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Home My WebLink About204-1201a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 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): GL: 34.80 BF: N/A 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-4 TPI: x- y- Zone-4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone-4 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 N/A (ft MSL) 22.Logs Obtained: 23. BOTTOM 20" H-40 112' 10-3/4" K-55 2,286' 7-5/8"K-55/L-80 3,994' 4" L-80 3,979' 4-1/2" L-81 3,837' 4-1/2" L-82 4,033' 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 11/4/2020 2,438' NSL, 4,055' WEL, SEC. 33, T13N, R10E, UM 4,137' NSL, 3,279' WEL, SEC. 32, T13N, R10E, UM 1,362' NSL, 3,454' WEL, SEC. 29, T13N, R10E, UM 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, Uncemented Slotted Liner6-3/4" TUBING RECORD Uncemented Slotted Liner 9,863' 9,885' 750 sx Class 'G' 3,910' 3,970' 9-7/8" 6-3/4" 6,7304-1/2" Uncemented Slotted Liner BOTTOM 3-1/2" 260 sx Arctic Set (Approx.) Surface 316 sx AS Lite, 259 sx Class 'G' AMOUNT PULLED 9.5 Surface 6,773' 2,699' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska LLC WAG Gas 204-120 / 320-376 68.16 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 551315 6009461 50-029-23214-60-00 MILNE PT UNIT I-14L1 MILNE POINT / SCHRADER BLUFF OIL ADL0025517 & ADL0025906 N/A9,910 / 3,973' 9,910 / 3,973' August 16, 2004 August 14, 2004 CASING WT. PER FT.GRADE CEMENTING RECORD 3011220 SETTING DEPTH TVD 6013724 TOP HOLE SIZE 546795 546596 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/A / N/A N/A / N/A Surface Surface Per 20 AAC 25.283 (i)(2) attach electronic information 29.7 9,740' Surface 3,777' 92 45.5 112' Surface 7,618' SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) 12.6 7,265' 7,482' 42" 12.6 6-3/4" Gas-Oil Ratio:Choke Size: Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By Grace Christianson at 9:44 am, Mar 06, 2024 Abandoned 11/4/2020 JSB RBDMS JSB 031424 xGDSR-3/15/24 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Surface Surface 1,800' 1,789' Top of Productive Interval 7,385' 3,930' Schrader Bluff 31. List of Attachments: Schematic & Daily Operations Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Taylor Wellman Digital Signature with Date:Contact Email:twellman@hilcorp.com Contact Phone: 777-8449 Wells 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. 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. Authorized Name and 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 Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.03.01 10:24:14 - 09'00' Taylor Wellman (2143) _____________________________________________________________________________________ Revised By: TDF 11/23/2020 SCHEMATIC Milne Point Unit Well: MPU I-14 Last Completed: 9/28/2020 PTD: 204-119 18 19 17Med Excluder Screen Slotted Liner Slotted Liner TD = 9,863’ (MD) / TD = 4,033’(TVD) 20” 7-5/8” 12 13 10-3/4” 13 14 15 TOC @ 6,473’ SLM PBTD =9,863’ (MD) / TD = 4,033’(TVD) 6 7 Orig. KB Elev.: 68.16’ Doyon 14 13 3 4 5 8 9 10 11 16 1 2 Tubing Cut @ 6,430‘ SLM 1111131333333333331113333333313333313113 111111133333333333133331111111333333333331333313333313 “OB” Lateral l “NB” Lateral “OA” Lateral “OB” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4” Liner “NB” 9.5 / L-80 / IBT 3.548 6,773’ 9,740’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.960 7,265’ 9,885’ 4-1/2” Liner “OB” 12.6 / L-80 / IBT 3.960 7,482’ 9,863’ TUBING DETAIL 4-1/2” Kill String 12.6 / L-80 / EZ-GO HT 3.958 Surface 6,730’ JEWELRY DETAIL No Depth Item 1 6,707’ X -Nipple 2 6,728’ Mule Shoe –Bottom @ 6,730’ 3 6,773’ NB Lateral Tie Back Sleeve 4 6,784’ NB Lateral ZXP Liner Top Packer 5 6,799’ NB Lateral LEM #2 (Lateral Entry Module) 6 6,809’ NB Lateral Hook Wall, Hanger above 7-5/8” Window 7 6,826’ NB Lateral Hook Wall, Hanger below 7-5/8” Window 8 6,845’ NB Lateral Swell Packer 9 7,265’ OA Lateral Tie Back Sleeve 10 7,276’ OA Lateral ZXP Liner Top Packer 11 7,311’ OA Lateral LEM #1 (Lateral Entry Module) 12 7,319’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 13 7,336’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 14 7,482’ OB Lateral Tie Back Sleeve 15 7,493’ OB Lateral ZXP Liner Top Packer 16 7,500’ OB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 17 9,740’ NB Lateral 4-1/2” Btm of Guide Shoe 18 9,885’ OA Lateral 4-1/2” Btm of Guide Shoe 19 9,863’ OB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 750 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 76.0 deg @ 6,710’ MD 60 deg @ 2,491’ MD WELLHEAD Tree 2-9/16” – 5M FMC Wellhead 11” x 11” 5M FMC Gen 5, w/ 2-7/8” FMC Tubing. 2-7/8” EUE 8rd on T&B, 2.5” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 ESP Replacement by Nabors 4ES – 8/26/2007 Install Kill String ASR#1 – 9/28/2020 Suspended by ASR#1 – 11/4/2020 LATERAL WINDOW DETAIL Top of “NB” Window @ 6,814’ MD; Bottom @ 6,826’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 7,324’ MD; Bottom @ 7,336’ MD; Angle @ top of window is 73 deg Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 Slickline 50-029-23214-00-00 204-119 9/17/2020 9/29/2020 9/18/2020 - Friday No operations to report. 9/16/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/17/2020 - Thursday WELL O/L ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/ 2,500H. RAN KJ, 2-7/8" OK-6 W/ 1-1/4" JDC (steel) 3 TIMES & PULLED BK-DGLV FROM ST# 1 @ 6,181' SLM (6,173' MD), ALL PACKING RECOVERED, REFER TO JOB LOG FOR RUN DETAILS. PULLED BEK-OGLV FROM ST# 2 @ 131' SLM (146' MD), ALL PACKING RECOVERED. SET BK-DGLV IN ST# 2 @ 131' SLM (146' MD), SAW 1' OF TRAVEL, SHEARED OFF CLEAN. No operations to report. No operations to report. 9/19/2020 - Saturday No operations to report. 9/22/2020 - Tuesday 9/20/2020 - Sunday No operations to report. 9/21/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 ASR#1 50-029-23214-00-00 204-119 9/17/2020 9/29/2020 9/25/2020 - Friday No operations to report. 9/23/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 9/24/2020 - Thursday No operations to report. Rig Down off of I-14 and mobilize equipment to A-pad for short term storage. Continue to RD. ND BOP, NU tree on I-14. Continue with equipment loadout to A-pad. Wells Group assists in well kill. Monitor well, conduct bleed, well dead. Install BPV with test dart. Clear location of well kill equipment. Remove secondary IA valve. ND Tree. Stage in Mud Boat, begin staging trailers and equipment on location. 9/26/2020 - Saturday POH with ESP Assembly on 2-7/8" tubing. Lay down ESP assembly. Clear and clean rig floor of equipment. Change out equipment in preparation to RIH with 4-1/2" 12.75# L-80 EZ-GO HT tubing workstring with P&A Tailpipe Assembly with 3.81" X-Nipple, 6.70" Fluted No-Go, and Mule Shoe entry guide. RIH with 4-1/2" 12.75# L-80 EZ-GO HT tubing workstring with P&A Tailpipe Assembly with 3.81" X-Nipple, 6.70" Fluted No-Go, and Mule Shoe entry guide. Continue to RIH with 4- 1/2" 12.75# L-80 EZ-GO HT tubing workstring with P&A Tailpipe Assembly with 3.81" X-Nipple, 6.70" Fluted No-Go, and Mule Shoe entry guide. Significant slack-off at ~6,540' md. Attempt to work pipe down. Consult with team and Day Supervisor. RU Power Swivel to Top Drive. Set torque limits to 2,000 ft/lbs. Rotate and reciprocate pipe in small movements. Able to make 2-3' gains with each rotation and reciprocation attempt. Work down with 2 joints (66') before normal calculated hanging weight is seen. Continue to MU with Power Swivel but able to move down with slow and steady set down weight. Begin to see Slack Off at makeup on Joint 202, ~6,710' md. Tag at 9' in. Make 6 pickups and setdowns to confirm tag. On fifth pickup, rotate while setting down to ensure Muleshoe is not hanging up and observe same slackoff at same depths. Pick up, stop rotation, use 5' stick to measure for space out. Lay down jts 202 and 201, MU pup jts and hanger, land assembly. PUW ~58k, SO ~32k. Calculated air string weight hanging off hanger 85k. Run in Lockdown Screws, secure well. Begin Rig Down operations. 9/29/2020 - Tuesday 9/27/2020 - Sunday Conduct PJSM with crew, conduct equipment and fluid checks;Complete rigging up. Monitor while fluid packing lines, all good. Fluid pack to BOP, no leaks. Conduct Shell test of 13-5/8" BOP to 250 psi low / 2,500 psi high. Troubleshoot bleed off, reconduct test and good test. Test BOP to 250 psi low / 2,000 psi high per Sundry with 2-7/8" and 4-1/2" test joints. Test Fire and Gas alarms. Conduct drawdown test. Test completed. Clear and clean rig floor of BOP test equipment. Stage in equipment for pulling completion. Bleed IA in preparation for pulling BPV. Conduct Sundry meeting with Day crew. Bleed IA and confirm 0 psi. Attempt to pull BPV and note some pressure underneath. Pump tubing volume through BPV taking returns through IA. Tubing on vacuum. Pull BPV. BOLDS. Unseat tubing hanger and pull to the floor. PUW = 45k. Cut and secure both ESP and heat trace cables. POOH laying down 2-7/8" 6.5# EUE tubing. Spool ESP cable and heat trace cable. 9/28/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 ASR#1 50-029-23214-00-00 204-119 9/17/2020 11/4/2020 No operations to report. (Pressure test RU. 250/2500psi) Pumped 25 bbls criesel down IA. Pumped 25 bbls criesel down TBG. Tags hung. Centrilift Pull Report. 10/3/2020 - Saturday No operations to report. 10/6/2020 - Tuesday 10/4/2020 - Sunday No operations to report. 10/5/2020 - Monday 10/2/2020 - Friday No operations to report. 9/30/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/1/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 CTU 50-029-23214-00-00 204-119 9/17/2020 11/4/2020 Log with READ GC/CCL from 7,700' to 6,780.2' and paint flag. Continue logging to 6,500'. POOH and verify good data. MU 4.5" Alph cement retainer and RIH to flag depth. Correct to element of cement retainer. PUH to setting depth of 7,560'. Pump 1/2" aluminum ball to set retainer. Ball landed and sheared at 40.8 bbls away. Set 10k down to confirm set. Perform injectivity test through retainer. R/U and pressure test cement pump and lines. Pump 43.1 bbls of 15.8 ppg class G cement. Pump all cement away and unsting from retainer with 20k overpull. Displace cement with Powervis and POOH. M/U 2nd cement retainer BHA. RIH and correct depth at EOP flag. RIH past setting depth and PUH to 7,250'. Drop 1/2" aluminum ball to set retainer. Set 10k down and confim retainer is set. Perform injectivity test. Pump 45 bbls of 15.8 ppg class G cement. Unsting from retainer at 39k up weight. POOH. MU READ 40 arm caliper for log of final retainer setting depth. MIRU Test BOPE to 250 low / 4,000 high. Continue operations 10/11/2020. 10/10/2020 - Saturday MU BOT Milling BHA and RIH. Stop at EOP flag at 6,481.07' and correct depth. Tag on depth at 6,801', PU and start milling. Had several stalls but eventualy milled through restriction. Backreamed to 6,790', shut down the pump and dry drifted through clean. RIH to tag fill and start FCO. Clean out to 7,700'. POOH while freeze protecting coil. Noted damaged cutters on gauge of mill. M/U and RIH with READ GR CCL logging BHA. Begin logging up from 7,700' ctmd. 10/13/2020 - Tuesday 10/11/2020 - Sunday RIH with 3.61 OD Drift Nozzle and READ Gamma CCL Logging Tools. Tag LEM at 6,804' made several attempts to get past. Log up to 6,500', make 1 more attempt to pass through LEM without success. Discuss options with Wells Foreman and OE and POOH to drift for Caliper tools. MU 2.75" Drift with Stingers and RIH. Ran past 6,804' clean. Continue RIH and tagged in lower LEM. Attempt to get jet through possible bridge and we are cleaning out fill. Decision made to POOH for a motor & mill to clean up upper LEM to pass retainers and clean out fill to 7,700'. 10/12/2020 - Monday 10/9/2020 - Friday No operations to report. 10/7/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 10/8/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 CTU 50-029-23214-00-00 204-119 9/17/2020 11/4/2020 10/16/2020 - Friday No operations to report. 10/14/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary Caliper log from 6,900' to 6,500' and paint EOP corelation flag. POOH and confirm good data. MU and RIH with 4-1/2" Alpha cement retainer. Correct at flag depth and set retainer at 6,803'. Drop 1/2" aluminum ball and set retainer at 41.5 bbls. Set 10k down and confirm set. MU and PT cement pump. Batch and test 45 bbls of 14.0 ppg Squeezecrete. Pump 41 bbls of 14.0 ppg Squeezecrete through retainer at 1.0 bpm and note increasing pressure as cement filled lateral. Unsting from retainer and leave 0.5 bbls of cement on top of retainer. POOH. MU and RIH with 2.50" BDJSN w/0.75" hole. Displace backside with KCL followed by diesel. Displace coil with KCL taking returns from tubing. Begin pumping 15.8 ppg class G cement down coil w/fresh water spacers. Pump 1 bbl cement around nozzle and begin taking returns from IA 1:1 with 40bbl gauge tank. Pump 13.1 bbls behind tubing and swap to take returns from tubing. @ 1 bpm. POOH laying in cement 1:1 to 6,398.2'. RBIH and contaminate to 6,500' ctmd. Pump .81" ball. Contaminated and washed down to 6,490' ctmd. POOH washing/contaminating at 80% with Powervis 10/15/2020 - Thursday No operations to report. No operations to report. No operations to report. 10/17/2020 - Saturday No operations to report. 10/20/2020 - Tuesday 10/18/2020 - Sunday No operations to report. 10/19/2020 - Monday Well Name Rig API Number Well Permit Number Start Date End Date MP I-14 Slick line 50-029-23214-00-00 204-119 9/17/2020 11/4/2020 No operations to report. No operations to report. 11/7/2020 - Saturday No operations to report. 11/10/2020 - Tuesday 11/8/2020 - Sunday No operations to report. 11/9/2020 - Monday 11/6/2020 - Friday No operations to report. 11/4/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary WELL S/I ON ARRIVAL, OPEN PERMIT W/PAD-OP, PT PCE 250L/2,500H. DRIFT TBG WITH 3.25" CENT, 5'x2.5" DRIVE DOWN BAILER (mule shoe ball) TO 6,473' SLM (recovered ~1/2 cup cement, state witnessed). PERFORM STATE WITNESS MIT-T 1,500psi WITH TRIPLEX (pass, see log for details). PERFORM STATE WITNESS MIT-IA 1,500psi WITH TRIPLEX (pass, see log for details). LOG TBG WITH HES MEMORY CCL-PRESSURE-TEMP TOOL FROM 6,470' SLM TO 6,270' SLM (good data). CUT TBG AT 6,430' SLM WITH HES MEMORY JET CUTTER. RDMO, CLOSE PERMIT W/PAD-OP. 11/5/2020 - Thursday No operations to report. 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Coil Cleanout w/ N2 Suspend Perforate Other Stimulate Pull Tubing Pump Cement Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing Cut 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,863'N/A Casing Collapse Conductor N/A Surface 2,470psi Production 4,790psi NB Liner 6,590psi OA Liner 7,500psi OB Liner 7,500psi 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: Operations Manager Contact Email:Abhijeet.Tambe@hilcorp.com 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 MILNE POINT / SCHRADER BLUFF OIL COMMISSION USE ONLY Authorized Name: 8,430psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025517 & ADL0025906 204-119 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23214-00-00 Hilcorp Alaska LLC Length Size 4,033' 9,863' 4,033' 639 N/A MILNE PT UNIT I-14 112'112' 12.66# / L-80 / Vam Top TVD Burst ±6,776 8,430psi MD N/A 2,966'7,910psi 5,210psi 6,890psi 2,286' 3,994' 3,979' 4.5" 2,699' 7,618' 4.5" 78'20" 10-3/4" 7-5/8" 2,665' 4" 2,620' 7,585' Authorized Signature: TBD 9,863'2,381' 4-1/2" 4,033' Perforation Depth MD (ft): See Schematic 3,837' See Schematic C.O. 477.05 9/11/2020 (3) Baker ZXP LTP and N/A 6,784 MD/ 3,780 TVD, 7,276 MD/ 3,913 TVD & 7,493 MD/ 3,972 TVD and N/A Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 9,885' 9,740' ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad A Helgeson 2020.09.11 18:36:37 -05'00' By Samantha Carlisle at 3:56 pm, Sep 11, 2020 320-376 SFD 9/11/2020MGR16SEP20 AOGCC to witness pressure test abandonment plug to 1500 psi and tag of cement (~ 6200' MD). First on-site inspection by AOGCC within 1 calendar year per 20 AAC 25.110(e). X DSR-9/15/2020 DSR-9/15/2020 10-407 DSR-9/15/2020 X Comm. 9/18/2020 dts 9/18/2020 JLC 9/18/2020 RBDMS HEW 9/21/2020 Reservoir Abandonment Well: MPU I-14 Date: 09-11-2020 Well Name:MPU I-14 API Number:50-029-23214-00 Current Status:Shut-In (ESP removed)Pad:I-Pad Estimated Start Date:09-17-2020 Rig:Coiled Tubing Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:204-119 First Call Engineer:Abhijeet Tambe (907) 777-8485 (O) (907) 331-9184 (M) Second Call Engineer:Ian Toomey (907) 777-8343 (O) (907) 903-3987 (M) AFE Number:Job Type:Reservoir Abandonment Current Bottom Hole Pressure:1,039 psi @ 4,000 TVD NB+OA+OB SBHP (08/16/2017 SI gauge reading) 4.99 PPG Maximum Expected BHP:1,039 psi @ 4,000’ TVD (EMW: 4.99 ppg) MPSP:639 psi Gas Column Gradient (0.1 psi/ft) Max Inclination 76° at 6,710’ MD Max Dogleg:7.6°/100ft at 2,013’ MD Brief Well Summary: MPU producer I-14 was drilled and completed as a Schrader Bluff producer in August 2004. OB and OA laterals were completed with 4-1/2” slotted liner while NB lateral was completed with 4” Baker Med Excluder Screens. ESP was changed out in 2007 and has been on production with the same ESP making approximately 200 bopd and 400 bwpd. Notes Regarding Wellbore Condition x 4-1/2” work string with mule shoe, perforated pup & X nipple stabbed into NB Tie Back sleeve at 6,773’ MD (Sundry 320-367). Objective: The purpose of this work is to abandon/isolate both Schrader intervals (N and O sands) with cement. The Schrader NB/OA/OB intervals needs to be abandoned for the new wells on Milne Point I-pad due to close approach risks and to help prevent potential MBE’s. Coil Tubing Procedure: 1. MIRU Coiled Tubing Unit w/ 2.0” coil and spot ancillary equipment. 2. Fill source tank w/source water. 3. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min Hi, 5 min Low each test. a. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient to meet weekly BOPE test requirement. b. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. c. No AOGCC notification required. d. Record BOPE test results on 10-424 form and submit within 5 days of test. 4. RIH w/ CCL memory logging carrier in conjunction with TEL/Nipple locator and 3.56” or equivalent jet swirl nozzle to ~7,540’ MD. Wash down as needed. a.Contingency: : If unable to reach bottom, RIH w/ 2.0” to 3.25” mill and extended reach cleanout BHA and cleanout to PBTD using 8.5 ppg 1% KCl w/liquid foamer and mix with Nitrogen. b. Depth is critical for setting the top cement retainer (above NB lateral) and by running TEL/nipple locator along with GR/CCL will help with tie-in and verification. Reservoir Abandonment Well: MPU I-14 Date: 09-11-2020 c. Min ID = 3.688” (LEM #2 @ 6,799’ & LEM #1 @ 7,311’ MD). 5. Mark CT as necessary for future runs and log OOH. Flag X nipple also and watch for the 3.688” profiles (slight over pull while pulling through LEMs) 6. Log up to 6,700’ and POOH. 7. LD CCL memory logging carrier. Abandoning OB Lateral (Slotted Liner) 8. MU 4-1/2” One Trip cement retainer and cementing nozzle and RIH. Correct depth at flag. a. Objective is to cement OB lateral. 9. Set Cement Retainer mid blank pipe joint at ±7,530’ MD – above OB lateral. a. Set down weight onto retainer to confirm set. 10. Establish injection through CT & cement retainer to ensure we have injection rate prior to the cement job. 11. Begin to mix 15.8 ppg retarded class G cement. Once blend is ready, pump ± 40 bbls of class G cement down the coil tubing. a. This cement slurry is slightly retarded as a contingency. If there is communication with the OH through the junction, cement could channel up on the back side and travel behind CT. Having slightly retarded cement gives us an opportunity to unsting from the retainer and POOH without getting stuck. b. Use freshwater spacers as needed around the cement. c. Target is to get all of 40 bbls of cement pumped through the retainer (4-1/2” slotted liner volume from retainer = 36 bbls) d. Do not exceed 1,000 psi above circulating pressure while pumping cement. e. If pressure starts to build up and unable to pump cement, unsting from the retainer and bullhead the cement away. In this scenario, cement could go into OB or into OA lateral above. After pumping cement away, contaminate cement to ±7,400’ as the next retainer will be set at ±7,306’ MD. 12. Once target cement volume is pumped through retainer or CT pressure exceeds 1,000 psi, come off the pumps and unsting from the retainer. Allow ~1/2 bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. a. Pull out of the cement as the last of the cement exits the nozzle stopping at 7,308’ to flag pipe. 13. Circulate coil tubing clean and POOH. Watch for and verify TEL/Nipple Profile locator at landmark features like 3.688” Seal Bores, Tubing Tail and X Nipple. Abandoning OA lateral (slotted liner) 14. MU 4-1/2” One Trip cement retainer and cementing nozzle and RIH. Note:Cement retainer (FH) running tool needs to be redressed prior to RIH. 15. Using the same flag from previous run, set Cement Retainer mid blank pipe joint at ±7,306’ MD – above LEM1 (OA lateral). a. Set down weight onto retainer to confirm set. Reservoir Abandonment Well: MPU I-14 Date: 09-11-2020 16. Establish injection through CT & cement retainer to ensure we have injection rate prior to the cement job. 17. Begin to mix 15.8 ppg class G cement. Once blend is ready, pump ± 50 bbls of class G cement down the coil tubing. a. Use freshwater spacers as needed around the cement. b. Target is to get all of 50 bbls of cement pumped through the retainer (4-1/2” slotted liner volume from retainer = 45 bbls) c. Do not exceed 1,000 psi above circulating pressure while pumping cement. d. If pressure starts to build up and unable to pump cement, unsting from the retainer and bullhead the cement away. In this scenario, cement could go into OA or into NB lateral above. After pumping cement away, contaminate cement to ±7,000’ as the next retainer will be set at ±6,800’ MD 18. Once targetcement volume is pumped through retainer or CT pressure exceeds 1,000 psi, come off the pumps and unsting from the retainer. Allow ~1/2 bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. a. Pull out of the cement as the last of the cement exits the nozzle stopping at 6,807’ to flag pipe. 19. POOH and circulate coil tubing clean as needed. Watch for and verify TEL/Nipple Profile locator at landmark features like 3.688” Seal Bores, Tubing Tail and X Nipple. Abandoning NB lateral (Screens) 20. MU 4-1/2” One Trip cement retainer and cementing nozzle and RIH. Note:Cement retainer (FH) running tool needs to be redressed prior to RIH. 21. Using the flag from previous run, set Cement Retainer in 9.80” section of the 4-1/2” (between 6,799’ and 6,807’ MD – above LEM2 (NB lateral). a. Set down weight onto retainer to confirm set. b. Pump down CTxT annulus to ~100 psi to confirm that retainer is fully set 22. Begin to mix Microfine Cement. Once blend is ready, pump ± 55 bbls of Microfine cement down the coil tubing. a. Use freshwater spacers as needed around the cement. Reservoir Abandonment Well: MPU I-14 Date: 09-11-2020 b. Target is to get all of 55 bbls of cement pumped through the retainer (4-1/2” Med Excluder screens volume from retainer = 52 bbls) c. Do not exceed 1000 psi above circulating pressure. 23. Once target minimum cement volume is pumped through retainer or CT pressure exceeds 1,000 psi, come off the pumps and unsting from the retainer. Allow ~1/2 bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. a. Pull out of the cement as the last of the cement exits the nozzle. b. There is a perforated joint below the X-nipple in the 4-1/2” work string that will enable us to pump (fullbore) the AOGCC required cement plug to isolate Schrader Bluff. So we do not want to cover those holes by laying too much cement above the retainer. 24. POOH and circulate coil tubing clean as needed. 25. RD CT unit. Fullbore / Slickline / Wireline Procedure – reservoir abandonment cement plug 26. RU cementers. 27. Establish circulation down 4-1/2” work string, through the perforated joint in the tail pipe and up the annulus. 28. Pressure test the casing and tubing (jug test) to 1,500 psi, and ensure the cement retainers are holding pressure 29. Mix and pump 20 bbls of 15.8 Class G cement followed with xx bbls of water and freeze protect fluid to spot cement above packer for 500ft cap in tubing and casing. a. 7-5/8” X 4-1/2” ann. Cap = 0.0246 bbls/ft. Cement volume = 0.0246 X 500 ft = 12.3 bbls 30. Wait on cement to gain 1,000 psi compressive strength. 31. RU slickline, RIH, tag TOC expected at +/- 6,200ft. 32. Pressure test tubing and IA to 1,500 psi for 30 min charted. Note: Notify AOGCC prior to the pressure test. 33. RU wireline, RIH and cut the tubing just above TOC. RD wireline. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Coil BOPE Schematic 5. N2 procedures and schematic for contingency. MPU I-14 is mechanically sound and will be secured with a cement plug that isolates hydrocarbon zone (Schrader Bluff) completely. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe and not a threat to public health. The main reason for ‘suspension’ is to preserve the future utility of the wellbore for possible sidetracking opportunity to enhance drainage. Thank you. Abhijeet Tambe | Sr. Operations Engineer |Hilcorp Alaska, LLC O: (907) 777-8485 | C: (907)331-9184 | Abhijeet.Tambe@hilcorp.com 3800 Centerpoint Drive, Suite 1400 | Anchorage, AK 99503 _____________________________________________________________________________________ Revised By: TDF 9/1/2020 PROPOSED Milne Point Unit Well: MPU I-14 Last Completed: 8/26/2007 PTD: 204-119 18 19 17Med Excluder Screen Slotted Liner Slotted Liner TD = 9,863’ (MD) / TD = 4,033’(TVD) 20” 7-5/8” 12 13 10-3/4” 13 14 15 PBTD =9,863’ (MD) / TD = 4,033’(TVD) 6 7 Orig. KB Elev.: 68.16’ Doyon 14 13 3 4 5 8 9 10 11 16 1 2 1111113133333333333113111113113333333333331113133333331333333311 1111111333333333331131111111111333333333331333333133113 “OA” Lateral “OB” Lateral “NB” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4” Liner “NB” 9.5 / L-80 / IBT 3.548 6,773’ 9,740’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.960 7,265’ 9,885’ 4-1/2” Liner “OB” 12.6 / L-80 / IBT 3.960 7,482’ 9,863’ TUBING DETAIL 4-1/2” Kill String 12.6 / L-80 / Vam Top 3.548 Surface ±6,776’ JEWELRY DETAIL No Depth Item 1 ±6,752 X -Nipple 2 ±6,772 Mule Shoe – Bottom @ ±6,773 3 6,773’ NB Lateral Tie Back Sleeve 4 6,784’ NB Lateral ZXP Liner Top Packer 5 6,799’ NB Lateral LEM #2 (Lateral Entry Module) 6 6,809’ NB Lateral Hook Wall, Hanger above 7-5/8” Window 7 6,826’ NB Lateral Hook Wall, Hanger below 7-5/8” Window 8 6,845’ NB Lateral Swell Packer 9 7,265’ OA Lateral Tie Back Sleeve 10 7,276’ OA Lateral ZXP Liner Top Packer 11 7,311’ OA Lateral LEM #1 (Lateral Entry Module) 12 7,319’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 13 7,336’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 14 7,482’ OB Lateral Tie Back Sleeve 15 7,493’ OB Lateral ZXP Liner Top Packer 16 7,500’ OB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 17 9,740’ NB Lateral 4-1/2” Btm of Guide Shoe 18 9,885’ OA Lateral 4-1/2” Btm of Guide Shoe 19 9,863’ OB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 750 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 76.0 deg @ 6,710’ MD 60 deg @ 2,491’ MD WELLHEAD Tree 2-9/16” – 5M FMC Wellhead 11” x 11” 5M FMC Gen 5, w/ 2-7/8” FMC Tubing. 2-7/8” EUE 8rd on T&B, 2.5” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 ESP Replacement by Nabors 4ES – 8/26/2007 LATERAL WINDOW DETAIL Top of “NB” Window @ 6,814’ MD; Bottom @ 6,826’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 7,324’ MD; Bottom @ 7,336’ MD; Angle @ top of window is 73 deg CURRENT DSR 9/15/2020 _____________________________________________________________________________________ Revised By: TDF 9/11/2020 PROPOSED Milne Point Unit Well: MPU I-14 Last Completed: 8/26/2007 PTD: 204-119 16 17 15Med Excluder Screen Slotted Liner Slotted Liner TD = 9,863’ (MD) / TD = 4,033’(TVD) 20” 7-5/8” 10 11 10-3/4” 13 12 13Cement Retainer1 ±7,530’ PBTD =9,863’ (MD) / TD = 4,033’(TVD) 4 5 Orig. KB Elev.: 68.16’ Doyon 14 13 1 2 3 6 7 8 9 14 Cement Retainer 2 ±7,306’ Cement Retainer3 between ±6,799’ to ±6,807’ TOC @ ±6,700’ Tubing cut just above TOC “OA” Lateral 10 11 13 4 5 14 “OA” L “OB” Lateral “NB” Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 92 / H-40 / Welded N/A Surface 112' 10-3/4” Surface 45.5 / K-55&L-80 / BTC 9.950 Surface 2,699’ 7-5/8" Production 29.7 / L-80 / BTC-MOD 6.875 Surface 7,618' 4” Liner “NB” 9.5 / L-80 / IBT 3.548 6,773’ 9,740’ 4-1/2” Liner “OA” 12.6 / L-80 / IBT 3.960 7,265’ 9,885’ 4-1/2” Liner “OB” 12.6 / L-80 / IBT 3.960 7,482’ 9,863’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 2.441 Surface 6,389’ JEWELRY DETAIL No Depth Item 1 6,773’ NB Lateral Tie Back Sleeve 2 6,784’ NB Lateral ZXP Liner Top Packer 3 6,799’ NB Lateral LEM #2 (Lateral Entry Module) 4 6,809’ NB Lateral Hook Wall, Hanger above 7-5/8” Window 5 6,826’ NB Lateral Hook Wall, Hanger below 7-5/8” Window 6 6,845’ NB Lateral Swell Packer 7 7,265’ OA Lateral Tie Back Sleeve 8 7,276’ OA Lateral ZXP Liner Top Packer 9 7,311’ OA Lateral LEM #1 (Lateral Entry Module) 10 7,319’ OA Lateral Hook Wall, Hanger above 7-5/8” Window 11 7,336’ OA Lateral Hook Wall, Hanger below 7-5/8” Window 12 7,482’ OB Lateral Tie Back Sleeve 13 7,493’ OB Lateral ZXP Liner Top Packer 14 7,500’ OB Lateral 7-5/8” x 5-1/2” HMC Liner Hanger 15 9,740’ NB Lateral 4-1/2” Btm of Guide Shoe 16 9,885’ OA Lateral 4-1/2” Btm of Guide Shoe 17 9,863’ OB Lateral 4-1/2” Btm of Guide Shoe OPEN HOLE / CEMENT DETAIL 20" Cmt w/ 260 sx of Arcticset I in 42” Hole 10-3/4" Cmt w/ 316 sx AS Lite, 259 sx Class “G” in 13-1/2” Hole 7-5/8” Cmt w/ 750 sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 500’ MD Max Wellbore Angle = 76.0 deg @ 6,710’ MD 60 deg @ 2,491’ MD WELLHEAD Tree 2-9/16” – 5M FMC Wellhead 11” x 11” 5M FMC Gen 5, w/ 2-7/8” FMC Tubing. 2-7/8” EUE 8rd on T&B, 2.5” CIW-H BPV Profile GENERAL WELL INFO API: 50-029-23214-00-00 Drilled and Completed by Doyon 14 – 8/28/2004 ESP Replacement by Nabors 4ES – 8/26/2007 LATERAL WINDOW DETAIL Top of “NB” Window @ 6,814’ MD; Bottom @ 6,826’ MD; Angle @ top of window is 75 deg Top of “OA” Window @ 7,324’ MD; Bottom @ 7,336’ MD; Angle @ top of window is 73 deg Milne Point ASR Rig 1 BOPE 2020 Updated 1/09/2020 11” BOPE 4.48' 4.54' 2.00' INTEGRATED 4.30'INTEGRATED 11" - 5000 2-7/8" x 5" VBR Blind11'͛- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualManual Stripping Head Coil Tubing BOP Milne Point Unit Revised: 1/8/2020 Valve, Swab, WKM-M, 4 1/16 5M FE Valve, Upper Master, Baker, 4 1/16 5M FE, w/ Hydraulic Valve, Lower Master, WKM-M, 4 1/16 5M FE Blind Blind Lubricator 4 1/16 15M Slip Slip Shear Shear Pipe Pipe Manual Gate 2 1/8 5M 2.00" Stripper Crossover spool 4 1/16 15M X 4 1/16 10M Manual Gate 2 1/8 5M Tubing Adapter, 4 1/16 5M Pump-In Sub 4 1/16 5M 1502 Union Crossover spool 4 1/16 10M X 4 1/16 5M To injection head Kill Port Plug Valve 2" / 10K Manual Plug Valve 2" / 10K Manual Kill Port STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Coil Tubing Unit Fluid Flow Diagram Cleanout w/ Nitrogen & Foam Updated 9/22/16 LEGEND: Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Check Valve Manual Choke Pressure Gauge 500 BBL KILL TANK Choke Manifold P 400 BBL UPRIGHT P Open VBR BLIND COIL PUMP 400 BBL UPRIGHT Open Closed Open Open Open Open Open Open Open P SW or KCL W/ FOAMER OR FRIC TION REDUCER 50 BBL FREEZE PROTECT TANK SW or KCL W/ FOAMER OR FRIC TION REDUCER To Flowline NITROGEN PUMP & TANK P COIL UNIT WITH 1.5” to 2.0” COIL 400 BBL UPRIGHT SEAWATER W/ DEFOAMER TRIPLEX • ~,-. ,'. ~. ,~ ~~ ;~ MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPg~_In~erts\Microfilm Marker.doc 1. Operations Performed: i1ldSI<a WI & Gas Co C o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter SUAij~R8rai~eqm f}, o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ~ Development o Exploratory 204-120 . 3. Address: o Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23214-60-00 - 7. KB Elevation (ft): KBE = 68.16' 9. Well Name and Number: MPI-14L 1 / 8. Property Designation: 10. Field 1 Pool(s): ADL 025517 Milne Point Unit 1 Schrader Bluff - 11. Present well condition summary Total depth: measured 9910' . feet true vertical 3973' I feet Plugs (measured) N/A Effective depth: measured 9910' . feet Junk (measured) N/A true vertical 3973' . feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1530 520 Surface 2664' 10-314" 2699' 2286' 5210 2480 Intermediate Production 7585' 7-5/8" 7618' 3940' 6890 4790 Liner 2499' 4-1/2" 7265' - 9885' 3910' - 3974' 8430 7500 Liner (OB) 2381' 4-112" 7482' - 9863' 3948' - 3975' 8430 7500 Perforation Depth MD (ft): Slotted Liner 7385' - 9841' 5CANNED SEP 2 7 2007 Perforation Depth TVD (ft): Slotted Liner 3941' - 3976' 2-718",6.5# L-80 6389' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): Baker ZXP Liner Top Packer 7276' 12. Stimulation or cement squeeze summary: Intervals treated (measured): R8DMS 8Ft SfP 2 {) 1D07 Treatment description including volumes used and final pressure: 13. Representative Dailv AveraQe Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: 127 7 115 350 317 Subsequent to operation: 251 15 209 360 313 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after work: o Exploratory ~ Development o Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 N/A Printed Name Sondra Stewman Title Technical Assistant - .../' Prepared By Name/Number: Si6ture~ ú'~~ Phone 564-4750 DateCB -4-lí] Sondra Stewman, 564-4750 . . .. Form 10-404 Revised 04/2006 ~ . STATE OF ALASKA . ~/?-P7 ALAYA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS ORIGINAL kr;.l).~ RECEIVED SEP J 4 2007 ission Submit OnglOal Only ~ C¡/Ífø7 ~ 2-9/16" - 5M FMC . Wellhead: 11" x 11" 5M FM Gen 5, W 2-7/8" FMC Tbg. 2-7/8" EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#/ft, H-40 OJÐ " Note" 103/4" 45.5 ppf L-80& K-55BTC-M (Drift ID = 10.050, cap. = .0981 bpf) Collapse 1 Internal Yield 2090 psi. I 358Q psi. 2480 psi. I 521.0 psi. K-55 159' thru 2,536' 103/4" Howco Float Shoe 12698' I 75/8" 29.7 ppf, L-80, BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpf) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf ) KOP @ 500' 50+ degree frorn 2300' Max hole angle = 76 degrees @ 6710' MD Window in 75/8" Casing @ 6814' - 6826' Well Angle @ window = ??' Baker Tie Back Sleeve 6773' Baker ZXP Liner Top Packer 6784' 4-1/2" Hook Hanger "LEM" 6799' Window in 75/8" Casing @ 7324' - 7336' Well Angle @ window = ??' Baker Tie Back Sleeve 7265' Baker ZXP Liner Top Packer 7276' Baker Tie Back Sleeve 7482' Baker ZXP Liner Top Packer 7493' V 7-5/8" Weatherford Float Collar 7533' 7-5/8" Weatherford Float Shoe 7618' DATE 08/28/04 08/26/07 REV. BY J. Cubbon L. Hulme COMMENTS Drilled & Completed Doyon 14 ESP change out - Nabors 4ES MPI-14)LI¡L-¿ eBelev.= 68.00'(Doyon14) NB Lateral OA Lateral Cameo 2-7/8" x1" KBMG Gas lift mandrel 146' Cameo 2-7/8" x1" 6173' KBMG Gas lift mandrel HES XN-Nipple (2.250" id) 6323' Pump Section, 82 stg. GC2900 AR 1:1 6335' Gas Separator 6353' Model - GRSFTX BAR H6 Tandem Seal Section, Series 513 6358' GSB3 DB SB/SB PFSNFSA CL5 Motor, 110 KMH-A 6372' 2152 volt /31 amp, PumpMate XTO w/6 fin centralizer 6385' 6 3/4" Hole td @ 9768 Baker Float shoe 9738' 55 jts. - 4", 9.5# L-80, IBT Blanks and 30 jts Baker Med Excluder Screen 6773'-9~') / Swell Pkr 6845' - 6869' 6 3/4" Hole td @ 9910' Blm Baker Float Shoe 9883' 44 jts. - 4 1/2" Slotted Liner 1 Z(S, 17 jts, 12.6# L-80 IBT (~9'-9885') 6 3/4'"Hole td @ 9863' Blm HES Type V Floal Shoe 9861' 30 jts. - 4 1/2" Slotted Liner 26 jts, 12.6# L-80 IBT (7482'-9863') MILNE POINT UNIT WELL 1-14 - 8?>a I tl· OO-CO API NO: 50-029-1. .. M LI '50- üZ'1- 2Za14-c..oo---oO L"Z.. sc-oz.C¡ - 3 IL- 1-00 BP EXPLORATION (AK) . . BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/19/2007 Rig Release: 8/26/2007 Rig Number: Spud Date: 8/2/2004 End: 8/26/2007 Date From - To Hours 8/21/2007 06:00 - 09:00 3.00 RIGD P PRE PTSM. Begin rigging down, preparing for truck arrival. Layover derrick. 09:00 - 15:30 6.50 MOB N PRE Move rig from Nabors Deadhorse yard to MPI-14. Encountered two flat tires on sub base. Replace same and continue rig Ip move. 15:30 - 00:00 8.50 MOB PRE Continue move to MPI-14. 8/22/2007 00:00 - 16:00 16.00 MOB P PRE Continue rnove from Nabors Deadhorse yard to MPI-14. Rig on location @ 1600-hrs. 16:00 - 18:00 2.00 RIGU P PRE Spot sub base, pits and pipe shed. Laid Herculite and berrned rig. 18:00 - 20:00 2.00 RIGU P PRE Held "Safety Stand Up" meeting with personnel from both rig crews. Meeting also attended by BP and Nabors management, I and MPU ops and HSE personnel. Continued with pre-tour meeting and crew change. 20:00 - 21 :00 1.00 RIGU P PRE PJSM. Raised derrick. 21 :00 - 00:00 3.00 RIGU P PRE Unstrung and restrung scoping lines. 8/23/2007 00:00 - 01 :00 1.00 RIGU P PRE Scoped derrick. Accepted rig @ 01 :00 hrs 8/23/2007. 01 :00 - 03:30 2.50 KILL P ,DECOMP RU lines to tree. Spotted and bermed tiger tank. RU lines to Ip I I tank and tested to 4000 psi. 03:30 - 05:00 1.50 KILL I DECOMP Filled pits with 120F heated brine. RU lubricator, pulled BPV. 05:00 - 11 :30 I 6.50 KILL I~ RREP I DECOMP . Replacing pulsation dampener on mud pump. Housekeeping. 11 :00 - 11 :30 I 0.50 KILL DECOMP PJSM - All crew: Kill well. Review well kill procedure and I assign tasks to crew. 11 :30 - 12:15 0.75 KILL P DECOMP Obtain well parameters - SITP = 530-psi, SICP = 690-psi, OAP = 140-psi. Begin bleeding well off to Tiger Tank. Bled tubing off to 430-psi and commenced pumping brine down tubing @ 4.0-BPM and bleeding off IA to tank. Pumped 57-Bbls. down I tubing. Pressure decreased to 90-psi with no returns from IA. Lined up circulating manifold to bullhead down IA. 12:15 - 13:151 1.00 KILL P DECOMP Initial pressures - SITP = Vac, SICP = 10, OAP = 140. Bullhead brine down IA - 5 BPM @ 160 psi. Controlled OA BUR from 140 to 450 psi with venting to bleed tank. SSV never reached over pressure range. Pumped 360 bbls down casing (6295 strokes). Bled OAP from 450 to 0 psi in 2 minutes (gas). Final pressures - SITP = Vac, SICP = Vac, OAP = O. 13:15 - 13:45 0.50 KILL P DECOMP Monitor well head pressures - SITP = Vac, SICP = Vac, OAP = 0.251 DHB 20. OAP increased 20 psi in 30 minutes. Clean up rig floor. Bring equipment to floor. 13:45 - 14:00 P DECOMP PJSM - All crew: Set TWC. FMC wellhead technician drifted 3" 1O-RD. x 2-7/8" EUE 8RD XO and lopso-opso for TWC. FMC wellhead technician dry rod set TWC in TBG HGR. 14:00 - 16:00 2.00 DHB P DECOMP PIT TWC from below - Pumped 50-Bbls. @ 5.0-BPM to test TWC from below. Gained O-psi. Well on vacuum. tested TWC from above to 3500-psi. Charted both tests for 10-minutes. 16:00 - 17:00 1.00 DHB P DECOMP Rig down test equipment. Prepare to nipple down Tree. 17:00 - 19:00 2.00 WHSUR P DECOMP Nipple down Tree. Set same aside for reuse. Held crew change. Performed pre-tour checks. 19:00 - 00:00 5.00 BOPSU P DECOMP PJSM. NU BOPE. Installed 2-7/8" x 5" VBRs. 8/24/2007 00:00 - 00:30 0.50 BOPSU P DECOMP Continued NU BOPE; installed landings on stack. 00:30 - 03:30 3.00 BOPSU P DECOMP PJSM. Tested BOPE to 250 psi low /3500 psi high. Test I witnessed by J. Crisp, AOGCC. Observed gas bubbling up Printed: 9/14/2007 10:06:30 AM .. .. . . BP Operations Summary Beport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 8/19/2007 8/26/2007 Spud Date: 8/2/2004 End: 8/26/2007 Date Task Description.of·Oþ~rà.tii(')hs 8/24/2007 00:30 - 03:30 I DECOMP tubing, past TWC. 03:30 - 04:15 DECOMP Added 106 bbls brine to IA. Pumped 3 bpm at 50 psi. Gas bubbling subsided; continuing minor gas leakage past TWC. 04:15 - 07:00 DECOMP Continued testing BOPE. Completed BOPE testing @ 0645-hrs. BO/LO 2-7/8" test joint. 07:00 - 07:30 0.50 PULL DECOMP Crews changed - PTSM. Prepare to rig up lubricator and Lopso-Opso to pull TWC. 07:30 - 08:30 1.00 PULL DECOMP PJSM with Veco valve crew. Bullhead 70 bbls down CSG @ 4 BPM (1185 strokes). 08:30 - 09:30 1.00 PULL DECOMP Land lubricator extension with Halliburton valve in HGR. MU Veco lubricator an pressure test to 500 psi. Pull TWC. TBG went on Vac. FL on CSG @ 1000'. 09:30 - 10:00 0.50 PULL DECOMP LD lubricator and lubricator extension. Stab into HGR with landing joint and TIW valve. 10:00 - 10:30 0.50 PULL DECOMP Pulled HGR free @ 50K - 45K to floor. Disconnect ESP cable and RU Centrlift and LO 2 7/8" TBG HGR. Test & tie cable to unit. 10:30 - 18:00 7.50 PULL DECOMP POH with 2 7/8" ESP completion. Recovered 110 LaSalle clamps, 3 flat guards, 5 protectolizers, 65 stands and 4 singles i 2-7/8" tubing, 3 GLM, X nipple, and pup jts. 18:00 - 19:00 1.00 PULL Ip DECOMP Held crew change and pre-tour meeting. Performed pre-tour I checks. Continued LD ESP ass'y. 19:00 - 20:00 1.00 RUNCO~P RUNCMP Cleared and cleaned rig floor. 20:00 - 21 :00 1.00 RUNCOMP RUNCMP PU swivel and kelly. Torqued kelly connections. 21 :00 - 00:00 3.00 RUNCO~P RUNCMP PUMU ESP assembly per Centrilift representative. 8/25/2007 00:00 - 00:30 0.50 RUNCO P RUNCMP Continued PUMU ESP ass'y on 2-7/8" tubing. MU X nipple, PU 4 singles and GLM. 00:30 - 02:45 2.25 RUNct RUNCMP RIH 29 stnds 2-7/8" tubing. Installed 50 LaSalle clamps. 02:45 - 04:00 1.25 RUNCO P RUNCMP RU to install heat trace. 04:00 - 06:30 2.50 RUNCO P RUNCMP RIH with 2-7/8" tubing and heat trace. 32 of 65 stands run @ 05:30 hrs. RIH with heat trace at 3 stands/hr. Flushed ESP ass'y with 12 bbls brine @ 1 bpm and 120 psi. 06:30 - 07:00 0.50 RUNCO~P RUNCMP PJSM. Performed pre-tour checks. Serviced rig. 07:00 - 18:00 11.00 RUNCO P RUNCMP Continued RIH with 2-7/8" tubing, heat trace and ESP cable. Flushed completion string with brine each 1000'. 18:00 - 18:30 0.50 RUNCO P RUNCMP PJSM. Performed pre-tour checks. Serviced rig. 18:30 - 21 :00 2.50 RUNCO RUNCMP Continued RIH with ESP ass'y on 2-7/8" tubing. 21 :00 - 22:00 1.00 RUNCO RUNCMP PUMU tubing hanger. Spaced out for cable and heat trace splices. 22:00 - 00:00 2.00 RUNCMP Spliced heat trace. 8/26/2007 00:00 - 01 :00 1.00 RUNCMP Continued splicing heat trace. 01 :00 - 03:30 2.50 RUNCMP Spliced ESP top connector. 03:30 - 05:00 1.50 RUNCMP Established parameters: PU 47k Ib, SO 35k lb. Landed tubing hanger. RILDS. Set TWC and tested from above and below to 1000 psi for 10 minutes. 05:00 - 08:00 3.00 BOPSU RUNCMP NO BOPE. 08:00 - 09:30 1.50 WHSUR RUNCMP Nipple up and test Tree to 5000-psi. Centrilift perform final ESP conductivity tests. Good test. 09:30 - 11 :00 1.50 I WHSUR P RUNCMP PUMU lubricator to top of Tree. PIT lubricator to 500-psi. Pul 10:30 - 14:00 I TWC. Set BPV. Release rig @ 1100-hrs. 3.50 RIGD P POST Lower derrick. Rig down sub base, pipe shed and pits. I Prepare to move off well. Rig off location @ 1400-hrs. Printed: 9/14/2007 10:06:30 AM ;Lì~ DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2041200 Well Name/No. MILNE PT UNIT SB 1-14L1 Operator BP EXPLORATION (ALASKA) INC 3r?u.J ry~~ý API No. 50-029.23214-~;'OJ MD 9910 - TVD 397~ Completion Date 8/27/2004 Completion Status 1-01L Current Status 1-0fL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number t=Etr-' D Asc I Rpt I '79 _ D Tap """"'12805 IßYI~Tap . ~u, MWD, GR, RES, IFR / CASANDRA, ASI (data taken from Logs Portion of Master Well Data Maint Name Directional Survey Directional Survey Induction/Resistivity LIS Verification Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments 7289 9910 Open 10/5/2004 IIFR SURVEY, FINAL I I 7289 9910 Open 10/5/2004 IIFR SURVEY, FINAL I I 66 9850 Open 10/29/2004 MWD/GR/EWR4/ROP 66 9850 Open 10/29/2004 MWD/GRlEWR4/ROP/DSN 12805 109 9910 Open 2/22/2006 ROP DGR EWR plus J Graphics --~- . 13579 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y €> ~N~ Chips Received? ,I N Analysis ~ Received? Daily History Received? @N ~/N . Formation Tops Comments: ~ Compliance Reviewed By: Date: ~)*~~ . . WELL LOG TRANSMITTAL g-04 - lôÜ }û4 - I ~11 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 Febmary 16, 2006 I êiS7q I ò5ê{; RE: MWD Formation Evaluation Logs MPI-14 L1 + L2 + L2 PBl + L2 PB2, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPI-14 Ll + L2 + L2 PBI + L2 PB2: LAS Data & Digital Log Images: 50-029-23214-60,61, 72, 73 1 CD Rom ~lh 0'\ :?~¡DtD . . ;2.f3r., (p 0 WELL LOG TRANSMITfAL ../ .--/ f ~~ ~) / , To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 21, 2004 RE: MWDFonnationEvaluationLogs MPI-14L1, AK-MW-3214396 1 LIS formatted Disc with verification listing. llPI#: 50-029-23214-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date/¥9 f~ r;;;{+~ .. . STATE OF ALASKA ._ ALASKA AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 0 C T D ;....~ .¿. 004- 1 ' 1a. Well Status: a Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 One Other 5. Date Comp., Susp., or Aband. 8/27/2004 6. Date Spudded 8/14/2004 7. Date T.D. Reached 8/16/2004 8. KB Elevation (ft): KBE = 68.16' CASING, liNER AND CEMENTING RECORD SETTING DePTH MD SeTTING DePTH TVO BOTTOM Top BoTTOM 112' 34' 112' 2699' 35' 2286' 7324' 33' 3927' 9885' 3910' 3974' o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2348' NSL, 4055' WEL, SEC. 33, T13N, R10E, UM Top of Productive Horizon: 4137' NSL, 3279' WEL, SEC. 32, T13N, R10E, UM (OA) Total Depth: 1362' NSL, 3454' WEL, SEC. 29, T13N, R10E, UM (OA) 4b. Location of Well (State Base Plane Coordinates): Surface: x- 551315 . y- 6009461 ~ Zone- ASP4 TPI: x- 546795 y- 6011220 Zone- ASP4 Total Depth: x- 546596 - y- 6013724' Zone- ASP4 18. Directional Survey aYes 0 No No. of Completions 21. Logs Run: MWD , GR , RES, IFRlCASANDRA , ABI 22. 20" 10-3/4" 7-518" 4-1/2" 94# 45.5# 29.7# 12.6# 34' 35' 33' 7265' H-40 L-80 L-80 L-80 23. Perforations open to Production (MD + TVD of T o,e and Bottom Interval, Size and Number; if none, state' none"): 4-1/2" Slotted Liner MD TVD MD TVD 7385' - 9841' 3941' - 3976' 26. Date First Production: Septemeber 27, 2004 Date of Test Hours Tested PRODUCTION FOR 10/2/2004 6 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED -AIr. Press. 24-HoUR RATE7 9. Plug Back Depth (MD+ TVD) 9910' + 3973' 10. Total Depth (MD+TVD) . 9910' + 3973' 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 42" 13-1/2" 9-718" 6-3/4" SIZE 2-7/8", 12.6# L-80 1b. Well ClaAšH.:rwmge a Development 0 Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 204-120 13. API Number 50- 029-23214-60-00 14. Well Name and Number: MPI-14L 1 15. Field 1 Pool(s): Milne Point Unit I Schrader Bluff Ft Ft 16. Property Designation: ADL 025517 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) '/W~¿Y)<.J 7:$ z-'¡ '/.YJ l;> ..31Z,7" 'rv ¿> ¿'þ 260 sx Arctic Set (Approx.) 316 sx AS Lite, 259 sx Class 'G' 750 sx Class 'G' Uncemented Slotted Liner DEPTH SET (MD) 6398' PACKER SET (MD) N/A DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 15 Bbls of Diesel and 75 Bbls of Dead Crude PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Electric Submersible Pump OIL-BeL GAs-McF WATER-BeL 1225 779 5 OIL-BeL 4900 GAs-McF 3116 WATER-BeL 20 I GAS-OIL RATIO 636 OIL GRAVITY-API (CORR) CHOKE SIZE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r. G'Mr.'L.¡:T!Îj~f'.! None . 3,o;i ,t;>¥ o R \ G 1 N A L VERIFiED I l__.l~::,<~.",,~ G F I Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE -RJ:WMS ~ 28. GEOLOGIC MARKERS. 29. eRMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD TVD SBF2-NA SBF21 SBF24-MF SBF1-NB SBF12 SBE4-NC SBE41 SBE3·ND SBE2-NE SBE1-NF TSBD-OA TSBD-OA TSBC TSBD-OA TSBD-OA 6736' 6764' 6835' 6861' 6935' 6983' 7002' 7034' 7046' 7211' 7334' 8273' 8969' 9208' 9357' 3768' 3775' 3793' 3800' 3820' 3833' 3838' 3846' 3850' 3894' 3930' 3946' 3943' 3967' 3977' None 30. List of Attachments: Signed Sondr( Stewma MPI-14L 1 Well Number Title Technical Assistant Date \ 0 - \. La - oy 204-120 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By NameINumber: Drilling Engineer: Sandra Stewman, 564-4750 Wa/terQuay, 564-4178 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-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 elevation in feet above mean low low water. 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: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None", ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Iœ!:.;. 2-9/16" - 5M FMC Wellhead: 11" x 11" 5M FrvA Gen 5, W 2-7/8" FMC Tbg.~" EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#/11, H-40 " Note" 103/4" 45.5 ppf L-80 & K-55 STC-M (Drift ID = 10.050, cap. = .0981 bpf) Collapse / Internal Yield K-55 2090 psi. I 3580 psi. L-80 2480 psi. I 5210 psi. K-55 159' thru 2,536' 103/4" Howco Float Shoe I 2698' I ~ 75/8" 29.7 ppf, L-80, BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpf) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. (drift id = 2.347" cap = .00592 bpf) KOP @ 500' 50+ degree from 2300' Max hole angle = 76 degrees @ 6710' MD Window În 75/8" Casing @ 6814' - 6826' Well Angle @ window = ??O Baker lie Back Sleeve 6773' Baker ZXP liner Top Packer 6784' 4-1/2" Hook Hanger "LEM" 6799' Window in 75/8" Casing @ 7324' -7336' Well Angle @ window = ??" Baker Tie Back Sleeve 7265' Baker ZXP liner Top Packer 7276' f ~A 7-S/8" Weatherford Float Collar 7533' 7-5/8" Weatherford Float Shoe 7618' Baker Tie Back Sleeve 7482' Baker ZXP Liner Top Packer 1493' MPI-14 NB Lateral OA Lateral ~B Lateral DATE 08/28/04 REV. BY COMMENTS J. Cubbon Drilled & Completed Doyon 14 Orig. KB elev. = 68.00' (Doyon 14) . L Cðmoo '-W ,,- KBMG Gas lift mandrel 146' Cameo 2-7/8" x1" KBMG Gas lift mandrel 2167' .. Cameo 2-7/8" x1" KBMG Gas lift mandrel 6170' HES XN-Nipple (2.250" id) 6321' Pump Seclion. 74 slg. GC2900 GPMTAR 1:1 6342' Tandem Inlake - Gas Separator 6358' Model-GRSFTXARH6 Tandem Seal Section, Series 513 I 6363' GSB3 DB UTIlT HL H6 PFS AFLAS IHSN . Molor, 171 KMH 2390 voll/44 amp, 6371' PumpMate w/6 fin centralizer 6392' L 6 3/4" Hole Id @ 9768' Baker Float shoe 9736' ~ V//////////////////N////N///I . 55 jts. - 4",9.5# L-80, IBT Blanks and 30 its Baker Med Excluder Screen(6773'-9739') rssw/," _10'~~~ ~ / Swell Pkr 6845' ,,6869' ~ 63/4" Hole Id @ 9910' Btm Baker Roal Shoe 9683' ~ 1./././././././././1 f 44 its. . 4 1/2" Slotted Liner 17 its, 12.6# L-80 1ST (7319'-9884') ~l"""" ,,'/"/'/// ~ 314'""" ~ @ 9863' Om HE$ "'" V"'. _ "'" '-.: r""/",,,,,/jf f 30 jts. - 4 112" Slotted Liner 26 jts, 12.6# L·80 IBT (7482'·9863') I' I I I I I r I II MILNE POINT UNIT ,WELL 1-14 .API NO: 50-029-2041190 ~p EXPLORATION (AK) BP Page 1 Legal Well Name: MPI-14 Common Well Name: MPI-14 Spud Date: 8/212004 Event Name: DRILL+COMPLETE Start: 8/1/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/27/2004 Rig Name: DOYON 14 Rig Number: Phase B/1/2004 22:00 - 00:00 2.00 MOB P PRE RID floor, Skid rig floor, Prepare for Move to MP-14 8/2/2004 00:00 - 03:30 3.50 MOB P PRE Pull off MPI-17,Move rig down pad to MPI-14, spot over well 03:30 - 04:30 1.00 MOB P PRE Skid rig floor,spot rock washer, spot water tank, Rigging up, Rig accepted @ 04:30 B/2/2004 04:30 - 07:00 2.50 RIGU P PRE Nipple up Diverter, take on H2o, 07:00 - 07:30 0.50 DRILL P SURF Clear floor of unneeded tool 07:30 - 17:30 10.00 DRILL P SURF Picking up drill pipe from pipe shed and standing in derrick, mixing spud mud 17:30 - 19:30 2.00 DRILL P SURF Picking up Bit, Motor 19:30 - 20:30 1.00 DRILL P SURF Pre Spud meeting with crews, function test diverter, fill hole, check lines, the right to witness test was wavier by Chuck Sheave AOOGC. 20:30 - 22:00 1.50 DRILL P SURF Spud well ,Drill to 257', Run Gyro every 100 ft. 22:00 - 23:00 1.00 DRILL P SURF Poh pick up Flex Des, Rih 23:00 - 00:00 1.00 DRILL P SURF Drill 257 to 347' with 60 rpms, 420 GPM, 1000 psi, run Gyro ever 100 ft., AST .57 ART .93 8/3/2004 00:00 - 21 :00 21.00 DRILL P SURF Directional Drill from 347' to 1972' - WOB 5 to 15 - RPM 60 - TO on 6k - off 2k - GPM 420 - PP on 11620 - off 1420 - PU 90- SO B5 - ROT B7 21 :00 - 22:00 1.00 DRILL P SURF CBU 3 X - RPM 70 - GPM 450 - PP 1700 - Flow check - Well static 22:00 - 23:00 1.00 DRILL P SURF Pump out to HWT @ from 1972 to 442' - Hole good no problems 23:00 - 23:30 0.50 DRILL P SURF RIH from 442' to 1 B77' - Precauctionary wash from 1 B77' to 1972' - tight @ 835 - no reaming or pumping required 23:30 - 00:00 0.50 DRILL P SURF Directional Drill from 1972' to 2030' - WOB 15 to 30 - RPM 60- TO on 6k - off 2k - GPM 420 - PP on 1620 - off 1420 - PU 90- SO 85 - ROT 87 B/4/2004 00:00 - 07:00 7.00 DRILL P SURF Directional Drill from 2030' to 2710' - TD 13.5" Hole - WOB 15 to 25 - RPM 60 - TO on 6k - off 3k - GPM 500 - PP on 2270 - off 2140 - PU 100 - SO 80 - ROT 90 07:00 - 09:00 2.00 CASE P SURF CBU 3 X - GPM 510 - RPM BO - TO 3 - ICP 2140 FCP 2030 09:00 - 10:30 1.50 CASE P SURF Flow Check - Pump out from 2710' to HWT 442' - Pump at drlg rate 500 gpm - 10:30 - 11 :30 1.00 CASE P SURF RIH from 442' to 2644' - Precauctionary wash from 2644' to 2710' - No problems 11:30 -13:30 2.00 CASE P SURF CBU 3 X - GPM 510 - PP 2080 - RPM BO - TO 3 k - Flow check 13:30 - 14:30 1.00 CASE P SURF Pump out from 2710' to HWT @ 442' 14:30 - 16:00 1.50 CASE P SURF Stand back 5' HWT - Lay down 8' BHA 16:00 - 16:30 0.50 CASE P SURF Clear rig floor 16:30 - 18:00 1.50 CASE P SURF Rig up casing tools to run 103/4' casing - PJSM 1 B:OO - 21:00 3.00 CASE P SURF Pick up 103/4' shoe joints - Check floats - Con't running 10 3/4' 45.5# L-80 and K-55 casing total of 63 joints to 2657' 21:00 - 21 :30 0.50 CASE P SURF Make up Landing joint and hanger - RIH from 2657' to 2699' land on hanger - Lay down Franks fill up tool - Make up Schlumberger Dowell cementing head and cementing lines - PU 1BO - So 115 21 :30 - 23:30 2.00 CASE P SURF CBU 2 casing volumes condition mud for cement job - PJSM for cementing - Stage up pump rate from 3 BPM to 8 BPM . PP 260 psi 23:30 - 00:00 0.50 CEMT P SURF Give to Schlumberger Pump 5 bbls water Printed: 813012004 9:44:42 AM · BP Qperations Legal Well Name: MPI-14 Common Well Name: MPI-14 Spud Date: 8/2/2004 Event Name: DRILL+COMPLETE Start: 8/1/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/27/2004 Rig Name: DOYON 14 Rig Number: Code NPT Phase 814/2004 23:30 - 00:00 0.50 CEMT P SURF Test lines to 3500 psi Pump 25 bbls water - @ 4 bpm - 200 psi - one gallon dye last 5 bbls pumped Give to Rig - pump 30 bbls treated water Schlumberger pump 20 bbls CW-100 - @ 5 bpm - 300 psi 75 bbls Mud Push mixed at 10.3 ppg - @ 4.5 bpm - 210 psi - Drop bottom plug last 5 bbls pumped 8/5/2004 00:00 - 02;00 2.00 CEMT P SURF Mix and pump 250 bbls 'ASL' @ 10.7 ppg - Yield 4.44 cf/sx cement - @ 6 bpm - 350 psi - Dye back after pumping 240 bbls Mix and pump 54 bbls Class G cement @ 15.8 ppg - Yield 1.17 cflsx cement - @ 3 bpm - 300 psi Drop top plug Pump 30 bbls water - @ 6 bpm - 230 psi Give to rig - Displaced with mud 219 bbls - @ 7 bpm - 300 psi - Cement back to surface after displacing 153 bbls Bump plug with 1500 psi - Hold for 3 mins - Bleed off - Floats holding - CIP @ 02:00 hrs - Total cement back 96 bbls 02:00 - 03:00 1.00 CASE P SURF Flush Annular / riser - Rig down cementing lines - Cement head - Lay down Landing joint 03:00 - 04:00 1.00 CASE P SURF Clear rig floor of cementing equipment - Casing tools - 04:00 - 05:00 1.00 CASE P SURF Nipple down Divertor System 05:00 - 06:00 1.00 CASE P SURF Nipple up FMC metal to metal seal well head - test to 1000 psi for 10 mins - 06:00 - 09:00 3.00 CASE P SURF Nipple up BOP's 09:00 - 10:00 1.00 CASE P SURF Install test plug· Rig up test equipment 10:00 - 13:30 3.50 CASE P SURF Test BOP's - Test Annular to 250 low - 2500 high for 5 mins each test - Test Rams - Choke manifold - Manual Kill / Choke valves - HCR Kill / Choke valves - (HCR Choke valve failed low test) - Upper / Lower IBOP - Floor safety valves - 250 low - 3500 high 5 mins each test - Perform Accumulator test - Lou Grimaldi with AOGCC witness testing of BOP's - Derrick inspection performed 13:30 - 16:00 2.50 CASE N RREP SURF Change out Choke HCR valve 16:00 - 16:30 0.50 CASE P SURF Test Choke HCR to 250 low 3500 high for 5 mins each test- Test choke line on same test - Test good 16:30 - 17:00 0.50 CASE P SURF Rig down testing equipment - Pull test plug - Install long bowl protector - Close annulus valves 17:00 - 18:00 1.00 CASE P SURF Rig up test recorder - Close Blind rams - Test casing to 2000 psi for 30 mins record on chart - Test good - Rig down test equipment 18:00 - 20:00 2.00 CASE P SURF Make up 9 7/8' BHA - Orient - Pick up 61/2' flex DC's- Surface test MWD 20;00 - 20:30 0.50 CASE P SURF RIH to 2614' - tag float collar - Fill pipe every 25 stands 20:30 - 21:00 0.50 DRILL P SURF Drill float equipment from 2614' to 2699' - Clean out 10' rat hole from 2699' to 2710' 21 :00 - 22:00 1.00 DRILL P SURF Circulate out cement - Displace to 8.9 ppg mud 22:00 - 22:30 0.50 DRILL P INT1 Drill from 2710' to 2730' 22:30 - 23:30 1.00 CASE P SURF CBU - Condition mud for FIT - GPM 500- PP 1425 - RPM 60- Rig up to FIT 23:30 - 00:00 0.50 EV AL P SURF Perform FIT - 2699' MD - 2286' TVD - Mud weight 8.9 - Surface pressure 310 = EMW 11.5 8/6/2004 00:00 - 00;30 0.50 CASE P SURF Rig down test equipment - SPR on pumps Printed: 8/30/2004 9:44:42 AM . BP Operations Summa Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Code NPT Phase 8/612004 00:30 - 16:00 15.50 DRILL P INTi 16:00 - 17:30 1.50 DRILL P INT1 17:30 - 19:30 2.00 DRILL P INT1 19:30 - 20:00 0.50 DRILL P INT1 20:00 - 21:00 1.00 DRILL P INT1 21:00-21:30 0.50 DRILL P INT1 21 :30 - 00:00 2.50 DRILL P INT1 8/7/2004 00:00 - 10:00 10.00 DRILL P INTi 10:00 - 11:00 1.00 EVAL N DPRB INT1 11:00 - 00:00 13.00 DRILL P INT1 8/8/2004 00:00 - 07:00 7.00 DRILL P INn 07:00 - 09:00 2.00 CASE P INT1 09:00 - 11:00 2.00 CASE P INT1 11 :00 - 11 :30 0.50 CASE P INT1 11 :30 - 12:30 1.00 CASE P INTi 12:30 - 15:00 2.50 CASE P INn 15:00-18:00 3.00 CASE P INT1 18:00 - 18:30 0.50 CASE P INTi 18:30 - 19:00 0.50 CASE P INT1 19:00 - 20:00 1.00 CASE P INTi 20:00 - 22:00 2.00 CASE P INTi 22:00 - 00:00 2.00 CASE P INn 8/9/2004 00:00 - 01 :00 1.00 CASE P INT1 01:00 - 01 :30 0.50 CASE P INTi 01 :30 . 05:30 4.00 CASE P INT1 05:30 - 06:00 0.50 CASE P INT1 Page 3 of11 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: . ion of Operations Directional Drill from 2730' to 5046' - WOB 15 to 30 - RPM 80- TO on 7 - off 5 - GPM 502 - PP on 2040 - off 1710 - PU 120- SO 80 - ROT 100 CBU 3 X - GPM 502 - PP 1750 Pump to shoe from 5046' to 2636' - No Problems - Pump out at drfg rate CBU at shoe - GPM 502 - PP 1450 - Thick mud - Lots of cuttings - some clay balls - lost + 35 bbls over shakers Cut drfg line - Rig service - Top drive service RIH from 2636' to 4951' - Precauctionary wash from 4951' to 5046' - No problems Directional Drill from 5046' to 5335' - WOB 15 to 20 - RPM 80 - TO on 7k - off 5k - GPM 508 - PP on 2070 - off 1870 - PU 130- SO 78 - ROT 100 Directional Drill from 5335' to 6390' - WOB 15 to 25 - RPM 80 - TO on 8 - off 6.5 - GPM 502 - PP on 2330 - off 2020 - PU 140- SO 82· ROT 105 MWD not getting good detection - Mad Pass from 6295' to 6390' Directional Drill from 6390' to 7256' - WOB 15 to 25· RPM 80- TO on 10 - off 7 - GPM 502 - PP on 2800 - off 2550 - PU 145- SO 80 - ROT 105 - From 7100' to 7256' - Detection not good - Mad pass required on each connection - Top NA sand 6772' MD 3768' TVD - Base NA sand 6868' MD 3802' TVD - Top of Window for NB sand 6821' MD Directional Drill from 7256' to 7625' - TD 9 7/8" hole - WOB 15 to 30 - RPM 80 - TO on 10 - off 7 - GPM 529 - PP on 2650 - off 2300 . PU 145 - SO 80 - ROT 105 - From 7256' to 7625' Detection not good - Mad pass required on each connection - Top OA sand 7331'· TVD 3929' CBU 3 X RPM 100 - TO 7K - GPM 502 - PP 2530 Pump out to from 7625' to last short trip depth @ 5000' at drfg rate 500 gpm CBU - GPM 500 - PP 2220 RIH from 5000' to 7545' - Precauctionary wash from 7545' to 7625' CBU 3 X - RPM 100 - TO 7K - GPM 502 - PP 2500 Pump out from 7625' to shoe @ 2650' - Pump at drlg rate 500 gpm CBU @ shoe - Flow check - Pump dry job POH to BHA Lay down 5" HWT - BHA Pull wear ring - Install test plug· Change DP rams to Casing rams . Test door seals to 1500 psi - Pull test plug - RIg up casing tools - PJSM Pick up float equipment· check floats - Con't RIH with 75/8" casing @ 1100' Con't running 7 5/8" 29.7# L-80 BTC-M casing to 2697' Circulate casing volume 124 bbls / 1241 strokes - 6 bpm @ 340 psi Con't running 7 5/8" casing to 7581' - Make up landing joint / hanger - RIH land casing at 7618' Rig down Franks fill up tool - Make up Dowell Schlumberger Printed: 613012004 9:44:42 AM · Operations Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 of 11 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: Code NPT 8/9/2004 05:30 - 06:00 0.50 CASE P INT1 06:00 - 10:00 4.00 CASE P INT1 10:00 - 12:00 2.00 CEMT P INT1 12:00 - 14:00 2.00 CASE P INT1 14:00 - 14:30 0.50 CASE P INT1 14:30·16:30 2.00 CASE P INT1 16:30 - 18:00 1.50 CASE P INT1 18:00 - 20:00 2.00 CASE P INT1 20:00 . 21 :00 1.00 CASE P INT1 21 :00 - 21 :30 0.50 DRILL P INT1 21 :30 - 22:30 1.00 CASE P INn 22:30 - 23:00 0.50 EVAL P INT1 23:00 - 00:00 1.00 DRILL P PROD1 8/10/2004 00:00 - 07:30 7.50 DRILL P PROD1 07:30 - 08:30 1.00 STKOH P PROD1 08:30 - 09:30 1.00 STKOH P PROD1 09:30 - 10:00 0.50 STKOH P PROD1 10:00 - 00:00 14.00 DRILL P PROD1 cementing head - Cementing lines Reciprocate string while circulating - Circulate condition mud for cement job - Stage up pump from 4 bpm to 6 bpm - ICP 420 - FCP 250 - PU 250 . SO 85 Give to Dowell Schlumberger Pump 5 bbls water Test lines to 4000 psi Pump 25 bbls CW-100 - 4.5 bpm @ 380 psi Pump 45 bbls Alpha spacer mixed at 10.3 ppg - 4 bpm @ 350 psi Drop bottom plug Mix and pump 155 bbls Class "G" yield 1.16 cf/sx 750 sxs at 15.8 ppg - 5.6 bpm @ 580 psi Drop top plug Displace with 354 bbls oil base mud - 6 bpm @ 400 psi - Slow to 3 bpm last 16 bbls pumped @ 800 psi· (stopped reciprocating string after 165 bbls displaced due to increase of drag up from 270 to 325 and decrease in slack off from 95 to 70) Bump plug with 1800 psi - 1000 psi over circulating pressure Bleed off pressure· Floats holding - CIP 12:00 hrs Rig down Dowell cementing head and cementing lines - Flush BOP stack - Blow down lines - Blow oil base mud out of landing joint - Lay down landing joint· lay down casg elevators - long bails - clear rig floor Install FMC pack-off· Test to 5K for 10 mins - Test good Install test plug - Change casing rams back to pipe rams - Test to 250 low - 3500 high for 5 mins each test - Pull test plug - Install wear ring - close annulus valves Make up BHA - Orient - Surface test MWD RIH - Tag up 7530' Break CIrculation - Test casing to 2500 psi for 30 mins - record on chart Drill shoe track from 7530' to 7618' ,. Drill 20' new hole from 7625' to 7645' Circulate hole clean for FIT - Pump 5903 stks 588 bbls to clean upwell Perform FIT· Mud weight 9.05 ppg - MD 7618' - TVD 3996- Surface pressure 510 psi = EMW 11.51 ppg Directional Drill 6 314" OB Lateral from 7645' to 7659' - WOB 0 to 5 - RPM 85 . TO on 4 - off 3.5 - GPM 251 - PP on 2430 . off 2320 - PU 125· SO 82 - ROT 101 Directional Drill from 7659' to 8427' - WOB 0 to 5 - RPM 80 - TO on 5 - off 4 - GPM 250 - PP on 2640 - off 2480 - PU 124- SO 75- ROT 96· Went out bottom of pay @ 7760' - Drilling ahead looking for OB Sand Circulate - Conference call with town - RPM 80 Tq 4K - GPM 250 - PP 2480 Pump out @ drilling rate to 7700' for open hole sidetrack # 1 in OB Lateral Cut trough from 7700' to 7720' for sidetrack # 1 in OB Lateral Open hole side track # 1 . Directional Drill from 7700' to 9290' - woe 0 to 5 - RPM 80 - TO on 5 - off 4 - GPM 250 - pp on Printed: 8/3012004 9:44:42 AM · Page 5 of 11 Legal Well Name: MPI-14 Common Well Name: MPI-14 Spud Date: 8/2/2004 Event Name: DRILL+COMPLETE Start: 8/1/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/27/2004 Rig Name: DOYON 14 Rig Number: Date Code NPT 8/10/2004 10:00 - 00:00 14.00 DRILL P PROD1 2990 - off 2770 - PU 135 - SO 50 - ROT 95 - Went out bottom of pay @ B637' - Drilling ahead looking for OB sand B/11/2004 00:00 - 01 :00 1.00 DRILL P PROD1 Directional Drill from 9290' to 9450' - WOB 0 to 5 - RPM 80 - TO on 5 - off 4 - GPM 251 - PP on 2990 - off 2770 - PU 135- SO 50 - ROT 95 - Drilling ahead looking for OB sand 01 :00 - 01 :30 0.50 STKOH P PROD1 Circulate - for trip out to open hole side track # 2 in OB Lateral 01 :30 - 02:30 1.00 STKOH P PROD1 Pump out to B32B' at drlg rate 02:30 - 03:00 0.50 STKOH P PROD1 Cutting trough 8328' to 8340' for open hole sidetrack # 2 in OB Lateral 03:00 - 05:30 2.50 DRILL P PROD1 Open hole side track # 2 . B340' time drill to 8360' - COuld not get side tracked started - Move to new location - Cut trough from B360' to B375' 05:30 - 06:00 0.50 DRILL P PROD1 Time drill from B375' to B400' 06:00 - 18:00 12.00 DRILL P PROD1 Directional Drill from 8400' to 9863' - TD OB Lateral - WOB 0 to 5 - RPM BO - TO on 7 - off 5 - GPM 251 - PP on 2725 - off 2550 - PU 145 - SO 65 - ROT 100 18:00 - 20:30 2.50 DRILL P PROD1 CBU 3 X - GPM 250 - PP 2740 - RPM B5 - TO 5 20:30 - 23:00 2.50 DRILL P PROD1 Pump out from 9B63' to 7900' - Pump at drlg rate - Work sidetrack at B375 - Back ream through it work string across it - Run check shot below it all ok - 7900' hole packing off - Pull from 7900' to 7600' without pump - 23:00 - 00:00 1.00 DRILL P PROD1 CBU 2 X - very little cuttings circulated out - GPM 250 - RPM 80 - PP 2700 psi 8/1212004 00:00 - 00:30 0.50 CASE P PROD1 Circulate hole clean - GPM 250 - PP 2700 00:30 - 01 :30 1.00 CASE P PROD1 Rig Service 01 :30 - 05:30 4.00 CASE P PROD1 RIH to 7700 - Taking weight - Pick up orient to low side - RIH from 7700 to 8427' - Taking weight - Pick up run survey @ 8425' 102 angle - In old hole - Pull back to 7700' orient to straight low side· RIH to B450 taking weight - Pick up to B425' - Run survey - orginal hole 102 degrees - redrill hole 92 degrees - Check shot 91.6 - Con't RIH washing and reaming from 8425' to B500' - Con't RIH from 8500' to 94B2' - Taking weight - Wash from 9482' to 9863' 05:30 - OB:oo 2.50 CASE P PROD1 CBU 3 X - Clean up hole - GPM 254 - PP 2700 - RPM 80 - TO 5K OB:OO - 12:30 4.50 CASE P PROD1 Flow check - Well static - Pump ou1 at drill rate - Ream across side tracks 8375' and 7720' serveral times to insure we can get back into new holes· Con't pump to shoe - CBU at shoe 12:30 - 13:30 1.00 CASE P PROD1 RIH - No problems 13:30 - 16:00 2.50 CASE P PROD1 CBU 3 X - GPM 254 - PP 2700 - RPM 80 - TO 5 K 16:00 - 17:30 1.50 CASE P PROD1 Flow check - Well static - Pump to shoe at drlg rate from 9863' to 761 B' Pump at drlg rate - No Problems 17:30 - 18:30 1.00 CASE P PROD1 CBU - Flow check - Well static 18:30 - 20:30 2.00 CASE P PROD1 POOH from 7618' to 524B' - Hole fill discrepancy - flow check - well static 20:30 . 22:00 1.50 CASE P PROD1 RIH to shoe7618' - Lost 6 bbls on trip in 22:00 . 22:30 0.50 CASE P PROD1 CBU - Flow check - Well static 22:30 - 00:00 1.50 CASE P PROD1 POH from 7618' to 7600' - Well swabbing - Pump out from 7600' to 617B' - Pump at 3 bpm B/13/2004 00:00 - 04:00 4.00 CASE P PROD1 Pump out from 617B' to 1250' BHA - Hole swabbing - Con't POH without pump from 1250' to 268' BHA 04:00 - 05:00 1.00 CASE P PROD1 Stand back BHA - Down load MWD - break bit - flush motor - 05:00 - 05:30 0.50 CASE P PROD1 Clear rig floor Printed: 813012004 9:44:42 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 8/13/2004 05:30 - 06:30 1.00 CASE P 06:30 . 09:00 2.50 CASE P 09:00 - 14:30 5.50 CASE P 14:30 - 15:30 1.00 CASE P Page 6 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: PROD1 Rig up casing tools to run 41/2" Slotted liner PROD1 Pick up 41/2" Slotted liner - Make up Baker Hanger / ZXP top packer PROD1 Run 41/2" slotted liner in hole on 4" DP PROD1 Tag bottom @ 9863' - Drop ball pump same down @ 4 bpm at 740 psi - Pressue up to 2000 psi - Slack off to 60K . Verify hanger set - Bleed psi to zero - Pressure up to 3000 psi - Stage up pressure to 5000 psi - No Indication of ZXP shear - Bleed off pressure to zero - Close Hydril - Pump down kill line - Pressure up annulus to 1500 psi - Good test - Bleed off pressure - Open Hydril - Rotate 15 tums to right with 5K TO - Pressure up to 500 psi - Pick up to 10' -Loss 500 psi - Pick up weight 10K less Clear rig floor - Monitor well- Well static POH from 7455' to 7425' hole swabbing - Pump out with 4 bpm from 7425' to Baker running tool Change out handling equipment to 3.5" - Service break running tool - Retrieve ball from ball seat Clean rig floor Moblize Milling BHA assembly to rig floor Pick up 3 1/2" HWT - 4 3/4" Drill collars - Stand back in derrick Make up Whipstock assembly RIH with whipstock assembly - Fill every 25 stds Broke circulation and oriented whipstock 25 degrees left of high side. Set BTM anchor. Picked up to assure anchor was latched. Set down and sheared off disconnect bolt. Milled window from 7324' to 7336'. Exited slide at 7336' and milled formation to 7347'. WOM 3K, 100 RPM, 7-8K ftlbs, 275 gpm at 1860 psi. Pumped sweep to help clean hole. Pump sweep and circulated 2 bottoms up. Reciprocated and rotated through window with 6K ftlbs torque at 1860 psi with 275 gpm. Monitor well. Pulled out of hole and laid down milling assembly. Stand back 31/2" HWP and 4 3/4" spiral DC's in mast - LD down MWD - Bumper jars - Mills Clean· clear floor Flush stack - Activate rams· Flush stack MU BHA - RIH with 4 3/4" Flex DC's - Jars - Surface test MWD - Good test RIH for 267' - to 7276' - fill DP @ 2663',5066',7276. Cut drlg line - Top drive service - Rig service Orient 10 degrees left of high side - side through window without pumping or rotating Directional Drill from 7347' to 7466' - WOB 5 . RPM (sliding) - TO on NA - off 5K - GPM 250- PP on 2300 - off 2170 - PU 130 - SO 85 - ROT 105 - ABI failed - POH for new Motor Circ to clear BHA - Pump out from 7466' to 7372' - Shut down pump - Pull through window from 7372' to 7276' - CBU - RPM 40 - TO 5K - GPM 250 @ 2200 psi - Flow check - Well Static POH for new Motor - From 7267' to 1034 POH from 1034' to 269' @ HWT Stand back BHA - Change out motor· Surface test @ 255 gpm - @ 1300 psi 15:30-16:00 0.50 CASE P PROD1 16:00 - 21 :30 5.50 CASE P PROD1 21 :30 - 22:00 0.50 CASE P PROD1 22:00 - 22:30 0.50 CASE P PROD1 22:30 - 23:00 0.50 STWHIP P PROD2 23:00 - 00:00 1.00 STWHIP P PROD2 8/14/2004 00:00 - 02:00 2.00 STWHIP P PROD2 02:00 - 05:30 3.50 STWHIP P PROD2 05:30 - 06:00 0.50 STWHIP P PROD2 06:00 - 08:00 2.00 STWHIP P PROD2 08:00 - 09:30 1.50 STWHIP P PROD2 09:30 - 12:00 2.50 STWHIP P PROD2 12:00 - 13:00 1.00 STWHIP P PROD2 13:00 - 13:30 0.50 STWHIP P PROD2 13:30 - 14:00 0.50 STWHIP P PROD2 14:00 - 15:00 1.00 STWHIP P PROD2 15:00 - 17:30 2.50 STWHIP P PROD2 17:30 - 19:00 1.50 STWHIP P PROD2 19:00 . 20:30 1.50 STWHIP P PROD2 20:30 - 21 :00 0.50 DRILL P PROD2 21:00 - 22:00 1.00 DRILL N DFAL PROD2 22:00 - 00:00 2.00 DRILL N DFAL PROD2 8/15/2004 00:00 - 00:30 0.50 DRILL N DFAL PROD2 00:30 - 01 :30 1.00 DRILL N DFAL PROD2 Printed: 813012004 9:44:42 AM · Page 7 of 11 Legal Well Name: MPI-14 Common Well Name: MPI-14 Spud Date: 8/2/2004 Event Name: DRILL+COMPLETE Start: 8/1/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/27/2004 Rig Name: DOYON 14 Rig Number: Date 8/15/2004 01 :30 - 04:30 3.00 DRILL N DFAL PROD2 RIH from 269' to 7285' - Fill pipe every 25 stds - Orient bit left of high side - RIH - to 7467' 04:30 - 17:30 13.00 DRILL P PROD2 Directional Drill from 7467' to 8825' - WOB 5 - RPM 80 - TO on 5.5 - off 4.5 - GPM 254 - PP on 2520 - off 2420- PU 140 - SO 70 - ROT 100 17:30 - 20:30 3.00 DRILL P PROD2 CBU 4 X - Circulate hole clean for short trip to shoe - Flow check - Well Static 20:30 - 23:00 2.50 DRILL P PROD2 Pump out from 8825' to 7367' - Tight packing off @ 8150' to 8080' - 7980' to 7939' - 7783' to 7767' - 7645' to 7625' - Pull with out pump through window from 7367' to 7272' - Pump out at drlg rate 23:00 - 00:00 1.00 DRILL P PROD2 CBU at shoe - GPM 250 - PP 2240 - RPM 80 - TO 5K - Lots of cuttings back - Lots of fine sand with cuttings 8/16/2004 00:00 - 00:30 0.50 DRILL P PROD2 Con't circulate hole clean - service rig / top drive - 5822 total stks to clean hole from 7272' - Orient to high side 00:30 - 01 :30 1.00 DRILL P PROD2 RIH from 7272' to 8730' - Precauctionary wash from 8730' to 8825' 01 :30 - 12:30 11.00 DRILL P PROD2 Directional Drill from 8825' to 9910' - TD OA Lateral - WOB 5 - r- RPM 80 - TO 7 - off 6 - GPM 254 - PP on 2600 - off 2480 - PU 140 - SO 85 - ROT 105 12:30 - 15:30 3.00 CASE P PROD2 CBU 3 X - RPM 80 - TO 5K - GPM 254 - PP 2480 - Flow check - Well Static 15:30 - 19:00 3.50 CASE P PROD2 Pump out from 9910' to 9100' - Pump at drlg rate - Back ream from 9100' to 7374' - Some light packing off seen through 9300' to 9100' - Pull through window without pump from 7374' to 7278' 19:00 - 20:00 1.00 CASE P PROD2 CBU - GPM 254 - PP 2250 - RPM 80 - TO 5K - Lots of cuttings with fine sand over shakers - Flow check - Well static 20:00 . 21:00 1.00 CASE P PROD2 RIH from 7278' to 9815' - Precauctionary wash from 9815' to 9910' 21:00 . 23:30 2.50 CASE P PROD2 CBU 3 X - RPM 80 - TO 5K - GPM 254 - PP 2480 - Flow check - Well Static 23:30 - 00:00 0.50 CASE P PROD2 Pump to shoe from 9910' to 9198' - Pump at drlg rate 8/17/2004 00:00 - 02:00 2.00 CASE P PROD2 Pump out to shoe from 9198' to 7368' - Pump at drlg rate - shut down pump - Pull through window· from 7368' to 7272' - No Problems on trip out 02:00 - 04:00 2.00 CASE P PROD2 CBU - Pump sweep - Pump Versa sweep to thin mud to pull whipstock - GPM 254- RPM 80 - TO 5K - 4500 strokes to clean up hole 04:00 - 06:30 2.50 CASE P PROD2 POH for whipstock retrieving tool from 7272' 06:30 - 07:30 1.00 CASE P PROD2 Stand back BHA 07:30 - 09:00 1.50 CASE P PROD2 Clear floor,Make up whipstock retrival BHA, surface test MWD 09:00 - 11:00 2.00 CASE P PROD2 Trip in to 7330 11:00 - 12:00 1.00 CASE P PROD2 Orient and hook, whipstock pull free with 240K 12:00 - 13:00 1.00 CASE P PROD2 Circ bottoms up with 263 Gals min 1850 psi 13:00 - 17:00 4.00 CASE P PROD2 POH, pulled at reduced rate fl swabbing, hole fill was 10 Bbls short 17:00 - 19:30 2.50 CASE P PROD2 Stand back 3 1/2 pipe and 4 3/4 dc, lay down whipstock and tail pipe assembly 19:30 - 20:00 0.50 CASE P PROD2 Clean floor of tail pipe jewelery 20:00 - 20:30 0.50 CASE P PROD2 Monitor well, flowing 1 to 1 1/2 bbls hr. 20:30 - 23:30 3.00 CASE N DPRB PROD2 Pick up Johnny Wacker, and float sub, Tripping in to 7,470' with drill pipe, fill pipe 2400,4800,7400, install TIW valve one Printed: 8/3012004 9:44:42 AM · BP Legal Well Name: MPI-14 Common Well Name: MPI-14 Spud Date: 8/2/2004 Event Name: DRILL+COMPLETE Start: 8/1/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/27/2004 Rig Name: DOYON 14 Rig Number: Date From· To Höürs Phase 8/17/2004 20:30 . 23:30 3.00 CASE N DPRB PROD2 jt. down, gained 8 bbls over calculated displacement on trip in. 23:30 - 00:00 0.50 CASE N DPRB PROD2 Circ, got gas to sUrface Immediately, mud cut to 8.5 8/18/2004 00:00 - 03:00 3.00 CASE N DPRB PROD2 Circ, Condition mud, raise mud wt to 9.2, lots of gas on bottoms, some crude oil 03:00 - 03:30 0.50 CASE N DPRB PROD2 Monitor well, well dead 03:30 - 04:30 1.00 CASE P PROD2 Slip and cut drill line 04:30 - 08:00 3.50 CASE N DPRB PROD2 POH 08:00 - 09:00 1.00 CASE P PROD2 Clear floor, Rig up to Pickup 4 1/2 Slotted Liner, PJSM 09:00 - 11 :00 2.00 CASE P PROD2 Picking up 41/2 Slotted liner and Baker Hook wall hanger, Total of 44 its Slotted, 17 its solid 11:00 - 15:30 4.50 CASE P PROD2 Tripping in with Liner, Took three attempts to exit window, liner wt @ 7324' window P/U 120K, S/O 90K, liner wt on bottom P/u 135k,S/0 85K, Shoe @ 9884', top of hook wall hanger 7319' 15:30 - 16:00 0.50 CASE P PROD2 Hook liner @ 7324', unhooked liner and went pass window, pull back and re hooked 16:00 - 17:00 1.00 CASE P PROD2 Drop ball pumped down @ 127 gpm 530 psi, pressure up to 3000psi to release from liner, pulled up to 7290' to verify release, lost 10k pickup wt., pressure up to 4,000 psi with test pump to shear ball 17:00 - 18:30 1.50 CASE P PROD2 Circ bottoms up 254gpm 1080 psi, flow check well, hole static 18:30 - 22:00 3.50 CASE P PROD2 POH with running tools, lay down same, clear floor 22:00 - 23:00 1.00 CASE P PROD2 Rig up to test, pull wear ring 23:00 - 23:30 0.50 CASE P PROD2 Test Bops and manifold 250psi-3500psi per test,S min. per test, test HydriI250-2500psi, 5 min per test., the right to witness test was wavied by Chuck Scheve AOOGC., Hcr valve on choke line failed on high test. 23:30 - 00:00 0.50 CASE N RREP PROD2 Removing HCR valve 8/19/2004 00;00 - 01 :30 1.50 CASE N RREP PROD2 Change out HCR valve 01 ;30 - 04:30 3.00 CASE P PROD2 Finish testing Bops and manifold 25Opsi-3500psi per test, 5 min. per test, test Hydril 250-2500psi, 5 min per test., the right to witness test was wavier by Chuck Scheve AOOGC. 04;30 - 05:00 0.50 CASE PROD2 Install wear ring 05:00 - 05:30 0.50 CASE P PROD2 Rig up to pickup LEM, PJSM 05:30 - 06;30 1.00 CASE P PROD2 Picking up Seal Assy, 3 its 4.512.6# L-80 Tubing, LEM, Baker seal bore extension, Baker ZXP liner top packer 06:30 - 10:30 4.00 CASE P PROD2 Tripping in with LEM. PU 125K SO 90K 10:30 - 12:00 1.50 CASE P PROD2 Latch LEM, @ 7321 Picked up with 10K over pickup to confirm latch,drop ball pump down 2 bpm 280 psi, pressure up to 4,000 psi to set ZXP packer and release LEM, Test annulus to 2500psi for 15 min., stand back 1 stand, rigged up and shear ball with First Energy pressure to 5200 psi to shear ball, P/U 95K top of liner tie back @ 7265'. 12:00 - 13;30 1.50 CASE P PROD2 Circ bottoms up 250 gpm, 1140 psi 13:30 - 17:00 3.50 CASE P PROD2 Tripping out, hole swabbing, pumped out to 3350', pull out from 3350 to surface, lay down running tools 17;00 - 20:00 3.00 STWHIP P PROD3 Picking up whipstock, space out pipe. and Bha, surface test MWD 20;00 - 00:00 4.00 STWHIP P PROD3 Tripping in with whipstock to 7158' 8/20/2004 00:00 - 00:30 0.50 STWHIP P PROD3 Orient whipstock to 18 degrees to left, set whipstock with 15K down,shear of whipstock with 35K down, had to make 5 attempts to shear 00:30 - 03;00 2.50 STWHIP P PROD3 Mill window with 279 gals min. 2100 psi, 80-100 rpms, top of window 6814', bottom window, 6826', TD 6839' Printed: 813012004 9:44:42 AM · BP Legal Well Name: MPI-14 Common Well Name: MPI-14 Spud Date: 8/212004 Event Name: DRILL+COMPLETE Start: 8/1/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/27/2004 Rig Name: DOYON 14 Rig Number: Date From"; To H 8/20/2004 03:00 - 04:30 1.50 STWHIP P PROD3 Circ, Pump sweep, work window 70 rpms, 273 gals min, 2100 psi 04:30 - 07:00 2.50 STWHIP P PROD3 Flow check, POH 07:00 - 07:30 0.50 STWHIP P PROD3 Stand back BHA 07:30 - 08:00 0.50 STWHIP P PROD3 Picked up stack washer, flush BOP stack 08:00 - 09:30 1.50 STWHIP P PROD3 Pick up BHA # 9 09:30 - 12:00 2.50 STWHIP P PROD3 Trip in to 6700' 12:00 - 13:30 1.50 STWHIP P PROD3 Cut and slip drilling line, service top drive 13:30 - 14:00 0.50 STWHIP P PROD3 Orient and slide thru window @ 6814' 14:00 - 20:00 6.00 DRILL P PROD3 Drill from 6838' to 7390' with 3K bit wt. 80 rpms, 2600 psi, 254 gpm., out of sand @ 7214' to 7390' 20:00 - 20:30 0.50 DRILL P PROD3 Circ for side track, Poh to 6986' 20:30 - 21 :30 1.00 DRILL P PROD3 Perform openhole side track @ 7020', trough 6986' to 7020' 21 :30 - 22:30 1.00 DRILL P PROD3 Time Drill from 7020 to 77063' 22:30 - 00:00 1.50 DRILL P PROD3 Drill from 7063' to 7227' with 3K bit wt. 80 rpms, 2600 psi, 254 gpm. out of sand from 7069' to 7170', AST 3.12, ART 2.15 8/21/2004 00:00 - 11 :00 11.00 DRILL P PROD3 Drill from 7227' to 8331' with 3K bit wt. 80 rpms, 2800 psi, 254 gpm. 11 :00 - 13:30 2.50 DRILL P PROD3 Circ, @ bottoms up with 80 rpms, 263gpm, 2850 psi 13:30 - 14:30 1.00 DRILL P PROD3 Pump out to window with full drilling rate, back ream 35 rpms, pull thru window with out pumping, work side track spot @ 7020', 14:30 - 15:00 0.50 DRILL P PROD3 Monitor well, service top drive 15:00 - 16:00 1.00 DRILL P PROD3 Circ bottoms up 263 gpm, 2570 psi, 35 rpms 16:00 - 17:00 1.00 DRILL P PROD3 Trip to bottom, @ 8331, wash last stand to bottom 17:00 - 00:00 7.00 DRILL P PROD3 Drill from 8331' to 9004' with 3K bit wt. 80 rpms, 3000 psi, 254 gpm., AST 5.1, ART 4.8, TQ 5K 8/22/2004 00:00 - 07:30 7.50 DRILL P PROD3 Drill from 9004' to 9595' with 3K bit wt. 80 rpms, 3100 psi, 275 gpm., out of sand @ 8822' 07:30 - 08:00 0.50 DRILL P PROD3 Circ for side track 08:00 - 08:30 0.50 DRILL P PROD3 Pump out to 9006', at full drilling rate 08:30 - 09:00 0.50 DRILL P PROD3 Orient and Trench hole 9013 to 9023' for low side side track 09:00 - 18:00 9.00 DRILL P PROD3 Drilling from 9024' to 9768' TD with 80 rpms, 3100 psi, 275 gal per min. out of sand 9225 to 9450, back in to sand 9450 to 9688, out of sand 9688 to 9768TD 18:00 - 21 :30 3.50 CASE P PROD3 Circ four bottoms up with 263 gpm.,2900 psi,80 rpms 21 :30 - 00:00 2.50 CASE P PROD3 Pumping out of hole with full drilling rate, 30 rpms, Hole tight, pulling 20 to 25K,over and torque, from 9450 to 9000, pulled slow. 8/23/2004 00:00 - 01 :30 1.50 CASE P PROD3 Pumping out to 6900 with full drilling rate, 30 rpms, pulled in to window with out pumping or rotating 01 :30 - 02:00 0.50 CASE P PROD3 Circ bottoms up @ 6800' 02:00 - 02:30 0.50 CASE P PROD3 Service Top drive 02:30 - 04:00 1.50 CASE P PROD3 RIH to 9768, wash last stand to bottom, went thru both sidetracks, no problems 04:00 - 09:00 5.00 CASE P PROD3 Circ, Three bottoms up with 263 gpm, 2900 psi, 80 rpms, 09:00 - 10:30 1.50 CASE P PROD3 Displace with new 9.2 Oil base mud, monitor well 10:30 - 11 :30 1.00 CASE P PROD3 Pumping out of hole with full drilling rate, 9768 to 8525' 11 :30 - 13:00 1.50 CASE N RREP PROD3 Change out saver sub on topdrive, circ thru cement line 13:00 - 14:30 1.50 CASE P PROD3 Pumping out of hole with full drilling rate, 8525 to 6892', pull thru window with out pumping to 6764' 14:30 - 15:30 1.00 CASE P PROD3 Circ and rotate 35rpms, 260 gpm. 2300psi, raise mud wt to 9.4 15:30· 18:00 2.50 CASE P PROD3 Poh to Bha Printed: 813012004 9:44:42 AM . . Legal Well Name: MPI-14 Common Well Name: MPI-14 Spud Date: 8/2/2004 Event Name: DRILL+COMPLETE Start: 8/1/2004 End: Contractor Name: DOYON DRILLING INC. Rig Release: 8/27/2004 Rig Name: DOYON 14 Rig Number: Date Frorn- To 8/23/2004 18:00 - 19:30 1.50 CASE P PROD3 Stand back SHA. lay down,Motor, Clear floor 19:30 - 20:00 0.50 CASE P PROD3 Download MDW 20:00 - 21 :30 1.50 CASE P PROD3 Picking up whip stock retrieval SHA, surface test MWD 21 :30 - 23:30 2.00 CASE P PROD3 Tripping in with whipstock hook to 6781' 23:30 - 00:00 0.50 CASE P PROD3 Orient 20 degree to left, hook whip stock, jar free after 2 trys. pull to 8781, monitor, well static. 8/24/2004 00:00 - 00:30 0.50 CASE P PROD3 Circ bottoms up @ 6871, no gas cut mud on bottoms up 00:30 - 01 :00 0.50 CASE P PROD3 Monitor well, well static 01:00 - 04:00 3.00 CASE P PROD3 Poh with whipstock 04:00 - 06:00 2.00 CASE P PROD3 Laying down whipstock, and space out pipe 06:00 - 08:00 2.00 CASE P PROD3 Clear floor, Load pipe shed with screens, rig up to pickup 4" screen Iiner,PJSM 08:00 - 11 :30 3.50 CASE P PROD3 Picking up 4" liner, Total of 54 jts 4 9.5# L-80 1ST blank pipe, 30 jts 4" C27 Screen pipe, swell packer, hook wall hanger 11 :30 - 20:30 9.00 CASE P PROD3 Tripping in with liner, went thru window first try, went in to side track #1 to 7390, pulled back to 7000' Rotate pipe 1/2 turn, went in right hole. trip in to 9739', We had lots of hanging up of centralizers on window from 7000' ft to 9739', we didn't see sidetrack #2 @ 9020' 20:30 - 21 :00 0.50 CASE P PROD3 Hooked window, on depth, un hook and went pass window, pull back up and rehook window, pick up and un hooked window, went pass window again, picked up and rehooked window, top of hook wall 6809', swell packer 6845', shoe 9739' 21 :00 - 21 :30 0.50 CASE P PROD3 Drop ball, pumped down 127 gpm, 550 psi, pressure up to 2800psi, release liner, lost 10K string, pull up to 6777', shear ball with 4300 psi with test pump, 21 :30 - 22:30 1.00 CASE P PROD3 Circ bottoms up 254 gals min, 1120 psi, monitor well 22:30 - 00:00 1.50 CASE P PROD3 Cut and slip drilling line, service top drive 8/25/2004 00:00 - 03:00 3.00 CASE P PROD3 POH with hook wall running tools, lay down same 03:00 - 03:30 0.50 CASE P PROD3 Rig up to P/U LEM tools, PJSM 03:30 - 05:00 1.50 CASE P PROD3 Picking seals assy, XO jt. 10 jts 4.512.6# L-80 Tubing, LEM,casing swivel,Baker ZXP liner top packer 05:00 - 07:30 2.50 CASE P PROD3 Tripping in with LEM, to 6800' 07:30 - 08:30 1.00 CASE P PROD3 Sting in to hook hanger, Orient Lem ,Locate seal assem. seals, @ 7293, top of LEM 6773' 08:30 - 09:00 0.50 CASE P PROD3 Drop ball, pump to seat @ 3 bbls min. 600 psi, set packer with 3800 ps, release from packer 09:00 - 11:00 2.00 CASE P PROD3 Pull to 6720' shear ball with test pump 5000 psi, circ bottoms up 4 bbls min., 780 psi 11:00 - 13:30 2.50 CASE P PROD3 Trip out with LEM running tools, lay down same 13:30 - 14:00 0.50 CASE P PROD3 clear floor 14:00 - 16:30 2.50 CASE P PROD3 Pick up circ. sub, trip in to 6731 16:30 - 20:30 4.00 CASE P PROD3 Displace well with 9.3 brine, pumped 30 bbls LVT, 25 bbls Viscosified 9.3 brine,30 bbls 9.3 brine w/ safesuf 0, 25 bbls Viscosified 9.3 brine, and 9.3 brine 20:30 - 21 :30 1.00 CASE P PROD3 Monitor well, service Rig 21 :30 - 00:00 2.50 CASE P PROD3 Lay down 4" drill pipe 8/26/2004 00:00 - 02:00 2.00 CASE P PROD3 Finish laying down pipe,out of hole 02:00 . 02:30 0.50 CASE P PROD3 Pull wear ring, rig up to lay down pipe out of derrick 02:30 - 05:00 2.50 CASE P PROD3 Laying down pipe out of derrick in mouse hole 05:00 . 07:00 2.00 RUNCOrvP RUNCMP Rigging up to run Tubing, spot spooling unit, PJSM 07:00 . 10:00 3.00 RUNCOrvP RUNCMP Pick up pump, fill with oil, make up cable, test Printed: 8/3012004 9:44:42 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8/2612004 10:00 - 18:30 18:30 - 21:30 21 :30 - 22:30 8/27/2004 22:30 - 00:00 00:00 - 00:30 00:30 - 02:00 02:00 - 03:30 03:30 - 06:00 06:00 - 07:00 MPI-14 MPI-14 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 8/1/2004 Rig Release: 8/27/2004 Rig Number: Spud Date: 8/2/2004 End: To 8.50 RUNCOfvP 3.00 RUNCOfvP 1.00 RUNCOfvP 1.50 RUNCOfvP 0.50 RUNCOIIIP 1.50 RUNCOIIIP 1.50 RUNCOfvP 2.50 RUNCOfvP 1.00 RUNCOIIIP Description of Operation RUNCMP Picking up 2 7/8 L-80 6.5 1ST tubing, test ever 2,000 ft and fill tubing, to 5673' RUNCMP Splice ESP cable RUNCMP Picking up 2 7/8 L-80 6.5 1ST tubing. test ever 2,000 ft and fill tubing, TD of pump 6398, Top of pump 6342', XN nipple 6321', glm 6170', glm 2167', glm 148', total 199 jts . Lesalle clamps 106 , P/U 83K, S/o 70K, Slocks 50K RUNCMP Test continuity, MIU to ESP hanger penetrator, retest continuity RUNCMP Finish MIU to ESP hanger penetrator. retest continuity RUNCMP Install top Lesalle clamp, land tubing and test Two way check to 1000 psi RUNCMP Nipple down BOPS RUNCMP I Nipple up FMC 11" X 2 9/16 ESP tubing head Adaper and CIW 29/16 5K Tree, Test tree and packoff to 5000 psi RUNCMP Dry rod, TWC valve out, dry rod in SPY, Secure well Rig release for rig move @ 07008/27/2004 Printed: 813012OO4 9:44:42 AM Surface Pressure LeakOffPres~Ure (BHP) EMW 310 (psi 1,367 (psi) 11.51 (ppg) 510 (psi 2,389 (psi) 11.51 (ppg) . . Printed: 8/30/2004 9:44:30 AM AMW 8.90 (ppg) 9.05 (ppg) Test Depth (TMD) TØstDepth (TVD) 2,699.0 (ft) 2,286.0 (ft 7,618.0 (ft) 3,996.0 (ft Legal Name MPI-14 Common Name: MPI-14 Test Date Test Type. 8/5/2004 FIT 8/9/2004 FIT WELL SERVICE REPORT. WELL JOB SCOPE MPI-14 NEW WELL POST DATE DAILY WORK 8/28/2004 FREEZE PROT AFE KEY PERSON MSD337396 FESCO-ANDERSON MINID 0" I DEPTH OFT UN I. FESCO 367 DAY SUPV CUBBON NIGHT SUPV CUBBON TTL SIZE 0" DAILY SUMMARY ( Freeze Protect) Freeze Protect TBG With 15 BBLS Diesel, Freeze Protect IA With 75 BBLS Dead Crude. IWHP=OIOIO. FWHP=OIO/O Init-> 0 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 06:00 Dispatched / Travel To Mod-58 06:28 Load Dead Crude 06:56 Load Diesel 07:16 Arrive On Location I Rig-Up 07:25 PT IA To 3500 Psi 07:27 1.0 start crude 350 Down IA 07:34 1.5 10 850 Down IA 07:47 1.9 35 1100 Down IA 08:09 1.9 75 1150 Swap To TBG 08:14 PT TBG To 3800 Psi 08:15 start Diesel 1125 Down TBG 08:34 Shut Down IRDMO Final-> 0 0 0 . FLUID SUMMARY 75 BBLS Dead Crude 10 BBLS Diesel 5 BBLS Diesel Paid For On Previous Job SERVICE COMPANY - SERVICE BP FESCO WAREHOUSE DAILY COST TOTAL FIELD ESTIMATE: $0 $650 $420 $1,070 CUMULTOTAL $3,360 $1,430 $420 $5,210 . AOGCC Robin Doason r 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well MPI-14 L 1 ;{& '-( -/z, c 30-Sep-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,289.15' MD 7,324.00' MD 9,910.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date /~¡6rf Please call me at 273-3545 if you have any q Regards. William T. Allen Survey Manager Attachment(s) Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPI MPI-14L 1 Job No. AKZZ3214396, Surveyed: 16 August, 2004 Survey Report 28 September, 2004 Your Ref: API 500292321460 Surface Coordinates: 6009461.02 N, 551315.31 E (70· 26'11.7636" N, 149· 34' 53.8198" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1009461.02 N, 51315.31 E (Grid) Surface Coordinates relative to Structure Reference: 325.53 S, 862.60 W (True) Kelly Bushing Elevation: 68. 16ft above Mean Sea Level Kelly Bushing Elevation: 68. 16ft above Project V Reference Kelly Bushing Elevation: 68. 16ft above Structure Reference SpE!I"""I"""Y-SUI"1 DFUL..L.ING· SERVices A Halliburton Company D EFI N ITIVE . . Survey Ref: svy1468 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-14L 1 Your Ref: API 500292321460 Job No. AKZZ3214396, Surveyed: 16 August, 2004 BPXA Milne Point Unit Measured True 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) 7289.15 73.050 337.280 3848.55 3916.71 1749.40 N 4492.58 W 6011179.47 N 546810.80 E 4509.21 Tie On Point .... 7324.00 72.910 336.750 3858.75 3926.91 1780.08 N 4505.59 W 6011210.05 N 546797.58 E 1.509 4539.41 Window Point 7352.90 76.280 337.050 3866.42 3934.58 1805.70 N 4516.52 W 6011235.60 N 546786.47 E 11.704 4564.68 7396.70 81.640 337.510 3874.81 3942.97 1845.34 N 4533.11 W 6011275.13 N 546769.61 E 12.281 4603.53 7442.81 87.780 337.990 3879.06 3947.22 1887.82 N 4550.49 W 6011317.48 N 546751.94 E 13.356 4644.87 . 7492.96 91.790 338.510 3879.24 3947.40 1934.39 N 4569.07 W 6011363.92 N 546733.04 E 8.063 4689.84 7543.13 93.400 339.030 3876.97 3945.13 1981.10 N 4587.22 W 6011410.51 N 546714.57 E 3.372 4734.58 7589.81 93.480 339.520 3874.17 3942.33 2024.68 N 4603.71 W 6011453.98 N 546697.78 E 1.062 4776.00 7638.87 94.080 340.030 3870.94 3939.10 2070.62 N 4620.63 W 6011499.79 N 546680.54 E 1.604 4819.31 7686.03 96.130 339.290 3866.74 3934.90 2114.66 N 4636.96 W 6011543.72 N 546663.91 E 4.619 4860.91 7735.53 95.940 338.070 3861.54 3929.70 2160.51 N 4654.85 W 6011589.45 N 546645.70 E 2.481 4904.90 7782.46 95.500 338.080 3856.86 3925.02 2203.83 N 4672.29 W 6011632.65 N 546627.97 E 0.938 4946.84 7828.08 95.130 337.820 3852.63 3920.79 2245.93 N 4689.34 W 6011674.63 N 546610.63 E 0.990 4987.68 7877.45 94.640 337.340 3848.43 3916.59 2291.41 N 4708.10 W 6011719.98 N 546591.55 E 1.387 5032.05 7925.64 92.470 339.840 3845.44 3913.60 2336.18 N 4725.66 W 6011764.63 N 546573.69 E 6.862 5075.06 7973.76 90.930 343.710 3844.01 3912.17 2381.85 N 4740.70 W 6011810.20 N 546558.34 E 8.652 5116.79 8019.97 90.190 345.800 3843.56 3911.72 2426.43 N 4752.84 W 6011854.69 N 546545.88 E 4.798 5155.65 8068.33 87.160 345.730 3844.68 3912.84 2473.29 N 4764.73 W 6011901.47 N 546533.67 E 6.267 5195.84 8117.65 82.630 348.150 3849.07 3917.23 2521.13 N 4775.83 W 6011949.23 N 546522:24 E 10.404 5236.10 8164.14 79.250 349.980 3856.39 3924.55 2566.19 N 4784.54 W 6011994.23 N 546513.22 E 8.244 5272.73 8216.01 78.880 351.750 3866.23 3934.39 2616.47 N 4792.63 W 6012044.46 N 546504.79 E 3.426 5312.38 8260.20 78.560 351.450 3874.87 3943.03 2659.35 N 4798.96 W 6012087.28 N 546498.17 E 0.984 5345.77 . 8310.44 78.260 351.670 3884.97 3953.13 2708.03 N 4806.18 W 6012135.91 N 546490.61 E 0.735 5383.71 8357.89 81.070 351.990 3893.48 3961.64 2754.23 N 4812.82 W 6012182.07 N 546483.66 E 5.959 5419.56 8406.76 86.420 355.950 3898.80 3966.96 2802.51 N 4817.91 W 6012230.32 N 546478.23 E 13.590 5455.65 8453.16 90.430 358.120 3900.08 3968.24 2848.82 N 4820.30 W 6012276.61 N 546475.52 E 9.825 5488.42 8504.35 96.370 1.350 3897.04 3965.20 2899.89 N 4820.55 W 6012327.67 N 546474.93 E 13.202 5522.77 8551.27 97.240 4.120 3891.48 3959.64 2946.42 N 4818.32 W 6012374.22 N 546476.83 E 6.148 5552.25 8599.70 95.750 4.780 3886.00 3954.16 2994.40 N 4814.59 W 6012422.22 N 546480.23 E 3.361 5581.58 8645.08 96.240 4.620 3881.26 3949.42 3039.38 N 4810.89 W 6012467.22 N 546483.62 E 1.135 5608.93 8694.75 95.140 4.350 3876.34 3944.50 3088.65 N 4807.03 W 6012516.52 N 546487.14 E 2.280 5639.03 8741.78 95.260 4.750 3872.08 3940.24 3135.34 N 4803.31 W 6012563.23 N 546490.54 E 0.885 5667.51 8788.81 92.970 4.900 3868.70 3936.86 3182.08 N 4799.37 W 6012610.00 N 546494.16 E 4.880 5695.85 8838.45 89.200 6.960 3867.76 3935.92 3231.43 N 4794.24 W 6012659.39 N 546498.95 E 8.654 5725.06 8887.38 86.610 6.910 3869.55 3937.71 3279.97 N 4788.34 W 6012707.96 N 546504.52 E 5.294 5753.15 28 September, 2004 - 9:17 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-14L1 Your Ref: API 500292321460 Job No. AKZZ3214396, Surveyed: 16 August, 2004 BPXA Milne Point Unit Measured True 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) 8934.64 85.860 7.220 3872.65 3940.81 3326.77 N 4782.54 W 6012754.80 N 546510.00 E 1.717 5780.16 8974.11 85.730 7.130 3875.55 3943.71 3365.82 N 4777.62 W 6012793.89 N 546514.65 E 0.400 5802.64 9029.11 84.000 7.410 3880.47 3948.63 3420.16 N 4770.69 W 6012848.27 N 546521.20 E 3.186 5833.84 9066.85 83.690 6.210 3884.52 3952.68 3457.41 N 4766.24 W 6012885.56 N 546525.40 E 3.266 5855.47 9125.03 84.130 5.090 3890.69 3958.85 3514.98 N 4760.54 W 6012943.17 N 546530.69 E 2.058 5889.76 . 9173.42 83.930 5.210 3895.72 3963.88 3562.92 N 4756.22 W 6012991.13 N 546534.68 E 0.481 5918.62 9219.97 85.680 5.160 3899.94 3968.10 3609.08 N 4752.03 W 6013037.32 N 546538.56 E 3.761 5946.40 9270.28 85.300 4.600 3903.89 3972.05 3659.06 N 4747.77 W 6013087.32 N 546542.48 E 1.342 5976.67 9314.84 87.410 5.190 3906.73 3974.89 3703.36 N 4743.97 W 6013131.65 N 546545.97 E 4.916 6003.49 9366.27 87.280 5.610 3909.11 3977.27 3754.51 N 4739.14 W 6013182.83 N 546550.45 E 0.854 6034.12 9410.20 90.120 5.480 3910.11 3978.27 3798.22 N 4734.89 W 6013226.57 N 546554.39 E 6.472 6060.22 9461.05 89.810 4.950 3910.14 3978.30 3848.86 N 4730.27 W 6013277.24 N 546558.67 E 1.207 6090.66 9507.31 90.000 6.070 3910.21 3978.37 3894.90 N 4725.83 W 6013323.31 N 546562.79 E 2.456 6118.17 9554.38 89.630 5.490 3910.37 3978.53 3941.73 N 4721.09 W 6013370.17 N 546567.21 E 1 .462 6145.99 9602.18 89.140 4.240 3910.88 3979.04 3989.36 N 4717.04 W 6013417.83 N 546570.94 E 2.809 6174.84 9650.77 90.250 3.970 3911.14 3979.30 4037.82 N 4713.56 W 6013466.31 N 546574.08 E 2.351 6204.69 9700.08 89.630 4.460 3911.19 3979.35 4087.00 N 4709.93 W 6013515.51 N 546577.37 E 1.603 6234.90 9746.23 90.800 5.310 3911.02 3979.18 4132.98 N 4706.00 W 6013561.52 N 546580.98 E 3.134 6262.74 9793.09 92.470 5.830 3909.68 3977.84 4179.59 N 4701.46 W 6013608.17 N 546585.21 E 3.732 6290.56 9838.69 92.290 5.860 3907.78 3975.94 4224.92 N 4696.82 W 6013653.52 N 546589.53 E 0.400 6317 .44 . 9910.00 92.290 5.860 3904.94 3973.10 ~ 4295.80 N 4689.54 W 6013724.45 N 546596.32 E 0.000 6359.46 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. . Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 312.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 991 O.OOft., The Bottom Hole Displacement is 6359.69ft., in the Direction of 312.491 ° (True). 28 September, 2004 - 9:17 Page 3 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPI- MPI-14L 1 Your Ref: API 500292321460 Job No. AKZZ3214396, Surveyed: 16 August, 2004 BPXA Milne Point Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~) ~) Comment 7289.15 7324.00 9910.00 3916.71 3926.91 3973.10 1749.40 N 1780.08 N 4295.80 N 4492.58 W 4505.59 W 4689.54 W Tie On Point Window Point Projected Survey . Survey tool proøram for MPI-14L 1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 352.00 0.00 351.96 352.00 9910.00 351.96 CB-SS-GYRO (MPI-14PB1) 3973.10 MWD+IIFR+MS (MPI-14PB1) . 28 September, 2004 - 9:17 Page 4 of 4 DrillQuest 3.03.06.006 II ~~ l~@ Lfl1 -=:;J tF-l\ cj)) . (ill FRANK H. MURKOWSKI, GOVERNOR Þ.I,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 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, Alaska 99519-6612 Re: Milne Point MPI-14Ll BkP Exploration (Alaska) Inc. Permit No: 204-120 Surface Location: 2348' NSL, 4055' WEL, SEC. 33, T13N, RlOE, UM Bottomhole Location: 1328' NSL, 3465' WEL, SEC. 29, T13N, RI0E, UM (OA) Dear Mr. Archey: Enclosed is the approved application for permit to redrill the above development well. The permit is for a new wellbore segment of existing well MPU 1-14, Permit No 204-119, API No. 50-029-23214-00. Production should continue to be reported as a function of the original API number stated above. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 6 - 7 (pager). S~ ce ly BY ORDER OF THE COMMISSION DATED this tY'day of July, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2348' NSL, 4055' WEL, SEC. 33, T13N, R10E, UM Top of Productive Horizon: 4563' NSL, 3460' WEL, SEC. 32, T13N, R10E, UM (OA) Total Depth: 1328' NSL, 3465' WEL, SEC. 29, T13N, R10E, UM (OA) 4b. Location of Well (State Base Plane Coordinates): Surface: X-551315 y-6009461 Zone-ASP4 16. Deviated Wells: Kickoff Depth: 7259' feet Maximum Hole Angle: 92 . STATE OF ALASKA . ALASKA (!l AND GAS CONSERVATION COrMlSSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory II Development Oil II Multiple Zone o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: IBI Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 MPI-14L 1 6. Proposed Depth: 12. Field I Pool(s): MD 9871' TVD 3993' Milne Point Unit I Schrader Bluff 7'l~e:rty Designation: S'\> \\Ç~ O&9;{)0 ADL 025517 "ì /;~ 8. Land Use Permit: , µ'1/ 'iV~ .. 13. Approximate Spud Date: 07/26/04 9. Acres in Property: 2555 14. Distance to Nearest Property: 3600' Hole 6-3/4" Casing 4-1/2" Weight 12.6# Specifications Grade Coupling Length L-80 BTC 2612' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL):KBE = 68' feet 1730' away from MPI-10 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 1739 Surface: 1346 Qµa9"Øf ~V"'e (c.f..or sacks MD TVD MD TVD (including stage data) 7259' 3933' 9871' 3993' Uncemented Slotted Liner PR!::S!::NIWELL CONDlyIØN$UMMARY (To beê::<:>mPl~.eºJ()"·RedriIlAND Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Depth MD (ft): 9880' 4058' NIA 9880' Structural Conductor 109' 20" 260 sx Arctic Set (Approx.) 109' 109' Surface 2769' 10-3/4" 371 sx PF 'L', 255 sx Class 'G' 2769' 2318' Intermediate Production 7531' 7-5/8" 747 sx Class 'G' 7531' 3998' Liner 2499' 12.6# Uncemented Slotted Liner 7381' - 9880' 3961' - 4053' 20. Attachments 0 Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): IBI Drilling Program 0 Time vs Depth Plot o Seabed Report IBI Drilling Fluid Program o Shallow Hazard Analysis 1B120 MC 25.050 Requirements Date: Contact Walter Quay, 564-4178 Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Pat Archey Title Senior Drilling Engineer Phone Permit To Drill API Number: I Permit App~o)'~ /. Number: .;)04- \)Q 50- C)"ðs'-'ð9\'\..\ -<':':>0 Date: 7/1 ~'ð? f/ Conditions of Approval: Samples Required 0 Yes 1'&No Mud Log Required 0 Yes ~No lfide Measures ,,,DYes ~No Directional Survey Required RYes 0 No \-Q<:;"~\û,",~. \3ù\>~\-'tf\\<~\ ~-\-S~~,\~~ \'--\~o.'tf O~?\ö\j~ Daæ ~~;J:~ O fj I G I N A L APPROVED BY ;\ ¡") .. THE COMMISSION o Drill III Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Suñace: '1t>ç:(' ,,¿t> 7,'1,0'/ 2348' NSL,~EL, SEC. 33, T13N, R10E, UM Top of Productive Horizon: 4563' NSL, 3460' WEL, SEC. 32, T13N, R10E, UM (OA) ~ Total Depth: 9. Acres in Property: ÞP'1- 14. Distance to Nearest Property: 1328' NSL, 3465' WEL, SEC. 29, T13N, R10E, UM (OA) . -2569;:'5>5' "1' p. 3600' 4b. Location of Well (State Base. Eb~.fI}1.C.oordinates): )~.1,tA 10. KB Elevation 15. Distance to Nearest Well Within Pool Suñace: x-551315 Y-80Wr~¡ Zone-ASP4 (Height above GL):( E 68' feet 1730' away from MPI-10 16. Deviated Wells: Kickoff Depth: 7259'/ feet 17. Maximum Antic' Pressures in psig (see 20 MC 25.035) Maximum Hole Angle: 92 Downhole: 3 Suñace: 1346· . STATE OF ALASKA e, ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 0 DevelopmenfGas 5. Bond: IBI Blanket 0 Single Well Bond No. 2S100302630-277 MPI·14L 1 6. Proposed Depth: 12. Field I 001(5): MD 9871' - TVD 3993' v Miln Point Unit I Schrader Bluff 7. Property Designation: M Ap L tI,l "'~5"'1a.4- ADL 025517 7J¡ T 8. Land Use Permit: 1 . Approximate Spud Date: 07/26/04 A ~t'\ 18. Casing Program: Size Casing 4-1/2" Grade Coupling Length MDfl L-80 BTC 2612' 725~ <\~, PRESENT WELL CONDITION SUM ~ Total Depth MD (ft): Total Depth TVD (ft): I Plugs (me~ Effective Depth MD (ft): IEffective Depth TVD 9880' 4058' N/A~ 9880' 4058' Size ,~ Cement Volume, Hole 6-3/4" Weight 12.6# (including stage data) Uncemented Slotted Liner 20. Attachments 0 Filing Fee, $10 o Property Plat IPeñoration Depth TVD (ft): IBI Drilling Program 0 Time vs Depth Plot o Seabed Report IBI Drilling Fluid Program o Shallow Hazard Analysis IBI 20 AAC 25.050 Requirements Date: Contact Walter Quay, 564-4178 Structural Conductor 109' 20" o sx Arctic Set (Approx.) 109' 109' Suñace 2769' 10-3/4" 371 sx PF 'L', 255 sx Class 'G' 2769' 2318' Intermediate _Production 7531' 747 sx Class 'G' 7531' 3998' Liner 2499' Uncemented Slotted Liner 7381' - 9880' 3961' - 4053' Peñoration Depth MD (ft): 21. Verbal Approval: 22. I hereby certify that the f egoing is true and correct to the best of my knowledge. Printed Name Pat Arc ey Title Senior Drilling Engineer Phone 564-5803 Permit To Drill I I 32/ f I /ò Permit Approval I See cover letter for Number: 2-D..,) 50- Oa~ 2 7 -co . Date: other requirements Conditions of Ap oval: Samples Required 0 Yes ~ ~o Mud Log Required 0 Yes ¡K"No . . Hydrogen Sulfide Me. asures . 0 Yes þ{No Directional Survey Required ~Yes ~ Other. ~~.;~\ 'ßr:::x~<?.\-G..~ fb,,~," t~~ì \-<.es.\-'t,,~~\ o.\(~ro~tJ nQ\G\NAl APPROVED BY THE COMMISSION Date Approved By: Form 10-401 Revised 06/2004 Submit In Duplicate . . MPI-14 Permit I Well Name: IMPI-14L1 Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Schrader Bluff Tri-Lateral Producer Surface Location: (As Built) Target Location: Top OB Target Location: ~".. BHLOBWell TO Target Location: :rop OA Target Location: BHL OA Well TD arget Location: Top NB Target Location: BHL NB Well TO Distance to Property line Distance to nearest pool 2,348' FSL, v 4,055' FEL, SEC. 33, T13N, R1 DE E=551315 N=6009461 4311'FSL,3362'FEL,SEC.32,T13N,R10E E=546710 N=6011394 Z= 3930' TVO SS 1328' FSL, 3465' FEL, SEC. 29 , T13N, R1 DE E=54B585 N=6013690 Z=3985' DID 88----- 4563' FSL,3460'FEL,SEC.32,T13N, R10E E=546610 N=6011645 Z= 3880' TVD SS 1328' F~L, 3465' FEL, SEC. 29 , T13N, R10E E=54f\!;A~ N:...601 ~90 Z=3925' TVD SS 4563' FSL, 3460' FEL, SEC. 32, ì13N, R10E E=546610 N=6011645 Z=3720' TVO SS 1328'FSL,346~FEL,SEC.29,T13N,R10E E=546585 N=6013690 Z=3755' TVO SS 3600' 1730' from MPI-10 '''''" " ) ,// / I AFE Number: 1 MS0337396 1 I Rig: 1 Doyon 14 Estimated Start Date: 126 July 04 I Operating days to complete: 123.5 MD: 19871' I 1 TVD: 13993' 1 I Max Inc: 192 1 I KOP: 17259' I 1 KBE: 168 Well Design (conventional, slim hole, etc.): I Trilateral Producer Objective: 1 Schrader Bluff DB, OA & NB 7 . Mud Program: 13-1/2" Surface Hole (0 - 2769'): Density (ppg PV YP API FL 8.6 - 9.5 10 - 25 30-50 NC-8 9-7/8" Intermediate Hole (2769 - 7531 '): Density (ppg PV YP API FL 9.0-9.3 8-15 26-32 6-8 6-3/4" OB Production Hole (7531-- 9880'): Density (ppg PV YP HTHP .9.0--'- 15 -25 20 < 8 /:.- ,'" "-.- (... . 6-3/4" OA ProducfionHóre(7259-- 9873'): ) Density (ppg PV YP HTHP / 9.0 15 -25 20 < 8 ~NB ~roduéti¿;:;-Hole (6664:9853'): Density (ppg PV YP HTHP 9.0 15 -25 20 <8 . MPI-14 Permit LSND pH 8.5 -9.5 LSND Chlorides < 1500 MOBM Electrical Stability 550:-_~00 MOBM Electrical Stability 550 - 900 pH 9.0-9.5 MBT < 25 Oil:Water Ratio 80:20 ..... - ---",. Oil:Water Ratio 80:20 ) ---/ ------ Oil:Water Ratio 80:20 MOBM Electrical Stability 550 - 900 LCM Restrictions: Yes. Use CaC03 as LCM Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to D5-4 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 lR. c::: Cement Program: ('Û.s\~~ C:.I.\~'i \r---~ \Q~P- Casing Size 10-3/4"45.5 Ib/ft L-80 BTC Surface Casing Lead Slurry to surface. Excess 100% over gauge hole. Top of tail cement 500' MD above casing shoe. Total Cement Volume: 346 bbl Wash 15-bbl water Basis Spacer Lead Tail Temp Casing Size 17-5/8" 29.7 Ib/ft L-80 BTC-M Intermediate Casing Bas' I Top of lead slurry 500' MD above Ugnu sand. IS Top of tail slurry 500' MD above TUZC. 40% excess over gauge. Total Cement Volume: 155 bbl Wash 75-bbl 1 0.1-lb/gal un-viscosified Alpha Spacer 293 - Bbl, 371 sx of 10.7 ppg Permafrost L - 4.44 fe/sx 53-bbl, 255-sx 15.8 Ib/gal Prem G - 1.17 fe/sx 25-bbl water Spacer 45-bbl (MW + 1.0-lb/gal) Alpha Spacer (Alpha) Tail 155-bbl, 747-sx 15.8 Ib/gal Prem G - 1.16 ft::S/sx Temp BHST ~80°F from SOR Evaluation Program: 8 13-1/2" Section Open Hole: Cased Hole: . MWD/GR IFR/CASANDRA Sperry InSite N/A 9-7/8" Section Open Hole: MWD/GRlRES IFRlCASANDRA Sperry InSite Cased Hole: N/A 6-3/4" Section Open Hole: MWD/GRlRES/ABI IFRlCASANDRA Sperry InSite Cased Hole: N/A Formation Markers: . I MDrkb Formation Tops (ft) TVDrkb (ft) BPRF TUZC Ugnu-MA Ugnu-MBl Ugnu-MB2 Ugnu-MC SBF2- Top NA SBF21-Base NA SBFl-Top NB SBFl2-Base NB SBE4-NC SBE2-NE SBEI-NF TSBD- Top OA TSBC-Base OA TSBB- Top OB SBAS-Base OB NB OWC OA OWC OB OWC 1933 5207 5782 5807 5960 6412 6635 6650 6765 6841 6898 6975 7127 7260 7393 7531 Pore Pressure (psi) 1818.00 3213.00 3448.00 3458.00 3518.00 3683.00 3763.00 3768.00 3803.00 3823.00 3838.00 3858.00 3898.00 3933.00 3968.00 3998.00 4023.00 760 1366 1468 1472 1498 1570 1635 1637 1653 1662 1668 1677 1695 1710 1726 1739 1750 3962.00 4008.00 4068.00 9 . ". MPI-14 Permit Estimated EMW I (Ib/gal)* 8.35 8.35 8.35 8.35 8.35 8.35 8.51 8.51 8.51 8.51 8.51 8.51 8.51 8.51 8.51 8.51 8.51 ,/ . . MPI-14 Permit CasinglTubin~ Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Bottom Tbg O.D. MD / TVDrkb M D / TVDrkb 42-in 20-in* 92# H-40 Welded 109' 0' 109' 1109' 13.5-in 10.75-in 45.5# L-80 BTC-M 2,769' 0' 2,769' 1 2,318' 9.875-in 7.625-in 29.7# L-80 BTC-M 7,531' 0' 7,531 13,998' 6.75-in 4.5-in 12.6# L-80 BTC 2,499' 7,381'/3,961 ' 9,880'/4,053' 0°~ S!9jted --- ~- 9,871 '/3.993,/ .. ... 6.75-in 4.5-in 12.6# L-80 BTC 2,612' 7,259'/3,933' OA Slotted o.75-in 4" X5" L-80 3, 1 ö~f 6,664' / 3,/33 9,853'/ 3,ôí3' NB Screens , Recommended Bit Program: BHA 1 2 3(OB) 4(OA) 5(NB) Hole Size 13.5" 9.875" 6.75" 6.75" 6.75" Depth (MD) 0' - 2,769' 2,769 - 7,531' 7,531 ' -9,880' 7,259' -9,873' 6,664 ' -9,853' Bit Type Hughes MXC1 POC Hycalog OS 146 Hycalog OS 146 Hycalog OS 146 Nozzle/Flow rate 10 . . MPI -14 Permit Well Control: Intermediate/Production hole: · Maximum anticipated BHP: 1,739j>si @ 3,998-ft TVDrkb - TSBB-Top OB · Maximum surface pressure: 1,346 psi @ surface (Based on BlIP and a full column of gas from TD @ O.I-psi/ft) · Planned BOP test pressure: 3,000-psi. For this well. approval is sou~ht to change the BOP testing interval from 7 to 14 days. An FIT to 11.5-lb/gal at the 1O-3/4"shoe. 67-bbl with 9.3-lb/gal mud. MOBM in Laterals/9.8 ppg Brine/7.0-lb/gal Diesel (1 ,800-ft tvd). · Integrity test: Kick tolerance: · Planned completion fluid: Drilling Hazards & Contingencies: · Hydrates have been encountered on I-Pad wells, but are not expected to be a major problem. Lost Circulation · We do not expect losses while drilling this well. Expected Pressures · On 2001 drilling, over-pressured Ugnu/Schrader Bluff was encountered. This was most likely caused by 1-10 injector. This well is to remain shut in while drilling. v Pad Data Sheet · Please Read the I-Pad Data Sheet thoroughly. Breathing · Not expected or predicted. Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · Four fault intersections are prognosed for this well. These are in the Ugnu (6,460' MD), the NE (7,085' MD), OB (8,000' MD) and a second in the OB (9,200' MD). Hydrogen Sulfide · MPI Pad is not designated as an H2S Pad. I-Pad wells <50-ppm H2S reported. Latest samplings: o MPI-06 o MPI-08 o MPI-15 <2 <2 <2 2/15/04 2/15/04 2/15/04 Anti-collision Issues · MPI-14 passes the Major Risk Criteria. The closest issue is MPI-13 at 700' with a 30' center to center distance. Distance to Nearest Property · MPI-14 is 3,600-ft from the nearest Milne Point property line. ". Distance to Nearest Well Within Pool · MPI-14 is 1730' from the Schrader Bluff sand penetration in MPI-10. ' 11 . . MPI-14 Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. The 20" conductor is installed. 2. NU Diverter Drilling 1. MIRU Doyon 14, ND Tree/NU BOP. 2. Function Test Diverter, PU 4" DP. 3. Drill 13.5" surface hole. 4. Run and cement 10.75" surface casing. 5. ND diverter, install wellhead and NU/Test BOP. 6. Drill 9.875" intermediate hole. 7. Run and cement 7-5/8" intermediate casing. 8. Displace to MOBM. Drill 6-3/4" OB horizontal production hole. 9. ~Rufl4.s:,slotted liner._---,'-----v/------~-"-'- ---. . .' -..,----~_.-- --....., ) 10. Run whipstõêk and mill window for OA lateral. h_~ "- / " ì' 11. Drill 6-3/4" OA horizontal production hole. \ . 12. Retrieve whipstock. ~ '~--'3un 4.5" slotted liner a~ off in 7.625" casing_/, 14. R~llwindow~er~1 15. Drill 6-3/4':£JÂhi~ontal production hole. /-5Þ 7· , . 16. Retrieve whipstock. 17. Run 4.5" screens completion liner and hang off in 7.625" casing 18. Displace MOBM with Brine 19. RU and Run 2.875" ESP Completion. 20. ND BOP/NU Tree 21. Freeze Protect. 22. RDMO Doyon 14. 12 . MPI-14 Proposed .. 110-3/4" Csg S oel @ 2,769' ~ 9.2 PPG Versapro MOBM below Completion ) L . TREE: 2-9/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M Tubing Head: FMC 11" X 2.875" I Orig KB elev (D-14)::: 69' .... I 109' Camco 2 7/8" x 1" sidepocket KBMM GLM -1S0' 2-7/8" 6.5 ppf, L-80, EUE production tubing (Drift 10 = 2.347", cap = 0.00579 bpf) Camco 27/8" x 1" sidepocket KBMM GLM 2 Jts above ESP 27/8" XN Nipple. 1 Jt above ESP ~ 10-314", 4S.S# L-BO BTC Csg Casing ID 9.9S0" Casing Drift 9.794" Centrilift ESP Centrilift Tandem Gas Separator Centrilift Tandem Seal Section Cairilift Motor 140 HP KMH-A 2244 Volt 37 Amp Pump Mate & Centralizer Baker ZXP Liner Top Packer & Hanger @ S,xxx' MD Baker Hookwall Hanger Window in 7-S/8" casing@ 6,664' MD Well Inclination @ Window = 700 Swell Packer@ -6,700' MD Baker Flexlock Liner Hanger Baker ZXP Liner Top Packer & Hanger @ S,7S0' MD I 6,664'- 9,853'1 6·3/4" NB Lateral ""'-"."---~~7 _:...:...ï>:·. '. _:'e"-.". _i-.:::';¡¡'::::._" _._',':_ .':-:::::.... -..,....-....-:. -:,::-::--:'-,- -,':',:,-". ..;.-~-::;. -. --.",;........---~._-- -. -¡...;,.-. _....,_,,,__.__>'-__^_~..."V.~ -. -- .-....'.-'.'.-:"'::::-'/:-:- _._ - e' ,. _.. _..... _ .:_..:.....:::_.._.:},..:.- - - _.. ,. e' _ _ -. _ _:_:-...::....:....... _,. - ..._ e"." _ _ ',_::'.,':.:._:_'::..',_ ^ -.-""_"""~'-o>=_"___'_________".~.,~"""___"______~"=-_" Baker Hookwall Hanger Window in 7-S/8" casing@ 7,2S9' MD Well Inclination @ Window = 7So - e--)'- --.... ..... ~YT-\\'-~ 6-3/4" OA Lateral I 7,259'-9,871'1 ~~- _ .. ÌI~~;.,::e~_ _ '__on .-___..- -_ ... _ \!f';"e~,_,_~ - --- - - .- - -. - - -- - Baker ZXP Liner Top Packer & Flexlock Hanger@ -7,400' MD ~-~ 7-518",29.7#, L-BO, BTC-M Casing Drift: 6.7S" Casing ID: 6.B75" 6·3/4" 08 Lateral I 7,531'-9,880'1 17-S/8" Casing Shoe @ 7,S31' MD I - - -- - - -- - - --- --- - DATE 06/14/2004 REV. BY W. Quay COMMENTS Proposed Trilateral Milne Point WELL: 1-14 API NO: 50-029- 50-029- 50-029- I .GRID\ _~__ 2'34'41" I I-PAD PLANT) . (\ 28 \) .}-pAD c- JG-PAD +14 .13 .12 .11 .8 .7 .4 .6 .3 .5 .2 .9 .1 .10 33 34 ~ ~AD !-PAD PROJECT AREA VICINITY MAP N.T.S. LEGEN D + AS-BUILT CONDUCTOR MPU I-PAD I . EXISTING CONDUCTOR NOTES 1. DATE OF SURVEY: DECEMBER 16, 2001 2. REFERENCE FIELD BOOK: MP01-08 PAGE 4. 3. ALASKA STATE PLANE COORDIN A TES ARE ZONE 4, ALASKA, NAD 27. 4. PAD SCALE FACTOR IS 0.9999031 5. HORIZONTAL CONTROL IS BASED ON j MPU I-PAD MONUMENTS 1-1 AND 1-2. 6. ELEVATIONS SHOWN ARE MPU DATUM. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF DECEMBER 17, 2001. LOCA TED WITHIN PROTRACTED SEC. 33, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL ASP. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS 14 Y= 6,009,461.02 N 1,120.14 70'26'11.764" 70.4366010' 34.8' 2348' FSL X= 551,315.31 E 1,020.23 149'34'53.820" 149.5816166' 4055' FEL ,; ~Oh' DRAWN ObP __0________________ COTTON --. ----------_._~ CHECKED OAD DATE 12/17/01 QRAWlNG SHEET FRBOl "'PI 08-01 MPU I-PAD ~ åJ~rn(bo JOB NO: SCALE· AS-BUlL T CONDUCTOR o '2/17/01 ISSUE FOO INFOOIIA TlON J.JC D;\) (fOCIN[utS iUOOlNfOSUfhh'QIIIS WELL 1-14 1 or 1 to, «Sf "M:1fI££O l¡O.NE 1'=150'± NO. OAIE REvtSlON BY CHK AH().I~",C(. ¡t.A$I\A .",,, COMPANY DETAIU REFERENCE TNFORMA TION SURVEY PROORAM Plan: MPI-14 Ll WPI3 (Plan MPI-14OdinIMPI·14 LI SP Amoco Co~nate (WE) Reference: Well Centre: Plan MPI-14 Odin, True Nonh Depth Fm Depth To SurveylPlan Tool Created By: Digital Business Client User Date: 6/23/2004 Vertical (TVD) Reference: 68.00 68.00 Calculation Method: Minimum Cur.'1I!I.Iæ Section (VS) Reference: Slot - (O.OON,O.OOE) 7259.00 9871.18 Planned: MPt-14 LI WPI3 V38 MWD+IFR+MS Checked: Date:_ Error System: ISCWSA Meüu~~~~~e~~ ~~~ Scan MedJod: Trav CyIinœr North Reviewed: Error Surface: Elliptical + Casing Date:_ Wamin~ Method: Rules Based CASING DETAILS I\pprf:;(~Ltt:, I Ut.I AIL~ ua¡e:_ No. TVD MD Name Size Name TVD +N/-S +FJ-W Nonhing Easting Shape oA I 3993.00 9871.00 4112" 4.500 MPI-14 LI TI B 3948.00 2216.66 -4690.38 6011645.00 546610.00 Point MPI- 1 4 LI T2A 3973.00 2887.74 -4835.78 6012315.00 546460.00 Point MPI-14 L1 T3 A 3973.00 3249.54 -4800.29 6012677.00 546493.00 Point FORMATION TOP DETAILS MPI-14 LI T5 3993.00 4261.98 -4701.31 6013690.00 546585.00 Point MPI-14 LI T4 A 4003.00 3717.29 -4755.07 6013145.00 546535.00 Point No. TVDPath MDPath Fonnation I 3933.00 7259.67 TSBD- Top OA WELL DETAILS 2 3968.00 8251.09 TSBC-Base OA Nom" +N/-S +EI-W Northing Easting latitude Long;tude Slot 3 3998.00 9174.54 TSBB- Top OB Plan MPI-14 Odin 1065.75 1076.SS 6009460.88 55131 S.07 70'26'11.762N 149"34'53.827W N/A SECTION DETAILS Sec MD Inc Azi TVD +NI-S +EI-W DLeg TFace VSec Target I 7259.00 74.75 334.51 3932.82 1725.21 -4481.12 0.00 0.00 4478.68 e 2 7279.00 77.12 334.90 3937.68 1742.75 -4489.4 I 12.00 9.00 4496.60 3 7499.09 92.23 337.95 3958.06 1943.02 -4576.73 7.00 11.54 4695.80 4 7720.10 92.23 337.95 3949.47 2147.71 -4659.65 0.00 0.00 4894.71 5 7795.63 90.00 334.00 3948.00 2216.66 -4690.38 6.00 -119.39 4963.79 MPI-14 Ll TI B 6 7980.93 86.74 344.63 3953.29 2389.67 -4755.72 6.00 107.17 5128.40 7 8161.94 86.74 344.63 3963.60 2563.93 -4803.60 0.00 0.00 5280.92 8 8489.08 90.00 4.00 3973.00 2887.74 -4835.78 6.00 80.80 5522.24 MP[-[4 Ll T2A 9 8519.56 90.67 5.70 3972.82 2918.10 -4833.2 I 6.00 68.46 5540.73 10 8744.51 90.67 5.70 3970. I 9 3141.93 -4810.86 0.00 0.00 5674.50 II 8852.70 86.35 5.52 3973.00 3249.54 -4800.29 4.00 -177.64 5738.95 MPI-[4 LI T3 A 12 8873.43 85.52 5.53 3974.47 3270.12 -4798.30 4.00 179.73 5751.29 13 9185.54 85.52 5.53 3998.86 3579.83 -4768.34 0.00 0.00 5937.11 ì ì 1 14 9323.75 91.05 5.50 4003.00 3717.29 -4755.07 4.00 -0.27 6019.60 MP[-14 LI T4 A 1 15 9327.16 91.05 5.64 4002.94 3720.68 -4754.74 4.00 90.00 6021.64 t;u ! ,;,-. 16 9871.1 8 91.05 5.64 3993.00 4261.98 -4701.31 0.00 0.00 6345.62 MPI-14Ll T5 3300 il ::E~:~Et--E£fi=t::1- -=:~:-~:=::::EE~I1 u_/ I_n .' '-~. ..- ,-- ~!4f~~fI11 /- ,M I -... il /' I .., 1 __I _,u. / -, -- 3600" / / I / " I â r-- I / ~__._u _n" I ! ! ~ta~ Dir~IIÓo' ¡ 9issis.¡ Mb.39~.~-tVÓ+-¡+ _-tn' 0 I I '~!~!rtÞ:rtf~~ 0 -f .... e ~ ! I .<: Õ. / 1 1- --/ ~ n _, (:: , õi i I " L I I I 'f ,.___n " - /1 1/ . / / L I > 3900 .... I , " 2 I- f-. in, / .-'- _ i J--- ,~ I c-' - -- r-- ~ i~ '-4. \ to ~" I -, J -, I, i . ,-¡-1-'T j \1 ¡- _,_n.' _-¡-_____ 1_ m .C.., ' MP T3A 'M~I-!4tJ¡r4~ L.. ! : !! i ,: t- __.',u m I :M~I \4· 1 ,wi> 4200 : ¡ -! ! +- r-- --- it4!Otln tMi 1,-- I-m -,- n."_'._ ___ ______ I n:: ::rî .'.',- _ In u---ff .- ¡._- ,- ___ _u - - 1-' -- i II .- ¡ . 1-- ;..+- --, I I , I I I I I I I I I I I I I I I 4200 4500 4800 5100 5400 5700 6000 6300 6600 6900 Vertical Section at 312.19° (300ft/in] SURVEY PROGRAM Plan: MPI·14 LI WPI3 (Plan MPI-14QdinIMPI-14 LI Depth Fm Depth To SurveylPlan Tool Created By: Digital Bus~ss Client User Date: 6/23/2004 7259.00 9871.18 Planned: MP!-14 LI WPIJ VJ8 MWD+IFR+MS Checked: Dale_ Reviewed: Dale:_ Approved: Dale_ WELL DETAILS Nomo 'WOS -<-EI·W Northing """'" latitude Longitude Slot Plan MPI·140.iîn 1065.75 1076.55 6009460.88 551315.07 10"26'11.762N 149°)4'5J.821W WA TARGET DETAILS Name TVD +N/-S +FJ-W Nonhing Easting Shape MPI-14 Fault#1 3703.00 1337.00 -5481.53 6010760.00 545825.00 Polygon MPI-14 Fault #2 3888.00 1567.30 -4794.87 6010995.00 546~1O.00 Polygon MPI-14 LI Tl B 3948.00 2216.66 -4690.38 6011645.00 546610.00 Point MPI-14 LI T2A 3973.00 2887.74 -4835.78 6012315.00 546460.00 Point MPI-14 LI T3 A 3973.00 3249.54 -4800.29 6012677.00 546493.00 Point MPI-14 GeoPoly 3974.00 531.30 -2923.77 6009972.00 548388.00 Polygon MPI-14 LI T5 3993.00 4261.98 -4701.31 6013690.00 546585.00 Point MPI-14 LI T4 A 4003.00 371 7.29 -4755.07 6013145.00 546535.00 Point MPI-14 Geo Poly 4008.00 1249.94 -4457.01 6010680.00 546850.00 Polygon MPI-14 Fault #3 4008.00 2466.87 -5443.75 6011890.00 545855.00 Polygon MPI-14 Fault #4 4053.00 3625.20 -5180.75 6013050.00 546110.00 Polygon SECTION DETAILS -- Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace vSec Target I '- 7259.00 74.75 334.51 3932.82 1725.21 -4481.I2 0.00 0.00 4478.68 2 7279.00 77.12 334.90 3937.68 1742.75 -4489.41 12.00 9.00 4496.60 3 7499.09 92.23 337.95 3958.06 1943.02 -4576.73 7.00 11.54 4695.80 4 7720.10 92.23 337.95 3949.47 2147.71 -4659.65 0.00 0.00 4894.71 5 7795.63 90.00 334.00 3948.00 2216.66 -4690.38 6.00 -119.39 4963.79 MPI-14 LI Tl B 6 7980.93 86.74 344.63 3953.29 2389.67 -4755.72 6.00 107.17 5128.40 7 8161.94 86.74 344.63 3963.60 2563.93 -4803.60 0.00 0.00 5280.92 8 8489.08 90.00 4.00 3973.00 2887.74 -4835.78 6.00 80.80 5522.24 MPI-14 LI T2A 9 8519.56 90.67 5.70 3972.82 2918.10 -4833.21 6.00 68.46 5540.73 10 8744.51 90.67 5.70 3970.19 3141.93 -4810.86 0.00 0.00 5674.50 II 8852.70 86.35 5.52 3973.00 3249.54 -4800.29 4.00 -177.64 5738.95 MPI-14 LI T3 A 12 8873.43 85.52 5.53 3974.47 3270.12 -4798.30 4.00 179.73 5751.29 13 9185.54 85.52 5.53 3998.86 3579.83 -4768.34 0.00 0.00 5937.1 I 14 9323.75 91.05 5.50 4003.00 3717.29 -4755.07 4.00 -0.27 6019.60 MPI-14 LI T4 A 15 9327.16 91.05 5.64 4002.94 3720.68 -4754.74 4.00 90.00 6021.64 16 L 9871.I8 91.05 5.64 3993.00 4261.98 -4701.31 0.00 0.00 6345.62 MPI-14 LI T5 CASING DETAILS No. TVD MD Name Size 3993.00 9871.00 41/2" 4.500 FORMATION TOP DETAILS . No. TVDPath MDPath Formation 3933.00 7259.67 TSBD-Top OA 3968.00 8251.09 TSBC-Base OA 3998.00 9174.54 TSBB- Top OB COMPANY DETAILS REFERENCE tNFORMA TrON BP Amoco CCKn'dinale (NIE) Reference: Well Centre: Plan MPI·14 Odin, True North Venical (TVD) Refemx:e: 68.00 68.00 Cakulation Method.: Minimum Curvature Section (VS) Reference; Slot· (O.OON.O.OOE) Error Syscem: ISCWSA Measu~aI~f::io~e~er;::; ~in~mum~~ture Scan Method; Trav Cylinder North Error Suñace; Elliptical + Casing Warnin¡¡:Method.: Rule5Based - . ... hi!·!· ~L~l+f·rjnjll·mt·nfrij - . ... .~. ~i ¡~I7.' ( rr~~lj~ ~tkliI;J;;9~F, .. = m ¡¡¡¡rill,!t! ..·.IT++ - ..f·: ij'·' ...[I..LI..L--1++1···'··· ..... hf..LI..n!++tnlJ····1T 4000 n. e ¡m¡-1-t++1IT ·"+_1_·· l·¡··jn ! I .. I j' 1 I - " ij::cc'~' 'I "'¡"hf · 'tve- -H- .... ". '.. '·++I¡n,,,'++_Llmmui+ n ... LL I+-rt+·j .. ....... ...... r' ¡ " CC~ lt~±~'l¡;.;",i,~~.4 : - \ ~ "Iu" ..._.L j I i j' 3500 -1 In:! ~ ,---'. I.: -, ¡n_ ¡: Î -1-1 1: - ..,. 'I 'll¡ H ' "I, ' = kPL .. ... J-+ i¥Dìr: 8 3.43'!M:)'13*4¡4~1"VJ!¡ ~r' .. im ... I ¡ ,ì i I I I . -.. I' ~.. Ta~ ¡ JJDir471OC1:bL.51IMo.3g701IS'T = .... I . .. t ~: t f· Lt. n .Lll.ll.··.:.. =. in' 1 : LJ lli:t:85i~.sk...iJ,,·9~2J¡;£;j).·..:.. ~ 3000 . J f ; i - L t j +¡....L-I.l '. -....+. ~ - .., I·· MÞ dTh¡ I, ...n ¡ yj-fm: ~ = -:' . ..\ .. n·i·¡nL¡lJ~i·+·+·riTJ~-.l.·~~I o . ... I ' I j I ~ = .·..n. I' . \ \\ _ ... ·····\r.siãliD¡r.6¡i~'; ¡Ü'6i9~;1D¡j6i61:fYD~.t i ,,"": , . \ \ ,rl =~.:;;;;¡;;:;t;;,;,;,,1;~Ftr '. L--, -+-. ,.Lu--t I - 1": !--.:. \\ f -, ".n. I + ·0 -J'. MPI·fl:U TI···· I i- _.. l\,~ ~/ ,·1· un ... -.. - , " ~ ~ I! r ."..' HIOf ·1"" "MO, t, 'Jill" : ==.. 'Ll +iLJ....j-· . j _ t ..n .+ ~ - .. _ I, 1.1 . f i· ±'En4-Dir : 149r.<fI' \1Ð, 19J8. 6' 1'¥D· ..,. """ . i\:} : ----;-, ! iLI-[,:'1 :__1_ ,'j- I I 'I 1 I I 1 I . =. i...... (\!\ il i J 1 f ~1·T;ta~~ r~~~~' :727~~ri~'9f¡~6~r L. n n ... !\ . f I 1 I '! I I.·I-LI..·I·..·I... ... ... =.. ,;:', Iii I t t ¡ ¡f¡+I+-+--' n. ..;. - 1\ c m ".I, l' ;);,¡;",; ;,;'Gj;.~f~' - i· ,\¡... I , - I I ì·' 11,·,··LLI. ..¡..'.uu tm~. \i . I . I I ' 500 - I \ !\ 1 i I 1 11 t ut+ju¡-tu·f·t+ r .m.C. -I.. u. tu. ~., \: ¡ i : l+': 1..I¡nl+ i··· \\. 1'\ 1m f f I ··.··f +1 ut+m _u ..u I.u~..\ + .. ....++1 ..mul. -i--~ -'= ~ b- i' \tl~tn. -l .¡t_.tl.. 'u.n 1\ i .m.m I I I I J -5000 -4500 -4000 -3500 West(-)/East(+) [500ft/in] . . BP-GDB BP Planning Report Company: Field: Site: Well: Wellpath: Plan: BP Amoco Milne Point M Pt I Pad Plan MPI-14 Odin MPI-14 L 1 MPI-14 L1 WP13 Date: 6/23/2004 Time: 10:00:06 Page: 1 Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin, True North Vertical (IVD) Reference: 68.0068.0 Section (VS) Reference: Well (0.00N,0.00E.312.19Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Principal: Yes Date Composed: Version: Tied-to: 12/1412001 38 From: Definitive Path Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: M Pt I Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6008388.01 ft 550245.83 ft Latitude: 70 26 Longitude: 149 35 North Reference: Grid Convergence: 1.282 N 25.422 W True 0.39 deg Well: Plan MPI-14 Odin Slot Name: Well Position: +N/-S 1065.75 ft Northing: 6009460.88 ft Latitude: 70 26 11.762 N +E/-W 1076.55 ft Easting : 551315.07 ft Longitude: 149 34 53.827 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 9871.00 3993.00 4.500 6.125 4 1/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 BPRF 0.00 0.00 0.00 TUZC 0.00 0.00 0.00 Ugnu-MA 0.00 0.00 0.00 Ugnu-MB 1 0.00 0.00 0.00 Ugnu-MB2 0.00 0.00 0.00 Ugnu-MC 0.00 0.00 0.00 SBF2-Top NA 0.00 0.00 0.00 SBF21-Base NA 0.00 0.00 0.00 SBF1-Top NB 0.00 0.00 0.00 SBF12-Base NB 0.00 0.00 0.00 SBE4-NC 0.00 0.00 0.00 SBE2-NE 0.00 0.00 0.00 SBE1-NF 0.00 0.00 7259.67 3933.00 TSBD-Top OA 0.00 0.00 8251.09 3968.00 TSBC-Base OA 0.00 0.00 9174.54 3998.00 TSBB-Top OB 0.00 0.00 - -_..------------------------ ---------------------- - .__..~--_._--_._._----- Targets Map Map <-- Latitude -> <- Longitude -> Name Description TVD +N/-S +EI-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft MPI-14 L 1 T1 B 3948.00 2216.66 -4690.38 6011645.00 546610.00 70 26 33.548 N 149 37 11.523 W MPI-14 L1 T2A 3973.00 2887.74 -4835.78 6012315.00 546460.00 70 2640.147 N 149 37 15.804 W MPI-14 L 1 T3 A 3973.00 3249.54 -4800.29 6012677.00 546493.00 70 26 43.706 N 149 37 14.769 W MPI-14 L 1 T5 3993.00 4261.98 -4701.31 6013690.00 546585.00 70 26 53.663 N 149 37 11.882 W MPI-14 L 1 T4 A 4003.00 3717.29 -4755.07 6013145.00 546535.00 70 26 48.306 N 149 37 13.450 W · e BP-GDB BP Planning Report Company: BP Amoco Date: 6/23/2004 Time: 10:00:06 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin, True North Site: M Pt I Pad Vertical (TVD) Reference: 6B.00 6B.0 Well: Plan MPI-14 Odin Section (VS) Reference: Well (0.00N,O.00E,312.19Azi) Wellpath: MPI-14 L1 Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/10OO deg/10OO deg/10OO deg 7259.00 74.75 334.51 3932.B2 1725.21 -44B1.12 0.00 0.00 0.00 0.00 7279.00 77.12 334.90 3937.68 1742.75 -44B9.41 12.00 11.B5 1.93 9.00 7499.09 92.23 337.95 395B.06 1943.02 -4576.73 7.00 6.B6 1.39 11.54 7720.10 92.23 337.95 3949.47 2147.71 -4659.65 0.00 0.00 0.00 0.00 7795.63 90.00 334.00 394B.00 2216.66 -4690.38 6.00 -2.95 -5.23 -119.39 MPI-14 L 1 T1 B 7980.93 B6.74 344.63 3953.29 23B9.67 -4755.72 6.00 -1.76 5.74 107.17 B161.94 B6.74 344.63 3963.60 2563.93 -4B03.60 0.00 0.00 0.00 0.00 84B9.0B 90.00 4.00 3973.00 28B7.74 -4B35.78 6.00 1.00 5.92 BO.BO MPI-14 L 1 T2A B519.56 90.67 5.70 3972.B2 2918.10 -4833.21 6.00 2.20 5.5B 68.46 B744.51 90.67 5.70 3970.19 3141.93 -4810.B6 0.00 0.00 0.00 0.00 B852.70 B6.35 5.52 3973.00 3249.54 -4800.29 4.00 -4.00 -0.16 -177.64 MPI-14 L 1 T3 A B873.43 B5.52 5.53 3974.47 3270.12 -4798.30 4.00 -4.00 0.02 179.73 91B5.54 B5.52 5.53 3998.86 3579.B3 -476B.34 0.00 0.00 0.00 0.00 9323.75 91.05 5.50 4003.00 3717.29 -4755.07 4.00 4.00 -0.02 -0.27 MPI-14 L 1 T4 A 9327.16 91.05 5.64 4002.94 3720.6B -4754.74 4.00 0.00 4.00 90.00 9871.18 91.05 5.64 3993.00 4261.9B -4701.31 0.00 0.00 0.00 0.00 MPI-14 L 1 T5 Survey MD loci Azim TVD Sys TVD N/S EIW DLS MapN MapE TooIl'Comn ft deg deg ft ft ft ft deg/100ft ft ft '"' 7259.00 74.75 334.51 3932.B2 3B64.B2 1725.21 -4481.12 0.00 6011155.05 546B22.62 Start Dir 12/1 0C' : 72! 7259.67 74.B3 334.53 3933.00 3B65.00 1725.BO -44B 1.40 12.00 6011155.64 546B22.34 TSBD-Top OA 7275.00 76.65 334.B2 3936.78 3B6B.7B 1739.22 -44B7.75 12.00 6011169.02 546B15.B9 MWD+IFR+M3 7279.00 77.12 334.90 3937.6B 3869.6B 1742.75 -4489.41 12.00 6011172.53 546B14.21 Start Dir 7/100' : 727! 7300.00 78.56 335.20 3942.11 3B74.11 1761.36 -4498.07 7.00 6011191.08 546B05.43 MWD+IFR+MS 7350.00 B1.99 335.90 3950.55 3882.55 1806.22 -451B.46 7.00 6011235.79 546784.73 MWD+IFR+M3 7400.00 B5.42 336.59 3956.03 3BBB.03 1B51.70 -453B.47 7.00 6011281.13 546764.40 MWD+IFR+M3 7450.00 BB.B6 337.2B 395B.52 3B90.52 1B97.64 -455B.04 7.00 6011326.93 546744.53 MWD+IFR+M3 7499.09 92.23 337.95 395B.06 3B90.06 1943.02 -4576.73 7.00 6011372.1B 546725.52 End Dir : 7493..09' M 7600.00 92.23 337.95 3954.14 38B6.14 2036.4B -4614.59 0.00 6011465.36 546687.03 MWD+IFR+M3 7700.00 92.23 337.95 3950.25 3BB2.25 2129.09 -4652.11 0.00 6011557.71 54664B.BB MWD+IFR+MS 7720.10 92.23 337.95 3949.47 3BB1.47 2147.71 -4659.65 0.00 6011576.27 546641.21 Start Dir 6/1 00' : 772( 7750.00 91.35 336.3B 394B.54 3B80.54 2175.25 -4671.24 6.00 6011603.73 546629.42 MWD+IFR+M3 7795.63 90.00 334.00 394B.00 3BBO.00 2216.66 -4690.38 6.00 6011645.00 546610.00 MPI-14 L 1 T1 E 7BOO.00 B9.92 334.25 3948.00 38BO.00 2220.59 -4692.29 6.00 601164B.92 54660B.07 MWD+IFR+MS 7850.00 B9.04 337.12 3948.46 3BBO.46 2266.15 -4712.88 6.00 6011694.33 5465B7.17 MWD+IFR+MS 7900.00 BB.15 339.99 3949.6B 3B81.6B 2312.67 -4731.15 6.00 6011740.72 54656B.5B MWD+IFR+MS 7950.00 B7.2B 342.86 3951.68 3B83.6B 2360.02 -4747.07 6.00 6011787.96 546552.34 MWD+IFR+MS 7980.93 B6.74 344.63 3953.29 3BB5.29 23B9.67 -4755.72 6.00 6011B17.54 546543.49 End Dir : 79B).93' M BOOO.OO B6.74 344.63 3954.38 3886.38 2408.03 -4760.76 0.00 6011835.B7 54653B.32 MWD+IFR+M S 8100.00 86.74 344.63 3960.07 3892.07 2504.30 -47B7.22 0.00 6011931.94 546511.20 MWD+IFR+M3 B161.94 B6.74 344.63 3963.60 3895.60 2563.93 -4803.60 0.00 6011991.45 546494.40 Start Dir 6/100' : 816' B200.00 B7.10 346.89 3965.64 3897.64 2600.76 -4B12.95 6.00 601202B.22 546484.B1 MWD+IFR+M3 B250.00 B7.59 349.85 3967.95 3B99.95 2649.68 -4B23.02 6.00 6012077.06 546474.41 MWD+IFR+M 5 B251.09 B7.60 349.92 3968.00 3900.00 2650.75 -4B23.21 6.00 601207B.13 546474.21 TSBC-Base C A B300.00 88.09 352.81 3969.84 3901.B4 2699.07 -4830.54 6.00 6012126.39 546466.54 MWD+IFR+M S 8350.00 88.59 355.77 3971.29 3903.29 2748.79 -4835.51 6.00 6012176.07 546461.23 MWD+IFR+MS B400.00 B9.10 35B.73 3972.30 3904.30 279B.72 -4837.91 6.00 6012225.9B 54645B.49 MWD+IFR+M3 B450.00 B9.60 1.69 3972.86 3904.B6 2B4B.71 -4B37.73 6.00 6012275.96 54645B.33 MWD+IFR+M3 B4B9.0B 90.00 4.00 3973.00 3905.00 2887.74 -4835.7B 6.00 6012315.00 546460.00 MPI-14 L 1 T2A 8500.00 90.24 4.61 3972.98 3904.98 289B.63 -4834.97 6.00 6012325.89 546460.75 MWD+IFR+M3 B519.56 90.67 5.70 3972.B2 3904.82 2918.10 -4B33.21 6.00 6012345.38 546462.37 End Dir : B5B.56' M B600.00 90.67 5.70 3971.88 3903.88 2998.14 -4B25.22 0.00 6012425.47 546469.81 MWD+IFR+M3 B700.00 90.67 5.70 3970.71 3902.71 3097.64 -4815.29 0.00 6012525.02 546479.05 MWD+IFR+MS B744.51 90.67 5.70 3970.19 3902.19 3141.93 -4B10.B6 0.00 6012569.33 5464B3.17 Start Dir 4/100' : B74· . . BP-GDB BP Planning Report Company: BP Amoco Date: 6/23/2004 Time: 10:00:06 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin, True North Site: M pt I Pad Vertical (TVD) Reference: 68.00 68.0 Well: Plan MPI-14 Odin Section (VS) Reference: Well (0.00N.0.00E.312.19Azi) Wellpath: MPI-14 L 1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S EfW DLS MapN MapE TooU:omn ft deg deg ft ft ft ft deg/1 000 ft ft 8800.00 88.45 5.61 3970.61 3902.61 3197.14 -4805.40 4.00 6012624.58 546488.26 MWD+IFR+M 5 8852.70 86.35 5.52 3973.00 3905.00 3249.54 -4800.29 4.00 6012677.00 546493.00 MPI-14 L 1 T3 A 8873.43 85.52 5.53 3974.47 3906.47 3270.12 -4798.30 4.00 6012697.59 546494.85 End Dir : 8873A3' M 8900.00 85.52 5.53 3976.55 3908.55 3296.49 -4795.75 0.00 6012723.97 546497.22 MWD+IFR+MS 9000.00 85.52 5.53 3984.36 3916.36 3395.72 -4786.15 0.00 6012823.26 546506.14 MWD+IFR+MS 9100.00 85.52 5.53 3992.17 3924.17 3494.95 -4776.55 0.00 6012922.54 546515.05 MWD+IFR+MS 9174.54 85.52 5.53 3998.00 3930.00 3568.92 -4769.39 0.00 6012996.56 546521.70 TSBB-Top 05 9185.54 85.52 5.53 3998.86 3930.86 3579.83 -4768.34 0.00 6013007.47 546522.68 Start Dir 4/100' : 918! 9200.00 86.10 5.52 3999.92 3931.92 3594.18 -4766.95 4.00 6013021.83 546523.97 MWD+IFR+MS 9300.00 90.10 5.50 4003.24 3935.24 3693.65 -4757.34 4.00 6013121.35 546532.89 MWD+IFR+MS 9323.75 91.05 5.50 4003.00 3935.00 3717.29 -4755.07 4.00 6013145.00 546535.00 MPI-14 L 1 T4 A 9327.16 91.05 5.64 4002.94 3934.94 3720.68 -4754.74 4.00 6013148.40 546535.31 End Dir : 9327.16' M 9400.00 91.05 5.64 4001.61 3933.61 3793.15 -4747.58 0.00 6013220.91 546541.96 MWD+IFR+M3 9500.00 91.05 5.64 3999.78 3931.78 3892.65 -4737.76 0.00 6013320.47 546551.10 MWD+IFR+M3 9600.00 91.05 5.64 3997.95 3929.95 3992.15 -4727.94 0.00 6013420.02 546560.23 MWD+IFR+Mt 9700.00 91.05 5.64 3996.13 3928.13 4091.65 -4718.12 0.00 6013519.58 546569.37 MWD+IFR+M 9800.00 91.05 5.64 3994.30 3926.30 4191.15 -4708.30 0.00 6013619.14 546578.50 MWD+IFR+M3 9871.00 91.05 5.64 3993.00 3925.00 4261.80 -4701.33 0.00 6013689.82 546584.98 4 1/2" 9871.18 91.05 5.64 3993.00 3925.00 4261.98 -4701.31 0.00 6013690.00 546585.00 MPI-14 L 1 T5 WELL DETAILS ANTI-COLLlSION SETTINGS COMPANY DETAILS BPAmo<o SURVEYPROORAM Depth Fm Depth To StlJ'W:yiPlan 33.00 1000.00 Planned: MPI_14 WPI6 V41 1000.00 9880.] 1 Planned: MPI-14 WPI6 V41 T001 CB.(JYRO-MS MWD+]FR+MS . SECTION DETAILS So< MD !no Azi TVD .N/<; ...FJ-w Dl<ß TFace VS<c T"", I 33,00 O.lJO 0.00 33.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 330.00 300.00 0.00 0.00 0.00 330.00 0.00 3 600.00 4.51 330.00 599.69 ]0.22 ·5.90 1.50 330.00 1114 4 800.00 7.47 28910 798.66 2JJ1 .22.\2 2.50 28334 30.70 , 1180.00 18.48 275.00 ]]68.47 34.73 ·105.72 3.00 336.80 101.65 6 1900.00 40.10 275.00 1792.70 65.25 -454.55 3.00 0.00 380.58 7 2040.28 40.10 275.00 1900.00 73.12 -544.56 0.00 0.00 452.56 , 276\.45 68.77 270.96 2315.2] 99.55 ·]124.30 4.00 -7.82 899.83 , 4732.09 68.17 270.96 3028.83 130.30 ·2960.93 0.00 0.00 228110 10 6180.19 "'.00 333.50 3600.00 805.00 -4030.00 4.00 102.14 3526.40 11 6621.82 "'.00 333.50 375817 1]73.98 -4213.97 0.00 0.00 3910.52 12 6765.49 74.10 332.75 3803.00 1295.10 -4275.67 4.00 .7.28 4037.99 MPI·14T] \3 6808.13 74.15 334.51 38]4.23 1J32.55 -4293.94 4.00 88.60 407617 14 7386.68 74.15 334.51 3966.41 1836.41 -4534.13 0.00 0.00 4592.64 I' 7531.25 SO.OO 337.00 3998.00 1965.00 -4592.00 4.00 25.09 4721.88 MP!·14 T2 B 16 7581.25 80.00 337.00 4006.68 201033 -4611.24 0.00 0.00 4766.58 17 7765.74 93.15 334,47 4017.67 2177.82 -4686.77 726 ·10.96 4935.03 I' 7789.85 93.15 334,47 401635 2199.55 -4697.15 0.00 0.00 495731 I' 7940.02 93.20 345.00 4008.00 2340.00 -4749.00 7.00 89.46 5090.06 MPI-14 T3 B 20 8076j8 85.13 346J3 4009.99 2471.99 -4782.73 6.00 170.66 5203.71 21 819]J2 85.13 34633 4019.92 2585.21 -4810.27 0.00 0.00 5300.15 22 8498.50 90.00 4.00 4033.00 2887.74 -4835.78 6.00 751)7 5522.24 MPJ.]4T4 2J 8527.60 90A3 ,.'" 4032.89 2916.73 -483333 6.00 75.60 5539.89 24 8775.01 90.43 ,.'" 4031.02 3]62.91 -4808.80 0.00 0.00 5687.07 " 8862.09 86.95 5.52 4033.00 3249.54 -4800.29 4.00 ·17713 5738.95 MP!-14 TS B 26 8872.82 '60S3 5.53 4033.61 3260.21 -4799.26 4.00 179.64 5745j5 27 9232.80 86.53 5.53 4055043 3617.85 -4764.66 0.00 0.00 5959.93 28 9332.75 90.52 5.s0 4058.00 3717.29 -4755.07 4.00 .oJ6 6019.60 MPI·14T6 29 9336.16 90.52 '.64 4057.97 3720.68 -4754.74 4.00 90.00 6021.64 30 9880.11 90.52 ,.64 4053.00 4261.98 -4701.31 0.00 0.00 6345.62 MP¡'¡4T7 Nomo Plan MP-14 Odin +N/-S +FJ·W 1065.75 1076.55 ....... ..."'" 551315.07 Lalitude Longitude Slot 70026'11.762N 14C}034'53.827W NlA Interpolation Method:MD Depth Range From: 33.00 Maximum Range: 1184.71 Interval: 50.00 TQ: 9880.11 Reference: Plan: MPI-14 WPI6 6009460.88 Calculation Method: Minimwn Curvature Error System: ISCWSA Scan Method: Tmv Cylind6r Nonh Error Surface: Elliptical + Casing Warning MetOOd: Rules Based -320 -300 From o o 500 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 9000 010000 11000 2000 000 Colour ToMD o 500 1000 1500 2000 2500 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 -250 -200 -150 -100 -50 -0 -50 -100 -150 -200 -250 -300 -320 WELLPATH DETAILS MPI-14 Rig: Ref. Datum: 68.00 68.00fI V.Seelion ""'10 312.W ~~ ~ 0.00 0.00 - LEGEND MPI.()3 (MPI...()3), Major Risk MPI.()4A (MPI..Q4A), Major Risk MP[.{)4 (MPI-04), Major Risk MPI.04 (MPI-04A), Major Risk MPI..()4 (MPI...Q4AL]). MajlX" Risk MPI..{)4 (MPI·04APBI), Major Risk MP(.()4 {MPI-Q4PBIJ, Major Risk MPI..Q6 (MPI..()6), Major Risk MPI..()7 (MPI..o7). Major Risk MP!..o8 (MPI·08), Major Risk MPI..09 (MPI..09). Major Risk MP·lO (MPI·IO), Major Risk MP·lO (MP_IOA), ~jor Risk MPI·] (MPi·1 I), MaJOl" Risk MPr·11 (MPI·IILI). Major Risk MPI·12 (MPI·IZ). Major Risk MP¡·IZ (MPI·12LI), Major Risk MPI·IZ (MP\·IZPBI), Major Risk MPI·IJ (MPI·13). Major Risk MPJ-Lorelei (Plan MP-lorelei). Major Risk Plan MPI·17 Thor (Plan MPI-17 LI), Major Risk Plan MP!·17 Thor (Plan MP[-l7 L2), Major Risk Plan MPI·]7 Thor (Plan MPI-17), Major Risk Plan MP!·LINK (Plan MPJ·LINK). Major Risk Plan MPI·Tank (plan MP·Tank), Major Risk Plan MPJ·Uller (Plan MPJ.lJlJer), Major Risk Plan MPI·Valhalla (Plan MPI·Valhalla), Major Risk MPJ-20 (MPJ-20), Major Risk MPJ-20 (MPJ-20A), Major Risk Plan MPJ·26 (Plan MPJ-26). Major Risk Plan MPJ·26(PIa.n MPJ-26L1), Ma.jorRisk Plan MPJ.26 (PIa.n MPJ-26L2), MajOr Risk Plan MPJ·Switch (Plan MPJ..switch), Major Risk MPI·14 MPI·14WPI6 Starting From TVD 33.00 -- . . Halliburton Company Anticollision Report Company: Field: Reference Site: Reference Well: Reference Wellpath: BP Amoco Milne Point M Pt I Pad Plan MPI-14 Odin MPI-14 Date: 4/24/2004 Time: 11:37:05 Page: Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: Plan MPI-14 Odin, True North 68.00 68.0 GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 ofreference Interpolation Method: MD Interval: 50.00 ft Depth Range: 33.00 to 9880.11 ft Maximum Radius: 1184.71 ft Reference: Error Model: Scan Method: Error Surface: Db: Oracle Plan: MPI-14 WP16 & NOT PLANNED P~')GRJ ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 2769.17 2318.00 10.750 13.500 103/4" 7531.25 3998.00 7.625 9.875 7 -51B" 9876.00 4053.04 4.500 6.750 4 1/2" Plan: MPI-14 WP16 Date Composed: 3/29/2004 Version: 41 Principal: Yes Tied-to: From Well Ref. Point Summary «: Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft MPt Pad MPI-03 MPI-03 V1 457.80 450.00 245.93 16.01 229.91 Pass: Major Risk MPt Pad MPI-04A MPI-04A V1 459.39 450.00 183.54 15.08 168.45 Pass: Major Risk M pt Pad MPI-04 MPI-04 V5 444.20 450.00 183.03 14.58 168.45 Pass: Major Risk M pt Pad MPI-04 MPI-04A V5 444.20 450.00 183.03 14.58 168.45 Pass: Major Risk MPt Pad MPI-04 MPI-04AL 1 V2 444.20 450.00 183.03 14.58 168.45 Pass: Major Risk MPt Pad MPI-04 MPI-04APB1 V1 444.20 450.00 183.03 14.58 168.45 Pass: Major Risk MPt Pad MPI-04 MPI-04PB1 V3 444.20 450.00 183.03 14.58 168.45 Pass: Major Risk M Pt Pad MPI-06 MPI-06 V10 497.62 500.00 212.20 15.42 196.78 Pass: Major Risk MPt Pad MPI-07 MPI-07 V1 497.44 500.00 156.81 18.75 138.05 Pass: Major Risk MPt Pad MPI-08 MPI-08 V3 613.58 650.00 117.32 15.70 101.62 Pass: Major Risk MPt Pad MPI-09 MPI-09 V12 353.23 350.00 331.47 10.54 320.93 Pass: Major Risk M Pt Pad MPI-10 MPI-10 V8 3830.53 4300.00 242.55 194.30 48.26 Pass: Major Risk M Pt Pad MPI-10 MPI-10A V1 2138.74 2500.00 326.57 50.95 275.62 Pass: Major Risk MPt Pad MPI-11 MPI-11 V4 695.39 700.00 90.49 17.55 72.94 Pass: Major Risk MPt Pad MPI-11 MPI-11L1 V2 695.39 700.00 90.49 17.55 72.94 Pass: Major Risk MPt Pad MPI-12 MPI-12 V10 403.62 400.00 63.89 10.20 53.69 Pass: Major Risk MPt Pad MPI-12 MPI-12L1 V11 403.62 400.00 63.89 10.09 53.80 Pass: Major Risk MPt Pad MPI-12 MPI-12PB1 V4 403.62 400.00 63.89 10.20 53.69 Pass: Major Risk MPt Pad MPI-12 Plan MPI-12 A (ThorT 33.30 28.70 60.14 0.00 60.14 Pass: NOERRORS MPt Pad MPI-13 MPI-13 V6 701.03 700.00 30.05 17.60 12.45 Pass: Major Risk M Pt I Pad MPI-Lorelei Plan MPI-Lorelei V1 PI 1467.67 1550.00 114.73 38.37 76.36 Pass: Major Risk M pt I Pad Plan MPI-14 Odin MPI-14 L 1 VO Plan: MPI 2700.00 2700.00 0.00 0.00 0.00 FAIL: NOERRORS M Pt I Pad Plan MPI-14 Odin MPI-14 L2 VO Plan: MPI 2700.00 2700.00 0.00 0.00 0.00 FAIL: NOERRORS M PtI Pad Plan MPI-14 Odin Plan MPI-14 PB1 old V1 33.00 33.00 0.00 0.00 0.00 FAIL: NOERRORS M Pt I Pad Plan MPI-17 Thor Plan MPI-17 L 1 VO Plan 6215.78 7750.00 436.31 125.12 311.19 Pass: Major Risk M Pt I Pad Plan MPI-17 Thor Plan MPI-17 L2 VO Plan 6169.16 7700.00 371.23 125.15 246.08 Pass: Major Risk M PtI Pad Plan MPI-17 Thor Plan MPI-17 V5 Plan: M 6080.66 7650.00 245.76 135.86 109.90 Pass: Major Risk M PtI Pad Plan MPI-Freya Plan MPI-Freya VO Plan 3019.53 3200.00 91.94 0.00 91.94 Pass: NO ERRORS M PtI Pad Plan MPI-LlNK Plan MPI-LlNK VO Plan: 835.91 900.00 408.81 25.00 383.81 Pass: Major Risk M PtI Pad Plan MPI-Tank Plan MPI-Tank VO Plan: 908.77 950.00 205.01 25.10 179.91 Pass: Major Risk M Pt I Pad Plan MPI-Uller Plan MPI-Uller V1 Plan 589.04 600.00 215.63 16.83 198.79 Pass: Major Risk MPtlPad Plan MPI-Valhalla Plan MPI-Valhalla VO P 6824.31 6650.00 276.69 108.72 167.98 Pass: Major Risk M pt J Pad MPJ-20 MPJ-20 V1 Out of range M Pt J Pad MPJ-20 MPJ-20A V8 Out of range M Pt J Pad Plan MPJ-26 Plan MPJ-26 V3 Plan: M Out of range M pt J Pad Plan MPJ-26 Plan MPJ-26L 1 VO Plan: Out of range M Pt J Pad Plan MPJ-26 Plan MPJ-26L2 V1 Plan: Out of range M Pt J Pad Plan MPJ-Switch Plan MPJ-Switch VO Pia Out of range . . Halliburton Company Anticollision Report ,- Company: BP Amoco Date: 4/24/2004 Time: 11:37:05 Page: 2 Field: Milne Point Reference Site: M PI I Pad Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin, True North Reference Well: Plan MPI-14 Odin Vertical (TVD) Reference: 6B.00 68.0 Reference Wellpatb: MPI-14 Db: Oracle Site: M pt I Pad Well: MPI-03 Rule Assigned: Major Risk Wellpath: MPI-03 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF()..HS Casing/HS>istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 33.50 33.50 20.00 20.00 0.00 0.00 92.93 92.93 240.41 1.02 239.39 Pass 63.50 63.50 50.00 50.00 0.10 0.07 92.93 92.93 240.46 1.BO 23B.65 Pass 113.50 113.50 100.00 100.00 O.2B 0.20 92.94 92.94 240.72 3.27 237.45 Pass 163.50 163.50 150.00 150.00 0.56 0.3B 92.96 92.96 241.06 5.13 235.94 Pass 213.50 213.50 200.00 200.00 0.82 0.57 93.01 93.01 241.43 6.9B 234.46 Pass 263.49 263.49 250.00 249.99 1.05 0.77 93.07 93.07 241.83 B.7B 233.05 Pass 313.04 313.04 300.00 299.99 1.2B 0.98 93.14 123.14 242.26 10.59 231.66 Pass 361.34 361.34 350.00 349.99 1.50 1.20 93.32 123.32 242.99 12.40 230.59 Pass 409.61 409.59 400.00 399.9B 1.72 1.42 93.64 123.64 244.16 14.21 229.95 Pass 457.BO 457.75 450.00 449.97 1.94 1.64 94.1B 124.1B 245.93 16.01 229.91 Pass 505.86 505.76 500.00 499.94 2.16 1.87 94.94 124.94 248.41 17.81 230.59 Pass 553.65 553.46 550.00 549.B3 2.3B 2.09 96.09 126.09 252.0B 19.60 232.4B Pass 600.97 600.65 600.00 599.59 2.59 2.31 97.61 127.91 257.17 21.37 235.BO Pass 645.35 644.89 650.00 649.22 2.73 2.53 99.24 142.30 263.84 22.86 240.99 Pass 689.40 6BB.76 700.00 69B.69 2.86 2.76 100.8B 154.34 272.29 24.33 247.97 Pass 733.04 732.17 750.00 747.97 2.96 2.98 102.52 164.14 2B2.38 25.6B 256.70 Pass 776.19 775.04 BOO.OO 797.02 3.06 3.20 104.18 172.10 294.07 26.98 267.10 Pass B1B.13 B16.63 850.00 845.78 3.17 3.42 105.B1 178.16 307.67 28.29 279.3B Pass 858.50 B56.54 900.00 894.18 3.29 3.65 107.42 1B2.59 323.40 29.61 293.79 Pass 897.88 B95.37 950.00 942.10 3.42 3.B7 109.04 186.35 341.2B 30.91 310.37 Pass 936.17 932.9B 1000.00 989.47 3.49 4.10 110.65 1B9.65 361.25 32.02 329.23 Pass 973.44 969.45 1050.00 1036.29 3.56 4.33 112.24 192.59 382.97 33.0B 349.B8 Pass 1009.67 1004.76 1100.00 10B2.57 3.61 4.55 113.7B 195.25 406.2B 34.07 372.22 Pass 1044.97 1039.01 1150.00 1128.42 3.61 4.78 115.22 197.61 431.09 34.90 396.20 Pass 1079.37 1072.24 1200.00 1173.88 3.62 5.00 116.52 199.70 457.30 35.70 421.60 Pass 1113.02 1104.59 1250.00 1219.10 3.62 5.23 117.71 201.57 484.55 36.47 448.0B Pass 1145.97 1136.09 1300.00 1264.0B 3.63 5.45 118.77 203.23 512.74 37.22 475.52 Pass 1177.77 1166.35 1350.00 130B.44 3.63 5.68 119.79 204.75 542.39 37.95 504.43 Pass 1207.76 1194.72 1400.00 1352.05 3.65 5.B6 120.7B 205.7B 573.5B 38.54 535.05 Pass 1237.00 1222.25 1450.00 1395.52 3.66 5.93 121.67 206.67 605.54 3B.B5 566.70 Pass 1265.77 1249.17 1500.00 1439.07 3.67 5.96 122.45 207.45 637.96 39.02 59B.94 Pass 1294.24 1275.67 1550.00 14B2.84 3.69 5.86 123.13 208.13 670.55 38.90 631.65 Pass 1322.48 1301.79 1600.00 1526.B6 3.70 5.76 123.72 20B.72 703.22 3B.79 664.43 Pass 1350.45 1327.50 1650.00 1571.11 3.72 5.66 124.24 209.24 736.01 3B.69 697.32 Pass 1378.0B 1352.74 1700.00 1615.50 3.75 5.62 124.69 209.69 76B.97 3B.71 730.25 Pass 1400.00 1372.64 1750.00 1659.33 3.76 5.71 125.15 210.15 B02.99 39.01 763.9B Pass 1430.07 1399.78 1 BOO.OO 1702.36 3.79 5.85 125.63 210.63 83B.22 39.46 79B.76 Pass 1454.64 1421.79 1B50.00 1745.01 3.82 6.10 126.08 211.08 B74.21 40.14 B34.0B Pass 147B.56 1443.09 1900.00 1787.46 3.85 6.33 126.51 211.51 910.75 40.74 B70.01 Pass 1500.00 1462.06 1950.00 1829.86 3.B7 6.52 126.90 211.90 947.70 41.19 906.51 Pass 1524.87 1483.93 2000.00 1872.24 3.91 6.70 127.24 212.24 9B5.03 41.66 943.37 Pass 1547.03 1503.27 2050.00 1914.37 3.94 6.88 127.56 212.56 1023.04 42.11 980.92 Pass 156B.37 1521.79 2100.00 1956.19 3.97 7.06 127.85 212.85 1061.79 42.59 1019.20 Pass 1589.14 1539.69 2150.00 1997.91 4.00 7.26 12B.11 213.11 1100.99 43.13 1057.B6 Pass 1600.00 1549.01 2200.00 2039.59 4.02 7.46 128.35 213.35 1140.62 43.63 1096.99 Pass 1629.10 1573.81 2250.00 20B1.09 4.07 7.68 12B.56 213.56 11BO.56 44.21 1136.34 Pass . . Halliburton Company Anticollision Report Company: BP Amoco Date: 4/24/2004 Time: 11 :37:05 Page: 3 Field: Milne Point Reference Site: M PtI Pad Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin, True North Reference Well: Plan MPI-14 Odin Vertical (TVD) Reference: 68.00 68.0 Reference Wellpath: MPI-14 Db: Oracle Site: M Pt I Pad Well: MPI-04A Rule Assigned: Major Risk Wellpath: MPI-04A V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HS>istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 33.50 33.50 19.90 19.90 0.00 0.00 92.97 92.97 179.66 1.02 178.64 Pass 63.60 63.60 50.00 50.00 0.10 0.07 92.96 92.96 179.67 1.81 177.87 Pass 113.60 113.60 100.00 100.00 0.28 0.18 92.93 92.93 179.73 3.22 176.52 Pass 163.60 163.60 150.00 150.00 0.56 0.31 92.92 92.92 179.86 4.90 174.96 Pass 213.60 213.60 200.00 200.00 0.82 0.44 92.93 92.93 180.06 6.60 173.46 Pass 263.60 263.60 250.00 250.00 1.05 0.61 92.94 92.94 180.30 8.31 171.99 Pass 313.26 313.26 300.00 300.00 1.28 0.79 92.95 122.95 180.59 10.03 170.55 Pass 361.99 361.99 350.00 350.00 1.51 0.98 93.08 123.08 181.15 11.76 169.39 Pass 410.70 410.69 400.00 400.00 1.73 1.16 93.35 123.35 182.10 13.46 168.64 Pass 459.39 459.35 450.00 449.99 1.95 1.32 93.54 123.54 183.54 15.08 168.45 Pass 508.05 507.95 500.00 499.95 2.17 1.48 93.59 123.59 185.53 16.72 168.81 Pass 556.65 556.46 550.00 549.82 2.39 1.65 93.35 123.35 188.24 18.38 169.86 Pass 604.93 604.60 600.00 599.56 2.60 1.83 92.81 124.33 191.73 20.02 171.70 Pass 650.96 650.47 650.00 649.18 2.74 2.03 91.96 136.47 196.29 21.47 174.82 Pass 696.67 696.00 700.00 698.68 2.88 2.23 90.80 145.77 202.18 22.92 179.25 Pass 741.95 741.03 750.00 747.98 2.98 2.44 89.32 152.37 209.57 24.27 185.30 Pass 786.67 785.44 800.00 797.03 3.08 2.65 87.56 156.79 218.61 25.60 193.01 Pass 830.07 828.44 850.00 845.78 3.20 2.88 85.60 158.86 229.60 26.99 202.62 Pass 872.37 870.24 900.00 894.18 3.34 3.10 83.57 159.55 242.78 28.38 214.40 Pass 913.89 911.11 950.00 942.37 3.45 3.32 81.64 159.70 257.91 29.69 228.22 Pass 954.59 951.03 1000.00 990.39 3.53 3.54 79.88 159.58 274.85 30.86 243.99 Pass 994.46 989.95 1050.00 1038.16 3.60 3.76 78.20 159.22 293.32 31.97 261.35 Pass 1033.42 1027.82 1100.00 1085.63 3.61 3.97 76.58 158.68 313.25 32.88 280.37 Pass 1071.23 1064.39 1150.00 1132.61 3.62 4.19 74.98 157.98 335.04 33.73 301.31 Pass 1107.75 1099.53 1200.00 1179.01 3.62 4.42 73.42 157.18 358.80 34.57 324.23 Pass 1142.77 1133.04 1250.00 1224.71 3.63 4.66 71.93 156.33 384.79 35.41 349.37 Pass 1176.21 1164.87 1300.00 1269.65 3.63 4.89 70.53 155.47 412.94 36.22 376.71 Pass 1208.89 1195.79 1350.00 1314.30 3.65 5.13 69.32 154.32 442.45 37.01 405.44 Pass 1240.76 1225.78 1400.00 1358.81 3.66 5.36 68.30 153.30 472.99 37.76 435.23 Pass 1271.89 1254.88 1450.00 1403.21 3.67 5.58 67.41 152.41 504.34 38.46 465.88 Pass 1302.27 1283.11 1500.00 1447.49 3.69 5.80 66.64 151.64 536.42 39.13 497.29 Pass 1331.53 1310.13 1550.00 1491.28 3.71 6.04 65.91 150.91 569.66 39.79 529.87 Pass 1359.54 1335.82 1600.00 1534.45 3.73 6.27 65.23 150.23 604.15 40.45 563.71 Pass 1386.28 1360.20 1650.00 1577.03 3.75 6.52 64.61 149.61 639.92 41.11 598.81 Pass 1411.78 1383.30 1700.00 1619.05 3.77 6.73 64.05 149.05 676.87 41.66 635.21 Pass 1436.56 1405.61 1750.00 1661.04 3.80 6.83 63.58 148.58 714.43 42.01 672.43 Pass 1460.80 1427.29 1800.00 1703.15 3.83 6.88 63.21 148.21 752.40 42.23 710.17 Pass 1484.51 1448.36 1850.00 1745.32 3.85 6.81 62.89 147.89 790.72 42.20 748.52 Pass 1507.67 1468.82 1900.00 1787.47 3.88 6.79 62.62 147.62 829.37 42.25 787.12 Pass 1529.89 1488.32 1950.00 1829.13 3.91 6.88 62.34 147.34 868.72 42.48 826.24 Pass 1551.06 1506.78 2000.00 1870.08 3.94 7.02 62.03 147.03 908.85 42.80 866.06 Pass 1571.01 1524.07 2050.00 1910.14 3.97 7.28 61.71 146.71 949.89 43.33 906.57 Pass 1589.72 1540.19 2100.00 1949.28 4.00 7.52 61.38 146.38 991.81 43.80 948.01 Pass 1600.00 1549.01 2150.00 1988.19 4.02 7.69 61.07 146.07 1034.19 44.14 990.05 Pass 1625.45 1570.71 2200.00 2027.18 4.07 7.81 60.81 145.81 1076.73 44.45 1032.28 Pass 1643.20 1585.74 2250.00 2066.85 4.10 7.81 60.61 145.61 1119.16 44.54 1074.62 Pass 1661.14 1600.85 2300.00 2107.34 4.13 7.83 60.48 145.48 1161.29 44.64 1116.65 Pass . . Halliburton Company Anticollision Report Company: BP Amoco Date: 4/24/2004 Time: 11 :37:05 Page: 4 Field: Milne Point Reference Site: M Pt I Pad Co-ordinate(NE) Reference: Well: Plan MPI-14 Odin. True North Reference Well: Plan MPI-14 Odin Vertical (TVD) Reference: 68.00 68.0 Reference Wellpath: MPI-14 Db: Oracle Site: M PtI Pad Well: MPI-04 Rule Assigned: Major Risk Wellpath: MPI-04 V5 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingIHS>istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 33.50 33.50 35.50 35.50 0.00 0.00 92.97 92.97 179.66 1.02 178.64 Pass 48.00 48.00 50.00 50.00 0.05 0.03 92.97 92.97 179.66 1.40 178.26 Pass 98.00 98.00 100.00 100.00 0.20 0.14 92.94 92.94 179.71 2.70 177.00 Pass 148.00 148.00 150.00 150.00 0.47 0.27 92.92 92.92 179.81 4.38 175.44 Pass 198.00 198.00 200.00 200.00 0.74 0.39 92.92 92.92 179.99 6.06 173.93 Pass 248.00 248.00 250.00 250.00 0.98 0.56 92.93 92.93 180.22 7.78 172 .44 Pass 298.00 298.00 300.00 300.00 1.21 0.73 92.94 92.94 180.49 9.49 170.99 Pass 346.79 346.79 350.00 350.00 1.44 0.92 93.02 123.02 180.94 11.22 169.71 Pass 395.51 395.50 400.00 400.00 1.66 1.11 93.26 123.26 181.75 12.95 168.81 Pass 444.20 444.17 450.00 449.99 1.88 1.27 93.50 123.50 183.03 14.58 168.45 Pass 492.87 492.79 500.00 499.96 2.10 1.43 93.60 123.60 184.84 16.20 168.64 Pass 541.50 541.33 550.00 549.87 2.32 1.60 93.46 123.46 187.31 17.86 169.45 Pass 590.05 589.77 600.00 599.66 2.54 1.77 93.01 123.01 190.56 19.51 171.04 Pass 636.63 636.20 650.00 649.32 2.70 1.97 92.26 132.98 194.73 21.02 173.71 Pass 682.45 681.84 700.00 698.85 2.84 2.16 91.20 143.17 200.19 22.46 177.73 Pass 727.88 727.04 750.00 748.22 2.95 2.37 89.82 150.57 207.09 23.86 183.24 Pass 772.79 771.66 800.00 797.35 3.05 2.59 88.13 155.61 215.60 25.18 190.42 Pass 816.70 815.20 850.00 846.20 3.16 2.81 86.22 158.45 225.94 26.55 199.39 Pass 859.26 857.30 900.00 894.71 3.30 3.03 84.20 159.41 238.44 27.94 210.50 Pass 901.02 898.45 950.00 942.96 3.43 3.25 82.22 159.69 252.99 29.31 223.67 Pass 941.98 938.68 1000.00 991.03 3.50 3.48 80.42 159.64 269.38 30.50 238.88 Pass 982.11 977.92 1050.00 1038.89 3.58 3.69 78.72 159.36 287.40 31.62 255.78 Pass 1021.37 1016.13 1100.00 1086.46 3.61 3.91 77.08 158.86 306.86 32.60 274.25 Pass 1059.57 1053.13 1150.00 1133.62 3.62 4.12 75.47 158.21 328.03 33.47 294.56 Pass 1096.50 1088.73 1200.00 1180.20 3.62 4.34 73.90 157.44 351.17 34.30 316.86 Pass 1132.01 1122.77 1250.00 1226.13 3.63 4.58 72.38 156.59 376.44 35.16 341.28 Pass 1165.93 1155.10 1300.00 1271.29 3.63 4.82 70.95 155.73 403.96 35.98 367.98 Pass 1198.77 1186.24 1350.00 1315.98 3.64 5.05 69.68 154.68 433.13 36.77 396.36 Pass 1230.91 1216.52 1400.00 1360.54 3.66 5.29 68.60 153.60 463.37 37.54 425.82 Pass 1262.26 1245.89 1450.00 1404.97 3.67 5.51 67.68 152.68 494.48 38.24 456.24 Pass 1292.89 1274.41 1500.00 1449.30 3.68 5.73 66.87 151.87 526.31 38.92 487.40 Pass 1322.54 1301.84 1550.00 1493.28 3.70 5.96 66.14 151.14 559.15 39.59 519.56 Pass 1350.94 1327.95 1600.00 1536.65 3.73 6.20 65.44 150.44 593.26 40.23 553.02 Pass 1378.08 1352.73 1650.00 1579.41 3.75 6.45 64.80 149.80 628.63 40.90 587.72 Pass 1403.94 1376.21 1700.00 1621.58 3.77 6.70 64.22 149.22 665.24 41.55 623.69 Pass 1428.89 1398.71 1750.00 1663.52 3.79 6.80 63.72 148.72 702.67 41.90 660.77 Pass 1453.30 1420.59 1800.00 1705.60 3.82 6.90 63.32 148.32 740.51 42.24 698.28 Pass 1477.17 1441.85 1850.00 1747.76 3.84 6.83 62.99 147.99 778.73 42.21 736.52 Pass 1500.00 1462.06 1900.00 1789.94 3.87 6.77 62.70 147.70 817.26 42.18 775.08 Pass 1523.07 1482.35 1950.00 1831.80 3.90 6.85 62.43 147.43 856.36 42.41 813.95 Pass 1544.58 1501.14 2000.00 1872.98 3.93 6.93 62.13 147.13 896.24 42.63 853.62 Pass 1564.92 1518.80 2050.00 1913.35 3.96 7.20 61.82 146.82 936.99 43.16 893.83 Pass 1583.99 1535.26 2100.00 1952.74 3.99 7.47 61.48 146.48 978.66 43.68 934.98 Pass 1600.00 1549.01 2150.00 1991.65 4.02 7.64 61.16 146.16 1020.91 44.04 976.87 Pass 1619.96 1566.05 2200.00 2030.59 4.05 7.81 60.89 145.89 1063.44 44.42 1019.01 Pass 1637.63 1581.04 2250.00 2069.98 4.09 7.81 60.67 145.67 1105.96 44.51 1061.45 Pass 1655.54 1596.15 2300.00 2110.25 4.12 7.81 60.51 145.51 1148.16 44.59 1103.57 Pass . . PERMIT TO DRILL 20 MC 25.005 (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. If multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of this section that is unique to that branch and need not include the $100 fee. I 42 00 W W 149 I 49 32 PU I 4 1 Propose~u OA Prod ....er 204-12 ) 7/9/2004 N ~ . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# v Development Service CHECK WBA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL ¡ (If API number last two (2) digits are between 60-69) ,Ø¡Ot/ .I~ /t/ ¿ / 2-0£/ r- /26 Exploration Stratigraphic ~'CLUE'" Tbe permit is for a n~ ",e~lbore se.gment of existing wen ¡11P?(, ...J.--- /'f- Permit No, 2Þ'I-11'r API No. 5lÞ ~ð-;!1 ~~ 3 2/,/ -ð() Production. sbould continue to be reported as a function' of tbe original API number. stated above. HOLE ]n accordance witb 20 AAC 25.005(1), an records, data and logs acquired for tbe pilot hole must be clearly differentiated în both name (name on permit plus PH) and API number (SO 70/80) from records, data and logs acquired for wen (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance witb 20 AAC 25.055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:xception. (Company Name) assumes tbe liability of any protest to the spacing .exception tbat may occur. An dry ditch sample sets submitted to tbe Commission must be in DO greater ·tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals througb target zones. Field & Pool MILNE POINT. SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT SB 1-14L 1 _Program DEV _ Well bore seg ~ - PTD#: 2041200 Company .BP EXPLORATION (ALASKA) INC Initial ClasslType ~EV / PEND _ GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal 0 Administration 1 Permittee attache.d_ - - - - - - - - - - - - - - _ _ NA _ _ _ _ _ _ _ Multilateral weJUee waive_d_per 20_AAC 25,Q05(el _ _ _ - - - - - - - - - - - 2 _Lease number _appropri<lte_ _ _ _ - - - - - - _ _ Ye$ _ _ _ Surface Ipeation 80L 25_906;tQP_prodµçtiYe inteNal an.d TDin ADL 25517 _ _ _ 3 _U_nique well_n_ame_aod OI.!l1)b_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . . . . . . _ . .Ye$. . _ _ . _ _ . . _ _ . _ _ - - - - - - - - - - - - - - - - - - - - - -. - - - - - - - - - - - - - - - - - - - - - - -- 4 Well Jocated in.a_ define.d -ppol_ .Ye$_ _ SGhrader. Bluff Oil F'Qol. govern_ed by CO A77. _ . . _ _ . - - - -- 5 We.IIJQcated prpper .distance_ from driJIing unitb.ound_ary_ _ .Ye$ _ . - - - - - - - - - - - - - - - - - - - - - - - 6 Well Jocpted pr:oper _distance_ from otbeJ wells_ _ . _. Ye$ _ _ _. - - - - - - - - - - - - - - - - - - - - - - - - 7 _Sµ{fícienLacreag.e.aYail<ible in_drilliog unjL .Ye$ _ _ - - - - 8 Jtdeviated. .Is weJlbore plaUncJu.ded _ .Ye$_ - - - - - - - - - - - - - - - - - -- 9 _O-per.ator only affected party. _ _ _ _ _ _ . Ye$_ _.. _ _._ - - - - - - - - - - - - - - - 10 .O-per:ator bas_apprppriateJ~ond inJQrce. _ _ . _ . . _ . . . . _ . _ _ _ . _ . . _ . _ . . _ . . . .Ye$. _ . . . . . _ _ . . _ _ _ . _ . . . . . _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Permit Gao be iS$ued wjtbout co_n$ervaJion order. . _ _ _ _ _ _ . _ _ _ ...Y_e$___ - - - - - - - - - - Appr Date 12 Permitc_ao be iS$u.ed wjtbQut administrathleapprpvaJ _ _ .Ye$ _ . SFD 7/9/2004 13 Can permit be approved before 15-day wait Yes . 14 We.ll Jocated within area and_strç¡t<lauthorized by lojection Ord_er # (puUO# incommeots) (ForNA - - - - - - - - - -- - - - - - 15 .All welJs_ within J l4.mile .are.a.of reyiew identlfied (For servjc_e well only>- . _ . . . . . _ _ . _ _ _ _ NA . . . . . _ . _ _ _ . . . . . . . _ . . . _ . . _ . _ _ _ _ . . . . . . . . . _ _ _ _ _ . . . . . _ _ . . . . . . _ _ .. . 16 Pre.-produ~ed iojector; .dur<ition.of pre.,pro.ductipn le$s than.:3 mOl1tbs (For_servtce well onJy) _ .NA - - - - - - 17 ACMP_Fïl1dingof Com>i$teocy.h_a$ bee_nissl,led for_this project. NA Multilateral weILbor.e, _ . _ _ . Engineering 18 .Coodu_ctor string_provided . . . _ .NA · . CQndUGtQrínstaJled.io MPI-14.. - - - - -- 19 _SJJrface_cç¡sin9_pJoteGts all_knowl1 USDWs . _ _ · NA · 8/l aquife.rs ex.empedAOCER 147J02(b)(3). 20 _CMT v_ol adequ_ateto circJJI<lteon_cond_uctor. & SUJtC$g . · NA · Surtace ca_stng in!>t<lUe_dJn MPI~t4, . _ . 21 _CMT v_ol adequ.ateJo tie-to Jong _striog to surf cs.g_ _ _ NA · Intermediate. Ga!>iog in$ta/led jn. MF'I-1IJ,._ . - - - - - - - - - - 22 _CMTwill Goyer.a!1 knownprQ(ll,lctiye hori;ZOl1s. _ . - - - - - - - - - - - - No_ . · _ Slotte_d Jioer _completion plaOl1e.d. InteJmedjaJe cement ¡:¡Ianned 500' above. any hydJQcp¡:bons.. _ 23 _C_asing de.sigos adeCua_te for C.T. B&p.ermafrO$t Ye$ _ _ _ _ _. - - - - - 24 A.dequ<lteJan_kage_oJ re_serve pit _ . - - - - - - - - - - · Ye$.. . . _ _ Rig jsequipped.with $teelpits. NoreseJlle.pjtplanned. All waste to.Clas!> )Iwell($t . 25 JtaJe-.drilL hasa 10A03 for <ibandol1ment beeo approved. · NA - - - - - - - - - - - -- 26 _A.dequ<lte well bore separatjo.n -Pf0-pose.d _ _ . . . . _ . . _ . _ . _ . _ _ _ . . _ _ . . _ . _ _ . Ye$ . . . . _ . _ pr.oJcCimtty an<lIY$is performe.d. p_nly _cl.o$e appro<lch issue js. mothe.r pore _apRroJ(. 40' tv.d .deep-er. 27 Jtdiverter reQuired, doe!> it meet regulatioos .NA · . 60F' st<lck wil! be io place.. _ . - - - - - - - -- Appr Date 28 _Drilling fluid_program $Ghematic& equipJi$tadequ<lte. _ . Ye$ · . Maximum BHP 8.5 .EMW._expectedBHP _8A .Planned MW9JQ in OA, _ . . TEM 7/9/2004 29 .B_OPE!>._dothey meetreguJa_tion _ . - - - - -- - - -- Ye$_ _ BF' has requested to -perform _B_QP. tests 011 a 14. day inte.NaJ. _Approyal recommended. . J(fQ(" 30 BPPEpres$ ra.ling appropriate; test to (puJ pSig in_comments) . Yes · Calculated_MASP 1346 psi. Planned ßOP _test pressure_ 3000 psi.. 31 C.hokemaMold compJies. w/API R~-5:3 (May 84)_ _ Yes - - - - - - - - - - - - - - - - 32 Work will pccur withouLoper¡;¡tion .shutdo.wn . - - - - - - Yes _ _ _ _ _.. - - - - - - 33 Is Rresence oJ H2S gas_ prob.able. _ _ . . . _ No . _ _ . . H2S ba_snotb.een produ.ced on Ipad.. Rig js.e_quippe_dwith $el1sor$_aod alarms. 34 Meçba_nic¡;¡condition ofwell$ wtthin AOR Yerified (For_service wel) onJy) _ _ . .NA - - Geology 35 Permit Gan be iS$u.ed w/o hydr:ogel1 s.ulfide measµre!> . - - - - - · Ye$. . _ Per _Skip _C_oyner, _BP. on619/Q4; .No H_2S _koownJn Schrader Sluff r:e$ervojr$ ç¡tI~Pad. 36 D<lta presented on_ Rote.ntial oveJRressure _Zone$. _ · Yes. · Expected reseNojr preSSUJe i$ .8,5_ppg EMW; wilLbe _drilled witb 9.0 ppg mud. Appr Date 37 Setsmicanalysjs. of !>baJlow gas_zones_ . . .NA SFD 7/9/2004 38 _Seabed .condition survey (if off-sh.ore) . _ _NA 139 . Conta.ct namelphoneJorweelsly progressre¡:¡orlS [explor¡;¡tpryoolyl _ NA Geologic Engineering ~~ , ot/l Commissioner: Date: Commissioner: Date Date OV) 7(12/ r .)....J- V¥,'II' _4 ........ V e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . Sperry-Sun Drilling Services LIS Scan Utility . e:<Ð f- (2,,0 $Revision: 3 $ LisLib $Revision: 4 $ Thu Oct 21 08:26:46 2004 ::::: J ;¿ ~ 6;- I . Reel Header Service name.... ........ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/21 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 Date. . . . . . . . . . . . . . . . . . . . .04/10/21 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 MPI-14 Ll 500292321460 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 21-0CT-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003214396 R. FRENCH D. GREEN MWD RUN 2 MW0003214396 R. FRENCH D. GREEN MWD RUN 6 MW0003214396 T. MCGUIRE E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW0003214396 T. MCGUIRE E. VAUGHN MWD RUN 8 MW0003214396 T. MCGUIRE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 13N 10E 2348 4055 MSL 0) 68.16 34.80 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 109.0 2699.0 6826.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MPI-14 L1 EXITS FROM THE MPI-14 WELLBORE AT 7324'MD/3927'TVD, WITHIN THE RUN 2 INTERVAL. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. 5. MWD RUNS 2,7,8 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 6 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K.COONEY (SIS/BP), DATED 8/26/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. LATERAL WELLBORES WERE SHIFTED/ CORRECTED TO THE MAIN MPI-14 WELLBORE, IF APPROPRIATE. 7. MWD RUNS 1,2,6-8 REPRESENT WELL MPI-14 L1 WITH API#: 50-029-23214-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9910'MD/3973'TVD. 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 (SEDP). SLIDE = NON-ROTATED INTERVALS. $ File Header Service name....... ......STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/21 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPD RPM FET RPS RPX $ . . clipped curves; all bit runs merged. .5000 START DEPTH 66.5 109.5 2666.0 2666.0 2680.0 2680.0 2680.0 STOP DEPTH 9850.5 9909.5 9857.5 9857.5 9857.5 9857.5 9857.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 6 7 8 MERGED MAIN PASS. $ MERGE TOP 66.5 2710.0 7325.5 7347.0 7466.5 MERGE BASE 2710.0 7325.0 7347.0 7466.5 9910.0 # 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 66.5 9909.5 4988 19687 66.5 9909.5 ROP MWD FT/H 0.74 4436.19 195.462 19601 109.5 9909.5 GR MWD API 5.71 138.36 70.8922 19569 66.5 9850.5 RPX MWD OHMM 1. 99 2000 16.7971 14356 2680 9857.5 RPS MWD OHMM 1. 08 2000 18.3528 14356 2680 9857.5 RPM MWD OHMM 0.91 2000 21.7476 14384 2666 9857.5 RPD MWD OHMM 1 2000 26.2647 14384 2666 9857.5 FET MWD HOUR 0.1217 162.568 1.10852 14356 2680 9857.5 . . First Reading For Entire File. .... .....66.5 Last Reading For Entire File.......... .9909.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/10/21 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..... ..04/10/21 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 GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 66.5 109.5 STOP DEPTH 2666.0 2710.0 # 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: 04-AUG-04 Insite 66.37 Memory 2710.0 109.0 2710.0 .6 63.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 120557 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 109.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): Spud Mud 9.20 128.0 . 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: 7.5 400 9.0 . .000 .000 .000 .000 .0 75.2 .0 .0 # 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 Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 66.5 2710 1388.25 5288 66.5 2710 ROP MWD010 FT/H 6.12 4436.19 144.853 5202 109.5 2710 GR MWD010 API 23.86 121.62 66.8563 5200 66.5 2666 First Reading For Entire File... ...... .66.5 Last Reading For Entire File........ ...2710 File Trailer Service name........ .... .STSLIB.002 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation. ..... .04/10/21 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...... .04/10/21 . 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 GR RPD RPM RPS RPX FET ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 2666.5 2680.0 2680.0 2680.0 2680.0 2680.0 2710.5 STOP DEPTH 7325.0 7325.0 7325.0 7325.0 7325.0 7325.0 7325.0 # 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. RESIS. 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): # 08-AUG-04 Insite 66.37 Memory 7324.0 2710.0 7324.0 65.8 80.0 TOOL NUMBER 053519 134760 9.875 2699.0 LSND 9.25 44.0 8.0 250 7.2 6.000 3.960 9.000 6.000 64.0 100.4 64.0 64.0 . . 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2666.5 7325 4995.75 9318 2666.5 7325 ROP MWD020 FT/H 2.66 615.11 222.978 9230 2710.5 7325 GR MWD020 API 5.71 124.75 66.9412 9318 2666.5 7325 RPX MWD020 OHMM 1. 99 99.27 13 . 506 9291 2680 7325 RPS MWD020 OHMM 1. 08 117.33 14.3353 9291 2680 7325 RPM MWD020 OHMM 0.91 2000 16.2714 9291 2680 7325 RPD MWD020 OHMM 1 2000 24.116 9291 2680 7325 FET MWD020 HOUR 0.1217 41.7956 0.768016 9291 2680 7325 First Reading For Entire File...... ... .2666.5 Last Reading For Entire File........ ...7325 File Trailer Service name. .... ....... .STSLIB.003 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation.. .....04/10/21 Maximum Physical Record. .65535 File Type. ............ ...LO Next File Name... ....... .STSLIB.004 Physical EOF File Header Service name.. .......... .STSLIB.004 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/10/21 Maximum Physical Record. .65535 File Type..... .......... .LO Previous File Name.. .....STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 . RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ . header data for each bit run in separate files. 6 .5000 START DEPTH 7325.5 STOP DEPTH 7347.0 # 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # 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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 14 -AUG-04 Insite 66.37 Memory 7347.0 7324.0 7347.0 73.0 73 .0 TOOL NUMBER 6.750 2699.0 Oil Based 9.10 83.0 .0 36000 .0 .000 .000 .000 .000 .0 100.4 .0 .0 . . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD060 FT/H Min 7325.5 0.86 First Reading 7325.5 7325.5 Last Reading 7347 7347 Mean 7336.25 14.2755 Nsam 44 44 Max 7347 29.4 First Reading For Entire File......... .7325.5 Last Reading For Entire File.. ...... ...7347 File Trailer Service name..... ..... ...STSLIB.004 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation..... ..04/10/21 Maximum Physical Record. .65535 File Type........... ... ..LO Next File Name.. ........ .STSLIB.005 Physical EOF File Header Service name. ..... ..... ..STSLIB.005 Service Sub Level Name... Version Number..... ......1.0.0 Date of Generation...... .04/10/21 Maximum Physical Record..65535 File Type.... ... ........ .LO Previous File Name... ....STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX RPS GR RPM FET RPD ROP $ 5 header data for each bit run in separate files. 7 .5000 START DEPTH 7297.5 7297.5 7325.5 7325.5 7325.5 7325.5 7347.5 STOP DEPTH 7416.0 7416.0 7409.0 7416.0 7416.0 7416.0 7466.5 # 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 14-AUG-04 Insite 66.37 Memory 7466.0 7347.0 7466.0 . MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 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 76.3 81. 6 . TOOL NUMBER 91360 156401 6.750 7336.0 Oil Based 9.10 83.0 .0 36000 .0 .000 .000 .000 .000 .0 82.4 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7297.5 7466.5 7382 339 7297.5 7466.5 ROP MWD070 FT/H 10.4 290.28 217.953 239 7347.5 7466.5 GR MWD070 API 51.92 100.38 74.4764 168 7325.5 7409 RPX MWD070 OHMM 0.16 2000 45.7966 238 7297.5 7416 RPS MWD070 OHMM 0.47 2000 81.5323 238 7297.5 7416 RPM RPD FET . 5.97 2.34 0.1939 27.01 77 .14 162.568 MWD070 OHMM MWD070 OHMM MWD070 HOUR 15.506 16.15 25.0981 182 182 182 First Reading For Entire File......... .7297.5 Last Reading For Entire File....... ... .7466.5 File Trailer Service name. ........... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .04/10/21 Maximum Physical Record..65535 File Type.... ........... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name......... ....STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/10/21 Maximum Physical Record. .65535 File Type........... .....LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 6 .325.5 7325.5 7325.5 7416 7416 7416 header data for each bit run in separate files. 8 .5000 START DEPTH 7409.5 7416.5 7416.5 7416.5 7416.5 7416.5 7467.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9850.5 9857.5 9857.5 9857.5 9857.5 9857.5 9910.0 16-AUG-04 Insite 66.37 Memory 9910.0 7466.0 9910.0 72 .9 97.2 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 91360 156401 $ . # 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. ....0 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 6.750 7336.0 Oil Based 9.10 83.0 .0 36000 .0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 , RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT MWD080 FT/H MWD080 API MWD080 OHMM MWD080 OHMM MWD080 OHMM MWD080 OHMM MWD080 HOUR Mean 8659.75 197.875 82.6062 23.0896 26.0411 32.2939 25.4233 0.862271 Min 7409.5 0.74 41.12 4.65 4.67 3.9 3.42 0.23 Max 9910 747.89 138.36 2000 2000 2000 2000 8.77 First Reading For Entire File......... .7409.5 Last Reading For Entire File....... ....9910 Nsam 5002 4887 4883 4883 4883 4883 4883 4883 . .0 96.8 .0 .0 First Reading 7409.5 7467 7409.5 7416.5 7416.5 7416.5 7416.5 7416.5 Last Reading 9910 9910 9850.5 9857.5 9857.5 9857.5 9857.5 9857.5 . . File Trailer Service name.. .......... .STSLIB.006 Service Sub Level Name. . . Version Number.... .......1.0.0 Date of Generation..... ..04/10/21 Maximum Physical Record. .65535 File Type......... .......LO Next File Name. ......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/10/21 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 Date. . . . . . . . . . . . . . . . . . . . .04/10/21 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