The URL can be used to link to this page

Home My WebLink About203-020 ) ) 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. cQ Q3 - D:}..O Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 ~E CAN '\ . Color Items: Greyscale Items: DIG~L DATA ~iskettes No. D Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: BY: e o Other:: Date: I~ ~ 6,~ /s/ VV\~ 111111111111111 m{J Project Proofing BY: ~aria ) Scanning Preparation BY: ~ \ Date: l.~ q ð,~ I X 30 T ~O Date: 1;)- c¡j 05 /s/ +::t3 = TOTAL PAGES '" ~'-~ (Count does not include cover shee~l1j) ...:.!J /s/ V r t Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) r.Pag~ Count Matches Number in Scannin9 pr7para~n: l/ YES BY e Date: (d-- '6. OS Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 1111111111111111111 NO /5/ VV1 D NO BY: Maria Date: /s/ IIII1I IIIII Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked 1III111111111111111 10/6/2005 Well History File Cover Page.doc -~~/- • STATE OF ALASKA ~0~0-08' ALASKA OIL AND GAS CONSERVATION COMMISSION i V V CJC_j ~ 4 2oa$ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,,°,~ ~~ns. Commission 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended 20AAC 25.105 zoAAC zs.11o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class:` ®Development - ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska} Inc.. 5. Date Comp,, Susp., or Aband. 9/17/2008 ~ 12. Permit to Drill Number 203-020 - 308-246 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/3/2003 13. API Number 50-029-21788-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/6/2003 14. Well Name and Number: PBU 07-30A 570 FNL, 302 FEL, SEC. 33, T11 N, R14E, UM Top of Productive Horizon: 3232' FSL, 3323' FEL, SEC. 28, T11 N, R14E, UM 8. KB (ft above MSL): 65'- Ground (ft MSL): 24' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3542' FSL, 4333' FEL, SEC. 28, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 11868' - 9008' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 675883. y- 5950348 Zone- ASP4 10. Total Depth (MD+TVD) 11902' - 9008' ' 16. Property Designation: ADL 028309 - TPI: x- 672766 y- 5954079 Zone- ASP4 Total Depth: x- 671749 y- 5954365 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ^ Yes ®No i t r i n rin inf rma i n r 20 AA 2 0 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): MWD, GR, MCNL, CCL 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 Surf 1 0' 28 P I 1 /" 7 - / - rf 4' -1 III ' - / " 47# L-8 urta 5' 8 3 ' 12- /4" 29 x I ' 7" 9# L-80 3' 32 ' 8 5' -1/2" 4 0 I ' 31/2"x33/16" x 2-7/8" 9.2# / 6.2# / 6.16# ' ' ' 3-3/4" x 4118" 1 7 I ' 23. Open to production or inject ion? ^ Yes ®No 24. TuawG RECORD If Yes, list each i (MD+TVD of Top 1£ Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2", 12.6#, 13Cr / L-80 9368' 9208' & 9273' MD TVD MD TVD {~ ` ~y ' 25. ACID, FRACTURE,.CEMENT SQUEEZE, ETC. t~i~¢q ~ ~~ ~}, q l ~r~1'i~i~ `~''....1 .~ ~s ~UUi~ DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 9873' Set Whipstock w/ Packer Assembl 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. Casing Press: CALCULATED 24-HOUR 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 •° y"°{{ t M - j Form 10-407 Revised 02/2007 t TINUED ON REVERSE SIDE y,y_~~ f ,~ /' s ~a i ~ C ~ ~~ rM ` Lj 2$. GEOLC3Z,IC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME 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. Top CGL 9730' 8693' None Base CGL 9848' 8780' 23S6 10393' 8843' 22TS 10511' 8893' 21TS 10590' 8939' Zone 1 B 10802' 9028' 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 foreg ing is true and correct to the best of my knowledge. 1b [/ ~~i Signed Terrie Hubble Title Drilling Technologist Date PBU 07-30A 203-020 308-246 Prepared By NameMumber. Te-rie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: Ron Phillips, 564-5913 INSTRUCTIONS GeNew-~: 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. IrerM ia: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). treM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IrerM 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). IreM 27: Provide a listing of intervals cored and the corzesponding 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 25.07E Form 10-407 Revised 02/2007 Submit Original Only • • 07-30A, Well History (Pre Rig Sidetrack) Date Summary 7/24/2008 WELL SI ON ARRIVAL. MADE 4 RUNS W/ 15' 2 5/8" STEM & S-BAILER FROM 9850 ' TO 9900' SLM. RAN 5' 2 5/8" STEM. MADE TARGET DEPTH OF 9950' SLM. RAN 10' 2 5/8" STEM. MADE 9948' SLM. RIG-DOWN, DECIDE TO RIG BACK UP TO TRY SOME DIFFERANT CONFIGS. RAN 3.25" CENT.TAG DEPLOY SLEEVE @ 9302' + 25' CORR.= 9327' MD. RAN 6' x 2.73" DMY WHIPSTOCK, 10' x 2 5/8" STEM TO 9,738' MD (9950' MD target). WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 9/4/2008 RIH with 2.625" dummy whipstock for drift. One slight bobble at 9735', clean all the way to 9980'. Ran thru 9735' twice. POOH. Freeze protect well w / 50/50 methanol to 2500' 38 bbls. RDMO. Job Complete. 9/14/2008 T/I/0= SSV/600/0. Temp= SI. Bleed fA & OAP to 0 psi (pre-CTD). AL, flowline & welihouse disconnected and removed. IA FL @ 144' (8 bbls). Bled IAP from 600 psi to 90 psi in 3 hours (fluid & gas). Ran out of time, night crew will continue. 2" integral installed on IA. Final WHPs =SSV/90/0. SV,WV,SSV,MV=C. IA,OA=OTG. 9/15/2008 T/I/0= 160/20/0 Temp= SI MIT-IA PASSED to 3000 psi, MIT-OA PASSED to 2000 psi, 3rd attempt. Load Tbg (pre CTD). Loaded Tbg w/ 5 bbls meth, 295 bbls SW, 30 bbls 60/40 meth for freeze protect. MIT-IA: Pressured up IA w/ 19 bbls crude. IA lost 80 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 120 psi in 30 min test. MIT-OA: pressured up OA w/ 5.5 bbls crude. OA lost 100 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 140 in 30 min test. Bled all pressures down to 0 psi. Final WHPs 0/0/0 IA/OA casing valves open to gauges, swab shut needle valve open to gauge at time of departure. 9/15/2008 T/I/O =SSV/120 /0. Temp = SI. Bleed IAP & OA to 0 psi (pre CTD). AL &flowline removed & blinded. Wellhouse removed. Integral on IA. WV & MV LOTO. IA FL @ 90'. Bled IAP, to BT, from 120 psi to 10 psi in 3 hrs. LRS arriving to MIT IA. Final WHPs =SSV/10/0. SV,SSV,WV,MV = C. IA, OA = OTG. NOVP. 9/16/2008 T/I/O =Vac/0/0 Pulled 4-1/16" ISA BPV # 511 , 4-5' ext. used, tag @ 60" thru stack for Nordic 1, no problems. 9/16/2008 T/I/0= Vac/0/0; Set 4-1/16" FMC ISA BPV #511 thru tree for Nordic 1 pre-rig; No ext. used, tagged @ 102". Complete. Page 1 of 1 a• BP EXPLORATION Page 1 of 9 Operations Summary Report Legal Well Name: 07-30 Common Well Name: 07-30 .Spud Date: 4/29/1988 Event Name: REENTER+COMPLETE Start: 9/16/2008 End: 9/25/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/25/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/16/2008 00:00 - 04:00 4.00 MOB P PRE Move rig from DS 6 to DS 7 04:00 - 06:00 2.00 MOB N WAIT PRE Waiting on BPV to be set. 06:00 - 07:00 1.00 MOB P PRE Back over well and set down. Accept rip at 07:00 hrs. 07:00 - 09:00 2.00 BOPSU P PRE NU BOP. 09:00 - 13:30 4.50 BOPSU P PRE Test BOP Test annular, blind /shears, 2" pipe /slip, 2-3/8" pipe /slip, lower 2" pipe /slip, HCR, kill line valves and stabbing valves. (witnessing of test waived by AOGCC representative Jeff Jones). 13:30 - 15:00 1.50 RIGU P PRE PJSM. Pull BPV, Well was dead. Service Injector Head. 15:00 - 17:30 2.50 WHIP P WEXIT Pumped E-Line slack management. PT inner reel valve, Cut 75' coil. M/U 2" Kendal coil connector. Pull test CTC with 35K. 17:30 - 19:30 2.00 WHIP P WEXIT M/U CoilTrak UOC. Test E-Line. MU whipstock running BHA #1 19:30 - 20:30 1.00 WHIP N WEXIT Wait on RA tags for WS 20:30 - 21:00 0.50 WHIP P WEXIT Install 2 RA tags in whipstock (5.3' from TOWS) PU Whipstock and WS setting BHA #1 21:00 - 23:00 2.00 WHIP P WEXIT RIH with BHA #1 CTC, UOC, LOC, Wear sub, P&C, EDC, DPS, DGS, HOT, Baker#10J Setting Tool, setting sleeve, BOT monobore WS 23:00 - 00:00 1.00 WHIP P WEXIT Log GR Tie-in, log down at 250 ft/hr down to WS setting depth 9/17/2008 00:00 - 00:15 0.25 WHIP P WEXIT Continue logging down to WS setting depth 00:15 - 00:30 0.25 WHIP P WEXIT RIH to 9890 ft Orient to 90L deg. Close EDC. Pressure up slowly, at 0.3 bpm. Ball seat shears at 3,840 psi, with 5 Klbs down on whipstock. Whi stock is set at 90L orientation, with top of whipstock (to window at 9,875 ft. 00:30 - 02:30 2.00 WHIP P WEXIT Swap wellbore to 2 ppb Biozan and POOH 02:30 - 02:45 0.25 WHIP P WEXIT PJSM for LD WS setting BHA Discuss procedure and risks 02:45 - 03:30 0.75 WHIP P WEXIT LD WS settin BHA and PU window milling BHA C.` , " 03:30 - 05:30 2.00 STWHIP P WEXIT RIH with milling BHA, UOC, LQC, Wear sub, P&C, EDC, DPS, c~'k!r! C DGS, Blind Sub, XO, BOT Xtreme, Diamond string mill and ~~.'~gj 2.74" diamond speed mill 05:30 - 07:30 2.00 STWHIP P WEXIT Tag WS ~ 9875.5', Circulate at 1.5 bpm tag with pump on ~ 9875, flag pipe at TOWS 06:00 15 bpm Q 2500 psi FS, 2600 psi. WOB 0.8K ECD 9.14. Milled to 9876'. 07:30 - 10:00 2.50 STWHIP P WEXIT Mill 2.74" window thru 3-3/16" liner. 1.5 bpm, 2500-3300 psi, 1-2K WOB, 1 fph, Milled to 9879'. 10:00 - 11:45 i.75 STWHIP P WEXIT Mill 2.74" window thru 3-3/16" liner. 1.5 bpm, 2500-3300 psi, 1-2K WOB, 1 fph, Exit liner at 9880'. Mill 1 ft at 1 fph to ream window. Top of window at 9875'. Bottom of window at 9880'. Milled to 9881'. 11:45 - 12:50 1.08 STWHIP P WEXIT Mill 10' of formation, 1.5 bpm, 2800-3200 psi, 1-2K wob, 8 fph. Milled to 9890'. 12:50 - 13:30 0.67 STWHIP P WEXIT Ream window area while swapping well to reconditioned FloPro. rnrnea: m~ui~wa i i:oo.cc nrvi IELLHEAD - FMC S NOTES: ***CHROME 4-1 /2" TBG'`** NOTE: CTUATOR =' AXELSON DRLG D~FT 0 ~ ~~ O ~ *D BELOW OVERSHOT (9243') ARE B. ELEV = 65' CORRtCTED TO TT 07/28/03 F. ELEV - OP = 1400' lax Angle = 95 @ 10954' " alum MD = 9925' 13-318 CSG, 68#, alum TV D = 8800' SS K-55, ID =12.415" 98' 13-3/8" CSG, 72#, L-80, ID = 12.347" H 3179' Minimum ID =1.92" @ 9306' 2-7/8" x 2-3/8" STL PIN, XO 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" TOP OF 7" LNR ~~ 9303' 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.992" ~~ 9348' -1/2" TBG-PC, 12.6#, L-80..0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-j 9545• MILLOUT WINDOW 9674' - 9680' RA TAG 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ 10340' 9873' Mech Whipstock, RA @ 9878 Ft PERFORATION SUMMARY REF LOG: SLB MCNL (9/23/08) ANGLE AT TOP PERF: 95 @ 10470' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 6 10470-10770 O 09/25/08 1.56" 6 10960 - 11420 O 09/25/08 10588' ~ 3-3/16 X 2-7/8" X ID = 2.377" 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" I--~ 10588' r 'C1~ 2-7/8" CIBP SET (08/07/05) 10710' PBTD 11868' 2-7/8" LNR, 6.16#, L-80, .0055 bpf, ID = 2.377" 11901' TD 11902' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/22/88 ORIGINAL COMPLETION 08/10/03 TGITCH CTD SIDETRACK (07-30A) 05/31/06 JNA/PAG CIBP SET @ 10710' (08/07/05) 09/01/07 LLUSV PERF (08/29/07) 09/25/08 NORDICI CTD SIDETRACK (07-308) 09/28/08 TLH CORRECTIONS 2169' -I4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS iT MD TVD DEV TYPE VLV LATCH PORT DAT 3 3406 3179 31 MMG-9CR DMY RK 0 07/16/ Z 6576 5922 30 MMG-9CR DMY RK 0 07/16/ 1 9116 8156 28 MMG-9CR DMY RK 0 08116/ g187' - 4-1/2" HES X NIP, ID = 3.813" -9200' -EST TOP OF CEMENT (05!10/07) 9208' 9-5/8" X 4-1/2" BAKER CR PKR, ID = 3.875" 9232' - 4-1/2" HES X NIP, ID = 3.813" 9243' UNIQUE OVERSHOT, ID = 3.958" 9269' * 9-5/8" X 4-1/2" BAKER DB PKR, ID = 4.75" 8273' * 4-1/2" BAKER SBE, ID = 4.75" 9299' ~ BKR DEPLOYMENT SLV, ID = 3.0" 9327' 4" BKR DEPLOY SLV, ID = 3.00" 9337' 3-1 /2" HES X NIP, ID = 2.813" g34$' 3-1/2" X 3-3/16" XO, ID = 2.80" 9385' ~--I TOC 3-3/16" (SCMT 6/08) 2-3/8",4.7#, L-80 STL LINER ID=1.995" 1151! ---_ _r-~ r~ __.r-~ .:_ r-~._ ---- PRUDHOE BAY UNff WELL: 07-308 PERMfT No: # API No: 50-029-21786-0;- SEC 33, T11 N, R14E, 2685.01' FEL & 2325.58' FN BP Exploration (Alaska) • a p U u ~ ~ F 4eS ~~ ./ ~--t p pp s +.,~,~, '~ i...4 +1.,,7 L.i d..~ i.~ t,~ ~. *...:~ L.1 .k (-iW,,~ ..:. 't~.a L ~"..~, ALASSA OIL AI~TD GA5 CO1~T5ER`TA7`IOAT COMI~II5SIOI~T Ron Phillips CT Drilling Engineer BP Exploration Alaska Inc. ~~~ JIJL ~ ~ ~~~$ PO Box 196612 Anchorage, AK 99519-6612 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-30A Sundry Number: 308-246 ~~3- Q a~,~ Dear Mr. Phillips: 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 Corrunission'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 ~'Sday of July, 2008 Encl. ~`' ,' ~,/- ~ l ~~ STATE OF ALASKA ~/~~` ~ Q ~ ~ ~ ~~'~ ~~ ,a- ~~ h~ jkf ~ ALA OIL AND GAS CONSERVATION COM ION ~ ,)~~_ ~ ® L APPLICATION FOR SUNDRY APPROVAL ~ ~ 20 AAC 25.280 Al~~ka ~~ ~ ~'~,~ ~'~';?~. (;Og~r~5~i0n 1. Type of Request: ®Abandon , ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Exten n"' _: ~' ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ ®Development ^ Exploratory 203-020- 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21786-01-00" 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 07-30A. Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ ADL 028309 ° 65' ~ Prudhoe Bay Field / Prudhoe Bay 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): 11902' ~ 9008' - 11868' ~ 9008' - 10710' None Casin Len th Size MD TVD Burst Colla 'se Structural Conduct r 110' 20" 110' 110' 1490 470 Surface 3179' 13-3/8" 3179' 2984' 3450 1950 Intermediate 9545' 9-5/8" 9545' 8532' 6870 476 Producti n Liner 371' 7" 9303' - 9674' 8320' - 8645' 8160 7020 Liner 2575' 3-1/2" x 3-3/16" x 2-7/8" 9327' - 11902' 8341' - 9008' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Above Pluq: 10030' - 10380' 8842' - 8840' 4-1l2", 12.6# 13Cr / L-80 9368' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'CR' packer; Packers and SSSV MD (ft): 9208'; 9-5/8" x 4-1/2" Baker'DB' packer 9269' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: August 1, 2008 ^ 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 Ron Phillips, 564-5913 Printed Name Ron Phillips Title CT Drilling Engineer Prepared By Name/Number: Signature Z~.r., ~ , 'SNP 1 Mpg Phone 564-5913 Date Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness \ ~ ~\` ~~ ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ''~ ~ ~T ~~v~~ ( ( S\KG..~C~1~1-©~ ~p~ Other: ~ ~ V~ e S ` ~~ ~ --~ c~"~ Subsequent Form Required: `~ APPROVED BY A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revise 06/2006 Submit In Duplicate ~: JUG ~ ~ ZDDB ~~IGl~l~l~ • • ` To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission ~.J From: Ron Phillips ~J CTD Engineer Date: June 26, 2008 Re: Prep 07-30A for CTD sidetrack Sundry approval is requested to abandon perforations in the 07-30A well in preparation for a sidetrack. The 07-30A was an August 2003 coil plus sidetrack. A window was milled in Z4 and a short horizontal section was drilled. After penetrating Zone 2C, the well dove back down and ended with a 1000' horizontal section in the primary Z1B target where 595' of the horizontal section was perforated yielding a first test of 2200 BOPD at 13000 GOR and a second test of 1300 BOPD at 19000 GOR. A borax log was ran in 2004, which clearly indicated no channels and all of the perfs took borax. Due to the high initial gas rates, 07-30A went to cycle within a year of initial production. A CIBP was set at 10710' MD in August 2005 for GSO and 25' of the Z2C lens was finally added. The well was POP'd for a short period of time, however the GOR was still above marginal and the well was SI. After nearly a year of healing, the well was POP'd again in June 2006 with some difficulty due to ice bridges with disappointing results. The well had not experienced any healing and the GOR was 60000. It was again SI for high GOR. The disappointing 2C adperfs were strangely similar to that of the 1B horizontal, however an August 2007 STP confirmed the CIBP was holding and we were not seeing communication across the plug. Additional 2C perfs were also added at that time in the saddle of the "S" hoping to tap into some better quality rock, however the well proved to be uncompetitive post-POP and was SI shortly thereafter. A SBHP performed on 3/3/08 couldn't reach -8800 TVDSS, but a calculation indicates 3272 psi. The CTD screening MIT-IA to 2500 psi passed, aMIT-OA to 2000 psi passed, and a PPPOT-T passed; the LDS were not functioned but in good visual condition. A PPPOT-IC cannot be perfromed as it has sealtite. A SCMT log was run in May 2008 to evaluate the cement top behind the 3-3/16" liner. The log determined the cement top was at 9385' which is 65' above the TSGR; therefore, a "tiny tool" coil sidetrack is the ~ption for this well. ~5}- The 07-30A well has been selected for a through tubing sidetrack due to the high GOR. The Nordic 1 Coiled Tubing Drilling rig is scheduled to move over the well around October 15, 2008. The sidetrack, 07-30B, will exit the existing 4-1/2" liner from a whipstock and will target the Ivishak Zone 2A reservoir. The existing perforations will be isolated by a fasdrill plug. The following describes work planned and is submitted as an attachment to Form 10- 403. Aschematic diagram of the proposed sidetrack is attached for reference. Pre-Rig Work: 1. Dummy off all GLM's. 2. Drift with Dummy WS 2.625" x 17' to 9950'. ~` S ~ ~~~\ 3. AC-LDS; AC-PPPOT- T. Q SZ 4. PT tree (MV, SV, WV). 5. Load and kill the well just before setting the plug (7.12ppg EMW). 6. Seta 3-1/2" fasdrill plug in 3-3/16" at 9900'_ and set Baker whipstock at 9870'. 7. Mill window low side. 8. Set BPV (if window is milled). 9. Bleed gas lift and production flowlines down to zero and blind flange. 10. Remove wellhouse, level pad. The pre CTD work is slated to begin on August O1, 2008. Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Pull BPV. 3. Swap the well to Flo-Pro. 4. Drill Build: 3" OH, 779' (30 deg/100 planned). Dir/Gr/Res. 5. Drill Lateral: 3" OH, 886' horizontal (12 deg/100 planned) -crossing one fault. 6. Run & cement 2-3/8" liner leaving TOL at 9300' & TOC at 9800' (left low for future cut and pull). 7. Test liner lap to 2000 psi. 8. Cleanout run to bottom with ~ and mill. • 9. Run MCNL/GR/CCL log. 10. Perforate 800' overbalanced 1-11/16" 2006 PJ HMX 6 SPF 60 deg. 11. Run liner top packer. 12. Circulate well to KWF brine. 13. Pressure test tree cap to 3500 psi. 14. Freeze protect well, Set BPV, RDMO. Post-Rig Work 1. Pull BPV 2. Re-install well house. Hook up flow line. 3. Run gas lift design. 4. RU test separator, flow test well. (800' of Zone 2 perforations) Ron Phillips CTD Drilling Engineer 564-5913 CC: Well File Sondra Stewman/Terrie Hubble TREE = FMC GEN 4 WELLHEAD`= FMC ACTUATOR = AXELSON KB. ELEV = 65' BF. ELEV = KOP = 1400' Max Angle = 99 @ 10976' Datum MD = 9925' Datum ND = 8800' SS S TES: ***CHROME4-1/2" TBG"** NOTE: O 7 ~3 oA *DEP .. rS BELOW OVERSHOT (9243') ARE CORRECT®TO TT 07/28103 13-3/8" CSG, 68#, 98' K-55, ID =12.415" 2169' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" H 3179' Minimum ID = 2.377" @ 10588' 3-3/16" x 2-718" XO 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" 9243' ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3406 3179 31 MMG-9CR DMY RK 0 07/16!06 2 6576 5922 30 MMG-9CR DMY RK 0 07/16/06 1 9116 8156 28 MMG-9CR DMY RK 0 08/16/03 9187' ~ 4-1/2" HES X NIP, ID = 3.813" -9200' EST TOP OF CEMENT (05!10/07) 9208' 9-5l8" X 4-1/2" BAKER CR PKR, ID = 3.875" 9232' - 4-1/2" HES X NIP, ID = 3.813" 9243' UNgUE OVERSHOT, ID = 3.958" 9269' * I-19-5/8" X 4-1l2" BAKER DB PKR ID = 4.75" 9273' * 4-1l2" BAKER SBE, ID = 4.75" TOP OF 7" LNR ~-~ 9303' 3-1/2" LNR, 9.2#, L-80, .0087 bpf, ID = 2.992" ~-{ 9348' 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9368' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9545' RA TAG 9680' PBTD 10293' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10340' ~TD~ 10350' PERFORATION SUMMARY REF LOG: SLB MCNL (8!8/03) ANGLE AT TOP PERF: 83 @ 11355' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2 6 10030 - 10055 O 08/29/07 2" 6 10355 - 10380 O 08/06/05 2" 4 11000 - 11260 C 08/09/03 2" 4 11455 - 11670 C 08/09/03 2" 4 11740 - 11860 C 08!09103 9327' H 4" BKR DEPLOY SLV, ID = 3.00" 9337' 3-1/2" HES X NIP, ID = 2.813" 934$' 3-1/2" X 3-3/16" XO, ID = 2.80" 9356' ~4-1/2" OTIS XN NIP (MILLED OUT) (BEHIND 9367' 4-112" BAKER SHEAROUT SUB (BEHIND P 9368' 4-112" TUBING TAIL (BEHIND PIPE) MILLOUT WINDOW 9674' - 9680' 4' ~-jTNV LSL SUB 10588' 3-3/16 X 2-7/8" XO ID = 2.377" 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" ~--~ 10588' Y 2-7/8" CIBP SET (08/07/05) 10710' PBTD 11868' - 2-7/8" LNR, 6.16#, L-80, .0055 bpf, ~ = 2.377" 11901' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfT 06/22/88 ORIGINAL COMPLETION 08/05/06 JCM/PJC PULL TTP/ SET PX TTP WELL: 07-30A 08/10/03 TGlTLH CTD SIDETRACK (07-30A) 10/23/06 GMD/PAG GLV GO (07/16/06) PERMtT No: 82030200 08/16/03 JCM(fLH GLV GO 05/21/07 JRA/TLH PLUG PULLED/CMT SOZ (5/1010 7} API No: 50-029-21786-01 08/06/05 JNA/PJC PERF & SET WFD CIBP 09/01/07 LLUSV PERF (08/29/07} SEC 33, T11 N, R14E, 2685.01' FEL 8 2325.58' FNL 05/31/06 JNA/PAG CIBP SET @ 10710' (08!07/05} 07/23/06 CJWPJC SET PX PLUG @ 9232' BP Exploration (Alaska) TREE = FMC GEN 4 WELLHEAD = FMC ACTUAT01~= AXELSON KB. ElEV = 65' BF.~EIEV = KOP = 1400' Max Angle = 99 @ 10976' Datum MD = 9925' Datum ND = 8800' SS 0 ~ ~~ O ~ SAFETY NOTES: *'*CHROME4-1/2" TBG'"* NOTE: DE BELOW OVERSHOT (9243') ARE Proposed CTD Sidetrack CORK 'TED TO TT 07/28/03 K-55, ID =12.415" 13-3/8" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.377" @ 10588' 3-3/16" x 2-7/8" XO 1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" 9243' TOP OF 7" LNR (~ 9303' I3-1/2" LNR 9.2#, L-80, .0087 bpf, ID = 2.992" ~ 9348' 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" 9368' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9$4$' MILLOUT WINDOW 9674' - 9680' RA TAG 968( 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ 10340' 9870' MII Window off Mech PERFORATION SUMMARY REF LOG: SLB MCNL (8/8/03) ANGLE AT TOP PERF: 83 @ 11355' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2 6 10030 - 10055 O 08/29/07 2" 6 10355 - 10380 O 08/06/05 2" 4 11000 - 11260 C 08/09/03 2" 4 11455 - 11670 C 08/09/03 2" 4 11740 - 11860 C 08/09/03 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 3 3406 3179 31 MMG-9CR DMY RK 0 07/16/06 2 6576 5922 30 MMG-9CR DMY RK 0 07/16/06 1 9116 8156 28 MMG-9CR DMY RK 0 08/16/03 9187' ~-~ 4-1 /2" HES X NIP, ID = 3.813" ^9200' -EST TOP OF CEMENT (05/10/07) 9208' i~9-5/8" X 4-1/2" BAKER CR PKR, ID = 3.875" 9232' - 4-1/2" HES X NIP, ID = 3.813" 9243' UNIQUE OV ERSHOT, ID = 3.958" 9269' "' 9-5/8" X 4-1/2" BAKER DB PKR, ID = 4.75" 9273' " 4-1/2" BAKER SBE ID = 4.75" 9310, ~~ BKR CTLRT DEPLOY SLV, ID = 3.0" 9327' 4" BKR DEPLOY SLV, ID = 3.00" 9337' 3-1/2" HES X NIP, ID = 2.813" 9348' 3-1 /2" X 3-3/16" XO, ID = 2.80" 9385' ~ TOC 3-3/16" (SCMT 6/08) )$00? TOC 2-3/8" (PLANNED) 2-3/8",4.7#, L-80 STL LINER ID=1.995" PBTD --L 11 2-7/8" LNR, 6.16#, L-80, .0055 bpf, ID = 2.377" - 11625' 1 D3/ 2.377" 7/8" XO I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfr 06/22/88 ORIGINAL COMPLETION 08/05/06 JCM/PJC PULL TTP/ SET PX TTP WELL: 07-30B 08/10/03 TG/TLH CTD SIDETRACK (07-30A) 10/23/06 GMD/PAG GLV GO (07/16/06) PERMfr No: 08/16/03 JCM/TLH GLV GO 05/21/07 JRA/TLH PLUG PULLED/CMT SQZ (5/10/0 7) API No: 50-029-21786-02 08/06/05 JNA/PJC PERF 8~ SET WFD CIBP 09/01 /07 LLVSV PERF (08/29/07) SEC 33, T11 N, R14E, 2685.01' FEL & 2325.58' FNL 05/31/06 JNA/PAG CIBP SET @ 10710' (08/07/05) 06/05/08 MSE PROPOSED CTD ST 07/23/06 CJWPJC SET PX PLUG @ 9232' BP r~cploration (Alaska) 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" ~-~ 2-7/8" CIBP SET (08/07/05) -{- 05/30/08 >IiO~~~11G1-~r1- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh # N0.4727 q~~ ~~*t ~ ~ ~(tQ~ Company: State of Alaska 'r~i~~tl~~~ '~t U Alaska Oil & Gas Cons Comm ~~'.tw Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 nn necnriniinn n..~.. DI n_I_- Z-03 11975773 SFRT f- (~ 05/20/08 1 P2-32 12066522 MEM TEM SURVEY - 05/19/08 1 1 18-13B 12021159 MEM PROD PROFILE '~- ~ ~ 05/18/08 1 1 Z-03 11975773 USIT ~ ~(~ 05/19/08 1 1 W-29 11999017 INJECTION PROFILE (,( 05/26/08 1 1 15-39A 11999018 PRODUCTION PROFILE - c. 05/28/08 1 1 07-30A 11963095 SCMT - ~ 05/27/08 1 1 14-09B 11982432 PROD PROFILE W/FSI - ~, v 05/27/08 1 1 A-34A 12057614 USIT - 0 '~ /(pG/D~- 05/26/08 1 1 GNI-04 11824353 OH LDWG EDIT (DSI) _ I L 11/07/07 1 1 . ~~.....-.-......... ..rr.. -.,~ „rv~.r . v. v~ba.~„~V.I1~~V nGI Vn1Y11YW VIYG \rVr7 GNl.fl I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. `' Anchorage, Alaska 99508 Date Delivered: `~ "~ ,"f_~~i~ a Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-2 38 / ATTN: Beth ~~ // Received by: C7 • Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, September 24, 2007 3:45 PM To: 'Preble, Gary 8 (SAtC)' Subject: DS 07-30A (203-020} ~ ~~c. '~o ~~'C~, ~ cs~~ls~ ~c.~~SS ~, ~~ t ~S~E 1 ~5~6 6~ ~~ ~ tc--~c,e-e~~~ ~~ t~C~v~ S .1~ ti-r:~ ~ e~'~ ~ ~~C~ ~c'"re ~CC~SI~,~ ~ ~~,~-~, ~.~„~+.~g~~_~~ Gary, This appeafs to be another well where the information does not ma#ch. I am unable to confirm when the perforations shown at 10355 -10380' were shot. It would appear tha# all the pertorations that existed in tfie well were isola#ed with the BP at 10710'. Thanks. Tom Maunder, PE AOGCC ;~ ;> ' ~r ~~~4 w'*` ` ~; ~ti,, ± j, ~t~t.~t.~ ~:;~'~ar~:~•~«cxc.;./ ~. 9/24/2007 . STATE OF ALASKA 9~~~ ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~+~~ ~~~L~ V ED ~~EP 0 7 2Q07 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ ._ ~'~ ~~~ ~nnr f',..,, Performed: Alter Casing ~ Pull Tubing~ Pertorate New Pool ~ Waiver~ Time Extension~ ~~~ d~flC~It3i'cryt~f' 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: rvame: Dev~elopment ~ Exploratory ~~ 2os-o2oo ~ 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21786-01-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 65 KB " PBU 07-30A ~ 8. Property Designation: 10. Field/Pool(s): _ ADLO-028309 . PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11902 - feet Plugs (measured) 10710 true vertical 9007.94 feet Junk (measured) None Effective Depth measured 11868 - feet true vertical 9007.89 - feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 3150 13-3/8" 72# L-80 29 - 3179 29 - 2983.89 4930 2670 Liner 21 3-1/2" 92# 13Cr80 9327 - 9348 8341.45 - 8359.86 10160 10530 Production 9517 9-5/8" 47# L-80 28 - 9545 28 - 8532.02 6870 4760 Liner 371 7" 29# L-80 9303 - 9674 8320.4 - 8644.54 8160 7020 Liner 1240 3-3/16" 6.2# L-80 9348 - 10588 8359.86 - 8938.38 Liner 1314 2-7/8" 6.16# L-80 10588 - 11902 8938 - 9007 13450 13890 Perforation depth: Measured depth: 10030' - 10055' 10355' - 10380' _ True Vertical depth: 8842' - 8841' 8836' - 8840' _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13cr 26 - 9243 4-1/2" 12.6# L-80 9273 - 9368 Packers and SSSV (type and measured depth) Baker S-3 Packer 9208 9-5/8" DV Packer 9269 0 0 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: 0 0 0 0 0 Subsequent to operation: 250 30331 4 0 1559 14. Attachments: 15. Well Class after ~roposed work~ Copies of Logs and Surveys Run Exploratory ~ Development ~' S@fvlC@ ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~' GINJ ~' WINJ 1 ~NDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/ if C.O. Exempt: ~ ~ Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/5/2007 ~. ISS101 rorm iu-4u4 rcevisea u4iru~ [~ t ( ~ ~ ~`~ ~ ~ :> n_a••~~5.~- _-_ : , ,.". " ` ~C~.~ ~ auo ~ i ai niy }~ t! l, y i ~`4 ,~_. (b'~ ~ ~ ~ 07-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/28/2007!;CTU #8, PPROF ! Add Perf; MIRU unit. Well flowing on arrival. Pad test ;;separator down; unable to put well in test. Ensure well is flow and normal WHP ' and choke setting. MU and RIH with 2.3" OD JSN. Tag CIBP at 10681' ctmd. POOH. MU and RIH with SLB STP. Log dynamic up%down~passes over interval ' 9250-10650' ctmd at 40,60,80 fpm. Perform stop counts at 9250', 10250', ' 10,500' and 10,650'. SI well and let it stack out. Log up/down pass for residual i cooling at 60 fpm. Paint flag at 9900' ctmd. POOH. ... Cont' on WSR 08/29/07 8/29/2007; CTU #8, PPROF / Add Perf; ... Cont' from WSR 08/28/07 ... Cont' POOH. LD ''. ;''.logging tools. Confirmed good logging data. Stop counts above CIBP confirm ~I q is holdinq MU and RIH with 25' of 2.0" PJ2006 Omega HMX 6 spf. Correct '' ; depth at flag. Perforate interval 10030'-10055' elmd. POOH. At surface; confirmed all shots have fired. Freeze protect well with 35 bbls 50/50 meth. Turn ? 'well over to DSO. *** Job Complete "`* FLUIDS PUMPED BBLS 53 50/50 MERTH 88 1% KCL with 0.6% SAFELUBE 141 TOTAL • -.,„._ ~~-~` MICROFILMED 03/01 /2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc 09/28/07 ~~11f~~~~~~~~ N0.4440 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 ,-~~~ NCV 4 7 200 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~~" ~ Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well .Inh !! Inn nncr~Intinn n~fe c1 r..i,.. r•n 15-39A 11661174 MEMORY PROD PROFILE 09123/07 W-42 11745235 MEM SBHPS/TEMP 09/14/07 1 Z-07A NIA SBHP SURVEY 09/14/07 1 A-04 11594519 SBHP SURVEY a - 08/26107 1 Y-24 11630499 LDL 09!04!07 1 L5-28A 11855810 PRODUCTION PROFILE - ~ 08/31/07 1 X-33 11849931 SBHP SURVEY ~ - ~/L 08/31/07 1 E-14A 11686784 LDL -~ - 09/23/07 1 01-15A 11855509 DDL ~ -pl(b 09!22/07 1 D-21 11626119 PRODUCTION PROFILE ~a - ~ 09/11/07 1 K-07D 11745234 MEM PROD PROFILE C - 09/06107 1 11-32 11630498 PRODUCTION PROFILE i L _ 09103107 1 L-01 11745233 MEM LDL a (~ (- ~ 09/04/07 1 07-30A 11651168 MEM STP & CORRELATION - 08/28/07 1 Z-28 11630500 INJECTION PROFILE ZC 09105107 1 Z-16 N/A SBHPSIJEWELRY / a 09/13107 1 14-26 11676959 LDL -/J 09/09/07 1 04-02A 11630504 LDL ~ 09/11/07 1 14-37 11695075 LDL 09113107 1 3-351E-36 11630502 PRODUCTION PROFILE 09/09/07 1 r LCNAC NNn1YVYVLCUl7C RC\.Clr'1 LST All7N1 N(V HNU.KF.tUKMiNIyVNt IiUY~' tA(:H I V: ( ~`~ii ,~., 1i BP Exploration (Alaska) Inc. ~~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~=, ~ .r ~, ~~~1~ Date Delivered: ,r, Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-26 ATTN: Beth Received by: • • ·r......J¡¡J' ~ STATE OF ALASKA .s:~..t:J7 AL~ OIL AND GAS CONSERVATION COM'¡¡¡rn:;ffiN2 1 1007 It REPORT OF SUNDRY WELL OPlIiRAiillJWlIins r. .".. . '71)-"2- . ·omm~lOa.. Stimulate DAnchoraae Other L:J çement Squeeze Waiver D Time"Ëxtension D Re-enter Suspended Well 0 5. Permit to Drill Number: 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 65 KB < 8. Property Designation: ADLO-028309 ' 11. Present Well Condition Summary: Total Depth measured 11902 < true vertical 9007.94 . Effective Depth measured 11868 true vertical 9007.89 - Casing Conductor Surface Liner Production Liner Liner Length 80 3150 21 9517 371 1240 Size 20" 91.5# H-40 13-3/8" 72# L-80 3-1/2" 9.2# 13Cr80 9-5/8" 47# L-80 7" 29# L -80 3-3/16" 6.2# L-80 Perforation depth: Measured depth: 10355 - 11740 True Vertical depth: 8836 - 8942 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. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations shut-in shut-in x Contact Gary Preble Printed Name G~ry pr~ // ¿ Þ Slgnatur~~~~~ Form 10-404 Re . ed 04/2006 ( 1 r 1 , r· , f\ 1/\ '. K 1"'1\1"- t=l Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Class: Development ~ Stratigraphic feet feet feet feet MD 30 - 110 29 - 3179 9327 - 9348 28 - 9545 9303 - 9674 9348 - 10588 - - 4-1/2" 12.6# 4-1/2" 12.6# Baker S-3 Packer 9-5/8" DV Packer o o Exploratory Service 9. Well Name and Number: 203-0200 - 6. API Number: 50-029-21786-01-00 PBU 07-30A "' 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool' Plugs (measured) Junk (measured) TVD 30 - 110 29 - 2983.89 8341.45 - 8359.86 28 - 8532.02 8320.4 - 8644.54 8359.86 - 8938.38 - 13Cr80 L-80 ~F.P MAY, 2' 2 2007 Title Data Management Engineer 10710 None Burst 1490 4930 10160 6870 8160 Collapse 470 2670 10530 4760 7020 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 .'_ 0 000 15. Well Class after Droposed work: Exploratory Development ~ 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. 26 - 9250 9250 - 9368 9208 9269 o o Tubing pressure o o Service GINJ WINJ WDSPL Sundry Number or N/A if C.O. Exempt: 307 -077 Phone 564-4944 Date 5/16/2007 W'~GDMS Rr:l I!"\ ., -- MA Y 2 2 îOD7 Submit Original Only \,--~/ 07 -30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY BBLS 380 5 385 5/8/2007 CTU #8, Sand Plug/Pkr Squeeze; MU and RIH with 2.75" BDN. Tag sluggits at 9306 ctmd. Correct depth to 9315' bkb (depth based on volume of sluggits and ccl from log). Fluid pack well and establish injectivity up the IA and ensure 1:1 returns up the IA and tbg. Lay in 550 Ibs of 20/40 river sand at 4 ppg. Tag consistent top at 9272' bkb. Re-establish injectivity up the IA and ensure 1:1 returns up the IA and tbg. Lay in 5 bbls of 15.8 ppg unislurry up the tbg. Circulate 3.7 bbls up the IA. WHP increased 400 Ibs as we squeezed cement through overshot and pkr. Estimated TOC in IA is 9200' bkb. POOH maintaining constant IA and WHP. ... Job in Progress. - Co nt' on WSR 05/09/07 ...CTU #8; Sand Plug/Packer Squeeze.MU and RIH with 2.75" BDN.MU & Rlh with 3.80" Parabolic Diamond Speed Mill. ..~~~~~ºþ..ID.Pr.9.gr.~~~~~~~~~~~·Ç9.~~i~~~ºQYV§Rº§!ºª!º?:::::............ 5/9/2007· CTU #8; Mill Cement/FCO; ... Cont' from WSR 05/08/07... RIH and tag TOC at 9166' ctmd. Mill cement down to 9265' ctmd. Appears we are in sand. POOH. MU and RIH with 2.0" JSN. Tag at 9265' ctmd. Attempt to jet with XS KCL at 3.5 bpm. Would not jet. POOH. MU and RIH with BKR 3.8" OD diamond speed mill. Mill several feet and break through crust. Jet through sand with mill down to 9300' ctmd with 3 Biozan sweeps. Chase OOH at 80%.MU and RIH with 2.0" JSN. ***Job In Progress*** ....Continued On WSR 05/10/07...... 5/10/2007· CTU #8, FCO/ Pull TTP; ... Cont' from WSR 05/09/07... MU and RIH with 2.0" JSN. Clean out sand from 9307' ctmd down to 9330' ctmd pumping frequent Biozan sweeps. Observed good indication via coil pressure that nozzle was in fishing neck. POOH chasing sand at 80%. MU and RIH with 3.0" GS hydraulic spear. Swap well to diesel. Latch and pull plug (10K overpull). POOH. TTP recovered. Perform MIT -IA to 2500 psi (see below). Passed. *** Job Complete *** T/I/0=466/625/110. MIT-IA to 2500 psi. Passed. Pumped 5.4 bbls of 60/40 Meth down IA to reach 2500 psi test pressure. IA lost 97 psi in the first 15 min and 48 psi in the second 15 min for a total of 145 psi in 30 min. Tubing and OA unchanged. Final Pressures T/I/0=452/500/11 O. FLUIDS PUMPED 1 % KCL 60/40 Math TOTAL RECE\Vt:.lJ I STATE OF ALASKA _ ALA Oil AND GAS CONSERVATION COM~OrQ 8 2007 REPORT OF SUNDRY WELL OPERA I S o o o .. 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: F 65 KB 8. Property Designation: ADLO-028309 11. Present Well Condition Summary: Total Depth measured true vertical 11902 ( feet 9007.94, feet Effective Depth measured true vertical 11868 ' 9007.89 ' Casing Conductor Surface Liner Production Liner Liner Perforation depth: Size 20" 91.5# H-40 13-3/8" 72# L-80 3-1/2" 9.2# 13Cr80 9-5/8" 47# L-80 7" 29# L -80 3-3/16" 6.2# L-80 Length 80 3150 21 9517 371 1240 Measured depth: 10355 -11740 True Vertical depth: 8836 - 8942 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 shut-in shut-in x ~ ~~ ~., Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic sian a. Other 0 bridge plug Waiver DAnCI¥l~~xtension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 203-0200 ./ Exploratory Service 9. Well Name and Number: 6. API Number: 50-029-21786-01-00 ./ PBU 07-30A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after oroposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas r WAG .. '..y Plugs (measured) Junk (measured) feet feetSCANNI:D MAY 1 4 2007 MD 30 - 110 29 - 3179 9327 - 9348 28 - 9545 9303 - 9674 9348 - 10588 TVD 30 - 110 29 - 2983.89 8341.45 - 8359.86 28 - 8532.02 8320.4 - 8644.54 8359.86 - 8938.38 - - - 4-1/2" 12.6# 13Cr80 4-1/2" 12.6# L-80 9-5/8"x4-1/2" Baker CR Packer 9-5/8"x4-1/2" Baker DB Packer o o 10710 None Burst 1490 4930 10160 6870 8160 Collapse 470 2670 10530 4760 7020 26 - 9250 9250 - 9368 9208 9269 o o Tubing pressure o o Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name Signature RBDMS 8Fl MAY 0 9 2007 WINJ WDSPl Title Data Management Engineer Phone 564-4944 ORIGINAL Date 5/7/2007 hh\ Submit Original Only '" . . 07-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 5/1/2007 ***WELL SHUT IN ARRIVAL*** PULLED PRONG@9314'SLM PULLED PXN PLUG BODY@9319'SLM *** JOB IN PROGRESS **CONTINUED ON WSR 5/2/07*** 5-1-07*** SET 3.5 XX PLUG @9316'SLM (T=360, IA=O, OA=O) 8.3/16 PORTS RAN CHECK SET CAME BACK SHEARED XX PLUG WITH TRI PLEX, 1900PSI HELD 30 MINS DUMP BAILED SLUGGITS 100 LBS ON TOP OF PLUG @9316'SLM *** LEFT WELL SHUT IN, TURNED WELL OVER TO OPERATOR*** **** JOB COMPLETE**** FLUIDS PUMPED BBLS 3.78 Gallons of slug-it 8 Diesel 8 Total . . SARAH PALIN, GOVERNOR AIfA~1iA. ORAND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Oliva Bommarito P.E. BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07 -30A Sundry Number: 307-077 ~Ùâ~OcW Dear Ms. Bommarito: f$(Gt~~NtÐ MAR {~ 2 2007 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, ~ DATED this L day of March, 2007 Encl. Abandon Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 1. Type of Request: Address: 0"13 31 I ~ 3,L.-VL-1 - L-L- . SfATEG ALASKA J-.'¡ FEB 2 8 2007 AL :A. OIL AND GAS CONSERVATION COMMI N/¥?\.\ APPLICATION FOR SUNDRY APPROVAlka Oil & Gas Cons. Coovnission 20 AAC 25.280 hora e Operational shutdown Waiver Other ./ Plug Perforations 0 Stimulate 0 Time Extension 0 Packer Squeeze Perforate New Pool 0 Re-enter Suspended Well 0 4. Current Well Class: 5. Permit to Drill Number: Developm ent 8 / Exploratory 0 203-0200 / Service 0 6. API Number: Suspend Repair well 0 Pull Tubing 0 Stratigraphic 0 Anchorage, AK 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: 11. Total Depth MD (It): 11902' Casing Conductor Surface Production Liner Liner Liner Liner Perforation Depth MD (It): 11455 - 11670 11740 - 11860 Packers and SSSV Type: 8. Well Name and Number: 50-029-21786-01-00/ No 0 PBU 07-30A / 10. KB Elevation (It): 11. Field/Pools(s): 65 KB I PRUDHOE BAY FIELD/PRODHOE OIL POOL / PRESENT WELL CONDITION SUMMARY ADL-028309 I Plugs (measured): 10710' . Total Depth TVD (It): Effective Depth MD (It): Effective Depth TVD (It): 9008' i 11868' 9008' Length Size TVD 80' 20" 91.5# H-40 30' 110' 30' 3150' 13-3/8" 72# L-80 29' 3179' 29' 9517' 9-5/8" 47# L-80 28' 9545' 28' 21' 3-1/2" 9.2# 13Cr80 9327' 9348' 8341' 371 7" 29# L-80 9303 9674 8320.4 1240 3-3/16" 6.2# L-80 9348 10588 8359.86 1314' 2-7/8" 6.16# L-80 10588' 11902' 8938' Tubing Grade: 13CR80 L-80 9208' 9269' o 0 o 0 13. Well Class alter proposed work: Exploratory 0 Development 8 110' 2984' 8532' 8360' 8645 8938 9008' Perforation Depth TVD (It): 9009.12 - 9009.7 9007.08 - 9007.89 9-5/8"x4-1/2" Baker CR Packer 9-5/8"x4-1/2" Baker DB Packer Tubing Size: 4-1/2" 12.6# 4-1/2" 12.6# Packers and SSSV MD (It): 12. Attachments: DescriDtive Sum m ary of Proposal 8 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Burst Junk (measured): None Collapse 470 2670 4760 10530 7020 1490 4930 6870 10160 8160 13450 13890 Tubing MD (It): 26' - 9250' 9250' - 9368' Service 0 15. Well Status alter proposed work: Oil 8 Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Prepcllt::u uy \;!ary Preble 5b4-4~44 3n /2007 Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title P.E. Contact Oliva Bommarito Phone 564-4096 Date COMMISSION USE ONLY 2/27/2007 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Other: ~OO ~ \ ~\ .........'" ~~ ,,""-.. ~ ~ \~~<;. \- Approved by: Form 10-403 Revised 06/2006 Sundry Number: 3D 7 - 01.--1 Location Clearance 0 RBDMS 8ft MAR 0 1 20D7 APPROVED BY THE COMMISSION Date: Submit in Duplicate , , PTRæ ::: W8...LHEAD ::: ACTUATOR = KB. 8...EV = BF. 8...EV = KOP= Max Angle = Datum MD = Datum TVD ::: '. FMC GEN 4 FMC AXELSON 65' 1400' 99 @ 10976' 9925' 8800' SS 13-3/8" CSG, 68#, K-55, ID =12.415" 113-3/8" CSG, 72#, L-80, ID = 12.347" H 3179' Minimum 10 = 2.377" @ 10588' 3-3/16" x 2-7/8" XO 14-1/2" TBG, 12.6#, 13CR. .0152 bpf, ID = 3.958" 9243' TOPOF 7" LNR I 13-1/2" LNR, 9.2#, L-80, .0087 bpf, ID::: 2.992" I 9348' 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9368' 19-5/8" CSG, 47#, L.80, ID = 8.681" I 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I [J£J 10340' 10350' PERFORA TtON SUMMARY REF LOG: SLB MCNL (8/8103) ANGLE AT TOP PERF: 83 @ 11355' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10355 . 10380 C 08/06/05 2" 4 11000 . 11260 C 08/09/03 2" 4 11455 - 11670 C 08/09/03 2" 4 11740 - 11860 C 08/09/03 DATE 06/22/88 08/10/03 08/16/03 08/06/05 05/31/06 07/23/06 REV BY COMMENTS ORIGINAL COM PLETION TGlTLH CTD SIDETRACK (07-30A) JClv\lTLH GL V C/O JNA/PJC PERF & SET WFD ClBP JNA/PAG CIBP SET@ 10710' (08/07/05) CJNlPJC SET PX PLUG @ 9232' 07 -30A S OTES: ***CHROME4-1/2" TBG*** NOTE: *DEPTHS BELOW OVERSHOT (9243') ARE CORRECTED TO TT 07/28/03 2169' -14-1/2" HES X NIP, ID = 3.813" I GAS LIFT MANDRELS ST MD TVD OEV TYÆ VLV LATCH 3406 3179 31 MMG-9CR DMY RK 6576 5922 30 MMG-9CR OMY RK 9116 8156 28 MMG-9CR DMY RK 9187' -14-1/2" HES X NIP, ID = 3.813" 1 9208' -19-5/8" X 4-1/2" BAKER CR PKR, ID = 3.875" 9232' 14-1/2" HES X NIP, 10 = 3.813" I -1 UNIQUE OVERSHOT, ID::: 3.958" I -19-5/8" X 4-1/2" BAKER DB PKR, ID = 4.75" -14-1/2" BAKER SBE, ID::: 4.75" I PORT OA TE o 07/16/0E o 07/16/0E o 08/16/02 -14" BKR DEPLOY SL V, 10 ::: 3.00" -12.81" PXTIP(08/05/06) I -13-1/2" HES X NIP, 10 = 2.813" I -13-1/2" X 3-3/16" XO, ID = 2.80" I -14-1/2" OTIS XN NIP (MILLED OUT) (BEHIND PlÆ) H4-1/2" BAKER SHEAROUT SUB (BEHIND PlÆ) -14-1/2" TUBING TAIL (BEHIND PlÆ) I I MILLOUTWINDOW 9674' - 9680' 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID - 2.80" I 12-7/8" CIBP SET (08/07/05) I DATE REV BY COMMENTS 08/05/06 JCMlPJC PULL TIP/ SET PX TIP 10/23/06 GMD/PA GLV C/O (07/16/06) PRUDHOE BAY UNIT W8...L: 07 -30A PERMIT No: "2030200 API No: 50-029-21786-01 SEe 33, T11N, R14E, 2685.01' F8... & 2325.58' FNl BP Exploration (Alaska) 1 .. ...\ ' Po . . bp 07-30A Summary of Proposal 2127/2007 1) Pull PX plug and replace with XX plug 2) Spot grarrular CaC03 & sand to a depth of 9255' MD. 3) With CTU, spot a balanced cement plug in the tubing & IA to 9200' MD. 4) Mill out cement, clean out sand and CaC03, and pull XX plug. 5) MITIA to verify squeeze success. BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO. Box 196612 Anchorage, Alaska 99519-6612 (9071561-5111 Ðtk!~~V\ --- ~~~ "Ul t>+ w ~ we-li ~ {( 1~ eik ~1Ji~,- of ~ ~~. R~ ~+ì~ W ~ web- ~I'{I {~~ ö~=Jb- 3 ~ S TES: ***CHROME 4-1 f2" TBG*** NOTE: *DEPTHS BELOW ARE CORRECTED TO TT 07f28f03 2169' ÆRFORA TION SUMMARY REF LOG: SLB MCNL (8/8/03) ANGLEATTOPÆRF 83 @ 11355' Note: Refef to Production DB fOf historical perf data SIZE SPF INTffiV AL Opn/Sqz 2" 6 10355 - 10380 2" 4 11000 11260 2" 4 11455 - 11670 2" 4 11740 - 11860 '"" c DATE COMMENTS PULL TIP/ SET PX TIP GLV C/O (07/16/06) PRUDHOE BA Y UNIT WELL: 07 -30A ÆRMIT No: '2030200 API No: 50-029-21786-01 SEC 33, T11 N, R14E, FNL Sf> Exploration (Alaska) 07-30A (PTD #2030200) Classified as Problem Well e e All, ZÜ$-CYz.o Well 07-30A (PTD #2OðZOO) has been found to have sustained casing pressure on the IA. The TIO pressures were 2380/2310/20 on 07/06/06 when the well failed a TIFL. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. WIE: Evaluate for GLV change out 3. SL: c/o GL Vs 4. DHD: Re-TIFL A wellbore schematic has been included for reference. «07-30A.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, ftnna (})u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: 07 -30A.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of I 7/13/20062:49 PM TREE" WELLHEAD" ACTUA TOR" KB. ELEV " BF. ELEV - KOP" Max Datum MD " Datum TVO = FMC GEN 4 FMC AXELSON 65' e 13-3/8" CSG, 68#, K-55, 10 =12.415" 13-3/8" CSG, 72#, L-80, !D = 12.347" Minimum ID = 2.377" @ 10588' 3-3/16" x 2-7/8" XO 14-1/2" TBG, 12.6#, 13CR, .0152 bpf, 10= 3.958" 9243' TOP OF 7" LNR I 13-1/2" LNR, 9.2#, L-80, .0087 bpf, !D = 2.992" I 14-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, 10 = 3.958" 9-5/8" CSG, 47#, L-80, 10 = 8.681" 7" LNR, 29#, L-80, .0371 bpf, ID" PERFORA TION SUMMARY REF LOG: SLB MCNL (8/8/03) ANGLE AT TOP ÆRF: 83 @ 11355' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sq TE 2" 6 10355 - 10380 0 08/06/05 2" 4 11 000 - 11260 C 08/09/03 2" 4 11455 - 11670 C 08/09/03 2" 4 11740 - 11860 C 08/09/03 DATE 06/22/88 08/10/03 08/16/03 08/06/05 05/31/06 REV BY COMMENTS ORIGINAL COM PLETION TGITLH CTD SIDETRACK (07-30A) JCMlTLH GL V C/O JNA/PJC ÆRF & SET WFD CIBP JNA/PAG CIBP SET @ 10710' (08/07/05) 9348' 9368' 9680' 10293' 10350' DATE 07 -30A S OTES: ***CHROME4·112" TBG*** NOTE: *DEPTHS BELOW OVERSHOT (9243') ARE CORRECTED TO TT 07/28/03 2169' 14-1/2" HES X NIP, 10=3.813" I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3406 3179 31 MMG-9CR DOME RK 16 08/16/03 6576 5922 30 MMG-9CR SO RK 20 08/16/03 9116 8156 28 MMG-9CR DMY RK 0 08/16/03 14-1/2" HES X NIP, ID = 3.813" I -19-5/8" X 4-1/2" BAKER CR PKR, 10 = 3.875" 14-1/2" HES X NIP, ID = 3.813" I -I UNIQUE OVERSHOT, !D = 3.958" I I CHEM CUT TBG (06/05/03) I 9-5/8" X 4-1/2" BAKER DB PKR, ID" 4.75" -14-1/2" BAKER SBE, 10 = 4.75" I 9327' 9337' 9348' 9356' 9367' 9368' 4" BKR DEPLOY SLV, ID = 3.00" 3-1/2" HES X NIP, ID = 2.813" H 3-112" X 3-3/16" XO, ID = 2.80" I H4-1/2" OTIS XN NIP (MILLED OUT) (BEHIND PIPE) I H4-1/2" BAKER SHEAROUT SUB (BEHIND PIPE) I H4-1/2" TUBING TAIL (BEHIND PIPE) I I MILLOUTWINDOW 9674' - 9680' 13-3/16" LNR, 6.2#, L-BO, .0076 bpf, ID = 2.80" I 12-7/8" C!BP SET (08/07/05) I REV BY COMMENTS PRUDHOE BA Y UNrr WELL: 07-30A PERMrr No: '2030200 API No: 50-029-21786-01 SEC 33, T11N, R14E, 2685.01' FEL & 2325.58' FNL BP Exploration (Alaska) '11( DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 >~~ "3> ~~j Permit to Drill 2030200 Well Name/No. PRUDHOE BAY UNIT 07-30A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21786-01-00 MD 11902 r / Completion Date 8/9/2003 /" Completion Status 1-01L Current Status 1-01L UIC N TVD 9008 REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, MCNL, CCL Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~D C Lis ~3307 Neutron 9087 11856 Case 9/30/2005 LDWG Edit of 2-pass MCNL .({ C Tf 12143 LIS Verification 9078 11854 Case 9/20/2003 Compensated Neutron Log - Memory ,¿{ GRlCCUCNL C Pds 12143 Neutron 2 9078 11854 Case 9/20/2003 Compensated Neutron Log - Memory ~ GRlCCUCNL Neutron 2 Blu 9078 11854 Case 9/20/2003 Compensated Neutron Log - Memory ~ GRlCCUCNL C Pds 12143 Casing collar locator 2 9078 11854 Case 9/20/2003 Compensated Neutron ¡ Log - Memory '~ GRlCCUCNL Casing collar locator 2 Blu 9078 11854 Case 9/20/2003 Compensated Neutron - Log - Memory GRlCCUCNL ED D Pdf Directional Survey 9660 11902 9/16/2003 Rpt Directional Survey 9660 11902 9/16/2003 ~~ C Lis ~2347 Gamma Ray 9680 11902 Open 1/9/2004 Gamma Ray - MWD C Pds 12347 Gamma Ray 9680 11902 Open 1/9/2004 Gamma Ray - MWD {og Gamma Ray Blu 9680 11902 Open 1/9/2004 Gamma Ray - MWD it~ Gamma Ray 9680 11902 Open 1/9/2004 Gamma Ray - MWD I Log Gamma Ray 2 Blu 9087 11856 Case 1/19/2005 MEMORY PROF & IPROF LOG/MEM GRlCCUSPINITEMP/PRE S Permit to Drill 2030200 ~ 11902 TVD 9008 Leak Well Cores/Samples Information: Name Well Cored? ADDITIONAL INFORMATION y~ Chips Received? Y 1 N Analysis Received? Comments: ~ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Well Name/No. PRUDHOE BAY UNIT 07-30A Completion Date 8/9/2003 Interval Start Stop ~ , Operator BP EXPLORATION (ALASKA) INC Completion Status 2 Blu 1-01L Current Status 1-01L 11856 Case 2/3/2005 9087 Sent Sample Set Number Comments Received Daily History Received? è/N ~/N Formation Tops Date: API No. 50-029-21786-01-00 UIC N memory borax log/mem gr/ccl/cnII .~ '-I /If fi V ~-- - Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well ;J..€:>')..-Â},8 4-10A1L-28 ?-.-o)rOr] F-34B I~>- Â1? H-26 ;"u;1.-0(.¡'ß J-16A ì-o) rÖ')..~ 07-30A BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 10679056 11054181 10662951 10942212 10715445 3ò 09/28/05 NO. 3476 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 Date BL Color CD 02103104 1 --- 1--- t ') '303 05131105 1/ 1../ /.3 J a~ 09117/03 1-- 1"- J'} 10 r 05/06/05 1 ~ 1~ 133'0'0 12109/04 1-- 13 )C:l7 RST MCNL RST MCNL MCNL (PRINT SENT 1/24105) --' ~\ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK L9503 838 ~ ATTN: Beth JJ j Received by: \ STATE OF AlASKA- AlA~ ~ Oil AND GAS CONSERVATION COMI'v. ,!ION REPORT OF SUNDRY WELL OPERATIONS " '. 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 65 KB 8. Property Designation: ADL-028309 11. Present Well Condition Summary: Total Depth measured 11902 true vertical 9007.94 Effective Depth measured 11868 true vertical 9007.89 Casing Conductor Surface Production Liner Liner Liner Liner Perforation depth: Length Size 80 20" 91.5# H-40 3150 13-3/8" 72# L-80 9517 9-5/8" 47# L-80 21 3-1/2" 9.2# 13Cr80 371 7" 29# L-80 1240 3-3/16" 6.2# L-80 1314 2-7/8" 6.16# L-80 Measured depth: 10355 - 10380 True Vertical depth: 8836.16 - 8840.04 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 354 291 x Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Class: IßeIqJll ent ir;?1 Stratigëll::hc Stimulate 0 Other 0 Waiver 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: ExpIcratay C 203-0200 Sa\Åce 6. API Number: 50-029-21786-01-00 9. Well Name and Number: 07 -30A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet Plugs (measured) 10710 feet Junk (measured) None feet feet MD TVD Burst Collapse 30 - 11 0 30 - 110 1490 470 29 - 3179 29 - 2983.89 4930 2670 28 - 9545 28 - 8532.02 6870 4760 9327 - 9348 8341.45 - 8359.86 10160 10530 9303 - 9674 8320.4 - 8644.54 8160 7020 9348 - 10588 8359.86 - 8938.38 10588 - 11902 8938.38 - 9007.94 13450 13890 4-1/2" 12.6# 13CR80 4-1/2" 12.6# L-80 9-5/8" x 4-1/2" Baker CR Packer 9-5/8" x 4-1/2" Baker DB Packer 26 - 9250 9250 - 9368 9208 9269 RBDMS 8FL AUG J 9 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 9720 7 0 8155 6 100 15. Well Class after Droposed work: ExpIaGtayL IßeIqJll ert ~ 16. Well Status after proposed work: 01 P <?as r V\V\G r Tubing pressure 867 1063 SeNce r V\.CEPLr QNJ r WNJ r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal . . f . ') Sign~~~ Form 10-404 Revised 04/2004 Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr ln~rG! N/\L Date 8/16/2005 Submit Original Only ,. ) ) 07 -30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 8/7/2005 CTU #4, 1.75 Coil, Set CIBP and PERF. ... Cont' from 08/06/2005 WSR ... MU WFD 2-7/8" CIBP. Flags correlated to MCNL 08/08/2003. RIH to lower flag at 10847' ctmd and correct depth to 10864' corrected ctmd (mid element of CIBP). PUH to 10710' correcetd ctmd and set CIBP. POOH. MU and RIH with 25' of 2.0" 6 spf PJ guns. RIH to upper flag at 10479' ctmd. Correct depth 10466' corrected ctmd (top shot of guns at flag). PUH to 10355' corected ctmd and fire guns. POOH. *** Job Complete *** FLUIDS PUMPED BBLS 0.0 0.0 0.0 TOTAL Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,-. Well /f:~'" I7CC-29A /.!J7- IJ¡ E-25 ~q5'ð.2.1 G-02A (jjJf/ {qif W-27A '"e-øt4 D-25A (__ !qq-O~'V DS 15-25A' - '" ~- ø"- E-39A '\ 02-168 ¡ 'I,... () l! C-25A :).o'l-:w1 E-17A ~D1"' i~~ C-41A j ~~¡~~ ~~~~~: '1Jr-ít?ïf 02-28A !15-tf63 --- D-11A ì '-.n 1 fa DS 05-24A ( V"1 - ~ 0 F--- Job# 10715422 10715423 10715424 10670031 10854314 10715428 10715430 10928597 10928598 10928602 10928606 10715445 10715446 10928607 10928608 10928609 (Prints--.. only-Job not complete) ;;<'0 =) _ Q,~ C) 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 08/20/04 1 08/21/04 1 08/23/04 1 08/24/04 1 08/27104 1 09/11/04 1 09/13/04 1 10/02/04 1 10/03/04 1 10/30/04 1 11/24/04 1 12/09/04 1 12/11/04 1 12/11/04 1 12/16/04 1 12/22/04 1 MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL MCNL 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: ~;; pç Alaska Data & Consulting Services 2525 G. ambell Street,~uit 00 .. (;L AnChora. ge, A~9950 38 1 / ATTNCe ~.. / 1 \ k.~ I ..ij ~ Rece v!3d by: .J;~ /1 · (/' .. 1/ V Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATIN: Seth ~. Well Job# 10928608 10715445 10964105 10830819 10928610 10670030 ('t5"¡-3 D-11A ~03-oZCDS 07 -30A ¡Ø2-o jl/ DS 14-098 ft5 "/~2-- P2-56 ,?-O If. US DS 11-06A I 'f1-ffð E-21A -- Log Description MEM PROD/lNJECTION PROFILE MEM PROF & IPROF LEAK DETECTION RST MCNL (PRINT ONLY-NO CD) MCNL (PRINT ONLY-NO CD) Date 12/16/04 12/09/04 12/23/04 06/20/04 12/24/04 08/22/04 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 ~ \ / ¡f' Date Delivered: (//~J~ Blueline 1 1 1 1 1 1 01/18/05 NO. 3307 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints CD Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99ï;o3028 A TIN: Beth ~ t Received by /, I('l~ ) ) f)O 3 -0C90 Transmittal Form '&i. BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West ih Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Wee pie Reference: 7-30A II Cont~i~s the following: II II 1 LDWG Compact Disc J,g)3 Y i- ¡ (Includes Graphic Image files) , 1 LDWG lister summary 1 blueline - OR/Directional Measured Depth Log I blueline - GR/Directional TVD Log II II II II I I LAC Job#: 504399 Sent By: Glen Borel ~ ..0::----. Received By: ~ô \ ,,-~_/y~~~ Date: ~~è~VED Date: . ". 0 '''''.''\. ..... " . 9 ¡'. ..;\, ...;. r·-r~;';~;:·:;~~;~~~;;~~~·;l· I..... . II.ot,qr '\II IOWftl .'1 ~I~ nWII. :,' ", -. : '''''~'I ",\~' :'IJÞI'O'''1'': "iiiIII ......: ..'I 1"'11II1, I.·..~' .. ,'_ ... ? ... :.'10 "I,' ....". ,._--------_..~.".._~....~..~._.... ,.....,._--~--_.._... :~'I'" ~:1t:',.,..(~.,. IL··...·"~., ...'",....,...... :::~::~.:: I__________··__··_··":_.._':"'_~_·_____.____R___ I ...~ð·L, ~., I,' l;!jtll;" Ë-~~~ : ØiU'1',,·1II .. ~ .,-.- -...., PLEASE ACKNOWLEDGE RECEIPT BY SIGNIN~a:iH~issiorrL . ~ OR FAXING YOUR COPY: ; FAX: (907) 267-6623··:~.r :_,.~~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ,-- --- --" Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth 09/16/03 NO. 2959 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description 23318 MCNL 23404 MCNL 23347 MCNL 23401 MCNL 23308 MCNL 23399 MCNL 23420 MCNL 23426 MCNL 23276 RST Color Date Blueline Prints CD '-- 05/15/03 1 1 Jjj1~f 06/26/03 1 1 OS/22/03 1 1 ~J ti;¡ JS 06/12/03 1 1 05/03/03 1 1 ~, 06/23/03 1 1 08/08/03 1 1 }J~=) 07/19/03 1 1 04/04/03 1 1 --"< PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ~ ?'" ..i""'\ 1F"" i\/f...... D ~=( r 'lJ t: ~ . ').. 1::.1 ~ -~' 1""'0 ,...... 1),,!,\""7 St.; 2. \) L\.iV,) Received b~. iý\~' 0 Ct .J:\f'Jv"\ ;\1"Ú'"). ,y' 2. (-;:;:¡~ (;ons. C-Dmmi5ðioo ~..5(h.."..a va \.it. "V."....... ~ Anchorage "'\ J ST A TE OF ALASKA \ ALASKi. 'IL AND GAS CONSERVATION COM., JSION 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: 570' SNL, 302' WEL, SEC. 33, T11 N, R14E, UM Top of Productive Horizon: 3232' NSL, 3323' WEL, SEC. 28, T11N, R14E, UM Total Depth: 3542' NSL, 4333' WEL, SEC. 28, T11 N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 675883 y- 5950348 Zone- ASP4 TPI: x- 672766 y- 5954079 Zone- ASP4 Total Depth: x- 671749 y- 5954365 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD, GR, MCNL, CCL 22. "'CÄSIN(3!"" ..$I.~~, i:': 20" 13-3/8" 9-5/8" 7" One Other 5. Date Comp., Susp., or Aband. 8/9/2003 6. Date Spudded 8/3/2003 7. Date T. D. Reached 8/6/2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 65' 9. Plug Back Depth (MD+ TVD) 11868 + 9008 Ft 10. Total Depth (MD+TVD) 11902 + 9008 Ft 11. Depth where SSSV set (Nipple) 2169' MD 19. Water depth, if offshore N/A MSL 1b. Well Class: o Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-020 13. API Number 50- 029-21786-01-00 14. Well Number PBU 07-30A 15. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028309 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) " ....',',',...,'.......:>:,<' : Wt.· PER . Fr', : ':'. 91.5# 68# / 72# 47# 29# 9.2# / 6.2# / 6.16# CASING, LINER AND CEMENTING RECORD ,; I .':S.· ·S. :r:r. ..·.I'N. G. :.".I:) EP.. T....· H:· ' ".'.";1 1;,:I.~.··.b.··.te.··.'i¡¡:. I....':.: }I" ::T'aF¡i "',':1 ': ',\BPTTOM ':\ .: I,,;:I:SI?E;."¡·"I' Surface 110' 30" 2892 # Poleset Surface 3179' 17-1/2" 3000 sx CS III, 600 sx 'G', 150 sx CS I Surface 9545' 12-1/4" 629 sx Class 'G' 9303' 9674' 8-1/2" 400 sx Class 'G' 9327' 11902' 3-3/4" x 4-1/8" 157 sx Class 'G' H-40 K-55/ L-80 L-80 L-80 L-80 23. Perforations 0Ren to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 4 spf MD TVD MD TVD 11000' -11260' 9023' - 9017' 11455' - 11670' 9009' - 9010' 11740' - 11860' 9007' - 9008' 26. Date First Production: August 25, 2003 Date of Test Hours Tested PRODUCTION FOR 8/31/2003 6.1 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 926 24-HoUR RATE I, I , '; I,:' ~ : ,'?'.:, ~' ;,' ~ ,I: .",: : "':, : ¡ ': :;; : ",I , " " I,':::''':''':'''''''':::::: ': ,," ,I I il I IAM00,NT:PtidEQ';., ....,. 'I, ,:,:', * 3-1/2" x 3-3/16" x 2-7/8" SIZE 4-1/2", 12.6#, 13Cr / L-80 PACKER SET (MD) 9208' & 9273' 24. DEPTH SET (MD) 9368' 'J.\ÇID,..FRACTURE,CE~ENT..SQUEEiE,.;··ETC. II...· ...'. ...... '.' ..... .....,. .'. ., DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 30 Bbls MeOH 25:,' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-BBL 1,394 Oll-BBl 5,485 GAs-McF 23,737 GAs-McF 93,391 W ATER-BsL -0- WATER-BsL -0- CHOKE SIZE 86° GAS-Oil RATIO 17,028 OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core·£hips; if none, state "none". : '::,'" ) + . ".... None ; î/x2; ~) l 'l:~Y,~~· , :-¿~ 0('0 -, ._. ,~,,,~ .....",... ."'" ~~ -"5 BFl SEP 1 ~t ?OOr DUPLICATE Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE RBDMS BFl SEP ~ .... '- 28. Top CGL Base CGL 23SB 22TS 21TS Zone 1 B GEOLOGIC MARKEF ) NAME MD TVD 9730' 8693' 9848' 8780' 10393' 8843' 10511' 8893' 10590' 8939' 10802' 9028' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 29. )ORMATION TESTS Include and briefly sùmmarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~n, 17 LI - Il/l/J_ Ttl T h I A t t D t 09 OLl 0-:> Terrie Hubble.....---,eJ\,~ J ~ i e ec nica ssis an a e·.." \... ~ PBU 07 -30A 203-020 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Dan Kara, 564-5667 Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. 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 2/2003 DUPLI CATE OperationsSurnmary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -30 07 -30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 7/19/2003 03:00 - 00:00 21.00 MOB P PRE Move Nordic 2 from MPU C pad to GBP DS 7-30A. Drop reel. Scope down & lower mast. Leave pad at 1100 am on 7-19-03. At Spine Road around midnight. 7/20/2003 00:00 - 00:00 24.00 MOB PRE Continue rig move from MPU to GPB. Hit several soft spots in Spine Road east of MPU cut off. Dig rig out & lay matting boards. Roads better after L & V Pad road. At J pad by 1400. Stop move at Price Pad due to emergency at LPC. Resume. Stop again due to problem at CPS. Resume move. Watering road in front of rig to reduce damage to chip seal pavement. Camp passed rig and on location at 2130. Continue move. 7/21/2003 00:00 - 01 :30 1.50 MOB PRE Continue rig move. On location at 0130 hrs. 01 :30 - 03:00 1.50 MOB PRE Re-grade pad in front of well head to accomodate rig mats. 03:00 - 14:00 11.00 MOB PRE Remove brakes from draw works. Install replacements. Wrong size shipped by manufacturer. Re-install old brakes. Install new scaffolding system in cellar. 14:00 - 18:00 4.00 MOB PRE Re-string blocks from 6 to 8 lines. Inspect derrick for "falling object" potential after derrick work (pipe rack mods & stabbing board mods) before raising mast. Continue to install scaffold system in cellar. 18:00 - 00:00 6.00 MOB PRE PJSM. Review plan forward on raising the derrick. Replace cable on bridge crane. Move choke line in cellar to allow for better scaffold useage. 7/22/2003 00:00 - 05:00 5.00 MOB P PRE Make final inspection of derrick for loose material/tools. Raise and pin derrick. Slip 165' of drilling line. Install choke line in cellar. Repair derrick climber. 05:00 - 05: 15 0.25 MOB P PRE PJSM on raising top section of derrick. 05:15 - 07:00 1.75 MOB P PRE Raise top section of derrick and secure. 07:00 - 09:00 2.00 MOB P PRE RU floor area. PU bails & injector. Finish scaffolding in cellar. 09:00 - 10:00 1.00 RIGU P PRE Spot rig over well. Meet with Pad Operator. Inspect pad. Order fluids to displace well. Accept rig at 1000 hrs on 7-22-03. 10:00 - 14:40 4.67 RIGU P PRE Continue to RU. Lay hardline. Load pits with KCL water. 14:40 - 16:30 1.83 BOPSUE P PRE Pull BPV. 16:30 - 18:00 1.50 BOPSUR N PRE MPI welds on cellar scaffolding 18:00 - 19:20 1.33 BOPSUR P PRE Prep to displace and kill well with 1 % KCL water. R/U lines to tbg and IA. Well dead. 19:20 - 19:40 0.33 BOPSUR P PRE PJSM. Review plan forward for displacement of well. Discuss options to install fall protection when working on top of SLB Power Pack building. 19:40 - 23:00 3.33 BOPSUR P PRE Pump 50 bbls down IA displacing diesel freeze protect from tbg. Taking returns to tiger tank. Swap to pumping down tbg and displace freeze protect from IA to tiger tank. 90ppm of H2S detected at bottoms-up. All H2S monitors functioned correctly. Continued pumping another 100 bbls and the well cleaned up and no H2S detected. Shutdown monitored well..dead. 23:00 - 00:00 1.00 BOPSURP PRE Set BPV and tested through IA to 1000 psi. Good test. Bleed off pressure. Prep to ND production tree. 7/23/2003 00:00 - 00: 15 0.25 BOPSUR P PRE PJSM review plan forward and hazards for ND production tree. 00:15 - 03:00 2.75 BOPSUR P PRE Blowdown and remove circulation lines to wellhead. Check bridge crane operation. ND production tree. 03:00 - 03:20 0.33 BOPSUR P PRE PJSM on NU 13 5/8" 5K BOP stack. 03:20 - 09:30 6.17 BOPSURP PRE NU BOPE. Crew change PJSM before continuing NU procedure. Utilize new cellar scaffolding. Printed: 8/11/2003 11 :01 :37 AM EXPLORATION Operations Summary Report Page 2 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -30 07 -30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 Date From- To Hours Task Code NPT Phase Description of Operations 7/23/2003 09:30 - 10:30 1.00 BOPSURP PRE Riser extension too long. Cut l' off and dress same. 10:30 - 15:00 4.50 BOPSURP PRE Continue to NU. Round up rest of testing tools, test joint etc. 15:00 - 22:45 7.75 BOPSURP PRE Test BOPE. Witness waived by C. Scheve. 7/22/03. Unable to test variable in btm rams due to FMC test plug. Will test after pulling completion. 22:45 - 00:00 1.25 PULL P DECOMP Pull FMC blanking plug and BPV. 7/24/2003 00:00 - 00:30 0.50 PULL P DECOMP Pull FMC blanking plug and BPV. Monitor well. 00:30 - 02:15 1.75 PULL P DECOMP RU Camco to spool SSSV control lines. PU landing joint. 02:15 - 02:30 0.25 PULL P DECOMP PJSM. Discuss plan forward for pulling tubing hanger. 02:30 - 03:45 1.25 PULL P DECOMP MU landing joint into tubing hanger. Back out LDS. Pull tubing hanger, PU wt = 145K. 03:45 - 05:00 1.25 PULL N DECOMP Hydraulic line leak on rig floor. Shut down hydraulics immediately. Replace hydraulic line. 05:00 - 06:00 1.00 PULL P DECOMP LD tubing hanger. 06:00 - 07:00 1.00 PULL P DECOMP RU to circulate. Reverse out tbg to verify no gas etc in wellbore. 07:00 - 13:30 6.50 PULL P DECOMP POOH with 4-1/2" BTC-M tbg & jewelry. Significant corrosion on nearly all pin ends of tbg. 13:30 - 18:00 4.50 PULL P DECOMP LD SSSV. Recovered 71 of 73 SS bands. Continue to POOH with 4-1/2" tubing completion. 160 joints as of 18:00. 18:00 - 00:00 6.00 PULL P DECOMP Continue to POOH with 4-1/2" tubing completion. Average approx. 20 joints per hour. Box and pin ends corroded. Corrosion damage is more pronounced on deepest joints of tubing. 7/25/2003 00:00 - 00:30 0.50 PULL P DECOMP Continue to POOH with 4-1/2" BTC-M tbg & jewelry. LD a total of 290jts of 4-1/2" tubing and 8 GLMs with pups. Chemical cut looks clean. Cut joint is 15.47' long, 4.6" OD. Confirm with Baker Fishing hand that overshot fits over cut end of tubing. Good fit, no modifications needed on overshot. Tbg drifted to 3.875" 00:30 - 01 :00 0.50 RUNCOrvP COMP PJSM. Discuss RU to run 3-1/2" PH6 workstring. 01 :00 - 03:00 2.00 RUNCOrvP COMP PU kelly bushing, kelly swivel, rathole. 03:00 - 06:00 3.00 RUNCOrvP COMP Load pipe shed with 3-1/2" WTS-6 DP. Drift and strap. RU rig tongs (needed to MU kelly). PU kelly valve. 06:00 - 06:30 0.50 RUNCOrvP COMP Hold PJSMITL mtg at crew change. Discuss Golden Rules: Permitting 06:30 - 09:30 3.00 RUNCOrvP COMP Continue to load 3-1/2" DP into pipe shed. Drift & strap same. 09:30 - 11 :30 2.00 RUNCOrvP COMP MU kelly & swivel assembly. 11 :30 - 14:00 2.50 BOPSUR P COMP Install FMC blanking plug. Test variable rams to 250/3500 psi. Test kelly valves etc. Pull test plug. 14:00 - 15:00 1.00 RUNCOrvP COMP Install wear bushing. 15:00 - 16:00 1.00 RUNCOrvP COMP Bring BHA components to rig floor. 16:00 - 16:15 0.25 RUNCOrvP COMP Hold PJSM with all hands to discuss MU and running BHA on 3-1/2" DP. Plan is to go slow as hands have not handled "big iron" together as a team for some time. 16:15-18:30 2.25 RUNCOrvP COMP MU BHA #1: washover shoe, wash pipe extension, dressing mill, jars etc. on six 4-3/4" drill collars. 18:30 - 19:00 0.50 RUNCOrvP COMP Discuss making up BHA with night crew and Baker Fishing hand. 19:00 - 19:45 0.75 RUNCOrvP COMP Continue MU wash over BHA #1. 19:45 - 21 :00 1.25 RUNCO~ RREP COMP Torque guage on Rig Tongs is suspect. Inspect. Replace Torque gauge with newly calibrated gauge. Re-torque connections on BHA. Turns out connections were torqued up Printed: 8/11/2003 11:01:37 AM ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -30 07 -30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 7/25/2003 19:45 - 21 :00 1.25 RUNCOMN RREP COMP 21 :00 - 22:00 1.00 RUNCOIVP COMP 22:00 - 00:00 2.00 RUNCOMN RREP COMP 00:00 - 02:00 2.00 RUNCOMN RREP COMP 02:00 - 02:15 0.25 RUNCOIVP COMP 02: 15 - 06:00 3.75 RUNCOIVP COMP 06:00 - 06:30 0.50 RUNCOIVP COMP 06:30 - 14:00 7.50 RUNCOIVP COMP 14:00 - 15:00 1.00 RUNCOIVP COMP 15:00 - 16:00 1.00 RUNCOIVP COMP 16:00 - 19:45 3.75 RUNCOIVP COMP 19:45 - 00:00 4.25 RUNCOIVP COMP 7/26/2003 7/27/2003 00:00 - 01 :00 1.00 RUNCOIVP COMP 01:00 - 01 :15 0.25 RUNCOIVP COMP 01:15 - 01:45 0.50 RUNCOIVP COMP 01 :45 - 04:45 3.00 RUNCOIVP COMP 04:45 - 06:00 1.25 RUNCOIVP COMP 06:00 - 06:30 0.50 RUNCOIVP COMP 06:30 - 09:00 2.50 RUNCOIVP COMP 09:00 - 10:00 1.00 RUNCOIVP COMP 10:00 - 11 :00 1.00 RUNCOIVP COMP 11:00-12:00 1.00 RUNCOIVP COMP 12:00 -12:15 0.25 RUNCOIVP COMP 12:15 -19:00 6.75 RUNCOIVP COMP 19:00 - 19:30 0.50 RUNCOIVP COMP 19:30 - 22:00 2.50 RUNCOIVP COMP 22:00 - 00:00 2.00 RUNCOIVP COMP 7/28/2003 00:00 - 03:00 3.00 RUNCOIVP COMP 03:00 - 06:00 3.00 RUNCOIVP COMP Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 Description of Operations correctly. PU remainder of drill collars. PU 2joints of 3-1/2" WTS-6 DP. Hydraulic splitter block for backups on the Eckel tongs failed. Wait on replacement part. Wait on replacement splitter. Install new splitter on Eckel tongs. PJSM: review plan forward for running drill pipe. Discuss job roles, emphasize good communication. PU 3-1/2" WTS-6 DP. 60 joints in the hole at 06:00. Hold PJSM with crew arriving on tour. Discuss handling drill pipe. Continue to RIH with overshot assembly on drill pipe. PU and tighten kelly connections. Reverse circulate 50 bbls to clear DP. Continue to RIH with BHA / PU drill pipe singles. 287joints in the hole at 19:45. Secure well and shut down for welder to modify stabbing board above rig floor. Modify stabbing board. NB: A stabbing board is necessary to run VAM-ACE tubing, Nordic 2 did not have a stabbing board built with the new derrick when the rig was modified and commisioned for CTD. Continue work on modifying new stabbing board. PJSM: Discuss plan forward for MU kelly to DP, Washing over tubing stub and pumping sweep. MU Kelly to DP. PU wt=155K, SO wt=142K. Bring pumps on to 4bpm at 550psi. Rotate at 200amp = 4,OOOft-lbs. RIH, see pressure increase 50psi and Torque increase to 4400psi as we wash over fish. RIH 40' on kelly, this puts top of fish at 9251 'DPM. Set down 10K. Let torque out, PU 10'. RIH, set down 10K. Let torque out, PU 2'. Bring pumps on to 8bpm, 1550-1900psi. Send 40bbl Hi-vis sweep around the long way. PU above fish once hi-vis pill exits DP. Stand back kelly into kelly shuck and POOH laying down 3-1/2" DP. Hold crew change PJSM and Tech Limit mtg. Review Driving Safety Golden rule with crew. COntinue to POOH with drill pipe. Lay down same. Pipe pulling dry. Inspect stabbing board welds - Tubosope / MPI. All in order. Continue to LDDP in singles. Break connections on kelly to prep for laying down same. PJSM with crew after Nordic change out. Continue to LDDP in singles. PJSM with crew, discuss LDDP. Watch slippery floor, pinch points and keeping rig floor clear. Keep non essential people off the floor. Discuss latching and unlatching elevators and hazards with using hydraulic tongs. Continue LD 3-1/2" WTS-6 Drill Pipe in singles. LD six drill collars and BHA #1. LD Kelly swivel, Kelly and rathole. Offload drill collars from pipe shed. Load pipe shed with 4-1/2" 13CR V AM-ACE. Drift and Strap Printed: 8f11f2003 11 :01 :37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 07 -30 07 -30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 From - To Hours Task Code NPT Phase Description of Operations 7/28/2003 03:00 - 06:00 06:00 - 06:30 06:30 - 14:30 14:30 - 15:30 15:30 - 17:00 17:00 - 21:15 21:15-21:45 21:45 - 00:00 7/29/2003 00:00 - 06: 15 06: 15 - 06:30 06:30 - 15:00 15:00 - 18:00 18:00 - 21 :45 21 :45 - 22:00 22:00 - 00:00 7/30/2003 00:00 - 01 :15 01:15 - 01:30 01 :30 - 04:10 04:10 - 04:20 04:20 - 06:30 06:30 - 09:00 09:00 - 09:30 09:30 - 10:00 10:00 - 17:30 3.00 RUNCOMP 0.50 RUNCOMP 8.00 RUNCOMP 1.00 RUNCOMP 1.50 RUNCOMP 4.25 RUNCOMP 0.50 RUNCOMP 2.25 RUNCOMP 6.25 RUNCOMP 0.25 RUNCOMP 8.50 RUNCOMP 3.00 RUNCOMP 3.75 RUNCOMP 0.25 RUNCOMP 2.00 RUNCOMP 1.25 RUNCOMP 0.25 RUNCOMP 2.67 RUNCOMP 0.17 RUNCOMP 2.17 RUNCOMP 2.50 RUNCOMP 0.50 RUNCOI\rP 0.50 BOPSUR. P 7.50 BOPSURP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP same. Hold PJSM for handling tubing with day crew. Continue to load pipe shed. Install e-line coil into reel house. Slm ops with loading pipe shed. Complete loading tubing. Strap & drift same. Load packer & other jewelry. RU floor to run completion. PJSM with Nabors Casing crew (3 people), VAM-PTS Reps (2 people), Baker Fishing hand and rig crew. Review Nabors Casing Service procedure for running Chrome tubing. Reveiw tubing summary and tally. Disucss HSE issues related to running chrome tubing. PU 4-1/2" 13CR-80 VAM-ACE tubing completion: Unique Mach ine 13CR overshot, X nipple w/ RHC sleeve, Baker 4-1/2" x 9-5/8" Chrome S3 Packer, X nip., 3x GLM w/dummies, X nip., FMC Tubing hanger. VAM-ACE reps on site consulting. Continue...PU 4-1/2" 13CR-80 VAM-ACE tubing completion. Average 16-18jts per hour. 120jts in the hole at 6:15am. Hold PJSM with all hands after crew change. Discuss specifics of running 13 cr pipe. Identify roles & responsibilities for all. Continue running 4-1/2" VAM completion including top GLM w/dummy and top X nip. Record PU and SO wt on jt #216, 143Kup and 110Kdown. Tag tubing stub 19' down on jt #217, set 1 OK down. PU and establish circulation down tubing, 3bpm at 80psi above tubing stub. See pressure increase as overshot is 2.5' over stub, back rate down to 2.2bpm at 500psi. Rotate pipe 1/2 turn. Tag again, for final space out calcs. Clean pits and prep to reverse circulate. Take on SW and Corrosion inhibitor. PJSM Reverse circulate 215bbls SW, 350bbls SW+Corrosion Inhibitor followed by 15bbls SW to flush surface lines at 3bpm. Continue to reverse circulate. Pump a total of 580 bbls to displace IA and partially displace tubing. PJSM on final space out of Tubing. Tag up and set down 1 OK on tubing stub to confirm landing depth. Tag up l' shallow after pumping hot fluid on backside. Space out overshot 2.5' above no-go on tubing stub. Land Tubing hanger and tighten LDS. PJSM with little red on pumping dead crude down Backside. Line out little red to IA. PT lines to 3500psi. Pump 140 bbls dead crude at 2 bpm taking returns via tubing. Drop ball n' rod. RU to set packer and PT tubing. Pressue tubing to 3500 psi (lAP = 100 psi). After 30 minutes, SITP = 3450 psi (lAP = 180 psi). Bleed pressure to 1500 psi. Using Little Red, pressure IA to 3500 psi (SITP climbed to 2150 psi). After 30 minutes, lAP = 3390 psi (SITP = 2140 psi). OAP = 0 psi. Bleed pressures. Set TWC. Safety meeting. ND 13-5/8" BOPE Printed: 8/11/2003 11 :01 :37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 07 -30 07 -30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 7/30/2003 Frorn- To Hours Task Code NPT Phase 17:30 - 21 :00 3.50 BOPSURP COMP 21:00 - 21:15 0.25 BOPSURP COMP 21:15-00:00 2.75 BOPSUR P WEXIT 00:00 - 02:30 2.50 BOPSURP WEXIT 7/31/2003 02:30 - 07:30 5.00 BOPSUR P WEXIT 07:30 - 08:00 0.50 BOPSUR N WEXIT 08:00 - 09:00 1.00 BOPSURP WEXIT 09:00 - 09:30 0.50 RUNCOrvP COMP 09:30 - 11 :00 1.50 RUNCOrvP COMP 11 :00 - 13: 15 2.25 RUNCOrvP COMP 13: 15 - 15:30 2.25 STWHIP P WEXIT 15:30 - 17:30 2.00 STWHIP N DPRB WEXIT 17:30 - 19:30 2.00 STWHIP P WEXIT 19:30 - 20:00 0.50 STWHIP P WEXIT 20:00 - 20: 15 0.25 STWHIP P WEXIT 20:15 - 22:15 2.00 STWHIP P WEXIT 22:15 - 00:00 1.75 STWHIP P WEXIT 8/1/2003 00:00 - 00: 15 0.25 STWHIP P WEXIT 00:15 - 01:10 0.92 STWHIP P WEXIT 01 :10 - 03:45 2.58 STWHIP P WEXIT 03:45 - 04:20 0.58 STWHIP P WEXIT 04:20 - 04:50 0.50 STWHIP P WEXIT Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 Description of Operations NU adapter flange and 4-1/16" tree. Tighten flanges. Fluid pack and PT tree to 5000psi. Good test. PJSM on NU 7-1/6" stack NU 7-1/16" BOPE. Notify AOGCC inspector at 20:00 that test will likely occur at 02:00 on 7/31. Continue NU 7-1/16" BOPE, install hydraulic lines, riser. RU IA and OA pressure transducers. Fill stack, install test cap, function test rams & get a good body test. Give notice to AOGCC inspector at 01 :45am. Clean up cellar, pipe shed & rig floor. BOPE test to 300 and 3500psi. AOGCC inspector Lou Grimaldi on site for test. Wait on BPV crew. Safety meeting. RU BPV lubricator. Pull TWC. Safety meeting with slickliners: Pull ball/rod, pull X-lock, drift with dummy whipstock, get corrected TD tag. RU. RIH. Tag rod at 9246' SLM. POOH. Recovered rod. RIH with 3.65" OD GS pulling tool. Tag 2167' SLM. PU and RIH -- fell thru. RIH. Latch X-lock at 9251' SLM. POOH. RIH with 3.685" x 20' dummy whipstock. Sat down 9314' SLM (kinda spongy like high DLS or corkscrewed pipe); work to 9324' SLM, then lost ground. Pulls to 1350# (700# normal up weight). Calculated corrected depths suggest dummy whipstock is stopping within the upper joint of the two full joints below the Baker DB packer. POOH. Break down dummy whipstock from 20' to 10'. RIH. Smooth thru tailpipe. Tag TD 9705' -- a little soft. POOH. RIH with TEL and junk basket. See end of tailpipe at 9380', subtract 12' to correct back to eline depth of 9368'md. RIH and tag PBTD and 9702' corrected. RD Slickline unit. PJSM. Cover pulling CT to rig floor, stabbing injector and re-heading CT. Review Schlumberger written step-by-step procedure for stabbing and unstabbing coil. PU and position injector over well. Pull end of CT to rig floor. Stab injector. Install new Schlumberger dimple connector. Pull test CTC to 3500 Ibs. Re-Head Eline coil. Continue to Re-Head Eline coil. PT CT to 3500psi. Good Test. PU BHA #2 Coiltrack package, Baker 10 setting tool and whipstock. Function test Coiltrack tools, ensure circ sub is open. 2 RA tags included in whipstock. RIH with BHA #2, circ sub open. Slowing down to 20fpm at Xnipples and GLM. Log down with GR from 9520'md. Subtract 12'. RIH, position bottom of whipstock at 9692.5', this puts the top of the whipstock at 9675'md. Orient to 30deg LOHS, close circ sub. Bring on pumps, ramp pressure up to 2800psi, see pressure drop off quickly as setting tool shears. Set down 5,OOOlbs. Top of Whipstock = 9675' Printed: 8/11/2003 11 :01 :37 AM RA tag = 9685' POH. Flag EOP at 9300' MD PJSM for LD whipstock running tools and PU window milling BHA. LD whipstock setting tools. PU window milling BHA. BHA #3. Shallow test MWD. RIH. Correct to 9,300' EOP flag. -12.8' correction. PU=40K, SO=18K. Start displacing to 2% KCI w/1/2 ppb biozan. RIH and tag pinch point dry at 9682'. Slight operpull. PUH. Short in MWD system. Trouble shoot MWD short. POH to change out MWD tool. Trouble shoot short. Found short in lower QC. Replace this and flow sub. RIH. Correct depth at flag (-14'). RIH. Up wt=40K, Dn wt=18K Tag pinch point dry 9679'. 10k OP. Bring pumps to 2.5/1500. RIH stall at 9674' -- ?? -- expected about 9677' or 9678'. PU, OP again, suggesting pinch point. Flag pipe and start easing into it. WEXIT Milling. Freespin= 1480psi @ 2.5bpm. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -30 07 -30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task Code NPT Phase 8/1/2003 04:20 - 04:50 0.50 STWHIP P WEXIT 04:50 - 06:45 1.92 STWHIP P WEXIT 06:45 - 07:30 0.75 STWHIP P WEXIT 07:30 - 08:40 1.17 STWHIP P WEXIT 08:40 - 10:40 2.00 STWHIP P WEXIT 10:40 - 11 :00 0.33 STWHIP P WEXIT 11 :00 - 11 :20 0.33 STWHIP N DFAL WEXIT 11 :20 - 17:00 5.67 STWHIP N DFAL WEXIT 17:00 - 18:15 1.25 STWHIP P WEXIT 18: 15 - 0.00 STWHIP P Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 Description of Operations CT in out Time Depth Prog DH WOB BPM BPM Press 18:17 9675.2' 1 ' 2.9 2.5 2.5 1578 19:15 9675.7' 1.5' 3.4 2.5 2.5 1620 20:08 9676.2' 2.0' 3.8 2.5 2.5 1652 20:40 9676.7' 2.5' 4.9 2.5 2.5 1690 21:30 9677.2' 3.0' 4.6 2.5 2.5 1690 15bbl HiVis Sweep 22:30 9677.7' 3.5' 4.4 2.5 2.5 1695 23:20 9678.2' 4.0' 4.4 2.5 2.5 1670 00:00 9678.7' 4.5' 4.6 2.5 2.5 1680 8/2/2003 00:00 - 04:00 4.00 STWHIP P WEXIT Continue Milling...Freespin = 1480psi at 2.5bpm CT in out Time Depth Prog DH WOB BPM BPM Press 00:00 9678.7' 4.5' 4.6 2.5 2.5 1680 00:45 9679.2' 5.0' 3.9 2.5 2.5 1675 01:30 9679.7' 5.5' 3.9 2.5 2.5 1770 02:21 9680.2' 6.0' 3.6 2.5 2.5 1825 15bbl hivis sweep See increased motor work @ 9680.3', get wt. back this is likely bottom of window. 03:00 9680.7' 6.5' 1.6 2.5 2.5 1700 03:30 9681.2' 7.0' 1.8 2.5 2.5 1720 03:45 9681.7' 7.5' 1.8 2.5 2.5 1750 03:55 9682.2' 8.0' 1.6 2.5 2.5 1700 2' into the OH 04:00 - 05:00 1.00 STWHIP P WEXIT Continue Milling in OH. 1600-1700psi,2.5/2.5bpm, WOB=1.5-1.6, 10-12fph. Mill to 9690.2'md Clean PU off bottom. Send 15bbl HiVis pill around. 05:00 - 07:00 2.00 STWHIP P WEXIT Backream up thru window, no motor work. RIH to 9690' md clean. PU and backream a few more times. Dry tag clean. Printed: 8/11/2003 11 :01 :37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -30 07 -30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 8/2/2003 05:00 - 07:00 2.00 STWHIP P WEXIT Send Flo-Pro mud down hole. 07:00 - 09:00 2.00 STWHIP P WEXIT POOH displacing well to mud. 09:00 - 09:30 0.50 STWHIP P WEXIT LD milling BHA #3. Both mills 3.79" +. Diamond string mill re-runnable. 09:30 - 10:40 1.17 DRILL P PROD1 MU drilling assembly, BHA#4 (1.8 deg motor and 4-1/8" STRWD324). 10:40 - 12:40 2.00 DRILL P PROD1 RIH. Correct depth at flag (-14'). Log tie-in and correct depth another (-1'). RIH with 30L TF. Slight bobble at 9683'. Tag TD 9692'. 12:40 -13:10 0.50 DRILL N DPRB PROD1 Try drilling, TF flopped to 150R. No movement and high current suggests we're in a bind. Will need to orient up in casing. PUH. Orient back to 30L. Unable to get back through window after a dozen attempts, tagging 9682' with clean PU's. Roll pumps at 0.25 BPM and skipped through. RIH with FS 2.7/3080. TF bouncing around off bottom (Apparently with these E-line tools, there is a magnet in the orientor that keeps track of movement. Mag interference right at the whipstock has been seen before. Usually this clears up after drilling a couple of feet). Drill 2.7/3080. It cleared up. 13:10 -15:15 2.08 DRILL P PROD1 Drill 2.7/3080. Found RA at 9679', about 6' shallower than expected. Drill to 9718', stall, aggressive motor work for about one more foot, then lost progress -- 350 psi MW but not getting drill-off. Attempt to get a bite -- seeing up to 600 psi differential, 11 k WOB -- no progress. Take some runs at it, got only one stall. Acts like a balled bit, but the differential is higher than what we typically see with balling conditions. Very high tool vibration. Try changing angle of attack with different TF's. Try feathering into it. Have fought it for over an hour without progress. 15:15 -17:30 2.25 DRILL N DFAL PROD1 POOH. Unable to POOH faster than about 14 FPM in low gear (should be getting 60-70 FPM). Call mechanic while limping out. Stop and flag pipe at 9300' EOP. POOH -- mysteriouly back to the 60 FPM, but it happened a couple more times while POOH. 17:30 - 18:30 1.00 DRILL N DFAL PROD1 LD Drilling assembly, BHA#4. HC STRWD3243 bicenter bit broke, left 4-1/4" long chunk of bit in the hole. (This bit was new when it was picked up and had drilled only 30' before it broke). 18:30 - 19:30 1.00 DRILL N DFAL PROD1 Discuss plan forward with town and slope team. Decide to set a OH Whiptock, aka, aluminum kick-off plug just outside window. 19:30 - 23:00 3.50 DRILL N DFAL PROD1 While headed up (E-line still anchored), redistribute slack back into reel and cut 120' of CT. Re-Head Eline Coil. Pressure test, Pull test good. 23:00 - 23:30 0.50 STKOH N DFAL PROD1 PU BHA #5: 3-1/2" Open hole whipstock on Coiltrak assembly (DGS, EDC, Power/comms, QC) 23:30 - 00:00 0.50 STKOH N DFAL PROD1 RIH with BHA #5, circ sub open. Shallow hole test tools at 1000', failed test, E-line tools not responding. 8/3/2003 00:00 - 03:30 3.50 STKOH N DFAL PROD1 Coiltrak tools not responding, POH and LD Coiltrak. Pulled eline out of the head. Re-Head eline coil. Troubleshoot tools, not responding. RIH past 500' and tool starts to work, should be able to override this. Apparently the override feature at shallow depths above 500' is not working. Printed: 8/11/2003 11 :01 :37 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -30 07 -30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 8 of 13 Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 Fróm - To Hours Task COde·· N PT Description of Operations 8/3/2003 03:30 - 05:00 05:00 - 05: 15 05:15-05:30 1.50 STKOH N 0.25 STKOH N 0.25 STKOH N DFAL PROD1 DFAL PROD1 DFAL PROD1 05:30 - 05:45 0.25 STKOH N DFAL PROD1 05:45 - 07: 15 1.50 STKOH N DFAL PROD1 07: 15 - 07:45 0.50 STKOH N DFAL PROD1 07:45 - 08:25 0.67 STKOH N DFAL PROD1 08:25 - 10:30 2.08 STKOH N DFAL PROD1 10:30 - 13:30 3.00 STKOH N DFAL PROD1 13:30 - 16:45 3.25 DRILL N DFAL PROD1 16:45 - 17:30 0.75 DRILL N DFAL PROD1 17:30 - 19:45 2.25 DRILL N DFAL PROD1 19:45 - 21 :45 2.00 DRILL P PROD1 RIH with BHA#5: 3-1/2" Open hole whipstock. Circ Sub open. Log down from 9520'. Correct depth -14'. RIH clean through window. Log RA at 9680' corrected depth. So, corrected window info: Top of whipstock = 9670' Top of window = 9674' Btm of window = 9680' RA = 9680' RIH thru window, did not see any bobbles near 9683. PU wt=38K Continue to PBTD, tag at 9719'. PU and verify tag. PU again, RIH and position bottom of OH whipstock at 9716'. Close circ sub (EDC). Pressure up to 4000psi and see press fall off as setting tool shears. Set down 2K Lbs, no movement. Top of OH whipstock = 9701 'md POH, flag EOP at 9300'md. Stand back injector head. LD Weatherford setting tool. PU BHA #6: Security 3.75" PDC FM2533R bit, 2 deg bent housing motor, HOT, DGS, DPS, EDC, Power and comms, quick connect. Check coil connector. Lock tight set screws. RIH. Correct depth at flag (-9'). Log tie-in (-3'). RIH. Clean thru window. Tag 9703' dry. Bring pump to 2.5/2900, Set TF at 30R. RIH slowly, saw bump in CTP at 9700', lost it immediately then saw bigger bump at 9702.5', Did not stall. Start time milling here -- shooting for the first couple of feet at 2 FPH. Very quick drill off at each tenth, as expected. Stall at 9,703.1. Time mill to 9704.5', Start some slow controlled drilling, got three quick spikes, heading for stalls, so slowed it down again. TF staying right at 30R. Stall at 9706', stall at 9708', then took off drilling. Drill to 9730' at 60 FPH. Getting aluminum shavings over shaker, plugged MM. Past where anchor would be (9716'), so we know we're sidetracked, but expecting to see higher inclination. POOH at full pump rate. CTP started climbing at around 8500', and lost all returns. No increase in WHP. No change in pulling weight. Choke line plugged somewhere between stack and WHP sensor. Take returns through kill line, Baker choke, and to possum belly. Try to blow debris out with rig air. Then try with test pump, cycling choke line HCR and pressuring up/bleeding choke line. Worked. Then plugged again. Unplug -- lots of aluminum (paper thin pieces averaging about 1/2" square). Because of geometry at window, may have milled-up more of the billet than normal. Finish POOH. Total mud lost to formation due to surface line packoff -15 bbls. Blow down lines again. Safety meeting, PU BHA #7 to C/O bits. DBS bit: Most of gage and shoulder cutters broken (1-6-BT-G). RIH. Correct -18.5 at flag. Correct +5 at the PIP tag, for a total depth correction of -13.5'. Orient highside and shut down pumps as we pass by both whipstocks. Tag bottom at 9731'md. Freespin= 3060 @ 2.7bpm. Drilling at 3250psi 2.7/2.7. Drilling getting a more Grabby near 9750', repeat stalls. Likely into Z3. Printed: 8/11/2003 11 :01 :37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-30 07 -30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 Drill to 9791 'md. DGS sub has stopped sending us useable data. Troubleshoot, decide to POH. POH LD BHA #7 for failed MWD tool. Troubleshoot MWD tools on catwalk. Continue to troubleshoot MWD tools on catwalk. Looks like the DPS sub (DHWOB) is interfering with signal transfer from tool to surface. DPS sub has caused similar problems in Sharjah recently. Test tools on catwalk without the DPS sub, good test. Decide to drop the DPS sub and get back to drilling. DFAL PROD1 PU BHA #8: New Hycalog DSX100 bit, Coiltrak assembly minus the DPS sub, re-run the same Xtreme motor. The used DS100 (SRL#105421) had missing and chipped cutters on pilot and gage, just starting to ring out on the pilot ( 6-4-BT-N). RIH with BHA #8. Tie in to the RA tag, no correction. Drill 18' to 9815'. Survey data coming back nonsense. Troubleshoot Coiltrak tools. Unable to get a good survey. Troubleshoot, first thought was vibration but it looks like the DGS sub is bad. POH for failed Coiltrack tools and plan to swap out DGS sub. LD BHA #8. Bit 7-5 and RO on pilot (after drilling only 25'). Put another DSX100. Swap DGS tools. Keep same 2.0 deg motor. RIH BHA #9. Correct depth at flag (-17'). Tag twice at 9682' with high left TF. Point it straight up. Got through. Prep to log RA -- surface BHI software trouble again. Reboot. Log tie-in -- no correction. RIH smooth thru AI whipstock. Drill. Good ROP, might be through the tough stuff. Drill to 9950'. No good azitmuths yet and lots of vibration. DLS's appear to be less than what we typically get with this motor. Wiper to OH whipstock. Structure may be coming in a little shallow with top of 26N now in the vicinity of 8781'. Also, current projections suggests that we will land between the desired 8775' SSTVD and the hardline 8785' SSTVD. Send logs to town to confirm directional plan forward. Revise desired landing depth to 8770'. POOH for stronger bend motor. LD DSX100 bit (8-5-RO). PU BHA #10: New DPI SRF-533 4-1/8" BC. Adjust motor to 2.7 deg. O-ring damage found in upper quick connect. LD entire BHA to change this 1 foot sub. RIH with BHA #10. Correct to Flag -20. +3' correction at RA tag. Briefly hung up at 9681' wi highside TF, let off injector pressure and skip past. Attempt to capture good surveys off bottom, tool still not producing solid numbers. Inclination looks good but azimuth is questionable. Park and take surveys at 9975, 9945, 9918 and 9875. PROD1 Freespin=2900 @ 2.7bpm. Tag bottom at 9977'md. Drill 3200-3300psi,2.7/2.7bpm. Getting ratty with stalls at 10020'md. PVT=342bbls @21 :00. Seeing some spurt losses at 10057'. DGS sub has given up again. Land well at 8/3/2003 19:45 - 21:45 2.00 DRILL P PROD1 21:45 - 22:15 0.50 DRILL N DFAL PROD1 22:15 - 00:00 1.75 DRILL N DFAL PROD1 00:00 - 00:45 0.75 DRILL N DFAL PROD1 8/4/2003 00:45 - 01 :15 0.50 DRILL N 01 :15 - 03:00 1.75 DRILL N DFAL PROD1 03:00 - 03:30 0.50 DRILL P PROD1 03:30 - 04:15 0.75 DRILL N DFAL PROD1 04:15 - 05:45 1.50 DRILL N DFAL PROD1 05:45 - 07:00 1.25 DRILL N DFAL PROD1 07:00 - 09:30 2.50 DRILL N DFAL PROD1 09:30 - 12:15 2.75 DRILL P PROD1 12:15 - 12:40 0.42 DRILL P PROD1 12:40 - 13:20 0.67 DRILL P PROD1 13:20 - 15:00 1.67 DRILL P PROD1 15:00 - 15:30 0.50 DRILL P PROD1 15:30 -16:15 0.75 DRILL N DFAL PROD1 16:15 - 18:20 2.08 DRILL P PROD1 18:20 - 20:00 1.67 DRILL N DFAL PROD1 20:00 - 21 :25 1.42 DRILL P Description of Operations Printed: 8/11/2003 11:01:37 AM PROD1 10101 'md and pull for motor, near bit inc= 92deg. Both GR and ROP(>100fph) suggest we have landed in the Z2 sand. PROD1 POH to swap motor. PROD1 Unstab, stand back injector. LD BHA #10. DPI BC bit was starting to ring out, missing and chipped cutters on pilot. (nb. The DPI bicenter design is poorly suited to being made up with the Little jerks, the neck is too short and it is easy to damage the bit when being MU or broken out.) PROD1 PU BHA #11: New Hycalog DS 100 (srl#1 05791), New Xtreme motor 2deg, new DGS sub. Changeout o-ring seals on lower QC. (nb. every time we break out the lower and upper disconnect the o-ring seal is cut despite being very careful stabbing.) PROD1 RIH with BHA #11. Correct to Flag -15.7'. Sit down at 9683' wi highside TF, PU and orient to 30R RIH clean. Tie in to RA -1.5'. DFAL PROD1 Get off bottom surveys to compare with our previous survey data. G-total and dip both look believable with this new DGS sub. The new GR tool is showing a baseline shift (-20api or more) from previous tools, calibration issue?? PROD1 Freespin = 2870psi @2.5bpm. Tag bottom at 101 OO'md. Drilling 3300-3500psi, 2.5/2.5bpm, TF=90L, Near bit inc=92deg, Avg ROP=100fph. Drill to 10260'md. A lot less vibration than previous runs -- maybe due to the motor change. Wiper to window Drill to 10410' Wiper to window. Hole in good shape. Continue drilling 70 - 100 FPH. Blew through 26N without seeing change in ROP. Drill to 10560'. Back on plan line. Wiper to window. Drill to 10640', started seeing losses here close to 1.0 BPM. Losses healed to 0.1 BPM within 20 minutes. Did not see any drilling break. Started losing 1.0 BPM again starting at 10680' (maybe bridge broke at the first spot), then gradually saw some healing. Drill to 10700'. Wiper to window. Hole very clean both directions. Check surveys off bottom. Drill 2.7/2.5 at 100 FPH. Very soft. May land a few feet deep. Drill to 10850' Wiper to window. Drill 2.7/2.55 to 10910'. Sand is too soft -- keep dropping. Want to land at 8965' -- project we'll be 85 deg at 8970'. Also, tar in sample at 10850' (8966' SSTVD), so want to get to 8960'. Discuss plan forward Drill ahead 40' with highside TF, now getting expected DL. Continue drilling ahead 2.7/2.66 150'/hr. Drill to 11091 '. Wiper trip. Tight off bottom pulled to 65k. Pulling 38-40k normal. Not able to pull faster than +/-30'/hr. Pulling above window. Checking output at Power Pack unit, stroker for swash plate control had a bad o-ring. Cirulating at 2.5/2.4 8.77/8.92 RIH tie-in at RA tag +12' correction. Drill ahead 2.61/2.54 to 11295'. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-30 07 -30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 hiOUrs Taák Code NPT Phase 8/4/2003 20:00 - 21 :25 1.42 DRILL P 21 :25 - 23:30 23:30 - 00:00 2.08 DRILL P 0.50 DRILL P 8/5/2003 00:00 - 00:30 0.50 DRILL P 00:30 - 02:30 2.00 DRILL P 02:30 - 03:20 0.83 DRILL N 03:20 - 05:00 1.67 DRILL P 05:00 - 05:45 0.75 DRILL P PROD1 05:45 - 07:00 1.25 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 10: 15 2.25 DRILL P PROD1 10:15 -11:00 0.75 DRILL P PROD1 11 :00 - 13:00 2.00 DRILL P PROD1 13:00 - 14:00 1.00 DRILL P PROD1 14:00 - 14:20 0.33 DRILL N DPRB PROD1 14:20 -15:30 1.17 DRILL P PROD1 15:30 - 16:30 1.00 DRILL P PROD1 16:30 - 17:00 0.50 DRILL P PROD1 17:00 - 18:00 1.00 DRILL P PROD1 18:00 - 19:20 1.33 DRILL P PROD1 19:20 - 20:10 0.83 DRILL P PROD1 20:10 - 21:30 1.33 DRILL N RREP PROD1 21 :30 - 22:15 0.75 DRILL P PROD1 22:15 - 00:00 1.75 DRILL P PROD1 Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 DescriptiOn of Operations Printed: 8/11/2003 11:01:37 AM EXPLORATION Operations Summary Report Legal Well Name: 07 -30 Common Well Name: 07-30 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Hours Task Code NPT 8/6/2003 00:00 - 00: 15 0.25 DRILL P 00:15 - 01 :30 1.25 DRILL P 01 :30 - 01 :55 0.42 DRILL P 01 :55 - 02:55 1.00 DRILL P 02:55 - 03:45 0.83 DRILL P 03:45 - 05: 15 1.50 DRILL P 05:15 - 06:30 1.25 DRILL P 06:30 - 07:30 1.00 DRILL P 07:30 - 08:45 1.25 DRILL P 08:45 - 10:45 2.00 DRILL P 10:45-12:15 1.50 DRILL P 12:15 -14:00 1.75 DRILL P 14:00 -16:00 2.00 DRILL P 16:00 - 18:50 2.83 DRILL P 18:50 - 19:30 0.67 DRILL P 19:30 - 19:45 0.25 DRILL P 19:45 - 20:15 0.50 DRILL P 20: 15 - 22:00 1.75 DRILL P 22:00 - 22: 15 0.25 CASE P 22:15 - 22:30 0.25 CASE P 22:30 - 00:00 1.50 CASE P 8/7/2003 00:00 - 02:45 2.75 CASE P Page 11 of 13 Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 COMP COMP COMP COMP 02:45 - 03:00 0.25 CASE P COMP 03:00 - 03:40 0.67 CASE P COMP 03:40 - 05:05 1.42 CASE P COMP 05:05 - 05:25 0.33 CASE P COMP 05:25 - 07:30 2.08 CASE P COMP 07:30 - 08:30 1.00 CASE P COMP Description of Operations Drill ahead f/11295' to 11315'. Wiper trip to window. Good hole condition. Drill ahead f/11315'. 2.68/2.64 FS 3050psi w/ 500 psi motor work. Swapping out mud system. Drilled to 11404'. Having problems getting motor work. Short wiper trip to 11270' Drill ahead f/11404' to 11502' 2.7/2.7 FS 2900psi 3-400psi motor work. Wiper trip to 9730'. 45k off bottom. Hole good on remainder of TOH. Good on TIH. Drill ahead f/11502' to 11600'. Wiper to window. Tie-in. Correct depth (+8.5'). RIH to corrected TD = 11606'. Need a little more pay to meet objectives. Will continue to drill (still have a couple hundred feet of polygon left). Drill 2.6/2.6/2800. Good weight transfer off bottom, but quite a bit of stacking while drilling. Drill to 11750' Wiper to window. Hole is smooth -- just a few bumps in CTP. Drill to 11900' -- end of polygon. Wiper to window. Log tie-in. Correct depth (+6'). RIH clean to TD. Tag corrected TD 11902'. Returns still near 100%. POOH, laying in 25 bbls new mud with 4% lubetex in open hole. Open circ sub above window. POOH to surface pumping at 4.0/3700. RIH to 1030'. (Pump 30 bbls freshwater followed by 30 bbls 50/50 meth.) Displace csg with FW leaving 15 bbls FW and meth in CT. Pull to surface. LID BHA #11 Circulate remaining water from coil with meth leaving only 50/50 meth for reel freeze protect. Cutoff CTC. Install internal grapple and pullback cable. Unstab from injector and secure coil to reel. R/U floor to run liner. PJSM review LL and plan forward to run liner. M/U 27/8" shoe track, 27/8" and 3 3/16" liner. Same time changing out reels to e-line free 2 3/8" coil. Continue M/U of 27/8" and 3 3/16" liner (14k liner wt). Same time changed out to e-line free 2 3/8" coil. Prep coil end with internal grapple and tugger wireline to stab coil into injector. Install hardlines. PJSM. Review plan forward to stab coil to injector. Cross hatch EZ torque lines to injector to stabilize. With wireline tugger bring coil into injector chains. Install Baker CTC. PT hard lines in reel house. Load and pump around coil dart 60.5 bbls. Pull test CTC to 30K and PT to 3500psi. M/U Baker CTLRT to liner. Total liner and running tool length 2584.85' RIH with liner. Wt check at window 50k up. RIH clean. Tag hard 11877', 11887', and TD at 11909'. Confirm tag 11909' Check circulation 1.0/1.0/1580. 54k up. Drop 5/8" ball and displace at 2.5/2.5/2585. Reduce to 0.5 BPM at 40 bbls in. Ball landed at 46 bbls -- shear ball seat at 3900 psi. PUH to breakover -- 29k up -- liner is off. Printed: 8/11/2003 11 :01 :37 AM ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -30 07 -30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT Phase 8/7/2003 08:30 - 10:00 1.50 CASE P COMP 10:00 -11:15 1.25 CEMT N SFAL COMP 11 : 15 - 11:45 0.50 CEMT P COMP 11:45 - 12:30 0.75 CEMT P COMP 12:30 - 13:50 1.33 CEMT P COMP 13:50 - 15:50 2.00 CEMT P COMP 15:50 - 16:30 0.67 CEMT P COMP 16:30 - 20:30 4.00 BOPSURP COMP 20:30 - 21 :00 0.50 EVAL P COMP 21:00-21:10 0.17 EVAL P COMP 21:10-00:00 2.83 EVAL P COMP 8/8/2003 00:00 - 00:30 0.50 EVAL P COMP 00:30 - 01 :40 1.17 EV AL P COMP 01:40 - 03:45 2.08 EVAL P COMP 03:45 - 04: 15 0.50 EVAL P COMP 04: 15 - 04:50 0.58 EVAL P COMP 04:50 - 06:15 1.42 EVAL P COMP 06: 15 - 06:45 0.50 EVAL P COMP 06:45 - 09:00 2.25 EVAL P COMP 09:00 - 09:15 0.25 EVAL P COMP 09: 15 - 09:45 0.50 EVAL P COMP 09:45 -10:15 0.50 EVAL P COMP 10:15-11:15 1.00 PERF P COMP 11: 15 - 11 :45 0.50 EVAL P COMP 11:45-12:15 0.50 PERF P COMP Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 Description of Operations Displace the well to 2% KCL. Final conditions 2.58/2.50/2000. Repair suction valve in pits (lost ability to isolate pit 3). Had to shut down pump to repair. Safety meeting with cementers Finish onloading remaining KCL into pits. Check circulation again. Took about one bbl to catch fluid in coil and a couple more to get returns, so the well is taking some fluid under static conditions. Circ stabilized at 2.17/2.03/1200. Lost 2 bbls in 15 minutes, which is close to what the pumping time will be with cement in OH. Will pump another couple bbls cement. Mix cement. At wt @ 12:30. PT lines to 4000 psi with KCL water. Load coil with 32 bbls Class G cement at 2.00/1.85. Load dart; flush all cement behind inner reel valve with bio water. Pump 0.2 bbls, check dart. Gone. Chase cement at 3.0/2.9 with 50 bbls of KCL water + 2 ppb biozan then back to KCL water. Zero MM out with cement at shoe. Slow down pump to 1.7 BPM at MMin of 58 bbls. PU LWP at 60.4 bbls, shear at 3300 psi. Displace LWP to LC at 2.97/2.81, slowing to 1.0 BPM about one bbl from bumping. Bump at 77.2 bbls (vs 77.3 theoretical), pressure to 1000 psi over. Bleed off. Checks holding. Unsting. Lost 1.2 bbls of fluid to formation with cement in open hole, about half this with cement across 10,640' loss zone. POOH, laying in remaining biowater about 0.6 BPM, pulling 90 FPM -- just enough to keep hole full. LD CTLRT. Perform weekly BOPE pressure test. Witness waived by AOGCC's Chuck Scheve. R/U to run MCNL PJSM review BHA and log source handling precedures and hazards. P/U BHA #12 Continue P/U BHA #12 2615.18' RIH to 9100'. Start logging down with MCNL at 60'/min to 11868 PBTD. Log up laying in 170K LSRV Flo-Pro mud back to 9100'. Cement UTC @ 0300 hrs 2000psi Circulate 9.0 ppg cement water to cuttings tank. Pressure test liner lap to 2000 psi for 30 min. Dropped 50 psi. TOH Safety meeting. Stand back injector, drop ball to open circ sub, standback 41 stands of CSH. Safety meeting: source. LD logging and milling tools. Check to make sure good log data. Safety meeting for perforating. Also, Douglas Stephens gave abbreviated rollout of Peer Review findings and SLB expectations. Download data into logs. Fax to Anchorage. Corrected PBTD = 11867' (Note: LWP sticks above LC 2.5'). Corrected TOL = 9324' MU guns. Printed: 8/11/2003 11 :01 :37 AM of 13 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-30 07-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 7/13/2003 Rig Release: 8/9/2003 Rig Number: N2 Spud Date: 4/29/1988 End: 8/9/2003 Hours Task Code NPT Phase Description of Operations 8/8/2003 12:15 -12:30 12:30 - 14:30 14:30 - 16:30 16:30 - 18:00 COMP COMP COMP COMP 0.25 PERF P 2.00 PERF P 2.00 PERF P 1.50 PERF P 18:00 - 18:45 COMP 0.75 PERF P 18:45 - 20:50 2.08 PERF P COMP 20:50 - 23:30 2.67 PERF P COMP 23:30 - 23:45 0.25 PERF P COMP 23:45 - 00:00 0.25 PERF P COMP 8/9/2003 00:00 - 03:40 3.67 PERF P COMP 03:40 - 03:55 0.25 PERF P COMP 03:55 - 04:15 0.33 WHSUB P COMP 04:15 - 05:30 1.25 WHSUB P COMP 05:30 - 06:30 1.00 RIGD P POST 06:00 - 06:30 0.50 RIGD P POST 06:30 - 08:00 1.50 RIGD P POST 08:00 - 15:00 7.00 RIGD P POST Crew change safety meeting. MU a total of 41 loaded and blank guns. MU 41 stands of CSH. Stab coil. RIH. No bobbles at liner top. Tag TD, PU to breakover 11874'. Correct depth 11867'. Drop 5/8" ball. Circulate to seat. Position guns on depth. With pipe moving up, shear firing head at 3300 psi. Perforate the following intervals with SLB 2.0" HSD 4 SPF Power Jet guns: 11 000' - 11260' 11455' -11670' 11740' - 11860' POOH filling across top of hole. Hold PJSM review procedures for laying down 1 1/4" CSH. LID 82 jts 1 1/4" hydril tubing PJSM review procedures and harzards for laying down perf guns. Clear pipe shed of hydril pipe. LID 41- 2" perf guns. All guns fired. (Placed absorbent material under guns while on pipe rack to drain prior to loadout) PJSM. Review plan forward to FP well and blowdown with N2. Coordinate loading of perf guns. P/U BHA to freeze protect well. RIH to 2000'. Lay-in 30 bbls 50/50 methanol back to surface. RU N2 pumpers. Safety meeting Blow down reel, bleed to pits. Unstab coil. Secure end to reel. Clean pits. Rig down. NU stack. NU and test tree. Release rig 15:00 hrs 8-9-2003. Printed: 8/11/2003 11 :01 :37 AM BP-GDB Baker Hughes INTEQ Survey Report ) ) L' 1 U} Company:. I3P.Amo.co Flttd: . Prµdhoe Bay Site: . . PBÐS 07 Well: 07-30 Wellpatb: 07~30A 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 Dått: 8/27/2003 Time: ·15:48:25 Cò':'ordinåte{~E)~eference: Well:07-3Ö, ,-rue North . Vertical (TV})) R~ference: 43:'304/29/198800:00 65;0 Section (VS) Reference: Well (0;00N,O;00E,297.00Azi) SUrVeyCalcuÜdion Method: Minimur'nCurvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 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: Longitude: North Reference: Grid Convergence: 70 15 49.847 N 148 33 56.934 W True 1.35 deg Well: 07 -30 Slot Name: 30 07 -30 Well Position: +N/-S 2237.57 ft Northing: 5950347.50 ft Latitude: 70 16 11.852 N +E/-W -1446.68 ft Easting : 675883.38 ft Longitude: 148 34 39.047 W Position Uncertainty: 0.00 ft Wellpath: 07-30A 500292178601 Current Datum: 43 : 304/29/1988 00:00 Magnetic Data: 7/23/2003 Field Strength: 57572 nT Vertical Section: Depth From (TVD) ft 38.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 07 -30 9670.00 ft Mean Sea Level 25.66 deg 80.84 deg Direction deg 297.00 Height 65.00 ft Survey Program for Definitive Well path Date: 8/27/2003 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 50.00 9660.65 1 : Schlumberger GCT multishot (50.00-103GIJ:Xrn~ Schlumberger GCT multishot 9670.00 11902.00 MWD (9670.00-11902.00) MWD MWD - Standard Annotation 1\'ID T\'D ft ft 9670.00 8640.31 KOP 11902.00 9007.20 TD Survey: MWD Start Date: 8/6/2003 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Survey MD Inel Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 9660.65 29.17 343.73 8632.14 8567.14 3220.57 -2306.61 5953513.09 673502.29 3517.32 0.00 9670.00 29.15 343.71 8640.31 8575.31 3224.95 -2307.89 5953517.43 673500.91 3520.44 0.24 9702.18 28.81 343.70 8668.46 8603.46 3239.91 -2312.26 5953532.29 673496.19 3531 .13 1.06 9731.97 32.73 343.70 8694.05 8629.05 3254.54 -2316.54 5953546.81 673491.57 3541.58 13.16 9770.06 39.37 343.70 8724.83 8659.83 3276.04 -2322.83 5953568.15 673484.79 3556.94 17.43 9812.83 46.74 343.70 8756.06 8691.06 3304.05 -2331.02 5953595.96 673475.95 3576.96 17.23 9872.17 56.73 340.34 8792.77 8727.77 3348.27 -2345.47 5953639.83 673460.47 3609.91 17.41 9903.19 63.39 340.04 8808.24 8743.24 3373.54 -2354.57 5953664.88 673450.77 3629.49 21.49 9933.14 68.37 337.22 8820.48 8755.48 3398.98 -2364.54 5953690.08 673440.21 3649.93 18.72 9962.58 72.74 329.98 8830.29 8765.29 3423.81 -2376.89 5953714.61 673427.29 3672.20 27.53 9992.44 79.27 326.66 8837.51 8772.51 3448.44 -2392.11 5953738.88 673411.50 3696.94 24.38 10012.40 85.45 324.99 8840.16 8775.16 3464.80 -2403.22 5953754.97 673400.01 3714.27 32.05 ) BP-GDB ) Baker Hughes INTEQ Survey Report L'\ I'Ll) Cömpany; BP Amoco Date: 8/27/2003 Tilne; ·.15:48:25 Fiêld; Prudhoe Bay Co-ordinate(NE) R~fereoce: Well: 07-30, TrUe North Site: . PB DS07 Vertical (TVD) :Reference: 43:30 :4/29/198800:0065:0 Well; 07':30 Section (VS) Reference;; Well (0;00N,0~00E,297;00Azi) Wellpåtb; 07 ~30A Survey CalculationMetbod;· . . Minimürn Curvature Db: Oracle Survey MD loci Azhn TVD SSTVD N/S E1W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/100ft 10042.79 91.81 322.23 8840.88 8775.88 3489.24 -2421.23 5953778.98 673381.43 3741.41 22.81 10071.93 91.20 314.40 8840.12 8775.12 3510.98 -2440.59 5953800.26 673361.57 3768.53 26.94 10100.05 92.95 307.57 8839.10 8774.10 3529.40 -2461.79 5953818.18 673339.95 3795.78 25.06 10136.70 94.79 300.78 8836.62 8771.62 3549.93 -2492.02 5953837.99 673309.25 3832.04 19.15 10170.48 94.83 307.67 8833.79 8768.79 3568.85 -2519.84 5953856.26 673281.00 3865.41 20.33 10200.95 92.30 314.27 8831.89 8766.89 3588.78 -2542.78 5953875.64 673257.60 3894.90 23.16 10234.23 90.55 320.50 8831.06 8766.06 3613.25 -2565.29 5953899.58 673234.52 3926.07 19.44 10270.06 88.49 315.77 8831.36 8766.36 3639.92 -2589.20 5953925.69 673210.00 3959.48 14.40 10311.55 87.92 306.73 8832.66 8767.66 3667.23 -2620.34 5953952.27 673178.23 3999.63 21.82 10337.54 86.61 303.39 8833.90 8768.90 3682.15 -2641.59 5953966.67 673156.64 4025.33 13.79 10373.68 79.95 302.29 8838.13 8773.13 3701.60 -2671.73 5953985.42 673126.06 4061.02 18.67 10410.39 72.24 298.95 8846.95 8781.95 3719.75 -2702.36 5954002.84 673095.02 4096.55 22.78 1 0441 .31 66.82 295.03 8857.76 8792.76 3732.90 -2728.14 5954015.39 673068.93 4125.50 21.17 10473.76 61.04 291.93 8872.02 8807.02 3744.53 -2754.86 5954026.39 673041.96 4154.57 19.77 10512.77 53.37 284.05 8893.16 8828.16 3754.73 -2785.95 5954035.86 673010.63 4186.91 25.96 10546.22 51.81 274.77 8913.50 8848.50 3759.08 -2812.11 5954039.60 672984.38 4212.20 22.51 10578.87 56.47 271.55 8932.63 8867.63 3760.52 -2838.52 5954040.42 672957.95 4236.38 16.36 10603.51 57.86 267.26 8945.99 8880.99 3760.30 -2859.21 5954039.72 672937.27 4254.72 15.68 10631.50 59.06 272.92 8960.64 8895.64 3760.34 -2883.05 5954039.21 672913.43 4275.98 17.76 10681.13 61.82 278.53 8985.14 8920.14 3764.68 -2925.97 5954042.53 672870.42 4316.19 11.29 10710.77 64.56 284.74 8998.52 8933.52 3770.03 -2951.86 5954047.27 672844.42 4341.68 20.86 10783.59 75.42 297.73 9023.49 8958.49 3794.96 -3015.28 5954070.71 672780.44 4409.51 22.41 10806.93 81.28 297.90 9028.20 8963.20 3805.62 -3035.49 5954080.90 672759.99 4432.35 25.12 10835.34 88.04 298.40 9030.85 8965.85 3818.96 -3060.41 5954093.65 672734.76 4460.62 23.86 10904.41 89.17 284.64 9032.54 8967.54 3844.22 -3124.49 5954117.41 672670.11 4529.19 19.98 10932.44 96.08 286.59 9031.25 8966.25 3851.75 -3151.44 5954124.31 672643.00 4556.62 25.61 10976.09 98.86 278.55 9025.57 8960.57 3861.17 -3193.64 5954132.74 672600.59 4598.49 19.34 11008.42 94.22 275.82 9021.89 8956.89 3865.18 -3225.50 5954136.01 672568.65 4628.70 16.62 11044.37 89.66 268.69 9020.67 8955.67 3866.59 -3261.37 5954136.58 672532.76 4661.30 23.53 11078.87 90.03 268.69 9020.76 8955.76 3865.81 -3295.86 5954134.98 672498.30 4691.67 1.07 11106.86 90.76 274.98 9020.57 8955.57 3866.70 -3323.82 5954135.23 672470.33 4716.99 22.62 11135.93 92.88 281.68 9019.65 8954.65 3870.91 -3352.55 5954138.76 672441.51 4744.50 24.16 11166.29 91.81 290.15 9018.40 8953.40 3879.22 -3381.70 5954146.39 672412.18 4774.24 28.10 11237.27 91.32 301.91 9016.46 8951 .46 3910.30 -3445.34 5954175.97 672347.83 4845.06 16.58 11268.96 89.33 299.73 9016.28 8951.28 3926.54 -3472.55 5954191.56 672320.25 4876.68 9.31 11305.81 92.97 292.37 9015.54 8950.54 3942.70 -3505.62 5954206.95 672286.81 4913.48 22.28 11344.16 93.56 287.88 9013.35 8948.35 3955.87 -3541.56 5954219.28 672250.58 4951 .48 11.79 11382.09 93.15 279.33 9011.13 8946.13 3964.77 -3578.33 5954227.32 672213.61 4988.28 22.53 11410.66 91.59 276.07 9009.94 8944.94 3968.59 -3606.61 5954230.48 672185.25 5015.22 12.64 11453.77 92.41 267.00 9008.44 8943.44 3969.75 -3649.64 5954230.63 672142.21 5054.08 21.11 11487.60 90.37 261 .25 9007.62 8942.62 3966.29 -3683.26 5954226.38 672108.68 5082.47 18.03 11 519.55 88.09 265.65 9008.04 8943.04 3962.64 -3714.99 5954222.00 672077.05 5109.09 15.51 11544.83 90.27 271.43 9008.41 8943.41 3962.00 -3740.25 5954220.76 672051.81 5131.30 24.43 11571.82 89.39 275.99 9008.49 8943.49 3963.75 -3767.18 5954221.88 672024.86 5156.08 17.21 11595.04 88.01 272.40 9009.01 8944.01 3965.44 -3790.32 5954223.04 672001.68 5177.48 16.56 11622.33 88.74 272.89 9009.79 8944.79 3966.70 -3817.57 5954223.66 671974.41 5202.33 3.22 11652.07 91.78 279.87 9009.65 8944.65 3970.01 -3847.11 5954226.27 671944.81 5230.14 25.60 11695.01 93.73 289.89 9007.58 8942.58 3981.00 -3888.50 5954236.29 671903.17 5272.02 23.75 11723.39 90.90 293.57 9006.44 8941.44 3991.50 -3914.84 5954246.17 671876.59 5300.25 16.35 11762.58 88.18 304.34 9006.75 8941.75 4010.44 -3949.08 5954264.31 671841.93 5339.35 28.34 11790.83 89.20 309.49 9007.40 8942.40 4027.40 -3971.65 5954280.73 671818.97 5367.16 18.58 11812.96 90.64 314.81 9007.43 8942.43 4042.24 -3988.05 5954295.19 671802.22 5388.52 24.90 11870.10 89.91 326.61 9007.15 8942.15 4086.39 -4024.17 5954338.47 671765.09 5440.74 20.69 COlDp;¡ny:BP Amoco . Fh~ld: Prudhoe Bay Site: PB DS 07 \Veil: . 07~30 Wellpath: 07~30A Survey MD loci ft deg 11902.00 89.91 ) BP-GDB ) Baker Hughes INTEQ Survey Report L:">o. I'LQ Date: 8/27/2003 TiJrie: 15:48:25 Page: 3 Co-ordinate(NE)Reference: W~II;07 ,30; True North Vertical (TV))) R.eferenc~: 43:$04/2911988 ÖC):OO 65.0 Section ('VS) Reference: Well (0:aON,O!00E,297.00Aii) SurveyCalculatioo Method: MinimurriCurvature . Db: Oracle Azim TVD SSTVD deg ft ft 326.61 9007.20 8942.20 N/S E/W MapN MapE ft ft ft ft 4113.02 -4041.72 5954364.69 671746.91 VS DLS ft deg/100ft 5468.47 0.00 I'~..nt Wellp~th: Tie on MD: Rig: Ref. Datum: V.Sectlon Anglo 297.00' ND !lþ15<31 9670<00 KG? ia4220 11902,00 TO 7700 1!!OO 7900 9000 9100 9200 W.llp.lh: (Ol·30107·30Aj Date' 8/2712003 BP I'rq~Qq ... 3:17 PM ~~~&r~~E (ill' fÆ~fÆ~~~fÆ . JtIIASIiA. ORAND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit 07-30A BP Exploration (Alaska) Inc. Permit No: 203-020 Surface Location: 570' SNL, 302' WEL, SEe. 33, TI1N, R14E, UM Bottomhole Location: 3375' NSL, 4040' WEL, SEC. 28, T11N, R14E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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). Sincerely, ~?~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this S!!:- day of February, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. jt.iG,t- z..-/r/"J 1 a. Type of work 0 Drill ORe-Entry 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 675883, Y = 5950348 570' SNL, 302' WEL, SEC. 33, T11 N, R14E, UM At top of productive interval x = 673517, Y = 5953461 2598' NSL, 2587' WEL, SEC. 28, T11 N, R14E, UM At total depth x = 672046, Y = 5954205 3375' NSL, 4040' WEL, SEC. 28, T11 N, R14E, UM 12. Distance to nearest property line 113. Distance to nearest well ADL 028310,1240' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9675' MD Maximum Hole Angle 18. Casin9 Program Specifications $Ize Hole Casino Weiaht Grade CouDlina "'l8x3-3I4' 3-3I16"x2·7/S" 6.2#/6.16# L-80 ST-L _ STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION COM SION PERMIT TO DRILL 20 MC 25.005 II Redrill /' 11 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil ".- o Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB = 65' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028309 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 07·30A / 9. Approximate spud dat~ 02/15/03 ,/ Amount $200,000.00 /. 14. Number of acres in property 15. P~sed depth (MD and TVD) 2560 11500' MD / 8960' TVDss o 17. Anticipated pressure {s~O AAC 25.035 (e) (2)} 91 Maximum surface 2144 psig, At total depth (TVD) 8800' / 3200 psig Setting Depth T()p Botom LenQth MD TVD MD TVD 2175' 9325' 8275' 11500' 8960' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantity of Cement (include staae data) 174 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10350 feet Plugs (measured) true vertical 9246 feet Effective depth: measured 10293 feet Junk (measured) Merla EQ Prong left in hole at about 10258' true vertical 9194 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 110' 20" 3179' 13-3/8" 9545' 9-5/8" 1037' 7" Cemented MD TVD 2892 # Poleset 110' 110' 300 sx CS III, 600 sx Class 'G' 3179' 2984' w/ Top Job of 150 sx CS I 629 sx Class 'G' 9545' 8532' 400 sx Class 'G' 9303' - 10340' 8320' - 9237' Open: 10094' - 10114' Sqzd: 9904' - 9909', 9916' - 9924', 10068' - 10082', 10092' - 10094' true vertical Open: 9016' - 9033' . Sqzd: 8847' - 8851', 8857' - 8864', 8992' - 9005', 9014' - 9016ôKa & .... III Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II HinJl"Q Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer NameINumber: Thomas McCarty, 223-7156 Prepared By NameINumber: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge I / d / Signed Thomas Mccartÿß. _ØµC( ~ .. Con::i:T::~I~~gineer .. Date O!?~ (/> Permit Number 1 API Number 1 APpçova~a~ I See cover letter 20:3'- C> <-G 50- 029-21786-01 >^../') (j '? for other requirements Conditions of Approval: Samples Required 0 Yes 13 No Mud Log Requi ed 0 Yes ~ No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required 181 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU OthEt5Rr&'riÄ~8~Et«é~S"OO pit'. M L. Bill Perforation depth: measured 20. Attachments by order of the commission Date 'Jlçh ~ sJbr:,ll~ Triplicate Approved By Form 10-401 Rev. 12-01-85 . . BP 7 -30A CTD Sidetrack Summary of Operations: / A CTD through tubing lateral is planned for 7-30. The coiled tubing sidetrack, 7-30A, will exit the 7" liner in Zone 4 and target Zone 2 and Zone 1. Prior to CTD sidetracking the well, the tubing patch will be pulled, the liner will be under-reamed, a thru tubing whipstock set and cement will be pumped past the whipstock. The window will be milled with coil time permitting. Approximately 1825' of 4-1/8" x 3-3/4" open hole is planned to access the target. The well will be completed with a solid, cemented liner. Once the liner is in place a memory GR/CCUCNL log will be run and perforations shot. A liner top packer will be run if necessary. / Phase 1: Prep work. Planned for February 7, 2003. 1. MIT of tubing and casing with patch in place is complete, 2. Slickline to pull tubing patch at 2964'. (A tubing patch will be re-run after the sidetrack) 3. Slickline to drift the tubing/casing. 4. Mill XN nipple to 3.8" and under-ream the 7" liner to ensure clean interval for setting whipstock 5. Wireline to set a through tubing retrievable WhiPst0œf:/9675'(8580'TVDSS), 6. Service Coil to cement past whipstock with approx ~bls cement. 7. Mill 3.8" window with coiled tubing if time permits p to the rig arriving Phase 2: Mill window, Drill and Complete sidetrack: Planned for February 15, 2002. Drilling coil will be used to mill the XN and window in the 7" liner if service coil could not mill the window in Phase 1. Drilling coil will then drill and complete the directional hole as per attached plan. Maximum hole angle is Planæe f,91 degrees, The lateral will be completed with a 2 7/8" x 33/16" solid cemented liner. Appro 18 Is of cement will be used for liner. MWD gamma ray will be run in. the open hole, memory GR/ NL will be run in the cased hole. Finally, approximately 500' of ,/ perforations will be shot. Mud Program: · Phase 1: 2% KCI and 2ppb Biozan for milling....-- · Phase 2: Drill with Flo-Pro (8.6 - 8.7 ppg) /' Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject or Pad 3, · All Class I wastes will go to Pad 3 for disposal. Casing Program: ."..- The production liner will be 2 7/8" ST-L solid liner from TD to approx. 10,300' MD, where it will be crossed over to solid 3 3/16" liner. Desired top of 3 3/16" liner will be at approx. 9325'md (8275'TVDss). The top of cement will be left below the top of the liner at 9600' (8515'TVDss) to preserve future sidetrack options out of the 7" liner. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack-off will be pressure tested to 400 psi and to 3500 psi. / · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan, 1825' planned horizontal. Max. planned hole angle is approx. 91 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run, Logging · An MWD Gamma Ray will be run over the entire open hole section. · Memory CNUCCUGR to be run in cased hole. Hazards . . · The most recent H2S test on 07-30 was Oppm on 2/12/01. DS-7 is not considered an H2S pad. . Lost circulation risk is considered medium, Reservoir Pressure Pore pressure is estimated to be 3200 psi at 8800'TVDss (7.0 ppg emw). Maximum surface pressure with gas (0.12 psi/ft) to surface is 2144 psi. / , TREE = WELLHEAD = ACTUA TOR = ~~~,~_~uuu KB. ELEV = BF. ELEV = < " """ n.M'" KOP= . ._. .,._'^.."u.~~,~~, Max Angle = , .~u,,,~~,,,,,,.,,,.u,.,......uu_wuum Datum MD = Datum 1VD = . FMC GEN 4 FMC AXELsON 65' 07-30 1400' 32 @ 6200' ". .... _·,_...u"".,..u. 9925' 8800'SS . 113-3/8" CSG, 68#, K-55, ID =12.415" - 98' ~ 130' ECLIPSE PATCH, ID = 2.246" H 2964' - 2994' I 113-3/8" CSG, 72#, L-80, ID = 12.347" H 3179' ~ I I Minimum ID = 2.246" @ 2964' 30' ECLIPSE PATCH L :8: I TOP OF 7" LNR H ~ 9303' r---.- 4-1/2"lBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" H 9368' 1--, 9-5/8" CSG, 47#, L-80, ID = 8.681" H 9545' t----.iII ÆRFORA TION SUMMARY REF LOG: BHCS ON 05/14/88 ANGLE AT TOP ÆRF: 26 @ 10094' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 1 9904-9909 C 08/26/88 3-3/8" 1 9916-9924 C 08/26/88 3-3/8" 6 10068-10082 C 08/26/88 3-3/8" 6 10092-10112 C 08/26/88 3-3/8" 4 10094-10114 0 12/19/92 I PBTD H 10293' -, 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" H 10340' ~ 10350' DATE 06/22/88 12/11/00 02/13/01 09/11/00 11/18/02 REV BY COMMENTS ORIGINAL COMA..ETION SIS-MD CONVERTED TO CANVAS SIS-MD FINAL RNITP CORRECTIONS CAO/KK SET ECLIPSE PATCH DATE REV BY COMMENTS :8:" ì . I ~OTES: VIDEO LOG INDICATES LARGE HOLES IN LNR@ 9903' and 9905' (05/07195) ~ 2210' 1-14-1/2" CAMCO BAL-O SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD 1VD DEV TYÆ VLV LATCH PORT DATE 1 2957 2794 32 MERLA TG 2 5061 4614 30 MERLA TG 3 6440 5805 32 MERLA TG 4 7515 6741 28 MERLA TG 5 8293 7428 27 MERLA TG 6 8818 7894 30 MERLA TG 7 9128 8167 28 MERLA TG 8 9188 8220 29 MERLA TG 9273' H 9-5/8" X 4-1/2" BAKER DB PKR, ID = 4.75" 9277' H 4-1/2" BAKER SBE, ID = 4.75" 1 . 9356' H 4-1/2" OTIS XN NIP, ID = 3.725" I H 4-112" BAKER SHEA ROUT SUB 1 H 4-1/2" TUBING TAIL I H ELM TT LOGGED 08/06/88 1 9367' 9368' 9368' ~ / 1 10258' - MERLA EO PRONG IN HOLE 1 PRUDHOE BAY UNIT WELL: 07-30 ÆRMIT No: 1880190 API No: 50-029-21786-00 SEC 33, T11 N, R14E, 2685.01' FEL & 2325.58' FNL BP Exploration (Alaska) FMC GEN 4 FMC AX8.S0N 65' 07 -30 A : VIDEO LOG INDICATES LARGE HOLES 9903' and 9905' (05/01/95) Proposed CTD Sidetrack TREE';' W8.LHEAD: ACTUATOR: KB. 8.EV : BF. 8.EV : KOP: Max Angle : Datum MD: Datum TVD : 1400' 32 @ 6200' 9925' 8800' SS 113-3/8" CSG, 68#, K-55, ID:12.415" H 98' p- I 3179' ~ H 113-3/8" CSG, 72#, L-80, ID: 12.347" H Minimum ID = 2.246" @ 2964' 30' ECLIPSE PATCH ~ I g I TOP OF 7" LNR H í 9303' r--. LNF1-f I ¡~-f ~ 14-1/2" TaG-PC, 12,6#, L-80, 0.0152 bpf, ID: 3.958" H 9368' 1--.. 9-5/8" CSG, 47#, L-80, ID: 8.681" H 9545' ~ H I PERFORATION SUMMARY REF LOG: BHCS ON 05/14/88 ANGLE AT TOP PERF: 26@ 10094' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz: DATE 3-3/8" 1 9904-9909 C 08/26/88 3-3/8" 1 9916-9924 C 08/26/88 3-3/8" 6 10068-10082 C 08/26/88 3-3/8" 6 10092-10112 C 08/26/88 3·3/8" 4 10094-10114 I PBTDI-f 10293' 7" LNR, 29#, L·80, 0.0371 bpf, ID: 6.184" H 10340' []§]-f 10350' DATE 06/22/88 12/11/00 02/13/01 09/11/00 11/18/02 REV BY COMMENTS ORIGINAL COMPLETION SIS-MD CONVERTED TO CANVAS SIS-MD FINAL RNITP CORRECTIONS CAO/KK SET ECLIPSE PATCH DATE REV BY . 2210' 1-14-1/2" CAMeO BAL-O SSSV NIP, ID: 3.813" I L - ~ ST 1 2 3 .. 4 5 6 7 8 GAS LIFT MANDRELS MD TVD DEV TYPE VLV LATCH PORT DATE 2957 2794 32 MERLA TG 5061 4614 30 MERLA TG 6440 5805 32 MERLA TG 7515 6741 28 MERLA TG 8293 7428 27 MERLA TG 8818 7894 30 MERLA TG 9128 8167 28 MERLA TG 9188 8220 29 MERLA TG g-{ 9273' H 9-5/8" X 4-1/2" BAKER DB PKR, ID: 4.75" 1 ì I 9277' H 4-1/2" BAKER SBE, ID: 4,75" 1 ----1 9356' 11 4-1/2" OTIS XN NIP, ID: 3.725" 1 I 9367' -f 4-1/2" BAKER SHEAROUT SUB 1 I 9368' H 4-1/2" TUBING TAIL 1 I 9368' l-f 8.M TI LOGGED 08/06/88 I ... H 10258' l-f MERLA EO PRONG IN HOLE COMMENTS PRUDHOE BAY UNIT W8.L: 07-30 PERMIT No: 1880190 API No: 50-029-21786-00 SEe 33, T11N, R14E, 2685.01' F8. & 2325,58' FNL BP Exploration (Alaska) BP Amoco WELLPAtH DeT.AU.$ PtIW#.5 1)7-30A 500292118601 Plmmt Welfpath:: 07~3Ø Tie- Oft MP. tG60;$$ ....' RM, DatUm: v_ - 297AO' 43 ~ 30 4i2$J1H& O(hOO .5.(l0ft ~~.: ~~; ::=;\0 OJ)O 0.00 0.00 REFERENCE INFORMATION Reference; WoII Cenlre: 07·30, True North Reference ~I:.'~ ~~Õ~)eI 43: 30 4129/1988 00:00 65.00 Minimum Curvature 81W11ON DßAII.. "'HI4$: <t-Ef.w :øJ.~ 1:fawe 0;00 0;00 (1,'0 200M ~oo 3.30;00 .00 3$0.00 QO m.ttO 20,00 0'.00- a4,OO @Ai) 20,(10 IDM .ttMW tM.DO 1~;QØ '0,00 12.00- .UO.Of) 1;tAlO $f)i#Q 1a-.OO no.r:ìo Ati TWÐ ttI.11343:.;7.3 B.13 :tUofO 3O.m 341." fØ.Oö :3:37,80 5.MJS 3-'8M 90.-00 31..49: ",,00- 3~1,"fI RP 2:92AW: Ø;95 292..:Sö SO.GO 2$2,$0 fO.U ttl1,JfØ 90.37 2IUJO- 9O.U 21riJ5 VÞ# Taf1\Vt ANNOTA11QN& 1'VO M-Þ Annotation TIP KOP · · · · 1 · · ,. .. .. T. +fi¡·w $Òij¡¡j> "i 8650 U ! 8100 .. > 8750- .. e 8800 ... 8850 _ LEGEND 07-30 (07-30) P!an#5 07"JOA Plan #5 Plan: Plan #5 (07-30/Plan#5 07-30A) Created By: 8rij Potnis Date: 112112003 Azimuths to True North Magnetic North: 26,02' icField 1543nT : 80.81' Date: 1/21/2003 Model: BGGM2002 4400 4300 ~- 4200 4100 4000 i' .. 3900 ì o 3800 .. "I'" - _3700 + - .c: 3600-- 1:: & 3500 ::;;;. ":"3400 .c: .. Š 3300 W 3200 3100 3000 2900- 2800 -4500 -4400 -4300 -4200 -4100·4000 ·3900 -3800 -3700 -3600 -3500 -3400 ·3300 -3200 -31 00 -3000 -2900 ·2800 -2700 -2600 -2500 ·2400 ·2300 -2200 -21 00 -2000 -1900 West(-)/East(+) [100ft/in] 3400 3450 3500 3550 3600 3650 3100 3750 3800 3850 3900 3950 4000 4050 4100 4150 4200 4250 4300 4350 4400 4450 4500 4550 4600 4650 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 5200 5250 5300 Vertical Section at 297.000 [50ft/in] -1t2112-003 . 1 í:15 AM bp ) BP ) Baker Hughes INTEQ Planning Report ...1 "HIS I,N""rEQ .' ',. .. .... ~.. .".~ "_""~" ,.._ ....,~." ,..,..,.__".~,,~ ....,.....'" ....~, H...·._."_. COD1pany: BPAmoco Field: Prudhoe6ay Site: PB DS07 Well: 07~30 Wellpatb: Plan#5 07 -30A _~"" __""M' ~.'""W ...._..~._._,_..."._..___"_~_..._ """_._"_~_,_.___._._~.._._."._".,,.~,,,~,.. _.._,._,_"_._...,,..,._,,_,.._ ~._'~._,_...,_,__ _. _,~._..___......,____".~_, _w..,~_._,,_..,,_". _.M._"_.._.....'".__...._"_,,..._,~~._ ,.._~...._....".. ,..__ _. .'_'~' u ._...~.,..,__~_."_ ,,_~.___ Dâ~e:·....'..·1/21/20q3· ..........,'.... ........ ..Time: ...·.11:15:40 rage:' Co-ordin.ate(NE)'Rerer~nee: 'vvell: 07-30, True North Vertical (TV[)Referenee: System: Mean Sea Level Sectio.n(VS) Referen~e.: Well (O;OON,O .00E,297 .00Azi) ..., ..... ...,_.., _.__ ~~~~~Ç~~~,~!~~~~!~I~~!~,~~:~.c~,_,,_~.i~i"~~~~~.y~~~~~_._,~__ ___.~~~_ _~~~~I_~ ... ..,.' ',.,...- .'.." ....,...". .,.".".._,"'.._"..._........_.".....'_.'.M..'....._"". . -. ",""" ..."....",-...... . 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: Alaska, Zone 4 Well Centre BGGM2002 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: Longitude: North Reference: Grid Convergence: 70 15 49.847 N 148 33 56.934 W True 1,35 deg Well: 07-30 Slot Name: 07-30 Well Position: +N/-S 2237.57 ft Northing: 5950347.50 ft Latitude: +E/-W -1446.68 ft Easting: 675883.38 ft Longitude: Position Uncertainty: 0.00 ft 30 70 16 11.852 N 148 34 39.047 W . ,--.--.-- --'",'-"'--- Wellpath: Plan#507-30A 500292178601 Current I>atum: 43 : 30 4/29/1988 00:00 Magnetic I>ata: 1/21/2003 Field Strength: 57543 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 07-30 9660.65 ft Mean Sea Level 26.02 deg 80.81 deg Direction deg 297.00 Height 65.00 ft Targets Map, Map <-- Latitude --> <:-- Longitude --> Name Desçription TVD +N¡:"S +E/-W Northing ~asting Deg Mi" See peg Min See , ..I.?i.~: Dir; ft ft ft ftft . . .' ,- . "-'" "'--,,,",g,. ....".,_....~.. ..l" .... ""',.' '~"""" ,...."._...~ .'. "~""- ..._.,: ~." ~.,.",..".",'.,.;..',.". ,"..- ".. ..... , "." .". _ . ...._... ,,'. . ..'..'....... '_.,_,_'-.,....~...,.N....,~'..'''__ L.,.~_I.",. . '''~' ..."."... ._-" ..,'..".",," ",., 07 -30A Polygon4.1 0.00 3858.89 -4069.59 5954109.99 671725.00 70 16 49.793 N 148 36 37.575 W -Polygon 1 0.00 3858.89 -4069.59 5954109.99 671725.00 70 16 49.793 N 148 36 37.575 W ·Polygon 2 0.00 4128.02 -4028.29 5954379.99 671759.99 70 16 52.440 N 148 36 36.377 W ·Polygon 3 0.00 4109.90 -3253.45 5954379.99 672534.99 70 16 52.266 N 148 36 13.808 W -Polygon 4 0.00 3763.50 -2556.31 5954049.99 673239.99 70 16 48.861 N 148 35 53.499 W -Polygon 5 0.00 3396.47 -2474.86 5953684.99 673329.99 70 16 45.252 N 148 35 51.124 W -Polygon 6 0.00 3689,62 -3033.20 5953964.99 672764.99 70 16 48.133 N 148 36 7.388 W 07 -30A Fault 1 0.00 3655.71 -4364,43 5953899.99 671435.00 70 16 47.793 N 148 36 46.159 W -Polygon 1 0.00 3655.71 -4364.43 5953899.99 671435.00 70 16 47.793 N 148 36 46.159 W -Polygon 2 0.00 3577.70 -3380.92 5953844.99 672420.00 70 16 47.031 N 148 36 17.514 W -Polygon 3 0.00 3474.31 -3023.22 5953749.99 672779.99 70 16 46.015 N 148 36 7.095 W ·Polygon 4 0.00 3577.70 -3380.92 5953844.99 672420.00 70 16 47.031 N 148 36 17.514 W 07-30A Fault 2 0.00 4661.13 -3725.73 5954919.99 672049.99 70 16 57.685 N 148 36 27.572 W -Polygon 1 0.00 4661.13 -3725.73 5954919.99 672049.99 70 16 57.685 N 148 36 27.572 W -Polygon 2 0.00 4227.71 -3585.81 5954489.99 672199.99 70 16 53.423 N 148 36 23.490 W 07 -30A T5.1 8785.00 3473.81 -2488.05 5953761.99 673315.00 70 16 46.012 N 148 35 51.509 W 07 -30A T5.2 8785.00 3664.30 -2677.67 5953947.99 673121.00 70 16 47.885 N 148 35 57.033 W 07 -30A T 4.4 8960.00 3943.51 -3752.50 5954201.99 672040.00 70 16 50.627 N 148 36 28.341 W I 07-30A T4.3 8965.00 3840.88 -3127.69 5954113.99 672667.00 70 16 49.620 N 148 36 10.142 W bp , BP ') BaJer Hughes INTEQ Planning Report Ie.. Iii.'.'.. BANI ... . ........ . -, ....... IN" fEQ __, ... ..'...." ._ .._,·.........R' .. ."'......_..".".",......."'_.....'..."'_"'~.."."_.",..~"'. ,....." ...._,..... ,,.,_, _..."~"~..~,._,, '''''.'''u''",.,_" . .'. .... ___.""""'R'.' ..,......,.. ._..,. _ ......._.._..'.....,..."..... ___"_""'_ ,....~~,_.__, ~......_"'_'..,. .'.',_" ,~.....,_ ....." ,..,_._.._.,_.....,. ..... ,_.......,,'"..,,~ ~,..~..._..._,_.~_.h..' '. Company: BP Amoco Field: PrudhoeBáy Site: PBDS07 Well: 07..30 Wellpath: Rlan#5 07;;30A .,.' .-.,.,.~--~ ,. ..'.'~.,._--".....'-.....,," ..""..... ...".---...,.,..."....... .....~. ..,..............."......."........ ,.--. .",_..... .--... .- Date:> 1/21/2093 .. .Thne:~11:15:40 Page: 2 Co-ord¡nate(NE)Refe~ençe: WelJ:07-30, True North Veriical(TVD)Reference:. System: Mean. $ea·. Level Section (VS) Reference: Well (0.00N,O.00.E,297.00Azi) .~~~e~.,.c;~I~~~~!i.~~_~!~~;~,~:.__c........_~.~~i~_~~.~~~~~~.~~..."..._......_._..~~.:.. ..~~~,cle Annotation 9660.65 8567.14 TIP 9675.00 8579.67 KOP 9695.00 8597.01 3 9792.46 8670,95 4 9874.46 8723.11 5 10066.33 8785.00 6 10141.33 8785.00 7 10336.33 8785.55 8 10535.01 8852.73 9 10872.92 8964.69 10 11127.92 8962.57 11 11377.92 8960.77 12 11500.00 8959.99 TD Plan: Plan #5 New landing target Principal: Yes Plan Section Information - - - ---. ...---- --- "..... ____.. __n. Date Composed: Version: Tied-to: 1/17/2003 4 From: Definitive Path MD Inel Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft de.9 .··deg ft ;ft ft deg/1?P.~,~~~/_1,?~,d~.~{Iq~~_ deg ~. " .""" ,..".',.u" "..,~.,.__ ; .;,:.",;....'.'i ". 'w . .,¡".'_,,'."',.,"_....~'.._, 9660.65 29.17 343.73 8567.14 3220.57 -2306.61 0.00 0.00 0.00 0.00 9675.00 29.13 343.70 8579.67 3227.28 -2308.57 0.30 -0.28 -0.21 200.06 9695.00 30.70 341.94 8597.01 3236.81 -2311.52 9.00 7.85 -8.81 330.00 9792.46 50.00 337.60 8670.95 3295.55 -2333.67 20.00 19.80 -4.45 350.00 9874.46 51.63 316,49 8723.11 3348.26 -2368.01 20.00 1.98 -25.74 268.90 10066.33 90.00 316.49 8785.00 3477.25 -2490.44 20.00 20.00 0.00 0.00 10141.33 90.00 331.49 8785.00 3537.75 -2534.40 20.00 0.00 20.00 90.00 10336.33 89.69 292.50 8785.55 3665.71 -2676.54 20.00 -0.16 -20.00 269.50 10535.01 49.95 292.50 8852.73 3735.64 -2845.40 20.00 -20.00 0.00 180.00 10872.92 90.50 292,50 8964.69 3854.78 -3133.10 12.00 12.00 0.00 0,00 11127.92 90.43 261,89 8962.57 3886.34 -3383.09 12.00 -0.03 -12.00 270.00 11377.92 90.37 291.90 8960.77 3916.01 -3628.45 12.00 -0.02 12.00 90.00 11500.00 90.36 277.25 8959.99 3946.64 -3746.27 12.00 -0.01 -12.00 270.00 Survey , .-....,~..._--,,_. '...,,"- ." ,.-.....-".......- -. ""~'" . ._.w.__ _....~_._.._. ,_.....___ ~_"._... _.._ '.,_ "'_'_""_'_'~h'" '..,. _,.._.~__. _ _.~_._..__._."__.._.''',,.._,... _"__.._,~_._..,, _~,__,~.~.._.". ,_~.._ ....... .,....". .._,".~..;.."..._."",. '.'.-' MD IncI Azlm SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft degl100ft deg ." ~ .- -.. . ",.." ._-, ."-,-....._.,,._~ . ......, ~ _.~ 9660.65 29.17 343.73 8567.14 3220.57 -2306.61 5953513.09 673502.29 3517.32 0.00 0.00 TIP 9675.00 29.13 343.70 8579.67 3227.28 -2308.57 5953519.75 673500.18 3522.11 0.30 200.06 KOP 9695,00 30.70 341.94 8597.01 3236.81 -2311.52 5953529.20 673497.01 3529.06 9.00 330.00 3 9700.00 31.69 341.61 8601.28 3239.27 -2312.33 5953531.64 673496.14 3530.90 20.00 350.00 MWD 9725.00 36.62 340.19 8621.97 3252.52 -2316.93 5953544.79 673491.23 3541.02 20.00 350.28 MWD 9750.00 41.57 339.08 8641.36 3267.30 -2322.42 5953559.42 673485.39 3552.62 20.00 351.45 MWD 9775.00 46.53 338.16 8659.32 3283.48 -2328.77 5953575.45 673478.68 3565.61 20.00 352.32 MWD 9792.46 50.00 337.60 8670.95 3295,55 -2333.67 5953587.40 673473.49 3575.47 20.00 352.98 4 9800.00 49.99 335.63 8675.79 3300.84 -2335.97 5953592.64 673471.07 3579.91 20.00 268.90 MWD 9825.00 50.18 329.12 8691.84 3317.82 -2344.85 5953609.40 673461.79 3595.53 20.00 270.17 MWD 9850.00 50.74 322.67 8707.77 3333.76 -2355.65 5953625.09 673450.62 3612.40 20.00 274.35 MWD 9874.46 51.63 316.50 8723.11 3348.26 -2368.01 5953639.29 673437.94 3629.98 20.00 278.45 5 9875.00 51.73 316.49 8723.44 3348.56 -2368.30 5953639.59 673437.64 3630.38 19.94 359.78 MWD 9900.00 56.73 316.49 8738.05 3363.27 -2382.26 5953653.97 673423.34 3649.50 20.00 0.00 MWD 9925.00 61.73 316.49 8750.84 3378.85 -2397.04 5953669.19 673408.20 3669.74 20.00 0.00 MWD 9950.00 66.73 316.49 8761.70 3395.17 -2412.54 5953685.15 673392.32 3690.96 20.00 0.00 MWD 9975.00 71.73 316.49 8770.56 3412.12 -2428.62 5953701.72 673375.85 3712.99 20.00 0.00 MWD 10000.00 76.73 316.49 8777.35 3429.57 -2445.18 5953718.77 673358.89 3735.66 20.00 0.00 MWD 10025.00 81_73 316.49 8782.02 3447.37 -2462.08 5953736.18 673341.57 3758.81 20.00 0.00 MWD 10050.00 86.73 316.49 8784.53 3465.41 -2479.20 5953753.81 673324.04 3782.25 20.00 0.00 MWD -, .",,,.,,,,..,..~..-..,._.,,.~-. bp "......,.... -,' ". "". ~... .~.. .', ~'._- ~.'~....,~'... . ) BP ) BaRer Hughes INTEQ Planning Report _... '""'....."'_,.".,,_,·.,...."'~'.:"...h. ....':'" '~'r- --, ~,~..','~'".'.~"..,._..~"...._.'I".--:.'....'. -'.~'~""~," ,..~..,.~.....,. ,. ".....- ..... ,-"'.'~'-"",'~.'~"- .-.... ....._..,-"~,._.':'"._".'._--:":".."._.':':',..'". ,_,~__"."._... - '":"-:_'.. Company: BP Amoco Field: Prudhoe Bay Site: PB D.S07 Well: 07,;,30 Wellpath: Plan#507;';30A Jjate:1121/2003 .... ........ ...Time:11:15:40 i»age: 3 COjOr~¡~ate(NE)~efer~nce: Well: 07-30, Trula North Venical (1'VD) Reference: system: Mean Sea Level Secti()~(VS) R,fi!ference~, .... . Well (0.OON,O.ØQE;297 .00~i) ~~.!:!~~"£~!~~~!!~~~_~.!.!~~~~.,~.;..;._~_i!1i~,~.~:2~~~!y~~., ...... __. ....._.~~~_....P~~~I~,.. _....,.. Survey '''-"' ... ,. .,....,.'.',. ,,.,. ...,... ,,'.-.......,... ." "'-'-..-., ...'~ ...,.,._-" ,.,.'...~, .'...._ 'n".._..."..~~..~..~...._..'_'.....~ ..', .~' 7'.~"""--" ...,." ',." -:.. ..~- ..-... ',~ ._u,.~,.._:.." ..... - ":-...~.....~,._"._..,~~_.~...,~_.-..: ,.~.'.' '''-,..,..... "" ,..-.._." .',".'.. ".___,"" ,..~,.__.....",."~.:,"" _,~" ,..~-':'""_ --:-. '"'...._ _~,_-:_~~,~..~..,..__,......~~.....~. ...._.,'. _~...'_. ..._".._".,....~.~... __.,,_...~....."",_..........'.,_ ",.._".,..~."" ._~'" Tool . - ... ...... ....,_..-.....~~-,~.. MD ft . . " ...".....,'.. '"'~''~''''''''''''' ............ 10066.33 10075.00 10100.00 10125,00 10141.33 10150.00 10175.00 10200.00 10225.00 10250.00 10275.00 10300.00 10325.00 10336.33 10350.00 10375.00 10400.00 10425.00 10450.00 10475.00 10500.00 10525.00 10535.01 10550.00 10575.00 10600.00 10625.00 10650.00 10675.00 10700.00 10725.00 10750.00 10775.00 10800.00 10825.00 10850.00 10872.92 10875.00 10900.00 10925,00 10950.00 10975.00 11000.00 11025.00 11050.00 11075.00 11100.00 11125.00 11127.92 11150.00 11175.00 11200.00 11225.00 lncl Azim , .,_~e.~..__,.._", .~~~,.. 90.00 316.49 90.00 318.23 90.00 323.23 90.00 328.23 90.00 331.49 89.98 89.94 89.90 89.86 89.81 89.78 89.74 89.70 89.69 86.95 81.95 76.95 71.95 66.95 61.95 56.95 51.95 49.95 51.75 54.75 57.75 60.75 63.75 66.75 69.75 72.75 75.75 78.75 81.75 84.75 87.75 90.50 90.50 90.50 90.50 90.49 90.49 90.48 90.47 90,47 90.46 90.44 90.43 90.43 90.43 90.43 90.43 90.42 .,,_....~...,~ ,,'.. ,.,,~ "" "'.'""~" ." .. '~~'.''''''_h';' ......._,,,: ."._,.."......... .~.. ,..10.'_..._" .... ..._......w...,.,." _......~... .Ii. 8AK:.. HUGH.S . " . .. h.. ......~ ~.N"rEQ . ·.n ..."... '''.'~'''_'\ .~,.",__.._ ."..... ,.,," ~_. .._.... ._..~_ ',h "..., _". .'., """'''-' SSTVD N/S E/W MapN M:åpE VS DLS TFO ft ft ft ft ft ft dèg/100ft deg '" ."". 'w·.., ...;~: .' '.."~.,.~,,, "..." ,._ ........ ".','. ~'~";_._""_'" '...............',.. ~",.._,~.,:~,,,..~.._ ." ::....:.....w..J :~.._-L.....,:~L.___',_, ';'J. .:_._.. .."".,._,......~....¡.....:__.'"".. ~_~..J...;";".. "__"..~'........_,:~"......._.... .__, .._..~,._..._._.,. .....:.....,... ..~ _,...; ".'__ .",. _...... w ...~_._~.._... 8785.00 3477.25 -2490.44 5953765.38 673312.53 3797.63 20.00 0.00 8785.00 3483.63 -2496.31 5953771.62 673306.51 3805.76 20.00 90.00 8785.00 3502.97 -2512.13 5953790.59 673290.25 3828.64 20.00 90.00 8785.00 3523.63 -2526.20 5953810.91 673275.69 3850.56 20.00 90.00 8785.00 3537.75 -2534.40 5953824.83 673267.17 3864.27 20.00 90.00 6 MWD MWD MWD 7 329.76 324.76 319.76 314.76 309.76 304.76 299.76 294.76 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.50 292.25 289.25 286.25 283.25 280.25 277.25 274.25 271.25 268.25 265.25 262.25 261.89 264.54 267.54 270.54 273.54 8785.00 8785.01 8785.05 8785.10 8785.17 8785.26 8785.37 8785.49 8785.55 8785.95 8788.37 8792.95 8799.65 8808.42 8819.20 8831.90 8846.43 8852.73 8862.20 8877.16 8891.04 8903.82 8915.46 8925.93 8935.19 8943.23 8950.01 8955.53 8959.76 8962.70 8964.34 8964.69 8964.67 8964.45 8964.23 8964.02 8963.80 8963.59 8963.38 8963.18 8962.98 8962.78 8962.59 8962.57 8962.40 8962.21 8962.03 8961.84 3545.30 3566.32 3586.09 3604.44 3621.25 3636.38 3649.72 3661.17 3665.71 3670.94 3680.46 3689.86 3699.07 3708.02 3716.65 3724.88 3732.67 3735.64 3740.09 3747.75 3755.70 3763.92 3772.39 3781.07 3789.95 3799.01 3808.22 3817.55 '3826.97 3836.47 3846.01 3854.78 3855.57 3864.43 3872.05 3878.41 3883.50 3887.30 3889.80 3891.00 3890.89 3889.47 3886.74 3886.34 3883.73 3882.01 3881.59 3882.48 -2538.65 -2552.17 -2567.47 -2584.43 -2602.92 -2622.81 -2643.95 -2666.16 -2676.54 -2689.17 -2712.15 -2734.85 -2757.09 -2778.71 -2799.55 -2819.43 -2838.22 -2845.40 -2856.14 -2874.65 -2893.85 -2913.70 -2934.14 -2955.11 -2976.56 -2998.43 -3020.66 -3043.18 -3065.94 -3088.88 -3111.92 -3133.10 -3135.02 -3158.39 -3182.20 -3206.37 -3230.85 -3255.55 -3280.42 -3305.39 -3330.39 -3355.34 -3380.19 -3383.09 -3405.01 -3429.94 -3454.94 -3479.92 5953832.28 5953852.98 5953872.38 5953890.33 5953906.70 5953921.37 5953934.21 5953945.13 5953949.43 5953954.36 5953963.34 5953972.20 5953980.89 5953989.34 5953997.48 5954005.24 5954012.58 5954015.39 5954019.58 5954026.81 5954034.31 5954042.07 5954050.05 5954058.24 5954066.62 5954075.16 5954083.85 5954092.64 5954101.54 5954110.49 5954119.50 5954127.77 5954128.51 5954136.82 5954143.88 5954149.67 5954154.19 5954157.41 5954159.33 5954159.95 5954159.25 5954157.25 5954153.95 5954153.47 5954150.36 5954148.05 5954147.05 5954147.36 673262.74 673248.74 673232.99 673215.60 673196.72 673176.48 673155.04 673132.57 673122.08 673109.34 673086.15 673063.23 673040.78 673018.96 672997.93 672977.86 672958,90 672951.65 672940.81 672922.13 672902.75 672882.72 672862.09 672840.92 672819.27 672797.19 672774.76 672752.02 672729.05 672705.90 672682.64 672661.26 672659.33 672635.75 672611.78 672587.46 672562.88 672538.09 672513.17 672488.19 672463.20 672438.29 672413.51 672410.62 672388.77 672363.89 672338.91 672313.92 3871.49 3893.08 3915.68 3939.12 3963.23 3987.83 4012.71 4037.70 4049.01 4062.64 4087.43 4111.93 4135.93 4159.26 4181.74 4203.20 4223.47 4231.21 4242.80 4262.77 4283.49 4304.91 4326.96 4349.59 4372.74 4396.33 4420.32 4444.62 4469.18 4493.93 4518.80 4541.65 4543.72 4568.56 4593.23 4617.66 4641.78 4665.51 4688.81 4711.60 4733.82 4755.41 4776.32 4778.71 4797.06 4818.50 4840.58 4863.24 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 20.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 269.50 MWD 269.50 MWD 269.50 MWD 269.51 MWD 269.52 MWD 269.54 MWD 269.55 MWD 269.57 MWD 269.60 8 180.00 MWD 180.00 MWD 180.00 MWD 180.00 MWD 180.00 MWD 180.00 MWD 180.00 MWD 180.00 MWD 180.00 9 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 360.00 MWD 0.00 MWD 0.00 MWD 0.00 MWD 360.00 MWD 0.00 MWD 0.00 10 270.00 MWD 270.00 MWD 269.97 MWD 269.95 MWD 269.92 MWD 269.89 MWD 269.87 MWD 269.84 MWD 269.82 MWD 269.79 MWD 269.77 MWD 269.75 11 90.00 MWD 90.02 MWD 90.04 MWD 90.06 MWD bp \) BP ) Baker Hughes INTEQ Planning Report INTEQ _.~"..... ."", ......,. ~... ,,~".. ·,,""M~'_"""'_' '....~.....'" "',,' ~.,.... ,.. ,,'~.."._, .._".. ".'." ~"'I' ...,,_ '''''........"..___ ~~, _,,_.., .,_ ".n".__'''''''.' _, _ "~''''''''''~'~'_'_'''.'''''' ..n'_...~,".~..'_"'" ._"..~..."". ,_ w.."..., ~... "._."~.,.". "_~, "" ..".." _.".. ..0. ,,_. ... CQmpany: BPAmoco Field: Prudhoe Bay Site: PBDS 07 Wen: 07-30 Wellpat~: Plan#507-30A Dat~~1121/2003.. .... TÏJne:11:15:40 Page: 4 Co-or(ijl1ate(NE;H~.eferellce: ·wen:O? -~O,T(1Je .North Ve~ti~.I(TVD)Ref'rence: System: Mean SeaLevel Section(V$lRef~re"ce: . Well «()~OON ,0.00E,297.00~i) s~~~Y.".s~~~~~~!:i_~~ ,~~t~~d: Minimum Cu~~~~~~_ ..__...'"_.!?~:_.. Oracle Survey . ".'." ....., ~".,.' ",-..,....- ...... ". .... _..~.."_.,, ~_ ..._ ,~,.,,,.,,",,,, ".,_ .".~".."... .._'N···." ..._ .._.._. . . '." .__.... ,~". ...._,._..... "'_....~...,,'_,... u__ ....~."..~_._, .,. ."""'..'_._'''~''_' _ .......~.__._.~.'"....,~_~~,_.. .,,",~,__"~....._ ."""_~"'''...''''''~_ ...., .'."...~' ."."~~""_'~"'" .._~.._~. _"~.~_.._' ,. ,'_....._..._ MD Incl Aiim SSTVD N/S E1W l\I(apN MapE VS DLS TFO Tool ft deg deg ft ft ft ft . .ft ft degl100ft deg ; "."..."~'-'.' ~...._,.._.~. '-"~".-'" , . -.... - - ... .." ~._.", ... .. '"... J, ;. ~.,..._.L ....,'~., ..,~.'....."........,,' ""~~'.'-". ... . .~.._, ~. ..._,... ."~."".""....,"'~".,.",, .."'~" ~:,~.._'''''~....,'~. ..._ ...u.... ". , .... .., ..... "._,._u ....,.........".....,,_~. .,. ~'_".'" ...', _. 11250.00 90.42 276.54 8961.66 3884.68 -3504.82 5954148.97 672288.98 4886.42 12.00 90.09 MWD 11275.00 90.41 279.54 8961.48 3888.18 -3529.57 5954151.89 672264.15 4910.06 12.00 90.11 MWD 11300.00 90.40 282.54 8961.30 3892.97 -3554.10 5954156.10 672239.51 4934.10 12.00 90.13 MWD 11325.00 90.39 285.54 8961.13 3899.04 -3578.35 5954161.60 672215.13 4958.46 12.00 90.15 MWD 11350,00 90.38 288.54 8960.96 3906.36 -3602.25 5954168.37 672191.07 4983.08 12.00 90.17 MWD 11375.00 90.37 291.54 8960.79 3914.93 -3625.73 5954176.38 672167.39 5007.89 12.00 90.19 MWD 11377,92 90.37 291.90 8960,77 3916.01 -3628.45 5954177.40 672164.65 5010.80 12.00 90.21 12 11400.00 90.37 289.25 8960.63 3923.77 -3649.11 5954184.67 672143.81 5032.74 12.00 270.00 MWD 11425.00 90.37 286.25 8960.47 3931.39 -3672.92 5954191.73 672119.84 5057.41 12.00 269.98 MWD 11450.00 90.37 283.25 8960.31 3937.75 -3697.09 5954197.53 672095.52 5081.83 12.00 269.96 MWD 11475.00 90.37 280.25 8960.15 3942.84 -3721.57 5954202.04 672070.94 5105.95 12.00 269.94 MWD 11500.00 90,36 277.25 8959.99 3946.64 -3746.27 5954205.27 672046.15 5129.69 12.00 269.92 TD All Measurements are from top of Riser 1/30/2003 s.... (]) (J) .- 0::: top of bag ,r -'!!-¡: ?-,', It BAG ~ ~ lL.'" .. bUm of bag middle of slips BI in dISh ears ........................., middle of pipes TOTs 2-3/8" combi ram/slips 1..........················- .---. middle of flow cross Mud Cross Mud Cross '--" '---' middle of blind/shears I 2-3/8" x 3-1/2" VBR pipe rams I 2-3/8" combi ram/slips I'· ......................., TOTs I .' ........................ - middle of pipe/slips ~,.-" '-.. ..~, ¡ ..::1 ,""... "',' . ,~, I Flow Tee P054997 DATE 12/19/2002 CHECK NO. P054997 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 12/19/2002 INV# CK121702F PERMIT TO DRILL FEE .. . f1.- O'll ~ 30 II H RECEIVEr: ,; ,'~~\! 30 2003 Alaska Oil & Gas Cons. Commission Anchorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ -~~~ 05::4 9 97 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT 00.00**10 III 0 5 ... ~ ~ ? III I: 0... i 2 0 iB ~ 5 I: 0 i 2 ? a ~ b III ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new well bore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing. exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY l3/ X WELL NAME J1/1u o'7-30A PROGRAM:Exp _ Dev,~ Redrll ~ Re-Enter _ Serv_ Wellbore seg_ FIELD & POOL r:: 71 t1J .Ç e:. INIT CLASS LJ ~./ / -ó,;-/' GEOL AREA 97 d UNIT# /1 Ç" d d ON/OFF SHORE .£L.,u ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . R N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. W ell located proper distance from drilling unit boundary. . Y N 6. W ell located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N #'4, tJ..· ,I _ 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ¡yr ~ 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . \:II N /I (Service Well Only) 13. Welll?cate~ v:(in ~rea & strata ~uth?riz~ by injection order #_ 'ý,~' /l,,).¡ , (Service Well Only) 14. All wells wlln ~ mile area of review Identified. . . . . . . . . '. ,)/N ENGINEERING 15. Conductor string provided. . .. . . . . . . . . . . . . . . . .V-.-* 16. Surface casing protects all known USDWs. . . . . . . . . -¥--N-- r/ 17. CMT vol adequate to circulate on conductor & surf csg. . . . . -¥-N- N¡k- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . j. N 19. CMT will cover all known productive horizons. . . . . . . .. . N 20. Casing designs adequate for C: T, B& permafrost. . . . . . . . . N,....... '\. 21. Adequate tankage or reserve pit. . . . . . . . . . . . . . . . . _ N Ct t.J U. . 22. If a re-drill, has a 10-403 fo! abandonment been approved., ., -J(¡-];¡ N 23. Adequate wellbore separation proposed.. .'.' . . . . . '.' . . <..:!:' N 24. If diverter required, does 'it meet regulations. .. . . . . .. '.. . ¥-N-' ("II+- /J C 25. Drilling fluid program schema~ic & equip list adequate. . . . . IN. (l/Lovi,L fh1tJ ~ 17. P pcz 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . , N . 2· J h j ..' 27. BOPE press rating appropriate; testto 3500 psig. N me; p -/'-f'-{- f£. II . 28'. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . ~/ ~ '30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y<ÞI/ rilL . (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . .-¥---tr N'I\ GEOLOGY 32. Permit can be issued w/o hydrogen sulfide measures. . . . . Y @ APPR DATE 33. Data presented on potential overpressure zones. . . . . . . . JfY N¡u( ~ ~I / 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . /"""'1" #~ 1/ ~ f_C!."1 35. Seabed condition survey (if off-shore ). . . . . .. ...... 't N ; (Explor to'-ry qñly) 36. Contact name/phone for weekly progress reports. ...... .. N GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RPýÞPc-: APPR DATE W6A- 2-/3Io'~ UIC ENGINEER TEM JDH JBR SFD WGA V/ MJW Rev: 10/15/02 G:\geology\permits\checklist.doc COMMISSIONER: COT DTS O?j01/03 M LB (;:J .2../~.r /" '" .s ( Comments/Instructions: ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to sim'plify finding infomlation, 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. ) ) fjÔ3-ò&d ').. ) I.f 1 -::t' **** REEL HEADER **** MWD 03/12/30 BHI 01 LIS Customer Format Tape 504399 01 ReCEIVED JAN 09 2004 "'IIkIOU6GaarMI,Commilion ~. **** TAPE HEADER **** MWD 03/12/30 3" CTK *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ~Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 9664.0000: STOP.FT 11902.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 33 TOWN.N 11N RANG. 14E PDAT. MSL EPD .F 0 LMF . KB FAPD.F 65 DMF KB EKB . F 65 EDF .F N/A EGL .F 0 CASE.F 9680 OS1 . DIRECTIONAL OS2 . PRESSTEQ I ~Remarks LOG MNEMONICS: GRAX = Gamma Ray APPARENT [MWD], (MWD-API units) ROP = Rate of Penetration, (ft/hour) REMARKS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and Remark File Version 1.000 Extract File: ldwg.las 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. 07-30A Prudhoe Bay 70 deg 16' 11. 852" N 148 deg 34' 39.047" W North Slope Alaska Baker Hughes INTEQ 3" CTK 29-Jul-03 500292178601 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 Other Services Line 2 R~~f\,,:'~ ADVANTAGE ~ 1ace system. ) (5) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) curve supplied by BPX (SWS, 08-08-03). (6) The well was tied into the Gamma Ray log from the 07-30 wellbore at 9488' MD. (7) The open hole sidetrack was made from the original hole 07-30APB1 at 9701' MD (8603' SSTVD). (8) The interval from 11874' MD (8942' SSTVD) to 11902' MD (8942' SSTVD) was not logged due to sensor to bit offset. CURVE SHIFT DATA OBSERVED, ACTUAL, DISPLACEMENT 9677.36, 9676.86, ! -0.494141 9685.01, 9687.73, ! 2.71582 9689.83, 9692.91, ! 3.08691 9706.88, 9707.49, ! 0.617188 9711.07, 9711.57, ! 0.494141 9724.05, 9723.8, -0.24707 9729.11, 9729.11, 0 9755.1, 9756.33, 1.23438 9759.79, 9760.28, 0.494141 9775.11, 9776.71, 1.60449 9785.17, 9786.04, 0.864258 9794.13, 9796.23, 2.09863 9945.95, 9945.83, -0.124023 9950.58, 9950.58, 0 9977.06, 9977.68, 0.617188 10085.3, 10083.1, -2.25488 10095.2, 10093.7, -1.54297 10119.2, 10117 -2.13672 10334.9, 10336 , 1.1875 10350.9, 10349.6, -1.30566 10398.7, 10399.9, 1.1875 10413.8, 10414.4, 0.59375 10415.8, 10416.4, 0.59375 10418.9, 10420.1, 1.18652 10433.7, 10434.9, 1.18652 10436.1, 10436.9, 0.831055 10449.2, 10450.9, 1.66211 10454.8, 10455.6, 0.831055 10460.7, 10461.8, 1.06836 10487.9, 10489.1, 1.18652 10496.6, 10498.4, 1.78125 10502.2, 10503.8, 1.66211 10516.1, 10517.3, 1.18652 10522.4, 10523.8, 1.4248 10531.2, 10534.1, 2.84863 10538.8, 10541.3, 2.49316 10552.9, 10556 , 3.08594 10561.9, 10563.6, 1.66211 10570 , 10572.5, 2.49316 10585.8, 10588.5, 2.6123 10603.1, 10606.1, 2.96777 10623.6, 10626 , 2.37402 10660.9, 10664.5, 3.56055 10665.2, 10669.3, 4.1543 10719.7, 10722.2, 2.49316 10725.7, 10728.9, 3.20508 10744.6, 10747.5, 2.84961 10767.8, 10771.6, 3.79883 10795.6, 10799.1, 3.56055 10814.9, 10817.9, 2.9668 10848, 10851.8, 3.79883 10943.9, 10946.7, 2.73047 10952.8, 10954 , 1.18652 10954.8, 10956.4, 1.66211 11186.2, 11187 , 0.831055 11240.2, 11240.6, 0.356445 11246.8, 11248 , 1.1875 11366.6, 11362.5, -4.03516 11377.7, 11373.7, -4.03613 11386.7, 11382.3, -4.3916 11394 , 11390.8, -3.20508 11397.9, 11396.2, -1.66211 11402.2, 11400 , -2.25488 11505.4, 11504.2, -1.1875 11708.2, 11785.5, 11794 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX 1170, ') 11783.6, 11793.5, -3.08594 -1.89941 -0.474609 ) Tape Sub file: 1 131 records... Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration (Alaska), Inc. 07-30A Prudhoe Bay North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!! !! !!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) curve supplied by BPX (SWS, 08-08-2003). *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAXOl ROPAOl 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 API 4 4 2 ROP MWD 68 1 F/HR 4 4 ------- ) 8 ) Total Data Records: 54 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9664.000000 11902.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 63 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration (Alaska), 07-30A Prudhoe Bay North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!! !! !!!!!! Remark File Version 1.000 This file contains the unedited raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPA GRAX ROPA GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length ) 1 2 68 68 GRAX MWD ROPA MWD Total Data Records: Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units **** FILE TRAILER **** 1 1 API F/HR 54 9664.000000 11902.000000 0.500000 feet Tape Subfile: 3 63 records... Minimum record length: Maximum record length: **** TAPE TRAILER **** MWD 03/12/30 504399 01 **** REEL TRAILER **** MWD 03/12/30 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 54 bytes 4124 bytes 2 records... 132 bytes 132 bytes ) 4 4 4 4 ------- 8 ) ) Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS ) DEPTH 9664.0000 9664.5000 9700.0000 9800.0000 9900.0000 10000.0000 10100.0000 10200.0000 10300.0000 10400.0000 10500.0000 10600.0000 10700.0000 10800.0000 10900.0000 11000.0000 11100.0000 11200.0000 11300.0000 11400.0000 11500.0000 11600.0000 11700.0000 11800.0000 11900.0000 11902.0000 GR -999.2500 20.7500 32.9470 18.3740 25.5399 24.0935 27.0991 24.5014 21.3685 65.8103 28.5857 21.9910 34.0864 32.7769 36.5561 26.2664 41.7692 30.6343 56.5761 62.3795 31.6615 35.1943 47.5889 38.0'100 -999.2500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units } ROP -999.2500 -999.2500 33.3373 19.3421 88.9508 161.2327 117.9573 126.0862 103.6204 74.7732 80.4381 130.8004 86.2659 143.1468 176.6317 147.9996 154.7717 197.4316 179.5336 219.2090 142.2456 1233.7461 164.1942 124.5250 468.2300 -999.2500 9664.000000 11902.000000 0.500000 feet ) ) Tape Subfile 3 is type: LIS DEPTH GRAX ROPA 9664.0000 -999.2500 -999.2500 9664.5000 -999.2500 -999.2500 9700.0000 38.2000 35.1200 9800.0000 19.6900 47.4500 9900.0000 24.6100 87.9200 10000.0000 24.1100 161.3800 10100.0000 22.6900 138.7900 10200.0000 23.6800 126.5800 10300.0000 22.6500 104.6400 10400.0000 Ill. 4600 85.9900 10500.0000 18.3900 100.0000 10600.0000 20.3500 167.4700 10700.0000 28.6600 42.3900 10800.0000 38.6900 135.6700 10900.0000 32.4600 174.1200 11000.0000 24.7100 90.0900 11100.0000 40.4100 141. 3300 11200.0000 28.7300 199.6100 11300.0000 61.2800 180.5500 11400.0000 36.4700 239.2300 11500.0000 29.4700 163.7600 11600.0000 39.2000 15.3800 11700.0000 32.0300 177.0000 11800.0000 36.1500 126.4000 11900.0000 -999.2500 0.4600 11902.0000 -999.2500 909.0000 Tape File Start Depth 9664.000000 Tape File End Depth 11902.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet .. '" ," ,\',i ) Tape Subfile 4 is type: LIS )