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202-016
Im~e Project Well History File Cov~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. 2- C2~ - 0 ~ 0 Well History File Identifier o Two-Sided Organizing {done} RESCAN ./ Color items: 11111111111111 II III ~escan Needed 1111111111111111111 DI<yA AL DATA trz{ Diskettes, No. ;}- o Maps: OVERSIZED (Scannable) o Grayscale items: o Other, Noffype o o Poor Quality Originals: Other items scannable by large scanner NOTES: o OVERSIZED (Non-Scannable) Logs of various kinds rnp 1111111111111111111 V'4P = TOTAL PAGES (p() o Other: BY: --------- ~ARly o Other DA"LJ/4Lf Project Proofing BY: ~B- -' DA" Wo/o <f" Scanning Preparation 4X30= bO + BY: ~ 74'{p./í tv - DA"tJdOc.¡- /sI Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: /;;0 /,/' PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: lr YES 'v: Dm, l~t/o(ISI Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BY: DATE: 151 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECiAl ATTENTION IS REaUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY . GRAYSCALE OR COLOR IMAGES) Mf NO NO 11/1/11111111111111 ReScanned (inlii\¡idual p·J(P [special MlûiHírJllj &c,¡¡¡ning ¡;pmplnlûd) 1111111111111111111 RESCANNED B"': BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked (done I II 11111111111/111/1 1211 OI02Rev3NOTScanned. wpd - - _ - • ~. ~, ~ ~a • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION MAY ~ ~ 2Q~19 WELL COMPLETION OR RECOMPLETION REPORT AND LOG .°;a Oil $~ Gas Cale, ~~.~mmissi©n 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended 1b. Well Class. ~ '' ` •'>~~ 20AAC 25.105 2oAAC zs.,,o ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero ^ Service ^ Strati raphic 2. Operator Name: 5. Date Comp., Susp., or Aband 12. Permit to Drill Number BP Exploration (Alaska) Inc. 05/04/2009 202-016 ~3©9-- ' ~/~ 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 02/19/2002 50-029-22259-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 02/22/2002 PBU 15-29A 148 FNL, 22 FWL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 8. KB (ft above MSL): 66.2' - 15. Field /Pool(s): 1785' FSL, 461' FEL, SEC. 09, T11 N, R14E, UM F " Ground (ft MSL): 32.4' Prudhoe Bay Field / Prudhoe Bay ,~~ ' ~=~ ~ r t Total Depth '~' ~ ~~ /~i/~ / 9. Plug Back Depth (MD+TVD) Oil Pool . 17851<SL,,¢6~1' FWL, SEC. 10, T11 N, R14E, UM 12833' ' 8739' - 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designati9n: , Surface: x- 675926 y- 5961332 Zone- ASP4 12900'' 8737' - ADL 028306 & 028303 TPI: x- 675260 y- 5968532 Zone- ASP4 (MD+TVD) 11. SSSV DeN h 17. Land Use Permit: Total Depth: x- 676264 y- 5968820 Zone- ASP4 A 18. Directional Survey ^ Yes ®No 19. Water depth, if offshore 20. Thickness of Permafrost {TVD): ' Submi electr ni n rin d inf rmation er 20 AA 25. N/A ft MSL 1900 (Approx.) 21. Logs Obtained (list all logs here and submit electronic and printed information per 20 AAC 25.071): MWD, GR, ROP, CCL, CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FT. .GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94.5# H-40 urf 110' Surface 11 30" 2000# C Idset II - / " 6 L- 41 rf I ' 9-5/8" 47# L- Surface 1076 ' S rf 833 ' 12-1/4" 2 2 cu ft Cla 'G' 7" 2 L-8 105 0' 11 0 ' 10' 8571' 8-1/2" 472 cu ft Clas ' 1/2" x 3-3/1 / # L- 1 7' - / " 112 I x 2-7/8" / 6.16# 23. Open to production or inject ion? ^ Yes ®No 24. TuIaING RI=_coRD If Yes, IISt each i (MD+ND of Top & Bottom; Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD None 4-1/2", 12.6#, L-80 6487' MD ND MD TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED ~ ~ 14 F ~ ~ ~~ ~~~~~~'~~,~„ ~~ ~- ~ ~. ~~ `~ ~~G? 10606' Set Cement Retainer w/ 26 Bbls'G'; placed 14 Bbls 9808' (TOC) below and 12 bbls on top 5791' Set EZSV 5786' Set Whipstock 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing Casing Press: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): PreSS. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Cores Ac wired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, 'rf needed). Submit detailed descriptions, core chips, photographs and laboratory analytical resufts:per 20 AAC 250.071. None ~ .~' -Q~ ~ '_ _ : _. Ali. ~tJN ~ ~. 209 Is 9 Form 10-407 ReVISed 02/2UU7 CONTINUED ON REVERSE .SIDE !`,~'' ~~~ ~`d .__ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. 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. Zone 1 B 11832' 8755' None Formation at Total Depth (Name): 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. (~ Signed Sondra wman Title Drilling Technologist Date~S -'~~ "~ I PBU 15-29A 202-016 Prepared ey Namenvumber. Sondra Stewman, 564-4750 Well Number Permit No. / A rOVal NO. Drilling Engineer: Garret Staudinger, 564-4242 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 1007 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: 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 ZZ: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: 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 29: 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 02/2007 Submit Original Only TREE= 4-1/16" CNV WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 66.2' BF. ELEV = NA KOP - 725' Max Angle = 98 @ 12425' Datum MD _ ~ Datum TV D = 8800' SS • 20' CONDUCTOR I-~ 94.5#, H-40, ID = ? 13-3/8" CSG, 68#, K-55 BTC XO TO L-80 BTC ~-1 112' 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" 4160' Minimum ID = 2.377" @ 11354' 3-3/16" X 2-7/8" LNR X-OVER 3.65" JET CUT (04/23/09) 6495' TOP OF CEMENT(TAGGED 04/21/09) 9808' BKR TIEBACK SLEEVE, ID = ? 10508` 9-5/8" X 7" BKR "H" LTP, ID = 6.29"? 10515' 9-5/8" X 7" BKR LNR HGR, ID =6.30;? 10520' 4-1/2" HES EZ DRILL CMT RETAINER (04/19/09) 10606 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-~ 10643, 9-5/8" CSG, 47#, L-80, ID = 8.681" 10760` 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.992" 10782` 7' WHIPSTOCK 11305' RA PIP TAG --11315' 15-29 11353' 3-3/16" X 2-7/8" LNR XO, ID = 2.377" 7" LNR, 26#, L-80 U4S, .0383 bfp, ID = 6.276" ~~ 1 PERFORATION SUMMARY REF LOG: SWS MEMORY GR/CNL ON 02/25/02 ANGLE AT TOP PERF: 83 @ 11882' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 2" 6 11882 - 11907 S 04/19/09 2" 4 11960 - 12120 S 04/19/09 2" 4 12390 - 12430 S 04/19/09 2" 4 12480 - 12790 S 04/19/09 J L 3-3/16" LNR, 6.2#, L-80 TC11, .0076 bof. ID = 2.786" 4-1/2" CAMCO BAL-O SSSVN, ID = 3.812" EST TOP OF CEMENT (08/23/03) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3704 3178 45 HES-TB DMY T-2 0 01/15/02 2 6042 4918 42 HES-TB DMY T-2 0 01/15/02 3 8163 6480 43 HES-TB DMY T-2 0 01/15/02 4 9998 7864 41 HES-TB `DMY T-2 0 01/15/02 5 10152 7976 42 HES-TB *DMY T-2 0 01/15/02 S TA # 4 Fk #.i = UMY CiLV'S FStIiINU C:tMtN I 10589' - j 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 10622' 4-1/2" HES X NIP, ID = 3.813" 10623` 3.70" BKR DEPLOY SLV, ID = 3.00" 10629' 3-1/2" BKR PUP PIX, ID = 2.990" 10633' 3-1/2" XN NIP, ID = 2.750" 1~ Os~a.' I--~4-172" WLEG, ID = 3.958" 10643' ELMD TT LOGGED 04/28/01 10782' 3-1/2" X 3-3/16" LNR XO, ID = 2.80" I 7" LNR MILLOUT WINDOW (15-29A) 11309' - 11316' ~ I 11353' PBTD 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" I-( 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 06/04/92 D-9 ORIGINAL COMPLETION 04/27/09 MV/PJC JET CUT (04/23/09) 07/16/96 D-14 RWO 02/26/02 NORDIC 1 CTD SIDETRACK (15-29A) 08/21/07 PJC WBS CORRECTIONS 09/22/07 DTR/SV XN PLUG SET (09/19/07) 04/27/09 DWWlPJC PULL XN / P&A (04119/09) PRUDHOE BAY UNff WELL: 15-29A PERMIT No: ~Z020160 APo No: 50-029-22259-01 SEC 22, T11 N, R14E, 148' SNL & 22' EWL BP Exploration (Alaska) • • 15-29A, Well History (Pre Rig Sidetrack) Date Summary 04/05/09 WELL S/I ON ARRIVAL. RAN 3 1/2" GS CORE, 3 1/2" X EO PRONG, S/D 2364' SLM. DRIFT W/ 2' x 1- 7/8" STEM, 2.30" CENT TO 3000' SLM. EQUALIZE XN PLUG W/ 3 1/2" GS CORE 3 1/2" x EO. DEV C«3 10615' SLM (10633' MD). 04/06/09 RAN 3 1/2" GS CORE, 3 1/2" X-EQ PRONG TO 10615' SLM (10633' MD), (RING ON BTM). ATTEMPT TO PULL 3 1/2" XN PLUG BODY FROM 10615' SLM (10633' MD) W/ 3 1/2" GS. ATTEMPT TO PULL PLUG BODY W/ 3 1/2" GR. PREPARING TO DROP CUTTER BAR. 04/07/09 T/I/O = 500/500/150 Assist Slickline. Pumped 38 bbls. crude down Tbg and 5 bbls. meth and 100 bbls. crude to freeze protect Tubing/flowline. Pressured up flowline to 1500 psi, notified DSO of well status. Wing-closed, swab-closed, master-open, ssv-closed, IA and OA-open to gauges. FWHP's = 500/500/100 04/07/09 LEFT TOOL STRING & CUTTER BAR IN HOLE C«~ 10633' MD. RIG DOWN SLICKLINE. WELL LEFT S/I ON DEPARTURE. 04/07/09 T/IA/OA= SSV/450/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RST) PPPOT-T RU 2 HP BT onto THA test void 50 psi to 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycled and torqued "ET style" all were in good working condition PPPOT-IC RU 2 HP BT onto IC test void 800 psi to 0 psi. flushed void until clean returns achieved. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycle and torqued LDS "ET style" all were in good working condition. 04/13/09 WELL S/I, SSV DUMPED. RECOVERED 5' x 1-7/8" CUTTER BAR FROM 10,566' SLM. RECOVERED TOOLSTRING FROM 10,569' SLM. 3-1/2" KEYLESS XN PLUG BODY REMAINING IN HOLE. WELL S/I, DSO NOTIFIED OF ALL WELL & VLV CONDITIONS. 04/17/09 T/I/O = 490/520/160. Temp = SI. TBG & IA FL's pre P&A (CTD screen). No AL. TBG & IA FL's Q surface. 04/17/09 MIRU CTU. MU and RIH with Baker fishing tools with 3" G spear. Tagged "XN" plug Q 10,599' CTM. Attempted to latch x 3 by setting down 4,000 Ibs, POOH. Did not get plug, paraffin on tools. 04/18/09 MU and RIH with Baker fishing tools with 3" G spear._ Engage XN plug at 10603' ctmd. Overpull 17500 Ib. Plug pulled free, simultaneously saw decrease in WHP. Pull to surface. Recovered XN plug. MU and RIH with Schlumberger memory STP logging tools. Perform PPROF/LDL to evaluate possible dumpflooding of cretaceous water to perforations. Log down pass at 80 fpm from 100' ctmd to 10900' ctmd. Perform repeat passes and stop counts over the interval 6900' - 10900'. Log final up pass from 11450' ctmd to surface to provide GR strip of parent wellbore as per program. 04/19/09 Finished STP logging run. Verified good data; log correction of +49.5' (reference SLB MCNL 25-Feb- 2002). Perform infectivity test prior to running squeeze packer: infectivity 1 bpm at 621 psi, 2 bpm at 924 psi. RIH w/ 4.5" Halliburton EZ Drill squeeze packer. Set squeeze packer with center of element at 10606.4' MD. Pull to surface. Perform infectivity test after running squeeze packer: infectivity 1 bpm at 745 psi, 2 bpm at 1130 psi. MU and RIH with Halliburton stinger assembly. Establish infectivity prior to stinging into retainer: 1 bpm at 913 psi. Sting into retainer and re-establish infectivity: while stung in to retainer, WHP is not responsive to applied circulation pressure. Pumped 5 bbl fresh water pad, 26 bbls 15.8 ppg class G cement, 5 bbls fresh water pad and displaced until squeeze pressure of 3900 psi was ac ieve w s e ow cement retainer, laved 12 bbls cement in 4-1/2" tba. leavina TOC at 9808'. Pooh, freeze protected well w/45 bbls diesel. Blow down coil w/N2. Rig down. Job Complete. 04/21/09 WELL S/I ON ARRIVAL. TAG TOC @ 9785' SLM W/ 3.70" CENT, S. BAILER (HARD BOTTOM, NO SAMPLE) (COIL TARGET DEPTH ~ 9808'). 04/22/09 LRS ATTEMPTED MIT-T TO 3000 PSI. TAG TOC C«~ 9788' SLM W/ 3.0" CENT & 2.5" SAMPLE BAILER (SAMPLE OF CEMENT). LEFT WELL S/I, NOTIFY DSO. Page 1 of 2 • • 15-29A, Well History (Pre Rig Sidetrack) Date Summary 04/22/09 T/I/0=700/600/20 Temp=Sl Assist Slickline, MITT FAILED to 3000 psi (Post Cement P&A for SDTRCK Pumped 85 bbls of 20°F diesel down Tbg and never caught significant pressure on Tbg while IA pressure increased. IA is fluid packed. Final WHP's = 680/640/vac. 04/22/09 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = 700/670/0 PSI. RIG UP-ELINE. 04/23/09 CUT 4.5" TUBING Q 6495' WITH 3.65" POWER CUTTER. WELL LEFT SHUT IN. ALL VALVES LEFT AS FOUND. FINAL T/I/O = 700/700/0 PSI. JOB COMPLETE. 04/25/09 T/I/0=680/680/50 Load Tbg with 9.8# NaCI brine (Pre Sidetrack) Pumped down Tbg with 3 bbls neat meth followed by 300 bbls 9.8# NaCI brine and 30 bbls crude. FWHP's=600/900/550. SV, WV, SSV = Shut. MV = O. IA, OA = OTG. Tags hung, DSO notified at departure. 04/27/09 T/I/0= 300/580/0. Temp=Sl. Circ Well. Pumped 3 bbls neat methanol, followed by 140 bbls of 9.8 brine down TBG. Capped with 5 bbls of diesel. Pumped 3 bbls neat methanol, followed by 412 bbls of 9.8 brine into IA. Pumped 2 bbls of neat methanol to flush lines. Capped IA with 10 bbls of diesel. MIT-OA ""PASS"" to 2000 psi. After 9 attempts and FBPE discussion with WIE (See MIT Data). Pumped 4 bbls of 50° crude down OA to reach test pressure. 15 min. check OA lost 50 psi. 30 min. OA lost 30 psi. Total loss 80 psi. Bled OA back to 0 psi. Bleed pressure on tbg and IA IA bled to 0 tbg at 210 psi rig down. (swab closed, wing closed, ssv closed, master open, annulus valves open to gauges operator notified of well status). 04/28/09 T/I/O = 230/5/VAC. Temp=Sl. Bleed WHPs to 0 psi. TBG, IA, OA FL near surface. No AL. Integral on companion. Bled TP to 200 psi in 30 min. Fluid to surface 10 min into bleed, C 200 psi, cut bleed rate. Called off job, FB to try to kill well. Final WHPs=200/5/0. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 04/28/09 Pumped a total of 490 bbls 9.8# brine, 11 bbls diesel down IA. Pumped a total of 161 bbls 9.8# Brine, 3bbls diesel down tubing. Monitor pressures for 30min. Swab, Wing, Grove =shut. Master, SSV, IA, OA = open. FWHP's 0/0/100. 04/29/09 T/I/O = MASTER/VAC/VAC. Temp = SI. Bleed IAP & OAP to 0 psi (pre-rig). No AL, no F/L. Bleed unnecessary due to annuli already being on vac. SV, WV, MV =Shut. SSV =Open. IA & OA = OTG. NOVP. Page 2 of 2 BP EXPLORATION Page 1 of 14 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To 5-29 5-29 REENTER+COM NABOBS ALAS NABOBS 7ES Hours Task PLET KA DRI Code E LLING NPT Spud Date: 6/4/1992 Start: 4/28/2009 End: I Rig Release: Rig Number: Phase Description of Operations 4/29/2009 15:00 - 18:30 3.50 MOB P PRE Release rig from A-44i at 15:00 hrs. Bridle up and prepare floor for move. Move pits module from substructure. 18:30 - 19:30 1.00 MOB P PRE Move substructure off A-44i. 19:30 - 21:00 1.50 MOB P PRE Pull pins from A-legs and lay down derrick. 21:00 - 00:00 3.00 MOB P PRE Move substructure to DS 15 well 29B. 4/30/2009 00:00 - 12:00 12.00 MOB P PRE Moving substructure from A-44i to 15-29B. Substructure arrived to DS 15 at 08:00 hrs. 12:00 - 17:00 5.00 MOB P PRE Spot Substructure on pad in preparation for pits, camp, and shop to move by and be staged. Set mats and lay herculite on top of mats. Cellar had not been rhino-lined; therefore, cellar was lined with herculite as per program. Spot Sattelite Camp and Truck Shop. 17:00 - 22:00 5.00 RIGU P PRE Spot Substructure over 15-296. Change out flow line to pits. Spot Pits Module. 22:00 - 00:00 2.00 RIGU P PRE Raise derrick, RU rig floor, bridal down, burm up around rig and hook up service lines. Spot cuttings tank (cuttings tank completed and passed all inspection requirements on 4/30/09). 5/1/2009 00:00 - 02:00 2.00 RIGU P PRE Continue preparing the cellar and rig floor. Take on 9.8 ppg brine into pits. Continue checking connections. Rig accepted at 02:00 hrs 05/01/09 on well 15-29B. 02:00 - 03:30 1.50 BOPSU P PRE Pressure test OA (9 5/8" x 13 3/8" annulus) to 2000 psi for 10 minutes; lost 40 psi during first 5 minutes and 10 psi uring last 5 minutes -good test. Took 10 bbls diesel to fill up OA. Pre-rig records indicate 4 bbls of crude were needed to fill up OA prior to test (4/27/09). Bleed OA pressure to 0 psi and RD test equipment. 03:30 - 05:30 2.00 BOPSU P PRE RU DSM lubricator and pressure test to 500 psi. Pull BPV. RD DSM lubricator. 05:30 - 06:00 0.50 BOPSU P PRE Reverse circulate 3 bbls diesel freeze protect out of tubing with 25 bbls of 9.8 ppg brine at 70 deg. Line up on tubing and circulate 11 bbls diesel freeze protect out of IA with 100 bbls of 9.8 ppg brine at 70 deg. Pump rate while circulating diesel freeze protect 3 bpm with 100 psi. Prior to circulate diesel freeze protect out of wellbore, IA took 31 bbls of 9.8 ppg brine to fill up. Once diesel freeze protect was out of hole, kept hole full with 9.4 ppg brine. 06:00 - 13:30 7.50 BOPSU P PRE Install TWC and pressure test from below to 200 psi for 5 minutes - ood test. Attem t to ressure test from above to 3500 psi in preparation for BOP test. Pressure test TWC from above bleeding off from 3500 psi. Inspect tree and and test pump valves - no visual leaks. Repeated test several times and continue looking for leaks. Continue to keep hole full by pumping 9.4 ppg brine down the IA. Note: Pre Spud meeting held with Johnston's crew during Pre Tour meeting. 13:30 - 16:30 3.00 BOPSU P PRE RU DSM lubricator, pressure test lubricator to 500 psi -good test. Pull TWC and inspect threads - no visual damage to any of its components. FMC installed new TWC. Printed: 5/18/2009 9:58:14 AM BP EXPLORATION Operations Summary Report Page 2 of 14 ~ Legal Well Name: 15-29 Common Well Name: 15-29 Spud Date: 6/4/1992 Event Name: REENTER+COMPLETE Start: 4/28/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date I From - To Hours Task Code ~ NPT ' Phase Description of Operations 5/1/2009 16:30 - 18:00 1.50 BOPSUR P PRE Pressure test TWC from above to 3500 psi for 10 minutes. 18:00 - 20:00 2.00 BOPSU P 20:00 - 22:00 2.00 BOPSU P 22:00 - 22:30 0.50 BOPSU P 22:30 - 00:00 1.50 BOPSU P 5/2/2009 00:00 - 04:00 ~ 4.00 ~ BOPSUF{ P 04:00 - 05:00 1.00 BOPSU P 05:00 - 08:00 3.00 BOPSU P 08:00 - 09:00 1.00 BOPSU P 09:00 - 09:30 0.50 BOPSU P 09:30 - 10:00 0.50 PULL P 10:00 - 12:30 I 2.50 I PULL I P 12:30 - 19:00 I 6.501 PULL I P 19:00 - 21:30 2.50 BOPSU P 21:30 - 22:30 1.00 BOPSU P 22:30 - 23:00 0.50 BOPSU P 23:00 - 00:00 1.00 BOPSU P 5/3/2009 00:00 - 03:30 3.50 CLEAN P Lost 100 si durin first 5 minutes and 0 si durin last 5 minutes. Isolate and change out valves on test um . Pressure test Test Pump for 10 minutes -good test. RD test e ui ment. PRE ND tree and adapter flange. PRE NU BOP. PRE RU test equipment for BOP testing. PRE Test BOP a ui ment with 4" and 4 1/2" test joints to 250 psi / 3500 psi. Each test held for 5 minutes. Bob Noble of AOGCC waived witness of test. Test witnessed by Toolpusher Lenward Toussant and WSLs Eli Vazquez and Carrie Williams. Continue filling IA with 9.4 ppg brine. Total of 329 bbls of 9.8 ppg brine lost to formation for today. Note: Pre Spud meeting held with Knighten's crew during Pre Tour meeting. PRE Continue testing BOP with 4" and 4.5" test joints. Rig Down test equipment and blow down lines. Filling the IA with 9.4 ppg brine, total volume 47 bbls. PRE Rig up Lubricator extension to pull TWC and test to 500 psi - 3 1/2" x 6" to rams not holdin . PRE Change out top 3 1/2" x 6" variable rams. Test 3 1/2" x 6" variable rams with 4" test joint to 3500 psi -good test. PRE Ri u Lubricator, test to 500 si - ood test. Pull TWC. Ri down Lubricator and extension. PRE Safety stand down. Meeting with all rig personnel to talk about the hand injury on Rig 33E. DECOMP Make up 4 1/2" TDS cross over to 1 jt of 4" DP in preparation to pull hanger. Pull and unseat 4 1/2" tubing hanger with 100K Ibs and ull to the ri floor. DECOMP Circulate 486 bbls of 9.4 ppg brine at 85 deg F with Safe-Surf-O at 5 bpm with 154 psi. Rig up 4 1/2" handling equipment including Schlumberger control line spooling equipment while circulating. Lost 7 bph while circulating. Monitor the well. DECOMP LD hanger. Pull and LD 4 1/2" IBT L-80 tubing from 6495'. Recovered 38 Stainless steal bands, 155 joints, 2 GLMs, 1 SSSV, and 20.31' cutjt. Rig down 4 1/2" handling equipment. Clean and clear rig floor. - Outside of tubing in fair to good condition. Inside of tubing is corroded with pitting. - All tubing, completion equipment, tree, and adapter flange NORM tested within limits. DECOMP PJSM with crew. Change out Upper IBOP and Lower IBOP on Top Drive. Change out grabber dies. DECOMP Rig up test equipment. Test Upper IBOP, Lower IBOP, 2 7/8" x 5" rams, and 3 1/2" x 6" rams with 4" test joint to 250 psi low and 3500 psi high. DECOMP Rig down test equipment. Blow down lines. Install wear ring. DECOMP RIH with 4" DP singles to 948'. DECOMP Continue picking up 4" DP from 948' to 5531'. Printed: 5/18/2009 9:58:14 AM BP EXPLORATION Page 3 of 14 Operations Summary Report Legal Well Name: 15-29 Common Well Name: 15-29 Spud Date: 6/4/1992 Event Name: REENTER+COMPLETE Start: 4/28/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To I, Hours Task Code NPT ', Phase Description of Operations 5/3/2009 00:00 - 03:30 3.50 CLEAN P DECOMP Fluid loss rate of 5 bph. 03:30 - 06;00 2.50 CLEAN P DECOMP POH and rac ac s s of 4" DP in derrick. Fluid loss rate of 5 bph. 06:00 - 10:00 4.00 CLEAN N RREP DECOMP Service the Top Drive. Clean and clear rig floor. Repair upper 10:00 - 11:30 I 1.501 CLEAN I P 11:30 - 16:00 I 4.501 CLEAN I P 16:00 - 16:30 I 0.50 I CLEAN I P 16:30 - 18:30 I 2.001 CLEAN I P 18:30 - 19:30 1.001 CLEAN ~ P 19:30 - 21:30 2.00 BOPSU~ P 21:30 - 23:30 2.00 BOPSU P 23:30 - 00:00 I 0.501 BOPSUF~P 15/4/2009 100:00 - 00:30 I 0.501 BOPSUa P 00:30 - 01:30 I 1.001 STWHIPI P 01:30 - 04:30 3.00 STWHIP P 04:30 - 07:30 3.00 STWHIP P 07:30 - 08:00 0.50 STWHIP P nR•M _ iR•~n R Fn Cl-1NHIP P ram valve on the BOP Accumulator manifold. Fluid loss rate of 5 bph. DECOMP Pick up 9 5/8" casing scraper BHA and RIH to 923'. BHA consists of: used MX-C1 Hughes bit, 9 5/8" csg scraper, bit sub with a float, 8 1/2" string mill, 9 jts - 6 1/2" Spiral DCs, 21jts - 4 "HWDP. Fluid loss rate of 5 bph. DECOMP RIH with scraper BHA on singles to from 6168' to 6487'. No issues with the trip. Tag 4 1/2" tbg stump at 6487'. PUW 135k, SOW 105k. ~~ Fluid loss rate of 5 bph. DECOMP Circulate bottoms up at 450 gpm with 1850 psi for a total of 374 bbls pumped while reciprocating pipe. Monitor the well for 15 min. Fluid loss rate of 5 bph. DECOMP POH with 9 5/8" scraper from 6487' to 923'. Stand back 4"DP, 4"HWDP, and 6 1/2" DC. Monitor the well. Fluid loss rate of 5 bph. DECOMP LD Scraper BHA. All components in full gauge. Clean and clear rig floor. Fluid loss rate of 5 bph. DECOMP Rig up Schlumberger E -Line unit. Pick up Halliburton 9 5/8" EZSV bridge plug. DECOMP RIH with Halliburton 9 5/8" EZSV bridge plug and set at 5791' MD (top element), 5' above casing collar at 5796' MD. Positive indication at surface of set. Tension in E line lost 569 lbs. PU 1' and set down 354 Ibs to confirm set. DECOMP POH with E -Line. Rig down Schlumberger E -Line unit. Verified tension sleeve in EZSV setting tool sheared. Monitor well while rigging down - no further losses noted. DECOMP Rig up to test EZSV bridge plug. Pressure test 9 5/8" csg to EZSV at 5791' to 3500 si for charted 30 min - ood test. Lost 30 psi during the first 15 min, and O psi lost during remainder of test. Ri down test a ui ment. WEXIT Make up 9 5/8" whipstock BHA with 8 3/8" Bottom Trip Anchor, Baker Gen II 9 5/8" whipstock slide, 8 1/2" window mill, 8 3/8" lower watermellon mill, 4 1/2" flex joint, 8 1/2" upper watermellon mill, 1 jt 5" HWDP, float sub, MWD, UBHO, 6 1/4" bumper sub, and 9 jts 6-1/4" DC. WEXIT RIH with Whipstock on 4"DP to 1496' and perform shallow hole test on MWD tools at 400 gpm with 705 psi -good test. Contnue to RIH from 1496' to 5786'. WEXIT Orient Whipstock 6ldegrees left of high side. Tag top of EZSV at 5786' and SO 18k to set bottom trip anchor. PU to confirm set. Shear mills from slide with 50k down weight. Pick up to confirm mills sheared from the whipstock assembly. WEXIT Displace the well to 9.3 ppg LSND milling fluid at 465 gpm with 1060 si for a total of 388 bbls. WEXIT Mill 8 1/2" window in 9 5/8" casing wit following parameters: Printed: 5/18/2009 9:58:14 AM 04/29/09 ,., `~ iFllllili~~~~1_ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .i.,ti ~ N0.5209 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 2-34/P-14 12017519 -- ----.. ...,.. ~ RST v~~G o~ wior CD 3-03/J-33 AZ4D-00013 - RST 09/27/09 04/05/09 1 1 1 15-29A J-09A AXBD-00022 AP3O-00024 CH EDIT PDC-GR (LDL) - RST L 04/18/09 1 3-01/N-29 15-29A 12-07A AYKP-00008 AXBD-00022 AY J - RST (~~.~ MEMORY LDL ~~~ - ~/ ~ `~~ 03/24/09 01/20/09 04/18/09 1 1 1 1 1 1 3 -00021 USIT 04/20/09 1 1 PLEASE ACKNOWLEDGE RE CEIPT BY SIGNI NG nNn aFr~iQti~Nr; nnio r•nov ~er.u:.,. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-f 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consultin ervices 2525 Gambell Street, Suit 00 Anchorage, AK 03-2 ATTN: Beth I 1 Received by: t ~- ~J i 04/29/09 ~~~I7~~~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .I~n e N0.5209 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 2-34/P-14 12017519 - ---- RST vaaas oL 1.010( GU 3-03/J-33 AZ4D-00013 RST _ 09/27/09 04/05/09 1 1 1 1 15-29A AXBD-00022 CH EDIT PDC-GR (LDL) - 04/18/09 1 J-O9A 3-01/N-29 AP3O-00024 AYKP-00008 RST L - RST (,~~ 03/24/09 01/20/09 1 1 1 1 15-29A 12-07A AXBD-00022 MEMORY LDL ~~~ ~ ~/ ~ Q ~~ 04/18/09 1 1 AY3J-00021 USIT 04/20/09 1 1 PLEASE ACKNOWLEDGE RE CEIPT wv sl[:w ar. enln RCTI Ioruulr_ .,,,~~ ~.,~.. ~,,..., ~... .__ _ ___-_. - . ~.-...... ~.....~ ..~. v. uo• v.~G a.vr t GNVfI 1 v: BP Exploration (Alaska) Inc. Alaska Data & Consultin ervices Petrotechnical Data Center LR2-1 2525 Gambell Street, Suit 00 900 E. Benson Bivd. Anchorage, AK 03-2 Anchorage, Alaska 99508 ATTN: Beth r ;; Date Delivered: -~"`-~- Received by: ~~----,~ • ";::~, • • a,~. ~:~ .J SARAH PALIN GO ,~ ~ VERNOR ~~ OLJ ~ alr4a7 333 W. 7th AVENUE, SUITE 100 COI~TSI,'`R~A7`IOl'1T CO1rII-II5SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Robert Tirpack FAx (907) 276-7542 Engineering Team Leader BP Exploration Alaska Inc. r ~-.,~~,~~~ ~ ~~ ~ €~ ~~ ~ ~~ &~L.u u' L - ~ . PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 15-29A Sundry Number: 309-098 V , ~ ~ ~~ ~~ Dear Mr. Tirpack: 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. When providing notice for a representative of the Commission to witness any required test, contact the Comrriission's petrolet.lm field inspector at (907) 659-3607 (pager). 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 Comnussion 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 Corrunission decision to Superior Court unless rehearing has been requested. Sincerely, iy~ DATED this .,~~day of March, 2009 Encl. Y 4 0 ~~~ (~ 0~ STATE OF ALASKA ~~~~®~~~ "- ~h~ ALA OIL AND GAS CONSERVATION COM~ION ,: p ~ ~(~~~ V ~-~ APPLICATION FOR SUNDRY APPROVAL ~~ 20 AAC 25.280 ~~..eg: ~ .: ~ ~ "e~~ ~~t~~. Cornmission 1. Type of Request: ®Abandon - ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time~~te~i~pE ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 202-016 - 3. Address: ^ Service ^ Stratigraphic 6. APt Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22259-01-00 - 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 15-29A- Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028306 & 028303 - 66.2' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12900' ~ 873T - 12833' - 8739' 10633' None in Len th iz M TVD urs Ila e tru ral n r 110' 11 110' 1 2 Surface 4160' 1 - /8" 41 0' 3508' 4 0 2270 Intermedi a 10760' 9-5/ " 107 0' 8338' 687 4760 P Liner 789' 7" 1 2 ' - 11309' 8210' - 8571' 7240 10 Liner 2277' 3-v2" x 3-3/16" x zaia" 10623' - 12 0 ' 8264' - 7 7' 1 160 1 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 11882' - 12790' 8760' - 8741' 4-1/2", 12.6# L-80 10644' Packers and SSSV Type: 7" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 10589' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: March 23, 2009 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garret Staudinger, 564-4242 Printed Name Robert Tirpack Title Engineering Team Leader Prepared ey Name/Number: Signature ~ ~~/' Phone 564-4166 Date .is/ ~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~ S t ~.~~~ T t~ ~~~ P S ~~ ~~rw~~~~ Gh~~~ca~ ~S~ Subsequent Form Required: (rte '-'tV - ~ ,~~- ~' -, rt ~ APPROVED BY e ~ ~ COMMISSIONER THE COMMISSION Dat A roved D Form 10-403 Revi~d 06/2006 ~ Submit In Duplicate by c,~~ • 15-29B Rig Sidetrack Well Type: Producer Current Status: This well is completed with 3-3/16" liner inside 4-1/2" L-80 tubing inside a 7" liner and is currently shut-in. Request: Abandon Reason for Sundry Application: As part of the rig sidetrack operation, the existing 15-29A perforations will be permanently abandoned as follows: - 21.2 bbls of 15.8 ppg Class G cement will be pumped through a cement retainer placed at 10,600'. A 100' cement plug will be placed on top of the cement retainer in the 4-1/2" tubing. The cement plug will be tagged with slickline. - Additional isolation from the perfs will be achieved with the cement in the new 7" x 9 5/8" liner lap, and a liner top packer. Reason for Sidetrack: 15-29A currently has an existing 9-5/8" production casing leak as well as tubing by inner annulus communication. A RWO option was considered, but well work events indicate that the formation is most likely dumpflooded. The sidetrack will target Z1A reserves in the northern portion of DS-15. Current Status: 15-29A is a CTD sidetrack that was drilled in February 2002. The well was drilled with a known PC leak at 7405' MD with the intention of having it sealed with a gel squeeze post-drilling. The OA was downsqueezed with 50 bbls of cement in August 2003 that resulted in a passing MIT-OA to 3000 psi. The well began to cycle in fall 2003, and subsequent add perfs did not help production results. On 1/31/05 the TxIA communication was established as the IAP was tracking the tubing pressure while attempting to POP the well. The well is currently secured with a 3-1/2" XN plug set at 10,633' on 9/19/07. The wellwork events indicate that the formation is most likely dumpflooded. 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) 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. • • Scope of Work: Squeeze 21.2 bbls of cement below a cement retainer in the 4-1/2" tubing at 10,600'. Lay 100' of cement on top of the retainer. Cut and pull the 4-1/2" L-80 completion. MASP: 2327 psi Estimated Start Date: May 15, 2008 Pre-rig prep work: F 1 Fluid ack the tubin and inner annulus w/ seawater/diesel. S 2 RU, ull 3-1/2" XN Plu @ 10,633' MD. Drift tubin to to of 3-1/2" liner. E 3 RU, run GR to in arent well from 10,800' to surface at 1800 ft/hr. E 4 Set 4-1/2" cement retainer at 10,600' C 5 P & A the perforations in the 15-29A wellbore with cement from 12,835' MD up to the 4-1/2" cement retainer at 10,600' MD. Lay in 100 ft of cement plug on top of retainer. RIH and sting into cement retainer at 10,600'. Perform infectivity test. Bullhead cement into perforations. Target squeeze pressure of --1000 psi over baseline injection WHP. Sting out of retainer and lay cement 100' MD in tubing above retainer. a. CEMENT CALCULATIONS i. 1482' of 2-7/8", 6.16# liner: .0058 bbls/ft = 8.6 bbls ii. 571' of 3-3/16", 6.2# liner: .0076 bbls/ft = 4.3 bbls iii. 159' of 3-1/2", 9.2# tubing: .0087 bbls/ft = 1.4 bbls iv. 23' of 4-1/2", 12.6#" tubing: .0152 bbls/ft = 0.4 bbls v. 100' of 4-1/2", 12.6#" tubing: .0152 bbls/ft = 1.5 bbls TOTAL (with 5 bbls excess) = 21.2 bbls . Note: If squeeze pressure cannot be achieved after cement is pumped, sting out of cement retainer and circulate from 100' above retainer to surface to ensure that the tubing above the cement plug is free of cement. BHP (formation): 3200 psi BHT (formation): 173 deg F Min TOC: 100' MD above cement retainer Max TOC: 1000' MD above cement retainer S 6 WOC. Drift for Jet Cutter. Ta To of cement lu . E 7 Jet cut the 4-1/2" tubin in the middle of a full ~oint at 6500' MD. F 8 Circulate the well to 9.5 ppg brine. Note PC leak 7405' MD. Freeze protect the IA and tubin with diesel to2,200'. F 9 CMIT - T x IA to 3,000 psi -for 30 minutes. Establish LLR: MIT - OA to 2,000 psi for 30 minutes D 10 Bleed all casin and annulus ressures to zero si. W 11 Function all tubing and casing LDS. Repair and replace as necessary. PPPOT - IC and PPPOT - T. V 12 Set a BPV. Remove well house and flow line. Level the pad as needed. Provide total well re aration cost on the handover form. Proposed Procedure: 1. MIRU. 2. Pull BPV. Circulate out freeze protection with 9.5 ppg brine and condition fluid as needed. If brine losses are significant with the 9.5 ppg brine, reduce the brine weight as required to a minimum 9.2 ppg. Set a TWC and test from below ("rolling test due to PC leak) and above to 3500 psi. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. RU and pull the 4-1/2", 12.6#, L-80, IBT-M tubing from the pre-rig jet cut at --6500' MD. Spool up the control line and count stainless steel bands (51 listed on tally). Test the lower set of pipe rams. • 5. PU 4" drillpipe and 9-5/8" clean-out assembly and clean-out well to the top of the tubing stub 6500' MD. (NOTE: If brine losses are a problem, cut the brine weight to 9.2 ppg.) 6. PU 9-5/8" RTTS. RIH to 6000' MD and pressure test above the RTTS to 3500 psi for 30 minutes and chart. (NOTE: A PC leak is possible, therefore if the test fails, the RTTS will be used to locate the leak point. The liner top will be brought high enough to repair the well.) 7. With E-line, run a 9-5/8" EZSV for 47# casing. Set the EZSV at 5790' MD. Rig down E-line. 8. If a good pressure test above the RTTS was achieved in Step #6, pressure test the EZSV to 3500 psi for 10 minutes. 9. PU 9-5/8" whipstock, bottom trip anchor and 8.5" window milling assembly (to include full gauge string mills). ~~` 10. Hang weight of 9-5/8" whipstock assembly and set storm packer just below the wellhead. 11. Change out the 9-5/8" pack-offs per FMC. ~,~p 12. RIH to the top of the EZSV. Orient and set the whipstock. Swap the well over to 9.6 ppg fresh water ~ 13. Mill a window in the 9-5/8" casing from 5770' MD' plus 20' of formation from mid-window. 14. Perform an FIT. POOH for drilling BHA. 15. MU an 8-1/2" drilling BHA with DIR/GR/RES and ghost reamer. RIH. Kick off and drill 8-1/2" intermediate interval to 7" casing point at the top of the Sag River (11,480' MD). NOTE: The mud will need to be weighted up with spike fluid. Plan for one weight-up with the spike fluid to 10.8 ppg over several circulations prior to drilling the HRZ and Kingak shale. 16. Change to 7" casing rams and test. 17. Run and cement a 7", 26#, L-80, BTC-M drilling liner throughout the 8-1/2" hole and back into the 9- 5/8". Set TOL to cover cretaceous (cretaceous top at top SV1). Set hanger /liner top packer and displace cement with mud. POOH. 18. MU a 6-1/8" BHA with DIR/GR/RES and RIH to the 7" landing collar. Pressure test liner and casing to 3500 psi for 30 min. Drill out the shoe plus 20' of formation while swapping over to new Flo-Pro drilling fluid. Perform an FIT. 19. Drill ahead per plan building to horizontal and complete the 10°/100' doglegs building the well for the planned Ivishak Z1 horizontal section of the well. POOH for bit and BHA change. 20. MU a 6-1/8" BHA with DIR/GR/RES/DEN/NEU. RIH, verify with town geo to MAD pass build interval. Drill ahead in the horizontal per plan to an estimated TD of 14,639' MD. 21. CBU, short trip, circulate until clean and spot a liner running pill. POOH. 22. Run and cement a 4-112", 12.6#, L-80, IBT-M liner from TD to 150' inside the 7" shoe. Set the liner top packer. 23. Run on DP 1400' of 2-7/8" HSD, 2006 PJ HMX, 6 spf perf guns and shoot over balanced. Fire guns, POOH. LD remaining DP 24. RU and run 4-1/2", 12.6#, 13Cr-80, Vam Top completion, tying into the 4-1/2" liner top. 25. Reverse circulate to spot corrosion inhibited seawater. 26. Drop ball and rod. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. Shear DCK valve. 27. Set and test a TWC. 28. ND BOPE. NU and test the tree to 5,000 psi. Pull TWC. 29. Freeze protect the well with diesel to 2200' MD. Set a BPV 30. RDMO. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. 2. Install gas lift valves. 3. Install wellhouse and flowlines. (If the Adapter Flange is changed, S-Riser work will be required.) Drilling Engineer: Garret Staudinger (907)564-4242 Production Engineer: Nathan Sinyangwe (907)564-5062 Geologist: Doug Stoner (907)564-5652 TREE= 4-1/16" CNV ACTUATOR = . ._ U LIS - K~. ELEV = 66.2' BF. ELEV _ .--, ~ KOP = 725' Max Angle = 98 @ 12425' Datum MD = NA Datum TVD = 8800' SS 20' CONDUCTOR 94.5#, H-40, ID = ? 13-3/8" CSG, 68#, K-55 BTC XO TO L-80 BTC 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" SAFETY NOTES: ***13-3/8" CSG BURST IS 3450 -~ ~ ~ PSI*** ELL ANGLE > 70° @ 11200' 112' 4~60~ BKR TIEBACK SLEEV E, ID = ? 9-5/8" X 7" BKR "H" LTP, ID = 6.29"? 9-5/8" X 7" BKR LNR HGR, ID =6.30;? 10508' 10515' Minimum ID = 2.377" @ 11354' 3-3/16" X 2-7/8" LNR X-OVER 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10643' 9-5/8" CSG, 47#, L-80, ID = 8.681 " 10760' 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.992" 10782' WHIPSTOCK 11305' RA PIP TAG 11315' 7" LNR, 26#, L-80 IJ4S, .0383 bfp, ID = 6.276" i-~ 12330' PERFORATION SUMMARY REF LOG: SWS MEMORY GR/CNL ON 02/25/02 ANGLE AT TOP PERF: 83 @ 11882' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11882 - 11907 C 12/23/03 2" 4 11960 - 12120 C 02/25/02 2" 4 12390 - 12430 C 02/25/02 2" 4 12480 - 12790 C 02/25/02 2075' 4-1/2" CAMCO BAL-O SSSVN, ID = 3.812" 3322' EST TOP OF CEMENT (08/23/03) GAS LIFE MANDRELS I I J~ 3-3/16" LNR, 6.2#, L-80 TC11, .0076 bpf, ID = 2.786" ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3704 3178 45 HES-TB DMY T-2 0 01/15/02 2 6042 4918 42 HES-TB DMY T-2 0 01/15/02 3 8163 6480 43 HES-TB DMY T-2 0 01/15/02 4 9998 7864 41 HES-TB DMY T-2 0 01/15/02 5 10152 7976 42 HES-TB DMY T-2 0 01 /15/02 10589' - j 7" X 4-1 /2" BKR s-3 PKR, ID = 3.875" 10622' 4-1/2" HES X NIP, ID = 3.813" 10623' 3.70" BKR DEPLOY SLV, ID = 3.00" 10629' 3-1 /2" BKR PUP PDC, ID = 2.990" 10633' 3-1 /2" XN NIP, ID = 2.750" 10633' 3-1/2" XN PLUG SET(09/19/07) 10644' 4-1 /2" WLEG, ID = 3.958" 10643' ELMD TT LOGGED 04/28/01 10782' 3-1 /2" X 3-3/16" LNR XO, ID = 2.80" 7" LNR MILLOUT WINDOW (15-29A) 11309' - 11316' 11353' 3-3/16" X 2-7/8" LNR XO, ID = 2.377" I 11353' I PBTD 2-7/8" LNR, 6.16#, L-80 STI., .0058 bpf, ID = 2.441" i~ 12900' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/04/92 D-9 ORIGINAL COMPLETION 03/05/05 TJPlTLH WANERSAFETY NOTEXXL'D 07/16/96 D-14 RWO 04/17/05 WIGS/PJC XXN PLUG IN NIP 02/26/02 NORDIC 1 CTD SIDETRACK (15-29A) 08/20/07 JLJ/PJC PULL XXN PLUG 09/03/03 KC/TLH WANERSAFETYNOTE 08/21/07 PJC WBSCORRECTIONS 09/12/03 CMO/TLP DATUM MD CORRECTION 09/22/07 DTR/SV XN PLUG SET (09/19/07) 01/18/04 JR/TLH PERFS / OA DWNSOZ (08/23/03) PRUDHOE BAY UNff WELL: 15-29A PERMIT No: RL020160 API No: 50-029-22259-01 SEC 22, T11 N, R14E, 148' SNL & 22' EWL BP 6cploration (Alaska) IRCC 9-1/10 l..iVY WELLHEAD= FMC ACTUATOR =' OILS ~ KB. ELE16 = tbd BF. ~ELEV = tbd KOP = 5770 Max Angle = 125 Datum MD = tbd Datum TV D = 8800' SS 15 -2 Proposed SAFETY NOTES: 13-318" CSG BURST IS 3450 PSI 3-3/8" CSG, 68#, K-55 BTC XO to L-80 Bll-1 122' 13-3/8" CSG, 68#, L-80, ID = 12.415" 4160' Minimum ID = 3.725" @ 11310' 4-1/2" OTIS XN NIPPLE T' TOL 5000' 9-5/8" Whipstock ~--~ 5770' 9-518" Bridge Rug 5790' PERFORATION SUMMARY REF LOG: ANGLEAT TOP PERF: Note: SIZE SPF INTERVAL OpnlSgz DATE 2.88" 6 1400' Tubing Cut N 6500' ~/ BKR TIEBACK SLEEV E 10608' CEMENTRETAINER 10600' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10670' ~ 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10643' WS -j 11306' ~ 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 12330' 2200' H4-1l2" X 3322' HEST TOP OF CEMENT (8/23/03) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 tbd 2 tbd 1 tbd 11260' I4-112" OTIS X NIP, ID = 3.813" 11270' 7" x 4-112" S-3 PKR 11290' 4-1/2" OTG X NIP, ID = 3.813" 11310' 4-1/2" OTIS XN NIP, ID = 3.725" 11330' 4-1/2", 12.6#, 13-CR, :0152 bpf, ID = 3.958" 11480' 7", 2li#, L-80, BTCM, 0.0383 ' bpf, ID = 6.276" GATE REV BY COMMENTS DATE REV BY COMMENTS 08104!92 D-9 ORIGINALCOMPLETION 03/05/05 TJP/TLH WANERSAFETY NOTEXXL'D 07!16/96 D-14 RWO 04/17/05 MGSJPJC XXN PLUG IN NIP 02!26/02 NORgC 1 CTD SIDETRACK (15-29A) 08/ZOro7 JLJ/PJC PULL XXN PLUG 09/03/03 KGTLH WAVER SAFETY NOTE 08/21/07 PJC WBS CORRECTIONS 09/12/03 CMOlTLP DATUM MD CORRECTION 09l22ro7 DTR/SV XN PLUG SET (09/19/07) 01/18J04 JR/TLH PERFS 1 OA DJIINSOZ (08/23 02117/08 GJS 15-296 PI7fOPOSAL PBTD H 14569' 14639' H4-112", 12.6#, L-80, .0152 bpf, 13.958" ~ R~UDHOE BAY UNfT WELL: 15-29B Proposed PERM1IAT No: tbd AR No: 50-Q29-22259-02 Sec. 22, T11 N, R14E, 148' SNL & 22' BtVL BP Exploration (Alaska) 09/27/07 N0.4437 Alaska Data & Consulting Services ~If1 (~ '7 Company: State of Alaska 2525 Gambell Street, Suite 400 ^~i ` +~~~~ iy V ~ ~+ ~ ~~~ ` Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Wnll Inh f! 1 nn rfncrrinfinn r1a4a AI. Cninr Cn 15-29A 11686783 SCMT ab 09!05/07 1 05-25B 17630496 SCMT _ < 08/30/07 1 02-33A 11813082 SCMT 08/31/07 1 15-28A 11686782 SCMT 09/04/07 1 N-27 11824345 SCMT - 09/12/07 1 05-22A 11813086 SCMT 09/18/07 1 S-400A 11855508 USIT - 09/18/07 1 E-27A 11676963 USIT (CEMENT) j 09/18/07 1 E-27A 11676963 USIT (CORROSION) 09/18/07 1 MPG-07 11594520 USIT S - ' 08/29/07 1 MPS-37 N/A SCMT - 09108/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGN{NG AND RETURNING ONE DOPY EACH TD: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 , , ,-~ 900 E. Benson Blvd. ~ ,~i~e ~~/ ~,-~ ~ ~- Anchorage, Alaska 99508 ~ ~ Date Delivered: sw - ~. u. • • Alaska Data & Consulting Serv es 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-283 ATTN: Beth ._ _.___ Received b j~ a~i~ " , §" ;,,. ;;ut'i'i'BiiI~wlCil! .: n_, i~ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm_ Marker.doc RE: Cancel Waiver: 15-29 . ') $~:~jeç~: l~E: Cancel \Va.iyer:TS~49 ~tPJn;}'.A114ers, Joe Lt'<::ai1q.~ts24@;ap~com> Dåt~:Frî;04Mar200514:4o:46~0900 ') -hie:. R-bd1 ZV'l, -Ù/~ Hi Jim. IS-ZÇ¡ 4- JG~ 3/4(05 Both 1~ and 17-11 have been 81. W-05 had the production casing hanger seals replaced during a RWO conducted May 2004. Let me know if you have any additional questions. Joe -----Original Message----- From: James Regg [mailto:jim_regg@admin.state.ak.us] Sent: Friday, March 04, 2005 2: 19 PM To: Anders, Joe L Cc: Winton GAubert Subject: Re: Cancel Waiver: 15-29 Joe - re: 15-29 and 17-11; does this mean the wells have been SI? re: W-05; repairs done to eliminate SCP? Jim Regg AOGCC Anders, Joe L wrote: Hello all. Well 15-29 (prO 2020160) has been reclassified from "Waiver" to 'Trouble". The well has both TxlA and a PC leak. Please remove any copies of the waiver and any waiver signs from the wellhouse. Call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator BP Exploration (Alaska), Inc 1-907 -659-5102 anders22@¿bp.com ::;CANNEt) MAR ], ~1 Z005 ] of] 3/4/2005 3:] 8 PM ) ) ;J7~~~~~1 DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 5rJ qr-J-~ ,_ Permit to Drill 2020160 Well Name/No. PRUDHOE BAY UNIT 15-29A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22259-01-00 MO 12900 ,.- TVD 8737 ..,- Completion Date 2/25/2002 ,.- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION ~ Mud Log No Samples No Directional Survey ~ DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/~ Number Nan Scale Media No Start Stop CH Received Comments ~ ¡¡¡ì~ P - Rpt 1 10815 12324 Case 1/9/2003 PS1 ED C c/10690 ¡lill.tl! 1 10452 12834 Case 3/29/2002 Rpt 1 10815 12864 Case 1/9/2003 ED 0 1 10815 12324 Case 1/9/2003 PS1 ED D 1 10815 12864 Case 1/9/2003 ED C 1,3 10819 12899 Open 6/2/2003 ED C Pdf 25 Final 11326 12900 Open 6/2/2003 MWD-ROP, NGP-MD ED C Pdf 25 Final 11326 8671 Open 6/2/2003 DELETE ED C Asc 1,2 10819 12356 Open 6/2/2003 PB1 ED C Pdf 25 Final 11326 12356 Open 6/2/2003 MWD-ROP, NGP-MD ED C Pdf 25 Final 11326 8741 Open 6/2/2003 MWD-NGP- TVD -q.b Las 11638 12188 Case 1/20/2004 Production Profile 5 Slu 11638 12188 Case 1/20/2004 CULLED - Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ) ) DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permit to Dri 2020160 Well Name/No. PRUDHOE BAY UNIT 15-29A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22259-01-00 MD 12900 TVD 8737 Completion Date 2/25/2002 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION C(yyN Welf Cored? Y/~ Daily History Received? Chips Received? ~ Formation Tops C0/N Analysis ~ Received? - - - Comments: ~ - - ~~ Compliance Reviewed By: Date: r---.. .----., dUd-O( Co WELL L.OG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7"'Street Suite # 700 Anchorage, Alaska 99501 RE: Distribution - Final Print(sJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy Df this transmittal letter to the attentiDn of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL LOG TYPE DATE Open Hole 1 5-29A 12-22-03 Res. Eva!. CH Mech. CH Caliper Survey Signed: ~ô\~, N~\'(')~:h..('-/V\ \ Print Name: DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT[S] 1 1 Date: RECEIVED ! ^ 1·1 2 (! ?¡\OJ ...,!¡ '" ! ....v .... Alaska Oil & Gas Cons. Commision ftt.diorage Phone:(281) 565-9085 Fax:(281) 565-1369 PRoACTivE DiAGNOSTic SERvicES, INC., PO Box 1 }69 STAffoRd TX 77477 E-mail: pds@memorylog.com ~~~\\\ ~ REPORT OR CoLOR Website: www.memorylog.com ~ STATE OF ALASKA ~ ALASKn JIL AND GAS CONSERVATION COfv....,SSION REPORT OF SUNDRY WELL OPERATIONS ~ 1. Operations Performed: Abandon 0 Alter CasingD Change Approved Program D 2. Operator SuspendD Repair Well 0 Pull TubingD Operation ShutdownD Plug PerforationsD Perforate New Pool 0 4. Current Well Class: Annular Disposal 0 OtherD Perforate [&] Variance 0 Stimulate 0 Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0160 Name: BP Exploration (Alaska), Inc. Development Œ] ExploratoryD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 66.20 8. Property Designation: ADL-0028303 11. Present Well Condition Summary: Stratigraphic 0 ServiceD 9. Well Name and Number: 15-29A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 6. API Number 50-029-22259-01-00 Total Depth measured 12900 feet true vertical 8737.2 feet Effective Depth measured 12834 feet true vertical 8739.2 feet Casing Conductor Liner Liner Liner Production Surface Length 80 794 572 1546 10730 4130 Plugs (measured) Junk (measured) None None Size MD TVD Burst Collapse 20" 94# H-40 30 - 110 30.0 - 110..0 1530 520 7" 26# L-80 10515 - 11309 8207.2 - 8571.4 7240 5410 3-112" 9.3# L-80 10782 - 11354 8349.9 - 8584.7 10160 10530 2-7/8" 6.5# L-80 11354 - 12900 8584.7 - 8737.2 10570 11160 9-5/8" 47# L-80 30 - 10760 30.0 - 8338.0 6870 4760 13-3/8" 68# J-55 30 - 4160 30.0 - 3508.1 3450 1950 Perforation depth: Measured depth: 11882 -11907,11960 -12120,12390 -12430,12480 -12790 REef''' .,..,~. Tubing ( size, grade, and measured depth): True vertical depth: 8760.06 - 8762.99, 8769.84 - 8781.05, 8765.56 - 8760.32, 8754.71 - 8741.3 30 - Packers & SSSV (type & measured depth): 4-1/2" 12.6# L-80 @ JAN 0 ~ . ¡'t< 10644 Alaska Oil & Gas @ 10515 Anch".,c" I"'tr~ @ 10589 \...~.- ' -',' .: if ~ .~~... .:.<!;",! ~ 7" Liner Top Packer 4-1/2" Baker S-3 Perm Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Form 10-404 Revised 2/2003 Oil·Bbl 988 977 Representative Dailv Averaae Production or Iniection Data Gas·Mel Water-Bbl Casing Pressure 34426 8 300 32970 7 200 Tubin Pressure 961 1143 15. Well Class after proposed work: ExploratoryD Development XJ Service 0 16. Well Status after proposed work: Operational Shutdown 0 Oil 00 GasD WAGD GINJD WINJD WDSPLD Prepared by Sharmaine (907) 564-4424. Sundry Number or N/A if C.O. Exempt: Title Technical Assistant 564-4424 .~ ~ - "" 15-29A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/23/03 11882'-11907' 6 SPF SWS 2". All shots fired FLUIDS PUMPED BBLS 36 Methanol 36 TOTAL Page 1 .~ STATE OF ALASKA~ ALASKh ùlL AND GAS CONSERVATION COfv..vdSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved ProgramD 2. Operator SuspendD Repair WellŒ Pull TubingD Operation Shutdown D Plug PerforationsD Perforate New Pool 0 4. Cùrrent Well Class: Perforate D VarianceD Stimulate D Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 202-0160 Annular Disposal D Other 0 Name: BP Exploration (Alaska), Inc. Development ŒI ExploratoryD 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 66.20 8. Property Designation: ADL-0028303 11. Present Well Condition Summary: StratigraphicD ServiceD 9. Well Name and Number: 15-29A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 6. API Number 50-029-22259-01-00 Total Depth measured 12900 feet true vertical 8737.2 feet Effective Depth measured 12834 feet true vertical 8739.2 feet Plugs (measured) Junk (measured) None None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 30 110 30.0 - 110.0 1530 520 Liner 794 7" 26# L-80 10515 11309 8207.2 - 8571.4 7240 5410 Liner 572 3-1/2" 9.3# L-80 10782 11354 8349.9 - 8584.7 10160 10530 Liner 1546 2-7/8" 6.5# L-80 11354 12900 8584.7 - 8737.2 10570 11160 Production 10730 9-5/8" 47# L-80 30 10760 30.0 - 8338.0 6870 4760 Surface 4130 13-3/8" 68# J-55 30 4160 30.0 - 3508.1 3450 1950 Perforation depth: Measured depth: 11960 -12120,12390 -12430,12480 -12790 True vertical depth: 8769.84 - 8781.05,8765.56 - 8760.32,8754.71 - 8741.3 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 4-1/2" 12.6# L-80 @ RECEIVED JAN 0 8 2004 7" Liner Top Packer 4-1/2" Baker S-3 Perm Packer 30 - 10644 @ 10515 Alaska Oil & Gas Cons. Commission @ 10589 Anchorage 12. Stimulation or cement squeeze summary: Intervals treated (measured): 3800' - 3803' Treatment descriptions including volumes used and final pressure: See Attached for Fluids: Final OAP 160 psi 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 958 993 35644 36004 o o o o 1029 886 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development 1&1 ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Operational Shutdown D Oil[XJ GasD WAGD GINJD WINJD WDSPLD Prepared by Sharmaine (907) 564-4424. Sundry Number or N/A if C.O. Exempt: Daily Report of Well Operations _ X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Copeland Printed Name Sharm ¡Copelan Title Technical Assistant Form 10-404 Revised 2/2003 .fØ)MS 564-4424 ,--.... ~ <s- " ,-- 15-29A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/23/03 T/I/O = 218010/400. OA Oownsqueeze. On location with OS. Hold safety meeting with OS and Nordic 1 crew. MIRU OS to OA. PJSM. PT lines to 3000 psi. Open up to OA and pumped 25 bbls of OS CW 101 surfactant. Followed up with 220 bbls of freshwater to 08/25/03 TIO= 2460/vac/vac. LNFT-IA Passed (PC Leak Waiver). OA FL @ 60' (4 bbls). 08/26/03 T/I/O = 2400/0/0. MIT - OA to 3000 psi -PASSED-. (Post OA Downsqueeze). Pressured OA to 3000 psi with 7.2 bbls of Crude. Started 30 min test. OA lost 180 psi in 15 min. Re-pressured to 3000 psi. OA lost 120 psi in the 1 st 15 min and 80 psi in the 2 FLUIDS PUMPED BBLS 25 DS CW 101 Surfactant 240 Freshwater 50 15.7# Arctic Set 1 Cement 194 Crude 509 TOTAL Page 1 ~ ~, d(Jd -0 ] <-0 ..¥"'''..---....,'.......-.. WELL LOG TRANSMITTAL To: State of Alaska May 14,2003 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tl! Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWDFormationEvaluationLogs 15-29A& 15-29APB1, AK-MW-22031 15-29A: Digital Log hnages: 50-029-22259-01 1 CD Rom '\ \ct<3S t5-29A PDt: Digital Log hnages: 50-029-22259-70 1 CD Rom 1\ <=1 ~Lo PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES 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: rC;)j¡"""C"""¡¡En 'J'E"""'D"'" r,-C' !!i --g V . JUN 0 2 2003 i\~,.,,,t,... (1" 'oi {~.., "'j ..... ".. " FUQìvI\.t.I \JÙ C; "'~t; \A}: ¡~i. wiJn1nll55rJTJ !-\;"'!cchorage ~~~~~ -.. ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska January 3, 2003 RE: MWDFormationEvaluationLogs 15-29A& 15-29APB1 AK-MW-22031 dO:;},.- 0/ to I ¡Y109 I t410(P8tJ 2 LDWG formatted Disks with verification listing. API#: 50-029-22259-01 & 50-029-22259-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) mc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: RECEIVED ,JAN 0 9 2003 ßJsst,,,, (\.'J þ f'.'.. .,. ...1/ !2vi:l,~ Cons. CQ '. ø~~~ ·mrtJJ8'fion ~ ."--" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well 181 Oil o Gas o Suspended o Abandoned o Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 202-016 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 vJ.OCAnot'l$ 50- 029-22259-01 4. Location of well at surface . "f\ ' \: /1,,~ :' 9. Unit or Lease Name 148' SNL, 22' EWL, SEC. 22, T11N, R14E, UM , H[>' &.¡" ':JC.I If ;; Prudhoe Bay Unit At top of productive interval 2. . 2'<;' 6'7- \ ,..., . &-1~ ..--_.~~.. ,,_-'_U._~_ j ¡g. n,.~~'3I J 1785' NSL, 4818' EWL, SEC. 09, T11N, R14E, UM ,,' 'iCX""" :>~,# 10. Well Number At total depth :¡ 15-29A 2049' NSL, 549' EWL, Sec. 10, T11N, R14E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 66.20' ADL 028303 12. Date Spudded 113. Date T.D. Reached 14. Date Comp., Susp., or Aband. 115. Water depth, if offshore 16. No. of Completions 2/19/2002 2/22/2002 2/25/2002 N/ A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD). 19. Directional Survey 20. Depth where SSSV se~ 21. Thickness of Permafrost 12900 8737 FT 12833 8739 FT 181 Yes 0 No (Nipple) 2078 MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, ROP, CCL, CNL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.5# H-40 Surface 110' 30" 000# Coldset II 13-3/8" 68# BTC Surface 4160' 16" 088 cu ft Coldset II. 505 CU ft Class 'G' 9-5/8" 47# BTC Surface 10760' 12-1/4" 825 cu ft Class 'G' 7" 26# IJ4S 10520' 11309' 8-1/2" 72 cu ft Class 'G' 3-112' x 3-3116' 9.3# 1 6.2# L-80 10623' 12900' 3-3/4" 112 cu ft Class IG' x2-7/S' 16.16# 24. Perforations open to Production (MD+ TVD of Top and 25. TUSING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 SPF 4-1/2", 12.6#, L-80 10644' 10589' MD TVD MD TVD 11960' - 12120' 8770' - 8847' 26. ACID, FRACTURE, CEMENT SaUEEZE, ETC. 12390' - 12430' 8766' - 8760' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12480' - 12790' 8755' - 8741' 2000' Freeze Protected with MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 4, 2002 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BsL GAs-McF WATER-BSL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BSL GAs-McF WATER-BSL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA --- Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit c . ~"'IV~U No core samples were taken. APR 10 2002 AlaBkaOll& GasCona. Commission Anchorage f"··U'.....\lr">.. H\I ~ I , .~. ~ C]' '\j 1'=\ L R APR ,5 Form 10-407 Rev. 07-01-80 \.) ¡ '\ ¡ ì ¡ r " 200 Submit In Duplicate BOMSBFl 2 Gt=: .~ r----. 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. Zone 1 B 11832' 8755' RECEIVED APR 1 0 2002 AlalkaOll&GasCona.Commis8ion AndIoIage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summaries. 32. I hereby certify that the fore oing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date ()Lf·/V·Q 15-29A Well Number 202-016 Permit No. / A roval No. Prepared By Name/Number: Sandra Stewman, 564-4750 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 Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-29A 15-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/14/2002 Rig Release: Rig Number: Spud Date: 6/4/1992 End: 2/14/2002 15:00 - 00:00 9.00 MOB N WAIT PRE Rig ready to lay down wind-walls and derrick. Wind speed above minimum of 15 MPH. Wait for wind to subside. 2/15/2002 00:00 - 01 :30 1.50 MOB N WAIT PRE WAIT ON WEATHER. Wind above 20 mph. 01 :30 - 06:00 4.50 MOB P PRE Lay down wind walls and derrick. 06:00 - 07:00 1.00 MOB N WAIT PRE WAIT ON SECURITY AND CPS PERSONNEL TO ARRIVE. 07:00 - 07:30 0.50 MOB P PRE SAFETY MEETING. Review move hazards and procedures. 07:30 - 12:00 4.50 MOB P PRE Move rig to spine road and to Pump 1. 12:00 - 12:30 0.50 MOB N WAIT PRE Wait for buses for plane traffic to pass both directions. 12:30 - 15:00 2.50 MOB P PRE Move rig to DS 15-29A, De-Pressure flowline to 0 psi. WHP= o psi. Perform wellsite pre-inspection with pad operator. Position rig over well. 15:00 - 18:30 3.50 MOB N WAIT PRE WAIT ON WEATHER. Wind to high to raise derrick and wind walls. 18:30 - 00:00 5.50 MOB N WAIT PRE Continue to wait on wind. Current weather 19 gusting to 27 mph. Derrick limit is 20 mph maximum. NOAA weather forcast 10-20 mph, dropping to 5-15 mph tomorrow. Continue to wait. 2/16/2002 00:00 - 06:30 6.50 MOB N WAIT PRE Winds 20 mph, gusting to 30 mph at 00:00. Continue to wait on wind. Green tank moved in and diked. Flowback tank installed, and hard line PT'd to 4000 psi. 06:30 - 18:00 11.50 MOB N WAIT PRE 06:30 Update. Winds still 20 mph, gusting 30 mph. Continue to wait on wind. 18:00 - 00:00 6.00 MOB N WAIT PRE 18:00 Update. Winds 15 mph, gusting 26 mph. Continue to wait on wind. 2/17/2002 00:00 - 06:30 6.50 MOB N WAIT PRE Still waiting on wind. 14 mph gusting to 22 mph. 06:30 - 07:00 0.50 MOB P PRE SAFETY MEETING. Review procedures and hazards of lifting derrick and wind walls. Wind at 12 - 18 mph. 07:00 - 10:00 3.00 MOB P PRE Raise pipe shed roof and derrick. Secure 8 guy wires to derrick. 10:00 -12:00 2.00 MOB P PRE Pick up injector head. MU guide arch. Stab CT. 12:00 - 14:45 2.75 BOPSU P DECOMP ACCEPT RIG AT 12:00 HRS, 02-17-02. Waited on Wind for a total of 50 hrs. [Before and after rig move]. N/U BOPE. Grease tree. Fill rig pits with 2% KCL water. 14:45 - 20:45 6.00 BOPSU P DECOMP Perform initial pressure / function test of BOPE. Witness waived by Lou Grimaldi. Send test report to AOGCC. Chart test. 5 min. low press. and 5 min. high press. All passed ok. Finish BOP test with the exception of the inner reel valve at 20:45. 20:45 - 21:10 0.42 STWHIP P WEXIT Safety meeting prior to begining operations. 21:10 - 21:40 0.50 STWHIP P WEXIT Cut coil, install Baker CTC, Pull test to 35klbs. 21:40 - 22:30 0.83 STWHIP P WEXIT Circulate to fill coil. PT CTC to 3500 psi. PT inner reel valve to 500 psi, 3500 psi. All passed ok. 22:30 - 23:00 0.50 STWHIP P WEXIT Make up BHA #1, window milling BHA. Baker Inteq straight motor, string reamer, Hughes DWM. 23:00 - 23:15 0.25 STWHIP P WEXIT Stab injector on well. 23: 15 - 00:00 0.75 STWHIP P WEXIT RIH with BHA #1. 2/18/2002 00:00 - 02:00 2.00 STWHIP P WEXIT 4500', Continue RIH with BHA #1, to mill window. Weight check at 9000'=34klbs. 02:00 - 04:10 2.17 STWHIP P WEXIT RIH, weight check at 11300'=43klbs. Tag at minimum rate at 11315', reset to pinch point of 11309' (-6' correction). Kick pumps on, free spin = 2.7 bpm, @ 1700 psi CTP. Re tag, begin milling. Looks like cement. Milled to 11312', got motor Printed: 3/4/2002 10:28:06 AM ...-....~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-29A 15-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/14/2002 Rig Release: Rig Number: Spud Date: 6/4/1992 End: 2/18/2002 02:00 - 04: 1 0 2.17 STWHIP P WEXIT work and hard tag. Set depth again to 11309' (additional-1.4' depth correction for a total of -7.4'). Begin milling at 2000 psi weight on bit. 04:10 - 06:00 1.83 STWHIP P WEXIT 11311.6' (2.6' into window) Pump 10 bbl biozan sweep. Continue milling with 1200 # weight on bit. 06:00 - 06:30 0.50 STWHIP P WEXIT 11315.8' (6.8' into window) Pump 15 bbl biozan sweep. Continue milling with 1500 Ibs weight on bit. Bottom of window seen at 11316 ft. Window milled thru 7", 26#, Liner, very easy and quickly. 06:30 - 09:00 2.50 STWHIP P WEXIT Mill 1 0 ft of formation to 11,326 ft. Back ream Window area. Stalled I overpull at 11305 ft. Work pipe free with 20K overpull. Pull up thru tailpipe to ensure clean BHA. RIH. 09:00 - 12:00 3.00 STWHIP P WEXIT Ream window. Ream down at top of whipstock, stall I overpull again. Ream down Swap well to FloPro while reaming window. Ream up I down four times, until window was clean. RIH clean to TD of 11326 ft with no pump. Back ream out with no excess motor work. 3.80" Window is clean. 12:00 - 14:30 2.50 STWHIP P WEXIT POOH with milling BHA. 14:30 - 15:00 0.50 STWHIP P WEXIT Layout milling BHA. Mill worn across face. Mill at 3.77" gauge, string mill at 3.80". 15:00 - 15:30 0.50 STWHIP P PROD1 M/U DS CTC. Pull test. 15:30 - 16:30 1.00 DRILL P PROD1 SAFETY MEETING. Review recent GPB DAFWC's with crew. Review procedure and hazards for Cutting CT and for BHA MU with crew. 16:30 - 18:00 1.50 DRILL P PROD1 Cut off 200 ft CT for fatigue maintenance. M/U CTC. Pull/Press test. M/U MWD BHA #2 with re-run Bit #2 [HYC DS49] and 1.69 deg bend motor. 18:00 - 19:00 1.00 DRILL P PROD1 Tour crew change and safety meeting. Reviewed upcoming operations, and also covered 4 L T A's for YTD. 19:00 - 20:00 1.00 DRILL P PROD1 MU BHA #2, Build section BHA #1. MU injector. 20:00 - 22:10 2.17 DRILL P PROD1 RIH with BHA #2, shallow hole test at 700', MWD and orienter passed ok. 22: 1 0 - 22:45 0.58 DRILL P PROD1 Log tie in pass down from 10860'-10900'. Make -10 correction. 22:45 - 23:35 0.83 DRILL N WAIT PROD1 Wait on directional plan. Original directional plan off depth by 100' MD. New plan sent up by town MWD was 100' long on landing well horizontally from desired. Slope directional engineer redrawing directional plan with consultation from slope and town geo's, and town directional hand. Taking extra time to get it right before starting drilling. Want all relevant people on same page. 23:35 - 23:45 0.17 DRILL P PROD1 Orient around to 10R. 23:45 - 00:00 0.25 DRILL P PROD1 Run thru window slick, with pumps down. Tag at 11328'. PU clean at 37klbs. Kick on pumps free spin=3600 psi at 2.6 bpm. Tf came up at 30R. Get a few more to get 100R TF. 2/19/2002 00:00 - 00:05 0.08 DRILL P PROD1 Orient to 100R TF. 00:05 - 01 :55 1.83 DRILL P PROD1 Begin drilling build section. TF=83R, 2.7/2.7 inlout. 3900 psi CTP (Free spin 3700 psi). 65 fpm. 01 :55 - 02:40 0.75 DRILL P PROD1 11419', TF falling off to the right, and now down to 173R. Orient around to 100R TF. 02:40 - 04:00 1.33 DRILL P PROD1 Resume drilling. 2.6/2.6/3750 psi. 40 fph ROP. 04:00 - 04: 15 0.25 DRILL P PROD1 11477', Wiper trip to shoe. Pull back thru window to ensure Printed: 3/4/2002 10:28:06 AM 1---" /"""-", Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-29A 15-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/14/2002 Rig Release: Rig Number: Spud Date: 6/4/1992 End: 2/19/2002 04:00 - 04:15 0.25 DRill P PROD1 that it is clean. Pulled to 11270'. No problems, drag, or overpulls at the window. Ran back down through the window slick. 04:15 - 04:30 0.25 DRill P PROD1 Orient around to 90R. 04:30 - 05:25 0.92 DRill P PROD1 11477', Resume drilling. 2.7/2.7/3950 psi. TF 90R. 05:25 - 05:35 0.17 DRill P PROD1 11524', orient to 90L to slide for 50'. 05:35 - 06: 15 0.67 DRill P PROD1 Resume drilling at 80l TF. 06:15 - 06:30 0.25 DRill P PROD1 11557', orient back around to 90R. 06:30 - 08:00 1.50 DRill P PROD1 Drilling build, TF = 70R, 2.5/2.5 bpm, 3500 psi, ROP = 80 fph, Incl = 60 deg. Up wt = 38K, Dwn wt = 11 K. Drilled to 11,650 ft. 08:00 - 08:30 0.50 DRill P PROD1 Wiper trip to window. Clean hole. RIH. 08:30 - 10:30 2.00 DRill P PROD1 Drilling build, TF = 80R, 2.6/2.6 bpm, 3500 psi, ROP = 100 fph, Incl = 81 deg. AZ = 67 deg. Drilled to 11,800 ft. 10:30-11:00 0.50 DRill P PROD1 Wiper trip to window. Clean hole. RIH. 11 :00 - 11 :40 0.67 DRill P PROD1 Drilling build, TF = 80R, 2.6 I 2.6 bpm, 3500 psi, ROP = 100 fph, Incl = 78 deg. Drilled to 11,870 ft. Right turn completed. 11 :40 - 12:00 0.33 DRill P PROD1 Orient TF to 1001. 12:00 - 14:45 2.75 DRilL P PROD1 Drilling build, TF = 100l, 2.6/2.6 bpm, 3500 psi, ROP = 10 fph, Incl = 76 deg. Very slow drilling after TF change. Stacking wt. Back reamed 50 ft. Drilled to 11899 ft. 14:45 - 15:30 0.75 DRill PROD1 Drilling build, TF = 100l, 2.6/2.6 bpm, 3500 psi, ROP = 10 fph, Incl = 74 deg. Drilled to 11,930 ft. 15:30-16:10 0.67 DRill P PROD1 Wiper trip to window. Clean hole. RIH. 16:10 - 18:20 2.17 DRill P PROD1 Drilling build, TF = 40l, 2.6/2.6 bpm, 3500 psi, ROP = 10 fph, Incl = 80 deg. Drilling ratty. Drilled to 11,986 ft. 18:20 - 18:35 0.25 DRill P PROD1 Orient TF to 44R. 18:35 - 19:00 0.42 DRill P PROD1 Drill ahead, stacking bad in shale at 75 deg at 8719' TVD. Trying to dig down and out of 13N at anticipated 8733' TVD and into sand 2.5/3500/60R to 11992' 19:00 - 19:25 0.42 DRilL P PROD1 Wiper to window. New mud ready at MI, but no vac trucks available 19:25 - 20:05 0.67 DRill P PROD1 log tie-in up from 11360' 20:05 - 20:30 0.42 DRill P PROD1 Add 14.0', RIH 20:30 - 21 :40 1.17 DRill P PROD1 Tag at 12005'. Drill ahead 2.5/3150/70R stacking 21:40 - 22:10 0.50 DRilL P PROD1 Orient around from 118R at 12029' 22:10 - 23:20 1.17 DRILL P PROD1 Drill ahead 2.5/3200/70R stacking. TF moving around the clock, MWD shorting off at times 23:20 - 23:40 0.33 DRill P PROD1 Orient around from 123R at 12039' (8731' TVD) 23:40 - 00:00 0.33 DRill P PROD1 Drill to 12046' 2/20/2002 00:00 - 00:30 0.50 DRill P PROD1 Drill to 12047' (8732' TVD) 00:30 - 00:50 0.33 DRill N SFAl PROD1 Reboot DS PC for CCA T 00:50 - 01:15 0.42 DRill P PROD1 Attempt to drill and MWD still toggles on/off, TF flops and still stacking. A few vac trucks available. Close enough to land about 8740' TVD 01: 15 - 01 :45 0.50 DRill P PROD1 Wiper to window 01 :45 - 03:45 2.00 DRill P PROD1 POOH to change BHA 03:45 - 05:20 1.58 DRilL P PROD1 Change bit, motor, MWD probe, burst disc sub, bleed sub jet, orientor. Bit was 4-2-1 w/ broken nose cutters from junk Printed: 314/2002 10:28:06 AM ~ -----... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-29A 15-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/14/2002 Rig Release: Rig Number: Spud Date: 6/4/1992 End: 2/20/2002 03:45 - 05:20 1.58 DRILL P PROD1 damage? 05:20 - 07:50 2.50 DRILL P PROD1 RIH w/ BHA #3 (1.04 deg motor) to 11300'. Subtract default 10' correction from CTD & RIH smoothly thru window to btm tagged @ 12051'. Check TF @ 60L. 07:50 - 08:00 0.17 DRILL P PROD1 Orient TF to 30L. Meanwhile start pumping fresh SFFP mud downhole. 08:00 - 09:00 1.00 DRILL P PROD1 Orient & drill to 12091' with 25L TF, 2.6/2.6bpm, 3400/3700psi & 44fph ave ROP. 09:00 - 09:15 0.25 DRILL P PROD1 Orient, drill to 12100' & level off with 45R TF, 2.6/2.6bpm, 3100/3400psi & 45fph ave ROP. 09:15 - 09:30 0.25 DRILL P PROD1 Orient & drill to 12107' with 90R TF, 2.6/2.6bpm, 3100/3400psi & 45fph ave ROP. 09:30 - 11 :00 1.50 DRILL P PROD1 Orient & drill to 12173' with 110R TF, 2.6/2.6bpm, 3300/3600psi & 65fph ave ROP. Lowering angle to +/-88 degs & intercept Zone 1A sand @ 12112' (8738 ftvd). New mud all around. 11 :00 - 11 :20 0.33 DRILL P PROD1 Orient & drill to 12184' with 45R TF, 2.6/2.6bpm, 3400/3600psi & 66fph ave ROP. 11 :20 - 11 :45 0.42 DRILL P PROD1 Orient & drill to 12204' with 60R TF,2.6/2.6bpm, 3400/3600psi & 48fph ave ROP. 11 :45 - 12:00 0.25 DRILL P PROD1 Orient & drill to 12215' with 60R TF, 2.6/2.6bpm, 3400/3600psi & 44fph ave ROP. 12:00 - 12:30 0.50 DRILL P PROD1 Wiper to window 12:30 - 12:40 0.17 DRILL P PROD1 Log & tie-into RA PIP tag (+1.5' correction). 12:40 - 13:00 0.33 DRILL P PROD1 RBIH 13:00 - 13:10 0.17 DRILL P PROD1 Drill to 12225' with 65R TF, 2.6/2.6bpm, 3300/3500psi & 60fph ave ROP. 13:10 - 13:20 0.17 DRILL P PROD1 Orient & drill to 12232' with 70R TF, 2.6/2.6bpm, 3300/3500psi & 42fph ave ROP. 13:20 - 14:10 0.83 DRILL P PROD1 Orient & drill to 12245' with 155R TF, 2.6/2.6bpm, 3300/3500psi & 39fph ave ROP. TF walking orientor to 90R. Suspect possible fault crossing between 12240' & 12245' (8743 ftvd). 14:10 - 14:15 0.08 DRILL P PROD1 Orient & drill to 12250' with 80R TF, 2.6/2.6bpm, 3300/3500psi & 60fph ave ROP. 14:15 - 15:20 1.08 DRILL P PROD1 Orient & drill to 12295' with 100R TF, 2.6/2.6bpm, 3300/3500psi & 42fph ave ROP. Exit zone 1A sand. 15:20 - 15:30 0.17 DRILL P PROD1 Orient TF to 90L. 15:30 - 15:45 0.25 DRILL P PROD1 Drill to 12300' with 75L TF, 2.6/2.6bpm, 3300/3500psi & 20fph ave ROP. 15:45 - 17:00 1.25 DRILL P PROD1 Drill to 12343' with 50L TF, 2.6/2.6bpm, 3400/3700psi & 34fph ave ROP. Meanwhile review forward options with town: aim up for lower zone 1 B sand @ 8715 ftvd or OH sidetrack & target zone 1 B. 17:00 - 17:25 0.42 DRILL P PROD1 Orient & drill to 12356' with HS TF, 2.6/2.6bpm, 3300/3500psi & 36fph ave ROP. Decide to POOH for OH sidetrack wI WS. 17:25 - 18:00 0.58 STKOH C PROD1 POOH BHA#3. 18:00 - 18:15 0.25 STKOH C PROD1 Log & tie-into RA PIP tag (+4' correction). 18:15 - 20:05 1.83 STKOH C PROD1 Continue POOH. Paint EOP flag @ 11000'. 20:05 - 20:45 0.67 STKOH C PROD1 LD drilling BHA 20:45 - 21 :25 0.67 STKOH C PROD1 MU Weatherford 3-1/2" aluminum OH whipstock assy 21 :25 - 00:00 2.58 STKOH C PROD1 RIH w/ BHA #4. Corr -17' at flag. 34.2k RIH thru window w/ sli wt loss. RIH to set depth Printed: 3/4/2002 10:28:06 AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-29A 15-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/14/2002 Rig Release: Rig Number: Spud Date: 6/4/1992 End: 2/21/2002 00:00 - 01 :00 1.00 STKOH C PROD1 Load 1/2" steel ball. Park at set depth 42k, 12.5k. Circ ball to seat with mud 1.8/2650. Press up in stages until shearout at 4200 psi. Set whipstock with top at 11814' (8686' TVD). Stack 5k to verify. PUH 36k 01 :00 - 03:00 2.00 STKOH C PROD1 POOH 03:00 - 03:15 0.25 STKOH C PROD1 LD WS setting tool 03:15 - 03:50 0.58 STKOH C PROD1 MU drilling assy 03:50 - 06:10 2.33 STKOH C PROD1 RIH w/ BHA #5 (1.04 deg motor). Corr -10' at 11000' 06:10 - 06:25 0.25 STKOH C PROD1 Set down at 11311', assume btm of window. Check TF at 139L. Orient to high side. RIH 06:25 - 06:40 0.25 STKOH C PROD1 Log tie-in up from 11355' (-2' correction). 06:40 - 07:30 0.83 STKOH C PROD1 RIH, orient TF to 122L & tag whipstock @ 11824'. 07:30 - 08:15 0.75 STKOH C PROD1 Orient 1 click and resume time drilling from 11824' at 0.1'/3mins, 110L TF, 2.6/2.6bpm, 3400/3450psi. Had couple of stalls. Abort LS kick off. 08:15 - 08:30 0.25 STKOH C PROD1 P/U & orient TF to 66L. 08:30 - 09:10 0.67 STKOH C PROD1 Restart time drilling from 11825' at 0.1 '/3mins, 70L TF, 2.6/2.6bpm, 3400/3450psi. 09:10 - 09:30 0.33 STKOH C PROD1 Continue time drilling from 11826' at 0.1'/1 min, 70L TF, 2.6/2.6bpm, 3400/3450psi. 09:30 - 10:00 0.50 STKOH C PROD1 Commence drilling from 11827' with 75L TF, 2.6/2.6bpm, 3300/3500psi & 84fph ave ROP. Drill to 11869'. Confirm departure with survey @ 11824', Incl = 81.19 degs, Azm = 79.39 degs. 10:00 - 10:20 0.33 STKOH C PROD1 Orient TF to RS. 10:20 - 10:30 0.17 STKOH C PROD1 Orient & drill to 11878' with 115R TF, 2.6/2.6bpm, 3700/3900psi & 54fph ave ROP. 10:30 - 10:40 0.17 STKOH C PROD1 Not dropping incl. Orient 1 click & drill to 11888' with 130R TF, 2.6/2.6bpm, 3600/3900psi & 60fph ave ROP. 10:40-11:10 0.50 STKOH C PROD1 Orient & drill to 11915' with 150R TF, 2.6/2.6bpm, 3500/3800psi & 54fph ave ROP. 11:10 -11:15 0.08 STKOH C PROD1 Orient & drill to 11920' with 120R TF, 2.6/2.6bpm, 3500/3800psi & 60fph ave ROP. 11:15 -11:25 0.17 STKOH C PROD1 Orient & drill to 11932' with 120R TF, 2.6/2.6bpm, 3400/3700psi & 72fph ave ROP. 11 :25 - 11 :45 0.33 STKOH C PROD1 Orient TF to 40R. 11:45 -11:55 0.17 STKOH C PROD1 Orient & drill to 11945' with 30R TF, 2.6/2.6bpm, 3500/3900psi & 78fph ave ROP. 11 :55 - 12:05 0.17 STKOH C PROD1 Orient & drill to 11955' with 50R TF, 2.6/2.6bpm, 3500/3900psi & 60fph ave ROP. 12:05 - 12:30 0.42 STKOH C PROD1 Orient & drill to 12000' with 100R TF, 2.6/2.6bpm, 3500/3900psi & 108fph ave ROP. 12:30 - 13:40 1.17 STKOH C PROD1 Wiper to the window. Observe restriction @ OH whipstock. Orient TF to 70L. Ream & backream whipstock area from 11825' to 11845' with slight motor work to clean any cuttings bed. Finally backreamed pass whipstock. 13:40 - 14:20 0.67 STKOH C PROD1 Continue wiper trip to window. RBIH smoothly thru whipstock without bobbles. PUH pass WS & RSIH - no restrictions. Continue RIH to btm. 14:20 - 14:30 0.17 STKOH C PROD1 Orient TF to 65R. 14:30 - 14:50 0.33 STKOH C PROD1 Orient & drill to 12025' with 65R TF, 2.6/2.6bpm, 3300/3500psi & 75fph ave ROP. 14:50 - 15:00 0.17 STKOH C PROD1 Orient TF to LS. Printed: 314/2002 10:28:06 AM ì ~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-29A 15-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/14/2002 Rig Release: Rig Number: Spud Date: 6/4/1992 End: 2/21/2002 15:00 - 15:20 0.33 STKOH C PROD1 Orient & drill to 12058' with 140L TF, 2.6/2.6bpm, 3300/3500psi & 99fph ave ROP. 15:20 - 15:30 0.17 STKOH C PROD1 Orient & drill to 12067' with 115L TF, 2.6/2.6bpm, 3300/3500psi & 54fph ave ROP. 15:30 - 15:45 0.25 STKOH C PROD1 Orient & drill to 12092' with 90l TF, 2.6/2.6bpm, 3400/3700psi & 100fph ave ROP. 15:45 -16:45 1.00 STKOH C PROD1 Orient & drill to 12155' with 70L TF, 2.6/2.6bpm, 3500/3800psi & 63fph ave ROP. 16:45 - 17:10 0.42 STKOH C PROD1 Wiper to the window - no bobbles @ OH whipstock. 17:10 - 17:25 0.25 STKOH C PROD1 Log & tie-into RA PIP tag (+6' correction). 17:25 - 17:50 0.42 STKOH C PROD1 RBIH smoothly to btm. No bobbles @ OH whipstock. 17:50 - 18:10 0.33 STKOH C PROD1 Orient & drill to 12177' with 75L TF, 2.6/2.6bpm, 3500/3900psi & 53fph ave ROP. 18:10 - 19:30 1.33 STKOH C PROD1 Drill to 12220' (8717' TVD) 2.6/3500n7L slowly building angle to follow dip and find target sand 19:30 - 20:35 1.08 STKOH C PROD1 Drill 12220-267' in a shale spudding ahead at 94 deg 20:35 - 21 :05 0.50 STKOH C PROD1 Wiper to window 21:05 - 21:15 0.17 STKOH C PROD1 log tie-in up from 11350'. Add 3.0' 21:15 - 22:00 0.75 STKOH C PROD1 RIH. Orient from 24R to 70L to go by OH WS 22:00 - 22:20 0.33 STKOH C PROD1 Orient around from 90R to drill 22:20 - 22:50 0.50 STKOH C PROD1 Drill ahead from 12267' and having better wt transfer 2.6/3450/10L at 93 deg 22:50 - 23:00 0.17 STKOH C PROD1 Orient to right at 12300' 23:00 - 00:00 1.00 STKOH C PROD1 Drilling 2.5/3350175R at 96 deg climbing thru 14N. Drill to 12340' 2/22/2002 00:00 - 00:25 0.42 DRILL P PROD1 200' wiper from 12340' to check shales. 1 0-15k overpulls 12200-260' 00:25 - 01 :50 1.42 DRilL P PROD1 Stacking and stalling from 12340' to 12366'. Severaloverpulls 01 :50 - 02:20 0.50 DRILL P PROD1 Wiper to window, shales fairly clean 02:20 - 02:30 0.17 DRILL P PROD1 log tie-in up from 11350'. Add 6.0' 02:30 - 03:05 0.58 DRILL P PROD1 RIH. Set down in shale at 12250', work thru. RIH to TD 03:05 - 04:30 1.42 DRILL P PROD1 Drill from 12369' 2.6/3550/86R at 96 deg looking for 1 B sand. Start new mud 04:30 - 05:40 1.17 DRILL P PROD1 Orient to level out at 12400' (8700' TVD) after penetration picked up after getting out of shale. Drill 60-100'/hr 2.6/3500/120R at 97 deg 05:40 - 06:20 0.67 DRILL P PROD1 Wiper to window from 12480' (8688' TVD). Shales clean 06:20 - 06:35 0.25 DRILL P PROD1 Log tie-in up from 11350'. Add 2'. 06:35 - 07: 1 0 0.58 DRILL P PROD1 RBIH. Set down in shale at 12250'. Work thru. Continue RIH to TD 07: 1 0 - 07:25 0.25 DRILL P PROD1 Orient & drill to 12500' with 45R TF, 2.6/2.6bpm, 3400/3600psi & 80fph ave ROP. 07:25 - 07:45 0.33 DRILL P PROD1 Orient & drill to 12538' with 70R TF, 2.6/2.6bpm, 3400/3600psi & 114fph ave ROP. 07:45 - 07:50 0.08 DRILL P PROD1 Orient & drill to 12545' with 100R TF, 2.6/2.6bpm, 3400/3600psi & 84fph ave ROP. Aiming for 92 degs incl. 07:50 - 08:20 0.50 DRilL P PROD1 Orient & drill to 12600' with 150R TF, 2.6/2.6bpm, 3400/3600psi & 11 Of ph ave ROP. 08:20 - 08:25 0.08 DRilL P PROD1 Orient to LS. 08:25 - 08:30 0.08 DRilL P PROD1 Orient & drill to 12610' with 130L TF, 2.6/2.6bpm, 3400/3600psi & 120fph ave ROP. 08:30 - 08:55 0.42 DRilL P PROD1 Orient & drill to 12634' with 85L TF, 2.6/2.6bpm, 3400/3600psi & 120fph ave ROP. Printed: 3/4/2002 10:28:06 AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-29A 15-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/14/2002 Rig Release: Rig Number: Spud Date: 6/4/1992 End: 2/22/2002 08:55 - 10:50 1.92 DRILL N SFAL PROD1 Start wiper trip to the window. At 12485', observe the CT inlet swivel valve fail with the housing stripping off from the shaft (IR#: 2002-IR-171353). Leaked 1 gal Flo-Pro mud onto the pad. Shut down operations. Held safety meeting and investigations. Cleaned-up leak & changed-out swivel valve. Meanwhile PUH occasionally to 12205' to prevent stuck pipe/freezing up. 10:50 - 12:30 1.67 DRILL N STUC PROD1 Establish circulation. P/test reel svivel valve to 5k - OK. Attempt to pull CT. Pulling heavy with 30k Olpull. Suspect differential sticking with no up/down movement. Work pipe & manage to move pipe downwards. Work shales down to 12275'. 12:30 -13:05 0.58 DRILL P PROD1 Continue wiper trip to window. 13:05 - 13:20 0.25 DRILL P PROD1 Log & tie-into RA PIP tag (+9' correction). 13:20 - 14:10 0.83 DRILL P PROD1 RBIH. Set down @ 12285', 12410'. Orient to drilled TFs & work thru. Continue RIH to TD. 14:10 - 14:25 0.25 DRILL P PROD1 Orient to LS. 14:25 - 14:50 0.42 DRILL P PROD1 Orient & drill to 12683' with 100L TF, 2.6/2.6bpm, 3400/3600psi & 120fph ave ROP. 14:50 - 15:10 0.33 DRILL P PROD1 Orient around to 130L. 15:10 - 16:00 0.83 DRILL P PROD1 Orient & drill to 12738' with 100-130L TF, 2.6/2.6bpm, 3400/3600psi & 100fph ave ROP. 16:00 - 17:15 1.25 DRILL P PROD1 Wiper to window. RBIH smothly to btm with slight bobble @ 12250' . 17:15 -17:35 0.33 DRILL P PROD1 Orient & drill to 12768' with 80-100L TF, 2.6/2.6bpm, 3400/3600psi & 100fph ave ROP. 17:35-18:15 0.67 DRILL P PROD1 Orient & drill to 12808' with 60L TF, 2.6/2.6bpm, 3500/3800psi & 100fph ave ROP. 18:15 -18:30 0.25 DRILL P PROD1 Orient TF to LS. 18:30 - 20:05 1.58 DRILL P PROD1 Drilling 50-90'/hr 2.5/3400/83L. Td well @ 12898'. 20:05 - 20:55 0.83 DRILL P PROD1 Wiper trip to window. Hole in good condition. 20:55 - 21:10 0.25 DRILL P PROD1 Log & tie-into RA PIP tag (+8' correction). 21:10-22:05 0.92 DRILL P PROD1 RBIH & tag TD @ 12899'. Drill additional l' to 12900' (8770.99 .., ftvd) -final TD. 22:05 - 23:00 0.92 DRILL P PROD1 POOH to window. Hole clean. 23:00 - 00:00 1.00 DRILL P PROD1 POOH for liner circulating @ max rate. Paint EOP flag @ 8300'. 2/23/2002 00:00 - 01 :30 1.50 DRILL P PROD1 Continue POOH drilling BHA#5 circulating @ max rate. 01 :30 - 02:30 1.00 DRILL P PROD1 PJSM. LD drilling BHA. 02:30 - 03:15 0.75 CASE P COMP RU to run liner. 03: 15 - 03:30 0.25 CASE P COMP Safety mtg re: liner 03:30 - 06:00 2.50 CASE P COMP MU 47 jts 2-7/8" 6.16# L-80 STL w/ float equipment & turbos, 18 jts 3-3/16" 6.2# L-80 TC11, 5 jts 3-1/2" 9.2# L-80 STL. 06:00 - 06:20 0.33 CASE P COMP Crew change. PJSM with day crew on liner M/U & RIH. 06:20 - 09:30 3.17 CASE P COMP Continue M/U 2-7/8" x 3-3/16" x 3-1/2" Liner. 09:30 - 10:40 1.17 CASE P COMP MU "XN" Nipple, Baker Deployment Sub & CTLRT. Install Baker CTC. Pull test to 35k & pressure test to 3500 psi - OK. 10:40 - 12:45 2.08 CASE P COMP RIH with liner on CT. See flag at 10608'. Correct to 10585'. PIU 40k. RIH smoothly to TD tagged @ 12880' CTD. P/U @ 42k & retag TD @ same depth. Set down 10k Ibs down on CTLRT. 12:45 - 13:40 0.92 CASE P COMP Load 5/8" steel ball & circ to seat with mud @ 2.8/2.8bpm, 3600psi. Slow down @ 40 bbls away. Ball on seat @ 50.9bbls. Printed: 31412002 10:28:06 AM ~\ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-29A 15-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/14/2002 Rig Release: Rig Number: Spud Date: 6/4/1992 End: 2/23/2002 12:45 - 13:40 0.92 CASE P COMP Ramp up to 4500psi & release CTLRT. P/U @ 40k & confirm release. 13:40 - 16:00 2.33 CASE P COMP Displace well to 2% KCI at 3.1/3.1 bpm & 2250psi. Meanwhile RlU Dowell cementers. 16:00 - 16:15 0.25 CASE P COMP PJSM with all personnel concerning cementing operations. 16:15 - 18:30 2.25 CASE P COMP Batch mix 27 bbls 15.8ppg cmt with additives. Cmt to wt @ 17:00 hrs. Flush/PT lines to 4k. Pumped 20 bbls cmt slurry @ 2.4/2.3 bpm & 2130 psi. Close inner reel valve & clean lines. Load/launch C1WP & confirm launch. Chase with KCL @ 2.5/2.4bpm & 1250psi. C1WP engage LWP at 59.4 bbls away. Shear plug with 3050psi. Continue displacing LWP @ 3.0/3.0 bpm, 3350 psi & bump @ 73.5 bbls away. 18 bbls cmt behind Inr. Floats held. Pressure up to 1000 psi & sting out of liner. CIP at 18:30 hrs. 18:30 - 20:30 2.00 CASE P COMP PUH, start jetting and reel swivel began leaking. POOH filling from BS 20:30 - 21 :00 0.50 CASE P COMP LD CTLRT 21 :00 - 00:00 3.00 CASE P COMP Weekly BOPE test. Witnessed by AOGCC Replace reel swivel 2/24/2002 00:00 - 02:30 2.50 CEMT P COMP Finish weekly BOPE test 02:30 - 02:40 0.17 CEMT P COMP Safety mtg re: PU workstring/PT 02:40 - 03:00 0.33 CEMT P COMP PT swivel assy to 4500 psi 03:00 - 05:45 2.75 CEMT P COMP MU 2.31" D331 DSM, 2-1/8" motor, MHA MU 73 CSH singles 05:45 - 06:15 0.50 CEMT P COMP RU to PT inner reel valve. 06:15 - 06:45 0.50 CEMT P COMP Crew change. PJSM with day crew. 06:45 - 07:30 0.75 CEMT P COMP PT inner reel valve to 4000 psi. 07:30 - 09:15 1.75 CEMT P COMP M/U injector & RIH with cleanout BHA#6 to above TOL. Wt check = 35k up. 09:15 - 10:00 0.75 CEMT P COMP Wash down clean with regular biozan sweeps from TOL to PBTD @ 1.6bpm, 1300psi. Tag PBTD @ 12825' CTD (tally depth = 12835'). 10:00 - 12:45 2.75 CEMT P COMP POOH clean out assy circulating @ 1.6bpm, 1750psi. RIB injector. Drop 5/8" ball to open-up circ sub. 12:45 - 13:00 0.25 CEMT P COMP PJSM on RIB CSH. 13:00 - 14:45 1.75 CEMT P COMP Stand back CSH. Install tree cap. 14:45 - 16:15 1.50 CEMT P COMP Line up to & test liner lap. Compressive strength of cement @ 13:00 was @ 2200psi. IIA 159 psi @ onset of test. Staged up in 500 psi intervals, monitoring I/A. PT @ 2000 psi, leaked 500 psi in 30 mins, no change in IA pressure thoughout test. Review forward plan with town & decide to run KB Inr top Pkr after perforating. 16:15 -16:30 0.25 EVAL P COMP PJSM on P/U 1 1/4" CHS tbg & CNL tools. 16:30 - 18:50 2.33 EVAL P COMP P/U CNL BHA #7 (2305.23') with 73 jts of 1-1/4" CSH tbg. P/U injector. 18:50 - 20:20 1.50 EVAL P COMP RIH wI CT 20:20 - 21 :45 1.42 EVAL P COMP Log down from 10450' at 30'/min 21 :45 - 23:05 1.33 EVAL P COMP Tag PBD at 12825' CTD. PUH 46k logging 30'/min while leaving 15 bbls fresh high LSRV Flo Pro mud in liner 23:05 - 00:00 0.92 EVAL P COMP POOH from 10450' 2/25/2002 00:00 - 00:25 0.42 EVAL P COMP Fin POOH w/ CNL 00:25 - 01 :55 1.50 EVAL P COMP Stand back CSH, LD 3 singles 01:55 - 02:10 0.25 EVAL P COMP Safety mtg re: Source/perf guns Printed: 3/412002 10:28:06 AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-29A 15-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/14/2002 Rig Release: Rig Number: Spud Date: 6/4/1992 End: 2/25/2002 02:10·02:30 0.33 EVAL P COMP LD CNL tool 02:30 - 03:10 0.67 PERF P COMP Load perf guns in pipeshed. RU to run guns. RU safety jt Download CNL 03:10 - 04:30 1.33 PERF P COMP MU 27 2" SWS perf guns and blanks wI E-Fire system 04:30 - 05:50 1.33 PERF P COMP MU 35 CSH doubles 05:50 - 07:50 2.00 PERF P COMP RIH wI CT. Wt check @ 10500 = 40k. Tag PBTD @ 12823'. Pull to P/U wt (50k) & correct depth to 12833'. 07:50 - 08:30 0.67 PERF P COMP PUH & postion for bottom shot @ 12790'. Line up for e-fire system pumping from Driller's console. Set-up seismic detector to THS for shot detection & function test it OK. Shut-in choke. Allow wellbore to stabilize for 3 minutes. 08:30 - 09:00 0.50 PERF N DPRB COMP Presure-up wellhead to 500 psi & hold for 1 min. Increase pressure to 700 psi & hold for 1 min. Dump pressure to 0 psi & wait for 2 mins. Crank-up to 800 psi & wait for 2 mins. Bleed off to 0 psi and wait for 5 mins. Observe no e-firing. Circulate coil & line-up for pumping via the Ops cab. 09:00 - 09:40 0.67 PERF N DPRB COMP Allow wellbore to stabilize for 3 minutes and repeat e-fire pumping sequence. Observe no e-firing. Circulate coil & review e-fire calculations & sequence - nothing amiss. Decide to try again. 09:40 - 10:30 0.83 PERF P COMP Repeat pumping sequence for e-fire twice, pumping via the CT in last trial. Observe more pressure losses, looks like well is drinking. Suspect e-fire head had fired without indications. Function test seismic detector - not working. Perf interval: 12390' - 12430' & 12480' - 12790'. 10:30 - 12:30 2.00 PERF N STUC COMP Attempt to PUH - pulling heavy up to 70k. No pipe movement - suspect btms guns are sanded up. Work pipe with 10 cycles to max 90k pull (weak pt is e-fire hd @ 33k). Put 800psi on the back side, dump same & pull - no luck. Attempt injectivity test for 15 mins - 0.1 bpm @ 1500psi. Call for pill & crude. 12:30 - 13:00 0.50 PERF P COMP Maintain 90k on CT during injectivity test. Open up choke to dump CT pressure & observe pipe come free. PUH to 12350' (above perf zone) with 52k. 13:00 - 13:15 0.25 PERF P COMP RBIH to 12575'. 13:15 - 14:05 0.83 PERF P COMP Pump 10 bbl perf pill and load 5/8" steel ball. Blow ball in to CT and circ down while positioning guns for bottom shot at 12120'. Chase ball to seat slowing to 1 bpm @ 51 bbls. Observe pressure increase after 59 bbls. No good indication of ball seating after 70bbls. 14:05 - 14:25 0.33 PERF N DPRB COMP Pressure up to 3800psi & observe no firing. SID pumps & ramp-up again to 4300psi - no firing. Try again up to 4300psi - getting returns while pumping. Attempt to pull, no pipe movement - pipe is stuck. 14:25 - 15:00 0.58 PERF N DPRB COMP Close choke, maintain 90k on CT & inject @ 1700psi. Open up choke to dump CT pressure & observe pipe come free. PUH to 12350' (above perf zone) with 52k. 15:00 - 15:20 0.33 PERF N DPRB COMP RBIH to 12625'. Meanwhile prepare fresh biozan pill for launching another 5/8" steel ball. 15:20 - 16:00 0.67 PERF N DPRB COMP Launch another 5/8" steel ball. Position guns for bottom shot at 12120'. Pump 10 bbls biozan pill behind ball & chase ball. No indication of ball seating after 70bbls. Ramp up to 4700psi twice. Still no indications of ball seating or gun firing. 16:00 - 18:45 2.75 PERF P COMP POOH to inspect perf gun assy. Meanwhile inspect injector Printed; 314/2002 10;28;06 AM /"1'""-. I I ! ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-29A 15-29A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/14/2002 Rig Release: Rig Number: Spud Date: 6/4/1992 End: 2/25/2002 16:00 - 18:45 2.75 PERF P COMP chains - OK. 18:45 - 19:00 0.25 PERF P COMP Safety mtg re: new crewlworkstring 19:00-21:10 2.17 PERF P COMP Standback 27 doubles, LD 16 singles 21:10 - 21:20 0.17 PERF P COMP Safety mtg re: LD perf guns 21 :20 - 00:00 2.67 PERF P COMP LD perf guns. Recovered both balls, no debris. Top set of guns fired. Guns below E-Fire head also fired. Load out guns Perforated 11960-12120', 12390-430', 12480-790' wI SWS 2" Powerjets at 4 spf Phz 1 2/26/2002 00:00 - 03:00 3.00 PERF P COMP RIH wI CSH doubles. POOH LDDP 03:00 - 04: 15 1.25 RIGD P COMP RIH wI side jet nozzle. Jet stack, RIH to 2000' and POOH freeze protecting with MeOH. SI swab (24) 04:15 - 05:00 0.75 RIGD N COMP Circ, WO DS N2 05:00 - 05: 1 0 0.17 RIGD P COMP Safety mtg re: N2 05:10 - 05:20 0.17 RIGD P COMP PT N2 @ 3500 psi 05:20 - 06:00 0.67 RIGD P COMP Blow down CT wI N2 and bleed off 06:00 - 08:00 2.00 RIGD P COMP PJSM. Clean out pits & tanks. Remove injector gooseneck & unstab coil. 08:00 - 10:00 2.00 RIGD P COMP C/O packoff & grease injector. Store injector in stabbing box. Continue cleaning out pits. 10:00 - 12:30 2.50 RIGD P COMP PJSM for ND. Nipple down BOP. Nipple up & pressure test tree cap. Rig Released time worked out to be @ 10:00 on 2/26/2002. Printed: 3/4/2002 10:28:06 AM ~ .-~\ 15-29A Prudhoe Bay Field / Prudhoe Bay Pool 50-029-22259-01 202-016 Rig Accept: Rig Spud: Rig Release: Drillin Ri : 02/17/02 02/19/02 02126/02 Nordic 1 POST RIG WORK 03/04/02 MIRU CTU # 5. REBUILD PACK - OFF. RIU NITTROGEN PUMP TRUCK. RIH PUMPING @ 750 SCF/D WI WELL IN TEST SEPARATOR. PARK @ 2100',4800',5507'. DECREASE N2 TO 500 SCF/D. PARK @ 6820' & 8381', WELL CLEANING UP IN TEST SEPARATOR. SO N2 AND MONITOR FOR 1 HR. WELL APPEARS TO BE FLOWING GOOD @ 4000 BOPD. POH WI CT 03/05/02 MIRU CTU # 5. REBUILD PACK - OFF. RIU NITTROGEN PUMP TRUCK. RIH PUMPING @ 750 SCFID WI WELL IN TEST SEPARATOR. PARK @ 2100', 4800', 5507'. DECREASE N2 TO 500 SCF/D. PARK @ 6820' & 8381'. WELL CLEANING UP IN TEST SEPARATOR. SO N2 AND MONITOR FOR 1 HR. WELL APPEARS TO BE FLOWING GOOD @ 4000 BOPD. POH WI CT ~ .~. ~ Dd-OIl.(J 27 -Feb-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 15-29APB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 2,205.05' MD 2,221.55' MD (if applicable) 3,091.01 ' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) f~E(':;E'VED t·1 ~" ;¡ ! 0¡:'IQ? '. ....~.... u .. LIJ \ I~ \: \ t.~ ...._ Ali$8 Oil & Gas Cons. Commission Anchorage DEFINITIVE North Slope Alaska BPXA PBU_EOA DS 15, Slot 15-29 ) 15-29A PB1 Job No. AKMW22031, Surveyed: 20 February, 2002 SURVEY REPORT 27 February, 2002 Your Ref: API 500292225970 Surface Coordinates: 5961332.39 N, 675926.78 E (70017' 59.8551" N, 148034' 30.2975" W) Kelly Bushing: 66.20ft above Mean Sea Level ) !!SpE!r"".....y-!!iLJI! SERVices Survey Ref: svy11117 A Halliburton Company e Sperry-Sun Drilling Services Survey Report for 15-29A PB1 Your Ref: API 500292225970 Job No. AKMW22031, Surveyed: 20 February, 2002 BPXA PBU_EOA DS 15 Vertical Section Dogleg Rate (0/100ft) Coordinates Eastlngs (ft) Globa Northlngs (ft) Coordinates Eastlngs (ft) Local Northlngs (ft) Vertical Depth (ft) Sub-Sea Depth (ft) A2im. North Slope Alaska ne! Measured Depth ft) Comment ) Tie On Point MWD Magnetic Window Point 2202.05 2221.55 2230.08 2242.25 2268.50 1.053 19.720 18.906 21.344 675041.97 E 675027.54 E 675023.13 E 675021.27 E 675025.35 E 5968082.09 N 5968155.18 N 5968183.32 N 5968214.50 N 5968265.41 N 726.54 W 739.25 W 743.01 W 744.13 W 738.86 W 6768.57 N 6841.97 N 6870.21 N 6901.42 N 6952.23 N 8544.72 8570.41 8579.48 8589.28 8610.22 8478.52 8504.21 8513.28 8523.08 8544.02 350.580 349.770 355.030 0.900 11.200 71.130 70.810 73.920 71.280 64.310 11227.20 11306.00 11335.91 11368.66 11423.96 2291.02 2312.69 2344.82 2375.11 2399.49 16.585 23.889 10.185 21.580 28.556 675033.33 E 675043.83 E 675060.21 E 675076.65 E 675092.60 E 5968300.05 N 5968327.68 N 5968367.01 N 5968402.07 N 5968424.80 N 730.08 W 718.93 W 701.64 W 684.38 W 667.90 W 6986.67 N 7014.04 N 7052.98 N 7087.64 N 7110.00 N 8628.73 8645.68 8670.32 8691.73 8705.43 8562.53 8579.48 8604.12 8625.53 8639.23 17.520 26.840 21.070 31.760 40.900 60.730 59.770 60.200 62.140 65.480 11464.06 11498.16 11547.39 11591.69 11622.69 2425.64 2455.46 2482.55 2515.16 2549.13 16.383 20.878 21.023 22.561 23.546 675111.14 E 675133.43 E 675154.98 E 675182.55 E 675213.29 E 5968446.28 N 5968468.46 N 5968486.01 N 5968503.81 N 5968518.28 N 648.86 W 626.06 W 604.11 W 576.13 W 545.06 W 7131.03 N 7152.69 N 7169.73 N 7186.88 N 7200.63 N 8717.06 8727.41 8734.72 8741.69 8747.49 8650.86 8661.21 8668.52 8675.49 8681.29 43.360 49.520 54.790 62.170 70.080 69.960 73.650 76.900 79.190 81.4 70 11653.36 11686.49 11715.24 11748.81 11783.31 ) 2579.37 2606.43 2632.85 2662.92 2692.09 23.042 21.684 16.699 26.274 23.163 675242.44 E 675269.99 E 675298.10 E 675329.62 E 675358.31 E 5968527.56 N 5968532.91 N 5968535.67 N 5968539.79 N 5968547.58 N 515.70 W 488.02 W 459.86 W 428.26 W 399.39 W 7209.22 N 7213.92 N 7216.03 N 7219.40 N 7226.52 N 8752.06 8756.50 8761.65 8768.77 8776.65 8685.86 8690.30 8695.45 8702.57 8710.45 77.290 83.440 88.010 79.750 72.540 81.560 80.510 78.840 75.940 74.440 11814.26 11842.69 11871.41 11904.01 11934.79 2746.06 2786.69 2817.60 2853.97 2887.88 13.888 8.106 12.216 13.088 26.088 675408.31 E 675445.17 E 675473.52 E 675507.09 E 675539.72 E 5968568.21 N 5968585.35 N 5968597.76 N 5968611.90 N 5968622.45 N 348.92 W 311.67 W 283.04 W 249.14 W 216.28 W 7245.98 N 7262.25 N 7273.99 N 7287.34 N 7297.12 N 8790.05 8797.88 8802.06 8804.27 8805.48 8723.85 8731.68 8735.86 8738.07 8739.28 65.340 67.450 67.970 69.030 77.820 77.780 80.420 84.200 88.860 87.100 11990.56 12031.96 12063.19 12099.70 12134.04 2919.63 295171 2987.59 3015.74 3048.40 7.279 19.703 14.497 9.216 6.111 675571.55 E 675604.64 E 675643.33 E 675674.75 E 675712.02 E 5968629.69 N 5968635.17 N 5968637.89 N 5968637.89 N 5968636.22 N 184.28 W 151.08 W 112.33 W 80.93 W 43.71 W 7303.62 N 7308.32 N 7310.14 N 7309.39 N 7306.86 N 8807.69 8809.42 8809.48 8809.19 8809.07 8741.49 8743.22 8743.28 8742.99 8742.87 79.220 84.670 89.950 92.760 95.040 85.170 88.940 90.880 90.180 90.180 12166.77 12200.37 12239.17 12270.59 12307.90 DriflQuest 2.00.08.005 Page 2 of 4 27 February, 2002 - 9:41 (I Sperry-Sun Drilling Services Survey Report for 15-29A PS1 Your Ref: API 500292225970 Job No. AKMW22031, Surveyed: 20 February, 2002 BPXA PBU EOA DS 15 Comment Vertical Section Dogleg Rate (0/100ft) Coordinates Eastings (ft) Globa Northlngs (ft) Coordinates Eastlngs (ft) Local Northlngs (ft) Vertical Depth (ft) Sub-Sea Depth (ft) North Slope Alaska Measured Depth (ft) 3070.23 3091.01 6.290 0.000 675736.81 E 675760.07 E 5968635.34 N 5968635.20 N Azim. ncl ) Projected Survey 18.94 W 4.31 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 7305.40 N 7304.71 N 8808.50 8807.50 8742.30 8741.30 91.700 91.700 92.460 92.460 12332.72 12356.00 _. Magnetic Declination at Surface is 26.475° (27-Feb-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 65.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12356.00ft. The Bottom Hole Displacement is 7304.71ft.. in the Direction of 0.034° (True). ) Comment nates Eastings (ft) d r on Coo Northings (ft) Stat TVD (ft) Comments Measured Depth (ft) Dríl/Quest 2.00.08.005 Tie On Point Window Point Projected Survey Page 3 of4 726.54 W 739.25 W 4.31 E 6768.57 N 6841.97 N 7304.71 N 8544.72 8570.41 8807.50 9:41 11227.20 11306.00 12356.00 27 February, 2002 '8 Sperry-Sun Drilling Services Survey Report for 15-29A PS1 Your Ref: API 500292225970 Job No. AKMW22031, Surveyed: 20 February, 2002 BPXA PBU EOA OS 15 North Slope Alaska ) Survey Tool Description Survey tool program for 15-29A PS1 To Measured Vertical Depth Depth (ft) (ft) Fro m Measured Vertical Depth Depth (ft) (ft) ) 2.00.08.005 DrillQuest (15-29) Page 4 of 4 AK-1 BP _HG - BP High Accuracy Gyro MWD Magnetic (15-29A PB1) 8544.72 8807.50 11227.20 12356.00 0.00 8544.72 9:41 0.00 11227.20 27 February, 2002 '-- r'--. ~ Ö} Òd-O 1<0 27 -Feb·02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 15-29A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 2,579.37' MD 2,588.74' MD (if applicable) 3,623.57' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) t,n D n! 0no? , ¡:..\;.. ...... ~.( L", _ Alaska Oil & Gas Cons. Commission AnOOoragê ) DEFINITIVE North Slope Alaska BPXA PBU_EOA DS 15, Slot 15-29 15-29A Job No. AKMW22031, Surveyed: 22 February, 2002 '-...' SURVEY REPORT 27 February, 2002 Your Ref: API 500292225901 Surface Coordinates: 5961332.39 N, 675926.78 E (70017' 59.8551" N, Kelly Bushing: 66.20ft above Mean Sea Level ) Survey Ref: svy11118 W) 148034' 30.2975" I) Sperry-Sun Drilling Services Survey Report for 15-29A Your Ref: API 500292225901 Job No. AKMW22031, Surveyed: 22 February, 2002 BPXA PBU_EOA DS 15 Comment Vertica Section Dogleg Rate (0/100ft) Coordinates Eastings (ft) Globai Northlngs (ft) Coordinates Eastlngs (ft) Local Northlngs (ft) Vertical Depth (ft) Sub-Sea Depth (ft) Azim. North Slope Alaska Incl Measured Depth (ft) ) Tie On Point Window Point 2579.37 2588.74 2625.05 2659.55 2691.30 21.653 29.019 8.500 14.201 675242.44 E 675251.82 E 675286.99 E 675319.37 E 675350.00 E 5968527.56 N 5968529.73 N 5968540.52 N 5968552.90 N 5968562.60 N 515.70 W 506.27 W 470.85 W 438.20 W 407.35 W 7209.22 N 7211.17 N 7221.14 N 7232.75 N 7241.73 N 8752.06 8753.52 8758.03 8761.63 8766.00 8685.86 8687.32 8691.83 8695.43 8699.80 77.290 79.390 69.200 71.660 75.880 81.560 81 .190 84.900 83.230 81.300 11814.26 11824.00 11861.12 11895.97 11928.40 2724.92 2753.52 2787.92 2819.46 2850.13 15.881 25.999 12.191 15.856 13.121 675383.54 E 675413.51 E 675451.42 E 675486.06 E 675518.50 E 5968570.61 N 5968574.53 N 5968575.51 N 5968576.62 N 5968580.21 N 373.62 W 343.57 W 305.65 W 270.99 W 238.48 W 7248.95 N 7252.17 N 7252.26 N 7252.56 N 7255.39 N 8770.12 8772.64 8774.91 8777.15 8779.81 8703.92 8706.44 8708.71 8710.95 8713.61 79.930 87.840 91.880 87.130 82.910 85.080 85.430 87.710 84.900 85.780 11963.15 11993.50 12031.50 12066.25 12099.00 2880.18 2929.93 2966.80 2985.85 3018.47 18.087 12.962 16.923 15.145 18.442 675549.09 E 675597.44 E 675631.55 E 675648.58 E 675676.60 E 5968586.15 N 5968600.64 N 5968614.82 N 5968623.39 N 5968640.29 N 207.75 W 159.09 W 124.65 W 107.43 W 79.01 W 7260.61 N 7273.97 N 7287.35 N 7295.51 N 7311.76 N 8781.44 8782.26 8781.32 8780.21 8778.37 8715.24 8716.06 8715.12 8714.01 8712.17 77.820 71.490 66.040 63.230 57.250 88.240 89.910 92.990 93.690 92.720 12130.22 12180.72 12217.70 12236.79 12269.59 ) 3048.05 3076.02 3106.68 3141.13 3171.49 12.001 5.598 21.378 16.042 15.442 675701.02 E 675723.82 E 675749.66 E 675780.34 E 675808.61 E 5968657.65 N 5968674.61 N 5968691.53 N 5968707.21 N 5968718.55 N 54.20 W 31.00W 4.77W 26.26 E 54.79 E 7328.54 N 7344.96 N 7361.27 N 7376.22 N 7386.90 N 8776.30 8773.33 8769.49 8765.05 8761.02 8710.10 8707.13 8703.29 8698.85 8694.82 54.610 54.790 61.470 67.090 71.850 95.180 96.770 97.380 97.290 97.790 12299.62 12328.20 12359.34 12394.09 12424.82 3202.27 3231.91 3267.13 3298.31 3330.25 22.502 6.205 19.555 10.428 21.131 675838.68 E 675868.62 E 675905.37 E 675939.31 E 675975.57 E 5968727.16 N 5968733.49 N 5968738.66 N 5968740.37 N 5968739.13 N 85.06 E 115.14 E 151.99E 185.96 E 222.18 E 7394.81 N 7400.44 N 7404.74 N 7405.65 N 7403.57 N 8757.11 8754.09 8750.09 8746.03 8743.52 8690.91 8687.89 8683.89 8679.83 8677.32 78.870 79.930 86.780 90.120 96.450 96.420 94.830 97.4 70 96.150 91.760 12456.37 12487.12 12524.47 12558.70 12595.09 3358.73 3402.60 3440.12 3480.79 3528.33 15.183 15.549 11.938 18.014 18.178 676008.09 E 676055.64 E 676094.64 E 676135.19 E 676180.00 E 5968737.63 N 5968740.47 N 5968746.24 N 5968756.00 N 5968772.64 N 254.66 E 302.26 E 341.39 E 382.16 E 427.35 E 7401.30 N 7403.03 N 7407.89 N 7416.69 N 7432.29 N 8742.67 8740.91 8740.15 8741.24 8740.58 8676.47 8674.71 8673.95 8675.04 8674.38 91.530 84.320 81.510 74.120 67.800 91.230 92.990 89.210 87.800 93.780 12627.67 12675.37 12714.82 12756.57 12804.42 DrillQuest 2.00.08.005 Page 2 0'4 9:46 27 February, 2002 I) Sperry-Sun Drilling Services Survey Report for 15·29A Your Ref: API 500292225901 Job No. AKMW22031, Surveyed: 22 February, 2002 BPXA PBU _EOA DS 15 Comment Vertical Section Dogleg Rate (0/100ft) Coordinates Eastlngs (ft) Globa Northlngs (ft) Coordinates Eastings (ft) Local Northlngs (ft) Vertical Depth (ft) Sub-Sea Depth (ft) North Slope Alaska Measured Depth (ft) ) 3570.08 3597.91 3623.57 14.357 16.365 0.000 676217.50 E 676241.48 E 676263.18 E 5968791.01 N 5968805.28 N 5968819.29 N 465.26 E 489.58 E 511.59 E 7449.77 N 7463.47 N 7476.98 N 8738.98 8738.25 8737.18 8672.78 8672.05 8670.98 Azim. 62.700 58.480 58.480 Incl 90.610 92.370 92.370 12846.22 12874.15 12900.00 Projected Survey Directions and coordinates are relative to True North Northings and Eastings are relative to Well Reference All data is in Feet (US) unless otherwise stated Vertical depths are relative to Well Reference Magnetic Declination at Surface is 26.475° (27-Feb-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 65.000° (True) Based upon Minimum Curvature type calculations, at a Measured Depth of 12900.00ft. The Bottom Hole Displacement is 7494.46ft.. in the Direction of 3.914° (True). ) Comment nates Eastings (ft) on Coord Northings (ft) Stat TVD (ft) Comments Measured Depth (ft) Tie On Point Window Poin Projected Survey 515.70 W 506.27 W 511.59 E 7209.22 N 7211.17 N 7476.98 N 8752.06 8753.52 8737.18 11814.26 11824.00 12900.00 DrillQuest 2.00.08.005 Page 30f4 27 February, 2002 . 9:46 e Sperry-Sun Drilling Servi6~~ Survey Report for 15·29A Your Ref: API 500292225901 Job No. AKMW22031, Surveyed: 22 February, 2002 . BPXA PBU_EOA DS 15 North Slope Alaska ) Survey Tool Description Survey tool program for 15-29A To Measured Vertical Depth Depth (ft) (ft) Fro m Measured Vertical Depth Depth (ft) (ft) \ ) DrillQuest 2.00.08.005 5-29) (1 Page 4 0'4 AK-1 BP _HG - BP High Accuracy Gyro MWD Magnetic (15-29A PB1) 8544.72 8737.18 11227.20 12900.00 0.00 8544.72 9:46 0.00 11227.20 27 February, 2002 '- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2- RECEIVED 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered t,t~R 2 9 2002 AlaskaOiI & Gas COOs.Commission Anchor8fJe Received Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-571 ATTN: Sherrie f \ E-25 /'1< 1-/:<- ( 22112 MCNL 02121/02 1 1 1 F-26A 1'1~-1 S?9 22113 MCNL 02121/02 1 1 1 D.S. 15-29A ~O;:: -O/v, 22107 MCNL 02125/02 I 1 1 Well Job # Log Description Date Blueline Sepia Color Prints CD Field: Prudhoe Bay State ot Alaska Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite Anchorage, AK 99501 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-57 ATTN: Sherrie 00 SC~IIn~I'" Company: NO. 924 03/26/02 c. ~1r~1rŒ (ID~ ~~~~[[~ ~..'-' y. . it" TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alistair Sherwood CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 15-29A BP Exploration (Alaska), Inc. Permit No: 202-016 Sur Loc: 148' SNL, 22' EWL, Sec. 22, TUN, R14E, UM Btmhole Loc. 2124' NSL, 626' EWL, Sec. 10, T11N, R14E, UM Dear Mr. Sherwood: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 15-29A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, G; ~~ c~echsli Taylor Chair BY ORDER OF THE COMMISSION DATED this]Jh day of February, 2002 jjc/Enclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. /-...., STATE OF ALASKA ,--\.., ALASKA 0._ AND GAS CONSERVATION COMMI~ )N PERMIT TO DRILL 20 AAC 25.005 VJgA 1-/1 (0 'L ..& ;> l,-\ JM It ;;L.IsJó~ 1a. Type of work 0 Drill 181 Redrill 1b. Type of well ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 148' SNL, 22' EWL, SEC. 22, T11N, R14E, UM At top of productive interval 1001' NSL, 647' WEL, SEC. 09, T11N, R14E, UM At total depth 2124' NSL, 626' EWL, Sec. 10, T11N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028306,2124' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 11455' MD Maximum Hole Angle 18. Casin~ Program Specifications I Grade ou lin L-80 ST-L 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 13196 feet 8743 feet 12112 feet 8799 feet Length Size 110' 20" 4124' 13-3/8" 10726' 9-5/8" 1822' 7" 1089' 4-1/2" D Exploratory D tratigraphic Test 181 Development Oil D Service 0 Development Gas Single Zon~ 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 67' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ':lzt~·4' ADL 028303-š) 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) Prudhoe Bay Unit 8. Well Number 15-29A Number 2S100302630-277 9. Approximate spud date 02/12/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13075' MD / 8675' TVDss 17. Anticipated pressure {see 20 MC 25.035 (e) (2)} 95 0 Maximum surface 2295 psig, At total depth (TVD) 88001 / 3550 psig Setting Depth Plugs (measured) Alaska OU & Gas Cons. Commission Anchorage Set 4-1/2" CIBP (03/99) Junk (measured) Cemented MD TVD 2000# Coldset II 3088 cu ft CS II, 505 cu ft Class 'G' 2825 cu ft Class 'G' 472 cu ft Class 'GI Packer Set 110' 4160' 10760' 12330' 12107' - 13196' 110' 3508' 8338' 8803' 8798' - 8741' Perforation depth: measured 12022' - 12062'; Slotted Liner: 12317' - 13172' true vertical 8788' - 8793'; Slotted Liner: 8803' - 8744' II Filing Fee D Property Plat II Drilling Fluid Program D Time vs Depth Plot Contact Engineer Name/Number: Alistair Sherwood, 564-4378 21. I ~erebY certify that the fore i ~s tru and corr~t to the be~t of my kn~~ledge . Signed Alistair Sherwood ( {/rf3lJr/~ Title CT Drilling Engineer 20. Attachments III BOP Sketch D Diverter Sketch III Drilling Program D Refraction Analysis D Seabed Report 0 20 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubble, 564-4628 API Number 50- 029-22259-01 Samples Required 0 Yes lifNo Hydrogen Sulfide Measures ~es 0 No Required Working Pressure for BOPE D2K 03K 04K 05K 010K Other: tec;t BL'?rE {o 3SDO est. wC;A- Original Signed By 12-01-8 ammy ec S I Permit Number I /... 2.þ :;;2--0 fe-' Conditions of Approval: by order of the commission Rev. Date ~ .r-... BPX 15-29a Sidetrack Summa!'\' of Operations: A CTD"sidetrack of production well 15-29 will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. ,/ Phase 1: Integrity test tubing, (MIT -tbg). Caliper & drift the tubing and liner. Set a mechanical whipstock in the liner. P&A open perforations below the whipstock with cement Planned for February 5, 2002 · Set a thru tubing 4%" x 7" mechanical whipstock at 11 ,306')1D (8,571' TVDss). · P&A existing perforations below the whipstock with 35 bbls of 15.8ppg cement. Pha~ 2: Drill and Complete CTD sidetrack: Planned for February 12, 2002 2%" coil will be used to drill a-1800 ft, 3%" open hole side~ck, (as per attached plan) from a window cut in 7" liner. The sidetrack will be completed with 2,450 ft of solid, cemented & perforated, 3-3/16" x 2-7/8" liner. Mud Program: · Phase 1: Seawater ./ · Phase 2: Seawater and Flo-Pro (8.6 - 8.7 ppg) Disposal: / · No annular injection on this well. · All drilling and completion fluids and all other CI~s II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. ,// Casing Program: / /' · 3-3/16", l-80, liner will be run from 10,620'md (TOl, 8,264' TVDss) to approximately 11,4~md, (100' outside of the window). 2-7/8" solid liner will complete the open"þole section to TD at 13,075' md. The completion will be cemented in place with approximately 33 bbls (annular volume +40% excess in OH) of 15.8 ppg class G cement. Well Control: · BOP diagram is attached. .,/ · Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. · The annular preventer will be tested to 400 psi and 2,200 psi. Directional · See attached directional plan. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · Real time MWD & Gamma Ray logs will be run while drilling the open hole section. · A memory GR/CCL will be run inside liner prior to perforating. H~~ds / · H2S is not a hazard on Drillsite 15. 15-29 was tested in Feb 01 and found to have a 3ppm H2S conc. · The wells directional trajectory has been designed to avoid fault crossings. The risk of low circulation is therefore low. · There is a known leak in the 9-5/8" casing at 7,405'md, which allowed Cretaceous waters to flow to Z1 via GlV #3 - GlV's have now been dummied oft. Consequently, hard scale, (BaS04) has been deposited in the tbg between 8163' to 10,644'. / Reservoir Pressure Reservoir pressure is estimat:,9 to be 3,550 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,295 psi. TREE : WB...LHEAD= ACTUATOR: KB. B...EV : BF. ElEV : KOP:::: Max Angle :::: Datum MD :::: Datum TVD== 4-1/16" CrN FMC OTIS 67.8' 750' 96 @ 12838' 12325' 8800' SS 13-3/8" CSG, 68#, L-80 BTC, ID:::: 12.415" Minimum ID = 3.271" @ 12107' 7" x 4-1/2" TIW SS HORZ PKR I TOPOF 7" LNR I 4-1/2"TBG, 12.6#, L-80 IBT-M, 0.0152 bpf, ID:::: 3.958" 9-5/8" CSG, 47#, L-80 BTC, ID:::: 8.681" I TOP OF 4-1/2" LNR I ~. 15-29 S.4=q'Y NOTES: W8...L EXCEEDS 70 DEGREES @ l' . AND GOES HORIZONTAL @ 12,200'. FISH- DMYVLV FROM STA #3 LOST IN HOLE· NOT FOUND IN CATCHER - POSSIBLY IN STA #4 OR 5. 2078' -i 4-1/2" CAMCO BAL-O SSSV NIP, ID:::: 3.812" I . GAS LIFT MANDRElS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 3704 3178 45 DMY T-2 01/15/02 2 6042 4918 42 DMY T-2 01/15/02 3 8163 6480 43 DMY T-2 01/15/02 4 9998 7864 41 DMY T-2 01/15/02 5 10152 7976 42 DMY T-2 01/15/02 10644' ÆRFORA TION SUMMARY REF LOG: MWD GR ON 5/30/92 ANGLEATTOPÆRF: 80 @ 12022' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8 6 12022-12062 C 04/28/01 3-3/8 SL 12317-13172 C 04/28/01 14-112" LNR, 12.6#, L-80 FL4S, 0.0152 bpf, ID:::: 3.958" I ITOPOF 4-1/2" LNR- SLOTTED I 17" LNR, 26#, L-80 1J4S, 0.0383 bpf, ID:::: 6.276" 4-1/2" LNR-SLOTTED,12.2#, L-80 FL4S, .0152 bpf, ID:::: 3.958" 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID:::: 3.958" lTO DATE REV BY COMMENTS 06/04/92 ORIGINAL COMPLETION 07/16/96 LAST WORKOVER 02/14/01 SIS-MD FINAL 05/01/01 CHITP CORRECTIONS 05/18/01 SW/KA PULL IBP 13172' DATE REV BY COMMENTS 01/15/02 MI-Vtlh GLVS 9-5/8" X 7" BAKER 'H' LNR TOP PKR W/TIEBACK SLEEVE 7" X 4-1/2" BAKER 'S-3' PKR, ID:::: 3.875" I 4-112" HES 'X' NIPPLE, ID:::: 3.813" I 10644' -1 4-1/2" TUBING TAIL WLEG 10643' H TTL B...MD - LOGGED 04/28/01 12107' 12112' 7" X 4-1/2" TIW SS HORIZONTAL PKR W/9.26' SLICK STICK, ID :::: 3.271" 4-1/2" CIPB 4.5" CAST IRON BRIDGE PLUG - 03/05/99 12116' -1 4-1/2" PORTED JOINT (37.63') PRUDHOE BAY UNIT WElL: 15-29 ÆRMIT No: 92-035 API No: 50-029-22259-00 Sec. 9 T11 N R14E, 1197.36 FB... 2088.1 FNL BP Exploration (Alaska) TREE = WELLHEAD= ACTUA TOR= KB. ELE\! = BF.ELËV = KOP= Max Angle = Datum MD = Datum "TVD= 4-1/16" CrN FMC OTIS 67.8' /--.... 15-29A S¥9."Y NOTES: WELL EXCEEDS 70 DEGREES @ 1· ¡' AND GOES HORIZONTAL @ 12,200'. FISH- DMY VL V FROM STA #3 LOST IN HOLE - NOT FOUND IN CATCHER - POSSIBLY IN STA #4 OR 5. 4-1/2" CAMeO BAL-O SSSV NIP, ID = 3.812" GAS LIFT MANDRELS "TVD DE\! TYPE MAN 3178 45 HES-TB 4918 42 HES-TB 6480 43 HES- TB 7864 41 HES- TB 7976 42 HES- TB Proposed CTD sidetrack 750' 96 @ 12838' 12325' 8800' SS . 2078' -1 STA MD 1 3704 2 6042 3 8163 4 9998 5 10152 10515' 10589' 13-3/8" CSG, 68#, L-80 BTC, ID = 12.415" Minimum ID = 3,271" @ 12107' 7" x 4-1/2" TIW 55 HORZ PKR TOPOF 7" LNR I I Top of 3-3/16" Liner H 10620' I 4-1/2" TBG, 12.6#, L-80 IBT-M, 0.0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" Mill Window off mechanical whipstock I TOPOF 4-1/2" LNR I PERFORA TION SUMMARY REF LOG: I\.o1WD GR ON 5/30/92 ANGLE AT TOP PERF: 80 @ 12022' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8 6 12022-12062 C 04/28/01 3-3/8 SL 12317-13172 C 04/28/01 12112' LATCH T-2 T-2 T-2 T-2 T-2 9-5/8" X 7" BAKER 'H' LNR TOP PKR W/TIEBACK SLEEVE 7" X 4-1/2" BAKER 'S-3' PKR, ID = 3.875" I 4-1/2" HES 'X' NIPPLE, ID = 3.813" 4-112" TUBING TAIL WLEG TTL ELMD - LOGGED 04/28/01 12-7/8" Liner, Cemented & Perf'd I 13075' 7" X 4-1/2" TrN SS HORIZONTAL PKR W/9.26' SLICK STICK, ID = 3.271" 4-1/2" CIPB 4.5" CAST IRON BRIDGE PlUG - 03/05/99 14-112" LNR, 12.6#, L-80 FL4S, 0.0152 bpf, ID = 3.958" H 12317' TOPOF 4-1/2" LNR- SLOTTED H 12317' 17" LNR, 26#, L-80 U4S, 0.0383 bpf, ID = 6.276" ...f.¡.'~:.~< 12116' -i 4-112" PORTED JOINT (37.63') 4-112" LNR-SLOTTED,12.2#, L-80 FL4S, .0152 bpf, ID = 3.958" 13172' 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I TD DATE REV BY COMMENTS DATE REV BY COMMENTS 06/04/92 ORIGINAL COMPLETION 05/18/01 WSW/KA PULL IBP 07116/96 LAST WORKOVER 12/15/00 SIS-lsl CONVERTED TO CANVAS 02/14/01 SIS-MD FINAL 05/01/01 CHIT? CORRECTIONS PRUDHOE BAY UNIT WELL: 15-29 PERMIT No: 92-035 API No: 50-029-22259-00 Sec. 9T11N R14E, 1197.36 FEL2088.1 FNL BP Exploration (Alaska) SIZE 1-1/2" 1-112" 1-1/2" 1-112" 1-112" /""--.- ..-... ... ...... lNTEQ ObP BP Amoco Baker Hughes INTEQ Planning Report , i Company: BP Amoco I Reid: Prudhoe Bay I Site: PB DS 15 I Well: 15-29 L~~~pa~~~ 15-29~___________ ~---_._~_._------------_._---_..._---_.- -, Date: 1/1512002 Time: 16:06:50 Page: i Co-ordlnate(NE) Reference: Well: 15-29, True North I Vertical (TVD) Reference: System:Mean Sea level ' Seetion(VS) Reference: Well (O.ooN,O.ooE.65.00Azi) I Survey Calculation Method: ~inimum CUlVat~~__n_-,:c-==-~~:_(~ra~le~ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 I Geo Datum: NAD27 (Clarke 1866) [_~~.n.!~~~!~__~~ Le,,-~__._________ ___________ Map Zone: Alaska, Zone 4 Coordinate System: Well Centre ¡ ___~eo_~~ç~e_tic_~ollel:__BG~~20~!__ _______________________J ,.._._-----_.-._--_.--_._~_.__._----_.._-- ---._------- - __... _____.__.___.___._u_._______._. ._____·__.u.'.___. ----------- _ __________nn_ mn_____ ---------- _ ----------1 I I PB DS 15 TR-11-14 UNITED STATES: North Slope ¡ Site Position: Northing: 5958837.36 ft Latitude: 70 17 35.236 N ¡ From: Map Easting: 676296.98 ft Longitude: 148 34 21.213 W ! Position Uncertainty: 0.00 ft North Reference: True I i Ground Level: 0.00 ft Grid Convergence: 1.34 deg I '--___.___________________~_._._______._._.____________._._..________________~_________,_.______.~_~____.___.___.----.J ¡-"'Well: ---15-29--------------------------------Sï~t-Nam;~~---29------------------------ i 15-29 i i Well Position: +N/-S 2503.68 ft Northing: 5961332.88 ft Latitude: 70 17 59.860 N i +EI-W -311.35 ft Easting: 675927.02 ft Longitude: 148 34 30.290 W I I Position Uncertainty: 0.00 ft J1 L_______.~.n_.______~__________._.____~___.____._~._.._.______~_________._._______. _____.__.____________._ ¡---WeIlPath: Plan#6 15-29A----------------------------D;illedF;;.;:------:¡-5=29--- ------------------ ---------1 j 500292225901 Tie-on Depth: 11455.00 ft I i Current Datum: 43:297/11/199600:00 Height 66.20 ft Above System Datum: Mean Sea Level i : Magnetic Data: 1/9/2002 Declination: 26.52 deg ! i Field Strength: 57507 nT Mag Dip Angle: 80.81 deg ¡ Vertical Section: Depth From (fVD) +N/-S +E/-W Direction I : ft ft ft deg : l-------------------------------------------------.------------- ----------------------------------------------------, ¡ 0.00 0.00 0.00 65.00 i Site: ~ _ ___._ _________._ .___~._._.________.__.._'"~_____._.~___. ."__..____.._~._._..______.________.___.____..____~_.____...___________._... .__..~_._._____~_._.____...__.._n______.___ __.___l r-~------------- i Plan: Plan #6 : Identical to Lamar's Plan #6 : Principal: Yes _._-._------_._---_.__._------_._------~---_._~------~--------.-------.----------.------.------.------, Date Composed: Version: Tied-to: 1/9/2002 1 From: Definitive Path .~----_._-~----_._---_._----------------- ._----------._----------_.~_._------------_.- _._-----_.._---_._------~_." Targets i-- I Name Description TVD ! ft f------·-------------------- I 15-29A T6.1 8730.00 I ¡ 15-29A T6.2 8710.00 i -~---_._---~------_._------ <- Longitude "->-1 Map Map <-- Latitude--> +N/-S +EI-W Northing Easting Deg Min Sec Deg Min See ! ft -- ft ft ft I 7286.49 -379.27 5968608.02 675377.29 70 1911.522 N 148 34 41.357 W ! 7350.36 -74.67 5968679.01 675680.30 70 19 12.150 N 148 34 32.469 W 7426.78 292.25 5968763.99 676045.30 70 19 12.902 N 148 34 21.762 W 7555.60 600.38 5968899.98 676350.31 70 19 14.168 N 148 34 12.770 W 15-29A T6.3 15-29A T6.4 8690.00 8675.00 -- --~.._--- ---.-------------.-------- ---- -_._-~----------_..._._--- -----.... -. - - ----------.-------..---..------ ._._ __..____..__._n_._.__.__________ . Annotation !-- ~D ~ -----~-------l !--_._--------_._------------_.~._-_._--------------_..._-_._--~_._---_._---~-----------~ : 11410.20 8539.06 TIP ! 11455.00 8554.44 KOP ¡ 11465.00 8557.75 1 , 11505.00 8568.05 2 11865.00 8704.41 3 12001.33 8732.42 4 12151.33 8726.38 5 12351.33 8709.41 6 . 12576.33 8695.02 7 : 12751.33 8689.57 8 12851.33 8686.54 9 13075.00 8674.93 TD u_ ..._ _____.__.__".____._______.. ._..____._._____.. _ . .__.~__.__._.__n~___________.___ .~__________.___ ,..___ .___~_. ... _._..~_.____._.._ __..._._______ ___u __.__._.. _..___._._"._'._.._ _n_ ObP ~. , -..... BP Amoco Baker Hughes INTEQ Planning Report -tIC INTRQ , Company: BP Amoco Field: Prudhoe Bay Site: PB DS 15 Well: 15-29 W,:ll?a~b:__ ~Ia~~~_~~þ,____ _._u m___ __________.__m__._~ ¡ Date: 1/15/2002 Time: 16:06:50 Page: 2 Co-ordlnate(NE) Reference: Well: 15-29, True North Vertkal (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,65.00Azi) . _~~!:,,-.!y_~~~~.!.a~~.!!.. ~!!'~_~:. __._~~~~.u~_<:'~~~.u!!______~'!.:_ _~~~!__. ___J Plan Section Information ___..__________.________~_______~__.__.___._ _..._.._._.._"..______._.________.__ ___._.~ __u_..._ __~______._~____~____..___.____________~._____~~_____.._____-----, I MD Inel Azlm TVD +N/-S +E/-W DLS Build Turn TFO Target ; , .,__~_. ___, ~~m ______d~~_ ,.__ __ft. _' _ .__ ___ ~___ ... _. _ __.~_________~e~~~~_~_eg/1~_~~/_~Oft ___ de!!..________________________..J : 11410.20 70.08 350.73 8539.06 6938.73 -756.02 0.00 0.00 0.00 0.00 I ! 11455.00 69.76 350.83 8554.44 6980.27 -762.76 0.74 -0.71 0.22 163.66 : 11465.00 71.50 351.88 8557.75 6989.59 ·764.18 20.00 ~7.35 10.54 30.00 11505.00 78.69 359.08 8568.05 7028.07 -767.18 25.00 17.99 17.98 45.00 11865.00 66.49 94.07 8704.41 7237.87 -561.16 25.00 -3.39 26.39 114.00 12001.33 90.00 68.65 8732.42 7258.88 -431.47 25.00 17.24 -18.65 310.00 12151.33 94.59 86.07 8726.38 7291.58 -285.84 12.00 3.06 11.62 75.00 12351.33 95.00 61.99 8709.41 7346.00 -95.65 12.00 0.21 -12.04 272.00 12576.33 92.19 88.90 8695.02 7401.83 119.69 12.00 -1.25 11.96 95.00 12751.33 91.33 67.91 8689.57 7436.81 290.07 12.00 -0.49 -12.00 268.00 12851.33 92.13 79.88 8686.54 7464.48 385.92 12.00 0.80 11.98 86.00 13075.00 93.71 53.05 8674.92 7552.81 588.86 12.00 0.70 -12.00 274.00 Survey rm--M:D-·-I;;~i-----~i~-----sSTVD--NIS----EiW----·--M~pN------M;pE -DLS------ÿS-yro------£ool--¡ ¡ ft deg deg ft ft ft ft ft deg/100ft ft deg J t-----~-:.--_·-d .---~--_ -----.-----______.___.__._...________ _~_______________~____.._.~~-.:-.-...~___'___~_"_____._________________, 11410.20 70.08 350.73 8539.06 6938.73 -756.02 5968251.56 675008.81 0.00 2247.25 0.00 TIP i 11425.00 69.97 350.76 8544.11 6952.46 -758.25 5968265.24 675006.26 0.74 2251.03 163.66 MWD 11450.00 69.80 350.82 8552.71 6975.63 -762.01 5968288.31 675001.96 0.74 2257.41 163.65 MWD 11455.00 69.76 350.83 8554.44 6980.27 -762.76 5968292.93 675001.10 0.74 2258.69 163.63 KOP 11465.00 71.50 351.88 8557.75 6989.59 -764.18 5968302.22 674999.46 20.02 2261.35 29.83 1 11475.00 11500.00 11505.00 11525.00 11550.00 11575.00 11600.00 11625.00 11650.00 11675.00 11700.00 11725.00 11750.00 11775.00 11795.37 11800.00 11825.00 1 '830.05 11850.00 11865.00 11875.00 11879.74 11900.00 11925.00 11950.00 11975.00 12000.00 12001.33 12025.00 12050.00 12075.00 12100.00 12125.00 12150.00 73.27 77.78 78.69 76.69 74.33 72.12 70.11 68.33 66.80 65.54 64.58 63.95 63.64 63.67 63.94 64.04 64.73 64.91 65.74 66.49 68.11 68.89 72.27 76.54 80.90 85.32 89.76 90.00 90.73 91.51 92.28 93.04 93.80 94.55 353.73 358.20 359.08 3.77 9.75 15.85 22.11 28.52 35.07 41.77 48.58 55.48 62.44 69.42 75.08 76.37 83.26 84.64 90.05 94.07 92.00 91.04 87.04 82.31 77.74 73.28 68.88 68.65 71.39 74.29 77.19 80.09 83.00 85.91 8560.78 8567.03 8568.05 8572.32 8578.58 8585.80 8593.89 8602.77 8612.32 8622.43 8632.98 8643.85 8654.90 8666.00 8675.00 8677.03 8687.85 8690.00 8698.33 8704.41 8708.26 8710.00 8716.74 8723.46 8728.35 8731.35 8732.42 8732.42 8732.27 8731.78 8730.96 8729.79 8728.30 8726.48 6999.05 7023.18 7028.07 7047.60 7071.63 7094.95 7117.31 7138.43 7158.06 7175.96 7191.94 7205.78 7217.34 7226.47 7232.04 7233.06 7237.04 7237.52 7238.36 7237.87 7237.38 7237.26 7237.59 7239.83 7244.09 7250.30 7258.39 7258.88 7266.96 7274.34 7280.49 7285.41 7289.08 7291.49 -765.37 -767.06 -767.18 -766.69 -763.85 -758.56 -750.88 -740.90 -728.74 -714.54 -698.48 -680.75 -661.54 -641.11 -623.71 -619.68 -597.51 -592.96 -574.86 -561.16 -551.95 -547.54 -528.44 -504.48 -480.35 -456.33 -432.71 -431.47 -409.23 -385.35 ·361.14 -336.66 -311.98 -287.16 . ._-"-----.- -- -----------"- -" --- 5968311.64 5968335.73 5968340.61 5968360.15 5968384.23 5968407.67 5968430.20 5968451.55 5968471.46 5968489.69 5968506.03 5968520.29 5968532.29 5968541.89 5968547.87 5968548.99 5968553.49 5968554.07 5968555.33 5968555.16 5968554.89 5968554.88 5968555.65 5968558.45 5968563.27 5968570.04 5968578.69 5968579.20 5968587.81 5968595.74 5968602.46 5968607.95 5968612.19 5968615.18 674998.05 674995.80 674995.56 674995.59 674997.87 675002.61 675009.77 675019.25 675030.95 675044.72 675060.40 675077.81 675096.73 675116.95 675134.21 675138.22 675160.29 675164.82 675182.89 675196.60 675205.83 675210.23 675229.32 675253.22 675277.24 675301.11 675324.52 675325.76 675347.80 675371.50 675395.56 675419.92 675444.50 675469.25 25.00 25.00 25.04 24.99 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.04 25.00 25.00 25.00 25.00 25.00 25.00 24.84 11.98 12.00 12.00 12.00 12.00 12.00 ---- ---.~.. - --------- .--" -.--..--- .----. 2264.27 2272.93 2274.89 2283.58 2296.31 2310.97 2327.38 2345.35 2364.66 2385.10 2406.40 2428.33 2450.62 2473.00 2491.12 2495.21 2516.98 2521.31 2538.06 2550.27 2558.42 2562.36 2579.81 2602.47 2626.14 2650.53 2675.36 2676.69 2700.26 2725.02 2749.57 2773.83 2797.75 2821.26 45.15 MWD 44.44 MWD 43.38 2 114.01 MWD 113.00 MWD 111.50 MWD 109.74 MWD 107.71 MWD 105.44 MWD 102.93 MWD 100.22 MWD 97.35 MWD 94.35 MWD 91.27 MWD 88.17 15-29A 85.67 MWD 85.11 MWD 82.13 15-29A 81.54 MWD 79.35 3 310.05 MWD 310.80 15-29A 311.15 MWD 312.48 MWD 313.75 MWD 314.65 MWD 315.18 MWD 315.90 4 74.98 MWD 75.02 MWD 75.07 MWD 75.17 MWD 75.31 MWD 75.48 MWD ObP Company: Field: Site: Well: Wellpatb: BP Amoco Prudhoe Bay PB DS 15 15-29 Plan#6 15-29A ./""'-., , -~ BP Amoco Baker Hughes INTEQ Planning Report ... ..... INTEQ Date: 1/1512002 Time: 16:06:50 Page: 3 Co-ordinate(NE) Reference: Well: 15-29. True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,65.00Azi) ___u_u_u_____.____u__Su~~~_~!'~_l1Ition~etb~:___~ini~':'~uc;urv~tu~.____._~~:~~~___" . .-.------.---.. --"'~--'--'------'-.- .. ---------_.-"--. Survey ,- '__"_'__U ..·_____._o··.u_ _.__...u..u__._._______.u.·uu___· uu___n_ ·____...______u___u_________._____uu_u____.____uu___________I i MD Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO. Tool · .... _~ __ ...__ d~_ un _ _d_eg.__.~_m_ __~u________~_______n_~_____u____~_____~~/~~____.!t_ ______deg _ --------1 12151.33 94.59 86.07 8726.38 7291.58 -285.84 5968615.30 675470.57 12.07 2822.50 74.78 5 i 12175.00 12200.00 12225.00 12250.00 12275.00 12300.00 12325.00 12350.00 12351.33 12375.00 12400.00 12425.00 12450.00 12475.00 12500.00 12525.00 12550.00 12575.00 12576.33 12600.00 12625.00 12650.00 12675.00 12700.00 12725.00 12750.00 12751.33 12775.00 12800.00 12825.00 12850.00 12851.33 12875.00 12900.00 12925.00 12950.00 12975.00 13000.00 13025.00 13050.00 94.68 94.77 94.84 94.90 94.95 94.98 95.00 95.00 95.00 94.75 94.47 94.18 93.87 93.56 93.23 92.90 92.56 92.21 92.19 92.09 91.98 91.86 91.74 91.61 91.48 91.34 91.33 91.53 91.73 91.93 92.12 92.13 92.33 92.53 92.72 92.91 93.09 93.26 93.42 93.57 13075.00 93.71 83.22 80.21 77.20 74.19 71.18 68.17 65.16 62.15 61.99 64.83 67.82 70.82 73.81 76.80 79.79 82.77 85.76 88.74 88.90 86.06 83.06 80.06 77.06 74.06 71.06 68.07 67.91 70.74 73.73 76.73 79.72 79.88 77.05 74.05 71.06 68.06 65.06 62.06 59.06 56.06 8724.46 8722.40 8720.31 8718.19 8716.04 8713.88 8711.70 8709.52 8709.41 8707.39 8705.39 8703.50 8701.75 8700.12 8698.64 8697.30 8696.11 8695.07 8695.02 8694.14 8693.25 8692.41 8691.62 8690.89 8690.22 8689.61 8689.57 8688.98 8688.27 8687.47 8686.59 8686.54 8685.62 8684.56 8683.41 8682.18 8680.87 8679.49 8678.04 8676.51 53.05 8674.93 7293.78 7297.37 7302.25 7308.40 7315.81 7324.46 7334.32 7345.37 7346.00 7356.55 7366.56 7375.36 7382.93 7389.26 7394.32 7398.11 7400.60 7401.80 7401.83 7402.87 7405.24 7408.91 7413.86 7420.09 7427.58 7436.31 7436.81 7445.16 7452.78 7459.15 7464.25 7464.48 7469.21 7475.44 7482.93 7491.65 7501.58 7512.69 7524.96 7538.34 7552.81 -262.35 -237.70 -213.27 -189.14 -165.36 -142.Q1 -119.14 -96.83 -95.65 -74.57 -51.75 -28.43 -4.67 19.46 43.89 68.56 93.41 118.35 119.69 143.31 168.18 192.89 217.38 241.58 265.42 288.83 290.07 312.20 336.00 360.16 384.61 385.92 409.09 433.28 457.10 480.49 503.40 525.75 547.48 568.53 5968618.05 5968622.22 5968627.66 5968634.38 5968642.34 5968651.54 5968661.93 5968673.50 5968674.16 5968685.20 5968695.73 5968705.08 5968713.21 5968720.10 5968725.73 5968730.09 5968733.17 5968734.95 5968735.01 5968736.60 5968739.55 5968743.80 5968749.32 5968756.12 5968764.16 5968773.43 5968773.96 5968782.83 5968791.01 5968797.94 5968803.61 5968803.87 5968809.14 5968815.94 5968823.98 5968833.24 5968843.71 5968855.34 5968868.11 5968881.98 675494.00 675518.56 675542.86 675566.85 675590.44 675613.59 675636.21 675658.26 675659.42 675680.25 675702.83 675725.93 675749.50 675773.48 675797.78 675822.36 675847.14 675872.05 675873.38 675896.97 675921.78 675946.39 675970.76 675994.80 676018.46 676041.66 676042.89 676064.82 676088.43 676112.43 676136.76 676138.06 676161.11 676185.14 676208.78 676231.96 676254.63 676276.71 676298.14 676318.88 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 11.89 11.99 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.19 12.00 12.00 12.00 12.00 12.00 12.00 12.00 11.73 11.98 12.00 12.00 12.00 11.67 11.98 12.00 12.00 12.00 12.00 12.00 12.00 12.00 588.86 5968896.92 676338.86 12.00 _ __.__._~___._.._.__._______M_.__..__ ...n··_._____......_________..__.. 2844.71 2868.57 2892.77 2917.25 2941.93 2966.75 2991.64 3016.53 3017.87 3041.43 3066.34 3091.20 3115.93 3140.47 3164.75 3188.71 3212.29 3235.40 3236.62 3258.47 3282.01 3305.96 3330.25 3354.81 3379.58 3404.49 3405.82 3429.41 3454.20 3478.79 3503.11 3504.39 3527.39 3551.94 3576.70 3601.58 3626.54 3651.49 3676.37 3701.11 271.95 MWD 271.77 MWD 271.52 MWD 271.27 MWD 271.01 MWD 270.76 MWD 270.50 MWD 270.23 MWD 268.75 6 94.94 MWD 95.24 MWD 95.48 MWD 95.71 MWD 95.92 MWD 96.11 MWD 96.29 MWD 96.45 MWD 96.59 MWD 98.22 7 268.09 MWD 267.89 MWD 267.79 MWD 267.69 MWD 267.59 MWD 267.50 MWD 267.42 MWD 266.45 8 85.95 MWD 86.07 MWD 86.16 MWD 86.25 MWD 87.83 9 274.09 MWD 273.89 MWD 273.76 MWD 273.63 MWD 273.48 MWD 273.32 MWD 273.15 MWD 272.98 MWD 3725.64 272.80 TD "n_ .._...._ ___ ...___...m_ 15-29A) Date: 111512002 Plan: Plan #6 (15-291P18~6 Created By: Brij Potnis _.__._~--------_._- --- Information" Direct: (907) 267-!X'13 Hughes ,~;'~~i ~J)~~~~~q.com Contact -----tiGËÑo-- -----r--- ---- 15-22!15-22) l Azimuths to True North :~~ :t~¡ M Magnetic North: 26.52' Plan#6 15-29A PIon f6 St~a~~~~~~~~ Dip ~9Ie: 80.81' Date: 1/9/2002 Model; 8GGM2001 - L\'~,:( '" ---~- ...____u._ .... ObP BP Amoco -- Bake , I INTEQ ____ L wm.LPA". NTAI'" .......11-1.. 1102.121.101 Pa_t....... 1.... n._ MOl 11....... tw. .,.:: v_ ..... .....- : .0 II' '"1''''' DttOI ...zeft ~ '= :~ .... 0_ .... REFERENCE INFORMATION ·(tf"ªlf~~9 \ 8000 ) ,,/~l!ñ_~~t~~~; 700 800 900 600 400 500 300 100 200 o -900 -800 -700 -600 -500 -400 -300 -200 -100 West(-)/East(+) [100ft/In] -~ <.~_.;Jd____ \ ì \ /' \ I 1\'2' -"i-c.", ~-j -~1Jtl \ \ \ \ f~- I -1700-1600 -1500-1400-1300 -1200 -1100 -1000 7900 7700- 7600- 'ë'75OO ~ 7400 ~ 7300-.: .... +-r2oo ...- .J: 1:: 7100 o ~ 7000'-:' ...... . ...- .J: 6900 ... :I 06800 en 6700 6400 6300 7800 6500 6600 ..... - - = .... 2147.1' ,1:"'" IM1.SI ..,.... 21Il1O.21' -.... .1:«22.50 3017..7 ....... ...... ~"":I' ....... !AAGETOETAllS TV[) ofoU..$ .aJN &moo 121641 -3".27 '71\)00 n~,38 _14,6' tll59COO U2$7~ 29225 ..aoo 1mv.. a0038 20 Co-ord!nate (NÆ¡ Reference: Well Centre: 15-29. True North v=~~~ ~::=~ ~:~9 ;~~~e1 MeasuAld Depth R_: 43: 29 7/111199600:00 66. Cak:utaUon Method: Minimum Curvature ..-noN tcr.u.a .. __ All ft..w.a..,.. · ......10 '10." »Io,n as... _,,",a _"An · ..,us.oo ....,. aso..a _SoL" ......, .?ft.". a ".LOO "..M ,..... "$1'.". ....... .,..,.,.. · ........ ...... 'MlM ..-os 7OÞ.O, ..,."". · ....LOG...... ....., ."MA' n".." ....,.. · .....ü _00 ..... S'Pu,a n..... ..u'A? ., .21..."..... MoO' .7a,. nM.ø .us.u · ''''.::12'''00 ..... .,....., ,MLoo ...... · 11:&7S.::12 ..... ....0 .....02 ,,,,,..a ..... '0 ..,...." ".SJ ....... ......,. ,as... ne.CI1' .. .....::12..." n.aa ....... "........ au.n it U01'L" u.,.. P.O. ..'....n 'F&S2.a' ...... ANNOTATION. TVD MD ....111.. .".... 11.".11 TIP ....... 11...... KOIÞ 1117..1S ......... .. ....... t........ I .7MAt u...... a .7:t1A2 tlNt.)s . .nuI '111'1.)) . ..,..tA1 . ....... 1 .....17 . ....... . ..,...., TD ..... ...... .... .... ..". '.).M 20.00 _00 _00 ....00 2L00 ......00 __ 21..00 ...00 ""00 ...00 172.00 .2.00 N.OCI ...00 MLOO '''00 ...... ...00 1:7....00 .- I~TI 1~-29A 'I '~TI '$-2MTI \ \ \ .. 8150 8200 8250 8300 'ë' ~ 8350 II) 8400 .... ~ 8450 a. . CI 8500 ¡¡ 8550 U 1:8600 . > .8650 ! 8700 ) ~!:P"': + \~-fS.~I$~4: :Ptari#61&.29!'i -..----\ DÐ [!l / fJ~r.~~t 7 f-B [is:~@.Ä~t!i:2i m pH~ITOO \ \ \ ~!f.~~JJ 8800 8850- 8900 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 3100 3150 3200 3250 3300 3350 3400 3450 3500 3550 3600 3650 3700 3750 3800 3850 3900 3950 4000 Vertical Section at 65.00· [50ft/In] -1/15/2-002- 4:04 PM 8750 .r--.. I ' .~ BOP-Tree Well Rig Floor 13" 5000 psi. , ~ Lubricator ID = 6.375" with 6" Otis Unions 17 1/16" 5000 psi BOP's. ID = 7.06" , , .till 11/4 Tum L T Valve ~ , , 71/16" 5000 psi (RX-46) or 41/16" 5000 psi (RX-39) , . Swab Valve , Tree Size ~ SSV ~ , I Master Valve , I tubing x 9-5/8" Annulus I ~ ~ 19-5/8" x 13-3/8" Annulus I Base Flange ~ Page 1 !~ r~ H 202459 I DATE I I CHECK NO. I .12/07/01 00202459 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR ALASKAO I LA DISCOUNT NET 00 120501 CK1205011 PYMT OMMENTS: HANDL NG INST: 100.00 100.00 Per it to Drill ee S/H - Terrie Hub Ie X4628 i (, : " . /1S\ ~ \0:J' ¡- . .,..m" ¡f""'" R t: t./ ,_,I I " ; - ~ " c"·..,c (' ""$ COffi!í:\sS\Qn ,~.\3SKa 0,\ G I.::.,,,, .J ",. . þ.,'"::::',, TOTAL ~ 100.00 - 100.00 THE ATTACHED CHECK IS IN PAYME~ T FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND. OHIO No. H 202459 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 4'i2 00202459 PAY ONE HUNDRED ~ 00/100************************************* US DOLLAR To The ORDER O~ ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 DATE 12/07/01 I I NOT VALID AFTER 120 DAYS \(e .J147iL«-. AMOUNT $100.001 III 20 2 ~ 5 q III I: 0 ~ ~ 2 0 ~ 8 q 5 I: 008 ~ ~ ~ q III ~ I ~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSNnTTALLETTER WELL NAME Md /Y z9/f CHECK 1 CHECK WHAT APPLIES STANDARD LETTER ADD-ONS (OPTIONS) "CLUE" DEVELOPMENT MULTI LATERAL The permit is for a new wellbore segment of existing weD ~ Permit No, API No. . (If api number last two (2) Production should continue to be reported as a function of digits are between 60-(9) the original API number stated above. DEVELOP7 PILOT HOLE (PH) In accordance with 20 AAC 25.005(t), all records, data and REDRILL 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). . EXPLORATION ANNULAR DlS~AL Annular disposal bas not been requested. . . ( ) [7 INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . L....) YES INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . REDRILL THIS WELL DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS L....) YES + SPACING EXCEPTION Enclosed is tbe approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates ) ) ) c o z o -I :E :::tJ - -I m - z -I J: - en > :::tJ m » _ann. disposal para req _ ON/OFF SHORE _D/1 723fti' . WELL NAME /<; <Z?.4' PROGRAM: ·~V¡- O/L GEOLAREA .....~:£/. ;o:¿¡ö¡ ~.... .... /' WELL PERMIT CHECKLIST FIELD & POOL :S-V exp COMPANY NIT CLASS Permit fee attached. . . . . . . Lease number appropriate. *". Unique well name and number. . Well located in a defined pool.. . . . . . . . . . . . . . Well located proper distance from drilling unit boundary. Well located proper distance from other wells.. .. Sufficient acreage available in drilling unit.. . . . . . If deviated, is wellbóre plat included.. . . . . . . . . Operator only affected party.. . . . . . . . . . . . . Operator has appropriate bond in force. . . . . . . . Permit can be issued without conservation order. . . Permit can be issued without administrative approval Can permit be approved before 15-day wait. . ~ /' . . 'n' : ·~·I Y N N/A Y N N/Ä Y N ¡.t/~ Y. N f'Jf, iN A-tkC¡ 'N ~CTDt<. Y N¡.J./A N_ N N~~ N N_ N Permit can be issued wlo hydrogen sulfide measures. Y Œ) Data presented on potential overpressure zones . . . Y..,,-N Seismic anal~~is of shallow gas zones. . . . . . . .. '" A >( N Seabed condItion survey (If off-shore). . . . . . . . . . . . . ~ Y N Contact name/phone for weekly progress reports [exploraJ.ØfÝ only] Y N {..£' Conductor string provided . . . . . . . . " Surface casing protects all known USDWs. . . . . . CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg. . CMT will cover all known productive horizons. . . . . . Casing designs adequate for C. T, B & permafrost. . . Adequate tankage or reserve pit.. . . . . . . . . . . . If a re-drill, has a 10-403 for abandonment been approved Adequate well bore separation proposed.. . . . . . . If diverter required, does it meet regulations . . . . . Drilling fluid program schematic & equip list adequate BOPEs, do they meet regulation . . . . . BOPE press rating appropriate; test to _ Choke manifold complies w/API RP-53 (M; Work will occur without operation shutdowl Is presence of H2S gas probable.. . . . ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. A~ç8. D. AT.E ("'7 !2. 1:..3fJ....:. ' V'ì 3. c/ --'"' ENGINEERING 14.' 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. APPR ?A TE 33. th ,}{} -D2.--34. , ANNULAR DISPOSAI.,,35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; (B) will not contaminate freshwater; or cause drilling waste to surface; (C) will not impair mechanical integrity .of the well used for disposal (D) will not damage producing formation or impair recovery from a pool; and (E) will not circum GEOLOGY: GEOLOGY Y N ;Jo (À,vLfL Í/C~/ L.~w<; ~~) eJtús1-cd Y N Y N Y N - - Y N - - Commentsllnstructions: 5IðC)' AAC 25.412. COMMISSION UIC/Annular WM 11/01/100) ~þ~ c:\msoffice\wordianldiana\checklist (rev. DATE APPR ,-... /~. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. ~, ....------... Sperry-Sun Drilling Services LIS Scan utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Dec 30 17:10:10 2002 Reel Header Service name............ .LISTPE Date................. ... .02/12/30 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. . . . . . . . . . . . . . . . . . . . .02/12/30 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 15-29A 500292225901 BP Exploration (Alaska) Inc. Sperry Sun 30-DEC-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-22031 S. LATZ WHITLOW/SARB MWD RUN 3 AK-MW-22031 S. LATZ SEVCIK/EGBIG # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 llN 14E 148 22 MSL 0) 67.00 .00 .00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 10644.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVD) . 3. WELL KICKED OFF FROM 15-29 WITH TOP OF WHIPSTOCK SET é} oJ - 0 {((:J II f:l109 ,r--... ~ AT 11326' MD, 8510' TVDSS. AFTER MWD RUN 2 MISSED THE TARGET ZONE, WELL WAS PLUGGED BACK TO 11824' MD, 8687' TVDSS. 15-29A PB1 DATA ARE PRESENTED ELSEWHERE. MWD RUN 3 WAS AN OPEN HOLE SIDETRACK AT THE PLUGBACK, DRILLED TO 15-29A TD. 4. MWD RUN 1-3 WERE DIRECTIONAL WITH PRESSURE CASE GAMMA (PCG) UTILIZING SCINTILLATION DETECTORS. 5. MWD DATA WAS DEPTH SHIFTED TO THE SCHLUMBERGER MEMORY CNL OF 2/25/2002, PER THE 4/5/2002 E-MAIL FROM D. SCHNORR (BP EXPLORATION). LOG AND HEADER DATA RETAIN DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 AND 3 REPRESENT WELL 15-29A WITH API # 50-029-22259-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12900' MD / 8670' TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY COMBINED (SCINTILLATION DETECTORS) $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/30 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10815.5 11325.0 STOP DEPTH 12864.5 12895.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -----.---- BASELINE DEPTH 10821.5 10844.0 11311.5 11416.0 11524.5 11566.0 11615.0 11642.0 11655.0 11695.5 11706.0 11829.0 11867.0 11892.0 11913.0 11922.5 11937.0 12086.5 12198.5 12354.0 12434.0 12864.5 GR 10825.0 10846.5 11314.0 11418.0 11524.5 11566.0 11615.0 11641.0 11654.5 11696.5 11707.0 11832.0 11870.5 11896.5 11916.5 11926.0 11940.5 12089.5 12202.0 12357.5 12438.0 12868.5 ~ ~ $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 3 MERGE TOP 10819.0 11824.5 MERGE BASE 11824.0 12899.5 # 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 Depth Units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD GR MWD units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam Rep 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10815.5 12895.5 11855.5 4161 10815.5 12895.5 ROP MWD FT/H 0.54 642.65 82.9288 3142 11325 12895.5 GR MWD API 14.48 1006.73 55.7242 3229 10815.5 12864.5 First Reading For Entire File..........10815.5 Last Reading For Entire File...........12895.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/30 Maximum Physical Record. .65535 File Type................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... version Number.......... .1.0.0 Date of Generation...... .02/12/30 Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10819.0 11327.5 STOP DEPTH 11824.0 11824.0 ~ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE NGP $ BOTTOM) TOOL TYPE NATURAL GAMMA PROBE # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction.. .............. . Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value................. . . . . . -999 Depth units............... . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 19-FEB-02 Insite 3.03 Memory 11824.0 11325.0 11824.0 59.8 81. 6 TOOL NUMBER 001 3.750 10644.0 F10 Pro 8.70 65.0 8.4 21000 5.8 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 .~ .0 138.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10819 11824 11321.5 2011 10819 11824 ROP MWD010 FT/H 3.64 642.65 81.3969 994 11327.5 11824 GR MWD010 API 14.48 1006.73 38.158 1141 10819 11824 First Reading For Entire File......... .10819 Last Reading For Entire Fi1e...........11824 ~ File Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... . .02/12/30 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.003 physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/30 Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP GR $ 3 ..------... header data for each bit run in separate files. 3 .5000 START DEPTH 11824.5 11824.5 STOP DEPTH 12899.5 12868.5 # 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 NGP $ BOTTOM) TOOL TYPE NATURAL GAMMA PROBE # 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: 22-FEB-02 Insite 3.03 Memory 12895.0 11824.0 12895.0 81. 3 97.8 TOOL NUMBER 001 3.750 10644.0 Flo Pro 8.70 65.0 8.7 24000 6.6 .000 .000 .000 .000 .0 145.0 .0 .0 ~ ''-----'''''' MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. . . . . . . . . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 Units FT FT/H API Size 4 4 4 Nsam Rep Code 1 68 1 68 1 68 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11824.5 12899.5 12362 2151 11824.5 12899.5 ROP MWD030 FT/H 0.54 315.87 83.6406 2151 11824.5 12899.5 GR MWD030 API 21. 81 171.74 65.2328 2089 11824.5 12868.5 First Reading For Entire File..... .....11824.5 Last Reading For Entire File...... .....12899.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/30 Maximum Physical Record. .65535 File Type................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/30 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.. ..... ........... ...02/12/30 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File ~ /~. ~ /~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 31 11:42:49 2002 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . .. . .02/12/31 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. .. . . . . . . . . .. .. .. . . . .02/12/31 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name... ............ . UNKNOWN Continuation Number..... .01 Previous Tape Name.......UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 15-29Apb1 500292225970 BP Exploration (Alaska) Inc. Sperry Sun 31-DEC-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-22031 S. LATZ WHITLOW/SARB MWD RUN 2 AK-MW-22031 S. LATZ SEVCIK/EGBIG # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 UN 14E 148 22 MSL 0) 67.00 .00 .00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 10644.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWI~3E NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVD) . 3. WELL KICKED OFF FROM 15-29 WITH TOP OF WHIPSTOCK SET c;(Cb1~D I ~ //470 ,""--"'\ /---"'\ AT 11326' MD, 8510' TVDSS. AFTER MWD RUN 2 MISSED THE TARGET ZONE, WELL WAS PLUGGED BACK TO 11824' MD, 8687' TVDSS. MWD RUN 3 WAS AN OPEN HOLE SIDETRACK AT THE PLUGBACK, DRILLED TO 15-291\ TD. 15-29A DATA ARE PRESENTED ELSEWHERE. 4. MWD RUN 1-3 WERE DIRECTIONAL WITH PRESSURE CASE GAMMA (PCG) UTILIZING SCINTILLATION DETECTORS. 5. MWD DATA WAS DEPTH SHIFTED TO THE SCHLUMBERGER MEMORY CNL OF 2/25/2002, PER THE 4/5/2002 E-MAIL FROM D. SCHNORR (BP EXPLORATION). LOG AND HEADER DATA RETAIN DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 1 AND 2 REPRESENT WELL 15-29A PB1 WITH API # 50-029-22259-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12356' MD / 8741' TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY COMBINED (SCINTILLATION DETECTORS) $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/31 Maximum Physical Record. .65535 File Type.... ............LO Previous File Name.......STSLIB.OOO Conunent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10815.5 11325.0 STOP DEPTH 12324.0 12355.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -----.---- BASELINE DEPTH GR 10821.5 10825.0 10844.0 10846.5 11311.5 11314.0 11416.0 11418.0 11524.5 11524.5 11566.0 11566.0 11615.0 11615.0 11642.0 11641.0 11655.0 11654.5 11695.5 11696.5 11706.0 11707.0 12324.0 12325.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 10819.0 12050.5 MWD 2 12051.0 12356.0 $ # 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 . UN Max frames per record.............Undefined Absent value...................... -999 Depth Units... . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD GR MWD Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam Rep 1 68 1 68 1 68 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 10815.5 12355 11585.3 3080 10815.5 12355 ROP MWD FT/H 0.85 2051 84.3884 2061 11325 12355 GR MWD API 14.48 1006.73 56.697 2148 10815.5 12324 First Reading For Entire File......... .10815.5 Last Reading For Entire File.......... .12355 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/31 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/31 Maximum Physical Record. .65535 File Type................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10819.0 11327.5 STOP DEPTH 12019.5 12050.5 # 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): 19-FEB-02 Insite 3.03 Memory 12050.5 11327.5 12050.5 r---. BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE NGP $ BOTTOM) TOOL TYPE NATURAL GAMMA PROBE # 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 . UN Max frames per record............ .Undefined Absent value......... . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Nsam Rep Code 1 68 1 68 1 68 Size 4 4 4 59.8 81. 6 TOOL NUMBER 001 3.750 10644.0 F10 Pro 8.70 65.0 8.4 21000 5.8 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 ~ ,/ .0 138.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10819 12050.5 11434.8 2464 10819 12050.5 ROP MWD010 FT/H 0.85 2051 97.5087 1447 11327.5 12050.5 GR MWD010 API 14.48 1006.73 43.4204 1532 10819 12019.5 First Reading For Entire File..........10819 Last Reading For Entire File.......... .12050.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/12/31 Maximum Physical Record. .65535 File Type.......... ......LO Next File Name...........STSLIB.003 ,""'--". Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .02/12/31 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 ~ header data for each bit run in separate files. 2 .5000 START DEPTH 12020.0 12051.0 STOP DEPTH 12325.0 12356.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE NGP $ BOTTOM) TOOL TYPE NATURAL GAMMA PROBE # 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 20-FEB-02 Insite 3.03 Memory 12325.0 12050.5 12325.0 77.8 92.5 TOOL NUMBER 001 3.750 10644.0 Fl0 Pro 8.70 65.0 8.5 22000 5.9 .000 .000 .000 .000 .0 142.0 .0 .0 /'. ~. Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing.................... .60 .lIN Max frames per record.............Undefined Absent value............. . . . . . . . . . -999 Depth Units....................... Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD020 MWD020 Nsam Rep 1 68 1 68 1 68 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 12020 12356 12188 673 12020 12356 ROP MWD020 FT/H 3.81 147.16 53.2992 611 12051 12356 GR MWD020 API 43.34 152.36 89.9726 611 12020 12325 First Reading For Entire File..........12020 Last Reading For Entire File........ ...12356 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation. ......02/12/31 Maximum Physical Record. .65535 File Type. ...............LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name.............LISTPE Date.................... .02/12/31 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 te. . . . . . . . . . . . . . . . . . . . .02/12/31 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number. .....01 Next Reel Name..... ......UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
