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Home My WebLink About201-079STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned H]t*suspendedl 1b. Well Class: 20MC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: Service ❑✓ - Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number/ Sundry: 1/12/2019 201-0791318-441 Hilcorp Alaska, LLC Abend.: 3. Address: 7. Date Spudded: 15. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage AK, 99503 6/16/2001 50-029-23014-60-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: Surface: Milne Pt Unit C-41 L1 694' FSL, 2297' FEL, Sec 10, T13N, R10E, UM, AK 6/21/2001 Top of Productive Interval: 9. Ref Elevations: KB: 45.17 17. Field / Pool(s): 2225' FNL, 72' FEL, Sec 22, T13N, R10E, UM, AK GL: 16.50 BF: Milne Pt Unitt Schrader Bluff Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 493' FNL, 925' FWL, Sec 26, T13N, R10E, UM, AK ADL0025516, ADL0025518, ADL0047434 9,825MD/4,152TVD &ADL0047437 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 14,148MD/ 4,339TVD N/A TPI: x- 560469.6311 y- 6020795.412 Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 561500.8531 y- 6017256.531 Zone -4 N/A 1,800 (Approx.)/ 1,721 (Approx.) 5. Directional or Inclination Survey: Yes U (attached) No Q 13. Water Depth, if Offshore: 21. Re-drill/Lateral Tnn Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 10;505 -MID 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 if necessary RECEIVED FEB 2 7 2019 23. CASING, LINER AND CEMENTING RECORD AMOUNT WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD RIC CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEM RBi.d PULLED 13-318/20 94#/ 54.5# H -40/J-55 Surface 110' Surface 110' 30" 260sx Arctic Set (Approx.) 7" 264 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" 12.6 L-80 13,954' 14,141' 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 (MD1TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/rVD) Size and Number; Date Perfd): Q� 4-1/2" 9,963' 9,854'MD/ 4,160'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE 177, / Was hydraulic fracturing used during completion? Yes ❑ No VE: iFIE D L (r- Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED 9,825'to 10,450' 187bbls of 16ppg, 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 __0 Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate Form 10-407 Revised 512017 CONTINUED ON PAGE 2 RBDMS 0 FEB Z 8 2013 mif ORIGINIAL o>n 6- 28. CORE DATA Conventional Core(s): Yes ❑ No Q Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cored (MDITVD, Fromlro), 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 --;Ptd 10,501' 4,322' Attach separate pages to this form, if needed, and submit detailed test Top Schrader OA 12,176' 4,339' information, including reports, per 20 AAC 25.071. Base OA / TSBC 12,820' 4,367' Base OA / TSBC 13,015' 4,363' Top Schrader OB 13,970' 4,340' 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. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Chad Helgeson Contact Name: Taylor Wellman "r't-✓ Authorized Title: Operations Manager Contact Email: twellman hIICOr .COm Authorized Contact Phone: 777-8449 Signature: C 6cl HelyS, Date: 2/26/2019 INSTRUCTIONS Gener 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 10404 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 1b: 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 8 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: 410", 5M Vkellhead:11" x4 1/2 "TCII T&B- Hnr. w/ 41/2" Type'H' BPV prone 13 3/8" 72 ppf, L-80 Casing 110' Tam port collar @ 1045' 7" 26 pp: L -BC, etre. production -swop ( drift ID o 6.161', cap, a C.0090 Fpr) 4.512.00 L4s0 TC- It Irbng (ID= 3.850', cap =.0152 BPF ) Rop ® ECC' Max eugtore An81r 76" ® 08(0'-1(,(60 LID Hole angle tough pede a OC d.e 7' x 5' Baku SL,ZXP Liner tap plo. 4.5' Baku CMD Skdi galcove 4.5" NES XN Nipple ( 3-725 No -(33o) 10,398' Baker Tie back sten 5.25 -4.375" LorrerWindow 10,505' li��..,., 4-1/2- CIBP 1 83 As C4 slotted line (1C,515'43,766) 45' 12.6# L -BC IBTtubing Baker Gtdde Shoe ®13,810 Baker P.a:k:AiBastlix3•�' �3,,Tff' 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 bills (493) cement (13,97T -14,470) MPC -41 KBelev. =30.10' DF elev. = 45.1T GL elev. =16.50' 11(icor, ,1laska. LLC SCHEMATIC Revised 1/29/2019 4-12 X Nipple (3813"to) 9823' 7 X4.12 L-80 HES T&T Packer ggyj• 4.1/2 X Nipple (3813'ID) 9999' 4-112-WLEG 8052' ,�Slnaee closed during 7/10105 RWM Upper window 10,091'- 10,103' 14jts. of solid liner (1C,109' -1C,696') 74 its. of Slotted Liner (1C,695' • 13,623') Baker float shoe ® 13,666' Baker packoff bushing ®13,623' Baker HR setting sleeve 10,405 Baker HMCllnerh3nger 1C421' EZSV Bridge Plug #2 1Q5P3' (Above Abandoned Lateral) Halliburton float collar R7111-71 EZSV Bridge Plug #1 11,147' (Above Abandoned Lateral) Halliburton Casing shoe Abandoned Open -Hole OB Lateral to 12,205' MD 4-1/2" SLOTTED INTERVALS OA L2 -10,515' -13,765 MD 4,324' - 4,345TVD OA L1 -10,6W -13,623' MD 4,349 -4,348 -TVD 12IM04MDO Isolate ower zone & ESP 4 -ES 711&05 Lee Hulme Isolate L2 & Open Li Sands4-ES 3125114 B.KmIde I Doan 16 RWO from ESP to Injector MILNE POINT UNIT WELL C-41 API NO: 50-029-23014.00 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. OAL= 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 PCH 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. POH 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, T1 disconnect (3/4" ball), 3.10" OD X0, 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 X0, 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 perf 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 perf 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 shot 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, #10.1 Hydraulic settint tool 2.63", Adapter Kit 3.5:, 4-1/2" Cast Irom Cement retainer. 3.59" OD. OAL 14.89'. Cought fluid at 600'. Tie into Upperflag 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 bbis 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. 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 1/19/2019 Daily Operations. 1/16/2019- Wednesday No activity to report. 1/17/2019 - Thursday No activity to report. 1/18/2019 - Friday No activity to report. 1/19/2019 -Saturday State Witness MIT -T to 2,200 psi (PASSED)and MIT -IA to 2,200 psi (PASSED). Witnessed by Bob Noble. Pump 1.4 bbls 60/40 to reach test pressure. 1st 15 Min Tbg lost 24 psi. 2nd 15 Min Tbg lost 10 psi. Bleed Tbg down to zero w/ 2 bbls 60/40 returned. Pump 2.7 bbls 60/40 down IA to reach test pressure. 1st 15 Min IA lost 52 psi. 2nd 15 Min IA 1 si. Bleed IA down w/ 3 bbls returned. 1/20/2019 -Sunday No activity to report. 1/21/2019 - Monday No activity to report. 1/22/2019 -Tuesday No activity to report. THE STATE oIALASKA 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 -41L1 Permit to Drill Number: 201-079 Sundry Number: 318-441 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.00gcc.closka.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 i'-� DATED this Ot day of October, 2018. RBDMSi OCT 10 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS /m,• 15 9D AAC. 9598D 1. Type of Request: Abandon to Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Aker Casing ❑ Other: Reservoir Abandonment L1 2. Operator Name: 4. Current Well Class: S. Permit to Drill Number: yµ„3 Hilcorp Alaska LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service Q . 201-079 - 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: ,Su -o2,9- 230% -4-, Anchorage Alaska 99503 50-029- -06-00 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-411-11 ' /� 9. Property Designation (Lease Number): X'P 6C0 7t67i P' 10. Field/Pool(s): ADL0025516, ADL0025518 & ADL0047434 /�"V "F MILNE POINT/ SCHRADER BLUFF OIL it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 14,148' 4,339' 13,955' 4,343' 1,250 10,523 & 11,147 N/A Casing Length Size MD TVD Burst Collapse Conductor 79' 13-3/8" 110' 110' N/A N/A Production 11,160' 7" 11,194' 4,398' 7,240psi 5,410psi Liner 456' 4-112" 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 12.6# / L-801 TC -II 9,963 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7x 41/2" 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 [] Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑Q - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/11/2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ 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: Be York Contact Name: Taylor Wellman �" r Authorized Title: Operations Manage —774. z Ww....n.0 Fa,t Contact Email: twellmaD hllcof .com ao Yo 2< 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: — Plug Integrity [ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 1lwj j� lkN;(!q a.� 2� O/'d J a -.Q �,¢ ZO AA c— 2 %, llL / / Post Initial Injections MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: l (� ' y o 7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �, , ORIGINAL �� , ,8 �1'� Formand 3 'g Fo ev 01 CT 10 ZWoved application is valid for 12 months from the date of approval. Attachments in Duplicate w K MCorp Alaska. LG 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: 1,650 psi @ 4,000' TVDss (SBHPS 10/03/15; 8.0 ppg EMW) Maximum Expected BHP: 1,650 psi @ 4,000' TVDss (SBHPS 10/03/15; 8.0 ppg EMW) MPSP: 1,250 psi (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 Ll 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. Gf a. Note that slickline attempted to drift the well but hit a very thick fluid and fell very slowly. FW 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. b. Stop and paint 2nd flat at 9850' md. 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. NIA L-1 Reservoir Abandonment Well: MPU C-41 IlikorV Alaska, 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. r s e •03Y LZ b. Target is to get at least 73bbls of cement pumped through the retainer. w / 33 A* - 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. Pull out 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. 15. Wait on cement to gain 1000psi compressive strength. 16. Pressure test casing to psi for 30 min charted.17. RD RD CT unit. +5` 2 P5- 0 Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Blank RWO Sundry Change Form Tree: 41/2 ", 5M VNkllhead:11" x41/2 " 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' 71' 16 ppf, L -BC, Stre. production oaring ( dda ID . 6.161", cap, . C.C88e bpf ) 4.5r 12.89 L-80 TC- 11 "ing ( ID = 3.958', cap =.0152 BPF ) KOP ® SCC' Max 1wl6on Angle:76' ® 83CC -1C,C 6C' MD Hole angle trough petle a 9C deg. 7"x 5' Bake SL-ZXP Liner top pla. 9562' 4.5' Bake CMD Siding sleeve 10,1)41' 4.5" HES XN Nipple ( 3.725' No -Go) 10.398' Baker Tie back stem 5.25' -4.375' 10,419' Lower Window (10,505' - 10,518') L1 83 ps of slotted liner (1C,615'43,765') 4.5-12.E#L-8C IBTtubina Baker Guide Shoe ® 13,81C Baker Packefi St s hi11,; & .3,;UT' I 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' 75 bbls (493') cement (13,977 -14,470) MPC -41 10 .7 k_pDF-elev=45.17' 't) GL elev. =16.50' r Hileorp Alaska, I.M. 4-19 X Nipple 13.813"10) 9823' 7x4 -12L-83 HES T&T Packar 98r' 4-12 X Nipple 13.813'ID) 9890 412' WLE-G 99- /Sleeve dosed during 7118/05 RM Upper Window 10,091'- 10,103' L2 4.5" 12.6#L -BC IBTtubina 14 jts. of solid liner (1 C,1 C9' -1 C,696') 74 ds. of Sloted Liner (16,695' -13,623') Baker float shoe ® 13,668' Baker packotf bushing ® 13,623' Baker HR settina sleeve 10,405' Baker HMC Iiner hanger tC,42t' EZSV Bridge Plug #2 10,523 (Above Abandoned Lateral) Halliburton float collar 11,113' EZSV Bridge Plug #1 11,147` (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 B. Hasebe 7/18/05 I Lee Hulme I Isolate L2 & Open Ll Sands 4 -ES 3125114 B.Kruskie Doyon 16 RWO from ESP to Injector MILNE POINT UNIT WELL C-41 API NO: 50-029-23014-00 7 Tree: 41Y2 ", 5M MPC -41 VWlhead: if" x 41/2 "TCII T&B. Hnr. w/ K16 >F elev. = 45.1T 4-1/2'Type'H' BPV profile GL elev. = 16.50' f , ' 13 3/8" 72 ppf, L-80 Casing 110' Tam port collar @ 1045' Hileorp Alaska, LLC 7" 26 ppf, L -SC, Bfro. production oacirp "y (drift ID. 6.151", cap. . C.00806pf) iA ��p 4.5" 12.68 L-80 TG II tubing /" ( ID = 3.958'. cap = .0152 BPF ) 4-1/2" SLOTTED INTERVALS OA L2 -10,515' -13,765' MD 4,324' - 4,345' TVD OA L7 -10,695' -13,623' MD 4,345` - 4,348' TVD t im "`". D1`' IVITV'`r"'J 4-12 X Nipple (3.813"to) 9823' TOC+! -9,850' 7X4-172L-83HES 7&T Packer 9854' Y.OP a FCC ' Maxi lkore Angler 76'®08CC'-1C,(6C'MD 4-V2XNipple (3.813"ID) 9ew Hole angle trough ped¢ a PC deg. , 4-1/2" Cement Retainer /- 9,939 - 7/18/05 7'x 5' Baker SL-ZXP Li1ar top pkc 9,962' JIM, ' 4112' WLEG H +/-10,015 ole Punch +/-10,010 to Slerrve dosed durilg 7/18105 RM 10,041' Upper Window 10,091'- 10,103' . 4.5" Baker CMD SI sleeve L2 4.5" HES XN Nipple ( 3.725' No -Go) 10,398' 4.5" 12.6#L -8C IBTtubing Baker Tie back stem 5.25 -4.375" 10,419' 14jts. of solid liner (1C,1C9-1C,696') 740s. o1 Slotted Liner (1C,695'- 13,623') Lower Window 1Q505' -10,518') Baker float shoe ® 13,668' 4-1/2" CIBP +/- 10,450' Baker packoff bushing 4D 13,623' L Baker HR setting sleeve 10,405' Baker HMC liner hanger 1C 421" 83 Ps of slotted liner (1C,515'-13,765') EZBridge Plug #2 10,523' 4.5' 12.6#L -8C IBTtubino (Above Abandoned Lateral) Baker Gulde Shoe 0 13,81C' Halliburton float collar 11,113' BakerPzr&off,'3,,W` EZSV Bridge Plug 41 11,147' (Above Abandoned Lateral) Halliburton Casing shoe 11,194' Baker Payzone Packer (13,954' -13,977') 3 jts 4.5" 12.6# L-801BT Solid tubing Halliburton Float Collar 14,096' Abandoned Open -Hole OB Lateral to 12,205' MD AT Halliburton Float Shoe 14,141' 75 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 L7 -10,695' -13,623' MD 4,345` - 4,348' TVD t im "`". D1`' IVITV'`r"'J MILNE POINT UNIT 7/13/01 7@4101 Moo a.Hasebe Ddred 8 Cased Nabors 22 e ESP Completion Nabom 4ES WELL C-41 API NO: 50-029-23014-00 2/2204 MDO Isolate owwerzne&rESP 4 -ES 7/18/05 Lee Hulme Isolate L2 & Open Ll Sands 4 -ES 3125/14 B.Kmskie Doyon 16 RWO from ESP to Injector COIL BOPS MILNE POINT UNIT MPU C-41 Hilrorp AI®eknLLC 09/26/2018 Coil Tubing BOP ( Lubricator to injection head Blind/Shear I—II' 1/16 1.50" Single Stripper mom Pipe J---11 t ---L Pipe Crossover spool 4 1/16 10M X 4 1/16 SM Manual Gate Manual Gate Crossover spool .6 2 1/8 5M 2 1/8 5M HHilcorp 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 HAK Page Date Procedure Change Prepared B Initials HAK Approved B Initials AOGCC Written Approval Received Person and Date Approval: Prepared: Operations Manager Date Operations Engineer Date • „1.'��\�I'/%ice n E STATE i- ke 1 p,i1 s E F -•% .',-'''-' 7,1, ^, / % l`.. ,. r 1 ��- �_ ll �_�`_ \�__�...�'Z: ��, a� , spi -_-__—,__-_-,*±_-,; 333 West Seventh Avenue "'r' �' Ci CiA'1_=.RlC i2 SEAN p \f \?ELI. Anchorage Alaska 99501 3572 k 9(' 27° 3 , �u ` LASY' :ax 907 2,( David BjorkS�. val) Mg 2 01.014 Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Q01 077 Anchorage, AK 99519-6612 Re: Milne Point Unit, Schrader Bluff, MPC-41L1 Sundry Number: 314-120 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, , p_.)2e4/„70, Cathy I. Foerster Chair DATED this S day of March, 2014. Encl. ••' STATE OF ALASKA RECEIVED ALASK,,JIL AND GAS CONSERVATION COMMI. JN • APPLICATION FOR SUNDRY APPROVAL FEB 2 8 201 __ 20 AAC 25.280 OTS 3 5 l �-- 1. Type of Request: AOGb ❑Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate ®Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing IN Other Convert to Injector 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. - 0 Exploratory ❑Stratigraphic 201-079 • 3. Address: 6. API Number: e,Alaska 99519-6612 ®Development' 0 Service P.O. Box 196612,Anchorage, 50.029-23014-60-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPC-41L1 - Will planned perforations require a Spacing Exception? 0 Yes ®No 9. Property Designatior 10.Field/Pool(s): ADL 047434, 025516&025518 • 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): 14148' - 4339' • 13955' • 4343' • 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 10468' 7" 37'- 10505' 37'-4323' 7240 5410 Liner 3405' 4-1/2" 10405'- 13810' 4300'-4345' 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10515-13765 Slotted Liner,13765-13954' 4325-4458'Slotted Liner,4345-4343'OH 2-7/8',6.5# L_80 9931' OH 4-1/2",12.6# 9962'-10419' Packers and SSSV Type: 7"x 5" Baker SLZXP Packer; Packers and SSSV 9962'/4187' • 4-1/2"Baker Payzone Packer MD(ft)and TVD(ft): 13954'/4342' • 12. Attachments: 13.Well Class after proposed work: • ®Description Summary of Proposal ®BOP Sketch ❑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 ®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: ,e,,/......2."-#.--,40/ Phone: 564 5683 Date: pa��/y Commission Use Only Conditions of approval: Notify Commission so that a representative may witness / Sundry Number: :�\Lk 'L\ C) ❑Plug Integrity 3BOP Test Mechanical Integrity Test ❑Location Clearance Other: n G /� test- fc (3 ,5- CI G Ps ' RBDMS AY 2014 5JStu.. tc 1,,�1'fi r55zcl rvl jT- 1A r-ccLvl'i-ec/ 4 It-rr S .-4b.7i rc(i:-J<<tiy, I/'l l cc1/ ' opcv cA ¢ lvYrs In cc0rflco' , CC t.,,, vt h A_t 1c. 6 Spacing Exception Required? 0 Yes 'No Subsequent Form Required: /G' —4, 4, pa ckc'/—cicpti-, 171 rie4ViC uA/(2ro ✓t�i per 20A�1c. ZS- 41Z (6 ) /) APPROVED BY Approved By: V / --)2)..t4,74-1,"--- COMMISSIONER THE COMMISSION Date: 3 -S- Form 10-403 Re i 0/2012 AASubmit In Duplicate �is / Approve OR jcO IaIt4oA2Enths from the pale of approv I P bp • 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-W 12.6#/ft L-80 tubing with HES TNT packer set at-9837' 6. Test tubing and IA to 3,500-psi. 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 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. • N APE-03 . : \ -3 1P81 MPB-0*__- AVE-.3AP82 AVC-41L2 t,PE-13 A-03 A-01 MPE-33 MP -13A1 .,A-02A '` 1 IPE-18 MPE--1`38 MPC-41P:, MP 0r MPE-20AL1 IrPE-19 • -20A '.• 1 f MPG-07f MPC-41L1 MPG-03 ' -." _ 19 moo i'o l 1000 2000 3000 /' MPCs11 Legend Wellbore with bottom hole symbol `M Intersection of wellbore with Schrader Bluff Formation CZ % mile distance from wellbore (NA intercept to TD) S : 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 Camco 2-7/8"x 1" 9,739` (drift ID=6.151",cap.=0.0383 bpf) 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 L. 1 Tandem Gas Separator 9,897' SE5798GA t �1 Tandem Seal Section 9,902' KOP @ 300 gsb3dbabhsnpfsa/gsb3dbltabhsnfsa Motor. 95 HP, 1330 volt. 9,915' Max wellbore Angle:75°@ 3300'-10,050'MD ~l 44 amp,Model KMH Hole angle trough perfs=90 deg. Centrilift Pumpmate gauge 9'925 7"x5"Baker SLZXP Liner top pkr. 9,962' at at 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 :.'•':r}?::Ss'::P•'::'••r: 4.5" 12.6#L-80 IBT tubing Baker Tie back stem 5.25"-4.375" 10,419' I 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' RlBaker packoff bushing @ 13,623' y' ::::':::�lk::•::::: :'::.:.'::::: ':':•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' 75 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"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) 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 I U .1/2"X Nipple 9,907 Hole angle trough perfs=90 deg. 7"x5"Baker SLZXP Liner top pkr. 9,962' 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::,�:•::::::::::,:�::.•:r:::.•:::air:::. 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' Baker packoff bushing @ 13,623' ,,_ ::::4:::,:::;: :v.:•:::::::. :::::::::; setting10,405' :•,•;;,;,;,.....,.,;..;:,,,,L1 Baker HR sleeve± ;:;i:r:,';;;?i::•:ti•:� :::r::::ds °; 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' 75 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 0 1 7t : i•5 ii al 1. Y �y OD 7 5 m1 a0 Oill QZ 6 m c1 4E 1 ! ., :'; \ 2 { Za 1 g 1 t 0 1 E w a a K O $• N w a a M Y 7 a -, = 3 a Z J r O = O Z 0000000 I Q 1 • � � it H ____- aM2 � aill �1 i :; - i ''''''' 2:.-i I! :t i Yin a -I II: nd _� /' ■ < N Z -46alm . j 2 2 o A Z El s _ $ C.>Q8 a '-rc - =oC. 5 Nao m m am maaaRYam io ' $ U'll © .i J W I Z XIn LA / AI ii 11=:‘,FAA, 111 z . 0 ] 20 I w Y c :- w a) ill III A co 0111M11 ■A� O > 0g 1- _t_ > ZN x 411112 c CDvn _ L Milne Point C- (PTD 201-079 & 201-127. 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 sup ortroducers MPE-20A. Cvr�vr. 74e well (rerlvCed x/ooI p/w/� 'O*J k.G , /fire-204-- Completion it a f t rtrr' irao%Co� �✓r CSD es a�f 4efloe "4'4 ,jiltirc,C'�j Si,,,,,1: r6 ' we// ' 0 a(tor 10a/c/ • fro e • Well MPC-41 (Permit# 201-078) was completed in July 2001 with two laterals Over, k?f MPC-41L1 (Permit# 201-079) and MPC-41 L2 (Permit# 201-122) as a Schrader 1.3/4 �d�" Bluff producer. Both laterals are completed in the Schrader Bluff OA sand. A 13- 0 r /00 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 • 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-41L2: 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.bettisCaalaska.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 • 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) From: Chmielowski, Jessie [Jessie.Carr@bp.com] Mt) _ 9(L( Sent: Monday, March 03, 2014 9:56 AM 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 • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 2 0 2014 APPLICATION FOR SUNDRY APPROVALS ®�� 20 AAC 25.280 1.Type of Request: Abandon❑ PIug for RedrilI❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Ext 'on❑ Operations Shutdown❑ Re-enter Susp.Well Stimulate❑ Alter Casing❑ Other: Convert to I .-ctor Q• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. , Exploratory ❑ Development Q . 201 I • r 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50 0 '-23014-60-00 7.Iferforatin : 8.Well Name and Number P 9 What Regulation or Conservation Order governs well spacing in this pool? S: MPC-41L1 -- Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025518 ; MILNE POINT, S 'RADER BLFF OIL 11. PRESENT WELL CONDITION SUMMARY 1 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(' =,.ured): Junk(measured): 14148 . 4339 + 13955 ' 4343 • None None Casing Length Size MD TVD Burst Collapse Structural Conductor 79 13-3/8"72#L-80 31 -110 -110 Surface None None None None None None Intermediate None None None None None None Production 10468 7"26#L-80 37-1050. ' 37-4323-1 7240 5410 Liner See Attachment See Attachment See Attach See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment ‘ See Attachment 2-7/8"6.5# r r L-80 21-9859 Packers and SSSV Type: See Attachment for Packer Types P-ckers and SSSV MD(ft)and TVD(ft): See Attachment for Packer Depths No SSSV Installed • No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service Q • 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 correct tot.- best of my knowledge. Contact Jessie Chmielowski Email Jessie.Chmielowski@BP.Com Printed Name Jessie Chmiel• ski Title Production Engineer 1 Signature Phone 564-5015 Date Prepared by Garry Catron 564-4424 _9 0„,u,-- O 'Cik\-- 2/7,-D/I y' COMMISSION USE ONLY � �-t Conditions of approval: Notify Commiss'.n so that a representative may witness Sundry Number. 3`� C`— ` Plug Integrity ❑ B••Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: SCANNED AUG 0 6 2014 RBDM MAY 10 2014 i , Spacing Exception 'equired? Yes ❑ No d Subsequent Form Required: APPROVED BY Approved -y: COMMISSIONER THE COMMISSION Date: 4 /2 ala?/i Form 10-403 Revised 10/2012 vtGIa ALor 12 months from the date of approval. Submit Form and Attachments in Duplicate -0 0 0 0 0 0 ao Do ao ao ao J J J J J N Q O 0 0 0 0 r00 O Co to Lc) p N N N tf) 0 ) 0 00 0 2 M M M 7 O co � N O cr co co I� � CU N co• O co � N CO co co M e 0. O • 000 O I� r Q co a- C) M N oo EC N r N O) O Lc) C In Cu O �- O 10) r O CO Q _' O co O O r r r p 2 C Q QO O U Q co co 8 CO N 2 cp coco 0 ocooco J 00 J O N CCOO. VD J Cl) QO a-- N (O tj N N uu • d' N 00 O 0 0 0 CO J M O CA z O CA H I- oCUoCLCLoZ Z W W 0 m OrD 0 J i O H Perforation Attachment ADL0025518 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPC-41L1 7/13/01 SL 10515 13765 4325 4345 MPC-41L1 7/13/01 OH 13765 13954 4345 4343 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0025518 Well Facility Type _ MD Top Description TVD Top MPC-41L1 PACKER _ 9963 5" Baker ZXP Top Packer 4188 MPC-41L1 PACKER 10405 7" Baker ZXP Top Packer 4300 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 supeort roducers MPE-20A.. as ter ie well pref�rcto/ /eollef �q 30�Z wG , M - Ja4- Com letion fer1kr ao%C9r 4vrGs nett ,In G�,` rvl''0ti Caw r!r/''y s well 7►b cm/ i'J '<<rOc' S0r//r,/ i'Nri'g),•t Well MPC-41 (Permit# 201-078) was completed in July 200'1 with two laterals ecoverp // MPC-41 L1 (Permit# 201-079) and MPC-41 L2 (Permit# 201-122) as a Schrader . prm Bluff producer. Both laterals are completed in the Schrader Bluff OA sand. A 13- 0 T 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 lir 00 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 Sundryfor conversion to water injection 1 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. MPE-03 \MP823 M- 1PB1 MPB-25 -- 17 MPE- 3APB2 MPB-04A MPC-411.2 AVE-13 '------;------.v -A-01 A-03 MPE-33 -1 MPB-09 1,-A-02A 1 NPE-1s MPC-41- MPE-20AL1 MPE-19 • -20A :1 f MPG-07 MPG4,L, MPG-03 ' -•' MPG-19 �000 �000 2000 3000 R / _,.......-'"-----1.--• MPG11 Legend Wellbore with bottom hole symbol Intersection of wellbore with Schrader Bluff Formation 1/4 mile distance from wellbore (NA intercept to TD) 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 Camco 2-7/8"x 1" 9,739` (drift ID=6.151",cap.=0.0383 bpf) sidepocket KBMM GLM 4.5"12.64 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 9,915' Max wellbore Angle:75°@ 3300'-10,050'MD Motor,95 HP, 1330 volt, 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 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` 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' Baker packoff bushing @ 13,623' r L1Baker HR setting sleeve 10,405' Baker HMC liner hanger •••••,.,..•.•.......................... / 10,421' 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 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 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@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.ferqusonalaska.qov 1 ' E EWED STATE OF ALASKA JAN 2 3 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 10 CC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Chan.‘Approved Program❑ Suspend❑ Plug Perforations Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well Stimulate❑ Alter Casing❑ • er. Injectivity Test , 0 2.Operator Name: 4.Current Well Class: 'e '` • Drill Number. BP Exploration(Alaska),Inc. —Exploratory ❑ Development E, , 201-079-0• 3.Address: Stratigraphic ❑ Service ❑ p.'PI Number. P.O.Box 196612,Anchorage,AK 99519-6612 ( 50-029-23014-60-00 • 7.If perforating: 8 W 0 ,' a and Number. R1._•b What Regulation or Conservation Order governs well spacing in this pool? SBL MPC-41L( Will planned perforations require a spacing exception? Yes El CI % 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025518 , =POIN CHRADER BLFF OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth •: aikPlugs( easured): Junk(measured): 14148. 4339 • 13955) r? „ 1 None None Casing Length I Size I MD ` 1�1 Burst Collapse Structural ,� Conductor 79 13-3/8"72#L-80 31-110 31-111 Surface None None None None None None Intermediate None None •n None None None Production 10468 7"26#L-80 37- I.I. 37-4323.1 7240 5410 Liner See Attachment See Attachment S7-'• • ment e Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Siz-. ubing Grade: Tubing MD(ft): See Attachment See Attachment 2 ''6. • III L-80 21-9859 Ilr Packers and SSSV Type: See Attachment for Packer Types . •SSV MD ')and TVD(ft): See Attachment for Packer Depths No SSSV InstalledNo SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 3.WI Class after proposed work: Detailed Operations Program ❑✓ , BOP Sketch ❑ Ex. . -tory ❑ Development ❑� • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil 2 . Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct tot - best of my knowledge. Contact Jessie chmielowski Email Jessie.chmielowski@BP.Com I Printed Name Jessie chmielow- i Title Production Engineer Signature i) n hone 564-5015 i 23// Prepared by Garry Catron 564-4424 ,oe ro_ COMMISSION USE O LY Conditions of approval: Notify Commission so at a representative may witness Sundry Number. %`L" 0 S Plug Integrity ❑ BOP Test • Mechanical Integrity Test ❑ Location Clearance ❑ I Other: HES wig �j0� RBDM MAY 0 9 2014 SCO Spacing Exception Required? Yes ❑ No Subsequent Form Required: jo 4o 4- APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: — C h1 .2/4/204 Pii' If 22111 Form 10-403 Revised 10/2012 Approv flpRie jahfrr�onths from the date of approval. Submit Form and Attachments in Duplicate iyFz/•/-/11-- �l tt LL -0 a) 00000 ctf CO c9 CO CO OD J J J J J (1 Q O 0 0 0 8 CO LS 0 UNN- r— C � 17) 0000C),,_ co co co 7 C) N O Nr 00 00 r COco Lo co • O0 O 't N CO M M M Q coO ~ r 00 O Q M M CO N NI- a3 CO C N r C C p O 0 N p O r p U) OQ � OMOO) p 2 � J Q 03 H •- ((D0N � U Q M (Y) N 5 co O p O 00 00 OO 00 J J J p J U) N (0 CO J CD (LS c•i/� NEo _ CO C) (V N co v- • V� N 0 0p 0) 0 0 (0 co 'cr0) ~ M p p0) J � z O O O 0• oWcoZ O Z Z o D 0 J J d 1— Perforation Attachment ADL0025518 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPC-41L1 7/13/01 SL 10515 13765 4325 4345 MPC-41L1 7/13/01 OH 13765 13954 4345 4343 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Packers and SSV's Attachment ADL0025518 Well Facility Type MD Top Description TVD Top MPC-41L1 PACKER 9963 5" Baker ZXP Top Packer 4188 MPC-41L1 PACKER 10405 7" Baker ZXP Top Packer 4300 • Tree: 2 9/16", 5M M P 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' 44:1Camco 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' sidepocket KBMM GLM 4.5"12.6#L-80 IBT-M tubing Hes XN-Nipple(2.205"id) 9,849 (ID=3.958",cap=.0152 BPF) Tandem Pump,Upper 214 Stg. 9,871' 2 7/8"6.5 ppf,L-80 8 rd EUE tubing _ FC925 FPMTAR 1:1,Lower (drift ID=2.347",cap=0.00592 bpf) 16 Stg.GCNSPH,GPBMTAR 1:1 k Tandem Gas Separator 9,897' -- SE5798GA S I Tandem Seal Section 9,902' KOP @ 300' ; gsb3dbabhsnpfsa/gsb3dbltabhsnfsa 9,915' Max wellbore Angle:75°@ 3300' 10,050'MD Motor,95 HP,1330 volt, 44 amp,Model KMH 9,925' Hole angle trough perfs=90 deg. Centrilift Pumpmate gauge 7"x5"Baker SLZXP Liner top pkr. 9,962° all NIB / Sleeve closed during RWO-✓ 4.5"Baker CMD Sliding sleeve 10,041' Upper Window 10 091 10 103' 0 L2 4.5"HES XXN Nipple(3.725"No-Go) 10,398' „{.}:.::}:. .:..:;t: },:;';•:ti::•:ti{•:: ::•..... 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' ill '4,-,t.) _ - Baker packoff bushing @ 13,623' ,.-:„.!..:-. ::1.. L1 Baker HR setting sleeve 10,405' ' Baker HMC liner hanger• • • .. . . .... ......••.•.•.... 9 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 • s by 0 Date: January 16, 2014 From: Jessie Chmielowski MPU Schrader Pad Engineer 907-564-5015 Subject: MPC-41 Injection Test MPC-41 is a candidate to convert from producer to injector. Before converting the well to injection, an injection test will be performed to ensure that the well does not have a Matrix Bypass Event (MBE) to offset producer MPE-20A. The plan for the injection test is to pump 500 barrels per day of produced water into MPC-41 for three days while monitoring offset well MPE-20A for any changes in watercut. • a) 4.0 / \ ▪ ? e = . 0u � � Q ▪ -0 E t / 2 0 / C / / k $ • Crts § •® C — 2 3 ] $ f D• > E _ § 2 73 E c o 2 t. % O / / § 0 V) CO ƒ 0 2 \ — f e - U 5 E I \ c E 5 16 T E v, 0 c a u o D. _ IR H < c ) % f \ I- > E c S §. . . . . . ,_ = oC50E m� #� 4 0 9 3 S • e \ - • \ / \ ) ; C" f 7 / / •0i \ -o,1 0 0 0 /i 8 .6 / § % ° 0 3. 0 a) _c / 3 % fI \ >. / @ 2 < $I I I / � ± 2 ! i 2 e E � = e \ 2 c -E' cu © E 5 Ee / » / & / 2 / 0 \/ ƒ / 2 � c, uU • co £ _ V) - ƒ / m / p - > 0 iocu / ) / » / > / \ £ / y = 3 $ 2 < g = a) § f ■ > [ £ y 9y .cm et � � ' $ 2 = Ec = & = , 0 % o tg } k ƒ 2Nk \ / / , B B @ / / \ / ± �< O ® q ' at � / / � = ., E v 2 / / $ \ 2 & c E { $ \ \ % pfd \ q A + ■ \ E) S $ / R c = o � \ \ \ \ . 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Cr H U C u t 4- CO C r6 'O U cp LL O .Q N • O V) U CO L = a o v a cu o c v o a o o � a) di= ee.. v H 2 2 ‘•7") _I = � �_ IA n C 3 -a a) Y H a s .L.•' v a� °L) a) v v U a) L a, `� C ,VL x a.7 (n LL •.•L vi ,-i N M 3 V) -O m 0 H co a F- V m ate) O IL vi y aJ H U (0) U F- U ,- • • • • • O •C E O U 0 li ra 4J > O LaJ c v U O O X Y "a •KO O Q�j Q v O�0 W U > O N a) E C a a N L a) l6 roN Uj r 1 ^ (UO C - N _ co j 2 Q 0 � OM1 N To > *' O N N ca co rn o O H u Ln Q m Q 0�1 a1 u C • Ferguson, Victoria L (DOA) From: Stone, Christopher <Christopher.Stone@bp.com> Sent: Friday,January 31, 2014 4:23 PM To: Ferguson,Victoria L(DOA) Subject: RE: MPC-41 (PTD 201-078, Sundry 313-048) Follow Up Flag: Follow up Flag Status: Flagged Victoria, As per our phone conversation, please withdraw Sundry 313-048, PTD 201-078,SBL MPC-41/L1/L2. Thanks, Chris Stone BP Exploration(Alaska)Inc. Lead Petroleum Engineer-Milne Point Office:907.564.5518 From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Friday,January 31, 2014 3:42 PM To: Stone, Christopher Subject: RE: MPC-41 (PTD 201-078, Sundry 313-048) Chris, Please respond to this email withdrawing Sundry 313-048, PTD 201-078, SBL MPC-41/L1/L2. 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.ferqusonCa�alaska.gov From: Stone, Christopher [mailto:Christopher.Stone@bp.com] Sent: Friday,January 31, 2014 3:12 PM To: Ferguson, Victoria L(DOA) Cc: Jessie.Carr@bp.com Subject: MPC-41 Sundry Application Questions Victoria, 1 r ' I have pulled the well files for MPC-41 in hopes of addressing the questions that you had regarding MPC-41's 7" production casing integrity. A summary of the initial production casing cementing job from 2001 as well as some highlights from the 2005 RWO highlight the integrity of the casing and provide verification that the upper L2 lateral is isolated. MPC-41 History Well MPC-41 was (Permit#201078)was completed in July 2001 with two laterals MPC-41L1 (Permit# 201079) and MPC-41L2 (Permit#201122) as a Schrader Bluff producer. 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 103 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. The well is currently open to the MPC-41L1 lateral (Permit#201079). During the 2005 RWO the workover rig closed the sliding sleeve to isolate the upper L2 lateral from production. A plug was set in the 4-1/2" XXN , Nipple_011.0,398' and a successful pressure test was conducted to 2000._psi veri ing the sleeve_was closed and holding. Please feel free to contact me or Jessie Chmielowski with any other questions that you may have regarding this well. Thanks, Chris Stone BP Exploration(Alaska)Inc. Lead Petroleum Engineer-Milne Point Office:907.564.5518 2 r 4, Bettis, Patricia K (DOA) From: Bettis, Patricia K(DOA) Sent: Wednesday, January 22, 2014 4:15 PM To: 'alecia.wood@bp.com' Subject: MPC-41 Sundry Application Good afternoon Alecia, In reviewing the application, it appears that the injectivity tests will actually take place within the MPU C-41 laterals (L1 and L2). If this is the case, please submit a Sundry Application for each of the laterals with proper permit to drill and API numbers, depths and other information specific to each lateral. If you have any questions, please do not hesitate to give me or Victoria Ferguson a call. 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 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LascrFiche\CvrPgs _Inscrts\Microfilm _ Marker. doc KI::GI::IVED STATE OF ALASKA _ ALASKAtIL AND GAS CONSERVATION CeJlfMlSSION JAN 0 9 2006 REPORT OF SUNDRY WELL OPERATlQNi&Gas Cons. Commission Anchorage 1. Operations Performed: Change Out ESP o Abandon o Suspend o Operation Shutdown o Perforate 181 Other o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 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. 181 Development o Exploratory 201-079-00 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23014-60-00 7. KB Elevation (ft): KBE= 45.17' 9. Well Name and Number: MPC-41L1 8. Property Designation: 10. Field 1 Pool(s): ADL 025518 Milne Point Unit 1 Schrader Bluff 11. Present well condition summary Total depth: measured 14148 feet true vertical 4339 feet Plugs (measured) NIA Effective depth: measured 13955 feet Junk (measured) NIA true vertical 4343 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 13-3/8" 110' 110' 1530 520 Surface Intermediate Production 10468' 7" 10505' 4323' 7240 5410 Liner 3404' 4-1/2" 10406' - 13810' 4300' - 4345' 8430 7500 Perforation Depth MD (ft): 10515' - 13765' Slotted Liner S{;ÁNNED JAN ¡ 1. 200e t ... .." Perforation Depth TVD (ft): 4325' - 4458' 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' 4-1/2" Baker Payzone Packer from 13954' - 13977' 13954' - 13977' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft JAN 1 () 2006 Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory 181 Development o Service o Well Schematic Diagram 16. Well Status after proposed work: 181 Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing IS true and correct to the best or my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 NIA Printed Name Sondra Stewman Title Technical Assistant sigÇ;;ure ~~ (-¡J ""\ :1, Phone . Prepared By Name/Number: .J.J(' 564-4750 Date 0\'-C6-0CoSondra Stewman, 564-4750 Form 10-404 Revised 04/2004 UKIGINAL Submit Original Only MP C-41 KB elev. = 30.10' DF elev. = 45.17' GL elev. = 16.50' Tree: 29/16", 5M Wellhead: FMC 11" x 11 ",A Gen. 5 and 11" x 2 7/8" FMC Tbg'Wr. wI 8 rd EUE threads top and bottom and 2.5" CIW 'H' BPV profile 13 3/8" 72 ppf, L-80 Casing ~ e I 136' I Cameo 2-7/8" x 1" side pocket KBMM GLM Tam port collar @ 1045' 7" 26 ppl, L-80, Btrc. production casing (drift ID = 6.1S1", cap. = 0.0383 bpI) 4.5" 12.6# L-80 IBT-M tubing (10 = 3.958", cap = .0152 BPF) 27/8" 6.S ppl, L-80 8 rd EUE tubing (drilt 10 = 2.347", cap = 0.OOS92 bpI) 9,739' I 9,849'1 9,871' I 9,897' 1 9,902' I 9,915' I 9,925' I Cameo 2-7/8" x 1" sidepocket KBMM GLM Hes XN-Nipple ( 2.20S" id) Tandem Pump, Upper 214 Stg. FC925 FPMTAR 1:1, Lower 16 Stg. GCNSPH, GPBMTAR 1:1 Tandem Gas Separator SE5798GA Tandem Seal Section gSb3dbabhsnplsa I gsb3dbltabhsnfsa Motor, 95 HP, 1330 volt, 44 amp, Model KMH Centrilift Pumpmate gauge KOP @ 300' Max wellbore Angle: 75° @ 3300'·10,OSO' MO Hole angle trough perfs = 90 deg. 7"xS" Baker SLZXP Liner top pkr. Sleeve closed during RWO 110,041'1 4.S" Baker CMO Sliding sleeve 4.5" HES XXN Nipple (3.72S" No-Go) 110,398' I Baker Tie back stem 5.25" - 4.375" 110,419'1 Lower Window (10,505' - 10,518') 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 110,421'1 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 111,194' I 83 jts 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) 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 7/13/01 7/24/01 8/07103 12/22/04 REV. BY MDO B. Hasebe MDO MDO COMMENTS Drilled & Cased Nabors 22 e ESP Completion Nabors 4ES ESP RWO Nabors 4-ES Isolate lower zone & ESP 4-ES MILNE POINT UNIT WELL C-4 t. API NO: 50-029-23014-00 ßP EXPLORATION (AK) -fl,1.i2 "".,.----... .--.. ........."",.""" A ~ ~ - Page 1 of 4 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/6/2005 121712005 12/8/2005 MPC-41 MPC-41 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To Hours Task Code NPT Phase 08:00 - 11 :30 3.50 RIGD P 11 :30 - 17:30 6.00 MOB P 17:30 - 00:00 6.50 MOB P 00:00 - 06:00 6.00 MOB P 06:00 . 15:30 9.50 MOB P 15:30 - 23:00 7.50 MOB P 23:00 - 00:00 1.00 RIGU P 00:00 - 03:00 3.00 MOB P 03:00 - 06:00 3.00 KILL P 06:00 - 08:00 2.00 KILL P I 08:00 - 08:30 0.50 WHSUR P 08:30 - 09:30 1.00 WHSUR P 09:30 - 11 :30 2.00 BOPSUF P 11 :30 - 14:00 2.50 BOPSUF P 14:00 - 14:30 0.50 BOPSUF P 14:30 - 17:30 3.00 PULL P 17:30 - 19:00 1.50 PULL N 19:00 - 21 :00 2.00 PULL N 21 :00 - 23:00 2.00 PULL N PRE PRE PRE PRE PRE PRE DECOMP PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DFAL DECOMP DFAL DECOMP DFAL DECOMP Start: Rig Release: Rig Number: Spud Date: 5/28/2001 End: 12/14/2005 12/6/2005 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 DS 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 1250 psi, taking returns thru choke to tiger tank. Circulate 180 bbls total, monitor well, well dead. PJSM. Set two way check valve. PJSM. NID wellhead. PJSM. NIU 135/8" x 5M BOPE. PJSM. Conduct full test on all BOPE components. 250 I 3500 psi. No failures. Test witnessed by Nabors Tool Pusher & BP Company Man. Witnessing 01 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 2 718" 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 ftllbs. 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: 12121/2005 1 :52:45 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: .4A. ~ ~ / BP EXPLORA TJON Operations Summary Report Page 2 of4 MPC-41 MPC-41 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 12/6/2005 Rig Release: 12/14/2005 Rig Number: Spud Date: 5/28/2001 End: 12/14/2005 From - To Hours Task Code NPT Phase Description of Operations 12/S/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 SOOO 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 freezeup. 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 hardline and pumping eqpt. Rig down hardline and pumping eqpt. 03:00 - 07:00 4.00 PULL N IDFAL DECOMP Waiting on forward plan, bullheaded (70) bbls heated seawater down annulus @ 1 bpm I 550 psi. 07:00 - 11 :30 4.50 PULL N DFAL OECOMP PJSM. POOH, (wet), w/2 7/S" tbg slowly, so as to avoid swabbing in well, 1 x 1, laying down singles. Hole taking right amount 01 fluid. 11 :30 - 14:00 2.50 PULL N DFAL OECOMP PJSM. Pull packer thru stack, note some small amounts 01 gas bubbling up thru seawater, fluid level in wellbore slowly dropping. NOTE: approximately (3 - 4) threads engaged in top 01 storm packer valve..., valve does not start to open until at least 12 threads engaged. Unscrew retrieving tool Irom 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 - 1S: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 11600 psi. Circulte 1 1/2 total hole volumes. Monitor well, well stable. 1S:00 - 22:00 4.00 KILL P DECOMP PIU & 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 01 gas back wi bottoms up. Monitor well, well stable. 23:30 - 00:00 0.50 KILL P DECOMP POH w/2-7/S' production tubing standing same back in derrick. 12/10/2005 00:00 - 04:00 4.00 PULL P DECOMP POH w/2-7/S' production tubing standing same in derrick. 04:00 - 06:00 2.00 CLEAN P DECOMP Clear & clean rig floor. RIU to P/U 2 7/S' 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 27/S" PAC drill pipe, XIO & jars. 10:30 - 13:00 2.50 CLEAN P DECOMP PJSM. Rig up to run 31/2' DP & RIH wi 31/2" DP, 45 jts. 13:00 - 15:00 2.00 CLEAN P DECOMP PJSM. Pick up & assemble kelly & swivel, upper & lower kelly 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. PIU bails. Printed: 12/2112005 1:52:45 PM ~ ~ ..., BP EXPLORATION Page30f 4 Operations Summary Report ...... .. Legal Well Name: M PC-41 Common Well Name: MPC-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: From -To HourS Task Code NPT Phase Description of Operations .. 12/10/2005 21 :30 - 00:00 2.50 CLEAN P DECOMP Con't to P/U 3 1/2" DP 1x1 & RIH wI clean out assy. 12/11/2005 00:00 - 01 :00 1.00 CLEAN P DECOMP Con't to P/U DP & RIH to TOL @ 9962'. 192 jts 31/2" DP + BHA. 01 :00 - 02:00 1.00 CLEAN P DECOMP 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 01 gasto surface. Also had black heavy oily returns. 02:00 - 06:00 4.00 CLEAN P DECOMP 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 3-112" 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'. 06:00 - 11 :00 5.00 CLEAN P OECOMP Continue to reverse circulate down singles @ 3 1/2 bpm, 900 I psi. Seeing spotty sandy returns. 11 :00 - 16:30 5.50 CLEAN P DECOMP PJSM. WI 272 jts of 3112 DP in the hole @ 12,503', begin I 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'. 16:30 - 00:00 7.50 CLEAN P DECOMP 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. P/U 11 OK SIO 35K. Reversing out heavy black very line grained sand. 12/12/2005 00:00 - 04:30 4.50 CLEAN P DECOMP Con't to Reverse out & clean wellbore from 13388 to 13777'. Had hard fill from 13529 to 13550'. P/U wt 110K, S/O 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 line grain sand & heavy black oily material. 04:30 - 06:00 1.50 CLEAN P DECOMP 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. 06:00 - 07:30 1.50 CLEAN P DECOMP PJSM. Continue reverse circulating @ 3 1/2 bpm @ 1000 psi, see both sweeps come back & circulate to clean returns. 07:30 - 17:00 9.50 CLEAN P DECOMP PJSM. POOH & lay down 31/2" DP. 17:00 - 20:30 3.50 CLEAN P DECOMP PJSM. POOH & UD 2 7/8" PAC DP. 20:30 - 21 :00 0.50 RUNCm p RUNCMP P/U running tool. Pull Wear Bushing. UD same. 21 :00 - 22:00 1.00 RUNCm p RUNCMP Clear & clean rig floor. 22:00 - 00:00 2.00 RUNCm p RUNCMP R/U floor & tools to run completion. Hang sheave. Load ESP into pipe shed. 12/13/2005 00:00 - 02:00 2.00 RUNCm p RUNCMP P/U, MIU & service ESP. 02:00 - 06:00 4.00 RUNCm p RUNCMP Pull MLE over sheave. Damaged MLE. Re-splice MLE. Plug in & test ESP. 06:00 - 12:00 6.00 RUNCor P RUNCMP 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. 12:00 - 13:30 1.50 RUNCor p RUNCMP PJSM. WI total of 68 stands in the hole, rig up to run heat trace & pull same over sheave. 13:30 - 20:30 7.00 RUNCor p RUNCMP PJSM. RIH w/2 7/8" completion string, ESP cable & heat trace. Printed: 12/21/2005 1:52:45 PM / ~ ~ - BPEXPLORATION Page 4. of 4 ()perati()ns..·Summar~lepørt . ... Legal Well Name: MPC-41 Common Well Name: MPC-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: Date From - To Hours Task Code NPT Phase Dé§cription of Operations <. 12/13/2005 20:30 - 00:00 3.50 RUNCŒ /P RUNCMP PJSM. Wltotal of 89 stands in the hole, change out spools and make splice 12/14/2005 00:00 - 01 :30 1.50 RUNCŒ p RUNCMP WI total of 89 stands in hole splice and test cable. Fill hole and flush pump 01 :30 - 06:00 4.50 RUNCOI p RUNCMP 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. 06:00 - 06:30 0.50 RUNCOI P RUNCMP Service rig. 06:30 - 08:30 2.00 RUNCŒ p RUNCMP PJSM. Continue to RIH w/2 7/8" completion string wI ESP cable & heat trace cable. 08:30 - 09:00 0.50 RUNCm p RUNCMP PJSM. M/U landing joint, install penetrator. 09:00 . 14:00 5.00 RUNCm p RUNCMP PJSM. Make heat trace splice & ESP field connector & test, OK. RID equipment & clear floor. 14:00 - 15:00 1.00 RUNCm p RUNCMP PJSM. Land completion string & RILOs. 56K up wt, 29K down wt. On ESP cable, used (108) La Salle clamps, (3) Ilat guards & (5) protectrolizers. On heat trace, used (1688) bands, (539) 6' flat guards, (30) 4' flat guards & (4) 3' flat guards. Install 2 I way check valve. 15:00 - 17:00 2.00 BOPSUF P RUNCMP PJSM. NID BOPE. 17:00 - 18:00 1.00 WHSUR P RUNCMP PJSM N/U Tree 18:00 - 19:00 1.00 RUNCm p RUNCMP Test tree to 5000 psi Final check ESP 19:00 - 20:00 1.00 WHSUR P RUNCMP PJSM P/U Lubricator Pull TWC and set PBV UO Same I Printed: 12/21/2005 1 :52:45 PM [Fwd: 4ES gas bubble] e e Subject: [Fwd: 4ES gas bubble J .... From: JeffJones <jeffjones@admin.state.akus> . Date: Fri,09 Dec2005 1'1:03:q9 ':'0900,. .......... '.. .... Tô~' Járnes Régg;<jim -"r~gg@adihin~st~të.akhus>',;/ .. . . .~'. .' ' \7\¿b\O{ , etJ{¡" . '., . '->;;':> t \ .":';: ':~" ::':. ';:. ........~. . .0 \ -'Ó '1Q . .. ,. .... . . .......... ...... .,'. ',"'1;." , . . . .q;' " ".. ,.. ., , ,.. .......¿> .... ." Hi Jim, This incident was originally reported to me at 1830 hrs. yesterday as a 10 BBL kick taken on Nabors 4ES re-entering MPU well C-41. Thank s , Jeff Content-Type: message/rfc822 4ES gas bubble Content-Encoding: 7bit ,:,,<¥H I;.'."{ ',. (;\\~h\:\t:.U <-'''4lf'''' " 1 of 1 12/9/2005 1 :00 PM 4ES gas bubble e e Subject: 4FS gas bubble From: "~SU, AO\\' Drlg Rig 4ES" <\1SUADWDrlgRig4ES@BP.com::> Datc: Fri, 09 Dee 2005 08:50:03 -0900 To: jcfljones@admin.stalc.ak.us 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' wi 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. 14ES gas bubble 1 of I 12/9/2005 12:23 PM 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' J....... STATE OF ALASKA.) E C E r ALASKA. L AND GAS CONSERVATION COivlMISSION REPORT OF SUNDRY WELL OPERATIONSJAN 272005 & Commission Chang@~~~ Ia Other 0 Time Extension Ia Repair Well 0 Plug Perforations 0 Stimulate Ia Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 4. Current Well Class: Ia Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 201-079-00 6. API Number: 50-029-23014-60-00 9. Well Name and Number: MPC-41L 1 8. Property Designation: 10. Field 1 Pool(s): ADL 025518 11. Present well condition summary Total depth: measured true vertical Milne Point Unit 1 Schrader Bluff Effective depth: measured true vertical 14148 4339 13955 4343 feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst Collapse 20" x 13-3/8" 110' 110' 1530 520 7" 10505' 4323' 7240 5410 4-1/2" 10406' - 13810' 4300' - 4345' Casing Structural Conductor Surface Intermediate Production Liner Length 110' 10468' 3404' SCANNED FEB 0 2005 Perforation Depth MD (ft): 10515' - 13765' Slotted Liner Perforation Depth TVD (ft): 4325' - 4458' Slotted Liner 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 4-1/2" Baker Payzone Packer from 13954' - 13977' L-80 L-80 9923' 9962' - 10419' 9962' 13954' - 13977' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft .IAN 3 1 2DD5 Treatment description including volumes used and final pressure: 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run Ia Daily Report of Well Operations 0 Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory Ia Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 N/A Printed Name Sondra Stewman ./ ~' -- ~ ",. ~ <.. Signature ~~k Form; 0-404 Kevised 04/2004 Title Technical Assistant ðTIe\ G ISi\rAt Prepared By Name/Number: DateOl- Z.S-ot) Sondra Stewman, 564-4750 Submit Original Only MP C-41 k-\ ~ ~ )l Tree: 2 9/16", 5M ') Wellhead: FMC 11" x 11", '- ., Gen. 5 and 11" x 2 7/8" FMC Tbg. Hm. wi 8 rd EUE threads top and bottom and 2.5" CIW 'H' BPV profile 13 3/8" 72 ppf, L-80 Casing 1 115' 1 KB elev. = 30.10' DF elev. = 45.17' GL elev. = 16.50' i j , 136' , Cameo 2-7/8" x 1" sidepocket KBMM GLM 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 (ID = 3.958", cap = .0152 BPF ) 27/8" 6.5 ppf, L-80 8 rd EUE tubing (drift 10 = 2.347", cap = 0.00592 bpf) 19,739' 1 Camco 2-7/8~ x 1" sidepocket KBMM GLM , 9,859" , 9,889" 19,894" , 9,908'1 l 9,923'1 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 1 gsb3dbltabhsnfsa Motor, 95 HP, 1330 volt, 44 amp, Model KMH Centrilift Pumpmate gauge KOP @ 300 ' Max wellbore Angle: 75° @ 3300'-10,050' MO Hole angle trough perfs = 90 deg. 19,962'1 7"x5" Baker SLZXP Liner top pkr. Sleeve open during RWO {{¡~)i r ~perWindow 10,091' -10,103' ... ~--~~. " . I L2, [Q i 4.5" 12.6# L-80 I~T 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' 1 --- EZSV Bridge Plug #2 110,523' 1 (Above Abandoned Lateral) Halliburton float collar 111,113' I --- EZSV Bridge Plug #1 111,147' 1 ~ (~~~ve Abandoned Lateral) ~Iiburton Casing shoe 111,194'1 ~andoned Open-Hole DB Lateral to 12,205' MD 110,041'1 4.5" Baker CMO Sliding sleeve 4.5~ HES XXN Nipple (3.725" No-Go) 110,398' I XN Plug installed on rig 12/22/04 f10,419' ~, Baker Tie back stem 5.25" - 4.375" , Lower Window (10,505' - 10,518') =.,r:.~ I - Ilf:";:l,- I L1 ^ 83 jts 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) 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 (tf) API NO: 50-029-23014-Gi ~ '50' Oz.l1 -2~7)1 ~ - l.P{ -00 BP EXPLORATION (AK) 00 ) ) BP EXPLORATION OperatlonsSummary Report Page 1 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 --- 12/15/2004 11 :00 - 13:00 2.00 RIGO 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 OECOMP P/U Lubricator, pull BPV, UO Lubricator. RIU 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. 122:00 - 22:30 0.50 KILL P DECOMP Bleed down well to TP 20, CP 30. Circ hot seawater thru tbg I 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 ¡ @ 210 psi, for 530 Bbls, until S.5 ppg seawater returns cleaned I up. Monitor well--on vacuum. i 02:30 - 03:00 0.50 WHSUR P DECOMP Install TWC. RIO surface lines and HCR Valve. 103:00 - 04:00 1.00 WHSUR P DECOMP NIO Tree and Adaptor Flange. Load and tally 3-1/2" DP in Pipe I Shed. I i 04:00 - 07:00 3.00 BOPSUR P OECOMP N/U BOPE. Continue to load and tally OP in Pipe Shed. : 07:00 - 10:30 3.50 BOPSURP OECOMP PJSM. Perform complete BOPE test. All valves & rams tested ¡ @ 250 I 3500 psi. Annular preventor tested @ 250 13500 psi. I Perform drawdown test. No failures. Witnessing of test waived I I by AOGCC North Slope Rep Jeff Jones. i ! 10:30 - 11:30 1.00 PULL P DECOMP PJSM. Pick up lubricator. Pull two way check valve. MIU 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 61K. 12:00 - 13:30 1.50 PULL P DECOMP Rig up to pull ESP. UO hanger. Fill hole, 24 bbls to fill. Static fluid level is approximately 800'. 13:30 - 20:30 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. 12/17/2004 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-SO, EUE 8 Rd tubing. 01 :00 - 03:00 2.00 PULL P DECOMP Breakout, check and UD ESP components. 03:00 - 04:00 1.00 PULL P DECOMP RIH w/10 stds to find tubing punches. Found in 94th stand, breakout and UO bad joint. 04:00 - 04:30 0.50 PULL P DECOMP POH and SIB 2-7/S" 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 08:00 - 09:00 1 swing. Huddle up & discuss safe plan forward. 1.00 FISH P DECOMP PJSM. Pick up Lateral Diverter BHA. 09:00 - 18:00 9.00 FISH P DECOMP PJSM. RIH w/lateraJ diverter BHA on 31/2" DP, picking up DP 1 x 1, slowly, due to wind. 18:00 - 19:30 1.50 FISH P DECOMP P/U Kelly and get parameters: P/U 127K, S/O 25K. Work Diverter into top lateral, watch wt drop to 15K, P/U to -140K, S/O to 15K, P/U and get good indication of latching. Depth is 308 jts + 36' on Kelly = -10,109'. S/O and begin pumping 2 BPM @ 750#,3 BPM @ 1200#,4 BPM @ 2000#. Stop pump, P/U 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 Oerrick. 22:30 - 00:00 1.50 FISH P DECOMP MIU BHA #2: Bullnose Sub, 2-5/S" DB Cutter, VIP Mud Motor, Printed: 12/3112004 9:22:10AM .) ') BPEXPLORA TION Operations Summary Report Page 2 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 ------ 12/17/2004 ¡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. 101 :00 - 04:00 3.00 FISH P DECOMP RIH BHA #2 on 3-1/2" OP from Oerrick. i 04:00 - 04:30 0.50 FISH P OECOMP Position Cutter BHA above top of Oiverter at 10,089', enter and stop wi No-Go Stabilizer on top of Oiverter wI 309 jts + 6' in i hole. Cutter located @ 10,126'. I i 04:30 - 06:00 1.50 FISH P DECOMP Start pump and begin cutting operations; 1/2 BPMl800 psi to 1-1/2 BPM 3000 psi. Pump 1000 stks (59 Bbls), SD pump, then I resume to verify cut. i 06:00 - 07:00 1.00 FISH P OECOMP 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. J 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 3 1/2" OP. : 16:00 - 17:00 1.00 FISH P OECOMP PJSM. Stand back collars & UO motor I under-reamer assembly. 17:00 - 19:00 2.00 FISH P OECOMP 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 OECOMP RIH wI new Cutter BHA on OP from Oerrick. Position Cutter assy inside Diverter, P/U and establish parameters: P/U 123K, ¡ S/O 25 K. ; 23:00 - 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. I 12/19/2004 i 00:00 - 01 :00 1.00 FISH P OECOMP SID Pump, then restart to verify cut following step-rate to 1-1/2 ; BPM @3300 psi. OK. Break-out and SIB Kelly. 101 :00 - 05:00 4.00 FISH P DECOMP POH wi 2nd Cutter BHA, SIB DP in Oerrick. i 05:00 - 06:00 1.00 FISH P DECOMP Breakout and UO Cutter Assy, pull blades and evaluate same. I ¡ 06:00 - 07:00 1.00 FISH P DECOMP Inspection of blades inconclusive. (1) blade broken off at the i "hilt". Opt to run in wi GS pulling tool. MlU same. I ¡ 07:00 - 10:00 3.00 FISH P DECOMP PJSM. RIH wI GS retrieving tool on 3 1/2" DP, 309 jts total. 110:00 - 10:30 0.50 FISH P DECOMP PJSM. Pick up kelly & establish parameters. 137K up wt, 26K I down wt. Note slush I ice in returns. ¡ 10:30 - 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 retums coming back. I 111 :00 - 12:00 1.00 FISH P DECOMP PJSM. Kill pump & slack off, tag @ 10,090', (5') in on kelly. ¡ Stack out 5 - 10K. Pick up & see overpull to 151 K & lost ¡ 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 10,085' .... ? I 12:00 - 16:00 4.00 FISH P DECOMP PJSM. 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. ! 16:30.17:30 1.00 FISH P DECOMP PJSM. Pick up fishing BHA...4 1/2" spear, stop sub, bumper sub, oil jars, & (9) 4 314" DCs. 17:30 - 21 :00 3.50 FISH P DECOMP RIH BHA #4 on 3-1/2" DP. 121:00 - 22:30 1.50 FISH P DECOMP P/U Kelly, build 40 Bbls EP Mud Lube Pill. Spot same. 122:30 . 00:00 1.50 FISH P DECOMP Parameters: P/U 100K, S/O 50 K. Slowly work down into Diverter and stack out @ 10,090'. Engage and P/U 200K, no give. Work pipe to set off jars @ 200 - 220K for 1-hour, pulled as high as 275K with no success. Mix up dry job to prepare to POOH. Printed: 12/3112004 9:22:10 AM ) ) BP EXPLORATION Operations Summary Report 12/20/2004 ¡ 00:00 - 04:00 4.00 FISH N DFAL OECOMP ; 04:00 - 05:00 1.00 FISH N OFAL DECOMP .05:00 - 08:30 3.50 FISH N DFAL DECOMP : 08:30 - 09:30 1.00 FISH N DFAL DECOMP Legal Well Name: MPC-41 Common Well Name: MPC-41 Event Name: WORKOVER Start: 12/15/2004 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/27/2004 Rig Name: NABORS 4ES Rig Number: Date I From - To Hours Task Code NPT Phase ------ --. -~. --------- : 09:30 - 10:30 1.00 FISH N DFAL DECOMP .10:30 - 12:00 1.50 FISH N DFAL DECOMP 12:00 - 15:00 3.00 FISH N DFAL DECOMP 15:00 - 16:00 1.00 FISH N DFAL DECOMP : 16:00 - 20:00 4.00 FISH N DFAL DECOMP ; 20:00 - 21 :30 1.50 FISH N DFAL DECOMP ¡ 21 :30 - 00:00 12/21/2004 :00:00 - 01:00 i 01 :00 - 04:00 104:00 - 08:00 I ¡ 08:00 - 09:30 I I ! ¡ í I I I I 109:30 - 10:30 I 110:30 - 11 :30 ¡ 2.50 FISH 1.00 FISH 3.00 FISH N N N DFAL DECOMP DFAL DECOMP DFAL OECOMP 4.00 FISH 1.50 FISH N P DFAL DECOMP DECOMP 1.00 FISH P DECOMP 1.00 FISH P DECOMP Page 3 of 6 Spud Date: 5/28/2001 End: Description of Operations --"- Pump dry job and POOH, SIB OP in Derrick. Break-out and UD 4-1132" Spear, Bumper Sub, Oil Jars. M/U BHA #6 Lateral Oiverter, 5" Baker GS running tool, 9-DCs. RIH wI BHA #6, on OP from Derrick. 30S jts total. PJSM. Kelly up & establish parameters. 88K up wt, 55K down wt. Slack off, kelly all the way down. Add 5' pup. Tag up 3S' in on # 308. Bottom of diverter @ 10,111'. Set down 15K & pick I up, see overpull of 10K, verified latched in. Set back down wI 10K on hanger. Bring on pump @ 4 bpm 11700 psi & slowly come off diverter wI GS running tool. Max weight up = 91 K. POOH wI GS running tool. PJSM. Slip & cut drilling line. Continue to POOH wI GS running tool. PJSM. UO GS running tool. P/U 3 1/S" Multi String Cutter Assembly. RIH w/3 1/8" Multi String Cutter. Position Multi-string Cutter @ 10,120' and establish free rotation parameters: P/U 84K, S/O 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. POH and SIB OP. Continue POH wI Multi-cutter BHA. SIB DC's, UD 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. RIH wi same Multi-String Cutter and blades. 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, frees pin torque @ 3000 ftIlbs, 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 1st 5 minutes, maybe 200 - 300 ftIlbs, then dropped back to 3000 ftIIbs. 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 kelly indicating cut. PJSM. Reverse circulate 1.5 OP volumes @ 5 bpm /1100 psi. Observe some pipe dope but no solids in returns. 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 & 1 st 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 51/2 bpm @ 2000 psi. Continue with cut for 30 minutes. Kick off pump & rotary table, Printed: 12/31/2004 9".22:10 AM ) ) BP EXPLORATION Operations Summary Report Page 4 of 6 Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 5/28/2001 Event Name: WORKOVER Start: 12/15/2004 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/27/2004 Rig Name: NABORS 4ES Rig Number: From - To Hours Task Code NPT Phase Description of Operations ------. 12/21/2004 10:30 - 11:30 1.00 I FISH P OECOMP 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 I FISH P OECOMP PJSM. Stand back kelly & POOH wI 3-1/8" multi string cutter I assembly. Blades on the Multi-String Cutter had wear patterns I i that indicate metal cutting had been accomplished, but not sure ! whether or not tubing wall has been fully cut. Wear patterns on ì actuating fingers of each blade show that the blade fingers I were heavily impacted by the pressure transfer piston. The i wear on these fingers was much more severe than on the I j previous run of this tool and on the blades run with the VI P 1.00 I FISH Mud Motor. 15:00 - 16:00 P OECOMP Clear and clean Rig Floor. 16:00 - 20:00 4.00 i FISH P DECOMP P/U GS Spear and RIH to pull Oiverter. 20:00 - 20:30 0.50 I FISH P DECOMP Get parameters: P/U wt = 80K, SIO wt = 52K. Work Spear into i I Diverter, set down to 42K, P/U and see required overpull of I 10K (-90K), and Oiverter pulled free. I 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 UO 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 OECOMP Continue TIH from Derrick. 07:30 - OS:OO 0.50: FISH P DECOMP Engage fish @ 10,091', P/U wt 80K, S/O wt 56K. Jar to 100K I overpull; fish came free, P/U then set back down and tag 3' I high. Joy! 08:00 - 11 :00 3.00 I FISH P DECOMP Monitor hole, then TOH wI fish, SIB OP and OC'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-SO cut jt = 6.2'; total = -33.5'. 12:30 - 16:30 4.00. FISH P DECOMP MIU BHA #10: 4-15/16" Tieback Polish Mill, Liner top Dress-off Mill, Bumper Sub, Oil Jar, 9-DC's, 1 jt 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, S/O 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 jts 3-1/2" DP. M/U Kelly, P/U wt 90K, SIO 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 Oerrick. 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 RUNCOt\fP RUNCMP Lube Rig. 06:30 - 07:00 0.50 RUNCOt\fP RUNCMP Rig up to handle 4/2" Tubing. 07:00 - 08:30 1.50 RUNCOt\fP RUNCMP Make-up Tie-Back Packer Assy as follows: Tie-Back Stem, Printed: 12/31/2004 9:22:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/23/2004 07:00 - 08:30 08:30 - 09:00 09:00 - 13:30 13:30 - 15:30 15:30 - 16:00 16:00 - 20:30 20:30 - 21:00 21 :00 - 22:00 22:00 - 00:00 12/24/2004 00:00 - 03:00 03:00 - 06:00 06:00 - 07:00 07:00 - 13:30 ) ) Page 5 of 6 BP EXPLORATION Operations Summary Aeport MPC-41 MPC-41 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES To Hours Task Code NPT Phase -"---- 1.50 RUNCOt I RUNCMP i 0.50 I RUNCO~ 4.50 I RUNCO~ ! I 2.00 I RUNCO~ I ¡ I ' I ¡ I i 0.50 I RUNCO~ ! I I 4.50 I BOPSUA P I ¡ , I ! 0.50! BOPSU~ P 1.00 WHSUR I P 2.00 WHSUR ¡ P I 3.00 I' WHSUR i P 3.00 RUNC°tfP ! RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP 1.00 RUNCOfv1\J RUNCMP 6.50 RUNCOfv1\J RUNCMP 13:30 - 14:00 0.50 RUNCOfv1\J RUNCMP 14:00 - 16:30 2.50 RUNCOtvt-J RUNCMP 16:30 - 17:30 1.00 RUNCOtvt-J RUNCMP 17:30 - 00:00 6.50 RUNCOtvt-J RUNCMP 00:00 - 13:30 13.50 RUNCOtvP RUNCMP 13:30 - 14:30 1.00 RUNCOtvP RUNCMP 14:30 - 16:00 1.50 RUNCOtvP RUNCMP 16:00 - 16:30 0.50 RUNCOtvP RUNCMP 16:30 - 00:00 7.50 RUNCOtvP RUNCMP 00:00 - 02:00 2.00 RUNCOtvP RUNCMP 12/25/2004 12/26/2004 Start: 12/15/2004 Rig Release: 12/27/2004 Rig Number: Spud Date: 5/28/2001 End: Description of Operations XN-Nipple wlXXN Plug installed, 4 1/2" XO Tubing Joint,S ea 41/2" Jts Tubing, 41/2" XO Tubing Joint, Sliding Sleeve in open position, 4 112M XO Tubing Jt, 7" x 5" Baker SL ZXP Liner Top Packer. Rig up to handle 31/2" Drill Pipe. TIH with Tie-Back Straddle Assy and 7" Baker SLZXP Liner Top Packer on 314 Jts 3-1/2" OP. 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 1 000 psi, bleed off, rotate off packer. UD 6-jts 3-1/2" DP. M/U landing jt and tubing hanger, P/U wt 83K, land hanger, RILOS. Install TWC. Perform weekly BOPE test per AOGCCIBP requirements. Jeff Jones, AOGCC, waived the right to witness BOPE test. Pressure test 250 psi low and 3500 psi high. Rig up libricator, pull TWC, UO same. Close blind rams, N/D Flow Nipple, N/U Shooting Head. RlU SWS W/L running equipment, BOPE stack, and Grease Injector. Continue to N/U SWS equipment. RIH wI SWS Pressure Recording Tool. Progress stopped @ -4400'. RlU lines and pump 1-1/2 BPM to move tools downhole. Bolted flange on top of Hydrilleaking. Attempt to tighten. No-Joy. Start POOH with E-Line. 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. 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-cage8. SW5...Change Grease Tubes, re-build Grease Head, cut and re-head Cable. Rig Crew replace Ring Gasket under bolted flange. Pick-up Lubricator and Tool String. Pressure test at 1,000 psi for 5 min. Good. RIH wI SWS Pres/Temp Tool. Pump tool down from -4,000'. Wait for tubing pressure to stabilize. 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. Continue downhole pressure monitoring @ 9250'. POH wi SWS E-line and Pressure Recording Tool. RID SWS, clear Pipe Shed, N/D Shooting Flange, N/U Flow Nipple. MIU landing joint, BOLDS, pull and UO Hanger. TOH and UD DP. Breakout and UD Liner Hanger Running Tool. Clear and clean Rig Floor. RlU 2-7/8" handling equipment and Printed: 12/31/2004 9:22:10 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date '> ) Page 6 of 6 BP EXPLORATION Operations Summary Report 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: From - To Hours Task Code NPT Phase --.-.---- 12/26/2004 00:00 - 02:00 02:00 - 06:30 06:30 - 08:00 08:00 - 09:00 09:00 - 11 :00 11 :00 - 20:00 20:00 - 22:30 22:30 - 00:00 12/27/2004 00:00 - 04:30 04:30 - 06:00 06:00 - 06:30 06:30 - 14:30 14:30 - 15:00 15:00 - 19:00 19:00 - 19:30 19:30 - 21 :30 21 :30 - 23:30 23:30 - 00:00 Description of Operations 2.00 RUNCOtvP ---_._--- 4.50 RUNCOtvP 1.50 RUNCOfvP 1.00 RUNCOfvP 2.00 RUNCOfvP 9.00 RUNCOIVN 2.50 RUNCOfvP 1.50 RUNCOfvP 4.50 RUNCOfvP 1.50 RUNCOfvP 0.50 RUNCOfvP 8.00 RUNCOfvP 0.50 RUNCOfvP 4.00 RUNCOfvP 0.50 RUNCOfvP 2.00 BOPSUP P 2.00 WHSUR P 0.50 WHSUR P i ¡WAIT I I I RUNCMP Centrilift ESP equipment. Load ESP assembly in Pipe Shed. Check and tally same. RUNCMP P/U and service ESP Pump and Motor. RUNCMP Well started to flow - 1-Bb1/20 minutes. Called E-Pad Operator to SII injection. Monitor well. Fluid level began to drop. RUNCMP Make ESP cable connection to motor. Secure cable wi Motor Lead Flat Guards. Test Cable, okay. TIH wi ESP, make 2900' and SID for Phase 3 weather. SIO ESP RIH Operations for Phase 3 weather. Resume TIH wi new ESP. RIU 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 I installing Heat Trace Flat Guards while concurrently TIH wI ESP Cable on 2-7/8" tubing from Derrick. RUNCMP RIH wi new ESP, installing Heat Trace Flat Guards w/1" steel straps, and checking cable electrical integrity every 2000'. I Averaging 4-stands per hour. RUNCMP I Make Reel-to-Reel splice in ESP power Cable. RUNCMP Lub Rig. RUNCMP Continue TIH wi ESP to 9924'. RUNCMP M/U landing joint to tubing hanger. Install penetrators. RUNCMP Space out Heat Trace pig tail. Make Upper ESP Cable connector splice. Make Heat Trace connector splice. RUNCMP Land tubing hanger. P/U wt = 50K, S/O wt = 30K. RILOS. Set TWC. RUNCMP N/O BOPE. RUNCMP N/U Tree and test tree and void to 5000 psi. Make final ESP Power and Heat Trace Cable tests, good. RUNCMP P/U Lubricator and pull TWC, install BPV. Secure Tree and Cellar. Release rig @ 0000 hours, 12/27/2004. RUNCMP RUNCMP RUNCMP RUNCMP Printed: 12/31/2004 9:22:10 AM STATE OF ALASKA .... ALASK~ JIL AND GAS CONSERVATION C~,v,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: [] Abandon [] Suspend [] Operation Shutdown [] Pedorate [] Variance [] Othe~ [] Alter Casing [] Repair Well [] Plug Perforations [] Stimulate [] Time Extension Change Out ESP [] Change Approved Program [] Pull Tubing [] Perforate New Pool [] Re-Enter Suspended Well [] Annular Disposal , 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. [] Development [] Exploratory 201-079 3. Address: [] Stratigraphic [] Service 6. APl Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23014-60-00 7. KB Elevation (ft): KBE= 45.17' 9. Well Name and Number: MPC-41L1 8. Property Designation: 10. Field / Pool(s): ADL 025518 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 14148 feet true vertical 4339 feet Plugs (measured) N/A Effective depth: measured 13955 feet Junk (measured) N/A true vertical 4343 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 13-3/8" 110' 110' 1530 520 Surface Intermediate Production 10468' 7" 10505' 4323' 7240 5410 Liner 3404' 4-1/2" 10406' - 13810' 4300' - 4345' Perforation Depth MD (ft): 10515'- 13765' Slotted Liner Perforation Depth TVD (ft): 4325' - 4458' Slotted Liner Tubing Size (size, grade, and measured depth): 2-7/8", 6.5# L-80 9986' Packers and SSSV (type and measured depth): 4-1/2" Baker Payzone Packer from 13954'- 13977' i", ' '~ ,,,','~'"i,, i;i' ....... ~"'~/ ~'" '~ ~'~" 12. Stimulation or cement squeeze summary: I,'l ,,' ,,,,, :,., ;,,! ,:?:.' : .,,,,~, Intervals treated (measured): ,~ 1 il"' ~I ":;'~"'~ ~',.[ ['~,~' Treatment description including volumes used and final pressure: 13. Representative Daily Avera~le Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin.q 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 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.C. Exempt: Contact Robert Odenthal, 564-4387I N/A ,,, Printed Name Sondra Stewman Title Technical Assistant Prepared By Name/Number: · Phone 564-,4750 Date~'/(~'-[")~' Sondra Stewman, 56~4-4~75Q~,~ Form 10-404 Revised 2/2003 ,qRiGiNAL 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. Scoped 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. Tubing 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 l/Sth, 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 I 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 10:54:59 AM BP EXPLORATION Page 2 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 -- 8/4/2003 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 P DECOMP Pulled ESP Cable over Sheave and Connected to Spooling Unit Reel. 08:00 - 10:00 2.00 PULL P 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 P DECOMP Repaired Elephant Trunk on Spooling Equipment. Shot Fluid Level - 2,500'. 10:30 - 12:30 2.00 PULL P 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 P 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 RUNCOI~ 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 RUNCOI~ 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 RUNCOI~ 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 RUNCOi~' 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 RUNCOi~ 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 RUNCOI~ 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 RUNCOI~ i COMP R / U to Run Heat Trace. M / U Flat Guards w/Bands. 08:30 - 17:30 9.00 RUNCOI~ i COMP RIH w/ESP Pump, ESP Cable and Heat Trace on 2-7/8" 6.5# 8rd Tubing. M / U Torque 2,350 ft / lbs. Tested Cable and Printed: 8/11/2003 10:54:59 AM BP EXPLORATION Page 3 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 -- 8/5/2003 08:30 - 17:30 9.00 RUNCOI~P 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 RUNCOr~' : 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 RUNCO~ 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 RUNCOI~P 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 BOPSUIq 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 WHSUR P COMP Held PJSM. R / U DSM Lubricator, Pulled TWC, 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: 8/11/2003 10:54:59 AM Permit to Drill 2010790 DATA SUBMITTAL COMPLIANCE REPORT 7~30~2003 Well Name/No. MILNE PT UNIT SB C-41L1 Operator BP EXPLORATION (ALASKA) INC MD 14148 -" TVD 4339 .~'"~-Completion Dat 7/17/2001 ---- Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-23014-60-00 UIC N REQUIRED INFORMATION Mud Log N_po Sample N._~o Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital l~edia Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments Directional Data FINAL ~ED'~ D Ver LIS Verification ~ D Ver LIS Verification , ~ D Ver LIS Verification ~--R'''''~' R Directional Data !,,R''''~ R Directional Data !j D Directional Data ~ ~ Cn See Notes oh 8/20/2001 Directional Data MWD ,~ital data 1 75 12137 Open 12/28/2001 10504 ' 1 75 8716 Open 12/28/2001 10503~' 1 75 14097 Open 12/28/2001 10499--c,//''~ FINAL oh 8/20/2001 Directional Data MWD FINAL oh 8/20/2001 Directional Data FINAL oh 8/20/2001 Directional Data digital data 1 75 14148 Open 1/17/2002 L,,1~99 Digital Data NOTE: No paper logs were received MD AND -FVD Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y,/(~ Chips Received? Analysis Y,..~- R~.nc. iv~.d ? Daily History Received? ""~ / N Formation Tops ~/N Comments: Permit to Drill 2010790 DATA SUBMITTAL COMPLIANCE REPORT 7130/2003 Well Name/No. MILNE PT UNIT SB C-41L1 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23014-60-00 MD 14148 'I'VD 4339 Completion Dat 7/17/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Date: To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7t~ Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPC-4I L1, AK-MM-10166 December 15, 200'1 MPC-41 L2: Digital Log Images: 50-029-2301,4-60 I CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACI:I-ED 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 Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVEI ,g d: · I JAN I ? 2002 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-41 PB 1, AK-MM- 10166 1 LIS formatted Disc with verification listing. API#: 50-029-23014-70 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 99518 BP iExplomtion (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: RECEIVED DEC 2 8 2001 Aiaska O~ & Gas ~ons. .Ancr,..,,oraf~e 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-41 PB2, AK-MM-10166 1 LIS formatted Disc with verification listing. API#: 50-029-230114-71 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 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: DEC 2 8 2001 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-41L1, AK-MM-10166 1 LIS formatted Disc with verification listing. API#: 50-029-23014-60 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 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: 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 [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-079 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23014-60 4. Location of well at surface , ~,r.,.,~ ~. ~:r,~.~ .~ , l" .......... ..... ~':'~ ~,,, ~-~. 9. Unit or Lease Name 694' NSL, 2298' WEE, SEC. 10, T13N, RIOE, U M ~ u;'~r- ~ ~ ---7 .'"-~ ..~' '"'~"'~'"" Milne Point Unit At top of productive interval ~ --,'-~-/.-/-~---7~ I V~ll:l~ At total depth~',' ~-- ~ t ~. ~ MPC-41 L1 495' SNL, 913' EWL, SEC. 26, T13N, R10E, UM ~ ............................ :d ~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ,11. Field and Pool Milne Point Unit / Schrader Bluff KBE = 45.17' ADL 025518 12. Date Spudded6/16/2001 113' Date T'D' Reached 114' Date c°mp'' Susp'' °r Aband'6/21/2001 7/17/2001 115' Water depth' if °ftsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+'rvD) 119. Directional Survey 1 20. Depth where SSS¥ set121. Thickness of Permafrost 14148 4339 FTI 13955 4343 FTI [] Yes [] NoI N/A MDI 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 SIZE CEMENTING RECORD AMOUNT PULLED 20" x ~3-3/8"94# / 54.5# H-40 / J-55 Surface 110' 30" 260 sx Arctic Set (Approx.) 7" 26# L-80 37' 10505' 9-7/8" 1456 sx Arctic Set II1~ 792 sx Class 'G' 4-1/2" 12.6# L-80 10406' 13810' 6-1/8" Uncemented Slotted Liner , 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE ' DEPTH SET (MD) PACKER SET (MD) ' ' 4-1/2" Slotted Section 2-7/8", 6.5#, L-80 10001' N/A MD TVD MD TVD 10515' - 13765' 4325' - 4345' 26. AC~D, 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. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 24, 2001 Electric Submersible Pump ~ate of Test Hours Tested PRODUCTION FOR OIL-aBE GAS-MCF WATER-aBE CHOKE SIZE I GAS-OIL RATIO 8/21/2001 6 TEST PERIOD 1635 437 266I 267 ~10w Tubing Casing Pressure CALCULATED OIL-aBE GAS-MCF WATER-aBE O1~ GRAVITY-APl (CORR) ' Press. 24-Hour RATE _28. CORE DATA Brief desc~iPti0n of lithol0gYl p0~osity, fractu'resl apparent dips a~d presence of"0il, gas or waie'~iF~U~~'i'~Ea .............. AUG 001 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Schrader OA 10501' 4322' Top Schrader OA 12176' 4339' Base OA / TSBC 12820' 4367' Base OA / TSBC 13015' 4363' Top Schrader OB 13970' 4340' 31. List of Attachments: Su'mmary of Daily Drilling Report's, Surveys ........ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble --~/~.~ ~ Title Technical Assistant Date MPC-41 L1 201-079 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 Legal Name: MPC-41 Common Name: MPC-41 Test Date Test TYpe Test Depth. (TMD) ~ Test Depth: (TVD) 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 ~PLORA¥1ON ' ' · Page 1 of 19 O.perations' Summary Report .. Legal Well Name: MPC-41 Common Well Name: MPC-41 Spud Date: 512812001 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 iFrom~To ~ctivitYcodel UPT :PhaSe: :i: ::,: Description of OPerations '.. 5/26/2001 12:00 - 00:00 12.00 MOB P 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 P PRE Hold Pre-Job Safety Meeting With All Nabors Personal And Peak Equipment Operators 00:30 - 01:00 0.50 MOB P PRE Move Sub Base Off Of Well Slot No. E-29i & Position On Pad 01:00 - 03:00 2.00 MOB P 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 Trailor - 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 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 · B P ExPEo RATIO N ·Page 21:,~)f:'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,Toi Hours Activity codei NPT, ,·phase: Description :of Operati0nS , 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 P 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 P SURF Make Up UBHO Sub & Stand Back In Derrick 21:30 - 22:00 0.50 DRILL P SURF Pick Up 5" Drill Pipe From Pipe Shed And Stand Back In Mast 22:00 - 23:00 1.00 DRILL P SURF Electrical Problem Sorted Out (Plug In Hall Way) Make Up BHA From Derrick & Initialize MWD Tool 23:00 - 00:00 1.00 DRILL P 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 fi-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-lbf torque on btm, 3000 ft-lbf torque off btm, 70 rpm top drive. 1650 psi on btm, 1400 psi off btm, at 530 gpm. 17:00 - 21:00 4.00 DRILL 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 ",' BP EXPLORATION Page~3 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 ,, ,. ..... , ,, , , 5/30/2001 22:30 - 00:00 1.50 DRILL P SURF 4500/3000 ft-lbf on/off btm, 140k PUW, 125k SOW, 130k ROTW. 5/31/2001 00:00 - 08:00 8.00 DRILL P 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 ROTVV. 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 MVVD. 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 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. 6/1/2001 00:00-13:00 13.00 DRILL P SURF Drill 6065'-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 pumps, 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, ROTW 142k, Torque on/off btm 14,000/10,000 ft-lbf. Pump on/off btm 2350/2050 psi. 10-30k WOB. 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 VVOB. 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 them 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 Service top 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, 20 jts HWDP. Printed: 7/2312001 11:49:12 AM Bp ExpEORATION-- Page 4of 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, T° HoUrs· Activity, code Phas~ ' Description of OPerations 6/2/2001 21:00 - 21:30 0.50 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 ~ SURF Drill 9915-10493'. Control drill 100 fph 10943-10572'. Top of CA 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 215011950 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 3 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 its. 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 Service 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 its then every 10th joint down starting at jt 140. Relief crew came Printed: 7123/2001 11:49:12 AM BP EXPLORATION Page 5 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 , 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~, LB0, 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 spin, 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 CVV100 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 Cl G 15.8 ppg, 1.17 cf/sk at 5.8 bpm. 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 BOPSUFiP SURF ND 20" riser. Finish cut on 7" csg. ND knife valve to flow-line & mud cross. 08:00 - 15:30 7.50 BOPSUFiP 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 6 0f',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 "i'Date .:. From ~'T0' 'H°Urs~ ACtiVitYcode" NPT Phase':: i : ':' Description of.OperatiOns ' ...... 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 fl 10 rains. 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 BOPSUFiN RREP SURF Inside BOP on Top Drive leaking. Remove pipe handler on top drive. Replace IBOP. Re-install pipe handler. 6/10/2001 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/99jts. POOH & stand back 3 1/2" DP. 18:30 - 00:00 5.50 DRILL P PROD1 MU bit, DGR/EWPJDM/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 spin, 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 Drill Ahead 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.Summary Rep°rt 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 :, -i,o' H0urS,ActiVity code NPT phase· Description of:OPerations:, : , 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 F3ROD1 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 I 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 ,lob 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: 7/23/2001 11:49:12 AM BP 'EXPLORATION Page:8' 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 i!:From.To HOUrs ACtivity.code 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 STWHIP 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! STWHIP 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 Down 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 STWHIP 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 MWD 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 EXPLORATION Page'9 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: N^BORS Rig Release: 7/12/2001 Rig Name: NABORS 22E Rig Number: 22E Date ,From, To'. ~H°urs 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 I 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 And 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 DFAL 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 1eof 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 6/18/2001 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 113:00 - 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 MVVD 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 03:30 - 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 2KTo 1OK With Pump Rate At 55 Strokes Or 233 GPM - Off Bottom Pump Pressure At 2325 Psi. & On Bottom Pump Pressure At Printed: 7123/2001 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 ActivityCode .,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 10K 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: 7/2312001 11:49:12 AM . Bp:EXpLORATION Page 12.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 ActivityCode 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. 07:00 - 09:00 2.00 DRILL 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 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. 18:30 - 00:00 5.50 CASE 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 "OA" Sand Open Hole Section To Float Shoe Depth At 14,141' - Top Of LSV At 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 C 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 "OA" 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: 7/23/2001 11:49:12 AM BP EXPLORATION Page 13 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° H°urs. ACtivity' Code NPT Phase DescriPtion of Operations : , ...... 6/24/2001 18:30 - 19:00 0.50 REMCM-I'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 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 PROD2 Circulate 2 7/8 Inner String And Bushing To Guide Shoe Volume 07:30 - 15:30 8.00 CASE P PROD2 RIH With 4 1/2" L-80 IBT 12.6 lb. Slotted Liner With 112 Stands Of 3 1/2" Drill Pipe From Mast To Window - Record Weight'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 P 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 P 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 its). 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. 14:00 - 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 ofi9 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 6/27/2001 15:30 - 21:00 5.50 S'I-WHIP 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 mins. 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 load 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 OA 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 mins. 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. Offioading 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 OA 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 OA lateral L-2.70 rpm, 5-10K WOB, 55 spm, 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 OA lateral L-2 per wellsite geologist. Add 300 bbls new BaradrilN mud AT.- 13600'. 140k PUW, 85k SOW, 112 ROTVV, 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 PROD3 MU 6 1/8" hole opener, stabilizer, DC, stabilizer, 2-DC, 2-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 spm, 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 ft-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: 7123/2001 11:49:12 AM BP EXPLORATION Page 15' 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 · , , , 7/2/2001 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 DH^. 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 w/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, .PVVD, 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 it, 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 °f 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 .. ,, 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. I 7/6/2001 '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 rains. Pump "dry job", blow-down top drive & mud line. 11:00 - 15:00 4.00 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, TIW 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 jt(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: 7/2312001 11:49:12 AM BP EXPLORATION Page.17of 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 .... 7/7/2001 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'. 7/8/2001 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 its 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 2.50 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 Page18°f 19 OPerations Summary' Report ,. iLegal 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. 711012001 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 IR 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 TA P 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 P 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 P 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: 7/2312001 11:49:12 AM BP EXPLORATION Page 19 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 , , ....... 7/12/2001 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: ' Date From- TO HourS=; ACtivity COde NPT iPha~e ·:' . · 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 SETAND BERM TIGER TANK. RIG UPANDTEST 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 DOPE. 19:30 - 20:30 1.00 PULL P DECOMP TEST DOPE 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 W'I' 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 W/5 STDS. STOP FLOW CHECK WELL. STILL SLIGHT FLOW FROM WELL. RIH W/5 STDS. PREP TO WT UP. 01:30 - 04:00 2.50 REST P DECOMP VVT UP FROM 9.1# TO 9.3#. 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~ ~ COMP 2-7/8" TIH W/ESP TO 6100-FT. INSTALL LASALLE CLAMPS EVERY COLLAR. 15:30 - 18:30 3.00 RUNCOI~' COMP CHANGE OUT REEL & SPLICE CABLE. 18:30-21:00 2.50 RUNCOI~ COMP CONTINUE TIH WELL. 231 JTSTIH. MU GLM W/ DUMMY. INSTALL LASALLE CLAMPS EVERY OTHER COLLAR. 21:00 - 21:30 0.50 RUNCOI~ COMP MU CAMCO GLM W/DPSOV INSTALLED. MU HANGER & LJ. INSTALL PENETRATOR. 21:30 - 23:00 1.50 RUNCOI~ COMP SPLICE EFT CONNECTOR. TEST GOOD. 23:00-23:30 0.50 RUNCOI~' COMP POW=48K. SOW= 29K. LAND HANGER, RILDS, INSTALL & TEST TVVC. 23:30 - 00:00 0.50 RUNCOI~ COMP ND DOPE 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 11:00:46 AM I MILNE POINT, ALASKA WELL TELEX TO: BixbylSmith Date: 17/18/01 FROM: Dale DeYonge Operational Cost: Well Name: IMPC-41 HB&R $1040.00 Main Category: IDRLG Diesel $945.00 Sub Category: I Freeze protect Operation Date: 17/17/01 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 InitiaIWHP: 100 IA: 500 OA: Final WHP: IA: OA: Diesel Used [15 bbls I Methanol Used [0 Diesel = $ 945.00 DRLG / Freeze Protect / Diesel 337243 - 9335-070-765 14-Aug-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Survey Re: Distribution of Survey Data for Well MPC-41 L1 Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 10,505.00' MD 10,551.26' MD 14,148.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) DEF N T VFz Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-41 MPC-41 L 1 Job No. AKZZ11092, Surveyed: 21 June, 2001 SURVEY REPORT 14 August, 2001 Your Ref: API-500292301460 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) DRILL. lNG S ER:V I E E"~ Survey Ref: svy9920 A Halliburton Company Sperry-Sun Drilling Services Survey Report for MPC-41 L 1 Your Ref: API-500292301460 Job No. AKZZ11092, Surveyed: 21 June, 2001 Milne Point Unit Measured Depth m) 10505.00 10551,26 10587.67 ... 10632.49 1 O678.46 Incl: 77.524 81.470 84.380 84.760 85.250 164.054 164.110 164.150 164.210 164.270 Sub-Sea Depth (ft) 4277.92 4286.36 4290.84 4295.08 4299.08 Vertical Depth (ft) 4323.09 4331.53 4336.01 4340.25 4344.25 10725.72 86.300 164.560 4302.57 4347.74 10771.83 88.710 166.070 4304.57 4349.74 10825.87 90.430 167.580 4304.98 4350.15 10864.08 90.180 166.820 4304.77 4349.94 10910.96 89.820 166.650 4304.77 4349.94 10956.99 90.060 167.030 4304.82 4349.99 11002.08 88.830 165.690 4305.26 4350.43 11050.43 89.080 163.940 4306.14 4351.31 11096.11 89.010 163.490 4306.90 4352.07 11142.22 91.420 165.750 4306.73 4351.90 11234.77 90.800 165.600 4304.94 4350.11 11326.89 92.160 165.810 4302.56 4347.73 11415.05 93.880 165.850 4297.91 4343.08 11472.08 89.380 165.890 4296.29 4341.46 11505.17 88.650 165.580 4296.86 4342.03 11599.72 90.120 166.340 4297.88 4343.05 11648.25 91.110 165.810 4~97.35 4342.52 11689.84 91.480 165.360 4296.41 4341.58 11734.65 91.050 165.210 4295.42 4340.59 11780.97 91.290 164.530 4294.48 4339.65 11824.95 90.060 163.830 4293.96 4339.13 11871.31 90.310 162.620 4293.81 4338.98 11918.32 90.310 162.340 4293.56 4338.73 11964.12 89.510 162.250 4293.63 4338.80 12010.17 90.120 160.850 4293.78 4338.95 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 8248.00 S 2245.73 E 6020746.21N 560475.71E 8291.73 S 2258.20 E 6020702.58 N 560488.52 E 8326.48 S 2268.08 E 6020667.90 N 560498.68 E 8369.41S 2280.25 E 6020625.07 N 560511.17 E 8413.49 S 2292.69 E 6020581.09 N 560523.96 E 8458.88 S 2305.35 E 6020535.80 N 560536.97 E 8503.44 S 2317.03 E 6020491.33 N 560549.00 E 8556.05 S 2329.34 E 6020438.82 N 560561.73 E 8593.31 $ 2337.81E 6020401.63 N 560570.48 E 8638.94 S 2348.56 E 6020356.08 N 560581.60 E 8683.76 S 2359.04 E 6020311.34 N 560592.43 E 8727.58 S 2369.68 E 6020267.61 N 560603.40 E 8774.23 S 2382.34 E 6020221.06 N 560616.43 E 8818.07 S 2395.14 E 6020177.32 N 560629.58 E 8862.52 S 2407.37 E 6020132.97 N 560642.15 E 8952.18 S 2430.27 E 6020043.49 N 560665.75 E 9041.41S 2453.00 E 6019954.44 N 560689.18 E 9126.77 S 2474.56 E 6019869.26 N 560711.40 E 9182.04 S 2488.47 E 6019814.10 N 560725.74 E 9214.10 S 2496.62 E 6019782.10 N 560734.15 E 9305.82 S 2519.56 E 6019690.56 N 560757.80 E 9352.92 S 2531.23 E 6019643.56 N 560769.85 E 9393.19 S 2541.59 E 6019603.37 N 560780.51 E 9436.52 S 2552.96 E 6019560.13 N 560792.23 E 9481.22 S 2565.05 E 6019515.52 N 560804.67 E 9523.53 S 2577.04 E 6019473.30 N 560816.99 E 9567.92 S 2590.42 E 6019429.02 N 560830.71E 9612.75 S 2604.57 E 6019384.31N 560845.21E 9656.38 S 2618.50 E 6019340.79 N 560859.48 E 9700.06 S 2633.07 E 6019297.22 N 560874.40 E Dogleg Rate (°/100ft) 8.531 7.993 0.858 1.074 2.304 6.166 4.235 2.094 0.849 O.976 4.034 3.656 0.997 7.165 0.689 1.494 1.952 7.891 2.397 1.750 2.314 1.401 1.016 1.557 3.218 2.665 0.596 1.758 3.316 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 8548.26 Tie On Point 8593.74 Window Point 8629.86 8674.48 8720.27 8767.40 8813.46 8867.46 8905.64 8952.49 8998.49 9043.56 9091.90 9137.56 9183.67 9276.19 9368.26 9456.28 9513.26 9546.34 9640.86 9689.38 9730.95 9775.75 9822.06 9866.03 9912.37 9959.35 10005.10 10051.08 14 August, 2001 - 13:01 Page 2 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 L1 Your Reft API-500292301460 Job No. AKZZ11092, Surveyed: 21 June, 2001 Milne Point Unit Measured Depth (ft) 12057.11 12124~48 12167.96 ... 12209.76 12257.58 Incl; 91.17o 91.050 85.010 86.990 88.030 Azim. 160.930 159.060 157.830 161.830 161.230 Sub-Sea Depth m) 4293.25 4291.94 4293.44. 4296.35 4298.43 Vertical Depth (ft) 4338.42 4337.11 4338.61 4341.52 4343.60 12302.92 86.370 165.790 4300.65 4345.82 12350.12 86.740 164.210 4303.48 4348.65 12394.97 86.680 163.580 4306.06 4351.23 12441.44 88.280 164.910 4308.10 4353.27 12490.92 88.340 164.990 4309.56 4354.73 12532.91 88.710 165.210 4310.64 4355.81 12585.59 86.620 163.730 4312.79 4357.96 12624.72 88.950 167.780 4314.30 4359.47 12669.61 89.200 167.680 4315.03 4360.20 12716.99 86.920 168.220 4316.63 4361.80 12762.80 87.160 167.350 4319.00 4364.17 12807.39 87.410 165.410 4321.11 4366.28 12855.24 87.840 167.560 4323.09 4368.26 12900.80 91.050 166.370 4323.53 4368.70 12946.13 91.790 167.460 4322.41 4367.58 12992.29 94.740 167.080 43t9.78 4364.95 13037.23 95.180 167.090 4~15.89 4361.06 13084.41 93.260 165.660 4312.42 4357.59 13129.00 93.320 165.440 4309.86 4355.03 13176.83 93.570 165.990 4306.99 4352.16 13224.80 94.310 165.180 4303.69 4348.86 13269.24 91.170 166.040 4301.57 4346.74 13318.65 91.790 164.230 4300.29 4345.46 13363.38 91.110 165.440 4299.16 4344.33 13411.65 88.030 163.600 4299.52 4344.69 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 9744.41 S 2648.44 E 6019252.99 N 560890.11 E 9807.70 S 2671.48 E 6019189.89 N 560913.65 E 9848.10 S 2687.44 E 6019149.61N 560929.92 E 9887.23 S 2701.81E 6019110.60 N 560944.60 E 9932.54 S 2716.95 E 6019065.40 N 560960.09 E 9975.95 S 2729.80 E 6019022.10 N 560973.28 E 10021.46 S 2741.99 E 6018976.68 N 560985.83 E 10064.48 S 2754.41E 6018933.76 N 560998.58 E 10109.16 S 2767.02 E 6018889.19 N 561011.54 E 10156.92 S 2779.86 E 6018841.53 N 561024.75 E 10197.48 S 2790.65 E 6018801.05 N 561035.86 E 10248.19 S 2804.74 E 6018750.45 N 561050.35 E 10286.08 S 2814.36 E 6018712.64 N 561060.26 E 10329.94 S 2823.90 E 6018668.85 N 561070.15 E 10376.25 S 2833.79 E 6018622.63 N 561080.39 E 10420.96 S 2843.46 E 6018577.99 N 561090.42 E 10464.25 S 2853.95 E 6018534.79 N 561101.25 E 10510.73 S 2865.12 E 6018488.40 N 561112.78 E 10555.11S 2875.40 E 6018444.10 N 561123.40 E 10599.24 S 2885.66 E 6018400.04 N 561134.01E 10644.19 S 2895.81 E 6018355.18 N 561144.51 E 10687.83 S 2905.82 E 6018311.62 N 561154.86 E 10733.55 S 2916.90 E 6018265.98 N 561166.30 E 10776.66 S 2928.01E 6018222.96 N 561177.75 E 10822.93 S 2939.79 E 6018176.79 N 561189.89 E 10869.28 S 2951.70 E 6018130.53 N 561202.16 E 10912.27 S 2962.73 E 6018087.63 N 561213.53 E 10960.01S 2975.41E 6018039.99 N 561226.57 E 11003.17 S 2987.10 E 6017996.93 N 561238.61 E 11049.68 S 2999.98 E 6017950.52 N 561251.85 E Dogleg Rate (°/100ft) 2.243 2.781 14.176 10.656 2.510 10.691 3.432 1.409 4.475 0.202 1.025 4.860 11.933 0.600 4.945 1.968 4.382 4.578 7.514 2.906 6.443 0.979 5.069 0.511 1.261 2.284 7.325 3.871 3.102 7.432 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 10097.91 10165.03 10208.20 10249.73 1O297.43 10342.69 10389.81 10434.58 10481.00 10530.45 10572.43 10625.06 10664.15 10708.97 10756.25 10801.93 10846.45 10894.23 10939.75 10985.03 11031.07 11075.80 11122.83 11167.35 11215.08 11262.93 11307.31 11356.70 11401.42 11449.68 14 August, 2001 - 13:01 Page 3 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 L 1 Your Ref: API-500292301460 Job No. AKZZ11092, Surveyed: 21 June, 2001 Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Inch Azim. Depth Depth Northings Eastings Northings Eastings (ft) , (ft) (ft) (ft) (ft) (ft) (ft) 13449.74 87.850 163.290 4300.89 4346.06 11086.16 S 3010.83 E 6017914.12 N 561262.98 E 13503.12 89.140 163.120 4302.29 4347.46 11137.25 S 3026.25 E 6017863.15 N 561278.80 E 13548.49 89.450 162.440 4302.85 4348.02 11180.58 S 3039.68 E 6017819.93 N 561292.57 E .. 13596.19 89.320 162.120 4303.36 4348.53 11226.01 S 3054.20 E 6017774.61 N 561307.44 E 13642.69 91.110 162.930 4303.19 4348.36 11270.37 S 3068.16 E 60~7730.37 N 561321.75 E 13687.44 91.480 163.010 4302.18 4347.35 11313.14 S 3081.26 E 6017687.70 N 561335.19 E 13731.90 91.420 163.120 4301.05 4346.22 11355.66 S 3094.21 E 6017645.28 N 561348.47 E 13785.23 91.050 162.120 4299.90 4345.07 11406.54 S 3110.13 E 6017594.52 N 561364.79 E 13826.26 90.860 161.590 4299.22 4344.39 11445.53 S 3122.91 E 6017555.64 N 561377.87 E 13875.74 90.610 161.170 4298.59 4343.76 11492.41 S 3138.71 E 6017508.88 N 561394.04 E 13919.86 90.680 161.740 4298.09 4343.26 11534.24 S 3152.74 E 6017467.16 N 561408.39 E 13968.04 91.230 160.740 4297.29 4342.46 11579.85 S 3168.23 E 6017421.67 N 561424.24 E 14013.58 90.990 159.040 4296.40 4341.57 11622.61 S 3183.88 E 6017379.04 N 561440.23 E 14077.95 91.170 158.870 4295.19 4340.36 11682.67 S 3207.00 E 6017319.16 N 561463.81 E 14148.00 91.170 158.870 4293.76 4338.93 11748.00 S 3232.24 E 6017254.03 N 561489.57 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.307° (23-May-01) The Dogleg Severity is in Degrees pe.r 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 164.760° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14148.00ft., The Bottom Hole Displacement is 12184.53ft., in the Direction of 164.617°.(True). Dogleg Rate (°/100ft) 0.941 2.438 1.647 0.724 4.225 0.846 0.282 1.999 1.372 0.988 1.302 2.369 3.769 0.385 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 11487.73 11541 .O7 11586.41 11634.07 11680.53 11725.24 11769.67 11822.95 11863.92 11913.31 11957.36 12005.44 12050.80 12114.83 12184.50 Projected to TD 14 August, 2001 - 13:01 Page 4 of $ DrillQuest Z00.08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 L1 Your Ref: API-500292301460 Job No. AKZZ11092, Surveyed: 21 June, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPC Comments Measured Depth (ft) 10505.00 10551.26 14148.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment · 4323.09 8248.00 S 2245.73 E Tie On Point 4331.53 82§1.73 S 2258.20 E Window Point 4338.93 11748.00 S 3232.24 E Projected to TD Survey tool program for MPC-41 L 1 From Measured Vertical Depth Depth (ft) (ft) To Measured Depth (ft) 0.00 0.00 14148.00 Vertical Depth (ft) 4338.93 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-Au g-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPC-41 Dear Dear Sir/Madam: EnclOsed are two survey hard copies and I disk L1 MWD Tie-on Survey: Window / Kickoff Survey Projected Survey: 10,505.00' MD 10,551.26' MD 14,148.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, "'-'7" / William T. Allen Survey Manager Attachment(s) RECEIVED AUG ?.0 .001 Nast~a Oi~ & Gas Cons. comm'~oD Milne Point Unit Alaska Drilling & Wells Milne Point MPC, Slot MPC-41 MPC-41 L 1 MWD Job No. AKMM10166, Surveyed: 21 June, 2001 SURVEY REPORT 14 August, 2001 Your Ref: API-500292301460 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) DRILLING SERVICE~ A Halliburton Company Survey Ref: svy9925 Sperry-Sun Drilling Services Survey Report for MPC-41 L 1 MWD Your Ref: AP!o500292301460 Job No. AKMM10166, Surveyed: 21 June, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10505.00 77.523 164.474 4277.94 4323.11 10551.26 81.470 164.110 4286.37 4331.54 10587.67 84.380 165.150 4290.85 4336.02 10632.49 84.760 164.210 4295.10 4340.27 10678.46 85.250 164.270 4299.10 4344.27 10725.72 86.300 164.340 4302.58 4347,75 10771.83 88.710 165.760 4304.59 4349.76 10825.87 90.430 167.660 4304.99 4350.16 10864.08 90.180 166.880 4304.79 4349.96 10910.96 89.820 166.870 4304.79 4349.96 10956.99 90.060 168.240 4304.84 4350.01 11002.08 88.830 166.280 4305.27 4350.44 11050.43 89.080 165.150 4306.16 4351.33 11096.11 89.010 164.500 4306.92 4352.09 11142.22 91.420 166.090 4306.74 4351.91 11234.77 90,800 166.330 4304.95 4350.12 11326.89 92.160 167.090 4302.57 4347.74 11415.05 93.880 165.690 4297.93 4343.10 11472.08 89,380 167.290 4296.31 4341.48 11505.17 88.650 164.930 4296.88 4342.05 11599.72 90.120 166.480 4297.89 4343.06 11648.25 91.110 165.050 4297.37 4342.54 11689.84 91.480 165.340 4296.43 4341.60 11734,65 91.050 166.390 4295.44 4340.61 11780.97 91.290 165.540 4294.49 4339.66 11824.95 90.060 164.240 4293.98 4339.15 11871.31 90.310 163.170 4293.83 4339.00 11918.32 90.310 162.800 4293.57 4338.74 11964.12 89.510 164.060 4293.64 4338.81 12010.17 90.120 161.750 4293.79 4338.96 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) 8233.31 S 2293.29 E 6020761.28 N 560523.15 E 8277.08 S 2305,60E 6020717.60 N 560535.80 E 8311.92 S 2315.17 E 6020682.83N 560545.65 E 8354.95 S 2326.96 E 6020639.90 N 560557.77E 8399.03 S 2339.40 E 6020595.92N 560570.56 E 8444.40 S 2352.15 E 6020550.65 N 560583.66 E 8488.90S 2364.03 E 6020506.24 N 560595.89 E 8541.49 S 2376.45 E 6020453.75N 560608.72E 8578.76 S 2364.87 E 6020416.55 N 560617.43 E 8624.41 S 2395.52 E 6020370.98 N 560628.44E 8669,36 S 2405.44 E 6020326.11N 560638.71 E 8713.34S 2415.38 E 6020282.21 N 560648.99 E 8760.18 S 2427.31 E 6020235.46 N 560661.29 E 8804.26 S 2439.26 E 6020191.48 N 560673.59 E 8848.86 S 2450.97 E 6020146.97 N 560685.64 E 8938.72 S 2473.02E 6020057.28 N 560708.40 E 9028.;34S 2494.19 E 6019967.83 N 560730.27 E 9113.90 S 2514.91E 6019882.44 N 560751.65 E 9169.32 $ 2528.22 E 6019827.13 N 560765.40 E 9201.43 S 2536.16 E 6019795.08 N 560773.59 E 9293.04 S 2559.50 E 6019703.65 N 560797.65 E 9340.08 S 2571.44E 6019656.71N 560809.95 E 9380.28 S 2582.06E 6019616.60 N 560820,89 E 9423.72 S 2593.00E 6019573.24 N 560832.17 E 9468.65 S 2604.23 E 6019528.40 N 560843.75 E 9511.10 S 2615.70 E 6019486.04 N 560855.54 E 9555.60 S 2628,70 E 6019441.64N 560868.90 E 9600.55 S 2642.46 E 6019396.80 N 560883.00 E 9644.45 S 2655.52 E 6019353.01 N 560896.41 E 9688.46 S 2669.06E 6019309.10 N 560910.29 E Dogleg Rate (°/100fi) 8.566 8.480 2.253 1.074 2.227 6.065 4.742 2.144 0.768 3.022 5.132 2.393 1.431 6.261 0.718 1.691 2.514 8.374 7.464 2,259 3.584 1.130 2.532 1.906 4.069 2.37O 0.787 3.259 5.188 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 8546.59 Tie On Point 8592.06 Window Point 8628.19 8672.81 8718.60 8765.73 8811.79 8865.79 8903.97 8950.81 8996.79 9041.83 9090.16 9135.84 9181.94 9274.44 9366.48 9454.47 9511.44 9544.51 9639.04 9687.55 9729.13 9773.92 9820.22 9864.20 9910.55 9957.53 10003.32 10049.34 14 August, 2001 - 13:00 Page 2 of 5 DrillQuest 2.00.08. 005 Sperry-Sun Drilling Services Survey Report for MPC-41 L 1 MWD Your Ref: AP1-$00292301460 Job No. AKMM10166, Surveyed: 21 June, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 12057.19 91.170 160.930 4293.26 4338.43 12124.48 91.050 159.940 4291.96 4337.13 12167.96 85.010 159.280 4293.45 4338.62 12209.76 86.990 163.170 4296.37 4341.54 12257.58 88.030 163.290 4298.45 4343.62 12302.92 86.370 167.180 4300.66 4345.83 12350.12 86.740 165.010 4303.50 4348.67 12394.97 86.680 164.340 4306.07 4351.24 12441.44 88.280 165.450 4308.12 4353.29 12490.92 88.340 165.830 4309.58 4354.75 12532.91 88.710 165.520 4310.66 4355.83 12585.59 86.620 164.200 4312.80 4357.97 12624.72 88.950 168.030 4314.32 4359.49 12669.61 89.200 167.740 4315.04 4360.21 12716.99 86.920 168.230 4316.65 4361.82 12762.80 87.160 167.910 4319.01 4364.18 12807.39 87.410 163.790 4321.12 4366.29 12855.24 87.840 168.920 4323.11 4368.28 12900.80 91.050 166,370 4323.55 4368.72 12946.13 91.790 167.440 4322.43 4367.60 12992.29 94.740 167.070 4319.80 4364.97 13037.23 95.180 166.920 4315.91 4361.08 13084.41 93.260 165.700 4312.44 4357.61 13129.00 93.320 165.310 4309.88 4355.05 13176.83 93.570 166.340 4307.01 4352.18 13224.80 94.310 164.990 4303.71 4348.88 13269.24 91.170 166.430 4301.59 4346.76 13318.65 91.790 164.250 4300.31 4345.48 13363.38 91.110 165.540 4299.18 4344.35 13411.65 88.030 163.210 4299.54 4344.71 Local Coordinates Global Coordinates Nothings Eaatinga Nothings Eastlngs (~) (~) (~) (~) 9733.00S 2684.10E 6019264.68N 560925.68 E 9796.40 S 2706.63E 6019201.46 N 560948.70 E 9837.11S 2721.76 E 6019160.87 N 560964.15 E 9876.58 S 2735.18 E 6019121.51 N 560977.88 E 9922.32 S 2748.96E 6019075.87 N 560992.02 E 9966.10 S 2760.50 E 6019032.19 N 561003.90 E 10011.83 S 2771.82 E 6018986.54 N 561015.58 E 10055.02 S 2783.66 E 6018943.45 N 561027,75 E 10099.84 S 2795.75E 6018898.73N 561040.20 E 10147.75 S 2808.02 E 6018850.92 N 561052.84 E 10188.42 S 2818.40 E 6018810,33 N 561063.54 E 10239.23 S 2832.15 E 6018759.63 N 561077.69 E 10277.17 S 2841.53 E 6018721.76 N 561087.36 E 10321.06 S 2850.95 E 6018677.95 N 561097.13 E 10367.37 S 2860.81 E 6018631.71 N 561107.34 E 10412.13 S 2870.26 E 6018587.03 N 561117.15 E 10455.31S 2881.15 E 6018543.94 N 561128.37 E 10501.75 S 2892.42 E 6018497.58 N 561140.01 E 10546.25 S 2902.17 E 6018453.17 N 561150.11E 10590.38 S 2912.44E 6018409.11 N 561160.72 E 10635.33 S 2922.60E 6018364.25 N 561171.23 E 10678.95 S 2932.68 E 6018320,70 N 561181.65 E 10724.66 S 2943.81 E 6018275.08 N 561193.14 E 10767.76 S 2954.96E 6018232.07 N 561204.62 E 10814.05 S 2966.65E 6018185.87 N 561216.68 E 10860.42 S 2978.50 E 6018139.60 N 561228.89 E 10903.43 S 2989.45 E 6018096.68 N 561240.18 E 10951.21S 3001.95 E 6018049.00N 561253.05 E 10994.38 $ 3013.60 E 6018005.92 N 561265.04 E 11040.86 S 3026.60 E 6017959.55 N 561278.40 E Dogleg Rate (°/100ft) 2.833 1.482 13.974 10.422 2.189 9.318 4.656 1.497 4.189 0.777 1.149 4.691 11.450 0.853 4.922 0.872 9.246 10.749 8.998 2.869 6.441 1.034 4.818 0.884 2.212 3.203 7.772 4.586 3.259 8.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 10096.28 1O163.36 10206.62 10248.23 1O295.99 10341.26 10388.36 10433.13 10479.56 10529.01 10570.98 10623.61 10662.69 10707.51 10754.78 10800.46 10844.98 10892.75 1O938.24 10983.53 11029.56 11074.30 11121.33 11165.84 11213.58 11261.43 11305.80 11355.19 11399.91 11448.17 _ 14 AUgust, 2001 - 13:00 Page 3 of 5 DrillQuest 2. 00. 08. 005 Sperry-Sun Drilling ServiceS Survey Report for MPC-41 L 1 MWD Your Ref: API-500292301460 Job No. AKMM10166, Surveyed: 21 June, 2001 Milne Point Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) LOcal Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 13449.74 87.850 162.860 4300.91 4346.08 11077.26 S 3037.71 E 6017923.23 N 561289.79 E 13503.12 89.140 163.070 4302.31 4347.48 11128.28 S 3053.34 E 6017872.33 N 561305.82 E 13548.49 89.450 162.650 4302.87 4348.04 11171.64 S 3066.71 E 6017829.08 N 561319.53 E 13596.19 89.320 162.520 4303.38 4348.55 11217.15 S 3080.98 E 6017783.69 N 561334.16 E 13642.69 91.110 162.670 4303.21 4348.38 11261.52 S 3094.89 E 6017739.43 N 561348.42 E 13687.44 91.480 164.220 4302.20 4347.37 11304.40 S 3107.64 E 6017696.65 N 561361.50 E 13731.90 91.420 164.330 4301.07 4346.24 11347.18 S 3119.69 E 6017653.96 N 561373.88 E 13785.23 91.050 162.480 4299.92 4345.09 11398.27 S 3134.91 E 6017602.99 N 561389.51 E 13826.26 90.860 163.830 4299.24 4344.41 11437.54 S 3146.80 E 6017563.82 N 561401.70 E 13875.74 90.610 162.060 4298.60 4343.77 11484.84 S 3161.31 E 6017516.63 N 561416.58 E 13919.86 90.680 161.740 4298.11 4343.28 t 1526.77 S 3175.02 E 6017474.81 N 561430.61 E 13968.04 91.230 162.020 4297.30 4342.47 11572.55 S 3190.00 E 6017429.14 N 561445.95 E 14013.58 90.990 159.500 4296.42 4341.59 11615.54 S 3205.00 E 6017386.28 N 561461.29 E 14077.95 91.170 159.240 4295.21 4340.38 11675.77 S 3227.68 E 6017326.22 N 561484.44 E 14148.00 91.170 159.240 4293.78 4338.95 11741.26 S 3252.50 E 6017260.93 N 561509.77 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vedical 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 164.760° (True), Based upon Minimum Curvature type calculations, at a Measured Depth of 14148.00ft., The Bottom Hole Displacement is 12183.43ft., in the Direction of 164.516° (True). Dogleg Rate (°/100ft) 1.033 2.448 1.151 0.385 3.863 3.560 0.282 3.537 3.322 3.612 0.742 1.281 5.558 0.491 0.000 Alaska Drilling & Wells Milne Point MPC Vertical Section Comment 11486.21 11539.55 11584.89 11632.55 11679.02 11723.74 11768.19 11821.49 11862.49 11911.94 11956.00 12004.12 12049.53 12113.61 12183.32 Projected Survey 14 August, 2001 - 13:00 Page 4 of $ DrillQuest 2.00. 08.005 Sperry-Sun Drilling Services Survey Report for MPC-41 L1 MWD Your Ref: API-500292301460 Job No. AKMM10166, Surveyed: 21 June, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPC Comments Measured Station Coordinates Depth TVD Northings Eastings (~t) (rt) (ft) (ft) 10505.00 4323.11 8233.31 S 2293.29 E 10551.26 4331.54 8277.08 $ 2305.60 E 14148.00 4338.95 11741.26 S 3252.50 E Comment Tie On Point Window Point Projected Survey Survey tool program for MPC-41 L 1 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 14148.00 4338.95 Survey Tool Description MWD Magnetic (MPC-41 PB1 MWD) 14 August, 2001 - 13:00 Page 5 of 5 Dr#IQ ues t 2. 00. 08. 005 CONSERVA~EION CO~SSION Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re.' Milne Point Unit MPC-41L1 BP Exploration (Alaska) Inc. Permit No: 201-079 Sur Loc: 694' NSL, 2298' WEL, Sec, 10, T13N, R10E, UM Btmhole Loc. 1107' SNL, 1038' EWL, Sec. 26, T13N, R10E, UM Dear Mr. Shultz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a new wellbore segment of existing well MPC-41, Permit No, 201-078. Production should continue to be reported as a function of the original API number stated above. 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. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this //'"g day of May, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA ,.,",_ AND CONSERVATION . ,ON ,.. ;,,)o~. PERMIT TO DRILL ¢-~, 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I :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 025518 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 2349' SNL, 5237' EWL, SEC. 22, T13N, R10E, UM MPC-41L1 Number 2S100302630-277 At total depth 9. Approximate spud date 1107' SNL, 1038' EWL, SEC. 26, T13N, R10E, UM 05/18/01 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 025906, 1038' MDI No Close Approach 2560 14800' MD / 4356' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} KickOff Depth 10616' MD Maximum HoleAngle 93° Maximum surface 1379 psig, At total depth (TVD) 4115'/1851 psig 18. Casing Program Specifications Setting Depth Size To 3 Bottom Quantity of Cement Hole Casing Weight Grade .Coupling Length MD TVD MD TVD (include stare data) 6-1/8" 4-1/2" 12.6# L-80 IBT-Mod 4200' 10516' 4335' 14800' 4356' LJncemented Slotted Liner 19. TOpresentbe completedwell conditionf°r Red rill,summaryRe-entry, and Deepen Operations./'/~~"~~~'~ ~/ ~1~ ~ ~~ Total depth: measured 14800 feet Plugs (measured) true vertical 4356 feet Effective depth: measured feet Junk (measured) ,~la~/ra U'~ 2n,. true vertical feet Oil& G~ ,.u(/ Casing Length Size Cemented &II~/~L,~. Comc~/~, TVD Structural Conductor 30" 20" 260 sx Arctic Set (Approx.) 110' 110' Surface Intermediate Production 9-7/8" 7" 3382 sx Arctic Set III, 249 sx Arctic Set I 11163' 4115' Liner 6-1/8" 4-1/2" Uncemented Slotted Liner 11100' - 14800' 4112'-4415' Perforation depth: measured true vertical 20. 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: Steve Shultz, 564-5491 Prepared By Name/Number: Sondra Stewman, 564-4750 21.1 hereby certify that the f?r-C~loing is ~F'u~and/~orrect to the best of my knowledge/ SteveShultz ~~ ~ ~~. ~ , 1-. _ ...... iF~./, hj,~~_ Title Senior Drilling Engineer Date Signed / Permit Number I AP, Number I ~ ~p(,ro.v~[~ate I See cover letter ~_ ~ / - o '-P '~ 50- ~2 ~ ~ .,Z: ~ o,/~' ~ ~ ~:~ , for other requirements Conditions of Approval: Samples Required [] Yes [].No Mud Log Required [] Yes I~I No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required ~/~ Yes [] No Required Working Pressure for DOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Other: ,.~-C~.~, ~.¥~,~- ~.:s~,~ .~RiGtNAL SIGNED BY by order of Approved By "'~ 'T~¥10r ~eem~unt Commissioner the commission Date. Form 10-401 Rev. 12-01-85 Submit In Triplicate Schrader Bluff 2001 Pro~lram MPC-41 Well Plan I Well Name: Type of Well (producer or injector): Producer (Multilateral) Surface Location: 694' NSL, 2298' WEL, Sec. 10, T13N, R10E X = 558,165.39 Y = 6,028,976.39 MPC-41 OB Target Start: 2874' SNL, 89' EWL, Sec. 23, T13N, R10E X = 560,637.59 Y = 6,020147.26 Z = 4371' TVDss MPC-41 OB Target End: 1102' SNL, 1045' EWL, Sec. 26, T13N, R10E X = 561,627.2 Y = 6,016,648.78 Z = 4369' TVDss MPC-41 L1 CA Target 2351' SNL, 47' WEL, Sec. 22, T13N, R10E Start: X = 560,496.25' Y = 6,020,668.78 Z = 4294' TVDss MPC-41 L1 CA Target 1107' SNL, 1038' EWL, Sec. 26, T13N, R10E End: X = 561,620.2 Y = 6,016,643.05 Z = 4310' TVDss I AFE Number: I I I Rig: I Nabors 22E I Estimated Start Date: I May 18, 2001 I I Operating days to complete: 142.5 OAMDI 10616'--)14800'] IOATVDrkb(TD)4356' I OAMax. lnc. 03° KBEI20.75' OB MD 11200'--)14800' OB TVDrkb (TD) 4415' OB Max. Inc. 91° I Well Design (conventional, slim hole, etc.): I Grassroots multi-lateral with extended horizontal I I laterals. ESP completion. I Objective: I Drill 9-7/8" mainbore hole to +/- 11200' MD. Land mainbore hOle in OB reservoir. I Run and cement 7" casing. Drillout shoe and drill ~ ral in OB. Run 4 Y2" I slotted liner with ha_cj:t~e_r top_p_a_.cke_~-~-~'r~ retrievable whipst~[ ........ ~-. ..... , - ."~..~.. _ .-~,, .... I OX ~nterval at +/- 10616 MD. M~II w~ndow ~n 7 casing. Dnll honzontal lateral ~n CA. ~-~\~-. I Run 4 Y2" slotted liner and hang off with a hookwall hanger system. Complete well I with a 2 7/8" ESP completion. Version #1, 4/25/2001 1. Current Well Information Schrader Bluff 2001 Pro~lram MPC-41 Well Plan 2.1 2.2 2,3 Well Name: APl Number: Well Type: Current Status: BHP: BHT: MPC-41 Development - Schrader Bluff Multilateral Producer New well, 20" conductor set 1963 psi Schader Bluff 'OB' sand. Normal pressure gradient. 80°F @ 4415' SS Estimated Mechanical Condition MPC-41: Nabors 22E: Conductor: Cellar Box MSL = 15.00' KB = 29.75' 20", 92 Ib/ft, H-40 Welded set at 110' RKB 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 Casing: 11200' 1 each 1 each 60 each 1 assembly I assembly 1 lot 7" 26# L-80 Hydril 521 Casing 7" Hydril 521 Float Shoe and Float Collar 7" 26# Hydril 521 Type TAM Cementer 7"x 9-5/8" Rigid SB Casing Centralizers FMC 11" 5m x 2 9/16" X-mas Tree Baker Level 3 Multilateral Equipment (Hookwall) 7" casing pups 5', 10', 20' with Hydril 521 2 x Production Liners: 7500' 200 off 4-5/8" x 5 3A" x 8" 7" x 4 Y2" 4 172" 4 W', 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-41 Well Plan 3. Drilling Hazards and Contin_qencies 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. 3.1.1. The 9-7/8" surface hole will be drilled with a diverter on the well. The 6-1/8" horizontals will be drilled with the BOP installed. MPC-41 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). 3.2. Kick tolerance 3.2.1. The 7" casing will be set int° the Schrader Bluff OB reservoir. The kick tolerance for the 6-1/8" horizontal open hole section is infinite assuming an influx at the 14800' 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. 3.3.2. 3.3.3. Lost circulation has not been encountered while drilling this interval on previous C-Pad wells. Clean hole ECD in the 9-7/8" surface hole is estimated to be 10.1 lb/gal. 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. 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 offtake or injection support. Reservoir pressure is expected to be 1963 psi (8.65 lb/gal). In this we!l, the Schrader Bluff formation will be drilled with 9.1 ppg mud. 3.5. Stuck Pipe 3.5.1. The C-41 directional plan has a 8488' interval of high angle (75°) in the surface hole with _+3600 feet to drill for each lateral in the OA/OB reservoirs. All these hole intervals have massive permeable sand intervals, which can lead to differential sticking of the drill string. Good drilling practices to avoid differential sticking are required in all hole sections. Minimum mud weights and proper mud Schrader Bluff 2001 Program MPC-41 Well Plan properties as outlined in the Baroid mud program must be closely followed. 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 liners. The 9.1 lb/gal mud will be 0.4 lb/gal overbalanced to the 8.65 lb/gal OA/OB sand reservoir pressure (86 psi differential pressure @ 4115' TVD). 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. f) 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. i) 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. Breathinq ,. Schrader Bluff 2001 Program MPC-41 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/OB 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/OB sand horizontal intervals in order to obtain enough pay sand to meet the oil rate production goals. 3,11, Hydrogen Sulfide 3.11.1. MPC Pad is not designated as an H2S Pad. Schrader Bluff 2001 Pro~lram MPC-41 Well Plan 4. Drilling 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. · Close Approach Wells: None · Close Approach Issues: We will be running IFR on the 9 7/8" hole section due to proximity of offset well to ensure directional control. The closest we will come to the edge of an elipse is 37 feet at 1293'. Well Name Current Status Production Priority I Precautions N/A N/A N/A I N/A 4.2. Well Control Expected BHP Max Exp Surface Pressure 1851 psi, 4115' TVD (estimated) 1378 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 4.3. Mud Proqram 9-7/8" Surface Hole Mud Properties: I Spud - LSND Freshwater Mud I Density (ppg) Funnel vis YP HTHP pH APl Filtrate LG Solids 8.6 - 9.2 50 - 150 25 -40 N/A 9.0 - 9.5 < 6 < 6.5 6-1/8" Production Hole Mud Properties: OB/OAI KCL - CaCO3 Baradril N Mud I Density (ppg) Funnel vis I YP HTHP pH I API Filtrate LG Solids 9.1 40 - 55I 22 - 27 < 10 8.0 - 8.5I 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. ~asln_Cl/I UDIn(:I I-'roe ram Hole Size Csg/ Wt/Ft Grade Conn Length Top Bottom Tb~ O.D. MD/TVDrkb MD/TVDrkb 30" 20" 92# H-40 Welded 80' 30'/30' 110'/110' 9-7/8" 7" 26# L-80 BTC-M 11163' 30' / 30' 11163' / 4415' 6-1/8" OB 4 ¥2" 12.6# L-80 IBT-Mod 3637' 11100' / 4412' 14800' / 4415' 6-1/8" OA 4 Y2" 12.6# L-80 IBT-Mod 4200' 10516' / 4335' 14800'/4337' Schrader Bluff 2001 Pro~lram MPC-41 Well Plan 4.6. Cement Calculations Casin~l Size I 7" 26 Ib/ft L-80 Hydril 521 I BasisI 250% excess over gauge hole in permafrost interval, 50% excess over gauge hole below permafrost This cement job will be pumped in 2 stages with a TAM Port Collar placed at 1000' MD The cement volumes will be confirmed by the acoustic caliper to be run whilst drilling the 9-7/8" hole section Need to ensure that the mud is conditioned to proper specs prior to pumping cement Total Cement Volume: Spacer 75 bbl of Viscosified Spacer (Mudpush XL Design) Weighted to 10.2 ppg Lead 966 sx 760 bbl 10.7 Ib/(:jal Class G Arctic Set III Light Tail 1031 sx 211 bbl 15.8 lb/gal Class G Arctic Set I Temp BHST -80° F from SOR, BHCT 85° F estimated by Dowell 4.7. Survey and Loqqin.q Program 9-718" Hole Section: Open Hole: Cased hole: 6-1/8" Hole Sections: Cased Hole: MWD I GR/Res / PWD - (Res. over production interval only) NB. MWD inclination sensor to be placed directly above motor None MWD / GR/Res / PWD / ABI / ABGR - (ABGR will be run if available) None 5. MPC-41 Operations Summary 5.1. Pre-Rig Operations 1. Install 20" conductor 5.2. Procedure 4. 5. 6, 8. 9. 10. 11 13. 16. MIRU Nabors 22E, NU diverter on 20" conductor, PU 5" drill pipe MU BHA with 9-7/8" milltooth bit, 6 3,4" Sperry MWD/LWD(GR-Res)/PWD/ABI/Caliper and 5" drill pipe Drill 9-7/8" surface hole as per directional plan ' ' Tangent angle 75°. Surface .hole landed on OBat 91 ° POOH. Reamer trip with Hole opener to TD Condition mud with lubes and spot casing running lube pill prior to 7" casing run. POOH Run 7" casing (with RA tag @ 100' above Top OA Sand and TAM Port Collar @ 1000') to TD. Cement casing to surface Tam Port Collar will be run as a contingency in case cement does not return to surface on first stage Install FM,,C, 11" 5m horizontal wellhead NU 13-5/8 ,,5m BOP. Test BO,,P to 2500/250 psi · 1 Lay down 5 drill pipe, PU 3 Y2 d!!,ll pipe MU BHA with 6-1/8' PDC bit, 4 3,4 MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3 Y2" drill pipe RIH. Drill out float equipment Displace hole to 9.1 lb/gal Bara Drill mud . Drill 20' o!, new hole and perform FIT to > 11.0 lb/gal Drill 6-1/8 OB lateral geosteering and short tripping as required. Maintain Bara Drill mud properties. TD criteria supplied by town POOH. Reamer trip with Hole Opener to TD Displace OB lateral with clean Bara Drill mud 17. -'18. 19. 20. 21. 22. 23. 24. 25. 26. 32. :34. Schrader Bluff 2001 Program MPC-41 Well Plan Run 4 Y2" slotted liner with inner string to OB lateral TD and hang off 100' inside 7" casing Make up Baker Window Master milling assembly with retrievable whipstock and MWD Install whipstock in top of liner hanger. Verify whipstock orientation with MWD Shear off and mill window MU BHA with 6-1/8" PDC bit, 4 3,4" MWD/LWD(GR-Res)/PWD/ABI/ABGR, 3 ¥2" drill pipe RIH. Displace hole to clean Bara Drill mud Drill OA horizontal lateral geosteering and short tripping as required. Maintain Bara Drill mud properties. TD criteria supplied by town POOH. Reamer trip with Hole Opener TD. Displace OA lateral with clean Bara Drill mud MU whipstock retrieval tool and MWD. RIH. Orient and jet whipstock face Engage and pull whipstock free RIH with 4 ¥2" slotted liner w/bent shoe joint, orient liner into window and run liner to point of hanging off with hookwall hanger Displace 7" casing to 9.1 lb/gal completion fluid (brine) POOH and L/D 3 ¥~" drill pipe . RIH with 2 7/8" tubing to top of 1s~ lateral and displace well to seawater Land 2 7/8" tubing, set TWC, ND BOPE and NU X-mas tree, pull TWC Pump enough volume of diesel to displace the annulus and tubing down to 2000' Set TWC and test. Remove TWC and install BPV. Secure well RDMO TRE.,.E: FMC 2-9/16" 5M POST-COMPLETION WELLHEAD:FMCGen5ASystem11,, 5M csg.head w/ ~rqp ....... C-41 &._C-41 L1 ( OrigKBelevss(N22E)=45.7' 7" x 2-7/8" tubing hanger I 113' ] 20" 92 Ib/ft, H-40 Welded ~ · : ! I Halliburton XN-Nipple (2.205" ID) 2-7/8% 6.3 Ib/ft, I_-80, F:UE-M i lapered Pump: Coupling OD: 3.5" ,/ Centrilift 27 stage GC2200 Drift/ID · 2.347"/2.441" Centrilift 72 stage GC 3500 Centrilift 16 stage GCNPSH I I Tandem gas seperator Seal section, Model GST#DBIPLPFS 190 HP KMH 2415v/48a Motor Standard 6 fin centralizedPump Mate I -10000 26#, L-80, Hydril Casing Drift: 6.151" ' Casing ID: 6.276" .....~'~'~ ~radrilN mud below the ESP Baker Hughes H°°kwall Hanger @ +/-10'150 / ~ ~l[~~'' ~'''~\ ~''/~- ''' L~Liner @ 14,800' MD OA Horizontal -- -- -- 6-1/8" OB Lateral ID I 11200'-14800'MD 4-1/2" Slotted Liner & Hanger DATE REV. BY COMMENTS Milne Point Unit WELL: C-41 ML 4/24/01 Steve Shultz Level 3 Multi-Lateral, 2 7/8" ESP Completion APl NO: BP Exploration (Alaska) COMPANY DETAILS BP Arao~:o CaJcuLsliou Metl~k Miuiu~m Cur~atme ~ System: ISCWSA Scan Method: 'fray Cyliu~r No~h Enut Surface: EIlil~i~l + C~u8 Wam[o~ M~h~d: Rules [3ased ANNOTATIONS No. TVD MD Annotation I 4341.6110616.00Start Dir 6°/100': 10616'MD, 4341.61~fVD 2 4372.6710919.57EndDir: 10~I9.57'MD, 4372.67'TVD 3 4358.6511180.30StartDir3°/100': lllS0.3'MD, 4358.65q'VD 4 4354.2411319.44EndDir: l1319.44'MD, 4354.24'TVD 5 4347.3912547.20StartDir3°/100': I2547.2'MD, 4347.39'TVD 6 4347.3512591.97EndDir: 12591.97' MD, 4347.35'TVD 7 4356.1714800.01Total Depth: 14800.02' MD, 4356.17'TVD REFERENCE INFORMAIION Coqn~ml* (N/E) Refe~nce: Well Centre: Plan MPC-41, Tree ~ Vexlical ('[VD) Ref~nffi, ee: 51:3610/151199710-3546_q0 Se~km tVS)Rere~uce: Sk,~- (OJ]~N.O.OOE} Meas,.mxl Depth Reference: 51:3610/151199710:.55 46_q0 Cakulafio~ Melhod: Minimum Cttrvamre FORMATION TOP DETAILS NO. TVDPath MDPath Formation I 4373.50 10834.31 TSBC(baseOA) SURVEY PROGRAM Plan: MPC-OL I ~vp04 ( Plan MPC-41/PIan MPC-41LI ) ~h Fm ~ To S~)~ T~I C~ By: K~ ~1~ Date: 4/25~l 1~16.~ 14~.~ P~M~LI~VI M~I~MS Ch~k~: ~te: ....... Re~ew~: ~le: ..... W~L ~TAI~ N~ ~N~-S*~-W ~ ~ ~fi~ L~i~ S~ P~I 1~7~6 1~21 ~76.~ 558165~3 7~9~.20~ 149~31~g~W ~A CASING DETAILS No. TVD MD Name Size I 4356.17 14800.01 4 1/2" 4.500 All TVD depths are ssTVD plus 46.5' for RKBE. IARGET DETAILS Name TVD +N:.-S +FJ-W Northin8Easfing Shape MPC-GLI TI 435430 -8981.16 2436.68 6020015.04 560672.{5 Point MPC-GLI 12 434?35 -10226.10 2794.01 6018773.05 561039.17 Poinl MPC-GLI '1'3 4356.17 -12360.78 3358.42 6016643.06 561620.20 Point SECTION DETAILS Sec MD lnc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 10616.0075.13 163.70 4341.61 -8324.26 2271.52 0.00 0.00 8628.62 ~ 2 10919.5793.08 166.81 4372.67 -8615.08 2347.94 6.009,97 8929.30 3 11180.3093.08 166.81 4358.65 -8868.57 2407.36 0.000.00 9189.50 4 11296.7391.00 164.00 4354.50 -8981.16 2436.68 3.00-126.53 9305.83MPC-GLI TI 5 11319.4490.32 163.96 4354.24-9002.98 2442.94 3.00-176,95 9328.54 6 12547.2090.32 163.96 4347.39-10182.94 2782.10 0.000.00 10556.14 7 12591.9789.77 165.19 4347.35-10226.10 2794.01 3.00 !14.11 10600.92 MPC-GLI T2 8 14800.0289.77 165.19 4356.17-12360.78 3358.42 0.00 0.00 12808.90 MPC-GLI T3 Start Dir 6°1100': 10616' MD, 4341.61'TVD End Dir: 10919.57' MD, 4372.67' TVD ...... : .... 7---Si~r~'Dir'3°/l~0'i l]i80.3'-iqD~4338~65'..~VD ' ' ' j StartDir3~/lO0':-l-2~47:2~MD,'4347'39~WD ........T6~alD~0ih!'I4800-02'MD,4356.ITTVD End Dir . ii31944, M~D~4354.24, TVD ! / End Dir : 12591.97' MD, 4347.35'TVD t 'rsBc!co~ o^) ........... _ .............. .... . . .... : .... ~ . . : ............ ; .. _~ .: .............. .. ... 8500 9000 9500 10000 10500 11000 11500 4 1/2" 12000 12500 13000 Vertical Section at 164.80° [500fl./in] COMPANY DETAILS BP Amoco C~louhfion Method: Minimum Cu~auue Enur Sloaem: ISCWSA Seau M~x~l: T~v Cy{~ ~ ~ ~ +C~ W~,~h~ ~ Ru~ ~ ~OTA~ONS No. ~ MD ~otalion I 4341.61 10616.00 St~ ~r 6°/1~': 10616'~, 4341.61~VD 2 4372.67 10~19.57 End~r: 10919.5T~,4372.67'~ 3 43~8.6~ !II80.30 St~r3°/l~': 11180.3'~,4358.6Y~ 4 43~4.24 11319.~ End~: II31~.~'~,43S4.24'TVD ~ 4347.39 12547.20 St~r 3°/1~': 12547.2' MD, 4347.39'T~ 6 4347.35 12~91.97 End ~r: 12591.97' ~, 4347.35' 7 43~6.17 14800.01 Tot~Depth: ]4800.02' MD, 4356. IT'~D -8000-- -9000 SURVEY PROGRAM Depth Fm Depth To S~vey~lan 10616.00 148~).02 Ph~I:MPC-GLIwp04VI T~I MWD-IFR-MS Plan: MPC-GLI wp04 (Plan MPC-41/PIan MPC-IlL I) Created By: K~n AHen Dale: 4/25/200 I Checked: Da~e: Reviewed: Dale: FORMATION TOP DETAILS No. TVDPath MDPath Formation I 4373.50 10834.31 TSBC(baseOA) CASING DETAILS No. TVD MD Name Size 1 4356.17 14800.01 4 1/2" 4.500 WELL DETAILS Name +N/-S +Fd-W lqo~ing Eaaing LatitudeLon~t~le Slot Pbn MPC-41 162736120216029976.00 55516533 70~29'23207N 149°31 '28284W N/A TARGET DETAILS /qau~ TVD +N/-S+E/-W NorthingEasling Shape MPC-GLI TI 435430 -8981.16 2436.68 6020015.04 560672.15 Poinl MPC-GLI T2 434735 -10226.10 2794.01 6015773.05 561039.17 Poim MPC-GLI T3 4356.17 .12360.78 3358.42 6016643.06 561620.20 Point -11000 -12000 tart Dir 6°/100': I0616' MD, 4341.6Iq'VD ~--End Dir: 10919.57' MD, 4372.67' TVD ......... =--, .i .... ..... ~-~-tm't Dir 3°/100': 11180.3'MD, 4358.65~rVD i ~End Dir: 11319.44' MD, 4354.24' TVD i ~g/ Start Dir 3°/100': 12547.2' MD, 4347.39q'~'D ~: ~d Dh-: 12591.97' MD, 4347.35' TVD ~ 1/2" -~ Total Depth: 14800.02' MD, 4356.17' TVD -13000 , , { , , , , 2000 SECTION DETAILS Sec MD Inc Afl TVD +N/-S +E/-W DLeg TFace VSec T~get I 10616.00 75.13 163.70 4341.61 -8324.26 2271.52 0.00 0.00 8628.62 2 10919.57 93.08 166.81 4372.67 -8615.08 2347.94 6.00 9.97 8929.30 3 11180.30 93.08 166.81 4358.65 -8868.57 2407.36 0.00 0.00 9189.50 4 11296.73 91.00 164.00 4354.50 -8981.16 2436.68 3.00 -126.53 9305.83 MPC-GLI TI 5 11319.44 90.32 163.96 4354.24 -9002.98 2442.94 3.00 -176.95 9328.54 6 12547.20 90.32 163.96 4347.39 -10182.94 2782.10 0.00 0.00 10556.14 7 12591.97 89.77 165.19 4347.35 -10226.10 2794.01 3.00 114.11 10600.92 MPC-GLI T2 8 14800.02 89.77 165.19 4356.17 -12360.78 3358.42 0.00 0.00 12808.90 MPC-GLI T3 All TVD depths are ssTVD plus 46.5' for RKBE. 3000 4000 5000 6000 7000 8000 9000 lO000 11000 West(-)/East(+) [ 1000ft/in] BP Amoco Planning Report- Geographic Company: BP Amoco Field: Milne Point Site: M Pt C Pad Well: Plan MPC-41 Wellpath: Plan MPC-41L1 Date: 4/25/2001 Time: 10i22:37 Co-ordinate(NE) Reference: Well: Plan MPC-41; True North Vertical (TVI)) Reference:' 51: 36 10/15/1997 10:55 46.5 Section (VS) Reference: Well (0.00N,0.00E,164.80Azi) Plan: MPC-GL1 wp04 Page: 1 Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Gee Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: M Pt C Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6027347.71 ft Latitude: 70 29 7.200 N 558058.04 ft Longitude: 149 31 31.821 W North Reference: True Grid Convergence: 0.45 deg Well: Plan MPC-41 Slot Name: Surface Position: +N/-S 1627.56 ft Northing: 6028976.00 ft Latitude: 70 29 23.207 N +E/-W 120.21 ft Easting: 558165.53 ft Longitude: 149 31 28.284 W Position Uncertainty: 0.00 ft Reference Point: +N/-S 1627.56 ft Northing: 6028976.00 ft Latitude: 70 29 23.207 N +EI-W 120.21 ft Easting: 558165.53 ft Longitude: 149 31 28.284 W Measured Depth: 46.50 ft Inclination: 0.00 de9 Vertical Depth: 46.50 ft Azimuth: 0.00 deg Wellpath: Plan MPC-41L1 Drilled From: Plan MPC-41 Tie-on Depth: 10616.00 ft Current Datum: 51: 36 10/15/1997 10:55 Height 46.50 ft Above System Datum: Mean Sea Level Magnetic Data: 3/7/2001 Declination: 26.37 deg Field Strength: 57445 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ff ff deg 0.00 0.00 0.00 164.80 Plan: MPC-GL1 wp04 Date Composed: 4/25/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 10616.00 75.13 163.70 4341.61 -8324.26 2271.52 0.00 0.00 0.00 0.00 10919.57 93.08 166.81 4372.67 -8615.08 2347.94 6.00 5.91 1.02 9.97 11180,30 93.08 166.81 4358.65 -8868.57 2407.36 0.00 0.00 0.00 0.00 11296.73 91,00 164,00 4354,50 -8981.16 2436.68 3.00 -1.79 -2.41 -126.53 11319.44 90.32 163.96 4354.24 -9002.98 2442.94 3.00 -3.00 -0.16 -176.95 12547.20 90.32 163.96 4347.39 -10182.94 2782.10 0.00 0.00 0.00 0.00 12591.97 89.77 165.19 4347.35 -10226.10 2794.01 3.00 -1.23 2.74 114.11 14800.02 89.77 165.19 4356.17 -12360.78 3358.42 0.00 0.00 0.00 0.00 MPC-GL1 T1 MPC-GL1 T2 MPC-GL1 T3 Section I : Start i;'~: .' ff' ..".'" ": deg 10616.00 75.13 10650.00 77.14 10700.00 80.10 10750.00 83.05 10800.00 86.01 10850.00 88.97 10900.00 91.92 10919.57 93.08 163.70 4341.61 -8324.26 2271.52 8628.62 0.00 0.00 0.00 0.00 164.06 4349.76 -8355.97 2280.68 8661.62 6.00 5.91 1.07 9.97 164.58 4359.62 -8403.16 2293.93 8710.63 6.00 5.91 1.04 9.88 165.10 4366.95 -8450.89 2306.86 8760.08 6.00 5.91 1.03 9.78 165.60 4371.72 -8499.04 2319.44 8809.85 6.00 5.91 1.01 9.70 166.11 4373.91 -8547.47 2331.65 8859.79 6.00 5.92 1.01 9.66 166.61 4373.52 -8596.06 2343.44 8909.76 6.00 5.92 1.00 9.63 166.81 4372.67 -8615.08 2347.94 8929.30 5.99 5.90 1.02 9.82 .... BP Amoco Planning Report - Geographic Company: BP Amoco Field: Milne Point Site: M Pt C Pad Well: Plan MPC-41 Wellpath: Plan MPC-41L1 Date: 4/2512001 Time: 10:22:37 Page: Co-ordinate(NE) Reference: Well: Plan MPC-41, True North Vertical(TVD) Reference: 51:36 10/15/1997 10:55 46.5 Section (VS) Reference: Well (0.00N,0.00E,164.80Azi) Plan: MPC-GL1 .wp04 Section 2: Start MD lnci Azim TVD +NI-S +E/-W VS DLS Build Turn TFO ff deg deg ft ff , ff ff deg/100ft deg/100ft deg/100ft deg 11000.00 93.08 166.81 4368.35 -8693.28 2366.27 9009.56 0.00 0.00 0.00 0.00 11100.00 93.08 166.81 4362.98 -8790.50 2389.05 9109.36 0.00 0.00 0.00 0.00 11180.30 93.08 166.81 4358.65 -8868.57 2407.36 9189.50 0.00 0.00 0.00 0.00 Section 3: Start :MD Incl Az'im TVD '+N/-s : +E/-W VS. DLS ·. Build Turn · TFO ft deg, deg ff , ft ft ff deg/lOOft deg/lOOff deg/iOOft deg 11200.00 92.73 166.33 4357.65 -8887.71 2411.93 9209.17 3.00 -1.79 -2.41 -126.53 11296.73 91.00 164.00 4354.50 -8981.16 2436.68 9305.84 3.00 -1.79 -2.41 -126.48 Section 4: Start 111319.44 ,deg/100ft :=d~g/iOoff deg/lOoft: '.~: :d~ 90.90 163.99 4354.45 -8984.30 2437.58 9309.11 3.00 -3.00 -0.16 -176.95 90.32 163.96 4354.24 -9002.98 2442.94 9328.54 3.00 -2.99 -0.18 -176.58 Section 5: Start Incl' deg: 11400.00 90.32 163.96 4353.79 -9080.40 2465.20 9409.09 0.00 0.00 0.00 0.00 11500.00 90.32 163.96 4353.23 -9176.51 2492.83 9509.07 0.00 0.00 0.00 0.00 11600.00 90.32 163.96 4352.67 -9272.61 2520.46 9609.06 0.00 0.00 0.00 0.00 11700.00 90.32 163.96 4352.11 -9368.72 2548.09 9709.05 0.00 0.00 0.00 0.00 11800.00 90.32 163.96 4351.56 -9464.82 2575.72 9809,04 0.00 0.00 0.00 0.00 11900.00 90.32 163.96 4351.00 -9560.93 2603.35 9909,03 0.00 0.00 0.00 0.00 12000.00 90.32 163.96 4350.44 -9657.03 2630.98 10009.01 0.00 0.00 0.00 0.00 12100.00 90.32 163.96 4349.88 -9753.14 2658.61 10109.00 0.00 0.00 0.00 0.00 12200.00 90.32 163.96 4349.32 -9849.25 2686.24 10208.99 0.00 0.00 0.00 0.00 12300.00 90.32 163.96 4348.76 -9945.35 2713.87 10308.98 0.00 0.00 0.00 0.00 12400.00 90.32 163.96 4348.21 -10041.46 2741.50 10408.96 0.00 0.00 0.00 0.00 12500.00 90.32 163.96 4347.65 -10137.56 2769.13 10508.95 0.00 0.00 0.00 0.00 12547.20 90.32 163.96 4347.39 -10182.94 2782.10 10556.14 0.00 0.00 0.00 0.00 Section 6: Start 12591.97 89.77 165.19 4347.35 -10226.10 2794.01 10600.91 3.01 -1.23 2.75 114.09 Section 7: Start 12600.00 12700.00 12800.00 12900.00 13000.00 13100.00 13200.00 13300.00 13400.00 13500.00 13600.00 13700.00 13800,00 13900.00 14000.00 14100.00 14200.00 14300.00 89.77 165.19 4347.38 -10233.86 2796.06 10608.94 0.00 0.00 0.00 0.00 89.77 165.19 4347.78 -10330.54 .2821.62 10708.94 0.00 0.00 0.00 0.00 89.77 165.19 4348.19 -10427.22 2847.19 10808.94 0.00 0.00 0.00 0.00 89.77 165.19 4348.59 -10523.89 2872.75 10908.93 0.00 0.00 0.00 0.00 89.77 165.19 4348.99 -10620.57 2898.31 11008.93 0.00 0.00 0.00 0.00 89.77 165.19 4349.39 -10717.25 2923.87 11108.93 0.00 0.00 0.00 0.00 89.77 165.19 4349.79 -10813.93 2949.43 11208.93 0.00 0.00 0.00 0.00 89.77 165.19 4350.19 -10910.60 2974.99 11308.92 0.00 0.00 0.00 0.00 89.77 165.19 4350.59 -11007.28 3000.55 11408.92 0.00 0.00 0.00 0.00 89.77 165.19 4351.00 -11103.96 3026.11 11508.92 0.00 0.00 0.00 0.00 89.77 165.19 4351.40 -11200.63 3051.68 11608.91 0.00 0.00 0.00 0.00 89.77 165.19 4351.80 -11297.31 3077.24 11708.91 0.00 0.00 0.00 0.00 89.77 165.19 4352.20 -11393.99 3102.80 11808.91 0.00 0.00 0.00 0.00 89.77 165.19 4352.60 -11490.67 3128.36 11908.90 0.00 0.00 0.00 0.00 89.77 165.19 4353.00 -11587.34 3153.92 12008.90 0.00 0.00 0.00 0.00 89.77 165.19 4353.40 -11684.02 3179.48 12108.90 0.00 0.00 0.00 0.00 89.77 165.19 4353.81 -11780.70 3205.04 12208.89 0.00 0.00 0.00 0.00 89.77 165.19 4354.21 -11877.37 3230.60 12308.89 0.00 0.00 0.00 0.00 BP Amoco Planning Report - Geographic Company: BP Amoco Field: Milne Point Site: M Pt C Pad Well: Plan MPC-41 Wellpath: Plan MPC-41L1 Date: 4/25/2001 Time: 10:22:37 Page: Co-ordinate(NE) Reference: Well: Plan MPC-41, True North Vertical (TVD) Reference: 51 ' 36 10/15/1997 10:55 46.5 Section (VS) Reference: Well (0.00N,0.00E,164.80Azi) Plan: MPC-GL1 wp04 Section 7: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 14400.00 89.77 165.19 4354.61 -11974.05 3256.16 12408.89 0.00 0.00 0.00 0.00 14500.00 89.77 165.19 4355.01 -12070.73 3281.73 12508.88 0.00 0.00 0.00 0.00 14600.00 89.77 165.19 4355.41 -12167.41 3307.29 12608.88 0.00 0.00 0.00 0.00 14700.00 89.77 165.19 4355.81 -12264.08 3332.85 12708.88 0.00 0.00 0.00 0.00 14800,02 89.77 165.19 4356.17 -12360.78 3358.42 12808.90 0.00 0.00 0.00 0.00 Survey , : :Map :' :Map ', <-- Latitude--> <--Longitude ---> , MD : lncl .'+Ni-S +E/-W ,. NOrthing' EaSting, ::. :: Deg Min Sec :Deg ,Min' Sec deg, , . .: : ' ':' '~ 10616.00 75.13 163.70 4341.61 -8324.26 2271.52 6020670.56 560501.87 70 28 1.336 N 149 30 21.519W 10650.00 77.14 164.06 4349.76 -8355.97 2280.68 6020638.93 560511.28 70 28 1.025 N 149 30 21.250W 10700.00 80.10 164.58 4359.62 -8403.16 2293.93 6020591.85 560524.89 70 28 0.560 N 149 30 20.861W 10750.00 83.05 165.10 4366.95 -8450.89 2306.86 6020544.22 560538.19 70 28 0.091 N 149 30 20.482W 10800.00 86.01 165.60 4371.72 -8499.04 2319.44 6020496.18 560551.15 70 27 59.617 N 149 30 20.112W 10850.00 88.97 166.11 4373.91 -8547.47 2331.65 6020447.85 560563.73 70 27 59.141 N 149 30 19.754W 10900.00 91.92 166.61 4373.52 -8596.06 2343.44 6020399.36 560575.90 70 27 58.663 N 149 30 19.408W 10919.57 93.08 166.81 4372.67 -8615.08 2347.94 6020380.38 560580.55 70 27 58.476 N 149 30 19.276W 11000.00 93.08 166.81 4368.35 -8693.28 2366.27 6020302.33 560599.49 70 27 57.707 N 149 30 18.738W 11100.00 93.08 166.81 4362.98 -8790.50 2389.05 6020205.30 560623.03 70 27 56.751 N 149 30 18.069W 11180.30 93.08 166.81 4358.65 -8868.57 2407.36 6020127.38 560641.95 70 27 55.983 N 149 30 17.532W 11200.00 92.73 166.33 4357.65 -8887.71 2411.93 6020108.28 560646.67 70 27 55.795 N 149 30 17.397W 11296.73 91.00 164.00 4354.50 -8981.16 2436.68 6020015.04 560672.15 70 27 54.876 N 149 30 16.671 W 11300.00 90.90 163.99 4354.45 -8984.30 2437.58 6020011.90 560673.07 70 27 54.845 N 149 30 16.644W 11319,44 90.32 163.96 4354.24 -9002.98 2442.94 6019993.27 560678.58 70 27 54.661 N 149 30 16.487W 11400.00 90.32 163.96 4353.79 -9080.40 2465.20 6019916.03 560701.44 70 27 53.899 N 149 30 15.834W 11500.00 90.32 163.96 4353.23 -9176,51 2492.83 6019820.15 560729.82 70 27 52.954 N 149 30 15.023W 11600.00 90.32 163.96 4352.67 -9272.61 2520.46 6019724.28 560758.20 70 27 52.009 N 149 30 14.212W 11700.00 90.32 163.96 4352.11 -9368.72 2548.09 6019628.40 560786.57 70 27 51.064N 149 30 13.401 W 11800.00 90.32 163.96 4351.56 -9464.82 2575.72 6019532.52 560814.95 70 27 50.118 N 149 30 12.589W 11900.00 90.32 163.96 4351.00 -9560.93 2603.35 6019436.64 560843.33 70 27 49.173 N 149 30 11.778W 12000.00 90.32 163.96 4350.44 -9657.03 2630.98 6019340.77 560871.71 70 27 48.228 N 149 30 10.967W 12100.00 90.32 163.96 4349.88 -9753.14 2658.61 6019244.89 560900.09 70 27 47.283 N 149 30 10,157W 12200.00 90.32 163.96 4349.32 -9849.25 2686.24 6019149.01 560928.47 70 27 46.337 N 149 30 9.346W 12300.00 90.32 163.96 4348.76 -9945.35 2713.87 6019053.14 560956.85 70 27 45.392 N 149 30 8.535W 12400.00 90.32 163.96 4348.21 -10041.46 2741.50 6018957.26 560985.22 70 27 44.447 N 149 30 7.724W 12500.00 90.32 163.96 4347.65 -10137.56 2769.13 6018861.38 561013.60 70 27 43.501N 149 30 6,913W 12547.20 90.32 163.96 4347.39 -10182.94 2782.10 6018816.11 561026.92 70 27 43.055 N 149 30 6.532W 12591.97 89.77 165.19 4347.35 -10226.10 2794.01 6018773.05 561039.17 70 27 42.631 N 149 30 6.183W 12600.00 89.77 165,19 4347.38 -10233.86 2796.06 6018765.30 561041.28 70 27 42.554 N 149 30 6.123W 12700.00 89.77 165.19 4347.78 -10330.54 2821.62 6018668.84 561067.60 70 27 41.603 N 149 30 5.373W 12800.00 89.77 165.19 4348.19 -10427.22 2847.19 6018572.37 561093.91 70 27 40.652 N 149 30 4.623W 12900.00 89.77 165.19 4348.59 -10523.89 2872.75 6018475.91 561120.22 70 27 39.702 N 149 30 3.873W 13000.00 89.77 165.19 4348.99 -10620.57 2898.31 6018379.44 561146.54 70 27 38.751 N 149 30 3.123W 13100.00 89.77 165.19 4349.39 -10717.25 2923.87 6018282.98 561172.85 70 27 37.800 N 149 30 2.373W 13200.00 89.77 165.19 4349.79 -10813.93 2949.43 6018186.51 561199.17 70 27 36.849 N 149 30 1.623W 13300.00 89.77 165,19 4350.19 -10910.60 2974.99 6018090.05 561225.48 70 27 35.898 N 149 30 0.873W 13400.00 89.77 165.19 4350.59 -11007.28 3000.55 6017993.58 561251.80 70 27 34.947 N 149 30 0.123W 13500.00 89.77 165.19 4351.00 -11103.96 3026.11 6017897.12 561278.11 70 27 33.996 N 149 29 59.373W 13600.00 89.77 165.19 4351.40 -11200.63 3051.68 6017800.65 561304.42 70 27 33.045 N 149 29 58.623W 13700.00 89.77 165.19 4351.80 -11297.31 3077.24 6017704.19 561330.74 70 27 32.094 N 149 29 57.873W 13800.00 89.77 165.19 4352.20 -11393.99 3102.80 6017607.72 561357.05 70 27 31.143 N 149 29 57.123W 13900.00 89.77 165.19 4352.60 -11490.67 3128.36 6017511.26 561383.37 70 27 30.193 N 149 29 56.374W 14000.00 89.77 165.19 4353.00 -11587.34 3153.92 6017414.79 561409.68 70 27 29.242 N 149 29 55.624W 14100.00 89.77 165.19 4353.40 -11684.02 3179.48 6017318.33 561435.99 70 27 28.291 N 149 29 54.874W BP Amoco Planning Report - Geographic Company: BP Amoco Field: Milne Point Site: M Pt C Pad Well: Plan MPC-41 Weilpath: Plan MPC-41L1 Date: 4/2512001 Time: 10:22:37 Co-ordinate(NE) Reference: Well: Plan MPC-41, True North Vertical (TVD) Reference: 51: 36 10/15/1997 10:55 46.5 Section (VS) Reference: Well (0.00N,0.00E,164.80Azi) Plan: MPC-GL1 wp04 Page: 4 Survey Map Map <-- Latitude ----> <-- Longitude ----> MD Incl Azim TVD +N/-S +E/-W Northing Easting DegMin Sec Deg Min Sec fl deg deg ff ff :ff ff ff 14200.00 89.77 165.19 4353.81 -11780.70 3205.04 6017221.86 561462.31 70 27 27.340 N 149 29 54.124W 14300.00 89.77 165.19 4354.21 -11877.37 3230.60 6017125.40 561488.62 70 27 26.389 N 149 29 53.375W 14400.00 89.77 165.19 4354.61 -11974.05 3256.16 6017028.93 561514.94 70 27 25.438 N 149 29 52.625W 14500.00 89.77 165.19 4355.01 -12070.73 3281.73 6016932.47 561541.25 70 27 24.487 N 149 29 51.875W 14600.00 89.77 165.19 4355.41 -12167.41 3307.29 6016836.00 561567.57 70 27 23.536 N 149 29 51.126W 14700.00 89.77 165.19 4355.81 -12264.08 3332.85 6016739.54 561593.88 70 27 22.585 N 149 29 50.376W 14800.02 89.77 165.19 4356.17 -12360.78 3358.42 6016643.05 561620.20 70 27 21.634 N 149 29 49.626W H 1 881 26 VENDOR A[ ~SKAO I LA,, 00 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET , , )41801 CKO41801A 100. O0 100. O0 PYMT (;OMMENTS: Perf~it to Drill I'ee HANDL NO INST: S/H - Tereie Hub tie X4628 -' ATTACHED CHECK IS IN PAYMENT FOR ffEMS DESCRIBED ABOVE. ~ 1 OO. OD 1 OO_ OD "';"" :"" FIRST NATION'AL BANK OF ASHLAND -, · , AN AFFILIATE or' · . NA~;O: ;;-L C:'; v C..r...?..~%L;. C- .'.' . · , · '.. 56-~8B ·. · 412 ., OO/.1,OO~.~~~~~*~~~~ US DOLL. AR DATE AMOUNT· $i0o'. oo ALASKA OIL AND. 'i:~,:"?1:333 WEST, 7TH AVENUE SUITE 1OO WELL PERMIT CHECKLIST COMPANY , ~,~,/~ WELL NAMEx'~',~'~- ~'?/-. / PROGRAM: exp dev redrll serv _ wellbore seg ~" ann. disposal para req FIELD& POOL .~'~__,,~'/./-_-y~ INIT CLASS Z~__y.~ ,?--~,~'~.J GEOLAREA ~'~,~.-,) UNIT# ~ 11 ~'.>__<~ ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... ~ N 2. Lease number appropriate ................... Y N 3. Unique well name and numberpool .................. ..................~ YYI! 4. Well located in a defined 5. Well located proper distance from drilling unit boundary .... Y 6. Well located proper distance from other wells .......... Y N 7. Sufficient acreage available, in ddlling unit ............ Y N. 8. If deviated, is wellbore plat included ............... ' ~vt-Y- N 9. Operator only affected party ...................~Y N 10. Operator has appropriate bond in force ............. ~ Y N 11. Permit can be issued without conservation order ........ Y N AP~.PR D_D~,'I'~ 12. Permit can.be issued without ad m in i strut/va approval ...... N ~.....5-~x/~/ 13. Can permit be approved before 15-day wait ........... N ENGINEERING 14. Conductorstdng provided ................... ........... YI~N~ ~.).~..~,~-~.~ ~ 15. Surface casing protects all known USDWs Y ~, 16. CMT vol adequate to circulate on conductor & surf csg ..... Y 17. CMTvoladequatetotie-inlongstringtosurfcsg ........ Y ~,y~.-'-~~ --~ - .. 18. CMT will cover all known productive horizons. ' Y~4,~_~ ~-.~,~m-~ ,~'_~ _ __ _~.~.~ C-..~ 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit .................~ N ~_._,~,.~.~-~.c,.~ ~'-'~c I ~'-,.t~ ~--~o,~,.~Cc 21. If a re-drill, has a 10-403 for abandonment been approved... ~ t~. '~ · 22. Adequate wellbore separation proposed .............. L'~N 23. If diverter required, does it meet regulations ..........~N_ ~ t~ ' 24. Ddlling .fluid program schematic & equip list adequate ...... ~~- .~ 25. BOPEs, do they meet regulation ......... '--' "-' ' ' ' N~i- ..... ,.~'~c~~-'~C~\~" D E 26. BOPE press rating appropriate; test to ~...,~,..~ psig. ~u~,_c.>~ e..c.~-\~~-. ~--~.c..~, C~ 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... ~'Y ~N ~ '~ '~'~'-~:: ~'?'~"~ ~~' 29. Is presence of H2S gas probable ................. ' ~ ~ ~X,.~..~,,,.~ ~.: , ~.. ~,~ ~.% ~,3/' <~e... ~.,~\ct.~-v,,.~, GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures ..... 31. Data presented on potential overpressure zones ....... YY~" 32. Seismic analysis of shallow gas zones,o y]~Y ! '/~/"/--J APPR ~D~E~3433' Seabed condition Survey (if off-shore) ............. Y N ' ~ ~ . / . Contact name/phone for weekly progress reports [exploratory ANNULAR DISPOSAL35. With proper cementing records, this plan · (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE . (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 -GEOL~)j~GY: ENGINEERING.:. 'UlC/Annular COMMISSION: Commentsllnstru~;tior}s: ' c:~msoffice\wordian~diana\checklist (rev. 111011/00) O Z O 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 APPE .N. DIXi 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 $ Fri Nov 23 08:52:05 2001 Reel Header Service name ............. LISTPE Date ..................... 01/11/23 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 ..................... 01/11/23 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 L1 500292301460 BP Exploration (Alaska), Inc. Sperry Sun 23-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 7 AK-MM-10166 T. GALVIN D. FERGUSON MWD RUN 8 AK-MM-10166 D. LABRECQUE D. FERGUSON 10 13N 10E 694 2298 RECEIVED 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: .00 45.17 16.50 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (ET) 20.000 110.0 9.875 7.000 10505.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - 3, 7, AND 8 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. MWD RUN 6 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 10505' MD, 4323' TVD TO 10541' MD, 4330' TVD IS DUE TO MILLING RUN. 6. MPC-4Lll IS TIED INTO MPC-41PB1 AT THE KICK OFF POINT. MPC-41L1 IS TIED INTO MPC-41 AT THE KICK OFF POINT. MPC-41L1 KICKS OFF FROM MPC-41PB1 AT 8550' MD, 3810' TVD. MPC-41L1 KICKS OFF FROM MPC-41 AT 10505' MD, 4323' 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, 7, AND 8 REPRESENT WELL MPC-41L1 WITH API # 50-029-23014-60. THIS WELL REACHED A TOTAL DEPTH OF 14148' MD, 4339' 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 ....... 01/11/23 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. DEPTH INCREMENT: .5000 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 10483 5 10489 0 10495 0 10498 0 10500 0 10501 0 10503 5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD GR 10479 5 10486 0 10490 5 10496 0 10498 5 10499 5 10500 5 STOP DEPTH 14097 5 14104 5 14104 5 14104 5 14104 5 14104 5 14150 5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 75.0 6046.5 2 6047.0 8550.0 3 8550.5 10505.0 7 10505.5 12126.0 8 12126.5 14150.5 $ # REMARKS: MERGED MAIN PASS. $ # 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 MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HR Min 75 1.98 12 54 0 09 0 06 0 06 0 04 0 09 Max Mean Nsam 14150.5 7112.75 28152 3011.61 228.012 27968 141.77 70.1062 28046 2000 17.8786 28010 2000 20.4687 28010 2000 23.352 28010 2000 39.8459 28010 32.36 0.952322 28010 First Reading 75 120 75 100 100 100 100 100 Last Reading 14150 5 14150 5 14097 5 14104 5 14104 5 14104 5 14104 5 14104 5 First Reading For Entire File .......... 75 Last Reading For Entire File ........... 14150.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/23 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 ....... 01/11/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 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 RPM RPS RPD FET RPX 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: 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 9.8 450 9.8 4.500 4.288 7.000 4.500 72.0 75.9 72.0 72.0 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 MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HR 4 1 68 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 06 0 04 0 09 Max Mean Nsam 6046.5 3060.75 11944 1014.02 278.708 11854 116.89 61.3222 11850 2000 29.7697 11785 2000 33.9932 11785 2000 36.2936 11785 2000 74.704 11785 6.18 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 ....... 01/11/23 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 ....... 01/11/23 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 RPM RPS RPX FET RPD GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5992 5 5992 5 5992 5 5992 5 5992 5 6000 0 6047 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: STOP DEPTH 8550 0 8550 0 8550 0 8550 0 8550 0 8550 0 8550 0 02-JUN-01 Insite 4.05.5 66.16 Memory 8550.0 73.8 77.9 TOOL NUMBER PB02044HWBRGF6 PB02044HWBRGF6 9.875 Spud Mud 9.30 73.0 8.6 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 3OO 5.0 4.200 3.074 6.100 3.200 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 65.0 91.3 65.0 65.0 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 ....... 01/11/23 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 ....... 01/11/23 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 RPD RPM RPS RPX GR ROP $ 8550 5 8550 5 8550 5 8550 5 8550 5 8550 5 8562 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 10505 10505 10505 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): STOP DEPTH 10505 0 10505 0 10505 0 10505 0 0 0 0 04-JUN-01 Insite 4.05.5 66.16 Memory 10505.0 70.3 86.9 TOOL NUMBER PB02044HWBRGF6 PB02044HWBRGF6 9.875 DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY {OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 10505.0 LSND 9.20 65.0 8.6 3OO 5.5 3.600 2.842 5.000 4.200 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 72.0 93.0 72.0 72.0 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HR Min 8550.5 2.12 26.4 1.18 1.14 1.13 1.27 0.13 Max 10505 3011.61 120 56 18 79 29 79 98 68 79 45 32 36 Mean Nsam 9527.75 3910 227.11 3887 70.4143 3910 3.99399 3910 4.1542 3910 4.66107 3910 4.70388 3910 0.976517 3910 First Reading 8550.5 8562 8550.5 8550.5 8550.5 8550.5 8550.5 8550.5 Last Reading 10505 10505 10505 10505 10505 10505 10505 10505 First Reading For Entire File .......... 8550.5 Last Reading For Entire File ........... 10505 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/23 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 ....... 01/11/23 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: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 10505.5 12079 5 GR 10505 5 12072 5 RPS 10505 5 12079 5 RPD 10505 5 12079 5 FET 10505 5 12079 5 RPX 10505 5 12079 5 ROP 10541 0 12126 0 $ LOG HEADER DATA DATE LOGGED: 18-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): 12123.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.5 MAXIMUM ANGLE: 93.9 # 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: $ # 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 TOOL NUMBER PB02035HAGR4 PB02035HAGR4 6.125 Baradril-N 9.10 45.0 8.5 28000 5.0 .180 .123 .140 .140 65.0 98.6 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD070 FT/H Min Max Mean Nsam 10505.5 12126 11315.8 3242 1.98 744.04 124.823 3171 First Reading 10505.5 10541 Last Reading 12126 12126 GR MWD070 API 49.48 132.88 RPX MWD070 OHMM 0.1 2000 RPS MWD070 OHMM 0.17 1811.2 RPM MWD070 OHMM 0.11 2000 RPD MWD070 OHMM 0.46 2000 FET MWD070 HR 0.28 29.95 84.0158 3135 17.9146 3149 20.4247 3149 34.4961 3149 37.3035 3149 1.57114 3149 10505 5 10505 5 10505 5 10505 5 10505 5 10505 5 12072 5 12079 5 12079 5 12079 5 12079 5 12079 5 First Reading For Entire File .......... 10505.5 Last Reading For Entire File ........... 12126 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPD RPM RPS RPX FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 12073.0 12080 0 12080 0 12080 0 12080 0 12080 0 12126 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE {MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL {FT) : STOP DEPTH 14097.5 14104 5 14104 5 14104 5 14104 5 14104 5 14150 5 21-JUN-01 Insite 4.05.5 66.16 Memory 14148.0 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) 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 85.0 94.7 TOOL NUMBER PB02035HAGR4 PB02035HAGR4 6.125 Baradril-N 9.20 50.0 9.0 28000 4.8 .100 .071 .150 .250 68.0 98.1 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 12073 14150.5 ROP MWD080 FT/H 5.05 932.71 GR MWD080 API 45.99 141.77 RPX MWD080 OHMM 2 63.09 RPS MWD080 OHMM 2.14 135.56 RPM MWD080 OHMM 2.25 1362.64 RPD MWD080 OHMM 2.49 86.3 FET MWD080 HR 0.23 30.01 First Mean Nsam Reading 13111.8 4156 12073 144.8 4049 12126.5 87.4806 4050 12073 12.4869 4050 12080 15.9748 4050 12080 17.5497 4050 12080 17.3939 4050 12080 1.72542 4050 12080 Last Reading 14150 5 14150 5 14097 5 14104 5 14104 5 14104 5 14104 5 14104 5 First Reading For Entire File .......... 12073 Last Reading For Entire File ........... 14150.5 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/11/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/11/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/11/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Sun Oct 21 11:45:36 2001 Reel Header Service name ............. LISTPE Date ..................... 01/10/21 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/10/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point 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-41PB2 500292301471 BP Exploration (Alaska), Inc. Sperry Sun 21-OCT-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 4 AK-MM-10166 T.GALVIN D. FERGUSON 10 13N 10E 694 2298 RECEIVED DEC 2 8 2001 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: .00 45.17 16.50 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 110.0 9.875 7.000 11200.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 - 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. THE GAP IN SROP FROM 8550' MD, 3810' TVD TO 8562' MD, 3813' TVD IS DUE TO PERFORMING OPEN HOLE SIDETRACK. 4. MPC-41PB2 IS TIED INTO MPC-41PB1 AT THE KICKOFF POINT. MPC-41PB2 KICKS OFF FROM MPC-41PB1 AT 8550' MD, 3810' TVD. 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. 5. MWD RUNS 1 - 4 REPRESENT WELL MPC-41PB2 WITH API % 50-029-23014-71. THIS WELL REACHED A TOTAL DEPTH OF 12205' MD, 4399' 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 ....... 01/10/21 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. DEPTH INCREMENT: .5000 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 12137 5 12144 0 12144 0 12144 0 12144 0 12144 0 12207 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 75.0 6046.5 2 6047.0 8550.0 3 8550.5 11212.0 4 11212.5 12207.0 MERGED MAIN PASS. 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 MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API 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 12207 3011.61 128.82 2000 2000 2000 2000 176.35 First Mean Nsam Reading 6141 24265 75 242.194 24152 120 66.6619 24126 75 17.2855 24089 100 19.4326 24089 100 21.7364 24089 100 43.7157 24089 100 1.67339 24089 100 Last Reading 12207 12207 12137.5 12144 12144 12144 12144 12144 First Reading For Entire File .......... 75 Last Reading For Entire File ........... 12207 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 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 $ 75.0 100 0 100 0 100 0 100 0 100 0 120 0 STOP DEPTH 5999 5 5992 0 5992 0 5992 0 5992 0 5992 0 6046 5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO 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: $ # 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 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 9.8 450 9.8 4.500 4.288 7.000 4.5OO 72.0 75.9 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT ROP MWD010 GR MWD010 RPX MWD010 RPS MWD010 RPM MWD010 RPD MWD010 FET MWD010 FT FT/H API OHMM OHMM OHMM OHMM HR 1 68 0 1 1 68 4 2 1 68 8 3 1 68 12 4 1 68 16 5 1 68 20 6 1 68 24 7 1 68 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 06 0 O4 0 09 Max 6046.5 1014.02 116.89 2000 2000 2000 2000 6.18 First Mean Nsam Reading 3060.75 11944 75 278.708 11854 120 61.3222 11850 75 29.7697 11785 100 33.9932 11785 100 36.2936 11785 100 74.704 11785 100 0.525262 11785 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 ....... 01/10/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW 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 RPX 5992.5 RPM 5992.5 GR 6000.0 ROP 6047.0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER /FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8550.0 8550.0 855O.0 8550.0 8550.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION {IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 02-JUN-01 Insite 4.05.5 66.16 Memory 8550.0 73.8 77.9 TOOL NUMBER PB02044HWBRGF6 PB02044HWBRGF6 9.875 Spud Mud 9.30 73.0 8.6 3O0 5.0 4.200 3.074 6.100 3.200 65.0 91.3 65.0 65.0 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 ....... 01/10/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/21 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log 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: 11151 11151 11212 STOP DEPTH 11151 5 11158 0 11151 5 11151 5 5 5 0 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: 04-JUN-01 Insite 4.05.5 66.16 Memory 11210.0 70.3 86.9 TOOL NUMBER PB02044HWBRGF6 PB02044HWBRGF6 9.875 11200.0 LSND 9.20 65.0 8.6 300 5.5 3.600 2.842 5.000 4.200 72.0 93.0 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 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 Units Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 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 11212 3011 61 120 56 38 75 38 51 98 68 79 45 32 36 Mean 9881.25 206.459 74.2491 4.87338 5.11613 5.6765 5.78751 0.923473 Nsam 5324 5301 5216 5203 5203 5203 5203 5203 First Reading 8550.5 8562 8550.5 8550.5 8550.5 8550.5 8550.5 8550.5 Last Reading 11212 11212 11158 11151.5 11151.5 11151.5 11151.5 11151.5 First Reading For Entire File .......... 8550.5 Last Reading For Entire File ........... 11212 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/21 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: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD RPM RPS RPX FET GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11152 0 11152 0 11152 0 11152 0 11152 0 11158 5 11212.5 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 12144 0 12144 0 12144 0 12144 0 12144 0 12137 5 12207 0 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 (I-N): 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: 12-JUN-01 Insite 4.05.5 66.16 Memory 12205.0 85.5 96.5 TOOL NUMBER PB02041GRHA4 PB02041GRHA4 6.125 Baradril-N 9.00 46.0 8.8 29000 5.0 .180 .139 .160 .210 70.0 93.0 70.0 70.0 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 MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 1 68 RPM MWD040 OHMM 4 1 68 RPD MWD040 OHMM 4 1 68 FET MWD040 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 Min Max Mean DEPT FT 11152 12207 11679.5 ROP MWD040 FT/H 5.11 2633.62 122.045 GR MWD040 API 40.7 128.82 75.4515 RPX MWD040 OHMM .. 0.28 977.54 6.47705 RPS MWD040 OHMM 0.36 25.58 6.76234 RPM MWD040 OHMM 0.16 1894.24 19.099 RPD MWD040 OHMM 0.68 2000 57.0169 FET MWD040 HR 0.46 176.35 12.3852 Nsam 2111 1990 1959 1985 1985 1985 1985 1985 First Reading 11152 11212.5 11158.5 11152 11152 11152 11152 11~52 Last Reading 12207 12207 12137.5 12144 12144 12144 12144 12144 First Reading For Entire File .......... 11152 Last Reading For Entire File ........... 12207 File Trailer Service name ............. STSLIB.005 Service Sub,Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/21 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/10/21 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 01/10/21 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 Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Oct 19 15:38:33 2001 Reel Header Service name ............. LISTPE Date ..................... 01/10/19 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 ..................... 01/10/19 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: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-10166 R. FRENCH J. PYRON MPC-41PB1 500292301470 BP Exploration (Alaska), Inc. Sperry Sun 19-OCT-01 MWD RUN 2 AK-MM-10166 D. LABRECQUE J. PYRON 10 13N 10E 694 2298 .00 45.17 16.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (ET) 20.000 110.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS {MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGE MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4). 3. 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. 4. MWD RUNS 1 AND 2 REPRESENT WELL MPC-41PB1 WITH API # 50-029-23014-70. THIS WELL REACHED A TOTAL DEPTH OF 8766' MD, 38637 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 ....... 01/10/19 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. DEPTH INCREMENT: .5000 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 $ # REMARKS: STOP DEPTH 8716 5 8710 0 8710 0 8710 0 8710 0 8710 0 8766 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 75.0 6046.5 2 6047.0 8766.0 MERGED MAIN PASS. $ # 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 MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HR Min 75 1.49 12 54 0 09 0 06 0 06 0 O4 0 09 Max Mean Nsam 8766 4420.5 17383 1014.02 266.256 17293 116.89 62.9684 17284 2000 21.9987 17221 2000 24.896 17221 2000 26.5292 17221 2000 52.8714 17221 16.06 0.647396 17221 First Reading 75 120 75 100 100 100 100 100 Last Reading 8766 8766 8716.5 8710 8710 8710 8710 8710 First Reading For Entire File .......... 75 Last Reading For Entire File ........... 8766 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/19 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 ....... 01/10/19 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 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 FET RPD RPS RPM 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 5999 5 5992 0 5992 0 5992 0 5992 0 5992 0 6046 5 31-MAY-01 Insite 4.05.5 66.16 Memory 6047.0 .0 76.4 TOOL NUMBER DGR EWR4 $ DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 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 PB02038HWBRGF6 PB02038HWBRGF6 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HR 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 75 6046.5 3060.75 11944 75 ROP MWD010 FT/H 4.86 1014.02 278.708 11854 120 GR MWD010 API 12.54 116.89 61.3222 11850 75 Last Reading 6046.5 6046.5 5999.5 RPX MWD010 OHMM RPS MWD010 OHMM RPM MWD010 OHMM RPD MWD010 OHMM FET MWD010 HR 0.09 2000 0.06 2000 0.06 2000 0.04 2000 0.09 6.18 29.7697 11785 33.9932 11785 36.2936 11785 74.704 11785 0.525262 11785 100 100 100 100 100 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 ....... 01/10/19 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 ....... 01/10/19 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 RPD RPM RPS RPX FET GR ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 5992.5 5992 5 5992 5 5992 5 5992 5 6000 0 6047 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): STOP DEPTH 8710 0 8710 0 8710 0 8710 0 8710 0 8716 5 8766 0 02-JUN-01 Insite 4.05.5 66.16 Memory 8766.0 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) 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 73.8 77.9 TOOL NUMBER PB02044HWBRGF6 PB02044HWBRGF6 9.875 Spud Mud 9.30 73.0 8.6 3OO 5.0 4.200 3.074 6.100 3.200 65.0 91.3 65.0 65.0 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 Min DEPT FT 5992.5 ROP MWD020 FT/H 1.49 GR MWD020 API 21.97 RPX MWD020 OHMM 1.38 RPS MWD020 OHMM 1.36 RPM MWD020 OHMM 1.38 RPD MWD020 OHMM 1.4 FET MWD020 HR 0.14 Max 8766 570 52 112 58 17 51 18 08 18 81 19 74 16 06 First Last Mean Nsam Reading Reading 7379.25 5548 5992.5 8766 239.117 5439 6047 8766 66.5584 5434 6000 8716.5 5.15157 5436 5992.5 8710 5.17377 5436 5992.5 8710 5.36042 5436 5992.5 8710 5.53956 5436 5992.5 8710 0.912176 5436 5992.5 8710 First Reading For Entire File .......... 5992.5 Last Reading For Entire File ........... 8766 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/19 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/10/19 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/10/19 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File