 .04 18 3 0 .06 2.33 Shallow pitting. 264 0 .04 17 3 ,05 i .07 2.30 Shallow pitting, 265 0 .02 1 2 .061 .07 2.30 Lt. Deposits. 266 0 .04 19 4 ,07 [ .08 2.30 Shallow pitting. 267 0 .03 14 4 .06 i .07 2.32 268 0 .03 16 4 .05 .07 2.30 Shallow pitting. LL Deposits. 269 0 .04 18 2 .07 .08 2.3t Shallow corrosion. 270 0 .03 12 2 0 .07 2.31 27t 0 .02 1(3 3 .06 .07 2.32 272 0 .02 1(3 1 .05 .07 2.31 Lt. Deposits. 273 0 .02 1(3 2 ,05 .07 2,31 274 0 .03 15 2 .05 .15 2.30 Shallow pitting. Deposits. 275 0 .03 12 1 0 .06 2]2 276 0 .02 1 2 .05 .06 2.32 Lt. Deposits. 277 0 .04 1~ 2 .06 .06 2.34 Shallow ~ 278 0 .02 1C 1 .07 .07 2.30 279 0 .03 14 2 ,06 .07 2.32 280 0 .02 11 2 .05 .07 2.31 Lt. Deposits. 281 0 .03 12 1 .06 .O6 2.32 282 0 .03 12 3 .05 .07 2.32 283 0 .04 1 ~ 5 .06 .07 2.31 Shallow pitting. Lt. Deposits. 284 0 .03 1~ 4 0 .06 2.34 Shallow pit~ng. 285 0 .03 12 2 0 .06 2.33 286 0 .02 1 t 3 .05 .07 2.32 Lt. Deposits. 287 0 .03 t ~ 1 .05 .06 2.32 288 0 .02 11 1 .05 .08 2.30 289 0 .02 1 .07 .08 2.29 Lt. Deposits. 290 0 .03 15 2 0 .05 2.34 Shallow pitting. 291 0 .03 12 1 0 ,05 2.34 292 0 .03 1-= 2 .07 .08 2.29 1 Lt. Deposits. 293 0 .03 12 2 .07 .08 2.29 294 0 .03 1~ 2 .05 .08 2.29 Shallow pitting, 295 0 ,03 [ 1_~ 3 .07 ~08 2.30 Shallow pit~n,~ Lt. Deposits. 296 0 .03 1Sj 2 .07 .08 2.31 Shallow p tting. Pipe Tabulations page 6 RECEIVED Atask~ Oil & Gas Cons. Armhm'age PDS CAI JOINT TABULATION SH Pipe: 2.875 ins 6.5 ppf EUE 8RD Wall thickness. Body: 0.217ins Upset = 0.311 ins Nominal iD: 2.441 ins Well: Field: Company: Country: Date: F~80 MILNE PT. UNIT BP EXPLORATION ALASKA USA April 07, 2000 Minimum ID inches 2.32 2.33 2.31 Shallow pitting, Lt. Deposits. 2.31 Line shallow corrosion. Lt Deposits. 2.30 2.31 2,30 2.31 2.32 2.31 2.30 2.33 2.33 2.31 2,32 2.32 2.31 Shallow pit~in~ Shallow pitting. Shallow pitting, Lt. Deposits. Lt, Deposits. Shallow pitting. Lt. Deposits. Line shallow corrosion. Shallow pitting. Deposits. Deposits. 2.31 Line shallow corrosion. 2.31 2.32 2.31 2.33 2.32 2.32 2.31 2.29 2.30 2.31 2.31 2.31 2.29 2.29 2.32 2.31 2.32 2.34 2.34 2.30 2.30 2.3t 2.32 2.30 2.32 2.28 t. Deposits. LL Deposits, Lt_ Deposits. Shallow pitting. LL Deposits. Shallow pitting, Deposits. Lt_ Deposits. Shallow pitting. Lt. Deposits. Shallow pitting. Line shallow corrosion. Lt. Deposits. Shallow pitting. Shallow pitting, Lt Deposits. 2.27 Line shallow corrosion, 2.27 2.27 2.26 2.27 2.28 Shallow pitting, Shallow pitting. Lt. Deposits. Shallow pitting. Shallow pitting. Lt. Deposits. penetration body metal toss body Damage profile %wa ) 50 1 O0 Pipe Tabulations page 7 RECEIVED APR 25 200© Alaska Oil & Gas Cz}ns. Cmmmi~mio~ PDS OINT TABULATION SHi Pipe: 2.875 ins 6~5 ppf EUE 8RD Well: F-80 Wall thickness. Body: 0.217ins Upset = 0.311 ins Field: MtLNE PT. UNIT Nominal ID: 2.441 ins Company: BP EXPLORATION ALASKA ~i penetration body Country: USA ~zts~/metal loss body Date: April 07, 2000 Joint Penetration Metal Projection Minimum Damage profile No. Upset Body Loss Upset 3ody ID Comments (% wall) inches inches % % inches inches inches 50 10~ 347 0 .03 13 2 .08 .09 2.28 348 0 .04 2C 5 .08 .09 2.28 Corrosion. ts 349 0 .04 19 5 .07 .08 2.30 Line shallow corrosion. Lt. Deposits. ts 350 0 .04 18 6 .05 .07 2.33 Shallow pitting, ts 351 0 .04 1 [~ 4 ,06 .08 2.31 Shallow pitting, ts 352 0 .04 16 4 .06 .07 2,32 Shallow pitting. Lt. Deposits. ~ 353 0 .03 13 2 .06 .07 2.32 354 0 .03 16 3 .09 .07 2.32 Shallow pitling. ~ 355 0 .04 1S 3 .09 .08 2.31 Line shallow corrosion. Lt. Deposits. ~ 356 0 .05 25 5 .08 .08 2.30 Line corrosion. ~ 357 0 .04 1~ 4 .08 .08 2.30 Line shallow corrosion. ~ 358 0 .04 1~ 4 .06 .07 2.33 Line shallow corrosion. Lt. Deposits. t~ 359 0 .04 1 3 :06 .07 2.31 Line shallow corrosion. /~ 360 0 .04 1~ 4 .07 .08 2.3t Line shallow corrosion. Lt Deposits, ~ 361 0 .04 1S 6 .06 ,07 2.32 Shallow pitfng. 362 0 .04 1~ 3 .07 .08 2.31 Line shallow corrosion. 363 0 .04 1S 4 .07 .08 2=30 Line shallow corrosion~ Lt. Deposits. ~ 364 0 .05 21 5 .07 .08 2.29 Isolated pit~ing,]~ 365 0 .03 1( 3 .07 .07 2.33 Shallow pitting. 366 0 .03 13 2 .06 .06 2.34 Lt. Deposits. ts 367 0 .04 2C 4 .09 .10 2.27 Corrosion. ~ 368 0 .04 1S 4 .09 .10 2.26 Line shallow corrosion. ~ 369 0 .03 14 3 .05 .07 2.32 Shallow pitting. Lt. Deposits. 370 0 .04 lC, 5 .08 .10 2.28 Line shallow corrosion. ~ 371 0 .04 1 ~ 3 .09 .11 2.26 Shallow pitting. Deposits. 372 0 .04 I ~ 3 .09 .10 2.26 Line shallow corrosion. ~ 373 0 ,03 15. 2 .10 .11 2.26 Shallow pitting. Deposits. ts 374 0 .03 12 1 ,10 .10 2.26 LC Deposits. ts 375 0 .04 1 ~ 5 .08 .11 2.25 Line shallow corrosion. Deposits. 376 0 .04 1 ~ 4 .06 .08 2.31 Line shallow corrosion. 377 0 .03 1~ 2 .05 .07 2.32 ~ 378 0 .04 1~ 6 .07 .07 2.33 [Line shallow corrosion. Lt. Deposits. 379 0 .04 17 4 .06 ,08 2.32 Shallow pitting. 380 0 .05 [ 21 4 .07 .08 2.29 Line corrosion. 38t 0 .05 [ 2z 6 .06 .07 2.32 Line corrosion. Lt. Deposits. 382 0 .04 18[ 6 .06 ~08 2,32 Line shallow corrosion. 383 0 .04 171 6 .05 .08 2.32 Shallow pitting. 384 0 .04 18i 5 .05 .07 2.33 kine shallow corrosion. Lt. Deposits. 385 0 .04 18 5 .06 .07 2.32 Line shallow corrosiom 386 0 ~05 2t 6 .05 .07 2.33 Line corrosion~ LL Deposits. 387 0 .03 15 5 .07 .07 2.32 Shallow pitting. 388 0 .04 17 4 .06 .06 2.33 Shallow pitting. 389 0 .04 18 6 .06 .06 2.32 Line shallow corrosion. Lt. Deposits. 390 0 .04 19 6 .07 .07 2.32 Line shallow corrosion. 391 0 i .04 20 8 .07 .07 2.32 Line corrosion. 392 0I .04 18 4 .07 .08 2.30 Line shaltow corrosion. Lt. Deposits. 393 I 0 .04 18 6 .07 .07 2.31 Shallow pitting. 394 0 .04 16 5 0 .07 2.31 Shallow corrosion. 395 0 .04 17 4 .08 .09 2.28 Shallow pitting. Lt. Deposits. 396 0 .05 22 7 .07 .07 2.31 Line corrosion, PDS CA[ JOINT TABULATION SHE Pipe: 2.875 ins 6.5 ppf EUE8RD Wail thickness. Body: 0.217ins Upset = 0.311 ins Nominal ID: 2.441 ins Well: Field: Company: Country: Date: F-80 MILNE PT. UNIT BP EXPLORATION ALASKA USA April 07, 2000 ID inches 2.32 2.31 2.34 2.33 Comments Line shallow corrosion. Line corrosion. 2.28 Line shallow corrosion. Lt. Deposits. 2.28 Line shallow corrosion. 2.33 2.33 2.34 2.31 2.33 2.34 2.32 2.32 2.37 2.37 Line shallow corrosion. Line shallow corrosion. Line shallow corrosion. Line shallow corrosion. LL Deposits. PORTED SUB Shallow corrosion. Damage Classifications Penetration / projection class, in order of damage severib/ Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 60% of circumference, but depth range does not exceed 2 * pipe ID Line - damage depth range exceeds 4 * pipe ID, but extends less than 30% of circumference General - damage depth range exceeds 2 * pipe ID and/or extends more than 30% of circumference Isolated - damage depth range does not exceed 4 * pipe ID or extend more than 30% of circumference Damage repo~ting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length = 0.243 feel penetration body metal loss body Damage profile (% ~vall) 50 1 O0 Pipe Tabulations page 9 RECEIVED APR 25 AnchOrage PDS Caliper Sections Well: F~80 Survey Date: April 07, 2000 Field: MILNE PT, UNIT Tool Type: MFC24 No,99628 Company: BP EXPLORATION ALASKA Tool Size: I 11/16" ins Country: USA No. of Fin§ers; 24 Tubing: 2.875 ins 6.5 ppf EUE 8RD Analysed: Steve Adcock Cross section for Joint 52 Tool speed = 38 Nominal iD = 2~441 Nominal OD = 2.875 Remaining wall area = 93 % Tool deviation = 21 ° at depth 1637.16 ft Finger 1 Radius = 1,412 ins PROBABLE HOLE 0~198 tn. = 91% HIGH SiDE: UP RECEIVED Alask~ Oil & Ga~ Co~s, Oorr~[~Ior~ Cross-Sectior~s page Well: F-80 Field: MILNE PT. UNIT Company: BP EXPLORATION ALASKA Country: USA Tubin 2.875 ins 6~5 ppi EUE 8RD PDS Caliper Sections Survey Date: April 07, 2000 Tool Type: MFC24 No.99628 Tool Size: 1 11/16" ins No. of Fingers: 24 Analysed: Steve Adcock Cross section for Joint 32 Tool speed = 43 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 93 % Tool deviation -- 8 ° at depth 1029.57 ft Finger 17 Radius = 1.404 ins Possible HOLE 0,187 In.= 86% HIGH SIDE = UP RECEIVED Cross~Sections page 2 PDS Caliper Sections Well: F-80 Survey Date: April 07, 2000 Field: MILNE PT. UNIT Tool Type: MFC24 No.99628 Company: BP EXPLORATION ALASKA Tool Size: 1 11/16" ins Country: USA No, of Fingers: 24 Tubin 2.875 ins 6.5 ppf EUE 8RD Analysed: Steve Adcock Cross section for Joint 47 Tool speed = 20 Nominal ID = 2.441 Nominal OD = 2.875 Remaining wall area = 92 % Tool deviation = 19 ° at depth 1487.65 ft Finger 24 Radius = 1.402 ins Possible HOLE 0.186 In. = 86% HIGH SIDE = UP RECEIVED A~aska Oil & Gas Cons, Cross*Sections page 3 PDS., LIPER JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf EUE8RD Wall thickness. Body: 0.217ins Upset = 0.311 ins Nominal ID: 2.441 ins Joint Depth Length Measured Type No. ID feet feet inches .1 33.28 4.74 nominal Pup 1 38.03 30.66 nominal 2 68.68 31.44 nominal 3 100.12 30.21 nominal 3.1 130.33 10.23 nominal Pup 3.2 140.56 6.09 nomina~ GIml 3.3 146.65 10.13 nominal Pup 4 156.78 30.51 nominal 5 187.29 31.29 nominal 6 218.58 30.70 nominal 7 249.28 29.39 nominal 8 278.67 30.23 nominal 9 308.90 31.42 nominal 10 340.32 30.11 nominal 11 370.43 31.67 nominal 12 402.10 31.43 nominal 13 433.53 31.64 nominal 14 465.1 7 30.13 nominal 15 495.30 31.42 nominal 16 526.72 30.87 nominal 1 7 557.59 30.38 nominal 18 587.97 30.36 nominal 19 618.33 29.56 nominal 20 647.89 29.57 nominal 21 677.46 30.36 nominal 22 707.82 30.25 nominal 23 738.07 30.47 nominal 24 768.54 30.57 nominal 25 799.11 29.51 nominal 26 828.62 30.76 nominal 27 859.38 29.78 nominal 28 889.16 30.46 nominal 29 919.62 31.43 nominal 30 951.05 30.55 nominal 31 981.60 29.16 nominal 32 1010.76 31.34 nominal 33 1042.10 28.06 nominal 34 1070.16 29.50 nominal ,35 1099.66 29.55 nominal 36 1129.21 29.30 nominal 37 1158.51 31.00 nominal 38 1189.51 31.56 nominal 39 1221.07 31.55 nominal 40 1252.62 31.37 nominal 41 1283.99 31.19 nominal 42 1315.19 31.55 nominal 43 1346.73 31.63 nominal 44 1378.36 31.46 nominal 45 1409.82 31.44 nominal 46 1441.26 31.50 nominal Well: F-80 Field: MILNE PT. UNIT Company: BP EXPLORATION ALASKA Country: USA Date: April 07, 2000 Joint Depth Length Measured Type No. ID feet feet inches 47 1472.76 31.38 nominal 48 1504.14 34.71 nominal 49 1538.85 32.30 nominal 50 1571.1 5 31.30 nominal 51 1602.45 31.29 nominal 52 1633.74 31.32 nomina~ 53 1665.06 31.22 nominal 54 1696.28 31.27 nominal 55 1727.55 31.30 nominal 56 1758.85 31.54 nominal 57 1790.39 31.38 nominal 58 1821.77 31.48 nominal 59 1853.25 31.14 nominal 60 1884.39 30.79 nominal 61 1915.18 31.32 nominal 62 1946.50 31.41 nominal 63 1977.91 33.16 nominal 64 2011.07 31.28 nominal 65 2042.35 30.77 nominal 66 2073.12 31.02 nominal 67 2104.14 31.08 nominal 68 2135.22 29.49 nominal 69 2164.71 31.50 nominal 70 2196.22 31.33 nominal 71 222 7.54 32.32 nominal 72 2259.86 31.42 nominal 73 2291.28 31.36 nominal 74 2322.65 31.49 nominal 75 2354.14 31.33 nominal 76 2385.47 31.47 nominal 77 2416.94 31.71 nominal 78 2448.65 31.39 nominal 79 2480.03 31.57 nominal 80 2511.60 31.56 nominal 81 2543.16 31.44 nominal 82 2574.60 31.43 nominal 83 2606.03 31.46 nominal 84 2637.49 31.61 nominal 85 2669.10 31.34 nominal 86 2700.44, 31.52 nominal 87 2731.96 31.36 nominal 88 2763.32 31.49 nominal 89 2794.81 29.53 nominal 90 2824.34 31.42 nominal 91 2855.76 31.52 nominal 92 2887.28 31.39 nominal 93 2918.67 31.69 nominal 94 2950.36 31.53 nominal 95 2981.89 31.37 nominal 96 3013.26 31.54 nominal Joint Tally page I RECEIVED APR 25 2000 Alaska Oil & Gas Cons. Oommissior~ Anchorage PDS LIPER JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf EUE 8RD Wall thickness. Body: 0.21 7ins Upset = 0.311 ins Nominal ID: 2.441 ins Joint Depth Length Measured Type No. ID feet feet inches '97 3044.80 31.45 nominal '98 3076.25 31.49 nominal 99 3107.75 31.50 nominal 100 3139.24 31.50 nominal 101 31 70.74 30.85 nominal 102 3201.59 31.28 nominal 103 3232.87 31.44 nominal 104 3264.31 31.51 nominal 105 3295.83 31.62 nominal 106 332 7.45 31.47 nominal 107 3358.92 31.50 nominal · 108 3390.42 31.40 nominal 109 3421.82 31.51 nominal 110 3453.33 31.30 nominal , 111 3484.63 31.55 nominal 112 3516.18 30.50 nominal 113 3546.68 31.67 nominal 114 3578.35 31.48 nominal 115 3609.83 29.30 nominal 116 3639.13 29.66 nominal 11 7 3668.79 29.26 nominal 118 3698.05 30.49 nominal 119 3 728.54 31.40 nominal 120 3759.94 30.98 nominal 121 3 790.92 31.63 nominal 122 3822.55 31.64 nominal 123 3854.19 31.56 nominal 124 3885.75 31.89 nominal 125 391 7.63 31.86 nominal 126 3949.49 31.28 nominal 127 3980.77 31.61 nominal 128 4012.38 31.45 nominal 129 4043.83 31.34 nominal 130 4075.17 31.42 nominal 131 4106.59 31.59 nominal 132 4138.19 31.45 nominal 133 4169.64 31.51 nominal 134 4201.15 31.43 nominal 135 4232.58 31.55 nominal , . 136 4264.13 29.36 nominal 13 7 4293.49 31.54 nominal 138 4325.03 31.31 nominal 139 4356.33 31.42 nominal 140 4387.75 31.78 nominal 141 4419.53 31.38 nominal 142 4450.91 31.57 nominal 143 4482.48 31.75 nominal 144 4514.23 31.84 nominal 145 4546.07 31.52 nominal 146 4577.59 30.51 nominal · , Well: F-80 Field: MILNE PT. UNIT Company: BP EXPLORATION ALASKA Country: USA Date: April 07, 2000 Joint Depth Lensth Measured Type No. feet feet inches 147 4608.10 '31.57 nominal 148 4639.67 31.74 nominal 149 4671.41 31.48 nominal 150 4702.89 30.20 nominal 151 4733.09 31.46 nominal 152 4764.55 33.04 nominal 153 4797,59 31.48 nominal 154 4829,07 31.3 7 nominal 155 4860,44 30.52 nominal 156 4890,96 31.52 nominal 157 4922,48 31.45 nominal 158 4953,93 31.50 nominal 159 4985,43 31.41 nominal i160 5016,84 30.76 nominal 161 5047,60 28.42 nominal 162 5076.02 31.12 nominal 1..63 5107.14 32.40 nominal 164 5139.54 31.34 nominal 165 5170.88 31.43 nominal 166 5202.31 31.58 nominal .167 5233.89 31.74 nominal 168 5265.63 30.34 nominal 169 5295.97 29.83 nominal 1 70 5325.80 31.45 nominal 171 5357.25 31.64 nominal 172 5388.89 31.69 nominal 173 5420.58 31.50 nominal 174 5452.08 31.53 nominal 175 5483.61 31.47 nominal 176 5515.08 31.70 nominal 177 5546.78 31.52 nominal 178 5578.30 30,26 nominal 179 5608.56 30.55 nominal 180 5639.11 30.86 nominal 181 5669.97 31.48 nominal 182 5701.45 31.22 nominal 183 5732,67 30.24 nominal 184 5762.91 31.29 nominal 185 5794.20 31.34 nominal 186 5825.54 31.37 nominal 187 5856.91 31.58 nominal 188 5888.49 31.24 nominal 189 5919.73 31.48 nominal 190 5951.21 30,48 nominal 191 5981.69 31.10 nominal 192 6012.79 31.28 nominal 1, 93 6044.07 31.28 nominal 194 6075.35 31.08 nominal 195 6106.43 31.33 nominal 196 , 6137.76 30.96 nominal Joint Tally page 2 RECEIVED APR 25 2000 Alaska Oil & Gas Cons. Commissior, Anchorage PDS, . LIPER JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf EUE 8RD Wall thickness. Body: 0.217ins Upset = 0.311 ins Nominal ID: 2.441 ins Joint Depth Length Measured Type No. ID feet feet inches 197 6168.72 31.23 nominal 198 6199.95 31.48 nominal 199 6231.43 30.81 nominal 200 6262.24 30.92 nominal 201 6293.16 31.21 nominal 202 6324.37 31.50 nomina~ 203 6355.87 31.40 nominal 204 6387,27 31.41 nominal 205 6418.68 31.25 nominal 206 6449.93 31.07 nominal 207 6481.00 28.16 nominal 208 6509.15 35.1 7 nominal 209 6544.32 29.45 nominal 210 6573.77 31.40 nominal 211 6605.1 7 31.47 nominal 212 6636.64 31.46 nominal 213 6668.10 31.26 nominal 214 6699.36 31.36 nominal 215 6730.72 31.34 nominal 216 6762.06 31.82 nominal 21 7 6793.88 31.44 nominal 218 6825.32 31.47 nominal 219 6856.79 31.49 nominal 220 6888.28 31.45 nominal 221 6919.73 31.92 nominal 1222 6951.65 31.47 nominal 223 6983.12 31.72 nominal 224 7014.84 29.35 nominal 225 7044.19 30.87 nominal [226 7075.06 31.40 nominal 22 7 7106.46 29.24 nominal 228 7135.70 31.27 nominal 229 7166.97 31.29 nominal 230 7198.26 31.32 nominal 231 7229.58 31.51 nominal 232 7261.09 29.43 nominal 233 7290.52 31.31 nominal 234 7321.83 30.64 nominal 235 7352.47 29.44 nominal 236 7381.91 29.04 nominal 237 7410.95 29.45 nominal 238 7440.40 29.97 nominal 239 7470.37 31.48 nominal 240 7501.85 29.68 nominal 241 7531.53 29.51 nominal 242 7561.04 31.53 nominal 243 7592.57 31.50 nominal 244 7624.07 31.46 nominal 245 7655.53 31.42 nominal 246 7686.95 31.57 nominal Well: F-80 Field: MILNE PT. UNIT Company: BP EXPLORATION ALASKA Country: USA Date: April 07, 2000 Joint Depth Length Measured Type No. feet feet inches 247 7718.52 31.38 nominal 248 7749.90 31.29 nominal 249 7781.1 9 31.35 nominal 250 7812.54 31.26 nominal 251 7843.80 31.86 nominal 252 7875.66 29.79 nominal 253 7905.45 31.40 nominal 254 7936.85 31.59 nominal 255 7968.44 32.17 nominal 256 8000.61 30.89 nominal 257 8031.50 31.09 nominal 258 8062.59 31.34 nominal 259 8093.93 31.95 nominal 260 8125.88 32.19 nominal 261 8158.07 30.97 nominal 262 8189.04 31.48 nominal 263 8220.52 31.43 nominal 264 8251.95 31.31 nominal 265 8283.26 30.93 nominal 266 8314.19 30.48 nominal 267 8344.67 29.47 nominal 268 83 74.14 29.59 nominal 269 8403.73 30.08 nominal 270 8433.81 29.43 nominal 271 8463.24 31.28 nominal 272 8494.52 28.92 nominal 273 8523.44 30.79 nominal 274 8554.23 29.63 nominal 275 8583.86 31.1 9 nominal 276 8615.05 31.44 nominal 277 8646.49 31.1 7 nominal 2 78 8677.66 31.93 nominal 2 79 8709.59 31.63 nominal 280 8741.22 31.42 nominal 281 8772.64 31.29 nominal 282 8803.93 31.32 nominal 283 8835.25 31.36 nominal 284 8866.61 31.50 nominal 285 8898.11 30.58 nominal 286 8928.69 31.36 nominal 287 8960.05 31.74 nominal 288 8991.79 31.2 7 nominal 289 9023.06 31.50 nominal 290 9054.56 30.93 nominal 291 9085.49 31.75 nominal 292 9117.24 32.55 nominal 293 9149.79 30.42 nominal 294 9180.21 31.85 nominal 295 9212.06 31.36 nominal 296 9243.42 31.47 nominal Joint Tally page 3 RECEIVED APR 26 2000 Alaska Oil & G~s Cons. Commissior~ Anchorage PDS LIPER JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf EUE8RD Wall thickness. Body: 0.217ins Upset -- 0.311ins Nominal ID: 2.441 ins Joint Depth Length Measured Type No. ID feet feet inches 297 9274.89 31.38 nominal 298 9306.27 31.35 nominal 299 9337.62 31.38 nominal 300 9369.00 29.54 nominal 301 9398.54 31.21 nominal 302 9429.75 3i .58 nominal '~303 9461.33 29.80 nominal 304 9491.13 32.42 nominal 305 9523.55 31.25 nominal 306 9554.80 31.36 nominal 307 9586.16 30.95 nominal 308 961 7.11 31.28 nominal 309 9648.39 30.54 nominal 310 9678.93 31.16 nominal 311 9710.09 31.38 nominal 312 9741.47 28.43 nominal 313 9769.91 36.03 nominal 314 9805.94 31.24 nominal 315 9837.18 31.21 nominal 316 9868.39 31.24 nominal 31 7 9899.63 31.45 nominal 318 9931.08 28.69 nominal 319 9959.77 31.49 nominal 320 9991.26 31.07 nominal 321 10022.33 31.39 nominal 322 10053.72 31.80 nominal 323 10085.52 31.31 nominal 324 10116.83 31.33 nominal 325 10148.16 31.49 nominal 326 101 79.65 31.32 nominal 327 10210.97 31.28 nominal 328 10242.25 31.02 nominal 329 10273.27 31.28 nominal 330 10304.55 31.28 nominal 331 10335.83 31.22 nominal 332 10367.05 31.36 nominal 333.. 10398.41 31.10 nominal 334. 10429.51 33.22 nominal 335 10462.73 31.30 nominal 336 10494.03 28.24 ~ominal 337 10522.27 31.29 nominal 338 10553.56 31.38 nominal 339 10584.94 31.32 nominal 340 10616.26 31.88 nominal 341 10648.14 31.03 nominal 342 10679.17 29.52 nominal 343 10708.69 30.78 nominal 344 10739.47 31.09 nominal 345 10770.56 31.06 nominal 346 10801.62 31.25 nominal Well: F-80 Field: MILNE PT. UNIT Company: BP EXPLORATION ALASKA Country: USA Date: April 07, 2000 Joint Depth Length Measured Type No. ID feet feet inches 'J47 10832.87 31.30 nominal 348 10864.17 31.08 nominal 349 10895.25 32.02 nominal 350 1092 7.2 7 30.96 nominal 351 10958.23 31.40 nominal 352 10989.63 30.82 nominal 353 11020.45 30.79 nominal 354 11051.24 26.75 nominal 355 11077.99 35.13 nominal 356 11113.11 31.15 nominal 357 11144.26 30.62 nominal 358 11174.88 30.55 nominal 359 11205.43 31.17 nominal 360 11236.60 30.97 nominal 361 11267.57 31.42 nominal 362 11298.99 31.36 nominal 363 11330.35 30.66 nominal 364 11361.01 33.77 nominal 365 11394.78 30.93 nominal [366 11425.71 31.1 9 nominal 367 11456.90 30.87 nominal ~i 368. 11487.77 30.97 nominal 369 11518.74 31 .t 2 nominal 3 70 11549.86 30.87 nominal 371 11580.73 31 .t 5 nominal 372 11611.88 30.85 nominal 373 11642.73 30.72 nominal 374 11673.45 31.87 nominal 375 11705.32 32.50 nominal 376 11737.82 30.10 nominal 377 11767.92 31.99 nominal 378 11799.91 30.75 nominal 3 79 11830.66 31.53 nominal 380 11862.19 30.71 nominal 381 11892.90 31.35 nominal 382 11924.25 31.21 nominal 383 11955.46 31.37 nominal 384 11986.83 31.12 nominal 385 1201 7.95 29.29 nominal 386 12047.24 31.39 nominal 387 12078.63 31.58 nominal 388 12110.21 31.37 nominal 389 12141.58 30.59 nominal 390 12172.1 7 32.18 nominal 391 12204.35 31.10 nominal 392 12235.45 31.14 nominal 393 12266.59 31.31 nominal 394 12297.90 31.18 nominal 395 12329.08 31.20 nominal 396 12360.28 31.04 nominal Joint Tally page 4 RECEIVED APR 25 2000 Alaska 0il & Gas Cons. Commission Anchorage PDS~ ;~LIPER JOINT TALLY SHEET Pipe: 2.875 ins 6.5 ppf EUE 8RD Wall thickness. Body: 0.217ins Upset-- 0.311 ins Nominal ID: 2.441 ins Well: Field: Company: Country: Date: F-SC) MILNE PT. UNiT BP EXPLORATION ALASKA USA April 07, 2000 Depth feet Length feet ID inches Type RECEIVED APR 25 ~000 Alaska Oil & Gas Cons. Commission Anchorage Joint Tally page 5 STATE OF ALASKA ALASKA'~CL. AND GAS CONSERVATION coM~JlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [~Operation Shutdown I~Stimulate I~Plugging []Perforate [~ Pull Tubing []Alter Casing [~ Repair Well []Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1943' NSL, 3046' WEL, SEC. 6, T13N, R10E, UM At top of productive interval 609' SNL, 1919' WEL, SEC. 11, T13N, R9E, UM At effective depth 646' SNL, 1976' WEL, SEC. 11, T13N, R9E, UM At total depth 673' SNL, 2018' WEL, SEC. 11, T13N, R9E, UM 5. Type of well: [~ Development [] Exploratory [] Stratigraphic E~ Service 6. Datum Elevation (DF or KB) KBE = 43.25' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-80 9. Permit Number / Approval No. 98-217 10. APl Number 50-029-22928 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 13408 feet true vertical 7179 feet Effective depth: measured 13295 feet true vertical 7077 feet Casing Length Size Structural Conductor 120' 20" Surface 5577' 9-5/8" Intermediate Production 7" Liner Plugs (measured) Junk (measured) Baker 7" WLSRBP with overshot & 4-1/2" retrieving tool at 13257' (WLM 3/99) Cemented 250 sx Arcticset I (Approx.) 550 sx PF E, 140 sx G, 1268 sx PF E, 175 sx PFC 13346' 340 sx Class 'G' MD TVD 120' 120' 5612' 3861' 13379' 7152' Perforation depth: measured 13164'-13184' true vertical 6960'-6977' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, EUE 8rd to 13150' Packers and SSSV (type and measured depth) Cavins Desander at 12954' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-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 E~ Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .,r"" ' ~ Terrie Nubble fl 2~ , _ Title Technical Assistant III Prepared By Name/Number: Terrie Hubble, 564-4628 Submit In Duplicate' Form 10-404 Rev. 06/15/88 Facility Date/Time 20 Mar 99 21 Mar 99 22 Mar 99 23 Mar 99 24 Mar 99 25 Mar 99 ! M Pt F Pad Progress Report Well MPF-80 Page 1 Rig Nabors 4ES Date 14 April 99 21:00-03:00 03:00-05:00 05:00-06:00 06:00-07:00 07:00-08:00 08:00-12:30 12:30-13:30 13:30-22:00 22:00-23:00 23:00-00:30 00:30-02:30 02:30-03:30 03:30-04:30 04:30-06:00 06:00-16:00 16:00-18:00 18:00-19:00 19:00-20:00 20:00-23:30 23:30-06:00 06:00-07:00 07:00-11:00 11:00-14:30 14:30-15:30 15:30-16:30 16:30-22:00 22:00-04:00 04:00-06:00 06:00-09:45 09:45-12:00 12:00-16:30 16:30-19:00 19:00-00:00 00:00-02:30 02:30-06:00 06:00-10:30 10:30-12:00 12:00-13:30 13:30-14:00 14:00-16:00 Duration 6hr 2hr lhr lhr 1 hr 4-1/2 hr 1 hr 8-1/2 hr 1 hr 1-1/2 hr 2hr lhr 1 hr 1-1/2 hr 10hr 2hr 1 hr lhr 3-1/2 hr 6-1/2 hr lhr 4 hr 3-1/2 hr lhr lhr 5-1/2 hr 6hr 2 hr 3-3/4 hr 2-1/4 hr 4-1/2 hr 2-1/2 hr 5hr 2-1/2 hr 3-1/2 hr 4-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 2hr Activity Rig moved 100.00 % Rigged up High pressure lines Retrieved Hanger plug Held safety meeting Tested High pressure lines Circulated closed in well at 12814.0 ft Monitor wellbore pressures Circulated closed in well at 12814.0 ft Removed Xmas tree Rigged up BOP stack Tested BOP stack Retrieved Hanger plug Removed Tubing hanger Pulled Tubing in stands to 500.0 ft Pulled Tubing in stands to 80.0 ft Retrieved ESP Flow check Worked on BOP - Lubricator Rig waited: Service personnel Installed Bridge plug Tested Bridge plug - Via string Bleed down well Set downhole equipment (wireline) Tested Bridge plug - Via string Rigged down sub-surface equipment - Setting tools Bullhead well Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Bullhead well Monitor wellbore pressures Rigged up sub-surface equipment - ESP Ran Tubing in stands to 9500.0 ft Serviced ESP Ran Tubing in stands to 13149.0 ft Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Retrieved Hanger plug Freeze protect well - 12.000 bbl of Diesel STATE OF ALASKA ALASKA?'~,,'"~".~L AND GAS CONSERVATION COMM¥~;$1ON REPORT OF ,SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 43.25' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number MPF-80 1943' NSL, 3046' WEL, SEC. 06, T13N, R10E, UM ~. Permit Number/ Approval No. At top of productive interval 198-217 613' SNL, 1915' WEL, SEC. 11, T13N, R09E, UM 10. APl Number At effective depth 50-029-22928-00 652' SNL, 1975' WEL, SEC. 11, T13N, R09E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 678' SNL, 2017' WEL, SEC. 11, T13N, R09E, UM Sands 12. Present well condition summary Total depth: measured 13408 feet Plugs (measured) true vertical 7179 feet Effective depth: measured 13295 feet Junk (measured) Baker 7" WLSRBP with overshot & 4-1/2" retrieving tool true vertical 7077 feet at 13257' (WLM 3/99) Casing Length Size Cemented MD TVD Structural Conductor 120' 20" 250 sx Arcticset I (Approx.) 120' 120' Surface 5577' 9-5/8" 550 sx PF E, 140 sx G, 1268 sx PF E, 175 5612' 3861' Intermediate Production 13346' 7" 340 sx Class 'G' 13379' 7152' Liner Perforation depth: measured 13164'- 13184' true vertical 6960' - 6977' APR 2'1 2000 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 13106' AJaska 0~i & G,~s Cons.~.omm~.~s.~ ~' "~ Packers and SSSV (type and measured depth) None Anchora(.~ 13. Stimulation or cement squeeze summary Intervals treated (measured) ' . : ---~- ~ ~ ~ f.-. Treatment description including volumes used and final pressure ' 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service I~ Daily Report of Well Operations 17. I hereby certify that the.~,~g~ .oing is tr~to the best of my knowledge'//') A/! ~ d Signed Terrie Hubble /' ,j(./~..,~ , Title Technical Assistant III Date "~ ~)"~) Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Progress Report Facility M Pt F Pad Well MPF-80 Page 1 Rig Nabors 4ES Date 17 April 00 Date/Time 09 Apr 00 06:00-09:00 06:00-09:00 09:00 09:00-14:00 09:00-14:00 14:00 14:00-21:30 14:00-16:30 16:30 16:30-21:30 10 Apr 00 21:30 21:30-01:30 21:30-01:30 01:30 01:30-02:30 01:30-02:00 02:00 02:00-02:30 02:30 02:30-04:00 02:30-04:00 04:00 04:00-05:00 04:00-05:00 05:00 05:00-06:00 05:00-06:00 06:00 06:00-08:00 06:00-08:00 08:00 08:00-00:00 08:00-00:00 llApr00 00:00 00:00-06:00 00:00-03:30 03:30 03:30-06:00 06:00 Duration 3 hr 3 hr 5 hr 5 hr 7-1/2 hr 2-1/2 hr 5 hr 4 hr 4 hr 1 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 1 hr 1 hr 1 hr 2 hr 2 hr 16hr 16hr 6 hr 3-1/2 hr 2-1/2 hr Activity Move rig Rig moved 100.00 % At well location - Slot Fluid system Fill pits with Brine Set Tanks & rig lines to tree & test same. & rig lub & pull bpv. & fill pits with 10.3 PPG. Brine. Completed operations Well control Circulated closed in well at 12814.0 ft Tbg. Psi=100 0 Ann= 1000 psi. Circ. well through choke & had 400 psi. on each side when circ. complete. (Note: had small amount of communication during kill due to holes and this could be detected by fluids returns.) Hole displaced with Brine - 125.00 % displaced Monitor wellbore pressures Monitor Psi. 400 psi. tbg & annulus & build volume to 10.7 ppg. Observed pressures - string: 400.000 psi, annulus: 400.000 psi Well control Circulated closed in well at 12817.0 ft circ. well with 10.7 ppg. & monitor same Static. Hole displaced with Brine - 125.00 % displaced Wellhead work Installed Hanger plug Equipment work completed Removed Xmas tree Equipment work completed Nipple up BOP stack Installed BOP stack Equipment work completed Test well control equipment Tested BOP stack Pressure test completed successfully - 3500.000 psi This test was a mid-week test Waived by John Crisp AOGC. Wellhead work Removed Hanger plug Equipment work completed Wellhead work (cont...) Removed Tubing hanger Equipment work completed Pull Single completion, 2-7/8in O.D. Laid down 13149.0 ft of Tubing Lay dn tbg. & esp assy ( did not visually find hole in tbg. ) Completed operations Run Single completion, 2-7/8in O.D. Installed ESP Clean Floor & Mu esp & check out Equipment work completed Ran Tubing to 2031.0 ft (2-7/8in OD) Stopped: To hold safety meeting RECE!V APR 2 1 20t A;a~ka Oii& Gas Cons. 6~ An¢~0rage :D 0 remission Facility M Pt F Pad Progress Report Well MPF-80 Page 2 Rig Nabors 4ES Date 17 April 00 Date/Time 12 Apr 00 06:00-21:00 06:00-21:00 21:00 21:00-00:30 21:00-00:00 00:00 00:00-00:30 00:30 00:30-01:30 00:30-01:30 01:30 01:30-06:00 01:30-03:00 03:00 03:00-06:00 06:00 Duration 15 hr 15hr 3-1/2 hr 3 hr 1/2 hr 1 hr 1 hr 4-1/2 hr 1-1/2 hr 3 hr Activity Run Single completion, 2-7/8in O.D. (cont...) Ran Tubing to 13015.0 ft (2-7/8in OD) Made one mid-line splice Completed run with ESP to 13015.0 ft Wellhead work Installed Tubing hanger Install hanger & make EFT connector to same. & land hanger. Equipment work completed Installed Hanger plug Equipment work completed Nipple down BOP stack Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree & test tree to 5000 psi. Equipment work completed Installed Hanger plug pull twc & install bpv & secure well etc. Equipment work completed RECE,VED APR 2 1 2000 Alamka 0ii & Gas Oons. C0mmi~i0~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [~ Oil 1--] Gas ~} Suspended [] Abandoned E~] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-217 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22928 4. Location of well at surface ~- ......... ~¢~.~.~.~.I~.~9.~ Unit or Lease Name 1943' NSL, 3046' WEL, SEC. 6, T13N, R10E, UM; ~,,_~:~ .:;r?'l':~ ._., ;::.,.. ~ ~.~.;..~,~¢.~-~ Milne Point Unit of productive interval---__!; ~.'/¢~./~_~; ~ ";.~-'.;;~*:',,-~%,.. __ ... ~0. Well Number At top 609' SNL, 1919' WEL, SEC. 11, T13N, RaE, UM~ ~".~(~.-_- - i '~~q ! ii:~-~ ¢,. MPF-80 At total depth i ~F'!} i :: . Field and Pool 673' SNL, 2018' WEL, SEC. 11, T13N, R9E, UM .~.'~ L.:. · ........ ..... ;f Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 43.25'I ADL 388235 12. Date Spudded10/28/98 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if OffshOre 16' NO' Of cOmpletiOns11/8/98 1/13/99 N/A MSL One i17. Total Depth (MD+TVD) I18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 13408 7179 FTI 13295 7077 FTI ~]Yes ~jNoI N/A MD t 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, D&l, GR, DWOB, DTQE, Gyro',' CDRi ADN, PWD 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO~I-OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 Surface 120' 24" _~50 sx Arcticset I (Approx.) 9-5/8" 40# L-80 35' 5612' 12-1/4" 550 sx PF E, 140 sx G, 1268 sx PF E, 175 sx PFC 7" 29# L-80 33' 13379' 8-1/2" 340 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 3 spf 2-1/2" Gun Diameter, 6 spf 2-7/8", 6.5#, L-80 13150' N/A MD TVD MD TVD 13164' - 13184' 6960' - 6977' 13164' - 13184' 6960' - 6977' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Frac 'A' Sands 93 M# of 16/20 Carbolite behind pipe Freeze Protect with 75 Bbls of Diesel (N-27E) Freeze Protect with 15 Bbls of Diesel (N-4ES) 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) February 8, 1999I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. _~4-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Anch0m9¢ Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. SBF-2-NA 5441' 3803' TSBB-0B 6229' 4066' SBA5 6484' 4140' Base of HRZ 12574' 6444' TKLB 12727' 6575' TKUD 12924' 6747' LCU 13102' 6905' TKUA 13135' 6934' TKA3 13142' 6940' TKA2 13160' 6956' TKA1 13187' 6980' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~_~_~_~ ~1~ Title TechnicalAssistantlll Date 0~¢~.,?? MPF-80 98-217 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and 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 Performance Enquiry Report Operator BP Exploration Date 01' 16, 11 Feb 99 Page 1 Formation Integrity Test for MPF-80 The analysis is from - 10:00, 02 Nov 98 - to - 10:00, 02 Nov 98 Programs in Result Table: MPF-80 Drill and Complete Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) Depth MDR Hole Size MDR MPF-80 Event 10:00, 02 Nov 98 10:00, 02 Nov 98 0 hr 0 min Obtained required level of integrity 13.0 7548.0 8-1/2 Facility Date/Time 27 Oct 98 28 Oct 98 29 Oct 98 30 Oct 98 31 Oct 98 01 Nov 98 02 Nov 98 M Pt F Pad 06:00-07:30 07:30-08:00 08:00-09:00 09:00-12:30 12:30-21:00 21:00-02:30 02:30-05:00 05:00-06:00 06:00-07:00 07:00-08:00 08:00-09:00 09:00-11:00 11:00-12:30 12:30-13:30 13:30-06:00 06:00-12:30 12:30-13:00 13:00-04:00 04:00-05:00 05:00-06:00 06:00-08:00 08:00-11:00 11:00-13:30 13:30-18:00 18:00-20:30 20:30-00:30 00:30-04:00 04:00-06:00 06:00-08:00 08:00-08:30 08:30-15:30 15:30-18:30 18:30-20:30 20:30-23:30 23:30-01:30 01:30-03:00 03:00-04:30 04:30-06:00 06:00-10:00 10:00-11:00 11:00-14:00 14:00-17:00 17:00-18:00 18:00-18:30 18:30-19:00 19:00-21:00 21:00-22:30 22:30-23:30 23:30-02:30 02:30-03:30 03:30-04:00 04:00-06:00 06:00-07:30 07:30-08:00 Duration 1-1/2 hr 1/2 hr lhr 3-1/2 hr 8-1/2 hr 5-1/2 hr 2-1/2 hr 1 hr 1 hr lhr lhr 2 hr 1-1/2 hr 1 hr 16-1/2 hr 6-1/2 hr 1/2 hr 15hr lhr lhr 2 hr 3 hr 2-1/2 hr 4-1/2 hr 2-1/2 hr 4 hr 3-1/2 hr 2hr 2 hr 1/2 hr 7hr 3 hr 2hr 3 hr 2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 4hr lhr 3hr 3hr lhr 1/2 hr 1/2 hr 2 hr 1-1/2 hr 1 hr 3 hr lhr 1/2 hr 2 hr 1-1/2 hr 1/2 hr Progress Report Well MPF-80 Rig ~ ~{~m~ ~ Page Date Activity Rig moved 10.00 % Held safety meeting Rig moved 10.00 % Rig moved 50.00 % Rig moved 100.00 % Rigged up Divertor Made up BHA no. 1 Made up BHA no. 1 Held safety meeting Made up BHA no. 1 Drilled to 119.0 ft Racked back drill pipe Drilled to 270.0 ft Made up BHA no. 1 Drilled to 2855.0 ft Drilled to 3710.0 ft Serviced Top drive Drilled to 5473.0 ft Circulated at 5473.0 ft Drilled to 5551.0 ft Drilled to 5628.0 ft Circulated at 5628.0 ft Repaired Drillfloor / Derrick Pulled out of hole to 670.0 ft R.I.H. to 5628.0 ft Circulated at 5628.0 ft Pulled out of hole to 670.0 ft Pulled BHA Rigged up Casing handling equipment Held safety meeting Ran Casing to 5612.0 ft (9-5/8in OD) Circulated at 5611.6 ft Mixed and pumped slurry - 241.000 bbl Circulated at 5612.0 ft Mixed and pumped slurry - 514.000 bbl Rigged down Casing handling equipment Rigged down Divertor Rigged up Wellhead primary components Rigged up BOP stack Ran Drillpipe in stands to 40.4 ft Tested BOP stack Racked back drill pipe Repaired Drillstring handling equipment Racked back drill pipe Serviced Top drive Made up BHA no. 2 R.I.H. to 2097.0 ft Drilled installed equipment - DV collar R.I.H. to 5525.0 ft Circulated at 5525.0 ft Tested Casing Drilled installed equipment - Landing collar Drilled installed equipment - Float shoe Drilled to 5648.0 ft 1 10 February 99 Progress Report Facility M Pt F Pad Well MPF-80 Rig (null) Page 2 Date 10 February 99 Date/Time 08:00-09:00 09:00-10:00 10:00-11:00 11:00-04:30 03 Nov 98 04:30-06:00 06:00-07:30 07:30-08:00 08:00-09:30 09:30-06:00 04 Nov 98 06:00-08:00 08:00-12:00 12:00-13:00 13:00-16:00 16:00-19:30 19:30-20:30 20:30-21:00 21:00-22:00 22:00-23:30 23:30-01:30 05 Nov 98 01:30-06:00 06:00-06:00 06 Nov 98 06:00-18:00 18:00-18:30 18:30-06:00 07 Nov 98 06:00-07:00 07:00-09:00 09:00-13:00 13:00-15:00 15:00-17:00 17:00-00:00 08 Nov 98 00:00-06:00 06:00-14:00 14:00-15:00 15:00-22:30 22:30-00:30 09 Nov 98 00:30-06:00 06:00-06:30 06:30-07:30 07:30-10:30 10:30-12:30 12:30-17:00 17:00-22:30 22:30-01:00 10 Nov 98 01:00-04:00 04:00-06:00 06:00-12:00 12:00-13:00 13:00-16:30 16:30-17:00 17:00-01:30 11 Nov 98 01:30-03:30 03:30-06:00 06:00-06:30 06:30-08:30 Duration 1 hr 1 hr 1 hr 17-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 20-1/2 hr 2 hr 4hr 1 hr 3hr 3-1/2 hr 1 hr 1/2 hr 1 hr 1-1/2 hr 2hr 4-1/2 hr 24 hr 12hr 1/2 hr 11-1/2 hr lhr 2 hr 4hr 2 hr 2 hr 7 hr 6 hr 8 hr 1 hr 7-1/2 hr 2hr 5-1/2 hr 1/2 hr 1 hr 3hr 2 hr 4-1/2 hr 5-1/2 hr 2-1/2 hr 3 hr 2 hr 6hr 1 hr 3-1/2 hr 1/2 hr 8-1/2 hr 2 hr 2-1/2 hr 1/2 hr 2 hr Activity Circulated at 5648.0 ft Performed formation integrity test Circulated at 5648.0 ft Drilled to 7548.0 ft Circulated at 7548.0 ft Pulled out of hole to 5469.0 fl Serviced Top drive R.I.H. to 7548.0 ft Drilled to 9443.0 ft Circulated at 9443.0 ft Pulled out of hole to 693.0 ft Pulled BHA Made up BHA no. 3 R.I.H. to 5595.0 ft Serviced Block line Serviced Top drive Circulated at 5595.0 ft R.I.H. to 9943.0 ft Circulated at 9443.0 ft Drilled to 9652.0 ft Drilled to 11458.0 ft Drilled to 12220.0 ft Flow check Drilled to 12697.0 ft Drilled to 12712.0 ft Circulated at 12712.0 ft Pulled out of hole to 9612.0 ft R.I.H. to 12712.0 ft Circulated at 12712.0 ft Drilled to 12761.0 ft Drilled to 12950.0 fl Drilled to 13100.0 ft Circulated at 13100.0 ft Drilled to 13408.0 ft Circulated at 13408.0 ft Pulled out of hole to 5500.0 ft Serviced Top drive R.I.H. to 9680.0 ft Circulated at 9680.0 ft Monitor wellbore pressures Strip into well from 9680.0 ft to 12755.0 ft Circulated at 12759.0 ft Worked on BOP - BOP stack Worked on BOP - BOP stack Circulated at 12759.0 ft Bleed down well Jarred stuck pipe at 12759.0 ft Circulated at 12500.0 ft Flow check Pulled out of hole to 5600.0 ft Circulated at 5600.0 ft Pulled out of hole to 3000.0 ft Circulated at 3000.0 ft Pulled out of hole to 200.0 ft Progress Report Facility M Pt F Pad Well MPF-80 Rig (null) Page 3 Date 10 February 99 Date/Time 08:30-10:30 10:30-12:30 12:30-14:30 14:30-15:00 15:00-15:30 15:30-18:30 18:30-20:00 20:00-21:30 21:30-22:30 22:30-02:00 12 Nov 98 02:00-06:00 06:00-12:00 12:00-14:30 14:30-18:00 18:00-19:00 19:00-20:00 20:00-21:00 21:00-21:30 21:30-01:30 13 Nov 98 01:30-04:30 04:30-05:30 05:30-06:00 06:00-07:30 07:30-08:00 08:00-09:00 09:00-15:30 15:30-16:30 16:30-22:30 22:30-00:30 14 Nov 98 00:30-06:00 06:00-09:00 09:00-10:00 10:00-12:30 12:30-13:00 13:00-14:30 14:30-22:30 22:30-01:00 15 Nov 98 01:00-03:00 03:00-06:00 06:00-08:30 08:30-10:30 10:30-11:30 11:30-15:30 15:30-16:30 16:30-17:00 17:00-06:00 16 Nov 98 06:00-07:00 07:00-14:30 14:30-16:30 16:30-22:30 22:30-00:00 17 Nov 98 00:00-06:00 06:00-08:30 08:30-12:30 Duration 2 hr 2hr 2 hr 1/2 hr 1/2 hr 3hr 1-1/2 hr 1-1/2 hr 1 hr 3-1/2 hr 4 hr 6 hr 2-1/2 hr 3-1/2 hr lhr 1 hr 1 hr 1/2 hr 4 hr 3 hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr lhr 6-1/2 hr lhr 6hr 2hr 5-1/2 hr 3 hr lhr 2-1/2 hr 1/2 hr 1-1/2 hr 8 hr 2-1/2 hr 2 hr 3 hr 2-1/2 hr 2 hr lhr 4 hr 1 hr 1/2 hr 13 hr lhr 7-1/2 hr 2 hr 6 hr 1-1/2 hr 6 hr 2-1/2 hr 4 hr Activity Pulled BHA Made up BHA no. 4 R.I.H. to 5600.0 ft Set Retrievable packer at 45.0 ft with 0.0 psi Installed BOP test plug assembly Tested BOP stack Removed BOP test plug assembly Functioned downhole tools at 45.0 ft Circulated at 5600.0 ft R.I.H. to 122316.0 ft Circulated at 12316.0 ft Reamed to 12896.0 ft Circulated at 12896.0 ft Reamed to 13020.0 ft Flow check Pulled out of hole to 12029.0 ft Flow check R.I.H. to 13020.0 ft Reamed to 13408.0 ft Circulated at 13408.0 ft Flow check Pulled out of hole to 13220.0 ft Pulled out of hole to 11550.0 ft Rest hole at 11550.0 ft R.I.H. to 13408.0 ft Circulated at 13408.0 ft Rest hole at 13408.0 ft Pumped out of hole to 8412.0 ft R.I.H. to 13408.0 ft Circulated at 13408.0 ft Circulated at 13408.0 ft Flow check Pumped out of hole to 10600.0 ft Flow check R.I.H. to 13408.0 ft Circulated at 13408.0 ft Pumped out of hole to 12000.0 ft Flow check Pumped out of hole to 8200.0 ft Pumped out of hole to 5600.0 ft Circulated at 5600.0 ft Flow check Pulled out of hole to 0.0 ft Rigged up Casing handling equipment Held safety meeting Ran Casing to 12200.0 ft (7in OD) Ran Casing to 13380.0 ft (7in OD) Circulated at 13380.0 ft Mixed and pumped slurry - 41.000 bbl Wait on cement Mixed and pumped slurry - 29.000 bbl Wait on cement Flow check Investigated pressure change Facility M Pt F Pad Progress Report Well MPF-80 Rig (null) Page Date 4 10 February 99 Date/Time 18 Nov 98 19 Nov 98 12:30-14:00 14:00-20:00 20:00-21:30 21:30-01:00 01:00-03:00 03:00-06:00 06:00-06:30 06:30-07:30 07:30-09:00 09:00-19:30 19:30-20:30 20:30-21:30 21:30-06:00 06:00-07:00 07:00-14:00 14:00-16:00 16:00-18:00 18:00-21:00 Duration 1-1/2 hr 6 hr 1-1/2 hr 3-1/2 hr 2 hr 3 hr 1/2 hr 1 hr 1-1/2 hr 10-1/2 hr lhr 1 hr 8-1/2 hr 1 hr 7hr. 2 hr 2hr 3hr Activity Mixed and pumped slurry - 66.000 bbl Wait on cement Removed BOP stack Installed Accessories Installed Tubing head spool Rigged up BOP stack Tested Casing Serviced Block line Rigged up Handling equipment Ran Tubing to 12523.0 ft (4-1/2in OD) Tested Casing Serviced Fluid system Conducted electric cable operations Conducted electric cable operations Laid down 7000.0 ft of 5in OD drill pipe Rigged down BOP stack Installed Xmas tree Freeze protect well - 75.000 bbl of Diesel Milne Point Unit, Alaska TO: Trina Cooper FROM: J. Fox/J. Spearman Well Name: IMP F-80 Main Category: I PERF Sub Category: I Initial Perforations Operation Date: 112 / 7 - 8 / 98 Date: 112/10/98 I Objective: The well was recently drilled and is ready for completion. A 20' interval in the A-3 sand will be perforated to immediately be followed by a fracture stimulation. A marked line GR/CCL log will also be run for primary correlation before the perforating and a static bottomhole pressure survey will be run after. This is a new fault block so the log will be run back to surface. The 2.5" guns will be shot at 3 spf and 120 deg. phasing. The smaller guns were required due to a crossover in the tubing tail w/a 3.0" ID. Due to poor hole azimuth and hole angle a 120 deg carrier was utilized. There are no 6 spf, 120 deg. phased guns available for 2.5" guns so a 6 spf 60 deg phasing was loaded at 3 spf 120 deg. phasing. Sequence of Events: 12/07/98 to 12/08/98 0900 MIRU ELine unit. Difficult rig up due to proximity of Nabors 27E drilling on F84. 1200 RIH w/GR / CCL on big line. No rollers were available. RIH to 9000' before setting down repeatedly. POOH. 1700 Rollers now available. Install rollers top and bottom. RIH w/GR/CCL to PBTD (13,301' ELMD) w/o problem. Log from PBTD to 4850'. POOH 2300 MU 20' x 2.5" hollow carrier loaded with 3 spf at 120 deg. phasing and big hole charges. 2 7/8" Petroline rollers located above and below the gun. RIH. Tool string repeatedly setting down at 5000'. POOH. 12/08/98 0100 Remove rollers and RIH w/gun assembly only. No luck. 0300 No hot oil units available to pump guns down due to field shut down. Order out two 10' guns perf guns. Attempt to run shorter tool string with no luck. 0600 Attempt 10' gun run with rollers - No luck POOH. 0700 Called Kuparuk to get Little Red Hot Oil unit 0800 RIH with 20' gun/CCL and rollers to 5145' MD. No luck. Wait on Hot oil Unit. 1430 Hot oil rig up. Started pumping at 1 bpm. No luck. Went to 2 bpm moving down hole to 6402. Stepped rate up to 3 bpm. Going along fine to +/- 8100'. Slowed rate to 2 bpm. Stopped. Back to 3 BPM. Out of fluids 80 bbls diesel pumped 1504 Called for more fluids. 120 methanol water available in clean vac truck diverted from freeze protecting 1616 Vac truck on location. Started at 3 bpm. RIH with guns. 50 bbls of Methanol water pumped 1645 Make correlation runs. 1710 Shoot guns based on GR/CCL Depth Determination log from 13,164-13,184 ELMD. Tubing tail at 13,538 ELMD. POOH. All shots fired. 1830 P/U pressure and temperature tool. RIH 2010 Park at 13,164. Initial BHP is 4206. 2210 < 5 psi/hr pressure rise achieved. Final BHP was 4221. POOH Results: objective A primary GR / CCL correlation Icg was run from PBTD (13,301 ') to 4850'. There is 4.5" tubing to 12,538' ELMD so CCL above that point is tubing not casing and the GR is somewhat attenuated from that point up as well. The well was perforated by correlating depth using the CCL. Tie in Icg/date: Schlumberger Depth Determination Iog/12/8/98 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter All depths are E-Line measure depth Shot Density Orientation Phasing I 3 SPF RDX UP BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: B Hill/J Hendrix FROM: J. Spearman DATE: 12-09-98 RE: MP F-80 FRAC AND FRAC (A Sand) SERVICE CO'S.: DS, Peak, Howco JOB SUMMARY The well was not freeze protected on the IA before the treatment, therefore HB&R was called out and 44 bbls of diesel was pumped via the IA. Freeze protection was done in case of early screen out occurred where circulation or pump in could not be achieved. The wellbore fluids to start the treatment based on TVD was: IA: 2370' of diesel and 9.9 brine to 6942. For the tbg HH: 3615' diesel, 60/40 Methanol water to 6403', and 9.9 brine to 6942'. A 77 bbl injectivity test was pumped at 30 BPM to validate open perforations. NWFP was 386 psi. Annulus pressure was treating between 2600 to 2800 psi. With the annulus pop off set for +/- 3300 psi very little room was left to safely pump the fracture treatment with out risking the pop off release (i.e. net pressure rise of 100 to 200 psi was expected with XL going through the perforations leaving no room for pressure build during the fracture operations). A field correction was made back to the position set at the DS camp for +/- 4300 psi. The next step was to pump a scour treatment. The scour treatment screen out when the 20 bbls XL overflush was at the perforations. The Pop Off on the annulus did not operate, hence the annulus pressure was exceeded. After the shut down, pressure was holding around 3300 psi and bleeding down very slowly. The perforations were surged and pressure drop to 1650 psi or near the level the injectivity test bleed down to. To ensure that we had well integrity, the OA was check and bleed down. DS placed a gauge on the OA for further pumping operations. The pop off was field calibrated using the tree saver pump. Once well integrity issues were resolved, a 83 bbl injectivity test was perform starting at 2.5 bpm stepping up to 30 bpm. NWFP of 974 psi was observed. The NWFP went up. Since NWFP went up indicating perforation plugging, the next step was to see if a XL fluid would remove the NWFP. A 200 bbls data frac was pumped at 30 bbls. The NWFP dropped to 905. With different fluids going through the perforations, the ultimate drop in NWFP would be around 150 to 200 psi. This was not enough to risk pumping another scour treatment. It was decided to cut the saw tooth shoe off and re-perforate with 3-3/8" guns. The well was freeze protected with 30 bbls of diesel. Post slickline tag found sand top at 23-30' below bottom perforation. This equates to about 1900 lbs of 20/40 proppant. 12/14/98 11:30 AM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL INJECTIVITY TEST Design Rate, Bbls Max Rate, Final ANN, ISIP NWB friction, Treat grad, BPM Pumped bpm psi AN N psi psi/ft PSI 30 77 30 2636 2250 386 0.78 NWFP is annulus pressure 1 min before shut down minus ISIP SCOUR TREATMENT Design Rate, Bbls Max Rate, Final ANN, ISIP NWB friction, Treat grad, BPM Pumped bpm psi ANN psi psi/ft PSI 30 77 30 6299 6000 N/A N/A Sand Lead prop Liner Sand Design total Proppant pumped, behind pipe, ft behind pipe, Liner Sand, Size Job was M# M# M# M# Screen out 3 2.8 94 3 1.9 20/40 SECOND INJECTIVITY TEST Design Rate, Bbls Max Rate, Final ANN, ISIP NWB friction, Treat grad, BPM Pumped bpm psi ANN psi psi/ft PSI 2.5 TO 30 83 30 3380 2406 974 0.78 NWFP is annulus pressure 1 min before shut down minus ISIP DATA FRAC Design Rate, Bbls Max Rate, Final ANN, ISIP NWB friction, Treat grad, BPM Pumped bpm psi ANN psi psi/ft XL PSI 30 160 30 3285 2380 905 0.78 NWFP is annulus pressure 1 min before shut down minus ISIP Operational problems POP did not release during the scour treatment screen out and the well was over pressured. I DATE/TIME OPERATIONS SUMMARY 12/09/98 1030 Pre-job Safety with Construction, Field Ops, 27E, and frac crew. 1100 HB&R Freeze protect IA. 1140 Pressure Test lines to 7136 1143 Start injectivity test 1148 Shut down Injectivity test ISIP - 2250 1225 Start Scour treatment 1236 Shut down - Screen out on Scour treatment. POP off did not work. 1253 Surge perfs Monitor pressure 1605 Start Data Frac 1620 Shut down 1733 Freeze Protect well with 30 bbls diesel 10 bbls of Glycol was pumped to clear the surface lines of diesel. 2030 Rig down off location PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM BPM PSIG PSIG BBL BBL COMMENTS INJECTIVITY TEST DISPLACEMENT = 214 BBLS 1143 0 1781 2225 0 0 Prepare to start Injectivity test 1145 3 2001 2435 1 1 Start injectivity test 1146 30.6 2680 5933 35 35 on slickwater 1147 30.3 2669 5392 68 68 Pumping 1148 2.5 2479 2591 77 77 Shut down ISIP 2250 1223 0 2115 1589 0 77 Monitor pressure Scour Treatment 1224 0 2115 1589 30 77 Start Scour treatment on 24 bbl pad 1225 29.8 2675 5040 12 107 Start 0.5 PPG stage 1226 30.3 2631 4979 12 119 Start 1 ppg stage 1226 30.4 2616 4875 37 131 Start 2 ppg stage 1228 30 2583 4106 20 168 Start overflush 1228 30 2662 3983 214 188 Start slick water Flush 1229 30 2583 4106 221 Pad at perfs 1233 30.2 2860 4147 329 0.5 ppg at perfs 1233 30 2867 4120 340 1 ppg at perfs 1233 30.2 2887 4111 352 2 ppg at perfs 1235 9.4 6000 6299 389 Overflush at perfs - Screen out. Annulus pop off did not function. 1245 0 3367 3378 389 Monitoring pressures 1253 0 3352 3378 389 Decide to surge perfs 1302 0 1666 1694 389 Perfs surges pressure came down to +/- 1670 psi and fell to this is 7 minutes. 1325 0 1649 1689 Freeze protect hard lines Pressure fell only to 1649 on annulus in 30 minutes. Not much of a drop 1456 Field Calibrated Pop Off to go at +/- 4100 psi Data Frac 1522 390 Prepare to perform injectivity test for data frac 2.5 1900 2050 Eased into well ramping up to 30 BPM 5 2918 3040 9.4 3197 3568 12.6 3256 3708 20 3276 4056 30 3380 4573 473 Shut down ISlP 2406 1604 Prepare to start data frac 1605 6.3 2142 2820 200 473 Start XL Data Frac 1611 30 3275 4788 231 673 Start Flush 20 ppg gel includes 17 bbls XL overflush 1613 30 3400 4958 687 XL at perforations 1620 30 3288 4527 887 Overflush on perfs 1620 30 3158 2422 904 Shutting down. ISIP 2388 psi Page 6 FLUIDS PUMPED 1st INJ TEST 77 Bbls YF120 Slickwater 2nd INJ TEST 83 bbls YF120 Scour treatment 109 Bbls YF130 Scour Flush 214 Bbls YF120 Slickwater XL Fluid DF 200 Bbls YF130 XL DF Flush 214 Bbls YF120 Slickwater ****TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME GEL QUALITY CONTROL CHECK SEA H20 Gel GEL GEL PIPE XL XL pH TEMP pH VISCOSITY TIME TIME pH Gel Surface XL 9.6 Water Milne Point Unit, Alaska TO: FROM: Well Name: Main Category: Sub Category: Operation Date: Anchorage Date: 112/27/98 Engineering MPU F-80 RE-PERF I'Objective: This well was originally perforated over a 20' interval in the A-3 sand with 3 SPF" big hole" charges at 120 deg. phasing using 2.5" hollow carrier guns. The subsequent frac stimulation pressured out during the scour treatment. One of the screen out contributing factors was considered to be inadequate number of perorations with adequate size. The initial 2.5" gun has smaller charges, more stand off, and lower shot density than used in the past. The same interval will be re-perforated with the same "big hole" charges but at 6 spf and 60 deg. phasing. Sequence of Events: 12/25/98 0700 - MIRU SWS completion E-Line unit. Load lubricator with diesel and pressure test to 3500 psig. RIH w/10' wt. bar, Petroline rollers, 20' x 2.5" hollow carrier (loaded w/35 UP 'bighole charges at 6 spf and 60 deg. phasing), petroline rollers, gun gamma, cablehead. The tool string ran in the hole fairly well to a depth of approx. 6200' before setting down repeatedly at the same depth. Call out hot oil unit to load dead oil. 1500 - Rig up hot oil unit to pump in sub and pressure test surface lines. Start bullheading into formation -unable to get adequate rate at less than 3000 psi surface pressure to move tool. Open annulus to circulate to tank through choke. Maintain approx. 1500 psig of back pressure. Circulate at 3 bpm to get adequate rate to get toolstring to move. Running speed approx. 5000 fph. Pump 95 bbls of 50:50 diesel / dead crude and 15 bbl. of diesel before running out of fluid. Standby for hot oil unit to go for another full load (150 bbl.) of dead crude (50 bbls. w/50% diesel). 1500 - Continue circulating toolstring down at 3 to 3.5 bpm and 2200 to 3000 psi surface pressure. Reduced back pressure from 1500 to 750 psi. Got toolstring to approx. 10,000' before toolstring started falling on it's own. Ran out of fluid again. Toolstring setting down repeatedly at 10,639'. Check cable - armor is slightly mashed and unable to fit through the flow tubes. Work cable back to original shape. Re-spool back onto drum 3 wraps and run back. Cable armor unraveled again. Unable to get through flow tubes and may strand if it did make it through. 2000 - Abort job. POOH and release completion unit. Reload hot oil truck with 30 bbl. of dead crude and freeze protect the annulus. 12126198 1000 - MIRU hot oil unit. MU 2.5" x 20' hollow carrier w/a set of 2.75" slickline rollers on bottom and Petroline rollers on top w/gun gamma above that (removed the weight bar above the upper rollers when it would not fit in the lubricator). 1300 - Rigged up hot oil unit loaded with 160 bbl. of dead crude. PJSM and pressure test to 3500 psig. RIH with gun assembly. Tool sting ran in the hole without stopping (i.e. no pumping was required). 1630 - Depth correlated guns. lAP = 1050 psig, tbg. press. = 1200 psig, OA = 300 psig. Pull up to (CCL) shooting depth of 13,164' (7.7' F/top shot to CCL) and detonate gun. Interval perforated =13,164' - 13,184'. 1730 - POOH. All shots fired. RDMO hot oil unit. Secure well. RDMO E-Line unit. Results: The 7" casing f/13,164' to 13,184' was re-perforated with 2.5" hollow carrier gun loaded at 6 spf / 60 deg. phasing big hole charges. Tie in Iog/date__12/07/98 Depth determination log.__ BP EXPLORATION (ALASKA) INC. Milne Point Unit TO: Anchorage Engineering FROM: J. Fox DATE: Dec. 29, 1998 RE: MPU F-80 'A' SAND RE-FRAC SERVICE CO'S.: Dowell and Peak JOB SUMMARY The first frac attempt resulted in a screen out during the scour treatment. A subsequent injectivity test and data frac indicated unacceptably high NWFP and the frac job was aborted. Wireline tags afterwards indicated no fill across the perfs. In preparations for this re-frac the same twenty foot zone was reperforated at six spf / 60 deg. phasing (with the same gun size / charges) to add to the existing 3 spf / 120 deg. phasing to provide better entry into the fracture. In addition to frac design changes the guar gel loading was increased to 50 pptg instead of 20 to 30 pptg. The re-frac resulted in placing 93 M# of 16-20 Carbolite proppant behind pipe. The first 7200 # of this pumped was ChemFIow AEA scale inhibitor impregnated proppant (diluted 1:1 with conventional 16-20 proppant). The original design called for approx. 50 M# of this AEA prop. but half of what arrived was returned to the mfg. due to it being consolidated in the shipping bags when it reached the Slope. There was approx. 26 M# loaded for this job but was cut off after 7200 lbs. had been pumped as it was "clumpy" and plugging up the blender hopper causing wide fluctuations in the slurry density. Higher than anticipated tubing friction pressure resulted in reducing pump rate to stay under max. allowable surface treating pressure of 6400 psig. In addition, 200 bbl. into the frac the gel loading was dropped from 50 pptg. To 40 pptg. There was no indication of net pressure build or tip screen out despite slowing the rate down to as Iow as 13 bpm during the final displacement of the slurry. An injectivity test and scour were performed prior to the frac. The fluid leakoff indicated by these suggested that the datafrac from the original frac attempt was still applicable, if not conservative, so another datafrac was considered to be unnecessary. The injectivity test indicated a NWFP of 650 psig. After the scour this NWFP was reduced to 430 psig which, while not ideal, was acceptable. A total of 6820 lbs. of 20 / 40 proppant was pumped during the scour treatment. If a similar set up is intended for the upcoming L-28a frac the following considerations may improve that job · QA/QC each bag of AEA ChemFIow proppant as soon as it reaches the Slope. Keep in warm storage and sealed in bags until just before the frac. Do not leave exposed to the air (humidity) any longer than necessary. Take a sample of the proppant and expose it to sub-freezing temperature to verify that moisture content will not cause freezing problem. · Increase maximum allowable surface treating pressures to allow design rates to be maintained. Currently trips are set 280 psig under the 80% burst of 4.5" tbg. This is 01/06/99 DATA FRAC & FRAC 1:48 PM SENT VIA MICROSOFT MAIL TIME!. RATE ANNP WHP STAGE CUM BPM PSIG PSIG BBL Ii BBL PUMPIk~.~SUMMARY COMMENTS conservative considering there will be on the annulus (possible exception is if PRV pops but IA pressure will still not go to zero). To reduce tbg. friction pressure ( to allow design rates to be maintained ) consider going to a lighter gel loading. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP ISIP, NWB friction, Treat grad, BPM Pumped bpm psi PSI psi psi/ft 30 100 30.4 3375 2729 650 0.895 SCOUR Bbls Bbls XL gel Prop behind Final STP, ISIP, psi NWB Treat grad, Pumped to Perfs pipe, M#/size psi friction, psi psilft 30 165 6.8 M# / 20-40 3087 2614 430 0.853 FRAC Sand Lead prop Tail prop Design total Tresaver pumped, behind pipe, behind behind pipe, Liner Sand, rubber left Job was M# M# pipe, M# M# M# in hole? /size /size to design 98.2 M# 7.2 M# 16-20 85.8 94 M# 5200 no A EA 16~20 ChemFIow Carbolite DATE/TIME OPERATIONS SUMMARY 12129/98 Wind NW @ 7 mph. Temp. = -23 / -36 deg WC 1000 Pre-job safety meeting. 1115 Open well - initial pressure = 1552 on tbg., 1384 on IA 1130 Pressure test treating lines to 7500 psig. 1140 Start pumping 100 bbl. of 50 pptg guar gel and displace for Injectivity test. 1153.5 S/D pumps and monitor pressure falloff. ISlP = 2729 psig on IA. NWFP = 650 psi 1205 Start pumping scour treatment. 50 bbl. XL, 50 bbl. 1 ppa, 50 bbl. 2 ppa, 15 bbl. XL, and overdisplace 5 bbl. 1218 S/D pumps and monitor pressure falloff. ISlP = 2614 psig on IA, NWFP = 650 psi 1145 Pump KCL down wellbore to heat lines. 1430 Replace #3 pump truck. 1447 Start pumping fracture stimulation. 1521 S/D pumps with frac at design. 1830 RU HB&R hot oil unit and pump an additional 5 bbl. of diesel into the tubing to finish freeze protect. 30 bbls total. Required pumping at very slow rate to 3800 psig. Pressure is slow to bleed to the formation due to sand on top of perfs. TIME~ RATE ~ BPM PUMPING SUMMARY ANNP WHP STAGE CUM PSlG PSIG BBL BBL COMMENTS 12/29/98 INJECTIVITY TEST DISPLACEMENT = 214.6 BBLS 1140 0 / 30 1430 1580 0 0 i Start pumping 50# gel 1142 25 3281 6500 40 40 At max. allowable pressure - Unable to reach ~ design rate. Displacing tbg. full ofdead crude. 1144 23 3250 6269 75 75 ! Backing down rate to stay under max. allowable ' treating pressure. 1146 23 3263 6294 100 / 0 100 Switch to 2% KCl water. 1148 30 3325 6001 85 185 Worked up rate up to design. 1149.5 30.4 3303 5576 114 214 gel on perfs 1150.5 29.8 3512 5630 144 244 1151.5 30.4 3464 5260 173 273 1153 30.3 3439 4628 218 318 1153.5 30 / 0 3376 224 324 S/D pumps. Monitor pressure falloff. ISlP = 2729 psig on IA, NWFP = 650 psi 1154.5 0 2798 2747 1156.5 0 2730 2504 1200 0 2629 2403 SCOUR 2275 2505 ~ 0 324 Start pumping I11205 0 / 30 206.31 3O 3435 4349. 25 349 At design rate. TIME : RATE ANNP WHP BPM · PSIG : PSIG PUMPING SUMMARY STAGE ~ CUM i BBL BBI COMMENTS 1207 29.3 3186 4399 50 / 0 374 Start 1 ppg. slurry 1208.5 29.9 3316 4944 50 / 0 424 Start 2 ppg slurry 1210.2 30.0 3395 5415 50 / 0 475 Start 15 bbl. XL sweep. 1210.5 29.6 3395 5516 15 / 0 490 Start displacement 1213 30.2 3494 5640 85 575 1213.5 30.0 3414 5662 50 541 pad on perfs 1214.5 30.4 3517 5424 99 589 1 ppg on perfs 1215.5 30.3 3256 4800 149 639 2 ppg slurry on perfs. 1217 30.3 3124 4376 199 689 Flush on perfs 1218.3 30 / 0 3087 4119 227 717 S/D pumps and monitor pressure falloff. ISlP = 2614 psig on IA, NWFP = 429 psi. 1219.5 0 2444 2536 1225 0 2494 2270 1230 0 2379 2156 1235 0 2293 2069 1240 0 2225 2000 1250 0 2131 1909 1300 0 2097 1872 1310 0 2086 1881 1320 0 2058 1836 FRAC 1444 0 1695 1729 0 0 Open up well. 1447 0 1682 1656 0 0 Start pumping pad. 1448.7 30 2894 4517 30 30 At design rate. 1450.5 29.9 2868 5273 93 93 1452 30.0 2920 5991 130 130 1452.7 26 2885 6188 155 / 0 155 Start 1 ppg slurry w/AEA proppant. Slowing rate to stay below maximum allowable STP. 1454 26 2914 6385 40 195 Reduce gel loading to 40 pptg 6422 245 1456 22.4 1458 20.6 2955 2991 6307 294 Having difficulty handling AEA proppant due to clumping plugging of blender hopper. Slurry density fluctuating widely as pieces are manually having to be broken up to get thru' blender Close gate on AEA and open up to conventional 16-20 Carbolite due to plugging problems. Still pumping at slow rate due to high friction pressure. 1501 26.2 2993 5639 355 1503.4 30.0 2923 5103 410 Back up to design mte. 1504.6 30.1 2883 4819 457 1506 30.2 2810 4536 496 PUMPING SUMMARY ~ . TIME RATE ANNP WHP STAGE ' CUM BPM PSIG ~ PSIG BBL BBL (~'~MMENTS 1507.5 30.5 2753 4375 536 Proppant concentration still fluctuating widely due to residual AEA in the hopper. 1508.3 30.0 2693 4307 567 : 1511 30.0 2603 4293 650 1512.8 30.0 2599 4315 702 1513.3 29.9 2597 4357 714 Start flush. 1517.5 30 / 25 2605 i 4183 809 Start slowing rate from 30 to 25 bpm in an attempt to induce a screen out. 1518.5 , 25 2625 3680 837 Start slowing rate from 25 to 20 bpm. 1519.5 20.7 2478 3313 865 1520.5 18.8 2493 3272 882 Start reducing rate from 18 to 13 bpm. 1521 13 2370 2978 : 905 1522.5 0 2195 2251 910.7 Pumps S/D. 197 bbl. displacement (17 bbl. underdisplacement. Monitoring pressure falloff. 1524.5 0 2173 2206 1526.5 0 2121 2160 Page 6 FLUIDS PUMPED DOWNHOLE INJ TEST& SCOUR: 717 FRAC: 911 1628 bbl. Bbls Bbls TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME 25 bbl. diesel into tubing PETREDAT WINDOW NONE DFIFRAC GEL QUALITY CONTROL CHECK SEA H20 ~ SEA H20 i 50# GEL 50# GEL PIPE pH TEMP i pH VISCOSITY TIME 7.0 102 to 114 . ' 3.9 sec. 7.1 min XL TIME :2:25 XL pH 9.0 FLUID ADDITIVES J-877 Guar LGC - 12. gptg F75N surfactant- I gptg M275 bacteriacide - 0.3 pptg L-10 boric acid Xler- 2 pptg Facility M Pt F Pad Progress Report Well MPF-80 Page 1 Rig Nabors 4ES Date 10 February 99 Date/Time 08 Jan 99 09 Jan 99 10 Jan 99 11 Jan 99 12 Jan 99 13 Jan 99 12:00-18:00 18:00-06:00 06:00-09:00 09:00-11:30 11:30-13:00 13:00-18:00 18:00-19:00 19:00-20:00 20:00-23:00 23:00-06:00 06:00-06:30 06:30-08:30 08:30-11:30 11:30-12:30 12:30-18:00 18:00-18:30 18:30-20:30 20:30-22:30 22:30-06:00 06:00-06:30 06:30-07:30 07:30-21:30 21:30-01:00 01:00-04:30 04:30-06:00 06:00-09:30 09:30-15:00 15:00-17:00 17:00-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-10:00 10:00-12:30 12:30-15:00 15:00-17:30 17:30-18:00 Duration 6 hr 12hr 3 hr 2-1/2 hr 1-1/2 hr 5hr 1 hr 1 hr 3 hr 7hr 1/2 hr 2hr 3 hr lhr 5-1/2 hr 1/2 hr 2 hr 2 hr 7-1/2 hr 1/2 hr lhr 14hr 3-1/2 hr 3-1/2 hr 1-1/2 hr 3-1/2 hr 5-1/2 hr 2 hr 9-1/2 hr 2hr 1-1/2 hr 1/2 hr 3-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 1/2 hr Activity Rig waited · Drill crews Rig moved 100.00 % Fill pits with Brine Retrieved Hanger plug Tested High pressure lines Circulated closed in well at 12538.0 ft Monitor wellbore pressures Rigged down Xmas tree Installed BOP stack Tested BOP stack Tested BOP stack Retrieved BOP test plug assembly Ran Drillpipe to 13249.0 ft (3-1/2in OD) Reverse circulated at 13295.0 ft Reverse circulated at 13295.0 ft Flow check Laid down 600.0 ft of Tubing Serviced Tubing Laid down 13000.0 ft of Tubing Held safety meeting Laid down 500.0 ft of Tubing Rigged up sub-surface equipment - Tubing Installed ESP Ran Tubing to 2262.4 ft (2-7/8in OD) Worked stuck pipe at 2262.4 ft Ran Tubing in stands to 2260.0 ft Conducted slickline operations on Slickline equipment - Tool run Installed ESP Ran Tubing to 6595.0 ft (2-7/8in OD) Serviced ESP Ran Tubing to 9262.0 ft (2-7/8in OD) Held safety meeting Ran Tubing to 13149.0 ft (2-7/8in OD) Installed Tubing hanger Removed BOP stack Installed Xmas tree Freeze protect well - 15.000 bbl of Diesel ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Milne Point Unit Well ..................... : MPF-80 API number ............... : 50-029-22928 Engineer ................. : J. Rathert 9ig: ..................... : Nabors 27E ~tate: ................... : Alaska Survey calculation methods ..... Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller's Pipe Tally GL above permanent ....... : 10.80 ft KB above permanent ....... : 43.25 ft DF above permanent ....... : 43.25 ft Vertical section origin- Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point '?atitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 254.60 degrees ORIGINAL 12-Nov-98 06:37:47 Spud date ................ : 28-Oct-98 Last survey date ......... : 12-Nov-98 Total accepted surveys...: 141 MD of first survey ....... : 112.00 ft MD of last survey ........ : 13408.22 ft Page 1 of 6 RECEIVED NOV 2 1998 BPXA PDC Geomagnetic data Magnetic model ........... : BGGM version Magnetic date ............ : 28-Oct-1998 Magnetic field strength..: 1145.69 HCNT Magnetic dec (+E/W-) ..... : 27.74 degrees!,,.2~,~.,~i~ Magnetic dip ............. : 80.74 degrees[ MWD survey Reference Criteria - Reference S .............. : 1003.00 mSal Reference H .............. : 1145.00 HCNT Reference Dip ............ : 80.74 degrees Tolerance of G ........... : (+/-) 4.00 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.30 degrees Corrections - Magnetic dec (+E/W-) ..... : 27.74 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.74 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)1998 Anadrill IDEAL ID5 iA 34R] _ -- ANADRILL SCHLUMBERGER Survey Report 12-Nov-98 06:37:47 Page 2 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 1 112.00 0.00 0.0 2 238.33 0.51 134.2 3 328.30 0.76 183.6 4 417.25 1.46 205.1 5 507.41 1.89 224.0 6 8 9 10 597.38 2.16 235.0 693.53 2.00 241.5 788.80 3.11 245.0 883.63 5.32 250.2 979.89 7.21 252.9 11 1075.39 9.27 253.3 12 1168.04 10.87 252.6 13 1261.52 12.81 255.0 14 1357.36 15.76 262.5 15 1452.47 16.69 263.6 16 1547.76 18.59 261.9 17 1641.64 20.20 265.6 18 1737.01 22.64 269.0 19 1833.09 23.49 269.4 20 1927.80 25.01 270.3 21 2023.12 26.82 268.0 ~ 22 2118.37 28.91 272.1 '~ 23 2213.85 29.22 271.0 24 2308.78 31.85 271.2 25 2403.70 34.94 270.2 26 2499.58 38.87 271.3 27 2594.92 38.98 271.5 28 2690.43 40.57 270.0 29 2783.14 42.63 268.5 30 2879.25 43.93 267.6 0.00 126.33 89.97 88.95 90.16 89.97 96.15 95.27 94.83 96.26 95.50 92.65 93.48 95.84 95.11 95.29 93.88 95.37 96.08 94.71 95.32 95.25 95.48 94.93 94.92 95.88 95.34 95.51 92.71 96.11 TVD depth (ft) 112.00 238.33 328.29 417.23 507.35 597.26 693.35 788.52 883.09 978.77 1073.28 1164.50 1255.99 1348.86 1440.18 1530.99 1619.54 1708.32 1796.72 1883.07 1968.81 2053.01 2136.47 2218.23 2297.47 2374.12 2448.29 2521.70 2591.02 2660.99 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- disp1 Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 0.00 -0.28 -0.29 0.64 2.66 5.54 8.88 13.04 19.96 30.45 44.13 60.33 79.50 103.02 129.31 157.89 188.65 222.60 259.02 296.55 336.87 379.74 424.10 470.34 520.54 575.82 633.17 691.86 751.41 815.49 0.00 0.00 -0.39 0.40 -1.27 0.65 -2.88 0.13 -4.99 -1.39 -7.03 -3.80 -8.87 -6.76 -10.76 -10.57 -13.33 -17.04 -16.62 -27.01 0.00 0.00 0.00 TIP 0.56 134.20 0.40 MWD 1.42 152.74 0.64 MWD M -- 2.88 177.32 0.90 MWD 5.18 195.51 0.77 MWD 7.99 208.42 11.16 217.32 15.08 224.49 21.63 231.95 31.71 238.39 0.52 0.30 1.18 2.36 1.99 -20.59 -40.11 45.08 242.82 2.16 -25.35 -55.59 61.10 245.49 1.73 -30.67 -74.01 80.12 247.49 2.14 -35.12 -97.19 103.34 250.13 3.63 -38.33 -123.57 129.37 252.77 1.03 -41.99 -152.20 157.89 254.58 -45.35 -183.18 188.71 256.10 -46.93 -217.96 222.95 257.85 -47.45 -255.60 259.96 259.48 -47.55 -294.49 298.31 260.83 2.07 2.16 2.87 0.90 1.65 -48.19 -336.14 -48.10 -380.63 -46.85 -427.00 -45.92 -475.21 -45.30 -527.45 339.58 261.84 2.17 383.66 262.80 2.98 429.56 263.74 0.65 477.43 264.48 2.77 529.39 265.09 3.31 -44.52 -585.00 586.69 265.65 4.16 -43.05 -644.89 646.32 266.18 0.18 -42.27 -705.98 707.25 266.57 1.94 -43.09 -767.52 768.73 266.79 2.47 -45.34 -833.37 834.60 266.89 1.50 MWD MWD MWD M -- MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 6-axis -- 6-axis 6-axis 6-axis 6-axis -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c) 1998 Anadrill IDEAL ID5 IA 34R] -- -- ANADRILL SCHLUMBERGER Survey Report 12-Nov-98 06:37:47 Page 3 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 31 2973.56 46.63 266.9 94.31 32 3066.68 47.84 266.5 93.12 33 3162.85 50.05 267.4 96.17 34 3256.73 51.73 266.7 93.88 35 3352.01 53.13 265.9 95.28 · 36 3448.71 54.77 264.5 96.70 ~? 37 3543.55 56.55 265.4 94.84 38 3639.17 58.19 266.2 95.62 39 3734.63 59.39 266.9 95.46 40 3830.13 61.28 267.4 95.50 TVD depth (ft) 2727.35 2790.58 2853.73 2912.95 2971.05 3027.95 3081.45 3133.01 3182.48 3229.74 41 3926.82 63.69 266.4 96.69 3274.41 42 4020.16 66.08 267.3 93.34 3314.02 43 4114.91 67.67 267.6 94.75 3351.23 44 4211.90 69.53 268.9 96.99 3386.62 45 4305.83 68.91 268.8 93.93 3419.95 Vertical Displ Displ Total At DLS Srvy section +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (ft) (deg) i00f) type 88O.87 947.71 1018.55 1089.68 1163.62 -48.56 -900.30 901.61 266.91 -52.50 -968.55 969.97 266.90 -56.35 -1040.96 1042.48 266.90 -60.10 -1113.70 1115.32 266.91 -64.98 -1189.06 1190.84 266.87 1240.47 -71.53 -1266.96 1268.98 266.77 1317.50 -78.42 -1344.96 1347.25 266.66 1396.49 -84.31 -1425.27 1427.76 266.61 1476.36 -89.22 -1506.77 1509.41 266.61 1557.36 -93.34 -1589.64 1592.38 266.64 1641.14 -97.99 -1675.26 1678.13 266.65 1723.72 -102.63 -1759.64 1762.63 266.66 1808.67 -106.50 -1846.69 1849.76 266.70 1896.41 -109.25 -1936.95 1940.03 266.77 1981.53 -111.01 -2024.75 2027.79 266.86 46 4402.25 69.02 268.1 96.42 3454.55 2068.91 -113.45 -2114.71 47 4496.30 68.75 268.4 94.05 3488.43 2154.17 -116.13 -2202.40 48 4590.94 70.94 266.9 94.64 3521.04 2240.71 -119.78 -2291.17 49 4685.66 70.64 267.7 94.72 3552.21 2327.97 -123.99 -2380.51 50 4781.38 70.71 267.4 95.72 3583.89 2416.00 -127.85 -2470.75 51 4877.17 70.61 267.3 95.79 3615.61 2504.15 -132.03 -2561.04 52 4972.69 70.80 267.5 95.52 3647.17 2592.07 -136.12 -2651.10 53 5068.27 70.64 267.8 95.58 3678.73 2679.96 -139.82 -2741.25 54 5162.96 71.67 265.9 94.69 3709.32 2767.52 -144.75 -2830.72 55 5259.10 70.65 268.0 96.14 3740.37 2856.40 -149.60 -2921.57 56 5353.65 68.82 268.8 94.55 3773.12 2942.53 -152.08 -3010.23 57 5448.84 70.64 267.5 95.19 3806.09 3029.34 -154.97 -3099.47 58 5543.70 70.89 268.1 94.86 3837.34 3116.54 -158.40 -3188.97 59 5692.21 68.85 267.7 148.51 3888.45 3252.23 -163.51 -3328.31 60 5784.21 68.03 268.8 92.00 3922.26 3335.37 -166.12 -3413.83 2117.75 266.93 2205.46 266.98 2294.29 267.01 2383.74 267.02 2474.06 267.04 2564.44 267.05 2654 . 60 267 . 06 2744.81 267.08 2834.42 267.07 2925.40 267.07 2.91 1.34 2.40 1.88 1.61 2.06 2.03 1.85 1.40 2.03 2.66 2.71 1.70 2.29 0.67 0.69 0.41 2.75 0.86 0.30 0.14 0.28 0.34 2.19 2.32 3014.07 267.11 2.09 3103.34 267.14 2.30 3192.90 267.16 0.65 3332.32 267.19 1.40 3417.87 267.21 1.43 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [ c)1998 Anadrill IDEAL ID5 IA 34R] -- -- ANADRILL SCHLUMBERGER Survey Report 12-Nov-98 06:37:47 Page 4 of 6 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) (deg) (deg) (ft) 61 5877.50 68.96 268.4 62 5970.82 71.47 268 . 0 63 6064.68 72.36 265.1 64 6159.94 72 . 61 261.7 65 6254 . 53 73.49 259.8 66 6347.09 73.70 259.9 ji' 67 6438.97 72.95 259.1 68 6534.95 72.00 258.0 69 6628.58 73.35 255.8 70 6722.84 73.37 255.5 71 6817.30 72.84 254.7 72 6911.70 74.22 254.5 73 7005.82 73.14 253.2 74 7100.84 74.68 253.1 75 7195.46 74.27 253.0 76 7289.39 74.00 252.6 77 7384.92 73.56 252.5 78 7478.75 74.62 251.7 79 7572.51 74.12 250.8 80 7667.07 75.64 249.8 81 7761.76 75.13 249.1 ~i~182 7857.09 74.51 249.0 ?83 7950.23 75.77 248.7 84 8046.18 75.33 248.3 85 8140.37 74.74 248.4 86 8235.74 76.33 246.3 87 8332.00 75.77 246.9 88 8427.54 75.43 246.4 89 8521.45 74.98 245.3 90 8615.74 74.69 245.4 TVD depth Vertical Displ Displ Total At DLS Srvy section +N/S- +E/W- displ Azim (deg/ tool (ft) (ft) (ft) (ft) (deg) I00f) type 93.29 3956.46 3419.59 -168.25 -3500.60 3504.64 267.25 93.32 3988.04 3504.93 -171.01 -3588.36 3592.43 267.27 93.86 4017.19 3592.21 -176.38 -3677.41 3681.63 267.25 95.26 4045.86 3681.97 -186.82 -3767.63 3772.26 267.16 94.59 4073.44 3771.92 -201.37 -3856.93 3862.18 267.01 92.56 4099.58 3860.34 -217.02 -3944.33 3950.30 266.85 91.88 4125.95 3948.04 -233.05 -4030.87 4037.61 266.69 95.98 4154.85 4039.34 -251.22 -4120.58 4128.23 266.51 93.63 4182.73 4128.64 -271.48 -4207.62 4216.37 266.31 94.26 4209.73 4218.94 -293.87 -4295.12 4305.16 266.09 94.46 4237.18 4309.32 -317.11 -4382.46 4393.92 265.86 94.40 4263.94 4399.84 -341.15 -4469.73 4482.73 265.64 94.12 4290.39 4490.16 -366.27 -4556.49 4571.19 265.40 95.02 4316.72 4581.43 -392.73 -4643.87 4660.45 265.17 94.62 4342.05 4672.56 -419.31 -4731.08 4749.62 264.94 93.93 95.53 93.83 93.76 94.56 94.69 95.33 93.14 95.95 94.19 4367.73 4762.87 -446.03 -4817.39 4837.99 264.71 4394.41 4854.54 -473.53 -4904.89 4927.70 264.49 4420.13 4944.68 -501.27 -4990.76 5015.87 264.26 4445.39 5034.82 -530.29 -5076.26 5103.88 264.04 4470.06 5125.85 -561.06 -5162.20 5192.60 263.80 4493.95 4518.91 4542.80 4566.74 4591.07 4614.89 4638.10 4661.86 4685.84 4710.50 95.37 96.26 95.54 93.91 94.29 5217.10 -593.23 -5247.99 5281.42 263.55 5308.67 -626.12 -5333.92 5370.54 263.31 5398.24 -658.60 -5417.87 5457.76 263.07 5490.63 -692.66 -5504.32 5547.73 262.83 5581.09 -726.23 -5588.90 5635.89 262.60 5672.69 -761.79 -5674.11 5725.02 262.35 5765.20 -798.90 -5759.85 5814.99 262.10 5856.85 -835.57 -5844.81 5904.23 261.86 5946.58 -872.72 -5927.66 5991.56 261.62 6036.41 -910.68 -6010.37 6078.97 261.38 1.07 2.72 3.09 3.41 2.13 0.25 1.17 1.47 2.67 0.31 0.99 1.48 1.75 1.62 0.45 0.50 0.47 1.40 1.07 1.90 0.90 0.66 1.39 0.61 0.63 2.71 0.84 0.62 1.23 0.32 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1998 Anadrill IDEAL ID5 iA 34R] -- __ ANADRILL SCHLUMBERGER Survey Report 12-Nov-98 06:37:47 Page 5 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 8708.46 73.92 244.4 92 8804.39 73.14 244.1 93 8900.57 75.07 244.7 94 8997.08 74.60 244.5 95 9090.02 76.55 244.1 .... 96 9184.34 76.31 244.4 ,/ 97 9280.02 76.14 244.2 98 9391.84 76.07 245.0 99 9486.20 76.29 244.1 100 9577.45 76.19 244.5 101 9671.13 75.98 243.7 102 9767.04 75.58 245.0 103 9862.10 75.49 245.5 104 9958.95 75.54 245.5 105 10052.63 75.19 245.2 106 10147.25 74.52 246.0 107 10241.50 74.22 245.5 108 10336.15 73.71 245.5 109 10432.64 73.75 245.5 110 10528.09 73.32 245.5 111 10623.60 73.57 245.9 ~12 10718.63 67.36 245.7 113 10813.56 64.28 242.8 114 10907.67 60.61 238.5 115 11003.62 60.52 238.4 116 11099.04 60.06 239.0 117 11193.16 59.36 238.4 118 11287.58 58.82 238.5 119 11381.96 57.37 237.8 120 11476.33 56.54 238.4 92.72 95.93 96.18 96.51 92.94 94.32 95.68 111.82 94.36 91.25 93.68 95.91 95.06 96.85 93.68 94.62 94.25 94.65 96.49 95.45 95.51 95.03 94 · 93 94.11 95.95 95.42 94.12 94.42 94.38 94.37 TVD depth Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) i00f) type type 4735.59 6124.39 -948 4762.78 6214.89 -988 4789.12 6305.92 -1028 4814.37 6397.66 -1068 4837.52 6486.21 -1107 4859.65 4882.43 4909.29 4931.83 4953.53 4976.06 4999.62 5023.37 5047.59 5071.26 5095.98 5121.38 5147.52 5174.55 5201.61 5228.82 5260.58 5299.47 5343.01 5390.17 5437.46 5484.93 5533.43 5583.31 5634.77 .54 -6091.20 6164.62 261.15 .50 -6174.06 6252.69 260.90 .47 -6257.48 6341.44 260.67 .42 -6341.63 6431.00 260.44 .46 -6422.73 6517.50 260.22 6576.41 -1147 6667.84 -1187 6774.74 -1234 6864.96 -1273 6952.16 -1311 .29 -6505.31 6605.70 260.00 .59 -6589.04 6695.21 259.78 .15 -6687.10 6800.03 259.54 .52 -6769.83 6888.58 259.35 .96 -6849.70 6974.21 259.16 7041.57 -1351 7133.05 -1391 7223.87 -1430 7316.47 -1469 7405.93 -1507 .68 -6931.49 7062.06 258.97 .92 -7015.30 7152.05 258.78 .46 -7098.89 7241.58 258.61 .34 -7184.22 7332.94 258.44 .15 -7266.60 7421.25 258.28 7496.14 -1544.88 -7349.77 7510.38 258.13 7585.82 -1582.16 -7432.53 7599.06 257.98 7675.64 -1619.88 -7515.31 7687.90 257.84 7767.10 -1658.29 -7599.59 7778.41 257.69 7857.48 -1696.25 -7682.89 7867.91 257.55 7947.93 -1733 8036.40 -1770 8121.57 -1808 8202.52 -1849 8282.78 -1892 .92 -7766.33 7957.53 257.41 .62 -7847.98 8045.24 257.29 .21 -7925.97 8129.61 257.15 .03 -7998.68 8209.62 256.98 .76 -8069.90 8288.89 256.80 8362.49 -1935.82 -8140.71 8367.71 256.62 8440.65 -1978.04 -8210.15 8445.07 256.45 8518.46 -2020.42 -8279.19 8522.15 256.29 8595.30 -2062.70 -8347.24 8598.33 256.12 8671.15 -2104.50 -8414.40 8673.58 255.96 1.33 0.87 2.09 0.53 2.14 0.40 0.27 0.70 0.96 0.44 0.86 1.38 0.52 0.05 0.49 1.08 0.60 0.54 0.04 0.45 0.48 6.54 4.28 5.62 0.13 0.73 0.93 0.58 1.66 1.03 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD M MWD 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis -- 6-axis [(c)1998 Anadrill IDEAL ID5 iA 34R] ANADRILL SCHLUMBERGER Survey Report 12-Nov-98 06:37:47 Page 6 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 121 11571.56 55.25 240.3 122 11666.'78 48.54 243.9 123 11762.56 45.13 246.8 124 11858.34 42.36 248.1 125 11953.25 41.37 248.9 126 12049.54 40.94 249.0 127 12145.52 40.53 248.8 128 12240.09 39.36 250.0 129 12335.77 36.52 248.1 130 12430.45 34.02 246.1 131 12526.30 32.37 241.8 132 12621.71 30.61 238.3 133 12715.45 30.18 236.8 134 12811.00 29.24 235.1 135 12905.26 28.45 237.1 136 13001.23 27.85 236.8 137 13096.10 27.71 237.1 138 13191.69 26.85 237.2 139 13286.95 26.08 236.9 140 13332.10 25.76 237.8 Survey Projected to TD: 't,141 13408.22 25.76 237.8 95.23 95.22 95.78 95.78 94.91 96.29 95.98 94.57 95.68 94.68 95.85 95.41 93.74 95.55 94.26 95.97 94.87 95.59 95.26 45.15 76.12 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) lOOf) 5688.17 5746.91 5812.43 5881.62 5952.30 6024.80 6097.52 6170.03 6245.48 6322.78 6403.00 6484.36 6565.22 6648.21 6730.77 6815.39 6899.32 6984.28 7069.56 7110.17 7178.72 8747.21 -2144.70 -8482.22 8749.17 255.81 8820.28 -2179.83 -8548.33 8821.89 255.69 8889.20 -2209.00 -8611.79 8890.59 255.61 8954.90 -2234.41 -8672.93 8956.14 255.55 9017.88 -2257.63 -8731.87 9019.00 255.50 9080.94 -2280.39 -8791.00 9081.96 255.46 9143.26 -2302.94 -8849.44 9144.18 255.41 9203.73 -2324.31 -8906.27 9204.57 255.37 9262.27 -2345.31 -8961.21 9263.03 255.33 9316.47 -2366.55 -9011.57 9317.13 255.29 9368.02 -2389.54 -9058.71 9368.57 255.22 9416.25 -2414.38 -9101.89 9416.67 255.14 9461.59 -2439.83 -9141.92 9461.89 255.06 9506.46 -2466.33 -9181.15 9506.65 254.96 9549.57 -2491.70 -9218.89 9549.68 254.88 9592.72 -2516.39 -9256.84 9592.77 254.79 9634.85 -2540.50 -9293.90 9634.87 254.71 9676.65 -2564.27 -9330.71 9676.65 254.63 9717.13 -2587.36 -9366.33 9717.13 254.56 9735.97 -2598.01 -9382.95 9735.98 254.52 9767.64 -2615.64 -9410.94 2.14 7.65 4.19 3.04 1.19 0.45 0.45 1.48 3.21 2.91 3.00 2.66 0.93 1.32 1.32 0.64 0.21 0.90 0.82 1.12 9767 . 67 254 . 47 0.00 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis Proj. [(c)1998 Anadrill IDEAL ID5 iA 34R] -- -- gyrold ORIGINAL RECEIVED DEC 1 8 1998 BPXA PDO B.P. EXPLORATION F PAD, WELL NO. MPF-80 MILNE POINT FIELD, ALASKA Gyro Continuous Multishot Survey Inside 4.5" TUBING Survey date · 19 - NOVEMBER, 1998 Job number · AK1198GCE510 CONTENTS JOB NUMBER: AK1198GCE510 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT II 1. DISCUSSION, SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER ' AK1198GCE510 Tool 777 was run in WELL# MPF-80 on SCHLUMBERGER 15/32" wireline inside 4.5" TUBING. The survey was completed without any problems. SURVEY CERTIFICATION SHEET JOB NUMBER · AK1198GCE510 The data for this survey and the Calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :~ ., JACK E. MAY OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK1198GCE510 CLIENT: B.P. EXPLORATION RIG: SCHLUMBERGER LOCATION: F PAD WELL: MPF-80 LATITUDE: 70.505 N LONGITUDE: 149.40 W SURVEY DATE: SURVEY TYPE : 19 - NOVEMBER, 1998 GYRO CONTINUOUS MULTISHOT DEPTH REFERENCE: ROTARY TABLE ELEVATION 43.8 MAX. SURVEY DEPTH: 12300' SURVEY TIED ONTO: N/A SURVEY INTERVAL: APl NUMBER: TARGET DIRECTION: 0-12300' 050-029-2292800 254.60 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. OUTRUN SURVEY LISTING A Gy r o d a t a D i r e c t i o n a i S u r v e y for B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AKl198GCES10 Run Date: 19-Nov-98 00:15:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from VerticalS' Reference: 43.8 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 254.600 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location I{orizontal Coordinates Calculated from Local Horizontal Reference A G y r o d a t a B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: P PAD, MILNE POINT FIELD, ALASKA Job Number: AKl198GCE510 D i r e c t i o n a 1 Survey Page MEASURED I N C L AZIMUTH DOGLEG VERTICAL DEPTH SEVERITY DEPTH feet deg. deg. deg./ feet 100 ft. SUBSEA VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 0.0 0.00 0.00 0.00 0.0 100.0 .35 130.96 .35 100.0 200.0 .41 133.64 .06 200.0 300.0 .50 183.21 .39 300.0 400.0 1.16 208.79 .74 400.0 -43.8 0.0 0.0 0.0 56.2 -.2 .3 131.0 156.2 -.5 1.0 132.0 256.2 -.6 1.6 144.5 356.2 .3 2.7 170.7 0.0 N 0.0 E .2 S .2 E .6 S .7 E 1.3 S 9 E 2.6 S .4 E 500.0 1.67 223.35 .62 500.0 600.0 ]..85 224.08 .19 599.9 700.0 2.16 223.64 .30 699.8 800.0 3.07 228.86 .94 799.7 900.0 5.29 245.52 2.51 899.5 456 556 656 755 855 .2 .1 .0 .9 .7 2.2 4.9 7.9 11.9 18.9 4.7 192.9 7.5 205.0 10.9 211.0 15.3 215.6 22.1 223.2 4.6 S 1.1 W 6.8 S 3.2 W 9.3 S 5.6 W 12.5 S 8.9 W 16.1 S 15.1 W 1000.0 7.30 250.85 2.09 998.9 1100.0 9.21 251.79 1.91 1097.8 1200.0 11.01 252.19 ]..81 1196.3 ].300.0 13.31 255.24 2.39 ].294.0 1.350.0 ].4.79 259.45 3.58 134.2.5 955 1054 ].152 1250 1298 .1 .0 .5 .2 .7 29.8 44.1 61.6 82.7 94.8 32 .3 231.5 46.1 237.6 63 .3 241.6 84.0 244 .6 95.8 246.2 20.1 S 25.3 W 24.7 S 38.9 W 30.1 S 55.6 W 36 . 0 S 75.9 W 38.6 S 87.7 W 1400.0 ].6.41 261.81 3.49 1390.7 1450.0 ].6.81 262.27 .84 1438.6 1500.0 17.22 262.01 .83 1486.4 ].550.0 ].8.50 261.64 2.58 1534.0 ].600.0 19.03 261.97 1.07 1581.3 ].346 1394 1442 1490 1537 .9 .8 .6 .2 .5 108 .2 122 .3 136.8 152 .1 168.0 108.9 248.0 122.8 249.6 ].37.1 250.9 ].52.2 252.0 168.1 253.0 40.8 S 101.0 W 42.8 S 11.5.1 W 44.8 S 129.6 W 47.0 S 144.8 W 49.2 S ]_60.7 W ].650.0 20.26 264.66 3.05 1628.4 1700.0 21.59 267.22 3.23 1675.1 1750.0 22.66 268.54 2.37 1721.4 1800.0 23.09 268.51 .87 1767.5 1850.0 23.55 268.45 .91 18].3.4 1584.6 1631.3 1677.6 1723.7 1769.6 184.6 202.1 220.4 239.3 258.5 184.6 253.9 202.1 255.0 220.5 256.1. 239.5 257.]. 259.0 257.9 5]..2 S 177.4 W 52.4 S 195.2 W 53.1. S 21.4.0 W 53.6 S 233.5 W 54.2 S 253.2 W A G y r o d a t a D i r e c t i o n a i S u r v e y B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, Job Number: AKl198GCE510 ALASKA Page 2 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL CLOSURE DEPTH DEPTH SECTION DIST. AZIMUTH feet feet feet feet deg. HORIZONTAL COORDINATES feet 1900.0 24.09 268.57 1.08 1950.0 25.30 268.62 2.43 2000.0 26.19 268.17 1.82 2050.0 27.40 267.61 2.47 2100.0 28.29 268.70 2.05 1859.2 1904.6 1949.6 1994.3 2038.5 1815.4 1860.8 1905.8 1950.5 ].994.7 278.1 298.4 319.5 341.4 364.1 278.8 258.7 299.4 259.4 320.9 260.0 343.3 260.5 366.4 261.0 54.7 S 273.4 W 55.2 S 294.3 W 55.8 S 316.0 W 56.6 S 338.5 57.4 S 36]..9 W 2150.0 29.05 270.84 2.55 2200.0 29.23 270.71 .38 2250.0 29.63 270.52 .82 2300.0 31.10 271.17 3.02 2350.0 32.82 271.43 3.44 2082 .3 2126.0 2169.6 2212 .7 2255.1 2038.5 2082.2 2125.8 2168.9 2211.3 387.3 410.7 434 .3 458.5 483 .9 390.1 261.5 414.2 262.1 438.5 262.5 463.5 263.0 489.7 263.4 57.5 S 385.9 W 57.2 S 410.2 W 56.9 S 434.8 W 56.5 S 460.1 W 55.9 S 486.5 W 2400.0 34.30 271.09 2.98 2450.0 36.43 270.98 4.27 2500.0 38.42 271.03 3.98 2550.0 39.18 270.89 1.54 2600.0 39.33 2r70.'73 .36 2296.8 2337.6 2377.3 243.,6.2 2454.9 2253.0 2293.8 2333.5 2372.4 24].1.1 510 .4 538.1 567.3 597 .3 627 .7 517.1 263.9 545.8 264.2 576.0 264.6 607.2 264.9 638.7 265.2 55.3 S 514.1 W 54.8 S 543.1 W 54.2 S 573.5 W 53.7 S 604.8 W 53.3 S 636.4 W 2650.0 39.61 270.47 .64 2700.0 40.54 269.37 2.35 2750.0 41.30 268.68 1.77 2800.0 42.57 268.06 2.66 2850.0 43.30 267.54 1.64 2493.5 2531.8 2569.6 2606.8 2643.4 2449.7 2488.0 2525.8 2563.0 2599.6 658 .3 689.3 721.0 753 .5 786 .7 670.3 265.5 702.4 265.7 735.1 265.8 768.5 265.9 802.5 266.0 52.9 S 668.2 W 53.0 S 700.4 W 53.6 S 733.1 W ' 54.5 S 766.5 W 55.8 S 800.6 W 2900.0 44.02 267.37 1.46 2950.0 45.16 267.41 2.2'-} 3000.0 46.82 267.65 3.33 3050.0 47.56 267.48 1.51 3].00.0 48.05 267.20 1.06 2679.5 2715.2 2749.9 2783.9 2817.5 2635.7 2671.4 2706.1 2740.1 2773.7 820.3 854.5 889.6 925.3 961.5 837.0 266.1 872.1 266.1 908.1 266.2 944.7 266.2 981.8 266.3 57.3 S 835.1. W 58.9 S 8'70.]. W 60.5 S 906.1 W 62.0 S 942.7 W 63.8 S 9'79.7 W A Gy r o d a t a D i r e c t i o n a i S u rv e y B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, Job Number: AKl198GCE510 ALASKA Page 3 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 3150.0 49.16 267.08 3200.0 50.33 266.88 3250.0 51.31 266.40 3300.0 52.02 266.16 3350.0 52.92 266.01 2 .23 2 .35 2 .09 1.47 1.82 2850.5 2882.8 2914 .4 2945.4 2975.9 2806.7 2839.0 2870.6 2901.6 2932.1 998.1 1019.3 266.3 1035.3 1057.4 266.3 1073.3 1096.2 266.3 1111.7 1135.4 266.3 1150.5 1175.1 266.3 65.6 S 1017.2 W 67.6 S 1055.3 W 69.9 S 1094.0 W 72.5 S 1133.1 W 75.2 S 1172.7 W 3400.0 53.56 265.69 3450.0 54.46 265.18 3500.0 55.1]. 265.06 3550.0 56.36 265.15 3600.0 57.07 265.43 1 .37 1.98 1.32 2 .51 1.49 3005.8 3035.2 3064.0 3092.2 3119.6 2962.0 2991.4 3020.2 3048.4 3075.8 1189.8 1215.1 266.3 1229.5 1.255.6 266.3 ].269.7 1296.4 266.3 13]_0.3 1337.7 266.2 1351.4 1379.5 266.2 78.1 S 12].2.6 W 81.3 S 1252.9 W 84.8 S 1293.6 W 88.3 S 1334.8 W 91.7 S 1376.5 W 3650.0 58.14 265.85 3700.0 58.65 266.43 3750.0 59.30 267.].0 3800.0 59.84 267.49 3850.0 61.49 267.54 2.26 i .41 1.74 1.27 3 .29 3146.4 3172.6 3198.4 3223.7 3248.2 3102.6 1392.8 1421.7 266.2 3128.8 1434.6 ].464.3 266.2. 3154.6 1476.4 1507.2 266.2 3179.9 1518.5 1550.3 266.2 3204.4 1561.0 1593.8 266.3 94.9 S 1418.6 W 97.8 S 146]..0 W 100.2 S 1503.8 W 102.3 S ].546.9 W ].04.1 S 1590.4 W 3900.0 62.57 267.58 3950.0 63.81. 267.48 4000.0 65.06 267.71 4050.0 66.44 267.92 41.00.0 67.24 268.23 2.17 2 .50 2.53 2 .78 1 .70 3271.6 3294.2 33].5.8 3336.3 3356.0 3227.8 3250.4 3272.0 3292.5 3312.2 1604.0 1647.5 1691.5 1735.8 ].780.5 1638.0 266.3 1682.6 266.3 1727.7 266.4 1773.3 266.4 1.819.2 266.4 106.0 S 1634.6 W 107.9 S 1679.3. W .~ 109.8 S 1724.2 W -~ 111.6 S 1769.8 W 113.1 S 1815.7 W 4150.0 67.77 268.57 4200.0 68.75 268.88 4250.0 69.76 268.91 4300.0 69.34 268.98 4350.0 69.38 268.89 1.24 2.04 2.02 .85 .19 3375.]. 3393.6 341]..3 3428.8 3446.4 3331.3 3349.8 3367.5 3385.0 3402.6 ].825.4 1870.4 ].915.8 1961.1 2006.5 1865.4 266.5 1911.8 266.5 1958.5 '266.6 2005.3 266.6 2052.1 266.7 114.4 S ].86]..9 W 115.4 S ].908.3 W 116.3 S 1955.1 W 117.2 S 2001.9 W 118.1 S 2048.7 W A G y r o d a t a D i r e c t i o n a i S u r v e y B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, Job Number: AKl198GCE510 ALASKA Page 4 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 4400.0 69.41 268.89 4450.0 69.14 268.83 4500.0 69.29 268.80 4550.0 69.66 268.50 4600.0 71.00 268.07 .O7 .55 .31 .92 2.80 3464.0 3481.7 3499.5 3517.0 3533.8 3420.2 3437.9 3455.7 3473.2 3490.0 2051.8 2097.2 2142.5 2187.9 2233.6 2098.8 266.8 2145.6 266.8 2192.3 266.8 2239.1 266.9 2286.2 266.9 119.0 S 2095.5 W 119.9 S 2142.2 W 120.9 S 2189.0 W 122.0 S 2235.8 W i~ 123.4 S 2282.8 W 4650.0 71.22 267.99 4700.0 71.12 267.96 4750.0 70.92 267.89 4800.0 70.87 267.78 4850.0 70.88 267.71 .47 .20 .43 .24 .13 3550.0 3566.1 3582.4 3598.8 3615.1 3506 3522 3538 3555 3571 .2 .3 .6 .0 .3 2279.7 2325.7 2371.7 2417.7 2463.7 2333.5 266.9 2380.8 266.9 2428.1 267.0 2475.3 267.0 2522.5 267.0 125.0 S 2330.1 W 126.7 S 2377.4 W 128.4 S 2424.7 W 130.2 S 2471.9 W 132.0 S 2519.]. W 4900.0 71.11 267.68 4950.0 71..38 267.67 5000.0 71.06 267.71. 5050.0 70.90 267.65 5100.0 71.06 267.67 .45 .55 .64 ' .34 .34 3631.4 3647.5 3663.6 3679.9 3696.2 3587 3603 3619 3636 3652 .6 .7 .8 .1 .4 2509.7 2555.9 2602.0 2648.0 2694.1 2569.8 267.0 2617.2 267.0 2664.5 267.0 2711.8 267.0 2759.0 267.1 134.0 S 2566.3 W 135.9 S 2613.6 W 137.8 S 2660.9 W 139.7 S 2708.2 W 141.6 S 2755.4 W 5150.0 71..57 267.08 5200.0 72.02 266.92 5250.0 71.38 267.25 5300.0 69.64 268.02 5350.0 69.25 268.61 1.51 .94 1.42 3 .78 1.34 3712.2 3727.8 3743.5 3760.2 3777.8 3668 3684 3699 3716 3734 .4 .0 .7 .4 .0 2740.3 2786.6 2833.0 2878.9 2924.4 2806.4 267.1 2853.9 267.1 2901.4 267.1 2948.5 267.1 2995.3 267.1 143.8 S 2802.7 W 146.3 S 2850.1 148.7 S 2897.5 W 150.6 S 2944.6 W 152.0 S 2991.4 W 5400.0 68.95 269.01 5450.0 70.34 268.68 5500.0 71.1.6 268.20 5550.0 70.81 268.46 5600.0 69.62 268.59 .97 2.84 1.88 .86 2.38 3'795.6 3813.0 3829.5 3845.8 3862.7 3751 3769 3785 3802 3818 .8 .2 .7 .0 .9 2969.7 3015.1 3060.9 3106.9 3152.5 3042.0 267.1 3088.8 267.1 3136.0 26'7.2 3183.3 267.2 3230.3 267.2 153.0 S 3038.1 W 153.9 S 3085.0 W 155.2 S 3132.2 W 1.56.6 S 31.79.4 W 157.8 S 3226.5 W A Gy r o d a t a D i r e c t i o n a 1 S u r ve y B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, Job Number: AKl198GCE510 ALASKA Page 5 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 5650.0 69.46 268.57 5700.0 69.25 268.29 5750.0 68.90 268.04 5800.0 68.37 268.15 5850.0 68.08 268.41 .33 .67 .84 1.08 .75 3880.2 3897.8 3915.7 3933.9 3952.4 3836.4 3854.0 3871.9 3890.1 3908.6 3198.0 3243.4 3288.8 3334.1 3379.2 3277.2 267.2 3323.9 267.2 3370.6 267.2 3417.2 267.3 3463.6 267.3 159.0 S 3273.3 W 160.2 S 3320.1 W 161.7 S 3366.7 W 163.3 S 3413.3 W ~i 164.7 S 3459.7 W 5900.0 69.51 268.74 5950.0 70.16 268.57 6000.0 71.63 267.96 6050.0 71.39 266.02 6100.0 72.03. 264.66 2.92 1.33 3.16 3.71 2.87 3970.5 3987.7 4004.1 4020.0 4035.7 3926.7 3943.9 3960.3 3976.2 3991.9 3424.4 3510.2 267.3 3470.0 3557.1 267.3 3515.9 3604.4 267.3 3562.2 3651.8 267.3 3608.8 3699.2 267.3 165.8 S 3506.3 W 166.9 S 3553.2 W ].68.4 S 3600.4 W 170.9 S 3647.8 W 174.7 S 3695.1 W 6150.0 72.37 263.51 6200.0 72.97 262.68 6250.0 73.71 261.11 6300.0 73.45 259.88 6350.0 73.22 259.84 2 .30 1.99 3 .35 2 .41 .47 4051.0 4065.9 4080.2 4094.3 4108.7 4007.2 3655.8 3746.8 267.3 4022.1 3703.0 3794.4 267.2 4036.4 3750.5 3842.1 267.1 4050.5 3798.2 3889.7 267.1 4064.9 3845.9 3937.2 267.0 179.6 S 3742.4 W 185.4 S 3789.8 W 192.1 S 3837.3 W 200.0 S 3884.6 W 208.5 S 3931.7 W 6400.0 73.02 259.43 6450.0 73.05 259.20 6500.0 72.42 258.84 6550.0 72.63 258.48 6600.0 71.89 257.70 .89 .43 1.43 .82 2.09 4].23.2 4137.8 4152.6 4].67.6 4182 . 9 4079.4 3893.6 3984.7 266.9 4094.0 3941.2 4032.1 266.8 4108.8 3988.8 4079.4 266.7 4123.8 4036.4 4126.6 266.6 4139.1 4083.9 4173.8 266.5 2].7.]. S 3978.8 W 225.9 S 4025.8 W r 235.0 S 4072.6 W''~ 244.4 S 4].19'.4 W 254.2 S 4166.0 W 6650.0 73.58 256.49 6700.0 72.92 255.91 6750.0 73.14 255.47 6800.0 73.09 255.11 6850.0 73.32 254.81 4.09 1...72 .94 .70 .75 4197.7 4212.1 4226.7 4241.2 4255.7 4153.9 4131.6 4220.9 266.4 4168.3 4179.5 4268.0 266.3 4182.9 4227.3 4315.0 266.2 4197.4 4275.1 4362.0 266.]. 4211.9 4323.0 4409.0 265.9 264.9 S 4212.5 W 276.3 S 4259.0 W 288.1 S 4305.4 W 300.3 S 4351.6 W 312.7 S 4397.9 W A G y r o d a t a D i r e c t i o n a i S u r v e y B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, Job Number: AKl198GCE510 ALASKA MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL DEPTH feet 6900.0 73.26 254.32 .95 6950.0 73.48 253.99 .78 7000.0 73.48 253.72 .52 7050.0 73.65 253.54 .47 7100.0 73.80 253.39 .43 4270.0 4284 .4 4298.6 4312 .7 4326.7 7150.0 74.41 253.38 1.22 7200.0 74.24 253.24 .43 7250.0 74.13 253.12 .33 7300.0 74.44 252.97 .70 7350.0 73.88 252.72 1.23 4340.4 4353.9 4367.6 4381.1 4394.8 7400.0 73.62 252.49 .67 7450.0 74.40 252.07 1.76 7500.0 74.71 251.52 1.24 7550.0 74.24 251.15 1.17 7600.0 74.99 250.30 2.21 4408.7 4422.5 4435.8 4449.2 4462.5 7650.0 75.66 249.78 1.68 7700.0 75.59 249.70 .21 7750.0 75.48 249.58 .33 7800.0 74.87 249.46 1.24 7850.0 74.94 249.31 .32 4475.1 4487.6 4500.0 4512.8 4525.9 7900.0 74.24 248.96 1..55 7950.0 75.59 248.81 2.73 8000.0 75.83 248.57 .66 8050.0 75.40 248.36 .95 8100.0 75.03 248.15 .84 4539.2 4552 .2 4564.5 4576.9 4589.7 Page 6 SUBSEA DEPTH feet VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet 4226.2 4240.6 4254.8 4268.9 4282.9 4296.6 4310.1 4323.8 4337.3 4351.0 4364.9 4378.7 4392.0 4405.4 4418.'7 443]..3 4443.8 4456.2 4469.0 4482.1 4495.4 4508.4 4520.7 4533 .1 4545.9 4370.9 4418.8 4466.7 4514.7 4562.7 4610.8 4658.9 4707.0 4755.1 4803.2 4851.1 4899.2 4947.3 4995.4 5043.5 5091.7 5140.0 5188.2 5236.4 5284.4 5332.4 5380.4 5428.6 5476.8 5524.8 4455.9 265.8 4502.9 265.7 4549.8 265.6 4596.7 265.4 4643.7 265.3 4690.7 265.2 4737.9 265.1 4785.0 265.0 4832.1 264.8 4879.1 264.7 4926.1 264.6 4973.0 264.5 5020.1 264.4 5067.0 264.2 5113.9 264.1 5160.8 264.0 5207.8 263.9 5254.7 263.7 5301.6 263.6 5348.4 263.5 5395.1 263.3 5441.9 263.2 5488.8 263.1 5535.7 263.0 5582.4 262.8 325.5 S 4444.0 W 338.5 S 4490.1 W 351.9 S 4536.2 W 365.4 S 4582.2 W 379.1 S 4628.2 W 392.8 S 4674.3 W 406.6 S 4720.4 W 420.5 S 4766.4 W 434.6 S 4812.5 W 448.8 S 4858.4 W 463.1 S 4904.2 W 477.7 S 4950.0 W 492.8 S 4995.8 W 508.2 S 5041.5 W 524.1 S 5087.0 W 540.6 S 5132.4 W 557.4 S 5177.9 W~' 574.3 S 5223.2 W 591.2 S 5268.5 W 608.2 S 5313.7 W 625.3 S 5358.8 W 642.7 S 5403.8 W 660.3 S 5448.9 W 678.1 S 5494.0 W 696.0 S 5538.9 W A G y r o d a t a D i r e c t i o n a i S u r v e y 3.P. EXPLORATION ~ELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, lob Number: AKl198GCE510 ALASKA Page ~EASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 8150.0 74.93 247.95 8200.0 74.97 247.52 8250.0 75.98 246.98 8300.0 76.10 246.52 8350.0 75.88 246.36 .45 .83 2.27 .92 .54 4602.6 4615.6 4628.2 4640.2 4652.3 4558.8 4571.8 4584 .4 4596.4 4608.5 5572.8 5629.1 262.7 5620.8 5675.8 262.6 5668.8 5722.5 262.5 5716.8 5769.2 262.3 5764.9 5815.9 262.2 714.1 S 5583.7 W 732.4 S 5628.4 W 751.1 S 5673.0 W 770.3 S 5717.6 W 789.6 S 5762.0 W 8400.0 75.80 246.16 8450.0 75.51 245.93 8500.0 75.18 245.72 8550.0 75.00 245.46 8600.0 74.92 245.19 .42 .73 .79 .61 .55 4664.6 4677.0 4689.6 4702.5 4715.5 4620.8 5812.8 5862.5 262.1 4633.2 5860.7 5909.1 261.9 4645.8 5908.5 5955.6 261.8 4658.7 5956.2 6002.0 261.7 4671.7 6003.9 6048.3 261.6 809.2 S 5806.4 W 828.8 S 5850.7 W 848.6 S 5894.8 W 868.6 S 5938.8 W 888.8 S 5982.7 W 8650.0 74.59 244.95 8700.0 74.15 244.65 8750.0 73.84 244.39 8800.0 73.42 244.12 8850.0 73.2]. 244.13 .81 1.06 .79 .98 .42 4728.6 4742.1 4755.9 4769.9 4784.3 4684.8 4698.3 4712.1 4726.1 4740.5 6051.5 6094.6 261.4 6098.9 6140.8 261.3 6146.2 6186.8 261.2 6193.4 6232.7 261.0 6240.5 6278.6 260.9 909.1 S 6026.4 W 929.6 S 6070.0 W 950.3 S 6113.4 W 971.1. S 6156.6 W 992.0 S 6199.7 W 8900.0 74.31 244.32 8950.0 75.03 244.44 9000.0 74.78 244.36 9050.0 74.84 244.24 9100.0 76.26 244.25 .24 .44 .52 .26 .85 4798.3 4811.5 4824.5 4837.6 4850.]. 4754.5 6287.8 6324.6 260.8 4767.7 6335.2 6370.8 260.7 4780.7 6382.7 6417.2 260.5 4793.8 6430.2 6463.5 260.4 4806.3 6477.8 6510.0 260.3 103.2.9 S 6242.9 W 3.033.7 S 6286.4 W ~i 1054.6 S 6329.9 W '~'! 1075.5 S 6373.4 W 1096.6 S 6417.0 W 91.50.0 76.50 244.31 9200.0 76.50 244.20 9250.0 76.36 244.09 9300.0 76.32 244.03 9350.0 76.08 243.91 .49 .21 .35 .14 .53 4861.9 4873.6 4885.3 4897.1 4909.0 4818.]. 4829.8 4841.5 4853.3 4865.2 6525.6 6573 .5 6621.3 6669.0 6716.7 6556.8 260.2 6603.5 260.1 6650.3 260.0 6697.0 259.8 6743.7 259.7 1117.7 S 6460.8 W 1138.8 S 6504.6 W 1160.0 S 6548.3 W 1181.2 S 6592.0 W 1202.5 S 6635.7 W A Gy r o d a t a D i r e c t i o n a i S u r v e y B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING [,oc. ation: F PAD, MILNE POINT FIELD, Job Number: AKl198GCE510 ALAS KA Page 8 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL CLOSURE DEPTH DEPTH SECTION DIST. AZIMUTH feet feet feet feet deg. HORIZONTAL COORDINATES feet 9400.0 76.08 243.76 .29 9450.0 76.23 243.53 .55 9500.0 76.40 243.34 .49 9550.0 76.39 243.27 .15 9600.0 76.06 243.34 .69 9650.0 76.02 243.40 .13 9700.0 76.12 243.59 .41 9750.0 75.81 243.78 .74 9800.0 75.39 244.07 1.00 9850.0 75.44 244.08 .10 9900.0 75.53 244.00 .23 9950.0 75.60 244.07 .19 10000.0 75.39 244.15 .46 1.0050.0 75.18 244.26 .46 ].0100.0 74.88 244.31 .61 10150.0 74.63 244.43 .55 10200.0 74.50 244.37 .29 10250.0 74.02 244.36 .95 10300.0 74.17 244.12 .55 1.0350.0 73.74 243.98 .89 10400.0 73.67 244.24 .52 10450.0 73.66 244.11 .25 ].0500.0 73.51 243.89 .52 10550.0 73.36 243.79 .35 10600.0 73.58 243.98 .56 4921.1 4933 .0 4944 . 8 4956.6 4968.5 4980.6 4992.6 5004.7 5017.2 5029.8 5042.3 5054.8 5067.3 5080.0 5092.9 5106.0 51.].9.3 5132.9 5146.6 5160.4 5174.5 5188.5 5202.7 52]_6.9 5231.1 4877.3 4889.2 4901.0 491.2.8 4924.7 4936.8 4948.8 4960.9 4973.4 4986.0 4998.5 501.1.0 5023 .5 5036.2 5049.1 5062.2 5075.5 5089.1 5102.8 5]..16 .6 5130.7 5144.7 5158.9 5173.1 5187.3 6764.4 6812.1 6859.7 6907.4 6955.0 7002 .6 7050.2 7097.9 7145.5 7193 .0 7240.6 7288.2 7335.8 7383.4 7430.9 7478.4 7525.8 7573.2 7620.5 766'7.7 7714.9 7762.1 7809.2 7856.3 7903.4 6790.4 259.6 6837.1 259.5 6883.8 259.4 6930.5 259.3 6977.2 259.2 7023.9 259.1 7070.7 259.0 7117.5 258.9 7164.3 258.8 7211.1 258.7 7258.0 258.6 7304.8 258.5 7351.7 258.4 7398.6 258.3 7445.5 258.2 7492.4 258.1 7539.2 258.0 7586.0 257.9 7632.7 257.8 7679.4 257.8 7726.0 '257.7 7772.7 257.6 781..9.3 257.5 7865.9 257.4 7912.5 257.3 1223.9 S 6679.2 W 1245.5 S 6722.7 W 1267.2 S 6766.2 W 1289.0 S 6809.6 W · 1310.9 S 6853.0 W 1332.6 S 6896.4 W 1354.3 S 6939.8 W 1375.8 S 6983.3 W 1397.1 S 7026.8 W 1418.2 S 7070.3 W 1439.4 S 7113.8 W 1460.6 S 7157.3 W 1481.7 S 7200.9 W 1502.8 S 7244.4 W 1.523.7 S 7287.9 W 1544.6 S 7331.4 W 1.565.4 S 7374.9 W 1.586.3 S 7418.3 W 1607.2 S 7461.6 W 1628.2 S 7504.8 W 1649.1_ S 7548.0 W 1670.0 S 7591.2 W 1691.1 S 7634.3 W 1712.2 S 7677.3 W 1_733.3 S 7720.3 W A Gy r o d a t a D i r e c t i o n a i S u rv e y B.P. EXPLOP_ATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, Job Number: AKl198GCE510 ALAS KA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL COORDINATES feet 3.0650.0 72.63 243.84 10700.0 69.96 243.34 3.0750.0 65.85 241.92 10800.0 64.92 240.65 10850.0 62.77 238.76 ].0900.0 60.71 237.05 10950.0 60.61 236.97 11000.0 60.68 236.97 3.1050.0 60.69 236.98 11100.0 60.15 236.99 11150.0 59.67 236.76 11200.0 59.39 236.73 11250.0 59.38 236.85 ].1300.0 58.50 23'7.06 11350.0 58.13 237.14 1].400.0 57.41 237.22 11450.0 57.35 237.31 11500.0 55.88 237.93 1.1550.0 55.94 238.03 11600.0 54.29 239.16 1].650.0 50.46 241.67 ].1700.0 46.77 243.96 11750.0 45.10 245.35 ].1800.0 44.09 245.76 ].]_850.0 42.79 246.45 1.92 5.41 8.64 2.96 5.47 5.10 .25 .14 .02 1.09 1.04 .55 .21 1.78 .77 1.45 .20 3.11 .20 3 .79 8.62 8.15 3.90 2.10 2 .76 5245.7 5261.7 5280.5 5301.3 5323 .4 5347.1 5371.6 5396.1 5420.5 5445.2 5470.3 5495.7 5521.1 5546 . 9 5573 .2 5599.8 5626.8 5654.3 5682.3 5710.9 5741.5 5774.5 5809.3 5844.9 5881.2 5201.9 5217.9 5236.7 5257.5 5279.6 5303.3 5327.8 5352.3 5376.7 5401.4 5426 · 5 5451.9 5477.3 5503 .1 5529.4 5556.0 5583.0 56].0.5 5638.5 5667.1 5697.7 5730.7 5765.5 5801.1 5837.4 7950.4 7996.9 8042 .2 8086.5 8129.8 8172.0 8213.6 8255.1 8296.6 8338.1 8379.3 8420.3 8461.3 8502.1 8542.7 8583.0 8623.2 8663.2 8702.8 8742.2 8780.6 8817.3 8852.7 8887.4 8921.4 7959.0 257.3 8005.1 257.2 8049.9 257.1 8093.6 257.0 8136.5 256.9 8178.2 256.8 8219.2 256.7 8260.2 256.6 8301.3 256.5 8342.3 256.4 8383.0 256.3 8423.7 256.2 8464 . 3 256.1 8504.7 256.0 8545.0 255.9 8585.0 255.8 8625.0 255.8 8664.7 255.7 8704.1 255.6 8743.3 255.5 8781.6 255.4 8818.2 255.4 8853.5 255.3 8888.1 255.3 8922.0 255.3 1754.3 S 7763.3 W 1775.4 S 7805.7 W 1796.7 S 7846.8 W ]_818.5 S 7886.7 W 1841.1 S 7925.5 W 1864.5 S 7962.8 W 1888.3 S 7999.3 W 1912.0 S 8035.9 W 1935.8 S 8072.4 W 1959.5 S 8108.9 W 1983.1 S 8145.1 W 2006.7 S 8181.1 W 2030.3 S 8217.1 W 2053.7 S 8253.1 W 2076.8 S 8288.8 W 2099.7 S 8324.3 W 2122.5 S 8359.7 W 2144.8 S 8395.0 W/I 2166.8 S 8430.1 W 2188.2 S 8465.1 W 2207.7 S 8499.5 W 2224.9 S 8532.9 W 2240.3 S 8565.3 W 2254.8 S 8597.3 W 2268.7 S 8628.7 W A Gy r o d a t a D i r e c t i o n a i S u rv e y B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, Job Number: AKl198GCES10 ALAS KA Page 10 MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL CLOSURE DEPTH DEPTH SECTION DIST. AZIMUTH feet feet feet feet deg. HORIZONTAL COORDINATES feet 11900.0 41.42 247.37 2.99 ]_1950.0 41.30 247.19 .35 ].2000.0 40.95 247.33 .72 12050.0 40.82 247.82 .70 ].2100.0 40.85 247.90 .12 5918.3 5874.5 8954.6 8955.2 255.2 5955.8 5912.0 8987.4 8987.9 255.2 5993.5 5949.7 9020.0 9020.4 255.2 6031.3 5987.5 9052.5 9052.9 255.2 6069.1 6025.3 9084.9 9085.3 255.1 2281.9 S 8659.6 W 2294.6 S 8690.0 W 2307.3 S 8720.4 W 2319.8 S 8750.6 W. 2332.1 S 8780.9 W 12150.0 40.68 247.81 .35 12200.0 40.53 247.61 .40 1_2250.0 39.28 24'7.36 2.53 12300.0 37.40 246.88 3.79 6107.0 6063.2 9117.4 91.17.7 255.1 6144.9 6101.1 9149.7 9150.0 255.1 6183.3 6139.5 9181.5 9181.8 255.0 6222.5 6178.7 9212.2 9212.5 255.0 2344.4 S 8811.1 W 2356.8 S 8841.2.W 2369.1 S 8870.9 W 2381.1 S 8899.4 W Final Station Closure: Distance: 9212.49 ft Az: 255.02 deg. A G y r o d a t a D i r e c t i o n a i S u rv e y for B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, ALASKA Job Number: AKl198GCE510SS [)ate: 19-Nov- 98 00:].5:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical"Reference: 43.8 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 254.600 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy r o d a t a D i r e c t i o n a i S u r v e y B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, Job Number: AKl198GCE510SS ALASKA Page SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet -43.8 0.00 0.00 0.00 0.0 .15 57.36 .15 100.0 .37 132.13 .22 200.0 .45 155.35 .21 300.0 .79 194.42 .54 0.0 43.8 143.8 243.8 343.8 0.0 0.0 0.0 .3 57.4 1.0 131.4 1.6 137.4 2.7 ]_55.9 0.0 N 0.0 E .1 S .1 E .4 S .4 E 9 S .8 E 1.9 S .7 E 400.0 1.38 215.17 .69 500.0 1.75 223.67 .43 600.0 1.99 223.89 .24 700.0 2.56 225.94 .58 800.0 4.05 236.22 1.63 443.8 543 .8 643 .8 743 .8 843.8 1.1 3.4 6.2 9.6 15.0 4.7 180.4 7.5 198.2 10.9 207.6 15.3 213.0 22.1 218.9 3.5 S .7 W 5.6 S 2.0 W 7.9 S 4.2 W 1.0.7 S 7.1 W 14.1 S 1]..7 W 900.0 6.19 247.90 2.33 1000.0 8.17 25]_.27 2.01 1100.0 ].0.05 251.97 1.86 1200.0 ].2.13 253.67 2.09 1300.0 14.83 259.51 3.58 943.8 1043 .8 1143 .8 1243 .8 1343.8 23 .7 36.3 52.3 71.9 95.2 32.3 226.9 46.1 234 .3 63 .3 239.4 84.0 243.0 108 .9 246.3 17.9 S 19.7 W 22.2 S 31.5 W 27.2 S 46.7 W 33.0 S 65.5 W 38.7 S 88.0 W 1400.0 16.86 262.24 .84 1500.0 18.61 261.71 2.26 1600.0 20.69 265.50 3.11 1700.0 22.87 268.53 1.64 1800.0 23.91 268.53 1.03 ].443.8 1543.8 1643.8 1743.8 1843.8 123.9 ]_55.4 190.4 229.6 271.5 137.1 249.8 168.1 252.2 202.1 254.3 239.5 256.5 278.8 258.4 43.0 S 1].6.7 W 47.4 S 148.1 W 51.6 S 183.3 W 53.4 S 223.5 W 54.5 S 266.6 W 1900.0 26.08 268.23 1.90 2000.0 28.38 268.96 2.11 2].00.0 29.39 270.63 .56 2200.0 32.36 271.36 3.33 2300.0 36.74 270.99 4.22 1943.8 2043.8 2143.8 2243.8 2343.8 316.8 367.0 420.3 477.1 542 .7 320.9 259.9 390.1 261.1 438.5 262.3 489.7 263.3 576.0 264.3 55.7 S 313.2 W 57.4 S 364.8 W 57.0 S 420.3 W 56.1 S 479.5 W 54.7 S 547.9 W A Gy r o d a t a D i r e c t i o n a i S u rv e y B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, Job Number: AKl198GCE510SS ALASKA Page SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 2400.0 39.29 270.77 .70 2500.0 40.79 269.15 2.16 2600.0 43.31 267.54 1.64 2700.0 46.53 267.6]. 3.15 2800.0 48.94 267.11 1.99 2443 .8 2543 .8 2643 .8 2743 .8 2843 .8 619.0 699.4 787.0 883 .4 990.6 638.7 265.1 735.1 265.7 837.0 266.0 908.1 266.2 101.9.3 266.3 53.4 S 627.3 W 53.2 S 710.8 W 55.8 S 801.0 W 60.2 S 899.8 W 65.3 S 1009.6 W 2900.0 51.98 266.17 1.50 3000 . 0 54 . 65 265 . 14 1 . 78 3].00.0 58.03 265.8]. 2.18 3200.0 6]_.].9 267.53 2.93 3300 . 0 66 . 74 268 . 04 2 . 36 2943.8 3043.8 3143.8 3243.8 3343.8 1109.6 1241.5 1388.8 1553.4 1752.9 1135.4 266.3 1296.4 266.3 1421.7 266.2 1593.8 266.2 18].9.2 266.4 72.3 S 1131.0 W 82.3 S 1265.1 W 94.6 S 1414.5 W 103.8 S 1582.6 W 112.2 S 1787.3 W 3400.0 69.37 268.90 .29 3500.0 7]..14 268.02 1.36 3600.0 71.32 267.67 .52 3700.0 71.35 267.27 1.46 3800.0 70.85 268.43 .98 3443.8 3543 .8 3643 .8 3743 .8 3843.8 1999.7 2262.0 2545.2 2833.8 3101.3 2052.1 266.7 2333.5 266.9 2617.2 267.0 2948.5 267.1 3183.3 267.2 117.9 S 2041.7 W 124.4 S 2312.0 W 135.4 S 2602.7 W 148.7 S 2898.3 W 156.4 S 3173.7 W 3900.0 68.22 268.29 .90 4000.0 72.20 264.05 2.56 43.00.0 72.80 259.06 .84 4200.0 73.13 255.06 .71 4300.0 74.37 253.35 1.02 3943.8 4043.8 4143.8 4243.8 4343.8 3358.2 3633.8 3960.6 4283.7 4622.8 3463.6 267.3 3746.8 267.3 4079.4 266.8 4409.0 266.0 4737.9 265.2 164.0 S 3438.1 W 177.3 S 3720.3 W 229.6 S 4044.8 W 302.5 S 4359.9 W 396.3 S 4685.8 W 440'0.0 74.43 251..30 1.20 4500.0 74.72 248.91 1.97 4600.0 76.03 246.48 .81 4700.0 74.11 244.61 1.03 4800.0 75.54 244.24 1.54 4443.8 4543.8 4643.8 4743.8 4843.8 4976.0 5349.6 5731.0 6104.9 6453.8 5067.0 264.3 5441.9 263.3 5815.9 262.3 6186.8 26]..3 6510.0 260.4 502.0 S 5023.0 W 631.6 S 5374.8 W 776.0 S 5730.7 W 932.2 S 6075.5 W 1085.9 S 6395.0 W A Gy r o d a t a D i r e c t i o n a i S u rv e y B.P. EXPLORATION WELL: MPF-80, 4.5"TUBING Location: F PAD, MILNE POINT FIELD, Job Number: AKl198GCE510SS ALAS KA Page SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. HORIZONTAL COORDINATES feet 4900.0 76.38 243.36 .49 5000.0 75.54 244.01 .23 5100.0 74.14 244.17 .63 5200.0 72.75 243.85 1.74 5300.0 61.00 237.29 5.15 4943.8 6855.5 6883.8 259.4 1265.3 S 6762.3 W 5043.8 7246.4 7304.8 258.5 1442.0 S 7119.1 W 5143.8 7610.8 7632.7 257.9 1602.9 S 7452.7 W 5243.8 7944.4 7959.0 257.3 1751.6 S 7757.8 W 5343.8 8166.2 8178.2 256.8 1861.3 S 7957.6 W 5400.0 60.18 236.99 1.02 5500.0 58.61 237.03 1.59 5600.0 56.44 237.69 2.00 5700.0 50.20 241.83 8.59 5800.0 44.12 245.75 2.16 5443.8 8335.7 8342.3 256.4 5543.8 8497.2 8504.7 256.0 5643.8 8647.9 8664.7 255.7 5743.8 8783.2 8818.2 255.4 5843.8 8886.3 8888.1 255.3 1958.]. S 8106.8 W 2050.8 S 8248.7 W 2136.3 S 8381.5 W 2208.9 S 8501.9 W 2254.3 S 8596.3 W 5900.0 41.34 247.24 1.19 6000.0 40.83 247.85 .50 6100.0 40.54 247.62 .20 6178.7 37.40 246.88 3.79 5943.8 8976.9 8987.9 255.2 6043.8 9063.2 9085.3 255.1 6143.8 9148.7 9150.0 255.1 6222.5 9212.2 9212.5 255.0 2290.5 S 8680.3 W 2323.9 S 8760.6 W 2356.4 S 8840.3 W 2381.1 S 8899.4 W Final Station Closure: Distance: 9212.49 ft Az: 255.02 deg. 4. QUALITY CONTROL I QUALITY CONTROL REPORT JOB NUMBER · AK1198GCE510 TOOL NUMBER' 777 MAXIMUM GYRO TEMPERATURE · 74.6 C MAXIMUM AMBIENT TEMPERATURE · 55.44 C MAXIMUM INCLINATION' 76.50 AVERAGE AZIMUTH · 255.02 WIRELINE REZERO VALUE · ADD 25' REZERO ERROR / K · N/A CALIBRATION USED FOR FIELD SURVEY' 2517 CALIBRATION USED FOR FINAL SURVEY' 2517 PRE JOB MASS BALANCE OFFSET CHECK: -.92 POST JOB MASS BALANCE OFFSET CHECK~ · USED O.O/N/A CONTINUOUS CONDITION OF SHOCK WATCHES -.110 UPON ARRIVAL AT RIG · OK UPON COMPLETION OF SURVEY' OK UPON RETURN TO ATLAS: OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING MWD 12335 36.52 248.09 6245.8 -2345.8 FINAL SURVEY 12300 37.40 246.88 6222.5 -2381.1 EASTING -8960.9 -8899.4 FUNCTION TEST JOB NUMBER: AK1198GCE510 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 1289 13.62 13.62 13.62 13.62 13.62 AZIMUTH M.D. ft 1 2 3 4 5 1289 256.97 256.80 256.92 256.88 257.01 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: AK1198GCE510 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 777 GYRO SECTION DATA SECTION POWER SECTION BACKUP TOOL No. 790 GYRO SECTION DATA SECTION POWER SECTION A0169 C0111 C0083 A0162 C0089 C0086 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0433 A0085 A0079 A0143 A0467 A0107 A0029 A0055 WIRELINE COMPANY: CABLE SIZE: 15/32" SCHLUMBERGER RUNNING GEAR 2.25" HOUSING w/ECCENTRIC BAR TOTAL LENGTH OF TOOL: 30 FEET MAXIMUM O.D.: 2.25 INCHES TOTAL WEIGHT OF TOOL: 210 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: AK1198GCE510 TUESDAY, 11/17/98 11:00 TO SLOPE 14:00 CHECK TOOLS, STANDBY WEDNESDAY, 11/18/98 16:00 18:00 19:00 21:30 23:00 TO ENDICOTT JOB DELAYED TO MILNE POINT MU TOOL RU SCHLUMBERGER, WARM UP TOOL THURSDAY, 1 00:15 03:45 06:30 07:30 09:00 12:00 13:30 14:00 16:00 1/19/98 PICK LIP GYRO RIH SURVEY IN TO 12300', PUMP TOOL DOWN SURVEY OUT LD TOOL, RD SCHLUMBERGER. TO ATLAS PROCESS SURVEY, CHECK TOOLS. TO MILNE POINT WITH RESULTS RETURN TO ATLAS. STANDBY ON SLOPE FOR ENDICOTT. 1/7/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12211 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) Color Well Job # Log Description Date BL Sepia Print LIS Tape MPL-39 L.t.[ ¢,._, 99003 USIT 980627 1 MPF-80 ~ ~'1 99005 DDL (PDC) 981207 1 MPB-05A I.x.I c._ INJECTION PROFILE 981227 1 1 MPB-18 / RST-INJECTION WFL 981223 I 1 MPJ- 17~ INJECTION PROFILE 981220 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED JAi ! I5 1999 Alaska Oil & Gas Cons. Cornhill}on Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sh~~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson,~/o DATE: Chairman January 10, 1999 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor ,/1~/~9 awpkajgf, doc FROM: Chuck Scheve, c ~ SUBJECT: Petroleum Inspector BOPE Test Nabors 4ES MPU F-80 PTD # 98-217 Sunday January 10, 1999: I traveled to BPX's MPU F-80 Well being completed by Nabors Rig 4ES and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows the test lasted 7 hours with 2 failures. The Blind Shear Rams failed to pressure test; these were replaced with a regular set of blind ram blocks and tested OK. The gas detector system was being repaired at the time of the test, repairs and calibration will be completed before conducting open hole operations. The Kelly valves were not tested today because it will not be used during completion of this well. The testing went well with good test procedures being employed by the Nabors crews. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized. Summary:. I witnessed the initial BOPE test on Nabors Rig 4ES completing Well MPU F-80. Nabors 4ES, 1/10/99, Test time 7 hours, 2 failures Attachment: awpkajgf, xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA ..... OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X Drlg Contractor: Nabors Rig No. 4ES PTD # 98-217 Operator: BPX Rep.: Well Name: MPU F-80 Rig Rep.: Casing Size: Set @ Location: Sec. Test: Initial X Weekly Other DATE: 1/lO/gg Rig Ph.# 659-4154 Larry Myers Gene Sweat 6 T. 13N R. IOE Meridian UM Test VllSC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign N/A Drl. Rig OK Hazard Sec. YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F 2 250/5,000 250/5,000 BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 250/3000 250/5,000 ~ 250/5,000 I 250/5,000 2 250/5,000 I 250/5,000 N/A N/A P/F P P F/P P P P CHOKE MANIFOLD: No. Valves 11 No. Flanges 22 Manual Chokes 1 Hydraulic Chokes 1 Test Pressure 250/5,000 Functioned Functioned P/F P ACCUMULATOR SYSTEM: N/A System Pressure 3000 I Pressure After Closure 1700 I ~IUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 30 sec. Trip Tank OK OK System Pressure Attained 2 minutes 220 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: OK Flow Indicator OK OK Nitgn. Bfl's: 4 @ 1700 Psi Meth Gas Detector Psig. H2S Gas Detector Number of Failures: 2 ,Test Time: 7.0 Hours. Number of valves tested 19 Repair or Replacement of Failed Equipment will be made within 1 days.~lotify 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. !. Supervisor at 279-1433 REMARKS: Blind Shear rams failed to pressure test and were replaced with regular blind rams The Gas dectectors were not operational at this time but will be before conducting open hole operations. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector FI-O21L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: awpkajgf Chuck Scheve GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 12173 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Milne Point (Cased Hole) 12/17/98 Well Job # Log Description Date BL Sepia LIS Tape F-80 DEPTH DETERMINATION 981207 1 1 F-80 STATIC MEASUREMENT 981208 1 1 F-17 t.~.~ ~ INJECTION PROFILE 981102 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED jAN 05 t999 Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN" Sh~./~ .4 Receive~/¢/ January 28, 1999 ~eoQues! Schlumberger GeoQuest 3940 Arctic Boulevard Anchorage, Alaska 99503 (907) 273-1700 (907) 561-8317 (Fax) TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the Depth Corrected CDR/ADN. CDR/ADN TVD'$ for well MPF-80. Job # 98618 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 E-TRANS 3 Bluelines each 1 Film each State of Alaska Alaska Oil & Gas Conservation Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 1 OH LIS Tape 1 Blueline each 1 Sepia each OXY USA, Inc. Attn: Darlene Fairly P.O. Box 50250 Midland, TX 79710. 1 OH LIS Tape 1 Blueline each 1 Sepia each Sent Certified Mail: P 067 695 526 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Date Delivered: FEB ,, Commission Schlumberger GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 A . .ka eared r.v(ces nll ng Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission Anchorage, AK November 13, 1998, 11:00 am Via Fax: 276-7542 Dear Mr. Wondzell: This note confirms our recent conversation regarding the present operations on MP F- 80 and our forward plan. We have been successful cleaning the well out to TD and are planning to run and cement the 7" casing. As noted previously, hydrocarbon is present in both the Schrader and Kuparuk and both zones are open to the 8-1/2" hole. Please reference the wellbore drawing with this letter. It is planned to cement the Kuparuk and Schrader zones separately. We plan to cement the Kuparuk as usual with "G" cement and a cement top of ~ 1000' above the B. For the Schrader, we plan to downsqueeze the cement followed by the freeze protection. As you requested, we will plan to run an evaluation log to determine the applicability of the downsqueeze to similar situations in the future. It is our plan to run the evaluation log when the completion rig is on the well. We will forward a copy of the log to you when it has been run. Thank you for discussing this proposal and approving the plan forward. If you have any questions, please contact myself (wk 564-4429, hm 345-0850) or Chuck Mallary (wk 564-5061, hm 345-7848). Operations Drilling Engineer Nabors 27E ~, uuz~ 1 A a ska eared r. vices rliling Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission Anchorage, AK Via Fax: 276-7542 Dear Mr. Wondzell: This note confirms our recent conversation regarding the present operations on MP F- 80 and the possible need to plug the lower wellbore due to hole problems. Please reference the drawing faxed with this note. We had successfully freed the drill string, tripped out of hole, tested BOPs, begun tripping into the well. We circulated the well at the 9-5/8" shoe and again at -12300' (below the logged fault). Minor losses were experienced at the shoe. Losses significantly increased while lifting dehydrated mud from 12300'. Washing/reaming commenced and the bit had reached -12800'. Tight hole is being experienced and reaming thus far has not been effective. Fluid losses are continuing. We plan to continue working the wellbore, however it is possible that this will not be successful and the lower wellbore will be abandoned. The abandonment proposal is: 1. TOH and LD BHA. 2. RIH open-ended. Run DP as deep as possible. Ideally the pipe should be at TD, however at a minimum the pipe should be no shallower than the top of the HRZ @ 12400'. 3. Spot a balanced plug to fill a minimum of 300' of wellbore. If successful in reaching TD, the plug must extend from TD to a minimum of 50' above the top of the Kuparuk. As with our production cement calculations, use the Kuparuk B as the top. 4. Slowly pull out of plug. Circulate DP clean. 5. POOH to next plug depth. Kickoff plug depth has yet to be determined. 300- 400' of cement will be set in the welt to kick off the well. Please contact myself (wk 564-4429, hm 345-0850) or Chuck Mallary (wk 564-5061, hm 345-7848). Nabors 27E r r~Ul'l ~ IIHD ul~ r~ta z~r' rHr~ i~u= · ~ ~ r o .~ ~ '-t ~ "t .-~ .._hared _, , .ervices l rilling October 2g, 1998 Mr. Blair Wondzcll Alaska Oil anti Gas Conservation Commission Anchorage, AK Via Fax: 1-907-276-7542 RE: Forward Operations Rig 27E Milne Point Dear Mr. Wondzcli: This letter confirms our discussion of last week regarding the forward plans for Rig 27E in Milnc Point. / Operations were completed on MP F-92i on October 26 and the rig is in final preparations to spud MI' F-80. targcls a undrilled fault block at the edge oF the field and Ihere i~ a risk of nm finding hydrocarbon. Ir it is determined that F-80 will not be completed, our fall back position is to plug back and sidelrack to a new BHL, Based on timing pro. jeclions, that decision point should be reached in about 11 days. II~ the well is to be plugged back we will provide the Commission notice and will submit the necessary Sundry and a permit application IBr thc new BHL at that time as you recommended. That well will be F-8Oa' If I:-80 i,s dc-tc~ ~uincd a success, 7" casing will be run as planned and the rig will move to MP F-84. in anticipation of an F-80 success, the application for permit to drill for F-84 should bc submitted by ~omorrow (Oct. 29). Please note that il' F-80 is sidetracked, F-84 will not be drillcd since the intended BHL of F-80a is the same as F-84. We hope keeping you informed of the options available in the next 2 weeks helps reduce potential lot confusion. If you require further information, please contact me at 564-4429, Chuck Mallary al 564-5061, or Paul Prince at 564- 5589. Sincerely ytmrs, Thomas E. Maunder SSD (.)potations Drilling Engineer Nabors 27E TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 27, 1998 Chuck Mallar¥ Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 100360 Anchorage, AK 99519-6612 Re; Milne Point Unit MPF-80 BP Exploration (Alaska) Inc. Permit No: 98-217 Sur Loc: 1943'NSL, 3046'WEL, Sec. 6, T13N, RiOE. UM Btmhole Loc. 4600'NSL 2019'WEL, Sec. 11, TI3N. R9E, UM Dear Mr. Mallarv: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill docs not cxcmpt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting dctcrminations arc made. Blowout prevention cquipmcnt (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a rcprescntative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Si Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type of work i~ Drill [---IRedrill llb. Typeofwell []Exploratory DStratigraphicTest [~ Development Oil [] Re-Entry [] Deepen1 [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 43.8' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation ,¢~ Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL.;34~,8-3~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1943' NSL, 3046' WEL, SEC. 6, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 4658' NSL, 1893' WEL, SEC. 11, T13N, R9E, UM MPF-80 At total depth 9. Approximate spud date Amount $200,000.00 4600' NSL, 2019' WEL, sEc. 11, T13N, R9E, UM 10/29/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355023, 621'I No Close Approach 1920 13597' MD / 7321' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 500' Maximum Hole Angle 75° Maximum surface 2883 psig, At total depth (TVD) 6935' / 3577' psig 18. Casing Program I Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' __.50 sx Arcticset I (Approx.) ._. 12-1/4" 9-5/8" 40# L-80 BOSS 5804' 31' 31' 5835' 3930' 620 sx PF 'E', 180 sx 'G', 175 sx PF 'C' 8-1/2" 7" 29# L-80 Hydril 563 13567' 30' 30' 13597' 7321' 200 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 M D TVD Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical ,,, 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Tom Maunder, 564-4429 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certj~tha~oreg~is true and correct to the best of my knowledge Signed ~/'//_"' ,~,2////'/~'~ ~ ~'-~'-O~,/ Chuck MalI~'W''~'' ~'' "-'~(.¢"~.--'~ Title Senior Drilling Engineer Date Commission Use Only Permit Number I APl Nu'~l~ber ...-. .-, I ApDroval Date _ I See cover letter "~;"-'~--'/,~ I 50- O Z._ ~ ---' ~ ~ ~' ~--- ~ I /'¢..~--,¢~1.._/¢;;~;~I for other requirements Conditions of Approval: Samples Required []Yes [] No Mud Log Required []Yes J~No Hydrogen Sulfide Measures J~Yes []No Directional S~rvey Required ~'Yes [] No Required Working Pressure for BOPE I--t2M' []3M; J~C, J5M; E]IOM; []15M Other: 0rigina~ Signed By by order of Approved By P,a.vid W. Johnston Commissioner the commission Date/~ r ~ .... STATE OF ALASKA -- - ALASKA ~JIL AND GAS CONSERVATION CON''cllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill I lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 43.8' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation ,~"," Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL.~388.~'~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1943' NSL, 3046' WEL, SEC. 6, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 4658' NSL, 1893' WEL, SEC. 11, T13N, R9E, UM MPF-80 At total depth i9. Approximate spud date Amount $200,000.00 4600' NSL, 2019' WEL, SEC. 11, T13N, R9E, UM 10/29/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 355023, 621'I No Close Approach 1920 13597' MD / 7321' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 500' Maximum Hole Angle 75° Maximum surface 2883 psig, At total depth (TVD) 6935' / 3577 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 BOSS 5804' 31' 31' 5835' 3930' 1620 sx PF 'E', 180 sx 'G', 175 sx PF 'C' 8-1/2" 7" 29# L-80 Hydril 563 13567' 30' 30' 13597' 7321' 200 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 M D TVD Structural ~ J Conductor ~ Surface Intermediate ~, ~ Production Liner Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Tom Maunder, 564-4429 Prepared By Name/Number: Kathy Campoamor, 564-5122 121. I hereby certj,fC)tha~/~e,J.,orego_irj~is true and correct to the best of my knowledge Chuck MalI~'W''~ ¢' ~ Title Senior Drilling Engineer Date /¢'! Commission Use Only Permit Number '1 APl Nu"t~ber~" .Approval Date.., I See cover letter /~'~'- '2' //,~' I 50- C:~ ~--~- .~. Z_ ~.~_. ~ /0 "~,~-7--'~' ~I for other requirements Conditions of Approval: Samples Required []Yes J~No Mud Log Required []Yes j~No Hydrogen Sulfide Measures []Yes []No Directional S~rvey Required ~j~Yes [] No Required Working Pressure for BOPE []2M; [] 3M; ,,~5M; [] 10M; I'-] 15M Other: Oi'igiFtat Si,qRed. B~~ by order of Approved By David W. Johnston Commissioner the commission Date/'¢'"',:~'~---y~;~ Form 10-401 Rev. 12-01-85 Submit In Triplicate ~ALASKA~ Date: To: Attn: From: Subject: October 26, 1998 Alaska Oil & Gas Conservation Commission David W, Johnston Kathy Campoamor,~ochnical Asst. Permit approval for MPF-80 eared trices rilling BP Exploration / Arco Alaska Dear Mr. Johnston, According to our records, the Permit To Drill for well MPF-80 was submitted to the ^OGCC on October 15, 1998. Originally we anticipated the spud date to be October 29, 1998 as indicated on the permit application. However, the well we are currently on is going extremely well and there is a high probability to spud the MPF-80 well a day earlier than originally planned. Please consider this as a request to change the spud date to October 28, 1998 and to have the Permit To Drill for MPF-80 approved and ready for pick up no later than October 28, 1998 if possible. Thank you in advance for your help. Cc: Well File Tom Maunder, ODE-Nabors 27E Shared Services Drilling Contact: I Well Name: I Type of Well (producer or injector): Tom Maunder IMP F-80 Well Plan Summary 564-4429 I Kuparuk Producer Surface Location: 1943' NSL, 3046' WEL, Sec. 06, T13N ,R10E, UM., AK Target Kuparuk 4658' NSL, 1893' WEL, Sec. 11, T13N, R09E, UM., AK Bottom Hole Location: 4600' NSL, 2019' WEL, Sec. 11, T13N, R09E, UM., AK I AFE Number: 1337112 I Rig: I Nabors 27-E I Estimated Start Date: I 29 Oct. 98 I I Operatin~l days to complete: IUD: 113,597 J I mVD:17,321'Bkb I IEEE: 118 I 43.8' Well Desitin: Ultra Slim Hole Long String HAW I 9-5/8", 40# Surface X 7", 29# Production Formation Markers: Formation Tops MD TVD (ss) EMW Formation Pressure Base Permafrost 1883 1800 8.4 ppg 786 psi NA Top Schrader Bluff 5935 3910 8.4 ppg 1727 psi OB Base Schrader Bluff 6932 4210 8.4 ppg 1856 psi TKUD 13025 6740 9.9 ppg 3469 psi TKUB 13163 6870 9.9 ppg 3536 psi TKUA 13185 6890 9.9 ppg 3547 psi TKUA3/Target 13190 6895 9.9 ppg 3550 psi TKUA2 13206 6910 9.9 ppg 3569 psi TEA1 13233 6935 9.9 ppg 3577 psi Miluveach 13297 6995 9.1 ppg 3337 psi Total Depth 13597___ 7277_+ 9.1 ppg 3612 psi · *These are estimated maximum pressures and the actual pressures may be lower. Casing/Tubing Pro~lram: Hole ,~ize ' Csg'/ Wt/Ft Grade Conn Length Top Btm Tb9 O.D. MDrFVD MDrrVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 BOSS 5,804 31/31 5,835/3,930 8-1/2" 7" 29# L-80 Hyd ril 13,567 30/30 13,597/7,321 563 The internal yield pressure of the 7" 29# casing is 8,160 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TEA1 at -,- 6,935 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of __.6,935 TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,577 psi is 2883 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" casing. PAGE 1 TEM10/15/982:04 PM Cementinq Pro_qram: Halliburton Cementinc Services Hole Casing Interval & VolUme~ Spacer Type of Cement Propertiesz Category Size/Depth Excess Surface Lead~ Lead .Lead Lead First Stage 9-5/8" @ 2,083-5,335' 635 sx 70 bbls Permafrost"E' Den 12.0 ppg 8,851' @ 30% 245 bbls Fresh water Yield 2.17 ft 3/sx excess Water 11.63 gps 'IT 4.0 hrs 5,335-5,835' Tail5 Tai~l Tai~l @ 30% 180 sx Premium Class "G" w/ Den 15.8 ppg excess 36 bbls 0.2 % CaCl, 0.15 #/sk Floceele Yield 1.15 ft 3/sx Water 4.9 gps TT 4.0 hrs Second Sta~je Lead~ Lead Lead Lead Stage collar° @ 0-1,933' 985 sx 75 bbls Permafrost"E" Den 12.0 ppg 2,083' @ 250% 380 bbls Fresh water Yield 2.17 ft 3/sx excess Water ~ 'IT 4.0 hrs Tail5 1,933'-2,083' 175 sx Tai~l Tai._~l @ 250% 30 bbls Permafrost"C" Den 15.6 ppg excess Yield 0.96 ft 3/sx Water ~ TT 4.0 hrs Production 7" @ 12,163'- LeadTM Lead Lead Den 15.8 ppg First Stage 19,197' 13,597' 200 sx 70 bbls. Premium Class "G" w/ Yield 1.15 ft 3/sx 41 bbls NSCI Spacer 0.2 % CFR-3 Water 5.0 gps 0.1% HR-5 TT 3.5-4.5 hrs @140° F 0.45% Halad 344 FI 50cc/30 min @140° F 1. Volumes are rounded up to the nearest 10 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and mud's to ensure compatibility prior to pumping job. 3. A Type H ES Cementer will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2,083'MD_+ 4. The calculated first stage lead is designed to fill from the 9-5/8'" ES Cementer at 2,083' md to 5,335' md which is 500' above the shoe pills 30% Excess. 5. The calculated first stage tail cement volume is designed to fill from 500' md above the shoe to surface TD at 5,835' md (3,930 TVD bkb) plus 30% open hole excess and 80' 9-5/8", 40# casing shoe joint volume. 6. The surface hole Second Stage Lead Cement Volume covers the interval from 0-1,933' md The designed second stage lead cement volume includes 250% open hole excess.. 7. The surface hole Second Stage Tail Cement Volume covers the interval from 1,933-2,083' md The calculated second stage tail cement volume includes 250% open hole excess. 8. Install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). 9. This casing depth is planned to be above the Schrader Bluff. The Schrader Bluff is prognosed to be wet. 10. The production hole is planned as a single stage, however if the LWD logs indicate hydrocarbon in the Schrader a second stage will be pumped. The first stage estimated cement volume is designed to cover the interval from 12,163' md (1000'+ above the Kuparuk B Sand) to TD at 13,597' plus 30% open hole excess and the shoe joint volume of 80' md of 7", 29# casing. 11. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install one per joint from above the float collar to 120' above the Kupaurk B-Sand. Use two centralizers per joint on the shoe joints. 12. If the Schrader Bluff is hydrocarbon bearing, a centralizer recommendation will be provided. 13. Install two 7" marker joints and position three joints above the Kuparuk B sand. 14. Place all centralizers in middle of joints using stop collars. 15. Mix all cement slurries in the surface and production holes on the fly - batch mixing is no.._~t necessary. PAGE 2 TEM 2:04 PM 10/15/98 Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Logs: None Surface-12-1/4" 1. MWD/LWD D&I / GR / DWOB / DTQE from spud to TD of surface hole, real time & recorded 9-5/8" Cased Hole 1. Gyrodata multi-shot survey of 9-5/8" casing after drillout. Survey is needed for target sizing. This will accomplish an in hole reference as on earlier wells. Final Production 1. MWD/LWD 8-1/2" D&I/CDR/GR/ADN/PWD/DWOB/DTQE ADN is only required from the 'D' shale to TD, real time and recorded. All other logs required from drill out of 9-5/8" to TD, real time and recorded. 2. Open Hole: DP conveyed RFT/GR if Kuparuk is oil bearing. Cased Hole Logs: 1. None planned. Mud Logging 1. Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) during all operations. 12-1/4" and 8-3/4" Hole M10 PowerPlus DWOB/DTQE: GR: CDR: ADN: ROP: PWD Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Pressure While Drilling Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point ~lel gel Loss % 8.6-9.4 50-150 15-35 8-15 10-30 9-10 8-15 <10 Production Mud Properties to Change LSND Freshwater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point ~lel ~lel Filtrate %LGS 8.6-9.3 35-45 6-20 3-10 7-20 8.5-9.5 6-12 NC <6 Production Mud Properties from HRZ to LSND Freshwater Mud TD. Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel ~tel Filtrate %LGS 10.5 35-45 6-20 3-10 7-20 8.5-9.5 <4 10-12 for <6 HRZ Miluveach Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. PAGE 3 TEM 2:04 PM 10/15/98 Directional: KOP1 500' Start Variable @ 1.0°- 2.5°/100 to 71.4° inc. and 245.4° az. EOB @ 4,297 71.40-75° from 4,297-10,690' Tangent Hole Angle Final Drop Maximum Hole Angle Close Approach Wells Survey Program Start Final Drop 10,690' @ 2.5°/100 to 20° incl. 245.4 Az° EOD 12,890' md 75° from 7,020-10,690'. All wells may remain flowing while drilling F-80 and no shut-ins are required. 1. Surface to 5,804' MWD surveys. 2. 5,804'-TD MWD surveys. Disposal: No "Drilling Wastes" will be injected or disposed into F-80 while drilling this well. Cuttings Handlin_q: 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. Fluids Handlin_cl: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Obiective: MPU F-80 is planned as a Kuparuk River A Sand producer tapping an undrilled fault block to the southwest of F-Pad. TD is planned at 13,597' with a final departure of 9,770'. The well is S-shaped with a final angle of 20°. The surface casing will be shallow set above the Schrader Bluff at 5,835' (3,930' TVD bkb). The casing is shallow set to preserve sidetrack options should the intended reservoir target prove non-productive. It is intended to set the casing in a shale interval between the base of the Ugnu and the top of the Schrader Bluff. In well F-95i, the shale interval is 3990-4020' TVD. Geolo_clV This well is located to the southwest of F-Pad. The primary targets are the Kupauuk A sands. No major faulting is anticipated while drilling this well in the Kuparuk Reservoir however there is some potential faulting uphole in the Colville Brookian unconformity. Recoverable reserves associated with this producer are 1.18 MMBO. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be virgin in this undrilled fault block. Reservoir pressure is estimated at 3547 psi at 6933' tvd, (9.9 ppg EMW) in the Kuparuk formation. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. The shallow set surface casing design is has been planned for this well to preserve a sidetrack option should the intended target be determined non- productive. Close Approaches There are no close approaches associated with the drilling of MP F-80, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. Water, Gas and WAG Iniection This is an undrilled fault block. Milne Point production and injection are not expected to have effected the area. There is a possibility of some effect from ARCO's 3R-20 injection well if the fault block is not isolated. Annular Iniection Currently annular injection is not permitted on F-Pad. PAGE 4 TEM 2:04 PM 10/15/98 Lost Circulation: Lost circulation is prevalent while running casing and cementing in the surface but also occurs in the production hole. Losses are extremely probable while cementing the production casing in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing to bottom. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Contingencies have been incorporated to well program remedy loses if encountered. Mud weights will be maintain between 9.1-9.4 ppg down to the D shale as usual. Treatments of LCM may be added to the mud to "plate" off the Schrader Bluff sands as well as others exposed in the wellbore. The intent of adding LCM is in preparation for the increased mud weight necessary to drill the virgin pressure Kuparuk. Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on F-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing. While running 9-5/8" casing the following problems were experienced: hole packing off; tight hole, bridging, and stuck casing. While drilling the surface hole additional time has been spent reaming and conditioning the hole prior to cementing because of tight hole. Attention should be given to the Ugnu formation to reduce the chances of differential sticking in these formation with higher mud's weights. Differential sticking concerns will also exist in the production interval since the Schrader Bluff sands will be exposed below the shoe. The LCM additions mentioned previously should help "plate" off the sands to allow increase mud weight tolerance. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk D Shale. This common occurrence has often caused difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8-3/4" production interval. Shale instability is possible in the Miluveach and may result in tight hole or packing off so preventative measures must be taken to alleviate this risk if the Miluveach is inadvertently entered without treating the mud system.. Differential sticking is most likely to occur while running the production string. Formation Pressure: KUPARUK A1 SAND 6,935' TVDss 3,577 PSI 9.9 PPG EMW Formation pressures are expected to be virgin and the pore pressure is estimated at 9.9 ppg EMW. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at ± 7534' TVDss. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of ±6,935' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,577 psi is 2,883 psi. Higher pore pressure values are not expected however, there is the potential of some effect due to ARCO's 3R-20 injection well. See the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on F Pad. PAGE 5 TEM 2:04 PM 10/15/98 MP F-80 Kuparuk Producer Proposed Summary of Operations 1. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5 Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. 4. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. 5. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD/LWD (GR/DIR/DWOB/DTOQ) from surface to 12-1/4" TD. Corrolate GR data with prior wells to identify casing seat. 6. Run 9-5/8" casing. Space out ES Type H Cementer to 2,083' md. 7. Perform Two Stage Cement Job. Complete the surface casing cementing check list. 8. ND 20" Diverter, NU and Test 13-5/8" BOP 9. MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ/PWD). RIH, Drill out Float Equipment and 20' of new formation. Perform the FIT as per Recommended Practices Manual. Record pressure versus cumulative volume during the LOT test for the well file. 10. Drill 8.75" hole to TD as per directional plan. Use PWD information to assess hole cleaning. Observe for losses as mud weight is increased to enter the Kuparuk sands. Make sure sufficient footage is drilled to provide 250' of production rat hole between the top of the Kuparuk A3 sand and PBTD before running the 7" casing. 11. Condition hole and POOH for DP conveyed RFT. Prospective intervals will be chosen by geology. Following RFTs, make wiper trip and POOH for casing. 12. Run 7" casing. 13. Perform Single Stage Cement Job. If the Schrader sands are determined to be hydrocarbon bearing, a second stage cement job will be designed to provide necessary isolation. Complete the production casing cementing check list. 14. Displace cement with 9.9 ppg brine and enough diesel to cover from the base of permafrost to surface (+-2200' MD). 15. Bump the plug and test casing to 3500 psig for 5 minutes. Bleed off pressure and check floats. 16. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 17. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTERVALS ARE SELECTED. PAGE 6 TEM 2:04 PM 10/15/98 Anadrill Schlumberger ~, Alaska Dis~r~c~ 3940 Arctic Blvd. Anchorage, AK 99503 (907) 273-1700 Fax 561-8537 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPF-80 TR22-B (P5A) Field ........ : Milne Point Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.50761606 N e,lrface Long.: 149.66031677 W Legal Description Surface ...... : 1942 FSL 3046 FEL S06 T13N R10E UM Target TR22B.: 4658 FSL 1893 FEL Sll T13N R09E UM BHL .......... : 4600 FSL 2019 FEL Sll T13N R09E UM STATION IDENTIFICATION KOP/CURVE 1.00/100 CURVE 1.50/100 ,, LOCATIONS - ALASKA Zone: 4 X-Coord Y-Coord 541517.49 6035392.88 532246.00 6032783.00 532119.96 6032724.42 MEASURED INCLN D~RECTION DEPTH ANGLE AZIMUTH 0.00 0.00 0.00 500.00 0.00 267.00 600.00 1.00 267.00 650.00 1.50 267.00 700.00 2.25 267.00 800.00 3.75 267.00 850.00 4.50 267.00 900.00 5.50 267.00 1000.00 7.50 267.00 1100.00 9.50 267.00 1200.00 11.50 267.00 1300.00 13.50 267.00 PROPOSED WELL PROFILE CURVE 2.00/100 Prepared ..... : 24 Sep 1998 Vert sect az.: 254.60 KB elevation.: 43.80 f= Magnetic DCln: +27.369 (E) scale Factor.: 0.99990196 Convergence,.: +0.32021499 ANADRtLL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOP, EXECUTION PLAN VErTICAL-DEPTHS TVD SUB-SEA 0.00 -4~.80 500.00 456.20 599.99 556.19 649.98 606.18 699.96 656.16 SECTION DEPART 0.00 -0.00 0.85 1.92 3.52 ~F;r~&'°~&'~:='& ~~~& ~ = = = '" ~= ' ~ ~ ="~ ~'- - :-- m m m COORDINATES-FROM ALASKA Zone 4 TOOL DL/ WELLHEAD X y FACE 100 mmmmmmmmmm mmmmmmmm~m mmmmmmmmm mmmmmmmmmm mmma amma 0.00 N 0.00 E 541517.49 6035392.88 93L 0.00 0.00 N 0.00 E 541517.49 6035392.88 93L 0.00 0.05 S 0.87 W 541516.62 6035392.83 93L 1.00 0.10 S 1.96]W 541515.53 6035392,77 93L 1.00 0.19 S 3.59 W 541513.90 6035392.67 93L 1.50 799.82 756.02 849.69 805.89 899.50 855.70 998.85 955.05 1097.74 1053.94 8.63 12.14 16.40 27.45 41.89 0.46 S 8,82 W 541508.67 6035392.37 93L 1,50 0.65 S 12.41 W 541505.08 6035392.16 93L 1.50 0.88 S 16.76 W 541500.73 6035391.91 HS ,~2.00 1.47 S 28.07 W 541489.43 6035391.25 HS 2.00 2.24 S 42.83 W 541474.68 6035390.40 HS 2.00 1196.06 1152.26 1293.69 1249.89 59.68 80.82 3.20 S 61.03 W 541456,49 6035389.34 HS 2.00 4.33 S 82.64 W 5~41434.88 6035388.09 HS 2.00 (Anadrill (c)98 MPFSOP5 3.2C 9:50 AM P) MPF-80 TR22-B (PSA) 24 Sep 1998 Page 2 PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION VERTICAL-DEPTHS SECTION COORDINATES-FROM ALASKA Zone 4 TOOL DL/ IDENTIFICATION DEPTH /%NGLE AZIMUTH TVD SUB-SEA DEPART WELLHEAD X Y FACE 100 1400.00 15.50 267.00 1390.50 1346.70 105.27 5.64 S 107.64'W 541409.89 6035386.64 HS 2.00 1500.00 17.50 267.00 1486.38 1442.58 133.01 7.13 S 136.00 W 541381.54 6035384.99 HS 2.00 1600.00 19.50 267.00 1581.20 1537.40 164.00 8.79 S 167.69 W 541349.87 6035383.16 HS 2.00 1700.00 21.50 267.00 1674.87 1631.07 198.20 10.62 S 202.66 W 541314.91 6035381.13 MS 2.00 END 2.00/100 CURVE 1800.00 23.50 267.00 1767.25 1723.45 235.58 12.62 S 240.87 W 541276.71 6035378.91 HS 2.00 BASE PEP. MAFROST ~RVE 2.00/100 1883.47 23.50 1900.00 23.50 2000.00 25.50 2100.00 27.50 2200.00 29.50 2300.00 31.50 2400.00 33.50 2500.00 35.50 2600.00 37.50 2700.00 39.50 267.00 1843.80 1800.00 268.08 14.37 S 274.11 W 541243.49 6035376.98 HS 0.00 267.00 1858.96 1815.16 274.52 14.71 S 280.69 W 541236.91 6035376.60 HS 0.00 267,00 1949.95 1906.15 315.02 16.88 S 322.10 W 541195.52 6035374.20 MS 2.00 267.00 2039.44 1995.64 358.60 19.22 S 366.66 W 541150.98 6035371.62 HS 2.00 267.00 2127.31 2083.51 405.20 21.71 S 414.31 W 541103.35 6035368.85 MS 2.00 267.00 2213.47 2169.67 454.76 24.37 S 464.99 W 541052.69 6035365.92 HS 2.00 267.00 2297.81 2254.01 507.24 27.18 S 518.64 W 540999.06 6035362.80 HS 2.00 267.00 2380.21 2336.41 562.55 30.15 S 575.20 W 540942.52 6035359.52 HS 2.00 267.00 2460.60 2416.80 620.64 33.26 S 634.60'W 540883.15 6035356.08 MS 2.00 267.00 2538.85 2495.05 681.44 36.52 S 696.76 W 540821.01 6035352.47 HS 2.00 2800.00 41.50 267.00 2614.89 2571.09 744.87 2900.00 43.50 267.00 2688.61 2644.81 810.85 3000.00 45.50 267.00 2759.94 2716.14 879.30 3100.00 47.50 267.00 2828.77 2784.97 950.14 3200.00 49.50 267.00 2895.03 2851.23 1023.28 39.91 S 761.62 W 540756.18 6035348.71 HS 2.00 43.45 S 829.08 W 540688.75 6035344.80 MS 2.00 47.12 S 899.07 W 540618.78 6035340.74 HS 2.00 50.91 S 971.51 'W 540546.38 6035336.54 HS 2.00 54.83 S 1046.29 W 540471.62 6035332.21 HS 2.00 3300.00 51.50 3400.00 53.50 3500.00 55.50 3600.00 57.50 3700.00 59.50 3800.00 61.50 3900.00 63.50 4000.00 65.50 (A~nadrill (c)98 MPFSOP5 3.2C 9:50 AM P) 267.00 2958.63 2914.83 1098.64 58.87 S 1123.35 W 540394.60 6035327.74 HS 2.00 267.00 3019.50 2975.70 1176.12 63.02 S 1202.57 W 540315.41 6035323.14 HS 2.00 267.00 3077.57 3033.77 1255.63 67.28 S 1283.87 W 540234.15 6035318.43 MS 2.00 267.00 3132.76 3088.96 1337.07 71.65 S 1367.14 W 540150.91 6035313.~'0 HS 2.00 267.00 3185.01 3141.21 1420.34 76.11 S 1452.28 W 540065.80 6035308.66 MS 2.00 .I 267.00 3234.25 3190.45 1505.34 80.67 S 1539.19 W 539978.93 6035303.62 HS 2.00 267.00 3280.42 3236.62 1591.97 85.31 S 1627.77 W 539890.39 6035298.49 MS 2.00 267.00 3323.47 3279.67 1680.11 90.03 S 1717-_~.~__.~3~Q0.29 6035293.26 HS 2.00 _ ANADR~I L AKA-DPC FEASIBILITY PLAN NOT APPROVED EXECUTION I IDI A kl ,J..k ,_-.-~ MPF-80 TR22-B (P5A) 24 Sep 1998 Page 3 PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION VERTICAL-DEPTHS SECTION COORDINATES-FROM ALASKA Zone 4 TOOL DL/ IDENTIFICATION DEPTH A/qGLE AZIMUTH TVD SUB-SEA DEPART WELLHEAD X Y FACE 100 4100.00 67.50 267.00 3363.34 3319.54 1769.68 94.83 S 1809.47 W 539708.75 6035287.95 HS 2.00 4200.00 69.50 267.00 3399.99 3356.19 1860.54 99.70 S 1902.38 W 539615.88 6035282.56 HS 2.00 END 2.00/100 CURVE 4297.33 71.45 267.00 3432.52 3388.72 1950.13 104,50 S 1993.98 W 539524.32 6035277,25 HS 2.00 9-5/8" CSG PT <11> 5935.59 71.45 267,00 3953.80 3910.00 3467.01 185,78 S 3544.97 W 537973,96 6035187.31 HS 0,00 SCHRADER NA 5935.59 71.45 267.00 3953.80 3910.00 3467.01 185.78 S 3544.97 W 537973.96 6035187.31 HS 0.00 CURVE 2.50/100 6180.79 71.45 267.00 4031.82 3988.02 3694.04 197.95 S 3777.11 W 6200.00 71.50 266.50 4037.92 3994.12 3711.84 198.98 S 3795.29 W 6300.00 71.81 263.88 4069.40 4025.60 3805.14 206.94 S 3889.87'W 6400.00 72.15 261.28 4100.34 4056.54 3899.30 219,22 S 3984,15W 6500,00 72.52 2'58.68 4130.69 4086.89 3994.15 235.80 S 4077.98 W 537741.92 6035173.85 84L 0.00 537723.74 6035172.71 83L 2.50 537629.22 6035164.22 83L 2,50 537535.02 6035151.42 82L 2,50 537441.30 6035134.32 81L 2.50 TOP OB 6600.00 72.93 256.10 4160.38 4116.58 '4089.52 256.64 S 4171.16 W 6700.00 73.38 253.53 4189.37 4145.57 4185.22 281.71 S 4263.51 W 6800.00 73.85 250.97 4217.58 4173.78 4281.07 310.96 S 4354.87 W 6822.42 73.96 250.40 4223.80 4180.00 4302.56 318.08 S 4375.20 W 6900.00 74.35 248.43 4244.98 4201.18 4376.88 344.32 S 4445.07 W 537348.24 6035112.96 80L 2.50 537256.04 6035087.38 79L 2.50 537164.85 6035057.62 79L 2.50 537144.56 6035050.39 79L 2.50 537074.85 6035023.76 78L 2.50 BASE SCHRADER END 2.50/100 CURVE CURVE 2.50/100 6932.87 74.53 247.59 4253.80 4210.00 4408,34 356.18 S 7000.00 74.89 245.89 4271.51 4227.71 4472.48 381.75 S 7019.72 74.99 245.39 4276.63 4232.83 4491.30 389.60 S 10690.59 74.99 245.39 5227.06 5183.26 7991.34 1865.92 S 10700.00 74.76 245.39 5229.52 5185.72 8000.30 1869.70 S 10800.00 72.26 245.39 5257.90 5214.10 8094.95 1909.62 S 10900.00 69.76 245.39 5290.44 5246.64 8188.28 1948.99 S 11000.00 67.26 245.39 5327.07 5283.27 8280.12 1987.73 S 11100.00 64.76 245,39 5367.73 5323.93 8370.30 2025.77 S 11200.00 62.26 245.39 5412.33 5368.53 8458.64 2063.03 S 11300.00 59.76 245.39 5460.79 5416.99 8544.98 2099,45 S 11400.00 57.26 245.39 5513.02 5469.22 8629.15 2134.95 S 11500.00 54.76 245.39 5568.93 5525.13 8710.99 2169.47 S (Anadrill (c)98 MPF80P5 3'.2C 9:50 AM P) 4474.43 W. 537045.56 6035011.74 78L 2.50 4533.91 W 536986.23 6034985.84 77L 2.50 4551.27 W 536968.92 6034977.89 HS 2.50 7775.00 W 533753.81 6033483.72 LS 0.00 7783.25 W 533745.57 6033479.90 LS 2.50 7870.43,W 7956.39 W 8040.98 W 8124.04 W 8205.41'W 8284.93 W 8362.45 W 8437. 533658.63 6033439.49 LS 2.50 533572.90 6033399.65 LS 2.50 533488.53 6033360.44 LS 2.50 533405.69 6033321.95 LS 2.50 533324.54 6033284.23 LS 2.50 .1 533245.24 6033247.38 LS 2.50 533167.92 6033211.45 LS 2.50 ~--W---5'3~}~2-.-~4--60~13_~6~ LS 2.50 Al',! A n~n -,.' .... ,,:1.~ AKA-DPC F'.F. AS IBILITY PLAN NOT' APPROVED FOR EXECUTION PI A lxl 44. ~--/f ~ ,. MPF-80 TR22-B (P5A) 24 Sep 1998 Page 4 PROPOSED WELL PROFILE STATION IDENTIFICATION mmmm~m.mmm~...m.mmmm TOP HRZ BASE HRZ MEASURED INCLN DEPTH ANGLE 11600.00 52.26 11700.00 49.76 11800.00 47.26 11900.00 44.76 12000.00 42.26 12100.00 39.76 12200.00 37.26 12300.00 34.76 12400.00 32.26 12500.00 29.76 12600.00 27.26 12675.59 25.37 12700.00 24.76 12785.07 22.63 12800.00 22.26 mmmmmmmms lxmssmllxmmmmmmmm DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 245.39 5628.39 5584.59 245.39 5691.30 5647.50 245.39 5757.55 5713.75 245.39 5827.00 5783.20 245.39 5899.52 5855.72 SECTION COORDINATES-FROM DEPART WELLHEAD mmmum/ml mmmJmmmmmm lmmmmmmmmm 8790.34 2202.94 S 8510.92 W 8867.06 2235.30 S 8581.58~W 8940.99 2266.48 S 8649.68,W 9012.01 2296.44 S 8715.09 W 9079.96 2325.10 S 8777.68.W 245.39 5974.97 5931.17 9144.73 2352.42 S 245.39 6053.22 6009.42 9206.19 2378.34 S 245.39 6134.10 6090.30 9264.22 2402.82 S 245.39 6217.48 6173.68 9318.71 2425.81 S 245.39 6303.18 6259.38 9369.56 2447.25 S 245.39 6391.04 6347.24 9416.67 2467.13 S 245.39 6458.80 6415.00 9449.75 2481.08 S 245.39 6480.91 6437.11 9459.96 2485.38 S 245.39 6558.80 6515.00 9493.70 2499.62 S 245.39 6572.60 6528.80 9499.33 2501.99 S mmmmmmmmmmmmmmmmmmmm mmmm mmmm ALASKA Zone 4 TOOL DL/ X Y FACE 100 533019.85 6033142.63 LS .2.50 532949.38 6033109.88 LS 2.50 532881.46 6033078.32 LS 2.50 532816.23 6033048.00 LS 2.50 532753.80 6033018.99 LS 2.50 .. 8837.33,W 532694.31 6032991.34 LS 2.50 8893.94 W 532637.85 6032965.11 LS 2.50 8947.39 W 532584.55 6032940.33 LS 2.50 8997.58 W 532534.49 6032917.07 LS 2.50 9044.41 W 532487.78 6032895.36 LS 2.50 9087.81'W 532444.51 6032875.25 LS 2.50 9118,27'W 532414.12 6032861.13 LS 2.50 9127.67 W 532404.75 6032856.77 LS 2.50 9158.76 W 532373.75 6032842.37 LS 2.50 9163.94 W 532368.58 6032839.97 LS 2.50 TKL B 12871.09 20.48 END 2.50/100 CURVE 12890.37 20.00 TKU D (KUP CAPROCK) 13025.42 20.00 TKU B 13163.77 20.00 Tk'U A 13185.05 20.00 'i':iGT TR22-B ********* 13190.37 20.00 TKA 3 13190.37 20.00 TKA 2 13206.33 20.00 TKA 1 13232.94 20.00 MILUVEACH 13296.79 20.00 TD 7" LNR PT <1 I> 13596.79 20.00 (Anadrill (c)98 MPFSOP5 3.2C 9:50 AM P) 245.39 6638.80 6595.00 9524.90 2512.78 S 245.39 6656.89 6613.09 9531.49 2515.55 S 245.39 6783.80 6740.00 9577.08 2534.79 S 245.39 6913.80 6870.00 9623.79 2554.49 S 245.39 6933.80 6890.00 9630.97 2557.52 S 245.39 6938.80 6895.00 9632.77 2558.28 S 245.39 6938.80 6895.00 9632.77 2558.28 S 245.39 6953.80 6910.00 9638.16 2560.55 S 245.39 6978.80 6935.00 9647.14 2564.34 S 245.39 7038.80 6995.00 9668.70 2573.43 S 245.39 7320.71 7276.91 9769.98 2616.15 S 9187.49W 532345.09 6032829.05 LS 2.50 9193.56,W 532339.04 6032826.24 HS 2.50 9235.55 W 532297.16 6032806.77 HS 0.00 9278.57 W 532254.25 6032786.83 HS 0.00 9285.19 W 532247.65 6032783.77 HS 0.00 9286.85 W 532246.00 6032783.00 HS 0.00 9286.85 W 532246.00 6032783.00 HS 0.00 9291.81 W 532241.05 6032780.70 MS 0.00 9300.08 W 532232.80 6032776.87 HS 0.00 9319.94 W 532213.00 6032767.66 HS 0.00 .I 9413.23 W 532119.96 6032724.42 0.00 AN.AD~'t.L AKA-DPC FEASIBILITY PLAN NOT APPP,,OVED FOR, EXECUTION PLAN SHARED SERVI'CES 'DRTLL'TNG' A?'4AD';,., 't. L AKA-DPC Fr.. ,'~c I~!LITY PLAN NOT APPROVED FOP,' EXECUTION PLAN Anadril] Schlumberger ,. MPF-80 TR22-B (PSA) VERTICAL SECTION VIEW Section at' 254.60 TVB Scale.' 1 inch = 1500 feet · Dep Scale.' ] inch = ~500 feet Braw0 ' 24 Sep ~998 ~> i A "' Marker ldentifica[ion MO BKB SECTN INCL Al KB 0 0 0 0,0 :!), B __ B) KOP/CURVE 1.001100 500 500 -0 0.0 C-- C) cURVE 1.50/100 650 650 2 1.5 -- D ~v D) CURVE 2.00/100 850 850 12 4.5 E) END 2.00/100 CURVE 1800 ~767 236 23.E 'J F) CURVE 2.00/100 ~900 1859 275 23.~ ........... G) END 2.00/~00 CURVE 4297 3433 J950 7~.z , H) 9-5/8" CS6 PT <11> 5936 3954 3467 7~.z - ~A~E~D~F-¢~ I) CURVE 2.50/100 6~81 4032 3694 7~.Z J) END 2.50/~00 CURVE 7020 4277 449~ 74.~ K) CURVE 2.50/100 10691 5227 799~ 74.~ L) END 2.50/100 CURVE 12890 6657 9531 20.6 '~ M) TGT TR22-B ~~ 13~90 6939 9633 20.( N) TO 7" LNR PT <11> 13597 7321 9770 20.C , , ~-~¢~I-II-m ~4 ....................... ~ ................ ,..-'~.~. · , .... - ................. :~:~ " ~_i_.:._~:~_~i ~ .', - -:: -,~u=,~.~-.-,~,.-------.-------------.----.----------.---------~........ ................ ..... ;;;:i ~-;-~- ~~-' ' ' , 2250 75OO 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 go00 Section Departure ]r~]] (c)98 MPFSOP5 3.2C 9:50 AM P) 9750 10500 11250 12000 ~2750 SHARED SERVTCES DRZLLING - TR22 B (P5A) " \ IVlr-'F.OU ~ mr-r- u I,F,J~] VERTICAL SECTION VIEW · Q ~s~r- ~ ............ Sec(~on ~[: 254.60 i ~ TVD Scale.' ~ inch = ~00 ~e[ ) Oep Scale.' 1 inch = 100 feel Drawn · 24 Sep 1998 ~nadrJ]] $ch]umberger Marker Identification MD BKB SECTN INCLN ) A) END 2.50/t00 CURVE 128g0 6657 g§3! 20.00 B) TGT TR22-B ~~ 13JgO 693§ §633 20.00 C) TD 7" LNR PT <Il> 13597 732~ 9770 20.00. )-. _ _ 'T~'u'b-¢'u¢ ~iP'~O~Y - 'T~U~- ~ ....... :~: ~ ~ ~:~ ~ ~ ....... ~ .~,~- ~ ........ -T~A~ - ~¢ · ........... m I I I ~TL~VEACH 7039 ...... J [ A x~ AF'q IL AK ~-DPC O] AP'[)ROx~ED OR EX~(~U ~ ON ~, P_AN I 9300 9350 9400 9450 9500 g550 9600 9650 g700 9750 9800 9850 9900 9950 10000 SHAR'E'D' Marker Identification MD A) KB 0 B) KOP/CURVE 1.00/100 500 C) CURVE 1.50/100 650 D) CURVE 2.00/100 850 E) ENO 2.00/100 CURVE 1800 F) CURVE 2.00/100 1900 G) END 2.00/100 CURVE 4297 H) 9-5/8" CSG PT <11 > 5936 I} CURVE 2.50/t00 6181 J) ENB 2.50/100 CURVE 7020 K) CURVE 2.50/100 10691 L) END 2.50/100 CURVE 12890 M) TGT TR22-B ~***~***~ 13190 N) TI] 7" LNR PT <11> 13597 SERVT"cE'S' DRTL'LTN'G, ,[',,,, ',,'1 N/S ON OE, ON OE OS 1S 12 13 S 241 15 S 281 105 S 1994 186 S 3545 198 S 3777 39O S 4551 1866 S 7775 2516 S 9194 2558 S 9287 2616 S 9413 Anad?J ]] Schlumberger MPF-BO TR22-B (P5A) PLAN VIEW CLOSURE ' 9770 feet at Azimuth 254.47 DECLINATION.' +27.369 (E) SCALE ' 1 inch : 1200 feet DRAWN. ' 24 Sep 1998 ' ANADRILL AKA-DPC ;10200 9600 9000 8400 7800 7200 6600 6000 5400 4800 4200 3600 3000 2400 1800 1200 600 0 600 <- NEST' EAST -> i i aOrl)! (c)98 MPFSOP5 3.2C 9:51 AM P) Shared Services Drilling Contact: I Well Name: I Type of Well (producer or injector): Tom Maunder IMP F-80 Well Plan Summary 564-4429 I Kuparuk Producer Surface Location: 1943' NSL, 3046' WEL, Sec. 06, T13N ,R10E, UM., AK Target Kuparuk 4658' NSL, 1893' WEL, Sec. 11, T13N, R09E, UM., AK Bottom Hole Location: 4600' NSL, 2019' WEL, Sec. 11, T13N, R09E, UM., AK I AFE Number: 1337112 I Estimated Start Date: ! Rig: I Nabors 27-E 1 29 Oct. 98 [ I Operating days to complete: I 18 I MD: 113,597 I I TVD: 17,321' Bkb ! IKBE: i® Well Design: Ultra Slim Hole Long String HAW I 9-5/8", 40# Surface X 7", 29# Production Formation Markers: Formation Tops MD TVD (ss) EMW Formation Pressure Base Permafrost 1883 1800 8.4 ppg 786 psi NA Top Schrader Bluff 5935 3910 8.4 ppg 1727 psi OB Base Schrader Bluff 6932 4210 8.4 ppg 1856 psi TKUD 13025 6740 9.9 ppg 3469 psi TKUB 13163 6870 9.9 ppg 3536 psi TKUA 13185 6890 9.9 ppg 3547 psi TKUA3FFarget 13190 6895 9.9 ppg 3550 psi TKUA2 13206 6910 9.9 ppg 3569 psi TKA1 13233 6935 9.9 ppg 3577 psi Miluveach 13297 6995 9.1 ppg 3337 psi =l-otal Depth 13597+ 7277_+ 9.1 ppg 3612 psi · *These are estimated maximum pressures and the actual pressures may be lower. CasingJ'l'ubing Program: Hole ~ize Csg'/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 BOSS 5,804 31/31 5,835/3,930 8-1/2" 7" 29# L-80 Hyd ril 13,567 30/30 13,597/7,321 563 The internal yield pressure of the 7" 29# casing is 8,160 psi. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at _+ 6,935 TVDbkb In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of _--,-6,935 TYDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,577 psi is 2883 psi using a 0.1 psi/ft gas gradient, well below the internal yield pressure rating of the 7" ca_sing. PAGE I TEM10/15/982:04 PM Cementing Program: Halliburton Cementin( Services Hole Casing Interval & Vol~'me~ Spacer Type of Cement Properties~ Cate~lory Size/Depth Excess Surface Lead4 Lead Lead Lead. First Stage 9~5/8'' @ 2,083-5,335' 635 sx 70 bbls Permafrost "E" Den 12.0 ppg 8,851' @ 30% 245 bbls Fresh water Yield 2.17 ft 3/sx excess Water 11.63 gps TT 4.0 hrs 5,335-5,835' Tail5 Tai~l Tai~l @ 30% 180 sx Premium Class "G' w/ Den 15.8 ppg excess 36 bbls 0.2 % CaCl, 0.15 #/sk Floceele Yield 1.15 ft 3/sx Water 4.9 gps TT 4.0 hrs Second Sta[je L~adb Lead Lead Lead Stage collar° @ 0-1,933' 985 sx 75 bbls Permafrost "E' Den 12.0 ppg 2,083' @ 250% 380 bbls Fresh water Yield 2.17 ft 3/sx excess Water 11.63 gps TT 4.0 hrs Tail5 1,933'-2,083' 175 sx Tai~l Tai.__[ @ 250% 30 bbls Permafrost "C" Den 15.6 ppg excess Yield 0.96 ft 3/sx Water 3.65 gps TT 4.0 hrs Production 7" @ 12,163'- Lead~ ~ Lead Lead Den 15.8 ppg First Stage 19,197' 13,597' 200 sx 70 bbls. Premium Class "G" w/ Yield 1.15 ft 3/sx 41 bbls NSCI Spacer 0.2 % CFR-3 Water 5.0 gps 0.1% HR-5 TT 3.5-4.5 hrs @140° F 0.45% Halad 344 FL 50cc/30 min @140° F 1. Volumes zre rounded up to the nearest 0 sacks. 2. Ensure thickening times are adequate relative to pumping job requirement. Actual times should be based on job requirements and lab tests. Perform lab tests on mixed cements, spacers and mud's to ensure compatibility prior to pumping job. 3. A Type H ES Cementer will be installed in the 9-5/8" csg. 200' md below the base of the Permafrost at 2,083'MD_+ 4. The calculated first stage lead is designed to fill from the 9-5/8"' ES Cementer at 2,083' md to 5,335' md which is 500' above the shoe plus 30% Excess. 5. The calculated first stage tail cement volume is designed to fill from 500' md above the shoe to surface TD at 5,835' md (3,930 TVD bkb) plus 30% open hole excess and 80' 9-5/8", 40# casing shoe joint volume. 6. The surface hole Second Stage Lead Cement Volume covers the interval from 0-1,933' md The designed second stage lead cement volume includes 250% open hole excess.. 7. The surface hole Second Stage Tail Cement Volume covers the interval from 1:933-2,083' md The calculated second stage tail cement volume includes 250% open hole excess. 8. Install one(l) Bow Spring Centralizers per joint on the bottom 10 joints of 9-5/8" casing (required). 9. This casing depth is planned to be above the Schrader Bluff. The Schrader Bluff is prognosed to be wet. 10. The production hole is planned as a single stage, however if the LWD logs indicate hydrocarbon in the Schrader a second stage will be pumped. The first stage estimated cement volume is designed to cover the interval from 12,163' md (1000'+ above the Kuparuk B Sand) to TD at 13,597' plus 30% open hole excess and the shoe joint volume of 80' md of 7", 29# casing. 11. Use 7" x 8-1/4" Straight Blade Rigid Centralizers and install one per joint from above the float collar to 120' above the Kupaurk B-Sand. Use two centralizers per joint on the shoe joints. 12. If the Schrader Bluff is hydrocarbon bearing, a centralizer recommendation will be provided. 13. Install two 7" marker joints and position three joints above the Kuparuk B sand. 14. Place all centralizers in middle of joints using stop collars. 15. Mix all cement slurries in the surface and production holes on the fly - batch mixing is no~t necessary. PAGE 2 TEM 2:04 PM 10/15/98 Logging/Formation Evaluation Program: Anadrill Schlumberger Open Hole Logs: None Surface-12-1/4" 1. MWD/LWD D&I / GR / DWOB / DTQE from spud to TD of surface hole, real time & recorded 9-5/8" Cased Hole 1. Gyrodata multi-shot survey of 9-5/8" casing after drillout. Survey is needed for target sizing. This will accomplish an in hole reference as on earlier wells. 1. MWD/LWD D& I/C D R/G R/A D N/PW D/DWO B/DTQ E ADN is only required from the 'D' shale to TD, real time and recorded. All other logs required from drill out of 9-5/8" to TD, real time and recorded. 2. Open Hole: DP conveyed RFT/GR if Kuparuk is oil bearing. 1. None planned. 1. Schlumberger IDEAL System in the surface and production holes. SPIN Log: Record: GR, Depth, Surface Torque and DWOB/DTOQ, ROP, Hook Load, RPM, Pump Pressure, GPM (in and out) during all operations. Final Production 8-1/2" .Cased Hole Logs: Mud Logging 12-1/4" and 8-3/4" Hole M10 PowerPlus DWOB/DTQE: GR: CDR: ADN: ROP: PWD Directional Inclination and Azimuth DWOBB/DTOQ Gamma Ray Compensated Dual Resitivity Azimuthal Density Neutron (Density, Porosity, and Sonic Caliper) Rate of penetration Pressure While Drilling Mud Program: Baroid Drilling Fluids Inc. Surface Mud Properties: LSND Freshwater Mud Density Marsh Yield 10 sec 10 min pH Fluid Solids (PPG) Viscosity Point ~lel ~lel Loss % 8.6-9.4 50-150 15-35 8-15 10-30 9-10 8-15 <10 Production Mud Properties to Change LSND Freshwater Mud Over Depth at TKUD Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel gel Filtrate %LGS 8.6-9.3 35-45 6-20 3-10 7-20 8.5-9.5 6-12 NC <6 Production Mud Properties from HRZ to LSND Freshwater Mud TD. Density Marsh Yield 10 sec 10 min pH APl HTHP Solids (PPG) Viscosity Point gel ~lel Filtrate %LGS 10.5 35-45 6-20 3-10 7-20 8.5-9.5 <4 10-12 for <6 HRZ Miluveach Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. The diverter, BOPE and drilling fluid system schematics are on file with AOGCC. PAGE 3 TEM 2:04 PM 10/15/98 Directional: KOP1 500' Start Variable @ 1.0% 2.5°/100 to 71.4° inc. and 245.4° az. EOB @ 4,297 71.4o-75° from 4,297-10,690' Tangent Hole Angle Final Drop Maximum Hole Angle Close Approach Wells Survey Program Start Final Drop 10,690' @ 2.5°/100 to 20° incl. 245.4 Az° EOD 12,890' md 75° from 7,020-10,690'. All wells may remain flowing while drilling F-80 and no shut-ins are required. 1. Surface to 5,804' MWD surveys. 2. 5,804'-TD MWD surveys. Disposal: No "Drilling Wastes" will be injected or disposed into F-80 while drilling this well. Cuttinqs Handlin¢l: 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. Fluids Handling: All drilling wastes will be hauled off and disposed of in accordance with pertinent rules and regulations. GENERAL DISCUSSION Well Obiective: MPU F-80 is planned as a Kuparuk River A Sand producer tapping an undrilled fault block to the southwest of F-Pad. TD is planned at 13,597' with a final departure of 9,770'. The well is S-shaped with a final angle of 20°. The surface casing will be shallow set above the Schrader Bluff at 5,835' (3,930' TVD bkb). The casing is shallow set to preserve sidetrack options should the intended reservoir target prove non-productive. It is intended to set the casing in a shale interval between the base of the Ugnu and the top of the Schrader Bluff. In well F-95i, the shale interval is 3990-4020' TVD. Geology This well is located to the southwest of F-Pad. The primary targets are the Kupauuk A sands. No major faulting is anticipated while drilling this well in the Kuparuk Reservoir however there is some potential faulting uphole in the Colville Brookian unconformity. Recoverable reserves associated with this producer are 1.18 MMBO. DRILLING HAZARDS AND RISKS SUMMARY: Formation pressures are expected to be virgin in this undrilled fault block. Reservoir pressure is estimated at 3547 psi at 6933' tvd, (9.9 ppg EMW) in the Kuparuk formation. The well profile has been designed to avoid close approaches and no wells will be shut in while drilling this well. The shallow set surface casing design is has been planned for this well to preserve a sidetrack option should the intended target be determined non- productive. Close Approaches There are no close approaches associated with the drilling of MP F-80, however, tolerance lines should be carefully monitored and deviations from the proposed well path minimized. Water~ Gas and WAG Injection This is an undrilled fault block. Milne Point production and injection are not expected to have effected the area. There is a possibility of some effect from ARC©'s 3R-20 injection well if the fault block is not isolated. Annular Iniection Currently annular injection is not permitted on F-Pad. PAGE 4 TEM 2:04 PM 10/15/98 Lost Circulation: Lost circulation is prevalent while running casing and cementing in the surface but also occurs in the production hole. Losses are extremely probable while cementing the production casing in wells with shallow set surface casing. Losses have been experienced while drilling the 12-1/4" surface and while circulating to condition mud before, while and after running surface casing to bottom. Major losses have also occurred while cementing the production casing. In many instances, the losses were minimized by reducing swab and surge pressures, minimizing mud weight and conditioning the mud before cementing. Contingencies have been incorporated to well program remedy loses if encountered. Mud weights will be maintain between 9.1-9.4 ppg down to the D shale as usual. Treatments of LCM may be added to the mud to "plate" off the Schrader Bluff sands as well as others exposed in the wellbore. The intent of adding LCM is in preparation for the increased mud weight necessary to drill the virgin pressure Kuparuk. Stuck Pipe Potential: Running gravel's, sticky clays, tight coal sections, packing off, bridging, and stuck pipe have occurred while drilling the 12 1-4" surface holes on F-Pad. Excessive amounts of reaming have been required to condition the hole to run surface casing. While running 9-5/8" casing the following problems were experienced: hole packing. off; tight hole, bridging, and stuck casing. While drilling the surface hole additional time has been spent- reaming and conditioning the hole prior to cementing because of tight hole. Attention should be given to the- Ugnu formation to reduce the chances of differential sticking in these formation with higher mud's weights. Differential sticking concerns will also exist in the production interval since the Schrader Bluff sands will be exposed below the shoe. The LCM additions mentioned previously should help "plate" off the sands to allow increase mud weight tolerance. While drilling the production section increased torque and drag have been experienced after drilling into Kuparuk D Shale. This common occurrence has often caused difficulties, so care should be taken to avoid the stuck pipe potential while drilling the 8-3/4" production interval. Shale instability is possible in the Miluveach and may result in tight hole or packing off so preventative measures must be taken to alleviate this risk if the Miluveach is inadvertently entered without treating the mud system.. Differential sticking is most likely to occur while running the production string. Formation Pressure: KUPARUK A1 SAND 6,935' TVDss 3,577 PSI 9.9 PPG EMW Formation pressures are expected to be virgin and the pore pressure is estimated at 9.9 ppg EMW. The deepest anticipated gas should occur no deeper than the oil water contact which is expected below the TKA1 at + 7534' TVDss. In this instance, this worst case surface pressure would occur with a full column of gas from the reservoir from a depth of +_6,935' TVDbkb. The maximum anticipated surface pressure in this case assuming a reservoir pressure of 3,577 psi is 2,883 psi. Higher pore pressure values are not expected however, there is the potential of some effect due to ARCO's 3R-20 injection well. See the updated Milne Point F-Pad Data Sheet prepared by Pete Van Dusen for information on F pad and review recent wells drilled on F Pad. PAGE 5 TEM 2:04 PM 10/15/98 MP F-80 Kuparuk Producer Proposed Summary of Operations . . . . . 10. 11. 12. 13. 14. 15. 16. Drill and Set 20" Conductor. Weld an FMC landing ring for an FMC Gen 5 Well head on conductor as well as a nipple to aid in performing potential well head stability cement job. Prepare location for rig move. MIRU Nabors 27E drilling rig. NU and test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by an AOGCC supervisor. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD/LWD (GR/DIR/DWOB/DTOQ) from surface to 12-1/4" TD. Corrolate GR data with prior wells to identify- casing seat. " Run 9-5/8" casing. Space out ES Type H Cementer to 2,083' md. Perform Two Stage Cement Job. Complete the surface casing cementing check list. ND 20" Diverter, NU and Test 13-5/8" BOP MU a PDC bit on an extended power section medium speed motor, with Directional MWD and LWD (GR/DIR/CDR/DWOB/DTOQ/PWD). RIH, Drill out Float Equipment and 20' of new formation. Perform the FIT as per Recommended Practices Manual. Record pressure versus cumulative volume during the LOT test for the well file. Drill 8.75" hole to TD as per directional plan. Use PWD information to assess hole cleaning. Observe for losses as mud weight is increased to enter the Kuparuk sands. Make sure sufficient footage is drilled to provide 250' of production rat hole between the top of the Kuparuk A3 sand and PBTD before running the 7" casing. Condition hole and POOH for DP conveyed RFT. Prospective intervals will be chosen by geology. Following RFTs, make wiper trip and POOH for casing. Run 7" casing. Perform Single Stage Cement Job. If the Schrader sands are determined to be hydrocarbon bearing, a second stage cement job will be designed to provide necessary isolation. Complete the production casing cementing check list. Displace cement with 9.9 ppg brine and enough diesel to cover from the base of permafrost to surface (+-2200' MD). Bump the plug and test casing to 3500 psig for 5 minutes. Bleed off pressure and check floats. ND BOPE and 11" drilling spool NU tubing spool and dry hole tree and Test Tree. RDMO Nabors 27E. 17. RDMO Nabors 27E. THE WORKOVER PROGRAM WITH A DETAILED COMPLETION PROCEDURE SHALL BE SUBMITTED ONCE THE PERFORATION INTER VALS ARE SELECTED. PAGE 6 TEM 2:04 PM 10/15/98 Anadrill Schlumberger ~, Alaska Dis~r~c~ 3940 Arctic Blvd. Anchorage, AK 99503 (907) 273-1700 Fax 561-8537 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING Well ......... : MPF-80 TR22-B (P5A) Field ........ : Milne Point Computation..: Minimum Curvature Units ........ : FEET Surface Lat..: 70.50761606 N Surface Long.: 149.66031677 W Legal Description Surface ...... : 1942 FSL 3046 FEL Target TR22B.: 4658 FSL 1893 FEL BHL .......... : 4600 FSL 2019 FEL LOCATIONS - ALASKA Zone: X-Coord S06 T13N R10E b~4 541517.49 Sll T13N R09E UM 532246.00 Sll T13N R09E UM 532119.96 4 Y-Coord 6035392.88 6032783.00 6032724.42 PROPOSED WELL PROFILE ~m~mmmmmmmmmmmmmmmmm mmmmmmmm mmmmmm STATION MEASURED INCLN IDENTIFICATION DEPTH ANGLE KB 0.00 0.00 KOP/CURVE 1.00/100 500.00 0.00 600.00 1.00 CURVE 1.50/100 650.00 1.50 700.00 2.25 mmmmmmmmm mmmmmmmmmmmmmmmmm DIRECTION VERTICAL-DEPTHS AZIMUTH TVD SUB-SEA 0.00 0.00 -43.80 267.00 500.00 456.20 267.00 599.99 556.19 267.00 649.98 606.18 267.00 699.96 656.16 Prepared ..... : 24 Sep 1998 Vert sect az.: 254.60 KB elevation.: 43.80 ft Magnetic Dcln: +27.369 (E) scale Factor.: 0.99990196 ..~onvergence..: +0.32021499 mmmmmmmm SECTION COORDINATES-FROM . DEPART WELLHEAD , 0.00 0.00 N 0.00 E -0.00 0.00 N 0.00 E 0.85 0.05 S 0.87 W 1.92 0.10 S 1.96 iW 3.52 0.19 S 3.59 W ANADRiLL AKA-DPC FEAS ! B I L ITY P LAN NOT APPROVED FOR EXECUTION PLAN i i L ~ m~ = ALASKA Zone 4 X Y 541517.49 6035392.88 541517.49 6035392.88 541516.62 6035392.83 541515.53 6035392.77 541513.90 6035392.67 CURVE 2.00/100 800.00 3.75 850.00 4.50 900.00 S.50 1000.00 7.50 1100.00 9.50 267.00 799.82 756.02 267.00 849.69 805.89 267.00 899.50 855.70 267.00 998.85 955.05 267.00 1097.74 1053.94 8.63 0.46 S 8.82 W 12.14 0.65 $ 12.41 W 16.40 0.88 S 16.76 W 27.45 1.47 S 28.07 W 41.89 2.24 S 42.83 W 541508.67 6035392.37 541505.08 6035392.16 541500.73 6035391.91 541489.43 6035391.25 541474.68 6035390.40 mmmm mmmm TOOL DL/ FACE 100 93L 0.00 93L 0.00 93L 1.00 93L 1.00 93L 1.50 93L 1.50 93L 1.50 HS 2.00 .I HS 2.00 HS 2.00 1200.00 11.50 1300.00 13.50 267.00 1196.06 1152.26 267.00 1293.69 1249.89 59.68 80.82 3.20 S 61.03 W 4.33 S 82.64 W 541456.49 6035389.34 HS 2.00 5~1434.88 6035388.09 HS 2.00 (Anadrill (c)98 MPF80P5 3.2C 9:50 AM P) MPF-80 TR22-B (PSA) 24 Sep 1998. Page 2 PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION VERTICAL-DEPTHS SECTION COORDINATES-FROM AI~ASKA Zone 4 TOOL DL/ iDENTIFICATION DEPTH ANGLE AZIMUTH TVD SUB-SEA DEPART WELLHEAD X Y FACE 100 1500.00 17.50 267.00 1486.38 1442.58 133.01 7.13 S 136.00 W 541381.54 6035384.99 HS 2.00 1600.00 19.50 267.00 1581.20 1537.40 164.00 8.79 S 167.69 W 541349.87 6035383.16 HS 2.00 1700.00 21.50 267.00 1674.87 1631.07 198.20 10.62 S 202.66 W 541314.91 6035381.13 HS 2.00 END 2.00/100 CURVE 1800.00 23.50 267.00 1767.25 1723.45 235.58 12.62 S 240.87 W 541276.71 6035378.91 MS 2.00 BASE PERMAFROST CURVE 2.00/100 1883.47 23.50 267.00 1843.80 1800.00 268.08 14.37 S 274.11 W 541243.49 6035376.98 HS 0.00 1900.00 23.50 267.00 1858.96 1815.16 274.52 14.71 S 280.69 W 541236.91 6035376.60 MS 0.00 2000.00 25.50 267.00 1949.95 1906.15 315.02 16.88 S 322.10 W 541195.52 6035374.20 HS 2.00 2100.00 27.50 267.00 2039.44 1995.64 358.60 19.22 S 366.66 W 541150.98 6035371.62 HS 2.00 2200.00 29.50 267.00 2127.31 2083.51 405.20 21.71 S 414.31 W 541103.35 6035368.85 HS 2.00 2300.00 31.50 267.00 2213.47 2169.67 454.76 2400.00 33.50 267.00 2297.81 2254.01 507.24 2500.00 35.50 267.00 2380.21 2336.41 562.55 2600.00 37.50 267.00 2460.60 2416.80 620.64 2700.00 39.50 267.00 2538.85 2495.05 681.44 24.37 S 464.99 W 541052.69 6035365.92 HS 2.00 27.18 S 518.64 W 540999.06 6035362.80 HS 2.00 30.15 S 575.20 W 540942.52 6035359.52 HS 2.00 33.26 S 634.60'W 540883.15 6035356.08 HS 2.00 36.52 S 696.76 W 540821.01 6035352.47 HS 2.00 2800.00 41.50 267.00 2614.89 2571.09 744.87 39.91 S 761.62 W 540756.18 6035348.71 HS 2.00 2900.00 43.50 267.00 2688.61 2644.81 810.85 43.45 S 829.08 W 540688.75 6035344.80 HS 2.00 3000.00 45.50 267.00 2759.94 2716.14 879.30 47.12 S 899.07 W 540618.78 6035340.74 HS 2.00 3100.00 47.50 267.00 2828.77 2784.97 950.14 50.91 S 971.51 W 540546.38 6035336.54 HS 2.00 3200.00 49.50 267.00 2895.03 2851.23 1023.28 54.83 S 1046.29 W 540471.62 6035332.21 HS 2.00 3300.00 51.50 267.00 2958.63 2914.83 1098.64 3400.00 53.50 267.00 3019.50 2975.70 1176.12 3500.00 55.50 267.00 3077.57 3033.77 1255.63 3600.00 57.50 267.00 3132.76 3088.96 1337.07 3700.00 59.50 267.00 3185.01 3141.21 1420.34 3800.00 61.50 267.00 3234.25 3190.45 1505.34 3900.00 63.50 267.00 3280.42 3236.62 1591.97 4000.00 6~.50 267.00 3323.47 3279.67 1680.11 (Anadrill (c)98 MPFSOP5 3.2C 9:50 AM P) 58.87 S 1123.35 W 540394.60 6035327.74 HS 2.00 63.02 S 1202.57'W 540315.41 6035323.14 HS 2.00 67.28 S 1283.87 W 540234.15 6035318.43 HS 2.00 71.65 S 1367.14 W 540150.91 6035313.~'0 HS 2.00 76.11 S 1452.28 W 540065.80 6035308.66 HS 2.00 .1 80.67 S 1539.191W 539978.93 6035303.62 HS 2.00 85.31 S 1627.77 W 539890.39 6035298.49 HS 2.00 90.03 S 1717-_~Q..~__.~3~Q0.29 603~293.26 HS 2.00 _ ANADR~I L AKA-DPC FEASIBILITY PLAN NOT APPROVED 7OR EXECUTION MPF-80 TR22-B (PSA) 24 Sep 1998 Page 3 PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION VERTICAL-DEPTHS SECTION COORDINATES-FROM ALASKA Zone 4 TOOL DL/ iDENTIFiCATION DEPTH ANGLE AZIMUTH TVD SUB-SEA DEPART WELLHEAD X Y FACE 100 4100.00 67.50 267.00 3363.34 3319.54 1769.68 94.83 S 1809.47 W 539708.75 6035287.95 HS 2.00 4200.00 69.50 267.00 3399.99 3356.19 1860.54 99.70 S 1902.38 W 539615.88 6035282.56 HS 2.00 END 2.00/100 CURVE 4297.33 71.45 267.00 3432.52 3388.72 1950.13 104.50 S 1993.98'W 539524.32 6035277.25 HS 2.00 9-5/8" CSG PT <11> 5935.59 71.45 267.00 3953.80 3910.00 3467.01 185.78 S 3544.97 W 537973.96 6035187.31 HS 0.00 SCHRADER NA 5935.59 71.45 267.00 3953.80 3910.00 3467.01 185.78 S 3544.97 W 537973.96 6035187.31 HS 0.00 CURVE 2.50/100 6180.79 71.45 267.00 4031.82 3988.02 3694.04 197.95 S 3777.11 W 537741.92 6035173.85 84L 0.00 6200.00 71.50 266.50 4037.92 3994.12 3711.84 198.98 S 3795.29 W 537723.74 6035172.71 83L 2.50 6300.00 71.81 263.88 4069.40 4025.60 3805.14 206.94 S 3889.87'W 537629.22 6035164.22 83L 2.50 6400.00 72.15 261.28 4100.34 4056.54 3899.30 219.22 S 3984.15 W 537535.02 6035151.42 82L 2.50 6500.00 72.52 258.68 4130.69 4086.89 3994.15 235.80 S 4077.98 W 537441.30 6035134.32 81L 2.50 TOP OB 6600.00 72.93 256.10 4160.38 4116.58 '4089.52 256.64 S 4171.16 W 537348.24 6035112.96 80L 2.50 6700.00 73.38 253.53 4189.37 4145.57 4185.22 281.71 S 4263.51 W 537256.04 6035087.38 79L 2.50 6800.00 73.85 250.97 4217.58 4173.78 4281.07 310.96 S 4354.87 W 537164.85 6035057.62 79L 2.50 6822.42 73.96 250.40 4223.80 4180.00 4302.56 318.08 S 4375.20W 537144.56 6035050.39 79L 2.50 6900.00 74.35 248.43 4244.98 4201.18 4376.88 344.32 S 4445.07 W 537074.85 6035023.76 78L 2.50 BASE SCHRADER 6932.87 74.53 247.59 4253.80 4210.00 4408.34 356.18 S 4474.43 W, 537045.56 6035011.74 78L 2.50 7000.00 74.89 245.89 4271.51 4227.71 4472.48 381.75 S 4533.91 W 536986.23 6034985.84 77L 2.50 END 2.50/100 CURVE 7019.72 74.99 245.39 4276.63 4232.83 4491.30 389.60 S 4551.27 W 536968.92 6034977.89 HS 2.50 CURVE 2.50/100 10690.59 74.99 245.39 5227.06 5183.26 7991.34 1865.92 S 7775.00 W 533753.81 6033483.72 LS 0.00 10700.00 74.76 245.39 5229.52 5185.72 8000.30 1869.70 S 7783.25 W 533745.57 6033479.90 LS 2.50 10800.00 72.26 10900.00 69.76 11000.00 67.26 11100.00 64.76 11200.00 62.26 245.39 5257.90 5214.10 8094.95 1909.62 S 7870.43.W 533658.63 6033439.49 LS 2.50 245.39 5290.44 5246.64 8188.28 1948.99 S 7956.39 W 533572.90 6033399.65 LS 2.50 245.39 5327.07 5283.27 8280.12 1987.73 S 8040.98 W 533488.53 6033360.44 LS 2.50 245.39 5367.73 5323.93 8370.30 2025.77 S 8124.04 W 533405.69 6033321.95 LS 2.50 245.39 5412.33 5368.53 8458.64 2063.03 S 8205.41'W 533324.54 6033284.23 LS 2.50 .1 11300.00 59.76 245.39 5460.79 5416.99 8544.98 2099.45 S 8284.93 W 533245.24 6033247.38 LS 2.50 (Anadrill {c)98 MPFSOP5 3'.2C 9:50 AM P) 11400.00 57.26 245.39 5513.02 5469.22 8629.15 2134.95 S 8362.45 W 533167.92 6033211.45 LS 2.50 11500.00 54.76 245.39 5568.93 5525.13 8710.99 2169.47 S 8437.8 L-~---5'~}9-2-.-~4~-6/1/3_1~=.5_~ LS 2.50 AN .",r').. R, r l. L AKA-DPC FEASIBILITY PLAN NOT, APPROVED FOR EXECUTION MPF-80 TR22-B (P5A) 24 Sep 1998 Page 4 PROPOSED WELL PROFILE STATION MEASURED INCLN DIRECTION VERTICAL-DEPTHS SECTION COORDINATES-FROM ALASKA Zone 4 TOOL DL/ iDENTIFICATION DEPTH ANGLE AZIMUTH TVD SUB-SEA DEPART WELLHEAD X Y FACE 100 11600.00 52.26 245.39 5628.39 5584.59 8790.34 2202.94 S 8510.92 W 533019.85 6033142.63 LS 2.50 11700.00 49.76 245.39 5691.30 5647.50 8867.06 2235.30 S 8581.58'W 532949.38 6033109.88 LS 2.50 11800.00 47.26 245.39 5757.55 5713.75 8940.99 2266.48 S 8649.68.W 532881.46 6033078.32 LS 2.50 11900.00 44.76 245.39 5827.00 5783.20 9012.01 2296.44 S 8715.09 W 532816.23 6033048.00 LS 2.50 12000.00 42.26 245.39 5899.52 5855.72 9079.96 2325.10 S 8777.68,W 532753.80 6033018.99 LS 2.50 .. 12100.00 39.76 245.39 5974.97 5931.17 9144.73 2352.42 S 8837.33.W 532694.31 6032991.34 LS 2.50 12200.00 37.26 245.39 6053.22 6009.42 9206.19 2378.34 S 8893.94 W 532637.85 6032965.11 LS 2.50 12300.00 34.76 245.39 6134.10 6090.30 9264.22 2402.82 S 8947.39 W 532584.55 6032940.33 LS 2.50 12400.00 32.26 245.39 6217.48 6173.68 9318.71 2425.81 S 8997.58 W 532534.49 6032917.07 LS 2.50 TOP HRZ BASE HRZ 12500.00 29.76 12600.00 27.26 12675.59 25.37 12700.00 24.76 12785.07 22.63 12800.00 22.26 245.39 6303.18 6259.38 9369.56 2447.25 S 9044.41 W 532487.78 6032895.36 LS 2.50 245.39 6391.04 6347.24 '9416.67 2467.13 S 9087.81 W 532444.51 6032875.25 LS 2.50 245.39 6458.80 6415.00 9449.75 2481.08 S 9118.27 W 532414.12 6032861.13 LS 2.50 245.39 6480.91 6437.11 9459.96 2485.38 S 9127.67 W 532404.75 6032856.77 LS 2.50 245.39 6558.80 6515.00 9493.70 2499.62 S 9158.76 W 532373.75 6032842.37 LS 2.50 245.39 6572.60 6528.80 9499.33 2501.99 S 9163.94 W 532368.58 6032839.97 LS 2.50 TKL B 12871.09 20.48 245.39 6638.80 6595.00 9524.90 2512.78 S 9187.49W 532346.09 6032829.05 LS 2.50 END 2.50/100 CURVE 12890.37 20.00 245.39 6656.89 6613.09 9531.49 2515.55 S 9193.56,W 532339.04 6032826.24 HS 2.50 TKU D (KUP CAPROCK) 13025.42 20.00 245.39 6783.80 6740.00 9577.08 2534.79 S 9235.55 W 532297.16 6032806.77 HS 0.00 TKU B 13163.77 20.00 245.39 6913.80 6870.00 9623.79 2554.49 S 9278.57 W 532254.25 6032786.83 HS 0.00 TKU A 13185.05 20.00 245.39 6933.80 6890.00 9630.97 2557.52 S 9285~19 W 532247.65 6032783.77 HS 0.00 TGT TR22-B .... ***** 13190.37 20.00 TKA 3 13190.37 20.00 TKA 2 13206.33 20.00 TKA 1 13232.94 20.00 MILUVEACH 13296.79 20.00 TD 7" LNR PT <[ I> 245.39 6938.80 6895.00 9632.77 2558.28 S 9286.85 W 532246.00 6032783.00 HS 0.00 245.39 6938,80 6895.00 9632.77 2558.28 S 9286.85W 532246.00 6032783.00 HS 0.00 245,39 6953.80 6910.00 9638.16 2560.55 S 9291.81 W 532241.05 6032780.70 HS 0.00 245.39 6978.80 6935.00 9647.14 2564.34 S 9300.08 W 532232.80 6032776,87 HS 0.00 245.39 7038.80 6995.00 9668.70 2573.43 S 9319.94 W 532213.00 6032767.66 HS 0.00 .1 13596.79 20.00 245.39 7320.71 7276.91 9769.98 2616.15 S 9413.23 W 532119.96 6032724.42 0.00 (Anadrill (c)98 MPFSOP5 3.2C 9:50 AM P) AN.,.t'-,DR :I.L AKA-DPC FEASIBILITY PLAN NOT APPROVED FOP., ~X/r-,~ t:/ , :uUTION PLAN SHARED SLRVlCLS DRILLING "'~ u.,.,, uL AKA-DPC 1-~, l",i .h, '"', ~'," FE:,,XSI B! LIT¥ PLAN NOT APPROVED FOR. EXECUTION PLAN Anadr~ ]] Schlumberger MPF-80 TR22-B (P5A) VERTICAL SECTION VIEW Section at' 254.60 TVD Scale.' 1 inch = 1500 feet · Oep Scale.' 1 inch = 1500 feet Draw0 · 24 Sep 1998 x Marker Ident if icat ion MO BKB SECTN INCLI A) KB 0 0 0 O. O~ B-- B) KOP/CURVE 1.00/100 500 500 -0 0.0 _.____C~,- C) cuRvE 1.50/100 650 850 2 ~.5 O-F D) CURVE 2.00/100 850 850 12 4.5 E) END 2.00/100 CURVE 1800 1767 235 23.5 F) CURVE 2.00/100 1900 1859 275 23.5 -- ~ ..... G) END 2.00/100 CURVE 4297 3433 ~950 71.45 -L H) 9-5/8" CSG PT <11 > 5936 3954 3467 71.45 -~ ~A~E-P~'R~A~I"-I'~ I) CURVE 2.50/100 6181 4032 3694 7~.4 J) END 2.50/100 CURVE 7020 4277 4491 74.9 K) CURVE 2.50/100 10691 5227 799~ 74.9 L) ENB 2.50/100 CURVE 12890 6657 9531 20.0 M) TGT TR22-B *~~ 13190 6939 9633 20,0 - N) TD 7" LNR PT <il > 13597 7321 9770 20.(3 ..... ,, ................... H,,,I, %~=o¢~.,~ ,~, i,~Z_"" ................ --~-~-,~,~o~'""-'...._ ......i~'-'----'-"'--'---'--'----'"'""-'"'-'-'---'-"-'--------:-':---'-'"" i'¢~-~7; ~'~-~;ii~t-;-;-;- ;-;-;;7' .I~~o~,_- ~...... ,,,,,,.,,,,, ,,,,, ..,,, ,.,,,,,,,,, ,,,,,,.,.,,,,,,,.,,,,, 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 , 9750' , 10500 11250 12000 12750 Section DeParture , , , 1 (C)98 MPFGOP§ 3.2C 9:50 AM P) SHARED SERVICES DRILLING ~oo- NNN MPF-80 TR22-B (P5A) VERTICAL SECTION VIEW 6550--- ~ ' -~rr, qr-~3~ Section at: 254.60 TVD Scale ' 1 inch = 100 l'~et 66oo- JDep Scale.' 1 inch = 100 feel Drawn · 24 Sep 1998 6650_ I'KL B 66:9 , ,4nadrJ l] Schlumberger 6700 . Marker Identification MD BKB SECTN INCLN ~ A] END 2.50/100 CURVE 12890 6657 9531 20.00 B] TGT TR22-B ~~ 13190 6939 9633 20.00 C] TO 7' LNR PT <11> 13597 7321 9770 20.00 6750- - .._ . , 'TR'u-b-IfuF C'iP~OZ.KI' - ~4 ..... v 6soo. .. j D J 6850- ,, j 6900 I 7000 7050 -R'I'LO'V~'A~'H 7039 --' I 7t00, 7150 E X2(_SLI I ON i i 7350- J i SHARED SERVICES DRILLING ~8pkep IOen(~f~cation MO N/S E/W Al KB 0 0 N 0 8) KOP/CURVE t.00/t00 500 0 N 0 C) CURVE 1.50/i00 650 0 S 2 O) CURVE 2.00/100 850 I S 12 E) ENO 2.00/100 CURVE 1800 13 S 241 F) CURVE 2.00/100 1900 15 S 28! G) ENO 2.00/100 CURVE 4297 t05 S 1994 H) 9-5/8' CSG PT <11 > 5936 ~86 S 3545 I) CURVE 2.50/100 618t ~98 S 3777 J} ENO 2.50/100 CURVE 7020 390 S 455~ K) CURVE 2.50/t00 ~0691 ~866 S 7775 L) ENO 2.50/100 CURVE 12890 2516 S 9194 H) TGT TR22-B xx~xx~xx 13190 2558 S 9287 N) TO 7" LNR PT <11 > t3597 2616 S 94&3 Anadr ~ 1 ] Sch I umberger I PF-80 TR22-B (P5A) PLAN VIEW CLOSURE ..... : 9770 feet at Azimuth 254.47 DECLINATION.: +27.369 (E) SCALE .......: :1 inch = ~200 feet DRAWN .......: 24 Sep 1998 AKA-DPC ANADRILL ~'"~-'"' '- · . EFT ^ NC)-'F A ~PR()VEl) FO E>:.-SZUT!O!q · PLAM FE ---- ~ ................... -- ...... "---T--R--- ~------ j ~___ ~,~ .. ~i .......... I .............. 10200 9~00 9000 8400 7800 7200 6600 6000 5400 41t00 4200 3600 3000 2400 '~800 1200 riO0 0 600 <- ~ESI · EAST -> ',1 {cl98 MPFSOP5 3.2C 9:51 AM P) H 140324 VENDOR At ASKAST 14 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 0709C~:E CKOTOC~r--/81"l 100. O0 100. O0 HANDLING INST: s/h kathy campoamo~ x 5122 · WELL PERMIT CHECKLIST COMPANY WELL NAME/¢'/,/b_,~ .-'~,.~(~ PROGRAM: exp [] dev~'redrll [] serv [] wellbore seg II ann. disposal para req II FIELD & POOL _.~_~./'_Qr_~_ INIT CLASS GEOLAREA UNIT# /,/,,/',.~ ,~...<~:;:' ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper dislance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficienl acreage available in drilling unil ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 0. Operator has appropriate bond in force ............. 1. Permit can be issued without conservation order ........ 2. Permit can be issued without administrative approval ...... 3. Can permit be approved before 15-day wait ........... ENGINEERING APPR DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMl- vol adequate to circulate on conductor & surf csg ..... 17. CMl- vol adequate to tie-in long string to surf csg ........ 18. CMl- will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a rl0-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to 5~ Q(--., psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N//'Y N ...... 31. Data presenled on potential overpressure zones ....... Y,,,,N' ~ , /"2 32. Seismic analysis of shallow gas zones. ' .,~y NN ~~:::~. 33. Seabed condition survey (if off-shore) ............. 34. Con. tact.nam, elphon.e.for weekly progress reports ...... :// Y N l exploramry only] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) w_jJLc~tain waste in a suitable rec '_ew~:l~one; ....... (B~will not col~~ cau;e drilling waste... lo surface; (C) wij~'~bt '~gdty of the w-~lt-ase~or disposal; (D) ~on or impair recove~from a pdol; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOL~Y: Y N Y N Y N Y N Y N ENGi~EER[~Gi" ..~C/Anr~i;;i coMMIssION: JDH. ,....-----~- /' "----. RNC ~ ~-~) co co'~/~'- ~ Comments/Instructions: ~l:cheklisl rev 05129198 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... R OE VED Alaska 0il & Gas Cons, Com~ COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : MPF-80 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292292800 REFERENCE NO : 99005 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JAN-1999 14:22 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 99/01/ 5 ORIGIN : FLIC REEL NAME · 99005 CONTINUATION # : PREVIOUS REEL : CO~94ENT : BP EXPLORATION, MILNE POINT, MPF-80, API# 50-029-22928-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/01/ 5 ORIGIN · FLIC TAPE NAME : 99005 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : BP EXPLORATION, MILNE POINT, MPF-80, API# 50-029-22928-00 TAPE HEADER MILNE POINT CASED HOLE WIRELINE LOGS WELL NAME: MPF-80 API NUMBER: 500292292800 OPERATOR: BP EXPLORATION (ALASKA), INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 5-JAN-99 JOB NUMBER: 99005 LOGGING ENGINEER: V LOMAX OPERATOR WITNESS: J FOX SURFACE LOCATION SECTION: 6 TOWNSHIP: 13N RANGE: iOE FNL: FSL: 1943 FEL: 3046 FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 43.25 GROUND LEVEL: 10.80 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 13295.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JAN-1999 14 '.22 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER .. DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GR ....... REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE DEPTH DETERMINATION LOG AQUIRED ON BP EXPLORATION'S MPF-80 WELL. THIS LOG IS THE PRIMARY DEPTH CONTROL FOR THIS WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION ' O01CO1 DATE · 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NU~BER: 1 DEPTH INCREMENT: 0.5000 FILE StC4MARY LDWG TOOL CODE START DEPTH STOP DEPTH GR 13296.0 4850.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GR ....... REMARKS: THIS FILE CONTAINS THE EDITED DATA. THE CURVES HAVE LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JAN-1999 14:22 PAGE: BEEN CLIPPED AT FIRST READINGANDATLASTREADING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NtrM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1291522 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 1291522 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 1291522 O0 000 O0 0 1 1 1 4 68 0000000000 TENS.GR LB 1291522 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13296.000 GRCH. GR 52.286 CCL.GR 0.103 TENS.GR DEPT. 4850.000 GRCH. GR 18.757 CCL.GR -0.008 TENS.GR 3509.000 1119.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JAN-1999 14:22 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NVJMBER 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: 0.5000 FILE SUM~zARY VENDOR TOOL CODE START DEPTH STOP DEPTH 13344.5 4849.0 GR LOG HEADER DATA DATE LOGGED: 07-DEC-98 SOFTWARE VERSION: 8Cl - 205 TIME LOGGER ON BOTTOM: 1840 07-DEC-98 TD DRILLER (FT) : 13295.0 TD LOGGER (FT) : 13301.0 TOP LOG INTERVAL (FT) : 4850.0 BOTTOM LOG INTERVAL (FT) : 13296.0 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAB~VIA RAY PSPT PRESS TEMP $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER GR PSPT-A 8. 500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JAN-1999 14:22 PAGE: DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 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) : 13295.0 BRINE/DIESEL 9.90 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS) : NEAR COUNT RATE HIGH SCALE (CPS) : TOOL STANDOFF (IN): REMARKS: THANK YOU FOR USING SCHLUMBERGER. JOB RUN OFF SCHLUMBERGER CRANE. PRIMARY DEPTH CONTROL LOG - NO TIE IN. NEW WELL - NO PRODUCTION DATA. .46" DIAMETER LINE MARKED TO 18,000' TO ENSURE PRIMARY DEPTH CONTROL. MARKS VERIFIED; WHEEL CORRECTION DETERMINED TO 16,000' ON 12-6-98. TOOL ZERO AT GROUND DEPTH - 32.45' - CALCULATED FROM DRILL FLOOR AND GROUND LEVEL ELEVATIONS LISTED ON WELL SKETCH. RAN WHEELS ON LOGGING TOOLS TO AID IN DECENT. THIS FILE CONTAINS THE RAW DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JAN-1999 14:22 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 24 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 42 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUNIB AUjFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1291522 O0 000 O0 0 2 1 1 4 68 0000000000 TENS GR LB 1291522 O0 000 O0 0 2 1 1 4 68 0000000000 GR GR GAPI 1291522 O0 000 O0 0 2 1 1 4 68 0000000000 WPRE GR PSI 1291522 O0 000 O0 0 2 1 1 4 68 0000000000 WTEP GR DEGC 1291522 O0 000 O0 0 2 1 1 4 68 0000000000 CCLC GR V 1291522 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 13344.500 TENS.GR 1047.000 WTEP.GR 75.830 CCLC.GR -0.038 DEPT. 4849.000 TENS.GR 1114.000 WTEP.GR 23.316 CCLC. GR -999.250 GR.GR 65.008 WPRE. GR GR.GR 18.757 WPRE.GR 3288.705 1485.577 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-JAN-1999 14:22 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/01/ 5 ORIGIN · FLIC TAPE NAME : 99005 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, MILNE POINT, MPF-80, API# 50-029-22928-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/01/ 5 ORIGIN : FLIC REEL NAME : 99005 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, MILNE POINT, MPF-80, API# 50-029-22928-00
