The URL can be used to link to this page

Home My WebLink About203-192 e e Image Project Well History File Cover 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. ~ () 3 - 1 c¡ :J- Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 1111111111111111111 RESCAN ¿/color Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, No/Type: D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: D Other:: BY: ~ Date d-- <611J~ 151 0tf 11111111111111" 1/1 Project Proofing BY: ~ Date d- '?if 6ft; ~ x 30 = hn Date d-/~I 00 >>If + 3 = TOTAL PAGES b3 (Count does not include cover sheet) .rnP 151 . . , 11111111111111" 1/1 151 Scanning Preparation BY: ~ Production Scanning Stage 1 Page Count from Scanned File: h 4- (Count does include cover sheet) Page Count Matches Number in scann.i~reparation: V YES BY: C _ Ma'i~) Date: a.-J 15 t Ó0 Stage 1 If NO in stage 1, page(s) discrepancies were found: 151 NO rnp YES NO BY: Maria Date: 151 11111111111I11 11111 Scanning is complete at this point unless rescanning is required. ReScanned III II 111111 "' "III BY: Maria Date: 151 Comments about this file: Quality Checked 11111111/11I" 1/11I 10/6/2005 Well History File Cover Page.doc • • Page 1 of 1 Maunder, Thomas E (DOA) From: Hubble, Terrie L [Terrie.Hubbie@bp.com] Sent: Wednesday, March 25, 2009 4:14 PM To: Maunder, Thomas E (DOA) Subject: RE: DS 07-29C (203-192) Yes, it was sidetracked by Nordic #2 (CTD). Someone was too quick on selecting the rig. Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, March 25, 2009 3:40 PM To: Hubble, Terrie L Subject: DS 07-29C (203-192) Terrie, I am reviewing the 407 for the P&A of this well. Nabors 2ES is shown as the rig, however the operations summary reads "coil". Should the rig be Nordic 2? Tom Maunder, PE AOGCC ~ nt`;~=; ~,.~ ,~. -~ ~~v~.~ ~~'~i'j~*~,~''t~€~i~+ E't~'y-- `"' ~ 3/26/2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ;.~.. `:~ ~: 2009 ' lion 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended 2oAAC 2s.1os 2oAAC 2s.1,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1b: ~'C1'e ass~~ ®Develop~'Or~~Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 3/3/2009 ~ 12. Permit to Drill Number 203-192 309-064 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/25/2003 13. API Number 50-029-21782-03-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/31/2003 14. Well Name and Number: PBU 07-29C 452 FEL, SEC. 33, T11 N, R14E, UM FNL, 327 Top of Productive Horizon: 245' FSL, 223' FEL, SEC. 21, T11 N, R14E, UM 8. KB (ft above MSL): 52.9' Ground (ft MSL): 24.4' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1858' FSL, 54' FEL, SEC. 21, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 10944' 8662' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 675856 y- 5950465 Zone- ASP4 10. Total Depth (MD+TVD) 13020' 8940' 16. Property Designation: ADL 028306 TPI: x- 675807 y_ 5956442 Zone- ASP4 - 5958058 Zone- ASP4 Total Depth: x- 675935 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: y 18. Directional Survey ^ Yes ^ No ' I " t info r 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR, GR, RES 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT. WT. PER FT. ' GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED" 1. H 10' S 1 # P ' 291 sx CS II 3000 sx CS III 500 sx Class 'G' / " 4 -8 74 ' 7 7 ' -1 /4" 5 s 1 7 ' 7" 7 , 1 1' -1 " 1 I ' ,~ 23. Open to production or inject ion? ^ Yes ®No 24. TU81NG RECORD If Yes, Ilst each I (MD+TVD of To & Bottom; Pe nt@N81 Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD p 4-1/2", 12.6#, L-80 10378' 10321' MD TVD MD TVD 25. ACID, Fw-cTURE, CEMENT SQUEEZE; ETG. ~~,~~ ;`~ 'c .,t'`t...~3i~~ ~~S,I^~` ~~ '`~;'" ~ +~~~~ DEPTH INTERVAL MD AMOUNT Hi KIND OF MATERIAL USED 10985' Set CIBP 10944' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS T@sted: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 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+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed): Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None •~--~•. "~ j~9 ~~~t ,~. ~~~~ ~ E~ ilr Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE Z8. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS 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. Sag River 10522' 8351' None Shublik A 10573' 8389' Shublik B 10597 8407 Shublik C 10619' 8423' Eileen 10638' 8437 Sadlerochit 10647 8444' Zone 3 /Top CGL 10860' 8601' Zone 2C /Base CGL 10948' 8665' 23S8 /Zone 2B 11044' 8737' 21TS /Zone 2A 11190' 8839' Zone 1 B 11321' 8904' 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 fore oing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Drilling Technologist Date PBU 07-29C 203-192 309-064 Prepared ByNameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: ~! Rixse, 564-5620 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Sak Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production ftom each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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 separatety produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the cerresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 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 Onry 07-29C, Well History (Pre Rig Sidetrack) Date Summary 02/16/09 WELL SHUT IN ON ARRIVAL. DRIFTED TO 11183' SLM WITH 20' x 3.70" DMY WHIP STOCK, (STOP DUE TO DEVIATION). WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED. 02/19/09 WELL SI ON ARRIVAL. INITIAL T/I/O = 2400/1600/340 SPOT ELINE TO SET WEATHERFORD CIBP. LRS LOADING WELL WITH 250 BBL CRUDE. 02/19/09 T/I/0=2450/0/0 Assist E-Line (CTD Prep) Loaded Tbg with 5 bbl methanol spear and 250 bbls crude. E- Line to set CIBP. 02/20/09 Assist E-Line set CIBP. MITT PASSED to 3000 psi (Pre CTD). Fluid packed Tbg with 4.0 bbls crude, pressured up Tbg with additional 4.3 bbls crude for MITT. Tbg lost 140 psi in the 1st 15 mins and 40 psi in the 2nd 15 mins for a total pressure loss of 180 psi in 30 mins. Bled Tbg to zero. FWHP's = 0/0/0. E- line in control of well upon departure. 02/20/09 LRS CONTINUE LOADING WELL WITH 250 BBL CRUDE. T/I/O 140/50/0. ELINE SET 4.5" (3.55" OD) WEATHERFORD CIBP AT 10,985 FT MID-ELEMENT. DEVIATION AT PLUG SET 42 DEGREES. LRS MIT ON TUBING TO 3000 PSI PASSED. FINAL T/I/O = 0 / 50 / 0 PSI. WELL LEFT SHUT IN. JOB COMPLETE. 02/21/09 T/I/0=S1/0/0 Freeze Protect Flowline (Pre-CTD). Pumped down flowline with 5 bbls neat, 135 bbls crude and 3 bbls neat to pressure up flowline. Final WHP's = SI/0/0. SV = C, WV = C, SSV = C, MV = O, IAV = OTG, OAV = OTG. 02/26/09 T/I/0=0/0/0; presure test tree pre rig 5000 psi master /wing- 5000 psi swab 10min (passed). Page 1 of 1 BP EXPLORATION Page 1 ofd Operations Summary Report Legal Well Name: 07-29 Common Well Name: 07-29 Spud Date: 2/14/1988 Event Name: REENTER+COMPLETE Start: 2/17/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/5/2004 Rig Name: '"^"~~~~ Noc~'~~~ ~'~g Number: 2 Date From - To Hours ~' Task Code I NPT ~ Phase .Description of Operations 3/2/2009 04:00 - 04:35 0.58 MOB P PRE PJSM for rig move. Meet with DSO for rig move. 04:35 - 06:00 1.42 MOB P PRE Mobilize rig from 07-20B to 07-29D. 06:00 - 12:00 I 6.001 RIGU I P I I PRE 12:00 - 18:00 6.00 RIGU P PRE 18:00 - 18:30 0.50 RIGU P PRE 18:30 - 19:20 0.83 RIGU P PRE 19:20 - 19:40 0.33 RIGU P PRE 19:40 - 00:00 I 4.331 BOPSUR P I I PRE 13/3/2009 100:00 - 01:10 I 1.171 BOPSUR P I I PRE 01:10 - 01:30 0.33 RIGU P PRE 01:30 - 02:45 1.25 RIGU P PRE 02:45 - 03:40 0.921 RIGU P PRE 03:40 - 04:05 ~ 0.42 ~ RIGU ~ P ~ ~ PRE 04:05 - 04:10 0.08 RIGU N SFAL PRE 04:10 - 04:25 0.25 RIGU N SFAL PRE 04:25 - 04:40 0.25 RIGU N SFAL PRE 04:40 - 07:00 2.33 RIGU P PRE 07:00 - 08:00 1.00 RIGU P PRE 08:00 - 10:00 2.00 RIGU P PRE 10:00 - 12:00 2.00 WHIP P WEXIT 12:00 - 16:50 4.83 WHIP P WEXIT 16:50 - 19:30 2.67 WHIP P WEXIT finish prep around well head. Spot rig over tree. Accept rig at 0600 hrs on 3/2/09 Berm cellar. Spot external equipment. Switch office to rig power. Install new 2-3/8" reel. NU BOPs in cellar. Attach all lines to same. Secure BOPS with chains. Take on fluid in pits. Pick up reel and install hard line. Continue to rig up tiger tank hard line ect. PJSM BOP test Continue to rig up BOP and shell test. Service leaking Gray Lock Fittings. Notified AOGCC with 2 hr notice Test witness waived by Jeff Jones, AOGCC C~ 19:30. Test BOPE as per well plan, AOGCC regs, and permit to drill #209023. Test to 250 psi low and 3500 psi high. Record all data electronicallly and on roll chart. Test witness waived by Jeff Jones, AOGCC. Continue to teat BOPE as per well plan, AOGCC regs, and permit to drill # 209023. All data recorded electronically and on roll chart, and reported on AOGCC test form. Test witness waived by Jeff Jones AOGCC. PJSM to pull coil across. RU and pull coil across. Stab pipe into injector. Had to disconnect front guide roller to get pipe stabbed in. Reinstall front guide roller. Cut grapple off of coil. OC E line -PASS. Cap eline for pumping slack. Stab on well with injector. Circulate forward to clear coil. Unable to pump with pump 2 -Frozen line on the off drillers side in the "cantilever" section. Change to pump 1 -Frozen as well. Complete a confined space entry permit and notify security. PJSM on using steam to thaw out lines in confined space. Thaw frozen pump lines to establish flow paths for pumps 1 and 2. Circulate coil clean with 2 coil volumes, leading in with McOH. PJSM on slack management and cutting coil. RU to reverse circulate slack in to reel. Cut 34' of coil. MU a-coil head. Test same. Mu Baker 4-1/2 monobore whipstock on Inteq mwd tools. Stab coil. Test tools. Get on well. Run in hole. WHP up to 375psi, heating up hydrates in wellbore Printed: 3/16/2009 1:49:04 PM BP EXPLORATION Page 2 e~ Operations Summary Report Legal Well Name: 07-29 Common Well Name: 07-29 Spud Date: 2/14/1988 Event Name: REENTER+COMPLETE Start: 2/17/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/5/2004 Rig Name: ''f~6'Q~a~2'6t~~~~~ Ig Number: 2 Date From- To ~ Hours ' Task Code li NP~~se ' Description of Operations 3/3/2009 16:50 - 19:30 2.671 WHIP P WEXIT Circulate out gas w/ KCI, then swap to 2 ppb biozan 19:30 - 19:50 0.33 WHIP P 19:50 - 21:40 1.83 WHIP P 21:40 - 21:55 0.25 WHIP P 21:55-23:10 1.25 WHIP P L:s:iu - u.uu whir r n 3/4/2009 00:00 - 01:00 1.00 STWHIP P ~~'Z9~lJ 01:00 - 03:25 2.42 STWHIP P 03:25 - 04:10 I 0.751 STWHIPI P 04:10 - 04:20 0.17 STWHIP P 04:20 - 06:50 2.50 STWHIP P 06:50 - 10:30 I 3.671 STWHIPI P 10:30 - 12:50 2.33 STWHIP N 12:50 - 13:20 0.50 STWHIP N 13:20 - 14:20 1.00 STWHIP N 14:20 - 14:50 0.50 STWHIP N 14:50 - 16:40 1.83 STWHIP N 16:40 - 17:00 0.33 STWHIP N 17:00 - 17:20 0.33 STWHIP N 17:20 - 20:05 2.75 STWHIP N 20:05 - 22:10 2.08 STWHIP N WEXIT EXIT WEXIT WEXIT Log tie-in to PDC GR, corr -21.5' Tag top of CIBP ~ 10,974 ft (10 ft high as planned) PU to 10,952.5 ft, close EDC. Pressure up to 3150 psi. to set whipstock. Without picking up, stack 6 K3's DH WOB PUWT44K#'s Set whipstock C~ ipq'lyft TOP OF WHIPSTOCK. POOH with 0=1.7 bpm PJSM while POOH for LD/PU of BHA's Tag up and flow check well. Unstab injector and LD Whipstock setting BHA. Setting tool looked normal, straight, and all indications were for normal operation. PU window milling BHA, and stab on injector. WEXIT RIH C~ min rate with window milling BHA WEXIT Continue to RIH pumping min rate. W EXIT Tag XN @ 10,377 ft dry. PU, pumps to 2.3 bpm RIH and Tag C~ 10,374.4 ft start of MW. Continue to mill XN nipple Milling with 100 to 200 psi MW. - No Stalls RIH to 10,380 ft then PU to 10,360 ft twice. Dry drift was clean. WEXIT RIH Log for GR tie in 10,598 ft to 10671 ft -19 ft correction. WEXIT RIH WEXIT Dry tag top of WS Cud 10,944.3 ft. PU & Pumps on to 2.25 bpm Q 2025 psi Tag Q 10,944.1 ft -Stalled. 10,943.7 ft -Stalled, 10,943.75-Stalled, still stalling trying to get started. Lost ground back to 10942.90' after a total of 14 stalls WEXIT Mill from 10942.90' 2.48/2160 in increments of 0.05'/10 min. Mill to 10943.90' and stall. Give up after 5 stalls at this depth DPRB WEXIT POH to check mill DPRB WEXIT LD 2 jts PH6, standback MWD assy. Mill was worn on complete gauge to 3.70" No-go. SR was 3.74" No-go. No used SR on location DPRB WEXIT WO BTT to drive to Deadhorse and return with complete new mill, new SR and fresh motor all bucked up DPRB WEXIT MU milling assy w/MWD and 2 jts PH6 DPRB WEXIT RIH w/milling assy circ thru mill 0.47/600 Pass thru XN at reduced speed w/ no wt loss DPRB WEXIT Log tie-in down to GR marker at 10566', corr -19' RIH to tag at 10944.9'. PUH 46.3k PVT 239 DPRB WEXIT Start motor 2.73/2300. Park at 10943.5' 2.73/2300 and stalled after 5 min. PUH w/ 3k OP. Park at 10942.0' 2.72/2270 DPRB WEXIT Begin time milling from 10942.0' 2.72/2250 0.05'/6 min Stall ~ 10,943.5 ft DPRB WEXIT PU to 10,930 ft and restart motor. RIH slowly to 10,943 ft and park. Printed: 3/16/2009 1:49:04 PM TREE _ W~LL`HEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP = 9736 Max Angle = 96 @ 12733° Datum MD = 11220' Datum TVD = 8800' SS 13-3/8" CSG, 72#, K-55, ID = 12.347" ITII LII'T'1 I = 2.3°' 10607' Ille out I•oflle PERFORATION SUMMARY REF LOG: ???? on mm/dd/yy ANGLE AT TOP PERF: 88 @ 11900' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11900-12120 O 03/19109 2" 6 12250-12340 O 03119109 2" 6 12380-12450 O 03/19109 2" 6 12520-12590 O 03%19109 2" 6 12690-12950 O 03/19109 2" 6 13100-13260 O 03.119109 TOP OF WHIPSTOCK 9736' I 9-5/8" CSG, 47#, L-80, ID = 8.681 " I-( 10591' I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I I 7" CSG, 29#, L-80, .0417 bpf, ID = 6.538" I 2215' I-i 4-1/2" HES X NIP, ID = 3.813" I 10378' I I 10522' I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3191 3160 25 MMG DMY RK 0 12/15/08 3 5801 4999 45 MMG DMY RK 0 12/15/08 2 7957 6514 48 MMG DMY RK 0 01/06/04 1 10064 8014 42 KBG-2 DMY BK 0 01/06/04 9585' ~-~ 9-5/8" X 7" HMC C2/ ZXP LNR TOP PKR 10300' -~ 4-1/2" HES X NIP, ID = 3.813" 10321' 7" X 4-1/2" S-3 PERM PKR, ID = 3.875" 10344' 10365' 4-1/2" HES X NIP, ID = 3.813" 4-1/2" HES XN NIP, ID mHied to = 3.80" 10376' 7" X 4-1/2" HMC C2/ZXP LINER TOP PKR 10378' 4-1/2" WLEG 4-1/8" FMC FMC SAFETY NOTES: ORIGINAL W ELLBORE AND "A" AXELSON ~ ~° i SIDETRACK NOT SHOWN ON DIAGRAM. 65' i i 1~-1 ,~: o E~ . _~ ~ ~~. _. ~~~~4 _ , k 4T-.n ~~, "lS 12931' PBTD 4-112" LNR, 12.5#, L-8C3, .0152 bpf, ID = 3.95 '[$019' ~~ DATE REV BY COMMENTS DATE REV BY COMMENTS 03/07/88 ORIGINALCOMPLETION 03/19/09 NORDIC2 CTDSIDETRACK(07-29D) 12/25/98 CTDSIDETRACK(07-29A) 03/24/09 /TLH CORRECTIONS 02/19/03 DAC/KK CTD SIDETRACK (07-296) 01/07/04 JLM/KA RIG SIDETRACK (07-29C) 06/04/04 SRB/KAK CORRECTIONS 01/15/09 BSEISV GLV C/O (12/15/08) PRUDHOE BAY UNIT WELL: 07-29D PERMff No: API No: 50-029-21782-04 SEC 33, T11 N, R14E, 452' FNL & 327' FEL BP Exploration (Alaska) • • 0 a a SARAH PAL/N, GOVERNOR COj`SER~~O O~SSIO~ 333 W. 7th AVENUE, SUITE 100 ~~••~~..ll~~l/ii---777-7io1` ANCHORAGE, ALASKA 99501-3539 John McMullen PHONE (907) 279-1433 FAX (907) 276-7542 Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 ~,Q~ ~ ~ Gj ,~- Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-29C Sundry Number: 309-064 Dear Mr. McMullen: `~~ ~~~~~a FEB :~ ~ 2Q09 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 Commission's petroleum 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 Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 1 ~ day of February, 2009 Encl. a ~ ,~(~( /~•~-\ ~ /~~~ ~Y ~~7'~ STATE OF ALASKA ~~~~ ~~ ~~ ~ ~°~ ~~ AL~4 OIL AND GAS CONSERVATION COM~~1~J~ 1 7 ~Q~`3 ~, ,~ APPLtCATtON FOR SUNDRY APPROVAL ~,l~ •~ 20 AAC 25.280 Alaska Oil & Gas Cons• C~mmiss~a~t 1. Type of Request: ®Abandon ~ ^ Suspend ^ Operation Shutdowg, ,^ ierforate im xtension ^ After 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 203-192 , 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21782-03-00 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 07-29C- Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028306 - 52.9' ~ 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): 13020' - 8940' 12931' - 8943' ' None 12925' h 'z MD TV 13 rs II tr r I r 11 ' rf 37 7' 13-3/ " 37 7' 6 1 In rme i 74 ' 9- / " 7 4' 7 47 0 P 'n r 8' 7" 574' - 16 70 in r 4-1 1 '- 1 1 8 843 7 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11162' - 12930' 8821' - 8943' 41/2", 12.6# L-80 10378' Packers and SSSV Type: 7" x 4-1/2"'S-3' packer Packers and SSSV MD (ft): 10321' 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: Immediately ^ 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 Mel Rixse, 564-5620 Printed Name Joh ii(c l fi Title En ineering Team Leader Prepared By Name/Number Signature Phone 564-4711 Date t"~ ~~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number. _ ~(p Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~~ ~'c~ ~s.r-~.''e~~ ~-,~® ` ~ ~ rr~ ~C~'~~~C°' Subsequent Form Required: APPROVED BY ~,/ ~ COMMISSIONER THE COMMISSION Date A roved B : Form 10-403 Revised 56/2006 Submit In Duplicate ~_~ , ,. r ~ ~ ~ G =. _ • • To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mel Rixse CTD Engineer Date: February 12, 2009 Re: 07-29C Perforation Abandonment and new CTD Sidetrack Sundry Approval Request Sundry approval is requested for well PBU 07-29C. It is proposed to set a CIBP to abandon the C lateral. A new coil tubing drilling sidetrack is planned to follow. The CTD side track will target the Zone 1A sands in an offset fault block to the east. 1,000' of perforations in the Zone 1 A sands is anticipated. WELL HISTORY/CURRENT STATUS: Well 07-29C was rotary sidetracked in January 2004 as a horizontal Z1 A producer after the 07-29B coil sidetrack in Feb 2003 would not flow due to stuck pert guns. In 2005, 07-29C was a marginal producer with only ~20% on-time. A June 2004 PPROF/IPROF indicated a majority of the production was entering from the bottom set of perforations. A CIBP was set at 12665' MD in April 2006 for a gas shut-off (GSO). The GSO was successful; however the remaining perforations would not flow at a competitive rate on their own. In November 2006, the Z1A perfs above the CIBP were stimulated with a 50 bbl DAD acid wash and 75' (11390-440' MD & 11450-475' MD) of high quality Z1 A rock in the heel was perforated. The new perfs provided sufficient energy to lift production from the lower Z1A interval and generated a substantial oil rate. Oil rate dropped off in early August 2007, and the well did not show apositive/healing response to shut-in time. The CIBP was milled up on 2/12/08 in order to access oil rate from the Z1A toe perfs. The production returned to the rates from before setting the plug, but the well started cycling with minimal healing. End- of-life Z2B lens perfs (10') were shot in Nov 2008. There was an initial oil rate buzz, but it lasted for one welltest and the GOR quickly rose over MGOR. The well passed aMIT-IA to 3000 psi, MIT-OA to 2000 psi, and PPPOT-T to 5000 psi in Dec 2008 during CTD screening. A caliper log (Dec 2008) indicated the tubing and liner are in good-to-fair condition with a maximum wall penetration of 21%. REASON FOR SIDETRACK: 07-29C is not a competitive well, exhibits minimal recharge, and has low remaining value. Pre-Rig Operations Pre-Rig Operations 1. S Drift to 11,100' ELMD for cement retainer and BTT 4-1/2" monobore whipstock. 2. E Set CIBP at 10,985' ELMD 3. F MIT -Tubing 3000 psi 4. C Mill XN nipple in tubing tail at 10,365' MD with left hand motor to 3.80". 5. E Set Whipstock at 10,950' ELMD with SLB WPP tool. 6. O PT tree (MV,SV,WV) 7. O Bleed gas lift and production flowlines down to zero and blind flange 8. O Remove S-Riser, Remove wellhouse, level pad -Complete Rig Sidetrack Operations: (Sche~d to begin on March 1, 2009) 1. 2. 3.~ 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high Pull BPV. • ~ ~~~ .~ e~v~-~ Mill 3.80" window through 4-1 /2" liner at 10,950' ELMD. i Drill drop/turn section with 4-1/8" bicenter bit, and land well. Drill lateral section to 13,530' MD w/ resistivity log. Run 3-3/16" x 2-7/8" solid liner w/cementralizers to TD. Place liner top at 10,750' MD. Cement liner from TD to TOL (10,750'MD) with 15.8ppb cement. Clean out liner/Run MCNVGR/CCL log. Test liner lap to 2000 psi. Perforate per geologist. Set liner top packer (if fails liner lap test) Freeze protect well to 2500' with methanol. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. RDMO. Post Rig: 1. Pull BPV 2. Install GLV 3. RU test separator 4. Re-install well house and attach production lines ~.~~~z,~d~iC ~ Mel Rixse <~.~/ CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble TREE= 4-118' FMC WELLHEAD= FMC ACTUATOR= AXELSON KB. ELEV = 65' ~ BF. EIEV = KOP = 9736 I Max Angle _ 95 @ 11814' Datum MD = 11220' Datum TVD = .......13800' SS '8" CSG, 72#, K-55, ID =12.347" I--I 3767' (- Minimum ID = 3.725" @ 10365' 4-112" HES XN NIPPLE PERFORATION SUMuIA RY REF LOG: MWD/ DGR ON 11(01104 ANGLEATTOPPERF 49° @ 11162" Note: Refer to Woduction DB for histarical pert data SIZE SFF INTERVAL OprJSgz DATE 3-318" 6 11162 - 11172 O 11!15!08 2-718" 6 11390 - 11440 O 11120/06 2-718" 6 11450 - 11475 O 11/20106 2-7l8" 6 11820 - 12140 O 01104104 2-718" 6 12210 - 12450 O 01!04/04 2-715" 6 12560 - 12635 O 01/04/04 2•~/$ i. 127D5- 12937 ~~ o I /oy/ I TOP OF WH~STOCK ~ 9-5/8" CSG, 47#. L-80, iD = 8.681" !-3l8" LNR, 4.41#, L-80, .0036 bpf, ID = 1.92" I'1 72546' I 4-1/2" TBG, 12.6#, L-80, .0152 bpf. ID= 3.958" 4-112" HES X NIP, ID = 3.813" I 7" X 4-112" S-3 FSRM PKR, ID = 3.875" 4-112" HES X NIP, ID = 3.813" i5 4-1l2" HES XN N~, O = 3.725" 10376' 7" X 4-112" HIV1C C21ZXP LNR TOP PKR 10378' a-1n" WLEG FISH - WRD CIBP DEBRIS MLLED 8 PUSHED TO BTM {02112/08) 11 12925' CTM ~......,, 4-1/2" LNR 12.6#, L-80, .0152 bpf; ID = 3.958" 13019' DA RE BY MM N V Y M 03107/88 ORIGINAL COMPLETION 06/01/07 RCTIPAG GLV GO (0.5!30/07) 12/25198 CTD SIDETRACK 07- 02!18!08 SRB/PJC MILLCIBP (02!121080 02119V03 DAGKK CTD SIDETRACK 7-296 02119108 /TLH FISH CORRECTK)N CTM 01107/04 JLMlKAK RIG SIDETRACK (07-29C) 12!06108 GJBIPJC ADPERF 11/15I~} 06/04/04 SRB/KAK CORRECT~NS 01!15/09 BSE(SV GLV GO 12!15/08 01/03107 OOBlTLH ADPERFS 11/20/06 Q ~ ~~ 9 C SIDETRACK NOT SHOW N ON D GRAM AND "A 14-112" HES X NIP, b= 3.813" I GAS LIFT MANDRELS S M D DEV TYPE VLV LATCH P T DA 4 3191 3160 25 MMG DMY RK 0 12!15/08 3 5801 4999 45 MMG DMY RK 0 12115/08 2 7957 6514 48 MMG DMY RK 0 01/06/04 1 10064 8014 42 KBG-2 DMY BK 0 01/06104 9585' H 9-518" X 7" HMC C2! ZXP LNR TOP PKR MLLOUT WINDOW 9746' - 9762' PRUDHOE BAY UNR WELL 07-29C PERMIT No: 1031920 API No: 50-029-21782-03 SEC 33, T11 N, R14E, 452' FNL & 32T FEL BP 6~ploration (Alaska) TREE= 41/8' FMC 1NELLhfAD= FMC ACTL4ITOR = AXELSON KB. ELEV = 65' BF. ELEV = -- KOP = 9736 Mex Angb = 35 Q 11814' Datum MD = 11220' Datum ND = 8800' SS i ~J Q O ! '~ V D SAFETY NOTES: ORIl3NAL WELLBORE AND "A•• Proposed CTD Sidetrack SIDETRACK NOT SFIOWN ON DIAGRAM. r,AC I IFT MANf1RFl S Minimum ID = 3.726" ~ 10366' 4-1/2" HES XN NIPPLE PERFORATION SlA4MARY REF LOG: MWD / DGR ON 11/01!04 ANGLE AT TOP PERF: 49' ~ 11162' Note: Refer to Productan DB for historical pert data SRE SPF INTERVAL OpNSgz DATE &3/8' 6 11162 - 11172 O 11115/08 2-7/8' 6 11 ~0 - 11440 O 11/ZQ106 2-718' 6 11450 - 11475 O 1120/OG 2-7/8' 6 11820 - 12140 O 01!04/04 2-7/8" 6 12210 - 12450 O 01/04/04 2-718" 6 12560 - 12636 O 01104/04 TOP OF WHIPSTOCK 973$' II 41/2" TBG, 12.871, L-80, .0152 bpf, ID = 3.958" I B to = 11600' 3-3/16 x z-718 x-over D 13-3/16" x 2-718" cemented and oeA'd I ST MO ND DEV TYPE VLV LATCH PORT DATE 3191 3180 25 MMG DMY RK 0 12/15/08 3 5801 4999 45 MMG DMY RK 0 12/15J08 2 7957 &514 48 MMG DMY RK 0 O1/0&04 1 10064 8014 42 KBG-2 DMY 6K 0 01/0804 I 9-5/8" X 7" HMC C2/ ZXP LNR TOP PKR I .'.._!„__.+1..'.'.~i~~J S~ .. 976. DATE REV BY COMMENTS DATE REV BY COMMENTS 03/07A9 ORIGINAL COMPLETION 08/01/07 RCT/PAG GLV GO (05/30107) 12/2SD8 CTD SIDETRACK (07-29A) 02/18!08 SRB/PJC MILL C6P (02/12/080 02/19/09 DAClKK CTD SIDETRACK (07-298) 02/19/08 ITCH FISH CORRECTION (CTM) 01J07/04 JLMlKAK RIO SIDETRACK (07.2lC) 12/06/08 GJBlPJC ADPERF (11175/08) 08/04/04 SRB/KAK CORRECTIONS 01/15109 BSE/SV GLV GO (72/15/08) 01/03/07 OOBITCH ADPERFS (11/20/06) 02/05/09 MSE PROPSEDCTDSIDETRACK PRUDHOE BAY UNIT WELL: 07-29D PERMR No: API No: 50-029-21 782-04 BP Exploration (Alaska) Date: February 17, 2009 To: File , ~ From: Jane Williamson ~ Uv Subject: PBU 7-29C BP has requested approval to plug-back Prudhoe 7-29C Ivishak Zone lA lateral for a CTD sidetrack targeting the same zone in a separate fault block. The well is a cyclic producer, and when on, produces at a GOR exceeding 50 Mscf/STB. No value remains as an oil producer. I recommend approval of this request. o~-29c ~ - ai Rate (cai (bbua > ~+ Gas Fate (CL7j (MUtf/d ) V1~ter Fite (CD/ (bbUd ) - Gas / ai Ratio (ru~/ba > ,ooo - v~ater Cart (°~ ) 500 ,~0 so ~..r ,o 5 0.5 0.3 . _ ~_ -~-~ 2004 05 V' OPERABLE: 07-29C (PTD #2031920)Tubing Integrity Restored Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, December 16, 2008 9:51 AM~~~ 1 Z`~~~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); GPB, EOC Specialists; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Optimization Engr; GPB, Wells Opt Eng Cc: Kaminski, Alice; Holt, Ryan P (ASRC); Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 07-29C (PTD #2031920)Tubing Integrity Restored AI I, ,/ Well 07-29C (PTD #2031920) passed an M!T-IA to 3,000 psi after dummy gas lift valves were set. The passing test confirms that tubing integrity has been restored. The well has been reclassified as Operable. Please call with any questions or concerns. Thanks you, Andrea Hughes Well Integrity Coordinator ~T~;~~.~I, J~1{~ ~ ~~ Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, December 08, 2008 3:12 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GCi/3/FS3); GPB, EOC Specialists; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Optimization Engr; GPB, Wells Opt Eng Cc: Kaminski, Alice; Winslow, Jack L.; Holt, Ryan P (ASRC}; Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: 07-29C (PTD #2031920) for sustained casing pressure due to TxIA Comm Ali, ,~ Well 07-29C (PTD #2031920) has been found to have sustained casing pressure on the IA. The well broke MOASP on 12f05l08 With Ti0 pressures of 2400/24001200 psi. A TEFL was conducted on 12/06108 that failed due to overnight fluid movement and pressure build up. The well has been reclassified as Under Evaluation and has been placed under the 28 day clack. The following corrective action has been put in place. 1. D: TIFL -FAILED 2. S: Caliper tubing, run DGLV's 3. F: MiT-IA to 3000 psi, LLR if fails A TIO plot and wellbore schematic are attached. Please contact me with any questions. Thank you, Taylor Wellman filling in far Anna Dube/Andrea Hughes Office: 659-5102 12/24/2008 OPERABLE: 07-29C (PTD #2031920)Tubing Integrity Restored Page 2 of 2 • Pager: 659-5104 x 1154 12/24/2008 PBU 07-29C PTD 203-192 12/8/2008 i _~ti,. '"~~ ~ =, ~.___.__ ___ .._ _.r__ . ~___.. ,,: ,,;:r:~ mrsa> ~zneroo r r.Ai:x: x•,nrc~~ :=ra~ae ~ansroc~ w~~~~> ~a~~c~c~c ro~zcwa; TREE = 4-1/8" FMC WELLHEAD = FMC ACTUATOR- AXELSON KB. ELEV = 65' BF. ELEV = KOP = 9736 Max Angle = 95 @ 11814' Datum MD = 11220' Datum TV D = 8800' SS -~ ~ ~ SAFETY N~: ORIgNAL W ELLBORE AND "A" SIDETRAC OT SHOW N ON DIAGRAM. 221$' (-~ 4-1/2" HES X NIP, ID = 3.813" 13-318" CSG, 72#, K-55, ID = 12.347" 3767' Minimum ID = 3.725" @ 10365' 4-112" HES XN NIPPLE PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: ?'~? c? 11390' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7f8" 6 11390 - 11440 O 11!20;06 2-7/8" 6 11450 - 11475 O 11/20!06 2-7t8" 6 11820 - 12140 O 01(04/04 2-7!8" 6 12210 - 12450 O 01/04/04 2-7/8" 6 12560 - 12635 O 01/04/04 2-718" 6 12705 - 12930. O 01;04;04 70P OF WHIPSTOCK ~-~ 9736• ESZV -~ 9771' 9-518" CSG. 47#, L-80, 1D = 8.681" 10591' 10300' --~ 4-112" HES X NIP, ID = 3.813" 10321' 7" X 4-1,'2" S-3 PERM PKR, iD = 3.875" 10344' ~ 4-112" HES X NIP, ID = 3.813" 10365' 4-1/2" HES XN NIP, ID = 3.725" 10376' 7" X 4-1/2" HMC C21ZXP LNR TOP PKR ~ 10378' 4-1/2" WLEG •3/8" LNR, 4.41#, L-80, .0036 bpf, ID= 1.92" ~-j 12546' ~ \ 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10373' y 12931' STD 7" CSG, 29#, L-80, .0417 bpf, ID = 6.538" 10522' FISH - WRD CIBP DEBRIS MILLED & PUSHED TO BTM (02/12/08) 12925' CTM 4-1l2" LNR, 12.6#, L-80, .0152 bpf, iD = 3.958" 13019' DATE REV BY COMMENTS DATE REV BY COMMENTS 03!07188 OREG{NAL COMPLETION 06/01/07 RCTlPAG GLV C(O (05r30l07) 12125198 CTD SIDETRACK {07-29A) 02~18i08 SRBiPJC MILL CIBP (02112!080 02/19103 DACIKK CTD SIDETRACK {07-298) 02/19108 /TLH FISH CORRECTION (CTM} 01/07!04 JLMfKA R!G SIDETRACK {07-29C} 06/04/04 SRB/KAK CORRECTIONS 41/03107 OOBfTLH ADPERFS {11120106} GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3191 3160 25 MMG DMY RK 0 05/30/07 3 5801 4999 45 MMG DMY RK 0 05/30/07 2 7957 6514 48 MMG DMY RK 0 01/06(04 1 10064 8014 42 KBG-2 DMY BK 0 01!06/04 9585' ~-~ 9-518" X 7" HMC C21 ZXP LNR TOP PKR MILLOUT WINDOW 9746' - 9762' PRUDHOE BAY UNfr WELL: 07-29C PERMff No: 2031920 API Na: 50-029-21782-03 SEC 33, T11 N, R14E, 452' FNL & 327' FEL BP Explaration {Alaska) ' ~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM SIGN REPORT OF SUNDRY WELL OPERATIONS /~ 8-~ ,~~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver[] Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~' - Exploratory 203-1920 - 3. Address: P.O. Box 196612 Stratigraphic I°°" Service 6. API Number: Anchorage, AK 99519-6612 50-029-21782-03-00 - 7. KB Elevation (ft): 9. Well Name and Number: 52.9 KB - PBU 07-29C - 8. Property Designation: 10. Field/Pool(s): ADLO-028306 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 13020 - feet Plugs (measured) None true vertical 8939.94. feet Junk (measured) 12925 - 2-12-08 1~f~ '- ~ ~~~ +'~~~`~~~ ~ Effective Depth measured 12931 - feet - true vertical 8942.59 - feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 28 - 108 28 - 108 1490 470 Surface 3738 13-3/8" 72# K-55 29 - 3767 29 - 3626 3700 2230 Intermediate 9716 9-5/8" 47# L-80 30 - 9746 30 - 7779 6870 4760 Production 948 7" 29# L-80 9574 - 10522 7650 - 8351 8160 7020 Liner 2650 4-1/2" 12.6# L-80 10369 - 13019 8239 - 8940 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 24 - 10368 0 0 - Packers and SSSV (type and measured depth) 7" Top Packer 9585 4-1/2" Baker S-3 Perm Packer 10320 4-1/2" Baker KB Top Packer 10376 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: SI 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory l~ Development - Service C Daily Report of Well Operations X 16. Well Status after proposed work: Oil - Gas WAG I~ GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 11/24/2008 Form 10-404 Revised 04/2006 - ~* ~, ~ ,, ~~~'~-- ~._ Submit Original Only ~~/°~~ 07-29C 203-1920 oGQ~ e~er_Wiu~tiT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd De th Base 07-29C 1/3/04 PER 11,820. 12,140. 8,950.06 8,944.09 07-29C 1/3/04 PER 12,210. 12,450. 8,945.09 8,946.12 07-29C 1/3/04 PER 12,560. 12,635. 8,943.59 8,939.64 07-29C 1/3/04 PER 12,705. 12,930. 8,938.02 8,942.59 07-29C 4/7/06 BPS 12,665. 12,930. 8,938.68 8,942.59 07-29C 11/19/06 APF 11,450. 11,475. 8,945.95 8,950.43 07-29C 11/20/06 APF 11,450. 11,475. 8,945.95 8,950.43 07-29C 11/21/06 APF 11,390. 11,415. 8,929.57 8,937.26 07-29C 11/21/06 APF 11,415. 11,440. 8,937.26 8,943.74 07-29C 2/12/08 BPP 12,665. 12,930. 8,938.68 8,942.59 07-29C 11/14/08 APF 11,162. 11,172. 8,820.74 8,827.27 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 07-29C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/13/2008'*""`WELL SHUT-IN ON ARRIVAL, SSV OPEN, INITIAL PRESSURES '.2350/500/0. *"`'' ""**JOB CONTINUED 14-NOVEMBER-2008.*""` 11 /14/2008; "`Continued from 11-13-08"T/I/0=2300/550/0 Temp=S/I Assist E-line Load ~TBG (Kill well) Pumped 5 bbl neat followed by 290 bbls 120' crude down !TBG.FWHP'S=100/650/0 DSO notified upon departure E-line stil on well & in 'control of all wellhead valves 11/14/2008'"~""JOB CONTINUED FROM 13-NOVEMBER-2008."""" RAN 3.38" HSD 6SPF ~ 60 DEG PHASED PJ 3406 GUN, SHOT 11162'-11172' DEPTH CORRECTED TO SLB PDC LOG DATED 20-NOV-06. ALL SHOTS FIRED. PUMPED 290 BBLS OF CRUDE PRIOR TO PERFORATING TO SHOOT IN FLUID. DSO l NOTIFIED OF TREE VALVE STATUS, FINAL PRESSURES, 0/600/0, JOB COMPLETE. FLUIDS PUMPED BBLS 1 diesel 1 Total ~' ~,~~~ ~~~~~ STATE OF ALASKA ~~.?SOlj ALASKA OIL AND GAS CONSERVATION COM ~1~510N FHB 2 2 ~~~~ REPORT OF SUNDRY WELL OPERATION~Ska ~,~ $ ~~~ Cons. Cnmmiccinn 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other~~~h~IBP _. Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~] Waiver ~ Time Extension ~ ° Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~~' Exploratory 203-1920 3. Address: P.O. Box 196612 Stratigraphic Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-21782-03-00 7. KB Elevation (ft): 9. Well Name and Number: 52.9 KB - PBU 07-29C 8. Property Designation: 10. Field/Pool(s): _ ADLO-028306 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 13020 l feet Plugs (measured) None true vertical 8939.94 ~ feet Junk (measured) 12925' 2-12-08 f Effective Depth measured 12931 i feet ~~ F~D ~ ~ 2UU$ true vertical 8942.59 - feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 28 - 108 28 - 108 1490 470 SURFACE 3738 13-3/8" 72# K-55 29 - 3767 29 - 3626 3700 2230 INTERMEDIATE 9716 9-5/8" 47# L-80 30 - 9746 30 - 7779 6870 4760 PRODUCTION 948 7" 29# L-80 9574 - 10522 7650 - 8351 8160 7020 LINER 2650 4-1/2" 12.6# L-80 10369 - 13019 8239 - 8940 8430 7500 Perforation depth: Measured depth: 11390 - 11440 11450 - 11475 11820 - 12140 12210 - 12450 12560 - 12635 12705-12930 True Vertical depth: 8930 - 8944 8946 - 8950 8950.06 - 8944.09 8945.09 - 8946.12 8943.59 - 8939.64 8938 - 8943 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 24 - 10378 0 0 - Packers and SSSV (type and measured depth) 7" Top Packer 9585 4-1/2" Baker S-3 Perm Packer 10320 4-1/2" Baker KB Top Packer 10376 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ [ L (.~ }(~f~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 289 23504 3 310 Subsequent to operation: 958 25931 194 708 14. Attachments: 15. Well Class after proposed work: copies of Logs and surveys Run Exploratory ("~ Development ~' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~! GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre ,r' Title Data Management Engineer J Signature Phone 564-4944 Date 2(21(2008 ~ b~~(~~5 • • 07-29C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVlTYDATE SUMMARY _~ 2/10/2008CTU #6, Mill CIBP; MIRU. Cont' on WSR 2/11/08 ... 2111 /2008 CTU #6, Mill CIBP; Cont' from WSR 2/10/08 ... RIH with Baker 2 7/8" Xtreme motor with 3.70" 5- blade concave junk mill. Liquid pack well down backside. Tag plug at 12654' ctmd. Pick up, record freespin, and attempt to mill on plug. Repeatedly stack out weight on plug without achieving motor work. POOH and inspect toolstring. Mill face shows evenly distributed wear. One tooth is missing from face of mill. It seems we were milling on something. RBIH with same BHA with new motor. Dry tagged down at 12678' ctmd. Begin milling on CIBP. Cont' on WSR 2/12/08 ... __ 2/12/2008',CTU #6, Mill CIBP; Cont' from WSR 2/11/08 ... Milling on CIBP at 12676' ctmd. 'At 12682' ctmd, lost all WHP returns oin south. Continue to mill and push ' IBP to bottom. Sat down hard at 12925' ctmd. Attempt to mill and push :deeper with no success. POOH backreaming, seeing some partial stalls and overpulls as if dragging debris at bit. POOH clean from 12210' ctmd. FP well to .:2500' with 60/40. Lay down tools. Found good wear on mill face and some ',scarring on sides. Left well SI. Notified DSO of well status. RD CTU #6. *** 'Job Complete *** NOTE: Caution should be taken when entering horizontal liner because of possible CIBP debris. FLUIDS PUMPED BBLS 78 60/40 METH 367 1 % KCL 445 Total ~'"~-- .~' ~' .~ at''.,` ,.~= MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\C~rPgs_InsertstMicrofilm Marker.doc 07-29C (PTD# 2031920) Classified as Problem Well . All, Well 07-29C (PTD# 2031920) has been found to have sustained casing pressure on the IA. The TIO pressures on OS/20/07 were 2320/1980/28 and the well failed a TIFL on build up rate. The plan forward for this well is as follows: 1. D: TIFL - FAILED on BUR 2. S: Run DGL Vs in sta# 4 & 3 3. F: MITIA '~- q '770 'I 4 Î.t! L- '60 I i"'l.I-vt p::. £tß 7ö ps. <S'ep::: lî5ùr:¡'í (Zß. 'ô t ivŒ Y p) ok p.er CV 41 Z-- A wellbore schematic has been included for reference. «07 -29C.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thanks, Donald Reeves (filling in for Anna Dube) Well Integrity Coordinator 907-659-5102 907-659-5100 x1154 pgr 5~ JUN 0 6 2007 Content-Description: 07 -29C.pdf 07-29C.pdf! Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/1/20074:38 PM TREE " WELLHEAD - ACTUATOR- KB. ELEV - . ELEV - 4-1/8" FMC FMC AXELSON 65' 07 -29C SAFETY NO . ORIGINAL WELLBORE AND" A" SIDETRACK NOT SHOWN ON DIAGRAM. !'v1ax~~:!.gl~_= Datum MD = Datum TVD = 9 95@11814' 11220' 8800' SS 2215' -1 4-1/2"HESXNIP,ID=3.813" I 13-3/8" CSG, 72#, K-55, ID = 12.347" 3767' GAS LIFT MANDRELS ST MD TVD DEV TY PE VLV LATCH PORT DATE 4 3191 3160 25 M1I.1G DOME RK 16 01/18/04 Minimum ID:: 3.725" @ 10365' 3 5801 4999 45 MMG SO RK 20 01/18/04 2 7957 6514 48 MMG DMY RK 0 01/06/04 4-1/2" HES XN NIPPLE 1 10064 8014 42 KBG-2 DMY RK 0 01/06/04 PERFORA TION SUMrv1ARY REF LOG: A NGLE AT TOP PERF: ??? @ 11390' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 6 11390 - 11440 0 11/20/06 2-7/8" 6 11450 - 11475 0 11/20/06 2-7/8" 6 11820-12140 0 01/04/04 2-7/8" 6 12210 - 12450 0 01/04/04 2-7/8" 6 12560 - 12635 0 01/04/04 2-7/8" 6 12705 - 12930 C 01/04104 9585' -1 9-5/8" X 7" HMC C2/ ZXP LNR TOP PKR I MILLOUT WINDOW 9746' - 9762' ESZVI 4-1/2" HES X NIP, 10 = 3.S13" I I TOP OF WHIPSTOCK I 9736' 9771' -i 7" X 4-1/2" S-3 PERM PKR, 10 = 3.875" -i 4-1/2" HES X NIP, 10 = 3.813" I 4-1/2" HES XN NIP, !D = 3.725" 19-5/S" CSG, 47#, L-SO, 10 = 8.681" :: 7" X 4-1/2" HMC C2/ZXP LNR TOP PKR - 4-1/2" WLEG I I 2-3/8" LNR, 4.41#, L-80, .0036 bpf, 10 = 1.92" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" I -J PBTD 7" CSG, 29#, L-80, .0417 bpf, !D = 6.538" I I 4-1/2" WFRD CIBP SET (04/07/06) 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I OA TE REV BY COMMENTS 03/07/88 ORIGINAL COMPLETION 12/25/98 CTD SIDETRACK (07-29A 02/19/03 DAC/KK CTD SIDETRACK (07-298) 01/07/04 JLM/KA RIG SIDETRACK (07-29C) 01/18/04 JLJ/KAK GLV C/O 06/04/04 SRB/KAK CORRECTIONS COMMENTS PRUDHOE SA Y UNrr WELL: 07-29C PERMrr No: 2031920 API No: 50-029-21782-03 SEC 33. T11 N, R14E, 452' FNL & 327' FEL 8P Exploration (Alaska) . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Holej Open Holej Mechanical Logs and j or Tubing Inspection(Caliper j MTI) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services,lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 t:. ~.¡ 1) 2) 3) 4) 5) 6) 7) EDE Disk F - 47A Coil Flag EDE Disk D.S. 12 - 138 Jewelry Log EDE Disk D.S.07 - 29C Coil Flag 26-Oct-06 .:Jðh -('3Ã 1t J~/a'?5 03.Qct-06 " I q ((J - (') ¡-:J- · I t../Q7~ 19-N~m--:;';," " ¡<¡~ Print Name: ê./J--- (I}¡,ì~h ill" mah t/I k~A_ Signed: Date : PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PGSj~i;¡CHCGt1;G¡:@r\ilSji¡lC.;R~n..DG.CC;fu1 WEBSITE : \j\jVifV'\J.;V¡E;VìGR.YLCG,CO~J¡ 0:\00_ PDSA,'C-2006\Z _ W ordlDistnbution\TransmittaJ _ Sheets\Transmit_ OriginaLdoc I STATE OF ALASKA. I?~C~/I/, ALAS Oil AND GAS CONSERVATION COMM NAh NOt-' 3 72'D REPORT OF SUNDRY WELL OPERATIONS 1"'1-8th, . 0 ?r.f D Stimulate 0 Other D liiJ,~ C D WaiverD Time Extension D 4il. .1, ði/s.r>.. o Re-enter Suspended Well D (.I'Vfiige (.,i,¡i)1. 5. Permit to Drill Number: 203-1920 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 52.9 KB 8. Property Designation: ADLO-028306 11. Present Well Condition Summary: Total Depth measured 13020 feet true vertical 8939.94 feet Effective Depth measured 12931 feet true vertical 8942.59 feet Casing Length Size Conductor 80' 20" 91.5# H-40 Surface 3738' 13-3/8" 72# K-55 Intermediate 9716' 9-5/8" 47# L-80 Production 948' 7" 29# L -80 Liner 2650' 4-1/2" 12.6# L-80 Perforation depth: Measured depth: 11820 - 12140 True Vertical depth: 8950.06 - 8944.09 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 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 Daily Report of Well Operations Oil-Bbl 1534 890 x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic MD 28' - 108' 29' - 3767' 30' 9746' 9574' - 10522' 10369' - 13019' 12210 - 12450 8945.09 - 8946.12 4-1/2" 12.6# Exploratory Service 9. Well Name and Number: 10. Field/Pool(s): PRUDHOE 6. API Number: 50-029-21782-03-00 PBU 07-29C D Plugs (measured) None Junk (measuredl' __ None TVD 28' - 108' 29' - 3626' 30' - 7779' 7650' - 8351' 8239' - 8940' 12560 - 12635 8943.59 - 8939.64 L-80 7" Top Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker KB Top Packer o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 65002 0 0 6644 245 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Signature C'{" to. Í'\.\l<.tí:::.:n [1F (~ ~ t:. ù_/r"tJ'ti::~w.tJ-' ¥;,,' - I ,..- ~- Burst 1490 3700 6870 8160 8430 Collapse 470 2230 4760 7020 7500 12705 - 12930 8938.02 - 8942.59 SURFACE· 10378' 9585 10320 10376 o Tubing pressure 259 255 Service Title Data Engineer Phone 564-4944 WINJ WDSPL Date 11/29/2006 o 4 2006 Submit Original Only . . 07-29C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/18/2006 CTU #8, Perf / Acid Stim; MIRU unit. Perform slack management on iCoil capilary. Connect iCoil head and perform line test. Connection tests from both sides of reel indicate fiber-optic line is broken 3700' from the base of the reel. Blow down reel with nitrogen. RDMO and road unit to shop for reel swap back to conventional coil. *** Job Incomplete *** 11/19/2006 CTU# 8, Perforating. MIRU, RIH with PDS logging string & 3,0" DJN for tie-in log, Log GR/CCL from 10,016'-11,618'. POOH. MU and RIH with 1st set of guns. While RIH weights became more and more erratic. PUH and determine that we have an ice sheath around us. Eventually coil was unable to move. Call out LRS to pump hot diesel down IA. ... Cont' on WSR 11/20/06 ... 11/19/2006 Assist coil TBG rd to location start up job in progress 11/20/2006 CTU #8, Perf / Acid Stim; .., Cant' from WSR 11/19/06 ... LRS pumped 300 bbls of hot diesel down IA and eventually coil came free. Ensure well is freeze protected and and ice around coil is thawed with 60/40 meth. Cant' RIH to flag and correct depth. Perforate interval 11 ,450-11 ,475 corrected depth with 2-7/8" powerjet omega, HMX 6 spf. POOH. MU 2nd set of guns and RIH to flag an correct depth. 2nd run misfired due to leaking MHA (MHA was pressure tested prior to RIH). POOH. MU and RIH with SLB gr /ccl and 3.0" OD JSN, .,. Cant' on WSR 11/21/06,.. 11/20/2006 Continued from 11-19-06 T/I/O=21 00/300/80 Assist coil TBG Pumped 308 bbls of 180* diesel down IA followed by 49 bbls of 180* crude Final Whp's=1300/225/50 11/21J2006 CTU #8, Perf / Acid Stim; ,., Cont' from 11/20/06... Log gr/ccl over interval 11425'-11980' ctmd, Paint flag at 11247' ctmd. POOH. MU and RIH with 2nd set of guns, Perforate interval 11,415'-11,440' corrected depth with 2-7/8" PJ Omega, HMX 6 spf. POOH. MU and RIH with 3rd set of guns. Perforate interval 11 ,390'- 11,415' corrected depth with 2-7/8" PJ Omega, HMX 6 spf. POOH. MU and RIH with 2.5" JSN. Drift lower perfs down to 12,645' ctmd. PUH to 10,500' and fluid pack well with 160 bbls 1 % KCL followed by 40 bbls of diesel. Establish initial injectivityof 1150 psi at 1.0 bpm. Jet 30 bbls of diesel across interval 11 ,810'- 12645' ctmd at 1.3 bpm. WHP fell approx 100 psi during jetting. ... Cont' on WSR 11/22/06 ... 11/22/2006 CTU #8, Perf / Acid Stim; ,.. Cant' from WSR 11/21 50 bbls DAD 15% HCL across interval 11 ,810'-12,635' ctmd at 1,5 bpm, followed by 50 bbls 1 % KCL. WHP fell approx 200 psi over the course of the stimulation. Final injectivity 800 psi at 1.0 bpm and 1150 psi at 1.5 bpm. POOH. RDMO. *** Job Complete *** . . FLUIDS PUMPED BBLS 66 1 % KCL 28 DIESEL 50 DAD 15% HCL 80 60/40 METH 224 TOTAL e e WELL LOG TRANSMITTAL ~ ,q~ /35l£l) To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 RE: MWD Formation Evaluation Logs 07-29C, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 07-29C: LAS Data & Digital Log hnages: 50-029-21782-03 1 CD Rom ß1íibL~ ~I :J ~/ótrJ -g ~b DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Operator BP EXPLORATION (ALASKA) INC Permit to Drill 2031920 Well Name/No. PRUDHOE BAY UNIT 07-29C I/r; I 'J..~... "f 8940 ;'"" Completion Date ~4 " Completion Status 1-01L MD 13020,. TVD ~- REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: DIR,GR,RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No (¿ ~ Directional Survey Directional Survey Induction/Resistivity Rate Gf "-IIdrällon ~ ~ Inr.J¡l,..tion/Roci~hdy. U.""ç.~~:, ~ R~tp nf IF'enf-l,,,,lI''on ,?_/J D ../J.JìM ~\ ~ 12410 D ~ \..\ ~ 12410 ED ED Rpt ,~ ~ I I 2-4 2-4 2-4 Leak 2 Blu -~- Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Daily History Received? Formation Tops Analysis Received? ~/ -------- Comments: !f1~J.. ^)-~À()~ API No. 50-029-21782-03-00 Current Status 1-01L UIC N Directional G;ey ) ./ Yes (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH . Received Comments 9733 13020 1/13/2004 9733 13020 1/13/2004 MWD 9580 12969 2/19/2004 GR, EWR4, ROP 9580 12969 2/19/2004 GR, EWR4, ROP 9580 12969 2/19/2004 GR, EWR4, ROP 9~O 1!WO'J ;)'W.C::JCi en, ::wn I, ",or 10123 12945 Case 213/2005 mem borax log/mem gr/ccllcn1/ Sample . Set Number Comments 0N ~/N DATA SUBMITTAL COMPLIANCE REPORT 1/5/2006 Permit to Drill 2031920 Well Name/No. PRUDHOE BAY UNIT 07-29C Operator BP EXPLORATION (ALASKA) INC MD 13020 TVD 8940 Completion Date 1/8/2004 Completion Status 1-01L Current Status 1-01L ~,--- Compliance Reviewed By: Date: API No. 50-029-21782-03-00 UIC N . . Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . Well Job # 10715391 10728396 10715393 10715395 10715402 10715404 10670016 10715406 10715407 10861913 10715410 10861916 10715413 10861920 10715418 10715421 2.20'b)'ij, ß-12B ~15-3SB ;¡O:3 - i q 4 -",¡¡j-¡ ¡ C D-04B / DS 18-13A Lc'!;-I"¡S K-10B DS 02-15A 1 _ ¡.,,, DS 2-33A "-: ".... L..? /9FtX;) DS 07 -03A 2tJ}.¡q¿ DS 07-29C !17'ðþ E-15B %11 -ì5i.f DS 18-27C ~Jj.;'t).C«¡ E-24B r1,. /09 DS 18-31 ~.¡- il 0 K-09C ./0'1-0'11 C-17B ('1) .&14 C-39 . (Prints . T only-Job not complete) MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL i07S~ /}¿, 3 --;:7\} ':./' t (:. (12. 01/24/05 NO. 3318 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 03/21/04 1 04/03/04 1 04/07/04 1 04/16/04 1 05/16/04 1 05/18/04 1 OS/23/04 1 06/03/04 1 06/04/04 1 06/05/04 1 06/13/04 1 06/20/04 1 07/05/04 1 07/16/04 1 08/10/04 1 08/19/04 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 'j c:0 /013 I I Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 åL ATTN: Beth A (7 Reo' ed by ~¡" CUt'~~ . . &Ld~}C¡~ WELL LOG TRANSMI'ITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska February 12,2004 RE: MWD Formation Evaluation Logs 7-29C, AK-MW-2827126 1 LDWG formatted Disc with verification listing. API#: 50-029-21782-03 j é9 Lf /0 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: " ~.~ .~ Signed: ~\"-'- )~\,\,,_C ~:YY, RECEIVED ,F" 1," 11(\,'\ · .; / ~ ,I J Ii , ...-vv'+ ,A,¡I$~Mª C~ Or. GasC{\JI$.Co~ '\r:'I"¡'~.. r";.,,~·,"f' " ' ·...,'v..,· .... ~~~ \\\.~ . STATE OF ALASKA ALAS~ AND GAS CONSERVATION COM.ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 452' SNL, 327' WEL, SEC. 33, T11N, R14E, UM Top of Productive Horizon: 245' NSL, 223' WEL, SEC. 21, T11 N, R14E, UM Total Depth: 1858' NSL, 54' WEL, SEC. 21, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 675856' y- 5950465' Zone- ASP4 TPI: x- 675807 y- 5956442 Zone- ASP4 Total Depth: x- 675~; ÂY- 5958058' Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: DIR, GR, RES One Other 5. Date Comp., Susp., or Aband. 1/5/2004 / 6. Date Spudded 12125/2003 7. Date T.D. Reached 12/31/2003 I 8. KB Elevation (ft): 52.9' 9. Plug Back Depth (MD+ TVD) 12931 + 8943 10. Total Depth (MD+ TVD) , 13020 + 8940 f 11. Depth where SSSV set (Nipple) 2215' MD 19. Water depth, if offshore NIA MSL CASING SIZE 20" 13-318" 9-518" 7" 4-1/2" CASING, LINER AND CEMENTING RECORD SErTINGDEPTH MP SETTING DEPTHTVP BOTTOM Top BOTTOM 110' Surface 110' 3767' Surface 3626' 9746' Surface 7779' 10522' 7650' 8351' 13019' 8239' 8940' 22. 91.5# 68# 1 72# 47# 29# 12.6# H-40 K-55 I L-80 L-80 L-80 L-80 Surface Surface Surface 9574' 10369' 23. Perforations open to Production (MD + TVD of To,e and Bottom Interval, Size and Number; if none, state' none"): 2-7/8" Gun Diameter, 6spf MD TVD MD TVD 11820' - 12140' 8950' - 8944' 12210' - 12450' 8945' - 8946' 12560' - 12635' 8944' - 8940' 12705' - 12930' 8938' - 8943' None Form 10-407 Revised 12/2003 30" 17-1/2" 12-1/4" 8-112" 6" 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-192 13. API Number 50- 029-21782-03-00 14. Well Name and Number: PBU 07 -29C 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028306 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) ·-yíU'~~ "1; 79b / /YI P /.779' ;rv;D 2568 # Poleset 291 sx CS II, 3000 sX CS III, 500 sx Class 'G' 354 sx CS I, 700 sx Class 'G' 198 sx Class 'G' 303 sx Class 'G' SIZE 4-1/2", 12.6#, L-80 DEPTH SET (MD) 10378' PACKER SET (MD) 10321' 25. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 160 Bbls of Diesel CONTINUED ON REVERSE SIDE GI~ ~BFl 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): January 23, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-Bsl 1/24/2004 6.1 TEST PERIOD" 2,382 23,873 -0- Flow Tubing Casing Pressure CALCULATED ..... Oll-Bsl GAs-McF WATER-Bsl Press. 314 24-HoUR RATE""" 9,732 93,927 090 27. Brief description of lithology, porosity, fractures, apparent~~;: ~';;~resence of oil, gas or water (attacRJ¡~fšD.Mt!i~~sary). Submit core chips; if none, state "none". rc¡ï~,;;tr;:'lõÑ1 '¡ J " ¡ il ~j 1'. ,,!'" ~. ' .~ !./ D-?oi¡ 0 R I IÃ¿-~ · GINAL \;.._-_.........~,.,_.~ CHOKE SIZE I GAS-Oil RATIO 83 10,024 Oil GRAVITY-API (CORR) FEB 0 3 2004 Alaska Oil P.i Gas Al1c.hor3g¡~ FEB 04 20(1~ , v 28. GEOLOGIC MARKERS. NAME MD TVD Sag River 10522' 8351' Shublik A 10573' 8389' Shublik B 10597' 8407' Shublik C 10619' 8423' Eileen 10638' 8437' Sadlerochit 10647' 8444' Zone 31 Top CGL 10860' 8601' Zone 2C I Base CGL 10948' 8665' 23SB I Zone 2B 11044' 8737' 21TS I Zone 2A 11190' 8839' Zone 1 B 11321' 8904' Zone 1A 11390' 8930' 29. .RMATlON TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECEI FEB 0 3 2004 Alaska 011 & Gas Cons. AnchoragfJ 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~^.^ L1 fl~lJ_ Ttl T h IA t t D t OI')~03-0U Terrie Hubble ~I O/V ~ ~ ~ i e ec nica ssis an a e ^ ì. PBU 07 -29C 203-192 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Rob Tirpack, 564-4166 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 20: True vertical thickness. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 nDI('!~!f\ Printed: 1/1312004 3:17:04 PM . . EMW 12.00 (ppg) 9.44 (ppg) .......-..-...-- Page 1 of 1 Leak Off Pressure (BHP) 4,834 (psi) 4,094 (psi) -...--.... Surface Pressure 485 (psi) 450 (psi) AMW 10.80 (ppg) 8.40 (ppg) Test Depth (TVD) ....................~. - ¥. 7,752.0 (ft) 8,350.0 (ft) BP EXPLORATION Leak-Off Test Summary . ._Ie~tDeE~ (TMD) 9,782.0 (ft) 10,522.0 (ft) Test Type -. FIT FIT Test Date 12/24/2003 12/27/2003 Legal Name: 07 -29 Common Name: 07 -29C Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To ---.--...- 12/18/2003 17:30 - 00:00 12/19/2003 00:00 - 03:30 03:30 - 05:00 05:00 - 17:00 17:00 - 21 :00 21 :00 - 00:00 12/20/2003 00:00 - 08:00 08:00 - 15:30 15:30 - 17:30 17:30 - 00:00 \~ - BP EXPLORATION Operati'ons Summary Report 07 -29 07 -29C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Hours! Task Code NPT 6.50 MOB P 3.50 MOB P 1.50 MOB P 12.00 MOB P 4.00 MOB P 3.00 MOB N PRE WAIT PRE Page 1 of 9 Start: Rig Release: Rig Number: Phase 12/18/2003 1/5/2004 2 Spud Date: 2/14/1988 End: 1/5/2004 PRE PRE PRE PRE PRE PRE PRE 12/21/2003 00:00 - 07:00 7.00 RIGU P PRE 07:00 - 07:30 0.50 RIGU P DECOMP 07:30 - 09:00 1.50 WHSUR P DECOMP 09:00 - 13:30 4.50 KILL P DECOMP 8.00 MOB N WAIT PRE 13:30 - 14:30 1.00 WHSUR P DECOMP 14:30 - 16:30 2.00 WHSUR P DECOMP 16:30 - 22:00 5.50 BOPSURP DECOMP 7.50 MOB P 2.00 RIGU P 6.50 RIGU P Description of Operations .-------- Rig Down Rig Floor And Can-Rig Top Drive - Lay down Mast. Load up Pit Complex and Satellite Camp. Load up Truck Shop. Ready the Sub for move to DS 7-29C Move the Pit Complex and the Satellite Camp over to DS 07-29C. Move the 2ES Substructure from S-27B to DS 07-29C. Rig moving system front, inside tire locked up at the S pad turnoff. Get replacement parts, motor and clutch, off of 3S and fix 2ES. Test moving system. Begin travelling down the road @ 1700 hrs. Begin moving from the S pad turnoff to J pad. CPS was to measure the max height of the rig at J pad to assure themselves that there would be no contact made with the overhead lines. At 2100, when the rig got to J pad, the winds had picked up to greater than 20 mph and it was deemed unsafe to use the manlift At this time, the rig was stopped from moving to wait for the weather to break. Currently the rig is sitting on the Spine Road next to J pad. As of 11 :45pm, the field has gone to a Phase 2 condition. Note: On Standby Waiting on Weather as of 210012/19/2003 Continue standby waiting on weather (with full crews) to break so CPS can measure the height of the rig and allow it to pass under the power lines. Changeout the double gate ram bodies on the BOP stack while waiting on weather. As of 0300, the main roads are Phase 1 and the access roads and pads are Phase 2. Wind speed reduced to less than 20 mph - Phase 1. CPS measured the height of the rig and the rig was allowed to continue from J pad to DS 7. Note: Total Rig standby time (with full crews) - 11 hours. Set Herculite. Spot Sub Base over well 7-29C. Work on Mud Pump #2 installation. Hold PJSM, raise and pin the derrick. Spot the pits, cuttings tank, Mud and Geo shacks. Spot the camp, truck and welding shops. Berm in the rig and start taking on seawater. Hang Bridle lines and continue to rig up and install #2 mud pump. Roll the pump with seawater to test - good. Accept Rig 0700 12/21/2003 Hold Rig Pre-spud safety meeting and review the Pre-spud Checklist. Rig up to displace out the diesel freeze protection fluid. Pull BPV with lubricator - 0 psi on tubing and annulus. Reverse circulate out the diesel through the choke to the cuttings tank @ 3bpm. Pump 40 bbl Safe-Clean pill to surface the long way @ 9bpm until fluid was clean. Monitor the well and blow down lines. Well static. Install BPV. Test from below to 1000psi for 10 minutes. Nipple down the tree and adapter flange. Install Blanking plug. Send off tree and adapter for inspection and possible reuse on this well. Nipple up the BOP's. Check and tighten all flanges. Install top 3.5"x6" variable rams and blind/shear rams. Install mousehole. Load pipeshed Printed: 2/2/2004 11 :21:13 AM ~ . Page 2 of 9 BP EXPLORATION Operations Summary Report DECOMP Test BOP's and all related valves to 250 psi low and 3,500 psi high. Note: Called AOGCC Rep John Crisp who waived the witnessing of the test. DECOMP Continue testing BOP's to 250 psi low and 3,500 psi high. DECOMP Pull Blanking Plug with FMC. Rig up DSM Lubricator to pull BPV. Bring tubing handling equipment to the floor. DECOMP Pull BPV with Lubricator - no pressure seen. Rig down the lubricator and clear the floor. Attach crossover to landing joint. Changeout elevators, pick up landing joint and screw into 9" LH ACME threads with 6-1/2 turns. POH with Tubing Hanger. P/U - 130K with no over pull. Cut appears to be clean. Lay down the tubing hanger and clear the floor. Rig up Camco to spool up 2 control lines. Rig up Camco control line spooling unit and lay down 4.5" tubing to SSSV (tubing cut estimated to be 9820'). Rig down spooling unit and clear the floor. Retrieved 73 of 74 bands. Lay down 4.5", 12.6 # L-80 tubing from 7,597' to surface. 311 jts of tubing + 4.27' of the next joint, 5 GLM's, 1 SSSV pulled out of the hole. Rig down tubing handling equipment and clear the floor. Test BOP's with 4" HT -40 Test jt. Install wear ring. PJSM with Schlumerger. Rig up Schlumberger. RIH with CCLlJB and 8.5" GR. Tag up at 9,771' WLM. Pull up 200 ft and try 2 more times. Each time, same result. POH with E-line. Confer with town to ensure okay to set EZSV @ 9,771' WLM· below the Top of the HRZ. Confer with Baker hand that EZSV @ 9,771' would be okay to mill the window. Estimate that EZSV would be -8' above the next casing collar having seen one @ 9,737' WLM. Plan forward to set EZSV at 9,771'. RIH with EZSV to 9,771' MD. Set EZSV. Top of whipstock calculates out to 7' below next collar seen on logs at 9,737'. POH with Schlumberger. RID Schlumberger. Clear the floor. Pressure test the 9-5/8" casing to 3500 psi and hold for 30 minutes - good test. Bleed off pressure. PJSM. M/U BHA. Upload and Surface test MWD. M/U Whipstock assembly. P/U 9 Drill Collars and 18 jts of HWDP. Single in the hole with Whipstock BHA on 4" Drill Pipe to 6,552'. Fill the pipe and test MWD every 3,000'. Cut and slip drilling line - cut 115'. RIH with Whipstock BHA from 6,552' to 9,729'. Break circulation and orient whipstock to 24 degrees LHS. P/U- 200K, S/O - 160K RIH and tag bottom @ 9769'. Set down 20K to set the anchor. Surface indication that anchor is set. P/U 5K to verify anchor is set. Set down 45K to shear bolt. Surface indication bolt sheared. P/U to neutral - top of whipstock and chain the brake handle down. Whipstock set at 24 degrees LHS. WEXIT Swap over fluids to 10.8 ppg LSND fluid - 500 gpm @ 1700 psi WEXIT Mill window and 20' of new hole from 9,746' to 9,778'. Bit weight - 9-20K, TQ - 6-12K. ROP - 3-5 ftIhr. 500 - 525 gpm, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-29 07 -29C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date , ¡ ! From - To Hours Task Code NPT Phase ¡ --------.---. .... ._........._.........__.-._..._~ ..-......--..-.....- 12/21/2003 22:00 - 00:00 2.00 BOPSURP 12/22/2003 00:00 - 02:00 02:00 - 03:00 2.00 BOPSUR P 1.00 WHSUR P 03:00 - 04:00 1.00 WHSUR P 04:00 - 05:00 1.00 PULL P DECOMP 05:00 - 09:00 4.00 PULL P DECOMP 09:00 - 18:30 9.50 PULL P DECOMP 18:30 - 19:30 1.00 PULL P DECOMP 19:30-21:00 1.50 PULL P DECOMP 21 :00 - 22:00 1.00 PULL P DECOMP 22:00 - 00:00 2.00 PULL P DECOMP 12/23/2003 00:00 - 01 :30 1.50 PULL P DECOMP 01:30 - 03:15 1.75 PULL P DECOMP 03:15 - 04:30 1.25 PULL P DECOMP 04:30 - 05:30 1.00 PULL P DECOMP 05:30 - 08:00 2.50 STWHIP P WEXIT 08:00 - 10:30 2.50 STWHIP P WEXIT 10:30 - 17:00 6.50 STWHIP P WEXIT 17:00 - 18:00 1.00 STWHIP P WEXIT 18:00 - 22:30 4.50 STWHIP P WEXIT 22:30 - 23:00 0.50 STWHIP P WEXIT 23:00 - 00:00 12/24/2003 00:00 - 07:30 1.00 STWHIP P 7.50 STWHIP P Start: Rig Release: Rig Number: Spud Date: 2/14/1988 End: 1/5/2004 12/18/2003 1/5/2004 2 Description of Operations Printed: 2/2/2004 11 :21: 13 AM . . Page 3 of 9 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES i Date From - To i Hours Task Code NPT Phase 12/24/2003 00:00 - 07:30 7.50 STWHIP P WEXIT 07:30 - 08:30 1.00 STWHIP P WEXIT 08:30 - 09:30 1.00 STWHIP P WEXIT 09:30 - 14:30 5.00 STWHIP P WEXIT 14:30 - 16:00 1.50 STWHIP P WEXIT 16:00 - 18:30 2.50 DRILL P INT1 18:30 - 23:00 4.50 DRILL P INT1 23:00 - 00:00 1.00 DRILL P INT1 12/25/2003 00:00 - 11 :30 11.50 DRILL P INT1 11 :30 - 12:30 1.00 DRILL P INT1 12:30 - 16:30 4.00 DRILL P INT1 16:30 - 18:30 2.00 DRILL P INT1 18:30 - 19:30 1.00 DRILL P INT1 19:30 - 20:00 0.50 DRILL P INT1 20:00 - 23:30 3.50 DRILL P INT1 23:30 - 00:00 0.50 DRILL P INT1 12/26/2003 00:00 - 04:00 4.00 DRILL P INT1 04:00 - 07:00 3.00 BOPSURP INT1 07:00 - 09:30 2.50 CASE P INT1 09:30 - 10:00 0.50 CASE P INT1 10:00 - 16:00 6.00 CASE P INT1 16:00 - 16:30 0.50 CASE P INT1 16:30 - 17:30 1.00 CASE P INT1 17:30 - 19:30 2.00 CEMT P INT1 19:30 - 20:00 0.50 CASE P INT1 Start: Rig Release: Rig Number: Spud Date: 2/14/1988 End: 1/5/2004 12/18/2003 1/5/2004 2 Description of Operations 2,600 psi. TOW - 9,746', BOW - 9,762'. P/U - 195K, S/O- 150K, Rot - 165K. Recovered 35# of metal. Circ sweep. Stand back one stand of 4" drillpipe. Perform FIT to 12.0 ppg EMW and hold for 10 minutes POH with Milling BHA from 9,778'. UD UBHO, Bumper Sub and Mills. Clear floor. Pull Wear Ring. Flush stack. Function test rams. Install Wear Ring. PJSM. P/U Drilling BHA. Orient MWD. Shallow Pulse Test MWD - 500 gpm @ 950 psi. RIH to 9,559' filling pipe and testing MWD every 3,000'. Install blower hose. Break Circulation - 500 gpm, 2900 psi. Orient MWD to -30 LHS. RIH to 9,636'. LWD from 9,636' to 9,736'. Check orientation. P/U - 190K, S/O - 150K Complete orientation. RIH through window and drill directionally to TD - 10,522'. P/U - 205K, S/O - 150K, Rot - 175K, TQ - 11 K, 520 gpm, 3,410 psi. Lost circulation @ 10,522'. Open Kill lines and fill annulus. Loss of 135 bbls. POH into the casing @ 9,650'. Monitor the well. Blow down the top drive and surface equipment. Fill across the top to establish loss rate. Hole stable. Build mud volume. Service Top Drive. Mix 100 bbl LCM pill at 30#/bbl. RIH to 10,522' without problem. Break circulation. Stage up pumps to 4 bpm @ 850 psi and spot LCM pill. POH into casing @ 9,650'. No problems tripping to shoe. Monitor well. Static. Pump dry job and drop 2-3/8" rabbit. POH from 9,650' to 1,064'. No losses. UD 5" HWDP to 877' UD remaining BHA. Down load and flush MWD. Clear the floor. Install 7" rams in the upper set. Pull wear ring. Install test plug and test to 3500 psi. Re-install wear ring. RU casing handling equipment. PJSM. PU 7", 29# NSCC Liner. RIH. PU hanger/packer assembly. Pump liner volume @ 3 bpm and 120 psi. Rig down casing handling equipment and clear the floor. RIH with liner on 4" drill pipe from the derrick to 9,740'. Fill pipe every 10 stands. No losses. Circ at TOW - 9,740'. No losses. Run in open hole. PU - 187K, SO - 127K. MU cement head on single and RIH. Tag bottom @ 10,522'. Break circ and stage up to 4 bpm without losses. PJSM. PT lines to 4500 psi. Pump 26.8 bbls 12ppg Mudpush spacer, 42.7 bbls 15.8 ppg Class G cement, displace with 126 bbls of 10.8 ppg LSND fluid @ 4 bpm. No losses. Bump plug on calculated volume. Cement in place @ 19:15. Pressure up to 3500 psi and set the HMC hanger. Release from the hanger and circulate cement returns up the hole. Set weight down to set the ZXP packer. Rotate down to ensure set. Printed: 2/2/2004 11 :21 : 13 AM . . BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-29 07 -29C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date , I From - To Hours ¡ Task Code I NPT Phase 12/26/2003 20:00 - 20:30 0.50 CASE P INT1 20:30 - 00:00 3.50 CASE P INT1 12/27/2003 00:00 - 02:00 2.00 CASE P INT1 02:00 - 06:00 4.00 BOPSURP INT1 06:00 - 07:00 1.00 CASE P INT1 07:00 - 08:30 1.50 DRILL P PROD1 08:30 - 10:30 2.00 DRILL P PROD1 10:30 - 13:00 2.50 DRILL P PROD1 13:00 - 14:30 1.50 DRILL P PROD1 14:30 - 15:30 1.00 DRILL P PROD1 15:30 - 17:30 2.00 DRILL P PROD1 17:30 - 21 :00 3.50 DRILL P PROD1 21 :00 - 21 :30 0.50 DRILL P PROD1 21 :30 - 22:30 1.00 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 12/28/2003 00:00 - 00:00 24.00 DRILL P PROD1 12/29/2003 00:00 - 15:00 15.00 DRILL P PROD1 15:00 - 16:30 1.50 DRILL P PROD1 16:30-21:00 4.50 DRILL P PROD1 21 :00 - 00:00 3.00 DRILL P PROD1 12/30/2003 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 06:30 4.00 DRILL N WAIT PROD1 06:30 - 10:30 4.00 DRILL P PROD1 10:30 - 11 :00 0.50 DRILL P PROD1 11 :00 - 11 :30 0.50 DRILL P PROD1 11 :30 - 13:00 1.50 DRILL P PROD1 13:00 - 00:00 11.00 DRILL P PROD1 Page 4 of 9 Start: 12/18/2003 Rig Release: 1/5/2004 Rig Number: 2 Spud Date: 2/14/1988 End: 1/5/2004 Description of Operations ... .... .~.. - ---- CBU @ 12 bpm. LD cement head and a single. POH from 9,574' to 3,900'. POH from 3,900'. LD C2 running tool. Clear the floor. Change out top set of rams from 7" to 3.5" x 6" variable rams. Test BOP's - 250 psi low and 3,500 psi high. AOGCC witness of the test waived by Jeff Jones. Pressure test casing to 3,500 psi and hold for 30 minutes - good test. PU BHA #3 to 196' and shallow pulse test MWD. PU 105 jts of drill pipe and RIH from 196' to 3,460'. RIH from 3,460' to 9,525'. Fill pipe every 3,000' Cut and slip 93' of drilling line. Service top drive and crown. RIH and tag landing collar insert @ 10,438' Drill out float equipment and cement from 10,438' to 10,518' Pump 125 bbl spacer/water sweep and displace the wellbore to 8.4 ppg FloPro mud @ 275 gpm, 1400 psi. Drill shoe and 20' of new hole to 10,545' Pull into shoe and perform FIT to 9.6 ppg. Pressure during test dropped off and held @ 450 psi for an EMW of 9.44 ppg. Drill from 10,545' to 10,600'. ART -1.42 hrs. PU -170K, SO- 145K, ROT - 165K. TQ 5-6K, 250 gpm, 1520 psi on bottom. Drilled 6" Directional Hole By Rotating And Sliding From 10,600' To 11,458' WOB Rotating 15,000# - 20,000#, WOB Sliding 15,000# To 25,000#, RPM 80 To 90, Motor RPM 82, Torque Off Bottom 6,000 ft /Ibs - On Bottom 7,000 ft /Ibs, Pump Rate 270 gpm, SPP Off Bottom 1,520 psi, On Bottom 1,700 psi. String Weight Up 185,000#, String Weight Down 145,000#, String Weight Rotating 168,000# - ART = 6.82 hrs. - AST= 10.13 hrs. Drilled 6" Directional Hole By Rotating And Sliding From 11,458' To 11,862'. ART=6.5 hrs AST=6 hrs UP WT=185K DN WT=145K ROT WT=168K Circ. POH to shoe @ 10,522'. (Weather went to Phase 3) Drop bar and open circ sub. POH f/10,522' to 198'. Handle BHA. UD Jars, MWD, bit and motor. Start P/U BHA #4. Make Up BHA No.4 And RIH To 191' - Pick Up 5" Sperry Sun Motor, Make Up 6" Smith MDT52 PDC Bit, Pick Up Float Sub, String Stabilizer, And MWD / LWD Tools - Orient And Initialize MWD/LWD Tools - RIH Out Of Mast With (3) Flex Drill Collars, Dailey Mechanical Jars, Make Up Circulating Sub, And Cross Over Sub - Surface Test Sperry Sun Equipment (Test Good) Phase 3 Weather Conditions - Wait On Weather RIH With Directional BHA No.4 From 191' To 10,455' - Fill Drill String Every 3,000 Feet Service Top Drive And Traveling Blocks RIH With Directional BHA No.4 From 10,455' To 11,160' Wash And Ream Under Gage Hole From 11,160' To 11,862' Drilled 6" Directional Hole By Rotating And Sliding From 11,862' To 12,510' WOB Rotating 5,000# - 12,000#, WOB Sliding 5,000# To 12,000#, RPM 85, Motor RPM 246, Torque Off Bottom 5,000 ft /Ibs - On Bottom 7,000 ft /Ibs, Pump Rate 320 gpm, SPP Off Bottom 1,950 psi, On Bottom 2,400 psi. Printed: 2/2/2004 11:21:13AM ... .. Page 5 of 9 BP EXPLORATION Operations Summary Report String Weight Up 184,000#, String Weight Down 140,000#, String Weight Rotating 165,000# - ART = 4.43 hrs. - AST = 1.49 hrs Drilled 6" Directional Hole By Rotating And Sliding From 12,510' To 13,020' WOB Rotating 10,000# - 20,000#, WOB Sliding 10,000# To 20,000#, RPM 85, Motor RPM 246, Torque Off Bottom 6,000 ft /Ibs - On Bottom 8,000 ft /Ibs, Pump Rate 320 gpm, SPP Off Bottom 2,000 psi, On Bottom 2,400 psi. String Weight Up 185,000#, String Weight Down 138,000#, String Weight Rotating 165,000# - ART = 5.49 hrs. - AST = 8.63 hrs Circulate Sweep Around At 7.6 BPM With 2,000 Psi. While Rotating And Reciprocating Drill String Monitor Well Bore (Static) - Wiper Trip POH With Directional BHA No.4 From 13,020' To 11,769' With No Problems RIH With Directional BHA No.4 From 11,769' To 13,020' With No Problems Circulate Hole Clean At 7.6 BPM With 2,000 Psi. While Rotating And Reciprocating Drill String Monitor Well Bore (Static) - POH With Directional BHA No.4 From 13,020' To 10,549' Drop Dart And Open Circulation Sub - Circulate Bottoms Up At 12.5 BPM With 1,300 Psi. - Remove Blower Hose - Monitor Well Bore (Static) - Pump Dry Job And Blow Down Surface Equipment PROD1 POH With Directional BHA NO.4 From 10,549' To 191' PROD1 POH Laying Down Directional BHA No.4 From 191' - Lay Down Cross Over Sub, Circ. Sub, Dailey Jars, (3) Flex Drill Collars - Flush Out BHA With Fresh Water And Blow Down Surface Equipment - Down Load Sperry Sun MWD/LWD Tools - Lay Down Hang Off Collars, MWD/LWD Tools, Float Sub, And String Stabilizer, Remove Smith 6" PDC Bit And Lay Down Mud Motor - Clear Rig Floor COMP Rig Up Power Tongs - Casing Tools And Equipment COMP Hold Pre-Job Safety Meeting With All Personal Regarding Liner Running Operation - Pick Up And RIH With Shoe Track - Baker Lock Connections To Landing Collar Joint NO.3 - Verify Floats Holding - RIH With 63 Joints Of 41/2" IBT-M 12.6 lb. L-80 Casing To 2,625' - Make Up To Mark Torqued To 3,200 ftIlbs. COMP Change Out Handling Equipment To 3 1/2" DP Elevators - M / U Baker HMC Liner Hanger, ZXP Packer, Liner Tie Back Sleeve, And Running Tool - Change Out Handling Equipment 4" DP Elevators P / U Cross Over, (1) 4" Drill Pipe Pup Joint, RIH w/1 Stand 4" Drill Pipe From Mast To 2,767' Circulate 41/2" Liner Volume At 220 GPM With 170 Psi. - Recorded Liner Weight At 30,000# RIH With 63 Joints Of 41/2" IBT-M 12.6 lb. L-80 Liner On 4" Drill Pipe From 2,767' To 10,480' - Fill 4" Drill Pipe Every 10 Stands Circulate 4 1/2" Drill Pipe And Liner Volume At 220 GPM With 560 Psi. - String Weight Up 166,000#, String Weight Down 135,000# RIH With 41/2" IBT-M 12.6 lb. L-80 Liner On 4" Drill Pipe From Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-29 07 -29C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES i Date From - To Hours Task 'Code NPT Phase I -.-.-.-.-----.--.....-..... 12/30/2003 13:00 - 00:00 11.00 DRILL P PROD1 12/31/2003 00:00 - 18:00 18.00 DRILL P PROD1 18:00 - 20:00 2.00 DRILL P PROD1 20:00 - 21 :00 1.00 DRILL P PROD1 21 :00 - 21 :30 0.50 DRILL P PROD1 21 :30 - 00:00 2.50 DRILL P PROD1 1/1/2004 00:00 - 01 :30 1.50 DRILL P PROD1 01 :30 - 02:30 1.00 DRILL P PROD1 02:30 - 05:30 05:30 - 07:30 3.00 DRILL P 2.00 DRILL P 07:30 - 08:00 08:00 - 11 :30 0.50 CASE P 3.50 CASE P 11 :30 - 12:00 0.50 CASE P 12:00 - 12:30 0.50 CASE P COMP 12:30 - 16:30 4.00 CASE P COMP 16:30 - 17:00 0.50 CASE P COMP 17:00 - 18:30 1.50 CASE P COMP Start: Rig Release: Rig Number: Spud Date: 2/14/1988 End: 1/5/2004 12/18/2003 1/5/2004 2 Description of Operations .......... -. ..---- ..-.... ..._--,_.. -..-.--.... . _..w___ w ... . .......-..-...-. Printed: 2/2/2004 11:21:13AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: / .~ ..... . Page 6 of 9 BP EXPLORATION Operations Summary Report 07-29 07 -29C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To Hours Task i Code NPT Phase --------- 1/1/2004 17:00 - 18:30 18:30 - 20:30 20:30 - 23:30 1/2/2004 23:30 - 00:00 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 02:30 1.50 CASE P COMP 2.00 CASE P COMP 3.00 CEMT P COMP 0.50 CASE P 1.00 CASE P COMP COMP 0.50 CASE P COMP 1.00 CASE P COMP Start: 12/18/2003 Rig Release: 1/5/2004 Rig Number: 2 Spud Date: 2/14/1988 End: 1/5/2004 Description of Operations 10,480' To 12,989' With No Problems - Pick Up Baker Cement Head - Install Manifold And Circulating Lines - Establish Circulation At 1.8 BPM With 610 Psi And Full Returns - Wash To Bottom At 13,020' - String Weight Up 190,000#, String Weight Down 140,000# Stage Up Pumping Rates From 1.8 BPM With 620 Psi. To 5.5 BPM With 1,350 Psi. Well Bore Attempting To Pack Off Reduce Rate To 5.0 BPM With 1,070 Psi - Reciprocate 4 1/2" Liner - Hold Pre-Job Safety Meeting With All Personal Involved With Cementing Operation - Batch Mix 15.8 PPG Cement Shut Down And Turn Over To Dowell - Pump 5 BBlS Water- Test Surface Lines And Equipment To 4,500 Psi. (Test Good) - While Reciprocating Pipe Pump 20 BBLS CW 100, 35 BBLS 9.5 PPG Mud Push, Followed With 62.5 BBLS (302 Sacks) 15.8 PPG Class "G" Tail Cement At 5.1 BPM - Wash Up Lines To Floor - Drop Dart And Displace With 68 BBLS Perf Pill, Followed Up With 8.5 PPG Flo-Pro Mud At 5.1 BPM With 800 Psi. - Slow Rate And latch Liner Wiper Plug With 102.9 BBlS Pumped Away - Increase Rate To 4.9 BPM - With Full Returns At 107 BBLS Into Displacement Pressure Increased To 1,488 Psi Reduce Rate To 3.0 BPM Pressure Remained At 1,460 Psi. - Shut Down Reciprocating Liner And Increase Rate To 4.9 BPM With 2,078 Psi. And Full Returns - Slow Rate To 3.8 BPM With Final Circulating Pressure At 1,810 Psi. - Bump Plug With A Total Of 143.4 BBLS Pumped Increase Pressure To 4,000 Psi. To Set Baker Liner Hanger - Bleed Off Pressure And Check Floats (Floats Held) - Cement In Place At 21 :26 Hours - Rotate 15 Turns To The Right And Release From Liner- Pressure Up To 1,000 Psi. - Pick Up To Release Pack Off From Seals, Pressure Remained The Same, Increase Pressure To 1,580 Psi And Pick Up On String, Pressure Remained The Same While Exposing Running Tool Dogs At This Point Very Probable Cement Fell Into Liner - Slack Off String With 70,000 Ibs. To Set Baker ZXP Packer Rotate And Repeat Process Several Times (Clear Surface Indication That Packer Set) - Pressure Up To 3,050 Psi. Pick Up On String, Pressure Remained The Same - Cement Manifold On Rig Floor Not Lined Up Properly Bleed Off Pressure And Line Up Manifold - Establish Circulation Ramp Up Pumps To Maximum Rate At 13.0 BPM With 2,350 Psi. And Circulate Bottoms Up- 20 BBlS Mud Push And Spacer Back To Surface With An Increase Of PH From 8.8 To 11.2 And The Highest Mud Weight At 9.5 PPG - Top Of Liner At 10,368', Landing Collar At 12,931', Float Collar At 12,974', Float Shoe At 13,017' Consult With Anchorage Operations Drilling Engineer Regarding Cementing Problem Displace Well To Sea Water At 13.0 BPM With 2,400 Psi. Displace Well To Sea Water At 13.0 BPM With 2,400 Psi. - Clean Possom Belly And Under Shakers Break Down Cement Circulating Lines And Lay Down Baker Cementing Head - POH From 10,368' To 10,275' Slip And Cut 87 Feet Of 1 1/4" Drilling Line Printed: 2/2/2004 11:21:13AM ~ .. Page 7 of 9 BP EXPLORATION Operations Summary Report legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-29 07 -29C REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 12/18/2003 Rig Release: 1/5/2004 Rig Number: 2 Phase I ; Date From - To Hours Task Code NPT .-. .-- -. .... 1/2/2004 02:30 - 03:00 0.50 CASE P 03:00 - 05:30 2.50 CASE P 05:30 - 07:30 2.00 CASE P COMP COMP COMP 07:30 - 08:00 0.50 CLEAN N CEMT COMP 08:00 - 09:00 1.00 CLEAN N CEMT COMP 09:00 - 15:00 6.00 CLEAN N CEMT COMP 15:00 - 19:30 4.50 CLEAN N CEMT COMP 19:30 - 21 :00 1.50 CLEAN N CEMT COMP 21 :00 - 22:00 1.00 CLEAN N CEMT COMP 22:00 - 22:30 0.50 CLEAN N CEMT COMP 22:30 - 00:00 1.50 CLEAN N CEMT COMP 1/3/2004 00:00 - 02:00 2.00 CLEAN N CEMT COMP 02:00 - 02:30 0.50 CLEAN N CEMT COMP 02:30 - 05:00 2.50 CLEAN N CEMT COMP 05:00 - 06:00 1.00 EVAL P COMP 06:00 - 06:30 0.50 PERF P COMP 06:30 - 07:30 1.00 PERF P COMP 07:30 - 08:00 0.50 PERF P COMP 08:00 - 09:30 1.50 PERF P COMP 09:30 - 10:00 0.50 PERF P COMP 10:00 - 14:30 4.50 PERF P COMP 14:30 - 15:30 1.00 PERF P COMP Spud Date: 2/14/1988 End: 1/5/2004 Description of Operations .....- -.......-...-.. -. .. ..-...-.......-..- -.-..--- ..._h_____ .... _..__._...._._._______ Service Top Drive, Traveling Blocks, And Crown Sheaves Pump Dry Job And Blow Down Top Drive - POH With Baker 4 1/2" Liner Running Tool From 10,275' To 2,807' Lay Down 4" Drill Pipe (90 Joints) From 2,807' To 34' - Inspect Running Tool Brass Pins Were Sheared Indicating That The ZXP Packer Did Set - Service Baker Running Tool And Lay Down - Clear Rig Floor Rig Up 2 7/8" Handling Tools, Power Tongs And Equipment Make Up BHA NO.5 - Pick Up 2 7/8" PDM Motor, And 3.75 O.D. Flat Bottom Mill - Make Up Cross Overs And Float Sub Pick Up 84 Joints Of 27/8" Pac Drill Pipe From 17' To 2,607' RIH With BHA NO.5 On 4" HT -40 Drill Pipe From 2,607' To 12,931' (Top Of Landing Collar) - No Cement Found In 41/2" Liner Circulate Out 4 1/2" Liner Volume And Spot Perf Pill Drop Dart Open Circulating Sub - Circulate Bottoms Up At 10.5 BPM With 1,100 Psi. Pump Dry Job And Blow Down Surface Equipment POH With Clean Out Assembly BHA NO.5 From 12,931' To 8,672' POH With Clean Out Assembly BHA NO.5 From 8,672' To 2,607' - Lay Down Circulation Sub And Cross Overs Rig Up 2 7/8" Handling Tools, Power Tongs And Equipment POH Laying Down 2 7/8" PAC Drill Pipe From 2,607' - Clear Rig Floor Test 9 5/8" Casing, 7" Liner And 4 1/2" Liner At 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) - Blow Down Surface Equipment Hold Pre-Job Safety Meeting Regarding Peforation Gun Handling Operation - Bring Schlumberger Handling Tools To Rig Floor For Perf Guns Pick Up 1,143' Of Schlumberger 27/8" HSD Perforation Guns- 860 Feet 38C CleanPACK Charges Loaded With 6 SPF At 60 Degree Phase - Make Up Firing Head And Cross Overs To 1,151' Rig Up 27/8" Handling Tools, Power Tongs And Equipment RIH With Schlumberger 2 7/8" HSD Perforation Guns Picking Up 50 Joints Of 2 7/8" Pac Drill Pipe From 1,151' To 2,690' Rig Down 2 7/8" Handling Tools, Power Tongs And Equipment Install Cross Overs - RIH With 2 7/8" HSD Perforation Guns On 4" HT-40 Drill Pipe From 2,690' To 12,931' (Top Of Landing Collar) Place Perf Guns On Depth w/ Bottom Shot At 12,930, Top Shot At 11,820', Spaced Out Throughout The Interval w/ 860 Feet 38C CleanPACK Charges Loaded With 6 SPF At 60 Degree Phase - Close Upper Pipe Rams - Pressure Up To 2,500 Psi. And Fire Perf Guns - Bleed Pressure To 0 Psi. - Open Upper Rams Perforated Intervals: 11,820' To 12,140' 12,210' To 12,450' 12,560' To 12,635' Printed: 2/2/2004 11 :21: 13 AM .... . BP EXPLORATION Operations Summary Report Page 8 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -29 07 -29C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 12/18/2003 1/5/2004 2 Spud Date: 2/14/1988 End: 1/5/2004 Date From - To Hours Task ¡Code NPT! Phase Description of Operations -----------------...-.--..- .......-.." .n_ .._____.......____.__._ 1/3/2004 14:30 - 15:30 1.00 PERF P COMP 12,705' To 12,930' 15:30 -16:30 1.00 PERF P COMP POH With Perf Guns Above Top Shot At 11,820' - From 12,930' To 11,744' - Lost 8 BBLS - Monitor Well Bore (Static) 16:30 - 17:30 1.00 PERF P COMP Slip And Cut 67 Feet Of 1 1/4" Drilling Line 17:30 - 18:00 0.50 PERF P COMP Service Top Drive And Traveling Blocks 18:00 - 22:30 4.50 PERF P COMP POH Laying Down 4" Drill Pipe (290 Joints) From 11,744' To 2,720' 22:30 - 23:00 0.50 PERF P COMP RIH With 4" Drill Pipe Out Of Mast From 2,720' To 3,929' 23:00 - 23:30 0.50 PERF P COMP POH Laying Down 4" Drill Pipe (40 Joints) From 3,929' To 2,690' 23:30 - 00:00 0.50 PERF P COMP Rig Up 2 7/8" Handling Tools, Power Tongs And Equipment 1/4/2004 00:00 - 01 :30 1.50 PERF P COMP Lay Down 2 7/8" Pac Drill Pipe From 2,690' To 1,182' - Monitor Well Bore (Static) 01 :30 - 02:00 0.50 PERF P COMP Hold Pre-Job Safety Meeting Regarding Peforation Gun Handling Operation 02:00 - 02:30 0.50 PERF P COMP Bring Schlumberger Equipment To Rig Floor - Change Out Handling Tools For Perf Guns 02:30 - 05:30 3.00 PERF P COMP Pull Last Joint Of 2 7/8" PAC Drill Pipe To Rig Floor - Break Down Firing Head And Cross Overs - POH Laying Down Schlumberger 2 7/8" HSD Perforation Guns - All Charges Fired 05:30 - 06:30 1.00 PERF P COMP Wash Off And Clean Rig Floor - Clear Floor Of Schlumberger Tools And Equipment 06:30 - 07:00 0.50 WHSUR P COMP Rig Up And Pull Wear Bushing 07:00 - 07:30 0.50 RUNCOMP COMP Rig Up 4 1/2" Tubing Handling Tools, Power Tongs And Equipment 07:30 - 17:30 10.00 RUNCOMP COMP Hold Pre-Job Safety Meeting Regarding Tubing Running Operation - Run 4 1/2" Completion - Pick Up Tail Pipe Assembly Baker Lock Connections Below Baker S -3 Packer - RIH With 41/2" (245 Joints) L-80 12.6 lb. IBT-M Tubing To 10,379' -Torque To 3,200 ftllbs. 17:30 - 18:30 1.00 RUNCOMP COMP Space Out 4 1/2" Completion String - Lay Down 3 Joints Of 4 1/2" Tubing - Pick Up 2 Space Out Pup Joints - Pick Up Joint No.243 - Make Up FMC Tubing Hanger - Up Weight At 135,000 Ibs. Down Weight At 108,000 Ibs. - Top Of 7" Liner Tie Back Sleeve At 10,368' - Wire Line Entry Guide At 10,377' 18:30 - 19:00 0.50 RUNCOMP COMP Land FMC Tubing Hanger - Run In Lock Down Studs 19:00 - 23:00 4.00 RUNCOMP COMP Reverse Circulate Sea Water And Corrossion Inhibitor At 3 BPM With 170 Psi. 23:00 - 00:00 1.00 RUNCOMP COMP Drop Ball And Rod - Pressure Up On The Tubing To 3500 Psi To Set The Packer - Hold The Pressure For 30 Minutes On Chart Recorder For Tubing Test (Test Good) 1/5/2004 00:00 - 01 :00 1.00 RUNCOMP COMP Bleed Tubing Pressure To 1500 Psi. - Pressure Annulus To 3500 Psi For 30 Mininutes For Packer Test On The Chart Recorder - Bleed Off The Tubing Pressure To Shear The DCR Valve Set At 2500 Psi. 01 :00 - 01 :30 0.50 WHSUR P COMP Install BPV - Test From Below To 1,000 Psi (Test Good) - Blow Down Surface Lines And Equipment 01 :30 - 03:00 1.50 BOPSUR P COMP Nipple Down 13 5/8 BOP Stack And Related Equipment 03:00 - 05:00 2.00 WHSUR P COMP Nipple Up Tubing Head Adapter And Production Tree - Test Tubing Head Adapter To 5,000 Psi. (Good Test) 05:00 - 06:00 1.00 WHSUR P COMP Rig Up DSM Lubricator And Pull Back Pressure Valve - Install Tree Test Plug - Test Tree To 5,000 Psi. (Good Test) 06:00 - 06:30 0.50 WHSUR P COMP Rig Up DSM Lubricator And Pull Tree Test Plug - Rig Down Printed: 2/2/2004 11:21:13AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ...... - Page 9 of 9 BP EXPLORATION Operations Summary Report 07-29 07 -29C REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From - To ' Hours Task Code NPT ¡ Phase 1/5/2004 06:00 - 06:30 0.50 WHSUR P COMP 06:30 - 07:30 1.00 WHSUR P COMP 07:30 - 09:00 1.50 WHSUR P COMP 09:00 - 10:00 1.00 WHSUR P COMP 10:00 - 11 :00 1.00 WHSUR P COMP 11 :00 - 12:00 1.00 WHSUR P COMP Start: 12/18/2003 Rig Release: 1/5/2004 Rig Number: 2 Spud Date: 2/14/1988 End: 1/5/2004 Description of Operations Lubricator And Clear Rig Floor Rig Up Circulating Lines And Equipment. Test Lines To 3000 psi Reverse Circulate 160 Barrels Of 60 Degree Diesel At 2.4 BPM With 350 Psi. U-Tube Diesel From Annulus To Tubing Pick Up T-Bar And Install Back Pressure Valve - Install Tree Cap And Test Back Pressure Valve From Below At 1,000 Psi. For 5 Minutes - Suck Back Diesel In U-Tube Lines - Drain And Rig Down Same Remove Secondary Annulus Valve And Install Flange - Install Tree And Annulus Gauges - Secure Well - Clean Up Cellar Area *NOTE* - Rig Released From Well Work On DS 07-29C At 12:00 Hours On 01-05-2004 Printed: 2/2/2004 11 :21: 13 AM 7 -29C ~po,~~ Co"pletior'l .' J--; . TREE = WB.LHE;AQ.oo, . ACTUATQR= KB. 8.E:Y'~ BF. aEVoo, q,'"=\?k1 KOP=~' <¥\. "1. Max Angle oo()OQ 12000'" ll.ßi.ð\ . Datum M) '" 11220' Datum TVD = 8800' SS 4-1/8" FMC FMC AXaSON 65' 1 - .¡.>t!vi····'· ' 'X' Nipple @t?4r~~,··:;;;! '~_: ":,.:" "_C;~;_'-":, -, .... 13-3/S", ·7'2#, K-S·S','.': '.. ..,;;:'....;' '.... . .. .. ',¡/\'~<"',..: ,,' b i'i..',,';", '" ,,' ..," " ",-.~..';... ." ..... ' 3767' · 14-1/2", 12.6#, L0080.JBT..M Tubing I Tubing Tail: -10'Pup Joint 'i.0,,2.q,~ -X Nipple (3.813") I -10' Pup Joint ~0, ~2.ø -Packer . -20' Pup Joint i..a:h~'-:.-X Nipple (3.813") , -20' Pup Joint :\.0 \~S ~ -XN Nipple (3.725") -10' Pup Joint :i(l).-~\¿J~-WLEG O\~I:{~ , ' 9-S/8" X 7" HMC Liner Hanger.with C2IZXP Lin~r Top Packer -c-~~ 0 (=- \I.;)~.C\~A1o' \2> l~ o~ ~~~~lo2' ·("Y"\Þ, GLM Design: 3 \ o."~ I #4 - 3150' TVD - 4;;112"X 1.$ SV 5B<1>i ~ - 5000' TVD - 4-1/2" X1:s. DV ~5'1 I, #2 - 6500' TVD - 4-,1!2"X 1.'5- DV :1,.Œ>,(l)£Ø #1 - 8000' TVD - 4":1/2" X 1" - DV <::\l~ß' .: r- 9,820' 9,8S0' 10,30S' ~ . . - ! , Packer @ r r . 11"..::1.fZ) \3 '2JD 7" X 4-1/2" HMC Liner Hanger with C2/ZXP Liner Top Packer @ . - -- 'i..\l)\~8' ., . 11,470' ", 29#, L-80 r 2_3:::,~6~, L,sO 12,8'15' m. 3-3/16",6.2#, L-80 i Date Rev By Commen~ 11-11-03 :RBT Propósed Completion ;!, ~ :1Ø,S22 I . ~:~~t:lì~~-Q~:~~1'J:~~t'~~~~~~~~§/~~':'~:¡:1~~: 4-1/2", 12.6#, L-SO, IBT-M@.__' :~d)i.q' , -" . UJ' \' ,C.@ :1.þ,(l)2.Q)' " I " ..,.~.~~., . ".1· PRUDHOE BAY UNIT . . , ' i WELL:7-29C APJ N.O: Permit NO: GPB Rotary Drilling ,'f . " 'f!' . AOGCC Howard Ok/and 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well 7-29C Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,733.69' MD 9,746.00' MD 13,020.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) d03~· \9~ 09-Jan-04 RECEIVED J.\N 1 J 2004 ,tîjª~ka Oif& Gas Cons. ConmlMbt ,t'J1000rag$ Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 07 07-29 - 7-29C Job No. AKZZ2827126, Surveyed: 31 December, 2003 Survey Report 8 January, 2004 Your Ref: API 500292178203 - Surface Coordinates: 5950464.69 N, 675855.79 E (70· 16'13.0103" N, 148· 34' 39.7704" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 950464.69 N, 175855.79 E (Grid) Surface Coordinates relative to Structure Reference: 2355.62 N, 1472.92 W (True) Kelly Bushing Elevation: 52. 90ft above Mean Sea Level Kelly Bushing Elevation: 52.90ft above Project V Reference Kelly Bushing Elevation: 52. 90ft above Structure Reference speaf'""f'""Y-SUI'1 DFtlL.L.l'NG seFt,vn::es A Halliburton Company DEFINITIVE . . Survey Ref: svy4149 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-29 - 7-29C Your Ref: API 500292178203 Job No. AKZZ2827126, Surveyed: 31 December, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9733.69 40.020 1 0.790 7716.84 7769.74 4823.79 N 71.09 W 5955285.50 N 675672.01 E 4820.44 Tie On Point AK-6 BP _IFR-AK 9746.00 39.820 11.040 7726.28 7779.18 4831.55 N 69.59 W 5955293.29 N 675673.33 E 2.083 4828.23 Window Point 9774.31 41.320 10.820 7747.79 7800.69 4849.62 N 66.10 W 5955311 .45 N 675676.40 E 5.323 4846.39 9869.31 43.010 10.120 7818.20 7871.10 4912.33 N 54.52 W 5955374.41 N 675686.51 E 1.846 4909.37 . 9962.54 42.560 9.440 7886.62 7939.52 4974.74 N 43.76 W 5955437.05 N 675695.81 E 0.692 4972.03 10055.78 42.360 9.750 7955.41 8008.31 5036.80 N 33.27 W 5955499.34 N 675704.84 E 0.310 5034.34 10148.83 42.740 8.180 8023.96 8076.86 5098.95 N 23.47 W 5955561.70 N 675713.19 E 1.212 5096.72 10241.34 41 .990 8.310 8092.31 8145.21 5160.64 N 14.53 W 5955623.59 N 675720.69 E 0.816 5158.62 10336.61 43.450 7.030 8162.30 8215.20 5224.70 N 5.91 W 5955687.82 N 675727.80 E 1.783 5222.87 10430.17 43.130 7.690 8230.41 8283.31 5288.32 N 2.30 E 5955751.62 N 675734.53 E 0.592 5286.68 10508.79 42.520 6.990 8288.07 8340.97 5341.32 N 9.13 E 5955804.77 N 675740.12 E 0.984 5339.84 10599.78 41 .330 6.150 8355.77 8408.67 5401.72 N 16.09 E 5955865.31 N 675745.67 E 1 .446 5400.39 10693.82 41.920 5.040 8426.06 8478.96 5463.88 N 22.18 E 5955927.60 N 675750.30 E 1.004 5462.69 10787.32 43.080 7.620 8495.00 8547.90 5526.65 N 29.16E 5955990.51 N 675755.81 E 2.239 5525.62 10880.88 43.360 7.040 8563.18 8616.08 5590.20 N 37.33 E 5956054.23 N 675762.50 E 0.519 5589.35 10974.58 42.250 6.000 8631.93 8684.83 5653.45 N 44.57 E 5956117.64 N 675768.25 E 1 .404 5652.77 11037.77 41.250 4.320 8679.07 8731.97 5695.35 N 48.36 E 5956159.62 N 675771.06 E 2.374 5694.75 11068.30 42.010 5.910 8701.89 8754.79 5715.55 N 50.17 E 5956179.86 N 675772.40 E 4.262 5714.99 11102.71 43.870 6.570 8727.08 8779.98 5738.85 N 52.72 E 5956203.21 N 675774.41 E 5.561 5738.35 11132.61 46.830 8.840 8748.09 8800.99 5759.93 N 55.58 E 5956224.34 N 675776.78 E 11.276 5759.49 11163.23 48.800 9.550 8768.65 8821.55 5782.32 N 59.21 E 5956246.82 N 675779.88 E 6.659 5781.97 . 11197.20 52.590 9.960 8790.17 8843.07 5808.22 N 63.66 E 5956272.81 N 675783.73 E 11 .196 5807.97 11228.70 57.190 8.720 8808.28 8861.18 5833.64 N 67.84 E 5956298.33 N 675787.31 E 14.954 5833.49 11256.34 61.680 8.810 8822.33 8875.23 5857.16 N 71.46 E 5956321.92 N 675790.38 E 16.247 5857.09 11288.86 64.470 9.460 8837.06 8889.96 5885.78 N 76.07 E 5956350.64 N 675794.32 E 8.762 5885.82 11318.84 65.250 9.940 8849.79 8902.69 5912.53 N 80.64 E 5956377.49 N 675798.26 E 2.978 5912.68 11349.97 67.240 9.990 8862.33 8915.23 5940.60 N 85.57 E 5956405.66 N 675802.54 E 6.394 5940.86 11381.28 69.980 9.630 8873.75 8926.65 5969.32 N 90.54 E 5956434.50 N 675806.83 E 8.816 5969.70 11410.66 72.880 8.790 8883.11 8936.01 5996.81 N 94.99 E 5956462.08 N 675810.64 E 10.236 5997.29 11441.36 76.710 9.050 8891.16 8944.06 6026.07 N 99.58 E 5956491.44 N 675814.55 E 12.502 6026.66 8 January, 2004 - 15:52 Page 2 of 5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-29 - 7-29C Your Ref: API 500292178203 Job No. AKZZ2827126, Surveyed: 31 December, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin9s Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11473.67 81.240 9.500 8897.34 8950.24 6057.36 N 104.70 E 5956522.84 N 675818.93 E 14.087 6058.07 11504.01 86.300 9.540 8900.63 8953.53 6087.10 N 109.68 E 5956552.69 N 675823.22 E 16.678 6087.92 11535.43 89.440 8.950 8901.79 8954.69 6118.08N 114.73 E 5956583.78 N 675827.54 E 10.168 6119.03 11567.68 89.070 8.330 8902.21 8955.11 6149.96 N 119.57E 5956615.77 N 675831.64 E 2.239 6151.02 11601.98 89.010 8.010 8902.79 8955.69 6183.91 N 124.44 E 5956649.82 N 675835.71 E 0.949 6185.08 . 11629.19 89.940 7.520 8903.04 8955.94 6210.87 N 128.12 E 5956676.86 N 675838.76 E 3.863 6212.12 11657.99 89.380 7.780 8903.21 8956.11 6239.41 N 131.95 E 5956705.48 N 675841.93 E 2.144 6240.75 11689.55 91.230 8.030 8903.04 8955.94 6270.67 N 136.29 E 5956736.83 N 675845.53 E 5.915 6272.11 11721.84 91.880 7.560 8902.16 8955.06 6302.65 N 140.67 E 5956768.91 N 675849.16 E 2.484 6304.19 11755.31 91.760 7.830 8901.10 8954.00 6335.80 N 145.15E 5956802.15 N 675852.87 E 0.882 6337.45 11781.49 93.370 8.950 8899.93 8952.83 6361.68 N 148.97 E 5956828.11 N 675856.08 E 7.489 6363.41 11814.06 94.700 9.530 8897.64 8950.54 6393.74 N 154.18 E 5956860.29 N 675860.54 E 4.453 6395.60 11850.59 92.960 9.350 8895.20 8948.10 6429.70 N 160.16E 5956896.37 N 675865.68 E 4.789 6431.69 11879.21 91.600 9.390 8894.06 8946.96 6457.91 N 164.82 E 5956924.69 N 675869.67 E 4.754 6460.01 11910.49 91.700 9.410 8893.16 8946.06 6488.76 N 169.92 E 5956955.65 N 675874.06 E 0.326 6490.98 11943.60 91.820 9.330 8892.14 8945.04 6521.41 N 175.31 E 5956988.42 N 675878.68 E 0.436 6523.76 11974.37 90.280 9.300 8891.58 8944.48 6551.77 N 180.29 E 5957018.88 N 675882.95 E 5.006 6554.23 12001.75 90.280 9.320 8891.44 8944.34 6578.79 N 184.72 E 5957046.00 N 675886.75 E 0.073 6581.36 12035.90 90.460 9.340 8891.22 8944.12 6612.49 N 190.26 E 5957079.82 N 675891.50 E 0.530 6615.18 12067.08 90.150 8.590 8891.06 8943.96 6643.28 N 195.12 E 5957110.72 N 675895.63 E 2.603 6646.09 12095.98 90.370 8.140 8890.93 8943.83 6671.88 N 199.32 E 5957139.40 N 675899.17 E 1.733 6674.78 12129.17 89.230 8.100 8891.04 8943.94 6704.73 N 204.01 E 5957172.36 N 675903.09 E 3.437 6707.75 . 12161.38 89.040 7.620 8891.53 8944.43 6736.64 N 208.41 E 5957204.36 N 675906.75 E 1.603 6739.75 12190.73 89.260 7.420 8891.96 8944.86 6765.73 N 212.25 E 5957233.53 N 675909.91 E 1.013 6768.94 12236.99 89.600 7.580 8892.42 8945.32 6811.59 N 218.29 E 5957279.52 N 675914.87 E 0.812 6814.94 12284.89 89.170 7.930 8892.94 8945.84 6859.05 N 224.75 E 5957327.12 N 675920.22 E 1.157 6862.54 12325.56 89.540 7.970 8893.40 8946.30 6899.33 N 230.38 E 5957367.52 N 675924.90 E 0.915 6902.95 12374.11 90.060 8.250 8893.57 8946.47 6947.39 N 237.23 E 5957415.73 N 675930.63 E 1.216 6951.17 12421.26 90.280 8.070 8893.43 8946.33 6994.06 N 243.92 E 5957462.54 N 675936.23 E 0.603 6998.00 12468.96 90.680 7.460 8893.03 8945.93 7041.32 N 250.36 E 5957509.94 N 675941.57 E 1.529 7045.41 12500.14 91.110 7.400 8892.54 8945.44 7072.24 N 254.40 E 5957540.94 N 675944.88 E 1.392 7076.41 12531.42 91.820 5.250 8891.74 8944.64 7103.32 N 257.84 E 5957572.09 N 675947.59 E 7.236 7107.57 12563.03 92.440 5.320 8890.56 8943.46 7134.77 N 260.75 E 5957603.60 N 675949.77 E 1.974 7139.09 12596.44 93.460 5.900 8888.85 8941.75 7167.98 N 264.01 E 5957636.88 N 675952.25 E 3.511 7172.36 12627.63 92.960 5.260 8887.10 8940.00 7198.97 N 267.04 E 5957667.93 N 675954.55 E 2.601 7203.42 8 January, 2004 - 15:52 Page 3 of 5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-29 - 7-29C Your Ref: API 500292178203 Job No. AKZZ2827126, Surveyed: 31 December, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12655.86 91.480 4.440 8886.01 8938.91 7227.08 N 269.42 E 5957696.09 N 675956.28 E 5.992 7231.58 12690.21 91.080 4.030 8885.24 8938.14 7261.32 N 271.96 E 5957730.39 N 675958.02 E 1.667 7265.88 12721.59 88.370 3.540 8885.39 8938.29 7292.63 N 274.03 E 5957761.73 N 675959.36 E 8.776 7297.23 12750.23 87.960 2.010 8886.31 8939.21 7321.22 N 275.42 E 5957790.35 N 675960.07 E 5.528 7325.85 12784.31 88.210 1.030 8887.44 8940.34 7355.27 N 276.32 E 5957824.41 N 675960.18 E 2.966 7359.91 . 12821.51 88.770 358.560 8888.42 8941.32 7392.45 N 276.19 E 5957861.58 N 675959.18 E 6.806 7397.08 12844.44 89.170 358.460 8888.84 8941.74 7415.37 N 275.59 E 5957884.48 N 675958.05 E 1.798 7419.98 12876.03 89.320 358.140 8889.25 8942.15 7446.95 N 274.65 E 5957916.02 N 675956.37 E 1.119 7451.51 12908.95 89.540 356.150 8889.58 8942.48 7479.82 N 273.02 E 5957948.85 N 675953.97 E 6.081 7484.34 12937.77 90.000 352.800 8889.70 8942.60 7508.50 N 270.24 E 5957977.46 N 675950.52 E 11.733 7512.94 12968.41 92.130 350.680 8889.13 8942.03 7538.82 N 265.84 E 5958007.66 N 675945.42 E 9.807 7543.13 12980.94 92.340 350.390 8888.64 8941.54 7551.17 N 263.78 E 5958019.96 N 675943.07 E 2.856 7555.43 - 13020.00 92.340 350.390 8887.04 8939.94 - 7589.65 N 257.27 E 5958058.28 N 675935.66 E 0.000 7593.73 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 1.4520 (True). Magnetic Declination at Surface is 25.4810 (21-Dec-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 13020.00ft., The Bottom Hole Displacement is 7594.01ft., in the Direction of 1.9410 (True). . 8 January, 2004 - 15:52 Page 4 of 5 Dri/lQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-29 - 7-29C Your Ref: API 500292178203 Job No. AKZZ2827126, Surveyed: 31 December, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9733.69 9746.00 13020.00 7769.74 7779.18 8939.94 4823.79 N 4831.55 N 7589.65 N 71.09 W 69.59 W 257.27 E Tie On Point Window Point Projected Survey . Survey tool program for 07-29 - 7-29C From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9733.69 0.00 9733.69 7769.74 13020.00 7769.74 AK-1 BP _HG (07-29) 8939.94 AK-6 BP _IFR-AK (7-29C) . 8 January, 2004 - 15:52 Page 5 of 5 DrillQuest 3.03.05.005 . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 7-29C MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,733.69' MD 9,746.00' MD 13,020.00' MD (if applicable) . d03' 1<1d-. 09-Jan-04 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED JV¡ 1·3 2JG4 Alaska Oil & Gas Cons. Comrniaion Aochorage Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 07 07-29 - 7-29C MWD . Job No. AKMW2827126, Surveyed: 31 December, 2003 Survey Report 8 January, 2004 Your Ref: API 500292178203 Surface Coordinates: 5950464.69 N, 675855.79 E (70016' 13.0103" N, 148034' 39.7704" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 950464.69 N, 175855.79 E (Grid) Surface Coordinates relative to Structure Reference: 2355.62 N, 1472.92 W (True) Kelly Bushing Elevation: 52. 90ft above Mean Sea Level Kelly Bushing Elevation: 52.90ft above Project V Reference Kelly Bushing Elevation: 52.90ft above Structure Reference spel"'""l"'""y-sUF1 OAIL.L.ING SEAVIt:ES A Halliburton Company Survey Ref: svy4150 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-29 - 7-29C MWD Your Ref: API 500292178203 Job No. AKMW2827126, Surveyed: 31 December, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9733.69 40.020 10.790 7716.84 7769.74 4823.79 N 71.09 W 5955285.50 N 675672.01 E 4820.44 Tie On Point MWD Magnetic - 9746.00 39.820 11.040 7726.28 7779.18 - 4831.55 N 69.59 W 5955293.29 N 675673.33 E 2.083 4828.23 Window Point 9774.31 41.320 10.820 7747.79 7800.69 4849.62 N 66.10 W 5955311.45 N 675676.40 E 5.323 4846.39 9869.31 43.010 8.100 7818.21 7871.11 4912.52 N 55.65 W 5955374.57 N 675685.38 E 2.619 4909.53 . 9962.54 42.560 9.790 7886.63 7939.53 4975.07 N 45.81 W 5955437.33 N 675693.76 E 1.322 4972.31 1 0055.78 42.360 9.970 7955.42 8008.32 5037.08 N 35.01 W 5955499.58 N 675703.10 E 0.251 5034.58 10148.83 42.740 8.290 8023.97 8076.87 5099.20 N 25.03 W 5955561.92 N 675711.63 E 1 .287 5096.93 10241.34 41.990 8.570 8092.32 8145.22 5160.87 N 15.89 W 5955623.78 N 675719.32 E 0.836 5158.81 10336.61 43.450 7.460 8162.31 8215.21 5224.86 N 6.88W 5955687.97 N 675726.83 E 1.724 5223.01 10430.17 43.130 8.020 8230.41 8283.31 5288.43 N 1.75 E 5955751.72 N 675733.98 E 0.534 5286.78 1 0508.79 42.520 6.990 8288.08 8340.98 5341.42 N 8.74 E 5955804.85 N 675739.72 E 1.181 5339.92 10599.78 41.330 6.600 8355.77 8408.67 5401.78 N 15.93 E 5955865.37 N 675745.51 E 1.339 5400.45 10693.82 41 .920 5.420 8426.07 8478.97 5463.90 N 22.47 E 5955927.63 N 675750.59 E 1.043 5462.72 10787.32 43.080 7.860 8495.01 8547.91 5526.63 N 29.79 E 5955990.51 N 675756.44 E 2.156 5525.62 10880.88 43.360 7.230 8563.19 8616.09 5590.15 N 38.20 E 5956054.21 N 675763.37 E 0.550 5589.32 10974.58 42.250 6.140 8631.93 8684.83 5653.38 N 45.62 E 5956117.60 N 675769.30 E 1.424 5652.72 11037.77 41 .250 4.850 8679.08 8731.98 5695.26 N 49.65 E 5956159.56 N 675772.36 E 2.086 5694.69 11068.30 42.010 6.560 8701.90 8754.80 5715.44 N 51.67 E 5956179.78 N 675773.90 E 4.477 5714.92 11102.71 43.870 6.900 8727.09 8779.99 5738.72 N 54.42 E 5956203.12 N 675776.11 E 5.447 5738.26 11132.61 46.830 9.110 8748.10 8801.00 5759.78 N 57.39 E 5956224.24 N 675778.59 E 11.208 5759.38 11163.23 48.800 10.110 8768.66 8821.56 5782.15 N 61.18 E 5956246.69 N 675781.85 E 6.874 5781.84 . 11197.20 52.590 10.350 8790.18 8843.08 5808.01 N 65.85 E 5956272.65 N 675785.92 E 11.170 5807.81 11228.70 57.190 9.110 8808.29 8861.19 5833.40 N 70.19 E 5956298.14 N 675789.67 E 14.954 5833.31 11256.34 61.680 9.230 8822.34 8875.24 5856.89 N 73.99 E 5956321.71 N 675792.91 E 16.249 5856.88 11288.86 64.470 9.760 8837.06 8889.96 5885.48 N 78.77 E 5956350.41 N 675797.03 E 8.701 5885.59 11318.84 65.250 10.320 8849.80 8902.70 5912.21 N 83.50 E 5956377.24 N 675801.13 E 3.103 5912.43 11349.97 67.240 10.320 8862.34 8915.24 5940.24 N 88.61 E 5956405.38 N 675805.58 E 6.393 5940.58 11381.28 69.980 9.920 8873.76 8926.66 5968.94 N 93.73 E 5956434.19 N 675810.03 E 8.832 5969.39 11410.66 72. 880 9.360 8883.11 8936.01 5996.39 N 98.39 E 5956461.74 N 675814.05 E 10.035 5996.96 11441.36 76.710 10.010 8891.16 8944.06 6025.59 N 103.37 E 5956491.05 N 675818.35 E 12.642 6026.27 8 January, 2004 - 15:48 Page 2 of 5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-29 - 7-29C MWD Your Ref: API 500292178203 Job No. AKMW2827126, Surveyed: 31 December, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11473.67 81.240 10.220 8897.34 8950.24 6056.80 N 108.94 E 5956522.38 N 675823.19 E 14.035 6057.62 11504.01 86.300 9.980 8900.63 8953.53 6086.48 N 114.23 E 5956552.18 N 675827.78 E 16.696 6087.42 11535.43 89.440 9.420 8901.80 8954.70 6117.43 N 119.52 E 5956583.24 N 675832.34 E 10.151 6118.49 11567.68 89.070 8.600 8902.22 8955.12 6149.28 N 124.57 E 5956615.20 N 675836.65 E 2.789 6150.46 11601.98 89.010 8.140 8902.79 8955.69 6183.21 N 129.56 E 5956649.24 N 675840.85 E 1.352 6184.51 . 11629.19 89.940 7.860 8903.04 8955.94 6210.15 N 133.35 E 5956676.26 N 675844.00 E 3.569 6211.54 11657.99 89.380 7.850 8903.22 8956.12 6238.68 N 137.28 E 5956704.88 N 675847.27 E 1.945 6240.16 11689.55 91.230 8.510 8903.05 8955.95 6269.92 N 141.77 E 5956736.21 N 675851.03 E 6.224 6271.50 11721.84 91.880 7.670 8902.17 8955.07 6301.87 N 146.32 E 5956768.26 N 675854.82 E 3.289 6303.56 11755.31 91.760 8.240 8901.11 8954.01 6335.01 N 150.95 E 5956801.49 N 675858.68 E 1.740 6336.80 11781.49 93.370 9.530 8899.94 8952.84 6360.84 N 154.98 E 5956827.42 N 675862.11 E 7.877 6362.73 11814.06 94.700 9.980 8897.64 8950.54 6392.86 N 160.49 E 5956859.56 N 675866.87 E 4.310 6394.88 11850.59 92.960 10.070 8895.20 8948.10 6428.75 N 166.83 E 5956895.59 N 675872.37 E 4.770 6430.92 11879.21 91.600 9.780 8894.07 8946.97 6456.92 N 171.76 E 5956923.86 N 675876.64 E 4.859 6459.20 11910.49 91.700 8.980 8893.17 8946.07 6487.77 N 176.86 E 5956954.82 N 675881.02 E 2.576 6490.17 11943.60 91.820 11.020 8892.15 8945.05 6520.36 N 182.61 E 5956987.54 N 675886.00 E 6.169 6522.89 11974.37 90.280 11.010 8891.58 8944.48 6550.56 N 188.48 E 5957017.86 N 675891.17 E 5.005 6553.23 12001.75 90.280 8.600 8891 .45 8944.35 6577 .54 N 193.15 E 5957044.94 N 675895.20 E 8.802 6580.32 12035.90 90.460 8.340 8891.23 8944.13 6611.31 N 198.18 E 5957078.83 N 675899.44 E 0.926 6614.21 12067.08 90.150 10.230 8891.06 8943.96 6642.08 N 203.21 E 5957109.71 N 675903.75 E 6.142 6645.10 12095.98 90.370 8.610 8890.93 8943.83 6670.59 N 207.94 E 5957138.32 N 675907.81 E 5.657 6673.72 12129.17 89.230 9.390 8891.05 8943.95 6703.37 N 213.13 E 5957171.21 N 675912.24 E 4.162 6706.62 . 12161.38 89.040 8.480 8891.53 8944.43 6735.19 N 218.13 E 5957203.13 N 675916.49 E 2.886 6738.55 12190.73 89.260 7.980 8891.97 8944.87 6764.23 N 222.33 E 5957232.27 N 675920.02 E 1.861 6767.69 12236.99 89.600 8.680 8892.43 8945.33 6810.00 N 229.03 E 5957278.18 N 675925.65 E 1.682 6813.62 12284.89 89.170 9.300 8892.94 8945.84 6857.31 N 236.52 E 5957325.65 N 675932.02 E 1.575 6861.10 12325.56 89.540 7.050 8893.40 8946.30 6897.56 N 242.30 E 5957366.03 N 675936.86 E 5.606 6901.49 12374.11 90.060 7.820 8893.57 8946.47 6945.70 N 248.58 E 5957414.30 N 675942.02 E - 1.914 6949.77 12421.26 90.280 9.790 8893.43 8946.33 6992.29 N 255.80 E 5957461.05 N 675948.15 E 4.204 6996.53 12468.96 90.680 8.180 8893.03 8945.93 7039.40 N 263.25 E 5957508.32 N 675954.49 E 3.478 7043.81 12500.14 91.110 9.980 8892.55 8945.45 7070.19 N 268.17 E 5957539.21 N 675958.69 E 5.935 7074.71 12531.42 91.820 7.730 8891.75 8944.65 7101.08 N 272.98 E 5957570.21 N 675962.78 E 7.540 7105.72 12563.03 92.440 6.41 0 8890.57 8943.47 7132.43 N 276.87 E 5957601.64 N 675965.94 E 4.611 7137.16 12596.44 93.460 4.740 8888.85 8941.75 7165.64 N 280.11 E 5957634.92 N 675968.40 E 5.851 7170.43 12627.63 92.960 5.000 8887.10 8940.00 7196.67 N 282.75 E 5957666.00 N 675970.32 E 1.806 7201.52 8 January, 2004 -15:48 Page 3 of 5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-29 - 7-29C MWD Your Ref: API 500292178203 Job No. AKMW2827126, Surveyed: 31 December, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin9s Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 12655.86 91.480 4.130 8886.01 8938.91 7224.78 N 285.00 E 5957694.16 N 675971.91 E 6.080 7229.69 12690.21 91.080 3.780 8885.24 8938.14 7259.04 N 287.37 E 5957728.47 N 675973.47 E 1.547 7263.99 12721.59 88.370 2.590 8885.39 8938.29 7290.37 N 289.11 E 5957759.83 N 675974.48 E 9.432 7295.36 12750.23 87.960 3.740 8886.31 8939.21 7318.95N 290.69 E 5957788.44 N 675975.40 E 4.261 7323.97 12784.31 88.210 2.690 8887.45 8940.35 7352.96 N 292.60 E 5957822.48 N 675976.51 E 3.165 7358.01 . 12821.51 88.770 0.010 8888.43 8941 .33 7390.13 N 293.48 E 5957859.66 N 675976.52 E 7.357 7395.20 12844.44 89.170 357.150 8888.84 8941.74 7413.05 N 292.91 E 5957882.56 N 675975.41 E 12.592 7418.09 12876.03 89.320 357.650 8889.26 8942.16 7444.60 N 291.48 E 5957914.07 N 675973.24 E 1.652 7449.60 12908.95 89.540 355.360 8889.59 8942.49 7477.46 N 289.47 E 5957946.87 N 675970.47 E 6.988 7482.39 12937.77 90.000 354.190 8889.70 8942.60 7506.16 N 286.84 E 5957975.50 N 675967.18 E 4.362 7511.02 12968.41 92.130 350.850 8889.13 8942.03 7536.53 N 282.86 E 5958005.77 N 675962.48 E 12.927 7541.27 12980.94 92.340 350.690 8888.64 8941.54 7548.88 N 280.85 E 5958018.08 N 675960.18 E 2.106 7553.58 13020.00 92.340 350.690 8887.05 8939.95 7587.40 N 274.54 E 5958056.43 N 675952.97 E 0.000 7591.92 Projected Survey -- All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 1.452° (True). Magnetic Declination at Surface is 25.4810 (21-Dec-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 13020.0Oft., The Bottom Hole Displacement is 7592.36ft., in the Direction of 2.0720 (True). . 8 January, 2004 - 15:48 Page 4 of 5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 07 - 07-29 - 7-29C MWD Your Ref: API 500292178203 Job No. AKMW2827126, Surveyed: 31 December, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northin9s Eastings (ft) (ft) (ft) Comment 9733.69 9746.00 13020.00 7769.74 7779.18 8939.95 4823.79 N 4831.55 N 7587.40 N 71.09 W 69.59 W 274.54 E Tie On Point Window Point Projected Survey . Survey tool program for 07-29 - 7-29C MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9733.69 0.00 9733.69 7769.74 13020.00 7769.74 AK-1 BP _HG (07-29) 8939.95 MWD Magnetic (7-29C MWD) . 8 January, 2004 - 15:48 Page 5 of 5 DrillQuest 3.03.05.005 . r ~ . FRANK H. MURKOWSKI, GOVERNOR AIf"SIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit PBU 07-29C BP Exploration (Alaska), Inc. Pennit No: 203-192 Surface Location: 452' SNL, 327' WEL, Sec. 33, T11N, R14E, UM Bottomhole Location: 1955' NSL, 115' WEL, Sec. 21, T11N, R14E, UM Dear Mr. Isaacson: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). ~ .. BY ORDER OF THE COMMISSION DATED this /q1day of November, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ""CiA- tll/~{wfYJ 1 a. Type of work 0 Drill ORe-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3; Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 452' SNL, 327' WEL, SEC. 33, T11 N, R14E, UM Top of Productive Horizon: 412' NSL, 191' WEL, SEC. 21, T11N, R14E, UM Total Depth: 1955' NSL, 115' WEL, SEC. 21, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-675856 y-5950465 Zone-ASP4 16. Deviated Wells: Kickoff Depth 18.. Gasiog Program Size Casinç¡ 7" _ STATE OF ALASKA _ ALASKA Clll'AND GAS CONSERVATION CO~SION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: IS! Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 13121 TVD 8941 7. Property Designation: ADL 028306 III Redrill ./ III Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU 07 -29C ~ 12. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 8. Land Use Permit: 13. Approximate Spud Date: December 22,2003 14. Distance to Nearest Property: 28,825 9. Acres in Property: 2560 9780 ft Maximum Hole Angle 93° 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool (Height above GL): 52.9' feet 15-47 is 108' away at 13003' MD / 17. Anticipated pressure (see 20 MC 25.035) ;'"" Max. Downhole Pressure: 3708 psig. Max. Surface Pressure: 2879 psig Quantity of Cemeot (cJ.or sacks) (including ;,tage data) 182 sx Class 'G' 304 sx Class 'G' - 6" 4-1/2" Weight 29# 12.6# Grade L-80 L-80 Coupling Length BTC-M 859' IBT-M 2762' MD 9650' 10359' TVD 7735' 8233' MD 10509' 13121' TVD 8343' 8941' Hole 8-1/2" 19. PRESENTW¡;:LL CONDITION SUMMARY (To, be completed fQrRedrill AND Re~entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Depth MD (ft): Depth TVD Junk (measured): 12550 8944 None 12533 8944 9850 Structural Conductor 110 20" 2568 # Poleset 110' 110' Surface 3767' 13-3/8" 291 sx CS II, 3000 sx CS III, 600 sx 'G' 3767' 3626' Intermediate 10591 ' 9-5/8" 354 sx CS 1,700 sx Class 'G' 10591' 8424' Production Liner 720' 7" 387 sx Class 'G' 10371' - 11091' 8269' - 8777' Liner 766' 3-3/16" 123 sx Class 'G' 10363' - 11129' 8263' - 8802' Liner 2241' 3-1/2" x 2-3/8" 61 sx Class 'G' 10305' - 12546' 8221' - 8944' 20. Attachments IS! Filing Fee 0 BOP Sketch IS! Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8953' - 8943' IS! Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report IS! Drilling Fluid Program IS! 20 MC 25.050 Requirements Perforation Depth MD (ft): 11400' - 12520' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Billlsaacson Title Senior Drilling Engineer Signature l ~ll \ Phone 564-5521 Date: Contact Rob Tirpack, 564-4166 Date Prepared By Name/Number: Terrie Hubble, 564-4628 Permit To Drill I API Number: Number: 20 _~ - / c¡ 2. 50- 029-21782-03-00 Conditions of Approval: Samples Required Hydrogen Sulfide Measures Other: ~st &VE 10 ~$OO p~¿. DYes ~No gYes D No I Permit APproval/ L·(l Date: II lq~? Mud Log Required Directional Survey Required See cover letter for other requirements DYes ~ No .81 Yes [] No OrIginal Signed By Sarah paün ORIG/NAL COMMISSIONER BY ORDER OF THE COMMISSION ( I //9 ~ß SUb~t In Óuplicate Approved By: Form 10-401 Revised 3/2003 Date It e IWell Name: 17-29C Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 1 A Bottom Hole Location: x = 675,856 Y = 5,950,465 452' FNL 327' FEL Sec. 33, T11 N, R14E Umiat X = 675,835 Y = 5,956,610 TVDss 8,900' 4867' FNL 191' FEL Sec. 21, T11 N, R14E Umiat X = 675,871 Y = 5,958,154 TVDss 8,888' 3325' FNL 115' FEL Sec. 21, T11N, R14E Umiat I AFE Number: 1 PBD4P2158 1 I Estimated Start Date: 112/22/03 1 I MD: 113,121' 1 I TVD: 18,941' 1 ,/ I Rig: 1 Nabors 2ES / I Operating days to complete: 120.0 I GL: 124.4' I I KB: 128.5' I I KBE: 152.9' I Well Design (conventional, slim hole, etc.): 1 Dual String Horizontal Sidetrack I Objective: 1 Ivishak Zone 1 A Formation Markers (Sperry wp04) Formation Tops MD TVD THRZ N/A 7,696' KOP 9,780' 7,805' BHRZ 9,848' 7,856' TJF 9,895' 7,891' T JD 10,050' 8,005' T JB 10,256' 8,157' TSAG 10,509' 8,343' TSHU 10,559' 8,380' TSAD-TZ4B 10,627' 8,430' TCGL-TZ3 10,857' 8,599' BCGL-TZ2C 10,945' 8,664' 23SB-TZ2B 11,027' 8,724' 21TS- TZ2A 11,183' 8,833' TZ1 B 11,303' 8,896' TD 11,121' 8,941' BSAD N/A 8,963' TD Criteria: Based on 800' of perfable Zone 1A. 7-29C Permit to Drill TVDss 7,643' 7,753' 7,803' 7,838' 7,952' 8,104' 8,290' 8,327' 8,377' 8,546' 8,611' 8,671' 8,780' 8,843' 8,888' 8,910' Comments 8.6 ppg EMW 8.6 ppg EMW 8.6 ppg EMW Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Not penetrated lo.R 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW .g.ç Page 1 e e Directional - Sperry wp04 KOP: 9,780' MD Maximum Hole Angle: _430 in 8-1/2" Intermediate section -930 in 6" horizontal section. Close Approach Wells: There are three (3) wells that have been ris~t 1 in 200 to pass BP's anti- collision policy: 15-47,15-14, and 15-13~ 15-47 has a center to center distance 0 0', his occurs at 13,003' MD at 7 -29C and 9400' MD at 15-47. 15-47 is curren shut-in and plugged back with sand in the tubing. This is the closest well to 7-2~. / 15-14 has a center to center distance of ..,5 ; this occurs at 10,005' MD at 7 -29C and 9475' MD at 15-14. 15-14 is curren y shut-in and plugged back with sand over the perfs. ='.'" 15-13 has a center to center distance 0 04', this occurs at 11,961' MD at 7 -29C and 10,075' MD at 15-13. 15-13 is a c roducer that is currently on production. Survey Program: MWD with IFR/Casandra. Nearest Property Line: 28,825' CasingITubing Program Hole Size CsgfTbg O.D. Wt/Ft Grade Conn Length Top Btm /" MDrrVD MDrrVD 8-1/2" 7" 29# L-80 BTC-M 859' 9650'/7735' 10509'/8343' 6" 4-1/2" 12.6# L-80 IBT -M /' 2762' 10359'/8233' 13121 '/8941' Tubing 4-1/2" 12.6# L-80 IBT-M 10,272' GL 10300'/8194' Mud Program Window Milling Mud Properties: LSND I Whip Stock Window 9 5/8" I Density (ppg) I Viscosity I PV YP I 10 sec gel I Chlorides I PH I API FII 10.8 40 - 60 15-25 40+ 15-20 <1000 9.0- 9.5 4-6 Intermediate Mud Properties: LSND I 8-1/2" hole section Density (ppg) I Viscosity I PV YP I 10 sec gel Chlorides I PH I API FII 10.8/' 40 - 60 12-14 22-28 15-20 <500 9.0 5-6 Production Mud Properties: Flo-Pro I 6" hole section Density (ppg) I TauO I PV YP I LSYP Chlorides I pH API FI 8.4 - 8.5 3-7 10 26-30 8-14 < 3,000 9.0 - 9.5 4-6 Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GR/Res- Real time Open Hole: None Cased Hole: None 6" Production: Drilling: Open Hole: Cased Hole: Sample Catchers - over entire interval, samples described Dir/GR - Real time None None 7-29C Permit to Drill Page 2 e e Cement Program I Casing Size 17" 29#, L-80 Intermediate Liner Basis: lead: None Tail: Based on 605' of 7" X 8-1/2" open hole with 40% excess, 80' shoe track, 150' liner lap, and 200' 4" DP X 9-5/8" casing excess. Tail TOC: 9750' MD (TOl) I Total Cement Volume: I lead I None /l ~') Tail 38 bbls, 211 ftC?A'acks Class G @ 15.8 PP~.6J.t3/sack I Casing Size 14.5" 12.6#, L-80 Production Liner Basis: lead: None Tail: Based on 2627' of 4-1/2" X 6" open hole with 40% excess, 150' 4-1/2" X 7" Liner lap, and 200' of 7" X 4" DP excess. Tail TOC: 10355' MD 1TOl) I Total Cement Volume: lead I None /l L'J Tail 65 bbls, 365 ft3,~cks Class G @ 15.8 ppg~Jt3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing/7" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 3708 psi (8.6 ppg @ 8292' TVDss) 2879 psi (.10 psi/ft gas gradient to surface) Infinite with a 12.0 ppg FIT Rams test to 3,500 psi/250 psi. /' Annular test to 2,500 psi/250 psi 3500 psi surface pressure 12.0 ppg FIT after drilling 20' outside window 3286 psi (7.1 ppg @ 8900' TVDss) 2396 psi (.10 psi/ft gas gradient to surface) Infinite with 9.6ppg FIT Rams test to 3,500 psi/250 psi. / Annular test to 2,500 psi/250 psi 3500 psi surface pressure 9.6 ppg EMW FIT 8.4 ppg Seawater / 6.8 ppg Diesel Disposal . No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. 7 -29C Permit to Drill Page 3 e e Sidetrack and Complete Procedure Summary Pre-Riq Work: 1. Drift the 4-1/2" tubing to the top of fish @ -9850' MD. 2. Chemical cut the 4-1/2", 12.6#, L-80 BTC-M tubing at -9820' MD. 3. Fluid pack T X IA with seawater and freeze protect same with diesel. 4. Test the 9-5/8" pack-off to 5000 psi and tubing hanger seals to 3000 psi. 5. Function all lock-down screws. Repair or replace as needed. 6. Bleed casing and annulus pressures to zero. 7. Set a BPV in tubing hanger. Secure well. 8. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. Riq Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. /' 4. Pull 4-1/2" tubing from above pre-rig cut. 5. RU e-line. Run GR/JB for 9-5/8",47# casing to top of tubing stub. ~ 6. MU 9-5/8", 47# bridge plug on e-line with CCL. RIH and set at 9800' MD, set as needed to avoid cutting a casing collar. 7. Pressure test casing to 3500 psi for 30 minutes. ../' 8. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 9. Swap over to 10.8 ppg milling fluid. 10. Mill window in 9-5/8" casing at 9800' MD, plus 20' past middle of window. Perform FIT. POOH. / 11. MU 8-1/2" drilling assembly with Dir/GR/Res and RIH. Kick off and drill the 8-1/2" intermediate interval, building and turning at 5°/100' to a 43° hold angle. /~ 12. Drill ahead to casing point at Top Sag River to an estimated depth of 10,509' MD. 13. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 9,6~.MD. Displace cement with mud. POOH. 14. MU6" BHA with Dir/GR and RIH to the landing collar. 15. Pressure test wellbore to 3500 psi for 30 minutes. /' 16. Drill shoe track. Swap over to 8.6 ppg mud and drill 20' of new formation. Perform FIT. 17. Drill the 6" production interval b~ing at 10°/100' to horizontal, targeting Z1A Ivishak. Drill ahead to an estimated TD of 13,121' MD. 18. Run and cement a 4-1/2" liner throughout the 6" wellbore and back into the 7" drilling liner to 10,359' MD. .....- 19. Displace well to clean seawater. 20. RIH with DPC perf guns. Perf intervals to be determined from LWD logs. 21. POOH. LD DP and perf guns. 22. Run 4-1/2",12.6#, L-80 completion tying into the 4-1/2" liner top. _____. 23. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. ", 24. Set and test TWC. 25. ND BOPE. NU and test the tree to 5000 psi. 26. Freeze protect the well to -2200' and secure the well. 27. RDMO Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. 7-29C Permit to Drill Page 4 - e 7-29C Drilling Program Job 1: MIRU Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto 18-03B. The closest neighboring wells are spaced as follows: 7-28A at -59' and 7-14A at -60'. Care should be taken while moving onto the well. Spotters will be used at all times. /' ~ Drill Site 7 is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Reading Date 7 -28A 4 ppm 10/04/95 7-14A 2 ppm 02/10/01 15-47 4 ppm 03/05/01 15-13 4 ppm 02/03/02 #1 Closest SHL with H2S Reading #2 Closest SHL with H2S Reading #1 Closest BHL with H2S Reading #2 Closest BHL with H2S Reading ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Conüngencres ~ 7-29B is currently shut-in at surface. Pre-Rig operations did not NOT include cement work. The existing perforations will remain uncemented. 7-29B was drilled by CTD Rig Nordic 2 in 2/03. During perforation operations, the perf guns became stuck while POOH. 7 -29B has open perforations below the fish. Monitor well at all times for signs of pressure or fluid losses.gas. ~ Note and record required PU weight to pull tubing at cut point. ~ NORM test all retrieved well head and completion equipment. ~ Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP ~----- Job 3: Window Mill HazardsandConüngencres ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP 7-29C Permit to Drill Page 5 - e Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies >- The intermediate section will kick off in the Kingak 'JD' interval and drill to the top of Sag River. For this well, due to the tangent at 43° inclination at a 10° azimuth, maintain mud weight at 10.8 ppg, from the KOP to the 7" liner point. Follow all shale drilling practices to minimize potential problems. - >- There are no fault crossings in the intermediate section. >- There is one close approach issue with 15-14 while drilling the intermediate hole section. 15-14 has a center to center distance of 351', this occurs at 10,005' MD at 7-29C and 9475' MD at 15-14. 15-14 is currently shut-in and plugged back with sand over the perfs. >- KICK TOLERANCE: In the worst-case scenario of 9.6 ppg pore pressure at the Sag River depth, a fracture gradient of .12.0 ppg at the 9-5/8" casing window, and 10.8 ppg mud in the hole, the kick tolerance is infinite. /' Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 6: Install 7" Intermediate Liner Hazards and Contingencies >- Avoid high surge pressures with controlled running speeCfir an by breaking circulation slowly. High surge pressures could lead to losses to the Sag River ~acerb ingak instability problems. >- Ensure the liner top packer is set prior to POO~ismay require gOing through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP ~;-!-,~"""""'~-~. 7-29C Permit to Drill Page 6 . e Job 7: Drill 6" Production Hole Hazards and Contingencies ~ A pump out sub will be run in the BHA to aid in placing LCM material. ~ There is one fault crossing in the production section. This occurs at -12,510' MD and has an estimated throw of 10' to the North. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ There are two close approach issues while dril '1he production hole section. The wells are 15-47 and 15- 13. 15-47 has a center to center distance 'fOs:{this occurs at 13,003' MD at 7-29C and 9400' MD at 15- 47. 15-47 is currently shut-in and plugge bðêk with sand in the tubing. This is the closest well to 7-29C. 15-13 has a center to center distance of 1044', this occurs at 11,961' MD at 7 -29C and 10,075' MD at 15-13. 15-13 is a cycle producer that is currently on production. ~ KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gradient of 9.5 ppg at the 7" casing window, and 8.5 ppg mud in the hole, the kick tolerance is Infinite. /" Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP . ............___:w.......-~, ~--- Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.6ppg mud will be -650psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. ~ Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Halliburton Cement Program ~_.'<.=.'<, Job 10: DPC Perforate Production Casinq Hazards and Contingencies ~ Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs . .:. Follow Schlumberger's perforating practices and recommendations. .:. "OPC Perforating" RP _.~. ,...........,w~."!'ë." 7-29C Permit to Drill Page 7 e e Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP ~~~- Job 13: ND/NUlRelease Riq Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto 18-038. The closest neighboring wells are spaced as follows: 7-28A at -59' and 7-14A at -60'. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 7-29C Permit to Drill Page 8 e e 7-29C Well .Summarv of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Hole Section: · There is one close approach issue: 15-14. This well has a center to center distance of 351', this occurs at 10,005' MD at 7-29C and 9475' MD at 15-14. 15-14 is currently shut- in and plugged back with sand over the perfs · Differential sticking has been experienced in the past. Keep pipe moving at all times. · There are no fault crossings expected in the intermediate hole section. · Lost circulation while drilling the intermediate hole has not been problematic at DS7. In the event of lost circulation, consult the LCM Decision Tree. · The intermediate hole section will be drilled with a recommended mud weight of 10.8 ppg to ensure shale stability in the Kingak. · Kick tolerance is Infinite with a 12.0 ppg FIT. Production Hole Section: · There is one fault crossing in the production section. This occurs at -12,510' MD and has an estimated throw of 10' to the North. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. · Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. · There are two close approach issues while drilling the production hole section. The wells are 15-47 and 15-13.15-47 has a centerto center distance of 108', this occurs at 13,003' MD at 7-29C and 9400' MD at 15-47. 15-47 is currently shut-in and plugged back with sand in the tubing. This is the closest well to 7-29C. 15-13 has a center to center distance of 1044', this occurs at 11,961' MD at 7-29C and 10,075' MD at 15-13. 15-13 is a cycle producer that is currently on production · Kick tolerance is Infinite with a 9.6 ppg FIT. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULFIDE - H2S / · This drill-site not designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE DS 7 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 7-29C Permit to Drill Page 9 TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = ~~~~".~.,..~~,~,..,~ KOP= Max Angle = ~.....~.~,,^^~ Datum MD = DatumTVD= 4-1/8" FMC FMC ~~._."._.' ..... .0<" . AXELSON 65' e 07-298 I S~TES: 2600' 96 @ 12005' 11220' 8800' SS . 113-3/8" CSG, 72#, K-55, ID = 12.347" H 3767' J Minimum ID = 1.91" @ 10325' 3-1/2" X 2-3/8" XO :-, ¡Top of Fish @ 9850,0 · TOP OF 3-3/16" LNR, 6.2#, ID = 2.786" H 10368' ~ 19-5/8" X 7" LNR HGR H 10371' I ·~r 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 10460' 1 19-518" CSG, 47#, L-80, ID = 8.681" H 7" LNR, 29#, L-80, .0372 bpf, ID = 6.184" H 11470' 1 TOP OF WHIPSTOCK H 11130' PERFORA TION SUMMARY REF LOG: ANGLEATTOPPERF: 83 @ 11400' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 1-1/2" 4 11400-11695 0 02/15/03 1-1/2" 4 11735 - 12030 0 02/15/03 1-1/2" 4 12090 - 12200 0 02/15/03 1-1/2" 4 12310 - 12335 0 02/15/03 1-1/2" 4 12385 - 12520 0 02/15/03 NOT CONFIRMED; GUNS LEFT DOWN HOLE 2223' H 4-112" OTIS HRQ SSSVN, ID = 3.813" I GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 2811 2804 13 TGPD DOME TG 16 02/23/03 IlL 2 5260 4623 46 TGPD SO TG 20 02/23/03 3 7052 5885 46 TGPD DMY TG 06/19/02 4 8378 6803 46 TGPD DMY TG 06/21/88 5 9367 7503 44 TGPD DMY TG 06/21/88 6 9889 7894 38 TGPD DMY TG 12/30/98 7 10191 8133 39 TGPD DMY TG 11/05/98 8 10281 8203 41 TGPD DMY TG 06/19/02 i 10305' H 3.70" BKR DEPLOYMENT SLV, ID = 3.0" 1 10320' H 3-1/2" HES XN NIP, ID = 2.75" 1 -l 10325' H 3-1/2" X 2-3/8" XO, ID = 1.91" I ~ 10365' 11 TOPOFBKRLOCSEALASSY I (BEHIND CT LNR) 10366' 11 9-5/8" X 4-1/2" BKR DB PKR, ID = 4.750" I (BEHIND CT LNR) 10377' 11 BTM OF 4-1/2" BKR SEAL ASSY I (BEHIND CT LNR) 10379' 11 BTM OF BKR SBE, ID = 4.750" I (BEHIND CT LNR) 10449' H 4-1/2" OTIS XN NIP, ID = 3.8" (MILLED OUT) I 10461' H 4-1/2" WLEG (BEHIND LNR) 1 L ~ ~ MILLOUT WINDOW 11129' - 11133' 19955' -12217'11 FISH (SEE WELL I FILE FOR DETAILS) 12533' H PBTD I I 2-3/8" LNR, 4.41#, L-80, .0036 bpf,ID= 1.92" H 12546' 1 .m 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.786" H 12815' 1 DATE 03/07/88 12/25/98 02/19/03 02/23/03 06/05/03 09/10/03 REV BY COMMENTS ORIGINAL COMPLETION CTD SIDETRACK (07-29A) DAC/KK CTD SIDETRACK (07-29B) DAC/KK GLV C/O CMOITLP MAX ANGLE CMOITLP DATUM MD CORRECTION DATE REV BY COMMENTS PRUDHOE BAY UNfT WELL: 07-29B PERMfT No: 2022390 API No: 50-029-21782-02 SEe 33, T11 N, R14E, 452' FNL & 327' FEL BP Exploration (Alaska) 7-2118 Pre-Rig Work / ~ L . TREE = WELLHEAD = ACTUA TOR = ~,^,'".~~'"' KB. ELEV = BF. ELEV = KOP= .. n ".... _""'~ Max Angle = .--.----.--"---,-------------..,----,'.-,,,'-,^ Datum MD = DatumTVD= 4-1/8" FMC FMC AXELSON 65' . ~ (.- Tubing Cut @ 9,820' , Top of Fish @ 9,850' :....: Top of Deployment Sleeve @ 10,305' 2600' 96 @ 12005' ".,...,,~,~.~~'" 11220' 8800' SS ~ ~ fï ~ ~ ~ m Date 11-11-03 Rev By Comments RBT Proposed Pre-Rig Work PRUDHOE BAY UNIT WELL: 7-29B API NO: Permit NO: GPB Rotary Drilling 7 -29C ptoposed Cottlpletion 3767' ~ 'X' Nipple @ 2200' MD . 13-3/8" 72# K-55 , , TREE = 4-1/8" FMC WELLHEAD = FMC w<_,_.~__._..___.___________.___...._...........~, ~ , ACTUA TOR = AXELSON "H ~"."~""~~mm .. '" "M~..m~,. KB. REV = 65' SF. REV = WW MM '" "~"."w,,.~~u KOP = 2600' Max Angle = 96 @ 12005' . .~.~muw "._, , w..w'w'w~w~....w. Datum MD = 11220' , ... ~'w~~"wo,,' Datum TVD = 8800' SS ~4-1/2", 12.6#, L-80, IBT-M Tubing I Tubing Tail: -10' Pup Joint -X Nipple (3.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (3.813") -20' Pup Joint -XN Nipple (3.725") -10' Pup Joint -WLEG 9,650' 9-5/8" X 7" HMC Liner Hanger with C2/ZXP Liner Top Packer / 9,800' - 9,820' 9,850' 10,305' GLM Design: #4 - 3150' TVD - 4-1/2" X 1" - SV #3 - 5000' TVD - 4-1/2" X 1" - DV #2 - 6500' TVD - 4-1/2" X 1" - DV #1 - 8000' TVD - 4-1/2" X 1" - DV ~ . . - 7" X 4-1/2" Packer @ 10,300' ~' 10,591' .. 11,470'~ 7", 29#, L-80~ Pil !- j q:<~ ~ 7" X 4-1/2" HMC Liner Hanger with C2/ZXP Liner Top Packer @ 10,359' 7", 29#, L-80, BTC-M @ 10,509' .",. \ ~ 9-5/8",47#, L-80 ~ '@ f kt ..~;+1. ~,~ '. ili· ::~ '~:-(J .0 12,546' ~ 2-3/8",4.4#, L-80 12,815' W. 3-3/16",6.2#, L-80 Date Rev By Comments /' 4-1/2",12.6#, L-80, IBT-M @ 13,121' 11-11-03 RBT Proposed Completion PRUDHOE BAY UNIT WELL: 7-29C API NO: Permit NO: GPB Rotary Drilling . PROTRACTED SEC~ION ~:._ 28 ~__ . C:~C. 33 I I .-~ ~. i\'~ i;1 ~~ - ~o ,~ I (It 0 I O. -'. -' 0 :0 o o - ,N 0 O. '1 0 "0 :-C-O ~O -.""'" . ~q ... OF A( '__ I ..~~...~.. ·...f.n'a. r"-r.··· : ..~~... '"CI) · , ~..,. ,,* ... 49TH i \ '* f ,················t,· .... If \. --, .~.~I \~.. . . ~ ~. dERA1D D. . . LS-6299 _.. . . . .~_.. ... "~.v ~..~..~~-~ . -,....U1esslOnJ' ~. - ",~.......... 1ts H I " "9 _ 1/ SEC. 27 -- .. .. . c . I- ... . SEC. 34 tf -. D { - ... .~ ò I J4 I ~ -- TUN TION .'--- o o o o o o o o 4 ~WELL No. 28 LA1: . 7001" 13.!S88" LONG.. 14SO 34' 40,140" 394' F. N.L. ELEV. T.O.PAD: 24.1 \ . ~WELL No. 29 LAT.· 700l'·13~010.. LONG.· 148°34'39.770" . 452' F.N.L. ELEV. T.O. PAD. 24.4' , HEREBY CER~FY THAT I AM . PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA' AND THAT THIS PLAT REPRESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF: 1-8-88 NOTES \¡ WE LL No. 30 LAT.: 70° 16'" .857 LONG.· I~ 34' 39.044 510' F.N.l.. ELEV. T. O. PAD. 24.0 I VICINITY MAP NO SCALE Y.5,950,523.12 X. 675,841.74 . 339~ F. E. L. , ELEV. O.G.: 22.0 ± Y. 5,950,464.69 11:. 615,855. n 327'. . F.£L ELEV. O.G.. 22..0' ± V.5.950.348.05 X. 6~.183.46 302' f.E..L.' ELEV. O.G.: 22.01 ± :1.fImiY & ~ 1£. ; .". CO ~;'.';:':_ I. IASIS OF COORDINATES 1$ HVL AS.BUILT,WELLS I THRUV 2. ALL COORDIN ATES ARE A..S.P. ZONE 4. 3. ALL DISTANCES ARE TRUE. 4. ELEVATIONS ARE ARCD DATUM. 5. O.G. ELEVATIONS ARE FROM OWG PLD· 3115 -??oo1 6. REF. DWG: VECO, "AS STAKED· CONDUCTORS 27- 35. 7. REF. F.B. LPB 88-1. o 1/8/88 CONDUCTOR RIEV DATE. DfSCRlfÞTlO II <> ARCa Ala.ka Inc. Sublidia" of At/otitic Riehfi.ld CoMpony PRUDHOE FACILITIES PROJECT. PRUDHOE BAY DRA.'''~ TITLE AS-BUILT DRILL SITE No.7 WELL No.s 28,29 8 ~O OAU ORA.. BB An/CC .... AS 1886 f /8/88 CNECKED "'B. ~ lID. SII7 KALE B8 ... B. g/,t N . T. S . A....ItOVf. 77 K' ¿ .oft( ;~~7"" ay CHIC'D A....'D ORA.I"~ .... . I"££T R£V. NSOP - ??oo- CEA -3100003 201 OF I 0 AS .eUIL T COMPANY DETAILS BP Amaro REFERENCE INFORMATION SURVEY PROGRAM Calculation Method: Minimum Curvature Error Sysa."1u: ISCWSA &','"IIn Method: Trav Cyiinœr North Error Surface: Ellipûça!'" Casing Warning Method: Rules Based Depth Fm Depth TQ Survey/Plan 9180.00 1312050 P1a.nood:7~29Cwp04V27 Tool MWD+JFR+MS lÀite: 1111112003 Date Cheeked: Reviewed: Pate:_ FORMATION TOP DETAILS WELL DETAILS N~ +-Ni-S +Ð-W Northing F-""'g Ù1ritude Longitude S.lot No. TVDPath MDPath Formation ()7·19 2355J8 ·147151 59504ó4,6I) 675855,79 í48":34';39.710W 29 1 7855.90 9847.62 BHRZ TARGET DETAILS 2 7890.90 9895.15 LCU I Kingak I TJF 3 8004.90 10049.97 TJD """" lVD ;'NI~S +E/-W -... Easting Shape 4 8156.90 10256.40 TJB Hard Line llL54 5 8342.90 10509.01 Sag River 7·29C Tl Rev 2 19492 6 8379.90 10559.26 Shublik F29C Poly RIiJ'" 1 122,00 7 8429.90 10627.!6 TSAD I TZ4B 8 8598.90 10856.68 TCGL I TZ3 SECTION DETAILS 9 8663.90 10944.96 BCGL I TZ2C !O 8723.90 11026.74 23SB I TZ2B Sec MD Inc Azi TVD +N/-S +E/-W DLe! TFace VSec Tatge! 11 8832.90 11182.94 2ITS I TZ2A !2 8895.90 11302.83 TZlB ! 9780.00 39.31 11.78 7805.40 4852.77 -65.31 0.00 0.00 484956 13 8918.90 11362.20 TDE 2 9800.00 41.40 9.97 7820.64 4865.49 -62.87 ~.OO -30.00 4862.33 3 9828.71 4258 8.75 7841.97 4884.44 -59.75 5.00 -35.00 4881.35 CASING DETAILS 4 10509.01 4258 8.75 8342.90 5339.39 10.27 0.00 0.00 5337.93 5 10944.96 42.58 8.75 8663.90 5630.93 55.14 0.00 0.00 563052 No. TVD MD Name Size 6 10956.98 42.83 7.02 8672. 73 5639.00 56.26 10.00 -78.76 5638.62 7 11088.79 42.83 7.02 8769.40 5727.94 67.20 0.00 0.00 5727.80 8342.90 10509.01 7" 7.000 8 I 1560.59 90.00 8.00 8952.90 6144.51 122.80 10.00 1.34 6145.65 7-29C Poly Rev 1 9 12473.09 90.00 8.00 8952.90 7048. I 4 249.80 0.00 0.00 7052.20 8940.90 13120.49 41/2" 4.500 10 13120.50 92.09 342.18 8940.90 7687.59 194.92 4.00 -85.21 7690.06 7-29C Tl Rev 2 8800-- 7600- SW Oir 12/toO' : 9780' MD. 7805.4'TVO Start Oir 5/100': 9800' MD. 7820.64'TVD End Oir : 9828.71' MO, 7841.97' TVO ï:S' ~ :5 ::!. .d Õ. Ö -¡¡¡ c 1::: " ;:. " 2 ¡... 1 J088.79'MD, 8769.4'TVD Start Dir4/1OO': 12473.09' MD. 8952.9'TVD : 11560.59' MD. 8952.9' TVD , I ' 8000 I ¡ I ! I 1 I , I ' 8400 COMPANY Dh"TAILS BP Amoco REFERENCE INFORMATION 750(}- 13120.5' MD, 8940.9' TVD : 12473.09' MD, 8952.9'TVD 07-29 (07-29A) " 650(}- ~ 8 :!1 +' ):¡ 1: ~. ):¡ g '" 500(}- MD, 7841.97' TVD 7820.64'TVD MD, 7805.4'TVD 4500 -500 1 I I I ! ¡ 1 500 West(-)IEast(+) [500ft/in] , I ' 1000 SURVEY PROGRAM .!)eptb Pm Depth To Survøy!Plan 9780.00 13120.50 Planned: 7~1fJC wp04 V27 Tool MWD+!FR+MS ---I I I Plan: 7-29C wp04 (07~29/P¡an 07-29C) Created 5y: Ken AHen C'hecked: Date: 11111/2003 Da1e:_ Date Revie:wed: WELL DETAILS N~ +NI·S +FJ-W Northing Easting Luriiude Longitude Slot 01-29 235538 -1471.51 5950464.69 {i7S855.79 10~16'13.(I1ON 14SØ34J9.770W 29 N~ TVD +NI~S +Ej-W 5234.47 7687.59 6144.51 Sec MD Ine 1 9780.00 39.31 2 9800.00 41.40 3 9828.7! 42.58 4 10509.01 42.58 5 10944.96 42.58 6 10956.98 42.83 7 11 088. 79 42.83 8 11560.59 90.00 9 12473.09 90.00 10 13120.50 92.09 Azí TVD +N/-S 11.78 7805.40 4852.77 9.97 7820.64 4865.49 8.75 7841.97 4884.44 8.75 8342.90 5339.39 8.75 8663.90 5630.93 7.02 8672.73 5639.00 7.02 8769.40 5727.94 8.00 8952.90 6144.51 8.00 8952.90 7048.14 342.18 8940.90 7687.59 l ,I I I' I I ¡P I ,I' ,I Il TARGET DETAILS Northing Ea..ocim¡: .Shàpe SECTION DETAILS +E!~W DLeg TFace VSec Target -65,31 0.00 0.00 4849.56 -62.87 ~2;00 -30.00 4862.33 -59.75 5.00 -35.00 4881.35 10.27 0.00 0.00 5337.93 55.14 0.00 0.00 5630.52 56,26 10.00 .78.76 5638.62 67,20 0.00 0.00 5727.80 122.80 10.00 1.34 6145.65 7-29C Poly Rev 1 249.80 0.00 0.00 7052.20 194.92 4.00 -85.21 7690.06 7-29C Tl Rev 2 FORMATION TOP DETAILS No. TVDPath MDPath Fonnalion 1 7855.90 9847.62 BHRZ 2 7890.90 9895.15 LCU! Kingak! TJF 3 8004.90 10049.97 Till 4 8 I 56.90 10256.40 TJB 5 8342.90 10509.01 Sag River 6 8379.90 10559.26 Shublik 7 8429.90 10627;16 TSAD! TZ4B 8 8598.90 10856.68 TCGL! TZ3 9 8663.90 10944,96 BCGL! TZ2C 10 8723.90 11026.74 23SB ! TZ2B 11 8832.90 11182,94 21TS/TZ2A 12 8895.90 11302.83 TZtB 13 8918.90 11362.20 TDF CASING DETAILS No. TVD MD Name Size 1 8342.90 10509Æ 7" 7.000 2 8940.90 13120.49 41/2" 4.500 e Sperry-Sun KW A Planning Company: Field: Site: WeD: WeDpath: Plan: BP Amoco Prudhoe Bay PB DS 07 07-29 Plan 07-29C 7-29C wp04 Principal: Yes Vertical Section (VS) Survey Calculation Method: Date Composed: Version: Tied-to: Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: PB DS 07 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948144.78 ft 677382.28 ft Latitude: 70 15 Longitude: 148 33 North Reference: Grid Convergence: e 52.90' 52.9 Well (0.00N,O.00E,1.45Azi) Minimum Curvature Db: Oracle 10/14/2003 27 From: Definitive Path Alaska, Zone 4 Well Centre bggm2003 49.847 N 56.934 W True 1.35 deg WelI: 07-29 Slot Name: 29 07-29 WelI Position: +N/-S 2355.38 ft Northing: 5950464.69 ft Latitude: 70 16 13.010 N +E/-W -1471.51 ft Easting : 675855.79 ft Longitude: 148 34 39.770 W Position Uncertainty: 0.00 ft WelIpath: Plan 07-29C DrilIed From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 52.90' 9/17/2003 57576 nT Depth From (TVD) ft 25.90 Height 52.90 ft +N/-S ft 0.00 Casing Points 07-29 9780.00 ft Mean Sea Level 25.60 deg 80.85 deg Direction deg 1.45 DIameter in in 10509.01 8342.90 7.000 8.500 7" 13120.49 8940.90 4.500 6.125 4 1/2" Formations MD TVD Fllrmations LJthology ft ft 0.00 WS2 0.00 0.00 0.00 WS1 0.00 0.00 0.00 CM3 0.00 0.00 0.00 CM1 0.00 0.00 0.00 THRZ 0.00 0.00 9847.62 7855.90 BHRZ 0.00 0.00 9895.15 7890.90 LeU I Kingak I T JF 0.00 0.00 10049.97 8004.90 TJD 0.00 0.00 10256.40 8156.90 TJB 0.00 0.00 10509.01 8342.90 Sag River 0.00 0.00 10559.26 8379.90 Shublik 0.00 0.00 10627.16 8429.90 TSAD I TZ4B 0.00 0.00 10856.68 8598.90 TCGL I TZ3 0.00 0.00 10944.96 8663.90 BCGL I TZ2C 0.00 0.00 11026.74 8723.90 23SB I TZ2B 0.00 0.00 11182.94 8832.90 21TS I TZ2A 0.00 0.00 11302.83 8895.90 TZ1B 0.00 0.00 11362.20 8918.90 TDF 0.00 0.00 7 -29C Poly Rev 1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 Company: Field: Site: Well: Wellpath: Targets Hard Line -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 7-29C 11 Rev 2 e Sperry-Sun KW A Planning e BPAmoco Prudhoe Bay PB DS 07 07-29 Plan 07-29C Date: 11/1212003 time: 07:54:35 Page: 2 Co-ordinate(NE) Reference: Well: 07-29, True North Vertieal (TVD) Referenee: 52.90' 52.9 Section (VS) Referenee: Well (0.00N,O.00E,1.45Azi) Survey Caleulation Method: Minimum Curvature Db: Oracle Deseription Dip. Dir. ~..p Northing It 5234.47 111.54 5955700.00 675844.99 70 17 4.491 N 148 34 36.521 W 5234.47 111.54 5955700.00 675844.99 70 17 4.491 N 148 34 36.521 W 5628.13 -39.32 5956090.00 675684.99 70 17 8.363 N 148 34 40.916 W 5887.86 -238.32 5956345.00 675479.99 70 17 10.917 N 148 34 46.713 W 5628.13 -38.47 5956090.02 675685.84 70 17 8.363 N 148 34 40.891 W 7687.59 194.92 5958154.24 675871.04 70 17 28.617 N 148 34 34.090 W 6144.51 122.80 5956610.00 675834.99 70 17 13.441 N 148 34 36.193 W 6222.19 9.58 5956685.00 675719.99 70 17 14.205 N 148 34 39.491 W 7164.89 121.64 5957630.00 675809.99 70 17 23.477 N 148 34 36.226 W 7624.70 -77.69 5958085.00 675599.99 70 17 27.999 N 148 34 42.034 W 7853.69 182.75 5958320.00 675854.99 70 17 30.251 N 148 34 34.444 W 7295.51 524.83 5957770.00 676209.99 70 17 24.761 N 148 34 24.477 W 5854.90 316.10 5956325.00 676034.99 70 17 10.593 N 148 34 30.561 W ft 8652.90 8652.90 8652.90 8652.90 8652.90 8940.90 8952.90 8952.90 8952.90 8952.90 8952.90 8952.90 8952.90 Plan Seetion Information MD ft 9780.00 9800.00 9828.71 10509.01 10944.96 10956.98 11088.79 11560.59 12473.09 13120.50 Survey MD ft 9780.00 9800.00 9828.71 9847.62 9895.15 9900.00 10000.00 10049.97 10100.00 10200.00 10256.40 10300.00 10400.00 10509.01 10559.26 10600.00 10627.16 10700.00 10800.00 10856.68 10900.00 10930.02 10944.96 Inel ADm TVD .DI-S .J~uUd Turn TFO deg deg ft deg/10Oft·' d~J ~Qft<!~1 00ft deg 39.31 11.78 7805.40 4852.77 -65.31 0.00 0.00 0.00 0.00 41.40 9.97 7820.64 4865.49 -62.87 12.00 10.47 -9.07 -30.00 42.58 8.75 7841.97 4884.44 -59.75 5.00 4.12 -4.24 -35.00 42.58 8.75 8342.90 5339.39 10.27 0.00 0.00 0.00 0.00 42.58 8.75 8663.90 5630.93 55.14 0.00 0.00 0.00 0.00 42.83 7.02 8672.73 5639.00 56.26 10.00 2.06 -14.43 -78.76 42.83 7.02 8769.40 5727.94 67.20 0.00 0.00 0.00 0.00 90.00 8.00 8952.90 6144.51 122.80 10.00 10.00 0.21 1.34 90.00 8.00 8952.90 7048.14 249.80 0.00 10.00 0.21 0.00 92.09 342.18 8940.90 7687.59 194.92 4.00 0.32 -3.99 -85.21 7-29C Poly Rev 1 7-29C 11 Rev 2 Target Inel ADm TVD Sys TVD ~PN VS DLg. > . TFO deg deg ft ft ft ft <!~1.00ft deg 39.31 11.78 7805.40 7752.50 5955314.30 675677.12 4849.56 0.00 0.00 MWD+IFR+MS 41.40 9.97 7820.64 7767.74 5955327.07 675679.26 4862.33 12.00 330.00 MWD+IFR+MS 42.58 8.75 7841.97 7789.07 5955346.08 675681.94 4881.35 5.00 325.00 MWD+IFR+MS 42.58 8.75 7855.90 7803.00 5955358.77 675683.59 4894.05 0.00 0.00 BHRZ 42.58 8.75 7890.90 7838.00 5955390.66 675687.74 4925.95 0.00 0.00 LeU I Kingak I T JF 42.58 8.75 7894.47 7841.57 5955393.91 675688.16 4929.20 0.00 0.00 MWD+IFR+MS 42.58 8.75 7968.10 7915.20 5955461.01 675696.89 4996.32 0.00 0.00 MWD+IFR+MS 42.58 8.75 8004.90 7952.00 5955494.54 675701.25 5029.86 0.00 0.00 TJD 42.58 8.75 8041.73 7988.83 5955528.10 675705.61 5063.43 0.00 0.00 MWD+IFR+MS 42.58 8.75 8115.37 8062.47 5955595.19 675714.34 5130.54 0.00 0.00 MWD+IFR+MS 42.58 8.75 8156.90 8104.00 5955633.03 675719.26 5168.40 0.00 0.00 TJB 42.58 8.75 8189.00 8136.10 5955662.28 675723.07 5197.66 0.00 0.00 MWD+IFR+MS 42.58 8.75 8262.63 8209.73 5955729.38 675731.79 5264.77 0.00 0.00 MWD+IFR+MS 42.58 8.75 8342.90 8290.00 5955802.51 675741.31 5337.93 0.00 0.00 7" 42.58 8.75 8379.90 8327.00 5955836.23 675745.69 5371.66 0.00 0.00 Shublik 42.58 8.75 8409.90 8357.00 5955863.56 675749.25 5399.00 0.00 0.00 MWD+IFR+MS 42.58 8.75 8429.90 8377.00 5955881.79 675751.62 5417.23 0.00 0.00 TSAD I TZ4B 42.58 8.75 8483.53 8430.63 5955930.66 675757.98 5466.12 0.00 0.00 MWD+IFR+MS 42.58 8.75 8557.16 8504.26 5955997.75 675766.70 5533.23 0.00 0.00 MWD+IFR+MS 42.58 8.75 8598.90 8546.00 5956035.78 675771.65 5571.27 0.00 0.00 TCGL I TZ3 42.58 8.75 8630.80 8577.90 5956064.84 675775.43 5600.34 0.00 0.00 MWD+IFR+MS 42.58 8.75 8652.90 8600.00 5956084.98 675778.05 5620.49 0.00 0.00 Hard Line 42.58 8.75 8663.90 8611.00 5956095.00 675779.35 5630.52 0.00 0.00 BCGL I TZ2C e Sperry-Sun e KW A Planning COß1P"~Y: B~~OCQ Field: Prl,l~hoeBªY Site: PB OS 07 Well: 07-29 W¢IIP~th: Plan 07.29(; Method: Oracle Survey TVD MapN ft ft 10950.00 42.68 8.02 8667.61 8614.71 5956098.39 675779.77 5633.91 10.00 MWD+IFR+MS 10956.98 42.83 7.02 8672.73 8619.83 5956103.10 675780.28 5638.62 10.00 MWD+IFR+MS 11000.00 42.83 7.02 8704.29 8651.39 5956132.20 675783.17 5667.73 0.00 180.00 MWD+IFR+MS 11026.74 42.83 7.02 8723.90 8671.00 5956150.29 675784.97 5685.82 0.00 180.00 23SB I TZ2B 11088.79 42.83 7.02 8769.40 8716.50 5956192.26 675789.14 5727.80 0.00 180.00 MWD+IFR+MS 11100.00 43.95 7.05 8777.55 8724.65 5956199.92 675789.91 5735.47 10.00 1.34 MWD+IFR+MS 11150.00 48.95 7.21 8811.99 8759.09 5956235.96 675793.57 5771.51 10.00 1.31 MWD+IFR+MS 11182.94 52.24 7.29 8832.90 8780.00 5956261.28 675796.19 5796.83 10.00 1.21 211S I TZ2A 11200.00 53.95 7.34 8843.14 8790.24 5956274.84 675797.61 5810.40 10.00 1.15 MWD+IFR+MS 11250.00 58.95 7.45 8870.77 8817.87 5956316.26 675802.00 5851.83 10.00 1.13 MWD+IFR+MS 11300.00 63.94 7.55 8894.66 8841.76 5956359.91 675806.72 5895.49 10.00 1.06 MWD+IFR+MS 11302.83 64.23 7.56 8895.90 8843.00 5956362.44 675806.99 5898.02 10.00 1.02 TZ1B 11350.00 68.94 7.65 8914.64 8861.74 5956405.45 675811.71 5941.05 10.00 1.01 MWD+IFR+MS 11362.20 70.16 7.67 8918.90 8866.00 5956416.81 675812.97 5952.41 10.00 0.98 TDF 11400.00 73.94 7.74 8930.55 8877.65 5956452.54 675816.96 5988.15 10.00 0.97 MWD+IFR+MS 11450.00 78.94 7.82 8942.26 8889.36 5956500.82 675822.41 6036.45 10.00 0.95 MWD+IFR+MS 11500.00 83.94 7.90 8949.70 8896.80 5956549.93 675828.03 6085.57 10.00 0.93 MWD+IFR+MS 11550.00 88.94 7.98 8952.80 8899.90 5956599.48 675833.76 6135.13 10.00 0.92 MWD+IFR+MS 11560.59 90.00 8.00 8952.90 8900.00 5956610.00 675834.99 6145.65 10.00 0.91 7 -29C Poly Rev 1 11600.00 90.00 8.00 8952.90 8900.00 5956649.14 675839.56 6184.81 0.00 0.00 MWD+IFR+MS 11700.00 90.00 8.00 8952.90 8900.00 5956748.46 675851.16 6284.16 0.00 0.00 MWD+IFR+MS 11800.00 90.00 8.00 8952.90 8900.00 5956847.78 675862.76 6383.50 0.00 0.00 MWD+IFR+MS 11900.00 90.00 8.00 8952.90 8900.00 5956947.10 675874.36 6482.85 0.00 0.00 MWD+IFR+MS 12000.00 90.00 8.00 8952.90 8900.00 5957046.41 675885.96 6582.20 0.00 0.00 MWD+IFR+MS 12100.00 90.00 8.00 8952.90 8900.00 5957145.73 675897.56 6681.55 0.00 0.00 MWD+IFR+MS 12200.00 90.00 8.00 8952.90 8900.00 5957245.05 675909.15 6780.89 0.00 0.00 MWD+IFR+MS 12300.00 90.00 8.00 8952.90 8900.00 5957344.37 675920.75 6880.24 0.00 0.00 MWD+IFR+MS 12400.00 90.00 8.00 8952.90 8900.00 5957443.69 675932.35 6979.59 0.00 0.00 MWD+IFR+MS 12473.09 90.00 8.00 8952.90 8900.00 5957516.28 675940.83 7052.20 0.00 0.00 MWD+IFR+MS 12500.00 90.09 6.93 8952.88 8899.98 5957543.03 675943.70 7078.96 4.00 274.79 MWD+IFR+MS 12600.00 90.42 2.94 8952.43 8899.53 5957642.81 675949.97 7178.76 4.00 274.78 MWD+IFR+MS 12700.00 90.75 358.95 8951.40 8898.50 5957742.78 675949.29 7278.73 4.00 274.77 MWD+IFR+MS 12800.00 91.08 354.97 8949.80 8896.90 5957842.44 675941.66 7378.39 4.00 274.73 MWD+IFR+MS 12900.00 91.40 350.98 8947.63 8894.73 5957941.33 675927.12 7477.25 4.00 274.66 MWD+IFR+MS 13000.00 91.72 346.99 8944.91 8892.01 5958038.95 675905.74 7574.84 4.00 274.58 MWD+IFR+MS 13100.00 92.03 343.00 8941.64 8888.74 5958134.84 675877.62 7670.67 4.00 274.47 MWD+IFR+MS 13120.49 92.09 342.18 8940.90 8888.00 5958154.22 675871.04 7690.05 4.00 274.34 41/2" 13120.50 92.09 342.18 8940.90 8888.00 5958154.24 675871.04 7690.06 4.00 274.31 7-29C T1 Rev 2 WELL DETAILS ""'" +NI-8 +E!·W Northing ¡'::&.tíng U¡titude Langit:t.lœ Slot 07-29 235538 -1471.51 595û464.69 675855.79 70~16'!3.0!ON !4R"34'39.770W 29 ANTI-COLLlSION SETTINGS [nterpoJaÚün Method:MD Depth Ran!,,,, From: 9780,00 Maximum Range: 1509.46 Interval: 25.00 To: 13120.50 Reference: Plan: 7-29C wp04 Calculation!\.%1hod: Minimum ('urvature- ErrÖf" System.:- ISCWSA Scan Method: TmvCy1índerNorth Error Surfooe; EJliptical + Casing w.arning Method: Rules- BMed SURVEY PROGRAM Depth Fro Depth To SurveyiPlan 9181100 13 120.50 Planned: 7·29C wp04 V27 MWD+iFR+MS -128 -120 -100 -80 --60 -40 -20 -0 -20 -40 --60 -80 -100 -120 -128 COMPANY DETAfLS BP AmOèO 90 Tool WELL PATH DETAILS Plan07-29C Parent WcJJpai:h: Tie-on MD: 07·29 978ú.OO 52.90' 52.900: Origìn Origin +N/·S +Ef-W SíatÛJ!g FromTVD 25.90 J.45~ 0.00 0.00 LEGEND """ , 2 , 4 , 6 7 , 9 10 MD "" ."" SBL'TION DEl' AILS lVD +N!wS +E!-W DLq¡: TFm::e vSec Target 7~29C Poly Rev 1 7·29C Tl Rev 2 P055162 DATE I I 10/6/2003 CHECK NO. 055162 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 10/6/2003 INV# PR100103B PERMIT TO DRILL FEE H D(·~qû e THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX No. P 055162 CONSOLIDATED COMMERCIAL ACCOUNT PAY: TO THE ORDER OF: Octöber6;2003 II *******$1&0.00*******1 NOT V.81!Q,,~£T.sfl1;W ~AY~. ,.,,~_~._, :-=-...,: 1:: :::"::~. <'..:: .:'.::; ·::s::::::·:.:;"/:.}.:~~:1.~~:;::~.?\:;: :.::1 .............:J~::........,...,................, i~);~.·6;~1;¡;\~;;.~i;;~;;:i;t;··j e 1110 5 5 . b 2111 I: 0... . 20 31 a q 5 I: o. 2 ? 8 q bill e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Pll-OT (PH) "CLUE" The permit is for a new wenbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function· of tbe original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot hole must be clearly differentiated in botb name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for wen (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes tbe liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to tbe Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Company _ BP EXPLORATION (Al.,6.SKA) INC Well Name: PRUDHOE BAY UNIT 07-29C Program DEV Well bore seg PTD#: 2031920 Field & Pool _ PRUDHOE~BAY. PRUDHOE OIL - 640150 nitial ClasslType DEV 11~ GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal 0 Administration I Permit fee ~ttaçhed_ - - - - - - - - - Yj;¡s _ _ _ _ _........ 12 .Le~sj;¡.number .appropri¡:¡te. . . . . . . . - - - - - - - Xes. - - - - - - 3 .U.nique well_n_a[11j;¡_and r:JL!mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Yj;¡S_ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ __ 4 Well JQc¡:¡tj;¡d In_a_ d_efinedpool. . . . _ - - - - - - - Xes. - - - - - - - - - - - - - - 5 WellJQcatj;¡d pr.oper _distance. from driJling unitb.ound.ary_ _ _ Xes. - - - - - - 6 WellJQcat~d properdistançe. from otber welJs. _ _ _ Yj;¡s - - - - - - - - - - - - - - - - 7 .S_uffiçienlaçreage_ayail¡:¡ble ¡ndr;liog lInjl . . . . . . _ _ _ Yes. - - - - - - - - - - - - 8 Jtd~viated, js weJlbQre plaUncJuded . . . - - - - - - - - - - - Yj;¡S. - - - - - - 9 _Operator onl}' affeçted party . - - - - - - - - - - - - - Yj;¡S. - - - - - 10 _Oper.ator bas_appropriateJ:¡ond inJorce _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _Y_es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ 11 Permit can be issued without co_nservation order Yj;¡s.. _. _......... __ - - - - - Appr Date 12 P~rmit c_an be issu.ed witbQut administratil¡e_approvaJ . . . . . _ . . . Xes _ _ _......... - - - - - - -- RPC 11/18/2003 13 Can permit be approved before 15-day wait Yes 14 WeIIJQc¡:¡t~d within ~re~ and_strataauthorlzed byJlljectioo Ord~r # (PuUOfl incomm.ellts)(ForNA _ _ _ _ . . . . . . . _ _ _ - - - - - e 15 _All wel!s_ wit!1iJl J l4J'(Iile _are.a_of reyiew idj;¡otified (For servjc_e well ()I)I}'L _ _ _ _ _ _ . _ _ _ _ _ _ _ _NA _ . _ _ _ _ _ _ _ _ . . . . . . . . . _ . . . . . . . 16 Pre-produ.ced injeçtor;dur¡:¡tio.n_of pre-production Ij;¡Ss. than 3 montbs_ (For.service well only) . NA.... . - - - - - - - - - - - 17 ACMPFïndingof co n.slste ncy has bee.n.issued for.tbis pr_ojeçt ......... _NA - - - - - - - - - - - - - Engineering 18 .C_ollductor stringprQvided . - - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - 19 _S_urfacj;¡casing.pJotec.ts all known. USQWs . - - - - - - - NA 20 CMT vol adequ_ate.to çirculate.o_n .conduçtor. & SUJf.csg . - - - - - - - - - - - - - NA.... _. - - - - - -- 121 _CMT vol adequ.ate.to tie-inlQng .string to_surf csg. . _ _ _ . . . . . . . . . . _ - - - - - NA....._....... ._ - - - - - - - 22 .CMTwill c;oyeralll<no.wnproductiye bQri~on.s. . . . . . . _ . _ .... Y~$. _. - - - - 23 .C.asillg desiglls ad.eClua.te for C,T., B .&. permafr.ost - - - - - - - Xes. - - - - - - 24 .Adequ.ate.tankage.oJ reserve pit. - - - - - - Y.es . . _ . . . . l\I~bors_2ES, . . . . . . . 25 Jf.aJe-drilL has.a. 10,403 fQr abandonment be~1l apprQved - - - - - - - -- - - - - - - - - Xes . . . _ . _ . 11113/2003._ 26 Adequ.ate.wellbore separation-Proposed. . . _ _ _ _ _ _ _ . _ . . ... -... - - - -.... - - - Yj;¡$... - _.... _..... - - - - _......_ 27 Jf.diverter req!Jif~d, dQes it meet reguJa.tions - - - - - - - - ..._.......... .NA . Sidet(ack. . - - - - - - - Appr Date 28 .Drilliog fjuid program schematic & eq.uip Jistadequate. . . . . . . . . . . . . - - - - Yj;¡$. . . Max MW to..8.ppg. . . . . . WGA 11/18/2003 29 BOP¡::s,.d_othey meetreguJation . - - - - - - - - - .... Y~s. - - - - - - - - - 30 .BOP¡::press raJjllg appropriate; Jest to _(puJ p$ig tn .comments) . . . . . . _ .Yes. . . Test to.3500.psi.MSF' 28.79 psi. e 31 Choke.manifold çQmpJies. w/API RF'-53. (May 64). . . . . . . . . . Y.es_ 32 WQrk will OCC!J( withollLoperatjon _sbutdown. - - - - - - - - - - - - Y~$... . 33 Js presençe_ Qf H2S gas. probable. - - - - - - - - - - - - - - - - - - - .... No.. __ 34 Meçt]anicaLcoodjtion of we.lIs within AOR yerified lFor.s.ervice w~1J onJ}')_ NA. .... Geology 35 P~rmit call be issu.ed wlo hyd(ogen. sulfide measures. . . . . . . . . . . _ - - - - - - - - No.... . 36 .D.ata.preseoted on pote.ntial oveJRres.sure .zone$. . . . . . . . . . _ .. NA Appr Date 37 .S~tsmic.analysjs. of $haJlow gaS.ZOlleS NA... . - - - - - - - - - - - - - - - - - RPC 11/18/2003 38 .S~abedcondition Sllrvey(if off-shore) NA - - - - - - - - - - - - - - - - - - -- 39 CQnta.ct name/phone. for.wee~ly prpgressreport$ [e1<ploratory .Dilly] - - - - - - - -- . NA I Geologic Engineering Public ,~k Commissioner: Date: Commissioner Date Commissioner ð'P .D T- '7 9) ~ e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr·...ng Services LIS sca~ility . (~û3- \q~ (" $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 11 10:12:08 2004 )}0t,O Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/02/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.......... ..... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/02/11 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 7-29C 500292178203 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services Il-FEB-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002827126 J. BOBBITT J. RALL / J. MWD RUN 3 MW0002827126 J. BOBBITT J. RALL / J. MWD RUN 4 MW0002827126 T. GALVIN R. BORDES / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 11N 14E 452 327 MSL 0) 52.90 24.40 RECEIVED # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.000 6.000 CASING SIZE (IN) 9.625 7.000 7.000 DRILLERS DEPTH (FT) 9546.0 10522.0 10522.0 r '" ,-, t'rï' ~ i î.; /1_'i~_"t ¡ ,. c..... ",-+ # ~~"b.\\\~ REMARKS: 1. ALL DEPTH~E BIT DEPTHS UNLESS OTHERWISE~ED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9746' MD AND THE BOTTOM WAS AT 9762' MD. THE WHIPSTOCK WAS POSITIONED DURING MWD RUN 1. UPHOLE TIE-IN DATA ARE MERGED WITH RUN 2 DATA - NO INDIVIDUAL RUN DATA ARE PRESENTED FOR RUN 1. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 5. MWD RUNS 3 & 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK SHIFTED UPWARD 8 FEET, PER E-MAIL FROM K. COONEY, BP EXPLORATION (ALASKA), INC., DATED 2/9/04. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 4 REPRESENT WELL 50-029-21782-03. THIS WELL ~~EACH\D A TOTAL DEPTH (TD) OF 7-29C WITH API#: 13020'MD/8940'TVD. -- ./ SROP SMO<:YrHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/11 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 1 and clipped curves; all bit runs merged. .5000 START DEPTH STOP DEPTH GR 9580.. 12969.0 . FET 9725.0 10469.0 RPD 9725.0 10469.0 RPM 9725.0 10469.0 RPS 9725.0 10469.0 RPX 9725.0 10469.0 ROP 9770.5 13012.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9580.5 13012.0 $ GR 9588.5 13020.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 2 3 4 MERGE TOP 9588.5 10522.0 11862.0 MERGE BASE 10522.0 11862.0 13020.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type...... ............0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value............ ......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9580.5 13012 11296.3 6864 9580.5 13012 ROP MWD FT/H 0.4 268.94 94.0682 6484 9770.5 13012 GR MWD API 13.72 477.65 76.93 6778 9580.5 12969 RPX MWD OHMM 0.64 1682.94 4.69022 1489 9725 10469 RPS MWD OHMM 0.57 1726.58 4.87783 1489 9725 10469 RPM MWD OHMM 0.54 2000 12.2302 1489 9725 10469 RPD MWD OHMM 0.56 2000 38.6048 1489 9725 10469 FET MWD HOUR 0.33 26.97 2.25707 1489 9725 10469 First Reading For Entire File........ ..9580.5 Last Reading For Entire File......... ..13012 File Trailer Service name........... .~LIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/11 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name... ......... .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/02/11 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 FET RPD RPM RPS RPX ROP $ 2 ~ header data for each bit run in separate files. 2 .5000 START DEPTH 9588.5 9733.0 9733.0 9733.0 9733.0 9733.0 9778.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 10485.0 10477.0 10477.0 10477.0 10477.0 10477.0 10522.0 25-DEC-03 Insite 66.37 Memory 10522.0 9778.0 10522.0 41.3 43.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 149206 134758 # 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): 8.500 9547.0 LSND 10.80 51. 0 MUD PH: . MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 9.5 . 1200 3.5 2.200 74.0 1. 370 123.0 1. 500 74.0 1. 000 74.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.. ........ .Feet Data Reference Point...... ....... .Undefined Frame Spacing..... ........ ....... .60 .1IN Max frames per record............ .Undefined Absent value............. ........ .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9588.5 10522 10055.3 1868 9588.5 10522 ROP MWD020 FT/H 4.9 235.41 116.903 1488 9778.5 10522 GR MWD020 API 46.81 381.07 135.709 1794 9588.5 10485 RPX MWD020 OHMM 0.64 1682.94 4.69022 1489 9733 10477 RPS MWD020 OHMM 0.57 1726.58 4.87783 1489 9733 10477 RPM MWD020 OHMM 0.54 2000 12.2302 1489 9733 10477 RPD MWD020 OHMM 0.56 2000 38.6048 1489 9733 10477 FET MWD020 HOUR 0.33 26.97 2.25707 1489 9733 10477 First Reading For Entire File........ ..9588.5 Last Reading For Entire File......... ..10522 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .04/02/11 Maximum Physical Record. .65535 File Type. .......... .....LO Next File Name......... ..STSLIB.003 . Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/11 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. 3 .5000 START DEPTH 10485.5 10522.5 STOP DEPTH 11813.5 11862.0 # 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 GM $ BOTTOM) TOOL TYPE Dual GR # 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): 29-DEC-03 Insite 4.3 Memory 11862.0 10522.0 11862.0 40.4 94.7 TOOL NUMBER 82758 6.000 10522.0 Flo-pro 8.40 54.0 8.3 2250 6.1 .000 .000 .000 .000 .0 120.0 .0 .0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): . . # # REMARKS: $ # Data Format Specification Record Data Record Type......... ....... ..0 Data Specification Block Type... ..0 Logging Direction........ ..... ....Down Optical log depth units.. ....... ..Feet Data Reference Point..... ....... ..Undefined Frame Spacing............. ...... ..60 .1IN 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 Rep 68 68 68 Name DEPT ROP GR MWD030 MWD030 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10485.5 11862 11173.8 2754 10485.5 11862 ROP MWD030 FT/H 2.9 223.55 59.4582 2680 10522.5 11862 GR MWD030 API 13.72 477.65 57.8464 2657 10485.5 11813.5 First Reading For Entire File......... .10485.5 Last Reading For Entire File.......... .11862 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/11 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name......... ..STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/11 Maximum Physical Record. .65535 File Type...... ...... ... .LO Previous File Name... ... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 4 header data for each bit run in separate files. 4 .5000 VENDOR TOOL CODE GR ROP $ START .H 11814.0 11862.5 STOP DEPTH 12977.0 13020.0 # 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 GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record......... ....Undefined Absent value.... .............. ....-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units FT FT/H API Nsam Rep 1 68 1 68 1 68 Code Size 4 4 4 . 31-DEC-03 Insite 4.3 Memory 13020.0 11862.0 13020.0 88.0 93.5 TOOL NUMBER 69706 6.000 10522.0 FLO-PRO 8.60 45.0 9.4 1500 7.0 .000 .000 .000 .000 .0 130.8 .0 .0 Offset o 4 8 Channel 1 2 3 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11814 13020 12417 2413 11814 13020 ROP MWD040 FT/H 0.4 268.94 119.446 2316 11862.5 13020 GR MWD040 API 27.16 163.09 53.4043 2327 11814 12977 First Reading For Entire File....... ...11814 Last Reading For Entire File....... ....13020 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/02/11 Maximum Physical Record. .65535 File Type........... .... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/02/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.......... ..... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments.. .............. .STS LIS writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/02/11 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