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Home My WebLink About202-160 Image P. Jject Well History File Cc; 1r Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. r) 0 a - L ~ Q Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~scan Needed I RESCAN ~olor Items: 0 Greyscale Items: DIJITAL DATA ø Diskettes, No. tf- 0 Other, NolType: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: BY: Helen ~ 0 Other:: I I Date:.;l 10S I ~ /s/ Y11 Project Proofing Scanning Preparation BY: Helen ~ t~ x 30 = qD i Date: ~ 1. ()Ò /5/ VV1P + ~ trf = TOTAL PAGES III Ácount doeS noJ include cover sheet, IÎA. .p Date: ~ c¡ oS- /s/ V f r . I. BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: J J g (Count does ¡nctu7e co sr sheet) Page Count Matches Number in Scanning Preparation:' YES . 1 Helen' Maria) Date:~ c¡ ~ If NO in stage 1, page(s) discrepancies were found: YES I NO NO IfJ mf BY: Stage 1 BY: Helen Maria Date: /s/ I I Date: /s/ Quality Checked 1111111.111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 op,. - /:7O . 02-P Mr. Jim Regg Alaska Oil and Gas Conservation Commission MtiAU_ 20 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB H -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 --P H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 H -06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 H -11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18/2010 H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18 /2010 1415 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 11-16 2000650 50029205920200 0 NA NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 H -18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 H -20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 • H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 I-I-22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 I-1-23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 1-1-25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 11-26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 1-1-28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 H -30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 H -31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 11-32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 H -33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 H -34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 H -35 1951490 50029226000000 1.7 NA 1.7 _ NA 15.30 2/16/2010 H -36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 H -38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 ' • STATE OF ALASKA is ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WIND ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 7/1/2010 202 - 160 310 - 122 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 08/23/2002 50 029 - 20100 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 12/25/2002 PBU H -02A 4207' FSL, 1265' FEL, SEC. 21, T1IN, RUE, UM 8, KB (ft above MSL): 73,27 15. Field / Pool ( ): Top of Productive Horizon: 627' FSL, 2769' FEL, SEC. 21, T11 N, R1 3E, UM GL (ft above MSL): 44.01' Prudhoe Bay Field /Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 252' FSL, 984' FEL, SEC. 21, T11 N, R1 3E, UM 2511' 2511' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x 643319 y 5959715 Zone ASP4 12950' 8863' ADL 028284 TPI: x 641892 y 5956108 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x 643684 y 5955767 Zone ASP4 N/A 18. Directional Survey: ❑ Yes ® No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): Submit electronic and printed information per 20 AAC 25.050 N/A ft MSL 1900' (Approx.) Re -Drill /Lateral Top Window MD/TVD: 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. MWD, PWD, DIR, GR, ABI, RES, NEU, DEN 5529' 5528' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. I GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 157.5# Conductor Surfa ce 100' Surfa ce 100 36" 275 x Cement rf rf 4" 4200 sx: Permafr 13 -3/8" x 9 - 5/8" 68# / 47# K -55 / N -80 Surface 29' Surfa 5528' 12 -1/4" 1561 sx CI 'G' 1825 sx PF & 502 sx'G' 7" 26# 3980' 1 10861', 3980' 727' 1 8 -1/2" 165 sx Class 'G' 4 -1" 12 1 71 4' -/" 1278 sx Class" 24. Open to production or,injection? ❑ Yes ®No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET MD PACKER SET MD / TVD (MD +TVD of Top & Bottom; Perforation Size and Number): 4 -1/2 ", 12.6#, 13Cr80 2805'- 10718' 10648'/ 8618' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9551' P &A w/ 54.5 Bbls Class 'G' 2702' Set EZSV 2511' Set Whipstock 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL-BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: Gas -MCF: WATER -BBL: OIL G RAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, as or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory anal 50.071. None RBDMS JUL 2 9 201 A AlBSKa UN & Gas C$rJ'COr ISSIof Form 10-407 Revised 12/2009 CONTINUED O REVERSE A 3/. �o d nginal Only ! zp a 29. - GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Colville Mudstone 2 6231' 6189' None Colville Mudstone 1 7000' 6739' Top HRZ 7617' 7061' LCU 8120' 7326' Kingak 8821' 7682' Sag River 10850' 8721' Shublik 10904' 8749' Sadlerochit 11080' 8835' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Teme Hubble Title: Drilling Technologist Date: PBU H -02A 202 -160 310 -122 Prepared ByName/Number. Terrie Hubble, 564 -4628 Well Number Permit No. /Approval No. Drilling Engineer: Mel Rixse, 564 -5620 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only H -02A, Well History (Pre Rig Sidetrack) Date Summary 4/24/2010 WELL FLOWING ON ARRIVAL. INITIAL T /I /O: 780 /1350 / 0. SHUT -IN WELL. RUN 1: 3.7" GAUGE RING ON JUNK BASKET TO 11000'. RUN 2: TUBING PUNCH 10707'- 10711'. 4/25/2010 INITIAL T /I /O: 780/1350/ 0 TUBING PUNCH GUN 2: INTERVAL 10656 FINAL T /I /O: 745/1300/0 JOB COMPLETE. 4/26/2010 T /1 /0= 400/1240/0/120 temp =S /I Injectivity Test (Sidetrack Prep) Pumped 1 bbl neat meth & 387 bbls crude down TBG @ 5 bpm @ 550 psi, for an Injectivity test. PE & Pad -Op notified of results. FW P= 0/1240/0/120 4/28/2010 T /I /O /00= SSV/1260/5/170. Temp= SI. Bleed IA & OAP < 300 psi (Secure). AL shut -in @ casing valve, ALP= 1650 psi. IA FL @ 4085' (sta # 5). Bled IAP from 1260 psi to 150 psi in 2 hours (all gas). Monitored for 30 minutes, IAP increased 10 psi. Alemite test -port fitting @ 9 o'clock position shows signs of hydraulic leak. Warning tag not to pump methanol into OA/OOA needs to be replace. Job completed. Final WHPs= SSV/160/5/170. 5/4/2010 T /1 /0/00 = Vac /300/0/180 Load IA with crude. Heat Transport of diesel to 75 °F (Secure) Pumped into the IA with 210 bbls of crude. Final WHP's = Vac/Vac /0/180 5/5/2010 Fullbore P & A. Pum ped 288 bbls of 1 % KCL, 10 bbls of Chemical wash 10 54.5 bbls of 15.8 ppa "G" Cmt (6 bbls clean, 24 bbls w/ agregate, 24.5 bbls clean Cmt). 2 bbls H2O, Drop 6" sponge ball, 5 bbls H2O. Displace with 147 diesel. CIP = 11:57 hrs. TOC = 9,551' and SLM. 5/8/2010 WELL S/I ON ARRIVAL. DRIFT W/ 2'11 7/8" STEM, 3.70" CENT, 2.50" S- BAILER TO 9551' SLM (bailer empty). DRIFT W/ 2'1 7/8" STEM, 3.25" CENT, 2.50" S- BAILER TO 9551' SLM (bailers full of cement). SET 4 1/2" SLIP STOP CATCHER @ 8720' SLM. PULL DGLV FROM STA # 2 @ 8586' SLM / 8603' MD. PULLED EMPTY CATCHER FROM 8720' SLM. WELL S/I ON DEPARTURE. 5/10/2010 T /1 /0= 0/0/0/200 Temp= S/I CMIT -TxIA to 2500 psi (Rig sidetrack prep) CMIT -TxIA PASSED to 2500 Dsi: P assed on 2nd Attempt, Pumped 5.5 bbls diesel down IA to pressure TBG /IA to 2500 psi. TBG /IA lost 10/20 psi in the 1 st 15 mins and 10/20 psi in the 2nd 15 mins for a total loss of 20/40 psi during the 30 min test. Bled WHPS to 0 psi. FW H Ps 0/0/0/200 5/10/2010 T /1 /0= 200/160/0 Circ well to 1% kcl (RWO) Spear with 2 bbls neat meth followed by 646 bbls 1% kcl down TBG up IA to H -29 flow line. Pump 150 bbls 110° diesel down IA and U -tube for freeze protect TxIA. Pump 5 bbls diesel through hardline to H -29 for freeze protect. Bleed WHP's to 0 psi. FWHP's =0/0/0 5/12/2010 WELL SI ON ARRIVAL. INITIAL T /1 /0= 50/0/0 POW ERCUTTER SHOT AT A DEPTH OF 2805 FINAL T /I /O = 40/0/0 JOB COMPLETED. WELL LEFT SI. 5/16/2010 T /1 /0/00 = ONAC /10/200. Temp = SI. Bleed WHPs to 0 psi, monitor gas rate on OOA (pre RIG). ALP = 260 psi. AL SI @ casing valve. OA FL near surface. OOA cemented to surface. Cellar is - 12'3" wide x 7'8" long x 3'- 4 1/2' deep with boarded sides. Conductor is 30 ". Will need cellar floor leveled before liner is installed. Bled OAP from 10 psi to 0 psi in 4 mins (all gas). Bled OOAP from 200 psi to 0 psi in 1 min and maintained open bleed for 5 hrs (see log for gas rate & 4 gas meter reading details). Monitored for 30 mins. OOAP increased 1 psi. Final WHP's = 0+/VAC /0 +/1. Job complete. 5/16/2010 T /1 /0= 0/VAC /0 +, Temp =Sl. Repair leaking well head. Found 2 weeping LDS assemblys on tubing spool upper flange. Stung into TBG hanger test void (0+ psi), bled to 0 psi. Adjusted all gland nuts. PT test void to 5000 psi for 15 min, leaks mitigated. Bled void to 0 psi. T /I /O= ONAC /O +, Temp =Sl. Repair leaking well head. 5/17/2010 T /1 /0 /00= SSVNac /10/40. Temp =Sl. WHPs (pre Rig). ALP =270. OAP increased 10 psi, OOAP increased 39 psi since yesterday. 5/19/2010 T /I /O /00= 2NAC /5/80. Temp= SI. Bleed WHPs to 0 psi, maintain open bleed throughout shift (pre RIG). AL SI @ casing valve. ALP= 260 psi. TBG & OA FL near surface. OOA cemented to surface. Bled TP from 2 psi to 0+ psi in <1 min. Bled OA from 5 psi to 0 psi in <1 min. Bled OOA from 80 psi to 0 psi in <1 min. Maintained open bleed on OA & OA for 5 hrs. Monitored for 30 min, TP remained unchanged, OA increased 2 psi, OOA increased 5 psi. Final WHPs= ONAC /2/5. 5/20/2010 T /I /O /00 = 2NAC/4/46. Temp = SI. Bleed WHPs to 0 psi (pre rig). ALP = 300 psi. AL SI @ casing valve. Tbg, OA & OOA FL's near surface. Bled TP from 2 psi to 0 psi in < 1 min. Bled OAP from 4 psi to 0 psi in 1 min. Bled OOAP from 46 psi to 0 psi in < 1 min and maintained open bleed on OOA for 4 hrs, taking air samples every hr (see log for details). OAP increased 1 psi. Monitored for 30 mins. OOAP increased 1 psi. Final WHPs = ONAC /1/1. Job complete. Page 1 of 2 0 H -02A, Well History (Pre Rig Sidetrack) Date Summary 5/21/2010 T /1 /0 /00 =2NAC /5/10. Temp= SI. Bleed WHPs to 0 psi, maintain open bleed throughout shift (pre RIG). AL SI @ casing valve. ALP= 260 psi. TBG & OA FL near surface. OOA cemented to surface. Bled TP from 2 psi to 0+ psi in <1 min. Bled OA from 5 psi to 0 psi in <1 min. Bled OOA from 10 psi to 0 psi in <1 min. Maintained open bleed on TBG, OA & OOA for 5 hrs. Monitored for 30 min, TP remained unchanged, OA increased 2 psi, OOA increased 5 psi. Final WHPs= ONAC /2/5. Job complete. 5/22/2010 T /1 /0 /00= 0 +NAC /O +/20. Temp= SI. Bleed WHPs to 0 psi, maintain open bleed throughout shift (pre rig). AL SI casing valve. ALP= 260 psi. TBG, OA, OOA FL near surface. Bled TBG, OA, OOA to 0 psi in <1 min. Held open bleed on TBG, OA & OOA for 6 hr. Monitored for 30 min, TBG & OAP remained unchanged, OOAP increased 5 psi. Final WHPs= ONAC /0/5. Job complete. 5/23/2010 TWO = 5NAC/3/39. Temp = St. Bleed WHPs to 0 psi, maintain OOA open bleed throughout shift (pre rig). AL SI @ casing valve. TBG, OA & OOA FL near surface. Bled TBG pressure from 5 psi to 0 psi in < 1 min. Bled OAP from 2 psi to 0 psi in 2 min. Bled OOA from 39 psi to 0 psi in < 1 min and maintained open bleed on OOA for 4 hrs. During bleed OAP increased 1 psi. Monitored for 30 mins. OOAP increased 1 psi. See log for details. Final WHPs = ONAC /1/1. Job complete. 5/23/2010 T /I /0 /00 =1Nac /1/10. Temp =Sl. Bleed WHP's to 0 psi maintain open OOA bleed throughout shift. (pre -Rig). TBG, OA & OOA FL's all near surface. Bled TP, OAP & OOAP to 0 psi in < 1 minute, maintaining open bleed on T, O & 00 for the shift. TP, OAP & OOAP remained @ 0 psi for 7.5 hours. Rig down & monitor for 30 minutes for end of shift. TP, OAP & OOAP remained @ 0 psi during monitor. Final WHP's= ONac /0/0. Job complete. 5/23/2010 T /1 /0 /00= 0/0/0/0, Temp =Sl. PPPOT-T (PASS), PPPOT -IC (PASS), pre RST. PPPOT -T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: Stung into test port (0 psi). Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 2500 psi in 1 min. Torqued LDS to 600 Ibft. Pressured void to 3500 psi, lost 2500 psi in 1 min. Bled to 0 psi. RU to PKG port and re- energized the secondary Y seal. Pressured test void to 3500 psi, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 5/25/2010 T /1 /0 /00= BPVNAC /1/40. Temp= SI. Monitor (post bleed). AL SI @ casing valve. ALP= 260 psi. OAP increased 1 psi, OOAP increased 40 psi since 5/22/10. Page 2 of 2 rtt.lmeric -ALASKA ' ; Pic f 1 0'' �:. r��arr iry �r Common Well Name: H-02 AFE No Event Type: MOBILIZATION (MOB) Start Date: 6/21/2010 End Date: X3- OOTWG -C (565,347.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: Rig Contractor: DO Y O N DRILLING INC. UWI: Active Datum: H -02 @64.Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 6/21/2010 06:00 - 10:00 4.00 MOB N WAIT PRE WAIT ON SIMULTANEOUS RIG MOVES. MOVE ROCK WASHER CHANGE OUT SAVER SUB & GRABBER DIES ON TOP DRIVE REMOVE HEATERS & MOUSE HOLE FROM CELLAR REPAIR RIG FLOOR OIOE SKATE HANDRAIL CLEAR FLOOR O F TOOLS FOR MOVE 10:00 11:00 1.00 MOB N WAIT PRE WAIT ON SIMULTANEOUS RIG MOVES. PRE -JOB SAFETY MEETING RD LINES UNDER FLOOR 11:00 12:30 1.50 MOB N WAIT PRE WAIT ON SIMULTANEOUS RIG MOVES. PRE -JOB SAFETY MEETING SKID FLOOR TO MOVING POSITION HOLD AAR MEET 12:30 - 13:30 1.00 MOB N WAIT PRE WAIT ON SIMULTANEOUS RIG MOVES. REMOVE CELLAR DOORS, FRONT SLIPS, HANDRAILS, PU STAIRS OF OF HIGHLINE @ 13:30 13:30 00:00 10.50 MOB N WAIT PRE WAIT ON SIMULTANEOUS RIG MOVES. PRE -JOB SAFETY MEETING MOVE RIG OFF OF WELL SPOT THE RIG NEXT TO THE SHOP PLUG SHOP INTO RIG REMOVE STACK FROM CELLAR INSTALL FRONT BOOSTER FRAMES, FRONT BOOSTERS, REAR BOOSTERS CHANGE OUT DS TONG HANGING CABLE AND SHEAVE INSPECT DRAW WORKS CHAINS 6/22/2010 00:00 13:00 13.00 MOB N WAIT PRE WAIT ON SIMULTANEOUS RIG MOVES PERFORM RIG MAINTENANCE - CHANGE OUT ODS TONG HANGING LINE & SHEAVE CHANGE OUT RISER CABLE IN PIT 2 INSPECT DERRICK - CHANGE OUT 3" VALVE ON AIR LINE TO RIG FLOOR SHORTEN #2 CONVEYER CHAIN. WELDER REPLACE "T" ON BOILER BLOW DOWN LINE 13:00 13:15 0.25 MOB P PRE PRE -JOB SAFETY MEETING 13:15 18:00 4.75 MOB P PRE MOVE DOWN B -PAD, TURN RIG AROUND, MOVE OFF OF B -PAD TO PRICE PAD 18:00 00:00 6.00 MOB P PRE WAIT ON RIG MATS TO BE LAID OUT 6/23/2010 00:00 04:00 4.00 MOB P PRE MOVE RIG TO GC -2 04:00 06:00 2.00 MOB P PRE LAY RIG MATS TO MOVE AROUND GC -2 06:00 10:00 4.00 MOB N RREP PRE REMOVE FRONT BOOSTER, BOOSTER BRAC KET, & FRONT SPREADER BEAM Printed 7/6/2010 10:15:27AM North America ALASKA - BPae,t,2 AM- Operation Sumimary Report Common Well Name: H-02 AFE No Event Type: MOBILIZATION (MOB) Start Date: 6/2112010 End Date: X3- OOTWG -C (565,347.00) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: Rig Contracto D O Y ON DRILLING INC. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 16:00 6.00 MOB N RREP PRE CHANGE OUT INSIDE DS TIRE IN FRONT INSTALL FRONT FROG, SUPPORT BRACES, STEARING ARM, VERTICLE RIG BRACE, LANDING STEPS, FLOORING, BOOSTER BRACKET,BOOSTERS SIMOPS: LAY RIG MATS 16:00 18:30 2.50 MOB P PRE MOVE RIG FROM GC -2 TO H -PAD 18:30 21:30 3.00 MOB P PRE REMOVE REAR BOOSTERS, FRONT BOOSTERS, I BOOSTER BRACKET PU BOP STACK HANG CELLAR DOORS PU MOUSE HOLE 21:30 23:00 1.50 MOB P PRE MOVE RIG SPOT OVER WELL H-02 SHIM UNDER RIG 23:00 23:15 0.25 MOB P PRE PRE -JOB SAFETY MEETING 23:15 00:00 0.75 MOB P PRE SKID RIG FLOOR INTO DRILLING POSITION HOOK UP SERVICE LINES TO THE RIG FLOOR (STEAM, WATER, AIR) SIMOPS: LAY RIG MATS FOR ROCK WASHER, LAY HERCULITE FOR ROCK WASHER 6/24/2010 00:00 02:00 2.00 MOB P PRE RU ON H -02. SPOT ROCK WASHER. SPOT GEO AND MUD TRAIERS. SPOT FUEL TANK. 02:00 05:30 3.50 BOPSUR P PRE ACCEPT RIG AT 02:00 HRS. REMOVE BLIND FLANGE FROM TREE. DOUBLE VALVE OA AND IA OUTLETS, INSTALL 1502 UNION. START FILLING PITS W ITH BRINE. 05:30 11:00 5.50 BOPSUR P PRE RU TO PRESSURE TEST. TEST OOA WITH DIESEL TO 1,000 PSI, STOP PUMPING - PRESSURE IMMEDIATELY FELL OFF PRESSURED UP TO 1,000 PSI AGAIN WITH SAME RESULT. TEST OA TO 2,000 PSI AND HOLD FOR 10 MINUTES. - TEST LOST 15 PSI IN 10 MINUTES TEST TBG X IA TO 2,500 PSI AND HOLD FOR 10 MINUTES. TEST LOST 25 PSI IN 10 MINUTES BLOW DOWN ALL LINES. Printed 7/6/2010 10:15:27AM Common Well Name: H-02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- OOTWG -C (4,984,180.00) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Datefrime: 6/23/1971 12:00:OOAM Rig Release: Rig C ontractor: DOYON DRILLING INC. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/24/2010 11:00 13:00 2.00 BOPSUR P DECOMP RIG UP DSM LUBRICATOR AND TEST TO 500 PSI. - NO LEAKS PULL BACK PRESSURE VALVE. RD DSM 13:00 15:00 2.00 BOPSUR P DECOMP DISPLACED DIESEL FREEZE PROTECT WITH 32 BBL SAFE SURF O AND 8.4 PPG BRINE. - RECOVERED 150 BBLS DIESEL. LET FLUID STAND FOR 10 MINUTES. PUMP 10 BBL. TO CONFIRM ALL DIESEL REMOVED FROM WELL. 15:00 15:30 0.50 BOPSUR P DECOMP BLOW DOWN CIRCULATING LINES. RIG UP LINES TO IA 15:30 16:00 0.50 BOPSUR P DECOMP CONFIRM NO FLOW. DRY ROD TWC _ 16:00 17:30 1.50 BOPSUR P DECOMP TEST TWC FROM BELOW WITH 1,000 PSI FOR 10 MINUTES. - LOST 20 PSI IN 10 MINUTES TEST TWC FROM ABOVE WITH 3,500 PSI FOR 10 MINUTES. LOST 30 PSI IN 10 MINUTES -- 17:30 18:30 1.00 BOPSUR P DECOMP , RD ALL CIRC LINES VAC FLUIDS OU OF TREE 18:30 18:45 0.25 BOPSUR P DECOMP PRE -JOB SAFETY MEETING 18:45 20:30 1.75 BOPSUR P DECOMP BUILD FLOOR AROUND CELLAR NIPPLE DOWN TREE BREAK TREE FROM ADAPTOR RE- TORQUE LDS TEST RUN THE 4 -1/2" IF X 4 -1/2" NSCT X -OVER TO TEST JOINT 7 TURNS TO MAKE UP HAND TIGHT 20:30 00:00 3.50 BOPSUR P DECOMP INSTALL 18" SPACER SPOOL NU STACK CHANGE OUT SPACER ON CHOKE LINE 6/25/2010 00:00 03:00 3.00 BOPSUR P DECOMP INSTALL 1' SPACER SPOOL ON CHOKE LINE 1 NU RISER AND FLOW LINE 03:00 04:00 1.00 BOPSUR P DECOMP RU LINES AND TEST PUMP TO TEST BOPE 04:00 11:00 7.00 BOPSUR P DECOMP TEST BOPE 3,500 PSI HIGH, 250 PSI LOW, 5 MIN EACH n _ p UPPER RAMS (3 -1/2" X 6 ") W/ 4" & 4 -1/2" TEST y / 3 1 V JOINT - LOWER RAMS (2 -7/8" X 5 ") W/ 4" & 4 -1/2" TEST JOINT - CHOKE & KILL LINE, BLIND SHEARS, KILL LINE VALVE, - ANNULAR PREVENTOR TO 2,500 PSI HIGH, 250 PSI LOW WITH 4" TEST JOINT TEST WITNESSED BY BP WSL DUNCAN FERGUSON, ZACH SAYERS, DOYON TP NICK MARMON, HARRY GOCHENAUER AOGCC WITNESS WAIVED BY LOU G RIMALDI 11:00 13:00 2.00 BOPSUR N RREP DECOMP CHANGED MANUAL VALVE ON KILL LINE. Printed 7/6/2010 10:16:12AM N�ica /P Page os Common Well Name: H-02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- OOTWG -C (4,984,180.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: Rig Co ntract or: DOYO DRI INC. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 15:30 2.50 BOPSUR P DECOMP CONTINUE TO TEST BOPE 3,500 PSI HIGH, 250 PSI LOW, 5 MIN EACH VALVES 1,2,4,5,6,7,8,9,10,11,12,13,14 UPPER IBOP ON TOP DRIVE VALVE 3 TIW DART VALVE ACCUMULATOR TEST TEST WITNESSED BY BP WSL DUNCAN FERGUSON, ZACH SAYERS, DOYON TP NICK MARMON, HARRY GOCHENAUER AOGCC WITNESS WAIVED BY LOU GRIMALDI RIG ON HIGHLIN'E AT 13 :00 15:30 16:00 0.50 BOPSUR P DECOMP BLOW DOWN CHOKE & KILL LINE RD TESTING EQUIPMENT _ 16:00 16:15 0.25 BOPSUR P DECOMP PRE -JOB SAFETY MEETING i 16:15 18:00 1.75 BOPSUR P DECOMP PU DSM LUBRICATOR EXTENSION & TOOLS RU & TEST TO 500 PSI FOR 5 MIN NO LEAKS PULL TWC FLOW CHECK - STATIC RD & LAY DOWN DSM TOOLS SIMOPS: RU TO PERFORM INJECTIVITY TEST ON THE OOA (18 -5/8" X 13 -3/8 ") INJECT AT 1 GPM, 1,000 PSI TOTAL OF 4 GAL PUMPED AWAY OOA SLOWLY BLED DOWN TO 600 PSI IN 15 MINUTES 18:00 18:30 0.50 PULL P DECOMP PREPARE FOR PU LLING 4 -1/2" TUBING MU 4" DP, 2 XOS SUCK OUT STACK I SCREW INTO HANGER SCREW INTO TOP DRIVE BACK OUT LOCK DOWN SCREWS 18:30 19:00 0.50 PULL P DECOMP PULL 4 -1/2" TUBING HANGER TO THE RIG FLOOR —�— 83K PULL TO F_ REE HANG ER 19:00 19:30 0.50 PULL P DECOMP CBU 7 BPM, 100 PSI SIMOPS: LIFT CASING EQUIPMENT TO RIG FLOOR 19:30 20:00 0.50 PULL P DECOMP RU CASING EQUIPMENT 20:00 20:30 0.50 PULL P DECOMP LD 4" DP, 2 XOS, 4 -1/2" HANGER BLOW DOWN TOP DRIVE CHANGE OUT ELEVATORS MU FLOOR VALVE _ 20:30 20:45 0.25 PULL P DECOMP PRE -JOB SAFETY MEETING 20:45 00:00 3.25 PULL P DECOMP PULL 4 -1/2" 12.6 #, 13CR80, NSCT TUBING FROM 2,805' TO 60' MD _ Printed 7/6/2010 10:16:12AM N orth America = ALASKA BP P � O'pbratin Slummary Report Common Well Name: H- 02_DIMS AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- OOTWG -C (4,984,180.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: R ig C DO Y O N DRILLING INC. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/2612010 00:00 - 00:15 0.25 PULL P DECOMP LD 4 -1/2 12.6# 13CR80. NSCT TUBING F ROM 60' TO SURFACE - RETREIVED 1 X- NIPPLE 92 TOTAL FULL JOINTS (RANGE 2) 1 CUT JOINT, 9.072',4-15/16" CLEAN CUT WITH FLARE 00:15 01:00 0.75 CLEAN P DECOMP CLEAR RIG FLOOR OF CASING RUNNING EQUIPMENT 01:00 01:30 0.50 CLEAN P DECOMP PU BAKER CLEAN OUT BHA 01:30 02:30 1.00 CLEAN P DECOMP LOAD COLLARS IN THE PIPE SHED I STRAP DRILL COLLARS 02:30 04:00 1 1.50 CLEAN P DECOMP MU 9-5/ 8" - CLEAN OUT BHA WITH 8 -1/2" BIT AND FULL GAGE STRING MILL AND 9 EA 6 1/4" DRILL COLLERS. 04:00 05:30 1.50 CLEAN P DECOMP RIH WITH CLEAN OUT BHA TO 2,200' TAKING WEIGHT PICK UP 10' 05:30 06:00 0.50 CLEAN P DECOMP. PICK UP 10'. RUN BACK DOWN ROTATING, NOTED A SMALL TORQUE SPIKE AND STRING FELL THROUGH. PASSED TOOLS THROUGH TIGHT SPOT TWO TIM WITH NO OBSTRUCTION. 06:00 06:30 0.50 CLEAN P DECOMP RIH. TAG CUT TUBING AT 2.817'. 06:30 07:30 1.00 CLEAN P DECOMP CIRCULATE. PUMP AROUND 30 BBL HIGH VISC PILL 07:30 08:30 1 1.00 CLEAN P DECOMP POOH FROM 2,675' TO 2,231'MD. WORK PIPE THRU 9 -5/8" DV COLLAR @ 2,200' MD. POOH TO 303' MD 08:30 09:30 1.00 CLEAN P DECOMP CHANGE OUT ELEVATORS TO 5 ". STAND BACK 6 -1/4" DRILL COLLARS IN DERRICK. LD BAKER TOOLS A 8.5" BIT _ 09:30 10:00 0.50 CLEAN P DECOMP PERFORM RIG EVAC DRILL. 4 MINUTE RESPONSE TIME 10:00 10:30 0.50 CLEAN P DECOMP CLEAR RIG FLOOR OF BAKER TOOLS DOWN BEAVER SLIDE 10:30 11:00 0.50 CLEAN P DECOMP SERVICE TOP DRIVE & BLOCKS 11:00 13:00 2.00 PULL P DECOMP SPOT E -LINE CREW. PJSM. RU E -LINE USIT LOG - FOR 9 -5/8" 13:00 15:30 2.50 PULL P DECOMP LOG FROM 2,800' TO SURFACE WITH USIT TOOL DV TOOL LOCATED AT 2,275' MD TOC LOCATED AT 1,996' M 15:30 17:00 1.50 PULL P DECOMP LD LOGGING TOOLS. I TES CCL/GR CONNECTION 17:00 0.25 PULL P DECOMP PRE -JOB SAFETY MEETING 19:00 1.75 PULL t P �— DECOMP pU 9 -5/8" EZSV WITH GR/CCL. RIH TO 2,702', LOCATE, AND SET EZSV. TOP OF EZSV AT 2,702' MD. POO & LD E -LINE 19:00 19:15 0.25 PULL P DECOMP PRE -JOB SAFETY MEETING Printed 7/6/2010 10:16:12AM N tti Amerti a' :- ALASKA ;' _ Pale 4 rim 00eratian 5urnmary Rdoo t Common Well Name: H-02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- OOTWG -C (4,984,180.00) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: R ig Contracto DO DRIL LING INC. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 19:15 20:30 ( 1.25 PULL P DECOMP RU TO TEST CASING. TE ST 9 -5/8" CASING AND EZSV TO 2.500 PSL FOR 30 MIN. - TEST LOST 10 PSI IN THE 1ST 15 MINUTES AND O PSI IN THE 2ND 15 MIN FOR A TOTAL OF 10 PSI. RD TEST EQUIPMENT AND BLOW DOWN LINES 20:30 21:00 0.50 PULL P DECOMP PU BAKER 8 -1/4" MULTI STRING CUTTING TOOLS TO THE RIG FLOOR 21:00 21:30 0.50 PULL P DECOMP MU CUTTER, XO , STABILIZER, PUMP OUT SUB, XO 21:30 22:30 1.00 PULL P DECOMP MU 3 STANDS '6 -1/4" DRILL COLLARS, XO. PU 18 JOINTS OF HWDP 22:30 23:30 1.00 PULL P DECOMP RIH WITH 4" DP FROM 841' TO 1,791' 23:30 00:00 0.50 PULL P DECOMP ATTEMPT TO LOCATE 9 -5/8" CASING COLLARS (NSCC THREADS) PUW - 107K; SOW - 109K, 5 BPM, 410 PSI; 6 BPM, 550 PSI 6127/2010 00:00 00:30 0.50 PULL P DECOMP ' CONTINUE TO LOCATE COLLARS 00:30 01:00 0.50 PULL P DECOMP CUT 9 -5/8" CASING AT 1,857' MD PUW- 100K; SOW - 11 OK 80 RPM, 1 -6K TQ CASING DOPPED DOWN ON KNIVES (IN COMPRESSION) PULLED 375K TO FREE CASING CUTTER PERFORMED DERRICK INSPECTION 01:00 0200 1.00 CLEAN P DECOMP RU LITTLE RED TO PUMP DIESEL DOWN DP THROUGH CUT INTO 9 -5/8" X 13 -3/8" ANNULUS PERFORM PRE -JOB MEETING WITH ALL HANDS 02:00 03:30 1.50 CLEAN P DECOMP PUMP DIESEL INTO 9 -5/8" X 13 -3/8" ANNULUS THROUGH CUT PUMPED 22 BBLS AWAY AT 2 BPM PRESSURE STARTED CLIMBING TO 2,000 PSI SLOW DOWN RATE TO STAY BELOW 2,000 PSI (0.25 - 0.5 BBUMIN) STOP PUMPING AND LET DIESEL SOAK FOR 10 MINUTES DECISION MADE TO INCREASE PRESSURE THRESHHOLD TO 3,000 PSI PUMP AT RATE TO STAY BELOW 3,000 PSI (0.25 - 0.5 BBUMIN) STOP PUMPING AND LET DIESEL SOAK FOR 20 MINUTES 03:30 04:00 0.50 CLEAN P DECOMP BLEED OFF ALL PRESSURE AND ALLOW TO EQUALIZE RD AT RIG FLOOR DROP BALL AND ROD i PRESSURE UP TO 1,400 PSI TO SHEAR PUMP OUT SUB 04:00 05:00 1.00 CLEAN P DECOMP CONTINUE TO CIRCULATE 140 BBLS DIESEL TOTAL ABLE TO CIR CULATE AT 2 BPM, 300 PSI 05:00 06:00 1.00 CLEAN P DECOMP LET DIESEL SOAK IN ANNULUS FOR 1 HOUR Printed 7/6/2010 10:16:12AM No�t�t�America' .Ake =. ESP Pag'i: C/perat€rn Sum Report Common Well Name: H -02 DIMS AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 ( End Date: X3- OOTWG -C (4,984,180.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: Ri Contractor: DOYON DRILLING IN C. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs I Task 7Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 07:00 1.00 CLEAN DECOMP CIRCULATE 260 BBL AT 5 BPM WITH 1450 PSI. RECOVER 200 BBL DIESEL AND SMALL AMOUNT OF CONTAMINATED DIESEL IN OPEN TOP TANK. BLOW DOWN LINES. FLOW CHECK 07:00 09:00 2.00 CLEAN P DECOMP POOH FROM 1857' TO 841'. CHANGE ELEVATORS TO 5" STAND BACK 5" HWDP AND 6 1/4" DRILL COLLARS. LAY DOWN BAKER MULTI STRING CUTTER. WEAR PATTERN ON BLADES INDICATE THE CASING IS CUT. 09:00 10:00 F 3.O CLEAN P DECOMP CLEAR RIG FLOOR OF TOOLS. PULL WEAR RING. 10:00 13:00 CLEAN P DECOMP FLOW CHECK FOR 15 MINUTES. WELL STATIC. NIPPLE DOWN BQP. R IG DOWN FLOW LINE AND RISER NIPPLE.' DISCONNECT KILL AND CHOKE LINES. SET BOP BACK ON STUMP IN CELLAR. NIPPLE DOWN SPACER SPOOL AND TUBING SPOOL - CAMERON HANDS PREP SLIPS FOR PULLING CAMERON INSTALLED HANDLES ON SLIPS AND SECURED TO CASING WITH WIRE. 13:00 15:30 2.50 CLEAN P DECOMP Nu BoPE NIPPLE UP 5' LONG 5000 PSI, 13 5/8" SPACER SPOOL. NIPPLE UP BOP. NU RISER FLOW LINE, BLEED OFF LINE, HOLE FILL LINE SIMOPS: PU SUPER TONGS TO RIG FLOOR 15:30 16:00 0.50 CLEAN P DECOMP PU BAKER TOOLS TO THE RIG FLOOR MU 1 JOINT OF 4" DP, BUMPER SUB, SPEAR ASSEMBLY TO TOP DRIVE 16:00 16:30 0.50 CLEAN P DECOMP ENGAGE 9 -5/8" CASING PULL 5K TO CONFIRM CAMERON BACK OUT LOCK DOWN SCREWS 16:30 17:30 1.00 CLEAN P DECOMP PULL 9 -5/8" CASING TO TH RIG FLOO PULLED FREE AT 160K PULLED AT 125K AFTER FREE REMOVE SLIPS AND PACK -OFF ASSEBLY LID 1 JT 4" DP, XO, BUMPER SUB RU 4 -1/2" IF CIRC SUB & VALVE TO THE CEMENT HOSE 1 7:30 17:45 0.25 CLEAN P DECOMP PRE -JOB SAFETY MEETING 17:45 20:00 2.25 CLEAN P DECOMP CIRCULATE 200 BBLS DIESEL @ 100 DEG -2 BPM, 250 PSI SUCK BACK LINES RD LITTLE RED 20:00 22:00 2.00 CLEAN P DECOMP ISOLATE PIT #4 TO MIX 100 BBLS OF 9.8 PPG BRINE Printed 7/6/2010 10:16:12AM C per tion Summery Report Common Well Name: H -02 DIMS AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- OOTWG -C (4,984,180.00) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: H -02 @64.Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 23:30 1.50 CLEAN P DECOMP PUMP 100 BBLS OF 9.8 PPG BRINE, 30 BBLS ASFE SURF-0 PILL, 250 BBLS SEAWATER 4 BPM, 170 PSI 5 BPM, 270 PSI 6 BPM, 320 PSI 8 BPM, 460 PSI MAX PRESSURE SEEN = 680 PSI NO EVIDENCE OF ARTIC PACK SEEN AT _ SURFACE 23:30 00:00 0.50 CLEAN P DECOMP LD SPEAR & TOP JOINT TOP 9 -5/8" CASING JOINT = 24.25' CHANGE OUT ELEVATORS 6/28/2010 00:00 03:00 3.00 PULL P DECOMP LD 9 -5/8 ", 47# L -80 NSC_ C CASING FROM 1.857 I TO SURFACE ' CUT JOINT = 14.40' LONG 03:00 04:00 1.00 PULL P DECOMP CLEAR RIG FLOOR OF CASING EQUIPMENT 04:00 05:00 1.00 PULL P DECOMP PU BAKER TOOLS TO RIG FLOOR 05:00 06:00 1.00 PULL P DECOMP 9-5/8" DRESS OFF X 13 -3/8" SCRAPER _ ASSEMBLY 06:00 06:30 0.50 PULL P DECOMP CHANGE OUT 5" ELEVATORS TO 4" RIH FROM 864' TO 1,800' MD WITH 4" DP PUW- 111K; SOW- 111K' ROT- 111K 420 GPM, 420 PSI -40 RPM, 1 K TQ _ 06:30 08:00 1.50 PULL P DECOMP TAG 9 -5/8" CASING STUMP AT 1,856' MILL DOWN TO 1,857' 80 RPM, 5 -9K TQ 336GPM, 250 PSI 08:00 08:30 0.50 PULL P DECOMP CIRCULATE 30 BBLS HIGH VISCOSITY SWEEP 546 GPM, 530 PSI 08:30 09:00 0.50 PULL P DECOMP POOH FROM 1,857' TO 864' _ CHANGE OUT ELEVATO FROM 4" TO 5" 09:00 09:30 0.50 PULL P DECOMP POOH WITH BHA FROM 864' TO SURFACE STAND BACK 5" HWDP (18) _ STAND BACK 6 -1/4" DRILL C OLLARS (9) 09:30 10:00 0.50 PULL P DECOMP BREAK DOWN BAKER 9 -5/8" DRESS OFF X 13 -3/8" SCRAPER ASSEMBLY 10:00 11:00 1.00 PULL P DECOMP CLEAR RIG FLOOR OF BAKER TOOLS 11:00 16:00 5.00 BOPSUR P DECOMP NIPPLE DOWN BOP STACK REMOVE FLOW LINE, RISER, & 5' SPACER SPOOL REMOVE 9 -5/8" CASING SPOOL ND 20" 3,000 PSI WELL HEAD FLANGE 16:00 17:00 1.00 PULL P DECOMP WELD E -SLIPS TOGETHER & TO CASING IN PREPERATION TO PULL RU WACHS CUTTER AND CUT 13 -3/8" CASING HOOK UP BRIDGE CRANE TO PULL 13 -3/8" STUB & SLIPS FROM CASING HEAD _ WOULD NOT PULL FREE _ 17:00 18:00 1.00 PULL P DECOMP INSTALL MOUSE HOLE PU CEMENT HEAD, XOS (4), CENTRALIZERS (55), AND 1 JOINT OF 4" DP Printed 7/6/2010 10:16:12AM c)rt Arraf AI.AvA F�.,; P ' p� #u "mi3 pert Common Well Name: H -02 DIMS AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- OOTWG -C (4,984,180.00) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: Rig Contra DOYON DRILLING INC. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 22:00 4.00 PULL P DECOMP MU 1 JT 4" DP, XO, BUMPER SUB, 13 -3/8" CASING SPEAR ENGAGE SPEAR INTO 13 -3/8" CASING ABOVE CUT PULL 150K TO ATTEMPT TO RELEASE - NO GO HEAT CASING HEAD WITH STEAM FOR 1 HR WORK SPEAR UP AND DOWN TO 200K TO ATTEMPT TO RELEASE - NO GO SLACK OFF TO PUT BUMPER SUB IN NUETRAL PULL 200K AND RELEASE 13 -3/8" CASING SLACK OFF AND RELEASE FROM SPEAR BREAK DOWN SPEAR ON RIG FLOOR LID 13 -3/8" CASING AND SLIPS 22:00 00:00 2.00 PULL P DECOMP PU CASING RUNNING TOOLS TO RIG FLOOR i SIMOPS: CHIP CEMENT FROM WELLHEAD TO PLACE WACHS CUTTER RU WACHS CUTTER C UT THE 18 -5/8" CASING BELOW THE 20" STARTING HEAD REMOVE THE WELL HEAD FROM THE CELLAR CLEAN UP CELLAR IN PREPERATION FOR RUNNING 9 -5/8" CASING 6/29/2010 00:00 00:30 0.50 CASING P DECOMP RU TO RUN 9 -5/8" CASING 00:30 03:30 160 CASING P DECOMP MU TIEBACK CASING PATCH BAKER CASING PATCH BAKER EXTERNAL CASING PACKER HES ES CEMENTOR BAKER LOK ALL CONNECTIONS BELOW ES CEMENTER R IH WITH 9-5/8",47#, L -80, BTC -M CASING RUN 1 RIDGID SRTAIGHT BALDE CENTRALIZER PER JOINT USE BEST-0-LIFE ON ALL BTC -M THREADS 03:30 04:00 0.50 CASING P DECOMP MU 5' PUP JOINT TO TOP OF JOINT # 44 MU CROSSOVER TO TOP DRIVE PUW - 125K; SOW - 130K 04:00 05:00 1.00 CASING P DECOMP RIH TO ENGAGE BOWEN CASING PATCH 9 -5/8" CASING STUB IS AT 1,857' MD ROTATE 9 -5/8" CASING DOWN TO LOCATE (STUB SLACK OFF 80K TO SET CASING PATCH PICK UP 140K OVER CASING WEIGHT TO ENGAGE SLIPS SET CASING IN HAND SLIPS WITH 140K TENSION Printed 7/6/2010 10:16:12AM I�ti Arterica GALA° - BPs Common Well Name: H-02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- OOTWG -C (4,984,180.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: Rig Co ntr ac t o r: DOYON DRILLIN IN UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 06:00 1.00 CASING P DECOMP BREAK OFF CROSSOVER FROM TOP DRIVE INSTALL LONG BALES MU HES CEMENT HEAD AND LINES RIG UP TO PUMP PRESSURE UP TO 450 PSI VALVE ON CEMENT HEAD LEAKING 06:00 06:30 0.50 CASING N CEMT DECOMP . LD BAD CEMENT HEAD 06:30 07:30 1.00 CASING N CEMT DECOMP j RU NEW CEMENT HEAD 07:30 08:00 0.50 CASING P DECOMP RESSURE UP TO 1,000 PSI FOR 10 MIN GOOD TEST INCREASE`: PRESSURE TO 1,400 PSI AND OPEN ECP HOLD FOR 10 MIN P RESSURE LEVELED OUT AT 1,000 PSI 08:00 08:30 0.50 CASING P DECOMP INCREASE PRESSURE TO 1,900 PSI TO CLOSE I ECP PRESSURE BLEEDING OFF. ES CEMENTER PARTIALLY OPENED INCREASE PRESSURE, PUMPING AT 2 BPM, TO FULLY OPEN ES CEMENTER OPENED AT 2,500 PSI ESTABLISH CIRCULATION AND ZERO STROKE COUNTERS 08:30 09:30 1.00 CASING P DECOMP CIRCULATE 250 BBLS OF 150 DEG SEAWATER TILL RETURNS REACH 87 DEG Printed 7/6/2010 10:16:12AM N6tth,P�ertriea; RLAKA? " Page98 Operation Summary Report Common Well Name: H -02 DIMS AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- OOTWG -C (4,984,180.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: R ig Contractor: DO D RILLING IN C. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) _ 09:30 11:00 1.50 CASING P DECOMP CE ENT 9 -5/8" CASING WITHOUT RECIPROCATION AS FOLLOWS: 09:45 PUMP 5 BBL OF WATER 09:50 TEST LINES TO 4,000 PSI - GOOD 09:52 START MIXING 15.8 PPG CEMENT 10 :10 PUMP 129 BBL 15.8 PPG TAIL CEMENT AWAY AT 5 BPM 15.8 PPG CLASS G 10:36 STOP PUMPING CEMENT 10:38 DROP ES CEMENTOR CLOSING PLUG 10:39 SCHLUMBERGER WASH UP 5 BBL ON TOP OF PLUG 10:40 DISPLACE WITH RIG PUMPS - DISPLACE WITH SEAWATER 10:50 CATCH UP TO CEMENT 8 BPM, 300 PSI, 740 STROKES INTO DISPLACEMENT 10:55 SLOW PUMP RATE TO 2 BPM AT 1,100 STROKES. ANTICIPATED PLUG BUMP AT 1,257 STROKES PLUG BUMP AT 1,274 STROKES 11:01 SHUT DOWN DISPLACEMENT AT 1,276 STROKES (128.9 BBL DISPLACED) 620 PSI FINAL PRESSURE AT 2 BPM BEFORE SHUTTING DOWN BLEED OFF PRESSURE AND CHECK FOR FLOW NO FLOW OBSERVED FULL RETURNS THROUGHOUT JOB. CEMENT CONTAMINATED BRINE TO CELLAR. NO GOOD CEMENT RETURNS TO CELLAR -- CEMENT IN PLACE AT 11:01 CM� ACTUAL CEMENT JOB VOLUME: 104.6 BBLS 15.8 PPG CLASS G TAIL; 502 SACKS AT 1.17 CUFT /SK RECIRCULATING VALVE LEFT OPEN IN CEMENT PUMPTRUCK - MICROMOTION SAW 129 BBLS FLUID, 104.6 BBLS WENT DOWNHOLE 11:00 14:30 3.50 CASING P DECOMP WAIT ON CEMENT POSITION 9 -5/8" CASING TO CENTER IN ROTARY TABLE WHILE WAITING ON CEMENT: WAITING ON ORDERS FROM ANCHORAGE OPERATIONS /ENGINEERING FOR UPCOMING TOP JOB LOAD PIPE SHED WITH 7" CASING TO DRIFT AND STRAP i OFFLOAD FLUID FROM PITS AND CLEAN SAME Printed 7/6/2010 10:16:12AM irt1 Ame b , _ ALA Page`�t Operation °Summary Keport Common Well Name: H- 02_DIMS AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- OOTWG -C (4,984,180.00) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: Rig Contracto D DRILLING I NC. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 14:30 16:30 ( 2.00 CASING N CEMT DECOMP HOLD PJSM WITH CREW FOR TOP JOB PUMP 15.8 PPG CEMENT INTO 9 -5/8" X 1 -3/8" . ANNULUS - PUMP 1 BBL OF CEMENT AND WAIT FOR CEMENT TO SWAP OUT WITH SEAWATER - REMOVE DISPLACED SEAWATER WITH SUPERSUCKER REPEAT PROCESS UNTIL 8 BBLS CEMENT PUMPED - CEMENT NOW COVERING 9 -5/8" X 13 -3/8 ", 13 -3/8" X 18 -5/8 ", 18 -5/8" X 30" AND 9 -5/8" X 30" ANNULI. WASH UP INTO CELLAR CLEAN OUT CELLAR AND PREP FOR WELDING CENTERING BRACKET 16:30 00:00 7.50 CASING P DECOMP WAIT ON CEMENT CENTER UP 9 -5/8" CASING IN WELL DRIFT AND STRAP 7" CASING LOAD AND STRAP 4" DRILLPIPE 6/30/2010 00:00 01:00 1.00 CASING P DECOMP SLACK OFF ON 9 -5/8" CASING TO BLOCK WEIGHT - CASING MOVED 318" AT CUT POINT REMOVE CEMENT HEAD, CROSSOVER, AND DRAIN CASING TO CELLAR FLOOR 01:00 - 01:30 0.50 CASING P DECOMP RIG UP WACHS CUTTER AND CUT 9 -5/8" CASING AT CELLAR HEIGHT CUT MEASURED TO MINIMIZE S -RISER MODIFICATION BACK OUT PUP JOINT AND LAY DOWN LAY DOWN CUT JOINT CUT JOINT LENGTH: 34.05' 01:30 02:00 0.50 CASING P DECOMP REMOVE 9 -5 /8" CASING HANDLING EQUIPMENT FROM RIG FLOOR DRESS 9 -5/8" CASING STUB FOR SLIPLOCK WELLHEAD 02:00 05:00 3.00 WHSUR P DECOMP MOBILIZE SLIPLOCK WELLHEAD TO CELLAR INSTALL SLIPLOCK WELLHEAD ON 9 -5/8" CASING STUB LINE UP WELLHEAD TO FLOWLINE TIGHTEN BOLTS TO ENERGIZE SECONDARY SEAL 05:00 06:00 1.00 WHSUR P DECOMP RIG UP AND TEST SECONDARY SEAL ON j SLIPLOCK WELLHEAD TO 3,800 PSI FOR 30 MINUTES - 80% COLLAPSE PRESSURE FOR 9 -5/8" 47# L -80 CASING RI DOWN TEST EQUIPMENT 06:00 11:00 5.00 BOPSUR P DECOMP NIPPLE UP BOP ADAPTER FLANGE NIPPLE UP BOP STACK INSTALL STACK EXTENION ON CHOKE LINE INSTALL RISER EXTENTION NO CASING MOVEMENT WITH ADDED WEIGHT OF B _ Printed 7/6/2010 10:16:12AM Ncs�#f1 AettTi }4UK Opera #i ©n Summa epo Common Well Name: H-02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6123/2010 End Date: X3- OOTWG -C (4,984,180.00 ) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: Rig Contractor: D OYON DRILLING INC. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 13:30 2.50 BOPSUR P DECOMP INTALL TEST PLUG TEST WELLHEAD BREAKS, CASING SPOOL ANNULUS VALVE, AND CHOKE LINE TO 250 PSI LOW, 3,500 PSI HIGH 5 MINUTE, CHARTED TES _ 13:30 14:00 0.50 WHSUR P DECOMP INSTALL WEAR BUSHING OBTAIN RAM MEAS UREMENTS FROM RKB 14:00 14:30 0.50 WHSUR P DECOMP INSPECT AND SERVICE TOP DRIVE, BLOCKS, AND DRAWORKS 14:30 1530 1.00 CASING P DECOMP PICK UP AND MAKE UP CLEANO BHA PER BAKER FISHING REP AS FOLLOWS: 8 -1/2" USED TRICONE BIT 2X BOOT BASKETS BIT SUB FLOAT SUB LUBRICATED BUMPER SUB. OIL JAR PUMP -OUT SUB (2- 3/16" OD DART TO OPEN) 4 -1/2" IF PIN X 4 -1/2" H -90 BOX CROSSOVER 9X DRILL COLLARS 4 -1/2" H -90 PIN X 4 -1/2" IF BOX CROSSOVER - 4 -1/2" IF PIN X 4" HT -38 BOX CROSSOVER TOTAL BHA LENGTH 321.0' 15:30 18:00 2.50 CASING P DECOMP RIH ON DRILLPIPE SINGLES FROM 321' TO 1,771' MD PICKING UP SINGLES FOR DRILLPIPE MANAGEMENT BEGA TAKING WEIGHT AT 1,771' 18:00 20:30 2.50 CASING P DECOMP WASH DOWN FROM 1,771' TO 1,803' DRILL OUT CLOSING PLUG AND ES CEMENTER FROM 1,803' TO 1,807' MD PUW 92K, SOW 95K 400 GPM, 380 PSI 80 RPM, TQ ON 2K, OFF OK - 5 -10K WOB WASH DOWN FROM 1,807' TO 1,871' MD USING SAME PARAMETERS CEMENT STRINGERS ENCOUNTERED _ 20:30 21:30 1.00 CASING P DECOMP RIH ON DRILLPIPE SINGLES FROM 1,871' TO 2,679' MD CONTIN DRILLPIPE MANAGEMENT 21:30 22:30 1.00 CASING P DECOMP WASH D OWN_FR�� -��Q' oN� TAG E ZSV AT 2.701' MD 252 GPM, 310 PSI SET 25K DOWN WEIGHT ON INITIAL TAG PICK UP AND SET 1 O TO CONFIRM DEPTH PICK UP ABOVE EZSV AND CIRCULATE BOTTOMS UP ROTATE AND RECIPROCATE PIPE 400 GPM, 260 PSI Printed 7/6/2010 10:16:12AM I c it# _Amen _.ALAS _ F? Pag ,12 Aperation Summary Report Common Well Name: H-02 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- OOTWG -C (4,984,180.00) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: Rig C DO Y O N DRILLING I NC. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 22:30 00:00 1.50 CASING P DECOMP LID 1 JOINT 4" DRILLPIPE FLOW CHECK WELL NO FLOW BLOW DOWN TOP DRIVE POOH FROM 2,690' TO 321' RACK BACK 3 STANDS DRILL COLLA 7/1/2010 00:00 01:00 1.00 CASING P DECOMP LAY DOWN OIL JAR EMPTY 7" BOOT BASKETS - SMALL RUBBER PIECES FROM ES CEMENTER CLOSING PLUG AS WELL AS SMALL METAL FRAGMENTS AND SHAVINGS FROM ES CEMENTER OPENING AND CLOS SLEEVES 01:00 02:00 1.00 CLEAN i P WEXIT MAKE UP DRIFT BHA PER BAKER REP AS FOLLOWS: 8 -1/2" USED TRICONE BIT 2X BOOT BASKETS BIT SUB FLOAT SUB 8 -1/2" STRING MILL 8 -1/2" STRING MILL LUBRICATED BUMPER SUB 4 -1/2" IF PIN X 4 -1/2" H -90 BOX CROSSOVER 9X DRILL COLLARS 4 -1/2" H -90 PIN X 4 -1/2" IF BOX CROSSOVER 4 -1/2" IF PIN X 4" HT -38 BOX CROSSOVER TOTAL BHA LENGTH 320.2' RUNNING BHA DUE TO CEMENT STRINGERS ENCOUNTERED BELOW CASING STUB - CONFIRM WHIPSTOCK ASSEMBLY CAN REACH DESIRED DEPTH 02:00 03:30 1.50 CLEAN P WEXIT SLIP AND CUT DRILLING LINE 03:30 05:30 2.00 CLEAN P WEXIT RIH ON 4" DRILLPIPE SINGLES FROM 320' TO 27 02'. TAG EZSV PLUG. _ 05:30 06:00 0.50 CLEAN P WEXIT CIRCULATE BOTTOMS UP AT 10 BPM WITH 660 PSI. ROTATE AT 40RPM AND RECIPROCATE PIPE WHILE CI RCULATING 06:00 07:00 1.00 CLEAN P WEXIT POH TO 320' FLOW CHECK AND BLOW DOWN TOP DRIVE PRIOR TO TRIP. BRINE WEIGHT IN AND OUT: 9.4 PPG 07:00 08:00 1.00 CLEAN P WEXIT CHANGE ELEVATORS FROM 4" TO 5" TO HANDLE BHA. STAND BACK DRILL COLLARS, LAY DOWN BOOT BASKETS, JARS A MILLS. 08:00 09:00 1.00 WHIP P WEXIT CLEAR RIG FLOOR OF CLEAN OUT BHA. PICK UP BAKER MILLS AND CROSS OVERS FOR WHIPST RUN 09:00 10:00 1.00 EVAL P WEXIT RIG UP LINES TO PRESSURE TEST. TEST 9 5/8" CASING TO EZSV AT 2702' WITH 2,500 PSI FOR 30 MINUTES. BLOW DOWN LINES. RIG DOWN TEST LINES. Printed 7/6/2010 10:16:12AM °North Am�riia "= ALASKA -„ _ Page, t3 0pperatlon S u mmary Report Common Well Name: H -02 DIMS AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/23/2010 End Date: X3- OOTWG -C (4,984,180.00) Project: Prudhoe Bay Site: PB H Pad Rig Name /No.: DOYON 14 Spud Date/Time: 6/23/1971 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: H -02 @64.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 12:30 2.50 WHIP P WEXIT PJSM WITH RIG CREW, BAKER HAND, GYRO DATA HANDS AND DD ON PICKING UP WHIPSTOCK BHA. PICK UP 161' OF 4 1/2" TUBING TAIL PIPE SPACER PICKUP WHIPSTOCK AND MILLING BHA ATTACH MILLING BHA TO WHIPSTOCK SLIDE WITH 35K SHEAR PIN RUN 9 EACH 6 1/4" DRILL COLLARS RUN 18. EACH 5" HWDP RIH T 1084' _ 12:30 13:30 1.00 WHIP P WEXIT RIH WHIPSTOCK AND MILLS ON 4" DRILL PIPE TO 2198'. TAKING WEIGHT, 5K TO 12K. STOP, PICK UP 20'. TURN STRING 90 DEG TO THE RIGHT. RIH WITH NO PROBLEMS TO 2220' 13:30 14:30 1.00 WHIP P WEXIT RIG UP GYRO DATA AND SPERRY SUN WIRE LINE UNIT. 14:30 15:00 0.50 WHIP P WEXIT RIH WHIPSTOCK AND MILLS ON 4" DRILL PIPE TO 2692' 15:00 16:30 1.50 WHIP P WEXIT RUN GYRO DATA TO 2,438' MD PERFORM 3 CHECKSHOT RUNS TO ORIENT _ WHIPSTOCK TO 270 DEG 16:30 17:00 0.50 WHIP P WEXIT MAKE UP 1 STAND OF DRILLPIPE RIG DOWN GYRO EQUIPMENT RIH AND TAG ON EZSV AT 2,701' MD SET DOWN 20K TO SET WHIPSTOCK ANCHOR - PICK UP 10K OVER STRING WEIGHT TO CONFIRM ANCHOR IS SET SET DOWN AND SHEAR MILL OFF OF W HIPSTOCK_ 17:00 18:00 1.00 STWHIP P WEXIT PUMP HIGH -VIS SWEEP DISPLACE WELL FOLLOWING SWEEP WITH 9.4 PPG LSND DRILLING M 18:0 - -0 0 0 0 6.00 STCTPL P WEXIT OBTAIN SLOW PUMP RATES '07..B MILL WINDOW PLUS 20' TO 2,548' MD PUW 117K, SOW 120K, ROT 120K 336 GPM, 400 PSI 80 RPM, 0 -10K TO TOP OF WINDOW: 2,511', BOTTOM OF WINDOW: 2,528' 1 WORK MILLS THROUGH WINDOW MULTIPLE TIMES - ABLE TO WORK THROUGH WITH PUMPS OFF AND WITHOUT ROTATION 7/2/2010 00:00 01:00 1.00 STWHIP P WEXIT PUMP SWEEP SURFACE -TO- SURFACE. RECOVERED 265 LBS METAL SHAVINGS 01:00 02:00 1.00 STWHIP P WEXIT RIG UP AND PERFOM LOT j - PUMPED TOTAL OF 12 STROKES ACHIEVED LEAKOFF AT 500 PSI 13.2 PPG EM Printed 7/6/2010 10:16:12AM TREE _ CIW SAFETY N COMPOSITE WRAP REPAIR SH LEAK -DO WELLHEAD = Cw �0 NOT PUMPO OR METH BLEND INTO OA DUE TO CHEM ACTUATOR = BAKER C INCOMPATIBILITY W /EPDXY RESIN IN WRAP * ** 4 -1/2" KB. ELEV = 64 DR LG DRAFT CHROME TBG & LNR * ** ORIG & "A" WELLBORE NOT SHOWN BF. ELEV = 44.83' KOP = 5700' 30" CONDUCTOR 100' 1804' —F9 CEMENTER Max Angle =53° @ 10159' Datum MD = 10081' 1825 9 -5/8" BKR ISO -ZONE EXT CSG PKR, ID = 8.75" Datum TV D = 8800' SS 2194' 4 -1/2" HES X NIP, ID = 3.813" 9 -5/8" CSG, 47 #, L -80 BTC, ID = 8.681" 1856' 9 -5/8" BKR (BOWEN) CSG PATCH, ID = 9.85" 1860' 2221' 13 -378" Dv 13-3/8" CSG, 68 #, K -55, ID = 12.415" 1 2271' 2271 —F13- 3/8" X 9 -5/8" TM/ TIEBACK PKR 9 -5/8" CSG, 47 #, N -80 NSCC, ID = 8.681" 2271' 2271' 13 -3/8" X 9 -5/8" XO, ID = 8.681" 18 -5/8" CSG, 96.5 #, K -55 BTRS, 2308' ID = 17.655" 9 -5/8" WHIPSTOCK (06/27/10) 511' 9- 5/8 WINDOW (H-0213) 2511' - 2528' 9 -5/8" EZSV (06/26/10) 2702' GAS LIFT MANDRELS ST MD TVD !35 JKBG-2 VLV LATCH PORT DATE 4 3545 3505 DOME BK 16 07/23/10 Minimum ID = @ 3 6056 5605 SO BK 20 07/23/10 4 -1/2" HES XN NIPPLE 2 7994 7193 DMY BK – 05/08/10 1 9475 8404 DMY BK 0 04/27/04 9510 4 -1 /2" HES X NIP, ID = 3.813" PERFORATION SUMMARY REF LOG: 9545' 7" X 4 -1/2" HES TNT PKR, ID = 3.856" ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE --- 4-1/2" HES X NIP, ID = 3.813" 9647' 44 -172" HES XN NIP, I D = 3. 9653 7" X 5" BKR HRD LTP 4-1/2" TBG, 12.6 #, 13CR -85 9658 w / 11' TIEBACK, ID = 4.40" I VA M TOP, .0152 bpf, ID = 3.958" 9660' 4 -1/2" WLEG, ID = 3.958" 7" LNR, 26 #, L -80 VA TOP HC 9730' XO TO L -80 BTGM 14 ELMD TT NOT LOG 9680' 5" X 4 -1/2" XO, ID = 3.930" 7" LNR, 26 #, L -80 BTGM, .0383 bpf, ID = 6.276" 9815' 4 -1/2" LNR, 12.6 #, 13CR -85, 10230' 10141' PBTD VAM TOP, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/28/75 ORIGINAL COM PLEHON WELL: H-02B 08/13/86 N1 ES RWO PERMIT No: ° 2011460 12/30102 N2ES SIDETRACK (H -02A) API No: 50- 029 - 20100 -02 07/18/05 D -14 SIDETRACK (H -02B) SEC 21, T11 N, R13E, 1073' FNL & 1265' FEL 07/25/101 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) 07/08/10 Scblum6erger Alaska Data & Consulting Services 2525 Gambell Street, Suke 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # l Log Description Date BL ~. u N0.5557 Company: State o1 Alaska Alaska Oil 6 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Color CD 04-45 L-203 P-28 AYKP-00086 B3S0-00065 AY1 M-00047 JEWELRY LOG/PERF RECORD '° USIT USIT ~ 06125/10 05/02/10 06/D8/10 1 1 1 1 1 1 P-28 N-OtA 8-Ot BB6M-00018 AYKP-00092 BCRD-00031 SONIC CBL PRODUCTION PROFILE LEAK DETECTION LOG a 06/14/10 07/05/10 07/02/10 1 1 1 1 1 1 N-16 W-21 A H-02A B-138 H-23A B-21 BCRD-00032 BAUJ-00034 AYKP-00088 AYKP-00091 B5JN-00048 63S0-00062 PRODUCTION PROFILE MEMORY PROD PROFILE USIT SCMT RST RST D7/04/10 07/03/10 06/26/10 07/02/10 04/16/10 04/28/10 1 1 1 1 1 1 1 1 1 1 1 1 \ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ~.r .,, ,(~ J1._ 2011 ~, ~~ `~ F~-l: Prudhoe Bay - H-02A Sundry Modification Request Maunder, Thomas E (DOA) From: Rixse, Mel G [Mel.Rixse@bp.com] Sent: Tuesday, June 22, 2010 3:19 PM To: Maunder, Thomas E (DOA) Cc: Egbejimba, Uchenna J; Ai<, D&C Rig 14 Well Site Leader Subject: RE: Prudhoe Bay - H-02A Sundry Modification Request Tom, Thank you for getting back to me on these issues. Mel Rixse Drilling Engineer BP Exploration Alaska, lnc. email: mei.rixse@bp.com Text Message 9072233605@txt.att.net (907)564-5620 -Office (907)223-3605 - Celi cc. John Egbejimba, Doyon 14 WSL From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, June 22, 2010 2:57 PM To: Rixse, Met G Subject: RE: Prudhoe Bay - H-02A Sundry Modification Request Page 1 of 3 As you point out, not setting the RBP is dependant on getting a good pressure test. If that is successful, any internal path to the reservoir will be isolated by two independent plugs. With both of those plugs verified, it would appear that the AOGCC plugging requirements are met for the deeper section of H-02A. The need for a debris barrier is BP's option. Tom Maunder, PE AOGCC From: Rixse, Mel G [mailto:Mel.Rixse@bp.com] Sent: Tuesday, June 22, 2010 2:41 PM To: Maunder, Thomas E (DOA) Subject: RE: Prudhoe Bay - H-02A Sundry Modification Request Tom, Thanks for getting back to me. In response to your questions I have the following: 2. A. If we get a good pressure test and don't run the RBP, we will let the debris fall to the top of the EZSV, which should be well below the whipstock setting depth. 2. B. There is concern that debris would be a problem on top of the RBP. We would dump sand on top of the RBP if we run it, just as you suggest. I apologize for not stating that in the procedure. 3. I will not have a BOP or a riser installed when we are running the 9-518" casing. I have a 'rhino' lined cellar and will have 2 vac trucks on line to the cellar when we run the 9-5/8" tie-back. 4. I do have the PTD. I hope this answers your questions. Mel Rixse 6/22/2010 FVY: Prudhoe Bay - H-02A Sundry Modification Request Drilling Engineer BP Exploration Alaska, Inc. email: mel.rixse@bp.com Text Message 9072233605@txt.att.net (907)564-5620 -Office (907)223-3605 -Cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, June 22, 2010 2:15 PM To: Rixse, Mel G Subject: RE: Prudhoe Bay - H-02A Sundry Modification Request Page 2 of 3 Hi Mel, I have looked at your request. 1. Reducing the test pressure to 2500 psi is acceptable. 2. Is there any concern that debris from the cut and all the other work you will do could cause problems when you run the whipstock? I don't see it stated to put sand on top of the RBP. 3. If I read the procedure correctly, you won't have a BOP installed when you run the replacement 9-5/8" casing. Do you already have the PTD? I look forward to your reply, Tom Maunder, PE AOGCC From: Rixse, Mel G [mailto:Mel.Rixse@bp.com] Sent: Tuesday, June 22, 2010 1:47 PM To: Maunder, Thomas E (DOA) Subject: FW: Prudhoe Bay - H-02A Sundry Modification Request Tom, I sent this to Guy Schwartz. It looks like you are covering for him. I hope you can review this so we can discuss. Doyon 14 will be moving to this well later today. Thanks. Mel Rixse Drilling Engineer BP Exploration Alaska, Inc. email: mel.rixse@bp.com Text Message 9072233605@txt.att.net (907)564-5620 -Office (907)223-3605 -Cell From: Rixse, Mel G Sent: Tuesday, June 22, 2010 1:39 PM To: 'Schwartz, Guy L (DOA)' Subject: Prudhoe Bay - H-02A Sundry Modification Request Guy: I would like to request a revision to Sundry Number 310-122 for work related to the Prudhoe Bay Unit 6/22/2010 FVu: Prudhoe Bay - H-02A Sundry Modification Request Page 3 of 3 well H-02A with Rig Doyon 14. I have 3 changes to the sundry request I would like you to consider. They are the following: 1. I would like to limit the test of the existing IA (the 4-1/2" x 9-5/8") to 2500 psi rather than going to 2700 psi. 2. I would like to have the oUtion to forego the setting of the RBP on step number 13 if we get a passing MIT-IA to 2500 psi (in step #1 above). and 3. I would like to forego testing the BOPE 9-5/8" casing rams at step number 18. The reason for request number 1: H-02A has an exposed 13-3/8" x 9-5/8" K-55 68# crossover rated to a burst pressure of 3450 psi. That crossover was installed in 1971 so I would like to limit the stress on this older equipment to 2500 psi. The reason for request number 2: H-02A now has a pressure tested cement abandonment plug across the perforations. After the existing tubing is pulled, a second tested barrier, an EZSV, will be set at approximately 2700' MD. The RBP will be a redundant 3rd barrier. The reason for request number 3: H-02A will already have two downhole barriers. Testing 9-5/8" pipe rams adds risk to the operation because of the significant loads placed upon the test joint and the risk of ejecting the test joint if the rams would fail. I will call you to discuss. Sincerely, Mel Rixse Drilling Engineer BP Exploration Alaska, Inc. email: mel.rixse@bp.com Text Message 9072233605@txt. att. net (907)564-5620 -Office (907)223-3605 -Cell 6/22/2010 • • Greg Hobbs Engineering Team Leader BP Exploration (Alaska), Inc. ~ ~~~~ O ~,~ P.O. Box 196612 ,~, 6r~,~,~t Yy~,'= °' ~p ~ '"~ ~ a, Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-02A Sundry Number: 310-122 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. c~~ Chair DATED this! day of April, 2010. Encl. • Schwartz, Guy L (DOA) From: NSU, ADW Well Integrity Engineer [PISUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, April 16, 2010 12:45 PM To: Schwartz, Guy L (DOA) Cc: Rixse, Mel G; NSU, ADW Well Integrity Engineer Subject: RE: DS H-026 Sidetrack question (PTD 210-046) Attachments: H-02A.pdf; H-02 (PTD #2021600) T-I-O Plot.doc Guy, Page 1 of 3 Enclosed is the TIO plot for H-02 (PTD 2021600) for the last 4 years per your request. I am enclosing a current wellbore schematic for reference. Gerald Murphy (for Anna Dube) Well Integrity Coordinator GPB Phone: (907) 659-5102 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, April 16, 2010 9:05 AM To: NSU, ADW Well Integrity Engineer Cc: Rixse, Mel G Subject: FW: DS H-02B Sidetrack question (PTD 210-046) Anna/Mel, I agree the OOA in this well is manageable... Could I see a TIO plot for the well ??? Just curious about the bleed rate for the OA . (Did the IC packoff change out in 2006 slow the OA buildup?) I think the new casing (9 5/8" ) will take care of this issue but want to understand a bit more before 1 send the sundry through. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Rixse, Mel G [mailto:Mel.Rixse@bp.com] Sent: Thursday, April 15, 2010 5:17 PM To: Schwartz, Guy L (DOA) Subject: RE: DS H-02B Sidetrack question (PTD 210-046) Guy, Regarding H-02B Wellhead and Surface Casing Work: In answer to your questions: 1) Why the new wellhead ? To replace an old wellhead and remove the exposure of IA pressures to very old K-55 grade intermediate casing. 4/16/2010 . ~ Page 2 of 3 Discussion of Scope: The surface hole of H-02 was drilled in 1971. A string of 18-5/8" K-55 surface casing was set and cemented. The intermediate casing string was a tapered string of 13-3/8" K-55 (to 2271'MD) crossed over to 9- 5/8" N-80 to 8300' MD. The intermediate casing was cemented in 3 stages with the final stage providing 30 bbls returned to surface. In 1986 a 9-5/8" tie-back string was run from 2271' to surface and cemented with 25 bbls (200') at the shoe. BP would like to remove the existing wellhead and replace it with a new "slip-lock" well head supported on a robust string of 9-5/8" casing. The cemented 13-3/8" X 18-5/8" annulus (OOA) will be opened to the atmosphere. R new 9-518" casing string will be run and will be fully cemented from 1853'MD to surface and will provide a durable support for the new slip-lock wellhead. The 'old' existing OA (external to the 9-5/8" tie-back) will also be exposed to the atmosphere, but it will be fully cemented when the new 9-5/8" tieback is run. After drilling the intermediate hole section, the new 7" x 9-5/8" annulus will become the monitorable OA. 2) Wha# is the condition of the current 13 3!8" x 18 5/8" annulus ? The 13-3/8" x 18-5/8" annulus is fully cemented. It does not pass an MIT. The OOA does build pressures of 400-500 psi, if left shut-in. If opened, even when the well is POP, the measureable gas near the wellhead and within the well house is insignificant and almost immeasurable. The MIT-OA passes to 2400 psi. There should be no communication from the OA to the OOA. 3) Why are you pulling the existing 9 5!8" ? The existing 9-5/8" tie-back casing is being cut, pulled, and replaced to provide mechanical support for the new slip-lock wellhead. The new slip-lock wellhead requires more length of 9-5/8" casing above the existing cellar, then is currently available from the existing 9-5/8" casing. I hope this provides an overview of the scope of the wellhead work we propose for H-02. Sincerely, Mel Rixse ODE From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, April 15, 2010 3:13 PM To: Rixse, Mel G Subject: DS H-02B Sidetrack question (PTD 210-046) Mel, Gould you elaborate on the well-plan for H-026 concerning the surface casing work per our phone conversation...... 1) Why the new wellhead ? 2) What is the condition of the current 13 3/8" x 18 5/8" annulus ? 3) Why are you pulling the existing 9 5/8" ? 4) Any other details to help understand the wellwork up to starting the sidetrack. Thanks a lot, Guy Schwartz Senior Petroleum Engineer AOGCC 4/16/2010 • Page 3 of 3 ' 793-1226 (office} 444-3433 (cell) 4/16/2010 u H-02 (PTD #2021600) T/I/O Plot Well: H-02 4.000 3,000 "[,000 1,000 • -~- T6g ~- IA -~ OA DOA --s- DOOA On 08!07106 12l09/D6 04/12/07 D8114/07 12/18/07 04/18/DB 08r20/08 12/22/08 04/25/09 08/27/09 12129:09 STATE OF ALASKA ', ~; ~~ ~ '~ ALAS~IL AND GAS CONSERVATION COMMI~N ~\a' 4~~a APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 RECEI!/E~ nPR 1 s 20~0~ iy~O 1. Type of Request: ~,~$ f1118SI0f1 ^ Abandon ®Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved ~~ ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 202-160' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20100-01-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU H-02A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): , ADL 028284 - Prudhoe Bay Field / rudhoe Bay Oil Pool 11. PRE8ENT WELL CONDITION SUMMARY Total Depth MD (ft); Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12950' - 8863'- 12862' 8867 None None Casin Len Size MD TVD Burst Colla e Structural Conductor 1 1 1 Surface 230 ' 18-5/8" 2 2306' 93 87 Intermediate 55 9' 1 -3/8" x 9-5/8" 4 0 227 Production Liner 881' 7" 980' - 10 61' 980' - 7 7' 7240 541 Liner 22 4-1/ " 1 710' - 12949' 8 49' - 8863' 84 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12180' - 12850' 8857' - 8867' 4-1/2", 12.6# 13Cr80 10718' Packers and SSSV Type: 7" x 4-1 /2" Baker Premier packer Packers and SSSV 10648' / 8618' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ' ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 22, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ^ WAG~w~ Plugged ^ SPLUG ' Commission Representative: ~ C/~~ ~/ ~•" 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mel Rixse 564-5620 Printed Name Gre He b Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-4191 Date Terrie Hubble, 564-4628 Commission Use Onl Conditions of approv I: Notify Commission so that a representative may witness '?~ ~ ~ _ Sund Number: [ ry J o ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ location Clearance * 3Soa ~ sz Qo P ~S f Other: ~e~~. c.P f~s~'+ v ~ LP/es 4Ppro~~.P 2 c ~gi4c Z5. ZSS ('~) . Subsequent Form Required: / D , Y APPROVED BY q f Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 Revis` e3~{~OQ9_ _c APR ~ ~ ~O~O Submit In Duplicate g~v7 ~RI~~~AL ~-y,s'~ • by • ~ ~~ To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mel Rixse Operations Drilling Engineer Date: April 12, 2010 Re: H-02A Abandonment, and new Sidetrack Sundry Approval Request Sundry approval is requested for H-02A. Abandonment of the existing A-leg is proposed, followed by a sidetrack to a new bottom hole location. The isolation of the existing wellbore from the top most hydrocarbon producing zone, the ~ River, is demonstrated from the existing intermediate liner cementing records. Isolation from the existing perforations and cement isolation above the existing packer will be executed by shooting holes in the existing production tubing then laying in cement in the existing production tubing. WELL HISTORY/CURRENT STATUS: Well Construction: A rig workover was performed in 1986 to replace 7" tubing with 5.5", and run a 9 5/8" tie back string to surface. The 9 5/8" tieback was cemented with 25 bbl cement. H-02 was gas lifted between 1986 and 1991. In 2002 H-02A was rotary sidetracked as a horizontal designed to access at-risk oil remaining between two injectors in the southern portion of H-pad. Drilling experienced problems running the first liner to TD, which resulted in a liner cut & pull. A cement plug was set, and a second sidetrack was kicked off at 5630'. After the sidetrack hole was drilled into the Sag River to 10861' MD, a 7" liner was set and cemented. This second liner . was also troublesome to get to bottom, but eventually pushed down. Part of the trouble is thought to be the high angle of the wellbore through the Kingak, which averaged 59 degrees. Drilling operations of H-02A were suspended after the casing was set and cemented so that the rig could move to operations onto the annular communication incident at A-22. 15 weeks later the rig resumed operations on H- 02A. Drilling experienced total fluid losses in the production hole at 11,969'MD. LCM was spotted with little success of reducing the losses. The decision was made to drill ahead which succeeded in reducing the losses to 9 bbls/hr. Drilling crossed a second fracture zone at 12,390'MD again with total losses. The geologists feel that the losses at 12,390' were actually a second breakdown of the fracture at 11,969'MD. Heavy LCM stopped the losses, but the tool face had difficulty maintaining inclination in the final build. Drilling completed the well to TD without incident; nothing was noted about losses during the cement job. H-02A was perforated with 520' of Zone 4B perforations both above and below the fracture zones. Seven ' months later the well was shut in with a report of bubbling in the cellar that was repaired with Sealtite in outer casing packoffs in January the following year. Production time was intermittent due to the very high water cut and low oil production. A borax log in 2005 confirmed channelling from 12,700'MD (middle lower perfs) to well above top perforations at 12,180'MD. Due to the volume of fluid pumped to control the drilling LC event, a squeeze of the channel was deemed not likely to succeed (corroborated in 6/2009 peer review). In Sept 2007, the well was reported to have a building OOA pressure and the well was SI with a starting head leak in Feb 2008. Anncomm: H-02A was completed with 13-Cr tubing during the 2002 rig sidetrack. The well has a known slow IAxOA leak (manageable by bleeds). The SH leak was repaired with Furmanite in April 2009 and continues to fail MIT-OOA to 1000psi. H-02A has "Operable" status, but is leaking into the cellar. REASON FOR SIDETRACK: H-02A is currently SI with high water cut and zero on-time. H-02A's location is high value, but the damaged completion has no repair options. The sidetrack into the fault shadow will allow for high angle slant hole penetration of the NLOC, retain wire-line capability and allow for recovery of the block. Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the provisions of 20 AAC 25.285 (f) (1) D~ regarding the initial testing of the BOPE as follows when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams will be tested at the earliest opportunity during • path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. -f ~~ TtirS ~XiS n`-7y ~°'wlJ~c~ ~~~lr Pre-Riq Operations: ~~~°-' 7 / ~~~/® 1. F MIT-OOA - 1560 psi (80% collapse pressure 13-3/8" K-55) 2. F MIT-OA - 2700 psi (80% burst pressure 13-3/8" K-55) - 3. F CMIT-T x IA 2700 psi 4. O Function test LDS tubing, replace if damaged. Function test LDS-IC, replace if damaged. 5. S Drift tubing and liner with 3.5" drift to 3000'MD 6. O Test for infectivity. 7. E Punch holes in 4-1/2" production tubing at ~10,700'MD (just above 4-1/2" Liner top packer) and ~10,655'MD just below 4-1/2" production tubing packer (10,648'MD) 8. O Full bore cement squeeze 15.8 ppg cement abandonment plug. Leave TOC ~9648'MD. 9. S Drift to TOC and to 3000' MD for jet cutter. 10. F MIT-T 3500 psi, MIT- IA 2700 psi 11.E Jet cut the 4-1/2" tubing in the middle of a full joint at 2800' MD. 12. V Bleed all casing and annulus pressures to zero psi. Open OOA. Monitor LEL in wellhouse. 13. O Rebuild cellar with impermeable liner. 14. V Set BPV 15. V PT tree (MV,SV,WV) 16. O Bleed gas lift and production flowlines down to zero and blind flange 17. O Remove S-Riser, Remove wellhouse, level pad -Complete Riq Operations: 1. MIRU Nabors rig Doyon 14. 2. Pull BPV. Circulate out freeze protection with seawater and condition fluid as needed. Pressure test OOA to 1560 psi. Pressure test OA to 2700 psi. CMIT TxIA to 2700 psi. ` 3. Set a TWC and test from below to 1000 psi and above to 2000 psi. 4. Bleed tubing hanger void and IA to zero. 5. Nipple down tree and tubing head adapter. Function test LDS. - 6. Nipple up and test BOPE from above to 3500 psi high/250 psi low. Pull TWC. 7. RU and pull the 4'/i 12.6 #, 13 CR VAM ACE tubing from the pre-rig jet cut at 2,800' MD. Test the lower set of pipe rams. Inspect all completion equipment for NORM. 8. RU and run 9-5/8" casing scraper to top of tubing stub. 9. RU eline. Run GR/JB/CCL to tubing stub. 10. RIH with USIT/CCL. Log to surface in cement/corrosion mode to determine top of cement in the 13 3/" x 9-' 5/s°' annulus. 11. With E-line, run a 9-5/8" EZSV for 47# casing. Set the EZSV at 2,700' MD, to avoid milling a casing collar. Rig down E-line. 12. Pressure test the EZSV to 2700 psi for 10 minutes. 13: RIH with 9 5/e" HES RBP on drill p~ Set RBP --100' below the 9 5/e" cut depth 14. RIH with Baker 8-'/a" multi-string c er BHA per Baker fishing rep. Cut 9-5/8" casing above TOC (expected at 1853' MD) per fishing hand. • 15. ND BOPE. 16. ND tubing spool, install slip handles across split in hanger S 17. NU Full bore spacer spool (in place of tubing spool). r 18. NU BOPE. 19. Pull 9-5/8" casing hanger to floor/LD 9-5/8" casing. 20. Dress casing stub and 13-3/8" casing w/scraper. 21. ND BOPE. RU 2 vac trucks to cellar. LD 9-5/8" casing spool. 22. Cut 13-3/8" casing below slips in well head. 23. Pull 13-3/8" casing slips w/13-3/8" casing stub. 24. Cut 18-5/8" casing below lower most casing head. LD Lower most casing head. 25. Run 9-5/8" casing from 1853' to surface. 26. Cement 9-5/8" casing to surface. 27. Cut casing as good working level for slip on wellhead. 28. Install new 9-5/8" slip-lock well head/Slip Lock Casing Head. 29. NU and test BOPE. (Release Vac trucks.) 30. Rig-up slickline and pull RBP. 31. PU 9-5/8" whipstock, bottom trip anchor, 8.5" window milling assembly and RIH to the top of the EZSV. Orient and set the whipstock. (Gyro MWD or singleshot survey will be required.) Swap the well over to fresh water LSND milling fluid 32. Mill a window in the 9-5/8" casing from 2,500' MD' plus minimum of 20' of new formation from mid-window. Circulate wellbore clean. Cement is expected behind the 9-5/8" casing. 33. PU into 9-5/8" casing. Perform a LOT. POOH for drilling BHA. 34. PU 4" drill pipe. 35. MU an 8-1/2" drilling BHA with GR/RES/PWD/MWD and ghost reamer. RIH. 36. Kick off and drill 8-1/2" intermediate interval with LSND drilling fluid. Continue drilling intermediate hole to 7" casing point at the top of the Sag River. Weight up to 10.6 at top of HRZ. 37. Change to 7" casing rams and test to 250 psi low / 3500 psi high. 38. Run a 7", 26#, L-80, VAMTOP HC casing to surface. 39. Cement 7" casing with a 1000' tail of 15.8 ppg class G cement. Displace cement with mud. 40. While hanging 7" casing, lift BOPE (at top 9-5/8" casing head) to install 7" slips in wellhead, set down 7", run in LDS, and energize primary seals on 7" casing. 41. Cut 7" casing above IC casing spool at proper height for secondary packoffs. 42. Set back BOPE. Install tubing spool with packoffs. Test IC casing hanger flange and 7" packoffs. 43. NU BOPE and test to 3500 psi. 44. WOC until 500 psi compressive strength. Freeze protect 9-5/8" X 7" annulus. 45. M/U a 6-1/8" MWD/LWD drilling assembly. P/U additional 4" drill pipe as required to TD the well and RIH to top of the float collar and test the casing to 4000 psi f/30 minutes and chart. 46. Displace the well to 8.5 ppg Flo-Pro mud. 47. Drill out shoe and 20' of new formation and perform the planned FIT. Drill ahead, per directional proposal and rig site geologist, to well TD at approximately 10,518' MD. 48. Condition the hole as required in preparation for the planned open-hole logs and running and cementing the 4-~/z" production liner. 49. POOH, VD excess 4" drill pipe and BHA. 50. If hole is in good condition, R/U and run the 4'h", 12.6#, 13 Cr, VAMTOP liner. 51. Cement the liner per program bumping the plug with clean seawater. Release from the liner and set the packer and circulate excess cement to surface displacing the well to clean seawater above the liner top. 52. POOH and inspect and UD liner running tools. 53. After cement reaches a minimum 1000 psi compressive strength, R/U and pressure test the well to 2000 psi for 30 minutes and record the test. 54. R/U and run a 4-~/2", 12.6#, 13 Cr, VAMTOP completion. Space and land the tubing with the tubing tail inserted into the liner tie back sleeve. RILDS. 55. Install and test TWC (from below.) 56. N/D the BOPE. N/U the adapter flange and tree and test tree and adapter to 5,000 psi with diesel. 57. RU DSM. Pull TWC. 58. Reverse circulate filtered seawater, followed by inhibited seawater, followed by diesel freeze protect down the IA and U-tube the diesel freeze protect into place through the tree. 59. Drop ball/rod through the tree pressure up on the tubing side with diesel to set the completion packer. 60. Individually test the tubing and annulus to 3500 psi for 30 minutes and record each test. 61. Install and test a BPV. 62. Secure well / RD and move-off well. P~/~ V '% ' Post-Rig Operations: • 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. RU E-line and run SCMT log across the 4-1/2" production liner if required/desired to confirm the quality of the cement job on the 4-1/2" liner. 3. With E-line, perforate well per the Asset. 4. AOGCC MIT-IA POST POI (per WIC) (injector) 5. Install the well house, instrumentation, and flow line. (NOTE: This work will be completed under a separate AFE.) C' ;~~~ Mel Rixse Operations Drilling Engineer CC: Well File Sondra Stewman/Terrie Hubble TRH SAFETY NOTES: 4-112 ME TBG 733/8 X 18318" IS H -~ 2A CMTDTO Sl82FACE FROM A STACf TOOL @ 2221' MD 2217' I--14-112" HES X NIP, ID = 3.813" i" CSG, 47#, N-80, NSGC, ID= 8.681" I-1 2271' 13-3/8" CSG, 68#, K-55, ID = 12.415" 2271' i-5.~8" CSG, 96.5#, K-55, ID = 17.655" 2308' Minimum ID = 3.725" @ 10706' 4-1/2" HES XN NIPPLE 19-5(8" X T' BKR ZXP LNR TOP PKR ID = 6.260" I I ML.LOUT W~1DOW (H-02A) 5529' - 5545' WHPSTOCK $$29' 10627' 4-112° HEiSX NIP, ID= 3.813" 106Q$' 7" X 4-112" BKR PREM PKR D = 3. 1flFiR_4 4-112" HES X NIP. D = 3.813" HES XN NIP, ID = 3.725" I /2" WLEG, ID = 3.958° f3MD TT NOT LOGGf~ 7" X 5" BKR ZXP LNR TOP PKR, ID - 5250" 9-518" CSG, 47#, N-80, ID = 8.681" I"I 8300' PH2FORATION SUMMARY R~ LOG: ANGLEAT TOPPeRF: 97° @ 12180' Note: Refer to Production DB for historical pert data SQE SPF INTEft/AL OpnlSgz DATE 2-112" 4 12180 - 12350 O 12/27/02 2-1Y2° 4 12430 - 12580 O 12127/02 2-112° 4 12650 - 12850 O 12/27102 i" X 9-518" TM/ TIEBACK PKR 3" X 9-518" XO, ID = 8.681" !.AR I IF'f MA Nf)<2R S ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3076 3076 0 KBG-2 DMY BK 0 12/29/02 5 4085 4085 0 KBG-2 DONE BK 16 01 /23/03 4 5572 5571 5 KBG-2 S/O BK 20 04!27104 3 6730 6581 47 KBG-2 DMY BK 0 12/29102 2 8603 7573 59 KBG-2 DMY BK 0 12!29!02 1 10562 8575 61 KBG-2 DMY BK 0 04(27/04 4-1/2" TBG, 12.6#, 13CR. .0152 bof. D = 3.958° 7" LNR, 26#, L-80..0382 bpf. D = 6250" I""I 10867' ( / 4-112' LN1; 12.6#, LSO, .0152 bpf, ID- 3.958" 129L/49' DATE REV BY COMMENTS DATE REV BY COMMENTS 12!28!75 ORIGINAL COMPLETION 07/29109 RLMIPJC PULL PX PLUG (07110109) 12130102 JLMIKK RKaSIDEfRACK(H-02A) 03122/04 ATDITLP CMT TO SURFACE, DV PKR 04/17/04 ???IKAK ADD 9-518" CSG DESCRIPTION OM.27/04 KSIKAK GLV CIO 05105/08 SEWlPJC SEf f1C PLUG (051003!08} PRUDHOE BAY UNff WELL: H-02A PERMff No: RL021600 API No: 50-029-20100-01 SEC 21, T11 N, R13E 1070' FNL & 1266' FEL BP t3cpbration (Alaska) ' . lFi~= V\fl Ll-64D= 412' U1V I/OY MD . - -- ACTl14TCR= r --- OTIS F'8 ELEV = 73.3 ----_ BF. BF1/= .. 44.831 KDP= 2500 Mac Arx,~e = 77°10393 M_LQJfV1I~iX7/V(FiO~ 2~0 H-02B P!~lOPOSED I OFFOF9SIBECASING.~Uh 1813' 9-518" Halliburton ES Cementer 1833' 9-518" Baker ECP 1853' 3518" Bowen Casing Patch 1863' 9-5l8" CSG, 47#, L-80, HYD-563, ID=8.681" 1853' TOC 2200' 4-1 i2" HES X NIP, ID = 3.813" 2271' 13-318" X 9-518" TNV TIEBACK PKR 133/8" CSG, 68#, K-55, ID =12.415' 2271' \ 9-518" CSG, 47#, N-80, NSCC, ID = 8.681" 2271' 2308' 18-518" CSG, 96.5#, K-55, ID = 17.665" CAS LIFT MANDRELS E TBG. WELLHEAD BUILT ST MD ND DEV TYPE VLV LATCH PORT DATE 4 -3600 3587 KBMG S/O 8K 3 -6400 5847 KBMG DMY BK 0 2 -8300 7377 KBMG DMY BK 0 1 -9600 8500 KBMG DMY BK 0 Minimum ID = 3.725" ~ 9700' 4-1/2" HES XN NIPPLE ~ 4-112" TBG, 12.6#, 13 0152 bpf, ID = 3.958" finch - Punch. 9557' 4-12" HES X NIP, ID = 3.813" 8712• 9582' T' X e-v2° Ha~liburtcn TfYi Pr(R 9 G 9626' 412" HES X NIP, ID = 3-813" 9700' 4-12" HES XN NIP, ID = 3.725" 9702' 5'x7" T~enack S,eeve/Z XP Liner Top Packer 9722' Baker Rexbck Gner hanger 9$72' 7" CSG, 26#, L-80, .0382 bpF, ID = 6.276" 4-12" LNR, 12.6#, 13Cr-85, 10398' 0152 bpf, ID = 3.958" 12128R5 ORIGINAL COM PLEiKN! 0729109 RLMIPJC PULL PX PLUG (07/1010 12130102 JLMIKK RIG SIDETRACK(H-02A) 9/17!09 MGR RST PROPOSED 0322104 ATDITLP CMT TO Sl1F2FACE, f)1/ PKR 04!17!04 ???lKAK ADD 35/8" CSG DESCRIPTION 0427/D4 KSlKAK GLV GO 05/05/08 SEWlPJC SET PX PLUG (051~3A8) 10310' PBTD WELL: H-028 PERMIT No: 2021600 API No: 50-029-20100.02 SEC 21, T11 N, R13~ 1070' FNL & 1266° FE1 8P Exploration (Alaska) i _~ SEC 16 ~- - - - - ~ ~? GC2 I -~- SEC 21 ;- ,'~._ ~ m l ~- o \ 1 z _. i J ~ SEC 16 SEC 15 D_ (] 27 ~ o I 28 ^ 21 _ ~ _ 7 -- 1D 22 - - - - - 25 18 8 24 J3 3~ H PAD 17 ,~ 4 ~ 3 ^ SEC 21 SEC 22 ~ 29 2 2~ VICINITY MAP za N TS 18 (Yi,~_ H PAD 3~ ,5 l.(J„`~}{.J`(,h/ ~F q oooooa ~q ~E s~ , o r~P 1 ~ 'e~ _ oo°~ ~ ~ ~ ~ \ ( ~~~ 13 ooaaaoaaoa o oooovavaaoo o a 31 12~ 00000000000000000000 0 Alliso 'c`~e Richard F. 32 n pp '~o, ~ ~6Xl CJ 10 ^ 37 QO ~ ~~~R~~iiOO.. "'~'ESSIONN- 34 9 SURVEYOR'S CERTIFICATE LEGEND I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED ~. AS-BUILT WELL TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT ^ EXISTING WELL THIS AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT NOTES: SUPERVISION AND THAT ALL 1. DATE OF SURVEY: MARCH 15, 2010. DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 15, 2010. 2. REFERENCE FIELD BOOK: NS10-12 PG's. 15-22. 3. COORDINATES ARE DATUM NAD 27, ALASKA STATE PLANE, ZONE-4. 4. GEODETIC COORDINATES ARE NAD 27. GRAPHIC SCALE 5. HORIZONTAL & VERTICAL CONTROL IS BASED ON 0 200 400 aee H-PAD OPERATOR MONUMENTS. (TN FEET 7. VERTICAL DATUM IS BPX MSL. 1 inch = 400 ft. 1 !l/~ATCI'1 1117TUiAl DD~ITDA!`TCf1 crr ~~ T 11 ni R 1~ F uAATAT AAFRTf1TAN AI ASKA WELL A.S.P. PLANT GEODETIC GEODETIC TOP OF SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSIT[ON(D.DD) CELLAR BOX OFFSETS Y= 5,959,715.38 N= 2099.50 70'17'50.767" 70.2974353' 44 01' 4207 FSL H-2 X= 643,319.30 E= 2000.39 148'50'21.698" 148.8393606' . 1265 FEL ORAwN: F. Robert 9ARNHART CHECKED: Wes, ~J ~^1 DATE: N 3 16 10 DRAMING: FR810 woH 01 WOA H PAD ASSOC. ~A AS-BUILT WELL LOCATION °'°~`"°'"°'.~.`~. WELL H-2 ~m~~ NO: LE: 1 •=a00' SHEET: 1 aF 1 • ~ Mauncler, ~'horn~s E t~C~A From: Preble, Gary B (SAIC) [Gary.Preble@bp.comj Sent: Monday, July 13, 2009 6:24 PM To: Maunder, Thomas E (DOA) Subject: RE: Emailing: 15-07C-203-097-WORK SUMMARY-REV.PDF, H-02A-202-160-WORK SUMMARY-REV.PDF Not at the present. The P.E. is on vacation. -----Original Message----- From: Maunder, Thomas E (DOAj [mailto:tom.maunder@alaska.gov] Sent: Mon 7/13/2009 3:25 PM _ To: Preble, Gary B (SAIC) Subject: RE: Emailing: 15-07C-203-097-WORK SUMMARY-REV.PDF, H-02A-202-160- ORK SUMMARY- REV.PDF ?1 Thanks Gary. So it appears tha~ the "wrap" was not successful on H-02A. Any ideas what the future plans might be? Tom ~~~~;+~~*'~' ; ' :' `a ~~~~ -----Original Message----- '"~'`~ `'~ ` ~` ~ From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Monday, July 13, 2009 1:23 PM To: Maunder, Thomas E (DOA) Subject: Emailing: 15-07C-203-097-WORK SUMMARY-REV.PDF, H-02A-202-160-WORK SUMMARY-REV.PDF Tom, Sorry for the error. E-26a was correct and the attachments contain the corrected data for H-02A 202-160 and 15-07c 203-097. G].ad you are still reading everything. The message is ready to be sent with the following file or link attachments: 15-07C-203-097-WORK SUMMARY-REV.PDF H-02A-202-160-WORK SUMMARY-REV.PDF Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «15-07C-203-097-WORK SUMMARY-REV.PDF» «H-02A-2Q~2-160-WORK SUMMARY-REV.PDF» 1 STATE OF ALASKA , ALASI~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~~ 1. Operations Abandon ~ Repair Well Q~ Plug Perforations ~ Stimulate~ Other ~ Furmanite Wrap Performed: Alter Casing ~ Pull Tubing ~ Pertorate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown [] Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: ivame: De~lopment r Exploratory I~ 2o2-~soo ~ 3. Address: P.O. Box 196612 Stl'8t1g1'BphiC r Service (- 6. API Number: Anchorage,AK 99519-6612 50-029-20100-01-00- 7. KB Elevation (ft): 9. Weli Name and Number: 73.27 KB _ PBU H-02A ` 8. Property Designation: 10. Field/Pool(s): ADLO-028284 - PRUDHOE BAY Fieid/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12950 feet Plugs (measured) 10662' 5/9/07 true vertical 8863.02 feet Junk (measured) None Effective Depth measured 12862 feet true vertical 8866.61 feet Casing Length Size MD TVD Burst Collapse Conductor 100 30" 157.5# SurFace - 100 Surface - 100 880 Surtace 2306 18-5/8"96.5# K-55 Surtace - 2306 Surtace - 2306 930 870 Production 5529 13-3/8"X9-5/8" 68#/47# Surface - 5529 Surface - 5528 4930 2270 Liner 4200 7"26# L-80 3980 - 10961 3980-8780 7240 5410 Liner 2239 4-1/2" 12.6# L-SO 10710 - 12949 8649 - 8863 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ , Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13-CR SURFACE -10717' 0 0 - Packers and SSSV (fype and measured depth) 9-5/8"X7" BKR ZXP LNR 3980' 7"X4-1/2" BKR PREM PKR 10648' 7~"X5" BKR ZXP LNR TOP PKR 107 10' ~~~~~~~ ~ ~ 12. Stimulation or cement squeeze summary: ~ U~ 3 O 200~ Intervals treated (measured): ~~~~-~ `~ ~ \ti ~~ ~~ ~laska Oil & Gas Cons. Commissi Treatment descriptions including volumes used and final pressure: /~fiE~lOra¢}~ 13. Representative Daily Average Production or injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory r Dev~elopment ~~ Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil r- Gas r WAG r GINJ r WINJ r WDSPL ~ 17. I hereby certiy that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer -~ Signature Phone 564-4944 Date 6/29/2009 Form 10-404 Rev~ed 04/2006 ~~~ J~L ~~~~Qg ~""'~~ ~ Submit Original Only r H-02A 202-160 PERF OTTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base H-02A 12/27/02 PER 12,180. 12,350. 8,857.19 8,836.13 H-02A 12/27/02 PER 12,430. 12,580. 8,829.4 8,837.12 H-02A 12/27/02 PER 12,650. 12,850. 8,844.88 8,866.74 H-02A 5/9/07 BPS 10,662. 12,850. 8,624.75 8,866.74 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • ~lll~~and~r, Tl~~ma~ ~ Q~~ From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Monday, July 13, 2009 1:23 PM To: Maunder, Thomas E (DOA) Subject: Emailing: 15-07C-203-097-WORK SUMMARY-REV.PDF, H-02A-202-160-WORK SUMMARY-REV.PDF Attachments: 15-07C-203-097-WORK SUMMARY-REV.PDF; H-02A-202-160-WORK SUMMARY- REV.PDF '~'-'-~-~.~ ~~ . ~.. is-a~c-zo~-n9~-w~~u+-~v~-~~-wQ 3ftlC SUMI++1l~RY-f~,:~K ~11l~M~6~Y-REV.. Tom, Sorry for the error. E-26a was correct and the attachments contain the corrected data for H-02A 202-160 and 15-07c 203-097. Glad you are still reading everything. The message is ready to be sent with the following file or link attachments: 15-07C-203-097-WORK SUNIMARY-REV.PDF H-02A-202-160-WORFC SUMMARY-REV.PDF Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attaehments are handled. «15-07C-203-097-WORK SUMMARY-REV.PDF» « H-02A-202-160-WORK SUMMARY-REV.PDF» Page 1 of 1 t~~und~r, Thpmas E (DOA) Frarr~: Maunder, Thor~as E (~OA) Sent: M4nday, July 13, 2009 10:19 AM To: Gar~ Preble (SAlC) SubjeCt: E-26A (197-141), M-02A (202-160), D~a 15-07C (203-097) Gary, I am reviewing the 404s for th~ rer,ent Furmanite starting head re~airs on these weils. Oper~ti~ns sumr~aries were at#ached Mow~v~r it appears, for th~ most part, that the surr~maries a~e identical. The same summaries are attached to all ~ 40~~ for activities sfiated to occur May 18 - June 4, 2009. Identical operations are described for May 7- May 17 f~r DS 15-07C and E-26l~. There ~re some unique activitiss d~scribed at the beginning of pS 15-07C and the er~d of H~02A. Pd appreciate your reconciling these reports. While I can understand similar overall operations, it is not valid for the opErations to agree down to the individual pressure readings or water level soundings in the cEllar, Thanks ir~ adrrance. Tom Maunder, PE AOGCG ~ ~ H-02A DESCR.IPTION OF V9'ORK C~M~'LETED NRWtJ UPE~tATI~NS EVENT` SUMMARY 5117/2009;T/lIQI00-SSV/50/1010+. TBmp,S1. Cut of# 1-'~/2" pipe riser in conductar ~wlalr sawsall (prep ~urmanitej. Cut 1-112` pipe riser off 5° belaw tap of 3conductor. Heater installed in well house & celfar floor is dry. !Vo visi~le or ; iaudi~~Ie s~gns of SC leak. ........ _..._._...._. .. . ._.._ ._- ---_..iSV,. WV,. SSV=Cbsed._._MV=Open....lA,_OA & O~A=OTG. N~VP. < . . _._......_. __. ............_.. ..... _._~_......_ ..... ....._._. ; sl2~I20as~~iE/O/o0 ~ S5V/~0/20/50. Temp = S€. Purge OC3A w11Q' N2 bianket ~i ~{Furmanite prep). O~A cemen#ed to surface. AL line S! ~ casing valve. ; ~ALP = 1600 psi. WH & cet#ar prep completed for Furmanite job. OOA FL : ; near surface. Bted OOAP #rom ~0 psi #o Q psi in 1 min into BT (gas). ~ Increased OOAP w/N2 from 0 psi to ~20 psi in 1 rr-in. Monitored pressures ; !far 30 min. ~~AA unchanged, ~inal V~IMPs = S5VIS0/20112Q. ~ WV, SV, SSV w ciosed. MV = open. IA, 4A = O~"G. ; s E I ~ 3 1 1 i ,.............~.. _._........_.._~..... ~ ..........................~..._ ......... _...... _.............................. .........; ......... .. . ..... .. .... . .. ... .. . ........ % 5/22/2009~7/i/O/Cl0 r S5V/80/1~/80. Temp = SI, . Verify N2 on OOA, hold open ; ~bleed for Furmanite wrap (Furmanite wrap}. ~OA cemented. fVa standing ' ~water in cellar, Cam ositech sandblasted 8H. Furmanite ins#allerf ; i campasite wrap on SH (11:30 am). Held apen Iee or 7.5 rs. ; Pass down ta night shif#. ;SV, WV, SSV=C. IA, QA, OOA=OTG. NOVP, " ._...._ ~ - _...___... _._.._...___. ...................s..............:._.._.............,._.._..._......,....................................~._......_.._..._......__................_~........._.................._....._.._.._..... ........._..........; 5123/2009;T/1/0/00 ~ SSV/50/10/~. Temp = Sl, Verify N2 on UC7A, hold open bleed ~ ;for Furmanite wrap. Ch~nged oui vu# with night shift, Heater vntir~e I '•.blowing 9nto cellar. Furmanite crew arrived and installed add'€tianai wraps. 1 ; Furmanite trailer le t on ocat~on. urn~ over a rnp s j. s= ~ , WV, SSV = G. MV = O. IA, C3A, OdA = ~TG. NOVP. ...............__.._._,...__.........._...,_....._._r...,......._...._..........~...._......_. __....._____._~.._ .. _..._...__.....~......_~....~.........._.................... .._.._.._ 5/23/2009;T/i/OIOO~SSV/60/10I0. 1'emp=Sl. Ha[d open bEeed for Furmanite wrap :(Furmanite wrap). '*Cc~ntinued from day shift'* Maintained open bleed on ~OOA for ~urmanite cure. Final T11J0/OU=S~V/50/10J0_ sSV, WV, SSV=C. MV=O. IA, 4A, OOA~4TC~, hfOVP. . ...... ....._ ...........~ ..................._..................,.._......._._...._......_._............. ._..... ....,.......,......._..._._......._............._-.....~.._......,........,.._......................_......_....._.,........_......... 5l24I20U9;T/ti0/00=S5V/50/10/0. Temp=Sl. Hold open bleed for Furmanfte wrap ;(Furmanite wrap). ** Gontinued trorr~ day shift. '* Maintained open bleed ~on OtJA for Furmanita cure. Fina! T/1101~0=55V/5(3/i 010. ~SV, WV, SSV=C. MV~Q, (A, (JA:OTG. NOVP. _.__.............._,............_.......__.....:_......._..._..._...._..__.......,........................... .. ..._.__. ~ ....... .........._.._...................... ...._.._. .........._~..........._.. _......: 5/2412009;T/f/0/~0= SSV/50I1410. Temp= SI. Hold open bleed tor Furmanite wrap. 4 i"•~Continued from night shifi*"". Maintained open bleed on OOA for ; ~Furrrtanite cure. Furmanite wrap compieted ~ 10 am. SI bleed. ` iMonitored for S hrs 34 min. OOAA increased 8 si. Bled OOAP from 8 psi ; ; o psi m ess an min. o open lee ~r 48 hr Furrnani#e cure time. ~ ; Final WHPs= 5SV/50/10/0. ~ ....................~k. .............._....~. :SV,_WV, SSV :.Closed.._.MV= Open......lA, OA, OOA- ~TG..--h10VP,......._......_..... : ~ ~ .................. . .. .._~.........._....._..........,,...._.~... ......_~............._....._....._......._............~....................._....._.._....__..__..........._....... .... ..__.... 7/VO/00=SSVI55113I0. Temp~51. Hold open bteed for Furmanite wrap i {Furmanite wrap}. ALP=1330 psi, SI ~ casing va(ve. ""' Confinued from j day shiFt "* Maintained apen 40A bleed ior Furmanite cure. Final ` T/I/O/00=SSV/55/~ 3/0. ~ SV, WV, SSV=G. MV=O. IA, OA=OTG. Nt~VP. j 5/27~ --- --- .._ .__..._._ ___......_. .... , ... ............_...._........._..........._~...._........_........._..........__..._..._...._........ ...._ ..........._._,........_..... T/~/O/{70= SSV/55Iy 5/0. Tern~ Sl. Hold open bleed #or Furmanita Wrap {Furrnanite Wrapj. Al. connecled and shut-in C~ casing valve, ALP = 15Q0 psi. Continued from day craw holding open bleed on OI~A for i2 haurs, WHPs unchanged. Final WNPs= S5V/55115/0. SV,WV,SSV,ALC=clased. MV-open. iA,0A,00A=open to gauge. NOVP. ......~..._ ............................._...........,..._._v.._e_~..____........ _ ...~........_......__,_............._,..... ._.._._.....~............,...~.............:... T/ll0/00= SSV/40/10l0. Tsm~r- SI. Haid open blsed for Furmanite wrap. ~'*Change oui with night shiit:'*k Heater btawing inta ce{f~r and working properly. Maintainecf open bleed on OOA far Furmanite c~re. "`*Three nuts on THA not 100%"'*. Final WHPs= SSV/40/10l0. SV, W V, SSV= Closed. MV= Upen. (A, bA, ~bA= OTG. f~tJVP, _.......__... _...._ ...............................r...._.__.,_~... . ...................~............._ .. .~...~.._..._.. ~ ............._............ ..._.. T/I1C}!fl0 = 55V/40/10J0. Temp ~ SI. Ho(d open bleed for Furmanite wrap {Furmanite wrap}. ALP =13~4 psi & 5t ~ casing valve. "'Continued from night shift'". Maintained OOA bl~ed for Furmarti#e cure. Si bleed @ 2pm. Monitored during rig down. N4 change in pressures. Final WHPs = SSV/40/iOJa. 5V, WV, SSV=C. MY=Q, iA, OA, OOA~OTG. NOVP. ........._.........~_._..._......_..._...._...__..._.....__.~...__...._.._ .............._....._......_.._....._~----....._.___._...._........,.......~.._..._..._. _............ T/Il0/00= SSV/50l10/t0. Temp~ 81. ~nsure heat~r is still on well & working {Furmanite wrapj. Al. S! ~ casing valve, AL.F'= i400 psi. lAR increased 10 psi, OAP unchanged, OOAP increased 10 psi overnigh#. Meater worl~ing proper~y. ~ 5/28/2oQ9 ~ ~ .. _......._. ..._. ..... .____..._ ............................. .......... ... .... .. ..........._...._........._..._.._...__........ ..........._ ,.,...._.................. - T/IIO ~ SSV/55/15/35. Temp ~. SI. ~nsure heater is siili ot~ welf. Heaier anline b[owing on#o Furmanite. IAP increased ~ psi, ~AP increased 5 psi, OOAP increased 25 psi avernight. SV, WV, SSV = C. MV = O. IA, C?A = OTG. NOVP. ............a..._...._..._...i...._._...._..._....._........._ ....................................:................._.............._......_............................._....__............_......................__.. ~-- - ~- 5/29/2009~T/i/0100 = SSV/40/10/2Q. Temp=51. Ensure heatar is sti11 on we(1. AL is ~connected & Sl ~ casing valve, AL.P» 1470 ps~. Hsa#er is working & in ~ cetlar. iSV,WV,SSU=Closed. MV=~pen. IA,OA=OTG. NQVP. .................~..._._.._~..._~........._._.__.~_...._.,...........~......._.........,.........,..._...,..........................................................~..__.._......._...___........._..._....... _.._ 5J30/2009:T/110/00=5SV/50/10/40. Terr~p,Sl. Ensure heater is or~ we11. AL S! @ ,aasing valve, ALP-147~ psi, IAP inareased f0 psi, OAP unohanged, =0{}AP increased 20 psi overnighi. Heater is working on Furmanite cure. ~SV, WV, SSV=CIosed. MV=Open. IA, OA=OTG. NOVP. ...._ .. _.. -.._....,.__..._. . --....__........_- - -......_...... - _- ....................-- ~- __... •-----......._~_.._.................._... _.... ......_... 5/3112fl09!T/I/0/04=SSV/53J14143. 1"emp=51. ~tonitor WHP's &~nsure heater is ; still on weli head. (~ost Fu rmanite Job). Fieater is sti(1 an the weil and a running hot. IAP increased 3 psi t~vernigh#. OAP inoreased 4 psi overnight, ; OOAP increased 3 psi overnight. 1SV, 5SV & WV = CI~OSED. fv1V = OPEN. IA, OA & OOA = OTG. N4VP. .........._. .................:............... ............._......................_._........_...._....._.....~.__.._....._.._...._...._..___..........__._.,_..._~.~_...__..._...._......_.~...._ ...._.. 6/3/20a9~T/t/Q= SSVl50/10/30, Temp= SL "FAILED' MIT-OOA to i 000 psi w/ Iiriplex (repair SH leak}. AL Si ~ ~ateral & casing vaive. Increased C?C1AP from 30 psi ta 104a psi, pressure dropped oif rapidly to 500 psi, ~ repressure six more times wit same resTin~'3~ ~al of ; B1ed QOAP from 470 ~si ta 0 asi in 30 sec. Monitored far 30 rrsin with no ~ ~ !Changed in WHPs. ~inal WHPs= 88V/50/10J0. ' ~ lS~, . - . - • , =~TZ~.~Tc5~7~P. i ! i i s H-02A (PTD #2021600) Classified as Problem Well e e All, Well H-02A (PTO #2021600) has been found to have sustained casing pressure on the OA. The TIO pressures were 200/1520/1060/270 on 05/12/06 when the OA pressure was bleed but repressurized The plan forward for this well is as follows: / 1. OHO: Bleed OAP, monitor for build-up 2. OHO: Bleed lAP & OAP to 0 psi 3. CAM: Evaluate wellhead seals ./ .....,. 'r~",h'\l t;; n -J; \'1iiti1J ~J", 'j~,~,," (~ A well bore schematic has been included for reference. «H-02A. pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, )Inna CDu6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 )(1154 )Inna (])u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 )(1154 Content-Description: H-02A.pdf H-02A.pdf . Content-Type: application/octet-stream Content-Encoding: base64 1 ¿6 Z- btd.'\¡\f/ 5~ 5/30/200610:46 AM TREE = 4-1/2" CIW WB..LHEAD - MCEVOY A GrUA TOR = OTIS KB. ELEV - 73.3' BF. ELEV - 44.83' KOP = 5700' Max Angle - 99 @ 11732' DatumMD = 11010' DatumTVD = 8800' SS 9-518" CSG, 47#, N-80, NSCC, ID = 8.681" 13-318" CSG, 68#, K-55, ID = 12.415" H-02A SAFETY NOTES: 4-112" CHROME TOO. 13-3/8 X 18-5/8" IS CMT'DTO SURFACE FROM A STAGETOOL@ 2221' MD ST MD 6 3076 5 4085 4 5572 3 6730 2 8603 1 10562 18-5/8" CSG, 96.5#, K-55, 0 = 17.655" Minimum ID = 3.725" @ 10706' 4-1/2" HES XN NIPPLE 3980' ND 3076 4085 5571 6581 7573 8575 GAS LlFTMANDRB..S DEV TYÆ VLV LATCH o KBG-2 DMY BK o KBG-2 DOME BK 5 KBG-2 SIO BK 47 KBG-2 DMY BK 59 KBG-2 DMY BK 61 KBG-2 DMY BK FORT DATE o 12/29/02 16 01/23/03 20 04/27/04 o 12/29/02 o 12/29/02 o 04/27/04 9-518" X 7" BKR ZXP LNR TOP A<R, 10 = 6.260" H ELMO TT NOT LOGGED I I MILLOur WINDOW 5529' - 5545' 1 TOP OF WHIPSTOCK I 9-5/8" BRIDGE PLUG 9-5/8" CSG, 47#, N-80, 10 = 8.681" 17" LNR, 29#, L-80, .0371 bpf,ID 6.184" I 9318' ÆRFOAA TION SUM~RY REF LOG: ANGLE AT TOP PERF: 97@ 12180' Note: Refer to Production DB for historical perf data SIZE SPF INTERIIAL OpnlS z DATE 2-1/2" 4 12180-12350 0 12/27/02 2-1/2" 4 12430 -12580 0 12/27/02 2-1/2" 4 12650 - 12850 0 12/27/02 4-1/Z' TBG, 12.6#, 13-CR, .0152 bpf, 0 = 3.958" 4-lIZ' HESX NIP, 0=3.813" 7" X 4-1/2" BKR PREM PKR, 0 = 3.920" I 7" LNR, 26#, L-80, .0382 bpf, 0 = 6.250" I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" DATE 12/28/75 12/30102 01/23/03 07/24/03 07114/03 08/22/03 REV BY COMMENTS MW/KAK 13-3/8" CSG CORREGrION ATMLP CMTTO SURFACE, DV PKR ???/KAK ADD 9-5/8" CSG DESCRIPrION KSIKA K GL V C/O REV BY COMMENTS ORIGINAL COMPLETION JLM/KK RIG SIDEI"RACK(H-02A JCM'TP SEI" GLV DESIGN MW/KAK TBG/LNRCORRECllON CMOJrLP KB ELEVA TION, MAX ANGLE RWUKK GLV C/O DATE 09/25/03 03/22/04 04/17/04 04/27/04 PRUDHOE BAY UNIT WB.. L: H- 02A ÆRMrr No: 2021600 API No: 50-029-20100-01 SEC21, T11N, R13E, 1070' FNL& 1266' FB.. BP Exploration (Alaska) e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc e e WELL LOG TRANS MITT AL (' ( r I --*C} ) ~\ - 11)0 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17,2006 136D\ RE: MWD Formation Evaluation Logs H-02A PBl, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 H-02A PBI: LAS Data & Digital Log linages: 50-029-20100-70 1 CD Rom f~' Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Date Bl 02-308 10980587 RST 07/17/05 1 PSI-07 10674389 RST 10/27/03 1 PSI-07 10679045 RST 12/26/03 1 l3-02 11072860 RST 06/13/05 1 X-16A 10980531 RST 03/01/05 1 F·30 10987523 RST 06/22/05 1 W-31 10913021 RST 06/30/05 1 2-15 10980580 RST 07/10/05 1 C-30 10980583 RST 07/13/05 1 W-39A 10928650 MCNl 10/16/05 1 18-31A 10942210 MCNl 04/28105 1 H-02A ;), Ó Q - I {PO 10928622 MCNl 04/05/05 1 05-24A 10928609 MCNl *(PRINT SENT 1/24/05) * 12/22/04 K-06A 11075903 MCNl 07/30/05 1 l-03 10913041 OH lDWG EDIT FOR WIRELlNE DATA 08/01/05 2 B·02A 10889169 SCMT 09/22/04 H-05 10674407 CBl 01/21/04 G-13A 10563175 SCMT 06/17/03 E·06A 11051045 SCMT 05/19/05 W-20 10672389 USIT 06/03/04 MPF-87 A 10708043 USIT 01/08/04 MPA-03 11058243 USIT 09/07/05 MPF-89 11051088 USIT 08/17/05 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 SCANNED NOV 2 9 2005 Date Delivered: , b D.f \ \ < - III ,r if ( , " ''.-'' - ,\ . r,cc\~ ! u . .-;) NO. 3602 11/17/05 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne P~6;¿-1 bo, Color 1 1 1 1 1 1 1 1 1 CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 -- I -3 385 ~ Alaska Data & Consulting Services 2525 Gambel/ Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Received by L~~t 0- ') ï"""" \" I , , V,"""", ~ 'iI",,", ,\ ''1J ,~~,Ct- lf0f05 0(,1 'lø 6 . .("~1~\\ C~~1~1!'~":I!~ó) o~~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 15, 2003 RE: MWD Formation Evaluation Logs: H-02A & H-02A PB1, AK-MW-22140 H-02A & H-02A PDt: Digital Log Images 50-029-20100-01, 70 :;F)}~~~ 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:) ( OJ- ~ \_. 1hJ (JiLJ Signed: 0",,( Î 1+.. DÀA ~ fS 1 Dj-~ .-....,.....-~.... $tANNED OCT 3 1 2005 " . ;to^~ (l<J ~;{ -L H-02 Cancel Waiver Notice ) ) Pðct t+-~!-A ~''ß \ rvA~(a ql~(oÇ Subject: a,..e:f Cancel Waiver Notice ~ t From: "Anders, Joe L" <anders22@BP.com>,.f)..".. .·.0:... ,.,a:-I~() Date: Sun, 28 Aug 200520:43:50 ..0800 ~".. Tô:;jim;....regg@admil1.state.ak.us~ ·winton_aubert@adnlin.state.ak:.us, "Rossberg,R Steventl <RossbeRS@BP.com>, "NSU, ADW Well' Operations Supervisor". ..,. . <NSU ADWW ellOperationsSupervisor@BP . com>, '''GPE,. Ge2 Area Mgr" <GPBGÇ2TL@BP.com>, ~'GPB,'GC2W ellpadl;ead" <GPBGC2W ellpadLead@BP~com>, "GPB,Wells' Opt Eng~' . <G:PBWellsOptEng@l3P .com>, "GPB" Optimization Engr" <GPBOptimizationEl1gr@BP .com>, "GPB,Ops Mgrtl <GPBQpsMgr@BP.com>, "OPB, Optimization Engr" .' . I <GPBOptimizationEngr@BP.co11l>, "'Warren,,'Mike" <WarrenM@BP~com>" "Engel, HarryR" ,I I <F:ngeIHR@13P~com>,GPBWel1radsHPYQ@BP.com II'. . " '" I ,I CC:' "Dube;Ã11na I T"«Anna.Dube@BP.com>,,'IReeves, Donald F"<ReevesDf@BP.com>, "Hughes, . Andrea (VECO)" <hugha4(fYBP.coIl1>~ "Luck~tt, ElyZ.(VECQ)"<:luckez@BP.com>, "NSU,ADW . W~ll Integrity Engineer" <NSUADWWellIntegrityEngirieer@BP.com> I ,. I ,; I ¡ p-ïi) #- 2Ð1..J (,0 0 All: ,µ -o"-ZA The waiver for well J::L-.f>Tis canceled and the well has been reclassified to a Normal well. Review of the well pressure history does not support the diagnosis of IAxOA communication. Bruce & Richie: would you please ensure the H Pad Operator removes the laminated Waiver sign and the "Waiver Well" plaque on the well house. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom ~i... ¡j" ~;:, l~ ¡Ä.~ It: \¡;¡ tt·, C 0 ('0 Jt 20 n~¡ ")",,,.t ~\ ,X'i.\t,,,.(.· ,~¡.IL" ü· 1 of 1 9/9/2005 2:42 PM ~.. q J~ ~~.~ \-p DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 )fJ(,td. ~)~ ~Z API No. 50-029-20100-01-00 Permit to Drill 2021600 MD 12950 ,~/ Well Name/No. PRUDHOE BAY UNIT H-02A Operator BP EXPLORATION (ALASKA) INC TVD 8863../ Completion Date 12/29/2002 /" Completion Status 1-01L UIC N Current Status 1-01L REQUIRED INFORMATION Samples No Mud Log No Directional Survey G::)../ "'---- (data taken from Logs Portion of Master Well Data Maint) ",,-," Interval OHI Start Stop CH Received Comments 5624 12950 Open 1/9/2003 5509 10505 Open 1/9/2003 PB1 MWD 5509 10505 Open 1/9/2003 PB1 MWD 5624 12950 Open 1/9/2003 MWD 5624 12950 Open 1/9/2003 MWD 5624 12950 Open 1/9/2003 5509 1 0505 Open 1/9/2003 PB1 5504 10448 Open 3/26/2003 PB1 25 - 5504 12900 Open 3/26/2003 5509 1 0505 Open 1/9/2003 PB1 5504 12900 Open 3/26/2003 5504 10448 Open 3/26/2003 PB1 5504 12949 Case 1 0/27/2003 25 1-7 5561 12950 Case 1 0/27/2003 ROP J DGR, EWR - MWD 25 1-7 5561 12950 Case 1 0/27/2003 ROP, DGR, EWR - MWD 25 1-7 5561 12950 Case 1 0/27/2003 SLDJ CTN, DGR - MWD 25 1-7 5561 12950 Case 1 0/27/2003 SLD, CTN, DGR - MWD DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Mej;l/Frmt ...-et>L.4' Rpt --é'D ~..". Rpt ,-,,(~' ~/ ¿3pt .,/ ED [J;Y' Rpt Rpt Rpt ~ D ~"D .;::D C Asc ED C Pdf ED C Pdt ED C Pdf ..ED C Pdt MWD, PWD, DIR, GRJ ABIJ RESJ NEU, DEN Electr Dataset Number Na}11e c.err;ctional Survey Directional Survey Log Log Run Scale Media No 1 ~ctional Survey Directional Survey c.-etrê'ctional Survey Directional Survey cJdtf~tional Survey LIS Verification See Notes LIS Verification Directional Survey J11676[).rlS Verification / CA'1677 q¿(SVerl¡ication '"'12197 LIS Verification 12197 Induction/Resistivity 12197 Rate at Penetration 12197 Density "'12197 Neutron DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2021600 Well Name/No. PRUDHOE SAY UNIT H-02A > 'Operator'BP EXPLORATION (ALASKA) INC API No. 50-029-20100-01-00 Name Interval Start Stop Completion Status 1-01L Current Status 1-01L UIC N 5561 12395 Open 6/9/2004 GRAPHIC IMAGES, MWD, ROP, DGR, EWR 5561 10505 Open 1 0/29/2004 ROP/DGR Sample Set Sent Received Number Comments MD 12950 TVD 8863 Completion Date 12/29/2002 £'e:6 C Pdf 6.25'80 Rate of Penetration Ltf)" C Pdf 41796 Rate of Penetration Well Cores/Samples Information: >~ Well Cored? ADDITIONAL INFORMATION y~ Chips Received? ~ ~ Daily History Received? t) ~/N FôrmationTops Analysis Received? Comments: Compliance Reviewed By: (k Date: J( ~)~;'Jho ~ ) ') WELL LOG TRANSMITTAL October 26, 2004 State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 I To: RE: MWD Formation Evaluation Logs: H-02A PBI, AK-MW-22140 H-02A PBl: Digital Log Images: 50-029-20100-70 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Datelffl BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 2- 02, -/(PO ) ) :202.-/"0 12.~--?o WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950] May 13, 2004 RE: MWD Formation Evaluation Logs: H-02A, AK-MW-22140 .H-02A: Digital Log Images: 50-029-20100-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: io Ie) f Si~OO:~ ¡ JtL~ () RECEIVED ¡' P I 0 9 1)004 ,-,,'{IN L 4jt!5Kô ÙJ.â it Gas ~~. vOfm-ni~t } rH".ftfìf99f ) ') ¡ ¿J08 -J wü WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 15, 2003 RE: MWD Formation Evaluation Logs: H-021\ AK-MW-22140 H-02A: Digital Log Images 50-029-20100-01 1 CD Rom )(9) ~ 1- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LRZ-l 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signe~ê\~ ~~~ ~~~i'<\~ ) c9œ-/0D ¡1(P'71 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska March 21,2003 RE: MWD Formation Evaluation Logs H-02A PB 1, AK-MW-22140 1 LDWG formatted Disc with verification listing. llPI#: 50-029-20100-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO mE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: y - ,nn~.~ ) Signed(~.. I ~wl..A-/ RECEIVED MAR 2 6 2003 Alaska on & Gas Cons. Commiseion Anchorage '> aœ- (~o !/0/b WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska March 21, 2003 RE: MWD Formation Evaluation Logs H-02~ AK-MW-22140 1 LDWG formatted Disc with verification listing. llPI#: 50-029-20100-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ~tJkrJ Signed: REceiVED MAR 26 2003 Alaska or: & Gas Cons. ~n Anchorage '4. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 03/11/03, Put on Production ') ') .. 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 202-160 302-377 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20100-01 4. Location of well at surface 9. Unit or Lease Name 1073' SNL, 1266' WEL, SEC. 21, T11N, R13E, UM X = 643318, Y = 5959715 Prudhoe Bay Unit At top of productive interval 4655' SNL, 2768' WEL, SEC. 21, T11N, R13E, UM X = 641892, Y = 5956106 10. Well Number At total depth 5030' SNL, 984' WEL, SEC. 21, T11 N, R13E, UM X = 643684, Y = 5955764 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool RKB = 73.27' ADL 028284 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8/23/2002 12/25/2002 12/29/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12950 8863 FT 12862 8866 FT a Yes 0 No 22. Type Electric or Other Logs Run MWD, PWD, DIR, GR, ABI, RES, NEU, DEN 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 30" 157.5# Conductor Surface 100' 36" 18-5/8" 96.5# K-55 Surface 2306' 24" 13-3IS"x 9-5!S" 68# / 47# K-55/ N-80 Surface 5529' 12-1/4" 7" 26# L-80 3980' 10861' 8-1/2" 4-1/2" 12.6# L-80 10710' 12949' 6-1/8" Classification of Service Well H-02A 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2217' MD 1900' (Approx.) CEMENTING RECORD ;2.75 sx Cement 4200 sx Permafrost 1561 sx Class 'G', 1825 sx PF 165 sx Class 'G' ;2.78 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4 spf MD TVD 12180' - 12350' 8857' - 8836' 12430' - 12580' 8831' - 8838' 12650' - 12850' 8845' - 8866' 25. SIZE 4-1/2'" 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 10718' PACKER SET (MD) 10648' MD TVD 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 156 Bbls of Diesel 27. Date First Production March 9, 2003 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED No core samples were taken. MAR 1"'-1 r ,I'\. 1'1 :' I l.. Vi,;':) Form 10-407 Rev. 07-01-80 3nMS 8Fl Alaska a~¡ & G"',... .",-. ..... ;,. '. II tii.) l"Ot/;;;... t..i-mr¡i'l£!.'t!.!') ""H,H. .."f'i.lh Anch0ftt3a Submit In Duplicate , '<'1fì ¡Vf!-\K ! 2 'l ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. CM2 6231' 6188' CM1 7000' 6739' HRZ 7617' 70611 Leu 8120' 73261 Kingak 88211 7682' Sag River 108501 8721' Shublik 109041 8749' Sadlerochit 11 080' 8835' 31. List of Attachments: Summary of Daily>Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~. Signed Terrie Hubble ~ ÂJ\Å..Q.. ..~ Title Technical Assistant Date 03./1". 0 3 H-02A 202-160 302-377 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Phil Smith, 564-4897 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 ''\. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 23. CASING SIZE 30" 18-5/8" 13-318" x 9-5/S" 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1073' SNL, 1266' WEL, SEC. 21, T11N, R13E,UM At top of productive interval 4655' SNL, 2768' WEL, SEC. 21, T11N, R13E, UM X = 641892, Y = 5956106 10. Well Number At total depth 5030' SNL, 9841 WEL, SEC. 21, T11 N, R13E, UM X = 643684, Y = 5955764 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool RKB = 73.27' ADL 028284 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 8/23/2002 12/25/2002 ~ 12/29/2002 I 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12950 8863 FT 12862 8866 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, PWD, DIR, GR, ABI, RES, NEU, DEN CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 100' 36" Surface 2306' 24" Surface 5529' 12-1/4" 3980' 10861' 8-1/2" 10710' 12949' 6-1/8" Classification of Service Well ¡ .''''¿;i~;~i:,~~,(~:'¡i)~¡''''~ i s~L2~~7::P4 L~ ,." ~="":r:f~' , . .~,. i 7. Permit Number ~.~ .~~,': 202-160 302-377 " ...,. "+1; 8. API Number ,~. '; 50-029-20100-01 9. Unit or Lease Name X = 643318, Y = 5959715 Prudhoe Bay Unit H-02A 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2217' MD 1900' (Approx.) '--yV~ ~~SD: mo ~.b2$ 7Yl) WT. PER FT. 157.5# 96.5# 68# I 47# 26# 12.6# GRADE Conductor K-55 K-55 / N-80 L-80 L-80 CEMENTING RECORD ;2.75 sx Cement 4200 sx Permafrost 1561 sx Class 'G', 1825 sx PF 165 sx Class 'G' 278 sx Class 'G' AMOUNT PUllED 7" 4-1/2" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4 spf MD TVD 12180' - 12350' 8857' - 8836' 12430' - 12580' 8831' - 8838' 12650' - 12850' 8845' - 8866' 25. SIZE 4-1/2", 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 10718' PACKER SET (MD) 10648' MD TVD 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 156 Bbls of Diesel 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) NIA PRODUCTION FOR Oil -BBl TEST PERIOD GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oll-BBl GAs-McF WATER-BBl Oil GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. r"" ~ '.-'i1 \- Form 10-407 Rev. 07-01-80 :~"R B 0 M S B F L era 1 (I Submit In Duplicate I Ci v 20m "I. ) 29. Geologic Markers Marker Name Measured Depth CM2 6231' CM1 7000' HRZ 7617' LCU 8120' Kingak 8821' Sag River 10850' Shublik 10904' Sadlerochit 11080' 31. List of Attachments: ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 6188' 6739' 7061' 7326' 7682' 8721' 8749' 88351 Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHUbble~~J ~ Title Technical Assistant Date O~.J8"06 H-02A 202-160 302-377 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Phil Smith, 564-4897 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: H-02 Common Name: H-02A Test Date 8/22/2002 8/31/2002 12/19/2002 FIT FIT FIT Test Type Test Depth (TMD) 5,561.0 (ft) 5,561.0 (ft) 10,861,0 (ft) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) 5,561.0 (ft) 5,561.0 (ft) 8,727.0 (ft) AMW 10.50 (ppg) 10.50 (ppg) 8.50 (ppg) Surface Pressure 440 (psi) 575 (psi) 680 (psi) Leak Off Pressure (BHP) 3,473 (psi) 3,608 (psi) 4,533 (psi) ,¡. Page 1 of 1 EMW 12.02 (ppg) 12.49 (ppg) 10.00 (ppg) ~ ~ Printed: 1/2/2003 1 :23:56 PM ') ) Bp.'E~I::>I...ORÄIIØN Qp~.r~t.lC)Î1$........§.~..mrl~.Îj......~~.p.().rt: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Fr()rn~ To HÖûrs Task Code. .NPT Phase 8/19/2002 23:00 - 00:00 1.00 RIGU P 8/20/2002 00:00 - 01 :00 1,00 RIGU P 01 :00 - 09:00 8,00 MOB P 09:00 - 09:30 0.50 PULL P 09:30 - 10:00 0.50 PULL P 10:00-11:00 1,00 PULL P 11:00-12:00 1,00 PULL P 12:00 - 14:00 2.00 PULL P 14:00 - 16:00 2.00 PULL P 16:00 - 17:00 1.00 PULL P 17:00 - 19:30 2.50 PULL P PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 8/21/2002 19:30 - 20:30 1.00 PULL P 20:30 - 21 :00 0.50 PULL P 21 :00 - 22:00 1.00 PULL P 22:00 - 22:30 0.50 PULL P 22:30 - 23:00 0.50 PULL P 23:00 - 00:00 1,00 PULL P 00:00 - 06:30 6.50 PULL P 06:30 - 07:30 1.00 STWHIP P 07:30 - 08:00 0,50 STWHIP P 08:00 - 09:00 1.00 STWHIP P 09:00 - 11 :00 2.00 STWHIP P 11 :00 - 14:00 3.00 STWHIP P 14:00 - 15:00 1.00 STWHIP P 15:00 - 16:00 1.00 STWHIP P 16:00 - 17:30 1.50 STWHIP P 17:30 - 18:30 1.00 STWHIP P 18:30 - 22:00 3.50 STWHIP P 22:00 - 23:00 1.00 STWHIP P 23:00 - 00:00 1.00 STWHIP P 00:00 - 02:30 2.50 STWHIP P 02:30 - 03:00 0.50 STWHIP P 03:00 - 04:30 1.50 STWHIP P 04:30 - 05:00 0.50 STWHIP P 05:00 - 06:00 1.00 STWHIP P 06:00 - 06:30 0.50 STWHIP P 06:30 - 07:30 1.00 STWHIP P 07:30 - 13:00 5.50 STWHIP P 13:00 - 14:00 1.00 STWHIP P 14:00 - 15:00 1.00 STWHIP P WEXIT WEXIT DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 8/22/2002 WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 Il)~sçriþti()n:bf @Ø~rati(jri$ Rig down on H-20 well. Prepare to move to H-02A. RD and prep to move, Move rig, pits and camp to H-02A location, Spot same and RU. All berms, handrails, Pit liners and walkways in place. Accept rig at 0900 hrs. Pre Spud meeting. Install secondary valve on annulus. Pull BPV with lubricator. Dry rod in TWC and test from below to 2000 psi. ND tree. Function test Lock Down Screws. Check hanger threads. Plug control line ports. NU BOP's Change out Top Drive saver sub to 4-1/2" IF, Test BOP's. Test bag ,Upper rams, Blinds, HCR manual valves and floor valves. AOGCC waived witnessing test. Chuck Shieve Pull TWC with lubricator. MU landing joint and pull tubing hanger to floor. Pulled free with 175K UP WT 115k of which 30K is block WT. Circulate Condet pill around 13 bpm @ 450 psi. LD tubing hanger. RU casing equipment. LD 5-1/2" tubing. Continue to LD 5-1/2" tubing and SSSV, Pipe corroded on pin ends, Set test plug and test lower pipe rams and annular preventer. Pull test plug and set wear ring. PJSM PU BHA #1. MU BHA#1 946' RIH to 5638'. Cut and slip drill line. Circulate sweep around. 13 bpm @ 875 psi. POH to BHA. Stand back HWDP and collars. RU wireline and run 9-5/8" Bridge Plug with GR/CCL to 5553'. Set BP and POH, Test casing and bridge plug to 3000 psi. Lost 90 psi in 30 min OK. MU BHA #2 Whipstock and milling assembly. RIH with whipstock to 5,541' WLM. UP WT 170K, DN WT 165K. Circulate one DP volume. RU and RIH with GYRO. Orient. Six checks shots made at 203+-1 degrees OK. POH with wireline. Tag bridge plug @ 5,554' WLM. Set whipstock @ 203 degrees. Change well overto 10.5 mud @ 13-1/2 BPM and 1200 PSI. Mill window 5529' - 5545 and open hole 5545' - 5561'. UP 165K, DN 150K, ROT 155K, RPM 90, TQ 4500 ft-Ibs, 450 GPM, 1180 psi. Circulate Hi Vis Sweep. Work window 450 GPM @ 1100 PSI. Perform FIT Test to 12.0 ppg EMW. (5,529' TVD Mud, Printed: 1/2/2003 1 :24:03 PM ) ) BRE:X.Pl..:OIRATtON Qperâtiø'à$.~tlm,lÎjâ.ry..Røp()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 , Date Fröm'-Tê> . HÖurs Task. Cöde NPT Q~$çri5tiÖq..øfC)þ$ratiÞn~ 8/22/2002 14:00 -15:00 15:00 - 17:00 17:00 - 18:30 18:30 - 20:00 20:00 - 00:00 00:00 - 00:30 00:30 - 01 :00 01 :00 - 02:00 1.00 STWHIP P 2.00 STWHIP P 1,50 STWHIP P 1.50 STWHIP P 4.00 STWHIP P 0.50 STWHIP P 0.50 STWHIP P 1.00 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 8/23/2002 02:00 - 02:30 02:30 - 03:00 03:00 - 05:00 05:00 - 05:30 05:30 - 06:00 06:00 - 07:30 07:30 - 11 :00 0.50 STWHIP P 0.50 STWHIP P 2.00 STWHIP P 0.50 STWHIP P 0.50 STWHIP P 1.50 STWHIP P 3.50 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 11 :00 - 13:00 2,00 STWHIP P WEXIT 13:00 - 00:00 11.00 STWHIP P WEXIT 8/24/2002 00:00 - 10:00 10.00 STWHIP P WEXIT 10:00 - 10:30 0.50 STWHIP P WEXIT 10:30 - 12:00 1.50 STWHIP P WEXIT 12:00 - 12:30 0.50 STWHIP P WEXIT 12:30 -13:00 0.50 STWHIP P WEXIT 13:00 - 13:30 0.50 STWHIP P WEXIT 13:30 - 16:30 3,00 STWHIP P WEXIT 16:30 - 17:30 1.00 STWHIP P WEXIT 17:30 - 23:30 6.00 STWHIP P WEXIT 23:30 - 00:00 0,50 STWHIP P WEXIT 8/25/2002 00:00 - 01 :00 1.00 STWHIP P WEXIT 01 :00 - 01 :30 0.50 STWHIP P WEXIT 01 :30 - 02:00 0.50 STWHIP P WEXIT 02:00 - 02:30 0,50 STWHIP P WEXIT 02:30 - 18:00 15.50 STWHIP P WEXIT 18:00 - 19:00 1,00 STWHIP P WEXIT 19:00 - 19:30 0.50 STWHIP P WEXIT 19:30 - 20:00 0.50 STWHIP P WEXIT 20:00 - 20:30 0.50 STWHIP P WEXIT 20:30 - 00:00 3.50 STWHIP P WEXIT 8/26/2002 00:00 - 06:30 6,50 STWHIP P LNR1 with10.5 ppg mud and 432 PSI surface pressure) POH to BHA. LD window milling BHA. Flush stack and seNice wear ring. MU BHA #3 Directional drilling assembly 1,22 degree motor. MU Directionally drilling assembly. RIH picking up drill pipe. SeNice top drive, While replacing a failed bolt on Iron Roughneck. Continue RIH while picking up drill pipe to 2,801'. Fill pipe and function test the MWD 550 GPM @ 2,620 PSI OK. Continue RIH to 5478' Fill pipe and function test MWD 550 GPM @ 2,374 PSI. OK. Continue to RIH to 5,509', PJSM RU Schlumberger. RIH and orient 208 degrees. POH Run thru window and directionally drill from 5561' to 5638', UP WT 160K, DN WT 155K. 210 SPM,2000 psi off bottom and 2295 psi on bottom. AST= 2.3 Run Gyro survey @ 5,638'. Directionally drill 5,638' to 6,108'. ART 2 HRS, AST 5.4 HRS, UP WT 165K, DN WT 155K, RT WT 160K, Torque 4-5K. Directionally drill form 6, 108 to 6,719'. up wt 165, dn wt 155 rot wt 160 tq OFF 4k on 5-6k ast= 3.6 HRS art = 2.0 HRS. Circulate bottom up. Short trip thru window. Pulled 40K over from 6,237' to 6,430', Service top drive. RIH from 5,478 to 6,624'. Fill pipe Wash from 6,624' to 6,719' Directionally drill from 6,719' to 7,193'. AST= 1.6 hrs ART = 1,9 hrs. Sweep hole high vis pill 585 gpm @ 2850 psi. Directionally drill 7,193 to 7,474'. AST= 1.6 hrs ART= 1.1 hrs. UP 170K, DN WT 155k, ROT WT 160K, TO 6-7K. Increased mud wt from 10.5 ppg to 10.8 ppg. Speep hole with high vis pill 575 gpm @ 3000 psi. Drill from 7,474' to 7,568' Monitor well. Short trip due to high ECD 12.2ppg EMW to 6,710' No Fill. Circulate bottom up 3000 psi @ 14 bpm. ECD post circulation 11.7 ppg EMW, Directionally drill from 7,568' to 8,980'. Control drilling.150 -180 ftlhr. UP WT 175K, DN WT 155k, ROT WT 170K, TO OFF 5K, TO ON 6-7K AST=.3hrs, ART= 12.5hrs. Circulate bottom up. 570 gpm 2950 psi. Monitor well. Static. Wiper trip to 7,568'.ECD 12.1 ppg EMW prior to wiper trip. No Problems RIH PU singles. Fill pipe. Circulate sweep 560 gpm @ 2800 psi. Post circulation ECD 11.7 ppg EMW. Directionally drill from 8,980' to 9,220'. UP WT 195K, DN WT 165K, ROT WT 180K, TO 8-9K. Directionally drill from 9,220' to 9,732'. 115 RPM, WOB 12-20, GPM 550, TO on 11, TO off 9, UP WT 215, DN WT 165, ROT Printed: 1/2/2003 1 :24:03 PM ) , ') BPEXPLGRArtON Qp~.ra~iQns....$....trI~êl.J;Y....R~p()rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 Daté From-"To Hours Task. Code NPT. 8/26/2002 00:00 - 06:30 6,50 STWHIP P LNR1 185, ECD 11.9 ppg 06:30 - 07:00 0,50 STWHIP P LNR1 Change out swap on pump, 07:00 - 12:30 5.50 STWHIP P LNR1 Directionally drill from 10138 to 10185'.ART =7.1 hrs, AST =.8 hrs 115 RPM, WOB 15-20, GPM 525, TO on 12, TO off 9, UP WT 225, DN WT 170, ROT 195, ECD 11.9. 12:30 - 13:30 1,00 STWHIP P LNR1 Change out two swaps on pump #2. 13:30 - 14:00 0.50 STWHIP P LNR1 Circulate 285 GPM 1100 psi. Number one pump failed leak between fluid end and discharge manifold. Trouble shoot during short trip, 14:00 - 17:00 3.00 STWHIP P LNR1 POH to 5,475' 40 - 60 K over pull @ 9,192'-8,977' and 55-60 K overpull @ 8,565' to 8,500'. 17:00 - 18:00 1,00 STWHIP P LNR1 Cut and slip drill line, 18:00 - 18:30 0.50 STWHIP P LNR1 Service top drive. 18:30 - 20:00 1.50 STWHIP P LNR1 RIH NO Problems on trip. 20:00 - 21 :00 1.00 STWHIP P LNR1 Circulate bottom up 559 gpm @ 3190 psi. 21 :00 - 00:00 3.00 STWHIP P LNR1 Directionally drill 1 0, 185 to 10,225. ART = ,2 hrs, AST 1.2 hrs. 110 RPM, WOB 10, GPM 559, TO on 13, TO off 10, UP WT 235, ON WT 165, ROT 190, ECD 11,7 8/27/2002 00:00 - 01 :00 1,00 STWHIP P LNR1 Directionally drill from 10,225' to 10,296'. 110 RPM,558 GPM,UP WT 230, DN WT 175, ROT 190,ECD 11,67 01 :00 - 03:00 2.00 STWHIP N SFAL LNR1 SPILL 15 gallons 3 not contained, SEE IR 297532. Hole in secondary kill hose at interconnect. Repair 2"DEMCO's, 03:00 - 07:00 4,00 STWHIP P LNR1 Directionally drill from 10,296' to 10,496'. 07:00 - 08:00 1.00 STWHIP P LNR1 Circulate bottom up for sample 13 bpm @ 3525 psi. 08:00 - 08:30 0.50 STWHIP P LNR1 Directionally drill from 10,496' to 10,505'.110 RPM,19K WOB, 3000 psi off, 3450 psi on,TO off 10,TO on 11, UP WT 235K, DN WT 175K ROT 195K. 08:30 - 10:00 1.50 STWHIP P LNR1 Circulate around sweep 13 bpm @ 3525 psi. 10:00 - 13:30 3.50 STWHIP P LNR1 Short trip to 5,475' Pulled 45-50K over 9579' - 9,558', 9,525' - 9500', 8530' - 8500' No Problems, 13:30 -14:00 0.50 STWHIP P LNR1 Service top drive, 14:00 - 16:30 2.50 STWHIP P LNR1 RIH to 10,505 TD. 25 - 30 K down drag 9500' - 9580', 16:30 - 18:30 2.00 STWHIP P LNR1 Stage up pumping and tag bottom 10,505 no fill. Sweep hole and circulate bottom up. 540 GPM @ 2900 psi. Reciprocate and rotate pipe. 18:30 - 19:30 1.00 STWHIP P LNR1 Spot liner running pill. Drop ESS. Pump dry job, 19:30 - 00:00 4.50 STWHIP P LNR1 POH from 10,505' to 893', Check shots at 10,236',10,142' & 10,047'.25 - 30K over pull @ 9520,8560',8500', and 6485'. Monitor well at shoe static. 8/28/2002 00:00 - 04:00 4.00 STWHIP P LNR1 LD BHA. Down load MWD data, 04:00 - 04:30 0.50 STWHIP P LNR1 Clear floor. 04:30 - 05:00 0.50 STWHIP P LNR1 PU cementing head and change out pup from 4" to 5". 05:00 - 05:30 0.50 STWHIP P LNR1 Pull wear ring. 05:30 - 06:30 1.00 STWHIP P LNR1 Test variable rams with 7" test joint. 06:30 - 07:00 0.50 STWHIP P LNR1 Install wear ring. 07:00 - 08:30 1.50 STWHIP P LNR1 RU casing equipment. PJSM with crew, 08:30 - 09:00 0.50 STWHIP P LNR1 MU float equipment and check floats. 09:00 - 16:00 7.00 STWHIP P LNR1 PU 5517' of 7" liner to top of window. Fill every5 joints. PU 250K 16:00 -16:30 0.50 STWHIP P LNR1 Circulate one liner volume, 250 GPM, @ 450 PSI, UPWT 150K, DN WT 135K. 16:30 - 17:30 1.00 STWHIP P LNR1 PU 7" liner from 5517' to 6447'. 17:30 - 18:00 0.50 STWHIP P LNR1 MU Baker Flex lock hanger and ZXP liner top packer assembly. Printed: 1/2/2003 1 :24:03 PM ") ) BPEXPLORATION Op~~@tiØll$..$I.I~:O'i~",.R~p:p~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Pagê4>oft9 Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 Date Fröm:~Tc> . Hours Task 8/28/2002 18:00 - 00:00 6.00 STWHIP P LNR1 8/29/2002 2.00 STWHIP P 00:00 - 02:00 LNR1 02:00 - 03:00 1.00 STWHIP N STUC LNR1 03:00 - 03:30 0.50 STWHIP N STUC LNR1 03:30 - 04:00 0.50 STWHIP N STUC LNR1 04:00 - 05:30 1,50 STWHIP N STUC LNR1 05:30 - 06:30 1,00 STWHIP N STUC LNR1 06:30 - 11 :30 5.00 STWHIP P LNR1 11 :30 - 13:00 1.50 STWHIP P LNR1 13:00 - 14:00 1,00 STWHIP P LNR1 14:00 - 15:30 1,50 STWHIP N STUC LNR1 15:30 - 00:00 8.50 STWHIP N STUC LNR1 8/30/2002 00:00 - 00:30 0.50 STWHIP N STUC LNR1 00:30 - 03:30 3,00 STWHIP N STUC LNR1 03:30 - 04:30 1.00 STWHIP N STUC LNR1 04:30 - 05:00 0.50 STWHIP N STUC LNR1 05:00 - 06:00 1.00 STWHIP N STUC LNR1 06:00 - 07:00 1,00 STWHIP N STUC LNR1 07:00 - 07:30 0.50 STWHIP N STUC LNR1 07:30 - 11 :30 4.00 STWHIP N STUC LNR1 11 :30 - 12:00 0.50 STWHIP N STUC LNR1 12:00 - 13:00 1.00 STWHIP N STUC LNR1 13:00 - 15:30 2.50 STWHIP N STUC LNR1 15:30 - 16:00 0.50 STWHIP N STUC LNR1 16:00 - 17:00 1.00 STWHIP N STUC LNR1 17:00 - 18:30 1.50 STWHIP N STUC LNR1 18:30 - 19:00 0.50 STWHIP N STUC LNR1 19:00 - 20:00 1.00 STWHIP N STUC LNR1 20:00 - 20:30 0.50 STWHIP N STUC LNR1 20:30 - 22:30 2.00 STWHIP N STUC LNR1 RIH on DP from 6483' to 9705', Working liner down from 9500', Working pipe to bottom. Fill pipe at 7640' and 9420'. Picking up to breakover and slacking off. Breakover values varing between 275 to 350K. Pipe moving in the range of 6" to 3' per cycle. Steady but slow progress. Continue to work liner to 9718, Breakover values trending down from 350K to 240K, Progressing 6" to 3' per cycle. Progress is slow but steady. Worked pipe to 9718 picked up lost 18'. Worked back to 9712, Tube locked between 9712' to 9696'. Worked pipe to 460K No Go. Contacted Phil Smith agreed to attempt breaking circulation limiting pressure to 1000 psi. Well presurred to 1000 psi in 49 strokes. Calculation indicate the shoe may be plugged. Baker recommended not pressuring over 2000 psi, Liner hanger is pinned for 3100 psi. OK'd with Phil and pressured to 2000 psi. Could not break circulation. Hold 220 K over while waiting on orders. No change. Release from liner hanger with 18 turns to the right. POH and lay down running tool. Clear floor and pull wear ring. Test BOP. Witnessing waived by Lou Grimldi AOGCC. Install wear ring. Inspect and adjust break. Service top drive Cut drill line. PU drill collars while waiting on Schlumberger Eline. PU Halliburton EZSV bridge plug, Log into position and set at 5913'. POH and PU chemical cutter. RIH and cut 7" casing at 5893'. POH Good indication of cut. RD Schlumberger chemical cutter. PU and MU fishing BHA. RIH to 3237' 93K UP 90K DN, Engage fish at 3243'. Set 20K down. PU to 250K. Come free. 160K hook load. POH standing back 5" drill pipe. LD fishing BHA. Rig Up Casing equipment. LD 65 joints of 7" casing and cutoff 3.51'. Rig down casing equipment. MU cementing BHA. RIH to 5825', Wash last stand down at 1 bbl/min @ 250 psi. Tag EZSV at 5911. Set down 5K. Circulate bottom up 12 bbl/min @ 860 psi. Displace out 10.8 ppg mud with 10.5 LSND mud 12 bbllmin @ 900 psi. Pump 5 bbl 2% KCL, Test lines to 2000 psi. Pump 10 bbl 2% KCL, 21 bb 17# cement, 3 bbl 2% KCL, and displace with 52.5 bbl mud. Pull out of balanced plug SLOW! from 5900' to 5503'. Top of window is 5529'. Reverse circulate 2 bbllmin 390. No cement to surface. Lost 7bbl. Pump dry job and blow down surface equipment. POH. Printed: 1/2/2003 1 :24:03 PM ') ) BPEÞ<PLORATION Ç)p~fÇlti()tJ~.......~t;lm'I11C1~..'..ReÞØrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 gate Fro01"'.~."'o Hours Task' COdè NPT Phase DésôriptiÖn.öfOperatiöns 8/30/2002 22:30 - 23:00 0.50 STWHIP N STUC LNR1 LD cementing BHA. 23:00 - 00:00 1.00 STWHIP N STUC LNR1 Clear floor. 8/31/2002 00:00 - 03:30 3.50 STKOH N STUC LNR1 PU BHA#5. Surface check MWD at 88'. 03:30 - 05:00 1,50 STKOH N STUC LNR1 RIH with 5" DP. from 922' to 5411'. PU 9 additional joints. Fill pipe @ 2200' and 5400'. 05:00 - 05:30 0.50 STKOH N STUC LNR1 Service top drive. 05:30 - 07:30 2.00 STKOH N STUC LNR1 Wait on cement. 07:30 - 08:00 0,50 STKOH N STUC LNR1 Perform FIT test to 12.5 ppg EMW with 582 psi. 08:00 - 08:30 0,50 STKOH N STUC LNR1 RIH from 5411' to 5437' tagging cement. Taking from 5 - 10 K down weight. 08:30 - 09:30 1.00STKOH N STUC LNR1 Wash soft cement from 5437' to 5525'. Work thru window 5529' to 5545' wiith out the pump taking from 15 to 20 K down. POH to 5411', 09:30 - 10:00 0.50 STKOH N STUC LNR1 CBU @ 11 bbll min 2380 psi. 10:00 - 11 :00 1.00 STKOH N STUC LNR1 Wash cement from 5537' to 5638'. @ 11 bbl / min 2380 psi. Cement still soft.( contaminated) 11 :00 - 00:00 13,00 STKOH N STUC LNR1 Drill from 5638' to 5664', Cement firming up at 5664'. UP WT 165K, DN WT 150K, ROT 155K. Time drill from 5664' to 5697' ART = .2 hrs and AST = 7.2 hrs. UP WT 165K, DN WT 150K, ROT 155K, TO 4. 9/1/2002 00:00 - 13:30 13.50 STKOH N STUC LNR1 Directionally driIl8.5"hole from 5793'. to 6175'. UP WT 170, DN WT 150 ROT 160, TO off 5 TO on 6-8, ART=.6 AST= 8.5 hrs, Cement contamination driving the PH to 10. Treating mud to condition for PH. Start adding lubricants after verification with lab test that there was no adverse reaction due to the elevated PH. 13:30 - 14:30 1,00 STKOH N STUC LNR1 CBU 13 bbl / min @ 3000 psi. 14:30 - 15:30 1.00 STKOH N STUC LNR1 Short trip from 6175' to 5506'. Orient 40 right @ 5630 to enter the new sidetrack. 15:30 - 17:00 1,50 STKOH N STUC LNR1 Directionally drill 6175' to 6208', ART = 0, AST = =1 hr. WOB 5k, pressure on bottom 2900 psi, pressure off 2570 psi, @576 gpm, Bit drilling off 5' then progressively lost weight. After reaming down we were able to drill ahead an additional 5' before weight transfer problem return. Acts like bit is under gage and hanging up on the near bit stabilizer. Back reaming is wiping out the dogleg from the slide. Getting behind on the curve. POH for a bit. 17:00 - 17:30 0.50 STKOH N STUC LNR1 Pump dry job, 17:30 - 20:00 2.50 STKOH N STUC LNR1 POH to BHA. 20:00 - 21 :30 1,50 STKOH N STUC LNR1 Stand back HWDP and collars. 21 :30 - 23:30 2.00 STKOH N STUC LNR1 LD mud motor, near bit stab, and bit. Bit and near bit in full gage. Bit has two chipped teeth on gage row. Replace near bit with 1/16th under gage stabilizer. UP new motor and bit, Orient Motor and MWD. 23:30 - 00:00 0.50 STKOH N STUC LNR1 Function test MWD. 9/2/2002 00:00 - 02:00 2.00 STKOH N STUC LNR1 PU and RIH with BHA# 6 to 5506'. Filling pipe at 2,500' and 5,506'. 02:00 - 03:00 1.00 STKOH N STUC LNR1 Cut and slip 76' of drill line. 03:00 - 03:30 0.50 STKOH N STUC LNR1 Service Top Drive. 03:30 - 04:00 0.50 STKOH N STUC LNR1 RIH from 5506'. No Trouble. At Top of window orient 62R @ 5602'. KOP for new hole 5660'. No Problem, RIH to 6208'. 04:00 - 21 :30 17.50 STKOH N STUC LNR1 Directionally drill from 6208' to 7585'. Top of HRZ. AST = 5.2 hours, ART = 6.2 UP WT 180, DN WT 155, ROT 170 ( pre Printed: 1/2/2003 1 :24:03 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 Øaté From>+To Hours Task Code ...NPT Phase [)~~crip~i<:>n...qfQp~r~tiqns 9/2/2002 04:00 - 21 :30 17.50 STKOH N STUC LNR1 HRZ drilling perameters @ 7602', RPM 105, WOB 20,550 gpm, off bottom pressure 3225 psi, on bottom pressure 3500 psi, TO off 6, TO on 7-8, ROP 150 ftlhr, ECD 12.2 ppg, 21 :30 - 22:30 1,00 STKOH N STUC LNR1 Circulate high vis sweep 13bbl / min @ 3150 psi. 22:30 - 00:00 1,50 STKOH N STUC LNR1 Short trip to window, Pulled 20k over at 6240'. 9/3/2002 00:00 - 00:30 0,50 STKOH N STUC LNR1 Service Top Drive. 00:30 - 01 :30 1.00 STKOH N STUC LNR1 RIH to 7,585'. (No problems passing thru window and no orientation needed to re-enter sidetracked wellbore). 01 :30 - 12:00 10.50 STKOH N STUC LNR1 Drill 8-1/2" hole with 1.5 deg motor from 7,585' to 8,447'. ART= 6.6, AST=0.7 hrs. UWT=195K, DWT=150K, ROT=175K, Torque off = 7.5K ft-Ib, on = 8,OK. 12:00 - 23:00 11,00 STKOH N STUC LNR1 Drill 8-1/2" hole from 8,447' to 9,338'. ART= 7.2, AST= 0.3 hrs. UWT=200K, DWT=160K, ROT=180K, Torque off = 9K ft-Ib, on = 11K. 23:00 - 00:00 1.00 STKOH N STUC LNR1 Circ HI-Vis sweep at 13 BPM and 3,000 psi. Pump slug, flow check well. 9/4/2002 00:00 - 01 :30 1,50 STKOH N STUC LNR1 Short trip to 7,450' with no excess drag. RIH to TD with no excess down drag. Orient toolface. 01 :30 - 12:00 10.50 STKOH N STUC LNR1 Drill 8-1/2" hole with 1.5 deg motor from 9,338' to 10,100'. ART= 3.4, AST= 3.4 hrs. UWT=225K, DWT=170K, ROT=190K, Torque off = 11 K ft-Ib, on = 13K. 12:00 - 22:30 10,50 STKOH N STUC LNR1 Drill from 10,100' to 10,861', ART= 4.8, AST= 2.0 hrs. UWT=245K, DWT=170K, ROT=1905, Torque off = 11 K ft-Ib, on = 14K. 22:30 - 0.00 STKOH N STUC LNR1 Sweep hole clean with HI-Vis sweep at 13 BPM and 3,130 psi. Pump slug and flowcheck well. 9/5/2002 00:00 - 03:00 3.00 STKOH N STUC LNR1 Short trip. Up drag of 15-30K for the first 4 stands off bottom (TD to 10,309' = azimuth change at the tail of this hole section). Pull35K over at 8,729',8,691', wipe thru, continue POOH to inside 9-5/8" csg without problems, 03:00 - 05:00 2.00 STKOH N STUC LNR1 Flow check well. Cut and slip 73' of drill line. Service TD, and Crown. 05:00 - 07:30 2.50 STKOH N STUC LNR1 RIH. Re-enter side tracked hole without problems, RIH, with 1 0-15K average drag. 07:30 - 09:00 1.50 STKOH N STUC LNR1 Circ Btms Up, staging rate up slowly to 12 BPM and 3,400 psi. Rotate and wash last stand to bottom. Rotate and reciprocate pipe while pumping Hi-Vis sweep around. Heavy returns of splintered pieces of shale. 09:00 - 12:00 3.00 STKOH N STUC LNR1 Circulate well at 12 BPM and 2,940 psi, while increasing mud weight from 11.0 - 11.5 ppg. Reciprocate and rotate pipe throughout. UWT = 265K, DWT = 165K, Torque off = 18K ft-Ib. 12:00 - 16:30 4.50 STKOH N STUC LNR1 Continue circulating and weighting up to 11.8 ppg mud weight. Shale cuttings size and volumes decreasing. Pump slug. 16:30 - 21 :00 4.50 STKOH N STUC LNR1 POOH to inside 9-5/8" casing at 5,472' with 35K overpull at 10,290', 20K overpull at 8,320', and 7,851'. No losses on trip out. 21 :00 - 21 :30 0,50 STKOH N STUC LNR1 Grease torque tube track for Top Drive. 21 :30 - 00:00 2.50 STKOH N STUC LNR1 RIH to 10,485 with average drag of 5-1 OK Ibs from the window at 5,545' to the top of the HRZ at 7,528'. Continue RIH with 15-20K down drag. No losses while tripping in the hole. 9/6/2002 00:00 - 00:30 0.50 STKOH N STUC LNR1 Wash to bottom. No fill on bottom. 00:30 - 02:00 1.50 STKOH N STUC LNR1 Circulate bottoms up at 400 GPM. Circulate 341 of 518 bbls to Printed: 1/2/2003 1:24:03 PM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 19-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Bate Frôm~TÓ:Hôurs Task. Cöde,NPT Phase 9/6/2002 00:30 - 02:00 1.50 STKOH N STUC LNR1 02:00 - 03:30 1,50 STKOH N STUC LNR1 03:30 - 07:30 4.00 STKOH N STUC LNR1 07:30 - 09:00 1.50 STKOH N STUC LNR1 09:00 - 14:00 14:00 - 15:30 15:30 - 16:30 16:30 - 18:30 5.00 STKOH N 1,50 STKOH N 1.00 STKOH N 2,00 STKOH N STUC LNR1 STUC LNR1 STUC LNR1 STUC LNR1 18:30 - 19:30 1.00 STKOH N STUC LNR1 19:30 - 20:30 1.00 STKOH N STUC LNR1 20:30 - 22:30 2.00 STKOH N STUC LNR1 22:30 - 00:00 1,50 STKOH N STUC LNR1 9/7/2002 00:00 - 02:30 2.50 STKOH N STUC LNR1 02:30 - 04:30 2.00 STKOH N STUC LNR1 04:30 - 05:00 0,50 STKOH N STUC LNR1 05:00 - 05:30 0.50 STKOH N STUC LNR1 05:30 - 06:30 1.00 STKOH N STUC LNR1 06:30 - 07:30 1.00 STKOH N STUC LNR1 07:30 - 10:00 2.50 STKOH N STUC LNR1 10:00 - 11 :00 1.00 STKOH N STUC LNR1 Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 lPe$Þriþ~i(;)n.. cjfC)p~r(;3tiÔH$ CBU with minor losses. Flow returns decreased to 50%, and losses = 4 BPM while pumping. Shut down pumps (total lost = 49 bbl). Static losses without pumping = 1 BPM. Losses decreased to 1 bbl per 5 minutes. Mix 50 bbl LCM pill with 20 Ib/bbl of Barofibre and 10 Ib/bbl of Liquid Casing, Pump at 165 GPM and 500 psi (ECD = 12.4 ppg). Lost total returns at 1,200 of 3,150 strokes of displacement, shut down pumps. (171 bbls lost). Continue pumping at 3.5 GPM with loss rate at 2-4 BPM. Spot LCM pill atTD. POOH 10,861' to 10,390' with 35K over pull. Continue POOH to 5,506' with UWT = 260-270K (15-25K overpull) , decreasing to 1 0-20K over pull, and losses decreasing to 1 bbl per 5 stands pulled. NOTE: Total losses since circulating on bottom = 497 bbl. Monitor well. Loss rate while static = 0 bbl. Circulate at 3 BPM and 330 psi with losses = 1 bbl/min. Spot 35 bbl LCM pill at 40 Ib/bbl Barofibre and Liquid Casing. No returns while spotting LCM. POOH. Download MWD data, LD BHA. LD BHA, clean and clear rig floor. Pull Wear Bushing, set test plug. Test BOPE 250/3,500 psi for 5/5 min: Annular Preventer, Top Pipe Ram wI 4-1/2" x 7" Variable Rams, Blind Ram, Mud Cross, Lower Pipe Rams wI 2-7/8" x 5" Variable Rams, Lower Mud Cross. Tested Blind Rams, Choke Manifold, HCR, Kill and Choke lines, IBOP. Testing witnessed by Chuck Scheve of the AOGCC. Pull test plug and set Wear Bushing, PU and RIH with cleanout BHA. Note: lost 14 bbl of mud during 6 hours of the hole staying static. RIH to above the window. Attempt to circulate. Had 5% returns, shut down pumps. Cut and slip 69' of drill line, Service Top Drive. RIH to 10,570' and hit bridge. Ream to 10,600' at 85 RPM, 2 BPM, ROT 190K, Torque 10-11 K ft-Ib. PU and pull 1 OOK over and jar free. Back ream to 10,510'. Reached the torque limiter on two occasions. Work through tight spot with 25% returns, adding LCM to system, Ream final 3 stands to bottom at 85 RPM, 120 GPM, 500 psi, 10-11 K ft-Ib, zero returns. No fill on bottom. Total losses while RIH = 87 bbl. Pump and spot 50 bbl pill on bottom with 30 Ib/bbl Steal Seal, 20 Ib/bbl Barofibre, 20 Ib/bbl medium Baroseal. No returns while displacing. POOH to 9,752' with no overpull, and no problems. Spot 50 bbl pill at 3 BPM and 390 PSI containing 30 Ib/bbl Steal Seal, 20 Ib/bbl Barofibre, 20 Ib/bbl medium Baroseal. No returns while displacing, POOH to 5,492" with no overpull, and no problems. Spot 50 bbl pill at 3 BPM and 270 PSI containing 30 Ib/bbl Steal Seal, 20 Ib/bbl Barofibre, 20 Ib/bbl medium Baroseal. Printed: 1/2/2003 1 :24:03 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 Hours' . Task. Cödè ..NPT .Phase j)e$Þtiþtipn...qf Pþèrätiör1s 9/7/2002 10:00 - 11 :00 1.00 STKOH N STUC LNR1 Lost 26 of 96 bbls while displacing. 11 :00 - 13:30 2.50 STKOH N STUC LNR1 POOH to BHA. 13:30 - 14:30 1.00 STKOH N STUC LNR1 Lay down BHA. 14:30 -15:30 1,00 STKOH N STUC LNR1 Clear and clean rig floor. 15:30 - 16:30 1,00 CASE N STUC LNR1 RU casing handling tools. 16:30 - 00:00 7.50 CASE N STUC LNR1 MU and thread lock float joints. Straight blade cents on shoe joints only. RIH with 118 jts of 7", 26 Ib/ft, L-80, BTC-M casing. Lost 45 bbls while RIH, Total losses for 24 hours = 653 bbls. 9/8/2002 00:00 - 01 :00 1.00 CASE N STUC LNR1 Fill casing above the window and circulate at 1 BPM, 240 psi. UWT= 145K, DWT= 135K. Lost 1 bbl per 7 min while circulating. 01 :00 - 01 :30 0.50 CASE N STUC LNR1 Pass through window and enter side tracked hole without problems, 01 :30 - 06:30 5.00 CASE N STUC LNR1 Continue running 7", 26#/ft, L-80, BTC-M csg to 9,900' without problems. Lost 100 bbl while in open hole, Work last 4 stands to bottom with 40-50K of drag, Lost 150 bbl while TIH. 06:30 - 08:30 2,00 CEMT P LNR1 Circulate and condition mud at 5 BPM and 900 psi, with 25% returns, 7 BPM and 1,200 psi - zero returns. Hold PJSM for cementing. 08:30 - 12:00 3.50 CEMT P LNR1 Pump 5 bbl of water and test surface lines to 4,500 psi. Pump 36.5 bbl of 12.6 ppg Alpha Spacer, 35 bbl (170 sx) of 15.8 ppg, "G" cement + additives at 4 BPM, displace with the calculated volume of 330 bbl of seawater at 7 BPM, and plug did not bump. Consulted with engineering staff. Overdisplaced with. 75 bbl, bumped plug and pressured up casing string to 4,500 psi setting the Flex-Lok liner hanger. Slight returns while pumping 1 displacing cement. Bleed off pressure, check floats - okay, Release from liner hanger, keeping positive pressure on the drillstring. CIP: 11 :30 hrs. 12:00 - 12:30 0,50 CEMT P LNR1 Pump 100 bbl of seawater at 10 BPM and 700 psi. Set down 60K with indications of packer setting. 12:30 - 14:00 1.50 CEMT P LNR1 Displace wellbore to clean seawater at 12 BPM and 820 psi. No fluid losses while pumping or when well was static. 14:00 - 14:30 0.50 CEMT P LNR1 LD cement head. 14:30 - 17:30 3,00 CASE P LNR1 POOH laying down 125 jts of 5" DP. LD liner running tool. 17:30 -18:30 1.00 CASE P LNR1 RIH with drillpipe in the de rick to 3,800'. 18:30 - 20:30 2.00 CASE P LNR1 POOH laying down 5/1 DP. 20:30 - 23:00 2.50 CASE P LNR1 Cut and slip 80' of drill line. Service Top Drive. Note: Total Losses for 24 hrs = 617 bbl. Zero losses after cementing casing. 9/9/2002 00:00 - 01 :30 1.50 CASE P LNR1 Continue LD 5/1 DP. Clear and clean rig floor. Pull Wear Ring, 01 :30 - 02:30 1.00 CASE P LNR1 Pressure test 7/1 x 9-5/8/1 casing to 3,000 psi. Pressure dropped 1,500 psi in 12 minutes. Bleed off test pressure. 02:30 - 04:30 2.00 CASE P LNR1 Change out top RAMS to 3-1/2/1 x 6/1 Variables. Pressure test to 250/3,500 psi for 5/5 minutes. Install Wear Ring. 04:30 - 06:00 1.50 CASE N DFAL LNR1 PU packoff, rotating sub and DCs. 06:00 - 08:00 2.00 CASE N DFAL LNR1 MU Seal Assembly, and rotating dog sub, and HWDP, 08:00 - 10:00 2.00 CASE N DFAL LNR1 RIH to 3,980' (93 jts picked up). Printed: 1/2/2003 1 :24:03 PM ') ') Bp.., EXPLIDRAIIQN Ø:Þêt~ti()Îjls.: ..$tJ~'(Î)iJ¡IiJ.geþ()tt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Tåsk Codë .'NPT Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 Dë$çription qfØp~r~tic>ri~ 9/9/2002 10:00 - 14:00 4.00 CASE N DFAL LNR1 14:00 - 15:00 1.00 CASE N DFAL LNR1 15:00 - 16:30 1.50 CASE N DFAL LNR1 16:30 - 17:30 1.00 CASE N DFAL LNR1 17:30-18:30 1.00 CASE N DFAL LNR1 18:30 - 21 :00 2,50 CASE N DFAL LNR1 21 :00 - 23:00 2.00 CASE N DFAL LNR1 23:00 - 00:00 1.00 CASE N DFAL LNR1 9/10/2002 00:00 - 01 :00 1.00 CASE N DFAL LNR1 01 :00 - 01 :30 0.50 RUNCOIVP COMP 01 :30 - 04:00 2.50 RUNCOIVP COMP 04:00 - 05:30 1,50 RUNCOIVP CaMP 05:30 - 06:00 0.50 RUNCOIVP COMP 06:00 - 07:00 1.00 RUNCOIVP COMP 07:00 - 08:30 1.50 RUNCOIVP CaMP 08:30 - 10:00 1.50 RUNCOIVP CaMP 10:00 - 12:00 2.00 RUNCOIVP CaMP 12:00 - 13:00 1.00 RUNCOIVP COMP 13:00 - 14:30 1.50 RUNCOIVP CaMP 14:30 -17:00 2.50 RUNCOIVP CaMP 12/16/2002 15:00 - 00:00 9.00 MOB P PRE Sting seal assembly into tieback receptical and test DP and 7" csg to 1,100 psi-ok. PU and set down 60K on packer while rotating. PU and test casing to 3,000 psi. Bled down 1,000 psi in 10 minutes. Release pressure, and set down 70K on packer and rotate, Retest casing to 3,000 psi with 300 psi lost in 15 minutes. Set down 70K on pkr, rotated, and pressured the backside with 700 psi, resulting in an effective down weight of 100K. Released pressure and PU. Retested csg to 3,000 psi, with 300 psi of pressure lost in 15 minutes. Bled off pressure. Stabbed seal assembly into receptical and tested 9-5/8" csg and liner top pkr to 3,000 with no bleed off. Bled off pressure. PU above seals and tested 7" liner x 9-5/8" csg to 3,000 psi with 300 psi bleed off in 15 min. POOH, Handle BHA. LD Rotating Dog tool. PU 7" RTTS packer and BHA. RIH and set RTTS packer below the liner hanger and liner top pkr, at 4,012' Test 9-5/8" csg and liner top packer to 3,000 psi for 30 min - ok. Release presuure. Pressure up DP and pressure test 7" liner below the packer to 3,000 psi for 30 minutes - ok, Release DP pressure, release RTTS pkr, blow down surface equipment. POOH laying down DP. LD BHA. Continue to LD BHA. Pull Wear Ring. RU handling equipment. PJSM. Run 48 jts of 4-1/2", 12.6#/ft, L-80, NSCT, Class B tbg. Land tbg, Land tbg hanger and run in LDS. Install TWC and test to 2,000 psi from below. Nipple down BOPE. Nipple up tree and adaptor flange and test to 5,000 psi. RU lubricator, pull TWC, rig down lubricator. RU Hot Oil Services, test lines to 2,500 psi. Pump 140 bbl of diesel freeze protect at 2,5 BPM and 800 psi. U-tube same. Instal BPV and test from below to 2,000 psi for 10 min. Rig down lines. Secure tree, remove secondary annulus valve, Remove Beaver Slide, Stairs and Landing, due to width limitations with A-Pad facilities, RELEASE RIG @ 17:00 HS - Sep 9-02 Prepare rig for move to H-Pad - Blow down rig pit complex and stage on DS-18 - Dress out mast and layover same - Move sub base off well - Hold pre-job safety meeting with all personal regarding move to H-Pad - Clean up location and preform post pad inspection. *NOTE* Sub Base left DS-18 headed for H-Pad (23 Miles) at 21 :30 Hours 12-16-2002 Rig released from DS 18-05A for move to H-Pad at 15:00 Hours on 12-16-2002 Printed: 1/2/2003 1 :24:03 PM ) ) Bp. EXPLORATION Øperatio.n~. ...S..~I1¡II"IJ~.~....R~pørt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Hours Task Côdê NPT Phase' 12/17/2002 00:00 - 07:00 7.00 MOB P PRE 07:00 - 09:00 2,00 MOB P PRE 09:00 - 12:00 3,00 MOB P PRE 12:00 - 17:00 5,00 RIGU P PRE 17:00 - 19:00 2,00 RIGU P PRE 19:00 - 19:30 0.50 BOPSUR P DECaMP 19:30 - 20:00 0,50 WHSUR P DECaMP 20:00 - 21 :00 1.00 WHSUR P DECaMP 21 :00 - 23:30 2.50 CLEAN P DECaMP 23:30 - 00:00 0.50 WHSUR P DECaMP 12/18/2002 00:00 - 01 :30 1.50 WHSUR P DECaMP 01 :30 - 03:30 2.00 BOPSUR P DECaMP 03:30 - 04:00 0.50 BOPSUR P DECaMP 04:00 - 08:00 4.00 BOPSUR P DECaMP 08:00 - 08:30 0.50 BOPSUR P DECaMP 08:30 - 10:00 1.50 WHSUR P DECaMP 10:00 - 11 :00 1.00 WHSUR P DECaMP 11 :00 - 11 :30 0.50 PULL P DECaMP 11 :30 - 14:00 2.50 PULL P DECaMP Pager 1.0ôf 19 Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 Pe$çriþ1ion...øfQþ$ratiqqs Move Sub Base To H-Pad At 05:00 Hours Turning Onto Spine Road At Twin Towers - Load Out Misc. Rig Equipment Loads On Peak Trailors For Transport - Perform Pre-Pad Inspection On H-Pad With Drill Site Operator Wait On Mat Placement As Per Engineering Specs At GC-2 Flow Lines Move Sub Base From GC-2 To H-Pad - Lay Herculite And Spot Sub Base Hold Pre-Job Safety Meeting - Raise Mast And Rig Up Rig Floor - Remove Bridal Lines - Pick Up And Rig Up Can-Rig Top Drive - Move Mud Pits, Truck Shop, And Camp From DS 18 To H Pad And Spot Same - Build Berm And Spot Cuttings Tank - Rig Up Utility Lines To Pits - Spot Mud Mans Unit, Gelogist Shack And Power Up Same Circulate Steam And Water Around - Test Mud Line To 3,500 Psi. - Install Geronimo Line - Prepare Mud Tanks And Pumps For Fluid Install Secondary Annulus Valve And Verify That Pressure On Tubing And Casing At 0 Psi. *NOTE* Rig Accepted For Well Work On H-02A At 17:00 Hours (Backed Up 2 Hours From 19:00 Hours Due To Mat Laying At GC-2 Flow Lines) Hold Pre-Spud Meeting With All Personal - Review Rig Acceptance Check List Rig Up DSM Lubricator And Pull BPV Rig Up Circulating Lines To Tree And Test To 3500 Psi. - Circulate Diesel Freeze Protect From Well With 8.5 PPG Sea Water - Verify That Well Is Dead Dry Rod TWC Valve And Test From Below At 1000 Psi. - Blow Down Surface Equipment Nipple Down 13 5/8" 5M Tree Adaptor And 4 1/8" Cameron Tree Nipple Up BOP And Related Equipment Install Test Joint And Rig Up Testing Equipment - Fill BOP And Choke With Water Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector John Spaulding - Test Annular, Upper Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Test Pit PVT System And Perform Accumulator Test Rig Down BOP Testing Equipment - Lay Down Test Joint- Clear Floor Rig Up DSM Lubricator And Pull TWC Valve - Lay Down Lubricator Pick Up Landing Joint And Make Up Into Hanger - Back Out Lock Down Studs - Pull Hanger To Rig Floor - Lay Down Landing Joint And Cameron Hanger Rig Up Casing Tools And Equipment - Bring Thread Protectors To Rig Floor Lay Down 48 Joints Of 4 1/2" Tubing Printed: 1/2/2003 1 :24:03 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Oatê Fröh') >.;; To . HOUrs Task Gode NPT Phase 12/18/2002 14:00 - 14:30 0,50 PULL P DECOMP 14:30 - 15:30 1,00 BOPSURP DECOMP 15:30 - 16:00 0.50 BOPSURP DECOMP 16:00 - 16:30 0.50 CASE P PROD1 16:30 - 17:00 0.50 DRILL P PROD1 17:00 - 20:00 3.00 DRILL P PROD1 20:00 - 21 :00 1.00 DRILL P PROD1 21 :00 - 22:00 1.00 DRILL P PROD1 22:00 - 00:00 2.00 DRILL P PROD1 12/19/2002 00:00 - 01 :00 1.00 DRILL P PROD1 01 :00 - 09:00 8.00 DRILL P PROD1 09:00 - 10:00 1,00 DRILL P PROD1 10:00-11:00 1,00 DRILL P PROD1 11 :00 - 11 :30 0.50 DRILL P PROD1 11 :30 - 12:30 1.00 DRILL P PROD1 12:30 - 13:00 0.50 DRILL P PROD1 13:00 - 13:30 0.50 DRILL P PROD1 13:30 - 00:00 10.50 DRILL P PROD1 Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 D~$QriþtíbI1Þf;Qf)eratiqns . Rig Down Casing Tools And Equipment - Clear Rig Floor Install Test Joint - Rig Up And Test Lower Pipe Rams At 250 Psi. Low And 3,500 Psi. High Rig Down BOP Testing Equipment - Install Short Bowl Protector - Lay Down Test Joint - Clear Floor Test Casing To 3,000 Psi. For 10 Minutes (Test Good) - Blow Down Surface Equipment Service Can-Rig Top Drive And Traveling Blocks Pick Up 90 Joints Of 4" Drill Pipe POH Standing Back 30 Stands 4" Drill Pipe In Mast - Will Be Used For Drilling This Hole Section Clear Rig Floor - Hold Pre Job Safety Meeting - Bring BHA To Rig Floor And Finish Loading Pipe Shed Pick Up 6 1/8" Drilling Assembly BHA NO.8 - Make Up Security PDC Bit To Motor - Pick Up Stab MWD / LWD Tools And Orient - Initialize MWD Tools Continue To Pick Up BHA NO.8 - Hold Pre-Job Safety Meeting And Load Nukes - RIH To 420' And Surface Test At 275 GPM With 1050 Psi. Pick Up Singles Of 4" Drill Pipe And RIH Install Can-Rig Top Drive Blower Hose - Wash Down From 10,592' To 10,760' Tag Cement - Drill Cement From 10,760' To Top Of Landing Collar At 10,770' Drill Cement And Shoe Track From 10,770' To 10,846' - 280 GPM With 1900 Psi. Displace Well Bore To 8,6 PPG Flo-Pro Mud System While Rotating And Reciprocating Drill String Drill Remainder Of Shoe Track 10,846' To 10,854' - Wash And Ream Rat Hole And Drill New 61/8" Hole To 10,881' Circulate Bottoms Up Verify 8,5PPG Mud Weight In And Out Hold Pre-Job Safety Meeting - Pull Bit In 7" Casing Shoe Closed Pipe Rams And Performed FIT. Volume Pmp'd Pressure .3 BBL 120 psi .5 BBL 240 psi .7 BBL 370 psi 1,0 BBL 500 psi 1.2 BBL 630 psi 1.3 BBL 700 psi Held Test F/10 minutes wI 60 Psi. Pressure Loss. MW 8.5 ppg, Csg Shoe TVD 8,727' Pressure 700 psi = 10,04 PPG. EMW. Bleed Pressure To 0 Psi. - Open Pipe Rams Obtain Slow Pump Rates With New Mud - Directional Drill Ahead From 10,881'To 11,153'-WeightOn Bit5KTo 19K- With Pump Rate At 129 Strokes Or 316 GPM - Off Bottom Pump Pressure At 1950 Psi. & On Bottom Pump Pressure At 2250 Psi. - Top Drive RPM At 0 To 30 - Off Bottom Torque At 6K - String Rotating Weight At 150K - With Pump On Drag Up At 165K And Drag Down At 145K Printed: 1/2/2003 1 :24:03 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 [Qate Frbm- To 'Houts Task. Code NPT Phase [)é$çNptiørt'..þfQpØrptiqns 12/19/2002 13:30 - 00:00 10.50 DRILL P PROD1 Lithology Encountered: 10860' To 10960' - (Sag River Sand) - Very Poor Samples Due To Cement Contaimination - Predominately Fine Grained Clean Sand - Drilled This Section At 50 FPH Rap While Sliding For Directional Turn 10960 To 11080 - (Shublik) - Predominately Lime Stone Chalking To Dense Locally Finely Crystalline, Mottled. Clean To Very Argillaceous - Overall Slow Rap 10 To 20 FPH While Sliding, Occasionally Higher In Cleaner Shale Interbeads - Shublik "c" Becoming More Finely Crystalline Yielding Slightly Higher RaP'S While Sliding 11800' To 11153' At Midnight - (Sadlerochit Zone 4B) - Clean Disaggreated Fine To Medium Sand - Upper Lobe Appears Productive - Evidence Of Salt Water Influx In Some Lower Sands - Pronounced Drilling Break At TSAD Rapid Rap In Sands - Thin Shales Indicated By Slower Rap Intervals Formation Top TVD TVDSS SGR 10852 8722 8649 TSHA 10904 8750 8677 TSHB 10977 8788 8715 TSHC 11029 8814 8741 TSAD 11 080 8835+1- 8763 12/20/2002 00:00 - 19:00 19.00 DRILL P PROD1 Actual Rotating Time At .45 Hours (20 Feet) Actual Slide Time At 7.45 Hours (272 Feet) Directional Drill Ahead From 11,153' To 11,969' - Weight On Bit 5K To 19K - With Pump Rate At 129 Strokes Or 316 GPM- Off Bottom Pump Pressure At 1950 Psi. & On Bottom Pump Pressure At 2250 Psi. - Top Drive RPM At 0 To 30 - Off Bottom Torque At 6K - String Rotating Weight At 150K - With Pump On Drag Up At 165K And Drag Down At 145K Lithology Summary: 11450 Zone 4B Predominantly Sand With Thin Shale Interbeds. Sands Are Fine To Medium Grained, Clean, Disaggregated, With Overall Poor Shows Of Oil. Section Appears Productive 11200-350, Water Swept 11350-11450. High RaP's While Sliding For Directional Build. 11450-11600 Zone 4B Shaley Siltstone, Light To Medium Gray, Commonly Clayey And Sticky, With Thin Sand Interbeds. Rop Generally Slower And Erratic, Increased Difficulty Sliding. 11600-11969 Zone 4B Inverted Wellbore. Fine To Medium Grained, Moderately Well Sorted And Clean Sands. Resistivities Of 6-9 Ohms Indicate Water Swept Sands. Possible Fault At 11800 Separating Uphole Productive Correlative Interval From Swept Sands Seen Here. Printed: 1/2/2003 1 :24:03 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BPEXPL0RATI0N , ~1>.~..~~t,p.n$.....S.tJl1I1ll11C:1.Öj;.,...'f',pij.rt 0.50 DRILL N 0.50 DRILL N 0.50 DRILL N 0,50 DRILL N 1.00 DRILL N 1.50 DRILL N 0.50 DRILL N 1.50 DRILL N 3.75 DRILL N H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Spud Date: 6/23/1971 End: 12/29/2002 Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: lDate From;. To HOl.IÏ"sTâsk 'CedèNPT Des$ri ptiof1qf<PØérÇ1~ipøs 12/20/2002 19:00 - 19:30 19:30 - 20:00 20:00 - 20:30 20:30 - 21 :00 21 :00 - 22:00 22:00 - 23:30 23:30 - 00:00 12/21/2002 00:00 - 01:30 01:30 - 05:15 FLUD PROD1 Lost Total Returns - Pick Up And Monitor Losses - Static Loss Rate At 192 BPH FLUD PROD1 Start Mixing LCM Pill NO.1 - POH From 11,969' To 11,432' 50 Barrel LCM Pill At 20 PPB Consisted Of The Following Additives: 20 PPB Mix 2 Medium FLUD PROD1 FLUD PROD1 FLUD PROD1 *NOTE* While Pumping LCM Pill No,1 Had No Returns Keep Back Side Full And Spot 50 Barrel LCM Pill Continue To POH To 10,780' (7" Casing Shoe 10,861') Monitor Well Bore Static Losses Slowed To 85 BPH - During This Phase Service Top Drive And Traveling Blocks - Consult With Anchorage Drilling Manager And Drilling Engineer Regarding LCM Decision Tree Losses Mix And Pump LCM Pill No.2 - Change Shaker Screens To A Coarse Mesh 180-100-50 FLUD PROD1 50 Barrel LCM Pill At 40 PPB Consisted Of The Following Additives: 20 PPB Mix 2 Medium 10 PPB Safe Carb 250 10 PPB Safe Carb 40 FLUD PROD1 FLUD PROD1 *NOTE* While Pumping LCM Pill No,2 Had No Returns Monitor Well Bore Static Losses Slowed To 60 BPH Mix And Pump LCM Pill No,3 50 Barrel LCM Pill At 50 PPB Consisted Of The Following Additives: 30 PPB Mix 2 Medium 10 PPB Safe Carb 250 10 PPB Safe Carb 40 FLUD PROD1 *NOTE* While Pumping LCM Pill NO.3 Had No Returns Drop Bar And Open Circulating Sub - Prepare And Pump LCM Pill No.4 - Pull Screens On Mud Pump *NOTE* While Mixing LCM Pill Static And Pumping Fluid Losses Were From 60 BPH To 144 BPH From Midnight To 04:30 Hours Losses At 595 Barrels Averaged Out To 132 BPH 50 Barrel LCM Pill At 100 PPB Consisted Of The Following Additives: 20 PPB Nut Plug Coarse 25 PPB Mix 2 Medium 25 PPB "G" Seal 15 PPB Safe Carb 250 15 PPB Safe Carb 40 Printed: 1/2/2003 1 :24:03 PM ,,) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) BP EXPLORATION QP~û-ti.~I1!)...'~l;Imm~ry......Repørt H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 Frorn>~Tö Hours Task CodèNPT p~$þriptjonöfOþer~tiQns 12/21/2002 01:30 - 05:15 05: 15 - 09:00 09:00 - 13:00 13:00 - 14:00 14:00 - 14:30 14:30-17:00 3.75 DRILL N 3.75 DRILL N FLUD PROD1 FLUD PROD1 4.00 DRILL N FLUD PROD1 1.00 DRILL N 0.50 DRILL N FLUD PROD1 FLUD PROD1 2.50 DRILL N FLUD PROD1 17:00 - 21 :30 4.50 DRILL N FLUD PROD1 21 :30 - 22:30 1.00 DRILL N FLUD PROD1 22:30 - 23:00 0,50 DRILL N FLUD PROD1 23:00 - 23:30 0.50 DRILL N FLUD PROD1 23:30 - 00:00 0.50 DRILL N FLUD PROD1 12/22/2002 00:00 - 02:00 2.00 DRILL N FLUD PROD1 02:00 - 08:00 6.00 DRILL P PROD1 *NOTE* While Pumping LCM Pill No.4 Had No Returns Monitor Well Bore Static Losses After Pumping LCM Pill No.4 - Losses At 60 BPH Decreasing To 24 BPH Start Mixing LCM Pill No.5 50 Barrel LCM Pill At 100 PPB Consisted Of The Following Additives: 20 PPB Nut Plug Coarse 25 PPB Mix 2 Medium 25 PPB "G" Seal 15 PPB Safe Carb 250 15 PPB Safe Carb 40 *NOTE* While Pumping LCM Pill No.5 Had Partial Returns - Monitor Well Static Losses At 13 To 24 BPH Pump Dry Job - Blow Down Surface Equipment - POH With 4" Drill Pipe Standing Back In Mast To 420' POH With BHA No.8 From 420' To 100' Hold Pre-Job Safety Meeting - Remove Sources From MWD / LWD Tools - Lay Down Monel Drill Collar - Pull Bit To Floor - Gauge 6 1/8" PDC Bit And Inspect Mud Motor *NOTE* Static Losses At 10 BPH RIH To 110' Make Up HOC And Install New Pulser Tool - Down Load Data From LWD Tool And Initialize For This Bit Run - Install Sources And Single Action By Pass Sub (SABS) RIH To 516' - Surface Test MWD Tool 300 GPM With 1075 Psi. RIH With 4" Drill Pipe From Mast To 10,781' Slip And Cut 98 Feet Of 1 1/4" Drilling Line Service Can-Rig Top Drive And Traveling Blocks Break Circulation Verify That Bit Not Plugged And Tools Operating Correct Prior To Going Into Open Hole - Install Top Drive Blower Hose Continue To RIH To 11,434' - Starting To Take Weight - Connect Top Drive And Proceed To Wash To Bottom Continue To Wash And Ream To Bottom Cleaning Out LCM From 11,434' To 11, 969' - During This Phase Of Operation Losses Remained At 30 BPH Directional Drill Ahead From 11,969' To 12,395' - During This Phase Of Operation Losses Increased To 138 BPH With Flo-Pro Mud - Started To Drill Ahead With 2% KCL Water And Encountered Total Losses At 12,044' At 420 BPH - Continued To Drill Ahead Regained 50 Percent Of Prior Flow Rate To Surface Losses At This Point 138 BPH - Drilled To 12,395' And Encountered Total Losses Again 420 BPH Lithology Encountered: 11950-12140 Zone 4B Poor / No Samples Across Shakers (LCM And / Or No Returns). MWD Logs Indicate Clean (GR < 30 API), Water Swept Sands (Res 4-6 Ohms), High ROP Printed: 1/2/2003 1 :24:03 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 HoÙrs Task Code NPT De!)criptiQo:ÞfPþ$ratiQn$ 12/22/2002 02:00 - 08:00 6.00 DRILL P PROD1 08:00 - 09:00 1.00 DRILL N FLUD PROD1 09:00 - 11 :30 2.50 DRILL N FLUD PROD1 11 :30 - 12:30 1.00 DRILL N FLUD PROD1 12:30 - 13:30 1,00 DRILL N FLUD PROD1 13:30 - 14:00 0.50 DRILL N FLUD PROD1 14:00 - 14:30 0.50 DRILL N FLUD PROD1 14:30 - 15:00 0.50 DRILL N FLUD PROD1 15:00 - 20:30 5,50 DRILL N FLUD PROD1 20:30 - 22:00 1.50 DRILL N FLUD PROD1 While Sliding And Rotating. 12140-12395 Zone 4B Well Has Reentered Oil Column At 12140 MD (8789 TVDSS) - Well Staying In Clean, Massive Sand, With Only Minor Thin Shale Beds. Possible Fault At 12390, Causing Lost Circulation Problems POH From 12,395' To 10,781' - Fill Back Side Thru Kill Line On Trip Out To Shoe (Losses At 3 BPM) Wait On 2% KCL Water - Slow Coming Due To Phase II Weather Conditions - Mix LCM Pill No,1 50 Barrel LCM Pill At 100 PPB Consisted Of The Following Additives: 20 PPB Nut Plug Coarse 25 PPB Mix 2 Medium 25 PPB "G" Seal 15 PPB Safe Carb 250 15 PPB Safe Carb 40 *NOTE* Total Losses From Midnight To Noon- 600 Barrels Flo-Pro Mud 1755 Barrels Of KCL Water 2355 Total Barrels Of Fluid Drop Ball And Shift Open SABS Tool (Haliburton Equipment Services Single Action By-Pass Sub) - Spot LCM Pill No.1 At 3 BPM With 165 Psi. Monitor Losses - Keeping Back Side Full - Prepare LCM Pill No.2 50 Barrel LCM Pill At 100 PPB Consisted Of The Following Additives: 20 PPB Nut Plug Coarse 25 PPB Mix 2 Medium 25 PPB "G" Seal 15 PPB Safe Carb 250 15 PPB Safe Carb 40 Static Losses At 80 To 120 BPH Attempt To Pump 50 BB!. LCM PiII- Plugged String POH With 4" Drill Pipe From 10,860' To 10.314' Attempt To Circulate (No Good) - Blow Down Top Drive- Remove Top Drive Blower Hose POH (WET) From 10,314' To 422' With 4" Drill Pipe Standing Back In Mast - Static Losses During Trip Out To BHA At 120 BPH Change Out Handling Equipment To Accept Lift Subs For Drill Collars - POH With BHA From 422' To 235' String Plugged With LCM At SABS Tool And 50' Above Tool- Lay Down 1 Joint 31/2" HWDP And Replace Same - Pump Thru Printed: 1/2/2003 1 :24:03 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 Datè FrÖm~To Hours Task Cdde . NPT PhaSe . [)esçrip~jÖn()f()þ$r~ti()ns 12/22/2002 20:30 - 22:00 1,50 DRILL N FLUD PROD1 Remainder Of BHA Verify All Clear 22:00 - 00:00 2.00 DRILL N FLUD PROD1 POH From 235' To 140' With BHA - Remove Sources From LWD Tools And Down Load - POH And Stand Back BHA- Static Losses At 90 To 120 BPH *NOTE* Total Losses From Noon To Midnight 446 Barrels Of KCL Water 12/23/2002 00:00 - 00:30 0,50 DRILL N FLUD PROD1 Service Can-Rig Top Drive And Traveling Blocks 00:30 - 02:00 1.50 DRILL N FLUD PROD1 RIH With Open Ended 4" Drill Pipe From Mast To Inside 7" Liner - Static Losses At 120 BPH 02:00 - 03:30 1.50 DRILL N FLUD PROD1 Pump 150 Barrel LCM Pill At 100 PPB With Following Additives: 20 PPB Nut Plug Coarse 10 PPB Nut Plug Medium 25 PPB Mix 2 Coarse 10 PPB Mix 2 Medium 20 PPB "G" Seal 1 0 PPB Safe Carb 250 5 PPB Safe Carb 40 03:30 - 05:00 1,50 DRILL N FLUD PROD1 POH With 4" Drill Pipe From 4200' Standing Back In Mast 05:00 - 07:30 2.50 DRILL N FLUD PROD1 Make Up BHA NO.1 0 Initialize MWD / LWD Tools Load Sources And RIH To 422' - Surface Test MWD Tools 07:30 - 11 :30 4,00 DRILL N FLUD PROD1 RIH With 4" Drill Pipe From 422' To 9,197' - Break Circulation Slowly 1 BPM With 250 Psi. - Circulate 10 Minutes At 5 BPM With 1185 Psi. - Continue To RIH To 9,383' - Break Circulation Slowly See Pressure Increase At 474 Psi. - Attempt To Un-Plug String (NO GOOD) *NOTE* Well Bore Total Losses From Midnight To Noon At 500 Barrels 11 :30 - 12:00 0.50 DRILL N FLUD PROD1 POH From 9,383' To 9,197' - Attempt To Circulate Pressured Up To 750 Psi. (NO GOOD) 12:00 - 16:30 4.50 DRILL N FLUD PROD1 Blow Down Top Drive - POH (WET) With Plugged String From 9,197' To 422' *NOTE* Static Losses At 0 BPH 16:30 - 17:30 1,00 DRILL N FLUD PROD1 POH With BHA Stand Back In Mast From 422' To 140' - Remove Sources And Down Load MWD Data 17:30 - 18:30 1.00 DRILL N FLUD PROD1 Continue To POH With BHA - Break Bit And Lay Down Motor (Both Packed With LCM) - Clean Out 3' Of MWD Tool *NOTE* Clean Pump Suctions Of LCM - Transfer Fluid In Pit 3 To Vac Truck And Clean PIT - Run Fluid Over Shaker From Vac Truck To Remove Any Previous Coarse Residue From LCM Pills 18:30 - 20:00 1,50 DRILL N FLUD PROD1 Make Up BHA NO.11 And Stand Back In Mast - Make Up 2 Each Float Subs With 2 Each Non-Ported Floats 20:00 - 20:30 0.50 DRILL N FLUD PROD1 Clear Rig Floor And Wash Down Same From Wet Trip 20:30 - 21 :00 0.50 BOPSUR N FLUD PROD1 Pick Up Test Joint - Make Up 4" HT-40 Full Opening Safety Valve And IBOP Valve - Pull Wear Ring 21 :00 - 00:00 3.00 BOPSUR N FLUD PROD1 Install Test Plug - Fill BOP Equipment With Water - Rig Up Printed: 1/2/2003 1 :24:03 PM ) ~) BF?E*WtORATION O..pèr~~i.Qr)~........~..pmm~ryi...~~..~~.rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 [)Ø~çripti()r19f()p~r~tiøhs . 12/23/2002 21 :00 - 00:00 3.00 BOPSURN FLUD PROD1 12/24/2002 00:00 - 00:30 0.50 BOPSURN FLUD PROD1 00:30 - 01 :00 0.50 BOPSUR N FLUD PROD1 01 :00 - 03:00 2,00 DRILL N FLUD PROD1 03:00 - 06:00 3.00 DRILL N FLUD PROD1 06:00 - 14:00 8.00 DRILL N FLUD PROD1 14:00 - 00:00 10.00 DRILL P PROD1 12/25/2002 00:00 - 02:00 2,00 DRILL P PROD1 02:00 - 03:00 1.00 DRILL P PROD1 03:00 - 05:00 2.00 DRILL P PROD1 05:00 - 06:30 1.50 DRILL P PROD1 06:30 - 07:30 1,00 DRILL P PROD1 07:30 - 08:30 1.00 DRILL P PROD1 08:30 - 10:00 1.50 DRILL P PROD1 10:00 - 14:00 4.00 DRILL P PROD1 14:00 - 16:00 2.00 DRILL P PROD1 16:00 - 16:30 0.50 DRILL P PROD1 16:30 - 17:00 0.50 CASE P COMP 17:00 - 20:30 3,50 CASE P COMP 20:30 - 21 :00 0.50 CASE P COMP 21 :00 - 21 :30 0.50 CASE P COMP 21 :30 - 23:00 1.50 CASE P COMP Testing Equipment - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector Chuck Sheave - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower tBOP Valves At 250 Psi. Low And 3,500 Psi. High - Test Pit PVT System And Perform Accumulator Test *NOTE* Well Bore Total Losses From Noon To Midnight At 0 Barrels Continue To Test BOP And Related Equipment. Rig Down Testing Equipment - Install Wear Bushing And Energize Lock Down Studs - Clear Rig Floor - Blow Down Choke Manifold, Top Drive, Choke And Kill Lines. Make Up BHA No,11 - RIH To 387' - Surface Test MWD Tool And Mud Motor. RIH With 4" Drill Pipe from 387' to 8,600'. Wash from 8,600' to 11,467'. Encountering 35K overpull. Wash and ream from 11,467' to 12,395' at 6 bpm, 995 psi. Started losing fluid at 11,960'. Flow went from 27% to 12%. Drill from 12,395' to 12,860'. Losses started at 145 bph and increased to 400 bph. No returns. Filling back side to keep hole full. From 12,395' to 12,475' sliding to decrease angle, TF=160L. ROP 40 - 160 fph. Slide decreased inclination and yielded some rt. hand turn. Slide from 12,613' to 12,690' to correct azimuth, TF=70L. Slide decreased inclination and turned left, Motor response is approx. 55 degress off from TF due to formation or motor torqueing down hole. Slide to build angle. Drill from 12,860' to TD at 12,950'. AST=0.1, ART=1.1. Pump 55 bbl mud sweep. No returns. Short trip to casing shoe. Back ream tight spot from 12,080' to 12,055'. Work tight spots from 11,946' to 11,852', 25K to 50K over pulls, Slip and cut drilling line, Service top drive and crown. RIH from 10,830' to 12,950'. Taking weight (25K) at 11,480', 11,496', 12,473', 12,649'. 3' of fill on bottom. Spot 90 bblliner running pill in open hole section at 6 bpm, 1,125 psi. No returns. POH from 12,950' to 10,830'. 50K over pull at 11,498' to 11,456'. Drop rabbit. Monitor static loss at 250 bph, Filling back side to keep hole full. Continue to POH to 387'. Change handling equipment. LD BHA. Clear floor. RU casing equipment. MU 4 1/2" float equipment and check floats, ok. Run 55 joints 41/2",12.6#, L-80, BTCM tubing to 2,213'. 1 Baker payzone external casing packer between joints 20 and 21. Change handling equipment and MU Baker HMC liner hanger and ZXP liner top packer. Circulate liner volume at 7 bpm, 130 psi. RIH from 2,238' to 4,588' with 4" DP from derrick. Fill every 10 Printed: 1/2/2003 1 :24:03 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES HoÙrs Task Code NPT Phasé 12/25/2002 21 :30 - 23:00 1.50 CASE P COMP 23:00 - 00:00 1,00 CASE N RREP COMP 12/26/2002 00:00 - 03:00 3.00 CASE P COMP 03:00 - 03:30 0.50 CASE P COMP 03:30 - 04:30 1.00 CASE P COMP 04:30 - 05:00 0.50 CASE P COMP 05:00 - 06:00 1.00 CASE P COMP 06:00 - 08:00 2,00 CEMT P COMP 08:00 - 08:30 0.50 CASE P COMP 08:30 - 10:30 2.00 CASE P COMP 10:30 - 11 :00 0.50 CASE P COMP 11 :00 - 13:30 2.50 CASE P COMP 13:30 - 17:30 4.00 CASE P COMP 17:30 - 18:30 1.00 PERF P COMP 18:30 - 19:30 1.00 PERF P COMP 19:30 - 21 :00 1.50 PERF P COMP 21 :00 - 23:00 2.00 PERF P COMP 23:00 - 00:00 1.00 PERF P COMP 12/27/2002 00:00 - 04:00 4.00 PERF P COMP 04:00 - 05:00 1.00 PERF P COMP Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: Spud Date: 6/23/1971 End: 12/29/2002 stands. Repair iron roughneck. RIH from 4,588' to 10,786' with 41/2" liner. Circulate one DP and liner volume at 6 bpm, 400 psi. No returns. RIH from 10,786' to 12,950'. Taking 40 K down at 12,059' and 12,340', Work liner through tight areas. MU cement head. Circulate open hole volume at 6 bpm, 410 psi. No returns. Hold PJSM with cementers. Batch mix cement. Pump 20 bbls of water. Test cement lines to 4,500 psi. Pump 58 bbls of 15.8 ppg class G latex cement, drop dart, displace with 68 bbls of perf pill followed by seawater. Good indication of cement lifting by pressure increase. Pressure decreased after 32 bbls of cement exited the shoe, Bump plug at calculated volume. No returns during most of the job. Partial returns the last 25 bbls prior to bumping plug. CIP at 07:23, Pressure up and set liner hanger. Bleed pressure to 500 psi. Slack off to confirm hanger set. Pressure up and inflate ECP. 0.2 bbls required to inflate ECP, Float shoe at 12,949' Landing collar at 12,862' Top of Liner tie back at 10,710' Top of ECP at 12,122' Rotate 20 turns to release from liner. Hold 1000 psi on DP, unsting liner running tool from packing and begin circulating with no returns. Pick up and expose packer setting lugs. Set down 40K to set liner top packer. Set down repeatedly with and without rotation to ensure packer is set. Test casing to 1,000 psi to confirm liner top packer is set. Displace well bore to clean seawater at 5 bpm, 530 psi. LD cement head. LD 4" DP from 10,710' to 8,405'. POH and LD liner running tool. Clear floor. RU 2 7/8" handling tools. Test casing to 3,000 psi for 30 minutes. Hold PJSM for picking up perf guns. PU 2 1/2" Halliburton perf guns, Millennium charges, 4 SPF, 90 deg phasing, and firing head to 695'. PU 2 7/8" DP from 695' to 2,226'. Change handling equipment. RIH w/4" DP to 3,250', RIH with perf guns to 12,850'. Tag plug on top of landing collar at 12,860' and place guns on depth. Pressure up to 2,000 psi and bleed off pressure to fire guns. Perforations from: 12,180' -12,350' 12,430' - 12,580' 12,650' - 12,850' .J 2 1/2" millennium charges, 4 SPF, 90 degree phasing, Good Printed: 1/2/2003 1 :24:03 PM ) ) BPSÞ<PLQRA.TION Qp~'~~~iC)n.š..'..$~mmä..ry...~gPC).rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/27/2002 12/28/2002 12/29/2002 H-02 H-02A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Spud Date: 6/23/1971 End: 12/29/2002 Start: 12/17/2002 Rig Release: 12/29/2002 Rig Number: FrÖm~"To HoUrs Task Code NPT @€j$çriþti()nÖfQþ~~~~iPM$ 04:00 - 05:00 1.00 PERF P COMP indication of guns firing on sound recorder. Lost 10 bbls after guns fired. 05:00 - 05:30 0.50 PERF P COMP Pull perf guns above top shot. Monitor well. Losing at 40 bph. 05:30 - 06:00 0.50 PERF P COMP Service top drive. 06:00 - 07:30 1,50 PERF P COMP Slip and cut drilling line. 07:30 - 10:30 3,00 PERF N RREP COMP Repair pipe skate, 10:30 - 19:00 8,50 PERF P COMP LD 4" DP, 19:00 - 22:00 3,00 PERF P COMP RU 2 7/8" handling equipment. LD 2 7/8" DP. 22:00 - 00:00 2.00 PERF P COMP LD perf guns. All shots fired. 00:00 - 00:30 0.50 PERF P COMP Pull wear bushing. 00:30 - 01 :30 1,00 PERF P COMP RD handling tools. Clear rig floor. 01 :30 - 03:00 1.50 RUNCOrvP COMP RU casing equipment to run tubing, 03:00 - 20:30 17.50 RUNCOrvP COMP PJSM. Run 41/2",12.6#,13 Cr-80, NSCT gas lift completion. MU torque 4,000 ft*lbs. 20:30 - 21 :30 1.00 RUNCOrvP COMP Space out tubing. MU tubing hanger. PU=145K, SO=115K 21 :30 - 22:30 1.00 RUNCOrvP COMP Land tubing hanger. RILDS. 22:30 - 00:00 1.50 RUNCOrvP COMP Reverse circulate clean seawater with corrosion inhibitor at 3 bpm, 150 psi. 00:00 - 01 :00 1.00 RUNCOrvP COMP Reverse circulate clean seawater with corrosion inhibitor. 01 :00 - 02:00 1.00 RUNCOrvP COMP Drop ball and rod assembly. LD DP landing joint and XO. LD casing equipment. Clear rig rig. 02:00 - 03:30 1.50 RUNCOrvP COMP Pressure up tubing to 4,200 psi and hold for 5 minutes to set packer. Bleed pressure to 3,000 psi and test tubing for 30 minutes. Bleed tubing pressure to 1,500 psi. Test inner annulus to 3,000 psi for 30 minutes. Bleed tubing pressure to zero and shear DCK valve. Packer set at 10,648' WLEG is 4' into liner tie back. 03:30 - 04:30 1.00 RUNCOrvP COMP Install BPV and test from below ot 3,000 psi. Blow down lines. 04:30 - 06:00 1.50 WHSUR P COMP Change out blind rams to blind shear rams. 06:00 - 07:30 1.50 WHSUR P COMP ND BOP. 07:30 - 09:30 2,00 WHSUR P COMP Change out 3 lock down screws. NU adapter flange and tree. Test to 5,000 psi. 09:30 - 10:30 1.00 WHSUR P COMP RU lubricator. Pull TWC. 10:30 - 12:00 1.50 WHSUR P COMP RU hot oil pump truck, Test lines to 3,000 psi. Reverse circulate 156 bbls of diesel at 3,5 bpm, 2,400 psi. 12:00 - 13:00 1.00 WHSUR P COMP U-tube diesel into tubing. 13:00 -14:00 1.00 WHSUR P COMP Install BPV and test to 3,000 psi. 14:00 - 15:00 1.00 WHSUR P COMP Secure tree. Remove secondary annulus valve. Release rig at 15:00. Printed: 1/2/2003 1 :24:03 PM ') ) dO dr1to 0 31-Dec-02 Phillips Alaska, Inc. Attn: Sandy Lemke ATO-148 700 G Street Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well H-02A Dear Sir / Madam Enclosed is one hard copy and a barcoded disk with the *.PTT and *.PDF files. Tie-on Survey: 5,624.37' MD Window / Kickoff Survey 5,630.00' MD (if applicable) Projected Survey: 12,950.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attach mente s) RECEIVED JAN 0 9 2003 AIaiœ on & Gas Cons. Commi8Iion AIlÚK'"",C; Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA H Pad H-02A .~ Job No. AKZZ22140, Surveyed: 4 September, 2002 Survey Report 6 January, 2003 Your Ref: API 500292010001 Surface Coordinates: 5959717.84 N, 643318.05 E (70017' 50.7912" N, 148050' 21.7328" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 959717.84 N, 143318.05 E (Grid) Surface Coordinates relative to Structure Reference: 2107.92 N, 1994.06 E (True) Kelly Bushing: 73. 27ft above Mean Sea Level Elevation relative to Project V Reference: 73.27ft Elevation relative to Structure Reference: 73.27ft spe......,y-sul'1 DRILLING SSAVIc:es A Halliburton Company Survey Ref: svy11342 Sperry-Sun Drilling Services Survey Report for PBU _WOA H Pad - H-02A Your Ref: AP/500292010001 Job No. AKZZ22140, Surveyed: 4 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 5624,37 9.250 211.320 5549.65 5622.92 63.93 S 22.30 W 5959653.50 N 643296.97 E -1 .45 Tie On Point - 5630,00 9.650 211.300 5555.20 5628.47 - 64.72 S 22.78 W 5959652.70 N 643296.51 E 7.105 -1.66 Window Point 5652,84 9.280 220.490 5577.73 5651.00 67.76 S 24.97 W 5959649.62 N 643294.38 E 6.804 -2.81 5684.00 9,660 234.050 5608.47 5681.74 71.20 S 28.72 W 5959646.10 N 643290.70 E 7.246 -5.31 5716,90 11 .400 246.930 5640.82 5714.09 74.10 S 33.94 W 5959643.11 N 643285.52 E 8.866 -9.39 5749,03 13,120 257.600 5672.22 5745.49 76.13 S 40.43 W 5959640.96 N 643279.08 E 8.832 -14.93 ~ 5779.31 14.270 265.780 5701.64 5774.91 77.14 S 47.51 W 5959639.81 N 643272.02 E 7.429 -21.35 5811,62 16,190 272.760 5732,82 5806.09 77.22 S 55.98 W 5959639.57 N 643263.55 E 8.207 -29.38 5842.23 17.610 278.040 5762,11 5835.38 76.36 S 64.83 W 5959640.26 N 643254.69 E 6.827 -38.06 5873,87 17.830 278.040 5792.24 5865.51 75.02 S 74.36 W 5959641 .42 N 643245.13 E 0.695 -47.54 5905.40 19.480 286.120 5822.12 5895.39 72.88 S 84.20 W 5959643.37 N 643235.26 E 9.713 -57.55 5937.35 21.240 283.900 5852.08 5925.35 70.01 S 94.93 W 5959646.03 N 643224.47 E 6.015 -68.65 5969.96 22.510 284.220 5882.34 5955.61 67.06 S 106.72 W 5959648.76 N 643212.63 E 3.912 -80.77 6002.49 23.640 287.060 5912.26 5985.53 63.61 S 118.99W 5959651.97 N 643200.29 E 4.875 -93.51 6097,31 26.310 289.940 5998.21 6071.48 50.87 S 156.93 W 5959663.99 N 643162.12 E 3.093 -133.53 6129.66 27.690 286.800 6027.04 6100.31 46.25 S 170.86 W 5959668.34 N 643148.10 E 6.132 -148.21 6195.18 29.580 283.630 6084,55 6157.82 38.04 S 201.16 W 5959675.97 N 643117.65 E 3.700 -179.56 6290,61 33.540 267.620 6165,99 6239.26 33.57 S 250.50W 5959679.50 N 643068.24 E 9.679 -227.86 6385,92 36.050 255.300 6244,35 6317.62 41.79 S 304.01 W 5959670.26 N 643014.90 E 7.819 -276.21 6481,03 37.210 247.430 6320,72 6393.99 59.94 S 357.66 W 5959651.09 N 642961.60 E 5.082 -321.63 6576.08 38.390 235.300 6395.92 6469.19 87.82 S 408.54 W 5959622.25 N 642911.26 E 7.910 -361.41 6670,98 44.090 227.290 6467.31 6540.58 127.05 S 457.10 W 5959582.10 N 642863.46 E 8.178 -395.47 6766,31 49.550 220.770 6532.55 6605.82 177.08 S 505.22 W 5959531.16 N 642816.30 E 7.589 -425.77 6862.23 54.800 213.600 6591.40 6664.67 237.45 S 550.81 W 5959469.93 N 642771.87 E 8.046 -450.4 7 .~ 6956,85 58.680 206.4 70 6643.33 6716.60 305.92 S 590.27 W 5959400.72 N 642733.72 E 7.515 -466,84 7051.52 58.270 206.950 6692.83 6766.10 378.00 S 626.54 W 5959327.96 N 642698.84 E 0.612 -479.06 7146.19 57,950 206.080 6742.85 6816.12 449.93 S 662.42 W 5959255.36 N 642664.33 E 0.850 -490.97 7242.09 57.160 205.950 6794.30 6867.57 522.66 S 697.92 W 5959181.97 N 642630.23 E 0.832 -502.25 7337.26 59.430 205.690 6844.31 6917.58 595.54 S 733.18 W 5959108.43 N 642596.36 E 2.396 -513.26 7431.86 59,620 205.740 6892.29 6965.56 669.00 S 768.56 W 5959034.31 N 642562.39 E 0.206 -524.21 7526.31 58.900 205.180 6940.56 7013.83 742.29 S 803.45 W 5958960.36 N 642528.90 E 0.917 -534.75 7620.13 58.700 205.530 6989.17 7062.44 814.81 S 837.82 W 5958887.20 N 642495.92 E 0.384 -545.02 7712.58 58.420 205,130 7037,39 7110.66 886.10 S 871.56 W 5958815.28 N 642463.54 E 0.477 -555.09 7806.94 57.580 204.360 7087,39 7160.66 958.77 S 905.06 W 5958741.98 N 642431.44 E 1.128 -564.49 7901.28 58,330 205.630 7137.45 7210.72 1031.25 S 938.85 W 5958668.88 N 642399.03 E 1.391 -574.23 6 January, 2003 - 14:58 Page 2 0(6 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA H Pad - H-02A Your Ref: AP/500292010001 Job No. AKZZ22140, Surveyed: 4 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7995,31 58.400 205.110 7186.77 7260.04 1103.588 973.15 W 5958595.90 N 642366.12 E 0.477 -584.50 8088.78 57.900 204,640 7236.09 7309.36 1175.61 8 1006.55 W 5958523.25 N 642334.10 E 0.685 -594.00 8182.09 59,560 204.910 7284.52 7357.79 1248.02 8 1039.97 W 5958450.21 N 642302.07 E 1.796 -603.41 8277.35 59.480 205.100 7332.84 7406.11 1322.42 8 1074.68 W 5958375.16 N 642268.79 E 0.191 -613.43 8371.46 59.260 204,940 7380.79 7454.06 1395.80 8 1108.92 W 5958301.14 N 642235.95 E 0.276 -623.32 7501.77 1468.30 8 1142.47 W 5958228.02 N 642203.78 E .~ 8464,50 59.050 204,730 7428.50 0.297 -632.83 8558.86 58,340 204.250 7477.52 7550.79 1541.67 8 1175.90 W 5958154.03 N 642171.77 E 0.869 -641.94 8651,98 60.190 203.780 7525.11 7598.38 1614.788 1208.47 W 5958080.31 N 642140.60 E 2.033 -650.33 8746.79 60.520 204,370 7572.01 7645.28 1690.01 8 1242.08 W 5958004.45 N 642108.42 E 0.643 -659.05 8841,00 60.420 204.640 7618.44 7691.71 1764.59 8 1276.08 W 5957929.23 N 642075.85 E 0.271 -668.33 8935,32 60.050 204.490 7665.27 7738.54 1839.06 8 1310.12 W 5957854.13 N 642043.24 E 0.416 -677,70 9029.29 59,690 203.850 7712.44 7785.71 1913.21 8 1343.40 W 5957779.36 N 642011.38 E 0.703 -686.43 9123,10 59,120 204,090 7760.18 7833.45 1986.99 8 1376.20 W 5957704.96 N 641979.99 E 0.646 -694.83 9216.48 58.960 203.430 7808.22 7881.49 2060.288 1408.46 W 5957631.07 N 641949.13 E 0.630 -702,87 9307.48 58.4 70 203.730 7855.48 7928.75 2131.568 1439.57 W 5957559.22 N 641919.39 E 0.608 -710.43 9405.43 59.260 203.430 7906.12 7979.39 2208.40 8 1473.11 W 5957481.75 N 641887.32 E 0.848 -718.58 9500,17 59.040 202.630 7954.71 8027.98 2283.25 8 1504.93 W 5957406.31 N 641856.94 E 0.761 -725.71 9594.79 58.850 203.270 8003.52 8076.79 2357.89 8 1536.54 W 5957331.08 N 641826.76 E 0.613 -732.70 9688,79 58,320 200.790 8052.52 8125.79 2432.24 8 1566.63 W 5957256.16 N 641798.09 E 2.321 -738.35 9783.62 57.970 197.560 8102.58 8175.85 2508.30 8 1593.08 W 5957179.61 N 641773.09 E 2.916 -740.00 9877.85 57.550 194.480 8152.85 8226.12 2584.89 8 1615.08 W 5957102.62 N 641752.56 E 2.800 -737.25 9972.04 58.570 190.690 8202.69 8275.96 2662.888 1632.47 W 5957024.31 N 641736.65 E 3.582 -729.70 1 0065.79 58.710 188.700 8251.49 8324.76 2741.798 1645.95 W 5956945.16 N 641724.68 E 1.819 -718.14 ~J 10159.03 58.120 185.790 8300.33 8373.60 2820.57 8 1655.97 W 5956866.21 N 641716.16 E 2.733 -703.32 10253.32 58.550 184.070 8349.83 8423.10 2900.52 8 1662.87 W 5956786.14 N 641710.80 E 1.618 -685.17 10347.83 60.830 177.060 8397.57 8470.84 2982.03 8 1663.61 W 5956704.63 N 641711.61 E 6.841 -660.69 10442,09 61.110 171 , 160 8443.34 8516.61 3063.958 1655.16 W 5956622.88 N 641721.62 E 5.480 -627.33 10535.90 60.750 170.450 8488.92 8562.19 3144.898 1642.06 W 5956542.21 N 641736.27 E 0.765 -589.86 10629,70 59.990 170.260 8535.30 8608.57 3225.27 8 1628.40 W 5956462.10 N 641751.46 E 0.829 -552.03 10724.46 59.620 170.440 8582.95 8656.22 3306.02 8 1614.67 W 5956381.63 N 641766.72 E 0.424 -514.02 10783.91 58.670 166.540 8613.45 8686.72 3356.01 8 1604.49 W 5956331.84 N 641777.85 E 5.854 -488.90 10893.16 58.450 162.970 8670.45 8743.72 3445.92 8 1579.99 W 5956242.41 N 641804.06 E 2.795 -437.81 10925.26 57.510 158.080 8687.48 8760.75 3471.578 1570.93 W 5956216.94 N 641813.61 E 13.242 -421.27 10955.59 58.520 152.560 8703.55 8776.82 3494.93 8 1560.19 W 5956193.79 N 641824.79 E 15.790 -403.84 10985,87 59,810 147,760 8719.08 8792.35 3517.478 1547.25 W 5956171.51 N 641838.16 E 14.261 -384.57 6 January, 2003 - 14:58 Page 3 of6 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU _WOA H Pad - H-02A Your Ref: AP/500292010001 Job No. AKZZ22140, Surveyed: 4 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 11019.30 63,240 142.270 8735.03 8808.30 3541.51 S 1530.40 W 5956147.79 N 641855.47 E 17.706 -361.10 11050,74 64.130 137.800 8748.97 8822.24 3563.10 S 1512.30 W 5956126.55 N 641873.98 E 13.054 -337.22 11080.53 65,170 133.390 8761.73 8835.00 3582.33 S 1493.46 W 5956107.69 N 641893.17 E 13.825 -313.37 11114,06 67,050 129.310 8775.31 8848.58 3602.57 S 1470.45 W 5956087.89 N 641916.57 E 12.458 -285,23 11145,27 68,780 127.040 8787.05 8860.32 3620.44 S 1447.72 W 5956070.45 N 641939.64 E 8.726 -258.08 11173,29 70,560 124.950 8796.78 8870.05 3635.87 S 1426.46 W 5956055.42 N 641961.19 E 9.448 -233.10 .'........"ø 11208.06 72.760 121.330 8807.73 8881.00 3653.91 S 1398.83 W 5956037.92 N 641989.16 E 11.734 -201.25 11239.04 74.100 119,040 8816.56 8889.83 3668.83 S 1373.16 W 5956023.49 N 642015.10 E 8.301 -172.22 11267,17 75,640 117.270 8823.90 8897.17 3681.64 S 1349.22 W 5956011.13 N 642039.28 E 8.177 -145.50 11300,83 78.090 115.270 8831,55 8904.82 3696.15 S 1319.83 W 5955997.19 N 642068.95 E 9.298 -113.06 11331,82 80.540 113.000 8837.30 8910.57 3708.60 S 1292.04 W 5955985.28 N 642096.97 E 10.691 -82.79 11359.92 81 ,6°° 109,360 8841,66 8914.93 3718.62 S 1266.16 W 5955975.75 N 642123,03 E 13,34 1 -55,08 113~J3,53 83,090 106.980 8846,14 8919.41 3729.01 S 1234.52 W 5955965.97 N 642154.87 E 8.301 -21,77 11424,96 84.21 0 102.760 8849.62 8922.89 3737.02 S 1204.33 W 5955958.53 N 642185.20 E 13,812 9.41 11453.26 84.450 99.730 8852.41 8925.68 3742.51 S 1176.71W 5955953.57 N 642212,92 E 10.688 37,38 11487,32 86.680 96.620 8855.05 8928,32 3747.34 S 1143.11 W 5955949.38 N 642246.61 E 11.213 70.83 11517,93 88.770 94.720 8856.26 8929.53 3750.36 S 1112.67 W 5955946.94 N 642277.10 E 9.224 100.71 11547,38 89.450 94.530 8856.72 8929.99 3752.73 S 1083.32 W 5955945.13 N 642306.49 E 2.397 129.36 11580.34 92.520 93.690 8856.16 8929.43 3755.10 S 1050.46 W 5955943.40 N 642339.39 E 9.657 161.34 11611.21 96.100 91.320 8853.84 8927.11 3756.44 S 1019.71 W 5955942.64 N 642370.16 E 13.895 191.00 11639,75 96.730 91.490 8850,65 8923.92 3757.14 S 991.36 W 5955942.48 N 642398.52 E 2.285 218.18 11673,60 98.460 92.870 8846.17 8919.44 3758.41 S 957.83 W 5955941.84 N 642432.06 E 6.515 250.46 11732,02 99.270 92.980 8837,17 8910.44 3761.36 S 900.19 W 5955940.00 N 642489.76 E 1.399 306.20 ~ 11825.41 95.790 101.540 8824.91 8898.18 3773.07 S 808.45 W 5955930.04 N 642581.70 E 9.820 397.06 11872.90 96,040 103.040 8820.02 8893.29 3783.13 S 762.30 W 5955920.86 N 642628.04 E 3.186 444.06 11920.57 95.980 102.350 8815.03 8888. 30 3793.55 S 716.05 W 5955911.33 N 642674.47 E 1.445 491.27 12015.29 96.720 101.700 8804.55 8877.82 3813.165 623.98 W 5955893.48 N 642766.90 E 1.037 584.89 12108.94 97.280 100.720 8793.14 8866.41 3831.23 S 532.80 W 5955877.15 N 642858.41 E 1.198 677.19 12202.79 97.720 100.780 8780.89 8854.16 3848.58 S 441.39 W 5955861.54 N 642950.14 E 0.473 769.50 12295,56 96.420 100.350 8769.4 7 8842.74 3865.46 S 350.88 W 5955846.39 N 643040.94 E 1.475 860.78 12363.04 97.780 99.070 8761.13 8834.40 3876.76 S 284.88 W 5955836.35 N 643107.15 E 2.758 927.04 12457.39 87,910 104.120 8756.45 8829.72 3895.69 S 192.72 W 5955819.19 N 643199.66 E 11.745 1020.55 12491.24 86.740 106.410 8758.03 8831.30 3904.59 S 160.10 W 5955810.91 N 643232.44 E 7.590 1054.32 12522.06 86.430 105.970 8759.86 8833.13 3913.17 S 130.56 W 5955802.90 N 643262.14 E 1.744 1085.07 12552.40 86.300 105.370 8761.79 8835.06 3921.34 S 101.40 W 5955795.28 N 643291.44 E 2.020 1115.32 6 January, 2003 - 14:58 Page 4 of6 DriflQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA H Pad.. H..02A Your Ref: AP/S00292010001 Job No. AKZZ22140, Surveyed: 4 September, 2002 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 12643.56 82.410 101,910 8770.75 8844.02 3942.74 S 13.28 W 5955775.56 N 643379.96 E 12736,70 80.480 93.400 8784.63 8857.90 3955.01 S 77.91 E 5955765.03 N 643471.37 E 12830,57 88.890 90.450 8793.32 8866.59 3958.13 S 171.23 E 5955763.69 N 643564.73 E 12883,77 92.520 89.440 8792.67 8865.94 3958.08 S 224.42 E 5955764.76 N 643617.91 E 12950,00 92.520 89.440 8789.76 8863.03 3957.44 S 290.58 E 5955766.67 N 643684.05 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 108.000° (True). Magnetic Declination at Surface is 26.0500(22-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 12950.00ft., The Bottom Hole Displacement is 3968.09ft., in the Direction of 175.801 ° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~) ~) Comment 5624,37 5630,00 12950,00 5622.92 5628.47 8863.03 63.93 S 64.72 S 3957.44 S 22.30 W 22.78 W 290.58 E Tie On Point Window Point Projected Survey 6 January, 2003 - 14:58 Page 5 0'6 ~ BPXA Dogleg Rate (0/100ft) Vertical Section Comment 5.698 1205.75 9.269 1296.26 9.489 1385.98 7.082 1436.55 0,000 1499.27 Projected Survey .~' .~ DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_WOA H Pad - H-02A Your Ref: AP/500292010001 Job No. AKZZ22140, Surveyed: 4 September, 2002 ,. ~ BPXA North Slope Alaska Survey tool program for H-02A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 5509.27 0.00 5509.27 5508.34 12950.00 5508.34 AK-1 BP _HG - BP High Accuracy Gyro(H-02) 8863.03 AK-6 BP _I FR-AK(H-02APB 1 ) ~ ~ 6 January, 2003 - 14:58 Page 60f6 DrillQuest 3.03.02.004 ') ) óìOd.~/~o 31-Dec-02 Phillips Alaska, Inc. Attn: Sandy Lemke ATO-148 700 G Street Anchorage, AK 99501 Re: Distribution of Survey Data for Well H-02A MWD Dear Sir / Madam Enclosed is one hard copy and a barcoded disk with the *.PTT and *.PDF files. Tie-on Survey: 5,624.37 I MD Window / Kickoff Survey 5,630.00' MD (if applicable) Projected Survey: 12,950.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECE'VED JAN 0 9 200~ Attachment( s) ~ on &. Gas \ìOn$. CÐn'...~"1 At\dtoragt ~. Sperry-Sun Drilling Services North Slope Alaska BPXA PBU WOA H Pad H-02A MWD ~ Job No. AKMW22140, Surveyed: 4 September, 2002 Survey Report 6 January~ 2003 Your Ref: API 500292010001 Surface Coordinates: 5959717.84 N, 643318.05 E (70017' 50.7912" N, 148050' 21.7328" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 .~ Surface Coordinates relative to Project H Reference: 959717.84 N, 143318.05 E (Grid) Surface Coordinates relative to Structure Reference: 2107.92 N, 1994.06 E (True) Kelly Bushing: 73.27ft above Mean Sea Level Elevation relative to Project V Reference: 73.27ft Elevation relative to Structure Reference: 73.27ft spe'-''-'y-sul! DRIL.L.ING seRVices A Halliburton Company Survey Ref: svy11344 Sperry-Sun Drilling Services Survey Report for PBU_WOA H Pad - H-02A MWD Your Ref: AP/500292010001 Job No. AKMW22140, Surveyed: 4 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5624.37 9.250 211.320 5549.65 5622.92 63.93 8 22.30 W 5959653.50 N 643296.97 E -1.45 Tie On Point 5630.00 9.650 211.300 5555.20 5628.47 64.728 22.78 W 5959652.70 N 643296.51 E 7.105 -1.66 Window Point 5652.84 9.280 220.490 5577.73 5651.00 67.768 24.97 W 5959649.62 N 643294.38 E 6.804 -2.81 5684.00 9.660 234.050 5608.47 5681.74 71.20 8 28.72 W 5959646.10 N 643290.70 E 7.246 -5.31 5716,90 11 .400 246.930 5640.82 5714.09 74.108 33.94 W 5959643.11 N 643285.52 E 8.866 -9.39 5749,03 13,120 257.600 5672,22 5745.49 76.13 8 40.43 W 5959640.96 N 643279.08 E 8.832 -14.93 .-, 5779,31 14,270 265,780 5701.64 5774.91 77.14 8 47.51 W 5959639.81 N 643272.02 E 7.429 -21.35 5811,62 16,190 272.760 5732,82 5806,09 77.22 8 55.98 W 5959639.57 N 643263.55 E 8.207 -29,38 5842,23 17.610 278.040 5762,11 5835.38 76.36 8 64.83 W 5959640.26 N 643254.69 E 6.827 -38,06 5873,87 17,830 278.040 5792.24 5865.51 75.02 8 74.36 W 5959641.42 N 643245.13 E 0.695 -47.54 5905.40 19.480 286.020 5822.12 5895.39 72.89 S 84.20 W 5959643.36 N 643235.26 E 9.628 -57.55 5937,35 21.240 283.900 5852.08 5925.35 70.03 8 94.94 W 5959646.01 N 643224.46 E 5.972 -68.65 S969.96 22,510 284.030 5882.34 5955.61 67.1 0 8 106.73 W 5959648.72 N 643212.62 E 3.897 -80,77 6002.49 23.640 286.470 5912.26 5985.53 63.748 119.02 W 5959651.84 N 643200.26 E 4.550 -93,50 6097,31 26,310 290.010 5998.21 6071.48 51.158 157.01 W 5959663.70 N 643162.04 E 3.226 -133,52 6129,66 27.690 286.800 6027.04 6100.31 46.53 8 170.94 W 5959668.06 N 643148.03 E 6.203 -148.20 6195,18 29,580 283.450 6084.55 6157.82 38.36 8 201.25 W 5959675.64 N 643117.57 E 3.784 -179.54 6290,61 33.540 267.360 6165,99 6239.26 34.09 8 250.60 W 5959678.98 N 643068.15 E 9.718 -227.80 6385,92 36,050 254.930 6244.35 6317.62 42.61 8 304.06 W 5959669.44 N 643014.86 E 7.881 -276.01 6481.03 37.210 246.930 6320.72 6393.99 61.168 357.57 W 5959649.87 N 642961.71 E 5.162 -321.17 6576,08 38.390 234.920 6395.93 6469.20 89.43 8 408.24 W 5959620.64 N 642911.59 E 7.834 -360.62 6670,98 44,090 226.990 6467.31 6540.58 128.94 8 456.57 W 5959580.21 N 642864.02 E 8.141 -394.38 6766.31 49.550 220.610 6532.55 6605.82 179.178 504.49 W 5959529.08 N 642817.07 E 7.520 -424.43 ~' 6862.23 54.800 213.590 6591.40 6664.67 239.61 8 550.00 W 5959467.79 N 642772.72 E 7.956 -449.03 6956.85 58.680 206.480 6643.33 6716.60 308.08 8 589.46 W 5959398.58 N 642734.58 E 7.500 -465.40 7051.52 58.270 207.010 6692.83 6766.10 380.148 625.77 W 5959325.83 N 642699.64 E 0.644 -477.67 7146.19 57.950 206.140 6742.85 6816.12 452.03 8 661.73 W 5959253.27 N 642665.06 E 0.850 -489.66 7242.09 57.160 206.040 6794.30 6867.57 524.71 8 697.32 W 5959179.93 N 642630.86 E 0.828 -501.05 7337.26 59.430 205.770 6844.31 6917.58 597.548 732.69 W 5959106.44 N 642596.89 E 2.397 -512.18 7431.86 59.620 205.900 6892.29 6965.56 670.928 768.22 W 5959032.39 N 642562.76 E 0.233 -523.30 7526.31 58.900 205.230 6940.56 7013.83 744.158 803.25 W 5958958.51 N 642529.13 E 0.976 -533.98 7620.13 58.700 205.560 6989.17 7062.44 816.65 8 837.67 W 5958885.37 N 642496.11 E 0.369 -544.31 7712.58 58.420 205.180 7037.39 7110.66 887.928 871.47 W 5958813.47 N 642463.68 E 0.463 -554.43 7806.94 57,580 204.260 7087.39 7160.66 960.60 8 904.93 W 5958740.15 N 642431.60 E 1.215 -563.80 7901.28 58.330 205,540 7137.45 7210.72 1033.138 938.60 W 5958667.00 N 642399.32 E 1.398 -573.41 6 January, 2003 - 15:00 Page 20f6 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services ;. Survey Report for PBU_WOA H Pad - H-02A MWD Your Ref: AP/500292010001 Job No. AKMW22140, Surveyed: 4 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7995,31 58.400 204.880 7186.77 7260.04 1105.56 S 972.70 W 5958593.93 N 642366.61 E 0.602 -583.46 8088.78 57.900 204.440 7236.09 7309.36 1177.72 S 1005.83 W 5958521.16 N 642334.86 E 0.668 -592.66 8182.09 59,560 204,730 7284.52 7357.79 1250.24 S 1039.01 W 5958448.01 N 642303.07 E 1.799 -601.81 8277.35 59.480 204.830 7332.84 7406.11 1324.78 S 1073.42 W 5958372.84 N 642270.09 E 0.123 -611.50 8371.46 59.260 204,890 7380.79 7454.06 1398.25 S 1107.46 W 5958298.72 N 642237.45 E 0.240 -621.18 ~ 8464,50 59,050 204,850 7428.50 7501.77 1470.728 1141.06 W 5958225.62 N 642205.25 E 0.229 -630,73 8558,86 58,340 204,390 7477.52 7550.79 1544.01 8 1174.65 W 5958151.71 N 642173,06 E 0.860 -640,03 8651.98 60,190 203,970 7525,11 7598.38 1617.038 1207.43 W 5958078.08 N 642141.68 E 2,024 -648,64 8746.79 60,520 204.460 7572.01 7645.28 1692.188 1241 .22 W 5958002.30 N 642109.32 E 0.568 -657.56 8841,00 60.420 204.680 7618.44 7691.71 1766.738 1275.31 W 5957927.11 N 642076.67 E 0.229 -666.94 8935,32 60.050 204.490 7665.27 7738.54 1841.188 1309.37 W 5957852.02 N 642044.03 E 0.429 -676.33 9029,29 59,690 204.410 7712.44 7785,71 1915.178 1343.01 W 5957777.41 N 642011.81 E 0.390 -685.46 9123.10 59,120 204,220 7760.18 7833.45 1988.758 1376.26 W 5957703.20 N 641979.97 E 0.632 -694,34 n21 6.48 58,960 205.430 7808.22 7881.49 2061.438 1409.88 W 5957629.90 N 641947.74 E 1.124 -703.86 9307.48 58.470 204,510 7855.48 7928.75 2131.938 1442.71 W 5957558.79 N 641916.26 E 1.018 -713,30 9405.43 59.260 203.680 7906,12 7979.39 2208.46 8 1476.93 W 5957481.62 N 641883.50 E 1.085 -722.20 9500,17 59.040 202,530 7954.71 8027.98 2283.27 S 1508.85 W 5957406.21 N 641853.02 E 1.068 -729.43 9594.79 58,850 203.330 8003.52 8076.79 2357.928 1540.43 W 5957330.97 N 641822.86 E 0.752 -736.40 9688.79 58.320 200.930 8052.52 8125.79 2432.22 S 1570.65 W 5957256.11 N 641794.07 E 2.251 -742.18 9783,62 57.970 197.770 8102,58 8175.85 2508.20 8 1597.34 W 5957179.63 N 641768.83 E 2.854 -744.08 9877.85 57.550 195.100 8152,85 8226.12 2584.64 S 1619.89 W 5957102.78 N 641747.74 E 2.438 -741.91 9972.04 58.570 191.060 8202.70 8275.97 2662.47 S 1637.96 W 5957024.62 N 641731.16 E 3.797 -735.04 10065.79 58.710 189.030 8251 .49 8324.76 2741.29 S 1651.92W 5956945.54 N 641718.71 E 1.855 -723.96 ~ 10159.03 58.120 186.070 8300.33 8373.60 2820.02 S 1662.36 W 5956866.64 N 641709.77 E 2.777 -709.56 10253.32 58.550 184.470 8349.83 8423.10 2899.93 S 1669.73 W 5956786.60 N 641703.93 E 1.515 -691.88 10347.83 60.830 177.060 8397.58 8470.85 2981.42 S 1670.75 W 5956705.10 N 641704.46 E 7.184 -667.67 10442.09 61.110 171.770 8443.34 8516.61 3063.40 S 1662.73 W 5956623.29 N 641714.04 E 4,916 -634.71 10535.90 60.750 170.440 8488.92 8562.19 3144.41 8 1650.06 W 5956542.54 N 641728.26 E 1.297 -597.62 10629.70 59,990 170.500 8535.30 8608.57 3224.82 S 1636.56 W 5956462.40 N 641743.29 E 0.812 -559.94 10724.46 59.620 170.760 8582.96 8656.23 3305.628 1623.22 W 5956381.86 N 641758.16 E 0.457 -522.28 10783.91 58.670 166.980 8613.45 8686.72 3355.69 8 1613.38 W 5956331.99 N 641768.96 E 5.687 -497.45 10893,16 58.450 162,790 8670.46 8743.73 3445.64 S 1589.09 W 5956242.52 N 641794.96 E 3.278 -446.55 10925.26 57,510 157,860 8687.49 8760.76 3471.26 S 1579.94 W 5956217.08 N 641804.60 E 13.345 -429.93 10955.59 58.520 151,630 8703.56 8776.83 3494.51 8 1568.96 W 5956194.05 N 641816.01 E 17.735 -412.31 10985,87 59.810 147,700 8719.09 8792.36 3516.94 S 1555.83 W 5956171.87 N 641829.57 E 11.930 -392.89 6 January, 2003 - 15:00 Page 3 of6 DrillQl1est 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU _WOA H Pad - H-02A MWD Your Ref: API 500292010001 Job No. AKMW22140, Surveyed: 4 September, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 11019.30 63,240 142,320 8735.03 8808.30 3540.98 S 1538.97 W 5956148.15 N 641846.89 E 17.471 -369.43 11050,74 64,130 137.830 8748.98 8822.25 3562.58 S 1520.89 W 5956126.90 N 641865.38 E 13.110 -345.55 11080,53 65,170 133.500 8761,73 8835.00 3581.83 S 1502.08 W 5956108.02 N 641884.55 E 13.591 -321.71 11114,06 67,050 129.680 8775.32 8848.59 3602.17 S 1479.15 W 5956088.12 N 641907.86 E 11.829 -293.62 11145,27 68,780 127.470 8787.05 8860.32 3620.20 S 1456.54 W 5956070.53 N 641930.81 E 8.589 -266.55 ~ 11173,29 70.560 129,580 8796.79 8870.06 3636.56 S 1435.99 W 5956054.56 N 641951.67 E 9.498 -241.95 11208,06 72.760 124,690 8807.73 8881.00 3656.47 S 1409.68 W 5956035.15 N 641978.35 E 14.772 -210,78 11239,04 74,100 123,120 8816,57 8889.84 3673.03 S 1385.04 W 5956019.06 N 642003.31 E 6.504 -182.22 11267.17 75,640 121,920 8823.91 8897.18 3687.63 S 1362.14 W 5956004.91 N 642026.48 E 6.850 -155.94 11300,83 78.090 119.210 8831.56 8904,83 3704.29 S 1333.92 W 5955988.79 N 642055.01 E 10.698 -123,95 11331,82 80,540 120.900 8837.31 8910.58 3719.54 S 1307.57 W 5955974.04 N 642081.65 E 9.551 -94,17 11359,92 81 .600 109.590 8841.68 8914.95 3731.36 S 1282.50 W 5955962.70 N 642106,94 E 39.938 -66.68 11393,53 83,090 101,120 8846.17 8919.44 3740.17 S 1250.41 W 5955954.51 N 642139.19E 25,366 -33.44 11424,96 84,21 0 98,910 8849.64 8922.91 3745.60 S 1219.65 W 5955949.67 N 642170.05 E 7,844 -2,50 11453,26 84.450 94,650 8852.44 8925.71 3748.92 S 1191.69 W 5955946.88 N 642198.07 E 15.003 25.11 11487,32 86,680 92.520 8855.08 8928.35 3751,04 S 1157.80 W 5955945.40 N 642231.99 E 9.041 58,00 11517,93 88.770 92.250 8856.29 8929.56 3752.31 S 1127.25 W 5955944.71 N 642262.56 E 6.884 87.45 11547,38 89.450 91.610 8856.75 8930.02 3753.31 S 1097.82 W 5955944.28 N 642292.01 E 3.171 115,75 11580.34 92,520 92.790 8856.18 8929.45 3754.57 S 1064.89 W 5955943.64 N 642324.95 E 9.978 147.45 11611,21 96.100 92.410 8853.86 8927.13 3755.97 S 1034.15 W 5955942.83 N 642355.72 E 11.662 177.13 11639,75 96.730 92.250 8850.67 8923.94 3757.12 S 1005.81 W 5955942.22 N 642384.07 E 2.277 204.43 11673,60 98.460 92.800 8846.20 8919.47 3758.60 S 972.29 W 5955941.38 N 642417.61 E 5.359 236.77 11732.02 99.270 95.030 8837.20 8910.47 3762.54 S 914.71 W 5955938.54 N 642475.26 E 4.018 292.75 ~ 11825.41 95.790 101,900 8824.94 8898.21 3776.18 S 823.20 W 5955926.65 N 642567.01 E 8.189 383.99 11872,90 96.040 101.750 8820.05 8893.32 3785.86 S 776.97 W 5955917.85 N 642613.42 E 0.613 430.95 11920,57 95.980 107.090 8815.06 8888.33 3797.66 S 731.07 W 5955906.93 N 642659.53 E 11.141 478.25 12015.29 96.720 103.910 8804.58 8877.85 3822.82 S 640.37 W 5955883.51 N 642750.70 E 3.427 572.29 12108.94 97.280 100.300 8793.16 8866.43 3842.31 S 549.50 W 5955865.75 N 642841.92 E 3.872 664.73 12202.79 97.720 101.590 8780.91 8854.18 3859.97 S 458.15 W 5955849.83 N 642933.60 E 1 .441 757.07 12295,56 96.420 101.230 8769.49 8842.76 3878.18 S 367.90 W 5955833.34 N 643024.17 E 1 .453 848.53 12363.04 97.780 100.390 8761.15 8834.42 3890.74 S 302.13 W 5955822.04 N 643090.17 E 2.364 914.96 12457.39 87.910 106,150 8756.47 8829.74 3912.36 S 210.57 W 5955802.18 N 643182.13 E 12.105 1008.72 12491.24 86.740 112.080 8758.05 8831.32 3923.42 S 178.64 W 5955791.72 N 643214.26 E 17,837 1042.51 12522,06 86.430 108.820 8759.89 8833.16 3934.17 S 149.82 W 5955781.53 N 643243.29 E 10,607 1073.24 12552.40 86.300 108.440 8761.81 8835.08 3943.85 S 121.12 W 5955772.40 N 643272.16 E 1.321 1103.52 6 January, 2003 - 15:00 Page 4 0'6 DrillQLlest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for P8U_WOA H Pad.. H-02A MWD Your Ref: AP/500292010001 Job No. AKMW22140, Surveyed: 4 September, 2002 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 12643.56 82.410 102.160 8770.79 8844.06 3967.78 S 33.69 W 5955750.14 N 643360.04 E 12736.70 80.480 91.300 8784.68 8857.95 3978.58 S 57.63 E 5955741.08 N 643451.54 E 12830,57 88,890 88.270 8793,37 8866.64 3978.21 S 151.00 E 5955743.23 N 643544.89 E 12883.77 92,520 88.770 8792.72 8865.99 3976.84 S 204.17 E 5955745.62 N 643598.02 E 12950,00 92,520 88.770 8789.80 8863.07 3975.42 S 270.32 E 5955748.30 N 643664.14 E All data is in Feet (US) unless otherwise stated, Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference, Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US), Vertical Section is from Well Reference and calculated along an Azimuth of 108.000° (True). Magnetic Declination at Surface is 26,0500(22-Aug-02) B<Jsed upon ~v1illirnurn Curvature type calculations, at a Measured Depth of 12950.00ft., The Bottom Hole Displacement is 3984,60ft., in the Direction of 176.110° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (tt) (tt) Comment 5624,37 5630.00 12950.00 5622.92 5628.4 7 8863.07 63.93 S 64.72 S 3975.42 S 22.30 W 22.78 W 270.32 E Tie On Point Window Point Projected Survey 6 January, 2003 - 15:00 Page 5 0'6 Dogleg Rate (0/100tt) 8.074 11.714 9.517 6.888 0,000 Vertical Section 1194.07 1284.26 1372.95 1423.09 1485,57 BPXA Comment Projected Survey ~- ........... DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU _WOA H Pad - H-02A MWD Your Ref: AP/500292010001 Job No. AKMW22140. Surveyed: 4 September. 2002 BPXA North Slope Alaska Survey tool program for H-02A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 5509,27 0.00 5509.27 5508,34 12950.00 5508.34 AK-1 BP _HG - BP High Accuracy Gyro(H-02) 8863.07 MWD Magnetic(H-02APB1 MWD) ~ '- .-.".,1'" 6 January, 2003 - 15:00 Page 60'6 DrillQuest 3.03.02.004 ) ) dÖd-Jte 0 31-Dec-02 Phillips Alaska, Inc. Attn: Sandy Lemke ATO-148 700 G Street Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well H-02A PB1 Dear Sir / Madam Enclosed is one hard copy and a barcoded disk with the *.PTT and *.PDF files. Tie-on Survey: 5,509.27' MD Window / Kickoff Survey 5,529.00' MD (if applicable) Projected Survey: 10,505.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECE\VED JAN 0 9 2003 AIa8ka OK & Gal Cons. ConIIi8IiOn AndØIge Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA H Pad H-02APB1 ,-,3 Job No. AKZZ22140, Surveyed: 27 August, 2002 Survey Report 16 October, 2002 Your Ref: API 500292010070 Surface Coordinates: 5959717.84 N, 643318.05 E (70017' 50.7912" N, 148050' 21.7328" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 959717.84 N, 143318.05 E (Grid) Surface Coordinates relative to Structure Reference: 2107.92 N, 1994.06 E(True) Kelly Bushing: 73.27ft above Mean Sea Level Elevation relative to Project V Reference: 73.27ft Elevation relative to Structure Reference: 73.27ft =pe.-..-.y-sut'1 DRIL.L.ING SEEAVIc:es A Halliburton Company Survey Ref: svy11341 Sperry-Sun Drilling Services Survey Report for PBU _WOA H Pad. H-02APB1 Your Ref: API 500292010070 Job No. AKZZ22140, Surveyed: 27 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5509.27 1.420 211.000 5435.07 5508.34 55.62 8 17.20 W 5959661.90 N 643301.91 E 58.22 Tie On Point AK-6 BP JFR-AK 5529.00 1.420 212.380 5454.80 5528.07 56.04 8 17.46 W 5959661.48 N 643301.66 E 0.173 58.70 Window Point 5562.00 4.630 211.650 5487.75 5561.02 57.528 18.38 W 5959659.98 N 643300.77 E 9.728 60.38 5591.35 6.770 211.440 5516.95 5590.22 60.00 8 19.90 W 5959657.4 7 N 643299.29 E 7.292 63.21 5624.37 9.250 211.320 5549.65 5622.92 63.93 8 22.30 W 5959653.50 N 643296.97 E 7.511 67.67 5656.05 11.490 211.260 5580.81 5654.08 68.80 8 25.26 W 5959648.57 N 643294.11 E 7.071 73.20 5688.42 12.850 211.220 5612.45 5685.72 74.648 28.80 W 5959642.67 N 643290.68 E 4.202 79.83 5719.47 14.730 211.190 5642.60 5715.87 80.97 8 32.63 W 5959636.26 N 643286.97 E 6.055 87.01 5751.38 16.550 211.160 5673.33 5746.60 88.33 8 37.09 W 5959628.82 N 643282.66 E 5.704 95.36 5784.54 17.580 211.140 5705.03 5778.30 96.66 8 42.12 W 5959620.40 N 643277.78 E 3.106 104.81 5818.75 18.480 211.130 5737.56 5810.83 105.728 47.59 W 5959611.23 N 643272.48 E 2.631 115.09 5850.32 19. 120 211.120 5767.44 5840.71 114.438 52.85 W 5959602.42 N 643267.39 E 2.027 124.97 5879,50 19.270 211.110 5795.00 5868.27 122.64 8 57.81 W 5959594.12 N 643262.59 E 0.514 134.29 5914.00 20,530 210.950 5827.44 5900.71 132.71 8 63.86 W 5959583.94 N 643256.73 E 3.656 145.70 5945.74 22.640 209.720 5856.95 5930.22 142.798 69.76 W 5959573.75 N 643251.03 E 6.799 157.08 5974,16 24.660 208.000 5882.99 5956.26 152.778 75.25 W 5959563.66 N 643245.73 E 7.510 168.25 6007.96 27.110 206.380 5913.39 5986.66 165.90 8 81.98 W 5959550.41 N 643239.24 E 7.544 182.78 6039.18 29.400 204.270 5940.89 6014.16 179.26 8 88.30 W 5959536.93 N 643233.19 E 8.001 197.42 6069.99 31.600 204.350 5967.44 6040.71 193.51 8 94.73 W 5959522.56 N 643227.02 E 7.142 212.94 6104.83 34.140 203.500 5996.70 6069.97 210.798 102.40 W 5959505.13 N 643219.69 E 7.410 231.72 6134.75 35.660 202.830 6021.24 6094.51 226.53 8 109.13 W 5959489.27 N 643213.26 E 5.239 248.75 6165.51 35.580 203.080 6046.24 6119.51 243.03 8 116.12 W 5959472.64 N 643206.59 E 0.540 266.57 ~. 6199.01 35.660 199.850 6073.48 6146.75 261.188 123.25 W 5959454.36 N 643199.80 E 5.620 286.03 6230.34 36.770 202.410 6098.75 6172.02 278.44 8 129.93 W 5959436.97 N 643193.45 E 5.988 304.49 6261 .52 38.110 204,140 6123.51 6196.78 295.85 8 137.42 W 5959419.42 N 643186.29 E 5.463 323.34 6356,66 38.880 204.580 6197.97 6271.24 349.80 8 161.85W 5959365.02 N 643162.90 E 0.859 382.12 6451.40 38.250 204.490 6272.05 6345.32 403.52 8 186.37 W 5959310.84 N 643139.40 E 0.668 440.71 6546.96 36.730 203,870 6347.87 6421.14 456.58 8 210.20 W 5959257.34 N 643116.59 E 1,639 498.45 6643.20 38.740 208.800 6424,00 6497.27 509.30 8 236.36 W 5959204.13 N 643091.44 E 3,766 556.57 6736.95 40,630 209.340 6496.14 6569.41 561.62 8 265.45 W 5959151.26 N 643063.36 E 2,049 615.17 16 October, 2002 - 10:24 Page 20f5 DrillQlIest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU_WOA H Pad - H-02APB1 Your Ref: API 500292010010 Job No. AKZZ22140, Surveyed: 27 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6832.08 46.540 211.810 6565.02 6638.29 618.01 8 298.86 W 5959094.24 N 643031.03 E 6.464 678.95 6927,72 45,980 212.940 6631 .15 6704.42 676.37 8 335.86 W 5959035.19 N 642995.15 E 1.035 745.68 7023.77 49,710 211.450 6695.60 6768.87 736.63 8 373.76 W 5958974.22 N 642958.40 E 4.050 814.49 7118,61 49.560 211.420 6757.02 6830.29 798.28 8 411.45 W 5958911.86 N 642921.90 E 0.160 884.57 7212,17 50.710 210.610 6816.99 6890.26 859.838 448.45 W 5958849.62 N 642886.08 E 1.397 954.33 923.56 8 .--- 7304.56 55.620 210.270 6872.37 6945.64 485.89 W 5958785.18 N 642849.86 E 5.323 1026.33 7397.60 58.820 209.890 6922.73 6996.00 991.25 8 525.09 W 5958716.76 N 642811.96 E 3.456 1102.61 7490.89 58.690 209.620 6971,12 7044.39 1060.498 564.67 W 5958646.77 N 642773.70 E 0.284 1180.50 7584.83 58.510 208.350 7020.07 7093.34 1130.638 603.53 W 5958575.91 N 642736.19 E 1.170 1259.02 7679.91 58.300 207.680 7069.88 7143.15 1202.128 641.57 W 5958503.70 N 642699.52 E 0.640 1338.60 7773.83 57.990 205.780 7119.45 7192.72 1273.37 8 677.45 W 5958431.79 N 642665.01 E 1.750 1417.29 7868.22 57.690 207.200 7169.70 7242.97 1344.888 713.09 W 5958359.60 N 642630.74 E 1.313 1496.17 7961.88 57.780 207.110 7219.70 7292.97 1415.358 749.23 W 5958288.46 N 642595.94 E 0.126 1574.21 8056,32 57.400 206.410 7270.31 7343.58 1486.548 785.13 W 5958216.60 N 642561.41 E 0.744 1652.85 8150.53 57.430 206,540 7321.05 7394.32 1557.608 820.52 W 5958144.88 N 642527.38 E 0.121 1731.22 8244.94 57.350 206.980 7371.93 7445.20 1628.60 8 856.33 W 5958073.20 N 642492.94 E 0.402 1809.67 8338.94 57.230 206,620 7422,73 7496.00 1699.208 891.99 W 5958001.94 N 642458.63 E 0.347 1887.68 8434.05 57.010 206.060 7474.36 7547.63 1770.788 927.43 W 5957929.69 N 642424.56 E 0.546 1966.57 8527.40 56.930 206.570 7525.24 7598.51 1840.948 962.12 W 5957858.89 N 642391.21 E 0.466 2043.87 8621.37 56.630 206.660 7576.72 7649.99 1911.228 997.34 W 5957787.95 N 642357.34 E 0.329 2121.45 8715.64 56,61 0 206.580 7628.59 7701.86 1981.598 1032.61 W 5957716.92 N 642323.41 E 0.074 2199.13 8810.09 56.510 206.970 7680.64 7753.91 2051.96 8 1068.12 W 5957645.89 N 642289.26 E 0.360 2276.87 8903.39 56,320 208.460 7732.25 7805.52 2120.768 1104.26 W 5957576.40 N 642254.43 E 1.346 2353.32 ~ 8996.94 56.290 207.010 7784.15 7857.42 2189.65 8 1140.48 W 5957506.84 N 642219.53 E 1 .290 2429.87 9090.96 55.540 207.160 7836.84 7910.11 2258.98 8 1175.94 W 5957436.85 N 642185.40 E 0.809 2506.60 9185.16 55,140 207.780 7890.42 7963.69 2327.738 1211.68 W 5957367.43 N 642150.98 E 0.688 2582.87 9278.79 55.020 207.470 7944.01 8017.28 2395.758 1247.28 W 5957298.74 N 642116.69 E 0.300 2658.41 9373.64 53,780 207.250 7999.23 8072.50 2464.24 8 1282.72 W 5957229.59 N 642082.56 E 1.321 2734.35 9468.17 53.810 207.240 8055.06 8128.33 2532.05 8 1317.64 W 5957161.12 N 642048.94 E 0.033 2809.48 9562.60 53,500 207,910 8111.03 8184.30 2599.478 1352.85 W 5957093.04 N 642015.02 E 0,659 2884.32 9656.43 53,320 207.280 8166,96 8240.23 2666.24 8 1387.75 W 5957025.62 N 641981.40 E 0.572 2958.45 9750.21 52.880 207.670 8223.27 8296.54 2732.788 1422.34 W 5956958.44 N 641948.08 E 0.575 3032,27 9843.46 52,610 206.650 8279.72 8352.99 2798.81 8 1456.23 W 5956891.77 N 641915.46 E 0.918 3105.40 9937.59 51.840 205,160 8337.38 8410.65 2865.73 8 1488.73 W 5956824.24 N 641884.24 E 1.495 3178.96 10032,03 51,300 206.180 8396.08 8469.35 2932.41 8 1520.78 W 5956756.96 N 641853.47 E 1,021 3252,16 ---- 16 October, 2002 - 10:24 Page 3 of5 DrillQuest 3.03.02.002 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 10125.93 50.900 204.680 8455.05 8528.32 10220.21 54.440 198,820 8512.24 8585.51 10314.14 60.720 191.730 8562.62 8635.89 10407.86 61.330 190.280 8608.02 8681.29 10429.59 61.110 189.730 8618.48 8691.75 10505,00 61.110 189.730 8654.92 8728.19 Sperry-Sun Drilling Services Survey Report for PBU_WOA H Pad - H-02APB1 Your Ref: AP/500292010070 Job No. AKZZ22140, Surveyed: 27 August, 2002 BPXA Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (°/1 OOft) 2998.40 S 1552.16 W 5956690.38 N 641823.35 E 1.314 3324.50 3068.00 S 1579.83 W 5956620.27 N 641797.02 E 6.204 3399.18 3144.42 S 1600.52 W 5956543.47 N 641777.78 E 9.230 3478.29 3224.90 S 1616.17 W 5956462.70 N 641763.67 E 1.502 3559.78 3243.66 S 1619.48 W 5956443.89 N 641760.72 E 2.439 3578.67 ~ 3308.73 S 1630.64 W 5956378.61 N 641750.81 E 0.000 3644.12 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 197.316° (True). Magnetic Declination at Surface is 26.0500(22-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 10505.00ft., The Bottom Hole Displacement is 3688.72ft., in the Direction of 206.235° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5509.27 5529.00 10505.00 5508.34 5528.07 8728.19 17.20 W 17.46 W 1630.64 W 55.62 S 56.04 S 3308.73 S 16 October, 2002 - 10:24 Comment '-" Tie On Point Window Point Projected Survey Page 4 0'5 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for PBU _WOA H Pad - H-02AP81 Your Ref: AP/500292010070 Job No. AKZZ22140, Surveyed: 27 August, 2002 BPXA North Slope Alaska Survey tool proøram for H-02APB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 5509.27 0.00 5509.27 5508.34 10505.00 5508.34 AK-1 BP _HG - BP High Accuracy Gyro(H-02) 8728.19 AK-6 BP _I FR-AK(H-02APB 1 ) --'" ~ 16 October, 2002 - 10:24 Page 5 0'5 DrillQuest 3.03.02.002 ) ) 31-Dec-02 Phillips Alaska, Inc. Attn: Sandy Lemke ATO-148 700 G Street Anchorage, AK 99501 Re: Distribution of Survey Data for Well H-02A PB 1 MWD Dear Sir / Madam Enclosed is one hard copy and a barcoded disk with the *.PTT and *.PDF files. Tie-on Survey: 5,509.27' MD Window / Kickoff Survey 5,529.00' MD (if applicable) Projected Survey: 10,505.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECE\\lED JAM 0 9 2.00~ Ht1Jø. Oi\ It Gaa cons. eommi8*W' ~ dQ"jfç;O . Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_WOA H Pad H-02APB1 MWD .~ Job No. AKMW22140, Surveyed: 27 August, 2002 Survey Report 16 October, 2002 Your Ref: AP/500292010070 Surface Coordinates: 5959717.84 N, 643318.05 E (70017' 50.7912" N, 148050'21.7328" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 959717.84 N, 143318.05 E (Grid) Surface Coordinates relative to Structure Reference: 2107.92 N, 1994.06 E(True) Kelly Bushing: 73.27ft above Mean Sea Level Elevation relative to Project V Reference: 73.27ft Elevation relative to Structure Reference: 73.27ft spel'r'\f-suf! DRILLING sSFtVIc:es A Halliburton Company Survey Ref: svy11343 Sperry-Sun Drilling Services Survey Report for PBU_WOA H Pad - H-02APB1 MWD Your Ref: API 500292010070 Job No. AKMW22140, Surveyed: 27 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5509.27 1.420 211.000 5435.07 5508.34 55.62 S 17.20 W 5959661.90 N 643301.91 E 58.22 Tie On Point MWD Magnetic 5529.00 1.420 212.380 5454.80 5528.07 56.04 S 17.46W 5959661.48 N 643301.66 E 0.173 58.70 Window Point 5562.00 4.630 211.650 5487.75 5561.02 57.52 S 18.38 W 5959659.98 N 643300.77 E 9.728 60.38 5591.35 6.770 211.440 5516.95 5590.22 60.00 S 19.90 W 5959657.47 N 643299.29 E 7.292 63.21 5624.37 9.250 211,320 5549.65 5622.92 63.93 S 22.30 W 5959653.50 N 643296.97 E 7.511 67.67 '-I 5656,05 11.490 211.260 5580.81 5654.08 68.80 S 25.26 W 5959648.57 N 643294.11 E 7.071 73.20 5688.42 12.850 211.220 5612.45 5685.72 74.64 S 28.80 W 5959642.67 N 643290.68 E 4.202 79.83 5719.47 14,730 211.190 5642.60 5715.87 80.97 S 32.63 W 5959636.26 N 643286.97 E 6.055 87.01 5751.38 16.550 211.160 5673.33 5746.60 88.33 S 37.09 W 5959628.82 N 643282.66 E 5.704 95.36 5784.54 17,580 211,140 5705.03 5778.30 96.66 S 42.12 W 5959620.40 N 643277.78 E 3.106 104.81 5818,75 18.480 211.130 5737.56 5810.83 105.72 S 47.59 W 5959611.23 N 643272.48 E 2.631 115.09 5850.32 19.120 211.120 5767.44 5840.71 114.43 S 52.85 W 5959602.42 N 643267.39 E 2.027 124.97 5879,50 19,270 211.110 5795.00 5868.27 122.64 S 57.81 W 5959594.12 N 643262.59 E 0.514 134.29 5914.00 20.530 211.100 5827.44 5900.71 132.70 S 63.88 W 5959583.95 N 643256.72 E 3.652 145.70 5945.74 22.640 209,850 5856.95 5930.22 142.76 S 69.79 W 5959573.77 N 643250.99 E 6.803 157.07 5974,16 24,660 208.100 5882.99 5956.26 152.74 S 75.31 W 5959563.69 N 643245.67 E 7.524 168.23 6007.96 27.11 0 206.460 5913.39 5986.66 165.86 S 82.06 W 5959550.45 N 643239.16 E 7.551 182.76 6039.18 29.400 204.580 5940.89 6014.16 179.19 S 88.42 W 5959536.99 N 643233.06 E 7.869 197.39 6069,99 31.600 204.530 5967.44 6040.71 193.42 S 94.92 W 5959522.65 N 643226.84 E 7.141 212.90 6104.83 34,140 203,730 5996.70 6069.97 210.67 S 102.64 W 5959505.25 N 643219.44 E 7.396 231 .68 6134.75 35.660 202.970 6021.24 6094.51 226.39 S 109.43 W 5959489.40 N 643212.96 E 5.284 248.70 6165,51 35.580 203.300 6046.24 6119.51 242.86 S 116.47 W 5959472.80 N 643206.24 E 0.677 266.52 ~ 6199.01 35.660 199.950 6073.48 6146.75 261.00 S 123.65 W 5959454.53 N 643199.40 E 5.828 285.97 6230,34 36,770 202.400 6098.75 6172.02 278.25 S 130.34 W 5959437.15 N 643193.04 E 5.822 304.44 6261.52 38.110 204,150 6123.51 6196.78 295.66 S 137.84 W 5959419.61 N 643185.88 E 5.487 323.29 6356.66 38,880 204,310 6197.97 6271.24 349.66 S 162.14 W 5959365.15 N 643162.61 E 0.816 382.07 6451.40 38,250 204.230 6272.05 6345.32 403.50 S 186.42 W 5959310.86 N 643139.36 E 0.667 440.70 6546,96 36,730 203.460 6347.87 6421.14 456.69 S 209.93 W 5959257.23 N 643116.86 E 1.664 498.48 6643.20 38.7 40 208.460 6424.00 6497.27 509.58 S 235.75 W 5959203.85 N 643092.06 E 3.803 556.66 6736.95 40.630 209.430 6496.14 6569.41 561.96 S 264.73 W 5959150.93 N 643064.09 E 2.121 615.29 16 October, 2002 - 10:28 Page 20f5 DrillQuest 3.03.02.002 ., Sperry-Sun Drilling Services Survey Report for PBU_WOA H Pad - H-02APB1 MWD Your Ref: API 500292010070 Job No. AKMW22140, Surveyed: 27 August, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6832,08 46.540 211.810 6565.02 6638.29 618.338 298.18 W 5959093.93 N 643031.72 E 6.447 679.06 6927.72 45.980 212.890 6631 .15 6704.42 676.71 8 335.15 W 5959034.87 N 642995.87 E 1.004 745.79 7023,77 49.710 211.490 6695.60 6768.87 736.97 8 373.05 W 5958973.89 N 642959.12 E 4,031 814.60 7118.61 49.560 211.480 6757.02 6830.29 798.59 8 410.79 W 5958911.56 N 642922.56 E 0.158 884.66 7212,17 50.710 210.700 6816.99 6890.26 860.09 8 447.87 W 5958849.37 N 642886.66 E 1.386 954.41 ~' 7304.56 55.620 210.420 6872.37 6945.64 923.748 485.45 W 5958785.01 N 642850.30 E 5.320 1026.37 7397.60 58.820 209.910 6922.73 6996.00 991.37 8 524.75 W 5958716.64 N 642812.30 E 3.4 70 1102.62 7490.89 58.690 209.920 6971.12 7044.39 1060.508 564.52 W 5958646.77 N 642773.85 E 0.140 1180.46 7584.83 58.510 208.580 7020.07 7093.34 1130.46 8 603.70 W 5958576.08 N 642736.02 E 1 .233 1258.91 7679.91 58.300 207.660 7069.88 7143.15 1201.888 641.87 W 5958503.93 N 642699.21 E 0.853 1338.46 7773.83 57.990 205.740 7119.45 7192.72 1273.158 677.72 W 5958432.00 N 642664.74 E 1.767 1417.16 7868.22 57.690 206.930 7169.70 7242.97 1344.768 713.16 W 5958359.73 N 642630.66 E 1.114 1496.08 7961.88 57.780 206.650 7219.70 7292.97 1415.458 748.86 W 5958288.36 N 642596.32 E 0.270 1574.19 8056,32 57.400 206.040 7270.31 7343.58 1486.90 8 784.24 W 5958216.25 N 642562.31 E 0.678 1652.93 8150.53 57.430 206.210 7321.05 7394.32 1558.178 819.19 W 5958144.33 N 642528.72 E 0.155 1731.38 8244.94 57.350 206.690 7371.93 7445.20 1629.388 854.62 W 5958072.46 N 642494.66 E 0.437 1809.90 8338.94 57,230 206.420 7422.73 7496.00 1700.128 889.98 W 5958001.05 N 642460.66 E 0.273 1887.96 8434.05 57,010 205.950 7474.36 7547.63 1771.808 925.22 W 5957928.72 N 642426.78 E 0.475 1966.88 8527.40 56.930 206.450 7525.24 7598.51 1842.02 8 959.78 W 5957857.85 N 642393.58 E 0.457 2044.21 8621,37 56.630 206.490 7576.73 7650.00 1912.398 994.82 W 5957786.82 N 642359.89 E 0.321 2121.82 8715.64 56.610 206.590 7628.59 7701.86 1982.828 1029.99 W 5957715.74 N 642326.06 E 0.091 2199.52 8810.09 56.510 207.070 7680.64 7753.91 2053.158 1065.56 W 5957644.74 N 642291.84 E 0.437 2277.25 8903,39 56.320 208.570 7732.25 7805.52 2121.898 1101.83 W 5957575.33 N 642256.88 E 1.355 2353.67 : "'-" 8996,94 56.290 207.180 7784.15 7857.42 2190.69 8 1138.22 W 5957505.84 N 642221.81 E 1.237 2430.18 9090.96 55.540 207.200 7836.84 7910.11 2259.958 1173.80 W 5957435.92 N 642187.56 E 0.798 2506.90 9185,16 55.140 207,950 7890.42 7963.69 2328.638 1209.67 W 5957366.56 N 642153.01 E 0.781 2583.14 9278.79 55.020 207.720 7944.01 8017.28 2396.52 8 1245.52 W 5957298.00 N 642118.46 E 0.239 2658.62 9373.64 53.780 207.430 7999.23 8072.50 2464.88 8 1281.22 W 5957228.97 N 642084.07 E 1.331 2734.51 9468.17 53,810 207.340 8055.06 8128.33 2532.61 8 1316.30 W 5957160.59 N 642050.28 E 0.083 2809.61 9562,60 53,500 207.730 8111.03 8184.30 2600.05 8 1351.46 W 5957092.49 N 642016.42 E 0.467 2884.47 9656.43 53.320 207.620 8166.96 8240.23 2666.778 1386.45 W 5957025.11 N 641982.70 E 0.214 2958.58 9750.21 52,880 206.740 8223.27 8296.54 2733.48 8 1420.71 W 5956957.76 N 641949.72 E 0.885 3032.46 9843.46 52,610 205,760 8279.72 8352.99 2800.05 8 1453.54 W 5956890.58 N 641918.17 E 0.885 3105.78 9937.59 51.840 203.850 8337.38 8410.65 2867.58 S 1484.76 W 5956822.47 N 641888.25 E 1.800 3179,54 10032,03 51 ,300 205.200 8396.08 8469.35 2934.89 8 1515.46 W 5956754.59 N 641858.83 E 1.257 3252.93 16 October, 2002 - 10:28 Page 3 of5 DrillQuest 3.03.02.002 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 10125.93 50.900 204.900 8455.05 8528.32 10220.21 54.440 199.000 8512.24 8585.51 10314.14 60,720 191.760 8562.62 8635.89 10407.86 61.330 190.540 8608.02 8681.29 10429.59 61.110 189.680 8618.49 8691.76 10505.00 61.110 189.680 8654.92 8728.19 .. Sperry-Sun Drilling Services Survey Report for PBU_WOA H Pad - H..()2APB1 MWD Your Ref: AP/500292010070 Job No. AKMW22140, Surveyed: 27 August, 2002 BPXA Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (°/1 OOft) 3001.09 S 1546.40 W 5956687.81 N 641829.16 E 0.493 3325.35 3070.59 S 1574.32 W 5956617.79 N 641802.58 E 6.231 3400.01 3146.97 S 1595.14 W 5956541.02 N 641783.21 E 9.323 3479.12 3227.41 S 1611.00 W 5956460.30 N 641768.89 E 1.312 3560.63 3246.16 S 1614.34 W 5956441 .49 N 641765.91 E 3.614 3579.53 "~ 3311.24 S 1625.44 W 5956376.20 N 641756.05 E 0.000 3644.97 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 197.316° (True). Magnetic Declination at Surface is 26.0500(22-Aug-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 10505.00ft., The Bottom Hole Displacement is 3688.68ft., in the Direction of 206.146° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5509.27 5529,00 10505.00 5508.34 5528.07 8728,19 55.62 S 56.04 S 3311.24 S 17.20 W 17.46 W 1625.44 W 16 October, 2002 - 10:28 Comment .~' Tie On Point Window Point Projected Survey Page 4 0'5 DriflQuest 3.03.02.002 .. Sperry-Sun Drilling Services Survey Report for PBU_WOA H Pad - H-02APB1 MWD Your Ref: AP/500292010070 Job No. AKMW22140, Surveyed: 27 August, 2002 ,. ( BPXA North Slope Alaska Survey tool program for H-02APB1 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 5509.27 0.00 5509.27 5508.34 10505.00 5508.34 AK-1 BP _HG - BP High Accuracy Gyro(H-02) 8728.19 MWD Magnetic(H-02APB1 MWD) ~ °,-", 16 October, 2002 - 10:28 Page 50'5 Dril/Quest 3.03.02.002 1. Type of Request: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 0 Suspend 0 Plugging 0 Time Extension 0 Perforate /. 0 Repair Well 0 Pull Tubing 0 Variance II Other 0 Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate Re-Enter Ops Shutdown ) ) kJ6Æ- 12-/iOf()1- ¡Vlv6 (l.{' 0(0 L ~ J 2.rl11 L..øí \ '11( 10 y 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: IBI Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) Plan AKB = 74.85' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 1073' SNL, 1266' WEL, SEC. 21, T11 N, R13E, UM At top of productive interval 515' NSL, 2583' WEL, SEC. 21, T11 N, R13E, UM (As Planned, Not Penetrated Yet) At effective depth 4456' SNL, 2864' WEL, SEC. 21, T11 N, R13E, UM (Approx. Current PBTD at 10817') At total depth 4493' SNL, 2855' WEL, SEC. 21, T11 N, R13E, UM (Approx, Current TO at 10861') 12. Present well condition summary Total depth: measured 8. Well Number/ H-02A ~p r11tN)Jmber ~2-jß6' I 302-317 1. I Number 50- 029-201 00-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool true vertical 10861 feet 8728 feet 10817 feet 8704 feet Plugs (measured) true vertical Effective depth: measured Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 6881' 7" 165 sx Class 'GI 100' 2306' 5529' (TOW) / 3980' - 10861' 3980' - 8727' 100' 2306' 8299' 100' 30" 275 sx cement 2306' 18-5/8" 4200 sx Permafrost 8300' 13-3/8" x 9-518" 1561 sx Class 'G" 1825 sx PF true vertical None RECE\VED DEC 10 2002 n Gomm\SS\IlD Freeze Protection String: 4-1/2",12.6#, L-80 to 2007"'as\taOU,&GaS\Jt>ßS8ø . . ~. . ...., AnchOrag Perforation depth: measured None Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) None 13. Attachments IBI Description Summary of Proposal 14. Estimated date for commencing operati°o/ December 20, 2002 16. If proposal was verbally approved 0 Detailed Operations Program 15. Status of well classifications as: IBI Oil 0 Gas 0 Suspended 0 BOP Sketch " Service Name of approver Contact Engineer Name/Number: Phil Smith, 564-4897 17. I hereby certify that the ':oregoing is true and correct to the best of my knowledge Signed Billlsaacson ~." ,\ L . Title Senior Drilling Engineer , Date Approved Prepared By Name/Number: Terrie Hubble, 564-4628 Date DEL I. 2CXJL " .. "C;p~sSiOJt~~.~qmy , . . . Conditions of Approval: Notify Commission so representative ")t"'itness I A IN....' -::¿ 177' Plug integrity - BOP Test Location clearance - pprova 0...::1 ¿? d- ""~.J Meçhanicallntegrity Test - . Su~~q~ent form .lequired 10- 4-07 Te»t- 'S-o P6 fr; ~£,CÃ? P <;¿ a A-f( tO~~(,~ p-e-v~f ~~(J~4--eL~Ç afpl't. . . '7111~'ð Approved by order of the Commission 0 IC,INAL SIGNED DV !' c\. (:.~ CommiSSioner Date. /t~ 1.( () V Form 10-403 Rev. 06/15/88 t'( M L. Bill ,. .,: ~8J{M S B F l DEC I 2 200fubmlt In n hcate ~ , ¡. ') ) To: Winton Aubert - AOGCC Date: December 9, 2002 From: Phil Smith - BPXA GPB Rotary Drilling Subject: Reference: H-02A Re-enter Operations Shut Down API # 50-029-20100-00 Nabors 2ES is scheduled to return to operations on H-02A on or about December 20th, 2002 to resume, operations drilling 6 1/8" horizontal section as previously planned. The T' casing is in place as shown in ~ the updated proposed completion diagram attached. Scope Ria Operations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace weU to seawater. Set TWC. 3. Nipple down tree. Nipple up and test SOPE. /' 4. Pull the 4Y2" freeze protections tubing. ' 5. RIH with 6 1/8" drilling assembly. Test casing to 3000 psi. /' 6. Drill out shoe and displace well to 8.5 ppg Flo Pro mud. Drill 20' 0 ew formation, 7. Drill 6 1/8" production hole as per directional plan to TO well at 12,9 ' MD. /' 8. Short trip, CSU, spot liner running pill, POH. / 9. Run and cement a 4 ~", 12.6#, L-80 production liner to TO. Displace with perf pill and seawater. Circulate the well to clean seawater at the liner top, POOH. 10. DPC perforate -500' with 2 ~" guns at 4spf and 200 psi und~alanced. /' 11. Run 4 Y2", 12.6# L-80 completion tying into the 4 ~" liner top. 12. Set packer and test the tubing and annulus to 3000 psi for 30 minutes. 13. Nipple down the SOPE. Nipple up and test the tree to 5000 psi. 14. Freeze protect the well. 15. Set SPY. Rig down and move off. Post-RiQWork: // 1. Install wellhouse and flowlines. 2. Pull SPY. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated Start Date: ~. Phil Smith Operations Drilling Engineer 564-4897 H-02A Re-enter Operations Shut Down H-02A ProJ;)sed Completion . . 13-3/8" x 9-5/8" TIW Tieback X PKR " 13-3/8 x 9-5/8" XO 2271' ~ L l þ¡ - I . l 8300' 9-5/8" ~ CSG, 47#, N-80 J J , i.. Cement P & A- ~ - r ~ 4-112' 'Xàrdrg Nwe wth 3.813 sealli:re. 113-3/8" CSG, 68#, N-80, ID = 12.415" 1-1 118-5/8" CSG, 96.5#, K-55, ID = 17.655" 1-1 ) TREE = WELLHEAD = .. " .,.,. ACTUA TOR = . . . . ... KB. ELEV = BF. ELEV = .. .. KOP= . .... .. .,' Max Angle = . ... . ............ Datum MD = ,. " <.. .. . "" " Datum TV D = 2200' 2271' 2308' GAS LIFT MANDRELS TVD I Size I Valve Type 6 GLMs Gas Lift Mandrel Spacing TBD No I 4-1/2" 12.6# 13Cr, Tubing with GLM's {¡. I +/-5380' I BAKER 7" x 9-5/8" Tie Back Sleeve ~ ZXP Liner Top Packer 'Flex lock' Hydraulic Liner Hanger Window Milled from Whipstock Window at 5529-5545" MD I . 10,185' 10,210' 10230' 10,253' 10,265' 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker' S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.725" seal bore. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve, I +/-10,262' I BAKER 5" x 7" Tie Back Sleeve ZXP Liner Top Packer 'FlexLock' Hydraulic Liner Hanger Wf I +/-10,861' I / 7",26#, L-80, BTC-M Date 12/28/75 12/06/02 Comments Rev By PGS Original Completion Updated Proposed Completion 4-1/2" 12.6 #/ft, L-80, IBT-Mod Plug Back Depth Horizontal Sidetrack into Zone 4 Sands 6" crvv MCEVOY , . 'OTIS 63.95' 44.83' 8800' SS I +/-12,966' I I +/-12,870' I ~~.... aa PRUDHOE BAY UNIT WELL: H-02A API NO: 50-029-20100-01 Prudhoe Bay Unit STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ) ) ''; 1. Operations performed: II Operation Shutdown 0 Stimulate 0 Pull Tubing 0 Alter Casing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 0 Plugging 0 Perforate 0 Repair Well 0 Other 5. Type of well: IBI Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) Plan RKB = 74.85' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 1073' SNL, 1266' WEL, SEC. 21, T11N, R13E, UM At top of productive interval 515' NSL, 2583' WEL, SEC. 21, T11 N, R13E, UM (As Planned, Not Penetrated Yet) At effective depth 4456' SNL, 2864' WEL, SEC. 21, T11 N, R13E, UM (Approx. Current PBTD at 10817') At total depth 4493' SNL, 2855' WEL, SEC. 21, T11 N, R13E, UM (Approx. Current TD at 10861') 8. Well Number , H-02A 9. Permit Number / Approval No. 202-160 302-317 10. API Number 50- 029-201 00-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10861 feet 8728 feet 10817 feet 8704 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 7" 165 sx Class 'G' 100' 2306' 5529' (TOW) /' 3980' - 10861' 100' 2306' 8299' 100' 30" 275 sx cement 2306' 18-5/8" 4200 sx Permafrost 8300' 13-3/8" x 9-5/8" 1561 sx Class 'G', 1825 sx PF 6881' 3980' - 8727' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) Freeze Protection String: 4-1/2", 12.6#, L-80 to 2007' Packers and SSSV (type and measured depth) None Treatment description including volumes used and final pressure RbElfilVtu OCT 1 6 2002 13. Stimulation or cement squeeze summary Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiJ-Bbl Gas-Mef Water-Bbl At.œa Gas ConS. Gommtsslon lu'acfio'a~ø Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments IBI Copies of Logs and Surveys run IBI Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble AAW ~ Title Technical Assistant 16. Status of well classifications as: IBI Oil 0 Gas 0 Suspended Service Date ID .}lo .O~ Form 10-404 Rev. 06/15/88 Prepared By NameINumber: Terrie Hubble, 564-4628 R B D M 5 B F L OCT 2 I 2~ò'2mit In Duplicate Legal Name: H-02 Common Name: H-02 Test Date 8/22/2002 8/31/2002 FIT FIT Test Type Test Depth (TMD) 5,561.0 (ft) 5,561.0 (ft) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) 5,561.0 (ft) 5,561.0 (ft) AMW 10.50 (ppg) 10.50 (ppg) Surface Pressure 440 (psi) 575 (psi) Leak Off Pressure (BHP) 3,473 (psi) 3,608 (psi) Page 1 of 1 EMW 12.02 (ppg) 12.49 (ppg) .~' ^~ Printed: 9/25/2002 4:10:49 PM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/19/2002 8/20/2002 8/21/2002 8/22/2002 H-02 H-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES From - To Hours Task Code NPT Phase 23:00 - 00:00 1.00 RIGU P PRE 00:00 - 01 :00 1.00 RIGU P PRE 01 :00 - 09:00 8.00 MOB P PRE 09:00 - 09:30 0.50 PULL P DECOMP 09:30 - 10:00 0.50 PULL P DECOMP 10:00 - 11 :00 1.00 PULL P DECOMP 11 :00 - 12:00 1.00 PULL P DECOMP 12:00 - 14:00 2.00 PULL P DECOMP 14:00 - 16:00 2.00 PULL P DECOMP 16:00 - 17:00 1.00 PULL P DECOMP 17:00 - 19:30 2.50 PULL P DECOMP 19:30 - 20:30 1.00 PULL P DECOMP 20:30 - 21 :00 0.50 PULL P DECOMP 21 :00 - 22:00 1.00 PULL P DECOMP 22:00 - 22:30 0.50 PULL P DECOMP 22:30 - 23:00 0.50 PULL P DECOMP 23:00 - 00:00 1.00 PULL P DECOMP 00:00 - 06:30 6.50 PULL P DECOMP 06:30 - 07:30 1.00 STWHIP P WEXIT 07:30 - 08:00 0.50 STWHIP P WEXIT 08:00 - 09:00 1.00 STWHIP P WEXIT 09:00 - 11 :00 2.00 STWHIP P WEXIT 11 :00 - 14:00 3.00 STWHIP P WEXIT 14:00 -15:00 1.00 STWHIP P WEXIT 15:00 - 16:00 1.00 STWHIP P WEXIT 16:00 - 17:30 1.50 STWHIP P WEXIT 17:30 - 18:30 1.00 STWHIP P WEXIT 18:30 - 22:00 3.50 STWHIP P WEXIT 22:00 - 23:00 1.00 STWHIP P WEXIT 23:00 - 00:00 1.00 STWHIP P WEXIT 00:00 - 02:30 2.50 STWHIP P WEXIT 02:30 - 03:00 0.50 STWHIP P WEXIT 03:00 - 04:30 1.50 STWHIP P WEXIT 04:30 - 05:00 0.50 STWHIP P WEXIT 05:00 - 06:00 1.00 STWHIP P WEXIT 06:00 - 06:30 0.50 STWHIP P WEXIT 06:30 - 07:30 1.00 STWHIP P WEXIT 07:30 - 13:00 5.50 STWHIP P WEXIT 13:00 - 14:00 1.00 STWHIP P WEXIT 14:00 - 15:00 1.00 STWHIP P WEXIT Page 1 of 9 Start: Rig Release: Rig Number: 2ES Spud Date: 6/23/1971 End: 8/20/2002 Description of Operations Rig down on H-20 well. Prepare to move to H-02A. RD and prep to move. Move rig, pits and camp to H-02A location. Spot same and RU. All berms, handrails, Pit liners and walkways in place. Accept rig at 0900 hrs. Pre Spud meeting. Install secondary valve on annulus. Pull BPV with lubricator. Dry rod in TWC and test from below to 2000 psi. ND tree. Function test Lock Down Screws. Check hanger threads. Plug control line ports. NU BOP's Change out Top Drive saver sub to 4-1/2" IF. Test BOP's. Test bag ,Upper rams, Blinds, HCR manual valves and floor valves. AOGCC waived witnessing test. Chuck Shieve Pull TWC with lubricator. MU landing joint and pull tubing hanger to floor. Pulled free with 175K UP WT 115k of which 30K is block WI. Circulate Condet pill around 13 bpm @ 450 psi. LD tubing hanger. RU casing equipment. LD 5-1/2" tubing. Continue to LD 5-1/2" tubing and SSSV. Pipe corroded on pin ends. Set test plug and test lower pipe rams and annular preventer. Pull test plug and set wear ring. PJSM PU BHA #1. MU BHA#1 946' RIH to 5638'. Cut and slip drill line. Circulate sweep around. 13 bpm @ 875 psi. POH to BHA. Stand back HWDP and collars. RU wireline and run 9-5/8" Bridge Plug with GRlCCL to 5553'. Set BP and POH. Test casing and bridge plug to 3000 psi. Lost 90 psi in 30 min OK. MU BHA #2 Whipstock and milling assembly. RIH with whipstock to 5,541' WLM. UP WT 170K, DN WT 165K. Circulate one DP volume. RU and RIH with GYRO. Orient. Six checks shots made at 203+-1 degrees OK. POH with wireline. Tag bridge plug @ 5,554' WLM. Set whipstock @ 203 degrees. Change well over to 10.5 mud @ 13-1/2 BPM and 1200 PSI. Mill window 5529' - 5545 and open hole 5545' - 5561'. UP 165K, DN 150K, ROT 155K, RPM 90, TQ 4500 ft-Ibs, 450 GPM, 1180 psi. Circulate Hi Vis Sweep. Work window 450 GPM @ 1100 PSI. Perform FIT Test to 12.0 ppg EMW. (5,529' TVD Mud, Printed: 9/25/2002 4:11 :07 PM ') ) BP EXPLORATION Operations Summary Report Page 2 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 2ES 8/20/2002 Spud Date: 6/23/1971 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/22/2002 14:00 - 15:00 1,00 STWHIP P WEXIT with1 0.5 ppg mud and 432 PSI surface pressure) 15:00 - 17:00 2.00 STWHIP P WEXIT POH to BHA. 17:00 - 18:30 1.50 STWHIP P WEXIT LD window milling BHA. 18:30 - 20:00 1.50 STWHIP P WEXIT Flush stack and service wear ring. 20:00 - 00:00 4.00 STWHIP P WEXIT MU BHA #3 Directional drilling assembly 1.22 degree motor. 8/23/2002 00:00 - 00:30 0.50 STWHIP P WEXIT MU Directionally drilling assembly, 00:30 - 01 :00 0.50 STWHIP P WEXIT RIH picking up drill pipe. 01 :00 - 02:00 1.00 STWHIP P WEXIT Service top drive. While replacing a failed bolt on Iron Roughneck. 02:00 - 02:30 0.50 STWHIP P WEXIT Continue RIH while picking up drill pipe to 2,801'. 02:30 - 03:00 0.50 STWHIP P WEXIT Fill pipe and function test the MWD 550 GPM @ 2,620 PSI OK. 03:00 - 05:00 2.00 STWHIP P WEXIT Continue RIH to 5478' 05:00 - 05:30 0.50 STWHIP P WEXIT Fill pipe and function test MWD 550 GPM @ 2,374 PSI. OK. 05:30 - 06:00 0.50 STWHIP P WEXIT Continue to RIH to 5,509'. PJSM 06:00 - 07:30 1.50 STWHIP P WEXIT RU Schlumberger. RIH and orient 208 degrees. POH 07:30 - 11 :00 3.50 STWHIP P WEXIT Run thru window and directionally drill from 5561' to 5638'. UP WT 160K, DN WT 155K. 210 SPM,2000 psi off bottom and 2295 psi on bottom. AST= 2.3 11 :00 - 13:00 2.00 STWHIP P WEXIT Run Gyro survey @ 5,638:. 13:00 - 00:00 11.00 STWHIP P WEXIT Directionally drill 5,638' to 6,108'. ART 2 HRS, AST 5.4 HRS, UP WT 165K, DN WT 155K, RT WT 160K, Torque 4-5K. 8/24/2002 00:00 - 10:00 10,00 STWHIP P WEXIT Directionally drill form 6,108 to 6,719'. up wt 165, dn wt 155 rot wt 160 tq OFF 4k on 5-6kast= 3.6 HRS art = 2.0 HRS. 10:00 - 10:30 0,50 STWHIP P WEXIT Circulate bottom up. 10:30 - 12:00 1,50 STWHIP P WEXIT Short trip thru window. Pulled 40K over from 6,237' to 6,430'. 12:00 - 12:30 0.50 STWHIP P WEXIT Service top drive. 12:30 - 13:00 0,50 STWHIP P WEXIT RIH from 5,478 to 6,624'. 13:00 - 13:30 0.50 STWHIP P WEXIT Fill pipe Wash from 6,624' to 6,719' 13:30 - 16:30 3,00 STWHIP P WEXIT Directionally drill from 6,719' to 7,193'. AST= 1.6 hrs ART = 1.9 hrs. 16:30 - 17:30 1,00 STWHIP P WEXIT Sweep hole high vis pill 585 gpm @ 2850 psi. 17:30 - 23:30 6,00 STWHIP P WEXIT Directionally drill 7,193 to 7,474'. AST= 1.6 hrs ART= 1.1 hrs. UP 170K, DN WT 155k, ROTWT 160K, TO 6-7K. Increased mud wt from 10.5 ppg to 10.8 ppg. 23:30 - 00:00 0.50 STWHIP P WEXIT Speep hole with high vis pill 575 gpm @ 3000 psi. 8/25/2002 00:00 - 01 :00 1.00 STWHIP P WEXIT Drill from 7,474' to 7,568' 01 :00 - 01 :30 0.50 STWHIP P WEXIT Monitor well. 01 :30 - 02:00 0.50 STWHIP P WEXIT Short trip due to high ECD 12.2ppg EMW to 6,710' No Fill. 02:00 - 02:30 0.50 STWHIP P WEXIT Circulate bottom up 3000 psi @ 14 bpm. ECD post circulation 11.7 ppg EMW. 02:30 - 18:00 15.50 STWHIP P WEXIT Directionally drill from 7,568' to 8,980'. Control drilling.150 -180 ftlhr. UP WT 175K, DN WT 155k, ROT WT 170K, TO OFF 5K, TO ON 6-7K AST=.3hrs, ART= 12.5hrs. 18:00 - 19:00 1.00 STWHIP P WEXIT Circulate bottom up. 570 gpm 2950 psi. Monitor well. Static. 19:00 - 19:30 0.50 STWHIP P WEXIT Wiper trip to 7,568'.ECD 12.1 ppg EMW prior to wiper trip. No Problems 19:30 - 20:00 0.50 STWHIP P WEXIT RIH PU singles. 20:00 - 20:30 0.50 STWHIP P WEXIT Fill pipe. Circulate sweep 560 gpm @ 2800 psi. Post circulation ECD 11.7 ppg EMW. 20:30 - 00:00 3.50 STWHIP P WEXIT Directionally drill from 8,980' to 9,220'. UP WT 195K, DN WT 165K, ROT WT 180K, TO 8-9K. 8/26/2002 00:00 - 06:30 6.50 STWHIP P LNR1 Directionally drill from 9,220' to 9,732'. 115 RPM, WOB 12-20, GPM 550, TO on 11, TO off 9, UP WT 215, DN WT 165, ROT Printed: 9/25/2002 4:11 :07 PM ) ) BP EXPLORATION Operations Summary Report Page 3 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 2ES 8/20/2002 Spud Date: 6/23/1971 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/26/2002 00:00 - 06:30 6.50 STWHIP P LNR1 185, ECD 11,9 ppg 06:30 - 07:00 0.50 STWHIP P LNR1 Change out swap on pump. 07:00 - 12:30 5.50 STWHIP P LNR1 Directionally drill from 10138 to 1 0185'.ART =7.1 hrs, AST = .8 hrs 115 RPM, WOB 15-20, GPM 525, TO on 12, TO off 9, UP WT 225, DN WT 170, ROT 195, ECD 11.9. 12:30 -13:30 1.00 STWHIP P LNR1 Change out two swaps on pump #2. 13:30 - 14:00 0.50 STWHIP P LNR1 Circulate 285 GPM 1100 psi. Number one pump failed leak between fluid end and discharge manifold. Trouble shoot during short trip. 14:00 - 17:00 3.00 STWHIP P LNR1 POH to 5,475' 40 - 60 K over pull @ 9,192'-8,977' and 55-60 K overpull @ 8,565' to 8,500', 17:00 - 18:00 1.00 STWHIP P LNR1 Cut and slip drill line. 18:00 - 18:30 0.50 STWHIP P LNR1 Service top drive. 18:30 - 20:00 1.50 STWHIP P LNR1 RIH NO Problems on trip. 20:00 - 21 :00 1.00 STWHIP P LNR1 Circulate bottom up 559 gpm @ 3190 psi. 21 :00 - 00:00 3.00 STWHIP P LNR1 Directionally drill 1 0, 185 to 10,225. ART = .2 hrs, AST 1.2 hrs. 110 RPM, WOB 10, GPM 559, TO on 13, TO off 10, UP WT 235, DN WT 165, ROT 190, ECD 11.7 8/27/2002 00:00 - 01 :00 1.00 STWHIP P LNR1 Directionally drill from 10,225' to 10,296'. 110 RPM,558 GPM,UP WT 230, DN WT 175, ROT 190,ECD 11.67 01 :00 - 03:00 2.00 STWHIP N SFAL LNR1 SPILL 15 gallons 3 not contained. SEE IR 297532. Hole in secondary kill hose at interconnect. Repair 2"DEMCO's. 03:00 - 07:00 4.00 STWHIP P LNR1 Directionally drill from 10,296' to 10,496'. 07:00 - 08:00 1.00 STWHIP P LNR1 Circulate bottom up for sample J3"bpm 3525 psi. 08:00 - 08:30 0.50 STWHIP P LNR1 Directionally drill from 10,49 0 10,50 . 110 RPM, 19K WOB, 3000 psi off, 3450 psi on,T 0 , Q on 11, UP WT 235K, DN WT 175K ROT 195K. 08:30 - 10:00 1.50 STWHIP P LNR1 Circulate around sweep 13 bpm @ 3525 psi. 10:00 - 13:30 3.50 STWHIP P LNR1 Short trip to 5,475' Pulled 45-50K over 9579' - 9,558', 9,525' - 9500',8530' - 850d' No Problems. 13:30 - 14:00 0.50 STWHIP P LNR1 Service top drive. 14:00 - 16:30 2.50 STWHIP P LNR1 RIH to 10,505 TD. 25 - 30 K down drag 9500' - 9580'. 16:30 - 18:30 2,00 STWHIP P LNR1 Stage up pumping and tag bottom 10,505 no fill. Sweep hole and circulate bottom up. 540 GPM @ 2900 psi. Reciprocate and rotate pipe. 18:30 - 19:30 1,00 STWHIP P LNR1 Spot liner running pill. Drop ESS. Pump dry job. 19:30 - 00:00 4,50 STWHIP P LNR1 POH from 10,505' to 893'. Check shots at 10,236',10,142' & 10,047'.25 - 30K over pull @ 9520, 8560', 8500', and 6485'. Monitor well at shoe static. 8/28/2002 00:00 - 04:00 4.00 STWHIP P LNR1 LD BHA. Down load MWD data. 04:00 - 04:30 0.50 STWHIP P LNR1 Clear floor. 04:30 - 05:00 0.50 STWHIP P LNR1 PU cementing head and change out pup from 4" to 5". 05:00 - 05:30 0.50 STWHIP P LNR1 Pull wear ring. 05:30 - 06:30 1.00 STWHIP P LNR1 Test variable rams with 7" test joint. 06:30 - 07:00 0.50 STWHIP P LNR1 Install wear ring. 07:00 - 08:30 1.50 STWHIP P LNR1 RU casing equipment. PJSM with crew. 08:30 - 09:00 0.50 STWHIP P LNR1 MU float equipment and check floats. 09:00 - 16:00 7.00 STWHIP P LNR1 PU 5517' of 7" liner to top of window. Fill every5 joints. PU 250K 16:00 - 16:30 0.50 STWHIP P LNR1 Circulate one liner volume. 250 GPM, @ 450 PSI, UPWT 150K, DN WT 135K. 16:30 - 17:30 1.00 STWHIP P LNR1 PU 7" liner from 5517' to 6447'. 17:30 - 18:00 0.50 STWHIP P LNR1 MU Baker Flex lock hanger and ZXP liner top packer assembly. Printed: 9/25/2002 4: 11 :07 PM ) BP EXPLORATION Operations Summary Report Page 4 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 2ES 8/20/2002 Spud Date: 6/23/1971 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/28/2002 18:00 - 00:00 6,00 STWHIP P LNR1 RIH on DP from 6483' to 9705'. Working liner down from 9500'. Working pipe to bottom. Fill pipe at 7640' and 9420'. Picking up to breakover and slacking off. Breakover values varing between 275 to 350K. Pipe moving in the range of 6" to 3' per cycle. Steady but slow progress. 8/29/2002 00:00 - 02:00 2.00 STWHIP P LNR1 Continue to work liner to 9718. Breakover values tr ing down from 350K to 240K. Progressing 6" ~r cy e. Progress is slow but steady. Worked pipe 9718 Icked up lost 18'. Worked back to 9712. Tube lock d ween 9712' to 9696'. Worked pipe to 460K No Go. 02:00 - 03:00 1.00 STWHIP N STUC LNR1 Contacted Phil Smith agreed to attempt breaking circulation limiting pressure to 1000 psi. Well presurred to 1000 psi in 49 strokes.Calculation indicate the shoe may be plugged. Baker recommended not pressuring over 2000 psi. Liner hanger is pinned for 3100 psi. OK'd with Phil and pressured to 2000 psi. Could not break circulation. 03:00 - 03:30 0,50 STWHIP N STUC LNR1 Hold 220 K over while waiting on orders. No change. 03:30 - 04:00 0.50STWHIP N STUC LNR1 Release from liner hanger with 18 turns to the right. 04:00 - 05:30 1.50 STWHIP N STUC LNR1 POH and lay down running tool. 05:30 - 06:30 1.00 STWHIP N STUC LNR1 Clear floor and pull wear ring. 06:30 - 11 :30 5.00 STWHIP P LNR1 Test BOP. Witnessing waived by Lou Grimldi AOGCC, Install wear ring. 11 :30 - 13:00 1,50 STWHIP P LNR1 Inspect and adjust break. Service top drive 13:00 -14:00 1.00 STWHIP P LNR1 Cut drill line. 14:00 -15:30 1.50 STWHIP N STUC LNR1 PU drill collars while waiting on Schlumberger Eline. 15:30 - 00:00 8.50 STWHIP N STUC LNR1 PU Halliburton EZSV bridge plug. Log into position and set at 5 3'. OH and PU chemical cutter. RIH and cut 7" casing at ~OH Good iñdication of cut. 8/30/2002 00:00 - 00:30 0,50 STWHIP N STUC LNR1 .' chlumberger chemical cutter. 00:30 - 03:30 3,00 STWHIP N STUC LNR1 tJ and MU fishing BHA. 03:30 - 04:30 1.00 STWHIP N STUC LNR1 RIH to 3237' 93K UP 90K DN, 04:30 - 05:00 0,50 STWHIP N STUC LNR1 Engage fish at 3243'. Set 20K down. PU to 250K. Come free. 160K hook load. 05:00 - 06:00 1.00 STWHIP N STUC LNR1 POH standing back 5" drill pipe. 06:00 - 07:00 1.00 STWHIP N STUC LNR1 LD fishing BHA. 07:00 - 07:30 0.50 STWHIP N STUC LNR1 Rig Up Casing equipment. 07:30 - 11 :30 4.00 STWHIP N STUC LNR1 LD 65 joints of 7" casing and cutoff 3.51'. 11 :30 - 12:00 0.50 STWHIP N STUC LNR1 Rig down casing equipment. 12:00 - 13:00 1.00 STWHIP N STUC LNR1 MU cementing BHA. 13:00 - 15:30 2.50 STWHIP N STUC LNR1 RIH to 5825'. 15:30 - 16:00 0.50 STWHIP N STUC LNR1 Wash last stand down at 1 bbl/min @ 250 psi. Tag EZSVat 5911. Set down 5K. Circulate bottom up 12 bbllmin @ 860 psi. 16:00 - 17:00 1.00 STWHIP N STUC LNR1 Displace out 10.8 ppg mud with 10.5 LSND mud 12 bbllmin @ 900 psi.- 17:00 - 18:30 1.50 STWHIP N STUC LNR1 pu"&=<% KCl, Test lines to 2000 psi. Pump 10 bbl 2% KCL, 21 J7# cement, 3 bbl 2% KCL, and displace with 52.5 bbl 18:30 - 19:00 0.50 STWHIP N STUC LNR1 Pull out of balanced plug SLOW! from 5900' to 5503'. Top of window is 5529'. 19:00 - 20:00 1.00 STWHIP N STUC LNR1 Reverse circulate 2 bbl/min 390. No cement to surface. Lost 7bbl. 20:00 - 20:30 0.50 STWHIP N STUC LNR1 Pump dry job and blow down surface equipment. 20:30 - 22:30 2.00 STWHIP N STUC LNR1 POH. Printed: 9/25/2002 4: 11 :07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BP EXPLORATION Operations Summary Report H-02 H-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Page 5 of 9 Start: Rig Release: Rig Number: 2ES Spud Date: 6/23/1971 End: 8/20/2002 Date From - To Hours Task Code NPT Phase Description of Operations 8/30/2002 22:30 - 23:00 0,50 STWHIP N STUC LNR1 LD cementing BHA. 23:00 - 00:00 1.00 STWHIP N STUC LNR1 Clear floor. 8/31/2002 00:00 - 03:30 3.50 STKOH N STUC LNR1 PU BHA#5. Surface check MWD at 88'. 03:30 - 05:00 1,50 STKOH N STUC LNR1 RIH with 5" DP. from 922' to 5411'. PU 9 additional joints. Fill pipe @ 2200' and 5400'. 05:00 - 05:30 0.50 STKOH N STUC LNR1 Service top drive. 05:30 - 07:30 2.00 STKOH N STUC LNR1 Wait on cement. 07:30 - 08:00 0,50 STKOH N STUC LNR1 Perform FIT test to 12.5 ppg EMW with 582 psi. 08:00 - 08:30 0,50 STKOH N STUC LNR1 RIH from 5411' to 5437' tagging cement. Taking from 5 - 10 K down weight. 08:30 - 09:30 1.00 STKOH N STUC LNR1 Wash soft cement from 5437' to 5525'. Work thru window 5529' to 5545' wiith out the pump taking from 15 to 20 K down. POH to 5411'. 09:30 - 10:00 0.50 STKOH N STUC LNR1 CBU @ 11 bbl / min 2380 psi. 10:00 - 11 :00 1.00 STKOH N STUC LNR1 Wash cement from 5537' to 5638'. @ 11 bbll min 2380 psi. Cement still soft.( contaminated) ~ 11 :00 - 00:00 13.00 STKOH N STUC LNR1 Drill from 5638' to 5664', Cement f ng p 566. UP WT 165K, DN WT 150K, ROT 155 Tim~ III from"5664' to 5697' ART = .2 hrs and AST = 7.2 hrs. . T 165K, DN WT 150K, ROT 155K, TO 4. 9/1/2002 00:00 - 13:30 13.50 STKOH N STUC LNR1 Directionally driIl8.5"hole from 5793'. to 6175'. UP WT 170, DN WT 150 ROT 160, TO off 5 TO on 6-8. ART=.6 AST= 8.5 hrs, Cement contamination driving the PH to 10. Treating mud to condition for PH. Start adding lubricants after verification with lab test that there was no adverse reaction due to the elevated PH. 13:30 - 14:30 1.00 STKOH N STUC LNR1 CBU 13 bbl / min @ 3000 psi. 14:30 - 15:30 1,00 STKOH N STUC LNR1 Short trip from 6175' to 5506'. Orient 40 right @ 5630 to enter the new sidetrack. 15:30 - 17:00 1,50 STKOH N STUC LNR1 Directionally drill 6175' to 6208'. ART = 0, AST = =1 hr. WOB 5k, pressure on bottom 2900 psi, pressure off 2570 psi, @576 gpm. Bit drilling off 5' then progressively lost weight. After reaming down we were able to drill ahead an additional 5' before weight transfer problem return. Acts like bit is under gage and hanging up on the near bit stabilizer. Back reaming is wiping out the dogleg from the slide. Getting behind on the curve. POH for a bit. 17:00 - 17:30 0.50 STKOH N STUC LNR1 Pump dry job. 17:30 - 20:00 2.50 STKOH N STUC LNR1 POH to BHA. 20:00 - 21 :30 1.50 STKOH N STUC LNR1 Stand back HWDP and collars. 21 :30 - 23:30 2.00 STKOH N STUC LNR1 LD mud motor, near bit stab, and bit. Bit and near bit in full gage. Bit has two chipped teeth on gage row. Replace near bit with 1/16th under gage stabilizer. UP new motor and bit, Orient Motor and MWD. 23:30 - 00:00 0.50 STKOH N STUC LNR1 Function test MWD. 9/2/2002 00:00 - 02:00 2.00 STKOH N STUC LNR1 PU and RIH with BHA# 6 to 5506'. Filling pipe at 2,500' and 5,506'. 02:00 - 03:00 1.00 STKOH N STUC LNR1 Cut and slip 76' of drill line. 03:00 - 03:30 0.50 STKOH N STUC LNR1 Service Top Drive. 03:30 - 04:00 0.50 STKOH N STUC LNR1 RIH from 5506'. No Trouble. At Top of window orient 62R @ 5602'. KOP for new hole 5660'. No Problem. RIH to 6208'. 04:00 - 21 :30 17;50 STKOH N STUC LNR1 Directionally drill from 6208' to 7585'. Top of HRZ. AST = 5.2 hours, ART = 6.2 UP WT 180, DN WT 155, ROT 170 ( pre Printed: 9/25/2002 4: 11 :07 PM ) ) BP EXPLORATION Operations Summary Report Page 6 of 9 Leg al Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 2ES 8/20/2002 Spud Date: 6/23/1971 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/212002 04:00 - 21 :30 17.50 STKOH N STUC LNR1 HRZ drilling perameters @ 7602', RPM 105, WOB 20,550 gpm, off bottom pressure 3225 psi, on bottom pressure 3500 psi, TO off 6, TO on 7-8, ROP 150 ftlhr, ECD 12.2 ppg. 21 :30 - 22:30 1.00 STKOH N STUC LNR1 Circulate high vis sweep 13bbll min @ 3150 psi. 22:30 - 00:00 1.50 STKOH N STUC LNR1 Short trip to window. Pulled 20k over at 6240'. 9/3/2002 00:00 - 00:30 0.50 STKOH N STUC LNR1 Service Top Drive. 00:30 - 01 :30 1,00 STKOH N STUC LNR1 RIH to 7,585'. (No problems passing thru window and no orientation needed to re-enter sidetracked wellbore). 01 :30 - 12:00 10.50 STKOH N STUC LNR1 Drill 8-1/2" hole with 1.5 deg motor from 7,585' to 8,447'. ART= 6.6, AST=0.7 hrs. UWT=195K, DWT=150K, ROT=175K, Torque off = 7.5K ft-Ib, on = 8.0K. 12:00 - 23:00 11.00 STKOH N STUC LNR1 Drill 8-1/2" hole from 8,447' to 9,338'. ART= 7.2, AST= 0,3 hrs. UWT=200K, DWT=160K, ROT=180K, Torque off = 9Kft-lb, on = 11K. 23:00 - 00:00 1.00 STKOH N STUC LNR1 Circ HI-Vis sweep at 13 BPM and 3,000 psi. Pump slug, flow check well. 9/4/2002 00:00 - 01 :30 1.50 STKOH N STUC LNR1 Short trip to 7,450' with no excess drag. RIH to TD with no excess down drag, Orient toolface. 01 :30 - 12:00 10.50 STKOH N STUC LNR1 Drill 8-1/2" hole with 1.5 deg motor from 9,338' to 10,100'. ART= 3.4, AST= 3.4 hrs. T=225K, DWT=170K, ROT=190K, Torque = 11 ~ft-Ib, on = 13K. 12:00 - 22:30 10,50 STKOH N STUC LNR1 Drill from 10,100' t 10,861X'ART= 4.8, AST= 2.0 hrs. UWT=245K, DW 'f-7e-t{ROT=1905, Torque off = 11 K ft-Ib, on = 14K. 22:30 - 0.00 STKOH N STUC LNR1 Sweep hole clean with HI-Vis sweep at 13 BPM and 3,130 psi. Pump slug and flowcheck well. 9/5/2002 00:00 - 03:00 3.00 STKOH N STUC LNR1 Short trip. Up drag of 15-30K for the first 4 stands off bottom (TD to 10,309' = azimuth change at the tail of this hole section). Pull35K over at 8,729',8,691', wipe thru, continue POOH to inside 9-5/8" csg without problems. 03:00 - 05:00 2.00 STKOH N STUC LNR1 Flow check well. Cut and slip 73' of drill line. Service TD, and Crown. 05:00 - 07:30 2,50 STKOH N STUC LNR1 RIH. Re-enter side tracked hole without problems. RIH, with 1 0-15K average drag. 07:30 - 09:00 1.50 STKOH N STUC LNR1 Circ Btms Up, staging rate up slowly to 12 BPM and 3,400 psi. Rotate and wash last stand to bottom. Rotate and reciprocate pipe while pumping Hi-Vis sweep around. Heavy returns of splintered pieces of shale. 09:00 - 12:00 3.00 STKOH N STUC LNR1 Circulate well at 12 BPM and 2,940 psi, while increasing mud weight from 11.0 - 11.5 ppg. Reciprocate and rotate pipe throughout. UWT = 265K, DWT = 165K, Torque off = 18K ft-Ib. 12:00 - 16:30 4.50 STKOH N STUC LNR1 Continue circulating and weighting up to 11.8 ppg mud weight. Shale cuttings size and volumes decreasing. Pump slug. 16:30 - 21 :00 4.50 STKOH N STUC LNR1 POOH to inside 9-5/8" casing at 5,472' with 35K overpull at 10,290', 20K overpull at 8,320', and 7,851'. No losses on trip out. 21 :00 - 21 :30 0.50 STKOH N STUC LNR1 Grease torque tube track for Top Drive. 21 :30 - 00:00 2.50 STKOH N STUC LNR1 RIH to 10,485 with average drag of 5-10K Ibs from the window at 5,545' to the top of the HRZ at 7,528'. Continue RIH with 15-20K down drag. No losses while tripping in the hole. 9/6/2002 00:00 - 00:30 0.50 STKOH N STUC LNR1 Wash to bottom. No fill on bottom. 00:30 - 02:00 1.50 STKOH N STUC LNR1 Circulate bottoms up at 400 GPM. Circulate 341 of 518 bbls to Printed: 9/25/2002 4: 11 :07 PM ) ) BP EXPLORATION Operations Summary Report Page 7 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 2ES 8/20/2002 Spud Date: 6/23/1971 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/612002 00:30 - 02:00 1.50 STKOH N STUC LNR1 CBU with minor losses. Flow returns decreased to 50%, and losses = 4 BPM while pumping. Shut down pumps (total lost = 49 bbl). Static losses without pumping = 1 BPM. Losses decreased to 1 bbl per 5 minutes. 02:00 - 03:30 1.50 STKOH N STUC LNR1 Mix 50 bbl LCM pill with 20 Ib/bbl of Barofibre and 10 Ib/bbl of Liquid Casing. Pump at 165 GPM and 500 psi (ECD = 12.4 ppg). Lost total returns at 1,200 of 3,150 strokes of displacement, shut down pumps. (171 bbls lost), Continue pumping at 3.5 GPM with loss rate at 2-4 BPM. Spot LCM pill atTD. 03:30 - 07:30 4,00 STKOH N STUC LNR1 POOH 10,861' to 10,390' with 35K over pull. Continue POOH to 5,506' with UWT = 260-270K (15-25K overpull) , decreasing to 10-20K over pull, and losses decreasing to 1 bbl per 5 stands pulled. NOTE: Total losses since circulating on bottom = 497 bbl. 07:30 - 09:00 1.50 STKOH N STUC LNR1 Monitor well. Loss rate while static = 0 bbl. Circulate at 3 BPM and 330 psi with losses = 1 bbl/min. Spot 35 bbl LCM pill at 40 Ib/bbl Barofibre and Liquid Casing. No returns while spotting LCM. 09:00 - 14:00 5.00 STKOH N STUC LNR1 POOH. Download MWD data, LD BHA. 14:00 -15:30 1.50 STKOH N STUC LNR1 LD BHA, clean and clear rig floor. 15:30 -16:30 1.00 STKOH N STUC LNR1 Pull Wear Bushing, set test plug. 16:30 - 18:30 2.00 STKOH N STUC LNR1 Test BOPE 250/3,500 psi for 5/5 min: Annular Preventer, Top Pipe Ram wI 4-1/2" x 7" Variable Rams, Blind Ram, Mud Cross, Lower Pipe Rams wi 2-7/8" x 5" Variable Rams, Lower Mud Cross. Tested Blind Rams, Choke Manifold, HCR, Kill and Choke lines, IBOP. Testing witnessed by Chuck Scheve of the AOGCC. 18:30 - 19:30 1.00 STKOH N STUC LNR1 Pull test plug and set Wear Bushing. 19:30 - 20:30 1.00 STKOH N STUC LNR1 PU and RIH with cleanout BHA. Note: lost 14 bbl of mud during 6 hours of the hole staying static. 20:30 - 22:30 2.00 STKOH N STUC LNR1 RIH to above the window. Attempt to circulate. Had 5% returns, shut down pumps. 22:30 - 00:00 1,50 STKOH N STUC LNR1 Cut and slip 69' of drill line. Service Top Drive. 9/7/2002 00:00 - 02:30 2.50 STKOH N STUC LNR1 RIH to 10,570' and hit bridge. 02:30 - 04:30 2.00 STKOH N STUC LNR1 Ream to 10,600' at 85 RPM, 2 BPM, ROT 190K, Torque 10-11 K ft-Ib. PU and pull 1 OOK over and jar free. Back ream to 10,510'. Reached the torque limiter on two occasions. Work through tight spot with 25% returns, adding LCM to system. 04:30 - 05:00 0.50 STKOH N STUC LNR1 Ream final 3 stands to bottom at 85 RPM, 120 GPM, 500 psi, 10-11K ft-Ib, zero returns. No fill on bottom. Total losses while RIH = 87 bbl. 05:00 - 05:30 0.50 STKOH N STUC LNR1 Pump and spot 50 bbl pill on bottom with 30 Ib/bbl Steal Seal, 20 Ib/bbl Barofibre, 20 Ib/bbl medium Baroseal. No returns while displacing. 05:30 - 06:30 1,00 STKOH N STUC LNR1 POOH to 9,752' with no overpull, and no problems. 06:30 - 07:30 1.00 STKOH N STUC LNR1 Spot 50 bbl pill at 3 BPM and 390 PSI containing 30 Ib/bbl Steal Seal, 20 Ib/bbl Barofibre, 20 Ib/bbl medium Baroseal. No returns while displacing. 07:30 - 10:00 2.50 STKOH N STUC LNR1 POOH to 5,492" with no overpull, and no problems. 10:00 - 11 :00 1.00 STKOH N STUC LNR1 Spot 50 bbl pill at 3 BPM and 270 PSI containing 30 Ib/bbl Steal Seal, 20 Ib/bbl Barofibre, 20 Ib/bbl medium Baroseal. Printed: 9/25/2002 4: 11 :07 PM ') ) BP EXPLORATION Operations Summary Report Page 8 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 2ES 8/20/2002 Spud Date: 6/23/1971 End: Date From - To Hours Task Code NPT Phase Description of Operations 9/712002 10:00 - 11 :00 1.00 STKOH N STUC LNR1 Lost 26 of 96 bbls while displacing. 11 :00 - 13:30 2.50 STKOH N STUC LNR1 POOH to BHA. 13:30 -14:30 1.00 STKOH N STUC LNR1 Lay down BHA. 14:30 - 15:30 1.00 STKOH N STUC LNR1 Clear and clean rig floor. 15:30 - 16:30 1.00 CASE N STUC LNR1 RU casing ~g loois. 16:30 - 00:00 7.50 CASE N STUC LNR1 MU and thre ell06k float joints. Straight blade cents on shoe joints only. ~ith 118 jts of 7", 26 Ib/ft, L-80, BTC-M casing. Lost 45 bbl hile RIH. Total losses for 24 hours = 653 bbls. 9/8/2002 00:00 - 01 :00 1.00 CASE N STUC LNR1 Fill casing above the window and circulate at 1 BPM, 240 psi. UWT= 145K, DWT= 135K. Lost 1 bbl per 7 min while circulating. 01 :00 - 01 :30 0.50 CASE N STUC LNR1 Pass through w.riâOw and enter side tracked hole without problems. / 01 :30 - 06:30 5.00 CASE N STUC LNR1 Continue r ning 7/, 26#/ft, L-80, BTC-M csg to 9,900' without problems. ostjØb bbl while in open hole. Work last 4 stands to bottom "40-50K of drag. Lost 150 bbl while TIH. 06:30 - 08:30 2.00 CEMT P LNR1 Circulate and condition mud at 5 BPM and 900 psi, with 25% returns, 7 BPM and 1,200 psi - zero returns. Hold PJSM for cementing. 08:30 - 12:00 3,50 CEMT P LNR1 Pump 5 bbl of water and test surface lines to 4,500 psi. Pump 36.5 bbl of 12.6 ppg Alpha Spacer, 35 bbl (170 sx) of 15.8 ppg, "G" cement + additives at 4 BPM, displace with the calculated volume of 330 bbl of seawater at 7 BPM, and plug did not bump. Consulted with engineering staff. Overdisplaced with. 75 bbl, bumped plug and pressured up casing string to 4,500 psi setting the Flex-Lok liner hanger. Slight returns while pumping I displacing cement. Bleed off pressure, check floats - okay, Release from liner hanger, keeping positive pressure on the drillstring. CIP: 11 :30 hrs. 12:00 - 12:30 0.50 CEMT P LNR1 Pump 100 bbl of seawater at 10 BPM and 700 psi. Set down 60K with indications of packer setting. 12:30 - 14:00 1.50 CEMT P LNR1 Displace wellbore to clean seawater at 12 BPM and 820 psi. No fluid losses while pumping or when well was static. 14:00 - 14:30 0.50 CEMT P LNR1 LD cement head. 14:30 - 17:30 3.00 CASE P LNR1 POOH laying down 125 jts of 5" DP. LD liner running tool. 17:30 - 18:30 1.00 CASE P LNR1 RIH with drillpipe in the derick to 3,800'. 18:30 - 20:30 2.00 CASE P LNR1 POOH laying down 5" DP. 20:30 - 23:00 2.50 CASE P LNR1 Cut and slip 80' of drill line. Service Top Drive. Note: Total Losses for 24 hrs = 617 bbL Zero losses after cementing casing. 9/9/2002 00:00 - 01 :30 1.50 CASE P LNR1 Continue LD 5" DP. Clear and clean rig floor. Pull Wear Ring. 01 :30 - 02:30 1.00 CASE P LNR1 Pressure test 7" x 9-5/8" casing to 3,000 psi. Pressure dropped 1,500 psi in 12 minutes. Bleed off test pressure. 02:30 - 04:30 2.00 CASE P LNR1 Change out top RAMS to 3-1/2" x 6" Variables. Pressure test to 250/3,500 psi for 5/5 minutes. Install Wear Ring. 04:30 - 06:00 1.50 CASE N DFAL LNR1 PU packoff, rotating sub and DCs. 06:00 - 08:00 2.00 CASE N DFAL LNR1 MU Seal Assembly, and rotating dog sub, and HWDP. 08:00 - 10:00 2.00 CASE N DFAL LNR1 RIH to 3,980' (93 jts picked up). Printed: 9/25/2002 4: 11 :07 PM ) ~) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-02 H-02 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task Code NPT Phase 9/9/2002 10:00 - 14:00 4.00 CASE N DFAL LNR1 14:00 - 15:00 1.00 CASE N DFAL LNR1 15:00 - 16:30 1.50 CASE N DFAL LNR1 16:30 - 17:30 1.00 CASE N DFAL LNR1 17:30 - 18:30 1.00 CASE N DFAL LNR1 18:30 - 21 :00 2,50 CASE N DFAL LNR1 21 :00 - 23:00 2.00 CASE N DFAL LNR1 23:00 - 00:00 1.00 CASE N DFAL LNR1 9/10/2002 00:00 - 01 :00 1.00 CASE N DFAL LNR1 01 :00 - 01 :30 0,50 RUNCOMP COMP 01 :30 - 04:00 2.50 RUNCOMP COMP 04:00 - 05:30 1.50 RUNCOMP COMP 05:30 - 06:00 0.50 RUNCOMP COMP 06:00 - 07:00 1.00 RUNCOMP COMP 07:00 - 08:30 1.50 RUNCOMP COMP 08:30 - 10:00 1.50 RUNCOMP COMP 10:00 -12:00 2.00 RUNCOMP COMP 12:00 - 13:00 1.00 RUNCOMP COMP 13:00 -14:30 1.50 RUNCOMP COMP 14:30 - 17:00 2.50 RUNCOMP COMP Page 9 of 9 Start: Rig Release: Rig Number: 2ES Spud Date: 6/23/1971 End: 8/20/2002 Description of Operations Sting seal assembly into tieback receptical and test DP and 7" csg to 1,100 psi-ok. PU and set down 60K on packer while rotating. PU and test casing to 3,000 psi. Bled down 1,000 psi in 10 minutes. Release pressure, and set down 70K on packer and rotate. Retest casing to 3,000 psi with 300 psi lost in 15 minutes. Set down 70K on pkr, rotated, and pressured the backside with 700 psi, resulting in an effective down weight of 100K. Released pressure and PU. Retested csg to 3,000 psi, with 300 psi of pressure lost in 15 minutes. Bled off pressure. Stabbed seal assembly into receptical and tested 9-5/8" csg and liner top pkr to 3,000 with no bleed off. Bled off pressure. PU above seals and tested 7" liner x 9-5/8" csg to 3,000 psi with 300 psi bleed off in 15 min. POOH. Handle BHA. LD Rotating Dog tool. PU 7" RTTS packer and BHA. RII-lafÍCÍ s t RTTS packer below the liner hanger and liner top ~r, at 4,0 2' . est 9-5 "csg and liner top packer to 3,000 psi for 30 min - " k> ease presuure. Pressure up DP and pressure test 7" liner below the packer to 3,000 psi for 30 minutes - ok, Release DP pressure, release RTTS pkr, blow down surface equipment. POOH laying down DP. LD BHA. Continue to LD BHA. Pull Wear Ring. RU handling equipment. PJSM. Run 48 jts of 4-1/2", 12.6#/ft, L-80, NSCT, Class B tbg. Land tbg. Land tbg hanger and run in LDS. Install TWC and test to 2,000 psi from below. Nipple down BOPE. Nipple up tree and adaptor flange and test to 5,000 psi. RU lubricator, pull TWC, rig down lubricator. RU Hot Oil Services, test lines to 2,500 psi. Pump 140 bbl of diesel freeze protect at 2.5 BPM and 800 psi. U-tube same. Instal BPV and test from below to 2,000 psi for 10 min. Rig down lines. Secure tree, remove secondary annulus valve. Remove Bea~er Slide, Stairs and Landing, due to width lim~'ta. ti on. ."". ..~.I.t.~;f\-pad facilities. ,/ RE ASE"RIG @ 17:00 HS - Sep 9-02 .""""",r"" Printed: 9/25/2002 4: 11 :07 PM .. ) STATE OF ALASKA!!\ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL [J Suspend [J Plugging [J Time Extension [J Perforate [J Repair Well [J Pull Tubing [J Variance [J Other II Operation Shutdown [J Re-Enter Suspended Well [J Stimulate VJ6,+ .:J:(t- /VI. IA> ¡Ol è.{./OL 144' I bl.- /'()/7/~2- 1. Type of Request: [J Abandon [J Alter Casing [J Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 6. Datum Elevation (DF or KB) Plan RKB = 74.85' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 1073' SNL, 1266' WEL, SEC. 21, T11 N, R13E, UM At top of productive interval 515' NSL, 2583' WEL, SEC. 21, T11N, R13E, UM (As Planned) At effective depth 8. Well Number H-02A 9. Permit Number 202-160 10. API Number 50- 029-201 00-01 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool At total depth 200' NSL, 692' WEL, SEC. 21, T11N, R13E, UM (As Planned) 12. Present well condition summary Total depth: measured true vertical 1 0861 feet 8728 feet feet feet Plugs (measured) true vertical Effective depth: measured Junk (measured) Casing Structural Conductor Su rface Intermediate Production Liner Length Size Cemented MD TVD 100' 100' 2306' 2306' 5529' (TOW) 8299' 100' 30" 275 sx cement 2306' 18-5/8" 4200 sx Permafrost 8300' 13-3/8" x 9-5/8" 1561 sx Class 'G', 1825 sx PF Perforation depth: measured None RECE1VED OCT 032002 true vertical None Tubing (size, grade, and measured depth) Alaska Oil & Gas Qons. Commission Freeze Protection String: 4-1/2", 12.6#, L-80 to 2007' Anchorage Packers and SSSV (type and measured depth) None 13. Attachments 181 Description Summary of Proposal 0 Detailed Operations Program 15. Status of well classifications as: 181 Oil 0 Gas 0 Suspended 0 BOP Sketch 14. Estimated date for commencing operation September 10, 2002 16. If proposal was verbally approved Winton Aubert Name of approver Contact Engineer Name/Number: Phil Smith, 564-4897 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHUbble~~ ~ Trtle Technical Assistant - '.- o. Co",,"iS$ion~>()nJy> Conditions of Approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - Mechanical Integrity Test~ SUbSeqUent.lonn required 10- LfOtf (;Jr'iUINAL SIGNED ,0, , Approved by order of the Commission 0 Taylor Se6ri1~~".;'h~ Form 10-403 Rev. 06/15/88~,;' . 9/5/2002 Date Approved Service Prepared By Name/Number: Terrie Hubble, 564-4628 Date /D'DÄ.O~ I Approval No. 3D ~ - 3 ? Commissioner DateJN0~J~ Subm¡t~ 'Tri~cate \ ) , Hubble, Terrie L From: Sent: To: Subject: Hubble, Terrie L Wednesday, October 02, 2002 2:29 PM Winton Aubert (E-mail) H-02A Ops Shutdown, Permit #202-160 Hi Winton, I need to know how you would like me to handle, paperwork wise, the H-02A Ops Shutdown. Nabors 2ES was drilling this well, when it was decided to pull them off and move to repair A-22. Originally the plan had been to move back on H-02A when the A-22 workover was complete. Phil Smith had a telephone conversation with you about all this and he says you advised him that you didn1t need anything on H-02A, but would require a 10-403 on A-22, which was submitted. H-02A Rig Released on 09/09/02. According to the Regs, I am required to submit a 10-404 on this well within 30 days, unless waived by the Commission if the rig will return within 60 days, however I won't have an approval number for that form. At present, the return to H-02A has been pushed back to the later part of November because when the rig moved off H Pad a major culvert near GC-2 suffered damage and they want to wait-until the ground is firmer before returning. So now, finally to the question, what paperwork do you want me to submit? Terrie Hubble GPB Drilling & Wells 564-4628, MB7-5, Cube 718 1 ) ) Hubble, Terrie L From: Sent: To: Cc: Subject: Smith, Phil G (FAIR) Thursday, September 05, 2002 4:55 PM Hubble, Terrie L NSU, ADW Drlg Rig 2es H-02A Operations Shutdown To: Winton Aubert AOGCC Re: Permit # 202-160, API # 50-029-20100-01, Prudhoe Bay Well H-02A Operations Shutdown Nabors 2ES will shutdown operations on H-02A for approximately two weeks to perform a workover on A-22. Due to the nature of the casing failure on A-22, and the broader scope issues associated with it, the workover is considered very high priority. Nabors 2ES will return to H-02A to finish the 6 1/8" horizontal section and completion following the two-week workover on A-22. Proposed H-02A suspension: Complete the T' liner cement operation as permitted. RIH with 4" DP to the 7" landing collar and change the well over to sea water. Pressure test the casing to 3000 psi for 30-minutes POH, LD Drillpipe RIH with 2000. of 4-1/2" 12.6# L-80 tubing. Land tubing hanger in wellhead. RILDS. Set TWC, ND BOPs NU Tree and adapter flange and test same to 5000 psi. Pull TWC. Freeze protect the well by circulating diesel around the tubing and annulus to 2000.. Set BPV and test from the annulus side to 3000 psi Release rig to A-22 RWO. 1 ) } ~o~JŒ (ill !Æ~ ~ TONY KNOWLES, GOVERNOR A.I,A.SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. -¡m AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Brian Robertson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit H -02A BP Exploration (Alaska), Inc. Permit No: 202-160 Surface Location: 1073' SNL, 1266' WEL, Sec. 21, TllN, R13E, UM Bottomhole Location: 200' NSL, 692' WEL, Sec. 21, TllN, R13E, UM Dear Mr. Robertson: Enclosed is the approved application for permit to redrill the above development well. The permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Blowout prevention equipment (BOPE) must be tested in accordance with 20AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, {ß1~{L)¿.~/ Cammy O~bhsli Taylor Chair BY ORDER OF THE COMMISSION DATED thisl2t day of August, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work [J Drill II RedriU [J Re-Entry [J Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well. at surface 1073' SNL, 1266'WEL, SEC. 21, T11N, R13E, UM At top of productive interval 515' NSL, 2583' WEL, SEC. 21, T11N, R13E, UM At total depth 200' NSL, 692' WEL, SEC. 21, T11N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028287, 200' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 5530' MD Maximum Hole Angle 18. Casin~ Program Specifications $Ize Hole GSlsinQ Weight Grade CouolinQ 8-1/2" 7" 26# L-80 BTC-M 6-1/8" 4-1/2" 12.6# 13Cr80 Vam Ace \,JGA- -Õ/I/O L ALASKA\...2 AND ~:~~g:S~~:;;ON COMM.JION ~ f!/ 'I)#Ø').. PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well [J Exploratory [J Stratigraphic Test II Development Oil [J Service [J Development Gas [J Single Zone [J Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB ::: 74.85' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028284 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / H-02A 9. Approximate spud date 08/10/02 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12950' MD 18875' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 97 ° Ma><imum surface /2360 psig, At total depth (TVD) 8000' I 3240 psig Setting Depth TQp Botom I enQth MD TVD MD TVD 4815' 5380' 5380' 10195' 8569' 2905' 10045' 8486' 12950' 8875' 11. Type Bond (See 20 AAC 25.025) ,~. Number 2S 100302630-277 Quantity of Cement (include $taQe data) 165 sx Class 'G' // 325 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9336 feet 9334 feet 8803 feet 8802 feet Length Plugs (measured) IBP at 8803' Junk (measured) Fish: WD Packer and EZ Drill BP at 9071' Size Cemented MD TVD 100' 30" 2306' 18-5/8" 8300' 13-3/8" x 9-518" 1574' 275 sx cement 4200 sx Permafrost 1561 sx Class ~'r~ ¥ f~01 ~" ~'"" \\,~".,"" ", 375 sx Class 'G' 100' 2306' 8300' 100' 2306' 8299' 7" 7742' - 9316' 7741' - 9314' JUL 3'\ Perforation depth: measured 20. Attachments 8779' - 8785' Alaska & ¡!1,'1,ch(J1'W''(\ Below Bridge Plug: 8830' - 8860', 8872' - 8902'; ~é12' -'8942', 8955' - 8965', 8976' - 8996' true vertical 8778' - 8784' Below Bridge Plug: 8829' - 8859', 8871' - 8901', 8911' - 8941', 8953'- 8963', 8974' - 8994' II Filing Fee [J Property Plat [J BOP Sketch [J Diverter Sketch II Drilling Program II Drilling Fluid Program [J Time vs Depth Plot [J Refraction Analysis [J Seabed Report [J 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21...IS~::;Y ::~=e ror:oin:;':æ~~~i:i;i:~~~:~""'¿";;;l Date 7/ ~I/D-L Permit Number API Number APWrV!D~ See cover letter :2. 0..2. - / tC: Q 50- 029-20100-01 ñ , ), for other reauirements Conditions of Approval: Samples Required 0 Yes 181 No Mud Log ~eqUI ed 0 Yes t8I No Hydrogen Sulfide Measures BI Yes 0 No Directional Survey Required 181 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T~ t- ~~ PE ~ ~ C;Oo p ç(' . OoglOal Signed By by order of ~~;~o~~~~r Rev. 12-01-8~Nnmy Oechsli Taylor 0 R fLjli~Ä L the commission () C/) Date ~,l j'!7\ Submit In Triplicate " ) ) I Well Name: I H-02A Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Sidetrack Horizontal Producer Surface Location: Estimated Target Location: Sadlerochit Zone 48 Bottom Hole Location: x = 643,318.13 1073' FNL , 1266' FEL X = 642,080.00 515' FSL, 2583' FEL X = 643,977.07 200' FSL , 692' FEL I AFE Number: I PBD-4P1883 I Estimated Start Date: I 08/10/02 I MD: 112,950' I I TVD: 18875' Y = 5,959,715.00 Sec. 21, T11 N, R13E Umiat Y = 5,956,000.00 TVDss 8750 Sec. 21, T11 N, R13E Umiat Y = 5,955,720.17 TVDss 8800 Sec. 21, T11 N, R13E Umiat I 1 I I RiQ: 1 Nabors 2ES // I OperatinQ days to complete: 123.5 ./ I BF/MS: 146.5' I I I I RKB: 174.85' 1 I I I Well DesiQn (conventional, slim hole, etc.): 1 Horizontal Sidetrack /' I Objective: I Zone 4B, Sadlerochit CasingfTubing Program Hole Size Csgl WtlFt Tbg a.D. 7" 8 Y2" 61/8" Tubing 4 Y2" 4 Y2" Directional KOP: 15,530' MD (1.5° incl) Maximum Hole Angle: Close Approach Well: Survey Program: H-02A Sidetrack 26# 12.6# 12.6# Gr~e Conn Length Top Btm MDrrVD MDrrVD L-80 BTC-mod 4815' 5380 / 5380' 1 0,195 / 8569' 13Cr-80 Vam Ace 2905' 10,045' / 8486' 12,950' / 8875' L-80 TC-II -10,015' GL 10,035' / 8481' Up to 96.5° in the target section 2.4° @ 4500' in original well The closest wellbores are the H-29A and H-34 at 118' and 145', respectively, /' center-to-center distances from the planned wellbore. All wells pass major risk criteria. Standard MWD survey from kick-off to TD. Page 1 ," ') ) Mud Program Window Milling Mud Properties: LSND I Whip stock Window 9 5/8" I Density (p~) Viscosity PV YP tauO HTHP pH API FI 10.0 50 - 60 10-13 25 - 35 6-8 <10 9.0 <6 Drilling Mud Properties: LSND 18 Y2" Hole Section in HRZ I Density (p~) Viscosity PV YP tauO HTHP pH API FI 10.6 45 - 55 11 -15 20 - 30 4-7 <10 8.5 - 9.0 <6 Production Mud Properties: Quickdril-N I 6 1/8" hole section I Density (pp~ Viscosity PV YP tauO MBT pH API FI 8.4 - 8.6 45 - 55 6-8 22 - 27 4-7 <3 8.5 - 9.0 NIC Logging Program 8 %" Intermediate: Sample Catchers - None Drilling: MWD PWD Dir/GR- Real time throughout entire interval. Open Hole: None Cased Hole: None Open Hole: Cased Hole: Sample Catchers - Two, at Company man call out MWD ABI Dir/GRlRes/Neu/Den - Real time GR/RES throughout entire interval to help geosteer, Memory Neu/Den None None 6 1/8" Production: Drilling: Cement Program Casing Size 17" Intermediate Liner Basis: Lead: None Tail: Based on 85' of 7" shoe tract and 1000' of 8 Y2" open hole x 7" casing annulus with 40% excess. (~Iiner lap or 9 5/8" x 4" DP annulus volume). Tail TOC: -9195' /' MD (8020'TVDbkb). Fluid Sequence & Volumes: Pre 10 bbls Water Flush Spacer Lead Tail 30 bbls Alpha Spacer at 11.6 ppg None / /' 35 bbl I 196 fe I 165 sks of Halliburton 'G' at 15.8 ppg and 1.19 dIsk, BHST 2100 @ 8825' TVDss TT = Batch Mix 4 to 4.5 hrs Casing Size I 4 %" Production Liner Basis: Lead: None Tail: Based,¿:>n 2755' of 6 1/8" open hole with 40% excess, 150' of 4 Y2" x 7" liner lap, 85 shoe tract. Tail TOC: -10,538' MD (8815' TVDbkb).- Liner top. Fluid Sequence & Volumes: Pre 10 bbls Water Flush Spacer Lead Tail 30 bbls Alpha Spacer at 9.5 ppg None / / 69 bbl I 386 fe I 325 sks of Halliburton 'G' at 15.8 ppg and 1.19 dIsk, BHST 2240 @ 8800' TVDss TT = Batch Mix 4 to 4.5 hrs H-02A Sidetrack Page 2 .' ) ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. /' BOPE and drilling fluid system schematics are currently on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3240 psi @ 8000' TVDss - Ivishak . Maximum surface pressure: 2360 psi @ surface /' (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 3500 psi / 8.6 ppg seawater /7.2 ppg Diesel . . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . Markers Formation Tops (Wp#10) TVDss MDbkb Comments UG1 WS1 CM3 THRZ BHRZ Top Jurassic Sag River Shublik Top Sadlerochit TD 4800 5480 5695 7090 7300 7400 8610 8640 8740 88001 9.3 ppg EMW @ 4900' TVD Not penetrated /' 3240 psi @ 8800' TVD (7.1 ppg EMW) ,/ 12,950 TD Criteria: 500' minimum of pay zone. Sidetrack and Complete Procedure Summary H-02A Sidetrack Page 3 .' ') RiQ Operations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. / 4. Pull 5 Y2" tubing from cut. 5. Change out 9 5/8" casing packoff if necessary. 6. MU window milling BHA drift down to JÞé KOP. 7. Set bridge plug on wireline at :t5555' such that the window will not be cut through a casing collar. Test casing to 3000 psi. 8. RIH with 9 5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on bridge plug. Change well over to milling fluid. Mill window in casing at:t 5530' MD. Perform FIT to 12.0 ppg. POOH. 9. Kick-off and drill th~ Y2" section as per the directional plan to top of Sag River formation. 17 1 O. Change pipe rams as re~ired. Run and cement a 7" drilling liner, displace with mud. 11, Test casing to 3000 psi. Drill out shoe and 20' of new formation, displace well to 8.5 ppg QuickDRILn mud. 12. Drill 6 1/8" production hole as per directional plan to TO well at :t12,950' MD. 13. Short trip, CBU, spot liner running pill, POH. /' 14. Run and cement a 4 Y2", 12.6#, L-80 production liner to TO. Displace with perf pill and seawater. Circulate the well to clean seawater at the liner top, POOH. 15. OPC overbalanced approximately 500' with 2 Y2" perf guns. 16. Run 4 Y2", 12.6# 13Cr-80 completion tying into the 4Y2" liner top. 17. Set packer and test the tubing and annulus to 3000 psi for 30 minutes. 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 19. Freeze protect the well. 20. Rig down and move off. Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. H-02A Sidetrack Page 4 ~' ) Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move to H-02A. The closest wells are on 60' spacing either side. ~ D-Pad is a designated as an H2S site: Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Closest BHL Wells H-23 10ppm H2S (5/5/2002) H-06 25 ppm (7/9/2002) H-29 10ppm (8/25/2000) H-01 10 ppm (4/22/1999) / The maximum level recorded of H2S on the pad was 180 ppm on 5/5/2001. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Job 2: De-complete Well Hazards and Contingencies ~ The perforated intervals and lower section of this well should be isolated by 2 barriers (the cement plug and the seawater). The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. Job 3: Run Whipstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Job 4: Drill 8 Y2" Intermediate Hole Hazards and Contingencies ~ The well will be kicked off in the Ugnuand drilling through the Kingak; wellbore stability is a major concern. Ensure the mud weight does not drop below the minimum stated requirement. Use PWD to ensure good drilling and connection practices. ~ KICK TOLERANCE: In the worst-case scenario of 10.0 ppg pore pressure at the top Sadlerochit depth, a fracture gradient of 1 ~ppg at the 9 5/8" casing window, and 10.6ppg mud in the hole, the kick tolerance is 52 bbls. Kick tolerance is infinite under the more reasonable case of 7.1 ppg reservoir pressure. ~ H pad has a history of shallow gas in the West Sak area (5200-5700) though all kicks were maintained with 9.8 ppg mud. Planned KO MW is 10.0 ppg. Job 6: Install 7" Intermediate DrillinQ Liner Hazards and Contingencies ~ Minimize surge while RIH with the drilling liner. Lost circulation has been a problem in the 7500' TVD region and at the top of the reservoir in previous wells (see pad data sheet). Avoid penetrating much into the Sag River formation in the 8 Y2" section. H-02A Sidetrack Page 5 .' ') ) Job 7: Drill 6 1/8" Production Hole Hazards and Contingencies ~ Faults surround the target polygon. A small fault to the north, a moderate fault to the west, and a large fault to the south. Additionally, there is possibly a fault at the end of the target polygon. Stay within the target polygon except as to increase the footage of the horizontal section in the event the minimum 500' of pay interval is not achieved or if high oil saturations remain. ~ Fluid saturations and contacts are not well established. Be prepared to geo-steer as necessary, but confirm any major deviations from plan with the Anchorage team before drilling ahead. ~ Kick tolerance is infinite in this hole section under any reasonable circumstance. ~ The closest well (after significant footage from the window) is H-34 at 145' center to center while drilling at 7700'. Watch for magnetic interference while surveying in this area. Job 9: Install 4Y2" Production Liner Hazards and Contingencies Differential sticking is a concern. The 8.5 ppg Quickdril will be -650 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. Job 10: DPC Perforate Hazards and Contingencies ~ Observe Halliburton's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. »»>-- Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ Though there are no close proximity surface issues, identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig about the pad and while positioning on the hole. H-02A Sidetrack Page 6 TREE = .' WELLHIîAD = . ÄëTÙÄ TOR = .. . ,'....'" "'",,,..''''M . , .," KB, ELEV = "n'"'''''' .. BF. ELEV = 6" CrN MCEVOY . .. ......... -, . OTIS "'h'.. .n",,' . ... ",. . 63,95' 44.83' ') .. .....".. ".... ....... ... ....". Max Angle = 2 @ 4400' ÓätumK.1Ô';'ww,w,,,,, ,. . "'8865; YU" .,." .'- .. w.'.'.'.','.',w,v .,..... .. .... ..."" Datum TVD = 8800' SS 113-3/8" CSG, 68#, N-80, ID = 12.415" l-i 2271' 118-5/8" CSG, 96.5#, K-55, ID = 17.655" l-i 2308' Minimum ID = 3.725" @ 7774' 4-1/2" OTIS XN NIPPLE r 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4,892" l-i 7698' I TOP OF 7" LNR l-i 7742' 14-1/2" TAILPlÆ, 12.6#, L-80, .0152 bpf, ID = 3.958" l-i 7812' 19-5/8" CSG, 47#, N-80, ID = 8.681" l-i 8300' 1---41 ÆRFORA TION SUMMARY REF LOG: BHCS 07/24/71 ANGLE AT TOP ÆRF: 1 @ 8830' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 2 8779-8785 0 10/08/90 4" 4 8830-8860 C 01/10/87 2-7/8" 4 8872-8902 C 01/10/87 2-7/8" 4 8912-8942 C 01/10/87 2-7/8" 4 8955-8965 C 01/10/87 2-7/8" 4 8976-8996 C 01/10/87 I PBTD l-i 9160' I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1-1 93181 H-02 I SAFET'fTES: TOP OF SCALE @ 8796'. 8 1 I r 1 ~ 2136' 1-i5-1/2" OTIS SSSV LAND NIP, ID = 4.562" 1 22711 l-i 13-3/8" X 9-5/8" TrN TIEBACK PKR 1 ~ 2271' l-i 13-3/8" X 9-518" XOI GAS LIFT MANDRELS TVD DEV 1YÆ VLV LATCH 3266 0 OTIS RA 5086 2 OTIS RA 6540 1 OTIS RA 7452 2 OTIS RA 7559- 2 OTIS RA PORT DATE ST MD 5 3266 4 5086 3 6540 2 7452 1 7559 L I I L 7627' 1-i5-1/2" SLIDING SLY, ID = 4.562" I i ì 1 7683' I-iTBG SEAL ASSY I Z z I 76981 1-i9-5/8" X 5-1/2" TrN PKR, ID = 4.75" I \ ¡ I 7698' 1-i5-1/2" X 4-1/2" XO I 1 7741' 1-i4-1/2" OTIS X NIP, ID = 3,813" 1 .. I f l 7774' 1-i4-1/2" OTIS XN NIP, ID = 3.725" I 78121 1-14-1/2" TBG TAIL, ID = 3.958" 1 7785' l-i ELMD TT LOGGED 12/29/89 I ~ ~ 8803' l-i TOP OF IBP 1 ,/ -..- ~ 9071' l-i FISH - WD PKR & EZ DRILL BP I DATE 12/28/75 08/86 02/15/01 03/01/01 08/14/01 REV BY DA TE REV BY COMMENTS PRUDHOE BAY UNIT WELL: H-02 ÆRMIT No: 71-0160 API No: 50-029-20100-00 Sec. 21, T11N, R13E BP Exploration (Alas ka) COMMENTS ORIGINA L COMA-EriON RWO SIS-SL T CONVERTED TO CANVAS SIS-LG FINAL RNlKA K CORRECTIONS TREE == .' WELLHEAD == . ~.,.,..... ". A CTUA TOR == .,,, , " ...... '" " KB, ELEV == .,. ,- .. BF, ELEV == 6"CW MCEVOY OTIS 63.95' 44.83' ") H-02 Pre-Rig ) . .. . ,w,- . . .... .._, M,~,~ ~~~~~w~,,,. ,w,2.~ 4~~o.: Datum MD == 8865' " ., ", ... . . , . . ,,".w.W."oW," " '.~W-",.'.'.'.'.'W U "" ,... Datum TVD == 8800' SS 113-3/8" CSG, 68#, N-80, ID == 12.415" 1-1 1 2136' 1-15-1/2" OTIS SSSV LAND NIP, ID == 4.562" 1 <8 1 2271' 1-113-3/8" X 9-5/8" TW TIEBACK PKR 1 2271' H ~ 1 2271' 1-113-3/8" X 9-5/8" Xol 2308' ~ ~ 118-5/8" CSG, 96,5#, K-55, ID == 17,655" 1-1 Minimum ID = 3.725" @ 7774' 4-1/2" OTIS XN NIPPLE I 5-1/2" TBG, 17#, L-80, ,0232 bpf, ID == 4,892" 1-1 7698' I TOP OF 7" LNR 1-1 7742' 14-1/2" TAILPlÆ, 12.6#, L-80, .0152 bpf, ID == 3,958" l-i 7812' 19-5/8" CSG, 47#, N-80, ID == 8.681" 1-1 8300' I~ PERFORA TION SUMrv1ARY REF LOG: BHCS 07/24/71 ANGLE AT TOP PERF: 1 @ 8830' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 2 8779-8785 0 10/08/90 4" 4 8830-8860 C 01/10/87 2-7/8" 4 8872-8902 C 01/10/87 2-7/8" 4 8912-8942 C 01/10/87 2-7/8" 4 8955-8965 C 01/10/87 2-7/8" 4 8976-8996 C 01/10/87 I PBTD 1-1 9160' 1 7" LNR, 29#, L-80, .0371 bpf, ID == 6.184" l-i 9318' DA TE REV BY COMMENTS 12/28/75 ORIGINAL COMPLETION 08/14/01 RNlKAK CORRECTIONS 01/17/02 WDQ Proposed Completion DA TE REV BY I I i ì z z \¡ 11 I á'~~r~~. .. :t:~;:'~:.~;:~ .:f;;;~:J.~~~ I .. .~~.', ':.., ~.. " I .'. -.. ..-;.. 9 -.-- %l1li£. COMMENTS -5900' -- Tubing Cut 7627' l-i 5-1/2" SLIDING SL V, ID == 4.562" I 7683' 1-1 TBG SEAL ASSY I 7698' 1-19-5/8"X5-1/2"TWPKR, ID==4,75" I 7698' 1-15-1/2" X 4-1/2" XO I 7741' 1-i4-1/2" OTIS X NIP, ID == 3,813" I 7774' 1-14-1/2" OTIS XN NIP, ID == 3.725" 1 7812' 1-14-1/2" TBG TAIL, ID == 3.958" 1 7785' 1-1 ELMD TT LOGGED 12/29/89 I / Cement P & A 8803' 1-1 TOP OF IBP I 9071' 1-1 FISH - WD PKR & EZ DRILL BP 1 PRUDHOE BAY UNIT WELL: H-02 PERMIT No: 71-0160 API No: 50-029-20100-00 Sec. 21, T11N,R13E BP Exploration (Alaska) .' H-02A Prop,~"sed Completion ) TREE = WELLHEAD = ,..".,.. .,.... ........ ...... ACTUA TOR = . ," 'W,", .. ," .." ...~,... o. KB. ELEV = . ... ..,..,... .. -, BF, ELEV = 6" CrN MCEVOY ....",.......,..... .. OTIS 63,95' 44.83' 13-3/8" x 9-5/8" TIW Tieback & PKR " 13-3/8 x 9.5/8" XO 2271' ~ Cement P & A 8300' 9-5/8" CSG, 47#, N-80 l M ~ I ~ r ~ L . -,.. ... .....", ... ..... .w.- .--. Max Angle = "'''W,,",W,"...-M"'''''W,',",",',",'''''"MW.W,W,",W,",",''''',",",",",........W.WW..... '" .. ",",","",,",w. , Datum MD = .e,..... .. ., . .... Datum ìVD = 8800' SS 2200' 2271' 4-112' '>Urdrg N~e wth 3.813 seal !:be. 113-3/8" CSG, 68#, N-80, ID = 12.415" 1-1 118-5/8" CSG, 96.5#, K-55, ID = 17.655" l-i 4-1/2" 12.6# 13Cr, Tubing with GLM's 2308' No I GAS LIFT MANDRELS TVD I Size I Valve Type 6 GLMs Gas Lift Mandrel Spacing TBD / ~ I +/-5380' I BAKER 7" x 9-5/8" Tie Back Sleeve ~ ZXP Liner Top Packer 'Flexlock' Hydraulic Liner Hanger. r ... I . Ð I J , i It. ~ - Window Milled from WhiPstOCk/' Top of Window at +/-5530' MD 9,975' 9,990' 10,015' 10,035' 10,045' I +/-10,195' I 7",26#, L-80, BTC-M Date 12/28/75 07/11/02 4-1/2" 'X' Landing Nipple with 3,813" seal bore. T' x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.725" seal bore. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. I +/-10,045' I BAKER 5" x 7" Tie Back Sleeve ZXP Liner Top Packer 'FlexLock' Hydraulic Liner Hanger 4-1/2" 12.6 #/ft, L-80, BTC-Mod Plug Back Depth I +/-12,950' I I +/-12,865' I it,t.t'...:,o.' t.'.. ::.:.,;.~ Horizontal Sidetrack into Zone 4 Sands Rev By Comments PRUDHOE BAY UNIT WELL: H-02A API NO: 50-029-20100-01 PGS Original Completion Proposed Completion Prudhoe Bay Unit d 4900- 5600 6300 :e d:! 8 !::. t ð 11 7000 'f ~ ~ 7700 . 8400 COMPANY DETAILS REFERENCE INFORMATION Co-ordinate (NÆ) Reference: Well Centre: H-02, True North Vertical (1VD) Relèrence: 74,85 74,85 Section (VS) Reference: Slot - 02 (O,OON,O,ooE) Measured Depth Reference: 74,85 74.85 OIlculaUoo Method: Minimwn CUrvature SURVEY PROGRAM Depth Fm Depth To SurveylPlan 5530.00 12950,11 Planned: H-02a wp09 VI Checked: Plan: H-02a wp09 (H-02IPlan H.02A) Created By: Ken Allen Date: 1/1112002 Date: Date: Tool BP Amoco OIlculaliOll Method: Minimwn CUrvature ~; ~:~r ~';vW¿'iœr North Enor Surfåce: Elliptical + Casing Wam;/1¡ Me/hIJd: Rules Baaed MWD Reviewed: WELL DETAILS Basting Latih1de Longitude Slot 643318,05 70ol7'50,79IN 148°50'21.733W 02 1 ec MD Inc Azi TVD +N/-S +EI-W DLeg TFace VSec Target 5530.00 1.42 211.00 5529.07 -56.02 -17.42 II lilt 0.00 52.93 6189.70 41.00 207.92 6131.93 -262.51 -127.37 tl lilt 356.83 241.47 7189.70 41.00 207.92 6886.64 -842.21 -434.56 (I (III 0.00 770.95 7449.60 56.59 207.92 7057.32 -1014.46 -525,84 tlllll 0.00 928.29 9982.78 56.59 207.92 8452.00 -2883.00 -1516.00 (11111 0.00 2634.99 10195.29 56.59 199.42 8569.00 -3045.33 -1587.15 I \-1. -90.00 2785.40 10400.88 74.38 182.18 8654,49 -3227.78 -1619.91 II ~II -45.39 2961.24 10405.02 74.38 182.18 8655.60 -3231.76 -1620.06 JJ 1111 0.00 2965.16 11066.57 76.00 103.00 8854.85 -3691.98 -1265.80 ""Í I ~II -100.92 3471.55 H-02a Start ~ 0 11184.64 85.43 102.52 8873.88 -3717.69 -1152.27 K 1111 -2.90 3513.31 1 11341.85 85.43 102.52 8886.39 -3751.66 -999.29 111111 0.00 3568.94 .2 11428.76 90.00 )-g°'00 8889.85 -3768.61 -914.15 flllll -28.96 3597.96 H-02a Land Rev3 3 11543.32 96.54 97.89 8883.32 -3786.39 -801.24 to UII -17.81 3631.79 A 11999.09 96.54 97.89 8831.38 -3848.54 -352.72 IIfJII 0.00 3757.80 5 12113.64 90.00 100.00 8824.85 -3866.32 -239.81 h 1111 162.07 3791.63 H-02a Mid3 6 12172.88 86.45 99.89 8826.69 -3876.54 -181.50 t, 1111 -178.28 3810.14 7 12950.11 86.45 99.89 8874.85 -4009.82 582.70 I) Otl 0.00 4051.94 H-02a TD Rev3 Name +NI-S +EI-W Nodbiog H-02 2108,67 1992.14 5959717,84 TARGET DETAILS Name ~~~~0u2 H-02a TO Rev3 TVD +EI-W +NI-S 8849.85 -3187,75 -1643,41 5956499.58 8824.85 .386632 -239,81 5955847,95 8874.85 -4009.82 582,70 5955720.17 ~~%~ , ~m~~ .oo~ ""'Ok ,61.9TM ~ .ø Á..~--"'" - } \--\CM' . O,6131.93'TVD ~ / ' - --..... ~ ^-<J I~ , 7000 ~~M""tJ" " .. If 61100': 71897' , . MD,6886.64'TVO -=.nd Ltr : 7449 6' 1.;M . MD, 7057.32' TVD 'lK.....1:J "~ ~T~ 90~ SECTION DETAILS Start Dir 61100': 5530' MD, 5529.07'TVD ...--- WSl ...~ .......... C~3 "'A '" '4:b fJ' ~ "-/ .....""" ~ ", No. TVD - . Northing Easting Shape 641735.85 Polygon 643152.03 Point 643977,06 Point FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 1 2 3 4 5 6 7 8 9 10 II 12 13 14 15 5529.07 5530.00 WSI 5750.85 5754.56 CM3 6189.85 6266.45 CM2 6723.85 6974.00 CMl 7024.8S 7393.13 THRZ 7274.85 7844.71 TKLB 7286.85 7866.51 LCU 7321.85 7930.08 TIG 7682.85 8585.77 TJF 7809.85 8816.44 TJE 8040.85 9236.01 TJD 8274.85 9661.03 TIC 8398.85 9886.25 TJB 8479.85 10033.37 TIA 8568.85 10195.02 TSGR CASING DETAILS MD Name Size .~ I 8568.85 10195.02 7" 2 8874.85 12950.10 41/2" 7.000 4.500 EIId::>ù . 1;<172.88' MD, 8826,69' TVD ( -4.. - T uta! Depth: 12950.11' MD, 8874.85' TVD ~ 4112" ~;:t"rt Nr I,/IOU ' 11999.09' MD, 8831.38'TVD 2100 2800 3500 Vertical Section at 171.73° [700ft/in] 4200 I 4900 TB Start Dir 3.3../10,)': ~98Z.78' M>. 8452'TVD ~,TIA oo:o--.r TSGR Start Dir 1.51.00': lC19~29' MD, 8569":VD ;.. >- End ::>ir : lCAOO.88' MD, 8654.4-9' TVr 'l ~ Start Dir 11.5/HO' : 104 )5.ü2' MD, 8655.6''"":'VD I I 101)0 . - - All TVD depths are Stdit Dir 811O~ ; 1106.,.57' MJ, 8J54,8S'-=v'D J I 9100-- ~n(' Di' : Illl!4.6L' MD. ~8n88' TV) ssTVD Plus 74 85' Úor RKBE Star:DiJ6/100':llJ41.85'MD,88~6.~9'TVD . . . End Dir: 154-3.32' WD, 888éo.32 T\lD I' i ¡¡I ¡Ii i I Iii I 0 ~ I~ I 5600 d Æ <= 0 0 !::. +' f ~ J tIJ Start Die 3.34/100' : 9982.78' MD, 8452'lVD StaLl'At l.SIOO': 1019~.29' lAu, ~S69'. Vii All TVD depths are 8500 í/ 7" --Jf( ~ 3ndDir : '04()()'88'MD,8~54Æ'TVD ssTVD plus 74.85' for RKBE. ~ 3liul ::>il I. .5/H'O' . 1-)405.-)2' MD, 8655.6'~VD I\{J Start Dir WOO' : 11066.57' MD, 885"-.85'1VD E:ld Dir : 1 184.ii4' M::>, 8873.88' TVú ~. Start D r 61100': 11341 85' WD, 8386.39'TVD ¡ Start Die 6/100': 11999.09' MD, 8831.38'lVD H-02a Start I Ent Die : 12172.88' MD, 8826.69' TVD ~i-02aLan~ ~otalDepth: 12950.11'MD,8874.85'TVD End Dir : 11543.32" MD 888:'.32' -VD H 02 M'd3 - a 1 '-02a wp09 L 1/2" F -mil TO Rf.v~ COMPANY DETAILS REFERENCE INFORMATION Co-ordinate (NÆ) Referenœ: Well Centre: Ho02, True North Vertical (IVD) lœtèrenœ: 74.8574.85 Section (VS) Reference: Slot- 02 (O.ooN,O.ooE) Measured Deplh Reference: 74,85 74.85 Calculation Method: Minimum Curvature SURVEY PROGRAM Depth Fm Depth To SurveylPlan 5530,00 12950.11 Planned: H-02a wp09 VI BP Amoco Calculation Method: Minimum Curvature ~:; mœ~:: is;:¿.tinder North Error Surface: Elliptical + Casin8 Warn;! Melh<Jd: Rulea Based 0 H-02 (H-02) End Dir : 6189.1' MD. 613' .93' ':'VD ! ee MD -700 5530.00 1.42 6189.70 41.00 7189.70 41.00 7449.60 56.59 9982.78 56.59 10195.29 56.59 10400.88 74.38 10405.02 74.38 11066.57 76.00 0 11184.64 85.43 . 1 11341.85 85.43 2 11428.76 90.00 Þ3 11543.32 96.54 :A 11999.09 96.54 . 5 12113.64 90.00 6 12172.88 86.45 7 12950.11 86.45 Sod Dir : 7449.6' MD, 7057.32' TVD .1400 -2100 -2800 -3500 -4200 -2100 -1400 -700 0 West(-)Æast(+) [700ftJin] 700 I 1400 Plan: H-02a wp09 (H-02IPlan H-02A) Tool Date: 1111/2002 Created By: Ken Allen Checked: Date: . . MWD Reviewed: Date: WELL DETAILS Name +N/.S Easüng Latitude Loogitude Slot +EI.W Northiog H-02 2108,67 1992.14 5959717,84 643318,05 70017'50,79IN 148°SO'2L733W 02 TARGET DETAILS Ine Name 1VD +NI.S +EI-W Northing &sting Shape Bo02A Polyg0n2 8849.85 .3187.75 -1643AI 5956499.58 641735.85 PolY8on H-02a M¡dJ 8824.85 -3866.32 .239.81 5955847,95 643152,03 Point H-02a lD Rev3 8874.85 -4009.82 582.70 5955720.17 643977.(J6 Point H-02a Land Rev3 8889.85 .3768.61 -914,15 5955932,77 642476.01 Point H-02a Start 8854.85 .3691.98 .1265.80 5956002.68 642122,99 Point SECTION DETAILS Azi TVD +N/-S +E/-W DLeg TFaee VSec Target 211.00 5529.07 -56.02 -17.42 0.00 0.00 52.93 207.92 6131.93 -262.51 -127.37 6.00 356.83 241.47 207.92 6886.64 -842.21 -434.56 0.00 0.00 770.95 207.92 7057.32 -1014.46 -525.84 6.00 0.00 928.29 207.92 8452.00 -2883.00 -1516.00 0.00 0.00 2634.99 199.42 8569.00 -3045.33 -1587.15 3.34 -90.00 2785.40 182.18 8654.49 -3227.78 .1619.91 11.50 -45.39 2961.24 ."-V 182.18 8655.60 -3231.76 -1620.06 0.00 0.00 2965.16 103.00 8854.85 -3691.98 -1265.80 11.50 -100.92 3471.55 H-02a Start 102.52 8873.88 -3717.69 -1152.27 8.00 -2.90 3513.31 102.52 8886.39 -3751.66 -999.29 0.00 0.00 3568.94 100.00 8889.85 -3768.61 -914.15 6.00 -28.96 3597.96 H-02a Land Rev3 97.89 8883.32 -3786.39 -801.24 6.00 -17.81 3631. 79 97.89 8831.38 -3848.54 -352.72 0.00 0.00 3757.80 100.00 8824.85 -3866.32 -239.81 6.00 162.07 3791.63 H-02a Mid3 99.89 8826.69 -3876.54 -181.50 6.00 -178.28 3810.14 99.89 8874.85 -4009.82 582.70 0.00 0.00 4051.94 H-02a TD Rev3 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 5529.07 5530.00 WSI 2 5750.85 5754.56 CMJ 3 6189.85 6266.45 CM2 4 6723.85 6974.00 CMl 5 7024.85 7393.13 THRZ 6 7274.85 7844.71 TKLB 7 7286.85 7866.51 LeU 8 7321.85 7930.08 TJG 9 7682.85 8585.77 TJF 10 7809.85 8816.44 TJE 11 8040.85 9236.0 I TJD 12 8274.85 9661.03 TJC 13 8398.85 9886.25 TJB 14 8479.85 10033.37 TJA 15 8568.85 10195.02 TSGR " CASING DETAILS No. TVD MD Name Size 8568.85 10195.02 7" 7.000 8874.85 12950.10 4 1/2" 4.500 I 2100 .' ) BP Amoco Planning Report.. Geographic ") Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: PB H Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5957572.25 ft Latitude: 641366.07 ft Longitude: North Reference: Grid Convergence: H-02 H-02 Surface Position: +N/-S 2108.67 ft +E/-W 1992.14 ft Position Uncertainty: 0.00 ft Reference Point: +N/-S 2108.67 ft +E/-W 1992.14 ft Alaska, Zone 4 Well Centre BGGM2001 70 17 30.055 N 148 51 19.802 W True 1.08 deg Slot Name: 02 Northing: 5959717.84 ft Latitude: 70 17 50.791 N Easting : 643318.05 ft Longitude: 148 50 21.733 W Northing: 5959717.84 ft Latitude: 70 17 50.791 N Easting : 643318.05 ft Longitp.de: 148 50 21.733 W Measured Depth: 31.85 ft Inclination: 0.00 deg Vertical Depth: 31.85 ft Azimuth: 0.00 deg Well: Wellpath: Plan H-02A Drilled From: Tie-on Deptb: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 74.85 11/15/2001 57489 nT Depth From (TVD) ft 0.00 Height 74.85 ft +N/-S ft 0.00 Plan: H-02a wp09 Date Composed: Version: Tied-to: Principal: Yes Plan Section Information H-02 5530.00 ft Mean Sea Level 26.42 deg 80.77 deg Direction deg 171.73 1/10/2002 1 From: Definitive Path 5530.00 1.42 211.00 5529.07 -56.02 -17 .42 0.00 0.00 0.00 0.00 6189.70 41.00 207.92 6131.93 -262.51 -127.37 6.00 6.00 -0.47 356.83 7189.70 41.00 207.92 6886.64 -842.21 -434.56 0.00 0.00 0.00 0.00 7449.60 56.59 207.92 7057.32 -1014.46 -525.84 6.00 6.00 0.00 0.00 9982.78 56.59 207.92 8452.00 -2883.00 -1516.00 0.00 0.00 0.00 0.00 10195.29 56.59 199.42 8569.00 -3045.33 -1587.15 3.34 0.00 -4.00 -90.00 10400.88 74.38 182.18 8654.49 -3227.78 -1619.91 11.50 8.65 -8.39 -45.39 10405.02 74.38 182.18 8655.60 -3231.76 -1620.06 0.00 0.00 0.00 0.00 11066.57 76.00 103.00 8854.85 -3691.98 -1265.80 11.50 0.24 -11.97 -100.92 H-02a Start 11184.64 85.43 102.52 8873.88 -3717.69 -1152.27 8.00 7.99 -0.40 -2.90 11341.85 85.43 102.52 8886.39 -3751.66 -999.29 0.00 0.00 0.00 0.00 11428.76 90.00 100.00 8889.85 -3768.61 -914.15 6.00 5.25 -2.90 -28.96 H-02a Land Rev3 11543.32 96.54 97.89 8883.32 -3786.39 -801.24 6.00 5.71 -1.84 -17.81 11999.09 96.54 97.89 8831.38 -3848.54 -352.72 0.00 0.00 0.00 0.00 12113.64 90.00 100.00 8824.85 -3866.32 -239.81 6.00 -5.71 1.84 162.07 H-02a Mid3 12172.88 86.45 99.89 8826.69 -3876.54 -181.50 6.00 -6.00 -0.18 -178.28 12950.11 86.45 99.89 8874.85 -4009.82 582.70 0.00 0.00 0.00 0.00 H-02a TD Rev3 Section 1: Start MD Incl Azim TV» +N/-S +EI-W VS DLS Build Turn TFO ft deg deg ft ft It ft degf100ft deg/100ft degl100ft deg 5530.00 1.42 211.00 5529.07 -56.02 -17.42 52.93 0.00 0.00 0.00 0.00 5550.00 2.62 209.55 5549.06 -56.63 -17.77 53.49 6.00 6.00 -7.26 -3.17 5600.00 5.62 208.63 5598.92 -59.77 -19.51 56.35 6.00 6.00 -1.84 -1.72 .' ) ') BP Amoco Planning Report - Geographic Section 1: Start MD ft 5650.00 5700.00 ' 5750.00 5800.00 5850.00 5900.00 5950.00 6000.00 6050.00 6100.00 6150.00 6189.70 Section 2: Start Inel deg 8.62 11.62 14.62 17.62 20.62 23.62 26.62 29.62 32.62 35.62 38.62 41.00 Adm d~ 208.35 208.21 208.13 208.08 208.04 208.01 207.99 207.97 207.95 207.94 207.93 207.92 ,TVD ft , 5648.53 5697.75 5746.44 5794.47 5841.70 5888.02 5933.29 5977.38 6020.18 6061.57 6101.43 6131.93 +N/-S ft, -65.22 -72.95 -82.96 -95.20 -109.65 -126.27 -145.00 -165.81 -188.63 -213.40 -240.06 -262.51 +EI-W ft -22.46 -26.62 -31.98 -38.52 -46.22 -55.06 -65.02 -76.08 -88.19 -101.33 -115.47 -127.37 VS . ft . 61.31 68.37 77.50 88.67 101.86 117 .03 134.14 153.15 173.99 196.61 220.96 241.46 DLS Build Turn deg/100fLd8g11QQftdegllOQft 6.00 6.00 -0.56 6.00 6.00 -0.27 6.00 6.00 -0.16 6.00 6.00 -0.11 6.00 6.00 -0.08 6.00 6.00 -0.06 6.00 6.00 -0.05 6.00 6.00 -0.04 6.00 6.00 -0.03 6.00 6.00 -0.03 6.00 6.00 -0.02 6.00 6.00 -0.02 TFO deg -0.80 -0.52 -0.39 -0.31 -0.26 -0.22 -0.20 -0.18 -0.16 -0.15 -0.13 -0.15 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7189.70 41.00 41.00 41.00 41.00 41.00 41.00 41.00 41.00 41.00 41.00 41.00 Section 3: Start l\ß), . ':'Ipç[" ' ft. . ,~eg 7200.00 41.62 7250.00 44.62 7300.00 47.62 7350.00 50.62 7400.00 53.62 7449.60 56.59 Section 4: Start ,MIl ft 7500.00 7600.00 7700.00 7800.00 7900.00 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8700.00 8800.00 8900.00 9000.00 9100.00 9200.00 9300.00 9400.00 'Inel . Øeg. 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 56.59 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 -~" ..q~ 207.92 207.92 207.92 207.92 207.92 207.92 , ,AZbti -'(jag. .. 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 207.92 6139.70 6215.17 6290.65 6366.12 6441.59 6517.06 6592.53 6668.00 6743.47 6818.94 6886.64 ''IMJ . '~:, 6894.38 6930.87 6965.52 6998.25 7028.94 7057.32 .~TVD " ',' ft 7085.07 7140.13 7195.20 7250.26 7305.32 7360.38 7415.45 7470.51 7525.57 7580.64 7635.70 7690.76 7745.82 7800.89 7855.95 7911.01 7966.07 8021.14 8076.20 8131.26 -268.48 -326.45 -384.42 -442.39 -500.36 -558.33 -616.30 -674.27 -732.24 -790.21 -842.21 ) <~+Nì.:.s' ", .;ft,~ ' -848.22 -878.41 -910.25 -943.65 -978.52 -1014.46 :::+1!,t,: -1051.63 -1125.39 -1199.15 -1272.91 -1346.67 -1420.43 -1494.19 -1567.95 -1641.71 -1715.46 -1789.22 -1862.98 -1936.74 -2010.50 -2084.26 -2158.02 -2231.78 -2305.53 -2379.29 -2453.05 -130.53 -161.25 -191.97 -222.69 -253.41 -284.13 -314.85 -345.57 -376.29 -407.01 -434.56 . +¡þW:,' ft ,: -437.74 -453.74 -470.62 -488.32 -506.79 -525.84 .+EbW.' "';.dt.', -545.54 -584.63 -623.71 -662.80 -701.88 -740.97 -780.06 -819.14 -858.23 -897.32 -936.40 -975.49 -1014.57 -1053.66 -1092.75 -1131.83 -1170.92 -1210.01 -1249.09 -1288.18 246.92 299.86 352.81 405.76 458.71 511.66 564.61 617.56 670.51 723.46 770.96 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 .~- .' .,Jt::. 776.44 804.02 833.10 863.61 895.46 928.29 ;:~t~:';:(j~~~i:~9Þft;'~~ . 6.00 6.00 0.00 0.00 6.00 6.00 0.00 0.00 6.00 6.00 0.00 0.00 6.00 6.00 0.00 0.00 6.00 6.00 0.00 0.00 5.99 5.99 0.00 0.00 '. 'VS:: ,. "..'ff}>. 962.24 1029.61 1096.98 1164.35 1231.72 1299.09 1366.46 1433.84 1501.21 1568.58 1635.95 1703.32 1770.69 1838.06 1905.43 1972.80 2040.17 2107.54 2174.91 2242.28 .,...;,.J)LS>..".~BuiId.':....T~rn. '. :~1~,~l()()ft'dew109ft : 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFO, ,'(jag'. . 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 . ' ) ) BP Amoco Planning Report - Geographic Section 4: Start 9500.00 9600.00 9700.00 9800.00 9900.00 9982.78 56.59 56.59 56.59 56.59 56.59 56.59 Section 5: Start 207.92 207.92 207.92 207.92 207.92 207.92 8186.32 8241.39 8296.45 8351.51 8406.58 8452.00 -2526.81 -2600.57 -2674.33 -2748.09 -2821.85 -2883.00 -1327.26 -1366.35 -1405.44 -1444.52 -1483.61 -1516.00 2309.65 2377.02 2444.39 2511.76 2579.14 2634.99 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 10000.00 56.59 10100.00 56.59 10195.29 56.59 Section 6: Start 207.23 8461.48 -2895.74 -1522.65 2646.65 203.23 8516.54 -2971.24 -1558.23 2716.24 199.42 8569.00 -3045.33 -1587.15 2785.40 3.34 3.34 3.34 . =~;~~~Q9ft"'~:~~F 0.00 -4.00 -90.19 0.00 -4.00 -91.10 0.00 -4.00 -91.05 1 0200.00 1 0225.00 1 0250.00 1 0275.00 1 0300.00 10325.00 10350.00 10375.00 1 0400.88 56.97 59.02 61.11 63.24 65.40 67.59 69.81 72.04 74.38 198.96 196.58 194.31 192.12 190.02 187.99 186.02 184.11 182.18 8571.58 8584.83 8597.31 8608.97 8619.81 8629.78 8638.86 8647.03 8654.49 -3049.05 -3069.24 -3090.12 -3111.64 -3133.75 -3156.39 -3179.51 -3203.04 -3227.78 -1588.45 -1594.91 -1600.68 -1605.73 -1610.05 -1613.63 -1616.47 -1618.55 -1619.91 2788.90 2807.95 2827.78 2848.35 2869.61 2891.50 2913.97 2936.96 2961.25 11.50 /'11.50 11.50 11.50 11.50 11.50 11.50 11.50 11.50 8.09 8.20 8.37 8.52 8.65 8.76 8.86 8.94 9.03 -9.76 -9.51 -9.10 -8.74 -8.42 -8.13 -7.87 -7.65 -7.44 -45.39 -45.14 -43.88 -42.74 -41.72 -40.81 -40.00 -39.28 -38.55 Section 7: Start j.\ß) {nel ." Azbn .' .1',VÐ. ~'+N/';~f ' +E/. W' >,'JVs. DtS, Btìild, ,Turn 'TFO, 'ft, '~eg. .',: 'rJ~ ..ft, ::ft:::<',',:~.~:,: .' :ff. -,'.:;~~~::~~1~d~:~',.~ 10405.02 74.38 182.18 8655.60 -3231.76 -1620.06 2965.16 0.00 0.00 0.00 180.00 Section ,,;:'~D-- 10425.00 10450.00 10475.00 10500.00 10525.00 10550.00 10575.00 10600.00 10625.00 10650.00 10675.00 10700.00 10725.00 10750.00 10775.00 10800.00 10825.00 10850.00 10875.00 10900.00 10925.00 10950.00 10975.00 11000.00 11025.00 8 : Start - ''JJìèJ .. ';'"dég 73.96 73.46 73.01 72.61 72.24 71.92 71.65 71.43 71.25 71.13 71.05 71.02 71.04 71.11 71.23 71.40 71.62 71.88 72.20 72.55 72.95 73.40 73.89 74.41 74.98 , .Aûm, .~~89. 179.83 176.88 173.92 170.94 167.95 164.94 161.93 158.91 155.88 152.84 149.81 146.77 143.73 140.69 137.65 134.62 131.60 128.59 125.58 122.59 119.61 116.64 113.69 110.75 107.83 ,':~~, 8661.05 8668.06 8675.28 8682.67 8690.22 8697.91 8705.72 8713.64 8721.64 8729.70 8737.81 8745.94 8754.07 8762.17 8770.24 8778.25 8786.18 8794.01 8801.73 8809.30 8816.71 8823.95 8830.99 8837.82 8844.42 ., ,'\::.fNi~~: ,:ft';!':~ -3250.98 -3274.96 -3298.82 -3322.49 -3345.92 -3369.04 -3391.80 -3414.14 -3436.00 -3457.33 -3478.08 -3498.19 -3517.61 -3536.30 -3554.20 -3571.27 -3587.47 -3602.76 -3617.10 -3630.45 -3642.78 -3654.06 -3664.25 -3673.35 -3681.31 ,::f~~>~~~ .. -)~!-':: -1620.40 2984.13 -1619.71 3007.96 -1617.79 3031.85 -1614.64 3055.73 -1610.28 3079.54 -1604.70 3103.22 -1597.94 3126.72 -1589.99 3149.97 -1580.89 3172.91 -1570.65 3195.50 -1559.30 3217.66 -1546.88 3239.35 -1533.40 3260.50 -1518.91 3281.08 -1503.44 3301.02 -1487.03 3320.28 -1469.73 3338.80 -1451.57 3356.54 -1432.60 3373.46 -1412.87 3389.50 -1392.42 3404.65 -1371.32 3418.84 -1349.61 3432.06 -1327.35 3444.26 -1304.59 3455.41 :-:~=~;:;:~;;:~1~ ,.'-r;: 11.50 -2.12 -11.75 -100.92 11.50 -1.97 -11.80 -100.28 11.50 -1.80 -11.86 -99.45 11.50 -1.63 -11.92 -98.60 11.50 -1.45 -11.97 -97.72 11.50 -1.27 -12.01 -96.81 11.50 -1.09 -12.05 -95.89 11.50 -0.90 -12.09 -94.95 11.50 -0.70 -12.12 -93.99 11.50 -0.51 -12.14 -93.02 11.50 -0.31 -12.15 -92.04 11.50 -0.11 -12.16 -91.06 11.50 0.09 -12.16 -90.07 11.50 0.28 -12.15 -89.08 11.50 0.48 -12.14 -88.09 11.50 0.68 -12.12 -87.11 11.50 0.87 -12.09 -86.14 11.50 1.06 -12.06 -85.18 11.50 1.25 -12.02 -84.24 11.50 1.43 -11.97 -83.31 11.50 1.61 -11.92 -82.41 11.50 1.78 -11.87 -81.52 11.50 1.95 -11.81 -80.66 11.50 2.11 -11.75 -79.83 11.50 2.26 -11.69 -79.03 ) ) DP Amoco Planning Report - Geographic Section 9: Start 3483.34 3501.04 3513.32 8.00 8.00 7.99 7.99 7.99 7.98 Section 11 : Start -3753.41 -3763.41 -3768.61 Section 14: Start i MD Incl Az~ TVD +N/~ +EI-W VS ÐLS BuDd Turn TFO ft deg deg ft ft It ft degl100ft degl100ft. degl1 00ft deg 12050.00 93.63 98.83 8826.87 -3855.91 -302.56 3772.31 6.00 -5.71 1.85 162.07 12100.00 90.78 99.75 8824.94 -3863.98 -253.25 3787.39 6.00 -5.71 1.84 162.15 12113.64 90.00 100.00 8824.85 -3866.32 -239.81 3791.63 5.98 -5.70 1.83 162.23 Section 15: Start MD lncl ADm TVD +NJ-S +EI-W. VS DLS BuDd Tom TFO ft -deg deQ ft ft .ft ft degl100ft deg/100ft degl100ft deg 12150.00 87.82 99.93 8825.54 -3872.61 -204.01 3803.01 6.00 -6.00 -0.18 -178.28 12172.88 86.45 99.89 8826.69 -3876.54 -181.50 3810.13 5.99 -5.99 -0.19 -178.14 . - ) ) BP Amoco Planning Report - Geographic Section 16: Start Mn Joel Azbn TVJ) . +N/-S . +FJ-W VS DI,.$ - BuDd Turn TFO ft deg deg, ft ft It ,ft ØØgl100ft degl100ft<deg/100ft deg 12200.00 86.45 99.89 8828.37 -3881.19 -154.83 3818.57 0.00 0.00 0.00 0.00 12300.00 86.45 99.89 8834.56 -3898.33 -56.51 3849.68 0.00 0.00 0.00 0.00 12400.00 86.45 99.89 8840.75 -3915.47 41.82 3880.78 0.00 0.00 0.00 0.00 12500.00 86.45 99.89 8846.95 -3932.62 140.14 3911.89 0.00 0.00 0.00 0.00 12600.00 86.45 99.89 8853.14 -3949.76 238.47 3942.99 0.00 0.00 0.00 0.00 12700.00 86.45 99.89 8859.33 -3966.90 336.79 3974.10 0.00 0.00 0.00 0.00 12800.00 86.45 99.89 8865.52 -3984.05 435.12 4005.21 0.00 0.00 0.00 0.00 12900.00 86.45 99.89 8871.71 -4001.19 533.44 4036.31 0.00 0.00 0.00 0.00 12950.11 86.45 99.89 8874.85 -4009.82 582.70 4051.94 0.00 0.00 0.00 0.00 Survey 5530.00 1.42 211.00 5529.07 -56.02 -17.42 5959661.51 643301.71 70 17 50.240 N 148 50 22.240 W 5550.00 2.62 209.55 5549.06 -56.63 -17.77 5959660.89 643301.36 70 17 50.234 N 148 50 22.251 W 5600.00 5.62 208.63 5598.92 -59.77 -19.51 5959657.71 643299.69 70 17 50.203 N 148 50 22.301 W 5650.00 8.62 208.35 5648.53 -65.22 -22.46 5959652.21 643296.84 70 17 50.150 N 148 50 22.387 W 5700.00 11.62 208.21 5697.75 -72.95 -26.62 5959644.40 643292.83 70 17 50.074 N 148 50 22.509 W 5750.00 14.62 208.13 5746.44 -82.96 -31.98 5959634.30 643287.67 70 17 49.975 N 148 50 22.665 W 5800.00 17.62 208.08 5794.47 -95.20 -38.52 5959621.93 643281.36 70 17 49.855 N 148 50 22.855 W 5850.00 20.62 208.04 5841.70 -109.65 -46.22 5959607.34 643273.94 70 17 49.713 N 148 50 23.080 W 5900.00 23.62 208.01 5888.02 -126.27 -55.06 5959590.56 643265.41 70 17 49.549 N 148 50 23.338 W 5950.00 26.62 207.99 5933.29 -145.00 -65.02 5959571.64 643255.81 70 17 49.365 N 148 50 23.628 W 6000.00 29.62 207.97 5977.38 -165.81 -76.08 5959650.62 643245.16 70 17 49.160 N 148 50 23.950 W 6050.00 32.62 207.95 6020.18 -188.63 -88.19 5959527.58 643233.48 70 17 48.936 N 148 50 24.303 W 6100.00 35.62 207.94 6061.57 -213.40 -101.33 5959502.56 643220.82 70 17 48.692 N 148 50 24.686 W 6150.00 38.62 207.93 6101.43 -240.06 -115.47 5959475.64 643207.19 70 17 48.430 N 148 50 25.098 W 6189.70 41.00 207.92 6131.93 -262.51 -127.37 5959452.97 643195.72 70 17 48.209 N 148 50 25.445 W 6200.00 41.00 207.92 6139.70 -268.48 -130.53 5959446.94 643192.67 70 17 48.151 N 148 50 25.538 W 6300.00 41.00 207.92 6215.17 -326.45 -161.25 5959388.40 643163.07 70 17 47.581 N 148 50 26.433 W 6400.00 41.00 207.92 6290.65 -384.42 -191.97 5959329.86 643133.46 70 17 47.010 N 148 50 27.328 W 6500.00 41.00 207.92 6366.12 -442.39 -222.69 5959271.32 643103.85 70 17 46.440 N 148 50 28.224 W 6600.00 41.00 207.92 6441.59 -500.36 -253.41 5959212.78 643074.25 70 17 45.870 N 148 50 29.119 W 6700.00 41.00 207.92 6517.06 -558.33 -284.13 5959154.24 643044.64 70 17 45.300 N 148 50 30.014 W 6800.00 41.00 207.92 6592.53 -616.30 -314.85 5959095.70 643015.04 70 17 44.730 N 148 50 30.910 W 6900.00 41.00 207.92 6668.00 -674.27 -345.57 5959037.16 642985.43 70 17 44.160 N 148 50 31.805 W 7000.00 41.00 207.92 6743.47 -732.24 -376.29 5958978.62 642955.83 70 17 43.590 N 148 50 32.700 W 7100.00 41.00 207.92 6818.94 -790.21 -407.01 5958920.08 642926.22 70 17 43.019 N 148 50 33.595 W 7189.70 41.00 207.92 6886.64 -842.21 -434.56 5958867.56 642899.67 70 17 42.508 N 148 50 34.398 W 7200.00 41.62 207.92 6894.38 -848.22 -437.74 5958861.50 642896.60 70 17 42.449 N 148 50 34.491 W 7250.00 44.62 207.92 6930.87 -878.41 -453.74 5958831.01 642881.18 70 17 42.152 N 148 50 34.957 W 7300.00 47.62 207.92 6965.52 -910.25 -470.62 5958798.85 642864.92 70 17 41.839 N 148 50 35.449 W 7350.00 50.62 207.92 6998.25 -943.65 -488.32 5958765.13 642847.86 70 17 41.510 N 148 50 35.965 W 7400.00 53.62 207.92 7028.94 -978.52 -506.79 5958729.92 642830.05 70 17 41.167 N 148 50 36.503 W 7449.60 56.59 207.92 7057.32 -1014.46 -525.84 5958693.62 642811.69 70 17 40.814 N 148 50 37.058 W 7500.00 56.59 207.92 7085.07 -1051.63 -545.54 5958656.08 642792.71 70 17 40.448 N 148 50 37.633 W 7600.00 56.59 207.92 7140.13 -1125.39 -584.63 5958581.59 642755.04 70 17 39.723 N 148 50 38.772 W 7700.00 56.59 207.92 7195.20 -1199.15 -623.71 5958507.11 642717.37 70 17 38.997 N 148 50 39.911 W 7800.00 56.59 207.92 7250.26 -1272.91 -662.80 5958432.62 642679.70 70 17 38.272 N 148 50 41.050 W 7900.00 56.59 207.92 7305.32 -1346.67 -701.88 5958358.14 642642.03 70 17 37.546 N 148 50 42.188 W 8000.00 56.59 207.92 7360.38 -1420.43 -740.97 5958283.65 642604.36 70 17 36.821 N 148 50 43.327 W 8100.00 56.59 207.92 7415.45 -1494.19 -780.06 5958209.17 642566.69 70 17 36.096 N 148 50 44.466 W 8200.00 56.59 207.92 7470.51 -1567.95 -819.14 5958134.68 642529.02 70 17 35.370 N 148 50 45.605 W 8300.00 56.59 207.92 7525.57 -1641.71 -858.23 5958060.20 642491.35 70 17 34.645 N 148 50 46.744 W " ') BP Amoco Planning Report - Geographic ) Survey ~.Latitude - --> <-- LQogitude ..-.> -. :}~~~~~.~. ~Mm-&~ . -.' -1715.46 -897.32 70 17 33.919 N 148 50 47.883 W 8500.00 56.59 -1789.22 -936.40 70 17 33.194 N 148 50 49.022 W 8600.00 56.59 -1862.98 -975.49 70 17 32.468 N 148 50 50.160 W 8700.00 56.59 -1936.74 -1014.57 70 17 31.743 N 148 50 51.299 W 8800.00 56.59 207.92 7800.89 -2010.50 -1053.66 5957687.77 642303.00 70 17 31.017 N 148 50 52.438 W 8900.00 56.59 207.92 7855.95 -2084.26 -1092.75 5957613.29 642265.33 70 17 30.292 N 148 50 53.577 W 9000.00 56.59 207.92 7911.01 -2158.02 -1131.83 5957538.80 642227.66 70 17 29.566 N 148 50 54.715 W 9100.00 56.59 207.92 7966.07 -2231.78 -1170.92 5957464.32 642189.99 70 17 28.841 N 148 50 55.854 W 9200.00 56.59 207.92 8021.14 -2305.53 -1210.01 5957389.83 642152.32 70 17 28.115 N 148 50 56.993 W 9300.00 56.59 207.92 8076.20 -2379.29 -1249.09 5957315.35 642114.65 70 17 27.390 N 148 50 58.131 W 9400.00 56.59 207.92 8131.26 -2453.05 -1288.18 5957240.86 642076.98 70 17 26.664 N 148 50 59.270 W 9500.00 56.59 207.92 8186.32 -2526.81 -1327.26 5957166.38 642039.31 70 17 25.939 N 148 51 0.409 W 9600.00 56.59 207.92 8241.39 -2600.57 -1366.35 5957091.89 642001.65 70 17 25.213 N 148 51 1.547 W 9700.00 56.59 207.92 8296.45 -2674.33 -1405.44 5957017.41 641963.98 70 17 24.488 N 148 51 2.686 W 9800.00 56.59 207.92 8351.51 -2748.09 -1444.52 5956942.92 641926.31 70 17 23.762 N 148 51 3.824 W 9900.00 56.59 207.92 8406.58 -2821.85 -1483.61 5956868.44 641888.64 70 17 23.037 N 148 51 4.963 W 9982.78 56.59 207.92 8452.00 -2883.00 -1516.00 5956806.68 641857.42 70 17 22.436 N 148 51 5.906 W 10000.00 56.59 207.23 8461.48 -2895.74 -1522.65 5956793.82 641851.01 70 17 22.310 N 148 51 6.100 W 10100.00 56.59 203.23 8516.54 -2971.24 -1558.23 5956717.66 641816.88 70 17 21.568 N 148 51 7.136 W 10195.29 56.59 199.42 8569.00 -3045.33 -1587.15 5956643.04 641789.38 70 17 20.839 N 148 51 7.978 W 10200.00 56.97 198.96 8571.58 -3049.05 -1588.45 5956639.29 641788.16 70 17 20.802 N 148 51 8.016 W 10225.00 59.02 196.58 8584.83 -3069.24 -1594.91 5956618.99 641782.08 70 17 20.604 N 148 51 8.204 W 10250.00 61.11 194.31 8597.31 -3090.12 -1600.68 5956598.00 641776.72 70 17 20.398 N 148 51 8.372 W 10275.00 63.24 192.12 8608.97 -3111.64 -1605.73 5956576.39 641772.08 70 17 20.187 N 148 51 8.519 W 10300.00 65.40 190.02 8619.81 -3133.75 -1610.05 5956554.20 641768.18 70 17 19.969 N 148 51 8.645 W 10325.00 67.59 187.99 8629.78 -3156.39 -1613.63 5956531.50 641765.03 70 17 19.746 N 148 51 8.749 W 10350.00 69.81 186.02 8638.86 -3179.51 -1616.47 5956508.33 641762.63 70 17 19.519 N 148 51 8.832 W 10375.00 72.04 184.11 8647.03 -3203.04 -1618.55 5956484.77 641761.00 70 17 19.288 N 148 51 8.892 W 10400.88 74.38 182.18 8654.49 -3227.78 -1619.91 5956460.01 641760.11 70 17 19.044 N 148 51 8.932 W 10405.02 74.38 182.18 8655.60 -3231.76 -1620.06 5956456.03 641760.04 70 17 19.005 N 148 51 8.936 W 10425.00 73.96 179.83 8661.05 -3250.98 -1620.40 5956436.81 641760.07 70 17 18.816 N 148 51 8.946 W 10450.00 73.46 176.88 8668.06 -3274.96 -1619.71 5956412.84 641761.21 70 17 18.580 N 148 51 8.926 W 10475.00 73.01 173.92 8675.28 -3298.82 -1617.79 5956389.03 641763.58 70 17 18.346 N 148 51 8.869 W 10500.00 72.61 170.94 8682.67 -3322.49 -1614.64 5956365.42 641767.18 70 17 18.113 N 148 51 8.778 W 10525.00 72.24 167.95 8690.22 -3345.92 -1610.28 5956342.09 641771.99 70 17 17.883 N 148 51 8.650 W 10550.00 71.92 164.94 8697.91 -3369.04 -1604.70 5956319.08 641778.01 70 17 17.655 N 148 51 8.488 W 10575.00 71.65 161.93 8705.72 -3391.80 -1597.94 5956296.45 641785.21 70 17 17.431 N 148 51 8.290 W 10600.00 71.43 158.91 8713.64 -3414.14 -1589.99 5956274.27 641793.58 70 17 17.212 N 148 51 8.059 W 10625.00 71.25 155.88 8721.64 -3436.00 -1580.89 5956252.59 641803.10 70 17 16.997 N 148 51 7.793 W 10650.00 71.13 152.84 8729.70 -3457.33 -1570.65 5956231.45 641813.74 70 17 16.787 N 148 51 7.495 W 10675.00 71.05 149.81 8737.81 -3478.08 -1559.30 5956210.93 641825.48 70 17 16.583 N 148 51 7.164 W 10700.00 71.02 146.77 8745.94 -3498.19 -1546.88 5956191.06 641838.28 70 17 16.385 N 148 51 6.802 W 10725.00 71.04 143.73 8754.07 -3517.61 -1533.40 5956171.90 641852.13 70 17 16.194 N 148 51 6.409 W 10750.00 71.11 140.69 8762.17 -3536.30 -1518.91 5956153.50 641866.97 70 17 16.010 N 148 51 5.987 W 10775.00 71.23 137.65 8770.24 -3554.20 -1503.44 5956135.90 641882.78 70 17 15.834 N 148 51 5.536 W 10800.00 71.40 134.62 8778.25 -3571.27 -1487.03 5956119.14 641899.50 70 17 15.666 N 148 51 5.058 W 10825.00 71.62 131.60 8786.18 -3587.47 -1469.73 5956103.27 641917.12 70 17 15.507 N 148 51 4.554 W 10850.00 71.88 128.59 8794.01 -3602.76 -1451.57 5956088.33 641935.56 70 17 15.357 N 148 51 4.025 W 10875.00 72.20 125.58 8801.73 -3617.10 -1432.60 5956074.36 641954.80 70 17 15.216 N 148 51 3.472 W 10900.00 72.55 122.59 8809.30 -3630.45 -1412.87 5956061.39 641974.78 70 17 15.085 N 148 51 2.897 W 10925.00 72.95 119.61 8816.71 -3642.78 -1392.42 5956049.46 641995.45 70 17 14.963 N 148 51 2.301 W 10950.00 73.40 116.64 8823.95 -3654.06 -1371.32 5956038.58 642016.77 70 17 14.852 N 148 51 1.686 W 10975.00 73.89 113.69 8830.99 -3664.25 -1349.61 5956028.80 642038.66 70 17 14.752 N 148 51 1.054 W BP Amoco Planning Report - Geographic ) " '. . ' Survey 11025.00 74.98 107.83 8844.42 .3681.31 -1304.59 5956012.61 642084.00 70 17 14.585 N 148 50 59.742 W 11050.00 75.58 104.92 8850.77 -3688.12 -1281.40 5956006.24 642107.32 70 17 14.518 N 148 50 59.066 W 11066.57 76.00 103.00 8854.85 -3691.98 -1265.80 5956002.68 642122.98 70 17 14.480 N 148 50 58.612 W 11100.00 78.67 102.86 8862.18 -3699.28 -1234.01 5955995.99 642154.90 70 17 14.408 N 148 50 57.686 W 11150.00 82.67 102.66 8870.28 -3710.17 -1185.90 5955986.01 642203.21 70 17 14.301 N 148 50 56.284 W 11184.64 85.43 102.52 8873.88 -3717.69 -1152.27 5955979.14 642236.97 70 17 14.227 N 148 50 55.304 W 11200.00 85.43 102.52 8875.10 -3721.01 .1137.32 5955976,11 642251.98 70 17 14.194 N 148 50 54.868 W 11300.00 85.43 102.52 8883.07 -3742.62 -1040.01 5955956.36 642349.68 70 17 13.982 N 148 50 52.033 W 11341.85 85.43 102.52 8886.39 -3751.66 -999.29 5955948.10 642390.56 70 17 13.893 N 148 50 50.847 W 11350.00 85.86 102.28 8887.01 .3753.41 -991.35 5955946.50 642398.53 70 17 13.876 N 148 50 50.615 W 11400.00 88.48 100.83 8889.48 -3763.41 -942.43 5955937.44 642447.63 70 17 13.778 N 148 50 49.190 W 11428.76 90.00 100.00 8889.85 -3768.61 -914.15 5955932.78 642476.00 70 17 13.727 N 148 50 48.366 W 11450.00 91.21 99.61 8889.63 -3772.23 -893.22 5955929.56 642496.99 70 17 13.691 N 148 50 47.756 W 11500.00 94.07 98.69 8887.32 .3780.17 -843.92 5955922.56 642546.44 70 17 13.613 N 148 50 46.320 W 11543.32 96.54 97.89 8883.32 .3786.39 -801.24 5955917.15 642589.22 70 17 13.552 N 148 50 45.076 W 11600.00 96.54 97.89 8876.86 .3794.12 -745.46 5955910.49 642645.13 70 17 13.476 N 148 50 43.451 W 11700.00 96.54 97.89 8865.47 -3807.76 -647.05 5955898.73 642743.78 70 17 13.342 N 148 50 40.584 W 11800.00 96.54 97.89 8854.08 -3821.40 -548.64 5955886.97 642842.42 70 17 13.208 N 148 50 37.717 W 11900.00 96.54 97.89 8842.70 -3835.03 -450.24 5955875.22 642941.06 70 17 13.074 N 148 50 34.850 W 11999.09 96.54 97.89 8831.38 -3848.54 -352.72 5955863.57 643038.81 70 17 12.941 N 148 50 32.009 W 12050.00 93.63 98.83 8826.87 -3855.91 -302.56 5955857.16 643089.10 70 17 12.868 N 148 50 30.547 W 12100.00 90.78 99.75 8824.94 -3863.98 -253.25 5955850.03 643138.55 70 17 12.789 N 148 50 29.111 W 12113.64 90.00 100.00 8824.85 -3866.32 -239.81 5955847.95 643152.03 70 17 12.766 N 148 50 28.719 W 12150.00 87.82 99.93 8825.54 -3872.61 -204.01 5955842.34 643187.94 70 17 12.704 N 148 50 27.676 W 12172.88 86.45 99.89 8826.69 -3876.54 -181.50 5955838.84 643210.52 70 17 12.666 N 148 50 27.020 W 12200.00 86.45 99.89 8828.37 -3881.19 -154.83 5955834.71 643237.27 70 17 12.620 N 148 50 26.244 W 12300.00 86.45 99.89 8834.56 -3898.33 -56.51 5955819.44 643335.90 70 17 12.451 N 148 50 23.379 W 12400.00 86.45 99.89 8840.75 -3915.47 41.82 5955804.18 643434.52 70 17 12.283 N 148 50 20.514 W 12500.00 86.45 99.89 8846.95 .3932.62 140.14 5955788.91 643533.15 70 17 12.114 N 148 50 17.650 W 12600.00 86.45 99.89 8853.14 .3949.76 238.47 5955773.65 643631.77 70 17 11.945 N 148 50 14.785 W 12700.00 86.45 99.89 8859.33 .3966.90 336.79 5955758.39 643730.40 70 17 11.777 N 148 50 11.921 W 12800.00 86.45 99.89 8865.52 -3984.05 435.12 5955743.12 643829.03 70 17 11.608 N 148 50 9.056 W 12900.00 86.45 99.89 8871.71 -4001.19 533.44 5955727.86 643927.65 70 17 11.440 N 148 50 6.191 W 12950.11 86.45 99.89 8874.85 -4009.82 582.70 5955720.17 643977.07 70 17 11.355 N 148 50 4.756 W H DATE 7/12/02 CHECK NO. H207006 207006 DATE DESCRIPTION VENDOR DISCOUNT NET GROSS INVOICE I CREDIT MEMO 7/12/02 INV# CK071002G PERMIT TO DRILL FEE íC lJ ~L~ F' ,JUL 31 2002 Afaslm DB & t~as AnchoratJI:1 \-\-OÀft THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ PAY TO THE ORDER OF ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVE STE 100 ANCHORAGE, AK. 99501 r:.: ~rY!;He.~fJ:~. ).?g.~~i...: \~:.} :..... ~:....,:... ..~ i ~ ',',:-.:. '. :-':'::"'. ":":' :'.\:'j'/:.:. '.:...... . ;':'. '.~.:.: ':';'. ":-" :""':'':('A~~ ::'~""I"".~~""': :,....::.....1 ~\\f+0 &0~Pi.~;;;~~~;¡~~~~(1i:~A:~:l II' 2 0 ? 0 0 b /I' I: 0... . 2 0 3 a q 5 I: 0 0 8 ...... . ~ JI' of H .~ .~' TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME IlirA ;1-02-// PTD# 2D2--/h/? CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/1 0/02 C\j ody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 'WELL PERMIT CHECKLIST COMPANY ßI."x WELLNAME{ðú d-ð24 PROGRAM: Exp- DevL Redrll~ Re-Enter - Serv- Wellboreseg- .FIELD & POOL ~7"o/5~ INITCLASS IJP~ /-o/¡ GEOLAREA <¡7cJ UNIT# I/h_~~ ON/OFFSHORE 01{) ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . R N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . (Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, iswellbore plat included.. . . . . . . . . . . . . . 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 12. Permit can be issued without administrative approval.. . . . . :¡j N , (Service Well Only) 13. Wetllocated wlin ar.ea & strata authorized by injection order#- ~.Y ýt/,IJ, (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. h ~ ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . (!¡) N 16. Surface casing protects all known USDWs. . . . . . . . . . . ø N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . -¥--N- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ¥--N- 19. CMT will cover all known productive horizons. . . . . . . . . . ,. N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . .. N I 21. Adequate tankage or reserve pit.. . . . ; . . . . . . . . . . . . N tJa. bo rt; Zr= S 22. If a re-drill, has a 10-403 for abandonment been approved. . . .. N 7/ t~/p Ì- . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . . . . i' Y N N/A-- 25. Drilling fluid program schematic & equip list adequate. . . . . " N 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . .. N ,. 27. BOPE press rating appropriate; test to 3500 psig. N MS I~ 'l1)&0 pS t 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N ;-80 ppÞ^- m~,¡(: . 31. Mechanical condition of wells within AOR verified. . . . . . . . '¥-N'"" f'-J / Ai- ~~.4. Á~r~ "APPR DATE ,~ :6d2- APPR DATE '1,",4A- .8/1 (01- " (Service Well Only) GEOLOGY .APPR DATE //L ~b2 (Exploratory Only) Rev: 07/12/02 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. . . . . . . . GEOLOGY: R~ UIC ENGINEER JBR PETROLEUM ENGINEERING: TEM JDH SFD- WGA ~G,A- MJW G:\geology\permits\checklist.doc COMMISSIONER: COT DTS 0 ~/O 1 J c... /1 Commentsllnstructions: ) 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. infonnation of this nature is accumulated at the end of the file under APPENDIX. No special. effort has been made to chronologically" . organize this category of infonnation. ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Mar 25 10:12:19 2003 Reel Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/03/25 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.....................03/03/25 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comm.ents. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MV'JD/MAD LOGS # WELL NAME: .iè'.PI NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-22140 J. SACK R. BORDES 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-22140 J. SACK R. BORDES 1 # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD H-02A 500292010001 BP Exploration Sperry Sun 25-MAR-03 MWD RUN 2 AK-MW-22140 R. MCNEILL D. LOWE / B. MWD RUN 5 AK-MW-22140 J. SACK R. BORDES / 21 11N 13E 1073 1266 .00 73.27 46.50 (Alaska), Inc. MWD RUN 3 AK-MW-22140 R. MCNEILL D. LOWE / B. MWD RUN 7 AK-MW-22140 J. SACK R. BORDES 1 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 3980.0 6.000 7.000 10859.0 # REMARKS: aDd - 11o~ fiG 1fQ ) ') 1. ALL DEP'l'HS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD) UNLESS OTHERWISE NOTED. 3. MWD RUN 1 WAS DIRECTIONAL WITH DUAL GAHHA RAY (DGR) UTILIZING GEIGER-HUELLOR TUBE DETECTORS AND PRESSURE WHILE DRILLING (PWD). 4. THE 7" CASING COULD NOT BE RUN TO BOTTOM. THE TOP 500' OF CASING WAS CUT OFF AND REMOVED. A CEMENT PLUG WAS SET IN THE OPEN HOLE AT 5630' MD, 5629' TVD. H-02A PB1 DATA IS PRESENTED ELSEWHERE. 5. Mí1ÏJD RUNS 2-3 WERE DIRECTIONAL WITH DUAL GAJV!MARAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND PRESSURE WHILE DRILLING (PWD). 6. MWD RUNS 4-5 WERE DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), STABILIZED LITHO-DENSITY (SLD), AND COMPENSATED THERMAL NEUTRON (CTN). 7. MWD RUN 6 DID NOT MAKE ANY FOOTAGE. NO DATA IS PRESENTED. 8. MWD RUN 7 WAS DIRECTIONAL WITH DGR AND EWR. 9. DEPTH SHIFTING AND CORRECTION WAIVED PER THE E-MAIL OF 1/8/2003 FROM D. SCHNORR OF BP EXPLORATION (ALASKA) INC. 10. MWD RUNS 1-5 AND 7 REPRESENT WELL H-02A WITH API # 50-029-20100-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12395' HD, 8863' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED - GEIGER-MULLER TUBE DETECTORS SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (HEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE) SBD2 = SMOOTHED BULK DENSITY COMPENSATED (LOW-COUNT BIN) SC02 = SHOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SHOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.5-8.6 PPG MUD FILTRATE SALINITY: 11,000 PPM FORMATION WATER SALINITY: 11,000 FLIUD DENSITY: 1.00 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ CHLORIDES PPM CHLORIDES File Header Service name.............STSL1B.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/25 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name... ....STSL1B.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and 1 clipped curves; all bit runs merged. DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FCNT NCNT NPHI PEF FET RPD RPM RPS RPX DRHO RHOB $ .5000 START DEPTH 5504.5 5561.5 10767.5 10768.5 10768.5 10782.5 10810.5 10810.5 10810.5 10810.5 10810.5 10861. 0 10861.0 ') STOP DEPTH 12900.0 12949.0 12301.5 12301.5 12301.5 12316.0 12907.0 12907.0 12907.0 12907.0 12907.0 12316.0 12316.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 1 2 3 4 5 7 MERGED MAIN PASS. $ MERGE TOP 5504.5 5543.0 6150.0 10767.5 11875.5 12338.0 MERGE BASE 10505.0 6208.0 10861.0 11969.0 12395.0 12949.0 # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth uni.ts........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units.... ... . . . .. . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FTIH 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 RPH MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD GICM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Hin Hax Hean Nsam Reading Reading DEPT FT 5504.5 12949 9226.75 14 8 90 5504.5 12949 ROP MWD FTIH 0.48 1356.63 112.476 14776 5561.5 12949 GR MWD API 6.51 524.82 108.32 14792 5504.5 12900 RPX MWD OHMM 0.36 2000 17.4076 4194 10810.5 12907 RPS MWD OHMM 0.44 1950.24 16.0766 4194 10810.5 12907 ) ) RPM MWD Om-1M 0.24 1901.45 18.7963 4194 10810.5 12907 RPD MWD OHMM 0.57 2000 54.3389 4194 10810.5 12907 FET MWD HOUR 0.24 2536.87 66.8987 4194 10810.5 12907 NPHI MWD PU-S 4.81 58..95 23.8702 3067 10768.5 12301.5 FCNT MWD CNTS 120 3703 677.523 3069 10767.5 12301. 5 NCNT MWD CNTS 14 712 53284 28422.6 3067 10768.5 12301. 5 RHOB MWD G/CM 2.038 3.341 2.42391 2911 10861 12316 DRHO MWD G/CM -0.437 0.94 0.0532978 2911 10861 12316 PEF MWD BARN 1.12 19.85 3.73892 3068 10782.5 12316 First Reading For Entire File..........5504.5 Last Reading For Entire File...........12949 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/25 Maximum Physical Record..65535 F i Ie 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.......03/03/25 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 5504.5 5561.5 STOP DEPTH 10448.5 10505.0 # 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: 27-AUG-02 Insite 0.43 Hemory 5630.0 5504.0 5630.0 1.4 61. 3 # TOOL STRING (TOP TO BOTTOH) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUHBER 164580 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 3980.0 # BOREHOLE CONDITIONS ') ) HUD TYPE: HUD 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: LSND 10.80 44.0 9.6 300 3.1 .000 .000 .000 .000 .0 187.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames pèr record.............Undefined Absent value. ... . . " . . .. .. .. . . . . . . -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Hean Nsam Reading Reading DEPT FT 5504.5 10505 8004.75 10002 5504.5 10505 ROP MWD010 FT/H 0.59 2391. 59 143.525 9888 5561.5 10505 GR MWD010 API 36.16 378.23 130.413 9889 5504.5 10448.5 First Reading For Entire File..........5504.5 Last Reading For Entire File...........l0505 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/25 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.003 Physical EOF File Header Service name......... ....STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/25 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OO2 ) Comment Record FILE HEADER FILE NUMBER: RAli'J MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 5543.0 5600.5 STOP DEPTH 6149.5 6208.0 # 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 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O 01-SEP-02 Insite 0.43 Memory 6208.0 5630.0 6208.0 9.3 27.7 TOOL NUMBER 164580 8.500 3980.0 LSND 10.40 45.0 11. 5 600 6.8 .000 .000 .000 .000 .0 138.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ) ) ROP MWD020 GR MWD020 FT/H API 4 4 1 68 1 68 4 8 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5543 6208 5875.5 1331 5543 6208 ROP MWD020 FT/H 0.48 591.76 88.6639 1216 5600.5 6208 GR MWD020 API 34.77 138.99 88.5973 1214 5543 6149.5 First Reading For Entire File..........5543 Last Reading For Entire File...........6208 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1. O. 0 Date of Generation.......03/03/25 Maximum Physical Record..65535 File T:ype................ 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.......03/03/25 Maximum Physical Record..65535 File T:ype................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUHBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 6150.0 6208.5 STOP DEPTH 10802.5 10861.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (HEHORY OR REAL-TIHE): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOH LOG INTERVAL (FT): BIT ROTATING SPEED (RPH): HOLE INCLINATION (DEG HINIHUM ANGLE: MAXIMUM ANGLE: 04-SEP-02 Insite 0.43 Hemory 10861. 0 6208.0 10861.0 33.5 60.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUHBER 164580 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 3980.0 # ) ) 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: LSND 11. 05 43.0 9.4 600 2.8 .000 .000 .000 .000 .0 198.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction................. Down Optical log depth units............ Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined ,z\bsent value..................... .-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6150 10861 8505.5 9423 6150 10861 ROP MWD030 FT/H 4.06 413.68 128.142 9306 6208.5 10861 GR MWD030 API 49.92 400.25 138.009 9306 6150 10802.5 First Reading For Entire File..........6150 Last Reading For Entire File...........l0861 File Trailer Service name.............STSLIB.OO4 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/25 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...........l.0.0 Date of Generation.......03/03/25 Maximum Physical Record..65535 Fi 1 e Tjrpe................ LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FI LE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF GR RPD RPM RPS RPX FET DRHO RHOB ROP $ 5 ) header data for each bit run in separate files. 4 .5000 START DEPTH 10767.5 10768.5 10768.5 10782.5 10803.0 10810.5 10810.5 10810.5 10810.5 10810.5 10861.0 10861. 0 10861. 5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME); TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ STOP DEPTH 11875.0 11875.0 11875.0 11890.0 11911. 5 11918.5 11918.5 11918.5 11918.5 11918.5 11890.0 11890.0 11969.0 BOTTOM) TOOL TYPE DUAL GAMJv1A RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON E1ectromag 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: $ 20-DEC-02 Insite 0.43 Memory 11969.0 10861.0 11969.0 58.5 99.3 TOOL NUMBER 62456 112439 100983 73634 6.000 10859.0 FIo-Pro 8.60 46.0 9.1 12000 5.8 .360 .180 .340 .460 72.0 212.0 72.0 72.0 ) # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point... ...........Undefined Frame Spacing.... .................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT M\;'-WO 40 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10767.5 11969 11368.3 2404 10767.5 11969 ROP MWD040 FT/H 0.8 1183.28 77.0026 2216 10861.5 11969 GR MWD040 API 18.71' 524.82 65.9702 2218 10803 11911 . 5 RPX MWD040 OHMM 0.36 2000 22.899 2217 10810.5 11918.5 RPS MWD040 OHMM 0.44 1950.24 18.8567 2217 10810.5 11918.5 RPM MWDO 40 OHMM 0.24 1901.45 22.2899 2217 10810.5 11918.5 RPD MWDO 40 OHMM 0.57 2000 87.5972 2217 10810.5 11918.5 FET MWD040 HOUR 0.44 2536.87 121.962 2217 10810.5 11918.5 NPHI MWD040 PU-S 4.81 58.95 24.0259 2214 10768.5 11875 FCNT MWD040 CNTS 120 3703 706.911 2216 10767.5 11875 NCNT MWD040 CNTS 14712 53284 28723.6 2214 10768.5 11875 RHOB MWD040 G/CM 2.089 3.079 2.43409 2059 10861 11890 DRHO MWD040 G/CM -0.172 0.94 0.048389 2059 10861 11890 PEF MWD040 BARN 1.36 19.85 4.08758 2216 10782.5 11890 First Reading For Entire File..........10767.5 Last Reading For Entire File...........11969 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......03/03/25 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 Nurober...........l.0.0 Date of Generation.......03/03/25 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.005 ') Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NPHI NCNT RHOB DRHO PEF GR RPX RPS RPM RPD FET ROP $ 6 ') header data for each bit run in separate files. 5 .5000 START DEPTH 11875.5 11875.5 11875.5 11890.5 11890.5 11890.5 11912.0 11919.0 11919.0 11919.0 11919.0 11919.0 11969.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ STOP DEPTH 12301.5 12301. 5 12301. 5 12316.0 12316.0 12316.0 12337.5 12344.5 12344.5 12344.5 12344.5 12344.5 12395.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND C.A.SING 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: $ # 22-DEC-02 Insite 0.43 Memory 12395.0 11969.0 12395.0 96.0 97.7 TOOL NUMBER 62456 112439 100983 73634 6.000 10859.0 FIo-Pro 8.50 49.0 8.9 11000 6.4 .360 .200 .340 .460 72.0 135.1 72.0 72.0 ) Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts. .. . . . . . . . .... . . . . '.. . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 RHOB MWD050 G/CM 4 1 68 44 12 DRHO MWD050 G/CM 4 1 68 48 13 PEF MWD050 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11875.5 12395 12135.3 1040 11875.5 12395 ROP MWD050 FT/H 8.38 1356.63 130.769 852 11969.5 12395 GR MWD050 API 6.51 82.3 27.0039 852 11912 12337.5 RPX MWD050 OHMM 0.51 22.78 9.31851 852 11919 12344.5 RPS MWD050 OHMM 0.56 27.74 11. 2773 852 11919 12344.5 RPM MWD050 OHMM 0.8 32.6 13.374 852 11919 12344.5 RPD MWD050 OHMM 0.95 35.61 15.1765 852 11919 12344.5 FET MWD050 HOUR 0.35 32.16 4.40795 852 11919 12344.5 NPHI MWD050 PU-S 17.05 34.01 23.4663 853 11875.5 12301. 5 FCNT MWD050 CNTS 275 989 601.176 853 11875.5 12301.5 NCNT MWD050 CNTS 18521 34140 27641.2 853 11875.5 12301. 5 RHOB MWD050 G/CM 2.038 3.341 2.3993 852 11890.5 12316 DRHO MWD050 G/CM -0.437 0.409 0.0651608 852 11890.5 12316 PEF MWD050 BARN 1.12 12.85 2.83209 852 11890.5 12316 First Reading For Entire File..........11875.5 Last Reading For Entire File...........12395 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/25 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/25 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.006 Cormnent Record "". ) FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 7 ') header data for each bit run in separate files. 7 .5000 START DEPTH 12338.0 12345.0 12345.0 12345.0 12345.0 12345.0 12395.5 STOP DEPTH 12900.0 12907.0 12907.0 12907.0 12907.0 12907.0 12949.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 25-DEC-02 Insite 0.43 Memory 12950.0 12395.0 12950.0 80.5 97.8 TOOL NUMBER 62456 73634 6.000 10859.0 Water 8.60 54.0 10.1 13000 6.6 .600 .270 .000 .000 67.0 156.0 .0 .0 , ) ) Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 Om-1M 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12338 12949 12643.5 1223 12338 12949 ROP MWD070 FT/H 0.86 305.86 94.5686 1108 12395.5 12949 GR MWD070 API 18.35 72.4 32.3814 1125 12338 12900 RPX MWD070 OHMM 1. 97 24.46 12.7118 1125 12345 12907 RPS MWD070 OHMM 2.26 24.38 14.2326 1125 12345 12907 RPM MWD070 OHMM 2.52 29.27 16.0182 1125 12345 12907 RPD MWD070 OHMM 3.33 34.5 18.457 1125 12345 12907 FET MWD070 HOUR 0.24 55.76 5.7134 1125 12345 12907 First Reading For Entire File..........12338 Last Reading For Entire Fi1e...........12949 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/03/25 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name... ........ ..LISTPE Date.....................03/03/25 Origin...................STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments.. ...............STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................03/03/25 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............ ....UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Mar 21 11:19:28 2003 Reel Header Service name.............LISTPE Date. . .. . . . . . . . . . . . . . . . . .03/03/21 Origin...................STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Tape Header Service name.............LISTPE Date.....................03/03/21 Origin...................STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name....... .UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay 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-MW-22140 J. SACK R. BORDES / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services H-02A PB1 500292010070 BP Exploration Sperry Sun 21-MAR-03 (Alaska), Inc. 21 11N 13E 1073 1266 .00 73.27 46.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 13.625 2308.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD) UNLESS OTHERWISE NOTED. c5? [B- / toe) 111011 ) 3. };1WD RUN 1 WAS DIRECTIONAL WITH DUAL GAHMA RAY (DGR) UTILIZING GEIGER-HUELLOR TUBE DETECTORS AND PRESSURE WHILE DRILLING (PWD). 4. THE 7" CASING COULD NOT BE RUN TO BOTTOM. THE TOP 500' OF CASING WAS CUT OFF AND REMOVED. A CEHENT PLUG WAS SET IN THE OPEN HOLE AT 5630' MD, 5629' TVD. H-02A WAS DRILLED WITH MWD RUNS 2-7 AND ITS DATA IS PRESENTED ELSEWHERE. 5. DEPTH SHIFTING AND CORRECTION WAIVED PER THE E-MAIL OF 1/8/2003 FROM D. SCHNORR OF BP EXPLORATION (ALASKA) INC. 6. MWD RUN 1 REPRESEN'fS WELL H-02A PB1 WITH API # 50-029-20100-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10505' MD, 8728' TVD. SROP = SHOO'rHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/03/21 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 5504.5 5561.5 STOP DEPTH 10448.5 10505.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BliSELINE DEPTH $ # MERGED PBU MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 5504.5 MERGE BASE 10505.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999.25 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5504.5 10505 8004.75 10002 5504.5 10505 ROP MWD FT/H 0.59 2391. 59 143.525 9888 5561.5 10505 GR MWD API 36.16 378.23 130.413 9889 5504.5 10448.5 First Reading For Entire File..........5504.5 Last Reading For Entire File...........10505 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... ..03/03/21 Maximum Physical Record..65535 Fi 1 e 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.......03/03/21 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OO1 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 5504.5 5561.5 STOP DEPTH 10448.5 10505.0 # 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: 27-AUG-02 Insite 6.02 Memory 10505.0 5504.0 10505.0 1.4 61.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G~ RAY $ TOOL NUMBER 164580 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 2308.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): LSND 10.80 44.0 ). ) MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 9.6 300 3.1 .000 187.000 .000 .000 .0 186.8 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999.25 Depth Units..... . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 F1'/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5504.5 10505 8004.75 10002 5504.5 10505 ROP MWD010 FT/H 0.59 2391.59 143..525 9888 5561.5 10505 GR MWD010 API 36.16 378.23 130.413 9889 5504.5 10448.5 First Reading For Entire File..........5504.5 Last Reading For Entire File...........10505 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/21 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name.... .......STSLIB.003 Physical EOF Tape Trailer Service name.............LISTPE Date.....................03/03/21 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 031 03/21 '>11 ) Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. ) Scientific Technical Services