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Home My WebLink About202-0721a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" H-40 112' 7" L-80 4,617' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Pumped 297.6 Bbls Clas G Cement Water-Bbl: PRODUCTION TEST Not On Production Date of Test: Oil-Bbl: Flow Tubing To Surface N/A Gas-Oil Ratio:Choke Size: Circulated Through Both Strings 8,246' Set CIBP (Long String) 8585 8,150 - 8,155' Tubing Punch ( Long String) 4,800 - 4,805' Tubing Punch ( Short String) 35' Surface Per 20 AAC 25.283 (i)(2) attach electronic information 92# 26# 112' SIZE DEPTH SET (MD) 8205 PACKER SET (MD/TVD) 2-3/8" 42" CEMENTING RECORD 6004833.51 SETTING DEPTH TVD 6005001.66 TOP HOLE SIZE 569747.00 June 30, 3460 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. 1,800' Approx. N/AN/A N/A 8,695' / 4,626' 2,850' NSL, 3,779' FWL, SEC. 6, T12N, R11E, UM Surface / Surface GL: 38.9 BF: N/A 4/12/2002 4/7/2002 CASING WT. PER FT.GRADE 926sx Class 'L' AMOUNT PULLED Surface 8,686' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska LLC WAG Gas 202-072 / 323-655Aband.: 6/12/2025 3,353' FSL, 20' FEL, SEC. 12, T12N, R10E, UM 72.7 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 565989.85 6000021.49 50-029-23079-00-00 MILNE PT UNIT S-07 MILNE POINT / SCHRADER BLUFF OIL ADL0380109 & ADL0380110 N/A 3,017' FSL, 3,995' FWL, SEC.06, T12N, R11E, UM MWD, GR, IFR, CASANDRA & SCMT If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 326sx Class 'G' 8231 8315 2-3/8" BOTTOM 9-7/8" 260sx Arctic Set (Approx.) 35' Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment 569961.3 Abandoned 6/12/2025 JSB RBDMS JSB 072525 xG Received 7/11/2025 DSR-9/11/25 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 8,234' 4,254' 8,038' 4,102' 8,074' 4,129' 8,110' 4,157' 8,136' 4,176' SBE1-NF 8,197' 4,225' TSBD-OA 8,234' 4,254' 8,279' 4,290' 8,316' 4,320' SBA5 8,354' 4,350' SB OBF SB OBF 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Ryan Thompson Digital Signature with Date:Contact Email:ryan.thompson@hilcorp.com Contact Phone: 907-564-5280 Operations Manager General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. TSBB-OB SBE4-NC SBE2-NE Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. TSBC Authorized Name and SBF2 SBF1-NB Formation Name at TD: INSTRUCTIONS Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. 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. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Scott Pessetto (9864) DN: cn=Scott Pessetto (9864) Date: 2025.07.11 09:46:25 - 08'00' Scott Pessetto (9864) Size Spf Interval (TVD) KOP @ 380‘ Hole angle thru perfs = 37 DEG. Max. hole angle = 79.48 deg @ 3383‘ DATE REV. BY COMMENTS MILNE POINT UNIT WELL No.: S-07i API : 50-029-23079-00 BP EXPLORATION (AK) Orig. KB Elev. = 72.70 Orig. GL Elev. = 39.20 Perforation Summary MPU S-07iWellhead: 06/22/02 Drilled by Cased Doyon 141 20" x 34“ insulated, 215 #/ft A-53 112‘ 7“ Halliburton Float Collar PBTD 8684‘7“ Halliburton float shoe 8600‘ 7“ 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) Short String 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES XN-Nipple (1.875” pkg. bore) No-Go 1.791” Long String 1.75“ ball. 7“ x 2-3/8” Baker “GT” Ret. dual pkr. 7“ x 2-3/8” Baker “FH” Ret. pkr. OA sands OB sands 2-3/8“, 4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) MDO 2185‘ 8168‘ 8220‘ 2246‘ 8171‘ 8302‘ 8205‘ 8285‘ 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES XN-Nipple (1.875” pkg. bore) No-Go 1.791”3 3/8“ 3 3/8“ 4 4 8248‘ - 8258’ 8264‘ - 8274’ 4278‘ - 4286‘ 8328‘ - 8343’ . 1.945“ ID. 2.41“ ID. 4266‘ - 4274’ 4330‘ - 4342’ Tree: CIW 2 1/16“ 5M Dual string 11“ x 2 3/8” 5M FMC dual string Hanger thread 2 3/8“ EUE top and IBT bottom 2” CIW-H BPV profile 8231‘Tubing tail / WLEG XN x XN x x x 08/31/02 Lee Hulme Completion Rig 4ES 2-3/8“ Baker ‘E’ Hydro Trip Sub (2.00” pkg. bore)8310‘ 1.875“ XXN plug set 9-6-11 well is secured due to Surface Casing Leak. x XN Calculated top of K-Max gel (6861‘) and Thermatek (7378’) pumped 8/8/11 Weatherford CIBP set @ 8246‘ Tubing punched 8150‘ - 8155’ (4 shots/foot) Tubing punched 4800‘ - 4805’ (4 shots/foot) Hilcorp Alaska 11/17/2011 Darci Horner Cemented to surface (P&A) Cement to surface in short string, long string and 7” casing 6/11/2025 Tom Fouts Surface Excavation and Casing Cut (P&A) Well Name Rig API Number Well Permit Number Start Date End Date MP S-07 Well Support 50-029-23079-00-00 202-072 1/17/2025 6/12/2025 1/17/2025 - Friday WHP's prep for Demobe and P&A. T/I/O- 0/0/0. Walk down well for disco, excavate and cutting off the well head, start ACWR to excavate. Will be back out to disco and pull well house at a later date. 1/15/2025 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 1/16/2025 - Thursday No operations to report. No operations to report. No operations to report. 1/18/2025 - Saturday No operations to report. 1/21/2025 - Tuesday 1/19/2025 - Sunday No operations to report. 1/20/2025 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP S-07 Well Support 50-029-23079-00-00 202-072 2/21/2025 6/12/2025 2/21/2025 - Friday Well Support techs pulled well houses on S-07 S-06 and S-08 in prep for P&A for S-07. Attempted to pull foundations but foundations are frozen, installed heater and wraped foundations. covered cellars with ply wood. 2/19/2025 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/20/2025 - Thursday No operations to report. No operations to report. No operations to report. 2/22/2025 - Saturday No operations to report. 2/25/2025 - Tuesday 2/23/2025 - Sunday No operations to report. 2/24/2025 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP S-07 Well Support 50-029-23079-00-00 202-072 2/21/2025 6/12/2025 2/28/2025 - Friday No operations to report. 2/26/2025 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 2/27/2025 - Thursday Well Support techs removed foundation in prep for upcoming bell Survey and cleaned up broken wood and debris. No operations to report. No operations to report. 3/1/2025 - Saturday No operations to report. 3/4/2025 - Tuesday 3/2/2025 - Sunday No operations to report. 3/3/2025 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP S-07 Well Support 50-029-23079-00-00 202-072 1/17/2025 6/12/2025 6/6/2025 - Friday No operations to report. 6/4/2025 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/5/2025 - Thursday No operations to report. OBTAIN CSE PERMIT & HOT WORK PERMIT. AOGCC INSPECTOR KAM ST.JOHN LOOKED AT CUT OFF WELLHEAD. ENTER CELLAR. WELD 6' EXTENSION TO INSULATED CONDUCTOR TO MAKE FLUSH WITH ALL ANNULI. MIX & CEMENT TUBING, IA & INSULATED CONDUCTOR VOID WITH 8 SACKS OF CLASS 'G' CEMENT. The Roads and Pads team trimmed & trenched and set the shoring box using the crane. Set rig mats around work area. Rig up safety railing around work area. Rig up safety davit/retreval system. 6/7/2025 - Saturday OBTAIN CSE PERMIT & HOT WORK PERMIT. AOGCC INSPECTOR KAM ST.JOHN LOOKED AT CUT OFF WELLHEAD. ENTER CELLAR. WELD 6' EXTENSION TO INSULATED CONDUCTOR TO MAKE FLUSH WITH ALL ANNULI. MIX & CEMENT TUBING, IA & INSULATED CONDUCTOR VOID WITH 8 SACKS OF CLASS 'G' CEMENT. 6/10/2025 - Tuesday 6/8/2025 - Sunday OBTAIN CSE PERMIT & HOT WORK PERMIT. ENTER CELLAR & REMOVE CEMENT FROM INSULATED CONDUCTOR WITH JACK HAMMERS. REMOVE OUTER JACKET ON INSULATED CONDUCTOR. REMOVE INSULATION FROM CONDUCTOR. RU CRANE & RU WACHS SAW. CUT OFF WELLHEAD 5' BELOW TUNDRA.. ~10' TO TOC INSIDE LONG STING TUBING 2-3/8" TUBING. SHORT STRING TUBING HAS CEMENT TO SURFACE - 2-3/8" TUBING. ~5' TO TOC INSIDE IA - 7" CASING. CEMENT TO SURFACE INSIDE INSULATED CONDUCTOR - 34" CONDUCTOR. ALL PICTURES IN O:DRIVE UNDER WELL FOLDER. 6/9/2025 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP S-07 Well Support 50-029-23079-00-00 202-072 2/21/2025 6/12/2025 No operations to report. No operations to report. 6/14/2025 - Saturday No operations to report. 6/17/2025 - Tuesday 6/15/2025 - Sunday No operations to report. 6/16/2025 - Monday 6/13/2025 - Friday No operations to report. 6/11/2025 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary OBTAIN CSE & HOT WORK PERMIT. AOGCC'S GUY COOK ON LOCATION TO WITNESS CEMENT - 05:30 - STILL NOT CURED. WRAP WITH VIS QUEEN & APPLY HEAT. HAMMER DROP TEST CEMENT - VEY HARD. AOGCC'S GUY COOK ON LOCATION TO WITNESS CEMENT -18:30 - VERY HARD. WELDERS WELDED MARKER CAP PLATE ON CASING STUMP (INSULATED CONDUCTOR). PICTURES SENT TO GUY COOK. THE CAP IS 4.9' BELOW TUNDRA. ALL PICTURES IN O:DRIVE UNDER WELL FOLDER. 6/12/2025 - Thursday Safety removed davit. Rig down hand rails. Pull rig mats from around well. Pull shoring box. Back fill well slot with gravel. 2025-0611_Surface_Abandon_MPU_S-07_gc Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 6/12/2025 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment Petroleum Inspector MPU S-07 Hilcorp Alaska LLC PTD 2020720; Sundry 323-655 6/11/2025: I arrived on site at 06:00 am and met with Matthew Ross with Hilcorp Alaska and we spoke about the cement to surface. Upon inspection of the cement, it was found that the cement was to surface but was not set. I inspected the identification plate and found that the information on the plate was correct. I left location to return when the cement was finished setting up. I returned to MPU S-07 at 17:30 pm after receiving a call from Mr. Ross that the cement was set up and ready for the identification plate installation. Upon inspection, the cement was good and hard, and I gave the approval for the identification plate to be welded onto the casing. I verified that the casing was cut 4 feet 9 inches below tundra level. After the identification plate was installed properly, I gave the approval for the well to be buried. Attachments: Photos (6)    2025-0611_Surface_Abandon_MPU_S-07_gc Page 2 of 4 Surface Abandonment – MPU S-07 (PTD 2020720) Photos by AOGCC Inspector G. Cook 6/11/2025 2025-0611_Surface_Abandon_MPU_S-07_gc Page 3 of 4 2025-0611_Surface_Abandon_MPU_S-07_gc 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): 8,695'NA Casing Collapse Conductor 470psi Production 5,410psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 8,205' MD / 4,231' TVD & 8,285' / 4,295' TVD and N/A Ryan Thompson ryan.thompson@hilcorp.com 907-301-1240 Perforation Depth MD (ft): See Schematic See Schematic 2-3/8" 2-3/8" 4.7# / L-80 / IBT 8,231' 7" x 2-3/8" GT Ret. Dual & 7' x 2-3/8" FH Ret. And N/A 112' 20 inch 7 inch8,684' MD 1,490psi 7,240psi4,617'8,684' Length Size Proposed Pools: 112' 112' 4.7# / L-80 / IBT TVD Burst 8,315' SCHRADER BLUFF OIL N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380110 202-072 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23079-00-00 Hilcorp Alaska LLC C.O. 477.05 AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 1/15/2023 Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE POINT 4,626' Surface Surface 0 8,246' / Surface MILNE PT UNIT S-07 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:53 am, Dec 08, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.12.08 09:30:18 - 09'00' Taylor Wellman (2143) 323-655 MGR30JAN2024 SFD 12/20/2023 10-407 Photo document as described. AOGCC to witness cement in all annuli before welding plate in place. Abandon 2024 ADL0380109, SFD DSR-12/8/23*&:JLC 1/31/2024 2/1/24Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2024.02.01 09:46:49 -09'00' RBDMS JSB 020624 Plug and Abandon Well: MPS-07 PTD: 202-072 API: 50-029-23079-00-00 Well Name:MPS-07 API Number:50-029-23079-00-00 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:202-072 First Call Engineer:Ryan Thompson 907-564-5005 907-301-1240 (M) Second Call Engineer:Todd Sidoti 907-632-4113 AFE Number:TBD MASP:0 psi, cement to surface. Brief Well Summary MPS-07 was drilled in 2002 as a dual string PWI injector in the Schrader Bluff formation. In April of 2011 a surface casing leak was identified during a failed MIT-IA. Due to the surface casing leak and an upcoming close approach for drilling, the well was approved to be P&A’d. A Thermatek treatment was pumped on the short string in August of 2011 and had a successful pressure test to 1500 psi. In October 2011 the short string had a passing MIT-T to 2260 psi against the Thermatek plug and the long string had a passing MIT-T to 2240 psi with an XN plug set at 8302’. In November of 2011 a CIBP was set in the long string @ 8246’ and tubing punches were performed in the long and short string. The well was then P&A’d to surface circulating cement down the long string taking returns to the IA until cement to surface. The IA was then shut in and returns were taken from the short string until cement to surface. Cement was now to surface across all annuli. Cement was tagged at 11’ in both the long string and short string in 2013. Notes Regarding Wellbore Condition x Cement to surface across all Annuli. x The well is a dual string monobore completion. x Last suspended well inspection was completed 9/20/20. Objective: x To perform a complete P&A of the well. Procedure 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 – 202-072 c. Well Name – MPU S-07 d. API Number - 50-029-23079-00-00 *** Notify AOGCC Inspector of wellhead removal. (24-hour minimum notice) Attachments: 1. As-built Schematic 2. Redline Schematic Plug and Abandon Well: MPS-07 PTD: 202-072 API: 50-029-23079-00-00 Plug and Abandon Well: MPS-07 PTD: 202-072 API: 50-029-23079-00-00 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): 8,695'NA Casing Collapse Conductor 470psi Production 5,410psi 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 Abhijeet.Tambe@hilcorp.com 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 8,684'8,684' 7 inch No SSSV See Schematic 4,617' 4.7# / L-80 / IBT 112'20 inch 112' 8,205' MD / 4,231' TVD Authorized Signature: 2-3/8" NA TVD Burst 4,295' 7,240psi Tubing Grade:Tubing MD (ft): 1,490psi112' MD 50-029-23079-00-00 Length Size 4,626'Surface Surface PRESENT WELL CONDITION SUMMARY 8,246' / Surface STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380110 202-072Hilcorp Alaska LLC MILNE PT UNIT S-07 MILNE POINT / SCHRADER BLUFF OIL Perforation Depth TVD (ft): Tubing Size: 7" x 2-3/8" GT Ret. Dual Packer Perforation Depth MD (ft): See Schematic 7' x 2-3/8" FH Ret. Packer 8,285' / 4,295' TVD 2-3/8" 4.7# / L-80 / IBT 4,252' COMMISSION USE ONLY Authorized Name: Authorized Title: Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:53 am, Apr 01, 2021 321-158 Chad Helgeson (1517) 2021.03.31 16:38:41 - 08'00' DSR-4/1/21DLB 04/01/2021 X MGR05APR21 *Per 20 AAC 25.110 Suspended Wells: (e) Next inspection shall be conducted 24 months before September 30, 2025. *An exception is allowed to 20 AAC 25.112(d) - 'Plugging of the surface' as requirement for suspension. Under 20 AAC 25.110(c)(1) a wellhead is installed which provides the exception. *Per 20 AAC 25.112(i) a variance is approved to allow the well to remain in its current condition as current condition of the well allow now movement of sources of hydrocarbons or freshwater. Comm. 4/6/21 dts 4/5/2021 JLC 4/6/2021 RBDMS HEW 4/6/2021 March 26, 2021 Jesse Chmielowski, Chair Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Milne Point S-07 (PTD # 202-072) 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 S-07 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. S-07 is a dual string injector that was suspended on 11/17/2011. The well (long string as well as short string) 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) 2021.03.31 16:37:57 - 08'00' Page |2 Milne Point Unit well MP S-07 Technical Justification for Application for Renewal of Suspension Status March 09, 2021 Well Status: Milne Point Unit well MP S-07 (PTD# 202-072) was suspended on 11-17-2011 after a near surface casing leak was discovered during a failed MIT-IA in April 2011. After the leak discovery, the well was classified as Not Operable. To avoid anti-collision with then planned sidetrack of MP S-01, the decision was made to secure the well. And due to the integrity issues of 7” casing, both tubing strings and the 7” casing were fully cemented bringing cement to surface in November 2011. The well is mechanically sound as evident by the cement returns observed at surface. 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 S-07 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. During AOGCC witnessed well inspection (09-20-2020), long string tubing pressure was recorded as 160 psi (from thermal expansion). The tubing pressure was bled down to 0 psi on 10-12-2020 (3 weeks after the inspection). The current well pressure readings are LS/SS/ OA = 0 psi/ 0 psi / 0 psi Request: Hilcorp Alaska LLC requests approval for renewal of the existing suspension status for MP S-07. 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.The well is fully cemented above the reservoir to surface. A wellhead has been left in place to seal the opening to allow suspension approval under 20 AAC.110 (c)(1). 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 LS - 160 SS - 0 IA 0 OA 0 Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm None Dual string well (long string/short string) 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 ArendMPS-07 (907)249-4383 Follow Up Actions Needed: Hilcorp 202-072 Condition of Surrounding Surface Location: 11/17/11 311-307 REVIEWED BY: Other (specify in comments) PLB 12/2014 MPS-07 Suspended Well Inspection 9-20-20 Size Spf Interval (TVD) KOP @ 380‘ Hole angle thru perfs = 37 DEG. Max. hole angle = 79.48 deg @ 3383‘ DATE REV. BY COMMENTS MILNE POINT UNIT WELL No.: S-07i API : 50-029-23079-00 BP EXPLORATION (AK) Orig. KB Elev. = 72.70 Orig. GL Elev. = 39.20 Perforation Summary MPU S-07iWellhead: 06/22/02 Drilled by Cased Doyon 141 20" x 34“ insulated, 215 #/ft A-53 112‘ 7“ Halliburton Float Collar PBTD 8684‘7“ Halliburton float shoe 8600‘ 7“ 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) Short String 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES XN-Nipple (1.875” pkg. bore) No-Go 1.791” Long String 1.75“ ball. 7“ x 2-3/8” Baker “GT” Ret. dual pkr. 7“ x 2-3/8” Baker “FH” Ret. pkr. OA sands OB sands 2-3/8“, 4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) MDO 2185‘ 8168‘ 8220‘ 2246‘ 8171‘ 8302‘ 8205‘ 8285‘ 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES XN-Nipple (1.875” pkg. bore) No-Go 1.791”3 3/8“ 3 3/8“ 4 4 8248‘ - 8258’ 8264‘ - 8274’ 4278‘ - 4286‘ 8328‘ - 8343’ . 1.945“ ID. 2.41“ ID. 4266‘ - 4274’ 4330‘ - 4342’ Tree: CIW 2 1/16“ 5M Dual string 11“ x 2 3/8” 5M FMC dual string Hanger thread 2 3/8“ EUE top and IBT bottom 2” CIW-H BPV profile 8231‘Tubing tail / WLEG XN x XN x x x 08/31/02 Lee Hulme Completion Rig 4ES 2-3/8“ Baker ‘E’ Hydro Trip Sub (2.00” pkg. bore) 8310‘ 1.875“ XXN plug set 9-6-11 well is secured due to Surface Casing Leak. x XN Calculated top of K-Max gel (6861‘) and Thermatek (7378’) pumped 8/8/11 Weatherford CIBP set @ 8246‘ Tubing punched 8150‘ - 8155’ (4 shots/foot) Tubing punched 4800‘ - 4805’ (4 shots/foot) Hilcorp Alaska 11/17/2011 Darci Horner Cemented to surface (P&A) Cement to surface in short string, long string and 7” casing 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 8,695 feet Surface, 8,246 & 8,600 feet true vertical 4,626 feet N/A 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 2-3/8"4.7# / L-80 / IBT 8,231' 4,252' Tubing (size, grade, measured and true vertical depth)2-3/8"4.7# / L-80 / IBT 8,285' 4,295' 8,205' / 4,231' Packers and SSSV (type, measured and true vertical depth)N/A 8,285' / 4,295' 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: 5,410psi8,684' 7" 8,684' 4,617' Oil-Bbl measured true vertical Packer GT Ret. Dual Packer FH Ret. Packer 20" WINJ WAG Water-Bbl MD measured 112'112' TVD 7,240psi 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 220-072 50-029-23079-00-00 Plugs ADL0380110 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OILN/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 Conductor MILNE PT UNIT S-07 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure Senior Engineer: Senior Res. Engineer: Collapse 470psi Burst 1,490psi Production N/A Casing 8,205 & 8,285 4,231 & 4,295 777-8333 2. Operator Name 112' measured Size Junk Length L G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Chad A Helgeson 2020.10.07 16:05:57 -08'00' By Samantha Carlisle at 11:26 am, Oct 09, 2020 SFD 10/12/2020 202 DSR-10/12/2020MGR15OCT2020 RBDMS HEW 11/12/2020 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 LS - 160 SS - 0 IA 0 OA 0 Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm None Dual string well (long string/short string) 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 ArendMPS-07 (907)249-4383 Follow Up Actions Needed: Hilcorp 202-072 Condition of Surrounding Surface Location: 11/17/11 311-307 REVIEWED BY: Other (specify in comments) PLB 12/2014 MPS-07 Suspended Well Inspection 9-20-20 Size Spf Interval (TVD) KOP @ 380‘ Hole angle thru perfs = 37 DEG. Max. hole angle = 79.48 deg @ 3383‘ DATE REV BY COMMENTS Perforation Summary 20" x 34“ insulated, 215 #/ft A-53 112‘ 7“ Halliburton Float Collar PBTD 7“ Halliburton float shoe8684‘ 8600‘ 7“ 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) Short String 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES XN-Nipple (1.875” pkg. bore) No-Go 1.791” Long String 1.75“ ball. 7“ x 2-3/8” Baker “GT” Ret. dual pkr. 7“ x 2-3/8” Baker “FH” Ret. pkr. OA sands OB sands 2-3/8“, 4.7 #/ft L-80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) 2185‘ 8168‘ 8220‘ 2246‘ 8171‘ 8302‘ 8205‘ 8285‘ ‘ 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES X-Nipple (1.875” pkg. bore) 2-3/8“ HES XN-Nipple (1.875” pkg. bore) No-Go 1.791”3 3/8“ 3 3/8“ 4 4 8248‘ - 8258’ 8264‘ - 8274’ 4278‘ - 4286‘ 8328‘ - 8343’ . 1.945“ ID. 2.41“ ID. 4266‘ - 4274’ 4330‘ - 4342’ ELMD 8231‘Tubing tail / WLEG XN x XN x x x 2-3/8“ Baker ‘E’ Hydro Trip Sub (2.00” pkg. bore)8310‘ Note Well was completed as a monobore completion (only 7“ casing) but was completed with a tubing spool and casing spool. There is no outer annulus. Lower lock down screws are backed out. Do not attempt to run in lower lock down screws as they can be run in past their sealing point. Also if the well develops a leaking API seal ring contact the Well Operations Coord. x-3387. 1.875“ XXN plug set 9-6-11 well is secured due to Surface Casing Leak. x XN Calculated top of K-Max gel (6861‘) and Thermatek (7378’) pumped 8/8/11 Weatherford CIBP set @ 8246‘ Tubing punched 8150‘ - 8155’ (4 shots/foot) Tubing punched 4800‘ - 4805’ (4 shots/foot) Superceded Well S-07 On behalf of Tfouts Hilcorp Alaska Suspended Well Inspection Review Report inspeccNo: susBD8200921131745 Date Inspected: 9/20/2020 ' Inspector: Brian Bixby' Type ufInspection VVeUName: M|LNEPTUNIT S-07 - permit Number: 2020720 ' Suspension Approval: Sundry - # 311-307 Suspension Date: 11/17/2011 ' � Location Verified? W UVerified, How? Other (specify incomments) ^ Offshore? 11 Subsequent Date AO6[ZNotified: 9/18/2020 Operator: Hi|corpAlaska, LLC Operator Rep: Jon Arend Wellbore QiagemAvail? Photos Taken? Well Pressures (psi): Tubin�: 160 Fluid inCellar? |A: O ' BPV\nstaUed? [1 OA: 0 VRP|og(s)lnstaOed7 E1 Wellhead Condition All o/the valves onthe appeared ingood working order with working gauges onthe Tubing, |Aand OA. There are noVR � Plugs o/UPVinstalled. Condition ofCellar Good Condition. I did not observe and excessive water in cellar, trash or any sheen. - Surrounding Surface Condition Everything looked good. I did not see debris or sheen around the pad. Comments | verified the location using the pad map. Dual String completion. Short String pressureT/|/O = O/O/O ' Supervisor Comments Photos (3)attached ~ Monday, September 28'2O20 o j- cnti x � j ; - ' 00 d J . Xili 00 0 C14 (D Q. C/) Q rn o Q c�OQ ami = O . F- c U) a a a �■ F � 1 t.;3' o Na All W,rrrsON STATE OF ALASKA S E P 2 2 2015 AIL OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull TubingU ❑ Operations shutdown Performed: Suspend f'-j.' Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ arforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ESP Change-out 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska,LLC Development.❑ Exploratory ❑ 202-072 3.Address: Stratigraphic❑ Service ❑✓ 6.API Number: 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23079-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0380110 MILNE PT UNIT SB S-07 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A p. k '` . . . MILNE POINT/SCHRADER BLUFF OIL 11.Present Well Condition Summary: ' *"/ ?, * s Surface,8,246& Total Depth measured 8,695 feet Plugs measured 8,600 feet true vertical 4,626 feet Junk measured N/A feet 4 8,205 Effective Depth measured Surface. feet Packer measured 8,285 feet 4 ti: . * 4,231 true vertical ' .Surface ' feet true vertical 4,295 feet I, ,; « 4 Casing Length Size ' ` a MD 4TVD , Burst Collapse Conductor ' , • e P, 's Surface 112" 20" 112' 112' 1,490psi 470psi Intermediate a Production 8,684' 7" 8,684' 4,617' 7,240psi 5,410psi Liner Perforation depth Measured depth See Attached Schematic feet SCANNED D : 1 ly 2 815 True Vertical depth See Attached Schematic feet 2-3/8" 4.7#/L-80/IBT 8,231' 4,252' Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/L-80/IBT 8,285' 4,295' GT Ret.Dual Packer 8,205'/4,231' Packers and SSSV(type,measured and true vertical depth) FH Ret.Packer N/A 8,285'/4,295' 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 0 Exploratory❑ Development❑ Service ❑✓ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑✓ SPLUG❑ 17.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 sporhoIa(C�hiIcorp.com Printed NameOR El Porhola Title Operations Engineer Signature ✓,,�kPhone 777-8412 Date 9/22/2015 Form 10-404 Revised 5/2015 ,/9670---y /t, .- /,--,3- RBDMS SEP 15 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: MPS-07 Oper.Rep: Bill Kruskie PTD No.: 202-072 Oper.Phone: 1-907-670-3387 Location Verified? Yes Oper.Email: wkruskierethilcorD.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Date AOGCC Notified: 08/21/15 Suspension Date: 11/17/11 Type of Inspection: Subsequent Sundry No.: 311-307 Wellbore Diagram Avail.? Yes Photos Taken? Yes Well Pressures(psi): Tubing NA IA 0 OA 0 Condition of Wellhead: Good,no visable leaks and all gauges are installed,wellhouse,well head sign installed,full tree, Condition of Surrounding Surface Location: Good. Follow Up Actions Needed: No Comments: Map on location. Attachments: Pictures REVIEWED BY: Area map Insp.Supry WBS Comm PLB 12/2014 MPS-07 2015 Suspended Well Inspection Form 11, • Tree: CIW 2 1/16"5M Dual string Wellhead:11"x 2 3/8"5M FMC dual string MPU S-07 i Orig. KB Elev. =72.70 Hanger thread 2 3/8"EUE top and IBT bottom , , Orig. GL Elev. =39.20 2"CIW-H BPV profile CEMEivT To Su laFAfE /,Y St#0 ST,11/T4'� LONG 20"x 34"insulated,215#/ft A-53 112' S TR A N G My D '7" C.4!/^r Short String Long String Hiker's Ale«ia"11.1.4 2185' 2-3/8"HES X-Nipple(1.875"pkg.bore) 2-3/8"HES X-Nipple(1.875"pkg.bore) 2246' KOP @ 380' Max. hole angle=79.48 deg @ 3383' Hole angle thru perfs=37 DEG. Note Well was completed as a monobore completion(only 7"casing)but was completed 7"26#,L-80,BTRC Casing with a tubing spool and casing spool.There is (drift id=6.151,cap.=.0383 bpf) no outer annulus.Lower lock down screws are backed out.Do not attempt to run in lower lock 2-3/8",4.7#/ft L-80,IBT tubing down screws as they can be run in past their (drift id=1.901,cap.=.00387 bpf) sealing point.Also if the well develops a leaking API seal ring contact the Well Operations Coord. x-3387. Tubing punched 4800'-4805'(4 shots/foot) Calculated top of K-Max gel(6861')and Thermatek(7378')pumped 8/8/11 x 2-3/8"HES X-Nipple(1.875"pkg.bore) 8171' 8168' 2-3/8"HES X-Nipple(1.875"pkg.bore) x Tubing punched 8150'-8155'(4 shots/foot) 7"x 2-3/8'Baker"GT"Ret.dual pkr. 8205' 1.945"ID. 8220' 2-3/8"HES XN-Nipple(1.875"pkg.bore) No-Go 1.791" Weatherford CIBP set(418246' 8231' Tubing tail/WLEG Perforation Summary 7'x 2-3/8"Baker"FH"Ret.pkr. 8285' 2.41"ID. Size Spf Interval (TVD) lin 2-3/8"HES XN-Nipple(1.875"pkg.bore) 8302' OA sands No-Go 1.791" 3 3/8" 4 8248'-8258' 4266'-4274' ELMD 8264'-8274' 4278'-4286' OB sands 1111 2-3/8"Baker'E'Hydro Trip Sub 3 3/8" 4 8328'-8343' 4330'-4342' (2.00"pkg.bore) 8310' F • 31.75"ball. 8600' 7"Halliburton Float Collar PBTD �� 8684' 7"Halliburton float shoe DATE REV.BY COMMENTS MILNE POINT UNIT 06/42/02 MDO Drilled by Cased Doyon 141 WELL No.:S-07i 08/31/02 Lee Hulme Completion Rig 4ES API"50-029-23079-00 , I 0 I I • , . , _ - „.... - ''.• - . , ,„, ..... , - • , 4.., .• .10 . • i f 't r ., , • Itit,t, ' .... t .tt . 1 A ' , ..: • , , t I:t I . .., . . 4 . • ''.1 ,1,:' . e • . 1 , , t • . ., ,. • 7,7 . ti , I C. WELL NAME MPS•07 Mine Point Unit ' OWNER E1E,E.:Qe,secE13-ECEE1,322914 ' . . •9- Sec 12,712N,R1OE I I .i SUR LOCATION NEE 4,se OPERATOR 5Bp079elor230700 alion(Alaska)Inc • ,,.API NUMBER 0 ""'„"-,,,.:.',••„:7,-,, 2 •,' • t DRILLING PERMIT 202-072 ',, • - -...',,.. •1 •EE El-- , E' — _. • ,, '-, .—, • In I ,4 - , ...... . 2,• '-,..•'-',-E'EEEEE,J,,,EEE•11.1 i . - — • • • .--, 1111P9E • 1 3 ,...- 'S- "eeee,..e 444 44ee, '. - - . imMI '..''''''',.t,' • ,...„, 1 .7il•ffflift7 ,.. • - „ , ... . . . . , ,.... . . ., . e 1 . .. ' . ...: . ,...," t.. . 3 r 1 . ., I °I' .._ , . • :. • _ . . _. . ... 4 In 0 .4ko, i ' I N). li. . , •. 1 11111 .. ...* , . . Ins- • 1 . . . . :. . . ''',.,. .•. . ... lir 416 .. , •...: 1 ',. I - - 1 , 1 - . , - ,, . • .. • , . . . • t , • a t `�Y v ti._ A Y' A °T i ' 1,—.11,• 1`a' II Xg , YJ , 0 rt y +R A �Il4, . - 5 WELL NAME MPS•O7 i - • OWNER Milne Point Unit OPERATOR BP Exploration(Alaska)Inc • . 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OJ� 00 O �7 z N O C0 A ►0 1 i L CO i] A - ' o Ut p A 0 D M r a-,�\ -�1 a\ \ r i I N u ■ -9 � I I Q y _ R.3 IIIy N I : L-1,,__ rx---11 / r r 1 cnq g M i i1 ., . , L I N s Q co a t- I K a m r o I 11E3 0 L- 136'--►` J4.ii I o cT-7 I i_ Z M ✓ Z m /j — 490' C f Z_ // . // D // // / �ii0,,Ty • • • 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 S-07 r Oper.Rep: Bill Kruskie PTD No.: 2020720 - Oper.Phone: 907-670-3387 Location Verified? Yes Oper.Email: Milne-WellsiteSupervisorsOhi If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore - Suspension Date: 11/17/11 Date AOGCC Notified: 08/20/15 Sundry No.: 311-307 - Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes - Well Pressures(psi): Tubing - Photos Taken? Yes IA 0 OA 0 Condition of Wellhead: Condition appeared good. Dual string completion.Full tree,SSVs closed no flow line attached. 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 JIM(5 Comm PLB 06/2014 2015-0823_Suspend_MPU_S-07_cs.xlsx STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMMI SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well Li Plug Perforations ❑ Perforate ❑ Other Susp Well Inspection Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. ShutdownD Stimulate - Other ❑ Re -enter Suspended WelFJ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 202 -072 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service • 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23079 -00 -00 7. Property Designation (Lease Number): _ 8. Well Name and Number: ADL0380110 MPS -07 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A MILNE POINT, SCHRADER BLFF OIL 11. Present Well Condition Summary: Total Depth measured 8695 feet Plugs measured None feet true vertical 4626.21 feet Junk measured None feet Effective Depth measured 8302 feet Packer measured See Attachment feet true vertical 4308.88 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 78 20" 91.5# H-40 1 34 - 112 34 - 112 1490 470 Surface None None None None None None Intermediate None None None None None None Production 8816 7" 26# L -80 34 - 8850 34 - 4752.88 7240 5410 Liner None None None None None None Perforation depth Measured depth 8248 - 8258 feet 8264 - 8274 feet 8328 - 8343 feet True Vertical depth 4265.64 - 4273.64 feet 4278.45 - 4286.45 feet 4329.67 - 4341.66 feet Tubing (size, grade, measured and true vertical depth) 2 -3/8" 4.7# L -80 34 - 8330 34 - 4331.27 Long String 2 -3/8" 4.7# L -80 34 - 8246 34 - 4264.04 Short String Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: %�/epl�ms) MAR 0 4 2013 RECEIVED Intervals treated (measured): 7b!'�� G AUG 21 2012 Treatment descriptions including volumes used and final pressure: ��!!,, 13. Representative Daily Average ProducAOrredt Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service Q ■ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP o - 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 Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature )3(AAAT Ce Phone 564 -4424 Date 8/21/2012 V � (1/ °1�� RBDNAS AUG 2 2 IOU . Lam Form 10-404 Revised 10/2010 Submit Original Only Packers and SSV's Attachment ADL0380110 SW Name Type MD TVD Depscription MPS -07 PACKER 8220 4170.57 2 -3/8" Baker GT Dual Packer MPS -07 PACKER 8300 4234.58 7 X 2.375 Baker FH Ret Packer • Packer Count = 2 SSSV Count = 0 • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: MPS -07 Field /Pool: Milne Point Permit # (PTD): 202 -072 API Number: 50- 029 - 23079 -00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: Surface Location: Section: Twsp: Range: Nearest active pad or road: S -Pad / Milne Point Road 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: Clean / Wellhouse has been removed Pad or location surface: Good Location cleanup needed: Remove old pit liner from Cellar Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: No Discoloration, Sheens on pad, pits or water: Clean water in cellar Samples taken: No Access road condition: Good Photographs taken (# and description): Yes / Attached 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: All valves closed and tagged or locked, Blinds installed where needed and working gauges installed where needed. Cellar description, condition, fluids: Old piece of pit liner which crew will remove today. Rat Hole: None Wellhouse or protective barriers: Yes there is a well guard in place Well identification sign: Will remove from wellhouse and attach to wellhead today. Tubing Pressure (or casing if no tubing): Zero Psi with valve closed Annulus pressures: Zero Psi with valve closed Wellhead Photos taken (# and description): Work Required: Pit Liner was removed Operator Rep (name and signature): Brian Bixby AOGCC Inspector: Bob Noble Other Observers: No Inspection Date: 7/21/2012 AOGCC Notice Date: Time of arrival: 3:30 PM Time of Departure: 4:00 PM Site access method: Drive to location • • Milne Point Unit Well MPS -07, PTD 202 -072 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of MPS -07 on 7/21/2012. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Report of Sundry Well Operations (10 -404) • 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 one - quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • MPS -07 was suspended on 11/17/2011. The work was documented in a completion report (form 10 -407 submitted 12/12/11. • MPS -07 is located on a maintained pad and is accessible by the Milne Point road system • The strata through which the well was drilled is neither abnormally geo- pressured or deleted • The well is secured with cement to surface • Both tubing strings are cemented to surface • The production casing by tubing string annulus is cemented from the upper packer (8205') to surface • Follow -up annulus pressures showed zero psi on 7/24/12. M. Bill 08/20/12 III • • Tree: 2 Dual string M P U S — 07 Wellhead: ad:ll" x x 2 2 81 3// 8" 5M FMC dual string Orig. KB Elev. = 72.70 Hanger thread 2 3/8" EUE top and IBT bottom Orig. GL Elev. = 39.20 2" CIW -H BPV profile reps. P CEMENT S t Rh To F CE /K ' Sr LON 20" x 34" insulated, 215 #/ft A -53 1 112` 1 � / S TA i.v G MY D 7" CAI/Pia 0 Short String 0010; Long Strinq 2185' I 2 -3/8" HES X- Nipple (1.875" pkg. bore) 0 x 4 OP ` x 2-3/8" HES X- Nipple (1.875" pkg. bore) 1 2246` I KOP @ 380' Max. hole angle = 79.48 deg @ 3383' � / Hole angle thru perfs = 37 DEG. d �0 / 7" 26#, L -80 BTRC Casing Note Well was completed as a monobore completion (only 7" casing) but was completed 9 / % 00.0 (drift id = 6.151, cap.= .0383 bpf) with a tubing spool and casing spool. There is _ no outer annulus, tower lock down screws are 2 -3/8 ", 4.7 #/ft L -80, IBT tubing �/ backed out. Do not attempt to run in lower lock I / clown screws as they can be run in past their (drift id = 1.901, cap. = .00387 bpf) p/ /I / sealing point. Also if the well develops a leaking / / API seal ring contact the Well Operations Cooed. x -3387. Tubing punched 4800' - 4805' (4 shots/foot) . 0 0 Calculated top of K -Max gel (6861 `) and 00 Thermatek (7378'} pumped 8/8/11 /irg� Ora 1 8168' 12 -3/8" HES X- Nipple (1.875" pkg. bore) 0 x x 2.3/8" HES X- Nipple (1.875" pkg. bore) ( 8171' I 01 p' Tubing punched 8150' - 8155' (4 shots/foot) dor .ri∎ - 7" x 2 -3/8" Baker "GT" Ret. dual pkr. 1 8205' 1.945" ID. 8220' 1 2 -3/8" HES XN- Nipple (1.875" pkg. bore) xN 1,1 No -Go 1.791" Al Weatherford CIBP set @ 8246' 8231' I Tubing tail / WLEG I Perforation Summary 7" x 2 -3/8" Baker "FH" Ret. pkr. 1 8285` I 2.41" ID. Size Spf Interval (TVD) >;v 2 -3/8" HES XN- Nipple (1.875" pkg. bore) 1 8302` I OA sands No -Go 1.791 3 3/8" 4 8248' - 8258' 4266' - 4274' 8264' - 8274' 4278' - 4286' ELMD I ` OB sands 2 -3/8" Baker `E' Hydro Trip Sub 3 3/8" 4 8328' 8343' 4330' - 4342' mil (2.00" pkg. bore) 1 8310` 7 0 1.75" ball. 8600' 1 7" Halliburton Float Collar PBTD 8684' ( 7" Halliburton float shoe DATE REV. BY COMMENTS MILNE POINT UNIT 06/22/02 MDO Drilled by Cased Doyon 141 WELL No.: S - 07i 08/31/02 Lee Hulme Completion Rig 4ES API : 50 - 23079 - BP EXPLORATION (AK) I 0 ,z 90' ►— 270' .. 270 420 270 • I I rILE I ( 1115 A 141 Li 1 Ell I I F.— 150' � . �.. • ■MANAAM■■A■ ■■...u..... �, 5 4 3 1 .... • I 35 34 33 33 . . N a . . . 14 33 32 . r 18 . 15 14 it n " m 9 90 a3 ai 3a s 1 � � M 0 I Z r I ED : I --- ._._ .1— op fl -�„ 210' -- ►-._ - -- - 1013' \ \\ \ \ Enter /Exit \ \ \ \ WELL PRODUCER Ili or ❑ WELL INJECTOR A DATE : 5/22/2012 SCALE : 1 "" = 250" MAP DATE : 2011 MILNE POINT UNIT - S PAD WELL SLOT W /CONDUCTOR !41 bs14495.mxd PU S Pad a M July 11, 2012 Approximate 1 Scale: 1" =200' 20 DMC 0 7 -85 aerometr _ r _ 1 z 4 � , - ` s Y } 1 „,,,, , .. ',,,,,;-,,,...- /. ..4',",%,_,,„,_ . ” ? .-',"'; -_ '.- 417 .' • • - • t - - ..t.c.. - .•.- ••.: ,•--- •s' !.. if.; • . ..•., .-• , ,,...: • ' ....,* '''-'‘:- - -,., • r...': ,r,..... ---,,';',. t..4 - - - 3 :f *. 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LOCArga WE i'.. +➢RF 1$. ?' „ « r. ff y '"fit 7.4-* ■ 31- JAN -2012 2 252, Schhnnherger 5885 Alaska Data & Consulting Services scoNNED MAR 2 8 a013 Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01 -24A BINC -00093 INJECTION PROFILE 15- Jan -12 1 1 01 -25 BBSK -00105 INJECTION PROFILE , 9- Jan -12 1 1 14-44A BUTT -00054 MEMORY LEAK DETECT LOG 28- Dec -11 1 1 01 -02 BVYC -00024 CROSSFLOW CHECK 30- Dec -11 1 1 V -212 BAUJ -00106 MEMORY INJECTION PROFILE 26- Dec -11 1 1 S -110 BX69 -00018 USIT 7-Jan-12 1 01 -02 BYS4 -00015 CROSSFLOW CHECK 4-Jan-12 1 • R -16 BG4H -00106 SBHPS 23- Dec -11 1 1 01 -30 BD88 -00189 MEMORY INJECTION PROFILE 19- Dec -11 1 1 15-47 BG4H -00105 CEMENT BOND LOG SCMT 20- Dec -11 1 1 13 -12A BVYC -00018 ISOLATION SCANNER 30- Nov -11 1 1 MPI -18 BG4H -00107 ISOLATION SCANNER 25- Dec -11 1 1 NGI -10 BBSK -00102 USIT 16- Dec -11 1 1 Z -116 BBSK -00104 ISOLATION SCANNER 22- Dec -11 1 1 V -222 BUTT -00051 MEMORY INJECTION PROFILE 26- Dec -11 1 1 V -106A BCRJ -00108 FSI 15- Aug -11 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 PANED 4 2012 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission a0 a 0 7�- 333 West 7 Avenue S _ Anchorage, Alaska 99501 / Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -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 III • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPS -Pad 10/11/2011 Corrosion • Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD it API if Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 """-`- MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS-11 2021130 50029230920000 1 NA 1 NA 10.2 7/292011 MPS -12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 729/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS-14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/292011 MPS -15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7292011 MPS -17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/292011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS-21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 7/28/2011 MPS -23 2021320 50029230980000 Open Flutes - Treated MPS -24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 72812011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS-26 2030610 50029231500000 1 NA 1 NA 8.5 72812011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 72812011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7282011 MPS-31 2020140 50029230660000 Open Flutes - Treated MPS -32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7282011 MPS-33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 72812011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS-90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 r • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended IS 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service 151 Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: BP Exploration (Alaska), Inc. Aband.: 11/17/2011 202 -072 311 -307 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, AK 99519 -6612 4/7/2002 50- 029 - 23079 -00 -00 1 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 3353' FSL, 20' FEL, SEC. 12, T12N, R10E, UM 4/12/2002 MPS -07 Top of Productive Horizon: 8. KB (ft above MSL): 72.7 15. Field /Pool(s): 2850' FSL, 3779' FWL, SEC. 06, T12N, R11 E, UM GL (ft above MSL): 38.9 MILNE POINT FIELD/ Total Depth: 9. Plug Back Depth(MD +TVD): SCHRADER BLUFF POOL 3017' FSL, 3995' FWL, SEC. 06, T12N, R11E, UM 8600 4549 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 565989.85 y- 6000021.49 Zone- 4 8695 4626 ADL 380109 & 380110 TPI: x- 569747.00 y- 6004833.51 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: z - 569961.30 y- 6005001.66 Zone- 4 NONE 18. Directional Survey: Yes ❑ No ISI 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/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 20AAC25.071): 22.Re -drill /Lateral Top Window MD/TVD: MWD, GR, RES, IFR / CASANDRA, SCMT N/A 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 92# H-40 SURFACE 112' SURFACE 112' 42" 260SXARCTICSET(APPROX.) 7" 26# L -80 35' 8686' 35' 4617' 9-7/8" 926 SX CLASS 'L', 326 SX CLASS 'G' 24. Open to production or injection? Yes ❑ No 151 If Yes, list each 25. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) 2 -3/8" 4.7 #, L -80 8231' 8205' 2 -3/8" 4.7 #, L -80 8315' 8285' ' .. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' ' 't JAN `.� 012 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8246' SET CIBP (LONG STRING) 8150 -8155' TUBING PUNCH (LONG STRING) 4800 -4805' TUBING PUNCH (SHORT STRING) TO SURFACE IN TUBING PUMPED 297.6 BBLS CLASS G CEMENT CIRCULATED THROUGH BOTH STRINGS 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 (Gorr): Press. 24 -Hour Rate -► 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No ID 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 25.071. RECEPt ORT '' ri w Flopma DEC 16 201117 Alaska Oil & Ggs Corns. Coreknissian Form 10-407 Revised 12/2009 fA.- l•Z` .t 2.� CONTINUED ON REVERSE 6 % j / V4_ _ Submit original only v • • 29. GEOLOGIC MARKERS (List all formations and markers encountered): '30. FORMATION TESTS NAME 1 MD + TVD Well tested? Li Yes El No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, Permafrost - Top and submit detailed test information per 20 AAC 25.071. Permafrost - Base SBF2 -NA 8038' 4102' SBF1 -NB 8074' 4129' SBE4 -NC 8110' 4157' SBE2 -NE 8135' 4176' SBE1 -NF 8197' 4225' TSBD -OA 8234' 4254' TSBC 8279' 4290' TSBB -OB 8316' 4320' SBA5 8354' 4350' Formation at total depth: 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Aras Worthington Printed Nam-. oe�stu Title: Petrotechnical Data Technologist Signatu -: � , Phone: 564 -4091 Date: 12/12/2011 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 b: 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 elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 } y . • MPS -07 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/10/2011 {Continued from 11/09/11 WSR. CT -8 1 3/4" Scope of Work: P&A. MU Weatherford MHA w/ 1.8" drift Tag plug @ 8284'. Correct to drillers depth of XN 'plug. Pull to 8000' and flag CT. Test pump. Max rate is 0.4 bpm /3900 psi CTP. L5 POOH w /drift, lay down drift asssembly. MU /RIH, & set WFT CIBP @ 8246', POOH. At surface, fill hole and PT plug to 1000 psi for 5 min's, good. MU /RIH w/ 5', 4 spf ;tubing punch. Job in progress. Continued on 11/11/11 WSR. 11/11/2011 Continued from 11/10/11 WSR. CT -8 1 3/4 ". Scope of Work: P &A. Tie -in to flag. ;Tubing punch interval 8150' -8155' @ 4 spf. Emergency Drill - Fire. Difficulties getting gun to fire. Continue various methods to fire guns, swapped out fluids, 'surging pressure on firing head. EMERGENCY DRILL ON MPU F -PAD, we had =unfired guns in hole with non freeze protected fluids. Met with crew disucussed 'muster points and well securing procedures and evacuation procedures. FP CT & CT/Tbg Ann, Cycle pressure up to 6000 psi no results, POOH w /guns. Gun did not fire. Ball recovered. Inspect firing head. No problems found, ball was on seat. PT MHA to 3800 psi, no problem. MU /RIH w/ TCP E -Fire head /5' - 4 spf decentralized ;tubing punch. in progress. Continued on 11/12/11 WSR. 11/12/2011; Continued from 11/11/11 WSR. CT -8 1 3/4 ". Scope of Work: P &A. Tie into flag. Park @ 8150' to chant 5' of 4 spf tubing bunch. Perform TCP E -fire sequence. Try 3 times down backside. 2 times down backside and coil. Establish circulation of 0.8 bpm @ 2000 psi WHP. Built IAP. POOH, keeping hole full w /diesel. RD TCP E -Fire rgun assembly, all shots fired. Stab on to WH and start circ out down LS & up 2 3/8" x :7" Ann. w /diesel. Circ out LS with diesel. RD lubricator /BOP's, move over to SS well ;side. Re -rig to short string. MU Weatherford MHA w/ 1.8" drift. In progress. 'Continued on 11/13/11 WSR 1 3 11/13/2011 Continued from 11/12/11 WSR. CT -8 1 3/4 ". Scope of Work: P &A. Rigged up on iSS. Drift w/ 1.8" to 4810'. Clear. Emergency Drill: Loss of pressure control and primary containment. MU E -fire head, 5' of 4 spf tubing punch w/ decentralizer. RIH to 4808' to shoot interval 4800' - 4805:. Guns fired, est circ up IA, POOH. Hole loaded with diesel. POP off, confirmed all shots fired, RD SWS E -fire guns /firing head. RD Inform MPU PE, MOL. to S- 110.NOTE: Will be taking returns up 7" Ann with any `pumping down either Tbg.strings. « <Job Complete » >. 11/16/2011 Well Support Demobed well and set BPV. Removed wellhouse, flowlines, foundation, installed blinds & 1502 flanges and torqued to spec for P &A cementing work. No BPV was set E _ 11/16/2011 rTIO =SSV /0 Temp =Sl Injectivity test (P &A) ***WSR continued on 11- 17 -11 * ** • 11/17/2011 * * *WSR CONTINUED FROM 11 -16 -11 Injectivity test (P &A) pumped 26 bbls 70* !diesel down long string taking returns up IA established injectivity rate of 900 psi @ 3 I bpm. pumped 24 bbls 70* diesel down long string taking returns up short string. ; Established injectivity rate of 1600 psi @ 3.5 bpm. Flushed hard line out with 45 bbls ;diesel. Cementers in control of well at departure.FWHP's = 0/0/0 11/17/2011 LS /SS /IA = 0/0/0. (Injectivity Test and P & A.) LRS completed PT. Online down LS :taking returns up the IA. Established injection of 3 bpm @ 900 psi with 47 psi on the , IA. Switched to pumping down LS and taking returns up SS. Established injection rate of 3.5 bpm @ 1600 psi with 508 psi on the IA. Fluid started coming up casing at —40 psi. Used vac truck to keep fluid in flutes of conductor. SLB rigged up and PT'd. Pum • ed 250 bbls of 15.8 ppg class G cement down the Ion • strin • takin • returns up t a IA. emen re urns a su ace. "umpe• an additional 25 bbls down the long string ng taking returns up the IA. SI IA return line and opened the short string return `line. Pumped 22.6 bbls of -••-■ •• , • •- ••• �• -..'�• - i • •- ort string. Volume from perforations to surface on the short string was 18.5 bbls. 'dumped a total of 22.6 bbls up the short string. SD Cleaned up cement van and RDMO. Final WHP's = 0/0/0. FLUIDS PUMPED BBLS 164 METH/WTR 515 DIESEL 51 SLICK 1% KCL 297.6 15.8 PPG CLASS G CEMENT 1027.6 TOTAL W Tree: CIW 2 1/16" 5M Dual string M P U S - 07 i Wellhead:11" x 2 3/8" 5M FMC dual string Orig. KB Elev. = 72.70 Hanger thread 2 3/8" EUE top and IBT bottom 1 Orig. GL Elev. = 39.20 2" CIW -H BPV profile 20" x 34" insulated, 215 #/ft A -53 112' i f _ ., ✓� .4----- c Short String Long_String 1� £ IA 2185' 2 -3/8" HES X- Nipple (1.875" pkg. bore) x :' x = 2 -3/8" HES X- Nipple (1.875" pkg. bore) 1 2246' KOP @ 380' Max. hole angle = 79.48 deg @ 3383' Hole angle thru perfs = 37 DEG. Note Well was completed as a monobore 7" 26#, L -80, BTRC Casing completion (only 7" casing) but was completed 9 with a tubing spool and casing spool. There is (drift id = 6.151, cap.= .0383 bpf) no outer annulus. Lower lock down screws are backed out. Do not attempt to run in lower lock 2 -3/8 ", 4.7 #/ft L -80, IBT tubing down screws as they can be run in past their (drift id = 1.901, cap. = .00387 bpf) sealing point. Also if the well develops a leaking API seal ring contact the Well Operations Coord. t/ 0 x -3387. Tubing punched 4800' - 4805' (4 shots /foot C011ix e d tqa -Ma get it'86 } ) ,14 2 -3/8" HES X- Nipple (1.875" pkg. bore) I 8171' 1 8168' 2 -3/8" HES X- Nipple (1.875" pkg. bore) x 0 Tubing punched 8150` - 8155' (4 shots /foot) 7" x 2 -3/8" Baker "GT" Ret. dual pkr. 1 8205' 1.945" ID. 1 8220' 2 -3/8" HES XN- Nipple (1.875" pkg. bore) xN No-Go 1.791" • Weatherford CIBP set @ 8246' V 1 8231' 1 Tubing tail / WLEG i. Perforation Summary 7" x 2 -3/8" Baker "FH" Ret. pkr. 1 8285 I 2.41" ID. Size Spf Interval (TVD) ::s 8302' 2 -3/8" HES XN- Nipple (1.875" pkg. bore) 1 1 OA sands No-Go 1.791" 3 3/8" 4 8248' - 8258' 4266' - 4274' 8264' - 8274' 4278` - 4286` ELMD I ' I OR Santis '' 2 -3/8" Baker `E' Hydro Trip Sub 3 3/8" 4 8328' - 8343' 4330' - 4342' (2.00" pkg. bore) ( 8310' I i t#1 7 , < 4 , 0 ' 1 8600' 7" Halliburton Float Collar PBTD 0 1.75" ball. 1 8684` 1 7" Halliburton float shoe 1111.1M • DATE REV. BY COMMENTS MILNE POINT UNIT 06/22/02 MDO Drilled by Cased Doyon 141 WELL No.: S -07i 08/31/02 Lee Hulme Completion Rig 4ES API : 50 -029- 23079 -00 BP EXPLORATION (AK) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 01, 2011 TO: Jim Regg ' Itic P.I. Supervisor � �� ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -07 FROM: John Crisp MILNE PT UNIT SB S -07 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB S - 07 API Well Number: 50 029 - 23079 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr111031105242 Permit Number: 202 -072 -0 Inspection Date: 10/27/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I- S-07 ' Type Inj. N TVD 4231 IA o 0 0 0 P.T.D 2020720 TypeTest SPT Test psi 1500 TOA Interval OTHER P/F P - Tubing 2040 2260 " 2194 2173 - Notes: Short String MIT -T performed pre -P &A. Re -pump re -test. Monobore Injector. fee aCso y,* Wit , 0 Cr Ut0311 01 Tuesday, November 01, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 01, 2011 TO: Jim Regg P.I. Supervisor "Rece II i� SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -07 FROM: John Crisp MILNE PT UNIT SB S -07 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 2—_ NON- CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB S -07 • API Well Number: 50- 029 - 23079 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr111031104901 Permit Number: 202-072-0 Inspection Date: 10/27/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well T s -07 T Inj N TVD 4231 IA P.T.D� 2020720 TypeTest SPT Test psi 1500 - OA — — Interval OTHER - P/F F - Tubing I^ 160 2175 2040 Notes: Short String MIT -T performed pre -P &A. Monobore Injector. aSG SAS Mit,TCr 11103 h©S F i-.0l; Z • Tuesday, November 01, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 01, 2011 TO: Jim Regg ( (q11( P.I. Supervisor ' / SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -07 FROM: John Crisp MILNE PT UNIT SB S -07 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB S - 07 API Well Number: 50 - 029 - 23079 - 00 - 00 Inspector Name: John Crisp lnsp Num: mitJCr111031105618 Permit Number: 202 - 072 - Inspection Date: 10/27/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well T S-07 ,Type Inj j N . I TVD 4231 • IA 0 — = o 0 0 P.T.DI 2020720 - TypeTest SPT Test psi 1 1500 OA Interval OTHER P /I, P - Tubing � 8 9 2240 - 2137 2095 - Notes: Long String MIT -T performed pre -P &A. Monobore Injector. DE fir, , it ! trr Tuesday, November 01, 2011 Page 1 of 1 • o[F Asly,i(A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM11IISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Aras Worthington Wells Intervention Team Lead BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPS- 07SS /LS Sundry Number: 311 -307 Dear Mr. Worthington: 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, Daniel T. Seamount, Jr. ,J Chair DATED this �G I day of October, 2011. Encl. r STATE OF ALASKA Al'tk RECEI �' .•i, 7 ALASKA" AND GAS CONSERVATION COMMISSIO• > APPLICATION FOR SUNDRY APPROVALS pm 0 C T 0 4 2011 20 AAC 25.280 / , /011 I � 1 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool Repair Well ❑ Aiwa waNiErvoirGantrca iDD Suspend E Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Ancri ' ension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 202 -0720 . 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 . 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23079 -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: • Spacing Exception Required? Yes ❑ No ❑ MPS 07SS /LS 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 380110 MILNE POINT Field / SCHRADER BLUFF 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): 8695 ' 4626.21 ' 8600 4548.59 7378,8220(SS), 8302(LS) NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20 "X34" 215.5# A -53 34 112 34 112 Surface Intermediate Production 8651' 7" 26# L -80 33 8684 33 4617 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - (SS) 2 -7/8" 4.7# L -80 30 8231 - (LS) 2 -7/8" 4.7# L -80 31 8310 Packers and SSSV Tvoe: 2 -3/8" BAKER RET. DUAL PKR Packers and SSSV MD and TVD (ft): 8205 4231 2 -3/8" BAKER FH RET. PKR 8285 4295 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El ` 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/17/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ' IS 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington Printed Name s Worthington / Title Wells Intervention Team Lead Signature f Phone Date 564 -4102 10/3/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 1 - 30 - 7 Plug Integrity / BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ A ' Other: _ A t ie. I1 Vie_. / r 14c.�4+.. �`�� ov Zo , 4 • `1 L(� a Subsequent Form Required: y 0 7 APPROVED BY Approved by: ( / COMMISSIONER THE COMMISSION Date: /a hi 1 1 1 REIDIALS OCT 17 r R ORIGINAL l��/ ■ Form 10-4 evised 1/2010 �/ Submit in Duplicate MPS -07 202 -072 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPS -07LS 8/24/02 PER 8,328. 8,343. 4,329.67 4,341.66 MPS -07SS 8/24/02 PER 8,248. 8,258. 4,265.64 4,273.64 MPS -07SS 8/24/02 PER 8,264. 8,274. 4,278.45 4,286.45 MPS -07LS 4/20/11 BPS 8,302. 8,343. 4,308.88 4,341.66 MPS -07SS 4/20/11 BPS 8,220. 8,274. 4,243.27 4,286.45 MPS -07SS 8/8/11 BPS 7,378. 8,274. 3,708.86 4,286.45 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 III 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 • • • To: Alaska Oil & Gas Conservation Commission From: Josh Allely bP Wells Group Engineer BP Alaska Date: September 26 2011 Re: Milne Point MPS -07 Sundry Approval Sundry approval to abandon the MPS -07 wellbore is requested. MPS -07 is a dual string produced water injector with perforations in the OA and OB sands. On 04/09/2011, the well failed a MIT -IA due to a near surface casing leak and was classified as Not Operable. MPS -07 must be secured for the upcoming side -track of MPS -01A for anti - collision purposes. Due to the integrity issues of the 7" casing, it is planned to fully cement both tubing strings and the 7" casing bringing cement to surface. Once it is verified that the wellbore is fully cemented, we will cut the wellhead off below pad level placing the well in a suspended state. Final abandonment (ie cutting the conductor, casing, and tubing 4 feet below tundra) will occur during final field abandonment. Well Information Short String (OA Sands) On 08/08/2011, a Thermatek treatment (used to shut off a matrix bypass event) was pumped down the short string into the OA sands leaving the top of the Thermatek plug at 7378' MD. The plug was successfully pressure tested to 1500 psi. Long String (OB Sands) The long string is secured with a XXN plug set in the XN nipple at 8302' MD. The plug was successfully tested to 2000 psi. P &A Plan Tubing punch holes will be shot in the short string above the Thermatek plug at 7378' MD. Tubing punch holes will be shot in the long string immediately above the packer at 8205' MD. Cement will be circulated down the long string, up the 7" casing until cement is verified at surface. Once cement is verified, the short string will be opened and 7" casing shut -in and cement will be circulated up the short string until cement is verified at surface. Wellhead remediation will follow after the cement has set up. � ®F -el/ ( -ed'Q/ ac j`-e/4 v� Cp 0� a � ,,- � well ,S toe n'vdePe _. o ' e Se ver" ,' 1004 • . • too s /A:r The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed cement plug is attached for reference. Nof; t �7 T s �`1 • f fi ► e�s b b�a� Planned Work: 1. S — Punch tubing in the short string above the Thermatek plug at 7378' MD. 2. S — Punch tubing in the long string above the XXN plug and packer at 8200' MD. 3. F — Circulate cement down the long string, up the 7" casing and short string leaving the Iv! ° '�� welibore fully cemented. 4. 0 — Remediate wellhead. Josh Allely Wells Group Engineer 564 -5732 (w) 350 -7362 (c) Dan Kara Wells Group Engineering Team Lead 564 -5667 (w) 240 -8047 (c) ,. .. . . • 0 Figure 1: Current wellbore schematic as of 09/26/2011 Traa: C1W 2 019' 591099 . . Wei, - . 2. 9.4 090 .: - Hang mpu S-0 1 7' • ,. KB Hey = 72 70 14. • or , - ., , 2 • - SUE top ono MT « • , # , , ........--.. Orig. GL Elmo Vfi 3920 I , i tAA I f K-riA StAs"L VIC-4'4 A i 1 Aga Ora- lilt, /7011 2r XIV , ' • «.2154A-53 11? i : iioat *I :' . *.• . S 1 2-iss: 2 HES X4443040 (t IS' 2.341' 009 )491, .. , 11 820' P80 WHO ;' I KOP 4 ; Max, hale and =70 48 thsaj i4 33E1 3' st . v . ,. , . aa a TrifrObrf, Hew 1 et . . . "..,. 37 DEG r10 ahlior heolohl4. , • . • • . ,, : ea , put D�4 it , ., *Aorta , , r • . dowr1 • OP ileY .. benmat. . ----------- , a 7' 2 I. 0314C '::: ... API: . . e(to ., .. ale . .. i ' ., a rood OM ai 4 6161, cop ,-, 9383 WO K.... • - 2-3Ar, 4 7 hat L40, 1ST ■ .. (*A so = i 9131. r...4) r COW tilX) ........._ .. r 2.316.. x_to.. rizn-pkt bc.re 1 61711 81; ' 2-318' tES X-Nipple (1 675* piw. ball) ' 4 * FA , 1 r x 2 - 3 . 4 5 ' .1.: ; f Tir Bet, tithil Or i 945* 10 74 4 ;..* . 2- ; HES XN-N .1 „ (1 .975' Op, Pete) No-Go 1 79t" , ma 4 TOiftg UM J' VA.EG r , Pelf . . . Stmtunary 7/ A 4 .' 82;4* , . Size Sp. Interve4 (TVD) , 1 1 3 - 104-N ip pl 0 1 828 pag 0 . :) 1 834.X2° 1 3 3. 4 8248' - 8250 42SE I Na...Ga 1 791' _421* 42/a ... ; ..; , = DI ' j %''' 2-3,18' Bagaw 'P 14r:fro TTip Sub VT ,,,- 4 a -53413' 4339 - 4342' ina 1 8318' NI 120' 080. .__ . 0 1 TS' bah , H , 1 r 14.3. ,, o■ Eloal Cater PAID N DATE REV. BY C0*0•EN1S MILNE POINT I.INIT, WO oohed by , w . . 141 LL NEL: S-071 i ; 11412 Les *Arne Com Rig 4ES API ; 59 ____ ,.,...,_,_ : ' EXPLORATION (AK) .,. , . 0 • Figure 2: Proposed wellbore schematic post P&A r ren OW 2 V143' 5tV CATAI Stfliqj et, ri u ..7 Wellboad:11' r2 3/8" 5M FMC dual ging MPU ,a -f 1 Orig. KB Elam a 12.70 Her throng 2 318" ELIE top and IT trodure „.„.r. Ong Gt. EieV, -,,,, 39.20 7 CIWA BP V make 4 , ri ei p ,1 0 0 i fo.3po4,1 A c t Int On 20 x 34 54, 215 Mb Ar63 riii f i , FAH) I 8 mo G-5 5 2 al Le3b511 r , i'd e. , 1 z. # = r ,;•74V-0 I 2185 1 2 -30 HIS X- Nipple (1 E75' pkg Lee) x ' e r 4 0.6 ..-,: , 2-318, H ,..- . 0 0 , -. ES X-Nipple (1 875 pito Dore) 2 r,..,„ a Z rallI5 ,r3 - „,. , F f K08' A r t 380' rr$11 t , Max Note angle o 79.48 deg P. 3383' it '5, Nola Well was Al -• tr. as a monk.. o Hole a I - Eau pens o 37 DEG. e ,,,, comet r (only r awing) nut VMS completed watt a tubing spool and casing um . Ttmte 16 no outer atendus Lower lonA down Saewe are backed ma Do not attempt to run kg tower lock , down screws as they can be run in past them seeing point Also if the well dews '* rx a leakeig 7' 268, L-80 BTRC CastrIg je 4 .-: API --ox I brig marmite Well Omuta% Cored (deft rd = 8.151 rap = 0383 but) ' x-3387 r , r - RI A 2-3/55 4 7 MI 1180, lii I tubing One. ict 1 901 cep a B0387 bet) TO - r g- - - L1 4 . 4 1 * kir , 1 PI.144.41 1 31(7 ‘ trl ... - M l'bfk 0 F 7 NE a m Ort tr, A 11 51- 5 -:.” pil - „„....,..........,...„ ,. 4 . 7-318' 1-IFS X-Nipple (1 876' peg bore) [T17 1 8158' I 2-318" tIES X-41tpute (1 575 pInt bore) 4 ,, r ' ! 1°11 4 9 1 P , - Nitut414 Pueol VI ot.)11 - 1-.0,1a_ g ' =,..7,7:: 7 x 2-3/8' Bearer "GT' it duel tAr 821 1 945' ID r 2 31.8' HIS Mg-topple (1 .875' peg bore) No-G.° 1 ii 8231' Tubing tair / WLEG .1 Perforation Summary x 2-3(8" Baker TB' Rut pkr 8285' , Size Spf Interval (IVO) r 7 re . 4 3-3/8 HES XNAlipMe 11 876 pkg bore) 8302' 1 1 33/8' 4 8248' - 8258 42 'ft' - 4274' 1 5284' - 8274 4278 - 4286' ELMD 1_J No-Go 1,191' ..,_ 2-3/8 Baker '5' Hydro Trip Sub 3 3/8 4 8328' - 8343' 4330' - 4342' NM 8.331i 54 (2 00' pig bete) — 1 I I I I 75" Ea [ 88P/ 1 7' Hallturem Float Collar 58113 Ca ' '52*5 555 , ■ . ■ ' 7 lianiburtort float shoe ■ .......* ,„,,.„„..„,„,„... DATE REV 13Y CaMMEMIA MILNE POINT UNIT 062202 MIX) Drilled by Cased Doyen 141 WE No 54) 71 08131/02 118 Corn.. - '3n. Rig 416 _-- — API ' 50029-23079.00 III BP EXPLORATION (AK) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other is MBE TREATMENT Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ WaiverD Time Extension ❑ 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 ❑ Exploratory ❑ r 202 -0720 3. Address: P.O. Box 196612 Stratigraphic Service IS 6. API Number: 00 r 00 Anchorage, AK 99519 -6612 P 50- 029 - 23079 -b QQ, 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 380110 . MPS -07SS 10. Field /Pool(s): MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 8695 feet Plugs (measured) None feet true vertical 4626.21 feet Junk (measured) None feet Effective Depth measured 8600 feet Packer (measured) 8205 8285 feet true vertical 4548.59 feet (true vertical) 4231 4295 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 34 - 112 34 - 112 Production 8651' 7" 26# L -80 33 - 8684 33 - 4617 7240 5410 Intermediate Production Liner ',_ ,A � } -j` t 5[� $ i Liner Perforation depth: Measured depth: SEE ATTACHED - _ - True Vertical depth: _ - - Tubing: (size, grade, measured and true vertical depth) 2 -3/8" 47# L -80 30 - 8231 30 - 4252 Packers and SSSV (type, measured and true vertical depth) 2 -3/8" BAKER GT RET. DUAL PKR . 8205 it 4231 2 -3/8" BAKER FH RET. PKR 8285 4295 RECEIVEV 12. Stimulation or cement squeeze summary: SEP U 8 2011 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Alaska Oil & Gas Cons. Commission Ancnorago 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 368 728 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratoryD Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: 1 W'N25 Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 0 WAGE: 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: 311 -236 Contact Joe Lastufka Printed Na , oe Lastuf Title Petrotechnical Data Technologist Signat k Phone 564 -4091 Date 9/7/2011 RBDMS SEP 09 201*- r ' 04 14 7 e-l( Form 10 -404 Revised 10/2010 Submit Original Only MPS -07SS 202 -072 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPS -07SS 8/24/02 PER 8,248. 8,258. 4,265.64 4,273.64 MPS -07SS 8/24/02 PER 8,264. 8,274. 4,278.45 4,286.45 MPS -07SS 4/20/11 BPS 8,220. 8,274. 4,243.27 4,286.45 MPS -07SS 7/25/11 BPP 8,220. 8,274. 4,243.27 4,286.45 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 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 • • • • MPS -07SS DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY • � - :e a 8/8/2011 Thermatek treatment on MPS- 07SS * ** T /IA/OA 480/0/0 Pumped 21 bbl's PW, 5 bbl's K -max gel, 58 bbl's PW, inj pressure 970 psi. Mix and pump 3 bbl's K- maxJ.Z bbl's Thermatek, 2 bbl's K -max gel„ stage thermatek with 8 bbl's PW and 21 bbl's diesel. Estimated top of Thermatek at 7378' W/2 bbl's K -max gel to 6861' md. T /IA/OA ** *Job Complete * ** 8/10/2011 'T /I =0/0 MITT to 1500 psi [ Short String ] * ** PASSED * * ** [ Test cement ] Pumped .16 bbls diesel to reach test psi of 1502 psi. 1st test lost 160 psi in 15 minutes. Bumped pressure back up to 1544 psi. 1st 15 minute test psi 1510/0 2nd 15 minutes test psi 1502/0 Tubing lost 34 psi and 8 psi for a total of 42 psi. Bled off Tbg psi FWP's =0/0 Swab, Wing, SSV = Closed Master, IA = Open to gages / FLUIDS PUMPED BBLS 12 THERMATEK 10 K -MAX GEL 90 PW 37 DIESEL 149 TOTAL • • Tree: CIW 2 1/16" 5M Dual string Wellhead:11" x 2 3/8" 5M FMC dual string M P U S -07 i Orig. KB Elev. = 72.70 Hanger thread 2 3/8" EUE top and IBT bottom Orig. GL Elev. = 39.20 2" CIW -H BPV profile 20" x 34" insulated, 215 Nit A-53 1 112` I,; Short String Long String 2185' I 2-3/8" HES X- Nipple (1.875" pkg. bore) x x 2 -3/8" HES X- Nipple (1.875" pkg. bore) I 2246' I '4W! 1,1: . f it 174 ,4 tfi #4 KOP @ 380' Max. hole angle = 79.48 deg @ 3383' Hole angle thru perfs = 37 DEG. Note Well was completed as a monobore %.,, g":;;,-,! completion (only 7" casing) but was completed ` with a tubing spool and casing spool. Their is / 4 04, rifo no outer annulus. Lower lockdown screws are backed out. Do not attempt to run in lower lock - down screws as they can be run in past their Plet sealing point. Also if the well develops a leaking 7" 26#, L -80, BTRC Casing API seal ring contact the Well operations Coord. (drift id = 6.151, cap.= .0383 bpf) : s x3387. 2 -3/8 ", 4.7 #/ft L -80, IBT tubing 4. (drift id = 1.901, cap. = .00387 bpf) '` x 2 -3/8" HES X- Nipple (1.875" pkg. bore) I 8171' I 8168' I 2 -3/8" HES X- Nipple (1.875" pkg. bore) x I 111 ' ` 7" x 2 -3/8" Baker "GT" Ret. dual pkr. I 8205' 1 1.945" ID. I 8220' I 2 -3/8" HES XN- Nipple (1.875" pkg. bore) ;� -, No -Go 1.791" r � I 8231' Tubing tail / WLEG ° } r Perforation Summary 7' x 2 -3/8" Baker "FH" Ret. pkr. I 8285' I .41 "ID. Size Spf Interval (TVD) • OA sandy 2 -3/8" HES XN- Nipple (1.875" pkg. bore) I 8302' I No -Go 1.791" 3 3/8" 4 8248' - 8258' 4266' - 4274' 8264' - 8274' 4278' - 4286' ELMD I ' I OB sands 2 -3/8" Baker `E' Hydro Trip Sub 3 3/8" 4 8328' - 8343' 4330' - 4342' (2,00 pkg. bore) 1 8310` 1 1 8600' I 7" Halliburton Float Collar PBTD 1.75" ball. 8684' I 7" Halliburton float shoe 0 ' DATE REV. BY COMMENTS MILNE POINT UNIT MDO Drilled by Cased Do on 141 06/22/02 y y WELL No.: S -07i 08/31/02 Lee Hulme Completion Rig 4ES API : 50 -029- 23079 -00 BP EXPLORATION (AK) • • sr DIF kasEn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMNIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Keith Lopez Petroleum Engineer o 7 BP Exploration (Alaska), Inc. a / P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPS -07SS Sundry Number: 311 -236 f 1 Dear Mr. Kara: YLANOV k 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 - - kend. Sin - Air D Sea o . n , a i d , DATED this Z/ day of July, 2011. Encl. , STATE OF ALASKA ( i f — , �"'�' ALASKA, AND GAS CONSERVATION COMMISSIO• 1,1,f APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: MBE TREATMENT " 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 202 -0720 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ig 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23079 -81 -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: Spacing Exception Required? Yes ❑ No ❑ MPS -07SS - , 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 380110 MILNE POINT Field / SCHRADER BLUFF Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 8695 - 4626.21 - 8600 - 4548.59 - 8220 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 34 112 34 112 Surface 8651' 7" 26# L -80 33 8684 33 4617 7240 5410 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 2 -3/8" 4.7# L -80 24 8231 Packers and SSSV Tvpe: 2 -3/8" BAKER GT RET. DUAL PKR Packers and SSSV MD and ND (ft): 8205 4231 2 -3/8" BAKER FH RET. PKR 8285 4295 I 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service IS 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/4/2011 Oil p Gas ❑ WDSPL ❑ Suspended - ` j ,.p.k 16. Verbal Approval: Date: WINJ 0 GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Keith Lopez Printed Name Keith � L . oppez Title PE � Signature ��C.vvl 7 q Phone Date G �� 564 -5718 7/21/2011 Prepared by Joe Lastufka 564-4091 COMMISSION USE ONLY � Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 I I- D 5 t `F✓ p ff:Pk Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ g Other: , P' , zsf on Subsequent Form Required: ,O i I / `' APPROVED BY 1� ^ �� ?�,,,r/ Approved b • SSIONER THE COMMISSION Date: . / • • f DMS JUL 2 9 !On , 7 . 4...... 7. Z7- cl Form 10 -403 Revised 1/2010 O 1 .� 497% Submit in Duplicate MPS -07SS 202 -072 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPS -07SS 8/24/02 PER 8,248. 8,258. 4,265.64 4,273.64 MPS -07SS 8/24/02 PER 8,264. 8,274. 4,278.45 4,286.45 MPS -07SS 4/20/11 BPS 8,220. 8,274. 4,243.27 4,286.45 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 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 • • • by To: Mark O'Malley /Rob Handy Date: July 21, 2011 MPU Ops Team Leaders From: Keith Lopez, MPU Schrader Pad Engineer 907- 564 -5718 Subject: MPS -07SS MBE Treatment Step Unit Operation 1 F Shut in all offset producers. Bullhead water into MPS -07SS. 2 F Bullhead treatment down MPS -07SS (OA sand). Keep well and offset producers and injectors shut in for minimum of 2 days and flow producers to a tank before returning to production. OBJECTIVE 1. Divert water by sealing the preferential path of injection with a cement acting fluid. Measure of success 1. Treatments are displaced into formation. CRITICAL ISSUES • Ensure pumping pressure is not above the fracture gradient. • Ensure cleanliness of pump equipment and hard line (pre and post job) & properly dispose of remnant fluid per guidance from the Environmental Team. Background MPS -07 is a monobore dual completed injector in the OA and OB sands supporting MPE -24A. The OA zone has developed an MBE with MPE -24A and injection in this zone increases the WC in MPE -24A as the water is simply cycled from the injector. Additionally, MPS -07 has recently developed a surface casing leak rendering the well inoperable. The long term plan for this well is to P&A both zones in preparation for the well to be sidetracked. The purpose of this treatment is to plug the MBE before P&A'ing and sidetracking to decrease the odds of the sidetrack reconnecting to the existing MBE. PROCEDURE 2 47 it Stage 1. Injection Test 1. RU, hold pre -job safety meeting, PT surface lines M T- ? pw- w� 2. Ensure offset producers are SI. P +r 3. Spear in with Methanol, followed by produced water. Attempt to hold injection rate constant while adjusting pressure as needed. 4. Contact Engineering to discuss the injection pressure /rate trends. Once consensus is achieved that the fluid can be successfully placed into formation at acceptable rate /pressure continue with remainder of program. • • Stage 2. Treatment 5. Ensure offset producers are offline 6. Pump produced water pre -flush followed by cement acting fluid treatment and diesel displacement. Allow setup time. 7. Rig down all equipment and hold post job assessment meeting to capture learnings to be incorporated into future jobs. 8. Forward all post job assessments (w/ all rheology test summary) and continuous pressure and rate data from job to Pad Engineer. • • Tree: Y Cr.: 5N Duai sg1rg 11 A b Wellhead:l 1' x 2.10 5141 FMC Zkta sirng M r U S -0 ! 7 i aria. KB Elev. = 722 70 Hanger thread 2 378' EUE top and 1337 3ottLn 1 — Lng. GI_ Elev. = 39 23 2' CIWV -ht BPV poodle 20' x 34` inoulated, 216 ARI A-63 1 112' I hart S rin! Loner String 1 21as. I 2 -30 '3' 4 1ES X- Nipple! 11.87r p5g bore x 2 -11.` HES X Nlppie (1.675' pttg, bete ■ I `-'' I KOP a 380` Max. hole angle = 79. -16' deg ! :? 3383• Hale angle tt1r� pert: = 37 DEC; t,; -E W sae omp etes as a Morobcsre compettor only r casing; but was competed with a tubng spoci and casing spool. Their Is no outer annlaus. Loser Iockdvsn ecrwa7 are Gacted olat. Do not astempa to run Ir °vier lock - down screws as they can be run In pas: Meir sexing palm. . Also trifle eel deseicps a 'eakirg 7" 25.1, L-E0, 13T9 C Casing API seal ring contact the Well coera;Yans Coon ISM Id - 6.1E1, cap.- .0313 opr; x3387. 2 -? r, 4.7 Bit Lea, IET tubing "r1 it - 1.901, cap. - .00337 bph x 2 -11? HES X- Nlppte 1:1.175' pug. bore) I 117 I I E.1 6E I 2 -36' HES X- Nlpp<e (1.3' ' pkg. Lore: 9 " x 2- 1'11`Baker -Gr Bet deal akr. I &2DE I 1.94.5' IYA. I 322L I 2 -1'8' HES X14*Nippee 11.875' pkg. ttcxs;a No-GO 1.791` IL 1 9 XXN plugs Set 04 -20-11 - I 1231' I Turing tall 7 WL€G Well Is secured do to &ewe ' Casing peat Perforation Summary � x 2-3,V Baker 'Ft? Rel. Or I =. I '.41` ID. . Size Slot Interval (ND) _ -378' 1IES XN- N`ppie ;1.875' pkg. tone) I 13302' I OA sands No-Go 1.791' 3 3f8' 4 1241 -1251 I 4266 -4274' E264 -1274 52+8' - 423+5' ELMID I ' I oe sands 2-11' Baker 'E Hy Map Sub 3 378' 4 -321' -1343` 4330' - 4242' — 83`0' q.00' pkg. bare) :c_7' I iallburton Collar °ETD -- I , 6 r - =' I -' Hailburton flout shoe A M, CAT= =EV. BY COMME`iTD MILNE POINT UNIT 06:21=2 MOD Dr'lec rj Case] : 141 WELL Na.: S - 07i 06 „'C2 Lee H1ar1e Co s_ton R4 4ES API : 50 BP EXPLORATION (AK) -NOT OPERABLE: MPS -07 (PTD #2020720) Failed MIT -IA Page 1 of 1 • Schwartz, Guy L (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Saturday, April 09, 2011 7:14 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; Daniel, Ryan; AK, OPS MPU Control Room; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Quy, Tiffany Subject: NOT OPERABLE: MPS -07 (PTD #2020720) Failed MIT -IA Attachments: MPS -07 (PTD #2020720) TIO and Injection Plot.doc; MPS -07 (PTD #2020720) wellbore schematic.pdf All, Produced water injector MPS -07 (PTD #2020720) failed a MIT -IA on 04/09/2011 with fluid to surface in the conductor pipe.. The well is a dual tubing string completion with a single casing string. The failed MIT -IA indicates the lack of two competent barriers in the wellbore. The well is reclassified as Not Operable and shall cease injection and be freeze protected as soon as safely possible. The plan forward will be to evaluate the well for rig workover considerations. A TIO and injection plot and wellbore schematic have been included for your reference. «MPS -07 (PTD #2020720) TIO and Injection Plot.doc» «MPS -07 (PTD #2020720) wellbore schematic.pdf» Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/27/2011 2Q2011 Not Operable Injector Re, • Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, July 04, 2011 4:44 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 2Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 2Q2011.zip� JUL Tom, Jim, Phoebe and Guy, Attached is the 2Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 202011.zip» Notes on wells: Removed from Quarterly Injection Report: 13 -09 (PTD #1811580): RWO repaired TxIA comm. On 04/30/11 END 3- 43/P -36 (PTD #1931700): Surface casing leak repaired with Brink platelets on 05/17/11 LGI -08 (PTD #1860570): Not Operable Producer that had been mismarked in BP system as a not operable injector thereby being generated to report MPF -92 (PTD #1981930): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 MPF -95 (PTD #1981790): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 P2 -16 (PTD #1931230): RWO repaired PC leak and TxIA comm. On 04/15/11 U -10 (PTD #1851970): TxIA comm. That was repaired with a tubing patch on 06/05/2011. Moved to Monthly Injector report pending AOGCC witnessed test WGI -06 (PTD #1900300): RWO repaired TxIA comm. Well moved to Monthly Injector report pending AA cancellation Z -12 (PTD #1891020): TxIA communication repaired with cement packer on 05/24/11. Added to Quarterly Injection Report: L- 23 PTD #2090990 : MIT -IA failed on 05/01/11. MPS -07 PTD # ' 0720 MIT -IA failed on 04/09/11 MPS -13 (PTD #2021140): Passed MIT -IA on 04/11/11. LTSI that requires AOGCC MIT -IA when put on production. V -227 (PTD #2091160): Exhibiting rapid IA repressurization. Classified as Not Operable on 06/20/11. 7/5/2011 Well MPS -07 Injection Plot TIO Plot Well: MPS -07 a -- Pressure vs. Rate g PTD: 2020720 -- Tbg - ____ IA MPS -07 is a monobore injector — OA , completion, therefore the AOGCC requires a state witnessed MITIA every 2 years. a _ Q • Last 90 days • Last Month 1 u � o 0 0 0 0 1 1 1 1 2/19/11 5/12/11 8/2/11 Injection Rate, MCFPD _ • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 07/01/11 0 0 -100 06/30/11 0 0 -100 06/29/11 0 0 -100 06/28/11 0 40 -100 06/27/11 0 40 -100 06/26/11 0 0 -100 06/25/11 0 0 -100 06/24/11 0 0 -100 06/23/11 0 0 -100 06/22/11 0 0 -100 06/21/11 0 0 -100 06/20/11 0 0 -100 06/19/11 0 0 -100 06/18/11 0 0 -100 06/17/11 0 0 -100 06/16/11 0 0 -100 • 06/15/11 0 0 -100 06/14/11 0 0 -100 06/13/11 0 0 -100 06/12/11 0 0 -100 06/11/11 0 0 -100 06/09/11 0 0 -100 06/08/11 0 0 -100 06/07/11 0 0 -100 06/06/11 0 0 -100 06/05/11 0 0 -100 06/04/11 0 0 -100 06/03/11 0 0 -100 06/02/11 0 0 -100 06/01/11 0 0 -100 05/31/11 0 0 -100 MEMORANDUM State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 13, 2011 TO: Jim Regg zT , 41 t4'(1 P.I. Supervisor / 7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -07 FROM: Chuck Scheve MILNE PT UNIT SB S -07 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB S -07 API Well Number: 50 029 - 23079 -00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110410161327 Permit Number: 202 -072 -0 Inspection Date: 4/9/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-07 Type Inj. W TVD 4231 ' IA 0 P.T. 2020720 I T y peTest SPT Test psi 1500 - OA Interval OTHE P/F F Tubing 900 _ Notes: Well is a single casing string design. While attempting to attain test pressure on casing fluid surfaced in conductor and pressure returned to O. - Wednesday, April 13, 2011 Page 1 of I NOT OPERABLE: MPS -07 (PTD #2020720) Failed MIT -IA Page 1 of 1 • • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, April 09, 2011 7:14 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; Daniel, Ryan; AK, OPS MPU Control Room; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Quy, Tiffany Subject: NOT OPERABLE: MPS -07 (PTD #2020720) Failed MIT -IA Attachments(MPS -07 (PTD #2020_726)10 and Injection Plot.doc; MPS -07 (PTD #2020720) wellbore schematic.pd f All, Produced water injector MPS -07 (PTD #2020720) failed a MIT -IA on 04/09/2011 with fluid to surface in the conductor pipe.. The well is a dual tubing string completion with a single casing string. The failed MIT -IA indicates the lack of two competent barriers in the wellbore. The well is reclassified as Not Operable and shall cease injection and be freeze protected as soon as safely possible. The plan forward will be to evaluate the well for rig workover considerations. A TIO and injection plot and wellbore schematic have been included for your reference. «MPS -07 (PTD #2020720) TIO and Injection Plot.doc» «MPS -07 (PTD #2020720) wellbore schematic.pdf» Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Aki JUL 1 2 2 01 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/5/2011 • I MPS -07 (PTD #2020720) TIO Plot 04 -09 -2011 Well: MPS -117 300,_ � — Thg tIA 2000- _A_ GA `_.. 00A - -- 000A On • 1 000 - • 01/15.'11 01/22/11 0129/11 02/05/11 02/12/11 02/19/11 02/26/11 03/05/11 03/12/11 03/19/11 03/26/11 04/02/11 04)09/11 • MPS -07 (PTD #2020720) Injection Plot Well: MPS -07 750 1 i3u0 • 960 1 ]) 01 650 600 800 550 700 - 500 -WHIP 600- 450 £ SW 400 PW • -MI 500 — 01 v — OHia 400 3W On 250 300 200 • • 200 , 150 100 100 50 01/15/11 01/22/11 01 /29/11 02/05/11 02/12/11 02/19/11 02/26/11 03/05/11 03/12/11 03/19/11 03/26/11 04/02/11 04/09/11 MEMORANDUM 'ro: Jim I2egg ~~t~ ~ t~~~~12(1t~ P.I. Supervisor r'xolvl: Bob Noble Petroleum Inspector LJ State of Alaska :\Iaska (hl and (ras Conservation Commission DACE: \~Vednesday, April t5, 20(1`3 Si; ILIEC'T: 1lechanical Hrtegity "I'c~stti }3P EXYLOft.AT]ON' rA1.ASK:~) INC S-07 '~f11.NE: P1' t".~Il'1' sB S-07 Sre: Inspector Iv(lN_CnNF1DENTIAL Keviewed By: P.I. Suprv Comm MILNE PT UNIT SB S-Q7 API Well Number: 50-029-230'79-0o-oU Inspector Name: Bob Noble Well Name: mitRCNO9oatat6a226 Permit Number: Zoe-t»Z-° ~ Inspection Date: aita~2oo9 Insp Num. Rel Insp Num: Packer Depth Pretest Initial IS Min. 30 Min 45 Min. 60;Min. - - ~ y `~- IA a _ __ _ _ ._. - 1 T i ,6G 1 S 10 i 17&U ~~~ ~ 17C,(t / i Well s u~ YP J. vv a~ii ~ _ _ ~ _ ---- - ~ ~_ ,_ _- L za?a7~a T e In sr t ~ TVD f~fu I ~ - -+ __ -- --- P T.. ! . y - -~Ty peTest 1 ~.._L_Test _pcI L _.. _-- -. -'~ OA ~ ~ _ I xr:cwAx f> / Tubtng~ u~;ii .. ~ icf,n 1_ _to~c~ __I u~so _ . _ _ Interval __ _. _ -... P/F --_.. _ ---___ Notes: 2-year test, monobore, duel string well ~,r.i~~~ ~~~ 1 t `~~ivt I'agc I of 1 WecU~esday, `April t5> 2009 . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Su pervisor Kerf 4(?~{¡)7 DATE: Monday, April 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORA nON (ALASKA) INC 5-07 MILNE PT UNIT SB 5-07 n--011- ~Oo- FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 'Íßi- - Comm NON-CONFIDENTIAL Well Name: MILNE PT UNIT SB S-07 API Well Number: 50-029-23079-00-00 Inspector Name: Chuck Scheve Insp N urn: mitCS070415080716 Permit Number: 202-072-0 Inspection Date: 4/14/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 5-07 Type Inj. I N I TVD I 4231 IA 0 1700 1650 1640 P.T.D 2020720 TypeTest I SPT! Test psi I ]500 OA Interval OTHER P/F P ,/ Tubing 400 500 500 500 ! I Notes: Test perfonned due to leaks encountered on other monobore completions. SCANNED APR 3 0 2007 Monday, April 23, 2007 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP ACT / Milne Point / S-Pad 04/14/07 Jeff Rea / Lee Hulme Chuck Scheve ~1)~- D7~ Packer Depth Pretest Initial 15 Min. 30 Min. WeIlIMPS-07 I Type Inj. N TVD 1 4,231' Tubing 400 500 500 500 Interval I 0 P.T.D.12020720 I Type test P Test psil 1500 CasinQ 1,700 1,650 1,640 PtFI P Notes: 4.4 bbls diesel to 1700 psi. Bled to 0 psi OA Well is currently SI. Proactive testing to determine IA status due to leaks found on other monobore completions. WeIlIMPS-09 I Type Inj. W TVD I 4,368' Tubing 800 800 800 800 Interval! 0 P.T.D.12020200 I Type test P Test psil 1500 Casing 280 1,710 1,670 1,670 PtFI P Notes: 1.6 bbls diesel to 1710 psi. Bled to 300 psi OA Proactive testing to determine IA status due to leaks found on other monobore completions. WeIlIMPS-13 I Type Inj.1 N TVD I 4,166' Tubing 1,220 1,220 1,220 1,220 Intervall 0 P.T.D.12021140 I Type test P T est psi! 1500 CasinQ 1,800 1,720 1,720 PtFI P Notes: 3.4 bbls diesel to 1800 psi. Bled to 250 psi OA Well is currently SI. Proactive testing to determine IA status due to leaks found on other monobore completions. WeIlIMPS-21 I Type Inj. N I TVD I 4,027' Tubing 200 250 250 250 Interval I 0 P.T.D.12020090 I Type test P Test psil 1500 Casing 220 1,720 1,680 1,680 PtFI P Notes: 1.7 bbls diesel to 1720 psi. Bled to 200 psi OA Well is currently SI. Proactive testing to determine IA status due to leaks found on other monobore completions. Weill I Type Inj.1 I TVD I Tubing Intervall P.T.D.I I Type test T est psi! Casing PtFI Notes: OA . . TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test ~~4NNED p R = Internal Radioactive Tracer 8u'ff~--" A R A = Temperature Anomaly 8urvey D = Differential Temperature Test 1 7 2007 INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form BFL 9/1/05 MIT MPU 8-07, 8-09, 8-13, 8-21 4-14-07.xls . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 25,2006 RE: MWD Formation Evaluation Logs: MPS-07, AK-MW-22062 MPS-07 : Digital Log Images 50-029-23079-00 1 CD Rom PLEASE ACK'\TOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRA..~SMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 r\ Signed: l . '--"" ~ tL\ Q/ /.. SCANNED AUG 3 1 2005 U, ê.. dOd - Cf1- d 1i' /-{J 13 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MEMORANDUM State of Alaska ) Alaska Oil and Gas Conservation Comm) TO: Jim Regg <7,. t 4'"t1IrK P.I. Supervisor \~ ~tt DATE: Tuesday, April 12, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-07 MILNE PT UNIT SB S-07 Src: Inspector ft"\,1·· ....'r pV Reviewed By: P.I. Suprv..... -re?,£-- Comm FROM: Jeff Jones Petroleum Inspector NON-CONFIDENTIAL Well Name: MILNE PT UNIT SB S-07 Insp Num: mitJJ050407143607 ReI Insp Num: API Well Number: 50-029-23079-00-00 Permit Number: 202-072-0 Inspector Name: Jeff Jones Inspection Date: 4/5/2005 Well I S-07 Type Inj. P.T. I 2020720 TypeTest Interval REQVAR P/F /' Notes: This monobore dual tubing string well is on a 2 year MIT test cycle required by variance. The pressure values displayed in the OA cells reflect ¡/ the test pressures observed on the tubing "long string" and the pressure values displayed in the tubing cells reflect the test pressures observed on the tubing "short string". 1.4 BBLS of diesel was pumped and this well meets the AOGCC requirements for a successful MIT. Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. S TVD 4231 IA 460 2210 2170 2160 SPT Test psi 1057.75 OA 1525 1525 1525 1525 P Tubing 1260 1260 1260 1260 "" . ,¡ G) 1 2DU~} SGJ.\N\~ED Wï\ ~ ~»J - Tuesday, April 12,2005 Page 1 of I -.., - ...- -... ---. -.....::1 Wellhead:11" x 2 3/8" 5M FMC dual string Hanger thread 2 3/8" EUE top r \BT bottom 2" CIW-H BPV profile , MPU S-07i Orig. KB Elev. = 72.70 Orig. GL Elev. = 39.20 20" x 34" insulated, 215 #/ft A-53 GE.:J j Short String I 2185' I 2-3/8" HES X-Nipple (1.875" pkg. bore) t4t œl 2-3/8" HES X-Nipple (1.875" pkg. bore) I 2246' I KOP @ 380' Max. hole angle = 79.48 deg @ 3383' Hole angle thru perfs = 37 DEG. 7" 26#, L-80, BTRC Casing (drift id = 6.151, cap.= .0383 bpf) . 2-3/8~', 4.7 #/ft L..80, IBT tubing (drift id = 1.901, cap.=.00387 bpf) I 8168' I 2-3/8" HES X-Nipple (1.875" pkg. bore) Long String 2-3/8" HES X-Nipple (1.875" pkg. bore) I 8171' I I 8205' I "".".'.·"'·""'1."'1. :."'.í.".'·..I~...I.· 7" x 2-3/8" Baker "GT" Ret. dual pkr. I':'·'''''''·'i''~.''''''··'''''"~'''''] 1.945" 10. I 8220' I 2-3/8" HES XN-Nipple (1.875" pkg. bore) No-Go 1.791" I 8231' I Tubing tail! WLEG Peñoration Summary Size Spf Interval (TVD) OA sands 33/8" 4 8248' - 8258' 4266' - 4274' 8264' - 8274' 4278' - 4286' OB sands 33/8" 4 8328' - 8343' 4330' - 4342' 18600' 18684' 7" Halliburton Float Collar PBTD 7" Halliburton float shoe DATE 06/22/02 08/31/02 REV. BY MOO I ~.:".',. ~ ~ ~ ""@'"'"''':''''''''''''''''''':''""r'''''''''':''''''' 7" 2-3/8" B k "FH" R t k ~:"""'..'"'.""«.^'''''.".'''.'''''.''w. ''''''111''''1 x a er e . p r. ,.,.",.",,,,,,.ú,.,,,...,,,,,,,.).,,,.,...,,,.... 2.41" 10. I 8285' I ~ o ~. '-~,,,"'~;..'. .. .~. .-.... COMMENTS Drilled by Cased Doyon 141 Completion Rig 4ES Lee Hulme II jW~i;:~k ............... ~ 2-3/8" HES XN-Nipple (1.875" pkg. bore) I 8302' I No-Go 1.791" ELMD I' 2-3/8" Baker 'E' Hydro Trip Sub (2.00" pkg. bore) I 8310' ~ 1.75" ball. MILNE POINT UNIT WELL No.: S-07i API : 50-029-23079-00 BP EXPLORATION (AK) J- i ¥ ~~ DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Permit to Drill 2020720 MD 8695 v' Well Name/No. MILNE PT UNIT SB S-07 Operator BP EXPLORATION (ALASKA) INC 5fz ~ ¡ /Jf/.~( c2ß'~ ~ API No. 50-029-23079-00-00 TVD 4626 ~ Completion Date 8/24/2002 ~ Completion Status 1WINJ REQUIRED INFORMATION Mud log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, IFR/GASANDRA, SCMT Well Log Information: Log/ Data Digital ~ Med/Frmt ~C ~ e-B5 D Rpt ~ Electr Dataset Number Name ~e 00937 See Notes ~ent Evaluation Vó970 LIS Verification Log Log Run Scale Media No 5 Col 1 5 Col LIS Verification ¡;./fê~perature 5 Col Well Cores/Samples Information: Name Interval Start Stop Received Sent Well Cored? ADDITIONAL INFORMATION ~ Daily History Received? Chips Received? "Y-+N--- Analysis Received? Comments: Formation Tops ---~ Compliance Reviewed By: ) , ~ Current Sta~~~~~ -=~~~~-~..>: Directional Survey @=~-------- - ---~-----_.~--->._-~.~---~- (data taken from logs Portion of Master Well Data Maint) '"-~ Interval OH/ Start Stop CH Received Comments ------------...-.----------- - 7500 8587 Case 6/21/2002 7500 8587 Case 6/21/2002 SCMT GR, CCl HTEN 7500 8587 Case 6/21/2002 96 8657 Open 8/1/2002 96 8657 Open 8/1/2002 7500 8587 Case 6/21/2002 ~-~----,----- ._--~---'---.- Sample Set Number Comments --", ~N Ø/N --~----~~----~~-~ -----~-~._---_._-_._-- Date: '~~ C) ~~ ~~-;!r~5=~=~==~~~ ø=---_U- Y , .. ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised 11/14/02, Start Injection - 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned !HI Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 33531 NSL, 20' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 2850' NSL, 9791 WEL, SEC. 06, T12N, R11 E, UM At total depth 3016' NSL, 762' WEL, SEC. 06, T12N, R11 E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 72.7' ADL 380110 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 4/7/2002 4/12/2002 8/27/2002 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 8695 4626 FT 8600 4549 FT 0 Yes !HI No 22. Type Electric or Other Logs Run MWD , GR , RES, IFR 1 CASANDRA , SCMT 23. CASING SIZE 20" 7" Classification of Service Well Water Injection 7. Permit Number 202-072 302-253 8. API Number 50- 029-23079-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS-07i 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 18001 (Approx.) WT. PER FT. 92# 26# GRADE H-40 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 112' 42" 260 sx Arctic Set (Approx.) 351 86861 9-7/8" 926 sx Class 'L', 326 sx Class IG' AMOUNT PULLED TUBING RECORD SIZE DEPTH SET (MD) 2-3/8",4.7#, L-80 8231' 2-3/8",4.7#, L-80 8285' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL/USED Freeze Protected with 96 Bbls of Diesel. Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. ,RE eEl V E D 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 4 SPF MD TVD OA Sands OA Sands 25. MD TVD 26. 82481 - 8258' 82641 - 8274' 4266' - 4274' 4278' - 4286' 08 Sands 08 Sands 83281 - 8343' 4330' - 4342' 27. Date First Production 11/05/02 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR OIL-BBL TEST PERIOD WATER-BBL GAs-McF OIL-BBL GAs-McF WATER-BBL RBDMS 8Fl G(v Form 10-407 Rev. 07-01-80 PACKER SET (MD) 82051 8285' CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-API (CORR) NOV 1 4 2002 Alaska Oil.& Gas GODS. Commission Anchorage Submit In Duplicate r' ( 29. Geologic Markers Marker Name Measured Depth SBF2-NA 80381 SBF1-NB 8074' SBE4-NC 81101 SBE2-NE 81351 SBE 1-NF 8197' TSBD-OA 82341 TSBC 8279' TSBB-OB 83161 SBA5 8354' 31. List of Attachments: 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 41021 4129' 4157' 4176' 4225' 42541 4290' 43201 4350' RECEIVED NOV 1 4 2002 Alaska Oil & Gas Cons. Commissior, Anchorage 32. I hereby certify that the for~going is true and correct to the best of my knowledge Signed s~- Title Technical Assistant Date l, l - l"-J -1)"1-- MPS-07i . 202-072 302-253 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. Drilling Engineer: Robert Odenthal, 564-4387 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 (OF, 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 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ( (' 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned a Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3353' NSL, 20' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 2850' NSL, 979' WEL, SEC. 06, T12N, R11 E, UM At total depth 3016' NSL, 762' WEL, SEC. 06, T12N, R11 E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 72.7' ADL 380110 12. Dat~pudded 13. Date T.D. Reached 14. Date Comp.",§1Jsp., or Aband. 1;112002 Jþ 4/12/2002'" 8/~jl2.002 h 1> 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 8695 4626 FT 8600 4549 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD , GR , RES, IFR 1 CASANDRA , SCMT .?3, CASING SIZE 20" 7" Classification of Service Well Water Injection 7. Permit Number 202-072 302-253 8. API Number 50- 029-23079-00 9. Unit or Lease Name Milne Point Unit 10. Well Number MPS-07i 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) WT. PER FT. 92# 26# GRADE H-40 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 112' 42" 260 sx Arctic Set (Approx.) 35' 8686' 9-7/8" 926 sx Class 'L', 326 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 4 SPF MD TVD OA Sands OA Sands 25. TUBING RECORD SIZE DEPTH SET (MD) 2-3/8",4.7#, L-80 8231' 2-3/8", 4.7#, L-80 8285' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 96 Bbls of Diesel. PACKER SET (MD) 8205' 8285' MD TVD 26. 8248' - 8258' 8264' - 8274' 4266' - 4274' 4278' - 4286' OB Sands OB Sands 8328' - 8343' 4330' - 4342' 27. Date First Production Not On Injection Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA r-~ - LI'.U." , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. 'fife tßrE-- i.,. t u OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) No core samples were taken. OCT In SEP 2 7 2002 Alaska Oft & Gas Gons. commisSion Anchorage RBDMS 8Fl Form 10-407 Rev. 07-01-80 ~ ~ l " 1 'i L Submit In Duplicate ( 29. Geologic Markers Marker Name Measured True Vertical Depth Depth SBF2-NA 8038' 4102' SBF1-NB 8074' 4129' SBE4-NC 8110' 4157' SBE2-NE 8135' 4176' SBE1-NF 8197' 4225' TSBD-OA 8234' 4254' TSBC 8279' 4290' TSBB-OB 8316' 4320' SBA5 8354' 4350' 31. List of Attachments: ( 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. RI~I1VEO SEP 2 7 2002 Alaska Qt}& Gas Gons. commiSSion Anchorage Summary of Daily Drilling Reports, Surveys and a Post Rig summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~/~ Signed Sondr~tewman ~~~ Date Title Technical Assistant M PS-07i Well Number 202-072 302-253 Permit No. / Approval No. INSTRUCTIONS Prepared By Name/Number: Sondra Stewman, 564-4750 Drilling Engineer: Robert Odenthal, 564-4387 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 ( BP EXPLORATIQN eperations Summary Report Pagè1'.' of3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-07 MPS-07 DRILL +COMPLETE NABORS NABORS 27ES Start: 4/7/2002 Rig Release: 4/14/2002 Rig Number: 27E Spud Date: 4/8/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 4/5/2002 17:00 - 00:00 7.00 RIGU P PRE RIG DOWN, MOVING RIG FROM MPE-13 TO MPS-07 MOVED CAMP AND SHOPS, AND PUMPS, MOTORS AND PITS 4/6/2002 00:00 - 00:00 24.00 RIGU P PRE MOVE RIG ON TO MPS-07i AND RIGGING UP 4/7/2002 00:00 - 01 :00 1.00 DRILL P INT1 DAYLIGHT SAVING TIME, RIG WAS ACCEPTED @ 00:01 04/07/2002 01 :00 - 01 :30 0.50 DRILL P INT1 PJSM ON NIPPLlNG UP DIVERTER 01 :30 - 10:00 8.50 DRILL P INT1 N/U 20" DIVERTER AND 16" LINE 10:00 - 19:30 9.50 DRILL P INT1 PICKING UP 5" DRILL PIPE AND STANDING IN DERRICK 19:30 - 20:30 1.00 DRILL P INT1 INSTALL SECOND SECTION OF DIVERTER LINE TOTAL 80 FT. 20:30 - 23:00 2.50 DRILL P INT1 FINISH PICKING UP 5" DRILL PIPE, PICK UP TOTAL OF 85 STANDS 23:00 - 23:30 0.50 DRILL P INT1 PREFORM DIVERTER TEST, WITNESS OF TEST WAS WAIVED BY JEFF JONES OF AOGCC 23:30 - 00:00 0.50 DRILL P INT1 PICKING UP BHA 4/8/2002 00:00 - 00:30 0.50 DRILL P INT1 HELD PJSM ON HANDLING BHA. 00:30 - 03:30 3.00 DRILL P INT1 MAKE UP BHA#1-PU 9-7/8" MXC-1 BIT, MOTOR SET AT 1.5 DEGREES AND MWD. UPLOADED MWD. 03:30 - 04:00 0.50 DRILL P INT1 FILL CONDUCTOR WITH MUD AND CHECK FOR LEAKS. 04:00 - 05:00 1.00 DRILL P INT1 TAGGED BOTTOM AT 113' AND ROTARY DRILLED FROM 113' TO 270'. 05:00 - 06:00 1.00 DRILL P INT1 PULLED OUT OF HOLE AND RACKED BACK 2 STANDS OF HWDP AND PICKED UP 3 FLEX COLLARS. 06:00 - 00:00 18.00 DRILL P INT1 DIRECTIONAL DRILL FROM 270' - 2,329', WITH 85 RPM, BIT WT. 15-20K, 450 GALS MIN,1700 PSI, TO 4-5K, AST 5 ART 8.25 4/9/2002 00:00 - 10:00 10.00 DRILL P INT1 DIRECTIONAL DRILL FROM 2,329'-4022 MD, TVD 2711 WITH 100 RPM, BIT WT. 15-20K, 500 GALS MIN, 2200 PSI, TO 4-5K, AST 1.5 ART 4.25 10:00 - 11 :30 1.50 DRILL P INT1 CIRC. 3 BOTTOMS UP 11 :30 - 15:00 3.50 DRILL P INT1 PUMPING OUT TO HW PIPE @ 725 15:00 - 16:30 1.50 DRILL P INT1 PULL OUT WITH BHA- RESET MOTOR TO 1.22- CHANGE BIT 16:30 - 18:30 2.00 DRILL P INT1 DOWN LOAD MWD TOOL 18:30 - 19:30 1.00 DRILL P INT1 SERVICE TOPDRIVE, ADJUST BRAKES 19:30 - 22:00 2.50 DRILL P INT1 TRIP IN WITH BHA TO 215, TIGHT, WORK TRU AND TEST MWD TRIPPING TO BOTTOM TIGHT FROM 1400 TO 1700, REAM LAST STAND TO BOTTOM @4022 22:00 - 00:00 2.00 DRILL P INT1 DIRECTIONAL DRILL FROM 4022' TO 4306', WITH 120 RPM, BIT WT. 15-20K, 510 GALS MIN,2100 PSI, TO 4-5K, AST 0 ART .75 4/1 0/2002 00:00 - 04:00 4.00 DRILL P INT1 DIRECTIONAL DRILL FROM 4306' TO 4700 WITH 120 RPM, BITWT. 20-25K, 510 GALS MIN, 2100 PSI, 04:00 - 05:00 1.00 DRILL N DPRB INT1 CIRC. CHECKING MWD TOOL 05:00 - 21 :30 16.50 DRILL P INT1 DIRECTIONAL DRILL FROM 4780' TO 7004 WITH 120 RPM, BIT WT. 20-25K, 510 GALS MIN,2100 PSI, 21 :30 - 00:00 2.50 DRILL P INT1 CIRC FOR SHORT TRIP, STANDING BACK ONE STAND EVERY 6000 PS, CIRC 3 BOTTOMS UP,510 GALS MIN., 2100 PSI, 120 RPMS 4/11/2002 00:00 - 00:30 0.50 DRILL P INT1 CIRC FOR SHORT TRIP, STANDING BACK ONE STAND EVERY 6000 PS, CIRC 3 BOTTOMS UP,510 GALS MIN., Printed: 4/15/2002 1:33:55 PM ( BP EXPLORATION Operati'ons".'Summary'Report Page 2 of3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-07 MPS-07 DRILL +COMPLETE NABORS NABORS 27ES Start: 4/7/2002 Rig Release: 4/14/2002 Rig Number: 27E Spud Date: 4/8/2002 End: Date From - To Hours Activity Code NPT Phase Description of Operations 4/11/2002 00:00 - 00:30 0.50 DRILL P INT1 2100 PSI, 120 RPMS 00:30 - 06:30 6.00 DRILL P INT1 SHORT TRIP TO HWP PUMPING OUT (NO PROBLEMS) 06:30 - 07:00 0.50 DRILL P INT1 SERVICE TOP DRIVE 07:00 - 10:00 3.00 DRILL P INn TRIPPING IN TO 7004, FILL PIPE EVERY 25 STANDS, NO PROBLEMS 10:00 - 00:00 14.00 DRILL P INT1 DIRECTIONAL DRILL FROM 7004' TO 8256' WITH 120 RPM, BIT WT. 20-25K, 510 GALS MIN, 2300 PSI, CONTROL DRILL FROM 7900' @ 200 FT PER HR. TOTAL ART 4.25 AST 5 4/12/2002 00:00 - 04:00 4.00 DRILL P INT1 DIRECTIONAL DRILL FROM 8256' to TD 8695' WITH 120 RPM, BIT WT. 20-25K, 510 GALS MIN, 2400 PSI, CONTROL DRILL FROM 7900' @ 200 FT PER HR. TOTAL ART 2.75 ASTO 04:00 - 07:00 3.00 DRILL P INT1 CIRC. FOR SHORT TRIP WITH 130 SPM 546 GALS MIN, 2600 PSI 125 RPMS, STAND BACK STAND OF PIPE EVERY 30 MINS., 3 BOTTOMS UP 07:00 - 11 :00 4.00 DRILL P INT1 SHORT TRIP TO HWP, PUMPED OUT TO 7,000, NO PROBLEMS 11 :00 - 11 :30 0.50 DRILL P INT1 SERVICE RIG 11 :30 - 15:00 3.50 DRILL P INT1 TRIP TO BOTTOM 8695, NO PROBLEMS, FILL PIPE EVERY 25 STANDS 15:00 - 18:30 3.50 DRILL P INn CIRC. 3 BOTTOMS UP WITH 2600 PSI 550 GALS MIN. 120 RPMS 18:30 - 22:00 3.50 DRILL P INT1 SLUG PIPE TRIP OUT TO HWP, NO PROBLEMS 22:00 - 00:00 2.00 DRILL P INT1 LAYING DOWN BHA 4/13/2002 00:00 - 00:30 0.50 CASE P INT1 LAYING DOWN BHA 00:30 - 01 :00 0.50 CASE P INT1 PJSM ON RUNNING CSG 01 :00 - 10:00 9.00 CASE P INT1 RIG UP AND RUNNING 212 JTS OF 7" 26# L-80 BTC CSG FINAL S/O WT. 90,000, LAND ON LANDING RING, SHOE @ 8685 BPTD @ 8,598 10:00 - 11 :00 1.00 CASE P INT1 CIRC. THRU FILL UP TOOL WITH 338 GALS MIN. 650 PSI 11 :00 - 12:00 1.00 CEMT P INT1 RIG UP CEMENTING HEAD AND LINES 12:00 - 13:30 1.50 CEMT P INT1 CIRC. THRU CEMENTING HEAD WITH 338 GALS MIN. 650 PSI TOTAL 2 CSG VOL. 13:30 - 19:00 5.50 CEMT P INT1 CEMENT WITH HALLIBURTON, PUMP 50 BBLS. WATER, TEST LINES TO 3,000, 50 BBLS OF 10.2 SPACER, DROP BTM PLUG, 1700 SXS., 1259 BBLS, 10.7 CLASS L LEAD, 350 SXS, 76 BBLS, TAIL 15.8 CLASS G, DROP PLUG, DISPLACE WITH 253 BBLS BRINE 10.4 AND 78 BBLS DIESEL, BUMP PLUG WITH 2000#, FLOATS OK, 400 BBLS OF 10.7 CEMENT TO SURFACE. 19:00 - 21 :00 2.00 CEMT P INT1 FLUSH RISER AND RIG DOWN CEMENTING HEAD AND LAY DOWN LANDING JT., BLOW DOWN LINES 21 :00 - 00:00 3.00 BOPSUR P INT1 NIPPLE DOWN 20" HYDRILL AND DIVERTER LINES 4/14/2002 00:00 - 01 :00 1.00 BOPSUR P INT1 NIPPLE DOWN DIVERTER 01 :00 - 06:00 5.00 BOPSUR P INT1 NIPPLE UP WELL HEAD FMC GEN 6 5000# SET DOWN 30K TO ENERGIZE WELL HEAD TESTED TO 1000# LAND TUBING 4 1/2 HANGER WITH BPV, N/U ADAPTER FLANGE, 41/16 MASTER VALVE TREE CAP AND TEST TO 5,000# 06:00 - 12:00 6.00 DRILL P INT1 LAYING DOWN DRILL PIPE FROM DERRICK IN MOUSE HOLE 12:00 - 14:00 2.00 DRILL P INT1 RIG UP TO ANNULUS WITH HB&R, TEST LINE TO 4500PSI, Printed: 4/15/2002 1:33: 55 PM ( Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPS-07 MPS-07 DRILL +COMPLETE NABORS NABORS 27ES Start: 4/7/2002 Rig Release: 4/14/2002 Rig Number: 27E Spud Date: 4/8/2002 End: 4/14/2002 From - To Hours Activity COde NPT Phase 12:00 - 14:00 2.00 DRILL P INT1 14:00 - 18:00 4.00 DRILL P INT1 18:00 - 00:00 6.00 DRILL P INT1 Description of Oper~tions TEST CSG FOR 30 MIN. WITH 4500 PSI, RIG DOWN HB&R BLOW DN LINES, SECURE WELL AND CELLAR AREA, CLEANING PITS, UNLOADING PIPE SHED RIG RELEASED @ 1800 HRS FOR RIG MOVE RIGGING DOWN, MOVE PUMP MODULE AND FIRST SECTION PIPE SHED TO TEXACO PAD, PULL MOTOR COMPLEX DOWN PAD, PULL PIT COMPLEX AWAY AND TURN AROUND Printed: 4/15/2002 1:33:55 PM ( BP EXPLORATION Operations Summary Report Page 1 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-07 MPS-07 COMPLETION NABORS DRILLING CO. NABORS 4 Start: 8/23/2002 Rig Release: 8/27/2002 Rig Number: 4ES Spud Date: End: 8/27/2002 Date From - To Hours Task Code NPT Phase Description ofOperatiohs 8/23/2002 09:00 - 14:00 5.00 RIGU P PRE MI/RU SAFE OUT EQUIPMENT RIG ACCEPT 1400 HRS. 8/23/2002 14:00 - 15:00 1.00 WHSUR P COMP NIPPLE ON TREE 15:00 - 16:30 1.50 WHSUR P COMP NIPPLE UP UPPER TBG. SPOOL 16:30 - 18:00 1.50 BOPSUR P COMP NIPPLE UP BOP 18:00 - 23:30 5.50 BOPSUR P COMP TEST CSG. TO 4000 PSI. & SET TEST PLUG & TEST BOP TO 250/2500 PSI. & PULL TEST PLUG (TEST WITNESSED BY JOHN CRISP WITH AOGC. 23:30 - 00:00 0.50 CLEAN P COMP MU BIT & SCRAPER 8/24/2002 00:00 - 03:30 3.50 CLEAN P COMP RIH WITH SCRAPER & BIT PICKING UP 3.5" DP 180 JTS. 03:30 - 04:30 1.00 CLEAN P COMP CUT & SLIP DRLG. LINE 04:30 - 07:30 3.00 CLEAN P COMP CONTINUE TO RIH TO PBTD @ 8600' 4ES KB. 07:30 - 09:00 1.50 CLEAN P COMP CHG. OUT WELL BORE FLUIDS TO 9.1 PPG. BRINE 09:00 - 12:00 3.00 CLEAN P COMP POOH & LAY ON BIT & SCRAPER 12:00 - 13:00 1.00 PERF P COMP MAKEUPHESPERFGUNS 13:00 - 16:00 3.00 PERF P COMP RIH WITH HES PERF GUN ON 3.5" DP 16:00 - 20:00 4.00 PERF P COMP RIG SWS & RUN GR/CCL & CORRELATE TO POSITION PERF GUNS. POOH & RIG ON SAME. 20:00 - 20:30 0.50 PERF P COMP POSITION GUNS & PSI. TO 3200 & GIVE 6-MIN. DELAY & PERF INTERVALS. 8248'--8258'-10' GUN 8264'--8274'--10' GUN- 8328'--8343' --15' GUN 4-SPF 3-3/8" RDX DP VNNGUN RANDOM PHASING 21.5" PEN. 0.41" EH 20:30 - 21 :30 1.00 PERF P COMP REVERSE CIRC TWO DP VOLUMES. 21 :30 - 00:00 2.50 PERF P COMP POOH 8/25/2002 00:00 - 00:30 0.50 PERF P COMP LAY ON PERF GUNS 00:30 - 04:30 4.00 EVAL P COMP MU & RIH WITH HES CHAMP PKR. TO 8307' & SET & PRESSURE TEST ISOLATION BETWEEN "OA" & "OB" SANDS OK 04:30 - 08:30 4.00 EVAL P COMP POOH LAYING ON 3.5" DP & CHAMP PKR. 08:30 - 10:30 2.00 BOPSUR P COMP CHG. RAMS IN BOP TO 2-3/8" & TEST TO 250 /3500 10:30 - 16:00 5.50 RUNCOrvP COMP RIG TBG. TOOLS & PU & RIH WITH 261 JTS. 2-3/8" TBG. 16:00 - 19:00 3.00 PULL P COMP POOH & STAND BACK LONG STRING. 19:00 - 00:00 5.00 RUNCOrvP COMP PU & RIH WITH 261 JTS. 2-3/8" TBG. FOR SHORT STRING (DUAL) 8/26/2002 00:00 - 00:30 0.50 RUNCOrvP COMP RIH WITH 2-3/8" TBG. 00:30 - 02:30 2.00 RUNCOrvP COMP POOH & STAND 261 JTS. (87) STDS. IN DERRICK FOR RE-RUN ON DUAL PKR. COMPLETION 02:30 - 03:30 1.00 BOPSURP COMP CHG. SINGLE RAMS TO DUAL FOR 2-3/8" & TEST TO 250/ 3500 PSI. 03:30 - 04:30 1.00 RUNCOrvP COMP RIG UP DUAL COMPLETION RUNNING TOOLS 04:30 - 05:00 0.50 RUNCOrvP COMP MAKE UP DUAL PKRS. 05:00 - 14:00 9.00 RUNCOrvP COMP RIH WITH DUAL STRING FROM DERRICK TO PKR. SETTING DEPTH @ 8285' 14:00 - 18:00 4.00 EVAL P COMP RIG SWS & RUN 1-11/16" GR/CCL & TIE INTO SCMT & PERF. TIE IN LOG & DETERMINE PKRS l' LOW. POOH & RIG DOWN SWS. 18:00 - 19:30 1.50 RUNCOrvP COMP SPACE OUT & LAND & TEST DUAL HANGER. 19:30 - 20:30 1.00 BOPSURP COMP SET TWC & TEST & NIPPLE ON BOP 20:30 - 23:30 3.00 WHSUR P COMP NIPPLE UP TREE & TEST SAME TO 250/5000 PSI. & PULL TWC 23:30 - 00:00 0.50 CHEM P COMP REVERSE CIRC. 178 BBL. TREATEDF BRINE WITH COREXIT &FOLLOW WITH 80 BBL. DIESEL &DROP PKR Printed: 9/4/2002 10:57:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8/26/2002 8/27/2002 ( BP . EXPLORATION Operations Summary. Report MPS-07 MPS-07 COMPLETION NABORS DRILLING CO. NABORS 4 From - To Hours ..Task Code NPT Phase 23:30 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 03:00 03:00 - 04:30 04:30 - 06:00 0.50 CHEM P 1.50 RUNCOI\tP 1.00 RUNCOI\tP 0.50 RUNCOI\tP 1.50 RUNCOI\tP 1.50 RUNCOI\tP COMP COMP COMP COMP COMP COMP Page 2 of 2 Start: 8/23/2002 Rig Release: 8/27/2002 Rig Number: 4ES Spud Date: End: 8/27/2002 Descri ptionof Operations SETTING BALL & U-TUBE TO DUAL STRINGS TBG. SET FH PKR. TO 2500 PSI. & TEST FOR 30-MIN (GOOD) SHEAR SUB @ 4100 PSI. PSI. ANNULUS TO 3000 PSI. & MONITOR FOR 30-MIN OK PERFOR INJ. TEST THROUGH SHORT STRING 2-BBL. PER MIN @ 1400 PSI. SEEN NO COMMUNICATION TO OTHER AVENUES OK. DROP SETTING BALL AND PUMP INTO POSITION ON SHORT STRING IN "XN" THAT HAS RHC PLUG INSTALLED & PSI. TBG. TO 2500 & MONITOR FOR 30- MIN OK & SHEAR OUT BALL AT 3600 PSI. RIG LUBRICATOR & SET BPV IN SHORT & LONG STRING & RIG DOWN LINES ATTACHED TO TREE & SECURE AREA & RELEASE RIG @ 0600 HRS. 8/27/2002 Printed: 9/4/2002 10:57:55 AM Well: Field: API: Permit: ( MPS-07i Milne Point 50-029-23079-00 202-072 Rig Accept: 04-07 -02 Rig Spud: 04-08-02 Rig Release: 04-14-02 Drilling Rig: Nabors 27ES POST RIG WORK 05/07/02 MIRU CTE #2. RIH with SCMT. Tag TO at 8595 CTMD log main pass to 7500. Log repeat from 7800 to 7500. SCMT shows ratty cement from shoe to 8450. Good cement from 8450 to 7850. Moderate cement from 7850 to 7500. POH pumping MEOH. OOH. RDMOx 08/27/02 Arrived location, held pre-job safety meeting, Pressure tested to 3500 psi, start down the short string tubing. Pumped 8 bbls diesel @ .86 bpm wI 1500 psi max. Switched to long string tubing and pumped 8 bbls diesel @ .86 bpm wI 1600 psi max. AOGCC Attn: Lisa Weepie 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Definitive Re: Distribution of Survey Data for Well MPS-07 Dear Sir / Madam: Enclosed are 2 survey hard copy(s) and 1 disk. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0,000.00 I MD 0,000.00 ' MD 8,695.00 ' MD ~oa-07~ 18-Apr-02 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED , '"'n t"\ r. "no? J.:. ¡-' ~"' I '0 . H \. . \.... "-IJ- Alaska Oil & Gas Cons.Conunission Andlorage BP EXPLORA TION ,ALASKA) DEF/~I INC. ' v~TIVE Milne Point Unit BPXA Milne Point MPS, Slot MPS-07 MPS-07 Job No. AKZZ22062, Surveyed: 12 April, 2002 SUR VE Y R E PO R T 19 April, 2002 Your Ref: API # 5002923079 Surface Coordinates: 6000021.49 N, 565989.85 E (70° 24' 37.7873" N, 149027'45.5698" W) Kelly Bushing: 72. 70ft above Mean Sea Level 5(..Je!i.' .."\I-IIU., DAIL.L.ING SEÀVU:ES A Halliburton Company Survey Ref: svy10111 Sperry-Sun Drilling Services D . Survey Report for MPS-D7 Your Ref: API # 5002923079 'E¡:I^,/~ Job No. AKZZ22062, Surveyed: 12 April, 2002 BP EXPLORATION (ALASKA) INC. 1 V€ne POin~:~~ Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 0.00 0.000 0.000 -72.70 0.00 O.OON O.OOE 6000021.49 N 565989.85 E 0.00 AK-6 BP_.IFH-AK 198.49 0.390 152.630 125.79 198.49 0.60 S 0.31 E 6000020.89 N 565990.17 E 0.196 -0.33 289.25 0.320 15.960 216.55 289.25 0.638 0.52E 6000020.86 N 565990.38 E 0.728 -0.24 - 377.75 2.540 23.870 305.01 377.71 1.40 N 1.38 E 6000022.90 N 565991.22 E 2.512 1.93 469.26 4.010 20.100 396.37 469.07 6.26 N 3.30E 6000027.78 N 565993.10 E 1.623 7.05 558.97 5.320 27.450 485.78 558.48 12.90 N 6.30E 6000034.44 N 565996.04 E 1.602 14.24 651.51 8.030 32.350 577.69 650.39 22.17 N 11.74E 6000043.76 N 566001.39 E 2.990 24.97 747.06 11.370 24.480 671.86 744.56 36.38 N 19.21 E 6000058.04 N 566008.74 E 3.753 40.95 843.35 14.460 24.830 765.71 838.41 55.93 N 28.20 E 6000077.67 N 566017.55 E 3.210 62.23 937.30 16.680 24.630 856.20 928.90 78.84 N 38.74 E 6000100.67 N 566027.89 E 2.364 87.16 1030.80 19.230 25.780 945.14 1017.84 104.91 N 51.03 E 6000126.84 N 566039.95 E 2.753 115.69 1127.05 20.880 25.960 1035.55 1108.25 134.60 N 65.44 E 6000156.67 N 566054.09 E 1.715 148.42 1220.58 22.'110 26.740 1122.49 1195.19 165.51 N 80.76 E 6000187.71 N 566069.14 E 1.664 182.66 1314.88 25.020 26.540 1208.82 1281.52 199.41 N 97.76 E 6000221.76 N 566085.84 E 2.769 220.33 1409.47 28.770 25.900 1293.16 1365.86 237.80 N 116.64 E 6000260.31 N 566104.39 E 3.976 262.78 1503.56 31.530 26.460 1374.51 1447.21 280.20 N 137.50 E 6000302.89 N 566124.87 E 2.949 309.67 1596.98 30.730 25.350 1454.48 1527.18 323.64 N 158.60 E 6000346.51 N 566145.59 E 1.054 357.56 1698.51 33.770 23.070 1540.34 1613.04 373.05 N 180.77 E 6000396.13 N 566167.32 E 3.225 411.03 1784.45 32.170 23.030 1612.44 1685.14 416.09 N 199.08 E 6000439.32 N 566185.25 E 1.862 457.05 1881.91 34.900 24.250 1693.67 1766.37 465.40 N 220.69 E 6000488.82 N 566206.42 E 2.885 510.12 1976.32 37.320 25.800 1769.94 1842.64 515.79 N 244.24 E 6000539.42 N 566229.53 E 2.740 565.17 2069.34 37.700 26.080 1843.72 1916.42 566.73 N 269.02 E 6000590.57 N 566253.85 E 0.448 621.34 2164.16 40.690 25.360 1917.20 1989.90 620.71 N 295.01 E 6000644.78 N 566279.36 E 3.190 680.73 2257.93 43.070 26.510 1987.01 2059.71 676.99 N 322.40 E 6000701.31 N 566306.25 E 2.667 742.80 2350.56 43.530 29.070 2054.43 2127.13 733.18 N 352.02 E 6000757.75 N 566335.37 E 1.959 806.03 2445.92 47.660 30.320 2121.15 2193.85 792.33 N 385.78 E 6000817.20 N 566368.61 E 4.431 874.00 2539.95 52.370 31.560 2181.55 2254.25 854.09 N 422.83 E 6000879.29 N 566405.12 E 5.110 945.96 2634.32 57.330 34.100 2235.87 2308.57 918.87 N 464.69 E 6000944.43 N 566446.40 E 5.697 1023.09 2725.67 62.410 36.980 2281.72 2354.42 983.10 N 510.63 E 6001009.07 N 566491.78 E 6.193 1102.00 2820.28 67.040 35.730 2322.10 2394.80 1051.99 N 561.32 E 6001078.40 N 566541.85 E 5.037 1187.40 ---_._.~_._-- 19 April, 2002 - 14:11 Page 2 of 5 DrillQuest 2.00.09.003 BP EXPLORATION (ALASKA) INC. Mifne Point Unit Measured Depth (ft) Incl. 2914.70 68.280 3009.57 67.520 3103.28 71.170 3196.41 76.890 3289.88 78.590 3383.49 79.480 3479.58 76.890 3574.45 76.740 3668.41 76.470 3762.15 76.020 3856.48 75.830 3951.01 75.900 4046.72 75.550 4141.49 74.250 4234.57 72.460 4330.59 72.310 4425.47 73.120 4519.02 72.870 4613.63 72.430 4708.73 72.170 4801.76 74.000 4896.32 77.410 4990.90 77.790 5084.85 78.410 5179.34 77.960 5273.23 78.310 5368.00 76.960 5462.08 77.790 5556.07 77.250 5649.43 74.300 19 April, 2002 - 14:11 Azim. 34.800 34.730 33.000 36.120 35.300 34.730 34.990 34.730 34.150 32.900 32.430 32.260 31.980 30.750 30.920 32.890 35.480 34.810 34.460 34.170 34.540 36.020 35.010 35.030 34.060 33.930 34.560 34.310 34.720 34.210 Sub-Sea Depth (ft) 2357.99 2393.69 2426.74 2452.36 2472.20 2490.01 2509.68 2531.32 2553.09 2575.38 2598.32 2621.40 2645.00 2669.69 2696.35 2725.41 2753.61 2780.97 2809.18 2838.09 2865.16 2888.51 2908.82 2928.19 2947.54 2966.84 2987.13 3007.70 3028.01 3050.95 Vertical Depth (ft) 2430.69 2466.39 2499.44 2525.06 2544.90 2562.71 2582.38 2604.02 2625.79 2648.08 2671.02 2694.10 2717.70 2742.39 2769.05 2798.11 2826.31 2853.67 2881.88 2910.79 2937.86 2961.21 2981.52 3000.89 3020.24 3039.54 3059.83 3080.40 3100.71 3123.65 . . :.<;;::'::"'.,v"~~~~~S> ..'Sperry-Sun Drilling Services.' Survey Report for MPS-07 Your Ref: API #- 5002923079 Job No. AKZZ22062, Surveyed: 12 April, 2002 - --.--+-"--------.---- Local Coordinates Northings Eastings (ft) (ft) 1123.30 N 1195.51 N 1268.31 N 1341.99 N 1416.15 N 1491.42 N 1568.59 N 1644.38 N 1719.76 N 1795.66 N 1872.69 N 1950.14 N 2028.69 N 2106.82 N 2183.39 N 2261.07 N 2336.01 N 2409.16 N 2483.46 N 2558.29 N 2631.76 N 2706.55 N 2781.73 N 2857.02 N 2933.20 N 3009.38 N 3085.90 N 3161.62 N 3237.23 N 3311.84 N 611.74E 661.86 E 710.70 E 761.49 E 814.80 E 867.53 E 921.28 E 974.08 E 1025.77 E 1076.06 E 1125.44 E 1174.49 E 1223.80 E 1271.43 E 1317.13 E 1365.50 E 1416.40 E 1467.90 E 1519.22 E 1570.30 E 1620.52 E 1673.44 E 1727.10 E 1779.86 E 1832.31 E 1883.68 E 1935.77 E 1987.68 E 2039.68 E 2090.89 E Page 3 of 5 Global Coordinates Northings Eastings (ft) (ft) 6001150.15 N 6001222.80 N 6001296.03 N 6001370.15 N 6001444.78 N 6001520.51 N 6001598.16 N 6001674.41 N 6001750.25 N 6001826.59 N 6001904.05 N 6001981.93 N 6002060.92 N 6002139.46 N 6002216.43 N 6002294.54 N 6002369.92 N 6002443.52 N 6002518.27 N 6002593.55 N 6002667.47 N 6002742.72 N 6002818.38 N 6002894.13 N 6002970.77 N 6003047.40 N 6003124.37 N 6003200.55 N 6003276.62 N 6003351.67 N 566591.64 E 566641.12 E 566689.31 E 566739.45 E 566792.10 E 566844.17 E 566897.24 E 566949.36 E 567000.39 E 567050.00 E 567098.70 E 567147.06 E 567195.68 E 567242.61 E 567287.64 E 567335.32 E 567385.56 E 567436.40 E 567487.07 E 567537.48 E 567587.06 E 567639.32 E 567692.31 E 567744.40 E 567796.17 E 567846.87 E 567898.28 E 567949.52 E 568000.85 E 568051.40 E Dogleg Rate (o/100ft) Vertical Section 1.598 1274.68 0.804 1362.55 4.261 1450.22 6.934 1539.68 2.011 1630.94 1.123 1722.80 2.708 1816.81 0.310 1909.14 0.666 2000.53 1.381 2091.58 0.524 2183.07 0.189 2274.73 0.463 2367.46 1.858 2458.90 1.931 2547.99 1.962 2639.48 2.743 2730.05 0.735 2819.47 0.584 2909.75 0.399 3000.33 2.004 3089.32 3.912 3180.88 1.118 3273.18 0.660 3365.07 1.112 3457.54 0.397 3549.42 1.566 3641.97 0.920 3733.76 0.715 3825.51 3.204 3915.98 liaJ . BPXA Mifne Point MPS Comment _. ~-2£- DrillQIlf!st 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for MPS-07 Your Ref: API # 5002923079 Job No. AKZZ22062, Surveyed: 12 April, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/1 OOft) 5743.86 74.040 33.830 3076.71 3149.41 3387.14 N 2141.72 E 6003427.42 N 568101.56 E 0.475 4006.82 5838.44 73.470 34.750 3103.17 3175.87 3462.16 N 2192.87 E 6003502.89 N 568152.05 E 1.111 4097.61 5934.28 73.900 34.770 3130.09 3202.79 3537.72 N 2245.31 E 6003578.91 N 568203.82 E 0.449 4189.56 6028.76 73.160 36.810 3156.88 3229.58 3611.22 N 2298.30 E 6003652.87 N 568256.15 E 2.214 4280.07 6122.64 72.560 39.420 3184.55 3257.25 3681.79 N 2353.66 E 6003723.93 N 568310.89 E 2.732 4369.46 6214.88 72.090 43.280 3212.56 3285.26 3747.75 N 2411.71 E 6003790.41 N 568368.35 E 4.020 4456.47 6309.69 71.300 47.270 3242.35 3315.05 3811.09N 2475.64 E 6003854.30 N 568431.72 E 4.081 4544.51 6403.12 70.290 51.300 3273.10 3345.80 3868.63 N 2542.49 E 6003912.43 N 568498.06 E 4.214 4629.31 6498.45 69.660 55.830 3305.76 3378.46 3921.81 N 2614.52 E 6003966.25 N 568569.62 E 4.513 4713.32 6590.45 69.090 54.380 3338.16 3410.86 3971.07 N 2685.14 E 6004016.13 N 568639.80 E 1.600 4793.27 6682.69 68.420 55.020 3371.59 3444.29 4020.75 N 2755.30 E 6004066.42 N 568709.52 E 0.973 4873.33 6776.82 68.970 54.770 3405.79 3478.49 4071.18N 2827.05 E 6004117.49 N 568780.82 E 0.635 4954.88 6869.75 68.210 55.570 3439.71 3512.41 4120.59 N 2898.06 E 6004167.53 N 568851.39 E 1.145 5035.18 6966.15 67.940 54.450 3475.71 3548.41 4171.87 N 2971.33 E 6004219.45 N 568924.20 E 1.114 5118.27 7058.99 67.680 54.140 3510.77 3583.47 4222.04 N 3041.13 E 6004270.24 N 568993.56 E 0.417 5198.54 7153.91 67.010 54.840 3547.33 3620.03 4272.92 N 3112.44 E 6004321.74 N 569064.41 E 0.981 5280.23 7246.96 67.750 55.350 3583.12 3655.82 4322.07 N 3182.88 E 6004371.51 N 569134.41 E 0.943 5359.99 7341.91 65.550 55.340 3620.75 3693.45 4371.64 N 3254.58 E 6004421.71 N 569205.68 E 2.317 5440.80 7436.08 61.240 53.980 3662.92 3735.62 4420.31 N 3323.26 E 6004470.99 N 569273.92 E 4.755 5519.19 7530.68 57.950 54.450 3710.79 3783.49 4468.02 N 3389.43 E 6004519.28 N 569339.67 E 3.504 5595.41 7624.14 55.330 53.430 3762.18 3834.88 4513.95 N 3452.53 E 6004565.77 N 569402.37 E 2.948 5668.46 7719.26 52.780 53.230 3818.01 3890.71 4559.94 N 3514.30 E 6004612.30 N 569463.72 E 2.686 5740.81 7811.19 51.880 53.420 3874.19 3946.89 4603.40 N 3572.66 E 6004656.27 N 569521.69 E 0.993 5809.18 7902.35 48.170 52.440 3932.75 4005.45 4645.49 N 3628.40 E 6004698.85 N 569577.06 E 4.152 5874.97 7995.43 43.440 52.740 3997.61 4070.31 4686.02 N 3681.38 E 6004739.86 N 569629.69 E 5.087 5937.95 8090.70 39.740 52.550 4068.85 4141.55 4724.38 N 3731.65 E 6004778.66 N 569679.61 E 3.886 5997.62 8185.74 37.210 53.130 4143.25 4215.95 4760.11 N 3778.76 E 6004814.80 N 569726.41 E 2.689 6053.35 8278.73 36.740 52.740 4217.54 4290.24 4793.82 N 3823.39 E 6004848.90 N 569770.74 E 0.565 6106.03 8372.72 37.130 52.100 4292.67 4365.37 4828.26 N 3868.15 E 6004883.74 N 569815.19 E 0.583 6159.40 8465.79 36.470 52.840 4367.20 4439.90 4862.22 N 3912.36 E 6004918.09 N 569859.10 E 0.854 6212.07 - --~-.-.-.._._-------,~- ------~~-- 19 April, 2002 - 14:11 Page 4 0(5 DriflQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for MPS-07 Your Ref: API # 5002923079 Job No. AKZZ22062, Surveyed: 12 April, 2002 . BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8560.43 35.680 52.340 4443.69 4516.39 4896.08 N 3956.63 E 6004952.34 N 569903.06 E 0.891 6264.67 8623.27 35.190 52.140 4494.89 4567.59 4918.39 N 3985.43 E 6004974.90 N 569931.67 E 0.801 6299.14 8695.00 35.190 52.140 4553.51 4626.21 4943.76 N 4018.07 E 6005000.56 N 569964.08 E 0.000 6338.26 Projected Survery -, All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.001 ° (19-Apr-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 33.320° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8695.00ft., The Bottom Hole Displacement is 6370.68ft., in the Direction of 39.103° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8695.00 4626.21 4943.76 N 4018.07 E Projected Survery Survey tool program for MPS-07 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 8695.00 4626.21 AK-6 BP _'FR-AK ---_.._._--~ ~-~---_.---*-- - 19 April, 2002 - 14:11 Page 5 of 5 DrillQuest 2.00.09.003 qO~-01~ 18-Apr-02 AOGCC Attn: Lisa Weepie 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Distribution of Survey Data for Well MPS-07 MWD Dear Sir / Madam: Enclosed are 2 survey hard copy(s) and 1 disk. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0,000.00 ' MD 0,000.00 ' MD 8,695.00 ' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) l r"\n t') " 1)0 /-,For ¡-\ L () t.. 02 AlaicaOiJ&GasCoøs. ~~Îe8Î AriQ. VVI'IJI'IVìI!On BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA Milne Point MPS, Slot MPS-07 MPS-07 MWD Job No. AKMW22062, Surveyed: 12 April, 2002 SUR VE Y R E PO R T 19 April, 2002 Your Ref: API #5002923079 Surface Coordinates: 6000021.49 N, 565989.85 E (70024' 37.7873" N, 149027'45.5698" W) Kelly Bushing: 72.7Oft above Mean Sea Level sper-ar-ay-su., DAILLING S'eAvTcìæs A Halliburton Company Survey Ref: 5vy10112 Sperry-Sun Drilling Services . Survey Report for MPS-07 MWD Your Ref: API #5002923079 Job No. AKMW22062, Surveyed: 12 April, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs . Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (01100ft) 0.00 0.000 0.000 -72.70 0.00 O.OON O.OOE 6000021.49 N 565989.85 E 0.00 MWD Magnetic 198.49 0.390 153.020 125.79 198.49 0.60S 0.31 E 6000020.89 N 565990.16 E 0.196 -0.33 289.25 0.320 16.270 216.55 289.25 0.635 0.52E 6000020.86 N 565990.37 E 0.728 -0.25 ~", 377.75 2.540 24.160 305.01 377.71 1.39 N 1.39 E 6000022.89 N 565991.23 E 2.512 1.93 469.26 4.010 20.310 396.37 469.07 6.24N 3.33E 6000027.76 N 565993.12 E 1.623 7.05 558.97 5.320 27.550 485.78 558.48 12.87 N 6.34E 6000034.42 N 565996.08 E 1.598 14.24 651.51 8.030 32.480 577.69 650.39 22.13 N 11.80 E 6000043.72 N 566001.45 E 2.991 24.97 747.06 11.370 24.580 671.86 744.56 36.33 N 19.30 E 6000057.99 N 566008.83 E 3.755 40.96 843.35 14.460 25.020 765.71 838.41 55.86 N 28.34 E 6000077.60 N 566017.69 E 3.211 62.24 937.30 16.680 24.940 856.20 928.90 78.72 N 38.99 E 6000100.55 N 566028.14 E 2.363 87.19 1030.80 19.230 26.070 945.14 1017.84 104.72 N 51.41 E 6000126.66 N 566040.34 E 2.752 115.75 1127.05 20.880 26.310 1035.55 1108.25 134.34 N 65.98 E 6000156.40 N 566054.64 E 1.716 148.50 1220.58 22.410 27.190 1122.49 1195.19 165.14 N 81.52 E 6000187.34 N 566069.90 E 1.672 182.77 1314.88 25.020 26.980 1208.82 1281.52 198.90 N 98.78 E 6000221.26 N 566086.87 E 2.769 220.47 1409.47 28.770 26.380 1293.16 1365.86 237.14 N 117.98E 6000259.66 N 566105.73 E 3.975 262.96 1503.56 31.530 26.990 1374.51 1447.21 279.35 N 139.21 E 6000302.06 N 566126.58 E 2.951 309.90 1596.98 30.730 25.920 1454.48 1527.18 322.59 N 160.73 E 6000345.48 N 566147.72 E 1.041 357.85 1698.51 33.770 23.600 1540.34 1613.04 371.79 N 183.37 E 6000394.88 N 566169.93 E 3.232 411 .40 1784.45 32.170 23.580 1612.44 1685.14 414.65 N 202.08 E 6000437.91 N 566188.26 E 1.862 457.49 1881.91 34.900 24.750 1693.67 1766.37 463.76 N 224.14 E 6000487.21 N 566209.88 E 2.878 510.64 1976.32 37.320 26.210 1769.94 1842.64 513.97 N 248.09 E 6000537.63 N 566233.39 E 2.720 565.76 2069.34 37.700 26.540 1843.72 1916.42 564.71 N 273.25 E 6000588.59 N 566258.10 E 0.462 621.98 2164.16 40.690 25.840 1917.20 1989.90 618.48 N 299.69 E 6000642.59 N 566284.06 E 3.188 681.43 2257.93 43.070 27.040 1987.01 2059.71 674.52 N 327.57 E 6000698.88 N 566311.45 E 2.678 743.58 2350.56 43.530 29.640 2054.43 2127.13 730.42 N 357.73 E 6000755.04 N 566341.11 E 1.988 806.85 2445.92 47.660 30.820 2121.15 2193.85 789.25 N 392.04 E 6000814.18 N 566374.90 E 4.420 874.86 2539.95 52.370 31.980 2181.55 2254.25 850.72 N 429.59 E 6000875.97 N 566411.90 E 5.097 946.85 2634.32 57.330 34.440 2235.87 2308.57 915.22 N 471.87 E 6000940.84 N 566453.62 E 5.671 1023.98 2725.67 62.410 37.300 2281.72 2354.42 979.18 N 518.18 E 6001005.21 N 566499.36 E 6.184 1102.86 2820.28 67.040 36.110 2322.10 2394.80 1047.76 N 569.29 E 6001074.24 N 566549.86 E 5.024 1188.24 -----~-'--~ --- --.-----.._-~ 19 April, 2002 - 14:12 Page 20f5 DriflQlJest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for MÞ8-07 MWD Your Ref: API #5002923079 Job No. AKMW22062, Surveyed: 12 April, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 2914.70 68.280 35.100 2357.99 2430.69 1118.77N 620.13 E 6001145.69 N 566600.07 E 1.644 1275.51 3009.57 67.520 35.110 2393.68 2466.38 1190.68 N 670.68 E 6001218.05 N 566649.98 E 0.801 1363.36 3103.28 71.170 33.400 2426.74 2499.44 1263.15 N 720.01 E 6001290.95 N 566698.67 E 4.253 1451.02 3196.41 76.890 36.400 2452.35 2525.05 1336.52 N 771.24 E 6001364.77 N 566749.25 E 6.878 1540.47 3289.88 78.590 35.580 2472.20 2544.90 1410.42 N 824.91 E 6001439.14 N 566802.26 E 2.011 1631.70 3383.49 79.480 34.990 2490.01. 2562.71 1485.44 N 877.99 E 6001514.63 N 566854.68 E 1.134 1723.55 3479.58 76.890 35.260 2509.68 2582.38 1562.36 N 932.10 E 6001592.02 N 566908.11 E 2.709 1817.55 3574.45 76.740 34.980 2531.32 2604.02 1637.91 N 985.24 E 6001668.04 N 566960.58 E 0.328 1909.87 3668.41 76.4 70 34.010 2553.09 2625.79 1713.24 N 1037.01 E 6001743.83 N 567011.68 E 1.045 2001.26 3762.15 76.020 33.010 2575.38 2648.08 1789.16 N 1087.28 E 6001820.19 N 567061.27 E 1.142 2092.31 3856.48 75.830 32.570 2598.32 2671.02 1866.08 N 1136.83 E 6001897.54 N 567110.14 E 0.495 2183.80 3951.01 75.900 32.370 2621.40 2694.10 1943.42 N 1186.04 E 6001975.31 N 567158.67 E 0.218 2275.46 4046.72 75.550 32.390 2645.00 2717.70 2021.75 N 1235.71 E 6002054.08 N 567207.65 E 0.366 2368.20 4141.49 74.250 31 .160 2669.69 2742.39 2099.53 N 1283.89 E 60021.32.28 N 567255.14 E 1.858 2459.66 4234.57 72.460 31.350 2696.35 2769.05 2175.76 N 1330.16 E 6002208.92 N 567300.74 E 1.933 2548.78 4330.59 72.310 33.360 2725-41 2798.11 2253.07 N 1379.14 E 6002286.65 N 567349.03 E 2.001 2640.28 4425.47 73.120 35.970 2753.61 2826.31 2327.57 N 1430.66 E 6002361.61 N 567399.89 E 2.762 2730.84 4519.02 72.870 35.240 2780.97 2853.67 2400.30 N 1482.75 E 6002434.80 N 567451.33 E 0.793 2820.23 4613.63 72.430 34.870 2809.18 2881.88 2474.23 N 1534.61 E 6002509.18 N 567502.54 E 0.596 2910.49 4708.73 72.170 34.590 2838.09 2910.79 2548.69 N 1586.23 E 6002584.09 N 567553.50 E 0.392 3001.06 4801.76 74.000 34.850 2865.16 2937.86 2621.84 N 1636.92 E 6002657.69 N 567603.54 E 1.985 3090.03 4896.32 77.410 36.300 2888.51 2961.21 2696.35 N 1690.23 E 6002732.67 N 567656.19 E 3.900 3181.58 4990.90 77.790 35.450 2908.82 2981.52 2771.20 N 1744.36 E 6002807.99 N 567709.66 E 0.965 3273.86 5084.85 78.410 35.580 2928.19 3000.89 2846.03 N 1797.76 E 6002883.29 N 567762.40 E 0.674 3365.72 5179.34 77.960 34.550 2947.54 3020.24 2921.73 N 1850.90 E 6002959.46 N 567814.86 E 1.168 3458.17 5273.23 78.310 34.370 2966.84 3039.54 2997.49 N 1902.89 E 6003035.67 N 567866.18 E 0.417 3550.03 5368.00 76.960 35.010 2987.13 3059.83 3073.60 N 1955.57 E 6003112.25 N 567918.19 E 1.570 3642.58 5462.08 77.790 34.700 3007.70 3080.40 3148.94 N 2008.04 E 6003188.05 N 567969.99 E 0.939 3734.35 5556.07 77.250 35.140 3028.01 3100.71 3224.18 N 2060.57 E 6003263.75 N 568021.85 E 0.734 3826.08 5649.43 74.300 34.090 3050.95 3123.65 3298.65 N 2111.97E 6003338.67 N 568072.60 E 3.343 3916.54 ~ ---_u_--- -.------- _.._-~_._-_._~ 19 April, 2002 - 14:12 Page 30'5 DrillQ(J(!st 2.00.09.003 ,.:i$perry.Sun Drilling Serviéè~;f!;(' . Survey Report for MPS-07 MWD Your Ref: API #5002923079 Job No. AKMW22062, Surveyed: 12 April, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 5743.86 74.040 33.600 3076.71 3149.41 3374.10 N 2162.57 E 6003414.57 N 568122.53 E 0.570 4007.39 5838.44 73.470 34.690 3103.17 3175.87 3449.25 N 2213.54 E 6003490.17 N 568172.83 E 1.260 4098.18 5934.28 73.900 34.920 3130.09 3202.79 3524.78 N 2266.04 E 6003566.15 N 568224.66 E 0.504 4190. 13 6028.76 73.160 37.080 3156.88 3229.58 3598.08 N 2319.29 E 6003639.92 N 568277.26 E 2.328 4280.63 6122.64 72.560 39.720 3184.55 3257.25 3668.38 N 2375.00 E 6003710.71 N 568332.35 E 2.762 4369.97 6214.88 72.090 43.600 3212.56 3285.26 3734.02 N 2433.40 E 6003776.87 N 568390.17 E 4.040 4456.91 6309.69 71.300 47.570 3242.35 3315.05 3797.01 N 2497.68 E 6003840.42 N 568453.88 E 4.062 4544.85 6403.12 70.290 51.600 3273.10 3345.80 3854.20 N 2564.83 E 6003898.20 N 568520.53 E 4.214 4629.53 6498.45 69.660 56.070 3305.76 3378.46 3907.04 N 2637.11 E 6003951.68 N 568592.34 E 4.455 4713.39 6590.45 69.090 54.950 3338.16 3410.86 3955.80 N 2708.08 E 6004001.06 N 568662.87 E 1.297 4793.11 6682.69 68.420 55.250 3371.59 3444.29 4004.99 N 2778.59 E 6004050.87 N 568732.94 E 0.787 4872.95 6776.82 68.970 55.040 3405.79 3478.49 4055.11 N 2850.55 E 6004101.62 N 568804.46 E 0.620 4954.36 6869.75 68.210 55.820 3439.71 3512.41 4104.20 N 2921.79 E 6004151.34 N 568875.27 E 1.131 5034.51 6966.15 67.940 54.720 3475.71 3548.41 4155.14 N 2995.29 E 6004202.94 N 568948.31 E 1.095 5117.46 7058.99 67.680 54.230 3510.77 3583.47 4205.09 N 3065.25 E 6004253.50 N 569017.83 E 0.563 5197.63 7153.91 67.010 54.860 3547.33 3620.03 4255.90 N 3136.60 E 6004304.94 N 569088.73 E 0.935 5279.28 7246.96 67.750 55.380 3583.12 3655.82 4305.02 N 3207.06 E 6004354.68 N 569158.75 E 0.948 5359.03 7341.91 65.550 55.000 3620.75 3693.45 4354.78 N 3278.63 E 6004405.07 N 569229.88 E 2.346 5439.92 7436.08 61.240 54.290 3662.91 3735.61 4403.48 N 3347.29 E 6004454.37 N 569298.11 E 4.626 5518.33 7530.68 57.950 54.620 3710.79 3783.49 4450.91 N 3413.67 E 6004502.39 N 569364.06 E 3.491 5594.43 7624.14 55.330 53.530 3762.18 3834.88 4496.69 N 3476.88 E 6004548.73 N 569426.86 E 2.968 5667.41 7719.26 52.780 54.270 3818.01 3890.7,1 4542.07 N 3539.09 E 6004594.65 N 569488.67 E 2.754 5739.50 7811.19 51.880 54.010 3874.19 3946.89 4584.70 N 3598.06 E 6004637.80 N 569547.27 E 1.004 5807.51 7902.35 48.170 53.030 3932.74 4005.44 4626.21 N 3654.23 E 6004679.80 N 569603.07 E 4.152 5873.05 7995.43 43.440 53.660 3997.61 4070.31 4666.05 N 3707.75 E 6004720.12 N 569656.23 E 5.105 5935.74 8090.70 39.740 53.430 4068.85 4141.55 4703.62 N 3758.61 E 6004758.13 N 569706.75 E 3.887 5995.07 8185.74 37.210 54.000 4143.25 4215.95 4738.61 N 3806.26 E 6004793.55 N 569754.09 E 2.688 6050.49 8278.73 36.740 53.410 4217.54 4290.24 4771.72 N 3851.34 E 6004827.05 N 569798.88 E 0.633 6102.92 8372.72 37.130 52.870 4292.67 4365.37 4805.60 N 3896.53 E 6004861.33 N 569843.77 E 0.540 6156.05 8465.79 36.470 53.410 4367.19 4439.89 4839.04 N 3941.13 E 6004895.17 N 569888.07 E 0.790 6208.50 --------- 19 April, 2002 - 14:12 Page 4 of 5 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for MPS-07 MWD Your Ref: API #5002923079 Job No. AKMW22062, Surveyed: 12 April, 2002 . BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit Milne Point MPS Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8560.43 35.680 52.010 4443.69 4516.39 4872.80 N 3985.47 E 6004929.31 N 569932.11 E 1.206 6261.06 8623.27 35.190 52.740 4494.89 4567.59 4895.04 N 4014.33 E 6004951.81 N 569960.77 E 1.030 6295.50 8695.00 35.190 52.740 4553.51 4626.21 4920.07 N 4047.23 E 6004977.13 N 569993.45 E 0.000 6334.49 Projected Survey -~.c'~ All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.001° (19-Apr-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 33.320° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8695.00ft., The Bottom Hole Displacement is 6370.80f1., in the Direction of 39.441° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8695.00 4626.21 4920.07 N 4047.23 E Projected Survey ~~. Survey tool program for MPS-07 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 8695.00 4626.21 MWD Magnetic . --_._----_..~------ ---------.--.- 19 April, 2002 - 14:12 Page 50'5 DrillQlJcst 2.00.09.003 ( STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL jlJGÆ- -tl ~I 01- ~ r(f~ /)\~ cP/O' » . 1. Type of Request: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 0 Suspend 0 Plugging 0 Time Extension II Perforate 0 Repair Well 0 Pull Tubing 0 Variance II Other 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate Completion of Well ytI'"' 5. Type of well: 0 Development 0 Exploratory 0 Stratigraphic II Service 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3353' NSL, 20' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 28501 NSL, 9791 WEL, SEC. 06, T12N, R11 E, UM At effective depth 3012' NSL, 768" WEL, SEC. 06, T12N, R11E, UM At total depth 3016' NSL, 7621 WEL, SEC. 06, T12N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 6. Datum Elevation (DF or KB) KBE = 72.71 7. Unit or Property Name Milne Point Unit 8. Well Number /' MPS-07i 9. Permit Number 202-072 10. API Number 50- 029-23079-00 11. Field and Pool Milne Point Unit / Schrader Bluff 8695 feet Plugs (measured) 4626 feet 8684 feet Junk (measured) 4617 feet Length Size Cemented MD TVD 801 20" 260 sx Arctic Set (Approx.) 112' 1121 86511 7" 1703 sx PF ILl, 347 sx Class 'GI 86861 46191 Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments a Description Summary of Proposal RE E I E ^ ! 1(' n p r¡[Hl? f;\Uv u ,J LVIi.... Alaska OH& Gas Gons. Commission Anchorage 14. Estimated date for commencing operation August 17, 2002 16. If proposal was verbally approved 0 Detailed Operations Program 15. Status of well classifications as: 0 Oil 0 Gas 0 Suspended Service Water Injection Name of approver Contact Engineer NamelNumber: 17. I hereby certify that Signed Robert Odenthal Date Approved Robert Odenthal, 564-4387 oregoin~ is~e anc cor~ the best of my knowledge -"" \-J~ CJ j ~ Title Drilling Engineer 0 BOP Sketch Prepared By Name/Number: Sondra Stewman, 564-4750 Conditions of Approval: Notify Commission so representative m)tWitness Plug integrity - BOP Test Location clearance - Mechanical Integrity Test ~ Subsequent form required 10- t../ 0 7 .It 11 J c'fAÁ-I't- c¡ ,CI\¡ 'h-/I L"'~' ~..., tt../ 'r-l ~.., Approved bV order of the Commission 0 . IgTr1ð1 SI9.. .. y Form 10-403 Rev. 06/15/88 Cammy 09f' I ~I~ (::, f L l' ~\ ~ \;~,~)! , Date Approval No. .30 Z. - Z.S3 lest ßpfE f-c¿ 5500 (lSrlJ . Commissioner Date i /¡ ~ Submit I~ ~riPlicate ( MPU S-07 Scope: 1. MIRU N4ES. 2. ND Tree. NU BOP. There are no open perfs in the well. '" 3. RIH to -2000' md and displace out diesel to kill weight brine. 4. RIH and perforate using tubing or drill pipe conveyed guns. Intervals (Ref SCMT log dated 5/7/02) 8240' - 8260' md (OA sand) 8318 '- 8338' md (OB sand) Guns 3-3/8" HSD, 4 spf, random phasing, 34B HJ II, RDX (21.9" pen, 0.40" eh) 5. RIH with bit and scraper to TD to condition hole for completion. 6. Run the dual 2-3/8" completion as per attached schematic (top packer at -8200' md, bottom packer at -8280' md.) 7. ND BOP. NU dual 2-1/16" 5M CIW Tree. 8. Freeze Protect 9. Set BPV 10. RMDO 4ES. Tree:4 1/16" WKM val! ,M Wellhead: 11" X 4 1/2" wi 4" CIW BPV 20" 92# ppf, H-40 I 113' I KOP @ 380' Max. hole angle = 55.8 deg @6498' Hole angle thru perfs = . 7" 26#, L-80, BTRC Casing (drift 10 = 6.151, cap.= .0383 bpf) Peñoration Summary Size Spf Interval MPU S-07i A 2000' of diesel 10.4# Brine (TVD) ~. ~ DATE 04/14/02 REV. BY L. Hulme COMMENTS Drilled by Nabors 27-E Orig. KB Elev. = 72.70 Orig. GL Elev. = 32.00 I 41/2" NSCT pup jt wi WLEG 5.67' I Short joints 8173' - 8192' 7" Halliburton Float Collar I 8600' I 7" Halliburton float shoe I 8684' I MILNE POINT UNIT WELL No.: S-07i API: 50-029-23079-00 BP EXPLORATION (AK) . OA Perfs 8240- 8260' md (.' ~ . ~ 1 ';' ~ ! ~ .i ~ :J ~ t ~' 'i .~ J -. t~ '; ~,~ ! "~,~ '1 fl'. ¡ ~ ~ .t ;11 ~ ~ ~ ~ ¡ .f i. , ;¡ ': ~. i ~ ~t~ ~ ".' i, .; . r. ~ { ,1 ~ I~ ~~ ~ , . .. I~~. ~ , ¡ ., f j ! .~ ~. ~ ~ _i :¡' :~ ~ ! :1 ¡ j ~ it . :~- Ii ~; -, :. ;.~~.t~ r. .J ,1 I.'~ :J ~ 1f .f; ~ . ,~ î OB Perfs - 8318- 8338' md - ....- Proposed MPs-ot~...al string completion ~ 2-3/8" 'X' nipples (set at - 2200' md) i-- 2-3/8" 4.7# L80 IBT tubing strings 7" x 2-3/8" Baker GT dual packer (set at - 8200' md) 2-3/8" 4.7# L80 1ST pup jt (-10') 2-3/8" 'X' nipple with 1.875" no-go 2-3/8" 4.7# L80 1ST pup jt (-10') Re-entry guide 7" x 2-3/8" Baker FH packer (set at -8280' md) 2-3/8" 4.7# L80lBT pup jt (-10') 2-3/8" 'X' nipple with 1.875" no-go 2-3/8" 4.7# L80 1ST pup jt (-10') Re-entry guide 2-3/8" Dual Strings with dedicated OA and 08 injection. Note to File Well MPS-07i PTO 202-072 Sundry 302-253 The Area of Review around well MPS-07i was checked by H. Okland and W. Aubert on 8/8/02. AOGCC's GeoFrame planimeter measurement function was calibrated in feet. No wells in the AOGCC GeoFrame database pass within one quarter mile of MPS-07i's injection interval. ~6;A- -8111-/o L Winton Aubert Petroleum Engineer ( ~42.3;' 1--___- I I I I ~ /~ ' ,. ---....." , "" .. moo . " 4i57.S- I '1. 705" E -24A" 1\ . ""--24" I I \ I I \ I . I ,è, I \ . i \ I I \ MPS-07i! i ~ ¡/ ~ . I i I I i . I I "".'''''''''1'''''''' . I I í I .. I J I I I I i I . I I I I I I ~ 69 ~.L. O~, -O5l~ ," ",.vN.'.>---, - ~, . '~~ ~:~)f , d rv1 r; .:.:. 1 .......ww................~".. .. ...,,",N."""".y.y..,y.,....,"'"~''' ~Œ.-D7~ 10970 WELL LOG TRANSMI'ITAL To: State of Alaska Alaska Oil and Gas Conservation COmtn. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 31, 2002 RE: MWD Fonnation Evaluation Logs MPS-07, AK-MW-22062 1 LIS fonnatted Disc with verification listing. API#: 50-029-23079-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Sign~OQQpJ RECE\VED AUG 0 J- 2002 AtaskaOil & Gas Cons. eommision .;b\in.tmorage ( ( @~KC-:>c @ ~ .IL. - 1: (' : F ~~~~~~~ TONY KNOWLES, GOVERNOR ATtASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUíTE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. . P. O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point S-07i BP Exploration (Alaska) Inc. Pennit No: 202-072 Sur. Loc. 3353' NSL, 20' WEL, SEC. 12, T12N, R10E, UM Btmhole Loc. 2899' NSL, 3872' EWL, SEC. 06, T12N, RIlE, UM Dear Mr. Archey, Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Milne Point S- 07i. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, CrÙVwvwy, (ku ~ Cammy (;)echs1i TayloQ Chair BY ORDER OF THE COMMISSION DATED thisWay of March, 2002 jjcÆnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. - .. þ ..._'" .. '- ~ ~ liJGA. 3/ ¿ II O'J- It- <¿ ( Ç)~ -~ '":>- ALASKA Ol( \JD GAS CONSERVATION COMMIS( N PERMIT TO DRILL 20 MC 25.005 1 a. Type of work II Drill 0 Redri" 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3353' NSL, 20' WEL, SEC. 12, T12N, R10E, UM At top of productive interval 2794' NSL, 3738' EWL, SEC. 06, T12N, R11 E, UM At total depth 2899' NSL, 3872' EWL, SEC. 06, T12N, R11E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 025518,2380' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade CouDlina Lenath 20" 92# H-40 Welded 80' 7" 26# L-80 BTC 8373' 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Development Oil II Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 72' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 380110 7. Unit or Property Name Milne Point Unit 8. Well Number MPS-07i ./ 9. Approximate spud date 04/05/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8445' MD / 4432' TVD 0 17. Anticipated pressure {sÿe 20 AAC 25.035 (e) (2)} 75 Maximum surface 1540 psig, At total depth (TVD) 4278' / 1968 psig Setting Depth T OD Bottom MD TVD MD TVD Surface Surface 113' 113' Surface Surface 8445'/ 4432' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Hole 42" 9-7/8" Quantitv of Cement (include staae data) 260 sx Arctic Set (Approx.) 926 sx Class 'L', 326 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD Perforation depth: measured true vertical II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Matt Green, 564-5581 Prepared By Name/Number: Terrie Hubble, 564-4628 :~~,~,~~,~~~~,~~~Ø,~,I~~ .' ,'" ,"/'" "., .,.}'.".' " "..., . " ..,' .;...- '...' ,. ',.' ".:'.,"."",'.. .;,", "",.."" "": ,', " "":', :":"':.<:.",C ""'." .' ',;,';":'0'., "..' ""C":' ':"<'-',:'" ,'.-."". }i;3,.:Ç~:~~'::Uë":f,~~l~ft, ~~~".R,JtJ~,,,,;...,,.,.:,,... ',' ., :".'"i:, ":.,,:::,.,:,,",,":':"':',',o!-,',.i,..,':'''. ',"'.',;.".,..".'..:'"0'""",,,'" .'."""""::", ,"'..., "'" .,",,:,,'.," '>"'."""":'''','"',.".;::.;J',..',. ':.,' ",C.., ,..:. ..., ' Permit Number API Number ApprOV¡1 Date See cover letter 20 ¿ - 6?.z.. 50- 0 .2 J' - ..2...3 0 ;7 ? 3, d I 0;;). for other requirements Conditions of Approval: Samples Required 0 Yes B No Mud Log Required 0 Yes 18J No Hydrogen Sulfide Measures 0 Yes .E No Directional Survey Required .s Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: \A.. \.\/;'~,,(:"'~\~ \....c\' \"\'Q~ .\.o,~",^,~\~~' <:)'" ~ by order of OriWllA1 S1gr II'; ~\I¡ I G9£:>'Rrr is~orer the commission Cammy 0.,(\ , I \ A - 20. Attachments Approved By Form 10-401 Rev. 12-01-85 Date -~ aÎ/a~ Submi{ In Triplicate ( I Well Name: I MPS-07i Drill and Complete Program Summary Schrader Bluff ( ~d Pro~uam MPS-07 Permit I Type of Well (service / producer / injector): I S-Shaped Injector Bottom Hole Location: 1926' FNL, (3352' FSL), 20' FEL, (5259' FWL), SEC. 12, T12N, R1 DE X=565,989.85 Y=6,000,021.66 2485' FNL, (2794' FSL), 1022' FEL, (3738' FWL), SEC. 6, T12N, R11 E X=569,707 Y=6,004,777 2=4134 TVDss 2517' FNL, (2761' FSL), 1064' FEL, (3697' FWL), SEC. 6, T12N, R11 E X=569,666 Y=6,004,744 2=4206 TVDss 2380' FNL, (2899' FSL), 888' FEL, (3872' FWL) SEC. 6, T12N, R11 E X=569,840 Y=6,004,883 2 = 4360 TVDss Surface Location: Target Start Location: "OA" Target Start Location: "OB" I Objective: I Schrader "OA" & "OB" I Rig: I Nabors 27E / I I Operating days to complete: 19.2 I I Max Inc: 175 I I KOP: 1300 I I KBE: 172 I I I I AFE Number: 1337280 I Estimated Start Date: 15 April 2002 I MD: 18,445 I I TVD: 14,432 I I Well Design (conventional, slimhole, etc.): I Conventional Grass Roots Injector Mud Program: See Attached 9-7/8" Production Hole Mud Properties: Spud - LSND Freshwater Mud Density (ppg} Funnel visc YP HTHP pH API Filtrate LG Solids 8.6 - 9.20 75 - 150 25 - 60 N/A 9.0 - 9.5 < 8 < 6.5 LCM Restrictions: None ¡' Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Cement Program: Casing 7.0-in 26-lb/ft L-80 BTC surface casing Size Basis 250% excess over gauge hole in permafrost interval, 400/0 excess over gauge hole below permafrost. Top of tail cement 500-ft TVD above top of N-sand. Total Cement Wash 20-bbl Water Spacer Vol: 752-bbl Spacer 50-bbl Viscosified Spacer (Alpha De~n) weighted to 10.5-lb/gal Lead 685-bbl, 926ßx 10.7Ib/gal Class L - 4.15 fe/sx (cement to surface) Tail 67-bbl, 326'Sx 15.8Ib/gal Prem G - 1.1§ fe/sx (top of tail at7,480-ft Temp BHST ~ 80°F from SOR, BHCT 85°F estimated by Halliburton 1 ( Evaluation Program: Milne( '''It MPS-07 Well Proaram 9.875-in Hole Section: Open Hole: MWD/GRlRES/PWD IFRlCASANDRA Cased Hole: SCMT (post rig) Formation Markers Formation Tops MOrkb TVDrkb TVOss Pore Pressure Estimated EMW (ft) (ft) (ft) (psi) (ppg)* Base Permafrost 1933 1822 1750 863 Top Ugnu 7156 3623 3551 1673 8.65 Top Ugnu M 7773 3913 3841 1803 8.65 NA 7980 4058 3986 1869 8.65 NB 8016 4084 4013 1881 8.65 NC 8056 4115 4043 1894 8.65 NE 8079 4133 4062 1903 8.65 NF 8131 4175 4104 1922 8.65 Top OA 8147 4188 4134 1935 8.65 Base OA 8204 4236 4164 1949 8.65 Top OB 8257 4278 4206 1968 8.65 / Base OB 8296 4308 4236 1981 8.65 TO 8445 4432 4360 2037 8.65 OWC 8319 4408 4336 2026 * Based on SS depths CasingITubing Program See attached Hole Size Csg/ WtlFt Grade Conn Length Top Bottom Tbg 0.0. MD I TVDrkb MD / TVDrkb 42-in 20-in* 92# H-40 Welded 80' 0' 113' / 113' 9.875-in 7.0-in 26# L-80 BTC 8373' 0' 8,445' / 4,432' * The 20-in conductors are insulated! Recommended Bit Program: BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 9.875-in 0' - 3,500' Smith FGXiPS 3-15 & 1 -1 0 2 9.875-in 3,500' - 8,445' Smith FGXiPS 3-14 & 1-1 0 2 ( Milne ~ t MPS-07 Well Program Well Control: Production hole will be drilled with a diverter. . Maximum anticipated BHP: ) 968-psi @ 4,278-ft TVDrkb - Top of "DB" . Maximum surface pressure: 1540-psi @ surface (Based on BHP and a full column of gas from TD @ 0.1-psi/ft) . Planned BOP test pressure: Function test diverter ,,/ . Kick tolerance: N/ A . Planned completion fluid: 10A-lb/gal brine / 7.0-lb/gal Diesel (2,000-ft MD) Drilling Hazards & Contingencies: Hydrates . Hydrates have not yet been seen on S pad, but have been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the permafrost (+/- 1 ,800-ft TVDss) but may be present in shallower SV sands and al~as deep as 3,000-ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. . Watch out for deeper gravels below the permafrost or gravels that calve off within the permafrost and tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past, several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation I' . Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. We do not expect losses while drilling this well. . H-06 (1995): Lost 100-bbl running 9-5/8" casing, good returns during cementing except no returns for last 20-bbl, contaminated cement to surface, cement 12 ft down, no top job. . H-05 (1995): Lost returns drilling at 5,360-ft (3,700-ft TVD), 40-bph to keep full, treated w/ LCM pills for two days, total losses 838-bbl, made hole opener run with some continued losses. . H-05 (1995): Ran 9-5/8" casing, lost 46-bbl conditioning mud. . H-07 (1995): Lost 50-bbl running 9-5/8" casing. . E-24 (1998): Made hole opener run, worked tight spots 1965,2620,3465,5900 and 6000, lost 72-bbl while circulating. . H-08A (1997): Had some minor losses while running 4-1/2" liner. . Follow the LOST CIRCULATION DECISION MATRIX in the well program if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3 Milne r '-:1t MPS-07 Well ProQram Expected Pressures . It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.65 Ib/gal EMW~Jn this well, the Schrader Bluff formation will be drilled with 9.1 to 9.2-lb/gal mud. . However, there is a possibility of overpressure from MPE-29i via a transmissive fault. Flow-check the well when the reservoir is entered. Pad Data Sheet . Please Read the S-Pad Data Sheet thoroughly. Breathing . N/A Hydrocarbons . Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Free Gas may be encountered below the Upper Ugnu. Faults . 3,500:t200-ft MD I 2,672-ft TVDrkb; 175-ft fault up to north, below the permafrost. . 5,750:t200-ft MD I 3,200-ft TVDrkb: 40-ft fault down to north, in the Ugnu. . 6,800:t200-ft MD I 3,500-ft TVDrkb: 50-ft fault up to south, in the Ugnu. Hydrogen Sulfide / . Milne Point S-Pad is not designated as an H2S Pad. Anti-collision Issues . None, except for consideration of planned wells. Integrity Testing . Will be drilled on diverter and no FIT/LOT is required. / 4 ( DRILL & COMPLETION PROCEDURE Milne{ )1 MPS-07 Well ProQram Drillinq 4. 5. MIRU Nabors 27E, NU diverter. Drill 9.87S-in hole to 8.445-ft MD. 4.432-ft TVD. / Rig up and run 7.0-in 26-lb/ft, L-80, BT&C casing to total'depth and cement in place. Install tubing head and Christmas tree. /' RD Nabors 27E. 1. 2. 3. 5 Field: Milne Point Well: MPS-07 DIRECTIONAL LWD OPEN HOLE LOGGING NONE NONE MWD/GRlRES IFR/CAS NONE 14-3-2002 BP EXPLORA TIOH Milne Point Unit MPS-07 Actual Surface Location: 1926' NSL & 20' FEL Bottom Hole Location: 2380' FNL & 888' FEL Status: Not Drilled ENG: Steve Campbell, Matthew Green RIG: Nabors 27E RKB: 72-ft FORM DEPTH HOLE CASING MUD INFO MD ITVD SIZE SPECS PIT INFO INFORMATION Wellhead Permafrost 20" 92# H-40 FMC Gen 6 20" x 11" 5M Welded 112' 112' 42 Insulated 250 % Excess Permafrost 40 % Excess Top of Tail Cement Top of N sand OA sand OB sand Total Depth 1 ,942' 1 ,822' 7,480' 7,980' 4,057' 8,169' 4,206' 8,257' 4,278' 8,445' 4,432' Lead Cement Volume 686.0 bbls 927 Sacks KOP @ 300' EOB @ 3067' AA=25 VS=1401' Tail Cement Volume 66.8 bbls 326 Sacks SOD @ 7275' EOD @ 8147' M=52 VS=6173' 97/8" Smith FGXiPS Production Casing 7" 26# L-80 BT&C MW = 9.2 MPS-07 Well Plan Schematic.xls I PLANT - ~~ 1, s'oO'oO'. CRID Mar-13-2002 OT:2T Frcm-t.CC WING 6 r -- -r- - ,.... ~ - , ( I I r l I I L j I I I I ~ MPS-33 ~ 1 831 I MPS-29i 4- I I MPS-27'" j r MPS-24i -+- 1 I .21 I L J I I I .15 ~ , '---L .9 I I MPS-7i + I r --- ''tSêCì - - or- -- I MPS-Q3 ~ -S -~7" r 11 MPS-01 'fcr 0; 72~, IY10 I . T7 <N --.:.. '£ ... ' R71f I I. I 1 ~ ¡ I I r¿"". I iff--- :::z - - _r- - - '- - _L ~ MPU +90T-659-5065 ( T-T15 P.002/002 21 28 .... ~._"'-----.I.~. ./1 J~ H-PAD T13,." 112N 2 35 32 :s:s ~-... I(~ 5 PRdEcT.3 J~r=A-,._.~ - S-PAD " B ~ 10 14 1.3 ~"" 17 'Õ 15 - :-. 18 Q:Œ VICINITY MAP N.T.S, --. LFGEND ~ AS-STAKED CONDUCTOR EXISTING CONDUCTOR . NOTf'S; 1. DA TE OF SURvEy: MARCH 6, 2002. 2. REFER~NCE fIELD 800K; MP02-03 PAGE 18. ~. COORPNATES ARE: ALASKA STATE PLANE. ZONE-4 NAC-27. ,... GEODETIC COOROINATES ARE NAD-27. S. MPU S-PAD AVERAGE SCALE fACTOR 1$; 0.999904923. 6. HORIZONTAL CONTROL IS 8ASE;O ON MPU CfP MONUMENT CF'P-3 ANO MPU H-PAD MONUMENT H-1. 7. ELEVATIONS ARE BPX MEAN SEA L.EvEL BASED ON MILNE: POINT PIPELINE VE:RTICAL CONTROL ;¡ t ~ :x t 1 ì : LOCATED WITHIN PROTRACTED SEC. 12. T. 12 N.. R. 10 E.. UMIAT MERIDIAN, ALASKA " \VEl.L A.S.P. I PLAN"T ~-" GEODETIC. -- GEOD-ETIC GROUND SECTIÖN NO. COORDINATES COORDINATES POSITION(OMS) 'POSITlON(D.DD) ELEVATION QfFSETS : . y= 6,000,021.66' Ñ= 2,2.37.00 70.24'37.789" 70.410496.9.' 3.35-:3' FSL MPS- ,. : X¡;; 565,989.86 E= 6.869.00 149"27'45.570" 149.4626583" 38,7' 20' FEL .. ~ ~ t ¡ ! H - .-l~O"~~ -]--W ~ ffi~~~o ~.f.!£. :-:7 :.=.:::."-' I'V, CtlI< ---.~...... ~..... ~-- ~ -......., . ! -.-.. 1 0 .1/8/02 IS&.EO ..aIt_'f'IIÇf!!,lA~ ! . ,.0. CA 1£ " . n AE.,.S1QN DR^""c. BURT C"~C"¡'"I' COTTON . ,:jAIL. OFtA_G..Jl.e192 FRS02 hiPS to-OO ä1'oO Së;:;X"" . 1"- 200' 4) b~ -- MILNE POINT UNIT S-PAD AS-STAKED CONDUCTOR WELL MPS-07i . Sr1Eë:T , 01 , 03/13/02 WED 06:34 [TX/RX NO 6322] I4J OO~ BP EXPLORA TION (A ) INC. '-. ~'Ÿfit Unit B A Working, Slot MPS-07 07 Wps - MPS-07 Wp05 Revised: 21 February. 2002 PROPOSAL REPORT 21 February, 2002 ~ Surface Coordinates: 6000021.66 N. 565989.85 E (70024' 37.7890" N. 149027' 45.5697" W) Surface Coordinates relative to Project H Reference: 1000021.66 N, 65989.85 E (Grid) Surface Coordinates relative to Structure: 49.80 N. 354.72 W (True) Kelly Bushing: 72.00ft above Mean Sea Level =-1-IE!n-ty-!5Ur1 DÂla::LluNG.....~S.ÉA V.I.CS S ~ HallibUrton Company Proposal Ref: pro 10066 """~I....Y-.!!5LII'"'1 Milne Point Unit OAtL...tNGA:';:b:~~: BPXA MPS-Pad MPS-07 WPOS DrillQuest' Single Well Target Data for MPS-07 WP05 Measurement Units: ft Coordinate Target Point TVD Name Type MPS-07 T] Top OA Entry Point 4] 88.00 Northings Eastings SSTVD 4116.00 Northings ASPY 6004777.00 N Eastings ASP X 569707.00 E Target Shape 4722.3] N 3759JJ2 E Point Proposal Data for MPS-07 Wp05 0 Vertical Origin: ~~~~~~~~~;~~ns : North Reference: Well Well ft True North ~Begin Dir @ 2.0000/100ft: 300.001t MD, 300.00ft TVD ~ Dir Rate Increase @ 2.5000/100ft: 499.91ftMD,499.75ftTVD 1600 - Dir Rate Decrease @ 1.0000/1001t: 1640.75ftMD,1572.00ftTVD nd Dir, Start Sail @ 35.536°: 1942.44ftMD,1822.00ftTVD Dogleg severity: Degrees per 100 feet (US) Vertical Section Azimuth : 33.320° Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azlm. Vertical Northlngs Eastlngs Vertical Dogleg Depth Depth SectIon Rate ,-~ 0.00 0.000 0.000 0.00 O.OON O.OOE 0.00 300.00 0.000 0.000 300.00 O.OON O.OOE 0.00 OJX)O 499.91 3.998 25.506 499.75 6.29N 3.00E 6.91 2.000 1640.75 32.519 25.506 1572.00 325.57 N 155.33 E 357.38 2.500 1942.44 35.536 25.506 1822.(X) 477.92 N 228.02 E 524.62 I. 000 2065.33 35.536 25.506 1922.(XJ 542.39 N 258.711 E 595.311 (WOO 3067.40 75.000 34.506 2482.44 1232.41 N 675.47 E 1400.87 4.000 5967.40 75.000 34.506 3233.02 3540.76 N 2262.33 E 4201.45 O.(X)() 6462.94 69.832 54.598 3384.08 3876.07 N 2590.77 E 4662.05 4.000 7274.61 69.832 54.598 3663.93 4317.44N 3211.81 E 5372.(}J 0.000 8147.12 35.000 5L711 4188.00 4722.3IN 3759.02 E 6010.92 4. UOO 8444.98 35.000 51.711 4432.00 4828.18 N 3893.12 E 6173.05 OJ)(]O 800 - , . 000.00 - Q) ~ .c ~ () £:) ~ 2400 - t () > - - - - - - - - -- - - -- - - ~ - -- -- -. - -' - - - - - ---- - - --- - - ~-- - -- ~- -- - .~-_._- -- Begin Dir @ 4.oooo/100ft: 2065.33ft MD, 1922.00ft TVD Current Well Properties _"!OOO.o~ End Dir, Start Sail @ 75.000° : 3067.40ftMD,2482.44ftTVD Well: Horizontal Coordinates: Ref. Global Coordinates: 6000021.66 N, 565989.85 E Ref. Structure: 49.80 N, 354.72 W Ref. Geographical Coordinates: 70° 24' 37.7890" N, 149° 27' 45.5697" W MPS-07 Wps 3200 - ¡15OO-00 RKB Elevation: 72.00ft above Mean Sea Level 72.00ft above Structure True North Feet (US) ~000.00 J5OO.00 [<;()()O_OO North Reference: Units: .S-011M '/105 Dir @ 4.oooo/100ft: 5967.40ft MD, 3233.02ft TVD nd Dir, Start Sail @ 69.832° : 6462.94ftMD,3384.08ftTVD Begin Dir @ 4.0000/100ft: 7274.61ft MD, 3663.93ft TVD f'-'" 1~5OO_00 MPS-07 T1 Top OA 4188.00ft TVD, 4722.31 N,3759.02..!= == 4000 - - - -~-- - -~~ - - -- - -- -- - --- -- -- - --~ - End D~, Start Saiï @ 35.000°: 8147.12ftMD,4188.oóf~- -- g ------ - ----~- - .---- - --- - --- -- -- --- -- --~--- -- ---- -- - -- - - - - ~--- - ---- .. -------- -.. ---_.-:--~ ~oo II --~ - --.---.-- -- -_._-~ .- --- - .- - - -- - .- ---~- -- ~~ -- - - -~-- .- --- - -...- - -.-- -. -------- -- n ..c -- - -~ - ~ - - --- -- -~ - -~- -- ~-- -- -- - - - -~ ~~ - - --~- - -- - ------- 0 .¡;; 0 Scale: 1 inch = 800ft I 800 I 1600 I 2400 I 3200 Vertical Section (Well) I 4000 I 4800 J-"'" 7" Casi19 8444.98f1MD 4432.00ft TVD I I 5600 6400 Section Azimuth: 33.320° (True North) q¡ -æ 0 CJ) Total Depth: 8444.98ftMD,4432.00ftTVD __!II_..__~ ^ ^^ ^"" ^^'" ~ \1 '\I-5U1 Milne Point Uni~ DRIi_LING SEiftv,c:es BPXA AHalllllu_C~ M~~-pad MPS-07 WP05 DrillQuest' Single Well Target Data for MPS-07 WP05 Measurement Units : ft Coordinate Target Point TVD Northings Eastings SSTVD Northlngs Eastings Target Name Type ASPY ASP X Shape MPS-07TI TopOA Entry Point 4188.00 4722.3IN 3759.02 E 4116.00 6004777.00 N 569707.00 E Point Well: Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure: Ref. Geographical Coordinates : RKB Elevation: Current Well Properties MPS-û7 WP05 6000021.66 N, 565989.85 E 49.80 N, 354.72 W 70° 24' 37.78908 N, 149° 27' 45.5697" W North Reference: Units: 72.00ft above Mean Sea Level 72.00ft above Structure True North Feet (US) 800 - 1" Casing 8444.98fl MO 4432.00fl TVO 4800 - 3200 - Total Depth: 8444.98ftMD,4432.00ftTVD 4000 - Begin Dir @ 4.oo00/100ft: 7274.61ft MD, 3663.93ft TVD End Dir, Start Sail @ 69.832° : 6462.94ftMD,3384.08ftTVD Begìn Dir @ 4.0000/1OOft: 5967.40ft MD, 3233.02ft TVD - ã3 ~ en ~ 2400 - :ë 1:: 0 Z Proposal Data for MPS-07 Wp05 Vertical Origin: Horizontal Origin: Measurement Units: North Reference: Well Well ft True North 1600 - Dogleg severity : Degrees per 100 feet (US) Vertical Section Azimuth: 33.320° Vertical Section Description:Well Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azlm. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 0.00 0.000 O.(XJ() O.(}() O.(X)N O.(}()E 0.00 300.00 0.000 O.()(X) 3()(J.()() O.OON o.()() E (J.{J() (>.000 499.91 3.998 25.506 499.75 6.29N 3.00E 6.91 2.()()() 1640.75 32.519 25.506 1572.00 325.57 N 155.33 E 357.38 2.500 1942.44 35.536 25.506 1822.00 477.92 N 228.02 E 524.62 ¡.()()() 2065.33 35.536 25.506 1922.00 542.39 N 258.78 E 595.38 O.()()() 3067.40 75.000 34.506 2482.44 1232.41 N 675.47 E 14()().87 4.(()() 5967.40 75.{)()() 34.506 3233.02 3540.76 N 2262.33 E 4201.45 O.!)(X) 6462.94 69.832 54.598 3384.08 3876.07 N 2590.77 E 4662.05 4.()(X) 7274.61 69.832 54.598 3663.93 4317.44 N 3211.81 E 5372.01 O.(XX) 8147.12 35.{)()() 51.711 4188.00 4722.31 N 3759.02 E 6010.92 4.()(X) 8444.98 35.0(]() 51.711 4432.00 4828.18 N 3893.12 E 6173.05 (J.OOO End Dir, Start Sail @ 75.000°: 3067.40ftMD,2482.44ftTVD a; ãi u en 0 Begin Dir @ 4.oo00/100ft: 2065.33ft MD, 1922.ooft TVD End Dir, Start Sail @ 35.536° : 1942.44ftMD,1822.ooftTVD ir Rate Decrease @ 1.0000/1ooft: 1640.75ftMD,1572.0OftTVD \:--...Dir Rate Increase @ 2.5ooo/100ft: 499.91ftMD,499.75ftTVD BeQin Dir @ 2.0ooo/100ft : 300.ooft MD, 300.00ft TVD I I 800 1600 Eastings (Well) I 2400 I I 3200 4000 Reference is True North tš 0 ex;¡ II ~ u .5: 0 Scale: 1 inch = 800ft DrillQuest 2.00.09.006 Sperrj ...~unD,.lllingSfJ" tees Proposal Data - MPS-07 Wps - MPS-07.Wp05 001= 5.8 Draft Copy 1 ':1 M~) II~rì.~r ~~ ~)~~'Tik~)rÞ:ifÞi1~'T~vs,.r 1 -,e - 2 t1T:.~147~jà':,:',8'1'?~$Q. 35.00 51.7t. 4188.00 . .' ''';.!' I.J.?':..__I:,i~~:~~i~-;,;];:~~~~.~~t'~:iiif~~-~~t'X~i~ì.~t~{I- ..~?~.~~t~~~;[ 21 February, 2002 - 9:39 DrlllQuest Sperry-Sun Drilling Services . Proposal Report for MPS-07 Wps - MPS-07 Wp05 Revised: 21 February, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Dev Working Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -72.00 0.00 O.OON O.OOE 6000021.EiE? 989.85 E 0.00 100.00 0.000 0.000 28.00 100.00 O.OON O.OOE 600oo~¡~6ttN 989.85 E 0.000 0.00 200.00 0.000 0.000 128.00 200.00 O.OON O.OOE 6000021.66 Nfc 89.85 E 0.000 0.00 300.00 0.000 0.000 228.00 300.00 O.OON O.OOE . :c:6O()Op2f:£6_N - - 89.85 E 0.000 0.00 Begin Dir @ 2.000°/1000 : 300.000 MD, 300.00ft TVD - 400.00 2.000 25.506 327.98 399.98 1.58N 565990.59 E 2.000 1.73 499.91 3.998 25.506 427.75 499.75 565992.80 E 2.000 6.91 Dir Rate Increase @ 2.500°/1000 : 499.91 ftMD,499.75ftTVD 500.00 4.000 25.506 427.84 499.84 3.01 E 6000027.98 N 565992.80 E 2.500 6.91 600.00 6.500 25.506 527.41 599.41 6.95E 6000036.28 N 565996.67 E 2.500 15.98 700.00 9.000 25.506 626.49 698.49 L~O 12.75 E 6000048.50 N 566002.37 E 2.500 29.34 800.00 11 .500 25.506 724.88 .~ ~~6.88~_=~- 20.41 E 6000064.63 N 566009.89 E 2.500 46.97 900.00 14.000 25.506 822.41 29.92 E 6000084.63 N 566019.21 E 2.500 68.83 1000.00 16.500 25.506 918.88 41.24 E 6000108.46 N 566030.33 E 2.500 94.89 1100.00 19.000 25.506 1014.11 54.37 E 6000136.09 N 566043.21 E 2.500 125.09 1200.00 21 .500 25.506 1107.93 69.27 E 6000167.46 N 566057.84 E 2.500 159.38 1300.00 24.000 25.506 1200.14 85.92 E 6000202.51 N 566074.18 E 2.500 197.69 1400.00 26.500 25.506 1290.58 1362.58 218.59 N 104.29 E 6000241.16 N 566092.21 E 2.500 239.95 1500.00 29.000 25.506 1379.07 1451.07 260.61 N 124.34 E 6000283.36 N 566111.88 E 2.500 286.07 1600.00 31.500 25.506 1465.44 1537.44 306.08 N 146.03 E 6000329.01 N 566133.17 E 2.500 335.98 1640.75 32.519 25.506 1500.00 1572.00 325.57 N 155.33 E 6000348.59 N 566142.30 E 2.500 357.38 Dir Rate Decrease @ 1.0000/100ft: 1640.75ftMD, 1572.0OOTVD 1700.00 33.112 25.506 1549.79 1621.79 354.55 N 169.16 E 6000377.69 N 566155.87 E 1.000 389.19 .~ 1800.00 34.112 25.506 1633.07 1705.07 404.51 N 193.00 E 6000427.86 N 566179.26 E 1.000 444.03 1900.00 35.112 25.506 1715.37 1787.37 455.78 N 217.45 E 6000479.34 N 566203.27 E 1.000 500.30 1942.44 35.536 25.506 1750.00 1822.00 477.92 N 228.02 E 6000501.58 N 566213.64 E 1.000 524.62 End Dir, Start Sail @ 35.536° : 1942.44ftMD, 1822.0OftTVD Base Permafrost 2000.00 35.536 25.506 1796.84 1868.84 508.12 N 242.43 E 6000531.90 N 566227.78 E 0.000 557.76 2065.33 35.536 25.506 1850.00 1922.00 542.39 N 258.78 E 6000566.31 N 566243.83 E 0.000 595.38 Begin Dir @ 4.000°/1000: 2065.33ft MD, 1922.000 TVD 21 February, 2002 - 9:44 Page2of7 Drll/Quest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for MPS-07 Wps - MPS-07 Wp05 Revised: 21 February, 2002 BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Dev Working Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/1 OOft) 2100.00 36.886 26.048 1877.97 1949.97 560.83 N 6000584.ft~ 252.57 E 4.000 615.68 2200.00 40.790 27.439 1955.85 2027.85 616.80 N 600064t.œN 280.32 E 4.000 677.97 2300.00 44.708 28.625 2029.27 2101.27 676.69 N 6000'la! .22 cN~ 11 .70 E 4.000 745.55 2400.00 48.637 29.658 2097.88 2169.88 740.21 N 0- ~~7~:Of)~}\lo 46.57 E 4.000 818.08 2500.00 52.574 30.572 2161.33 2233.33 807.03 N f?;c 60~32i?rN 566384.76 E 4.000 895.22 ~ 2600.00 56.517 31.395 2219.33 2291.33 566426.08 E 4.000 976.60 2700.00 60.466 32.147 . 2271.58 2343.58 566470.33 E 4.000 1061.81 2800.00 64.418 32.841 2317.84 2389.84 566517.29 E 4.000 1150.43 2900.00 68.374 33.491 2357.87 2429.87 566566.74 E 4.000 1242.05 3000.00 72.331 34.107 2391.49 2463.49 566618.43 E 4.000 1336.20 3067.40 75.000 34.506 2410.44 '~:1~~' 675.47 E 6001259.99 N 566654.41 E 4.000 1400.87 End Dir, Start Sail @ 75.0000 : 3067.4OftMD,2482.44ftTVD 3100.00 75.000 34.506 2418.8g - ~; 24~8. 693.31 E 6001286.09 N 566672.02 E 0.000 1432.35 3200.00 75.000 34.506 2444.76"C_~c 251~36 748.03 E 6001366.17 N 566726.03 E 0.000 1528.92 3300.00 75.000 34.506 2470.64 cC~,2~1:2f64 802.75 E 6001446.25 N 566780.04 E 0.000 1625.49 3400.00 75.000 34.506 2496.52 ~e68.52 857.47 E 6001526.33 N 566834.06 E 0.000 1722.06 3500.00 75.000 34.506 2522.41 2594.41 1576.75 N 912.19 E 6001606.41 N 566888.07 E 0.000 1818.64 3600.00 75.000 34.506 2548.29 2620.29 1656.35 N 966.91 E 6001686.49 N 566942.09 E 0.000 1915.21 3700.00 75.000 34.506 2574.17 2646.17 1735.95 N 1021.63 E 6001766.57 N 566996.10 E 0.000 2011.78 3800.00 75.000 34.506 2600.05 2672.05 1815.54 N 1076.35 E 6001846.64 N 567050.11 E 0.000 2108.35 3900.00 75.000 34.506 2625.93 2697.93 1895.14 N 1131.07 E 6001926.72 N 567104.13 E 0.000 2204.92 4000.00 75.000 34.506 2651.81 2723.81 1974.74 N 1185.79 E 6002006.80 N 567158.14 E 0.000 2301.49 4100.00 75.000 34.506 2677.70 2749.70 2054.34 N 1240.51 E 6002086.88 N 567212.16 E 0.000 2398.07 4200.00 75.000 34.506 2703.58 2775.58 2133.94 N 1295.22 E 6002166.96 N 567266.17 E 0.000 2494.64 4300.00 75.000 34.506 2729.46 2801.46 2213.54 N 1349.94 E 6002247.04 N 567320.18 E 0.000 2591.21 4400.00 75.000 34.506 2755.34 2827.34 2293.14 N 1404.66 E 6002327.12 N 567374.20 E 0.000 2687.78 4500.00 75.000 34.506 2781.22 2853.22 2372.73 N 1459.38 E 6002407.20 N 567428.21 E 0.000 2784.35 4600.00 75.000 34.506 2807.11 2879.11 2452.33 N 1514.10 E 6002487.28 N 567482.23 E 0.000 2880.93 4700.00 75.000 34.506 2832.99 2904.99 2531.93 N 1568.82 E 6002567.35 N 567536.24 E 0.000 2977.50 4800.00 75.000 34.506 2858.87 2930.87 2611.53 N 1623.54 E 6002647.43 N 567590.25 E 0.000 3074.07 4900.00 75.000 34.506 2884.75 2956.75 2691.13 N 1678.26 E 6002727.51 N 567644.27 E 0.000 3170.64 21 February, 2002 - 9:44 Page30f7 DrlllQuest 2.00.09.006 BP EXPLORATION (ALASKA) INC. Milne Point Unit Measured Depth (ft) Incl. 5000.00 75.000 5100.00 75.000 5200.00 75.000 5300.00 75.000 5400.00 75.000 5500.00 75.000 5600.00 75.000 5700.00 75.000 5800.00 75.000 5900.00 75.000 5967.40 75.000 6000.00 74.600 6100.00 73.422 6200.00 72.319 6300.00 71.300 6400.00 70.369 6462.94 69.832 6500.00 69.832 6600.00 69.832 6700.00 69.832 6800.00 69.832 6900.00 69.832 7000.00 69.832 7100.00 69.832 7155.91 69.832 7200.00 69.832 7274.61 69.832 7300.00 68.817 7400.00 64.823 7500.00 60.828 21 February, 2002 - 9:44 Azim. 34.506 34.506 34.506 34.506 34.506 34.506 34.506 34.506 34.506 34.506 34.506 35.792 39.769 43.793 47.864 51.983 54.598 54.598 54.598 54.598 54.598 54.598 54.598 54.598 54.598 54.598 54.598 54.543 54.319 54.079 Sub-Sea Depth (ft) 2910.63 2936.52 2962.40 2988.28 3014.16 3040.04 3065.93 3091.81 3117.69 3143.57 3161.02 Vertical Depth (ft) 2982.63 3008.52 3034.40 3060.28 3086.16 3112.04 3137.93 3163.81 3189.69 3215.57 _&2~~3.Q~2 - Sperry-Sun Drilling Services Proposal Report for MPS-07 Wps - MPS-07 Wp05 Revised: 21 February, 2002 Local Coordinates Northings Eastings (ft) (ft) 2770.73 N 2850.33 N 2929.92 N 3009.52 N 3089.12 N - - - 3169.56-i~=; 324~:~~6 c~:;-!~ 3566.49 N 3197.12 :C=~326~rJ2 - -' 3642.45 N 3226.58~~!j8¡M 3713.70 N 3257.81~:1529.81 3779.89 N 3290.65 3312.08 3324.86 3359.33 3393.81 3428.29 3462.77 3497.25 3531.72 3551 .00 3566.20 3591.93 3600.89 3640.25 3685.91 3362.65 3384.08 3396.86 3431.33 3465.81 3500.29 3534.77 3569.25 3603.72 3623.00 3638.20 3663.93 3672.89 3712.25 3757.91 3840.69 N 3876.07 N 3896.22 N 3950.60 N 4004.98 N 4059.36 N 4113.73 N 4168.11 N 4222.49 N 4252.89 N 4276.87 N 4317.44 N 4331.21 N 4384.67 N 4436.70 N 1732.98 E 1787.70 E 1842.42 E 1897.14 E 1 - 2 2170.73 E 2225.45 E 2262.33 E 2280.44 E 2339.32 E 2402.96 E 2471.08 E 2543.33 E 2590.77 E 2619.13 E 2695.64 E 2772.15 E 2848.67 E 2925.18 E 3001 .69 E 3078.21 E 3120.98 E 3154.72 E 3211.81 E 3231.16 E 3305.92 E 3378.06 E Page 4 of 7 Global Coordinates Northings Eastings (ft) (ft) 6002807 .5~~ 6002t38~m~~ 6Q02961.75 N-- -~-60030ltl~~~~ N;c - 600M27,.J1N "è~~3207.98~N 6003288.06 N 6003368.14 N 6003448.22 N 6003528.30 N 6003582.27 N 6003608.16 N 6003684.64 N 6003756.45 N 6003823.24 N 6003884.68 N 6003920.47 N 6003940.87 N 6003995.92 N 6004050.97 N 6004106.03 N 6004161.08 N 6004216.13 N 6004271.18 N 6004301 .96 N 6004326.24 N 6004367.31 N 6004381.25 N 6004435.37 N 6004488.03 N 698.28 E 752.29 E 06.31 E 60.32 E 567914.34 E 567968.35 E 568022.36 E 568076.38 E 568130.39 E 568184.41 E 568220.81 E 568238.69 E 568296.89 E 568359.91 E 568427.44 E 568499.15 E 568546.27 E 568574.45 E 568650.48 E 568726.51 E 568802.54 E 568878.57 E 568954.60 E 569030.63 E 569073.13 E 569106.66 E 569163.38 E 569182.62 E 569256.90 E 569328.58 E . BPXA MPS-Pad Dev Working Dogleg Rate (o/100ft) Vertical Section Comment 0.000 3267.21 0.000 3363.79 0.000 3460.36 0.000 3556.93 0.000 3653.50 0.000 3750.07 0.000 3846.64 0.000 3943.22 0.000 4039.79 0.000 4136.36 0.000 4201.45 Begin Dir @ 4.000°/1000 : 5967.4011 MD, 3233.02ft TVD 4.000 4232.89 4.000 4328.71 4.000 4423.21 4.000 4515.94 4.000 4606.43 4.000 4662.05 End Dir, Start Sail @ 69.832° : 6462.94ftMD,3384.08ftTVD 0.000 4694.47 0.000 4781.94 0.000 4869.41 .~ 0.000 4956.87 0.000 5044.34 0.000 5131.81 0.000 5219.28 0.000 5268.18 Top Ugnu 0.000 5306.75 0.000 5372.01 Begin Dir @ 4.0000/10Ott : 7274.61 ft MD, 3663.93ft TVD 4.000 5394.15 4.000 5479.89 4.000 5562.99 DrillQuest 2.00.09.006 BP EXPLORATION (ALASKA) INC. Milne Point Unit Measured Depth (ft) Inc I. 7600.00 56.835 7700.00 52.841 7773.34 49.913 7800.00 48.849 7900.00 44.857 7980.02 41.664 8000.00 40.867 8015.77 40.238 8055.91 38.637 8078.81 37.723 8100.00 36.878 8131.18 35.635 8147.12 35.000 8169.09 35.000 8193.51 35.000 8200.00 35.000 8256.99 35.000 8263.09 35.000 8300.00 35.000 8400.00 35.000 8444.98 35.000 Azim. 53.820 53.536 53.308 53.220 52.863 52.540 52.453 52.382 52.193 52.080 51.970 51.801 51.711 51.711 51.711 51.711 51.711 51.711 51.711 51.711 51.711 Sub-Sea Depth (ft) 3737.65 3795.23 3841.00 3858.36 3926.73 3985.00 4000.02 4012.00 4043.00 4061.00 Vertical Depth (ft) 3809.65 3867.23 3913.00 3930.36 3998.73 4057.00 4072.02 4084.00 4115.00 4133.00 Sperry-Sun Drilling Services Proposal Report for MPS-D7 Wps - MPS-07 Wp05 Revised: 21 February, 2002 Local Coordinates Northings Eastings (ft) (ft) 4487.04 N 4535.45 N 4569.59 N 4581.69 N 4625.54 N 4077.85 At49.8.ft-,~?- 41 03.0~c¿- ~41~~~ß~ 4116.00 .~. 41 gf[~ C'~C 4134.00 ~'~!D6.00 4154.00 4226.00 4159.32 4206.00 4211.00 4241.24 4323.15 4360.00 4231.32 4278.00 4283.00 4313.24 4395.15 4432.00 4730.12 N 4738.80 N 4741.11 N 4761.36 N 4763.53 N 4776.65 N 4812.19 N 4828.18 N 3447.23 E 3513.09 E 3559.10 E 3575.31 E 3, 3715.98 E 3727.15 E 3737.28 E 3751.79 E 3759.02 E 3768.91 E 3779.90 E 3782.83 E 3808.48 E 3811.23 E 3827.85 E 3872.87 E 3893.12 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 33.320° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8444.98ft., The Bottom Hole Displacement is 6202.23ft., in the Direction of 38.880° (True). 21 February, 2002 - 9:44 Page50f7 Global Coordinates Northings Eastings (ft) (ft) 6004538.9~ 6OO4581m~ 6po~.52 ~:~ - ~- . 6O%63~lqE> J~:= cf 60~79~:f~N ~- "<;:_<4712.74 N 6004720.85 N 6004727.18 N 6004742.95 N 6004751.73 N 6004759.72 N 6004771.23 N 6004777.00 N 6004784.90 N 6004793.67 N 6004796.00 N 6004816.48 N 6004818.68 N 6004831.94 N 6004867.88 N 6004884.04 N 569625.77 E 569636.16 E 569644.23 E 569664.26 E 569675.36 E 569685.41 E 569699.82 E 569707.00 E 569716.82 E 569727.74 E 569730.64 E 569756.12 E 569758.84 E 569775.35 E 569820.05 E 569840.16 E . BPXA MPS-Pad Dev Working Dogleg Rate CO/100ft) Vertical Section Comment 4.000 5643.05 4.000 5719.68 4.000 5773.48 Top Ugnu M 4.000 5792.51 4.000 5861.17 4.000 5912.90 SBF2-NA 4.000 5925.34 4.000 5935.03 SBF1-NB 4.000 5959.14 SBE4-NC 4.000 5972.54 SBE2-NE 4.000 5984.70 4.000 6002.18 4.000 6010.92 SBE1-NF End Dir, Start Sail @ 35.000° : 8147.12ftMD,4188.0OftTVD Target - MPS-07 T1 Top OA TSBD-OA TSBC 0.000 6022.88 0.000 6036.17 0.000 6039.71 0.000 6070.72 TSBB-OB 0.000 6074.04 SBA5 0.000 6094.13 0.000 6148.56 0.000 6173.05 Total Depth: 8444.98ftMD,4432.0OftTVD 7" Casing Dr/I/Quest 2.00.09.006 DrlllQuest 2.00.09.006 Page 60f7 21 February, 2002 - 9:44 1750.00 0.000 0.506 1942.44 1822.00 1750.00 477.92 N 228.02 E Base Permafrost ~-. 3551.00 0.000 0.506 7155.91 3623.00 3551.00 4252.89 N 3120.98 E Top Ugnu 3841.00 0.000 0.506 7773.34 3913.00 3841 .00 4569.59 N 3559.10 E Top Ugnu M 3985.00 0.000 0.506 7980.02 4057.00 3985.00 4658.77 N 3677.23 E SBF2-NA 4012.00 0.000 0.506 8015.77 4084.00 4012.00 4673.04 N 3695.81 E SBF1-NB 4043.00 0.000 0.506 8055.91 4115.00 4043.00 4688.64 N 3715.98 E SBE4-NC 4061.00 0.000 0.506 8078.81 4133.00 4061.00 4697.33 N 3727.15 E SBE2-NE 4103.00 0.000 0.506 8131.18 4175.00 4103.00 4716.61 N 3751.79 E SBE1-NF 4134.00 0.000 0.506 8169.09 4206.00 4134.00 4730.12 N 3768.91 E TSBD-OA 4154.00 0.000 0.506 8193.51 4226.00 4154.00 4738.80 N 3779.90 E TSBC Formation Name Penetration Point Sub-Sea Depth (ft) Profile Measured Vertical Depth Depth (ft) (ft) Eastings (ft) Northings (ft) Total Depth: 8444.98ftMD,4432.0OOTVD --- --- - 4828.18 N~·c\ ØB93.f2 E ~ - - 1232.41 N 675.47 E ~.f:I Dit1'itart Sail @ 75.000° : 3067.4OOMD,2482.44ftTVD 3540.76 N 2262.33 5Y;E·á~J1 ôi&.4.0000/1OOO: 5967.400 MD, 3233.02ft TVD 3876.07 N 259Qi77j¡c . ;?Eng,f)ir, Start Sail @ 69.832° : 6462.94ftMD,3384.08ftTVD -- - - 4317.44 N _~_-> 3~1JI:81Et ~~gil1 Dir @ 4.oo00/1ooft: 7274.61ft MD, 3663.93ft TVD 4722.31J"',f:<"~~~~t'@~~02 Et~~:~ End Dir, Start Sail @ 35.000° : 8147.12ftMD,4188.0OOTVD -- = - -- Begin Dir @ 2.000°[1 000 :~JJQ!t~,,,ªs.Þ:ooft lNO Dir Rate Increa~-:@~~cO-50~4I 00ff~9g:~ftMD,499.75ftTVD Dir Rate Decr~e @ 1.00~'tl;tQ9J1J 164~.15ftMD, 1572.0OOTVD End Dir, Start~1 @ 35.W6~-~~42.44ftMD,1822.00ftTVD gifL-Rir @ 4;QQQ~/100Jf: 2065.33ft MD, 1922.000 TVD - -- - -- - ~- --- - - -" ---" .. --- - - ---- - - --- . - --- --- - "-- --- - - - . O.OOE 3.00E 155.33 E 228.02 E 258.78 E O.OON 6.29N 325.57 N 477.92 N 542.39 N Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. 4432.00 2482.44 3233.02 3384.08 3663.93 4188.00 300.00 499.75 1572.00 1822.00 1922.00 Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) c _ - BPXA MPS-Pad Dev Working . Sperry-Sun Drilling Services Proposal Report for MPS-07 Wps - MPS-07 Wp05 Revised: 21 February, 2002 Formation Tops 8444.98 3067.40 5967.40 6462.94 7274.61 8147.12 300.00 499.91 1640.75 1942.44 2065.33 Measured Depth (ft) Comments BP EXPLORATION (ALASKA) INC. Milne Point Unit BP EXPLORATION (ALASKA) INC. Milne Point Unit Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Formation Tops (Continued) 4206.00 4211.00 0.000 0.000 Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> Targets associated with this wellpath Target Name MPS-07 T1 Top OA 21 February, 2002 - 9:44 0.506 0.506 Sperry-Sun Drilling Services Proposal Report for MPS-07 Wps - MPS-07 Wp05 Revised: 21 February, 2002 Profile Penetration Point Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 8256.99 8263.09 4278.00 4283.00 To Measured Vertical Depth D (ft) 8444.98 Northings (ft) 4206.00 4211.00 -- -- - .- Casing Eastings (ft) Formati9n Name 4761. 4763 Target Entry Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Mean Sea Level/Global Coordinates: Geographical Coordinates: 4188.00 4116.00 4722.31 N 3759.02 E 6004777.00 N 569707.00 E 70025' 24.2271" N 1490 25' 55.3097" W Page 70f7 . BPXA MPS-Pad Dev Working - Target Target Shape Type Point .-"" DrlllQuest 2.00.09.006 ( ( Sperry-Sun Drilling Services Proposal Report for MPS-D7 Wps - MPS-D7 WpOS Revised: 21 February, 2002 . BP EXPLORATION (ALASKA) INC. Milne Point Unit BPXA MPS-Pad Dev Working Measured Depth (ft) Vertical Depth (ft) Vertical Dogleg Build Turn Toolface Section Rate Rate Rate Azimuth (ft) CO/100ft) CO/100ft) CO/100ft) lnel. Azim. Northings (ft) Eastings (ft) 0.00 0.000 0.000 100.00 0.000 0.000 200.00 0.000 0.000 300.00 0.000 0.000 400.00 2.000 25.506 0.00 100.00 200.00 300.00 399.98 O.OON O.OON O.OON O.OON 1.58 N O.OOE 0.00 E O.OOE O.OOE 0.75 E 0.00 0.00 0.00 0.00 1.73 2.000 2.000 0.000 25.506 499.91 3.998 25.506 500.00 4.000 25.506 600.00 6.500 25.506 700.00 9.000 25.506 800.00 11.500 25.506 499.75 499.84 599.41 698.49 796.88 6.29N 6.30N 14.56 N 26.73 N 42.79 N 3.00 E 3.01 E 6.95 E 12.75 E 20.41 E 6.91 6.91 15.98 29.34 46.97 2.000 2.500 2.500 2.500 2.500 2.000 2.500 2.500 2.500 2.500 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 900.00 14.000 25.506 894.41 1000.00 16.500 25.506 990.88 1100.00 19.000 25.506 1086.11 1200.00 21.500 25.506 1179.93 1300.00 24.000 25.506 1272.14 62.70 N 86.44 N 113.96 N 145.19 N 180.09 N 29.92 E 41 .24 E 54.37 E 69.27 E 85.92 E 68.83 94.89 125.09 159.38 197.69 2.500 2.500 2.500 2.500 2.500 2.500 2.500 2.500 2.500 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 1400.00 26.500 25.506 1362.58 1500.00 29.000 25.506 1451.07 1600.00 31.500 25.506 1537.44 1640.75 32.519 25.506 1572.00 1700.00 33.112 25.506 1621.79 218.59 N 260.61 N 306.08 N 325.57 N 354.55 N 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 1800.00 34.112 25.506 1900.00 35.112 25.506 1942.44 35.536 25.506 2000.00 35.536 25.506 2065.33 35.536 25.506 1705.07 1787.37 1822.00 1868.84 1922.0()~":J'" , . " I,' : ¡:!~: 'I" '" ~:~:;¡::f'~~:~~>;';/:~~: ~ . '~8:625 ":I¡:¡"21q'~¡27 676.69 N 29;E>58¡(¡':!::'2169.88 740.21 N 301áz2',;"lo'.' 2233.33 807.03 N :':¡:j:!:::;::~::!::!'ï:¡,,"'i 404.51 N 1.000 1.000 1.000 1.000 1.000 1.000 0.000 0.000 0.000 0.000 0.000 0.000 E 242.43 E 258.78 E 2100.00 36.886 2200.00 40.790 2300.00 44.708 2400.00 48.637 2500.00 52.574 267.69 E 295.93 E 327.84 E 363.28 E 402.06 E 615.68 677.97 745.55 818.08 895.22 4.000 4.000 4.000 4.000 4.000 3.892 3.904 3.918 3.929 3.937 1.564 1.390 1.186 1.033 0.915 13.572 13.135 12.051 11. 180 10.471 2600.00 56.517 31.395 2291.33 2700.00 60.466 32.147 2343.58 2800.00 64.418 32.841 2389.84 2900.00 68.374 33.491 2429.87 3000.00 72.331 34.107 2463.49 876.84 N 949.30 N 1024.06 N 1100.74 N 1178.98 N 444.00 E 976.60 488.89 E 1061.81 536.51 E 1150.43 586.64 E 1242.05 639.02 E 1336.20 4.000 4.000 4.000 4.000 4.000 3.943 3.948 3.952 3.955 3.958 0.823 0.751 0.695 0.650 0.615 9.890 9.412 9.019 8.698 8.437 3067.40 75.000 34.506 2482.44 3100.00 75.000 34.506 2490.88 3200.00 75.000 34.506 2516.76 3300.00 75.000 34.506 2542.64 3400.00 75.000 34.506 2568.52 1232.41 N 1258.36 N 1337.95 N 1417.55 N 1497.15 N 675.47 E 1400.87 , 693.31 E 1432.35 748.03 E 1528.92 802.75 E 1625.49 857.47 E 1722.06 4.000 3.959 0.593 8.230 3500.00 75.000 34.506 2594.41 3600.00 75.000 34.506 2620.29 3700.00 75.000 34.506 2646.17 3800.00 75.000 34.506 2672.05 3900.00 75.000 34.506 2697.93 1576.75 N 1656.35 N 1735.95 N 1815.54 N 1895.14 N 912.19 E 1818.64 966.91 E 1915.21 1021.63 E 2011.78 1076.35 E 2108.35 1131.07 E 2204.92 21 February, 2002 - 9:39 DrillQuest 2.00.09.006 Page 10f3 ( ( . Sperry-Sun Drilling Services Proposal Report for MPS-D7 Wps - MPS-07 WpOS Revised: 21 February, 2002 BP EXPLORATION (AlASKA) INC. BPXA Milne Point Unit MPS-Pad Dev Working Measured Vertical Vertical Dogleg Build Turn Toolface Depth Incl. Azim. Depth Northings Eastings Section Rate Rate Rate Azimuth (ft) (ft) (ft) (ft) (ft) CO /1 OOft) (°/1000) (0/10Oft) 4000.00 75.000 34.506 2723.81 1974.74 N 1185.79 E 2301.49 4100.00 75.000 34.506 2749.70 2054.34 N 1240.51 E 2398.07 4200.00 75.000 34.506 2775.58 2133.94 N 1295.22 E 2494.64 4300.00 75.000 34.506 2801.46 2213.54 N 1349.94 E 2591.21 4400.00 75.000 34.506 2827.34 2293.14 N 1404.66 E 2687.78 4500.00 75.000 34.506 2853.22 2372.73 N 1459.38 E 2784.35 4600.00 75.000 34.506 2879.11 2452.33 N 1514.10 E 2880.93 4700.00 75.000 34.506 2904.99 2531.93 N 1568.82 E 2977.50 4800.00 75.000 34.506 2930.87 2611 .53 N 1623.54 E 3074.07 4900.00 75.000 34.506 2956.75 2691.13 N 1678.26 E 3170.64 5000.00 75.000 34.506 2982.63 2770.73 N 1732.98 E 3267.21 5100.00 75.000 34.506 3008.52 2850.33 N 1787.70 E 3363.79 5200.00 75.000 34.506 3034.40 2929.92 N 1842.42 E 3460.36 5300.00 75.000 34.506 3060.28 3009.52 N 1897.14 E 3556.93 5400.00 75.000 34.506 3086.16 3089.12 N 1951.86 E 3653.50 5500.00 75.000 34.506 3112.04 3168.72 N 5600.00 75.000 34.506 3137.93 3248.32 N 5700.00 75.000 34.506 3163.81 3327.92 N 5800.00 75.000 34.506 3189.69 3407.52 N 5900.00 75.000 34.506 3215.57 3487.11 N 5967.40 75.000 34.506 6000.00 74.600 35.792 4232.89 4.000 -1.226 3.946 108.015 6100.00 73.422 39.769 4328.71 4.000 -1.179 3.976 107 .67S 6200.00 72.319 43.793 4423.21 4.000 -1.102 4.024 106.582 6300.00 71.300 47.864 4515.94 4.000 -1 .020 4.071 105.396 6400.00 70.369 4606.43 4.000 -0.931 4.119 104.125 6462.94 69.832 4662.05 4.000 -0.854 4.156 102.772 6500.00 69.832 4694.47 6600.00 69.832 4781.94 6700.00 69.832 54"~ 4869.41 6800.00 69.832 54.598 3500.29 4059.36 N 2848.67 E 4956.87 6900.00 69.832 54.598 3534.77 4113.73 N 2925.18 E 5044.34 7000.00 69.832 54.598 3569.25 4168.11 N 3001 .69 E 5131.81 7100.00 69.832 54.598 3603.72 4222.49 N 3078.21 E 5219.28 7200.00 69.832 54.598 3638.20 4276.87 N 3154.72 E 5306.75 7274.61 69.832 54.598 3663.93 4317.44 N 3211.81 E 5372.01 7300.00 68.817 54.543 3672.89 4331.21 N 3231.16 E 5394.15 4.000 -3.995 -0.217 -177.105 7400.00 64.823 54.319 3712.25 4384.67 N 3305.92 E 5479.89 4.000 -3.995 -0.225 -177.086 7500.00 60.828 54.079 3757.91 4436.70 N 3378.06 E 5562.99 4.000 -3.994 -0.240 -176.99S 7600.00 56.835 53.820 3809.65 4487.04 N 3447.23 E 5643.05 4.000 -3.994 -0.259 -176.88S 7700.00 52.841 53.536 3867.23 4535.45 N 3513.09 E 5719.68 4.000 -3.993 -0.284 -176.754 7800.00 48.849 53.220 3930.36 4581.69 N 3575.31 E 5792.51 4.000 -3.993 -0.316 -176.590 7900.00 44.857 52.863 3998.73 4625.54 N 3633.61 E 5861.17 4.000 -3.992 -0.357 -176.391 8000.00 40.867 52.453 4072.02 4666.79 N 3687.68 E 5925.34 4.000 -3.990 -0.411 -176.147 8100.00 36.878 51 .970 4149.85 4705.23 N 3737.28 E 5984.70 4.000 -3.989 -0.482 -175.845 21 February, 2002 - 9:39 Page2of3 Or¡IIQuest 2.00.09.006 ( Sperry-Sun Drilling Services Proposal Report for MPS-07 Wps - MPS-07 Wp05 Revised: 21 February, 2002 . BP EXPLORATION (ALASKA) INC. BPXA Milne Point Unit MPS-Pad Dev Working Measured Vertical Vertical Dogleg Build Turn Toolface Depth Incl. Azim. Depth Northings Eastings Section Rate Rate Rate Azimuth (ft) (ft) (ft) (ft) (ft) CO /1 OOft) (0/10Oft) (0/10Oft) 8147.12 35.000 51.711 4188.00 4722.31 N 3759.02 E 6010.92 4.000 -3.987 -0.551 -175.470 8200.00 35.000 51.711 4231.32 4741.11 N 3782.83 E 6039.71 8300.00 35.000 51.711 4313.24 4776.65 N 3827.85 E 6094.13 8400.00 35.000 51.711 4395.15 4812.19N 3872.87 E 6148.56 8444.98 35.000 51.711 4432.00 4828.18 N 3893.12 E 6173.05 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 33.320° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8444.98ft., The Bottom Hole Displacement is 6202.23ft., in the Direction of 38.880° (True). 21 February, 2002 - 9:39 Page30f3 DrillQuest 2.00.09.006 '120,% -:> ~ Ú' ?.r '4 ~ C""ltd Ry: P..eh ¡¡",hzm.,n 1f~elling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [15fÞ'¿¡1k'd: Ú',& Re\ìcwed: ------------ J SECTION !lET Aß.S 1\1> +Ni-S +EI.V; IJle¡< TFace WUJ. D'TAILS COMPANY DETAilS ß4.t4.98 P]anne.!: MPS-07 WP-05 VI Nmne +N/-S Easting longitude Slot BP Amoco SURVEY PR(XòRAM D<pth To SmwylPiiln ANTI-COLLISION SETIINGS Latinlde +Ð-W Norttûng Interpolation Method:MD Interval: 50.00 Depth Range From: 72.00 To: 8444.98 Maximum Range: 1037.30 Reference: Plan: MPS-07 \VP-05 Ca1culan.."Jn Method: Minimum Curvature: En'" System: ISCWSA Sean Metllùd: Trav Cylinder No,tll Enor Surtace: Elliptical + Casing Warning Method: Ru1es na.~ed Plan MPS-07 565989.85 70'U.'7.789N 1~9'2n5.570W N/A .J6.82 - 35~. 78 600002 1.(>6 Colour ToMD 250 500 750 1000 1250 1500 1750 :!OOO ~OOO 4000 5000 6000 7000 8000 9000 -20.0 -182 -175 -125 -100 -75 -50 -25 -0 270 -15.0 -25 -20.0 -50 '" i. è.!' , $'~ ' -7f:~ ~'", 01 $00;,' -~. ;-- ,$:-fJ -... I, £3 ~:$ ~ ¡f t-Ik~.f ~O~. §Si ""~ " ... §i" ~~ ¡:.; 01' . ~:#:flo~ ~~~ ~~JbI:," . ~~~ '" $' q:.~~- ~~~~~ q:.~~ fJ~~~~~ ~ ~~.... ~>- -~;,;~ q:.~r ~ -..:' ~ -17f -182 ~ ".-.. -1~ J''O/ ~~ -1~ 'J>'O~ $~l~' i1~~~-, 0$- . ~b' " .s'\.o ~ ~\!.'=' F:.r' ~ b \.."(\;1>' \,'5.1)'&) -.# - ,~S,IJ (,Y\9.\\ ~ />,§' ~v 0<:"\ \ ~ "l\# \'\~~ ~\\ Plan MPS-09 (Plan MPS-(9) ...- ~""""50 Þ Þt,¡" 4/þ í'q" It ,5'-1.4- /Þ.5'ý) (Þ/iit} <'It ~ ("44 JI- 'Þ$-O,¡ w"/"ð': ~ -°<; Travel1ing Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [75ft/in] IDe Azi OJXI 0.00 O.Œ 0.00 4.00 25.51 32.52 25.51 35.54 25.5t 35.54 25.51 15.00 :4.51 15.00 34.51 69.Iß 54.60 69.!!.l 54.60 35.00 51.71 35.00 51.71 From Colour 0 250 500 750 1000 1250 1500 1750 2000 3000 4000 Tool MWD>n'R+MS ToMD 250 500 750 1000 1250 1500 1750 2000 ~OOO 4000 5000 6000 7000 !WOO 9000 nJX) JIX1IX) 499.75 1571.99 1821.98 1921.98 2482.40 3132.97 3J114.Ut .1663.91 4188.00 443\.99 (1.(10 O.IX! 6.:10 325.59 477.94 542.41 1232.42 :1540.67 3M75.% 4317.:11 4722.18 4828.04 WII)J'ATI1 D!'1'^!LS PL1n MPS-07 Rig' Ref. );¡Iunr S~Pad l"k\ 72.lK¡O Origin Orifu\ St>I1uUl +N/.S ,.ll.W hurnT") 0.10 0,00 0.(10 V.Sectìllll Angl< 3M.MM LEGEND - Mi'') I~ I !\frIO; I~I M."" krlt. .... ~tr'J :!1,PL1fI ~n" 'p M,"'I k.....L - ran MP'" 111,PIiart ~p" IIIJ Pt.l,,". RD~ - PtDn f\.{PI\.cJ? ,rtUJ MP' !I~I. M.I,.r Ih... .-.- r~IIp.Ir""'O"lr'la..Pvfr",UII r.tl,.rlll.'!" .... hill p..lr~ lLllrbn Mln, ILl! M.J'-.I Rulo. -- ""...n MP'" Il\ d"laJ1 ~u." 114;.) Mol'" N..L PA..n MJ'S 11'1 ¡"Þ.dl M".'" U"L Mo.", k..." t'un MI" II' ,rL.u¡ Mt" II L 1I.t.,þ.r W,,,,,, Ptu1 ~.g.'''.O~ ,Pilip r-tP\": (N.. Mo"'1 Jc.'''\ - Pt." ~U', 10 rP"d1 ~r', 1", ~tr.J." lb." h" MP~.II .11.n r.u'~ '1!!1. ~!J~'r RÞ~ ~ rbn MIJ".I~ II-'lan ~n",I!1 "'1.1"1 R.J.~" - I'thl p.o'') 1'11'''1 I\{['') 101. P.1.J,'rll¡¡,8r. - I'"" Mr'~ 1 I ,rL.1 Mr~ I h. ~\;,,'r R~l - 1'&111 Mi" I" 11'1.&11 PAP' lIe,- Mol'" IlI..L -- 1-'t,,11 MY' 7 (IJk1I1 Mi" Ihl. ,"".."1(,,,,, - p~" Þ..IP~ I~ ,Plaq MI~ III) "'1..,.r I(r"L --- Ptln MI-!;; 1~(Pbrl MP'i.17, ~b..'rlf:l"'L. ....... PtJn~" .!O,PI.lr¡ ~ß'".!ln ~IJ"'I R¡:,.L - rL,,, MP~.~~ ,PIa'i MJu)-,:J) ~"'''-' R1'ooL ...... ('&roLl Pog'.., 211PkLI:I ,,"D" ~li f\.&.,-, R~II ~ 1'.,1 ~~ In ..... MI"' 1t"1 WI' It'> ...-.... Plan: MPS.1I7 WP-1I5 (l'un MPS-071'k.n MPS-I11) 1J",,:(Y'J21/~ [)a",:- ' [)at<: --- VS.., Target II.(J() 0.110 3.00 155.37 128.01 158.83 675.58 2262.59 2591.05 3212.(JI} 375<).30 3893.40 0.(1) 0.110 IJ.OO ILOO 2,00 2BI 2.50 0.00 1.00 0.00 0.00 0.00 4.00 13.57 0.00 0.00 4.m 101U}2 O.IKI lI.m 4.00 182.90 0.00 0.00 o.m 0.00 6.7') 350.97 515.21 584.71 1383.44 4176.47 4MlM 5..77.()5 603U2 620:UO ~ . Sperry-SUD Anticollision Report (' Company: BP Amoco F1eld: Milne Point Reference Site: M Pt S Pad Reference WeD: Plan MPS..Q7 Reference WeDpath: Plan MP8-07 GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 72.00 to 8444.98 ft Maximum Radius: 1037.30 ft Date: 0212112002 Time: 09: 19:26 Page: 1 Co-ordinate(NE) Reference: Vertieal(TVÐ)Referencè: Well: Plan MP8-07, True North S-Pad Dev 72.0 Reference: Error Model: Scan Method: Error Surface: Db: Oracte Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cytinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 0210812002 Validated: No Planned From To Survey ft 1t 72.00 8444.98 Version: Toolcode 7 Tool Name Planned: MPS-07 WP..Q5 V1 MWD+IFR+MS MWD+ IFR+ Multi Station -Used in Preference Casing Points <------.,.-------------~ Offset Wellpath --------~---~--.,----> Reference Offset Ctr-Ctr . No-Go AlloWable Site Well Wellpath MD MD DistàI1ce Area Deviation Warning ft ft ft ft ft . . M Pt S Pad MPS-15 MPS-15 V7 397.42 400.00 118.43 5.86 112;58 Pass: Major Risk M Pt SPad MPS-21 Plan MPS.,21 V11 299.98 300.00 210.88 4.27 206.62 Pass: Major Risk M Pt SPad Plan MPS-01 Plan MPS-01 VO Plan: M 857.72 850.00 79.83 14.94 64.93 Pass: Major Risk M Pt S Pad Plan MPS-02 Plan MPS-02 V2 Plan: M 704.31 700.00 64.31 12.55 51.81 Pass: Major Risk M Pt S Pad Plan MPS-03 Plan MPS-03 V3 Plan: M 680.27 675.00 59.80 10.79 49.06 Pass: Major Risk M Pt S Pad Plan MPS-04 Plan MPS-D4 V1 Plan: M 526.63 525.00 44.20 9.33 34;91 Pass: Major Risk M Pt S Pad Plan MPS-05 Plan MPS-05 VO Plan:. M 675.67 675.00 23.50 12.59 10.92 Pass: Major Risk M Pt S Pad Plan MPS-06 Plan MPS-06 VO Plan: M 424.96 425~00 15.94 8.29 7.66 Pass: Major Risk M Pt S Pad Plan MPS-08 Plan MPS-l1 VO Plan: M 474.34 475.00 16.91 9.18 7.74 Pass:. Major Risk M Pt S Pad Plan MPS-09 Plan MPS-09 V3 Plan: M 399.13 400.00 29.57 5.58 24.04 Pass: Major Risk M PtS Pad Plan MPS-10 Plan MPS-13 VO Plan: M 423.72 425.00 46.27 8.26 38.01 Pass: Major Risk M Pt S Pad Plan MPS-11 Plan MPS-08 VO Plan: M 373.98 375.00 60.49 6.92 53.58 Pass: Major Risk M PtS Pad Plan MPS~ 12 Plan MPS-12 VO Plan: M 373.74 375;00 75.62 7.32 68.30 Pass: Major Risk M Pt S Pad Plan MPS-13 Plan MPS-10 VO Plan: M 373.49 375.00 91.29 7.32 83.98 Pass: Major Risk M Pt S Pad Plan MPS-14 Plan MPS-14 VOPlan: M 373.26 375.00 105.62 7.32 98;31 Pass: Major Risk M Pt S Pad Plan MPS-16 Plan MPS-18 VO Plan: M 421.39 425.00 135.43 8.23 127.20 Pass: Major Risk M Pt S Pad Plan MPS-17 Plan MPS-16 VO Plan: M 372.54 375.00 150.61 7.31 143.30 Pass: Major Risk M Pt S Pad Plan MPS-18 Plan MPS-19 VO Plan: M 348.21 350.00 165.32 6.54 158.78 Pass: Major Risk M Pt S Pad Plan MPS-19 Plan MPS-17 VO Plan: M 372.08 375~00 180.64 7.29 173.36 Pass: Major Risk M Pt S Pad Plan MPS-20 Plan MPS-20 VO Plan: M 371.84 375.00 195.60 7.30 188.31 Pass: Major Risk M Pt S Pad Plan MPS-22 Plan MPS-24 VO Plan: M 347.59 350.00 225.26 6.54 218.73 Pass: MajorRisk M Pt S Pad Plan MPS-23 Plan MPS-22 VO Plan: M 371.15 375.00 240.59 7.29 233.30 Pass:. Méljor Risk Site: M Pt S Pad Well: MPS-15 aole Assigned: Major Risk Wellpath: MPS-15 V7 Inter-Site Error: 0.00 ft Reference Offset SeOû.,Major A~ Ctr.,Ctr .' No.,Go Allowable MD TVD MD TVD Ref Offset 1'FO+AZI.TFO~HS.Câsblg Distance... Area Deviatiôn Warning 1t ft 1t it ft ft deg deg in ft ft it 75.00 75.00 75.00 75.00 0.00 0.04 255.59 255.59 7.000 118.91 0.87 118.04 Pass 100.00 100.00 100.00 100.00 0.02 0.06 255.60 255.60 7.000 118.87 1.20 117.67 Pass 125.00 125.00 125.00 125.00 0.04 0.07 255.62 255.62 7.000 118.80 1.56 117.24 Pass 150;00 150.00 150.00 150.00 0.07 0.07 255.65 255.65 7.000 118.71 1.92 116.79 Pass 175.00 175.00 175~00 175.00 0.10 0.08 255.67 255.67 7.000 118.61 2.28 116.33 Pass 200.00 200.00 200.00 200.00 0.13 0.11 255.71 255.71 7.000 118.48 2.70 115.78 Pass 225.00 225.00 225.00 225.00 0.16 OJ4 255.74 255.74 7.000 118.35 3.12 115.23 Pass 250.00 250.00 250.00 250.00 0.18 0.17 255.78 255.78 7.000 118.21 3.53 114.68 Pass 275.00 275.00 275.00 275.00 0.21 0.19 255.82 255.82 7.000 118.07 3.93 114~14 Pass 300.00 300.00 300.00 300.00 0.24 0.21 255.86 255.86 7.000 117.93 4.35 113.58 Pass 324.36 324.36 325.00 325.00 0.27 0~24 255.88 230.37 7.000 117.84 4.74 113.11 Pass 348.72 348.72 350.00 350.00 0.29 0.26 255;82 230.31 7.000 117.90 5.13 112.77 Pass 373.07 373.07 375.00 374,99 0.32 0.28 255.70 230.19 7.000 118.08 5~50 112.59 Pass ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LEITER CHECK 1 STANDARD LEITER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL ~ INJECTION WELL REDRlLL .- WELL NAME 11/ S - Q /í CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) . ANNUL~ DJWOSAL <LL)NO ANNULAR DISPOSAL <--> YES ANNULAR DISPOSAL THIS WELL. "CLUE" Tbe permit is for a new wellbore segment of existing weD ----' Permit No, . API No. . .. Production should continue to be reported as a function of the original API number stated above. . In accordance with~O AAC 25.005(1), aU r~ords, data and logs acquired for the pilot hole must be clearly . differentiated in both name (name on permit plus PH) and API number (50 -70/80) . from . records, data and logs acquired for wel~(n~me on permit). Annular disposal has ~ot been requested . ~ . Annular Disposal. of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated... . ANNULUS <--> YES. + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is tbe approved application for permit to drill tile above referenced well. Tbe permit is approved ,sùbject to full compliance with 20 AAC 25.055. Approval to periorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. H 205543 DATE INVOICE / CREDIT MEMO DESCRIPTION 021302 CK021302L PYMT COMMENTS: HANDLING INST: Perni t to Dr i II :="ee StH - Sandra Stewman \'----~/Y/I ~)~~) -- C~;"-l I ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 DATE 02/15/02 CHECK NO. 00205543 GROSS 100.00 VENDOR DISCOUNT 00 ALASKAOILA NET 100.00 X4750 100.00 100. 00 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND. OHIO No. H 205543 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 """""412 00205543 ,~~ P¡.\Y ONE HUNDRED & 00/100************************************* US DOLLAR To The ORDER Of ÄLASKA üIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AI" 99 ~.o 1 DATE 02/15/02 AMOUNT $100.00 NOT VALID AFTER 120 DAYS ç¿ 6 ifi/:.{ .. .' .f( ,\, ' '" ~- ~....J' i /i"'ðo'1:'. ~ . '.., ....L"'.-J..,~\,.¡¡ 118 2 0 5 5 ... j 118 I: 0... ~ 2 0 j 8 g 5 t: 0 0 B ...... . g 118 WELL PERMIT CHECKLIST COMPANY ð')l ~ WELL NAME #/?f- c> //"" FIELD & POOL Ä 77:,- ,~~- hp/"'t-J INIT CLASS 7-1Û__)r,~ ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator hàs appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . A¡¡R 1>.f ~E.J. 12. Permit ca~ be issued without administrativ~ approval.. . . . . ¡(// ~ ..r<-ð/ð'2..-.13. Can permIt be approved before 15-day walt.. . . . . . . . . . ENGINEERING 14. Conductor string provided... . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT 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 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . 23. If diverter 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 tJ/A- psig. 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued w/o hydrogen sulfide measures. . . . . 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . A~~ 2~ T~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . /f ~ 176/c><-. 34. Contact name/phone for weekly progress reports [exploratory onl ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~ TEM œ '!A. '8;/~t..t> COT SFD- WGA W6k' DTSOS/2..110~ JMH AP.PIR DATE 'f¥itl~ ~12-I{o2-' /tr¿'lrL '/db~~ GEOLOGY APPR DATE G:\geology\templates\checklist.doc PROGRAM: Exp - Dev - Redrll - Serv X Wellbore seg - Ann. disposal para req - GEOL AREA 7),'-Ò UNIT# II J>.2.. 7 ON/OFF SHORE ~ ~~. Å 1J.'<: ~d-Je/ aN /~r-d.r /~ Ä £: ~4c:h.4..1 <~, ",--/, Æ- "~¿/~ r ~ ~~ 34J,~~ /:7#4/f<-. ~ý ~, ~~.~}1 ga~b: -P~ðJ/eI :i ¡r-1,-Þ2' ;/::, C"~, :44:', (~~ ~ ~ \d: @ J/3' TV Þ. '-¥-"M" ¡.JIlt- ~~. b Q N Altt () yt;. 2.1 E:. ~ /itA ~. N oN ~CL.\c~Q- o..~~~." t"'''' ~ ( ~,~\;'t~ ~\.s.. N I'll ç P .::. /t£L/o p~" . ~ N ~ S MIA ~V4l~ <~ ~N Y@ Y N Y N Y ~ ~ ¡J. ÚL<fA"'-~</ d;Ç.foÇ....( ~tU(J(}~{ ~.,,~ ~ G~T Commentsllnstructions: Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process. but is part of the history file. . To improve the readability of the Well History file and to sim.pltfy finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special.effort has been made to chronologically. . organize this category of information. ó{C:t;}- O/~ 10970 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jul 25 11:29:43 2002 Reel Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 07 /2 5 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........... .... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/07 /25 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........... .... . UNKNOWN Continuation Number..... .01 Previous Tape Name. ..... . UNKNOWN Comments. ... ........ ... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-07 500292307900 B.P Exploration Sperry Sun 25-JUL-02 Alaska, Inc. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22062 R. FRENCH E. VAUGHN MWDRUN 2 AK-MW-22062 R. FRENCH C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3353 20 0 72.70 38.70 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 20.000 113.0 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. DIGITAL AND LOG DATA ONLY ARE SHIFTED TO THE SCHLUMBERGER GAMMA RAY RUN ON 07-May-2002. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. PDC LOG RECEIVED FROM D. SCHNORR ON 06/27/02. 5. MWD RUNS 1 AND 2 REPRESENT WELL MPS-07 WITH API#: 50-029-23079-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8696.5'MD/4627.4'TVD (SHIFTED) . SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name...... ...... .STSLIB.OOl Service Sub Level Name... Version Number..... .... ..1.0.0 Date of Generation..... ..02/07/25 Maximum Physical Record..65535 File Type........ ...... ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY 'PBU TOOL CODE RPD RPM RPS RPX FET GR 1 clipped curves; all bit runs merged. .5000 START DEPTH 88.0 88.0 88.0 88.0 88.0 96.5 STOP DEPTH 8649.5 8649.5 8649.5 8649.5 8649.5 8657.0 ROP $ 134.5 8696.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ---- BASELINE DEPTH GR 88.0 90.0 7488.0 7490.0 7513.0 7513.0 7524.5 7523.0 7559.0 7557.0 7576.5 7575.5 7586.5 7584.5 7630.5 7627.5 7646.0 7645.0 7654.5 7652.0 7696.0 7697.0 7716.5 7719.0 7766.0 7771.5 7803.5 7803.0 7909.0 7911.0 7922.0 7922.5 7990.0 7991.5 8004.5 8006.0 8045.0 8044.0 8070.0 8072.0 8095.0 8098.0 8118.5 8118.5 8147.5 8146.0 8205.5 8202.5 8256.0 8255.5 8280.5 8278.5 8312.5 8310.5 8340.0 8340.0 8396.5 8391.5 8405.5 8405.0 8514.0 8511.5 8547.5 8547.0 8696.5 8695.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 90.0 4021.5 MWD 2 4021.5 8695.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.......... ... .....0 Data Specification Block Type.....O Logging Direction.......... ...... . Down Optical log depth units..... .... ..Feet Data Reference Point............. . Undefined Frame Spacing..... ...... ......... .60 .1IN Max frames per record............ . Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 88 8696.5 4392.25 17218 88 8696.5 RPD MWD OHMM 0.15 2000 80.844 17124 88 8649.5 RPM MWD OHMM 0.14 2000 35.8958 17124 88 8649.5 RPS MWD OHMM 0.12 1790.94 27.4705 17124 88 8649.5 RPX MWD OHMM 0.11 459.07 20.5452 17124 88 8649.5 FET MWD HOUR 0.05 12.93 0.524248 17124 88 8649.5 GR MWD API 17.09 120.24 68.262 17122 96.5 8657 ROP MWD FT/H 3.26 122067 284.688 17125 134.5 8696.5 First Reading For Entire File...... ....88 Last Reading For Entire File..... .... ..8696.5 File Trailer Service name....... ... ...STSLIB.001 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .02/07/25 Maximum Physical Record. .65535 File Type............... .LO Next File Name........ ...STSLIB.002 Physical EOF File Header Service name...... .... ...STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/07/25 Maximum Physical Record. .65535 File Type. .............. .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPX RPS RPM GR ROP 2 header data for each bit run in separate files. 1 .5000 START DEPTH 90.0 90.0 90.0 90.0 90.0 98.5 136.5 STOP DEPTH 3975.0 3975.0 3975.5 3975.0 3975.0 3983.0 4021.5 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: ' MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.. .......... ... ..Down Optical log depth units......... ..Feet Data Reference Point..... ........ . Undefined Frame Spacing........ .... ........ .60 .1IN Max frames per record.... ........ . Undefined Absent value.. ....... ............ .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 09-APR-02 Insite 66.37 MEMORY 4022.0 90.0 4020.5 .0 79.5 TOOL NUMBER PBOO145HWRG6 PBOO145HWRG6 9.875 Water 9.20 160.0 8.5 600 8.4 Based 2.000 1.990 2.400 2.700 68.0 68.3 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD010 OHMM 4 1 68 4 2 RPM MWD010 OHMM 4 1 68 8 3 RPS MWD010 OHMM 4 1 68 12 4 RPX MWD010 OHMM 4 1 68 16 5 FET MWD010 HOUR 4 1 68 20 6 GR MWD010 API 4 1 68 24 7 ROP MWD010 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 90 4021.5 2055.75 7864 90 4021.5 RPD MWD010 OHMM 0.15 2000 151.993 7771 90 3975 RPM MWD010 OHMM 0.14 2000 60.5628 7771 90 3975 RPS MWD010 OHMM 0.12 1790.94 40.8009 7771 90 3975 RPX MWD010 OHMM 0.11 261.69 28.3295 7772 90 3975.5 FET MWD010 HOUR 0.05 1.52 0.367359 7771 90 3975 GR MWD010 API 17.09 117.04 63.6114 7770 98.5 3983 ROP MWD010 FT/H 3.26 122067 303.337 7771 136.5 4021.5 First Reading For Entire File......... .90 Last Reading For Entire File.......... .4021.5 File Trailer Service name...... ..... ..STSLIB.002 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.. .... .02/07/25 Maximum Physical Record..65535 File Type. ............ ...LO Next File Name. ... ..... ..STSLIB.003 Physical EOF File Header Service name..... ..... ...STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. .... ..02/07/25 Maximum Physical Record. .65535 File Type.. ........... ...LO Previous File Name.... ...STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS RPM RPD FET RPX GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 3975.5 3975.5 3975.5 3975.5 3976.0 3983.5 4022.0 STOP DEPTH 8648.5 8648.5 8648.5 8648.5 8648.5 8656.0 8695.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... ....... ..0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet. Data Reference Point..... ... .... ..Undefined Frame Spacing.................... .60 .1IN Max frames per record... ...... ....Undefined Absent value........... ......... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 12-APR-02 Insite 66.37 MEMORY 8695.0 4020.5 8696.5 35.2 78.4 TOOL NUMBER PBOO145HWRG6 PBOO145HWRG6 9.875 Water 9.20 85.0 8.4 400 10.0 Based 2.100 1.560 2.600 3.000 65.0 89.6 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS RPX FET GR ROP MWD020 MWD020 MWD020 MWD020 MWD020 OHMM OHMM HOUR API FT/H 4 4 4 4 4 1 1 1 1 1 68 68 68 68 68 12 16 20 24 28 4 5 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3975.5 8695 6335.25 9440 3975.5 8695 RPD MWD020 OHMM 0.56 2000 22.1579 9347 3975.5 8648.5 RPM MWD020 OHMM 0.66 681.46 15.5478 9347 3975.5 8648.5 RPS MWD020 OHMM 2.25 1476.6 16.5769 9347 3975.5 8648.5 RPX MWD020 OHMM 2.18 459.07 14.161 9346 3976 8648.5 FET MWD020 HOUR 0.08 12.93 0.655162 9347 3975.5 8648.5 GR MWD020 API 17.63 120.24 72.1455 9346 3983.5 8656 ROP MWD020 FT/H 5.01 910.16 269.257 9347 4022 8695 First Reading For Entire File..... .... .3975.5 Last Reading For Entire File......... ..8695 File Trailer Service name.......... ...STSLIB.003 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation. ..... .02/07/25 Maximum Physical Record..65535 File Type.... . . . . . . . . . . . . LO Next File Name..... ..... .STSLIB.004 Physical EOF Tape Trailer Service name........ .... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 07 /25 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.......... ... ...UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments.......... ...... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........ .... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 07 /25 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........ ....... . UNKNOWN Continuation Number..... .01 Next Reel Name......... ..UNKNOWN Comments........... ......STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File