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201-122
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas El SPLUG ❑ Other ❑ AbandonedoSuspendedL 1b. Well Class: 20MC 25.105 N" 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG[—] WDSPL ❑ No. of Completions: Service E] Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: 1/12/2019 201-122 / 318-442 Hilcorp Alaska, LLC Abend.: 3. Address: 7. Date Spudded: 15. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage AK, 99503 5/28/2001 50-029-23014-61-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16, Well Name and Number: Surface: Milne Pt Unit C41 L2 694' FSL, 2297' FEL, Sec 10, T13N, R10E, UM, AK 6/13/2001 Top of Productive Interval: 9. Ref Elevations: KB: 45.17 17. Field / Pool(s): 2334' FNL, 153' FWL, Sec 23, T13N, R10E, UM, AK GL: 16.50 BF: Milne Pt Unit/ Schrader Bluff Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1696' FNL, 2123' FEL, Sec 23, T13N, RI OE, UM, AK ADL0025516, ADL0047434 & ADL0047437 9,825MD/ 4,152TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 558167.1705 y-6028976.132 Zone -4 12,087MD/ 4,39TVD N/A TPI: x- 560696.0775 y- 6020688.078 Zone -4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 563693.2339 y- 6021351.587 Zone -4 10,523MD/4,327TVD 1,800 (Approx.)/ 1,721 (Approx.) 5. Directional or Inclination Survey: Yes LJ (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 110,091- µD 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, 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 d necessary RECEIVED FEB 2 7 2019 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 13-3/8/20 94#/ 54.5# H -40/J-55 Surface 110' Surface 110' 30" 260sx Arctic Set (Approx.) 7" 26# L-80 37' 11,197' 37' 4,399' 9-7/8" 1,456sx Arctic Set iii, 792sx Class 4-1/2" 12.6 L-80 9,963' 10,419' 4,188' 4,303' 6-1/8" 4-1/2" 12.6 L-80 10,085' 13,668' 4,219' 4,348' 6-1/8" 4-1/2" 12.6 L-80 10,405' 13,810' 4,277' 4,365' 6-1/8" 4-1/2" 1 12.6 L-80 13,954' 1 14,141' 1 4,371' 4,379' 6-1/8" 24. Open to production or injection? Yes ❑ No Q 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/fVD) Size and Number; Date Perfd): I 4-1/2" 9,963' 9,854'MD / 4,160 -TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DAT !I Was hydraulic fracturing used during completion? Yes LJ No r /Z i q VERIFIED Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED MiT 9,825'to 10,450' 187bbis of 16 ppg, Class'G' Cement 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Test Period Flow Tubing Casing Press: I Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (carr): Press 24 -Hour Rate Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 RBDMS M(z FEB 2 8 2019 Submit ORIGINAL on 3 -`i -1S A// if /�3,5,r`� 7G 28. CORE DATA Conventional Core(s): Yes ❑ No ❑✓ Sidewall Cores: Yes ❑ No ❑✓ If Yes, list formations and intervals cored (MD/TVD, Fromlfo), and summarize lithology, and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑� If yes, list intervals and formations tested, briefly summarizing test results. Top Schrader OA 10,680' 4,327' Attach separate pages to this form, if needed, and submit detailed test Base OA / TSBC 12,120' 4,363' information, including reports, per 20 AAC 25.071. Base OA / TSBC 12,180' 4,363' Base OA / TSBC 13,610' 4,358' Formation at total depth: Schrader Bluff 31. List of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Chad Helgeson Contact Name: Taylor Wellman TcJ Authorized itla: Operations Manager Contact Email: tvvellmanQhilco! .COm AuthorizedContact Phone: 777-8449 Signature: `//Yy ^J � << Q h Date: 2/26/2019 INSTRUCTIONS Genera .J This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: 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. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: 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. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. 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. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: 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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only Tree: 412", 5M-41 KBelev=30.10' VWIhead:ll"x 41/2 "TCII T&B. Hnr. w/ MPC DF elev. = 45.17 4-12" Type'H BPV profile I I I I I I GL elev. =16.50' 13 3/8" 72 ppf, L-80 Casing 110' Tam port collar @ 1045' Ililcorp Alaskn. I,I,C 71126 ppf, L -BC, Biro, production oaelnQ SCHEMATIC Revised 1112912019 (dd4ID. 6.151", oap.. [.0080 Lpl ) 4.5" 12.68L450 TC- II Whi1g (ID = 3.955', cap =.0152 8 PF ) 4.12 X NoPIP (3813"to) 9823' TOC 9,825' 7 X 4-1f2 L -8D MES T&T Packer 9854' hop @ ACC'' t&xNV10bortgnele:76•003(C'-1C,C6CMD - 4-1/2 X Nipple 13813" to) - 9890' Hole angle trough pedc= 91 deg. _ ' ,930' 4-1/2" Cement Retainer 9:930'1— 7'x 5'Baker SL-ZXP Liwv top pkr. 8962•'4-12'WLEG Tx 9.482 tole Punch 1 10,015'0,010 to Blame dosed Wrilg 7118105 RM Upper Window 10,091'-10,103' , 4.5'Baker CLDSkd'ag slewe 10,041 : 4.5"llESXNWplo(3.725'No-Ge) 18,398. 4.5" 12.6#L -8C IBTtubIng Baker Tie back stem 5.25' - 4.375' 10.419' 14jts. of so8d liner (1C,1109 -1C,696') ` 7411*. of Slotted Liner (I C,695' -13,623') Lower Window 10,505 -10,519') Baker float shoe 0 13,668' 4.1/2" CIBP 10,450' Baker packoff bushing ® 13,623' L Baker HR setting sleeve 10 405' Baker HMC llnerhanger 1C 421' 83 As of *lotted liner (1C,515'43,766) EZSV Bridge Plug #2 10,523' 4.5`12.6#L-8CIBTtubing (Above Abandoned Lateral) Baker Gulde Shoe 913,81(.1' Halliburton float collar 11 113' Baker Pae off 8es-,4IV &' ?3,,TA.F' EZSV Bridge Plug #1 11,147' (Above Abandoned Lateral) Halliburton Casing shoe 11 194' Baker Payzone Packer (13,954' -13,977') 3 its 4.5" 12.6# L-80IBT Solid tubing Halliburton Float Collar 14,096' Abandoned Open -Hole OB Lateral to 12,205' MD 4.5" Halliburton Float Shoe 14,141' 75 bbls (493') cement (13,977'- 14,470) _ 4-/2" L ED INTERVALS OA L2 -10,515' -13,765' MD 4,324' - 4,345' TVD OA L1-10,695' - 13,623' MD 4,345' - 4,346' TVD MILNE POINT UNIT Nabors 4ES 1nIC1 I r -A4 Nabors 4 -ES 1ne & ESP 4 -ES 7/18105 ' Lee Hulme ' Isolate L2 & Open Ll Sands 4 -ES 3/25/14 B.Kruskle Doyon 16 RWO from ESP to Injector Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-41 CTU 50-029-23014-00-00 201-078 1/8/2019 1/12/2019 Daily Operations. 1/2/2019 - Wednesday No activity to report. 1/3/2019 - Thursday No activity to report. 1/4/2019 - Friday No activity to report. 1/5/2019 -Saturday No activity to report. 1/6/2019 -Sunday No activity to report. 1/7/2019 - Monday No activity to report. 1/8/2019 -Tuesday MIRU CTU 6. PJSM. MU BHA #1- 3.10" OD CTC, 3.12" OD DBPV, TJ disconnect (3/4" ball), 3.10" OD XO, 2.375" OD PDS carrier with GR/CCL logging tool enclosed, 2.10" OD X0, 3.65" OD Jet Nozzle. CAL= 17.15'. Head to well and stab on. Function test BOP rams. All move all open. Head to well and stab on. Function test BOP rams. All move all open. RIH with BHA #1 taking returns to tank. Start pumping down coil SLK 1%. 4,500'. Increase pump rate to 2.5 bpm, 6,500'ctm. Continue RIH. Swap to gel 10 bbls at 8,250'2.5 bpm at 2,100psi. set down weight at 8500'. Continue jetting through at 2.5 bpm. Pump second gel pill. Hard spot at 9,277'. Switch to slick water. set down slightly at 9,700'., Continue jetting. Making short 300' trips. Make trip from 9,860' up to 9,330'. Continue RIH with short trips. Sending 10 bbl gel pills. Stop at 10,500' ctm. Increase rate to 3.2 bpm. Pump 150% bottoms up. Slow rate to 1 pam. Log Memory GR/CCL from 10,500' to 9,700'. Stop and flag pipe at 10,250' and 9,849'. Start POH pumping 1 bpm. slick. Switch to MW for freeze protect. Saw sligt over pull at 6,700'. continue POH while FP with M/W. Pipe starting to come back dark. Pack off pressure increased indicating possibly pulling debris up from well on CT. Well is fully freeze protected. Tried pumping mW and cold diesel into bops to clear pipe. Suspect heavy crude set up due to cold freeze protect fluids. Call out Ad Hoc LRS hot oil truck. LRS on location. Safety meeting. PT Treating line 250/2,500psi. Start pumping 135 deg F diesel into the top of the well. RIH with CT to make sure problem area is addressed. Pumped 50 bbls of hot diesel. PCH with out problem and clean CT. POH to surface. SD LRS. RD hot oil unit. Secure well for the night. Install night cap and pressure test 250/2,500psi. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-41 CTU 50-029-23014-00-00 201-078 1/8/2019 1/12/2019 Daily Operations. 1/9/2019 - Wednesday CTU crew on site. Start Breaking down lubricator to check Packoffs Temperature -35 deg F. Change out Packoffs Heavy solid oil in packoffs. Need to heat to get apart.. Make up Lub. MU CTC. Pull test 3,0000#s. MU BHA #2 - 3.10" OD CTC, 3.12" OD DBPV, TJ disconnect (3/4" ball), 3.10" OD XO, 2" Ported Crossover to 3/4" SRT, 4.5" BO Shifting Tool (1.58'), OAK 7.72. Stab on to well. PT Coil and PCE Low/ High 300/3995 Psi. Test check valves. RIH with BHA2. Tie into Top Flag. Log EOP is 9,829.95. Plus 7.72 to correct to flag. Corrected 0 feet correction to upper flag. Wt check 12,600# at 8,737'. Drop below the Baker CMD Sliding Sleeve. Pull back through to close sleeve. Did not see tension increases. Ran through Slicing sleeve at varying speeds multiple times. Verification that Sliding sleeve is closed. POH. On surface. Ball of steel shavings on top of shifting tool. Recover sample. Secure well for the night. 1/10/2019 - Thursday Dry Run to swab with magnets to attempt to clean out bop. Removed a bunch of shavings from bops. Stab back on with same tool string to make short magnet run.. Pressure test back side. Low/ High. 250/1,950 PSI RIH for short trip with mag. Go to 200 ft. POH to check magnets. On surface. Magnet loaded up with small shavings. Not a matt of metal shavings. Clean magnet and make another run. PT low/ hi 250/2,500 psi RIH for another Magnet trip. RIH to 3,500'. POH to check/clean magnet. Back on surface. A lot of shavings on magnet. Some "brillo pad" shavings. MU BHA #4 - 3.10" OD CTC, 3.12" OD DBPV, 3.12" TJ disconnect (3/4" ball), 3.10" OD XO, 3.1" Crossover,2.6" X over, #101 Hydraulic settint tool 2.63", Adapter Kit 3.5: 4-1/2" CIBP 3.59" OD. DAL 14.47'. Pt on backside low/ hi 250/2,500 psi RIH with CIBP. Wt check 14,000# at 9,500'. Tie in to the flag.(EOP 10230.1 LOG) Make depth 10,243.93 . Depth is corrected to center element of CIBP. Continue down hole. Set CIBP at 10,450. Load ball into CT. Bull head fluid into formation to pump ball around coil. Start pumping M/W to send setting ball. Pumped 37 bbl M/W to seat ball. Pressure up0 CT to 4,500 psi. Bled pressure off back side. Setting tool sheared and set the CIBP at 10,450'. Set down weight to verify plug set. Pressure test plug and sliding Sleeve. MIT pressure test to 2,000 psi for 30 minutes. Good test. POH. Re paint flags. On surface. RD setting tool. PT MHA low / high 450/3,500 psi. PT Firing head. Prep to pert in AM. Secure well for the night. 1/11/2019 - Friday PT PCE on back side. Low/ High 250/ 2,500 PSI. RIH with Tubing punch pert gun. 5' long, 4 spf, HNS Charges. Find fluid at 2325'. Tie into upper flag at 8949.5', Correct to GR/CCL log. Set Gun with top shat at 10010'. Circulate 37 bbls to displace ball to firing head. Shoot gun 110,010 to 10,015' corrected md. Good indication gun fired. Injectivity test. Initial .9 at 1,445 psi. POH pumping FP down back side of CT. On surface. All shots fired. MU BHA 5 Cement retainer. PT PCE on back side. Low/ High 250/ 2,500 psi. RIH with BHA #5 MU BHA #4 - 3.10" OD CTC, 3.12" OD DBPV, 3.12" TJ disconnect (3/4" ball), 3.10" OD X0, 3.1" Crossover,2.6" X over, #10 J Hydraulic settint tool 2.63" , Adapter Kit 3.5:, 4-1/2" Cast Irom Cement retainer. 3.59" OD. DAL 14.89'. Cought fluid at 600'. Tie into Upper flag at 9,849.5, Correct to GR/CCL log. Place Retainer at 9,930 COE. Pump 40bbls m/w for ball to seat. Pressure up to 4,300 psi. Bleed pressure fro back side. Cl Cement Retainer set. Set down 4000 # to verify set. POH. On surface. RD running equipment. RU baker Stinger. Secure well for the night. Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MP C-41 CTU 50-029-23014-00-00 201-078 1/8/2019 1/12/2019 Daily Operations. 1/12/2019 -Saturday PT CT and PCE 250/ 3,990 psi. RIH with BHA#6. Halliburton cementers on location. Tie into Flag, Wt check 15,200 at 9,800'. Jet some M/W out stinger to make sure top of Retainer is clean. Sting into cement Retainer. Set down 5k# on retainer. Pressure test back side of CT. Holding good. No communication. safety Operational meeting. PT Hallib treating line low/ High 800/4,500 psi. start to warm up CT with warm slick water before starting Cement. Cement wet at 11:07. FP CTU pump. Start pumping Fresh water pre flush. Start pumping 16 PPG, Glass G cement down the coil. Slow rate to 1.2 bpm at 2800 psi as cement leaves Coil and enters Liner. Complete pumping Cement. Flush with fresh water. Volume 85 bbls of cement. SD at 39 bbls of water displacement down the ct. Unsting from Cement retainer. Start pump back up and lay in 2 bbls of cement on top of retainer. When cement out nizzle pull up to 9,500 for safety. Circulate in slug of GeoVis gel for contamination and lift. RUN back down Dress off top of cement to 9825'. Jet out extra cement to surface chasing with 1%KCI Slick water. FP the well to 2,750'. Secure well. RIG down CTU #6. Pt of cement plug after 15 hours minimum for 1,000 psi compressive strength. 1/13/2019 -Sunday No activity to report. 1/14/2019 - Monday No activity to report. 1/15/2019 -Tuesday No activity to report. THE STATE °fALASKA. GOVERNOR BILL WALKER Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU C -41L2 Permit to Drill Number: 201-122 Sundry Number: 318-442 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www,aogcc.a laska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of October, 2018. RBDMS OCT 10 2018 � .F,� , n 0E' E STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS % , .a 20 AAC 25.280 1. Type of Request: Abandon 3 lug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ IP Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Reservoir Abandonment L 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: 40 M.3, Hilcorp Alaska LLC Exploratory ❑ Development ❑ ❑ . Stmtigraphic ❑ Service �,., 201-122 3. Address: 3800 Centerpoint Dr, Suite 1400 6 API Number: 5 Anchorage Alaska 99503 4,B 50-0�1�303B, :o. 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 477.05 Will planned perforations require a spacing exception? Yes ❑ No MILNE PT UNIT C-411-2 . 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0025516, ADL0047434 & ADL0047437 MILNE POINT/ SCHRADER BLUFF OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,850' 4,36T 13,850' 4,367' 1,250 10,523 & 11,147 N/A Casing Length Size MD TVD Burst Collapse Conductor 79' 13-3/8" 110' 110' NIA N/A Production 11,160' 7" 11,194' 4,398' 7,240psn 5,410psi Liner 456 4-1/2" 10,419' 4,303' 8,430psi 7,500psi L2 Liner 3,583' 4-1/2" 13,668' 4,360' N/A N/A L1 Liner 3,405' 4-1/2" 13,810' 4,345' N/A N/A Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2" 12.6# / L-801 TC -II 9,963 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7" x 4-1/2" HES T&T, 7" x 5" SL-ZXP and N/A 9,854 MD/ 4,160 TVD & 9,962 MD/ 4,187 TVD 12. Attachments: Proposal Summary Q Wellbore schematic ❑Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑Q Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑Q 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/11/2018 OIL ❑ WINJ ❑ GAS ❑ WAG ❑ WDSPL ❑ Suspended ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Q 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written appro Authorized Name: Bo York Contact Name: Taylor Wellman 7W4 Authorized Title: Operations Manag T?; y,, t Mlatw rrr' East Contact Email: tvvellmanl hilcor .001T1 6u /.4. Contact Phone: 777-8449 Authorized Signature: Date: 10/2/2018 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I� ( ` L Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: l7 (Q I l ro3'f8 � t KI A I RBDMS OCTi� �ioand i Submit Form and Form 10-403 Revised 412017 Approved app � at i v fir n m the date of approval. Attachments in Duplicate 116 K llil..w Alaska, LLI Reservoir Abandonment Well: MPU C-41 Date:09/19/2018 Well Name: MPU C-41 API Number: 50-029-23014-00 Current Status: Water Injector Pad: MP C -Pad Estimated Start Date: October 7, 2018 Rig: Coil Tubing Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 201-078 First Call Engineer: Taylor Wellman (907) 777-8449 (0) (907) 947-9533 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: WeIIEZ Entry Required: Yes Current Bottom Hole Pressure: Maximum Expected BHP: MPSP: 1,650 psi @ 4,000' TVDss 1,650 psi @ 4,000' TVDss 1,250 psi (SBHPS 10/03/15; 8.0 ppg EMW) (SBHPS 10/03/15; 8.0 ppg EMW) (0.1 psi/ft gas gradient) Brief Well Summary: MPC -41 was originally drilled as a production well in the OB sands in 2001. The OB sands were isolated and the well was sidetracked into a multilateral (2 laterals) in the OA sands in 2005. The well produced until 2014 when the well was converted to multilateral water injection. The objective was to support production from the OA from MPE-20. Since this time injection rates were dialed in and there is support reaching MPE-20. Notes Regarding Wellbore Condition • The well has passed a MIT -IA to 2000psi on 05/15/18 proving tubing, packer and 7" casing integrity. Objective: 1. To isolate the L1 lateral from the L2 lateral. 2. Abandon the entire L2 horizontal lateral with cement. The planned redevelopment pattern for the E - Pad Schrader reservoir requires this wellbore to be isolated to help prevent potential MBE's. Coil Tubing Procedure: 1. MIRU CT unit and spot support equipment. Fill uprights with filtered seawater. 2. Pressure test BOPE to 250psi low/ 3,500psi high, 10 min each test. a. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. b. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. 3. RIH w/ 1.75" nozzle and begin FCO of tubing to a target depth of 10,500' md. a. Note that slickline attempted to drift the well but hit a very thick fluid and fell very slowly. Even putting the well on injection only allowed them to reach 4900' before pulling out of hole. b. Attempt to circulate and gain full returns to surface w/ seawater and gel sweeps. c. If unable to gain returns, jet tubing to target depth to clean tubing walls while taking returns to formation. 4. RIH with shifting tool BHA and close the Baker CMD Sliding Sleeve at 10,041' md. 5. MU 3.66" OD nozzle and memory GR/CCL BHA and RIH to 10,500' md. Log up from 10,500'— 9800' and as per memory logging specialist. a. Stop at 10,250' and paint flagon coil tubing. LI b. Stop and paint 2nd flat at 9850' md. P`/k c. Use MPC -41 lower completion tally dated 12/22/2004 for correlation. 6. MU 4-1/2" CIBP and RIH. Correct depth at flag and set CIBP at ±10,450' md. Reservoir Abandonment Well: MPU C-41 E k.c I, AN ka, LU Date: 09/19/2018 7. Conduct an MIT -T to 2000psi for 30 min (charted) to confirm CIBP set. 8. MU 5' tubing punch BHA and RIH. Punch tubing from ±10,010'— 10,015' md. a. Use previous coil flag for depth correction. b. Confirm injectivity, into the L2 lateral. Target rates are >2bpm. 9. MU 4-1/2" cement retainer and RIH. Set retainer at±9,930' md. a. Set down weight onto retainer to confirm set. b. Pump down CTxT annulus to "'100psi to confirm that retainer is fully set. 10. Confirm injection rates into the L2 lateral. 11. Begin to mix cement. Once blend is up 15.8ppg, pump ±85bbls of cement down the coil tubing at max rate through the retainer. a. Use freshwater spacers as needed around the cement. IF ;ka. b. Target is to get at least 73bbls of cement pumped through the retainer. c. Max pump pressure = xxxxpsi. 12. Once target minimum cement volume is pumped through retainer or with 2bbls of cement in the coil (whichever volume is greater) come off the pumps and unsting from the retainer. Allow --bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. a. Pullout of the cement as the last of the cement exits the nozzle. 13. Swap to contaminate and RIH to clean out to 9,830' md. 14. POOH and circulate coil tubing clean as needed. a. Freeze protect well on way out of hole. 1/ 15. Wait on cement to gain 1000psi compressive strength. N° IL. [ �Po_Jfar 16. Pressure test casing to j,50Wsi for 30 min charted. T� 17. RD CT unit. I 11i Attachments: / l©-3 -IS 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO Sundry Change Form Tree: 41/2", 5M Nkllhead:11" x 41/2 " TCI I T&B. Hnr. w/ 4-1/2" Type'H'BPV profile — 13 3/8" 72 ppf, L-80 Casing 110' Tam port collar @ 1045' 7" X ppf, L -BC. Btro. prodoetiae oating (dr* 10.6.161", cap.. C.080 ll pt) 4.6' 12.6#L-80 TC— II tubing ( ID = 3.958', cap =.0152 BPP ) KOP ® SCC' Max twlbom Aegle: 76' ® 08CC-11C,C 610' MD Hole angle trough peso = PC deg. 7'x 5' Baker SL-ZXP Liner top pkr. 97962' 4.S13a ker C PAD Sliding skiers 10,041' 4.5" PIES XN Nipple ( 3.725' No -Go) 10,398' Baker Tie back stem 5.25' -4.375" 10,419' Lower Window (10,505' -10,518') 83 jts of slotted liner (1C,515'43,765') 4.5' 12.6#L -BC IBTtubino Baker Guide Shoe QR 13,81C Baker Packoft8a%;hity �&_, 73,7ff' Baker Payzone Packer (13,954' -13,977') 3jts 4.5" 12.6# L-801BT Solid tubing Halliburton Float Collar 14,096' 4.5" Halliburton Float Shoe 14,141' 75 bbls (493') cement (13,977 - 14,470) MPC -41 Iev_3D'a' kB� eev.=45AT &P GL elev. = 16.50' rt w'"3 Hileorp Alaska, LId: 4-1 a X Nipple (3.813" 10 ) 9823' 7 X 4-1r2 L-80 HES T&T Packer 9854' 4-112 x Nipple (3813' lO) 9890' 4-V2-WLEG �� .,Sleeve dosed during 7118105 R7/1I0 Upper Window 10,091'- 10,103' L2 4.5" 12.6#L -8C IBTtubino 14)1;. of solid liner (1C,1C9' -110,696') 74jts. of Slimed Liner (1C,695' - 13,623') Baker float shoe ® 13,668' Baker packoff bushing ® 13,623' Baker HR setting sleeve 10,4D5' Baker HMC liner hanger r1C 42V EZSV Bridge Plug 92 10,523' (Above Abandoned Lateral) Halliburton float collar 11,113 EZSV Bridge Plug #111,147' (Above Abandoned Lateral) \Halliburton Casing shoe 11,194' Abandoned Open -Hole OB Lateral to 12,205' MD 4-1/2" SLOTTED INTERVALS OA L2 -10,515' -13,765' MD 4,324' - 4,345' TVD OA L1 -10,695' - 13,623' MD 4,345' - 4,348' TVD 7/24/01 1 B.Hasebe 2/22/04 1 MDO I Isolate lower zone & ESP 4 -ES 7/18/05 Lee Hulme Isolate L2 & Open L1 Sands 4 -ES 3/25/14 B.Kmskie Doyon 16 RWO from ESP to Injector MILNE POINT UNIT WELL C-41 API NO: 50-029-23014-00 Tree: 41/2 ", 5M MPG' „41 °J£B encu. 30:10 ? V allhead:11"x 41/2 "TCII T&B. Hnr. w/ / 5.BF elev. = 45.17' 4-12" Type'H' BPV profile GL elev. =16.50' lo 13 3/8" 72 ppf, L-80 Casing 110' Tam port collar @ 1045' 7"M ppf, 48C, Biro. production owing (dda 10. 6.161", cap.. C.C888 blit) 4.5" 12.64 L-00 TC- II tubing ( ID = 3.958-, cap =.0152 BPF ) KOP ® 8CC ' Max walEore Ang1a:76"® 88(C'-1C,C6C' MD Hole angle trough peas = PC deg. 4-1/2" Cement Retainer +/-9,930'1- 7'x ,930' - 7'x 5' Baker SL-ZXP Liner top pM 9,962' Hole Punch +/-10,010 to + 4.5 Baka CMD Siding sleeve 10,04" 4.5" HES XN Npple ( 3.725' No -Go ) R05-9-9-1 Baker Tie back stem 5.25" - 4.375 10,419' Lower Window (10,505' - CIBP+/- 83 As M slotted liner (1C,515'43,765') 4.5" 12.6#L -8C IBTtubino Baker Gulde Shoe ® 13,811)' Baker Paekoff 9as^,hiltf & ' VF' Baker Payzone Packer (13,954' - 13,977') 3 jts 4.5" 12.6# L-80 I BT Solid tubing Halliburton Float Collar 14,096' 4.5" Halliburton Float Shoe 14,141' 75 bbls (493) cement (13,97T - 14,470) Hileara Alaska, UA: �lr- IA J r6a- 4-1 Q a" 4-12 X Nipple (3.813"10) 9623' 7X4-V2L-80 HEST&T Packer 98w 4-1f2 X Nipple (3.81T ID) 989D' 4-1/2-WLEG 98@' Sleeve dosed during 7/18705 RM Upper Window 10,091'- 10,103' L2 4.5" 12.6#L -8C IBTtubino 14jts. of solid liner (1C,1c9'-1C,696') 74 As, of Slotted Liner (1C,695' - 13,6231 Baker float shoe ® 13,668' Baker packott bushing ® 13,623' Baker HH setting sleeve t0,dD5' Baker HMC liner hanger 1C 421' EZSV Bridge Plug 02 10523' (Above Abandoned Lateral) Halliburton float collar 11,113' EZSV Bridge Plug 41 11,147' (Above Abandoned Lateral) Halliburton Casing shoe 11,19-4' Abandoned Open -Hale OB Lateral to 12,205' MD 4.1/2" SLOTTED INTERVALS OA L2 -10,515' -13,765' MD 4,324' - 4,345' TVD OA L1 -10,695' - 13,623' MD 4,345' - 4,348' TVD 7124/01 1 B. 2/22/04 1 MDO I Isolate lower zone & ESP 4 -ES 7/18/05 Lee Hulme Isolate L2 & Open L1 Sands 4 -ES 3/25/14 B.Kruskie Doyon 16 RWO from ESP to Injector MILNE POINT UNIT WELL C-41 API NO: 50-029-23014-00 COIL BOPS MILNE POINT UNIT MPU C-41 09/26/2018 Coil Tubing BOPL. I Lubricator to injection head 1.50" Single Stripper Blind/Shear pipe J---11 F ---L pipe Crossover spool 4 1/16 10M X 4 1/16 5M ■!III Ila II�����II r Manual Gate Manual Gate Crossover spool ® 2 1/8 5M 2 1/8 5M UHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Date: September 26, 2018 Subject: Changes to Approved Sundry Procedure for Well MP C-41 Sundry #:xxx-xxx Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date HAK Procedure Change Prepared B Initials HAK Approved B Initials AOGCC Written Approval Received Person and Date Approval: Prepared: Operations Manager Date Operations Engineer Date • of This . ‘ - /: 1H% ATF r % I\ aofa „;I ' CLQ. ` i _ \_ .L z.,1 2_,.-t,,,, ,Jam,_ 2., '� fir„ '�y:- 333 Nes; Seventh Avenue ” —"--' ,e ( \'F.RNo yFAN 'ARNEi.E Anchorage Alaska 99501 3572 ^^^TTT���)77,-,-,,, I� � ^/��-,� 90%279 14..., A ,1. ox. 9'7 2 o 75.c; David Bjork ID OP 2 'Lp1 Engineering Team Leader SN BP Exploration (Alaska), Inc. ao ( _ r P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Schrader Bluff, MPC-41L2 Sundry Number: 314-121 Dear Mr. Bjork: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, PI i Cathy P. , oerster Chair DATED this 0 day of March, 2014. Encl. ‘' STATE OF ALASKA • ALASK. IL AND GAS CONSERVATION COMMIE N RECEIVED • APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 FFB 2 8 2014 1. Type of Request: n 3 51/ f q--- ❑Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Prog GCC ❑Suspend 0 Plug Perforations 0 Perforate ®Pull Tubing• 0 Time Extension �v ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing ®Other Convert to Injector ' 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. 201-122 • 3. Address: ❑Exploratory 0 Stratigraphic Alaska 99519 6612 ®Development 0 Service P.O. Box 196612,Anchorage, 6. API Number: 50.029-23014-61-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPC-41L2 Will planned perforations require a Spacing Exception? ❑YesNo 9. Property Designatior *5 10.Field I Pool(s): ADL 047434&0474371 25SIc13 Milne Point Unit/Schrader Bluff• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13850' ' 4367' • 13850' 4367' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20"X 13-3/8" 110' 110' 1530/4930 520/2670 Surface Intermediate Production 10054' 7" 10091' 4220' 7240 5410 Liner 3583' 4-1/2" 10085'- 13668' 4218'-4360' 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): ,10695'- 13623'Slotted Liner 4329'-4358'Slotted Liner 2-718",6.5# L 80 9931 4-1/2",12.6# 9962'-10041' Packers and SSSV Type: 7"x 5"Baker SLZXP Packer Packers and SSSV 9962'/4187' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development ®Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation March 25,2014 0 Oil is WINJ-0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Abby Warren,564-5720 Printed Name: David Bjork Title: Engineering Team Leader Email: Abigail.Warren@bp.com Signature: � ovie".-' Phone: 564-4750 Date: ori/ hiy Commission Use Only Conditions of approval: Notify Commission so that a representative may witness \ �� ,�,�" Sundry Number: •• ❑Plug Integrity tJ BOP Test Q Mechanical Integrity Test 0 Location Clearance Other: Jr f tU SG c5 RBDMSNAY 09 2011 3 pp ,5746(,/e. l�Vifht55CC) M / T'/� /-Calvl\ r—cCI all Sfabi/i� cc/ 1 .-71 c c J-1'4 r1 . ! i?Jce fI, Y, opc-1-a f �' S ir, ct « 2) -CIarie-C_. lAvii`h 410 / o 13- Spacing Exception Required? 0 Yes ET/No Subsequent Form Required: /Q - 9 0 L}- Packc c 1 ept hi vav-iaJ--1cz civopr4)vc ci pCr aoAA-C2s4/2 (h) APPROVED BY Approved By: 7-'e9-ae-iiCOMMISSIONER THE COMMISSION Date: 3 -S -�Form 10-403 Revised 1 2012 Ar r i v i for 12 months from the date of approval Submit In Duplicate UL /C-3/5-//4-• �� V 1 I V /1 P11.6 3/11/IY /e----,� 7/7 kip Sundry Request for converting MPC-41 to an injector Well: MPC-41 Date: 2/27/2014 Engineer: Abby Warren MASP: 1362 psi Well Type: Injector Estimated Start date: March 25th, 2014 History: MPC-41 was drilled and completed in July 2001 with two laterals in the Schrader Bluff OA sand. It had a history of solids production when the injection rate on offset well MPE-13Bi was accidentally increased due to a programming error. The solids issue was resolved once the injection rate was lowered. MPC-41 had a RWO to replace an ESP with an electrical failure in June 2003. After the RWO, MPE-13Bi was put back on injection and a MBE broke through between it and MPC-41. MPC-41 remained shut in due to the MBE. During a RWO in December 2004, a straddle with sliding sleeve was placed across the upper lateral L2, a plug was set to isolate the lower lateral L1 and a new ESP was installed. There continued to be issues with the MBE between MPC-41 and MPE-13B and the resulting solids production from MPC-41. In December 2005, another RWO was performed to pull the ESP close the sliding sleeve on the upper lateral L2, pull the plug out of the lower lateral L1, perform a FCO in the lower lateral L1 and set an ESP. The returns from the FCO were heavy oily material and very fine formation sand. MPC-41 remained online until September 2006 when it was shut in due to high GOR. The well came back online in March 2007 and stayed online until March 2009 when it was shut in due to high GOR and low injection support in the area. Producer MPE-20A was determined to be a better well in the hydraulic unit. The purpose of this RWO is to convert MPC-41 to an injector to support well MPE-20A Scope of Work: Pull the old ESP completion and run injection tubing Pre Rig Prep Work: Task W PPPOT-T&IC, Function LDS S Dummy Shallow GLM, pull deep GLV, caliper tubing to surface, SBHP (30 days prior to RWO) E SBHP (10 days prior to rig arrival if needed, based on 30 day and ESP gauge comparison) ✓ Set BPV O Pull well-house, flow-line, prep pad for the rig. Proposed RWO Procedure: 1. MIRU Doyon 16. Kill well. ND tree. NU and test BOPE with four preventers configured top down (annular, 2-7/8" x 5"VBRs, blind shears, mud cross and 2-7/8" x 5" VBRs). Test the VBRs and the annular to 3500-psi. 2. Pull the old-2-7/8" ESP completion. 3. Pressure test the casing to 3500 psi. 4. RU slickline and caliper casing from 1000' to surface 5. Run 4-'/z" 12.6#/ft L-80 tubing with HES TNT packer set at-9837' 6. Test tubing and IA to 3,500-psi. v- 7. Set BPV. ND BOPE. NU and test tree. RDMO. Post rig Work ✓ Pull BPV S Pull ball and Rod, Pull RHC seat Area of Review — Milne Point C-41 (PTD 201-079 & 201-122) This Area of Review is required prior to the conversion of well MPC-41 from a producer to a water injector. This AOR discusses wells within 1/4 mile of the well's entry point into the Schrader Bluff Formation to the bottom of MPC-41 well bore completion. Four other weilbores, MPA-01, MPA-03, MPE-20AL1 and MPG-03A, enter the Schrader Bluff formation in this area of review. The tables below illustrate the wells within the AOR, distance from MPC-41, completion details, and annulus integrity/cement conditions based on in-depth review of each well. Distance Well Name PTD (feet) Annulus Inte•rit MPC-41 201-079 0 TOC estimated at surface MPA-01 179-040 420 TOC at surface; well is P&A'd MPA-03 183-001 250 TOC at surface; well is P&A'd MPE-20A 204-054 580 TOC unknown MPG-03A 204-219 1210 TOC unknown Table 1: Table showing distance&annulus integrity of wells within AOR Hole Vol. of Well Name Casing Size Cement Schrader depth (MD) Schrader depth (TVDss) MPC-41 7" 8-1/2" 500 bbls 9816' -4105 MPA-01 9-5/8" 12-1/4" 400 bbls 4210' -4168 MPA-03 9-5/8" 12-1/4" 246 bbls 4504' -4168 MPE-20A 7-5/8" 9-7/8" 107 bbls 5320' -4236 MPG-03A 7" 8-1/2" 68 bbls 5871' -4080 Table 2: Completion Detail Well MPA-01 (Permit # 179-040) was completed in 1980. MPA-01 was drilled as an exploration well and the wellbore crossed the Prince Creek, Kuparuk, Sag and Sadlerochit formations. A 13-3/8" surface casing was run to 2766' MD and cemented to surface with 614 bbls of Howco Permafrost cement. A 9-5/8" production casing was run to 9719' MD and cemented in place with 328 bbls of Class G cement and 72 bbls of Permafrost 'C' cement. The well was plugged and abandoned in April 2008. Well MPA-03 (Permit # 183-001) was completed in 1983. MPA-03 was drilled as an exploration well and the wellbore crossed the Schrader Bluff formation in the N and 0 sands. A 13-3/8" casing was run to 2500' MD and cemented to surface with 410 bbls of Arco Fondu cement and 102 bbls of Permafrost 'C' cement. A 9- 5/8" production casing was run to 5095' MD and cemented in place with 195 bbls of Class G cement, 51 bbls of Permafrost `C' cement and 130 bbls of Arctic Pac. The well was plugged and abandoned in December 2005. Well MPE-20A (Permit # 204-054), including lateral MPE-20AL1 (Permit # 204- 055), was completed in 2004. Producer MPE-20A's main wellbore is completed in the Schrader Bluff OA sand, and the MPE-20AL1 lateral is completed in the Schrader Bluff N sand. The well was sidetracked in May 2004 after abandoning the parent well MPE-20 (Permit # 195-071) with a EZSV set in the 9-5/8" casing at 4220' MD and pumping 30 bbls of Class "G" cement under while leaving 5 bbls of Class "G" cement on top of the EZSV. An EZ-BP (CIBP) was set in the 9-5/8" casing at 2700' MD, and the casing and plug were pressure tested to 1500 psi for 30 minutes. The 9-5/8" casing was cut at 2520' MD and pulled out of the well. 27 bbls of Arctic Set 1 cement was placed on top of the EZ-BP between 2700' MD and 2510' MD. A CIBP was set in the 13-3/8" casing at 2489' MD and pressure tested at 1500 psi for 30 minutes. In May 2004, after the parent wellbore was isolated, a window in the 13-3/8" casing was milled at 2457' MD and 7-5/8" casing was run and set to 5989' MD and cemented with 107 bbls of Class `G' cement. The 7-5/8" casing was pressure tested to 3500 psi for 30 minutes. During construction of the parent well, MPE-20 (Permit # 195-071), 13-3/8" surface casing was run to 2587' and cemented with 161 bbls of Permafrost `E' cement, 51 bbls of Class G cement and 31 bbls of Permafrost `E' cement. 9-5/8" casing was run to 4681' MD and cemented with 77 bbls of Class `G' cement. Well MPG-03A (Permit # 204-219) was completed in 2004. The well is completed as an injector in the Schrader Bluff N, OA, and OB sands. The well was sidetracked in September 2004 after abandoning the parent well MPG-03 (Permit # 189-046) with a EZSV set in the 7" casing at 4899' MD and pumping 38 bbls of Class `G' cement under while leaving 10 bbls of Class `G' cement on top of the EZSV. The rig performed a pressure test to 1500 psi for 30 minutes. A second EZSV was set in the 7" casing at 3201' DPM and pressure tested to 1500 psi while monitoring the OA (no indication of flow or communication was noted) prior to cutting the 7" casing at 1987'. A second EZSV cement retainer was set in the 7" casing at 1985' MD and 53 bbls of Arctic Set 1 cement was pumped below. In November 2004, after the parent wellbore was isolated, a window in the 9-5/8" casing was milled at 1981' MD and 7" casing was run and set to 6536' MD and cemented with 68 bbls of Class `G' cement. The 7" casing was pressure tested to 3000 psi for 30 minutes. During construction of the parent well, MPG- 03 (Permit # 189-046), 13-3/8" surface casing was run to 110' and cemented to surface using Arctic Set cement, 9-5/8" casing was run to 2931' MD and cemented with 181 bbls of Type `E' cement and 138 bbls of Class `G' cement. • N MPE-03 4, M' •1PB1 MPB-25 - MPE-1APB2 \ MPB-04A MPC-41L2 MPE 13 r \ MPE-33/ NPA-C43 w WPA-01 -1 1 , , MPB-09 \\ \. 'v4 ' 'A-02A MP‘ •1 MPE MPE 18 MPC-41P' s/MPE-20AL1pip;,!,02' MPE-19 ti., *�\ - -ZOA ��N * MPG-07 MPC-41L1 MPG-03 ' +43A J____-__.___.__ —ter :9 1000 /i'' o 100o 2000 3000 R -* MPG-11 Legend Wellbore with bottom hole symbol Intersection of wellbore with Schrader Bluff Formation 14 mile distance from wellbore (NA intercept to TD) c:::\_:) Figure 1: Map showing wells within 0.25 mi radius from MPC-41. Tree: 2 9/16", 5M MP C-41 KB elev.=30.10' Wellhead: FMC 11"x 11", 5M, uen.5 DF elev. =45.17' ' and 11"x 2 7/8" FMC Tbg. Hnr.w/ GL elev.= 16.50' 8 rd EUE threads top and bottom and 2.5"CIW'H'BPV profile 13 3/8" 72 ppf, L-80 Casing 115' Camco 2-7/8"x 1" 136' sidepocket KBMM GLM Tam port collar @ 1045' 0 7"26 ppf,L-80,Btrc.production casing drift ID=6.151",cap. 0.0383 bpf Camco 2-7/8"x 1" ( = P ) ' ' sidepocket KBMM GLM 9,739 4.5"12.6#L-80 IBT-M tubing9,849' (ID=3.958",cap=.0152 BPF) 411wr Hes XN-Nipple(2.205"id) 2 7/8"6.5f,L-80 8 rd EUE tubingIIIITandem Pump,Upper 214 Stg. Q$71' PP FC925 FPMTAR 1:1,Lower (drift ID=2.347",cap=0.00592 bpf) IBM 16 Stg.GCNSPH,GPBMTAR 1:1 Tandem Gas Separator 9,897' SE5798GA - Tandem Seal Section 9,902' KOP @ 300' gsb3dbabhsnpfsa/gsb3dbltabhsnfsa Motor,95 HP, 1330 volt, 9,915' Max wellbore Angle:75°@ 3300'-10,050'MD 44 amp,Model KMH 9,925' Hole angle trough perfs=90 deg. Centrilift Pumpmate gauge 7"x5"Baker SLZXP Liner top pkr. 9,962' at lit Sleeve closed during RWO Upper Window 10,091'- 10,103' 4.5"Baker CMD Sliding sleeve 10,041' ••• 4.5"HES XXN Nipple(3.725"No-Go) 10,398` """"""""' :: " �::•;:�:::,:�::::::•:: ,: �s :, 4.5 12.6#L-80 IBT tubing Baker Tie back stem 5.25"-4.375" 10,419' 14 jts. of solid liner(10,109' - 10,696') - - 74 jts. of Slotted Liner(10,695' - 13,623') Lower Window(10,505'- 10,518') ....milBaker float shoe @ 13,668' Baker packoff bushing @ 13,623' '.:'x `;' ;L1 Baker HR setting sleeve 10,405' .. >r;+l :.:•:.:r"r F.�„ ::::::::: Baker HMC liner hanger 10,421' A 83 jts of slotted liner ( 10,515`-13,765') EZSV Bridge Plug#2 10,523' 4.5" 12.6#L-80 IBT tubing (Above Abandoned Lateral) Baker Guide Shoe @ 13,810' Halliburton float collar 11,113' Baker Packoff Bushing @ 13,765' EZSV Bridge Plug#1 11,147' (Above Abandoned Lateral) Halliburton Casing shoe 11,194' Baker Payzone Packer(13,954' - 13,977') 3 jts 4.5" 12.6#L-80 IBT Solid tubing Halliburton Float Collar 14,096' Abandoned Open-Hole OB Lateral to 12,205' MD 4.5" Halliburton Float Shoe 14,141' 7.5 bbls(493')cement(13,977' - 14,470) 4-1/2"SLOTTED INTERVALS OA L2- 10,515' - 13,765' MD 4,324' -4,345' TVD OA L1 - 10,695' - 13,623' MD 4,345' -4,348'TVD DATE REV. BY COMMENTS 7/13/01 MDO Drilled &Cased Nabors 22 e MILNE POINT UNIT 7/24/01 B. Hasebe ESP Completion Nabors 4ES WELL C-41 8/07/03 MDO ESP RWO Nabors 4-ES API NO: 50-029-23014-00 12/22/04 MDO Isolate lower zone& ESP 4-ES BP EXPLORATION (AK) 12/12/05 MDO FCO L-01 liner& ESP Completion Tree: 2 9/16", 5M MPC-41 Proposed KB elev.=30.10' Wellhead: FMC 11"x 11", 5M, Gen. 5 DF elev.=45.17' and 11"x 2 7/8" FMC Tbg. Hnr.w/ GL elev.= 16.50' 8 rd EUE threads top and bottom and 2.5"CIW'H' BPV profile 13 3/8" 72 ppf, L-80 Casing 115' Camco 2-7/8"xi" 136' sidepocket KBMM GLM Tam port collar @ 1045' 0 7"26 ppf,L-80,Btrc.production casing drift ID=6.151",cap.=0.0383 bpf) 4.5"12.6#L-80 IBT-M tubing ,ID=3.958",cap=.0152 BPF) 4.5"12.6#L-80 TCII tubing ID=3.958"cap .0152 BPF) . , 4-1/2"X Nipple 9.847' 7 x 4-1/2"HES TNT 9,877' KOP @ 300' Max wellbore Angle:75°@ 3300'-10,050'MD 0 0 4-1/2"X Nipple 9,907' Hole angle trough perfs=90 deg. 1 1/.1'9 133 7"x5"Baker SLZXP Liner top pkr. 9,962' Olt Sleeve closed dNring RWO iCC Uppdr Window 1091'- 10,103' 4.5"Baker CMD Sliding sleeve 10,041' ••• • L2 4.5"HES XXN Nipple(3.725"No-Go) 10,398' ' v..'t." . 4.5' 12.6#L-80 IBT tubing Baker Tie back stem 5.25"-4.375" 10,419' 14 jts. of solid liner(10,109' - 10,696') 74 jts. of Slotted Line 10,695`- 13,623') Lower Window(10,505'- 10,518') Baker float shoe @ 13, Baker packoff bushing @ 13,623' 1 L1 Baker HR setting sleeve 10,405' Baker HMC liner hanger 10,421' A 83 jts of slotted liner ( 10,515`-13,765') EZSV Bridge Plug#2 10,523' 4.5" 12.6#L-80 IBT tubing (Above Abandoned Lateral) Baker Guide Shoe @ 13,810' Halliburton float collar 11,113' Baker Packoff Bushing @ 13,765' EZSV Bridge Plug#1 11,147' (Above Abandoned Lateral) Halliburton Casing shoe 11,194' Baker Payzone Packer(13,954' - 13,977') 3 jts 4.5" 12.6#L-80 IBT Solid tubing Halliburton Float Collar 14,096' Abandoned Open-Hole OB Lateral to 12,205' MD 4.5" Halliburton Float Shoe 14,141' 7.5 bbls (493') cement(13,977' - 14,470) 4-1/2"SLOTTED INTERVALS OA L2- 10,515' - 13,765' MD 4,324' -4,345'TVD OA L1 - 10,695' - 13,623' MD 4,345' -4,348' TVD DATE REV. BY COMMENTS 7/13/01 MDO Drilled &Cased Nabors 22 e MILNE POINT UNIT 7/24/01 B. Hasebe ESP Completion Nabors 4ES WELL C-41 8/07/03 MDO ESP RWO Nabors 4-ES API NO: 50-029-23014-00 12/22/04 MDO Isolate lower zone& ESP 4-ES BP EXPLORATION (AK) 12/12/05 MDO FCO L-01 liner&ESP Completion . b Ii gg B 6 igl W 0 i • _ (I)(n O 0 5 .0 : .: : : : :: : .:. 1 z .„_ .::c iI91 I-- L, a V) e$ o a m w N a x .• 1 g a z a a O ,.- ::: w a a 5 Jtn OcLZ J } J = 0 x 0 Z iTio-1) 80 111111 .■11■.■- " �- _ § 3 C 0 CL -11111=11111111 401=11.1 g vi n O v� N -�-_' o O a �v a= J as am N -0: �J 7 -�-� 11111111.111- Z , _yam I! a N a -� - • -j vioiadii 2 Z Z � L �6 p O O J W J $ a uW= c/ .�- a iw a _0 b N 2 X U 7 3 2 OJX a d mm m 0,o I - d !"W�3O I II IJ 10 w I Z 0t" , =•' ....,F _1 E ii. ji �Y " /1., 13 Nilililis II a N I. lir cn (D ill III A m V T .... m 01111.11 a 46 01 ' .I■ ; a 0 § R m Q \n Milne Point C. (PTD 201-079 & 201-12,' Current Status The Milne Point well C-41 was drilled and completed as a Schrader Bluff formation producer in January 2001. The well has been shut in due to a failed ESP. MPC-41 was last online in 2009, and the well tested at 120 bopd, 20% WC and 1140 scf/stbo GOR. MPC-41 has no known casing problems. The Base Management team's (with approval from the Reservoir Management) plan forward is to convert well MPC-41 to an OA sand injector in the Schrader Bluff pool. The conversion will increase injection capacity in the hydraulic unit, establish new streamlines between wells and better support producers MPE-20A. coPevr, a4e precJvera i'eelCote 0 q 50*",,p - s - frac Completion a �Ct`t�r' it-Cor- Orr lees a, 44 r��/�:foic:4J Mrr. pnc, r4. wed/ ad ai•,e r , /4#1 o4 froot Well MPC-41 (Permit# 201-078) was completed in July 2001 with two laterals *rover, nly MPC-41L1 (Permit#201-079) and MPC-41L2 (Permit# 201-122) as a Schrader tc r /000°4 Bluff producer. Both laterals are completed in the Schrader Bluff OA sand. A 13- 14e id 3/8" casing was run to 110' and cemented with 260 sacks of Arctic set cement. A 7" production casing was run to 11,197' MD and cemented in place with 1456 140�''"a' 4, sacks of 10.7 ppg Arctic Set II cement followed by 792 sacks of 15.7 ppg Class "' G cement. During the cement job full returns were observed at the surface, approximately 500 bbls of cement. Following the cement job the casing was tested to 3500 psi for 30 minutes. Although no cement bond log was run after the cementing operation, we are confident that there is competent cement isolation on both the production and surface casing to facilitate a conversion from producer to injector. The well is completed with slotted liner in the Schrader Bluff OA sand. Plan Forward: 1) Obtain Sundry for conversion to water injection 2) Perform rig workover to remove ESP and complete well for injection service 3) Complete water injection header tie-in 4) Place well on water injection (confirm AOGCC approval prior to injection) 5) AOGCC witnessed MITIA once injection has stabilized Bettis, Patricia K (DOA) From: Lastufka, Joseph N [Josephiastufka@bp.com] Sent: Monday, March 03, 2014 10:26 AM To: Chmielowski, Jessie; Bettis, Patricia K(DOA); Ferguson, Victoria L (DOA) Subject: RE: SBL MPC-41 L2: Sundry Application Patricia, I think we have another confusing issue with this well... A separate set of MPC-41 Lateral sundries were submitted by me this past week (2/28), due to a rig workover which will pull the existing ESP completion and run a 4-1/2" tubing with packer completion. I believe that the 3 sundries submitted prior to mine (created by Garry Catron and signed by Jessie Chmielowski) are to be withdrawn and the 2 sundries that I submitted (signed by David Bjork) will replace them for tubing pull and conversion to injector.The Area of Review is attached to all the sundries. Victoria, Could you please help confirm my understanding and please let me know if you need any additional information? As always, thanks for your help! Joe From: Chmielowski, Jessie Sent: Monday, March 03, 2014 9:58 AM To: Lastufka, Joseph N Subject: FW: SBL MPC-41L2: Sundry Application Hi Joe, For the MPC-41 Sundry, can you please check Box 11 per Patricia's question below? I don't have the form in front of me to check the numbers. I have already answered her second question. Thanks,Jessie From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, February 27, 2014 1:23 PM To: Chmielowski, Jessie Subject: SBL MPC-41L2: Sundry Application Good afternoon Jessie, On the Form 10-403, Box 11, the effective depth is shown as 0 MD and 45'TVD. Is this correct? Also, I want to verify that the slotted liner interval for MPC-41L2 is from 10,695' to 13,623' MD; and for MPC-41L1,the slotted liner interval is from 10,515'to 13,765' MD. 1 4 Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • . RECEIVED STATE OF ALASKA FEB 2 Q 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ¢� 20 AAC 25.280 A °�� 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Ch. :e Approved Program❑ Suspend❑ Plug Perforations❑ Perforate El Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ • er Convert to Iniector 0 2.Operator Name: 4.Current Well Class: 5.Perm' o Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development Q 201-122-0• 3.Address: Stratigraphic ❑ Service ❑ 6. . "I Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23014-61-00 7.If perforating: 8.Well Na and Number: What Regulation or Conservation Order governs well spacing in this pool? • SBL MPC-41 L2 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047437 ' L. E '•INT, SCHRADER BLFF OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Dept D ft): Plugs(measured): Junk(measured): 13850 . 4367 0 4 None None Casing Length Size MD ND Burst Collapse lapse Structural Conductor 79 13-3/8"72#L-80 31-110 31-110 1 Surface None None None None None None Intermediate None None None None None None Production 10054 7"26#L-80 -100' 37-4219.75 7240 5410 Liner See Attachment r See Attachment ment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): T .ing ''z- / Tubing Grade: Tubing MD(ft): 10695-13623 4329.34-4358.46 :'6.5#L-80 L-80 21-9859 Packers and SSSV Type: 5"Baker ZXP Top Packer Packers and SSSV MD(ft)and ND(ft): 9963,4187.63 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal X 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch • Exploratory ❑ Development ❑ Service ❑, 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ Q GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and . ect to the best of my knowledge. Contact Jessie Chmielowski Email Jessie.Chmielowski©BP.Com Printed Name Jessi=Chmielowski Title Production Engineer Signaturerl)/f-j-i , ` Phone 564-5015 ,D t� J Prepared by Garry Catton 564-4424 ♦ (/J COMMISSION USE ONLY Conditions of approval: Notify C. mission so that a representative may witness Sundry Number. 3\ ` ° l• Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 5 SCANNEfl AUG 0 6 2014 RBDMS iMAY 10 2014 Spacing Excep•.n Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: �(COMMISSIONE1R THE COMMISSION Date: Form 10-403 Revised 10/2012 ApproOaRictGiiv It fA21flbnths from the date of approval. Submit Form and Attachments in Duplicate -0 0 0 0 0 0 mCOCbCOCOCO 0 J J J J J N Q O 0 0 0 cD O O co L •;1- Co p N I— N- 10 0 OOOOoN- M coM V Lo O V V' N CO V CO CO 1"-- a) �U) Cn (6 CO O O m Oa O Co N N M N V V 'Cr 'Zr F- • O Cb Q C)- '— cV CO CV V V L F- (3 c Ln co mcocoC° a2 U) O Q ' OcoO0) O C CL Q 0 CO 1.0O U Q co O O CO N W O O O O 00 CO CO CO J J J COO J 4 J 10 N N Co co - O CO CX) _ N �C j - V' cam) co 0) CA N CO CO N N- CO Lo 00 OO J C) 0) Z O O mI I- U CC 0 Z Z WW O m O ZZ fD O J J d H Milne Point C-41 (PTD 201-079 & 201-122) Current Status The Milne Point well C-41 was drilled and completed as a Schrader Bluff formation producer in January 2001. The well has been shut in due to a failed ESP. MPC-41 was last online in 2009, and the well tested at 120 bopd, 20% WC and 1140 scf/stbo GOR. MPC-41 has no known casing problems. The Base Management team's (with approval from the Reservoir Management) plan forward is to convert well MPC-41 to an OA sand injector in the Schrader Bluff pool. The conversion will increase injection capacity in the hydraulic unit, establish new streamlines between wells and better support producers MPE-20A. Completion Well MPC-41 (Permit# 201-078) was completed in July 2001 with two laterals MPC-41L1 (Permit # 201-079) and MPC-41L2 (Permit # 201-122) as a Schrader Bluff producer. Both laterals are completed in the Schrader Bluff OA sand. A 13- 3/8" casing was run to 110' and cemented with 260 sacks of Arctic set cement. A 7" production casing was run to 11,197' MD and cemented in place with 1456 sacks of 10.7 ppg Arctic Set II cement followed by 792 sacks of 15.7 ppg Class G cement. During the cement job full returns were observed at the surface, approximately 500 bbls of cement. Following the cement job the casing was tested to 3500 psi for 30 minutes. Although no cement bond log was run after the cementing operation, we are confident that there is competent cement isolation on both the production and surface casing to facilitate a conversion from producer to injector. The well is completed with slotted liner in the Schrader Bluff OA sand. Plan Forward: 1) Obtain Sundry for conversion to water injection 2) Perform rig workover to remove ESP and complete well for injection service 3) Complete water injection header tie-in 4) Place well on water injection (confirm AOGCC approval prior to injection) 5) AOGCC witnessed MITIA once injection has stabilized Area of Review — Milne Point C-41 (PTD 201-079 & 201-122) This Area of Review is required prior to the conversion of well MPC-41 from a producer to a water injector. This AOR discusses wells within 1/4 mile of the well's entry point into the Schrader Bluff Formation to the bottom of MPC-41 well bore completion. Four other wellbores, MPA-01, MPA-03, MPE-20AL1 and MPG-03A, enter the Schrader Bluff formation in this area of review. The tables below illustrate the wells within the AOR, distance from MPC-41, completion details, and annulus integrity/cement conditions based on in-depth review of each well. Distance Well Name PTD (feet) Annulus Inte.rit MPC-41 201-079 0 TOC estimated at surface MPA-01 179-040 420 TOC at surface; well is P&A'd MPA-03 183-001 250 TOC at surface; well is P&A'd MPE-20A 204-054 580 TOC unknown MPG-03A 204-219 1210 TOC unknown Table 1: Table showing distance&annulus integrity of wells within AOR Hole Vol. of Well Name Casing Size Cement Schrader depth (MD) Schrader depth(TVDss) MPC-41 7" 8-1/2" 500 bbls 9816' -4105 MPA-01 9-5/8" 12-1/4" 400 bbls 4210' -4168 MPA-03 9-5/8" 12-1/4" 246 bbls 4504' -4168 MPE-20A 7-5/8" 9-7/8" 107 bbls 5320' -4236 MPG-03A 7" 8-1/2" 68 bbls 5871' -4080 Table 2: Completion Detail Well MPA-01 (Permit # 179-040) was completed in 1980. MPA-01 was drilled as an exploration well and the wellbore crossed the Prince Creek, Kuparuk, Sag and Sadlerochit formations. A 13-3/8" surface casing was run to 2766' MD and cemented to surface with 614 bbls of Howco Permafrost cement. A 9-5/8" production casing was run to 9719' MD and cemented in place with 328 bbls of Class G cement and 72 bbls of Permafrost 'C' cement. The well was plugged and abandoned in April 2008. Well MPA-03 (Permit # 183-001) was completed in 1983. MPA-03 was drilled as an exploration well and the wellbore crossed the Schrader Bluff formation in the N and 0 sands. A 13-3/8" casing was run to 2500' MD and cemented to surface with 410 bbls of Arco Fondu cement and 102 bbls of Permafrost 'C' cement. A 9- 5/8" production casing was run to 5095' MD and cemented in place with 195 bbls of Class G cement, 51 bbls of Permafrost 'C' cement and 130 bbls of Arctic Pac. The well was plugged and abandoned in December 2005. Well MPE-20A (Permit # 204-054), including lateral MPE-20AL1 (Permit # 204- 055), was completed in 2004. Producer MPE-20A's main wellbore is completed in the Schrader Bluff OA sand, and the MPE-20AL1 lateral is completed in the Schrader Bluff N sand. The well was sidetracked in May 2004 after abandoning the parent well MPE-20 (Permit # 195-071) with a EZSV set in the 9-5/8" casing at 4220' MD and pumping 30 bbls of Class "G" cement under while leaving 5 bbls of Class "G" cement on top of the EZSV. An EZ-BP (CIBP) was set in the 9-5/8" casing at 2700' MD, and the casing and plug were pressure tested to 1500 psi for 30 minutes. The 9-5/8" casing was cut at 2520' MD and pulled out of the well. 27 bbls of Arctic Set 1 cement was placed on top of the EZ-BP between 2700' MD and 2510' MD. A CIBP was set in the 13-3/8" casing at 2489' MD and pressure tested at 1500 psi for 30 minutes. In May 2004, after the parent wellbore was isolated, a window in the 13-3/8" casing was milled at 2457' MD and 7-5/8" casing was run and set to 5989' MD and cemented with 107 bbls of Class `G' cement. The 7-5/8" casing was pressure tested to 3500 psi for 30 minutes. During construction of the parent well, MPE-20 (Permit # 195-071), 13-3/8" surface casing was run to 2587' and cemented with 161 bbls of Permafrost `E' cement, 51 bbls of Class G cement and 31 bbls of Permafrost `E' cement. 9-5/8" casing was run to 4681' MD and cemented with 77 bbls of Class `G' cement. Well MPG-03A (Permit # 204-219) was completed in 2004. The well is completed as an injector in the Schrader Bluff N, OA, and OB sands. The well was sidetracked in September 2004 after abandoning the parent well MPG-03 (Permit # 189-046) with a EZSV set in the 7" casing at 4899' MD and pumping 38 bbls of Class `G' cement under while leaving 10 bbls of Class `G' cement on top of the EZSV. The rig performed a pressure test to 1500 psi for 30 minutes. A second EZSV was set in the 7" casing at 3201' DPM and pressure tested to 1500 psi while monitoring the OA (no indication of flow or communication was noted) prior to cutting the 7" casing at 1987'. A second EZSV cement retainer was set in the 7" casing at 1985' MD and 53 bbls of Arctic Set 1 cement was pumped below. In November 2004, after the parent wellbore was isolated, a window in the 9-5/8" casing was milled at 1981' MD and 7" casing was run and set to 6536' MD and cemented with 68 bbls of Class `G' cement. The 7" casing was pressure tested to 3000 psi for 30 minutes. During construction of the parent well, MPG- 03 (Permit # 189-046), 13-3/8" surface casing was run to 110' and cemented to surface using Arctic Set cement, 9-5/8" casing was run to 2931' MD and cemented with 181 bbls of Type `E' cement and 138 bbls of Class `G' cement. I \ PPE-03 0,1 MPB-23 M' •1PB1 MPB-25 MPBI' • PPE-.3APB2 MPC-41L2 PPE-13 - ✓03--<"-:-..A-01 1/PE-3333 MPA- f-13AP= MPB-09 -A-02A MP, 1 - ACE-18 MPC-41' MPE-20AL1 ..NNNNNNNMPE-19 It -zoA IN* �L :1 MPC-07 MPC-41L1 AoPG,03 - .‘,1 10°* ' 19 i000 i000 2000 3000 R MPG-11 Legend ii Wellbore with bottom hole symbol at Intersection of wellbore with Schrader Bluff Formation 1 1/4 mile distance from wellbore (NA intercept to TD) /Q: Figure 1: Map showing wells within 0.25 mi radius from MPC-41. . Tree: 2 9/16", 5M MP C-41 KB elev. =30.10' • Wellhead: FMC 11"x 11", 5M, Gen. 5 DF elev. =45.17' and 11"x 2 7/8" FMC Tbg. Hnr.w/ - GL elev. = 16.50' 8 rd EUE threads top and bottom and 2.5"CIW'H' BPV profile 13 3/8"72 ppf, L-80 Casing 115' Camco 2-7/8"x 1" 136' sidepocket KBMM GLM Tam port collar @ 1045' 0 7"26 ppf,L-80,Btrc.production casing drift ID=6.151",cap. 0.0383 bpf Camco 2-7/8'x 1" 9 739 ( = P ) sidepocket KBMM GLM 4.5"12.6#L-80 IBT-M tubing 9,849' (ID=3.958",cap=.0152 BPF) Hes XN-Nipple(2.205"id) L 80 8 rd EUE tubingTandem Pump,Upper 214 Stg. 9,871' 2 7/8"6.5 ppf, FC925 FPMTAR 1:1,Lower (drift ID=2.347",cap=0.00592 bpf) 16 Stg.GCNSPH,GPBMTAR 1:1 Tandem Gas Separator 9,897' SE5798GA Tandem Seal Section 9,902' KOP @ 300' gsb3dbabhsnpfsa/gsb3dbltabhsnfsa Max wellbore Angle:75°@ 3300'-10,050'MD Motor,95 HP, 1330 volt, 9,915' 44 amp,Model KMH 9,925' Hole angle trough perfs=90 deg. Centrilift Pumpmate gauge 7"x5"Baker SLZXP Liner top pkr. 9,962` 1111 1111011 Sleeve closed during RWO Upper Window 10,091'- 10,103' 4.5"Baker CMD Sliding sleeve 10,041' ••• • L2 4.5"HES XXN Nipple(3.725"No-Go) 10,398` „::r:titi.:::ti:: :{. r;'r'r:r . 'rr::::i:'r}: ?..'...: ' 4.5"12.6#L-80 IBT tubing Baker Tie back stem 5.25"-4.375" 10,419' 14 jts. of solid liner(10,109'- 10,696') 74 jts. of Slotted Liner (10,695'- 13,623') Lower Window (10,505' - 10,518') - = Baker float shoe @ 13,668' I Baker packoff bushing @ 13,623' ,,a L1 Baker HR setting sleeve 10,405' ........................................ Baker HMC liner hanger�- �'�ll / 9 10,421' A 83jts of slotted liner 10,515`-13,765' ( ) EZSV Bridge Plug#2 10,523' 4.5"12.6#L-80 IBT tubing (Above Abandoned Lateral) Baker Guide Shoe @ 13,810' Halliburton float collar 11,113' Baker Packoff Bushing @ 13,765' _ EZSV Bridge Plug#1 11,147' (Above Abandoned Lateral) Halliburton Casing shoe 11,194' Baker Payzone Packer(13,954'- 13,977') 3 jts 4.5"12.6#L-80 IBT Solid tubing Halliburton Float Collar 14,096' Abandoned Open-Hole OB Lateral to 12,205' MD 4.5"Halliburton Float Shoe 14,141' 7.5 bbls (493') cement(13,977'- 14,470) 4-1/2"SLOTTED INTERVALS OA L2- 10,515`- 13,765'MD 4,324'-4,345'TVD OA L1 - 10,695'- 13,623' MD 4,345'-4,348'TVD DATE REV. BY COMMENTS 7/13/01 MDO Drilled & Cased Nabors 22 e M I LN E POINT UNIT 7/24/01 B. Hasebe _ ESP Completion Nabors 4ES WELL C-41 8/07/03 MDO ESP RWO Nabors 4-ES API NO: 50-029-23014-00 12/22/04 MDO Isolate lower zone& ESP 4-ES BP EXPLORATION (AK) 12/12/05 MDO FCO L-01 liner& ESP Completion • Bettis, Patricia K (DOA) From: Lastufka, Joseph N [Joseph.Lastufka@bp.com] Sent: Monday, March 03, 2014 10:26 AM To: Chmielowski, Jessie; Bettis, Patricia K (DOA); Ferguson, Victoria L (DOA) Subject: RE: SBL MPC-41 L2: Sundry Application aor- taa Patricia, I think we have another confusing issue with this well... A separate set of MPC-41 Lateral sundries were submitted by me this past week (2/28), due to a rig workover which will pull the existing ESP completion and run a 4-1/2" tubing with packer completion. I believe that the 3 sundries submitted prior to mine (created by Garry Catron and signed by Jessie Chmielowski) are to be withdrawn and the 2 sundries that I submitted (signed by David Bjork) will replace them for tubing pull and conversion to injector. The Area of Review is attached to all the sundries. Victoria, Could you please help confirm my understanding and please let me know if you need any additional information? As always, thanks for your help! Joe From: Chmielowski, Jessie Sent: Monday, March 03, 2014 9:58 AM To: Lastufka, Joseph N Subject: FW: SBL MPC-41L2: Sundry Application Hi Joe, For the MPC-41 Sundry, can you please check Box 11 per Patricia's question below? I don't have the form in front of me to check the numbers. I have already answered her second question. Thanks,Jessie From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, February 27, 2014 1:23 PM To: Chmielowski, Jessie Subject: SBL MPC-41L2: Sundry Application Good afternoon Jessie, On the Form 10-403, Box 11, the effective depth is shown as 0 MD and 45'TVD. Is this correct? Also, I want to verify that the slotted liner interval for MPC-41L2 is from 10,695' to 13,623' MD; and for MPC-41L1,the slotted liner interval is from 10,515'to 13,765' MD. 1 Y . • Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907)793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 Bettis, Patricia K (DOA) a/y -W‘ IJ From: Chmielowski, Jessie [Jessie.Carr@bp.com] M C.- �1L2 Sent: Monday, March 0(, 2014 9:56 AMS To: Bettis, Patricia K DOA Subject: RE: SBL MPC-41L2: Sundry Application Hi Patricia, I'll check the info in Box 11 and get back to you. I see that there is a box at the bottom of the MPC-41 well schematic where the slotted liner intervals for L1 and L2 have been swapped. I'll get that updated. Yes, the slotted liner intervals you wrote below are correct. MPC-41L2: 10,695'to 13,623' MD MPC-41L1: 10,515'to 13,765' MD; there is also a portion of open hole between the Baker guide shoe at 13,810' MD and the Baker Payzone Packer at 13,954' MD. Thanks,Jessie From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Thursday, February 27, 2014 1:23 PM To: Chmielowski, Jessie Subject: SBL MPC-41L2: Sundry Application Good afternoon Jessie, On the Form 10-403, Box 11, the effective depth is shown as 0 MD and 45'TVD. Is this correct? Also, I want to verify that the slotted liner interval for MPC-41L2 is from 10,695' to 13,623' MD; and for MPC-41L1,the slotted liner interval is from 10,515'to 13,765' MD. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 Ferguson, Victoria L (DOA) From: Chmielowski, Jessie <Jessie.Carr@bp.com> Sent: Tuesday, March 04, 2014 2:17 PM To: Ferguson, Victoria L (DOA) Cc: Lastufka,Joseph N Subject: RE: SBL MPC-41(PTD 201-078, Sundry 314-096), SBL MPC-41L1(PTD 201-079, Sundry 314-097), SBL MPC-41L2(PTD 201-122, Sundry 314-098) Please withdraw the 3 Sundries for well MPC-41 that were created by Garry Catron and signed by me,Jessie Chmielowski. These are to be replaced by 2 Sundries for well MPC-41 that were submitted by Joe Lastufka and signed by David Bjork. Thanks,Jessie From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson(a alaska.gov] Sent: Tuesday, March 04, 2014 2:01 PM To: Chmielowski, Jessie Cc: Lastufka, Joseph N Subject: SBL MPC-41(PTD 201-078, Sundry 314-096), SBL MPC-41L1(PTD 201-079, Sundry 314-097), SBL MPC- 41L2(PTD 201-122, Sundry 314-098) Please respond to this email with a request to withdraw the subject Sundries. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave, Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson a(�alaska.gov 1 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _lnserts\Microfilm _ Marker. doc STATE OF ALASKA I RECEIVED ALASKalL AND GAS CONSERVATION CO MISSION J4bL 0 9 2006 REPORT OF SUNDRY WELL OPERt.1J8~~~scons.commission ., ,. 1. Operations Performed: Change 'Out ESP o Abandon o Suspend o Operation Shutdown o Perforate 1m Other o Alter Casing 1m Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 1m Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit 10 Drill Number: BP Exploration (Alaska) Inc. 1m Development o Exploratory 201-122-00 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23014-61-00 7. KB Elevation (ft): KBE = 45.17' 9. Well Name and Number: MPC-41L2 8. Property Designation: 10. Field 1 Pool(s): ADL 047437 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 13850 feet true vertical 4367 feet Plugs (measured) NIA Effective depth: measured 13850 feet Junk (measured) NIA true vertical 4367 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" X 13-3/8" 110' 110' 1530 520 Surface Intermediate Production 10054' 7" 10091 ' 4220' 7240 5410 Liner 3583' 4-1/2" 10085' - 13668' 4218' - 4360' 8430 7500 iC¡~NEr j !¡ì\Í <¡ 1 2005 Perforation Depth MD (ft): 10696' - 13623' Slotted Liner .0 ',,",- "h, .J Perforation Depth TVD (ft): 4330' - 4358' Slotted Liner 2-7/8",6.5# L-80 9931' Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# L-80 9962' - 10419' Packers and SSSV (type and measured depth): 7" x 5" Baker SLZXP Packer 9962' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Ft ,IAN 1 0 2006 13. ReDresentative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 1m Daily Report of Well Operations o Exploratory 1m Development o Service 1m Well Schematic Diagram 16. Well Status after proposed work: 1m Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing IS true ana correct to tne best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 N/A Printed Name §ondra Stewman Title Technical Assistant ~~ -- .- ,,){~~repared By Name/Number: Sign~ure ~>-'~().;r- Phone 564-4750 Date Ð l'-~1) ndra Stewman. 564-4750 . . Form 10-404 Revised 04/2004 Submit Onglnal Only nPI~'f\'^' e M P C-41 Tree: 29/16". 5M _ Wellhead: FMC 11" x 11", ~en. 5 and 1,1" x 2 7/8" FMC Tbg. Hm. wi 8rdEUE thre¡:lds tqpandbottom and 2.5" CIW 'H' BPV profile 133/8" 72 ppf, L-80 Casing ~ KB elev. = 30.10' DF elev. = 45.17' GL elev. = 16.50' Cameo 2-7/8" x 1" sidepocket KBMM GLM I 136' I Tam port collar @ 1045' 7" 26 ppf, L-80, Btre. production casing (drift 10 '" 6.151", cap. '" 0.0383 bpf) 4,5" 12,6# L-80 IBT-M tubing ( ID '" 3,958", cap'" ,0152 BPF ) 2 7/8" 6.5 ppf, L-80 8 rd EUE tubing (drift 10", 2.347", cap'" 0.00592 bpf) 9,739' I 9,849' I 9,871' I 9,897' I 9,902' I 9,915' I 9,925' I Cameo 2-7/8" xi" sidepoeket KBMM GLM Hes XN-Nipple ( 2,205" id) Tandem Pump, Upper 214 Stg, FC925 FPMTAR 1:1, Lower 16 8tg, GCNSPH, GPBMTAR 1:1 Tandem Gas Separator SE5798GA Tandem Seal Section gSb3dbabhsnpfsa 1 gsb3dbltabhsnfsa Motor, 95 HP, 1330 volt, 44 amp, Model KMH Centrilift Pumpmate gauge KOP @ 300 ' Max wellbore Angle: 75" @ 3300'-10,050' MD Hole angle trough perfs", 90 deg. 7"x5" Baker SLZXP Liner top pkr, Sleeve closed during RWO 110,041'1 4,5" Baker CMD Sliding sleeve 4,5" HESXXN Nipple (3,725" No-Go) 4.5" 12.6# L-80 IBT tubing 14 jts. of solid liner (10,109' - 10,696') 74 its. of Slotted Liner (10,695' - 13,623') Baker float shoe @ 13,668' Baker packoff bushing @ 13,623' Baker HR setting sleeve 110,405' I Baker HMC liner hanger 110,421' I EZSV Bridge Plug #2 110,523' I (Above Abandoned Lateral) Halliburton float collar 111,113' I EZSV Bridge Plug #1 111,147' I (Above Abandoned Lateral) Halliburton Casing shoe 1,11,194' I Baker Tie back stem 5.25" - 4.375" 83 its of slotted liner (10,515'-13,765') 4.5" 12.6# L-80 IBT tubing Baker Guide Shoe @ 13,810' Baker Packoff Bushing @ 13,765' Baker Payzone Packer (13,954' - 13,977') 3 its 4.5" 12.6# L-80 IBT Solid tubing Halliburton Float Collar 14,096' 4.5" Halliburton Float Shoe 14,141' 7.5 bbls (493') cement (13,977' - 14,470) Abandoned Open-Hole OB Lateral to 12,205' MD 4-1/2" SLOTTED INTERVALS OA L2 - 10,515' -13,765' MD 4,324' - 4,345' TVD OA L 1 - 10,695' - 13,623' MD 4,345' - 4,348' TVD DATE REV. BY COMMENTS 7/13/01 MDO Drilled & Cased Nabors 22 e MILNE POINT UNIT 7/24/01 B. Hasebe ESP Completion Nabors 4ES WELLC-41 8/07/03 MDO ESP RWO Nabors 4-ES API NO: 50-029-23014-00 12/22/04 MDO Isolate lower zone & ESP 4-ES 12/12/05 MDO BP EXPLORATION (AK) e Page 1 of 4 BP EXPLORATION Operations Summary Report MPC-41 M PC-41 WORKOVER Start: 12/6/2005 NABORS ALASKA DRILLING I Rig Release: 12/14/2005 NABORS 4ES Rig Number: From~, ~~__! Hours I Task t~o~~l NPT ~~~~~, ! 08:00 - 11 :30 3.50 RIGD P PRE 11 :30 - 17:30 6.00 MOB P PRE 17:30 - 00:00 6.50 MOB P PRE 00:00 - 06:00 6.00 MOB P PRE 06:00 - 15:30 9.50 MOB P PRE 15:30 - 23:00 7.50 MOB P PRE 23:00 - 00:00 1.00 RIGU P DECOMP 00:00 - 03:00 3.00 MOB P PRE Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date --,.,-....., 12/6/2005 12/712005 12/8/2005 03:00 - 06:00 3.00 KILL DECOMP P 06:00 - 08:00 2.00 KILL P DECOMP 08:00 - 08:30 08:30 - 09:30 09:30 - 11 :30 11 :30 - 14:00 0.50 WHSUR P 1.00 WHSUR P 2.00 BOPSUF P 2..50 BOPSUF P DECOMP DECOMP DECOMP DECOMP 14:00 - 14:30 14:30 - 17:30 0.50 BOPSUF P 3.00 PULL P DECOMP DECOMP 17:30 - 19:00 1.50 PULL DFAL DECOMP N 19:00 - 21 :00 2.00 PULL DFAL DECOMP N 21 :00 - 23:00 2.00 PULL DFAL DECOMP N Spud Date: 5/28/2001 End: 12/14/2005 Description of Operations -.----- ... .---..- .---.- Rig down. Prep to move. Move from DS 13 to Santa Fe pad. SD for weather. WOW. WOW (Phase 2 conditions). Continue to WOW. WOW Continue rig move from OS 13 to MPC-41. Spot rig over MPC-41. Spot rig & components. Rig up on well. Rig Accepted @ 03:00 hrs, 12/08/2005. PJSM. Spot tiger tank. RIU lines to tree & tiger tank & test @ 3500 psi, OK. Take on heated seawater. Pre job meeting with regard to circulating well wi kill wt fluid & general overview of workover. SITP = 0 psi, SICP = 0 psi. Line up & pump heated seawater down tubing @ 5 bpm I 250 psi, taking returns thru choke to tiger tank. Circulate 180 bbls total, monitor well, well dead. PJSM. Set two way check valve. PJSM. N/D wellhead. PJSM. N/U 135/8" x 5M BOPE. PJSM. Conduct full test on all BOPE components. 250/3500 psi. No failures. Test witnessed by Nabors Tool Pusher & BP Company Man. Witnessing of test waived by AOGCC rep Jeff Jones. PJSM, P/U lubricator & pull two way check vavle. PJSM. BOLDs. Pull hanger to floor & UD same, 24K up wt. M/U (2) jts 2 7/8" L-80 8 rnd tbg & RIH, tag Halliburton Storm packer wi pumping 3/4 bpm @ 75 psi. See pressure increase, shut down pump wi 300 psi trapped on tubing, indicating stabbed into top of Storm Packer. Bleed pressure and attempt to screw into Storm Packer wi 22 turns using chain tongs holding neutral wt. Had to go to power tongs and put 22 - 23 rt hand turns in tubing, maintaining torque below 2300 ftIlbs. Release torque, pull to 55K to verify packer unseated and attempt to circulate, no good. Pressured up on tubing, indicating circulation valve in Storm Packer closed or plugged. Repeat process several times wi no success. Pull (1) full joint and fill hole, monitor well, fluid slowly dropping. Con't to monitor well, well started to flow. Close in annular. As annular was closing fluid rose 5-6' above rig floor, due to annular not closing completely. Well shut in. Check pressure. No pressure showing on guage. Open bleed line & check well, well stable, Open annular. Fluid level could not be seen. Fill hole wi 20 bbls. Monitor well, FL slowly falling while annulus "boiling". ( air cutting thru fluid). Con't to monitor well. Notified AOGCC, Steve Rossberg, Dave Reem & MP front desk.. NOTE: The uncontrolled release was approx. 25 Gals. Entire Release was contained within rig. Reviewed operation wi Steve Rossberg & Formulated plan forward to attempt to shear out plug in Storm Packer. Pressure up to 4500 psi wi rig pumps to attempt to gain circulation. UD 2nd jt so as to be working @ floor level. Wait on Schlumberger pump truck. Printed: 12/21/2005 1:52:45 PM BP EXPLORATION Page 2 of 4 Operations Summary Report legal Well Name: MPC-41 Common Well Name: M PC-41 Spud Date: 5/28/2001 Event Name: WORKOVER Start: 12/6/2005 End: 12/14/2005 Contractor Name: NABORS ALASKA DRilLING I Rig Release: 12/14/2005 Rig Name: NABORS 4ES Rig Number: .__1 From ~ ~~._: Hour~_~.,_Task ~ ¡ ; Phase Description of Operations Date Code I NPT _n_.__. ._.u._...... _n. ....--.... ...--- .- .... . . n_.____...__. 12/8/2005 23:00 - 00:00 1.00 PULL N DFAL DECOMP Schlumberger arrive on location at 2300 hrs. PJSM prior to rigging up hardline. Rig up hardline and pumping eqpt. 12/9/2005 00:00 - 00:30 0.50 PULL N DFAL DECOMP Rig up hardline and pumping eqpt. 00:30 - 01 :00 0.50 PULL N DFAL DECOMP PJSM. Reviewed written procedure with rig crew and Schlumberger crew. Circulated 10 bbls. hot seawater through hardlines to prevent freezeup. Cleared rig floor of all personnel. Pressure tested lines to 8000 psi. Good test. 01 :00 - 01 :45 0.75 PULL N DFAL DECOMP Pressure up slowly on tubing and storm packer shear plug to 7500 psi. Volume to pressure up - .4 bbls. Held pressure for 5 minutes. Shear plug did not shear. Bled pressure back to 0 psi. Circulated 2 bbls. seawater through hardlines and pumping eqpt. to prevent freeze up. Pressure tubing and storm packer shear plug to 7500 psi. and held pressure for 5 minutes with no shear noted. Bled pressure to 0 psi. 01 :45 - 03:00 1.25 PULL N DFAL DECOMP Blow down hard line and pumping eqpt. Rig down hardline and pumping eqpt. 03:00 - 07:00 4.00 PULL N DFAL DECOMP Waiting on forward plan, bullheaded (70) bbls heated seawater down annulus @ 1 bpm 1550 psi. 07:00 - 11 :30 4.50 PULL N DFAL DECOMP PJSM. POOH, (wet), wi 27/8" tbg slowly, so as to avoid swabbing in well, 1 x 1, laying down singles. Hole taking right amount of fluid. 11 :30 - 14:00 2.50 PULL N DFAL DECOMP PJSM. Pull packer thru stack, note some small amounts of gas bubbling up thru seawater, fluid level in wellbore slowly dropping. NOTE: approximately (3 - 4) threads engaged in top of storm packer valve..., valve does not start to open until at least 12 threads engaged. Unscrew retrieving tool from storm valve. "0" ring needs repalcing.... order more from town. Clean out small rocks, dirt I mud from valve cavity. These obstructions were preventing retrieving tool from screwing in far enough to open storm valve, & also from plug being sheared wi 7500 psi. Cleaned out cavity & waited on "0" ring. Install "0" ring & screw retrieving tool into Storm Valve, (22) turns. RIH (30'), close bag & rig up to take returns thru choke to tiger tank. Bleed (gas) off tubing... 20 psi. 14:00 - 18:00 4.00 PULL P DECOMP PJSM. Line up & pump seawater down tubing, taking mostly crude returns thru choke & out to tiger tank. Take clean returns to pits. Circulating @ 3 1/2 bpm I 1600 psi. Circulte 1 1/2 total hole volumes. Monitor well, well stable. 18:00 - 22:00 4,00 KILL P DECOMP P/U & RIH wI 2-7/8" production tbg. 22:00 - 23:30 1.50 KILL P DECOMP Circulate bottoms up, 4 bpm @ 900 psi, small amount of gas back wI bottoms up. Monitor well, well stable. 23:30 - 00:00 0.50 KILL P DECOMP POH w/2-7/8" production tubing standing same back in derrick. 12/10/2005 00:00 - 04:00 4.00 PULL P DECOMP POH w/2-7/8" production tubing standing same in derrick. 04:00 - 06:00 2.00 CLEAN P DECOMP Clear & clean rig floor. R/U to P/U 2 7/8" PAC DP. 06:00 - 06:30 0.50 CLEAN P DECOMP PJSM. Run & set wear bushing. 06:30 - 07:00 0.50 CLEAN P DECOMP PJSM. Service rig. 07:00 - 10:30 3.50 CLEAN P DECOMP PJSM. M/U hollow, toothed cleanout mill. RIH on 125 jts 2 7/8" PAC drill pipe, XIO & jars. 10:30 - 13:00 2.50 CLEAN P DECOMP PJSM. Rig up to run 31/2" DP & RIH w/3 1/2" DP, 45 jts, 13:00 - 15:00 2.00 CLEAN P DECOMP PJSM, Pick up & assemble kelly & swivel, upper & lower kelly I cocks, Pressure test same @ 350 I 3500 psi. Upper kelly cock failed pressure test, change out same & test, OK. 15:00 - 21 :30 6.50 CLEAN P DECOMP Swivel leaking. Work on & repack swivel. P/U bails. I I e Printed: 12/21/2005 1:52:45 PM e Page 3 of 4 BP EXPLORATION Operations Summary Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES " Dat~ _ __I ~rom -uTa ¡ Hours ! Ta~k--' Code 12/10/2005 21 :30 - 00:00 2.50 CLEAN P 12/11/2005 00:00 - 01 :00 1.00 CLEAN P 01 :00 - 02:00 1.00 CLEAN P 02:00 - 06:00 4.00 CLEAN P 06:00 - 11 :00 5.00 CLEAN P 11 :00 - 16:30 5.50 CLEAN P 16:30 - 00:00 7.50 CLEAN P 12/12/2005 4.50 CLEAN P 00:00 - 04:30 Start: Rig Release: Rig Number: ¡ ¡ NPT Phase ì DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 04:30 - 06:00 1.50 CLEAN P DECOMP 06:00 - 07:30 1.50 CLEAN P DECOMP 07:30 - 17:00 9.50 CLEAN P DECOMP 17:00 - 20:30 3.50 CLEAN P DECOMP 20:30 - 21 :00 0.50 RUNCO RUNCMP 21 :00 - 22:00 1.00 RUNCO RUNCMP 22:00 - 00:00 2.00 RUNCO RUNCMP 12/13/2005 00:00 - 02:00 2.00 RUNCO RUNCMP 02:00 - 06:00 4.00 RUNCO RUNCMP 06:00 - 12:00 6.00 RUNCMP 12:00 - 13:30 1.50 RUNCMP 13:30 - 20:30 7.00 RUNCMP 12/6/2005 12/14/2005 Spud Date: 5/28/2001 End: 12/14/2005 Description of Operations ....... n_'" ,__.._n_... Con't to P/U 31/2" DP 1x1 & RIH wI clean out assy. Con't to P/U DP & RIH to TOL @ 9962'. 192 jts 31/2" DP + BHA. R/U circulating head. Close in annular & Reverse 2 pipe volumes to surface, Losses were 100 BPH @ 4 BPM. 36 BPH @ 3 BPM. Had small amount of gasto surface. Also had black heavy oily returns. P/U 15 singles of 3-1/2" DP & RIH. Stop and circualte two bottoms up. Returns contain crude oil and small amount of very fine solids. Fluid losses -56 bbls/hr. PIU additional 15 singles 3-1/2" DP and stop and circulate two bottoms up with EP mud lube mixed in fluid. returns contain crude oil and small amount of very fine solids. Fluid losses -56 bbls./hr. 251 jts in the hole @ 11,835'. Continue to reverse circulate down singles @ 3 1/2 bpm, 900 psi. Seeing spotty sandy returns. PJSM. WI 272 jts of 3 1/2 DP in the hole @ 12,503', begin seeing heavy solids returns, very fine sand & some oil. Shaker unable to catch fine sand, Reverse circulating down singles, circulating (20) bbls between each connection, and reversing to clean returns every (5) connections. 3 1/2 bpm @ 900 - 1100 psi. 107K up wt, 37K down wt. Added 2nd bbl of EP mud lube to system. @ 16:30 hrs, 282 jts in the hole @ 12,817'. Con't to Clean out well bore to 13388'. 300 jts of 31/2" DP in hole. Reversing in singles, 3 112 BPM @ 1000 psi. PIU 11 OK SIO 35K. Reversing out heavy black very fine grained sand. Con't to Reverse out & clean well bore from 13388 to 13777'. Had hard fill from 13529 to 13550'. P/U wt 11 OK, SIO 35K. Reversing @ 31/2" BPM @ 800-1000 psi. Packed off several times from 13706 to 13777'. Could not get deeper than 13777'. Returns consisted of very fine grain sand & heavy black oily material. Mix & pump 2-20 bbl Hi-Vis sweeps while reversing well bore clean. Displacing well wi clean seawater & produced water. 3 1/2 BPM @ 1000 psi. PJSM. Continue reverse circulating @ 3112 bpm @ 1000 psi, see both sweeps come back & circulate to clean returns. PJSM. POOH & lay down 31/2" DP. PJSM. POOH & LID 2 7/8" PAC DP. P/U running tool. Pull Wear Bushing. LID same. Clear & clean rig floor. R/U floor & tools to run completion. Hang sheave. Load ESP into pipe shed. P/U, M/U & service ESP. Pull MLE over sheave. Damaged MLE. Re-splice MLE. Plug in & test ESP. PJSM. RIH wi ESP assembly on 2 7/8" L-80 6.5# EUE 8rnd tubing, megging ESP cable & pumping down tubing every 2000', OK. PJSM. WI total of 68 stands in the hole, rig up to run heat trace & pull same over sheave. PJSM. RIH wi 2 7/8" completion string, ESP cable & heat trace. Printed: 12/21/2005 1:52:45 PM · e Page 4 of 4 BP EXPLORATION Operations Summary Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date I Fr~~- ToJHours I Ta~k I Code 12/13/2005 20:30 - 00:00 3.50 RUNCO 12/6/2005 12/14/2005 Spud Date: 5/28/2001 End: 12/14/2005 Start: Rig Release: Rig Number: NP~ I_p~ase RUNCMP 12/14/2005 00:00 - 01 :30 1.50 RUNCMP 01 :30 - 06:00 4.50 RUNCMP 06:00 - 06:30 0.50 RUNCMP 06:30 - 08:30 2.00 RUNCMP 08:30 - 09:00 0,50 RUNCMP 09:00 - 14:00 5.00 RUNCMP 14:00 - 15:00 1.00 RUNCMP 15:00 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 20:00 2.00 BOPSU P 1.00 WHSUR P 1.00 RUNCO 1.00 WHSUR P RUNCMP RUNCMP RUNCMP RUNCMP Description of Operations PJSM. W/total of 89 stands in the hole, change out spools and make splice WI total of 89 stands in hole splice and test cable. Fill hole and flush pump PJSM. RIH wi ESP assembly on 2 7/8" L-80 6.5# EUE 8rnd tubing, megging ESP cable & pumping down tubing every 2000', OK. Service rig. PJSM. Continue to RIH w/2 7/8" completion string wi ESP cable & heat trace cable. PJSM. M/U landing joint, install penetrator. PJSM. Make heat trace splice & ESP field connector & test, OK. RID equipment & clear floor. PJSM. Land completion string & RILDs. 56K up wt, 29K down wt. On ESP cable, used (108) La Salle clamps, (3) flat guards & (5) protectrolizers. On heat trace, used (1688) bands, (539) 6' flat guards, (30) 4' flat guards & (4) 3' flat guards. Install 2 way check valve. PJSM. NID BOPE. PJSM NIU Tree Test tree to 5000 psi Final check ESP PJSM PIU Lubricator Pull TWC and set PBV UD Same Printed: 12/21/2005 1 :52:45 PM [Fwd: 4ES gas bubble] e e Subject: [Fwd: 4ES gas bubble ] , From: Jeff Jones <jeffjones@admin.state.ak.us> Da,te: Frj~ 09 Dee 200Sp :03:09 -0900.."", l'ô:'j'JamesRegg',<jim~regg@ådmitLstate.ak tŒ? ,,-' . \\'1"':, 'X-f?(.Il \Z,,~~ \v . '. ., '. ',,: L~· ". ;'l~~' 1 CL... if" c~Or""1 t7u'lfl v r Hi Jim, This incident was originally reported to me at taken on Nabors 4ES re-entering MPU well C-41. Thanks, Jeff 1830 hrs. yesterday as a 10 BBL kick Content-Type: message/rfe822 4ES gas bubble Content-Encoding: 7bit ijt;hN~'{tL c I of I 12/9/2005 I :00 PM 4ES ga,s bubble e e Subject: 4ES gäs bubble ,'.>",..' ..' .' From: "NSU, ADW I?rlgRig 4ES'i<N~UADWDrlgRig4ES@BP.com> D~te:Fri;,':09 pee .2005 08:~p:03';0900 . rô: jë'ff j onè:š@adtni#~statè"iäk.t1·š>· . '$\';;.,. :.. '. .. . ..,~"". ",.. ."' Jeff, As per our phone conversation, here is what happened. Date of incident: 12/08/2005 Time: 17:50 hrs Location: Milne Pt C-41 Scenario: A Halliburton Storm Packer was set @ 2330' w/ approximately 7500' of 27/8" tubing hanging off below it. We went in to retrieve the Storm Packer. This is done by screwing into the packer and opening the storm valve which allowas us to pump thru the packer & on down the tubing. For some reason, (yet to be determined), the valve did not function properly. We were, however, able to screw into the packer with the retrieving tool, and successfully unseat the packer. The well was monitored for approximately 45 minutes. Residual gas, that was trapped under the packer, migrated up the hole and flow was noted. The annular preventor was closed at the remote station, but the solenoid actuator did not cause the valve at the accumulator to go all the way over to the closed position. As a result, the annular preventor did not close all the way. As a result, fluid sparyed above the rig floor 5' -6'... approximately 25 gallons. The problem was rectified, the annular closed & well shut in. No discernable pressure was seen on any of the gauges. We bled off the well thru the choke... very small amount of gas..and filled the hole and monitored. The well was stable, taking a small amount of fluid. No flow, no influx, just residual gas that had accumulated under the packer. Let me know if you need more. 4ES gas bubble I of I 12/9/2005 12:23 PM ", STATE OF ALASKA "", RECEI ALASKA _~L AND GAS CONSERVATION CChv;MISSION " ': REPORT OF SUNDRY WELL OPERATION~N 27 Z005 ¡ 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 45.17' B Repair Well 0 Plug Perforations 0 Stimulate B Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well ChcAgt~~ BOther 0 Time Extension 13850 feet 4367 feet Plugs (measured) NIA 13850 feet Junk (measured) NIA 4367 feet Size MD TVD Burst 20" X 13-3/8" 110' 110' 1530 8. Property Designation: ADL 047437 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface I nterm ediate Production Liner Length 110' 10054' 3583' 7" 4-1/2" Perforation Depth MD (ft): 10696' - 13623' Slotted Liner Perforation Depth TVD (ft): 4330' - 4358' Slotted Liner 4. Current Well Class: B Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 201-122-00 6. API Number: 50-029-23014-61-00 9. Well Name and Number: MPC-41L2 10. Field 1 Pool(s): Milne Point Unit 1 Schrader Bluff Collapse 520 10091' 4220' 10085' - 13668' 4218' - 4360' SCANNED FE8 0 2 2005 7240 5410 2-7/8",6.5# Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# Packers and SSSV (type and measured depth): 7" x 5" Baker SLZXP Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): L-80 L-80 9923' 9962' - 10419' 9962' Treatment description including volumes used and final pressure: RBDMS 8Ft JAN:} 1 2005 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run B Daily Report of Well Operations B Well Schematic Diagram Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure Tubinq Pressure 15. Well Class after proposed work: 0 Exploratory iii Development 0 Service 16. Well Status after proposed work: BOil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 N/A printe.~_~~~,ondra Stewman , , S~ature ~~Á~.-/'-- Form 10-404 Revised 04/2004 Title Technical Assistant Phone~", '""""'~,,,,'" , ~7:/;Õ.,,: G.,,'!,,', f , R1 ï ~ 11' ,~i sJ <:, :', '~" ,î l Prepared By Name/Number: ID~ -lvt::;,-os Sondra Stewman, 564-4750 L- Submit Original Only 1. ,'j MP C-41l.\ ~~l ~:~~e~~:~~'C 51~" x 11", 6.,:ben. 5 and 11" x 2 7/8" FMC Tbg. Hnr. wi 8 rd EUE threads top and böttom and 2.5" CIW 'H' BPV profile 133/8" 72 ppf, L-80 Casing 1 115' 1 ~ Tam port collar @ 1045' 0 7" 26 ppf, L-80, Btrc. production casing ( drift 10 ::: 6.151", cap. ::: 0.0383 bpf ) 4.5" 12.6# L-80 IBT-M tubing ( 10 = 3,958", cap = .0152 BPF ) 27/8" 6.5 ppf, L-80 8 rd EUE tubing (drift 10 = 2.347", cap = 0.00592 bpf) KOP @ 300 ' Max wellbore Angle: 75° @ 3300'-10,050' MO Hole angle trough perfs = 90 deg. KB elev. = 30.10' DF elev. = 45.17' GL elev. == 16.50' ) , r 136' I 19,739' 1 1 9,859' I 19,889' I 19,894' I I 9,908' I 19,923' I I 9,962' I - . r /' Sleeve open during RWO I I - Þt'" Upper Window 10,091' - 10,103' 10,041' ... L2 7"x5" Baker SLZXP Liner top pkr. 4,5" Baker CMO Sliding sleeve 4,5" HES XXN Nipple (3.725" No-Go) XN Plug installed on rig 12/22/04 Cameo 2-7/8" x 1" sidepocket KBMM GLM Camco 2-7/8" x 1" sidepoeket KBMM,GLM Tandem Pump, Upper 214 Stg. FC925 FPMT AR 1: 1, Lower 16 Stg. GCNSPH, GPBMTAR 1:1 Tandem Gas Separator SE5798GA Tandem Seal Section gSb3dbabhsnpfsa I gsb3dbltabhsnfsa Motor, 95 HP, 1330 volt, 44 amp, Model KMH Centrilift Pumpmate gauge 110,398' I 110,419'1 .== Baker Tie back stem 5.25" - 4.375" =9 F Lower Window (10,505' - 10,518') - - [Q 4.5" 12.6# L-80 IBT tubing 14 jts. of solid liner (10,109' - 10,696') 74 jts. of Slotted Liner (10,695' - 13,623') Baker float shoe @ 13,668' Baker packoff bushing @ 13,623' ./ Baker HR setting sleeve 110,405' 1 ./ Baker HMC liner hanger 110,421' I --- EZSV Bridge Plug #2 110,523' I (Above Abandoned Lateral) Halliburton float collar 111,113' I --- EZSV Bridge Plug #1 111,147' I ~ (~~~ve Abandoned Lateral) ~Iiburton Casing shoe 111,194' I ~andoned Open-Hole OB Lateral to 12,205' MD ^ 83jts of slotted liner ( 10,515'-13,765') 4.5" 12.6# L-80 IBT tubing Baker Guide Shoe @ 13,810' Baker Packoff Bushing @ 13,765' Baker Payzone Packer (13,954' - 13,977') 3 jts 4.5" 12.6# L-80 IBT Solid tubing Halliburton Float Collar 14,096' 4.5" Halliburton Float Shoe 14,141' 7.5 bbls (493') cement (13,977' - 14,470) L1 ~ 4-1/2" SLOTTED INTERVALS OA L2 - 10,515' - 13,765' MD 4,324' - 4,345' TVD OA L 1 - 10,695' - 13,623' MD 4,345' - 4,348' TVD DATE REV. BY COMMENTS 7/13/01 MDO Drilled & Cased Nabors 22 e 7/24/01 B. Hasebe ESP Completion Nabors 4ES 8/07/03 MDO ESP RWO Nabors 4-ES 12/22/04 MDO Isolate lower zone & ESP 4-ES MILNE POINT UNIT WELL C-41 (þ API NO: 50-029-23014-œ ~ '5D - OZt1 -1..~lJl ~ ~ lot -00 BP EXPLORATION (AK) 00 II< 'þ ) ') 8P,EXPLOHATION Oper~ti~n~$ummary Réport PágE:) 1óf6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-41 MPC-41 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/15/2004 Rig Release: 12/27/2004 Rig Number: Spud Date: 5/28/2001 End: Date From - To Hours Task Code NPT Phase Description of Operations 12/15/2004 11 :00 - 13:00 2.00 RIGD P PRE PJSM. Scope down & lower derrick. Rig down rig components. 13:00 - 20:00 7.00 RIGU P DECOMP PJSM. Move around pad & rig up on MPC-41. Raise & scope up derrick. Accept rig at 1800 hrs. 20:00 - 21 :30 1.50 WHSUR P DECOMP P/U Lubricator, pull BPV, LID Lubricator. R/U lines to Tiger Tank and test. Double check lines. R/U lines to tree and test to 3500 psi. SITP 710 psi, SICP 20 psi. 21 :30 - 22:00 0.50 KILL P DECOMP PJSM--Pre-Spud safety meeting wI all crew. 22:00 - 22:30 0.50 KILL P DECOMP Bleed down well to TP 20, CP 30. Circ hot seawater thru tbg punches @ 8919-8921', 3-4 BPM @ 30-50 psi for 90 Bbls. 22:30 - 23:30 1.00 KILL P DECOMP SI annulus and bullhead 3-tubing volumes, -150 Bbls, 3 BPM @ 1200 psi. 23:30 - 00:00 0.50 KILL P DECOMP Open annulus and circulate back to Tiger Tank. 12/16/2004 100:00 - 02:30 2.50 KILL P DECOMP Continue circulation of heated seawater thru annulus, 3 BPM I @ 210 psi, for 530 Bbls, until 8.5 ppg seawater returns cleaned up. Monitor well--on vacuum. 02:30 - 03:00 0.50 WHSUR P DECOMP Install TWC. RID surface lines and HCR Valve. 03:00 - 04:00 1.00 WHSUR P DECOMP NID Tree and Adaptor Flange. Load and tally 3-1/2" DP in Pipe I Shed. 104:00 - 07:00 3.00 BOPSUP P DECOMP N/U BOPE. Continue to load and tally DP in Pipe Shed. 07:00 - 10:30 3.50 BOPSUP P DECOMP PJSM. Perform complete BOPE test. All valves & rams tested @ 250 I 3500 psi. Annular preventor tested @ 250 I 3500 psi. Perform drawdown test. No failures. Witnessing of test waived by AOGCC North Slope Rep Jeff Jones. 10:30 - 11 :30 1.00 PULL P DECOMP PJSM. Pick up lubricator. Pull two way check valve. M/U landing joint & BOLDS. 11 :30 - 12:00 0.50 PULL P DECOMP PJSM. Pull hanger to floor. Hanger pulled free @ 50K, up weight increased slowly to 70K & broke back to 61 K. 12:00 - 13:30 1.50 PULL P DECOMP Rig up to pull ESP. LID hanger. Fill hole, 24 bbls to fill. Static fluid level is approximately 800'. 13:30 - 20:30 I 7.00 PULL P DECOMP PJSM. POOH w/2 7/8" ESP completion & heat trace, double displacing on hole fill. 20:30 - 21 :30 1.00 PULL P DECOMP Change out cable reels. 21 :30 - 00:00 2.50 PULL P DECOMP Continue POOH wI ESP, SIB 2-7/8" tubing in Derrick. 12117/2004 00:00 - 01 :00 1.00 PULL P DECOMP Pulled ESP to Drill Floor, recovered 104 stands + 1 joint of 2-7/8",6.5#, L-80, EUE 8 Rd tubing. 01 :00 - 03:00 2.00 PULL P DECOMP Breakout, check and LID ESP components. 03:00 - 04:00 1.00 PULL P DECOMP RIH wl10 stds to find tubing punches. Found in 94th stand, breakout and LID bad joint. 04:00 - 04:30 0.50 PULL P DECOMP POH and SIB 2-7/8" tbg in derrick. 04:30 - 06:00 1.50 PULL P DECOMP Clear and clean rig floor. 06:00 - 08:00 2.00 FISH N WAIT DECOMP Phase III declared at Milne Pt. High winds causing blocks to swing. Huddle up & discuss safe plan forward. 08:00 - 09:00 1.00 FISH P DECOMP PJSM. Pick up Lateral Diverter BHA. 09:00 - 18:00 9.00 FISH P DECOMP PJSM. RIH wI lateral diverter BHA on 31/2" DP, picking up DP 1 xi, slowly, due to wind. 18:00 - 19:30 1.50 FISH P DECOMP P/U Kelly and get parameters: P/U 127K, SIO 25K. Work Diverter into top lateral, watch wt drop to 15K, P/U to -140K, SIO to 15K, P/U and get good indication of latching. Depth is 308 jts + 36' on Kelly = -10,1 09'. S/O and begin pumping 2 BPM @ 750#, 3 BPM @ 1200#,4 BPM @ 2000#. Stop pump, PlU and pull out of Diverter wI 130K, dropping back to 125K. 19:30 - 22:30 3.00 FISH P DECOMP POOH wI BHA #1, SIB DP in Derrick. 22:30 - 00:00 1.50 FISH P DECOMP M/U BHA #2: Bullnose Sub, 2-5/8" DB Cutter, VIP Mud Motor, Printed: 12/31/2004 9:22:10 AM .) ) BPEXPLORA TION OPE!r~~iø'fI$$ummary Report Pag~2 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-41 MPC-41 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/15/2004 Rig Release: 12/27/2004 Rig Number: Spud Date: 5/28/2001 End: Date From - To Hours Task Code NPT Phase Description of Operations 12/17/2004 22:30 - 00:00 1.50 FISH P DECOMP Stabilizer on 9-DC's. 12/18/2004 00:00 - 01 :00 1.00 FISH P DECOMP Continue M/U BHA #2. 01 :00 - 04:00 3.00 FISH P DECOMP RIH BHA #2 on 3-1/2" DP from Derrick. 104:00 - 04:30 0.50 FISH P DECOMP Position Cutter BHA above top of Diverter at 10,089', enter and stop wI No-Go Stabilizer on top of Diverter wI 309 jts + 6' in hole. Cutter located @ 10,126'. 04:30 - 06:00 1.50 FISH P DECOMP Start pump and begin cutting operations; 1/2 BPM/800 psi to 1-1/2 BPM 3000 psi. Pump 1000 stks (59 Bbls), SD pump, then 06:00 - 07:00 I resume to verify cut. 1.00 FISH P DECOMP Continue wI cutting operation as above. 1.5 bpm @ 3000 psi. 07:00 - 08:00 1.00 FISH P DECOMP WI cutter on depth, mix & pump weighted pill & pump (30) bbls @ 1.5 bpm @ 3000 psi. 08:30 - 10:00 1.50 FISH P DECOMP PJSM. Slip & cut drilling line. 10:00 - 12:00 2.00 FISH N RREP DECOMP Thaw kill line & mud cross. 12:00 - 16:00 4.00 FISH P DECOMP PJSM. POOH (wet) wi 31/2" DP. 16:00 - 17:00 1.00 FISH P DECOMP PJSM. Stand back collars & UD motor I under-reamer assembly. 17:00-19:00 2.00 FISH P DECOMP Inspect cutter blades on underreamer & remove same. Decide to make additional cutter run wI new blades to ensure clean cut. Make up new cutter assy. No dimensional change to BHA. 19:00 - 23:00 4.00 FISH P DECOMP RIH wI new Cutter BHA on DP from Derrick. Position Cutter assy inside Diverter, P/U and establish parameters: P/U 123K, 8/0 25 K. - 00:00 1.00 FISH P DECOMP Start pump, slowly increase from 1/2 BPM @ 300 psi to 1-1/2 BPM @ 3300 psi. Cut for 1-hour. 12/1 9/2004 00:00 - 01 :00 1.00 FISH P DECOMP SID Pump, then restart to verify cut following step-rate to 1-1/2 BPM @3300 psi. OK. Break-out and SIB Kelly. 01 :00 - 05:00 4.00 FISH P DECOMP POH wI 2nd Cutter BHA, SIB DP in Derrick. 05:00 - 06:00 1.00 FISH P DECOMP Breakout and UD Cutter Assy, pull blades and evaluate same. 06:00 - 07:00 1.00 FISH P DECOMP Inspection of blades inconclusive. (1) blade broken off at the "hilt". Opt to run in wI GS pulling tool. M/U same. 07:00 - 10:00 3.00 FISH P DECOMP PJSM. RIH wI GS retrieving tool on 3 1/2" DP, 309 jts total. 10:00 - 10:30 0.50 FISH P DECOMP PJSM. Pick up kelly & establish parameters. 137K up wt, 26K ! down wt. Note slush I ice in returns. 110:30 - 11 :00 0.50 FISH P DECOMP Line up & circulate 105 degree seawater the long way @ 4 bpm I I 2000 psi until we get 60 - 65 degree returns coming back. 111 :00 - 12:00 1.00 FISH P DECOMP PJSM. Kill pump & slack off, tag @ 10,090', (5') in on kelly. i Stack out 5 - 10K. Pick up & see overpull to 151 K & lost I I weight. Pick up (20') & slack off & tag & stack 5 - 10K as I before. Pick up & see overpull wI some drag. Break off kelly. I Start to POOH & notice drag gone. Pick up jt # 310 & tag up @ i I 10,085' .... ? I 112:00 - 16:00 4.00 FISH P DECOMP PJ8M. POOH wI Fishing BHA, filling hole wI heated seawater. 116:00 - 16:30 0.50 FISH P DECOMP PJSM. Stand back collars & UD BHA. Recovered diverter. i 16:30 - 17:30 1.00 FISH P DECOMP PJSM. Pick up fishing BHA...4 1/2" spear, stop sub, bumper I sub, oil jars, & (9) 4 3/4" DCs. 117:30 - 21 :00 3.50 FISH P DECOMP RIH BHA #4 on 3-1/2" DP. ! 21 :00 - 22:30 1.50 FISH P DECOMP P/U Kelly, build 40 Bbls EP Mud Lube Pill. Spot same. i 22:30 - 00:00 1.50 FISH P DECOMP Parameters: P/U 100K, S/O 50 K. Slowly work down into i Diverter and stack out @ 10,090'. Engage and P/U 200K, no i give. Work pipe to set off jars @ 200 - 220K for 1-hour, pulled i I as high as 275K with no success. Mix up dry job to prepare to I I POOH. I I I Printed: 12/31/2004 9:22:10 AM . ì ) ) BP EXPLOHA TION Operations Summary Report Page30f 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-41 MPC-41 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/15/2004 Rig Release: 12/27/2004 Rig Number: Spud Date: 5/28/2001 End: Date From - To Hours Task Code NPT Phase Description of Operations 12/20/2004 00:00 - 04:00 4.00 FISH N DFAL DECaMP Pump dry job and POOH, SIB DP in Derrick. 04:00 - 05:00 1.00 FISH N DFAL DECOMP Break-out and LID 4-1/32" Spear, Bumper Sub, Oil Jars. M/U BHA #6 Lateral Diverter, 5" Baker GS running tool, 9-DCs. 05:00 - 08:30 3.50 FISH N DFAL DECOMP RIH wI BHA #6, on DP from Derrick. 308 jts total. 08:30 - 09:30 1,00 FISH N DFAL DECaMP PJSM. Kelly up & establish parameters. 88K up wt, 55K down wt. Slack off, kelly all the way down. Add 5' pup. Tag up 38' in on # 308. Bottom of diverter @ 10, 111'. Set down 15K & pick up, see overpull of 10K, verified latched in. Set back down wI 10K on hanger. Bring on pump @ 4 bpm I 1700 psi & slowly come off diverter wI GS running tool. Max weight up = 91 K. 09:30 - 10:30 1.00 FISH N DFAL DECOMP POOH wI GS running tool. 10:30 - 12:00 1.50 FISH N DFAL DECOMP PJSM, Slip & cut drilling line. 12:00 - 15:00 3.00 FISH N DFAL DECOMP Continue to POOH wI GS running tool. 15:00 - 16:00 1.00 FISH N DFAL DECOMP PJSM. LID GS running tool. P/U 3 1/8" Multi String Cutter Assembly. 16:00 - 20:00 4.00 FISH N DFAL DECOMP RIH w/3 1/8" Multi String Cutter. 20:00 - 21 :30 1.50 FISH N DFAL DECOMP Position Multi-string Cutter @ 10,120' and establish free rotation parameters: P/U 84K, SIO 55K, 64 RPM, Rot Wt 70K, Torque 3,000 ft-Ibs. Continue rotating, start pump and work up to 79 SPM, 1250 psi. Can't see torque change with cutters extended. Rotate for 1-hour. Stop pump and rotation, P/U 5', lower to verify cut, but can't see change on wt indicator. 21 :30 - 00:00 2.50 FISH N DFAL DECOMP POH and SIB DP, 12/21/2004 00:00 - 01 :00 1.00 FISH N DFAL DECOMP Continue POH wI Multi-cutter BHA. 01 :00 - 04:00 3.00 FISH N DFAL DECOMP SIB DC's, LID and examine Multi-cutter at surface and see no wear that would indicate that a cut was made. Decide to run same blades back in and increase circulating pressure for next cutter run. Confer wI town, at the same time, Baker stripped cutter sub and found sand that appeared to be stopping actuating piston movement, which explained the very limited movement of the blades. 04:00 - 08:00 4.00 FISH N DFAL DECOMP RIH wi same Multi-String Cutter and blades. 08:00 - 09:30 1.50 FISH P DECOMP PJSM. P/U 5' pup & kelly up. Establish parameters. 82K up wt, 58K down. 69K rotating wt. RIH & tag top of diverter wI drill collars with 308 jts in the hole + 40'...5; pup & 35' of kelly..reference point. P/U & position cutter 36' in on rotary @ 10,119' DPM. Kick in rotary table, freespin torque @ 3000 ft/lbs, 60 RPM. Bring on pump & gradually increase initial rate of 2 bpm @ 400 psi to 6 bpm @ 2200 psi over a period of 5 - 10 minutes. Saw some torque increase in the 1 st 5 minutes, maybe 200 - 300 ft/lbs, then dropped back to 3000 ftllbs. Continued with cut for another 25 - 30 minutes. Shut down pump & rotary & pick up 10'. Bring on pump @ 500 psi & slack off slowly, see normal down weight start to drop off 36' in on 09:30 - 10:30 I kelly indicating cut. 1.00 FISH P DECOMP PJSM. Reverse circulate 1.5 DP volumes @ 5 bpm 11100 psi. Observe some pipe dope but no solids in returns. 10:30 - 11 :30 1.00 FISH P DECaMP Consult town & opt for another cut. Kick in pump & slack off, see weight drop 31' in on kelly, looks like collar where 2.5' pup & 1st full jt meet. Opt to pick up (1 '). Position cutter wI 30' in on kelly @ 10,113'. Kick in rotary table @ 60 RPM and bring on pump, gradually increasing rate to 5112 bpm @ 2000 psi. Continue with cut for 30 minutes. Kick off pump & rotary table, Printed: 12/31/2004 9:22:10 AM , , ') ') BP" EXPLORATION Operêltions$YI'rIITIary Report Page 4 of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-41 MPC-41 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/15/2004 Rig Release: 12/27/2004 Rig Number: Spud Date: 5/28/2001 End: Date From - To Hours Task Code NPT Phase Description of Operations 12/21/2004 10:30 - 11 :30 1,00 FISH P DECOMP pick up & slack off wI pump on, see collar wI 31' in on kelly but no good indication of 2nd cut. 11 :30 - 15:00 3.50 FISH P DECOMP PJSM. Stand back kelly & POOH wI 3-1/8" multi string cutter assembly. Blades on the Multi-String Cutter had wear patterns that indicate metal cutting had been accomplished, but not sure whether or not tubing wall has been fully cut. Wear patterns on actuating fingers of each blade show that the blade fingers were heavily impacted by the pressure transfer piston. The wear on these fingers was much more severe than on the previous run of this tool and on the blades run with the VIP Mud Motor. 15:00 - 16:00 1.00 FISH P DECOMP Clear and clean Rig Floor. 16:00 - 20:00 4.00 FISH P DECOMP P/U GS Spear and RIH to pull Diverter. 20:00 - 20:30 0.50 FISH P DECOMP Get parameters: P/U wt = 80K, SIO wt = 52K. Work Spear into Diverter, set down to 42K, P/U and see required overpull of 10K (-90K), and Diverter pulled free. 20:30 - 00:00 3.50 FISH P DECOMP TOOH, SIB DP in Derrick. Very little drag while TOOH. 12/22/2004 00:00 . 02:30 2.50 FISH P DECOMP SIB DCs, breakout and UD GS Spear and Diverter. Clear and Clean Drill Floor. M/U 4-1/32" Spear and Grapple. 02:30 - 04:30 2.00 FISH P DECOMP RIH BHA #10: 4-1/32" Spear and Grapple. 04:30 - 06:30 2.00 FISH P DECOMP Cut and Slip Drilling Line. Lube rig. 06:30 - 07:30 1.00 FISH P DECOMP Continue TIH from Derrick, 07:30 - 08:00 0,50 FISH P DECOMP Engage fish @ 10,091', P/U wt 80K, S/O wt 56K. Jar to 100K overpull; fish came free, P/U then set back down and tag 3' high. Joy! 08:00 - 11 :00 3.00 FISH P DECOMP Monitor hole, then TOH wI fish, SIB DP and DC's in Derrick. 11 :00 - 12:30 1,50 FISH P DECOMP Wash and release fish from spear and UD same. The cut appears to have been nearly 100% of the wall thickness. Recovered: Hook Hanger = 23.8'; 4-1/2", 12.6#, L-80 Pup Jt = 3.53'; 4-1/2", 12.6#, L-80 cut it::: 6.2'; total = -33.5'. 12:30 - 16:30 4.00 FISH P DECOMP M/U BHA #10: 4-15/16" Tieback Polish Mill, Liner top Dress-off Mill, Bumper Sub, Oil Jar, 9-DC's, 1 it 3-1/2" DP, and 7" Casing Scraper. TIH to cleanout to Bottom Lateral Liner top. Tag up @ 10,109'. 16:30 - 18:00 1.50 FISH P DECOMP P/U Kelly. P/U wt 82K, SIO wt 54K, Rot wt 65K, 5 BPM @ 1300 psi. Ream and wash to 10,117'. Circulate Bottoms Up. 18:00 - 19:30 1.50 FISH P DECOMP SIB Kelly, cont TIH for total 317 its 3-1/2" DP. M/U Kelly, P/U wt 90K, S/O wt 54K, Rot wt 69K. Wash into and polish Tieback Receptacle, 80-85 RPM, Torque 150 Amps, 4-5 BPM @ 900-1400 psi. Bottom out 22' in on Kelly. Swallowed 5' into Tieback. Tieback top @ 10,419'. 19:30 - 22:00 2.50 FISH P DECOMP Circulate 50 Bbls Hi-Vis Sweep 5 BPM @ 1400 psi to cleanout well. Recovered sand, drilling mud, and small amount of gelled EP Mud Lube. 22:00 - 00:00 2.00 FISH P DECOMP TOH, UD 8-jts 3-1/2" DP, SIB remainder in Derrick. 12/23/2004 00:00 - 02:00 2.00 FISH P DECOMP TOH and SIB 103-Stands 3-1/2" DP. 02:00 - 04:00 2.00 FISH P DECOMP Clean and UD 9-Drill Collars. Break-out and UD Jars, Bumper Sub, Liner-Top Dress-off Mill, Tieback Polish Mill. Inspection of Liner-Top mill showed uniformly good wear pattern. 04:00 - 06:00 2.00 FISH P DECOMP Clear and Clean Rig Floor. 06:00 - 06:30 0.50 RUNCOrvP RUNCMP Lube Rig. 06:30 - 07:00 0.50 RUNCOrvP RUNCMP Rig up to handle 4 12" Tubing. 07:00 - 08:30 1.50 RUNCOrvP RUNCMP Make-up Tie-Back Packer Assy as follows: Tie-Back Stem, Printed: 12/31/2004 9:22:10 AM . . ') ) BP EXPLORATION OperationsSummaryR~port Page 50f 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-41 MPC-41 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/15/2004 Rig Release: 12/27/2004 Rig Number: Spud Date: 5128/2001 End: Date From - To H 0 u rs Task Code NPT Phase Description of Operations 12/23/2004 07:00 - 08:30 1.50 RUNCOMP RUNCMP XN-Nipple w/XXN Plug installed, 41/2" XO Tubing Joint, 5 ea 41/2" Jts Tubing, 4 1/2" XO Tubing Joint, Sliding Sleeve in open position, 41/2" XO Tubing Jt, 7" x 5" Baker SL ZXP Liner I Top Packer. 08:30 - 09:00 0.50 RUNCOMP RUNCMP Rig up to handle 31/2" Drill Pipe. 09:00 - 13:30 4.50 RUNCOMP RUNCMP TLH with Tie-Back Straddle Assy and 7" Baker SLZXP Liner Top Packer on 314 Jts 3-1/2" DP. 13:30 - 15:30 2.00 RUNCOMP RUNCMP Work Tieback Seal Assy into position thru Tieback @ 10,419'. P/U wt 88K, S/O wt 40K. Set down, and P/U 1-2', drop packer setting ball, circulate on seat, pressure up to 4000 psi, bleed off to 1000 psi. PT annulus to 1000 psi, bleed off, rotate off packer. 15:30 - 16:00 0.50 RUNCOMP RUNCMP UD 6-jts 3-1/2" DP. M/U landing jt and tubing hanger, P/U wt 83K, land hanger, RILDS. 16:00 - 20:30 4.50 BOPSUF< P RUNCMP Install TWC. Perform weekly BOPE test per AOGCC/BP requirements. Jeff Jones, AOGCC, waived the right to witness BOPE test. Pressure test 250 psi low and 3500 psi high. 20:30 - 21 :00 0.50 BOPSUP P RUNCMP Rig up libricator, pull TWC, UD same. 21 :00 - 22:00 1,00 WHSUR P RUNCMP Close blind rams, NID Flow Nipple, N/U Shooting Head. 22:00 - 00:00 2.00 WHSUR I P RUNCMP RlU SWS W/l running equipment, BOPE stack, and Grease Injector. 12/24/2004 00:00 - 03:00 3.00 WHSUR P RUNCMP Continue to N/U SWS equipment. 03:00 - 06:00 3,00 RUNCOMP RUNCMP RIH wI SWS Pressure Recording Tool. Progress stopped @ I -4400'. RlU lines and pump 1-1/2 BPM to move tools downhole. Bolted flange on top of Hydrit leaking, Attempt to tighten. No-Joy. Start POOH with E-Line, 06:00 - 07:00 1.00 RUNCOMN RUNCMP Stop E-line Tool at -200'. Attempt to move E-Line. Unable to come up or go down. E-line seems to be stuck in Grease Head. Discuss possible causes. 07:00 - 13:30 6.50 RUNCOM\J RUNCMP PJSM. Monitor Well. Use Rig steam to warm-up Lubricator and Grease Injector Head. Attempt to move cable. No-Joy. PJSM. Well remains dead. Lift lubricator...verify tools not stuck down hole. Raise lubricator. Clamp off line. Strip lines and tools out of Well. Close Blind Rams. Lay down Tools and lubricator. Tear down and inspect Grease Tubes. E-Line had a slight "bird-cage". SWS...Change Grease Tubes, re-buitd Grease Head, cut and re-head Cable. Rig Crew replace Ring Gasket under bolted flange. 13:30 - 14:00 0.50 RUNCOM\J RUNCMP Pick-up lubricator and Tool String, Pressure test at 1,000 psi for 5 min. Good. 14:00 -16:30 2.50 RUNCOM\J RUNCMP RIH wI SWS PresfTemp Tool. Pump tool down from -4,000'. 16:30 - 17:30 1.00 RUNCOM\J RUNCMP Wait for tubing pressure to stabilize. 17:30 - 00:00 6.50 RUNCOM\J RUNCMP Call E-Pad operator to begin injection into MPE-13i, A and B zones @ 1000 BWPD each. E-Pad confirmed injection start-up @ 1730 hrs. 12/25/2004 00:00 - 13:30 13.50 RUNCOtvP RUNCMP Continue downhole pressure monitoring @ 9250'. 13:30 - 14:30 1.00 RUNCOtvP RUNCMP POH wI SWS E-line and Pressure Recording Tool. 14:30 - 16:00 1.50 RUNCOtvP RUNCMP RID SWS, clear Pipe Shed, NID Shooting Flange, N/U Flow Nipple. 16:00 - 16:30 0.50 RUNCOtvP RUNCMP M/U landing joint, BOLDS, pull and UD Hanger. 16:30 - 00:00 7.50 RUNCOtvP RUNCMP TOH and UD DP. Breakout and UD Liner Hanger Running Tool. 12/26/2004 00:00 - 02:00 2.00 RUNCOtvP RUNCMP Clear and clean Rig Floor. RlU 2-7/8" handling equipment and Printed: 12/31/2004 9:22:10 AM ) " -) ) BP EXPLORATION OperationsSummaryRepQ~~ ' Page 6 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-41 MPC-41 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/15/2004 Rig Release: 12/27/2004 Rig Number: Spud Date: 512812001 End: Date From - To Hours Task Code NPT Phase Description of Operations 12/26/2004 00:00 - 02:00 2.00 RUNCOMP RUNCMP Centrilift ESP equipment. Load ESP assembly in Pipe Shed. Check and tally same. 02:00 - 06:30 4.50 RUNCOMP RUNCMP P/U and service ESP Pump and Motor. 06:30 - 08:00 1.50 RUNCOMP RUNCMP Well started to flow - 1-Bb1/20 minutes. Called E-Pad Operator to SII injection. Monitor well. Fluid level began to drop. 08:00 - 09:00 1.00 RUNCOMP RUNCMP Make ESP cable connection to motor. Secure cable wI Motor Lead Flat Guards. Test Cable, okay. 09:00 - 11 :00 2.00 RUNCOMP RUNCMP TIH wI ESP, make 2900' and SID for Phase 3 weather. 11 :00 - 20:00 9.00 RUNCOrvN WAIT RUNCMP SID ESP RIH Operations for Phase 3 weather. 20:00 - 22:30 2.50 RUNCOMP RUNCMP Resume TIH wI new ESP. 22:30 - 00:00 1.50 RUNCOMP RUNCMP R/U for running Heat Trace Cable. Pull Heat Trace Cable over dual sheave in Derrick. Check Spooler operation and communications with Spooler Operator. Hold PJSM for installing Heat Trace Flat Guards while concurrently TI H wI ESP Cable on 2-7/8" tubing from Derrick. 12/27/2004 00:00 - 04:30 4.50 RUNCOMP RUNCMP RIH wI new ESP, installing Heat Trace Flat Guards wI 1"steel straps, and checking cable electrical integrity every 2000'. Averaging 4-stands per hour. 04:30 - 06:00 1.50 RUNCOMP RUNCMP Make Reel-to-Reel splice in ESP power Cable. 06:00 - 06:30 0.50 RUNCOMP RUNCMP Lub Rig. 06:30 - 14:30 8.00 RUNCOMP RUNCMP Continue TIH wI ESP to 9924'. 14:30 - 15:00 0.50 RUNCOMP RUNCMP M/U landing joint to tubing hanger. Install penetrators, 15:00 - 19:00 4.00 RUNCOMP RUNCMP Space out Heat Trace pig tail. Make Upper ESP Cable connector splice. Make Heat Trace connector splice, 19:00 - 19:30 0.50 RUNCOMP RUNCMP Land tubing hanger. P/U wt = 50K, SIO wt = 30K. RILDS, Set TWC. 19:30 - 21 :30 2.00 BOPSUP P RUNCMP N/D BOPE. 21 :30 - 23:30 2.00 WHSUR P RUNCMP N/U Tree and test tree and void to 5000 psi. Make final ESP Power and Heat Trace Cable tests, good. 23:30 - 00:00 0.50 WHSUR P I RUNCMP P/U Lubricator and pull TWC, install BPV. Secure Tree and Cellar. Release rig @ 0000 hours,12/27/2004. Printed: 12/31/2004 9:22:10 AM L STATE OF ALASKA '"[ ALASKA ,~. AND GAS CONSERVATION CO ,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: [] Abandon [] Suspend [] Operation Shutdown [] Pedorate [] Variance [] Othe, [] Alter Casing [] Repair Well [] Plug Perforations r"l Stimulate [] Time Extension Change Out ESP [] Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-Enter Suspended Well I'"1 Annular Disposal 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska)Inc. [] Development [] Exploratory 201-122 3. Address: [] Stratigraphic [] Service 6. APl Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23014-61-00 7. KB Elevation (ft): KBE = 45.17' 9. Well Name and Number: M PC-41 L2 8. Property Designation: 10. Field / Pool(s): ADL 047437 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 13850 feet true vertical 4367 feet Plugs (measured) N/A Effective depth: measured 13850 feet Junk (measured) N/A true vertical 4367 feet Casing Length Size M D TVD Burst Collapse Structural Conductor 110' 20" X 13-3/8" 110' 110' 1530 520 Surface Intermediate Production 10054' 7" 10091' 4220' 7240 5410 Liner 3583' 4-1/2" 10085'- 13668' 4218'- 4360' Perforation Depth MD (ft): 10696'- 13623' Slotted Liner Perforation Depth TVD (ft): 4330' - 4358' Slotted Liner Tubing Size (size, grade, and measured depth): 2-7/8", 6.5# L-80 9986' Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: , ,, 13. Representative Daily Avera~le Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: [] Copies of Logs and Surveys run [] Exploratory [] Development [] Service ,, ,,,,, ,, [] Daily Report of Well Operations 16. Well Status after proposed work: [] Oil [] Gas [] WAG [] GINJ [] WINJ [] WDSPL ii i 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Robert Odenthal, 564-4387I N/A Printed Name Sondra Stewman Title Technical Assistant ~ ~~ ,~~. * '* ¢'""~ t ~*.'~ .-¢'%*'-J' Prepared BY Namo/N urrlber: Phone ,56:~-,~7~01 · , Date f..~r~~~ ~.~Sondra Stewman, 564-.4750 Sign ,-,~ ...... _ ,,..,, ,..,,, ~'orm 10-40,4 :vised 2/2003 RBD $gFL AUG i 9 200 BP EXPLORATION Page 1 of 3 Operations Summary Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: WORKOVER Start: 8/2/2003 End: 8/6/2003 'Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8~6~2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 8~3~2003 08:00 - 09:00 1.00 MOB P PRE Held PJSM. Rigged Down. S¢oped Down and L / D Derrick. 09:00 - 10:00 1.00 MOB P PRE Broke Apart Rig Modules. Prepared to Move Rig. Held PJSM w/Truck Drivers and Drilling Crew. 10:00 - 11:30 1.50 MOB P PRE Moved Rig from MPL-13 to MPC-41. 11:30 - 12:00 0.50 MOB P PRE Moved and Spotted Sub Over MPC-41. 12:00 - 13:00 1.00 MOB P PRE Held PJSM. Raised and Scoped Derrick. R / U Derrick and Rig Floor. 13:00 - 14:00 1.00 MOB P PRE Spotted Pit Module, Pipe Shed and Camp. Bermed Rig. 14:00- 15:00 1.00 MOB P PRE R/U Lines to Tree and Wellhead. R/UTigerTankand Hardlines. 15:00 - 16:00 1.00 WHSUR P DECOMP Held PJSM. R / U DSM Lubricator, Pulled BPV, R / D DSM. iTubing Pressure 1,430 psi, Annulus Pressure 790 psi. Accepted Rig at 1500 hrs 8 / 3 / 2003. 16:00 - 16:30 0.50 WHSUR P DECOMP Held Pre Spud Meeting, Took on Seawater. Tested Hardlines to 3,000 psi. OK. 16:30 - 18:00 1.50 KILL P DECOMP Monitored Well, Tubing 1,400 psi, Annulus 800 psi. Bled Down Tubing and Annulus. 18:00 - 18:30 0.50 KILL P DECOMP Shut Well in and Monitored Pressure Build Up in 1/2 Hour. Tubing 400 psi, Annulus 200 psi. 18:30 - 19:00 0.50 KILL P DECOMP Bled Down Tubing and Annulus. 19:00- 19:30 0.50 KILL P DECOMP Shut Well in and Monitored Pressure Build Up in 1/2 Hour. Tubing 470 psi, Annulus 0 psi. 19:30 - 20:00 0.50 KILL P DECOMP Pumped Down Tubing to Displace Well to 8.6 ppg Seawater. Pump Rate 4 bpm, 1,050 psi. Pumped Tubing Volume, 57 bbls. Shut in Choke and Bullheaded 20 bbls. Volume from End of Tubing to The Top of the Bottom Lateral. 20:00 - 20:30 0.50 KILL P DECOMP Displaced Well to 8.6 ppg Seawater, Pump Rate 4 bpm, 800 psi. Total Volume Pumped, 100 bbls, Annulus Pressure Increased Rapidly from 0 psi to 750 psi w/Gas Bubble at Surface. Shut Down Pump and Shut In Well. Annulus Pressure Stabilized at 1,150 psi. 20:30 - 22:00 1.50 KILL P DECOMP Circulated Out Gas Bubble w/Choke Open 1/8th, Pump Rate 2 bpm, 100 psi. Annulus Pressure Decreased to 950 psi, Choke Open 1/4, Increased Pump Rate to 3 bpm, 370 psi. Annulus Pressure Decreased to 500 psi, Choke Open 1/2, Increased Pump Rate to 4 bpm, 1,000 psi. Annulus Pressure Decreased to 0 psi, Choke Open Full, Pump Rate to 4 bpm, 800 psi. Displaced Well to 8.6 ppg 140 deg Seawater. Total Volume Pumped 377 bbls. 22:00 - 23:30 1.50 KILL P DECOMP Continued to Circulate 8.6 ppg 140 deg Seawater. Lined Up and Took Returns to The Pits. Pump Rate 5 bpm, 1,600 psi. Circulated Well Until Returns Cleaned Up. Total Volume Pumped for Total Displacement 700 bbls. Lost 120 bbls During Displacement. 23:30 - 00:00 0.50 KILL P DECOMP Monitored Well w/Open Annulus and Tubing. No Flow. 8/4/2003 00:00 - 00:30 0.50 KILL P DECOMP Shut In Well. Monitored Well for Pressure Build Up in 1/2 Hour. Tu,bing 0 psi, Annulus 0 psi. 00:30 - 01:00 0.50 WHSUR P DECOMP Opened Well, No Flow. Set TWC and Tested to 1,000 psi from Above, OK. 01:00 - 03:00 2.00 WHSUR P DECOMP Held PJSM. N / D Production Tree. 03:00 - 04:30 1.50 BOPSUF P' DECOMP Held PJSM. N / U 13-5/8" x 5,000 psi BOP Stack. Hydril Annular Preventer, Blind Rams, Mud Cross, Lower Pipe Rams w/2-7/8" x 5" Variable Rams. Printed: 8/11/2003 10:54:59AM BP EXPLORATION Page 2 of 3 Operations Summary Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: WORKOVER Start: 8/2/2003 End: 8/6/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8/6/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 81412003 04:30 - 06:00 1.50 BOPSUF!P DECOMP Held PJSM. Function Tested Annular, Pipe Rams and Blind Rams. Body Tested BOP Stack and Choke Manifold to 2,500 psi High / 250 psi Low. All Tests Held f/5 Min. All Pressure Tests Held w/No Leaks or Pressure Loss. Witness of BOP Test Waived by AOGCC Rep Chuck Scheve. 06:00 - 06:30 0.50 WHSUR P DECOMP Held PJSM, R / U DSM Lubricator, Pulled TWC, R / D DSM. Annulus 0 psi, Tubing on Vacuum. 06:30 - 07:00 0.50 PULL P DECOMP Held PJSM. M / U Landing Joint and XO. M / U to Tubing Hanger and BOLDS. Unseated Tubing Hanger and Pulled Tubing Hanger to Rig Floor. String Weight Up 56,000~. 07:00 - 07:30 0.50 PULL P DECOMP Broke Out and L / D Landing Joint, XO and Tubing Hanger. Checked ESP Cable, OK. Filled Hole, Volume Pumped 41 bbls, Fluid Level was Down at 1,400'. 07:30 - 08:00 0.50 PULL 3 , DECOMP Pulled ESP Cable over Sheave and Connected to Spooling Unit Reel. 08:00 - 10:00 2.00 PULL ~ DECOMP POOH w/2-7~8" 8rd EUE Tubing to 6,400'. Racked Tubing in Derrick. Pumped 2 x Displacement. 10:00 - 10:30 0.50 PULL ~ DECOMP Repaired Elephant Trunk on Spooling Equipment. Shot Fluid Level - 2,500'. 10:30 - 12:30 2.00 PULL ~ DECOMP POOH w/2-7/8" 8rd EUE Tubing to 3,190'. Racked Tubing in Derrick. Pumped 2 x Displacement. 12:30 - 13:00 0.50 PULL 3 DECOMP Changed Out ESP Cable Spools in Spooling Unit. Filled Hole, Volume Pumped 40 bbls, Fluid Level was Down 1,350'. Prior to Filling Hole, Shot Fluid Level, Ecometer Indicated Level at 650', MisRun. 13:00 - 15:00 2.00 PULL P DECOMP POOH w/2-7~8" 8rd EUE Tubing. Racked Tubing in Derrick. Pumped 2 x Displacement. 15:00 - 17:00 2.00 PULL P DECOMP Broke Out and L / D ESP Pump Assembly. Closed Blind Rams and Shot Fluid Level. Ecometer Indicated Fluid Level at 650'. MisRun, Readings Unreliable. 190 bbls SW Pumped While POOH. 17:00 - 19:00 2.00 RUNCO~ COMP R / D Pulling Equipment and Single ESP Cable Sheave. Cleared Rig Floor. Hung Double Sheave. R / U Equipment to Run New ESP Assembly and 2-7~8" Tubing. ~ 19:00 - 22:30 3.50 RUNCO~ COMP M / U ESP Assembly. Connected MLE to ESP Pump and Secured. Tested Cable, Pump and Phoenix Multisensor, OK. 22:30 - 00:00 1.50 RUNCO~ COMP RIH w/ESP Pump and Cable on 2-7~8" 6.5~ 8rd Tubing. M / U Torque 2,350 ft / lbs. Installed ESP Cable Clamp Every Joint. 8~5~2003 00:00 - 02:30 2.50 RUNCO~ COMP RIH w/ESP Pump and Cable on 2-7~8" 6.5~ 8rd Tubing to 4,400'. M / U Torque 2,350 ft / lbs. Tested Cable and Pumped 10 bbls SW Down Tubing to Ensure Tubing was Clear of Debris Every 2,000'. / 02:30 - 06:00 3.50 RUNCO~ COMP Cut ESP Cable and Changed Out Cable Spools in Spooling Unit. Spliced and Tested Cable. OK. Pumped 10 bbls SW Down Tubing to Ensure Tubing was Clear of Debris. 06:00 - 07:00 1.00 RUNCO~ P COMP RIH w/ESP Pump and Cable on 2-7~8" 6.5~ 8rd Tubing to 6,475'. M / U Torque 2,350 ft / lbs. Tested Cable and Pumped 10 bbls SW Down Tubing to Ensure Tubing was Clear of Debris Every 2,000'. 07:00 - 08:30 1.50 RUNCO~ P COMP R / U to Run Heat Trace. M / U Flat Guards w/Bands. 08:30 - 17:30 9.00 RUNCO~ P COMP RIH w/ESP Pump, ESP Cable and Heat Trace on 2-7/8" 6.5~ 8rd Tubing. M / U Torque 2,350 ft I lbs. Tested Cable and Printed: 8/11/2003 10:54:59 AM BP EXPLORATION Page 3 of 3 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-.41 Spud Date: 5/28/2001 Event Name: WORKOVER Start: 8/2/2003 End: 8/6/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 8~6~2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 8~5~2003 08:30 - 17:30 9.00 RUNCOI~ COMP Pumped 10 bbls SW Down Tubing to Ensure Tubing was Clear of Debris Every 2,000'. 17:30 - 18:00 0.50 RUNCOI~ COMP M / U Tubing Hanger, Landing Joint and XO. Installed Penetrators in Hanger. String Weight Up 59,000#, String Weight Down 34,000#. 18:00 - 00:00 6.00 RUNCOI~ COMP Spaced Out Heat Trace. M / U EFT Connectors to Splice on Heat Trace and ESP Cable. 8~6~2003 00:00 - 01:30 1.50 RUNCOI~ COMP M / U EFT Connectors to Splice on Heat Trace and ESP Cable. Switched Out 8.08' Pup Jt for 1 - 6.17' and 1 - 1.44' Pup Jts. Attached Cables and Tested, OK. 01:30 ~ 02:00 0.50 RUNCOI~ COMP Landed Tubing Hanger and RILDS. Completion Equipment Set At The Following Depths: Item Length Depth ESP Pump Assembly 64.69' 9,989.30' 2-7~8" 6.5# 8rd Pup Jt 10.82' 9,913.79' 246 Jts 2-7/8" 6.5~ 8rd EUE Tbg 7,725.43' 2,188.36' #1 GLM Assembly 26.50' 2,161.86' 64 Jts 2-7/8" 6.5# 8rd EUE Tbg 2,008.50' 153.36' #2 GLM Assembly 26.30' 127.06' 3 Jts 2-7/8" 6.5# 8rd Tbg 94.45' 32.61' 2-7/8" 6.5# 8rd Pup Jt 6.17' 26.44' 2-7/8" 6.5# 8rd Pup Jt 1.44' 25.00' Tubing Hanger 4.39' 20.61' 02:00 - 02:30 0.50 RUNCO~ COMP Broke Out and L / D Landing Joint. Set TWC and Tested. Drained BOP Stack and Blew Down Lines. 02:30 - 03:30 1.00 BOPSUF:P COMP Held PJSM. N / D BOPE. 03:30 - 04:30 1.00 WHSUR P COMP Held PJSM N / U Tree. 04:30 - 05:00 0.50 WHSUR P COMP Held PJSM. R / U to Tree. Pressure Tested Tree to 5,000 psi, OK. R / D Lines From Tree. 05:00 ~ 05:30 0.50' VVHSUR !P COMP Held PJSM. R / U DSM Lubricator, Pulled TVVC, Set BPV, R / D DSM. 05:30 - 06:00 0.50 WHSUR ;P COMP Secured Well. Released Rig at 0600 hrs 8 / 6 / 2003. Printed: 8/1112003 10:54:59 AM Permitto Drill 2011220 DATA SUBMITTAL COMPLIANCE REPORT 713012003 Well Name/No. MILNE PT UNIT SB C-41L2 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23014-61-00 MD 13850 'I-VD 4367 Completion Dat 7/17/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N_.9o Sample N_go Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type ~..Media Fret Name Log Log Scale Media Run No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments ED~ D Ver LIS Verification R Cn ~,See Notes Directional Data ,.Di1~ion al Data Directional Data DjmCt~nal Data 1 FINAL FINAL FINAL FINAL 1 75 75 13795 13850 Open 12/28/2001 ~'0~06 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 oh 8/20/2001 Open 1/17/2002 ~---41~0 Directional Data MWD Directional Data MWD digital data Directional Data Directional Data digital data Digital Well Log Data NOTE: No paper copies of logs were received. MD ^N TV Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y ,.~ Chips Received? ~ Analysis Y / N R ~.r~iv~.d ? Daily History Received? ~' / N Formation Tops (~ / N Comments: Permit to Drill 2011220 MD 1385O TVD Compliance Reviewed By: 'DATA SUBMITTAL COMPLIANCE REPORT 7/3012003 Well Name/No. MILNE PT UNIT SB C-41L2 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-230'14-61-00 4367 Cl~ion Dat 7/17/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N Date: To: WELL LOG TRANSMITY~ State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7a' Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPC-41 L2, AK-MM-10166 December 15, 2001 MPC-41 L2: Digital Log Images: 50-029-23014-61 1 CD Rom PLEAsE ACKNOWI,EDGE .RECEIPT BY- SIGNING AND RE~G THE ATTACHEi~ COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Cemer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED JAN I 7 2002 gJmkaOil & Oas Cons. Commlmior, To-' WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 December 21,2001 RE: MWD Formation Evaluation Logs MPC-41L2, AK-MM- 10166 1 LIS formatted Disc with verification listing. API#: 50-029-23014-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 9951. 8 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: RECEIVED F"' LO D.,",,.., 2 8" 01 ,~b.a ('~t & Gas ~r~.~, ('" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service r"l TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-122 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23014-61 4. Location of well at surface '., .;:,,,' ~-~::, ,~.,, ! . . , 9. Unit or Lease Name 694'At topNSL'of productive2298' WEk,intervaiSEC. 10, I13N, R10E, UMii . , ~,=,,~.-,.,~ Milne Point Unit 2344' SNL, 157' EWL, SEC. 23, T13N, R10E, UM ~ ',.,~EL~ i: [ SuTf'~~ I. 10. Well Number At total depth __.~,~.~.. .... . t I !:~.~ ~ MPC-41 L2 1700' SNL, 3148' EWL, SEC. 23, T13N, R10E, UM ......... ..... " 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE = 45.17' ADL 047437 12. Date Spudded 6/28/2001D teT'D' R °hed I'4' D"te c°mp'' su'p'' °r Ab""d'z/,/2001 7/17/2001 115' water depth' if °ffsh°re N/A MSL J 16. ,o. o, ComP,etions One 17. Total Depth (MD+TVD) J 18. Plug Back Depth (MD+TVD) J19.' Directional Survey J 20. Depth where SSSV setJ 21. Thickness of Permafrost 1385o 4367 FTJ 1385O 4367 . FTJ [] Yes [] No.J N/A MDJ 1800'... (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD, ABI , 23. CASING, LINER AND CEMENTING RECORD , ,, , CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED , , , ,,, , 20,,x ~a.a/8,, 94# / 54.5# H-40 / J-55 Surface 110' 30,, 260 sx Arctic Set (Approx.) .... 7" 26# L-80 37' 1'0091" 9-7/8" 1456 sx Arctic Set III, 792 sx Class 'G' , 4-1/2" 12.6# L-80 10085' 18668' 6-1/8" Uncemented Slotted Liner , , ~ i 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 2-7/8", 6.5#, L-80 10001' N/A MD TVD MD TVD 10696' - 13623' 4330' - 4858' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect Tubing with 15 Bbls Diesel Freeze Protect IA with 65 Bbls Dead Crude , , 27. ' ....... P~ODUOT,'0N TES~ ............................. Date First Production Method of operation (Flowing, 'gas lift, etc.) ........................................ July 24, 2001 Electric Submersible Pump Date of Test Hour's Tested PRoDuoT~O'N FOR OIL-BB'L' GAS-M'OF ..... WATER-BBL CHOKE SIZE J GAs-OIL RATIO ' ' 8/21/2001 6 TEST PER~OD 1635 437 266J 267 FI0w Tubing 3asing Pressure CALCULATED "' 01L-BB~ .... GAS-MC:;F ...... WATER'BBL .... O~L ISFIAVlTY-AF;I (CC)FIFO ...................... Press. 24-Hour RATE , , ,,,, ,,, ,,, ,,, , ,, , ,,, , ,,,,, , ,, , , ,,,,,,, ,, , , , , ~ , , , ,,,,,,,, ,,,, , ,, ,,, , , , , , ,, , ,,, , , ,, ,, ,,,,, 28. CORE DATA .~ ~ ~;'~ //~"' r"~ ........ Brief description Of lithology, porosity, fractures, apparent di'ps and presence of oil, gas or water. AU(; ~ 8 7_001 Alaska 0il & Gas Cons. Commissior~ Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Top Schrader OA 10680' 4327' Base OA / TSBC 12120' 4363' Base OA / TSBC 12180' 4363' Base OA / TSBC 13610' 4358' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,~~,~, ~ Title Technical Assistant Date MPC-41 L2 201-122 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 · .: ~ : : :~ BP ~EXPLoRATioN Page 1 of 1 Legal Name: MPC-41 Common Name: MPC-41 Test. Date : Test Type i ~ : :::::TestDePth (~O) : ~ AMw SurfaCe pressure Leak Off Pressure (BHP) EMW 6/12/2001 FIT 11,240.0 (ft) 4,400.0 (ft) 9.00 (ppg) 450 (psi) 2,507 (psi) 10.97 (ppg) Printed: 8/24/2001 10:23:31 AM ' 'BP ~PEO"RATION ",' '~ .'. Page 1 of 19 . Operati°ns'.su'mmarY RePort"- ,'," '- , . Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: N^BORS 22E Rig Number: 22E ,.Date ' From-To HOURS: Activity code NP:T Phase '. ' DeScripti°n of oPerations '.: 5/26/2001 12:00 - 00:00 12.00 MOB ~ PRE Blow Down And Disconnect Steam, Water, And Mud Lines Then Disconnect Air Lines - Pick Up 21 1/4" Annular With Bridge Crane System - Disconnect And Pull Back Electrical Cables - Pick Up All Steps And Landings - Move And Load Pipe Shed Tioga Heater- Install Towing Tongue On Pipe Shed And Move To End Of "E" Pad - Jack Up And Move Motor Shed To Enterance Of E Pad - Remove Rock Washer From Pit Complex And Load - Install Towing Tongue On Second Pipe Shed And Back To End Of "E" Pad - Move Pit & Pump Complex To The Enterance Of "E" Pad - Pull Sub Base Off Of Hole And Position On "E" Pad For Removal Of Cattle Shoot. 5/27/2001 00:00 - 00:30 0.50 MOB = PRE Hold Pre-Job Safety Meeting With All Nabors Personal And Peak Equipment Operators 00:30 - 01:00 0.50 MOB 3 PRE Move Sub Base Off Of Well Slot No. E-29i & Position On Pad 01:00 - 03:00 2.00 MOB ~ PRE Move Motor Complex And Pit/Pump Room Complex From "E" Pad To "C" Pad And Stage - Remove Cattle Shoot From Sub Base And Load Out On Trailer - Move Both Sets Of Wheel Bolsters To The Inside Position For Traveling Down The Road. 03:00 - 04:00 1.00 MOB P PRE Hook Onto Pipe Sheds With Bed Trucks - Secure For Hauling To C-Pad 04:00 - 05:30 1.50 MOB P PRE Road Two Pipe Sheds And Sub Base From "E" Pad To "C" Pad 05:30 - 08:00 2.50 MOB P PRE Close Sub Base Doors - Move Both Sets Of Wheel Bolsters To The Outside Position For Getting Over Well Slot No. C-41 - Install & Pin Cattle Shoot On Sub Base - Set Sub Base Matting Boards And Lay Herculite 08:00 - 12:00 4.00 MOB P PRE Set Sub Base Over Well Slot No. C-41 - Set Mud Pit & Pump Complex 12:00 - 13:30 1.50 MOB P PRE Lay Matting Boards And Herculite For Rock Washer 13:30 - 14:30 1,00 MOB P PRE Move And Stage Matting Boards For Pipe Shed - Move Motor Complex Around 14:30 - 15:30 1,00 MOB P PRE Lay Matting Boards For 1st Pipe Shed And Set Unit - Remove Towing Gooseneck 15:30 - 16:30 1.00 MOB :P PRE Lay Matting Boards For Motor Complex And Set Unit - Hook Up Service Lines 16:30 - 17:00 0,50 MOB !P PRE Lay Matting Boards For 2nd Pipe Shed And Set Unit - Remove Towing Gooseneck 17:00 - 18:00 1.00 MOB I P PRE Set Fuel Transfer Building & Spot Main Fuel Storage Tank - Spot Holding Tank For Cement Water 18:00 - 21:00 3.00 RIGU P PRE Nipple Up Diverter Spool With 16" Outlet & Knife Valve Reduced To 10 3/4" Diverter Line. *Note* The Diveter Line Is Run Between The Electrical Cable Tray's And Above The Production Flow Lines (Some Have 3500 Psi.) Then To The Open Pit Where A Targeted Tee Is Installed Heading Parallel With Production Flowlines To The Open End of The Pits. 21:00-21:30 0.50 RIGU P PRE Set21 1/4" Annular On Diverter Spool - Install Bolts 21:30 - 00:00 2.50 RIGU P PRE Install Western Gear Pipe Master Lay Down Machine Track To Rig Floor- Continue To Nipple Up 21 1/4" Diverter System- Install Turnbuckles - Pick Up Tools And Cellar - Berm Around Rig - Continue To Dress Mud Pumps - Work On Drag Link For Cuttings Trough 5/28/2001 00:00 - 03:00 3.00 RIGU P PRE Hook Up Flow Line To Bell Nipple - Load Pipe Shed With 5" Drill Pipe Mix Spud Mud - Set Cuttings Tank - Work On Berm Printed: 7/23/2001 11:49:12 AM Bp EXPLoRATiON Page'2 of 19 Operations sUmmary RepOrt i· Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: N^BORS 22E Rig Number: 22E From,To H°~ ActivityCode NPT: ::Phase:~ ' ' DescriPti0n of OperatiOns , ..... :, 5/28/2001 00:00 - 03:00 3.00 RIGU P PRE Around Rig - Spot Spare Parts Building - String Out Geronimo Line. 03:00 - 05:00 2.00 RIGU P PRE Torque Up Bolts On 21 1/4" Annular To 16" Diverter Spool - Function Test Diverter And Preform Accumulator Test - Witness Of Test Was Waived By AOGCC Representive's John Spaulding And Jeff Jones 05:00 - 11:30 6.50 DRILL P SURF Pick Up And Stand Back 5" Drill Pipe 11:30 - 12:30 1.00] DRILL P SURF Hold Pre-Spud Meeting With Drilling Crews And Support Personal 12:30 - 13:00 0.50 DRILL P SURF Continue To Pick Up 5" Drill Pipe And Stand Back In Mast 13:00 - 15:30 2.50 DRILL P SURF Pick Up 5" HWDP And Stand Back In Mast - Teflon Drift Tight Change Out Rabbit For Metal Drift - Remove Spacer Plate On Varco Top Drive Lift Cylinder 15:30 - 18:00 2.50 DRILL ~ SURF Pick Up New Drilling Assembly - Pick Up Sperry Sun Steerable Directional BHA Tools - Mud Motor, MWD Tool, Filter Sub, String Stab Change AKO Setting On Motor - Make Up Bit - Pick Up Hang Off Sub And Install MWD Sensor Tools - Make Up HOC And Talk To Tool - Rig Up Slick Line Sheave For Single Shot Survey's 18:00 - 21:00 3.00 DRILL N RREP SURF Work On Varco Top Drive - Trouble Shoot Electrical Problems With DC Power 21:00 - 21:30 0.50 DRILL ~ SURF Make Up UBHO Sub & Stand Back In Derrick 21:30 - 22:00 0.50 DRILL 3 SURF Pick Up 5" Drill Pipe From Pipe Shed And Stand Back In Mast 22:00 - 23:00 1.00 DRILL 3 SURF Electrical Problem Sorted Out (Plug In Hall Way) Make Up BHA From Derrick & Initialize MWD Tool 23:00 - 00:00 1.00 DRILL 3 SURF Spud Well At 23:05 Hours - Drill Ahead From 110' To 181' - Weight On Bit 5K To 15K - Pump Pressure @ 91 Strokes Or 381 GPM (Off Bottom 450 Psi. & On Bottom 550 Psi.) - Torque @ 80 RPM (Off Bottom 2K & On Bottom 3K) - String Rotating Weight @ 90K - With Pump On Drag Up @ 95K Drag Down @ 85K 5/29/2001 ; 00:00 - 13:30 13.50 DRILL P SURF Drill 181-1808'. WOB 15-30k; 2500 ft lbs torque; 60rpms; 1050/1300psi- off bottom and on bottom 13:30 - 15:30 2.00 DRILL P SURF Wiper trip to the collars. Pumped out 11 stands drill pipe and pulled 7 stands hwdp-no problems, no swabbing. 15:30 - 16:30 1.00 DRILL P SURF Trip in hole. No problems. 16:30 - 23:00 6.50 DRILL P SURF Drill 1808'-3029'. WOB 10-20k; 3000-4000 ft-lbs torque off-on btm.; 70 rpm; 1300/15000 psi off/on btm. 23:00 - 00:00 1.00 DRILL P SURF Pump 30 bbl viscous sweep & start short trip (planned to 1600'). 5/30/2001 00:00 - 01:30 1.50 DRILL P SURF Finish wiper trip 2500-1559'. 01:30 - 02:30 1.00 DRILL P SURF TIH 1559'-3029'. Ream last 60' to btm. 02:30 - 17:00 14.50 DRILL P SURF Drill 3029'- 4655' & hold angle at 76.5 degrees inclination, 161 degree azimuth. 15- 20k WOB, 140000 PUW, 125000 SOW, 130000 ROTW. 4500 ft-lbftorque on btm, 3000 ft-lbftorque off btm, 70 rpm top drive. 1650 psi on btm, 1400 psi off btm, at 530 gpm. 17:00 - 21:00 4.00 DRILL I P SURF Circulate btms up & start wiper trip to 1775'. Pulled total 32 stands. Pumped out at 400 gpm w/the 1st 18 stands and pulled 14 add. stands to 1580'. 21:00 - 22:30 1.50 DRILL P SURF Trip back to bottom at 4655. Hole tight going back in at 2989-3079 ft. 22:30 - 00:00 1.50 DRILL P SURF Drill 4655-4843'. 530 gpm, 1650/1400 psi on/off btm, Printed: 7/23/2001 11:49:12 AM EXPLORA~TION Page 3 of 19 BP OperatiOnS. Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From ~To HOurs Activity COde NPT ':'Phase' , DesCription of Operations. 5/30/2001 22:30 - 00:00 1.50 ;)RILL 3 SURF 4500~3000 ft-lbf on/off btm, 140k PUW, 125k SOW, 130k ROTW. 5/31/2001 00:00 - 08:00 8.00 DRILL 3 SURF Drill 4843'-6047'. Total drilling hrs (26.25); 19.75 Rot hrs; 6.5 sliding hrs; 550 gpm, 1900/1750 psi on/off btm, 8-10k/7 ft-lbf on/off btm, 170k PUW, 115k SOW, 135k Ro'rw. 08:00 - 09:00 1.00 DRILL P SURF Pump sweep and circulate hole clean 09:00 - 13:00 4.00 DRILL P SURF Pump out 15 stands at 400 gpm with 1000 psi. Pull 5 stands-no swabbing. Pump dry job and pooh to bha. No problems 13:00 - 15:00 2.00 DRILL ~P SURF L/d hang off sub and Iwd and bit. Clear rig floor. 15:00 - 16:00 1.00 DRILL ;P SURF MU 9 7~8" Smith FGS+CT bit & BHA No.2. 16:00 - 17:00 1.00 DRILL P SURF Load MWD. RIH w/HWDP & 5 in DP. Pulse test MWD. 17:00 - 23:00 6.00 DRILL P SURF TIH w/5" DP picking up singles from pipe shed. Pipe stacking out at 2400' -2800'(through the build section). Worked through section without pumps. Fill DP w/mud. TIH w/total 162 singles to 5876'. Wash down to 6047' no fill. 23:00-00:00 1.00 DRILL P SURF Dri116047-6065'. PUW 175K. SOW l00k. ROTVV 135K. PSI on/off btm 1800/1600 at 525 GPM. SFC RPM 80. BTM RPM 249. Torque 10K/8K on bottom/off bottom. 6/1/2001 00:00-13:00 13.00 DRILL P SURF Dri116065'-7722'. PUW 175K. SOW 100k. ROTW 135K. PSI on/off btm 1800/1600 at 525 GPM. SFC RPM 80. BTM RPM 249. Torque 10K/8K on bottom/off bottom. 13:00 - 14:00 1.00 DRILL P SURF Pump sweep and circulate hole clean. 14:00 - 16:30 2.50 DRILL P SURF Wiper trip to 5900'. Pulled 8 stds without problems. Hole started swabbing on stand #9. Pumped out stands 9-18 with 400 gpm with 1200 psi. Pulled stands 19 and 20 without 3umps, no problems-no swabbing, 16:30 - 18:00 1.50 DRILL P SURF TIH. Hole taking weight. Had to work through tight spots from 7002-7342. Pumped from 7342-7437. Ran the last 3 stands in. Wash and ream last stand down. 18:00 - 18:30 0.50 DRILL P SURF Wash down 7340-7471'. TIH to 7722'. 18:30 - 00:00 5.50 DRILL P SURF Drill 7722-8314'. PUW 195k, SOW 105k, ROTVV 142k, Torque on/off btm 14,000/10,000 ft-lbf. Pump on/off btm 2350~2050 psi. 10-30k WeB. 90 rpm surface. 270 rpm btm hole. (.33 rpm/gpm). 6/2/2001 00:00 - 07:00 7.00 DRILL P SURF :Drill 8314'-8766. PUW 195k, SOW 105k, ROTW 142k, 'Torque on/off btm 14,000/10,000 ft-lbf. 550gpm,Pump on/off btm 2350~2050 psi. 10-30k WeB. 90 rpm surface. 270 rpm btm hole. We made a connection at 8689'. Several sections drilled from 20-50 fph. At 8766' the bit stopped drilling there was a pressure spike from 2400-2700 psi. Then there was a 200-300 pressure drop. We tried all options but none worked. The psi would drop off immediately when you picked up. 07:00 - 15:00 8.00 DRILL N DFAL SURF Pumped out 16 stands from 8766'-7266'. Pulled 5 stands and pumped the dry job. Stood the bha back in derrick. The bit, bit sub. and 7-1/2 inches of the 4" drive shaft were left in the hole. Total length of fish left in hole was 2-1/2 feet. Decision was made to do an open hole sidetrack. 15:00 - 16:00 1.00 DRILL N DFAL SURF Servicetop drive. 16:00 - 18:00 2.00 DRILL N DFAL SURF Cut & slip 106' of drilling line. 18:00 - 20:00 2.00 DRILL N DFAL SURF MU 36 jts 3 1/2" 15.5~ DP. 20:00 - 21:00 1.00 DRILL N DFAL SURF MU 9 7/8" MXC1 bit, 1.5 deg bend motor 8", MWD, DC's, jars, 2O jts HWDP. Printed: 7123/2001 11:49:12 AM ' BP ExpLORATION ' Page 4 of 19 · ' OPeratiOns Summary RePOrt Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: N^BORS 22E Rig Number: 22E Date ; FrOm,'To Hours ActivityCode ilNPT Phase' , DesCriPtion of Operations '6/2/2001 21:00 - 21:300.50 DRILL N DFAL SURF Align MWD. 21:30 - 00:00 2.50 DRILL N DFAL SURF TIH w/5" DP to 4660'. 6/3/2001 00:00 - 06:00 6.00 DRILL N DFAL SURF Continue tripping in hole to 5600'. Stacking out weight and could not get down. Wash and ream from 5600'-8600'. 06:00 - 12:00 6.00 STKOH N DFAL SURF Start sidetracking and cutting a trough. Tagged old fish at 8625'. Pooh one stand to 8506'. Start sidetraking again. Well was sidetracked at 8550'. Continue drilling to 8766'. 12:00 - 22:30 10.50 STKOH P SURF Drill 8766'-9915. Wob 20-25K; 550 gpm; 2000 psi; Torque-15K/13k-on/off bottom. 22:30 - 00:00 1.50 STKOH P SURF Circulate sweep bottoms up. Pump out of hole 9915-9540. 6/4/2001 00:00 - 01:30 1.50 STKOH P SURF Continue pumping out of hole 9540-8506. 01:30 - 02:00 0.50 STKOH P SURF POOH 8506-8038' with no hole problems. 02:00 - 03:00 1.00 STKOH P SURF TIH 8038-9915 no fill. Took 20k down weight. Wash & ream last stand to btm. 03:00- 20:00 17.00 STKOH P SURF Drill 9915-10493'. Control drill 100 fph 10943-10572'. Top of OA sand drilled at 10215'. Drill 10572-11210 section TD. PUW235K, SOW 105K, ROTW 105K. 20-40KWOB. Torque on/off btm 17000/15000. SPP on/off btm 2150/1950 at 550 GPM. ECD from PWD tool measuring 10.4 ppg. Acoustic caliper shows the average hole diameter at 10.24" for an overall 4% increase over gauge hole. 20:00- 00:00 4.00 STKOH P SURF Circulate bottoms up. Pump high viscosity sweep. Pump & back ream out of hole to 9071. Continue TOOH to 8883' with no hole problems. 6/5/2001 00:00 - 05:00 5.00 STKOH P SURF POOH to HWDP wiper trip/f/8883-810'. Clear rig floor. 05:00-11:00 6.00 STKOH P SURF RIH 810'-11210' Fill pipe every11 stands. Hit ledge at 7130'. 11:00 - 18:00 7.00 STKOH P SURF Circulate & condition mud to 18 Ib/100ft^2 yield point, 4 mi water loss(APl-30). Lubricant concentration raised to 5.5% (Lube-tex & Drill'nSlide). 18:00 - 00:00 6.00 STKOH P SURF POOH, Steel Line Measure (SLM). Record PUW, SOW, ROTW, ROT Torque(50 rpm) every 5 stands. Hole in excellent condition & pump-out was not required. 6/6/2001 00:00 - 01:30 1.50 CASE P SURF Continue POOH from 2592'. SLM DP measurement. Record PUW, SOW, ROTW, TQ, every 5 stands. 01:30 - 06:00 4.50 CASE P SURF Lay down HWDP 20 jts. LD BHA 3 flex DC's. Drain mud motor, break out drill bit. Download MWD. Laydown XO, stabilizer, float sub, motor,& MWD. Clear floor. 06:00 - 07:00 1.00 CASE P SURF Sen/ice top drive. 07:00 - 08:30 1.50 CASE P SURF RU casing running tools, change out elevator bails. RU fill-up line. 08:30 - 09:00 0.50 CASE P SURF Safety & planning meeting held on running and rotating 7" casing. 09:00 - 18:30 9.50 CASE P SURF RIH w/7", 26#, Hydril 521, IJ casing 140 jts 5880 ft. approx. Check floats, install straight blade centralizers on first 40 joints. 18:30 - 19:00 0.50 CASE P SURF Safety & planning meeting held on rig floor activities, organization, personnel positioning, drive sub handling, skate operations. Prepare crew for casing rotation/circulation w/ top drive operations. Kept pipe moving during safety meeting. 19:00 - 00:00 5.00 CASE P SURF RIH w/7" casing. Circulate 5 bpm, 150 psi, & rotate 1st ten jts then every 10th joint down starting atjt 140. Relief crew came Printed: 7123/2001 11:49:12 AM BP EXPLORATION Page 5 of 1.9 Operations ,Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From - To Hours Activity Code NPT Phase Description of Operations 6/6/2001 19:00 - 00:00 5.00 CASE P SURF on tour at 11 pm and held tech limits meeting "Observing Ongoing Casing Running/Rotating Operations" of crew on tour. 6/7/2001 00:00 - 06:30 6.50 CASE P SURF Continue running in hole w/7" 26#, L80, 521 IJ casing. Casing started to "stack-out" at joint 205 approximately 8800 ft. MU drive sub and screwed in w/top drive. Establish circulation at 75 spm, 7.5 bpm, 300 psi. Keeping pipe moving. Circulate bottoms up in 67 minutes. Continue TIH breaking circulation and rotating down every 10th joint and as necessary. 06:30 - 10:00 3.50 CASE P SURF Install 7" TAM port collar between joints 258 & 259. Layed out and replaced 1 damaged jt (270) of casing. Casing would not go without rotating and circulating final 21 joints to bottom. Unable to reach TD on last joint using landing joint and mandrel hanger. Pick up one additional joint. Circulate and rotate final joint of casing into hole. Recorded PUW, ROTW, SOW, & Torque values every 10 jts to TD for drag plot modeling. 10:00 - 20:00 10.00 CASE P SURF Circulate & condition mud lowering rheology to less than 10 YP, adding water and thinner as necessary. Continue rotating pipe down while reciprocating approximately 15' strokes. Pump 80 bbl bicarbonate treated mud ahead of cement job.(prevent flowline plugging). 20:00 - 20:30 0.50 CASE P SURF PJSM- Upcoming cementing operations and safety review with all personnel on rig. Written cementing & contingency plans forward prepared and reviewed. 20:30 - 23:30 3.00 CASE P SURF Start pumping cement job: Schlumberger pumped 5 bbls CW100, Pressure test lines to 4500 psi. Pump 45 bbls CW100 at 5 bpm. Pump 75 bbls mud push(w/red dye) spacer at 5 bpm. SD & drop btm wiper plug. Pump lead cement 1092 bbl ASIII cement mixed at 10.7 ppg, 4.44 cf/sk at 6.8 bpm. Pump tail cement 158 bbls CIG 15.8 ppg, 1.17 cf/sk at 5.8 bprn. SD & drop top wiper plug. Pump 10 bbls water spacer. SD & flush cmt lines. 23:30 - 00:00 0.50 CASE P SURF Switch to rig pumps & begin pumping displacement w/9.3 ppg mud at 8 bpm. Good mud returns. Cement to surface estimated at 500 bbls. Supersuckers & vac trucks loading out mud & cement returns to disposal site. 6/8/2001 00:00 - 02:00 2.00 CASE P SURF Continue displacing cement with rig pumps. Bump plug at 0100 hrs, 4175 strokes, 2500 psi. Release pressure, check floats, and holding ok. Final circulating pressure at 5 bpm 1300 psi. Recovered approximately 500 bbls cement to surface. LD cmt head. 02:00 - 03:00 1.00 BOPSUF P SURF ND diverter stack & flowline. Disconnect lines from 20" riser. Drain stack of cement debris. Clean cellar w/supersucker. 03:00 - 05:00 2.00 BOPSUF P SURF PU on 20" Hydril diverter & set emergency slips. Cut & drain 7" casing joint & LD same. Pulled 50,000 Ibf tension & set slips. 05:00 - 08:00 3.00 BOPSUF P SURF ND 20" riser. Finish cut on 7" csg. ND knife valve to flow-line & mud cross. 08:00 - 15:30 7.50 BOPSUF P SURF Weld on casing head adaptor & allow to cool. Small leak in weld. Repair weld. Test w/N2 to 1000 psi for 10 mins 15:30 - 21:30 6.00 BOPSUF P SURF NU csg head, DSA, & BOP stack. Tighten locking ring to FMC head. Test to 1250 psi f/10 mins. Contact AOGCC w! 3 hrs Printed: 7/23/2001 11:49:12 AM ~ BP'EXPLORATION ~, Page 6of 19 · .. , OperationS Summary Report. .... · · . Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End' 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E ~" Date::i:i~ From:~r:!Hours ACtivitycode., NpT phaSe 6/8/2001 15:30 - 21:30 6.00 BOPSUF.P SURF notice of pending BOP test. Torque up BOP stack bolts. RU choke & kill lines. RU turnbuckles & align stack. RU flow nipple, flowline, hole fill & bleeder lines. 21:30 - 00:00 2.50 BOPSUF,P SURF Change out saver sub on top drive. 6/9/2001 00:00 - 02:30 2.50 BOPSUF,P SURF Change-out top drive gripper dies & pipe guide for 3 1/2" DP. RU test equipment & install 2nd annulus valve. 02:30 - 03:30 1.00 BOPSUF:N RREP SURF Fill stack & choke manifold w/water. Notice leak in flow-line below btm rams. Re-torque bolts on drilling spool-still leaking. 03:30- 06:30 3.00 BOPSUF:N RREP SURF ND BOP & replace ring gasket. NU BOP. 06:30 - 12:00 5.50 BOPSUF:N RREP SURF Install test joint & plug. Fill stack & test BOPE to 250 psi Iow and 2500 psi high f/10 mins. Valve 15 on the choke manifold did not test. Test plug leaked during Annular test. Pull test plug, replace seal. Re-install test plug & continue testing. 12:00 - 18:00 6.00 BOPSUF:P SURF Fill stack with water. Test Hydril bag, accumulator, blind rams, lower IBOP, Lower pipe rams, manifold valve to choke, HCR on choke, dart valve. NOTE: John Crisp of AOGCC witnessed BOP test. 18:00 - 00:00 6.00 BOPSUF:N RREP SURF Inside BOP on Top Drive leaking. Remove pipe handler on top 6/1 drive. Replace IBOP. Re-install pipe handler. 0/2001 00:00 - 02:00 2.00 BOPSUF;N RREP SURF Re-assemble pipe handler after changing out IBOP. 02:00 - 04:00 2.00 BOPSUF:P SURF Test choke valve #15 & upper IBOP 250 psi & 2500 psi OK. Blowdown choke & kill lines. Rig -up bails. 04:00 - 13:00 9.00 P PROD1 LD 5" DP in mouse hole. 5000' left standing in derrick. 13:00 - 18:30 5.50 DRILL P PROD1 Change jaws on iron roughneck. PU, rabbit, & RIH w/99its. POOH & stand back 3 1/2" DP. 18:30 - 00:00 5.50 DRILL P PROD1 MU bit, DGRJEWR/DM/PWD/UBHO BHA. Adjust motor to 1.5 deg bend. Orient offset. Initialize MWD. 6/11/2001 00:00 - 00:30 0.50 DRILL P PROD1 Surface test MWD at 5 bpm, 900 psi. OK 00:30 - 13:00 12.50 DRILL P PROD1 Blowdown top drive. PU 3 1/2" drillpipe in singles from pipe shed and RIH to 10728'. Circulate mud system. 13:00 - 14:30 1.50 DRILL P PROD1 Slip & cut 91' of drilling line. 14:30 - 15:30 1.00 DRILL P PROD1 Change bails. 15:30 - 16:30 1.00 DRILL P PROD1 ~RIH tag float collar at 11113'. Test casing to 3500 psi for 30 minutes. 16:30 - 18:00 1.50 DRILL P PROD1 Drill FC, cmt, FS & clean-out to 11210'. 18:00 - 23:00 5.00 DRILL P PROD1 Move-in vac trucks & super sucker. Circulate mud system drawing down pit 8. Shut-down & clean pit suction. Mix & pump 30 bbl Iow vis & 30 bbl weighted hi-vis spacer. 23:00 - 00:00 1.00 DRILL P PROD1 Start displacing old mud w/new BARADRILn mud system at 60 spm, 6 bpm, 2700 psi. 6/12/2001 00:00 - 01:00 1.00 DRILL P PROD1 Continue Fluid Displacement And Clean Out Mud Trough's In Pit System 01:00 - 01:30 0.50 DRILL P PROD1 Circulate And Build Volume 01:30-02:00 0.50 DRILL P PROD1 ' DrillAhead From 11,210'To 11,240' 02:00 - 03:00 1.00 DRILL P ~ PROD1 Pull Back Into 7" Casing Shoe At 11,194' And Circulate Bottoms Up 03:00 - 03:30 0.50 DRILL P PROD1 Preform Formation Integrity Test To 11.0 PPG @ 450 Psi. With 9.1 PPG Mud 03:30- 18:30 15.00 DRILL P PROD1 Directional Drill Ahead From 11,240' To 11,900' 18:30 - 20:00 1.50 DRILL N DFAL PROD1 Circulate And Condition Mud - Consult With Steve Schultz & Larry Vendal For Decision On Drilling Ahead 20:00 - 00:00 4.00 DRILL P PROD1 Directional Drill Ahead From 11,900' To 12,090' 6/13/2001 00:00 - 01:00 1.00 DRILL P PROD1 Continue To Drill Ahead From 12,090' To 12,205' Printed: 7/23/2001 11:49:12 AM BP EXPLORATION ' ~ Page 7 of 19 Operations :summa RepOrt Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 ,Contractor Name: N^BORS Rig Release: 7/12/2001 i Rig Name: NABORS 22E Rig Number: 22E DeSCription of:OperatiOns Date 'From - To Hours ACtiVity Code NPT phasel. =,,. · · ,, 6/13/2001 01:00 - 02:00 1.00 DRILL N PROD1 Pump Up Survey - Circulate And Consult With Steve Schultz, Larry Vendal & Mik Triolo For Decision On Drilling Ahead 02:00 - 02:30 0.50 DRILL C PROD1 POH To 11,730' 02:30 - 04:00 1.50 DRILL C PROD1 Open Hole Side Track (Trough Ahead Under Cut Low Side Of Hole) Directional Drill Ahead From 11,730' To 11,790' 04:00- 10:00 6.00 DRILL C PROD1 Continue To Directional Drill Ahead From 11,790' To 12,087' 10:00 - 10:30 0.50 DRILL C PROD1 Circulate & Condition Mud 10:30 - 11:30 1.00 DRILL C PROD1 POH To 7" Casing Shoe To 11,198' 11:30 - 13:30 2.00 DRILL C PROD1 Circulate And Pump Hi-Vis Sweep Around - Pump Dry Job 13:30 - 14:00 0.50 DRILL C PROD1 Blow Down Varco Top Drive & Surface Circulating System 14:00 - 18:00 4.00 DRILL ~C PROD1 POH With 3 1/2" Drill Pipe Stand Back In Mast 18:00 - 19:00 1.00 DRILL C PROD1 Lay Down Drilling Jars, (3) Flex Drill Collars, And Float Sub 19:00 - 20:30 1.50 DRILL C PROD1 Retrieve Data From Sperry Sun Logging Tools 20:30 - 21:30 1.00 DRILL C PROD1 Continue To Lay Down BHA - Drain Mud Motor - Break Off Bit - Lay Down Hang Off Sub, MWD Tool, LWD Tool, Mud Motor 21:30 - 22:00 0.50 DRILL C PROD1 Clear Off Rig Floor Of Sperry Sun Logging Tools & BHA - Bring Haliburton Packers To Rig Floor With Running Tool 22:00 - 22:30 0.50 DRILL C PROD1 Hold Pre Job Safety Meeting - Make Up Haliburton Running Tool Pick Up EZSV Bridge Plug And Make Up To Running Tool 22:30 - 00:00 1.50 DRILL C PROD1 RIH With EZSV Bridge Plug On 3 1/2" Drill Pipe (SLM) 6/14/2001 00:00 - 05:00 5.00 DRILL C PROD1 RIH With EZSV Bridge Plug On 3 1/2" Drill Pipe (SLM) To 11,147' 05:00 - 05:30 0.50 DRILL C PROD1 Break Circulation Wash And Clean EZSV Bridge Plug Setting Area - Apply 35 Turns To The Right - Apply An Additional 5 Turns To The Right - Release Torque From String - Pick Up And Verify That EZSV Is Set @ 11,147' To 25K Above Normal Upward Drag - Shear Off From EZSV With 45K @ 195K - Pick String Up To 11,137' - Apply 30 Turns To The Right And Release Torque - Sit Down And Tag EZSV With 30K - Pick Up String And Test EZSV To 3,500 Psi. For 10 Minutes - Bleed Off Pressure 05:30 - 06:00 0.50 DRILL C PROD1 Pump Dry Job - Blow Down Top Drive And Circulating System 06:00 - 12:00 6.00 DRILL C PROD1 POH With Bridge Plug Running Tool (SLM) 12:00 - 12:30 0.50 DRILL C PROD1 Change Out Haliburton EZSV Running Tool And Make Up Second EZSV Bridge Plug 12:30 - 13:00 0.50 DRILL C PROD1 Service Varco Top Drive, Traveling Blocks, And Crown Sheaves 13:00 - 19:00 6.00 DRILL C PROD1 RIH With Second EZSV Bridge Plug On 3 1/2 Drill Pipe To 10,523' (SLM) 19:00 - 20:00 1.00 DRILL C PROD1 Break Circulation Wash And Clean EZSV Bridge Plug Setting Area - Apply 35 Turns To The Right - Apply An Additional 5 Turns To The Right - Release Torque From String - Pick Up And Verify That EZSV Is Set @ 10,523' To 25K Above Normal Upward Drag - Shear Off From EZSV With 45K @ 195K - Pick String Up To 10,513' - Apply 30 Turns To The Right And Release Torque - Sit Down And Tag EZSV With 30K - Pick Up String And Test EZSV To 3,500 Psi. For 10 Minutes - Bleed Off Pressure 20:00 - 20:30 0.50! DRILL C PROD1 Pump Dry Job - Blow Down Top Drive And Circulating System Install Safety Wire On Varco Top Drive 20:30 - 00:00 3.50; DRILL C PROD1 POH With Haliburton Bridge Plug Running Tool 6/15/2001 00:00 - 00:30 0.50 P PROD2 Clear Rig Floor - Lay Down Haliburton EZSV Bridge Plug Printed: 7123/2001 11:49:12 AM Bp EXPLORATION Page 8of 19 , , - OperatiOns Summary Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From-To HoUrs ActivitylCode NPT .Phase` · . Description :of Operations:':~ ,' , , 6/15/2001 00:00 - 00:30 0.50 P PROD2 Running Tool - Bring Baker Oil Tools Mills & Cross Over Subs To Rig Floor. 00:30 - 04:00 3.50 STWHIP P PROD2 Pick Up Baker Oil Tools Window Master Whipstock & Milling Assembly - Orient MWD Tool - Down Load Data - Pick Up (1) 4 3/4" Drill Collar - Surface Test MWD Tool 04:00 - 05:30 1.50 STVVHIP P PROD2 Pick Up 4 3/4" Drill Collars And 3 1/2" HWDP 05:30 - 12:00 6.50 STWHIP P PROD2 RIH With Whipstock & 3 1/2" Drill Pipe Out Of Mast To 10,518' ~12:00 - 13:00 1.00 STVVHIPi P PROD2 Hold Pre Job Safety Meeting - Make Up Top Drive & Break Circulation - Establish Working Parameters - Survey And Orient Direction Of Whipstock To High Side For Kick Off - Strap In Whipstock To Top Of EZSV @ 10,523' And Set D,,own On Bridge Plug And Set Same - Shear Window Mill Shear \ Release Bolt ~ 13:00 - 19:30 6.50 S'I'WHIP P PROD2 Mill Window From 10,505' To 10,518' - Continue To Drill Formation To 10,538' 19:30 - 20:30 1.00 STWHIP P PROD2 Circulate Sweep Around While Working In And Out Of Window Monitor Well (Static) - Mix And Pump Dry Job - Blow Down Top Drive And Surface Circulating System 20:30 - 00:00 3.50 STVVHIP P PROD2 POH With 3 1/2" Drill Pipe And Stand Back In Mast 6/16/2001 00:00 - 00:30 0.50 P PROD2 Continue To POH - Stand Back 3 1/2" HWDP 00:30 - 02:00 1.50 STVVHIP P PROD2 Lay Down 4 3/4" Drill Collars And Window Master Milling Assembly 02:00 - 02:30 0.50 DRILL P PROD2 Make Up Mud Motor To MWD Tool And Stand Back In Mast 02:30 - 03:00 0.50 DRILL P PROD2 Pull FMC Wear Bushing 03:00 - 04:00 1.00 DRILL P PROD2 Pick Up BOP Stack Flushing Tool And Wash Out Stack - Lay Down Flushing Tool And Baker Oil Tools Mills 04:00 - 05:00 1.00 DRILL P PROD2 Hold Pre-Job Safety Meeting - Make Up Test Plug And Seat In Well Head Profile - Rig Up Test Equipment To Choke Manifold And Test Joint - Open Annulus Valve 05:00 - 09:00 4.00 DRILL P PROD2 Weekly BOP Test Witness Waived By AOGCC Representive John Spaulding - Test All Choke Valves, Upper And Lower Pipe Rams, Blind Rams, HCR Valves, Manual Valves On Choke And Kill Line, Upper And Lower IBOP Valves On Top Drive, Dart Valve, And Full Opening Safety Valve At 250 Psi. Low Pressure For 5 Minutes And 2500 Psi. High Pressure For 10 Minutes. Rig Down All Test Equipment 09:00 - 09:30 0.50 DRILL P PROD2 Install Wear Bushing - Blow Down All Surface Lines 09:30 - 11:00 1.50 DRILL P PROD2 Hold Pre-Job Safety Meeting - Pick Up And Make Up BHA (At Bit Inclination On Motor Would Not Turn On) - Lay Down Motor And Shuffle 3 1/2" HWDP In Mast 11:00 - 12:00 1.00 DRILL P PROD2 Pick Up Second Mud Motor - Make Up Bit And Orient With MWD Tool 12:00 - 13:00 1.00 DRILL P PROD2 Initialize MWD Tool 13:00 - 14:00 1.00 DRILL P PROD2 Make Up (3) Flex Drill Collars, Jars, And (5) 3 1/2" HWDP 14:00 - 14:30 0.50 DRILL P PROD2 Break Circulation And Surface Test MVVD Tool 14:30 - 18:00 3.50 DRILL P PROD2 RIH With (96) Stands Of 3 1/2" Drill Pipe And (24) Joints Of 3 1/2" HWDP And (7) Stands Of 3 1/2" Drill Pipe To 10,501' 18:00 - 18:30 0.50 DRILL P PROD2 Break Circulation And Orient Mud Motor To High Side - Work :Thru Window (NO Problems) Wash To 10,538' 18:30 - 00:00 5.50 DRILL P PROD2 ! Directional Drill Ahead From 10,538' To 10,900' - Weight On 'Bit 5K To 15K - Pump Pressure @ 62 Strokes Or 260 GPM (Off Bottom 2300 Psi. & on Bottom 2650 Psi.) - Torque @ 80 RPM (Off Bottom 2K & On Bottom 5K) String Rotating Weight ..... Printed: 7/23/2001 11:49:12 AM Bp EXPLO ,RATION Page9 of 19 OperatiOns Summa ' Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 :Rig Name: NABORS 22E Rig Number: 22E Date .From- To Hours Activity Code NPT phaSe Description of Operations . .... , 6/16/2001 18:30 - 00:00 5.50 DRILL P PROD2 @ 128K - With Pump On Drag Up @ 155K Drag Down @ 105K 6/17/2001 00:00 - 09:30 9.50 DRILL P PROD2 Directional Drill Ahead Thru Schrader Bluff "OA" Sand From 10,900' To 11,438' - Weight On Bit 5K To 15K - Pump Rate @ 65 Strokes Or 275 GPM (Off Bottom Pressure At 3000 Psi. & On Bottom Pressure At 3200 Psi.) - Top Drive At 80 RPM (Off Bottom Torque At 2K & On Bottom Torque At 5K) String Rotating Weight At 118K - With Pump On Drag Up At 147K And Drag Down At 107K 09:30 - 12:30 3.00 DRILL N DFAL PROD2 MWD Tool Recieving Poor Signal After Swaping Out Mud While Drilling - Mud Appears To Have Aired Up -Pump 30 Barrel Lo-Vis Sweep - Circulate And Condition Mud Also Work Pipe And Check Out Sperry Sun Surface Sensors And Equipment - While Attempting To Get A Good Detection Signal 12:30 - 14:30 2.00 DRILL P PROD2 Drill Ahead From 11,438' To 11,519' 14:30 - 15:00 0.50 DRILL N DFAL PROD2 Attempt To Regain Detection Signal For Sperry Sun Tools 15:00- 18:30 3.50 DRILL P PROD2 Drill Ahead From 11,519' To 11,680' 18:30 - 20:00 1.50 DRILL N DFAL PROD2 Circulate And Work Pipe While Attempting To Regain Detection Signal For Sperry Sun Tools - Charge Pulsation Dampners On Mud Pumps From 750 Psi. To 1,000 Psi. - Transfer 175 Barrels Into Active System From Trip Tank To Raise Pit Volume To Allow More Time For Air To Break Out Of The Mud - Change Flow Path Of Fluid In Mud System From Pits 5 Thru 8 To Flow Thru Pits 1 Thru 8 Using All Pits - Change Sperry Sun Sensor Placement On Stand Pipe - Add Drilling Slide To Mud *Note* Both Mud Engineers, Directional Drillers, Companyman, And Toolpushers Working To Solve Problem - After Making Above Changes We Were Able To Drill Ahead With A Workable Signal. 20:00 - 00:00 4.00 DRILL P PROD2 Drill Ahead Thru Schrader Bluff "OA" Sand From 11,680' To 11,990' - Weight On Bit 2K To 5K With Pump Rate At 66 Strokes Or 277 GPM - (Off Bottom Pressure At 2950 Psi. & On Bottom Pressure At 3175 Psi.) - Top Drive RPM At 30 To 65 - (Off Bottom Torque At 2K & On Bottom Torque At 5K) String Rotating Weight At 118K - With Pump On Drag Up At 143K iAnd Drag Down At 102K 6/18/2001 00:00 - 02:30 2.50 DRILL P PROD2 Continue To Directional Drill Ahead Thru Schrader Bluff "OA" Sand From 12,000' To 12,075' - Weight On Bit 2K To 5K With Pump Rate At 66 Strokes Or 277 GPM - Off Bottom Pump Pressure At 2950 Psi. & On Bottom Pump Pressure At 3175 Psi. - Top Drive RPM At 30 To 65 - Off Bottom Torque At 2K & On Bottom Torque At 5K String Rotating Weight At 118K - With Pump On Drag Up At 143K And Drag Down At 102K 02:30 - 03:00 0.50 DRILL N DFAL PROD2 Poor Signal Detection With Sperry Sun Equipment - Change Out (2) Transducer's On Stand Pipe Manifold 03:00 - 04:00 1.00 DRILL P PROD2 Drill Ahead From 12,075' To 12,123' 04:00 - 04:30 0.50 DRILL N DF^L PROD2 Signal Failure - Attempting To Regain Detection Signal For Sperry Sun Tools 04:30 - 06:30 2.00 DRILL P PROD2 ECD At 11.6 PPG Pump Out Of The Hole Thru Schrader Bluff "OA" Sand Formation To Whipstock Window In Order Clean Open Hole Section For Reducing ECD's 06:30 - 08:30 2.00 DRILL P PROD2 Pump Sweep And Circulate Hole Clean - Monitor Well Bore Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 1'0 of 19 Operations Summary,Report · Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From,To Hours ;Activity .Code NPT phase' DescriptiOn of Operations :: 6/18/2001 06:30 - 08:30 2.00 DRILL P PROD2 (Static) - Change Sperry Sun Sensor Placement And Recheck Signal (NO GOOD) - Pump Dry Job - Blow Down Top Drive And Circulating System 08:30 - 12:30 4.00 DRILL N DFAL PROD2 POH To 365' With 3 1/2" Drill Pipe And HWDP 12:30 - 13:00 0.50 DRILL N DFAL PROD2 Surface Test MWD Tool - Blow Down Top Drive 13:00 - 13:30 0.50 DRILL N DFAL PROD2 Continue To POH To BHA 13:30 - 14:30 1.00 DRILL N DFAL PROD2 Adjust AKO Setting On Mud Motor To 1.5 And Orient To MWD Tool - Lay Down Pulser And Hang Off Sub 14:30 - 16:00 1.50 DRILL N DFAL PROD2 Down Load MWD Data - Inspect Pulser 16:00 - 17:30 1.50 DRILL N DFAL PROD2 Make Up Hang Off Sub And Install Pulser- Initalize MWD Tool 17:30 - 18:30 1.00 DRILL N DFAL PROD2 RIH With BHA To 365' - Surface Test Sperry Sun MWD Tool - Well Appeared To Be Flowing (Shut In At Surface) - Notify Nabors Toolpusher And BP Drilling Supervisor - NO PRESSURE - After Investigating Air From Filling BHA Came To Surface - Open Choke - Check For Flow At Shakers (NO FLOW) - Open Up Well And Monitor Well Bore For Ten Minutes For A NO FLOW - Talk With Rig Personal About Good Job Shuting In Well And Following BP Shut In Procedures - Continue On With Operation Blow Down Top Drive 18:30 - 19:30 1.00 DRILL N PROD2 Safety Meeting With Nabors Alaska Drilling Manager Mr. Jim Denny And Rig Personal 19:30 - 23:00 3.50 DRILL N DFAL PROD2 RIH With 3 1/2" Drill Pipe From Mast To 10,484' '23:00 - 00:00 1.00 DRILL P PROD2 Service Varco Top Drive - Install New Grease Zerts In Guide Rollers 6/19/2001 00:00 - 03:30 3.50 DRILL N RREP PROD2 Continue To Change Out Guide Roller On Varco Top Drive i03:30 - 05:00 1.50 DRILL P PROD2 Slip And Cut 110' Of 1 3/8" Drilling Line And Adjust Draworks Mechanical Brakes .05:00 - 07:30 2.50 DRILL P PROD2 RIH From Top Of Whipstock Window Take Check Shot At 11,392' And 11,800' - Continue To RIH To 12,094' Wash And Ream To Bottom At 12,123' 07:30 - 00:00 16.50 DRILL P PROD2 Continue To Directional Drill Ahead Thru Schrader Bluff "OA" Sand From 12,123' To 12,863' - Drill From 1930 Hours To 2300 Hours At High Side From 12,863' To 12905' Per Geologist- Drill From 2300 Hours To 00:00 Hours Straight Down From 12,905' To 12,,915' - Weight On Bit 2K To 10K With Pump Rate At 55 Strokes Or 233 GPM Off Bottom Pump Pressure At 2300 Psi. & On Bottom Pump Pressure At 2425 Psi. - Top Drive RPM At 0 To 70 - Off Bottom Torque At 2K & On Bottom Torque At 5K String Rotating Weight At 120K - With Pump On Drag Up At 138K And Drag Down At 100K *NOTE* Having A Problem Getting Weight Transfered To Bit At Present Time There Is 3.75 Percent Lube Tex In Mud System And We Are Using All Drill String Weight Toward Bit, We Are Able To Get Good Differential On Initial Slack Off Then Have To Pick Up String And Lower Again To Get Another Bite Of Formation. May Consider POH For A Wiper Trip And Adding 3 1/2 HWDP To String If Sliding Operation Doesn't Improve. 6/20/2001 00:00 - 13:00 13.00 DRILL P PROD2 Continue To Directional Drill Ahead Thru Schrader Bluff "OA" Sand From 12,905' To 13,340'- Weight On Bit 2K To 10K With Pump Rate At 55 Strokes Or 233 GPM - Off Bottom Pump Pressure At 2325 Psi. & On Bottom Pump Pressure At Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 11 of 19 , OperatiOns_ Summa Report , , Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E · Date From - To Hours Activity Code NpT .::PhaSe DesCription of OperatiOns !6/20/2001 00:00 - 13:00 13.00 DRILL P PROD2 2600 Psi. Top Drive RPM At 30 To 70 Off Bottom Torque At 5K & On Bottom Torque At 7K String Rotating Weight At 128K - With Pump On Drag Up At 150K And Drag Down At 85K 13:00- 14:00 1.00 DRILL P PROD2 Circulate Bottoms Up For Wiper Trip 14:00 - 15:00 1.00 DRILL P PROD2 POH (15 Stands) 12,052' - Wiper Trip (No Pumps, No Problems) '15:00 - 15:30 0.50 DRILL P PROD2 RIH To 13,247' (No Problems) 15:30 - 16:00 0.50 DRILL P PROD2 Break Circulation - Wash And Ream From 13,247' To 13,340' Swap Out Mud System Due To MBT's Above 3 Per Well Plan 16:00 - 00:00 8.00 DRILL P PROD2 Directional Drill Ahead From 13,340' To 13,712' 6/21/2001 00:00 - 06:30 6.50 DRILL P PROD2 Continue To Directional Drill Ahead Thru Schrader Bluff "OA" Sand From 13,712' To 14,148' - Weight On Bit 2K To 1OK With Pump Rate At 55 Strokes Or 233 GPM - Off Bottom Pump Pressure At 2325 Psi. & On Bottom Pump Pressure At 2600 Psi. Top Drive RPM At 30 To 70 Off Bottom Torque At 6K & On Bottom Torque At 10K String Rotating Weight At 128K - With Pump On Drag Up At 155K And Drag Down At 85K 06:30 - 08:30 2.00 DRILL P PROD2 Circulate And Condition Hole - Geologist Confirmed Fault Crossed And TD On Lateral Section At 14,148' 08:30 - 13:30 5.00 DRILL P PROD2 Pump Out Of The Hole To Whipstock Window - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Circulating System Wash Off Rig Floor Due To Pulling Pipe Wet. 13:30 - 19:00 5.50 DRILL P PROD2 Continue To POH (Slow) Due To Swabbing - Increase Pulling Speed As Hole Permitted 19:00 - 20:30 1.50 DRILL P PROD2 Monitor Well Bore (Static) - Work BHA - Down Load Data From Sperry Sun Tools - Remove Pulser - Lay Down Hang Off Sub, PWD Tool, Gamma/Resistivity Float Sub, Mud Motor, & 6 1/8" Bit Clean Up And Clear Rig Floor Of Sperry Sun Tools 20:30 - 21:30 1.00 DRILL P PROD2 Hold Pre Job Safety Meeting - Drain BOP Stack - Make Up Bushing Puller And Pull Wear Ring - Install Test Plug And Test Joint - Rig Up Test Equipment 21:30 - 00:00 2.50 DRILL P PROD2 Test BOP And Related Equipment ~ Witness Of Test Waived By AOGCC Inspector Chuck Sheave - Test All Manual Valves On Choke Manifold And Super Choke, 13 5/8 Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valve's On Choke And Kill Line, Upper And Lower Top Drive IBOP Valves, Dart Valve And Full Opening Safety Valve At 250 Psi. Low Pressure For 5 Minutes And 2,500 Psi. High Pressure For 10 Minutes. 6/22/2001 00:00 - 02:30 2.50 DRILL P PROD2 Continue To Test BOP And Related Equipment 02:30 - 03:30 1.00 DRILL P PROD2 Rig Down Testing Equipment - Pull Test Plug - Install Wear Ring And Energize 4 Lock Down Studs - Blow Down Top Drive, Choke Manifold, Choke And Kill Lines - Clear Rig Floor 03:30 - 05:00 1.50 DRILL P PROD2 Pick Up 6 1/8" Hole Opener, (3) Stabilizer's, Float Sub, And Pony Collar 05:00 - 10:30 5.50 DRILL P PROD2 Continue To RIH With 3 1/2" Drill Pipe From Mast To 10,522' 10:30 - 00:00 13.50 DRILL P PROD2 Ream Schrader Bluff "OA" Sand Lateral Section From 10,522' To 14,148' (NO FILL) - Weight On Hole Opener 2K To 5K With Pump Rate At 66 Strokes Or 275 GPM - Pump Pressure At 2325 Psi. - Top Drive RPM At 100 Torque At 3K To 5K String Rotating Weight At 128K- With Pump On Drag Up At 155K And Drag Down At 85K 6/23/2001 00:00 - 01:30 1.50 DRILL P PROD2 Hold Pre Job Safety Meeting With New Crew Coming From Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 12 of 19 Operations Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E · Date: From T°' Hours ACtivity Code NPT phase ' 'Description of Operations , · , 6/23/2001 00:00 - 01:30 1.50 DRILL P PROD2 Day's Off Circulate And Condition Mud At 14,148' 01:30 - 07:00 5.50 DRILL P PROD2 Monitor Well Bore (Static) - Drop Rabbit - Attempt To POH With Hole Opener (Well Swabbing) Pump Out Of The Hole - Attempt To Pull Pipe After Every Row Stood Back In Mast - SLM And Get Up And Down Weight's In Open Hole Every 500' In Open Hole With Pump Off. 107:00 - 09:00 2.00 DRILL I P PROD2 Circulate And Spot 2% EP Mud Lube In Casing 09:00 - 14:30 5.50 DRILL ~P PROD2 Continue To POH Slow Due To Swabbing At Higher Speed 14:30 - 16:00 1.50 DRILL i P PROD2 Monitor Well Bore (Static) - Lay Down BHA - Clear Rig Floor 16:00 - 17:30 1.50 CASE P PROD2 Hold Pre Job Safety Meeting - Rig Up To Run Baker P & A Kit 17:30 - 18:30 1.00 CASE P PROD2 Pick Up And RIH With Baker Oil Tools Plug And Abandon Kit Per Procedure - Change Elevators - RIH With One Stand Of 3 1/2" Drill Pipe From Mast And Check Float Equipment. I 18:30 - 00:00 5.50 CASE i p PROD2 Continue To RIH With 3 1/2" Drill Pipe From Mast To 7,907' - Fill Pipe Every 20 Stands Verify Correct Displacement. 6/24/2001 00:00 - 02:30 2.50 CASE C PROD2 RIH With Baker Oil Tools Plug And Abandon Kit Per Procedure With 3 1/2" Drill Pipe From Mast To 10,405' - Fill Pipe Every 20 Stands Verify Correct Displacement. 02:30 - 03:30 1.00 CASE C PROD2 Circulate Drill Pipe And Liner Volume - Change Out Bales To Longer Set To Facilitate Installation Of Swing, Head Pin, And Full Opening Safety Valve Under Top Drive Pipe Handler. 03:30 - 06:00 2.50 CASE C PROD2 Continue To RIH Thru Schrader Bluff"CA" Sand Open Hole Section To Float Shoe Depth At 14,141' - Top Of LSVAt 13,953' - Position Baker Payzone Open Hole Packer Element Across Following Depth Top At 13,955' And Bottom At 13'975' 06:00 - 06:30 0.50 CASE !C PROD2 Pick Up And Make Up Head Pin And Cement Hose 06:30 - 07:00 0.50 CASE lC PROD2 Circulate And Condition Mud At 5 Barrel Per Minute With 1200 Psi. Hold Pre Job Meeting With All Personal On Up Coming Cement And Displacement Operation 07:00 - 09:00 2.00 REMCM"C PROD2 Pump 5 Barrels Of 6% KCL Water - Test Lines And Surface Equipment At 4000 Psi. (Good Test) - Pump 5 Barrels Of 6% KCL Water- Mix And Pump 7 1/2 Barrels (37 Sacks) Of 15.8 PPG Cement At 3 BPM w/1050 Psi. - Drop Drill Pipe Wiper Dart Pump 5 Barrel Water - Drop Foam Plug - Start Displacement At 4.1 BPM w/1450 Psi. 90 Barrels Away Slow Rate To Bump Plug - Bump Plug w/97 3/4 Barrels Away At 500 Psi. To 900 Psi. - Increase Pressure In 200 Psi. Increments "LS" Valve Opened On Packer At 2500 Psi. - Shut Down Pump Pressure Stablized At 1600 Psi. Hold For 2 To 3 Minutes To Square Off Element - Bleed Off Pressure To 650 Psi. To Check Volume Of Inflation Fluid (1/4 Barrel To Inflate) - Bleed Pressure To 0 Psi. Verify Packer Set By Slacking Off 5K Pounds - Pressure Up To 3000 Psi. To Shear Hydraulic Disconnect - Bleed To 0 Psi. - Pick Up To Verify Disconnected - Pull One Stand 09:00 - 11:00 2.00 REMCM"C PROD2 Circulate Out Cement And Spot New Mud Thru "CA" Sand Open Hole Section 11:00 - 14:00 3.00 REMCM"C PROD2 Monitor Well Bore (Static) - POH To 10,200' Slow To Prevent Swabbing With 3 1/2" Drill Pipe Stand Back In Mast 14:00 - 18:30 4.50 REMCM"C PROD2 Monitor Well - Pump Dry Job - Blow Down Top Drive And Circulating System - Continue To POH 18:30 - 19:00 0.50 REMCM"C PROD2 Lay Down Baker Hydraulic Disconnect Running Tool- Clear Printed: 712312001 11:49:12 AM BP EXPLORATION Page 13 of 19 Operations ,Summar Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E ..Date From - To Hours Activity Code NPT Phase Description of Operations' · · .... ,,, 6/24/2001 18:30 - 19:00 0.50 REMCM"C PROD2 Rig Floor 19:00 - 20:30 1.50 CASE P PROD2 Hold Pre Job Safety Meeting - Rig Up Casing Tools And Equipment To Run 4 1/2" Slotted Liner 20:30 - 00:00 3.50 CASE P PROD2 RIH With 4 1/2" L-80 IBT 12.6 lb. Slotted Liner 6/25/2001 00:00 - 01:30 1.50 CASE P PROD2 Hold Pre Job Safety Meeting - Rig Up Equipment To Run Inner String Of 2 7/8" Fox Tubing 01:30 - 06:00 4.50, CASE i P PROD2 Pick Up Slick Stick, Crossover, 106 Joints 2 7/8" Fox Tubing, 4 Foot Pup Joint For Space Out, Crossover, To Complete Inner String And Run Inside 4 1/2" Slotted Liner 06:00 - 06:30 0.50 CASE P PROD2 Change Out Elevators For 3 1/2 Drill Pipe - Pick Up Baker 7"X 5" HMC Hydraulic Liner Hanger And ZXP Mechanical Set Packer - Make Up Crossover To 2 7/8" Inner String And Make Up To 4 1/2" Slotted Liner. 06:30 - 07:00 0.50 CASE P PROD2 Rig Down 2 7/8" Equipment And Clear Rig Floor - Dress Hanger And Fill With PAL Mix 07:00 - 07:30 0.50 CASE P I PROD2 Circulate 2 7/8 Inner String And Bushing To Guide Shoe Volume 07:30 - 15:30 8.00 CASE 3 PROD2 ;RIH With 4 1/2" L-80 IBT 12.6 lb. Slotted Liner VVith 112 Stands Of 3 1/2" Drill Pipe From Mast To Window - Record VVeight's Up And Down Per Engineer - Continue To RIH With Slotted Liner Thru Schrader Bluff "OA" Sand - Top Of Baker ZXP Packer At 10,405' And Baker Guide Shoe At 13,810' 15:30 - 16:30 1.00 CASE ~ PROD2 Drop 29/32" Ball - Circulate At 4 BPM w/1200 Psi. To Get Ball On Seat - Calculated Volume To Seat Ball 960 Strokes - Ball On Seat At 827 Strokes - Pressure Up To 1900 Psi To Set Baker 7"X5" HMC Hydraulic Liner Hanger - Slack Off String Weight 25K For Verification Of Hanger Setting - Pressure Up To 3,300 Psi. To Release HR Tool Shear Ball Seat Pressure At 0 Psi. - Pick Up Check Weight Reduction Lost 12,000 lbs. Continue To Pick Up 5 To 6 Feet To Expose Packer Setting Dog Sub - Slack Off 30,000 lbs. To Set Packer - Repeat 3 Times - Tag Liner Top At Proper Depth 10,405' 16:30 - 22:30 6.00 CASE 3 PROD2 Stand Back 2 Stands - Monitor Well - Pump Dry Job - POH With Baker Liner Running Tool And 2 7/8" Inner String 22:30 - 23:30 1.00 CASE P PROD2 Rig Up Tubing Tongs - Break Out And Lay Down Baker Liner Running Tools And Crossovers - Change Out Elevators And Clear Rig Floor 23:30 - 00:00 0.50 CASE P PROD2 Lay Down 2 7/8" Inner String 6/26/2001 00:00 - 06:30 6.50 STWHIP P PROD2 Continue LD 2 7/8" tubing (106 jts). Clear floor, LD handling tools. PU 3 1/2" single & MU to top drive. 06:30 - 11:00 4.50 STWHIP P PROD2 Cut & slip 106' of drilling line. Weld hand rail at derrick board. Service top drive. Inspect & measure bridle lines. 11:00 - 17:00 6.00 STWHIP P PROD3 MU milling BHA & whipstock w/Iocator seal assembly. Load MWD. RIH w/9- 4 3/4" DC's, & 2 stands HWDP. Test MWD. 17:00 - 00:00 7.00 STWHIP P PROD3 TIH w/whipstock assembly to TOL. 6/27/2001 00:00 - 04:30 4.50 P PROD3 Set whipstock anchor w/20K Ibf weight and pull 15K to check anchor. Set 35K Ibf weight 3x and shear lug bolt. Mill window 10091-10103. Drill/mill formation to 10119'. 04:30 - 14:00 9.50 STWHIP P PROD3 Pump hi vis sweep. Monitor well and POOH 10119-9730'. Continue POH and LD BHA and 4 3/4" DC's. Download MWD. PU motor, MU to MWD, and stand-back. LD mill assembly. 114:00 - 15:30 1.50 STWHIP P PROD3 Clear floor, pull wear ring. Grease crown. ~15:30 - 21:00 5.50 STWHIP P PROD3 Flush stack, kill HCR, & choke HCR. MU test assy & install Printed: 7/23/2001 11:49:12 AM , . BP EXPLORATION Page 14 of 19 OperatiOns Summa RePort Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From., To Hours Activity Code NPT Phase DescriPtion of OPerations ,,, 6/27/2001 15:30 - 21:00 5.50 STWHIP P PROD3 test plug. Conduct BOP test of all rams, annular, HCR's, choke valves, floor valves, floor valves, top drive IBOP's, to 250 psi Iow for 5 mins and 2500 psi high for 10 rains. Koomey test. BOP test witnessing waived by Lou Grimaldi of AOGCC. 21:00 - 22:00 1.00 DRILL P PROD3 MU BHA, orient motor, and Icad MWD. 22:00 - 00:00 2.00 DRILL P PROD3 TIH w/6 1/8" bit, 1.5 deg bend motor & BHA to 4166'. PUW 120K, SOW 100K. 6/28/2001 00:00 - 03:00 3.00 DRILL P PROD3 Continue TIH 4966-10119'. 03:00 - 00:00 21.00 DRILL P PROD3 Break circulation & drilling. Shaker screens blinding off. Change-out screens. Directionally drill, building angle and making azimuth change for L-2 lateral. Base of CA sand at 4360'. Received & changed out 900 bbls fresh BaradrilN mud from plant. Drill 10119 to 11027 ft at midnight report time. PUW 130K, SOW 100K, ROTW 115K, TQON 3K, TQOFF 2K, RPM 70, WOB 6k, SPP 2400 psi, 55 SPM, 232 GPM. SPR at 20 SPM = 670 psi, SPR at 30 SPM = 860 psi. 6/29/2001 00:00- 16:30 16.50 DRILL P PROD3 Drilling 11027-11955'. PUW 130, SOW 98, ROTW 115, TQ on/off 3k ft-lbf. 16:30 - 17:30 1.00 DRILL P PROD3 Circulate bottoms up. 17:30 - 20:30 3.00 DRILL P PROD3 POH w/pumps on to 10021. Monitor well for 10 rains. Pull BHA through window and into casing. Serviced top drive. 20:30 - 21:30 1.00 DRILL P PROD3 Trip back in hole, break circulation and back on bottom drilling. Offloading 600 bbls "old" mud to vac trucks and preparing to take on 600 bbls "new" Baradriln mud. 21:30 - 00:00 2.50 DRILL P PROD3 Drilling ahead in CA lateral L-2 to 12139'. 10.85 ECD, 56 spm, 236 gpm, 2650 psi SPP on btm, 2450 psi SPP off btm, 4k ft-lbf TQ on btm, 3k ft-lbf off btm, 132K PUW, 98K SOW, 123K ROTW, 2-10K WOB, 60 RPM. 6/30/2001 00:00 - 0.00 DRILL P PROD3 Drill 12138-13543' in CA lateral L-2.70 rpm, 5-10K WOB, 55 spin, 233 gpm, 3000 psi SPP on btm, 2650 psi SPP of btm, 4K TQ on, 3K TQ off btm. 11.7 ppg avg ECD per PWD. Added 600 bbls fresh BaradrilN mud at 12200'. 7/1/2001 00:00 - 06:00 6.00 DRILL P PROD3 Drill ahead 13543 to 13850 TD CA lateral L-2 per wellsite geologist. Add 300 bbls new BaradrilN mud AT~ 13600'. 140k PUW, 85k SOW, 112 ROTW, TQ on/off 5k/3k ft-lbf, 54 spm, 230 gpm, 2-10k WOB. 06:00 - 07:30 1.50 DRILL P PROD3 Pump weighted, hi-vis sweep. 07:30- 21:00 13.50 DRILL P ~PROD3 POOH, pumping out, 13850-9929'. LD MWD, PWD, Gamma, RES, float sub, motor, & bit. 20:00 - 21:00 1.00 DRILL P i PROD3 MU 6 1/8" hole opener, stabilizer, DC, stabilizer, 2-DC, 12-HWDP BHA. 21:00 - 23:30 2.50 DRILL P PROD3 !TIH w/BHA on 3 1/2" DP. 23:30- 00:00 0.50 DRILL P PROD3 Ream 10149-10424. 130 PUW, 102 SOW, 112 ROTW, 63 spin, 255 gpm, 100 rpm, 2100 psi SPP, 3K ft-lbf rotary torque. 7/2/2001 00:00 - 12:30 12.50 DRILL P PROD3 Ream w/6 1/8" hole opener assembly 10424'-13850'. 130k PUW, 90K SOW, 115K RoTW, 3K ff-lbf torque. At 12056, 12848, 13436 torque increased to 5K. 12:30 - 14:30 2.00 DRILL P PROD3 Circ & condition mud. Monitor well for 10 mins. Spot 300 bbls new 9.1 ppg BaradrilN w/7 % lubricant on btm. 14:30 - 17:30 3.00 DRILL P PROD3 Pump out of hole through window to 10059'. Circulate 2% EP mud lube into system. 17:30 - 19:00 1.50 DRILL P PROD3 Circ & condition mud. Monitor well for 10 mins. 19:00 - 00:00 5.00 DRILL P PROD3 Pump out of hole 10 stands, check for swabbing-OK, pump dry Printed: 7/23/2001 11:49:12AM BP EXPLORATION page 1.5of 19 OperatiOns Summary RepOrt. · Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From-To HOurs ACtivityCode NpT phase' DesCription of Operations , , 7/2/2001 19:00 - 00:00 5.00 DRILL P :PROD3 job, & TOOH. Log PU & SOW every 1000'. POOH to 2700' at midnight report time. 7/3/2001 00:00 - 05:00 5.00 DRILL P . PROD3 POOH slowly to BHA. Monitor well for 10 mins. LD hole opener BHA. Clear floor, MU whipstock retrieval BHA. 05:00 - 09:30 4.50 DRILL P PROD3 RIH w/whipstock retrieving BHA, 4 stds HWDP, and 3 1/2" DP to 10038'. 09:30 - 11:30 2.00 DRILL P PROD3 Slip & cut 96' of drillling line. Service top drive. 11:30 - 12:00 0.50 DRILL P PROD3 Orient hook to Iow-side of hole wi Sperry MWD 12:00 - 21:00 9.00 DRILL P PROD3 Latch onto whipstock slot w/hook retrieving tool. Pull and jar. Whipstock came free w/70K pull over string weight. POOH slowly w/whipstock. LD 12 jts HWDP, jars, bumper sub, collar. 21:00 - 22:30 1.50 DRILL P PROD3 . Download MWD, LD MWD, PWD, FS, 1 jt HWDP, retrieving hook, whipstock, subs, 9 jts of 3 1/2" DP. 22:30 - 23:30 1.00 DRILL P PROD3 Clear rig floor rig up casing running equipment. Function test blind rams. 23:30 - 00:00 0.50 DRILL P PROD3 Pre-job safety & planning meeting w/rig crew and service . personnel. 7/4/2001 00:00 - 07:30 7.50 CASE P PROD3 RIH w/4 1/2" guide shoe, shoe jt, pack-off bushing, 75 jts 4 1/2", 12.6~, L80 slotted liner, 14 jts solid liner. Set casing on elevators on rotary table. 07:30 - 14:00 6.50 CASE P PROD3 Rig up slip bowl assembly & RIH inside 4 1/2" liner assembly w/stinger & 112 jts inner string( 2 7/8" FOX). Space out inner sting to bushing. MU Baker hook-wall hanger assembly w/ tension lock swivel. 14:00 - 16:30 2.50 CASE P PROD3 RIH to 10098 top of 7" casing window for OA lateral L-2. (Window depth 10091-10103'). 16:30 - 23:00 6.50 CASE N DPRB PROD3 Attempt to exit window with bent shoe joint (10" offset from axis, bend in mid-jt). Set down at liner top 10420' (OA L1 lateral). Stood back 4 stands and made 20 attempts to exit using tension lock swivel to effect rotation of liner shoe joint in 15 degree increments. Attempted rotation & torque monitoring at mid-window depth while lowering assembly through window depth and set down at lower liner top each attempt at 10420'. (Top sleeve allows ,,,6' of travel to guide shoe). 23:00 - 00:00 1.00 CASE N DPRB PROD3 CBU & review options w/ODE Campbell. 7/5/2001 00:00 - 00:30 0.50 CASE N DPRB PROD3 Circulate bottoms up. Crew change- pre-job safety and planning meeting. Monitor well. 00:30 - 05:00 4.50 CASE N DPRB PROD3 Pull 5 stands above window. Lowered guide shoe and bent joint to window depth and attempted to exit. 5 attempts and each time set back down on previous liner top at 10420'. 130K PUW, 110 SOW. 05:00 - 06:30 1.50 CASE N DPRB PROD3 CBU & monitor well for 10 mins. 06:30 - 10:30 4.00 CASE N DPRB PROD3 POOH 10050' to 7786' slowly due to swabbing. 10:30 - 11:00 0.50 CASE N DPRB PROD3 Circulate bottoms up. 11:00 - 16:00 5.00 CASE N DPRB PROD3 POOH rom 7786' to liner hanger assembly. LD Tension lock swivel. !16:00 - 16:30 0.50 CASE N DPRB PROD3 Service top drive & grease crown. ,16:30 - 00:00 7.50 CASE N DPRB PROD3 RIH w/liner hanger assy. Rotate incremental 1/2 turns at surface, work out torque down drill string, and make 16 attempts to exit window w/guide shoe and 4 1/2" bent joint Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 16 of 19 Operations Summa RePort Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date : From'To HoUrs Activity Code NPT Phase Description of Operations , ,,, 7/5/2001 16:30 - 00:00 7.50 CASE N DPRB PROD3 liner. Make one attempt by pulling assy up slowly across window depth at 8 RPM and attempt to "catch" window while observing torque. 2500-3500 fi-lb "bobble" on torque indicator. Lower assembly & tag top of previous liner. PU 1 stand off previous liner and conduct "base-line" torque reading test at 8 rpm surface rotation-2500 ft-lbf. Pull 4 stands (1 stand above window depth) & make multiple attempts by rotating 1 1/2 turns drillpipe at surface. Work torque down drillstring & liner & attempt to lower through window. All attempts resulted in setting down at 10420' prior liner top on the 4th stand of pipe. 71612001 00:00 - 08:00 8.00: CASE N DPRB PROD3 Attempt to work 4 1/2" liner through 7" casing window. Multiple trips from 10088' to 10420' orienting, rotating 1/2 turn at sfc on each attempt and working torque down the drill string. Increased rotations to 1 1/2 times. Attempted to rotate 8 rpms at surface while lowering guide shoe/bent jt assy past casing window. Saw torque increase from 2500 up to 3500 fi-lbs at window depth. After several attempts this torque indication ceased. 08:00 - 10:00 2.00! CASE ~N DPRB PROD3 Circulate bottoms up & monitor well for 10 mins. 10:00 - 11:00 1.00 CASE ~ N DPRB PROD3 POOH 5 stands. Monitor well for 10 mins. Pump "dry job", blow-down top drive & mud line. 11:00 - 15:00 4.001 CASE . N DPRB PROD3 POOH w/3 1/2" DP to hookwall liner hanger assy. Monitor well for effects of swabbing. 15:00 - 17:00 2.00 CASE N DPRB PROD3 Change out bales. Lay-down liner hanger assy. 17:00 - 23:30 6.50 CASE N DPRB PROD3 Lay down 70 joints 2 7/8" FOX inner string, xo's, ball seat, catcher, & slick stinger. 23:30 - 00:00 0.50 CASE N DPRB PROD3 Rig up 4 1/2" handling tools, clear rig floor, crew change, & prepare to lay-down 4 1/2" liner & assembly. 7/7/2001 00:00 - 01:00 1.00 CASE N DPRB PROD3 Cont. servicing toP drive. 01:00 - 05:00 4.00 CASE N DPRB PROD3 Laydown 14 joints 4 1/2" solid liner, 75 jts solid liner, pack-off bushing, bent joint, and guide shoe. Guide shoe had minor scrapes on its nose. Joints #38 & 56 were slightly bent. Some stop collars came loose. 05:00 - 06:00 1.00 CASE N DPRB PROD3 Clear floor, pull wear ring, install test plug below BOP, fill stack and choke manifold. 06:00 - 12:00 6.00 CASE P PROD3 Test HCR, Hydril, choke manifold, TIVV valve, Dart, Upper & Lower pipe rams, Blind rams, manual choke & kill valves to 250 psi Iow and 2500 psi high. BOP test witnessing waived by AOGCC John Spaulding. Remove test plug, rig-down test assy, install wear ring, blow down and line up choke manifold, clear rig floor. 12:00 - 17:30 5.50 CASE N DPRB PROD3 Made up guide shoe & bent it(16' from center w/10" offset from axis) float sub, and MWD collar. TIH on 3 1/2" DP. 17:30 - 18:00 0.50 DRILL N DPRB PROD3 Checked toolface w/MWD. 135 deg left of high side. Made qtr turn, tool face was erratic from 180-270. Worked pipe w/tool face changing continuously. Lowered guide showe to window depth w/pumps on and toolface transmitting. Toolface now holding 40 deg left of high-side. Lowerd guideshoe/bent joint through window depth, weight indicator showed 10K loss. TIH 10725 indicating successful window exit. 18:00 - 19:00 1.00 DRILL N DPRB PROD3 Circulated bottoms up 2500 strokes working pipe. Mud in acceptable condition. 19:00 - 19:30 0.50 DRILL N DPRB ' PROD3 Pull up above window w/140k PUW with no weight change. Printed: 712312001 11:49:12 AM ,. BP EXPLORATION Page 17 of 19 Operations .Summa Report Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E · Date From - To Hours Activity code :NPT PhaSe Description of Operations 7/7/2001 19:00 - 19:30 0.50 DRILL N DPRB PROD3 Pump up toolface w/234 gpm, 55 spm, 1650 psi SPP. 132 deg right of high side. Move guide shoe across window, lowered no weight loss, no window exit. 19:30 - 20:30 1.00 DRILL N DPRB PROD3 Qtr turn work pipe, lowered and did not exit window. Check toolface at 44 deg left. RIH past top of liner depth to 10450 and confirmed that the assembly again exited the window. 20:30 - 23:00 2.50 DRILL N DPRB PROD3 Pull up above window depth. Pre-job safety and planning meeting held then cut and slip drilling line 101'. 23:00-00:00 1.00 DRILL N DPRB PROD3 Mix 25 bbl dry job at11.2 ppg. Start POOH w/ 31/2" DP to 9000'. 71812001 00:00 - 04:30 4.50 CASE N DPRB PROD3 TOOH w/3 1/2" DP. LD MWD collar & float sub. 04:30 - 05:30 1.00 CASE N DPRB PROD3 Change-out elevators & rig-up 4 1/2" handling tools 05:30 - 09:30 4.00 CASE N DPRB PROD3 RIH w/4 1/2" guide shoe, bent joint, pack-off bushing, 75 joints slotted liner, 14 joints solid liner. Set liner in elevators on rotary table. Tie-off handles. 09:30 - 15:30 6.00 CASE N DPRB PROD3 RU handling tools, tongs, elevators for 2 7~8" FOX. RIH w slick stinger on 112 jts 2 7/8" FOX tubing & space-out. 15:30 - 16:30 1.00 CASE N DPRB PROD3 MU 4 1/2" x 7" Hook-wall Liner Hanger Assembly to FOX tubing & 4 1/2" liner w/runningtool. 16:30 - 18:30 2.00 CASE N DPRB PROD3 RIH w/liner assembly on 3 1/2" DP to window depth at 10091-10103'. 18:30 - 20:00 1.50 CASE N DPRB PROD3 Make 3 attempts at lowering guide shoe & bent joint through the casing window. Each time the string was rotated and torque was worked down the drillstring via pipe movement. Weight indicator was monitored for indications of window exit. Set down twice on the previous top of liner at 10420'. On the 3rd attempt the assembly went out the window and into open hole. 20:00 - 21:30 1.50 CASE P PROD3 PUW at 150K, SOW at 110K. Lowered liner assembly into open hole and set hook on lower edge of casing window w/20K slack-off weight. 21:30 - 23:00 1.50 CASE P PROD3 Pumping down drill string at 1 bpm to clear DP, inner string, and stinger. Good circulation & returns. Dropped ball & displaced to seat. Pressured up to 2500 psi to hydraulic release hanger &collet. Picked up off hanger and set back down. Pressured up to 3600 psi to blow out ball into catcher and open circulating port. PUW 140K. Top of liner-10085 ft. Btm of liner-13668 ft. 23:00 - 00:00 1.00 CASE P PROD3 Started pulling stinger out of bushing slowly. Continued slow pull until cross-overs cleared inner diameter of liner hanger. Continue pulling out of hole with 3 1/2" drillpipe. 7/9/2001 00:00 - 01:30 1.50 CASE P PROD3 POOH w/3 1/2" DP to 10070'. Monitor well f/10 mins. 01:30 - 04:00 2.501 CASE P PROD3 Pump 25 bbls 11.2# weighted slug "dry job". Blow down top drive & mud line. Continue POOH. 04:00 - 10:30 6.50 CASE P PROD3 LD liner running tool. RU handling tools and lay-down 112 jts 2 7~8" FOX tubing. RD handling tools. 10:30 - 11:00 0.50 CASE P PROD3 Lay-down Baker slick stinger assy. 11:00 - 14:30 3.50 TA N DPRB COMP PU Baker 7 inch RBP. RIH on 3 1/2" DP to 4268'. Down drag increasing & fluid level dropping. Hole being "surged" while TIH. Monitor well. Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 18 of 19 Operations Summa Report , Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date ! :From To Hours ActivityCode NPT Phase Description of Operations' , , , 7/9/2001 14:30 - 17:30 3.00 TA N DPRB COMP Pump 25 bbl, 11.2 ppg, weighted slug. Blow down top drive & mud line. POOH w/7" RBP. Monitor. 17:30-21:30 4.00 TA N DPRB COMP MU 7" csg scraper, bit sub, & bit. &TIH. 21:30 - 23:30 2.00 TA N DPRB COMP Circulate wellbore & condition mud. Mud in 37vis & 9.1 ppg. Mud out 57 vis 9.4 out. Started centrifuge Conditioned to 9.1 ppg & 40 vis out. (Mud was loaded up w/CaCO3 after multiple "dry jobs" pumped prior to TOOH). 23:30 - 00:00 0.50 TA N DPRB COMP Start POOH w/scraper assy. 7/10/2001 00:00 - 04:30 4.50 DRILL N DPRB PROD1 POH with 7" casing scraper and 6" bit. 04:30 - 05:00 0.50 DRILL N DPRB PROD1 Service rig. 05:00 - 09:00 4.00 TA N DPRB COMP Make up 7" Baker Retrievable Bribge Plug (RBP) on 3 1/2" drill ;pipe and RIH to 9100'. RBP taking weight and forcing mud into :the formation. 09:00 - 10:00 1.00 TA P COMP Drop 1 7/16" ball and pump down same. Pressure up to 2000 psi, pull 15K over pull and set RBP at 9060'. 10:00 - 10:30 0.50 TA P COMP Test RBP to 2500 psi for 10 minutes and record on chart. 10:30 - 15:30 5.00 TA P COMP Drop 2" ball to open ports in circulating sub. Displace mud in hole with 8.5 ppg sea water. 15:30 - 17:30 2.00 TA P COMP Displace 8.5 ppg Sea WaterTo 9.1 ppg KCL Brine 17:30 - 00:00 6.50 TA P COMP POH Laying Down (294 Joints) 3 1/2" Drill Pipe - Lay Down Baker Model "J" Setting Assembly & Clear Rig Floor 7/11/2001 00:00 - 02:30 2.50 DRILL P PROD3 RIH With 3 1/2" Drill Pipe From Mast 02:30 - 07:00 4.50 DRILL P PROD3 POH Laying Down 3 1/2" Drill Pipe 07:00 - 07:30 0.50 DRILL P PROD3 Pull Wear Ring And Install Test Plug 07:30 - 09:30 2.00 TA P COMP Hold Pre Job Safety Meeting - Remove 3 1/2" X 6" Variable Rams From Top Pipe Ram Profile And Install 2 7/8" Rams - Test @ 2500 Psi. For 10 Minutes 09:30 - 10:30 1.00 TA P COMP Hold Pre Job Safety Meeting - Rig Up Tools To Run 2 7~8" Tubing 10:30 - 20:00 9.50. TA P COMP Pick Up Baker RPB Model "M" Retrieving Head With Cross Over With 279 Joints Of 2 7/8" EUE (6.4 lb.) L-80 Tubing And RIH :20:00 - 21:00 1.00 TA P COMP Hold Pre Job Safety Meeting With Rig Crews. Pick Up FMC Tubing Hanger - Install TWC And Blanking Plugs - Make Up Hanger & Landing Joint - Top Drive And Traveling Blocks Weight At 70K - Completion String And Top Drive & Blocks Up Weight At 98K And Down Weight At 90K 21:00 - 23:00 2.00 TA P COMP Drain BOP Stack - Land 2 7/8" Tubing Completion String In Tubing Spool - Energize Lock Down Studs - Test Two Way Check Valve On Annulus Side @ 1000 Psi. For 10 Minutes - Test Two Way Check Valve From Tubing Side @ 1000 Psi. For 10 Minutes 23:00 - 23:30 0.50 TA P COMP Rig Down Test Equipment & Lay Down Test Joint - Rig Down Tubing Tongs And Equipment - Clear Rig Floor 23:30 - 00:00 0.50 T^ 3 COMP Hold Pre Job Safety Meeting - Change Rams In Top Gate To 3 1/2" X 6" Varaibles - Remove Mouse Hole & Bell Nipple - Prepare To Nipple Down BOP Stack And Related Equipment - Clean Mud System 7/12/2001 00:00 - 03:30 3.50 TA ~ COMP Continue To Change Rams In Top Gate To 3 1/2" X 6" Variables & Nipple Down BOP And Related Equipment 03:30 - 06:00 2.50 TA 3 COMP Install FMC Tubing Head Adapter And Cameron 2 9/16" 5M Tree Test Tubing Head Adapter Void Area With FMC At 5000 Psi. (OK) - Install Pump In Flange On Wing Valve - Rig Up Printed: 7/23/2001 11:49:12 AM BP EXPLORATION Page 19of 19 · Operations Summar Report Legal Well Name: MPC-.41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: DRILL+COMPLETE Start: 5/27/2001 End: 7/12/2001 Contractor Name: NABORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date From. To Hours Activi~ COde NpT Phase Description of Operations · , ...... . . 7/12/2001 03:30 - 06:00 2.50 TA P COMP Circle Chart Recorder - Pressure Test Tree At 5000 Psi. With Rig Test Pump - Rig Up Manifold To Freeze Protect Annulus And Tubing. 06:00 - 09:00 3.00 TA P COMP Pull Two Way Check Valve - Rig Up HB&R & Pump 80 Barrels Diesel Down Annulus & U-Tube Into 2 7~8" Tubing 09:00 - 10:30 1.50 TA P COMP Rig Down HB&R - Remove Second Tubing Head Valve - Install Blind Flange On Manumatic Wing Valve - Install Back Pressure Valve 10:30 - 12:00 1.50 DRILL P COMP Clear Rig Floor Of Cross Overs And Misc. Tools - Nabors Alaska Drilling Rig 22E Released From MPC-41 @ 1200 Hours On 7/12/2001 Printed: 7/23/2001 11:49:12 AM " BP' EXPLORATION Page 1 of 1 · Operations SUmmary Report' Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: COMPLETION Start: 7/16/2001 End: Contractor Name: NABORS Rig Release: 7/17/2001 Rig Name: NABORS 4ES Rig Number: · D~te .,i From "T° 'Hours ActiVitycOde 'NPT PhaSe DeScription of OPerations · . . · · , 7/15/2001 06:00 - 09:00 3.00 MOB P PRE MOVE FROM E-13A TO MPC-41. 09:00- 10:00 1.00 RIGU P PRE RAISE & SCOPE DERRICK. 10:00 - 12:30 2.50 RIGU P PRE SET AND BERM TIGER TANK. RIG UP AND TEST HARDLINES AND HCR TO TREE. LOAD PITS W/9.1 BRINE. 12:30 - 13:00 0.50 RIGU P PRE PRESSURE TEST ALL LINES TO TREE & TANK. 13:00 - 14:00 1.00 KILL P DECOMP PRE-COMPLETION MEETING. PULL BPV. 14:00 - 16:00 2.00 KILL P DECOMP CIRCULATE DIESEL FROM WELL. MONITOR RETURNS. 9.1#. 16:00 - 17:00 1.00 PULL P DECOMP ND TREE. 17:00 - 19:30 2.50 PULL P DECOMP NU BOPE. 19:30 - 20:30 1.00 PULL P DECOMP TEST BOPE STACK 250~3500 PER BP/AOGCC REQUIREMENTS. RIGHT TO WITNESS WAIVED BY AOGCC...C. SHEVE 20:30 - 21:30 1.00 PULL P DECOMP PU LUB. PULL TWC. LD LUB. 21:30 - 22:30 1.00 PULL P DECOMP MU LJ. BOLDS. PU HANGER & TBG. PU WT 36K#. BO & LD HANGER. 22:30 - 23:00 0.50 PULL P DECOMP RUN 10 JTS TBG IN HOLE. SET DOWN 10K ON RBP. LATCH UP. 23:00 - 00:00 1.00 PULL P DECOMP CIRCULATE HOLE VOL WITH 9.1# BRINE. 7/16/2001 00:00 - 00:30 0.50 REST P DECOMP MONITOR WELL. VERY SLIGHT FLOW FROM ANNULUS. TBG DEAD. 00:30 - 01:30 1.00 REST P DECOMP START POOH WI5 STDS. STOP FLOW CHECK WELL. STILL SLIGHT FLOW FROM WELL. RIH WI5 STDS. PREP TO WT UP. 01:30-04:00 2.50 REST P DECOMP W'I' UP FROM 9.1# TO 9.34¢. MONITOR WELL WELL DEAD. 04:00 - 09:00 5.00 REST P DECOMP START POOH WITH 2 7/8" TBG AND RBP. 09:00 - 11:30 2.50 P COMP OOH W/RBP. CLEAR FLOOR. RU TO RUN ESP. ATTACH CABLE & SECURE TO ESP. 11:30 - 15:30 4.00 RUNCOI~i:' COMP 2-7/8" TIH W/ESP TO 6100-FT. INSTALL LASALLE CLAMPS EVERY COLLAR. 15:30 - 18:30 3.00, RUNCOr I:) COMP CHANGE OUT REEL & SPLICE CABLE. 18:30 - 21:00 2.50 RUNCOr~I:) COMP CONTINUE TIH WELL. 231 JTS TIH. MU GLM VV/DUMMY. INSTALL LASALLE CLAMPS EVERY OTHER COLLAR. '21:00 - 21:30 0.50 RUNCO~ P COMP MU CAMCO GLM VV/DPSOV INSTALLED. MU HANGER & LJ. INSTALL PENETRATOR. ;21:30 - 23:00 1.50 RUNCOt I:) COMP SPLICE EFT CONNECTOR. TEST GOOD. 23:00 - 23:30 0.50 RUNCOr F' COMP POW= 48K. SOW= 29K. LAND HANGER, RILDS, INSTALL & TEST TWC. 23:30 - 00:00 0.50 RUNCOr P COMP ND BOPE STACK. 7/17/2001 00:00 - 01:00 1.00 BOPSUF P COMP REMOVE BOPE. 01:00 - 02:00 1.00 WHSUR P COMP INSTALL X-MASS TREE. TEST HANGER SEALS AND TREE TO 5,000 PSI. GOOD. 02:00 - 03:00 1.00 WHSUR 'P COMP RU LUBRICATOR. PULL TWC. SET BPV. FINAL ESP CHECK. GOOD. SECURE WELL. RELEASE RIG. . Printed: 7/23/2001 11:08:46 AM [MILNE POINT, ALASKA WELL TELEX TO: FROM: Well Name: Main Category: Sub Category: Operation Date: Bixby / Smith Dale DeYonge MPC-41 DRLG Freeze protect 7/17/01 Date: 17/18/01 Operational Cost: HB&R $1040.00 Diesel $ 945.00 Total $1945.00 Objective: To freeze protect Well after DRLG completion Operation: HB&R pumped 15 BBLS diesel down the tubing at 1 bpm and 65 bbls of dead crude down the IA at 1.35 bpm. Conclusion: Well bore is freeze protected Initial WHP: 100 IA: 500 OA: Final WHP: IA: OA: Diesel Used 115 bbls I Methanol Used 10 Diesel = $ 945.00 DRLG / Freeze Protect / Diesel 337243 - 9335-070-765 14-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPC-41 L2 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 10,056.52' MD 10,103.00' MD 13,850.00' MD (if applicable Please call me at 273-3545 if you have any questions or' concerns. Regards, (¢--~ William T. Allen Survey Manager Attachment(s) RECEIVED AUG DEFINITIVE Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-41 MPC-41 L2 Job No. AKZZ11092, Surveyed: 1 July, 2001 SURVEY REPORT 14 August, 2001 Your Reft API-500292301461 Surface Coordinates: 6028976.39 N, 558165.53 E (70° 29' 23.2107" N, Kelly Bushing: 45.17ft above Mean Sea Level 149°31'28.2842"W) O R I ~ ~"i' NG' S ERVi'EE'S Survey Ref: svy9921 Halliburton Company Sperry-Sun Drilling Services Survey Report for MPC-41 L2 Your Ref: AP!-500292301461 Job No. AKZZ11092, Surveyed: 1 July, 2001 Milne Point Unit Measured Depth Incl: (ft) , 10056,52 75,170 164,190 10103,00 76,740 163,190 10133,37 .., 77,780 162,550 10185,31 _ 77,720 159,420 10226,41 79,230 156,980 Sub-Sea Depth' (ft) 4166.09 4177.37 4184.07 4195.09 4~.03.31 Vertical Depth (ft) 4211.26 4222.54 4229.24 4240.26 4248.48 10273.11 81.100 150.650 4211.29 4256.46 10317.74 82.160 143.450 4217.80 4262.97 10362.64 80.730 137.960 4224.48 4269.65 10411.84 80.110 140.840 4232.67 4277.84 10454.88 79.600 140.860 4240.25 4285.42 10502,76 79,300 137,970 4249,02 4294,19 10545,54 79,480 134,660 4256,90 4302,07 10592,56 79,470 128,730 4265,49 4310,66 10639,35 79,670 124,470 4273,97 4319,14 10683,20 79,200 123,990 4282,01 4327,18 10729,34 80,990 122,170 4289,95 4335,12 10774,15 84,150 120,420 4295,74 4340,91 10822,02 86,550 115,150 4299,62 4344,79 10866,55 86,370 111,660 4302,37 4347,54 10910,97 86,310 112,610 4305,21 4350,38 10960.00 87.720 111.200 4307.76 4352.93 11002.00 88.950 107.000 4~08.98 4354.15 11051.65 88.590 103.720 4310.05 4355.22 11094.82 91.230 104.230 4310.12 4355.29 11144.88 91.850 99.280 4308.77 4353.94 11192,31 91,050 93,980 4307,57 4352,74 11237,19 92,090 91,260 4306,34 4351,51 11284,35 92,090 87,740 4304,62 4349,79 11327,47 91,050 82,150 4303,44 4348.61 11372,74 90,620 78,390 4302,78 4347,95 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 7831,83 S 2121,73 E 6021161,39 N 560348,46 E 7875,11 S 2134,39 E 6021118,22 N 560361,46 E 7903,42 S 2143,12 E 6021089,98 N 560370,40 E 7951,40 S 2159,65 E 6021042,13 N 560387,31 E 7988,78 S 2174,61E 6021004,86 N 560402,56 E 8030,05 S 2194,91 E 6020963,76 N 560423,18 E 8067,07 S 2218,91E 6020926,92 N 560447,47 E 8101,42 S 2247,01 E 6020892,79 N 560475,85 E 8138,25 S 2278,58 E 6020856,21N 560507,70 E 8171,11S 2305,33 E 6020823,57 N 560534,71E 8206.85 S 2335.95 E 6020788.06 N 560565.60 E 8237.25 S 2364.99 E 6020757.89 N 560594.88 E 8267.99 S 2399.49 E 6020727.42 N 560629.62 E 8295.42 S 2436.43 E 6020700.29 N 560666.77 E 8319.66 S 2472.07 E 6020676.32 N 560702.60 E 8344,47 S 2510,15 E 6020651,81 N 560740,87 E 8367,54 $ 2548,1.1E 6020629,03 N 560779,02 E 8389,77 S 2590,31E 6020607,14 N 560821,38 E 8407,42 S 2631,09 E 6020589,80 N 560862,30 E 8424,13 S 2672,15 E 6020573,42 N 560903,49 E 8442.39 S 2717.58 E 6020555.51N 560949.06 E 8456.13 S 2757.24 E 6020542.09 N 560988.83 E 8469.27 S 2805.10 E 6020529.32 N 561036.79 E 8479.70 S 2846.99 E 6020519.22 N 561078.76 E 8489.89 S 2895.96 E 6020509.41 N 561127.81 E 8495,36 S 2943,04 E 6020504,31N 561174,94 E 8497,41 S 2987,86 E 6020502,61 N 561219,76 E 8497,00 S 3034,97 E 6020503,39 N 561266,88 E 8493,20 S 3077,89 E 6020507,52 N 561309,76 E 8485,56 S 3122,50 E 6020515,52 N 561354,31 E Dogleg Rate (°/100ft) 3,971 3,994 5,890 6,88O 13,942 16,136 12,503 5,908 1,186 5,967 7,617 12,399 8,964 1,519 5,491 8,045 12,063 '7,833 2,139 4.064 10.416 6.644 6.228 9.962 11,297 6,486 7,459 13,181 8,359 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 1431,07 Tie On Point 1439,91 Window Point 1446,13 1458,43 1470,07 1486.69 1507.38 1532.38 1560.62 1584.40 1611,79 1638,07 1669,76 1704,16 1737,55 1773,33 1809,14 1849,23 1888,32 1927,77 1971,43 2009,75 2056,28 2097,10 2145,00 2191,43 2235,89 2282,86 2325,95 2371,05 14 August, 2001 - 13:01 Page 2 of 5 DrillQuest 2.00. 08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 L2 Your Ref: APi-5002~2301461 Job No. AKZZ11092, Surveyed: 1 July, 2001 Milne Point Unit Measured Depth (ft) Incl: Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11421.84 89.750 74.850 4302.62 4347.79 11465.94 88.220 72.130 4303.40 4348.57 11515.71 .. 87.850 69.970 4305.11 4350.28 11561.31 87.910 69.560 4306.79 4351.96 11609.26 88.400 69.060 4308.34 4353.51 11654.62 88.950 68.020 4309.39 4354.56 11702.79 89.320 67.970 4310.11 4355.28 11747.97 89.880 67,630 43,10.43 4355.60 11796.84 91.050 67,590 4310.03 4355.20 11842.57 89.260 69.330 4309.91 4355.08 11885.05 89.380 70.560 4310.41 4355.58 11930.09 87.780 71.480 4311.53 4356.70 11975.10 86.740 71.830 4313.68 4358.85 12024.89 87.420 71.940 4316.22 4361.39 12069.59 87.600 71.130 4318.16 4363.33 12111.85 87.850 70.910 4319.84 4365.01 12160.09 90.980 71.630 4320.33 4365.50 12206.34 91.850 71,010 4319.19 4364.36 12252.26 92,400 70.560 4317.48 4362.65 12297.79 90.370 -70.720 4316.38 4361.55 12346.14 90.430 70.160 4316.05 4361.22 12390.33 90.250 69.830 4~15.78 4360.95 12437.17 89.940 68.820 4315.71 4360.88 12481.46 88.340 65.660 4316.37 4361.54 12527.99 90.620 66.890 4316.79 4361.96 12571.72 91.170 67.340 4316.11 4361.28 12618.69 91.110 67.280 4315.18 4360.35 12665.12 91.480 69.110 4314.13 4359.30 12710.30 91.720 70.940 4312.87 4358.04 12762.53 91.850 71.850 4311.24 4356.41 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 8474.20 S 3170.26 E 6020527.25 N 561401.98 E 8461.67 S 3212.53 E 6020540.11N 561444.15 E 8445.51S 3259.57 E 6020556.63 N 561491.06 E 8429.75 S 3302.33 E 6020572.72N 561533.69 E 8412,82 S 3347.16 E 6020590.01N~ 561578.39 E 8396.23 S 3389.36 E 6020606.93 N 561620.47 E 8378.18 S 3434.02 E 6020625.32 N 561664.98 E 8361.11 S 3475.85 E 6020642.72 N 561706.67 E 8342.50 S 3521.03 E 6020661.69 N 561751.71 E 8325.71 $ 3563.57 E 6020678.81 N 561794.11 E 8311.15 S 3603.47 E 6020693.69 N 561833.90 E 8296.50 S 3646.04 E 6020708.66 N 561876.36 E 8282.35 S 3688.72 E 6020723.14 N 561918,92 E 8266.89 S 3735.98 E 6020738.97 N 561966.06 E 8252.75 S 3778.33 E 6020753.45 N 562008.30 E 8239.01 S 3818.26 E 6020767.50 N 562048.12 E 8223.53 S 3863.94 E 6020783.34 N 562093.68 E 8208.72 S 3907,74 E 6020798.49 N 562137,36 E 8193.62 S 3951.07 E 6020813,93 N 562180,57 E 8178.53 S 3994.01 E 6020829.35 N 562223.39 E 8162.34 S 4039.57 E 6020845.90 N 562268.83 E 8147.22 S 4081.10 E 6020861.34 N 562310.23 E 8130.69 S 4124,92 E 6020878.22 N 562353.92 E 8113,56 $ 4165.75 E 6020895.67 N 562394.62 E 8094.84 S 4208,34 E 6020914.72 N 562437.06 E 8077.83 S 4248.62 E 6020932.04 N 562477.21 E 8059.72 S 4291.95 E 6020950.49 N 562520.39 E 8042.48 S 4335.04 E 6020968.07 N 562563.35 E 8027.05 S 4377.49 E 6020983.83 N 562605.67 E 8010.40 S 4426.96 E 6021000.87 N 562655.02 E Dogleg Rate (°/lOOft) 7.424 7.076 4.401 0.908 1.460 2,593 0.775 1.450 2.396 5.459 2.909 4.097 2,438 1.383 1.855 0.788 6.658 2.310 1.547 4.472 1.165 0,851 2.256 7.996 5,567 1.625 0.181 4.020 4.084 1.759 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 2419.62 2462.82 2511.09 2555.06 2601.20 2644.69 2690.74 2733.90 2780.54 2824.37 2865.39 2909.08 2952.82 3001.25 3044.68 3085.66 3132.51 3177.43 3221.92 3266.01 3312.81 3355.49 3400.59 3442.75 3486.81 3528.43 3573.17 3617,60 3661.23 3711,97 14 August, 2001 - 13:01 Page 3 of 5 DriliQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 L2 Your Ref: API-500292301461 Job No. AKZZ11092, Surveyed: 1 July, 2001 Milne Point Unit Measured Depth Incl. (ft) 12804,39 91.970 12849,74 89.880 12896.84 .. 89,380 12945,02 90.000 12989,74 90.250 71.670 72,090 72,170 72,560 72.400 Sub-Sea Depth (ft) 4309.84 4309.11 4309.42 4309.68 4309.58 Vertical Depth (ft) 4355.01 4354.28 4354.59 4354.85 4354.75 13038.29 89.630 72.840 4309.63 4354.80 13082.96 89.880 72.580 4309.82 4354.99 13129.92 89.820 72.220 4309.94 4355.11 13175.73 90.000 71.670 4310.01 4355.18 13222.89 89.690 71.510 4310.14 4355.31 13268.31 89.940 70.650 4310.29 4355.46 13318.59 89.570 70.240 4310.50 4355.67 13363.36 89.940 70.650 4310.70 4355.87 13408.65 89.140 69.320 4311.06 4356.23 13452.72 89.450 69.130 4311.60 4356.77 13503.16 91.230 70.230 4311.30 4356.47 13543.94 89.140 71.110 4311.17 4356.34 13593.78 88.090 73.050 4312.38 4357.55 13639.02 88.460 73.020 4313.74 4358.91 13681.97 87.970 73.170 4315.07 4360.24 13734,19 87,910 73,560 4316.95 4362,12 13780.22 87.600 73.440 4~18.76 4363,93 13850.00 87,600 73,440 4321,68 4366,85 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 7997.30 S 4466.70 E 6021014.27 N 562694.65 E 7983.20 S 4509.79 E 6021028.71 N 562737.63 E 7968.75 S 4554.62 E 6021043.51N 562782.34 E 7954.15 S 4600.53 E 6021058.47 N 562828.14 E 7940.69 S 4643.18 E 6021072.26 N 562870.68 E 7926.19 S 4689.51E 6021087.13 N 562916.90 E 7912.91S 4732.16 E 6021100.74 N 562959.44 E 7898.71 S 4776.92 E 6021115.29 N 563004.09 E 7884.51S 4820.48 E 6021129.82 N 563047.53 E 7869.62 S 4865.22 E 6021145.07 N 563092.16 E 7854.89 S 4908.19 E 6021160.13 N 563135.01 E 7838.06 S 4955.57 E 6021177.33 N 563182.26 E 7823.08 S 4997.76 E 6021192.64 N 563224.33 E 7807.58 S 5040.31 E 6021208.48 N 563266.76 E 7791.95 S 5081.51E 6021224.43 N 563307.83 E 7774.43 S 5128.81E 6021242.31N 563354.99 E 7760.93 S 5167.29 E 6021256.11 N 563393.36 E 7745.60 S 5214.69 E 6021271.81 N 563440.65 E 7732.41 S 5257.94 E 6021285.34 N 563483.79 E 7719.93 S 5299.02 E 6021298.15 N 563524.77 E 7704.99 S 5349.02 E 6021313.48 N 563574.65 E 7691.92 S 5393.12 E 6021326.89 N 563618.65 E 7672.05 S 5459.95 E 6021347.28 N 563685.32 E Dogleg Rate (°/100ft) 0.517 4.701 1.075 1.520 0.664 1.566 0.807 0.777 1.263 0.740 1.972 1.098 1.234 3.427 0.825 4.148 5.561 4.425 0.821 1.193 0.755 0.722 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 3752.69 3796.85 3842.76 3889.78 3933.43 3980.85 4024.50 4070.33 4114.95 4160.83 4204.91 4253.58 4296.91 4340.65 4383.06 4431.70 4471.21 4519.77 4564.01 4606.02 4657.13 4702,20 4770,51 Projected To TD 14 August, 2001 - 13:01 Page 4 of $ DrillQuest 2.00.08.005 Sperry-SUn Drilling Services Survey Report for MPC-41 L2 Your Ref: API-500292301461 Job No. AKZZ11092, Surveyed: 1 July, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPC All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are;relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.307° (23-May-01) The Dogleg 'Severity is in Degrees per 100 feet (US). Vedical Section is from Well and cal(~ulated along an Azimuth of 85.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13850.00ft., The Bottom Hole Displacement is 9416.55ft., in the Direction of 144.562° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 10056.52 4211.26 7831.83 S 2121.73 E 10103.00 4222.54 7875.11 S 2134.39 E 13850.00 4366.85 7672.05 S 5459.95 E Comment Tie On Point Window Point Projected To TD Survey tool program for MPC-41 L2 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 13850.00 4366.85 Survey Tool Description AK-6 BP_IFR-AK (MPC-41 PB1) 14 August, 2001 - 13:01 Page 5 of 5 DrillQuest 2.00.08.005 14-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well MPC-41 L2 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 10,056.52' MD 10,103.00.' MD 13,850.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-41 MPC-41 L2 MWD Job No. AKMM10166, Surveyed: 1 July, 2001 SURVEY REPORT 14 August, 2001 Your Ref: API-500292301461 Surface Coordinates: 6028976.39 N, 558165.53 E (70° 29' 23.2107" N, Kelly Bushing: 45.17ft above Mean Sea Level 149° 31' 28.2842" W) ORiL _LING S'E FI-V I C E c: A Halliburton Company Survey Ref: svy9926 Sperry-Sun Drilling Services Survey Report for MPC-41 L2 MWD Your Ref: API-500292301461 Job No. AKMM10166, Surveyed: 1 July, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10056.52 75.170 164.810 4166.11 4211.28 10103.00 76.740 163.190 4177.39 4222.56 10133.37 77.780 162.550 4184.08 4229.25 10185.31 77.720 159.420 4195.11 4240,28 10226.41 79.230 156.980 4203.32 4248.49 10273.11 81.100 152.400 4211.30 4256.47 10317.74 82.160 144.620 4217,81 4262.98 10362.64 80.730 139.460 4224.49 4269.66 10411.84 80.110 142.230 4232.68 4277.85 10454.88 79.600 142.070 4240.26 4285.43 10502.76 79.300 139.150 4249.03 4294,20 10545.54 79.480 136.780 4256.91 4302.08 10592.56 79.470 131.070 4265.50 4310.67 10639.35 79.670 126.960 4273.98 4319.15 10683.20 79.200 126.660 4282.02 4327.19 10729.34 80.990 125.190 4289.95 4335.12 10774.15 84.150 121.830 4295.75 4340.92 10822.02 86.550 118.270 4299.63 4344.80 10866.55 86.370 114.810 4302.38 4347.55 10910.97 86.310 114.530 4305,22 4350.39 10960.00 87.720 115.690 4307.77 4352.94 11002.00 88.950 107,830 4308.99 4354.16 11051.65 88.590 102.570 4310.06 4355.23 11094.82 91.230 102.250 4310.13 4355.30 11144.88 91.850 96.970 4308.78 4353.95 11192.31 91.050 91.390 4307.58 4352.75 11237.19 92.090 88.350 4306.35 4351.52 11284.35 92.090 85.370 4304.63 4349.80 11327.47 91.050 79.820 4303.45 4348.62 11372.74 90.620 74.330 4302.79 4347.96 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 7815.94 S 2173.40 E 6021177.69 N 560400.00 E 7859.28 S 2185.83E 6021134.45 N 560412.77E 7887.59 S 2194.56 E 6021106.21 N 560421.72 E 7935.57 S 2211.09 E 6021058.36 N 560438,63 E 7972.95 S 2226.05 E 6021021.09 N 560453.87 E 8014.54 S 2245.72E 6020979.67 N 560473.87 E 8052.15 S 2268.77E 6020942.23 N 560497.21 E 8087.15 S 2296.06E 6020907.45 N 560524.78 E 8124.77S 2326.69 E 6020870.07 N 560555.71 E 8158.22S 2352.69 E 6020836,82 N 560581.96 E 8194.59 S 2382.56 E 6020800.68 N 560612.11 E 8225.82 S 2410.71 E 6020769.68 N 560640.51 E 8257.88 S 2443.99 E 6020737.88 N 560674.04 E 8286.84S 2479.74E 6020709.20 N 560710.01 E 8312.67 S 2514.25 E 6020683.64N 560744.73 E 8339.33 S 2551.06 E 6020657.27 N 560781.74 E 8363.85 S 2588.10 E 6020633.04N 560818.97 E 8387.74S 2629.39 E 6020609.48 N 560860.45 E 8407.59 S 2669.14 E 6020589.93 N 560900.36 E 8426.10 S 2709.43 E 6020571.74 N 560940.78 E 8446.87 S 2753.76 E 6020551.31N 560985.28 E 8462.42 S 2792.72E 6020536.07 N 561024.36 E 8475.43 S 2840.61 E 6020523.43 N 561072.34 E 8484.71 S 2882.76 E 6020514.49 N 561114.57 E 8493.06 S 2932.08 E 6020506.52 N 561163.96 E 8496.52 S 2979,35 E 6020503.44 N 561211.25 E 8496.42 S 3024.21E 6020503.89 N 561256.11E 8493.83S 3071.26 E 6020506.84 N 561303.14 E 8488.28 S 3113.99 E 6020512.73N 561345.82 E 8478.16 S 3158.09 E 6020523.19 N 561389.84 E Dogleg Rate (°/lOOff) 4.779 3.994 5,890 6.880 10.459 17.409 11.802 5.693 1.240 6.028 5.461 11.939 8.649 1.265 4.990 10.247 8.948 7.766 0.643 3.722 18.934 10.616 6.160 10.616 11.881 7.157 6.315 13.090 12.163 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 1483.93 Tie On Point 1492.53 Window Point 1498.76 1511.05 1522.69 1538.66 1558.34 1582,49 1609.72 1632.70 1659.29 1684.61 1714.97 1748.06 1780.19 1814.53 1849.29 1888.34 1926.22 1964.73 2007.09 2044.54 2091.11 2132.30 2180.71 2227.50 2272.19 2319.29 2362.34 2407.15 14 Augus~ 2001-13:00 Page2of$ D rillQues t 2. 00. 08. 005 Sperry-Sun Drilling Services Survey Report for MPC-41 L2 MWD Your Ref: API-500292301461 Job No. AKMM10166, Surveyed: 1 July, 2001 Milne Point Unit Measured Depth (ft) Incl. 11421.84 89.750 11465.94 88.220 11515.71 87.850 11561.31 87.910 11609.26 88.400 Azim. 73.740 69.900 67.800 67.640 67.380 Sub-Sea Depth (ft) 4302.63 4303.41 4305.12 4306.80 4308.35 Vertical Depth (fi) 4347.80 4348.58 4350.29 4351.97 4353.52 11654.62 88.950 66.640 4309.40 4354.57 11702.79 89.320 66.760 4310.12 4355.29 11747.97 89.880 66.670 4310.44 4355.61 11796.84 91.050 66.300 4310.04 4355.21 11842.57 89.260 68.930 4309.92 4355.09 11885.05 89.380 69.620 4310.42 4355.59 11930.09 87.780 70.890 4311.54 4356.71 11975.10 86.740 71.080 4313.69 4358.86 12024.89 87.420 71.120 4316.23 4361.40 12069.59 87.600 70.800 4318.17 4363.34 12111.85 87.850 70.240 4319.85 4365.02 12160.09 90.980 70,940 4320.34 4365.51 12206.34 91.850 70.270 4319.20 4364.37 12252.26 92.400 69.650 4317.49 4362.66 12297.79 90.370 70.330 4316.39 4361.56 12346.14 90.430 68.130 4316.06 4361.23 12390.33 90.250 68.320 4315.79 4360.96 12437.17 89_940 67.510 4315.72 4360.89 12481.46 88.340 64.630 4316.38 4361.55 12527.99 90.620 65.520 4316.80 4361.97 12571.72 91.170 65.860 4316.12 4361.29 12618.69 91.110 65.900 4315.19 4360.36 12665.12 91.480 67,500 4314.14 4359.31 12710.30 91.720 69.640 4312.87 4358.04 12762.53 91.850 70.410 4311.25 4356.42 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (fi) (ft) 8464.65 S 3205.30 E 6020537.07 N 561436.94 E 8450.90 S 3247.18 E 6020551.15 N 561478.71E 8432.95 $ 3293.57 E 6020569.46 N 561524.96 E 8415.68 S 3335.73 E 6020587.06N 561566.99 E 8397.35 $ 3380.01 E 6020605.74 N 561611.13 E 8379.63 S 3421.76E 6020623.78 N 561652.73 E 8360.58 S 3466.00E 6020643.17 N 561696.82 E 8342.72S 3507.50 E 6020661.36 N 561738.18 E 8323.23 S 3552.30 E 6020681.20 N 561782.83 E 8305.81 $ 3594.58 E 6020698.95 N 561824.97 E 8290.78 S 3634.31 E 6020714.29 N 561864.58 E 8275.57 S 3676.69 E 6020729.83N 561906.84 E 8260.92 S 3719.19 E 6020744.81N 561949.23 E 8244.82 S 3766.24 E 6020761.29 N 561996.14 E 8230.25 S 3808.45E 6020776.18 N 562038.24 E 8216.17 S 3848.26 E 6020790.58 N 562077.94 E 8200.14 S 3893.75E 6020806.96 N 562123.30 E 8184.78 S 3937.36 E 6020822.66 N 562166.79 E 8169.06S 3980.47 E 6020838.72 N 562209.78 E 8153.48 S 4023.24 E 6020854.62 N 562252.42 E 8136.34 S 4068.44E 6020872.12 N 562297.49 E 8119.95 S 4109.48 E 6020888.83 N 562338.40 E 8102.34 S 4152.88E 6020906.78 N 562381.66 E 8084.38 $ 4193.35 E 6020925.06 N 562421.99 E 8064.77S 4235.55 E 6020945.00 N 562464.03 E 8046.77 S 4275.39 E 6020963.31 N 562503.73 E 8027.58 S 4318.25 E 6020982.83 N 562546.44 E 8009.22 S 4360.88 E 6021001.53 N 562588.93 E 7992.72S 4402.92 E 6021018.35 N 562630.84 E 7974.89 S 4451.99 E 6021036.57 N 562679.76 E Dogleg Rate (°/100ft) 2.141 9.372 4.282 0.375 1.157 2.032 0.807 1.255 2.511 6.957 1.649 4.535 2.349 1.368 0.821 1.450 6,649 2.374 1.804 4.702 4.552 0.592 1.852 7.438 5.260 1.479 0.154 3.536 4,764 1,494 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 2455.36 2498.28 2546.05 2589.57 2635.28 2678.41 2724.13 2767.03 2813.37 2857.01 2897,89 2941.43 2985.05 3033.32 3076.65 3117.53 3164.24 3209.03 3253.34 3297.31 3343.83 3386.14 3430.91 3472.80 3516.54 3557.80 3602.17 3646.24 3689.56 3739.99 14 August, 2001 - 13:00 Page 3 of 5 DrillQuest 2. 00. 08. 005 Sperry-Sun Drilling Services Survey Report for MPC-41 L2 MWD Your Ref: API-500292301461 Job No. AKMM10166, Surveyed: 1 July, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 12804.39 91.970 70.440 4309.85 4355.02 12849.74 89.880 71.260 4309.12 4354.29 12896.84 89.380 71.540 4309.42 4354.59 12945.02 90.000 71.820 4309.69 4354.86 12989.74 90.250 71.600 4309.59 4354.76 13038.29 89.630 72.430 4309.64 4354.81 13082.96 89.880 72.650 4309.83 4355.00 13129.92 89.820 72.090 4309.95 4355.12 13175.73 90.000 71.950 4310.02 4355.19 13222.89 89.690 71.860 4310.15 4355.32 13268.31 89.940 70.310 4310.30 4355,47 13318.59 89.570 70.550 4310.51 4355.68 13363.36 89.940 70.820 4310.71 4355.88 13408.65 89.140 69.350 4311.07 4356.24 13452.72 89.450 68.760 4311.61 4356.78 13503.16 91.230 69.290 4311.31 4356.48 13543.94 89.140 70.900 4311.18 4356.35 13593.78 88.090 71.950 4312.38 4357.55 13639.02 88.460 71.880 4313.75 4358.92 13681.97 87.970 72.030 4315.08 4360.25 13734.19 87.910 72.490 4316.96 4362.13 13780.22 87.600 72.480 4318.76 4363.93 13850.00 87.600 72.480 4321.69 4366.86 Local Coordinates Global Coordinates Northlngs Eastlngs Northings Eastlngs (ft) (ft) (ft) (fi) 7960.87 S 4491.40 E 6021050.90 N 562719.07 E 7946.00S 4534.24 E 6021066.10 N 562761.78 E 7930.97 S 4578.88 E 6021081.48 N 562806.30 E 7915.83S 4624.61 E 6021096.98 N 562851.92 E 7901.79 S 4667.07 E 6021111.34 N 562894.27 E 7886.80 S 4713.25 E 6021126.69 N 562940.33 E 7873.40 S 4755.86 E 6021140.43 N 562982.83 E 7859.18 S 4800.62 E 6021155.00N 563027.47 E 7845.04 S 4844.19 E 6021169.48 N 563070.93 E 7830.39 S 4889.02 E 6021184.48 N 563115.65 E 7815.67 S 4931.98 E 6021199.54 N 563158.50 E 7798.83 S 4979.36 E 6021216.75N 563205.74 E 7784.02S 5021.61 E 6021231.89 N 563247.87 E 7768.59 S 5064.19 E 6021247.65N 563290.33 E 7752.84S 5105.34 E 6021263.72 N 563331.36 E 7734.79 S 5152.43E 6021282.14 N 563378.31 E 7720.90 S 5190.77E 6021296.33 N 563416.54 E 7705.03 S 5238.00E 6021312.57 N 563463.64 E 7690.99 S 5280.99 E 6021326.94 N 563506.52 E 7677.70 S 5321.81 E 6021340.56 N 563547.23 E 7661.80 S 5371.51 E 6021356.85 N 563596.81 E 7647.95 S 5415,37 E 6021371.03N 563640.56 E 7626.96 S 5481.86 E 6021392.54 N 563706.88 E Dogleg Rate (o/lOOft) 0.295 4.950 1.217 1.412 0.745 2.134 0.746 1.199 0.498 0.684 3.457 0.877 1.023 3.695 1.512 3.682 6.469 2.979 0.832 1.193 0.888 0.674 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 3780.48 3824.44 3870.22 3917.10 3960.63 4007.93 4051.55 4097.38 4142.01 4187.95 4232.03 4280.70 4324.08 4367.84 4410.21 4458.70 4498.10 4546.53 4590.58 4632.40 4683.30 4728.20 4796.26 Projected Survey 14 August, 2001 - 13:00 Page 4 of $ DrillQuest 2. 00.08. 005 Sperry-Sun Drilling Services Survey Report for MPC-41 L2 MWD Your Ref: API-500292301461 Job No. AKMM10166, Surveyed: 1 July, 2001 Milne POint Unit Alaska Drilling & Wells Milne Point MPC All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.307° (23-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 85.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13850.00ft., The Bottom Hole Displacement is 9392.62ft., in the Direction of 144.293° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 10056.52 4211.28 7815.94 S 2173.40 E 10103.00 4222.56 7859.28 S 2185.83 E 13850.00 4366.86 7626.96 S 5481.86 E Comment Tie On Point Window Point Projected Survey Survey tool program for MPC-41 L2 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 13850.00 4366.86 Survey Tool Description MWD Magnetic (MPC-41 PB1 MWD) 14 August, 2001 - 13:00 Page 5 of 5 DrillQuest 2. 00. 08. 005 0IL AND GAS CONSERYA ION COPl I SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage AK 99519 Re: Milne Point Unit MPC-41 L2 BP Exploration (Alaska) Inc. Permit No: 201-122 Sur Loc: 694' NSL, 2298' WEL,SEC. 10, Ti3N, R10E, UM Btmhole Loc. 3589' NSL, 2027' WEL, SEC. 23, T13N, RIOE, UM Dear Mr. Shultz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you fi.om obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until ali other required permitting determinations are made. The permit is for a new wellbore segment of existing well MPC-41 Permit No, 201-78, API No. '50-029-23014. Production should continue to be reported as a function of the original API number stated above. Annular disposal has not been requested as part of the Permit to Drill application Milne pOint Unit MPC-41L2. Blowout prevention equipment (BOPE) mUst be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, · . ount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ',Pff -/<day of June 2001. -- jjc/Enclosures cc: Department of Fish & Game, Habitat Section w/o enci. Department of Environmental Conservation w/o encl. {~"' STATE OF ALASKA ALASKA OIL',~ND GAS CONSERVATION COMMIS~...N PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test 511 Development Oil la. Type of work [][] Re-EntryDrill [][] DeepenReddll 1 b. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned KBE = 29.75' Milne Point Unit / Schrader 3. Address 6. Property Designation Bluff P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047437 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 694' NSL, 2298' WEL, SEC. 10, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 3404' NSL, 185' WEL, SEC. 22, T13N, R10E, UM MPC-41L2 Number 2S100302630-277 At total depth 9. Approximate spud date 3589' NSL, 2027' WEL, SEC. 23, T13N, R10E, UM June 24, 2001 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025516, 3252' MDI No Close Approach 2560 13939' MD /4383' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10075' Maximum Hole Angle 90 o Maximum surface 1467 psig, At total depth (TVD) 4383' / 1971 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6-1/8" 4-1/2" 12.6# L-80 IBT-Mod 3864' 10075' 4215' 13939' 4383' Uncemented Slotted Liner , , , , , 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12090 feet Plugs (measured) Bridge plugs at 11147' MD and 10520' MD true vertical 4396 feet Effective depth: measured 12090 feet Junk (measured) true vertical 4396 feet Casing Length Size Cemented MD -I-VD Structural Conductor 110' 13-3/8" 260 sx Arctic Set (Approx.) 110' 110' Surface Intermediate 11197' 7" 1456 sx Amtic Set III, 792 sx Class 'G' 11197' 4235' Production Liner RECEIVED JUN ~ 9Z001 Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission Anchorage ~0. Attachments [] Filing Fee ' ' [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program' [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: James Franks, 564-4468 Prepared By Name/Number: Sondra Stewrnan, 564-4750 21. I hereby certify that the fore ~'~r~ is true ah"d ~6~rre(~ to the best of my knowledge _ / _.. / . ' ,,Sig~d Stev~S:ultz ~ ~ Permit Number APl Number/ A p. ovall I~a.~.!. See cover letter Z o,~' - ,/2. 2_ 50-029-23014-61 (.~ ,?~//~..,// for other requirements Conditions of Approval: Samples Required [] Yes ~ No Mud L/Sg Req~red [] Yes 1~ No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required I~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Other: Approved By ~'~.~ 'laylor $~arnour~ ..., ,,., ,, ~ A i Commissioner the commission Date Form 10-401 Rev. 12-01-85 'ORiGiNAL Sui Triplicate Schrader Bluff 2001 Pro~lram MPC-41L2 Well Plan I Well Name: Type of Well (producer or injector): I MPC41 -L2 Producer (Multilateral) Surface Location: 694' FSL, 2298' FEL, Sec. 10, T13N, R10E X = 558,165.39 Y = 6,028,976.39 :~:.~..:,' .i::i:!:'~! :::::i ::: i::.~::!-~.:':'.:~i.~.~:!` : 'i~:! .ii~ii~.:';!i.: ::: . : , :.~ :.:..< : ·: MPC-41L2 CA Target 3404' FSL, 185' FEL, Sec. 22, T13N, R10E Start: X = 560353.84 Y = 6021144.17 Z = 4215' TVDrkb MPC-41L2 CA Target 3589' FSL, 2027' FEL, Sec. 23, T13N, R10E End: X = 563789 Y = 6021358 Z = 4383' TVDrkb I AFE Number: I I l Rig: I Nabors 22E I Estimated Start Date: I June 24, 2001 I I Operatin~l days to complete: I 14 I OAMD I 10075'-~13939' I I OATVDrEb(TD)I 43 3' I I OAUax. lnc, 190° I1KBE 29.75' I Well Design (conventional, slim hole, etc.): I Grassroots multi-lateral with extended horizontal I I laterals. ESP completion. Objective: Run retrievable whipstock at top of CA interval at +/- 10075' MD and drill -3900' of 6-1/8" horizontal lateral. Mill window in 7" casing. Drill horizontal lateral in CA. Run 4 Y2" slotted liner and hang off with a hookwall hanger system. Complete well with a 2 7/8" ESP completion. Version #1, 6/14/2001 1. Current Well Information Schrader Bluff 2001 Pro~lram MPC-41L2 Well Plan Well Name: APl Number: Well Type: Current Status: BHP: BHT: MPC-41L2 Development - Schrader Bluff Multilateral Producer 7" casing set and cemented 1971 psi Schader Bluff 'OA' sand. Normal pressure gradient. 80°F @ 4415' SS Estimated 2.1 Mechanical Condition 2.2 2.3 MPC-41: Nabors 22E: Conductor: Surface casing: Cellar Box MSL = 16.5' KB = 29.75' 20", 92 Ib/ft, H-40 Welded set at 110' RKB 7", 26 Ib/ft, Hydril 521 set at 11197' Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Expected reserves 2.1 MMbbl Production rate: 2043 b/d Production rate: 568 b/d Materials Needed Production Liner: 4500' 250 of 4-5/8" x 5 3,~,, x 8" 7" x 4 Y2" 4 Y2", 12.6#, L-80, IBT-Mod Slotted Liner Rigid Straight Blade Centralizers and stop rings Baker liner top hanger w/liner top packer and inner string Baker guide shoe, packoff bushing Schrader Bluff 2001 Program MPC-41L2 Well Plan 3. Drilling Hazards and Contingencies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill Type Frequency Comments D1 Tripping (1) per week, per crew Conducted only inside casing. D2 Drilling (1) per week, per crew Either in cased or open hole. DO NOT shut-in well in open hole. D3 Diverter Prior to spud, per crew Once per week per crew while drilling with diverter in place. D4 Accumulator Prior to spud or RWO Approx. every 30 days, thereafter at convenient times. D5 Well Kill Prior to drill out, Prior to drill out the intermediate and production strings. Never per crew carry out this drill when open hole sections are exposed. 3.2. 3.1.1. The 6-1/8" horizontal will be drilled with the BOP installed. MPC-41L2 is being drilled in an undrained fault block and reservoir pressure is expected to be virgin 8.65 lb/gal equivalent. The planned mud weight is 9.1 lb/gal which provides a 0.45 lb/gal overbalance (80 psi). Kick tolerance 3.2.1. The 7" casing will be set into the Schrader Bluff OB reservoir. The kick tolerance for the 6-1/8" horizontal open hole section is infinite assuming an influx at the 13939' in the Schrader OB formation. This is a worst case scenario based on a 8.65 ppg pore pressure gradient in the top of the production section and a minimum fracture gradient of 12.0 lb/gal at the 7" casing shoe with a 9.1 ppg mud in the hole. 3.3. Lost Circulation 3.3.1. Lost circulation has not been encountered while drilling this interval on previous C-Pad wells. 3.3.2. Clean hole ECD in the 6-1/8" horizontal holes is estimated to be 11.7 lb/gal. Maintain minimum ECD thru use of proper hole cleaning procedures, PWD monitoring, and control drilling. 3.3.3. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing 3.4. Unexpected Hiqh Pressures 3.4.1. It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. This well is in an undrained fault block with no off take or injection support. Reservoir pressure is expected to be 1963 psi (8.65 lb/gal). In this well, the Schrader Bluff formation will be drilled with 9.1 ppg mud. 3.5. Stuck Pipe 3.5.1. The C-41L2 directional plan has a _+3900 feet to drill for the lateral in the OA reservoir. This hole interval has massive permeable sand intervals, which can lead to differential sticking of the drill string. Good drilling practices to avoid differential sticking are required in the hole section. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. Schrader Bluff 2001 Pro~lram MPC-41L2 Well Plan 3.5.2. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.5.3. There is a risk of differentially sticking the 4 Y2" slotted liner. The 9.1 lb/gal mud will be 0.4 lb/gal overbalanced to the 8.65 lb/gal OA sand reservoir pressure. The liner should be kept moving as much as.possible while running in the open hole. In order to combat this tendency, solid stand off centralizers will be run on the liner two per joint to ensure the casing from contacting the wellbore wall and allowing the casing to become differentially stuck. 3.6. Pad Data Sheet 3.6.1. Please Read the C-Pad Data Sheet thoroughly 3.7. Hydrates 3.7.1. Hydrates have not been encountered on previous C-Pad wells and are not expected. However hydrates have been encountered on H-Pad and mud returns should be monitored to determine if hydrates are encountered on this well. 3.7.2. In the event of hydrates forming, the following procedures should be undertaken: a) Remember that hydrate gas is not a gas sand. Mud weight will hold a gas sand back. But, once the hydrate is disturbed, the gas is coming out of the hole. All that mud weight does is control how radically the gas breaks out at surface allowing you to continue drilling and getting through the section as quickly as possible. b) 2 ppb Lecithin - have in mud system prior to drilling hydrates c) 0.6% Drill & Slide - have in mud system prior to drilling hydrates d) Have mud weight at a max 9.8 MW prior to drilling into the hydrate section. Would usually cut mud weight back to normal weight (8.6 - 9.2) once we were 300-400' below the hydrate section and the gas had settled down. Note: This is applicable to the H-Pad wells. The 9.8 mud weight may vary from pad to pad depending on hydrate gas concentration. e) Weigh mud out with both pressurized and non-pressurized mud scales. The non-pressurized mud scales reflect actual mud cut weight. Drill through the hydrate section as quickly as possible, while minimizing gas belching at bell nipple. Slower pump rates may be applicable while monitoring torque and drag for potential problems. g) Minimize circulation time. This accelerates the hydrate thawing problem releasing more gas into the wellbore. h) Keep mud circulating temperature as cold as possible. Open up the bit nozzle size as much as possible. This will reduce the bit nozzle velocity (lower temperature), aid in drilling a more gauge surface, and has not adversely affected the ROP. A surface caliper log has shown gauge hole even through the permafrost by adjusting (opening up) the bit nozzles. 3.8. Breathin ,q Schrader Bluff 2001 Pro~lram MPC-41L2 Well Plan 3.8.1. No breathing problems are expected drilling the Ugnu or the Schrader Bluff formations. 3.9. ,Hydrocarbons 3.9.1. Hydrocarbons will be encountered in the Ugnu and Schrader Bluff intervals. 3.10. Geosteerinq 3.10.1. Two rig site geologists are required onsite for accurate geosteering through the thin OA sands 3.10.2. It is critical that we achieve a high percentage of 6-1/8" hole in reservoir zone drilling in the OA sand horizontal intervals in order to obtain enough pay sand to meet the oil rate production goals. 3.11. Hvdroqen Sulfide 3.11.1. MPC Pad is not designated as an H2S Pad. Schrader Bluff 2001 Program MPC-41L2 Well Plan 4. Drillin_q Program Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPC-41. · CIoseApproach Wells: None · Close Approach Issues: Well Name I Current Status Production Priority Precautions N/A I N/A N/A N/A 4.2. Well Control Expected BHP 1971 psi, 4383' TVD (estimated) 4.3. Mud Proqram Max Exp Surface Pressure 1467 psi (0.115 psi/ft gas gradient) BOPE Rating 5000 psi WP (entire stack & valves) Planned BOPE Test Pres. 2500/250 psi Rams and Valves 2000/250 psi Annular 6-1/8" Production Hole Mud Properties: OB/OAI KCL - CaCO3 Baradril N Mud Density(PPg) IFunnelvis I YP I HTHP I pH 9.1 I 40 - 55 22 - 27 < 10 8.0 - 8.5 I IAPIFiltrate ILGSolids 4 - 6 < 12 ppb 4.4. Formation Markers Formation Tops ft MD ft TVDss Pore psi EMW (ppg) Base Permafrost 1856 1785 Top Ugnu 8415 3776 1698 8.66 Top Ugnu M 9665 4097 1844 8.65 NA 10019 4188 1885 8.65 NB 10138 4219 1898 8.65 NC 10220 4240 1908 8.65 NE 10323 4266 1919 8.65 NF 10485 4308 1938 8.65 Top OA 10607 4339 1952 8.66 Base OA 10745 4372 1967 8.65 Top OB 10970 4407 1983 8.65 Base OB NA 4431 1994 8.66 4.5. Casinc~/Tubinq Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Bottom Tbg O.D. MDrrVDrkb MD/TVDrkb 6-1/8" OA 4 Y2" 12.6# L-80 IBT-Mod 3864' 10075' / 4215' 13939'/4383' 4.6. Survev and Lo_qqin~ Proqram 6-1/8" Hole Sections: I MWD / GR/Res / PWD / ABI / ABGR - (ABGR will be run if available) Cased Hole:I None Schrader Bluff 2001 Program MPC-41L2 Well Plan 5. MPC-41 L2 Operations Summary 5.1. Procedure 1. MIRU Nabors22E 2. NU 13-5/8" 5m BOP. Test BOP to 2500/250 psi 3. PU 3 Y2" drill pipe 4. Make up Baker Window Master milling assembly with retrievable whipstock and MWD 5. Install whipstock in top of liner hanger. Verify whipstock orientation with MWD 6. Shear off and mill window 7. MU BHA with 6-1/8" PDC bit, 4 3,4" MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3 Y2" drill pipe 8. RIH. Displace hole to clean Bara Drill mud 9. Drill OA horizontal lateral geosteering and short tripping as required. Maintain Bara Drill mud properties. TD criteria supplied by town 10. POOH. Reamer trip with Hole Opener TD. 11. Displace OA lateral with clean Bara Drill mud 12. MU whipstock retrieval tool and MWD. RIH. Orient and jet whipstock face 13. Engage and pull whipstock free 14. RIH with 4 Y2" slotted liner w/bent shoe joint, orient liner into window and run liner to point of hanging off with hookwall hanger 15. Displace 7" casing to 9.1 lb/gal completion fluid (brine) 16. POOH and L/D 3 W' drill pipe 17. RIH with 2 7/8" tubing to top of Ist lateral and displace well to seawater 18. Land 2 7/8" tubing, set TWC, ND BOPE and NU X-mas tree, pull TWC 19. Pump enough volume of diesel to displace the annulus and tubing down to 2000' 20. Set TWC and test. 21. Remove TWC and install BPV. Secure well 22. RDMO 2REE: FMC Horizontal 3-1/8" 5M PROPOSED COMPLETION ' WELLHEAD: FMC Horizontal l,", 5M tbg. head C-41 L1 & C-41 L2 .~. .~.v--~.~ 11" x 3-1/2", EUE (btm)~.. { Cellar Box ELEV = 16.5' FMC tbg. hanger, 'H' BPV profile I ' I J 1 1 O' J Welded13 3/8"0" 92 Ib/ft, U-40 · [ ; · I ! 2 7/8". 9.3 Ib/ft. L-80. EUE-M I Coupling OD: ~4,;5" . , , Dr~ft/ID : 2.867 /2.992" : -~~'~.Hy-~ri1521 I ~ . .... ~ ,,,,. n~ ,0+~.0, Tn 110 075'- ~A Casing Drift' 6 151" -- ~ ~' ~- .............. I ' ' Casing ID: ~.~76" ~ Lower 6-1/8" OA Lateral TD 110,505'- 14,800' ~ , I I I I I I I ~ . 4-1/2" Slotted Liner with Hook Wall Hanger(BOT) / ~, '-~ IWindowin 7"casing~ 10075' I I ', I Well Inclination ~ Window= 90 Deg I / ', ''~ / t' OA .orizon~l I ::~::~ / ..................... I Window in 7" casing ~ 10,505' I ~', "-_ I Well Inclination ~ Window = 75Degrees I ~- ....... ............... ~'~" :'~"~"~ ~/'~ '~ ~ ~ ~ ........................ .... ~ ... ~ .... ~ ... ~ .... I~ 4-1/2" Slotted Liner & Hanger ~a~mg Shoe ~ 11,197' ~ ~ __ ~ ~ We~ation ~ Shoe = 9~egrees ~ ~¢~ ~ Referenc~ ~ ~ATfi REV. BY GOMM~T8 , ~ilno ~oint Hnit WELL: C~1 ML L1 & L2 5/09/01 SMS APl NO: 6114/01 JDF Level 3 Multi-Lateral, 3-1/2" Completion BP Exploration (Alaska) I Alaska Drilling & ~s ~ ~ Milne~oint ~PC ~ ~ ~ -~ ~ ·. ~O~A ~ ~ L REPORT ~ dun,, ~00~ DRILLING SERVICES Proposal Ref: pro9871 A Halliburton Company Sperry-Sun Drilling Services Proposal Report for MPC-41 RIG - MPC-41 L2 Wp03 Milne Point Unit Measured Depth (ft) 10075.00 Incl. Azim. Sub-Sea Vertical Depth Depth (ft) (ft) 75.085 163.982 4170.84 4216.01 10100.00 75.254 162.309 4177.24 4222.41 10154.80 75.664 158.651 4191.00 4236.17 10200.00 76.045 155.645 4202.05 4247.22 10300.00 77.017 149.031 4225.36 4270.53 10371.73 77.816 10400.00 78.154 10500.00 79.440 10560.58 80.285 10600.00 80.858 10700.00 82.389 10800.00 84.013 10852.88 84.902 10900.00 85.708 11000.00 87.456 11100.00 89.233 11147.70 90.086 144.321 4241.00 4286.17 142.473 4246.89 4292.06 135.972 4266.33 4311.50 132.062 4277.00 4322.17 129.529 4283.46 43~8.~ 123.138 4298.04 116.795 4309.80 ~~ 113.456 431~~6~ lO~~=.=83 97.~ ~2~:~2 4372.89 94.~~28.00 4373.17 -- 11200.00 90.114 91.831 4327.91 4373.08 11300.00 90.165 85.831 4327.67 4372.84 11400.00 90.215 79.832 4327.33 4372.50 11500.00 90.263 73.632 4326.92 4372.09 11 539.97 90.281 71.434 4326.73 4371.90 11600.00 90.281 71.434 4326.43 4371.60 11700.00 90.281 71.434 4325.94 4371.11 11800.00 90.281 71.434 4325.45 4370.62 Local Coordinates Northings Eastlngs (ft) (ft) 7849.01 S 2126.63 E 7872.14 S 2133.63 E 7922.13 S 2151.36 E 7962.51 S 2168.38 ~ t~1031.09 N 8048.58 S 22~1_ ~ ~0945.37 N r 08ss.13N S s020791.40 N ~44.91 ~ ~375.3~E 6020750.31 N 2404.80 E 6020725.14 N 6328.89 S 2484.46 E 6020667.19 N 8378.45 S 2570.44 E 6020618.30 N 8400.80 S 2618.08 E 6020596.33 N 6418.36 S 2661.63 E 6020579.10 N 8448.11 $ 2758.86 E 6020550.10 N Global Coordinates ~. ~ _~_. leg Northings Eastln~ ~ ~, (fi) ~2112~~0360.67 E 6.505 ~1071 .~' 560378.79 E 6.505 560396.12 E 6.505 560441.93 E 6.505 Vertical Section 7600.77 7623.60 7674.46 7717.13 7813.30 8467.31 S 2864.90 E 6020531.67 N 8472.68 S 2902.29 E 6020526.67 N 560480.63 E 6.505 7883.21 560497.49 E 6.505 7910.86 560582.11 E 6.505 8008.55 580805.31 E 6.505 8067.27 560634.95 E 6.505 8105.12 560715.06 E 6.505 8199.32 560801.43 E 6.505 8289.95 560849.25 E 6.505 8,336.02 560892.93 E 6.505 6375.82 560988.39 E 6.505 8455.85 8475.78 S 2954.49 E 6020523.98 N 8473.74 S 3054.43 E 6020526.80 N 6461.27 $ 3153.60 E 6020540.05 N 8438.50 S 3250.92 E 6020563.58 N 6426.57 S 3289.07 E 6020575.80 N 8407.46 S 3345.97 E 6020595.36 N 8375.62 S 3440.77 E 6020627.94 N 6343.78 S 3535.56 E 6020660.52 N 561086.58 E 6.505 8528.99 561134.01 E 6.505 8561.18 561186.23 E 6.0(X) 8594.36 561286.14 E 6.000 8651.43 561385.22 E 6.000 8699.61 561 462.36 E 6.000 8738.36 561520.41 E 6.000 8751.1 2 561577.16 E 0.000 8769.09 561671.71 E 0.000 8799.03 561766.25 E 0.000 8828.96 Alaska Drilling & Wells MIIne Point MPC Comment KOP L2: Start Dir @ 6.50°/100ft ' 10075.00ftM D,4216.01ftTVD: TF 85 deg. Left Top NE Top NF Top OA TSBC (base OA) Dir Rate Decrease @ 6.00°/100ft : 11147.70ftM D,4373.17ftTVD Target - MPC-41 L2 Ta, Geological End Dir, Start Sail @ 90.281 o. 11 539.97ftM D,4371.90ft'l'VD 18 June, 2001 - 14:02 Page 2 of 6 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPC-41 RIG - MPC-41 1.2 Wp03 Milne Point Unit Measured (~) Incl. 11900.00 90.281 12000.00 90.281 12100.00 90.281 12200.00 90.281 12300.00 90.281 12300.07 90.281 12327.13 89.469 12400.00 89.469 12500.00 89.469 12600.00 89.469 12700.00 89.469 12800.00 89.469 12900.00 89.469 13000.00 89.469 13100.00 89.469 13200.00 89.469 13300.00 89.469 13400.00 89.469 13500.00 89.469 13600.00 89.469 13700.00 89.469 13800.00 89.469 13900.00 89.469 13939.37 89.469 13939.70 89.469 Sub-Sea Vertical Local Coordinates Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 71.434 4324.96 4370.13 8311.94 S 3630.36 E 71.434 4324.47 4369.64 8280.10 S 3725.15 E 71.434 4323.98 4369.15 8248.26 $ 3819.94 E 71.434 4323.49 4368.66 8216.42 S 3914.74 E 71.434 4323.00 4368.17 8164.58 S 4009.53 E 71.434 4323.00 4368.17 8184.55 S 40~~~0823.45 N 71.420 4323.06 4368.23 ~ S 6~0832.27 N 71.420 4323.73 4368.90 52.72~ ~ -,,04.3--E 6020856.03 N 71.420 4324.66 43~9.~ ~. ~86~_~ 4199.10 E 6020888.63 N 71.420 4325.59 ~~ ~ 4293.89 E 6020921.23 N 71.420 4327~~7~ 8025.27 S 4483.45 E 6020986.43 N _. ~ ~.~-~ -- 71.42_L~ -~.-' T ~~.~ 7993.41 S 4578.24 E 6021019.04 N 7.~aJ~Nl,.~k29 ~-~T3=~4.45 7961.55 S 4673.02 E 6021051.64 N 7~0 ~ ~75.39 7929.69 $ 4767.81 E 6021064.24 N 71.4~~1.1 5 4376.32 7897.82 S 4662.59 E 6021116.84 N 71.42~ 4332.07 4377.24 7865.96 S 4957.37 E 6021149.44 N 71.420 4,333.00 4378.17 7834.10 S 5052.16 E 6021182.05 N 71.420 4,333.93 4379.10 7802.24 S 5146.94 E 6021214.65 N 71.420 4334.85 4380.02 7770.38 S 5241.73 E 6021247.25 N Global Coordinates ~ .. ~leg Northings Eastln~ 6020758~.__7 N ~20~g.88 E O.O(X) ~o823.~562238.96 E 0.000 Vertical Section 8858.89 8888.83 8918.76 8948.70 8978.63 562239.03 E 0.000 8978.65 562264.61 E 3.000 8986.75 562333.49 E 0.000 9008.54 562428.03 E 0.000 9038.45 562522.56 E 0.000 9068.36 562617.09 E 0.000 9098.27 562711.62 E 0.000 9128.18 562806.15 E 0.0(X) 9158.09 562900.69 E 0.000 9188.00 562995.22 E 0.000 9217.91 563089.75 E 0.000 9247.82 563184.28 E 0.000 9277.73 563278.81 E 0.000 9307.64 563373.34 E 0.000 9337.55 563467.88 E 0.000 9367.47 71.420 4335.78 4380.95 7738.52 S 5336.51 E 6021279.85 N 563562.41 E 0.000 71.420 4336.71 4381.88 7706.65 S 5431.29 E 6021312.45 N 563656.94 E 0.000 71.420 4337.63 4382.80 7674.79 S 5526.08 E 6021345.06 N 563751.47 E 0.000 71.420 4,338.00 4383.17 7662.25 S 5563.39 E 6021357.89 N 563788.69 E 0.000 71.420 4338.00 4383.17 7662.14 S 5563.71 E 6021368.00 N 563789.00 E 0.003 9397.38 9427.29 9457.20 9468.97 9469.07 Alaska Drilling & Wells MIIne Point MPC Comment Begin Dir @ 3.000°/100ft: 123~7f MD, 4368.17ft TVD Target - MPC-41 L2 Tb, Geological End DIr, Start Sail @ 89.469°: 12327.13ftMD,4368.23ftTVD Total Depth: 13939.37ftMD,4383.17ftTVD 4 1/2' Liner Target - MPC-41 L2 Tc, Geological 18 June, 2001 - 14:02 Page 3 of 6 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPC-41 RIG - MPC-41 L2 Wp03 Milne Point Unit All data is in Feet (US) unless otherwise stated. Directions and coordinates am relative to True North. Ver'dcal depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.284° (18-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 144.016° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13939.70ft., The Bottom Hole Displacement is 9469.07ft., in the Direction of 144.016° (True). Commn~ Measured Depth 10075.00 11147.70 11539.97 123(X).07 12327.13 13939.37 Station Coordinates Northings (ft) 4216.01 7849.01 4373.17 8472.68~ 2~;~102.2~ E 4371.90 ~ 8~ ~ ~3~9.07 E 4368.2~ ~7_~ S -- 4035.25 E 4383.17 ~~2.25 S 5563.39 E KOP L2: Start Dir @ 6.50°/100ff: 10075.00ftMD,4216.01ftTVD: TF 85 deg. Left Dir Rate Decrease @ 6.00°/10Oft : 11147.70ftMD,4373.17ftTVD End Dir, Start Sail @ 90.281 °: 11539.97ftMD,4371.90ftTVD Begin Dir @ 3.000°/100ft: 12300.07ft MD, 4368.17ft TVD End Dir, Start Sail @ 89.469°: 12327.13f1MD,4368.23ftTVD Total Dep~h'13939.37flMD,4383.17ffTVD Alaska Drilling & Wells Milne Point MPC 18 June, 2001 - 14:02 Page 4 of 6 DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPC-41 RIG- MPC-41 L2 Wp03 Milne Point Unit Formation Tops Formation Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (fi) Deg. Deg. 3680.00 0.000 0.448 4001.00 0.000 0.448 4105.00 0.000 0.448 4135.00 0.000 0.448 4165.00 0.000 0.448 4191.00 0.000 0.448 4241.00 0.000 0.448 4277.00 0.000 4315.00 0.000 4351.00 0.000 4381.00 0.000 Casing details Profile Measured Vertical Depth Depth (ft) (ft) 8237.49 3725.17 9444.12 4046.17 9816.07 4150.17 9933.15 4180.17 10052.24 4210.17 10154.80 4236.17 10371.73 4286.17 0.448 10560.58 432~.1~ 427'~L,,a~ 8244.91 S 0.448 10852.88 _43J~__.~.~ 4315.~ 8400.80 S From ~ ~--~-- To Measured Vertical ~sured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Penetration Point Depth Northings Eastings (ft) (ft) (ft) 3680.00 6164.72 S 1~.09 E ' '~'~'~u 4001.00 7266.47 S ~~20 S Ugnu a o5.oo 4135.00 7717.2~~~~0 E Top NB 4165.00 ~ ~ 21~-q~ E Top NC 419~~ ~J~S~_ 2151.30 E 42~ ~ ~ S ~- 2251.96 S 2375.36 E 2618.08 E Casing Detail Top NE Top NF Top OA TSBC (base OA) TSBB-OB SBA5 (base OB) <Surface> <Surface> <Run-TD> <Run-TD> 4 1/2" Liner Alaska Drilling & Wells MIIrm Point MPC 18 June, 2001 - 14:02 Page 5 of 6 DrillQuest 2.00.09.001 Sperr~ Sun Drilling Ser~ ';es Proposal Data - MPC-41 RIG - MPC-41 1_2 Wp03 · .,3 ' 11539.969 392,265, 90.281 '.':. 7t.434 '..4371.90 '.~?.?, ..-1.27. 8426.57 S .8289,07.E 6.000 ' .' 0.000 0.000 270.506 8751.12 : :4Ti:'.~'. 12300.073'760.104 90,281-"71,434 4368.17':' "";'-3.73 8184.55s 4009.60E' "."0,000 ".-3.000 -0.051 0.000 8978.65 "5.'. 12327.134 27.062 89.469 .'71.420"'4368.23 0.06 8175.93S :4035.25E 3.000 0.000 0.000 180.968 8986.75 18 June, 2001 - 14:01 - 1 - DriilQuest Milne Point Unit Alaska Drilling & Wells Proposal Data for MPC-41 L2 Wp03 vMtlca] Origin: Wel Ho~onlaJ OflCn: Wel MM~en[ UMs: North RMemnce: True North vDo~i ~n ~lmu~h: Degrees per 100 feM (US)144.016° Ye~ical Seclion Deacrlpliort Well Ven'lcal Section Odgln: 0.00 N,0.00 E ~ Incl, ~ Ye~bal Noflhln9~ Eastll~ VM~ml 10075.0075.085 16:5.9824216.01 7849.01 S 2126.63 £ 7600.77 ! ! 147.70 90.086 94.969 4.37:5.1.7 8472.68 S 2902.29 E 856].18 6.$05 I ]$:59.97 90.281 71.434 4:571.90 842637 S 3289.07 E 8751.12 6.000 ]23(X).07 90.281 71.434 4368.17 8184.:5:5 S 4009.60 E 8978.65 0.000 123Z'/.1:5 89.469 71.420 4568.23 8175.93 S 40:5:5.25 E 8986.75 :5.000 13939.7089.469 71.420 4:58:5.17 7662.14 S 5:56:3.71 E 9469.07 0.000 Current Well Prop~rti~ Milne Point MPC I DrillQuest' MPC-41 L2 Wp03 Single Well Target Data for MPC-41 1.2 Wp03 Meast~emer~ Urns: fl Targe( Poln~ TVD ~ Nodhirt~e E.~qlnge Nor~hlflg~ EMllnge TM~M MPC-4I 12 Poly Eatry Point 4373.17 4328.CO f~20526.67 N~61134.01E 8472.68 S 2902.29 E Polygo~ P,o~Point A 4373.17 4328.00 602~ 15.99 N5~647.00 E 8179.56 S 2417.56 E B 4373.17 4328.00 5021495.00 N563370.00 E 7521.87 S 5145.79 E C 4373.17 4328.00 6021453.99 N563856.99 E 7566.69 S 5632.45 E 4373.17 452:8.006021138.00 N5~3959.99 E 7883.47 S 5732.97 E 4373.17 4328.00 6020113.00 N5(~Y27.00 E 8884.72 S 2~92.0~ E F 4373.17 4328.00 fff20~ 15.99 N 5~0647.00 E 8179.56S 2417.56 E MPC-41 L2Ta F, ntry Point 4373.17 4328.~0 fi020526.67 N 5~1134.01 E 8472.68 S 2902,29 E Point MPC41 L2Tb F,m-y Po~ m 4368.17 4323.00 6020~23.45 N562239.03 E 8184.$5 S 4009.60 E Point MPC-41 L2Tc EntryPo~nt 4383.17 4338.00 6021358.00N 563789.00 E 7662.14 S 5563.71 E Point Well: MPC-41 RIG Horizontal Coordinates: Ref. Global Coo~inates: 6028976.39 N, 558165.53 E Ref. Structure Reference: 1627.79 N, 120.23 E Ref. Geographical Coordinates: 70° 29' 23.2107' N, 149° 31' 28.2842' W RKB Elevation: 45.17/t ab(we Mean Sea Level 45.171t above Structure Reference North Reference: True North Units: Feet (US) KOP L2:5~1 D~ 0 6.50*/1{X)fl : 10075.0~lMD,4216.0ffiTVO: Ti= 85 deg. Left Draft Copy Only To~nl Depth: :' 41/2' Lin~ 3IPC-41 1.2 Tc /'~, 4585.17 73'11. 7662.14 5. $St~J.71 E ~1~ ,,,,,,,?1~ /, ~ / 3tPC-4I L2 Ta 4373.17 TVD, 8472.68 S. 2902.29 E · , '~'~ :~ .., ~ MPC-41 Pol)' I I I 2000 2500 3000 Scale: linch = 50Oft DrEOuest 2.00.09.001 MPC-41 1,29 Tb 4368.17 7't7), 81,g4.55 S. 4(KBJ. 6tl E Begin D~' 0 3.000'/100fl : End Dir, S~art Sai O I 3500 I Eastin,qs I 4500 I 500o MPA-OI 3 I 5500 I 600O Reference is True North Milne Point Unit Alaska Drilling & Wells Milne Point MPCJ DriHQuest' MPC-41 L2 Wp03~ Proposal Data for MPC-41 L2 Wp03 Ver'~.,al O~'lgin:W®l ~O~&: ftWel Noelh Refereree: True Norlh vD~~~: Degrees per100 feet (U$)144.016° Ver~cal Seclion Desc~Wel Vertical Section Odgin: 0.00 N,0.00 E Measured Incl. Azlm. Verlical Norlfllng$ Ea~flng~ Vertical Dog~g Rate 10075.00 75.085 163.982 4216.01 7849.01 S 2126.63 E 7600.77 11147.70 gO.086 94.9~ 4373.17 847Z68 S 2~T2.29 E 8561.18 6.505 ]3939.70 89.469 7L420 43~3.17 7(~_14 s 5563.?] E 9469.o7 o.mo Draft Copy Only Single Well Target Data for lI~!~C-41 L2 Wp03 Meas~rernest Units: ft Tmgst Pok~ TVD TI/Dss NorUgng~ E~I~ No~ F~ T.n~st Type A~PY A~PX MPC-4112 Poly En,~ Poim 43?3.17 4328.00 6020526-67 N 5611~.01 £ ~72.68 S 2902.29 E Po~go, BO~ Poim A 4373.17 4328.00 6020~15.99 N 50)647.00 E 8179.5~ S 2417~6 E 13 4373.17 4328.00 6021495.00 N 563370.00 E 7521,87 S 5145.79 E C 4373.17 4328.00 6021453.99 N 563856.99 E 75~6,69 S 5632.45 E D 4373.17 4328.00 6021138.00 N 563959.99 E 7883.47 S 5732.97 E E 4373.17 4328J30 6020113.00 N 560927.00 E 8884.72 S 2692.06 E F 4373.17 4328.00 6020815.99 N 560647.00 E 8179.56 S 2417.56 E MPC-41 I-2 Ta rmtt7 Point 4373.17 4328.00 6020526.67 N 561134,01 E 8472.68 S 2902.29 E Potm IVlPC-41 L2 Tb Eno7 Point4368.17 4323.00 6020~Z3.45 N 562239.03 E 8184.55 S 4009.60 E Potnl MPC-41 L2 Tc Enlry Point 4383.17 4338.00 6021358.00 N 563789.00 E 7662.14 S 5563,71 E Potn~ Current Well Properties Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref, Geographical Coordinates: RKB Elevation: North Reference: Units: MPC-41 6028976.39 N, 558165.53 E 1627.79 N, 120.23 E 70° 29' 23.2107' N, 149° 31' 28.2842' W 45.17ft above Mean Sea Level 45.17ff above Structure Reference True North Feet (US) . / / / /' / / o '. ,,~. ,,. ~_' _.;~, ..... ~,~ ~:~ ~- .~,~.~,~ - ~ ~ '-' ........... _ ...... -::~r~. 1 ~¢ _. ,~ .~ o~' ~' ~' .... ..... ~ ......... ~ ~ ~' ..* ~. ~- ~ ......,.. ,.-, ,, ,, - - ~C-~;;.~. ~ .... ==-- -- --~~ ~'~"~ _ = -.~- ~,:~.,~ -- - M~i ~W~~ ............ :tIPC-41 L~ Ta MPC-41 12 Tb 4~3 17 TI~ 8184 ~ ~ 4009 60 ~ 17 ~ 847~ ~8 S 2902 ~9 E . . ; , ..'5., ' ~ MPC.41 I.. Tc 4383.17 TIED. 7~2.14 S, 55~3.71 E I I I I I I I I I 7500 7800 8100 8400 8700 9000 9300 9600 9900 ScaJe: linch = 300ff Vertical Section Sec-tim Azimuth: 144.016° (True North) DrillQuest 2.00.09.001 Sperry-Sun Drilling Services Proposal Report for MPC-41 RIG- MPC-41 L2 Wp03 Milne Point Unit Targets associated with this wellpath Target Name MPC-41 L2 Pohj MPC-41 L2 Ta MPC-41 L2 Tb MPC-41 L2 Tc Target E tea ~73.17 ~ 8472.68 S ~68.17 S184,55 S ~.17 7662.14 S Alaska Drilling & Wells MIIne Point MPC Target Target Shape Type 2902.29 E Polygon Geological 2902.29 E Point Geological 4009.60 E Point GeologicaJ 5563.71 E Point Geological 18 June, 2001 - 14:02 Page 6 of 6 DrillQuest 2.00.09.001 WELL DETAILS Name +N/-S +Et.W Nom'~g East~g LatitudeLongitude Slot PImMPC=41 1627.948 120.212 602~976.390 $58165_530 70=2ef23.211N 149~31'28.2~AW Ihl/A ANTI-COLLISION lmerpolalion Method:MD lnten, ak 25.000 Depth RangeFtom: 10075.000 To: 13939.935 Maximum Range: 1616.732 Reference: Plan: MPC-41 L2 Wp03 --160 --150 --125 --75 33 -5O --25 --0 -25 -5O -75 -100 COMP.ANY I~..TAILSI SURVEY PROGRAM "'~° I~hFm Depth To Sun. ey/P'nn Tool Caleeinlio,~Med~d: I~m'in',nmCa~,~m~e [10075.1~0 I.'19.t9,941 Phtmed:Ml~-41L2WpO3Vl MWD+IFR+MS E,ma¢ Syslem: ISCWSA I Scan Me~od: Tret Cylnd~ l"4o~tb From Colour To MD 0 9500 9500 10000 10000 11000 11000 12000 12000 13000 13000 14000 14000 15000 15000 16000 --125 .,~' 21' 50 -150 --160 ~! }' ~ ~: Tr~lfing ~lind~imut~<~~)~de~}V; Cent~ to C&~-'~&afi:on [50~ 90 WELl.PATH MPC41 L2 Aagl~ 144.015' 0,0I~I3FT~I~.IEO 0.(g0 Pisa h~C-41 (P'aa MPC-41), NO,E.a~ORS MPC-Il I.2 WiMB Plaa: Ml~41 I-2 Wp03 (Plan MPC41/MIE41 Clmled BF. Dnae K Vaalm Dale: O6t 1~2001 Chaired: Dae: ~: Dale: _ SECTION DE'fAlLS Sec MD lee Ati TVD +Nt-S+E/-WDL~ TFac¢ VSe~Tatg~ I 10075.000 75.080 163.970 4215.022 -7849353 2127.185 0.000.1]00 7f~01.733 11147.474 90.1~0 95.(~0 4,:1T3.1~4 -84'/33OI 29023646fro 275,~63 8561.964 3 115.10~q58 90.294 71.417 437'2.1163 -gt/27344 3290.138 6XD-89.2~6 8T52_M5 123~O. 1.~ 90.294 '/IAI'/ &'168.1'~ -8185.276 d010.12l 0.~00.000 89'/9.518 MPC-41L~Tb 12.127.644 89.469 '/I.419 436~27 -817~.516 4036,1T/ 3.00 179a~2 8~7.740 6 13939.941 89.469 71.419 43~3.170 -7662,791 5564.366 0.OD0.000 9469.9~0 M~C-41 L2 Tc Sperry-Sun Anficollision Report ~d'ereoce WeB: Plan MPC.,41 ' ' ' Retereace Welll~h:' MPC-41 L2 '.' .,, . ~l{r~:' 0~*/1~1n '''i '[~lae: 14:09:31 Page: . , . ,"' .,,:, Db: Oracle NO GLOBAL SCAN: Usiag user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Medaxl: MD Interval: 25.000 fl Error Modal: ISCWSA Ellipse Depth Range: 10075.030 to 13939.935 ft Scan Method: Tray Cylinder North Maximum Radius: 1616.732 ft Error Surface: Ellipse+Casing Survey Program for Definitive Wellpath Date: 06/14/2001 Validated: No Version: 3 Planned From To Survey Toolcode Tool Name ft ft 227.140 10073.670 MPC-41 RigMWD (0) MWD+IFR+MS MWD + IFR + Multi Station - Used in Preference 10075.000 13939.940 Planned: MPC-41 L2 Wp03 V1 MWD+IFR+MS MWD + IFR + Multi Station Casiag Points 14212.427 0.030 5.500 6.030 Case,?. Summary Site M Pt A Pad MPA-01 M Pt A Pad MPA-02A M Pt A Pad MPA-02 M Pt A Pad MPA-02 M Pt A Pad MPA-03 M Pt B Pad MPB-25 M Pt C Pad Plan MPC-41 M Pt C Pad Plan MPC-41 M Pt E Pad MPE-03 MPA-01 Vl MPA-02A Vl MPA-02 Vl MPA-02A V2 MPA-03 Vl MPB-25 Vl 13795.714 4375.000 396.439 108.343 288.040 Pass: Major Risk Out of range Out of range 13888.476 3714.170 1350.863 171.209 1226.263 Pass: Major Risk 13103.812 4650.000 231.635 194.176 37.386 Pass: Major Risk Out of range Plan MPC-41 Vll Plan: 10099.995 10100.000 0.298 299.889 -295.852 FAIL: Major Risk Plan MPC-41L1 V10 Plard0269.483 10300.000 18.365 323.565 -297.546 FAIL: Major Risk MPE-03 Vl Out of range Site: M Pt A Pad Well: MPA-01 Rule Assigned: Major Risk Wellpoth: MPA-01 V1 Inter-Site Error: 0.000 ft Reference. ~"". ::: ';' ,"Offset',.. ,'.,:::'..~'.. Se',. ,MtOOr'!' ".." =' .'.'::., '::'..': ".::.?i?:,:;':~"::' '::' AIIOwable:'~' ':':::' :: ;:' '. :":' '~.'' =''' MD · "TVD'. .... MD" .,TVD' . ".R~:,.' ,..Offset:' '..~AZI"TFO;HS: '.~':"':'.:"l~stum~,"" .AFea ' ' De~ation". ". warulng' .' .' ft · :. fi. '" .ft '."'. fi, i:.': ',' ",'ft :. ,:.' '.:, .:.:,.'.:.ft'..: .... :.~... '..: ..:..'~,' .' :... in ':'.':' '.. :ii.. :.":,....fl'"":" "' :'It ::' ' '..'n · ........ ' "'.. 13755.904 4381.523 2825.000 2824.929 19.844 1.515 85.666 14.246 13756.474 4381.528 2850.000 2849.926 19.847 1.524 85.889 14.469 13757.036 4381.533 2875.000 2874.924 19.851 1.533 86.119 14.699 13757.589 4381.539 2900.000 2899.922 19.854 1.541 86.355 14.935 13758.138 4381.544 2925.000 2924.920 19.857 1.518 86.598 15.178 1606.051 102.631 1527.618 Pass 1581.842 102.718 1503.312 Pass 1557.651 102.755 1479.023 Pass 1533.481 102.792 1454.752 Pass 1509.334 102.732 1430.511 Pass 13758.695 4381.549 2950.000 2949.918 19.861 1.489 86.848 15.428 13759.259 4381.554 2975.000 2974.915 19.864 1.459 87.106 15.686 13759.830 4381.559 3000.000 2999.913 19.867 1.428 87.373 15.953 3760.401 4381.565 3025.000 3024.911 19.871 1.420 87.648 16.228 3760.960 4381.570 3050.000 3049.908 19.874 1.415 87.931 16.511 1485.212 102.655 1406.296 Pass 1461.117 102.575 1382.104 Pass 1437.050 102.494 1357.939 Pass 1413.010 102.479 1333.789 Pass 1388.993 102.474 1309.657 Pass 3761.506 4381.575 3075.000 3074.905 19.877 1.410 88.222 16.802 3762.040 4381.580 3100.000 3099.903 19.880 1.404 88.522 17.102 3762.579 4381.585 3125.000 3124.900 19.884 1.422 88.833 17.413 3763.154 4381.590 3150.000 3149.897 19.887 1.444 89.157 17.737 3763.766 4381.596 3175.000 3174.894 19.891 1.465 89.494 18.074 1365.000 102.469 1285.545 Pass 1341.032 102.464 1261.456 Pass 1317.099 102.528 1237.386 Pass 1293.217 102.603 1213.360 Pass 1269.390 102.679 1189.384 Pass 3764.415 4381.602 3200.000 3199.890 19.895 1.486 89.846 18.426 3765.097 4381.608 3225.000 3224.886 19.899 1.567 90.213 18.793 3765.806 4381.615 3250.000 3249.881 19.903 1.6,53 90.595 19.175 3766.542 4381.621 3275.000 3274.876 19.907 1.734 90.994 19.574 13767.305 4381.628 3300.000 3299.870 19.912 1.812 91.411 19.991 1245.622 102.754 1165.458 Pass 1221.913 103.007 1141.558 Pass 11 98.265 103.278 1117.693 Pass 1174.680 103.537 1093.851 Pass 1151.164 103.785 1070.065 Pass 13768.086 4381.636 3325.000 3324.864 19.916 1.889 91.845 20.425 13768.868 4381.643 3350.000 3349.858 19.921 1.964 92.299 20.879 13769.651 4381.650 3375.000 3374.852 19.926 2.035 92.774 21.354 1127.719 104.031 1046.335 Pass 1104.347 104.268 1022.666 Pass 1081.054 104.497 999.062 Pass I DATE CHECK NO. H 191146 IO~,/o4,'o~ oo~~I VENDOR ~LA~I~AO I LA OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET PYMT {OMMENTS: PERP!IT TO DRILL FEE HANDL~NO INST: S/H - TERRIE HUBBLE X4628 IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. I (el ~I,11 ] 100_ O0 100. O0 BP EXPLORATION, (ALASKA)INC. FIRST NATIONAL BANK OF ASHLAND No. H 1.9..1.'.i..'46 co.~o~,o^~o co~,~,c ~ ~:o~; PAY TO Th e DRDER O~ RO. BOX 196612 ANCHORAGE, ALASKA 99519-6612 AN AI-HLIAII: 01- ~.:'.?..,~,,~.. C.'~, ~:%.,,, .... ,~'.", :". ?,% i ,":,' ..;.; '" ..., 56-389 412 O01C~I ,:':.. :!::!::,~ATE::~.:.?: TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 STANDARD LETTER "CLUE" DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL CHECK WHAT APPLIES ADD-ONS (OPTIONS') MULTI LATERAL 1 The permit is for a new wellbore segment of existing well (If apl number last two (2) Production should continue to be reported as a function of digits are between 60-69) PILOT HOLE (PH) ANNULAR D)SPOSAL ( ~/)NO , the original API number stated above. In accordance with 20 AAC 25.005(0, ali records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus Pig) and APl number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested... INJECTION WELL REDRILL ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... ( ) YES + Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ,(Company Name) will assume the liability of any protest to the spacing exception that may occur. SPACING EXCEPTION Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY .~ ~,~ WELL NAME~'/,~'-- ~/Z,,2_. PROGRAM: exp FIELD & POOL 5 2...5' / ~-/~ INIT CLASS I ADMINISTRATION 1. Permit fee attached ....................... dev ~ redrll serv , G~L AREA ~? ~ .. UNIT# · .. .PR _DATE 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............. ·.. 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit canbe issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 27. 28. 29. Conductor stdng provided ......... .......... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... I, !GEOLOGY 30. 32. ANNULAR DISPOSAL35. APPR DATE CMT vol adequate to.tie-in long string to surf csg .... .... CMT will cover all known productive hodzons ..... ' ..... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ....... ; ...... If diverter required, does it meet regulations .......... Drilling .fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ............ BOPE press rating appropriate; test to Choke manifold complieS w/APl RP-53 (May 84) ........ wellbore sag ? ...ann. disposal para req o//..~.?_._~' ON/OFF SHORE ,,--~ Work will occur without operation shutdown ........... · Is presence of H2S gas probable ................. Y permit can be issued wlo hydrogen sulfide measures ...... Y N ,,,/.. Data presented on potential overpressure zones ....... Y Seismic analysis of shallow gas zones ............. Y//N Seabed condition survey (if off-shore) ............. ' ~ N ' · Contact name/phone for weekly progress reports [exploratoryo~ry] Y N With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; ~ ' (C) will not impair mechanical integrity of the well used for diSposal; Y' N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLQGY: ENGINEERING: ~ UlClAnnular COMMIS, SJON: . ' ' .... ~~'/----' ~I~_',,,L" WlV~t'"'--~ ~ '~'~S ~"/ Comments/Instructions: TEIVi~.Z~,.",~,~/7 q;/, ¢ JMH .,,.~ .~,. ~-J:i _..,,.,,,~.--.,..~ -~ | . . ....... . .. ...... IO ,Z O Z -.I '-r' c:lmsoffice\wordian~iana\checklist (rev. 11101H00) 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 APPENDIXi .. No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Sat Nov 24 11:59:28 2001 Reel Header Service name ............. LISTPE Date ..................... 01/11/24 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 ..................... 01/11/24 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 Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-10166 R. FRENCH J. PYRON MPC-41 L2 500292301461 B.P. Exploration (Alaska), Inc Sperry Sun 24-NOV-01 MWD RUN 2 AK-MM-10166 D. LABRECQUE J. PYRON MWD RUN 3 AK-MM-10166 D. LABRECQUE J. PYRON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 10 AK-MM-10166 T. GALVIN J. PYRON 10 13N 10E 694 2298 RECEIVED DEC 2 8 2001 Ar~c~r89e ELEVATION (FT FROM MSL 0 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD OPEN HOLE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 0.00 45.17 16.50 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (ET) 20.000 110.0 9.875 7.000 8550.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - 3, AND 10 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. MWD RUN 9 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). THIS RUN WAS USED TO SET THE WHIPSTOCK AND MILL AND IS NOT PRESENTED. 4. THE GAP IN SROP FROM 8550' MD, 3810' TVD TO 8562' MD, 3813' TVD IS DUE TO PERFORMING OPEN HOLE SIDETRACK. 5. THE GAP IN SROP FROM 10091' MD, 4220' TVD TO 10119' MD, 4226' TVD IS DUE TO MILLING RUN. 6. MPC-4L2 IS TIED INTO MPC-41PB1 AT THE KICK OFF POINT. MPC-41L2 IS TIED INTO MPC-41 AT THE KICK OFF POINT. MPC-41L2 KICKS OFF FROM MPC-41PB1 AT 8550' MD, 3810' TVD. MPC-41L2 KICKS OFF FROM MPC-41 AT 10091' MD, 4220' TVD (TOP OF WHIPSTOCK). DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHNOOR OF BP EXPLORATION ALASKA, INC. DATED 9/7/01. MWD DATA CONSIDERED PDC. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 3, AND 10 REPRESENT WELL MPC-41L2 WITH API % 50-029-23014-61. THIS WELL REACHED A TOTAL DEPTH OF 13850' MD, 4367' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ START DEPTH 75.0 100 0 100 0 100 0 100 0 100 0 120 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: STOP DEPTH 13795 0 13802 0 13802 0 13802 0 13802 0 13802 0 13848 5 EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet BIT RUN NO MERGE TOP MERGE BASE 1 75.0 6046.5 2 6047.0 8550.0 3 8550.5 10091.0 10 10091.5 13848.5 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD FT/H 4 1 68 MWD API 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit DEPT FT ROP MWD FT/H GR MWD AP1 RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HR Min 75 2.12 12 54 0 09 0 06 0 06 0 04 0 09 Max 13848.5 1340.62 137.03 2000 2000 2000 2000 32.36 First Mean Nsam Reading 6961.75 27548 75 227.944 27380 120 69.3894 27441 75 17.4752 27405 100 20.3001 27405 100 21.9922 27405 100 38.6461 27405 100 0.760771 27405 100 Last Reading 13848.5 13848.5 13795 13802 13802 13802 13802 13802 First Reading For Entire File .......... 75 Last Reading For Entire File ........... 13848.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/24 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 ....... 01/11/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPX RPS RPM RPD FET ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 75 0 100 0 100 0 100 0 100 0 100 0 120 0 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 5999 5 5992 0 5992 0 5992 0 5992 0 5992 0 6046 5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 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: 31-MAY-01 Insite 4.05.5 66.16 Memory 6047.0 .0 76.4 TOOL NUMBER PB02038HWBRG6 PB02038HWBRG6 9.875 Spud Mud 8.40 117.0 9.8 45O 9.8 4.500 4.288 7.000 4.500 72.0 75.9 72.0 72.0 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 RPX MWD010 OHMM 4 1 68 RPS MWD010 OHMM 4 1 68 RPM MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API RPX MWD010 OHMM RPS MWD010 OHMM RPM MWD010 OHMM RPD MWD010 OHMM FET MWD010 HR Min 75 4.86 12 54 0 09 0 06 0 O6 0 O4 0 09 Max 6046.5 1014.02 116.89 2000 2000 2000 2000 6.18 Mean Nsam 3060.75 11944 278.708 11854 61.3222 11850 29.7697 11785 33.9932 11785 36.2936 11785 74.704 11785 0.525262 11785 First Reading 75 120 75 100 100 100 100 100 Last Reading 6046.5 6046.5 5999.5 5992 5992 5992 5992 5992 First Reading For Entire File .......... 75 Last Reading For Entire File ........... 6046.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/24 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 ....... 01/11/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 5992 5 8550 0 FET 5992 5 8550 0 RPD 5992 5 8550 0 RPX 5992 5 8550 0 RPM 5992 5 8550 0 GR 6000 0 8550 0 ROP 6047 0 8550 0 $ LOG HEADER DATA DATE LOGGED: 02-JUN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.5 DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8550.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 73.8 MAXIMUM ANGLE: 77.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02044HWBRGF6 EWR4 ELECTROMAG. RESIS. 4 PB02044HWBRGF6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 8550.0 BOREHOLE CONDITIONS MUD TYPE: Spud Mud MUD DENSITY (LB/G): 9.30 MUD VISCOSITY (S): 73.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.200 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.074 91.3 MUD FILTRATE AT MT: 6.100 65.0 MUD CAKE AT MT: 3.200 65.0 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 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 HR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HR Min 5992.5 21.29 23.2 1.68 1.64 1.67 1.79 0.14 Max 8550 570.52 112 58 17 51 18 08 18 81 19 74 16 06 Mean Nsam 7271.25 5116 241.332 5007 67.9326 5101 5.34458 5116 5.36745 5116 5.55919 5116 5.74475 5116 0.924685 5116 First Reading 5992.5 6047 6000 5992.5 5992.5 5992.5 5992.5 5992.5 Last Reading 8550 8550 8550 8550 8550 8550 8550 8550 First Reading For Entire File .......... 5992.5 Last Reading For Entire File ........... 8550 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/24 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 ....... 01/11/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET GR RPX RPS RPD RPM ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 8550.5 8550 5 8550 5 8550 5 8550 5 8550 5 8562 0 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 DGR DUAL GAMMA RAY EWR4 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) STOP DEPTH 10091 0 10091 0 10091 0 10091 0 10091 0 10091 0 10091 0 04-JUN-01 Insite 4.05.5 66.16 Memory 10091.0 70.3 86.9 TOOL NUMBER PB02044HWBRGF6 PB02044HWBRGF6 9.875 10091.0 LSND 9.20 65.0 8.6 3OO 5.5 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HR 4 1 68 3.600 2.842 5.000 4.200 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 72.0 93.0 72.0 72.0 Name Service Unit Min DEPT FT 8550.5 ROP MWD030 FT/H 2.12 GR MWD030 API 26.4 RPX MWD030 OHMM 1.18 RPS MWD030 OHMM 1.14 RPM MWD030 OHMM 1.13 RPD MWD030 OHMM 1.27 FET MWD030 HR 0.13 Max 10091 845.09 120 56 18 79 29 79 98 68 79 45 32 36 Mean Nsam 9320.75 3082 245.608 3059 66.7543 3082 3.69405 3082 3.85981 3082 4.41921 3082 4.43928 3082 0.985665 3082 First Reading 8550.5 8562 8550.5 8550.5 8550.5 8550.5 8550.5 8550.5 Last Reading 10091 10091 10091 10091 10091 10091 10091 10091 First Reading For Entire File .......... 8550.5 Last Reading For Entire File ........... 10091 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/24 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 ....... 01/11/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX GR FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 10091.5 10091 5 10091 5 10091 5 10091 5 10091 5 10119 0 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: 13795 13802 13848 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS STOP DEPTH 13802 0 13802 0 13802 0 13802 0 0 0 5 01-JUL-01 Insite 4.05.5 66.16 Memory 13850.0 77.7 92.4 TOOL NUMBER PB02035HAGR4 PB02035HAGR4 6.125 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Baradril-N 9.10 52.0 8.3 26000 4.2 .200 .141 .150 .400 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD100 FT/H 4 1 68 GR MWD100 API 4 1 68 RPX MWD100 OHMM 4 1 68 RPS MWD100 OHMM 4 1 68 RPM MWD100 OHMM 4 1 68 RPD MWD100 OHMM 4 1 68 FET MWD100 HR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 70.0 102.0 7O.O 70.0 Name Service Unit Min Max DEPT FT 10091.5 13848.5 ROP MWD100 FT/H 5.78 1340.62 GR MWD100 API 45.23 137.03 RPX MWD100 OHMM 0.3 55.19 RPS MWD100 OHMM 0.64 2000 RPM MWD100 OHMM 3 2000 RPD MWD100 OHMM 3.44 2000 FET MWD100 HR 0.2 5.43 Mean 11970 131.049 84.3933 12.038 15.6775 17.9082 18.2751 0.928348 Nsam 7515 7460 7408 7422 7422 7422 7422 7422 First Reading 10091.5 10119 10091.5 10091.5 10091.5 10091.5 10091.5 10091.5 Last Reading 13848.5 13848.5 13795 13802 13802 13802 13802 13802 First Reading For Entire File .......... 10091.5 Last Reading For Entire File ........... 13848.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/11/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 01/11/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
